Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
206-044
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1J-184 KUPARUK RIV U WSAK 1J-184 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-184 50-029-23305-00-00 206-044-0 W SPT 3334 2060440 1500 375 376 375 375 172 184 184 184 4YRTST P Adam Earl 5/7/2022 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1J-184 Inspection Date: Tubing OA Packer Depth 1060 1980 1960 1955IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509101518 BBL Pumped:2.1 BBL Returned:2 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:30:46 -08'00' /T=164 Regg, James B (CED) PM 7v6m4o From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, May 31, 2019 4:25 PM p�I / To: Regg, James B (CED) k- I �14 f`1 Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv; CPF1&2 Ops Supt Subject: LPP /SSV Returned to Service on CPAI Wells 11-127 and 1J-184 on 5/31/2019 Jim, The low pressure pilots (LPP) on wells 11-127 (PTD #206-047, 206-048, 206-049) and 11-184 (PTD# 206-044, 206-045) were returned to service and removed from the "Facility Defeated Safety Device Log' today, 5/31/2019, as the LPP setpoints were lowered to accommodate sustained low injection pressure in both wells. 1J-127 is currently injecting 824 BWPD at 364 psi wellhead pressure. 11-184 is currently injecting 715 BWPD at 257 psi wellhead pressure. The LPP's on 1J-127 and 1J-184 had been defeated on 5/6/2019 and 4/8/2019, respectively, after the wellhead pressures fell below the LPP setpoint while on injection. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 K�)Ui1J -164 Za60400 Regg, James B (DOA) From: NSK West Salk Prod Engr <n1638@conocophiIlips.com> Sent: Monday, April 8, 2019 11:43 AM�C�,7�4qf To: Regg, James B (DOA) j I i Cc: NSK Optimization Engr; Autry, Sydney; Braun, Michael (Alaska); Sudan, Hari Hara; CPF1 Ops Supv; CPF1&2 Ops Supt; CPF1 DS Lead Techs Subject: Defeated LPP/SSV on CPAI well 1J-184 on 4/8/2019 Jim, The low pressure pilot (LPP) on well 1J-184 (PTD# 206-044, 206-045) was defeated today, 4/8/2019 after the wellhead pressure fell below the LPP setpoint while on injection. The well is currently injecting 960 BWPD and wellhead pressure is 470 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Convert to WAG INJ 0 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Ezploratory❑ 206-044 Stratigraphic ❑ Service Q 6. API Number: 3. Address: P. 0. BOX 100360, Anchorage, Alaska 99510 50-029-23305-00-00 7. Property Designation (Lease Number): e. Well Name and Number: KRU 1J-184 ADL 25662 25661 380058 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): N/A 10. Field/Pool(s): Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17,105 feet Plugs measured none feet true vertical 3,406 feet Junk measured none feet Effective Depth measured 17,020 feet Packer measured 6,730 feet true vertical 3,387 feet true vertical 3,334 feet Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A Conductor 80' 20" 108' 108' Surface 3,949' 13.375" 3977' 2,239' Intermediate 9,247' 9.625" 9,275' 3,424' Liner 8,173' 5.5" 17,105' 3,408' Perforations: Horizontal slotted liner Measured depth: 9,289-17,020 feet True Vertical depth: 3,426-3,387 feet Packers and SSSV (type, measured and true vertical depth) Baker ZXP LinerTop packer 8,730' MD 3,334' TVD SSSV TYPE: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1200 11300 1590 Subsequent to operation: 10 1250 10 11000 11560 14. Attachments (required per 20 AAC 25.070, 25.071, x 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service ❑� Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑� GINJ ❑ SUSP ❑ SPLUG ❑ 17. 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: 318-550 Contact Name: Sydney Autry Authorized Name: Sydney Autry Authorized Title: Sr. Petroleum Engineer Contact Email: sydney.autry@cop.Com Authorized Signature: Date: 2/ V /-W Lq Contact Phone: 907-265-6813 117-L- 31111 91 R MSt FEB 2 51019 Form 30-404 Revised 4/2017 Submit Original Only IJ -184 CONVERT TO WAG Date Event 01/24/2019 PUMP 1,5 BBSL METH DWN WTR INJ LINE 1.5 BBLS METH DWN TBG & 50 BBLS DSL DWN TBG FOR FREEZE PROTECT. "JOB COMPLETE" 01/29/2019 Begin MI injection 1J-184 ConocoPhillips eB Attributes Max Angie Sk M TD Alaska. I c.S WeIIWre APIIVWI Fleb Name WeIlE0re51alus her ID MD(M1NBI ACI BIm IXK81 500292330500 WEST SAK INJ 1].8]0.0 KBGMtM) Pig RelNea Oale 31.51 5/2542006 Comment HES(ppm1 Gale SSSAA NIPPLE AnnWNion Entl pate Ed10412015 lAwpMLmmeh-ua..n..asul 1249EOPM 0 aeMl Anndi Depth (XKB) EM ONe Am,NYbn Last Mad By EnE Gate - -"'-- "- ..................... _. LEN Tag'. Fav Reason', PULL DH CHOKE W/3.W N0GO I ppmven 11/131201] ....... HANGER, 227...... . Dashing bunni casing De:cupuon oD (in) IDpn) rapinrc3 Set Cepa IN H8) sit lMpm (T ropded wuL94l06 Hto EAD 1080 C0NDDCTORInsulate0 20 19.124 30.0 10) 11180 9400 H-40 opium oD(in) IB 111 TaP IXKBI Se10.gIn BN OepIh WVLen (00 Grafi TBP Tn,ead 2(TWER.23L. 3.97 SURFACE 13318 12.015 30.2 3.98) 22390 8800( BTC SURFACE Gazing OD (in) ID her iop IXK27 Set Depth bet 0eptl, Th,eaO WVL40 400 3krail-.4242 4000 L-80 BT MEDIATE 9.27 BTC INTERMEDIATE 95/8 0.835 Gues Gazing DescNptien OD (In) )Din) Top8827 Sel OeplM1 (XKB) Set Depth NDj... WVLen (I.. G,atle Top TM1reaO Eff (OKIS) (WE, CONDUCTOR ImW1ed DLINER HH 51/2 4.950 802J0 9.0939 3,3963 1550 less 1080 Liner Details Nominal ID NIPPLE i 4781 Toppi TopIN011NNB1 1.1mll°I IIem DO Ch. n) 8.027.0 3.350.5 80.23 HANGER Hook Hanger (outside casing) 1740 81848.0 3,354.1 80.25 HANGER Hook Hanger (Inside casing) 5020 GAB LIFT, ?cam 8,854.3 3.3552 00,24 XO BUSHING Crossoyer Bushing 5000 8.90).3 3.364.3 ]9.99 ECP BAKER PAYZONE EXTERNAL CASING PACKER 4.910 9,019.5 3.3038 00.15 XO Reducing CROSSOVER 55x45" 3.960 9,064.4 3,3914 00.30 BENTJ, 3.940 SURFACESIS W70 Oased 0Oorplion GO On) I011nl Tap (ryN0) Bet`OGEUUBISel Depm(NDS.. V Umff-.rGrade Topwtl Thr B BAND SLOTTED 51/2 4950 0,8329 1].105.0 3,405.6 1550b00 Hy0n1521 SLEEVE. a,7D2.0 LINER Liner Details mina110 Top )XKB rop WO) Top Incl8 1KE Des Com IIn) Run TA88 8.932.9 3,368.8 ]9.8] PACKER HRD ZAP LT Packer 1500 SEAL ASSY. B 7w+ 8.9514 33]2.0 ]9.84 NIPPLE RB Rackoff Beal Nipple 6220 Q954.3 3,372.5 ]9.05 HANGER FlexLock Liner Hanger 6.230 8,963.3 3,374.1 79.90 SBE 19047 Casing seal Bore 4.750 1),030.1 3,389.7 79.13 Swell Packer Swell PackerwNAM Connections 3950 Casing 0iecriplion OD IIn) Off') Too NISI $el OeplM1 InNB) Sm Oeptn (TVD)._ WVLen (I... Gea]e top Trued O LINER LEM 41/2 3.950 8,]302 8.9736 33]5.9 12IS L-80 IBT Liner Details Nommen. Top lnn0l Top(ND)(nNB) Top incl(') 11am Des comp (In) 81 3,333.9 ]9.]1 PACKER SLOOP LINER TOP PACKER 4890 8.751.3 3,33].] 80.06 XO BUSHING CROSSOVER BUSHING 4890 8,]52] 3,337.9 80.08 SBR 19047 CASING SEAL B0RE RECEPTACLE 4.750 PACNER dddm. 8,7724 3,341.3 80.20 XO BUSHING CROSSOVER BUSHING 3.930 8,814.3 3,348.4 80.23 HANGER LEM ABOVE HOOK HANGER 3.930 8,822.1 3,349.7 80.23 HANGER LEM INSIDE HOOK HANGER Sum 8,832.1 3359.9 80.11 NIPPLE CAMCO DB NIPPLE 3.562 8,9]0.4 3,3753 79.93 SEAL ASSY BAKER SEAL ASSEMBLY 3.900 SEAL PSSYi a, 910 Tubing Strings D LINER LEM, a,'/30.1dATaU Tubing CeYnpliOn Smng (in) Top(XKB) SO Depth (X. SO Depth (ND) (... W1(INTO Grade Top Con nxlion d-1/2C0MPLETI0N 4V2 3.95s 00 6]605 334U6 126o L-80 )BTM 2015 RAD Com letion nBt211e ..;` D LINER HH;8027.0�90939I Ix Tope(i Top(TVD) B Topincl(') Re.M Com Nomura lD It,) 22,7 221 0.08 HANGER VW. Gray 13-518 X 103/4 Fab. TBG hanger bawl w/ 10� 4.500 314 x4-112 TBG hangerw14.909' MCA top threads and 4 INTERMEOIATE; 2>I�9$)50 -10! IBM voi threads. 478.4 4783 330 NIPPLE CaInCo 4-112'DB-6 Nipple with 3.875"NOGOProfie SN- 3.785 N15NiD94 (PULLED 11/9201].50' CHOKE W/ 3 80" NOGG 127" OAL)) 8,702.0 3.3288 7925 SLEEVE Baker4-12"CMUSliding Sleeve W13.81V'XProflle- 3813 Pan in Closed Position 6.)50.1 333].5 8004 SEAL ASSY Baker 19047 20 IT Seal assembly with 4-R spaceout 3.640 Other In Hole (Illireline, retrievable plugs, valves, pumps, fish, etc.) Top(Np Top Incl Top (IIKB mKB Co. Ron DNe ID (in) 8,9.40 3.360.2 ]9.99 PACKER D -SAND BAKER PAY2ONE CASING PACHER 5/222006 4910 (PUSHED DOWNHOLE FROM ORIGINAL LEM) 6,9]30 3,3)58 1994 SEALASSY D SAND BAKER SEALASSEMBLY(FROM 5/23/2006 3.900 ORIGINAL LEM) r Perforations & Sbfs sem r Den Top(NO) Tem(ND) "umsyr sm)5:9298617.02d Top(XNa) Farm (NON) MKS) (XKB) Line D. 0 Type coin 9289.0 17,0200 34252 3,387.8 WSB,WSC, 54112006 320 SL0TS smating Add Aofetl WS B, 1J-180 Alpe B blankpMS slotted ts: 0,125"x2 0.125"x "x32Ifflabl the 32 spl (� 4 adjacent rowg NINE. Centers Seaters re staggered 18 Seat.ends . non 3flry ends Mandml Inserts SI Ni N Top(ftKBI Top IND) (XKB) Make Mi ODlinl Berw VNwe Type Larc Type pori Type Blm (in) ied (psi) T(psi) Ran Osie Com 2,120 i767, CamCo KBMG t GAB LIFT CRAY BK 0000 OO N192015 BSANDS OTTEOUNB; a9e2ti ✓ KUP INJ 1J-184 ConocoPhillips "' a aaska.lDC. MmPM LouMY na.lao. nn4rzD1] ¢49s PM vamv k mo enera a e Eaa nolo Ae�memo 5/242006 NOTE'. CANNOT ENTER Li LATERAL 5/242006 NOTE'. MULTI -I ATERAL WELLo 11184(13 -SAND). 1J-18411 (D -SAND) 1/12009 NOTE: VIEW SCNEMATICW/Kaska SThemal:CD OREV CONDUCTOR ImWtta: SO G. 1050 N IPPLE.178d OFSLIFT:2,14]0 SLI IF CE, 30239T0 SLEEVE: EM0 SFX PSSY', 615501 PACKER:8W10 SEK PSSY, a 960 D LINER LEN: 81. 1.9]&8 D LINER XX: ENDO -9.013 9 INTERMEDIATE: 274 -9,275,0 - 4A,2]5USm]S:9MO11.020.0 SLOTS. 9 MO 17.020 0 SSANDSLOT ED LINER: Rllll]105a� MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,May 14,2018 P.I.Supervisor ,'? A li_xt I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1J-184 FROM: Lou Laubenstein KUPARUK RIV U WSAK 1J-184 Petroleum Inspector Src: Inspector Reviewed By: ..r P.I.Supry J1Z_ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK IJ-184 API Well Number 50-029-23305-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-044-0 Inspection Date: 5/9/2018 Insp Num: mitLOL180510145646 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1J-184 Type Inj W 'TVD 3334 ' Tubing I 594 - 595 - 594 - 594 - r PTD 2060440 Type Test SPT Test psi 1500 IA 1100 • 1800 1780 - 1775 - BBL Pumped: L 3.5 BBL Returned: j L6 OA j 169 179. 179- 179 Interval r 4YRTST P/F P Notes: scANNED R JUN 042018 Monday,May 14,2018 Page 1 of 1 r1) . . a) T Q - ori E > t 0 CD 7 p a N p (" t. 1 a ; a s o ro D cel � �Y Y - "00 cu `° 0 h r U N '8 ". >IIQc r o +N+ 41O C C 03 C 6 a -- 03 d a o _c o a) >` 3 Q ❑ Q n n n n n n n N p Cr m < k p > > > > > > > > > > > E +' t -Up o �- n O O O O O O O O O O O L. +-, i N 1.4.1Z Z Z Z Z Z Z Z Z Z Z w E L N 2 0 N M 4 to n c41) O) r T r N A COto u -E L C N Z ❑ U -0 n3 o u I- cc + C ns U ` 00000000000 C v v N i a J J J J J J J J J J J b0 C w, 0 y W W W W W W W W W W W N v •C F- LL LL LL LL LL LL LL LL LL LL LL ., a) a) a) Q J J J J J J J J J J J ,, C', 1- Q Q Q Q Q Q Q Q Q Q Q a) 0 C 4_ `= G p; Q Z Z Z Z Z Z Z Z Z Z Z U @ a) p , O ° LL LL LL LL LL LL LL LL LL LL LL CC E' > '- U > - a) * N' O oC E U C Z; Q u U a) CIO U s`o. O 0 o G G I-- f0 a) U u t c C O V - ~ > 000 a o 0 RS t-) 7 Q a) a N C a LL N4 a [�, O ❑ 't 't C -JOOOOLLOO Qi arc Baa = ° aaaaceaa 7.1 u Fcc a a Cr m U r J M (a co .0 Kr N d AS O • r z *tet xW 0 lJ ~> 0 0 to O. J J J J J J J J J J -I z -1 W233333333333 4 ,oomW � 01 1 I 1 I 1.111 I ce ce re Ce CL CC BY CL OC CC Ce 2C W W W W W W W W W W W LJJ > > > > > > > > > > > 2reccreccreccreccwecce Z Y Y Y Y Y Y Y Y Y Y Y > > > > > > > ❑ > > > In . 12, CLCCCCCLIYWCCI:CCLCLCC i 2.4) ti W Q Q Q Q Q Q Q Q Q Q Q /e� LL a a a a a a a a a a a 0 0 13 > > > > > > > > > > > (0 O. Y Y Y Y Y Y Y Y Y Y Y O 0, C1.0 O 11.1 r..- ( w n co v u� a, r N M o a in X n v� O o o n n o <- v r v Cr O K o 0 0 0 0 r r o r .-- o w co CV U p o • 0 0 0 0 0 0 0 o 0 o w V o 0 0 0 o O o o O o O U.) V) N n n -) r 1.-- -) co > 1]� � -) o 0 ) co Co co ) 0 00 W r- > > > N N ❑ 2 2 rL 7 2 E Q c LU X a C Lu - u O (73Y N O O O r 0 0 0 0 0 0 Jd O (a w O f0 O O t0 0 0 0 0 0 0 N Q Cr t0 r t0 M t0 00 1n N r .77 vi M r W 00 N 0 n 0 0 In ( I I I I I I - a [+') r N in N N M N M N M N I N .:(1 N N cc-,e) (c...:, N N N N N N E I::: T T M a) a) O O 0) a) TC _c R NNNONN NNNNN ( O 0 Q1 O O O o O o O O O 0 L O U O O O O O o O O O O Oy,+ M C O a-0 C if) u) u) )n Un In in N N U) U) ❑. 'O O C aa w •r0 'a/ d U U Z 0)o a, 0A a OD Lu cc h .Q N N ca H al O O N r' N N p co N a) C Y Y a) y m m r r r M r r ,- r r !•' 4) N 41 ‘,,,(') C O_ Q N a- W N W ,- a'- e- N r r N Z u, O O 0 CO o Ql It a a h-0 0- F- • • & ( �."-=I e4,- PTA, Z,O Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Wednesday,June 7, 2017 5:34 PM To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Sullivan, Michael; Krysinski, Marina L; Targac, Gary; Effiong, Michael; Stanley, Scott M Subject: LPP/SSV returned to service on 1J-184 on 06/07/2017 Jim, The low pressure pilot(LPP) on well 1J-184 (PTD#206-044, 206-045)was returned to service and removed from the safety defeat log on 06/07/2017, after a downhole choke was installed in the well to maintain wellhead injection pressure above the low pressure pit set point. The well is currently injecting at approximately 1340 BWPD with a wellhead injection pressure of 654 psi The LPP had been defeated on 03/05/2017. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Pager: 1 907 659-7000 pg. #497 Email: n1638(a�conocophillips.com sump JUL17 2017 • • �� � ,4 Regg, James B (DOA) 2,60:44-e, From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, March 05, 2017 8:23 PM -Clzt- '5(6117 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Stanley, Scott M; Sullivan, Michael; Krysinski, Marina L;Targac, Gary; Stanley, Scott M; Effiong, Michael Subject: Defeated LPP/SSV on CPAI well 1J-184: 03/05/2017 Jim, The low pressure pilot(LPP) on well 1J-184 (PTD#206-044, 206-045) was defeated today, 03/05/2017, after the well was restarted. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 1345 BWPD at a wellhead injection pressure of 48 psig. The AOGCC will be notified when the injection pressure has increased to above 500 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Thank you. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Mobile: 1 713 632-4851 Pager: 1 907 659-7000 pg. #497 Email: n1638conocophillips.com SCANNED MAY p. 201? 2.060441 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday, February 16, 2017 8:52 PM C''//lit lit 7 To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Stanley, Scott M; Sullivan, Michael; Krysinski, Marina L; Targac, Gary; Effiong, Michael Subject: LPP/SSV returned to service on 1J-184: 2/14/17 Jim, v The low pressure pilot(LPP) on well 1J-184(PTD#206-044, 206-045)was returned to service and removed from the safety defeat log on 02/14/2017, after the well was shut-in. The LPP had originally been defeated since 01/06/2017. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kind Regards, Scott Stanley / Michael Effiong West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234f `'"1�' ��� t car Pager: (907) 659-7000 #497 s • n1638@conocophillips.com 1 nr6 2-06044o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday,January 06, 2017 9:44 PM \c---(7(1 � I l/I 7 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Krysinski, Marina L; CPF1&2 Ops Supt Subject: Defeated LPP/SSV on CPAI well 1J-184 Jim, The low pressure pilot(LPP) on well 1J-184 (PTD#206-04 206-045)was defeated today, 01/06/2017, after the well head injection pressure fell below 50 psig. and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 1344_ BWPD at a wellhead injection pressure of 78 psig. The AOGCC will be notified when the injection pressure has increased to above 500 p ig and the LPP/SSV function is returned to normal, in accordance 3' with "Administrative Approval No. CO 4066.001."� Please let me know if you have any questions. Thank you. Best regards, Michael Effiong (Alternate: Scott Stanley) West Sak Production Engineer ConocoPhillips Alaska Inc. Office: 1 907 659-7234 Mobile: 1 713 632-4851 SCANNED MAY I 12 i7 Pager: 1 907 659-7000 pg. #497 Email: n1638 c(Dconocophillips.com 1 • • KK'(fl j eViv Regg, James B (DOA) I �Ll(Oo From: Haakinson, David <David.Haakinson@conocophillips.com> �' Sent: Monday, January 11, 2016 12:02 PM �P � 1 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Optimization Engr; CPF1&2 Ops Supt;Jensen, Marc D; Stanley, Scott M; Sullivan, Michael; Braden,John C; Targac, Gary; Hall, Tyler A Subject: LPP/SSV returned to service on 1J-184: 1/10/16 Jim, The low pressure pilot(LPP) on injector 1J-184(PTD#206-044 206-045)was returned to service and removed from the safety defeat log on January 10, 2016, a era ownhole choke was installed in the well. The wellhead pressure continues to increase, and the downhole choke will be removed once wellhead pressure is projected to be above 500 psi without it. This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Sorry for the mistake on PTD numbers. Regards, David Haakinson / Tyler Hall West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SCANNED 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,December 03,2015 TO: Jim Regg Fer (q 4�i P.1.Supervisor `'� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-184 FROM: Matt Herrera KUPARUK RIV U WSAK 1J-184 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry - NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 13-184 API Well Number 50-029-23305-00-00 Inspector Name: Matt Herrera Permit Number: 206-044-0 Inspection Date: 11/29/2015 Insp Num: mitMFH151130101441 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1J-184 Type Inj W'TVD 3334 Tubing 275 - 275 276 - 277 - PTD 2060440 - Type Test SPT Test psi 1500 IA 1123 1805 1789 - 1787 - Interval INITAL P/F P ,/ OA 163 217 • 177 169 - Notes: IA tested to 1800 PSI per CPAI Rep - scoop SEP 16 2016. Thursday,December 03,2015 Page 1 of 1 . STATE OF ALASKA • SKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing F Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well F Re-enter Susp Well r r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206-044 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23305-00 7.Property Designation(Lease Number): 8.Well Name and Number: AD,25562,25661,380058 KRU 1J-184 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 17870 feet Plugs(measured) None true vertical 3751 feet Junk(measured) None Effective Depth measured 17105 feet Packer(measured) 8907 true vertical 3408 feet (true vertical) 3364 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN: 78 20 108 108 0 0 SURFACE 3947 13.375 3977 2239 0 0 INTERMEDIATE 9248 9.625 9275 3424 0 0 B SAND SLOTTEI 8172 5.5 17105 3406 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9289-17020w t et " 0, True Vertical Depth: 3426-3388 48( a; ,t kt. Or:-.C. {(fig 2315 a Tubing(size,grade,MD,and TVD) 4.5, L-80,8768=MD,3341=TVD 0 C4 r A Packers&SSSV(type,MD,and ND) HRD ZXP Liner Top Packer 8932=MD 3369=TVD,SLZXP Liner Top Packer 8730=MD 3334=TVD,D-Sand Baker Payzone Casing Packer 8907=MD 3364=TVD NIPPLE-Cameo"DB-6"Nipple w/No-Go Profile @ 478 MD and 478 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development r Service F Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas rWDSPL I-- Printed Printed and Electronic Fracture Stimulation Data r GSTOR IT WINJ r WAG 1 GINJ IT SUSP IT 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: 315-643 Contact Danny Kaneta'�.265-6048 Email Danny.Kane anconocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer Signature Phone:265-6048 Date gr Form 10-404 Revised 5/2015 147-1— /4�fiz RBDMS uLL, 0 2 1015 Submit Original Only 1/G . KUP dip 1J-184 ConocoPhilhps Well Attrib s Max Angle&MD TD Alaska Iflt Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) COnOCCYttillips 1 500292330500 WEST SAK INJ 17,870.0 r... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple Laterals-1J-184,12/1/2015 2;51;52 PM SSSV:NIPPLE Last WO: 10/31/2015 31.51 5/25/2006 Vertical salemabc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WORKOVER,GLV C/O lehallf 11/18/2015 HANGER;22.7 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR Insulated 20 19.124 30.0 108.0 108.0 94.00 0-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ' L] I �"`'SURFACE 13 3/8 12.415 30.2 3,977.0 2,239.0 68.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread a INTERMEDIATE 9 5/8 8.835 27.4 9,275.0 3,424.2 40.00 L-80 BTC , CONDUCTOR Insulated;30.0. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD).. Wt/Len(I Grade Top Thread 108.o D LINER HH 5 1/2 4.950 8,827.0 9,093.9 3,396.3 15.50 Liner Details NIPPLE,478.4 ..-: Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) it €€ 8,827.0 3,350.5 80.23 HANGER Hook Hanger(outside casing) 7.740 GAS LIFT;2,147.0 8,848.0 3,354.1 80.25 HANGER Hook Hanger(inside casing) 5.020 8,854.3 3,355.2 80.24 XO BUSHING Crossover Bushing 5.000 8,907.3 3,364.3 79.99 ECP BAKER PAYZONE EXTERNAL CASING PACKER 4.910 • • 9,019.5 3,383.8 80.15 XO Reducing CROSSOVER 5.5x4.5" 3.960 SURFACE;30.2-3,977.0 9,064.4 3,391.4 80.38 BENT JT 3.940 SLEEVE;8,702.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread B SAND SLOTTED 5 1/2 4.950 8,932.9 17,105.0 3,405.6 15.50 L-80 Hydril 521 LINER , Liner Details El' Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Corn (in) SEAL ASSY.8.75o 1 i 8,932.9 3,368.8 79.87 PACKER HRD ZXP LT Packer 7.500 al 8,951.4 3,372.0 79.84'NIPPLE RS Packoff Seal Nipple 6.220 8,954.3 3,372.5 79.85 HANGER FlexLock Liner Hanger 6.230 k4, 8,963.3 3,374.1 79.90 SBE 190-47 Casing Seal Bore 4.750 lk J! I 17,030.1 3,389.7 79.13 Swell Packer Swell Packer wNAM connections 3.960 11 6 J Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Y lif D LINER LEM 41/2 3.958 8,730.2 8,973.6 3,375.9 12.60 L-80 18T Id,_ "t Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inol(°) Item Des Corn (in) 8,730.2 3,333.9 79.71 PACKER SLZXP LINER TOP PACKER 4.890 if8,751.3 3,337.7 80.06 XO BUSHING CROSSOVER BUSHING 4.890 PACKER;8,907.0 - - 8,752.7 3,337.9 80.08 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 •"11./• 8,772.4 3,341.3 80.20 XO BUSHING CROSSOVER BUSHING 3.930 • 8,814.3 3,348.4 80.23 HANGER LEM ABOVE HOOK HANGER 3.930 :-: l. 8,822.1 3,349.7 80.23 HANGER LEM INSIDE HOOK HANGER 3.688 8,882.1 3,359.9 80.11 NIPPLE CAMCO DB NIPPLE 3.562 SEAL ASSY;8,973.0 8,970.4 3,375.3 79.93 SEAL ASSY BAKER SEAL ASSEMBLY 3.900 D LINER LEM;8,730.1-8,973.8 11 Tubing Strings 11 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 4-V2 COMPLETION 41/2 3.958 0.0 8,768.5 3,340.6 12.60 L-80 IBTM 2015 RWO ,, Completion Details D LINER HH;8,827.09,093.9 AlE. Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 22.7 22.7 0.06 HANGER 'Vetco Gray 13-5/8 x 10-3/4 False TBG hanger bowl w/10 4.500 INTERMEDIATE;27.4-9,275.0 -3/4 0 4-1/2 TBG hanger wl 4.909"MCA top threads and 4-1/2 IBTM bottom threads. 478.4 478.3 3.30 NIPPLE •Camco 4-1/2"DB-6 Nipple with 3.875"No-Go Profile SN- 3.875 N15N1094 8.702.0 3,328.8 79.25 SLEEVE Baker 4-1/2"CMU Sliding Sleeve W/3.813"X Profile- 3.813 Ran in Closed Position - 8,750.1 3,337.5 80.04 SEAL ASSY Baker 190-47 20-ft Seal assembly with 4-ft spaceout 3.840 {{{ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I-. Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) 8,907.0 3,364.2 79.99 PACKER D-SAND BAKER PAYZONE CASING PACKER 5/22/2006 4.910 (PUSHED DOWNHOLE FROM ORIGINAL LEM) 8,973.0 3,375.8 79.94 SEAL ASSY D-SAND BAKER SEAL ASSEMBLY(FROM 5/23/2006 3.900 --r ORIGINAL LEM) Perforations&Slots Shot Den - - Top(TVD) Stem(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (8808) Zone Date ft) Type Com SLOTS;9189.0-17,020.0 9289.0 17,020.0 3,426.2 3,387.8 WS B,WS C, 5/11/2006 32.0 SLOTS Alternating solid/slotted WS B,1J-184 pipe-6 blank jts/5 slotted jts/2 blank jts: 0.125"x2.5"x32 spf @ 4 Circumferential adjacent rows,3" Centers staggered 18 _, deg.,3 ft.non-slotted ends Mandrel Inserts St ati --.4N Top(ND) Valve Latch Port Size TRO Run (LL Top(MOB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,147.0 1,787.5 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/9/2015 Notes:General&Safety End Date Annotation 5/24/2006 NOTE: CANNOT ENTER L1 LATERAL 5/24/2006 NOTE:MULTI-LATERAL WELL:1J-184(B-SAND),1J-184L1(D-SAND) B SAND SLOTTED LINER, -.1.-- • KUP INJ 1J-184 ConocoPhillips aat.t,°.,a Alaska,Inc. COrtOcoPtuiltps • Multiple Laterals-1J-184,12/1/20152:51:53 PM Vertical eche/nets(actJaq HANGER;22.7 Notes:General&Safety 1 End Date Annotation 1/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0REV CONDUCTOR Insulated,30.0-_ 108.0 4 NIPPLE;478.4 _ a a GAS LIFT,2,147.0 11 SURFACE;30.2-3,977.0_ re 1 a SLEEVE;8,702.0 SEAL ASSY.8,750.1 4r.. ilk i4II II k 6` J 1I p4 If PACKER;8,907.0 — hiMil • ii . r: y Ii SEAL ASSY,8,973.0 _ D LINER LEM,8,730.1-8,973.6 4 D LINER HH 8827.0-9093.9 INTERMEDIATE;27.49,2750 SLOTS;9,289.0-17,020.0 1 I m B SAND SLOTTED LINER; 1 8,932.9-17,105.0 i • . :i, k: ' ' 0 Operations Summary (with Timelog Depths) 1J-184 iilii Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T X Operation (EKE) End Depth(EKE) 10/26/2015 10/26/2015 3.00 MIRU MOVE MOB P Prep cellar area for rig move. Warm 12:00 15:00 up moving system,and pull front mats from under rig. Pull off 1J-180 and remove rigging material from around well. Clean area for Environmental handover to production. 10/26/2015 10/26/2015 6.00 MIRU MOVE MOB P Move in mats and lay herculite,Pull 15:00 21:00 Nabors 9ES over well and sit down. Move in pit module and tie in interconnect. Complete CPAI acceptance list-Accept Nabors 9ES at 21:00 hrs on 10-26-15. 10/26/2015 10/26/2015 1.00 MIRU WHDBOP MPSP P PU lubricator and pull BPV/Lay down 21:00 22:00 Lubricator-Obtain pressures-TBG= 133 psi, IA=215 psi and OA= 145 psi. 10/26/2015 10/27/2015 2.00 MIRU MOVE RURD P Tie in circulation lines from the well to 22:00 00:00 the choke house. Bring 8.5 ppg KWF on board into rig pits and Condition KWF w/.06%by volume Safe lube. 10/27/2015 10/27/2015 4.75 MIRU WELCTL RURD P Continue to bring 8.5 ppg KWF on 00:00 04:45 board into rig pits and Condition KWF w/.06%by volume Safe lube. 10/27/2015 10/27/2015 3.50 MIRU WELCTL KLWL P PJSM,Circulate 890 bbls of 8.5 ppg 04:45 08:15 KWF w/.06%by volume Safe Lube to kill tanks thru Open Sliding sleeve @ 8,699-ft @ 4 bpm @ 396 psi while holding 100 psi over sip of 150 psi. Pummped 666 bbls and recovered 595 bbls=89%returns.71 bbl losses. 10/27/2015 10/27/2015 0.50 MIRU WELCTL OWFF P Shut well in and monitor pressures-0 08:15 08:45 psi,blow down lines and monitor well for flow. No flow. 10/27/2015 10/27/2015 0.50 MIRU WELCTL RURD P RD circulation lines and put away. 08:45 09:15 Prep area for ND of the Tree. 10/27/2015 10/27/2015 0.75 MIRU WHDBOP MPSP P Dry rod in BPV and lay down dry rod. 09:15 10:00 10/27/2015 10/27/2015 1.00 MIRU WHDBOP NUND P ND Tree and hang back. 10:00 11:00 10/27/2015 10/27/2015 2.00 MIRU WHDBOP OTHR T clean and clear wotk area anround 11:00 13:00 well head. Work on functioning lock down screws- 10/27/2015 10/27/2015 0.50 MIRU WHDBOP MPSP P Intstall blanking plug 13:00 13:30 10/27/2015 10/27/2015 4.00 MIRU WHDBOP NUND P NU BOPE,obtain RKB's, Install 13:30 17:30 mouse hole and turn buckles. 10/27/2015 10/27/2015 1.00 MIRU WHDBOP RURD P RU BOP test equipment 17:30 18:30 Page 1/5 Report Printed: 12/1/2015 • `` Operations Summary (with Timelog Depths) its 1J-184 C nocoPhillips .. She ke Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(Er) Phase Op Code I Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 10/27/2015 10/28/2015 5.50 MIRU WHDBOP BOPE P Conduct Initial BOP test at 250/3,500 18:30 00:00 psi with 4"and 4-1/2 test joints. Chuck Scheve waived witness of the test @ 5:50 hrs on 10-26-15. 24 hr notice was given @ 4:55 hrs on 10-26- 15. Test#1 Blind Rams,CM valves 1,2,3 and 16, Upper IBOP and Demco Kill valve on mud manifold Test#2 Blind Rams,CM valves 4,5 and 6, Lower IBOP and HCR Kill valve Test#3 Blind Rams,CM valves 7,8 and 9, Manual Kill valve and 4-1/2 EUE 8rd FOSV Test#4 Blind Rams, Manual and Hydraulic Choke and HCR Kill. Test#5 Blind Rams,CM valves 10 and 11 Test#6 Blind Rams,CM valves 12, 13 and 14. Test#7 Annular,CM valves 15,4"HT FOSV Test#8 Upper VBR's,4"HT Dart Valve,HCR Choke Test#9 Upper VBR's and Manual Choke Page 2/5 Report Printed: 12/1/2015 • - s .fa*f Operations Summary (with Timelog Depths) uz' 1J-184 ConocoPtaiitms Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS)', End Depth(#KDjs 10/28/2015 10/28/2015 1.50 MIRU WHDBOP BOPE P Continue to Conduct Initial BOP test at 00:00 01:30 250/3,500 psi with 4"and 4-1/2 test joints. Chuck Scheve waived witness of the test @ 5:50 hrs on 10-26-15. 24 hr notice was given @ 4:55 hrs on 10-26-15. Test#10 Lower VBR's,4-1/2 test joint,and 4- 1/2 FOSV--Koomey Test System Pressure-3,000 psi After closure-1,650 psi 1st 200 psi gain-26 seconds Full system pressure-146 seconds N2 Bottles-6 Ave 2,042 psi Test#11 Lower VBR's,4-1/2 test joint,4-1/2 FOSV,HCR Kill/Choke Test#12 Annular,4-1/2 test joint,4-1/2 FOSV, Outer Test Spool,HCR Kill Test#13 Upper VBR's,4-1/2 test joint,4-1/2 FOSV, Inner Test Spool, HCR Kill 10/28/2015 10/28/2015 2.00 MIRU WHDBOP MPSP P Pull Blanking plug and BPV 01:30 03:30 10/28/2015 10/28/2015 0.50 COMPZN RPCOMP PULL P Back out lockdown screws. Pull 03:30 04:00 hanger off seat 210k and pull seals at 95K. 10/28/2015 10/28/2015 2.00 COMPZN RPCOMP CIRC P Circulate 1.5 hole volumes @ 9 bpm 04:00 06:00 @ 360 psi-took 25 bbls to fill hole and 37 bbls to get 8.5 ppg back surface. Total losses=48 bbls - equivalent to 17 bph losses. 10/28/2015 10/28/2015 0.25 COMPZN RPCOMP PULL P Lay down tubing hanger and landing 06:00 06:15 joint. 10/28/2015 10/28/2015 0.75 COMPZN RPCOMP PULL P Lay down 4.5"TBG form 8,744-ft to 8,744.0 8,414.0 06:15 07:00 8,414-ft. Up wt=94K,Dn wt=61K 10/28/2015 10/28/2015 2.50 COMPZN RPCOMP MPSP X PU,MU and RIH w/9-5/8 40#Baker 8,414.0 107.0 07:00 09:30 Storm packer with 8,414-ft of 4.5 completion TBG hanging from the bottom of the packer to 107-ft and set. Test Storm packer to 500 psi-bleed off pressure and blow down lines. Drain stack. 10/28/2015 10/28/2015 1.25 COMPZN RPCOMP NUND X PJSM,Pull mouse hole,turn buckles, 107.0 0.0 09:30 10:45 riser. ND BOPE stack and rack back. 10/28/2015 10/28/2015 9.75 COMPZN RPCOMP EQRP X PJSM,RU tools and drill out galled 0.0 0.0 10:45 20:30 lock down,dress threads and service other lock down screws. MU landing joint to TBG hanger and land on No go. Attach to parent bowl. Back landing joint. Page 3/5 Report Printed: 12/1/2015 • • Operations Summary (with Timelog Depths) ."4' 1J-184 ConocciPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End Depth(ftKE) 10/28/2015 10/28/2015 1.00 COMPZN RPCOMP NUND X NU BOPE,install riser,turn buckles 0.0 0.0 20:30 21:30 and mouse hole. 10/28/2015 10/28/2015 0.25 COMPZN RPCOMP BOPE X Install blanking plug for shell testing 0.0 0.0 21:30 21:45 purposes. 10/28/2015 10/28/2015 0.75 COMPZN RPCOMP BOPE X RU and shell test BOPE @ 250/ 0.0 0.0 21:45 22:30 3,500 psi. RD test equipment blow down lines and drain Bop. 10/28/2015 10/28/2015 0.25 COMPZN RPCOMP BOPE X Pull blanking plug 0.0 0.0 22:30 22:45 10/28/2015 10/29/2015 1.25 COMPZN RPCOMP PULL X MU landing joint and screw in top 0.0 0.0 22:45 00:00 drive. BOLDS, Un land TBG hanger and false bowl @ 100K. Lay down hanger and landing jt. 10/29/2015 10/29/2015 1.50 COMPZN RPCOMP MPSP X PJSM,PU,MU and RIH w/retrieving 0.0 107.0 00:00 01:30 overshot to 107-ft and engage Storm packer. Open unloader and check for pressure below packer. Release packer and POOH. Lay down storm packer. 10/29/2015 10/29/2015 1.00 COMPZN RPCOMP RURD X Change over elevators and handling 107.0 8,414.0 01:30 02:30 equipment from drill pipe to Tubing. Clean and clear rig floor in preparation for pulling and laying down 4-1/2 Tubing. 10/29/2015 10/29/2015 11.00 COMPZN RPCOMP PULL P POOH,laying down and tallying de 8,414.0 0.0 02:30 13:30 completion from 8,414-ft to seal assembly 10/29/2015 10/29/2015 0.50 COMPZN RPCOMP RURD P Clear and clean rig floor-off load pipe 0.0 0.0 13:30 14:00 shed. 10/29/2015 10/29/2015 0.50 COMPZN RPCOMP SFTY P Hold PJSM with all involved with 0.0 0.0 14:00 14:30 running 4-1/2 completion. 10/29/2015 10/30/2015 9.50 COMPZN RPCOMP PUTB P PU,MU and RIH w/4-1/2, 12.6#,L-80 0.0 6,660.0 14:30 00:00 IBTM-M Tubing Completion to 6,660-ft filling hole w/4 bbls every 15 jts. Average MU Torque 3,800 ft/lbs. Up wt-71KDn wt-57K 10/30/2015 10/30/2015 3.25 COMPZN RPCOMP PUTB P Continue to PU,MU and RIH w/4-1/2, 6,660.0 8,772.5 00:00 03:15 12.6#,L-80 IBTM-M Tubing Completion from 6,660-ft filling hole w/ 4 bbls every 15 jts. Average MU Torque 3,800 ft/lbs. Up wt-71K Dn wt-57K to 8,772.51-ft. No go. PU 4- ft and space out. Lost 8 bbls during tripping operations 10/30/2015 10/30/2015 0.25 COMPZN RPCOMP PRTS P Close annular and pressure test the IA 8,772.5 8,732.0 03:15 03:30 to 1,000 psi for 10 minutes. Good Test. Bleed off pressure and open annular. 10/30/2015 10/30/2015 1.00 COMPZN RPCOMP HOSO P Pull jts 304 thru 302. PU 13.51-ft of 8,732.0 8,732.0 03:30 04:30 TBG pups. RIH below jt#302. PU, MU,RU landing joint on TBG hanger. RU to reverse circulate CI Brine taking returns to kill tank if needed. 10/30/2015 10/30/2015 5.75 COMPZN RPCOMP CRIH P PT treating lines at 3,500 psi. -good 8,732.0 8,732.0 04:30 10:15 test. Reverse circulate 570 bbls of CI brine down the IA taking returns up the Tubing to the kill tanks @ 3.5 bpm @ 344 psi. Recovered 478 bbls at the kill tanks-lost 92 bbls to formation. Page 4/5 Report Printed: 12/1/2015 • Operations Summary (with Timelog Depths) of. 1J-184 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code` Time P-T-X Operation (ftKB)', End Depth(ftKB)` 10/30/2015 10/30/2015 2.75 COMPZN WHDBOP THGR P Engage Seals into the SBE and Open 8,732.0 8,769.0 10:15 13:00 annular,Drain stack through the IA. Land hanger with Mule shoe at 8,769- ft.and RILDS. Blow down lines. Test upper and lower hanger seals @ 250/ 5,000 psi for 10 minutes. 10/30/2015 10/30/2015 0.50 COMPZN RPCOMP RURD P Remove landing joint, 8,769.0 8,769.0 13:00 13:30 10/30/2015 10/30/2015 1.50 COMPZN RPCOMP PRTS P PT IA @ 2,500 psi for 30 minutes on 8,769.0 8,769.0 13:30 15:00 chart. Monitor the TBG for flow.- Good Test. Bleed of IA and ramp up the pressure to 3.500 psi in an attempt to shear out the SOV Valve. Took 3 attempts prior to shearing @ 3,900 psi. 10/30/2015 10/30/2015 0.50 COMPZN RPCOMP RURD P Blow down all choke and kill lines in 8,769.0 8,769.0 15:00 15:30 preparation for ND of BOPE 10/30/2015 10/30/2015 0.25 COMPZN WHDBOP MPSP P Install 4"BPV with dry rod 8,769.0 8,769.0 15:30 15:45 10/30/2015 10/30/2015 1.25 COMPZN WHDBOP NUND P Pull mouse hole,riser and ND BOPE 0.0 0.0 15:45 17:00 10/30/2015 10/30/2015 0.50 COMPZN WHDBOP NUND P NU Tree 0.0 0.0 17:00 17:30 10/30/2015 10/30/2015 0.50 COMPZN WHDBOP MPSP P Pull BPV with dry rod and install TWC 0.0 0.0 17:30 18:00 10/30/2015 10/30/2015 1.25 COMPZN WHDBOP PRTS P Pressure test the adapter/Seal neck 0.0 0.0 18:00 19:15 void @ 250/5,000 for 10 minutes. RU test pump and PT tree with diesel- 250/5,000 psi. Found flange between upper and lower master leaking-tighten bolts and re test.- good test. 10/30/2015 10/30/2015 0.50 COMPZN WHDBOP MPSP P Pull TWC with dry rod 0.0 0.0 19:15 19:45 10/30/2015 10/30/2015 3.00 COMPZN WHDBOP FRZP P RU lines from the well to the kill tank 0.0 0.0 19:45 22:45 to take returns. Pt and verify no leaks. 10/30/2015 10/31/2015 1.25 COMPZN WHDBOP FRZP P PJSM, MIRU Little Red Services. PT 0.0 0.0 22:45 00:00 treating lines @ 2,200 psi,reverse circulate 110 bbls @ 2 bpm. 10/31/2015 10/31/2015 1.25 COMPZN WHDBOP FRZP P Continue to Freeze protect by closing 0.0 0.0 00:00 01:15 in Production valve and bull head 55 @ 1,000 psi ICP and 1,550 psi FCP. RD Little Red Services. Allowing the well to swap through jumper hoses. 10/31/2015 10/31/2015 3.25 DEMOB WHDBOP MPSP P PU,RU and operate lubricator and 0.0 0.0 01:15 04:30 lubricate in the BPV. Lay down and offload lubricator. Secure well and Service Tree. Release Nabors 9ES @ 04:30 hrs on 10-31-15 Page 5/5 Report Printed: 12/1/2015 20(,-0i-ty 3c1 WELL LOG TRANSMITTAL PROACTIVE DIAf1NOSTIC SERVICES, INC. DATA LOGGED ‘o /27/2015 K.BENDER To: AOGCC R _ E 1 Makana Bender 333 West 7th Avenue OCT 23 b16 Suite 100 Anchorage, Alaska 99501 GCC (907) 793-1225 ® RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 SCANNED AUG 1 1 2Q1 Fax: (907) 245-8952 1) LeakPointTM Survey(.-1 10-Oct-15 1J-184 BL/CD 50-029-23305-00 2) Signed : /''j _-, / Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx z-DG-344 q • • 21,0 3� k WELL LOG TRANSMITTAL PROACTIVE DIACINOSTIC SERVICES, INC. To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 10-Oct-15 1J-184 1 Report /CD 50-029-23305-00 2) Signed : i224t41LI<%,56_,,eirat, Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: WEBSITE: D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx eco- o Li Li CEIVED • 'st .11 Da 13 ats Memory Multi-Finger Caliper ,. Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1J-184 Log Date: October 10, 2015 Field: West Sak Log No.: 17019 State: Alaska Run No.: 1 API No. 50-029-23305-00 Pipe Description: 4.5 inch 12.6 lb. L-80 IBT-M Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 8,648 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the top of GLM 1 at 2,040 feet(Driller's Depth). This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 4.5 inch tubing logged appears to be in mostly fair to poor condition,with multiple possible holes and wall penetrations ranging from 40%to 91%wall thickness in 201 of the 285 joints logged. Recorded damage appears as deep isolated pitting and a line of pits, broadening into line corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. SCANNED AUG 1 1 2016 MAXIMUM RECORDED WALL PENETRATIONS : Descripr,, _,anon Joint Possible Hole 91 183 5,659 Ft. (MD) Possible Hole 89 221 6,816 Ft. (MD) Possible Hole 87 215 6,628 Ft. (MD) Possible Hole 87 180 5,564 Ft. (MD) Possible Hole 87 230 7,093 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. J. Marinovich C.Waldrop J. McAnelly ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888)565-9085 Fax: (281)431-7125 E-mail: PDSAnalvsismemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907)659-2314 • • PDS Report Overview ,` Body Region Analysis Well: 1J-184 Survey Date: October 10,2015 Field: West Sak Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches Country: USA No. of Fingers: 40 Pipe 4.5 in. 12.6 ppf L-80 IBT-M Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT-M 3.958 in. 18 ft. 8,648 ft. Penetration(WO wall) Damage Profile(c/o wall) 200 NEN Penetration body Metal loss body 0 0.1 50 100 150 100 - 40 50 4 GLM 1 (2:00) -- 0 to 20 to 40 to over 20% 40% 85% 85% )(> Number of joints analyzed(total=285) 10 74 195 6 Damage Configuration(body) 146 250 — 200 .___ 150 196 100 _ 50 iii,, , ,,,., 246 0 �� Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=278) 36 0 236 0 6 Bottom of Survey=280 • • PI PDS Report Joint Tabulation Sheet Well: 1J-184 Survey Date: October 10,2015 Field: West Sak Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT-M Tubing 3.958 in. 0.271 in. 18 ft. 8,648 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (in.) (in.) % (in.) 0 50 100 0.1 18 0 0.08 31 2 3.95 Pup Line of Pits. 1 23 0.06 0.08 29 2 3.94 Line of Pits. 1.1 54 0 0.06 21 2 3.93 Pup Line of Pits. 1.2 63 0.05 0.05 18 1 3.95 Pup Shallow Line of Pits. 2 67 0 0.05 17 1 3.96 Shallow Line of Pits. 3 105 0 0.07 27 1 3.95 Line of Pits. 4 136 0 0.09 33 2 3.95 Line of Pits. 5 167 0 0.02 6 1 3.95 6 197 0 0.06 24 2 3.94 Isolated Pitting. 7 229 0 0.03 13 2 _ 3,96 _ 8 259 0 0.08 31 2 3.95 Isolated Pitting. 9 289 0.06 0.09 33 1_ , 3,93 Line of Pits. 10 319 0.04 0.12 44 7 3.95 Line of Pits. 11 350 0.07 0.07 25 2 3.95 Line of Pits. 12 381 0 0.08 31 2 3.96 Line of Pits. 13 412 0 0.09 34 2 3.95 Line of Pits. 14 442 0 0.07 25 2 3.96 Line of Pits. 15 473 0 0.07 27 2 3.96 Line of Pits. 15.1 503 0 0 0 0 3.86 4.5"CAMCO DB-6 NO GO NIPPLE 16 504 0.06 0.09 34 2 3.95 Line of Pits. 4 17 535 0 0.10 38 2 3.93 Line of Pits. 18 565 0 0.10 36 2 3.92 Line of Pits. 19 595 0 0.10 37 2 3.95 Line of Pits. 20 626 0 0.10 36 2 3.96 Line of Pits. ., 21 657 0 , 0.09 , 32 3 3.94 Line of Pits. 22 688 0 0.13 48 4 3.95 Line of Pits. 23 719 0 0.13 49 4 3.94 Line of Pits. 24 750 0 0.11 41 2 3.95 Line of Pits. 25 781 0 0.03 12 2 3.95 26 812 0 0.07 24 3 3.92 Line of Pits. 27 842 0.06 0.12 44 3 3.95 Line of Pits. 28 874 0 0.12 43 3 3.90 Line of Pits. oi 29 903 0.07 0.12 45 3 3.94 Line of Pits. 30 934 0 0.09 33 2 3.95 Line of Pits. 31 965 0 0.10 35 4 3.96 Line of Pits. 32 996 0 0.11 40 4 3.95 Line of Pits. 33 1027 0 0.02 8 1 3.94 34 1058 0.11 0.14 51 4 3.95 line of Pits. `1 35 1089 0 0.12 45 2 _ 3.94 , Line of Pits. 36 1119 0.06 0.11 41 3 3.95 Line of Pits. 37 1150 0.09 0,12 45 3 3.94 Line of Pits. .: ts 38 1180 0 0.14 50 3 3.95 Line of Pits. 39 1212 0 0.11 39 2 3.94 Line of Pits. 40 1242 0.08 0.14 52 4 3.93 Line of Pits. 41 1273 0 0.11 39 4 3.90 Line of Pits. Lt.Deposits. 