Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
206-049
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FEB 2 2 2M 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown' ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well El Convert to WAG INJI] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhilllps Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic❑ Service l] 206-049 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23306-61-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1J -127L2 ADL 25650, 25661 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): NIA 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,227 feet Plugs measured none feet true vertical 3,685 feet Junk measured none feet Effective Depth measured 12,194 feet Packer measured 5,025 feet true vertical 3,684 feet true vertical 3,482 feet Casing Length Size MD TVD Burst Collapse Structural NIA WA NIA N/A Conductor 80' 20" 121' 121' Surface 2,215' 10.75" 2,258' 2,216' Intermediate 6,388' 7.625" 6,429' 3,724' Liner 7,152' 4.5" 12,194' 3,684' Perforations: Horizontal slotted liner Measured depth: 5,159'-12,119 feet True Vertical depth: 3,511'-3,682 feet Packers and SSSV (type, measured and true vertical depth) Baker ZXP LlnerTop packer 5,025' MD 3,482' TVD SSSV TYPE: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf I Water -Bbl I Casing Pressure Tubing Pressure Prior to well operation: o 0 11400 11200 1610 Subsequent to operation:10 1400 10 11050 11660 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas ❑ WDSPL D Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 319-017 Contact Name: Sydney AUtry Authorized Name: Sydney Autry Contact Email: sydney.autry@cop.com Authorized Title: Sr. Petroleum Engineer Date: ?121 LZQ5 Contact Phone: 907-265-6813 Authorized Signature: /I9 Form 10-404 Revised 4/2017 V7`L 3//// ABDIMS1 FEB 2 5 2019 Submit Original Only 1 J-27L2 CONVERT TO WAG DTTM JOBTYP SUMMARYOPS START 2/14/19 PUMPING PUMPED 3 BBLS METHANOL DWN FL FOR FREEZE TRACKING PROTECT & 4 BBLS METHANOL DWN TBG FOR ONLY WAG. "iOB COMPLETE" KUP INJ WELLNAME 1J-127 WELLBORE 1J-127 ConocoPhlllips WN in- ibutes Max AngleB MD TO lJr/, FIaW Neme .0the a APWWI WR" -so", ncH°) MD IXXBI ...TONS, Alaska. Inc.WESTSAK 500292330600 INJ 5.43 10,339.16 11,9970 inumpew.n. IT I? azlmn5+a.No PM Last Tag Vwti:W ePrralc l.I Annotation Ceplk (BBaI EMDab W."Res" "'n"49y _-_-- ....._._...__ __....,..,____. HANGER: 9i7 Last Tag; 4,9830 3/31200] 1J-127 WV5. Conversion Last Rev Reason Annohllon EM Gate Wellawe ". M. By �i CCNDVCTCR InsuM�A'. aa+mO NIPPLE; iB23 suRyAGE: a3.z?sJ.J- Gel Lan. 2,kil GeSLar', 3.9,09.. SIEEVE; ANS2 ILCATOR; SW18 SEA, "BY 5.G5.5 Dsallo uesR;%011 12107 D LINER BEN; SONTRE,21z8 BSWD ussR; S.aea Xz _ B ONER Lou, S,+}a.5b.5m0 INTERMED.TE AG.Sa,ia.a SLOTS:.fia.OT.afO�� dors:7.we.Ba,zsz.0� SLOr&..511. 41: �y SLOT$9,40.De..a.0�7 sLors; maRSIA"O0� SLOTS. 10.805.0.11.4112.0_ti SLOTS'. nMpoll.Sl O. - Illy asaxouNER', ARDS -1R �l l +tA1lT Rev Reason'. REVISE LINER 11. be 105 5/168013 1J-12] osborl Casing Strings Co.,., Description 00(inl ID (in) top IRRBI get Dep",iMe) -1 Oap",jN01... M.. (I Grade Top TNwatl CONDUCTOR Insulated 20 19.12 434 1210 1210 94,00 K-55 WELDED 34° Con, Mscrlption 00(inl ID 6n1 Top antro Set Depth Otl(el sort Dryers 01,10.. WIILem 6...Groke Top Throne SURFACE 10314 995 43.3 2,25).] 2$16.1 45.50 L40 BTC Cnlnp Deunperbn OD IInI ID lin) TOP IBRB) Seer CepM"i'd sonOeps, INDL.. mmon 11... Grape Top N. INTERMEDIATE )WB 6.0) 40.5 6,428.8 3)24.6 29,70 L-80 BTC Gaaine.. ."pk, OD pnl ID 9n) Top (Rod ager Depto (RK.) No oner"W" We no Gn4e Top phe". O LINER DEM 612 396 5,024.8 5,2120 3,529.0 12.60 L80 IBTM Liner Details Top B18e1 To'(WID)Bael Nominal IS Topinclpl Item Des com lin) 5,024.8 3,4823 T605 PACKER ZXP LINER TOP PACKER 4.950 5, .8 3,486.8 7653 SBR Casing Seal Bore Receptacle 4750 5,063.5 391.3 76]4 XO BUSHING Crossover Bushing 3.950 5.068] 3,492.5 7665 HANGER LEM Above Hook Hanger 3.950 5,0)89 3,494.8 7648 HANGER LEM Below Hook Hanger 3686 5.1655 3,5162 7481 BENTJT BENT JOINT 3.8M 52088 3,528.0 ]3.50 SEAL ASSY Baker Seal Assembly 3.880 Casing Deunplun OD llnl m (nl Top IRHBI Stl Deim po B) set Drym (No1... WtlLen (_. Grade Top TIN B LwER LEM 4112 3.96 5,1)6.5 5,5010 3,6014 12.60 L -BO IBT-M Liner Details NombwllD Top(tltel Top (TW111XXe) Top trot l') Rem Des Com (in) 5,1765 3,519.1 74.48 PACKER 2XP5It x7 -WB" Liner Tap Packer 4.9W 5,195.7 3,5244 73.90 SBR 19647 Casing Seal Bore Receptacle 4709 5.2153 35 7330 XO BUSHING X"eshing S-18" Hydnt%3x4-112'IBT 600" 3.920 5,34).1 3,566.8 75.87 HANGER LEM Above Hook Hanger 3.909 5,358.0 3,569.5 ]599 HANGER LEM Inside Hook Hanger 3710 5,423.1 3584.9 76.60 NIPPLE Comm 'DB -6' Nipple, I.D. 3.563', IBTM 521 -OD 3.563 5,49]] 3,600.8 79.30 SEAL ASSY Baker Seel Assembly 4-1Z ST -L Box up 475 -OD 4000 ollm DescrllNbn ODlip ASAND LINER 41/2 ID (n) Top me) neer Cepm mNa) aM Deplk OVD) ver.S...Grade Top Thread 396 5,453.9 11,990.7 3866.0 12.60 L-80 BTC -M Liner Details Top (IXel TOp (iV011BKB1 Nomintl ID Top Incl p) I4m Des CAN, (In) 5,453.9 3,592.0 ]729 PACKER HRD ZXP Liner Top Packer 5500 5,4)2.8 3,596.0 78.15 NIPPLE RS rockoff Seal Nipple 3.562 5,4756 3,596.6 )8.28 HANGER 11.1.11, liner Hanger 4.853 5,4855 3,598.5 ]8.74 SBE Casing Seal Bore Extension 4.750 5.505.1 360221 ]9.64 IXU BUSHING Crossover SunM1'mg 3.920 Tubing Strings Tubing DeserlPnon I arm. Ma_.mlm) Tnpnike) Seer Deplk lX_Rl Deptk TVD)(... -deed, Gme rop conn«1pn TUBING 41/2 396 3]J 5,0561 3469.6 1260 L80 IBT Completion Details TopIN01 lntlTop(Ikel IXk) It.m Oea Com ID(�) 3]]JL7000 HAN ER Ve. Gray TubingHanger 4.500 482.3 482.341 NIPPLE 4112" Camco DB Nipple 3.875"' 36]5 4,983.2 3,4]1.8.99 SLEEVE Baker CMUSlidingSleeve 3810 ;74 5.0318 3.683.9622 LOCATOR Baker Locetor 38]5 5.033.5 3.684.3627 SEALASSY Baker Seal Assembly 3875 perforation & Slots roplKKel BenlKKel TOpunin (Xkel eNn(TV01 Dace) uoxmz�ne Dam Shot Den proi.m I Time cam 6,6280 ],351. ,) 14 3,739.8 WSA2,1JA2) NW% 32.0 SLOTS L L TS THIS WELLBORE Alternating slo6eNmlid pipe 0.125" x 25' x 32 spl @ 4 Circumferential adjacent rows, 3r Centers staggered 18 deg'. 3 a' nonslOMd ends 7, ,252.0 3,748.3 3,748.9 WS A2, 1J-127 6/412006 320 SLOTS 8.511D 9.147.0 3,7517 37608 WS A2, 1J-127 6//12006 320 SLOTS 94460 9,820.0 3,]631 3]764 WS A2, 1J-12) W4I2006 32.0 SLOTS -i 20 10,6]].0 3,805.5 3]99.3 WS A2, 1J-12] WG2006 320 SLOTS 108050 11,482.0 3,806.1 I 3,835.1 WS A2, 1]-12] 1wei 32.0 SLOTS 11,6950 II.S4501 3,847.7 3,864.1 WS A2, 1J-127 IW41MM I 32.0 I SLOTS Mandrel Inserts sl ars N Top nVOl Valve latch Appele TRO Run Top IKKBI .MIB) Mak. Madel ODdhe Sery Type Type (In) .pep Run Dab Com 2469.1 95. CAMCOK -- 1 GA LIFT DMY BK -1 0.000 0.0 9842006 1R -_ AB LIFT 2 3,909.5 3,140.4 CAMCO 1 GDMY BK -1 0.000 0.0 9258009 KUP INJ WELLNAME U-127 WELLBORE 1J-127 1111 Conoc6Phillips Na6ka. lm. NIPPLE: 453.3 SIIRFPCE. 4]TZW 7� CASUFr:Z.LI— wsuFr.6E®s— ,1MER LEK; 017ER-E.— INTERMEOIATE! S 661368 SLOTS; 66R. 67.3510�� 1 SLOTS; 7.60E" M.O�l l 81Ai6; 6511 O8,ta)0—ti SLOTS. 9610..M 0-------_ SLATS', 1038 Ia 7T0� SLOTS, 10.615.O11.'PE'D AOT5; 11.856611515.0�� PSWO LINER: Si61.&� 11.5307 ConocoPhillip5 Alaska. Irk. SURFACE.^ a 2259 WS LIFT Z. KIM 1J -127L2 Well Attributes-- - -- --� tMa..An e & Mp TD Wellbore APIIUWI Fold Name Well Stylus Inel l°) MD Ifl✓.BI Hct:1,/MMB) 91.99 10,651.71 12.22].0 500292330661 WEST SAK INJ Comment H251pPm) Me Anndalio8 End Dvle KBUMIaI Pg Releaze Date 44.39 716/2006 SSSV. NIPPLE Las, WO'. Date Arnota\bn De In nINB Entl Dat Annotation Laal Motl By EnO1161 REVISE LINER 11.6M IDs osbod L _511612013 Last Ta9'. 4.983.01 31311200) He Reason: _ _ casin Strin s Set Depin,f.. sal ceplM1 ITVDI 54ing W,.. airing SMng Top TFrtl Cazinq Dezcr 0l on a\i ng0 5 ing 1D .Top ltMB 3,683.9 1160 1-80 IBT D -SAND LINER 4112 3AJ6 5041.9 12.193) Liner Details Top Depth Noml... PD) Toy Incl comment ID 6n) TOP(AkB) INKS) (1) Item Dear' loop 5,041.9 3,486.3 ]6.48 HANGER Model S-1- Hook Hanger inside of 7- 5.630 5,058.3 3,489.5 75.23 HANGER Baker Madel'B-1'Hook Hanger insideol7- 5.630 12,164.2 3,683.0 88.29 BENT JT ., 2.992 Perforations $Slots Top(vD) elm IND) Dena "Ke) IXNB) Zone 0. IeM1... Type Comment Tap RnB) BM NIINB) 5,203.0 3,510.6 3,515.8 WS D. 1J -127L2 7220W 32.0 SLOTS AALILL$LOg STHIS 5.159.0 soELLBORd pipe 0.125"x 2.5 x 32 spf @ 4 Ci..pret renti8l adjacent rove, 3- Centers staggered 18 ft. 3 ft. non -stoned ends 5,419.0 5.892.0 3,520.0 3,525.8 WS D. 1J.127L2 7122006 VA SLOTS 6,151.0 6,624.0 3,5323 3,542.0 WS 0, 1J -127U 7122006 32.0 SLOTS 6,924.0 7,391.0 3.546.8 3.549.3 WS D.1J-12]L2 ]212006 32.0 SLOTS 7,685.0 7.982.0 3,549.2 3.552.6 WS D. 1b1271-2 7212 06 32.0 SLOTS 8,284.0 8,748.0 3,56].6 3,5]6.4 WS O,1J-12]1-2 7212006 32.0 SLOTS 8,950.0 S WA 3,582.7 3,502.5 WS D. IJ -127L2 11712006 32.0 SLOTS 9,674.0 10,064.0 3,583.6 3,589.7 WS D,1J-1271-2 7212006 32.0 SLOTS 10,275.0 10,751.0 3.599.9 3.618.5 WS D,111271-2 711/2006 32.0 SLOTS 11,01.0 11.476.0 3,619.5 3,639.0 WS D. TJ -1271-2 ]22006 32.0 SLOTS 11,733.0 12,1190 3.657.6 3,681.8 WS D, 1J-12712 7212006 32.0 SLOTS Notes: General $Safe End Data 11412006 Hnnome" — NOTE: VIEW SCHEMATIC WlAlaska SCMemalic9.OREV 1d127(ASANOL U-1211-1 IBRDNO), IJ -12712 (D -SAND) 71412006 NOTE: MULTbLATERALW I -L: .� AAantlre" : s — Top Deptn Top Valve Latch a... /TVD) Incl OD N... Top(1IK0) (e6B) P) Make MOGaI (iN eery Type Type Run Dale BK M-M 1 2.469.1 2,395.0 35.12 CAMCO KGG-2-1R 1 GAS LIFT DMV -1 2 3,909.5 3.140.4 67.18 CAMCOKBG-2-1R 1 GAS LIFT DMV BK -0 912512009 THE STATE OfALASKA GOVERNOR MIKE DUNLEAVY Sydney Autry Production Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J -127L2 Permit to Drill Number: 206-049 Sundry Number: 319-017 Dear Mr. 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 fiuther 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, ot�5�� Daniel T. Seamount, Jr. Commissioner DATED this 3 0 day of January, 2019. RBDMb`j FER 9 12019 RECEIVED JAN 16 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0GL CC APPLICATION FOR SUNDRY APPROVALS A0GCC 20 AAC 25.280 1. Type of Request: Abandon D Plug Perforations El Fracture Stimulate ❑ Repair Well 0 Operations shutdowlp Suspend ❑ Perforate O Other Stimulate O Pull Tubing E3 Change Approved Progran❑ Plug for Redrill ❑ Perforate New Pool o Re-enter Susp Well ❑ Alter Casing 0 Other: Convert to WAG INJo 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory D Development ❑ Stratigraphic 0 Service p 206-049 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23306-61-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A 011y1r! 1 KRU 1J -127L2 ' Will planned perforations require a spacing exception? Yes ❑ No t2 9. Property Designation (Lease Number): Z56s0 •g_ 10. Field/Pool(s): ADL 25661, ADL"660- 0% i9 I Kuparuk River Field / West Salk 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): 12,227' 3,685' 12,194' 3,684' 1973 None None Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 121' 121' Surface 2215' 10.75" 2258' 2216' Intermediate 6388' 7.625" 6429' 3724' Liner 7,152' 4.5" 12,194' 3,684' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slots: 5,159'-12,119'MD Slots: 3,511'-3,682'TVD 4.5" L-80 5,056' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = Baker ZXP Liner Top Packer MD= 5025 TVD= 3482 SSSV = NONE N/A 12. Attachments: Proposal Summary Wellbore schematic RI 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑r 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1 -Feb -19 OIL ❑ WINJ ❑ WDSPL ❑5 Suspended GAS ❑ WAG 10 GSTOR ❑ SPLUG 0 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 Signature: Date: ! COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number: 1 GOI ,-1y 1 \Sl Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No 5K Subsequent Form Required: /0 — 4 () LF - APPROVED BY G Approved by: COMMISSIONER THE COMMISSION Date: vTz 1/3009 VJFR n 12019 ',yp'y�uklof��1 R �%'�� I'A\I RBDMS Submit Form and `I'r/ Form 10-403 Revised 4/2017 Approved applicati�sUand BI irN a date of approval. Anach nts in Duplicate 1J -127L2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J -127L2 (PTD# 206-049) from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1J -127(L2) was completed as an injector on 7/6/2006 to provide waterflood support in the D, B, and A West Sak sands to offset producers 1J-101 and 1J-115. 1 �TaC 28o5 M The top of the Ugnu C sand was found at 3,291' MD / 2,908' TVD The top of the Ugnu B sand was found at 3,846' MD / 3,116' TVD The top of the Ugnu A sand was found at 4,153' MD / 3,223' TVD The top of the West Sak D sand was found at 5,075' MD / 3,494' TVD Area Map with 1/< mile radius around target injection zone (see attached): The map attached shows that, in addition to the offset producers (1J-101 and 1J-115), there are two Kuparuk wells (1 D-40 and 1 D -40A) and one West Sak well (1 D-134) that have penetrations in the West Sak interval located within a 1/4 mile radius of the 1J -127L2 penetrations of the West Sak interval. Mechanical Condition of Well to be Converted: The mechanical condition of West Sak injector 1J-1271-2 is good. The injection tubing/casing annulus is isolated via a Baker ZXP liner top packer located at 5,025' MD (3,482' TVD). The last state -witnessed MITIA was performed on May 9, 2018 to 2000 psi. V CBL and interpretation of the cement quality: See attached AOR detail for offset well condition. The 20" Conductor was cemented with 248 sx of ASI The 10-3/4" Surface casing was cemented with 450 sx AS Lite, followed by 130 sx DeepCrete, 107 bbls of cement to surface. The 7-5/8" Intermediate casing was cemented with 460 sx Class "G" cement, bumped plug, floats held. 1J -127L2 DESCRIPTION SUMMARY OF PROPOSAL Conditions for approval (if applicable): The 1J-115 vented packer will have a semi-annual vented packer pilot function test in conjunction with State Witnessed Safety Valve system testing as noted below: Packer Vent Valves — SVS Testing Requirements -- Inner Annulus (IA) SSV is part of the well SVS; test in conjunction with the well's other SVS components Test consists of: oVerify both tubing and IA SSV's stroke closed (function test) oVerify both SSV's hold pressure differential (performance test) oVerify the vented packer panels dump pressure (function test) --Document IA SSV performance test on separate SVS Test Report; o1 report shows test results for normal components; 2nd report shows results for IA SSV oDocument the packer vent panel dumps in remarks of IA SSV test report --IA SSV and vented packer panel tests count towards pad statistics --A drawdown test of the packer vent valves is not required as part of the Packer Vent Valve/SVS Testing requirements. Tap of D -sand Top of D -Sand Oil Top of Cement Top of Cement Top of Cement PTD API WELL NAME STATUS Oil Pool (MD) Pool (TVD) (MD) (TVD) Determined By Reservoir Status Zonal Isolation Cement Operations Summary Mechanical Integrity Weatherford Hydrow 11 Dual- 16"-260 sx AS 11 4/24/2014 - MITIA passed to Cementtosurface String Packer at 2,964' MD 7.625"-175 sx& 292 sx Class G Lead 2000 psi 198-111 500292289200 1D-134 Producing 5,556' 3,591' Surface Surface during 2nd stage(2,000'TVD). Perfs open for Cement to Cement, 278 sx Class G&60 sx ASI Tail Surface casing repair 7.625" cement job. production surface behind 7,625" surface Cement coin plated 5/13/14:1 bbls of casing. Portland Type 1 cement. 96 bbls of cement P&A w/ cement plugs: 29 bbls 20D-190 500292296900 10-40 P&A 5,360' 3,605' Surface Surface returns to surface P&A. Sidetracked as 1D 15.8ppg cement, 19 bbls 15.8 20"-503 sx AS Lite 9.625"- 818 sx AS III LW, 477 sx LiteCRETE P&A on rig completed during 9.625" 40A. cement. Cement to surface 9/2/2000 cementjob. behind 9.625" surface casing. 7" -180 sx Class G 20"/9.625"/T' -See 1D40 Baker ZXP Liner Top Packer of 30,385' MID and ]"x9.625" - 50 bbl cement plug post 7" 7/09/2018-2000 ITIA passed 200-190 500292296901 1D -40A Injecting 5,360' 3,605' Surface Surface See 1D-40 Perls open for injection csg pull cement job 9.625"cement job (top@ to 2000 psi surface) 7"-180 sx Cie.G 3.5"-170 sx Class 195 bbls cement Viking Vented Packer at 5,094' 20"- 171 sx A51, 161 sx A51 9/07/2017 -MITT passed to returns to surface Slotter liners open for MD (3,190' TVD). Cement to 10.75"- 534 sx ASL, 274 sx DeepCrete 3000 psi, MITIA passed to 206-122 500292332000 L-115 Producing 6,095' 3,554' Surface Surface surface behind 10.75 surface 7.625"-1]5 bbls Class 2500 psi, new Tbg Packoffs during 10.75" cementjob. production casing and behind 7.625" 7.625" Tie -back - 446 sx Class G, 13 bbls tested to 5000 psi from 1903' to surface. of cement to surface 1/13/2019 -IA DDT passed Baker ZXP Liner Top Packer of 20" -152 sx ASS, 130 sx ASI 7/19/2018 - MITT passed to 43urface bbls to Slotter liners open for 4,141' MD (3,438' TVD). 10.75"- 460 sx Arctic5et, 148 sx 2500 psi 205-182 500292328600 L-101 Producing 4,204' 3,452' Surface Surface durientng DeepCrete .75"ceduirng 10.]5"cementjob. production Cement to 7625'-310 sx DeepCrete to 7/22/2002500 10.75" surface wzing. surface casing. psipassed 2500 psi 1 ADL025651 Well Pad — Well Trajectory 1J-1271-2, Open Interval QU-12712 01 Quartermile Buffer X West Sak Top in non -West Sak Wells + West Sak Base in non -West Sak Wells Non -West Sak Well - - - Inactive non -West Sak Well West Sak Well West Sak Well WS Interval j_ --_-I West Sak PA CPAI Leases ConocoPhillips Alaska IJ -127L2 Injection Sundry 0 12/5/2017 1 ADL025650 I q ADL026661 o G ADL025662 0.2 0.4 0.6 ■ Miles i, IN o 0 0 T I I N ,R10E_ T10NR110E N A ConocoMillips Naske, Inc. ®l' CLOTS WellEme AVI/UWI FiNtl Name 500292330661 WEST SAK 6.936I.E1 lomsno.]s, i 1 i - 1 Anirolallon DeptM1 @NBI Entl Dtle Annotation Last Tag: 4,983.0 3(]11200] Rey Reason: REVISE LINER 11.6# IDs :1 I 1- IL- 1 i aLOTs, I1,M1-11 J]6 5,058.3 3.489.5 7523 HANGER Baker Model'&PH.I,Hanger insid.Of7- 5.630 76es7.912 Perforations & Slots 1 i I I ]l2/2008 32.0 a i SI -OTO i 6,151.0 6,624.0 3,532.3 3,542.0 I . 11.T1113,11a €_i' ,1 €1 1 WS D. 1J -127U 712/2006 32.0 SLOTS 8.284.0 8,748.0 3,567.6 3,576.4 WE D. 1JA27L2 7/22006 32.0 SLOTS 8,950.0 9,460.0 3,5U.7 3.582.5 SLOTS. 1 1 e.eso-gaw ! B 1 WS D, IJ -12712 722006 32.0 -F 1- WS D, iJ-12712 70@ 06 320 SLOTS 11,733.0 12.119.0 3,657.6 3,681.8WS SLOBS._ SLOTS Notes: General & SafetF Fn4 Date Am endion -1 F e i - SLOTS._ WellEme AVI/UWI FiNtl Name 500292330661 WEST SAK We113tatuf mm'T MDIRKBI ACfBM (RKBI INJ 91.99 10,651]1 12,22].0 lomsno.]s, i 1 i - 1 Anirolallon DeptM1 @NBI Entl Dtle Annotation Last Tag: 4,983.0 3(]11200] Rey Reason: REVISE LINER 11.6# IDs I 1 1 I 1- IL- Ca sing Deacriptlen StNnSO- SW�g ID..TOPIRKB) SN CeptM1 I1... Set DepIM1 ITVDL.. StnnBW1.String...Smne Top TM1rtl 1}$AND LINER 4112 3.476 5,041.9 12,193.] 316619 11.60 LEO MIT Liner Details Top DePm (TVD) ToPmcl None— Top(", (RK8) V) Item Dese"Pon Comment ID(fin) I1,M1-11 J]6 5,058.3 3.489.5 7523 HANGER Baker Model'&PH.I,Hanger insid.Of7- 5.630 12,164.2 3,683.0 88.29 BENTJT 2.992 Perforations & Slots 1 i Type Comment 5,159.0 5,203.0 3,510.6 3,515.8WSD,1J-127L2 ]l2/2008 32.0 SLOTS ALL SLOTS THIS WELLBORE: Alternating s1011ed/solid pipe 0.128'x 2.5-x 32 spf@ 4 Circumferedbal adjacent mws, X Centers staggered 18 deg., 3 R nonaloRed ends _I L smrs____-1- 6,151.0 6,624.0 3,532.3 3,542.0 I . 11.T1113,11a €_i' ,1 SLOTS 7,685.0 7,9820 3,549.2 3.558.6 WS D. 1J -127U 712/2006 32.0 KUP 1J -127L2 Well AttributeS Max Angle & MD TD WellEme AVI/UWI FiNtl Name 500292330661 WEST SAK We113tatuf mm'T MDIRKBI ACfBM (RKBI INJ 91.99 10,651]1 12,22].0 Comment TOSmpm) DHe AnnMatlon SSSV. NIPPLE Last WO'. Entl Dale KB -mm, Rig...... Dale 44.39 7/6/2006 Anirolallon DeptM1 @NBI Entl Dtle Annotation Last Tag: 4,983.0 3(]11200] Rey Reason: REVISE LINER 11.6# IDs Last Mod By EnE Dah osb.d 1 511612013 Casin Strin s Ca sing Deacriptlen StNnSO- SW�g ID..TOPIRKB) SN CeptM1 I1... Set DepIM1 ITVDL.. StnnBW1.String...Smne Top TM1rtl 1}$AND LINER 4112 3.476 5,041.9 12,193.] 316619 11.60 LEO MIT Liner Details Top DePm (TVD) ToPmcl None— Top(", (RK8) V) Item Dese"Pon Comment ID(fin) 5,041.9 3,486.3 76.48 HANGER Model"B-1- Hook Hangar inside of]- SWO 5,058.3 3.489.5 7523 HANGER Baker Model'&PH.I,Hanger insid.Of7- 5.630 12,164.2 3,683.0 88.29 BENTJT 2.992 Perforations & Slots Top Mid son (TVD) Top (RKB) Btm (RKB) (aKB) (RKBI snot Den. Zone oNe (fM1-- Type Comment 5,159.0 5,203.0 3,510.6 3,515.8WSD,1J-127L2 ]l2/2008 32.0 SLOTS ALL SLOTS THIS WELLBORE: Alternating s1011ed/solid pipe 0.128'x 2.5-x 32 spf@ 4 Circumferedbal adjacent mws, X Centers staggered 18 deg., 3 R nonaloRed ends 5,419.0 5,892.0 3,520.0 3,525.8 WS D. 1J-12]12702006 32.0 SLOTS 6,151.0 6,624.0 3,532.3 3,542.0 WS D. 1J-12712 722006 32.0 SLOTS 6,924.0 7,391.0 3,546.8 3,549.3 WS D, 1J-12712 722006 32.0 SLOTS 7,685.0 7,9820 3,549.2 3.558.6 WS D. 1J -127U 712/2006 32.0 SLOTS 8.284.0 8,748.0 3,567.6 3,576.4 WE D. 1JA27L2 7/22006 32.0 SLOTS 8,950.0 9,460.0 3,5U.7 3.582.5 WS D. U-12712 7=006 32.0 SLOTS 9,674.0 10,064.0 3,583.6 3,589.7 645 D,1J-12712 7=06 32.0 SLOTS tO,D5.0 10,751.0 3,599.9 3,618.5 WS D, IJ -12712 722006 32.0 SLOTS 11001.0 11,476.0 3,619.5 3,639.0 WS D, iJ-12712 70@ 06 320 SLOTS 11,733.0 12.119.0 3,657.6 3,681.8WS D, 1J-12712 722006 32.0 SLOTS Notes: General & SafetF Fn4 Date Am endion 7/42006 NOTE: VIEW SCHEMATIC wiMaska ScbenmtiC9.OREV ]142006 INDTE: MULTI -LATERAL WELL: 1.F127(A-SAND),1J-12711(8-SAND), IJ-127U(DEAN)) Mandrel Details s... N... TOPIRKB) Top Ofpin (de.I /RKBI Too and 00 valve Type 1°I Mak¢ Model lint Bery iYPe TYpe POM1 Slee TqO Run (n) (Psi)Run Date Com... 1 2.469.1 2395.0 35.12 CAMCO KBG-2-1R / GAS LIFT DMV BK -11-U-1 0.0 9242006 2 3,909.5 3,140.4 67.18 CAMCO KBG-2-1R 1 GAS LIFE DMY BK -1 0.000 0.0 9252009 Boyer, David L (DOA) From: Autry, Sydney <Sydney.Autry@conocophillips.com> Sent: Tuesday, January 22, 2019 4:38 PM To: Boyer, David L (DOA) Cc: Davies, Stephen F (DOA) Subject: RE: [EXTERNAL] Sundry for KRU 1J -127L1 (No. 319-018) Dave/Steve, 1. Correct, the KOP (from the mainbore "1J-127") was at 5358' MD and the 1J- 127L1PB1 was drilled to a TD of 10,915'MD. After calling TD of 10,9151MD for 1J-127L1PB1, the BHA was pulled uphole to 10,4051MD for an open -hole sidetrack to continue drilling 1J -127L1 to a TD of 12,002'MD (lined to 11,966'MD). 2. TOC for the intermediate casing was estimated to be at 2805'MD per the CBL run on 6/05/2006. Please let me know if you have any additional questions! Thanks, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak 1E/1J ConocoPhillips Alaska, Inc. Sydney.Autrya?conocophillips.com W:907-265-6813 C:907-342-7606 From: Boyer, David L (DOA) <david. boyer2@a laska.gov> Sent: Tuesday, January 22, 2019 1:17 PM To: Autry, Sydney <Sydney.Autry@conocophillips.com> Cc: Davies, Stephen F (DOA) <steve.davies@alaska.gov> Subject: [EXTERNAL]Sundry for KRU 1J -127L1 (No. 319-018) Hi Sydney, L,!5 w -e v- -to 542 vtL5 C;CO (5 P_ r rkj c to P (4t, am the other geologist at AOGCC working closely with Steve Davies, who is on vacation this week. Steve had several questions on the application: 1. For 11-127L1PB1, was the KOP 5358' MD and the T.D. 10,915'? 1 found these depths on a 2006 data transmittal from Sperry Sun, please confirm. 2. Do you know the Top of Cement (TOC) for the intermediate casing in the 11-1271.1 lateral? Thank you for addressing Steve's concerns. Dave Boyer Senior Geologist AOGCC 1 • • WELL L®G T SIVIIT"I'AI, 'T®e State of Alaska July 31, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 ~ Anchorage, Alaska 99501 11? RE: MWD Formation Evaluation Logs: 1J;J.71+L1+L1PB1+L2+pB1+pB2 AK-MW-4376108 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-172+L1+L1PB1+L2+PBl+PB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23306-00,60,61,70,71,72 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23306-00,60,61,72 Digital Log Images 1 CD Rom 50-029-23306-00,60,61,70,71,72 .,,~.~~~~ ~~~ ~y 'p Zppg ~e~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNIl~1G A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage,,; t~~aska 9951'8 Anchorage, Alaska 99508 rr.. ~ ~$ i~lv i i' !' Date: ~y ~ ~-r Signed: (./.~ ,~i j ~x~~. ~a~wC+ ~ f~~ ~~-- i~~~, STATE OF ALASKA ~ ; ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS .~ t. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-049 / 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 '`.~ 50-029-23306-61 7. KB Elevation,(ft): 9. Well Name and Number: RKB43' '`~ ''' 1J-127L2 8. Property De ' natiort:~„` ti. 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 1.2227' feet true vertical 3685' feet Plugs (measured) Effective Depth measured 4983' feet Junk (measured) true vertical 3472' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 121' 121' SURFACE 2215' 10-3/4" 2258' 2216' INTERMEDIATE 6386' 7-5/8" 6429' 3724' D-SAND LINER 7109' 4.5" 12187' 3683' Perforation depth: Measured depth: 5159'-12119' true vertical depth: 3509'-3681' ~~ AUG ~ 20D8 Tubing (size, grade, and measured depth) 4.5", L-80, 5056' MD. Packers & SSSV (type & measured depth) D-sand ZXP liner top pkr @ so25' CamcoDB-6 nipple @ 482' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1224 -- Subsequent to operation 848 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after 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: 308-250 Contact Guy Schwartz @ 265-6958 Printed Name Guy~al Title Wells Group Engineer D c~ i ~~~ - ~ r Signature ~ Phone Date P ared b Sharon Allsu Drake 263-4612 ,- ` ~ ~ ~' ~~~~-- (~~ts `~ 1. I~~ ^ , o~rr~,1Q-¢Of4 avised Q4L2006 Submit Original Only tt~ • 1J-127 Well Work Events • DATE SUMMARY 7/18/08 Reel Blow Down.Travel to SLB Yard to Prep unit for 2 3/8" Coil. 7/19/08 PREP UNIT #4 FOR 2 3/8" 7/21/08 RIH TO 11388' CTMD INSIDE A-LATERAL AND PUMPED 290 bbls OF BAKER MICRO WASH SYSTEM TO 6500' CTMD.LEFT WELL SHUT IN FOR PRODUCT TO SOAK ON FILTER CAKE. JOB INPROGRESS 7/22/08 RIH WITH ISO SLEEVE, TOOL SHIFTED THE CMU OPEN, CONTINUE RIH SET ISO SLEEVE @ 5361' CTMD. POOH/ P/U DIVERTER BHA, RIH SET IN "D" LAT @ 5065' CTMD. POOH - P/U CMU SHIFTING TOOL, CLOSE SS @ 4973' CTMD, BLED IA DOWN, CONFIRM CMU IS CLOSED. POOH AND STAND BACK CTU FOR NIGHT. PREPARE FLUIDS FOR WASH IN AM. 7/23/08 MAKE UP 2.5"JSN WITH 2.3/8 MHA. RIH TAG "D"LAT @ 5086' CTMD. POOH, INSPECT PIPE STRAIGHTNER & MAKE ADJUSTMENTS. P/U BAKER UP/DOWN JARS & 4.5" GS. RIH, LATCH INTO DIVERTER @ 5065' CTMD. P/U 8~ JAR DOWN INTO PLACE AGAIN. POOH, INSTALL 2-3/4" JSN TAGGED UP @ 5083' CTMD (BOTTOM OF DIVERTER). POOH, INSPECT BHA - NO MARKS, STAND BACK CTU FOR NIGHT. 7/24/08 4 CTU RUNS. RIH WITH 2.5" JSN, 2-1/8" SB, KJ, & 2-3/8" MHA/CTC. DOWN TO 5082' CTMD. TAGGED UP, TRIED MULTIPLE ATTEMPS, POOH. MARKING ON NOZZLE INDICATE A PINCH POINT. P/U 4" GS & UP/DOWN JARS, PULL DIVERTER-INSPECT. MARKS DOWN THE BOTTOM OF RAMP, KEYWAY LOOKS GOOD. RIH SET DIVERTER BOTTOM 5085' CTMD, TOP 5067' CTMD. P/U 2.40" JSN, SB, MHA, RIH TAG 5083' CTMD, P/U 10K OVERPULL, SET BACK DOWN CLEAN P/U. POOH, INSPECT NOZZLE -SAME MARKS AS PREVIOUS NOZZLE RUN. STAND BACK CTU FOR NIGHT. 7/25/08 RIH WITH 2.5" JSN, DC, CV, 2-3/8" CTC WITH CHOKE CLOSED. TAG DIVERTER @ 5083' SET UP TO BULLHEAD ACID. HOLD SAFETY MEETING, START PUMPING @ 3 BPM, CIRC PRESS - 3300 PSi, WHP 540 PSI, IA 330. PUMP 350 BBLS OF ACID AWAY, TRIED TO GET THROUGH DIVERTER WHILE PUMPING WITH NO LUCK. FLUSH CT WHILE POOH. CT @ SURFACE INSTAL 4" GS & JARS, RIH PULL DIVERTER. CT @ SURFACE, NOTIFY DSO -WELL LEFT SHUT IN FOR 24 HOURS. RIG DOWN CTU. A D ~~~ ~~ ~~~~ I • • ~~~` KRU 1 J-127L2 j Cc~nc~~+~'t~tp~ A1~ska, (n~. • • ~ '~~ { °°'.. ~.:s ~°"°ti, N pp~ 4Qy~ ~ --~ yyr `~-~ E I ~ ~ ~...-.~ jptf ~ yt ~ ~ ~ i ' -~ ~ ~~`~ ~I ~ ' ~~ f ~..-...+f 4~f ~.k' ~ j q A it~.IF ~ ~ ~ t I '~ Y5 yy f _ ~ / } J ~. ~ 1 j ay 1F f p ~~ ~~ ` f ~ ~-, ~~ ... \-..- Z..A L..i ~'. {.,.._...J A-.~ j~ ~` ~ A i g k.I X..S A ~. ALASKA OIL A1~TD GAS CO1~T5ERQA7'IO1~IT C01-I1rIIS5IOI~T Guy Schwartz Wells Group Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Kield, West Sak Oil Pool, 1J-127L2 ~~ Sundry Number: 308-250 l~ Dear Mr. Schwartz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As 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 Commssion 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 8day of July, 2008 Encl. Sincerely. ~~~ STATE OF ALASKA ~(~~ ~ ~ ~~QB ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL~-'~~ ~~~ ~~ ~~+~ :~. t~Omr~iv~rOrt 20 AAC 25.280 Anc;. 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate 0 Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-049 3. Address: Stratigraphic ^ Service Q , 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23306-61 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ 1J-127L2 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661, 25650 • RKB 43' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12227' 3685' ' 4983' 3472' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 20" 121' 121' SURFACE 2215' 10-3/4" 2258' 2216' INTERMEDIATE 6386' 7-5/8" 1i42g' 3724' D-SAND LINER 7109' 4.5" 12187' 3683' Perforation Depth MD (ft): Perforation Depth ND (ft Tubing Size: Tubing Grade: Tubing MD (ft): ~-"~' 5159'-12119' 3509'-3681' 4.5" L-80 5056' Packers and SSSV Type: Packers and SSSV MD (ft) D-sand ZXP liner top pkr @ 5025' CamcoDB-6 nipple @ 482' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: July 21, 2008 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: Guy Schwartz @ 265-6958 Printed Name GUV SChWartz Title: Wells Group Engineer Signature Phone 265-6958 - ,7 Date '7" ~y-~I Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Pfug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~ APPROVED BY r/Q %~ Approved by: OMMISSIONER THE COMMISSION ' Date: (/ (/ ~~JJ Form 10-403 Revised 06/2006 ~ ~' ~~~_, ~i~~_ ~ `~ 2~D8 (~ Submit in Duplicate • • 1J-127 Microwash Stimulation 7-14-2008 History: 1J-127 is a multilateral West Sak Injector that was drilled with OBM and completed with a slotted liner. Injection surveys indicated B lateral was taking almost all the injection. The D and A laterals are currently not getting adequate injection support. The D and A laterals will be treated with Baker's "Microwash "system in hopes of eliminating or reducing the amount of OBM filtercake on the wellbore face. Procedure: The basic process is using 2 3/8" coil tubing to lay in the Microwash product 1:1 along the slotted liner and letting it soak for 24-36 hrs before commencing injection. The product will not be brought back to surface after injection. Outline of procedure: r 1. Isolate the B lateral by setting an ISO sleeve at B lateral junction --~ iSC`~~5 ~- 2. RIH with 2 3/8" CT and lay in 327 bbls of Microwash 1:1 . 3. Let soak for 24 hrs and commence infection. 4. SI well and RIH, set diverter in D lateral. 5. RIH with Nozzle and lay in 327 bbls of Microwash 1:1 6. Let soak for 24 hrs and recommence injection. 7. Pull D lateral Diverter. Pull ISO sleeve. ~ 8. Run mainbore IPROF to determine new splits. ~~' ~ ~~~~~~ .. --...~; KRU 1J-127L2 Cono~oPhillips Ataska, Inc 1 J-127L2_ API 500292330661 Well T INJ An ie TS: de a7 SSSV T e: NIPPLE Ori Com letion: 7/6/2006 An le TD: 88 de 12227 Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE Reference Lo : 43' RKB Ref Lo Date: Last U date: 12/2/2007 Last Ta : 4983 TD: 12227 ftKB i gas i ag uace: i.v s v~in~i i max nose Hng~e: i ac aeg cm ~ uoa~ _ i _ i _ i ~asine String -ALL STRINGS Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 121 121 62.60 H-40 WELDED SURFACE 10.750 0 2258 2216 45.50 L-80 BTC INTERMEDIATE 7.625 0 6429 3537 29.70 L-80 BTCM D-SAND LINER 4.500 5078 12155 3683 11.60 L-80 BTC L2 WINDOW 8.000 5082 5084 _ 3496 0.00 _ ___ I ubing Strang - I USING _ _ -. Size ~ _ Top ~ Bottom ~ TVD Wt ~ -- ~ Gratle I Thread - - 4 500 0 - -- 5056 3490 -- 12fi0 L-30 _ ~ IBTM - - - Perforations Summary _ __ _J _- Interval TVD Zone Status Ft SPF Date T Comment 5159 - 12119 3509 - 3681 WS D, WS 6960 32 7/2/2006 Slots Alternating slotted/solid pipe D,WS D,WS D Gas Lift MandrelsNalves - . . . I C I MD ~ TVD ~ Man Mfr ~ Man Type ~ V Mfr ~ V Type I V OD ~ Latch ~ Port I TRO ~ Date Run I VN I (p111~, equ~~etc.~-COMPLETION _~__ I I I TERMEDIATE r ~ (0-6429, - I ---- Wt:29.70) - I I , I 4983 3472 SLEEVE-C BAKER CMD SLIDING SLEEVE w/CAMCO 3.81" DB PROFILE -CLOSED 7/14/2006 3.812 5031 3483 LOCATOR BAKER LOCATOR GBH-22 -SPACED OUT 2' ABOVE FULLY INSERTED 3.875 5033 3484 SEAL BAKER SBE SEAL ASSEMBLY 3.875 Other ( De h plugs, ND equip., etc T e - .) - D-SAND LINER/LEM DETAIL _ _ _ Descri ion _ ~ ID 5025 3482 PACKER D-SAND ZXP LINER TOP PACKER 4.950 5044 3487 SBR D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 5063 3491 BUSHING D-SAND CROSSOVER BUSHING 5.5" TO 4.5" 3.950 5064 3491 PUP D-SAND PUP 3.958 5069 3493 HANGER D-SAND LEM ABOVE HOOK HANGER 3.950 5078 3495 HANGER D-SAND BAKER MOD B1 FHH INSIDE CASING 4.500 5094 3498 HANGER D-SAND BAKER MOD B1 FHH OUTSIDE CASING 4.500 5208 3516 SEAL D-SAND LEM BAKER SEAL ASSEMBLY 3.880 12155 3683 XO D-SAND CROSSOVER 4.5" TO 3.5" 3.500 12157 3683 BENTJT D-SAND BENT JOINT 2.992 12185 3684 SHnE D-SAND BAKER OPEN GUIDE SHOE 0.000 eneral Notes I l4 ~~ DATA SUBMITTAL COMPLIANCE REPORT ~i~i2oos Permit to Drill 2060490 Well Name/No. KUPARUK RIV U WSAK 1J-127L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23306-61-00 MD 12227 TVD 3685 Completion Date 7/6/2006 Completion Status 1-OIL Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type 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 'Ftgt 14048 LIS Verification ED C Lis 14048 Induction/Resistivity D Asc Directional Survey Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~I Daily History Received? N Chips Received? P~`N~- Formation Tops N Analysis Y~ Received? Comments: Open 8/22/2006 2219 12169 Open 8/22/2006 ROP, FET, Res, GR 5082 12227 Open 11/9/2006 Compliance Reviewed By: Date: ~_ Ll 1 /VIJ • 4V1Vl1lVk VL1 A1/ i •.u•.~ vu~ av av. • a.. a v .• ~.. ~.. .~ Maunder, Thomas E (DOA) __ From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPFl Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, iJ-102, 1J-127, iJ-164, 1J-180 Tom ;Jim, The LPP/SSV's on all of the West Sak DS1 E and DS'I J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following welts had been defeated; permit to drill numbers are also listed. I ~niasn't sure if yo! i +n~anted the permit to drill number for the mainbore only or the laterals as well so included both. WELL ID Permit to ®rill No. 1E-112 204-091 (MAIrJBORE), 204-092 (L1 ), 204-093 (L2) 1J-102 206-110 (MAINBORE), 206-111 (L1), 206-112 (L2) '1J-105 207-027 (fUiAIi~IBORE), ?_07-028 (L1), 207-029 (L2) r--~ 1J-'127 206-047 (MAINBORE}, 206-048 (L1 ), 206-049 (L2) 1J-160 207-015 (MAiNBORE), 207-016 (L1), 207-0'17 (L2) 1J-164 205-144 (MAINBORE}, 205-145 (L1), 205-146 {L2) 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: 1J-105 and 1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Flat Hunt /Pete Nezaticky /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 • • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-127L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,056.83' MD Window /Kickoff Survey: 5,082.00' MD (if applicable) Projected Survey: 12,227.00' 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 _/ f~v ~Q~' ~ Signed Please calf me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~s~~ o ~ ~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ T ~ ~ ~~1v~~i REPORT OF SUNDRY WELL OPERATIli~l+~~„ ~ ~~;~~, r:':~-~~~;r;,;•. L Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Ott~1'ta ;; ". '~ Prod to WINJ - Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-049 / 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23306-61 7. KB Elevation (ft): 9. Well Name and Number. RKB 121' 1J-127L2 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 Kupa~uk River Field L West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12227 feet true vertical 3685' • feet Plugs (measured) Effective Depth measured 12185' feet Junk (measured) true vertical 3683', feet Casing Length Size MD _ ND Burst Collapse Structural CONDUCTOR 121' 20" 121' 121' SURFACE 2137 10-3/4" 2258' 2216' L2 WINDOW 2' 7-5/8" 5084' 3496' INTERMEDIATE 6308' 7-5/8" 6429' 3725' D-SAND LINER 7077 4-1/2" 12155' Perforation depth: Measured depth: Alternating slotted/sol id pipe 5159' - 12119' true vertical depth: 3511' - 3682' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5056' MD. Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 482' 12. Stimulation or cement squeeze summary: - Inter als treat d d ; y `^.q~€;~~ ~_ UGC ~ ~~D~ v (measure e ) m 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 2427 4199 1 1182 339 Subsequent to operation 921 698 106 14. Attachments. 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ - WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-314 contact Bob Christensen /Bob Buchholz Printed Nam Robert D hriste sen Title Production Engineering Technician Signature Phone 659-7535 Date t ,p 6~ ~ / Form 10-404 Revised 04/2004 ~ Submit Origin OnIY/~~~ • 1J-127L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/27/06 Well shut in for Producer to Injector conversion 10/01/06 Commenced Water Injection service • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Robert Buchholz Production Engineering Technician ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-127L2 Sundry Number: 306-314 Dear Mr. Buchholz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner DATED this~`C" day of September, 2006 Encl. c~b~,, _C,~``~ • ConocoPhillips September 11, 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 • Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 _; ~~ } ~ ~- ;~ = '~ ._._ ~~'~~o Subject: Sundry Applications for Proposed Change of Well Class ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on Kuparuk well 1 Q-02B and 1 Q-02L 1. ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on West Sak wells 1J-127, 1J-127L1, 1J-127L2, 1J-184, 1J-184L1. If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Robert W. Buchholz i Attachments: 10-403 Forms rrrs ~~i3 ,~ ~~~ RECEIVE ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~,Q-~ APPLICATION FOR SUNDRY APPROVAL SEP 1 2 200p a,~~ 20 AAC 25.280 Alaska na R, r,~. r...._ ,._ 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiv~nChn ~ Other ~ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension tt11TT^dd~e~/' ~,t ',, O~ '/` ' ~ ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ `~ , _ _ ' J ~ Re-enter Suspended Well ^ ~' ` G(gsS b 9•/ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 206-049 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23306-61 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S ^ NO Q 1J-127L2 ° 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661, 25650 RKB 121' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12227 3685' 12185' ~ 3683' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 20" 121' 121'. SURFACE 2137' 10-3/4" 2258' 2216' L2 WINDOW 2' 7-5/8" 5084' 3496' INTERMEDIATE 6308' 7-5/8" 6429' 3725' D-SAND LINER 7077' 4-1/2" 12155' 3683' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Alternating slotted/solid pipe 5159' - 12119' 3511' - 3682' 4-1 /2" L-80 5056' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 482' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Sept. 29, 2006 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 Robert W. Buchholz Title: Production Engineering Technician Signature Phone 659-7535 Date Y// // ~ Commission se Onl Conditions of a r l N tif C i i th t t ti it Sundry Number: ~ "" ~'~ pp ova : o y omm ss on so a a represen a ve may w ness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: SIBS ~F~ SEP ~ 5 1006 Subsequent Form Required: ~"~~~-~ APPROVED BY • Q Approved by: COMMISSIONER THE COMMISSION Date: - ^~ Form 10-403 R ised 0 /2006 (1 ~ (_ ~ ~ ~ ~ Submit in Dupli to 1J-127L2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-127L2. This well was pre-produced fora 45 day period in order to recover oil based drilling fluids prior to putting the well on injection. Lateral 1 J-127L2 will provide pressure support for the West Sak D sands. The 10-3/4" Surface casing (2258' and / 2216' tvd) was cemented with 450 sx AS Lite followed by 130 sx DeepCrete. The 7-5/8" Intermediate casing (6429' and / 3725' tvd) was cemented with 460 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5025' and / 3482' tvd. This well also contains a Lower B sand 5-1/2" x 7-5/8" ZXP Liner Top Packer located @ 5176' and / 3519' tvd. The top of West Sak D sand was found at 5075' and / 3494' tvd. The top of West Sak B sand was found at 5357' and / 3569' tvd. The top of West Sak A sand was found at 6607' and / 3730' tvd. .~ KRU ~~»r~cr~~~llips ~,~~ska,1~~~ 1J-127L2 API: 500292330661 WeII T : PROD SSSV T e: NIPPLE Ori Com letion: 7/6/2006 Annular Fluid: Last W/O: < ~ Reference Lo : 43' RKB Ref Lo Date: <' Last Ta TD: 12227 ftKB ;:. Last Tag Date ~_ _ - _ Max Hole Angle: __ 92 d 10652 ' Casing String -ALL STRIN GS .: Descri ion Size To x :> :< ~ CONDUCTOR 20.000 0 >: SURFACE 10.750 0 PACKER (5025-5044, OD:6.550) SBR (50445063, OD:6.280) PUP (50645069, OD:4.500) .HANGER (5069-5078, OD:6.620) Perf (5159-12119) TERMEDIATE (asazs, OD:7.625, Wt:29.70) ~ ''~'! l~ I' ~. '~' ~ 't'' _ : Tubing String -TUBING 1J-127L2 4ngle @ TS: 4ngle @ TD: Rev Reason: Last Uodate: Wt Grade Thread 62.60 H-40 WELDED 45.50 L-80 BTC 29.70 L-80 BTCM 11.60 L-80 BTC Bottom ND 121 121 2258 2216 6429 3537 12155 3683 5084 3496 _ Size Top ~ Bottom r - ND ~ Wt Grade --- - - Thread _ - - - -- 4 500 0_ ~ SOS_6 ' - - - _ _ 3.490 _ 12.60 ~ _ L-80 L -- IBTM _ __ Perforations Summa - Interval -_ - ND Zone Status - Ft ~ SPF - Date T T e - ---____- Comment 5159 - 12119 3509 - 3681 WS D,WS 6960 32 7/2/2006 Slots Alternating slotted/solid pipe D,WS D,WS D Gas Lift Mandrels/Valves St MD ND Man Man T e yp V Mfr V T ype V OD Latch __ Port TRO Date Run _ Vlv Mfr Cmnt 1 2469 2395 CAMCO KBG-2-1 R GLV 1.0 BK-1 0.188 1500 7/15/2006 2 3909 3140 CAMCO KBG-2-1R -- - OV 1.0 ~ BK-1 - 0.313 0 7/15/2006 Other ( plugs, equip., etc.) -COMPLETION _ De th ND T e Descri tion ID 38 38 HANGER VETCOGRAYTUBINGHANGER 4.500 482 482 NIP CAMCO DB-6 NIPPLE w/3.875" NO GO PROFILE 3.875 4983 3472 SLEEVE-C BAKER CMD SLIDING SLEEVE w/CAMCO 3.81" DB PROFILE -CLOSED 7/14/2006 3.812 5031 3483 LOCATOR BAKER LOCATOR GBH-22 -SPACED OUT 2' ABOVE FULLY INSERTED 3.875 5033 Other - De th 3484 plugs, ND SEAL -- equip., et T e BAKER SBE SEAL ASSEMBLY ---- c.) - D-SAND LINER/LEM DETAIL __ _ -_ Descri tion 3.875 _ ID 5025 3482 PACKER ZXP LINER TOP PACKER 4.950 5044 3487 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 5063 3491 BUSHING CROSSOVER BUSHING 5.5"T04.5" 3.950 5064 3491 PUP 3.958 5069 3493 HANGER LEM ABOVE HOOK HANGER 3.950 5078 3495 HANGER BAKER MOD 61 FHH INSIDE CASING 4.500 5079 3495 HANGER LEM INSIDE HOOK HANGER 3.688 5094 3498 HANGER BAKER MOD B1 FHH OUTSIDE CASING 4.500 5208 3516 SEAL LEM BAKER SEAL ASSEMBLY 3.880 12155 3683 XO CROSSOVER 4.5" TO 3.5" 3.500 12157 3683 BENT JT 2.992 12185 3684 SHOE BAKER OPEN GUIDE SHOE 0.000 Gene[al Notes j I Date Note _ - - -- - I 7/4/2006 MULTI-LATERAL WELL: 1J-127 (A-SAND), 1J-127L1 (B-SAND), 1J-127L2 (D-SAND) TREE: VETCO GRAY! HORZ / 4-1/8" 5M i~'C:iA.NICAL INTEGRITY REPORT ~ ~ ~°`,~C.~ UD 1: _ _ _ : ~ OPER ~ FZELD +~~ ~ ~. ~~~~~ _ ~~ ALL DAT ~_ TD : ?~.. Casing ~~~~ Shoe. (,,~~~ I~ID =__~e= : Shoe: '~ `~~ ~ ~~ TVD ; lid . ~ ~ ?~ ~ ~, TV~D -.~o~~y ~~~ Pecxer ~~.~~ '~ Tom; Ser et ole S_ce ~~~~ end ; Perfs to v`= LF.r~?~=C~.y ZNTEGR?TY - PART # ~ ~'~ ~.~~ ~:,.~.; ~ ~ ~~~i Otis annulus Press Test: _~ 15 IIin ~Q min Comments. r `~'CH~NIC?_I., ZNTEGRTT`~ - PART #Z ~--~ 1~~~~~~ a ~' ~, :~ <~ 1j ',7° Cement Vol~mmes :~ r~~t. L iner CsQ '-~~~s~ DV ~~ Cwt voI to cover oe=s ~~`=~ ~~.~. `~~~ ~~>\~~ ~~~~:~ti~~ ~ c~ "°~~ 6 _ eoretical TOC ;~~~~~ ~.~~c~~~~,; ~~~ Cement Bond Log (Yes or No) ~.~~ In AOGCC File .~o~~~~ ~ ,. C3L Fvzluation, gone ebove perfs ~~~: ~~~ ~~: ~~ ~l '`~'~A "5d~`~~V< L1c^,e'~~~ w`»£ ~I\ ~ :~~, \~ i~ ~+~~s1 C:~ ~~! ~ ~G ~ C~i~`>9~~a i Proauction Log: "?'ype CONC.-LJS~ONS: Parma i 1 Par rL. ra ~~ '~®~~ `a `a3 ~ t,v luation WELL LOG TRANSMITTAL • To: State of Alaska July 27, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE:MWD Formation Evaluation Logs: 1J-127, PB1, PB2, Ll, L1 PB1 & L2, AK-MW-4376108 1 LDWG formatted CD Roin with verification listing(s). API#: 50-029-23306-00, 70, 71, 60, 72, 61. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:-~~~~- Signed: -,--.,-.".`.-~ ~~CEIVED nuG ~z 2 coos ~; Gil & Gas Cons. Con-mission Anchora9P aa~ ~ opt-, a~~ - oyf~ ~ 20~ -b~1 ~ i~ba ~- • ConocoPhillips August 10, 2006 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~ ~. _ ,- ,~ ~~ Subject: Well Completion Reports for 1 J-127, 1 J-127L1 and 1 J-127L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1J-127, 1J-127L1, 1J-127L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling ~~~~~ RT/skad V C~-. STATE OF ALASKA ` AUG 1 1 ZOO6 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORI°~~~4~`I~S' $~G~,~ns. Commissiutt ~ a~ 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _XX Pre-Produced Injector ~ 1b. Well Class: Development ^ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: July 6, 2006 • 12. Permit to Drill Number: 206-049 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: , 2006 •/~•~' 13. API Number: 50-029-23306-61 ' 4a. Location of Well (Governmental Section): Surface: 1739' FSL, 2324' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: June 26, 2006 14. Well Name and Number: 1J-127L2 ' At Top Productive Horizon: 1563' FNL, 572' FEL, Sec. 35, T11N, R10E, UM 8. KB Elevation (ft): 43' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 286' FSL, 569' FEL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): ~ 12185' MD / ~d~ ~~ West Sak Oil Pool ' ~ $ •/~-p~L 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558888 y- 5945553 Zone- 4 10. Total Depth (MD + ND): 12227' MD / 3685' ND 16. Property Designation: ADL 25661 & 25650 TPI: x- 560622 y- 5947543 Zone- 4 Total Depth: x- 560562 , - 5954671 Zone- 4 11. Depth where SSSV set: nipple @ 482' 17. Land Use Permit: ALK 471 8~ 468 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3236' MD QQ Q 21. Logs Run: -r^ !a'J Gf~ '~DZf /YJ ~ 3~7 ~i ~ ~•~/~ ~ •Q~o GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 94# K-55 43' 121' 43' 121' 42" 248 sx AS 1 10.75" 45.5# L-80 43' 2258' 43' 2216' 13.5" 45o sx AS Lite, 130 sx DeepCRETE 7-5/8" 29.7# L-80 43' 6429' 43' 3724' 9-7/8" 460 sx DeepCRETE 4.5" 12.6# L-80 5078' 12187' 3494' 3683' 6.75" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore none slotted liner from 5116'-5202', 5419'-5892', 6151'-6624', 6924'-7391', 7685'- 7982', 8284'-8748', 8950'-9460', 9675'-10064', 10275'-10751', 11001'- 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11476', 11733'-12156' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production July 29, 2006 Method of Operation (Flowing, gas lift, etc.) pre-Produced Injector- Gas Lift Oil -shares production with 1J-127 and 1J-127L1 Date of Test 8/2/2006 Hours Tested 23 hours Production for Test Period --> OIL-BBL 2694 GAS-MCF 2093 WATER-BBL 0 CHOKE SIZE 30 Bean GAS-OIL RATIO 829 Flow Tubing not available Casing Pressure 1183 Calculated 24-Hour Rate -> OIL-BBL 2709 GAS-MCF 2246 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". co~npLErloN NONE S E~I`~ AUG ~ ~ 2006 .°_? ~TO~. VE l,F,~ Form 10-407 Revised 12/2003 ~ ~ ~ ^ ~ ~ /f ~ CONTINUED ON REVERSE ~ ~~~ ~ ~ ~~ i za. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-127L2 Top West Sak 5075' 3494' West Sak D 5075' 3494' West Sak D 5670' 3521' West Sak D 7970' 3553' West Sak D 10090' 3590' Base West Sak 12227' 3685' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Name nd Tomas Title: Greater Kuoaruk Area Drillino Team Leader ~~~0 ~ ` ' C Signature __~~%~ ~~ Phone Date ~ Prepared by Sharon Allsup-Drake ~~Q ~~~/ JAS INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 S Halliburton Company Survey Report Compam~: ConocoPhillipsAlaska Inc. Date: 7/25/2006 Time: 08:37:01 Page: 1 Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 1J-127;True North Site: Kuparuk 1J Pad Vertical(TVD) Re ference: 1J-127L2: 122'.3 WeIL• 1J-127 Section (VS) Refer ence: -Well (O.OON,O.OOE;O.OOAZi) Wellpath: 1J-127L2 _ .____. - --- Survey Calculation - - _ _ - Method: PJlinimum Curvat _ --- ure Db: Oracle - _- - Field: Kuparuk River Unit _ North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 ': WeII: 1J-127 Slot Name: Well Position: +N/-S -367.81 ft Northing: 5945552.62 ft Latitude: 70 15 42.640 N +E/-W 94.82 i Position Uncertainty: 0.00 ft Easting : 558887.63 ft Longitude: ft 149 31 26.247 W -~ - Wellpath: 1J-127L2 Drilled From: 1J-127PB1 500292330661 Tie-on Depth: 5056.83 ft Current Datum: 1 J-127L2: Height 122.30 ft Above System Datum: Mean Sea Level 1 Magnetic Data: 5/15/2006 Declination: 24.09 deg Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.30 0.00 0.00 0.00 Survey Program for Definitive Wellpath ~, Date: 7/20/2006 Validated: No Version: 1 l Actual From To Survey Toolcode Tool Name i ft ft 100.00 827.00 1J-127P61 gyro (100.00-827.00) CB-GYRO-SS Camera based gyro single shot 861.59 5056.83 1 J-127PB1 (861.59- 10339.16) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5082.00 12191.66 1J-127L2 (5082.00-12191_66) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey -- _ _ - iv1D Inci 9zim I'VD Sys "IVD rti/5 E/W 111apV MapE Tool ft deg deg ft ft ft ft ft ft 41.30 0.00 0.00 41.30 -81.00 0.00 0.00 5945552.62 558887.63 TIE LINE 100.00 0.29 110.60 100.00 -22.30 -0.05 0.14 5945552.57 558887.77 CB-GYRO-SS 180.00 0.18 27.30 180.00 57.70 -0.01 0.39 5945552.61 558888.02 CB-GYRO-SS '~ 279.00 0.19 28.17 279.00 156.70 0.27 0.54 5945552.90 558888.16 CB-GYRO-SS 356.00 0.32 80.33 356.00 233.70 0.42 0.81 5945553.05 558888.43 CB-GYRO-SS ~'I 456.00 1.12 74.41 455.99 333.69 0.73 2.02 5945553.37 558889.65 CB-GYRO-SS 545.00 2.11 64.82 544.95 422.65 1.66 4.34 5945554.31 558891.96 CB-GYRO-SS 645.00 2.68 63.01 644.87 522.57 3.50 8.09 5945556.19 558895.70 CB-GYRO-SS 732.00 4.16 65.48 731.71 609.41 5.74 12.78 5945558.46 558900.36 CB-GYRO-SS 827.00 4.52 57.35 826.44 704.14 9.19 19.06 5945561.95 558906.62 CB-GYRO-SS 861.59 4.47 58.25 860.92 738.62 10.63 21.36 5945563.42 558908.90 MWD+IFR-AK-CAZ-SC 956.63 4.68 54.22 955.66 833.36 14.85 27.65 5945567.68 558915.16 MWD+IFR-AK-CAZ-SC I 1052.51 5.32 47.90 1051.17 928.87 20.11 34.12 5945573.00 558921.59 MWD+IFR-AK-CAZ-SC I ~ 1143.52 5.46 42.05 1141.78 1019.48 26.16 40.15 5945579.09 558927.58 MWD+IFR-AK-CAZ-SC 1242.54 5.14 43.96 1240.38 1118.08 32.85 46.39 5945585.83 558933.76 MWD+IFR-AK-CAZ-SC 1337.69 5.52 46.68 1335.12 1212.82 39.06 52.68 5945592.08 558940.00 MWD+IFR-AK-CAZ-SC 1432.67 5.72 51.68 1429.64 1307.34 45.13 59.71 5945598.21 558946.98 MWD+IFR-AK-CAZ-SC 1527.58 6.15 52.75 1524.04 1401.74 51.14 67.47 5945604.28 558954.69 MWD+IFR-AK-CAZ-SC 1623.19 9.13 51.40 1618.79 1496.49 58.97 77.48 5945612.19 558964.64 MWD+IFR-AK-CAZ-SC ~ 1719.82 11.37 48.41 1713.87 1591.57 70.08 90.60 5945623.40 558977.67 MWD+IFR-AK-CAZ-SC 1814.93 14.58 48.65 1806.54 1684.24 84.21 106.60 5945637.66 558993.56 MWD+IFR-AK-CAZ-SC ~~ 1906.43 16.70 50.73 1894.65 1772.35 100.14 125.42 5945653.73 559012.26 MWD+IFR-AK-CAZ-SC ~ 2000.97 20.00 51.63 1984.37 1862.07 118.78 148.62 5945672.55 559035.30 MWD+IFR-AK-CAZ-SC 2089.91 24.56 51.75 2066.65 1944.35 139.68 175.08 5945693.65 559061.59 MWD+IFR-AK-CAZ-SC 2191.50 27.30 51.80 2158.00 2035.70 167.16 209.97 5945721.40 559096.27 MWD+IFR-AK-CAZ-SC i 2218.41 28.62 51.62 2181.77 2059.47 174.98 219.87 5945729.30 559106.11 MWD+IFR-AK-CAZ-SC ~, ~ 2305.36 30.17 51.95 2257.53 2135.23 201.38 253.41 5945755.95 559139.43 MWD+IFR-AK-CAZ-SC 2399.99 33.14 51.46 2338.07 2215.77 232.16 292.37 5945787.03 559178.15 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~ou,p.uiy: ConocoPhillipsAlaska Inc. Date: 7/25/2006 Time: 08:37:01 Page: 2 Field: Ku paru k River Unit ' Co- ordinate(NE) Reference: Well: 1J-12 7, True North ~itc: Ku paru k 1J Pad Ver tical (T~'D)''Reference: 1J-127L2: 122 .3 Well: 1J -127 ticc~ iun (VS) Reference: Well (O.OON,O. OOE,O:OflAzi) Wellpath: 4J-1272 tiur vc} Calculation Method: Minimum C urv ature - Dbi-Oracle Surve~° _ __ ~iD Inc l Azim TVD __ _ S~sTVD N/S -- EIW 11apN D1apE Tool ft deg deg ft ft ft ft ft ft ', 2494.12 36 .32 52. 92 2415. 42 2293.12 265 .01 334.75 5945820 .21 559220 .26 MWD+IFR-AK-CAZ-SC 2588.99 40 .87 51 .70 2489. 55 2367.25 301 .20 381.55 5945856 .77 559266 .77 MWD+IFR-AK-CAZ-SC 2685.01 44 .88 51 .27 2559. 90 2437.60 341 .88 432.65 5945897 .84 559317 .55 MWD+IFR-AK-CAZ-SC 2777.19 48 .35 50. 17 2623. 21 2500.91 384 .30 484.48 5945940 .66 559369 .05 MWD+IFR-AK-CAZ-SC 2875.27 49 .07 48. 90 2687. 93 2565.63 432 .13 540.55 5945988 .92 559424 .73 MWD+IFR-AK-CAZ-SC 2970.01 52 .64 49. 32 2747. 73 2625.43 480 .22 596.09 5946037 .44 559479 .89 MWD+IFR-AK-CAZ-SC 3065.06 55 .99 50 .70 2803. 17 2680.87 529 .81 655.24 5946087 .48 559538 .64 MWD+IFR-AK-CAZ-SC 3161.26 61 .58 51 .77 2853. 01 2730.71 581 .28 719.38 5946139 .45 559602 .37 MWD+IFR-AK-CAZ-SC 3256.01 66 .39 51. 87 2894. 55 2772.25 633 .90 786.29 5946192 .59 559668 .86 MWD+IFR-AK-CAZ-SC 3350.89 68 .63 52. 64 2930. 85 2808.55 687 .55 855.61 5946246 .78 559737 .75 MWD+IFR-AK-CAZ-SC 3445.28 67 .66 51 .70 2965. 98 2843.68 741 .28 924.80 5946301 .04 559806 .52 MWD+IFR-AK-CAZ-SC 3539.87 68 .27 50. 73 3001. 47 2879.17 796 .21 993.15 5946356 .49 559874 .43 MWD+IFR-AK-CAZ-SC i 3635.58 67 .85 50. 45 3037. 23 2914.93 852 .57 1061.74 5946413 .38 559942 .57 i MWD+IFR-AK-CAZ-SC 3724.88 68 .12 49 .72 3070. 71 2948.41 905 .69 1125.24 5946466 .99 560005 .64 MWD+IFR-AK-CAZ-SC 3825.17 67 .76 49 .72 3108. 37 2986.07 965 .78 1196.15 5946527 .63 560076 .07 MWD+IFR-AK-CAZ-SC 3919.58 67 .52 48 .08 3144. 29 3021.99 1023 .17 1261.94 5946585 .53 560141 .41 MWD+IFR-AK-CAZ-SC 4018.04 70 .82 43 .16 3179. 32 3057.02 1087 .54 1327.65 5946650 .40 560206 .60 MWD+IFR-AK-CAZ-SC 4107.97 71 .02 43 .03 3208. 72 3086.42 1149 .60 1385.71 5946712 .91 560264 .18 MWD+IFR-AK-CAZ-SC 4207.68 71 .51 38 .01 3240. 76 3118.46 1221 .35 1447.03 5946785 .13 560324 .93 MWD+IFR-AK-CAZ-SC 4301.53 71 .62 34 .56 3270. 45 3148.15 1293 .11 1499.71 5946857 .29 560377 .04 MWD+IFR-AK-CAZ-SC 4397.30 71 .06 31 .00 3301. 10 3178.80 1369 .38 1548.83 5946933 .94 560425 .56 MWD+IFR-AK-CAZ-SC 4488.02 71 .88 28 .89 3329. 93 3207.63 1443 .91 1591.76 5947008 .79 560467 .90 MWD+IFR-AK-CAZ-SC 4584.57 71 .75 28 .39 3360. 06 3237.76 1524 .41 1635.73 5947089 .63 560511 .23 MWD+IFR-AK-CAZ-SC 4680.74 73 .93 22 .91 3388. 45 3266.15 1607 .22 1675.46 5947172 .73 560550 .31 MWD+IFR-AK-CAZ-SC ~ 4777.20 74 .14 17 .45 3415. 00 3292.70 1694 .23 1707.44 5947259 .98 560581 .60 MWD+IFR-AK-CAZ-SC ' 4872.35 73 .49 11 .09 3441. 55 3319.25 1782 .73 1729.96 5947348 .65 560603 .43 MWD+IFR-AK-CAZ-SC 4967.95 74 .60 6 .03 3467. 84 3345.54 1873 .59 1743.62 5947439 .61 560616 .38 MWD+IFR-AK-CAZ-SC 5056.83 76 .86 1 .69 3489. 76 3367.46 1959 .50 1749.40 5947525 .56 560621 .49 MWD+IFR-AK-CAZ-SC 5082.00 76 .42 1 .07 3495. 58 3373.28 1983 .99 1749.99 5947550 .04 560621 .89 MWD+IFR-AK-CAZ-SC 5120.20 78 .34 3 .04 3503. 92 3381.62 2021 .24 1751.33 5947587 .29 560622 .93 MWD+IFR-AK-CAZ-SC 5213.23 86 .08 7 .73 3516. 53 3394.23 2112 .90 1760.01 5947679 .02 560630 .89 MWD+IFR-AK-CAZ-SC 5303.81 90 .09 12 .20 3519. 56 3397.26 2202 .02 1775.67 5947768 .25 560645 .86 MWD+IFR-AK-CAZ-SC 5400.76 89 .57 10 .93 3519. 85 3397.55 2297 .00 1795.11 5947863 .37 560664 .55 MWD+IFR-AK-CAZ-SC 5494.53 89 .08 6 .94 3520. 95 3398.65 2389 .61 1809.67 5947956 .08 560678 .38 MWD+IFR-AK-CAZ-SC 5588.71 89 .89 3 .77 3521. 80 3399.50 2483 .36 1818.45 5948049 .89 560686 .43 MWD+IFR-AK-CAZ-SC 5682.36 91 .31 0 .83 3520. 82 3398.52 2576 .92 1822.21 5948143 .46 560689 .46 MWD+IFR-AK-CAZ-SC 5777.13 89 .01 356 .46 3520. 55 3398.25 2671 .63 1819.97 5948238 .14 560686 .48 MWD+IFR-AK-CAZ-SC 5871.29 86 .35 354 .49 3524. 36 3402.06 2765 .41 1812.55 5948331 .85 560678 .33 MWD+IFR-AK-CAZ-SC II 5965.68 88 .17 356 .08 3528. 88 3406.58 2859 .36 1804.80 5948425 .73 560669 .84 MWD+IFR-AK-CAZ-SC 6059.34 88 .84 356 .19 3531. 32 3409.02 2952 .78 1798.49 5948519 .09 560662 .80 MWD+IFR-AK-CAZ-SC 6152.96 89 .95 359 .00 3532. 31 3410.01 3046 .30 1794.56 5948612 .57 560658 .15 MWD+IFR-AK-CAZ-SC 6245.08 88 .83 359 .90 3533. 29 3410.99 3138 .41 1793.68 5948704 .66 560656 .54 MWD+IFR-AK-CAZ-SC 6338.64 88 .77 4 .08 3535. 25 3412.95 3231 .87 1796.93 5948798 .13 560659 .06 MWD+IFR-AK-CAZ-SC ~~, 6434.37 88 .40 1 .49 3537. 61 3415.31 3327 .45 1801.58 5948893 .74 560662 .96 MWD+IFR-AK-CAZ-SC 6528.99 89 .64 359 .93 3539. 23 3416.93 3422 .04 1802.75 5948988 .33 560663 .39 MWD+IFR-AK-CAZ-SC ~ 6621.67 88 .08 355 .90 3541. 08 3418.78 3514 .62 1799.38 5949080 .87 560659 .30 MWD+IFR-AK-CAZ-SC I 6715.38 88 .78 355 .10 3543. 64 3421.34 3608 .01 1792.03 5949174 .18 560651 .22 MWD+IFR-AK-CAZ-SC 6809.42 88 .59 354 .83 3545. 80 3423.50 3701 .66 1783.78 5949267 .76 560642 .24 MWD+IFR-AK-CAZ-SC I, 6903.47 90 .26 354 .84 3546. 75 3424.45 3795 .32 1775.31 5949361 .34 560633 .04 MWD+IFR-AK-CAZ-SC ~' 6996.17 88 .52 353 .20 3547. 73 3425.43 3887 .50 1765.66 5949453 .44 560622 .66 MWD+IFR-AK-CAZ-SC ~, 7092.31 88 .96 353 .39 3549. 85 3427.55 3982 .96 1754.43 5949548 .80 560610 .70 MWD+IFR-AK-CAZ-SC 7184.71 90 .00 356 .52 3550. 69 3428.39 4074 .99 1746.31 5949640 .75 560601 .85 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ' Company: ConocoPhillipsAlaska Ina Date: 7/25/2006 Time: 08:37:01 Page: 3 Field: Kuparu k River Unit Co-ordinatc (NE) Rcfcrencr. Well: 1J-12 7, True North Site: Ku paru k 1J Pad Vertical (TVD) Reference: 1J-127L2: 122.3 WeH: 1J -127 &ectio n (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J -127L2 Surve y Calc ulation Method: PJlinimum C urvat ure's Db: Oracle Suncv - _ __ NID Int l Azim __ 'CVD Sys TVD« N/S E/W IV1apA A~IapE Tool ', ft deg deg ft __ _ _ _ ft ft ft ft ft _ __ ' ~, 7277.43 90 .07 358.62 3550. 63 3428 .33 4167 .62 1742. 38 5949733. 34 560597. 20 MWD+IFR-AK-CAZ-SC 7372.64 91 .68 0.87 3549. 18 3426 .88 4262. 81 1741. 95 5949828. 51 560596. 03 MWD+IFR-AK-CAZ-SC 7465.81 90 .81 1.12 3547. 15 3424 .85 4355 .94 1743. 57 5949921. 64 560596. 92 MWD+IFR-AK-CAZ-SC 7557.61 89 .82 358.89 3546. 65 3424 .35 4447 .73 1743. 58 5950013. 42 560596. 21 MWD+IFR-AK-CAZ-SC 7651.50 89. 33 357.39 3547. 34 3425 .04 4541. 57 1740. 53 5950107. 22 560592. 43 MWD+IFR-AK-CAZ-SC 7743.61 90. 45 358.19 3547. 52 3425 .22 4633. 61 . 1736. 98 5950199. 22 560588. 16 MWD+IFR-AK-CAZ-SC 7836.26 88. 64 0.82 3548. 26 3425 .96 4726. 24 1736. 18 5950291. 84 560586. 63 MWD+IFR-AK-CAZ-SC 7932.59 87. 78 1.68 3551. 26 3428 .96 4822. 50 1738. 28 5950388. 10 560587. 98 MWD+IFR-AK-CAZ-SC 8025.89 86. 73 0.17 3555. 73 3433 .43 4915. 67 1739. 79 5950481. 28 560588. 76 MWD+IFR-AK-CAZ-SC 8119.73 88. 60 359.69 3559. 56 3437 .26 5009. 43 1739. 67 5950575. 02 560587. 91 MWD+IFR-AK-CAZ-SC i 8212.88 86. 97 359.59 3563. 16 3440 .86 5102 .51 1739. 09 5950668. 08 560586. 60 MWD+LFR-AK-CAZ-SC 8306.44 85 .67 358.15 3569. 16 3446 .86 5195 .85 1737. 25 5950761. 40 560584. 03 MWD+IFR-AK-CAZ-SC 8400.46 86 .92 2.94 3575. 24 3452 .94 5289 .64 1738. 14 5950855. 18 560584. 19 MWD+IFR-AK-CAZ-SC , 8494.54 90 .15 6.14 3577. 65 3455 .35 5383 .37 1745. 58 5950948. 96 560590. 90 MWD+IFR-AK-CAZ-SC 'I ~I 8588.73 90 .44 3.66 3577. 16 3454 .86 5477 .21 1753. 63 5951042. 85 560598. 21 MWD+IFR-AK-CAZ=SC I I, 8682.74 90 .62 358.56 3576. 29 3453 .99 5571 .16 1755. 45 5951136. 81 560599. 29 MWD+IFR-AK-CAZ-SC 8776.20 88 .01 352.25 3577. 41 3455 .11 5664 .26 1747. 97 5951229. 83 560591. 09 MWD+IFR-AK-CAZ-SC '~ 8870.62 88 .09 356.89 3580. 62 3458 .32 5758 .18 1739. 04 5951323. 67 560581. 42 MWD+IFR-AK-CAZ-SC ~, 8963.10 88 .90 359.83 3583. 05 3460 .75 5850 .58 1736. 40 5951416. 03 560578. 06 MWD+IFR-AK-CAZ-SC 9058.03 91 .50 2.15 3582. 72 3460 .42 5945 .48 1738. 04 5951510. 94 560578. 95 MWD+IFR-AK-CAZ-SC 9151.86 90 .56 2.06 3581. 04 3458 .74 6039. 23 1741. 48 5951604. 70 560581. 67 MWD+IFR-AK-CAZ-SC 9243.92 90 .75 359.90 3579. 98 3457 .68 6131. 26 1743. 06 5951696. 74 560582. 52 MWD+IFR-AK-CAZ-SC 9339.69 88 .76 359.81 3580. 39 3458 .09 6227 .03 1742. 81 5951792. 49 560581. 53 MWD+IFR-AK-CAZ-SC ' 9432.74 88. 77 1.86 3582. 40 3460 .10 6320. 04 1744. 17 5951885. 50 560582. 16 MWD+IFR-AK-CAZ-SC 9526.84 89 .52 2.57 3583. 80 3461 .50 6414. 06 1747. 81 5951979. 53 560585. 06 MWD+IFR-AK-CAZ-SC ~I 9620.51 90. 44 359.78 3583. 83 3461 .53 6507. 70 1749. 73 5952073. 18 560586. 25 MWD+IFR-AK-CAZ-SC 9713.68 89. 38 356.63 3583. 98 3461 .68 6600. 81 1746. 81 5952166. 25 560582. 60 MWD+IFR-AK-CAZ-SC ~, 9808.37 89. 20 357.04 3585. 15 3462 .85 6695. 35 1741. 58 5952260. 74 560576. 64 MWD+IFR-AK-CAZ-SC ~~ 9902.41 88. 15 356.07 3587. 33 3465 .03 6789. 19 1735. 93 5952354. 53 560570. 25 MWD+IFR-AK-CAZ-SC 9995.58 89. 83 354.74 3588. 97 3466 .67 6882. 04 1728. 47 5952447. 31 560562. 07 MWD+IFR-AK-CAZ-SC 10087.53 89. 26 353.47 3589. 70 3467 .40 6973. 50 1719. 03 5952538. 68 560551. 91 MWD+IFR-AK-CAZ-SC ~ 10182.50 86. 34 351.86 3593. 35 3471 .05 7067 .61 1706. 91 5952632. 68 560539. 06 MWD+IFR-AK-CAZ-SC .10276.65 85 .55 353.97 3600. 01 3477 .71 7160 .80 1695. 33 5952725. 77 560526. 75 MWD+IFR-AK-CAZ-SC 10370.24 84 .50 357.70 3608. 12 3485 .82 7253 .77 1688. 56 5952818. 68 560519. 25 MWD+IFR-AK-CAZ-SC ', 10463.66 86 .32 3.81 3615. 61 3493 .31 7346 .84 1689. 79 5952911. 74 560519. 76 MWD+IFR-AK-CAZ-SC '~ 10557.65 90 .53 4.62 3618. 19 3495 .89 7440 .52 1696. 69 5953005. 46 560525. 93 MWD+IFR-AK-CAZ-SC 10651.69 91 .99 5.06 3616. 12 3493 .82 7534 .20 1704. 63 5953099. 19 560533. 13 MWD+IFR-AK-CAZ-SC 10745.93 89 .44 3.43 3614. 95 3492 .65 7628 .16 1711. 60 5953193. 20 560539. 36 MWD+IFR-AK-CAZ-SC 10839.99 90 .14 3.40 3615. 29 3492 .99 7722. 05 1717. 20 5953287. 12 560544. 23 MWD+IFR-AK-CAZ-SC I 10933.58 88 .08 1.94 3616. 74 3494 .44 7815. 52 1721. 56 5953380. 61 560547. 86 MWD+IFR-AK-CAZ-SC ii ' 11027.09 86 .41 0.25 3621. 24 3498 .94 7908. 90 1723. 35 5953473. 99 560548. 92 MWD+IFR-AK-CAZ-SC ~~ 11121.24 86 .98 359.30 3626. 67 3504 .37 8002. 89 1722. 98 5953567. 97 560547. 81 MWD+IFR-AK-CAZ-SC ~~ 11214.84 85 .92 0.23 3632. 46 3510 .16 8096. 31 1722. 60 5953661. 37 560546. 70 MWD+IFR-AK-CAZ-SC 11308.75 I 90 .78 2.47 3635. 17 3512 .87 8190. 12 1724. 81 5953755. 19 560548. 18 MWD+IFR-AK-CAZ-SC ! 11402.71 88 .51 4.87 3635. 75 3513 .45 8283. 87 1730. 82 5953848. 98 560553. 46 MWD+IFR-AK-CAZ-SC 11496.38 86. 04 2.30 3640. 20 3517 .90 8377. 24 1736. 67 5953942. 38 560558. 58 MWD+IFR-AK-CAZ-SC 11590.23 84. 37 1.07 3648. 05 3525 .75 8470. 71 1739. 42 5954035. 86 560560. 60 MWD+IFR-AK-CAZ-SC ' 11684.36 86. 62 1.02 3655. 44 3533 .14 8564. 53 1741. 14 5954129. 68 560561. 57 MWD+IFR-AK-CAZ-SC 11778.43 86. 73 1.07 3660. 90 3538 .60 8658. 43 1742. 85 5954223. 58 560562. 55 MWD+IFR-AK-CAZ-SC 11872.35 88. 47 0.33 3664. 83 3542 .53 8752. 25 1743. 99 5954317. 40 560562. 96 MWD+IFR-AK-CAZ-SC 11965.52 84. 11 0.12 3670. 86 3548 .56 8845. 20 1744. 36 5954410. 34 560562. 60 MWD+IFR-AK-CAZ-SC 12060.25 86. 56 0.37 3678. 56 3556 .26 8939. 61 1744. 76 5954504. 74 560562. 27 MWD+IFR-AK-CAZ-SC 12153.59 88 .35 0.67 3682. 71 3560 .41 9032 .85 1745. 61 5954597. 98 560562. 39 MWD+IFR-AK-CAZ-SC 1 Halliburton Company, Survey Report Company: ConocoPhiilips Alaska Inc. Date: 7/2512006 'l'ime: 08:37:01 Page: 4 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-127, True North Si[e: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-127L2: 122.3 Well: 1J-127 Section (VS) Reference: Well (O;~ON,O.OOE,O.OOAzi) ~'4'elipatln 1J-127E_2 Survey Calculation IVlethod: Minimum Curvature 1)b: Oracle Survey ____ rID Incl Azim 'I'VD Sys TVI) V/S E/VV MapV NIapE Tool ft deg deg ft ft ft ft ft ft ~ 12191.66 88.15 0.37 3683.87 3561.57 9070.90 1745.96 5954636.03 560562.43 MWD+IFR-AK-CAZ-SC ~ 12227.00 88.15 0.37 3685.01 3562.71 9106.22 1746.18 5954671.34 560562.39 PROJECTED to TD ~onocoPhi[ips Time Lo Summa Wethfew tNeb Repcsrting Time Logs Date From To Dur S. De th E Depth Phase Code Subcode T COM 05/11/2006 00:00 06:00 __ 6.00 _ MIRU MOVE RURD P Prepare f/ move to 1J Pad: Move the rock washer away from rig and stage on 2T pad out of way. Finishing cleaning pits. Jacked up cantilever support legs. Secure pipe shed. Secure stairs and landings. Secure beaver slide. Skid rig floor. Secure top drive to stand on rig floor. Break apart FMC 16" speed head f/ DSA (16" x 21-1/4") and 21-1/4" "T". Clean cellar area around well 2T-40. Pickup Handi-berm and store. Blew down steam and water lines. 06:00 09:30 3.50 MIRU MOVE RURD P Continue preparing to move f/ 2T-40 to 1J -127. Change oil filters in rig unit movin s stem h draulics. 09:30 09:45 0.25 MIRU MOVE SFTY P Pre job safety meeting on moving rig sub and its off of well 2T-40. 09:45 12:00 2.25 MIRU MOVE MOB. P Move rig module and pit module off of well 2T-40 and off of mattin boards. 12:00 14:00 2.00 MIRU MOVE OTHR P Load matting boards on truck, haul to 1J. Pickup herculite. Clean up around wel(2T-40. 14:00 18:00 4.00 MIRU MOVE MOB P Move rig sub and pit module off 2T pad towards 2A pad. Moved rig module to within 3/8 of a mile of 2A with pits to within 1/2 mile of 2A pad. (Note: 2T to 2A = 1.8 miles . 18:00 18:30. 0.50 MIRU MOVE SFTY P Crew change. PJSM on moving rig. 18:30 20:15 1.75 MIRU MOVE MOB P Move Rig module to 2A pad. Problem developed w/ moving system of Pit module, unable to move. Pit Module is .5 miles f/ 2A ad. 20:15 20:45 0.50 MIRU MOVE . MOB P Move drilling module f/ entrance of 2A ad toward the exit of 2A ad. 20:45 00:00 3.25 MIRU MOVE RGRP T Working to troubleshoot and fix problem with moving system of Pit module. Doing preventative maint checking of drilling module moving s stem. 05/12/2006 00:00 07:00. 7.00 MIRU MOVE RGRP T Working on Pit module moving system right rear hydraulic brake clutches. Module is .5 miles f/ 2A pad on the road f/ 2T to 2A. 07:00 09:30 2.50 MIRU MOVE MOB P Travel .5 miles w/Pit module to arrive @ 2A pad. Total miles moved is 1.9 miles. 09:30 15:00 5.50 MIRU MOVE MOB P Leave 2A pad w/ both the rig module and the pit module, travel to 2B pad. Total miles moved is 4.4 miles. ~~ge 1 of II7 -- _ Time Logs - - - - _ -- Date _ From To Dur S.~th E. Depth Phase Code Subcode T COM_ - - - - - - - - 05/12/2006 15:00 18:30 3.50 MIRU MOVE MOB P Check tires on module. Crew change. 18:30 20:00 1.50 MIRU MOVE MOB P Leave 2B pad w/ both the Rig module and the pit module. Arrive @CPF 2 @ 2000 hrs. Tota! miles moved is 6.9 miles. 20:00 20:30 0.50 MIRU MOVE MOB P Travel around CPF 2 with both. modules. 20:30 21:15 0.75 MIRU MOVE MOB P Check both modules. 21:15 00:00 2.75 MIRU MOVE MOB P Leave CPF 2, moving both modules. At midnight both modules @ 2 Z pad travelin towards Oliktok/S ine "Y". 05/13/2006 00:00 02:00 2.00 MIRU MOVE MOB P Continue moving both Rig module and Pit module f/ 2Z pad towards Oliktok/Spine "Y". Arrive @ "Y" @ 0200 hrs. Total miles moved 10.9 miles. 02:00 03:00 1.00 MIRU MOVE MOB P Check tires and equipment. Let traffic et around. 03:00 04:30 1.50 MIRU MOVE MOB P Move both Rig module and Pit module f/ Oliktok/Spine "Y" towards 1J pad. Move to Hill @ 1 R road. Attempt to climb up hill twice. Abort effort. Call Peak cats to help assist. Modules are not blockin traffic. 04:30 08:30 4.00 MIRU MOVE WOEQ T Waiting on Peak to assist with 2 cats to climb up hill @ Spine/1 R. Check equipemnt while waiting on equipment. Crew Chan e. 08:30 10:00 1.50 MIRU MOVE OTHR T OfFload (2) cats, connect to front of Rig module. Proceed to help get rig up Hill @ Spine/1 R road. Continue to move sub w/ cats to 1A access. 10:00 10:30 0.50 MIRU MOVE MOB P Traffic moving around modules. Prepare to move Pit module with out hel f/ cats. 10:30 11:30 1.00 MIRU MOVE MOB P Maneuver Pit module uphill by its own power without help f/ cats and continue to 1A access. 11:30 12:30 1.00 MIRU MOVE MOB P Prepare to move both modules f/ 1A acess/S ine road towards CPF 1. 12:30 17:30 5.00 MIRU MOVE MOB P Move both modules f/ 1A toward 1J pad. Off Spine road / 1 D pad @ 1730 hrs. 17:30 18:30 1.00 MIRU MOVE MOB P Move both modules around to back side of road around 1 D ad. 18:30 20:00 1.50 MIRU MOVE MOB P Wait on APC toolhouse truck to come out of 1J pad. Crew change. Prep both modules f/ last 3.2 miles of move to 1J-127 well 20:00 00:00 4.00 MIRU MOVE MOB P Move from 1D road onto 1J road. Travel with both modules to 1J pad. Within 1/2 mile of 1J pad, which is .7 mile f/ well midni ht 5/13/2006. PagQ 2 of ~7 Time. L~----__- _ _ S . e,th E. De th Date From To Dur C~M Code.... Suhcede T Phase - - --- 05/14/2006 00:00 00:30 0.50 _ _ _ MIRU MOVE MOB _ P Continue moving Rig sub module and Pit module to 1J pad. On pad with both midni ht thirt . 00:30 01:00 0.50 MIRU MOVE MOB P Move down pad past Doyon rig 141 cam with both ri and it module. 01:00 02:30 1.50 MIRU MOVE MOB P Move drilling module onto mats and re are to move over well 1J-127. 02:30 03:45 1.25 MIRU MOVE PSIT P Maneuvering drilling module to center over well 1 J-127. 03:45 04:30 0.75. MIRU MOVE MOB P Preparing to move pit module. Lower supports feet f/ cantilever. Close cellar doors. 04:30 05`30 1.00 MIRU MOVE SKID P Skid rig into drilling position. Start moving Pit module towards matting boards. 05:30 09:30 4.00 MIRU MOVE MOB P Moving pit module to mat up w/ drilling module. Start up 3 MBTU heater to warm up cellar area. Repair hose leak on Pit moving system. Install (2 bolts) f/ 21-1/4" "T" to Vetco Gray Quick connect adapter. Peak trucks leaving Deaadhorse @ 0600 hrs to arrive @ 2T pad to move shop, rockwasher, camp and chan a house. 09:30 09:45 0.25 MIRU MOVE SFTY P PJSM on NU Diverter system. Continue working to get Pit module into ostion. 09:45 10:15 0.50 MIRU MOVE PSIT P Position Pit module to Drilling module and set down @ 1015 hrs. Peak leaving 2T pad @ 1000 hrs w/ camp, sho and rockwasher. 10:15 12:00 1.75 MIRU MOVE RURD P Working on NU of diverter and beaver slide, Lay out herculite f/ rockwasher. Begin hooking up steam, water, air @ 0945 hrs. 12:00 14:30 2.50 MIRU MOVE RURD P Continue rigging up. Connect flowline between its and ri . 14:30 18:00 3.50 MIRU MOVE RURD P Peak set rockwasher in place. Rigging up lines, setting stairs, setting tanks, install handiberm. Still rigging up around rig and fixing beaver slide, Rig acce ted 1800 hrs on 5/ 14/2006 18:00 21:00 3.00 121 121 MIRU MOVE RURD P Berm around rig and rock washer. Weld up beaver slide and repair door in dog house. Install all landings around cuttings tank and rig entrys. Remove steam loops f/inside of cuttings tanks. Clean pump room and replace 3" butterfl valve in um room. 21:00 00:00 3.00 121 121 MIRU MOVE RURD P PU riser and check measurements f/ flow line. Looked good. MU riser and flowline. Trimmed herculite around rig. Install blind flange on kill line and shut 3" demco kill line. Install all plugs in um s. F'~c e 3 ~f S7 f Time L~ -. -- - _ I '.Date _ From To --- Dur - S e th E. De th Phase Code - Subcode T COM,. _ _ 05/15/2006 00:00 03:00 3.00 121 121 SURFA DRILL OTHR P Fitted plates around riser and install herculite around riser to prevent leaks to cellar. Prepare pits (replace valve in pits) to take on water. Hook up cellar alarm and cellar pump. Hooke up Hyd lines f/ accumulator to knife valve and annular. Pressured up hydraulic system of accumulator, ready to function test. Start loading 180 joints of Weatherford 5" drill pipe into pipe shed. Will follow w/ 20 joints of 5" Weatherford HWDP. 03:00 06:00 .3.00 121 121 SURFA DRILL OTHR P Mixing spud mud. Wlf mix 800 bbls. Changing top drive f/ 4" XT-39 to 4-1/2" IF. Continue loading 5" drill pipe into i e shed. 06:00 10:00 4.00 121 121 SURFA DRILL OTHR P Remove 4" equipment from rig floor. PU 5" equipmet while rigging up for 5" drill i e. 10:00 12:00 2.00 121 121 SURFA DRILL OTHR P . Continue rigging up 16" diverter lines. RU containment. PU BHA # 1 in pipe shed. 12:00 14:15 2.25 121 121 SURFA DRILL OTHR P Continue rigging up to PU 5" drill pipe. Clean up tools and equipment. Work on housekee in . 14:15 14:30 0.25 121 121 SURFA DRILL SFTY P PJSM on picking up 5" drill pipe, standin .back in derrick. 14:30 18:00 3.50 121 121 SURFA DRILL PULD P PU Weatherford 5" drill pipe from pipe shed, torque up and stand back in derrick. Rabbit dp w/ 2.91" rabbit. A total of 26 stands picked up @ 1800 hrs 18:00 22:00 4.00 121 121 SURFA DRILL PULD P Continue PU Weatherford 5"drill pipe from pipe shed, torque up and stand back in derrick. Rabbit dp w/ 2.91" rabbit. A total of 46 stands picked up 2200 hrs 22:00 23:30 1.50 121 121 SURFA RIGMN RGRP T Clean up and repair leak on hyd hose on EZ-Torque. 1 quart spill into secondary containment reported to securit 2145 hrs. 23:30 00:00 0.50 121 121 SURFA DRILL PULD P Continue PU Weatherford 5"drill pipe from pipe shed, torque up and stand back in derrick. Rabbit dp w/ 2.91" rabbit. A total of 55 stands picked up midni ht. 05/16/2006 00:00 03:30 3.50 121 121 SURFA DRILL PULD P Finish PU Weatherford 5" dp and stand back in derrick. Total of 60 stands of 5" plus 20 jts of Weatherford 5" HWDP. and Dail 'ars. 03:30 04:30 1.00 121 121 SURFA DRILL PULD T UD jars due to damage on lower bumper caused by hanging up in well head while POOH to stand back. 04:30 06:00 1.50 121 121 SURFA DRILL PULD P PU new set ofjars, make up with 2 jts of HWDP. PU 3 flex 8" nm drill collars. Stand back in derrick. ;gage 4 of 87 Time Logs Date From To _ Dur S eeth E De th Phase_ Code SubcocJe T COrv9._ ___ 05/16/2006 06:00 07:00 1.00 121 121 SURFA DRILL PULD P PU to floor Sperry Sun MWD tool. Break and change choke in pressure drop sub f/ 28 to 32. Inspect tool joints and MU hand . UD in i e shed. 07:00 09:00 2.00 121 121 SURFA RIGMN SVRG P Service Rig. Raise mud bucket line. 09:00 09:15 0.25 121 121 SURFA DRILL SFTY P PJSM on diverter drill. 09:15 10:15 1.00 121 121 SURFA WELCT BOPE P . Held diverter drill. Function tested diverter and accumulator. 10:15 10:30 0.25 121 121 SURFA DRILL SFTY P PJSM on PU/MU Sperry Sun Gyro. 10:30 11:15 0.75 121 121 SURFA DRILL RURD P RU Sperry Sun Gyro. 11:15 11:30 0.25 121 121 SURFA DRILL SFTY P PJSM on PU/MU Sperry Sun BHA #1. 11:30 12:00 0.50 121 121 SURFA DRILL PULD P PU motor, bit and MWD. 12:00 12:30 0.50 121 121 SURFA DRILL OTHR P Orient MWD. 12:30 13:45 1.25 121 121 SURFA DRILL OTHR P PU UBHO sub and crossovers to rig floor. Work on Hi-Line ower hook u . 13:45 14:30 0.75 121 121 SURFA DRILL OTHR P Install top drive bell guide f/ 5" drill i e. 14:30 15:30 1.00 121 121 SURFA DRILL CIRC P Rig up to fill hole. 40 spm. watching f! leaks. 40 bbls to fill hole. Swap to Hi Line ower. 15:30 18:00 2.50 121 201 SURFA DRILL DRLG P Drill 13-1/2" surface hole f/ 121' to 201'. WOB = 5-10k. ,Pump 500-545 gpm w/ 990 psi. Mud Mtr rpm 130 to 142. Rot rpm 80. Torque on bottom 2-4k ft Ib, torque off bottom 2-3k ft Ib. PU wt 85k, SO wt 88k. Rot wt 85k. 18:00 18:30 0.50. 201 255 SURFA DRILL DRLG P Drill 13-1 /2" surface hole f/ 201' to 255'. WOB = 5-10k. ,Pump 470 gpm w/ 620 psi. Mud Mtr rpm 130 to 142. Rot rpm 50. Torque on bottom 2-4k ft Ib, torque off bottom 2-3k ft Ib. MW 8. 8ppg, vis 350. PU wt 85k, SO wt 88k. Rot wt 88k. 18:30 19:00 0.50 255 255 SURFA DRILL TRIP P POOH, inspect bit. , 19:00 19:30 0.50 255 255 SURFA DRILL TRIP P Trip in hole to 255' (PU stand of 8" NM flex collars and stand of 5" HWDP w/ jars). Establish circ, ready to drill ahead. 19:30 20:30 1.00 255 263 SURFA DRILL DRLG P Drill 13-1/2" surface hole f/ 255' to 263'. WOB = 4k. ,Pump 544 gpm w/ 890 psi. Mud Mtr rpm 141. Rot rpm 90. Torque on bottom 2k ft Ib, torque off bottom 1.5k ft Ib. MW 8. 8ppg, vis 350. PU wt 95k, SO wt 100k: Rot wt 100k. 20:30 21:00 0.50 263 263 SURFA DRILL SRVY P Run Sperry Sun gyro @ 263.23', inclination = .25 deg, asimuth = 110.6 Note: previous gyro's were run @ 120' and180'. Para a of 87 __ Time Logs -- --- S epth E Death Phase ..Cede Subcode T FfGfTI To Dur Date ~QM _ _ __ __ 05/16/2006 _ 21:00 00:00 __ 3.00 263 446 SURFA DRILL DRLG P Drill 13-1/2" surface hole f/ 263' to 446' (TVD 446). WOB 8-10k. ,Pump 604 gpm w/ 1150 psi. Mud Mtr rpm 157. Rot rpm 80. Torque on bottom 2k ft Ib, torque off bottom 1.5k ft Ib. MW 8. 8ppg, vis 350. PU wt 102k, SO wt 106k. Rot wt 105k. Total hrs on bit = 4.43 hrs, total hrs on 'ars = 4.43 hrs. 05/17/2006 00:00 00:30 0.50 446 446 SURFA DRILL SRVY P Run Sperry Sun gyro survey. Survey depth 437.9' MD. Inclination 1.12 deg, asmuith 74.41 de . 00:30 01:00 0.50 446 446 SURFA DRILL OTHR P Pressure test surface mud lines to upper kelly valve to 3500 psi. Visual walk down on lines with no visual leaks. 01:00 03:00 2.00 446 632 SURFA DRILL DDRL P Directional Drill 13-1/2" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.50 deg bend from 446' - 632' (186') (TVD = ???'). ART = .78 HRS, AST = .89 HRS. Total hrs on bit = 6.1 hrs., Total hrs on jars = 6.1 hrs, 5-10k WOB, 80 rpm's, 157- 150 mtr rpm, 604-575 gpm w/ 8.8 ppg MW, on bottom press 1452-1110 psi, off bottom press 1000-1350 psi, on bottom torque 2k ft/Ib, off bottom torque 1.5k ft/ Ib, PU wt 102-108k, SO wt 106-111 k, Rot wt 105-110k. 03:00 03:30 0.50 632 632 SURFA DRILL SRVY P Run Sperry Sun gyro survey. Survey depth 627' MD (TVD 545'). Inclination 2.11 de ,asmuith 64.82 de . 03:30 06:00 2.50 632 814 - SURFA DRILL DDRL P Directional Drill 13-1/2" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.50 deg bend from 632' - 814' (186') (TVD = 810'). ART = .92 HRS, AST = .77 HRS. Total hrs on bit = 7.79 hrs., Total hrs on jars = 7.79 hrs, 10-20k WOB, 90 rpm's, 164- 160 mtr rpm, 630-616 gpm w/ 8.8 ppg MW, on bottom press 1452-1560 psi, off bottom press 1350-1503 psi, on bottom torque 2-5k ft/Ib, off bottom torque 1.5k ft/ Ib, PU wt 108-120k, SO wt 111-120k, Rot wt 105-120k. 06:00 08:00 2.00 814 908 SURFA DRILL DDRL P Directional Drill 13-1/2" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.50 deg bend from .814' - 908' (94') (TVD = 907'). ART = .57 HRS, AST = .16 HRS. Total hrs on bit = 8.52 hrs., Total hrs on jars = 8.52 hrs, 10-20k WOB, 90 rpm's, 163 mtr rpm, 627 gpm w/ 9.1 ppg MW, on bottom press 1570 psi, off bottom press 1550 psi, on bottom torque 4k ft/Ib, off bottom torque 2-4k ft/ Ib, PU wt 125k, SO wt 125k, Rot wt 122k. Pac~^~ 6 crf P7 __ Time Logs ~ _ _ Date From To Dur _5. [?epth E._Depth Phase Ccde _Subcade T COM __ __ _ _ 05/17/2006 08:00 08:30 0.50 908 908 SURFA DRILL SRVY P Run Sperry Sun gyro survey. 