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Home My WebLink About206-047New Plugback Esets 6/25/2024 Well Name API Number PTD Number ESet Number Date 1J-127 PB1 50-029-23306-70-00 206-047 T39006 8-22-2006 1J-127 PB2 50-029-23306-71-00 206-047 T39007 8-22-2006 1J-170 PB1 50-029-23310-70-00 206-062 T39008 8-22-2006 1J-170 PB2 50-029-23310-71-00 206-062 T39009 8-22-2006 2K-28AL1 PB1 50-103-20385-71-00 211-134 T39010 10-13-2011 2K-28AL1 PB2 50-103-20385-72-00 211-134 T39011 10-13-2011 PBU 13-27B PB1 50-029-20947-70-00 211-048 T39012 8-11-2011 PBU 13-27B PB2 50-029-20949-71-00 211-048 T39013 8-11-2011 15-02B PB1 50-029-20697-71-00 206-072 T39014 3-7-2008 15-02B PB2 50-029-20697-72-00 206-072 T39015 3-7-2008 CD2-07 PB1 50-103-20472-70-00 203-187 T39016 2-22-2006 CD2-07 PB2 50-103-20472-71-00 203-187 T39017 2-22-2006 E-23C PB1 50-029-21763-71-00 211-053 T39018 9-30-2011 E-23C PB2 50-029-21763-72-00 211-053 T39019 9-30-2011 NS-25 PB1 50-029-23181-70-00 203-166 T39020 3-22-2004 NS-25 PB2 50-029-23181-71-00 203-166 T39021 3-22-2004 OP18-08 PB1 50-029-23449-70-00 211-059 T39022 10-14-2011 OP18-08 PB2 50-029-23449-71-00 211-059 T39023 10-14-2011 1J-127 PB1 50-029-23306-70-00 206-047 T39006 8-22-2006 1J-127 PB2 50-029-23306-71-00 206-047 T39007 8-22-2006 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1J-127 KUPARUK RIV U WSAK 1J-127 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-127 50-029-23306-00-00 206-047-0 W SPT 3482 2060470 1500 588 589 588 588 171 258 244 236 4YRTST P Adam Earl 5/7/2022 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1J-127 Inspection Date: Tubing OA Packer Depth 1210 2000 1950 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509110821 BBL Pumped:0.6 BBL Returned:0.5 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:07:09 -08'00' Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1C-150 50-029-23496-00 906922998 West Sak Multi Finger Caliper Field & Processed 17-Jan-21 0 1 2 1C-150 50-029-23496-00 906922998 West Sak Injection Profile with TMD3D Field & Processed 17-Jan-21 0 1 3 1D-125A 50-029-22904-01 906903184 West Sak Plug Setting Record Field- Final 4-Jan-21 0 1 4 1D-142 50-029-23529-00 906921246 West Sak Multi Finger Caliper Field & Processed 15-Jan-21 0 1 5 1D-142 50-029-23529-00 906921246 West Sak Injection Profile with TMD3D Field & Processed 16-Jan-21 0 1 6 1E-105 50-029-23243-00 906936637 West Sak Injection Profile Field & Processed 25-Jan-21 0 1 7 1E-117 50-029-23251-00 906931006 West Sak Injection Profile Field & Processed 21-Jan-21 0 1 8 1J-118 50-029-23337-00 906941926 West Sak Packer Setting Record Field- Final 26-Jan-21 0 1 9 1J-122 50-029-23359-00 906955932 West Sak Injection Profile with TMD3D Field & Processed 6-Feb-21 0 1 10 1J-127 50-029-23306-00 906953848 West Sak Injection Profile with TMD3D Field & Processed 2-Feb-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2060470 E-Set: 34726 Regg, James B (CED) Gm 2060.70 From: NSK West Sak Prod Engr <nl638@conocophi Ili ps.com> Sent: Friday, May 31, 2019 4:25 PM To: Regg, James B (CED) �'�( 44111 Cc: Autry, Sydney; Braun, Michael (Alaska); CPF1 DS Lead Techs; CPF1 Ops Supv, CPF1&2 Ops Supt Subject: LPP /SSV Returned to Service on CPAI Wells 1J-127 and 1J-184 on 5/31/2019 Jim, The low pressure pilots (LPP) on wells 1J-127 (PTD #206-047, 206-048, 206-049) and 111-184 (PTD# 206-044, 206-045) were returned to service and removed from the "Facility Defeated Safety Device Log" today, 5/31/2019, as the LPP setpoints were o erea to accommodate sustained low injection pressure in both wells. 1J-127 is currently injecting 824 BWPD at 364 psi wellhead pressure. 1J-184 is currently injecting 715 BWPD at 257 psi wellhead pressure. The LPP's on 1J-127 and IJ -184 had been defeated on 5/6/2019 and 4/8/2019, respectively, after the wellhead pressures fell below the LPP setpoint while on injection. This notification is in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 1<,eu r-�!- -(27 Regg, James B (DOA) ��U47p From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Monday, May 6, 2019 10:14 AM To: Regg, James B (DOA) l Cc: CPF1 Ops Supv; CPF1&2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Sudan, Hari Hara; CPF1 DS Lead Techs Subject: Defeated LPP/SSV on CPAI Well 1J-127 on 5/6/2019 Jim, The low pressure pilot (LPP) on well 1J-127 (PTD #206-047, 206-048, 206-049) was defeated today, 5/6/2019, as the wellhead pressure fell below the LPP setpoint while on injection. The well is currently injecting at 677 BWPD with a wellhead pressure of 486 psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing E] Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing E] Change Approved. Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well El Convert to WAG INJQ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhllllps Alaska, Inc. Development ❑ Exploratory E] Slratigraphic❑ Service I] 206-047 3. Address: P. O. BOX 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23306-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU U-127 ADL 25650 25661 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): N/A 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11,997 feet Plugs measured none feet true vertical 3,866 feet Junk measured none feet Effective Depth measured 11,991 feet Packer measured 5,025 feet true vertical 3,866 feet true vertical 3,482 feet Casing Length Size MD TVD Buret Collapse Structural N/A N/A N/A 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 6,537' 4.5" 11,991' 3,866' Perforations: Horizontal slotted liner Measured depth: 6,628'-11,945' feet True Vertical depth: 3,731'-3,864' 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:10 0 11400 11200 1610 Subsequent to operation: 10 1400 10 11050 11660 14. Attachments (required per20AAC 25.070, 25.071, 8 25.293) 15. Well Class after work: Daily Report of Well Operations 2 Exploratory ❑ Development ❑ Service [a Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 3 GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318.374 Contact Name: Sydney Autry Authorized Name: Sydney Autry Contact Email: sydney.autry@cop.com Authorized Title: Sr. Petroleum Engineer Date: Z/7,1/2ziq Contact Phone: 907-265-6813 Authorized Signature: Form 10-404 Revised 4/2017 vrZ 3/y!9DMS1 FEB 2 51019 Submit Original Only 1 J-27 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. "jOB COMPLETE' KUP INJ WELLNAME 1J-127 WELLBORE 1J-127 C/�y�/�/� R/s NVolhilliPs Alaska. Inc qo�Annolation Well Attributes Maz Angle & MD TD FWN Name WenMI APNNWI Wallpo,a aiaiva ncll°) MD(Nes) ACI BIm RRal WEST SAK 500292330600 INJ 543 10,339.16 1199].0 ... Counneent H2s(ppm) base Entl oale XBGrE 1111 Rip Release Gare SSSV: NIPPLE Last WO: 4439 7I612006 Mtlylau . 1J1P,.Issos12:Ua:3NPM Last Tag Ve4e,espear Rlancen AnnoWbn DaPM IXxe) EM GM Wellnore lastMM BY ............. . . ....._...._ ..................... HANGER, 37.7 Last Tag: 4,983.0 31312007 iJ-1D 3 Conversion Last ReV Reason Annoblion EnE Dein WeIIWre IaIMad By IRev 3.} IL a.N-1Mo NIPPLE:.@.S SWNFACE,49.2-a.3L7� Sea Apr: 2.12.1 GASUT.....s aLEEVE:..ms.2 L.TER:e.Ca19 SEAA89Y: S.Oila oBAND LINER: Ages 12'1857 DURERLEM:5.D24.M.212o BGANp uNEa'. 5.8x8 111252 _ S LINER E. SITS 11 ,NTERMEDIeTE:.O.S6..ID8 sloTs:6.ema7.35t0�� SL .".6000 E2.D L 11_ slors:asn oe,uzo-� r IC S-0TS:9.4.e069Aa� akors:lD,sed SLOTS: 1o.enins .oma SUCTS:11,l9e.r"..5------ MSNNDLINER:S.453& 11.11 Reason: REVISE LINER 116X IDs 511N2013 1J-12] osbo0 asing StringscONOVCMRIrc4alea _,. GescrlPass GD(Inl lona, 1PIXKe)set Wein(bun sat pages lND)._WUlen(1, IsoaOe ropThenal ONDUCTOR Insulated 20 19.12 43.4 1210 121.0 94.00 K-55 WELDED Casing description 0Dlln) ID lin) TOPIX43.3RBI sM CepM 1N(B) Bet DepM Rva1 Wren 11... Gratle Top TM1rW SURFACE 10314 9.95 2,2573 2,216.1 45.50 L40 BTC Casing.,loop OD 18W) IG did Top(MtIn BNDephadea BM WPM(Nak..WRLm(I...Grage TOPTnreatl INTERMEDIATE JS18 6,87 40.5 8,428.8 3,724.6 29.70 L-80 BTC Casing aescriplbn OD lin, oln) ToplXRsR .H WIM(BI Wi WpM 11VD) MI -inn 9...Gmde .'T.. D LINER LEM 4112 396 5,0248 5212.0 3,529.0 1260 LBO IBTM Liner Details Nominal IG Top Rein TO0101lXRe1 Toplug9 nem one Co. fn) 5024.8 3482,31 7605 PACKER ZXPUNER TOPPACKeR 4.950 5,043.8 3,48651 76.53 SBR rasing Seal Bore Receprde 4.750 5063.5 3,4913 76.74 X08USHING Crosswer Bushing 3.950 5,068.] 3,4925 76.65 HANGER LEM Above Hook Hanger 3.950 5078.9 3494.8 78.48 HANGER LEM Below Hook Hanger .888 5,165.5 3,5162 74.81 BENTJT BENTJOINT 3.8 0 5208.8 ,5280 ] .50 SEALA SY Baker Sual Assembly 3880 Casing GescripNon ODIInI ID llnl Tap1M0) SeL aepM MNBI BN WpM IND)... Wtllm (I... Graf Top Thread B LINER LEM 4 (i 39I. 5.1]65 5,5010 ),6014 12.60 L-1 IST -M Liner Details xaminN lG ToptK) Top PrIND) BI Top 1.11) item Das Can (in) 5,176.5 ,5191 74.48 PACKER Z%P 5 -12'x7 -SIB" Liner Top Packer 4.950 5,195.7 3,524.4 73.90 SBR 19047 asing Seal Bare Receptacle 4 750 5,2153 ,529.9 7.30 XO BUSHING XO Bushing Sl2' Hydri1563x4-1 PBT 6.00' 3.920 5.34].1 3,566.8 75.7 HANGER LEM Above Hook Hanger 398 5.358.0 3,569.51 75. HANGER LEM Inside Hook Hanger 3710 5,423.1 3, .9 76.8 NIPPLE Camro'DB " NipplelD.3.563',li 5,21- OD 3.563 5,4973 3, 8 79. SEALASSY Baker Seal Assembly 4-112"ST-L Box up 4.75"Op 4000 Casing GeenaiPiron GD (int ID On) rop lXHe) set WpM ISIM) . CapM mot... wuLen O... Gsaae TOP Tnreaa A -SAND LINER 4112 3.96 54539 11,9907 3,8660 12.60 L-80 BTC -M Liner Details xcmle lD Top(TRUS) roP ITYDHXKBI rop malt) Ilam Da Co. n5 5,45).8 3,592.0 ]729 PACKER PRO ZXP liner Top Packer 5.500 5,472. 3,596, 7815 NIPPLE RS PedwR ¢al Nipple 3562 5,475.6 3,596. 7828 HANGER Fkxlpck Liner Hanger 4853 -3,5985178,74181E Casing Seal Bore Extension 471 5.485.5 5,505.1 3.W2.21 19 be IXO BUSHING IGIOSSOVerroarning 3920 Tubing Strings Tubing GesalpNan atrinP Ma... ID(nl Top1 -1 Sn GepM IX_Sel GepM ING)1.-WI pdX) Gentle Top Connection TUBING 4v2 396 377 5,056.1 3,489.6 12.60 L80 IS Completion Details TOP INGI nominal TOP IXR81 MKB) m Cea Com ID (1n) 3)) 3l JR Vemo ray Tubing Hangar 4.500 482.3 4823 412' aom DB Nipple 3.875" 3.075 4,983.2 3,471.8 Baker MU Sliding Sleeve 3810 174.99SLEEVE 50318 34839OR Baker Locator 3875 5,0335 3,484.3SSY Baker SEal Assembly 3875 Perforations & Slots Teething) BImges) Too Pool (ARE) Bun IND) MB) unxedzone page Shoot Wns I. 1 TYPe Com 6,628.0 7.3510 3,7314 3,739.8 WSA2, 1J-127 61412006 32.0 SLOTS ALL SLOTS THIS WELLBORE: Allernaling slotieNsalid pipe 0.125" x 25"x 32 spf@ 4 Circumkrentlal adjacent rows, 3' Carers sW9gered 18 dei 3h. non -sloped 7, 90 7252.0 3,748.3 37489 WSA2,11-127 fi14cK06 32.0 SLOTS ,511.0 9,1470 3,]513 3,]60.8 1ki A2, 1J-12] 61412 32.0 SLOTB T.-fA6.01 9,820.0 3,763.1 3 778 JWS A2, IJ -11/ 61412006 1 32.0 ISLOTS 10,382010,6]7.0 3.1`v.5 3,]99.3 WS A2, 1J-127 W412006 32.0 SLOTS 10,005.0 114620 3, 3.835.1 WS A2, 1J-1ZJ 740006 32.0 ISLOTS 11,8950 11,945.0 J,647J 3,864.1 WS A2, 1J-12] 6142006 32.0 IbL.TS Mandrel Inserts an an Tepss) N Top(hKa) rKsl Make MWeI o0(in) eery Ver IJkM1 I Type Type Pao 6rte TRO Run (In) (psi) Run Dab Com 2,469.1 2,395.2 CAMCO KB - 1R 1 SLFT DMY BK -1 0000 0.0 912412008 2 3,9095 3.141J 4 ILAMCO nu - 1R 1 GAS LIFT DMY BK -1 0000 00 9252009 KUP INJ WELLNAME 1J-127 WELLBORE 1J-127 ConocoPhillips ALES",, tr>c Im I ALES", // MMWb L. 1-u-rn,]R12115 +2oo:3s PM Notes: General B Safety Vw541s[Nem�Sclreel) Entl Oah Annobfbn 7/412006 NDT@ MULTI -LATERAL WELL, J-127 (ASAND), IJA27L1 (B SAND), IJ -1271 -2 (D -SAND) 7/412006 I.LI,E'. VIEW SCHEMATIC wIAWska Stllematic9.OREV NPNGER, 3]] CONDUCTOR ImW W G" .11210 NIRPLE:.S SURFACE: 0.48-22517 GAS LIFT: Z.1 GAGUFT;3RGSS SLEEVE', 0.9012 LOCPTOR, GOSI9 SEALARR, S.CW5 pSWO LINER I 5,M1.S- 121917 0 LINER LEM', S,ON.B5,2120 64iAND LINER. 5.358.6 I, AS2 B LINER OEM: 5, 176.55.5010 INTERMEDNTE I0.SBAIDB SLOTS: UDS 0-7,3510— 1 ll 0 ] SLOTS: 7.tlBM=O. SLOTS, B$I 1.M, 1<20� SLOTS, %,M6 M.SA 0�� SLOTS: I... GI 3677 SLOTS: IO,BX011�0 — r BLOTS. ttM611..O� 11 A,EAND uuER: pW A�� f n,w6] MEMORANDUM S • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 14,2018 TO: Jim Regg e' Z P.I.Supervisor ACL SUBJECT: Mechanical Integrity Tests ll CONOCOPHILLIPS ALASKA,INC. 1J-127 FROM: Lou Laubenstein KUPARUK RIV U WSAK 1J-127 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry �312- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-127 API Well Number 50-029-23306-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-047-0 Inspection Date: 5/9/2018 Insp Num: mitLOL180510144553 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IJ-127 - Type Inj j W TVD 3482 - Tubing 630 ' 630 ' 630 - 630 - PTD 2060470 Type Test SPT Test psi 1500 IA 1245 2000 1950 ' 1940 - BBL Pumped: 0.5 - !BBL Returned: 0,5 OA 177 . 262 - 250 - 240 - Interval 1 4YRTST P/F P Notes: SCANNED JUN 0 2r)8 Monday,May 14,2018 Page 1 of 1 r /-' 11 • P _c 0 r W t j (Om r x co }G{QQ� O ONW O > '^ l 1 oi ¢ op ((D E 0 . r PP , 0., v O o C ro 0 L 1 CI H ( r r r r r r- r rr- v p a m J 0 0 0 0 0 0 0 0 0 0 0 ,_ _04-, )„ '� �' W ZZZZZZZZZZZ y= co N L a N M 4 1A r 00 O r r r r O 4"' >- c U 'p (II O 4- 1:. : (1) O c i O 'v +-, U co O o ❑ ❑ ❑ ❑ ❑ cacao C : y IF - vi _1 _1 -1 _1 _1 _1 _1 _1 _1 _1 _1 0 W W W W W W W W W WW "= U LL LL LL LL LL LL LL LL LL LL LL +, a) a1 a1 'O -I J J J J J J J J J J J Q- > Q Q Q Q Q Q Q Q Q Q Q C 0 c Z Z Z Z Z Z Z Z Z Z Z U co a p �- LL LL LL LL LL LL LL LL LL LL LL C _ -0 c a1 G ,,,t: r6 +U+ > +O+ N t` E a u v ... 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If) If) )f) U') a) cf) N 3 a) a00 Q v I ELU u v CU CD CC r al ULU lei Q $ r M 6i 'i Q N ro O O O N (0 aJ a A Z 4-, v) = y N N ...c Y 2 2 Q m o L H CL Q N LLAJ r M N M E z a) ro :9a , 3 c F a Q • • K,Rtt (J—iz7 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Tuesday, July 19, 2016 1:59 PM IL.L'z‘, 71(,di(t To: NSK West Sak Prod Engr; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M Subject: LPP/SSV's returned to service on CPAI 1J wells Jim, The low pressure pilots(LPP) on the following wells were returned to service today, 7/19/16, after injection pressures increased above their pilot settings. - PTD#207-070, 207-071, 207-072) 1J-127 PTD#206-047 206-048, 206-049) 1J-136 (PTD#206-154, 206-155) 1J-156 (PTD#206-067,206-068, 206-069) The aforementioned wells have been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 406B.001." Notification will be sent when the remaining 1J water injector's LPP's are placed back in service. Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 ` I. iNE® JAN i 12017 Pager: (907) 659-7000 #497 n1638@conocophillips.com From: NSK West Sak Prod Engr Sent:Sunday,July 17, 2016 7:57 AM To: Regg,James B (DOA)<jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067 • cono J•hilli•s.com>; NSK Problem Well Supv<n1617@conocophillips.com>; Sullivan, Michael <Michael.Sullivan • conoco. illi.s.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>• argac, Gary <Gary.Targac@conocophillips.com>; NSK Optimization Engr<n2046 • con. o•hilli•s.com>; CPF1 DS Operators <n1275@conocophillips.com>; Stanley, Scott M <Scott.M.Stanle • co •co•hilli•s.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI 1J wells Jim, 1 ca06' D q7 Regg, James e B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday,July 17, 2016 7:57 AM la7?1 To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI 1J wells Jim, The low pressure pilots (LPP) on the following wells were defeated today, 7/17/16, after water injection service was restored to drillsite 1J following the CPF-1 facility shut down. 1J-102 (PTD#206-110, 206-111, 206-112) 1J-118(PTD#206-176, 206-177,206-178) 1J-122 (PTD#207-070, 207-071, 207-072) t-127 P #206-047 0 -048, 206-049Lff SCANNED JAN .1. 2 2017 1J-136 (PTD#206-154, 206-155) 1J-154(PTD#205-035, 205-036, 205-037) 1J-156(PTD#206-067,206-068, 206-069) The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." All injectors are on water injection and stable with building wellhead injection pressures. The AOGCC will be notified when each well's LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1O(0-041 2G2�� WELL LOG TRANSMITTAL DATA LOGGED / 2O15 K BENDER To: Alaska Oil and Gas Conservation Comm. August 31, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 .0 <. �CASA L1 RE: IPROF Log with TMD3D: 1J-127 ;C. Run Date: 8/9/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1J-127 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-23306-00 1PROF Log with TMD3D (Field print) 1 Color Log 50-029-23306-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. SCANNED Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: m "zote""t Image Project VNell History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. O~~ Y1 - V ~- 7 Well History File Identifier Organizing (done) *~wo-sided III II'lll II III II II RE CAN DIGITAL DATA Color Items: ~skettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: Re,~e~~eeaea iuiuuuuuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ D ^ Other:: /s/ Project Proofing III IIIIII VIII I~ III BY: Maria Date: /s/ Scanning Preparation ~ x 30 = ~~ + _~ =TOTAL PAGES off. ~ D a / (Count does not include cover sheet) BY: Mari Date: ~ ' ~ ~ / /s/ '""~~ ~ J / Production Scanning III IIIIII VIII (I III Stage 7 Page Count from Scanned File: ~ ~ (Count does include cover sheet) Page Count Matches Number in Scan ing P eparation: ~ YES NO BY: Maria Date: ~ ~ ©~ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III P 10/6/2005 Well History File Cover Page.doc • • Page 1 of 2 Maunder, Thomas E (DOA) From: Gauer, Jenn L [ Jennifer .L.Gauer @conocophillips.com] Sent: Tuesday, October 11, 2011 4:52 PM To: NSK West Sak Prod Engr; CPF1 Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist Subject: LPP /SSV Returned to Service on 1J -127 and 1J -154 West Sak injectors Tom and Jim, The low pressure pilots (LPP) on the wells listed below have been returned to service on 10/11/2011 after the wellhead injection pressures stabilized above the setting of the low pressure pilot. Current wellhead pressure pressure and injection rate are also listed below. This pilot had been defeated on 9/16/2011 in accordance with "Administrative Approval No. CO 406B.001." The injection pressures has increased on the following wells so as to remain above 500 psi and the LPP /SSV function has been returned to normal. Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1J -127 (20 206 -049) 555 954 1J-154 (205- 036,205 -037) 557 925 In addition to the LPP being returned to service on 1J -164, I have summarized the current defeated LLP situation at 1J below. The wells in red still have LLPs defeated, and the others wells have been returned to service with their returned to service date at the end. An email has been sent for all wells that have had their LLP returned to service. Please let me know if you have any questions. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.265.6782 Mobile - 303.248.6641 . From CPF1 Prod Engr Sent: Friday, September 16, 2011 6:44 PM To: tom.maunder@alaska.gov'; 'jim.regg @alaska.gov' Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 1J West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) Returned to normal 10/11/2011 • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, September 16, 2011 6:44 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK West Sak Prod Engr; Hutcherson, Mark R; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L Subject: RLPP /SSV defeated on multiple 1J West Sak injectors: 16- Sept -2011 Tom and Jim, The low pressure pilots (LPP) on the following wells were defeated on 09/16/2011 when the injectors were returned to service after being shut in since August 17, 2011 for pipeline pigging facility modifications. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" since the wells are all either below 500 psi or very close. As of 1830 hrs on 09/16/2011, wellhead injection pressure and injection rates are as follows for each well: Well Permit to Drill #s Wellhead Injection Pressure (PSI) Injection Rate (BWPD) 1J-105 (207- 027,207- 028,207 -029) 345 639 1J- (206- 176,206- 177,206 -178) 327 1020 1J-127 06 -048, 206 -049) 337 934 1J-154 (205- 036,205 -037) 369 623 1J-160 (207- 015,207- 016,207 -017) 352 568 1J-164 (205- 144,205 -145, 205 -146) 479 1082 1J-180 (206- 150,206 -151) 537 478 1 J -184 (206- 044,206 -045) 502 646 The AOGCC will be notified when the injection pressures have increased so as to remain above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269 @conocophillips.com 659 -7493 .i*; t_,.: ,t1 !'l pager 659 -7000 765 I I 9/19/2011 MEMORANDUM To: Jim Regg ~ ~C, ~ ~, P.I. Supervisor 1 ~(' 1 FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-127 KUPARUK RIV U WSAK 1J-127 Src: Inspector NON-CONFIDENTIAL i Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1J-127 API Well Number: 50-029-23306-00-00 Insp Num: mitRCN100516140307 Permit Number: 206-047-0 Rel Insp Num: Inspector Name: Bob Noble Inspection Date: 5/14/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J-127 ,Type Inj. ~'~ TVD sasz IA ]020 1700 ~ 16so 16so P.T.D 2060470 TypeTBSt~ SPT Test psi 1700 '~~ QA 206 273 260 ~ 253 Tubing Interval 4YRTST p~ P ~ 620 L 620 622 622 _ Notes: ,~~I~. ~~q'c~' ~e5~---15GVes; ~_ `; Ij''lf •~ -.,i~ia- ~~i i.: ~'. ._~ ' Monday, May 24, 2010 Page I of 1 • ~~ ~: ., ~~ '~,~ ~ f `s, a F `~`' 4 .MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE.. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~~ Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov AOGCC REP. Bob Noble - 3 ~ `~ OPERATOR: ConocoPhillips Alaska Inc. n FIELD /UNIT /PAD: Kuparuk /KRU / 1J '^-~ ~ ~ / DATE: 05/14!10 ~ tF! OPERATOR REP: Colee /Phillips - AES /{~,: Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 Type Inj. W TVD 3,566' Tubing 657 656 655 654 Interval 4 P.T.D. 2061100 Type test P Test psi 1500 Casing 990 1,700 1,680 1,680 P/F P Notes: OA 165 205 172 165 Well 1J-105 Type Inj. W TVD 3,639' Tubing 558 558 558 557 Interval 4 P.T.D. 2070270 Type test P Test psi 1500 Casing 1,098 1,800 1,780 1,780 P/F P Notes: OA 155 156 156 156 Well 1J-118 Type Inj. W TVD 3,599' Tubing 657 658 658 658 Interval 4 P.T.D. 2061760 Type test P Test psi 1500 Casing 1,100 1,790 1,780 1,780 P/F P Notes: OA 175 192 177 175 Well 1J-122 Type Inj. G TVD 3,684' Tubing 1,751 1,751 1,751 1,750 Interval 4 P.T.D. 2070700 Type test P Test psi 1500 Casing 809 1,690 1,640 1,620 P/F P Notes: OA 141 214 174 156 Well 1J-127 Type Inj. W TVD 3,482' Tubing 620 620 622 622 Interval 4 P.T.D. 2060470 Type test P Test psi 1500 Casing 1,020 1,700 1,680 1,680 P/F P Notes: OA 206 273 260 253 Well 1J-136 Type Inj. N TVD 3,503' Tubing 600 600 600 600 Interval 4 P.T.D. 2061540 Type test P Test psi 1500 Casing 276 1,700 1,670 1,660 P/F P Notes: OA 173 183 182 180 Well 1J-154 Type Inj. W TVD 3,437' Tubing 624 624 624 624 Interval 4 P.T.D. 2050350 T pe test P Test psi 1500 Casing 1,098 1,850 1,840 1,840 P/F P Notes: OA 527 527 527 527 Welt 1J-156 Type Inj. W TVD 3,410' Tubing 628 625 623 620 Interval 4 P.T.D. 2060670 Type test P Test psi 1500 Casing 1,147 1,900 1,890 1,890 P/F P Notes: OA 206 206 206 205 Well 1J-160 Type Inj. W TVD 3,212' Tubing 626 626 626 S~ 625 Interval 4 P.T.D. 2070150 Type test P Test psi 1500 Casing 925 1,680 1,650 1,640 P/F P Notes: OA 332 333 333 334 #, n ~„ ~. MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x15 .J J a/ • ! Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubing 580 578 576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P/F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 1,866 .1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubing 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casing 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P/F P Notes: OA 165 220 178 172 TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test '~ V ,~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s MEMORANDUM To: Jim Regg ~~~ ~~2-~~(~ P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 27, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 J-127 KUPARUK RIV U WSAK ]J-127 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv,~~- Comm Well Name: KUPARUK RIV U WSAK 1J-127 Insp Num: mitRCN090526113347 Rel Insp Num: API Well Number: 50-029-23306-00-00 Permit Number: 206-047-0 Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1J"127 Type Inj. ~/ TVD - ~ 3482 IA 780 1520 1500 1500 P.T.D 2060470 TypeTest SPT Test psi 1520 QA 260 263 255 250 Interval 4YRTST per, P / Tubing 586 586 586 586 Notes: Wednesday, May 27, 2009 Page 1 of 1 s- ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~~~,;`iG`~.f::,~: ~~.~ ~ ~i C~~i Anchorage, AK 99518 Fax: (907j 245-8952 1) Injection Profile 2) 24-Jan-09 1 J-127 1 Color Log / EDE 50-029-23260-00 u~ c ~~- b`~~ ~~s5-~ ~y Signed Print Name: ~,, ~, :. , _~_. Date ,~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Rp SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-Man.: ~dsar~l:~aor~aeCt~r~emor~~lo€~.~oss3 WEBSrrE: ~awrw.sra~~cer~!®cl.~arra C:1Documenis and Settings\Owner\Desk[op\Transmit_Conoco.~gc LPP/SSV returned to service on 1J-127 Page 1 of 1 Maunder, Thomas E (DOQj From: NSK West Sak Prod Engr [n163$@conocophillips.com] Sent: Thursday, September 18, 2008 4:26 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA} Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Allen; NSK West Sak Prod Engr; CPF1 Prod Engr Subject: LPP/SSV returned to service on 1J-127 Tom /Jim, The tow pressure pilot on 1 J-127 (PTD 206-047 / 206-048 L1 / 206-049 L2) was returned to service 9/18/2008. Eric Hollar West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7573 Pager: (907) 659-7000 x791 From: NSK West Sak Prod Engr Sen#: Tuesday, September 16, 2008 4:11 PM To: 'Maunder, Thomas E (DOA)'; yim,regq(~alaska.gov' Cc: CPFl DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; .knkins, Lubbie Allen; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1J-127 [fiESEND] Tom /Jim, The fow pressure picot {LPP) on 1J-127 (PTD 206-047 / 206-048 L1 1206-049 L2) was defeated 9/16/2008 when the well was returned to service after being shut in for a few days. Current wellhead pressure is 492 psig, injection rate is 965 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC wit! be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001". Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 9/19/2008 LPP/SSV defeated on 1J-127~SEND] Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Tuesday, September 16, 2008 4:11 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Jenkins, Lubbie Alien; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1J-127 [RESEND] Tom /Jim, The low pressure pilot (LPP) on 1J-127 (PTD 206-047 / 206-048 L1 / 206-049 L2) was defeated 9/16/2008 when the well was returned to service after being shut in for a few days. Current wellhead pressure is 492 psig, injection rate is 965 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Sa#ety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Eric Holiar / Hai Hunt West Sak Production Engineer GonocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 `,~.+~~~~ ~FP :~ `~ 2008 9i~6i2oas /~~ n~~~~a! I" I~ Ss rger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~- ~ ~ ~~ ,~ ~; ~~~~ ATTN: Beth ;-~;.,;>;,+~~ Well Job # Log Description _ ;.~ NO. 4861 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit Date BL Color CD 09/05/08 iJ-127 12096529 INJECTION PROFILE ' - ~ '~ 08/14/08 1 1 iR-11 12096530 PRODUCTION PROFILE 08/15/08 1 1 iJ-118 12066541 MEM INJECTION PROFILE 08/17/08 1 1 iJ-122 12066542 MEM INJECTION PROFILE / 08/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE (Q 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE ~(- v CQ 08/19/08 1 1 1J-105 12066543 MEM INJECTION PROFILE '}- I(p 08/19/08 1 1 2E-12 11996653 SBHP SURVEY C.. I gC_(-~ ~ 08/21/08 1 1 iJ-156 12080419 INJECTION PROFILE ( 08/21/08 1 1 1A-26 12080420 SBHP SURVEY qQ -( S 08/22/08 1 1 1A-23 12080421 SBHP SURVEY ( '~ ~ 08/22/08 1 1 2D-05 12080422 - ((p '- INJ PROF/LDL ~ 08/23/08 1 1 1H-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 26-03A 11996656 PRODUCTION PROFILE /' 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY ~ p~- ~(D l 08/26/08 1 1 2M-11 12080427 PRODUCTION PROFILE f :. ~ $~Q 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE '- Oa ~f4 08/30/08 1 1 2E-13 12080431 SBHP SURVEY ~ - G 08/31/08 1 1 2E-14 12080432 SBHP SURVEY L(-- 08/31/08 1 1 iB-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 1H-18 11996666 INJECTION PROFILE - ~/ 09/03/08 1 1 F-10 11996660 PLUG SETTING RECORD 08/28/08 1 1 iG-05 11996665 PACKER SETTING RECORD 09/02/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • r • • ConocoPhillips Alaska P.O, BOX 100360 _ ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder ~ ~ ~ ~ '~. Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 ~~~N~ SEF ~: 2008 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6`",2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date • 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29!2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1 J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1 J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1J-105 207-027 8" NA 8" NA 1.28 9!5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1 J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1 J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1 J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1J-184 206-044 8" NA 8" NA 1.28 9/6/2008 LPP/SSV returned to service o~ -127 • Page 1 of 2 Maunder, Thomas E (DOA From: NSK West Sak Prod Engr [n1638@conocophillips.com} Sent: Tuesday, September 09, 2008 10:56 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Pierson, Chris R; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on 1 J-127 Tom /Jim, The low pressure pilot on 1 J-127 jPTD 206-047 ! 206-048 / 206-049) was returned to service on 8/30/2008. The well is currently injecting 1465 bwpd at 575 psi wellhead pressure. Please let me know if you have any questions. Regards, Hai Hunt !Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax; (907) 659-7749 Email: n1638 aL")ConocoPhillips.com From: NSK West Sak Prod Engr ~~~~~ SEA :~ 2D~$ Sent: Monday, August 18, 2008 9:52 AM To: NSK West Sak Prod Engr; 'Maunder, Thomas E (DOA)'; yim.regg@alaska.gov` Ce: CPFl DS Lead Techs; CPFl Prod Supt; Targac, Gary; NSK Problem Well Supv; Pierson, Chris R Subject: LPP/SSV Defeated on 1J-127 Tom /Jim, The low pressure pilot (LPP) on 1J-127 (PTD 206-047 / 206-048 L1 / 206-049 L2) was defeated on 8/18/2008 when the well was returned to service after being shut in for wellwork. Current wellhead pressure is 396 psi, injection rate is 1240 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001 ". Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 9/9/2008 Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anclora~e Alaska ~9S'18 WELL LOG TRANSMITTAL To: State of Alaska July 31, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~' ~ d~7 RE: MWD Formation Evaluation Logs: 1J-1-72+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 50-029-233 06-00,60,61,70, 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 ~~.~~ ~G'G ~~ ~. ~~~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: -=, gate: ~ ~Z 1 '~(~b ~ • BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 l1e ~~~~ v Signed: uze a~ ~ v~ ~ ~ ~ ~~~ y ~ ~~e a6~- o~~s ~r~~~~ ~ Soto-o~-e ~ ~ ~~~~ LPP/SSV Defeated on 1J-127 Page 1 of 1 • • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Monday, August 18, 2008 9:52 AM To: NSK West Sak Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Pierson, Chris R Subject: LPP/SSV Defeated on 1 J-127 Tom /Jim, The low pressure pilot (LPP) on 1J-~7 (PTD 206-047 / 206-048 L1 / 206-049 L2) was defeated on 8/18/2008 when the well was returned to service after being shut in for wellwork. Current wellhead pressure is 396 psi, injection rate is 1240 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log". The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer CanocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 ~~~~ ~~G ~ ~ 20~i~ 8/18/2008 .,/~-,~ ~/S-D~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~!dS n r,~ - ~. ~. 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ 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: COnOCOPhilllps Alaska, InC. Development ^ Exploratory ^ ~1 206-047 / 3. Address: Stratigraphic ^ Service ~ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 `'~ 50-029-23306-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 43' ~"'`~ 1 J-127 8. Property Designatrc~n: x,10. Field/Pool(s): ~ ADL 25661, 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11997' feet true vertical 3866' feet Plugs (measured) Effective Depth measured 4983' feet Junk (measured) true vertical 3472' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 121' 121' ~~ ' " ' ~ ~~ A(~~ .~ '~ ~~~ SURFACE 2215 10-3l4 2258 2216 INTERMEDIATE 6386' 7-5/8" 6429' 3724' A-SAND LINER 6535' 4.5" 11989' 3865' Perforation depth: Measured depth: 6628'-7351', 7609'-8252', 8511'-9147', 9446'-9820', 1 0362'-10677', 10805'-11482', 11695'-11945' true vertical depth: 3731'-3740', 3748'-3749', 3752'-3761', 3763'-3778', 3805'-3800', 3804'-3835', 3848'-3864' Tubing (size, grade, and measured depth) `_ i~ ('~ 4.5", L-80, 5056' MD. ~ J ~J t, f'~~~15~~~~~~ 5~~~ ~OC~C ` Packers & SSSV (type & measured depth) A-sand HRD ZxP liner top pkr ~ 545a' y ~ ~y~, ~ _ ' Camco'DB-6' nipple @ 482' i`~ / 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 Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: 308-249 Contact Guy Schwartz 5-6958 Printed Name Guy Sch Title Wells Group Engineer Signature Phone Date ~- ~G - Pre aced b Sharon All u -Drake 263-4612 Form 10-404 evised 04/2006 ~ ~ Submit Original Only ~~~`~- w • 1 J-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 & 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. 1~ ,1~'~ ~. ~ KRU 1J-127 Cc-nc~co~'hilips Alaska! ~rlc. 1J-127 ~ -- - _ _ __ _ _ _ APL SOU292330600 Well T e: INJ __ An le ~ TS: d ~ SSSV T e: NIPPLE Ori Com letion: 716/2006 An le TD: 88 de 11997 Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE Reference L 43' RKB Ref Lo Date: Last U dater 12/27/2007 Last Ta :4983 TD: 11997 ftK6 '~ Last Tag D»te 3/31/2007 Max Hole Angle 44 deq n 10531 Casin String ALL STRIN GS Descri ion Size To Bottom ND Wl Grade Thread ~ CONDUCTOR 20.000 0 121 121 62.60 H-40 WELDED SURFACE 10.750 0 2258 2216 45.50 L-80 BTC Ij I INTERMEDIATE 7.625 0 6429 3724 29.70 L-80 BTCM TERMEDIATE (0-6429, OD:7.625, Wt:29.70) ~ ~ ~ ^ ' ' ,. ~ ~ ~ I ~ I ^ ~ I D-SAND LINER TOP 4.500 5078 5084 3496 11.60 L-80 BTC L2 WINDOW 8.000 5082 5084 3496 0.00 B-SAND LINER TOP 4.500 5353 5360 3570 11.60 L-80 BTC L1 WINDOW 8.000 5358 5360 3570 0.00 A-SAND LINER 4.500 5454 11989 3866 11.60 L-80 BTCM -- -- ~,Tubi~tg String-TU_BIN~ Size To Bottom TVD Wt Grade Thread ~_ 4 SOr~ 0_ SOSG 3490 1 ~ GO L ?