42 1304 0 0.11 41 3 3,93 Line of Pits. 43 1335 0 0,15 55 3 3.95 Line of Pits. 44 1366 0 0.07 26 1 3.95 Line of Pits. 45 1396 0.11 0.16 58 4 3.95 Line of Pits. Amin 46 1427 0 0.06 22 1 3.96 Isolated Pitting. LI IPenetration Body Metal Loss Body Page 1 • • PDS Report Joint Tabulation Sheet Well: 1J-184 Survey Date: October 10,2015 Field: West Sak Analyst: C.Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT-M Tubing 3.958 in. 0.271 in. 18 ft. 8,648 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 47 1456 0 0.09 35 3 3.93 Line of Pits. 48 1487 0.07 0.14 51 5 3.91 Line of Pits. J' 49 1518 0.08 0.13 48 4 3.95 Line of Pits. t. 50 1548 0 0.13 47 3 3.95 Line of Pits. 51 , 1580 0 0.12 42 3 3.95 _Line of Pits. 52 1610 0.04 0.14 6 3.94 Line of Pits. mti 53 1641 0.05 0.09 2 3.94 Line of Pits. ■ 54 1671 0.09 0.07 2 3.90 Line of Pits. 55 1702 0 0.03 10 2 3.96 56 1733 0.05 0.15 55 3 , 3.94 Line of Pits. 57 1761 0 0.09 , 34 3 3.94 Line of Pits. 58 1791 0 0.11 41 3 _ 3,95 Line of Pits. um 59 1822 0.08 0.10 36 2 3.94 Line of Pits. • 60 1851 0 0.13 48 4 3.95 Line of Pits. m 61 1882 0.06 0.03 12 1 3.93 62 1912 0 0.09 32 2 3.89 Line of Pits. Lt.Deposits. ■■ 63 1943 0 0.11 42 2 3.93 Line of Pits. • 64 1972 0 0.05 20 2 3.90 Isolated Pitting. • 65 2003 0 0.06 22 1 3.94 Line of Pits. 65.1 2034 0 0.04 15 3 3.96 Pup Shallow Pitting. 65.2 2040 0 0 0 0 3.87 GLM 1 (LATCH @ 2:00) 65.3 2047 0 0.02 8 2 3.92 Pup 66 2053 0 0.09 35 2 3.92 Line of Pits. • 67 2084 0 0.09 32 3 3.94 Line of Pits, • 68 2114 0 0.06 23 1 3.94 Line of Pits. • 69 2146 0 0.06 , 23 1 3.95 Line of Pits. • 70 2176 0 0.10 37 3 3.88 Line of Pits. Lt.Deposits. • 71 2207 0 0.16 59 4 3.95 Line of Pits. ■� 72 2237 0 0.11 39 3 3.93 Line of Pits. ■ 73 2268 , 0 0.12 43 3 3.94 Line of Pits. • 74 2298 0 0.10 37 3 3.95 Line of Pits. • 75 2328 0 0.13 47 3 3.93 . Line of Pits. ■ 76 2358 0.05 0.09 33 3 3.92 Line of Pits. • 77 2389 0 0.09 15 2 3.92 Line of Pits. oti 78 2421 0 0.10 37 4 3.93 Line of Pits. 79 2451 0.06 0.11 39 3 3.91 Line of Pits. 80 2482 0 0.11 41 3 3.93 Isolated Pitting. • 81 2513 0.05 0.08 29 2 3.93 Isolated Pitting. • 82 2543 0.07 0.12 45 2 3.93 Line of Pits. • 83 2573 0.04 0.08 29 2 3.93 Line of Pits. • 84 2605 0.05 0.10 37 4 3.94 Line of Pits, ■� 85 2635 0.04 0.11 42 3 3.91 Line of Pits. • 86 2666 0.05 0.09 34 2 3.94 Isolated Pitting. 87 2697 0 0,07 27 2 3.94 Line of Pits. 88 2727 0 0.11 42 2 3.94 Line of Pits. 89 2757 0 0.09 32 2 3.92 Line of Pits. 90 2788 0.05 0.16 61 3 3.93 Line of Pits. tit 91 2819 0 0.09 33 2 3.93 Line of Pits. 92 2850 0.06 0.09 32 2 3.92 Line of Pits. i _ 93 2880 0 0.07 26 3 3.93 Line of Pits. IPenetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet Well: 1J-184 Survey Date: October 10,2015 Field: West Sak Analyst: C.Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT-M Tubing 3.958 in. 0.271 in. 18 ft. 8,648 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 94 2911 0,05 0.07 24 1 3,93 Line of Pits. 95 2942 0 0.09 32 3 , 3.94 Line of Pits. 96 2973 0 0.07 27 2 3.87 Isolated Pitting. Lt.Deposits. 97 3002 0 , 0.10 37 6 3.94 Line of Pits. -- 98 3033 0 0.08 30 2 3.88 Line of Pits. Lt.Deposits. mum 99 3063 0.05 0.09 32 2 3.94 Line of Pits. 100 3095 0 0,10 37 3 3.93 Line of Pits. • 101 3125 0.04 0.11 41 5 3.92 Line of Pits. n- 102 3156 , 0.04 0.13 48 2 3.91 Line of Pits. Nom 103 3187 0.05 0.13 47 3 3.90 Line of Pits. • 104 3217 0.06 0.10 38 3 3.90 Line of Pits. • 105 3248 0.10 0.11 41 4 3.89 Line of Pits. Lt.Deposits. ■ 106 3278 0 0.11 40 2 3.93 Line of Pits. 107 3309 0.04 0.08 31 2 3.93 Line of Pits. 108 3340 0.05 0.10 36 2 3.93 Line of Pits. 109 3370 0.05 0.12 42 4 3.94 Line of Pits. 110 3402 0.06 0.10 37 3 3.95 Line Corrosion. 111 3432 0.06 0.10 37 2 3.89 Line of Pits. Lt.Deposits. 112 3463 0.04 0.10 35 3 3.91 Line of Pits. 113 3494 0.05 0.10 38 3 3.94 Line of Pits. 114 3524 0.06 0.11 39 3 3.93 Line of Pits. 115 3555 0.10 0.12 42 3 3.91 Isolated Pitting. 116 3587 0.09 0.13 48 3 3.90 Isolated Pitting. 117 3617 0.04 0.12 46 4 3.92 Line of Pits. 118 3648 0.04 0.12 43 4 3.93 Line of Pits. 119 3678 0.09 0.13 47 3 3.92 Isolated Pitting. 120 3709 0.06 0.15 56 4 3.87 Line of Pits. Lt.Deposits. 121 3740 0.06 0.10 36 3 3.94 Line of Pits. 122 3771 0.07 0.12 43 3 3.94 Line of Pits. 123 3801 0 0.10 36 3 3.92 Line of Pits. 124 3831 0.06 0.13 48 3 3.94 Line of Pits. 125 3861 0.07 0.11 41 3 3.92 Line of Pits. 126 3891 0 0.14 51 3 3.88 Line of Pits. Lt.Deposits. 127 3922 0 0.17 61 3 3.89 Line of Pits. Lt.Deposits. 128 3953 0 0.15 56 2 3.91 Line of Pits. 129 3983 0.05 0.15 55 3 3.94 Line of Pits. 130 4014 0.04 0.10 38 3 3.92 Line of Pits. 131 4043 0.05 0.16 60 3 3.88 Line Corrosion. Lt.Deposits. 1. 132 4073 0 0.12 45 3 3.88 Line of Pits. Lt.Deposits. n 133 4104 0.04 0.14 50 3 3.90 Line of Pits. 134 4135 1.05 1.16 58 4 3 91 Line of Pit . 135 4166 0 0.12 44 4 _ 3.91 Line of Pits. 136 4196 0.12 0.18 68 4 3.91 Line of Pits. 137 4227 0 0.19 70 6 3.92 Line of Pits. °vim 138 4257 0.12 0.17 61 5 3.93 Line of Pits. 139 4288 0.14 0.18 67 4 3.93 Line of Pits. 140 4319 0 0.16 60 4 3.94 Line of Pits. 141 4350 0.08 0.17 62 4 3.93 Line of Pits. 142 4380 0 0.15 55 3 3.93 Isolated Pitting. 143 4411 0.08 0.13 46 3 3.93 Line Corrosion. IPenetration Body Metal Loss Body Page 3 • • 11:i:3 PDS Report Joint Tabulation Sheet Well: 1 J-184 Survey Date: October 10,2015 Field: West Sak Analyst: C.Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Noni. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT-M Tubing 3.958 in. 0.271 in. 18 ft. 8,648 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (in.) (in.) % (in.) 0 50 100 144 4441 0.09 0.13 49 3 3.95 Line Corrosion. 145 4471 0.09 0.16 58 6 3.93 Line of Pits. 146 4502 0 0.13 49 4 3.93 Line of Pits. is 147 4532 0.06 0.15 56 3 3.93 Line of Pits. 148 4563 0.05 0.17 64 3 3.95 Line Corrosion. ANII 149 4593 0.05 0.15 56 4 3.93 _ Isolated Pitting. IN 150 4624 0.08 0.11 40 . 4 3.91 Isolated Pitting. Maio 151 4654 0.06 0.15 54 5 3.94 Line Corrosion. .mom 152 4684 0.05 0.14 52 3 3.93 Line of Pits. ■w 153 4715 0.06 0.17 63 4 3.94 Line of Pits. moo 154 4746 0.08 0.15 54 4 3.94 Line Corrosion. Nomm 155 4775 0.10 0.19 . 71 , 4 3.94 Line Corrosion. mom 156 4807 0.09 0.17 63 5 3.92 _ Line Corrosion. .mom 157 4837 0.16 0.11 39 3 3.88 Line Corrosion. Lt. Deposits. Emma 158 4867 0.09 0.14 53 4 3.94 Line of Pits. Emma. 159 4899 0.10 0.17 62 4 3.93 Line of Pits. J., 160 4929 0.05 0.21 77 6 3.91 Line Corrosion. 161 4960 0.11 0.16 60 4 3.89 _Line of Pits. Lt.Deposits. I. 162 4989 0.05 0.17 63 4 3.93 Line of Pits. 163 5020 0.09 0.13 46 4 3.92 Line of Pits. 164 5051 0.08 0.13 48 4 3.91 Line of Pits. 165 5082 0.08 0,21 78 8 3.91 Isolated Pitting. 166 5113 0.12 0.14 52 4 3.93 Line Corrosion. 167 5143 0.05 0.12 44 4 3.94 Line Corrosion. 168 5173 0.07 0.16 60 4 3.93 Line Corrosion. 169 5204 0.14 0.16 58 4 3.93 Line Corrosion. 170 5235 0.12 0.14 52 4 3.93 Isolated Pitting. 171 5266 0.10 0.13 48 3 3.93 Line of Pits. 172 5297 0.13 0.12 46 4 3.93 Line of Pits. 173 5328 0.09 0.17 62 4 3.95 Isolated Pitting. 174 5359 0.04 0.17 63 7 3.94 Isolated Pitting. 175 5390 0.11 0,17 62 4 3.93 Isolated Pitting. 176 5422 0.06 0.15 56 5 3.93 Isolated Pitting. 177 5452 0.08 0.14 52 4 3.92 Line of Pits. 178 5483 0.17 0.21 78 6 3.95 Line Corrosion. q 179 5514 0.06 0.20 75 6 3.88 Line Corrosion. Lt. Deposits. 180 5545 0.09 0.24 87 4 3.94 Possible Hole! 181 5576 0.11 0.15 56 5 3.94 Line Corrosion. .mmom 182 5606 0.12 0.15 55 7 3.93 Isolated Pitting. immom 183 5638 0.11 0.25 91 6 3.88 Possible Hole! Lt. Deposits. Immo 184 5669 0.14 0.15 . 57 4 3.94 Line of Pits. Nommo 185 5700 0.13 0.14 51 4 3.92 Line Corrosion. Emoting 186 5731 0.15 0.16 57 4 3.93 Line Corrosion. Immo 187 5761 0.10 0.18 68 . 7 3.91 Isolated Pitting. isoimm 188 5793 0.08 0.20 73 6 3.93 Line of Pits. ••••• 189 5824 0.10 0.19 . 70 5 3.91 Isolated Pitting. =MINI 190 5855 0.10 0.17 63 4 3.87 Isolated Pitting. Lt.Deposits. N. 191 5885 0.08 0.19 69 7 3.93 Line Corrosion. loll 192 5917 0.17 0.18 65 6 3.93 _ Line Corrosion. imam 193 5947 0.10 0.20 75 5 3.94 Line of Pits. IPenetration Body Metal Loss Body Page 4 • • PDS Report Joint Tabulation Sheet Well: 1J-184 Survey Date: October 10,2015 Field: West Sak Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT-M Tubing 3.958 in. 0.271 in. 18 ft. 8,648 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 194 5978 0.08 0.16 . 59 6 3.90 Line Corrosion. Immo 195 6009 0.11 0.17 62 4 3.94 Line Corrosion. MIMI= 196 6037 0.14 0.18 67 6 3.93 Line Corrosion. NOME= 197 6068 0.09 0.19 69 5 3.93 ,Line of Pits. Dm 198 6099 0.06 0.17 62 5 _ 3,92 Isolated Pitting. MIN 199 6129 0.09 0.15 56 5 3.89 Line Corrosion. Lt.Deposits. .• 200 6160 0.14 0.15 56 7 3.94 Line Corrosion. 201 6191 0.10 0.17 62 5 3.90 Isolated Pitting. Lt.Deposits. 202 6222 0.06 0.17 61 6 3.85 Line Corrosion. Lt.Deposits. 203 6253 0.10 0.16 59 5 3.90 Line of Pits. 204 6284 0.13 0.17 62 5 3.91 Line Corrosion. 205 6314 0.07 0.17 63 , 4 3.93 Isolated Pitting. 206 6345 0.09 0.13 49 4 3.94 Line Corrosion. $_ 207 6375 0.09 0.14 53 5 3.90 Line Corrosion. Lt. Deposits. 208 6406 0.04 0.15 56 6 3.89 Line Corrosion. Lt. Deposits. 209 6437 0.11 0.18 65 6 3.94 Line Corrosion. 210 6468 0.09 0.17 64 5 3.93 Line of Pits. 211 6499 0.10 0.15 55 5 3.93 Line of Pits. 212 6529 0.12 0.15 54 3 3.91 Isolated Pitting. 213 6560 0.11 0.18 65 5 3.88 Isolated Pitting. Lt.Deposits. 214 6591 0.11 0.19 70 5 3.92 Line of Pits. 215 6622 0.18 0.24 87 6 3.92 Possible Hole! 216 6653 0.17 0.18 66 7 3.92 Line of Pits. )�a 217 6683 0.08 0.19 68 4 3.94 Line of Pits. Aim 218 6714 0.04 0.19 70 6 3.94 Line of Pits. 219 6745 0.12 0.18 67 6 3.93 Line of Pits. 220 6776 0.14 0.22 79 6 3.93 Isolated Pitting. 221 6807 0.19 0.24 89 7 3.92 Possible Hole! 222 6837 0.14 0.21 76 7 3.94 Line Corrosion. 223 6868 0.06 0.18 67 6 3.93 Line of Pits. 224 6900 0.13 0.20 74 6 3.93 Line Corrosion. 225 6930 0.06 0.14 50 6 3.88 Isolated Pitting. Lt.Deposits. 226 6962 0.08 0.22 82 5 3.93 Line of Pits. 227 6993 0.16 0.22 79 7 3.93 Line Corrosion. 228 7023 0.10 0.14 51 5 3.92 Line Corrosion. 229 7055 0.10 0.12 43 3 3.93 Line of Pits. 230 7086 0.05 0.24 87 7 3.94 Possible Hole! 231 7117 0.17 0.23 _ 86 8 3.92 Possible Hole! moms 232 7147 0.09 0.22 83 8 3.91 Line of Pits. mmnin 233 7178 0.05 0.22 81 6 3.93 Line of Pits. 1.1111111111111 234 7208 0.09 0.15 55 5 3.94 Line of Pits. momma 235 7239 0.06 0.15 55 4 3.93 Line Corrosion. =mom 236 7270 0.06 0.21 78 6 3.88 Line of Pits. Lt.Deposits. mons 237 7301 0.11 0.14 52 4 3.92 Line of Pits. mmmin 238 7332 0.10 0.14 51 6 3.92 Line Corrosion. imismn 239 7363 0.19 0.20 73 6 3.93 Line Corrosion. =mom 240 7394 0.07 0.19 71 7 3.94 Line Corrosion. =mom 241 7425 0.12 0.17 62 5 3.93 Line of Pits. mommo 242 7455 0.11 0.13 46 7 3.93 Line Corrosion. mud 243 7486 0.11 0.18 65 6 3.88 Line Corrosion. Lt.Deposits. IPenetration Body Metal Loss Body Page 5 • S 1111 PDS Report joint Tabulation Sheet Well: 1J-184 Survey Date: October 10,2015 Field: West Sak Analyst: C.Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBT-M Tubing 3.958 in. 0.271 in. 18 ft. 8,648 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 244 7516 0.07 0.18 66 6 3.91 Line of Pits. 245 7547 0.12 0.15 55 7 3.93 Line Corrosion. 246 7577 0.09 0.19 70 5 3.94 Line of Pits. 247 7608 0.07 0.15 56 5 3.92 Line Corrosion. 248 7639 0,12 0.15 55 4 3.93 Line of Pits. a; 249 7670 0.08 0.18 66 5 3.93 Line Corrosion. 250 7701 0.12 0.19 68 7 3.92 Isolated Pitting. 1 251 7731 0.12 0.18 67 6 3.92 Line of Pits. I mm 252 7762 0.15 0.16 58 7 3.93 Line Corrosion. ■ 253 7794 0.12 0.18 68 6 3.94 Line of Pits. 254 7825 0.10 0.20 72 7 3.93 Line of Pits. 255 7856 0.07 0.18 66 6 3.83 Line Corrosion. Lt. Deposits. 256 7886 0.07 0.10 38 6 3.88 Line Corrosion. Lt. Deposits. 257 7916 0.10 0.11 41 3 3.92 Line of Pits. 258 7947 0,13 0.17 63 7 3.92 Isolated Pitting. 259 7978 0.11 0.14 53 6 3.92 Line Corrosion. • 260 8010 0.11 0.20 72 9 3.92 Line Corrosion. 261 8040 0.10 0.12 45 6 3.93 Line Corrosion. 262 8071 0.14 0.19 70 6 3.95 Isolated Pitting. 263 8102 0.09 0.12 44 6 3.93 Line of Pits. mom 264 8133 0.08 0.14 51 5 3.93 Line of Pits. Immo 265 8166 0.08 0.15 55 5 3.93 Line of Pits. um= 266 8197 0.12 0.16 61 7 3.93 Isolated Pitting. Immo 267 8228 0.08 0.16 60 6 3.89 Line Corrosion. Lt. Deposits. mums 268 8258 0.09 0.11 41 5 3.93 Line Corrosion. imam 269 8289 0.12 0.18 66 5 3.91 _Line of Pits. ■mm■ 270 8322 0.12 0.17 62 4 3.93 Line Corrosion. ■mum 271 8351 0.11 0.17 63 6 3.91 Line Corrosion. mum 272 8383 0.11 0.16 60 4 3.94 Line Corrosion. Immo 273 8413 0.07 0.11 41 4 3.93 Line Corrosion. ■m■m 274 8444 0.09 0.11 41 5 3.93 Line Corrosion. mom 275 8475 0.06 0.17 62 6 3.88 Line Corrosion. Lt.Deposits. Isom 276 8506 0.12 0.16 58 4 3.91 Line of Pits. Emma 277 8537 0.14 0.22 80 8 3.92 Line Corrosion. immmmmsi 278 8567 0.07 0.22 80 8 3.91 Line Corrosion. imam., 279 8596 0.14 0.22 79 8 3.86 Line Corrosion. Lt.Deposits. imp 280 8628 0.10 0.18 66 7 3.89 Line Corrosion. Lt. Deposits. Penetration Body Metal Loss Body Page 6 • • PDS Report Cross Sections Well: 1J-184 Survey Date: October 10,2015 Field: West Sak Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 IBT-M Analyst: C.Waldrop Cross Section for Joint 183 at depth 5,659.431 ft. Tool speed=49 Nominal ID=3.958 Nominal OD=4.5 : Remaining wall area=94% Tool deviation =74° / Finger= 11 Penetration=0.247 in. Possible Hole 0.25 in.=91%Wall Penetration HIGH SIDE=UP • • 45). PDS Report Cross Sections ti Well: 1J-184 Survey Date: October 10,2015 Field: West Sak Tool Type: UW MFC 40 No.218452 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 IBT-M Analyst: C.Waldrop Cross Section for Joint 221 at depth 6,815.908 ft. Tool speed=51 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area=97% Tool deviation=75° r Finger=34 Penetration=0.242 in. Possible Hole 0.24 in.=89%Wall Penetration HIGH SIDE=UP 411 • F KUP !NJ 1J-1£34 ConocoPhillips 1 , Wifiabriaaes- �r le. .,tea •,L 4'W7ma"...... ,_ N>.ns VAUNT.Nola1 I•i nln,91 .. P.O.201 ,�, : 500292330500 WEST SAS. DU 17,870 0 ••- Con oori N20(p.m) 04. arnotolion I1nd 04. 080.](411 1Rro1 Imo 04, Pimple Ler**a•IJ-/la.'082976:.46.0VNM SSSV.NIPPLE Loot WD. 1:/1,2006 31.511 5575.4006 vow sd,u+MllO Naar At.vs*,m n.r+l,1N7(R1 809 0*. Amnl*1m _ 1.4 MM q 48,40*. .._..Last Tap. Rev Rea:on GLV CO 1413-617 56/2315 14iIWE-3:22 a ''• car 819Seines Casnq Do sonphan OD(14) OLm) Top(11901 Set D.phQNB) Set Depth ITV DI...VA/Len U...Gnat Top11read - CONUL)CTORlnsulatec 21) 19124 300 1080 108.0 9400 1-1-40 '448140484 (. ...n6, nion 00 on) 014,) Top(ft N81 Sa00<plhpI8flO 1 Ski 0406 O). VA/Len(! prank Top T4akkd �� SURFACEo133,9 12.115 302 3.9770 2239.0 68.001-80 BTC Conote... 0n 00(In) 0(141 Top 01912) S*DopeT11'8) Sal Depth(TVO)...9A/LenQ. Orad, Tap Thread ,cO8O1FTtwrnwesee;suu INTERMEDIATE 9543 8.035 27.4 92750 3.424.2 40.001-80 ETC IOBD (tong Drsrnphon 00 0^1 101,01 Top(NNBS 040. 9.8148) Sat Nath IWO)..VA/Lkn0 Onda TW 114,84 0 LINER HH 5-/2 4 550 9,127 0 9,0939 3.395 2 15.50 MOAN 002.2 - LM1erDetalls lilts in GKtKT:904/ 0*8,11 61 rapINpl@N8) Tq, ol Ir. ,ern O.. Can 81.1 N'T''''' 8,827.0 3,350.5 8023 HANGER •Hock Harger[orts+de:amp) 7./40 i 6.8460 3,254.1 80.21 HANGER Hook Mangofisde wing: 61324 B.@5d 3 4..AG 2 8024 5C0 BU:HIFIG •Lrp.a...64441,44p ?VA) stlrfACE m1 a.onD a 8,5 3 3,364 3 79.59 ECP BAKER PAY2CINE(EXTERNAL CASING PACKER 4.910 8113105 C.e,aaa ._. NB 9.0191 3,:838 8015 XO PTCP5J no LROSSOVEH?.584.5 3708 k 9 064-4 3.,91.4 08.38 BENT JT 3940 uun)Las9Ndgn union) 01.1 -1981181911 syt DpinMK. S.4050011VU( 049.0914..0r10M 4P Ir9aa L1 8 SANE SLOT TED 5.2 4.550 85329 17.1050 3,4056 15.501.80 1•611521 LOCPTOP•6,74.8 LINE R Liner Details SEAL ASSY;8,7'.00 TO re rr 141 Top 44640 Top 11V0110981 tap Owl('1 Nom 6s Can Irl 8,73[51 3,928 /7.2/ HALEtH HHU OCR'LI Packet /708 .11111 89514 3,372.0 7984 NIPPLE RSPacin1Seal Nipp(e 6220 8.954 3 3,.72.5 7985 HANGER FleoLod,Linn Hance 6.230 SLEEVE aenI I 8.9632 3,741 7990966 19.47 Peony cool Ba• 4.750 17.0.1 1 3.389../ 17.13 Swell Padker 11 Q 5 well Pa[kd,NAM oarw,actlons }9yjJ 7 3a 'Csnng Desandran 00)/n) 09n) Top)NNB)4W'kph NB) Sat Depth(1V01...VAllen(1..Grade Tap164884 0 LINER LEI.. 1389 •2 3 958 0,730.2 8.9736 3.3259 12.60 1-80 IBT III Liner Details wmA1 o „R Top 131461 rap ITVO)Ie KBI Tcp lr>rl l•) Nkm Oaf Can In( PLUG.2.8020 .1. 8.7302 3,:339' 7971 PACKER 512�t'LINERTOP PACKE9 4890 8./•.,1 4 3..3/ 0 / 5113 Cb X0 8 _7112LHUH 12911-11311451 11UV12911-113114 4 890 79 990,(Oaf o ■ 8.751.7 3-.3/9 80.08 SER 1W-47CASIN(s 4tAL80 FE I$CEP1ACLE 4/90 .100 8,772.4 3,341.3 80.2� X0 BUSHING CROSSOVER BUSHING 3930 .� 8.814.3 3,:48.4 80 43l 1 HANGER LE M ABOVE HOOK HANGER 3931) 1 8.13221 3,.451/ 311;13 HAMAR 2kMINSIUl HULIK 24411[2 3688 9.81421 3,:69 9 SU T1 NIPPLE CAMCO 08 NIPPLE W4.30,LUL 3662 <Ea.<xcr-.s.onn '"14 .. • •o 3 AK ALA. WO' 3900 D LINER 004.s.�I.1,o736� _ Tubing fittings rubr'g Ce<npl.or. 11nny N. O 1"3 n) Tcp(nIB) '5'r..74; h(F or o-h I107I I NA 112It 1 C.ra T.Rx C 84 ,, TUBING WO -0 12 39581 228$4 0.9.761 la 3.3403) 1260 LOT IIBiM0 ,0 Compist)en Details 11„.4,04 ID 0 LRERo49,,95279-4093 r •' Top I11P0 Tap1108114401 1 Ina(•) ken Des Com - Iml 228 HANGER Vetc3GtayHp111".4-1/."'w/4.909"MCATOTCnew 3'5500 913/. 502.1 4.0 t 511306 14.147 0M00'486 Nlppew/3.8/5 NO'002'10617 3891 .TEA.EMTE.27 49.276 0 AN9913 ZZ'Rd 7471 SI 4fVF.E Rakn4hl kin SIrLrcJ\i.wrr.wJf'Amrn•RT'.-TR'P 19711 j)CLUSED 8/23441 874899 33'3'-2 13.1 Clc LOCATOR ',BAKER LOCATOR 3880 ' [ 87560 '�:14 4 SEAL Ba4.7r473 SBESe.4Ano,of/4S'IBT6aakc 1. 3880 Other In Hole(Wireline retrievable Plugs.valves,pumps.fish,etc.) ToplTV0) To 0 I Tnn•nKA( In10R) 1'1 rYc 0.n 119, 1/1,r.. 8.8221 3.349.7 8323 SLEEVE-C 3684-ISO SLEEVE ACROSS LEM 8/23/2014 8.88220 3.3599 1)0.11 PLUG 1..567'6B PLUG --- 8/5/2014 0080 0.70/0- 3.344.2 73.93 PACE LR ID-SAND BAKER PAYZOK LASINGT'AC'E R 5/".2,20(9 4 310 (PUSHE000'wN-TOLE FROM 7RIGINAL LEM) 89,'10 ..3/5.3 79.94 SEALAS/Y 1)-SAND BAKER SEAL ASSEMIL','T-ROM 5/27.2008 3900 ORIG 119E1 LE 441 • Perforations&Slots she IA ro B Top(1 VC) @n-TVO) (slot.4 Top MINN Be,'+(tth, j QNB) 0148) Ursa Oke 1) Type Com 31015.92194.1.,0200 92890 17,020.0 1425.2 3.387,8 Wa B.815 C. 531,20136 320 91015 'AOernaIRg soldhiolled WS B.1J-184 pipe-6bdad Ass slot/WA/2 dark 89 0.125'.25".32:@ O5 4 9irounloron141 adjacent novo,7' Caile's Panned 18 dog..39 m0-xloped endo Mandel Inserts St 4,1 R Top(IVO) Vak. Ls1>h 4ort,) TRO Run Top 2.048 (RKeD Malo yodel O[(irt) SAN Dr E'Tp. (In IFsi 4m D4k Can 1' 2.0(1 1,712.6 CAkCO KGB-2 1 Sas Lb DNY EXP 0.� 00 5,{/2015 PKG 8 SAN)41011E-0 J4ER; a 4.278 1 T,Int n,. 1, of r„� • • 0,0', I%%ice s� THE STATE Alaska Oil and Gas A, ,;-s 1, of/ jAsKALConservation Commission iv -icet. - -- It ik _c 333 West Seventh Avenue Ai GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \T* Main: 907.279.1433 ®F ALAS— Fax: 907.276.7542 www.aogcc.alaska.gov Danny Kane 5000 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 �� Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-184 Sundry Number: 315-643 Dear Mr. Kane: 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 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, 1416 Cathy 7 Foerster Chair --)/ DATED this G1 day of October, 2015 Encl. RBDMS O T 2 3 2015 STATE OF ALASKA eKA OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing , Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r. Re-enter Susp Well r Other: r- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory r Development r 206-044 ' 3.Address: Stratigraphic r Service p- 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23305-00 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No / KRU 1J-184 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25662,25661,380058 , 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): ' 17870 ' 3751 ' 17105' ' 3408' 8882' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 3947 13.375 3977' 2239' RECEIVED INTERMEDIATE 9248 9.625 9275' 3424' B SAND SLOTTED 3406' OCT 12 2015 LINER 8172 5.5 17105' fr/2///g >AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slots from 9289-17020' ' 3426-3388' 4.5 L-80 8767 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-SLZXP LINER TOP PACKER MD=8739 TVD=3334 PACKER-D-SAND BAKER PAYZONE CASING PACKER(PUSHED MD=8907 TVD=3364 PACKER-HRD ZXP LT PACKER MD=8933 TVD=3368 NIPPLE-4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile MD=502 TVD=502 . 12.Attachments: Description Summary of Proposal Fel 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory r Stratigraphic r Development r Service 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/21/2015 OIL r VVINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG Fol GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown E Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Danny Kane @ 265-6048 Email: Danny.Kanea(7.conocoehillips.com Printed Name Danny Kane Title: Sr.Wells Engineer Signature Phone:265-6048 Date t2-C,GT-2199 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness X315--(e 443 Plug Integrity r BOP Test VMechanical Integrity Test I' Location Clearance r Other: O lip 7-r- .. /--" tic" 357; o p 5 r ( Ai p5 P /S /4 55- p S r J , f rt v,vl o v /7 rt v t vi "Fr r its f to 2 5 0 /9 5 t /--a 1--z- Kr, f-r1155-,C(./1'tiG7=(fl- i 1-V-i-fdJ 4f-l-C �r b-i /r3�cl ���r� � Spacing Exception Required? Yes ❑ No D Subsequent Form Required: /D ~-G 01- Approved 1- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: [0'2/`/ V fit'/0 i 1/,---- Approved application is valid for 1 months f om th date of approval. submit Form and Form 10-403 Revised 5/2015 f topaf .ytachments in Duplicate 0RIGINAL ,� / 3/43----- R13DMS' L 4 al( • ConocoPhillips RECEIVED Alaska OCT 12 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 �1 AOGC October 8,2015 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover West Sak Injector KRU 1J-184/ 1J-184 L1 (PTD#206-044/206-045). KRU 1J-184/1J-184 L1 was spudded in April 2006 and completed as a dual-lateral West Sak B-&D-sand injector. After receiving permission from the AOGCC to gas-lift the well by opening the sliding sleeve,the well was initially brought on pre-production. During pre-production, a production profile log showed that only the B-sand lateral was producing and when coiled tubing was brought on the well to perform a fill clean-out,they discovered that access to the D-sand lateral was lost. After reviewing the drilling&coiled tubing data,the town engineering team determined that the D-sand lateral entry module(LEM)was installed 180°out of phase preventing access to the D-sand lateral. A rig work-over was performed in November 2006 to pull the upper completion,mill the injection packer,pull the D-sand LEM, and replace with a new D-sand LEM&upper completion. After finishing the rig work-over,the well was placed back on pre-production until January 2007 when the well was converted to water injection service. In 2014,the well failed an AOGCC-witnessed MIT IA and was shut-in. Subsequent diagnostic work has confirmed a hole in the tubing above 8,700'MD. / The proposed rig work-over of 1J-184/ 1J-184 L1 will consist of pulling the entire existing 4-t/2"upper completion to the seal assembly and replacing with a new 4-%2"upper completion to bring the well back on water-alternating-gas injection service. This Sundry is intended to document the proposed rig workover on KRU 1J-184 / 1J-184 L1 where the intent is to pull tubing and to request approval to workover this well. If you have any questions or require any further information, please call me at 265-6048 or email me at danny.kane@conocophillips.com. Sincerely, Danny Kane Senior Wells Engineer CPAI Drilling and Wells III KUP INJ 1J-184 ConocoPhiliipswell Attributes Max Angle&MD TD - Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status not y) 'MD(ftKB) Act Btm(ftKB) r rW=.+rrw,„ 500292330500 WEST SAK INJ 17,870.0 ... Comment H28(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple Laterals-13-184,516/20153:45.04 PM SSSV:NIPPLE Last WO: 12/11/2006 31.51 5/25/2006 Vesical schematic(acwafl Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - Last Tag: Rev Reason:GLV C/O hipshkf 5/6/2015 HANGER:22.8 F ;tl)ll Casing Strings i Casing Description CONDUCTOR Insulated OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Lon(I...Grade Top Thread 20 19.124 30.0 108.0 108.0 94.00 H-40 Welded I l 1 I - Casing Diption OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACEescr13 3/8 12.415 30.2 3,977.0 2,239.0 68.00 L-80 BTC Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth)TVD) Wt/Len(I Grade Top Thread il1INTERMEDIATE 95/8 8.835 27.4 9,275.0 3,424.2 40.00 L-80 BTC „.CONDUCTOR Insuhl ed;30.0-.0 Caning Description OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(ND)...Wt/Len Q...Grade Top Thread 08 1 D LINER HH 5 1/2 4.950 8,827.0 9,093.9 3,396.3 15.50 NIPPLE 502.2 Liner Details I, I Nominal ID GAS LIFT;2,040.0 Top(ftKB) Top(TVD)(ftKB) Top ncl(") Item Des Com (in) lir 8,827.0 3,350.5 80.23 HANGER Hook Hanger(outside casing) 7.740 8,848.0 3,354.1 80.25 HANGER Hook Hanger(inside casing) 5.020 j 8,854.3 3,355.2 80.24 XO BUSHING Crossover Bushing 5.000 SURFACE',30.2-3,977.0 ;7 8,907.3 3,364.3 79.99 ECP BAKER PAYZONE EXTERNAL CASING PACKER 4.910 all 9,019.5 3,383.8 80.15 XO Reducing CROSSOVER 5.504.5" 3.960 SLEEVE-G 8699.8 IIT 9,064.4 3,391.4 80.38 BENT JT 3.940 1 .1., Casing Description IOD(in) IID(in) Top(BOB) I Set Depth(ftKB) I Set Depth(ND)...WtlLen(I...Grade 'Top Thread B SAND SLOTTED 51/2 4.950 8,932.9 17,105.0 3,405.6 15.50 L-80 Hydril 521 LOCATOR 8,748.9 LINER _�_f Liner Details SEAL ASSY;8,750.0 ..., '', Nominal ID Top((tKB) Tap(TVD)(ftKB) Top Incl(") Item Des Com (in) 8,932.9 3,368.8 79.87 PACKER HRD ZXP LT Packer 7.500 1,(d 8,951.4 3,372.0 79.84 NIPPLE RS Packoff Seal Nipple 6.220 8,954.3 3,372.5 79.85 HANGER FlexLock Liner Hanger 6.230 SLEEVE-G,8,822.1 I lir r 8,963.3 3,374.1 79.90 SBE 190-47 Casing Seal Bore 4.750 17,030.1 3,389.7 79.13 Swell Packer Swell Packer wNAM connections 3.960 1,r Casing Description OD(in) ID(in) "Top)ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(L..Grade Top Thread D LINER LEM 4 1/2 3.9581 8,730.2 8 973.6 3,375.9 12.60 L-80 IBT e�° Liner Details Nominal ID Top(ftKB) Top(ND)(BOB) Top Incl(°) Item Des Com (in) PLUG;0,082.0 / 8,730.2 3,333.9 79.71 PACKER SLZXP LINER TOP PACKER 4.890 8,751.3 3,337.7 80.06 XO BUSHING CROSSOVER BUSHING 4.890 PACKER;0,907.0 ; �., 8,752.7 3,337.9 80.08 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 MI 8,772.4 3,341.3 80.20 XO BUSHING CROSSOVER BUSHING 3.930 'owl 8,814.3 3,348.4 80.23 HANGER LEM ABOVE HOOK HANGER 3.930 �II$- 8,822.1 3,349.7 80.23 HANGER LEM INSIDE HOOK HANGER 3.688 8,882.1 3,359.9 80.11 NIPPLE CAMCO DB NIPPLE W/DB PLUG 3.562 SEAL ASSY;8,973.0 = 8,970.4 3,375.3 79.93 SEAL ASSY BAKER SEAL ASSEMBLY 3.900 D LINER LEM;8,730.1-8,973.6 '� Tubing Strings. 'a' Tubing Description String Ma...ID)in) Top(BOB) Set Depth(ft..Set Depth(ND)(...Wt(Ibift) Grade Top Connection TUBING WO 4 1/2 3.958 22.8 8,767.0 3,340.3 12.60 L-80 IBTM Completion Details Nominal ID D LINER NH;8,827.0-9,093.9 -al_ Top(ftKB) Top(TVD)(ftKB) Top Incl("I Item Des Com )i)) 22.8 22.8 0.06 HANGER Vetco Gray Hgr 11"x 4-1/2"w/4.909"MCA Top Conn 3.500 502.2 502.1 4.07 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.875"No-Go Profile 3.875 INTERMEDIATE:27.4-9,275.0 8,699.8 3,328.4 79.21 SLEEVE-C Baker 4.5"CMD Sliding Sleeve w/Camco 3.81"'DB'P 3.810 (CLOSED 8/23/14) I- 8,748.9 3,337.2 80.02 LOCATOR BAKER LOCATOR 3.880 8,750.0 3,337.4 80.04 SEAL ASSY Baker 4.74"SBE Seal Assy.w/4.5"IBT box up I. 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc,) Top(TVD) Top Incl Top(BOB) (BOB) (") Des Com Run Date ID(in) 8,822.1 3,349.7 80.23 SLEEVE-C 3.688"ISO SLEEVE ACROSS LEM 8/29/2014 8,882.0 3,359.9 80.11 PLUG 3.562"DB PLUG 8/29/2014 0.000 8,907.0 3,364.2 79.99 PACKER D-SAND BAKER PAYZONE CASING PACKER 5/22/2006 4.910 (PUSHED DOWNHOLE FROM ORIGINAL LEM) 8.973.0 3,375.8 79.94 SEAL ASSY D-SAND BAKER SEAL ASSEMBLY(FROM 5/23/2006 3.900 ORIGINAL LEM) Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots8 Top(ftKB) Btm(ftKB) (BOB) (ftKB) Zone Date t) Type Com SLOTS;9389.0-17,020.0 9,289.0 17,020.0 3,426.2 3,387.8 WS B,WS C, 5/11/2006 32.0 SLOTS Alternating solid/slotted WS B,1J-184 pipe-6 blank jts/5 slotted jts/2 blank jts: 0.125"x2.5"032 spf@ 4 Circumferential adjacent rows,3" Centers staggered 18 deg.,3 ft.non-slotted ends Mandrel Inserts St ati i on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (805) Make Model OD(in) Dery Type Type (in) (psi) Run Date Com '- i' 2,040.0 1,742.6 CAMCO KGB-2 1 Gas Lift DMY EXP 0.000 0.0 5/4/2015 PKG 11111- B SAND SLOTTED LINER; 8,932.5-17,105.0 111 KUP INJ • 1J-184 ConocoPhillips Alaska,Inc. t..,,..iRmips ••• Multiple Laterals-1/-184,5/6/20153:45.05 PM Vertical schematic(actual) FANGER:228 : lit; Notes:General&Safety End Dace Annotation 10111113111.111.11.11411.11.111111111111111, MAL 5/24/2006 NOTE:CANNOT ENTER L1 LATERAL 5/24/2006 NOTE:MULTI-LATERAL WELL:1J-184(B-SAND),1J-184L1(D-SAND) 1/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0REV __CONDUCTOR Insulated.30.0-A.A/�.~N./ 10.0 NIPPLE:502.2 GAS LIFT;2,040.0 Ele I.; ))3 1 SURFACE;30.23,977.0 0 SLEEVE;8,699.8 1 1 I 1F_i LOCATOR;8,748.9 s—'- SEAL ASSY;8,750.0 rit81 SLEEVE-C'.8,822.1 Ill ¢ 101 It Is. 41 ri ll i PLUG;8,882.0 i///� PACKER;8,907.0 ,T,-'' 4lilt. ;.II SEAL ASSY;8,973 0-‘ _ ' D LINER LEM;8,730.1-8,973.6 A D LINER HH:8.827.0-9,093.9 . INTERMEDIATE;27.4-9,275.0 SLOTS,9,289.0-17,520.0 l 1 IMF B SAND SLOTTED LINER; 8,932.9-17,105.0' 111 • • KRU 1J-184 (& 1J-184 L1) —Proposed Rig Workover Pull & Replace Upper Completion PTD #:206-044 (& 206-045) Current Status: KRU 1J-184(& 1J-184 L1),a West Sak B-&D-sand dual-lateral injector,is currently shut-in after failing multiple MIT-IAs as a result of a tubing leak identified to be shallower than 8,700'MD. Please see below for the well integrity history of 1J-184,including the aforementioned failure which required the well to be shut-in: o 2006(April)-The KRU 1J-184& 1J-184 L1 dual lateral injector was drilled and completed. • The well was brought on pre-production. PPROF splits showed all production was coming from the D-lateral. Coiled-tubing unable to enter D-lateral for fill clean-out. Suspect misalignment of the D-lateral LEM(lateral entry module)during installation. o 2006(November)-KRU 1J-184 is worked over to replace the D-lateral LEM. Regained D-lateral access. o 2014-Failed a MIT-IA(15-May-2014). • The MIT-IA failed during a four-year AOGCC-witnessed test leaking 2.8 gpm at 1,205 psig. • The tubing&IC pack-offs were pressure-tested successfully. Either failed completion or casing integrity has caused the leak(not at surface). • Coiled tubing cycled the Baker CMD sliding sleeve open&close,but follow-up MIT-IAs still failed,leaking 0.16 bpm at 2,070 psig&0.25 bpm at 2,175 psig. • Coiled tubing set a 3.562"DB-P plug in the DB nipple profile at 8,882'MD to isolate the B-sand lateral. Set an isolation sleeve across the D-sand LEM at 8,814'MD to isolate the D-sand lateral. Attempted a MIT-T but failed the pressure-test. Applied coiled tubing weight and attempted a MIT-T,MIT-IA,&CMIT-TxIA-all tests failed. Diagnostic work inconclusive on leak location. • Coiled tubing set a CAT standing valve at 8,700'MD(immediately above the Baker CMD sliding sleeve). Attempted a MIT-T-failed. Attempted a CMIT-TxIA,passed. • Confirms there is a tubing leak above 8,700'MD. • Confirms integrity of the IA(tubing x production casing,surface to the SLZXP packer). • Suspect that the isolation sleeve and/or the DB-P plug are leaking(why prior coiled- tubing work failed an MIT-T,MIT-IA,&CMIT-TxIA where test pressure was leaking to the West Sak sands). • Slickline attempted a lead-detect log but the leak rate was too low to be conclusive(<0.25 bpm). Scope of Work: Pull the 4-1/2"upper completion&run a new 4-1/2"upper completion. General Well Info: Well Type: Injector MPSP: 1,485 psi using MASP=(PP-(0.1*TVD)),assuming dry gas gradient to surface. Reservoir Pressure/TVD: West Sak B/D-1,825 psi/3,409' TVD(10.3 ppg EMW) Wellhead Type/Pressure Rating: ABB Vetco Gray Horizontal(13-3/8"5M x 4-1/16"5M) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-IA Failed 14-May-2014 Last Passed 14-May-2010 CMIT-TxIA Passed 02-May-2015 Production Casing Integrity Confirmed MIT-OA-Open Shoe Earliest Estimated Start Date: 21-ac_T-2Cet5 Production Engineer: Michael Sullivan Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com • KRU 1J-184 (& 1J-184 L1) — Proposed Rig Workover Pull & Replace Upper Completion PTD #:206-044 (& 206-045) Summary of Proposed RWO Procedure: Proposed Pre-Rig Work: 1. RU Coiled Tubing. a. Perform a leak-detect log to find&locate the leak(s). b. Perform a CMIT-TxIA to confirm that the Isolation Sleeve&DB plug were set&holding pressure. c. Open the Baker CMD sliding sleeve at 8,699'MD. d. RD Coiled Tubing. 2. Set the BPV. Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull the BPV. Circulate seawater around through the open Baker CMD sliding sleeve at 8,699' MD. Obtain SITP&SICP;if pressure is observed at surface,calculate the required KWF and circulate around as necessary. Verify the well is static. 3. Set the BPV,ND the tree,set the blanking plug,NU BOPE,&test BOPE to 250/3,500 psi low/high. 4. Pull the blanking plug&BPV,screw in the landing joint,BOLDS,&unseat the tubing hanger. 5. P/U on the tubing&pull the tubing hanger to the rig floor. Verify that the well is static& TOH laying down the existing 4-1/2"upper completion(entire upper completion to the base of the locating seal assembly). 6. M/U&TIH with the new 4-1/2"upper completion as per design to just above the casing sealbore receptacle. 7. Engage the seal assembly until fully-located into the casing sealbore receptacle. P/U from fully-located,space- out 7',&mark the pipe at surface. 8. Space-out the completion with tubing pups and M/U the tubing hanger, 9. Swap the well over to corrosion-inhibited seawater across the upper completion. 10. Land the tubing hanger&RILDS. 11. Pressure-test the tubing&IA. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV(IA to tubing shear). 12. Back-out the landing joint&install the BPV. 13. ND BOPE,NU the tree,install the tree test plug,&pressure test the tree to 250/5,000 psi. Pull tree test plug. 14. Freeze protect the well through the SOV in GLM#1. 15. Set the BPV. 16. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull the BPV. 2. RU Coiled Tubing: a. Remove the SOV from GLM#1 &replace with a DV. b. Pull the Isolation Sleeve from across the D-Sand LEM c. Pull the 3.562"DB Plug set within the DB Nipple at 8,882'MD. d. RD Coiled Tubing. 3. Reset well house(s)&re-attach flow line(s). 4. Turn the well over to operations. 0 • ❑ _c `__ i.6O `.eoW❑ . �` $ . olO allom '43,?—s,-,- 47., ,eeh. n ..1- : a va G 2Eo p x> u=m `. O ` C C 10n I 3 0 _ JJ m _80, C 1 N R .-gL " C11a L re ao 2 ` t ❑ EO _ ono o7t> $ 0 x 2r o ` , 2 ,-§.H W .= ;,4,t a iii .fiIA ?a m x>. it; _j f6 ->° m o . _ o3c +4-1 e, d3 am - _cu) I) y _ t _ 0 AK ' N E = J O10N N L2 on " oo J i K ` N T.0,.- 0 :1p C \ 1 O_ ` . 1- ^ � a 1,$ `2 .13v 2 ° f � o W g a' o y_ O n} } Um ms N s ' N P.1-3I8 . y `ma _ =` wmC x❑ 0, „.,,o-, = Y e 0]F J O Fo Ug ns .7-. ayr yO . y- v X Y mok.PVu0.. ZoEL. -�m Y j M_ CES e'l 23 tg-r- Ilti FO co �N .. U lieLE---iii , Tm m xN bIl d 24 11 S Ea J n _*,-.,-q _ L L O N ❑ LI, m O_ X o m v 11 f s.pr 0 R mQ'n mrnJ -a ,L 0 .iOO ^ , ° a1,40'2 2 c ++ C JoQ tn CD n O _ ..- .c S� - , N,mN ; 23v A` (0 tem ,:r 444. �r c °N iiHf” • 2 to o I1i1mo ,==« 3 IC cCe Y 3 O iL. maw 11 4000 °'a �b ` ' ca V = \ J` MN V :-:702:i�o ❑ co m a ^' :L: = ci.La Uv = N0 Nao c,Az,\ OO N .z, _ � Jc ° ~x in N Em _ \ N a X Jc ailjoitc, in Y2' '''' LL yp — e 2 ❑aO O O J 1,t 6 .._,.,,,. / 7. N1-, ir? ,,,..,,,..„,t ., e„,, ..„ ❑LL Z >. 0 012 ❑a Q O X Y ie. - _ O 2 o r O 0„. c� ''I 0 i� yN 2ma mF f m o_ y n x• c ' .40 m 0," m O m Y .I \ `^ * ° L J \ 31 F pl S ,q' � N I O C ! m u 3 ❑ c a A r X n❑o o 3 a -, ,2,-7> d a m : A \ a m n~x ❑ ❑ • U 2 3 Zam 2aJ m ❑ `3 N ' Z !c !J w 7,72 ' bOi uM 722 N ` N 7 \� \e021 �: .E.... . 0 `` =a ea' mh� 20 CC mW nyNQW,= °",,-1 82mo O N N«N3 \ E o2 °0 a> .o awe U a a j /U . m = Qm K m ap a I W t fzom F °'x mM .2 ;;-?°'= xJ J NG ON FF L v 0o 00 v❑ x a- € m ::•i qui .4_,.._.._,...i k,.c 0.1 lu. �'� ma � as;;AO J 1:;"? K n • ~, • 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. 02~`Q - V ~- 4- Well History File Identifier Organizing ~do~e~ Two-sided ~~I II~~~~ II ~~I ~~ III ^ Rescan Needed III IIIIII II II III IN RESCAN DIGITAL DATA OVERSIZED (Scannable) ~lor Items: 1~Diskettes, No. ~ ^ Maps: V~ ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: D ~ /s/ Project Proofing II I II'l II I (III I I III BY: Maria Date: iJ ~ /s/ ~' Scanning Preparation ~ x 30 = + ~ =TOTAL PAGES~,~ (Count does not include cover sheet) ,^ n BY: Maria Date: /s/ ~/ r Y Production Scanning Stage 7 Page Count from Scanned File: -~~ (Count does include c/over sheet) Page Count Matches Number in Scanning Preparation: I/ YES NO BY: Maria Date: '~ ~ ~ / O ~ /s/ Stage ~ If NO in stage 7, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II I) II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: a,a~.~~e~.~ iiiuiuuuuiiu 10/6/2005 Well History File Cover Page.doc • • Page 1 oft Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Saturday, September 17, 2011 6:21 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RE: RLPP /SSV defeated on 1J -156 West Sak injectors and returned to service for 1J -180 and 1J- 184: 17- Sept -2011 Tom and Jim, The low pressure pilot (LPP) on the following well was defeated on 09/17/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV has been tagged and the status is recorded in the "Facility Defeated Safety Device Log" since the wells is below 500 psi. As of 1800 hrs on 09/17/2011, wellhead injection pressure and injection rates are as follows for the well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1J-156 (206- 067,206- 068,206 -069) 437 899 The AOGCC will be notified when the injection pressure on this well has increased so as to remain above 500 psi and the LPP /SSV function has been returned to normal, in accordance with "Administrative Approval No. CO 406B.001." The injection pressures has increased on the following wells so as to remain above 500 psi a_ nd the LPP/SSV function has been returned to normal. Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1 J -180 (206- 150,206 -151) 555 471 071-184 • •-04 , 06 -045) 539 640 Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 . {fat C pager 659 -7000 765 om: CPF1 Prod Engr Sen : , September 16, 2011 6:44 PM To: 'tom.ma malaska.gov'; 'jim.regg @alaska.gov' Cc: CPF1 DS Lead Tec , --- 1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, •1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multip - e -st Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeate• a- 16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigg -. ility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safe • - .qe Log" since the 9/19/2011 Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, September 16, 2011 6:44 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 1J West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1 J -105 (207- 027,207- 028,207 -029) 345 639 1J-118 (206- 176,206- 177,206 -178) 327 1020 1J-127 (206- 047,206 -048, 206 -049) 337 934 1 J -154 (205- 036,205 -037) 369 623 1J-160 (207- 015,207- 016,207 -017) 352 568 1J-164 (205 - 144,205 -145, 205 -146) 479 1082 1 J- 206 -1 06 -151) 537 478 J -184 (206 -044 06 -045) 502 646 The AOGCC will be notified when the injection pressures have increased so as to remain above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 pager 659 -7000 765 9/19/2011 MEMORANDUM To: Jim Regg ~~` 6I i I iu P.I. Supervisor j FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS'ALASKA INC 1J-184 KUPARUK RIV U WSAK 1J-184 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK iJ-184 API Well Number: 50-029-23305-00-00 Insp Num: mitRCN100516155243 permit Number: 206-044-0 Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 5/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P.T.D IJ-lsa zoboaao Type Inj.