08:30 12:00 3.50 908 1,196 SURFA DRILL DDRL P Directional Drill 13-1/2" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.50 deg bend from 908' to 1196'(288') (TVD = 1193'). ART = 1.74 hrs, AST = .54 hrs. Total hrs on bit = 10.8 hrs., Total hrs on jars = 10.8 hrs, 10-20k WOB, 90 rpm's, 163-162 mtr rpm, 627-623 gpm w/ 9.1 ppg MW, on bottom press 1570- 1680 psi, off bottom press 1550- 1530 psi, on bottom torque 4-8k ft/Ib, off bottom torque 2-4k ft/ Ib, PU wt 125-128k, SO wt 125-130k, Rot wt 122-128k. 12:00 15:15 3.25 1,196. 1,577 SURFA DRILL DDRL P Directional Drill 13-1l2" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.50 deg bend from 1196' to 1577'(381') (TVD = 1573'). ART = 2.28 hrs, AST =0.0 hrs. Total hrs on bit = 13.08 hrs., Total hrs on jars = ??? hrs, 10-20k WOB, 90 rpm's, 163-169 mtr rpm, 625-651 gpm w/ 9.1 ppg MW, on bottom press 1700-1850 psi, off bottom press 1570-1680 psi, on bottom torque 4-8k ft/Ib, off bottom torque 4k ft/ Ib, PU wt 130-132k, SO wt 130-135k, Rot wt 130-135k. 15:15 15:30 0.25 1,577 1,577 SURFA DRILL SFTY P PJSM on rigging down Sperry Sun ro unit. 15:30 16:00 0.50 1,577 1,577 SURFA DRILL RURD P Rig down Sperry Sun gyro unit. 16:00 1.8:00 2.00 1,577 1,755 SURFA DRILL DDRL P Directional Drill 13-1/2" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.50 deg bend from 1577' to 1755'(178') (TVD = 1748'). ART = .47 hrs, AST =1.12 hrs. Total hrs on bit = 14.67 hrs., Total hrs on jars = 14.67 hrs, 10-20k WOB, 90 rpm's, 168 mtr rpm, 645 gpm w/ 9.1 ppg MW, on bottom press 1820-1780 psi, off bottom press 1680-1650 psi, on bottom torque 6-8k ft/Ib, off bottom torque 5-6k ft/ Ib, PU wt 140k, SO wt 135-138k, Rot wt 135-140k. Fagg T rrf 87 Time Lis -- - --- - _ :Date Fro m To D_u_r S __E~ E Depth Phase _ -.Cade,, _Subcede T COM __ _ _ 05/17/2006 _. 18:00 00:00 6.00 1,755 2,171 SURFA DRILL DDRL P Directional Drill 13-1/2" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.50 deg bend from 1755' to 2171'(416') (TVD = 2137'). ART = 1.67 hrs, AST = 2.01 hrs. Total hrs on bit = 18.35 hrs., Total hrs on jars = 18.35 hrs, 10-20k WOB, 90 rpm's, 168 mtr rpm, 645 gpm w/ 9.1 ppg MW, on bottom press 1700-1800 psi, off bottom press 1650-1670 psi, on bottom torque 2-8k ft/Ib, off bottom torque 2-6k ft/ Ib, PU wt 140-150k, SO wt 138-145k, Rot wt 140-151 k. 05/18/2006 00:00 01:30 1.50 2,171 2,268 SURFA DRILL DDRL P Directional Drill 13-1/2" surface hole w/ 8" Sperry drill 4/5 lobe - 5.3 stage mtr w/ 1.50 deg bend from 2171' to 2268'(97') (TVD = 2224'). ART = 0.0 hrs, AST = .85 hrs. Total hrs on bit = 19.2 hrs., Total hrs on jars = 19.2 hrs, 10-20k WOB, 90 rpm's, 159- 162 mtr rpm, 611-625 gpm w/ 9.1 ppg MW, on bottom press 1760-1840 psi, off bottom press 1660-1690 psi, on bottom torque 2-8k ft/Ib, off bottom torque 2-6k ft/ Ib, PU wt 150-152k, SO wt 145-146k, Rot wt 151 k. 01:30 04:30 3.00 2,268 2,268 SURFA DRILL CIRC P Circulate and recip and rotate pipe while circ to clean hole prior to short trip @ TD of 2268'. Work pipe 90'. Irc 650 gpm w/ 1800 psi, 90 rpm w/ 3-4k ftllb for ue. 04:30 06:00 1.50 2,268 650 SURFA DRILL TRIP P Visual flow check,-0K. POOH f/ 2268' to 650' @ 0600 hrs. Monitoring~lling hole using trip tank. 25k overpull @ base of permafrost. Another tight spot @ 770' to 750'. Pull 25k over and swab a little. All other, lookin ood. D6:00 06:30 0.50 650 476 SURFA DRILL TRIP P Continue POOH f/ 650to 476'. 06:30 09:00 2.50 476 2,268 SURFA DRILL TRIP P RIH f/ 476'. Fill pipe @ 1290'. Continue RIH, establish circ, cirGrotate last 90' down to 2268'. No roblems, no fill. 09:00 10:45 1.75 2,268 2,268 SURFA DRILL CIRC P Circ and conditiion mud and hole f/ 10-3/4" casing. 483 gpm w/ 1050 psi, 90 rpm w/ 6-8k ft/Ib torque. Gas 12-24 units. 10:45 12:00 1.25 2,268 1,293 SURFA DRILL TRIP P UD single, POOH to 2145'. Survey, pump dry job, continue POOH to 1293'. 12:00 13:00 1.00 1,293 817 SURFA DRILL TRIP P Continue POOH to 5" HWDP @ 817'. 13:00 13:30 0.50 817 162 SURFA DRILL TRIP P Stand back 6 stands 5" HWDP, UD jars, PU single and stand back last stand 5" HWDP 13:30 14:30 1.00 162 0 SURFA DRILL PULD P UD BHA and break off bit. Pa~}2 3 of 87 - -- - - -- Time Loys .Date Fron; To Dur S_ ~e th E_De th-Phase _ Code Subcode T COM 05/18/2006 14:30 15:00 0.50 0 0 SURFA DRILL OTHR P Clean and clear rig floor. 15:00 15:15 0.25 0 0 SURFA CASIN( SFTY P PJSM on running 10-3/4" surface casin 15:15 18:00 2.75 0 0 SURFA CAS1N( RURD P RU GBR casing tools to run 10-3/4" casin . 18:00 19:00 1.00 0 0 SURFA CASINC OTHR P PU landing joint, MU to Vetco Gray hanger. RIH and dummy run to load shoulder. POOH. Remove hanger f/ landing joint. UD landing joint into cellar. 19:00 19:30 0.50 0 0 SURFA CASIN( SFTY P Held PJSM on running 10-3/4" casing 19:30 23:30 4.00 0 0 SURFA CASIN( RNCS P PU/MU 10-3/4 Weatherford shoe joint , threadlock joint, Weatherford Float collarjoint,followw/totalofb1 more joints of casing in hole, then Vetco gray hanger and landing joint. Land on hanger w/ shoe @ 2257.68' PU wt 170K, SO wt 155k. Blocks 75k. 23:30 23:45 0.25 0 0 SURFA CASIN( RURD P R/D GBR fillup tool 23:45 00:00 0.25 0 0 SURFA CEMEf~ RURD P RU Dowell cement head. 05/19/2006 00:00 00:30 0.50 2,258 2,258 SURFA CEME~ RURD P RU circulating lines to circ casing prior to cement 'ob. 00:30 02:00 1.50 2,258 2,258 SURFA CEMEI~ CIRC P Circulate prior to cement job. Start w/ 4.5 bpm w/ 200. psi. Initial PU wt 170k., SO wt 155k. Stage pumps up after 100 bbls pumped to 6 bpm w/ 170 psi. After 260 bbls pumped increase rate to 7 bpm w/ 200 psi. After 500 bbls pumped stage up to 7.5 bpm w/ 180 psi. Reciprocated pipe 30 stroke 6 ft er min. 02:00 02:45 0.75 2,258 2,258 SURFA CEME~ SFEQ P After pumping 570 bbs, increased rate to 8 bpm w/ 200 psi. Circulated a total of 945 bbls. Final circ pressure @ 8 bpm w/ 190 psi. Final PU wt 178k, SO wt 160k. PJSM w/drilling crew and Dowell and APC vac truck drivers while continuing to circ prior to cement job. Continue reciprocating pipe 30' stroke @ 6 feet per min. Initial mud properties before cementing: 9.1 ppg, vis 150, PV 20/35 YP, 10 sec gels 10, 10 min gels 19, 30 min gels 25. After circ and condition properties : 9.1 ppg weight, vis 55, PV 12/14 YP, 10 sec gels 4, 10 min els 7, 30 min els 8. 'ago ~ of 87 -- - - _ _- Time Logs __ ~ Uate From To Dur S. epth E. Depth Phase Code Subccde T CO^4 __ _ ___ ___ _ 05/19/2006 02:45 04:45 2.00 2,258 2,258 _ SURFA CEME~ _ OTHR P Dowell mix and pump 10 bbls CW 100 @ 8.3 ppg, shut down and test lines to 3500 psi. Follow w/another 40 bbls CW 100 (8.3 ppg) @ 5 bpm w/ 200 psi. Mix and pump 41.4 bbls Mud push w/ red dye (10.5 ppg) @ 4 bpm w/ 174 psi. Drop bottom plug, Mix and pump 360 bbls (450 sx) AS lite (4.49 cu ft/sx yield) (water 20.569 gal/sx) weight 10.7 ppg. Pump @ 6.4 bpm w/ 350 psi. Follow w/ 64 bbls(130 sx) DeepCrete tail cement (2.46 cu ftlsx) (8.144 gal/sx) weight 11.9 ppg. Start off pumping tail @ 2 bpm w/ 110 psi, increase to 6 bpm w/ 480 psi, then after 34 bbls pumped increase and stay @ 6.7 bpm, final pressure 604 psi., Drop top plug. Dowell cleanup on top of plug w/ 20 bbls water. Note: Continued to reciprocate pipe until 0432 hrs, then landed, final down wt was 132k, final PU wt was 182k. 42 bbls tail had been pumped when quit reci . 04:45 05:15 0.50 2,258 2,258 SURFA CEMEI~ DISP P Rig finish displacing cement w/ rig pumps @ 7 bpm w/ 9.0 ppg mud pretreated w/ SAPP, bicarb and desco, with initial pressure 350 psi, slowed rate to 3 bpm f/ last 10 bbls w/ 440 psi final circ pressure. Bumped plug @ 0513 hrs w/ 1000 psi. Calculated 1882 strokes, actual 1886 strokes to bump plug. Note: Red dye @ surface @ 0447 hrs after 33 bbls mud displaced w/ rig pumps. Approx 107 bbls of 10.9 ppg good cement circ to surface. 05:15 05:30 0.25 2,258 2,258 SURFA CEMEf~ OTHR P Held 1000 psi f/ 10 min. bleed off pressure and check floats, OK. Pump SAPP water to flush stack and flow line. 05:30 06:00 0.50 0 0 SURFA CEME(~ RURD P Rig down Dowell cement head and remaining casing tools. Prepare to back out Vetco Gray left handed landing joint. Vetco Gray rep Mark Jensen on ri floor su ervise. 06:00 06:30 0.50 0 0 SURFA CASIN( RURD P Finish rigging down GBR casing tools f/ floor. Clean floor. Pull landin 'oint. 06:30 09:30 3.00 0 0 SURFA CASIN( RURD P Change top drive over. UD long bales. PU and install short bales and drilling 5" elevators. 09:30 12:00 2.50 0 0 SURFA WELC7 NUND P Nipple down riser. Remove 20" diverter. Clean out flowline, F~agQ 'ltI trf ~7 -- _ - -- - Time Logs _ __ - _____ ~ Uate From To Dur S. e th E. De th Phase Code Subcode- T__COM __ 05/19/2006 12:00 16:30 4.50 0 0 SURFA WELCT NUND P NU wellhead. Remove 20" annular f/ cellar. Hook up hydraulic lines to BOP stack. PU and set BOP stack and set after holding PJSM. Pitwatcher and rockwasher are cleaning pits and transfering mud. Roustabouts removing 9 joints of 10-3/4" casing f/shed, and uttin BHA # 2 in shed. 16:30 16:45 .0.25 0 0 SURFA WELCT OTHR P PJSM on changing rams. 16:45 00:00 7.25 0 0 SURFA WELCT OTHR P Change lower pipe rams f/ 4" to 7-5/8", then change top pipe rams f/ 3-1/2" x 6" to 4-1/2" x 7". .05/20/2006 00:00 01:30 1.50 0 0 SURFA WELCT NUND P NU flow nipple, install turnbuckles, install drip plate under rig floor f1 spill prevention. Ihspec all unions and flanges. Install drain hoses f/ rig floor to cellar. Install mouse hole. Install roughneck track. Straighten up rig floor, re to test BOPE. 01:30 02:30 1.00 0 0 SURFA WELCT OTHR P Rig up to test BOPE. Set test plug. Make up test joint and floor safety valves. Fill stack w/water. Visual f/ leaks. Bringing BHA into pipe shed, lace in order er directional driller. 02:30 06:00 3.50 0 0 SURFA WELCT BOPE P Witness of BOP test waived by AOGCC inspector John Crisp. Begin testing BOPE. Tighten flange of DSA to Vetco Gra MB28 wellhead. 06:00 08:30 2.50 0 0 SURFA WELC7 BOPE P Continue testing 13-5/8" BOPE. HCR on choke line. Upper and lower IBOP on top drive. Floor dart valve would not test due to Pin end shoulder connection leak. Also the floor safety valve tested, but the box face of tool 'oint bad as well. Will test others later. 08:30 09:15 0.75 0 0 SURFA WELCT BOPE P Accumulator test, full charge 2850 psi, after closing 1400 psi, 200 psi build up 1-1/2 min, full char e 3 min 56 sec. 09:15 10:30 1.25 0 0 SURFA WELCT BOPE P Rig down 5" test joint, RU to test blinds, OK. Then test 7-5/8" lower pipe rams, OK. Tested to 250 psi low f/ 5 min and 3000 si hi h f/ 5 min. 10:30 12:00 1.50 0 0 SURFA WELC7 OTHR P Pull test plug, lay down 7-5/8" test joint and 10' pup joint. PU joint of 5" dp and 10' pup joint. Set Vetco Gray wear bushing (9-7/8" ID, 10-9/16" OD, 4' 10-7/8" length). Blow down choke manifold, choke line, kill line and top drive. 12:00 12:45 0.75 0 0 SURFA WELCT OTHR P Lay down joint of 5" dp and 10' pup jt. 12:45 13:30 0.75 0 0 SURFA WELC7 BOPE P Pick up another floor safety valve and dart valve. Test 5"floor safety valve and dart valve to 250 psi low and 3000 psi hi h, OK. P~~e 11 of ~7 ~~ Time Logs Date _ From To Dur S: cpth E De~tt; Phase .- Ccde Suk;code- T _ COM 05/20/2006 13:30 13:45 0.25 0 0 SURFA DRILL SFTY P PJSM on picking up BHA #2. 13:45 14:00 0.25 0 0 SURFA WELCT OTHR P Rig down BOPE test equipment. 14:00 15:45 1.75 0 83 SURFA DRILL PULD P PU/MU BHA#2. Make up Hughes 9-7/8" MX-1 bit, 7" Sperry Drill lobe 7/8- 6 stage motor 9.75" stab, nm float sub, 9.75" integral blade stabilizer, MWD/Directional, MWD/Gamma/Res/PWD, MWD/TM-HOC to 83'. Orient motor to MWD. 15:45 16:30 075 83 83 SURFA DRILL OTHR P Upload Sperry Sun MWD 16:30 17:15 0.75 83 268 SURFA DRILL OTHR P Continue MU BHA #2. Mu stand of 6.75" nm flex drill collars and stand of 5" HWDP to 268'. Shallow test MWD, OK. Pumping 481-533 gpm w/ 910-1050 si. 17:15 18:00 0.75 268 828 SURFA DRILL TRIP P Continue in hole w/ BHA #2. Run another stand of 5" HWDP, then PU/MU Daily 6.2" OD drilling jar (ser # 15061067), then 13 joints of 5" HWDP, follow w/ Weatherford 9.88" OD ghost reamer (793.94' behind bit), then one more 5" HWDP to 828.11'. 18:00 19:30 1.50 828 2,142 SURFA DRILL TRIP P RIH w/ 5" dp f/ 828.11' to tag up @ 2142' on cement stringers. RU to circ and condition mud f/ casin test. 19:30 21:15 1.75 2,142 2,142 SURFA DRILL CIRC P Circulate and even out mud to 9.2 ppg f/ casin test. 21:15 22:30 1.25 2,142 2,142 SURFA CASIN( DHEQ P RU to test casing to 3000 psi f/ 30 min. Chart test. Rig down testing e ui ment. 22:30 00:00 1.50 2,142 2,256 SURFA CEME~ DRLG P Drill cement stringers f/ 2142' to wiper rubbers on top of float collar @ 2172.53', then shoe track cement to top of float shoe @ 2255.9'.Drilled w/ 410 gpm w/ 900 psi off bottom and 1030 psi on bottom. Motor rpm 135 rpm, rotary rpm 40-50 rpm, torque 3k ft Ib for ue. WOB 2-4k. 05/21/2006 00:00 00:45 0.75 2,256 2,268 SURFA CEMEI~ DRLG P Drill 10-3/4" float shoe to 2258', then rat hole to 2268'.. Drill w/ 410 gpm w/ 900 psi off bottom, 1030 psi on bottom. Motor rpm 135. Rotary rpm 40-50. Torque 3k ft Ib. WOB 2-4k. PU wt 150k, SO wt 145k, Rot wt 145k. 00:45 01:00 0.25 2,268 2,288 SURFA DRILL DDRL P Drill 20' new hole f/ 2268' to 2288' (20') (2241.83' TVD). AST =.28 hrs. Hrs on bit = .28 hrs, jar hrs = .28 hrs. Drill w/ 500 gpm, 1320 psi, 6k WOB, 80 rpm w/ rotary rpm, motor rpm = 165. PU wt 150k, SO wt 145k, Rot wt 145k. IM~icJe 12 of 37 -- -- Time. Logs_ - - - - - Date From To Dur S. ye~th E. De th.Phase Lcde Subcode T _ COM _ __ __ 05/21/2006 01:00 02:30 1.50 2,288 2,288 SURFA DRILL CIRC P Circ and condition hole and mud f/ formation integrity test after drilling 20' new hole to 2288'. Pumping 500 gpm w/ 1250 psi and 80 rpm rotary, motor 165 r m. Circulated 700 bbls. 02:30 03:00 0.50 2,288 2,288 SURFA DRILL FIT P RU and perform FIT, using 9.2ppg mud. Casing shoe @ 2257.68' (TVD= 2215.92'. Drilled to 2288' MD (TVD 2241.83'). Leak off @ 493 psi = EMW of 13.5 03:00 03:30 0.50 2,288 2,288 SURFA DRILL FIT P Bleed off pressure. Returns of .5 bbl. Rig down test equipment. Blow down circ line and kill line. 03:30 04:30 1.00 2,288 . 2,288 INTRM1 RIGMN SVRG P Service rig. Grease top drive, traveling blocks and drawworks. 04:30 06:00 1.50 2,288 2,411 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 2288' -2411' (123') (TVD = 2343'). ART = .16 hrs, AST = .53 hrs. Total hrs on bit = .97 hrs., Total hrs on jars = .97 hrs, 5-10k WOB, 90 rpm's, 167 mtr rpm, 506 gpm w/ 9.2 ppg MW, on bottom press 1250 psi, off bottom press 1120 psi, on bottom torque 3k ft/Ib, off bottom torque 3k ft/ Ib, PU wt 151 k, SO wt 139k, Rot wt 145k. Max gas= 15 units. ECD's = 9.4. 06:00 07:15 1.25 2,411 2,535 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 2411' -2535' (124') (TVD = 2443'). ART = .16 hrs, AST = ..61 hrs. Total hrs on bit = 1.74 hrs., Total hrs on jars = 1.74 hrs, 10-15k WOB, 90 rpm's, 170 mtr rpm, 515 gpm w/ 9.2 ppg MW, on bottom press 1250 psi, off bottom press 1120 psi, on bottom torque 7-8k ft/Ib, off bottom torque 6k ft/ Ib, PU wt 151 k, SO wt 140k, Rot wt 145k. Max gas= 15 units. ECD's=9.4 07:15 09:15 2.00 2,535 2,535 INTRM1 DRILL CIRC P Circ hole clean. Perform PWD baseline. MW 9.2 ppg, PV/YP = 18/19. Pumping 500 gpm w/ 60 rpm = 9.36 ppg, 90 rpm = 9.37 ppg. Pumping 600 gpm w/ 60 rpm = 9.38 ppg, 90 rpm = 9.4 ppg. Misc survey's f/ Cassandra erformed. I'r~~ 13 of £37 - - - - _ _ -- Time Logs ~ -- Date From To Dru - - epth S - E. Depth Phase ubccde Code S T CCM 05/21/2006 09:15 _ 12:00 2.75 , 2,535 2,835 INTRM1 T DRILL _ _ DDRL _ P - Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 2535' -2835' (300') (TVD = 2661'). ART = .4 hrs, AST = 1.19 hrs. Total hrs on bit = 3.33 hrs., Total hrs on jars = 3.33 hrs, 10-15k WOB, 90 rpm's, 170 mtr rpm, 515-534 gpm w/ 9.2 ppg MW, on bottom press 1150-1300 psi, off bottom press 1120-1240 psi, on bottom torque 4-5k ft/Ib, off bottom torque 3-4k ft/ Ib, PU wt 150-158k, SO wt 140k, Rot wt 145-150k. Max gas= 15 units. ECD's = 9.63-9.56. 12:00 18:00 6.00 2,835 3,317 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 2835' -3317' (482') (TVD = 2918'). ART = .64 hrs, AST = 2.75 hrs. Total hrs on bit = 6.72 hrs., Total hrs on jars = 6.72 hrs, 10-15k WOB, 90 rpm's, 171- 182 mtr rpm, 520-552 gpm w/ 9.2 ppg MW, on ` bottom press 1150-1300 psi, off bottom press 1290-1480 psi, on bottom torque 4-6k ft/Ib, off bottom torque 4-8k ft/ Ib, PU wt 158-160k, SO wt 140k, Rot wt 145-150k. Max gas= 15 units. ECD's = 9.6-9.64. 18:00 00:00 6.00 3,317 3,678 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 3317' -3678' (361') (TVD = 2995'). ART = 2.65 hrs, AST = .7 hrs. Total hrs on bit = 10.07 hrs., Total hrs on jars = 10.07 hrs, 10-15k WOB, 90 rpm's, 171- 182 mtr rpm, 520-552 gpm w/ 9.2 ppg MW, on bottom press 1150-1300 psi, off bottom press 1290-1480 psi, on bottom torque 4-6k ft/Ib, off bottom torque 4-8k ft/ Ib, PU wt 158-160k, SO wt 140k, Rot wt 145-150k. Max gas= 15 units. ECD's = 9.6-9.64. ppg. Pumped 20 bbls of Hi vis weighted to 10 swee 3357' and 3390'. _.__ . Aga 14 of X37 Time Logs - -= - -- _ _--- _ __ 'Date From To Dur S. De th E:Je th Phase Code _ Subcode~ T C;~M _ 05/22/2006 00:00 06:00 6.00 3,678 4,079 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 3678' -4079' (401') (TVD = 3198'). ART = 2.23 hrs, AST = 1.45 hrs. Total hrs on bit = 13.75 hrs., Total hrs on jars = 13.75 hrs, 5-15k WOB, 90 rpm's, 199-205 mtr rpm, 605-620 gpm w/ 9.2 ppg MW, on bottom press 1630-1710 psi, off bottom press 1380-1660 psi, on bottom torque 4-5k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 158-160k, SO wt 138-140k, Rot wt 143-148k. Max gas= 15 units. ECD's = 10-9.76. ppg. Pumped 25 bbls of Hi vis weighted to 10 swee 3750'. 06:00 12:00 6.00 4,079 4,504 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 4079' -4504' (425') (TVD = 3337'). ART = 2.57 hrs, AST = 1.85 hrs. Total hrs on bit = 18.17 hrs., Total hrs on jars = 18.17 hrs, 5-20k WOB, 90 rpm's, 202-210 mtr rpm, 614-637 gpm w/ 9.1+ppg MW, on bottom press 1620-1740 psi, off bottom press 1400-1620 psi, on bottom torque 5-7k ft/Ib, off bottom torque 3-6k ft/ Ib, PU wt 162-170k, SO wt 143-138k, Rot wt 150-152k. Max gas= 15 units. ECD's = 9.67-9.81 ppg. Pumped 25 bbls Hi vis weighted sweep while drilling f/ 4070' to 4135' (@ 0600 hrs . 12:00 18:00 6.00 4,504 4,913 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 4504' -4913' (409') (TVD = 3443'). ART = 1.48 hrs, AST = 2.47 hrs. Total hrs on bit = 22.12 hrs., Total hrs on jars = 22.12 hrs, 5-30k WOB, 90 rpm's, 179-203 mtr rpm, 543-616 gpm w/ 9.1+ppg MW, on bottom press 1460-1820 psi, off bottom press 1330-1660 psi, on bottom torque 3-7k ft/Ib, off bottom torque 5-9k ft/ Ib, PU wt 170k, SO wt 138-140k, Rot wt 150-151 k. ECD's = 9.82-9.98 ppg. Pumped 18 bbls Hi vis weighted to 10 ppg sweep while drilling f/ 4535'-4625' 1300 hrs . r age 'i 5 of II7 Time Lis __ _ _ - - - - - - _ ~ Date From To Dur S De th E. DC th Phase Code 5ubcode_ T CQM _ _ _ __ 05/22/2006 18:00 00:00 6.00 4,913 5,166 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 4913' -5166' (253') (TVD = 3511.9'). ART = 1.68 hrs, AST = 1.3 hrs. Total hrs on bit = 25.1 hrs., Total hrs on jars = 25.1 hrs, 5-20k WOB, 90 rpm's, 198-203 mtr rpm, 600-615 gpm w/ 9.1+ppg MW, on bottom press 1820-1920 psi, off bottom press 1740-1830 psi, on bottom torque 5-7k ft/Ib, off bottom torque 4-7k ft/ Ib, PU wt 170-172k, SO wt 140k, Rot wt 151-155k. ECD's = 9.98-10.4 ppg. Pumped 25 bbls Hi vis weighted to 10.5 ppg sweep while drilling f/ 5104' (@ 2300-2330 hrs). Dum ed swee when back to surface. 05/23/2006 00:00 06:00 6.00 5,166 5,483 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 5166' -5483' (31 T) (TVD = 3593'). ART = 3.14 hrs, AST = 1.47 hrs. Total hrs on bit = 29.71 hrs., Total hrs on jars = 29.71 hrs, 10-20k WOB, 90 rpm's, 203-210 mtr rpm, 615-635 gpm w/ 9.1+ppg MW, on bottom press 1780 psi, off bottom press 1650 psi, on bottom torque 5-10k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 178k, SO wt 143k, Rot wt 156k. ECD's = 9.86-10.04 06:00 12:00 6.00 5,483 5,864 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 5483' - 5864' (381') (TVD = 3655'). ART = 2.34 hrs, AST = .73 hrs. ADT = 3.07 Hrs. Total hrs on bit = 32.78 hrs., Total hrs on jars = 32.78 hrs, 10-20k WOB, 90 rpm's, 203-210 mtr rpm, 615-635 gpm w/ 9.1+ppg MW, on bottom press 1840 psi, off bottom press 1710 psi, on bottom torque 5-10k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 182k, SO wt 140k, Rot wt 155k. ECD's = 9.97 - 10.04 12:00 18:00 6.00 5,864 6,245 INTRM1 DRILL DDRL P Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 5864' - 6245' (381') (TVD = 3707). ART = 3.27 hrs, AST = .30 hrs. ADT = 3.57 Hrs. Total hrs on bit = 36.35 hrs., Total hrs on jars = 36.35 hrs, 10-20k WOB, 90 rpm's, 203-210 mtr rpm, 615-635 gpm w/ 9.1+ppg MW, on bottom press 1810 psi, off bottom press 1700 psi, on bottom torque 7-8k ft/Ib, off bottom torque 5-7k ft/ Ib, PU wt 185k, SO wt 138k, Rot wt 155k. ECD's = 1023 ~~ ~~ge 1 ~ of 87 Time Logs -- -- - -- Date From To Dur S:>De tf'~ E. De th Bhase Code e Subcod T COM __ 05/23/2006 _ 18:00 21:30 ___ 3.50 6,245 6,435 INTRM1 DRILL _ DDRL _ P _ Directional Drill 9-78" hole w/ 7" Sperry drill 7/8 lobe - 6.0 stage mtr w/ 1.50 deg bend from 6245' -6435'(190') (TVD = 3753'). ART = 1.43 hrs, AST = 1.12 hrs. ADT = 2.64 Hrs. Total hrs on bit = 38.99 hrs., Total hrs on jars = 38.99 hrs, 10-20k WOB, 90 rpm's, 203-210 mtr rpm, 615-635 gpm w/ 9.1+ ppg MW, on bottom press 1820 psi, off bottom press 1700 psi, on bottom torque 8-10k ft/Ib, off bottom torque 5-10k ft/ Ib, PU wt 185k, SO wt 139k, Rot wt 155k. ECD's = 10.25 21:30 23:00 1.50 6,435 6,435 INTRM1 DRILL CIRC P Pump weighted Hi -Visc sweep on bottom while reciprocate & rotate drill string. Pump @ 630 GPM's - 1810 PSI. Pump until returns cleaned up. Begin clean pits for bringing on MOBM. 23:00 00:00 1.00 6,435 5,107 INTRM1 DRILL REAM P BROOH from 6435' - 5107' @ drilling parameters. Pumps @ 625 GPM's - 1800 PSI with 90 RPM's. Obtain SLM as drill pipe was racked back. Obtain Torque & drag parameters as per rig en ineer eve 5 stands. 05/24/2006 00:00 06:00 6.00 5,107 3,053 INTRM1 DRILL REAM P BROOH from 5107' - 3053' @ drilling parameters. Pumps @ 625 GPM's - 1800 PSI with 90 RPM's. Obtain SLM as drill pipe was racked back. Obtain Torque & drag parameters as per rig engineer every 5 stands. Observe hole unloading when circulating bottoms up with Ghost Reamer in shoe. Hole looked good while backreaming , no issues. 06:00 06:30 0.50 3,053 2,255 INTRM1 DRILL REAM P Continue BROOH from 3053' - 2255', brin in bit into shoe. 06:30 08:15 1.75 2,255 2,255 INTRM1 DRILL CIRC P Pump Hi Visc weighted sweep at shoe at 600 GPM's - 1650 PSI. Reciprocate & rotate drill string @ 90 RPM's with 4K torque. Monitor well -static. Blow down To Drive & lines. 08:15 09:30 1.25 2,255 828 INTRM1 DRILL TRIP P POOH with BHA #2 from 2255' - 828'. Monitor well -static. 09:30 09:45 0.25 828 828 INTRM1 DRILL SFTY P Held PJSM with crew & Sperry Sun Hands. Discuss Safety Issues and rocedure for la in down BHA. 09:45 11:45 2.00 828 100 INTRM1 DRILL PULD P Breakout & lay down BHA #2. Lay down 1 jnt 5" HWDP (30.81'), 6 1/2" Ghost Reamer (6.96'), 13 -Joints 5" HWDP (400.18'), 6 1/4" Drilling Jars (30.06'), 6 -Joints 5" HWDP (184.03'), 3 -joints Non Mag Flex Drill collars 93.19' . 11:45 12:00 0.25 100 100 INTRM1 DRILL PULD P RU & flush Drilling Assembly with water as er Directional driller. F'agQ 17 of 37 Time Lis - - - - - - Date From To Dur S. Depth E,_Depth Phase Code Sut~code_ T COM _ 05/24/2006 12:00 12:30 0.50 100 90 INTRM1 DRILL PULD P Breakout & lay down 6 3/4" MWD TM HOC 10.0' . 12:30 14:00 1.50 90 90 INTRM1 DRILL OTHR P Plug in and download MWD assembly. Pull 7 5/8' casin .tools to ri floor. 14:00 15:30 1.50 90 0 INTRM1 DRILL PULD P Breakout & lay down remaining BHA. Lay down 6 3/4" MWD GAmma/Res/ PWD (28.02'), MWD Directional assembly (9.20'), 6 3/4" Integral Blade stabilizer (6.97'), 6 12P' Float Sub (2.42'), 7" Sperry Drill Lobe 7/8 - 6.0 stage Motor (25.42'), and Hughes 9 7/8" MX-1 Bit (.85'). Inspect & grade bit to 1 /2/WT/A/E/ER/TD. Observed proper hole fill. Drain Stack & RU & ull Wear rin . 15:30 15:45 0.25 INTRM1 DRILL SFTY P Held PJSM on rig up casing e ui ment. Discuss Safet issues. 15:45 18:00 2.25 INTRM1 CASIN( RURD P Rig all casing equipment including tongs ,elevators, spiders and pick up sling. Inspect tools, and double check all tools and centralizer count. Crew Chan e. 18:00 18:30 0.50 INTRM1 RIGMN SVRG P Service Rig & egipment. Finish prep for casin run. 18:30 23:00 4.50 0 2,257 INTRM1 CASIN( RNCS P Make up 7 5/8" Shoe joint, and threadlock joint. Continue make up Float collar joint. Install centralizers in a 3 for 2 pattern as per program, and check floats. Good. Continue run 7 5/8" from surface to 2257'. Shoe depth. Install Tandem Rise centralizers in a 3 for 2 pattern on the first 31 joints, leaving the window joints free of centralizers or stop rings. Continue install tandem rise centralizers on 'oints 33 - 46 on collars onl . 23:00 00:00 1.00 2,257 2,257 INTRM1 CASIN( CIRC P Using Franks Fill up tool, circulate bottoms up at the shoe with pumps at 5 BPM - 280 PSI. Reciprocate casing string. UP WT = 135K, SO WT = 120 K. 05/25/2006 00:00 02:00 2.00 2,257 3,1.12 INTRM1 CASINC RNCS P Continue run 7 5/8" 29.7# intermediate casing to 3112' MD. Fill every joint and circulate down 2 joints slowly after evry 15 joints ran. Pump @ 5 BPM - 250 PSI. } 3g4 1~ cif 37 Time Logs Hate From To Dur S. Dc th l=.De th Fhase Code Subcode T COM 05/25/2006 02:00 04:30 2.50 3,112 3,112 INTRM1 CASIN( RNCS NP Tag up at 31.12' MD. Observe casing not packing off, and good returns. Attempt to beat down and through bridge in hole, no success. Observed Franks Fill up tool rubber failed at the same time. Lay down 1 joint of casing, and rig down Franks Fill up tool. Install circulation head and continue circulating at 45 SPM - 250 PSI while reciprocate casing string. Hole looked good. Wait on new rubber for 45 minutes. Install on Franks tool, and Rig up Franks fill up tool. Pick up 1 joint of 7 5/8" casing. Tag @ 3112' MD once again, and work through bridge by repeated set down, setting as much as 70K down. Obtain success and continue in hole with casin . 04:30 06:00 1.50 3,112 4,470 INTRM1 CASIN( RNCS P Continuerun 7 5/8" casing from 3112' to 4470'. Fill every joint and circulate down 2 joints slowly after evry 15 joints ran. Pump @ 5 BPM - 330 PSI. Crew Chan e 06:00 07:30 1.50 4,470 4,817 INTRM1 CASIN( RNCS P Insert Franks Fill up tool on joint #114 @ 4817'. Circulate joint down @ 45 SPM - 250 PSI, moving old mud up hole. 07:30 10:00 2.50 4,817 6,428 INTRM1 CASIN( RNCS P Continue RIH with 7 5/8" casing from 4817' - 6428'. Fill eve 'oint white RIH. 10:00 10:45 0.75 6,428 6,428 INTRM1 CASINC CIRC P Insert Franks fill up tool and circulate to condition mud. Pumps @ 35 SPM - 300 PSI. Mud WT = 9.1 PPG. 10:45 11:15 0.50 6,428 INTRM1 CEMEI~ RURD P Lay down Franks Fill up tool. Make up 7 5/8" Cement Head & Lines. 11:15 13:45 2.50 INTRM1 CEMEI~ CIRC P Continue Circulate & condition mud @ 60 SPM - 6 BPM - 270 PSI. Clear & clean floor area. LAy down Casing runnin E ui ment. 13:45 15:00 1.25 INTRM1 CEME~ DISP P Held PJSM with entire crew & Dowell Crew. Discuss safety issues and procedure for pumping cement job. Designate Spill Champion. Pump 10 BBLS of 8.3 PPG CW 100 . Pressure Test lines to 3500 PSI. Pump 40 BBLS of 8.3 PPG CW 100. Drop Bottom Plug. Continue pump 75 BBLS of 11.0 PPG MudPush II, and 184 BBLS of 12.5 PPG Class G Tail cement. Reciprocate casing string i strokes of 20'. Dro To Plu . 15:00 16:00 1.00 INTRM1 CEMEI~ DISP P Turn over to Rig. Displace cement with 9.0 PPG MOBM @ 6 BPM - 290 PSI, catching cement. Slowing pumps to 2 BPM - 830 PSI observing bumping plug with 284 BBLS and pressure to 1300 PSI. Hold ressure for 5 minutes. E'~C~2 19 Cat 87 Time Lois - - - - - -- Date From To Dur S. Depth E Depth Phase Code_ Subcode T_ COM _ _ 05/25/2006 16:00 16:15 0.25 INTRM1 CEMEt~ DISP P Bleed pressure and Check Floats. Floats held. 16:15 18:00 1.75 INTRM1 CEMEf~ RURD P Drain BOP stack. Blow down all lines and Cement head. Rig Down Cement head & lines. SIMOPS: Begin ND BOP stack, and load pipe shed with 4" XT 39 drill i e. Crew Chan e 18:00 20:00 2.00 INTRM1 CASIN( NUND P Continue Nipple down Lower well head flange. Prepare cellar for picking up Bop stack. Drain annulus. Rig up and vac out 7 5.8" casing to below the well head with trash pump. Inspect all Bridge crane cables and shackles. Check all weights before lifting stack, and verify cables and lines were correct. PJSM with Vetco Gray reps. Discuss Safety Issues and procedure for settin emer enc sli s. 20:00 22:30 2.50 INTRM1 CASIN( NUND P Pick up BOP stack and lower flange on well head. Install emergency slips as per Vetco Gray reps. Set casing down on slips with approximately 50K overpull on string. Pull cut off joint from stack. RD Slips and equipment on floor. Rig up WACHS pneumatic casing cutter and cut casing. Install 7 5/8" Packoff as er Vetco Gra . 22:30 23:30 1.00 INTRM1 CASIN( NUND P Rig Up & Test packoff and flange break to 3800 PSI for 10 minutes. Clean & clear cellar area of tools and e ui ment. 23:30 00:00 0.50 INTRM1 CASIN( NUND P Complete Nipple up Bop stack, and flowline. Install turnbuckles, and s lash late. 05/26/2006 00:00 02:00 2.00 INTRM1 CASIN( OTHR P Complete Nipple up and rig up lines to erform Annular In'ectivit test. 02:00. 02:30 0.50 INTRM1 CASINC OTHR P Rig up lines and perform Annular Infectivity test to 13.0 PPG EMW on the 10 3/4" x 7 5!8" Annulus. 10 minute bleed off from 360 PSI to 200 PSI. Continue pump 30 BBLS of 8.3 PPG water down annulus at 2 BPM - 640 PSI. Shut in pressure = 840 PSI. SIMOPS: Rig down long bales on Top drive, install Short bales. Rig up to lay down 5" Drill i e form derrick. 02:30 03:30 1.00 INTRM1 CASINC RURD P Continue rig up to lay down 5" Drill Pipe from derrick. Prepare pipe shed. Finish putting in 1 row of 4" drill pipe in shed, for re aration to ick u same. 03:30 06:00 2.50 INTRM1 CASIN( RURD P Breakout & lay down 5" Drill pipe from derrick. Crew Chan e. 06:00 08:00 2.00 INTRM1 CASIN( RURD P Continue breakout & lay down 5" Drill pipe from the derrick. Repair pipe skate switch & hydraulic line on Iron roughneck. Load remaining row of 4" in shed while work on Iron Rou hneck. ;'~xc~e ~~ of 37 Time Logs _ _-- - ^ate From_ To Dur _ _S_._Depth E Det~th~Phase,_ Code _ S;~bcode T _ COM_ _ 05/26/2006 08:00 12:00 4.00 INTRM1 CASIN( RURD P PJSM with crew. Discuss Safety Issues and correct procedures for la in down DP. 12:00 13:45 1.75 INTRM1 CASIN( RURD P Continue lay down 5" drill pipe from derrick leaving a total of 22 stands racked back. 13:45 14:45 1.00 INTRM1 WELCT OTHR P Pull 4" XT 39 14:45 15:30 0.75 INTRM1 WELCT OTHR P Install test plug. Hold PJSM. Discuss Safety Issues and procedure for chan in rams in BOP stack. 15:30 .18:00 2.50 INTRM1 WELCT NUND P Change rams in stack installing 3 1/2" x 6" VBR's in top set and 9 5/8" rams in bottom set. Crew chan e 18:00 19:30 1.50 INTRM1 WELCT BOPE P PJSM with crew. Discuss changing rams and safety issues. Continue changing rams. Close and tighten doors. Pick up test joint and make up test plug. RIH to land plug. RU to test maifold and RU chart. Test Dart valves & floor valve. Test to 250 PSI low / 3000 PSI as er ermit. 19:30 21:30 2.00 INTRM1 WELCT BOPE P Continue test Upper pipe rams 3 1/2" x 6" VBRs, and Floor valve. All. test recorded on chart and tested to 250 PSI low / 3000 PSI hi has er ermit. 21:30 22:00 0.50 INTRM1 WELCT OTHR P Rig down all test equipment & test chart. Pull & la down test lu . 22:00 00:00 2.00 INTRM1 RIGMN RGRP P Inspect & install 4" saver sub on Top drive, removin 5" Saver sub. 05/27/2006 00:00 01:00 1.00 INTRM1 RIGMN SVRG P Continue change out saver sub, Gripper & dies on Top Drive from 5" IF to 4" XT-39. 01:00 02:00 1.00 INTRM1 CASIN( OTHR P Pick up test joint & wear bushing. RIH ste WB, and RILDS. Pull & lay down test 'oint & runnin tool. 02:00 06:00 4.00 INTRM1 DRILL TRIP P Pick up 4" Drill Pipe with Super Sliders made up 2 per joint, from pipe shed., rackin back in derrick. Crew Chan e 06:00 11:00 5.00 INTRM1 DRILL TRIP P PJSM with crew. Discuss Safety Issues and procedure for picking up 4" DP and racking back in derrick. Continue pick up 4" DP & rack in derrick. 153 Joints total of Super Sliders -installed 2 per joint. 45 joints of slick DP. 11:00 11:30 0.50 INTRMI DRILL SFTY P PJSM with crew & Sperry Sun reps. Discuss Safety Issues and procedure for picking up BHA #3, 6 3/4" Drilling assembl with Geo Pilot & nukes. 11:30 12:00 0.50 0 18 INTRM1 DRILL PULD P Make up BHA # 3. MU 6 3/4" Security PDC bit with 3 x 21's jets (1.29'), with %" 5200 GEO -Pilot 16.17 . a~~ge ~'! cf ~7 Time Logs ~ ~Dafe .From To_ Dur 5. Depth E. Depth Phase Code 4ubc;oJe= T__ COM 05/27/2006.12:00 14:00 2.00 18 90 INTRM1 DRILL PULD P Continue making up BHA #3, picking up 4 3/4" Non Mag G.P. Flex Drill collar (11.55').4 3/4" MWD Directional (8.56'), 4 3/4" Smart Stabilizer Sleeve. Type (3.59'), 4 3/4" Gamma /Res (24.52'), 4 3/4" PWD (10.82'), 4 3/4" TM-HOC (11.27'), and 4 3/4" Non MAg Float sub 2.38' . 14:00 15:00 1.00 90 90 INTRM1 DRILL OTHR P Plug in and upload MWD assembly. Screw in and perform shallow pulse test @ 320 GPM's - 500 PSI. Good test. 15:00 15:15 0.25 90 90 INTRMI DRILL PULD P Rig up and blow down Top Drive & lines. 15:15 18:00 2.75 90 1,977 INTRM1 DRILL PULD P Continue make up remaining BHA #3. Make up 4 3/4" Integral Blade stabilizer (4.58'), 3 joints Non Mag Flex Drill Collars (93.39'), Crossover (3.00'), 1 -Joint 4" HWDP (30.68'), 4 3/4" Drilling Jars (32.25'), 1 -Joint 4" HWDP (30.69'). and 4" drill pipe to 197T. Crew Chan e. 18:00 18:30 0.50 1,977 1,977 INTRM1 DRILL TRIP P Fill drill string with mud, set bit depth, and pulse test pumping @ 300 GPM's -560 PSI. Good Test. 18:30 00:00 5.50 1,977 5,727 INTRM1 DRILL TRIP P Continue trip in hole picking up 4" drill pipe in singles from 1977' - 5727'. including 48 joints of 4" DP (1502.72'), 4 3/4" Dailey DNT Drilling Jars (32.04'), 3 joints 4" Drill pipe (94.27'), and 4 3/4" Dailey Accelerator (32.09'). Observe proper hole fill. Make up torque 22K FULbs. 05/28/2006 00:00 02:30 2.50 5,727 6,335 INTRM1 DRILL TRIP P Continue trip in hole from 5727' - 6258'. Screw in and pump to break in bearings on Geo=Pilot as required, with pumps @ 220 GPM's - 1270 PSI. Work Drill string down to 6335'. Rotating at 50 RPM's - 5K torque. UP WT = 145K, SO WT = 112K, ROT WT = 136K. Observe tagging soft cement @ 6335' and tagging FC. Stop, and ull 1 stand. 02:30 03:30 1.00 6,335 6,335 INTRM1 CASIN( DHEQ P Rig up lines and equipment including test chart. Pump to clear all lines of air. Pressure test 7 5/8" casing to 3000 PSI - 30 minutes. On chart. Observe 100 PSI bled off in 30 minutes. 03:30 04:30 1.00 6,335 6,335 INTRM1 RIGMN SFTY P Bleed all pressure and rig down test equipment. PJSM with crew. Discuss safety issues and procedure for slipping and cutting drilling line, and performing inspections on Top Drive & draw works. gage 22 of 3~ Time Locy~ _ _ _ From To Dur S_ Dept(t E De ttt Phase_ Code Subcode _ T COM_ _ _ Date _ 05/28/2006 04:30 06:00 1.50 6,335 6,335 INTRM1 RIGMN SVRG P Rig up and Slip & cut 18 wraps of off drilling line drum. Inspect Top Drive & inspect brakes, and draw works. Crew Chan e 06:00 07:00 1.00 6,335 6,335 INTRM1 RIGMN SVRG P Continue Rig Service with greasing up Top Drive, Blocks. Inspect & Grease crown section. Inspect draw works and D na-matic brake um s. 07:00 07:15 0.25 6,335 6,335 INTRM1 DRILL SFTY P PJSM with crew. Discuss safety issues including drilling float equipment, monitoring pits for gain/loss, and inspection of well control a ui ment. 07:15 07:45 0.50 6,335 6,335 INTRM1 DRILL REAM P Wash & ream back into hole to tag Plu sat 6335' MD. 07:45 10:45 3.00 6,335 6,435 INTRM1 DRILL DHEQ P Drill out float equipment, cement from 6335' to 6435' (93'). Pumps @ 237 GPM's - 1600 PSI. Torque @ 5-6K, with WOB 2-5K. 10:45 12:00 1.25 6,435 6,455 INTRM1 DRILL DHEQ P Drill 20' of new hole from 6435' - 6455' MD TVD 3726'. Pumps @ 250 GPM's - 1720 PSI. WOB = 2-5K, with Torque @ 5-6K. Rotate 90 RPM's. ART -.34 Hrs, Total Bit Hrs = .34, Total Jar Hrs _ .34. Max Gas observed = 26 Units. 12:00 13:15 1.25 6,455 6,455 INTRM1 DRILL CIRC P Circulate & condition mud for LOT properties of 8.8 PPG, while reciprocate & rotate drill string. Pumps @ 245 GPM's - 1670 PSI. UP WT = 145K, SO WT = 115K, ROT WT = 125K. Pull DP back to 6352'. 13:15 14:00 0.75 6,455 6,455 INTRM1 DRILL LOT P PJSM. Discuss Safety Issues and procedure to perform LOT. RU lines and chart for LOT. 14:00 14:45 0.75 6,455 6,455 INTRM1 DRILL LOT P Perform LOT pumping down Drill string and annulus observing pressure break over @ 1275 PSI, continuing to pump away 3 BBLs. Mud WT = 8.7 PPG. TVD = 3726', for a calculated EMW of T5.4 PPG. 10 minutes shut in bled down to 750 PSI and held. 14:45 15:30 0.75 6,455 6,455 PROD1 DRILL LOT P Bleed all pressures and rig down equipment. Blow down all lines includin choke line. 15:30 16:00 0.50 6,455 6,455 PROD1 DRILL TRIP P Trip back in hole from 6352' to tag bottom at 6455'. Establish circulation and record parameters including Slow Pump rates = #1 - 20 SPM - 350 PSI, 30 -SPM -600 PSI. #2 Pump = 20 SPM -340 PSI, 30 SPM - 570 PSI. 3'~~ 23 c°f ~7 Time Logs - - - - Date From To Dur S Depth_ E Depth Phase Code__ Subcode T COM _ _ 05/28/2006 16:00 18:00 2.00 6,455 6,628 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A Lateral from 6455' - 6628' MD. TVD = 3732'. (173'). UP WT = 150K, SO WT = 110K, ROT WT = 128K. WOB = 10K, 90 RPM's with Torque on bottom @ 5-6K, Torque off bottom @ 4-5K. Pumps @ 300 GPM's - 2420 PSI. ECD's @ 9.84 PPG, Max Gas observed = 26 Units. Total Bit Hrs = 1.58, Total Jar Hrs = 1.58. ADT & ART = 1.24 Hrs. Baseline ECD = 9.6 PPG. Crew Chan e 18:00 00:00 6.00 6,628 7,192 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A Lateral from 6628' - 7192' MD. TVD = 3737'. (173'). UP WT = 152K, SO WT = 110K, ROTWT = 131 K. WOB = 8-10K, 90 RPM's with Torque on bottom @ 5-8K, Torque off bottom @ 4-5K. Pumps @ 300 GPM's - 2440 PSI. ECD's @ 10.16 PPG, Max Gas observed = 28 Units. Total Bit Hrs = 5.33, Total Jar Hrs = 5.33. ADT & ART = 3.75 Hrs. Survey @ 7158' MD, 3735' TVD, INC = 89.52 DEG, Azimuth = 355.50 Deg. Mud Wt = 8.8 PPG, Visc = 62, YP = 16 05/29/2006 00:00 06:00 6.00 7,192 7,565 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A Lateral from 7192' - 7565' MD. TVD = 3749'. (373'). UP WT = 152K, SO WT = 110K, ROT WT = 131 K. WOB = 8-10K, 120 RPM's with Torque on bottom @ 5-8K, Torque off bottom @ 4-5K. Pumps @ 300 GPM's - 2440 PSI. ECD's @ 10.26 PPG, Max Gas observed = 28 Units. Total Bit Hrs = 8.15, Total Jar Hrs = 8.15. ADT = 2.82 HRS, ART = 2.82 Hrs. Survey @ 7531' MD, 3747' TVD, INC = 87.49 DEG, Azimuth = 357.51 Deg. Mud Wt = 8.8 PPG, Visc = 62, YP = 16 Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Crew . Chan e ~ i Page 2~ ~;t 87 . Time Logs - - - - - - -- - - -- - - - - Date From To Dur S_ Depth. E. Ge th Phase Code Subc~de T COM __ 05/29/2006 06:00 12:00 6.00 7,565 8,021 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A Lateral from 7565' - 8021' MD. TVD = 3747'. (456'). UP WT = 158K, SO WT = 104K, ROT WT = 128K. WOB = 6-7K, 120 RPM's with Torque on bottom @ 5-6K, Torque off bottom @ 4-5K. Pumps @ 312 GPM's - 2950 PSI. ECD's @ 10.79 PPG, Max Gas observed = 55 Units. Total Bit Hrs = 12.11., Total Jar Hrs = 12.11. ADT = 3.96 HRS, ART = 3.96 Hrs. Survey @ 7999' MD, 3746' TVD, INC = 90.03 DEG, Azimuth = 357.46 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 18 Pump Hi Visc weighted sweeps to aid in hole cleanin and control ECD's. 12:00 18:00 6.00 8,021 8,550 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A Lateral from 8021' - 8550' MD. TVD = 3751'. (529'). UP WT = 160K, SO WT = 100K, ROT WT = 128K. WOB = 5-1 OK, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-5K. Pumps @ 312 GPM's - 2950 PSI. ECD's @ 10.58 PPG, Max Gas observed = 46 Units. Total Bit Hrs = 16.2, Total Jar Hrs = 16.2. ADT = 4.09 HRS, ART = 4.09 Hrs. Survey @ 8467' MD, 3751' TVD, INC = 89.66 DEG, Azimuth = .05 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 18. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates. #1 pump @ 20 SPM - 460 PSI. 30 SPM - 700 PSI. #2 Pump @ 20 SPM -480 PSI, 30 SPM - 780 PSI. Crew Chan e 18:00 00:00 6.00 8,550 8,946 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A Lateral from 8550' - 8946' MD. TVD = 3760'. (396'). UP WT = 160K, SO WT = 100K, ROT WT = 128K. WOB = 5-1 OK, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-5K. Pumps @ 312 GPM's - 2900 PSI. ECD's @ 10.72 PPG, Max Gas observed = 45 Units. Total Bit Hrs = 20.14, Total Jar Hrs = 20.14. ADT = 3.94 HRS, ART = 3.94 Hrs. Survey @ 8933' MD, 3759' TVD, INC = 89.47 DEG, Azimuth = 2.13 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 20. Pump Hi Visc weighted sweeps to aid in hole cleanin and control ECD's. __ __ ---- P~g~ 2a cf u7 Time Logs - bate From To D ur S D~th E De th Phase Code Subcvcde _ T COf~M1 __ __ . _ 05/30/2006 _ 00:00 06:00 _ 6.00 _ _ 8,946 9,445 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A Lateral from 8946' - 9445' MD. TVD = 3760'. (499'). UP WT = 170K, SO WT = 95K, ROT WT = 125K. WOB = 5-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 312 GPM's - 3150 PSI. ECD's @ 11.32 PPG, Max Gas observed = 51 Units. Total Bit Hrs = 23.58, Total Jar Hrs = 23.58. ADT = 3.44 HRS, ART = 3.44 Hrs. Survey @ 9400' MD, 3761' TVD, INC = 87.17 DEG, Azimuth = 359.90 Deg. Mud Wt = 8.85 PPG, Visc = 69, YP = 20. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Crew Chan e 06:00 07:00 1.00 9,445 9,533 PROD1 DRILL DDRL P Directional drill 6 3/4" hole in the A Lateral from 9445' - 9533' MD. TVD = 3766'. (499'). UP WT = 185K, SO WT = 95K, ROT WT = 130K. WOB = 5-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 300 GPM's - 3050 PSI. ECD's @ 11.20 PPG, Max Gas observed = 56 Units. Total Bit Hrs = 24.59, Total Jar Hrs = 24.59. ADT = 1.01 HRS, ART = 1.01 Hrs. Survey @ 9499' MD, 3765' TVD, INC = 88.12 DEG, Azimuth = 2.52 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleanin and control ECD's. 07:00 10:30 3.50 9,533 9,533 PROD1 RIGMN RGRP T Observe Swivel Packing failed. No spills. POOH, stand back 2 stands. Install TIW valve in drill string. 81ow down Top Drive & lines. lnstall Head pin and circulating hose. Circulate & reciprocate Drill string @ 6 BPM - 2250 PSI. Change out swivel packing on top drive, and pull TIW valve & lines. RIH back to bottom. Time Logs Date Frorn To Dur S. Depth E. De th Phase Code Subcode T COM __ _ 05/30!2006 10:30 12:00 1.50 9,533 9,627 _ PROD1 _ DRILL DDRL P Continue Directional drill 6 3/4" hole in the A Lateral from. 9533' - 9627' MD. TVD = 3768'. (94'). UP WT = 185K, SO WT = 95K, ROT WT = 130K. WOB = 5-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 300 GPM's - 3050 PSI. ECD's @ 11.25 PPG, Max Gas observed = 51 Units. Total Bit Hrs = 25.47, Total Jar Hrs = 25.47. ADT = .88 HRS, ART = .88 Hrs. Survey @ 9499' MD, 3765' TVD, INC = 88.12 DEG, Azimuth = 2.52 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleanin and control ECD's. 12:00 18:00 6.00 9,627 10,061 PROD1 DRILL DDRL P Continue Directional drill 6 3/4" hole in the A Lateral from 9627' - 10061' MD. TVD = 3792'. (434'). UP WT = 180K, SO WT = 90K, ROT WT = 130K. WOB = 5-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom 4-6K. Pumps @ 302 GPM's - 2940 PSI. ECD's @ 11.40 PPG, Max Gas observed = 60 Units. Total Bit Hrs = 29.39, Total Jar Hrs = 29.39. ADT = 3.92 HRS, ART = 3.92 Hrs. Survey @ 10061' MD, 3789' TVD, INC = 88.18 DEG, Azimuth = 359.29 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates. #1 pump @ 20 SPM - 460 PSI. 30 SPM - 760 PSI. #2 Pump @ 20 SPM -440 PSI, 30 SPM - 760 PSI. Crew Chan e Za~cJe ~7 of 37 Time Logs Date . From To Dur S. De th E_ Depth Phase Code S~;bcoda T -__- CC)M - -- - 05/30/2006 18:00 22:00 __ 4.00 - - 10,061 _ 10,373 - PROD1 DRILL DDRL P Continue Directional drill 6 3/4" hole in the A Lateral from 10061' - 10373' MD. TVD = 3780'. (312'). UP WT = 180K, SO WT = 90K, ROT WT = 120K. WOB = 5-10K, 120 RPM°s with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 312 GPM's -.3100 PSI. ECD's @ 10.94 PPG, Max Gas observed = 51 Units. Total Bit Hrs = 31.95, Total Jar Hrs = 31.95. ADT = 2.56 HRS, ART = 2.56 Hrs. Survey @ 10339' MD, 3784' TVD, INC = 95.43 DEG, Azimuth = 0.00 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates. #1 pump @ 20 SPM - 460 PSI. 30 SPM - 760 PSI. #2 Pump @ 20 SPM -440 PSI, 30 SPM - 760 PSI. Observe Assembly out of sand, discuss options with in town Geolgy. Decision to Pull back and erform o en hole sidetrack. 22:00 22:15 0.25 10,373 10,373 PROD1 DRILL SRVY NP Shoot surveys verifying bit position and for eolo 22:15 23:00 0.75 10,373 10,086 PROD1 DRILL REAM NP Back ream out of hole from 10373' - 10086'. 23:00 23:30 0.50 10,086 10,086 PROD1 DRILL SRVY NP Shoot multiple surveys for sidetrack, and recalibrate S er Sun MWD. 23:30 00:00 0.50 10,086 10,125 PROD1 DRILL SRVY NP Orient tool face at 150 Degrees left with 80% deflection on Geo-Pilot assembly to perform open hole sidetrack at 10086' MD. 05/31/2006 00:00 02:30 2.50 10,086 10,100 PROD1 DRILL DDRL NP Perform troughing operations for open • hole sidetrack, troughing from 10086' - 10100'. Observe kick off and inclination chan es kickin off at 10100' MD. 02:30 06:00 3.50 10,100 10,402 PROD1 DRILL DDRL NP Continue Directional drill 6 3/4" hole in the A Lateral from 10100' - 10402' MD. TVD = 3808'. (302'). UP WT = 175K, SO WT = 95K, ROT WT = 125K. WOB = 5-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 309 GPM's - 3150 PSI. ECD's @ 11.52 PPG, Max Gas observed = 51 Units. Total Bit Hrs = 34.44, Total Jar Hrs = 34.44. ADT = 2.49 HRS, ART = 2.49 Hrs. Survey @ 10342' MD, 3804' TVD, INC = 85.64 DEG, Azimuth = 356.85 Deg. Mud Wt = 8.75 PPG, Visc = 65, YP = 21. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates. #1 pump @ 20 SPM - 470 PSI. 30 SPM - 780 PSI. #2 Pump @ 20 SPM -460 PSI, 30 SPM - 780 PSI. Crew Chan e ^- P~~c~A 2~ ~f S7 ~ ~ Time Lis ~ i Date From To _ Dur 5. Depth E Uepth; Phase _ Code_ Subcod_e_ T _ COM 05/31/2006 06:00 12:00 6.00 10,402 T 10,716 PROD1 DRILL DDRL P Continue Directional drill 6 3/4" hole in the A Lateral from 10402' - 10716' MD. TVD = 3798'. (314'). UP WT = 190K, SO WT = 85K, ROT WT = 129K. WOB = 8-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 314 GPM's - 3230 PSI. ECD's @ 11.40 PPG, Max Gas observed = 53 Units. Total Bit Hrs = 38.75, Total Jar Hrs = 38.75. ADT = 4.31 HRS, ART = 4.31 Hrs. Survey @ 10624' MD, 3800' TVD, INC = 92.3 DEG, Azimuth = 1.86 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 20. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates. #1 pump @ 20 SPM - 520 PSI. 30 SPM - 800 PSI. #2 Pump @ 20 SPM 520 PSI, 30 SPM - 840 PSI. Observe Geo-Pilot failure, with 125% deflection. Could not correct. 12:00 12:30 0.50 10,716 10,716 PROD1 DRILL TRIP T POOH to 10700' MD. Pump to observe trouble and attempt to gain correction on Geo-Pilot assembl . No success. 12:30 17:00 4.50 10,716 9,254 PROD1 DRILL REAM T BROOH from 10716' - 9254'. Pumps at 305 GPM - 2950 PSI. Observe good hole conditions, with ro er hole fill. 17:00 18:00 1.00 9,254 9,254 PROD1 RIGMN' RGRP T Observe Top Drive swivel pack off failed. Install TIW floor valve on stand # 95. Make up circulation head & lines. Circulate @ 6 BPM - 2300 PSI, while reiprocate drill string. Change out Top Drive swivel ackin .Crew Chan e 18:00 18:45 0.75 9,254 9,254 PROD1 RIGMN RGRP T Continue change out Swivel packing on Top Drive. Breakout & blow down lines and remove TIW floor valve & circultin head. 18:45 00:00 5.25 9,254 6,258 PROD1 DRILL REAM T Continue BROOH from 9254' - 6258' MD. UP WT = 150K, SO WT = 105K. Rotate @ 60 RPM's, with 5-6K torque. Pumps @ 297 GPM - 2100 PSI. Back ream rate @ 50-60 ft/minute. Obtained T & D parameters as per rig engineer. Observe good hole conditions, proper hole fill. WWT representative on rig floor for inspection of Super Sliders on TOH. All sliders in correct position and in ood sha e. 06/01/2006 00:00 00:30 0.50 6,258 6,446 PROD1 DRILL REAM T Continue BROOH from 6258' -6446' MD. Inspecting Super Sliders as per WWT rep. All Sliders in good shape & in ro er osition. i~a~~ 2If of 47 Time. Logs - -- - -- - ~ ~ate From ' To Du r Depth S E Depth Phase Code Subcode T COM _ 06/01/2006 . 00:30 _ 01:00 _ 0.50 . 6,446 6,058 PROD1 __ DRILL TRIP T Continue POOH on elevators with 4 more stands inspecting Super Sliders as per WWT rep. All Sliders in good shape & in proper position. UP WT = 145K, SO WT = 110K. 01:00 02:30 1.50 6,058 6,058 PROD1 DRILL CIRC T Pump a Hi Visc weighted sweep with assembly in the shoe @ 300 GPM's 1775 PSI. Observe 10 % increase in cuttings at shakers when sweep returned and hole cleaned up. Pump Dry job. Monitor well -static. Grease u Swivel Packin 02:30 04:30 2.00 6,058 1,945 PROD1 DRILL TRIP T POOH on elevators from 6058' - 1945' MD. Observe proper hole fill, no swabbin . 04:30 06:00 1.50 1,945 348 PROD1 DRILL PULD T Pick up 1 single of 4" XT 39 to make full stand in BHA. POOH from 1945' to 348'. Rack back all 4" HWDP, Jars and accelerator. Crew Chan e 06:00 07:00 1.00 348 90 PROD1 DRILL PULD T Continue rack back BHA up to the MWD assembl . 07:00 07:45 0.75 90 90 PROD1 DRILL OTHR T Plug in and down load MWD assembly as er MWD re . 07:45 08:45 1.00 90 0 PROD1 DRILL PULD T Breakout & lay down Geo -Pilot & bit assembly. Inspect & grade bit. Bit graded @ 1 /2/BT/G!X/I /CT/ DTS. La down Flex Drill collar. 08:45 10:15 1.50 0 90 PROD1 DRILL PULD T Make up BHA #4. Make up 6 3/4" Security FMF 36412 PDC bit with 3 x 21's jets (1.29'), with %" 5200 GEO -Pilot (16.11').4 3/4" Non Mag G.P. Flex Drill collar (11.55').4 3/4" MWD Directional (8.56'), 4 3/4" Smart Stabilizer Sleeve Type (3.59'), 4 3/4" Gamma /Res (24.52'), 4 3/4" PWD (10.82'), 4 3/4" TM-HOC (11.27'), and 4 3/4" Non MA Float sub 2.38' . 10:15 10:45 0.50 90 90 PROD1 DRILL PULD T Plug in and Upload MWD assembly as er MWD re . 10:45 11:15 0.50 90 348 PROD1 DRILL PULD T Continue TIH with 4 3/4" Integral Blade stabilizer (4.58'), 3 joints Non Mag Flex Drill Collars (93.39'), Crossover 3.00' , 11:15 12:00 0.75 348 348 PROD1 DRILL TRIP T Screw into string with Top Drive & perform Shallow pulse test with pumps @ 250 GPM's - 1070 PSI. Rotate @ 25 RPM's. Good test. 12:00 12:30 0.50 348 1,945 PROD1 DRILL TRIP T Run remaining BHA, 1 -Joint 4" HWDP (30.68'), 4 3/4" Drilling Jars (32.25'), 1 -Joint 4" HWDP (30.69'). and 4" drill pipe to 1945'. Lay down single picked up for extra joint in stand. Double check all DP. gage ~~ gf ~3~ --- - - -- - i, Time Logs Date Fror~~ To Dur S Depth E De th Phase Code Subcooe T COM ._ _ _ _ _ 06/01/2006 12:30 _ 18:00 _ 5.50 1,945 _ 10,100 PROD1 . DRILL TRIP T Continue trip in hole from 1945' - - 10100'. Fill drill string every 25 stands. Observe hole taking proper hole fill, and controlling trip speed as not to sur a well. Crew Chan e 18:00 19:00 1.00 10,100 10,373 PROD1 DRILL REAM T Make up Top Drive> Wash & ream hole down to 10373' MD observing assembly tracked into old hole. 60 RPM's with pumps @ 230 GPMs - 2500 PSI. 19:00 19:30 0.50 10,373 10,080 PROD1 DRILL TRIP T Pull back to 10080'. 19:30 20:00 0.50 10,080 10,278 PROD1 DRILL REAM T Wash & ream again from 10080' - 10278' MD, attempting to steer into new hole. 233 GPM -2100 PSI. Obtain surveys & ABI to observe inclinations indicating once again assembly tracked into old hole. 20:00 20:30 0.50 10,278 10,080 PROD1 DRILL TRIP T POOH from 10278' - 10080' MD. 20:30 21:00 0.50 10,080 10,110 PROD1 DRILL TRIP T Begin troughing hole, at 10080' - 10110', until able to continue trip in hole . 21:00 21:30 0.50 10,110 10,716 PROD1 DRILL TRIP T Trip in hole back to 10273' MD observe tagging up on bridge. Survey inclinations assured assembly in new hole. Wash & ream from 10273' - 10283' (10'). Continue trip in hole from 10283' - 10716' MD. 21:30 00:00 2.50 10,716 10,939 PROD1 DRILL DDRL P Continue Directional drill 6 3/4" hole in the A Lateral from 10716' - 10939' MD. TVD = 3808'. (223'). UP WT = 180K, SO WT = 90K, ROT WT = 125K. WOB = 8-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 314 GPM's - 3230 PSI. ECD's @ 11.30 PPG, Max Gas observed = 57 Units. Total Bit Hrs = 1.62, Total Jar Hrs = 40.37. ADT = 1.62 HRS, ART = 1.62 Hrs. Survey @ 10905' MD, 3804' TVD, INC = 84.61 DEG, Azimuth = 358.38 Deg. Mud Wt = 8.8 PPG, Visc = 63, YP = 20. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Geologists indicating drilling out of sand 250' and consultin with town. 06/02/2006 00:00 00:30 0.50 10,939 10,939 PROD1 DRILL SRVY NP Geologists indicating drilling out of sand 250' and consulting with town. Pump to obtain surveys, for verification. Decision to pull back & erform o en hole sidetrack. 00:30 00:45 0.25 10,939 10,620 PROD1 DRILL TRIP NP POOH from 10939' - 10620'. Sidetrack Depth picked by onsite Geologist & Directional Driller. 00:45 01:15 0.50 10,620 10,620 PROD1 DRILL SRVY NP Obtain surveys for sidetrack corrections 10620' MD. r ~~e 31 ~f ~7 Time Low- -_ - - - - - - -- - _ - - -- _ _ -- ~, Date From To Dur Depth S. depth E Phase Code Subcode T COM _ _ _ _ 06/02/2006 01:15 03:30 2.25 .10,620 _ 10,640 PROD1 DRILL DDRL NP Begin troughing for open hole sidetrack from 10620' - 10640'. Pumps @ 307 GPM'-s -3300 PSI. torque @ 6K, with 100 RPM's. KOP @ 10640'.. Observe inclination change indicating sidetrackin as er DD. 03:30 06:00 2.50 10,640 10,840 PROD1 DRILL DDRL NP Continue Directional drill 6 3!4" hole in the A Lateral from 10640' - 10840' MD. TVD = 3809'. (200'). UP WT = 180K, SO WT = 90K, ROT WT = 125K. WOB = 8-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 309 GPM's - 3350 PSI. ECD's @ 11.30 PPG, Max Gas observed = 57 Units. Total Bit Hrs = 4.0, Total Jar Hrs = 42.75. ADT = 2.38 HRS, ART = 2.38 Hrs. Survey @ 10812' MD, 3804' TVD, INC = 86.07 DEG, Azimuth = 358.32 Deg. Mud Wt = 8.7 PPG, Visc = 69, YP = 23. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Crew Chan e 06:00 07:00 1.00 10,840 10,939 PROD1 DRILL DDRL NP Continue Directional drill 6 3/4" hole in the A Lateral from 10840' - 10939' MD. TVD = 3810'. (99'). UP WT = 180K, SO WT = 90K, ROT WT = 125K. WOB = 8-10K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 305 GPM's - 3250 PSI. ECD's @ 11.71 PPG, Max Gas observed = 53 Units. Total Bit Hrs = 4.62, Total Jar Hrs = 43.37. ADT .62 HRS, ART = .62 Hrs. Survey @ 10905' MD, 3809' TVD, INC = 88.42 DEG, Azimuth = 358.76 Deg. Mud Wt = 8.7 PPG, Visc = 67, YP = 17. Pump Hi Visc weighted sweeps to aid in hole cleanin and control ECD's. 07:00 12:00 5.00 10,939 11,315 PROD1 DRILL DDRL P Continue Directional drill 6 3/4" hole in the A Lateral from 10939' - 11315' MD. TVD = 3827'. (376'). UP WT = 180K, SO WT = 90K, ROT WT = 125K. WOB = 10-12K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 311 GPM's - 3350 PSI. ECD's @ 11.62 PPG, Max Gas observed = 58 Units. Total Bit Hrs = 7.64, Total Jar Hrs = 45.87 ADT = 3.12 HRS, ART = 3.12 Hrs. Survey @ 11282' MD, 3826' TVD, INC = 88.29 DEG, Azimuth = .14 Deg. Mud Wt = 8.7 PPG, Visc = 69, YP = 17. Pump Hi Visc weighted sweeps to aid in hole cleanin and control ECD's. ... i~~c~e 3~ of 3~ Time Lo~_ _ Date From To Dur S. Deth t. De th Phase _Code_ Subcode. T _ _COM __ __ _ _ __ ___ 06/02/2006 12:00 18:00 6.00 11,315 11,784 _ PROD1 DRILL DDRL P Continue Directional drill 6 3/4" hole in the A Lateral from 11315' - 11784' MD. TVD = 3855'. (469'). UP WT = 200K, SO WT = 85K, ROT WT = 127K. WOB = 10-12K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 304 GPM's - 3350 PSI. ECD's @ 11.80 PPG, Max Gas observed = 58 Units.Total Bit Hrs = 11.11, Total Jar Hrs = 48.24 ADT = 2.12 HRS, ART = 2.12 Hrs. Survey @ 11750' MD, 3852' TVD, INC = 85 DEG, Azimuth = .04 Deg. Mud Wt = 8.7 PPG, Visc = 69, YP = 17. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates. #1 pump @ 20 SPM - 490 PSI. 30 SPM - 790 PSI. #2 Pump @ 20 SPM 490 PSI, 30 SPM - 720 PSI. Crew Chan e 18:00 20:45 2.75 11,784 11,997 PROD1 DRILL DDRL P Continue Directional drill 6 3/4`' hole in the A Lateral from 11784' - 11997' MD. TVD = 3866'. (213'). UP WT = 200K, SO WT = 85K, ROT WT = 127K. WOB = 10-12K, 120 RPM's with Torque on bottom @ 6-7K, Torque off bottom @ 4-6K. Pumps @ 313 GPM's - 3250 PSI. ECD's @ 11.14 PPG, Max Gas observed = 58 Units.Total Bit Hrs =.12.77, Total Jar Hrs = 49.9 ADT = 1.66 HRS, ART = 1.66 Hrs. Survey @ 11997' MD, 3866' TVD, INC = 87.52 DEG, Azimuth = 359.65 Deg. Mud Wt = 8.7 PPG, Visc = 62, YP = 15. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates. #1 pump @ 20 SPM - 490 PSI.. 30 SPM - 790 PSI. #2 Pump @ 20 SPM 490 PSI, 30 SPM - 720 PSI. Crew Chan e 20:45 21:00 0.25 11,997 11,997 PROD1 DRILL SRVY P TD the well at 11997 MD, 3866' TVD as per Directional Driller. Obtain final surve s. 21:00 22:30 1.50 11,997 11,997 PROD1 DRILL CIRC P Circulate & condition mud, pumping a 25 BBL Hi Visc weighted sweep to clean hole. Rotate & reciprocate drill string @ 120 RPM's with 7K torque. Pumps at 300 GPM's - 3000 PSI. UP WT = 180K, SO WT = 90K, ROT WT = 125K, ECD = 11.16 PPG. Max gas observed = 40 Units. Observe shakers clean. 22:30 00:00 1.50 11,997 11,220 PROD1 DRILL TRIP P BROOH from 11997' - 11220'. Back ream rate at 90 RPM's with 7K torque. Pumps at 301 GPM's - 3000 PSI. UP WT = 180K, SO WT = 90K, ROT WT = 125K, MAx as observed = 40 Units. ~~ Page ?~ of !37 - __ - - - ~_Time Logs - - - - - - 1 ~Date From To Dur Depth S . E. Depfh Phase Code Subco__de T COM_ ~ 06/03/2006 00:00 02:00 2.00 _ _ 11,220 10,000 PROD1 DRILL TRIP P Continue BROOH from 11220' - 10000'. Monitor well -static. Blow down Top Drive & lines. WWT rep on rig floor inspecting Super Sliders. A-I looked ood and in correct osition. 02:00. 03:00 1.00 10,000 9,700 PROD1 DRILL TRIP P Continue POOH on elevators from 10000' - 9700' Observe good hole conditions and proper hole fill. Pump D Job. 03:00 04:30 1.50 9,700 6,424 PROD1 DRILL TRIP P POOH on elevators from 9700 - 6424' MD. Inside 7 5/8" casing shoe. Observe good hole conditions and proper hole fill. Monitor well -static. UP WT = 170K, SO WT = 100K. 04:30 06:00 1.50 6,424 8,380 PROD1 DRILL TRIP P Trip in hole from 6424' - 8380'. Observe tagging up on bridge, and setting all weight down. Work to continue in hole, crew chan e. 06:00 07:45 1.75 8,380 9,442 PROD1 DRILL REAM P . Continue working drill string in hole washinig & reaming down from 8380' - 9442'. Pump @ 280 GPM's- 2750 PSI. Rotate 50 RPM's. 07:45 08:15 0.50 9,442 9,630 PROD1 DRILL TRIP P Trip in hole on elevators from 9442' - 9630' observe losing string weight and to in u . 08:15 08:45 0.50 9,630 9,723 PROD1 DRILL REAM P Continue wash & ream from 9630' - 9723'. Pumps at 280 GPM's - 2750 PSI. Rotatin 70 RPM 08:45 09:45 1.00 9,723 10,126 PROD1 DRILL TRIP P Continue Trip in hole from 9723' - 10126' MD on elevators. 09:45 10:00 0.25 10,126 10,126 PROD1 DRILL SRVY P Screw into Top Drive & obtain MWD check shot surveys @ 10100' MD verifying assembly tracking into new hole. 10:00 11:00 1.00 10,126 10,752 PROD1 DRILL TRIP P Continue trip in hole from 10126' - 10752'. Observe no issues. 11:00 11:15 0.25 10,752 10,752 PROD1 DRILL SRVY P Screw into Top Drive & obtain MWD check shot surveys @ 10752' MD verifying assembly tracking into new hole. 11:15 11:45 0.50 10,752 11,036. PROD1 DRILL TRIP P Continue trip in hole from 10752' - 11306'. Screw into Top Drive utilizing TD weight to push drill string in hole. No um s or rotation. 11:45 12:30 0.75 11,036 11,036 PROD1 DRILL CIRC P Pumps on, circulate hole clean as per Co. Rep. Pump @ 280 GPM's - 2950 PSI. Reciprocate & rotate drill string until hole cleaned up. Observe sand & cuttin s across shakers. 12:30 14:30 2.00 11,306 11,997 PROD1 DRILL REAM P Continue wash & ream in hole from 11036' - 11997' MD = TD. Pumps at 280 GPM's - 2950-3250 PSI. Pump sweep observing ECD's climbing to 12.05 PPG EMW. ~'~g~ ~; of ~7 - _ _ ~ - - ~ime Low - - - -~ -- _. - ..Date From To Dur S De th E De th"Phase Code Subcode _T COP~I _- T Circulate hole clean, pumping 50 BBL 06/03/2006 14:30 16:00 1.50 11,997 11,990 PROD1 DRILL CIRC P Hi-Visc weighted sweep @ 280 GPM's - 3250 PSI. Pull 1 stand and rack back same. 16:00 16:30 0.50 11,990 11,990 PROD1 RIGMN SVRG P Make up Top drive & service Swivel Packing. Run stand back in hole to TD. 16:30 17:00 0.50 11,990 11,997 PROD1 DRILL CIRC P Continue Circulate hole clean, pumping 50 BBL Hi-Visc weighted swee 280 GPM's - 3250 PSI. 17:00 18:00 1.00 11,997 11,997 PROD1 DRILL CIRC P Pump 8.8 PPG SFMOBM to displace lateral with 250 BBLs. Leave 70 BBLS in drill strin .Crew Chan e 18:00 18:15 0.25 11,997 11,997 PROD1 DRILL OWFF P Monitor well -static. Prepare floor for POOH with drill strin . 18:15 18:45 0.50 11,997 11,660 PROD1 DRILL TRIP P POOH from 11997' - 11660' MD. Observe OBM out of balance and flowin over to of drill i e. 18:45 19:30 0.75 11,660 11,660 PROD1 DRILL CIRC P Mak up Top Drive. Mix & Pump 20 BBL dry job 2 pounds over mud wei ht.Blow down To Drive & lines. 19:30 00:00 4.50 11,660 5,790 PROD1 DRILL TRIP P Continue POOH from 11660' - 5790'. Observe good hole conditions, and ro er hole fill. 06/04/2006 00:00 02:15 2.25 5,790 1,945 PROD1 DRILL TRIP P Continue POOH from 5790' - 1945'. Observe good hole conditions, and proper hole fill. Drop 2 1/4" Drift in Drill strin .Obtain SLM on TOH. 02:15 02:45 0.50 1,945 1,780 PROD1 DRILL PULD P Breakout & lay down 4 3/4" Accerlerator Jar 32.09'), and 4 3/4" Mechanical drilling Jar (32.04'). Standin back 1 stand of 4" DP. 02:45 04:30 1.75 1,780 90 PROD1 DRILL TRIP P Rack back 16 stands of 4" DP (10502.72'), and 4" HWDP (30.69', 30.68'). Breakout & lay down DNT Mechanical Jars (32.25'). Stand back 4 3/4" Non Mag Flex Drill Collars 93.39' . 04:30 05;15 0.75 90 90 PROD1 DRILL PULD P Plug in and download MWD assembly. Pull up to break out bit. Inspect & grade sameto2/1 /CT/N/X/I/ NO / TD as per directional driller. Clean & clear floor area. 05:15 06:00 0.75 90 0 PROD1 DRILL PULD P Continue breakout & lay down BHA. Lay down 6 3/4" Security FMF 36412 PDC bit with 3 x 21's jets (1.29'), with %" 5200 GEO -Pilot (16.11').4 3/4" Non Mag G.P. Flex Drill collar (11.55'). 4 3/4" MWD Directional (8.56'), 4 3/4" Smart Stabilizer Sleeve Type (3.59'), Crew Chan e. Yee 3~ t~f 87 -- - - - - - ~ Time L~ Date From To _ _ Dur____ S Depth E. De th E'hase . Code Subcode _ .T (:OM 06/04/2006 06:00 06:30 0.50 0 0 PROD1 DRILL PULD P Continue Breakout & lay down BHA. Lay down 4 3/4" Gamma /Res (24.52'), 4 3/4" PWD (10.82'), 4 3/4" TM-HOC (11.27'), and 4 3/4" Non MAg Float sub (2.38'). Note: SLM indicated no correction needed on DP Tall . 06:30 07:00 0.50 0 0 PROD1 DRILL OTHR P Clear & clean rig floor of OBM and slip Hazards. 07:00 09:30 2.50 0 0 COMPZ CASIN( RURD P Rig up to run 4 1/2" Slotted Liner assembly. Pick up all handlling tools, and set all Spiralglider Centralizers on rig floor (120). Held PJSM with crew & BOT rep. Discuss Safety Issues and procedure for picking up and running 4 1!2" Liner. Identi "inch Points". 09:30 12:00 2.50 0 2,247 COMPZ CASIN< RUNL P Make up 4 1/2" Shoe Joint with ROT Silver Bullet Guide Shor (1.65'), Crossover pup (.63'), and Bfank joint (41.33'). Continue run 4 1/2" Slotted liner as per detail to 2247', installing SpiralGlider Centralizers 1 per joint except for joints with constrictor packers installed. Make up torque = 3800 ft/Ibs. 12:00 16:00 4.00 2,247 6,479 COMPZ CASIN( RUNL P Continue run 4 1/2" Slotted liner as per detail from 2247' - 6479', installing SpiralGlider Centralizers 1 per joint except for joints with constrictor packers installed. Make up torque = 3800 ft/Ibs. 16:00 16:45 0.75 6,479 6,535 COMPZ CASIN( RUNL P Make up Baker HRD ZXP Liner Top Packer (18.90') with RS PAckoff Seal Nipple (2.85'), Flexlock Liner Hanger (9.83'), 190-47 Casing Seal Bore Extension (19.65'), XO Bushing (1.41'), and 4 1/2" BTCM pup (3.79') as per BOT re .Total Liner len th = 6535'. 16:45 17:45 1.00 6,535 6,535 COMPZ CASIN( KURD P Clean & clear rig floor of all liner handling equipment including tongs elevators etc..Double check count on all Ccentralizers ran. 117 . 17:45 18:00 0.25 6,535 6,535 COMPZ CASIN( OTHR P Transfer & position 4" DP stands in derrick to utilize all DP with Super Sliders installed. Crew Chan e 18:00 19:00 1.00 6,535 6,535 COMPZ CASIN( OTHR P Continue Transfer & position 4" DP stands in derrick to utilize all DP with Super Sliders installed. Move 10 stands total 19:00 00:00 5.00 6,535 11,700 COMPZ CASIN( RUNL P Continue run 4 1/2" Slotted liner from 6535' - 11700' MD on Drill pipe from derck. Drop a 2 1/4" Drift in last 30 stands as DP had been chnaged in derrick. Observe good hole conditions, and running speed of 60' /minute as er BOT re . Time Logs r S. De th E. tDe th Phase Code SufJCOde T _ COM Date From To Du _ _ 06/05/2006 00:00 01:00 1.00 11,700 11,997 COMPZ CASINC RUNL P Continue run 4 1/2" Slotted liner from 11700' - 11997' MD on Drill pipe from deriick. Dropped a 2 1/4" Drift in last 30 stands as DP had been changed in derrick. Observe good hole conditions working through tight spots @ 11750' 11921' MD, and running speed of 60' / minute as per BOT rep. UP WT = 180K, SO WT = 80K. 01:00 02:15 1.25 11,997 11,989 COMPZ CASIN( RUNL P Tag TD at 11997' Pick up to locate on depth for constrictor settings.Guide shoe @ 11989'. Top of ZXP Liner = 5454' MD. Drop 1 3/4" Ball as per BOT rep, pump 40 BBLS allowing ball to seat. Pressure to 2000 PSI to set Liner Hanger, Set down 70K, continue pressure up to 3000 PSI to set ZXP PKR. Continue pressure to 3300 observing pressure equalized, and then to 4000 PSI to release setting tool. Bleed pressures. Rig up on test chart to perform annular test to 1000 PSI for 5 minutes. Good test. Bleed pressures. Pull up slow to observe setting Tool released from liner with an U wei ht of onl 143K. 40K lost. 02:15 06:00 3.75 5,454 40 COMPZ CASIN( RUNL P Pump Dry job. Blow down Top Drive lines. Monitor well -static. POOH rack back 4" DP. Breakout, Inspect & lay down Liner running tool as per BOT Re . 06:00 07:00 1.00 40 0 COMPZ CASIN( OTHR P Continue Breakout, Inspect & lay down Liner running tool as per BOT Rep. Clear & clean floor area. 07:00 08:30 1.50 0 0 COMPZ EVALVI~ SFTY P Held PJSM with crew &SWS reps. Discuss Safety Issues and procedure picking up E-line tools and running same. Rig SWS wireliners, sheaves etc.. 08:30 12:00 3.50 0 0 COMPZ EVAL1l~ ELOG P Make up E-Line tools and WLIH from surface to tag top of liner @ 5454'. Log for USIT SIMOPS: Load pipe shed with drill collars and 4" HWDP to make up 20 stands of Hybrid Push Pipe. Stra all i e. 12:00 15:30 3.50 0 0 COMPZ EVALVI~ ELOG P Contine wirline logging obtaining USIT log. WLOH, Rig. down all Sheaves and SWS equipment. Clear & clean Rig floor. 15:30 16:00 0.50 0 0 COMPZ RIGMN SVRG P Service & Inspect Top Drive. 16:00 16:30 0.50 0 0 COMPZ DRILL OTHR P Reposition stands of DP in derrick to make room for Hybrid Push pipe stands. P~ac~e 37 ~sf ~7 --- __ Time Logs _ --- -- - Dafe From To Dur S. Depth E_ De th Phase Code Supcode T CUM _ _ _ 06/05/2006 16:30 _ 18:00 1.50 _ 0 _ 0 _ COMPZ DRILL OTHR P Pick up NEW 5" Drill collars and 4" HWDP. Make up stands 2 joints of collars and 1 joint of HWDP for Push pipe stands. Make & break 2 times as reccommended for new pipe handling rocedures.Crew Chan e 18:00 23:00 5.00 0 0 COMPZ DRILL OTHR P Continue Pick up NEW 5" Drill collars and 4" HWDP. Make up stands 2 joints of collars and 1 joint of HWDP for Push pipe stands. Make & break 2 times as reccommended for new pipe handling procedures. Total of 20 stands of Push Pipe in derrick. Clear & clean floor area. Pull mouse ho-e from Rotary table, install in mousehole slot in floor. 23:00 23:30 0.50 0 0 COMPZ DRILL SFTY P Held PJSM with crew, BOT rep, and Sperry sun MWD. Discuss safety issues and procedure for picking up 7 5/8" Whipstock Assembly. Pull all tools to rig floor. Crew Change - chan a out da 23:30 00:00 0.50 0 0 COMPZ DRILL PULD P Pick up 2 joints of 3 1/2" space out drill pipe with Unloader sub and seals. as er BOT re . 06/06/2006 00:00 00:30 0.50 0 0 COMPZ DRILL PULD P POOH lay down 2 joints of space out pipe &Unloader sub with seals for whipstock run. Decision to test BOP's before TIH with Whipstock. Attempted to contact AOGCC. Left Messages as we were over our test date b 3 da s. 00:30 01:30 1.00 0 0 COMPZ WELCT BOPE P Held PJSM with crew. Discuss Safety Issues and procedure for testing BOP's. Ri u to test BOP's. 01:30 06:00 4.50 0 0 COMPZ WELC7 BOPE P Test Bop's. Test 06:00 07:00 1.00 0 0 COMPZ WELC7 BOPE P Continue testing BOPE, 250 psi low and 3000 psi high, 5 min each chart test.. Kommey test and floor safety valves. Dart valve failed to test. 07:00 07:15 0.25. 0 0 COMPZ WELC7 SFTY P PJSM on testing BOPE. 07:15 08:30 1.25 0 0 COMPZ WELCl' BOPE P Testing BOPS. Rig down floor safety valves, lay down test joint. Test blinds to 250 psi low and 3000 psi high. Test top drive Upper and lower IBOP. Lower valve failed test. 08:30 09:00 0.50 0 0 COMPZ WELCT BOPE T Rig up to re-test floor dart valve. Tested good to 250 psi low and 3000 psi hi h.. Ri down test. 09:00 09:15 0.25 0 0 COMPZ RIGMN SFTY T PJSM on changing out lower IBOP f/ to drive. 09:15 11:15 2.00 0 0 COMPZ RIGMN RGRP T Change out lower IBOP on top drive. Chan a out saver sub at same time. 11:15 12:00 0.75 0 0 COMPZ WELCT BOPE P Re test lower IBOP to 250 psi low and 3000 si hi h. Good test. t'~ge 3~ gat X37 -- ---- - Time Logs - --- -- -- Date From To Dur S Lie th E De th Phase Code Subcode T CQM 06/06/2006 12:00 14:00 2.00 0 0 COMPZ RIGMN SVRG P Service top drive and rig. 14:00 14:45 0.75 0 0 COMPZ WELCT OTHR P Pull test plug.. Drain stack. Set wear buskin . 14:45 15:00 0.25 0 0 PROD2 DRILL SFTY P PJSM on picking up whipstock BHA BHA #5 . 15:00 17:30 2,50 0 238 PROD2 DRILL PULD P Start PU Whipstock BHA (BHA #5) f/ "B" lateral. 17:30 18:00 0.50 238 238 PROD2 DRILL OTHR P Upload Sperry Sun MWD tool. 18:00 19:15 1.25 238 520 PROD2 DRILL OTHR P Continue upload Sperry Sun MWD tool. MU 3 stands of H brid collars. 19:15 19:30 0.25 520 520 PROD2 DRILL OTHR P Shallow test MWD tools. Blow down to drive. 19:30 22:00 2.50 520 3,400 PROD2 DRILL TRIP P RIH w/ 4" drill pipe f/ 520' to 3400'. Fill i e eve 25 stands. 22:00 00:00 2.00 3,400 3,775 PROD2 DRILL OTHR P Mad pass logging w/o pumping f/ 3400' seal depth (GR @ 3236') to 3775' seal depth (GR @ 3611.51'). Max 300' per hr to in rate. 06/07/2006 00:00 05:30 5.50 3,775 4,637 PROD2 DRILL OTHR P Mad pass logging w/o pumping f/ 3775' seal depth (GR @ 3611.51') to 4637' seal depth (GR @4473.51'). Max 300' per hr logging rate. Logging w/ Sperry Sun sonic f/ cement top on 7-5/8" cement 'ob. 05:30 06:00 0.50 4,637 4,730 PROD2 STK OTHR P Mad pass logging with pumps 60 spm (253 gpm) w/ 1680 psi f/ 4637' seal depth (GR @ 4473.51') to 4730' seal depth (GR @ 4566.51'). Max 300' per hr logging rate. Logging K-13 marker corrolation with whipstock assembly for proper spaceout of whipstock and window 06:00 08:00 2.00 4,730 5,360 PROD2 STK TRIP P Continue trip in hole w/ Baker whipstock assembly f/ 4730' to approx 5412' seal depth. Orient whipstock to final of 16 deg left of high side and slack off to top of ZXP packer @ 5454.12' (top of whipstock @ 5359.76') Set anchor w/ 20k down wt. Break mills free f/ whipstock slide w/ 40k. PU wt 160k. SO wt 140k. 08:00 12:00 4.00 5,358 5,370 PROD2 STK MILL P Take SPR's. # 1 mp @ 20 spm = 310 psi, 30 spm = 530 psi. #2mp @ 20 spm =300 psi, 30 spm = 520 psi. Start milling window in 7-5/8" casing @ 5358' (3569' TVD). Bottom of window @ 5370' (3572' TVD). Pump high vis weighted sweep 63 spm (268 gpm) w/ 1850 psi. Torque while milling 4-7k ft Ib, weight on mills 2-4k, 100 rpm. MW 8.8 wlvis=78. 12:00 13:00 1.00 5,370 5,389 PROD2 STK MILL P Continue to mill window. Starter mill f/ 5370' to 5389' (19'). Top of window @ 5358' MD (3569' TVD), bottom of window 5370' MD 3572' TVD . P~cJe 3~ of 37 __ - _ Time_Logs _ _ _ '-Date From To_ Dur S. De th_ c Depth_ Phase_ _ Code __ Subcode T _ COM __ __ _ 06/07/2006 13:00 13:45 0.75 5,389 5,389 PROD2 STK CIRC P Pump 20 bbl Hi vis/Low vis weighted sweep @ 5389'. Pumping 300 gpm w/ 2350 psi. Torque on bottom 4-7k ft Ib. Torque off bottom 3-4 k ft Ib. Weight on mills 2-4k. 110 rpm. Rot weight 158k. PU wt 160k. SO wt 140k. 13:45 14:00 0.25 5,389 5,389 PROD2 WELCT OWFF P Monitor well. OK. 14:00 14:30 0.50 5,389 5,389 PROD2 STK CIRC P Pump dry job, blow down top drive, fill tri tank. 14:30 18:00 3.50 5,389 144 PROD2 STK TRIP P POOH w/ BHA #5 (Whipstock f/ "B" lateral f/ 5389' to 144'. 18:00 18:30 0.50 144 144 PROD2 STK OTHR P Change out elevators and download S ei- Sun MWD. 18:30 19:45 1.25 144 0 PROD2 STK PULD P UD BHA. Clean and clear rig floor of Baker handling tools. Upper mill 19:45 20:30 0.75 0 0 PROD2 STK OTHR P PU 4" test joint, MU crossover and wear rin uller. Pull wear bushin . 20:30 21:45 1.25 0 0 PROD2 STK OTHR P Pickup stack flushing tool, flush stack, passing tool up and down past ram cavities. Drain stack. Blow down kill line and choke manifold. Blow down to drive. 21:45 22:15 0.50 0 0 PROD2 STK OTHR P Set wear bushing. 22:15 00:00 1.75 0 97 PROD2 DRILL PULD P Pickup and MU Hycalog 6-3/4" CRXE 1005H+GJV bit, and 5" Sperrydrill lobe 6/7- 6 stage w/ ABI mtr. Change bend angle f/ 1.22 deg to 1.5 deg, NM float sub, integral blade stabilizer (6.5" OD), NM terminating sub, Gamma/Res, DM-HOC, PWD, TM-HOC, Lay down Baker bumper sub, UD Sperry Bat tool. De th is 96.68' midni ht. 06/08/2006 00:00 00:30 0.50 97 97 PROD2 DRILL PULD P UD Sperry Sun TM and change out pulsar. Continue PU BHA #6 per S er Sun directional driller. 00:30 01:00 0.50 97 97 PROD2 DRILL OTHR P Sperry Sun upload MWD. 01:00 01:30 0.50 97 97 PROD2 DRILL PULD P Shallow test MWD. 300 gpm w/ 2000 - 2150 si.OK. 01:30 02:00 .0.50 97 1,216 PROD2 DRILL PULD P MU stand of flex collars, x-o, (1) 4" HWDP, Daily DNT meth jars, (1) 4" HWDP, (10) stands of 4" slick drill i e f/ derrick. 02:00 03:00 1.00 1,216 1,507 PROD2 .DRILL TRIP P Run (3) stands 4" dp f/ derrick. Remove su er sliders 2 er'oint . 03:00 03:30 0.50 1,507 1,529 PROD2 DRILL PULD P PU/MU x-o, anderguage agitator and shock sub, x-o. Pump @ 270 gpm w/ 3000-3385 psi. Unable to get MWD detection, noise. 03:30 03:45 0.25 1,529 1,841 PROD2 DRILL PULD P Run (3) stands Weatherford 4" dp, removing super sliders (2 per joint). PU/MU Dail DNT meth 'ars. e ia~~;;t3 °-rQ 4f ~7 Time Logs ~ -- - Date From To D_ur S Depth EDepth_ Phase_ Code _ _Subcode T COM - - _ 06/08/2006 03:45 04:00 0.25 1,841 1,966 PROD2 DRILL PULD P Run (1) stand Weatherford 4" drill pipe, removing super slideres (2 per joint). PU/MU Dail accelerators. 04:00 05:00 1.00 1,966 2,620 PROD2 DRILL TRIP P Continue RIH w/ BHA #6 on Weatherford 4" dp f/ 1966' to 2620'. Removing super sliders (2 perjoint). Note: Removed total of 14 stands of super sliders (84 super sliders removed) (37 stands in derrick have super sliders for total of 204 super sliders in derrick . 05:00 05:30 0.50 2,620 . 2,620 PROD2 DRILL CIRC P MU stand # 25, fill pipe, Test MWD while pumping 285-295 gpm w/ 3300 si. 05:30 06:00 0.50 2,620 4,122 PROD2 DRILL TRIP P Continue RIH w/ BHA #6 f/ 2620' to 4122'. 06:00 07:45 1.75 4,122 5,248 PROD2 DRILL TRIP P Crew change, continue RIH f/ 4122' to 5248'. Note: Window top @ 5358' MD/ 3569' TVD 07:45 08:00 0.25 5,248 5,248 PROD2 RIGMN SFTY P PJSM on slip and cut drilling line. 08:00 11:00 3.00 5,248 5,248 PROD2 RIGMN SVRG P Slip and cut 80' of 1-3/8"drilling line. Service to drive and crown. 11:00 12:00 1.00 5,248 5,341 PROD2 DRILL OTHR P Set block height f/ Totco and Sperry sun depth tracking. Fill pipe, orient to high side. Take slow pump rates: #1 mp 20 spm = 530 psi, 30 spm = 890 psi. #2 mp @ 20 spm =540 psi, 30 spm = 910 psi @ 5341'md, 8.7 ppg mw. - t'~g~ =~1 a°t r37 Time Loci - - - - - - _ Date ---- From -- To Dur 5. Depth, - E Depth Phase - Code Subcode T- ~ COM_ 06/08/2006 12:00 18:00 6.00 5,341 5,610 PROD2 DRILL DDRL P Directional Drill 6-3/4" hole w/ 5" Sperry drill 6/7 lobe - 6.0 stage mtr wlabi w/ 1.50 deg bend from 5389' -561.0' (221') (TVD = 3579'). ART = 3.55 hrs, AST = 1.04 hrs. Total hrs on bit = 4.59 hrs., Total hrs on jars = 56.11 hrs, 5-10k WOB, 90 rpm's, 207-230 mtr rpm, 269-299 gpm w/ 8.8 ppg MW, on bottom press 2970-3440 psi, off bottom press 3020-3250 psi, on bottom torque 2-5k ft/Ib, off bottom torque 3-5k ft/ Ib, PU wt 140k, SO wt 115-120k, Rot wt 122-127k. ECD's = 9.62-9.92 PPg• PWD baseline was performed while drilling @ 5542' w/8.7 ppg MW. Pumping 275 gpm w/ 3030 psi, 70 rpm = 9.68 ppg ECD, 90 rpm = 9.71 pP9 ECD. Pumping 300 gpm w/ 3430 psi, 70 rpm = 9.72 ppg ECD, 90 rpm = 9.74 ppg ECD. Concreations drilled :5359' to 5361' (2'), 5381' to 5385' (4'), 5387' to 5392'. (5'), 5432' to 5446' (14'), 5539' to 5548' (9'), 5595 to 5610' (15') (still till 5621' for total of 26' 18:00 00:00 6.00 5,610 6,111 PROD2 DRILL DDRL P Directional Drill 6-3/4" hole w/ 5" Sperry drill 6/7 lobe - 6.0 stage mtr w/abi w/ 1.50 deg bend from 5610' -6111' (501') (TVD = 3593'). ART = 2.45 hrs, AST = .69 hrs. Total hrs on bit = 7.73 hrs., Total hrs on jars = 59.25 hrs, 5-10k WOB, 90 rpm's, 217- 231 mtr rpm, 282-300 gpm w/ 8.8 ppg MW, on bottom press 3330-3400 psi, off bottom press 2700-3300 psi, on bottom torque 4-5k ft/Ib, off bottom torque 4k ft/ Ib, PU wt 135-138k, SO wt 112k, Rot wt 125k. ECD's = 9.79 - 10.0 ppg. BG gas 45-50 units. Concreations drilled: still a concreation from 5610' to 5621' (11'), 5715' to 5722' (T), 5739' to 5752' (13'), 5834' to 5838' (4'), 6107' to 6110' (3'). concreation drilling: slowed rpm to 70, increased WOB to 10-12k. Page r~~ of 37 Time Logs __ _ _ ~ Date From To Dur S Depth E Depth Phase Code Subcode T COM ___ ___ __ 06/09/2006 00:00 06:00 6.00 6,111 6,747 PROD2 DRILL DDRL P Directional Drill 6-3/4" hole w/ 5" Sperry drill 6/7 lobe - 6.0 stage mtr w/abi w/ 1.50 deg bend from 6111' -6747' (636') (TVD = 3599'). ART = 3.43 hrs, AST = .28 hrs. Total .hrs on bit = 11.44 hrs., Total hrs on jars = 62.96 hrs, 2-12k WOB, 90 rpm's, 231- 234 mtr rpm, 300-304 gpm w/ 8.7 ppg MW, on bottom press 3320-3450 psi, off bottom press 3200- 3300 psi, on bottom torque 4-5k ft/Ib, off bottom torque 4k ft/ Ib, PU wt 138- 140k, SO wt 112k, Rot wt 123-125k. ECD's = 9.77-10.4 ppg. BG gas 45-58 units. Concreations drilled: 6209' to 6219' (10'), 6226' to 6252' (26'), 6267' to 6270' (3'), 6311' to 6316' (5'), 6433' to 6434' 1' , 6736' to 6739' 3' . 