~U IBTM PerfDrat[ons Summary _ - - _ _ -- Interval ND Zone Status Ft SPF Date T Comment 6628 - 7351 3731 - 3740 WS A2 723 32 6/4/2006 Slots Alternatin slotted/solid i e 7609 - 8252 3748 - 3749 WS A2 643 32 6/4/2006 Slots Alternatin slotted/solid i e 8511 - 9147 3752 - 3761 WS A2 636 32 6/4/2006 Slots Alternatin slotted/solid i e 9446 - 9820 3763 - 3778 WS A2 374 32 6/4/2006 Slots Alternatin slotted/solid i e 10362 - 10677 3805 - 3800 WS A2 315 32 6/4/2006 Slots Alternatin slotted/solid i e 10805 - 11482 3804 - 3835 WS A2 677 32 6/4/2006 Slots Alternatin slotted/solid i e 11695 - 11945 3848 - 3864 WS A2 250 32 6/4/2006 Slots Alternating slotted/solid pipe Gas Lift Ma_ ndrelsNalvQs St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VN Cmnt 1 2469 2395 CAMCO KBG-2-1R DMY 1.0 BK-1 0.000 0 9!24/2006 2 3009 3140 CA_MCO Other (plugs a ui .etc De h TVD T e KBG-2-1R DMY 1.0 BK-1 0.000 0 9/2,F/2006 .) -COMPLETION 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 CMU 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, TVD SEAL BAKER SBE SEAL ASSEMBLY equip.1etc.) - A-SAND LINER DETAIL T e Descri ion 3.875 ID 5454 3592 PACKER A-SAND HRD ZXP LINER TOP PACKER 5.500 5473 3595 NIP A-SAND'RS' PACKOFF SEAL NIPPLE 4.875 5476 3596 HANGER A-SAND FLEXLOCK LINER HANGER 4.853 5486 3598 SBE A-SAND 190-47 CASING SEAL BORE EXTENSION 4.750 5505 3601 BUSHING A-SAND CROSSOVER BUSHING 3.920 11989 Other De h 3866 plugs,, ND SHOE equip., etc T e A-SAND ROT SILVER BULLET GUIDE SHOE .) - t)-SAAID & B-SAND LEMs -- -- Descri tion D nnn ID 5025 3482 PACKER D D-SAND ZXP LINER TOP PACKER 4.950 -~ 5044 3487 SBR D D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 5063 3491 Bushin D D-SAND CROSSOVER BUSHING 5.5" T04.5" 3.950 5064 3491 PUP D D-SAND PUP 3.958 5069 3493 HANGER(Dl D-SAND LEM ABOVE HOOK HANGER 3.950 5215 3530 Bushin B B-SAND CROSSOVER BUSHING 5.5" T04.5" 3.920 5216 3531 PUP B-SAND PUP 3.970 5347 3567 HANGER B B-SAND LEM ABOVE HOOK HANGER 3.980 5358 3569 HANGER B B-SAND LEM INSIDE HOOK HANGER 3.710 5358 3569 HANGER(B) General Notes Date I Note B-SAND BAKER MOD B1 IINSIDE CASINGI 3.980 7/4/2006 NOTE: MULTI-LATERAL WELL: 1J-127 (A-SANDI. 1J-127L1 IB-SANDI. 1J-127L2 (D-SAND) • • 20" 94p x 34" Insulated Conductor, sat at +!- 80' 10-374" x 4-112" Wellhead. 5000 psi 10-314" 68#, Casing D' Shoe, set ~ 2231' MD, 22or TVD ~ Tubing String 4.112" 12.6#, L-80, IBTM 3.958" ID, J.833" Drift 5-V2" X 7578" ZXP Linter ' Top Paeker w! Hold Seal Assembly Downs 4.75~SeaI OD ~~ 3S ..5033 -.~OS~ Seal Assembly 4.75" Seal OD 4112" Uner Shoe, 11.6f, L-80 BTC Set ~ 12301' MD, 3661' TVD Tubing, 3pscial Drift to +!- 600' MO 3.875" DB Nipple, for Possible SSSV L" 1~ GLMr Camco KBG•2, 4-1/2" X 1" ~ ~~~ GLM, Camco KBG-T, 4-1/2" X 1" 3~~~1/ CMU Sliding Sleeve, wl 3.81" DB Nipple ~-.1~y~ 1-7/2" X 75/8" Seal Bores Model'8' HOOK Hanger ].88" ID 5.112" X 7-5/8"ZXP Later Top Packer wl Hoid Downs Lateral Entry Module (LEM) Assembly --- ~..._ -- 5-712" %7318"ZXP Liner Top Packer with Hold Downs -._ Casing Sealbore Receptacle 1.75" ID Orienting Profile ~~ Autonwtie Alignment of LEM _ Positive Latching Colbt "--~ Indicates Gonect Location L'- _ Seal Bore for Utanl Isolation - 3.66" ID -~" Access Window \ Positive Lateral Access Via Thnr-Tubing Diverter \ Seal Bore for Lateral Isolation - 3.68" ID -'-^-.. Isolation Sea{ Asembly 1.75" Seal OD ].875" Sea11D Casing Sealbore Receptacle. 20' Length CQ +~~ ~ C"/'1/ i Lateral Envy Module(LEMJ J~ r D-sand Window '~' Sand Lateral ~at 5202' MD, 3487' TVD 4-112" 11.6f L-80 Slotted Linter Swivel 1712" Bent Joint ~~~ ,. Liner Every Outer Joint ~~ • , .~ ~ ~ . 111r Guide Shoe Casing Sealboro Recaptack .`,` 20' Length ~" avr x 7-51a° -- . Modal'8' HOOK Hanger Seal Bore 3 68" ID CQIrtOCt?~"11~~1}a5 West Sak 7-5/8" Injector 1 J-127 Tri-Lateral Completion ." 4-1/2" Liner Shoe, 11.6p, L-80 BTC Set ~ 12084' MD, 3717 TVD 3.582" DB Nippk 4112" 12.6f Tubin •'" °°"-----....._. 3.833" Drill 3.958' ID -.. _-.. • \, ,.. ` ~ 5-112".x 7318" ZXP ~'^' ~ `~~ `" Liner Top Packet 1 Seal Assembly wilhHoid Downs f 1 75" Seal t~ 'A' Sand Undulating Lateral s-v2" x 7314" •~ Plax lock 4112" 11.6f L20 Slotted Liner Hanger /Paeker Assembly et n9e Liner Every Other Joint 4G~M Shoe c +1. 5400' MD lJtter Ha r `., r'°~sing Sealboro Reeaptack. ~ .~ ,y _ ~ ~~~ 4-112" C 20' Length \~ ,~_..J~.+.;4: -'~.~ Set @ aat<r aueMa 5006. TNa OoCerMnt may not M relirodo<M or etaatMted. M emote a M part M Myr<rrw ar. M' my me<ns <Itokonk w nwceeniw, IneMelnq peotaeepykq. reoordine, a W enY Mferm+rfan slxp< aw0 nbi<vM ayal<m now Mevrrr a h<r<rahr InwwlW, MNeot wltelll perneaalen from eak<r HegMa be. Casing Shoe, Set at ~ ,_ _...._ ilD, 3737 TVD (84 deg wear aak rdA' ir4 ~~0~ ~~C ~"~~~ ~~~1 `~ `~ ~~~~ D~ / LaMnl Entry Module(I.EM) t3-sand Window /a:55zY MD, 357r TYO 'B' Sand Lateral ,* 4-112" 11.6! L-80 Stoned Lateral EI With Dive Wtetal A GS RunMrg toes suing In (3.00" ~': -- Coll Canrtector (t.OD' Length) t ~~ reack Pr<aswe Valve )1.60' Length) r--Fbw-iMU SwwN ~~ ~ 7t.2s Lengtnl -r---' HyUnufic ~~ 0leconnect ~'t )1.50' LengMj `~, GS Spear ~! 71.so' Lergthl s as n Appre,. oAL• 'Jars may be required in highry d<vtakv7 Lmar Swrvcl Liner Fvery Ctturr Jomt . 3-112" Bent Joint fit `` / ~1'~~~_ .'.~,--, f. _. 3-1IT'Gwde Shoc As PI. LPP/SSV returned to normal on 1J-127 Page 1 of ~ • Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Saturday, August 02, 2008 3:32 PM To: NSK West Sak Prod Engr; Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; Pierson, Chris R Subject: LPP/SSV returned to normal on 1 J-127 Tom /Jim, The LPP/SSV function on 1J-127 (,PTD 206-047 / 206-048 / 206-049) was returned to normal on 8/2/2008. Current injection rate is 1105 bwpd at 637 psi wellhead pressure. Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com From: NSK West Sak Prod Engr Sent: Monday, July 26, 2008 2:22 PM 70: 'Maunder, Thomas E (DOA)'; 'jim.regg@alaska.gov' Cc: CPFi DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV defeated on iJ-127 Tom /Jim, (Revised version) The iow pressure pilot (LPP) an 1J-127 (PTD 206-047 / 206-048 L1 ! 206-049 L2) was defeated on 7/28/2008 when the well was returned to service after being shut in for a clean out. Current wellhead pressure is 458 psi; injection rate is 1055 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001", Please let me know if you have any questions. Regards, Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. 8/3/2008 LPP/SSV defeated on 17-127 ~ ~ Maunder, Thomas E (DOA) Page 1 of 1 From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Monday, July 28, 2008 Z:22 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPf1 Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr; Pierson, Chris R Subject: LPP/SSV defeated on 1J-127 Tom /Jim, Revised version] The low pressure pilot (LPP) on 1 J-127 (PTD 206-047 / 206-048 L1 / 206-049 L2) was defeated on 7/28/2008 when the well was retumed to service after being shut in for a clean out. Current wellhead pressure is 458 psi; injection rate is 1055 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is retumed to normal, in accordance with "Administrative Approval No. CO 4066.001". Please let me know if you have any questions. Regards, Eric Hofliar / Hai Hunt West Sak Production Engineer ConocoPhiHips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 7/29/2008 LPP/SSV defeated on 1J-127 Page 1 of Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Monday, July 28, 2008 1:05 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: LPP/SSV defeated on 1 J-127 Tom, Correction on that--the HP pilot is not defeated. The operator was not familiar with the design of the system, our lead operator has clarified this for us. I'll resend the email with correct wording. Thanks. Eric Holler / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 ~~,~1N~ JUL ~ '~ 2D08 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, July 28, 2008 10:45 AM To: NSK West Sak Prod Engr Cc: Regg, James B (DOA) Subject: RE: LPP/SSV defeated on 1J-127 Eric, A question ... why was the HP pilot defeated? I can understand the LP but, although the chance is low, wouldn't you want the HP active in case of some plugging? Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:ni638@conocophillips.com] Sent: Monday, July 28, 2008 10:18 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPFi Prod Supt; Targac, Gary; NSK Problem Well Supv; NSK West Sak Prod Engr Pierson, Chris R Subject: LPP/SSV defeated on iJ-127 Tom /Jim, The low and high pressure pilot (LPP $~ HPP) on 1 J-127 (PTD 206-047 / 206-048 L1 / 206-049 L2) was defeated on 7128/2008 when the well was returned to service after being shut in for a clean out. Current wellhead pressure is 458 psi; injection rate is 1055 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC wilt be notified when the injection pressure has increased to above 500 psi and the LPP/HPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4068.001". 7/29/2008 • ~' ~ 1_... ~r~ ~ .J ~~ °' ALASSA OIL AI1TD GA5 CO1~T5ERQATIOI~T COMIrII55IO1~T Guy Schwartz Wells Group Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 • SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-127 ~~~ f ~ ~~ Sundry Number: 308-249 ~~ 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 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 ff 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, Dan Chair DATED this ~ day of July, 2008 Jr. Encl. v - s0 , STATE OF ALASKA ~~1 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ _ '~ ~~~ APPLICATION FOR SUNDRY APPROV,~ M a ~%';; ' ~.:..rr~3i~~~i~rt 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver "~~ `' Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate Q 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 ^ 206-047 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23306-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ~ ~ 1J-127 ' 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 CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11997' ~ 3866' 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" 6429' 3724' A-SAND LINER 6535' 4.5" 11989' 3865' Perforation Depth MD (ft): Perforation Depth TVD (ft Tubing Size: Tubing Grade: Tubing MD (ft): see attached schematic 4.5" L-80 5056' Packers and SSSV Type: Packers and SSSV MD (ft) A-sand HRD ZXP liner top pkr @ 5454' Camco 'DB-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 0 WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GU SChWB Title: Wells Group Engineer ~ Signature Phone 265-6958 Date .... ry -' ~~ Commission Use Onl i Sundry Number: [[ ~~ ~ 7 tness Conditions of approval: Notify Commission so that a representative may w Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~~ APPROVED BY /rlyq ~,,/Q Approved by: O ISSIONER THE COMMISSION ~ Date: (J (/!/ Form 10-403 Revised 06/200 p1 1 ~~y~~/~ } ~ ~~0~ y' ~Srubmit in Duplicate 1 1 , IVI /~'~j/Ij,,.,, 5 ~~~ .11.~~_ ~ ~` •~lc ~S' ~ 7• ~l . p $ • ~ 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 "Micro Wash "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: 1. Isolate the B lateral by setting an ISO sleeve at B lateral junction -~'~~,p~~~ '~~ 2. RIH with 2 3/8" CT and lay in 327 bbls of Microwash 1:1 . 3. Let soak for 24 hrs and commence injection. 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. r ~ont~~c~i'hrtlips Alaska, Ind, .. .. fiJ=127. API: 500292330600 Well T e: INJ f' KRU 1 J-127 i e..nie n rc~ i .ion n~ i SSSV T : NIPPLE Ori Com lesion: 7/6/2006 An le TD: 88 de 11997 Annular Fluid: Reference Lo : 43' RKB Last WlO: Ref Lo Date: Rev Reason: Last U date: FORMAT UPDATE 12/27/2007 Last Ta : 4983 TD: 11997 ftKB ~.astiagvace ~~ai~zvui ~ ngaxKOieAn~ie:~y+aegrculuos ~ ~ _~ Casin String -ALL STRINGS _ _ _ _ _ _ I fl-crriMinn Ci-rn ~~- - Tnn LL.»n... T\(fl 1AN l3raii- TY~r-e.i 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 3724 29.70 L-80 BTCM D-SAND LINER TOP 4.500 5078 5084 3496 11.60 L-80 BTC L2 WINDOW 8.000 5082 5084 3496 0.00 B-SAND LINER TOP 4.500 5353 5360 3570 11.60 L-80 BTC L1 WINDOW 8.000 5358 5360 3570 0.00 I A-SANU LINtK _--- I 4.5W I _ S4_S4 I _ 11~J89 I 38liti I __l l_ .tiU I L-8_ U I _BI GM _ I ,Tubing String -TUBING -- __ -_ _-- Size Top_ Bottom _ TVD Wt Grade_ Thread_ 4.500 0 5056 '190 1260 L-80 _ IBTM -- - _- Perforations Summary TERMEDIATE (06429, OD:7.625, Wt:29.70) _- , ~- ~ ~ ~ ~ _ ~ _ ~, ! tmerval rvD zone status Ft sPF Date r commem 6628 - 7351 3731 - 3740 WS A2 723 32 6/4!2006 Slots Altematin slottedlsolid i e 7609 - 8252 3748 - 3749 WS A2 643 32 6/4/2006 Slots Altematin slotted/solid i e 8511 - 9147 3752 - 3761 WS A2 636 32 6/4/2006 Slots Altematin slotted/solid i e 9446 - 9820 3763 - 3778 WS A2 374 32 6/4/2006 Slots Altematin slotted/solid i e 10362 - 10677 3805 - 3800 WS A2 315 32 6/4/2006 Slots Altematin slotted/solid i e 10805 - 11482 3804 - 3835 WS A2 677 32 6/4/2006 Slots Afternatin slotted/solid i e 11695 - 11945 3848 - 3864 WS A2 250 32 R/4/2006 Slots -- ~as Lift andrelsNalves - _ St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port Alternating slotted/slid pipe ~ __I TRO Date Run VN CmM 1 2469 2395 CAMCO KBG-2-1R DMY 1.0 BK-1 0.000 0 9/24/2006 2 3909 3140 CAMCO KBG-2-1R DMY 1.0 BK-1 0.000 0 9/25/2006 caner (plugs, equlp.l etc_1_- GUMF'LEIIUN _- - - De h TVD T e Uescri ion ID 38 38 HANGER VETCO GRAYTUBING HANGER 4.500 482 482 NIP CAMCO'DB-6' NIPPLE wl3.875" NO GO PROFILE 3.875 4983 3472 SLEEVE-C BAKER CMU 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 _ _ iQther (lugs, equip., etc.) -_A-SAND LINER DETAIL 11989 I 3866 I SHOE i A-SAND ROT SILVER BULLET GUIDE SHOE I 0.000 I -- _; - - 3th~zr lu s e ui ----_ , _~ --_(P 9 ~ q P•. etc.).- b-SAND & B~SAND LEMs ___- 5215 3530 Bushin B B-SAND CROSSOVER BUSHING 5.5" TO 4.5" 3.920 5216 3 31 PUP B-SAND PUP 3.970 5347 3567 HANGER B B-SAND LEM ABOVE HOOK HANGER 3.980 5358 3569 HANGER B B-SAND LEM INSIDE HOOK HANGER 3.710 5358 3569 HANGER(S) B-SAND BAKER MOD B1 IINSIDE CASINGI 3.980 __ - __ iGenerai Notes l0 DATA SUBMITTAL COMPLIANCE REPORT ~i~i2oos Permit to Drill 2060470 Well Name/No. KUPARUK RIV U WSAK 1J-127 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23306-00-00 MD 11997 TVD 3866 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 (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / iyp meairrmi rvurnuer rvame og Cement Evaluation 14027 LIS Verification I ~D C Lis 14027 Induction/Resistivity 5i~it 14027 LIS Verification ~fzD / C Lis 14027 Induction/Resistivity / Kpt 14027 LIS Verification C Lis D 14027 Induction/Resistivity ~ ~L'og Production oa Production D Asc Directional Survey D Asc Directional Survey D D Asc Directional Survey Log 14523 Injection Profile j ED C Las .14523 Injection Profile Injection Profile Induction/Resistivity scale meaia No Start Stop CH Received Comments 5 Col 1 3150 5434 Case 8/10/2006 USIT, GR, MaxTrac, CCL 05-June-2006 Open 8/22/2006 2219 11939 Open 8/22/2006 GR, Res, ROP, FET 0 0 Open 8/22/2006 PB1 2219 10315 Open 8/22/2006 PB1 GR, Red, ROP, FET 0 0 Open 8/22/2006 P62 2219 10882 Open 8/22/2006 P62 GR, Res, ROP, FET 15 Blu 1 100 5420 Case 9/12/2006 PPL, Welltec Tractor Conveyance 31-Aug-2006 15 Blu 1 100 5438 Case 10/16/2006 PPL w/Deft, Welltac Tractor Conveyance 14- Sep-2006 0 11997 Open 11/9/2006 0 10373 Open 11/9/2006 PB 1 0 10939 Open 11/9/2006 PB 2 1 Blu 4780 11730 Case 3/22/2007 Injection Profile, GR, CCL, Temp, Pres, Spin 11-Mar- 2007 Case 3/22!2007 Injection Profile data **Sent back due to wrong not L1 4/12/07** 5 Blu 1 100 5390 Case 4/20/2007 Injection Profile, Welltec Conveyance 17-Apr-2007 5 Blu 1 4800 5450 Case 1/28/2008 Injection Profile w/maxtrac conveyance 21-Jan-2008 DATA SUBMITTAL COMPLIANCE REPORT 7/7/2008 Permit to Drill 2060470 Well Name/No. KUPARUK RIV U WSAK 1J-127 Operator CONOCOPHILLIPS ALASKA INC MD 11997 TVD 3866 Completion Date 7/6/2006 Completion Status 1-OIL Current Status 1WINJ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM~ON Well Cored? Y Chips Received? Y / N Analysis Y / N Received? Comments: Daily History Received? ~N Formation Tops Q/ N API No. 50-029-23306-00-00 UIC Y Compliance Reviewed By: _~ Date: ___ Page 1 of 2 Regg, James B (DOA) (~ ,~~ _ ~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, March 07, 2008 3:52 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 10-404 converting a well to injector without packer MD Attachments: 1 C-20. pdf; 1 J-102. pdf; 1 J-156. pdf; 1 J-170. pdf; 1 J-127. pdf; 1 J-184. pdf Jim, Here are the schematics of the motherbores for the list ofi wells below. Let me know if you need any additional data or if the 10-404's need to be corrected and resubmitted. MJ Loveland ConocoPhillips Well Integrity Project Supervisor 659-7043 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, March 03, 2008 1:58 PM To: NSK Problem Well Supv Cc: Fleckenstein, Robert J (DOA) Subject: FW: 10-404 converting a well to injector without packer MD Martin - West Sak wells have some unique approvals as you are no doubt aware. We discussed the exemption from packer requirements (20 AAC 25.200} - I am still looking into whether that is a wel! by well approval or some blanket authorizationJpool rule. West Sak injectors are, I believe, also completed packerless but do have a seal bore assembly and a finer top packer for the tieback string isolating the injection formation from the tubing-casing annulus. Below is a list of wells from a search of our well files that do not show a packer depth on the well completion report (10-407} or report of sundry operations (10- 404). Please provide the MD and TVD of the uppermost liner top packer/seal bore assembly. Also, please remind those submitting the 404's and 407's of the uniqueness for these West Sak completions Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Fleckenstein, Robert J (DOA) Sent: Monday, March 03, 2008 1:06 PM To: Regg, James B (DOA) Subject: 10-404 converting a well to injector without packer MD Jim, The following wells have 10-404 submitted converting them from producers to injectors and have "none" or "no packer" in the packer MD data block: 2061100 WSAK 1 J-102 2060670 WSAK 1 J-156 3/12/2008 Page 2 of 2 2060620 WSAK 1 J-170 2060470 WSAK 1 J-127 2060440 WSAK 1 J-184 2051230 KRU 1 C-20 BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax:907-276-7542 *['Jet~~;e r~c~t~; ~~e~~> e~~<til ~cl~ress boh.flc,ck~..n5tc.in:rz al~i5la gc~y 3/12/2008 -.