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207-100
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS NOV 14 2019 1. Operations Abandon ❑ Plug Perforai Fracture Stimulate ❑ Pull Tubing ❑ Fwaufurwown ❑ Performed: Suspend ❑ Perforao Other Stimulate ❑ Alter Casing L] Change Approved Program ElPlu for Redrill Plug ❑ Perforate New Pc❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Convert WINJ to WAG ❑✓ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Stratigraphic ❑ Exploratory ❑ Service 207-100 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23364-6000 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25662, 25661, 25663, 385172 KRU 1 J -176L1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071g 10. Field/Pool(s): Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17,826 feet Plugs measured None feet true vertical 3,142 feet Junk measured None feet Effective Depth measured 17,738 feet Packer measured 10,216 feet true vertical 3,142 feet true vertical 3,159 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' Surface 3,748' 13.375" 3,792' 2,299' Intermediate 10,959' 9.625"x10.75" 11,000' 3,251' Liner 7,182' 4.5" 17,783' 3,142' Perforations: Horizontal slotted liner Measured depth: 10,661'-17,738' feet True vertical depth: 3,199'-3,142' feet Tubing (size, grade, measured and true vertical depth) 4.511 L-80 10,220' MD 3,160' TVD Packers and SSSV (type, measured and true vertical depth) Baker "ML" Anchor Seal Assembly 10,216' MD 3,1597VD SSSV TYPE - NA NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 0 0 1000 1200 1515 Subsequentto operation:10 1000 10 1700 11550 14. Attachments (required per 20 QAC 25070, 25.071, a 25283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development p ❑ 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: 319-432 Authorized Name: Sydney Autry Contact Name: Sydney Autry Authorized TitleProduction Engineer Contact Email: S dne .autrYc0 .Com Authorized Si nature: s Date 1 3 a Contact Phone: 907-265-6813 ,�lyilb�y 1�DDMS ±" NOV 14 2019 Form 10-404 Revised 4/2017 Submit Original Only 11-176L1 Description of Well Events Date Event Summary 10/26/2019: Convert to WAG KUP INJ WELLNAME 1J-176 WELLBORE 1J-176 C0noco W1illip5 Aks'ka. Inc. GAS LIFT, S6NFACE Ql. .M4. SLEEVE: 10, 11 i.1— LOSPTOR: 10.191 0 PER: 10,185.0 ANCHOR: 10,]136 SEAL ASSY. 10,i15O— DRANO LINER HN: 11,OM0 SLOTS 11,Ob.O11,4EC SLOTS, 11.788.D1 1,268.o�� SLOTS. 12,A 00-13,#640— SLOTS.13MC 37170 - SLOTS: 1401614,478.0 SLOTS: 14,]&10-1 5,3E00� SLOTS, 15,5100-148°5.0 SL0TS', 16.NCG16,7170� E. 16,T760.17...— SLOTS: 17.6210-17.6070 SSW 0 LINER: 10,4E77 17..E — KUP INJ WELLNAME 1J-176 WELLBORE 1J-176L1 r `.! ' i ii:4 p COttOCOi�li��ips All Attributes Mas Angle & AID TD Alaska rec. =a Sam. WaIIMreAPIIUVA WelloreSlYs clrl MDt I Ac13[m(NB) 5.10 12,49519 17,820.0 Comment H35 tppmf pffie AanBblbn End Lae NB6N ny Rig Rome Date SSSV: NIPPLE Last WO'. 4341 10141200) 1J 170Ll 111nmel W21 Pol Last Tag Vstiul smar.*l Annotellon Oepin!11KB) End One WeIIWre Lap Me" BY ........... ................ ...................... I. RArvcsR; a6.a .., Last Tao: 1J-1)6L1 Imdsbpr Last Rev Reason Annatel End Dde wenMre LaatmW ey Rev Reason: SHOW SLEEVE CLOSED 31152014 1J-1]611 M1lpshkf corvoucroR:4a.om.g Casing Strings easing Oeacnpnon o0!mt mg) Top lfIXal set Depth (nRet sof OBpin !rvOt... wuLen ll...Omae ToprnrBaa wppLB sg4s D-BAND LINER 412 348 10,601.1 1],]83.5 3,141.6 11.60 L-80 JBTC Liner Details I Nominal l0 Top We) Top !WO)need Tap Incl(°) Ihm Des Com (n) ws urr; 2318 2 10,601.1 3,19611 87.07 SLEEVE 7.0"Baker-HR" Liner Setting Sleeve-M 6'TBR 6.280 10,6093 3,196.61 87.25 XO Reducing XO Sub T' Hytl 521 X 5-12" Hyd 521 4.900 suRracE; 4a]a]a2N— 10,656.23,196.4 8821 XO Reducing 521 Box ^Hytl 521 P1n X0 (3.92" 3.920 3.920 ID) SLEEVE I m.1122 Perforations & Slots LOL Ov. 10,191.0 shat SBR, ID,1a50 oana ANLHOa; fO,]13.a Top Me) bell !anobM $EALNSSP, 10, 3150 OSWIO LINES Top DING) BM1n IRKS) (SNR) (Spin Linked IDne Day n TNN, Com .0t 14338.6 I 0,8' 2 10,661.0 11,118.0 3,198.6 3,198.6 WE D, 1J- 9282007 32.0 SLOTS Entire liner altemaling IrvTEameolaTe 1]611 global pipe 2.5" 10.]Ss9.ars®3aa; m s x.125" in 4 circumferential P9Yg D.N. UNER I£M', 10.310.2- rol Centers mneS.a Staggered Staggered tleg,3'Son. sl0ne0 ends 11,36].0 11,8680 3,200.4 $2p2.1 WS D, 11 912&200] 32.0 SLOTS 14 176L1 12,126.0 12,642.0 3,19.9 3,1]5] WE 928200] 32MOTE OTS _l} _ 1]611 12,899.0 13,370.0 3,1]0.] 3,172.6 WS O, J- 9l2&200] 32.0 SLOTS $LOi&: t0.fi91611.1150� 176L1 13,629.0 14,139.0 3,1]34 3,169.1 —w-S-b J- 9282007 32.0 SLOTS 1)611 I 16,398.0 14,887.0 7169.3 3,168.4 D, 1J- 9l2&200] 32.0 SLOTS - 11 1]611 _ 15,123.0 15,643.0 7168.4 3,167.1 —WTD, 1J- 9282007 32.0 SLOTS 1]611 SLOTS, u,a6zwteae.g�= 15,891.0 16,362.0 3,166.4 3,1626 WS D. 1J- 92&200] 32.0 SLOTS _ 7611 16,621.0 17,136.0 3,162.3 3,149.3 JWS D. 1J- 9282007 32.0 SLOTB ]611 17,351.0 1),]350 3,143.1 3,141.9 WSq J- 92812007 32.0 SLOTS 1]611 SLOTS; 12JMQ-12.6420� Notes: General & Safety End Date Annoushon 1013200] NOTE'. MULTI-LATERAL WELL-IJ-176 (B-BAND), 1J-17611 (D-BAND) 81172010 ll VIEW SCHEMATIC W/Alaska Schematic9.OREV SLOTS: 128C9.LL13,3100� SLOTS ,f ORD-14IMSg I SLOTS; 143980-it.86I SLOTS. 15.133.0-15,513.0 SLOTS; legal pLS363.0� SLor5: 18.6210-17,fa40� SLOTS; 17,3510.1>,ry80� PSAND LI N E R : I0BJ1. 1� l 9a5 THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Sydney Autry Senior Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J -176L1 Permit to Drill Number: 207-100 Sundry Number: 319-432 Dear Ms. Autry: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 11V- 1z eP Chair DATED this 2 day of October, 2019. RBDMS� OCT 102019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2n AAr. 2e 9an L J ..+..,s" 1. Type of Request: Abandon LJ Plug Perforations 11 Fracture Stimulate LJ Repair Well A Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to WAG INJ ❑� - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ElDevelopment ❑ Stratigraphic F-1ServiceQ 207-100 ' 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23364-6000 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No O 1J -176L1 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25662,25661: 25663, 385172 Kuparuk River Field /West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth,MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): i79 • J.Y783'" 3,142' 17,738' 3,142' 1708 None None Casing Length Size MD ND Burst Collapse Conductor 80' 20" 80' 80' Surface 3,748' 13.375" 3,792' 2,299' Intermediate 10,959' 9.625"x10.75" 11,000' 3,251' Liner 7,182' 4.5" 17,783' 3,142' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slots: 10,661'-17,738'MD Slots: 3,199'-3,142'ND 4.5" L-80 10,220' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): PACKER = Baker "ML" Anchor Seal Assembly, SSSV = NONE Packer = 10,216' MD/3,159'ND, SSSV = N/A 12. Attachments: Proposal Summary O Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1 -Oct -19 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑� GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sydney Autry Contact Name: Sydney Autry Authorized Title: Production Engineer Contact Email: sydney.autry@cop.com .'� Contact Phone: 907-265-6813 Authorized /^261'? Signature: ate: oK/ ow COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number' 31°I -W32 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: qJo z3 Post Initial Injection MIT Req'd? Yes ❑ No d RBDMS.ocr 10 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY Approved , 1 by: COMMISSIONER THE COMMISSION Date: 4 VlJ q'A^ Form 10.903 Revised' 2017 YTL /Ogl9 JONI--t ORIGINAL Approved application is valid for 12 months from the date of approval. �x !' G 7' /f Submit Form and Attachments in Duplicate ConocoPhillips September 20, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7u, Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 1J-176 from Water Injection service to Water Alternating Gas Injection service. IJ -176 was completed as an injector on 10/4/2007. No rig workovers have been completed at 1J-176 since being drilled & completed. Enclosed you will find 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1J-176, and 1J -176L1 (PTD 207-099 and 207-100). Also attached are supporting i documentation, including a map of the target injection area. Well integrity testing since completion includes: • IA & OA MIT to 3000 psi, Tbg & IC PO tested to 5000 psi, OCPO tested to 1000 psi (on rig) • 02/29/08 — Passing MITIA (Waived SW) to 3000 psi • 05/24/09 — Passing State Witnessed MITIA to 1980 psi • 05/22/10 — State Witnessed MITIA Inconclusive due to high volume to fill annulus • 06/04/10 — Passing State Witnessed MITIA to 1900 psi • 03/14/14 — MITIA Failed, unable to pressure up above 950 psi o 03/25/14 — Coil shifted CMD sleeve closed (was discovered open during diagnostics), MITIA passes to 2500 psi post shifting sleeve • 05/15/14 — Passing State Witnessed MITIA to 2000 psi • 10/09/14 — Passing MITIA to 3000 psi • 04/17/18 — Passing MITIA to 1700 psi • 05/09/18 —Passing State Witnessed MITIA to 1800 psi Sincerely, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 <S7- /261d-Nq 1J-17611 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J-1761-1 (PTD# 207-100) from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1J-1761-1 was completed as an injector on 10/4/2007 to provide waterflood support in the D and B West Sak sands to offset producers 1J-178 and 1J-174. The top of the Ugnu C sand was found at 5,830' MD / 2,586 TVD The top of the Ugnu B sand was found at 7,209' MD / 2,772' TVD The top of the Ugnu A sand was found at 7,989' MD / 2,875' TVD The top of the West Sak D sand was found at 10,236' MD / 3,162' TVD Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that there are two wells (1J-160 and KRU State 2) that have penetrations in the West Sak interval located within a 1/4 mile radius of the 1J -176L1 penetrations of the West Sak interval. Offset producers 1J-174 and 1J-178 are also reviewed in the AOR detail. Mechanical Condition of Well to be Converted: / ------------- ------------- The mechanical condition of West Sak injector 1J-1761-1 is good. The injection tubing/casing annulus is isolated via a TorqueMaster packer located at 10,210' MD (3,158' TVD). The last state -witnessed MITIA was performed on May 9, 2018 to 1800 psi. CBL and interpretation of the cement quality: See attached AOR detail for offset well condition. The 20" Conductor was cemented with 326 sx of AS1 The 13-3/8" Surface casing was cemented with 630 bbls 10.7ppg Lead cement, followed by 99 bbls 12.0ppg Tail ement, 245 bbls of cement to surface. The 9-5/8"x10-3/4" Intermediate casing was cemented with 921 sx 12.5ppg DeepCrete. TOC determined to be at 7830' MD per CBL. Conditions for approval (if applicable): § : ) [ \ ) }� Q\ /�wn 33 T'1PJR10E Ti0NR10E n 1J-176 Open Interval 1J-1761-1 Open Interval 1/4 Mile Radius 1J-176 OI 1/4 Mile Radius 1J-1761-1 OI ® Well Pad Wells within Radii i Kuparuk PA CPA[ Leases ADL025660 1J -i 62 JJ62L1. 1J-162L1PB1. 1J-162PB2 ADL025663 1J-176, 1,17LLt, UANPB1, 1J-174PB2 ADL385172 U-160, 11160 L1, 60 L2, U-1600PB1 U-17611 kRU STATE 2 34 U-176 5 11158, 1J-15BL1 1J-175, J-17611 N 0 0.1 0.2 0.3 0.4 0.5 Miles I ADL025661 1J Kuparuk PA Conoc Po 'vi' Alaska, Inc. U-176 10-403 Sundry Date: 12/21/2016 vf KUP INJ Conoco rs,hllllps Well Attributes Alaska, Im Wellbore ppWW1 ""0 Name WEST BAK Comment XRS (ppmj vLn&i 4dock do PM SSSV:NIPPLE 1J-176L1 IMax Angle &MD JTD WellhOup aside n011°f MOIXKB) ps[BIm SURE)500292336460 INJ 95.10 12,496.19 17,820.0 Dab gnnahtien Entl OaM KBGNI%I Rig Release Oak Last WO: 03.41 1014200] ,� o as me- <nnobllOn epi6lXKBl Entl Oele pnnotalbn Last Moo By Entl Oak Last Tao: Rev Reason: SHOW SLEEVE CLOSED M1ipsM1kf 3M1 512014 HPNOER, 35.8 - S asmg strings F easing Oeserl peon 6n) mlml TOp I%Kel Set Oeptn l%Ks Set Oeprn rvOL.. (L Grade TOp Thrme ion DSAND LINER 412 3.06 18601.1 1],]835 lei 3,141.6 11.601-81] BTC coxpvmoR; aaaap.0 U Liner Details ' NIPPLE; 5W.5 Top PIKE) ln BI Top IXKOI Top 0 Sam m Oes xominl ID a Com lin) 10.601.1 3.196.1 81.01 SLEEVE ].0" Baker -HR "Liner Setting Sleeve w) 6'T BR 6.280 10 609.] 3,196 fi 87.25 XO Reducing XO Sub] Hyd 521 X S- U MW 521 d.900 cos upT:2d162 IOSSS.2 3,198.4 8821 XO Reducing 512' Hytl 521 Box X 4112" Hyd 521 Pin %O (3.9P' 3.920 D.) Pertorations & Slots SURFPCE.437d,7O24� GATOR 10,1122 snot Dens LOCATOfl', 10.1510 ioplN01 him (NDI IOpera Pat R; 10.18 v.0 ioia,5 Top IflKD B[m lXNal (XKaI (XKDI Zone Oale 11 Type Co. AxcxOfla 02136 10,661.0 11,118.0 3,198.fi 3.198.6 WS U- "69128200] 32.0 SLOTS Enure liner aXemaling SEAL MV, 10,2158 IxION 1]6L1 s011etl/s0 tl pipe 2.5" 10 T5e8.8TSQXBtl; b5� X.125" In 4 11,SN deferential newsi 0.5ANO LINER LEM;10,2102- 8 3- enrersstagtand t0a55,3 o SAND LalEfl XX', 10313.& deg, 3' npnalo%ed erAs an 1¢6312 - 11,367.0 11,111 3,200.4 3,202.1 WS D, iJ- 9282001 32.0 SLOTS 1]fiLt 12,126.0 12,642.0 3,19]9 3,1]5.1 WS U. 1J- 9)28/200] 32.0 SLOTS ]611 _. 12,899.0 13,3]0.0 3,1'0.] 3.1]2.6 WSD,1J- 9/28200] 32.0 SLOTS 1]6LI 13,629.0 14,139.0 3,173.6 D, 1J- 3,169.1 WS 929/200] 32.0 SLOTS SLOTS I tasei09111a0-� 1]6L1 14,398.0 14,86].0 3,169.3 3 ENA WS D, 1J. 9128200] 320 SLOTS 1]fi11 15,123.0 15,643.0 3,1684 3,167.1 WE D, IJ- g281200] 32.0 SLOTS 1]6L1 15,891.0 16,362.0 31166.4 3,162.6 WS 0, IJ- 9/281200) 32.0 SLOTS SLOTS, 11W o-n.RRS-- 17611 16,621a 17,136.0 3.161 3,149.3 MD, 1J- 9281200] 32.0 SLOTS 1]6L1 17,351.0 1],]38.0 3,143.7 3,141.9 WS D, 1J- 91282007 320 SLOTS _ 1]61.1 Notes: General & Safety SLOTS, 12.126012a42.D-- - Ena Ome I am,obron _ _ 10131200] NOTE: RUL TI-LATERAL WELL -IJ-1]6(&SAND), 1J-176L1(DSAND) or 112010 NOTE: VIEW SCHEMATIC wIAlaska SCM1emariC9.OREV SLOTS; IRefi8.o-leT00- aLOTS,IS.c ISId,1N.0- SLOTS, 1a,aW ,Le6T0- SLOTS. 15,1MO15.643.0� SLOTS:15,691P10382a- SLOTS:leadd 0-17tiS,0- SLOTSI 9.351.0.11.736.0- DSANDLINER:Ideal1- 11.Ta3s� 4 arm uP oon OR a a SNm x'nr e o'nz3€w mon Jim \ ¢ �Rk P 0 p 3 z 3 �33yy 0 ay, is O O a O Eo o � u im3 FOR gii m£ S l 9 O S1! ^s m o « 2 00 on a g s rs00 ID o 01 mr ee� 0 3 Z 1 V/ K n `" w a mCD 4 CD d & ,V RL -s EE 0 o c s �j--- as^ 3 me m3 ¢ yxII c am g� kJm nii o0 W J Fa ,g F¢" 2 3 CL zm gis 4 � Loepp, Victoria T (CED) From: Autry, Sydney <Sydney.Autry@conocophillips.com> Sent: Thursday, October 3, 2019 3:16 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Victoria, Regarding your note below, the AIO allowing WAG injection at West Sak is AIO 2B (Conservation Order 406). For well 1J-176, there are no offset Kuparuk wells Are two Kuparuk wells in the AOR (1J-03 & 1D-36). • 1D-36 4 Surface casing is set at 7,047' MD below the top of the West Sak D sd) • 1J-03 4 Surface casing is set at 7,784' MD below the top of the West Sak D sd) in the AOR. For 1J-118 there (reaching 1,243'MD/618'TVD (reaching 1,612'MD/673'TVD Please let me know if you have any additional questions. Thanks, Sydney Autry West Sak 1E/1J Drillsite Engineer + GKA RWO Coordinator ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Autry, Sydney Sent: Saturday, September 28, 2019 6:33 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Victoria, Sorry for the slow reply - I have been on the slope the last few days and will be up here until Wednesday. I am aiming to send you an updated AOR in the next couple days. Thank you, Sydney Autry From: Loepp, Victoria T (CEO) <victoria.loepp@alaska.¢ov> Sent: Wednesday, September 25, 2019 10:55 AM To: Autry, Sydney<Svdney.Autrv@conocophillips.com> Subject: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Sydney, For any Kuparuk wells identified in the AOR of these wells, is the surface shoe above or below the WSak? 1 Please identify which AIO allows this WAG injection. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V ictoria. LoeppOa laska. g ov CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeop®alaska aov -2500 -3000 500292336400 2070990 KRU U-176 1686 FSL 2461 FWL TWP: 11 S - Range.- 10 E - Sec. 35 for M AOGCC Sept. 23, 2019 -2500 -3000 -- -- _ 3900 a9 W mac- 0200 o M0w0 _. .... L � G 95W �- . 00 �----a 5 " 0900 -y—.-- SOW ^T3 51W 1W 5200- 200'^ 5300 5 MW W SS50 56W t� 5]W 5800 5900,- WW 61W 00 MW 6 W 655W E6W Lhznu C 68 W ]0W 71 10 -_- ]200 T ]'W 7,830' MD: Operator's pic - ]SW noo - cement top from CBL. mudstone W W 6100 nu - -- 6�W — MW No 9]W 99W 89W 90W _ "WCement 920 isolates Ugnu sands 930 W from underlying West Sak woo sands injection intervals. " 4,9]W mudstone 9900— T 99W - mudstone 100 �oiozoo Injection in- terv—ls in -We - - / for M AOGCC Sept. 23, 2019 -2500 -3000 ,, STATE OF ALASKA • AA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other n Pull !so Sleeve Alter Casing r Rill Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Explorator r 207 -100 3. Address: 6. API Number: Stratigraphic r Service pl P. O. Box 100360, Anchorage, Alaska 99510 - 50- 029 - 23364 -60 - - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661, 25662, 25663, 385172 1J -176L1 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17820 feet Plugs (measured) None true vertical 3141 feet Junk (measured) None Effective Depth measured 17783 feet Packer (measured) none true vertical 3141 feet (true vertucal) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20 120 120 SURFACE 3749 13.375 3792 2301 INTERMEDIATE 2040, 8920 10.75 x 9.625 2080 x 11000 1793' x3250' 1 D -SAND LINER 7182 5.5 x 4.5 17784 3442' "' , ENED miw 7, 7 21T1 Perforation depth: Measured depth: slotted liner 11046'- 17365' True Vertical Depth: 3254' -3226' ,.,,._: <, - y, .,v - ,or,s. C nmrniSSion I Tubing (size, grade, MD, and TVD) 4.5, L -80, 10220 MD, 3160 TVD Packers & SSSV (type, MD, and TVD) SSSV - CAMCO 'DB -6' SSSV @ 505 MD and 504 TVD PACKER - BAKER "ML" SEAL ASSEMBLY @ 10215 MD and 3159 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable U1 Treatment descriptions including volumes used and final pressure: SCANNED p 12. Representative Daily Average Production or Injection Data Oil Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 342 786 318 Subsequent to operation 332 803 330 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Developments Service Stratigraphic fl 15. Well Status after work: Oil n Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ r WAG GINJ r SUSP r SPLUG r 16. 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 none Contact Christensen / Humphrey Cad 659 -7535 Printed Name Robert D. Christensen Title Prod Eng Specialist Signature / Phone: 659 -7535 Date /' / 0 iisDMS APR i 20 1 / 4 1 1 611---- ,111 9llg_ Form 10 -404 Revised 10/2010 Submit Original Only • • 1J -176L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary PULLED TYPE 2 ISO SLEEVE FROM 10217' CTMD, TURNED WELL TO PRODUCTION , 11/17/11 JOB COMPLETE. p p i KUP • 1J -176 • ConocoPhillips ;...14 Well Attributes Max Angle & MD TD Welibore API /UWI Field Name Well Status Inc' ( °) MD (ftKB) Act Btm (RKB) 500292336400 WESTSAK INJ 94.09 17,683.99 17,940.0 Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date "' _ SSSV: NIPPLE Last WO: 43.41 10/4/2007 Well Confia -1J -176, 11/30/20119.06.58 AM - Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date - - - -- - Last Tag: Rev Reason: PULL ISO SLEEVE ninam 11/30/2011 HANGER, 36 --mUMP • _ Casing Strings amm Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 44.0 80.0 80.0 94.00 H CONDUCTOR, Casing Description String 0... String 'D... Top (MB) Set Oepth (f... Set Depth (TVD)... String Wt... String Strng Top Thrd 44 SURFACE 133/8 12.415 43.7 3,792.4 2,298.6 68.00 L - 80 BTC SAFETY VLV, Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 504 INTERMEDIATE 95/8 8.835 40.5 11,000.0 3,247.6 40.00 L-80 BTC-m 10.75x9.875" Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS 2,3LIF18 T, D -SAND LINER HH 51/2 4.950 10,236.8 10,634.2 3,209.3 15.50 L -80 BTC-m Liner Details r 0 Top Depth SURFACE, L (TVD) Top Inc! Nome... 44-3192 Top (f6lB) (888) ( "1 Item Description Comment ID (In) SLEEVE, ' 10,236.8 3,163.9 83.81 HANGER Baker Model 'B Hook Hanger 95/8" x 7" (Inside csg) 7.510 1° LOCATOR, 10,257.8 3,166.1 83.72 HANGER Baker Model 'B Hook Hanger 9 5/8" x 7" (Outside csg) 6.290 = 10,191 \ 10,264.1 3,166.8 83.69 X0 BUSHING Crossover Bushing 4.920 PBR, 14195 � 1 ANCHOR, 10,410.1 3,183.4 82.95 ECP RTD ECP 4.650 10,214 \ ■•_ - SEAL ASSY, • I ' 10,602.3 3,205.5 83.22 XO Reducing Crossover 5 BTC box X 4 - 1/2" 3.930 Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - - BSAND LINER I 5 1/2 I 4.900 I 10,457.7 I 17,880.0 I 3,206.4 15.50 I L -80 I Hyd 521 ■ ■ Liner Details ■ I Top Depth (TVD) Top Inc' Nome... e>s I Top (RK8) (RKB) (°) Item Description Comment ID (en) 10,457.7 3,189.7 84.07 PACKER MLZXP Liner Top Packer 9-5/8" ( 8.43" ODx 7.50" ID) 67.5... ,I ' 10, 3,191.8 83.95 HANGER F)exLock Uner Hanger 7" x 9-5/8" ( 8.30" OD x 6.19" ID) 6.190 _ _ 10,484.2 3,192.4 83.91 X0 BUSHING X0 Bushing, 7" hyd 563 x 5-1/2" Hyd 563, (7.65" OD x 4.85" ID) 4.850 ■ _ ■ 10,485.4 3,192.5 83.91 SBE 190-47 Casing Seal Bore EM., Hyd 563 B x P, (6.26" OD x 4.75" ID) 4.750 D -SAND LINER 's_' Casing Description String 0... String ID... Top 1448 Set De t Set Depth TVD)... String Wt... String String Top Thrd LEM, .1 9 P g Y PI ) Depth P( th P( 9 9 B P 10,210 D -SAND LINER LEM 4 1/2 3.958 10,210.2 10,496.3 3,193.6 12.60 L -80 IBT -m 0 -SAND LINER Liner Details • 1111, r Top Depth 10,237- 10.834 a '.3 (TVD) Top Mel Nome... NTER 3 1 Top RKB ( ) Item Description Comment ID I 10 75,9 P 1 ) (888) ° Pion I n) 4011000 10,210.2 3,158.4 82.09 PACKER Baker Torquemaster Packer 813 -47x38 (9.625 ") 3.950 SLOTS, 10,222.7 3,160.1 81.87 HANGER LEM Above Hook Hanger 4 1/2" x 7 5/8" x 9 5/8" 3.960 11,046 -11 496 10,236.8 3,163.9 83.81 HANGER LEM Inside Hook Hanger 4 1/2" x 75/8" x 95/8" 3.688 10,294.7 3,170.0 83.57 NIPPLE Camco 4-1/2" 'D13' Nipple I.D. 3.562" 3.562 10,493.0 3,193.3 83.86 SEAL ASSY Baker Seal Assembly 4-1/2" STL Box up 3.880 Tubing Strings SLOTS, Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1,]ee -tzz TUBING 4 1/2 3.958 35.8 10,219.8 3,159.7 12.60 L -80 IBT -m Completion Details Top Depth 1 ▪ I (TVD) Top Inc! Nome... 1 Top MKS) (1988) (°) Item Description Comment ID (in) 35.8 35.8 -0.14 HANGER Vetco Gray 11" x 4 -1/2" w/ 4.909" MCA Top Connection 3.900 SLOTS. 504.5 504.0 5.39 SAFETY VLV 4 -1/2" Camco "DB-6" Nipple w/ 3.875" No-Go Profile 3.875 12,52° - 12.964 10,112.2 3,146.4 83.82 SLEEVE Baker 4.5 "CMD Sliding Sleeve w/ Camco 3.812 "'0-B' Profile(OPEN) 3.812 10,191.0 3,156.0 82.43 LOCATOR Seal Assembly Locator O.D. 5.24" I.D. 3.88" 3.880 10,195.0 3,156.5 82.36 PBR Baker Polish Bore Receptade O.D. 8.27" I.D. 3.88" 3.880 10,213.6 3,158.9 82.03 ANCHOR Baker Anchor Seal Assy . Crossovers 6.02"O.D.I.D.3.86" 3.860 SLOTS, 10,215.8 3,159.1 81.99 SEAL ASSY Baker "ML" Anchor Seal Assy. I.D. 3.86" 3.860 13,246- 13.717 Perforations & Slots • Shot • Top ITVD) Btm (TVD) Dens Top (8448) Btm (RK8) (RKB) (RK8) Zone Date ("••• Type Comment 11,046 11,498 3,253.5 3,259.5 WS B, 1J- 176 9/14/2007 32.0 SLOTS Entire Liner Aitemating slotted/solid SLOTS, pipe 2.5" x .125" in 4 circumferential 14,011.14,479 rows/ft 3" centers staggered 18 deg, 3' non - slotted ends 11,788 12,239 3,257.8 3,254.4 WS B, 1J -176 9/14/2007 32.0 SLOTS 12,520 12,964 3,249.9 3,247.3 WS B, 1J -176 9/14/2007 32.0 SLOTS 13,246 13,717 3,246.7 3,242.5 WS B, 1J -176 9/14/2007 32.0 SLOTS SLOTS. 