06:00 12:00 6.00 6,747 7,332 PROD2 DRILL DDRL P Directional Drill 6-3/4" hole w/ 5" Sperry drill 6/7 lobe - 6.0 stage mtr w/abi w/ 1.50 deg bend from 6747' -7332' (585') (TVD = 3606'). ART = 3.13 hrs, AST = .39 hrs. Total hrs on bit = 14.96 hrs., Total hrs on jars = 66.48 hrs, 10-15k WOB, 70-90 rpm's, 227- 231 mtr rpm, 295-301 gpm w/ 8.7 ppg MW, on bottom press 3410-3630 psi, off bottom press 3280-3400 psi, on bottom torque 4-6k ft/Ib, off bottom torque 4-5k ft/ Ib, PU wt 140-145k, SO wt 110k, Rot wt 125-122k. ECD's = 9.73-10.12 ppg. Gas 40-77 units. Concreations drilled: 6789' to 6795' (6'), 6817' to 6818' (1'), 6847' to 6854' (7'), 6894' to 6899' (5'), 6917' to 6921' (4'), 6956' to 6963' (7'), 6975' to 6977' (2'), 7177' to 7179' (2'), 7267' to 7275' (8'), 7288' to 7294' (6'), 7291' to 7294' 3' . Pa~ae ~~ cf 87 i Time Logs _ _ --- Date ___ _ From To___ Dur S, Uepth E. De th Phase Code Subcode T COM _ __ __ 06/09/2006 12:00 18:00 6.00 7,332 7,878 PROD2 DRILL DDRL P Directional Drill 6-3/4" hole w/ 5" Sperry drill 6/7 lobe - 6.0 stage mtr w/abi w/ 1.50 deg bend from 7332' -7878' (546') (TVD = 3610'). ART = 1.68 hrs, AST = 1.69 hrs. Total hrs on bit = 18.33 hrs., Total hrs on jars = 69.85 hrs, 5-15k WOB, 90 rpm's, 224- 232 mtr rpm, 291-302 gpm w/ 8.7 ppg MW, on bottom press 3440-3610 psi, off bottom press 3330-3460 psi, on bottom torque 4-5k ft/Ib, off bottom torque 4-5k ft/ Ib, PU wt 145-150k, SO wt 110-105k, Rot wt 125-122k. ECD's = 10.1-10.46 ppg. Gas 40-86 units. 7494' --With pumps on: SO wt 105k, Rotating 90 rpm SO wt 120k. Concreations drilled :7495' to 7512' (17'), 7516' to 7531' (15'), 7536' to 7542' (6'), 7564' to 7569' (5'), 7625' to 7627' (2'), 7722' to 7727' (5'), 7759` to 7768' 9' . 18:00 00:00 6.00 7,878 8,277 PROD2 DRILL DDRL P Directional Drill 6-3/4" hole w/ 5" Sperry drill 6/7 lobe - 6.0 stage mtr w/abi w/ 1.50 deg bend from 7878' -8277' (399') (TVD = 3621.6'). ART = 2.04 hrs, AST = 1.14 hrs. Total hrs on bit = 21.51 hrs., Total hrs on jars = 73.03 hrs, 5-15k WOB, 90 rpm's, 227- ' 231 mtr rpm, 295-300 gpm w/ 8.7 ppg MW, on bottom press 3630 - 3750 psi, off bottom press 3530- 3600 psi, on bottom torque 4-6k ft/Ib, off bottom torque 4-5k ft/ Ib, SPR @ 8056' MD 3605' TVD 9.6+ MW: #1 mp @ 20 spm = 600 psi, 30 spm = 950 psi SPR @ 8056' MD 3605' TVD 9.6+ MW: #2 mp @ 20 spm = 610 psi, 30 spm = 950 psi PU wt 150-152k, SO wt 110-98k, Rot wt 125k. ECD's = 10.52- 10.2 ppg. Gas 40-86 units. 7494' --With pumps on: SO wt 105k, Rotating 90 rpm SO wt 120k. 7964' --With pumps on: SO wt 105k, Rotating 90 rpm SO wt 120k. 8277' --With pumps on: SO wt 80k, Rotating 90 rpm SO wt 115k. Concreation drilled @ 7963' to 7966' 3' . P~c~~ ~4 of II7 Time Loc i __ _ Date From To Dur S De th E, De th Pnase Code Subcode T C0~~~1 _ _ __ 06/10/2006 00:00 06:00 6.00 8,277 8,565 PROD2 DRILL DDRL P Continue drilling from 8,277 (3610' TVD) to 8565' (288') (3,632' TVD) Bit hours =24.78 hrs. Jar hours=76.30. AST=1.36, ART=1.91, ADT=3.27, WO6=5-15K, 90 rpm„ 300 gpm, @ 3800 psi on bottom, 3650 psi off bottom. Torque= 5K ft-Ibs on bottom and 4-5K ft-Ibs off bottom, P/U=155k, S/O=95k. Rot=125k, Gas=40-90 units. ECD= 10.4 ppg. Flow out = 27%. [@ 8431' MD P/U w/ pumps on=150k, S/O w/ pump on = 90 k, Rot wt w/ pump on = 120 k.] Concreations drilled :8339 to 8343' (4'), 8480' to 8488' (8'), 8510' to 8519' 9' , 06:00 12:00 6.00 8,565 8,890 PROD2 DRILL DDRL P Continue drilling from 8565' (3,632' TVD) to 8890' (325') (3, 640' ND) Bit hours= 28.62, Jar hours= 80.14, AST=2.36, ART=1.48, ADT=3.84, WO6=5-15k, 90 rpm, Mtr rpm 215-224, 279-291 gpm @ 3430-3250 psi on bottom and 3330-3190 psi off bottom. Torque=5-7k ft-Ibs on botttom and 5k ft-Ibs off bottom. ECD= 10.1-10.4 ppg. Gas = 50-101 units. P/U = 155k, S/O = 102k, Rot= 120-125k w/ pump off. S/O w/ pump on @ 90 rpm = 118k w/o rotating = 103k @ 8890'. Adding LVT= 5 bbl/hr. Concreations drilled :8738' to 8742' 4' , 8775' to 8781' 6' . 12:00 18:00 6.00 8,890 9,273 PROD2 DRILL DDRL P Continue drilling from 8890' (3,640' ND) to 9273' (383') (3, 644' ND) Bit hours= 33.01, Jar hours= 84.53, AST=.63, ART=3.76, ADT=3.84, WO6=5-15k, 70-90 rpm, Mtr rpm 226- 212, 294-275 gpm @ 3430-3250 psi on bottom and 3420-3280 psi off bottom. Torque=5-7k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.5-10.63 ppg. Gas = 61-94 units.. P/U = 155-160k, S/O = 102-100k, Rot= 125-122k w/pump off. .Adding LVT= 7 bbl/hr Concreations drilled: 8890' to 8902' (12'), 905' to 9008' (3'), 9056' to 9068' (12'), 9161' to 9176' (15'), 9182' to 9184' (2'), 9187' to 9192' (5'), 9226' to 9231' (5'), 9236' to 9244' (8'), 9265' to 9277 12' . Time Logs Date From To Dur S De th E Depth Phase _ Code_ Subcode T ~ COM __ _ _ __ ~ 06/10/2006 18:00 00:00 6.00 9,273 9,517 PROD2 DRILL DDRL P Continue drilling from 9273' (3,644' TVD) to 9517' (244') (3, 650' TVD) Bit hours= 36.63, Jar hours= 88.15, AST=1.07, ART=2.55, ADT=3.62, W0B=8-15k, 70-90 rpm, Mtr rpm 211-215, 275-280 gpm @ 3400-3460 psi on bottom and 3280-3400 psi off bottom. Torque= 5-7k ft-Ibs on botttom and 4-6k ft-Ibs off bottom. ECD= 10.58-10.6 ppg. Gas = 45-85 units. P/U = 160-155k, S/O = 100- 95k, Rot= 122-125k w/ pump off. Pumps on rotating 120k, 155 PU wt and 95k SO wt. Concreations drilled :still f/ 9273' to 9277', 9285' to 9292' (7'),.9300' to 9306' (6'), 9339' to 9352' (13'), 9432' to 9443' (11'), 9456' to 9463' (T), 9466' to 9473'. T. 06/11/2006 00:00 06:00 6.00 9,517 9-,780 PROD2 DRILL DDRL P Continue drilling from 9517' (3,650' TVD) to 9780' (263') (3, 655' TVD) Bit hours= 40.75, Jar hours= 92.27, AST=1.08, ART=3.04, ADT=4..12, W06=8-12k, 70-90 rpm, Mtr rpm 216-217, 280-282 gpm @3460-3550 psi on bottom and 3350-3400 psi off bottom. Torque= 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.6-10.76 ppg. Gas = 50-90 units. P/U = 155-150k, S/O = 95-100k, Rot= 125k w/ pump off. At 9744': Pumps on rotating 120k, 150 PU wt and 95k SO wt. Concreations drilled :9519' to 9526' (7'), 9540' to 9553' (13'), 9568' to 9571' (3'), 9575' to 9578' (3'), 9584' to 9590' (6'), 9748' to 9753' (5'), 9765' to 9770' 5' . Page ~& at ~7 Time Low -- -- - - - Date From _ To Dur S. De>th E De th Phase Code Subcode T_ CO_M _ __ _ 06/11/2006 06:00 12:00 6.00 9,780 10,120 PROD2 DRILL DDRL P Continue drilling from 9780' (3,655' TVD) to 10120' (340') (3, 655' TVD) Bit hours= 45.2, Jar hours= 96.72, AST=1.16, ART=3.29, ADT=4.45, W06=10-20k, 70-90 rpm, Mtr rpm 217-211, 282-275 gpm @ 3500-3440 psi on bottom and 3400-3270 psi off bottom. Torque= 6-9k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.76-10.87 ppg. Gas = 45-94 units. P/U = 150-160k, S/O = 100-95k, Rot= 125- 118k w/ pump off. At 9932': Pumps on rotating 118k, and 95k SO wt. Concreations drilled :9797' to 9803' (6'), 9848' to 9855' (7'), 9882' to 9886' (4'), 9894'to 9896' (2'), 9918' to 9922' (4'), 9928' to 9932' (4'), 9956' to 9959' (3'), 9990' to 9993' (3'), 10000' to 10007' 7' , 10061' to 10065' 4' . 12:00 18:00 6.00 10,120 10,371 PROD2 DRILL DDRL P Continue drilling from 10120' (3,655' TVD) to 10371' (251') (3, 662' TVD) Bit hours= 49.46, Jar hours= 100.98, AST=2.16, ART=2.1, ADT=4.26, W06=15-20k, 90 rpm, Mtr rpm 214-209, 278-271 gpm @ 3500 psi on bottom and 3400 psi off bottom. Torque= 7-10k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.83-10.85 ppg. Gas = 51-80 units. P/U = 165k, S/O = 95-90k, Rot= 122-125k w/ pump off. Concreations drilled :None 18:00 00:00 6.00 10,371 10,663 PROD2 DRILL DDRL P Continue drilling from 10371' (3,662' TVD) to 10663' (292') (3667' TVD) Bit hours= 53.23, Jar hours= 104.75, AST=.73, ART=3.04, ADT=3.77, W06=10-20k, 90 rpm, Mtr rpm 210-223, 273-290gpm @ 3490-3750 psi on bottom and 3390-3480 psi off bottoms Torque= 7-10k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.85-11.08 ppg. Gas = 50-85 units. P/U = 165-162k, S/O = 95-100k, Rot= 120-125k w/ pump off. At 10494': Pumps on rotating 118k, pickup 155kand 85k SO wt. Concreations drilled :None -- - ~ f'~c~~e ~17 ~rf X37 _ _ _ - -- - - Time Logs __ _ _ _ Date From To Dur S . D~ih E De th Phase Code _ _S~bcode T _ COM_ 06/12/2006 00:00 04:45 _ 4.75 _ 10,663 10,915 PROD2 DRILL DDRL P Continue drilling from 10663' (3,667' TVD) to 10915' (252') (3701' TVD) Bit hours= 55.85, Jar hours= 107.37, AST=1.09, ART=1.53, ADT=2.62, WOB=10-15k, 90 rpm, Mtr rpm 216-223, 280-290gpm @ 3650-3750 psi on bottom and 3480-3440 psi off bottom. Torque= 7-10k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.91-11.1 ppg. Gas = 50-85 units. P/U = 160-170k, S/O = 100-85k, Rot= 122-125k w/ pump off. At 10870': Pumps on rotating 118k, pickup 160kand 80k SO wt. Concreations drilled :10702' to 10705' 3' ,and 10545' to 10548' 3' . 04:45 05:45 1.00 10,915 10,405 PROD2 STK TRIP T Pump out of hole f/ sidetrack. Pump f/ 10915' to 10405'. PU wt 150k @ 10405'. 05:45 06:45 1.00 10,405 10,495 PROD2 STK CIRC T Circ and condition f/ open hole sidetrack. Working hole f/ 10405'.-10495'. Circ 67 spm (283 gpm) w/ 3600 psi., rotating 90 rpm., torque 5-7k ft Ib. Obtain surve s. 06:45 08:00 1.25 10,405 10,435 PROD2 STK KOST T Time drill f/ 10405' (3661' TVD) and sidetrack "B" lateral 6-3/4" wellbore @ 10405', exiting 30 deg left and low. Continue to time drill f/ 10405' to 10435' (30') (3663'TVD). Bit hours = 57:08, Jar hrs =108.6, AST =1.23 hrs., art=O.Ohrs 08:00 12:00 4.00 10,435 10,589 PROD2 DRILL DDRL T Drilling"B" lateral from 10435' (3663' TVD) to 10589' (154') (3715' TVD) Bit hours= 59.92, Jar hours= 111.44, AST=1.62, ART=1.22, ADT=2.84, WOB=15k, 90 rpm, Mtr rpm 209, 271gpm @ 3500-3540 psi on bottom and 3390-3490 psi off bottom. Torque = 7-10k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.89-10.81 ppg. Gas = 9-84 units. P/U = 165-170k, S/O = 90-100k, Rot= 125-121 k w/ pump off. Concreations drilled :10573' to 10590' 1T . r~~ge ~~ ~:f 87~ Time Logs _ - -- - - - _ Date From To Dur S. Depth E De th Phase Code Subcode ~ T COM ._ __ _ __ _ 06!12/2006 12:00 15:30 3.50 10,589 10,683 PROD2 DRILL DDRL T Drilling "B" lateral from 10589' (3715' TVD) to 10683' (94') (3642' TVD) Bit hours= 62.49, Jar hours= 114.01, AST=2.19 hrs, ART=.38 hrs, ADT=2.57 hrs, WOB=10k, 90 rpm, Mtr rpm 221, 288gpm @ 3640 psi on bottom and 3470 psi off bottom. Torque = 7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 11.03 ppg. Gas = 9-84 units. P/U = 170k, S/O = 90-100k, Rot= 122k w/ pump off. Concreations drilled :10607' to 10611' (4'), 10620' to 10630' (10'), 10642' to 10655' 13' , 10671' to 10689' 18' . 15:30 21:00 5.50 10,683 10,590 PROD2 RIGMN SVRG T Pull a stand, set back, pull a single, install floor TIW valve, run single back in hole, Blow down top drive. Remove and changeout XT-39 saver sub on top drive. Service top drive. Note: Circ w/ 2" cementing/circulating hose and headpin @ 9-15 spm (38 to 63 gpm) w/ 170 psi, while working on to drive saver sub. 21:00 22:00 1.00 10,590 10,683 PROD2 DRILL TRIP T Pull single, remove floor TIW valve, RIH single, SO wt 95-90k w/ no pump. Hangup in derrick the 2" cementing hose. PU/MU stand #110 and wash and ream in hole f/ 10590' to TD @ 10683'. Pumping 67 spm (283 gpm) w/ 3680 psi, rotating 90 rpm w/ 5-7k ft Ib for ue. Record SPR's. 22:00 00:00 2.00 10,683 10,777 PROD2 DRILL DDRL T Drilling "B" lateral from 10683' (3642' TVD) to 10777' (94') (3661' TVD) Bit hours= 64.07, Jar hours= 115.59, AST=.38 hrs, ART=1.2 hrs, ADT=1.58 hrs, W06=10-15k, 90 rpm, Mtr rpm 218, 283gpm @ 3830 psi on bottom and 3680 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5k ft-Ibs off bottom.. ECD= 10.99 ppg. Gas = 50-84 units. P/U = 170k, S/O = 90k, Rot= 125k w/ pump off. Concreations drilled :still 10683' to 10689' 6' , 10696'to 10705' 9' . I~acJe a1~ of ~7 Time Logs Date From _ ~ To D_ ur S. Depth __ E. De ttt Phase Code Subcode _ T_ - - -- COA1 ~ 06/13/2006 00:00 03:30 3.50 10,777 10,915 PROD2 DRILL DDRL T Drilling "B" lateral from 10777' (3661' TVD) to 10915' (138') (3663.78' TVD) Bit hours= 66.21, Jar hours= 117.73, AST=.42 hrs, ART=1.72 hrs, ADT=2.14 hrs, WOB=8-10k, 70-90 rpm, Mtr rpm 212-214, 275-278gpm @ 3830-3810 psi on bottom and 3680-3620 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5k ft-Ibs off bottom. ECD= 10.99-11.03 ppg. Gas _ ??? units. P/U = 170-162k, S/O = 90-85k, Rot= 125-121 k w/ pump off. Concreations drilled :10826' to 10831' (5'), 10843' to 10850' (7'), 10865' to 10870' 5' . 03:30 06:00 2.50 10,915 10,991 PROD2 DRILL DDRL P Drilling "B" lateral from 10915' {3663.78' TVD) to 10991(76') (3665' TVD) Bit hours= 67.62, Jar hours= 119.14, AST=1.05 hrs, ART=.36 hrs, ADT=1.41 hrs, WOB=4-10k, 90 rpm, Mtr rpm 213, 277 gpm @ 3746-3780 psi on bottom and 3620 psi off bottome Torque = 7k ft-Ibs on botttom and 5-7k ft-Ibs off bottom. ECD= 11.03-11.14 ppg. Gas = ??? units. P/U = 162-170k, S/O = 85k, Rot= 121-120k w/pump off. With pumps on @ 10967': PU wt 155k, SO wt 71 k, Rot wt 118k. Concreations drilled :10980' to 10986' 6' . 06:00 12:00 6.00 10,991 11,262 PROD2 DRILL DDRL P Drilling "B" lateral from 109991' (3665' TVD) to 11262' (271') (3714' TVD) Bit hours= 71.12, Jar hours= 122.64, AST=1.44 hrs, ART=2.06 hrs, ADT=3.5 hrs, WOB= 10-22k, 90 rpm, Mtr rpm 213, 277-271 gpm @ 3746-3560 psi on bottom and 3620-3400 psi off bottom. Torque = 7-9k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 11.03-10.98 ppg. Gas = ??? units. P/U = 170-175k, S/O = 85k, Rot= 120-121 k w/ pump off. Adding LVT @ 5 bbl per hr. Concreations drilled :10994' to 11003' (9'), 11036' to 11041' (5'), 11070' to 11075' (5'), 11094' to 11096' (2'), 11120' to 11123' (3'), 11227 to 11228' (1), 11233' to 11237 4' . ~'~ge :~~1 ofi ~? Time L~ _ Date _ _ From To Dur S Depth E._ _De~ih Phase Cede _ Subcode__ T C:OM _ 06/13/2006 12:00 18:00 6.00 11,262 11,593 PROD2 DRILL DDRL P Drilling "B" lateral from 11262' (3714' ND) to 11593' (331') (3685' ND) Bit hours= 74.75, Jar hours= 126.27, AST=1.29 hrs, ART=2.34 hrs, ADT=3.63 hrs, WOB= 15-22k, 90 rpm, Mtr rpm 219-209, 285-271 gpm @ 3640-3450 psi on bottom and 3520-3370 psi off bottom. Torque = 7-10k ft-Ibs on botttom and 5-7k ft-Ibs off bottom. ECD= 11.18-11.12 ppg. Gas = ??? units. P/U = 180-175k, S/O = 82-80k, Rot= 120-118k w/ pump off. Adding no LVT. Concreations drilled :11317' to 11320' (3'), 11425' to 11429' (4'), 11483' to 11492' (9'), 11516' to 11519' (3'), 11525' to 11540' 15' . 18:00 00:00 6.00 11,593 11,755 PROD2 DRILL DDRL P Drilling "B" lateral from 11593' (3685' TVD) to 11755' (162') (3710' ND) Bit hours= 78.39, Jar hours= 129.91, AST=.22 hrs, ART=3.42 hrs, ADT=3.64 hrs, WO6= 8-15k, 90 rpm, Mtr rpm 212, 275 gpm @ 3880 psi on bottom and 33742 psi off bottom. Torque = 6-8k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 11.29 ppg. Gas = ??? units. P/U = 180k, S/O = 70k, Rot= 120k w/ pump off. With pumps on @ 11621': PU wt 165k, SO wt 70k, Rot wt 118k. Pumped 9.9 ppg weighted hi vis sweep while drilling @ 11725' (2200 hrs) 20% increase in cuttings was possibly noted at shakers. ECD's before pumping was 11,24 ppg, max observed while pumping was 11.45 ppg, and 11.28 ppg after sweep out of hole. Note: Turned Kelly/Top drive hose. Tested to 4000 psi after making connection back up. Concreations drilled :11670' to 11683' (13'), 11715' to 11730' (15'), 11729' to 11740' 11' . -------_ ~ P~c~e 51 cf ~7~ ' Time Logs Date From o ur Depth --- E. De th hase ode _ __ Subcode _ _ _ COr`~9 _ _ _ ' 06/14/2006 _ 00:00 -- 06:00 6.00 11,755 - 11,969 - PROD2 DRILL DDRL P Drilling "B" lateral from 11755' (3710' TVD) to 11969' (162') (3710' TVD) Bit hours= 83.24, Jar hours= 134.76, AST=.45 hrs, ART=4.4 hrs, ADT=4.85 hrs, WO6= 10-15k, 90 rpm, Mtr rpm 210-200, 273-260 gpm @ 3880-3550 psi on bottom and 3742-3380 psi off bottom. Torque = 6-10k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 11.29-11.03 ppg. Gas = 48-62 units. P/U = 180k, S/O = 70-80k, Rot= 120-125k w/ pump off. With pumps on @ 11811': SO wt 65-70k, Rot wt 118k. Pumped 9.9 ppg weighted hi vis sweep while drilling @ 11930' hrs' (0445 hrs) 20% increase in cuttings was possibly noted at shakers. Concreations drilled :11855' to 11863' 8'. 06:00 07:45 1.75 11,969 12,002 PROD2 DRILL DDRL P Drilling "B" lateral from 11969' (3728' TVD) to 12002' (33') (3717' TVD) Bit hours= 84.02, Jar hours= 135.77, AST=.00 hrs, ART=1.01 hrs, ADT=1.01 hrs, WO6= 8-15k, 90 rpm, Mtr rpm 212-200, 275-260 gpm @ 3880-3550 psi on bottom and 3742-3380 psi off bottom. Torque = 6-10k ft-Ibs on botttom and 8-10k ft-Ibs off bottom. ECD= 11.29-11.03 ppg. Gas = 48-62 units. P/U = 180k, S/O = 70-80k, Rot= 120-125k w/ pump off. Concreations drilled 07:45 08:30 0.75 12,002 12,002 PROD2 DRILL CIRC P Circulate and condition hole. 67 s m 283 m w/ 3750 si. 08:30 00:00 15.50 12,002 7,707 PROD2 DRILL REAM P Backream out of hole f/ 12002' (3717' TVD) to 770T (3602' TVD) @ midnight. Pumping 300 gpm w/ 3340 psi to 3520 psi., rotating 90 rpm. String speed 25-30 ft/min. Monitor displacement. Record torque and drag every 5 stands. PU wt @ 7707' = 132k, SO wt = 115k. __,__ P~~ ;;2of &7 .. Tithe Logs _ _ -- -- _ _ - - -- Date Froi~i To Dur _ S,_DEL>th E. De tp h Phase Code Subcod_e T C~~f~~ 06/15/2006 00:00 _ 02:30 2.50 7,707 5,240 PROD2 DRILL REAM P Continue backreaming out of hole f/ 7707' (3602' TVD) to 5435', pumping 280-300 gpm w/ 2840-3500 psi, rotating 90 rpm w/ 4-5k ft-Ibs torque. Pulling speed 30 ft/min. Then POOH with out pumps f/ 5435' to 5240' (3537 TVD). PU wt @ window 110k. Noticed 5k overpull (115k) w/ stabilizer @ TOW, bit pulled through window fine. Record PU & SO wt's every 5 stands. 5240': PU wt 90k. 02:30 03:30 1.00 5,240 5,240 PROD2 DRILL CIRC P Establish circulation. Pump 10.0 ppg weighted hi-vis (131 sec/gt) sweep f/ surface to surface, then another bottoms up to clean hole. Rotate 90 rpm and pump 300 gpm w/ 3450-3500 si, reci f/ 5248' to 5154'. 03:30 05:30 2.00 5,240 5,240 PROD2 RIGMN SVRG T Service rig: Top drive, crown sheaves, drawworks, traveling blocks. Break and turn kellylTop drive hose. Work on TD gripper adjustment. Work on driller's console SCR assignments cabinet to locate a loose wire--possibly effecting # 2 mp dropping off line. Test kelly hose to 4000 si. 05:30 06:00 0.50 5,240 5,431 PROD2 DRILL TRIP P Trip in hole f/ 5240', past window to 5431'. Bit went through window fine, stabilizer took 12-15k while slacking off to of window. 06:00 10:00 4.00 5,431 10,421 PROD2 DRILL TRIP P Continue trip in hole f/ 5431' to 10421'. Fill pipe every 25 stands. Record PU and SO wt's every 5 stands. Watching weight indicator close f/ 10405', noticed taking wt, PU to 10403'. 10:00 11:00 1.00 10,403 10,495 PROD2 DRILL REAM P Reamed f/ 10403' to 10495'. Reamed w/ 276 gpm, 3620 psi, rotating 90 rpm.. Survey @ bit depth of 10495' confirmed in ri ht hole. 11:00 12:00 1.00 10,495 12,002 PROD2 DRILL TRIP P Continue RIH f/ 10495' to 12202'. Record PU and SO wt's every 5 stands. Fill i e eve 25 stands. 12:00 13:30 1.50 12,002 12,002 PROD2 DRILL CIRC P Pump 32 bbl weighted to 10 ppg (131 sec/ qt) sweep @ 300 gpm w/ 3850 si. Rotate 90 r m. Pum ed 537 bbls. 13:30 14:30 1.00 12,002 12,002 PROD2 DRILL CIRC P Pump SFOBM (8.7 ppg) @ 285 gpm w/ 3800 psi. Rotate 90 rpm, torque 7-10k ft Ibs. Pum 330 bbls. 14:30 14:45 0.25 12,002 12,202 PROD2 DRILL OWFF P Monitor well. Static. 14:45 15:00 0.25 12,002 12,002 PROD2 DRILL CIRC P Pump 25 bbl dry job. Blow down top drive. 15:00 23:00 8.00 12,002 3,373 PROD2 DRILL TRIP P POOH f/ 12002' to 3373', recording PU and SO weights every 5 stands. SLM. Pi e came wet 3373'. - ;'ale 53 csf ~7 ~__ - Time Lois -- - - - Date From To Dur S. Depth E. De~tYi Phase Code Subcod_e T _ COM -- _- 06/15/2006 23:00 00:00 _ 1.00 3,373 3,373 PROD2 _ DRILL CIRC P Establish circulation. Circulate surface to surface 1520 strokes}, then pump dry job of 10-15 bbls, chase with 10 bbls. 06/16/2006 00:00 04:00 4.00 3,373 96 PROD2 DRILL TRIP P Continue POOH w/ BHA #6 f/ 3373' to MWD tools @ 96'. String still pulled wet to a itator, then d 04:00 06:00 2.00 85 85 PROD2 DRILL OTHR P Download Sperry Sun MWD tools. 06:00 07:15 1.25 85 0 PROD2 DRILL PULD P Lay down rest of BHA #6. Clear and clean ri floor. 07:15 07:30 0.25 0 0 COMPZ FISH SFTY P PJSM on PU BHA # 7 (Retrieval of whi stock f/ "B" lateral. 07:30 09:15 1.75 0 60 COMPZ FISH PULD P PU/MU BHA # 7 (retrieval of "B" lateral whipstock. Assembly consists of Whipstock retrieving hook, 1jt HWDP, float sub, 4-3/4" Bowen jars,4-3/4" Bowen Oil 'ars, x-o. 09:15 12:30 3.25 60 5,363 COMPZ FISH TRIP P RIH w/ BHA # 7 on same assembly which will be used to run liner. 5 stands 4" Weatherford dp w/ Western Wells super sliders, then 2 stands of Hybrids (2- 5" DC's and 1 -4" HWDP on top), then 3 stands of Weatherford 4" dp w/ Western Wells super sliders, then 2 stands of Hybrids (2-5" DC's and 1- 4" HWDP on top, then 29 stands of Weatherford 4" dp w/ Western Wells super sliders, then 15 stands more Hybrids. to 5363'. SLM, record PU and SO wt's every 3-5 stands. 12:30 14:00 1.50 5,363 5,363 COMPZ FISH CIRC P Fill Pipe, Circ, engage key into whi stock slot, ull free: 14:00 14:30 0.50 5,363 5,363 COMPZ FISH CIRC P Circ BU @ 255 gpm w/ 1450 psi. Circ total of 170 bbls. 14:30 14:45 0.25 5,363 5,363 COMPZ FISH OTHR P Monitor well. OK. 14:45 15:00 0.25 5,363 5,363 COMPZ FISH CIRC P Pump dry job. Drop a 2.375" rabbit w/ 100' wire attatched. Blow down top drive. 15:00 20:45 5.75 5,363 61 COMPZ FISH TRIP P POOH w/ Whipstock f/ "B" lateral to Baker BHA (61'). Record PU wt's only every 3-5 stands (depends if hybrids or ~ust 4" DP w/ su er sliders. 20:45 22:30 1.75 61 0 COMPZ FISH PULD P UD Baker retrieval BHA #7: Crossover sub, 4-3/4" Bowen Oil jar, Bowen lubricated bumper sub, float sub, 1 jt HWDP, whipstock retrieval tool. Clean and ins ect BHA riot to la in down. 22:30 23:00 0.50 94 0 COMPZ FISH PULD P UD Baker "B" lateral whipstock assembly: Baker Slide, debris sub, drain sub, shear disconnect, B!T anchor, blank sub, 2 jts 3-1/2" drill pipe, unloader sub, and seals. (total of 94.36' . ~.. ~~ 3~~€JeS~ of t37 Time Los Date From To Dur S, De th °E: ~e tp h Phase _ Code _ 5ubcode T__ COf~~ _ __ _ ) 06/16/2006 23:00 23:30 0.50 0 0 COMPZ CASIN( OTHR P Pick tools up f/ running 4-1/2" slotted and blank liner f/ "B" lateral. 23:30 00:00 0.50 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" slotted and blank liner in "B" lateral. 06/17/2006 00:00 06:00 6.00 0 6,573 COMPZ CASIN( RNCS P Run "B" lateral liner: 3-1/2" guide shoe, 3-1/2" bent joint, x-o, Then 4-1/2" 11.6 ppf L-80 BTC slots and blanks according to plan to 6573'. Run a Hydroform 4-1/2" x 6-1/8" spiral centralizer on 153 joints total. Run a Weatherford stop ring in the center of all 153 joints of 4-1/2". Recording PU and so wt's every 15 joints (approx every 640'). PU wt @ window 112k, SO wt 105k. PU wt with all of 4-1/2" liner jts(153) (6573')PU= 115k, SO wt 100k. (Liner: 115k-70k= 45k liner onl 06:00 07:00 1 .00 6,573 6,580 COMPZ CASIN( OTHR P PU tools to MU Sperry MWD. RU _ ton sand table. 07:00 08:00 1.00 6,580 6,582 COMPZ CASIN( OTHR P MU MWD tools as inner string to run w/ Baker Model B1 hook hanger. Orient to hook hanger. Line up hook han er to S er Sun MWD. 08:00 08:15 0.25 6,582 6,612 COMPZ CASIN( OTHR P MU Baker 61 Hook Hanger Hook Han erw/ tannin tool to liner. 08:15 08:45 0.50 6,612 6,612 COMPZ CASIN( RURD P Rig down Baker tools, clean and clear ri floor. 08:45 09:15 0.50 6,612 7,079 COMPZ CASIN( RUNL P RIH w/ Liner on 4" dp f/ 6612' to 7079'. Check MWD, pumping 30 spm w/ 750 psi. 125 gpm. Looks OK. Record PU and SO wt's eve 5 stands. 09:15 13:00 3.75 7,079 11,595 COMPZ CASIN< RUNL P Continue RIH w/ liner on 4" dp f/ 7079' to 11595'. Record PU and SO wt's every 5 stands. String took wt @ 11595'. Possibly a cetralizer hanging up @ window??). Work string 5 times, then OK. 13:00 13:45 0.75. 11,595 11,939 COMPZ .CASIN( RUNL P Trip in f/ 11595' to 11939'. Record PU and SO wt's eve 5 stands. 13:45 14:45 1.00 11,939 11,961 COMPZ CASIN( RUNL P PlJ a single of 4" dp, MU top drive, circ and orient. Toolface was 10 right (Hook was oriented same as toolface). Slack off and w/ 26' in on single (57 stands +26' off single), toolface went 60 deg ri ht. 14:45 16:15 1.50 11,961 11,961 COMPZ CASIN( OTHR P PU single, PU 20', rotate one round, went past window 10'. PU 30', reorient to 31 deg right, slack off and hook 26' in w/ 40k and toolface 40 deg right. PU 20', rotate 1/2 round, went past window 10' again. PU, orient 13 deg right, slack off hook @ 26 1/2' in, toolface 8 deg right. PU and rotate 1/2 round and went past 10' again. PU, orient 1 deg left, slack off 261!2' w/ 40k down., toolface 15 de ri ht. ~ ~~g~ ~~ of ~7 ~ _ . -_ ~, Time Logs To Dur S, Depth E Depth Phase__ Code _ Subcode _ T CQM Date From ~ _ ~ 06/17/2006 16:15 17:00 0.75 11,961 11,961 COMPZ CASINC CIRC P Drop 29/32" ball, slack off40k. Circ ball down @ 3bpm w/ 1000 psi, slow down @ 40 bbls pumped to 1 bpm. Ball on seat @ 42 1/2 bbls pumped. Presssure up to 4000 psi. Note: With 40k down: 4.84' deeper. (ie shoe @ 11966.27', tally is 11961.43' . 17:00 17:30 0.50 11,961 11,961 COMPZ CASIN( OTHR P RU test pump to exceed the 4000 psi pressure. Pressure up to 4500 psi to blow ball. 17:30 17:45 0.25 11,961 5,323 COMPZ CASIN( OTHR P UD top joint. UD next joint w/ PU wt of 175k, verifying liner release. Liner and string PU wt was 225k, SO wt was 115k w/shoe 11961.43'. 17:45 18:00 0.25 5,323 5,323 COMPZ RIGMN SFTY P PJSM on slip and cut drilling line. 18:00 20:00 2.00 5,323 5,323 COMPZ RIGMN SVRG P Slip and cut drilling line. Adjust brakes, service top drive and drawworks. 20:00 21:00 1.00 5,323 5,323 COMPZ CASINC CIRC P MU top drive.. Establish circulation. Pump dry job (25 bbls) for trip out of hole. 21:00 00:00 3.00 5,323 36 COMPZ CASIN( RUNL P POOH w/ liner running tools f/ 5323' to S er Sun MWD tools 36'. 06/18/2006 00:00 02:00 2.00 36 0 COMPZ CASIN( OTHR P Lay down Sperry MWD tools. UD baker runnin tools f/ "B" lateral liner. 02:00 02:30 0.50 0 0 COMPZ CASIN( RURD P Clear and clean rig floor. 02:30 03:00 0.50 0 PROD2 CASIN< SFTY P PJSM on running 4-1/2" LEM f/ "B" lateral. 03:00 04:15 1.25 0 305 PROD2 CASIN( RNCS P PU/MU 4-1/2" LEM assembly f/ "B" lateral: Baker seal assembly, 4-1/2"crossover bent joint 12.6 ppf I-80 ST-L, (1) joint 4-1/2" 12.6 ppf L-80 i IBT-M, Camco DB-6 nipple 3.563" ID, (1) joint 4-1/2" 12.6 ppf L-80 IBT-M, 9.80' pup jt 4-1/2" 12.6 ppf L-80 IBT-M, LEM inside Hook Hanger, LEM above Hook Hanger, (4) joints 4-1/2" 12.6 ppf L-80 IBT-M tubing, 2.06' pup joint 4-1/2" 12.6 ppf L-80 IBT-M, 4-1/2" pup jt 12.6 ppf L-80 IBT-M, X-O bushing, 190-47 Casin seal bore rece tacle. 04:15 04:45 0.50 305 335 PROD2 CASIN( RNCS P MU Baker 5-1/2" x 7-5/8" ZXP liner top packer w/ baker hyd setting tool and runnin tool. 04:45 05:15 0.50 335 335 PRODZ CASINC RURD P Rig down casing tools. Prepare to run in hole w/ LEM on 4" drillpipe and H brids. 05:15 05:30 0.25 335 335 PROD2 CASIN( SFTY P PJSM on running in hole w/ LEM on 4" drill i e. 05:30 06:00 0.50 335 1,550 PROD2 CASIN( RUNL P MU 3-1/2" x 4" XT-39 crossover and RIH w/ 4" drill pipe w/ super sliders and hybrids ((2)5" DC's + 4" HWDP) to 1550'. - ~'~g~ ~~ of~7 - - -- _ - - - -- Time Loys _ - - - - - Date From To Dur S. De th E Depth_ Phase_ Code Subcode__ ~ COfv1 _ __ _ __ 06/18/2006 06:00 10:00 4.00 1,550 .5,496 PROD2 CASIN( RUNL P Continue RIH w/ LEM on 4" string f/ 1550' to 5496.15'. RIH 80 ft er min. 10:00 10:15 0.25 5,496 5,496 PROD2 CASIN( SFTY P PJSM on setting LEM. 10:15 10:45 0.50 5,496 5,496 PROD2 CASIN( OTHR P Drop ball and circ down @ 130 gpm w/ 420 psi. On seat after pumping 36 bbls. Top of 5-1/2" x 7-5/8" ZXP packer @ 5171.64'. Pressure up to 3000 psi, then to 4000 si. 10:45 11:15 0.50 5,496 5,496 PROD2 CASIN( DHEO P Pressure test annulus to 1000 psi f/ 5 min, chart test. ood test. 11:15 12:15 1.00 5,496 5,496 PROD2 CASIN( CIRC P POOH to clear LEM w/ running tools, Circulate bottoms up @ 200 gpm w/ 700 si. Circ total of 170 bbfs. 12:15 12:30 0.25 5,496 5,496 PROD2 CASIN( SFTY P PJSM on pulling out of hole. Monitor well. Pum 21 bbls d 'ob. 12:30 16:30 4.00 5,496 18 PROD2 CASIN( RUNL P Blow down top drive. POOH w/ Baker LEM runnin tools. 16:30 17:00 0.50 18 0 PROD2 CASIN( RURD P Lay down Baker running tools. Clear and clean ri floor. 17:00 17:30 0.50 0 0 PROD3 STK OTHR P PJSM on running Baker Whipstock f/ "D" lateral. 17:30 1:8:00 0.50 0 70 PROD3 STK PULD P PU/MU "D" lateral whipstock assembl . 18:00 19:45 1.75 70 146 PROD3 STK PULD P Continue PU/MU Baker whipstock assembl f/ "D" lateral. 19:45 20:45 1.00 146 203 PROD3 STK PULD P PU/MU orient Sperry Sun MWD w/ Baker whipstock. Sperry Sun MWD is 189.19 deg right of high side of whi stock. 20:45 21:30 0.75 203 210 PROD3 STK OTHR P Sperry MWD upload to tools. 21:30 21:45 0.25 210 210 PROD3 STK OTHR P Pre job safety meeting on running whipstock and moving (adjust all super sliders up afoot on the drill pipe) Western Well tools super sliders. Two sliders per joint on 37 stands = 222 su er sliders to be moved. 21:45 00:00 2.25 210 864 PROD3 STK TRIP P MU crossover, then 3 stands Hybrids ((2) 5" DC's and a single 4" HWDP on top), follow with Weatherford 4" XT-39 drill pipe w/ 2 per joint super sliders. Moving super sliders up one foot on all joints. Retorque all bolts to 25 ft Ib torque. Replace any that look like they need replaced. Western Well Tools rep on floor during readjustment. RIH 60-80 ft per minute. Test MWD after 5 stands in hole. pump 205 gpm w/ 560 psi. 7 stands in hole midni ht to 864'. ~ ~ Pie x7 ~f 37 Time Loci _ -- I Date From To Dur_ S. Depth E. Depth Phase Code Subcode T _ COM _ _ 06/19!2006 00:00 03:30 3.50 864 2,546 PROD3 STK TRIP P RIH f/ 864' to 2546' w/ whipstock on Weatherford 4" XT-39 drill pipe w/ 2 per joint super sliders. Moving super sliders up one foot on all joints. Retorque all bolts to 25 ft Ib torque. Replace any that look like they need replaced. Western Well Tools rep on floor during re adjustment. RIH 60-80 ft er minute. 03:30 04:00 0.50 2,546 2,546 PROD3 STK CIRC P Fill pipe. establish circ @ 2546'. Pum in 193 m w/ 710 si, 45 s m. 04:00 04:15 0.25 2,546 2,546 PROD3 STK OTHR P Blow down top drive. 04:15 06:00 1.75 2,546 3,489 PROD3 STK TRIP P Continue RIH f/ 2546' to 3489' w/ whipstock on Weatherford 4" XT-39 drill pipe w/ 2 per joint super sliders. Moving super sliders up one foot on all joints. Retorque all bolts to 25 ft Ib torque. Replace any that look like they need replaced. Western Well Tools rep on floor during re adjustment. RIH 60-80 ft er minute. 06:00 08:15 2.25 3,489 4,604 PROD3 STK TRIP P Continue RIH f/ 3489' to 4604' w/ whipstock on Weatherford 4" XT-39 drill pipe w/ 2 per joint super sliders. Moving super sliders up one foot on all joints. Retorque all bolts to 25 ft Ib torque. Replace any that look like they need replaced. Western Well Tools rep on floor during re adjustment. RIH 60-80 ft er minute. 08:15 09:00 0.75 4,604 4,705 PROD3 STK CIRC P MU top drive. Establish circulation. MAD pass f/ 4634' to 4705' w/ Sperry Sun Gamma/Res Circ 217 gpm (51 s m w/ 1040 si. 09:00 10:15 1.25 4,705 5,114 PROD3 STK TRIP P Continue RIH w/ whipstock f/ 4705' to 5113.79'. Runnin seed 80 ft er min. 10:15 10:30 0.25 5,114 5,177 PROD3 STK OTHR P Tag @ 5177', Orient whipstock. Pump 212 m 50 s m w/ 1010 si. 10:30 11:00 0.50 5,177 5,082 PROD3 STK WPST P Set whipstock top @ 5080' MD. Set 10 deg left. Rot wt 120k. PU wt after release 130k. Rotate 60 rpm. Torque 2-5k ft lbs. Pumping 274 gpm (65 spm). Set down 18k on Anchor.. Set down 50k to shear and break mills free from slide. 11:00 18:00 7.00 5,082 5,115 PROD3 STK WPST P Start milling window f/ TOW @ 5082'. to BOW @ 5095'. Top of whipstock @ 5080'.Pilot mill to 5115', 4' of 6-3/4"guage hole. Pumping 275 gpm w/ 1543 psi. PU wt 140k, SO wt 115k, Rot wt 125k. 18:00 19:15 1.25 5,115 5,115 PROD3 STK CIRC P Pump weighted sweep. 10.0 ppg, 130 sec per quart vis. Rotate @ 90 rpm, pump 1640 psi. PU wt 128k, SO wt 123k. Work mills from 5115' to 5080' P~qe ~g o; 37 - __ __ ~ ~ ~ Time L~s__ - - ~~-~ gage.5~ oi' 8? Date From To Dur S._~_t_h E Depth_ Phase_ Code Subcode _ T_ _ CQM _ __ 06/19/2006 19:15 19:30 0.25 5,115 5,115 PRODS STK OTHR P Work through window w/ no pump and no rotation to re check window before POOH. OK. 19:30 19:45 0.25 5,115 5,110 PRODS STK TRIP P Lay down top single prior to pumping a d 'ob. 19:45 20:15 0.50 5,110 5,110 PRODS STK CIRC P Monitor well. Static. Pump dry job. blow down to drive. 20:15 00:00 3.75 5,110 2,525 PRODS STK TRIP P POOH f/ 5082'. to 2525'. Had to re position some of super sliders on top. single to be able to rack stgnd back in derrick. Measurement of top of fingers to ri floor = 85.4' 06/20/2006 00:00 03:30 3.50 2,525 213 PRODS STK TRIP P Continue POOH from 2740' - 213. Reposition Super Sliders as needed and obtain SLM on TOH. 03:30 04:00 0.50 213 0 PRODS STK PULD P Breakout & lay down BHA. Lay down crossover sub (2.98') and 4 3/4" Bum er Jar 7.87' , 04:00 05:00 1.00 0 0 PRODS STK OTHR P Plug in and download MWD assembly. 05:00 06:00 1.00 0 0 PRODS STK PULD P Continue lay down BHA.Lay down MWD assembly (56.11'), 4 3/4" Float sub (2.38'), 1 -joint of 4" HWDP (29.78'), 6 3/4" Upper mill (5.84'), Flex Joint (6.52'), Lower Mill (5.51'), and starting mill (1.15'). Inspect & gauge upper mill to full gauge. Clear & clean Ri Floor area. 06:00 08:00 2.00 0 0 PRODS WELCT ROPE P Rig up Test joint & RIH to pull wear bushin . Make u stack washer tool. 08:00 09:30 1.50 0 0 PRODS WELCT BOPE P Flush Stack, function all pipe rams. Blow down Mud cross, choke & kill lines. Breakout & lay down stack washer assembl . 09:30 10:30 1.00 0 0 PRODS WELCT BOPE P Rig up to test BOP stack. Install test fu . RU chart recorder. 10:30 17:00 6.50 0 0 PRODS WELCT BOPE P Perform complete BOP test, testing Pipe rams, blind rams, all manual & HCR valves. Test all Choke manifold valves & floor valves. Perform Koomey test, and test Top Drive Upper & lower valves. All tests to 250 / 3000 PSI recorded on chart. Witness of BOP test waived b John S auldin . 17:00 18:00 1.00 0 0 PRODS WELCT BOPE P Rig down all BOP testing equipment & blow down all lines. 18:00 19:00 1.00 0 0 PRODS WELCT BOPE P Make up Wear bushing & RIH to set. RILDS as per Vetco Gray rep on location. 19:00 20:30 1.50 0 0 PRODS DRILL SFTY P Clear & clean rig floor area, pulling all tools and equipment to rig floor. Change out broken dies in Iron Roughneck. Held PJSM with crew & Sperry Sun Reps. Discuss safety issues and procedure for making up BHA #8. - -- _ _ _ __ Time Lomas _ _~ Gate _ From To __ Dur _ S_ .Depth E Depth _ Phase erode Subcode T COAQ . 06/20/2006 20:30 22:30 2.00 0 92 PROD3 DRILL PULD P Make up BHA #8 as per DD &MWD reps. Make up 6 3/4" Security Bit FMF3641Z (1.30') with 3 x 21 jets for a TFA of 1.015 sq in., on 5.20" Geo-Pilot 5200 Series (16.18'). MU 4 3/4" Non MAg Fles Drill Coilar (11.55'), MWD DM/HOC (8.56'), 4 3/4" Smart Stabilizer Sleeve type (3.60'), MWD Gamma/Res (23.75'), MWD PWD (10.69'), TM HOC (11.27').4 3/4" Non Mag Float sub (2.38'), and 4 3/4" Inte ral Blade Stabilizer 4.58' . 22:30 23:30 1.00 92 92 PROD3 DRILL OTHR P Plug in and Upload MWD assembly. 23:30 00:00 0.50 92 283 PROD3 DRILL PULD P Continue Make up 3 -Non MAg Flex Drill collars (93.39'), Crossover sub (3.00'), 1 - Jnt 4" HWDP (30.68'), 4 3/4" Dailey Drilling Jars (32.25'), and 1 joint of 4" HWDP 30.69' . 06/21/2006 00:00 00:30 0.50 283 377 PROD3 DRILL OTHR P Rig Up and perform Pulse test as per MWD rep. Pumps at 260 GPM's - 1000 PSI. Good test. Break in Geo-Pilot Bearin sat 30-50 RPM's. 00:30 02:30 2.00 377 5,063 PROD3 DRILL TRIP P Continue trip in hole from 377' - 5063'. Fill Drill Strin eve 25 stands. 02:30 03:30 1.00 5,063 5,115 PROD3 DRILL REAM P Wash from 5063'- 5095' with no rotation. TOW = 5082'. Observe no issues passing through window area. Rotate down to 5115'. 03:30 06:00 2.50 5,115 5,295 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 5115' - 5295 MD. TVD = 3517'. (180'). UP WT = 129K, SO WT = 112K, ROT WT = 122K. WOB = 5-7K, 80 RPM's with Torque on bottom @ 5-6K, Torque off bottom @ 4-5K. Pumps @ 311 GPM's - 1430 PSI. ECD's @ 9.8 PPG, Max Gas observed = 38 Units.Total Bit Hrs = 1.11, Total Jar Hrs = 136.88 ADT = 1.11 HRS, ART = 1.11 Hrs. Survey @ 5213' MD, 3517 TVD, INC = 86.08 DEG, Azimuth = 7.73 Deg. Mud Wt = 8.8 PPG, Visc = 74, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Crew Chan e i~~~~a ~Q cst X37` Time Logs Date From To Dur S. Depth ED~eth_ Phase Code _ Subcode T__ COM _ _ _ __ 06/21/2006 06:00 12:00 6.00 5,295 5,811 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 5295' - 5811' MD. TVD = 3515'. (516'). UP WT = 140K, SO WT = 108K, ROT WT = 126K. WOB = 6-10K, 120 RPM's with Torque on bottom @ 5-6K, Torque off bottom @ 3-4K. Pumps @ 301 GPM's - 2150 PSI. ECD's @ 10.12 PPG, Max Gas observed = 45.2 Units.Total Bit Hrs = 3.39, Total Jar Hrs = 139.16 ADT = 2.28 HRS, ART = 2.28 Hrs. Survey @ 5777' MD, 3521' TVD, INC = 89.01 DEG, Azimuth = 356.46 Deg. Mud Wt = 8.8 PPG, Visc = 74, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleanin and control ECD's. 12:00 18:00 6.00 5,811 6,355 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 5811' - 6355' MD. TVD = 3537'. (544'). UP WT = 145K, SO WT = 110K, ROT WT = 127K. WOB = 6-10K, 120 RPM's with Torque on bottom @ 5-6K, Torque off bottom @ 3-4K. Pumps @ 307 GPM's - 2335 PSI. ECD's @ 10.12 PPG, Max Gas observed = 60 Units.Total Bit Hrs = 7.48, Total Jar Hrs = 143.25 ADT = 4.09 HRS, ART = 4.09 Hrs. Survey @ 6338' MD, 3535' TVD, INC = 88.77 DEG, Azimuth = 4.08 Deg. Mud Wt = 8.8 PPG, Visc = 74, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates @ 6280' MD. #1 pump @ 20 SPM - 360 PSI. 30 SPM - 580 PSI. #2 Pump @ 20 SPM 360 PSI, 30 SPM - 580 PSI. Crew Chan e gage ~1 Jt 37 _ - - -- Time Logs_ Date From To Dur pepth S E De~~th Phase Code Subcode T COM 06/21/2006 18:00 _ __ 00:00 6.00 _ . 