~, f~ ~`` Ct~nt~ctaPhllli~s Alaska, lnc. ~J-127 ~~ ,< C ( ~ j t, I ~~ I ~ TERMEDIATE to sazs, 00:7.625, Wt:29.70) KRU 1J-127 ijFc 5uutat3Suouu well T e: INJ Hn le m ia: de a SSSV T e: NIPPLE Ori Com letion: 7/6/2006 An le TD: 88 de 11997 Annular Fluid: Last W/O: Rev Reaso n: FORMAT UPDATE Reference Lo 43' RKB Ref Lo Date: Last U date: 12/27/2007 Last Ta : 4983 TD: 11997 ftK6 Last Taq Date: 3/31/2007 Casin 5trin -ALL STRI NGS Max Hole Anq_ le: 94 deq_ (o7 10531 Descri tion Size To Bottom TVD 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 3724 29.70 L-80 BTCM D-SAND LINER TOP 4.500 5078 5084 3496 11.60 L-80 BTC L2 WINDOW 8.000 5082 5084 3496 0.00 B-SAND LINER TOP 4.500 5353 5360 3570 11.60 L-80 BTC L1 WINDOW 8.000 5358 5360 3570 0.00 A-SAND I INFR d 500 SdSd 119R9 3RRF 11 60 I -Rn RTf:M Tubin Strin -TUBING j Size Top Bottom TVD Wt Grade I Thread 4.500 0 5056 3490 12.60 L-80 F. _F.1 Perforations Summary I L.ro...91 i Tvn i ~.,..e I et•~r..c I ~r i cow I n~rn I -r..~e I r..mme..~ €` 6628 - 7351 3731 - 3740 WS A2 723 32 6/4/2006 Slots Alternatin slotted/solid i e - 7609 - 8252 3748 - 3749 WS A2 643 32 6/4!2006 Slots Alternatin slotted/solid i e - "' "' "-- "' 8511 - 9147 3752 - 3761 WS A2 636 32 6/4/2006 Slots Alternatin slotted/solid i e 9446 - 9820 3763 - 3778 WS A2 374 32 6/4/2006 Slots Alternatin slotted/solid i e 10362 - 10677 3805 - 3800 WS AZ 315 32 6/4/2006 Slots Alternatin slottedlsolid i e 10805 - 11482 3804 - 3835 WS A2 677 32 6!4/2006 Slots Alternatin slotted/solid i e I lh4'~ - 11`14' I :51SgIS - .S1Stiq I Wti H[ I I %.`511 I :{f I h/q//III Ih I tilrlrC I Hlr?rrl~tln~ SI~~TP/1/Cnll/1 rl~? I Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Tyfe V OD Latch Port TRO Date Run Vlv Cmnt 1 2469 2395 CAMCO KBG-2-1R DMY 1.0 BK-1 0.000 0 9!24/2006 2 3909 3140 CAMCO KBG-2-1R DMY 1.0 BK-1 0.000 D 9/25/2006 Other (plugs, equip., etc.) -COMPLETION De th TVD T e Descri ion ID 38 38 HANGER VETCO GRAY TUBING HANGER 4.500 482 482 NIP CAMCO'DB-6' NIPPLE w/3.875" NO GO PROFILE 3.875 • ~ ~. . t Y _ ~ -= -- -- 1 1 _- , -- -- ~ -- -~;r ~ -- Ir r, _~i ~ ___ r rl i't t~ 4983 3472 SLEEVE-C BAKER CMU 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 Fn'33 3484 SE4L BPKFP SBE SE4L 4GSEPARLV 3 R75 Other (plugs, equip., etc.) - A-SAND LINER DETAIL 5063 3491 Bushin D D-SAND CROSSOVER BUSHING 5.5" TO 4.5" 3.950 5064 3491 PUP D D-SAND PUP 3.958 5069 3493 HANGER D D-SAND LEM ABOVE HOOK HANGER 3.950 5078 3495 HANGER D D-SAND BAKER MOD B1 FHH INSIDE CASING 4.500 5079 3495 HANGER(D) D-SAND LEM INSIDE HOOK HANGER 3.688 PUP 4.950 ~ 535A i gSgo i HANGERrR~ i R-CAND RnKER MOD 91 /IPrcIl1E r•aclNr;i i Z oRr) General Notes lather (plugs, equip., etc.) - D-SAND & B-SAND LEMs De th TVD T e Descri lion ID 5025 3482 PACKER D D-SAND ZXP LINER TOP PACKER 4.950 5044 3487 SBR (Dl D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # e,`~ y~'~''~ . E~ Mh'n ~~n'e ~ a~l° +Y~ ~y. +'Mn~ _n ~.1~'~ ~,~ ~y ~C1~~~ Log Description C, EG~-- N0.4564 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01 /25/08 28-13 11996584 PRODUCTION PROFILE ~L - Jp 01110108 1 1E-112 11994598 INJECTION PROFILE U~ - ~' 01111108 1 1J-164L1 12005203 MEM INJECTION•PROFILE ~Qj - ~ 5 ~C- 01122108 1 2M-20 11996596 PRODUCTION PROFILE - p~( 01/22/08 1 1C-170 11970605 USIT 12102107 1 2G-06 11994596 PSP MULTI-FINGER CALIPER 01110108 1 3K-102 11994599 MDT ~ - 01114/08 1 1J-127 11994603 INJECTION PROFILE (~Z.~ ~Q(p-[~(~- 01/21/08 1 2T-21 11839639 RST 1 ~ 08/02/07 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~b Lllll._!V • VV1V4L~vu Vla 1L ii~r~•iv/~ a.. ar..~ av ~.. .~ ~.. .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: LPPISSN defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 _. _.O _ _ _ . __. 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 [maiito:n1638@conocophillips.com] Sent; Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPFi DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1E-112, 1J-102, iJ-127, 1J-164, iJ-180 Tom /Jim, The LPPISSN's on all of the West Sak DS1 E and DS1 J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I wasn't sure if you wanted the permit to drill number for the mainbore only or the laterals as well so I included both. WELL iD Permit to Drill No. 1 E-112 204-091 (MAINBORE), 204-092 (L1 }, 204-093 (L2) 1J-102 206-110 {MAINBORE}, 206-111 (L1), 206-112 (L2) 1J-105 207-027 (MAiNBORE), 207-028 (L1), 207-029 (L2) '""? 1J-127 206-047 (MAiNBORE), 206-048 (L1), 206-049 (L2} 1J-160 207-015 (MAiNBORE), 207-016 (L1), 207-017 (L2) 1J-164 205-144 (MAiNBORE), 205-145 {L1), 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (C1) 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 Hai Hunt /Pete Nezaticky /Eric Hollar NSK West Sak Production Engineer ConocoPhiilips Alaska, Inc. Phone: (907) 659-7061 Fax: (907} 659-7749 Email: n1638@ConocoPhillips.com 8/27/2007 LYYl.7JV UCLCQLGU VII 11,.-11G~~VG~ 1J-1G/~ 1J-1VY~ 1J-LOV ~ rQ~G 1 Vl l Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Wednesday, August 15, 2007 2:01 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: LPPISSN defeated on 1 E-112, 1 J-102, 1 J-127, 1 J-164, 1 J-180-- ~O ~'" `~ ~~~~~ ao~ _i ~~ Tom /Jim, . ~~~"~~ The Low Pressure Pilots (LPP) for West Sak Water Injectors 1E-112, 1J-102, 1J-127, 1J-164, and 1J-180 were defeated because of low wellhead. injection pressure. These wells were shut in far a few days starting August 9 (CPF1 ESD/Coalesces shut down), allowing bottom hole pressure to fall off. The LPPs and SSVs have been tagged and their status is recorded en the "Facility L;efeated Safety Device Log." We expect the bottom hole pressures to build back up in a few days. The AOGCC will be notified when the injection pressure has increased to above 500 psi and the LPPISSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please !et me know if you have any questions or concerns. Regards, Hai Hunt Hai Hunt /Eric Hollar /Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 8/16/2007 ' _~, + S~~Ium6~~t~~ APR °~ 0 1.0~~~ Schlumberger -DCS ,, 2525 Gambell Street, Suite 400 ~`~~~~?~ Anchorage, AK 99503-2838 ATTN: Beth ~.. . , -; I " Well Job # Log Description N0.4219 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL Kuparuk Color CD 04/20/07 1A-10 11638846 INJECTION PROFILE 04/05/07 1 2L-313 11628996 LDL 04/08/07 1 1D-137 11628997 INJECTION PROFILE 04/09107 1 2N-311A N/A USIT 04106/07 1 2N-337B 11638852 SCMT 04/11/07 1 1J-184 11638853 SBHP 04/12/07 1 1 H-10 11638844 GLS 03120/07 1 2W-03 11649957 MEM LDLIPPROF 04/10/07 1 1E-112 11638856 INJECTION PROFILE 04114107 1 1J-156 11638857 INJECTION PROFILE 04115/07 1 1J-127 11638859 INJECTION PROFILE 04/17/07 1 1J-105 11628994 USIT 04/06/07 1 1J-164• 11638858 INJECTION PROFILE 04!16107 1 1J-164 ~ 11638860 INJECTION PROFILE 04/17107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~3 SELL LAG -------- 1'R~4/t/~n/1/TT:4L ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907j 245-8952 1 j 1 BL / EDE Disk 1 J - 127 L1 Injection Profile 2) 3) 4J 5j 6] 7) ~ Signed : _ ~ .~.----.~.. Print Name: L In f ~~ r,2 ~ ~'~~g l.~ „z ~: ~~ 1., 11-Mar-07 ~ y Date • ~,^ ..~ ~-~~; i~.au ~~~ , .W ~, PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907245-8952 E-MAIL : ?~5:~,1C:-iQR,~,GEC~~E~1r°,S~`a'~ t.^,O;Vi WEBSITE :'N~Fl,'~Pf.;HtE~C3RY# `~ECs.CCgt D: LNtaster_Copy_00_PDSAiJC-20xx\Z_ WordtDistnbu4on;Transmittal_Sheets\Transmit_Origu~al.doc LPP Defeated On West Sak Injectors at DS1J Subject: LPP Defeated On West Sak Injectors at DS1J From: NSK West Sak Prod Engr <n1638@conocophillips.com> Date: Sun, 14 Jan 2007 10:08:32 -0900 To: "Tom Maunder:" <tom maunder@adminstate.ak.us>, "Jim Regg:" <jim regg@adminatate.ak.us> CC: CPFl DS Lead Techs <nl 140@conocophiliips.com>, CPFI Prod Supt <n 1132@conocoph%llips.com> Tom /Jim, aOS- ~ ~ °~~ 1) The Low Pressure Pilot (LPP) for 1J-164 was defeated on 1/8/07 in accordance with "Administrative Approval No. CO 406B.001." The LPP and SSV have been tagged and recorded on the "Facility Defeated Safety Device Log." Wellhead pressure dropped below 500 psi on 1/8/07 after a foreign object became lodged in the restriction orifice (injection choke). The foreign object was removed on 1/13/07 (yesterday) and injection rate was returned to normal. The wellhead pressure is now 468 psi (1634 bwpd) and is building back up to where it was before the 1/8/07 event. I anticipate we will need to keep the LPP defeated for ~1 week. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. 2) The Low Pressure Pilots for 1J-127, 1J-154, 1J-156, and 1J-170 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: 1J-127 1517 BWPD, 548 PSI a~~ ~Ut-l'1 ~'~ 1J-154 1406 BWPD, 612 PSI a®5-03 1 J-156 3613 BWPD, 586 PSI ~t1 ~ _ ~ ~ ~ 1J-170 2737 BWPD, 540 PSI ~~~ _O~ a Regards, Hai Hai Hunt /Pete Nezaticky NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 1 of 1 6/12/2007 1:35 PM LPP Defeated On West Sak Injectors at DS1J Subject: LPP Defeated On West Sak Injectors at DS1J From: NSK West Sak Prod Enb <n1638@conocophilrips.com> Date: Sun, 14 Tan 2007 10:08:32 -Q900 'I'o: "1 om tilaunder:" <~tom_maundcr«~~-admin.stale.ak.tis~= ~, °~ dim Rc~~°~:" <_jin~ rc~~<~(~r;aclmin.state.ak.us=° CC: (-'PI~I DS Lcacr "I~echs ~ n1 I~(~ru`conocophillir~s.com-~, C'PFl Prod Surd ~~nl 132rci'conocopl~ilrips.com - Tom i Jim, 1 } The Low Pressure Pilot {LPP} for 1 J-164 was defeated on 118{07 in accordance with '°Administrative Approval No. CO 406B.001." The LPP and SSV have been tagged and recorded on the "Facility Defeated Safety Device Log." 1Nellhead pressure dropped below 500 psi on 118107 after a foreign object became lodged in the restriction orifice {injection choke). The foreign object was removed on 1113107 {yesterday} and injection rate was returned to normal. The wellhead pressure is now 468 psi {1634 bwpd} and is building back up to where it was before the 1181(37 event. I anticipate we will need to keep the LPP defeated for ~1 week The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. 2} The Low Pressure Pilots for 1 J-127, 1 J-154, 1 J-156, and 1 J-170 were placed back into service today as the injection well head pressures have come up above 500 psi. Current status: ~ 1J-127 1517 BV11PD; 548 PSI '~~ (Q._~; c.J`~ 1 J-154 1406 B~NPD. 612 PSI 1 J-156 3613 BV~IPD. 586 PSI 1 J-170 2737 Bi1~/PD. 540 PSI Regards, Hai 1 of I 1/16/2007 11:07 AM C~ 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-127 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,624.22' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,997.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.AllenCHALLIBURTON.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 '1 IU' tti ~ 6 Si ned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) app- ~`-{~ • • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-127PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 41.30' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 10,373.00' 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 'I CJ Date ~ lu~,i~~ a ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-127PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,061.35' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 10,939.00' 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 ~ I U 1 / ~.~''~ i( Si ned g Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) I~ 1 .~ RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ ~ 2 3 2006 REPORT OF SUNDRY WELL OPERAT`O~lSri ~~. r<~~, r,.._~ ~____ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ C~g,; T`~^/ Prod to WIND -a s.,9e~l t~~e Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ . Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended We11 ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-047 / ' 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23306-00 " 7. KB Elevation (ft): 9. Well Name and Number. RKB 121' 1J-127 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11997 ~ feet true vertical 3866' • feet Plugs (measured) Effective Depth measured 11988' feet Junk (measured) true vertical 3866' feet .Casing Length _ Size MD TVD Burst Collapse Structural CONDUCTOR 121' 20" 121' 121' SURFACE 2137 10-3/4" 2258' 2216' L2 WINDOW 2' 7-5/8" 5084' 3496' L1 WINDOW 2' 7-5/8" 5360' 3570' INTERMEDIATE 6308' 7-5/8" 6429' Perforation depth: Measured depth: Slotted Liner 6628'- 11945' true vertical depth: 3731'- 3864' 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: ~ ~ 2~~~ ~~ ~( Intervals treated (measured) - Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 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 0 - Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ _ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.o. Exempt 306-312 contact Bob Christensen /Bob Buchholz ~.~ Printed Name RO D. C istense Title Production Engineering Technician Signature Phone 659-7535 Date ~~ `~/~~ ~6I~ io- ~~:ob Form 10-404 Revised 04/2004' ( Sub Ori al nl ~~~NAL ~~ ro~~~~ • 1 J-127 • 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 From: NSK Problem Well Supv <n1 G l7icl~conocophillips.com> Date: "Tue. 24 Oct 2006 16:56:10-E~8O0 To: tommaunder(u~:admin.state.ak.us, jinlrc~~~<<~'admin.statc.ak_.us, boh tlcckcnsteit~(r~`a~lmin.statc.ak.us «MIT KRU 1D 10-22-06.x1s» «MIT KRU 1J 10-22-06.x1s» All, Enclosed are the state witnessed MITIA data for the two recent surface casing repairs 1 D-109, & 1D-120 and the initial MITIA post conversion of 1i3-127, 1J-156, and 1J-170. ~'d'-l`~ One thing to note regarding the 1J data is that all three wells are currently on a vacuum thus the tubing pressure is listed as zero. If you have any questions let me know Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com Content-Description: MIT KRU 1D 10-22-06.x1s MIT KRU 1D 10-22-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 ___ Content-Description: MIT KRU 1J 10-22-06.x1s MIT KRU 1J 10-22-06.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 10/30/2006 9:14 AM STATE OF ALASKA Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Conoco Phillips Alaska Inc. Kuparuk /KRU ! 1J 10/22/06 Greenwood /Noble Jeff Jones • Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-127 Type Inj. W TVD 3,482' Tubing 0 0 0 0 Interval I P.T.D. 2060470 Type test P Test psi 1500 Casing 1400 2180 2140 2140 P/F P Notes: Pre produced injectors, well on a vacuum OA 25 0 0 0 Well 1J-156 Type Inj. W TVD 3,410' Tubing 0 0 0 0 Interval I P.T.D. 2060670 Type test P Test psi 1500 Casing 750 2000 1950 1940 P/F P Notes: Pre produced injectors, well on a vacuum OA 0 0 0 0 Well 1J-170 Type Inj. W TVD 3,391' Tubing 0 0 0 0 Interval I P.T.D. 2060620 Type test P Test psi 1500 Casing 1720 2200 2170 2160 P!F P Notes: Pre produced injectors, well on a vacuum OA 150 150 150 150 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA D =Drilling Waste G =Gas I =Industrial Wastevdater N =Not Injecting W = Water M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test 1=Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT KRU 1J 10-22-06.x1s 4~ ~ ~ =:. ~~~~~~f .~a ~ ~~~~a Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~C~-o~~ ca o,.., r.) ~~ ~~ ~ `.mot,.. ~ °N(J~1~9~~ (, Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field Well Job # Log Description Date BL Kuparuk Color CD 10/13/06 1J-127 11404957 PROD PROFILE W/DEFT 09I14/O6 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T-39 11296724 PROD PROFILE W/DEFT 09/20106 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26!06 1 1A-17 11415622 PROD PROFILE W/DEFT 09/21/06 1 1L-06 11415625 SBHP SURVEY 09/24/06 1 1 F-07 11415629 LDL 09/27106 1 2F-O6 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04!06 1 2P-447 11404966 INJECTION PROFILE 10/06/06 1 2V-08A 11216327 USIT 09/21/06 1 i • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. RE: West Sak Defeated LLP Notification *Correction* Subject: RE: West Sak Defeated LLP Notification *Correcfion* From: NSK West Sak prod Engr <n1638c~conocophillips.coln> Date: Tue, U3 Oct 2006 12:54:40-0800 'Co:.ii~r~ LZe~~~ <-jiilire~~~(~cadinin.state.ak.u5:=, l~om Nlaundcr -tom maunder(uadmi~~.state.ak.us C'C: NSh ~~'e~t Sak Prod t~:n~~r~~-n 163~i~1'conocophillips.coin., Tom/Jim, I goofed on the defeated date the original email had 10/06/06 when it really was 10/01/06. I corrected the message below. Thanks, Pete From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Tuesday, October 03, 2006 12:50 PM To: ]im Regg; Tom Maunder Cc: NSK West Sak Prod Engr Subject: West Sak Defeated LLP Notification Tom /Jim, ~---~ ao~-c~~~ This email is to notify the AOGCC that 1J-127 and 1J-156 West Sak injectors, LPP (Low Pressure Pilot) have been defeated on 10/01/06 in accordance with "Administrative Approval No. CO 4066.001". The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log". Following are the current well conditions: 1J-127: Converted from pre-production to injection 10/01/06. Injecting 1310 bwpd at 90 psi. 1J-156: Converted from pre-production to injection 10/01/06. Injecting 950 bwpd at 210 psi. The AOGCC will be notified when the injection pressure has increased above 500 psi and the LPP function is returned to normal. Regards, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineers Ph: 907-659-7061 Fax: 907-659-7749 1 of 1 10/5/2006 1:13 PM FRANK H. MURKOWSKI, GOVERNOR Robert Buchholz Production Engineering Technician ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 • 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-127 Sundry Number: 306-312 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 fallowing 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, G ~~~ Cathy . Foerster Commissioner f~- DATED,this~ day of September, 2006 Encl. -~~`~ 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 Subject: Sundry Applications for Proposed Change of Well Class 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 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 Attachments: 10-403 Forms STATE OF ALASKA ~ ~~,'~ ~~~ ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ EP Y 2 2O ~,~•" APPLICATION FOR SUNDRY APPROVALAlaska Vii! & Gas Cons. Corm~ission 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ ~ ~1 ~ ,r~/~ V' ~ ~~s Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ g•~3'v 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 206-047 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23306-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S ^ NO Q 1J-127 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 (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11997 - 3866' 11988' ~ 3866' 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' L1 WINDOW 2' 7-5/8" 5360' 3570' INTERMEDIATE 6308' 7-5/8" 6429' 3725' Perforation Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner 6628'- 11945' 3731'- 3864 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 0 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 Robelt W. Buchholz Title: Production Engineering Technician Signature ~ Phone 659-7535 Date ~/~/ Q 6 Commissi n Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ (p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ±;;:.