~W TVD TypeTest ~ SPT i Test psi 3334 I~oo v jA 92s pA ~ I6s 1700 ! zzo 1680 lza 1680 ~ t~z Interyal4YRTST per, P,, Tubing 598 598 s97 597 Notes: pi,;;~. T~q'~ ~e~4- f~o~; y~,.r ,bt~•~ L:.~,: ~i •. Monday, May 24, 2010 Page 1 of 1 • > `:.~:. ,~ ~c ~~ ~. 'g, ~ «~'" r ; ~ "~ r," ~_ r }I r ~ ~i' ~ f F • h ~ „e~,,,~~. +'~!~" MICROFILMED 6/30/201.0 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1J ~.~ , t ~ ~ (, ~- DATE: OPERATOR REP: 05/14/10 Colee /Phillips - AES ~~ ~ .~-(' ~. J J ~ ~~` AOGCC REP: Bob Noble S ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 Type Inj. W TVD 3,566' Tubing 657 656 655 654 Interval 4 P.T.D. 2061100 Type test P Test psi 1500 Casin 990 1,700 1,680 1,680 P/F P Notes: OA 165 205 172 165 Well 1J-105 Type Inj. W TVD 3,639' Tubing 558 558 558 557 Interval 4 P.T.D. 2070270 Type test P Test psi 1500 Casing 1,098 1,800 1,780 1,780 P/F P Notes: OA 155 156 156 156 Well 1J-118 Type Inj. W TVD 3,599' Tubing 657 658 658 658 Interval 4 P.T.D. 2061760 Type test P Test psi 1500 Casing 1,100 1,790 1,780 1,780 P/F P Notes: OA 175 192 177 175 Well 1J-122 Type Inj. G TVD 3,684' Tubing 1,751 1,751 1,751 1,750 Interval 4 P.T.D. 2070700 Type test P Test psi 1500 Casing 809 1,690 1,640 1,620 P!F P Notes: OA 141 214 174 156 Well 1J-127 Type Inj. W TVD 3,482' Tubing 620 620 622 622 Interval 4 P.T.D. 2060470 Type test P Test psi 1500 Casing 1,020 1,700 1,680 1,680 P/F P Notes: OA 206 273 260 253 Well 1J-136 Type Inj. N TVD 3,503' Tubing 600 600 600 600 Interval 4 P.T.D. 2061540 Type test P Test psi 1500 Casing 276 1,700 1,670 1,660 P/F P Notes: OA 173 183 182 180 Well 1J-154 Type Inj. W TVD 3,437' Tubing 624 624 624 624 Interval 4 P.T.D. 2050350 Type test P Test psi 1500 Casing 1,098 1,850 1,840 1,840 P/F P Notes: OA 527 527 527 527 Well 1J-156 Type Inj. W TVD 3,410' Tubing 628 625 623 620 Interval 4 P.T.D. 2060670 Type test P Test psi 1500 Casing 1,147 1,900 1,890 1,890 P/F P Notes: OA 206 206 206 205 Well 1J-160 Type Inj. W TVD 3,212' Tubing 626 626 626 i~ 625 Interval 4 P.T.D. 2070150 Type test P Test psi 1500 Casing 925 1,680 1,650 1,640 P/F P Notes: OA 332 333 333 334 v/ MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubing 580 578 576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P/F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 . 1,866 1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubing 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casing 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P/F P Notes: OA 165 220 178 172 TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test V ,v/ V INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s lr~ MEMORANDUM To: Jim Regg ~~~ ~r/J`~'~ P.I. Supervisor ~ I FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 15, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-184 KUPARUK RIV U WSAK 1J-184 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1J-184 API Well Number: 50-029-23305-00-00 Inspector Name: John Crisp Insp Num: mitJCr090602154815 permit Number: 206-044-0 Inspection Date: 5/28/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- ~-1 J-] 84 ~ Welt Type Inj. N T'~ 3337 IA 1056 ~ 1785 1733 1719 ' - - P.T.D 2o6oaao TypeTest SPT' Test psi Leo'" ~ OA ~ lal 208 i ]so la7 P Tubin 600 4YRTST g ~ Interval P/F 600 I 600 600 ; _~_ L_ - _ - Notes: 4.8 bbl's pumped for test. Well not injecting @ the time of test. I told Operator since they were ready to pump on the well to PT & test the well & my Supervisor woud make determination on status of test. 1Lti ~ r~<'~ r,~ l~'~7iT' ~ s 15~'~s ~ ~~;. 1 ° ~ a^ r.'_ a E..a i [ k.~ r... ~ ~/ ~ '~ Monday, June 15, 2009 Page 1 of 1 LPP/SSV no longer defeated on 1J-184 - OS-JUNE-09 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, June 05, 2009 10:28 AM To: 'CPF1 Prod Engr' Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr; Regg, James B (DOA) Subject: RE: LPP/SSV no longer defeated on 1J-184 - 05-JUNE-09 Please note that the permit to drill number given is not correct for 1J-184. The correct number is 206-044. 203-027 is for 1 C-174. It appears that the well name was edited from an earlier message, but not the PT . No need to send a revised message to AOGCC. Tom Maunder, PE AOGCC From: CPF1 Prod Engr [mailto:n1269@conocophillips.com] Sent: Friday, June 05, 2009 10:24 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr Subject: LPP/SSV no longer defeated on iJ-184 - 05-JUNE-09 Tom /Jim, The low pressure pilot (LPP) on 1 J-184 (PTD 203-027) was returned to service 6/05/2009. Current wellhead pressure is 530 psi, injection rate is 660 bwpd. Thank you for your assistance, if you have any questions please contact me. David Lloyd Lagerlef/Kenneth Lloyd Martin CPF1 Production Engineers n 1269@conocophillips. com 659-7493 pager 659-7000 765 ~~;~ ~l.S~ 'v ~~ ~~(JJ ~.,,~ k;'i ~ . , 6/5/2009 LPP/SSV defeated on 1J-184 ~-JUNE-09 • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269@conocophillips.com] Sent: Wednesday, June 03, 2009 2:50 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK Problem Well Supv; Jenkins, Lubbie Allen; Gangl, Melissa A; Hibler, Kaycee; NSK West Sak Prod Engr ~ (, Subject: LPP/SSV defeated on 1J-184 - 03-JUNE-09 ~~, ~ ~° ~' ~ "1 { ~~ Tom/Jim, ~ D~~~t.~~ ~ ~ -" ~- The low pressure pilot (LPP) on 1 J-184 PTD 2 27 was defeated 6/03/2009 when the well was returned to service after being shut in 6/04/09 for a ch a change out. Current wellhead pressure is 479 psi, injection rate is 360 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001 ". David Lloyd Lagerlef/Kenneth Lloyd Martin CPF1 Production Engineers n1269@conocophillips.com 659-7493 pager 659-7000 765 ~' ~,~Q ~4 ,~L ~ 6/3/2009 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 ~~~ S~F x ~, 2~D8 Dear Mr. Maunder: a~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6t",2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • w ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 LPPISSN returned to normal on 1J-184 • • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n163$@conocophillips.com] Sent: Saturday, August 02, 2008 3:28 PM To: NSK West Sak Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv Subject: LPP/SSV retumed to normal on 1J-184 Tom /Jim, Page 1 of 1 The LPP/SSV function on 1J-184 (PTD 206-044. 206-045) was returned to normal on 8!2/2008. Current injection rate is 1368 bwpd at 544 wellhead pressure. Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Holler NSK West Sak Production Engineer ConocaPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@CanocoPhitlips.com ~~~~ AU G ~; ~ 200$ From: NSK West Sak Prod Engr Sent: Saturday, July 19, 2008 4:26 PM To: 'Maunder, Thomas E (DOA)'; 'jim.reggpalaska.gov' Cc: CPFi pS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1J-84 Tam /Jim, The low pressure pilot (LPP) on 1J-184 (PTD 20fi-044, 20fi-045) was defeated on 7/19/2008 when the well was retumed to service after being shut in since 6/12/2008. Current wellhead pressure is 375 psi; injection rate is 600 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device og. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is retumed to normal, in accordance with "Administrative Approval No. CO 40613.001." Please let me know if you have any questions. Regards, Eric Holler / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 8/3/2008 ~, ~~ Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Saturday, July 19, 2008 4:26 PM To: Maunder, Thomas E (DOA); Regg, James 8 (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Probiem Welt Supv; NSK West Sak Prod Engr Subject: LPPISSN defeated on 1J-84 Tom /Jim, The low pressure pilot (LPP) on 1J-184 (PTD 206-044, 206-045) was defeated on 7/19!200$ when the well was returned to service after being shut in since 6!12/2008. Current wellhead pressure is 375 psi; injection rate is 600 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device ,~ og. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, Eric Holiar / Hai Nunt West Sak Production Engineer ConocaPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 ~C~N~® JUL ~ ~ 200 7/20/2008 a s' J u,r.,~ DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060440 Well Name/No. KUPARUK RIV U WSAK 1J-184 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23305-00-00 MD 17870 TVD 3751 Completion Date 5/25/2006 Completion Status 1-OIL Current Status 1 WINJ IC Y REQUIRED INFORMATION _ Mud Log No Samples No Directional Survey ~ Ye~ DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name D D Asc Directional Survey "Cog Corrosion ED C Lis 13988 Induction/Resistivity ED C Asc 13988~nduction/Resistivity Rpt 13988 Induction/Resistivity I~og Production ~g Production ED C Lis 14575 °Ihdu tion/Resistivit y c Cog Pressure (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 28 17870 Open 6/27/2006 5 Col 1 6080 8920 5/24/2006 USITlGR/MaxTrac Cement & Corrosion Log 12-May- 2006 0 0 Open 7/19/2006 LIS 0 0 Open 7/19/2006 Text 0 0 Open 7/19/2006 15 Blu 1 100 8900 Open 9/12/2006 PP, WeIITec tractor Conveyance 29-Aug-2006 Blu 1 100 8910 Open 1/5/2007 PPL w/Welltrac Tractor 30- Dec-2006 3953 17870 Open 4/4/2007 LIS Veri, GR, FET, ROP 5 Blu 1 18 3065 Case 4/20/2007 SBHPS, TEMP, PRES, GR, CCL 12-Apr-2007 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /`"`~ f\ Chips Received? Y.~., Analysis YXN__ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received?~ N Formation Tops ~'),/ N DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060440 Well Name/No. KUPARUK RIV U WSAK 1J-184 Operator CONOCOPHILLIPS ALASKA INC MD 17870 TVD 3751 Completion Date 5/25/2006 Completion Status 1-OIL Current Status 1WINJ Comments: API No. 50-029-23305-00-00 UIC Y Compliance Reviewed By: ____._____ Date: ~ ~- ~.~lv~ LPP/SSV returned to normal on 1J-184 ~ Page 1 of 2 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.comj Sent: Sunday, May 18, 2008 5:07 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr Subject: LPP/SSV returned to normal on 1J-184 Tom /Jim, The LPP/SSV on 1J-184 (PTD 206-044'206-045) was returned to normal on 5113/2008. Current injection rate is 670 bwpd at 594 psi wellhead pressure. Please let me know if you have any questions. Regards, Hai Hunt From: NSK West Sak Prod Engr Sent: Sunday, May 11, 2008 7:25 AM To: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPFi DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1]-184 Tom /Jim, The low pressure pilot (LPP} on 1J-184 (PTD 206-044, 206-045) was defeated on 5/11/2008 when the well was returned to service after being shut in since 4/25/2008. Current wellhead pressure is 446 psi; injection rate is 1260 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injec#ion pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 5/19/2008 LPP/SSV defeated on 1J-184 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Sunday, May 11, 2008 7:25 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1J-184 Tom /Jim, The low pressure pilot (LPP) on 1J-184 (PTD 206-044, 206-045) was defeated on 5111/2008 when the well was returned to service after being shut in since 4/25/2008. Current wellhead pressure is 446 psi; injection rate is 1260 bwpd. The LPP and 5SV have been tagged and their status is recorded iri the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 5/12/2008 ~~ Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, March 07, 2008 3:52 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 10-404 converting a well to injector without packer MD Attachments: 1C-20.pdf; 1J-102.pdf; 1J-156.pdf; 1J-170.pdf; 1J-127.pdf; 1J-184.pdf Jim, Here are the schematics of the motherbores for the list of wells below. Let me know if you need any additional data or if the 10-404's need to be corrected and resubmitted. MJ Loveland ConocoPhillips Well Integrity Project Supervisor 659-7043 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, March 03, 2008 1:58 PM To: NSK Problem Well Supv Cc: Fleckenstein, Robert J (DOA) Subject: FW: 10-404 converting a well to injector without packer MD Martin - Page 1 of 2 ~ -~ d 4-4- West Sak wells have some unique approvals as you are no doubt aware. We discussed the exemption from packer requirements (20 AAC 25.200) - I am still looking into whether that is a well by well approval or some blanket authorization/pool rule. West Sak injectors are, I believe, also completed packerless but do have a seal bore assembly and a liner top packer for the tieback string isolating the injection formation from the tubing-casing annulus. Below is a list of wells from a search of our well files that do not show a packer depth on the well completion report (10-407} or report of sundry operations (10- 404}. Please provide the MD and TVD of the uppermost liner top packer/seal bore assembly. Also, please remind those submitting the 404`s and 407's of the uniqueness for these West Sak completions Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Fleckenstein, Robert J (DOA) Sent: Monday, March 03, 2008 1:06 PM To: Regg, James B (DOA) Subject: 10-404 converting a well to injector without packer MD Jim, The following wells have 10-404 submitted converting them from producers to injectors and have "none" or "no packer" in the packer MD data block: 2061100 WSAK 1 J-102 2060670 WSAK 1 J-156 3/12/2008 ~U (~,.-®~1~~ • ~ Page 2 of 2 2060620 WSAK 1 J-170 2060470 WSAK 1 J-127 2060440 WSAK 1 J-184 2051230 KRU 1 C-20 BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 ~'6'Je~~se r€«t~v z~r~~{- e~~raii c~c1~i~•~ss bc~f.~._tlc,cktttstt,~n~?>alasca.~,c~`- 3/12/2008 r~- ' Cara4coPhllips Alaska, tnc. 1J-184 TUBING ~ SSSV T e: I (0-$768, Annular Fluid: OD:4.500, Reference Lo ID:3.958) _ Last Ta Last Taq Date: Casin 5trin - t~ ~~' KRU 1 J-184 sau~uu vvefl T e: INd An le m iS: de m Ori Com letion: 5/25/2006 An le TD: 47 de 17870 Last W/O: 12!11/2006 Rev Reason: FORMAT UPDATE 3 Ref Lo Date: Last U date: 12/28!2007 TD: 17870 ftKB Max Hole Anqle: 93 deq (a7 15501 ALL STRINGS Descri lion Size To Bottom TVD Wt Grade Thread SURFACE 13.375 0 3977 2239 68.00 L-80 BTC INTERMEDIATE 9.625 0 9275 3424 40.00 L-80 BTCM CONDUCTOR 20.000 0 108 108 94.00 H-40 WELDED WINDOW L1 9.625 8848 8849 3354 0.00 B-SAND SLOTTED LINER 5.500 8932 17105 3406 15.50 L-80 HYD x.71 /RTf` AA XO BUSHING (s77z-a77a, OD:6.020) PUP (8774-8814, OD:4.500) COUPLING (8962-8963, OD:7 000) Pert (9289-17020) ,.lm~+cea =~. '.i ../ ~~ I ~ ~I~- I Y ~~~a~1 r - _ ~. ~ r r s I I .,' . I. I II I i I Tubing Strang - I ~Dlrvu 5¢e To Bottom T'lD Wt Gray n... P. 'ie _ Thread Perforations Summary ktlervai TVD Zone Status Ft SFF Date T e Comment 9289 - 17020 3426 - 3388 WS B,WS 7731 32 5/11/2006 SLOTS Alternating slotted/solid pipe - C.WS B aura. slurred IPn~rhs 5 jrs Gas Lift MandrelsNalves St I MD TVD Man Mfr rMan Type V Mfr V Type I V OD Latch Port (TRO I Date Run Cmnt 1 2036 1740 CAMCO I KBG-2 DMY ~ BK-5 0.000 0 3/25/2007 ~~ Other (plugs, equip., etc.) - B-SAND LINER & D-SAND LEM DETAIL i ncnth I rVn I Tvn> I. - nncrriminn - _ ._.. _ f _ In 1 8730 3334 PACKER D-SAND LEM SL ZXP LINER TOP PACKER 12/8/2006 7.500 8751 3338 XO BUSHING D-SAND LEM CROSSOVER BUSHING 1/8!2006 4.890 8753 3338 SBR D-SAND LEM 190-47 CASING SEAL BORE RECEPTACLE 12/8/2006 4.750 8772 3341 XO BUSHING D-SAND LEM CROSSOVER BUSHING 12/8/2006 3.930 8774 3342 PUP D-SAND LEM PUP 3.980 8814 3348 HANGER D-SAND LEM ABOVE HOOK HANGER 3.930 8822 3350 HANGER D-SAND LEM INSIDE HOOK HANGER 3.688 8827 3351 HANGER D-SAND BAKER MOD PZ HOOK HANGER INSIDE CSG 7.740 8933 3369 PACKER B-SAND'HRD' ZXP LINER TOP PACKER 7.000 8951 3372 NIP B-SAND'RS' PACKOFF SEAL NIPPLE 6.230 8954 3372 HANGER B-SAND FLEXLOCK LINER HANGER 6.230 8962 3374 COUPLING B-SAND COUPLING 4.880 8963 3374 SBE B-SAND 190-47 CASING SEAL BORE EXTENSION 4.750 17030 3390 PACKER B-SAND SWELL PACKER VAM CONNECTIONS 3.960 I I /UbL I 33Y/ I JVIIV 1 I C-JHNIJ rStIV I JVIN I W/NV1[' l)I<HNlir Yl-[:l.!-.U HNU VvtLUCU ~I"IU I I 4 `~.'~II I Other (plugs, equip., et c.) -COMPLETION De h TVD T e Descri lion ID 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 501 501 NIP CAMCO'DB-06' NIPPLE w/3.875" NO GO PROFILE 3.875 8700 3328 VALVE 3.81 DB CAT STANDING VALVE SET IN CMD 2/10/2007 0.000 8700 3328 SLEEVE-O BAKER 4.5" CMD SLIDING SLEEVE w/CAMCO 3.81 'DB' PROFILE -OPEN 3.812 '"' NOTE: GBH-22 LOCATOR SPACED OUT 4.7' ABOVE FULLY INSERTED""" 8750 3337 SEAL BAKER SBE SEAL ASSEMBLY 3.880 8767 3340 SHOE Ml1LE SHOE 3 95R ' General Notes ~ ~ Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Tuesday, June 12, 2007 2:15 PM To: Thomas Maunder Subject: RE: Notification of LPP Defeat on West Sak Pre-Produced Injectors Page 1 of ~,~ _-_. ~o ~-~ ~~ Tom, The only West Sak wells that have defeated pilots are 1 J-136 and 1 J-180. The LPP on 1 J-102 and 1 J 184 were activated 2 weeks ago and I was informed that you were notified at that time. If this is not the case please let me know. Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 i}~,~~ 4~ 4` ~ r-+ .,~ ~`) {} ~ C~ `~,.:,~" w, ~~'i:t '~i `w~6:w* l-~ ~1 ~ ? ~. c. ~ LI V J From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, June 12, 2007 1:38 PM To: NSK West Sak Prod Engr Subject: Re: Notification of LPP Defeat on West Sak Pre-Produced Injectors Pete or Hai, Do you have a listing of the WS injectors where the pilots are defeated? Thanks, Tom Maunder, PE AOGCC NSK West Sak Prod Engr wrote, On 6/11/2007 3:44 PM: Tom / Jim, This email is to notify the AOGCC that 1 J-136 and 1 J-180 West Sak pre-produced injectors, LPP (Low Pressure Pilot) have been defeated in accordance with "Administrative Approval No. CO 4066.001 ". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". Both wells required a non-adjustable choke insert on the water injection line to limit and control water injection at lower rates. Following are the current well conditions: 1J-136: Converted from pre-production to injection 06/08/2007. Injecting 1900 bwpd at 92 psi. 1J-180: Converted from pre-production to injection 06/09/2007. Injecting 1050 bwpd at 17 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. ~~~~ ~-~~- ~`"° sii gi2oo9 - RECEIVED ~~o~ STATE OF ALASKA APR 2 4 ?Q~J ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOId~ka oil & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other' 0 Prod to WINJ 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: ConocoPhlllips Alaska, InC. Development ^ Exploratory ^ 206-044 / 3. Address:. Strati ra hic 9 P ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23305-00 - 7. KB Elevation (ft): 9. Well Name and Number. RKB 0' 1J-184 8. Property Designation 10. Field/Pool(s): ADL 25662, 25661, 380058 Kuparuk River Field /West Sak OiI Pool 11. Present Well Condition Summary: Total Depth measured 17870' ~ feet true vertical 3751' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length. Size .... MD TVD Burst Collapse Structural _ _ _ _ CONDUCTOR 108' 20" 108' SURFACE 3977 13-3/8" 3977 INTERMEDIATE 9275' 9-5/8" 9275' WINDOW L1 1' 9-5/8" 8849' B-SAND SLOTTE 8173' 5-1/2" 17105' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8768' MD. Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 501' 12. Stimulation or cement squeeze summary: Intervals treated (measured) None Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tobin Pressure Prior to well operation 1263 481 51 1050 213 Subsequent to operators 941 1654 71 14. Attachments _ _ __ _ _ ___ 15.1IVeII 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: Oi10 Gas ^ WAG ^ GINJ ^ WINJ Q 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. . Exec contact Bob Christensen /Bob Buchholz Printed Name Robert W . Buchholz Title Production Engineering Technician ~J ,, / ~~ Signature G~ vl~, /°~~.~;c~'" " '' ~~ Phone 659-7535 Date ~ /Z Z /~~ Form 10-404 Revised 04/2004 n' ~~~IIS BFL., APR ~ ~ ZD07~ \, A ~ Submit Original Only • 1J-184 DESCRLPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/15/07 Commenced Water Injection ;y ia1 ~~ ~'.~~ ~:~n~. t ~s~~r;~i~~~c~r'~. Schlumberger -DCS ~ slam= 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.4219 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 04/20/07 1A-10 11638846 INJECTION PROFILE 04/05107 1 2L-313 11628996 LDL 04/08/07 1 1D-137 11628997 INJECTION PROFILE 04/09107 1 2N-311A N/A USIT 04/06/07 1 2N-3378 11638852 SCMT 04111/07 1 1J-184 11638853 SBHP 04/12/07 1 1 H-10 11638844 GLS 03/20/07 1 2W-03 11649957 MEM LDL/PPROF 04/10/07 1 1E-112 11638856 INJECTION PROFILE 04114107 1 1J-156 11638857 INJECTION PROFILE 04115/07 1 1J-127 11638859 INJECTION PROFILE 04/17107 1 1J-105 11628994 USIT 04/06107 1 1J-164 • 11638858 INJECTION PROFILE 04/16/07 1 1J-164 ~ 11638860 INJECTION PROFILE 04117/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~3 Re: West Sak IJ-184 Pre-Produced Injector I.LP Defeat Notification Subject: Re: West Sak 1J-184 Pre-Produced Injector LLP Defeat Notification From: Thomas Maunder <tom_maunder czadmin.state.ak.us> Date: Wed, 18 Apr 2007 08:23:51 -0800 To: 'ASK ~-Vest Sak Prod F~n~~r ~~-nl~>>8%u.conocophillih~.com~- C'C: lim Rc~~~~ ~ jim rc~~~~;~r.,idi~lin.state.al:.us~> ~dCo ~ O ~--1~--~ Thanks Pete. Keep us advised when the pilot is placed back in service. Tom Maunder, PE AOGCC NSK West Sak Prod Engr wrote, On 4/18/2007 8:21 AM: Tom /Jim, The Low Pressure Pilot (LPP) for West Sak Water Injector 1J-184 was defeated on 15-Apr-2007 (injection startup) because of low wellhead injection pressure. 1J-184 was recently converted from pre-production to water injection service. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal. 1J-184 is currently taking 1060 bwpd at 46 psig wellhead injection pressure." Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 1 of 1 4/18/2007 8:24 AM To: State of Alaska March 15, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-184 + L1, AK-MW-4348857 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-184 + Ll: Digital Log Images: 50-029-23305-00, -60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETiJRNLNG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 WELL LOG TRANSMITTAL 1 CD Rom f,~ jai Date: Signed: .._____ ~ 1~f5 ~~° ~C•' ~ -C~~l' ~~ ~ ~~5 ~~ ._.. ~~~ ~; ~, ~J ConocoPhillips January 11, 2007 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Commissioner ANN 1 ~ ~ap7 State of Alaska ~lask~ ~~il ~~ ~on~. Commission Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 ~b~?~l~i~rage Anchorage, Alaska 99501 Subject: Reports of Sundry Well Operations for 1 J-184 and 1 J-184L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent workover operations of the Kuparuk well 1 J-184 and 1 J-184L1. If you have any questions regarding this matter, please contact me at 265-6830 or Ty Kemner at 265-6480. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA Jars ~ r zoo? ALASKA OIL AND GAS CONSERVATION COMMISSION ~(a~k3 ~i( $t G85 ;;rarlse CO€1'IfiiISSiOdI REPORT OF SUNDRY WELL OPERATIONS ~~c(s~f~gl; 1. Operations Performed: Abandon ^ Repair Well Q ~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing Q , 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: COnOCOPhllllps Alaska, InC. Development ^~ Exploratory ^ 206-044 / 306-369 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23305-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1J-184 ' 8. Property Designation: , 10. Field/Pool(s): ADL 25662, 25661, 380058 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17870' feet true vertical 3751' feet Plugs (measured) Effective Depth measured 17105' feet Junk (measured) true vertical 3408' feet Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 3949' 13.375" 3977' 2238' Intermediate 9247' 9-5/8" 9275' 3423' Liner 8173' 5.5" 17105' 3408' Perforation depth: Measured depth: Blotter liner from 9289' -17020' true vertical depth: 3426'-3388' Tubing (size, grade, and measured depth) 4.5", L-80, 8768' MD. Packers & SSSV (type & measured depth) LEM D sand SL ZXP liner top packer ~ 8730' Camco'DB-06' nipple @ 501' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable 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 SI Subsequent to operation 1297 3639 48 -- 339 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 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: contact Ty Kemner @ 265-6480 Printed Name Randy Thomas Title CPAI Drilling Team Leader Signature ~~ l Phone -~5-6~ ~~ Date i ~1l/~ ~ Pre ared Shar llsu Drake 263-4612 {~ ~ l..f ~ t V ~ ~ 3~ rm ~ ~ '° 100; ~~~ Form 10-404 Revised 04/2004 ~ t"( bmit Original ly 111,,,--- 1 ` ~ ~• L3 ~ ~ /~ri< Ct~ttt~t~Philiips Alaska, Iliac, J-184 TUBING APL 5002y23: (0-8768, SSSV T e: NIPPLE OD:4.500, Annular Fluid: ID:3.958) LOCATOR (8749-8750, OD:5.190) BUSHING (8751-8753, OD:7.670) SBR (8753-8772, OD:6.280) BUSHING (ant-sna, 00:6.020) PUP-LEM (8774-8814, OD:4.500) COUPLING (8962-8963, OD:7.000) Perf (9289-17020) KRU 1 J-184 - - _ - --- PROD An le TS: d lion: 5/25/2006 An le TD: 47 d 17870 V/O: 12/11/2006 Rev Reason: WORKOVER, GLV C/O, OPEN SLV )ate: Last Update: 12/25/2006 Last Tag Date: I I Max Hole Angle: 193 deg (~ 15501 I Casino String -ALL STRINGS Descri lion Size To Bottom TVD VVt Grade Thread SURFACE 13.375 0 3977 2239 68.00 L-80 BTC INTERMEDIATE 9.625 0 9275 3424 40.00 L-80 BTCM CONDUCTOR 20.000 0 108 108 94.00 H-40 WELDED WINDOW L1 9.625 8848 8849 3354 0.00 B-SAND SLOTTED LINER 5.500 8932 17105 3406 15.50 L-80 HYD 521 /BTCM Tubing String -TUBING Size To Bottom TVD Wt Grade Thread 4.500 0 8768 3341 12.60 L-80 IBTM Perforations Summary Interval TVD Zone Status Ft SPF Date T e Comment 9289 - 17020 3426 - 3388 WS B,WS 7731 32 5/11/2006 SLOTS Alternating slotted/solid pipe _ C WS B -avg. slotted lengths 5 jts Gas Lift MandrelsNalves _- St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr _ ~ Cmnt 1 ~ t036 1740 CAMCO KBG-2 GLV 10 BK-5 0188 1410 12/1J/200 -- _ _ - - G Other (plugs, equip., etc. -COMPLETION De th TVD T e Descri lion ID 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 501 501 NIP CAMCO'DB-O6' NIPPLE w/3.875" NO GO PROFILE 3.875 8700 3328 SLEEVE-O BAKER 4.5" CMD SLIDING SLEEVE w/CAMCO 3.81 'DB' PROFILE - 3.812 8749 3337 LOCATOR BAKER LOCATOR *** NOTE: GBH-22 LOCATOR SPACED OUT 4.7' ABOVE FULLY INSERTED*** 8750 3337 SEAL BAKER SBE SEAL ASSEMBLY I 8767 3340 SHOE MULE SHOE Other (plug s, equip., etc.=B-SAND LINER & D-SAND LEM DETAIL __ - ~ Depth I TVD Type I Description 8730 3334 PACKER LEM D-SAND SL ZXP LINER TOP PACKER 12/8/2006 - ~ ~ - = 1 1 - - ( - 1 1 ~~h ID 7.500 4.890 4.750 3.930 3.980 117082 3397 JOINT BENT JOINT w/NOSE ORANGE PEELED AND WELDED SHUT I 4.950 Genera! Notes 8751 3338 BUSHING LEM D-SAND CROSSOVER BUSHING 1/8/2006 8753 3338 SBR LEM D-SAND 190-47 CASING SEAL BORE RECEPTACLE 12/8/2006 8772 3341 BUSHING LEM D-SAND CROSSOVER BUSHING 12/8/2006 8774 3342 PUP-LEM 8814 3348 HANGER LEM D-SAND ABOVE HOOK HANGER 8822 3350 HANGER LEM D-SAND INSIDE HOOK HANGER 8827 3351 HANGER D-SAND L1 BAKER MOD PZ HOOK HANGER INSIDE CSG 8933 3369 PACKER 'HRD' ZXP LINER TOP PACKER 8951 3372 NIP 'RS' PACKOFF SEAL NIPPLE 8954 3372 HANGER FLEXLOCK LINER HANGER 8962 3374 COUPLING COUPLING 8963 3374 SBE 190-47 CASING SEAL BORE EXTENSION 17030 3390 PACKER SWELL PACKER VAM CONNECTIONS I Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 11/29/2006 15:00 20:15 5.25 0 _ 0 COMPZ RPCOA RURD P Tie into off well annulus. Hard line into pad production header with pad reps. Ri u ortable choke manifold. 20:15 20:30 0.25 0 0 COMPZ RPCOM1 SFTY P PJSM-Topic=Well kill procedure & hazards. 20:30 00:00 3.50 0 0 COMPZ RPCOh OTHR P Start pumping @ .5 bpm (ICP 1140 psi) Stage pump to 4 bpm @ 135 bbls. pumped (350 psi) @ 250 bbls. pumped. Reduced pump rate to 3 bpm @ 290 bbls. Pumped 600 bbls. mud. 170 si. 11/30/2006 00:00 00:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM-Topic=Killing well. 00:15 01:00 0.75 0 0 COMPZ RPCOh CIRC P Pumped total of 740 bbls. to production header. Final pump ressure 180 si. Annulus 10 si. 01:00 01:30 0.50 0 0 COMPZ RPCOh RURD P Blow down hard line & rig down same. 01:30 12:00 10.50 0 0 COMPZ RPCOh CIRC P Continue circ. thru choke manifold on rig. SICP 50 psi SITP 0. Pump @ 1 bpm. 259 bbls. crude returns. Max gas 2332 units. total loss this tower 368 bbls. 12:00 15:30 3.50 0 0 COMPZ RPCOh CIRC P Continue circ. OBM @ 1 BPM @ 130 psi. (8-10 bph loss on last hr. pumping). Total losses this tour. Total loss to hole 401 bbls. 15:30 16:00 0.50 0 0 COMPZ RPCOh OTHR P Monitor well (No Flow) 16:00 17:00 1.00 0 0 COMPZ RPCOM1 OTHR P Blow down choke & lines-Set BPV Rig down lines & Scaffold. 17:00 19:00 2.00 0 0 COMPZ RPCOh NUND P PJSM=Nipple down tree-check tbg. threads-install blank plug-nipple up bo e. 19:00 19:45 0.75 0 0 COMPZ RPCOh DHEQ P Make up valves & 5" test joint & XO,S. Ri u test a ui ment. 19:45 20:00 0.25 0 0 COMPZ RPCOM1 SFTY P PJSM-Topic=Testing BOPE. 20:00 00:00 4.00 0 0 COMPZ RPCOh DHEQ NP Testing BOPE=Attempt first test (Leak) appears to be blank dart. rig down test manifold-pull test jt. & inspect blank dart. Replace same twice-still leakin . 12/01/2006 00:00 00:15 0.25 0 0 COMPZ RPCOh SFTY NP PJSM-Topic=testing BOPE. (Witness test waived b Jeff Jones AOGCC> 00:15 04:30 4.25 0 0 COMPZ RPCOA DHEQ NP Making multiple attempts to get VETCO test pop/et to seal. Nipple down bope-dress hanger threads-niplle up bope-remove bpv-install 2 way check valve & be in testin . ~-~---- Page ~ ~t 9 I Time Logs _ _ _ _______ Date From To Dur S_De~th E. De th Phase Code Subcode T COM _______ __ 12/01/2006 04:30 12:00 7.50 0 0 COMPZ RPCOh DHEQ P Test bope (all tests @ 250 low & 3000 psi high) Test blind rams. pick up 5" test jt. & test annular-upper rams-all choke valves-manual-HCR choke & kill-test floor safety valve-ibop & accumulator test-upper hydraulic ibop-lay down 5" test jt. pick up 4 1/2" test 't. 12:00 13:00 1.00 0 0 COMPZ RPCOh DHEQ P PJSM-Continue testing bope w/ 4 1/2" test jt. Test annular-upper pipe rams-upper hyd. ibop-250-low & 3000 hi h. 13:00 14:00 1.00 0 0 COMPZ RPCOh DHEQ P Rig down test equipment-lay down test jt. & XO,S-blow down top drive, choke & lines. Pump 2 bbls. @ 1/2 b m to fill annulus. 14:00 15:30 1.50 0 0 COMPZ RPCOh DHEO P Rig up shooting flange-lubricator & rod extentions-pull 2 way check (Well Static) Rig down lubricator & shooting flan e. 15:30 17:30 2.00 8,775 8,745 COMPZ RPCOh OTHR P Make up head pin-valve &circ. line on landing jt.-pick up landing jt. & make up in hanger-Back out lock down screws-pull tbg. & hanger to rig floor. (initial pick up wt. 110k when hanger floor 88k. 17:30 00:00 6.50 8,745 8,745 COMPZ RPCOh CIRC P Break circ. (pump 8 bbl. before returns) &circ. @ 1.5 bpm 150 psi. Lost Total of 34.2 bbls. mud. 12/02/2006 00:00 06:30 6.50 8,745 0 COMPZ RPCOR PULD P Lay down tbg. hanger-poh w/ 4.5" tbg. Rack back in derrick (SLM) 94 stands-lay down 1 glm-1 sliding sleeve-1 jt. tbg.-1 pup jt. w/ seat assembly. Calculate hole fill 40 bbls. Actual-56 bbls. 06:30 07:00 0.50 0 0 COMPZ RPCOh RURD P Rig down csg. equipment. 07:00 07:45 0.75 0 0 COMPZ RPCOh OTHR P Set wear bushing-clear & clean rig floor. 07:45 08:30 0.75 0 0 COMPZ RPCOR PULD P Pick up baker fishing tools. Install bell uides on to drive. 08:30 12:00 3.50 0 412 COMPZ RPCO PULD P Make up BHA-bowen itco spear 7.689 grapple-extention-8" OD stop sub-xo-bumper jar-oil jar-12 6 3/4" dc,s & intensifier'ar. 12:00 12:15 0.25 412 412 COMPZ RPCOh SFTY P PJSM-Topic=Picking up 5"drill pipe. 12:15 18:15 6.00 412 8,740 COMPZ RPCOh PULD P RIH-Picking up & drifting 5" drill pipe to 8740'-break circ. @ 3 bpm 220 psi-P/U 140k S/O 80k ROT 102k TO 8k. 18:15 19:00 0.75 8,740 8,756 COMPZ RPCOII OTHR P Wash in & engage fish @ 8756'-stack 15k to confirm catch-with 20k overpull-S/O to 10k over-apply 11 rounds left hand torge to 13k-back off indicated & free 8k for ue. ~~ Page 3 csf 9 _Time Lugs _ _ Date From_To Dur S. Depth E. De th Phase Code Subcode T COM 12/02/2006 19:00 00:00 5.00 8,756 8,756 COMPZ RPCOh CIRC P Circ. complete circ. @ 2.25 bpm Max as 58 units 15 bbl. loss to hole. 12/03/2006 00:00 00:30 0.50 8,756 8,756 COMPZ RPCOh CIRC P Continue circ. @ 2.25 bpm-130 psi. 00:30 00:45 0.25 8,756 8,756 COMPZ RPCOh OTHR P Monitor well-pump pill. 00:45 05:00 4.25 8,756 0 COMPZ RPCOh TRIP P POH w/fish. P/U 140k. Hole fill est. 72.5 bbls. Actual 82.75 bbls. 05:00 06:00 1.00 0 0 COMPZ RPCOh PULD P Lay down fish-service breaks & lay downs ear. 06:00 07:45 1.75 0 60 COMPZ RPCOh PULD P Make up milling assembly.=8.5" Metal muncher shoe-8.375" washpipe extention-xo-bum er sub-oil 'ar. 07:45 12:00 4.25 60 7,468 COMPZ RPCOh TRIP P R1H w/ 4 stands dc,s-PiU accelerator 'ar-continue RIH w/ DP to 7468'. 12:00 12:30 0.50 7,468 8,763 COMPZ RPCOA TRIP P PJSM & continue RIH to 8706'-P/U 140k S/O 75k ROT 105k-TO 8-9k-Wash & to ZXP 8763'. 12:30 00:00 11.50 8,763 8,766 COMPZ RPCOh OTHR P Milling over ZXP from 8763 to 8766'. 4 bpm 250 psi 100 rpm TO 10-13k WOB 5-16k) Pump 25 bbl hi vis sweep @ 22:00 hrs. (Max gas 77 units Total fluid loss 75 bbls. 12/04/2006 00:00 00:45 0.75 8,766 COMPZ RPCOA OTHR P Continue to mill packer @ 8767', 100 rpm, torque = 10-12 k, 175 gpm, 290 si, 00:45 02:00 1.25 COMPZ RPCOh OWFF P Monitor well, pump slug and blow down to drive 02:00 09:30 7.50 COMPZ RPCOh TRIP P POOH, 09:30 10:30 1.00 COMPZ RPCOh OTHR P Clean out junk baskets 10:30 11:00 0.50 COMPZ RPCOA OTHR P M/U new metal muncher mill shoe 11:00 11:15 0.25 COMPZ RPCOh OTHR P Clean rig floor 11:15 14:00 2.75 COMPZ RPCOt~ TRIP P R1H to 3766' 14:00 14:15 0.25 COMPZ RPCOh SFTY P PJSM, crew change out 14:15 15:45 1.50 COMPZ RPCOh TRIP P Continue RIH w/milling assembly. Fill drill pipe @ 6130'. Break circulation @ 6705' and tag ZXP packer @ 8766'. P/U = 140k, S/O=75k, Rot=104k. Lost 10 bbl mud on tri in hole 15:45 00:00 8.25 COMPZ RPCOA OTHR P Mill over ZXP packer from 8766' to 8768'. Lost total of 41 bbl mud 12/05/2006 00:00 12:00 12.00 8,768 8,769 COMPZ RPCOh OTHR P Milled on ZXP packer from 8,768' to 8,768.5', milled at 5-18K WOM, 60-90 rpm's, 3 bpm at 230 psi, 10-14K ft-Ibs torque, rot wt 104K, up wt 140K, do wt 80K, pumped 25 bbl hi vis sweep and had a small increase in the cuttings, have recovered approx. 25 Ibs of metal cuttings back and lost approx 30 bbls of mud to the hole. ~~ ~ t'~e 4 ~f 9~ Time Logs --- -- - -- -- Date____ From_ To rDur S Depth E. Depth Phase Code _. Subcode T COM ____ _ 12105!2006 12:00 16:45 4.75 8,769 8,769 COMPZ RPCOh OTHR P Cont to mill on ZXP packer at 8,768.5' with no progress, pumped 30 bbl hi vis sweep and had a small increase in the cuttings, lost approx 20 bbls of 8.2 ppg MOBM to the hole, decision was made to POOH and C/O mills 16:45 17:00 0.25 8,769 8,769 COMPZ RPCOh OWFF P Monitored well-static, pumped dry job 17:00 20:45 3.75 8,769 440 COMPZ RPCOh TRIP P POOH from 8,768.5' to BHA #3 at 440' 20:45 21:15 0.50 440 40 COMPZ RPCOM1 TRIP P POOH from 440' to 40', LD Intensifier 'ars and stood back 6 1/4" Dc's 21:15 22:15 1.00 40 40 COMPZ RPCOh PULD P Cleaned out boot baskets and changed out Metal Muncher mills, #2 mill was 30% worn, recovered 7-9 thin pieces of metal from ZXP packer ranging from 1/4" to 1"wide by 8-10" long from boot baskets, hole took talc fill on tri out. 22:15 00:00 1.75 40 1,765 COMPZ RPCOb TRIP P RIH with shoe #3 on BHA #4 from 40' to 1,765', PU Intensifierjars and RIH with 6 1/4" DC's and remaining milling BHA #4 on 5" DP to 1,765' 12/06/2006 00:00 02:45 2.75 1,765 8,700 COMPZ RPCOh TRIP P RIH with BHA #4 from 1,765' to 8,700', st wt up 140K, do wt 75K, lost approx 10 bbls mud while RIH 02:45 04:00 1.25 8,700 8,700 COMPZ RIGMN SVRG P Slip and cut 81' of drilling line and serviced to drive 04:00 04:15 0.25 8,700 8,769 COMPZ RPCO6 TRIP P RIH from 8,700' and washed over top of fish at 8,764' and tagged up at 8,768.5' 04:15 18:30 14.25 8,769 8,773 COMPZ RPCOh OTHR P Fin milling overZXP packer, milled from 8,768.5' to 8,772.5', (saw 12-18" of free travel after milling over slips on packer), milled at 5-12K WOM, 60 rpm's, 36 spm, 126 gpm at 220 psi, off btm torque 8K ft-Ibs, on btm 10-12K ft-Ibs, rot wt 104K, up wt 140K, do wt 75K, max gas was 204 units at btms up after RIH, lost approx 27 bbls of 8.2 ppg MOBM mud while milling, monitored well-static. 18:30 20:30 2.00 8,773 8,755 COMPZ RPCOh CIRC P Pumped 30 bbl hi vis sweep at 8,772' and PU to 8,755' to above TOF and fin circ sweep out of the hole, had 2% increase in cuttings from sweep, circ at 70 spm, 250 gpm at 500 psi, lost approx 7 bbls of MOBM while circ out the swee 20:30 20:45 0.25 8,755 8,755 COMPZ RPCOh OWFF P Monitored well-static and pumped dry 'ob 20:45 00:00 3.25 8,755 2,340 COMPZ RPCOh TRIP P POOH with milling BHA #4 from 8,755' to 2,340' 12/07/2006 00:00 01:00 1.00 2,340 31 COMPZ RPCOA TRIP P POOH with BHA #4 from 2,340' to 31', LD Intensifier jars and stood back 4 stds of 6 1/4" DC's '~g~ ~ cif 9 ~- Time Loc,~_ Date From To Dur S. th E. De th Phase Code Subcode T COM 12/07/2006 01:00 02:00 1.00 31 0 COMPZ RPCOti PULD P POOH LD jars, boot baskets and shoe, cleaned out baskets and recovered 12 of 20 slip sections from ZXP pkr, mill was 10% worn, cleared ri floor 02:00 03:30 1.50 0 0 COMPZ RPCOh OTHR P Pulled wear bushing and flushed out stack, re-installed wear bushin 03:30 04:15 0.75 0 31 COMPZ RPCOh PULD P MU fishing BHA #5 RIH to 31', RIH with spear assembly with 6.22" ra le, bum er sub and oil 'ars 04:15 08:00 3.75 31 8,684 COMPZ RPCOh TRIP P RIH with BHA #5 from 31' to 8,684', RIH with 4 stds DC's, Intensifierjars and string magnet on 5" DP to 8,684', st wt u 137K, do wt 77K 08:00 08:15 0.25 8,684 8,713 COMPZ RPCOI~ OTHR P RIH from 8,684' and speared fish at 8,770' setting 10K wt down (TOF @ 8,764'), PU to 160K with no movement, PU to 175K and saw LEM snap out of hook, jars did not go off, PU LEM assembly to 8,713' to clear seals of CSR, st wt u 140K. 08:15 10:15 2.00 8,713 8,713 COMPZ RPCOh CIRC P Circ btms up at 8,713', circ at 48 spm, 170 mat 210 si, max as 74 units 10:15 10:45 0.50 8,713 8,713 COMPZ RPCOh OWFF P Monitored well- static, pumped dry job and blew down to drive 10:45 14:00 3.25 8,713 437 COMPZ RPCOh TRIP P POOH from 8,713' to 437' 14:00 16:45 2.75 437 0 COMPZ RPCOh PULD P LD BHA #5 POOH from 437', LD Intensifierjars, 12- 6 1/4" DC's, jars and string magnet, LD spear with ZXP pkr, then POOH LD LEM assembly with seals, had full recovery of LEM, cleared ri floor 16:45 17:45 1.00 0 0 COMPZ RPCOA OTHR P Pulled wear bushing and flushed out the BOP stack 17:45 22:30 4.75 0 0 COMPZ WELCT BOPE P RU and tested BOPE, tested rams, valves and choke manifold to 250 psi low and 3,000 psi high including annular, tested with both 4 1/2" tbg and 5" DP, tested the alarms and koomey, had 3,000 psi on Koomey, 1,800 psi after functioning rams, took 35 seconds to build 200 psi, 3 min 5 sec. for full recovery. Note: Chuck Scheve W/AOGCC waived witnessing of test. 22:30 23:00 0.50 0 0 COMPZ RPCOh OTHR P Pulled test plug and installed wear bushin 23:00 00:00 1.00 0 0 COMPZ RPCOCV OTHR P Cleared rig floor and RU 2 718" PAC DP handlin tools 12/08/2006 00:00 02:15 2.25 0 268 COMPZ RPCOb PULD P MU CSR cleanout BHA #6 RIH to 268', MU 4 11/16" rev. circ jet basket & RIH with 7 jts of 2 7/8" PAC DP, 2-boot baskets bumper sub, oil jars, strip ma net and um out sub ~-- Page S of 9 r ~~ Time Loc_~ _ __ Date From To Dur S Depth E, De th Phase Code Subcode T COM _~ 12/08/2006 02:15 06:30 4.25 268 8,629 COMPZ RPCOA TRIP P RIH with BHA #6 from 268' to 8,629', PU 12 add. jts of 5" DP while RIH. (92 stds 5" DP in derrick 06:30 09:00 2.50 8,629 9,005 COMPZ RPCOh TRIP P Dropped 9/16" ball and circ down to seat while RIH from 8,629' with ball on seat at 8,819', cunt to RIH and rev. circ from 8,819' to 9,005', while RIH set down at 8,929', rotated 3 rds and cont RIH, sat down again at 8,939', rot. 3 rds and was able to RIH thru CSR to 9,005'„ st wt up 125K, do wt 76K, rot wt above CSR 100K. Note: Top of B lat ZXP pkr @ 8,933' and btm of CSR is 8,983' 09:00 13:00 4.00 9,005 8,819 COMPZ RPCOh CIRC P Pumped 30 bbl hi vis sweep and circ till sweep was 1,000' above rev. basket, circ at 4 bpm at 1,000 psi, dropped 2 1/4" ball and rod to open circ sub at top of BHA, ball did not seat, PU to 8,819' to clear CSR and rotated DP at 20 rpm's and ball landed on seat, opened circ sub at 1,500 psi and stopped rotation, then increased pump rate to 600 gpm at 425 psi, pumped 2nd hi vis sweep and with both sweeps out of hole did not see much increase in cuttings and was clean at the shakers. 