6,355 7,020 PROD3 DRILL DDRL P Directional drill 6 3!4" hole in the "D" Lateral from 6355'- 7020' MD. TVD = 3544'. (665'). UP WT = 139K, SO WT = 105K, ROT WT = 121 K. WOB = 5-10K, 130 RPM's with Torque on bottom @ 5-7K, Torque off bottom @ 3-5K. Pumps @ 310 GPM's - 2520 PSI. ECD's @ 10.14 PPG, Max Gas observed = 54 Units.Total Bit Hrs = 11.84, Total Jar Hrs = 147.61 ADT = 4.36 HRS, ART = 4.36 Hrs. Survey @ 6996' MD, 3548' TVD, INC = 88.52 DEG, Azimuth = 353.20 Deg. Mud Wt = 8.8 PPG, Visc = 74, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Observe 75% increase in cutting when sweep returned. Obtain Slow Pump Rates #1 pump @ 20 SPM - 420 PSI. 30 SPM - 640 PSL #2 Pump @ 20 SPM 440 PSI, 30 SPM - 650 PSI. Crew Chan e 06/22/2006 00:00 06:00 6.00 7,020 7,734 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 7020' - 7734' MD. TVD = 3549'. (714'). UP WT = 145K, SO WT = 98K, ROT WT = 126K. WOB = 5-10K, 130 RPM's with Torque on bottom @ 8-10K, Torque off bottom @ 3-5K. Pumps @ 310 GPM's - 2520 PSI. ECD's @ 10.68 PPG, Max Gas observed = 58 Units.Total Bit Hrs = 15.22, Total Jar Hrs = 150.99 ADT = 3.38 HRS, ART = 3.38 Hrs. Survey @ 7651' MD, 3547' TVD, INC = 89.33 DEG, Azimuth = 357.39 Deg. Mud Wt = 8.8 PPG, Visc = 73, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Observe 75% increase in cutting when sweep returned. Obtain Slow Pump Rates #1 pump @ 20 SPM - 480 PSI. 30 SPM - 680 PSI. #2 Pump @ 20 SPM 490 PSI, 30 SPM - 840 PSI. Crew Chan e Page 62 ~+f fl ~ ~~ __ s Time Lo -_ ~ - - -! g _ _ -_ --- Date From To Dur _ S. Depth_ E. De th Phase _ Code Subcode T _ C~M __ _ _ _ _ _._i _ 06/22/2006 06:00 ___ 12:00 6.00 7,734 8,153 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 7734' - 8153' MD. TVD = 3564'. (419'). UP WT = 155K, SO WT = 103K, ROT WT = 125K. WOB = 10-15K, 130 RPM's with Torque on bottom @ 7-8K, Torque off bottom @ 4-5K. Pumps @ 310 GPM's - 2720 PSI. ECD's @ 10.90 PPG, Max Gas observed = 86 Units.Total Bit Hrs = 19.89, Total Jar Hrs = 155.86 ADT = 4.67 HRS, ART = 4.67 Hrs. Survey @ 8119' MD, 3559' TVD, INC = 88.60 DEG, Azimuth = 359.69 Deg. Mud Wt = 8.8 PPG, Visc = 76, YP = 24. Pump Hi Visc weighted sweeps to aid in hole cleanin and control ECD's. 12:00 18:00 6.00 8,153 8,717 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 8153' - 8717 MD. TVD = 3564'. (564'). UP WT = 155K, SO WT = 100K, ROT WT = 124K. WOB = 10-15K, 120 RPM's with Torque on bottom @ 7-8K, Torque off bottom @ 4-5K: Pumps @ 317 GPM's - 2820 PSI. ECD's @ 11.07 PPG, Max Gas observed = 84 Units.Total Bit Hrs = 24.08, Total Jar Hrs = 159.85 ADT = 4.19 HRS, ART = 4.19 Hrs. Survey @ 8682' MD, 3576' TVD, INC = 90.62 DEG, Azimuth = 358.56 Deg. Mud Wt = 8.7 PPG, Visc = 73, YP = 22. Pump Hi Visc weighted sweeps to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates @ 8717' MD #1 pump @ 20 SPM - 490 PSI. 30 SPM - 740 PSI. #2 Pump @ 20 SPM 490 PSI, 30 SPM - 710 PSI. Crew Chan e 18:00 00:00 6.00 8,717 9,395 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 8717' - 9395' MD. TVD = 3582'. (678'). UP WT = 155K, SO WT = 98K, ROT WT = 127K. WOB = 5-10K, 120 RPM's with Torque on bottom @ 7-8K, Torque off bottom @ 4-5K. Pumps @ 315 GPM's - 2820 PSI. ECD's @ 10.75 PPG, Max Gas observed = 81 Units.Total Bit Hrs = 27.35, Total Jar Hrs = 163.12 ADT = 3.27 HRS, ART = 3.27 Hrs. Survey @ 9339' MD, 3580' TVD, INC = 88.76 DEG, Azimuth = 359.81 Deg. Mud Wt = 8.8 PPG, Visc = 72, YP = 22. Pump Hi Visc weighted sweeps @ 8950' to aid in hole cleanin and control ECD's. ___ ~_ ~ ~,ag~ 3 of 87 _ Time Logs Date From To - Dur - S. Depth E Depth Phase - Code - Subcode T COM_ _ _. _- _.- - -- 06/23/2006 ~ 00:00 06:00 _ _ 6.00 9,395 10,107 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 9395' - 10107' MD. TVD = 3587'. (712'). UP WT = 167K, SO WT = 95K, ROT WT = 128K. WOB = 5-10K, 120 RPM's with Torque on bottom @ 7-8K, Torque off bottom @ 4-5K. Pumps @ 315 GPM's - 2780 PSI. ECD's @ 10.98 PPG, Max Gas observed = 85 Units.Total Bit Hrs = 30.62, Total Jar Hrs = 166.39 ADT = 3.27 HRS, ART = 3.27 Hrs. Survey @ 10087' MD, 3589' TVD, INC = 89.26 DEG, Azimuth = 353.47 Deg. Mud Wt = 8.8 PPG, Visc = 68, YP = 21. Pump Hi Visc weighted sweeps @ 9713' to aid in hole cleaning and control ECD's. Crew Chan e 06:00 11:00 5.00 10,107 10,436 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 10107' - 10436' MD. TVD = 3615'. (329'). UP WT = 180K, SO WT = 85K, ROT WT = 125K. WOB = 10-15K, 120 RPM's with Torque on bottom @ 7-8K, Torque off bottom @ 4-5K. Pumps @ 310 GPM's - 2870 PSI. ECD's @ 10.98 PPG, Max Gas observed = 98 Units.Total Bit Hrs = 33.47, Total Jar Hrs = 169.24 ADT = 2.85 HRS, ART = 2.85 Hrs. Survey @ 10370' MD, 3608' TVD, INC = 84.50 DEG, Azimuth = 357.70 Deg. Mud Wt = 8.8 PPG, Visc = 67, YP = 18. Pump Hi Visc weighted sweep to aid in hole cleaning and control ECD's. Obtain Slow Pump Rates @ 10407' MD #1 pump @ 20 SPM - 580 PSI. 30 SPM - 860 PSL #2 Pump @ 20 SPM -575 PSI, 30 SPM - 845 PSI. Observed Geo-Pilot failure. We have drilled a total of 47 concrteions, 318' total, for an avera a thickness of 6.9 ft each. 11:00 12:15 1.25 10,436 10,436 PRODS DRILL CIRC T Decision to POOH. Circulate Bottoms upwith pumps at 72 SPM - 2870 PSI. Reciprocaqte & rotate drill string with 130 RPM's , UP WT = 122K, SO WT = 114K. 12:15 12:30 0.25 10,436 10,436 PRODS DRILL OWFF T Monitor well -static. 12:30 12:45 0.25 10,436 10,219 PRODS DRILL TRIP T POOH on elevators from 10436' - 10219'. Observe well taking proper hole fill with no swabbin issues. 12:45 13:00 0.25 10,219 10,219 PRODS DRILL TRIP T Screw into Top Drive, and break circulation. Pump dry job, blow down To Drive and all lines. ~~~ _ _ ~ ~ ~ e P~qe 6~ c€ 87 - --- - --- - - - - - - Time Low -- - Depth _E. Depth. Phase__ Code Subcode T __COM Dur S From To Date ~ _ _ _ ~_ 06/23/2006 13:00 18:00 5.00 10,219 1,595 PRODS DRILL TRIP T Continue POOH on elevators from 10219' - 1595'. Obtain T & D parameters as per Rig engineer every 5 stands in OH, and every 10 stands in cased hole. Crew Chan e 18:00 19:30 1.50 1,595 92 PRODS DRILL TRIP T Continue POOH on elevators from 1595' - 92'. Observe we11 taking proper hole fill. Rack back 4" HWDP & Non Mag Flex Drill collars. Breakout & lay down Integral Blade stabilizer & float sub. 19:30 20:30 1.00 92 92 PRODS DRILL PULD T Plug in and download MWD assembly. Pull up & breakout, lay down & inspect bit. Bit Gradedat2/2/BT/A/ X/I/ PN / DTF. bit will be rerun. 20:30 22:30 2.00 92 0 PRODS DRILL PULD T Breakout & lay down BHA as per DD &MWD reps. Lay down 5.20" Geo-Pilot 5200 Series (16.18'). MU 4 3/4" Non MAg Fles Drill Collar (11.55'), MWD DM/HOC (8.56'), 4 3/4" Smart Stabilizer Sleeve type (3.60'), MWD Gamma/Res (23.75'), MWD PWD (10.69'), TM HOC (11.27'). Clear & Clean Ri Floorarea. 22:30 00:00 1.50 0 92 PRODS DRILL PULD T Held PJSM with crew. Discuss Safety Issues and procedure for making up BHA #9. Make up 6 314" Security Bit FMF3641Z (1.30') with 3 x 21 jets for a TFA of 1.015 sq in., on 5.20" Geo-Pilot 5200 Series (16.18'). MU 4 3/4" Non MAg Fles Drill Collar (11.55'), MWD DM/HOC (8.56'), 4 3/4" Smart Stabilizer Sleeve type (3.60'), MWD Gamma/Res (23.75'), MWD PWD (10.69'), TM HOC (11.2T). 4 3/4" Non Mag Float sub (2.38'), and 4 3/4" Inte ral Blade Stabilizer 4.58' . 06/24/2006 00:00 03:00 3.00 92 92 PRODS DRILL PULD T Plug in and Upload MWD assembly. Observe MWD TM Failed twice. Change out TM probe. Plug in and upload ,retest, good test. Perform Pulse test. Geo Pilot - ood. 03:00 04:30 1.50 92 284 PRODS DRILL TRIP T Continue make up 3 Non Mag flex drill collars and 4" HWDP with Dailey DNT Drilling Jars. Establish circulation & pump @ 225 GPM -1050 PSI to break in Geo-Pilot Seals as per Sperry Sun DD. Tri in hole with 4" DP to 284' - 04:30 06:00 1.50 284 4,970 PRODS DRILL TRIP T Trip in hole from 284' - 4970'. Fill drill string every 25 Stands,, pumping @ 200 GPM - 925 PSI. Blow down Top drive & Lines. Crew Chan e 06:00 07:30 1.50 4,970 7,215 PRODS DRILL TRIP T Continue trip in hole from 4970' - 7215'. Fill drill string every 25 stands. Blow down To Drive & lines. - ~ ~~e ~~ cif i7 Time Logs -- - __ __ __ --- Ph C d S b d T COM ~'~~~ ~~i ~a~ X37 Date From To Dur S-Deptth E Depth ase .o e u co_ e - _ - - . _ 06/24/2006 _ 07:30 08:45 1.25 7,215 7,228 PROD3 DRILL TRIP T Set bit depths & corelate with MWD for check shots. Observe MWD failing to give proper inclinations on surveys. Repeat troubleshooting attempts. MWD would not res and correct) . 08:45 09:00 0.25 7,228 7,228 PROD3 DRILL OWFF T Monitor well -static. Mix dry job for POOH. 09:00 11:45 2.75 7,228 284 PROD3 DRILL TRIP T Pump dry job, Blow down Top Drive. POOH from 7228' - 284'. Observe hole takin ro er hole fill. 11:45 12:00 0.25 284 92 PROD3 DRILL TRIP T Rack back 4" HWDP & Non Mag Flex Drill collars. Breakout & lay down Inte ral Blade stabilizer & float sub. 12:00 12:45 0.75 92 92 PROD3 DRILL OTHR T Plug in and download MWD assembly. Held PJSM. Discuss Safety issues and procedure for changing out MWD assembl . 12:45 14:15 1.50 92 284 PROD3 DRILL PULD T POOH, breakout & lay down failed MWD assembly. Make up new tools. Plug in and upload MWD. Make up 4" HWDP & Non Mag Flex Drill collars. Breakout & lay down Integral Blade stabilizer & float sub. 14:15 14:30 0.25 284 377 PROD3 DRILL TRIP T Trip in hole from 284' - 377'. Screw into To Drive. 14:30 14:45 0.25 377 377 PROD3 DRILL OTHR T Perform Shallow hole pulse test on MWD assembly. Pump @ 200 GPM - 1050 PSI. Good test. 14:45 17:15 2.50 377 5,527 PROD3 DRILL TRIP T Continue trip in hole from 377' - 5527'. Obtain T & D parameters as per Rig engineer every 10 stands. Filling drill string every 25 stands. Observe proper displacement on drill string on TIH. No issues while BHA passing through top of window. 17:15 17:45 0.50 5,527 5,611 PROD3 DRILL TRIP T Continue TIH pumping up surveys at depths of 552T, 5570', and 5611' as per MWD reps. Pumps @ 250 GPM - 1670 PSI. Good surve s. 17:45 18:00 0.25 5,611 6,466 PROD3 DRILL TRIP T Continue trip in hole from 5611' - 6466'. Dis lacement correct. Crew Chan e. 18:00 18:30 0.50 6,466 6,749 PROD3 DRILL TRIP T Continue TIH pumping up checkshot surveys at 6468', 6654', 6707', 6749', with pumps at 253 GPM - 1670 psi. Rotate drill string at 120 RPM's as per DD to break in seals on Geo -Pilot. 18:30 23:00 4.50 6,749 10,400 PROD3 DRILL REAM T Continue TIH from 6749' - 7690'. Observe run out of string weight and set down. Make Top drive connection. Wash & ream stands from 8805' - 9094'. Continue trip in hole on elevators to 9376', wash down to 9657'. Run on elevators to 10207'. Continue RIH on elevators to 10400'. _~ Time Lo s i ~ - - - ~ _- _ Date From To Dur __ S. Depth - E. Depth - Phase Code ._ - Suk~code _ T COM _ _ 06/24/2006 23:00 23:30 0.50 10,400 10,436 PROD'S DRILL REAM T Make Top drive connection and wash from 10400' - 10436'. Pumps @ 275 GPM - 2250 PSI. Rotate drill string @ 120 RPM's. Perform checkshot survey, and set tool face deflection as er DD. 23:30 00:00 0.50 10,436 10,462 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 10436' - 10462' MD. TVD = 3615'. (26'). UP WT = 155K, SO WT = 80K, ROT WT = 120K. WOB = 10-15K, 120 RPM's with Torque on bottom @ 7-8K, Torque off bottom @ 4-5K. Pumps @ 275 GPM's - 2870 PSI. ECD's @ 11.42 PPG, Max Gas observed = 62 Units.Total Bit Hrs = 33.71, Total Jar Hrs = 169.48 ADT = ,24 HRS,. ART = .24 Hrs. Survey @ 10463' MD, 3616' TVD, INC = 86.32 DEG, Azimuth = 3.81 Deg. Mud Wt = 8.8 PPG, Visc = 72, YP = 20. Pump Hi Visc weighted sweep to aid in hole cleanin and control ECD's. 06/25/2006 00:00 06:00 6.00 10,462 10,954 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 10462' - 10954' MD. TVD = 3614'. (492'). UP WT = 165K, SO WT = 80K, ROT WT = 121 K. WOB = 10-15K, 120 RPM's with Torque on bottom @ 7-8K, Torque off bottom @ 4-5K. Pumps @ 308 GPM's - 3150 PSI. ECD's @ 11.51 PPG, Max Gas observed = 74 Units.Total Bit Hrs = 38.05, Total Jar Hrs = 173.82 ADT = 4.34 HRS, ART = 4.34 Hrs. Survey @ 10933' MD, 3616' TVD, INC = 88.08 DEG, Azimuth = 1.94 Deg. Mud Wt = 8.8 PPG, Visc = 70, YP = 18. Pump Hi Visc weighted sweep to aid in hole cleaning and control ECD's. Observe 150°l° increase in cuttings when first sweep back after TIH. ECD's down to 11.1 PPG. Crew Chan e 06:00 12:00 6.00 10,954 11,465 PRODS DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 10954' - 11465' MD. TVD = 3638'. (511'). UP WT = 175K, SO WT = 85K, ROT WT = 120K. WOB = 10-15K, 120 RPM's with Torque on bottom @ 8-10K, Torque off bottom @ 5-7K. Pumps @ 315 GPM's - 3120 PSI. ECD's @ 11.65 PPG, Max Gas observed = 96 Units.Total Bit Hrs = 41.76, Total Jar Hrs = 177.53 ADT = 3.71 HRS, ART = 3.71 Hrs. Survey @ 11402' MD, 3636' TVD, INC = 88.51 DEG, Azimuth = 4.87 Deg. Mud Wt = 8.8 PPG, Visc = 64, YP = 20. Pump Hi Visc weighted sweep to aid. in hole cleanin and control ECD's. !'a~~ 'a7 ~f 87 - - - - - __ Time Logs - - - - - - - -- - - -- ~ate From To - Dur De th S D~(h E Phase Code Subcod e T COM _ 06/25/2006 _ 12:00 18:00 6.00 . 11,465 _ _ 11,640 PROD3 DRILL _ DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 11465' - 11640' MD. TVD = 3653'. (175'). UP WT = 180K, SO WT = 80K, ROT WT = 125K. WOB = 10-15K, 120 RPM's with Torque on bottom @ 8-10K, Torque off bottom @ 5-7K. Pumps @ 320 GPM's - 3295 PSI. ECD's @ 11.45 PPG, Max Gas observed = 95 Units.Total Bit Hrs = 46.93, Total Jar Hrs = 182.70 ADT = 5.17 HRS, ART = 5.17 Hrs. Survey @ 11590' MD, 3648' TVD, INC = 84.37 DEG, Azimuth = 1.07 Deg. Mud Wt = 8.8 PPG, Visc = 64, YP = 20. Pump Hi Visc weighted sweep to aid in hole cleaning and control ECD's. Increase in cuttings observed when sweep returned = 25 -50% Crew Chan e 18:00 00:00 6.00 11,640 12,094 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 11640' - 12094' MD. TVD = 3690'. (454'). UP WT = 180K, SO WT = 75K, ROT WT = 121 K. WOB = 10-15K, 120 RPM's with Torque on bottom @ 8-10K, Torque off bottom @ 5-7K. Pumps @ 311 GPM's - 3150 PSI. ECD's @ 11.53 PPG, Max Gas observed = 95 Units.Total Bit Hrs = 50.28, Total Jar Hrs = 186.05 ADT = 3.35 HRS, ART = 3.35 Hrs. Survey @ 12060' MD, 3678' TVD, INC = 86.56 DEG, Azimuth = .37 Deg. Mud Wt = 8.75 PPG, Visc = 70, YP = 20. Pump Hi Visc weighted sweep to aid in hole cleaning and control ECD's. Total of 24Concretions drill since last on bottom = 156' for an average thickness of 6.5'. NOTE: Observed 20 Gallons of LVT 200 spill on pad outside of pit module. Rig crew stopped drilling as tanned for 30 minutes for Cleanu . ~r ~ _ ~ ~~~ 6~ of 87 Time Logs __ _ ~ ____ _ C d d ~ b T COM - - - ~e'~ga ~~ ~'~ 37 Date From To Dur S. Depth E Depth Phase o e -- ~u co e - - 06l26/2006 00:00 ___ 01:30 _ _ .1.50 12,094 12,227 PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the "D" Lateral from 12094' - 12227' MD. TVD = 3685'. (133'). UP WT = 180K, SO WT = 75K, ROT WT = 121 K. WOB = 10-15K, 120 RPM's with Torque on bottom @ 8-10K, Torque off bottom @ 5-7K. Pumps @ 311 GPM's - 3250 PSI. ECD's @ 11.91 PPG, Max Gas observed = 89 Units.Total Bit Hrs = 51.05, Total Jar Hrs = 186.82 ADT = .77 HRS, ART = .77 Hrs. Survey @ 12227 MD, 3685' TVD, INC = 86.15 DEG, Azimuth = ..37 Deg. Mud Wt = 8.75 PPG, Visc = 70, YP = 20. Pump Hi Visc weighted sweep to aid in hole cleaning and control ECD's. Total Concretions drill since last on bottom = 156' for an avera a thickness of 6.5'. 01:30 02:30 1.00 12,227 12,227 PROD3 DRILL CIRC P Mix & pump Hi Visc weighted sweep @ 310 GPM - 3260 PSI, allowing sweep to come up on the annulus. Reciprocate & rotate drill string while um swee . 02:30 02:45 0.25 12,227 12,227 PROD3 DRILL OWFF P Pumps off, Monitor well -static. Held PJSM on BROOH. Discuss Safety Issues and rocedure for BROOH. 02:45 06:00 3.25 12,227 10,200 PROD3 DRILL REAM P BROOH from 12227'- 10200' Initial back ream rate at 15 - 20 ft/min, observing no hole issues. Continue Back ream increasing string speed to 40-50 Ft/min. Back ream with pumps at 310 GPM - 3250 PSI observing no hole issues, with proper hole fill. ECD = 11.87 PPG. Crew Chan e 06:00 12:00 6.00 10,200 7,900 PROD3 DRILL REAM P Continue BROOH from 10200' - 7900' MD. Back ream with string speed to 40-50 Ft/min. Back ream with pumps at 300 GPM - 2950 PSI observing no hole issues, with proper hole fill. ECD = 10.8 PPG 12:00 18:00 6.00 7,900 5,531 PROD3 DRILL REAM P Continue BROOH from 7900' - 5531' MD. Back ream with string speed to 40-50 Ft/min. Back ream with pumps at 300 GPM - 2255 PSI observing no hole issues, with proper hole fill. ECD = 10.2 PPG. Crew Chan e 18:00 18:45 0.75 5,531 5,531 PROD3 RIGMN RGRP T Trouble shoot Top Drive problem. SHot pin assembly on Top Drive failed. Would not allow proper make up on drill strin for BROOH. 18:45 20:00 1.25 5,531 4,970 PROD3 DRILL TRIP P Continue POOH on elevators last 5 stands, with no hole issues and proper hole fill. Pull up inside window area, no issues bringing drilling assembly through window. Install TIW valve in drill strin . _ _ _~ -- - - Time Logs _ Date From To Dur S Depth E_ Depth Phase_ Code Subcode T COM __ _ - _ _ - - _ 06/26/2006 20:00 23:15. 3.25 4,970 4,970 PRODS RIGMN RGRP T Rig up and remove Top Drive Shot pin assembly from Top drive. Redress asssembl . 23:15 00:00 0.75 4,970 4,970 PRODS DRILL CIRC P Make up head pin assembly with hose and rig up to circulate Hi visc weighted sweep as' planned. Circulate at 300 GPM - 2000 PSI, pumping a total of 340 BBLS with no significant increase in cuttings observed at shakers when sweep returned. Redress top drive shot pin assembly while circulating sweep as tanned. 06/27/2006 00:00 00:30 0.50 4,970 4,970 PRODS DRILL CIRC P Contiue circulate Hi Visc sweep. Circulate at 300 GPM - 2000 PSI, pumping a total of 340 BBLS with no significant increase in cuttings observed at shakers when sweep returned. 00:30 01:30 1.00 4,970 4,970 PRODS RIGMN RGRP T Continue rebuild Top Drive Shot pin assembl .Install & test same. 01:30 01:45 0.25 4,970 4,970 PRODS RIGMN SFTY P Held PJSM with crew. biscuss Saftey issues and procedure for slipping & cutting drilling Line. Discuss new hands on crew. 01:45 04:00 2.25 4,970 4,970 PRODS RIGMN SVRG P Hang blocks., Rig up, Slip & Cut 144' of drilling line. Inspect Top Drive and draw works. Inspect brakes. Un hang blocks, and re are for TIH. 04:00 06:00 2.00 4,970 7,316 PRODS RIGMN OTHR P Pull TIW Valve from assembly. Trip in hole with drilling assembly from 4970' - 7316' MD. UP WT = 135K, SO WT = 110K. Obsreved no issues when passing BHA through window area. Crew Chan e 06:00 10:15 4.25 7,316 12,096 PRODS DRILL TRIP P Continue trip in hole from 7316' - 12096'. Fill drill string every 25 stands. Observe no issues in open hole. Hole looked clean. 10:15 11:15 1.00 12,096 1,227 PRODS DRILL REAM P Screw in to Top Drive, wash & ream from 12096' - 1227. Pumps at 300 GPM's - 3500 PSI. Rotate @ 120 RPM's with 5K torque. UP WT = 122K, SO WT = 105K, ROT WT = 112K. 11:15 12:00 0.75 1,227 12,227 PRODS DRILL CIRC P Circulate & condition hole while reciprocating & rotating drill string. Pum 300 GPM - 3500 PSI. 12:00 13:15 1.25 12,227 12,227 PRODS DRILL CIRC P Pump Hi Visc weighted sweep @ 300 GPM - 3500 PSI. Sweep = 10.2 PPG 135 VISC. 13:15 14:15 1.00 12,227 12,227 PRODS DRILL CIRC P Continue pumping displacing Open Hole volume with 360 BBLS of 8.8 PPG SFMOBM @ 300 GPM - 3450 PSI. Pump 10.2 PPG dry job. Monitor well -static. ----°-- rt _~ _ Iwa~e :'4 t~f ~? ~ ~ Time Loos _ _ _ ____ n~... ter,,.., r~ n. ~~ c no„th F flPnth PhacP ('nrie Si ihr.ndP T COM 06!27/2006 14:15 18:00 3.75 12,227 5,344 PROD3 DRILL TRIP P POOH on elevators from 12227' - 5344' MD. Obtain T & D parameters as per rig engineer every 5 stands in open hole. Check pipe tally with SLM on TOH. Observe no hole issues, no . over ull. Crew Chan e 18:00 20:45 2.75 5,344 283 PROD3 DRILL TRIP P Continue POOH from 5344' - 283'. Obtain T&D parameters as per rig engineer. Check pipe tally against SLM taken. No corrections needed. 20:45 21:45 1.00 283 92 PROD3 DRILL PULD P Breakout & lay down BHA #11 as per DD &MWD reps. Lay down 3 -Non Mag Flex Drill collars (93.39'), Crossover sub (3.00'), 1 - Jnt 4" HWDP (30.68'), 4 3/4" Dailey Drilling Jars (32.25'), and 1 joint of 4" HWDP 30.69' . 21:45 22:45 1.00 92 92 PROD3 DRILL PULD P plug in and download MWD as§ebly. 22:45 23:15 0.50 92 0 PROD3 DRILL Continue breakout & lay down 6 3/4" Security Bit FMF3641Z (1.30') with 3 x 21 jets for a TFA of 1.015 sq in., on 5.20" Geo-Pilot 5200 Series (16.18'). MU 4 3/4" Non Mag Flex Drill Collar (11.55'), MWD DM/HOC (8.56'), 4 3/4" Smart Stabilizer Sleeve type (3.60'), MWD Gamma/Res (23.75'), MWD PWD (10.69'), TM HOC (11.27').4 3/4" Non Mag Float sub (2.38'), and 4 3/4" Integral Blade Stabilizer (4.58'). Inspect&gradebit@2/3/BT/A/X / I / CT TD. Clean & clear floor area. Send tools out. 23:15 23:45 0.50 0 58 PROD3 DRILL PULD P Held PJSM. Discuss Safety Issues and procedure for making up BHA & new hands. Make up MWD assembly with float sub 58.47 . 23:45 00:00 0.25 58 95 PROD3 DRILL PULD P MU BOT Whipstock hook (7.50'), with 1 - 'oint of 3 1/2" HWDP 29.79' . 06/28/2006 00:00 00:45 0.75 95 95 PROD3 DRILL PULD P Continue make up BHA -Whipstock retrieving assembly. MU MWD assembly (58'). Orient MWD to 180 de of hook. 00:45 01:30 0.75 95 95 PROD3 DRILL PULD P Plug in and Upload MWD assembly. 01:30 02:00 0.50 95 117 PROD3 DRILL TRIP P Contirue MU BHA # 12 MU 3/4" Bumper Jar (7.8T), 4 3/4" Oil jar (11.14'), and crossover (3.00'). Total BHA len th = 117.77'. 02:00 02:15 0.25 117 211 PROD3 DRILL TRIP P Trip in hole with BHA #12 from 11 T - 211'. Attempt shallow pulse test. Could not get a good test as the pit volume allowed pump to suck air. Gettin ood ulses but not decodin . 02:15 03:45 1.50 211 2,455 PROD3 DRILL TRIP P Trip in hole from 211' - 2455'. Fill drill string and attempt pulse test. Good ulses, not decodin . F~r~e 71 of ~7 --- ~me Lods 'Date Frorn To Dur _S Depth E._Deptt~ Phase CodE Subcode T _ CQM _ _ 06/28/2006 03:45 05:15 1.50 2,455 5,082 PROD3 DRILL TRIP P Trip in hole from 2455' - 5082'. 05:15 06:00 0.75 5,082 5,087 PROD3 DRILL OTHR P Obtain parameters as per BOT fishing Rep. UP WT = 170K, SO WT = 140K. Pumps at 250 GPM - 1950 PSI. Observe good MWD pulses and surveys. Attempt to hook Whipstock assembly, with repeated attempts. Observe hooked 1 time, and pull to 50K over. Weight immediately fell off.Crew Chan e 06:00 07:15 1.25 5,087 5,087 PROD3 DRILL OTHR P Continue attempting to engage Whipstock assembly with no good indication of hook engaging. Observe finally a good set down, and pull up to see little or no gain in string weight. Whipstock should weigh +/- 5K. With a good set down weight, assumed latch up and BTA released, pull up slowl to observe no swabbin . 07:15 07:45 0.50 5,087 4,700 PROD3 DRILL TRIP P Continue pull up slowly from 5082' , while monitoring well for swab, or loss of fluid. None observed. No good indication of fish on. 07:45 11:45 4.00 4,700 117 PROD3 DRILL TRIP P Continue POOH slowly as per BOT rep. Monitor well for swabbing. None observed. Hole fill correct. 11:45 12:45 1.00 117 95 PROD3 DRILL PULD P Breakout & lay down Bumper jar 7.87' . & Oil Jar 11.14' . 12:45 13:30 0.75 95 0 PROD3 DRILL PULD P Pull remaining BHA to rig floor and observe "no fish". Breakout, Inspect & lay down Retrieving Hook. Hook in good shape with only a small mark on it, but left good indication that we had been hooked. 13:30 13:45 0.25. 0 0 PROD3 DRILL SFTY P PJSM with crew. Discuss Safety issues and procedure for laying down MWD assembl . 13:45 14:30 0.75 0 0 PROD3 DRILL PULD P Breakout & lay down MWD assembly as er S er Sun re . 14:30 15:45 1.25 0 464 PROD3 FISH PULD T PJSM with crew. Discuss Safety Issues and procedure for making up BHA # 13. MAke up Bha #13 as per BOT rep. MU 6.64" Box Tap (4.18'), 4 3/4" Float sub (2.38'), Bumper Jar (7.8T), Oil Jar (11.14'), 9 - jnts Hybrid Push Pipe. (278.26'). Total BHA = 464.14' 15:45 18:00 2.25 464 3,862 PROD3 FISH PULD T Trip in hole with BHA #13 from 464' - 3862'. Observe proper hole fill. UP WT = 140K, SO WT = 120K Crew Chan e 18:00 19:45 1.75 3,862 5,082 PROD3 FISH PULD T Continue Trip in hole from 3862' - 5082'. P~e~e i~ crf-~7 ~ _ ~ _ _ - Time Lo s _ _ _ _ - -- m te Fr G To Dur Depth S De th E F'hase Code Suboode T COM _ ___ -- a 06/28/2006 o 19:45 21:00 _ 1.25 _ _ 5,082 _ 5,082 PROD`S FISH - - FISH T Obtain parameters as per BOT rep. UP WT = 168K, SO WT = 148K. ROT WT = 156K. Pumps at 31 SPM - 380 PSI. Tagged top of whipstock on depth. Work Box Tap over top of whipstock, and work RH torque down to observe a 10K torque held in fish. Allow torque to release. Pull up to observe little or no increase in upweight. Monitor well - static. 21:00 00:00 3.00 5,082 306 PRODS FISH TRIP T POOH from 5082' - 306'. Observe proper hole fill, no swabbing. Indications that we may have a fish on, but no drag. The box Tap indicated we had a ood catch. 06/29/2006 00:00 00:45 0.75 306 0 PRODS FISH TRIP T Continue POOH with BHA #13. Rack Back 3 stands of hybrid push pipe. Lay down crossover sub, and POOH to observe no whipstock retrieved. Observe Box Tap held 26" of top of i whipstock. Discuss options with BOT rep. Decision to RIH with Retrieving Hook for run#2. Inspect Box Tap and take ictures. Send to town. 00:45 01:45 1.00 0 339 PRODS FISH PULD T Mu Fishing BHA #3. Retrieving Hook Assembly.MU Hook (7.50'), 3 1/2" HWDP (29.79', 4 3/4" Bumper Jar (7.87'), 4 3/4" Oil jar (11.14'), and crossover (3.00'). No MWD assembly. Total BHA = 339.94'. 01:45 04:30 2.75 339 5,084 PRODS FISH TRIP T Trip in hole with Fishing BHA #3 from 339' - 5084'. Fill drill string evry 25 stands. Observe ro er hole fill. ~~ ~g~ ?3 ~f ~7- ~ ~ -- me Logs - __ - ~ __ ~ Date From To Dur S Depth E_ De tp h Phase Code Subcode T COM - _ 06/29/2006 _ 04:30 06:00 __ 1.50 5,084 5,087 PROD3 __ FISH FISH T MU Top Drive. Wash down to expected top of fish @ 5084'.UP WT = 173K, SO WT = 148K, Pumps @ 27 SPM - 500 PSI. Tag top of whipstock @ 5084'. Pick up and rotate 1/4 turn to slack off and observe hook go over top of whipstock, and work down 6' on the slide and taking weight. Work hook to locate Slot @ 508T as planned. All depths and measurements verified and we are confident of them. Continue to work 1/4 RH turns in drill string to attempt to hook slot. We could see and set down on the bottom of the slot with the hook, but observed no increase in weight, or overpull as we pulled up on string. Continue fishing with repeated attempts to hook the slot with pumps on and off. We could not get down far enough on the slide to allow the wash port to wash the hook slot. We needed 10 more feet and could only slack off 6', when taking weight of up to 15K. The slide may have turned??? Continue attempt to engage the slot with no indication of success. Good set down indications but no increase in upweight or overpull. Crew chap e. 06:00 07:00 1.00 5,087 5,087 PROD3 FISH FISH T Continue attempts to engage whipstock slot @ 5087'. No indication of success, only indication of good set down weight, but no increase in u wei ht when icked u . 07:00 07:15 0.25 5,087 5,087 PROD3 FISH TRIP T Monitor well -static. Observe no fluid loss while fishin . 07:15 10:30 3.25 5,087 278 PROD3 FISH TRIP T POOH from 5087' (slot depth) - 278'. Observe ro er hole fill 10:30 11:00 0.50 278 0 PROD3 FISH PULD T Breakout, inspect and lay down retrieving hook. No damage or indications of having had a good hook on the whipstock. Clear & clean floor area. 11:00 14:00 3.00 0 0 PROD3 RIGMN RGRP T Held PJSM with crew. Discuss safety issues and procedure for repairing hydraulic cylinder on Iron Roughneck. Rig up, remove cylinder, and replace same. Good 'ob, no incidents. 14:00 14:15 0.25 0 0 PROD3 FISH SFTY T Held PJSM with BOT rep & crew. Discuss Safety Issues and procedure for makin u next BHA. ~.. T~~ ~~ge 7=~ cai ~7 - - _ _ _ ~ Time Logs _ - - -- ~ Date From To Dur S,_Depth E_ Depth Phase Code Subcode T _ COM _ _ _ _ 06/29/2006 _ 14:15 14:45 0.50 0 339 PROD3 FISH PULD T Make up Fishing BHA #4 as per BOT rep. MU Retrieving Hook Assembly, Hook with 8 Deg bend in it (7.50'), 3 1/2" HWDP (29.79', 4 3/4" Bumper Jar (7.87'), 4 3/4" Oil jar (11.14'), and crossover (3.00'). Total BHA length = 339.94'. 14:45 17:30 2.75 339 5,009 PROD3 FISH TRIP T Trip in hole with Fishing BHA #4 from 339' - 5009'. Fill drill string every 25 stands. Observed ro er hole fill. 17:30 18:00 0.50 5,009 5,087 PROD3 FISH FISH T Make Top Drive connection, and wash down to top of whipstock @ 5084'. UP WT = 173K, SO WT = 148K, Pumps @ 4.5 BPM - 620 PSI. Obtain parameters with no pump, UP WT = 173K, SO WT = 150K. Attempt to engage Slot in slide, as per BOT rep. With repeated attempts, no indications of successful catch. We only had indications of good set down weight on bottom of slot, but no increase in upweight or overpull. Hook would not engage slot completely. All measurements double checked and verified. Crew chan e 18:00 19:15 1.25 5,087 5,087 PROD3 FISH FISH T Continue attempt to engage whipstock slot with bent Retrieving hook. UP WT = 173K, SO WT = 148K, Pumps @ 4.5 BPM - 620 PSI. Obtain parameters with no pump, UP WT = 173K, SO WT = 150K. Attempt to engage Slot in slide, as per BOT rep. With repeated attempts, no indications of successful catch. On last attempt, observed up to a 17K overpull, while rocking drill string 1/4 turns left & right to aid in engagement. The weight slowly fell off like the Oil jars may have opened. We saw no significant increase in the upweight though. Discuss options. Decide to POOH with the hope of havin at least the slide. 19:15 22:00 2.75 5,087 339 PROD3 FISH TRIP T Monitor well, static. Observe well took about 3 BBLS to top off. POOH from 5087 - 339'. 22:00 23:00 1.00 339 0 PROD3 FISH PULD T Brekaout & fay down fishing assembly. Inspect retriveing hook. Hook indicated a "flat" spot on the leading edge indicating hook trying to engage slot but only getting into slot partially. Take Pictures, send to town. Clean & clear rig floor. Lay. down tools. Pull tools to rig floor while discuss options with town. ~~~_.~ ~ ._... _ ~'arJn ?;3 of 47 -- - - --- _ - - Time Low - _. - - - 1 -- _ __ Date From To Dur S, Depth E Depth Phase Code ._ Subcode T _ COM_ _ _ _ - __ 06/29/2006 23:00 23:45 0.75 0 313 PROD3 FISH PULD T Make up Fishing BHA 35. Make up 6 3/4" Inside Milling shoe (1.79'), 6 3/4" Wash Pipe pup (6.0'), 6 5/16" Washover Boot Basket (3.07'), 4 3/4" Float sub (2.38'), Bumper Jar (7.87'), Oil Jar (11.14'), Crossover (3.0'), and 3 stands of Hybrid pipe (278.26'). BHA #5 Total Len th = 313.51'. 23:45 00:00 0.25 313 1,154 PROD3 FISH TRIP T Trip in hole with BHA #5 from 313' - 1154'. Observe ro er hole fill. 06/30/2006 00:00 02:30 2.50 1,154 5,084 PROD3 FISH TRIP T Contiue Trip In hole with fishing BHA #5.6 3/4" x 4 3/4" Inside Mill Shoe Assembl .Observe ro er hole fill. 02:30 04:00 1.50 5,084 5,084 PROD3 FISH FISH T Make up Top Drive, obtain parameters. Wash down down to top of Whipstock @ 5084'. UP WT = 166K, SO WT = 144K, ROT WT = 153K. Torque at 3-5K. Pumps @ 225 GPM - 700 PSI. Tag top of whipstock @ 5084'. Rotate with mill to observe mill working down the slide and not OVER the top of it to mill the fishing neck. Repeat attempts to get mill over the Whipstock with no success. We could not SEE the top of the whipstock again, after milling, indicating the top was cleaned up. We also could not get out of the window, and were only able to go 4' down the slide. This may also indicate the slide has turned.?? 04:00 05:00 1.00 5,084 5,084 PROD3 FISH CIRC T Mix & pump Hi Visc sweep at 400 GPM's - 2200 PSI. Moniotor well - static. 05:00 06:00 1.00 5,084 3,765 PROD3 FISH TRIP T POOH from 5084' - 3765'. Observe Pro er Hole fill. Crew Chan e. 06:00 08:00 2.00 3,765 313 PROD3 FISH TRIP T Continue POOH from 3765' - 313'. Held BOP drill while tripping on TOH. All hands responded. Observed proper hole fill. 08:00 08:15 0.25 313 313 PROD3 FISH SFTY T Held PJSM with crew & BOT Rep. Discuss Safety Issues and procedure for laying down BHA. Safety Note: Forklift driver on nights experiencing health issue. Sent to Medic @ KOC. Hand being sent to town with Gallstone issues. 08:15 08:45 0.50 313 0 PROD3 FISH PULD T Breakout, Inspect & lay down 6 3/4" Inside milling shoe. MITI showed little or no marks on the ID to indicate that we had been over the top of the whipstock. No damage or serious indications on the OD of mill also. Clean out Boot basket. Recovered no iron. 08:45 09:15 0.50 0 0 PROD3 FISH PULD T Clear & clean floor area. Pull Washing Sub to ri floor. '_ ~- e --_- C' ~ G~' t s~ C}~ ~ P Time Logs__ ~ - - -- ---~ - - -- - - Date From To Dur S_Depth__E Depth Phase Code Subcode T COM _ _ _ _ 06/30/2006 09:15 09:30 0.25 0 312 PROD3 FISH PULD T Strap & make up Washing sub assembly. Fishing BHA # 6. Make up 4" XT39 Washing sub (6.80'), Crossover (2.96')', Float sub (2.38'), Bumper Jar (7.87'), Oil Jar (11.14'), Crossover (3.0'), and 3 stands of Hybrid Push pipe (278.26'). Total BHA = 312.41' 09:30 12:00 2.50 312 4,982 PROD3 FISH TRIP T Trip in hole with Fishing BHA #6 from 312' - 4982'. Fill drill string every 25 stands. Observe ro er hole fill. 12:00 12:30 0.50 4,982 5,073 PROD3 FISH FISH T Make Top Drive connection. Establish parameters. UP WT = 161 K, SO WT = 137K. ROT WT = 148K. Pumps at 420 GPM's - 2350 PSI. 12:30 13:45 1.25 5,073 5,089 PROD3 FISH FISH T Work string down to observe washing tool tag top of whipstock @ 5084'. Pull up, slowly rotate down to allow washing tool to 5089' MD. Reciprocate & rotate drill string allowing tool to wash slot in whipstock @ 5087'. Pump 25 BBLs of Hi Visc sweep, 8.8 PPG. Rotate @ 30 RPM's with 3-4K torque. '~ Observed no for ue issues on bottom. 13:45 15:45 2.00 5,089 312 PROD3 FISH TRIP T POOH from 5089' - 312'. Observe ro er hole fill. 15:45 16:00 0.25 312 0 PROD3 FISH PULD T Breakout, inspect & lay down wash sub assembly. Observe wash tool damaged, leaving a piece of iron in the hole, approximately 1 1/2" x 7" long. The end of the tool was damaged as well indicating tagging top of whipstock or junk, and peeling the end, allowing the tool to break. Obtain pictures and send to town. 16:00 16:15 0.25 0 339 PROD3 FISH PULD T Make up Fishing assembly #7. Make up Retrieving hook, bent as requested (7.50'), 1 -jnt of 3 1/2" HWDP (29.79'), Float sub (2.38'), Bumper Jar (7.87'), Oil Jar (11.14'), Crossover (3.00'), and 3 stands of Hybrid push pipe (278.26'). Total BH = 339.94. NOTE: 4th run with Retrieving hook assembly. 2 runs with Bent Hook. 16:15 18:00 1.75 339 2,681 PROD3 FISH TRIP T Trip in hole with Fishing BHA #7 from 339' - 2681'. Fill drill string every 25 stands, observing proper hole fill. Crew Chan e 18:00 20:00 2.00 2,681 5,084 PROD3 FISH TRIP T Continue trip in hole with 8HA #7 from 2681" - 5084'. Observe proper hole fill, fillin drill strin on bottom. 20:00 20:15 0.25 5,084 5,084 PROD3 FISH FISH T Make Top Drive Connection. Obtain parameters. UP WT = 170K, SO WT = 150K. Pum s 26 SPM - 270 PSI. ~ 1~~g~ ?7 oaf 87 ~____ ~ ____:_s _..; _ ~ - - - - -- Time Lo s g ~ _ Date From To Dur 5. Depth E De nth Phase Code S_ubcode T CAM ___ ____ ___ _ _~ _ 06/30/2006 20:15 22:00 1.75 5,084 5,099 PROD3 FISH FISH T Attempt to engage whipstock with retrieving hook. Observe tagging top of whipstock as before at 5084'. We were able to locate & set down in the slot @ 5087' 4 different times. We saw no increase in up weight or overpull each time we were able to set down, indicating hook would not engage. Repeat attempts to engage numerous times, observing we could slack off to 5' outside the bottom of the window to a depth of 5099'. This was thefirst time we could go down this far??. We utilized the washing slots in the Hook Tool joint to wash the slot, and continued to attempt to engage the slot. Again, with no success. Monitor well -static. 22:00 00:00 2.00 5,099 339 PROD3 FISH TRIP T POOH from 5084' - 339'. Observe ro er hole fill. 07/01/2006 00:00 00:15 0.25 339 0 PROD3 RIGMN SFTY T Held PJSM with Crew. Discuss Safety .Issues and procedure for laying down BHA & Slipping & cutting Drilling line with new hands. 00:15 01:15 1.00 339 0 PROD3 FISH PULD T Breakout, Inspect & lay down Bent hook assembly. Observe no damage on Retrievin Hook. Take Pictues. 01:15 02:45 1.50 0 0 PROD3 RIGMN SVRG T Rig up, Slip & cut drilling line. Inspect brakes,. Service To Drive. 02:45 03:30 0.75 0 320 PROD3 FISH PULD T Make up BHA #8.6.800" x 4 3/4" Bu4rn Shoe (4.04'), 6 3/8" Washpipe Extension (6.0'), Washover Boot Basket (3.07, 6 3!4" String Stabilizer (4.43'), Float Sub (2.38'), Bumper Jar (7.87'}, Oil Jar (11.14'), Crossover (3.0'), 3 -stands of Hybrid Push Pipe 278.26' .Total BHA = 320.19'. 03:30 04:45 1.25 320 1,441 PROD3 FISH TRIP T Trip in hole with Fishing BHA #8. Observe tagging up HARD @ 1441'. Suspect the stiff assembly and the OD of Shoe hung up in casing Collar. Attempt to get through, no success. Observe 40K over ull. 04:45 05:15 0.50 1,441 320 PROD3 FISH TRIP T POOH from 1441' - 320'. Observe ro er hole fill 05:15 06:00 0.75 320 0 PROD3 FISH PULD T Breakout & lay down BHA #8. Observe NO damage on Shoe. Discuss options with town. Crew Chan e 06:00 06:30 0.50 0 339 PROD3 FISH PULD T Continue POOH breakout & lay down BHA #8. Continue Discuss optiions with town. Decision to Rerun Straight Retrievin Hook assembl . 06:30 07:00 0.50 0 0 PROD3 RIGMN SVRG T Service Rig. Greasing draw works, etc. Retrieving Hook being sent from Deadhorse Sho . ~ac~e 7 of £~7 ~ Time Lo~_ - _ - - -- - - Dur _ S. De~t_h E _D_ e th Ph2se Code Subcode T C_OM_ _ _ _ _ ___ Date From To _ 07/01/2006 07:00 07:15 0.25 0 0 PROD3 FISH SFTY T Field PJSM with Crew & BOT Rep. Discuss safety issues, and procedure for making up BHA. Discuss "Proper Chan Bouts". 07:15 08:15 1.00 0 339 PROD3 FISH PULD T MU BHA #9. MU Retrieving hook, (7.50'), 1 -jnt of 3 1/2" HWDP (29.79'), Float sub (2.38'), Bumper Jar (7.87'), Oil Jar (11.14'), Crossover (3.00'), and 3 stands of Hybrid push pipe (278.26'). Total BHA = 339.94. NOTE: 5th run with Retrieving hook assembly. 2 runs with Bent Hook. 08:15 10:30 2.25 339 5,010 PROD3 FISH TRIP T Trip in hole with BHA #9 from 339' - 5010'. Observe ro er hole fill on tri . 10:30 10:45 0.25 5,010 5,010 PROD3 FISH FISH T Make up Top Drive. Obtain Parameters. UP WT = 173K, SO WT = 148K. Pumps at 26 SPM - 375 PSI. Slack off to tag top of fish as expected 5084'. 10:45 11:30 0.75 5,010 5,087 PROD3 FISH FISH T Work string with parameters as above, and locate slot in whipstock slide @ 5087'. Continue attempt to hook slot until observing hooked up while pulling up. Observe increase in weight and pull to 20K over allowing jars to bleed open. Continue work drill string as normal, finally pulling to 90K over to observe jars fire and BTA released. Pull assembly by window area observing 20K drag in string. FISH ONII 11:30 12:15 0.75 5,087 5,050 PROD3 FISH CIRC T Circulate bottoms up, observing hole taking 39 BBLs mud to fill. No gas on bottoms up. Monitor well 15 min - static. 12:15 12:45 0.50 5,050 4,864 PROD3 FISH TRIP T POOH SLOW from 5050' - 4864'. Drill string wet, hole swabbing. Observe that the drag on the debris cup wore out the cup and hole began to take fluid. 