- ; a ~G:~~~ ~~ , :.7 , ;~ ~~d~ Subsequent Form Required: 1~~ 1 ~ ~~ ~~~ ` SEP ~ 51006 APPROVED BY Approved by COMMISSIONER _~~ THE COMMISSION Date: Form 0-403 R~vised 06/2006 O ~ t ~' ~ t ~ ~ Submit in Duplicate 1 'v ,~.~ 1 J-127 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1 J-127. 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-127 will provide pressure .i support for the West Sak A 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 A sand 5-1/2" x 7-5/8" ZXP Liner Top Packer w / HRD located @ 5454' and / 3592' 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. r: . d 1J-427 -', r ~ ~ _ ~ it -, ~' `;,. a -: ~ tt .~ -_ E ; r ~ ~:: KRU 1 J-127 ~ Casing String -ALL STRINGS Description __ Size Top Bottom ~ TVD VVt Grade Thread C CONDUCTOR 20.000 0 121 121 62.60 H-40 WELDED Tubing Strin -TUBING Size To Bottom TVD 4 500 0 ~ 5056 3490 '.Perforations Summary Interval TVD Zone Status Ft _ _~ llyt i 12.60 1 SPF Date G _ Thread L 80 f _ IBT M T e Comment _ 6628 - 7351 3731 - 3740 WS A2 723 32 6!4/2006 Slots Alternatin slotted/solid i e 7609 - 8252 3748 - 3749 WS A2 643 32 6/4!2006 Slots Alternatin slotted/solid i e 8511 - 9147 3752 - 3761 WS A2 636 32 6/42006 Slots Alternatin slotted/solid i e 9446 - 9820 3763 - 3778 WS A2 374 32 6/42006 Slots Alternatin slotted/solid i e 10362 - 10677 3805 - 3800 WS A2 315 32 6/42006 Slots Alternatin slotted/soli d i e 10805 - 11482 3804 - 3835 WS A2 677 32 6/42006 Slots Alternatin slotted/solid i e 1169.5 - 11945 3848 - 3864 __ WS A2 Gas Liit Mandrels/Valves St MD TVD Man Man Type V Mfr Mfr 250 _ _ 32 6/42006 Slots Alternating slotted/solid pipe V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2469 2395 CAMCO KBG-2-1R GLV 1.0 BK-1 O.t88 1500 7/152006 2 3909 3140 CAMC_O KBG-2-1R - Other plu s, a ui ., etc. -COMPLETION De h TVD T e OV 1.0 BK-1 0:313 0 7/15/2006 - - __ Descri ion __ ID 38 38 HANGER VETCO GRAY TUBING HANGER 4.500 482 482 NIP CAMCO'DB-6' NIPPLE w/3.875" N O GO PROFILE 3.875 4983 3472 SLEEVE-C BAKER CMU 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 ASSE MBLY 3.875 Other (plugs, equip., etc.) - A-SAND LINER DETAIL De h TVD T e Descri lion ID 5454 3592 PACKER HRD ZXP LINER TOP PACKER 5.500 5473 3595 NIP 'RS' PACKOFF SEAL NIPPLE 4.875 5476 3596 HANGER FLEXLOCK LINER HANGER 4.853 5486 3598 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5505 3601 BUSHING CROSSOVER BUSHING 3.920 11989 Other ( 3866 SHOE ROT SILVER BULLET GU__I_DE SHOE 0.000 lu s, a ui p g q p., etc.) - D-SAND & B-SAND LEMs De th TVD T e Descri lion ID 5025 3482 PACKER D ZXP LINER TOP PACKER 4.950 5044 3487 SBR D 190-47 CASING SEAL BORE RECEPTACLE 4.750 5063 3491 Bushina(D1 CROSSOVER BUSHING 5.5" TO 4.5" 3.950 5196 13525 I SBR (B) 1190-47 CASING SEAL BORE RECEPTACLE I 4.750 I 5358 3569 HANGER B LEM INSIDE HOOK HANGER 3.710 5358 3569 HANGER(B BAKER MOD B1 (INSIDE CASINGS _ 3 980 ,General Notes _ _ - _ - - Date Note 7/42006 MULTI-LATERAL WELL: 1J-127 (A-SAND), 1J-127L1 (B-SAND), 1J-127L2 (D-SAND) TREE: VETCO GRAY / HORZ / 4-1/8" SM TREE CAP CONNECTION: 9.5"/ 4 TPHI. OTIS x4-1/8". 5M pc.~~ ~C:iA.NICAL INTEGRITY RrPORT ~ ~ ~ -~~C` UD ~ '.: _ . ~ OPER ~ FIELD L~ ~ ~ ~\Z~ - _~ ~ LL DAT ~_ TD : i-~.. Casing: ~1~(~ Shoe: (~,~~~ MD ..:,e.. Shoe. '~ TVD; ?ETD: PID TVD 315 TVD ; liv : ~ ~ ~ tJ Q, T~-D TVT ; _LP }'~ T~i~ .:gib; ~ V ~ ~ r PaCKer ~QSb _ole Sipe ~~1~ and ~`'=.C"r'..r~?~=C~.T, INTEGRTTY - PART #I TVD; Set at i-r~ \~~c'cJ.\ ~o ~\~-Fod1 Perfs to ~ . L~ ~~~c~.y.~ C SC~Fs~-t ~.c~ ~2 ~,.~~~ c~ C 5 ~tpC~` rnnuius Press Test• _~ 15 min .;r0 min Comments: '~'CHPNIC~s, INTEGRIT`~ - PART #2 ~"$ i~S~~atia~S Cement Volumes :~ Amt. Liner CsQ ~~crOs~s DV NQ,, f~ ~ v Cr,t Jol to cover pens ~~~5-t ~~c7~~n\~~5~ S~'~e~~J~~~~ci C~~~i'' _ eoretical TOC ~"~\~` C;~~ ~v~'.a~ ~~Zc~.S ~c~~ `T'~ C ~~o.~bw~~~ ~-hc~. ~ 3 \ Ste' Cement Bond Log (Yes oz No) ~~C., In AOGCC File •CP~S°~ ~' ~ CBL Evaluation, gone aoove perfs ~~~crc ~F3`~-S Cp~ t ~~~; 'Yy h ~( r_ e P z OQLlctlon 'Log : Type r,v luation i CONCLJS~ONS: j 1 Pazt r . i 1 ?art T2: ~' ~ ,mac ~ tL.i` 6~'~ ~ ~-3~ 4' ~ - -- -- ~~ SEP ~ 2 Zoos Sch[um6erger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth No. 3955 ' ~~II ~ Cas Cons. Commission /archcra~e Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Fiefd Well Job # Log Description Date BL Kuparuk Color CD 09/11 /06 2M-35 11213795 LDL 08/16/06 1 1Y-24A 11213786 SBHP 07/25106 1 2X-12A 11249946 PROD PROFILE W/DEFT 08/25/06 1 1D-06 11249948 INJECTION PROFILE 08/26/06 1 1A-10 11216318 INJECTION PROFILE 08/28/06 1 1J-184 11249951 PRODUCTION PROFILE 08/29/06 1 1J-127 11249953 PRODUCTION PROFILE 08/31/06 1 1J-170 11249954 PRODUCTION PROFILE 09/01/06 1 1G-04 11216321 INJECTION PROFILE 08/31/06 1 1D-12 11216322 PRODUCTION PROFILE 09/01/06 1 2F-O6 11216320 FLOWING BHP SURVEY 08/30/06 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • 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, L1, L1 PB1 & L2, AK-MW-4376108 1 LDWG formatted CD Rom 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:~~Ql_ Signed: -°~~°~"'J~ RECEIVED l~UG 2 2 2000 pil ~ Gas Cons.Oammission ... Anc~~ ~a~ ~ov~-, a~~ -au.~ ~ act -ate ~iYoa~- 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 R~~'E~~/ED State of Alaska AUG I 1 2006 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Alaska U~t & Gas Cons. C Anchorage, Alaska 99501 Anchorage 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, i~~~'-' R. Thomas ~ ~ ~ ~~~ Kuparuk Drilling Team Leader CPAI Drilling RT/skad • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIV~~~ AUG 1 12006 WELL COMPLETION OR RECOMPLETION REPORF~~~~~,s ta. Well Status: Oil O 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: A11Ch0f8 e Development ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. ~~ ~, ~ 5. Date Comp., Susp., q or Aband.: d~y , 2006 $ f ~ 12. Permit to Drill Number: 206-047 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 16, 2006 ' 13. API Number: 50-029-23306-00 ' 4a. Location of Well (Governmental Section): Surface: 1739' FSL, 2324' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: June 2, 2006 14. Well Name and Number: 1J-127 ' At Top Productive Horizon: 54' FNL, 568' FEL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 43' RKB 15. FieldlPool(s): Kuparuk River Field Total Depth: 50' FSL, 583' FEL, Sec. 23, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 11988' MD / 3865' TVD West Sak Oil P001 ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558888 y- 5945553 Zone- 4 10. Total Depth (MD + ND): - 11997 MD / 3866' TVD 16. Property Designation: ADL 25661 & 25650 TPI: x- 560613 y- 5949053 Zone- 4 Total Depth: x- 560550 - 5954436 ~ Zone- 4 11. Depth where SSSV set: nipple @ 482' 17. Land Use Permit: ALK 471 & 468 18. Directional Survey: Yes Q No^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3236' MD 21. Logs Run: 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" 46o sx DeepCRETE 4.5" 12.6# L-80 5454' 11989' 3590' 3865' 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 4.5" 5056' none slotted liner from 6628'-7351', 7609'-8252', 8511'-9147', 9446'-9820', 10632'-10676', 10806'-11482', 11695'-11945' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 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 Oit -shares production with 1J-127L1 and 1J-127L2 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 RA710 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". I;OMPLE7l~)~L 7~ NONE RBCHVIS BFIo AUG ~ ~ 2006 VER~1;tED n Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~ ` , A ~ CONTINUED ON REVERSE ~ ~. /~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-127 Top West Sak 5075' 3494' West Sak A2 6607' 3730' West Sak A2 9410' 3761' West Sak A2 11690' 3847' Base West Sak 11997' 3866' N/A 1J-127P61 TD 10373' 3781' 1 J-127PB2 TD 10939' 3808' 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 ~yy~Rand Thomas Title: Greater Kuoaruk Area Drillino Team Leader ~i~ ~ ~®~ ~ v ~~~ Signature ~l~% /~d/194~ Phone Date Prepared by Sharon Allsup-Drake .~~~'~.s 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 Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc.. Dater 7/20/2006 'l'ime: 09:26:35 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-127, True North Site: Kuparuk 1J Pad Vertical (TVD) Re ference: 1J-127: 122.3 Well: 1J-127 Section (VS) Reference: Well (OAON,0.OOE,O.OOAzi) Wellpath: 1J-127 Survey Calculation Method: Minimum Curva ture - Db: Oracle _- - - ~ Field: Kuparuk River Unit - -- -~ North Slope Alaska United States j Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre 'I i Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 J -- Well: 1 J-127 Slot Name: !. Well Position: +N/-S -367.81 ft Northing: 5945552.62 ft Latitude: 70 15 42.640 N +E/-W 94.82 ft Easting : 558887.63 ft Longitude: 149 31 26.247 W Position Uncertainty: 0.00 ft - ~ - --- --. -- ------ Wellpath: 1J-127 - ---- Drilled From: ------- 1J-127P62 _.--~ 500262330600 Tie-on Depth: 10624.22 ft Current Datum: 1 J-127: Height 122.30 ft Above System Datum: Mean Sea Level Magnetic Data: 5/15/2006 Declination: 24.09 deg i 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 1 Date: 7/20/2006 Validated: No Version: 4 I~ Actual From To Survey Toolcode Tool Name 'I ft ft J 100.00 827.00 1J-127PB1 gyro (100.00-827.00) CB-GYRO-SS Camera based gyro single shot 861.59 10061.35 1J-127PB1 (861.59- 10339.16) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 10100.00 10624.22 1 J-127PB2 (10100.00-10905.28) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 'i 1 0640.00 11962.36 1 J-127 (10640.00-11962.36) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C i Survey __ )1D Intl .Mini T~'D ~~s "CVD N/S E/~~' h1apN MapF, l i~ul 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 ~I 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 456.00 1.12 74.41 455.99 333.69 0.73 2.02 5945553.37 558889.65 CB-GYRO-SS 'i 545.00 2.11 64.82 544.95 422.65 1.66 4.34 5945554.31 558891.96 CB-GYRO-SS ~', i 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 ICI ~ 861.59 4.47 58.25 860.92 738.62 10.63 21.36 5945563.42 558908.90 MWD+IFR-AK-CAZ-SC ~!i 956.63 4.68 54.22 955.66 833.36 14.85 27.65 5945567.68 558915.16 MWD+IFR-AK-CAZ-SC 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 ', 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 Halliburton Company Survey Report Compan}~: ConocoPhillips Alaska Inc. Dater 7/2012006 Time: 09:26:35 .Page: 2 Field: Kuparuk River Unit Co-ordinate (NE) Reference: Well: 1J-12 7, True North Site: Kuparuk 1J Pad Vertic a[(TV D)Reference; 1J-127: 122.3 Well: 1J -127 Sectio n(VS) Re[erence: Well (OAON,O. OOE,O.OOAzi) ~1'ellpath: 1 J -127 Surve y Calc uhti nn ~teChod: Minimum C urv __ ature llb: Oracle _- Surcc~ __ J1D I~ul Azim TV'D Svs'I'Vll N/S f~:/~~' til:~p~ MapE Tool ' ft deg.. deg ft ft ft ft ft ft ', 2399.99 33.14 51.46 2338. 07 2215 .77 232 .16 292. 37 5945787 .03 559178 .15 MWD+IFR-AK-CAZ-SC ~ 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 j 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 3635.58 67.85 50.45 3037. 23 2914 .93 852. 57 1061. 74 5946413: 38 559942. 57 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 i 4680.74 73.93 22.91 3388. 45 3266 .15 1607 .22 1675. 46 5947172. 73 560550. 31 MWD+IFR-AK-CAZ-SC I 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 i 74.60 6.03 3467. 84 3345 .54 1873 .59 1743. 62 5947439. 61 560616. 38 MWD+IFR-AK-CAZ-SC II 5056.83 76.86 1.69 3489. 76 3367 .46 1959 .50 1749. 40 5947525 .56 560621. 49 MWD+IFR-AK-CAZ-SC it 5152.63 75.20 359.31 3512. 89 3390 .59 2052 .46 1750. 22 5947618. 50 560621. 58 MWD+IFR-AK-CAZ-SC 5250.44 72.24 359.74 3540. 31 3418 .01 2146 .33 1749. 44 5947712 .36 560620. 06 MWD+IFR-AK-CAZ-SC 5347.94 75.90 359.50 3567. 06 3444 .76 2240 .07 1748. 82 5947806 .08 560618 .71 MWD+IFR-AK-CAZ-SC 5442.84 76.78 0.34 3589. 47 3467 .17 2332 .28 1748. 69 5947898. 28 560617 .86 MWD+IFR-AK-CAZ-SC 5537.87 81.14 359.46 3607. 67 3485 .37 2425 .53 1748. 52 5947991 .52 560616. 96 MWD+IFR-AK-CAZ-SC 5588.99 81.04 359.68 3615. 59 3493 .29 2476 .03 1748. 14 5948042 .01 560616. 19 MWD+IFR-AK-CAZ-SC ~I 5632.95 80.75 0.15 3622. 54 3500 .24 2519 .44 1748. 08 5948085 .41 560615 .78 MWD+IFR-AK-CAZ-SC 5674.50 80.63 0.12 3629. 26 3506 .96 2560 .44 1748. 17 5948126 .41 560615 .56 MWD+IFR-AK-CAZ-SC ~ 5728.07 ~ 81.36 0.36 3637. 65 3515 .35 2613. 35 1748. 40 5948179 .31 560615 .37 MWD+IFR-AK-CAZ-SC I 5776.99 82.15 0.42 3644. 66 3522 .36 2661. 76 1748. 72 5948227. 72 560615. 32 MWD+IFR-AK-CAZ-SC 5822.98 82.15 0.68 3650. 95 3528 .65 2707. 32 1749. 16 5948273. 27 560615. 40 MWD+IFR-AK-CAZ-SC 5864.39 82.17 0.85 3656. 59 3534 .29 2748. 34 1749. 71 5948314. 29 560615. 63 MWD+IFR-AK-CAZ-SC 5918.15 82.02 0.95 3663. 99 3541 .69 2801. 58 1750. 55 5948367. 53 560616. 05 MWD+IFR-AK-CAZ-SC i 6013.26 81.88 0.10 3677. 31 3555 .01 2895. 75 1751. 41 5948461. 70 560616. 17 MWD+IFR-AK-CAZ-SC 6108.50 82.24 0.37 3690. 46 3568 .16 2990 .07 1751. 80 5948556. 01 560615. 82 MWD+IFR-AK-CAZ-SC 6203.81 83.40 359.48 3702. 38 3580 .08 3084 .63 1751. 67 5948650. 56 560614. 96 MWD+IFR-AK-CAZ-SC ; 6245.18 83.26 359.22 3707. 18 3584 .88 3125 .72 1751. 21 5948691. 64 560614. 17 MWD+IFR-AK-CAZ-SC 'I 6300.82 82.87 358.96 3713. 90 3591 .60 3180 .95 1750. 33 5948746. 85 560612. 86 MWD+IFR-AK-CAZ-SC 6394.32 86.20 359.72 3722. 80 3600 .50 3274 .00 1749. 26 5948839. 89 560611. 06 MWD+IFR-AK-CAZ-SC 6449.93 89.07 0.29 3725. 10 3602 .80 3329 .56 1749. 26 5948895. 44 560610. 64 MWD+IFR-AK-CAZ-SC ' 6502.61 89.18 0.82 3725. 90 3603 .60 3382 .23 1749. 77 5948948. 10 560610. 73 MWD+IFR-AK-CAZ-SC 6550.90 87.72 1.72 3727. 21 3604 .91 3430 .49 1750. 84 5948996. 37 560611. 43 MWD+IFR-AK-CAZ-SC 6594.47 86.37 1.40 3729. 45 3607 .15 3473 .98 1752. 03 5949039. 86 560612. 27 MWD+IFR-AK-CAZ-SC j 6689.32 87.69 2.47 3734. 37 3612 .07 3568 .65 1755. 23 5949134. 54 560614. 73 MWD+IFR-AK-CAZ-SC Sr Halliburton Company Survey Report C~mpan~:, ConocoPhillipsAlaska Inc. Date: 7/20/2006 lime: 09:26:35 Pale: 3 Field: Ku paruk River Unit Co-ordinate (NE) Reference: Well: 1J-12 7, T rue North Site: Kuparuk 1J Pad. Vertical (TVD) Reference: 1J-127: 122.3 Well: 1J -127 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wcllpath: 1J -127 Survcy'Calcula6 on iAlethod: Minimum Curvature Db: Oracle Survcti A1D incl Azim 'I'~~D Svs"I'VD N1S ElW MapN __ __ titapF Tool ', ', ft deg deg ft ft ft ft ft ft ~I 6782.82 88.98 2.58 3737 .09 3614.79 3662. 02 1759. 34 5949227.93 560618 .12 MWD+IFR-AK-CAZ-SC ~ 6877.15 89.85 3.16 3738 .05 3615.75 3756. 22 1764. 07 5949322.16 560622 .10 MWD+IFR-AK-CAZ-SC 6971.53 90.65 2.43 3737 .64 3615.34 3850. 49 1768. 67 5949416.45 560625 .97 MWD+IFR-AK-CAZ-SC 7065.29 91.08 0.63 3736 .22 3613.92 3944. 20 1771. 17 5949510.17 560627 .74 MWD+IFR-AK-CAZ-SC 7158.38 89.52 355.50 3735 .73 3613.43 4037. 20 1768. 03 5949603.13 560623 .87 MWD+IFR-AK-CAZ-SC 7252.27 89.22 356.56 3736. 77 3614.47 4130. 86 1761. 53 5949696.73 560616 .63 MWD+IFR-AK-CAZ-SC i 7345.58 87.36 356.22 3739 .55 3617.25 4223. 94 1755. 66 5949789.75 560610 .04 MWD+IFR-AK-CAZ-SC 7438.71 87.74 357.11 3743 .53 3621.23 4316. 82 1750. 24 5949882.58 560603 .90 MWD+IFR-AK-CAZ-SC 7531.99 87.49 357.51 3747 .41 3625.11 4409. 92 1745. 87 5949975.63 560598 .80 MWD+IFR-AK-CAZ-SC 7625.19 91.90 359.59 3747 .91 3625.61 4503. 06 1743. 51 5950068.74 560595 .71 MWD+IFR-AK-CAZ-SC ~ 7717.98 90.39 359.59 3746 .05 3623.75 4595. 83 1742. 85 5950161.49 560594 .32 MWD+IFR-AK-CAZ-SC 7811.88 89.84 359.29 3745 .87 3623.57 4689. 72 1741. 93 5950255.37 560592 .67 MWD+IFR-AK-CAZ-SC 7905.61 89.66 359.43 3746 .28 3623.98 4783. 45 1740. 88 5950349.07 560590 .89 MWD+IFR-AK-CAZ-SC ', 7999.44 90.03 357.46 3746 .53 3624.23 4877. 24 1738. 34 5950442.83 560587 .61 MWD+IFR-AK-CAZ-SC 8092.95 89.47 0.47 3746 .94 3624.64 4970. 72 1736. 65 5950536.29 560585 .19 MWD+IFR-AK-CAZ-SC 8186.92 89.04 358.61 3748 .16 3625.86 5064. 67 1735. 90 5950630.23 560583 .70 MWD+IFR-AK-CAZ-SC i 8279.88 89.85 0.82 3749 .06 3626.76 5157. 62 1735. 43 5950723.16 560582 .51 MWD+IFR-AK-CAZ-SC ', 8373.84 88.79 1.30 3750 .17 3627.87 5251. 56 1737. 17 5950817.10 560583 .52 MWD+IFR-AK-CAZ-SC 8467.23 89.66 0.05 3751 .44 3629.14 5344. 93 1738. 27 5950910.46 560583 .89 MWD+IFR-AK-CAZ-SC 'I 8560.93 89.66 356.82 3751 .99 3629.69 5438. 58 1735. 71 5951004.08 560580 .59 MWD+IFR-AK-CAZ-SC I~ 8655.20 87.11 357.91 3754 .65 3632.35 5532. 70 1731. 38 5951098.16 560575 .53 MWD+IFR-AK-CAZ-SC 8748.68 89.48 359.75 3757 .43 3635.13 5626. 11 1729. 47 5951191.54 560572 .89 MWD+IFR-AK-CAZ-SC 8835.16 89.22 1.51 3758 .41 3636.11 5712. 58 1730. 42 5951278.01 560573 .16 MWD+IFR-AK-CAZ-SC i~ 8933.75 89.47 2.13 3759 .54 3637.24 5811. 11 1733. 56 5951376.55 560575 .52 MWD+IFR-AK-CAZ-SC 9030.51 89.47 1.03 3760 .44 3638.14 5907. 83 1736. 22 5951473.28 560577 .44 MWD+IFR-AK-CAZ-SC i 9124.36 90.03 359.26 3760 .85 3638.55 6001. 67 1736. 46 5951567.11 560576 .94 MWD+IFR-AK-CAZ-SC 9218.36 91.64 358.50 3759 .48 3637.18 6095. 64 1734. 62 5951661.05 560574 .37 MWD+IFR-AK-CAZ-SC 9312.02 89.58 359.37 3758 .48 3636.18 6189. 27 1732. 88 5951754.66 560571 .90 MWD+IFR-AK-CAZ-SC ~I 9400.62 87.17 359.90 3760 .99 3638.69 6277. 