14.760 -15 250 14,011 14,479 3,244.8 3,243.2 WS B, 1J -176 9/14/2007 32.0 SLOTS 14,780 15,250 3,243.5 3,239.2 WS 8, 1J -176 9/14/2007 32.0 SLOTS 15,510 15,985 3,237.7 3,242.5 WS B, 1J -176 9/14/2007 32.0 SLOTS 16,241 16,717 3,241.9 3,229.0 WS B, 1J -176 9/14/2007 32.0 SLOTS SLOTS, 16,975 17,365 3,224.7 3,226.4 WS B, 1J -176 9/14/2007 32.0 SLOTS 15,510.10965 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Site TRO Run Stn Top (RKB) (RKB ( °) Make Model (in) seta Type Type (en) (psi) Run Date Com... MY BK 0.000 0.0 10/3/2007 1 2,318.2 1,899.2 65.84 CAMCO KBMG 1 GAS LIFT D SLOTS, 16,241 - 16.717 SLOTS, 16,97547,365 SLOTS, 17,821 - 17.837 B -SAND LINER. 10,458-17,880 TD (1J -176), 1 17,940 a f 1 KUP 1111 1J -176 Conoc > ...... . Alaska. I k.: KB (R) Rig Release Date "' 43.41 10/4/2007 — Well Cone,: -1J -176 11/ 30/7011 9 08 58 AM Schematic - Actual HANGER, 36 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens CONDUCTOR, Top (ftKB) Btm (RKB) (RKB) (RK8) Zone Date (eh..- Type Comment 44 - 80 tom 17,621 17,837 3,223.7 3,209.0 WS B, 1J -176 9/14/2007 32.0 SLOTS SAFETY VLV, imm. Notes: General & Safety II End Date Annotation • 10/4/2007 NOTE: MULTI - LATERAL WELL - 1J -176 (BSAND), 1J -176L1 (D-SAND) GAS LIFT 8/17/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0REV 2,318 emt C SURFAE, 44-G792 AE. SLEEVE. 10,112 leme- LOCATOR, �. 10,191 1 PBR, 10,195 a s ANCHOR, 10.214 \ SEAL ASSY. • - • 10,216 `! 1.1 r1t' I D -SAND LINER LEM. II 10,210 - 10,496 0 -SAND LINER HH, 4aa 10,237 - 10,634 6 NTERMEDIATE T 1 10 7549 875', 40-11,000 SLOTS. 11,046-11.498 SLOTS. 11,7138- 12,239 SLOTS. 12,520- 12,964 SLOTS, 13,246- 13,717 11 .1 . 1 I SLOTS, 14011 - 14,479 SLOTS. 14,780- 16250 SLOTS. 15,51015,985 SLOTS, 16,241- 16,717 SLOTS, 16,975 - 17,365 SLOTS, \ 17,621- 17,837 B -SAND TD (1 LINER. 10,458-17,880 TD (1.1-176). 1 17,940 r } j KUP • 1J -176L1 r ConocoPhillips ° Well Attributes Max Angle & MD TD Ai.,..-1, PI ., Wellbore API /UWI Field Name Well Status Intl ( °) MD (1668) Act Btm (RKB) al 500292336460 WEST SAK INJ 95.10 12,496.19 17,820.0 "" Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date "' SSSV: NIPPLE Last WO: 43.41 10/4/2007 Well Confio - 1J-176L1 1100/2511 9 49.53 AM - Schemalic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date - Last Tag: Rev Reason: PULL ISO SLEEVE ninam 11/30/2011 HANGER. 36 - ... P ■ Casing Strings ga Casing Descripton String 0... String 10 ...Top (RKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd D LINER 14 1/2 I 4 .000 I 10 I 1 7,783.5 3,141.6 I 11.60 I L -80 BTC CONDUCTOR, Liner Details 44 -60 Top Depth (TVD) Top Inc! Noml... SAFETY V Top (RKB) (,KB) (°) Item Description Comment ID (in) 504 10,601.1 3,196.1 87.07 SLEEVE 7.0" Baker "HR" Liner Setting Sleeve w/ 6' TBR 6.280 GAS LIFT, • 10,609.7 3,196.5 87.25 XO Reducing XO Sub 7" Hyd 521 X 5-1/2" Hyd 521 4.900 2,318 SURFACE, 10,656.2 3,198.2 88.21 XO Reducing 5 1/2' Hyd 521 Box X 4 1/2" Hyd 521 Pin XO (3.92" I.D.) 3.920 443,792 SLEEVE. 10,112 Perforations & Slots LOCATOR, Shot 10,191 Dens P64. 10,195 • Top (TVD) Btm (TVD) ANCHOR, Top (RKB) Bbn (RKB) 08K13) (RKB) Zone Date (sh•.• Type Comment 10,214 SEAL ABsy. 10,661 11,118 3,198.4 3,198.3 WS D, 1J - 176L1 9/28/2007 32.0 SLOTS Entire liner altemating slotted /solid Y, 10.216 pipe 2.5" x .125" in 4 circumferential D LINER INV rows/ft, 3" centers staggered 18 deg, OW LEM, M. 10,210 - 10,495 3' ran - slotted ends D - SAND LINER aar. HH,; " 11,367 11,868 3,199.3 3,201.9 WS D, 1J - 176L1 9/28/2007 32.0 SLOTS 10,237 - 18634 - SLOTS, a = - 12,126 12,642 3,197.9 3,175.4 WS D, 1J - 176L1 9/28/2007 32.0 SLOTS 10,661 - 11,118 NTERMEDIATE 12,899 13,370 3,170.7 3,172.5 WS D, 1J-176L1 9/28/2007 32.0 SLOTS 10 75.9 875', 40'11,000 13,629 14,139 3,173.4 3,169.7 WS D, 1J -176L1 9/28/2007 32.0 SLOTS 14 14,867 3,169.3 3,168.4 WS D, 1J -176L1 9128/2007 32.0 SLOTS 15,123 15,643 3,167.9 3,165.7 WS D, 1J -176L1 9/28/2007 32.0 SLOTS 15,891 16,36 2 6,621 2 3,166.6 3,162.7 WS D, 1J -176L1 9128/2007 32.0 SLOTS 1 17,136 3 otes: Gener ,163.2 3,149.3 WS D, 1J -176L1 9/28/2007 32.0 SLOTS 17,351 17,738 3,143.6 3,141.9 WS D, 1J -176L1 9/28/2007 32.0 SLOTS Nal & Safety End Date Annotation 10/3/2007 NOTE: MULTI - LATERAL WELL - 1J -176 (B- SAND), 1J -176L1 (D -SAND) 8/17/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV SLOTS, 11367 -11858 SLOTS, 12,126- 12,642 SLOTS, 12,899 - 13,370 SLOTS, 13,629 - 14,139 SLOTS. 1 II 14,398 - 14,867 SLOTS, 15,123 - 15,643 SLOTS, 15.891 - 16,362 Mandrel Details Top Depth Top Port (TVD) lncl 00 Valve Latch Size TRO Run Stn Top (RKB) (tee) ( °) Make Model (in) Sery Type Type lin) (psi) Run Data Com... 1 2,318.2 1,899.2 65.84 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2007 SLOTS, 16,621-17,136 SLOTS. 17,51- 17,738 D -SAND LINER, 10,801- 17,784 TD (1J.176L1), 17,820 . • ._~. ~~, ~4 ,°~ ~-~~ '~' ~, ~_ MICROFILMED 6/30/2010 DO NOT PLACE ANY .NEW .MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-176+L1 May 18, 2009 AK-MW-5126703 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-176+L1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: Color Log 50-029-23364-00,60 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: Color Log 50-029-23364-00,60 Digital Log Images 2 CD Rom 50-029-23364-00,60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Bryan.Bunnda@halliburto com ~~~ Date: _ _ ZOG9 Signed: (~ ~ ~ ~p~- ~ ! o U ~ ~ ~~ so ~~amissio€? ~s ~QI has ~~ Lrd'w •: t. V iJ:J 9 DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2071000 Well Name/No. KUPARUK RIV U WSAK 1J-176L1 Operator CONOCOPHILLIPS ALASKA INC MD 17820 TVD 3141 Completion Date 10/4/2007 Completion Status 1-OIL Current Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No Directional Su ey Yes i DATA INFORMATION Types Electric or Other Logs Run: GR/RES, CBL, USIT Well Log Information: Log/ Electr Data Digital Dataset Tvge Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments D D Asc Directional Survey t ~ Directionai Survey ~ pt LIS Verification C Lis 15982 Induction/Resistivity ~L 40 17820 Open 12/3/2007 40 17820 Open 1 2/312 0 0 7 3769 17820 Open 2/29/2008 LIS Veri, GR, FET, RPM, RPD, RPS, RPX, ROP 3769 17820 Open 2!29/2008 LIS Veri, GR, FET, RPM, RPD, RPS, RPX, ROP Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ^ Well Cored? Y~ Daily History Received? /v,)~,'~~ Chips Received? ~l'.I~L Formation Tops Y / N Analysis ~f-fd' Received? Comments: Compliance Reviewed By: API No. 50-029-23364-60-00 Date: "- • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPE .y , 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate .~ ~ Q Pre-Prod to !nj Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ ~ r ~ , "IOff ^ ~a'7/ ' Change Approved Program ^ Operat. Shutdown^ Perforate ^ ~ 7 ~-• Re-~us ended Well 2. Operator Name: 4. Current Well Status: ~a< ~ ~,f er. COnocoPhllllpS Alaska, InC. Development ^ Exploratory ~1 ~' 207-100 3. Address: Stratigraphic ^ Service ~ 6. A I Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23364-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 121' 1J-176L1 8. Property Designation: 10. Field/Pool(s): ALK 25661, 25662, 25663, 385172 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17820' feet true vertical 3141' feet Plugs (measured) Effective Depth measured 17783' feet Junk (measured) true vertical 3142' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3671' 13-3/8" 3792' 2299' INTERMEDIATE 1959' 10-3/4" 2080' 1794' INTERMEDIATE 8920' 9-5/8" 11000' 3251' D-SAND WIND01 1' 7-5/8" 10239' 3162' D-SAND SLOTTED LINER 7182' 4-1 /2" 17783' 3142' Perforation depth: Measured depth: 10661' - 17738' true vertical depth: 3144' - 3202' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10219' MD. Packers &SSSV (type & measured depth) PKR =Baker Torqu emaster 813-47, MLZXP Li ner Top Pkr PKR = 10210', 10458' SSSV= NIP SSSV= 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 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 1045 320 30 789 274 Subsequent to operation 2238 1511 237 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 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: 307-356 Contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title ., Production Engineering Technician /~~ Signature y %' one 659-7535 Date -, /Z~~~ / ~~ ~~~~ Form 10-404 Revised 04/2004 ~ ~ ~ ~ ~ ~ ~~ ' S Submit Origi~~y 1J-176L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/21/08 Commenced Water Injection WELL LOG TRANSMITTAL To: State of Alaska February 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-176 L1 AK-MW-5126703 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 3 64-60 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 ~ ~ 5 ~, ~ ~ Date: - ,L ~'~) ~_ ,~ Signed: ~o~-r od ~ ~ ~~ 2 ~'~ ~ ~' ~ 3r~ ~ „{_~ ConocoPhillips January 29, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: J. Eggemeyer Engineering Leader Drilling 8~ Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 a~~ _ ,t ;`,1~iy .e. i~.~ -. A 5'v ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 3Q-11, 1 J-137, 1 C-104, 1 E-29, 1 J-176, 1 J-176L1, 1 J-107 and 1 J-107L1 you requested. These summaries will replace the shorter summaries already submitted with the completion reports for these wells. If you have any questions regarding this matter, please contact me at 265-6049. << s~ ~ Sincerely, ~~~~ . Eggemeyer Engineering Team Leader CPAI Drilling wF. i- JE/skad • Page 1 of 1 Maunder, Thomas E (D4A) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 12, 2007 10:27 AM To: Eggemeyer, Jerome C. Subject: 1J-176 (207-099) and 1J-176L1 (207-100) Jerome, Further to our discussions, would you please provide the detailed operations reports for the following well {s)/operations. 1J-176 (207-099) One copy of the full summary (-176 8~ -176L1j 1J-176 (207-100) Summary for lateral (-176L1) only Thanks in advance. Call or message wi#h any questions. Tom Maunder, PE AOGCC ~~~ ~f ~~ Lp~ Q ~ 2/4/2008 CormcoPhillips November 9, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7~' Avenue Suite 100 Anchorage, Alaska 99501 Subject: Welt Completion Reports for 1J-17fi and 1J-176L1 Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak mulfi-lateral 1J-176 and 1J- 176t_1. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, ~__ ---__. _: : R. Thomas Kuparuk Drilling Team Leader CPAI Drilling • Randy Thom Kuparuk Driifing Team Leader Drilling & We11s RTlskad K~t~G~ v ~~ STATE OF ALASKA ~ ~~~ 1 ~ z~o~ ALASKA OIL AND GAS CONSERVATION COMMISSION k ~ ~ S Cr~t1~. ~g111C1'1~SSI~t~ WELL COMPLETION OR RECOMPLETION REPO ~-~V , 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: October 4, 2007 ~ 12. Permit to Drill Number: 207-100 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: September 18, 2007 13. API Number: S0-029-23364-60 " 4a. Location of Well (Governmental Section): Surface: 1686' FSL, 2461' FEL, Sec. 35, T11 N, R10E, UM 7. Date TD Reached: September 25, 2007 14. Well Name and Number: 1J-176L1 Top of Productive Horizon: 1087' FSL, 1805' FWL, Sec. 3, T10N, R10E, UM 8. KB (ft above MSL): 41' RKB Ground (ft MSL): 122' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1211' FNL, 1898' FWL, Sec. 15, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 17783' MD / 3142' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558751 ~ y- 5945498 ~ Zone- 4 10. Total Depth (MD + TVD): ~ 17820' MD / 3141' TVD ~ 16. Properly Designation: ALK 25661, 25662, 25663, 385172 TPI: x- 552510 y- 5939574 Zone- 4 Total Depth: x- 552669 - 5931998 Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 504' MD / 504 TVD 17. Land Use Permit: 471, 2177, 472, 2181 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1537' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): cop of window @ to2aa~ MD GR/RES, CBL, USIT 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" x 34" 78.6# H-40 41' 120' 41' 120' 42" 326 sx AS 1 13.375" 68# L-80 41' 3792' 41' 2301' 16" 800 sx Class G, 210 sx Class G 10.75" x 73.2# L-80 41' 2080' 41' 1793' 12.25" 921 sx DeepCRETE 9.625" 40# L-80 2080' 11000' 1793' 3250' 12.25" included above 5.5" x 4.5" 15.5# x 11.6# L-80 10237' 17783' 3162' 3142' 8.5" slotted/blank liner 23. Open to production or injection? Yes Q No If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore na 10419' alternating slotted liner from: 10601'-10661', 11118'-11366', 11868'-11953', 12642'-12899', 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13369'-13629', 14138'-14398', 14867'-15122', 15643'-15891', DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 16362'-16621', 17136'-17351' MD na 26. PRODUCTION TEST Date First Production November 5, 2007 Method of Operation (Flowing, gas lift, etc.) pre-produced injector -gas lift oil -shares injection with 1J-176 Date of Test 11/6/2007 Hours Tested 12 hours Production for Test Period -> OIL-BBL 1024 GAS-MCF 1268 WATER-BBL 36 CHOKE SIZE 40 Bean GAS-OIL RATIO 1137 Flow Tubing press. 397 psi Casing Pressure 961 Calculated 24-Hour Rate -> OIL-BBL 2032 GAS-MCF 2256 WATER-BBL 73 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071.... ~O .'_.7~. b?' NONE __ ,~11.~._..®, Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE .~:~~. ~l~P: ~ ~~ao~ ,SSA i~•~L.e7 ~~~~ ~~f~~i~ ORIGINAL r~ ~1 28. GEOLOGIC MARKERS (List all formations and ma rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1730' 1537' needed, and submit detailed test information per 20 AAC 25.071.. T3 3750' 2289' K15 3750' 2289' Ugnu C 6682' 2700' Ugnu B 7850' 2858' Ugnu A 8222' 2905' K13 9153' 3023' West Sak D 10236' 3162' West Sak C 17820' 3141' West Sak B 17820' 3141' N/A Formation at total depth: West Sak D 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet, cement detail summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 Printed Name Rand Thomas Title: Drilling Team Leader _, Signature ~~=-~ s~-~~ ~='v,.~ ._...~..P.hone .- Date l ( ~dr1 ~a 2 G : ~ ' ' c .Sr< INSTRUCTIONS Sharon Allsup-D2ke General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a 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 and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report ('umpan}: ConocoPhl!lips Alaska Inc. lAatc: 10/11/2007 Cimc 13.4G:54 I'n~c: I~icld: KuparukRiverUnit Co-ordinate(~1:)keference: V~Je11:1J-176,Tr u~North tiitr. Kuparuk 1J Pad Vc rticai (T~'I)1 Re ference: 1J-176 Actual RTE 121.5 ~~'cll: 1 J-176 Sec tiun (~~S) Reter encc Well (O.OON,O.OOE,130.OOAzI) ~1c1lp»tli: 1J-176L1 _ Su~ _ _ ze~ Csilculatio nMethod: MinimumCuiva __ ture llb: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-176 Slot Name: API 50-029-23360-00 Well Position: +N/-S -421.31 ft Northing: 5945498.05 ft Latitude: 70 15 42.114 N +E/-W -42.35 ft Easting : 558750.89 ft Longitude: 149.31 30.239 W Position Uncertainty: 0.00 ft Wellpath: 1J-176L1 Drilled From: 1J-176 API 50-029-23360-60 Tie-on Depth: 10231.12 ft Current Datum: 1 J-176 Actual RTE: Height 121.55 ft ~ Above System Datum: Mean Sea Level Magnetic Data: 8/10/2007 Declination: 23.23 deg ~ Field Strength: 57616 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.55 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 9/25/2007 Validated: Yes Version: 7 Actual From To Survey Toolcode Tool Name ft ft 50.00 465.00 1J-176 Gyro (50.00-465.00) (0) CB-GYRO-SS Camera based gyro single shot i 507.85 10231.12 1J-176 IIFR+MS+SAG (507.85-179 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 10238.00 17782.64 1J-176L1 IIFR+MS+SAG (10238.00 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey - -- - -- ~11D Incl ~zim TVD tiffs i!D \/S E/N' Ma~~A ~1npF Too! '~ ft deg deg ft ft ft ft ft ft 40.55 0.00 0.00 40.55 -81.00 0.00 0.00 5945498.05 558750.89 TIE LINE 50.00 0.28 140.37 50.00 -71.55 -0.02 0.01 5945498.03 558750.90 CB-GYRO-SS 112.00 0.38 147.90 112.00 -9.55 -0.31 0.22 5945497.74 558751.11 CB-GYRO-SS 182.00 0.56 148.16 182.00 60.45 -0.80 0.52 5945497.26 558751.42 CB-GYRO-SS I 243.00 1.10 164.35 242.99 121.44 -1.61 0.84 5945496.44 558751.74 CB-GYRO-SS I 300.00 1.00 188.94 299.98 178.43 -2.63 0.91 5945495.43 558751.82 CB-GYRO-SS 370.00 2.98 200.56 369.94 248.39 -4.94 0.18 5945493.11 558751.10 CB-GYRO-SS 465.00 5.08 214.90 464.70 343.15 -10.70 -3.10 5945487.33 558747.88 CB-GYRO-SS 507.85 5.50 213.54 507.36 385.81 -13.97 -5.32 5945484.04 558745.68 MWD+IFR-AK-CAZ-SC 603.13 8.60 229.53 601.92 480.37 -22.40 -13.26 5945475.55 558737.80 MWD+IFR-AK-CAZ-SC 698.04 12.17 234.19 695.26 573.71 -32.86 -26.78 5945464.98 558724.37 MWD+IFR-AK-CAZ-SC 792.82 14.51 233.23 787.48 665.93 -45.82 -44.39 5945451.89 558706.86 MWD+IFR-AK-CAZ-SC 887.72 16.43 228.96 878.94 757.39 -61.75 -64.04 5945435.81 558687.34 MWD+IFR-AK-CAZ-SC 983.88 20.94 224.92 970.01 848.46 -82.86 -86.45 5945414.53 558665.10 MWD+IFR-AK-CAZ-SC 1079.22 22.55 224.50 1058.57 937.02 -107.96 -111.29 5945389.23 558640.46 MWD+IFR-AK-CAZ-SC 1174.35 25.37 225.31 1145.49 1023.94 -135.31 -138.57 5945361.68 558613.39 MWD+IFR-AK-CAZ-SC 1268.88 29.96 223.89 1229.19 1107.64 -166.58 -169.35 5945330.17 558582.86 MWD+IFR-AK-CAZ-SC i 1364.04 32.74 224.46 1310.45 1188.90 -202.08 -203.85 5945294.41 558548.64 MWD+IFR-AK-CAZ-SC i 1455.53 37.35 225.23 1385.33 1263.78 -239.30 -240.90 5945256.90 558511.88 MWD+IFR-AK-CAZ-SC I 1554.45 40.75 227.35 1462.15 1340.60 -282.32 -285.97 5945213.53 558467.16 MWD+IFR-AK-CAZ-SC 1648.79 44.27 227.79 1531.68 1410.13 -325.32 -333.02 5945170.18 558420.45 MWD+IFR-AK-CAZ-SC 1744.01 49.20 226.53 1596.92 1475.37 -372.47 -383.82 5945122.63 558370.02 MWD+IFR-AK-CAZ-SC 1840.11 52.92 225.69 1657.31 1535.76 -424.29 -437.67 5945070.40 558316.59 MWD+IFR-AK-CAZ-SC 1936.10 54.46 226.69 1714.15 1592.60 -477.83 -493.49 5945016.43 558261.19 MWD+IFR-AK-CAZ-SC 2030.77 56.87 227.77 1767.55 1646.00 -530.90 -550.88 5944962.92 558204.22 MWD+IFR-AK-CAZ-SC 2125.41 61.13 227.77 1816.28 1694.73 -585.41 -610.93 5944907.94 558144.60 MWD+IFR-AK-CAZ-SC i 2220.83 63.29 231.20 1860.77 1739.22 -640.22 -675.11 5944852.64 558080.86 MWD+IFR-AK-CAZ-SC 2316.40 66.40 232.08 1901.39 1779.84 -693.89 -742.93 5944798.45 558013.46 MWD+IFR-AK-CAZ-SC ~:. Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. I?ate: 1011 1!2G0? "time 13:46:54 Pa~c: riddc Kuparuk River Unit Co-ordin:atc(NE)Refet~cncc well: 1J-176; True Notth tine: Kuparuk 1J Pad Vertical (l'~"D)Reference: 1J-176 Actlr3l RTE: 121.5 ~~rll: 1J-176 Section (~'S)Reference: Well (QOON,O.OOE,180.OOAzi) ~~cllpath: 1J-176L1 Sunny Calculation Melhod: Minimum Curvature Db: Orade __ __ _. Sun c~ ~1D ~ncl Azim I~~I) SysTVD V/S F./~1~ ~lapti Map F, -Fool ft deg deg ft ft ft ft ft ft --- _ ___ 2410.66 69.11 233.32 1937.07 1815.52 -746.75 -812.33 5944745.06 557944.49 MWD+IFR-AK-CAZ-SC 2505.98 72.48 232.27 1968.43 1846.88 -801.17 -884.01 5944690.08 557873.24 MWD+IFR-AK-CAZ-SC 2601.29 75.13 231.63 1995.01 1873.46 -857.59 -956.08 5944633.11 557801.62 MWD+IFR-AK-CAZ-SC 2696.35 74.79 230.65 2019.67 1898.12 -915.18 -1027.56 5944574.97 557730.60 MWD+IFR-AK-CAZ-SC 2791,94 73.94 231.29 2045.44 1923.89 -973.15 -1099.07 5944516.45 557659.55 MWD+IFR-AK-CAZ-SC 2886.58 74.74 228.96 2070.99 1949.44 -1031.57 -1168.99 5944457.49 557590.09 MWD+IFR-AK-CAZ-SC 2982.65 74.24 229.16 2096.68 1975.13 -1092.23 -1238.92 5944396.29 557520.65 MWD+IFR-AK-CAZ-SC 3076.93 74.05 229.47 2122.43 2000.88 -1151.35 -1307.70 5944336.64 557452.34 MWD+IFR-AK-CAZ-SC 3171.43 75.02 227.38 2147.63 2026.08 -1211.79 -1375.82 5944275.68 557384.70 MWD+IFR-AK-CAZ-SC 3263.31 75.47 227.26 2171.03 2049.48 -1272.02 -1441.14 5944214.94 557319.86 MWD+IFR-AK-CAZ-SC 3363.06 76.88 227.45 2194.87 2073.32 -1337.64 -1512.39 5944148.78 557249.13 MWD+IFR-AK-CAZ-SC 3455.78 75.34 228.39 2217.13 2095.58 -1397.96 -1579.19 5944087.95 557182.81 MWD+IFR-AK-CAZ-SC 3550.86 75.70 230.18 2240.90 2119.35 -1458.01 -1648.96 5944027.36 557113.51 MWD+IFR-AK-CAZ-SC 3646.36 76.34 231.10 2263.98 2142.43 -1516.78 -1720.61 5943968.04 557042.33 MWD+IFR-AK-CAZ-SC 3741.68 75.54 229.96 2287.13 2165.58 -1575.55 -1791.99 5943908.72 556971.42 MWD+IFR-AK-CAZ-SC 3766.00 76.36 230.27 2293.04 2171.49 -1590.68 -1810.09 5943893.45 556953.43 MWD+IFR-AK-CAZ-SC 3859.44 79.65 231.46 2312.45 2190.90 -1648.35 -1880.98 5943835.23 556883.01 MWD+IFR-AK-CAZ-SC 3955.16 81.94 231.91 2327.76 2206.21 -1706.93 -1955.11 5943776.09 556809.34 MWD+IFR-AK-CAZ-SC 4049.94 82.72 230.90 2340.42 2218.87 -1765.52 -2028.53 5943716.92 556736.39 MWD+IFR-AK-CAZ-SC 4144.42 81.41 231.87 2353.46 2231.91 -1823.92 -2101.64 5943657.96 556663.75 .MWD+IFR-AK-CAZ-SC 4240.65 81.34 232.00 2367.89 2246.34 -1882.58 -2176.54 5943598.73 556589.31 MWD+IFR-AK-CAZ-SC 4335.58 81.41 232.32 2382.13 2260.58 -1940.16 -2250.67 5943540.58 556515.65 MWD+IFR-AK-CAZ-SC 4430.82 80.73 234.18 2396.91 2275.36 -1996.45 -2326.05 5943483.71 556440.71 MWD+IFR-AK-CAZ-SC 4526.77 81.71 233.64 2411.56 2290.01 -2052.31 -2402.67 5943427.26 556364.53 MWD+IFR-AK-CAZ-SC ~ 4621.32 81.04 233.61 2425.74 2304.19 -2107.75 -2477.94 5943371.24 556289.71 MWD+IFR-AK-CAZ-SC 4716.18 81.60 231.97 2440.05 2318.50 -2164.45 -2552.62 5943313.96 556215.48 MWD+IFR-AK-CAZ-SC I 4809.82 82.82 232.97 2452.75 2331.20 -2220.97 -2626.19 5943256.87 556142.36 MWD+IFR-AK-CAZ-SC 4907.74 82.04 234.17 2465.65 2344.10 -2278.61 -2704.29 5943198.63 556064.72 MWD+fFR-AK-CAZ-SC 5002.74 83.69 234.71 2477.44 2355.89 -2333.43 -2780.97 5943143.22 555988.48 MWD+IFR-AK-CAZ-SC 5098.08 82.22 235.66 2489.14 2367.59 -2387.45 -2858.65 5943088.60 555911.23 MWD+IFR-AK-CAZ-SC 5193.62 82.41 234.48 2501.91 2380.36 -2441.66 -2936.27 5943033.79 555834.04 MWD+IFR-AK-CAZ-SC 5288.38 82.40 233.42 2514.44 2392.89 -2496.93 -3012.21 5942977.93 555758.54 MWD+IFR-AK-CAZ-SC 5383.52 81.97 232.70 2527.38 2405.83 -2553.58 -3087.55 5942920.71 555683.65 MWD+IFR-AK-CAZ-SC ~ 5478.65 82.03 232.98 2540.62 2419.07 -2610.48 -3162.62 5942863.22 555609.03 MWD+IFR-AK-CAZ-SC 5573.99 82.72 233.76 2553.27 2431.72 -2666.86 -3238.46 5942806.26 555533.65 MWD+IFR-AK-CAZ-SC 5668.39 82.66 233.72 2565.28 2443.73 -2722.24 -3313.96 5942750.30 555458.59 MWD+IFR-AK-CAZ-SC 5763.67 83.03 232.73 2577.15 2455.60 -2778.84 -3389.68 5942693.12 555383.32 MWD+IFR-AK-CAZ-SC 5858.54 81.65 232.25 2589.79 2468.24 -2836.09 -3464.26 5942635.29 555309.19 MWD+IFR-AK-CAZ-SC ~ 5954.56 82.48 232.77 2603.05 2481.50 -2893.97 -3539.72 5942576.83 555234.19 MWD+IFR-AK-CAZ-SC 6049.78 83.09 232.64 2615.01 2493.46 -2951.21 -3614.87 5942519.02 555159.50 MWD+IFR-AK-CAZ-SC 6144.85 82.22 233.75 2627.16 2505.61 -3007.69 -3690.36 5942461.95 555084.46 MWD+IFR-AK-CAZ-SC 6240.06 81.78 234.89 2640.41 2518.86 -3062.68 -3766.95 5942406.37 555008.31 MWD+IFR-AK-CAZ-SC ~ 6334.76 82.89 235.01 2653.04 2531.49 -3116.58 -3843.78 5942351.87 554931.91 MWD+IFR-AK-CAZ-SC 6428.04 82.40 234.81 2664.98 2543.43 -3169.76 -3919.48 5942298.11 554856.64 MWD+IFR-AK-CAZ-SC ! 6523.51 81.60 234.71 2678.27 2556.72 -3224.31 -3996.69 5942242.96 554779.86 MWD+IFR-AK-CAZ-SC 6618.77 82.53 233.15 2691.42 2569.87 -3279.86 -4072.95 5942186.83 554704.04 MWD+IFR-AK-CAZ-SC 6713.92 82.34 231.36 2703.95 2582.40 -3337.60 -4147.53 5942128.52 554629.92 MWD+IFR-AK-CAZ-SC 6808.96 82.34 231.19 2716.62 2595.07 -3396.52 -4221.02 5942069.03 554556.91 MWD+IFR-AK-CAZ-SC 6904.50 82.47 231.42 2729.24 2607.69 -3455.73 -4294.93 5942009.25 554483.46 MWD+IFR-AK-CAZ-SC 6997.91 82.47 231.92 2741.49 2619.94 -3513.16 -4367.57 5941951.26 554411.28 MWD+IFR-AK-CAZ-SC 7093.21 81.52 231.96 2754.76 2633.21 -3571.34 -4441.88 5941892.51 554337.44 MWD+IFR-AK-CAZ-SC 7187.59 81.79 233.26 2768.45 2646.90 -3628.04 -4516.07 5941835.24 554263.70 MWD+IFR-AK-CAZ-SC I Halliburton Company Survey Report Cunipany: ConocoPhillips Alaska Int. U»tc 10/11!2007 Time: 13:46:54 Pnt!c: S Field: Kuparok River Unit (~o-o rdin:~te(NE)Reference: Weli: 1J-176, True North Site Kuparuk 1J f ad ~~erticN{ (1 ~:D) References 1 J-176 Actual R7E' 121.5 ~~cll: 1J-176 Secfiou(VS)Referencc Well(O.OON,O-OOE180.OOAzi) ~~ellpadh: 1 J-176L1 Survey Calculation Method: Minimum Curvature Db; Orade Sun c~ ~~iD fncl ~zim TVD Sy~IVD. A!S L11~` -- Di.