12:45 13:00 0.25 4,864 4,864 PROD3 FISH TRIP T Make Top Drive connection. Pump dry 'ob. 2 PPB over. 13:00 16:00 3.00 4,864 339 PROD3 FISH TRIP T Continue POH with BHA #9 & FISH from 4864' - 339'. ~ _____ a0~ ~~ cif ~7 Time Lis ' ~ - --- -- - - Date Fro m To Dur S Depth E_ Depth Phase Code Sut~code T CC~M _ '~ 07/01/2006 __ 16:00 16:30. ._ 0.50 _ 339 95 __ PROD3 FISH PULD T Breakout & lay down Fishing assembly #9. Retrieving Hook. Set whipstock on clamp in rotary table. Take pictures, send to town. Whipstock slide indicated damage to the top from Box Tap run. It also showed effects of the initial milling job on the window. The Starting mill had tracked down the right side of the slide, and completely OFF to the right side at about the 9' mark, making its own tray. There is a definite THIN side on the right, as opposed to the left side of the tray. This indicated the slot may have been "pinched" while attempting to fish. The original MWD inclination indicated setting the slide @ 10 Degrees left of high side. The indication on the whipstock shows that the kick off may have been as much as 45 de rees Ri ht of hi h side. 16:30 18:00 1.50 95 0 PROD3 FISH PULD P Breakout & lay down Whipstock assembly. Lay down Whipstock (13.35'), Debris Sub (1.85'), Drain Sub (1.02'), Shear Disconnect (2.71'), BTA (3.22'), Crossover sub (1.35'), Blank SUb (1.00'), 2 Joints of 3 1/2 IF Drill Pipe (62.09'), Unloader sub (5.21'), and NO-Go with seals (1.92'). Total fish recovered = 95.72'. The seals on the seal assembly were in good shape with no dams e. Crew Chan e 18:00 18:30 0.50 0 0 PROD3 FISH PULD P Clear & Clean Rig Floor area. Send tools out. Pull Clean out tools to rig floor. 18:30 18:45 0.25 0 0 PROD3 FISH PULD T Begin Make up Fishing. BHA #10. 18:45 19:30 0.75 0 0 PROD3 FISH FISH T Floorhand observed Broken Metal Piece on top of Annular Bag in BOP Stack. Make up String Magnet on location on 1 joint of drill pipe. RIH to top of Annular, observing magnet pick up piece of lost metal. This piece came from the washing tool assembly previously run in hole to wash slot in whi stock where it broke off. 19:30 20:15 0.75 0 311 PROD3 FISH PULD NP Continnue Make up BHA #10. Make up 6 5/8" Reverse Basket (5.70'), 4 3/4" String Magnet (5.50'), Bumper Jar (7.8T), Oil Jar (11.14'), Crossover (3.00'), 3 stands of Hybrid Push Pipe 278.26' .Total BHA = 311.4T. 20:15 22:30 2.25 311 5,074 PROD3 FISH TRIP NP Trip in hole with BHA # 10 from 311'. - 5074'. Drop Ball on stand # 35 to have ball in lace when on bottom. _ ~'~~~ ~4 Qt °7 ~me Logs ,Date ...From To Dur S e th E. De th Phase..... .Code Subcode T COM ~ 07/01/2006 22:30 00:00 1.50 5,074 5,177 PRODS __ FISH _ FISH NP Make Top Drive Connection. Obtain parameters. UP WT = 165K, SO WT = 145K, ROT WT = 152K. Pumps @ 35 SPM - 810 PSI. Wash down without rotating through window area with no issues. Observed tagging on on top of B lateral top @ 5177' DPM. Repeat tag - same depth. Add 170 BBLs of SFMOBM to system displacing OBM while circulating bottoms up @ 60 SPM - 1550 PSI. Observed max gas @ 33 units. No issues with magnet in hole. 07/02/2006 00:00 00:15 0.25 5,177 5,177 PRODS FISH CIRC NP Monitor well -static. 00:15 02:45 .2.50 5,177 311 PRODS FISH TRIP NP POOH from 5177' - 311'. Observe ro er hole fill. 02:45 03:30 0.75 311 0 PRODS FISH PULD NP Breakout & lay down BHA. Lay down 6 5/8" Reverse Basket (5.70'), 4 3/4" String Magnet (5.50'), Bumper Jar (7.87'), Oil Jar (11.14'), Crossover (3.00'), 3 stands of Hybrid Push Pipe (278.26'). Total BHA = 311.47'. Clean out reverse basket, recovered handful of iron cuttings including broken piece of cut lip off of Box Tap previously run. The string magnet was full of iron cuttin s as well. 03:30 03:45 0.25 0 0 PRODS FISH PULD NP Clean & clear rig floor area, send tools out. 03:45 04:15 0.50 0 349 PRODS FISH PULD NP Make up BHA # 11. Dummy seals. Make up 4 3/4" Seals (3.27'), Tubing Joint IBT (41.86'), Crossover to XT39 (.67'), Crossover to 3 1/2 IF (.67), Bumper Jar (7.8T), Oil Jar (11.14'), Crossover to XT39 (278.26'). Total BHA = 349.03. Top of liner last tagged @ 5177' DPM. Expect to bottom out @ 5215' DPM. 04:15 06:00 1.75 349 3,440 PRODS FISH TRIP NP Trip in hole with BHA #11 from 349' - 3440'. Observe Proper Hole fill Crew Chan e. 06:00 07:45 4.75 3,440 5,142 PRODS FISH TRIP NP Continue Trip in hole with BHA # 11 from 3440' -5142'. Pick u sin le. 07:45 08:45 1.00 5,142 5,215 PRODS FISH FISH NP Obtain Parameters. UP WT = 175K, SO WT = 150K, Pumps @ 85 GPM's - 240 PSI. Circulate down to tag top of liner @ 5177' DPM. Continue slack off to bottom out on crossover in Seal Bore @ 5215'. Observe no issues with junk. Pumps off while insert dummy seals into seal bore. Pull out of seal bore. 08:45 09:00 0.25 5,215 5,177 PRODS FISH TRIP NP Monitor well -static. No fluid lost while um in . 09:00 11:30 2.50 5,177 349 PRODS FISH TRIP NP POOH with BHA #11 from 5177' - 349'. ~~c~~~ ~~ cif 37 Time Logs - - - --- - - -- -- -- -- - - - _ - - - --- ---- Date From To Dur 5. Depth E. Depth i Fha~e Code Su~coi;e_ T COh~1 ___ ___ __ 07/02/2006 11:30 13:15 1.75 349 0 PROD3 FISH PULD NP Breakout, inspect & lay down BHA. Lay down Dummy seals. Make up 4 3/4" Seals (3.27'), Tubing Joint IBT (41.86'), Crossover to XT39 (.67'), Crossover to 3 1/2 IF (.67), Bumper Jar (7.87'), Oil Jar (11.14'), Crossover to XT39 (278.26'). Total BHA = 349.03. Clean & clear rig floor area. Pull Casin runnin a ui ment to ri floor. 13:15 13:30 0.25 0 0 PROD3 CASIN( SFTY P PJSM with Crew, BOT Rep, and. Casing hands. Discuss Safety Issues and procedure for making up and runnin 4 1/2" Slotted liner assembl . 13:30 18:00 4.50 0 5,095 PROD3 CASIN( PUTB P Make up Baker Guide Shoe (1.48'), with joint of 3 1/2" 9.2 # L80 IBT bent Joint (28.05'), Crossover (1.45'). Continue pick up 4 1/2" Slotted liner as per detail with alternating slots / blanks as recommended. Run in hole to 5095' MD. UP WT = 107K, SO WT = 105K. Obtain T & D parameters as er Ri en ineer. Crew Chan e 18:00 21:30 3.50 5,095 7,115 PROD3 CASIN( PUTB P Continue RIH from 5095' - 7115' with 4 1/2" Slotted liner assembly. Observe no issues with bent joint going into open hole. First attempt!. Continue record T & D parameters as per rig en ineer. 21:30 21:45 0.25 7,115 7,115 PROD3 CASIN( SFTY P Held PJSM with entire crew & BOT rep. Discuss safety issuesand procedure for making up Hook Hanger assembly with MWD orientation. Identify Hazards. Reciprocate casing string while hold PJSM. Set string in sli s. 21:45 23:00 1.25 7,115 7,150 PROD3 CASIN< PUTB P MAke up Hook Hanger asembly with MWD tools. Orient MWD to mark on Hook Hanger 180 Degrees from Hook. UP WT = 125K, SO WT = 100K. 23:00 23:30 0.50 7,150 7,302 PROD3 CASIN( RUNL P Trip in hole with 4 1/2 liner assembly on dril pipe from 7150' - 7302'. Perform Shallow pulse test on MWD assembly 120 GPM's. Good test. 23:30 00:00 0.50 7,302 8,044 PROD3 CASIN< RUNL P Blow down Top Drive & lines. Continue trip in hole with 4 1/2 liner assembly on drill pipe from 7302' - 8044' MD Observe ro er hole fill. 07/03/2006 00:00 03:15 3.25 8,044 12,156 PROD3 CASIN( RUNL P Continue trip in hole with 4 1/2 liner assembly on drill pipe from 8044' - 12156' MD Observe proper hole fill & good open hole conditions. Obtain T & D arameters as er ri en ineer. ~~ ~~~qe S~ of ~7 Time Lis Date From To Dur S ~e th E. De th Phase Code Subcode T CAM 07/03/2006 03:15 05:00 1.75 12,156 12,186 PROD3 CASIN ( RUNL P Make Top Drive connection. UP WT = 210K, SO WT = 110K. Pumps @ 130 GPM's as per MWD rep for Slimhole tools, with 1260 PSI. Work string down to observe engage window with 10K set down weight on the first attempt. Allow MWD to pump survey indicating Hook Hanger at 63 Degrees right of high side. NOTE: Original orientation for whipstock @ 10 Degrees left of high side. Pull up to above window, rotate liner string 180 Degrees and work string up /down to allow rotation. Slack off to 10' past the bottom of the window @ 5094' MD. Observed pipe movement difficult as we were stacking out, and seeing 40 -50K overpull when picking up. Pull up again above window, and rotate 180 degrees again allowing rotation to get to Hook Hanger, and set down on bottom of window as before with 20K set down. MWD surveys indicated Hook Hanger @ 66 Degrees right of high side - 4 good surveys. Decision to set Hook Hanger now as a result of difficulty in up and down movement in string. All indications good that we have a proper Hook, and on depth @ 5094' MD as planned. Break DP connection at floor and drop 29/32" ball. Make connection. Allow ball to fall, pumping at 3 BPM - 920 PSI for 300 Strokes. Slow pumps to 2 BPM - 420 PSI observing ball seated and pressure to 1000 PSI. Pressure up to 4250 PSI with rig pump observing ball shear & pressure drop. Bleed all pressures and pick up to verify setting tool free of Hook hanger. New UP WT = 175K. Top of Hook Han er 5078' MD. 05:00 06:00 1.00 5,078 4,110 PROD3 CASIN( RUNL P POOH from 5078' to 4110. Observe ro er hole fill. Crew Chan e. 06:00 09:15 325 4,110 0 PROD3 CASINC RUNL P Continue POOH from 4110' -surface. Breakout, inspect & lay down liner settin tools. All ood. 09:15 10:00 0.75 0 0 PROD3 CASIN( OTHR P Rig up Tongs and make service breaks on Slimhole MWD assembly. Lay down same. 10:00 11:00 1.00 0 PROD3 CASIN( SFTY P Clear & clean rig floor area. Pull tools to rig floor for next run. Held PJSM with crew. Discuss safety issues and procedure for making up LEM assembl . - -- ~'~z~e ~,~ ~s~f z~7 Time Logs -- ---~ _~ _ .:.:.Code.... Subcode T COM_ - - - - _ _ _ - _-- - Date From To Dur 5 e th E. De th PhasP ~ 07/03/2006 11:00 12:00 1.00 0 152 PROD3 CASIN( PUTB P Make up LEM assembly as per BOT rep. Make up Baker Seal Assembly with STL box (3.25'), 1 Joint of 4 1/2" L80 IBT (43.22'), 2 - jnts 4 1/2" TBG (31.09') (31.06'), LEM assembly 34.68' ,with 4 1/2" TBG u 3.83' . 12:00 13:00 1.00 204 204 PROD3 CASIN( PUTB P Continue MU LEM Assembly picking up Crossover Bushing 5 1/2" Hydril x IBT (1.3T), 190-47 Casing Seal Bore Receptacle (19.66'), ZXP liner top PKR (19.05'), with setting tool (5.43'), and running tool (6.317'). Crossover to DP 5.33' .Total Assembl = 204.14'. 13:00 16:15 3.25 204 5;212 PROD3 CASIN( RUNL P Run 4 1/2" LEM assembly from 204' - 5212'. Observe ro er hole fill. 16:15 17:00 0.75 5,212 5,212 PROD3 CASIN( RUNL P RIH slowly as per BOT rep, observing seals going through Hook Hanger assembly attempting to enter lateral. Pick up, rotate 180 degrees, and slack off to allow seals to enter seal bore and observe latch up on LEM. UP WT = 170K, SO WT = 150K. 17:00 18:00 1.00 5,212 5,212 PROD3 CASIN( OTHR P Break DP connection, drop 1 3/4" ball, allowing to fall & pump ball down at 3 BPM - 750 PSI. Slow pumps to 2 BPM - 450 PSI. Observe ball seat and pressure up to 1000 PSI. Continue pressure up to 4000 PSI to set & release ZXP PKR. Bleed pressure. Close Annular. Line up and pump down annulus to pressure to 2500 PSI, holding pressure for 10 minutes. Good test. Record on chart. Bleed pressurese Pick up observing setting tool released and free from assembly. Top of ZXP now at 5024.79' MD. Crew. Chan e 18:00 23:30 5.50 5,212 0 PROD3 CASINC RNCS P POOH from 5025'- surface. Observe proper hole fill on TOH. Use VAC system to vac Super Sliders for re aration to la down same. 23:30 00:00 0.50 0 0 PROD3 CASIN( OTHR P Breakout, inspect and lay down running and setting tools. All tools looked ood. 07/04/2006 00:00 01:15 1.25 0 0 COMPZ RPCOh OTHR P Clear & clean Floor area. PuII tools to rig floor. Rig up to pull W.B. BOLDS ull and la down W.B. 01:15 01:30 0.25 0 0 COMPZ RPCOti SFTY P Held PJSM with crew, casing hands & BOT reps: Discuss safety Issues and procedure for running 4 1/2 IBT com letion. 01:30 06:00 4.50 0 4,700 COMPZ RPCOh RCST P Make up Baker 4 3/4" Seal Assembly & Locator sub. Continue RIH with 4 1/2" L80 IBT Completion string from surface to 4700'. 06:00 08:30 2.50 4,700 5,058 COMPZ RPCOti RCST P Continue RIH wl 4-112" 12.6 ppf L-80 IBT com letion f/ 4700' to 5058' a~e~'4of~? Time Loys D~te___ _ From To _ Dur epth E. Depth Phase .Code Subcode T CAM. __ __ ~ 07/04/2006 08:30 09:15 0.75 5,058 5,058 COMPZ RPCOti HOSO P Space out. L/D 3 joints, install 3.89' pup below joint # 159, MU Vetco hanger and landing joint. Land tubing. PU wt 112k, SO wt 105k. Installed BPV in han er before RIH. 09:15 10:15 1.00 0 0 COMPZ RPCOh OTHR P Run in lock down screws. Test upper and lower seals on Vetco/Gray hanger to 5000 si f! 10 min. each. OK. 10:15 11:00 0.75 0 0 COMPZ RPCOh RURD P Rig down casing tools. 11:00 11:45 0.75 0 0 COMPZ DRILL RURD P Rig up to laydown Weatherford 4" drill pipe from derrick, using mouse hole. Total of 127 stands of Weatherford 4" drill pipe (90 stands slick + 37 stands w/western well tools super sliders. 2 super sliders per joint f/ total of 222 super sliders. Also 20 stands of Hybrids ((2) 5" DC's w/one joint of 4" HWDP on top, all XT39 connectrions. Note: Little Red freeze protect OA w/ 90 bbls diesel, did not flush w/ water. Test lines to 2500 psi. Initial breakover @ 2850 psi. Injection rate of 1.5 bpm w/ 1750 psi. Ending pressure without um in was 775 si. 11:45 12:00 0.25 0 0 COMPZ DRILL SFTY P Pre job safety meeting on laying down 4" d in mousehole. 12:00 18:00 6.00 0 0 COMPZ DRILL PULD P Lay down 20 stands of hybrids ((2) 5" DC's w/ a joint of 4" HWDP on top)f/ driller's side of derrick. Lay down 19 stands slick 4" dp from off driller's side of derrick. 18:00 18:15 0.25 0 0 COMPZ DRILL SFTY P Pre job safety meeting on laying down 4" drill i e from derrick. 18:15 00:00 5.75 0 0 COMPZ DRILL PULD P Lay down Weatherford 4" drill pipe f/ derrick. Layed down 61 stands of slick 4" DP f/ off driller's side of derrick. Note: Left to be layed down is 37 stands of Weatherford 4" dp w/ Western Well Tools super sliders (2 per joint for total of 222 super sliders), and 10 more stands of slick 4" dp all on the driller's side of derrick. 07/05/2006 00:00 03:30 3.50 0 0 COMPZ DRILL PULD P Lay down Weatherford 4" drill pipe f/ derrick. Layed down 26 stands of 4" DP f/ driller's side of derrick (all 26 stands w/ Western Well Tools super sliders, removed 156 super sliders). Note: Left to be layed down is 11 stands of Weatherford 4" dp w/ Western Well Tools super sliders (2 per joint for total of 66 super sliders), and 10 more stands of slick 4" dp all on the driller's side of derrick. Note: Cleanin its i'~ye 3~ of 87 ~TimeLogs_ - - - -- --- _ _ Date Frorn To _ Dur ~. Lepth E Depth Phase Code Subcode- T CC~M -_ -_- -____-- 07/05/2006 03:30 04:15 0.75 0 0 COMPZ DRILL OTHR P Pull mousehole from rotary table and make up top drive to single. Set slips and clean and clear rig floor to get ready to cut and slip drilling line. Note: Cleanin its 04:15 05:15 1.00 0 0 COMPZ RIGMN SVRG P Slip and cut drilling line. Note: Cleanin its. 05:15 06:00 0.75 0 0 COMPZ DRILL PULD P Lay down Weatherford 4" drill pipe f/ derrick. Layed down 6 stands of 4" DP f/ driller's side of derrick (all 6 stands w/ Western Well Tools super sliders, removed 36 super sliders). Note: Left to be layed down is 5 stands of Weatherford 4" dp w/ Western Well Tools super sliders (2 per joint for total of 30 super sliders)., and 10 more stands of slick 4" dp all on the driller's side of derrick. Note: Cleanin its. 06:00 09:00 3.00 0 0 COMPZ DRILL PULD P Lay down Weatherford 4" drill pipe f/ derrick. Layed down 5 stands of 4" DP f/ driller's side of derrick (all 5 stands w/ Western Well Tools super sliders, removed 30 super sliders). and 10 more stands of slick 4" dp all on the driller's side of derrick. Note: Cleanin its. 09:00 09:15 0.25 0 0 COMPZ DRILL PULD P UD mousehole. RU to change saver sub on top drive f/ XT-39 to 4-1/2" IF. Note: Cleanin its. 09:15 09:30 0.25 0 0 COMPZ DRILL SFTY P Pre job safety meeting on changing out saver sub on top drive. Note: Cleanin its. 09:30 12:00 2.50 0 0 COMPZ RIGMN SVRG P Change out saver sub f/ 4" XT-39 to 4-1/2" IF. Note: Cleanin its. 12:00 12:45 0.75 0 0 COMPZ DRILL OTHR P Flush out kill line, choke line and hole fill lines to stack while laying down 4" equipment from rig floor. Note: Cleanin its. 12:45 13:00 0.25 0 0 COMPZ DRILL OTHR P Clean out drip pans. Cleaning pits. 13:00 13:15 0.25 0 0 COMPZ WELCT SFTY P Pre job safety meeting on nippling down BOPE. Note: Cleanin its. 13:15 18:00 4.75 0 0 COMPZ WELCT NUND P Nipple down 13-5/8" BOPE. 18:00 19:30. 1.50 0 0 COMPZ WELCT NUND P NU Vetco Gray tree. 19:30 21:00 1.50 0 0 COMPZ WELCT OTHR P Pull BPV. Install Two way check. RU to test and freeze protect well with little Red. s_ ~~ ~ E'~c JP ~~.} ~1 J~ Time Logs _ - _ _ _ - - - --- _Date From ;o Dur epth E. De th - Phase - Code Subcode T COM 07/05/2006 21:00 00:00 3.00 0 0 COMPZ WELCT OTHR T Pressure test little Red lines to 5000 psi. Test tree a 250 psi low and 5000 psi high. Test not good. Rig down and rearrange to eliminate possible leaking valves. Re- test, no good. Rig down chart recorder, double check prssure sensor, recorder and hose. Install new Two wa check valve. Retest, no ood. 07/06/2006 00:00 02:00 2.00 0 0 COMPZ WELCT OTHR T Pull Two way check valve, redress. Install Two way check valve. Attempt to test tree to 250 psi low and 5000 psi hi h. No hi h test. 02:00 04:00 2.00 0 0 COMPZ WELCT OTHR T Checking valves and connections on tree. Still no high pressure test. Talk w/ Town engineer and Vetco rep in town. Decision to keep attempting to test without Little Red connected to system (Use Vetco test pump, using ua eon tree ca flan e . 04:00 05:15 1.25 0 0 COMPZ WELCT OTHR P Testing tree. Finally held 5000 psi f/ 10 min without bleedin off. 05:15 05:45 0.50 0 0 COMPZ RPCOh FRZP P Rig up to freeze protect 4-1/2" tubing and 4-1/2" x7-5/8" annulus. Little Red ressure test lines to 3000 si. 05:45 06:00 0.25 0 0 COMPZ RPCOh FRZP P Little Red atarted pumping @ 1 bpm. Shut down after pumping 11.7 bbls (7" Otis Tree cap "O" ring leaking). Replace tree cap "O" ring. Note: Oil base Mud Returns to pits was 100 bbls while dis lacin diesel. 06:00 06:30 0.50 0 0 COMPZ RPCOh FRZP P Little Red start pumping again , 1bpm w/ 250 psi. Increase rate to 3 bpm w/ 1100 psi. Final rate 3 bpm w! 1300 psi. Little red pumped 100 bbls diesel down 4-1 /2" x 7-518" annulus, taking returns throu h o en slidin sleeve 4983'. 06:30 08:30 -2.00 0 0 COMPZ RPCOh FRZP P Swap valves and "U" tube diesel f/ annulus to tubing. Cleaning Oil base returns f/ its. 08:30 09:00 0.50 0 0 COMPZ RPCOti FRZP P Blow down lines, Rig down lines. Final ressure 275 si on both tb and ann. 09:00 10:00 1.00 0 0 COMPZ WELCT OTHR P Rig up lubricator and set BPV. 10:00 12:00 2.00 0 0 COMPZ WELCT OTHR P Remove lubricator. Install needle valves and guages while using vac truck to clean out cellar. Rig released f/ 1J-127 f/ move to 1J-109 (in line well-well move _ - -- ~~~~ ~7 c~ ~? ~ ~- ~ ~ ~ , ~ - v ~ r ALASSA OIL A1QD GAS Randy ThomO1~SERQA7`IO1~T COMI~IISSIOI~T Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 R FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-127L2 ConocoPhillips Alaska, Inc. Permit No: 206-049 Surface Location: 1739' FSL, 2324' FEL, SEC. 35, Tl 1 N, R 1 OE, UM Bottomhole Location: 287' FSL, 585' FEL, SEC. 23, T11N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill. the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other 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. The permit is for a new wellbore segment of existing well KRU 1J-127, Permit No. 206-047, API No. 50-029-23306-00. Production should continue to be reported as a function of the original API number stated above. 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~~. iy required test, contact the Commission's petroleum field inspector at (907 '65 -3607 (pager). N DATED this~day of April, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~ 20 AAC 25.005 1a. Type of Work: Drill ^/ ~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service Q 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: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-127L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12301' ~~ ND: 3661' ~ 12. Field/Pool(s): Kuparuk River Field - 4a. Location of Well (Governmental Section): Surface: 1739' FSL, 2324' FEL, Sec. 35, T11N, R10E, UM ' 7. Property Designation: ADL 25661 & 25650 ~ West Sak Oil Pool ' Top of Productive Horizon( 1528' FNL, 572' FE\L;'Sec. 35, T11 N, R10E, UM ° 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 4/27/2006 Total Depth: 287' FSL, 585' FEL, Sec. 23, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: <3 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558887 y- 5945552 ' Zone- 4 10. KB Elevation (Height above GL): 40' RKB feet 15. Distance to Nearest Well within Pool: 1 D-a0A , 1042' @ 6000 16. Deviated wells: Kickoff depth: 5202 ~ tt. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1647 psig ~ Surface: 1245 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size ons pec ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (inGuding stage data) 42" 20"x34" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2183' 40' 40' 2223' 2193' 440 sx AS Lite, 120 sx DeepCRETE 9-7/8" 7.625" 29.7# L-80 BTCM 6432' 40' 40' 6472' 3732' 380 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 7099' 5202' 3497' 12301' 3661' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (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 ~~, '"+N4 Perforation Depth MD (tt): Perforation Depth TVD (ft): ~~ i u~;si:+~t'~:~ 20. Attachments: Filing Fee _ BOP Sketch ^ Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~~? ~,~ ~ ;`~`~~~_~~ Phone "L.L-~S ~ ? SU Date 3%~t/c~ h n All Commission Use Only Permit to Drill Q Number: ~~~~~ ~ / API Number: p 2A // 50- d Z / ' ~ ~ 3V~~ W ~ Permit Approval Date: , See cover letter for other requirements Conditions of approval : If box is checked, well may of be used to explore for, test, or produce Coalbed methane, g yd tes, or gas contained in shales: ~~~ ~~ ~~ ~-S'A`GS ~~,~,~~ , Samples req'd: Yes ^ ud log req'd: Yes ^ No [~ Other: H2 easures: Yes No Tonal svy req'd: Yes [•~ No ^ APPROVED BY THE COMMISSION DATE: ~~/~ ~ 0 ,COMMISSIONER Form 10-401 Revised 12/2005 ~ 9 a~ ~ f ~ ~ Sub ~t in Duplicate ~~-~o~~~ rat ~~~~~~~~~ C App~n for Permit to Drill, Well 1J-127 L2 Revision No.0 Saved: 31-Mar-06 Permit It -.West Sak Well #1J-127 L2 •~°~ r.^ +~A Application for Permit to Drill Document;, II~1t~~+~ll Mdxirriiz~ Vlell Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fJ .................................................................................~--~--................ 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 ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 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-127L2 PERMIT IT Page 1 of 6 Printed: 31-Mar-06 ~~ ~ ~~~ • App~n for Permit to Drill, Well 1J-127 L2 Revision No.O Saved: 31-Mar-06 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 (i) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2tJ AAC25.040(b). Ear a watt with multiple we/! branches, each branch must similar/y be identified by a unique name and AP1 number by adding a suffix to the Warne designated for the we// by the operator and to the number assigned to the we// by the commission, The well for which this Application is submitted will be designated as iJ-127 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on fle with the commission and identified in the application.• (Z) a plat identifying the property and the property`s owners and showing (A)the caordinates of the proposed /ocatian of the we{I at the surface, at the top of each objective formation, and at tota/depth, referenced to governmental section fines (8) the coordinates of the proposed /ovation 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 wail at the top of each objective formation and at total depth; Location at Surface 1739' FSL & 2324' FEL -Sec 35 - T11N - R10E ° ASP Zone 4 NAD 27 Coordinates RKB Elevation 121' AMSL Northings: 5,945,552 Eastings: 558,887 Pad Elevation 81' AMSL Location at Top of Productive Interval West Sak "D" Sand 1528ft FNL & 572ft FEL -Sec 35 - T11N - R10E ASP zone 4 NAD 27 coordinates Measured De th, RKB: 5, 202 Northings: 5,947,579 Eastings: 560,622 Total l/ertica/De th, RKB: 3,497 Total ~ertica/ De th SS.• 3,388 Location at Total De th 287ft FSL & 585ft FEL -Sec 23 - T11N - R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 12, 301 Northings; 5,954,672 Eastings: 560,546 Total I/ertica/De th, RKB: 3,661 Total l/ertica/ De th, SS.• 3,552 and (D) other information required by 20 AAC 25.05D(b); 0 i 1J-127L2 PERMIT IT Page 2 of 6 _ ~ Printed: 31-Mar-06 • App~n for Permit to Drill, Well 1J-127 L2 Revision No.O Saved: 31-Mar-06 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permr"t to DriJ/ (Form iD-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed welfbore, including all adjacent we/Ibores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for at/ wells within 200 feet of the proposed wetlbore (A) list the names of the operators of those we/Is, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only off acted owner: The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An appir""cation for a Permit to flri// must be accompanied by each of the fotloc~ing items, except for an item a/ready on fi/e with the commission and identified in the application; (3) a diagram and description of the blowout prevention equipment (Bl1PE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as app/icab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-54 L2. 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 app/ication 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 0.45 psi/ft, or 8.7 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 1,245 psi, calculated thusly: MPSP =(3,661 ft TVD)(0.45 - 0.11 psi/ft) =1,245 psi ~ (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo pressured strata,. lost c/reulatr`on zones, and zones that have a propensity for differential sticking; Please see Attachment 2: iJ-127 L2 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item. a/ready on file with the commission and identified in the app/ication.• (5) a description of the procedure far conducting formation integrity tests, as required under 20 AAC 25.030(fJ; The parent wellbore, iJ-127, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in .accordance with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-127L2 PERMIT IT Page 3 of 6 Printed: 31-Mar-O6 ~~ EGINAL • Appl~ for Permit to Drill, Well 1 J-127 L2 Revision No.O Saved: 31-Mar-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/lcation for a Fermfi to IJri/! must be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the application: (6) a camplete proposed casing and cementing program as required by 30 AAC ZS. 030, and a description of any slotted liner, pre- perforated /mer, or screen. to be installed; Casin and Cementin Pro ram Hole Top etm Csg/Tbg -Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 5,617 6,472 / 3,732 12,089 / 3,869 Slotted- no cement Slotted Lateral (1J-127) 4-1/2 6-3/4" B Sand l L t 12.6 L-80 IBTM 6,562 5,522/ 3,571 12,084 / 3,712 Slotted- no cement fled era - a -' 6-3/4" D Sand 12.6 L-80 IBTM 7,099 5,202/ 3,497 12,301 / 3,661 Slotted- no cement slotted Lateral (1]-127 L2) -...~ 7. QiLV&gstem Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fo/%wing 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 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on 1J-127 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/cation for a Permit to Drill must be accompanied by each of the fo!/owing items, except for an item a/ready on frle with the commissr"on and identified in the application.• (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 2tl AAC 2S. 033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit ppg) 8.6 Plastic Viscosity 15 - 25 (Ib/100 s Yield Point 18 - 28 cP HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water 70 / 30 Ratio Electrical 650-900 Stability ~` 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. 1J-127L2 PERMIT IT Page 4 of 6 Printed: 31-Mar-O6 ~~~L App~n for Permit to Drill, Well 1J-127 L2 Revision No.0 Saved: 31-Mar-06 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication far sperm/t to Dr//l must be accompan/ed by each of the following /tents, except for an item already an fi/e with the commissian and identified in the application; (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths ofpred/cted abnormally geo pressured strata as requr"red by 20 AAC Z5. tJ33(t); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application far a Permit to ©ri1/ must be accompanied by each of the follow/ng items, except for an ifem a/ready on fi/e with the commissian and identified in the application: (I4) far an exploratory or stratigraphic test we/% a seismic refraction or reflection ana/ysis as required by ZO AACZS. D61(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 appl/cat/an for a Permit to ®rill must be accompanied by each of the fo/lowing items, except for an item already an file with the commission and identified in the application: (i1) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating dri//r"ng vessel, an ana/ysis afseabed conditions as required by ZQ AAC25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/icatr"on for sperm/t to Dr/// must be accompanied by each of the fo/%wing items, except far an /tem a/ready on fi/e with the commission and identified in the application; (ZZ) evidence showing that the requirements of2DAAC25.0z5 {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 app/ication for a Permit to Dri/l must be accompanied by each of the fo/lowing items, except for an item already on fr/e 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 i]-127 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of ~' MD / 3 ' TVD, the top of the D sand. 5~2' IK~/3c~9'~ ~ ~/~ ~/ 2. Mill 6-3/4"window. POOH. ~/~i;burlr!•,~•~jitnn~..~ ~z~~--,-~' ~'. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. ~j ~ ~, p(, 4. Drill to TD of D sand lateral at 12,301' MD / 3,661' 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. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. ORIGINAL 1J-127L2 PERMIT IT Page 5 of 6 Printed: 31-Mar-06 CJ Appl~ for Permit to Drill, Well 1J-127 L2 Revision No.O Saved: 31-Mar-06 10. 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. 11. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. 17. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 18. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri/l mustc be accompanied by each of the fallowing items, except for an item already on frle with the commission and identiFed in the app/ication,• (14) a genera/ description of how the operator p/ans to dispose of dri/ling 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 we/%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids r 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 iJ 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-127L2 PERMIT IT Page 6 of 6 Printed: 31-Mar-O6 ~~~ • • ConocoPhillips ~as~ ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-127 -Slot 1J-127 Plan 1J-127 L2 Plan: 1J-127 L2 (wp03) Proposal Report 31 January, 2006 lALLI~~R"~'C Sperry Qriltng Services ~~ ~ N O ~, O o ~ ~ v> NOO' Nr R K ll fnrrPR C ma u°~UmQ O u' 7 7 7 Q ~ ~ --- _____________ ___ d o ~ o p 0 ~ ~ J ~ y ~ N O+ C C C40~ O fCMrM CI O)G]r Y »>Y~ m ~ N i ~~ ~ m ~ a- - fV ~ u. l- f- / r ~ N M~ ~p N r ~ L O r 1n r 00 ~p I~ T N N ~ / / 1 O r N J Z r~ h a ~ S O N V: O M f~ O r M J /~ a 3 00 ~ W d n'~ V'aNNO TO)I~ LL / o ` m Q 0 ~,_, ~tL>~D OfNtOMMtAr rr rNM~~~N ~ / M ~ N Q O r M N O In r 1~ ~ Z ~ / O a ~ Z O M N r N ~ N N M Q N 1 n N U 0 ~ Q (n r N 00 N O t~ Oa 1~ N N O~ M~ N r~ 10 q Q~ M 0 0 g O O 1~ q M r b N O N 01 M O M ~ N t i N O / // / 3 ~ N N o ~ r ~ ~ r OON 000 N n ~ / °88 J ~ r NMMM N O ~ / / N Q O O O N ONON ~ u- ~. p i d 3 V a0 '/ // O ,o OMt~r ~~~~ N M LOO gOO1T0f~O ~ONMNN et cDO n M ~ « ~ N J N / ~ / / / / ^ o n M O iNO ~e -T ~-~~MO Q~~O C1 OfNNM~ ~ N N M M M M ~ ~p M n ~ t~l a C / ~2 / O / ° 6 8 ~ a 3 ` 0 Z r N M a ~ rn / ~, ~~ H 0 o Z r N M ~ lf) CO I~ q O) ~ J ~ / ` ` ~ 3 ~ ~ O 0 ~ r ~ ( ~~ `-' ~ ~ ~ ~..~ N M ~ ~ r ~ M ~ ~ c 3 °68 n ~ N ~ O '~ fD Q N N J ~ r O D N ~ rj o 3 o c0 ~ ~ ~ ~D n "' ~ ~ tq p 068 ~ N J O _ Q C \ \ (y ^ N ~ C N C N N ~ \\ N O \\ ~ ~ ~ ~ ~ O O QN yahN Q ~ O r h O ~ \\ \ ~ n N c . ~ N r 'r 3 ~ a M O ~ C N O _ ~ ~ ~ ~\ U \ °o CdN ~ O v a N N \\ O ~ C ~ 3 3 a r YY_`r 7 0 ~ ~ i 7 v m ~ u m C a '~ \ \ ~ ~ v ~F J O U O ~ .C C V .`~+ ~ (/~ ~ d ~ O ~° ~ a U N p N U \ \ ` ~ ~ O _ a N ~ ~ U a ~ o O \ °ss ~ J o > N M ~ O O \ \ \ N o O fD ~ \ \ O Q' ~ O .~ _ ~ \\ \ 06 M a O O °' Z tp m 0 \ H IA ~ ~ N J \ \ \ N \ ~ O M ~ \ \ N J O N ~ V - N ~ N ________ --------- --- \ M a ~ -- ----- ----- ------ - °Q8 3 n Q _ - ---- - _ - - - - ~ J O O N ~n m N _ _ - - - - - - __ - - _---' ~ ~ 2 J _ ___ LL __ ---~ p ~ N - ~ O O ~ o^i v °`99 ~ Q ~ M ° °Oy °o ~n ~ \ N °~Q O O N \ ~ ~~ o O N J O O O O O O V1 O r r O O O O O ~ ~ ~ O O O r O O N r O O O N O O ~ N O O O M O O N M O O O O O O O iff O d' ~ \f1 O O if1 ~ N ' 1J-1 11 -Toe (wp03 Project: Kuparuk River Unit a vr~ Site: Kuparuk 1J Pad L2 : TD 'a`a 12302ft MD, 3661ft ND : 287ft FSL 8 585ft FEL -Sec 23 - T11N - R1¢E ; Well: Plan 1J-127 _________________ Wellbore: PIan1J-127L2 ------- 1J-127 L2 (wp03) @ 12302'MD - - - - - - - - - Plan: 1J-127 L2 (wp03) _ _ _ _ 1J-127 L2 T10 (wp03 1J-127 L1(wp03)@12084'MD ------ _ __--- ----_____ _ - - - ~ 1J-127 L2 T9 (wp03 1J-127 (wp03) @ 12090'MD 1J-127 L2 TS (wp03 71 61 CASING DETAILS No ND MD Name Size 1 120.00 120.00 16 16 2 2193.20 2223.51 10 3/4" 10-3/4 3 3497.00 5202.13 7 5/8" TOW7-5/8 4 3661.2212301.75 41/2" 4-1/2 c_ 0 rn t 0 Z r 0 to DD Polygon defines a 100' wide corrido along the entire lateral length - allowabl deviation from plan is +/-50' _ _ 1J-127 L2 T7 (wp03 --------- 1J-127 L2 T6(wp03 -_------_-- 1J-127 L2 TS(wp03 ____-_______ 1J-127 L2 T4(wp03 -_--________ 1J-127 L2 T3 (wp03 --_------ 1J-127 L2 T2 (wp03 LZ :Continue Geosteer in D-Sand : 5524ft MD, 3526ft L2 : Continue Build ~ 3°I100ft , 6442ft MD, 3527ft N L2: Build~6.00°NOOftto92.2°Ilnc-5244ftMD,3506ftN _____________ _____ L2 : BOW @ 5214ft MD, 3500ft N , ' 3G L2 : TOW @ 5202ft MD, 3497ft ND - 1528ft FNL S 572ft FEL -Sec 35 - T11N - R1 E ~ kzp~uths to True North agnetic North: 24.22° Magnetic Field Strength: 57563.1 nT Dip Angle: 80.77° Date. 1 /512006 Model: BGGM2005 -2375 -1900 -1425 -950 -475 -------------- 1J-127 L2 T1(wp03 -------- 10 3/4" Casing @ 2224ft MD, 2193ft ND 475 950 1425 1900 2375 2850 fir' ConocoPhillips t~aska 3325 3800 4275 ~-'' ~ Halliburton Energy Services ~ HAI.L~E3tl'~TC'~N ConacoP~~~~~ps Planning Report -Geographic Database: Alaska EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-127 Wellbore: Plan 1J-127 LZ Design: 1J-127 L2 (wp03) Sperry Grilling Services Local Co-ordinate Reference: Well Plan 1J-127 -Slot 1J-127 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-127 - Siot 1J-127 Well Position +N/-S 0.00 ft Northing: 5,945,552.30 ft ' Latitude: 70° 15' 42.637" N +E/-W 0.00 ft Easting: 558,887.50ft ~` Longitude: 149° 31' 26.251" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore Plan 1 J-127 L2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength 1°) (°) UT) BGGM2005 1/5/2006 24.22 80.77 57,563 Design 1J-127 L2 (wp03) Audit Notes: Version: Phase: PLAN Tie On Depth: 5,202.12 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) lftl (ft) l°) 28.00 0.00 0.00 0.00 1/31/2006 4:30:36PM Page 2 of 8 COMPASS 2003.11 Build 48 ~ ~ / " Halliburton Energy Servic es H,/~L.LtBU1'~""~CN COt1tKt) ~ t1II lS Planning Report -Geographic ~ Spar*I- Drilling 5~rvices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-127 -Slot 1J-127 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: ~ Planned RKB @ 109.OOft (Doyon 141 (81+28)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Site: Kuparuk 1J Pad North Reference: True Weil: Plan 1J-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-127 L2 Design: 1J-127 L2 (wp03) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO lft) (°) (') (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) t°) 5,202.12 76.00 359.82 3,497.00 2,013.26 1,750.46 0.00 0.00 0.00 0.00 5,214.12 77.91 359.82 3,499.71 2,024.95 1,750.43 15.90 15.90 0.00 0.00 5,244.12 77.91 359.82 3,505.99 2,054.29 1,750.34 0.00 0.00 0.00 0.00 5,441.82 89.77 359.82 3,527.17 2,250.49 1,749.72 6.00 6.00 0.00 0.00 5,523.97 92.23 359.81 3,525.73 2,332.63 1,749.46 3.00 3.00 -0.01 -0.15 5,772.83 92.23 359.81 3,516.03 2,581.29 1,748.65 0.00 0.00 0.00 0.00 5,854.98 89.77 359.82 3,514.60 2,663.42 1,748.38 3.00 -3.00 0.01 179.85 6,204.98 89.77 359.82 3,516.00 3,013.42 1,747.29 0.00 0.00 0.00 0.00 6,230.02 89.27 359.85 3,516.21 3,038.46 1,747.21 2.00 -2.00 0.10 177.10 7,155.20 89.27 359.85 3,528.00 3,963.56 1,744.71 0.00 0.00 0.00 0.00 7,161.94 89.14 359.88 3,528.09 3,970.29 1,744.70 2.00 -1.95 0.45 166.99 7,355.25 89.14 359.88 3,531.00 4,163.59 1,744.28 0.00 0.00 0.00 0.00 7,373.17 88.78 359.84 3,531.33 4,181.51 1,744.23 2.00 -1.99 -0.20 -174.35 8,204.57 88.78 359.84 3,549.00 5,012.71 1,741.92 0.00 0.00 0.00 0.00 8,222.72 89.14 359.82 3,549.33 5,030.86 1,741.86 2.00 2.00 -0.13 -3.59 9,204.84 89.14 359.82 3,564.00 6,012.87 1,738.74 0.00 0.00 0.00 0.00 9,220.88 89.46 359.84 3,564.19 6,028.90 1,738.69 2.00 1.99 0.15 4.30 10,055.01 89.46 359.84 3,572.00 6,862.99 1,736.39 0.00 0.00 0.00 0.00 10,087.91 88.81 359.75 3,572.50 6,895.89 1,736.27 2.00 -1.98 -0.26 -172.42 10,305.10 88.81 359.75 3,577.00 7,113.03 1,735.34 0.00 0.00 0.00 0.00 10,321.66 88.49 359.82 3,577.39 7,129.58 1,735.28 2.00 -1.96 0.42 168.02 11,405.65 88.49 359.82 3,606.00 8,213.20 1,731.94 0.00 0.00 0.00 0.00 11,504.16 85.54 359.97 3,611.13 8,311.56 1,731.77 3.00 -3.00 0.15 177.15 11,698.10 85.54 359.97 3,626.23 8,504.91 1,731.67 0.00 0.00 0.00 0.00 11,856.60 90.29 359.88 3,632.00 8,663.26 1,731.46 3.00 3.00 -0.06 -1.10 11,986.32 85.75 359.77 3,636.48 8,792.86 1,731.07 3.50 -3.50 -0.08 -178.63 12,185.83 85.75 359.77 3,651.26 8,991.83 1,730.27 0.00 0.00 0.00 0.00 12,207.38 85.00 359.84 3,653.00 9,013.31 1,730.20 3.50 -3.48 0.32 174.77 12,301.76 '° 85.00 359.84 3,661.23 ~ 9,107.33 1,729.94 0.00 0.00 0.00 0.00 ?/31/2006 4:30:36PM Page 3 of 8 ~.