83 1732. 32 5951843.20 560570 .64 MWD+IFR-AK-CAZ-SC '~~ 9499.54 88.12 2.52 3765 .06 3642.76 6376. 63 1734. 41 5951942.01 560571 .95 MWD+IFR-AK-CAZ-SC 9592.76 88.67 2.03 3767 .67 3645.37 6469. 74 1738. 11 5952035.14 560574 .92 MWD+IFR-AK-CAZ-SC 9686.32 86.80 0.75 3771 .36 3649.06 6563. 20 1740. 37 5952128.60 560576 .46 MWD+IFR-AK-CAZ-SC 9781.05 87.00 1.45 3776 .49 3654.19 6657. 77 1742. 19 5952223.17 560577 .54 MWD+IFR-AK-CAZ-SC 9874.82 87.74 1.57 3780 .79 3658.49 6751. 41 1744. 66 5952316.82 560579 .27 MWD+IFR-AK-CAZ-SC 9968.09 86.50 0.23 3785 .48 3663.18 6844. 55 1746. 12 5952409.95 560580 .01 MWD+IFR-AK-CAZ-SC 10061.35 88.18 359.29 3789 .80 3667.50 6937. 70 1745. 73 5952503.09 560578 .89 MWD+IFR-AK-CAZ-SC i i 10100.00 89.12 359.43 3790 .72 3668.42 6976. 34 1745. 30 5952541.72 560578 .16 MWD+IFR-AK-CAZ-SC 10155.28 88.41 358.23 3791 .91 3669.61 7031. 59 1744. 17 5952596.96 560576 .60 BAWD+IFR-AK-CAZ-SC 10249.18 85.47 356.62 3796 .92 3674.62 7125. 25 1739. 96 5952690.57 560571 .65 MWD+IFR-AK-CAZ-SC 10342.82 85.64 356.85 3804 .18 3681.88 7218. 46 1734. 64 5952783.73 560565 .61 MWD+IFR-AK-CAZ-SC 10436.88 89.55 359.18 3808 .12 3685.82 7312. 35 1731. 39 5952877.58 560561 .62 MWD+IFR-AK-CAZ-SC 10530.53 93.63 1.14 3805 .53 3683:23 7405. 94 1731. 65 5952971.16 560561 .15 MWD+IFR-AK-CAZ-SC I 10624.22 92.30 1.86 3800 .68 3678.38 7499. 47 1734. 10 5953064.70 560562 .87 I MWD+IFR-AK-CAZ-SC 10640.00 92.10 1.66 3800 .07 3677.77 7515. 23 1734. 59 5953080.46 560563 .23 MWD+IFR-AK-CAZ-SC 10717.90 88.21 0.05 3799 .86 3677.56 7593. 10 1735. 75 5953158.34 560563 .78 MWD+IFR-AK-CAZ-SC 10812.25 86.07 358.32 3804 .57 3682.27 7687. 32 1734. 41 5953252.53 560561 .71 MWD+IFR-AK-CAZ-SC 10905.05 88,42 358.76 3809 .03 3686.73 7779. 97 1732. 05 5953345.15 560558 .62 MWD+IFR-AK-CAZ-SC 11000.36 87.72 358.48 3812 .24 3689.94 7875. 20 1729. 75 5953440.35 560555 .58 MWD+IFR-AK-CAZ-SC i 11094.38 87.04 358.32 3816 .54 3694.24 7969. 09 1727. 13 5953534.20 560552 .23 MWD+IFR-AK-CAZ-SC 11188.54 86.23 359.60 3822 .07 3699.77 8063. 07 1725. 42 5953628.16 560549 .79 MWD+IFR-AK-CAZ-SC 11282.13 88.29 0.14 3826 .54 3704.24 8156. 54 1725. 21 5953721.62 560548 .84 MWD+IFR-AK-CAZ-SC ~ 11376.31 87.41 1.30 3830 .07 3707.77 8250. 65 1726. 40 5953815.72 560549 .29 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. llate: 7/20/2006 Lime: 09:26:35 .Page: -t Ficld: Kuparuk River Unit Co-ordinatc~NE) Reference: Well: 1J-127, True North -Site: .Kuparuk 1 J Pad Vertical (TVD) Reference: 1 J-127: 122.3 Well: 1J-127 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzij ~Vellpath: 1J-127 Survey Calculation Method: Minimum Curvature Db: Oracle Sw-ve~ ', JiD Incl Azim __ TVD Sys lll) \i5 E/~V 1'(apN _ ____ I1IapE -Cool ', ft deg deg ft ft ft ft ft ft 11470.20 87.17 1.64 3834.51 __ 3712.21 8344.40 1728.80 5953909.48 560550.96 MWD+IFR-AK-CAZ-SC 11563.44 87.11 1.94 3839.16 3716.86 8437.48 1731.71 5954002.57 560553.14 MWD+IFR-AK-CAZ-SC 11656.98 85.87 i 0.54 3844.89 3722.59 8530.82 1733.73 5954095.91 560554.43 MWD+IFR-AK-CAZ-SC 11750.47 85.00 0.04 3852.33 3730.03 8624.01 1734.20 5954189.10 560554.18 MWD+IFR-AK-CAZ-SC 11844.19 86.25 359.30 3859.48 3737.18 8717.45 1733.66 5954282.52 560552.91 MWD+IFR-AK-CAZ-SC 11936.34 88.36 359.20 3863.81 3741.51 8809.49 1732.46 5954374.54 560550.98 MWD+IFR-AK-CAZ-SC ', 11962.36 87.52 359.65 3864.75 3742.45 8835.49 1732.20 5954400.53 560550.52 MWD+IFR-AK-CAZ-SC •11997.00 87.52 359.65 3866.25. 3743.95 8870.10 1731.99 5954435.14 560550.04 • PROJECTED to TD ~; Halliburton Company Survey Report c umpany: ConocoPhillipsAlaska Inc. Date: 7/20/2006 'l'ime: 09:01:48 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE)Reference: Well: 1J-127, True'North Site: Kuparuk 1J Pad Ve rtical (TVD) Re ference: 1J-127PB1 : 12 2.3 Well: 1 J-127 Section (VS) Refer ence: Well (O.OON,O.O OE,O.OOAzi) Wellpath: 1.1- i27PB1 Su rvey Calculatio n Method: Minimum Curva ture llb: 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 Well: 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 ft Easti ng : 558887.63 ft Longitude: 149 31 26.247 W Position Uncertainty: 0.00 ft Wellpath: 1J-127P61 Drilled From: Well Ref. Point 500292330670 Tie-on Depth: 41.30 ft Current Datum: 1J-127PB1 : Height 122.30 . ft Above System Datum: Mean Sea Level I Magnetic Data: 5!15/2006 Declination: 24.09 deg ~ Field Strength: 57565 nT Mag Dip Angl e: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg i 41.30 0.00 0.00 ------- 0.00 Survey Program for DeSnitive Wellpath Date: 6/8/2006 Validated: No Version: 1 , Actual Froro To Survey Toolcode Tool Name ~~ ft ft 100.00 827.00 1J-127PB1 gyro (100.00-827.00) CB-GYRO-SS Camera based gyro single shot ~~~ 861.59 10339.16 1 J-127PB1 (861.59- 10339.16) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey A1D Inc! Azim TVD Sys TVD N/S E/W 111apA ~~lapE Tog! 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 I 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 j 356.00 233.70 0.42 0.81 5945553.05 558888.43 CB-GYRO-SS 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 I' 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 1052.51 5.32 47.90 1051.17 928.87 20.11 34.12 5945573.00 558921.59 MWD+IFR-AK-CAZ-SC 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 I 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 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 2494.12 36.32 52.92 2415.42 2293.12 265.01 334.75 5945820.21 559220.26 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 7/2 012 0 0 6 Time: 09:01:48 Page: 2 Field: Ku paruk River Uni t Co-or dinate (NE) Kefercnec: Well: 1J-12 7, True North. Site: Kuparuk 1J Pad Vertical (I'VD) Reference: 1J-127PB1 : 12 2.3 Well: 1J -127 Sectio n (VS) Reference: Well (O.OON,O.O OE,0.0©Azi} VVellpath: _____ 1 J -127PB1 Survey Calculation Mcthud: Minimum C urvature Db: Oracle Sur~~cc J~1D Incl Azim TVD Sys T'VD N/S E/VV ___ ~IapV MapE Tool ', ft deg deg ft ft ft ft ft ft I 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 I 2777 .19 48.35 50 .17 2623. 21 2500.91 384 .30 484. 48 5945940 .66 559369. 05 MWD+IFR-AK-CAZ-SC l 2875 .27 49.07 48 .90 2687. 93 2565.63 432 .13 540. 55 5945988 .92 559424. 73 MWD+IFR-AK-CAZ-SC i, I 2970 .01 52.64 49 .32 2747. 73 2625.43 480 .22 596. 09 5946037 .44 559479. 89 MWD+IFR-AK-CAZ-SC 3065 I .06 55.99 50 .70 2803. 17 2680.87 529 .81 655. 24 5946087 .48 559538. 64 MWD+IFR-AK-CAZ-SC li 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 3635 .58 67.85 50 .45 3037. 23 2914.93 852 .57 1061. 74 5946413 .38 559942 .57 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 I, 3825 .17 67.76 49. 72 3108. 37 2986.07 965 .78 1196. 15 594&527 .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 I 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 i 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 5152 .63 75.20 359. 31 3512. 89 3390.59 2052 .46 1750 22 5947618 .50 560621. 58 MWD+IFR-AK-CAZ-SC 5250 .44 72.24 359. 74 3540. 31 3418.01 2146 .33 1749. 44 5947712. 36 560620. 06 MWD+IFR-AK-CAZ-SC 5347 .94 75.90 359. 50 3567. 06 3444.76 2240 .07 1748. 82 5947806. 08 560618. 71 MWD+IFR-AK-CAZ-SC I', 5442 .84 76.78 0. 34 3589. 47 3467.17 2332 .28 1748. 69 5947898. 28 560617. 86 MWD+IFR-AK-CAZ-SC 5537 .87 81.14 359. 46 3607. 67 3485.37 2425 .53 1748. 52 5947991. 52 560616. 96 MWD+IFR-AK-CAZ-SC 5588 .99 81.04 359. 68 3615. 59 3493.29 2476 .03 1748. 14 5948042. 01 560616. 19 MWD+IFR-AK-CAZ-SC ', 5632 .95 80.75 0. 15 3622. 54 3500.24 2519 .44 1748. 08 5948085 .41 560615. 78 MWD+IFR-AK-CAZ-SC ', 5674 .50 80.63 0. 12 3629. 26 3506.96 2560 .44 1748. 17 5948126. 41 560615. 56 MWD+IFR-AK-CAZ-SC ', 5728 .07 81.36 0. 36 3637. 65 3515.35 2613 .35 1748. 40 5948179 .31 560615. 37 MWD+IFR-AK-CAZ-SC ~', 5776 .99 82.15 0. 42 3644. 66 3522.36 2661 .76 1748. 72 5948227 .72 560615. 32 MWD+IFR-AK-CAZ-SC '~, 5822 .98 82.15 0. 68 3650. 95 3528.65 2707 .32 1749. 16 5948273 .27 560615. 40 MWD+IFR-AK-CAZ-SC ' 5864 .39 82.17 0. 85 3656. 59 3534.29 2748 .34 1749. 71 5948314 .29 560615. 63 MWD+IFR-AK-CAZ-SC I 5918 .15 82.02 0. 95 3663. 99 3541.69 2801 .58 1750. 55 5948367 .53 560616. 05 MWD+IFR-AK-CAZ-SC I, 6013 .26 81.88 0. 10 3677. 31 3555.01 2895 .75 1751. 41 5948461 .70 560616. 17 MWD+IFR-AK-CAZ-SC 6108. 50 82.24 0. 37 3690. 46 3568.16 2990 .07 1751. 80 5948556 .01 560615. 82 MWD+IFR-AK-CAZ-SC 6203. 81 83.40 359. 48 3702. 38 3580.08 3084. 63 1751. 67 5948650. 56 560614. 96 MWD+IFR-AK-CAZ-SC 6245. 18 83.26 359. 22 3707. 18 3584.88 3125. 72 1751. 21 5948691. 64 560614. 17 MWD+IFR-AK-CAZ-SC 6300 .82 82.87 358. 96 3713. 90 3591.60 3180. 95 1750. 33 5948746. 85 560612. 86 MWD+IFR-AK-CAZ-SC 6394 .32 86.20 359. 72 3722. 80 3600.50 3274. 00 1749. 26 5948839. 89 560611. 06 MWD+IFR-AK-CAZ-SC I 6449. 93 89.07 0. 29 3725. 10 3602.80 3329. 56 1749. 26 5948895. 44 560610. 64 MWD+IFR-AK-CAZ-SC i 6502 .61 89.18 0. 82 3725. 90 3603.60 3382. 23 1749. 77 5948948. 10 560610. 73 MWD+IFR-AK-CAZ-SC i 6550 .90 87.72 1. 72 3727. 21 3604.91 3430. 49 1750. 84 5948996. 37 560611. 43 MWD+IFR-AK-CAZ-SC ' 6594 I .47 86.37 1. 40 3729. 45 3607.15 3473. 98 1752. 03 5949039. 86 560612. 27 MWD+IFR-AK-CAZ-SC ii 6689 .32 87.69 2. 47 3734. 37 3612.07 3568 .65 1755. 23 5949134. 54 560614. 73 MWD+IFR-AK-CAZ-SC ~ 6782 .82 88.98 2. 58 3737. 09 3614.79 3662 .02 1759. 34 5949227. 93 560618. 12 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ' Company: ConocoPhillips Alaska Inc. Date: 7/20/2006 Time: 09:01:48 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Welh 1J-127, True North Site: Kuparuk 1J Pad Vertical(TV D) Reference: 1J-127PB1 : 1 22.3 Well: 1J -127 Section (VS) Reference: Well'(O.OON,0. 00E,O.OOAzi) Wcllpath: 1J -127PB1 Surve yC`alcuiati on~lethod: MinimumCurv ature llb: Oracle &n-ve~~ ~1ll Incl Azim __ - 'CVD Sys T~'D __ N/S ElW h1apN _ h1apE - Tool ft deg deg ft ft ft ft ft ft ', 6877.15 89.85 3.16 3738 .05 3615.75 3756. 22 1764. 07 5949322.16 560622.10 MWD+IFR-AK-CAZ-SC ~~ 6971.53 90.65 2.43 3737 .64 3615.34 3850. 49 1768. 67 5949416.45 560625.97 MWD+IFR-AK-CAZ-SC 7065.29 91.08 0.63 3736 .22 3613.92 3944. 20 1771. 17 5949510.17 560627.74 MWD+IFR-AK-CAZ-SC 7158.38 89.52 355.50 3735 .73 3613.43 4037. 20 1768. 03 5949603.13 560623.87 MWD+IFR-AK-CAZ-SC 7252.27 89.22 356.56 3736 .77 3614.47 4130. 86 1761. 53 5949696.73 560616.63 MWD+IFR-AK-CAZ-SC 7345.58 87.36 356.22 3739 .55 3617.25 4223. 94 1755. 66 5949789.75 560610.04 MWD+IFR-AK-CAZ-SC ', 7438.71 87.74 357.11 3743 .53 3621.23 4316. 82 1750. 24 5949882.58 560603.90 MWD+IFR-AK-CAZ-SC '~, 7531.99 87.49 357.51 3747 .41 3625.11 4409. 92 1745. 87 5949975.63 560598.80 MWD+IFR-AK-CAZ-SC i 7625.19 I 91.90 359.59 3747 .91 3625.61 4503. 06 1743. 51 5950068.74 560595.71 MWD+IFR-AK-CAZ-SC 7717.98 90.39 359.59 3746 .05 3623.75 4595. 83 1742. 85 5950161.49 560594.32 MWD+IFR-AK-CAZ-SC 7811.88 89.84 359.29 3745 .87 3623.57 4689. 72 1741. 93 5950255.37 560592.67 MWD+IFR-AK-CAZ-SC 7905.61 89.66 359.43 3746 .28 3623.98 4783. 45 1740. 88 5950349.07 560590.89 MWD+IFR-AK-CAZ-SC ~ 7999.44 90.03 357.46 3746 .53 3624.23 4877. 24 1738. 34 5950442.83 560587.61 MWD+IFR-AK-CAZ-SC 8092.95 89.47 0.47 3746 .94 3624.64 4970. 72 1736. 65 5950536.29 560585.19 MWD+IFR-AK-CAZ-SC 8186.92 89.04 358.61 3748 .16 3625.86 5064. 67 1735. 90 5950630.23 560583.70 MWD+IFR-AK-CAZ-SC 8279.88 89.85 0.82 3749 .06 3626.76 5157. 62 1735. 43 5950723.16 560582.51 MWD+IFR-AK-CAZ-SC 8373.84 88.79 1.30 3750 .17 3627.87 5251. 56 1737. 17 5950817.10 560583.52 MWD+IFR-AK-CAZ-SC 8467.23 89.66 0.05 3751 .44 3629.14 5344. 93 1738. 27 5950910.46 560583.89 MWD+IFR-AK-CAZ-SC 8560.93 89.66 356.82 3751 .99 3629.69 5438. 58 1735. 71 5951004.08 560580.59 MWD+IFR-AK-CAZ-SC ~I 8655.20 87.11 357.91 3754 .65 3632.35 5532. 70 1731. 38 5951098.16 560575.53 MWD+IFR-AK-CAZ-SC ~~, 8748.68 89.48 359.75 3757 .43 3635.13 5626. 11 1729. 47 5951191.54 560572.89 MWD+IFR-AK-CAZ-SC ~', 8835.16 89.22 1.51 3758 .41 3636.11 5712. 58 1730. 42 5951278.01 560573.16 MWD+IFR-AK-CAZ-SC j ~, 8933.75 89.47 2.13 3759 .54 3637.24 5811. 11 1733. 56 5951376.55 560575.52 MWD+IFR-AK-CAZ-SC ', 9030.51 89.47 1.03 3760 .44 3638.14 5907. 83 1736. 22 5951473.28 560577.44 MWD+IFR-AK-CAZ-SC I ', 9124.36 90.03 359.26 3760 .85 3638.55 6001. 67 1736. 46 5951567.11 560576.94 MWD+IFR-AK-CAZ-SC ', 9218.36 91.64 358.50 3759 .48 3637.18 6095. 64 1734. 62 5951661.05 560574.37 MWD+IFR-AK-CAZ-SC ~~ ', 9312.02 89.58 359.37 3758 .48 3636.18 6189. 27 1732. 88 5951754.66 560571.90 MWD+IFR-AK-CAZ-SC ', 9400.62 87.17 359.90 3760 .99 3638.69 6277. 83 1732. 32 5951843.20 560570.64 MWD+IFR-AK-CAZ-SC ~I 9499.54 88.12 2.52 3765 .06 3642.76 6376. 63 1734. 41 5951942.01 560571.95 MWD+IFR-AK-CAZ-SC I 9592.76 88.67 2.03 3767 .67 3645.37 6469. 74 1738. 11 5952035.14 560574.92 MWD+IFR-AK-CAZ-SC ~ 9686.32 86.80 0.75 3771 .36 3649.06 6563. 20 1740. 37 5952128.60 560576.46 MWD+IFR-AK-CAZ-SC 9781.05 87.00 1.45 3776 .49 3654.19 6657. 77 1742. 19 5952223.17 560577.54 MWD+IFR-AK-CAZ-SC 9874.82 87.74 1.57 3780 .79 3658.49 6751. 41 1744. 66 5952316.82 560579.27 MWD+IFR-AK-CAZ-SC ~ 9968.09 86.50 0.23 3785 .48 3663.18 6844. 55 1746. 12 5952409.95 560580.01 MWD+IFR-AK-CAZ-SC I 10061.35 88.18 359.29 3789 .80 3667.50 6937. 70 1745. 73 5952503.09 560578.89 I MWD+IFR-AK-CAZ-SC 10155.06 90.47 359.64 3790 .91 3668.61 7031. 39 1744. 86 5952596.77 560577.28 MWD+IFR-AK-CAZ-SC 10249.21 91.20 0.05 3789 .54 3667.24 7125. 53 1744. 60 5952690.89 560576.29 MWD+IFR-AK-CAZ-SC 10339.16 95.43 0.00 3784 .34 3662.04 7215. 31 1744. 64 5952780.66 560575.63 MWD+IFR-AK-CAZ-SC 10373.00 95.43 0.00 3781 .13 3658.83 7249. 00 1744. 64 5952814.34 560575.36 PROJECTED to TD Halliburton Company Survey Report Company: GonocoPhillipsAlaska Inc. Date: 7/2012006 Lime: 09:15:47 Pare: 1 lidd: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-127, True North Site: Kuparuk 1J Pad Vertical (TVD) Re ference: 1J-127PB2 : 122.3 Well: 1 J-127 Section (VS) Reference: Well (O.OON;O.OOE,O.OOAzi) Wellpath: 1J-127P62 Survey Calculation Dlethod: Minimum Curva ture Ub: Oracle ', Field: Kuparuk River Unit - -- - - -- ', North Slope Alaska ' ' United States ~ ', Map System:US State Plane Coordin ate System 1927 Map Zoue: Alaska, Zone 4 ', ', Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre ', Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1J-127 Slot Name: I ' Well Position: +N/-S -367.81 ft Northing: 5945552.62 ft Latitude: 70 15 42.640 N '~ +E/-W 94.82 l ft Easting : 558887.63 ft Longitude: 149 31 26.247 W ', i Position Uncertainty: 0.00 ft ', Wellpath: 1J-127PB2 Drilled From: 1J-127PB1-_ -_-_ _ 500292330671 Tie-on Depth: 10061.35 ft I Current Datum: 1 J-127PB2 : Height 122.30 ft Above System Datum: Mean Sea Level I ~i Magnetic Data: 5/15/2006 Declination: 24.09 deg 'I ', Field Strength: 57565 nT Mag Dip Angle: 80.77 deg j Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg I ~ 41.30 I 0.00 0.00 0.00 ~ Survey Program for Definitive Wellpath Date: 7/20/2006 Validated: No Version: 1 ~~, Actual From To Survey Toolcode Tool Name ft ft !~ 100.00 827.00 1 J-127PB1 gyro (100.00-827.00) CB-GYRO-SS Camera based gyro single shot ~'I 861.59 10061.35 1 J-127PB1 (861.59- 10339.16) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 10100.00 10905.28 1 J-127PB2 (10100.00-10905.28) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C ~ Survey JtD Intl Azim TVD . Sys TVD N/S E/W MapN D1apE 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 i 356.00 0.32 80.33 356.00 233.70 0.42 0.81 5945553.05 558888.43 CB-GYRO-SS 456.00 1.12 74.41 455.99 333.69 0.73 2.02 5945553.37 558889.65 CB-GYRO-SS i 545.00 2.11 64.82 544.95 422.65 1.66 4.34 5945554.31 558891.96 CB-GYRO-SS t ~ 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 1052.51 5.32 47.90 1051.17 928.87 20.11 34.12 5945573.00 558921.59 MWD+IFR-AK-CAZ-SC 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 i 1719.82 11.37 48.41 1713.87 1591.57 70.08 90.60 5945623.40 558977.67 MWD+IFR-AK-CAZ-SC ~i 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 ii 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 ' 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 Company: ConocoPhillips Alaska Inc. Uate: 7/20/2006 "Time: 09:15:47 Page: 2 Field: Kuparuk River Unif Co-or dinatc(NE) Reference: Well: 1J-12 7, True North Site: Ku paruk 1J Pad Vertical(`TVD) Reference: 1J-127PB2 : 12 2.3 Well: 1J -127 Section (VS) Reference: Well (O.OON,O.O OE,O.OOAzi) ' ~Vellpath: 1 J -127PB2 Surve y Calculati on Alcthod: Minimum Curva ture Db: Oracle Survc~ __ - MD Incl Azim - "TVD _ Sys 7l7) NlS E/W h1apN 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 3635.58 67. 85 50.45 3037 .23 2914.93 852. 57 1061.74 5946413 .38 559942 .57 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 I 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 i 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 5152.63 75. 20 359.31 3512 .89 3390.59 2052. 46 1750.22 5947618 .50 560621 .58 MWD+IFR-AK-CAZ-SC i 5250.44 72. 24 359.74 3540 .31 3418.01 2146. 33 1749.44 5947712 .36 560620 .06 MWD+IFR-AK-CAZ-SC 5347.94 75. 90 359.50 3567 .06 3444.76 2240. 07 1748.82 5947806 .08 560618 .71 MWD+IFR-AK-CAZ-SC 5442.84 76. 78 0.34 3589 .47 3467.17 2332. 28 1748.69 5947898 .28 560617 .86 MWD+IFR-AK-CAZ-SC 5537.87 81. 14 359.46 3607 .67 3485.37 2425. 53 1748.52 5947991 .52 560616 .96 MWD+IFR-AK-CAZ-SC 5588.99 81. 04 359.68 3615 .59 3493.29 2476. 03 1748.14 5948042 .01 560616 .19 MWD+IFR-AK-CAZ-SC 5632.95 80. 75 0.15 3622 .54 3500.24 2519. 44 1748.08 5948085 .41 560615 .78 MWD+IFR-AK-CAZ-SC I 5674.50 80. 63 0.12 3629 .26 3506.96 2560. 44 1748.17 5948126 .41 560615 .56 MWD+IFR-AK-CAZ-SC I I 5728.07 81. 36 0.36 3637 .65 3515.35 2613. 35 1748.40 5948179 .31 560615 .37 MWD+IFR-AK-CAZ-SC 5776.99 82. 15 0.42 3644 .66 3522.36 2661. 76 1748.72 5948227 .72 560615 .32 MWD+IFR-AK-CAZ-SC I 5822.98 82. 15 0.68 3650 .95 3528.65 2707. 32 1749.16 5948273 .27 560615 .40 MWD+IFR-AK-CAZ-SC '~ 5864.39 82. 17 0.85 3656 .59 3534.29 2748. 