13:00 13:30 0.50 8,819 8,720 COMPZ RPCOh OWFF P POOH 1 std from 8,819' to 8,720' and monitored well-static, pumped dry job and blew down to drive. 13:30 16:30 3.00 8,720 268 COMPZ RPCOh TRIP P POOH from 8,720' to BHA #6 at 268', calc fill on trip out 67.5 bbls, actual fill 69 bbls. 16:30 20:30 4.00 268 0 COMPZ RPCOR PULD P POOH from 268' LD BHA #6, recovered 1 more slip segment on magnet with very little recovery in boot baskets, cleared rig floor. (13 of 20 sli se ments recovered 20:30 20:45 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM with rig crew, Baker and Sperry Sun reps on picking up and running of LEM assembly with MWD tool. 20:45 21:15 0.50 0 0 COMPZ RPCOh RURD P RU to run LEM assembly 21:15 00:00 2.75 0 220 COMPZ RPCOR PULD P MU "D" lat LEM and seal assembly RIH to 220', began to MU Sperry Sun's MWD tool 12/09/2006 00:00 00:30 0.50 220 255 COMPZ RPCOh PULD P Fin MU Sperry Sun's MWD tool to the "D" lat LEM and seal assembly then MU the ZXP hanger and packer assembly RIH to 255'. St wt up and down 40K 00:30 06:00 5.50 255 8,912 COMPZ RPCOh TRIP P RIH with LEM from 255' to 8,912', shallow tested MWD at 475' while RIH, st wt u 126K, do wt 77K r- Time Logs _ __ i Date From To Dur S. De th E. De tEt Ph ; e Code Subcode T COM 12/09/2006 06:00 07:15 1.25 8,912 8,973 COMPZ RPCOh OTHR P RIH with seal assembly thru the hook with no problems, oriented hook and {atched into same, orientation showed to be set at 29 deg rt of high side, (previous MWD showed 38 deg rt) PU and st wt up inside CSR was 128K, do wt 78K, snapped out of LEM at 145K, 19K over st wt, rotated string 180 deg, RIH and tagged top of LEM 1' high, rotated add. 180 deg then snapped back into LEM, orientation showed 26 deg rt of high side, snapped in and out of LEM twice with same results settin 25K wt down. 07:15 08:30 1.25 8,973 8,730 COMPZ RPCOh OTHR P Dropped 1 3/4" ball and pumped down to seat, pumped down at 3 bpm at 790 psi, slowed pump and with ball on seat pressured up to 3,000 psi to set hanger and packer, increased to 4,000 psi and released running tool, set top of ZXP packer at 8,730' with btm of seals at 8,973.55', no problems settin ZXP. St wt u 126K 08:30 08:45 0.25 8,730 8,730 COMPZ RPCOh DHEQ P Tested ZXP packer and annulus at 8,730' to 2,500 psi for 5 min, good test. 08:45 12:30 3.75 8,730 945 COMPZ RPCOh TRIP P POOH wet with running tool from 8,730 to 945' 12:30 13:30 1.00 945 945 COMPZ RPCOh OTHR T Repair skate 13:30 15:30 2.00 945 0 COMPZ RPCOII PULD P POOH from 945' LD 10 stds of 5" DP and Baker's running tool, cleared rig floor. 15:30 16:15 0.75 0 0 COMPZ RPCO6 RURD P Pulled wear bushing and RU to run 4 1/2" com letion 16:15 16:30 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM with rig crew, Baker rep and tong operator on running of 4 1/2" com letion 16:30 00:00 7.50 0 6,925 COMPZ RPCOh RCST P RIH with 4 1/2" completion assembly to 6,925' per well plan, RIH with seal assembly, open CMD sliding sleeve on 4 1/2", 12.6#, L-80, IBTM tbg, MU KGB-2 GLM with dumm while RIH. 12/10/2006 00:00 00:45 0.75 6,925 8,700 COMPZ RPCOA RCST P Cont to RIH with 4 1/2" completion from 6,925' to 8,700', st wt up 87K, do wt 60K, blk wt 35K 00:45 02:00 1.25 8,700 8,767 COMPZ RPCOh HOSO P RIH from 8700' and tagged up on no go, PU and spaced out tbg, made up Vetco Gray hanger and landed 4 1/2", 12.6#, L-80 IBTM tb at 8,767'. 02:00 03:00 1.00 8,767 8,767 COMPZ RPCOh DHEQ P RILDS, tested upper and lower seals on hanger to 5,000 psi for 10 min and ck'd ok 03:00 04:00 1.00 8,767 8,767 COMPZ RPCOA NUND P ND BOP stack 04:00 06:15 2.25 8,767 8,767 COMPZ RPCOh NUND P NU tree and tested tree and void to 5,000 si and ck'd ok. ulled TWC rag~finf9 Time Logs Date _ From To Dur S Depth E. Depth Phase Code Subcode _T_ COM 12/10/2006 06:15 08:00 1.75 8,767 8,767 COMPZ RPCOA RURD P RU mousehole to LD 5" DP and RU little red to displace hole over to diesel, held PJSM on displacing hole over. 08:00 13:30 5.50 8,767 8,767 COMPZ RPCOh FRZP P Little Red displaced hole over from 8.3 ppg MOBM to diesel thru open sliding sleeve at 8,700', ave 4 bpm at 600 psi, pumped 648 bbls diesel and recovered 590 bbls of MOBM, calc disp. was 621 bbls. SIM-OP, LD 87 jts of 5" DP out of the derrick thru the mousehole and cleaning mud pits while displacing hole. 13:30 14:15 0.75 8,767 8,767 COMPZ RPCOM1 NUND P RU lubricator and installed BPV, secured well and RD scaffoldin 14:15 18:00 3.75 0 0 COMPZ RPCOh PULD P Fin LD 5" DP out of the derrick thru the mousehole, LD an add. 159 jts, LD a total of 246 ~ts. 18:00 20:00 2.00 0 0 COMPZ RPCOh OTHR P Slip and cut 72' of drlg line, cleaned and ins ected saver sub and ck'd ok 20:00 21:30 1.50 0 0 COMPZ RPCOh OTHR P Changed out lower set of pipe rams on BOP stack from 5" to 7 5/8" 21:30 00:00 2.50 0 0 COMPZ RPCOh OTHR P Fin cleaning pollution pan, rig floor and mud pits. RELEASED RIG @ 24:00 hrs 12/10/06 ~ ~~~~ 9 of 9 /J~~ ~Ci~~~~flf~i~~~i~ NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ry ~rj1 ....iii St Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01 /02/07 2N-304 11416232 FBHP SURVEY 10130106 1 2N-304 11296737 FBHP SURVEY 11104106 1 1D-109 N/A INJECTION PROFILE 11127/06 1 1J-136 (REDO) 11534188 USIT 12/10106 1 1R-18 NIA SBHP/DD 12/18106 1 1G-16 11551836 INJECTION PROFILE _ 12/19106 1 1D-103 11548555 INJECTION PROFILE 12/20106 1 3K-09A NIA SBHP SURVEY 12122106 1 3K-26 NIA SBHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12124/06 1 3S-19 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12126/06 1 2A-20 11548565 INJECTION PROFILE 12126!06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28106 1 1J-184 11538775 PRODUCTION PROFILE 12/30/06 1 s Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Re: Permission to pre produce IJ-184 PTD # 206-045 & 206-044 Subject: Re: Peamission to pre produce 1J-184 PTD # 206-045 & 206-044 From: Thomas Maunder <tom_maunder~?admin.state.ak.us> Date: Fri, 22 Dec 2006 08:3G:12 -0900 To: NSK l'rc~bl~:m Well Supv ~ -n I (i l ; ~ci~r~>nc~cuphillips.~onl = Perry, There are no issues that I know of. Good luck with the operations. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/22/2006 8:33 AM: Tom, It is a sliding sleeve that has been shifted to the open position. There is no device set in a profile like a commingling sleeve in an AVA. `You are correct with regard to the lack of GL mandrels. The well bore was completed to be an injector after it's short pre production period. There are na inherent annulus communication issues with the well due to leaks or mechanical failures. We performed an IittlTlA to 2500 psi prior to opening the sleeve. l agree with the splitting of hairs regarding gas lifting. There is a subtle difference between the sleeve and a gas lift valve, assuming the GLV checks are holding and [wanted to make sure the state didn't have any issues with temporarily using the sliding sleeve to assist in clean up. Perry From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, December 22, 2006 8:00 AM To: NSK Problem Well Supv Subject: Re: Permission to pre produce 1]-184 PTD # 206-045 & 206-044 Hi Perry, This gets down to splitting hairs. In order to gas lift you need some sort of communication from the IA to the tubing. GLMs are not ordinarily run in injection wells so your only option is to use the sliding sleeve. Normal flow should be from the IA via the sleeve into the tubing. If the well were to SI, I wouldn't think that flow would reverse. Is the sleeve just opened, or is there some device set in the profile? Look forward to your reply. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/22/2006 7:41 AM: Tom, 1 of 3 12/26/2006 7:37 AM Re: Permission to pre produce 1J-184 PTD # 206-045 &.206-044 i ~ I was concerned with gas lifting the well via the open CMD and thought that we would need verbal permission for that aspect of the operation since we have T X IA communication with the sleeve open during the clean up, Am I mistaken with regard to gas lift via the sleeve? Thanks Perry From: Thomas Maunder [mailto:tom maunder~a admin.state.ak.us] Sent: Monday, December 18, 2006 4:35 PM To: NSK Problem Well Supv Ce: jim_rec~c}@adminstate.ak.us Subject: Re: Permission to pre produce 1J-184 PTD # 206-045 & 206-044 Perry, 1J-184 and -184L1 are completed with 1-oil status. As such, they are production well(s) so you do not need permission to continue to produce them. You are correct that sundries will need to be submitted to convert the well(s) from producers to injectors. Thanks for the notice regarding the operations. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/18/2006 4:18 PM: Tom, ConocoPhillips would like to request approval to pre produce well 1J-184 PTD # 206-045 & 206-044 using gas lift through an open sliding sleeve at 8726 MD - 3333 TVD for approximately 90 days with option to extend after which a 10-403 will be submitted to convert 1J-184 to an injection well. CPAI originally submitted a similar request on 6/2/06 that was granted on 6/7/06. An attempt was made to flow both laterals on 8/27/06. It was determined that the hook hanger and Lateral Entry Module, LEM, was mistakenly set 180 degrees out of phase with the open hole preventing clean up and production from the isolated lateral. The well has since been worked over and the LEM reinstalled for entry into the lateral leg. We would like to reattempt to pre produce at this time. The West Sak PE will submit the 10-403 to convert to injection once the pre production diagnostics are finished. Approximate total production time will be 60 to 90 days. Please let me know if you have any questions or concerns. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 2 of 3 12/26/2006 7:37 AM Randy Thomas CPAI Drilling Team Leader ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, AK 99510 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, AIJISKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 w Re: Kuparuk River Field, West Sak Oil Pool, Well name: 1J-184 Sundry Number: 306-369 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As 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 November, 2006 Encl. M ,. Cc~ I s Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 14, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: N ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak iJ-184 well. The iJ-184 is a dual lateral injection well, PTD 206-044 (mainbore and B (ateral) and PTD 206-045 (D lateral), that will be pre-produced prior to being put on injection. - Once on injection, the iJ-184 will support the 1J-137 dual lateral producer to the East and the 1J- 182 dual lateral producer to the West The 1J-184 well was initially completed in May of 2006 and was placed on pre-production in June of 2006. The initial flowback procedure called for single lateral flowbacks from the B and D laterals. However, numerous attempts to set an inflatable bridge plug to isolate the B lateral failed. The flowback procedure was revised to flowback both laterals simultaneously. With both laterals flowing, a production profile was conducted and showed primary contribution from the B lateral only. A coil tubing cleanout for the D lateral was recommended to get more contribution from the D lateral. However, coil tubing was unsuccessful in numerous attempts to gain access to the D lateral through the D lateral LEM. A memory gyro was run to determine if the LEM was aligned properly to provide D lateral access. The memory gyro showed the D lateral LEM to be 180 degrees out of phase. A subsequent memory caliper log confirmed the LEM was 180 degrees out of phase. The purpose of the proposed workover will be to pull the existing LEM and rerun another LEM to provide D lateral access. The tubing will be removed prior to pulling the existing LEM and reinstalled after the LEM has been successfully rerun. The wellbore will be loaded with fluid of sufficient density to balance reservoir pressure. After the rig leaves location, coil tubing will be used to clean out the D lateral. If you have any questions or require any further information, please contact me at 265-6480. Sincerely, Tyrone T. Kemner Completion Engineer CPAI Drilling and Wells GRIGINAL M STATE OF ALASKA ~l"~~0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 _, 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^~ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^~ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 206-044 ° 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23305-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO Q ~ 1J-184 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25662, 25661, 380058 RKB 28' Kuparuk River Field /West Sak Oil Pool - 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (tt): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17870' 3751' 17105' 3408' Casing Length Size MD TVD Burst Collapse Conductor g0' 20" 108' 108' Surface 3949' 13.375" 3977' 2238' Intermediate 8247' 9-5/8" g275' 3423' Liner 8173' S.5" 17105' 3408' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): dotter liner from 9289'-17020' 342s'-3388' 4.5" L-80 8794' Packers and SSSV Type: Packers and SSSV MD (ft) HRD' ZXP liner top pkr @ 8933' Camco'DB-O6' nipple @ 498' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: November 22, Zoos Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ty Kemner @ 265-6480 Printed Name Randv Thomas Title: CPAI Drilling Team Leader Signature Phone 265-6830 Date ~ ~ ~( Y~p (~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness nical Integrity Test ^ Plug Integrity ^ BOP Test ~ Mecha Location Clearance ^ ~~~~ p Other: 30 ®®[~j~, Wa`vatv~-tvv-c., v ~~~L~~ ~tf~~ ~ ~.~~ l ~ i~!'{J ~~~ Subsequent Form Required: APPROVED BY / /~~~ Approved by: COMM ONER THE COMMISSION / ~ Date: ` ! V Form 10-403 Revised 06/2006 v `~ ~ ~ ~ ~ ~ i~ ;y Submit in Duplic ~~ ~/• lS'~ rte` '1/~~G~ West Sak 1 J-184 General Workover Procedure Pre-Rig Work: Slickline: 1. Pull GLV from GLM at 2,036' MD. 2. Install DGLV in GLM at 2,036' MD. General: 3. Prepare location for Doyon 141. General Workover Procedure: 1. MIRU Doyon 141. 2. Kill the well by circulating 8.5 ppg OBM down the 4-1/2" tubing, through the CMD sliding sleeve at 8,726' MD, and up the 4-1/2" tubing by 9-5/8" casing annulus. 3. Set BPV, ND tree, and install blanking plug, 4. NU 13-5/8" 3K BOP's. 5. Test BOP's on 4-1/2" and 5" tubulars to 250/3,000 psi (annular to 250/1,500 psi). MASP=1,075 psi (1,400 psi reservoir pressure at 3,250' TVD less 0.1 psi/ft gas gradient). 6. Pull blanking plug, pull BPV, and run hanger isolation sleeve. 7. Pull tubing hanger free and POOH standing back the 4-1/2" tubing completion. 8. Retrieve the tieback sleeve from the D lateral ZXP liner top packer at 8,761' MD. 9. Burn over the D lateral ZXP liner top packer at 8,761' MD. 10. Retrieve the D lateral ZXP liner top packer and LEM assembly. 11. Clean out the casing seal bore receptacle above the B lateral. 12. RIH with new D lateral ZXP liner top packer and LEM assembly. 13. Set D lateral ZXP liner top packer at +/- 8,750' MD and test same to 2,500 psi. 14. Rerun the 4-1/2" tubing completion. 15. Set BPV and ND BOP's. 16. NU tree. 17. Install tree test plug and test tree to 250/5,000 psi. Test packoff to 5,000 psi. 18. Pull tree test plug and BPV. 19. Freeze protect the well with diesel through the open CMD sliding sleeve at +/- 8,720' MD. - ~, ~g .~., _ _ _ ALASSA OIL A1~TD GAS COlYSERQA'1`IOl~1T COh'II-IISSIOIQ Robert Buchholz Production Engineering Technician ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-184 Sundry Number: 306-315 Dear Mr. Buchholz: FRANK H. MURKOWSKI, GOVERNOR 333 W. 7~" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As 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. Sincerely, Cathy . Foerster Commissioner DATED this day of September, 2006 Encl. v1C'(~ ~ ~?~~/ • ConocoPhillips September P 1, 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 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 ~, ~~, - Subject: Sundry Applications for Proposed Change of Well Class ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on Kuparuk well 1Q-02B and 1Q-02L1. ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on West Sak wells 1J-127, 1J-127L1, 1J-127L2, 1J-184, 1J-184L1. If you have any questions regarding this matter, please contact myself or Robert Christensen at 6S9-7S3S. Robert W. Buchholz Attachments: 10-403 Forms ~~ I~ECEIV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I`~ SEP 1 2 2006 APPLICATION FOR SUNDRY APPROVA~ska oil & Gas Cons. Commission 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other Q Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ /,"~~ Time Extension ^ _~' a~ ~Qt/! ClsiSf Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ j~'./3 -0 4 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 206-044 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23305-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ~ 1J-184 , 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25662, 25661, 380058 ~ RKB 0' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17870' 3751' 17105' 3406' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 3977' 13-3/8" 3977' 2239' INTERMEDIATE 9275' 9-5/8" g275' 3424' WINDOW L1 1' 9-5/8" 8849' 3354' 8173' S-1 /2" 17105' 3406' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Alternating Slotted/Solid Pipe 9289' - 17020' 3426' - 3388' 4-1 /2" L-80 8793' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 498' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 4, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen 1 Bob Buchholz Printed Name Robert W. Buchholz Title: Production Engineering Technician ~~~ ~" '~ ~ Signature ~ / Phone 659-7535 Date p Q . Commission Us nl Sundry Nu ber: ~ Conditions of approval: Notify Commission so that a representat ive may witness ~~ V! Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~SDN1S BFI- s~P 1 ~ 2oos Subsequent Form Required: ~~ ~\ ~ APPROVED BY "'" ~~ Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revi~ed 06/2006g~ " ~ ~~ ' ~~ H (, Submit in Dup ~cate q•~3.oG ~~/~' 1 J-184 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Dual-lateral Well 1J-184. This well was pre-produced fora 93 day period in order to recover oil based drilling fluids prior to putting the well on injection. Lateral 1J-184 will provide pressure support for the West Sak B sands. ~ The 13-3/8" Surface casing (3977' and / 2239' tvd) was cemented with 740 sx AS Lite followed by 228 sx DeepCrete. The 9-5/8" Intermediate casing (9275' and / 3424' tvd) was cemented with 589 sx DeepCrete. The injection tubing/casing annulus is isolated via SLZXP 7" x 9-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 8761' and / 3339' tvd. This well also contains a Lower B sand 7" x 9-5/8" ZXP Liner Top Packer w / HRD located @ 8933' and / 3369' tvd. The top of West Sak D sand was found at 8825' and / 3350' tvd. The top of West Sak B sand was found at 9255' and / 3421' tvd. KRU 1 J-184 ~t~r~c~~lil~i~~ ~4~~~~~lx lt~~: '!1 J-1.84 _ API:150029933050~ all Tvna~ I PROD ~Annle (n7 TSS I dan n I TUBING SSSV Type: NIPPLE Orig 5/25/2006 Angle @ TD: 47 deg @ 17870 (o-e793, OD:4 500 Com letion: . , ID:3.95&) Annular Fluid: Last W/O: Rev Reason: PULL SLEEVE Reference L : 28' RKB Ref Lo Date: Last U date: 8/31/2006 ' Last Ta TD: 17870 ftK6 ~ Last Ta Dates Max Hole An le: 93 de 15501 ~'• -_ _ _ _ I Caste String -ALL STRINGS - -- -- -;...~ Descri lion Size To Bottom ND Wt Grade Thread SURFACE 13.375 0 3977 2239 68.00 L-80 BTC INTERMEDIATE 9.625 0 9275 3424 40.00 L-80 BTCM <>"' CONDUCTOR 20.000 0 108 108 94.00 H-40 WELDED »»3~%: WINDOW L1 9.625 8848 8849 3354 0.00 A-SAND SLOTTED LINER 5.500 8932 17105 3406 15.50 L-80 HYD '; 521 BTCM Tutrin Stringy'-Untitled -- __ - - _- ~ .~ _ Size Top _ 1 -- _ Bottom ND Wt Grade Thread ~ PACKER - _ , ', ' 4.500 _ 0 _ _879.3_ _ 3345 i _1260__ L-80 _ IBTM (a7st-x775, __' Perforations Summary OD:9.625) Interval ND Zone Status Ft SPF Date T e Comment 9289 - 17020 3426 - 3388 WS B,WS 7731 32 5/11/2006 SLOTS Alternating slotted/solid pipe - ................. C,WS B -avg. slotted len the 5'ts "'- --- leas Lift Man drelsNalves BUSHING (a7az-a7sa, oD:7s7o) .......... •. °' `... _ I St OD6 1V4 AMfCO MKBG 2 e V Mfr V L~e V OD Latch rPort - TRO i Date Vlv Run Cmnt 1.0 , BK-5 0.188 ', 1460 6/6/2006 ,.:: Other lu s ui ., etc.) -COMPLETION JEWELRY -- _- __ _ De th ND T bescri lion ID BusHwG 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 (aao3-saga, 498 498 NIP CAMCO'DB-06' NIPPLE w/3.875" NO GO PROFILE 3.875 oD:s.ozo) 8726 3333 SLEEVE-O BAKER 4.5" CMD SLIDING SLEEVE w/CAMCO 3.81 'DB' PROFILE - 3.812 OPEN 6/6/2006 PUP-LEM 8775 3342 LOCATOR BAKER LOCATOR 3.980 (aaoa-as73, *** NOTE: GBH-22 LOCATOR SPACED OUT 4.7' ABOVE FULLY OD:4.500) INSERTED*** 8776 3342 SEAL BAKER SBE SEAL ASSEMBLY 3.880 8793 3345 SHOE MULE SHOE 3.958 Other (plugs,_ ui ., etc.) - B-SAND L1NI=R & D -SAND_LEM JEWELRY _ Deih ND T _ _ Descri lion ID 8761 3339 PACKER LEM D-SAND SL ZXP LINER TOP PACKER 7.500 8782 3343 BUSHING LEM D-SAND CROSSOVER BUSHING 4.890 8784 3343 SBR LEM D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 8803 3346 BUSHING LEM D-SAND CROSSOVER BUSHING 3.930 8804 3347 PUP-LEM 3.980 8814 3348 HANGER LEM D-SAND ABOVE HOOK HANGER 3.930 8822 3350 HANGER LEM D-SAND INSIDE HOOK HANGER 3.688 8827 3351 HANGER D-SAND L1 BAKER MOD PZ HOOK HANGER INSIDE CSG 7.740 8933 3369 PACKER 'HRD' ZXP LINER TOP PACKER 7.000 8951 3372 NIP 'RS' PACKOFF SEAL NIPPLE 6.230 8954 3372 HANGER FLEXLOCK LINER HANGER 6230 8962 3374 COUPLING COUPLING 4.880 8963 3374 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 17030 3390 PACKER SWELL PACKER VAM CONNECTIONS 3.960 17062 3397 JOINT BENT JOINT wMOSE ORANGE PEELED AND WELDED SHUT 4.950 -- General Notes _ _ _ __ -- -_ Date Note 5/24/2006 MULTI-LATERAL WELL: 1J-184 (B-SAND), 1J-184L1 (D-SAND) COUPLING TREE: VETCO GRAY/ HORIZONTAL/ 4-1/16" 5M (asst-s9s3, OD:7 000) ~~~~.... TREE CAP CONNECTION: 9" OTIS . ~ r..w._ . E ''.~ . Pert _ . ~~ (9259-17020) - f • i~.'Cz3.4NICAL INTEGRITY R :PORT =..G cS:.,~~~~. .N ~ LL DAT ~_ TD : ?~.. 'I'VD ; . BTD . ?•ID TVD Casing ~~ Shoe . ~ ~h 5 t-II) TVD ; li V . ~---?~ ~ ~ T<r~i - =: ~ e ~ . Shoe : '~ T`,TD ; '. c r . '~~ _',"~ -:~o,- V ~_Pacicer ~~~`~ TVD; Set at :ole S«e end Perfs to 1._. ~ vii ~.+..~--~ ~~'~-1~` +~ Jc ~C'r'.~?~=C~.I. INTEGR?'TY - PART #I r_nnulus Press Test• =~ 15 nin ~0 min Conents f 7 JJ b N L ,~ '~'CHANIC?~, INTEGR?TY -PART #Z Cement Volumes : Amt. Liner Cmt -rol to cover oer=; ~'3~ ~Vb'-~~~ ."~~~ oPER ~ FIELD ~~~~1 i~L-LZ~ ~S h ALL Nt1MF ER L ~ F~ ~ ZS ~"~C ~ ~-- • ~ 3~, ~~t C s ~ ~ ~~1 S'f ; D V __:eoretical TOC ~ 3~Z~,XS ~ ~~ - (o~_c~-dF . Cement Bond Log (Yes or No)~; In AOGCC File ~/ ia'~So C3L Evaluation, gone aoove perfs ~ '- ~J~r Production 'Log: '?'yve d CONC-LJS?OI1S ?art #1. ?ar~ i2: Evaluation ~~~ li-s-OS~ ~~ V SEP 1 z 2000 Sehlumberger Schlumberger-DCS ~~ ~~ _~~y 2525 Gambell Street, Suite 400 "y Anchorage, AK 99503-2838 ATTN: Beth NO. 3955 Gjl ;? Gas Gdns. Gcmmissicr ;~nchhrage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 09/11 /06 2M-35 11213795 LDL 08/16/06 1 1Y-24A 11213786 SBHP 07/25/06 1 2X-12A 11249946 PROD PROFILE W/DEFT 08/25/06 1 1D-06 11249948 INJECTION PROFILE 08/26/06 1 1A-10 11216318 INJECTION PROFILE 08/28/06 1 1J-184 11249951 PRODUCTION PROFILE 08/29/06 1 1J-127 11249953 PRODUCTION PROFILE 08/31/06 1 1J-170 11249954 PRODUCTION PROFILE 09/01/06 1 1G-04 11216321 INJECTION PROFILE 08/31/06 1 1 D-12 11216322 PRODUCTION PROFILE 09/01/06 1 2F-06 11216320 FLOWING BHP SURVEY 08/30/06 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907} 561-8317. Thank you. • ConocoPhillips June 30, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-184 and 1J-184L1 Dear Commissioner: • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~G~~ V ~~ JUL 1 2 2006 Alaska Oil & Gas Cons. C~rnission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk well 1J-184 and 1J-184L1. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, R. Thomas 1 Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~.E~~rv~® STATE OF ALASKA ~ JUL 1 2 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPO~~a~~~~a~"ssian _L__. 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: May 25, 2006 ~ 12. Permit to Drill Number: 206-044 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 24, 2006 13. API Number: 50-029-23305-00 4a. Location of Well (Governmental Section): Surface: 1530' FSL, 2424' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: May 9, 2006 14. Well Name and Number: 1J-184 At Top Productive Horizon: 962' FNL, 2323' FWL, Sec. 11, T10N, R10E, UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1093' FSL, 2413' FWL, Sec. 14, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 17105' MD / 3408' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558789 y- 5945342 Zone- 4 10. Total Depth (MD + TVD): 17870' MD / 3751' TVD 16. Properly Designation: ADL 25662, 25661, 380058 TPI: x- 558325 y- 5937568 Zone- 4 Total Depth: x- 558490 • - 5929064 Zone- 4 11. Depth where SSSV set: nipple @ 498' 17. Land Use Permit: ALK 2177 & 4604 18. Directional Survey: Yes ^/ No^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3977' MD 21. Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.6# H-40 28' 108' 28' 108' 42" 370 sx AS 1 13.375" 68# L-80 28' 3977' 28' 2238' 16" 74o sx AS Lite, 228 sx DeepCrete 9-5/8" 40# L-80 28' 9275' 28' 3423' 12.25" 589 sx DeepCRETE 5.5" 15.5# L-80 8932' 17105' 3369' 3408' 8.5" slotted liner 23. Pertorations 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" 8794' 8933' slotted finer from 9288' - 17020' MD 3426' - 3388' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production June 8, 2006 Method of Operation (Flowing, gas lift, etc.) Oil producer Date of Test 6/13/2006 Hours Tested 12 hours Production for Test Period --> OIL-BBL 385 GAS-MCF 695 WATER-BBL 35 CHOKE SIZE 15 Bean GAS-OIL RATIO 1924 Flow Tubing press. psi Casing Pressure 986 Calculated 24-Hour Rate -> OIL-BBL 731 J GAS-MCF 1406 WATER-BBL 69 OIL GRAVITY -API (corr) not available 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". ~` cot:~~~.~rlor~ } ~: ~zs DG NONE R~~MS BFI ~U< ~ ~ Zoos ~~~~a ~~-..~. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ®~ ~.~. ~c d~~ Ti~ ~~~~/r/~ r zs. 2s. 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". 1 J-184 West Sak B 9255' 3421' Base West Sak B 17050' 3394' N/A 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: Pat Reilly @ 265-6048 Printed Na Rand Thomas Title: Greater Kuoaruk Area Drilling Team Leader / Signature hone Lvs ~~~ Date 710 / O 6 INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 12/2003 Con©coPhillips Time Log Summary WeJhaew 1NQb ReVarting Time Logs _ ~ Date From To Dur S. De th E. Depth Phase Code Subcode T COM 04/23/2006 00:00 03:00 3.00 MIRU RIGMN RURD P Prep'd rig for move. Blew down water and glycol lines. Disconnected service lines. Sucked out cellar on 1J-152. 03:00 05:00 2.00 MIRU RIGMN RURD P Hled PJSM. Staged pipe shed (2 pieces), rock washer, boiler, motor, um ,and it com lexes down ad. 05:00 07:00 2.00 MIRU RIGMN RURD P Pulled sub off of well 1J-152 and s otted over 1J-184. 07:00 09:00 2.00 MIRU RIGMN RURD P Spotted pits, pump, and motor com lexes. 09:00 09:30 0.50 MIRU RIGMN RURD P Spotted rock washer and waste water tank. 09:30 11:00 1.50 MIRU RIGMN RURD P Spotted pipe shed (2 pieces). 11:00 12:00 1.00 MIRU RIGMN RURD P Worked on completing rig acceptance checklist. Hooked up all service lines and electrical lines. Turned on steam, and set up berm @ rock washer. Connected skate rail. Rig acceptance checklist complete. Ri acce ted 1200hrs 4/23/2006. 12:00 15:00 3.00 MIRU RIGMN RURD P Held PJSM. Nippled up 20" riser to diverter system and secured. Installed 4" valves in conductor. 15:00 17:00 2.00 SURFA DRILL OTHR P Loaded 5" DP in shed and strapped. P/U 5" tools and safet valves. 17:00 00:00 7.00 SURFA DRILL PULD P Held PJSM. P/U and drifted 5" DP (applying steam as needed) and S/B 195 'ts total. Total len th=6,021.21'. 04/24/2006 00:00 01:30 1.50 SURFA DRILL PULD P P/U 17 jts HWDP, jars, 1 std NMFDCs. R/B in derrick. 01:30 02:00 0.50 SURFA WELCT BOPE P Performed diverter test: Initiail Pressure=3000psi, Pressure after Closure=1800psi. 43 sec to 200 psi increase, 3min 22sec to 3000psi. Back-up Nitrogen Bottles (5) @ 2200 si. 02:00 04:00 2.00 SURFA RIGMN SVRG P C/O saver sub. 04:00 05:00 1.00 SURFA RIGMN SVRG P Held PJSM. Slipped and cut drilling line. 05:00 05:30 0.50 SURFA DRILL DHEQ P Flood conductor and check for leaks. 05:30 07:30 2.00 SURFA DRILL PULD P M/U BHA and test mud lines to 3000 si. 07:30 12:00 4.50 108 200 SURFA DRILL DRLG P Spudded well @ 0730hrs. Drilled ice from 80' to 108' MD. Drilled ahead to -' 200. ART=3.70hrs Jar hrs=39.97. PacJ~ ~ o~ ~~ ~ ~_ Time Logs Date From To Dur epth E. De th Phase Code Subcode OM 04/24/2006 12:00 12:30 0.50 200 215 SURFA DRILL DRLG P Drilled from 200' to 215' MD. ART=0.5 12:30 14:30 2.00 0 156 SURFA DRILL PULD P POOH. P/U MWD and PD sub. C/O stab on motor and set motor @ 1.83?. P/U UBHO sub and orient. RIH w/ NMFDCs to 156' MD. 14:30 15:00 0.50 156 215 SURFA DRILL OTHR P Run wireline gyro survey @ 75' MD (0.21? w/ 262.59? azimuth) and wash to 215' MD. 15:00 00:00 9.00 215 525 SURFA DRILL DDRL P Drilled 16" surface hole from 215' to 525' MD taking gyro surveys @ 90' intervals ART=1.23 AST=5.87 TDT=7.10 Jar hrs=47.07 PUW=67K SOW=67K ROT=67K TQon/off=2K/1 K Max Gas=28 Units 04/25/2006 00:00 12:00 12.00 525 1,425 SURFA DRILL DRLG P Drilled 16" surface hole from 525' to 1,425' MD/ 1,340' TVD. ART=1.36, AST=7.69, ADT=9.05. PU=84K, S0=80K, ROT=84K, TQon 2-7K, TQoff=1-4K, Max Gas=42 BTU, Jar H rs=56.12 12:00 22:30 10.50 1,425 2,466 SURFA DRILL DRLG P PJSM: Drilled from 1,425' to 2,466' MD, 1879" TVD. ART=1.6, AST=5.45, ADT=7.34. PU=94K, S0=70K, ROT=82K, TQon=6-7K, TQoff=3-4K, Max Gas=562 BTU at 2410'. Decreased to +/-100 BTU within the next 40'. Jar hrs=63.46. 22:30 23:00 0.50 2,466 2,466 SURFA DRILL REAM P Back reamed up one stand at TD. Tight and slightly packing off from 2466' to 2370'. 23:00 00:00 1.00 2,466 1,915 SURFA DRILL REAM P BROOH from 2,466 to 1,915' MD at 650 gpm, 40 rpm, 15-20 fpm. Watchin careful! for ackin off. 04/26!2006 00:00 02:45 2.75 1,915 200 SURFA DRILL REAM P Continue to BROOH from 1915' to 200' MD. 1800 psi, 153 spm, 45 rpm, TQ= 2-10K. 02:45 04:00 1.25 200 0 SURFA DRILL TRIP P POOH on elevators to surface with no problems. Change out pressure drop sub and turn motor to 1.15 de rees. 04:00 06:00 2.00 0 2,466 SURFA DRILL TRIP P TIH to 2450. Wash down to 2466'. Surve . 06:00 12:00 6.00 2,466 2,975 SURFA DRILL DRLG P Drill 16" hole from 2466' to 2975' MD, 2005' TVD. ART=2.49, AST=1.18, ADT=3.67. PU=93K, S0=69K, ROT=80K, TQon=8-10K, TQoff=2-8K Max Gas=144 BTU, Jar hours = 67.13 12:00 00:00 12.00 2,975 3,895 SURFA DRILL DRLG P PJSM. Drilled from 2975' to 3895' MD, 2228' TVD. ART=3.52, AST=4.7, ADT=8.22. PU=115K, S0=58K, ROT=82K, TQon=7-8K, TQoff=5-7K Jar hours = 75.35 Max Gas=144 BTU ..~®.a ~ e ~ age ~ t~f 2~ Time Logs Date From To Dur th E. De th Phase Code Subcode „OM 04/27/2006 00:00 00:30 0.50 3,895 3,988 SURFA DRILL DRLG P Drilled from 3895 to TD of 3988' MD, 2240.9' TVD. ART=0.74, AST=0.13, ADT=0.87 00:30 02:15 1.75 3,988 3,988 SURFA DRILL CIRC P CBU at 177 spm, 750 gpm, 2200 psi, TQ=7K 02:15 07:30 5.25 3,988 424 SURFA DRILL REAM P Survey. Monitor well: static. BROOH from 3988' to 424' MD. 07:30 08:15 0.75 424 70 SURFA DRILL TRIP P POOH on elevators from 424' to 70' MD. 08:15 09:30 1.25 70 0 SURFA DRILL PULD P Download MWD and LD BHA. 09:30 10:30 1.00 0 0 SURFA DRILL OTHR P Clean and clear rig floor. 10:30 11:30 1.00 0 0 SURFA CASIN( SFTY P PJSM. R/U casing equipment. 11:30 12:00 0.50 0 0 SURFA CASIN( PUTB P Make dummy run with 13 3/8" hanger. Satisfacto 12:00 14:30 2.50 0 84 SURFA CASIN( RNCS P PJSM. Run 13 3/8" casing. Jt 2 had damaged threads. LD and CO shoe 'oint and 't 2. 14:30 00:00 9.50 84 3,433 SURFA CASIN( RNCS P PU 13 3/8" casing. Place centralizers per program. Filling 6 bbls per joint. Check up and down weights every 10 joints. Break circulation and wash in from 1255 to 1428 at 60 bpom, 300# (Without pump PU=140K, S0=96K). Continue to run casing at 1608, S0=50-45 K, wash in from 1598-1682. (Without pumps PU=153K, S0=90K). Run to 1767', wash to 1894. Run to 1927. Wash to 1968. Run to 2130', wash to 2299'. Run to 2470'. Without pumps PU=270K, S0=80K. Wash to 3390 (Without pump PU=265K, S0=75K). Run in to 3433. Total 83 joints ran in, 11 washed in. 94 joints total. 04/28/2006 00:00 00:15 0.25 3,433 3,941 SURFA CASIN( RNCS P Continue to run 13 3/8" casing from 3,433' to 3941 00:15 00:30 0.25 3,941 3,977 SURFA CASIN( PUTS P M/U hanger and landing joint. RIH to 3977' casin shoe de th. 00:30 02:00 1.50 3,977 3,977 SURFA CASIN( CIRC P Circulate and condition mud at 7 bpm, 400 psi, PU=260K, S0=60K. Working pipe every 5 mins over 10 feet. Slightly sticky towards bottom & after circulatin im roved. 02:00 02:45 0.75 3,977 3,977 SURFA CASIN( PUTB P UD franks tool M/U cement head. 02:45 05:45 3.00 3,977 3,977 SURFA CASIN( CIRC P Continue to circulate and condition mud per mud engineer. Mud before cond. 9.6 ppg, Vis 175, PV 23, YP 47. Mud after cond. 9.0+ ppg, Vis 40, PV 12, YP 6. Held PJSM with Dowell cmt'ers, ASRC vac trucks, All rig ersonnel. 05:45 06:00 0.25 3,977 3,977 SURFA CEMEf~ SFEQ P Pump 5 bbls water to pressure test cement lines to 3000 si. e .~._.® ®a ~ ~ ~~~ 3 of ?3 ~..P Time Logs Date From To Dur th E. De th Phase Code Subcode OM 04/28/2006 06:00 10:00 4.00 3,977 3,977 SURFA CEME~ DISP P Pump cement per plan. Pumped 50 bbls of CW100, Followed by 50 bbls 10.5 ppg Mud Push with red bye. Dropped bottom plug, began mixing and pumping Articset Lite lead slurry. Pumped 601 bbls, 729 sks, Yeild 4,63 ft/sk, at 6.6 bpm, at 120 psi. Followed by Tail cement: 100.1 bbls of DeepCrete, 228 sks, 12.0 ppg, Yield 2.47 ft/sk, at 6.4 bpm @ 150 psi. Shut down and dropped btm plug. Kick plug out with 20 bbls of fresh water. Turned over to rig pumps and displaced cement with 556.0 bbls, 5522 stks, at 7.6 bpm, 76 spm @ Initial pressure 300 to final 800 psi at 7.6 bpm. Reciprocated pipe 10' every 5 minutes until 131.0 bbls cmt around shoe (1750' up annulas). Did not visually see red dyed mud push. Slowed rate down to 30 spm (3.0 bpm) @ 550 psi at 5480 stks. Saw thick returns at 94.8 bbls prior to bump. Bumped plug with 1100 psi, held 10 mins. Check floats, Floats held-OK. CIP at 09:50 hrs 2/28/06. Had full returns through out job with 44.8 bbls cmt returns to surface. Shoe at 3977' MD, Float collar at 3889. 10:00 12:00 2.00 3,977 3,977 SURFA CEME~ RURD P Check float equipment. Rig down cement equipment, landing jiont. Flush the stack. 12:00 15:00 3.00 0 0 SURFA WELCT NUND P Nipple down diverter system. Move everything from cellar. Bring in Vetco Gra wellhead. Clean u wellhead. 15:00 16:45 1.75 0 0 SURFA WELCT NUND P Nipple up 13 3/8" 5000#, Wellhead. Test lower flan a to 5000 si. 16:45 19:45 3.00 0 0 SURFA WELCT NUND P Nipple up BOPEs, attache turnbucles. Rig up secondary annulus values. Rig u flow ni le. 19:45 21:00 1.25 0 0 SURFA WELCT NUND P Change lower pipe rams to 9 5/8". 21:00 21:45 0.75 0 0 SURFA WELCT NUND P Bring test equpiment up to floor and rig u. 21:45 00:00 2.25 0 0 SURFA WELCT BOPE P Test BOPEs. 250 psi low, 3000 psi high. Testing witnessed by AOGCC John Crisp. Note; Cement samples caught from cement to surface has otten had. e _ m~ ~~ .~ ~__ ~~ 4 ~f ~;~ Time Logs' ~ Date From To Dur th E. De th Phase Code Subcode T OM 04/29/2006 00:00 02:30 2.50 0 0 SURFA WELCT BOPE P Continue to test BOPEs. 250 psi low, 3000 psi high. Test Top pipe rams CV 1, 12, 13, 14, Man Kill valve, upper IBOP, HCR Kill, CV 9, 11, Lower IBOP, CV 54, 8, 10, Dart valve, CV 4, 6, 7, Floor valve, CV 2, HCR Choke, Manual choke valve, annular preventer, lower pipe rams 9 5/8", blind rams, accumulator test, system pressure=3000 psi, after closed = 1800 psi, 200 psi attained 38 sec, full pressure attained 3 min 18 sec, Nitro en bottle ave=2300 si. 02:30 03:00 0.50 0 0 SURFA WELCT OTHR P Rig down Test equipment. Set wear bushin 12.415" ID. 03:00 04:00 1.00 0 0 SURFA RIGMN SVRG P PJSM for servicing top drive. Service To Drive and install short bails. 04:00 06:00 2.00 0 78 SURFA DRILL PULD P PJSM. MU BHA #3, Bit, Geop Pilot, NMFC, MWD, 8" pulser, and NMF sub. 06:00 07:00 1.00 78 78 SURFA DRILL OTHR P Plug in and upload MWD. 07:00 07:45 0.75 78 448 SURFA DRILL TRIP P RIH with BHA and 6 stands of HWDP. LD excess HWDP. 07:45 11:15 3.50 448 3,882 SURFA DRILL PULD P PJSM. P!U 5" DP from pipe shed. RIH with 36 joints and then P/U ghost reamer. RIH picking up 63 more joints to 3882' MD. 11:15 12:00 0.75 3,882 3,882 SURFA DRILL CIRC P CBU at 3882' MD. 154 spm, 650 gpm, 1300 si, TQ=S-10K. 12:00 13:00 1.00 3,882 3,882 SURFA CASIN( DHEQ P Blow down top drive. Rig up for casing test. Test 13 3/8" casing to 3000 psi for 30 mins. 13:00 13:30 0.50 3,882 3,882 SURFA CEME~ CIRC P Pump tube pill. Torque before = 5-10K, after 7K. 13:30 16:45 3.25 3,882 4,008 SURFA CEME~ DRLG P Tag float equipment at 3884' MD. Drill float collar and shoe track plus 20 ft of new hole to 4008' MD. Shoe at 3975' M D. 16:45 17:30 0.75 4,008 4,008 SURFA DRILL CIRC P Displace over to LSND mud at 730 m, 1500 si. 17:30 18:30 1.00 4,008 4,008 SURFA DRILL LOT P Rig up and perform LOT at 4008' MD, 2238' TVD, 9.1 ppg OMW, 642 psi, ECD = 14.6 18:30 19:30 1.00 4,008 4,010 INTRMI DRILL DRLG NP Attempted to start drilling. Made 2' and torsional efficiency light showing red. Added tubes to the mud. - _ e ..~~~ ~. -~ ~~ e ~~e s ~f Time Logs Date From To Dur th E. De #h Phase Code Subcode Tt`~ COM _ 04/29/2006 19:30 00:00 4.50 4,010 4,623 INTRM1 DRILL DRLG P Drilled from 4010' MD to 4623' MD, 2374' TVD. ADT=2.7 hrs. PU=105K, S0=70K, ROT=87K, TQon=6/8K, TQoff=5/7K ECDs=9.68, Max Gas=43 BTU, Jar hours=94.21 SPR at 4248 MD, 2292' TVD #1 20 spm / 90 psi, 20 spm / 130 psi #2 20 s m / 100 si, 30 s m /140 si 04/30/2006 00:00 12:00 12.00 4,623 6,010 INTRMI DRILL DRLG P Drilled from 4,623' to 6,010' MD, 2,699' TVD. WOB=2-25, 130 RPM, 700 gpm PU=124K, S0=70K, ROT=89K, TQon=2-10K, TQoff=7-10 Max Gas=37 BTU, Jar hrs=101.78 ECDs=9.68 SPR at 5,968' MD, 2,689' TVD #1 30 spm / 170 psi 40 spm / 220 psi #230s m/170 si 40s m/210 si 12:00 13:45 1.75 6,010 6,288 INTRM1 DRILL DRLG P Drilled from 6,010' to 6,288' MD. ECD s ike while makin connection 13 13:45 15:00 1.25 6,288 6,288 INTRM1 DRILL CIRC P Circulate while rotating or reciprocating pipe. 150 rpm, TQ=11 K, increase pumps to 750 gpm at 1600 psi. HOIe unloaded at bottoms u . 15:00 00:00 9.00 6,288 7,123 INTRM1 DRILL DRLG P Drilled from 6,288 to 7123' MD, 2,958' TVD. Pumped Hi Vis sweep at 6383' MD, 15% increase in cuttings. WOB=5-25K, 110/150 rpm, 650 gpm. PU=125K, S0=75K, ROT=96K, TQon=12/13K, TQoff=10K Max Gas=51 BTU, Jar hrs=108.69 ECDs=9.9 SPR at 6,935' MD, 2,958' TVD #1 30 spm / 240 psi 40 spm / 280 psi #2 30 s m / 240 si 40 s m / 290 si 05/01/2006 00:00 05:45 5.75 7,123 7,862 INTRM1 DRILL DRLG P Drill from 7123' to 7862' MD, 3127' TVD. ART=2.5, WOB=5-15K, 120 RPM, 600 m. 05:45 06:30 0.75 7,862 7,862 INTRMI DRILL CIRC P Screens blinding off with UGNU sands. Circulate until shakers cleaned u . ~.