-~° ~ ~ i s "`~~ ~~ t COMPASS 2003.11 Build 48 ' ` ~ ~ ~- Halliburton Energy Service s Ll~tuc~'Tp HAl COt'1+OCE3~I11IIIp5 Planning Report -Geographic . - Alaslca Sperry IDc1111ng Ssrvless Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-127 -Slot 1J-127 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-127 Survey Calculation Method: Minimum Curvature Weilbore: Plan 1J-127 L2 Design: 1J-127 L2 (wp03) Planned Survey 1 J-127 L2 (wp03) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°l (°) (ft) (ft) (ft) lftl lft) (ft) (°/100ft- (ft) 5,202.12 76.00 359.82 3,497.00 3,388.00 2,013.26 1,750.46 5,947,579.00 560,622.00 0.00 2,013.26 L2 : TOW @ 5202ft MD, 3497ft TVD -1528ft FN L 8 572ft FEL -Sec 35 - T 11 N - R10E - 7 518" TOW ~- 5,214.12 77.91 359.82 3,499.71 3,390.71 2,024.95 1,750.43 5,947,590.68 560,621.87 15.90 2,024.95 L2 : BOW @ 5214ft MD, 3500ft TVD 5,244.12 77.91 359.82 3,505.99 3,396.99 2,054.29 1,750.34 5,947,620.01 560,621.55 0.00 2,054.29 L2 : Build @ 6.00°/100ft to 92.2° lint - 5244ft M D, 3506ft TVD 5,300.00 81.26 359.82 3,516.09 3,407.09 2,109.24 1,750.16 5,947,674.96 560,620.95 6.00 2,109.24 5,400.00 87.26 359.82 3,526.09 3,417.09 2,208.69 1,749.85 5,947,774.39 560,619.86 6.00 2,208.69 5,441.82 89.77 359.82 3,527.17 3,418.17 2,250.49 1,749.72 5,947,816.19 560,619.40 6.00 2,250.49 L2 : Continue Build @ 3°/100ft , 5442ft MD, 3527ft TVD 5,500.00 91.51 359.82 3,526.52 3,417.52 2,308.67 1,749.53 5,947,874.36 560,618.76 3.00 2,308.67 5,523.97 92.23 359.81 3,525.73 3,416.73 2,332.63 1,749.46 5,947,898.31 560,618.49 3.00 2,332.63 L2 : Continue Geosteer in D-Sand : 5524ft MD, 3526ft TVD 5,600.00 92.23 359.81 3,522.77 3,413.77 2,408.60 1,749.21 5,947,974.27 560,617.65 0.00 2,408.60 5,700.00 92.23 359.81 3,518.87 3,409.87 2,508.52 1,748.88 5,948,074.18 560,616.55 0.00 2,508.52 5,772.83 92.23 359.81 3,516.03 3,407.03 2,581.29 1,748.65 5,948,146.94 560,615.74 0.00 2,581.29 5,800.00 91.42 359.82 3,515.17 3,406.17 2,608.45 1,748.56 5,948,174.09 560,615.44 3.00 2,608.45 5,854.98 89.77 359.82 3,514.60 3,405.60 2,663.42 1,748.38 5,948,229.06 560,614.84 3.00 2,663.42 5,900.00 89.77 359.82 3,514.78 3,405.78 2,708.44 1,748.24 5,948,274.07 560,614.34 0.00 2,708.44 6,000.00 89.77 359.82 3,515.18 3,406.18 2,808.44 1,747.93 5,948,374.05 560,613.25 0.00 2,808.44 6,100.00 89.77 359.82 3,515.58 3,406.58 2,908.44 1,747.61 5,948,474.04 560,612.15 0.00 2,908.44 6,200.00 89.77 359.82 3,515.98 3,406.98 3,008.44 1,747.30 5,948,574.02 560,611.05 0.00 3,008.44 6,204.98 89.77 359.82 3,516.00 3,407.00 3,013.42 1,747.29 5,948,579.00 560,611.00 0.00 3,013.42 1J-127 L2 T1 (wp03) 6,230.02 89.27 359.85 3,516.21 3,407.21 3,038.46 1,747.21 5,948,604.04 560,610.73 2.00 3,038.46 6,300.00 89.27 359.85 3,517.10 3,408.10 3,108.43 1,747.02 5,948,674.00 560,610.00 0.00 3,108.43 6,400.00 89.27 359.85 3,518.38 3,409.38 3,208.42 1,746.75 5,948,773.98 560,608.94 0.00 3,208.42 6,500.00 89.27 359.85 3,519.65 3,410.65 3,308.42 1,746.48 5,948,873.95 560,607.89 0.00 3,308.42 6,600.00 89.27 359.85 3,520.92 3,411.92 3,408.41 1,746.21 5,948,973.93 560,606.84 0.00 3,408.41 6,700.00 89.27 359.85 3,522.20 3,413.20 3,508.40 1,745.94 5,949,073.91 560,605.79 0.00 3,508.40 6,800.00 89.27 359.85 3,523.47 3,414.47 3,608.39 1,745.67 5,949,173.88 560,604.74 0.00 3,608.39 6,900.00 89.27 359.85 3,524.75 3,415.75 3,708.38 1,745.40 5,949,273.86 560,603.68 0.00 3,708.38 7,000.00 89.27 359.85 3,526.02 3,417.02 3,808.37 1,745.13 5,949,373.84 560,602.63 0.00 3,808.37 7,100.00 89.27 359.85 3,527.30 3,418.30 3,908.36 1,744.86 5,949,473.81 560,601.58 0.00 3,908.36 7,155.20 89.27 359.85 3,528.00 3,419.00 3,963.56 1,744.71 5,949,529.00 560,601.00 0.00 3,963.56 1J-127 L2 T2 (wp03) 7,161.94 89.14 359.88 3,528.09 3,419.09 3,970.29 1,744.70 5,949,535.74 560,600.93 2.00 3,970.29 7,200.00 89.14 359.88 3,528.67 3,419.67 4,008.35 1,744.62 5,949,573.79 560,600.55 0.00 4,008.35 7,300.00 89.14 359.88 3,530.17 3,421.17 4,108.34 1,744.40 5,949,673.76 560,599.55 0.00 4,108.34 7,355.25 89.14 359.88 3,531.00 3,422.00 4,163.59 1,744.28 5,949,729.00 560,599.00 0.00 4,163.59 1J-127 L2 T3 (wp03) 7,373.17 88.78 359.84 3,531.33 3,422.33 4,181.51 1,744.23 5,949,746.92 560,598.82 2.00 4,181.51 7,400.00 88.78 359.84 3,531.90 3,422.90 4,208.33 1,744.16 5,949,773.73 560,598.53 0.00 4,208.33 7,500.00 88.78 359.84 3,534.02 3,425.02 4,308.30 1,743.88 5,949,873.70 560,597.47 0.00 4,308.30 7,600.00 88.78 359.84 3,536.15 3,427.15 4,408.28 1,743.60 5,949,973.66 560,596.41 0.00 4,408.28 7,700.00 88.78 359.84 3,538.27 3,429.27 4,508.26 1,743.32 5,950,073.62 560,595.35 0.00 4,508.26 1/31/2006 4:30.36PM Page 4 of 8 COMPASS 2003.11 Build 48 '+~-' ~ ~ Halliburton Energy Services ~ t1At.L.IBLJp'tplV' ~011000~1i~~1~5 Planning Report -Geographic - Aiaska ~°rrI- milling S~RVicss Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-127 -Slot 1J-127 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Project: Kuparuk RiverUnit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-1.27 L2 Design: 1J=127 L2 (wp03) Planned Survey 1J-127 L2 (wp03) Map Map MD Inclination Azimuth TVD SSTVD +N!-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) lft) (ft) (ft) (°/100ft) (ft) 7,800.00 88.78 359.84 3,540.40 3,431.40 4,608.24 1,743.05 5,950,173.58 560,594.29 0.00 4,608.24 7,900.00 88.78 359.84 3,542.53 3,433.53 4,708.21 1,742.77 5,950,273.54 560,593.23 0.00 4,708.21 8,000.00 88.78 359.84 3,544.65 3,435.65 4,808.19 1,742.49 5,950,373.51 560,592.17 0.00 4,808.19 8,100.00 88.78 359.84 3,546.78 3,437.78 4,908.17 1,742.21 5,950,473.47 560,591.11 0.00 4,908.17 8,200.00 88.78 359.84 3,548.90 3,439.90 5,008.14 1,741.93 5,950,573.43 560,590.05 0.00 5,008.14 8,204.57 88.78 359.84 3,549.00 3,440.00 5,012.71 1,741.92 5,950,578.00 560,590.00 0.00 5,012.71 1J-127 L2 T4 (wp03) 8,222.72 89.14 359.82 3,549.33 3,440.33 5,030.86 1,741.86 5,950,596.14 560,589.80 2.00 5,030.86 8,300.00 89.14 359.82 3,550.48 3,441.48 5,108.13 1,741.62 5,950,673.40 560,588.95 0.00 5,108.13 8,400.00 89.14 359.82 3,551.98 3,442.98 5,208.12 1,741.30 5,950,773.38 560,587.85 0.00 5,208.12 8,500.00 89.14 359.82 3,553.47 3,444.47 5,308.11 1,740.98 5,950,873.35 560,586.75 0.00 5,308.11 8,600.00 89.14 359.82 3,554.96 3,445.96 5,408.10 1,740.66 5,950,973.32 560,585.65 0.00 5,408.10 8,700.00 89.14 359.82 3,556.46 3,447.46 5,508.08 1,740.35 5,951,073.29 560,584.55 0.00 5,508.08 8,800.00 89.14 359.82 3,557.95 3,448.95 5,608.07 1,740.03 5,951,173.27 560,583.45 0.00 5,608.07 8,900.00 89.14 359.82 3,559.45 3,450.45 5,708.06 1,739.71 5,951,273.24 560,582.35 0.00 5,708.06 9,000.00 89.14 359.82 3,560.94 3,451.94 5,808.05 1,739.39 5,951,373.21 560,581.25 0.00 5,808.05 9,100.00 89.14 359.82 3,562.43 3,453.43 5,908.04 1,739.07 5,951,473.19 560,580.15 0.00 5,908.04 9,200.00 89.14 359.82 3,563.93 3,454.93 6,008.03 1,738.75 5,951,573.16 560,579.05 0.00 6,008.03 9,204.84 89.14 359.82 3,564.00 3,455.00 6,012.87 1,738.74 5,951,578.00 560,579.00 0.00 6,012.87 1J-127 L2 T5 (wp03) 9,220.88 89.46 359.84 3,564.19 3,455.19 6,028.90 1,738.69 5,951,594.03 560,578.83 2.00 6,028.90 9,300.00 89.46 359.84 3,564.94 3,455.94 6,108.02 1,738.47 5,951,673.14 560,577.99 0.00 6,108.02 9,400.00 89.46 359.84 3,565.87 3,456.87 6,208.01 1,738.20 5,951,773.12 560,576.93 0.00 6,208.01 9,500.00 89.46 359.84 3,566.81 3,457.81 6,308.01 1,737.92 5,951,873.10 560,575.87 0.00 6,308.01 9,600.00 89.46 359.84 3,567.74 3,458.74 6,408.01 1,737.64 5,951,973.08 560,574.81 0.00 6,408.01 9,700.00 89.46 359.84 3,568.68 3,459.68 6,508.00 1,737.37 5,952,073.06 560,573.76 0.00 6,508.00 9,800.00 89.46 359.84 3,569.61 3,460.61 6,608.00 1,737.09 5,952,173.04 560,572.70 0.00 6,608.00 9,900.00 89.46 359.84 3,570.55 3,461.55 6,707.99 1,736.81 5,952,273.02 560,571.64 0.00 6,707.99 10,000.00 89.46 359.84 3,571.49 3,462.49 6,807.99 1,736.54 5,952,373.00 560,570.58 0.00 6,807.99 10,055.01 89.46 359.84 3,572.00 3,463.00 6,862.99 1,736.39 5,952,428.00 560,570.00 0.00 6,862.99 1J-127 L2 T6 (wp03) 10,087.91 88.81 359.75 3,572.50 3,463.50 6,895.89 1,736.27 5,952,460.90 560,569.63 2.00 6,895.89 10,100.00 88.81 359.75 3,572.75 3,463.75 6,907.98 1,736.22 5,952,472.98 560,569.48 0.00 6,907.98 10,200.00 88.81 359.75 3,574.82 3,465.82 7,007.95 1,735.79 5,952,572.94 560,568.27 0.00 7,007.95 10,300.00 88.81 359.75 3,576.89 3,467.89 7,107.93 1,735.36 5,952,672.90 560,567.06 0.00 7,107.93 10,305.10 88.81 359.75 3,577.00 3,468.00 7,113.03 1,735.34 5,952,678.00 560,567.00 0.00 7,113.03 1J-127 L2 T7 (wp03) 10,321.66 88.49 359.82 3,577.39 3,468.39 7,129.58 1,735.28 5,952,694.55 560,566.81 2.00 7,129.58 10,400.00 88.49 359.82 3,579.46 3,470.46 7,207.90 1,735.04 5,952,772.85 560,565.96 0.00 7,207.90 10,500.00 88.49 359.82 3,582.10 3,473.10 7,307.86 1,734.73 5,952,872.80 560,564.87 0.00 7,307.86 10,600.00 88.49 359.82 3,584.74 3,475.74 7,407.83 1,734.42 5,952,972.75 560,563.78 0.00 7,407.83 10,700.00 88.49 359.82 3,587.38 3,478.38 7,507.79 1,734.12 5,953,072.70 560,562.69 0.00 7,507.79 10,800.00 88.49 359.82 3,590.02 3,481.02 7,607.76 1,733.81 5,953,172.65 560,561.60 0.00 7,607.76 10,900.00 88.49 359.82 3,592.65 3,483.65 7,707.72 1,733.50 5,953,272.60 560,560.51 0.00 7,707.72 11,000.00 88.49 359.82 3,595.29 3,486.29 7,807.69 1,733.19 5,953,372.55 560,559.42 0.00 7,807.69 11,100.00 88.49 359.82 3,597.93 3,488.93 7,907.65 1,732.88 5,953,472.50 560,558.33 0.00 7,907.65 11,200.00 88.49 359.82 3,600.57 3,491.57 8,007.62 1,732.58 5,953,572.45 560,557.24 0.00 8,007.62 11,300.00 88.49 359.82 3,603.21 3,494.21 8,107.58 1,732.27 5,953,672.40 560,556.15 0.00 8,107.58 1/31/2006 4:30:36PM Page 5 of 8 COMPASS 2003.11 Build 48 ti ~ ~ ~'' ~ ~ Halliburton Energy Services ~ ~p~L~igv~ ~-~~y CQCIQGOPFIl~IlpS Planning Report -Geographic Alaska Stpeny Driliirtg Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-127 -Slot 1J-127 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-127 L2 Design: 1J-127 L2 (wp03) Planned Survey 1J-127 L2 (wp03) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ftl (ft) (ft) lft- lft) (ft) (°/100ft) (ft) 11,400.00 88.49 359.82 3,605.85 3,496.85 8,207.55 1,731.96 5,953,772.35 560,555.06 0.00 8,207.55 11,405.65 88.49 359.82 3,606.00 3,497.00 8,213.20 1,731.94 5,953,778.00 560,555.00' 0.00 8,213.20 1J-127 L2 T8 (wp03) 11,500.00 85.66 359.96 3,610.82 3,501.82 8,307.41 1,731.77 5,953,872.20 560,554.09 3.00 8,307.41 11,504.16 85.54 359.97 3,611.13 3,502.13 8,311.56 1,731.77 5,953,876.35 560,554.05 3.00 8,311.56 11,600.00 85.54 359.97 3,618.59 3,509.59 8,407.11 1,731.72 5,953,971.88 560,553.26 0.00 8,407.11 11,698.10 85.54 359.97 3,626.23 3,517.23 8,504.91 1,731.67 5,954,069.68 560,552.44 0.00 8,504.91 11,700.00 85.59 359.97 3,626.38 3,517.38 8,506.80 1,731.67 5,954,071.57 560,552.43 2.93 8,506.80 11,800.00 88.59 359.91 3,631.45 3,522.45 8,606.66 1,731.57 5,954,171.41 560,551.55 3.00 8,606.66 11,856.60 90.29 359.88 3,632.00 3,523.00 8,663.26 1,731.46 5,954,228.00 560,551.00 3.00 8,663.26 1J-127 L2 T9 (wp03) 11,900.00 88.77 359.84 3,632.36 3,523.36 8,706.66 1,731.36 5,954,271.39 560,550.56 3.50 8,706.66 11,986.32 85.75 359.77 3,636.48 3,527.48 8,792.86 1,731.07 5,954,357.59 560,549.59 3.50 8,792.86 12,000.00 85.75 359.77 3,637.49 3,528.49 8,806.51 1,731.01 5,954,371.23 560,549.43 0.00 8,806.51 12,100.00 85.75 359.77 3,644.90 3,535.90 8,906.23 1,730.62 5,954,470.94 560,548.25 0.00 8,906.23 12,185.83 85.75 359.77 3,651.26 3,542.26 8,991.83 1,730.27 5,954,556.52 560,547.24 0.00 8,991.83 12,200.00 85.26 359.82 3,652.37 3,543.37 9,005.95 1,730.22 5,954,570.64 560,547.08 3.50 9,005.95 12,207.38 85.00 359.84 3,653.00 3,544.00 9,013.31 1,730.20 5,954,578.00 560,547.00 3.50 9,013.31 1J-127 L2 T10 (wp03) 12,300.00 85.00 359.84 3,661.07 3,552.07 9,105.57 1,729.94 5,954,670.25 560,546.02 0.00 9,105.57 12,301.76 85.00 359.84 3,661.23 3,552.23 9,107.33 1,729.94 5,954,672.00 560,546.00 0.00 9,107.33 L2 : TD @ 12302ft MD, 3661ft TVD : 287ft FSL & 585ft FEL - Sec 23 - T11N - R10E - 4 1/2" - 1J-127 L2 T11 -Toe (wp03) ° 1/31/2006 4:30.36PM Page 6 of 8 COMPASS 2003.11 Build 48 F.... ~' ~ Halliburton Energy Services ~ t-tALtIBURTt3tIVi COnaCOP'htllps Planning Report -Geographic Spen'Y Qriiling Servtess Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-127 -Slot 1J-127 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-127 L2 Design: 1J-127 L2 (wp03) Geologic Targets Plan 1J-127 L2 TVD Target Name +NI-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,564.00 1J-127 L2 T5 (wp03) 6,012.87 1,738.74 5,951,578.00 560,579.00 - Point 3,516.00 1J-127 L2 T1 (wp03) 3,013.42 1,747.29 5,948,579.00 560,611.00 - Point 3,577.00 1J-127 L2 T7 (wp03) 7,113.03 1,735.34 5,952,678.00 560,567.00 - Point 3,528.00 1J-127 L2 T2 (wp03) 3,963.56 1,744.71 5,949,529.00 560,601.00 - Point 3,572.00 1J-127 L2 T6 (wp03) 6,862.99 1,736.39 5,952,428.00 560,570.00 - Point 3,549.00 1J-127 L2 T4 (wp03) 5,012.71 1,741.92 5,950,578.00 560,590.00 - Point 3,531.00 1J-127 L2 T3 (wp03- 4,163.59 1,744.28 5,949,729.00 560,599.00 - Point 3,606.00 1J-127 L2 T8 (wp03) 8,213.20 1,731.94 5,953,778.00 560,555.00 - Point 3,632.00 1J-127 L2 T9 (wp03) 8,663.26 1,731.46 5,954,228.00 560,551.00 - Point 3,653.00 1J-127 L2 T10 (wp03) 9,013.31 1,730.20 5,954,578.00 560,547.00 - Point 3,661.23 1J-127 L2 T71 -Toe (wp03) 9,107.33 1,729.94 5,954,672.00 560,546.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) l") (~') 120.00 120.00 16 20 2, 223.51 2,193.20 10-3/4 13-1 /2 5,202.13 3,497.00 7-5/8 9-7/8 12,301.75 3,661.22 4-112 6-314 1/31/2006 4:30:36PM Page 7 of 8 COMPASS 2003.11 Build 48 ;,-~ ~. ~ 1 _~ t ` ' S i ~ H llib t E ! ~' ' erv ces ur on nergy a ~,~~,L~~~~~ry COflOC4P~ t~EI[p5 Planning Report -Geographic ~~ AIBSkB Sperry Drilling Servicos Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-127 -Slot 1J-127 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-127 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-127 L2 Design: 1J-127 L2 (wp03) Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E!-W (ft) (°) (°) (ft) Iftl Ift) Name 1,510.00 0.00 0.00 1,510.00 0.00 0.00 Base Permafrost 1,643.21 2.16 52.28 1,643.20 0.50 0.64 T3 1,942.45 17.12 52.28 1,937.38 31.07 40.18 K15 2,223.51 31.18 52.28 2,193.20 101.24 130.91 T3 + 550 3,612.38 65.93 52.28 2,929.29 802.60 1,037.85 Ugnu C 4,300.75 66.96 37.74 3,208.17 1,213.07 1,512.29 Ugnu B 4,392.07 67.55 33.33 3,243.49 1,281.58 1,561.22 Ugnu A 4,593.19 69.25 23.77 3,317.67 1,445.63 1,650.38 K15 5,177.32 76.00 359.82 3,491.00 1,989.20 1,750.54 WSAK D 1/31/2006 4:30:36PM Page 8 of 8 COMPASS 2003.11 Build 48 i F, 5 u f »,. • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-127 Plan 1J-127 L2 Anticollision Summary 31 January, 2006 s~@ ~1"'t~~ll't~ i7@I"VEC@S ,~ ~~~,~ t - ~ ova _;„ n EavVm Y n O S~ u E_cf--Y ~N a rnN .o Env°o 3 o F u n ~y Ctf L ~ C ~ ~ (' ~ O O_ W ~ O C O AW c ~ ~ ~+ U U O 'o .^, N^ ~ ~ Pp) N N ~3 z'ti a c H o_ J r d O M S 9 ~ M 4ze 3° J 9 ~ ~ ~ O O .- ~ p M ~~~ 010 C h O n 2 ;S 3g +e ~d `o ,,~„ N m _ N N ; Z z rv ~ J C ~ n ~ N 0 G~d~ N ~ N 'W A J C N C 1 v End F ~`~~ _~Eu r C q O 1' ~ et ~g 0 m 0 N m O N ,_ 3 $$$s.ggs.$. $ x e~~ ~~y n~ ~ ~ ~~ry ~~ry~ r~ry~ w~q J J J J J J J J J J J rn b ~ u N n ~ n YN NegV dbNdd V NNNNraN0~p10mibObt~`~N TtV qC~e~ N ~ ~ >~e. u~~in'mew.°h°nr°`eowow.°~1um~mn~g~e.~~o «n.°~~HNNr°n °n nnaa~°n $.°e°m°m °mnnommooo 8.m Y S S S S ~ S g O~ S Cqi O n O N 0 r01 O O O O O ~ S ~ b S n O ~oooooo'o'o'c~a'o.~icaeeio'c'o~~%'o'o y O S S S S S S 0 0 0 S S S S S O 0 0 S O S S O 0 0 S S N S ~a`emwle eic eie wio a`ic rio noeV orvo'+e~nene a W P ~ ~ O° ~'! 1 V C n m ~ n N A n N N l~ l~ O d 0 33^<x~3eMyy~~~~a .era z ul~'^ °~~998~SS33^^M~ nn nrnnnnnnnnnnnn O F ~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ V W ~NONi eNV dbNd d V N N NmmnrMi n' 3rieac.~i~rieim Sao M..i~~i: n rvnnnnaa n°pnulommrncmmmoomm co~a~~~oo"SoSMSr^,S~S~S°;S~RS3rSr ~no^i uqi n l~eieau~>rr a ie: oia . a $nwnro'rnnu~i °je ~.ginnnMn~. r7. ~. e~nn.vi~nnnronron.iOanroM~nn d^ T p m b m o m o n A b ro eni a g A A adp q n ~r1HH~'f nnnMnlnnnMrtn r'1 w1M ref nnnnne~ coo°mA'mnnrnnnr~~°n ~~~aamoavu°~°n rnn°e°e N 1 V T N 01 m N T O W T 01 T W O 0 o m b N N N IAA{:mmmmmmmoromogmmmammommSiomam p.V a°mN~1^e~meD ~NU"l~~~Nm.e.en~r~mmao n'~iOnon~ N~1v~du~lonNa~~~~ea--~~ ~~e~-rvNHHrnnnnn N O ~ N c c G 7 _~ U O°i 0 0 0 0 0 0 0 0 0 0 0 0 °o °o °o ~ O~ O N N r 0 0 0 0 0 0 0 0 0 0 N N In I~ ~ ~ ~ ~ N M~ ~n to f~ a0 m ~ ~ ~ O ° ~ °0 1°n °o ton o° 1°n °o o °o °o °o °o °o °o °o °o °o N in !~ O N ~n ` N o°') V ~ tO0 rO 00 QOi O O N ° ~h ~~ u~ yaa > oL oC ~+~++~+ )' V O O E FU~~ 7 L ~ .-. ~ ~ i C ~ d `~ ~ '~ _ C i ~ m 1-4rd. e g~«~ 4i~~ 7 v~ D N r± + z°~ ~~ ~ o 0 r o 0 ~p~p ~~5~ p o 0 0 N ' Z ' ~ O ' m ~ m ~ F mv~s ~ ~ v ~ D: a c.~ c E O - rt O A C _Z 3awaf W N L u N 9 U u c C ~ O Z L W N L ~ ~ f W KLLO'KK p w _ LL' WpN ~yy 3 ~ , p u m°a g ~ .. ~. V 9p y N ~ v, U ~41'~CO~'1{~~lp5 Alaska Halliburton Energy Services Anticollision Report Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site; Kuparuk 1J Pad Site Error: O.OOft Reference Well; Plan 1J-127 Well Error: O.OOft Reference Wellbore Plan 1J-127 L2 Reference Design: 1J-127 L2 (wp03) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HAI.~.IBU~TQN Spslrry Drilling ~rvicas Well Plan 1J-127 -Slot 1J-127 Planned RKB @ 109.OOft (Doyon 141 (81+28)) Planned RKB @ 109.OOft (Doyon 141 (81+28)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-127 L2 (wp03) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referen Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 5,202.12 to 12,301.76ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,427.38ft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 1/31/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-127 (wp03) (Plan iJ-127) CB-GYRO-SS Camera based gyro single shot 800.00 5,202.12 1J-127 (wp03) (Plan 1J-127) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,202.12 12,301.76 1J-127 L2 (wp03) (Plan 1J-127 L2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 9/31/2006 4.36:OOPM Page 2 of 3 COMPASS 2003.11 Build 48 ~r~~„~ ~41'~000~'tl~~l~35 Alaska Halliburton Energy Services Anticollision Report Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-127 Well Error: O.OOft Reference Wellbore Plan 1J-127 L2 Reference Design: 1J-127 L2 (wp03) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • HAk1.6.tBUFtTDN Spsrry Driiliing S~nrtcfs Well Plan 1J-127 -Slot 1J-127 Planned RKB @ 109.OOft (Doyon 141 (81+28)) Planned RKB @ 109.OOft (Doyon 141 (81+28)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1 D Pad 1 D-38 - 1 D-38 - 1 D-38 Out of range 1 D-40 - 1 D-40 - 1 D-40 12,163.78 7,050.00 673.77 140.93 532.84 Pass -Major Risk 1 D-40 - 1 D-40A - 1 D-40A 12,164.19 7,050.00 675.98 140.74 535.25 Pass -Major Risk 1 D-42 - 1 D-42 - 1 D-42 Out of range i D-42 - 1 D-42L1 - 1 D-42L1 Out of range 1 D-42 - 1 D-42L1 P61 - i D-42L1 PBi Out of range Kuparuk 1J>Pad 1 J-03 - 1 J-03 - 1 J-03 5,218.31 5,350.00 1,389.43 108.44 1,280.99 Pass -Major Risk 1J-101 - 1J-101 - 1J-101 10,556.37 9,700.00 1,191.74 237.67 954.07 Pass -Major Risk 1J-101 - 1J-101 L1 - 1J-101 L1 12,168.21 11,300.00 1,249.81 285.60 964.21 Pass -Major Risk 1J-101 - 1J-101 L1 P61 - 1J-101 L1 PB1 11,165.32 10,300.00 1,248.63 261.64 986.99 Pass -Major Risk 1J-101 - 1J-101 L2 - 1J-101 L2 12,169.04 11,300.00 1,235.65 286.82 948.83 Pass -Major Risk 1J-164 - 1J-164 - 1J-164 Out of range 1 J-164 - 1J-164 L1 -1 J-164 L1 Out of range 1 J-164 - 1 J-164 L2 - 1 J-164 L2 Out of range 1J-164 - 1J-164 L2 PBi - 1J-164 L2 PB1 Out of range 1J-168 - 1J-168 - 1J-168 Out of range 1J-168 - 1J-168 L1 - 1J-168 L1 Out of range 1 J-168 - 1 J-168 L2 - i J-168 L2 Out of range iJ-168 - 1J-168 L2 P61 - 1J-168 L2 P61 Out of range Plan 1 J-112 Kuparuk Prelim -1 J-12 E Lateral - 1J-1 Out of range Plan 1J-112 Kuparuk Prelim - 1J-12 Pilot - 1J-12 Pil Out of range Plan 1J-112 Kuparuk Prelim -Plan 1J-12 W Lateral Out of range Plan 1J-115 -Plan 1J-115 - 1J-115 (wp01) 12,205.26 13,000.00 1,276.19 309.23 966.95 Pass -Major Risk Plan 1J-118 -Plan 1J-118 -Plan 1J-118 (wp01) Out of range Plan 1J-120 -Plan 1J-120 - 1J-120 (wp01) Out of range Plan 1 J-122 -Plan 1 J-122 - 1 J-122 (wp02) Out of range Plan 1 J-123 Kuparuk Prelim -1 J-23 E Lat - 1 J-23 E Out of range Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat - 1J-23 \ Out of range Plan 1J-124 -Plan 1J-124 - 1J-124 (wp01) BHI Out of range Plan 1 J-127 -Plan 1 J-127 -1 J-127 (wp03) 5,249.97 5,250.00 1.41 6.64 -5.22 FAIL -Mina Risk Plan 1J-127 -Plan 1J-127 L1 -1J-127 L1 (wp03} 12,082.20 12,084.47 69.26 116.09 -46.83 FAIL -Minor Risk Plan 1 J-166 - 1 J-166 - 1 J-166 Out of range Plan 1 J-166 -1 J-166 L1 - 1 J-166 L1 Out of range Plan 1J-166 - 1J-166 L1 PB1 - 1J-166 L1 PB1 Out of range Plan 1 J-166 - 1 J-166 L2 - 1 J-166 L2 Out of range Plan 1J-170 -Plan 1J-170 -1J-170 (wp02) Out of range Plan 1J-170 -Plan 1J-170 L1 - 1J-170 L1 (wp02) Out of range Plan 1J-170 -Plan 1J-170 L2 - 1J-170 L2 (wp02) Out of range WSP-1S -WSP-1S -WSP-1S Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/31!2006 4:36:OOPM Page 3 of 3 COMPASS 2003.11 Build 48 ~'°~~~ 1~-127L2'~rillinq H (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4".Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low f . Stripping drills, shut-in drills, increased Pressure mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip ~ sheets , um in out,. backreamin 1J-127L2 Drilling Hazards Summary '~ ~ ~ ~ ~ ~ 3/31/2006 1:17 PM 20" 94# x 34" Insulated Conductor, set at +/- 80' 103/4" x 4-1/2" Wellhead, 5000 psi Tubing, Special Drift to +/_ 500' MD 3.875" DB Nipple, for Possible SSSV GLM, Camco KBG-2, 4-1/2" X 1" GLM, Camco KBG-2, 4.1/2" X 1" 10-3/4" 68#, Casing ~ CMU Sliding Sleeve, w/ 3.81" DB Nipple Shoe, set ~ 2231' MD, 2207' TVD Tubing String Casing Sealbore Receptacle, 20' Length ~--~- -_~ 4-112" 12.6#, L-80, IBTM ~ ~--- - ----- -"---- 3.958" ID, 3.833" Drift lateral Entry Module(LEM) D-sand Window 'D' Sand Lateral ' ~ 5-112" X 7-518" ZXP Liner - /at 520 D 97 Top Packer wl Hold Assembly f/ /2 11'6# L-80 Slotted 3 112„ Bent Joint 4 er Swive4 Downs 75" Seal OD ~ ~,.._ Liner Every Other Joint / ~_ I r ~ - f•~.. , ---~- --_ {/ - ~.a 4-112" X 7-518" / S Model'B' HOOK Hanger .1 5-112" X 7-518 Packer wl -~ °~° La teral Entry Module (LEM) _ a '~ , Assembly C ,,, _- ~j ~ ~, .-~ 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Profile .~ Automatic Alignment of LEM Positive Latching Collet ~~ Indicates Correcf Location Seal Bore for Lateral Isolation - 3.68" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID j 3-112" Guide Shoe r. ~ ~~.~ 4-1/2" Liner Shoe, 11.6#,~.80 BTC Set ~ 12301' MD, 1' TVD Seal Assembly ~~~~ 4.75" Seal OD Casing Sealbore Receptacle 20' Length 4-112" X 7-518" Model 'B' HO OK Hanger Seal Bores_ 3.68" ID 4-112" 12.6# Tul 3.833" Drift 3.958" ID ConocoPhillips West Sak 7-5/8" Injector 1J-127 Tri-Lateral Completion As Planned rGii~ EfAKER KYGKES Baker Oil Tools Late ral Entry Module (LEM) With Diverters and Isolation Lateral Access Diverter Lateral Isolaaon Diverter GS Running Tool String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbor e DrifO 'GS' Profile for Coil Connector f Running/Retrieving O (1.00' Length) i Snap INSnap Out .~POSitive LOCadng~ r Back Pressure Valve Collet (1.60' Length) i i I Lateral Isdatlon ~- ~ Flow-Thru Swivel i Seals I (1.25' Length) f Lateral Diverter i I ' / Hydraulic Ramp i i ,i - Disconnect I d tl l M i b e (1.50' Length) s a on a n or Diverter Sleeve i ~_ GS Spear ' ~ ~~ Lateral Isolatbn (1.50 Length) ~ Seals I 6.85 h Approx. OAL' ~ B-sand Window lord at 5522' MD, 3571' rvD 'B' Sand Lateral 4-112" 11.6# L-80 Slotted Liner Swivel Liner Every Other Joint / 3-112" Bent Joint 3.562" DB Nipple 5-112" X 7518" ZXP Liner Top Packer with Hold Downs i 5-112" X 7-518" Liner Hangerl Packer Assembly at Flex Lock +I- 5400' MD Liner Hanger Casing Sealbore Receptacle, 20' Length © Baker Hughes 2005. This document may not be reprotluced or distributed, In whole or In part, In any form or by any means electronic or mechanical, Including photocopying, recording, or by any In}ormatlon storage and retrieval system now known or hereaner Invented, without written pennlsslon hom Baker Hughes Inc. may be required in highly deviated 18.5' Diverter Length 18.5' Sleeve Length cep applications (6' approz IengNl. 3-112" Guide Shoe 4-112" Liner Shoe, 11.6#, L-80 BTC Set ~ 12084' MD, 3712' TVD Seal Assembly 4.75" Seal OD 'A' Sand Undulating Lateral 4-112" 11.6# L-80 Slotted Liner Every Other Joint 4-112" Eccentric / ,Guide Shoe 7-5/8" Casing Shoe, Set at 6472' MD, 3732' TVD (84 deg) Eauipment Specifications 4-1 /2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Divener OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +l- 18.5' 4-112" Casing Shoe, 11.6#, L-80 BTC Set ~ 12085' MD, 3854' TVD • • • • TRANSMITTAL LETTER CHECKLIST WELL NAME k~u- / -? = /2-7L Z PTD# ~ ~ ~ d 'r / Development / Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /~i~GC, l ~-~ Z.7 (If last two digits in permit No. Zq~-0~7, API No. 50,~~-~-~. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-127L2 Program SER __ Well bore seg ,'] PTD#:2060490 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER! PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ --- Administration 1 Permitfee attached_ , .. _ NA_ West Sak D Sand multilateral well branch; fee waived per 20 AAC 25.005(e), 2 Lease number appropriate---..---_____________ Yes_ _. 3 Uni-que well_name and number - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - --- - 4 Well located in.a.defined-pool. - - _ - Yes KUPARUK RIVER,_WEST $AK OIL - 490150 governed by CO 4066_ _ - _ _ _ - 5 Well located proper distance from drilling unitboundary- - - - - - - - - - - - - - - - Yes CO 406B specife-s no restrictions as to well spacing except that no pay shall_be opened in_a well_ 6 Well located proper distance from other wells- _ _ Yes closer than 500 feet to anexternal-property line where ownership-or landownership changes. _ _ _ - , _ - . - _ _ 7 Suffcientacreageayailableind_ril_lingunit______________________ __________Yes---_ _________--__-_________ 8 If deviated,is_wellboreplat_included______------------------ ----------Yes---- ---_________.__,____ 9 Operator only affected party_____________________________ __________Yes--__ - ________---_____ - - - 10 Operator has approprtate_bondinforce__________________...- __--__-__-Yes____ -..- ------------------------------------------------------------------- 11 Permit_canbeissuedwithoutconservationorder__________________ __________Yes____ _____----____________-.-,--_-- ----------------------------------------- Appr Date 12 Permit-can be issued wjthout administrative_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - - _ - . - _ _ _ _ . - _ - - _ _ _ - -- - SFD 4/412006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_ Injection Order # (put 10# in_ comments)_(For_ Yes Area Injection Order No., 2B - ------------- 15 All wells_within 114_mile area of review identified (For service wel_I only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ - _ _ - KRl11J-101 and laterals, KR111 D-134 and laterals, and KRU_ 1 D-40A, - _ _ _ _ _ _ _ _ _ - - - - _ _ - - _ 16 Pre-produced injector: duration_of pre production less than 3 months-(For service well only) Yes - - . _ _ - 45_-day flow-back clean up _ _ _ _ _ _ _ _ _ _ _ _ _ _ ----------------------------- ACMP_Finding of Consistency-has been issued_forthis project_ NA_ -- _ - - _ - - -- Engineering 18 Conductor string_provided - - - - - - - _ _ - NA_ - --- - Conductor installed_in 1J-127.(206-047)_. -- 19 Surfacecasingprotectsallknown_U$DWs_____________________ _________ NA_____ _--All aquifers exempted, 40CFR_147.102~b)(3).__-.-_-______________ ------------------- 20 CMT_vol_ adequate_to circulate_o_n conductor & surf.csg _ - - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ - - - NA- . _ _ _ Surface casing set in_ 1_J-127._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 CMT-voladequate_totie-i_nlong stringto_surfcsg_________________ __________ NA----- ,-_Inte_rmediate-easing set in_1J-127._____-_..-_.______________ 22 CMT_willcover_allknown.productiyehorizons___________________ _____ ____No_____ __-$lottedlinercompletionplanned..-__________.---.--,-___.________.__-_--_- ---- 23 .Casing designs adequate for C,_T, B & permafrost_ _ NA_ - - _ - - _ - Motherbore tubulars met design specs._ NA for slotted lines- 24 Adequate tankage_or reserve pit . _ - - _ _ , _ Yes Rig isequipped with steel-pits.. No rese_rve_pitplanned, All waste to approved annulus or disposal wells. 25 If a_re-drill, has_a_ 1.0-403 for abandonment been approved N_A_ 26 Adequate wellbore separation_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - _ - ...Proximity analysis performed, Traveling cylinder path calculated, Nearest well is b lateral, ~60'_deeper._ _ _ - , - 27 If_diverter required, does it meet regulations- - _ _ _ - _ _ , _ - _ - . - _ - - NA_ BOP stackwill already-be in place, , ------------------------------------ Appr Date 28 Drilling flujd_ program schematic & equip list adequate_ _ _ - - _ Yes - - - - Maximum expected formation pressure 8,7, EMW._ Planned MW $:6-ppg or_as needed._ _ - . . TEM 4/10/2006 29 BOPEs,dotheymeet_regu_lotion__________-__-----_-___-- __-__ -_-,Yes____ ____________________ ~ ~ 30 BOPE_press rating appropriate; test to-(put prig in comments)_ - - .. _ - - _ - - _ Yes - - . . - _ MASP calculated at 1245 psi. 3K stack arrangement and test pressureplanned, ~ ~ 31 Choke-manifold complies w/API_RP-53(M_ay$4)__________________ __________Yes_--_ _ , -- - 32 Work willoccurwithoutoperationshutdown-------------- ------ ----------Yes_-__ _______--___________ ---------- 33 Is presenceof H2S gas_ probable _ _ - - _ - - . _ . _ _ . - - - No_ Minor_H2S_re orted in offsets. Ri is a ui ed with sensors and alarms. - - p 9 ~ q pp - 34 Mechanical condition of wells within AOR verified (FOrservice well only)- . - Yes _ - _ _ _ 1 D-134_and 1D-40 surface hole penetrate in AOR, Cementing records acceptable. - No AOR issues._ - . Geology 35 Permit can be issued wlo hydrogen_sulfide measures - . - - Yes _ - - _ _ - -Nearby well bores in pool,_ 1 D_-1.34 &_ 1_D-131, measured <10_ ppm H2S in 8!2004, Rig has sensors & al_a[ms. - . - 36 Data_presented on potential overpressure zones_ _ - - - Yes - . _ - _ Expected r_eservoirp[essure is 8,7_ppg EMW; will_be drilled with 8.6 ppg oil-based-mud. Mitigation_ Appr Date 37 Seismic analysis of shallow gas_zones_ -- _ . - - - NA_ _ measures discussed_in Drilling Hazards section. - - SFD 41412006 38 Seabed condition survey_(if off-shore) NA_ _ ------------------------------------------------------------ 39 Contactnamelphoneforweekly_progressreports_[exploratoryonly]------- ---------- NA_____ _---_._____.-_--_--,-__--_- Geologic Commissioner: Date: Engineering Date Public Commissioner: Co is Date West Sak D Sand multilateral well branch. ~,~,, '~ ~i ~ ,~_r3 .off • Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 26 16:27:03 2006 Reel Header Service name ............. LISTPE Date ..................... 06/07/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Writing Library Tape Header Service name ............. LISTPE Date ..................... 06/07/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: W-0004376108 LOGGING ENGINEER: P. SMITH OPERATOR WITNESS: F. `HERBERT MWD RUN 14 JOB NUMBER: W-0004376108 LOGGING ENGINEER: R. FRENCH OPERATOR WITNESS: F. HERBERT SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Technical Services 1J-127 L2 500292330661 ConocoPhillips Alaska, Inc. Sperry Drilling Services 26-JUL-06 MWD RUN 11 MWD RUN 12 W-0004376108 W-0004376108 R. FRENCH R. FRENCH F. HERBERT F. HERBERT 35 11N l0E 1739 2324 122.30 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2257.0 2ND STRING 6.750 7.625 5082.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE • • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 5082' MD/3495'TVD, WITHIN THE RUN 2 INTERVAL OF THE 1J-127 PB1 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 11. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,12,14 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 12,14 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND GEO-PILOT ROTARY STEERABLE BHA (GP) NO PROGRESS WAS MADE DURING MWD RUN 13. 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 1,2,11,12,14 REPRESENT WELL 1J-127 L2 WITH API#: 50-029-23306-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12227'MD/3685'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/26 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2219.5 RPS 2240.0 RPM 2240.0 FET 2240.0 RPD 2240.0 RPX 2240.0 ROP 2268.0 all bit runs merged. STOP DEPTH 12169.5 12176.5 12176.5 12176.5 12176.5 12176.5 12227.0 • • S BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 11 MWD 12 MWD 14 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2219. 5 5082.0 5082. 5 5115.0 5115. 0 10436.0 10436. 0 12227.0 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 N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2219.5 12227 7223.25 20016 2219.5 12227 RPD MWD OHMM 0.09 2000 45.957 19874 2240 12176.5 RPM MWD OHMM 0.3 1888.17 42.3607 19874 2240 12176.5 RPS MWD OHMM 0.08 2000 41.2571 19874 2240 12176.5 RPX MWD OHMM 0.31 2000 40.1941 19874 2240 12176.5 FET MWD HOUR 0.11 701.62 2.02335 19874 2240 12176.5 GR MWD API 19.39 117.69 68.1133 19901 2219.5 12169.5 ROP MWD FT/H 0.04 850.56 217.766 19919 2268 12227 First Reading For Entire File..........2219.5 Last Reading For Entire File...........12227 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/26 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 • • Date of Generation.......06/07/26 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2219.5 5082.0 RPM 2240.0 5082.0 RPD 2240.0 5082.0 RPX 2240.0 5082.0 FET 2240.0 5082.0 RPS 2240.0 5082.0 ROP 2268.0 5082.0 LOG HEADER DATA DATE LOGGED: 23-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5082.0 TOP LOG INTERVAL (FT) 2267.0 BOTTOM LOG INTERVAL (FT) 5082.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.2 MAXIMUM ANGLE: 86.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2257.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 52.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 600 FLUID LOSS (C3) 4.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.000 79.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.520 106.0 MUD FILTRATE AT MT: 2.000 79.0 MUD CAKE AT MT: 2.300 79.0 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 r~ • Optical log depth units... . .......Feet Data Reference Point ...... . .......Undefined Frame Spacing .. ........... . .......60 .lIN Max frames per record ..... . .......Undefined Absent value ... ........... .. ......-999 Depth Units .... ........... . ....... Datum Specifica tion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel 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 2219.5 5082 3650.75 5726 2219.5 5082 RPD MWD020 OHMM 0.09 2000 20.3657 5685 2240 5082 RPM MWD020 OHMM 0.3 1888.17 12.0829 5685 2240 5082 RPS MWD020 OHMM 0.08 33.59 10.2771 5685 2240 5082 RPX MWD020 OHMM 0.31 34.82 9.31456 5685 2240 5082 FET MWD020 HOUR 0.19 370.46 4.65612 5685 2240 5082 GR MWD020 API 19.39 117.69 68.8859 5726 2219.5 5082 ROP MWD020 FT/H 1.58 490.49 156.708 5629 2268 5082 First Reading For Entire File..........2219.5 Last Reading For Entire File...........5082 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/26 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .......... ...STSLIB.003 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/07/26 Maximum Physical Record..65535 File Type ............. ...LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5082.5 5115.0 LOG HEADER DATA DATE LOGGED: 19-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 • DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Memory 5115.0 5082.0 5115.0 76.9 76.9 TOOL NUMBER 6.750 5082.0 Mineral Oil Base 8.80 73.0 .0 20000 3.0 .000 .0 .000 .0 .000 .0 .000 .0 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 MWD110 FT/H 4 1 68 4 2 Name Service Unit Min Max Mean Nsam DEPT FT 5082.5 5115 5098.75 66 ROP MWD110 FT/H 0.04 18.16 8.16182 66 First Reading For Entire File.... ......5082.5 Last Reading For Entire File..... ......5115 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/26 Maximum Physical Record..65535 File Type ................LO First Last Reading Reading 5082.5 5115 5082.5 5115 • • 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.......06/07/26 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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: 12 DEPTH INCREMENT: .5000. FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5082.5 10378.5 FET 5082.5 10386.0 RPX 5082.5 10386.0 RPD 5082.5 10386.0 RPS 5082.5 10386.0 RPM 5082.5 10386.0 ROP 5115.5 10436.0 LOG HEADER DATA DATE LOGGED: 23-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10436.0 TOP LOG INTERVAL (FT) 5115.0 BOTTOM LOG INTERVAL (FT) 10436.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.5 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE -TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 017851 EWR4 Electromag Resis. 4 15'9436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5082.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 11 8.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): C 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 MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HOUR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ROP MWD120 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5082.5 10436 7759.25 10708 5082.5 10436 RPD MWD120 OHMM 2.48 131.65 56.9457 10608 5082.5 10386 RPM MWD120 OHMM 5.09 1254.81 54.2407 10608 5082.5 10386 RPS MWD120 OHMM 10.47 994.23 52.3316 10608 5082.5 10386 RPX MWD120 OHMM 7.66 887.48 50.1227 10608 5082.5 10386 FET MWD120 HOUR 0.11 701.62 0.693058 10608 5082.5 10386 GR MWD120 API 41.58 99.07 68.1801 10593 5082.5 10378.5 ROP MWD120 FT/H 1.84 850.56 250.848 10642 5115.5 10436 First Reading For Entire File..........5082.5 Last Reading For Entire File...........10436 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/26 Maximum Physical Record..65535 File Type ................LO 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....... 06/07/26 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: 14 DEPTH INCREMENT: .5000 • FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10379.0 12169.5 RPX 10386.5 12176.5 RPD 10386.5 12176.5 RPM 10386.5 12176.5 FET 10386.5 12176.5 RPS 10386.5 12176.5 ROP 10436.5 12227.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 26-JUN-06 Insite 66.37 Memory 12227.0 10436.0 12227.0 84.1 92.0 TOOL NUMBER 203301 159439 6.750 5082.0 • Mineral Oil Base 8.80 67.0 .0 25000 .0 .000 .0 .000 118.0 .000 .0 .000 .0 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 MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 ~~ RPX MWD140 OHMM 4 1 68 FET MWD140 HOUR 4 1 68 GR MWD140 API 4 1 68 ROP MWD140 FT/H 4 1 68 Name Service Unit Min Max DEPT FT 10379 12227 RPD MWD140 OHMM 12.4 160.81 RPM MWD140 OHMM 11.75 131.46 RPS MWD140 OHMM 10.86 2000 RPX MWD140 OHMM 10.33 2000 FET MWD140 HOUR 0.15 37.83 GR MWD140 API 43.39 96.56 ROP MWD140 FT/H 1.37 386.63 First Reading For Entire File..........10379 Last Reading For Entire File...........12227 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/26 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer • 16 5 20 6 24 7 28 8 Mean Nsam 11303 3697 54.0322 3581 55.2363 3581 57.6333 3581 59.8056 3581 1.78446 3581 66.6808 3582 219.291 3582 First Reading 10379 10386.5 10386.5 10386.5 10386.5 10386.5 10379 10436.5 Last Reading 12227 12176.5 12176.5 12176.5 12176.5 12176.5 12169.5 12227 Service name .............LISTPE Date .................... .06/07/26 Origin .................. .STS Tape Name ............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments ................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............ .LISTPE Date .................... .06/07/26 Origin .................. .STS Reel Name ............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments ................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