~pS V~pI~: fool ft deg deg ft ft ft ft ft ft - -__ _ ' 7283.87 81.16 234.99 2782.73 2661.18 -3683.84 -4593.22 5941778.84 554186.99 MWD+IFR-AK-CAZ-SC 7378.39 81.61 236.06 2796.89 2675.34 -3736.74 -4670.26 5941725.35 554110.38 MWD+IFR-AK-CAZ-SC 7474.55 82.34 235.52 2810.31 2688.76 -3790.27 -4749.00 5941671.21 554032.06 MWD+IFR-AK-CAZ-SC 7568.95 82.79 235.87 2822.53 2700.98 -3843.03 -4826.32 5941617.86 553955.16 MWD+IFR-AK-CAZ-SC 7663.86 82.90 235.48 2834.35 2712.80 -3896.13 -4904.09 5941564.16 553877.81 MWD+IFR-AK-CAZ-SC 7757.92 82.85 235.27 2846.02 2724.47 -3949.16 -4980.90 5941510.53 553801.43 MWD+IFR-AK-CAZ-SC 7851.65 82.78 232.81 2857.74 2736.19 -4003.76 -5056.16 5941455.35 553726.60 MWD+IFR-AK-CAZ-SC 7948.47 82.90 231.82 2869.81 2748.26 -4062.49 -5132.19 5941396.04 553651.05 MWD+IFR-AK-CAZ-SC 8043.22 82.03 232.35 2882.23 2760.68 -4120.21 -5206.29 5941337.75 553577.40 MWD+IFR-AK-CAZ-SC 8138.71 82.90 232.54 2894.75 2773.20 -4177.91 -5281.34 5941279.47 553502.81 MWD+IFR-AK-CAZ-SC I 8233.34 82.29 233.46 2906.95 2785.40 -4234.38 -5356.28 5941222.41 553428.32 MWD+IFR-AK-CAZ-SC 8328.89 83.21 233.41 2919.01 2797.46 -4290.85 -5432.41 5941165.36 553352.64 MWD+IFR-AK-CAZ-SC 8424.16 82.78 232.69 2930.63 2809.08 -4347.69 -5507.98 5941107.94 553277.53 MWD+IFR-AK-CAZ-SC 8518.47 82.29 229.54 2942.88 2821.33 -4406.38 -5580.76 5941048.69 553205.21 MWD+IFR-AK-CAZ-SC 8613.89 83.33 227.84 2954.83 2833.28 -4468.88 -5651.86 5940985.65 553134.60 MWD+IFR-AK-CAZ-SC 8710.11 83.72 224.95 2965.68 2844.13 -4534.81 -5721.09 5940919.18 553065.91 MWD+IFR-AK-CAZ-SC 8804.60 81.66 224.02 2977.70 2856.15 -4601.67 -5786.76 5940851.82 553000.77 MWD+IFR-AK-CAZ-SC 8899.48 81.35 222.58 2991.72 2870.17 -4669.96 -5851.11 5940783.04 552936.95 MWD+IFR-AK-CAZ-SC ~ 8995.13 83.19 221.78 3004.58 2883.03 -4740.19 -5914.75 5940712.31 552873.87 MWD+IFR-AK-CAZ-SC 9088.93 83.41 218.53 3015.53 2893.98 -4811.38 -5974.81 5940640.66 552814.37 MWD+IFR-AK-CAZ-SC I 9185.04 82.28 215.28 3027.50 2905.95 -4887.62 -6032.07 5940563.98 552757.71 MWD+IFR-AK-CAZ-SC 9280.71 81.97 211.28 3040.62 2919.07 -4966.83 -6084.06 5940484.38 552706.34 MWD+IFR-AK-CAZ-SC 9375.66 83.20 208.19 3052.87 2931.32 -5048.58 -6130.75 5940402.28 552660.30 MWD+IFR-AK-CAZ-SC 9470.78 82.77 204.05 3064.50 2942.95 -5133.33 -6172.31 5940317.22 552619.41 MWD+IFR-AK-CAZ-SC 9562.91 82.10 200.51 3076.63 2955.08 -5217.82 -6206.93 5940232.46 552585.45 MWD+IFR-AK-CAZ-SC ~ 9661.87 83.15 195.76 3089.34 2967.79 -5311.06 -6237.46 5940139.00 552555.65 MWD+IFR-AK-CAZ-SC 9756.53 81.85 191.76 3101.70 2980.15 -5402.20 -6259.79 5940047.70 552534.04 MWD+IFR-AK-CAZ-SC it 9851.38 82.34 188.40 3114.75 2993.20 -5494.68 -6276.23 5939955.10 552518.32 MWD+IFR-AK-CAZ-SC 9946.55 83.21 185.17 3126.72 3005.17 -5588.42 -6287.38 5939861.29 552507.91 MWD+IFR-AK-CAZ-SC 10041.69 83.21 180.76 3137.97 3016.42 -5682.74 -6292.26 5939766.94 552503.76 MWD+IFR-AK-CAZ-SC i 10135.44 83.41 177.64 3148.90 3027.35 -5775.83 -6290.96 5939673.87 552505.78 MWD+IFR-AK-CAZ-SC 10231.12 81.72 177.78 3161.28 3039.73 -5870.63 -6287.17 5939579.11 552510.31 MWD+IFR-AK-CAZ-SC 10238.00 81.84 177.76 3162.26 3040.71 -5877.43 -6286.91 5939572.31 552510.63 MWD+IFR-AK-CAZ-SC 10313.33 83.56 177.62 3171.83 3050.28 -5952.09 -6283.89 5939497.69 552514.23 MWD+IFR-AK-CAZ-SC 10409.68 84.17 177.43 3182.13 3060.58 -6047.80 -6279.76 5939402.03 552519.11 MWD+IFR-AK-CAZ-SC 10499.73 85.92 177.26 3189.91 3068.36 -6137.41 -6275.60 5939312.46 552523.96 MWD+IFR-AK-CAZ-SC 10596.08 86.97 177.08 3195.88 3074.33 -6233.46 -6270.85 5939216.46 552529.46 MWD+IFR-AK-CAZ-SC 10691.69 88.94 176.90 3199.29 3077.74 -6328.87 -6265.84 5939121.10 552535.22 MWD+IFR-AK-CAZ-SC 10786.77 88.88 175.49 3201.10 3079.55 -6423.72 -6259.53 5939026.31 552542.27 MWD+IFR-AK-CAZ-SC ~ j 10882.14 90.73 176.61 3201.43 3079.88 -6518.86 -6252.96 5938931.23 552549.58 MWD+IFR-AK-CAZ-SC ~ 10975.91 91.41 176.86 3199.68 3078.13 -6612.46 -6247.62 5938837.69 552555.65 MWD+IFR-AK-CAZ-SC 11071.35 89.93 178.67 3198.56 3077.01 -6707.81 -6243.90 5938742.37 552560.11 MWD+IFR-AK-CAZ-SC 11166.69 89.81 179.86 3198.78 3077.23 -6803.14 -6242.67 5938647.07 552562.08 MWD+VFR-AK-CAZ-SC 11261.88 90.61 183.96 3198.43 3076.88 -6898.26 -6245.85 5938551.94 552559.65 MWD+IFR-AK-CAZ-SC 11356.18 87.58 180.76 3199.92 3078.37 -6992.44 -6249.73 5938457.73 552556.50 MWD+iFR-AK-CAZ-SC 11450.94 88.76 180.13 3202.94 3081.39 -7087.15 -6250.46 5938363.03 552556.51 MWD+IFR-AK-CAZ-SC 11545.96 90.18 180.31 3203.82 3082.27 -7182.16 -6250.83 5938268.03 552556.88 MWD+IFR-AK-CAZ-SC 11640.74 91.04 180.19 3202.81 3081.26 -7276.94 -6251.24 5938173.27 552557.21 MWD+IFR-AK-CAZ-SC 11735.91 89.56 178.80 3202.32 3080.77 -7372.10 -6250.40 5938078.12 552558.79 MWD+IFR-AK-CAZ-SC ' 11830.55 90.36 178.64 3202.38 3080.83 -7466.71 -6248.29 5937983.54 552561.64 MWD+IFR-AK-CAZ-SC 11925.77 90.55 178.08 3201.63 3080.08 -7561.89 -6245.56 5937888.39 552565.11 MWD+IFR-AK-CAZ-SC ~! 12020.06 90.98 178.59 3200.37 3078.82 -7656.13 -6242.83 5937794.19 552568.58 MWD+IFR-AK-CAZ-SC 12115.95 91.60 178.79 3198.21 3076.66 -7751.97 -6240.63 5937698.37 552571.52 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (bmpan~: ConocoPhillips Alaska (rar. ihitc 10/11/2007 Y ime: 13'46'.54 P:iL'c: -t Field: Kuparuk River Unit (b-ordiu:~tc(NE)Refen•nce: Well' tJ-176, True North Silt Kuparuk 1J Pad ~~crtical (f~~D)Reference:, 1J-176 Actual RTE: 121.5 ~~ell: 1J-176 Section 1~'tifReterence: Well (O.OON.O.OOE,180.OOAzi) Wetipalh: 1J-176L1 Sun~e~ Calcuiatian>111eihod: Minimum Curvature Dh: Oracle Surcc~ ~lll Intl laim fYU 5~ l~~D V!S F.%~~' ~lapti~ ~tapl: fool ft deg deg ft ft ft ft ft ft 12211.08 90.73 179.96 3196.27 3074.72 -7847.07 -6239.60 5937603.29 552573.30 MWD+IFR-AK-CAZ-SC 12306.36 93.12 179.92 3193.07 3071.52 -7942.29 -6239.50 5937508.09 552574.14 MWD+IFR-AK-CAZ-SC 12401.64 92.96 179.55 3188.02 3066.47 -8037.44 -6239.06 5937412.96 552575.33 MWD+IFR-AK-CAZ-SC 12496.20 95.10 181.87 3181.37 3059.82 -8131.74 -6240.22 5937318.65 552574.90 MWD+IFR-AK-CAZ-SC 12591.30 90.85 181.04 3176.44 3054.89 -8226.66 -6242.63 5937223.73 552573.23 MWD+IFR-AK-CAZ-SC 12686.01 90.98 180.38 3174.93 3053.38 -8321.35 -6243.81 5937129.04 552572.79 MWD+IFR-AK-CAZ-SC 12782.13 91.66 179.94 3172.71 3051.16 -8417.45 -6244.07 5937032.96 552573.27 MWD+IFR-AK-CAZ-SC 12877.92 90.55 179.30 3170.87 3049.32 -8513.21 -6243.44 5936937.21 552574.66 MWD+IFR-AK-CAZ-SC 12971.66 90.24 179.26 3170.22 3048.67 -8606.94 -6242.26 5936843.50 552576.57 MWD+IFR-AK-CAZ-SC 13067.33 89.56 180.04 3170.39 3048.84 -8702.61 -6241.68 5936747.85 552577.90 MWD+IFR-AK-CAZ-SC 13161.63 89.56 179.10 3171.11 3049.56 -8796.90 -6240.97 5936653.57 552579.34 MWD+IFR-AK-CAZ-SC 13256.47 89.81 179.04 3171.63 3050.08 -8891.73 -6239.43 5936558.77 552581.62 MWD+IFR-AK-CAZ-SC 13351.12 89.31 178.75 3172.36 3050.81 -8986.36 -6237.60 5936464.16 552584.18 MWD+IFR-AK-CAZ-SC 13446.03 89.68 178.18 3173.19 3051.64 -9081.23 -6235.06 5936369.33 552587.46 MWD+IFR-AK-CAZ-SC I 13540.50 89.93 178.09 3173.52 3051.97 -9175.65 -6231.99 5936274.94 552591.27 MWD+IFR-AK-CAZ-SC 13636.14 90.30 179.06 3173.32 3051.77 -9271.26 -6229.61 5936179.36 552594.40 MWD+IFR-AK-CAZ-SC I 13731.91 90.73 180.08 3172.46 3050.91 -9367.02 -6228.89 5936083.62 552595.86 MWD+IFR-AK-CAZ-SC 13826.98 91.10 181.06 3170.95 3049.40 -9462.07 -6229.84 5935988.57 552595.66 MWD+IFR-AK-CAZ-SC 13922.57 90.48 180.73 3169.63 3048.08 -9557.64 -6231.33 5935893.00 552594.91 MWD+IFR-AK-CAZ-SC 14018.59 90.18 180.45 3169.07 3047.52 -9653.66 -6232.32 5935797.00 552594.67 MWD+IFR-AK-CAZ-SC 14113.57 89.81 181.17 3169.08 3047.53 -9748.62 -6233.66 5935702.03 552594.07 MWD+IFR-AK-CAZ-SC 14207.64 90.12 180.32 3169.14 3047.59 -9842.69 -6234.88 5935607.97 552593.58 MWD+IFR-AK-CAZ-SC 14302.54 89.68 177.90 3169.31 3047.76 -9937.57 -6233.41 5935513.11 552595.80 MWD+IFR-AK-CAZ-SC 14397.82 90.30 178.26 3169.32 3047.77 -10032.79 -6230.22 5935417.92 552599.73 MWD+IFR-AK-CAZ-SC 14493.32 89.81 178.53 3169.23 3047.68 -10128.25 -6227.54 5935322.49 552603.15 MWD+IFR-AK-CAZ-SC 14588.28 89.38 178.88 3169.90 3048.35 -10223.19 -6225.40 5935227.59 552606.04 MWD+IFR-AK-CAZ-SC 14684.29 90.43 179.00 3170.06 3048.51 -10319.18 -6223.62 5935131.62 552608.56 MWD+IFR-AK-CAZ-SC 14778.90 90.61 180.66 3169.20 3047.65 -10413.78 -6223.34 5935037.03 552609.58 MWD+IFR-AK-CAZ-SC 14874.20 90.36 181.44 3168.40 3046.85 -10509.06 -6225.09 5934941.75 552608.58 MWD+IFR-AK-CAZ-SC ~ 14968.92 89.81 182.39 3168.26 3046.71 -10603.73 -6228.25 5934847.07 552606.15 MWD+IFR-AK-CAZ-SC 15064.08 90.18 182.69 3168.26 3046.71 -10698.79 -6232.47 5934751.99 552602.68 MWD+IFR-AK-CAZ-SC I 15158.38 89.25 182.43 3168.73 3047.18 -10793.00 -6236.68 5934657.76 552599.20 MWD+IFR-AK-CAZ-SC 15255.00 90.79 183.64 3168.70 3047.15 -10889.48 -6241.80 5934561.26 552594.84 MWD+IFR-AK-CAZ-SC 15348.46 89.99 182.76 3168.06 3046.51 -10982.79 -6247.01 5934467.92 552590.35 MWD+IFR-AK-CAZ-SC 15443.37 90.18 179.56 3167.92 3046.37 -11077.67 -6248.93 5934373.03 552589.17 MWD+IFR-AK-CAZ-SC ~ 15538.08 90.12 178.00 3167.67 3046.12 -11172.35 -6246.92 5934278.38 552591.92 MWD+IFR-AK-CAZ-SC 15633.17 90.49 177.96 3167.17 3045.62 -11267.38 -6243.57 5934183.39 552596.02 MWD+IFR-AK-CAZ-SC 15728.95 89.68 175.67 3167.03 3045.48 -11363.01 -6238.24 5934087.81 552602.08 MWD+IFR-AK-CAZ-SC 15824.29 90.30 174.89 3167.04 3045.49 -11458.02 -6230.40 5933992.87 552610.67 MWD+IFR-AK-CA2-SC 15919.07 91.11 175.32 3165.88 3044.33 -11552.45 -6222.31 5933898.52 552619.49 MWD+IFR-AK-CAZ-SC 16012.97 90.05 176.12 3164.93 3043.38 -11646.08 -6215.30 5933804.96 552627.23 MWD+IFR-AK-CAZ-SC 16108.35 90.49 177.47 3164.48 3042.93 -11741.31 -6209.97 5933709.78 552633.30 MWD+IFR-AK-CAZ-SC 16203.15 90.30 178.69 3163.82 3042.27 -11836.05 -6206.80 5933615.08 552637.22 MWD+IFR-AK-CAZ-SC 16298.52 90.61 179.18 3163.07 3041.52 -11931.40 -6205.02 5933519.75 552639.73 MWD+IFR-AK-CAZ-SC 16393.50 89.99 179.95 3162.57 3041.02 -12026.37 -6204.30 5933424.80 552641.20 MWD+IFR-AK-CAZ-SC 16489.51 89.93 179.83 3162.63 3041.08 -12122.38 -6204.12 5933328.80 552642.13 MWD+IFR-AK-CAZ-SC 16584.81 90.12 179.65 3162.59 3041.04 -12217.68 -6203.69 5933233.52 552643.30 MWD+IFR-AK-CAZ-SC 16678.40 91.96 178.86 3160.89 3039.34 -12311.24 -6202.47 5933139.98 552645.25 MWD+IFR-AK-CAZ-SC 16772.30 91.47 178.38 3158.08 3036.53 -12405.07 -6200.21 5933046.17 552648.24 MWD+IFR-AK-CAZ-SC 16864.13 91.60 180.81 3155.62 3034.07 -12496.86 -6199.56 5932954.40 552649.61 MWD+IFR-AK-CAZ-SC ~ 16956.58 91.41 183.35 3153.20 3031.65 -12589.21 -6202.91 5932862.04 552646.97 MWD+IFR-AK-CAZ-SC 17048.37 91.10 181.56 3151.19 3029.64 -12680.89 -6206.85 5932770.34 552643.76 MWD+IFR-AK-CAZ-SC I '\ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc- Do-itc 10111/2007 Timr. 13.46.54 Pe~c: Field: KuparUk Riv er Unit Co-o rdinatcfNE)ltcfcrencr. Well: 1 J-176, T rue North Site: Kuparuk 1J Pad ~'crti cal (TAD}Reference 1J-176 Actual RTE: 121.5 We0: 1J-176 Secti unl~'S)Refemncr. Well (O.OON.O.O OE,180.OOAzI) «`cllpath: 1J-176L1 SurveyCalculation tilethod: Minimum Curvature Db: Orade Surcc~ Ill Incl .1~~im I'~U S~~sIFD ~%5 ~:.NV ~~1apfi ~1apE "fool ft deg deg ft ft ft ft ft ft 17138.40 91.35 179.67 3149.26 3027.71 -12770.89 -6207.81 5932680.34 552643.50 MWD+IFR-AK-CAZ-SC 17228.88 91.60 178.41 3146.93 3025.38 -12861.33 -6206.30 5932589.93 552645.72 MWD+IFR-AK-CAZ-SC 17323.11 91.53 178.61 3144.36 3022.81 -12955.49 -6203.85 5932495.80 552648.90 MWD+IFR-AK-CAZ-SC 17416.29 90.24 178.30 3142.92 3021.37 -13048.62 -6201.33 5932402.70 552652.14 MWD+IFR-AK-CAZ-SC 17507.60 89.68 177.16 3142.98 3021.43 -13139.86 -6197.72 5932311.50 552656.47 MWD+IFR-AK-CAZ-SC 17598.84 90.43 177.05 3142.89 3021.34 -13230.98 -6193.11 5932220.43 552661.78 MWD+IFR-AK-CAZ-SC 17691.28 90.42 178.88 3142.21 3020.66 -13323.36 -6189.83 5932128.09 552665.79 MWD+IFR-AK-CAZ-SC 17782.64 90.36 178.52 3141.59 3020.04 -13414.69 -6187.75 5932036.78 552668.57 MWD+IFR-AK-CAZ-SC ~ 17820.00 90.36 178.52 3141.35 - 3019.80 -13452.04 -6186.79 5931999.45 552669.83 PROJECTED to TD "D" Lat. Liner Detail well: 1J-176 L1 ConOCQPhill'~~S 4.5" Slotted and Blank - PIOp & Drop Date: 9/ 28 / 07 Alaska lne. Rig: Doyon 15 Supervisors: Mike Thornton / Granville Rizek DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 OD(in) nominal Max OD(in) actual ID(in) actual LENGTH TOPS 1 thru 51 are BTC Slots , 52 thru 64 Hydril 521 slot [reSeNed~ (reserved] (~eSeNedj 301 thru 384 BTC Blanks, 385 thru 402 Hyd 521 Blanks (~eSeNea~ (reserved] [reserved] [reserved] [reserved] [reserved] 10588.82 :: ::: ..::::,::::;;::.. 10588.82 5 DP to Surface =_> 10588.82 Baker Liner setting tool( Does not stay in hole) 8.22 8.22 3.77 12.28 10588.82 . " ....................................................................................................................... i"€~?'il~r:"Hl~>' Liner Sptt(Ing ~lt~ ~i16} 7E~f~ 7 8.26 6.28 8.64 10601.10 XO Sub 7" H d 521 X 5-1 /2" H d 521 7 7.07 4.9 1.12 10609.74 5 1/2", 15.5 f, L-80, H dril 521 Pu 'oint 5.5 5.72 4.92 3.66 10610.86 5 1/2", 15.5 f, LSO, H dri1521 Rece tacle Joint 5.5 5.73 4.89 41.70 10614.52 5 1/2" H d 521 Box X 41/2" H d 521 Pin XO 3.92" I.D. 5.5 5.72 3.92 1.28 10656.22 4-1/2", 12.6 f, LSO, H dril 521 PUP Jt. 4.5 4,72 3.92 3.73 10657.50 Jts 166 to 16 1 Jts d-1/2", 11.6,ppf, L-80, Hydril 521 S'Iotted Casing 4.5 4.695 3.92 40.98 10661.23 Jts lssto 1s 1 Jts 4-1/2", 116,ppf, L-80, Hydril 521 Blank Casing 4.5 4.695 3.92 41.37 10702.21 Jts 154 to 16 1 Jts 4-1 /2",11.6 ppf, L-80, Wydril 521 Slotted Casing 4.5 4.695 3.92 41.91 10743.58 Jts 163 to 15 1 Jts 41/2",'11.6'ppf, L$0, Hydril'S21 Blank Casing 4.5 4.695 3.92 41.60 10785.49 Jts 1s2 to 1s 1 Jts 4=1 /2' ; 11.6 ppf, L-80, Hydril 521 Slotted Casing 4.5 4.695 3.92 41.76 10827.09 Jts 151 to 151 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Blank Casing 4.5 4.695 3.92 41.82 10868.85 Jts 1so to 1s 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Slotted Casing 4.5 4.695 3.92 40.85 10910.67 Jts 159 to 15 1 Jts 4-112", 11.6 ppf, L-80, Hydril 521 Blank Casing' 4.5 4,695 3.92 41.98 10951.52 Jts 158 to 15 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Slotted Casing 4.5 4,695 3.92 41.95 10993.50 Jts 157 to 15 1 Jts 4-112", 11.6 ppf, L-80, Hydril 521 Blank Casing 4.5 4.695 3.92 41.87 11035.45 Jts 156 to 15 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Slotted Casing 4.5 4.695 3.92 40.88 11077.32 Jts 150 to 15 6 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Blank Casing 4.5 4.695 3.92 248.54 11118.20 Jts 148 to 14 2 Jts 4-112", 11.6 ppf, L$0, Hydril 521 Slotted Casing 4.5 4.695 3.92 83.70 11366.74 Jts 147 to 14 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Blank Easing 4.5 4.695 3.92 41.44 11450.44 Jts 146 to 14 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Slotted Casing 4.5 4.695 3.92 41.71 11491.88 Jts 145 to 14 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Blank Casing 4.5 4.695 3.92 42.60 11533.59 Jts 144 to 14 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Slotted Casing 4.5 4.695 3.92 39.61 11576.19 Jts 143 to 14 1 Jts 4-112", 11.6 ppf, L-80, Hydril 521 Blank Casing 4.5 4.695 3.92 42.57 11615.80 Jts 142 to 14 1 Jts 4-112", 11.6 ppf, L-80, Hydril 521 Slotted Casing.. 4.5 4.695 3.92 41.90 11658.37 Jts 141 to 141 1 Jts 4-1/2", 11.6 ppf, L-80, Hydril 521 Blank Casing 4.5 4.695 3.92 42.56 11700.27 Jts 140 to 14 1 Jts 4-1/2", 11.6 ppf, L$0, Hydril 521 Slotted Casing 4.5 4.695 3.92 41.71 11742.83 Jts 139 to 13 1 Jts 4-112", 11.6 ppf, L$0, Hydril 521 Blank Casing 4.5 4.695 3.92 42.67 11784.54 Jts 138 to 13 1 Jts 4-112", 11.6 ppf, L$0, Hydril 521 Slotted Casing 4.5 4.695 3.92 41.20 11827.21 Jts 136 to 13 2 Jts 4-1/2", 11.6 ppf, L$0, Hydril 521 Blank Casing 4.5 4.695 3.92 84.83 11868.41 „ :>::>:::;> ;:< ~O S~sb 4 5 ' ;.: d 5~1[X 4.5" „,BTCM .< _ ,:... 4.5 4.729 3.918 1.65 11953.24 Tor ue Inst ructions : Tor ue H d 521= 4400 ft-Ibs , BTCM w/ for rin s= 4500 ft-Ibs , BTCM ~ 2800 ft-Ibs Av 10 'ts to diamonds Total Foota a of each = 1,292.01' of H d 521, 2,825.61' of BTCM w/ Tor Rin s, 3,003.01' of BTCM Centrilizers : Run 1 - 4.5" X 6 1/8" H droform er 'oint floatin on Joints #1 thru # 166 =Total ran 166 Torque Rings In : Jts ~ 70 thru 135 =Total used 66 To of B Lat MLZXP = 10,457' MD / 3,186' TVD / 85 De - NO GO XO sub 10,484' MD 4.85" ID To of D Lat Window = 10,238' MD / 3,162 TVD / 81.84 De ,Bottom of Window 10,254'. Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 132 to 13 4 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 171.05 11954.89 Jts 130 to 131 2 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 85.74 12125.94 Jts 12s to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.36 12211.68 Jts 128 to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 42.79 12255.04 Jts 127 to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.63 12297.83 Jts 12s to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.46 12341.46 Jts 125 to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.33 12384.92 Jts 124 to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.45 12428.25 Jts 123 to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 40.48 12471.70 Jts 122 to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.64 12512.18 Jts 121 to 121 1 Jts 4.5" 11.6 ppf L$0 BTCM Blank csg with torque rings 4.5 5 4 43.64 12555.82 Jts 12o to 12 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.02 12599.46 Jts 114 to 11 6 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 256.72 12642.48 Jts 113 to 11 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 40.96 12899.20 Jts 112 to 11 1 Jts 4.5" 11.6 ppf L$0 BTCM Blank csg with torque rings 4.5 5 4 41.45 12940.16 Jts 111 to 111 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.65 12981.61 Jts 11o to 11 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.42 13025.26 Jts 109 to 10 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.59 13068.68 Jts 108 to 10 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.32 13112.27 Jts 107 to 10 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 42.62 13155.59 Jts 1os to 10 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.31 13198.21 Jts 105 to 10 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.38 13241.52 Jts 104 to 10 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 42.51 13284.90 Jts 103 to 10 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 42.10 13327.41 Jts s7 to 1oz 6 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 259.93 13369.51 Jts 95 to ss 2 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 83.89 13629.44 Jts 94 to 94 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 39.44 13713.33 Jts 93 to s3 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 40.31 13752.77 Jts 92 to 92 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.65 13793.08 Jts 91 ~to s1 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.27 13836.73 Jts 90 to s0 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.27 13880.00 Jts 89 to 89 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 42.34 13923.27 Jts 88 to 88 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.42 13965.61 Jts 87 to 87 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 42.91 14009.03 Jts 86 to 8s 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.44 14051.94 Jts 85 to 85 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.39 14095.38 Jts 7s to 8a 6 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 259.56 14138.77 Jts 78 to 78 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.41 14398.33 Remarks: Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 77 to 77 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 42.45 14441.74 Jts 7s to 7s 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.63 14484.19 Jts 75 to 75 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 38.07 14527.82 Jts 74 to 74 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 42.61 14565.89 Jts 73 to 73 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 42.34 14608.50 Jts 72 to 72 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.04 14650.84 Jts 71 to 71 1 Jts 4.5" 11.6 ppf L-80 BTCM Blank csg with torque rings 4.5 5 4 43.23 14693.88 Jts 7o to 70 1 Jts 4.5" 11.6 ppf L-80 BTCM Slotted csg with torque rings 4.5 5 4 43.39 14737.11 Jts ss to ss 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.28 14780.50 Jts ss to sa 1 Jts 4.5" 11.6 f L-80 BTCM Slotted cs 4.5 5 4 43.38 14823.78 Jts s2 to s7 6 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 255.68 14867.16 Jts so to si 2 Jts 4.5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 87.08 15122.84 Jts 5s to ss 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 4 43.31 15209.92 Jts 5a to ss 1 Jts 4.5" 11.6 f L-80 BTCM Slotted cs 4.5 5 4 43.15 15253.23 Jts 57 to s7 1 Jts 4.5" 11.6 f L$0 BTCM Blank cs 4.5 5 4 43.42 15296.38 Jts 5s to ss 1 Jts 4.5" 11.6 f L-80 BTCM Slotted cs 4.5 5 4 44.17 15339.80 Jts 5s to ss 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.41 15383.97 Jts 5a to sa 1 Jts 4.5" 11.6 f L-80 BTCM Slotted cs 4.5 5 4 43.38 15427.38 Jts 53 to 53 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.09 15470.76 Jts 52 to s2 1 Jts 4:5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 43.51 15513.85 Jts s1 to s1 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 4 42.73 15557.36 Jts so to so 1 Jts 4.5" 11.6 f L$0 BTCM Slotted cs 4.5 5 4 43.05 15600.09 Jts 44 to 49 6 Jts 4.5" 11.6 f L$0 BTCM Blank cs 4.5 5 4 247.98 15643.14 Jts 43 to 43 1 Jts 4.5" 11.6 f L$0 BTCM Slotted cs 4.5 5 4 43.33 15891.12 Jts 4z to 4z 1 Jts 4.5" 11.6 f L$0 BTCM Blank cs 4.5 5 4 43.42 15934.45 Jts 41 to 41 1 Jts 4.5" 11.6 f L$0 BTCM Slotted cs 4.5 5 4 42.80 15977.87 Jts a0 to a0 1 Jts 4.5" 11.6 f L$0 BTCM Blank csg 4.5 5 4 41.32 16020.67 Jts 39 to 39 1 Jts 4.5" 11.6 f L$0 BTCM Slotted cs 4.5 5 4 43.38 16061.99 Jts 3s to 3s 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.31 16105.37 Jts 37 to 37 1 Jts 4.5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 41.24 16148.68 Jts 36 to 36 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.30 16189.92 Jts 35 to 35 1 Jts 4.5" 11.6 f L-80 BTCM Slotted cs 4.5 5 4 43.13 16233.22 Jts 34 to 3a 1 Jts 4.5" 11.6 f L$0 BTCM Blank cs 4.5 5 4 42.73 16276.35 Jts 33 to 33 1 Jts 4.5" 11.6 f L$0 BTCM Slotted cs 4.5 5 4 43.04 16319.08 Jts 27 to 32 6 Jts 4.5" 11.6 f L$0 BTCM Blank cs 4.5 5 4 259.18 16362.12 Jts zs to zs 2 Jts 4.5" 11.6 f L$0 BTCM Slotted cs 4.5 5 4 85.83 16621.30 Jts za to za 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 4 43.16 16707.13 Jts z3 to z3 1 Jts 4.5" 11.6 f L$0 BTCM Slotted csg 4.5 5 4 43.28 16750.29 Remarks: D Lat TD @ 17,820' MD/ 3,141' TVD Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 4 LENGTH TOPS Jts 22 to 22 1 Jts 4.5" 11.6 f L-80 BTCM Blank csg 4.5 5 4 43.15 16793.57 Jts 21 to 21 1 Jts 4.5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 43.64 16836.72 Jts 20 to 20 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 42.58 16880.36 Jts 19 to 19 1 Jts 4.5" 11.6 f L-80 BTCM Slotted cs 4.5 5 4 43.08 16922.94 Jts 18 to 18 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 42.08 16966.02 Jts 17 to 17 1 Jts 4.5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 43.39 17008.10 Jts 16 to 16 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 41.35 17051.49 Jts 15 to 15 1 Jts 4.5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 43.42 17092.84 Jts 10 to 14 5 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 214.76 17136.26 Jts 9 to 9 1 Jts 4.5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 43.38 17351.02 Jts 8 to 8 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.33 17394.40 Jts 7 to 7 1 Jts 4.5" 11.6 f L-80 BTCM Slotted cs 4.5 5 4 42.98 17437.73 Jts 6 to 6 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.31 17480.71 Jts 5 to 5 1 Jts 4.5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 43.55 17524.02 Jts 4 to 4 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.32 17567.57 Jts 3 to 3 1 Jts 4.5" 11.6 f L~0 BTCM Slotted cs 4.5 5 4 43.04 17610.89 Jts 2 to 2 1 Jts 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.64 17653.93 Jts 1 to 1 1 Jts 4.5" 11.6 f L~0 BTCM Slotted csg 4.5 5 4 40.85 17697.57 4.5" 11.6 f L-80 BTCM Blank cs 4.5 5 4 43.40 17738.42 4-1/2", BTC Silver bullet Float Shoe 4.5 5.02 1.69 17781.82 Bttm ofShoe =__> 17783.51 17783.51 17783.51 17783.51 17783.51 D Lat TD 17,820' MD/ 3,141' TVD 17783.51 4-1 /2" Shoe 17,783.51' MD / 3,141' TVD Rat Hole 36.49' 17783.51 To of Plo 8 Dro is s aced out to match Hook Assembl 17783.51 17783.51 17783.51 17783.51 17783.51 17783.51 17783.51 17783.51 17783.51 17783.51 17783.51 Remarks: Up Wt. 260 K Ran out of do wt 13,567' MD. Rotated to bttm. Dn Wt. 0 K Hole Fluids: 50/50 SFOBM 8.4 g from TD to Window & Rot Wt. 153 K - 60/40 SFOBM w/ 3% - 776 lube from window to surtace. Blk Wt. 70 k Rot. Torque 16 K Time Logs Date From To Dur e th E De th Phase Code Subcode I OM 09/18/2007 00:30 01:15 0.75 0 0 PROD2 STK PULD P Pull all whipstock assembly tools & equipment to rig floor as per BOT rep. Held PJSM with crew, BOT, and SPerry reps. Discuss safety & hazard recognition issues. Discuss procedure for making up whipstock and space out assembl . 