~~m® _~_ _ ~°~e ;~ of 2~~ ® ~. _ ~~ ~ __ _ ~ Time Logs _ Date From To Dur th E. De th Phase Code Subcode OM 05/01/2006 06:30 12:00 5.50 7,862 8,370 INTRM1 DRILL DRLG P Drill from 7862' to 8370' MD, 3256' TVD. ART=1.99, Total ART=4.49 hrs, WOB=5-15, 120 rpm, 600 gpm PU=135K, S0=80K, ROT=103K, TQon=12-14K, TQoff=9-10K ECD=9.78, Max Gas=220 BTU, Jar hours=113.18 SPR at 8324' MD, 3244' TVD MW=9.1 PP9 #1 30 spm / 240 psi 40 spm / 280 psi #2 30 s m / 240 si 40 s m / 280 si 12:00 00:00 12.00 8,370 9,162 INTRM1 DRILL DRLG P Drill from 8370' to 9162' MD, 3407' TVD. ART=4.57, WOB=5-20, 90/150 rpm, 600 gpm PU=151 K, S0=67K, ROT=101 K, TQon=15-16K, TQoff=14K ECD=9.87, Max Gas=124 BTU, Jar hours=117.75 SPR at 9067' MD, 3393' TVD MW=9.2 PP9 #1 30 spm / 250 psi 40 spm / 310 psi #2 30 s m / 260 si 40 s m / 310 si 05/02/2006 00:00 00:45 0.75 9,162 9,280 INTRM1 DRILL DRLG P Drilled from 9162' to TD of 9280', 3425' TVD. ART=0.43 PU-105K, So-68K, ROT=105K, TQon=S-15K, TQoff=12-20K Max gas=197 BTU, Jar hours=118.18 ECD 9.97 00:45 02:00 1.25 9,280 9,187 INTRM1 DRILL CIRC P Survey at TD. Get SPR. Monitor well, static. Circulate. Rack back one stand and pump 50 bbls hi vis sweep. Work pipe slowly & circulate sweep out at 800 gpm, 190 spm, 150 rpm. TQ=11-14K. Saw very little increase in cuttings. 9280' MD, 3425' TVD MW=9.2 ppg #1 30 spm / 230 psi 40 spm / 280 psi #2 30 spm / 210 psi 40 spm / 300 si 02:00 10:00 8.00 9,187 9,280 INTRM1 DRILL REAM P RIH and tag bottom. BROOH at 190 s m=800 m, 2400 si, 150 r m. 10:00 12:00 2.00 9,280 9,280 INTRM1 DRILL CIRC P Pump 50 bbl weighted hi vis sweep at 3974' MD, 800 gpm, 190 spm, 100 rpm, TQ=4-5K, 1800 psi, +BU. PU=100K, SO-60K, Monitor well: static. Pum d 'ob. 12:00 14:00 2.00 9,280 445 INTRM1 DRILL TRIP P POOH to BHA. 14:00 16:30 2.50 445 0 INTRM1 DRILL PULD P LD BHA #3. XOs, Flex DCs, Plug in and download MWD. Continue to LD BHA. 1~ e® ~ ~~~ T tit ~3 ~ ~_.._...._....._a ® Time Logs _ II Date From To Dur . I th E. De th Phase Code Subcode T OM 05/02/2006 16:30 17:45 1.25 0 0 INTRMI DRILL OTHR P Grade bit and pull wear ring. Clear and clean ri floor. 17:45 19:30 1.75 0 0 INTRM1 CASIN( RURD P PJSM. Gring casing tools to rig floor. RU to run casin . 19:30 00:00 4.50 0 1,606 INTRM1 CASIN( RNCS P PJSM with other crew. PU shoe track and float. Test floats. RIH with 9 5/8" casin to 1606' MD with centralizers. 05/03/2006 00:00 03:45 3.75 1,606 3,970 INTRM1 CASIN( RNCS P PJSM. Continue to run 9 5/8" casing er detail from 1609 to 3970' MD. 03:45 04:30 0.75 3,970 3,970 INTRM1 CASIN( CIRC P CBU at surface shoe, 3970' MD. 6 b m, 350 si. 04:30 09:30 5.00 3,970 6,900 INTRM1 CASIN( RNCS P Cont to run casing to 6900. PU=200K, S0=70K. 09:30 11:00 1.50 6,900 6,979 INTRMI CASIN( CIRC P CBU and condition mud. Wash down to 6979 at 550 si, 7 b m. 11:00 12:00 1.00 6,979 7,244 INTRM1 CASIN( RNCS P Run casing to 7244' MD (190 jts), PU=205K, S0=67K. 12:00 16:00 4.00 7,244 9,275 INTRM1 CASIN( RNCS P Cont. to run casing to 9275' MD. Last LoDrag centralizer on jt 232. Total 'oints run 243. PU=225K, S0=85K. 16:00 17:30 1.50 9,275 9,275 INTRM1 CASIN( CIRC P Circulate and condition mud. Stage to 7 b mat 500 si. PU=205K, S0=90K. 17:30 18:00 0.50 9,275 9,275 INTRM1 CASIN( RURD P Rig down franks fillup tool. Blow down to drive. Ri u cement head. 18:00 20:00 2.00 9,275 9,275 INTRM1 CASIN( CIRC P Circulate and condition mud at 7 bpm, 500 si. Hold PJSM for cement 'ob. 20:00 21:30 1.50 9,275 9,275 INTRM1 CEME~ CIRC P Pump 10 bbls of CW100 and pressure test lines to 3500 psi. Pump 40bbls more of CW100. Pump 75bbls MudPush and drop bottom plug. Follow with 240 bbls of 12.5ppg, DeepCrete cement. Wash lines and dro bottom lu . 21:30 00:00 2.50 9,275 9,275 INTRM1 CEMEI~ DISP P Switch over to rig pumps. Rig chase plug with OBM. Reciprocated pipe until 6400 stks. Bumped plug at 6887 stks, 688 bbls mud. 05/04/2006 00:00 00:30 0.50 0 0 INTRM1 WELCT NUND P Drain stack. Nipple down BOPE. 00:30 01:30 1.00 0 0 INTRM1 WELCT NUND P Set Emergency slips with 75K down weight. Had to clean pipe very well to et the sli s to set. 01:30 03:00 1.50 0 0 INTRM1 WELCT NUND P RU WACHS pneumatic cutter & cut casing per Vetco rep. Pull cut joint out of the hole. Len th but =16.8'. 03:00 04:30 1.50 0 0 INTRM1 WELCT BOPE P Nipple up BOPE. Set packoff, test to 2500 psi for 10 mins. Set wear bushin . 04:30 07:00 2.50 0 0 INTRM1 WELCT BOPE P RU to 13 3/8" and 9 5/8" annulus and pressure test line. Perfrom infectivity LOT. Observed break over at 7.0 bbls and 210 psi (EMW=10.6 ppg). Pumped additional 23bbls mud. Flushed with 262 bbls of fresh water at 3 bpm, 550 psi. Shuffle pipe in derrick while um in water down annulus. .e ___ ®_ e _ ~. _~ ~'~c~~ $ ~~ ~3 _ Time Logs Date From To Dur th E. De th Phase Code Subcode T"~ COM 05/04/2006 07:00 12:00 5.00 0 0 INTRM1 DRILL PULD P RIH with mule shoe on DP and PU 22 stands of G drillpipe from derrick. Continue to RIH with S-135 drill pipe from shed. 12:00 13:00 1.00 0 0 INTRM1 DRILL PULD P Continue to PU S-135 drill pipe from shed, 54 stands. to shuffle order of i e in derrick. 13:00 16:00 3.00 0 0 INTRM1 DRILL PULD P POOH and stand back drill pipe with S-135 in the back to use on the top ortion of B lateral. 16:00 16:45 0.75 0 0 INTRM1 DRILL SFTY P Clear and clean rig floor. Bring jewerly to rig floor for next run. PJSM for PU BHA#4. 16:45 19:45 3.00 0 446 INTRM1 DRILL TRIP P Picking up BHA #4. Plug in and upload MWD (1 hr). Continue to PU BHA and RIH. 19:45 20:45 1.00 446 446 INTRM1 RIGMN SVRG P PJSM. Cut and slip drilling line. 20:45 21:15 0.50 446 495 INTRM1 DRILL DHEQ P Shallow test MWD. Break in GeoPilot. 21:15 00:00 2.75 495 2,780 INTRM1 DRILL TRIP P RIH with BHA #4, singling in from shed with 80 'oints, to 2780' MD. 05/05/2006 00:00 02:30 2.50 2,780 9,157 INTRM1 DRILL TRIP P Continue to single in with more 22 joints from shed and pipe from the derrick to 9157' MD. 02:30 03:30 1.00 9,157 9,157 INTRM1 CASIN( DHEQ P R/U and test 9 5/8" intermediate casin to 3000 si from 30 mins. 03:30 05:45 2.25 9,157 9,300 INTRM1 CEMEI~ DRLG P RIH to 9199' MD and drill out float equipment, shoe teack and 20' of new hole to 9300' MD. 05:45 06:15 0.50 9,300 9,300 INTRM1 DRILL CIRC P CBU at 169 spm, 600 gpm, ROT 90 r m with 2800 si. 06:15 07:00 0.75 9,300 9,300 INTRM1 DRILL LOT P Perform LOT at 9300' MD, 3428' TVD. Broke over at 14.4 ppg. Clean hole ECD is 9.8 at 600 m. 07:00 12:00 5.00 9,300 9,650 PROD1 DRILL DRLG P Drill from 9300' MD to 9650' MD, 3448' TVD. ADT=3.61 hrs PU=156K, S0=60 K, ROT=100K, TOon=14/15K, TQoff=13K Max ECDs=9.89, Max Gas=118 BTU, Jar hours 119.09 SPR at 9431 MD, 3445' TVD, 8.7+ MD #1 30 spm / 280 psi 40 spm / 380 psi #2 30 spm / 280 psi 40 spm / 370 si ~~~e .~~~ ~~ ~~ .age :~ of ~3 ~®e_ e Time Logs i Date From To Dur S: th' E. De th Phase Code Subcode OM _ 05/05/2006 12:00 00:00 12.00 9,650 10,825 PROD1 DRILL DRLG P Drill from 9,650' MD to 10,825' MD, 3431' TVD. The torsional efficiency was in the red zone after HWDP got outside of casing. Did not improve with WOB and RPM changes. Improved after HWDP reached +/_10,300' MD. ADT=6.26 hrs PU=160K, S0=50 K, ROT=100K, TQon=16K, TQoff=16K Max ECDs=10.46, Max Gas=102 BTU, Jar hours 125.35 SPR at 10,279 MD, 3429' TVD, 8.8 MD #1 30 spm / 330 psi 40 spm /440 psi #2 30 spm / 350 psi 40 spm / 440 si 05/06/2006 00:00 00:30 0.50 10,825 10,914 PROD1 DRILL DRLG P Drill from 10,825' MD to 10,914' MD, ADT=0.51 00:30 01:30 1.00 10,914 10,914 PROD1 DRILL CIRC P Pump hi vis sweep at 140 spm, 575 gpm, 3000 psi per DD and MWD hands. Ve little cuttin s increase. 01:30 12:00 10.50 10,914 11,862 PROD1 DRILL DRLG P Drilled from 10,914'to 11,862' MD, 3419' ND. ADT=4.61 PU=165K, S0=42K, ROT=100K, TQon=14K, TQoff=15-20K ECDs=10.92, Max Gas=206 btu, Jar hours=130.47 Concretion depths: 11,148'/11,153', 11,759'/11,764', 11,770'/11,773' MDs SPR at 11,751' MD, 3422' TVD MW=8.8 pP9 #1 30 spm / 390 psi 40 spm / 480 psi #2 30 spm / 420 psi 40 spm / 510 si 12:00 00:00 12.00 11,862 12,870 PROD1 DRILL DRLG P Drilled from 11,862' MD to 12,870' MD 3412' TVD. ADT=5.77 PU=175K, S0=0, ROT=105K, TQon=19K, TQoff=17K ECDs=11, Max Gas=174 btu, Jar hours=136.24 Concretion depths: SPR at 12,868' MD, 3411' TVD MW=8.75 ppg #1 30 spm / 360 psi 40 spm /440 psi #2 30 spm / 410 psi 40 spm / 490 si ~~a~ ' ~ gat 3 Time Lo~c s_ Date From To Dur S, e th E. Depth Phase Code Subcode OM 05/07/2006 00:00 12:00 12.00 12,870 14,010 PROD1 DRILL DRLG P Drilled from 12,870' MD to 14,010' MD 3403' TVD. ADT=6.47 hrs PU=180K, S0=0, ROT=100K, TQon=18-19K, TQoff=15-18K ECDs=11.20, Max Gas=267 btu, Jar hours=142.71 Concretion depths: 12,888'/12,892, 13,002'/12,238', 13,238'/13,243', 13,328'/13,331', 13,380'/13,392', 13,438'/13441', 13,404'/13,408', 13,457'/13,465', 13,495'/13,500', 13,620'/13,635' SPR at 13,820' MD, 3405' TVD MW=8.8 PP9 #1 30 spm / 400 psi 40 spm / 460 psi #2 30 spm / 480 psi 40 spm / 530 si 12:00 00:00 12.00 14,010 15,343 PROD1 DRILL DRLG P Drilled from 14,010' MD to 15,343' MD 3391' TVD. ADT=4.49 hrs PU=185K, S0=0, ROT=102K, TQon=18K, TQoff=20K ECDs=11.08, Max Gas=175 btu, Jar hours=147.2 Concretion depths: 14,473'/14,477', 14,458'/14,560' SPR at 15,056' MD, 3396' TVD MW=8.7 PP9 #1 30 spm / 430 psi 40 spm / 520 psi #2 30 spm / 420 psi 40 spm / 500 si 05/08/2006 00:00 12:00 12.00 15,343 16,379 PROD1 DRILL DRLG P Drilled from 15,343' MD to 16,379' MD 3377' TVD. ADT=5.2 hrs PU=190K, S0=0, ROT=100K, TQon=20K, TQoff=21 K ECDs=11.53, Max Gas= 950 btu, Jar hours=152.4 Concretion depths: 15,691'/15,700', 15,805'!15,813', 16,085'/16,093' SPR at 16,197' MD, 3375' TVD MW=8.7 PP9 #1 30 spm / 550 psi 40 spm / 600 psi #2 30 spm / 540 psi 40 spm / 590 si C~ .~.-----~_~~. ~~ ~ _ ~~~~ 11 csf ~3 Time Logs Date_ From To Dur S. th E. De th Phase Code Subcode T QM 05/08/2006 12:00 00:00 12.00 16,379 17,150 PROD1 DRILL DRLG P _ Drilled from 16,379' MD to 17,150' MD 3418' TVD. ADT=4.62 hrs PU=226K, S0=0, ROT=106K, TQon=18/20K, TOoff=22K ECDs=11.84, Max Gas=1118 btu, Jar hours=157.02 SPR at 17,052' MD, 3392' TVD MW=8.7 ppg #1 30 spm / 540 psi 40 spm / 630 psi #2 30 spm / 540 psi 40 spm /640 si 05/09/2006 00:00 05:15 5.25 17,150 17,795 PROD1 DRILL DDRL P Drilled from 17,150' to 17,795' MD. ADT=3.73 Concretion de ths: 17,679' to 17,682' 05:15 06:15 1.00 17,795 17,795 PROD1 DRILL CIRC NP Circulated and evaluated for geology. 06:15 07:30 1.25 17,795 17,870 PROD1 DRILL DDRL P Cont'd drilling from 17,795' to 17,870' MD / 3751' TVD w/ WO6=10-15K, 150 rpm, 611 gpm, 3900 psi. ADT=0.75 Jar hrs=161.5 PUW=250K SOW=O ROT=114K TQon/off=19K-21 K/19K-21 K ECD=12.2 Max Gas=129 Units 07:30 09:45 2.25 17,870 17,150 PROD1 DRILL WPRT P BROOH from 17,870' to 17,150' MD w! 150 r m, 611 m, 3900 si. 09:45 12:00 2.25 17,150 17,150 PROD1 DRILL CIRC P Circ'd a hi-vis weighted sweep and 2X BU w/ 150 r m, 611 m, 3900 si. 12:00 13:30 1.50 17,150 17,150 PROD1 DRILL CIRC P Cont'd to circ w/ 150 rpm, 611 gpm, 3800 si. Observed well, static. 13:30 15:00 1.50 17,150 16,295 PROD1 DRILL TRIP P POOH on elevators from 17,150' to 16,485' w/improper fill. Screwed in and pumped out from 16,485' to 16,295' MD. 15:00 00:00 9.00 16,295 9,620 PROD1 DRILL WPRT P BROOH from 16,295' to 9,620' MD. 05/10/2006 00:00 00:15 0.25 9,620 9,250 PROD1 DRILL WPRT P Cont'd BROOH from 9,620' to 9,250' M D. 00:15 01:30 1.25 9,250 9,250 PROD1 DRILL CIRC P Pumped weighted hi-vis sweep @ 600 m, 150 r m, 2850 si. 01:30 03:00 1.50 9,250 9,250 PROD1 RIGMN SVRG P Held PJSM, cut and slipped 84' drill line. Serviced TD. 03:00 03:15 0.25 9,250 10,177 PROD1 DRILL WPRT P TIH from 9,620' to 10,177' MD. SOW=O. 03:15 12:00 8.75 10,177 16,295 PROD1 DRILL WPRT P Washed and reamed in hole from 10,177' to 16,295' w/ 65 rpm, 313 gpm, 1500 si. 12:00 13:00 1.00 16,295 17,150 PROD1 DRILL WPRT P Cont'd to wash and ream from 16,295' to 17,150' MD w/ 65 rpm, 315 gpm, 1600 si and TQ=21 K. 13:00 15:30 2.50 17,150 17,150 PROD1 DRILL CIRC P Pumped a weighted hi-vis sweep and circa until shakers cleaned up w/ 600 m, 150 r m. I Page 12 gat Time Logs Date From To Dur ~ _ pth E De th Phase Code Subcode OM 05/10/2006 15:30 16:30 1.00 17,150 17,150 PROD1 DRILL OTHR P Displaced well to SFOBM from 17,150' to 8,600' MD w/ 600 gpm, 150 rpm, TQ=20K, and 3750 psi. PUW=210K SOW=OK 16:30 23:30 7.00 17,150 9,157 PROD1 DRILL TRIP P Observed well, static. POOH on elevators from 17,150' to 9,157'. UD 8 stands of G DP, installed super sliders be ininin std # 124. 23:30 00:00 0.50 9,157 9,157 PROD1 DRILL OTHR P Observed well, static. Blew down TD. Crew chan out. 05/11/2006 00:00 00:45 0.75 9,157 8,599 PROD1 DRILL TRIP P Cont'd TOOH from 9,157'to 8,599' MD while installing super-sliders. Dropped rabbit 2 3/8" 9,065' std #93 . 00:45 03:45 3.00 8,599 446 PROD1 DRILL TRIP P Cont'd to TOOH from 8,599' to 446' MD. 03:45 04:45 1.00 15,797 PROD1 DRILL PULD P S/B 3 stds HWDP, 1 std NMFDCs. UD float sub, and retrieved rabbit from to of'ars. 04:45 06:15 1.50 446 446 PROD1 DRILL PULD P Downloaded MWD. 06:15 07:00 0.75 446 0 PROD1 DRILL PULD P UD BHA #4 including: TM, HCIM, smart stab, EWR+DGR+PWD, smart stab, NMFDC w/ DM, eo- ilot and bit. 07:00 07:30 0.50 0 0 PROD1 DRILL OTHR P Cleared and cleaned rig floor. 07:30 08:30 1.00 0 0 COMPZ CASIN< RURD P Held PJSM, P/U and R/U 5 1/2" casin tools. 08:30 12:00 3.50 0 4,326 COMPZ CASIN( RNCS P RIH w/ 5 1/2" liner to 4,326' MD (91 'ts . 12:00 15:30 3.50 4,326 8,932 COMPZ CASIN( RNCS P Cont'd to RIH from 4,326' to 8,932' MD. P/U and ran seal assy, and ZXP acker. PUW=92K SOW=58K. 15:30 00:00 8.50 8,932 15,797 COMPZ CASIN( RUNL P Ran liner on DP from derrick. With 11 stds DP: PUW=105K SOW=65K ROT=88K TQ=4-5K w/ 25 rpm. RIH to 13,950' where SOW=O. Rotated liner in with 25 rpm and TQ=12K. RIH to 15,797'. 05/12/2006 00:00 02:00 2.00 15,797 17,105 COMPZ CASIN( RUNL P Cont'd to rotate liner from 15,797' to 17,105' MD w/ 25 rpm and TQapprox=20K. PUW=195K ROT=74K. 02:00 03:30 1.50 17,105 8,933 COMPZ CASIN( OTHR P Dropped ball and pumped down with 4.5 bpm to 1200 stks, 1.5 bpm to 1551 stks when ball seated. Pressured up and set ZXP w/ 4000 si. 03:30 08:00 4.50 8,933 0 COMPZ DRILL TRIP P Checked flow, static. POOH from liner to 8,933' MD. Stra ed OOH. 08:00 08:30 0.50 0 0 COMPZ DRILL PULD P Broke out and UD liner running tool. 08:30 09:00 0.50 0 0 COMPZ DRILL OTHR P Cleaned and cleared rig floor. 09:00 10:00 1.00 0 0 COMPZ WELCT NUND P Pulled wear bushing, installed test plug, filled stack and choke manifold w/water. ~ ~ _ ~.~~_ ~~e 1 ' oaf e Time Los ti` Date From To Dur th E. De th Phase Code Subcode T OM 05/12/2006 10:00 12:00 2.00 0 0 COMPZ WELCT BOPE P Started ROPE test w/ low pressure test @ 250 psi and high @ 3000 psi. Tested 3.5"X6" varible top rams, blind rams, choke valves 1-14, manual choke and kill valves, HCR choke and kill valves, 5" TIW valve, 5" dart valves. 12:00 14:00 2.00 0 0 COMPZ WELCT BOPE P Cont'd testing BOPE including gas alarms. Witnessing of test waived by Chuck Scheve 4:45 am 5/12/2006. 14:00 14:30 0.50 0 0 COMPZ WELC7 NUND P Pulled test plug, set wear ring. Blew down stand i e, choke, and all lines. 14:30 16:00 1.50 0 0 COMPZ EVALV~ RURD P Held PJSM. R/U and P/U a-line cement bond to USIT tools. 16:00 19:30 3.50 0 0 COMPZ EVALV~ WOEQ T CHECK USIT TOOL. NO AUXILLARY POWER (CAN'T TURN SUB). BEGIN TROUBLESHOOTING CALL FSM. REQUEST BU POWER DRAWER AND COMPUTER RACK BE SENT FROM PRUDHOE. REPLACE FAILED POWER DRAWER (WFAD -FOUND KNICKED WIRE ON BACKPLANE). FINISH WITH USIT CHECKS. 19:30 00:00 4.50 0 0 COMPZ EVAL~/1, ELOG P RIH w/ a-line to 3,000'. Begin to tractor down @ 1000' per hour. RIH to +/- 6,000' MD midni ht. 05/13/2006 00:00 08:00 8.00 0 0 COMPZ EVALV~ ELOG P Cont'd to RIH w/ USIT tool on tractor. Logged interval of interest w/good cement to 6,750' MD and fair cement to 6,250' MD (top of UGNU @ 6,469' MD). POOH w/ logging tools and R/D Schlumber er. 08:00 09:00 1.00 0 0 COMPZ RIGMN RGRP NP Replaced bushings in link tilt on TD. 09:00 09:45 0.75 0 0 PROD2 DRILL PULD P Held PJSM. Began to P/U whipstock assembl from beaver slide. 09:45 12:00 2.25 0 131 PROD2 DRILL PULD P P!U assembly as follows: seal, stop sub, unloader, pup jt, 2 jts 5" DP, blank sub, 9 5/8" trip anchor, safety disconnect, drain sub, debris sub, 8" OD master whipstock, window mill, lower watermelon mill, flex jt, upper watermelon mill. 12:00 13:30 1.50 131 215 PROD2 DRILL PULD P P/U 1 jt HWDP, float sub. Orient whipstock. Attempted to program MWD. Not res ondin correct) . 13:30 14:30 1.00 215 215 PROD2 DRILL PULD T UD and C/O MWD w/ new battery. 14:30 15:00 0.50 215 215 PROD2 DRILL PULD P Uploaded MWD. 15:00 15:30 0.50 215 409 PROD2 DRILL PULD P P/U and RIH w/ bumper sub and 6 hybrid DCs. BHA weight on hook=25K. 15:30 17:00 1.50 409 1,510 PROD2 STK TRIP P RIH 12 stds and C/O 2 jts DP w/ bad threads. SHT MWD 1510' MD. ~~P 1 ~ ~f 2~ ®~ ® m Time Logs --~ Date From To Dur th E. De th Phase Code Subcode T~ CrJM _ 05/13/2006 17:00 21:00 4.00 1,510 8,170 PROD2 STK TRIP P RIH w/whipstock assembly, filling pipe @ 4,855' and 7,880' MD. Broke circ 8,170' MD. 21:00 22:00 1.00 8,170 8,300 PROD2 STK OTHR P Made MAD pass from 8,207' to 8,300' MD. Orient whipstock as making pass to 12? left of HS. 22:00 23:00 1.00 8,300 8,824 PROD2 STK WPST P Cont'd to RIH and UD single to 8,901' MD. Broke circ and confirm orientation @ 12? left. PUW=140K and SOW=65K w/ pumps on. Stabbed in and stacked out to 18K WOB @ top of "B" lat liner 8,933' MD. Set and confirmed positive anchor. Stacked out 35-45K to shear off whipstock. Established rotation w/ 20 rpm and TQ=15K, increased to 60 rpm and TQ=8-10K w/ ROT=80K. 23:00 00:00 1.00 8,824 8,826 PROD2 STK MILL P Began to mill window @ 8,824' MD w/ 60 rpm, 140 spm, 494 gpm, M=2-4K 05/14/2006 00:00 09:30 9.50 8,826 8,881 PROD2 STK MILL P Cont'd to mill window. With TOW=8,824' MD and BOW=8,841' ~_~-~ ~ MD. Milled gauge hole to 8,861' MD w/ TD @ 8,881' MD. PUW=145K SOW=65K ROT=85K TQ=10K 09:30 10:00 0.50 8,881 8,793 PROD2 STK CIRC P Pumped weighted hi-vis sweep @ 500 m, 1800 si, 50 r m. 10:00 10:15 0.25 8,793 8,793 PROD2 STK OWFF P Checked flow, static. Pumped dry job and blew down TD. 10:15 12:00 1.75 8,793 6,828 PROD2 STK TRIP P POOH from 8,793' to 6,828' MD. 12:00 14:00 2.00 6,828 300 PROD2 STK TRIP P Held PJSM for new crew. Cont'd to POOH to BHA 300'. 14:00 16:00 2.00 300 0 PROD2 STK PULD P UD 6 hybrid DCs and bumper sub. Plugged in and downloaded MWD. UD milling assy w/upper mill full au e. Cleaned and cleared ri floor. 16:00 17:00 1.00 0 0 PROD2 STK OTHR P Pulled wear bushing, flushed BOP stack, reset wear bushin . 17:00 19:30 2.50 0 441 PROD2 DRILL PULD P P/U geo-pilot BHA and MWD. Programmed and uploaded MWD. RIH w/ BHA and HWDP. SHT MWD @ 441' MD. BHA PUW=22K 19:30 22:30 3.00 441 8,780 PROD2 DRILL TRIP P RIH to 8,780' MD. Filled DP @ 3222', 6003', 8780' MD. 22:30 23:30 1.00 8,780 8,780 PROD2 RIGMN SVRG P Held PJSM. Slipped and cut 81' DL. Serviced TD and ins ected brakes. 23:30 00:00 0.50 8,780 8,780 PROD2 RIGMN RGRP NP Held PJSM. C/O saver sub. 05/15/2006 00:00 00:30 0.50 8,780 8,780 PROD2 RIGMN RGRP NP Cont'd to C/O saver sub. ~ ~ ~'a~ ~~~ r~fi ~3~9 ~ ~~ ~ ~ Time Logs Date From To Dur th E. De th Phase Code Subcode T ~ GOM _ 05/15/2006 00:30 12:00 11.50 8,861 10,154 PROD2 DRILL DDRL P Ran through window and drilled undergauge hole from 8,861' to 8,881' MD. Directionally drilled 8.5" hole from 8,881' to 10,154' MD / 3,357' TVD. ADT=6.81 Bit hrs=6.81 Jar hrs=195.27 PUW=165K SOW=50K ROT=98K TQon/off=14K/15K ECD=10.99 Max Gas=516 Units Concretion depths:8944-8958', 9010-9013', 9392-9396', 9408-9410', 9465-9474', 9479-9485', -9508'. SPR#1=30stk/330psi, 40stk/400psi SPR#2=30stk/350psi, 40stk/400psi @ 9,710' MD / 3,361' TVD 8.8 MW 12:00 16:30 4.50 10,154 10,643 PROD2 DRILL DDRL P Held PJSM for new crew. Drilled from 10,154' to 10,643' MD where geo-span failed. ADT=3.9 hrs Bit hrs=10.71 Jar hrs=199.17 ECD=11.18 16:30 18:15 1.75 10,643 10,643 PROD2 DRILL CIRC T Circ'd and recip'd while C/O geo-span unit w/ 500 m, and 100 r m. 18:15 00:00 5.75 10,643 11,287 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 10,643' to 11,287' MD / 3,348' TVD. ADT=3.5 Bit hrs=14.21 Jar hrs=202.67 PUW=180K SOW=50K ROT=95K TQon/off=14-15 K/ 13-14 K ECD=11.01 Max Gas=386 Units Concretion depths:10154-10163', 10241-10246', 10248-10252', 11190-11195', 11210-11212'. SPR#1=30stk/400psi, 40stk/490psi SPR#2=30stk/370psi, 40stk/450psi @ 11,194' MD / 3,352' TVD 8.8+ MW 05/16/2006 00:00 12:00 12.00 11,287 12,631 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 11,287' to 12,631' MD / 3,339' TVD. ADT=6.52 Bit hrs=20.73 Jar hrs=209.19 PUW=185K SOW=45K ROT=102K TQon/off=14/15K ECD=11.44 Max Gas=551 Units Concretion depths: 11305-11310', 11357-11360' SPR#1=30stk/420psi, 40stk/480psi SPR#2=30stk/380psi, 40stk/460psi @ 12,504' MD / 3,339' TVD 8.8+ MW ~~~ _ ~~ ~...e~'a~~ 9 t 3 Time Logs -- Date From To Dur th E. De th Phase Code Subcode T OM ~ 05/16/2006 12:00 00:00 12.00 12,631 13,782 PROD2 DRILL DDRL P _ Directionally drilled 8.5" hole from 12,631' to 13,782 MD / 3,328' ND. ADT=8.57 Bit hrs=29.3 Jar hrs=217.76 PUW=190K SOW=OK ROT=90K TQon /off=15-17 K/ 13-14 K ECD=11.49 Max Gas=546 Units Concretion depths: 12630-12634', 12655-12662', 12677-12680', 12699-12709', 12723-12730', 12733-12740', 12742-12744', 12748-12751', 12760-12768', 12771-12781', 12793-12795', 12811-12814', 13219-13222', 13405-13408', 13595-13604', 13694-13703'. SPR#1=30stk/380psi, 40stW490psi SPR#2=30stk/370psi, 40stk/460psi @ 13,649' MD / 3,336' ND 8.9 MW 05/17/2006 00:00 12:00 12.00 13,782 15,007 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 13,782' to 15,007' MD / 3,335' ND. ADT=7.45 Bit hrs=36.75 Jar hrs=225.21 PUW=200K SOW=OK ROT=105K TQon/off=15-18K/15K ECD=11.81 Max Gas=520 Units Concretion depths: 14443-14445', 14488-14502', 14523-14526', 14533-14537, 14542-14550', 14556-14559', 14599-14612'. SPR#1=30stk/460psi, 40stk/520psi SPR#2=30stk/420psi, 40stk/510psi @ 14,790' MD / 3,342' ND 8.7+ MW 12:00 23:30 11.50 15,007 16,121 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 15,007' to 16,121' MD / 3,293' ND. Pumped 30 bbl weighted hi-vis sweep @ 15,315' and 16,026' w/ a 20% increase in cuttings noted on both. ADT=8.35 Bit hrs=45.10 Jar hrs=233.56 PUW=200K SOW=OK ROT=105K TQon/off=16-17K/15K ECD=12.42 Max Gas=277 Units Concretion depths: 115033-15036', 15040-15043', 15055-15060', 15082-15085', 15089-15093', 15313-15321', 15344-15369', 15560-15578', 15581-15585'. SPR#1=30stk/540psi, 40stk/620psi SPR#2=30stk/480psi, 40stk/580psi @ 16,026' MD / 3,296' ND 8.8 MW 23:30 00:00 0.50 16,121 16,121 PROD2 DRILL CIRC P Circ'd sweep around while rotating and reci rocatin . P~~ ~ 7 & 23 t~._ _-........._._._.._~ _.-..--.--.._._...---_........__.._.~ _........~..~_____ _..._..._.__ _ _~~.._... Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 05/18/2006 00:00 00:30 0.50 16,121 16,121 PROD2 DRILL CIRC P Cont'd to circ sweep OOH w/ 618 gpm, 3700 psi, 145 rpm. Noted a 20% increase in cuttings w/ECDs decreasin from 12.67 to 12.23. 00:30 07:15 6.75 16,121 16,692 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 16,121' to 16,692' MD / 3,355' TVD. Pumped 30 bll weighted hi-vis sweep on last stand. ADT=4.81 Bit hrs=49.91 Jar hrs=238.42 PUW=205K SOW=OK ROT=98K TQon/off=17K/16K ECD=12.23 Max Gas=257 Units SPR#1=30stk/540psi, 40stk/620psi SPR#2=30stk/480psi, 40stk/580psi @ 16,026' MD / 3,296' TVD 8.8 MW 07:15 08:00 0.75 16,692 16,692 PROD2 DRILL CIRC P Circ'd sweep OOH w/ 608 gpm, 3800 psi, 150 rpm. Observed 10% increase in cuttin s. 08:00 08:15 0.25 16,692 16,692 PROD2 DRILL OWFF P Checked flow, static. Garnered SPRs. 08:15 12:00 3.75 16,692 14,794 PROD2 DRILL WPRT P BROOH from 16,692' to 14,794' MD w/ 130 r m, 620 m, 3700 si. 12:00 20:30 8.50 14,794 8,785 PROD2 DRILL WPRT P Held PJSM and cont'd BROOH from 14,794' to 8,972' MD w/ 130 rpm, 620 gpm. While BROOH @ 14,762' hole packed off and rotary stalled. Bled off and broke down, pipe free. BROOH @ 10 fpm, from 14,790' to 14,740' MD w/ no further problems.Pumped and pulled through window from 8,972' to 8,785' MD. Pulled 65K going through window, went back down and came through again with 25K. PUW=165K SOW=50K ROT=95K above window. Monitored well, static. 20:30 21:30 1.00 8,785 8,785 PROD2 DRILL CIRC P Circ'd 30 bbl weighted hi-vis sweep w/ 130 rpm, 620 gpm while reciprocating. Noted 10% increase in cuttin s. 21:30 21:45 0.25 8,785 8,785 PROD2 RIGMN SVRG P Lubricated rig, blocks, TD, and crown. Monitored well, static. 21:45 23:00 1.25 8,785 10,733 PROD2 DRILL WPRT P RIH from 8,785' to 10,733' MD and filled DP. 23:00 00:00 1.00 10,733 11,476 PROD2 DRILL WPRT P Washed and reamed in hole from 10,733' to 11,476' MD w/ 70 rpm, 426 m, 1600 si. 05/19/2006 00:00 06:30 6.50 11,476 16,692 PROD2 DRILL WPRT P Cont'd wash and ream to bottom from 11,476' to 16,692' MD. 06:30 08:00 1.50 16,692 16,692 PROD2 DRILL CIRC P Pumped 30 bbl weighted hi-vis sweep around w! 620 gpm, 130 rpm, while reci rocatin throu hout. 08:00 09:00 1.00 16,692 16,692 PROD2 DRILL OTHR P Displaced MOBM to SFOBM with a total of 588 bbl @ 8.7 ppg. Chased dis lacement with 155 bbl OBM. 09:00 12:00 3.00 16,692 13,272 PROD2 DRILL TRIP P POOH on elevators from 16,692' to 13,272' MD w/ no roblems. ®~..,. _ ~e ~~; of'~3 ~ Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 05/19/2006 12:00 13:30 1.50 13,272 8,766 PROD2 DRILL TRIP P Held PJSM and cont'd to POOH from 13,272' to 8,766' MD. Open hole and window pulled slick. Monitored well, static. 13:30 16:30 3.00 8,766 446 PROD2 DRILL TRIP P Cont'd to POOH from 8,766' to HWDP. Monitored well, static. Diplacement Ion a total of 13 bbls. 16:30 18:00 1.50 446 81 PROD2 DRILL PULD P UD HWDP, and jars. Pumped and flushed MWD tools w/ 15 bbls clean mineral oil. UD 3 NMFDCs and float sub. 18:00 19:00 1.00 81 81 PROD2 DRILL PULD P Downloaded MWD. 19:00 20:00 1.00 81 0 PROD2 DRILL PULD P UD MWD, broke bit, cleaned and UD geo-pilot. Cleaned and cleared rig floor. P/U mousehole. 20:00 22:30 2.50 0 0 COMPZ DRILL PULD P Held PJSM and UD 20 stds 5" g-105 DP in mousehole. UD mousehole. 22:30 23:30 1.00 0 0 COMPZ RIGMN SVRG P Held PJSM. Cut and slipped 73' DL. Ins ected brakes and ad'usted. 23:30 00:00 0.50 0 0 COMPZ CASIN( RURD P R/U to run 5.5" liner. 05/20/2006 00:00 00:45 0.75 0 0 COMPZ CASIN( RURD P Cont'd to R/U casing equip. Held PJSM for runiin 5.5" liner. 00:45 08:30 7.75 0 7,480 COMPZ CASIN( RNCS P Run 5.5" liner as per detail w/ 181 jts in hole (1st 85 jts BTCM and last 96 jts Hydril 521). Ran 125 roller centralizers, 35 hydroform centralizers, and 21 constrictor packers (no centralizers on constrictor'ts 08:30 09:00 0.50 7,480 7,494 COMPZ CASIN( RNCS P M/U HR liner setting sleeve w/ associated u s and crossover. 09:00 12:45 3.75 7,494 11,937 COMPZ CASIN( RUNL P Held PJSM. Ran liner on DP from 7494' to 11,937' MD. Worked pipe through tight spot @ 11,300' MD. Garnered data for T&D analysis at intervals. 12:45 13:15 0.50 11,937 12,924 COMPZ CASIN( RUNL P Held PJSM. Cont'd to run liner of DP to 12,924' MD. Pumped and rotated through tight spot @ 11,937'. Slack off weight went to zero @ 12,924'. Begin to rotate liner down. 13:15 20:45 7.50 12,924 16,548 COMPZ CASIN( RUNL P Rotated liner in hole from 12,924' to 16,538' MD w/ 20 rpm, 106 gpm, 200 psi. Worked past tight spots @ 14,521' and 15,891'. P/U single and rotated to 16,562 w! PUW=190K ROT=70K. Pulled up in tension to 16,548' MD. ~.~ ~ _ ~e 13 of Time Logs Date From To Dur th E. De th Phase Code Subcode T OM 05/20/2006 20:45 21:45 1.00 16,548 9,053 COMPZ CASIN( OTHR P Dropped ball and pumped down (Note:ball seated @ 2031 stks 200 stks over calculated). Pressured up to 3000 psi and slacked off to 45K. Pressured up to 4150 psi and sheared out. PUW decreased to 165K from 190K. Liner in place @ 21:00 hrs w/ top @ 9,053' MD and bottom @ 16,548' MD. Monitored well, static. 21:45 22:15 0.50 9,053 8,757 COMPZ DRILL TRIP P UD single and POOH w/ DP to 8,757' MD (approx 100' above window). Cleaned floor and P/U mousehole. 22:15 00:15 2.00 8,757 8,757 COMPZ DRILL PULD P Held PJSM. UD 60 jts of G-105 DP from derrick using mousehole to provide more workspace on the rig floor. 00:15 00:45 0.50 8,757 8,757 COMPZ DRILL OWFF P Monitored well, static. Pumped dry 'ob for TOOH. 05/21/2006 00:00 03:15 3.25 8,757 0 COMPZ DRILL TRIP P POOH from 8,745' to surface. UD liner runnin tool. 03:15 03:45 0.50 0 0 COMPZ DRILL OTHR P Cleaned and cleared rig floor. P/U Baker whipstock retrieval tools from beaver slide. 03:45 04:30 0.75 0 67 COMPZ DRILL PULD P Held PJSM. M/U whipstock retrieval tools. 04:30 07:30 3.00 67 7,096 COMPZ DRILL TRIP P RIH from 67' to 7,096' MD. 07:30 08:00 0.50 7,096 7,096 COMPZ RIGMN SVRG P Service top drive. 08:00 08:30 0.50 7,096 7,096 COMPZ RIGMN SVRG P Held PJSM. C/O swivel packing on to drive. 08:30 09:30 1.00 7,096 8,829 COMPZ DRILL TRIP P Cont'd to RIH from 7,096' to 8,829' MD. PUW=147K SOW=65K. 09:30 10:00 0.50 8,829 8,829 COMPZ DRILL OTHR P Hooked whipstock @ 8,829' MD. Cocked jars and pulled to 175K, 210K, 230K and jars fired w/o shearing. Pulled to 250K sheared and whipstock free. PUW=150K. 10:00 12:00 2.00 8,829 8,800 COMPZ DRILL CIRC P CBU @ 8,800' w/ 88 spm, 295 gpm, 500 psi. Staged pump down to 6.5 bpm due to fluid losses w/ 300 psi, 66 s m. Lost total of 35 bbls fluid. 12:00 15:30 3.50 8,800 200 COMPZ DRILL TRIP P POOH from 8,800' to whipstock assembl .Monitored well, static. 15:30 17:30 2.00 200 0 COMPZ DRILL PULD P UD BHA and whipstock assembly. Noted roll off to the right on whipstock more noticable than usual. 17:30 18:30 1.00 0 0 COMPZ CASIN( RURD P P/U and R/U casing tools 18:30 21:30 3.00 0 277 COMPZ CASIN( RURD P P/U 5.5" hook hanger assembly w/ ECP and inner string MWD. Oriented high side 180? out from hook. Cleared ri floor of tools and ton s. P~~~ ~Q ~a Time Logs Date From To Dur ~ th E Depth Phase Code Subcode T . . OM _____ 05/21/2006 21:30 00:00 2.50 277 4,267 COMPZ CASIN( RUNL P RIH w/ 5.5" hook hanger assembly on DP. SHT MWD @ 738' MD. Cont'd to RIH to 4,267' MD. Filled DP @ 3,710' MD. 05/22/2006 00:00 02:45 2.75 4,267 9,089 COMPZ DRILL TRIP P Cont'd to RIH w! hook hanger assembly to 8,736' MD. Oriented to hi h side and RIH to 9,089' MD. 02:45 06:00 3.25 9,089 9,089 COMPZ DRILL OTHR P Hooked hanger w/ hook @ 8,846' (5' deep to talc) w/ shoe @ 9,087' MD. Set down 15K, toolface went from 7? left to 35? right, unhooked and toolface went back to the left, rehooked and toolface back to 35? right. Hook confirmed. P/U and rotate 180? to slide 10' past hook. All went well, pull back up and rotated 180? to hook final time. Hooked again toolface went back to 35?, attempted to set down. Weight went up to 12K and came off. Could not re-establish hook. PUW=160K SOW=65K 06:00 10:30 4.50 9,089 277 COMPZ DRILL TRIP T Monitored well, static. POOH from 9,089' to BHA @ 277'. Inspected hook hanger; welds had failed between hook and han er bod . 10:30 12:00 1.50 277 231 COMPZ DRILL PULD T Cleared and cleaned rig floor. R/U casing tongs and slim hole handling equipment. Broke out hook hanger, and slimhole MWD. UD hook han er. 12:00 13:00 1.00 231 231 COMPZ RIGMN SVRG P Held PJSM. Serviced rig including: draw works couplings, over ride, clutch, top drive, adjusted and inspected brakes. Washed pipe and blocks. 13:00 18:00 5.00 231 231 COMPZ DRILL WOEO T Waiting on new liner hanger. Monitored well on trip tank w! 2.8 bbl losses. 18:00 19:00 1.00 231 231 COMPZ DRILL PULD T P/U and M/U new 5.5" hook hanger (different model) assembly and oriented. Cleared ri floor. 19:00 23:00 4.00 231 8,733 COMPZ DRILL TRIP T RIH w/ hook hanger assembly. SHT MWD @ 644' MD. Cont'd to RIH to 8,733' MD (filled pipe @ 3,981' and 6,831' . Broke circ 8,733' MD 23:00 00:00 1.00 8,733 8,733 COMPZ DRILL OTHR T Oriented hook hanger to high side. PUW=150K SOW=70K 8,733 COMPZ DRILL 05/23/2006 00:00 02:15 2.25 8,733 9,093 COMPZ DRILL OTHR P Orient to hi side at 8733'. RIH to 9041' and tagged NoGo in mother bore. PU to 8828' turn 3/4 and run back into mother bore. Turn another 3/4 POOH to 8828, RIH and enter into D lat. Hook hanger at 9039' MD (Shoe depth). Pull up and rehook. Pull up, rotate 1/2 turn. Rehook and set down 30K on hook han er. PU=165K, S0=70K. ~~ I~ ~ ~ _ I~~g~ 21 ofi 23 Time Logs Date Fram To Dur th E. Depth Phase Code Subcode T OC M 05/23/2006 02:15 03:15 1.00 9,093 9,093 COMPZ DRILL OTHR P Drop ball and pump down at 36 spm, 130 m, 900 si. 03:15 04:00 0.75 9,093 9,093 COMPZ DRILL OTHR P Pressure up to 2700 psi to inflate ECP. Release Hook Hanger, attempt to shear pump out sub with no success. Pull out of Hook and establish circulation. 04:00 08:30 4.50 9,093 100 COMPZ DRILL TRIP P Monitor well, PU=160K. POOH to 100'. Calculated fill=70.7 bbls, actual 79.1 bbls. 08:30 09:30 1.00 100 0 COMPZ DRILL PULD P Service break and LD hook hanger running tools, slimhole MWD, & wash i e. 09:30 10:30 1.00 0 0 COMPZ DRILL PULD P Clear and clean rig floor, PU LEM tools from beaver slide. 10:30 11:00 0.50 0 0 COMPZ CASIN( RURD P PJSM and RU casing equipment. 11:00 12:00 1.00 0 130 COMPZ CASIN( PUTB P PJSM- MU LEM assembly: bent joint, 1 jt of 4.5" tbg, 2 9.8' pup joints, 1 jt 4.5" tb , &LEM. 12:00 14:00 2.00 130 215 COMPZ CASIN( PUTS P PJSM with other crew. PU LEM, seal bore, Inner string and SLZXP packer. Clear floor. 14:00 14:45 0.75 215 215 COMPZ RIGMN RGRP T Repair broken hydraulic nipple (power ton su I 14:45 19:00 4.25 215 8,781 COMPZ CASIN( RUNL P RIH with LEM assembly. fill drill pipe at 3010', 5834', 8211', break circulation at 8781'. PU=145K, S0=75K. 19:00 21:30 2.50 8,781 8,554 COMPZ CASIN( RUNL P Wash in 8781' to 8970'. PU single and land at 8976' MD & stack 40K over. PU 20K over to confirm latch. Drop ball and pump down at 4 bpm, 300 psi. Seat at 1477 stks. Pressure up to 3000 psi to set packer. Increase pressure to 4000 psi to release LEM. Pressure up backside to 1000 psi and test packer for 5 mins. PU 20' release dogs on running tool. SO and confirm top of SLZXP at 8976' MD. POOH 4 stds & LD single to 8554' MD. Blow down to drive and clean ri floor. 21:30 00:00 2.50 8,554 8,554 COMPZ DRILL PULD P PJSM. Lay down G-105 DP out of derrick in mouse hole. 72 'ts down . 05/24/2006 00:00 01:15 1.25 8,554 7,000 COMPZ DRILL PULD P Cont to LD 5" DP 51 jts. 01:15 05:45 4.50 7,000 675 COMPZ DRILL PULD P Monitor well: static. Pump dry job. POOH, clean OBM off super sliders and stand back. 05:45 07:15 1.50 675 0 COMPZ DRILL PULD P Serivice break and LD LEM running tools, 5 jts of 2 3/8" inner string and mule shoe. 07:15 07:45 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 07:45 08:15 0.50 0 0 COMPZ DRILL PULD P Pull wear bushing ~~ w~ _ m ~_ ~.. F~c~~ ~2 r~i ~:; ~~ ~ ~. ~~, - .~~. -....~...A.P`~ Time Logs i Date From To Dur th E. De th Phase Code Subcode T .,OM 05/24/2006 08:15 09:15 1.00 0 0 COMPZ RIGMN SVRG P Slip and cut 89' drilling line 09:15 09:45 0.50 0 0 COMPZ RPCOh RURD P PJSM- RU & run casing equipment. 09:45 12:00 2.25 0 1,044 COMPZ RPCOh RCST P PJSM- RIH with 4.5" 12.6# IBT com letion tubin .Ran 34 'oint. 12:00 19:30 7.50 1,044 8,794 COMPZ RPCOh RCST P PJSM- Continue to RIH with 4.5" completion tubing per detail to 8793.55'. 283 joints total, PU=85K, S0=58K. 19:30 20:30 1.00 8,798 8,794 COMPZ RPCOh HOSO P PU 2 joints from shed, tag up locator at 8771.5'. LD 3 joints, PU & space out with 9.81' pup, and RIH with jt 283. PU and landing joint. MU hanger and land tb 23K on han er . - 20:30 22:00 1.50 0 0 COMPZ RPCOh NUND P Run lock down screws. Test upper and lower hanger seals to 5000 psi for 10 mins. LD landin 'oint and clear floor. 22:00 23:00 1.00 0 0 COMPZ WELCT BOPE P PJSM-Change out lower rams to 7 5/8" 23:00 00:00 1.00 0 0 COMPZ WELCT NUND P PJSM- Nipple down ROPE. 05/25/2006 00:00 00:30 0.50 0 0 COMPZ WELCT NUND P Cont N/D BOPE. 00:30 03:15 2.75 0 0 COMPZ WELCT NUND P PJSM: NU Tree and test void to 5000 psi for 10 mins. Install SSV valve, test tree and all valves to 5000 psi for 10 min. Pull two wa check. 03:15 04:00 0.75 0 0 COMPZ RPCOh FRZP P PJSM: RU Little Red. SIMOPS PJSM. Displace well with 643 bbls of diesel. LD 5" Drill i e from derrick. 04:00 07:00 3.00 0 0 COMPZ RPCOh FRZP P Displace well with 643 bbls of diesel at 5 bpm, 550 psi, while LD 5" drill pipe from derrick. 07:00 08:30 1.50 0 0 COMPZ RPCOh RURD P Rig down little red, RU scaffolding in cellar. RU lubricator set BPV. Install blind flan es. Secured well. 08:30 12:00 3.50 0 0 COMPZ DRILL PULD P Continue to LD 5" drill pipe. Total of 159 'oints. 12:00 18:30 6.50 0 0 COMPZ DRILL PULD P Cont to LD 5" drill pipe and super sliders (total of 129 joints). Clear rig floor. 18:30 20:00 1.50 0 0 COMPZ MOVE RURD P Rig down. Pull skate rail. Secure rig floor. R/D pipe shed. Blow down water lines. ® ~_ e __•._... .~ •~• _.-. ~~ct~ ~ of Halliburton Company* Survey Report Company: ConocoPhillips Alaska Ina Date: 6/5/2006 Time: 16:27:03`- Page: 1 Ficld: Kuparuk River Unit Co-ordinatc(NE) Reference: WeII: 1J-184, True North Site: Kuparuk 1J Pad Vertical (TVD)Refer ence: 1J-184: 109.0 ~i'ell: 1J-184 Sectimt (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) ~~'ellpath: 1J-184 ___ _ - __ Survey Calculation J --__ lethod: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 i Geo Datum: NAD27 (Clarke 1866) I Coordinate Syste m: Well Centre 'i I Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 li Well 1J-184 Slot Name: :j Well Position: +N/-S -577.27 ft Northing: 5945342 .40 ft Latitude: 70 15 40.580 N 'I +E/-W -4.92 ft Fasting : 558789 .54 ft Longitude: 149 31 29.150 W Position Uncertainty: 0.00 ft I path: 1J-184 Drilled From: Well Ref. Point 500292330500 Tie-on Depth: 28.00 ft ', Current Datum: 1 J-184: Height 109 .00 ft Above System Datum: Mean Sea Level '. Magnetic Data: 4/21/2006 Declination: 24.11 deg j Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) ft +N/-S ft +E/-W ft Direction deg -- -..~ 28.00 0.00 0.00 180.00 I Survey Program for DeSnitive Wellpath Date: 12/17/2004 Validated: No Actual From To Survey Version: 4 Toolcode Tool Name ' ft ft 75.00 442.00 1 J-184 gyro ( ~ 75.00-442.00) CB-GYRO-SS Camera based gyro single shot ~ 473.59 17838.72. 1J-184 (473.59-17838.72) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ ~ Survey MD Iucl Azim TVD SysTVD ~'/S E/W N1apN b1apE 'Fool ft deg deg __ ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945342.40 ~ 558789.54 - TIE LINE 75.00 0.21 260.98 75.00 -34.00 -0.01 -0.09 5945342.39 558789.46 CB-GYRO-SS ~~, 168.00 0.19 101.32 168.00 59.00 -0.07 -0.10 5945342.33 558789.44 CB-GYRO-SS 'i 259.00 0.29 98.70 259.00 150.00 -0.13 0.27 5945342.27 558789.81 CB-GYRO-SS 350.00 0.43 224.27 350.00 241.00 -0.41 0.26 5945341.99 558789.81 CB-GYRO-SS 442.00 2.44 205.60 441.96 332.96 -2.43 -0.82 5945339.97 558788.73 CB-GYRO-SS 473.59 3.15 200.78 473.52 364.52 -3.85 -1.42 5945338.54 558788.15 MWD+IFR-AK-CAZ-SC 563.10 6.02 204.15 562.73 453.73 -10.43 -4.22 5945331.94 558785.41 MWD+IFR-AK-CAZ-SC 654.69 10.84 205.72 653.31 544.31 -22.58 -9.92 5945319.75 558779.80 MWD+IFR-AK-CAZ-SC 746.31 17.32 204.97 742.13 633.13 -42.72 -19.43 5945299.53 558770.45 MWD+IFR-AK-CAZ-SC ', 839.71 20.40 200.61 830.50 721.50 -70.57 -31.03 5945271.59 558759.06 MWD+IFR-AK-CAZ-SC 932.47 22.39 200.63 916.87 807.87 -102.24 -42.95 5945239.84 558747.40 MWD+IFR-AK-CAZ-SC 1025.56 25.34 202.42 1001.99 892.99 -137.26 -56.80 5945204.72 558733.82 MWD+IFR-AK-CAZ-SC ~~, I 1117.73 28.60 203.66 1084.13 975.13 -175.71 -73.18 5945166.14 558717.75 MWD+IFR-AK-CAZ-SC '! 1212.00 30.79 204.10 1166.01 1057.01 -218.40 -92.08 5945123.30 558699.17 MWD+IFR-AK-CAZ-SC i 1303.50 32.41 201.59 1243.95 1134.95 -262.59 -110.67 5945078.98 558680.93 MWD+IFR-AK-CAZ-SC 1397.78 36.51 201.58 1321.66 1212.66 -312.18 -130.29 5945029.24 558661.70 MWD+IFR-AK-CAZ-SC 1490.70 39.62 200.57 1394.81 1285.81 -365.64 -150.87 5944975.63 558641.54 MWD+IFR-AK-CAZ-SC 1582.91 44.47 198.51 1463.27 1354.27 -423.83 -171.47 5944917.29 558621.40 MWD+IFR-AK-CAZ-SC ~, ~ 1676.13 48.49 197.49 1527.45 1418.45 -488.11 -192.34 5944852.85 558601.04 MWD+IFR-AK-CAZ-SC 1768.41 50.04 197.87 1587.67 1478.67 -554.73 -213.57 5944786.08 558580.32 MWD+IFR-AK-CAZ-SC 1860.73 52.75 197.06 1645.27 1536.27 -623.54 -235.21 5944717.10 558559.22 MWD+IFR-AK-CAZ-SC I, 1953.20 56.91 195.32 1698.52 1589.52 -696.12 -256.26 5944644.37 558538.75 MWD+IFR-AK-CAZ-SC I ~i 2045.99 62.34 193.70 1745.43 1636.43 -773.60 -276.27 5944566.74 558519.34 ~ MWD+IFR-AK-CAZ-SC 2138.27 67.92 190.96 1784.23 1675.23 -855.35 -294.10 5944484.86 558502.15 MWD+IFR-AK-CAZ-SC I' 2230.74 72.47 188.70 1815.55 1706.55 -941.05 -308.92 5944399.06 558488.00 MWD+IFR-AK-CAZ-SC '~ ll 2323.93 75.02 184.96 1841.64 1732.64 -1029.86 -319.54 5944310.18 558478.08 MWD+IFR-AK-CAZ-SC 2414.36 74.93 184.40 1865.09 1756.09 -1116.91 -326.67 5944223.09 558471.63 MWD+IFR-AK-CAZ-SC 2505.48 75.28 181.86 1888.51 1779.51 -1204.82 -331.47 5944135.14 558467.51 MWD+IFR-AK-CAZ-SC 'I • Halliburton Company Survey Report Company: ConocoPhfllips Alaska Inc. Date: 6/5/2006 'l'ime: 16:27:03 Page: 2 Field: Ku paruk River Unit Co-ordinate(NE) Reference: Well: 1J-184, Tfue North Site: Ku paruk 1J Pad Vertical (TVD) Refe rence: 1J -184: 109.0 WetL• 1J-184 Section (VS) Reference: Well (O.OON,O. OOE, 180.OOAzi) Wcllpath: 1J-184 Surve}' Calcula tion Method: Mi nimum Curv ature Db: Oracle Survey -_ ___ ___ iWD Intl ;~zim TVD Sys Tb'D N/S E/R' hlapN [tlapE, Tool ft deg deg ft ft ft ft ft ft __ ~I 2599.69 _ 75 .14 _ 181. 