34 1749.71 5948314 .29 560615 .63 I MWD+IFR-AK-CAZ-SC ', 5918.15 82. 02 0.95 3663 .99 3541.69 2801. 58 1750.55 5948367 .53 560616 .05 MWD+IFR-AK-CAZ-SC '~, 6013.26 81. 88 0.10 3677 .31 3555.01 2895. 75 1751.41 5948461 .70 560616 .17 MWD+IFR-AK-CAZ-SC 6108.50 82. 24 0.37 3690 .46 3568.16 2990. 07 1751.80 5948556 .01 560615 .82 MWD+IFR-AK-CAZ-SC 6203.81 83. 40 359.48 3702 .38 3580.08 3084. 63 1751.67 5948650 .56 560614 .96 MWD+IFR-AK-CAZ-SC 6245.18 83. 26 359.22 3707 .18 3584.88 3125. 72 1751.21 5948691 .64 560614 .17 I MWD+IFR-AK-CAZ-SC 6300.82 82. 87 358.96 3713 .90 3591.60 3180. 95 1750.33 5948746 .85 560612 .86 MWD+IFR-AK-CAZ-SC 6394.32 86. 20 359.72 3722 .80 3600.50 3274. 00 1749.26 5948839 .89 560611 .06 MWD+IFR-AK-CAZ-SC 6449.93 89. 07 0.29 3725 .10 3602.80 3329. 56 1749.26 5948895 .44 560610 .64 MWD+IFR-AK-CAZ-SC ~I 6502.61 89. 18 0.82 3725 .90 3603.60 3382. 23 1749.77 5948948 .10 560610 .73 MWD+IFR-AK-CAZ-SC 6550.90 87. 72 1.72 3727 .21 3604.91 3430. 49 1750.84 5948996 .37 560611 .43 MWD+IFR-AK-CAZ-SC I~ 6594.47 86. 37 1.40 3729 .45 3607.15 3473. 98 1752.03 5949039 .86 560612 .27 MWD+IFR-AK-CAZ-SC I, 6689.32 87. 69 2.47 3734 .37 3612.07 3568. 65 1755.23 5949134 .54 560614 .73 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit ! Site: Kuparuk 1J Pad Nell: 1J-127 ~Vellpath: 1J-127PB2 Survc~° -__ J1U Intl Atim TVD ! ft deg deg ft s "CVD ft S ft Uate: 7/20/2006 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation A~lethod: F,IW N1apN ft ft `l'ime: 09:15:47 Page: 3 WeII: 1J-127, True North 1J-127PB2 : 122.3 WeII (O.OON,O.OOE,O.OOAz+) Minimum Curvature Ub: Oracle 11apL Tool ! ft _ 6782.82 88.98 2.58 3737 .09 3614.79 3662 _ .02 1759. 34 5949227 .93 560618 .12 _ MWD+IFR-AK-CAZ-SC 6877.15 89.85 3.16 3738 .05 3615.75 3756 .22 1764. 07 5949322 .16 560622 .10 MWD+IFR-AK-CAZ-SC ! 6971.53 90.65 2.43 3737. 64 3615.34 3850 .49 1768. 67 5949416 .45 560625 .97 MWD+IFR-AK-CAZ-SC 7065.29 91.08 0.63 3736. 22 3613.92 3944 .20 1771. 17 5949510 .17 560627 .74 MWD+IFR-AK-CAZ-SC 7158.38 89.52 355.50 3735. 73 3613.43 4037 .20 1768. 03 5949603 .13 560623 .87 MWD+IFR-AK-CAZ-SC 7252.27 89.22 356.56 3736. 77 3614.47 4130 .86 1761. 53 5949696 .73 560616 .63 I MWD+IFR-AK-CAZ-SC 7345.58 87.36 356.22 3739. 55 3617.25 4223 .94 1755. 66 5949789 .75 560610 .04 MWD+IFR-AK-CAZ-SC 7438.71 87.74 357.11 3743. 53 3621.23 4316 .82 1750. 24 5949882 .58 560603 .90 MWD+IFR-AK-CAZ-SC 7531.99 87.49 357.51 3747. 41 3625.11 4409 .92 1745. 87 5949975 .63 560598 .80 MWD+IFR-AK-CAZ-SC ! 7625.19 91.90 359.59 3747. 91 3625.61 4503 .06 1743. 51 5950068 .74 560595 .71 MWD+IFR-AK-CAZ-SC 7717.98 90.39 359.59 3746. 05 3623.75 4595 .83 1742. 85 5950161 .49 560594 .32 MWD+IFR-AK-CAZ-SC ' 7811.88 89.84 359.29 3745. 87 3623.57 4689 .72 1741. 93 5950255 .37 560592 .67 MWD+IFR-AK-CAZ-SC ! 7905.61 89.66 359.43 3746. 28 3623.98 4783 .45 1740. 88 5950349 .07 560590 .89 MWD+IFR-AK-CAZ-SC !, 7999.44 90.03 357.46 3746. 53 3624.23 4877 .24 1738. 34 5950442 .83 560587 .61 MWD+IFR-AK-CAZ-SC ! 8092.95 89.47 0.47 3746. 94 3624.64 4970 .72 1736. 65 5950536 .29 560585 .19 MWD+IFR-AK-CAZ-SC 8186.92 89.04 358.61 3748. 16 3625.86 5064 .67 1735. 90 5950630 .23 560583 .70 MWD+IFR-AK-CAZ-SC !, 8279.88 89.85 0.82 3749. 06 3626.76 5157 .62 1735. 43 5950723 .16 560582 .51 MWD+IFR-AK-CAZ-SC 8373.84 88.79 1.30 3750. 17 3627.87 5251 .56 1737. 17 5950817 .10 560583 .52 MWD+IFR-AK-CAZ-SC 8467.23 89.66 0.05 3751. 44 3629.14 5344 .93 1738. 27 5950910 .46 560583 .89 MWD+IFR-AK-CAZ-SC 8560.93 89.66 356.82 3751. 99 3629.69 5438 .58 1735. 71 5951004 .08 560580 .59 MWD+IFR-AK-CAZ-SC 8655.20 87.11 357.91 3754. 65 3632.35 5532 .70 1731. 38 5951098 .16 560575 .53 MWD+IFR-AK-CAZ-SC !, 8748.68 89.48 359.75 3757. 43 3635.13 5626 .11 1729. 47 5951191 .54 560572 .89 MWD+IFR-AK-CAZ-SC ~! 8835.16 89.22 1.51 3758. 41 3636.11 5712 .58 1730. 42 5951278 .01 560573 .16 MWD+IFR-AK-CAZ-SC ! ~ 8933.75 89.47 2.13 3759. 54 3637.24 5811 .11 1733. 56 5951376 .55 560575 .52 MWD+IFR-AK-CAZ-SC I 9030.51 89.47 1.03 3760. 44 3638.14 5907 .83 1736. 22 5951473 .28 560577 .44 MWD+IFR-AK-CAZ-SC ', 9124.36 90.03 359.26 3760. 85 3638.55 6001 .67 1736. 46 5951567 .11 560576 .94 MWD+IFR-AK-CAZ-SC ' 9218.36 91.64 358.50 3759. 48 3637.18 6095 .64 1734. 62 5951661 .05 560574 .37 MWD+IFR-AK-CAZ-SC ~ 9312.02 89.58 359.37 3758. 48 3636.18 6189 .27 1732. 88 5951754 .66 560571 .90 MWD+IFR-AK-CAZ-SC ', ' 9400.62 87.17 359.90 3760. 99 3638.69 6277 .83 1732. 32 5951843 .20 560570 .64 MWD+IFR-AK-CAZ-SC ! 9499.54 88.12 2.52 3765. 06 3642.76 6376 .63 1734. 41 5951942 .01 560571 .95 MWD+IFR-AK-CAZ-SC 9592.76 88.67 2.03 3767. 67 3645.37 6469 .74 1738. 11 5952035 .14 560574 .92 MWD+IFR-AK-CAZ-SC 9686.32 86.80 0.75 3771. 36 3649.06 6563 .20 1740. 37 5952128 .60 560576 .46 MWD+IFR-AK-CAZ-SC 9781.05 87.00 1.45 3776. 49 3654.19 6657 .77 1742. 19 5952223 .17 560577 .54 MWD+IFR-AK-CAZ-SC 9874.82 87.74 1.57 3780. 79 3658.49 6751 .41 1744. 66 5952316 .82 560579 .27 MWD+IFR-AK-CAZ-SC ! ! 9968.09 86.50 0.23 3785. 48 3663.18 6844 .55 1746. 12 5952409 .95 560580 .01 MWD+IFR-AK-CAZ-SC !, 10061.35 88.18 359.29 3789. 80 3667.50 6937 .70 1745. 73 5952503 .09 560578 .89 MWD+IFR-AK-CAZ-SC ' 10100.00 89.12 359.43 3790. 72 3668.42 6976 .34 1745. 30 5952541 .72 560578 .16 MWD+IFR-AK-CAZ-SC i 10155.28 88.41 358.23 3791. 91 3669.61 7031 .59 1744. 17 5952596 .96 560576 .60 MWD+IFR-AK-CAZ-SC !, 10249.18 85.47 356.62 3796. 92 3674.62 7125 .25 1739. 96 5952690 .57 560571 .65 MWD+IFR-AK-CAZ-SC ~', ~i 10342.82 85.64 356.85 3804. 18 3681.88 7218 .46 1734. 64 5952783 .73 560565 .61 MWD+IFR-AK-CAZ-SC I i 10436.88 89.55 359.18 3808. 12 3685.82 7312 .35 1731. 39 5952877. 58 560561 .62 MWD+IFR-AK-CAZ-SC II 10530.53 93.63 1.14 3805. 53 3683.23 7405 .94 1731. 65 5952971. 16 560561. 15 MWD+IFR-AK-CAZ-SC '~ 10624.22 92.30 1.86 3800. 68 3678.38 7499 .47 1734. 10 5953064. 70 560562. 87 MWD+IFR-AK-CAZ-SC I~ 10718.42 91.12 0.64 3797. 87 3675.57 7593 .60 1736. 15 5953158. 84 560564. 19 MWD+IFR-AK-CAZ-SC II 10812.06 87.89 358.70 3798. 68 3676.38 7687 .22 1735. 62 5953252. 44 560562. 91 MWD+IFR-AK-CAZ-SC ! 10905.28 84.61 358.38 3804. 77 3682.47 7780 .20 1733. 25 5953345. 39 560559. 82 MWD+IFR-AK-CAZ-SC 10939.00 ! 84.61 358.38 3807. 94 3685.64 7813 .76 1732. 30 5953378. 93 560558. 61 PROJECTED to TD Conoco hiiii s Time Lo Summa g rY ~ ~~,~,e~. ~E~ an~~ Time Logs _ _ __ _ _ _ _ _ Date From To Dur 5. De th E De th 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 weIF2T-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 jib 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 well 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. fi'age 1 of 8T' -- - - - Time Logs -- - _ - -Date _ From To __ Dur S Dzptli E De th 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 26 pad w/ both the Rig module and the pit module. Arrive @CPF 2 @ 2000 hrs. Total 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 up hill 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 1.7:30 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. _ r agQ 2 of ~7 - -- Time Logs -- - -- Date From To Dur.. S. Tenth F.-Death Phase.... .Code... Subcode T COM 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 1 J-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 d ~ ~ S ~ ~ aT ~ acre 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. Page 3 0€ 7 Time Logs -- Qate From To Dur S~e fh E. Depth Phase CocJe Subcode T CG~M. 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. Will 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. Page 4 of 87 Time Logs- -- -- -_ _ ~___ flatP Frnm Tn flair ~ I~anth: F f)erthAhaaa l'nria ~iihrnrle T CnM 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 ROPE 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 wf jars). Establish care, 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. Sppg, 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' and 180'. _ Page 5 of 87 Time Logs __ _ _ _ _ Date From To Dur S~e Th. E. De th Phase Code. Subcode T COM 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 = 90T). 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. ~~~ 0 of 37 r-- - - -- ---- - --- -- -- ----- _Time Lo_ gs _ ____ _ Date_ From To Dur e th E. De th Phase .Code Subcod_e___ 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 13-1/2" 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 18:00 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. Page 7 of 87 - - -- - Time Loys Date From To Dur S. ~e Th. E. Qe th Pt:ase__ Code Subcode T CAM Page 8 of 87 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 ft/Ib for ue. 04:30 06:00 1.50 2,268 650 SURFA DRILL TRIP P Visual flow check, OK. POOH f/ 2268' to 650' @ 0600 hrs. Monitoring/filling 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. 06:00 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 j ars, 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. - ____- --- - - - Time Logs - --------- - ------- --- - Date From To _ Dur ______.~th E_Depth_ 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 CASIN( RURD P RU GBR casing tools to run 10-3/4" casin . 18:00 19:00 1.00 0 0 SURFA CASIN( 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 collar joint, follow w/ total of 51 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 CEMEf~ RURD P RU circulating lines to circ casing prior to cement 'ob. 00:30 02:00 1.50 2,258 2,258 SURFA CEME~ 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. R t 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. Ccmtinue reciprocating pipe 30' stroke @ 6 fit 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. Page ~ of ~7 Time Logs _ - - --- - -- - Date From To Dur S. e th E. De th Phase.. Code. Subcode T C(~M 05/19/2006 02:45 04:45 _ 2.00 _ 2,258 2,258 SURFA CEMEh 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 life (4.49 cu ft/sx yield) (water 20.569 gal/sx) weight 10.7 ppg. Pump @ 6.4 bpm w! 350 psi. Fal!©w w/ 64 bbls{130 sx) DeepCrete tail cement (2.46 cu ft/sx) (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 34bbls 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 wharf quit reci . 04:45 05:15 0.50 2,258 2,258 SURFA CEME~ DISP P Rig finish displacing cement w/ rig pumps @ 7 bpm w/ 9.0 ppg mud pretreated w/ SAPP, bicarb and desco, wirh 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. Approz 107 bbls of 10.9 ppg good cement circ to surface. 05:15 05:30 0.25 2,258 2,258 SURFA CEME~ 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 CASINC 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 WELCT NUND P Nipple down riser. Remove 20" diverter. Clean out flowline, Page 1 Q rif 87 - -- --- Time Logs -- ------ --- ------ Date Froi~i To Dur S e th E. De th Phase...... Code...... Subcode_T _ COA~1 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 f/ spill prevention. Inspec 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 WELCT 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 0.76 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 ROPE 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 WELCT 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 WELCT 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. i~s3CJE 1 t C7f ~7 -- --- -- - -- -Time Lo~c s . Date From _ To _ Dur e th E. De th Phase Code 5ubcode 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 0.75 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 CASINC 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. Pacae 12 of 87 Time Logs -- ---- - --- -- - --- -- -- Date From To Dur____~epth_ E Depth. Phase Code 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. Page 13 of 87,;, - ------- - --- -- Ti_m_e Logs _ _ _ _ ____ Date From _ .To Dur ~e th E. De th Phase Code Subcode T C,OM _ _ 05/21/2006 09:15 12:00 2.75 2,535 2,835 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 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'. ~'~~e 1A~ cif 87 --- _-- Time Logs __ ..Date From To Dur S e th E De th Phase .....Code Subcode T COM 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 . ~~ge 15 of ~7 Time Logs „.Date From To Dur ,,___ S. e Sh E. De th Phase Ccde- - Subcode T CUM 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' (317') (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 w17" 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 fUlb, 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 = 10.23 ~~€~e ~a of £37 _Time Logs ____ _ _ _ _Date _____ Frorn To____ Dur S epth E Depth Phase Code Subcode T CUM ____ ____ ____ 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 I NTRM1 DRILL PULD P RU & flush Drilling Assembly with water as er Directional driller. ~'~cJ~ 17 oaf 87 Time Logs __ _ Date From To _Dur e th E_Depth Phase___ Code Subcode 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 (6.9T), 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 3,112 INTRM1 CASIN< 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. P~qe 18 cf 87 -- -- Time Logs _ ___ Date From To Dur epth S E. De th Phase Code Subcode T_ OR 4_ 05/25/2006 02:00 04:30 __ 2.50 _ 3,112 3,112 INTRM1 CASIN _ ( RNCS __ NP _ Tag up at 3112' 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 Continue run 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 @ 481 T. 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 while 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 CEME(~ RURD P Lay down Franks Fill up tool. Make up 7 5/8" Cement Head & Lines. 11:15 13:45 2.50 INTRM1 CEMEf~ CIRC P Continue Circulate & condition mud @ 60 SPM - 6 BPM - 270 PSI. Clear & clean floorarea. LAy down Casing runnin E ui ment. 13:45 15:00 1.25 INTRM1 CEMEI~ 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 G Tail cement. Reciprocate casing string i strokes of 20'. Dro To Plu . 15:00 16:00 1.00 INTRM1 CEMEf~ 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. Pa~~ ~ 0 cf ~7 Time Logs .Date Froi~~ To Dur S. ~e tp h E Depth_ Phase Code _SubcodeT COM 05/25!2006 16:00 16:15 0.25 INTRM1 CEMEI ~ DISP P Bleed pressure and Check Floats. Floats held. 16:15 18:00 1.75 INTRM1 CEMEI ~ 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 OO:OQ 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 CASIN( 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 PSL 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 CASIN( 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 I NTRM1 CASIN( RURD P Breakout & lay down 5" Drill pipe from derrick. Crew chan e. 06:00 08:00 2.00 I NTRM1 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. ~~e 20 €~f 8? Time Low- - _ -- - - -- -- - - Date From To D_ur S. e th_ E Depth Phase Code Subcode 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 INTRMI 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 testjoint & 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 INTRM1 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 I NTRM1 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' . P~je 21 ofi87 --- Time Logs ___ -- Date _ ..From To Lour S...e th E. De th Phase Code Sut~code, T CUM 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 INTRM1 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 1977. 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 Ft/Lbs. 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 I NTRM1 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. Page 22 of $7, -- - Time Logs Da±e From _ To Dur S. e th E. De~Th..Phase......... Code Subcod__e_ _T COM 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 welt 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 caiccttat~d E(NW of 15.4 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. l~at,~. e 23 of 87 - Time Logs -- - - ------ --- ., Date From To Dur S e th E. Depfh-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, ROT WT = 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, 374T 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 Page 2~ cif ~7 Time Logs .,Date From To ____ Dur ST~th E. Depth Phase Code 5ubcode 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 = 5-10K, 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' M D, 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 PSf. #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 = 5-10K, 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. ..Page 25 of E~ ,Time Logs -- -- - - - _Date .From To Dur S. epth E. Depth _Phase Code _ Subcode T OM__ 05/30/2006 00:0© 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. Blow. down Top Drive & lines. Install 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. Page 2~ of 87 05/30/2006 10:30 12:00 1.50 9,533 9,627 PROD1 12:00 18:00 6.00 9,627 10,061 PROD1 --- - - ---- Time Logs --- Qate From To Dur- S. e th E. De th Phase - -- - --- -- __ Code___ _Subcode T CUA4 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. 