01:15 04:45 3.50 0 522 PROD2 STK PULD P Make up whipstock and space out assembly as per BOT & Sperry Sun re s. Total len th of BHA = 522.00" 04:45 05:30 0.75 522 522 PROD2 STK PULD P Plug in and Up load MWD. 05:30 06:00 0.50 522 522 PROD2 STK PULD P Continue make up 3 Non-Mag flex drill collars. Crew Chan e 06:00 06:15 0.25 522 522 PROD2 STK PULD P Continue make up BHA installing Bum r ~ar and 5" HWDP. 06:15 06:30 0.25 522 522 PROD2 STK CIRC P Pulse test MWD assembly with pumps at 400 GPM's and 580 PSI. Good test. 06:30 12:00 5.50 522 8,800 PROD2 STK TRIP P Trip in hole with whipstock assembly at 2 minutes /stand as per BOT rep from 522' - 8800' MD> Fill drill string every 25 stands. Observed proper dis lacement. 12:00 12:30 0.50 8,800 9,391 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 8800' - 9391' MD. Fill drill strip . 12:30 13:00 0.50 9,391 9,461 PROD2 STK OTHR P Perform MAD PASS form 9391' - 9461' as per Geologists. Pumps @ 593 GPM's - 2900 PSI. UP WT = 190K, SO WT = 82K. 13:00 14:00 1.00 9,461 10,456 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 9461' - 10456" MD. Fill drill string every 25 stands. Observed ro er dis lacement. . 14:00 14:30 0.50 10,456 10,458 PROD2 STK WPST P Orient whipstock face to 12 Deg Left of high side. Pumps @ 430 GPM's - 1990 PSI. UP WT = 225K, SO WT = 100K. Slack off & tag top of B lat liner at 10458' DPM' and set seal into liner top. Continue slack off to set bottom trip anchor with 18K. Pull 10K over upweight to verify set. Set down 35K to shear bolt as planned. Top of whi stock 10237' DPM. 14:30 16:30 2.00 10,237 10,237 PROD2 STK CIRC P Diplace well with 8.3 PPG MOBM at 510 GPM's - 2300 GPM's. Circulate to get balanced mud weights at 8.4 PPG. 16:30 17:00 0.50 10,237 10,237 PROD2 STK CIRC P Monitor well -static. 17:00 18:00 1.00 10,237 10,240 PROD2 STK WPST P Obtain rotation of drill string, and mill window from 10238' - 10240' with 516 GPM's - 2300 PSI. Obtained slow Pump rates before milling window.Mllling at 80 RPM's with 14K TO on btm. WOM = 2K. Crew Chan e 1 PaaE 35 of v3 I i_ Time Lo s .Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/18/2007 18:00 22:30 4.50 10,240 10,290 PROD2 STK WPST P Continue mill window from 10240' - 10254' with 516 GPM's - 2300 PSI, at 80 RPM's with 6K TQ on btm. WOM = 6K. Milled window in 3.45 HRS, continuing milling open hole from 10254' -10290' in 1.58 HRS. Total open hole made = 36'. Pump sweep at bottom of window, and also at the bottom of o en hole. 22:30 23:45 1.25 10,290 10,290 PROD2 STK CIRC P Work mills through window area to clean same while pumping 40 BBL Hi Visc sweep at 600 GPM's - 2870 PSI. UP WT = 220K, SO WT = 140K, ROT WT = 160K, at 80 RPM's with 11 K TQ.Work mills through window without pumps or rotation to verify clean as er BOT re . 23:45 00:00 0.25 10,290 10,290 PROD2 STK CIRC P Mpnior well -static. 09/19/2007 00:00 00:30 0.50 10,290 9,850 PROD2 STK TRIP P Pull 5 stands on elevators observing well, no swabbing, with correct hole fill. 00:30 00:45 0.25 9,850 9,850 PROD2 STK CIRC P Pump dry job. 00:45 04:45 4.00 9,850 522 PROD2 STK TRIP P POOH on elevators from 9850' - 522. Observe well before ull BHA. 04:45 05:45 1.00 522 0 PROD2 STK PULD P POOH, racking back HWDP & DC"S. Breakout, Inspect & lay down mills. Mill gauged to full gauge of 8 1/2" as er BOT re . 05:45 06:30 0.75 98 98 PROD2 STK OTHR P Plug in and download MWD assembl . 06:30 06:45 0.25 0 0 PROD2 STK OTHR P Clean & clear rig floor of equipment & OBM. Rig up to Flush stack. Crew Chan e 06:45 07:30 0.75 98 0 PROD2 STK PULD P Breakout, Inspect & lay down mills. Mill gauged to full gauge of 8 1/2" as per BOT rep. Total fluid loss on TOH = 13 BBLS.Crew Chan e 07:30 09:15 1.75 0 75 PROD2 DRILL PULD P Held PJSM with crew, DD &MWD reps. Discuss safety & hazard recogniiton issues. Discuss procedure to make up BHA #11. Make up Geo-Pilot assembly with 8 1/2" Security FMF3643Z bit. Make up MWD assembl with float sub. 09:15 09:45 0.50 75 75 PROD2 DRILL PULD P Plug in and Upload MWD assembly. 09:45 10:15 0.50 75 352 PROD2 DRILL PULD P Make up remaining BHA including Non Mag flex drill collars, drilling jars and HWDP. Total BHA len th 10:15 10:30 0.25 352 352 PROD2 DRILL CIRC P Run 1 stand, and perform pulse test with pumps @ 600 GPM's - 1300 PSI. Rotate drill string to break in bearings on Geo- ilot. Page ~~ ~a v3 .Time Lo s Date From To Dur S. De th E. Oe th Phase Code Subcode T ' COM 09/19/2007 10:30 15:30 5.00 352 10,150 PROD2 DRILL TRIP P Trip in hole with BHA #11 from 352' - 10150'. Observed proper displacement. Fill drill string every 25 stands. Obtain T8~D parameters as per rig engineer. UP WT = 185K, SO WT = 105K. 15:30 16:00 0.50 10,150 10,150 PROD2 RIGMN SVRG P Service draworks & top drive. 16:00 16:30 0.50 10,150 10,290 PROD2 DRILL CIRC P Establish drilling parameters at top of window. Work drill string through window area with no issues. Tag bottom at 10290' DPM. 16:30 17:45 1.25 10,290 10,442 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 10290' - 10442' MD. TVD = 3185'. 17:45 18:15 0.50 10,442 10,442 PROD2 DRILL CIRC T Observed "noise" in MWD assembly with failed pulses. Trouble shoot all surface equipment, isolating pumps, and pressure testing. While trouble shooting, observed 1000 PSI loss in ressure in drill strin . 18:15 18:45 0.50 10,442 10,238 PROD2 DRILL TRIP T Pulled 2 stands to get back into cased hole above window. Continue trouble shoot, with indication that surface equipment fuctioning correctly. Crew Chan e 18:45 19:00 0.25 10,238 10,238 PROD2 DRILL TRIP T Continue trouble shoot, with indication that surface equipment fuctionin correct) . 19:00 19:15 0.25 10,238 10,264 PROD2 DRILL TRIP T Trip back in hole with drill string to attempt to tag bottom. Observed tagging high, at 10264', with no increase in drill string pressure. When tagging up, observed increase in for ue u 22-24K ft/Ibs. 19:15 23:15 4.00 10,264 0 PROD2 DRILL TRIP T Pump dryjob, POOH on elevators from 10264' -surface. Observed proper hole fill, with 3 BBLS loss. 23:15 00:00 0.75 0 PROD2 DRILL PULD T Observed that the Dailey Combo drilling jars had parted 17' down ftom the top of the connection, leaving 13' ofjars in hole and remaining BHA. Total BHA left in hole = 181.45. Obtain pictures, Breakout and laydown jars. Discuss issues with rig engineer. Call for BOT fisherman. 09/20/2007 00:00 02:15 2.25 0 338 PROD2 FISH WOSP T Make up 1 joint of 5" HWDP, Bumper sub and Oil jars with Float sub. Wait on BOT for 1/2 HR. Pull remaing tools to rig floor. Strap tools & Dress 8 1/8" over shot with 6 1/4" grapple & packoff. Make up Overshot. Adjust DP tall . 02:15 06:00 3.75 338 9,948 PROD2 FISH TRIP T Trip in hole with BHA #12, from 338' - 9948'. Observed proper displacement. Crew Chan e 06:00 06:15 0.25 9,948 10,238 PROD2 FISH TRIP T Continue trip in hole from 9948' - 10238' MD. e~ae~e ~7 os v3 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T GOM - 09/20/2007 06:15 07:15 1.00 10,238 10,238 PROD2 FISH FISH T Obtain Fishing parameters with UP WT = 180K, SO WT = 105K. Pumps at 2.5 BPM - 440 PSI. Attempt to work 8 1!8" Overshot assembly over top of whipstock. Observed setting down on whipstock top. Rotate to aloes free travel with no success. Set down weights from 10-30K. No success in getting O.S. past whipstock top. Suspect "lipped "over constricting the ID. 07:15 07:45 0.50 10,238 10,238 PROD2 FISH CIRC T Monitor well for 15 minutes. Static. Pum d ~ob. 07:45 11:45 4.00 10,238 338 PROD2 FISH TRIP T POOH on elevators from 10238' - 338'. Observed ro er dis lacement. 11:45 12:15 0.50 338 0 PROD2 FISH PULD T Rack back HWDP. breakout & lay down Overshot assembl . 12:15 12:30 025 0 0 PROD2 FISH PULD T Clean & clear rig floor of tools, and OBM. 12:30 13:00 0.50 0 348 PROD2 FISH PULD T Make up BHA # 13, Tapered mill assembly with upper watermelon mill. Make up string magnet. Total BHA - 348.66'. 13:00 17:15 4.25 348 10,145 PROD2 FISH TRIP T Trip in hole with fishing assembly - BHA 13 from 348' -10145' MD. Fill Drill string every 25 stands. Observed ro er dis lacement. 17:15 18:00 0.75 10,145 10,240 PROD2 FISH MILL T Obtain milling parameters. Slack off and tag top of whipstock at 10238' MD. UP WT = 180K, SO WT = 105K, ROT WT = 145K. Pumps at 4 BPM - 600 PSI. Dress top of whipstock from 10237' - 10240' DPM.with 45 RPM's observing free torque at 9K, and milling torques to 14K. Observed mills cleaned up top of whipstock,allowing free travel of 8 1/2" mills through top of whi stock. Crew Chan e 18:00 18:30 0.50 10,240 10,240 PROD2 FISH MILL T Continue dress top of whipstock from 10237' -10240' DPM.with 45 RPM's observing free torque at 9K, and milling torques to 14K. Observed mills cleaned up top of whipstock,allowing free travel of 8 1/2" mills through top of whi stock. Free travel - no rotation. 18:30 19:30 1.00 10,240 10,240 PROD2 FISH CIRC T Pump Hi visc sweep and circulate @ 600 GPM's - 1890 PSI. Observed increase in iron cuttings when sweep at surface. 19:30 20:00 0.50 10,240 10,240 PROD2 FISH OTHR T Monitor well -static. Obtain slow um rates. Pum d 'ob. 20:00 00:00 4.00 10,240 348 PROD2 FISH TRIP T POOH on elevators observing proper dis lacement from 10240' - 348'. Page 38 cf 53 Time Lo s Date From To Dur e th E. De th Phase Code Subcode OM 09/21/200 7 00:00 00:45 0.75 348 0 PROD2 FISH PULD T Rack back HWDP, breakout & lay down milling assembly. Inspect mills - good. No junk cuts. Observed string magnet with approximately 10 LBS of iron cuttin s. 00:45 02:15 1.50 0 340 PROD2 FISH PULD T Make up 8 1/8" overshot assembly with 1 joint of DP above Jars. Rig up and attempt to bend 5" DP joint to aid overshot going over top of whipstock as recommended. Observd joint bent 10' above pin end approximately 1 ". Total BHA = 340.14' 02:15 06:00 3.75 340 9,664 PROD2 FISH TRIP T Trip in hole with 8 1/8" Overshot from 340' - 9664. Observed proper displacement. Fill drill string every 25 stands. Crew Chan e 06:00 06:30 0.50 9,664 10,235 PROD2 FISH TRIP T Continue trip in hole from 9664' - 10235' DPM. 06:30 07:30 1.00 10,235 10,264 PROD2 FISH FISH T Break circulation. Establish fishing parameters. UP WT = 183K, SO WT = 107K. ROT WT =138K. Pumps at 3 BPM - 300 PSI. Wash down through window, no tag, continuing down to tag top offish @ 10260' MD, washing over fish to 10264'. Rotating at 30 RPM's with 8K TQ. Observed pump increase to 520 PSI, with increased torque to 12K. Stop rotation. Pull up to 245K verifying catch, and bring pumps to 420 GPM's - 1700 PSI to observed MWD ulses. Slow um s to 4 BPM. 07:30 08:00 0.50 10,264 10,140 PROD2 FISH FISH T Pull assembly to bring bit above top of whipstock at 10140'. Pumps at 3 BPM - 600 PSI to wash and clean hole as we pulled into casing. Observed max pull of 280K, indicating drag. Monitor well -static. Pum d 'ob. 08:00 12:00 4.00 10,140 900 PROD2 FISH TRIP T POOH with fish from 10140' - 900'. Observed ro er hole fill. 12:00 12:30 0.50 900 340 PROD2 FISH TRIP T Continue POOH from 900' - 340'. 12:30 12:45 0.25 340 181 PROD2 FISH PULD T Rack back HWDP, and lay down bent 'oint of 5" DP. 12:45 13:00 0.25 181 181 PROD2 FISH PULD T Breakout & lay down fishing assembly with fish in it to the bottom of the drillin ~ars. 13:00 14:30 1.50 181 0 PROD2 FISH PULD T Continue POOH, breakout & lay down fish. Fish = 181'. Breakout 8 lay down Flex drill collars, MWD assembly and Geo-Pilot. Inspect & gauge bit to full gauge and ready for rerun. Plugged in and downloaded MWD. ? I/Gge 3° of 53 Time Lo s .Date From To Dut S. De th E. De th Phase Code Subcode T COM . 09/21/2007 14:30 16:00 1.50 0 0 PROD2 FISH PULD T Pick up fishing assembly that was layed down, Breakout Overshot, and fish. Lay down same. Observed recovery of most of the inner spring of failed jar, and no inner bushing. Junk left in hole. 16:00 17:30 1.50 0 345 PROD2 FISH PULD T Make up 7 7/8" Reverse circulating basket with string magnet and float sub. Total BHA len th = 345.80'. 17:30 18:00 0.50 345 2,050 PROD2 FISH TRIP T Trip in hole with BHA # 15 from 345' - 2050' DPM. Observed proper displacement, filling drill string every 25 stands. Crew Chan e 18:00 21:30 3.50 2,050 9,860 PROD2 FISH TRIP T Continue trip in hole with BHA #15 from 2050' - 9860' DPM.Observed proper displacement, filling drill string eve 25 stands. 21:30 22:45 1.25 9,860 9,860 PROD2 RIGMN SVRG T Held PJSM with crew, Discuss safety 8 hazard recognition issues. discuss procedure to cut & slip drilling line. Cut & slip drilling line with no issues. Monitor well -static. 22:45 23:00 0.25 9,860 10,235 PROD2 FISH TRIP T Continue trip in hole from 9860' - 10235'. 23:00 00:00 1.00 10,235 10,444 PROD2 FISH FISH T Establish fishing parameters. Break circulation. UP WT = 175K, SO WT = 104K. ROT WT = 135K. Pumps at 6 BPM - 6500 PSI. Wash down through window, no tag, Observed pump pressure increase to 2470 PSI, indicating ball seated in reverse basket. String rotation at 30 RPM's continuing to wash from top of whipstock to bottom of hole at 10442' with rate increase to 8 BPM - at 10260'. Allow approximately 6" -1' of cut on bottom to 10444' DPM. Observed no obstructions or issues ettin basket to bottom. 09/22/2007 00:00 00:15 0.25 10,444 10,235 PROD2 FISH TRIP T Pumps off. POOH from 10444' -to above whi stock at 10235' . 00:15 00:45 0.50 10,235 10,235 PROD2 FISH TRIP T Monitor well -static. Pump dry job 00:45 04:30 3.75 10,235 345 PROD2 FISH TRIP T POOH from 10235' - 345'. Observed proper displacement. Total of 5 BBLS loss on TOH. 04:30 05:15 0.75 345 0 PROD2 FISH PULD T Breakout & lay down fishing BHA. Breakout reverses basket observing recovered 3 rocks, and a brass piece approximately 3" x 4". Picture taken and sent to town. 05:15 05:45 0.50 0 0 PROD2 FISH OTHR T Clean & clear rig floor of tools and OBM. 05:45 06:00 0.25 0 0 PROD2 DRILL SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss prcedure to make up 8 1/2" Drilling BHA. Pale 4G gf 53 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/22/2007 06:00 07:00 1.00 0 77 PROD2 DRILL PULD P Make up BHA #16.8 1/2" Drilling BHA. MU 8 1/2" Security FMF3643Z bit with 7600 series Geo-pilot. Make u MVVD assembl and Float sub. 07:00 07:45 0.75 77 77 PROD2 DRILL PULD P Plug in and Upload MWD assembly. 07:45 08:30 0.75 77 352 PROD2 DRILL PULD P Conttnue make up BHA #16 picking up Non mag flex drill collars, HWDP and Dailey combo drilling jars. Total BHA len th = 352.49' 08:30 08:45 0.25 352 352 PROD2 DRILL CIRC P Perform shallow pulse test. Pumps at 510 GPM's - 900 PSI. Rotate drill string to break in geo-pilot bearings as er DD. 08:45 13:15 4.50 352 10,156 PROD2 DRILL TRIP P Trip in hole from 352' - 10156'. Fill drill string every 25 stands. observed ro er dis lacement. 13:15 13:45 0.50 10,156 10,156 PROD2 RIGMN SVRG P Service & inspect Top drive. 13:45 14:45 1.00 10,156 10,442 PROD2 DRILL TRIP P Continue trip in hole from 10156' - 10266' DPM. Observed tagging up at 10266'. Repeat attempts to pass through 10266' with straight slack off, no go. Success with rotation, continuing rotate in hole to 10300'. Pumps at 600 GPM's - 2700 PSI. UP Wf = 190K, SO WT = 98K, ROT WT = 130K. Stop rotation & slack off to to bottom 10442' MD. 14:45 18:00 3.25 10,442 10,782 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 10442' - 10782' MD. TVD = 3200'. ADT = 2.74 HRS. Bit HRS = 2.74. ECD = 10.14 PPG. Crew Chan e 18:00 00:00 6.00 10,782 11,267 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 10782' -11267' MD. TVD = 3199'. ADT = 4.66 HRS. Bit HRS = 7.40. ECD = 10.71 PPG. 09/23/2007 00:00 06:00 6.00 11,267 11,858 PROD2 DRILL DDRL P Directional drill 8 112" D lateral from 11267' - 11858' MD. TVD = 3202'. ADT = 4.19 HRS. Bit HRS = 11.59. ECD = 10.78 PPG. Crew Chan e 06:00 12:00 6.00 11,858 13,019 PROD2 DRILL DDRL P Directional drill 8 112" D lateral from 11858' - 13019' MD. TVD = 3170'. ADT = 4.06 HRS. Bit HRS = 15.65. ECD = 11.75 PPG. 12:00 18:00 6.00 13,019 14,162 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from ~ 13019' -14162' MD. TVD = 3169'. ADT ' = 3.73 HRS. Bit HRS = 19.38. ECD = 11.85 PPG. Crew Chan e 18:00 00:00 6.00 14,162 15,282 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 14162' - 15282' MD. TVD = 3171'. ADT = 3.66 HRS. Bit HRS = 23.04. ECD = 12.20 PPG. 09/24/2007 00:00 06:00 6.00 15,282 16,042 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 15282'-16042' MD. TVD = 3162'. ADT = 3.11 HRS. Bit HRS = 26.15. ECD = 12.05 PPG. Crew Chan e ' Page 4fE o; v3 Time Lo s Date From To Dur th E. De th Phase Code Subcode T M 09/24/2007 06:00 08:15 2.25 16,042 16,232 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 16042' -16232'MD. ND = 3163'.Pump Hi Visc swee . 08:15 09:30 1.25 16,232 16,232 PROD2 DRILL CIRC P Circulate & condition mud while pump Hi Visc sweep out of hole. Pumps @ 620 GPM's - 3520 PSI. Reciprocate & rotate drill string_at 120 RPM's - 20K TQ. ECD=11.98 PPG. 09:30 12:00 2.50 16,232 16,423 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 16232' -16423 MD. ND = 3163'. ADT = 3.09 HRS. Bit HRS = 29.24. ECD = 12.09 PPG. 12:00 18:00 6.00 16,423 16,984 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral ftom 16423' -16984' MD. ND = 3152'. ADT = 3.96 HRS. Bit HRS = 33.20. ECD = 11.99 PPG. Crew Chan e 18:00 00:00 6.00 16,984 17,444 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 16984' - 17444' MD. ND = 3141'. ADT = 3.65 HRS. Bit HRS = 36.85. ECD = 12.14 PPG. 09/25/2007 00:00 06:00 6.00 17,444 17,820 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral. Max gas 235 units. Pumped a 40 bbls sweep (8.8 ppg/ 240 vis) while drilling at 17810'. 06:00 07:45 1.75 17,820 17,820 PROD2 DRILL CIRC P Circulate 3 BU after sweep back to surface. Sweep showed no appreciable amount of increase in cuttings. Pumping 600 gpm w/ 3980 psi. Rotate 150 rpm w/ 19ik ft Ibs of torque. ECD's 12.06 ppg. Rotating wt 145k. 07:45 12:00 4.25 17,820 16,140 PROD2 DRILL REAM P Backream out of the hole. Pumping 640 gpm w/ 3900 psi. Rotate 150 rpm w/ 17k ft Ibs of torque. Pulling speed 40-45 ft/min. 12:00 18:00 6.00 16,140 12,623 PROD2 DRILL REAM P Backream out of the hole. Pumping 700 gpm w/ 3750 psi. Rotate 150 rpm w/ 14k ft Ibs of torque. Pulling speed 40-45 ft/min. 18:00 00:00 6.00 12,623 10,339 PROD2 DRILL REAM P Backream out of the hole. Pumping 700 gpm w/ 3750 to 3300 psi. Rotate 150 rpm w/ 14 to 10k ft Ibs of torque. Pulling speed 40-45 ft/min. PU wt @ 10339': 200k, SO 80k, Rot wt 135k. 09/26!2007 00:00 00:15 0.25 10,339 10,228 PROD2 DRILL TRIP P Pull out of the hole, pumping 700 gpm w/ 3300 psi. PU 200k, SO 80k. Calculated fill 73 bbls, actual 114 bbls Runnin centrifu e . 00:15 02:30 2.25 10,228 10,228 PROD2 DRILL CIRC P Pump a 50 bbl sweep (9.9 ppg, 200 vis). Pumping 700 gpm w/ 3470 psi. Rotate 120 rpm w/ 10-11 k ft Ibs of torque. Rotating weight 135k. Slight increase in cuttings on returns of sweep. Continue to circulate a total of 1932 bbls. r~~ge 42 cf 53 Time Lo s Date- From To bur S. De th E. De th Phase Code Subcode T GOM 09/26/2007 02:30 03:00 0.50 10,228 10,150 PR0D2 DRILL OWFF P Monitor the well. Static. Service the blocks and top drive while monitoring well. Blow down to drive. 03:00 05:15 2.25 10,150 10,150 PR0D2 RIGMN SVRG P Change out the saver sub on the top drive. Change dies in the grabbers. Circulate over the top of the hole. Service the drawworks and crown. 05:15 06:00 0.75 10,150 10,722 PR0D2 DRILL TRIP P Trip in the hole on elevators. Record PU and SO wt's every 5 stands. PU wt 200k, SO wt 80k. 06:00 12:00 6.00 10,722 15,665 PROD2 DRILL REAM P Start reaming in the hole. Pumping 126 gpm w! 360- 560 psi, rotate 50 rn w/ 10-21 k ft Ibs of for ue. 12:00 12:15 0.25 15,665 15,665 PROD2 DRILL CIRC P Circulate @ 640 gpm w/ 3800 psi. Rotate 150 rpm w/ 21 k ft Ibs of torque to final of 17k ft Ibs of torque. Pumped a total of 220 bbls to help get into the hole. 12:15 15:30 3.25 15,665 17,820 PROD2 DRILL REAM P Ream in the hole. 30 rpm w/ 17k ft Ibs of torque, torque on bottom was 20k ft lbs. Pumping 126 gpm w/ 520 psi to final of 680 psi. Tagged bottom on depth. Hole took 7 bbls over calculated on tri in. 15:30 19:45 4.25 17,820 17,820 PR0D2 DRILL CIRC P Circulate and condition mud. Pumping 590 gpm w/ 4000 psi. Rotate 150 gpm w/ 19k ft Ibs of torque. PU wt 255k, 155k rot wt, no down wt. ECD's 12.12 ppg, initial and 11.94 ppg final. Circulated a bottom's up, then pumped a 9.2 ppg /220 vis sweep with no a reciable increase in cuttin s. 19:45 21:30 1.75 17,820 17,820 PR0D2 DRILL CIRC P Displace w/ 8.6 ppg/ 71 vis SFOBM. Rotate 120 rpm w/ 19k ft Ibs of torque. Start off Pumping 500 gpm w/ 3340 psi, increase to 525 gpm w/ 3460 psi, and final of 200 gprn w/ 890 psi. PU wt 290k, 155k rot wt, no down wt. 21:30 22:15 0.75 17,820 17,725 PR0D2 DRILL OWFF P Obtain SPR's. Record PU and SO wt's. Stand back a stand of 5" HWDP. Monitor well, Well is static. Drop a 2.33" OD rabbit w/ 156' of tail. 22:15 22:45 0.50 17,725 17,539 PROD2 DRILL TRIP P Pull 2 stands of 5" HWDP. Incorrect hole fill, swabbin . 22:45 00:00 1.25 17,539 16,710 PROD2 DRILL TRIP P Pump out of the hole. Pumping 126 gpm w/ 440 psi. Monitor returns using pit #5. Record PU and SO wt's per Rig engineer's directions. PU wt 285k, SO wt none. Note: A total of 4 bbls was lost to the hole while displacing to SFOBM, then an additional 7 were lost while pumping out, up to midnight. Total of 11 bbls. ~ P~c~e 4L, of 53 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T M 126 i P 09/27/2007 00 00 06:00 6 00 710 16 527 12 PROD2 DRILL TRIP P ng ump Pump out of the hole. : . , , gpm w/ 440 psi. Pumping 85 gpm w/ 200 psi. Monitor retums using pit #5. Record PU and SO wt's per Rig engineer's directions. PU wt 245k, SO wt none. Note: A total of 21 bbls were lost while um in out, u to 6 am. 06:00 09:45 3.75 12,527 10,227 PROD2 DRILL TRIP P Pump out of the hole. Pumping 126 gpm w/ 340 psi. Monitor returns using pit #5. Record PU and SO wt's per Rig en ineer's directions. 