93 1912 .56 _ 1803 .56 _ -1295. 86 __ -334. 49 5944044.09 558465. 21 MWD+IFR-AK-CAZ-SC 2692.15 76 .08 180. 00 1935 .54 1826 .54 -1385. 40 -335. 99 5943954.55 558464. 41 MWD+IFR-AK-CAZ-SC 2785.13 77 .47 179. 49 1956 .81 1847 .81 -1475. 91 -335. 59 5943864.05 558465. 52 MWD+IFR-AK-CAZ-SC i, 2879.16 76. 69 180. 48 1977 .84 1868 .84 -1567. 56 -335. 56 5943772.42 558466. 26 MWD+IFR-AK-CAZ-SC 2971.91 76. 83 180. 39 1999 .08 1890. 08 -1657. 84 -336. 25 5943682.14 558466. 28 MWD+IFR-AK-CAZ-SC 3064.99 78. 16 180. 02 2019 .23 1910. 23 -1748. 71 -336. 57 5943591.28 558466. 66 MWD+IFR-AK-CAZ-SG ~~ 3156.67 79 .03 179. 75 2037 .36 1928 .36 -1838. 58 -336. 39 5943501.42 558467. 54 MWD+IFR-AK-CAZ-SC j 3250.05 77 .99 182. 15 2055 .97 1946 .97 -1930. 07 -337. 90 5943409.94 558466. 75 MWD+IFR-AK-CAZ-SC 3342.74 76 .65 182. 83 2076 .31 1967 .31 -2020. 41 -341. 83 5943319.58 558463. 52 MWD+IFR-AK-CAZ-SC 3436.27 71. 61 182. 69 2101 .88 1992. 88 -2110. 24 -346. 16 5943229.72 558459. 89 MWD+IFR-AK-CAZ-SC 3528.37 71. 44 182. 27 2131 .07 2022 .07 -2197. 51 -349. 94 5943142.43 558456. 80 MWD+IFR-AK-CAZ-SC 3621.07 71 .99 181. 80 2160 .15 2051 .15 -2285. 48 -353. 07 5943054.46 558454. 36 MWD+IFR-AK-CAZ-SC 3713.58 78 .21 179. 99 2183 .93 2074 .93 -2374. 82 -354. 44 5942965.12 558453. 68 MWD+IFR-AK-CAZ-SC ~ 3805.22 75 .95 180. 56 2204 .42 2095 .42 -2464. 13 -354. 87 5942875.81 558453. 95 MWD+IFR-AK-CAZ-SC it 3895.79 79 .49 180. 15 2223 .68 2114 .68 -2552. 61 -355. 42 5942787.34 558454. 10 MWD+IFR-AK-CAZ-SC 3936.46 79. 17 179. 89 2231 .21 2122 .21 -2592. 58 -355. 43 5942747.37 558454. 39 MWD+IFR-AK-CAZ-SC 4032.62 78. 30 180. 66 2249 .99 2140. 99 -2686. 88 -355. 88 5942653.08 558454. 68 MWD+IFR-AK-CAZ-SC 4126.37 78 .73 180. 70 2268 .66 2159 .66 -2778. 75 -356. 97 5942561.22 558454. 31 MWD+IFR-AK-CAZ-SC 4219.08 78 .91 180. 43 2286 .63 2177 .63 -2869. 70 -357. 87 5942470.27 558454. 12 MWD+IFR-AK-CAZ-SC 4312.04 78 .40 181. 40 2304 .92 2195 .92 -2960. 83 -359. 32 5942379.14 558453. 38 MWD+IFR-AK-CAZ-SC 4405.60 78 .10 181. 92 2323 .97 2214 .97 -3052. 39 -361. 98 5942287.57 558451. 44 MWD+IFR-AK-CAZ-SC i 4498.03 76. 60 182. 50 2344 .22 2235 .22 -3142. 50 -365. 45 5942197.44 558448. 66 MWD+IFR-AK-CAZ-SC ~ 4590.13 76. 59 181. 02 2365 .57 2256 .57 -3232. 05 -368. 20 5942107.89 558446. 61 MWD+IFR-AK-CAZ-SC 4682.10 76 .29 181. 56 2387 .13 2278 .13 -3321. 43 -370. 22 5942018.50 558445. 30 MWD+IFR-AK-CAZ-SC 4775.26 76 .43 181. 55 2409 .10 2300 .10 -3411. 93 -372. 67 5941927.99 558443. 55 MWD+IFR-AK-CAZ-SC ~~! 4867.88 77 .36 180. 19 2430 .10 2321 .10 -3502. 13 -374. 04 5941837.80 558442. 88 MWD+IFR-AK-CAZ-SC 4960.59 76. 40 181. 78 2451 .15 2342 .15 -3592. 40 -375. 59 5941747.52 558442. 04 MWD+IFR-AK-CAZ-SC 'i 5052.83 76. 48 181. 48 2472 .77 2363 .77 -3682. 03 -378. 14 5941657.88 558440. 19 MWD+IFR-AK-CAZ-SC ~' 5145.75 76. 27 182. 97 2494 .66 2385. 66 -3772. 26 -381. 65 5941567.63 558437. 39 MWD+IFR-AK-CAZ-SC 5236.35 76. 59 182. 93 2515 .92 2406 .92 -3860. 22 -386. 18 5941479.66 558433. 54 MWD+IFR-AK-CAZ-SC 5328.91 77 .44 183. 50 2536 .72 2427 .72 -3950. 27 -391. 24 5941389.58 558429. 19 MWD+IFR-AK-CAZ-SC 5422.68 77. 21 184. 60 2557 .30 2448 .30 -4041. 52 -397. 70 5941298.28 558423. 44 i MWD+IFR-AK-CAZ-SCi 5516.89 76. 72 184. 39 2578 .54 2469 .54 -4133. 02 -404. 89 5941206.74 558416. 96 MWD+IFR-AK-CAZ-SC 5608.62 75. 66 184. 14 2600 .44 2491 .44 -4221. 85 -411. 52 5941117.87 558411. 03 MWD+IFR-AK-CAZ-SC 5700.69 75. 52 183. 78 2623 .35 2514 .35 -4310. 81 -417. 68 5941028.87 558405. 57 MWD+IFR-AK-CAZ-SC 5794.10 75. 46 183. 79 2646 .76 2537. 76 -4401. 05 -423. 65 5940938.60 558400. 30 MWD+IFR-AK-CAZ-SC 5887.06 75 .74 184. 24 2669 .87 2560 .87 -4490. 87 -429. 95 5940848.75 558394. 70 MWD+IFR-AK-CAZ-SC 5980.52 76. 84 183. 23 2692 .03 2583 .03 -4581. 47 -435. 86 5940758.11 558389. 50 MWD+IFR-AK-CAZ-SC ,' 6073.09 76. 05 182. 48 2713 .72 2604 .72 -4671. 35 -440. 35 5940668.21 558385. 72 MWD+IFR-AK-CAZ-SC '' 6165.98 76. 05 181. 84 2736 .12 2627 .12 -4761. 43 -443. 74 5940578.11 558383. 02 MWD+IFR-AK-CAZ-SC 6257.51 75. 98 181. 23 2758 .24 2649. 24 -4850. 22 -446. 12 5940489.32 558381. 34 MWD+IFR-AK-CAZ-SC 6350.69 76 .77 180. 40 2780 .19 2671 .19 -4940. 76 -447. 41 5940398.77 558380. 76 MWD+IFR-AK-CAZ-SC 6444.18 77. 01 179. 38 2801 .39 2692 .39 -5031. 81 -447. 23 5940307.73 558381. 64 MWD+IFR-AK-CAZ-SC 6536.15 76. 64 181. 09 2822 .36 2713 .36 -5121. 36 -447. 60 5940218.20 558381. 97 MWD+IFR-AK-CAZ-SC 6628.42 76. 47 180. 14 2843 .81 2734 .81 -5211. 09 -448. 56 5940128.46 558381. 71 MWD+IFR-AK-CAZ-SC 6720.25 75. 60 180. 68 2865 .97 2756 .97 -5300. 21 -449. 20 5940039.36 558381. 77 MWD+IFR-AK-CAZ-SC j I 6813.01 76. 16 182. 94 2888 .60 2779. 60 -5390. 11 -452. 04 5939949.44 558379. 63 MWD+IFR-AK-CAZ-SC 6905.31 76 .75 181. 27 2910 .22 2801 .22 -5479. 78 -455. 34 5939859.76 558377. 04 MWD+IFR-AK-CAZ-SC 6998.49 77. 13 181. 17 2931 .28 2822 .28 -5570. 53 -457. 27 5939769.01 558375. 81 MWD+IFR-AK-CAZ-SC 7091.36 76. 33 181. 25 2952 .60 2843 .60 -5660. 90 -459. 18 5939678.63 558374. 61 MWD+IFR-AK-CAZ-SC !. 7183.00 76. 43 182. 04 2974 .18 2865 .18 -5749. 92 -461. 74 5939589.60 558372. 75 MWD+IFR-AK-CAZ-SC 7276.13 77. 38 182. 13 2995 .28 2886 .28 -5840. 57 -465. 04 5939498.94 558370. 16 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska inc. Date: 6/5/2006 Time: 16:27:03 Page: 3 Field: Ku paruk River Unit Co-ordinate(NE) Rcfcreuce: Well: 1J-184, True North Site: Ku paruk 1J Pad Vertical'(TVD) Reference: 1J -184: 109.0 Well: 1J-184 Section (VS) Refere nce: Well (O.OON,O. OOE; 180.OOAzi) Wcllpath: 1J-184 Survey Calcuia tion Method: Mi nimum Curvatur e Db: Orade Survcv - _ _ __ MD Incl __ .4zim _ 7tiD _ _ Sys TVD ___ N/S E/VV ,ti1apN h1apE .Tool ', ft deg deg ft ft ft ft ft ft 7368.84 77 .05 182. 57 3015.79 __ 2906 .79 _ -5930.91 __ -468. 74 5939408. __ 59 558367. 15 MWD+IFR-AK-CAZ-SC 7461.78 77 .54 182. 86 3036.23 2927 .23 -6021.47 -473. 04 5939318. 00 558363 .57 MWD+IFR-AK-CAZ-SC ' 7554.44 77 .87 182. 25 3055.96 2946 .96 -6111.91 -477. 07 5939227. 54 558360. 24 MWD+IFR-AK-CAZ-SC 7646.15 77 .25 182. 56 3075.72 2966 .72 -6201.39 -480. 83 5939138. 04 558357. 18 MWD+IFR-AK-CAZ-SC 7739.18 76 .30 182. 63 3097.00 2988 .00 -6291.86 -484. 93 5939047. 55 558353. 79 MWD+IFR-AK-CAZ-SC 7830.57 75 .71 182. 34 3119.10 3010 .10 -6380.45 -488. 78 5938958. 94 558350. 63 MWD+IFR-AK-CAZ-SC 7924.67 75 .40 181. 52 3142.58 3033 .58 -6471.52 -491. 85 5938867. 85 558348. 27 MWD+IFR-AK-CAZ-SC 8016.02 75 .65 181. 52 3165.41 3056 .41 -6559.94 -494. 19 5938779. 43 558346. 62 MWD+IFR-AK-CAZ-SC 8108.35 74 .97 182. 65 3188.83 3079 .83 -6649.19 -497. 44 5938690. 16 558344. 07 MWD+IFR-AK-CAZ-SC 8200.91 75 .16 182. 58 3212.68 3103 .68 -6738.53 -501. 52 5938600. 80 558340. 69 MWD+IFR-AK-CAZ-SC 8292.53 75 .09 182. 54 3236.20 3127 .20 -6827.00 -505. 48 5938512. 32 558337. 42 MWD+IFR-AK-CAZ-SC i 8387.93 75 .80 181. 91 3260.17 3151 .17 -6919.26 -509. 06 5938420. 04 558334. 56 MWD+IFR-AK-CAZ-SC 8480.98 76. 94 181. 78 3282.10 3173 .10 -7009.64 -511. 97 5938329. 65 558332. 35 MWD+IFR-AK-CAZ-SC 8574.70 77 .36 182. 53 3302.95 3193 .95 -7100.95 -515. 41 5938238. 32 558329. 63 MWD+IFR-AK-CAZ-SC j 8665.93 78 .66 182. 78 3321.90 3212 .90 -7190.09 -519. 54 5938149. 16 558326. 19 MWD+IFR-AK-CAZ-SC 8759.26 80 .19 181. 84 3339.03 3230 .03 -7281.76 -523. 24 5938057. 48 558323. 21 MWD+IFR-AK-CAZ-SC 8852.31 80 .25 180. 30 3354.83 3245 .83 -7373.44 -524. 95 5937965. 80 558322. 22 MWD+IFR-AK-CAZ-SC ~~ 8944.56 79 .81 180. 29 3370.80 3261 .80 -7464.29 -525. 42 5937874. 95 558322. 46 MWD+IFR-AK-CAZ-SC 9036.73 80. 23 180. 21 3386.78 3277 .78 -7555.07 -525. 81 5937784. 18 558322. 77 MWD+IFR-AK-CAZ-SC '~ 9129.86 80 .74 179. 76 3402.17 3293 .17 -7646.92 -525. 79 5937692. 35 558323. 51 MWD+IFR-AK-CAZ-SC 9220.97 81 .38 179. 52 3416.33 3307 .33 -7736.92 -525. 22 5937602. 36 558324. 78 MWD+IFR-AK-CAZ-SC 9250.02 81 .69 179. 06 3420.61 3311 .61 -7765.65 -524. 87 5937573. 64 558325. 36 MWD+IFR-AK-CAZ-SC i 9307.48 81 .88 178. 50 3428.82 3319 .82 -7822.51 -523. 66 5937516. 80 558327. 01 MWD+IFR-AK-CAZ-SC ': 9399.78 84 .88 179. 25 3439.46 3330 .46 -7914.16 -521. 86 5937425. 17 558329. 53 MWD+IFR-AK-CAZ-SC I 9494.09 88 .05 178. 09 3445.27 3336 .27 -8008.25 -519. 67 5937331. 10 558332. 45 MWD+IFR-AK-CAZ-SC 9586.72 89 .02 177. 61 3447.64 3338 .64 -8100.79 -516. 20 5937238. 61 558336. 64 MWD+IFR-AK-CAZ-SC 9678.93 90 .44 178. 48 3448.07 3339 .07 -8192.94 -513. 05 5937146. 49 558340. 51 MWD+IFR-AK-CAZ-SC 9771.01 91 .61 177. 56 3446.43 3337 .43 -8284.95 -509. 87 5937054. 52. 558344. 41 MWD+IFR-AK-CAZ-SC 9864.89 92 .48 178. 78 3443.08 3334 .08 -8378.72 -506. 88 5936960. 79 558348. 14 MWD+IFR-AK-CAZ-SC 9956.80 92 .10 177. 76 3439.40 3330 .40 -8470.51 -504. 10 5936869. 03 558351. 62 i MWD+IFR-AK-CAZ-SC 10050.55 92 .10 179. 62 3435.97 3326 .97 -8564.17 -501. 96 5936775. 40 558354. 50 MWD+IFR-AK-CAZ-SC '~ 10142.09 90 .24 179. 94 3434.10 3325 .10 -8655.68 -501. 61 5936683. 90 558355. 56 MWD+IFR-AK-CAZ-SC 10234.50 90 .31 177. 51 3433.66 3324 .66 -8748.06 -499. 55 5936591. 54 558358. 34 MWD+IFR-AK-CAZ-SC it 10327.31 90 .25 177. 45 3433.20 3324 .20 -8840.78 -495. 47 5936498. 87 558363. 14 MWD+IFR-AK-CAZ-SC ' 10419.74 90. 56 175. 37 3432.55 3323 .55 -8933.02 -489. 69 5936406. 68 558369. 65 MWD+IFR-AK-CAZ-SC ~ 10511.87 89 .88 172. 22 3432.19 3323 .19 -9024.60 -479. 73 5936315. 20 558380. 32 MWD+IFR-AK-CAZ-SC 10606.17 90 .62 173. 43 3431.78 3322 .78 -9118.16 -467. 95 5936221. 74 558392. 83 MWD+IFR-AK-CAZ-SC 10697.84 90 .10 173. 20 3431.21 3322 .21 -9209.20 -457. 28 5936130. 79 558404. 21 MWD+IFR-AK-CAZ-SC 10789.16 89 .88 175. 06 3431.22 3322 .22 -9300.04 -447. 94 5936040. 04 558414. 25 MWD+IFR-AK-CAZ-SC 10884.68 91. 68 177. 52 3429.92 3320 .92 -9395.34 -441. 76 5935944. 80 558421. 18 MWD+IFR-AK-CAZ-SC 10974.62 89. 62 178. 11 3428.90 3319 .90 -9485.20 -438. 33 5935854. 97 558425. 31 MWD+IFR-AK-CAZ-SC ~~ 11067.75 90 .25 180. 43 3429.01 3320 .01 -9578.32 -437. 15 5935761. 88 558427. 22 MWD+IFR-AK-CAZ-SC 11161.87 89 .63 183. 29 3429.11 3320 .11 -9672.38 -440. 20 5935667. 81 558424. 90 MWD+IFR-AK-CAZ-SC 11256.04 89 .88 185. 68 3429.51 3320 .51 -9766.25 -447. 57 5935573. 89 558418. 27 MWD+IFR-AK-CAZ-SC ~ 11347.92 90 .69 185. 15 3429.05 3320 .05 -9857.72 -456. 24 5935482. 36 558410. 32 MWD+IFR-AK-CAZ-SC 11440.17 92. 42 182. 96 3426.55 3317 .55 -9949.70 -462. 76 5935390. 35 558404. 51 MWD+IFR-AK-CAZ-SC ' ~ 11533.44 90 .36 181. 65 3424.29 3315 .29 -10042.86 -466. 51 5935297. 17 558401. 49 MWD+IFR-AK-CAZ-SC 11627.16 90 .56 182. 30 3423.53 3314 .53 -10136.52 -469. 74 5935203. 50 558398. 99 MWD+IFR-AK-CAZ-SC 11719.81 90 .56 183. 85 3422.63 3313 .63 -10229.03 -474. 71 5935110. 96 558394. 75 MWD+IFR-AK-CAZ-SC 11812.90 91 .86 184. 26 3420.66 3311 .66 -10321.86 -481. 29 5935018. 09 558388. 89 MWD+IFR-AK-CAZ-SC 11906.67 90. 18 182. 25 3418.99 3309 .99 -10415.46 -486. 61 5934924. 46 558384. 30 MWD+IFR-AK-CAZ-SC ~ 11999.67 90. 56 182. 96 3418.39 3309 .39 -10508.36 -490. 84 5934831. 54 558380. 80 MWD+IFR-AK-CAZ-SC 12091.95 89 .81 181. 64 3418.10 3309 .10 -10600.56 -494. 54 5934739. 32 558377. 82 MWD+IFR-AK-CAZ-SC i Halliburton Company! Survey Report Company: ConocoPhillips Alaska Inc. Date: 6/5/2006 Time: 16 :27:03 Page: 4 Rie-d: Ku paruk River U nit Co-ord inate(NE) R eference: Well: 1J-184, True 'North Site: Ku paruk 1J Pad Vertical (TVD) Reference: 1J-184: 109.0 Well: 1J-184 Section (VS) Reference: Well'( O.OON,O.OOE, 180.OOAzi) Wellpath: 1J-184 Survey Calculation Method: Minim um Curvature Db: Oracle Sure c~' MD Licl lzim TVD SysTVD N/S E/W MapN MapE ____ _ Tool ft deg deg ft ft ft ft ft ft 12184 .33 89 .51 181. 03 3418 .64 3309 .64 -10692.91 -496.69 5934646. 96 558376.38 MWD+IFR-AK-CAZ-SC 12276 .12 91 .68 179. 05 3417 .69 3308 .69 -10784.69 -496.76 5934555. 20 558377.04 MWD+IFR-AK-CAZ-SC 12369 .70 91 .17 176. 94 3415 .36 3306 .36 -10878.18 -493.48 5934461. 75 558381.04 MWD+IFR-AK-CAZ-SC '; 12460 .78 89 .62 176. 33 3414 .73 3305 .73 -10969.09 -488.14 5934370. 88 558387.09 MWD+IFR-AK-CAZ-SC 12553 .27 90 .44 175. 88 3414 .69 3305. 69 -11061.37 -481.85 5934278. 67 558394.10 MWD+IFR-AK-CAZ-SC 12647 .48 91 .31 176. 13 3413 .25 3304 .25 -11155.34 -475.29 5934184. 76 558401.39 MWD+IFR-AK-CAZ-SC 12742 .53 90 .55 175. 39 3411 .70 3302 .70 -11250.12 -468.27 5934090. 05 558409.16 MWD+IFR-AK-CAZ-SC i ~I 12835 .55 89 .38 176. 20 3411 .76 3302 .76 -11342.88 -461.44 5933997. 35 558416.70 MWD+IFR-AK-CAZ-SC 12932 .26 91 .43 177. 99 3411 .08 3302 .08 -11439.46 -456.54 5933900. 83 558422.36 MWD+IFR-AK-CAZ-SC 13027 .60 88 .82 178. 04 3410 .87 3301. 87 -11534.73 -453.24 5933805. 59 558426.40 MWD+IFR-AK-CAZ-SC 13122 .80 89 .70 179. 01 3412 .10 3303. 10 -11629.89 -450.79 5933710. 46 558429.59 MWD+IFR-AK-CAZ-SC 13217 .69 89 .26 179. 13 3412 .96 3303 .96 -11724.76 -449.25 5933615. 61 558431.87 MWD+IFR-AK-CAZ-SC 13311 .68 91 .06 178. 95 3412 .70 3303 .70 -11818.74 -447.68 5933521. 67 558434.18 MWD+IFR-AK-CAZ-SC 13408 .39 89 .75 180. 76 3412 .01 3303 .01 -11915.44 -447.43 5933424. 98 558435.18 MWD+IFR-AK-CAZ-SC 13503 .54 91 .31 181. 34 3411 .13 3302 .13 -12010.56 -449.18 5933329. 85 558434.18 MWD+IFR-AK-CAZ-SC 13599 .05 90 .62 180. 24 3409 .53 3300. 53 -12106.05 -450.49 5933234. 37 558433.61 MWD+IFR-AK-CAZ-SC 13693 .97 91 .18 180. 73 3408 .04 3299. 04 -12200.95 -451.30 5933139. 47 558433.55 MWD+IFR-AK-CAZ-SC 13789 .41 90 .74 180. 68 3406 .44 3297 .44 -12296.37 -452.47 5933044. 05 558433.12 MWD+IFR-AK-CAZ-SC 13884 .41 90 .93 179. 57 3405 .05 3296 .05 -12391.36 -452.68 5932949. 07 558433.65 MWD+IFR-AK-CAZ-SC 13978 .13 90 .06 179. 15 3404 .24 3295 .24 -12485.07 -451.63 5932855. 38 558435.43 MWD+IFR-AK-CAZ-SC 'i 14076 ~ .11 89 .88 178. 95 3404 .29 3295 .29 -12583.04 -450.01 5932757. 44 558437.82 MWD+IFR-AK-CAZ-SC: I 14170 .57 89 .82 177. 40 3404 .54 3295 .54 -12677.44 -447.00 5932663. 07 558441.56 MWD+IFR-AK-CAZ-SC 14266 .16 90 .07 177. 73 3404 .63 3295. 63 -12772.95 -442.94 5932567. 61 558446.37 MWD+IFR-AK-CAZ-SC 14361 .09 90 .75 176. 59 3403 .95 3294 .95 -12867.76 -438.23 5932472. 85 558451.81 MWD+{FR-AK-CAZ-SC 14455 .42 91 .74 177. 10 3401 .90 3292 .90 -12961.92 -433.04 5932378. 74 558457.74 MWD+IFR-AK-CAZ-SC 14550 I .55 90 .68 178. 48 3399 .89 3290 .89 -13056.95 -429.38 5932283. 75 558462.15 MWD+IFR-AK-CAZ-SC 14645 .86 91 .24 179. 91 3398 .30 3289 .30 -13152.24 -428.04 5932188. 48 558464.23 MWD+IFR-AK-CAZ-SC 14740 .05 90 .06 180. 68 3397 .23 3288. 23 -13246.42 -428.52 5932094. 31 558464.48 MWD+IFR-AK-CAZ-SC ~ ', 14834 .90 89 .88 181. 27 3397 .28 3288. 28 -13341.26 -430.14 5931999. 48 558463.61 MWD+IFR-AK-CAZ-SC 14930 .72 90 .19 181. 42 3397 .22 3288. 22 -13437.05 -432.38 5931903. 68 558462.11 MWD+IFR-AK-CAZ-SC 15025 .28 90 .06 181. 33 3397 .01 3288 .01 -13531.58 -434.65 5931809. 14 558460.57 MWD+IFR-AK-CAZ-SC 15121 .47 90 .93 180. 74 3396 .18 3287 .18 -13627.75 -436.39 5931712. 97 558459.59 MWD+IFR-AK-CAZ-SC 15215 .78 91 .11 181. 21 3394 .50 3285 .50 -13722.03 -438.00 5931618. 69 558458.72 MWD+IFR-AK-CAZ-SC ~ 15310 .66 90 .86 181. 33 3392 .87 3283. 87 -13816.87 -440.10 5931523. 84 558457.36 MWD+IFR-AK-CAZ-SC 15404 .72 89 .81 178. 38 3392 .32 3283. 32 -13910.92 -439.86 5931429. 81 558458.33 MWD+IFR-AK-CAZ-SC 15500 .57 93. 41 177. 53 3389 .63 3280. 63 -14006.66 -436.44 5931334. 11 558462.49 MWD+IFR-AK-CAZ-SC 15596 .19 91 .91 178. 59 3385 .19 3276 .19 -14102.11 -433.21 5931238. 69 558466.47 MWD+IFR-AK-CAZ-SC I!, i 15691 .87 90 .86 178. 15 3382 .88 3273 .88 -14197.73 -430.49 5931143. 11 558469.94 MWD+IFR-AK-CAZ-SC i 15785 .61 90 .18 177. 50 3382 .03 3273. 03 -14291.39 -426.93 5931049. 48 558474.23 MWD+IFR-AK-CAZ-SC 15881 .07 91. 12 178. 38 3380 .95 3271. 95 -14386.78 -423.50 5930954. 13 558478.40 MWD+IFR-AK-CAZ-SC 15976 .71 90. 87 177. 27 3379 .29 3270. 29 -14482.34 -419.87 5930858. 62 558482.78 MWD+IFR-AK-CAZ-SC 16071 .04 90. 99 172. 20 3377 .75 3268. 75 -14576.23 -411.22 5930764. 81 558492.16 MWD+IFR-AK-CAZ-SC '~ 16166 .47 91 .36 174. 44 3375 .80 3266 .80 -14670.98 -400.12 5930670. 15 558504.00 MWD+IFR-AK-CAZ-SC 16260 .10 89 .93 177. 25 3374 .74 3265 .74 -14764.35 -393.34 5930576. 85 558511.51 MWD+IFR-AK-CAZ-SC ', 16357 .07 90 .13 179. 35 3374 .69 3265. 69 -14861.27 -390.46 5930479. 96 558515.14 MWD+IFR-AK-CAZ-SC i 16452 .27 89. 19 177. 75 3375 .26 3266. 26 -14956.43 -388.05 5930384. 83 558518.29 MWD+IFR-AK-CAZ-SC j 16547 .33 91. 49 179. 54 3374 .69 3265. 69 -15051.46 -385.81 5930289. 84 558521.28 MWD+IFR-AK-CAZ-SC 16642. 55 92. 04 179. 42 3371 .76 3262. 76 -15146.63 -384.94 5930194. 68 558522.89 MWD+IFR-AK-CAZ-SC 16735 .66 91 .91 178. 50 3368 .55 3259 .55 -15239.67 -383.25 5930101. 67 558525.30 MWD+IFR-AK-CAZ-SC 16830 .28 88 .07 180. 83 3368 .57 3259 .57 -15334.26 -382.70 5930007. 09 558526.59 MWD+IFR-AK-CAZ-SC; i 16925 ~i .33 84. 54 181. 59 3374 .69 3265. 69 -15429.07 -384.70 5929912. 27 558525.33 MWD+IFR-AK-CAZ-SC 17020 .16 79. 48 183. 29 3387 .87 3278. 87 -15522.87 -388.69 5929818. 46 558522.08 MWD+IFR-AK-CAZ-SC i .~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Dare: 6/5/2006 'l'ime: 16:27:03 Page:- Field: Kup aruk River Unit Co-ordinate(NE) Re ference: We1L 1J-184, True North Site: Kup aruk 1J Pad Vertical (TVD) Refe rence: 1J- 184: 109.0 Well: 1J-1 84 Section (VS) Referen ce: We ll (0.OON,O.OOE,1 80.OOAzi) ~~'ellpath: 1J-1 84 Survey Calculation Method: Minimum Curvature Db: Oracle Survc~ _- SID lncl Acim TVD SysTVD _ N/S __ E/~Y _ ___ MapN '~1apE Tool ft deg deg ft ft ft ft ft ft ~'~ 17115.37 76.09 183.78 3408.01 3299.01 -15615.73 -394.42 5929725.57 558517.07 MWD+IFR-AK-CAZ-SC 17211.54 75.13 185.03 3431.91 3322.91 -15708.60 -401.58 5929632.65 558510.64 MWD+IFR-AK-CAZ-SC 17306.88 71.11 184.29 3459.59 3350.59 -15799.51 -408.99 5929541.69 558503.94 MWD+IFR-AK-CAZ-SC 17401.41 67.27 183.09 3493.17 3384.17 -15887.68 -414.69 5929453.50 558498.93 MWD+IFR-AK-CAZ-SC 17496.54 62.97 181.44 3533.18 3424.18 -15973.88 -418.12 5929367.27 558496.17 MWD+IFR-AK-CAZ-SC 17591.99 58.58 181.07 3579.78 3470.78 -16057.14 -419.95 5929284.01 558494.99 MWD+IFR-AK-CAZ-SC 17687.31 53.96 181.23 3632.69 3523.69 -16136.38 -421.54 5929204.77 558494.02 MWD+IFR-AK-CAZ-SC 17782.48 49.30 182.50 3691.75 3582.75 -16210.93 -423.94 5929130.21 558492.20 MWD+IFR-AK-CAZ-SC 17812.26 47.80 182.33 3711.46 3602.46 -16233.23 -424.88 5929107.90 558491.44 MWD+IFR-AK-CAZ-SC 17838.72 46.59 182.72 3729.44 3620.44 -16252.63 -425.73 5929088.51 558490.73 MWD+IFR-AK-CAZ-SC 17870.00 46.59 182.72 3750.94 ~ 3641.94 -16275.33 -426.81 5929065.80 - 558489.83 PROJECTED to TD • • WELL LOG TRANSMITTAL To: State of Alaska June 29, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-184 & 1J-184 Ll, AK-MW-4348857 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23305-00, -60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~- o ~p(o -O~/~/ ~13945~ ~~ _... - - Signed: ~ a<t5~ `~ t 39~~ • r 14-Jun-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 1.00 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-184 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey: 17,838.72' MD (if applicable) Projected Survey: 17,870.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ , _ Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~CEIVED JUN 2 ~ 2006 al~elcBE>jl & Gas Cons. Commission Anchorage RE: 1J-184 PTD (206-044 & 206-045) Subject: RE: 1J-184 PTD (206-044 & 206-045) From: NSK Problem Well Supv <n1617 cr conocophillips.com> Date: Wed, 07 Jun 2006 10:15:50 -0800 To: NSK Problem ~~%ell SuP~~ ~n161 i~rr~:amocop~~illif~s.com>, ~~~inton_aubertru:ad~liin.state.ak.us, toi~~ ~lriunderr~l~adi~~in.~tate.ak.us C'C: NSK 1~t`est Sak Prod En~r ~=n163~(a:'cor~ocopl~illips.com~% W i ntan, Tom I dauble checked with the West Sak PE and he confirmed that standard practice is to submit all 10-407's as producers then submit the 10-403 to convert to injection ante the pre production diagnostics are finished. With your verbal permission we plan to preproduce each Ceg 14 days and the combined well for 30 days. Approximate total production time will be 60 to 90 days. Sincerely Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cel I 907-943-1244 -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, June 07, 2006 9:34 AM To: winton_aubert@admin.state.ak.us Subject: FW: iJ-184 PTD (206-044 8c 206-045) Winton, I found out today that Tam is out of the office. Would you give the following a read through and let me know your thoughts. Thanks in advance. Perry Klein -----Original Message----- From: NSK Problem Well Supv Sent: Friday, June 02, 2006 5:17 AM To: Thomas Maunder' Subject: iJ-184 PTD (206-044 & 206-045) Tom, ConocoPhillips would like to request approval to pre produce injection well 1J-184 using gas lift through an open sliding sleeve at 8726 MD - 3333 TVD for approximately 90 days with option to extend after which a 10-403 will be submitted to convert 1 J-184 to an injection well. pcz~ ~~ 1 of~~ 4/25/2007 10:48 AM SCM ~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECEIVED MAY 2 4.2006 NO. 3808 ~ ~ ~ ~• C~'a~i~iOR Company: Alaska Oi18 Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Well Job # Log Description Date BL Kuparuk Color CD 05/18/06 1G-01 REDO 11213744 INJECTION PROFILE i tf -tab 05/03/06 1 1Q-26 11258706 PRODUCTION LOG W/DEFT ~ - ~ 05/06/06 1 1A-03 11258708 PRODUCTION LOG W/DEFT I ~ j - a 05/07/08 1 1Y-15A 11216294 PRODUCTION LOG W/DEFT 05/08/08 1 1A-02 11258709 SBHP SURVEY l! a ~ 4s t - 05/09/08 1 1R-13 11258711 INJECTION PROFILE ~ - 05/10/06 1 2M-34 11216296 INJECTION PROFILE - 05/11/06 1 2F-03 11216298 SBHP SURVEY rt 05/14/06 1 2F-14 11216299 SBHP SURVEY ~ 05/14/06 1 1A-08 11258712 INJECTION PROFILE ~ C 05/14/06 1 3Q-11 11216301 LDL j ~~ - 05/16/06 1 1J-184 11216297 USIT -r c 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~.~= .] FW: Extending 1J-184 Surface Depth • Subject: FW: Extending 1J-184 Surface Depth Frorn: "Reilly, Patrick J" <Patrick..I.Keilly@conocophillips.com> Date: Wed, 26 Apr 2006 1 i):~t9:5~ -OSi~O To: Z~homas Mau~~dcr <tom maunclcr(uadmirl.state.ak.us=~~ Tom, On the email below, I meant 205 ft3, not 205 sacks. The new summary is enclosed. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly@conocophillips.com -----Original Message----- From: Reilly, Patrick J Sent: Wednesday, April 26, 2006 10:26 AM To: 'Thomas Maunder' Subject: RE: Extending iJ-184 Surface Depth Tom, We are planning on increasing the volumes with the lead cement and keeping the tail 800' long. Extending the surface to 4000' from 3639' gives us an additional 361' of hole. With 35% excess, that is 205 additional sacks of lead. I will send over the new complete summary design when our cement engineer completes it. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly@conocophillips.com -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, April 25, 2006 7:31 AM To: Reilly, Patrick J Subject: Re: Extending 1J-184 Surface Depth Hi Pat, So long as the requirements of the regulations are met (primarily cement to surface), deepening the surface casing depth as you propose is acceptable. Will you increase the tail cement volume to account for the additional hole? Please provide the new cementing numbers. Call or message with any questions. Tom Maunder, PE AOGCC • ~o6-oti~ 1 of 2 4/26/2006 12:19 PM FW: Extending 1J-184 Surface Depth • • Reilly, Patrick J wrote, On 4/24/2006 5:39 PM: Tom, We would like to extend the surface shoe to 4,000' from the current planned depth of 3,639'. That is about 84' TVD deeper. This will aid us in running our 9 5/8" intermediate casing. Our torque and drag model indicates that the extra 400' of cased hole (lower friction factor) will provide a significant amount of extra down weight. Without the extra weight, we might be pretty close to running out of weight. I have reviewed the issue with our geologist and he believes we should be OK from a cementing perspective. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly(c~conocophillips.com «Patrick.J.Reilly@conocophillips.com.vcf» Content-Description: 1J-184, 1338 Summary, V2.pdf 1J-184,1338 Summary, V2.pdf Content-Type: application/octet-stream Content-Encoding: base64 __ _ _ __ 2 of 2 4/26/2006 12:19 PM II ( Y~ ~ ~ ALASS~ OIL A1~TD GAS COI~TSER'QATI011T CO1~II-'IISSIOIQ Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 ~ FRANK H. MURKOWSKI, GOVERNOR r l' ~~ 333 W. 7"' AVENUE, SUITE 100 f ANCHORAGE, ALASKA 99501-3539 1 4 PHONE (907) 279-1433 FAX (907) 27&7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-184 ConocoPhillips Alaska, Inc. Permit No: 206-044 Surface Location: 1530' FSL, 2424' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1260' FSL, 2851' FEL, SEC. 14, T10N, RIOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmen~al agencies and does not authorize conducting drilling operations until all other r~ryuired permits and approvals have been issued. In addition, the Commission reserve:. +he 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this I day of April, 2006 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas a ~~ Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com ~Q~ 3 1 2006 March 31, 2006 ~~~i~i~9t'~ °°'~ Alaska Oii and Gas Conservation Commission 333 West 7`h Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1J-184 and 1J-184L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for two onshore multilateral injector wells, 1J-184 and 1J-184L1. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005. The expected spud date of 1)-184 is April 13, 2006 and a week later for 1J-184L1. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, n„ ~~~~ n -.~,--.----~ Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~ 1a. Type of Work: Drill ^/ - Re-drill ^ Re-entry ^ 1b. Curcent Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service ^/ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-184 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17626' TVD: 3619' ' 12. Field/Pool(s): Kuparuk River Field 4a. Loption of Well (Governmental Section): Surface: 1530' FSL, 2424' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ~~~ ADL 25662 & 380058,/-~/~ West Sak Oil Pool Top of Productive Horizon: 4305' FSL, 2933' FEL, Sec. 11, T10N, R10E, UM - S. Land Use Permit: ALK 2177 & 4604 13. Approximate Spud Date: 4/13/2006 Total Depth: 1260' FSL, 2851' FEL, Sec. 14, T10N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to y 1~,'~~ Nearest Property: ZA29' y/e1 7~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558789 ' y- 5945342 'Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. D~a~t9 Neares~ ~s_ /L / Well within Pool: West Sak 5 , 350' @ 10200' ~ 16. Deviated wells: Kickoff depth: 250 ' ft. Maximum Hole Angle: 90.5° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ~. c>( Downhole: 1640 psig ~ Surface: 1239 psig ' 18. Casing Program fications S Setting Depth Quantity of Cement Size pec Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 108' " 108' 260 cf ArcticCrete 16" 13.375" 68# L-80 BTC 3611' 28' 28' 3639' - 2150' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 9.625" 40# L-80 BTCM 9226' 28' 28' 9254' - 3428' - 630 sx DeepCrete 8.5" 5.5" 15.5# L-80 BTCM 8372' 9254' 3428' 17626' 3619' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To lie completed for Redrill and Re-Entry Operations) Total Depth MD (tt): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (tt): Junk (measured) Casing Length Size Cement Volume MD ND ConductodStructural Surface Intermediate Production Liner ~'{ ~@~ Perforation Depth MD (ft): Perforation Depth TVD (ft): 0~~ 20. Attachments: Filing Fee Q BOP Sketch / Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is Vue and correct to the best of my knowledge. Contact P8t Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~~ ~` ~ '~ Phone 2. Date 3 3 (/G . P nA Commission Use Only Permit to Drill " ~ Number. ~ ~p " ~~ / API Number: 50- Q 7.,..9 - L 3 3Q S-~ Permit Approval Date: ~. See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed me ane, gas hydra , or as contained in shales: ~y~"c' ~ ~M~~~ ~vc~i`t~ ~ ~ ~ Samples req'd: Yes ^ No ~ ud o req'd: Yes ^ No [' Other: ,.~©~Q~S` ~~.p ~~ ~S~`~~H?~gteasures: Yes ^ No Dir al req'd: Yes [v~ No ^ .~'c.~~~L~~~~~c~E.~c3.~~0~5~~c>_L~j«c~ ~''` l ~V ~ PROVED BY THE COMMISSION DATE: ,COMMISSIONER ~R ad Form 10-401 Revised 1212005 - f ~ ~ ~ ~ ~~ r~ ~ ~`''~ ~/~.~ub it in Duplicate • ~ation for Permit to Drill, Well 1J-184 .Revision No.O Saved: 29-Mar-06 Permit It -West Sak Well #1J-184 Application for Permit to Dill Document fIl 41 A 1 III 1 i f."' '1Me•II ~lQlue Table of Contents 1. Well Name .................................................................................................................................2 Requirements of 20 AAC 25.005 (~ ........................................................................................................................ 2 2. Location Summary ...................................................................................................................2 Requirements of 20 AAC 25.OOS(c)(2) .......:...................................................................................:....................... 2 Requirements of 20 AAC 25.OS0(b) ......:................................................................................................................. 3 3. Blowout Prevention. Equipment Information ........................................................................ 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................................... 3 4. Drilling Hazards Information ...................................................:............................................. 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests .................................................:.......3 Requirements of 20 AAC 25.005 (c)(S) .................................................................................................................. 3 6. Casing and Cementing Program ............................................................................................4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................................... 4 7. Diverter System Information ..................................................................................................4 Requirements of 20 AAC 25.005(c)(7) ..........................................................................................:........................ 4 8. Drilling Fluid Program .......................:..................................:.................................................4 Requirements of 20 AAC 25.OOS(c)(8) ........................:.......................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................................. 4 Intermediate Hole Mud Program (extended bentonite) .............................................................:............................ S Lateral Mud Program (MI FloPro NT) ...................................................................:.......:...................................... S 9. Abnormally Pressured Formation Information ....................................................................5 Requirements of 20 AAC 25.005 (c)(9) ...............................................:.................................................................. S 10. Seismic Analysis ........:..............................................................................................................5 Re uirements o 20 AAC 25.005 c 10 ........................... S q .f ()( ) ..................................................................................... 11. Seabed Condition Analysis ......................................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................................ S 1J-184 PERMIT IT Page 1 of 7 Printed: 29-Mar-O6 ~~.~... • ~ation for Permit to Drill, Well 1 J-184 Revision No.O Saved: 29-Mar-06 12. Evidence of Bonding ................................................................................................................5 Requirements of 20 AAC 25.005 (c)(12) ........................................:...................,................................:.................: S 13. Proposed Drilling Program .....................................................................................................5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................................ S 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................................7 Requirements of 20AAC25.005 (c)(14) .......................................................................................................:........7 15. Attachments ..............................................................................................................................7 Attachment 1 Directional Plan (14 pages) ...........:................................................................................................. 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................................ 7 Attachment 3 Cement Loads and CemCADE Summary (2 pagse) .........................:.................:............................ 7 Attachment 4 Well Schematic (1 pages) .....................................................................................................:.......... 7 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique Warne designated by the operator^ and a tanique API number a-signed by the contrrtission under 20 A.4C" 25.040(6). Por a well with multiple well branches, each branch must similarly he identified fiy a unique name andAPl number by adding a suffix to the name designated~ar tlae welt 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 1J-184, 2. Location Summary Requirements of 20 AAC 25.005(c)(2) Ara application for^ a Permit to Drill must be accompanied by each of the following itents, ea-cept for an item alreacl}~ on filewith the commissions and identified in the application: (2) a plat identifying the property and the prol'~erty's owners cnad showing (g)the coordinates of the proposed location of the well at the surface, at the top of each ob='ectn^e formation, ezrul at total depth, r~jerenced to governmental section lines. (B) the coordinates of the proposed location of the well at the sur~`ace, referenced to the state plane rnorditsate system for this state as maintaained Uv the National Ueodetic Survey in tlae Rrational Oceanic and Atmospheric Adrrtinistration; (L) the proposed depth of the x=ell at the top of each objective forrraakbn and at tots/depth; Location at Surface 1,530' FSL, 2424' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5,945,342 Eastings: 558,789 Pad Elevation 81' AMSL Location at Top of Productive Interval (West 4,305' FSL, 2,933' FEL, Section 11, T10N, R10E Sak "B" Sand ASP Z 4 NAD 27 di Measured Depth, RKB: 9,254 one Coor nates Northings: 5 937 555 Eastin s: 558 349 Total Vertical Depth, RKB.• 3 ,428 , , g , Total Vertical Depth, SS: 3,319 Location at Total Depth 1,260' FSL, 2,851' FEL, Section 14, T10N, RIDE. ASP Z 4 NAD 27 C di Measured Depth, RKB: 17,626 one oor nates Northin s: 5 929 231 Eastin s: 558 505 Total Vertical Depth, RKB: 3,619 g , g , , Total Vertical Depth, SS: 3,510 and (D) other information regaaired by 20 AAC 2~.(JSO(h); 1J-184 PERMIT /T Page 2 of 7 Printed: 29-Mar-O6 02'61N.AL ~ation for Permit to Drill, Well 1J-184 Revision No.O Saved: 29-Mar-06 Requirements of 20 AAC 25.050(b) ~~u well is to fie irttentioa-tally deviated, the applicaiion fnr a Permit to Drill (Form 10-a/II) must (7) include a Irlat, drawn to a suitable scale, showizag the path of the proposed wellfiore, iracludiz2g adl adjaeent x~ellbores with~irt 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all welts within 200 feet of the proposed x~ellhore (,4) list the names of tlae operators of those wells, to the extent that those names are known or discoverable in public recoraas, and show that each narraed operator has been ftzrnislted a copy of the application by certified rtaail; or p3) 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) f1n applieaiivn for a Permit to Brill must be accompanied by each of'the following items, c:xeept for an item alt"eculy on file with the commission and identified in the application: (3) a diagram grad descrzpticin of the blowozzt prevention equipment (HOPE) as required by 20 A(~.++4C 25.035, 20 ~1~1``C 25.036, or 20 ~1r2C 25.03:, cis applicable; ",CCCc Cc c`1c~~ ~ '!C C- ~~ t"t ~C O CHG. ` c`~ QS~r`~ p~y0~ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-184. Please see A C(}, information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. /~-~~ ~l~ 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a PErtnit to 1?rill must be accompanied bJ' each of the following items, except, jor an Item alreadv on file with the comrrtissian and identifier) in the applieatiora:~ (4) information on drilling hazards, including (A) the maximum downhole pressure that may be eracozmtered, criteria used to determine it, and maximum potentirxl surfue pressurr: hosed on a methane gradieni; The expected reservoir pressure in the West Sak sands in the 1J-184 area is 0.45 psi/ft, or 8.6 ppg EMW (equivalent ~ mud weight). The maximum potential surface pressure (MPSP) is 1,239 psi. Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 3,645'. The MPSP is: MPSP = (3,645 ft)(0.45 - 0.11 psUft) =1,239 psi ' (B) data on potential gtzr zones; The well bore is not expected to penetrate any gas zones. utzcl (C') dtzta concerning potential causes of hole prciblems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity.for c/ifferetztial stickuzg; Please see Attachment 2: 1J-184 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application far rz Permit to Drdl must be accompanied by each of the following items, except for cart item alreadv on file with the corzurtission and identfedd in the czppl-icatiort: (5) a descriptiotz of the procedure fcn' cotaductizag formation integrity tests, as regztired under 20 ~1AC 25.030{f); 1J-184 will be completed with 9-5/8" casing landed at the top of the West Sak "B" sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConcocoPhillips Alaska placed on file with the Commission. 1J-184 PERMIT /T Page 3 of 7 Printed: 29-Mar-O6 ~ation for Permit to Drill, Well 1J-184 Revision No.O Saved: 29-Mar-O6 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application, for q I'er'mii to Drill must be accompanied by each o_f t}ae following items, except for an item already on file wit}t fhe commission and identified ira the application: (h) a complete proposed casing and cernenting.progrmn as required fiy 20 AAC 2,5.0301, and a description ~f arzy slotted liner, pre perforated liner', or screen to be insttalled, See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length t~ID/TVD MD/TVD OD in in lb/ t Grade Connection t t t Cement Pro ram 20" 40" 62.5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,611 28' / 28' 3,639' / 2,150' 700 sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail Cement Top planned @ 5,745' 9-5/8" 12-1/4" 40 L-80 BTCM 9 226 28' / 28' 254' / 3 428' 9 MD / 2,656' TVD. Cemented , , , w/ 630 sx Dee CRETE 5-1/2 8-1/2" B Sand Lateral 15.5 L-80 BTCM 372 8 254' / 3 9 428' 626' / 3 17 619 Slotted-no cement Ot - 4 , , , , , 5-1/2 8-1/2" D Sand Lateral 15.5 L-80 BTCM 8 009 8 842' / 3 - no cement slotted (1J-184 Ll) , , , 7. Diverter System Information Requirements of 20 AAC 25.005(c)(?) ,4n application fhr a Permit to Drill must be accompanied by each of the following items, except for crn item already on file wiih the eornrnission and identified in the application: (?) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC' 25.035(h)(~); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1J- 184. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for ca Permit to L?rill must be acconzpanizd by each of the, following items, except for an item calreadv on file with the commission and identifiecd in the application: (c4) a drilling fluid program, inclztding a diagram grad description of the drilling fluid system, as required by 20 A.AC'S.033: Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Value Final Value Initial Value Final Value Density (pp~ 8.5 9.2 9.2 9.6 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50-70 50-70 30-50 30-50 (cP) Plastic Viscostiy 20-45 20-45 15-20 15-20 Ib/100 s pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate NC-8 0 NC-8 0 5 0-7 0 5 0-7 0 (cc % 30 min) . . . . . . *9.6 ppg if hydrates are encountered 1J-184 PERMIT IT Page 4 of 7 Printed: 29-Mar-O6 ORIGINAL • ~ation for Permit to Drill, Well 1 J-184 Revision IVo.O Saved: 29-Mar-O6 Intermediate Hole Mud Program (LSND) 10-3/4"Casing Shoe to Intermediate Casing Point Initial Value Densi ( 9.0-9.1 Funnel Viscosity 45-60 (seconds) Plastic Viscostiy 12-18 (lb/100 s Yield Point 26-35 (cP) API Filtrate 4-6 (cc / 30 min)) Chlorides (mg/l) <500 pH 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value Densi ( ) 9.0 Plastic Viscostiy (lb/100 s~ 15-25 Yield Point (cP 18-28 HTHP Fluid loss (ml/30 min @ <4.0 200psi & 1 SO° Oil /Water Ratio 80:20 Electrical Stability >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill rnzrst be accompanied by each of the_following items, cczcept for an item ah-eady bn file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabtelation setting out the depths of predicted ahnorrnally geo ~resst{red strata ar required by 20.9AC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a I'errttit to Drr.'ll must be acconzpanic:d by each of thefollowing items, except for art item alreaay on file with the cornrnisrion and iilentifietl in the application: {I0) far an exploratory yr stratigralrhic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061 {cr); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(I1) An application for a Permit to Drill mzrst be accompanied fly each of the,f rlla~wing ilenu, except for an Item already art,file with the commission atad identified in the application: ('ll) fa^ a well drilled from an offshore pka f~rrn, mobile bottom founded structure, jack-up rig, or floating drilling vessel, can analysis of seabed conditions as required by 20 A_AC 25.Ob1(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An appltcation for a Permit fo Drill must be accompanied by each of the. following items, except for carz item already-on file with the commission and identified in tlae application: (.1 Z) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met,' Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) rfn upplication fire a Permit to Drill must be accompanied by each of the,following aCcrrzs, except for an item already an file with the cammissiora sand identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1J-184 PERMIT IT Page 5 of 7 Printed: 29-Mar-06 ORIGINAL f~tion for Permit to Drill, Well 1J-184 Revision No.O Saved: 29-Mar-06 L Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install .landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,639' MD / 2,150' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. 6. PU 12-1/4" drilling assembly, with MWD, LWD &PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 9-5/8" casing point at 9,254' MD / 3,428' TVD, the prognosed top of the B sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 5,745' MD / 2,656' TVD if Ugnu formation is not oil bearing. (Top of cement to be 500 feet (MD) above shallowest oil bearing sand if Ugnu is oil bearing). Pressure test casing to 3,000 psi for 30 minutes and record results. P 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. `-'~' c~~r~ ~ `can ~E ~ ~~~ 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. ~~ ~~ 12. PU 8-1/2" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. 14. Directionally dri118-1/2" hole to TD at +/- 17,626'~MD / 3,619' TVD as per directional plan. 15. POOH, back reaming out of lateral. POOH. 16. Run USIT log for cement bond. ~~~ ~ ~ C., ~ 4 17. PU and run 5-1/2" slotted liner. P 18. Land liner, set liner hanger @ +/- 8,942' MD / 3,377'. POOH. Note: Remaining operations are covered under the IJ-184 Ll Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 8,842' MD / 3,359' TVD, the top of the "D" sand. 20. Mill 8-1/2" window. POOH. 21. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD, -RIH. 22. Drill to TD of "D" sand lateral at 16,851' MD / 3,378' TVD, as per directional plan. 23. POOH, back reaming out of lateral. POOH. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 5-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 1J-184 PERMIT IT Page 6 of 7 Printed: 29-Mar-O6 c r ~' ~+ ~~ ~tion for Permit to Drill, Well 1J-184 Revision No.O Saved: 29-Mar-06 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 29. POOH, laying down drill pipe as required. 30. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 31. Nipple down BOPE, nipple up tree and test. Pull BPV. 32. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 33. Set BPV and move rig off. 34. Rig up wire line unit. Pull BPV. i 35. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. Shut well in. 36. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applicatiorz fitr a Permit to Drill zrnzstc be accompanied by each of the foldowirag items, except.for an item alreadv on face ~vitlt the commission aaztl idenfi/ied in the uppliration: (14„„) a general description of hcnv the operator plans to dispose of drilling zraaad and cuttings and a statement of whether the ~Izerator intends to request autlaorizatioaa zrnder 20.AAC 25.080 for ata annular ctispasal operatioza in tlae Sven.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J 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 lE 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Doyon 141 West Sak 2004 3ksi BOP Configuration Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 CemCADE Summary Attachment S Well Schematic 1J-184 PERMIT IT Page. 7 of 7 Printed: 29-Mar-O6 ORIGINAL • Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular ~ To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-%2" to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" ~- To be tested to 250 psi and 3,000 psi only before running casing. ~_ Wellhead Valves tested to 3,000 psi upon assembly Doyon 141 West Sak 3 ksi 13-5 BOP 3KSheet9of~ +~OCtOCC.~~'~"1~~I~JS BOP Confi UPatlon prepared by Steve McKeever A1r~Sl{g g 8/11/2004 RE: 1 J-184 • • Subject: RE: 1 1- I ~4 From: "Reilly, Patrick 1" <Patrick_T.Reilllr~iconocophillips.com= Date: Wed, iii .~~i~r ~UOCi ] ti:> i : 1 -000 - To: Thomas fl~launcier <~torn nlaundcri'u'adn~in.statc.ak.us= Tom, Thanks for the guidance you provided in our phone conversation. Item l: Item 3 on page 3 of 7 should read as follows: An API 13-5/8" x 5,000 psi BOP stack (RSRRA} will be utilized to drill and complete the well. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 9-5/8" rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 9-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 9-5/8" OD. This is the same text that we have been using on our recent "Small Bore" wells except I have replaced 7 5/8" rams with 9 5/8" rams to handle the "Big Bore" intermediate casing. Item 2: In the past we had planned on cementing to 500' MD above the Ugnu B with the contingency plan of going higher if the logs indicated oil in the Ugnu C. However, since we will consider steam flooding the Ugnu in the future, we are planning all wells with the TOC 500' MD above the Ugnu C even if the logs indicate no oil. Item 3: The 1J-184/1J-154 close approach is a vertical separation while drilling the 1J-184 intermediate section. In the close approach sections of the well, 1J-184 will be in the K-13 and 1J-154L1 and L2 will be in the West Sak B and D respectively. There are not any close crossing concerns in the surface hole, however, we will be running gyros until we clear the other wells near the surface. Item 4: Please see the enclosed document showing the P&A diactram. There are 3 cement plugs in the well. The first 2 plugs were set in 1975 right after the well was drilled. The first is across the perforations (6295-6338 MD) The second plug is across the liner top (1911-2306 MD}. The last plug was set at surface during abandonment operations 3/7/86 - 3/14/86. It is approximately 150' of cement. It looks like a good P&A job. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX -at ri ck . J . Rei. 1. I_y~coz7ocophi.:~ l .i ups . com 1 of 2 4/6/2006 7:45 AM RE: 1J-184 -----Original Message----- • From: Thomas Maunder [mailto:tom maunder~~?admirx.state.ak.us Sent: Wednesday, April 05, 2006 12:18 PM To: Reilly, Patrick J Cc: Steve Davies; Dave Roby Subject: iJ-184 Hi Pat, I am reviewing the 1J-184 applications and had a couple of questions/comments. 1. On item 3 on page 3 of 7, while the 141 stack is RSRRA, the PRs are different. This is allowed since the required pressure rating could be as low as API 2K, but you all are using the 5K stack with different size PRs. I think it probably is appropriate to describe that here and also make a statement regarding the BOP test pressure. You do have the distinctions noted in the stack diagram. What do you think? 2. On step 9 of the procedure a comment is made regarding the 9-5/8" TOC and whether or not the Ugnu is oil bearing. we presume that LWD logs will be used to make that determination, correct? From the depths/lengths given in the directional information, it appears that the 5745' TOC is based on covering the Ugnu. Is that correct? What chances do the geologists give for having oil in the Ugnu? 3. On your hazards sheet you comment on the close approach with 1J-154 in the intermediate hole. Since you have a comment that the separation is vertical, is the close approach just caused by the trajectory of iJ-184 as you drill to land the 12-1/4" hole? Are there any concerns with other wells in the surface hole? Will you need gyros until you get away from the congestion on the pad? 4. The 3-D presentation is a great aid. Based on the information presented, the only well that needs to be "looked" at is WS 5. The other 1J wells identified are within the 1/4 mile radius, however they are within zone. I will be checking the WS 5 file, but I will need a statement from you regarding your assessment of the abandonment. Thanks in advance for looking into these questions. Call or message with any questions. Tom Maunder, PE AOGCC Content-Description: Proposed P&A West Sak S.PDF Proposed P&A West Sak S.PDF Content-Type: application octet-stream Content-Encoding: base64 2 of 2 4/6/2006 7:45 AM • • `t General Purpose Worksheet ~~~~ ~~, Subject ?ale No 0! LC.) ^ST $~p,~ RI U C,Q Ti~-TF '~ S file f~Or~ZSE~ ~c~/~! ...SC.~2,QNIf~TI~' 9Y 52S Date /- ~~ `~S wEtG NEr~ d es~ e~._ i ~ ~;C~n~i7 ~iNi~f~ AC~oss To~S oy C' ~ y-f,Nt~~, oF~ drLocv ?A~a `~ ~ ,~/,$%r ~ Ms~iZ~O/I w rC Dr's. c ~ • - CFu~t, ~~ ,~ ~ ,A_' ~ 50 zn e r.~T Sc.~~-fc.cA ~c~v ~F~ So ` q', 3 ~ 1~ t3Q~N~ laysn C~~v' ~i~~ %1 a30C~ - r9 ~l Q _~ _ _Q_~-,. - ~,a - :~ , ~ L ''~ i~%'~~ (- tinT -~ s u ~ H Ac c. ~.~/ ao 5 sx ~C 12Ml~ F/Z05T CN- T 7 " 7aL @ a io ~ , sy-2~ w~ a5o S~ A~-rcS~ Q'~~ yo ~ ~l7 ~, ~-9'S, arc @ rya nl~hr ~ Su2:ACE- c....~/S'S~% SX ~2~cS d ~~ Jo3 -~-~,~ts ,2i~r.,~s GG ~o.~ 7 " 2 E r~~ ~u t .2 ~v to is 3 ~"~ ~~ i/i _ K~ ~' 3 t ~'~ a3 ~ Soo -~s, d~ /~,~~,e `~ -~~a~ob -1~G77 Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 4/26/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 120' MD < Base of Permafrost at 1,685' MD (1,526' TVD) CemCADE Preliminary Job Design 13 3/8" Surface Casing feliminary Job Design basetl on limitetl input tlffia. FOf estimate pufpOSes Only. ~hl~mbrger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 3,200' MD. Lead Slurry Minimum pump time: 280 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (120'} x 1.00 (no excess) = 122.3 ft3 0.4206 ft3/ft x (1685' - 120') x 3.50 (250% excess) = 2303.8 ft3 0.4206 ft3/ft x (3200' - 1685') x 1.35 (35% excess) = 860.2 ft3 122.3 ft3 + 2303.8 ft3+ 860.2 ft3 = 3286.3 ft3 3286.3 ft3! 4.45 ft3/sk = 738.5 sks Round up to 740 sks Have 320 sks of additional Lead on location for Top Dut stage, if necessary. Tail Slurry Minimum pump time: 200 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (4000' - 3200') x 1.35 (35% excess) = 454.2 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 67.3 ft3 454.2 ft3 + 67.3 ft3 = 521.5 ft3 521.5 ft3/ 2.47 ft3/sk = 211.1 sks Round up to 220 sks BHST = 48°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time Ibbl) (min) < Top of Tail at 3,200' MD < 13 3/8", 68.0# casing in 16" OH TD at 4,000' MD (2,235' TVD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 585.3 83.6 116.9 DeepCRETE 6.0 92.9 15.5 132.4 Drop top plug 0.0 0.0 5.0 137.4 Water 5.0 20.0 4.0 141.4 Switch to rig 0.0 0.0 5.0 146.4 Mud 7.0 557. 79.7 226.1 Slow & bump plug 3.0 9.0 3.0 229.1 MUD REMOVAL Recommended Mud Properties: 9.7 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH'` II, Pv? 17-21, Ty ? 20-25 Centralizers: Recommend 2 per joint throughout tail slurry column EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 . 6000000 ~------- 5950000 I- ., 5900000 E----- 500000 600000 700000 f 800000 • ~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-184 -Slot 1J-184 1 J-184 Plan: 1J-184 (wp09) Proposal Report 12 March, 2006 ~~...~~ Sperry rtrillin+g Service ~~ ~~ ~~~ .~ ~ bn Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-184 Wellbore: 1 J-184 Plan: 1J-184 (wp09) WELL DETAILS: Plan 1J-184 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945342.40 558789.54 70°15'40.58N 149°31'29.15W 1J-184 SHL @ 1530ft FSL 8 2424ft FEL -Sec 35 - T11 N - 810 i KOP ~ 250ft MD, 250ft TVD - Build ~ 2..5°/100~t i i ~' Continue Build ~ 4°/100ft , 703ft MD, 700ft N i , i ,~ Sail LID 49° Inc : 1645ft MD, 1500ft N i i i 'Continue Build @ 5°/100ft , 1745ft MD, 1565tt TV i ' i ' ~ Sail ~ 76.45° Inc : 2377ft MD, 1854ft TV i , i i I~{,~4LL,tC3L.iF~7°C3f~l Sperry Drilling Services ~ i ~ Begin Drop ~ 4.6°/100ft to A2 Sand Base, 166508 MD, 3393ft ` -1000 i i i ~' i ~ ~ ~ BHL @ 17626ft MD, 3619ft TVD - 5 1/21' ' Base of Permatros~ ~' ~ ` i ~ 0 i ~~ T3 ~ . 20" Continue Build LID 3°/1008 , 8593ft MD, 3311ft TV `` ' ~' K15 0° i ~ i Sail ~ 80° Inc : 8742ft MD, 3342ft TV~ ~ ~ ~ i ~ ° ~ io° ° i i i ` c .i L 000 i , 20 ~ , gt) ~ ' Continue Build ~ 3°/100ft , 9155ft MD, 3413ft N 13 3/8" @ 3639ft MD, 2150ft TVq ~ ' ~ ' ~ ~ n i T3 + 550 p0 ~ i , ~ ~ ~ ~ ~- - -'T UGNU C-- -rO~~° i - ~ ~ 9 5l6" Casing @ 9254ft MD, 3428ft TV ` ~ ' ~ ,' i / " X2000 UGNU B . _. ~' - ~ _ f J r ~ T - ' - - _ ~ - ~ - -- ~ ' ~ ^ , ~ i r UGNU ~' ~ ~~ ~ 3000 - _. - .- ---- 1J -- -- 9) - - ~ i'-.. -. i-/ ---. _ ---iJ-184 L1(wP09-. °- _- -. - __.- ~ " -- -~_ ~ - °T C 4000 ~ K13 ` "" ~ ~~ ~~ 1J-184 T1 Dtop (wp09 ~ ~ ~~ ~ ~ 1J-184 T4 (wp09 ~~ ~~ ~ `~ ~~ ~ ~ West Sak ~ ~ `~ ~ ~ ~ ` ~ 1 J-184 T9 Toe (wp09 5000 ` West Sak C Sail ~ 95°Inc : 9322ft MD, 3435ft ~ ~ ~ . `\ ~ 1J-184 ( ~ \ ` T6 w ~ 0 ` 1 J"184 T2 (wp09 1J-184 T3 (wp09 ~ 1J-184 TB (wp09 ~ West Sak Continue Build ~ 3°/100ft , 9342ft MD, 3437ft TV 1J-184 T5 (wp09 1J-184 T7 (wp09 Continue GeoSteer in B-Sand 9515ft MD, 3444ft TV 6000 -2000 -1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 Vertical 5eclion al 180.00° (2000 ftlin) _1 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-184 Wellbore: 1 J-184 Plan: 1J-184 (wp09) c 0 0 0 L 1= Z O ConocoPhillips A43ska HAL-LIt3URTt71V SMRY DrilDny S~rvic~s 1J-184 T1 DtoP 1~9 1J-184 Geo-Poly (wp09) 1J-184 DD Poly @ 95% (wp09) DD Poly defines a corridor 100' ~ wide with allowable deviation ~ from plan of +/-50' E or W i I 1J-184 T2 (wp09 I I I I 1J-164 T3 (wp09 i 1J-184 T4 (wp09 - 1J-184 T5 (wp09 _ _ _ _ _ _ _ - I I 1J-184 T6 (wp06 _ _ _ _ _ i 1J-184 T7 (wp09 I I 1J-184 T6 (wp09 I '~_ I __ _1 Begin Drop X4.6°1100ft to A2 Sand Base,16850ft MD,3393ft i 1J-184 T9 Toe (wp09 - 7000 -6000 -5000 -4000 -3000 -2000 -1000 SHL ~ 1530ft FSL 8 2424ft FEL -Sec 35 • T11 N KOP ~ 250ft MD, 250ft TVD - Build ~ 2..5°/10 DW ;~ _ = =' _ - - - - - - - Continue Build ~ 4°/100R , 703ft MD, 700ft TV ~---------------------- Sail~49°Inc:1645ftMD,1500ftTV - - _ Continue Build ~ 5°/100ft , 1745ft MD, 1565ft TV Sail ~ 76.45° Inc : 2377ft MD, 1854ft TV 73 3/8" @ 3639ft MD, 2150ft TV 182° Continue Build ~ 3°/100ft , 8593ft MD, 3311ft TV Sail ~ 80° Inc : 8742ft MD, 3342ft TV 179, - Continue Build ~ 3°/100ft, 9155ft MD, 3413ft TV j„9,' ~ ' - - _ _ 'I ~ 9 5/8" Casing ~ 9254ft MD, 3428ft TV 179° I I _ _ _ ``~ ___-_ - - Sail ~ 85°Inc : 9322ft MD, 3435ft TV ` I I 179° I I '~ Continue Build @ 3°I100ft, 9342ft MD, 3437ft TV I I i Continue GeoSteer in B-Sand 9515ft MD, 3444ft TV m A f 0 e II 1(/9° BHL @ 17626ft MD, 3619ft TVD - 5 1/2' T Ni Azimuths to True North Magnetic North: 24.12° Magnetic Field Strength:57563.6nT Dip Angle: 80.77° Date: 4/15/2006 Model: BGGM2005 1000 2000 3000 4000 5000 6000 7000 ~-'" • Halliburton Energy Services ~ ~,~l..twll~luRT©N C4f'~OCtJ-Pf'll{~~"J~5 Planning Report -Geographic - -~-~~°~- Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-184 (28+g1) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+g1) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1 J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-184 Design: 1J-184 (wp09) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor _- _ _ __ _ _ Well Plan 1 J-184 -Slot 1 J-184 Well Position +N/-S 0.00 ft Northing: 5,945,342.40 ft ~ Latitude: 70° 15' 40.580" N +E/-W 0.00 ft Easting: 558,789.54 ft ~ Longitude: 149° 31' 29.150" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore Magnetics Design Audit Notes: Version: Vertical Section: 1 J-184 Model Name BGGM2005 1J-184 (wp09) Sample Date Declination Dip Angle (°) (°) 9/15/2003 25.1042 80.7383 3 Phase: PLAN Tie On Depth: Depth From (TVD) +N/-S +E/-W (ft) (ft) (ft) 28.00 0.00 0.00 Direction (°) 180.00 Field Strength (nT) 57,528 28.00 3/12/2006 11:33:51AM Page 2 of 11 `~~~~~ COMPASS 2003.11 Build 50 ` ~ ~ ~.- HaNiburton Energy Servic es HALLfBtJ(~T~f~V COI'14tQ~'11~~~JJ S Planning Report -Geographic - - --~ ~--- ~ Sperry Drliling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-184 Design: 1J-184 (wp09) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/.W Rate Rate Rate TFO (ft) ~~~ ~~~ (ft) (ft~ ~{~~ (°I100ft) (°I100ft) (°/100ft) (~~ 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.0000 250.00 0.00 0.00 250.00 0.00 0.00 0.00 0.00 0.00 0.0000 702.94 11.32 200.00 700.00 -41.92 -15.26 2.50 2.50 0.00 200.0000 1,645.17 49.01 200.00 1,500.00 -478.89 -174.30 4.00 4.00 0.00 0.0000 1,745.17 49.01 200.00 1,565.59 -549.83 -200.12 0.00 0.00 0.00 0.0000 2,377.35 76.45 182.00 1,854.35 -1,095.03 -294.88 5.00 4.34 -2.85 -34.9680 8,593.38 76.45 182.00 3,311.25 -7,134.23 -505.95 0.00 0.00 0.00 0.0000 8,742.24 80.00 179.24 3,341.64 -7,279.91 -507.51 3.00 2.39 -1.86 -37.5457 8,842.24 80.00 179.24 3,359.00 -7,378.39 -506.20 0.00 0.00 0.00 0.0000 9,155.24 80.00 179.24 3,413.35 -7,686.60 -502.11 0.00 0.00 0.00 0.0000 9,321.91 85.00 179.24 3,435.10 -7,851.78 -499.92 3.00 3.00 0.00 0.0000 9,341.91 85.00 179.24 3,436.84 -7,871.70 -499.66 0.00 0.00 0.00 0.0000 9,514.72 90.18 179.25 3,444.10 -8,044.28 -497.38 3.00 3.00 0.01 0.1140 9,839.88 90.18 179.25 3,443.05 -8,369.42 -493.13 0.00 0.00 0.00 0.0000 9,849.08 90.46 179.24 3,443.00 -8,378.62 -493.01 3.00 2.99 -0.11 -2.1429 9,855.02 90.40 179.24 3,442.96 -8,384.55 -492.93 1.00 -1.00 0.07 175.8485 10,849.42 90.40 179.24 3,436.00 -9,378.84 -479.82 0.00 0.00 0.00 0.0000 10,862.43 90.52 179.19 3,435.90 -9,391.85 -479.64 1.00 0.89 -0.45 -26.9324 11,848.80 90.52 179.19 3,427.00 -10,378.08 -465.61 0.00 0.00 0.00 0.0000 11,855.31 90.54 179.24 3,426.94 -10,384.59 -465.53 1.00 0.42 0.91 65.0749 13,849.52 90.54 179.24 3,408.00 -12,378.54 -439.23 0.00 0.00 0.00 0.0000 13,858.15 90.46 179.24 3,407.92 -12,387.17 -439.11 1.00 -1.00 0.00 -179.9360 14,849.87 90.46 179.24 3,400.00 -13,378.77 -426.03 0.00 0.00 0.00 0.0000 14,908.86 89.87 179.24 3,399.83 -13,437.76 -425.26 1.00 -1.00 0.00 -179.8796 15,849.19 89.87 179.24 3,402.00 -14,378.00 -412.83 0.00 0.00 0.00 0.0000 15,882.23 90.53 179.19 3,401.89 -14,411.04 -412.38 2.00 1.99 -0.17 -4.9450 16,849.57 90.53 179.19 3,393.00 -15,378.24 -398.64 0.00 0.00 0.00 0.0000 17,628.17 ' 55.18 183.03 3,619.00 ~ -16,110.24 -410.36 4.56 -4.54 0.49 174.5719 3/12/2006 11:33:51AM Page 3 of 11 COMPASS 2003.11 Build 50 ~~'rI~IAL ~ ' " Halliburton Energy Services HALt.IBt.3RTC~N C)t ~OCf}~ i1~~1~5 ~ Planning Report -Geographic - -. ~ ~- Sperry Drilling .~dl'YitC6rS Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparu k) ND Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1 J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-184 Design: 1J-184 (wp09) Planned Survey 1J-184 (wp09) MD Inclination Azimuth ND SSND (ft) (°) (°) Ift) tft) 28.00 0.00 0.00 28.00 -81.00 SHL @ 1530ft FSL & 2424ft FEL - Sec 35 - T11 N - R10E 100.00 0.00 0.00 100.00 -9.00 120.00 0.00 0.00 120.00 11.00 20" 200.00 0.00 0.00 200.00 91.00 250.00 0.00 0.00 250.00 141.00 KOP @ 250ft MD, 250ft ND -Buil d @ 2..5°/100ft 300.00 1.25 200.00 300.00 191.00 400.00 3.75 200.00 399.89 290.89 500.00 6.25 200.00 499.50 390.50 600.00 8.75 200.00 598.64 489.64 700.00 11.25 200.00 697.11 588.11 702.94 11.32 200.00 700.00 591.00 Continue Build @ 4°/1 00ft , 703ft MD, 700ft ND 800.00 15.21 200.00 794.45 685.45 900.00 19.21 200.00 889.96 780.96 1,000.00 23.21 200.00 983.16 874.16 1,100.00 27.21 200.00 1,073.62 964.62 1,200.00 31.21 200.00 1,160.89 1,051.89 1,300.00 35.21 200.00 1,244.55 1,135.55 1,400.00 39.21 200.00 1,324.18 1,215.18 1,500.00 43.21 200.00 1,399.40 1,290.40 1,600.00 47.21 200.00 1,469.84 1,360.84 1,645.17 49.01 200.00 1,500.00 1,391.00 Sail @ 49° Inc : 1645ft MD, 1500ft ND 1,684.81 49.01 200.00 1,526.00 1,417.00 Base of Permafrost 1,700.00 49.01 200.00 1,535.96 1,426.96 1,745.17 49.01 200.00 1,565.59 1,456.59 Continue Build @ 5°/100ft , 1745ft MD, 1555ft ND 1,800.00 51.28 197.99 1,600.73 1,491.73 1,854.56 53.56 196.11 1,634.00 1,525.00 T3 Map Map +N!_S +E!-W Northing Easting DLSEV Vert Section (ft) (ft) tft) (ft) (°/100ft) (ft) 0.00 0.00 5,945,342.40 558,789.54 0.00 0.00 0.00 0.00 5,945,342.40 558,789.54 0.00 0.00 0.00 0.00 5,945,342.40 558,789.54 0.00 0.00 0.00 0.00 5,945,342.40 558,789.54 0.00 0.00 0.00 0.00 5,945,342.40 558,789.54 0.00 0.00 -0.51 -0.19 5,945,341.89 558,789.36 2.50 0.51 -4.61 -1.68 5,945,337.78 558,787.90 2.50 4.61 -12.80 -4.66 5,945,329.57 558,784.98 2.50 12.80 -25.06 -9.12 5,945,317.27 558,780.61 2.50 25.06 -41.38 -15.06 5,945,300.91 558,774.80 2.50 41.38 -41.92 -15.26 5,945,300.37 558,774.61 2.50 41.92 -62.85 -22.87 5,945,279.39 558,767.16 4.00 62.85 -90.64 -32.99 5,945,251.52 558,757.26 4.00 90.64 -124.62 -45.36 5,945,217.45 558,745.16 4.00 124.62 -164.63 -59.92 5,945,177.33 558,730.91 4.00 164.63 -210.47 -76.61 5,945,131.36 558,714.59 4.00 210.47 -261.93 -95.33 5,945,079.77 558,696.26 4.00 261.93 -318.73 -116.01 5,945,022.80 558,676.03 4.00 318.73 -380.63 -138.54 5,944,960.74 558,653.99 4.00 380.63 -447.30 -162.80 5,944,893.89 558,630.25 4.00 447.30 -478.89 -174.30 5,944,862.21 558,619.00 4.00 478.89 -507.01 -184.54 5,944,834.01 558,608.98 0.00 507.01 -517.79 -188.46 5,944,823.21 558,605.15 0.00 517.79 -549.83 -200.12 5,944,791.08 558,593.74 0.00 549.83 -589.62 -213.81 5,944,751.19 558,580.36 5.00 589.62 -630.96 -226.47 5,944,709.76 558,568.03 5.00 630.96 1,900.00 55.49 194.62 1,660.37 1,551.37 -666.64 -236.27 5,944,674.00 558,558.51 5.00 666.64 2,000.00 59.78 191.59 1,713.90 1,604.90 -748.88 -255.36 5,944,591.62 558,540.06 5.00 748.88 2,100.00 64.14 188.81 1,760.91 1,651.91 -835.72 -270.94 5,944,504.67 558,525.16 5.00 835.72 2,200.00 68.54 186.23 1,801.03 1,692.03 -926.50 -282.89 5,944,413.81 558,513.92 5.00 926.50 2,300.00 72.99 183.80 1,833.97 1,724.97 -1,020.53 -291.11 5,944,319.73 558,506.43 5.00 1,020.53 2,377.35 76.45 182.00 1,854.35 1,745.35 -1,095.03 -294.88 5,944,245.21 558,503.25 5.00 1,095.03 Sail @ 76.45° Inc : 2377ft MD, 1854ft ND 2,400.00 76.45 182.00 1,859.66 1,750.66 -1,117.04 -295.65 5,944,223.20 558,502.65 0.00 1,117.04 2,500.00 76.45 182.00 1,883.10 1,774.10 -1,214.20 -299.04 5,944,126.03 558,500.02 0.00 1,214.20 2,600.00 76.45 182.00 1,906.54 1,797.54 -1,311.35 -302.44 5,944,028.86 558,497.38 0.00 1,311.35 2,700.00 76.45 182.00 1,929.98 1,820.98 -1,408.51 -305.83 5,943,931.69 558,494.74 0.00 1,408.51 3/12/2006 11:33:51AM Page 4 of 11 COMPASS 2003.11 Build 50 .._. '' • ~ ~ ~ Halliburton Energy Servic es HAt.t~.tBURTCIN CQl1QCC? PI1l~rl~}S Planning Report -Geographic ~~~~~ Alaska ~ g~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: 1J-184 (28+g1) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+g1) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Welt: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-184 Design: 1J-184 (wp09) Planned Survey 1J-184 (wp09) ~ ' Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) {ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 2,768.37 76.45 182.00 1,946.00 1,837.00 -1,474.93 -308.15 5,943,865.26 558,492.94 0.00 1,474.93 K15 2,800.00 76.45 182.00 1,953.41 1,844.41 -1,505.66 -309.23 5,943,834.52 558,492.10 0.00 1,505.66 2,900.00 76.45 182.00 1,976.85 1,867.85 -1,602.82 -312.62 5,943,737.35 558,489.47 0.00 1,602.82 3,000.00 76.45 182.00 2,000.29 1,891.29 -1,699.97 -316.02 5,943,640.18 558,486.83 0.00 1,699.97 3,100.00 76.45 182.00 2,023.73 1,914.73 -1,797.13 -319.42 5,943,543.01 558,484.19 0.00 1,797.13 3,200.00 76.45 182.00 2,047.17 1,938.17 -1,894.28 -322.81 5,943,445.84 558,481.56 0.00 1,894.28 3,300.00 76.45 182.00 2,070.60 1,961.60 -1,991.44 -326.21 5,943,348.67 558,478.92 0.00 1,991.44 3,400.00 76.45 182.00 2,094.04 1,985.04 -2,088.59 -329.60 5,943,251.50 558,476.28 0.00 2,088.59 3,500.00 76.45 182.00 2,117.48 2,008.48 -2,185.75 -333.00 5,943,154.33 558,473.65 0.00 2,185.75 3,600.00 76.45 182.00 2,140.92 2,031.92 -2,282.90 -336.39 5,943,057.16 558,471.01 0.00 2,282.90 3,638.76 76.45 182.00 2,150.00 2,041.00 -2,320.56 -337.71 5,943,019.50 558,469.99 0.00 2,320.56 13 318" @ 3639ft MD, 2150ft TVD - 4489ft FSL & 2764ft FEL -Sec 2 - T10N - R10E - T3 + 550 - 13 3/8" - 3,700.00 76.45 182.00 2,164.35 2,055.35 -2,380.06 -339.79 5,942,959.99 558,468.37 0.00 2,380.06 3,800.00 76.45 182.00 2,187.79 2,078.79 -2,477.21 -343.18 5,942,862.82 558,465.74 0.00 2,477.21 3,900.00 76.45 182.00 2,211.23 2,102.23 -2,574.37 -346.58 5,942,765.65 558,463.10 0.00 2,574.37 4,000.00 76.45 182.00 2,234.67 2,125.67 -2,671.53 -349.98 5,942,668.48 558,460.46 0.00 2,671.53 4,100.00 76.45 182.00 2,258.10 2,149.10 -2,768.68 -353.37 5,942,571.31 558,457.83 0.00 2,768.68 4,200.00 76.45 182.00 2,281.54 2,172.54 -2,865.84 -356.77 5,942,474.15 558,455.19 0.00 2,865.84 4,300.00 76.45 182.00 2,304.98 2,195.98 -2,962.99 -360.16 5,942,376.98 558,452.55 0.00 2,962.99 4,400.00 76.45 182.00 2,328.42 2,219.42 -3,060.15 -363.56 5,942,279.81 558,449.92 0.00 3,060.15 4,500.00 76.45 182.00 2,351.86 2,242.86 -3,157.30 -366.95 5,942,182.64 558,447.28 0.00 3,157.30 4,600.00 76.45 182.00 2,375.29 2,266.29 -3,254.46 -370.35 5,942,085.47 558,444.64 0.00 3,254.46 4,700.00 76.45 182.00 2,398.73 2,289.73 -3,351.61 -373.75 5,941,988.30 558,442.01 0.00 3,351.61 4,800.00 76.45 182.00 2,422.17 2,313.17 -3,448.77 -377.14 5,941,891.13 558,439.37 0.00 3,448.77 4,900.00 76.45 182.00 2,445.61 2,336.61 -3,545.92 -380.54 5,941,793.96 558,436.73 0.00 3,545.92 5,000.00 76.45 182.00 2,469.04 2,360.04 -3,643.08 -383.93 5,941,696.79 558,434.09 0.00 3,643.08 5,100.00 76.45 182.00 2,492.48 2,383.48 -3,740.23 -387.33 5,941,599.62 558,431.46 0.00 3,740.23 5,200.00 76.45 182.00 2,515.92 2,406.92 -3,837.39 -390.72 5,941,502.45 558,428.82 0.00 3,837.39 5,300.00 76.45 182.00 2,539.36 2,430.36 -3,934.54 -394.12 5,941,405.28 558,426.18 0.00 3,934.54 5,400.00 76.45 182.00 2,562.80 2,453.80 -4,031.70 -397.52 5,941,308.11 558,423.55 0.00 4,031.70 5,500.00 76.45 182.00 2,586.23 2,477.23 -4,128.85 -400.91 5,941,210.94 558,420.91 0.00 4,128.85 5,600.00 76.45 182.00 2,609.67 2,500.67 -4,226.01 -404.31 5,941,113.77 558,418.27 0.00 4,226.01 5,700.00 76.45 182.00 2,633.11 2,524.11 -4,323.16 -407.70 5,941,016.60 558,415.64 0.00 4,323.16 5,800.00 76.45 182.00 2,656.55 2,547.55 -4,420.32 -411.10 5,940,919.43 558,413.00 0.00 4,420.32 5,900.00 76.45 182.00 2,679.98 2,570.98 -4,517.48 -414.49 5,940,822.26 558,410.36 0.00 4,517.48 6,000.00 76.45 182.00 2,703.42 2,594.42 -4,614.63 -417.89 5,940,725.09 558,407.73 0.00 4,614.63 6,100.00 76.45 182.00 2,726.86 2,617.86 -4,711.79 -421.29 5,940,627.93 558,405.09 0.00 4,711.79 6,200.00 76.45 182.00 2,750.30 2,641.30 -4,808.94 -424.68 5,940,530.76 558,402.45 0.00 4,808.94 6,245.67 76.45 182.00 2,761.00 2,652.00 -4,853.31 -426.23 5,940,486.38 558,401.25 0.00 4,853.31 UGNU C 6,300.00 76.45 182.00 2,773.73 2,664.73 -4,906.10 -428.08 5,940,433.59 558,399.82 0.00 4,906.10 6,400.00 76.45 182.00 2,797.17 2,688.17 -5,003.25 -431.47 5,940,336.42 558,397.18 0.00 5,003.25 6,500.00 76.45 182.00 2,820.61 2,711.61 -5,100.41 -434.87 5,940,239.25 558,394.54 0.00 5,100.41 6,600.00 76.45 182.00 2,844.05 2,735.05 -5,197.56 -438.26 5,940,142.08 558,391.91 0.00 5,197.56 6,700.00 76.45 182.00 2,867.49 2,758.49 -5,294.72 -441.66 5,940,044.91 558,389.27 0.00 5,294.72 6,800.00 76.45 182.00 2,890.92 2,781.92 -5,391.87 -445.06 5,939,947.74 558,386.63 0.00 5,391.87 6,900.00 76.45 182.00 2,914.36 2,805.36 -5,489.03 -448.45 5,939,850.57 558,384.00 0.00 5,489.03 7,000.00 76.45 182.00 2,937.80 2,828.80 -5,586.18 -451.85 5,939,753.40 558,381.36 0.00 5,586.18 3/12/2006 11:33:51AM Page 5 of 11 COMPASS 2003.11 Build 50 ,~P'`~~I ~,.-' ~ Halliburton Energy Services • C41'tt)COPh111t~3s Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-184 Wellbore: 1 J-184 Design: 1J-184 (wp09) Planned Survey 1J-184 (wp09) ~aL~reuaT~nr Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) North Reference: True Survey Calculation Method: Minimum Curvature MD Inclination Azimuth TVD SSTVD +N/-S (ft) (°) (°) (ft) (ftl (ft) 7,100.00 76.45 182.00 2,961.24 2,852.24 -5,683.34 7,188.59 76.45 182.00 2,982.00 2,873.00 -5,769.41 UGNU B 7,200.00 76.45 182.00 2,984.67 2,875.67 -5,780.49 7,300.00 76.45 182.00 3,008.11 2,899.11 -5,877.65 7,400.00 76.45 182.00 3,031.55 2,922.55 -5,974.80 7,470.19 76.45 182.00 3,048.00 2,939.00 -6,042.99 UGNU A 7,500.00 76.45 182.00 3,054.99 2,945.99 -6,071.96 7,600.00 76.45 182.00 3,078.43 2,969.43 -6,169.11 7,700.00 76.45 182.00 3,101.86 2,992.86 -6,266.27 7,800.00 76.45 182.00 3,125.30 3,016.30 -6,363.42 7,900.00 76.45 182.00 3,148.74 3,039.74 -6,460.58 8,000.00 76.45 182.00 3,172.18 3,063.18 -6,557.74 8,100.00 76.45 182.00 3,195.61 3,086.61 -6,654.89 8,114.45 76.45 182.00 3,199.00 3,090.00 -6,668.93 K13 8,200.00 76.45 182.00 3,219.05 3,110.05 -6,752.05 8,300.00 76.45 182.00 3,242.49 3,133.49 -6,849.20 8,400.00 76.45 182.00 3,265.93 3,156.93 -6,946.36 8,500.00 76.45 182.00 3,289.36 3,180.36 -7,043.51 8,593.38 76.45 182.00 3,311.25 3,202.25 -7,134.23 Continue Bu ild @ 3°/100ft , 8593ft MD, 3311ft TVD 8,600.00 76.60 181.88 3,312.79 3,203.79 -7,140.67 8,700.00 78.99 180.02 3,333.93 3,224.93 -7,238.38 8,742.24 80.00 179.24 3,341.64 3,232.64 -7,279.91 Sail @ 80° In c : 8742ft MD, 3342ft TVD 8,773.13 80.00 179.24 3,347.00 3,238.00 -7,310.34 West Sak D 8,800.00 80.00 179.24 3,351.67 3,242.67 -7,336.79 8,842.24 80.00 179.24 3,359.00 3,250.00 -7,378.39 1J-184 T1 Dtop (wp09) Map Map +Ei_W Northing Easting DLSEV Vert Section (ft) (ft) (ft) (°/100ft) (ft) -455.24 5,939,656.23 558,378.72 0.00 5,683.34 -458.25 5,939,570.15 558,376.39 0.00 5,769.41 -458.64 5,939,559.06 558,376.08 0.00 5,780.49 -462.03 5,939,461.89 558,373.45 0.00 5,877.65 -465.43 5,939,364.72 558,370.81 0.00 5,974.80 -467.81 5,939,296.52 558,368.96 0.00 6,042.99 -468.83 5,939,267.55 558,368.17 0.00 6,071.96 -472.22 5,939,170.38 558,365.54 0.00 6,169.11 -475.62 5,939,073.21 558,362.90 0.00 6,266.27 -479.01 5,938,976.04 558,360.26 0.00 6,363.42 -482.41 5,938,878.88 558,357.63 0.00 6,460.58 -485.80 5,938,781.71 558,354.99 0.00 6,557.74 -489.20 5,938,684.54 558,352.35 0.00 6,654.89 -489.69 5,938,670.50 558,351.97 0.00 6,668.93 -492.60 5,938,587.37 558,349.72 0.00 6,752.05 -495.99 5,938,490.20 558,347.08 0.00 6,849.20 -499.39 5,938,393.03 558,344.44 0.00 6,946.36 -502.78 5,938,295.86 558,341.81 0.00 7,043.51 -505.95 5,938,205.13 558,339.34 0.00 7,134.23 -506.17 5,938,198.69 558,339.18 2.98 7,140.67 -507.78 5,938,100.97 558,338.33 3.00 7,238.38 -507.51 5,938,059.45 558,338.93 3.00 7,279.91 -507.11 5,938,029.03 558,339.57 0.00 7,310.34 -506.75 5,938,002.58 558,340.12 0.00 7,336.79 -506.20 5,937,961.00 558,341.00 0.00 7,378.39 8,899.83 80.00 179.24 3,369.00 3,260.00 -7,435.09 -505.45 5,937,904.31 558,342.19 0.00 7,435.09 8,900.00 80.00 179.24 3,369.03 3,260.03 -7,435.26 -505.45 5,937,904.13 558,342.20 0.00 7,435.26 9,000.00 80.00 179.24 3,386.39 3,277.39 -7,533.74 -504.14 5,937,805.69 558,344.27 0.00 7,533.74 9,100.00 80.00 179.24 3,403.76 3,294.76 -7,632.21 -502.84 5,937,707.24 558,346.35 0.00 7,632.21 9,112.90 80.00 179.24 3,406.00 3,297.00 -7,644.91 -502.67 5,937,694.53 558,346.62 0.00 7,644.91 West Sak C 9,155.24 80.00 179.24 3,413.35 3,304.35 -7,686.60 -502.11 5,937,652.85 558,347.49 0.00 7,686.60 Continue Bu ild @ 3°i100ft , 9155ft MD, 3413ft TVD 9,200.00 81.34 179.24 3,420.61 3,311.61 -7,730.77 -501.53 5,937,608.70 558,348.42 3.00 7,730.77 9,254.17 82.97 179.24 3,428.00 3,319.00 -7,784.42 -500.82 5,937,555.06 558,349.56 3.00 7,784.42 9 5/8" Casing atrD 9254ft MD, 3428ft TVD, 4305ft FSL & 2933 ft FEL. Sect 11 - T10N - R10E -West Sak B - 9 5/8" ~ 3/12/2006 11:33:51AM Page 6 of 11 ~, ; ~,.~. COMPASS 2003.11 Build 50 ' ~ • ~- , Halliburton Energy Servic es Hp,LE 1BtlRTC1N ~OC1E3C©~1f~~1~35 Planning Report -Geographic ~ - ~- ~ Sperry Drefling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-184 Design: 1J-184 (wp09) Planned Survey 1J-184 (wp09) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/.W Northing Easting pLSEV Vert Section Ift) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 9,300.00 84.34 179.24 3,433.07 3,324.07 -7,829.97 -500.21 5,937,509.52 558,350.51 3.00 7,829.97 9,321.91 85.00 179.24 3,435.10 3,326.10 -7,851.78 -499.92 5,937,487.72 558,350.97 3.01 7,851.78 Sail @ 85°Inc : 9322ft MD, 3435ft TVD 9,341.91 85.00 179.24 3,436.84 3,327.84 -7,871.70 -499.66 5,937,467.80 558,351.39 0.00 7,871.70 Continue Build @ 3°/100ft , 9342ft MD, 3437ft TVD 9,400.00 86.74 179.24 3,441.02 3,332.02 -7,929.64 -498.89 5,937,409.88 558,352.61 3.00 7,929.64 9,500.00 89.74 179.25 3,444.09 3,335.09 -8,029.57 -497.58 5,937,309.97 558,354.71 3.00 8,029.57 9,514.72 90.18 179.25 3,444.10 3,335.10 -8,044.28 -497.38 5,937,295.26 558,355.01 3.01 8,044.28 Continue GeoSteer in B-Sand 9515ft MD, 3444ft ND 9,600.00 90.18 179.25 3,443.82 3,334.82 -8,129.56 -496.27 5,937,210.00 558,356.80 0.00 8,129.56 9,700.00 90.18 179.25 3,443.50 3,334.50 -8,229.55 -494.96 5,937,110.03 558,358.89 0.00 8,229.55 9,800.00 90.18 179.25 3,443.18 3,334.18 -8,329.54 -493.65 5,937,010.06 558,360.97 0.00 8,329.54 9,839.88 90.18 179.25 3,443.05 3,334.05 -8,369.42 -493.13 5,936,970.19 558,361.81 0.00 8,369.42 9,849.08 90.46 179.24 3,443.00 3,334.00 -8,378.62 -493.01 5,936,961.00 558,362.00 3.00 8,378.62 1J-184 T2 (wp09) 9,855.02 90.40 179.24 3,442.96 3,333.96 -8,384.55 -492.93 5,936,955.06 558,362.12 1.00 8,384.55 9,900.00 90.40 179.24 3,442.64 3,333.64 -8,429.53 -492.34 5,936,910.10 558,363.07 0.00 8,429.53 10,000.00 90.40 179.24 3,441.94 3,332.94 -8,529.52 -491.02 5,936,810.13 558,365.17 0.00 8,529.52 10,100.00 90.40 179.24 3,441.24 3,332.24 -8,629.51 -489.70 5,936,710.16 558,367.27 0.00 8,629.51 10,200.00 90.40 179.24 3,440.54 3,331.54 -8,729.50 -488.38 5,936,610.20 558,369.37 0.00 8,729.50 10,300.00 90.40 179.24 3,439.84 3,330.84 -8,829.49 -487.06 5,936,510.23 558,371.47 0.00 8,829.49 10,400.00 90.40 179.24 3,439.14 3,330.14 -8,929.48 -485.74 5,936,410.27 558,373.57 0.00 8,929.48 10,500.00 90.40 179.24 3,438.44 3,329.44 -9,029.46 -484.42 5,936,310.30 558,375.66 0.00 9,029.46 10,600.00 90.40 179.24 3,437.74 3,328.74 -9,129.45 -483.11 5,936,210.33 558,377.76 0.00 9,129.45 10,700.00 90.40 179.24 3,437.05 3,328.05 -9,229.44 -481.79 5,936,110.37 558,379.86 0.00 9,229.44 10,800.00 90.40 179.24 3,436.35 3,327.35 -9,329.43 -480.47 5,936,010.40 558,381.96 0.00 9,329.43 10,849.42 90.40 179.24 3,436.00 3,327.00 -9,378.84 -479.82 5,935,961.00 558,383.00 0.00 9,378.84 1 J-184 T3 (wp09) 10,862.43 90.52 179.19 3,435.90 3,326.90 -9,391.85 -479.64 5,935,948.00 558,383.28 1.00 9,391.85 10,900.00 90.52 179.19 3,435.56 3,326.56 -9,429.42 -479.10 5,935,910.44 558,384.11 0.00 9,429.42 11,000.00 90.52 179.19 3,434.66 3,325.66 -9,529.40 -477.68 5,935,810.48 558,386.31 0.00 9,529.40 11,100.00 90.52 179.19 3,433.75 3,324.75 -9,629.39 -476.26 5,935,710.51 558,388.51 0.00 9,629.39 11,200.00 90.52 179.19 3,432.85 3,323.85 -9,729.38 -474.84 5,935,610.55 558,390.71 0.00 9,729.38 11,300.00 90.52 179.19 3,431.95 3,322.95 -9,829.36 -473.42 5,935,510.59 558,392.92 0.00 9,829.36 11,400.00 90.52 179.19 3,431.05 3,322.05 -9,929.35 -471.99 5,935,410.63 558,395.12 0.00 9,929.35 11,500.00 90.52 179.19 3,430.15 3,321.15 -10,029.33 -470.57 5,935,310.67 558,397.32 0.00 10,029.33 11,600.00 90.52 179.19 3,429.24 3,320.24 -10,129.32 -469.15 5,935,210.70 558,399.52 0.00 10,129.32 11,700.00 90.52 179.19 3,428.34 3,319.34 -10,229.30 -467.73 5,935,110.74 558,401.72 0.00 10,229.30 11,800.00 90.52 179.19 3,427.44 3,318.44 -10,329.29 -466.31 5,935,010.78 558,403.93 0.00 10,329.29 11,848.80 90.52 179.19 3,427.00 3,318.00 -10,378.08 -465.61 5,934,962.00 558,405.00 0.00 10,378.08 1 J-184 T4 (wp09) 11,855.31 90.54 179.24 3,426.94 3,317.94 -10,384.59 -465.53 5,934,955.50 558,405.14 1.00 10,384.59 11,900.00 90.54 179.24 3,426.52 3,317.52 -10,429.28 -464.94 5,934,910.82 558,406.08 0.00 10,429.28 12,000.00 90.54 179.24 3,425.57 3,316.57 -10,529.26 -463.62 5,934,810.85 558,408.18 0.00 10,529.26 12,100.00 90.54 179.24 3,424.62 3,315.62 -10,629.25 -462.30 5,934,710.89 558,410.28 0.00 10,629.25 12,200.00 90.54 179.24 3,423.67 3,314.67 -10,729.24 -460.98 5,934,610.93 558,412.38 0.00 10,729.24 12,300.00 90.54 179.24 3,422.72 3,313.72 -10,829.22 -459.66 5,934,510.96 558,414.47 0.00 10,829.22 3/12/2006 11:33:51AM Page 7 of 11 COMPASS 2003.11 Build 50 E ~-' • Halliburton Energy Services • HAILLtBUR~oN Cono~oP~itl~~35s~ Planning Report -Geographic ----~~-- Sperry ttirilitr~g Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature WeBbore: 1 J-184 Design: 1J-184 (wp09) Planned Survey 1 J-184 (wp09) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 12,400.00 90.54 179.24 3,421.77 3,312.77 -10,929.21 -458.34 5,934,411.00 558,416.57 0.00 10,929.21 12,500.00 90.54 179.24 3,420.82 3,311.82 -11,029.20 -457.02 5,934,311.03 558,418.67 0.00 11,029.20 12,600.00 90.54 179.24 3,419.87 3,310.87 -11,129.18 -455.70 5,934,211.07 558,420.77 0.00 11,129.18 12,700.00 90.54 179.24 3,418.92 3,309.92 -11,229.17 -454.39 5,934,111.11 558,422.87 0.00 11,229.17 12,800.00 90.54 179.24 3,417.97 3,308.97 -11,329.16 -453.07 5,934,011.14 558,424.97 0.00 11,329.16 12,900.00 90.54 179.24 3,417.02 3,308.02 -11,429.14 -451.75 5,933,911.18 558,427.07 0.00 11,429.14 13,000.00 90.54 179.24 3,416.07 3,307.07 -11,529.13 -450.43 5,933,811.21 558,429.17 0.00 11,529.13 13,100.00 90.54 179.24 3,415.12 3,306.12 -11,629.12 -449.11 5,933,711.25 558,431.27 0.00 11,629.12 13,200.00 90.54 179.24 3,414.17 3,305.17 -11,729.11 -447.79 5,933,611.29 558,433.37 0.00 11,729.11 13,300.00 90.54 179.24 3,413.22 3,304.22 -11,829.09 -446.47 5,933,511.32 558,435.47 0.00 11,829.09 13,400.00 90.54 179.24 3,412.27 3,303.27 -11,929.08 -445.16 5,933,411.36 558,437.56 0.00 11,929.08 13,500.00 90.54 179.24 3,411.32 3,302.32 -12,029.07 -443.84 5,933,311.40 558,439.66 0.00 12,029.07 13,600.00 90.54 179.24 3,410.37 3,301.37 -12,129.05 -442.52 5,933,211.43 558,441.76 0.00 12,129.05 13,700.00 90.54 179.24 3,409.42 3,300.42 -12,229.04 -441.20 5,933,111.47 558,443.86 0.00 12,229.04 13,800.00 90.54 179.24 3,408.47 3,299.47 -12,329.03 -439.88 5,933,011.50 558,445.96 0.00 12,329.03 13,849.52 90.54 179.24 3,408.00 3,299.00 -12,378.54 -439.23 5,932,962.00 558,447.00 0.00 12,378.54 1J-184 T5 (wp09) 13,858.15 90.46 179.24 3,407.92 3,298.92 -12,387.17 -439.11 5,932,953.37 558,447.18 1.00 12,387.17 13,900.00 90.46 179.24 3,407.59 3,298.59 -12,429.01 -438.56 5,932,911 .54 558,448.06 0.00 12,429.01 14,000.00 90.46 179.24 3,406.79 3,297.79 -12,529.00 -437.24 5,932,811 .57 558,450.16 0.00 12,529.00 14,100.00 90.46 179.24 3,405.99 3,296.99 -12,628.99 -435.92 5,932,711 .61 558,452.26 0.00 12,628.99 14,200.00 90.46 179.24 3,405.19 3,296.19 -12,728.98 -434.61 5,932,611 .64 558,454.36 0.00 12,728.98 14,300.00 90.46 179.24 3,404.39 3,295.39 -12,828.97 -433.29 5,932,511 .68 558,456.46 0.00 12,828.97 14,400.00 90.46 179.24 3,403.59 3,294.59 -12,928.95 -431.97 5,932,411 .71 558,458.56 0.00 12,928.95 14,500.00 90.46 179.24 3,402.80 3,293.80 -13,028.94 -430.65 5,932,311 .75 558,460.66 0.00 13,028.94 14,600.00 90.46 179.24 3,402.00 3,293.00 -13,128.93 -429.33 5,932,211 .78 558,462.75 0.00 13,128.93 14,700.00 90.46 179.24 3,401.20 3,292.20 -13,228.92 -428.01 5,932,111 .82 558,464.85 0.00 13,228.92 14,800.00 90.46 179.24 3,400.40 3,291.40 -13,328.91 -426.69 5,932,011 .85 558,466.95 0.00 13,328.91 14,849.87 90.46 179.24 3,400.00 3,291.00 -13,378.77 -426.03 5,931,962 .00 558,468.00 0.00 13,378.77 1J-184 T6 (wp06) 14,900.00 89.96 179.24 3,399.82 3,290.82 -13,428.90 -425.37 5,931,911.89 558,469.05 1.00 13,428.90 14,908.86 89.87 179.24 3,399.83 3,290.83 -13,437.76 -425.26 5,931,903.03 558,469.24 1.00 13,437.76 15,000.00 89.87 179.24 3,400.04 3,291.04 -13,528.89 -424.05 5,931,811.92 558,471.15 0.00 13,528.89 15,100.00 89.87 179.24 3,400.27 3,291.27 -13,628.88 -422.73 5,931,711.95 558,473.26 0.00 13,628.88 15,200.00 89.87 179.24 3,400.50 3,291.50 -13,728.87 -421.41 5,931,611.98 558,475.36 0.00 13,728.87 15,300.00 89.87 179.24 3,400.73 3,291.73 -13,828.86 -420.09 5,931,512.01 558,477.46 0.00 13,828.86 15,400.00 89.87 179.24 3,400.96 3,291.96 -13,928.85 -418.77 5,931,412.05 558,479.56 0.00 13,928.85 15,500.00 89.87 179.24 3,401.20 3,292.20 -14,028.84 -417.45 5,931,312.08 558.,481.66 0.00 14,028.84 15,600.00 89.87 179.24 3,401.43 3,292.43 -14,128.83 -416.12 5,931,212.11 558,483.76 0.00 14,128.83 15,700.00 89.87 179.24 3,401.66 3,292.66 -14,228.82 -414.80 5,931,112.14 558,485.86 0.00 14,228.82 15,800.00 89.87 179.24 3,401.89 3,292.89 -14,328.81 -413.48 5,931,012.17 558,487.97 0.00 14,328.81 15,849.19 89.87 179.24 3,402.00 3,293.00 -14,378.00 -412.83 5,930,963.00 558,489.00 0.00 14,378.00 1J-184 T7 (wp09) 15,882.23 90.53 179.19 3,401.89 3,292.89 -14,411.04 -412.38 5,930,929.97 558,489.71 2.00 14,411.04 15,900.00 90.53 179.19 3,401.72 3,292.72 -14,428.80 -412.13 5,930,912.21 558,490.10 0.00 14,428.80 16,000.00 90.53 179.19 3,400.80 3,291.80 -14,528.79 -410.71 5,930,812.25 558,492.30 0.00 14,528.79 16,100.00 90.53 179.19 3,399.89 3,290.89 -14,628.78 -409.29 5,930,712.28 558,494.50 0.00 14,628.78 16,200.00 90.53 179.19 3,398.97 3,289.97 -14,728.76 -407.87 5,930,612.32 558,496.70 0.00 14,728.76 16,300.00 90.53 179.19 3,398.05 3,289.05 -14,828.75 -406.45 5,930,512.36 558,498.91 0.00 14,828.75 3/12/2006 11:33:51AM Page 8 of 11 COMPASS 2003.11 Build 50 1~~~~~: A ~, a.._. • ~ ~r' Halliburton Energy Services H~o-4L~~3uRTt' ~a~«~1~~~ ~ Planning Report -Geographic _,~_~.