09:45 11:00 1.25 10,227 10,227 PROD2 DRILL CIRC P Circulate, pumping 600 gpm w! 2850 psi. Rotate 110 rpm w/ 15k ft Ibs of torque. Circulated a total of 850 bbls. Pumped a 40 bbl a sweep (8.6 ppg/ 200 vis . Sli ht increase in cuttin s. 11:00 11:15 0.25 10,227 10,227 PROD2 DRILL OWFF P Monitor well. Static. 11:15 13:00 1.75 10,227 10,227 PROD2 DRILL CIRC P Displace 8.65 ppg SFOBM w/ 8.8 ppg SFOBM w/ 776 tube. Purring 400 gpm w/ 1400 psi. Rotate 50 rpm w/ 15k ft Ibs of torque before and 13k ft Ibs of torque after displacement. PU 200k, Rot 135k, SO wt 78k. After displacement: 188k PU, 140k rotating wt and 101 k down wt. 13:00 13:15 0.25 10,227 10,227 PROD2 DRILL OWFF P Monitor well. Static. 13:15 17:30 4.25 10,227 352 PROD2 DRILL TRIP P POOH on elevators. Mud losses after displacement, on trip out, was 6 bbls. Record PU and SO wt's per Rig Engineer. Retrieved 2.33" rabbit on top of'ars. 17:30 18:00 0.50 352 169 PROD2 DRILL TRIP P Work BHA#16: Stand back 1 stand of 5" HWDP, UD Dail 'ars. 18:00 19:15 1.25 169 55 PROD2 DRILL PULD P Continue to UD BHA #16. 19:15 20:00 0.75 55 55 PROD2 DRILL OTHR P Download Sperry Sun MWD. 20:00 21:00 1.00 55 0 PROD2 DRILL PULD P Continue to UD BHA #16. Grade Bit. Note: Losses on the trip: TD to the shoe lost 30.5 bbls. Shoe to surface 18.16 bbls. Total losses for the trip = 49 bbls over calculated. 21:00 21:30 0.50 0 0 PROD2 DRILL OTHR P Clean floor. 21:30 22:00 0.50 0 0 COMPZ CASIN( RURD P RU to run the Slotted/Blank liner f/ the "D" lateral. 22:00 22:15 0.25 0 0 COMPZ CASIN ( SFTY P PJSM on running 4-112" Plop and drop liner f/ the "D" lateral. 80 BTC f L " 22:15 00:00 1.75 0 1,705 COMPZ CASIN ( RNCS P - 11.6 pp Run 40jts of4-1/2 slotted/blank liner, per the detail f/ the "D" lateral. PU and SO wt 90k. PagE ~~- of 53 Time Lo s Date From To Dur e th E. De th Phase Code Subcode OM 09/28/2007 00:00 04:30 4.50 1,705 7,190 COMPZ CASIN ( RNCS P . Continue to run 4-1/2" 11.6 ppf L-80 BTC slotted/blank finer, per the detail f/ the "D" lateral. Monitor well using the trip tank. Record PU and SO wt's per Rig Engineer. PU wt 110 k, SO wt 90 k. 04:30 05:00 0.50 7,190 7,190 COMPZ CASIN( RURD P Rig down casing tools. 05:00 06:00 1.00 7,190 9,094 COMPZ CASIN( RUNL P Run liner on 5" drill pipe. Fill pipe w/ 20 stands in the hole. Record PU and SO wt's per Rig Engineer. PU wt 140k, SO wt 105k, Rot wt 122k, Rot for ue 3-4k ft/ lbs. 06:00 07:00 1.00 9,094 10,232 COMPZ CASIN( RUNL P Continue running the 4-1/2" liner on 5" drill pipe. Record PU and SO wt's per Rig Engineer. Above the window: PU wt 157 k, SO wt 100 k, Rot wt 115, Rot for ue 4-5 k ft /Ibs. 07:00 09:15 2.25 10,232 13,567 COMPZ CASIN( RUNL P Continue running the 4-1/2" liner on 5" drill pipe. Record PU and SO wt's eve 5 stands in o en hole. 09:15 16:15 7.00 13,567 17,758 COMPZ CASIN( RUNL P Rotate liner in the hole due to no down wt. Record PU and SO wt's every 5 stands in open hole. Fill pipe every 25 stands. 16:15 18:00 1.75 17,758 17,783 COMPZ CASIN( RUNL P Tag the bottom of the hole @ 17820'. PU wt 260k, SO wt 75k, Rotating wt 155k, rotating torque 16k ft Ibs of torque. Set back a stand, work pipe to setting depth. Drop the 29/32" ball and pump 5 bpm w/ 740 psi for 130 bbls, then slow to 2 bpm w/ 160 psi after a total of 170 bbls pumped, then slow to 1.5 bpm w/ 110 psi till ball was on seat @ 213 bbls pumped. Increase pressure to 3200 psi and release the liner. PU wt Z30k, SO wt 120k. Tag top of liner @ 10601' (shoe @ 17783'). Pressure up to 4450 psi to shear circ sub. 18:00 18:15 0.25 17,783 10,601 COMPZ CASIN( RURD P Bleed off pressure. Rig down test pump lines. Line up mud pumps. Note: Total fluid lost while RIH w/ liner was 26 bbls. 18:15 18:45 0.50 10,601 10,240 COMPZ CASIN( OTHR P POOH from 10601'to 10240' to wash the slot on the whi stock. 18:45 19:45 1.00 10,240 10,240 COMPZ CASIN( CIRC P Circulate 405 gpm w/ 1280 psi, then 500 gpm w/ 1800 psi, then 600 gpm w/ 2460 psi, washing the retrieval slot on the whipstock. Circulate bottom's u . PU wt 215k, SO wt 90k. 19:45 20:00 0.25 10,240 10,240 COMPZ CASIN( OTHR P Monitor well. Slight flow. Mud out of balance. PB~Q ~~ G'i .,3 Time Lo s ..Date From To Dur S: De th E De th Phase Code Subcode T COM 09/28/2007 20:00 20:45 0.75 10,240 10,240 COMPZ CASIN( CIRC P Continue to circulate to even out mud weight. Pumping 500 gpm w/ 1790 psi. Circulate a bottom's up. Note: 14 bbls was lost to the hole while circulatin . 20:45 21:00 0.25 10,240 10,075 COMPZ CASINO OTHR P Pull 2 stands out of the hole with Baker runnin tools. 21:00 21:15 0.25 10,075 10,075 COMPZ CASIN( OTHR P Monitor well. Static. 21:15 00:00 2.75 10,075 3,356 COMPZ CASINO OTHR P Pull out of the hole with the Baker running tools. PU wt 125k, SO wt 108k. Record PU and SO wt's every 10 stands. 09/29/2007 00:00 02:00 2.00 3,356 30 COMPZ CASIN( OTHR P Pull out of the hole with the Baker running tools. PU wt 125k, SO wt 108k. Record PU and SO wt's every 10 stands. Loss of 9 bbls on trip out. Calculated 102 bbls, actual 111 bbls. 02:00 02:30 0.50 30 0 COMPZ CASIN( OTHR P Lay down Baker liner running tools. 02:30 03:00 0.50 0 0 COMPZ FISH PULD P Clean floor, PU Baker whipstock retrievi tools to floor. 03:00 03:15 0.25 0 0 COMPZ FISH SFTY P Pre job safety meeting on PU/MU fishin BHA. BHA #17. 03:15 04:30 1.25 0 259 COMPZ FISH PULD P MU BHA #17 (Retrieve the whipstock assembl 04:30 06:00 1.50 259 3,584 COMPZ FISH TRIP P RIH w/ BHA #17, filling pipe every 20 stands. Record PU and SO wt's every 10 stands. PU wt 120k, SO wt 110k. 06:00 09:00 3.00 3,584 10,106 COMPZ FISH TRIP P Continue to RIH w/ BHA #17, filling pipe every 20 stands. Record PU and SO wt's every 10 stands. 9 bbl loss of fluid to hole on tri in the hole. 09:00 10:15 1.25 10,106 10,106 COMPZ RIGMN SVRG P Slip and cut 110' of drilling line. 10:15 11:15 1.00 10,106 10,106 COMPZ RIGMN SVRG P Service rig and top drive. Check brakes on drawworks.. 11:15 11:30 0.25 10,106 10,244 COMPZ FISH TRIP P Continue trip in the hole. 11:30 14:15 2.75 10,244 10,416 COMPZ FISH FISH P Establish circulation above whipstock, pumping 400 gpm w/ 2210 psi. PU wt 220k, SO wt 105k, w/ pumps off PU 233k, SO 105k. Engage whipstock wl retrieval hook @ 10246', Overpull to 330k and set off jars. PU TO 340K and set off jars again.. Wash slot again w/ 400 psi and 2210 psi. Pick up and saw 50k over ull. 14:15 16:00 1.75 10,416 10,416 COMPZ FISH CIRC P Circulate BU @ 10201' (bottom of whipstock assembly @ 10416'). Pumping 400 gpm w/ 2210 psi. Mud weight at bottom's was 8.3 ppg (.5 light). Circulated a total of 780 bbls to get 8.8 ppg in and out. Note: lost 5 bbls to the hole when whi stock was ulled free. Page ~5 ut53 Time Lo s Date From To Dur e th E. De th Phase Code Subcode T COM 09/29/2007 16:00 17:15 1.25 10,416 10,416 COMPZ FISH OTHR P Monitor well, flowing. Rate of flow (gains), calculates to be 1.3 to 1.5 b h. 17:15 18:15 1.00 10,416 10,416 COMPZ FISH CIRC P Circulate 400 gpm w/ 2210 psi, weighting up f/ 8.8 ppg to 8.9 ppg. Circulate a total of 592 bbls. Note: 14 bbl gain due to additions of wei ht material. 18:15 18:45 0.50 10,416 10,403 COMPZ WELCT OTHR NP Appeared to have a gain in the pits. Shut top pipe rams, open HCR to choke. Monitor wellbore pressure of 20 psi at the choke. Rig supervisor and toolpusher were notified. Verified that there was no pressure. Opened top pipe rams. Note: Trip tank was pumped out to active pits. Chuck Sheave w/ AOGCC was notified of the rams bein shut. 18:45 21:30 2.75 10,403 10,403 COMPZ WELCT CIRC NP Circulate until 8.9 ppg MW was acheived in and out. Circulate 400 m w/ 2090 si. Circulate 1340 bbls. 21:30 22:00 0.50 10,403 10,403 COMPZ WELCT OWFF NP Monitor well, slight breathing-- to just about static. 22:00 23:15 1.25 10,403 10,046 COMPZ FISH TRIP P Pull out of the hole w/ Whipstock assembly. First stand pulled on elevators swabbed, then pumping out 3 stands (3 bpm w/ 280 psi). Swabbed a total of 11 bbls + should have taken 6 bbls = 17 bbl gain. PU wt 240k, dra in to 270k. 23:15 00:00 0.75 10,046 10,046 COMPZ FISH CIRC P Circulate a bottom's up. Pumping 500 gpm w/ 3180 psi. Circulate a total of 562 bbls. Mud weight 8.9 ppg in and out. 09/30/2007 00:00 00:15 0.25 10,046 10,046 COMPZ FISH OTHR P Monitor well, static. 00:15 01:45 1.50 10,046 9,772 COMPZ FISH OTHR P POOH with Baker retrieving hook and fish (whipstock assembly). Hole swabbing. Rotate while picking up trying to free up, no luck. Then reciprocate up and down trying to free up. Swabbing up, pushing mud back in the hole on the down stroke. Finally quit swabbing, hole taking fluid. Set back stand. Pull a stand with hole takin fluid. PU wt 240k. 01:45 02:00 0.25 9,772 9,772 COMPZ FISH OTHR P Monitor well, fluid falling slightly. 02:00 03:00 1.00 9,772 9,772 COMPZ FISH CIRC P Circulate bottom's up. Circulate a total of 552 bbls. Pumping 500 gpm w/ 2980 psi. Lost 26 bbls to the hole while circulatin . 03:00 03:15 0.25 9,772 9,772 COMPZ FISH OTHR P Monitor well, static to slight breathing. F~a~ ~? cf .^.3 Time Logs Date From To Dur e th E. De th Phase Code Subcode T M 09/30/2007 03:15 06:00 2.75 9,772 4,500 COMPZ FISH TRIP P POOH w/ Baker retrieval hook and fish (Whipstock assembly). Monitor well on the trip tank. Hole taking extra fluid over calculated. 06:00 08:30 2.50 4,500 276 COMPZ FISH TRIP P Continue to POOH w/ Baker fishing assembly with the fish (Whipstock assembly). Calculated hole fill 93.8 bbls, actual hole fill 93.8 bbls. 3 bbls over calculated. 08:30 09:45 1.25 276 185 COMPZ FISH PULD P Lay down Baker fishing assembly to the pipe shed. Break and lay down fish: Whipstock, debris sub, drain sub, string magnet, safety disconnect, bottom tri anchor, blank sub. 09:45 10:30 0.75 185 185 COMPZ FISH OTHR NP After breaking off 5" drill pipe under the blank sub, there was a uncontrolled release of fluid into secondary containment. Estimated 10 gals of OBM w/ crude. This release was due to trapped pressure in the remaining 5 joints of drill pipe under the blank sub. Pressure due to mi ratin as and oil. 10:30 12:00 1.50 185 0 COMPZ FISH PULD P Continue to tay down and back off space out pup and 5 jts of 5" drill pipe, unloader, crossover sub, no go sub and seal assembl . 12:00 12:45 0.75 0 0 COMPZ FISH PULD P PU/Break and lay down fishing assembl . 12:45 13:15 0.50 0 0 COMPZ FISH OTHR P Clean and clear rig floor. 13:15 14:00 0.75 0 0 COMPZ WELCT OTHR P Rig up to test BOPE. Drain stack, pull wear bushin ,fill with water. 14:00 19:00 5.00 0 0 COMPZ WELCT BOPS P Test ROPE. Witness of test waived by AOGCC inspector Chuck Scheve. Tested to 250 psi low and 3000 psi high. Test each fl 5 min. Chart test. Test upper pipe (3-1/2" x 6"variables w/ 5.5" and 4.5". Tested annular w/ 4.5". Tested all floor safety valves, upper and lower IBOP on the top drive, kill and choke line valves, choke manifold. Test Komme . 19:00 20:00 1.00 0 0 COMPZ WELCT OTHR P Rig down testing equipment. Drain stack. Set wear bushing. Blow down and line u choke manifold. 20:00 21:00 1.00 0 0 COMPZ CASIN( RURD P Rig up to run the 4-1/2" hook Hanger assembl . 21:00 21:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running the 4-1/2" Hook Han er assembl f/ the "D" lateral. 21:15 22:30 1.25 0 364 COMPZ CASIN( RNCS P PU/MU/RIH w/ 4-1/2" hook hanger assembl f/the "D" lateral. 22:30 00:00 1.50 364 364 COMPZ CASIN( OTHR P MU inner string tools w/ Sperry Sun Slim MWD. 156' of inner strip 10/01/2007 00:00 00:45 0.75 364 364 COMPZ CASINC OTHR P MU inner string tools w/ Sperry Sun Slim MWD.(156' of inner string). Orient to Baker hook hanger. Note orientation of bent 'oint to hook. r Time Lo s .Date. From To Dur S. De th E. De th Phase Code Subcode T COM 10/01/2007 00:45 01:15 0.50 490 490 COMPZ CASIN( RURD P Rig down GBR tongs. Rig down Baker small tools f/ the 2-3/8". 01:15 01:45 0.50 490 490 COMPZ CASIN( CIRC P Shallow test MWD. Pumping 120 gpm w/ 490 psi. Did not get a good test. Tried both pumps. Pump # 2: 120 gpm w/ 500 psi. 130 gpm w/ 540 psi. Pum # 1" 120 m w/ 470 si. 01:45 03:00 1.25 490 2,781 COMPZ CASIN( RUNL P RIH w/ Hook Hanger assembly on 5" drill pipe. Filling every 25 stands. Record PU and SO wt's every 10 stands. PU wt 120k, SO wt 100k. 03:00 04:15 1.25 2,781 2,781 COMPZ CASIN( OTHR P Work to get MWD detection. Pumping 115 gpm w/ 680 psi. Acheived a good toolface. 04:15 06:00 1.75 2,781 5,633 COMPZ CASIN( RUNL P RIH w/ Hook Hanger assembly on 5" drill pipe. Filling every 25 stands. Record PU and SO wt's every 10 stands. PU wt 155k, SO wt 105k. Fill and check MWD @ 5158', pumping 120 m w/ 680 si. Good test. 06:00 07:00 1.00 5,633 7,538 COMPZ CASIN( RUNL P Continue to RIH w/ Hook Hanger assembly on 5"drill pipe. Filling every 25 stands. Record PU and SO wt's every 10 stands. PU wt 120k, SO wt 100k. 07:00 07:30 0.50 7,538 7,538 COMPZ CASIN( CIRC P Fill and check MWD @ 7538', pumping 120 gpm w/ 680 psi. Good test 07:30 09:30 2.00 7,538 10,162 COMPZ CASIN( RUNL P Continue to RIH w/ Hook Hanger assembly on 5"drill pipe. Filling every 25 stands. Record PU and SO wt's every 10 stands. Total of 3 bbls loss while RIH. 09:30 11:45 2.25 10,162 10,623 COMPZ CASIN( RUNL P Orient MWD to 30L @ 10162', then RIH to 10505' (no go in the B lat), POOH to 10162', turn string 90 deg right. Work torque, then trip back to 10505' (tagged out again). POOH to 10162', turn string another 90 deg. Work torque and trip in to 10623'. Sucessfully went out the window on the 3rd attem t. 11:45 12:15 0.50 10,623 10,623 COMPZ CASIN( OTHR P Orient hook hanger to 10 left. Pumping 120 gpm w/ 820 psi. PU 248k, SO wt 105k with um son. 12:15 12:45 0.50 10,623 10,257 COMPZ CASIN( OTHR P PU wt 250k, SO wt 100k. RIH to 10257' and hook w/ 30k on Hook. Hooked @ 27 right. POOH to 10234', orient 1801eft then RIH to 10272' to confirm hook @ 10257'. POOH to 10234' and orient to 10 Left. PU wt 250k, SO wt 100k. RIH and hook @ 27 ri ht w/ 30k on hook. FaeE 49 q 53 Time Lo s Date 10/01/2007 From 12:45 To 14:30 Dur 1.75 S. De th 10,257 E. De th 10,257 Phase COMPZ Code CASIN( Subcode OTHR T P COM Drop and pump 29132" ball. Pump @ 120 gpm w/ 810 psi. Slow down to 88 gpm after 1400 strokes. Pumping 88 gpm w/ 420 psi. Bafl on seat @ 200 strokes (200.8 bbls). Pressure up to 2800 psi to inflate ECP, pressure bleed down to zero. While pumping 30 spm (298 gpm) was able to pressure to 4000 si and blow ball seat. 14:30 15:00 0.50 10,257 9,928 COMPZ CASIN( OTHR P Pull out of the hole on elevators with the inner strip f/ 10408' to 9928'. 15:00 16:15 1.25 9,928 9,928 COMPZ CASIN< CIRC P Circulate a bottom's up. Pumping 7 bpm w/ 750 psi, final pumping rate 9 b m w/ 1150 si. 16:15 16:45 0.50 9,928 9,928 COMPZ CASIN( OTHR P Monitor well. Breathing to static. 16:45 21:30 4.75 9,928 154 COMPZ CASIN( OTHR P Continue to POOH w/ Baker running tools. Monitor well on tri tank. 21:30 21:45 0.25 154 154 COMPZ CASIN( OTHR P Lay down Hook Hanger running tools. 21:45 22:15 0.50 154 154 COMPZ CASIN( OTHR P Break Sperry Sun MWD to change out ulsar. La down MWD. 22:15 23:30 1.25 154 0 COMPZ CASIN( OTHR P Lay down Hook Hanger running tools. Calcualted fill 94.5 bbls, actual fill 110.5 bbls. Hole took 16 bbls over calculated. 23:30 00:00 0.50 0 0 COMPZ CASIN( OTHR P Lay down Baker pups, clear/clean floor. Shut blind rams. 10/02/2007 00:00 00:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running LEM f/ the "D" lateral Hook Han er. 00:15 01:30 1.25 0 276 COMPZ CASIN( RNCS P Pickup/ Makeup LEM f/ the "D" lateral er the runnin order. 01:30 02:15 0.75 276 296 COMPZ CASIN( OTHR P Makeup inner string w/ Sperry Sun MWD. MU Baker Torquemaster to strip . Orient to o enin of LEM. 02:15 02:45 0.50 296 391 COMPZ CASIN( OTHR P PU/MU stand of 5"drill pipe. Shallow pulse test MWD. Pumping 118 gpm w/ 650 si. Good test. 02:45 10:30 7.75 391 10,420 COMPZ CASIN( RUNL P RIH w/ LEM on 5" drill string. Fill pipe every 25 stands. Recording PU and SO wt's every 10 stands. RIH 30' per min. Fill pipe @ 2645': pumping 105 gpm w/ 650 psi. Good test. Fill pipe @ 6954': pumping 115 gpm w/ ??? psi, Fill @ 8572' :pumping 115 gpm w/ 730 psi. PU wt 225k, SO wt 115k. Calculated displacement 104.5, actual 103.5 bbls. Note: 5" drill pipe: Ran 40 stands w/ super sliders, 50 stands slick, then 17 stands of 5" HWDP, then a working stand to settin de th. 10:30 10:45 0.25 10,420 10,420 COMPZ CASIN ( CIRC P Establish circulation w/ 100 gpm wJ 730 psi. Orient to 9 right. PU wt 225k, SO wt 115k. Foe 5Q of 53 Time Lo s Date From To Dur S. De th E. De th Phase Code- Subcode T COM 10/02/2007 10:45 11:15 0.50 10,420 10,496 COMPZ CASIN ( RUNL P Continue to RIH w/ LEM on 5" drill pipe. Pumping 100 gpm w/ 730 psi and collet latched in. Slacked off to 70k (45k below down wt), PU to 250k (25k over PU wt) to confirm latched in. Slack back off to block wt of 70k. LEM in lace w/ MWD readin 21 ri ht. 11:15 13:00 1.75 10,496 10,496 COMPZ CASIN( CIRC P Drop the 29/32" ball, pump down @ 109 gpm w/ 870 psi. till 160 bbls pumped, then slow to 84 gpm w/ 720 psi. Ball on seat after pumping 203 obis. Pressure to 4400 psi and release and shear ball f/ seat. 13:00 13:45 0.75 10,496 10,496 COMPZ CASIN( DHEQ P Establish circulation throught the kill line. Using the top pipe rams (3-1/2" x 6" variables), test the 9-5/8" & 10-3/4"casing and Baker Torquemaster Packer (813-47 x 38) to 2500 psi f/ 30 minutes. Chart test. Lost 75 si. Good test. 13:45 14:30 0.75 10,496 10,134 COMPZ CASIN( OTHR P Pull out of the hole. PU wt 220k, SO wt115k. 14:30 15:45 1.25 10,134 10,134 COMPZ CASIN( CIRC P Circulate @ 294 gpm w/ 840 psi, adding lubricant 776 to increase concentration to 3%. Circulated a total of 507 bbls. 15:45 16:15 0.50 10,134 10,134 COMPZ CASIN( OTHR P Monitor well. Slight breathing to static. 16:15 16:30 0.25 10,134 9,981 COMPZ CASIN( CIRC P Establish circulation pumping 28 gpm w/ 440 psi. Pump a 20 bbl dry job (10.1 ppg/72 vis). Then drop the Haggard ID wiper inside of the drill i 16:30 16:45 0.25 9,981 9,981 COMPZ CASIN< OTHR P Blow down the choke and kill lines, to drive too. 16:45 17:00 0.25 9,981 9,981 COMPZ DRILL SFTY P PJSM on laying down 5" drill pipe. 17:00 00:00 7.00 9,981 2,800 COMPZ DRILL PULD P Lay down 5"drill pipe to the pipe shed. Remove super sliders from the 5" drill pipe w/ POOH. At 2800' : PU wt 105k, SO wt 95k. Remove 6" liners and install 6-1/2" liners in #2 m . 10/03/2007 00:00 02:30 2.50 2,800 50 COMPZ DRILL PULD P Lay down 5"drill pipe to the pipe shed. Remove super sliders from the 5" drill pipe w/ POOH. Calculated fill 101 bbls, actual 109 bbls. 02:30 03:00 0.50 50 50 COMPZ DR1LL PULD P Remove super slider hardware from the floor. Clean floor. 03:00 03:15 0.25 50 50 COMPZ DRILL OTHR P RU to UD LEM running tool w/ Sperry Sun slim MWD. 03:15 03:30 0.25 50 50 COMPZ DRILL SFTY P PJSM on laying down LEM running tool. 03:30 04:15 0.75 50 0 COMPZ DRILL PULD P Break and UD Baker running tool f/ the LEM. Break and UD inner string (Sperry Sun MWD). Total loss on trip 7.8 bbls. Pace 51 of 53 Time. Lo s Date From To Dur e th E. De th Phase Code Subcode T M 10/03/2007 04:15 04:30 0.25 0 0 COMPZ DRILL OTHR P Drain stack, pull Vetco wear bushing and remove from the floor. 04:30 05:15 0.75 0 0 COMPZ DRILL RURD P Rig dowm LEM handling tools. Clean floor. 05:15 05:45 0.50 0 0 COMPZ RPCOh RURD P Rig up to run 4-1/2" injector com letion. 05:45 06:00 0.25 0 0 COMPZ RPCOh SFTY P Pre job safety meeting on running com letion. 06:00 16:30 10.50 0 10,199 COMPZ RPCOh RCST P PU/RIH w/ 4-1l2" 12.6 ppf L-801ST-m completion assembly. Record PU and SO wt's every 10 stands. Change liners in #1 mp to 6-1 /2". PU 130k, SO 88k. 16:30 17:00 0.50 10,199 10,219 COMPZ RPCOA RCST P Five foot in the hole to set Baker Anchor Seal assembly into the Baker Torquemaster packer (RIH on dp @ 10210') (tubing tally is 5.57' shorter, so by tubing tally 10215.80'), latch in. PU to 130k, then pull 40k over to shear 4 ins in the PBR. 17:00 17:15 0.25 10,219 10,122 COMPZ RPCOh TRIP P POOH to 10122' to space out. Totaf of 325 'ts in the hole. 17:15 18:00 0.75 10,122 10,122 COMPZ RPCOR OTHR P Figure space out to be approx 4' from fully inserted in PBR. Pups will allow f/ 3.42' space out. Used pup jts 7.79', 7.79', 3.8', 5.8'. Blow down choke and kill lines and the to drive. 18:00 19:00 1.00 10,122 10,219 COMPZ RPCOR HOSO P MU space out pups, then 1 full jt (JT # 326), then MU Vetco Gray MB 222A hanger w/ 4.909" MCA top connection. Total fluid lost on trip in w/ tubing = .7 bbls. 19:00 19:30 0.50 10,219 10,219 COMPZ RPCOh DHEQ P RILDS. Test upper and lower tubing hanger body to 230 psi low and 5000 psi high. Hold each test 10 min. OK. Witness b Ri Su ervisor. 19:30 23:15 3.75 10,219 0 COMPZ RPCOR NUND P Pull the 4-1/2" landing joint. Rig down the flow line, hole fill, choke and kill lines. Remove flow Hippie, PU BOP stack and set back. PU high pressure riser and set back. Continue cleaning pits. Changing liners and swabs in # 1 m to 6-1/2". 23:15 00:00 0.75 0 0 COMPZ RPCOh NUND P NU Vetco Gray 4-1/8" 5m horizontal injector tree w/ 9-1/2" 4TPIOtis tree ca 4.125" ID. Continue cleanin its. 10/04/2007 00:00 00:30 0.50 0 0 COMPZ RPCOh NUND P Continue to NU Vetco Gray 4-1/8" 5m Horizontal injector tree w/ 4-1/8" actuated valve. 00:30 01:15 0.75 0 0 COMPZ RPCOh DHEQ P Test tubing hanger void to 225 psi and 5000 psi. Hold f/ 10 min. Good test, witnessed b Ri Su ervisor. 01:15 03:00 1.75 0 0 COMPZ RPCOA DHEQ P Pull BPV, then set two way check. fill tree w/diesel. Test to 240 psi and 5050 psi. Hold each test f/ 10 min. Good test. Witness by Rig Supervisor. Pull two wa check. Page vi oa ~3 ' Time Lo s . Date From To Dur S. e th E. De th Phase Code Subcode T OM 10/04/2007 03:00 03:45 0.75 0 0 COMPZ RPCOh RURD P RU to freeze protect well w/diesel (185 bbl) to 2920' before "U" tubing and 2270' (1882' TVD @ 65 deg) after "U" tubin diesel. 03:45 04:00 0.25 0 0 COMPZ RPCOh SFTY P PJSM f/ freeze protecting well using ASRC um truck. 04:00 06:30 2.50 0 0 COMPZ RPCOh FRZP P ASRC pump 2 bbls, pressure test lines to 2500 psi. ASRC start off pumping 2 bpm w/ 300 psi @ the well, 750 psi @ the pump truck. Pumped 70 bbls w/ no losses, then increase rate to 3 bpm w/ 360 psi @ the well, 1050 psi @ the pump truck. While pumping 180 bbls wellhead pressure was 475 and pump truck pressure was 1050 psi. Pumped a total of 185 bbls of diesel w/ a total of 185 bbls returned to the pits. Final static pressure was 310 psi. Note: 8 bbls pumped before fluid to the bottom of the gas buster. 24.5 bbls pumped till fluid out the discharge of the gas buster. 16.5 bbls to fill gas buster. Note: Layed down 45 joints of 5"drill pipe from the derrick while pumping, via the mouse hole. 06:30 07:30 1.00 0 0 COMPZ RPCOh FRZP P "U" tube diesel f/ the annulus to the tubing. Initial pressure on the annulus was 310 psi, final pressure was 280 psi. Note: Continue to lay down 5" drill pipe from the derrick, using the mouse hole. Continue cleanin its. 07:30 11:45 4.25 0 0 COMPZ DRILL PULD P Continue to lay down 5" drill pipe from the derrick, using the mouse hole. While laying down drill pipe, observed an extra 20-30000 ft Ibs of torque required to break connections. RU rig tongs and snub line to keep from bendin 'oints. Move rock washer. 11:45 13:15 1.50 0 0 COMPZ RPCOh OTHR P RU lubricator and set BPV. Tubing pressure 210 psi, 10-3/4" & 9-5/8" x 4-1/2" tubing {IA) was 220 psi, 13-3/8" x 10-3/4" & 9-5/8" casing (OA) was 125 psi. Bleed pressure to zero above BPV. 13:15 15:00 1.75 0 0 COMPZ RPCOh OTHR P Cleaning up cellar box, secure well. Prepare rig floor to skid rig (pin back beaver slide), blowing down steam and water lines, disconnect air steam and mud lines. Page 53 c: v3 Daily Operations Summary Report 1J-176 Job: DRILLING ORIGINAL 18/16/2007 8/17/2007 8/18/2007 8/19/2007 8/20/2007 i 8/21 12007 8/22/2007 8/23i20D7 i 8/24/2007 8/25/2007 8/26/2007 8/27/2007 8/2S/2007 8129/2007 8/30/2007 8131 /2007 9/1 /2007 9/2/2007 5/3/2007 9/4/2007 9/5/2007 9/6/2007 9%7'200 7 9!8i20D 7 Erd oah r c -a=r s~.m ~ 8/17!2007 Demob rig from 1J-162. Move to 1J-176. Rig up. Rig accepted @ 2300 HRS 3-16-07 l 8/18/2007 Complete rlg up. C/O Saver sub, Slip & cut drilling line. Take on mud. Rack back DP. MU BHA #1. Spud well. Dril 16" surface hole to 317' TD. TVD = 317'. 8/19/2007 Directional Drill 16" Surface hole from 317' - 1593'. TVD = 1439'. ADT = 9.69 HRS ~ 8/20/2007 Directional Drill 16" Surface hole from 1593' - 3211' MD, TVD - 2157'. ADT = 11.39 HRS 8/21/2007 Directional Drill 1n" Surface hole from 3211' - 3805' = TD. TVD = 2302'. Observed "ledge" at 3400' MD +/-, and continue knock down ledge. Continue drill to TD well @ 3805 MD, TVD = 2302'. BROOH, pumping Hi Visc sweep. BROOH to 2834' @ 10 min/stand. 8/22/2007 Continue BROOH to 1692' MD. Trip back to TD. Circulate & POOH on elevators. Lay do BHA. RU 8 run 13 3/8" casing to 1410' MD. Hit bridge at 1410' MD Work casing string atempting to make hole. 8/23/2007 Continue work casing string through bridge @ 1410' MD_ No success- Rig up and POOH laying down casing. make hole operner BHA and trip in hole.POOH. MU Hoie operner BHA #2. 8/24/2007 Run Hole opener BHA to TD. Circulate & condition mud whole BROOH at 10 ftr'min. POOH. RU & run '13 3/8" casing to set on depth. Circulate ~ condition mud. Rig up & turn over to Dowell for cmt job. 8/25/2007 Nipple down Diverter system. NU BOP's 3 test same. Make up BHA #4, 12 1/4" drilling assembly. i 8/26/2007 Upload MWD. MU remaining BHA. TIH, picking up singles from pipe shed. MU 12 1/4" Ghost reamer. Perfom~ Pulse test. TIH. to tag FC. CBU. perform casing test to 3000 PSI. Drill out Shoe track. perform LOT to 14.3 ppg.. Drill 12 1/4" INT. Hole to 5758' MD. 2577' TVD 8/27/2007 Drill 12 1/4" Intermediate hole to 9690' MD. TVD = 3095'. Circulate sweep & condition mud, Circulate to control ECD's 8/28/2007 Drill 12 1/4" Intermediate hole to TD. CBU x 4, until hole clean, and POOH on elevators. 8/29/2007 BROOH, CBU x 5 at the shoe. slip and cut drilling line. continue POOH. lay do BHA #4 MU Hole opener BHA #5, upload same. 8/30/2007 Finish upload of MWD, finish MU BHA #5, RIH to 6600', Log f/ 6600' to 9050' (360-450 f}Jhr), RIH to 10250', Log f/ 10250' to 1 D875' (200 fb'hrj. 8/31/2007 Log f/ 10875' to 11010' (200 ft/hr), backream (11010`- 10455') slow while circ 6 8U's, monitor well, POOH on elevators f/ 10455' to 8652', monitor well, pump a dry job, POOH f/ 8652' to 3703', Circ casing clean, spot steel tube pill, POOH, remove sources, download, L/D BHA #5, clean floor, change top pipe rams to 10-3/4", test rams, RU f/ casing, PJSM on running 9-5/8" casing. 9/112007 Run 9-5/8" casing, CBU @ 1966', con't RIH wl casing. circ 290 bbls (a BU) @ 5000', continue running casing, circ 150 bbls (OH volume) a 7300', continue running casing.. circ 176 bbls @ 8913' white changing over equipment f/ 10-3/4". install x-o jt, circ 256 bbls while changing equipment, continue nrnning casing to 9900' @ midnight. 9/2/2007 Running i 0-3/4" casing f/ 9900' to i 0975, circ down {anding joint to 11092', circ 135 bbls, remove Frank's filiup tool, RIH to 11002', install Dowell cement head, reciprocate 30' while circulating and conditioning mud prior to cementing, Cement casing, displace w/ SFOBM, bump plug, floats did not hold, repressure to 1000 psi, still not holding, re-pressure to 800 psi WOC, Conduct infectivity test on 13-3/8" by 10-3/4" & 9-5/8" annulus, bleed off pressure on 10-3/4" casing-- cement set up with no bleed back. 9i3/2C07 Rig down cement head and lines, nipple down to PU BOP stack and set emergency slips, work on slips to fit around 10-3/4" casing, set 315k on wt indicator on the slips, cutoff 10-:;~4" casing, install packoff, NU VetcolGray '~ wellhead, test packoff, remove 10-3/4" rams fl top pipe, PUIMU 14 stands of 5" HWDP, Hydril rep look @ ram ', .shaft of off driller's upper pipe rams. change out clutch inside of BOPE, change upper rams to 3-1 /2" x 6", test ~~ rams. rig down testing equipment. 9/4/2007 Install VetcolGray wear bushing and secure same, PJSM, PU/MU BHA #6, shallow test, PU/RIH w/ i 7 stands of dp f/ the pipe shed, Run stands f/ the derrick, Run 40 stands w/ super sliders f/ the pipe shed, circ BU @ 10894', RU and test casing to 3000 psi, not holding, circ BU, test casing, not holding, test surface equipment- OK, monitor well, POOH w/ BHA #6, SLM. 9/5/2007 RUltest intermedaite casing with blinds shut. no test. MU Baker retrievamatic, RIH to 2103', test casing to 3000 psi- 5 min- good test ,RIH to 6478', test casing to 3000 psi- 5 min- good test, RIH to 10885', test casing to 3000 ' psi f/ 3D min- chart test- good test, pump dry job, POOH, L'D tool. Pull wear bushing, RU and test BOPE w/ 4-1/2", 5" and 5-112" test joint, R!D testing equipment, set Vetco Gray wear bushing. 9/6/2007 Blow down kill e~ choke lines, PJSM on PU/MU BHA #8, PU/MU/RIH w/ BHA #8 to 10821', slip and cut dulling line, service rig, make connection and drill cement, wiper plugs, FC @ 10909', cement, guide shoe @ 11000', rat hole to 11010', 20' of new hole to 11030', circulate, perform LOT (calculated to 13.1 ppg), Rig-down testing equipment, perform PWD baseline, directional drill "B" lateral to 11580'. 9/72007 Directional drill "B" lateral f/ 11580` to 15700'. 9!3/2007 Directional drill "E" lateral f/ 15700' to 1 7 1 36', BROOH to 16932' while work on # 2 mud pump. directional drill f/ 17136' to 17820'. 9/9/2007 Directional drill "B" lateral f/ 1782D' to 17940', pump a sweep and BROOH to 11080', POOH to the casing shoe, circ a sweep surf-surf- then 4+ BU's (3238 bbls) to clean casing. Service Rig. Page 1/3 Report Printed: 11/9/20071 Daily Operations Summary Report 1J-176 Job: DRILLING ORIGINAL SL~rt Gsts Ei~d Oa~a _ _ L s[24hr hum 9/9/2007 9/10/2007 Finish senncing rig, RIH f/ 10913' to 11018', Rotate and ream in the hole to TD @ 17940', Displace to 8.4 ppg SFOBM, monitor well, POOH on elevators to 17074', pump out to shoe, continue to pump out to 9203' ,POOH to 8442' @ midnight. 9/10/2007 9/1 1!2007 POOH w/ BHA #8 f/ 8442' to 353, PJSM, UD part of BHA # 8, downlaod MWD, Continue UD BHA #8, clean floor, remove shot pin assembly on the top drive. PJSM. RU Schlumberger WL to run USI, Run in hole to 2600', tractor to 8283`, POOH wl WL tools. LiD WL tools, install shot pin assembly on the top drive. 9/11/2007 9/12/2007 Finish working on the top drive, MU BHA # 9- cleanout run, TIH to shoe, the TIH to 13400' MD. Circulate each depth, monitor well with gains of 1 2 - 2 8 BBLS / HR. 9/12/2007 9/13/2007 Continue wash & ream into hole to TD @ 17940' MD. Circulate 8 condition mud monitoring well for flow. Pump Hi Visc sweep, and monitor well until no flow observed. Pump out of hole to 13064' MD, with proper hole fill. 9/13/2007 9/14/2007 Continue Pump out of hole to shoe. Sweep hole, and pull to 10300'. Displace well with SFMOBM with 776 Lube at 3~, POOH. RU SWS for USIT logging run, 9/14/2007 9/'15,'200? Pul! to 10300' MD. Displace well with 8.8 PPG MOBM Monitor well. POOH. Monitor well every 2000' on TOH. 9/15/2007 9/16/2007 Rig up and test upper rams & blind rams as per AOGCC regs. Rig up & Run 5 1/2" B lateral liner. Tag bottom @ 17946' with shoe. Pullup to set TOL on depth as planned. Drop ball and pump doom same. 9/16/2007 9/1712007 Set ~ release from 5 1/2 liner assmbly. Test casing & packer to 2500 PSI. CBU & condition mud. POOH. RU 3 run USIT log. 19/17/2007 9/13!2007 Complete USIT logging run. RD SWS. Rig up. Test BOP's. MU Whipstock assmy. i 9/18/2007 .9/1912007 Make up whipstock assmy. TIH, and set whipstock. Displace well with 8.4 PPG OBM. Mill window, Circulate ~ sweep until clean. Monitor well. 9/19/2007 9/20/2007 I POOH, Breakout & lay down Milling BHA. Flush BOP stack. Make up 8 112" Drilling BHA. TIH. Directional drill ~Ifrom 10290' - 10442' MD. TVD = 3185'. Observed 1000 PSI loss of pressure. Trouble shoot. POOH to surface ~ ~ ~^ I~'(o~,,,,?~~~~1-';~+' ~~'f~•bserving Drilling jars twisted off. X9/20;2007 9/21/2007 MU Overshot fishing BHA, TIH ,Could not get overshot assembly over top of whipstock. Repeat attempts. POOH, lay down BHA, MU Milling BHA, TIH to dress top of whipstock area until clean. Circulate a sweep around '~ with increased cuttings, at surface. POOH. 9/21/2007 9/22/2007 MU Overshot fishing BHA, TIH, Tag & catch fish. pullover to verify, pump to gain MWD pulses. POOH, lay down BHA, &fshing BHA. MU Reverse Circulating basket. TIH. Wash down to TD c~ 10444'. ,9122/2007 9/23/2007 POOH, lay down Fishing BHA. MU 8 1/2" Drilling BHA, TIH, Continue dril(D lateral from 10442' - i 1267' MD. ND = 3199'. ADT = 7.4 HRS. 19/23/2007 9/24/2007 Directional Drill D lateral to 15282' MD. TVD = 3171'- ADT = 15.64 HRS. Bit HRS=23.04. ECD = 122 PPG 9/24/2007 9/25/2007 Directional Drill D lateral to 17444' MD. TVD = 3141'. ADT= 13.81 HRS. Bit Hrs = 36.85. ECD = 1214 PPG 19/25/2007 9/26/2007 Directional Drill "D" lateral to TD @ 17820', circulate sweep and 3 BU, BROOH to 10339' @ midnight. ~ 9!2612007 9/27;2007 POOH w/ pumps f/ 10339' to above the window, pump 50 bbls weighted/hi vis sweep + 3 BU. monitor well, change out saver sub, service rig, trip in on elevators to 10722', ream in to 15665'. circ 220 bbls. continue to ream to TD @ 17820', circ BU, pump sweep around plus a BU, displace to 8,6 ppg SFOBM, monitor well. POOH total of 3 stands HWDP. pump out of the hole to 16710' @ midnight. 9;2712007 9/28/2007 GonGnue to pump out of the hole f/ 16710' to 10227, monitor well, circ a sweep, displace casing to 8.8 ppg SFOBM w/ 776 Tube, POOH on elevators, UD BHA #16, clean floor, RUlRun 4-1/2" slotted liner f/ the "D" lateral to 1705'. 9/28/2007 9/29/2007 Continue running 4-1/2" slotted liner f/ the "D" lateral f/ 1705' to 7194', rig down casing tools, RIH w/ liner on 5" drill pipe to 13567'. rotate liner to TD @ 17820', PU and put liner on depth, drop 29!32" ball pump to seat. release '~ from liner, blow ball seat. POOH to wash the slot on the whipstock @ 10240'. CBU, monitor well, CBU, POOH 2 ~, stands. monitor well, POOH w/ Baker running tools to 3356' @ midnight. 9/29/2007 9/30/2007 Continue POOH w/ Baker running tools from 3356', UD running tool, PU/MU/RIH with tools f/ retheving Hook Hanger to 10106', slip and cut drilling line, RIH, engage whipstock, pull free, circ, monitor well, weight up to 8.9 ppg, shut top pipe rams w/ 20 psi on choke, bleed off, circ, monitor well, POOH to 10046', hole swabbing, circulate. ,9130/2007 10/1/2007 Monitor well. POOH and try to free up whipstock assembly to pass fluid, work 10046' to 9955'. finally started ~ taking fluid, CBU, monitor well. POOH w~ Baker retieval hook and fish Whipstock assembly). LiD fshing tools to , pipe shed, UD whipstock assembly, PU fshing assembly, break and U'D fishing assembly, clean foor, RU to test ROPE. testing BOPE, set wear bushing, RUIRIH w/ "D" lat Hook hanger assembly. MU inner string. 10/1/2007 10/2/2007 MU inner sthng ft Hook Hanger assembly, orient MWD with the Baker Ho©k Hangar, R/D tongs and 2-3/8" handling tools, RIH one stand, shallow test MWD, RIH w/ hook hanger to above window (10162'), RIH and tag B lat no go, POOH, turn 90 deg, RIH and tag again, POOH turn 90 deg, RIH -out the window. Hook window @ 10257', PU turn 180, slack off past, PU, Hook window @ 10257', pump ball down to release and inflate ECP, ECP opened @ 2800 psi but could still circ, blow ball seat, POOH to 9928', circulateBU, monitor well, POOH w/ running tools, UD running tools, clean floor, prepare to PU LEM. Page 2/3 Report Printed: 11/9/2007! Daily Operations Summary Report 1 J-176 SlSC Dale 10/2/2007 10/3/2007 110/4/2007 Job: DRILLING ORIGINAL ~r,1 Dats.. L , 24-r 5 r. __.. 10/3/2007 PJSM on picking up 4-1/2" LEM f/ the "D" lateral, PU/MU/RIH w/ LEM, shallow test, RIH on 5" dp to mule shoe depth of 10496', latch in w/ final orientation of 21 right, pump down 29/32" ball, set Trorquemaster packer w! top @ 10210', test to 2500 psi f/ 30 min, POOH to 10134', circulate and freshen up the SFOBM w/ 776 lubricant to 3%, pump a 20 bbls dry job, drop the Haggard ID wiper, POOH Laying down 5"drill pipe. Depth of 2800' @ midnight. 1014/2007 Continue to POOH Laying down 5" drill pipe f/ 2800', break and V'D baker running tools and inner string, remove super slider hardware and misc. from rig floor, clean floor, Pull Vetco wear bushing, RU to run 4-1 /2" completion. PJSM, PUiRIH w/ 4-1 /2" 12.6 ppf L-80 IBT-m tubing, space out and land same w/ BPV set, N/~/NU tree. i 0/5/2007 NU Vetco Gray 4-1 /8" Hohzontal injector tree, test hanger void low and high, test tree low and high, freeze protect by pumping down the 10-3/4" 8~ 9-5/8" x 4-1/2" to 2920', then "U" tubing 185 bbls diesel back to the 4-1/2" tubing, this .should equalize @ 2592' MD (1992' TVD). Install BPV. secure well. Release rig @ 1500 hrs. Note: Layed down 5" dp f/ the derrick while freeze protecting and cleaning pits. Left 34 stands of 5" in the derrick w/ 2 stands of HWDP f/ next well. ~ Page 3/3 Report Printed: 11/9/20071 M • ~~~ ~- .~ ,.. m CO1~T5ERQ~ ATIOI~T C ~ SIpS~IT Robert D. Christensen Production Engineer Technician Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-176L1 Sundry Number: 307-356 Dear Mr. Christensen: SARAH PAl.IN, GOVERNOR 333 W. 7th 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. DATED thiS~ day of November, 2007 Encl. Sincerely, ~° l STATE OF ALASKA RELIVED ALAc:GA O!LAND GAS CONSERVATION COMMISS!ON ~QV ~ ~ ~~~,~ ~~~L~~A~'G~itJ F®R ~~~"~RY APPF~OVAL 2.0 AAC 25280 ~~flSk9 Oil & Gate Cnn: i'.nmmiiedir,~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ WaMl3t{ih~~~ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram 9 pp P 9 ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Producer to Suspended Well ^ Injector 2. Operator Name: 4. Current Weil Class: 5. Permit to Drill Number: CorocoPhillips Alaska, InC. Development ^ Exploratory ^ 2177-100 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. E3ox 10x360, Anchorage, Alas"ca 99510 50-029-23364-60 " 7. If perforating, closest approach in pool(s) ore~ed by this opera,-ion to nearest property line 8. Well Name and Number: where ownership or landownership chang es: Spacing Exception Required? Y0S ^ NO ^~ 1J-176L1 9. Property Designation: ; 10. KB Elevation (ft): 11. Field/Pool(s}: - ALK 25661, 25662, 25663, 385172 RKB 121' ' Kuparuk River Field / West Sak Oil Pool 'i2. P`:~:=S.vi~lTta':lELL CO:EDITION SU~.1'7ARY Total depth f~1D (it): Total Depth 7VD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17820' 3141' 17783' 3142' CLsing Length Size ~.~'D TVD Burst Collapse CO~'^DCTOR 120' 20" 120' 120' SURFACE 3671' 13-3/8" 3792' 2299' 1d ~'ERMEDIATE 1959' 10-3/4" ~ 2080' 1794' INTERMEDIATE 8920' 9-5/8" 11000' 3251' D-SAND WINDOW 1' 7-5/8" 10239' 3162' .D-SAND SLOTTED LINER 7182 4,_1/2" 17783' .3142' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10661' - 17738' 3144' - 3202'. 4-1 /2" L-80 10219' Packers and SSSV Type: Packers and SSSV MD (ft) PKR = Baker Torquemaster 813-47, MLZXP Liner Top Pkr PKR = 10210', 10458' SSSV= NIP SSSV= 504' '13. Attachments:. Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Wetl Status after proposed work: Commencing Operations: ~ Dec. 10, 2007 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:. Bob Christensen /Bob Buchholz Printed Name RO rt D. Chrl tenSetl Title: Production Engineering Technician Signature %- Phone 659-7535 Date J ~ ~~ ~ Commission Use Only SundryN_umb r: Conditions of approval: Notify Commission so thata representative may witness - ~~~ -~~/v\ Plug Integrity ^ BOP Test ^ Mechanics{ Integrity Te st ~ Location Clearance ^ Other: v ~ ~'~ I:IE (` ~ 2flflfi Subsequent Form Required:: L„~ APPROVED BY Approved by: MMISSIONER THE COMMISSION Date: ~ ~ ~U Form 10-403 Revised 06/2006 v ` -\ / Submit in Duplicate -.. YJ G.~'1J.\lif-IE~+v aJV~.i~.li''i1 `s Yr G1'' I'.-~~ vJ~iL ConocoPhillips Alaska Inc. requests approval to begin. Water Injection service in West Sak Dual-lateral Welt 1J-176L1. This wail i~as been pre-prcducea for apcroximaiLiy 30 days in order to recover Oil based drilling fluids prior to ;~uuing'ihe w;:+~ cn in::c:i~n. 1,~-176L1 u.iii provide pressure su;~uort for the West Saic D sands. The 13-3/8" Surface casing (3792" and / 2299' tvd) was cemented with 800 sx Class G followed by 210 sx Class G. The 9-5/U" intermc~;iGte casing (110G+J' ma / 3251' tvd) vvas cemented with 921 sx DeeNC-~r=Tc. The injection tubing/casing annulus is isolated via the following: Upper D sand Baker Torquemaster 813-47 packer located @ 10210' and / 3159' tvd, Up;~ r E sang f1(;_Z~~P 7°' x 9- 5/8" Liner Top ?acl:er located @ 10`~~3' and / 31 v9' tvd. The top of West Sak D sand was found at 102:;;i' and / 3162' tvd. D sand Lateral window top is located @ 10238' and / 3162' tvd. The tc;~ of V~Vest Sal< 3 send vras fcund a~ 1 C9~<` and / 32~~T tva. '~ _ ~ s a d t `~ ' ~~ ~. - I rA1~'a __ ~, p 8 ~ 4 r3 p i j .• ConocoPhillips A • • KRU laska, Inc. 1J-176L1 API: 500292336460 Well T e: SVC SSSV Type: NIPPLE Orig Com letion: 10/4/2007 Annular Fluid: Last WlO: Reference Lo : 43.32' RKB Ref L Date: Last Tag_ TD: 17820 ftKB ~ _ Last Ta Date: _ Max Hole An le: 95 d 12496 Casin Strin -ALL STRINGS I I I Description Slze Top Bottom T _ _ CONDUCTOR 20.000 0 120 1, SURFACE 13.375 0 3792 2~ INTERMEDIATE 10.750 0 2080 17 INTERMEDIATE 9.625 2080 11000 31 LOCATOR ;10191-rotas _ D-SAND WINDOW 9.000 10238 10239 31 , oo:s.zao) D-SAND SLOTTED LINER 4.500- _ __ 10601 17783 31 PaR Tubin Strin -TUBING ;tot95-to213 Size To ___ _ __ Bottom_ TVD Wt , 00:6.270) 4.500 _ 0 10219 3160 12.60 Perforations Summa Interval TVD Zone Status Ft SPF Date HANGER _ _ = __ =_~ 10661 - 11118 3198 - 3199 WS D 457 32 9/28/200; ;10237-10238, 11367 - 11868 3200 - 3202 WS D 501 32 9/28/200; 00:8.500) 12126 - 12642 3198 - 3176 WS D 516 32 9/28/200; 12899 - 13370 3171 - 3173 WS D 471 32 9/28/200; 13629 - 14139 3173 - 3169 WS D 510 32 9/28/200; 14398 - 14867 3169 - 3168 WS D 469 32 9/28/200; 15123 - 15643 3169 - 3167 WS D 520 32 9/28/200; 15891 - 16362 3166 - 3163 WS D 471 32 9/28/200; 16621 - 17136 3162 - 3149 WS D 515 32 9/28/200; C 17't51 - 177RR 't144 -'t14~ WC r) 'iR7 'i~ 9/~R/~()t); SI MU I VU Man MTr Man Iyp@ V MTr V Iype 1 2318 1902 - CAMCO KBMG - DMY Other Qlu s equip.Letc.Z=COMPLETION J ~ De ih TVD Type D 36 _ 36 _ HANGER _ VETC O GRAY TUBING HANGEF SLEEVE ;1oso1-1os1o 504 504 __ NIP _ CAMCO DB'6 NIPPLE w/3.875 N( , 00:6.260) ~ , ~ 10112 3146 SLEEVE-O BAKER CMD SLIDING SLEEVE v r I 10191 3156 LOCATOR BAKER LOCATOR/SEAL ASSY - 10195 3157 PBR BAKER PBR 10210 3159 PACKER D-SAND BAKER TOROUEMAST 10213 3159 ANCHOR BAKER ANCHOR SEAL ASSY CI Perf ;13629-14139) 1 ISSOVER BUSHING 7" TO 5.5" ICO'DB' NIPPLE ER SEAL ASSY MULE SHOE ER'HR' LINER SETTING SLEE )K HANGER CROSSOVER 5.5" :R CROSSOVER SUB 7" TO 5.: - 1J-176 (B-SAND). 1J-176L1 ([ 1J-176L1 Angle @ TS: deg @ Angle @ TD: 90 deg @ 17820 slotted/solid pipe 2.5" x .125" in 4 circumferential rows/ft, 3" centers staggered 18 deg, 3' Date Perf ;15123-15643) ~ • ~©~, -off I~'C:~ANICAL INTEGRITY . ~~ORT ' ~ ~ ~ v~O~ LUD u=_:~ : ~~.1'1' ~`1 4PER ~ FIELD C.1~ps~ ~L+.i flQcJ~~~ w-'~~ '.G r..~~~..~. ~~`5-O'~ hLLL NUMBER i S-~'~~o "t.,~ n ~ LL DAT_ ~_ TD : ?~.. TVD ; ?BTD : ?m TVD Casing . ~ ~lg Shoe . ~ ~OOI~ tID 3a~~TVD ; i~~l . !J ~ ?~ 1~ I~ -?'4"?i --=:,e.. Shoe. '~ T`,TD ; =Cr . '-t.D ",iD =~ S 1 ~°~ =ole Si:.e `~~ ~~ and "''~:.'r'..ts?~ =C~~, iNTEGRTTY - ??.RT # TV-D; sec ~~ r Perf~ ~~ wt tom 10aS'~ =nau 14 s Press Test : _? 15 nin .; 0 min Cor~ents '~' CHP ~t I C~~ 1NTE GRT'?'~ - PART # Z ~--~ 3'~ \ ~~~ S Cement Voles :: Amt. Liner CsQ ~1,a` 3Y. DV ~~ e 3oZo ~~ Cu.t -rot to cover Hers C1~ ~1~~.s~aa~ls~c) ~ CoUcr.~l~ W~~~Ov~ p~ 5 SOQ' . ~. ~O~oI~S S~s~~~ _ eoret~cal TCC ~'~~ ~~.~.~-~Z~Ot~ ~ "coo~~ s~c,~~-~ ~ ~-' 501 ~ Cement Bond Lag (Yes or No)~_; In AOGCC File~_ p ~ ' C3L ~vplua.o~~ b ~~ ,• LO t ~~ ~ ne above per_s ~ ~_ 'yQ ~~(~ - ~`j~Q;v r----, Production Log: Tgpe EvalL:at~on COI~GLJS?Oi15 ?art rl: - ~cr~ rL:~ ~~~ 24-Oct-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-176 L1 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 10,231.12' MD Window /Kickoff Survey 10,238.00' MD (if applicable) Projected Survey: 17,820.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 . Date';Z,~~~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~~ Lo ~ • 0 0 ~ a ~ SARAH PALIN, GOVERNOR ~SS~ OIII ~D t7r~7 333 W. 7th AVENUE, SUITE 100 C011TSERQA'1'IO1Q C011~II5SIOIQ / ANCHORAGE, ALASKA 99501-3539 f PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-176L1 ConocoPhillips Alaska, Inc. Permit No: 207-100 Surface Location: 1686' FSL, 2461' FEL, SEC. 35, Tl 1N, R10E, UM Bottomhole Location: 1209' FNL, 1887' FWL, SEC. 15, T10N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 1J-176, Permit No 207-099, API 50-029-23364-00. Injection should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Si cerel an T. Seamount Commissioner DATED this ~ day of July, 200? cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~h~~g ,EEIVED ~l~i_. ~ 3 2~~~ PERMIT TO DRILL 20 AAC 25.005 ='~,~;Ea'J!I ~ ~~~ lions. COfT1fTlISStOR n,,,.l,~,r~no ta. Type of Work: Drill ^~ Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service 0 Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ 8lanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-176L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17730', TVD: 3133' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1686' FSL, 2461' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ~ac~~'~ ADL 25661, 25662, 25663, 2a6~~2' ~ ,p'1i ~~ ~ West Sak Oil Pool Top of Productive Horizon: 893' FSL, 1835' FWL, Sec. 3, T10N, R10E, UM ~ 8. Land Use Permit: ALK 471, 2177, 472, 2181 13. Approximate Spud Date:. 8/5/2007 Total Depth: 1209' FNL, 1887' FWL, Sec. 15, T10N, R10E, UM ! 9. Acres in Property: 2560 14. Distance to Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558751 y- 5945498 - Zone- 4 10. KB Elevation (Height above GL): 121' AMSL feet 15. Distance to Nearest Well within Pool: 1J-162L2 , 514' 16. Deviated wells: Kickoff depth: 10347' eft. Maximum Hole Angle: 91.5° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1401 psig Surface: 1041 psig 18. Casing Program S if ti s Setting Depth Quantity of Cement Size pec ica on Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20"x 34" 94# K-55 Welded 80' 40' 40' 121' 121' 326 sx AS 1 16" 13-3/8" 68# L-80 BTC 3800' 40' 40' 3800' 2298' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 10.75" 73.2# L-80 BTCM 2000' 40' 40' 2000' 1689' 870 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 8910' 2000' 1689' 10910' 3250' see above 8.5" 4.5" 11.6# L-80 BTC 7383' 10347' 3185' 17730' 3133' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ff): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee BOP Sketch ^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dennis Hartwig @ 265-6862 Printed Name Randy Thomas Title Drilling Team Leader Signature 1 `'-~~ Phone ~ ~'- 6~ 3~ Date 6 ( 2-d to J a '^'~~ aron All D k Commission Use Only Permit to Drill Number: z~?