__~_w._.._.._...._ Sperry Drtllfng Ssrv~es:~ Database: EDM 2003;11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-184 Design: 1J-184 (wp09) Planned Survey 1J-184 (wp09) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°- (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 16,400.00 90.53 179.19 3,397.13 3,288.13 -14,928.73 -405.03 5,930,412.40 558,501.11 0.00 14,928.73 16,500.00 90.53 179.19 3,396.21 3,287.21 -15,028.72 -403.60 5,930,312.44 558,503.31 0.00 15,028.72 16,600.00 90.53 179.19 3,395.29 3,286.29 -15,128.70 -402.18 5,930,212.47 558,505.51 0.00 15,128.70 16,700.00 90.53 179.19 3,394.37 3,285.37 -15,228.69 -400.76 5,930,112.51 558,507.71 0.00 15,228.69 16,800.00 90.53 179.19 3,393.46 3,284.46 -15,328.68 -399.34 5,930,012.55 558,509.91 0.00 15,328.68 16,849.57 90.53 179.19 3,393.00 3,284.00 -15,378.24 -398.64 5,929,963.00 558,511.00 0.00 15,378.24 Begin Drop @ 4.6°/100ft to A2 Sa nd Base, 168 50ft MD, 3393ft TVD -1J-184 T8 (wp09) 16,900.00 88.24 179.40 3,393.54 3,284.54 -15,428.66 -398.02 5,929,912.59 558,512.01 4.56 15,428.66 17,000.00 83.70 179.84 3,400.58 3,291.58 -15,528.38 -397.36 5,929,812.88 558,513.45 4.56 15,528.38 17,100.00 79.15 180.28 3,415.49 3,306.49 -15,627.24 -397.46 5,929,714.04 558,514.13 4.56 15,627.24 17,200.00 74.61 180.73 3,438.19 3,329.19 -15,724.60 -398.31 5,929,616.69 558,514.03 4.56 15,724.60 17,300.00 70.07 181.21 3,468.52 3,359.52 -15,819.85 -399.93 5,929,521.44 558,513.16 4.56 15,819.85 17,400.00 65.53 181.71 3,506.29 3,397.29 -15,912.38 -402.28 5,929,428.90 558,511.53 4.56 15,912.38 17,500.00 61.00 182.26 3,551.27 3,442.27 -16,001.61 -405.37 5,929,339.66 558,509.14 4.56 16,001.61 17,600.00 56.46 182.85 3,603.18 3,494.18 -16,086.97 -409.16 5,929,254.28 558,506.01 4.56 16,086.97 17,628.17 55.18 183.03 3,619.00 3,510.00 -16,110.24 -410.36 5,929,231.00 558,505.00 4.57 16,110.24 BHL @ 17626ft MD, 3619ft TVD : 1260ft FSL & 2851ft FEL -Sec 14 - T10N - R10E - 51 /2" - 1J-184 T9 Toe (wp09) 3/12/2006 11:33:51AM Page 9 of 11 COMPASS 2003.11 Build 50 ~~~ ~~~~4 • ~ ~--' Halliburton Energy Services BURTON MA~l ~t}t'lt)CC?~"tf~~15 Planning Report -Geographic - ~----~~-~---~---~._.,~,_,~._,~__ Sp®rry Drilling Servlaes Database: EDM 2003.11. Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPfiillips Alaska (Kuparuk} TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-184 Design: 1J-184 (wp09) Geologic Targets 1J-184 TVD Target Name +N/-S +El-W Northing Easting ', (ft) -Shape ft ft (ft) (ft) 3,443.00 1J-184 T2 (wp09) -8,378.62 -493.01 5,936,961.00 558,362.00 - Point 3,408.00 1J-184 T5 (wp09) -12,378.54 -439.23 5,932,962.00 558,447.00 - Point 3,619.00 1J-184 T9 Toe (wp09) -16,110.24 -410.36 5,929,231.00 558,505.00 - Point 3,400.00 1J-184 T6 (wp06) -13,378.77 -426.03 5,931,962.00 558,468.00 - Point 3,427.00 1J-184 T4 (wp09) -10,378.08 -465.61 5,934,962.00 558,405.00 - Point 3,359.00 1J-184 T1 Dtop (wp09) -7,378.39 -506.20 5,937,961.00 558,341.00 - Point 3,393.00 1J-184 T8 (wp09) -15,378.24 -398.64 5,929,963.00 558,511.00 - Point 3,369.00 1J-184 Geo-Poly (wp09) -7,378.39 -506.20 5,937,961.00 558,341.00 - Polygon Point 1 -121.01 0.94 5,937,961.00 558,220.00 Point 2 -120.01 -4,354.61 5,933,606.00 558,255.00 Point 3 -93.01 -7,942.28 5,930,019.00 558,310.00 Point 4 -98.17 -8,730.34 5,929,231.00 558,311.00 Point 5 290.86 -8,733.38 5,929,231.00 558,700.00 Point 6 306.85 -7,966.40 5,929,998.00 558,710.00 Point 7 238.05 -4,353.41 5,933,610.00 558,613.00 Point 8 119.01 -0.93 5,937,961.00 558,460.00 3,436.00 1J-184 T3 (wp09) -9,378.84 -479.82 5,935,961.00 558,383.00 - Point 3,359.00 1J-184 DD Poly @ 95% (wp09) -7,378.39 -506.20 5,937,961.00 558,341.00 - Polygon Point 1 -50.00 0.39 5,937,961.00 558,291.00 Point 2 -36.81 -999.84 5,936,961.00 558,312.00 Point 3 -23.62 -2,000.07 5,935,961.00 558,333.00 Point 4 -9.41 -2,999.31 5,934,962.00 558,355.00 Point 5 16.97 -4,999.77 5,932,962.00 558,397.00 Point 6 30.17 -5,999.99 5,931,962.00 558,418.00 Point 7 43.37 -6,999.22 5,930,963.00 558,439.00 Point 8 57.56 -7,999.46 5,929,963.00 558,461.00 Point 9 48.35 -8,410.44 5,929,552.00 558,455.00 Point 10 45.84 -8,731.46 5,929,231.00 558,455.00 Point 11 145.85 -8,732.24 5,929,231.00 558,555.00 " Point 12 148.36 -8,411.22 5,929,552.00 558,555.00 Point 13 157.57 -8,000.24 5,929,963.00 558,561.00 Point 14 143.37 -7,000.01 5,930,963.00 558,539.00 Point 15 130.17 -6,000.78 5,931,962.00 558,518.00 Point 16 116.98 -5,000.55 5,932,962.00 558,497.00 Point 17 90.59 -3,000.09 5,934,962.00 558,455.00 Point 18 76.39 -2,000.85 5,935,961.00 558,433.00 Point 19 63.20 -1,000.62 5,936,961.00 558,412.00 Point 20 50.00 -0.39 5,937,961.00 558,391.00 3,402.00 1J-184 T7 (wp09) -14,378.00 -412.83 5,930,963.00 558,489.00 3/12/2006 11:33:51AM Page 10 of 11 COMPASS 2003.11 Build 50 Y" ~ Halliburton Energy Services ~ HA.LL~iE3URTGN COt1C?Ct~~hl~~p~5 Planning Report -Geographic _ ----- Spsrry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company; ConocoPhillips Alaska (Kuparuk) ND Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-184 Design: 1J-184 (wp09) - Point ~ Prognosed Casing Points Measured Depth (ft) 120.00 3,638.76 9,254.17 17,628.16 Vertical Depth (ft) 120.00 2,150.00 3,428.00 3,619.00 Casing Diameter C') 20 13-3/8 9-5/8 5-1/2 Hole Diameter C') 40 16 12-114 8-1i2 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W (ft) (°) (°) lft) (ft) (n) Name 1,684.81 49.01 200.00 1,526.00 -507.01 -184.54 Base of Permafrost 1,854.56 53.56 196.11 1,634.00 -630.96 -226.47 T3 2,768.37 76.45 182.00 1,946.00 -1,474.93 -308.15 K15 3,638.76 76.45 182.00 2,150.00 -2,320.56 -337.71 T3 + 550 6,245.67 76.45 182.00 2,761.00 -4,853.31 -426.23 UGNU C 7,188.59 76.45 182.00 2,982.00 -5,769.41 -458.25 UGNU B 7,470.19 76.45 182.00 3,048.00 -6,042.99 -467.81 UGNU A 8,114.45 76.45 182.00 3,199.00 -6,668.93 -489.69 K13 8,773.13 80.00 179.24 3,347.00 -7,310.34 -507.11 West Sak D 9,112.90 80.00 179.24 3,406.00 -7,644.91 -502.67 West Sak C 9,254.17 82.97 179.24 3,428.00 -7,784.42 -500.82 West Sak B 3/12/2006 11:33:51AM Page 11 of 11 COMPASS 2003.11 Build 50 A ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-184 1 J-184 1 J-184 (wp09) Anticollision Report 12 March, 2006 ~~~ S~eii~ry t~r~lling Seirvices ~~~.. r _ Z r o Y a ~ z o ~ i E~cmm 3 n 'c y V az' 41 N f m W Q Th ~~ W1~-y O 53 °o» u« n t a m d =_ NOtf - p r2 O .C.. y O~ ° °i`u~OE ~ - m yCj 3 O H U = U o ~ N ~~ o~ J n V C a iIi o 'o N Q b G p o ~~ 9 a ~ aN G c N U,`Hro n wo N ~ Q C< r n 2 n ~~ IO y„nm NO - n ~ ; 2 2FO' ~Oe h O pHmC y f E ti m ~ v o ~ a ~ O W ~ U ~ «O1Ed ~ c a o~E` - ~ A K ~p ~ M O O M N N r~i M o M G ~ If1 ~ N v ~ $ Y o ~ N O N N 0 N °o. 3 ., ., ., ... .-. m 3 o° S ; ~ ; i ~ ~ sg H wgSm roroe yNy Tnbn~ey~yid u,y~yi~~ebu~~nn OONN 1~~ d A< T era A n o N n< b n N n O,A ~~ O p n~ ~yy n ~ V Vf'1~1`I~I~e~l~onnrom M~ V <N uu~~ e(ppONOmeeeq e 10 0 0 0 0 0 b o< 0 0 0 0 ~ O d V 0 M O A O n 0 !~ ~~ O N ~o ode o000 ogo~a' yeev~lge ~ooooooge ~000~ N JOOO ^1 V evic riconoric ri e~o~o~c~c~ ore V J p W 3°o °ore°a~° mom ,°+~r1Di p ~CGUi^C~vi n,or oia ri'i eir ei ai ui via ei .e vi Nri aeo z ~ ,""?'R 'R~YYYYYYYYYYY4Y4Y4^Y O W ~ o$ m m m e N m n u n °n ° a o a w udi ~ n n e~ H ei w 2ocgq~c~m m5unm ao6m no`'~ R9'4 °4Rmmoo««"~'°o~$n'm pooo$mu~N~°o e~i.~~°o°om°o°m°o°m °o mom°om°e°o ~.eooo,~iia~~ar, ui .c «~MM~~~~~~~~~~~~~~~~~xM~ C o o ~ 0 0 V V 0 ~ V O V m m N N d O 4~ N N~ ~aannmmammmmmmmmmmormmmmmmn p oom~.~-~~rHNmmn `~ ~p~~~~^ ~3~~~~m~m3m343m~~~4~e ~.-«mWAmaamma ___ ~«~~e~ N O N ,~ a vi u n m m ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ H N N H H N H H H C~ L 0 0 0 0 0 0 p Op 0 0 0 0 0 0 0 0 0 0 0 O ~ O N O N N r O N O N O~ O~~ N V h~ W o ~ N O I~ ~ ~ ~ ~ N N M M N tp d0 m ~ ~ ~ ~ '- '- $ U I I I V n C m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ C N N O~ O ~/1 O h O O O O O O O O O O O O O N N !~ O N N I~ O N O N O N O~ O ~[I O N O ~~ O ~ .- ~ ~ N N M M N tD GO Q~ ~~~~~ r ~ - r O H - ;~ a ~ ~ ~ zV> ~ FUF U y ~ ~ a ~ 6~~ '~' c ~ '~- ~A~= F = G ~ - ~~~ ~y ~ ~ G rN O" ~ ~ 0 0 ~o 0 ~cwr oa~~°oa N r 2 ~ ~ y ~O~r Z m ~ F ```°+~ E z a$'~c O -'o~ Z 3.-m~f W d d d 9 U N L 2 ~ `a `u `v ~ W KCKKp d' W_pNt g Z~? a~ _ O " .. ~° OpU C Y u -Q=ln N b ~ d U ~ ~ .~.. N n a ~ 7 lO ~ ~ r ~ ~ ~ ~ A ~ -~ ._ .. ~-'' ConocoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: PEan 1J-184 Well Ercor: 6.OOft Reference Wellbore 1J-184... Reference Design: 1J-184 (wp09) Halliburton Energy Services Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALLiBEJRTOIN Sperry Drilling Services Well Plan 1 J-184 -Slot 1 J-184 1J-184 (28+81) ~ 109.OOft (Doyon 141 (28)) 1J-184 (28+81) @ 109:OOft (Doyon 141 (28)) True Minimum Curvature. 2.00 sigma EDM 2003.11 Single. User Db Offset Datum Reference 1J-184 (wp09) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,960.02ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 3/12/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-184 (wp09) (1J-184) CB-GYRO-SS Camera based gyro single shot 800.00 17,628.17 1J-184 (wp09) (1J-184) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/12/2006 12:25; 46PM Page 2 of 4 COMPASS 2003.11 Build 50 ~ • ConocoPhillips Alaska FiALLIBlJRTON Spent' Drilling Services Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1 J-184 -Slot 1 J-184 Project: Kuparuk River Unit ND Reference: 1J-184 (28+g1) @ 109.OOft (Doyon 141 (28)) Reference Site: Kuparuk 1J Pad MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site Error: O.OOft North Reference: True Reference Well: Plan 1 J-184 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-184 Database: EDM 2003.11 Single User Db Reference Design: 1 J-184 (wp09) Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1 J-14 - 1 J-14 - 1 J-14 702.15 700.00 63.91 13.21 50.78 Pass -Major Risk 1 J-154 - 1 J-154 - 1 J-154 290.73 300.00 622.92 6.60 616.32 Pass -Major Risk 1J-154- 1J-154 L1 - 1J-154 L1 8,653.70 11,285.00 193.55 - 49.08 144.81 Pass -Minor 1/200 1J-154 - 1J-154 L2 - 1J-154 L2 8,345.48 10,964.00 177.77 - 61.14 119.07 Pass -Minor 1/200 Plan 1J-127 -Plan 1J-127 - 1J-127 (wp03) 295.42 300.00 232.15 6.52 225.62 Pass -Major Risk Plan 1J-127 -Plan 1J-127 L1 - 1J-127 L1 (wpD3) 295.42 300.00 232.15 6.52 225.62 Pass -Major Risk Plan 1 J-127 -Plan 1 J-127 L2 - 1 J-127 L2 (wp03) 295.42 300.00 232.15 6.52 225.62 Pass -Major Risk Plan 1J-129 (013 Phase 2) -Plan 1J-129 - 1J-129 284.99 300.00 202.45 6.43 196.02 Pass -Major Risk Plan 1 J-130 -Plan 1 J-130 - 1 J-130 (wp02) 285.22 300.00 189.13 6.44 182.70 Pass -Major Risk Plan 1J-132 (012 Phase 2) -Plan 1J-132 - 1J-132 285.70 300.00 166.62 6.34 160.28 Pass -Major Risk Plan 1 J-133 - 1 J-133 - 1 J-133 (wp06) 285.95 300.00 158.14 6.39 151.75 Pass -Major Risk Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) 285.95 300.00 158.14 6.39 151.75 Pass -Major Risk Plan 1J-135 -Plan 1J-135 -Plan 1J-135 (wp01) 298.92 300.00 147.54 6.00 141.54 Pass -Major Risk Plan 1 J-136 - 1 J-136 - 1 J-136 (wp03) 347.53 350.00 147.09 7.73 139.37 Pass -Major Risk Plan 1 J-136 - 1 J-136 L1 - 1 J-136 L1 (wp03) 347.53 350.00 147.09 7.51 139.58 Pass -Major Risk Plan 1 J-137 - 1 J-137 - 1 J-137 (wp03) 882.14 900.00 138.74 19.87 118.91 Pass -Major Risk Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp03) 882.14 900.00 138.74 19.87 118.91 Pass -Major Risk Plan 1J-141 (L14 Phase 2) - 1J-141 (L14) A Lateral 301.05 300.00 177.35 6.72 170.62 Pass -Major Risk Plan 1J-142 (L15 Phase 2) - 1J-142 (L15) (Phase 301.42 300.00 189.39 5.35 184.04 Pass -Major Risk Plan 1 J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E Lat 285.18 300.00 220.61 6.33 214.28 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Kuparuk - 1J-73 W Lat 285.18 300.00 220.61 6.33 214.28 Pass -Major Risk Plan 1 J-173 Kuparuk - 1J-73 Pilot - 1 J-173 Pilot (wp 285.18 300.00 220.61 6.33 214.28 Pass -Major Risk Plan 1 J-174 (01 Pfiase 2) -Plan 1 J-174 - 1 J-174( 575.42 600.00 198.52 13.02 185.54 Pass -Major Risk Plan 1 J-176 (02 Phase 2) -Plan 1 J-176 - 1 J-176 767.81 800.00 155.06 15.86 139.34 Pass -Major Risk Plan 1 J-178 (03 Phase 2) -Plan 1 J-178 - 1 J-178 823.28 850.00 110.52 17.11 93.48 Pass -Major Risk Plan 1 J-180 (04 Phase 2) -Plan 1 J-180 - 1 J-180 784.86 800.00 66.74 16.11 50.66 Pass -Major Risk Plan 1 J-182 - 1 J-182 - 1 J-182 (wp05) 791.50 800.00 47.51 17.84 29.94 Pass -Major Risk Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) 791.50 800.00 47.51 17.63 30.16 Pass -Major Risk Plan 1J-184 - 1J-184 L1 - 1J-184 L1 (wp09) 16,849.57 16,850.52 14.56 - 360.73 -149.92 FAIL -Minor Risk WSP-09 -WSP-09 -WSP-09 330.55 350.00 207.15 8.44 198.71 Pass -Major Risk WSP-10 -WSP-10 -WSP-10 300.00 300.00 185.60 7.25 178.35 Pass -Major Risk WSP-11 -WSP-11 -WSP-11 382.09 400.00 182.62 9.04 173.59 Pass -Major Risk WSP-12 -WSP-12 -WSP-12 482.77 500.00 201.93 12.86 189.07 Pass -Major Risk WSP-13 -WSP-13 -WSP-13 653.07 650.00 226.13 16.52 209.61 Pass -Major Risk WSP-14 -WSP-14 -WSP-14 839.71 850.00 263.58 21.17 242.41 Pass -Major Risk Kuparuk River Unit Non Pad ~ ~ West Sak 5 -West Sak 5 -West Sak 5 h ¢ ~ 10,201.93 3,450.00 350.39 - 336.93 13.90 Pass -Major Risk ~. ~.p(. CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/12/2006 12:25:46PM Page 3 of 4 COMPASS 2003.11 Build 50 Halliburton Energy Services Anticollision Report ., I • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-184 -Slot 1J-184 1 J-184 Plan: 1J-184 (wpO9) 1/4 Mile Scan -Closest Well In Pool 12 March, 2006 AL~ Sperry Drilling Services Closest in POOL Closest A roach: Reference Well: 1J-184 B-Sand w 09 Plan Offset Well: 1J-154 L1 B-Sand Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments Depth Incl. An le TRUE Azi. ND E(+)/W(- (180°) Comments POOL Min Distance POOL Min Distance (639.18 ft) in POOL (639.18 ft) in POOL (3150 - 3350 Subsea (3150 - 3350 Subsea 639.18 9254.17 82.97 179.24 3318.469 5937554 558350 7784.581 ND)to 1J-154 L1 11285 90.53 172.41 3346.842 5938175 558199.1 7163.028 ND)to 1J-184 Closest A roach: Reference Well: 1J-1 84 L1 D-Sand w 09 Plan Offset Well: 1J-154 L2 D-Sand Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. r Depth Incl. Angle TRUE Azi. ND E + /VN(-) (180° Comments Depth Incl. Angle TRUE Azi. ND E + /W(-) (180°) Comments PO L Min Distance POOL Min Distance (531.85 ft) in POOL (531.85 ft) in POOL (3150 - 3350 Subsea (3150 - 3350 Subsea ND) to 1 J-184 L1 531.85 8842.24 80 179.24 3249.464 5937960 558341.5 7378.544 ND)to 1J-154 L2 10964 94.48 182.92 3248.863 5938474 558205.2 6863.461 (wp09) Plan Closest A roach: Reference Well: 1J -184 B-Sand w 09 Plan Offset Well: 1J-159 L1 B-Sand Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. TVD E(+)/W - (180°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(_) 180°) Comments L Min Distance POOL Min Distance (1292.2 ft) in POOL (1292.20 ft) in POOL (3150 - 3350 Subsea (3150 - 3350 Subsea ND) to 1 J-184 1292.19 1 =ir f. '"-"1". 9254.17 82.97 179.24 3318.469 5937554 558350 7784.581 TVD)to 1J-159 L1 11187 90.12 182.99 3397.885 5938276 559418.7 7070.906 (wp09) Plan Closes t A roach: Reference Well: 1J-184L1 D-Sand w 09 Plan Offset Well: 1J-159 L2 D-Sand Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. Angle TRUE Azi. TVD E(+)/W(-) (180°) Comments Depth Incl. Angle TRUE Azi. ND E(+)/W(_) (180° Comments P L Min Distance POOL Min Distance (1240.6 ft) in POOL (1240.6 ft) in POOL (3150 - 3350 Subsea (3150 - 3350 Subsea ND) to 1J-184 L1 1240.58 8842.24 80 179.24 3249.464 5937960 558341.5 7378.544 TVD)to 1J-159 L2 10884 94.51 180.37 3316.842 5938576 559416.3 6771.155 (wp09) Closes t A roach: Reference Wel l: 1J-184 w 09 Plan Offset Well: West Sak 5 d. Coords. - Coords. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. Depth Incl. Angle TRUE Azi. ND E + /W(-) (180°) Comments De th Incl. Angle TRUE Azi. ND E + /W(-) (180°) Comments PO L Min Distance POOL Min Distance (350.29 ft) in POOL (350.29 ft) in POOL (3150 - 3350 Subsea (3150 - 3350 Subsea ND) to 1 J-184 350.29 10200 90.4 179.24 3331.008 5936609 558369.9 8729.653 ND)to West Sak 5 3425 0.61 0 3327.442 5936601 558019.8 8735.724 (wp09) Plan J POOL Summary1J-184.x1s 3/12/2006 3:00 PM • ~~ ~ ~~ _- ~ ~ `~ ~, z 0 0 0 0 0 o O O O O 0 0 O ~ O O o ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ N J ~ • ~ ~ J r ' ~ ~ - I --°-- r e-' I I I I I ~ I r I I I i I ~ I I I I I I I ~ ~ ~ .. ~ ' _ .' ... ~......... I I I I I I I I W I I I I I I N C`7 N 1 I I I v ~ N ~ Y (9 , R _ ~ O ~ >N N ~~ > d _ ~ , ~ i H _ _ - i ! _ ., .. ,_ -. •,. -. .,_ ~~ d' .. _ ~ - .. .. • ~ ~ i r i ~ 7 ~ ~ •.. r- . -- -- r ~ , •. •,.. ,, ., ~. r° ... ........... •. , ~'- ._ ., .. .. . •. •. N '• _ J - ° --=------- . _ "' _ _ ~- -. ~. ~~ _, --. - . - i .,, ., ~ __ • ~ _ - ---.. ~' -. ... I ..- ~ ~ J '•- '• ''•. ~"~•- I _ ~'- .. . -~~-~ ---~•~ - r. : -- 3 . Y /~ -. •. , ~--. ~ ... o ~ -~-: -- ~ ------ ------- -------------.. ....---~---- - ,, -• I ._,_ ~ ~ •~ •.., t6 ~ ----... - - I ~ '~•-. Vi °-- ---' -----•- . O V ............. .. .. ....°---------~ . d .;;;; -~- O V O 1~-184 il_Iing Hazards Mumma (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED Surface Hole OF THESE RISKS) Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate ~ Control drill, Reduced .pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips .Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Intermediate Hole Hazard Risk Level Miti tion Strate Close Crossing with Low Separation is vertical. We will use 17-154 `-" eolo ical control to revent collision Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material,. stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo , LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low ~ Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Lowe Good hole cleaning, PWD tools, hole o ever runs, decreased mud wei ht Lost Circulation Low Reduced um rates mud rheolo , LCM Hole Swabbing on Trips Moderate , Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-184 Drilling Hazards Summary 3/29/2006 3:25 PM i~ CemCADE Preliminary Job Design 13 3/8" Surface Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location:. West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 3/21/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900. email: martin13@slb.com < TOC at Surface t Previous Csg. < 20", 91.5# casing at 120' MD < Base of Permafrost at 1,685' MD (1,526' TVD) < Top of Tail at 2,839' MD < 13 3/8", 68.0# casing in 16" OH TD at 3,639' MD (2,150' TVD) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and. 35% excess below the permafrost. The top of the tali slurry is designed to be at 2,839' MD. Lead Slurry Minimum pump time: 270 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (120') x 1.00 (no excess) = 122.3 ft3 0.4206 ft3/ft x (1685' - 120') x 3.50 (250% excess) = 2303.8 ft3 0.4206 ft3/ft x (2839' - 1685') x 1.35 (35% excess) = 655.3 ft3 122.3 it3 + 2303.8 ft3+ 655.3 ft3 = 3081.4 ft3 3081.4 ~s / 4.45 ft3/sk = 692.4 sks Round up to 700 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 190 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3639' - 2839') x 1.35 (35% excess) = 454.2 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 67.3 #t3 454.2 ft3 + 67.3 ft3 = 521.5 ft3 521.5 ft3/ 2.47 ft3/sk = 211.1 sks Round up to 220 sks BHST = 46°F, Estimated BHCT = 63°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 548.8 78.4. 111.7 DeepCRETE 6.0 92.9 15.5 127.2 Drop top plug 0.0 0.0 5.0 132.2 Water 5.0 20.0 4.0 136.2 Switch to rig 0.0 0.0 5.0 141.2 Mud 7.0 503.9 72.0. 213.2 Slow & bump plug 3.0 9.0 3.0 216.2 MUD REMOVAL Recommended Mud Properties: 9.7 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, TY ? 20-25 Centralizers: Recommend 2 per joint throughout tail slurry column ORIGINAL .~ • CemCADE Preliminary Job Design 9 5/8"Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 3/21/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martin13@slb.com ~~ `i Previous Csg. < 13 3/8", 68.0# casing at 3,639' MD < Top of Tail at 5,745' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 9,254' MD (3,428' TVD) Schlumberger Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 3509' MD annular length. Tail-Slurry Minimum thickening time: 260 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 3509' x 1.25 (25% excess) = 1373.8 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1373.8 ft3 + 34.1 ft3 = 1407.9 ft3 1407.9 ft3/ 2.25 ft3/sk = 625.7 sks Roundup to 630 sks BHST = 79°F, Estimated BHCT = 69°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage ~bPm) Volume (min) Time /bbll (mint CW 100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 75.0 15.0 40.0 DeepCRETE 5.0 250.7 50.1 90.1 Drop top plug 0.0 0.0 5.0 95.1 Water 5.0 20.0 4.0 99.1 Switch to rig 0.0 0.0 5.0 104.1 Mud 6.0 666.6 111.1 215.2 Slow & bump plug 3.0 9.0 3.0 218.2 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv ? 19-22, Ty ? 22-29 Centralizers: ?? 3 per 2 joints from 5700 - 7414 ?? 3 per 2 joints from 8534 - 9174 ?? 2 per joint on the shoe track OR161NAL Tubing, Special Drift to +l- 500' MD DB Nipple, set at +l- 500' MD GLM, Camco, 41/2" x 1" KBMG 13-318" Casing Shoe, /GLM, Camco, 41/2" x i" KBMG 68#, L-80, BTC set ~ f/ 3639' MD, 2150' ND CMD Sliding Sleeve, w/ DB Nipple Tubing String 4112" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift LOt~"g seal Assemby a.7s' swl oD T• x 9-5/e° zxP caner Top Packs ith Hakl Downs Lateral Entry ModulefLEM) OrknBng Profile Casirp Sealbore F 0.75"ID Ass m I 7" X 9-518" ZXP Liner Top Packer with Hold Downs 7.500" Tieback Ext. ID 6.278" Tool Body ID Casing Sealbore Receptacle 4.75" ID, 5.75" OD 20' Length Imo- Onen[ing Profile Automatic Alignment of LEM ` Positive Latching Collet \ dicates Correct Location Seal Bore for Lateral Isolation - 3.688" ID Access Window \ Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.688" ID Isolation Seal Asembly 4.75" Seal OD 3.875" SeaIID 2' Length 5112" Guide Shoe 5.1/2" Casing Shoe, 15.5#, L-80 BTCM 3.s6r' D8 Mippk Set ~ 18851' MD, 3378' ND Seal Asxmbly ~~ 1 4.75" SW OD 3.875"IU 'B' Sand Lateral 0 \\ 57/2" 155#; Ld0 Slotted Liner 9-518" Casing Shoe, 40.0#, L-80 BTC ~ 9254' MD, 3428' ND -~ (84 deg inc) ~ cake. Hvghea :pos. Tnia movmem may not be aprodv«e or m.bibatee, m whale or m can, m env form 8r. ,~- ^.. by any means electronic or mechanical. including Photo<opyin0. ra<ordin0. or by any information storage and retrieval system now known or hereafter invented, without wrinen permiaaion Irom Baker Hughes Inc. -- - -- ~- 5712" Eccentric ' Guide snce ~ Diverter and Sleeve Length: +1-19' f 'These aims are specific to the PZ reworketl equipment. Eauinment Specifications 5-112" X 9-518" HOOK Hanger' Mainbore Drift: 7.00" Mainbore Dritt, with diverter: 6.25" Lateral Drill, no diverter or LEM: 4.88" Lateral Drift, cal diverter, no LEM: 4.50" LateraOMainbore Diverter OD: 8.50" 4-112" Lateral Entry Module Mainbore Drift: 3.88" Mainbore Drill, cal isolation sleeve: 2.50" Lateral Drift, cal coil diverter: 3.00" OD of Diverter and Sleeve' +/- 3 60" 5-112" Casing Shoe,'~15.5#, BTCM Set @ 17626' MD, 619' ND i ~_... ' 2006 West Sak Dual Lateral Completion -Injector pawn ay: vKbnr March 29, 2008 Marc D. Kuck ConocoPhillips West Sak 9-5/8" Injector 1 J-184 Dual Lateral Completion As Planned .,.. NKINiMES Baker Oil Tools With Div Lateral erters and Isolation Access Diverter Lateral Isolation Diverter GS Running TOOl Strirg Installed Installed (3.00" Lateral Dr40 (2.50" ID Mainbor e Drill) 'GS' Profile for Cdl COnnecla I JRUnninglRetrieving` (7.00• Lengtnl Snap lNSnap Otrt ~ j rBack Pressure Valve /Positive Lowting~ (1.60'Lerpth) ~~ ' Lateral Isolation ~' ~ Fbw-Thru Swiad I Seals (1.25 Length) Lateral Diverter I ~ ~ / Hydraulic Ramp ' ~~ . ~ Disconnect IsoWtioN Mainbore ~ ' (1.50' Len91h) Diverter Sleeve I , '~ GS Spear (7.50' LerpM) ~~ I . Lakral Isaladan sera I ~ 8.85 R Approx OAL' 'Jars maY he required in highly devkted ' 79' Diverter Length 79' Sleeve Length ~' or tleep applications (6 approz lengll+. / atacle/ B-sand Window 'D' Sand Lateral at 8/842' MD, 3359' ND 57/2" 15.Sa, L-00 SkatM Llner /// Every Other Jaint 51/2" Bent Jdnt 5712" X 9-Sla" ~ Liner Swivel Seal Bores 3.66"ID 4-112" 726a TUbing 3.837" Drill 3.958" ID 7" X .•ZXP Liner Pac ~\ / T' X 9-~J18" Flat Lock Liner Hanger /Packer Assembly at LIne~Harlger +/- 9750' MD t Casing Sealbore Receptacle 4.75" ID • • • • SHARON K. ALLSUP-DRAKE - CON000PHILLIPS Aro t5so 1138 700 G ST. ANCHORAGE AK 99501 f,/~y~C,~ DATE PAY TO THE ~ ~ ,~~~ ~ 56-1551 /441 ORDER OF / t / ~~ ~~~~ yy~~--~~ .LPMOI' vc:. pOLLARS u ~" ~, ganChase ! j o,u~.o,~~ JPMorgan Chase Bank,`N.A. Valid Up to 5000 Dollars Columbus, OH ~ ~- I MEMO '~--~- ~: D 4 4 1 L 5 5 1 1 ~: 5:28 7 4'7 l 9D 7 9 2? il• -------- ------ --- -------~ ~5 1138 • • TRANSMITTAL LETTER CHECKLIST WELL NAME /'~ ~/.~- ~ ~~ ~g 7 PTD# 2'x(0 - d ~~ Development -~ Service Ex lorato Strati ra hic Test P rY g P Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -__) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception, assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/25/06 C:\jody\transmittal_checkl ist LL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK iJ-184 Program 5ER Well bore seg ^ PTD#:2060440 Company CONOCOPHILLIPS ALASKA INC Initial Classffype SER! PEND GeoArea 890 Unit 11160 On1Off Shore On Annular Disposal ^ Administration 1 Permit fee attached Yes 2 Lease number appropriate- - - - - - - - -- - - - - - - - - - - - - - - - No_ _ - _ - -Corrected omission on_401:_ Surface location is in ADL 25661_, top_prod_interual in ADL_25662, and. 3 Uniquewell,nameand number________________________________ ______Yes-__-__ _TDinADL 380058.._......__-_._,____._._.__._ 4 Well located ina_d_efnedpool___________________--_.-__----- __-,_-Yes__---_ -KUPARUKRIVER,_WESTSAKOIL-490150governedby CO406B____.______ ---------------- 5 Well located proper distance from drilling unit_boundary_ _ . - _ -Yes ..... - - C9 4066 specifes no restrictions as to well spacing except that no pay shall be opened in_awell_ 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - -- Yes , closer than 500 feet to_an external_property line where ownership_or landownership changes, . - _ . - 7 Sufficient acreageayail_ableigdrillingun_it__.______________________ ______Yes--___ _----.--_--__----_--__-___--_ - -- - 8 If deviated,is_wellboreplat_included_____________________________ ______Yes---_.- --------_--_--_.-._ 9 :Operator only affected party-__ ___ Yes-.__._ ._---------------- - -- - - -- 10 Ope[atorhas_appropriate-bond in force --- ------ ------ -- ---- -- --Yes- ---~ -- -- ------- ----- -------------- -- ------ - -- -- --- ---- -- 11 Permit_canbeissuedwithoutconservationorder_________ ___________ ______Yes______ __________,___.___________________,____.__ -- - Appr Date 12 Permit_canbeissuedwithoutad_minist[ative_approval------------------- ------Yes_-._.- -_-________________.__________.________._._______________________ SFD 41412006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authprized by Injection Order # (put1O# in_comments)_(For_ Yes .. - Area Injection Order No._26 15 All wells_within 1!4-mile area_of review identified (For sera-ice well gnly)_ _ _ _ _ _ _ __ _ _ _ _ _ _Yes _ . . _ . - KRU 1J-154_and laterals (Open),KRIJ 1J-159 and laterals (Open), W Sak 5 (P&A'd). KRU-1J-154L1_elosest at660 16 Pre-produced injector; duration of pre production less than 3 months_(For service well only) - _ Yes _ _ - - _ - .180-day flowbackon_gas-lift planned _ - - - . _ _ - ------------------------------------ ACMP,Finding of Consistency-has been issued_forthis project- N_A_ - --- Engineering 18 Conductor. sting-provided___________________________________ _____ Yes______ --------------------------------------------------------------------- 19 Surface casirlg_proteets allknown USDWS . . . . .. . . . . . .. . . . . .. . . . . . . . . NA_ _ _ _ _ All aquifers exempted, 40 CFR_147.102~b)(3). ------------------------------------ 20 CMT_vol_adequate_tocircul_ate_onconductor&surfcsg_.-_-._-_________ ______Yes-_--_- .----_----__-__--------_____-__------.__--_--__--__-_.___________-__ 21 CMT_vol_ adequate_t4 tie-in long string tosurf csg . .. . . ........ . . . . . . . . . . . .... No, All hydrocarbons will be covered, Annular disposal may be proposed.~ --------------------- 22 CMT.will coyer all known,productive horizons- No_ Slotted liner completion planned.. - _ _ - _ _ - -- - 23 Casiogdesignsadequatefo[C,T,B.&permafrost-------------------- Yes------ ------------------------------------------------------------_- 24 Adequate tankage_or reserve pit _ . - , Yes . - Rig is-equipped with steel-pits.. No rese_rve_pitplanned, All waste to approved disposal wells .. . . . . . ...... . 25 If_a.re-drill,has_a_1.0-403 for abandonment been approved________________ ______ NA-__._- --_---_--______--_--_--__-__--_--.-__.__--__-__-----__-_-_______--_ 26 Adequate wellboresegaration-proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ -Proximity analysis performed, Traveling cylinder path calculated, Gyros planned in surface hole, . _ _ _ .. . - _ 27 Ifdiverterrequired,doesitmeetregulations__.__ ................... ......Yes-__-__ --_--_----__-__--.-_--_____--_--.---._ - -- - Appr Date 28 Drilling fluid_program schemati4& equip listadequate- .. - - -- - - - - - - - -- - -Yes .. _ . - - -Maximum expected formation pressure 8,6_EMIW in WS. Planned MW 9,0-ppg.- - - - - - - . - - - . ... _ - - - - TE 4I6/2006 29 BOPES,_do they meet regulation _ _ _ _ _ _ _ Yes _ _ - ------------ `"" \ 30 BOPS-press rating appropriate; test to_(put psig in comments)- - Yes MASP calculated at 1239psi, $K stack arrangement and test pressureplanned; _ _ - - _ _ - - _ - - _ 31 Choke-manifgldcompliesw/API-RP-53 (May84)_________ ____________ ______Yes______ ________________-_____-__________,________________________-___,-____ 32 Work willoccu[withoutoperatjonshutdown________________________ ____Yes-___-_ __.________________________________________-__.,_ ------------------- 33 Is presence_of H2S gas probable . . . ... . .. . . .. . .. . . ... . . . . . . . . . . . .. . No_ , _ _ - . _ _ H2S has not_been reported in WS._ Rig is equipped_wikhsensors and alarms, - . - - .. _ 34 Mechanical condition of wells within AOR verified (For_seruice well only) Yes WS 5_is only penetration in AOR_and P&A is satisfactory. Other wells_a_re in zone. Geology 35 Pe[mit-eanbeissuedwlohydrogen-sulfidemeasures___________________ ______Yes______ ___..___.._-.-_.-_.-_.-_.._ -- 36 Data-presented on potential overpressure zones _ _ _ - - _ - _ _ - _ Yes . _ - - _ .Expected reservojrp[essure is 8,6_ppg EMW; will be drilled with 9.0 ppg mud ... . . . . . .. . . .. . . . . . . .. . Appr Date 37 Seismic analysis-of shallow gas.zones- - - - -- - - -- - -- - - - - NA_ _ . _ . - _ _ Gas hydrates may be encountered near base of permafrost, noted_in grilling Hazards Summary. _ _ _ _ - , _ _ _ _ _ SFD 41412006 38 Seabed condition survey-(ifoff-shore) - . _ _ ... _ - NA_ This wellwill_ be located in-the vicinity of the West Sak Pilot project_we_Ils (16~wells and_KRU 1J-154._ _ - , _ . _ _ 39 Contactnamelphoneforweekly_p_rogressreports[exploratQrypnlyJ___,-_-.- __-_-_ NA_______ _____________________________________________________________________ Geologic Engineering blic Date: Date ' West Sak B sand injection well. Date Commissioner: Comm issioner: C ner // %%rr C~~~Q~~ ~ ~~t° ~ ~ '~~ • • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Welf Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify Minding 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. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 29 09:42:04 2006 Reel Header Service name ....... ......LISTPE Date ............... ......06/06/29 Origin ............. ......STS Reel Name .......... ......UNKNOWN Continuation Number ......01 Previous Reel Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Tape Header Service name ....... ......LISTPE Date ............... ......06/06/29 Origin ............. ......STS Tape Name .......... ......UNKNOWN Continuation Number ......01 Previous Tape Name. ......UNKNOWN Comments ........... ......ST5 LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JOB NUMBER: W-0004348857 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: 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 ~o~,_ oy~ '~~39.~ Scientific Technical Services Scientific Technical Services 1J-184 500292330500 ConocoPhillips Alaska, Inc. Sperry Drilling Services 29-JUN-06 MWD RUN 4 W-0004348857 P. ORTH D. GLADDEN 35 11N l0E 1530 2424 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3977.0 2ND STRING 8.500 9.625 9275.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE • • PRESENTED. 4. MWD RUNS 3,4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GEOPILOT ROTARY STEERABLE BHA (GP) WITH AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-184 WITH API#: 50-029-23305-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17870'MD/3751'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3953.0 17832.5 RPD 3960.0 17825.0 FET 3960.0 17825.0 RPS 3960.0 17825.0 RPM 3960.0 17825.0 RPX 3960.0 17825.0 ROP 3988.5 17870.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3953.0 9280.0 MWD 4 9280.0 17870.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 • • Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3953 17870 10911.5 27835 3953 17870 RPD MWD OHMM 2.25 2000 47.5487 27731 3960 17825 RPM MWD OHMM 0.33 1743.45 35.8204 27731 3960 17825 RPS MWD OHMM 1.47 2000 33.9963 27731 3960 17825 RPX MWD OHMM 1.56 2000 33.8148 27731 3960 17825 FET MWD HOUR 0.1 78.98 0.88268 27731 3960 17825 GR MWD API 23.77 160.53 70.1495 27760 3953 17832.5 ROP MWD FT/H 1.32 1364.37 256.787 27764 3988.5 17870 First Reading For Entire File..........3953 Last Reading For Entire File...........17870 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3953.0 9244.0 FET 3960.0 9236.0 RPX 3960.0 9236.0 RPS 3960.0 9236.0 RPM 3960.0 9236.0 RPD 3960.0 9236.0 • ROP 3988.5 9280.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 02-MAY-06 Insite 66.37 Memory 9280.0 3988.0 9280.0 75.0 81.8 TOOL NUMBER 76571 78633 12.250 3977.0 Other 9.10 58.0 9.2 250 4.2 68.0 102.0 68.0 68.0 2.600 1.790 3.600 2.000 Data Format Specification Record Data Record Type ......... ........ .0 Data Specification Block Type.... .0 Logging Direction ........ ........ .Down Optical log depth units.. ........ .Feet Data Reference Point ..... ........ .Undefined Frame Spacing ............ ........ .60 .1IN Max frames per record .... ........ .Undefined Absent value ............. ........ .-999 Depth Units .............. ........ . Datum Specification Block sub-type...0 Name Service Order Units Si ze Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last i ~ Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3953 9280 6616.5 10655 3953 9280 RPD MWD030 OHMM 4.07 2000 19.8571 10553 3960 9236 RPM MWD030 OHMM 0.33 1089.68 16.4863 10553 3960 9236 RPS MWD030 OHMM 2.15 948.71 15.845 10553 3960 9236 RPX MWD030 OHMM 3.28 1670.76 14.3005 10553 3960 9236 FET MWD030 HOUR 0.1 67.01 0.814617 10553 3960 9236 GR MWD030 API 23.77 127.24 69.2955 10583 3953 9244 ROP MWD030 FT/H 3.13 708.88 265.359 10584 3988.5 9280 First Reading For Entire File..........3953 Last Reading For Entire File...........9280 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name ........... ..STSLIB.003 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/06/29 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 9236.5 17825.0 RPD 9236.5 17825.0 RPM 9236.5 17825.0 FET 9236.5 17825.0 RPS 9236.5 17825.0 GR 9244.5 17832.5 ROP 9280.5 17870.0 LOG HEADER DATA DATE LOGGED: 09-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 17870.0 TOP LOG INTERVAL (FT) 9280.0 BOTTOM LOG INTERVAL (FT) 17870.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 46.6 MAXIMUM ANGLE: 93.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 149206 EWR4 ELECTROMAG. RESIS. 4 145654 • 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 8.500 9275.0 • Mineral Oil Base 8.80 71.0 .0 19500 4.0 000 .0 000 192.2 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9236.5 17870 13553.3 17268 9236.5 17870 RPD MWD040 OHMM 2.25 2000 64.5606 17178 9236.5 17825 RPM MWD040 OHMM 1.58 1743.45 47.6979 17178 9236.5 17825 RPS MWD040 OHMM 1.47 2000 45.1472 17178 9236.5 17825 RPX MWD040 OHMM 1.56 2000 45.803 17178 9236.5 17825 FET MWD040 HOUR 0.1 78.98 0.924493 17178 9236.5 17825 GR MWD040 API 31.3 160.53 70.6757 17177 9244.5 17832.5 ROP MWD040 FT/H 1.32 1364.37 251.507 17180 9280.5 17870 First Reading For Entire File..........9236.5 Last Reading For Entire File...........17870 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 . • • Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