~~~~ API Number: ~/ !! // 50-OZ~~ ~..1~T~~U 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, methane, gas hydrates, or gas contained in shales: sa(x,O p`~1~~ ~},~. Samples req'd: Yes ^ No LJ Mud log req'd: Yes ^ No d Other. ~V H2S asures: Yes ^ No [v_r Directional svy req'd: Yes Q' No ^ V ~-~'~•~,.c,.~r~ oQ~.rv~C~pr~s 1 r*,. c~c c.o r~c `"~ ! A~ t O a. • APPROVED BY THE COMMISSION / ~ DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 9 l Submit in Duplicate Y ~' 7~Q'~ L ~s i!/' J~~ r ~plication for Permit to Drill, Well 1J-176 L1 Revision No.O Saved: 8-Jun-07 Permit It -West Sak Well #1J-176 L1 •~„d ~., :, Application for Permit to Drill Document ~,;~ I~I~'U~el nn,~ x i m i x¢ wail ~a~us Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(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)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 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 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 4 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 4 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 1J-176 L1 PERMIT IT Page 1 of 6 Printed: 8-Jun-07 ORIGINgL • Application ~rmit to Drill, Well 1J-176 L1 Revision No.0 Saved: 8-Jun-07 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as iJ-176 L1. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates o.r the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1,686' FSL, 2,461' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121.0' AMSL Northings: 5,945,498 Eastings: 558,751 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 893' FSL, 1,835' FWL, Section 3, T1ON, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 10, 347 Northings: 5,939,379 Eastings: 552,541 Total Vertical De th, RKB: 3 185 Total Vertical De th, SS: 3,064 Location at Total De th 1,209' FNL, 1,887' FWL Section 15, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 17,730 Northings: 5,931,391 Eastings: 552,659 Total Vertical De th RKB: 3,133 Total Vertical De th, SS: 3,012 and (D) other information required by 20 AAC 25.050(6); 1J-176 L1 PERMIT IT Page 2 of 6 '~ .~"`~ ~~ r'~ ~ Printed: 8tilun-07 Q C ~ ~ ) implication for Permit to Drill, Well 1 J-176 L1 Revision No.O Saved: 8-Jun-07 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form i 0-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1J-160L1 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-176 L1. Please see information on Doyon 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.44 psi/ft, or 8.4 ppg EMW ~' (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "D" sand formation is 1,041 psi, calculated thusly: MPSP = (3,185 ft TVD)(0.44 - 0.11 psi/ft) = 1,041 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: iJ-176 Li Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); The parent wellbore, iJ-176, will be completed with a 10-3/4" x 9-5/8" tapered intermediate casing landed in 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 ConocoPhillips Alaska placed on file with the Commission. No formation integrity test will be performed in the drilling of the 1J-176 Li. 1J-176 L1 PERMIT IT Page 3 of 6 R ~ Printed:8-Jun-07 t \ ~ ~ t . Application f~rmit to Drill, Well 1J-176 L1 Revision No.0 Saved: 8-Jun-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary 4-1/2 81/2" D Sand 11.6 L-80 BTC 17,730 10,347 / 17,730 / 3,133 Slotted- no cement slotted Lateral (1J-176 Ll) 3,185 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 2C AAC 25.035(h)(2); No diverter system will be utilized during operations on 1J-176 L1. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling Fluid program, including a diagram and description of the drilling Fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) ` Value Densit ) 8.4 - 8.5 Plastic Viscostiy (Ib/100 sf) 15 - 25 Yield Point (cP) 18 - 28 HTHP Fluid loss (ml/30 min 200 si 8 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 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 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an explorator}~ or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 1J-176 L1 PERMIT /T Page 4 of 6 Printed: 8-Jun-07 ~~ • ~plication for Permit to Drill, Well 1 J-176 L1 Revision No.O Saved: 8-Jun-07 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle with the commission and identified in the application: (i2) 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) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the iJ-176 Application for Permit to Drill. 1. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 10,347' MD / 3,185' TVD, the top of the D sand. 2. Mill 8-1/2" window. POOH. 3. Pick up 8-1/2"drilling assembly with LWD and MWD and PWD. RIH 4. Drill to TD of sand lateral at +/- 17,730' MD / 3,TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. RIH and set Seal Bore diverter 8. PU and run 4-1/2" slotted liner with Baker Oil Tools RAM Hangar system. 9. RIH, rotate self orienting liner hanger into window and land hanger. 10. Release hanger running tool. POOH. 11. 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. 12. POOH, laying down drill pipe as required.. 13. PU injection completion and RIH to depth. Land tubing. Set BPV. 14. Nipple down BOPE, nipple up tree and test. Pull BPV. 15. Freeze protect well with diesel. 1J-176 L1 PERMIT IT Page 5 of 6 Printed: 8-Jun-07 C~~!G(NAL Application ~rmit to Drill, Well 1 J-176 L1 Revision No.O Saved:8-Jun-07 16. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; 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 1J 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 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-176 L1 PERMIT IT Page 6 of 6 Printed: 8-Jun-07 • ConocoPhillips ~~~ Plan: 1 J-176 L1 (wp05) Sperry Drilling Services Proposal Report -Geographic 04 June, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-176 (Q2 Phase 2) 1J-176 L1 Local Coordinate Origin Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1 J-176 (02 Phase 2) Doyon 15 @ 121.OOft (D15 (40+81)) N True API - US Survey Feet ALI_~BUT Sperry ~rllling ~®rvices ~!~." ~ ~ f ~~ i ~w. b t wa'r F k t C l ~. Project: Kuparuk River Unit WELL DETAILS: Plan IJ-176 (Q2 Phase 2) NAD 1927 (NADCON CONUS) Alaska Zone 04 HALLIBUR!" Site: Kuparuk 1J Pad Well: Plan 1J-176 (02 Phase ) Ground Level: sl.oo Sperry Drilling Servic®s Wellbore: 1J-176 L1 +N/-S +F/-W Northing Fasting Latittude Longitude Slot Plan: 1J-176 L1 (wp05) 0.00 0.00 5945498.05 558750.89 70°15'42.1 I4N 149°31'30.239W ANNOTATIONS FORMATION TOP DETAILS ND MD Annotation No. TVDPath TVDSS MDPath Formation 3185.20 10347.37 L1 TOW @ 10347' MD, 3185' ND: 893' FSL, 1835' FWL-Seca-T10N-R1 1 1537.22 1416.22 1729.59 Pfrost 3133.00 17730.04 L1 TOE @ 17730' MD, 3133' TVD: 1209' FNL, 1887' FWL-Sect-T10N-R1 E 2 1640.92 1519.92 1905.30 T3 3 1935.14 1814.14 2686.23 K15 4 2143.69 2022.69 3326.80 Casing Pt 5 2696.91 2575.91 6587.90 Ugnu C 6 2856.85 2735.85 779G.14 Ugnu B 7 2944.79 2823.79 8460.48 Ugnu A 8 3078.45 2957.45 9492.14 K 13 9 3185.20 3064.2 10346.77 W Sak D CASING DETAILS No MD TVD TVDss Name Size 1 3326.80 2143.69 2022.69 13 3/8" 13-3/ 2 10347.37 3185.20 3064.20 5/8" TOW 9 3 17730.04 3133.00 3012.00 5 1 /2" 5 ~~~i 1500 ' ~ L1 TOW @ 10347' MD, 3185' ND: 893' FSL, 1835' FWL-Seca-T10N-R10E 2000 c --------------------- 0 2500 o °t L --_-_o--_ _p-f -------- - - - - - - - ------ - ------- --_ _ _ _ _ _-_-_ _ _---_- ~--------_-- p- o _ _ o_~ _ _ - _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - 03000 __---o=~ ® -------------------------------------------------------------------- -/~------------ ~,- - v c~ ------ I ° -- O -o o --- --- --- O - °--o --- o --- o°--- o -~--- ~--- - N ~ O O O ° O M O M O O O O O O O O q ~\ L ~ 3500 i ~ ~ 5 1 /2" ~ 9 5/8" TOW °' ~ o 4000 v 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 ' Vertical Section at 180.00° (1000 ft/in) ~, ConocoPhillips Alaska • COI'tOCO~'ti~flp5 Alaska Halliburton Company h' • HQLLIBURTON Compass Proposal Report - Geograp Ic gp®rry Drilling S®rvices Database: .Sperry EDM .11 ~ ~ Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Wellbore: Plan 1J-176 (Q2 Phase 2) 1J-176 L1 Survey Calculation Method: Minimum Curvature Design: 1J-176 L1 (wp05) Project Kuparuk River Unlt. North Slope Alaska, U nited Slates 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 1J-176 1C~`L Phase 2) Well Position +N/-S 0.00 ft Northing: 5,945,498.05ft Latitude: 70° 15' 42.114" N +E/-W 0.00 ft Easting: 558,750.89 ft Longitude: 149° 31' 30.239" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-176 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2006 6/4/2007 23.49 80.82 5: ,622 Design 1J-176 L1 ivdp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 10,347.37 Vertical Section: Depth Frorn (ND} +N/-S +E/-W Direction Iftl {ft) (ft) (°) 40.00 0.00 0.00 180.00 6/4/2007 5:45:46PM Page 2 of 8 COMPASS 2003.11 Build 48 ..~ Halliburton Company HALiLI$URTO COIIOCO~'11~~IpS Compass Proposal Report -Geographic Aia~ Sperry Drilling S®rvic®s ~ Database: .Sperry EDM .11 Local Co-ordinate Reference: __ Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: 'True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-176 L1 Design: 1J-176 L1 (wp05) Plan Summary Measured Dogleg Build Turn Depth Inclination Azimuth TVD TVDSS +N!-S +E/-W Rate Rate Rate TFO (ft) (~) (~) (ft) (ftl (ft) (ft) (°/100ft) (°1100ft) (°/100ft) (°) 10,347.37 £52.88 179.38 3,185.20 3,064.20 -6,070.96 -6,257.46 0.00 0.00 0.00 0.00 10,363.87 85.13 179.38 3,186.92 3,065.92 -6,087.36 -6,257.28 13.60 13.60 0.00 0.00 10,393.87 85.13 179.38 3,189.47 3,068.47 -6,117.25 -6,256.96 0.00 0.00 0.00 0.00 10,552.83 91.40 180.42 3,194.29 3,073.29 -6,276.05 -6,256.68 4.00 3.95 0.65 9.40 10,771.23 91.40 180.42 3,188.96 3,067.96 -6,494.38 -6,258.27 0.00 0.00 0.00 0.00 10,806.10 91.54 179.38 3,188.06 3,067.06 -6,529.24 -6,258.20 3.00 0.40 -2.97 -82.25 11,106.10 91.54 179.38 3,180.00 3,059.00 -6,829.12 -6,254.96 0.00 0.00 0.00 0.00 11,208.99 90.02 179.12 3,178.60 3,057.60 -6,931.99 -6,253.61 1.50 -1.48 -0.26 -170.16 11,805.36 90.02 179.12 3,178.40 3,057.40 -7,528.29 -6,244.41 0.00 0.00 0.00 0.00 11,894.82 90.75 179.63 3,177.80 3,056.80 -7,617.73 -6,243.44 1.00 0.81 0.58 35.41 12,905.67 90.75 179.63 3,164.60 3,043.60 -8,628.48 -6,236.99 0.00 0.00 0.00 0.00 13,016.62 89.64 179.62 3,164.23 3,043.23 -8,739.43 -6,236.27 1.00 -1.00 -0.01 -179.16 13,805.87 89.64 179.62 3,169.20 3,048.20 -9,528.64 -6,231.02 0.00 0.00 0.00 0.00 13,893.41 90.51 179.61 3,169.08 3,048.08 -9,616.18 -6,230.43 1.00 1.00 -0.01 -0.60 15,106.18 90.51 179.61 3,158.20 3,037.20 -10,828.88 -6,222.16 0.00 0.00 0.00 0.00 15,160.67 91.06 179.59 3,157.45 3,036.45 -10,883.36 -6,221.78 1.00 1.00 -0.04 -2.42 16,305.64 91.06 179.59 3,136.30 3,015.30 -12,028.10 -6,213.51 0.00 0.00 0.00 0.00 16,404.35 90.10 179.35 3,135.30 3,014.30 -12,126.80 -6,212.60 1.00 -0.97 -0.24 -166.30 17,730.04 90.10 179.35 3,133.00 3,012.00 -13,452.40 -6,197.62 0.00 0.00 0.00 0.00 6/4/2007 5:45:46PM - Page 3 of 8 COMPASS 2003.11 Build 48 ~~ / Halliburton Company HALLfBURTON C011000~'t1~~1~35 Compass Proposal Report -Geographic ,q~~ Bperry Drilling 8®rvic®s Database: Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillipS Alaska, Inc. < ND Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: F:uparuk River Unit MD Reference: Dayon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: A1inimum Curvature Wellbore; 1J-176 L1 Design: 1 J-176 Lt (vvp05) Planned Survey 1J-176 L_ 1 ;v,~p05) Map Map MD Inc! Azimuth ND (ft) TVDSS +N/-S +E/_yy Northing Easting DLSEV Vert Section Iftj (°) (') (ft) lft) (ft) (ft) lft) (°/100ft) (ftj 10,347.37 82.88 179.38 3,185.20 3064.20 -6,070.96 -6,257.46 5,939,379.05 552,541.59 0.00 6,070.96 yL1 TOW @ 10347' MD , 3185' TVD: 893' FSL, 1835' FWL-Seca-T10N-R10 E - W Sak D - 9 5!8" TOW 10,363.87 85.13 179.38 3,186.92 3065.92 -6,087.36 -6,257.28 5,939,362.64 552,541.89 13.60 6,087.36 10,378.90 85.13 179.38 3,188.20 3067.20 -6;102.34 -6,257.12 5,939,347.67 552,542.17 0.00 6,102.34 1J-176 1!4 Mile Heel 10,393.87 85.13 179.38 3,189.47 3068.47 -6,117.25 -6,256.96 5,939,332.76 552,542.45 0.00 6,117.25 10,400.00 85.37 179.42 3,189.98 3068.98 -6,123.36 -6,256.89 5,939,326.65 552,542.56 3.97 6,123.36 10,500.00 89.31 180.07 3,194.62 3073.62 -6,223.23 -6,256.45 5,939,226.80 552,543.78 4.00 6,223.23 10,552.83 91.40 180.42 3,194.29 3073.29 -6,276.05 -6,256.68 5,939,173.98 552,543.97 4.00 6,276.05 10,600.00 91.40 180.42 3,193.14 3072.14 -6,323.21 -6,257.02 5,939,126.82 552,543.99 0.00 6,323.21 10,700.00 91.40 180.42 3,190.70 3069.70 -6,423.18 -6,257.75 5,939,026.86 552,544.04 0.00 6,423.18 10,771.23 91.40 180.42 3,188.96 3067.96 -6,494.38 -6,258.27 5,938,955.67 552,544.08 0.00 6,494.38 10,800.00 91.52 179.56 3,188.23 3067.23 -6,523.15 -6,258.26 5,938,926.90 552,544.31 3.00 6,523.15 10,806.10 91.54. 179.38 3,188.06 3067.06 -6,529.24 -6,258.20 5,938,920.81 552,544.42 3.00 6,529.24 10,900.00 91.54 179.38 3,185.54 3064.54 -6,623.11 -6,257.19 5,938,826.97 552,546.16 0.00 6,623.11 11,000.00 91.54 179.38 3,182.85 3061.85 -6,723.06 -6,256.11 5,938,727.03 552,548.03 0.00 6,723.06 11,100.00 91.54 179.38 3,180.16 3059.16 -6,823.02 -6,255.02 5,938,627.09 .552,549.89 0.00 6,823.02 11,106.10 91.54 179.38 3,180.00 3059.00 -6,829.12 -6,254.96 5,938,621.00 552,550.00 0.00 6,829.12 1J-176 MB_D_CP1 (05108/07) 11,200.00 90.15 179.14 3,178.61 3057.61 -6,923.00 -6,253.75 5,938,527.14 552,551.95 1.50 6,923.00 11,208.99 90.02 179.12 3,178.60. 3057.60 -6,931.99 -6,253.61 5,938,518.15. 552,552.15 1.50. 6,931.99 11,300.00 90.02 179.12 3,178.57 3057.57 -7,022.99 -6,252.20 5,938,427.18 552,554.27 0.00 7,022.99 11,400.00 90.02 179.12 3,178.54 3057.54 -7,122.97 -6,250.66 5,938,327.21 552,556.59 0.00 7,122.97 11,500.00 90.02 179.12 3,178.50 3057.50 -7,222.96 -6,249.12 5,938,227.25 552,558.91 0.00 7,222.96 11,600.00 90.02 179.12 3,178.47 3057.47 -7,322.95 -6,247.58 5,938,127.29 552,561.23 0.00 7,322.95 11,700.00 90.02 179.12 3,178.44 3057.44 -7,422.94 -6,246.04 5,938,027.32 552,563.55 0.00 7,422.94 11,800.00 90.02 179.12 3,178.40 3057.40 -7,522.93 -6,244.49 5,937,927.36 552,565.88 0.00 7,522.93 11,805.36 90.02 179.12 3,178.40 3057.40 -7,528.29 -6,244.41 5,937,922.00 552,566.00 0.00 7,528.29 1J-176 MB_D_CP2 (05!08/07) 11,894.82 90.75 179.63 3,177.80 3056.80 -7,617.73 -6,243.44 5,937,832.57 552,567.67 1.00 7,617.73 11,900.00 90.75 179.63 3,177.73 3056.73 -7,622.92 -6,243.40 5,937,827.39 552,567.75 0.00 7,622.92 12,000.00 90.75 179.63 3,176.43 3055.43 -7,722.91 -6,242.77 5,937,727.42 552,569.16 0.00 7,722.91 12,100.00 90.75 179.63 3,175.12 3054.12 -7,822.90 -6,242.13 5,937,627.45 552,570.58 0.00 7,822.90 12,200.00 90.75 179.63 3,173.82 3052.82 -7,922.89 -6,241.49 5,937,527.47 552,572.00 0.00 7,922.89 12,300.00 90.75 179.63 3,172.51 3051.51 -8,022.88 -6,240.85 5,937,427.50 552,573.42 0.00 8,022.88 12,400.00 90.75 179.63 3,171.20 3050.20 -8,122.86 -6,240.22 5,937,327.53 552,574.83 0.00 8,122.86 12,500.00 90.75 179.63 3,169.90 3048.90 -8,222.85 -6,239.58 5,937,227.56 552,576.25 0.00 8,222.85 12,600.00 90.75 179.63 3,168.59 3047.59 -8,322.84 -6,238.94 5,937,127.59 552,577.67 0.00 8,322.84 12,700.00 90.75 179.63 3,167.29 3046.29 -8,422.83 -6,238.30 5,937,027.61 552,579.08 0.00 8,422.83 12,800.00 90.75 179.63 3,165.98 3044.98 -8,522.82 -6,237.67 5,936,927.64 552,580.50 0.00 8,522.82 12,900.00 90.75 179.63 3,164.67 3043.67 -8,622.81 -6,237.03 5,936,827.67 552,581.92 0.00 8,622.81 12,905.67 90.75 179.63 3,164.60 3043.60 -8,628.48 -6,236.99 5,936,822.00 552,582.00 0.00 8,628.48 1J-176 MB_D_CP3 (0 5/08/07) 13,000.00 89.81 179.62 3,164.14 3043.14 -8,722.81 -6,236.38 5,936,727.69 552,583.35 1.00 8,722.81 13,016.62 89.64 179.62 3,164.23 3043.23 -8,739.43 -6,236.27 5,936,711.07 552,583.59 1.00 8,739.43 13,100.00 89.64 179.62 3,164.75 3043.75 -8,822.80 -6,235.72 5,936,627.72 552,584.79 0.00 8,822.80 6/4/2007 5:45:46PM Page 4 of 8 COMPASS 2003.11 Build 48 ~~~~~ ,~~~~. ~-'' Halliburton Company H LIBURON C©t~C0~1~~~~~35 Compass Proposal Report -Geographic Sperry Drilling Servic®s Database: Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: I<uparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: I<uparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-176 L1 Design: 1J-176 L1 (wp05) Planned Survey 1J-176 L1 (wp05) Map Map MD Incl Azimuth ND {ft) TVDSS +N(-S +E/_yy Northiny Easting DLSEV Vert Section (ft) (~) (~) (ft) (ft) (ft) (ftl Ift) (`/100ft) (ft) 13,200.00 89.64 179.62 3,165.38 3044.38 -8,922.80 -6,235.05 5,936,527.74 552,586.24 0.00 8,922.80 13,300.00 89.64 179.62 3,166.01 3045.01 -9,022.79 -6,234.38 5,936,427.76 552,587.69 0.00 9,022.79 13,400.00 89.64 179.62 3,166.64 3045.64 -9,122.79 -6,233.72 5,936,327.78 552,589.13 0.00 9,122.79 13,500.00 89.64 179.62 3,167.27 3046.27 -9,222.79 -6,233.05 5,936,227.80 552,590.58 0.00 9,222.79 13,600.00 89.64 179.62 3,167.90 3046.90 -9,322.78 -6,232.39 5,936,127.83 552,592.02 0.00 9,322.78 13,700.00 89.64 179.62 3,168.53 3047.53 -9,422.78 -6,231.72 5,936,027.85 552,593.47 0.00 9,422.78 13,800.00 89.64 179.62 3,169.16 3048.16 -9,522.77 -6,231.05 5,935,927.87 552,594.92 0.00 9,522.77 13,805.87 89.64 179.62 3,169.20 3048.20 -9,528.64 -6,231.02 5,935,922.00 552,595.00 0.00 9,528.64 7J-776 MB_D_CP4 (0 5/08/07) 13,893.41 90.51 179.61 3,169.08 3048.08 -9,616.18 -6,230.43 5,935,834.48 552,596.27 1.00 9,616.18 13,900.00 90.51 179.61 3,169.02 3048.02 -9,622.77 -6,230.38 5,935,827.89 552,596.37 0.00 9,622.77 14,000.00 90.51 179.61 3,168.13 3047.13 -9,722.76 -6,229.70 5,935,727.92 552,597.83 0.00 9,722.76 14,100.00 90.51 179.61 3,167.23 3046.23 -9,822.76 -6,229.02 5,935,627.94 552,599.29 0.00 9,822.76 14,200.00 90.51 179.61 3,166.33 3045.33 -9,922.75 -6,228.34 5,935,527.96 552,600.75 0.00 9,922.75 14,300.00 90.51 179.61 3,165.43 3044.43 -10,022.74 -6,227.65 5,935,427.99 552,602.22 0.00 10,022.74 14,400.00 90.51 179.61 3,164.54 3043.54 -10,122.74 -6,226.97 5,935,328.01 552,603.68 0.00 10,122.74 14,500.00 90.51 179.61 3,163.64 3042.64 -10,222.73 -6,226.29 5,935,228.04 552,605.14 0.00 10,222.73 14,600.00 90.51 179.61 3,162.74 3041.74 -10,322.73 -6,225.61 5,935,128.06 552,606.60 0.00 10,322.73 14,700.00 90.51 179.61 3,161.84 3040.84 -10,422.72 -6,224.93 5,935,028.09 552,608.06 0.00 10,422.72 14,800.00 90.51 179.61 3,160.95 3039.95 -10,522.71 -6,224.25 5,934,928.11 552,609.52 0.00 10,522.71 14,900.00 90.51 179.61 3,160.05 3039.05 -10,622.71 -6,223.56 5,934,828.13 552,610.99 0.00 10,622.71 15,000.00 90.51 179.61 3,159.15 3038.15 -10,722.70 -6,222.88 5,934,728.16 552,612.45 0.00 10,722.70 15,100.00 90.51 179.61 3,158.26 3037.26 -10,822.69 -6,222.20 5,934,628.18 552,613.91 0.00 10,822.69 15,106.18 90.51 179.61 3,158.20 3037.20 -10,828.88 -6,222.16 5,934,622.00 552,614.00 0.00 10,828.88 7J-776 ~(B_Q_CP5 (O S/08107) 15,160.67 91.06 179.59 3,157.45 3036.45 -10,883.36 -6,221.78 5,934,567.53 552,614.81 1.00 10,883.36 15,200.00 91.06 179.59 3,156.73 3035.73 -10,922.68 -6,221.49 5,934,528.22 552,615.40 0.00 10,922.68 15,300.00 91.06 179.59 3,154.88 3033.88 -11,022.66 -6,220.77 5,934,428.25 552,616.90 0.00 11,022.66 15,400.00 91.06 179.59 3,153.03 3032.03 -11,122.64 -6,220.05 5,934,328.29 552,618.40 0.00 11,122.64 15,500.00 91.06 179.59 3,151.18 3030.18 -11,222.62 -6,219.33 5,934,228.33 552,619.90 0.00 11,222.62 15,600.00 91.06 179.59 3,149.34 3028.34 -11,322.60 -6,218.61 5,934,128.37 552,621.40 0.00 11,322.60 15,700.00 91.06 179.59 3,147.49 3026.49 -11,422.58 -6,217.88 5,934,028.41 552,622.91 0.00 11,422.58 15,800.00 91.06 179.59 3,145.64 3024.64 -11,522.56 -6,217.16 5,933,928.44 552,624.41 0.00 11,522.56 15,900.00 91.06 179.59 3,143.79 3022.79 -11,622.54 -6,216.44 5,933,828.48 552,625.91 0.00 11,622.54 16,000.00 91.06 179.59 3,141.95 3020.95 -11,722.52 -6,215.72 5,933,728.52 552,627.41 0.00 11,722.52 16,100.00 91.06 179.59 3,140.10 3019.10 -11,822.50 -6,215.00 5,933,628.56 552,628.91 0.00 11,822.50 16,200.00 91.06 179.59 3,138.25 3017.25 -11,922.48 -6,214.28 5,933,528.60 552,630.41 0.00 11,922.48 16,300.00 91.06 179.59 3,136.40 3015.40 -12,022.46 -6,213.55 5,933,428.63 552,631.92 0.00 12,022.46 16,305.64 91.06 179.59 3,136.30 3015.30 -12,028.10 -6,213.51 5,933,423.00 552,632.00 0.00 12,028.10 7J-776 NIB_d_CP& (0 5108/07) 16,400.00 90.14 179.36 3,135.31 3014.31 -12,122.45 -6,212.65 5,933,328.66 552,633.60 1.00 12,122.45 16,404.35 90.10 179.35 3,135.30 3014.30 -12,126.80 -6,212.60 5,933,324.32 552,633.68 1.00 12,126.80 16,500.00 90.10 179.35 3,135.14 3014.14 -12,222.45 -6,211.52 5,933,228.69 552,635.51 0.00 12,222.45 16,600.00 90.10 179.35 3,134.96 3013.96 -12,322.44 -6,210.39 5,933,128.72 552,637.42 0.00 12,322.44 16,700.00 90.10 179.35 3,134.79 3013.79 -12,422.43 -6,209.26 5,933,028.75 552,639.33 0.00 12,422.43 16,800.00 90.10 179.35 3,134.62 3013.62 -12,522.43 -6,208.13 5,932,928.78 552,641.24 0.00 12,522.43 16,900.00 90.10 179.35 3,134.44 3013.44 -12,622.42 -6,207.00 5,932,828.80 552,643.15 0.00 12,622.42 6/4/2007 5:45:46PM Page 5 of 8 COMPASS 2003.11 Build 48 ORIGINAL. Halliburton Company HALLIBURTON COIlOCO~'ll~~lp5 Compass Proposal Report -Geographic Alaska Sperry Drilling Services Database: Sperry EDM .11 Local Co-ordinate Reference: W~°II Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. 1VD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: P:linimum Curvature Wellbore: iJ-176 L1 Design: iJ-176 L1 (wp05) Planned Survey 1J-176 L1 (wp05) _ Map Map MD Incl Azimuth 7VD (ft) TVDSS +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ftj (ft) (ft} (ft) lft) (°1100ft) (ftj 17,000.00 90.10 179.35 3,134.27 3013.27 -12,722.41 -6,205.87 5,932,728.83 552,645.06 0.00 12,722.41 17,100.00 90.10 179.35 3,134.09 3013.09 -12,822.41 -6,204.74 5,932,628.86 552,646.97 0.00 12,822.41 17,200.00 90.10 179.35 3,133.92 3012.92 -12,922.40 -6,203.61 5,932,528.89 552,648.88 0.00 12,922.40 17,300.00 90.10 179.35 3,133.75 3012.75 _ -13,022.39 -6,202.48 _5,932,428.92 552,650.79 0.00 13,022.39_ 17,400.00 90.10 179.35 3,133.57 3012.57 -13,122.39 -6,201.35 5,932,328.94 552,652.70 0.00 13,122.39 17,500.00 90.10 179.35 3,133.40 3012.40 -13,222.38 -6,200.22 5,932,228.97 552,654.61 0.00 13,222.38 17,600.00 90.10 179.35 3,133.23 3012.23 -13,322.37 -6,199.09 5,932,129.00 552,656.52 0.00 13,322.37 17,700.00 90.10 179.35 3,133.05 3012.05 -13,422.37 -6,197.96 5,932,029.03 552,658.43 0.00 13,422.37 17,730.04 90.10 179.35 3,133.00 3012.00 -13,452.40 -6,197.62 5,931,999.00 552,659.00 0.00 13,452.40 L1 TOE @ 17730' MD, 3133' TVD: i , 1209' FNL, 1887' FWL-Sec15-T10N-R10E - 5 1/2" -1J-176 MB D_Toe (05/08/07) 6/4/2007 5:45:46PM Page 6 of 8 COMPASS 2003.11 Build 48 f..r~ ~ ....,, ~ Halliburton Company H !~!_! Tt~N ~OIlOCO~'ll!llp5 Compass Proposal Report -Geographic ,qia~ Sp®rry Drilling 8®rvic®e Database: Sperry EDM .11 Local Co-ordinate Reference: V';'ell Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: f.1inimum Curvature Wellbore: 1J-176 L1 Design: 1J-176 L1 (wp05) Geologic Targets 1 J-176 L 1 TVD TVDSS Target Name +N/-S +E/-W Northing Easting (ft) (ft) - Shaue ft ft (ft) (ft) 3,200.20 1J-176 MB_D_Heel (05/08/07) -6,076.03 -6,254.08 5,939,374.00 552,545.00 - Polygon Point 1 0.00 0.00 5,939,374,00 552,545.00 Point 2 -753.40 -0.87 5,938,621.00 552,550.00 3,158.20 1J-176 MB_D_CP5 (05/08/07) -10,828.88 -6,222.16 5,934,622.00 552,614.00 - Polygon Point 1 0.00 0.00 5,934,622.00 552,614.00 Point 2 -1,199.24 8.65 5,933,423.00 552,632.00 3,164.60 1J-176 MB_D_CP3 (05/08/07) -8,628.48 -6,236.99 5,936,822.00 552,582.00 - Polygon Point 1 0.00 0.00 5,936,822.00 552,582.00 Point 2 -900.21 5.98 5,935,922.00 552,595.00 3,178.40 1J-176 MB_D_CP2 (05108/07) -7,528.29 -6,244.41 5,937,922.00 552,566.00 - Polygon Point 1 0.00 0.00 5,937,922.00 552,566.00 Point 2 -1,100.28 7.42 5,936,822.00 552,582.00 3,169.20 1J-176 MB_D_CP4 (05/08/07) -9,528.64 -6,231.02 5,935,922.00 552,595.00 - Polygon Point 1 0.00 0.00 5,935,922.00 552,595.00 Point 2 -1,300.27 8:86 5,934,622.00 552,614.00 3,180.00 1J-176 MB_D_CP1 (05/08/07) -6,829.12 -6,254.96 5,938,621.00 552,550.00 - Polygon Point 1 0.00 0.00 5,938,621.00 552,550.00 Point 2 -699.45 10.55 5,937,922.00 552,566.00 3,133.00 1J-176 MB_D_Toe (05/08!07) -13,452.40 -6,197.62 5,931,999.00 552,659.00 - Point 3,188.20 1J-176 114 Mile Heel -6,076.03 -6,254.08 5,939,374.00 552,545.00 -Circle (radius 1,320.00) 3,121.00 1J-176 1/4 Mile Toe -13,452.40 -6,197.62 5,931,999.00 552,659.00 -Circle (radius 1,320.00) 3,136.30 1J-176 MB_D_CP6 (05/08107) -12,028.10 -6,213.51 5,933,423.00 552,632.00 - Polygon Point 1 0.00 0.00 5,933,423.00 552,632.00 Point 2 -1,424.50 15.89 5,931,999.00 552,659.00 ~ragnosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (`~) (") 3,806.92 2,300.00 13-3/8 16 10,347.39 3,185:20 9-518 12-1/4 17,730.02 3,133.00 5-112 8-1I2 6/4/2007 5:45:46PM Page 7 of 8 COMPASS 2003.11 Build 48 ~-' Halliburton Company ~OftOCO~'tl~a1~35 Compass Proposal Report -Geographic Ha.~uBUR-roN Sperry Drilling Services Database: '; .Sperry EDM .11 ~ Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: P.linim~,~m Curvature Wellbore: 1J-176 L1 Design: 1J-176 Li (wp05) Prognosed Formation Intersection Points Measured Depth Inclination Azimuth TVD TVDSS +N/-E (ft) +E/-W (ft} (ft) t`} (°} tft) (ft} Name 1,729.59 51.78 225.00 1,537.22 -423.76 -423.76 Pfrost 1,905.30 57.04 226.67 1,640.92 -522.79 -525.15 T3 2,686.23 71.00 230.31 1,935.14 -990.40 -1,073.62 K15 .3,326.80 71.00 230.31 2,143.69 -1,377.18. -1,539.71 Casing Pt 6,588.15 82.39 233.54 2,696.91 -3,308.11 -4,096.76 Ugnu C 7,796.50 82.39 233.54 2,856.85 -4,019.86 -5,060.06 Ugnu B 8,460.90 82.40 232.65 2,944.79 -4,411.38 -5,589.60 Ugnu A 9,492.66 82.71 198.29 3,078.45 -5,232.17 -6,174.39 K 13 10,347.37 82.88 179.38 3,185.20 -6,070.96 -6,257.46 W Sak D Ptan Annotations Measured Vertical Local Coor dinates Depth Depth +N/-S +EI-W Comment (ft) (ft- (ft) lft} 10,347.39 3,185.20 -6,070.97 -6,257.46 L1 TOW @ 10347' MD, 3185' TVD: 893' FSL, 1835' FWL-Seca-T10N-R10E 17,730.03 3,133.00 -13,452.39 -6,197.62 L1 TOE @ 17730' MD, 3133' TVD: 1209' FNL, 1887' FWL-Sect-T10N-R10E 6/4/2007 5:45:46PM Page 8 of 8 COMPASS 2003.11 Build 48 ~~~~a~„ ConocoPhillips Alaska r~ L Plan: 1J-176 L1 (wp05) Sperry Drilling Services Anticollision Summary 31 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-176 (Q2 Phase 2) 1J-176 L1 Local Coordinate Origin: Centered on Well Plan 1J-176 (Q2 Phase 2) Viewing Datum: Doyon 15 @ 121.OOft (D15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet LL T Sperry drilling S®rvicea ORIGINAL SURVEY PROGRAM Date: 2007-0604700:00:00 Validated: Yes Version: Depth FromDepth To Survey/Plan Tool 40.00 1000.00 CB-GYRO-SS 1000.00 3941.00 MWD+IFR-AK-CA<rSC 3941.0010347.37 MWD+IFR-.a6-CA~SC 10347.3717730.04 1J-176 LI (wp05) MWD+IFR-AK-CSC 0 270 180 90 Travelling Cylinder Azimuth (TFO+AZI) (°J vs Centre to Centre Separation ]150 ft/inJ REFERENCEINFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-176 (l'a2 Phase 2), True North Vertical (TVD) Reference: Doyon 15 ~ 121.OOft (D75 (40+81)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Doyon 15 ~ 121.OOft (D15 (40+81)) Calculation Method: Minimum Curvature COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based From Colour To MD ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 10347.37 To 17730.0367687055 Maximum Range:1968.96574133852 Reference: Plan: 1J-176 L1 (wp05) 330 %~ ~ 30. ~ 40 0 250 ~ ~ ~ / '?~~~ ~- ~ 250 500 ~ ~ ~ ~ 3 ~ ~~ 60 300 ~~ ~ ~ ` 500 750 ~ i - it ~ 750 1000 J,~ ~ ~ ~' 2 ~'~ ~\ - 1000 1250 1250 1500 .~ ~ ~ ' ,= X ~~ ~ i I T ~ ~ = ~ ~ ~ ~ ~ ~ ~' 1500 __ 1750 ~ ~ ~ ~ ~1, i l ] ~ , ~ 1 , ~. I l~ ~ ~1 1750 --... --- 2000 l I ~ ~ ~ i 1{ ~ I i 0 9 70 ~ zooo zzso , % ~ , ; , ~ I ~ I ] ~ 1 , ~ ~ ~ ~ 2250 2500 ~ V i ~~ 1/ i j 2500 2750 ~~ 1V ~\. ~~~_ ~j/ - I _' . ~~ 2750 3000 ~ ~' ~' ~; \ \ 3000 3250 \ j<., 20 ~, ~ ~ 3250 3500 - 120 240 3500 3750 \ 30 / ~ '~~ 3750 4000 ~ 4000 5000 40 k '. 5000 6000 6000 7000 210 "` 150 7000 -` 8000 50 8000 9000 180 9000 - ~ 10000 10000 11000 11000 12000 12000 13000 Travelling Cylinder Azimuth (TFO+AL'1) J°J vs Centre to Centre Separation J30 ftlinJ 13000 14000 SECTION DETAILS 14000 15000 s.~ MD 1~ Atl rv0 .ws .E/-w oL.v Tr.~. vs.. r.w.l 00 OOD fi0]0 % 3186 20 80]0 % 825) 48 0 15D00 16DDD . . . . . 103473] 82.86 119.38 2 10]639) 85.13 to 38 31%93 8081.38 825).28 13.fi0 0.00 608736 16DDD 17DDD J 10]93.87 %.13 1]9.38 3189.4] 8111.25 825698 0.00 0.00 611].25 5 10]]123 9140 180.42 318898 4319438 8258 OOD 000 6494.38 17000 18DDD 6 108%.10 9154 1]9]8 3188.06 8529.24 8258.20 3.00 -82.25 852924 1110610 9154 1938 318000 .883912 -65-0% OW 000 6839.13 1J-1 )6 MB_°CPI IOSOB.O.) 8 11208.% %.02 1]9.12 31)8.fi0 8931.% 825].81 1.50 -1]0.18 6931.% 160DD 190DD 11905 J6 %02 1]912 31]840 "`2639 624441 000 0.00 ]536.28 1J-1)6 MB_O_CP2 (05108100 10 11894.83 90.]5 1]963 31 P.80 -)61 T.)3 8243.M 1.00 35.41 )817.]3 1290591 90.]5 1]963 JI64.60 -862848 6336.99 0.00 000 %2848 1J-176 MB_D_CPJ (OYOfl~00 12 1301662 89.60 1)9.82 3/84.2) -0]]9.43 8238.2] 1.00 -1]8.16 8719.13 IJ 1]8058] 89.64 1]962 3169.20 -953864 -6331.02 000 0.00 952864 1J~1 ]8 Me_D_CP4 (OSOeroO 30 43 1 00 -0 80 %16 18 . . . . 14 1389141 90.51 1]9.61 3169.09 -%16.10 82 IS 1510618 90.51 11961 315820 10 2868 -6222.16 000 0.00 1082696 1J~1 )6 Me O CPS (OSOBI00 16 151ED.fi] 91.% 119.59 315745-10863.]6 -6321.16 1.00 -3A2 10883.% 1) 15305.64 9106 1]959 ]1 ]630 12 NIO -621].51 000 000 12026.10 1J-178 MB D_OPB (03/0810]) 181640435 90.10 1]9.35 3135.30-1212680 8212.80 1.00 -166.30 12128.80 19 1 ]130 04 %. f 0 1 ]9.35 31 ]3.00 -I Jd52 d0 619].63 000 0.00 13452 d0 1J-1 )fi MB_0_Tw (OSN6/00 NAD 27 ASP 3ne 4 WELL DETAILS: Plan 1J-176 (Q2 Phase 2) Ground Level: i.00 N{S FJVN Northing Fasting Latittude Longitude Slot 0.00 0.00 SBOS 55B50.8 7015B.11W 1B130.23W Halliburton Compan Anticollision Report Company: ConocoPhillips Alaska lnc. Date: 6/21/2007 Time: 10:55:39 Patie: 1~ Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinate(NE) Reference: Well: Plan 1J-176, True North Reference R'ell: Plan 1J-176 Vertical (TVD) Reference: Doyon 15 (40+81) 12 1.0 Reference ~~'ellpath: Plan 1 J-176 L1 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 1 J-176 L1 (wp05) & NOT PLANNE I Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 10347.37 to 17730.04 ft Scan Method: Trav Cylinder North Maximum Radius: 1969.00 ft Error Surface: Ellipse + Casing Casing Points 11ID TVD Diameter Hole Size Name ft ft in in 3326.80 2143.69 13.375 16.000 13 3/8" 10347.39 3185.26 9.625 12.250 9 5/8" TOW 17730.03 3133.00 5.500 8.500 5 1 /2" Plan: 1J-176 L1 (wp05) Date Composed: 6/6/2007 Version: 2 Principal: Yes Tied-to: From: Definitive Path Summary ---------------- Offset Wellpath ----- ---------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath ViD 111D Distance Area Deviation yi'arning ft ft ft ft ft Kuparuk 1J Pad 1J-160 1J-160L1 V6 Out of range Kuparuk 1J Pad 1J-160 1J-160L2 V2 Out of range Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V2 Plan: 17690.83 18800.00 1694.33 386.06 1308.26 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 V1 Plan 17691.52 18800.00 1694.61 373.10 1321.51 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan 1J-176 V1 Plan: 1 10350.00 10350.00 0.01 0.00 0.01 Pass: No Errors Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 L1 V3 Pla 17679.74 16350.00 1877.64 374.27 1503.38 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 V3 Plan: 17699.95 16375.00 1881.83 395.78 1486.05 Pass: Major Risk Non-Pad KRUST-02 KRUST-02 VO 16124.24 3025.00 620.73 205.22 415.51 Pass: Major Risk 2OGRAR OR161NAL 1J-17 .1 Drilling Hazard Summ (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8-1/2" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low d Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1J-176 L1 Drilling Hazards Summary R ,~, ~ ~ ~ prepared by Mike Greener ~ - ~ ~ 6/4/2007 1:43 PM µ ~~~~a~ 0 V ~ 13-3/S" Casing Shoe, 68#, L-80, BTC set ~ 3,800' MD, 2,300' ND Tubing String 4112" 12.6#, L-80, IBTM 3.958" ID, 3.890" Drift 10.'/." Casing, 73.2#, L-80, BTCM ~ 2,500' MD 3.875" DB Nipple GLM, Camco, 4112" x 1" KBG-2 CMD Sliding Sleeve, wl 3.81" DB Nipple Locating Seal J Assembly 4.75" Seal OD TorqueMaster Packer Lateral EntryJtlsddle~L PBR Seal Assembly wl TorqueMaster Production Anchor 4.75" Seal OD Assembly 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 _- Orienting Profile Automatic Alignment of LEM Positive Latching Collet Indicates Correct Location ~ Seal Bore for Lateral Isolation - J.688" ID ~ Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.688" ID IsoWtion Seal Asembly 4.75" Seal OD 3.875" Seal ID 2' Length ConocoPhillips 1 J-176 9-5/8" Intermediate Dual Lateral Liner Injector wp-04 'D' Sand L D-sand Window at 10,347 MD dvz" nsa, Hydril 3,185 ND' 83deg 521, L-eo slotted user / Every Other Joint Baker S-'/,"ECP Cro~sover-Hydri r• x 9-sla° / I Bores 411] 8"ID 4112" 12.6# Tubing 3.890" Drift 3.958"ID 7" X 9-518" MLZXP Liner Top @ 70,450' MD Liner Top Packer with Integrated RS Profile and Flexlock Slips Casing Sealbore Receptacle 4.75" ID ateral \ 41/2" 11.60, BTC, L-80 Slotted Liner Every Otner Joint 1521 xBTC/ .... Baker Oil Tools As Planned Late Wi h ral Entry Module (LEMI d I l ti Di rt t on ers an so a ve Lateral Access Diverter Lateral Isolation Divener GS Running Tool String Installed Installed p.00" Lateral Dritt) (2.50" ID Mainbore Drat) 'GS' Profile for Coil Connector JRUnninglRetrievingti (1.00' Length) Snap INSnap Out r Back Pressure Valve /POSltive Locating C llet (1.60'Len9th) o t l l l BOn ~' L Flow-Thru SwivN a era so a Seals ~ (1.25' Length) f Lateral Diverter /Hydraulic Ramp Disconnect IsolatioN Malnbore~ (1.50' Length) Diverter Sleeve I ~~ GS Spear ' / Lateral lsdadon ~ 6 (1.50 Length) 85ft Approx. Seals . OAL' I 'Nars"may be regluyred in highly b ^aheld 19' Diverter Length 19' Sleeve Length 1 ]~ ~/ 41l2"Guide Shce 4117' Casing Shoe, 11.6#, -80 BTCM b t l t shoe b tt Set ~ 17,730' MD, 3, ' ND Seal Assembly 4.75" Seal OD 'B' Sand Lateral 1112" 15.50, Hydril 5712" t5.5#, BTC, 521, L~0 Slotted Liner L-80 Slottetl Liner Every Other Joint Every Other Joint 5112" Guide Shce Eauiloment Specifications 7" X 9-518" HOOK Hanger Mainbore Drift: 7.00" Mainbore Drift, with diverter: 6.25" Lateral Dritt, no diverter or LEM: 6.28" Lateral Drift, wl diverter, no LEM: 5.12" LateraOMainbore Diverter OD: 8.50" 4-112" Lateral Entry Module Mainbore Drift: 7.68" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drin, wl coil divener: 3.00" OD of Diverter and Sleeve: +/- 3,60" Diverter and Sleeve Length: +1-19' 5-112" Casing Shce Set ~ 17,733' MD, 3,206' ND 9-518" Casing Shoe, 40.0#, L-80 BTC Crossover- Hydril 521 x BTC 10,910' MD, 3,250' ND BSdeg ®Baker Hughes 20117. This document may not be reproduced or distributed, in wTOk or in pan, n any loan or by ,ny means ekcuonic or m.cnamcat mavmne Pnoc«ePring. recorainB. or br am nrormmion.mraBUm retdevel system now known or herearter invented, wiln«t written permission Irom Baker HuBnes Inc a • • ~'RA~YSI~IZ'~'Af. I.~~!-~'Eid CiILCKLIST WELL LY~:~rE -_~/2G( /~ l-7~ ~.-/ P't'D# ZCS~ I~(~ Devetopmeat Service iYon-Conventions[ Welt Exploratory Stratigraphic Test Circle Appropriate Letter /paragraphs to be Included is Transmittal Letter ' CHECK w'xAT APPLIES HUU-ViVS (OPTIONS) TEXT FOR APPROVAL LETTER MliLTI LATERAL j (IF fast two digits i API number between 60-69) The permit is for a new wellbore segment of existing are~Permit vo. ZD - U ,API No. ~0-~- Z33( should continue to be reported as a function o~ e original API number stated above. PILOT EIOLE SPACING EXCEPTION i ; DRY DCfCH I SA!~IPLE ~ Non-Conventional j ~"ell i ' i ' I i I In accordance with 20 A.4C 2~.005(f), all records, data and logs acquired for the pilot hole must be clearly diiTerentiated in both well name (~0- PH) and API number ___,_) from records, data and logs acquired for well ?'he permit is approved subject to fiill compliance with 20 AAC ; 1 25.055. Approval to perforate and produce 1 inject is contingent upon issuance of a conservation order approving a spacing exception. liability of any protest to the spacing exception that may oc urs the I ~ Alt dry ditch sample sets submitted to the-Eommission must be in ; I no greater than 30' sample intervals from below the permafrost or I from where samples are first caught and IO' sample intervals through target cones. j Please note the following special condition of this permit; ~ production or production testing of coal bed methane is not allowed for (name of we!!) until after Corn anv iV'ame) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _IComnany Name} must contact the Commission to obtain advance approval of such water welt testing ro Rev: [ 25/06 C:' jody~transmittal_checklist • • ^1^ ~ ~ ~ ~ ~ ~ ~ , m a~ o a , , y y ~ ~ ~ ~ ~ ~ a~ ~ , o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~~ ~ ~ ~; `N°' 3 n, c O a. °, m. ai c °' .c ~ vi ~, ~ o ~ ~ Q C p {y ~p~ ~ ~ C• ~ ~ ° w yj, ~ , Q L, t a ~ O ~ T N, ~ ~ ~ ~ ~ O' ~ ~ ~ 4 ~ ~~ ~ O' y a N N m ~ f6 C a t ~ ~ ~ O . ~ ~ , ~ . ~ , c ~ ~ m. ~ a• ~ ~ , o ~ ~ m. 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Q' °, ar N' m' °, Y Z -a, o c, a ° ~~ ~ d >~ °` ~ ~~ m. y , c °~ ~ N a' , N c, , ~ vi °, ~ Q • i ; a E; E, = a , ~ • c, c E' r- m, m; o M' c' c ~, > F=' ~, v 4 m c' o ~S' a?' ~' c ~' ° o' Q- o o ni ~ n rn ~ c c~ m ~ ' ~ g ~' n ~; ~; ~ ~~ ~ , o. o ~ ~ o ~ .a ~, ~~, ° y ~ o o, ~, ~ ~, o o~ ~, ~ o, 3, ~, a, ~n a o, o o, ~, ~ ~n Y Q ° ~ c. c, .a. m. s _ .°c ~ ' ~ ~, ° N, ° .c, `° a °r ' ._., m, L O1 o ' 3, o o, ~~ v p 3, ~ a ~, a c a, m m ° ~ ~ ' c' - ~m o °~ 3; 3; m ' ° a, E, ~ ~ , $ m. ~, ~, 'v ~; y c o ~ ~', co ° ~ o N ~, a 'a Q ~ 0 3; t ~ °~ w U o p ~ O~ a ~; ~ ' m ° ~' ~ ~~ O, ~, - i1 ~~ ~~ O .. _ , W ~~ O~ C' a , p' Y O~ O~ p N ~~ ~ u i , ~°~ ~ ~, ~p~ ~ ~ C~ O~ o N~ Q ~, ~ , 0. J J a W Q a' N' N' ' L' 4 ' ~' T T a C' ~ ~ ~ ' d ° ' Y' a' ~ ~ y ~' y' - ' f6' ~ m O' O f/a : c. T ~ O, C • ~i z L, v O. ° y N O. a of a~' ~' m' o o E °. y, N' d y ~ ~, N, w' N y N ~ ~ of ~ m m N ~ p, m rn O ~, °, o ~' $f ~ C. U, > -. 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V~ V, Q ° a; ~ '=-; Q ~~ Q O O s, m; m; U ai ~, `~ ~~ m. ~ o m m, m m ~ o, V ~ U tiJ a , , , , , , , , , , , ~ , , -~ , ~ , ~ = O N M d' ~ co I~ M O O N N M V ~ O r M O> O M N M V u7 cD h a0 O) O ~ N M '7 ~ c° I~ M Q1 .- ~ N N N N N N N N N M M M M M M M M M U U ~ o O ^o . . °~ ~ O O m o l~''6 N m R o N mo ly6 N V p m o w D M ~ D °p ~ M oo'y y J N !~ ~ ~ ~ c.7 E W o .~ a o ~ a g~ -°° ao U ~ Q Q ~ W Q I- (~ Q (n .7 Well I-lisiory File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify finding infom~ation, 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. 1j-17611.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb O1 08:50:31 2008 Reel Header Service name .............LISTPE Date . ...................08/02/01 Origin ...................STS Reel Name...... ......,.UNKNOWN Continuation Number......01 Previous Reel Name...,...UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/02/01 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Physical EOF comment Record TAPE HEADER Kuparuk River Unit, west Sak MWD/MAD LOGS WELL NAME: 1J-176L1 API NUMBER: 500292336460 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: O1-FEB-O$ JOB DATA MWD RUN 2 MWD RUN 6 MWD RUN 7 Job NUMBER: Mw0005126703 Mw0005126703 Mw000512b703 LOGGING ENGINEER: B. HENNINGSE R. FRENCH B. HENNINGSE OPERATOR WITNESS: M. THORNTON M. THORNTON M. THORNTON MWD RUN 8 JOB NUMBER: MW0005126703 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1686 FEL: 2461 FW L : , Page 1 ~a~_~6~ ~~s~~a 1j-17611.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 121.55 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 10238.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10238' MD/3162'TVD, WITHIN THE RUN 2 INTERVAL OF THE 1J-176 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 6. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,7,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). THE BHA PARTED AT THE JARS DURING MWD RUN 7. THE BHA FISH WAS SUCCESSFULLY RETRIEVED. THERE IS AN UNEXPLAINED DATA GAP (10442.5'MD-10462'MD) IN THE SROP DATASET, AT THE START OF MWD RUN 8. 6. 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. 7. MWD RUNS 1,2,6-8 REPRESENT WELL 1J-176 L1 WITH API#: 50-029-23364-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17820'MD/3141'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 Page 2 ~ ~ 1j-17611.tapx 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.......08/02/01 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......sTSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPM RPS RPD RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3769.5 3780.0 3780.0 3780.0 3780.0 3780.0 3805.5 STOP DEPTH 17785.0 17777.5 17777.5 17777.5 17777.5 17777.5 17820.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 3769.5 10238.0 6 10238.5 10290.0 7 10290.0 10442.0 8 10442.0 17820.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging 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 Page 3 ~ ~ 1j-17611.tapx 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 Servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 3769.5 17820 10794.8 28102 3769.5 17820 RPD MWD OHMM 1.95 2000 53.1467 27996 3780 17777.5 RPM MWD OHMM 0.29 199.77 45.0839 27996 3780 17777.5 RPS MWD OHMM 0.75 132.45 44.8098 27996 3780 17777.5 RPX MWD OHMM 3.42 755.04 45.8964 27996 3780 17777.5 FET MWD HOUR 0.05 561.56 0.89465 27996 3780 17777.5 GR MWD API 17.55 110.47 62.711 28032 3769.5 17785 ROP MWD FT/H 1.9 1534.78 278.904 27990 3805.5 17820 First Reading For Entire File..........3769.5 Last Reading For Entire File...........17820 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type ................L0 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.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3769.5 10238.0 RPD 3780.0 10238.0 RPx 3780.0 10238.0 RPM 3780.0 10238.0 FET 3780.0 10238.0 RPS 3780.0 10238.0 ROP 3805.5 10238.0 Page 4 1j-17611.tapx LOG HEADER DATA DATE LOGGED: 27-AUG-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10238.0 TOP LOG INTERVAL (FT): 3805.0 BOTTOM LOG INTERVAL (FT): 10238.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79,7 MAXIMUM ANGLE: 85.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 230192 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 2080.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (5): 51.0 MUD PH: g,4 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 3.500 78.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.300 122.0 MUD FILTRATE AT MT: 2.600 78.0 MUD CAKE AT MT: 1.100 78.0 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 Name service order units size Nsam Rep Code offset Channel Page 5 1j-17611.tapx DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MwD020 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3769.5 10238 7003.75 12938 3769.5 10238 RPD MWD020 OHMM 1.95 2000 14.5097 12917 3780 10238 RPM MWD020 OHMM 0.29 141.85 13.2587 12917 3780 10238 RPS MWD020 OHMM 0.75 88.26 12.6347 12917 3780 10238 RPX MWD020 OHMM 3.42 39.65 11.1698 12917 3780 10238 FET MwD020 HOUR 0.05 112.95 0.75283 12917 3780 10238 GR MWD020 API 17.55 110.47 62.5427 12938 3769.5 10238 ROP MWD020 FT/H 9.15 1534.78 307.108 12866 3805.5 10238 First Reading For Entire File..........3769.5 Last Reading For Entire File...........10238 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 10238.5 10290.0 LOG HEADER DATA Page 6 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) 1j-17611.tapx 18-SEP-07 Insite 74.11 Memory 10290.0 10238.0 10290.0 .0 .0 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 10238.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S); 60.0 MUD PH: ,0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3): .Q RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 96.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 Page 7 1j-17611.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10238.5 10290 10264.3 104 10238.5 10290 ROP MWD060 FT/H 1.9 39.75 18.8829 104 10238.5 10290 First Reading For Entire File..........10238.5 Last Reading For Entire File...........10290 File Trailer Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File TyL~e. .LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10238.5 10408.0 FET 10238.5 10400.5 RPx 10238.5 10400.5 RPM 10238.5 10400.5 RPD 10238.5 10400.5 RPS 10238.5 10400.5 ROP 10290.5 10442.0 LOG HEADER DATA DATE LOGGED: 19-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10442.0 TOP LOG INTERVAL (FT): 10290.0 BOTTOM LOG INTERVAL (FT): 10442.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.8 Page 8 i • 1j-17611.tapx MAXIMUM ANGLE: $4,2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 10238.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 62.0 MUD PH: ,0 MUD CHLORIDES (PPM): 26500 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 89.6 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10238.5 10442 10340.3 408 10238.5 10442 Page 9 1j-17611.tapx RPD MwD070 OHMM 2.86 118.36 44.4692 325 10238.5 10400.5 RPM MwD070 OHMM 5.5 105.78 38.6947 325 10238.5 10400.5 RPS MWD070 OHMM 4.88 107.13 37.8031 325 10238.5 10400.5 RPX MWD070 OHMM 7.11 97.15 35.2082 325 10238.5 10400.5 FET MWD070 HOUR 0.13 561.56 12.1026 325 10238.5 10400.5 GR MWD070 API 44.25 91.16 62.9571 340 10238.5 10408 RoP MwD070 FT/H 13.85 500.32 292.068 304 10290.5 10442 First Reading For Entire File..........10238.5 Last Reading For Entire File...........10442 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 10401.0 17777.5 RPD 10401.0 17777.5 FET 10401.0 17777.5 RPM 10401.0 17777.5 RPS 10401.0 17777.5 GR 10408.5 17785.0 ROP 10462.5 17820.5 LOG HEADER DATA DATE LOGGED: 25-SEP-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17820.0 TOP LOG INTERVAL (FT): 10442.0 BOTTOM LOG INTERVAL (FT): 17820.0 Page 10 • • 1j-17611.tapx BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85,9 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97054 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 10238.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 67.0 MUD PH: ,0 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: 122.100 122.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Log~iny 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 MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 Page 11 • 1j-17611.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10401 17820.5 14110.8 14840 10401 17820.5 RPD MWD080 OHMM 38.63 219.05 87.1642 14754 10401 17777.5 RPM MWD080 OHMM 30.16 199.77 73.0873 14754 10401 17777.5 RPS MWD080 OHMM 24.31 132.45 73.1332 14754 10401 17777.5 RPX MWD080 OHMM 21.81 755.04 76.5346 14754 10401 17777.5 FET MWD080 HOUR 0.11 70.49 0.771923 14754 10401 17777.5 GR MWD080 API 39.6 88.7 62.8529 14754 10408.5 17785 RoP MwD080 FT/H 6.14 782.36 255.802 14717 10462.5 17820.5 First Reading For Entire File..........10401 Last Reading For Entire File...........17820.5 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EoF Tape Trailer Service name .............LISTPE Date . ...................08/02/01 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................08/02/01 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. scientific Technical services Library. scientific Technical Services Page 12