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 Wage 27 of 87 Time Logs .,Date From To Dur epth S. E. De th Phase Code Subc~de T C,~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. ND = 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 - 31.00 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' ND, 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'e Observe kick off and inclination than 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. ND = 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' ND, 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 rage 28 of 37 Time Lo ~__ Date From To _ Dur 5._ epth E. Depth Phase C ode_ S~ibcode T C'JM_ 05/31/2006 06:00 __ _ 12:00 _ 6.00 10,402 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. Page ~~ of 87 Time Logs Date From _ _ To Dur S. !e th E. ~e th 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 (11.2T), 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. Page 34 of 37 Time Loc~__ - - Qate From _ To _ __D_ ur S. ?e th E De th_ Phase :Lode Subcode T OM 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. Pie 31 of 37 Time Loci -- - - -- Date.... Frcm To. Dur e th E De th Phase Code Subcode T t,QM 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. ND = 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. --- F'~ge ~2 of i37 Time Logs -- -- - _ _ _ _ _ Date From.. . To Dur S. e th. E.De th Phase Code Subcode T QOM - _- -- -- 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 33 of 87 Time Logs ~ _ Date Fror~i To Dur S. e th E Depth Phase Code Subcode T CQt:1 _ ___ ___J 06/03/2006 00:00 02:00 2.00 11,220 10,000 PROD1 TDRILL TRIP P Continue BROOH from 11220' - 10000'. Monitor well -static. Blow down Top Drive & lines. WWT rep on rig floor inspecting Super Sliders. All 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 PSIa 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. Page 3~ of r~7 - -- -- - ~ Time Logs -- - - - - ~ .gate. _ From To Dur _ S. ~~e~th E Depth P_h_ase_ Code Subcode T_ COM - -- - - _ _ 06/03/2006 14:30 16:00 1.50 11,997 11,990 PROD1 DRILL CIRC P Circulate hole clean, pumping 50 BBL 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. ~'~cJ~ 35 of f37 Time Logs rDate_ From To Dur eeth_ E_ Depth Phase Code Subcode T COM ______ __ _ __ 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 Blank joint (41.33'). Continue run 4 112" 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 perjoint 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( RURD 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 deriick. 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 . ~'a~ge 36 ~rf 87 -- - -- - -- _ --- Time Logs _____ Date From.... To Dur S. e th E De th Phase..:... Code... Subcode T 'Oti1 _- -- 06/05/2006 00:00 01:00 1.00 11,700 11,997 COMPZ CASIN( 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 Dryjob. 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 EVALV~ ELOG P Make up E-Line tools and WLIH from suriac~e to tag-top of ifner @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 EVAL11~ 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. 6~~g2 37 cif f37 TimeLo~s- ---- - ----.-------- Date From To Dur S.- e ±h EDe th Phase,.. Gode Subcode T UM - - 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 hole 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 WELCT ROPE P Test Bop's. Test 06:00 07:00 1.00 0 0 COMPZ WELCT 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 WELCT SFTY P PJSM on testing BOPE. 07:15 08:30 1.25 0 0 COMPZ WELCT BOPE P Testing BOPE. 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 BOPS P Re test lower BOP to 250 psi low and 3000 si hi h. Good test. Page 33 of 8~ Time Logs - - Date From To Dur S. e th E. De th _ - -- .Phase .Code Subcode T - 'QM - - - ----- 06/06/2006 12:00 14:00 . 2.00 0 0 COMPZ RIGMN SVRG T P Service top drive and rig. 14:00 14:45 0.75 0 0 COMPZ WELC7 OTHR P Pull test plug.. Drain stack. Set wear bushin . 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' seat 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 w/vis=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 . I"'ag~ 33 of,87 __ - ----- Time Logs _ _ __ I'-Date From To Dur S. epth E_ Depth_Ph~se 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 er 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 mech 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 perjoint). PU/MU Dail DNT mech 'ars. i='~c~e ~~3 of 87 Time Logs i ~ Date From.....,. To Dur S. e th E. De th Phase .Code Subcode T _ ~,OM 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 perjoint). 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 per joint). 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. ~acJe 4'i of ft7 - --- --- - -- - Time Lomas __ __ Hate ....From Tu Dur- _ S. Tenth _F (~ecth Phase..... Cede Subcode T OPr1 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 w/abi w/ 1.50 deg bend from 5389' -5610' (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 PP9• PWD baseline was performed white drilling @ 5542' w/8.7 PP9 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 PP9 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 617 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. i~~c~e ~2 of ~7 .Time Logs ~ Date From To Dur S. e th E De th Phase Code Subcode T 'OM _ _ 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' -674T (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' . ~~ge 43 cif 37 --- -- - - TimeLogs __ _ _ _ Qate _ Frorn _ To Dur S. ~e th _ _ E. De ih _ _ Phase Code.. __ Subcode T __ Ohl. 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') (ND = 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' -827T (399') (ND = 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' ND 9.6+ MW: #1 mp @ 20 spm = 600 psi, 30 spm = 950 psi SPR @ 8056' MD 3605' ND 9.6+ MW: #2mp@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' . l~~~ae ~f t~7 Tune Logs Date From Tq Dur S. _~e th E. Depth Phase Code _ code Sub T 'DM ,_ ___ _ 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, W0B=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' TVD) 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' TVD) to 9273' (383') (3, 644' TVD) 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'), 9005' 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'. P~c~e •~5 of ~7 ~ Time Lo s 9 -- - ----- - --- ---- - I pDate From - To - - -- Dur _ S. epth_E. Depth Phase Code Subcode_ T._ CQM-_ 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 951 T (244') (3, 650' TVD) Bit hours= 36.63, Jar hours= 88.15, AST=1.07, ART=2.55, ADT=3.62, WOB=8-15k, 70-90 rpm, Mtr rpm 211-215, 275-280 gpm @ 3400-3460. psi on bottom arid 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 unitso 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' (T), 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, WOB=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' (T), 9540' to 9553' (13'), 9568' to 9571' (3'), 9575' to 9578' (3'), 9584' to 9590' (6'), 9748' to 9753' (5'), 9765' to 9770' 5, . Wage 46 of ~7 - -- Time Lo s 9 --- - ----- -- -----_-- - - --- -- _ _ ____ Date Fro~~i To Dur S.» e th ~. Depth Phase_Code Subcode T_ COM __ 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, W0B=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 T , 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, WO6=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, WO6=10-20k, 90 rpm, Mtr rpm 210-223, 273-290gpm @ 3490-3750 psi on bottom and 3390-3480 psi off bottom. 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 l~ar~. ~ ~7 of ~~ Time Lois --- - - - -- - -- - ------ --- ___ __ Qate .From To Dur S. e th E. De th :Phase Code Subcode T .OM 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, WO6=10-15k, 90 rpm, Mtr rpm 216-223, 280-290gpm @ 3650-3750 psi onbottom 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'ND). 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' 17' . Page dS ~f t37~ Time Logs _ Date From To Dur S. e th E De th Phase Code Subcode T 'OM 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 40777. (94') (3661' TVD) Bit hours= 64.07, Jar hours= 115.59, AST=.38 hrs, ART=1.2 hrs, ADT=1.58 hrs,. WO6=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' . P~~e <~=3 of F§7 - Time Loys -- - - ~ ~ date From To Dur S. e th E. De th Phase .Code..... Sutacode, T QM __ - 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' S' . 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, W0B=4-10k, 90 rpm, Mtr rpm 213, 277 gpm @ 3746-3780 psi on bottom and 3620 psi off bottom. 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'j (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 = 1.70-175k, 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 1123T 4' . ~~ar~e tai ref 37 Time Logs - - ------- ---- - -- - - ---- - --- - -- - ~ ~ Date From To Dur S. e th E De th Phase Code Subcode T _ _ _____ _ 06/13/2006 _ 12:00 18:00 6.00 11,262 11,593 PROD2 DRILL _ DDRL P Drilling "B" lateral from 11262' (3714' TVD) to 11593' (331') (3685' TVD) 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' TVD) Bit hours= 78.39, Jar hours=129.91, AST=.22 hrs, ART=3.42 hrs, ADT=3.64 hrs, WOB= 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' . ~aq~ ~1 of II7 Time Logs Date From To Dur S. eptf~ E. De th Phase C,cde Subcode _ T GOM _ ___ 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' ND) Bit hours= 83.24, Jar hours=.134.76, AST=.45 hrs, ART=4.4 hrs, ADT=4.85 hrs, WOB= 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' ND) Bit hours= 84.02, Jar hours= 135.77, AST=.00 hrs, ART=1.01 hrs, ADT=1.01 hrs, WOB= 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' ND) to 7707' (3602' ND) @ 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. Page S:? of ~7 ------- ---- -- Time Logs __ ___ natP Frnm Tn flair ~ flPnth F (-lr~nth PhacP (~nria ~iihGnC}.P... T ~n~l~ 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 (/.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-vas (131 seGgt) 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 kelly/Top 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'. P~g~ ~~ of °7 _Time Logs _ ___ _~__ __ _ _ ____ Date From To Dur `~.-Ue th E. De th Phase Code . Subcode 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 f13373' 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 wl 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 rior 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' . Page 5~ a~f ~7 - ~ --- -- Time Logs _ _ Date From To Dur S. e th E.-De th Phase Code 5ubcode T CAM __ 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" linerjts(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 61 hook hanger. Orient to hook hanger. Line up hook han er to S e Sun MWD. 08:00 08:15. 0.25 6,582 6,612 COMPZ CASIN( OTHR P MU Baker B1 Hook Hanger Hook Han er w/ runnin 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 PU 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 18:15 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. ~~ ' Pale s~ cf H7' Time Logs Date From To Dur _ __S. e th E: D~th Phase ...Code -Subcode_T COf~4 _ 06/17/2006 16:15 17:00 0.75 11,961 11,961 COMPZ CASIN( CIRC P Drop 29/32"ball, slack off 40k. 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. lie 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 CASIN( 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 IBT-M, CamcoDB-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 PROD2 CASIN( 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'. i Page ~~ ~rf 87 _Time Logs . Date From To Dur 5 e nth E Depth Phase Code- Subccde T CG~M, __,_ _ _ _ 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( DHEQ 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 bbls. 12:15 12:30 0.25 5,496 5,496 PROD2 CASIN( SFTY P PJSM on pulling ouf 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 18:00 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 a foot 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'. laage r7 ~f 37 Time Logs --- - - - - Cate Fro~~i 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 perjoint 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 10:30 025 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~~e 5& o~f s~7 - --- - - - - I T e Logs ~ Uat4 From To Dur S.< epttl- E De th___Phase Code Subcode T ',QM __ _ 06/19/2006 19:15 19:30 025 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 BOPE 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 lu . 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. ~'~ge a9 of r7 Time Log s- --_ -- _ _ __ -- -- -- -- Date From To Dur Se~th _E Depth Phase Code Subcode T OM 06/20/200 6 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 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" 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 = 351 T. (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 ~~ge b,~ of ~7 Time Low ___ _ _ Date From To Dur S. e th- E. De th Phase .....Code Subcode T GOM 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 Directionaldrill 6 314" 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 @ 3-4Ka 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 ~~ge 61 crf ~7 Time Lois ___ _,_ _ ..,.Gate Fro~1~ To Dur S.- e th E. De th Phase Cedz Subcode T l.GA4 __ __ __ 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 PSI. #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 P~~e a2 of 87 Time Logs ~ I From Dat To Dur 5.. ,P th_ E. De th Phase Gode Subcode. T QOM __ 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 PSL 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. Page ~:3 of ~7 ~ - Time Logs _- _._ - _ __ Date From To Dur S. Depth E. Dc tf 1 Phase Code-< Subccde , T CC~h1. __ ____ 06/23!2006 00:00 06:00 6.00 9,395 _ 10,107 _ PROD3 _ 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 PROD3 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 PSI. #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 avers a thickness of 6.9 ft each. 11:00 12:15 1.25 10,436 10,436 PROD3 DRILL CIRC T Decision to POOH. Circulate Bottoms upwith pumps at 72 SPM - 2870 PSI. Reciprocagte & rotate drill string with 130 RPM's , UP WT = 122K, SO WT = 114K. 12:15 12:30 0.25 10,436 10,436 PROD3 DRILL OWFF T Monitor well -static. 12:30 12:45. 0.25 10,436 10,219 PROD3 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 PROD3 DRILL TRIP T Screw into Top Drive, and break circulation. Pump dry job, blow down To Drive and all lines. Time Logs _ Date From To D ur 5:.,epth EDe th Phase Code Subcode T ~C~M --- 06/23/2006 13:00 _ 18:00 _ 5.00 10,219 1,595 PROD3 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 PROD3 DRILL TRIP T Continue POOH on elevators from 1595' - 92'. Observe well 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 PROD3 DRILL PULD T Plug in and download MWD assembly. Pull up & breakout, lay down & inspect bit. Bit Graded at 2 / 2 / BT / A / X / I / PN / DTF. bit will be rerun. 20:30 22:30 2.00 92 0 PROD3 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 (1127'). Clear & Clean Ri Floor area. 22:30 00:00 1.50 0 92 PROD3 DRILL PULD T Held PJSM with crew. Discuss Safety Issues and procedure for making up BHA #9. 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 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" Inte ral Blade Stabilizer 4.58' . 06/24/2006 00:00 03:00 3.00 92 92 PROD3 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 PROD3 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 PROD3 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 PROD3 DRILL TRIP T Continue trip in hole from 4970' - 7215'. Fill drill string every 25 stands. Blow down To Drive & lines. ~~ Page 6~ ref 87 Time Logs Date From To Dur__ S_ . 'e th €. De th .Phase Ccde Subcede T QOM 06/24/2006 07:30 08:45 1.25 7,215 7,228 PRODS DRILL TRIP T Set bifidepths & 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 PRODS DRILL OWFF T Monitor well -static. Mix dry job for POOH. 09:00 11:45 2.75 7,228 284 PRODS 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 PRODS 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 PRODS 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 PRODS 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 PRODS DRILL TRIP T Trip in hole from 284' - 377'. Screw into To Drive. 14:30 14:45 0.25 377 377 PRODS 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 PRODS 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 PRODS DRILL TRIP T Continue TIH pumping up surveys at depths of 5527, 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 PRODS 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 PRODS 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 PRODS 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'. Pane ~r6 of f3? --- _- - --- - --- Time Lo sc~ -- ---- --- - -- Date From ToDur____S. e th E pe~th Phase Code:,_ Subcode T CC?l~-1 __ _ I 06/24/2006 23:00 23:30 0.50 10,400 10,436 PRODS 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-SK, 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% 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. P~qe ~i7 ~f 87 - I Time Log _ -- - - - ~ ~ Date _ From_ To_ ___ Dur S,_ epth E_ De th Phase Code Subcodc T ~~OM__ 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 . Page ~3 of 87 Time Logs _ From -Cate To Dur S. ' epth E Depth Phase Code Subcode T _ COM __ 06/26/2006 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 upon 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 FUmin. 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 FUmin. 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 FUmin. 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 . ~'~ge ~9 ~f 87 Time Logs Datz ___ From To Dur S. e th E. Depth Phase Code Subcode_T C,QM 06/26/2006 20:00 23:15 3.25 4,970 4,970 PROD3 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 PROD3 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 PROD3 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 PROD3 RIGMN RGRP T Continue rebuild Top Drive Shot pin assembl .Install & test same. 01:30 01:45 0.25 4,970 4,970 PROD3 RIGMN SFTY P Held PJSM with crew. Discuss Saftey issues and procedure for slipping & cutting drilling Line. Discuss new hands on crew. 01:45 04:00 2.25 4,970 4,970 PROD3 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 PROD3 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 PROD3 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. PROD3 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 PROD3 DRILL CIRC P Circulate & condition hole while reciprocating & rotating drill string. Pum 300 GPM - 3500 PSI. 1.2:00 13:15 1.25 12,227 12,227 PROD3 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 PROD3 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. huge 7D of ~7 ~Time_Lo~- _ _ _ _- -- ____--- ~ Gate From To Dur S. _ e th E Gc th P};ase Code Subcode , 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 assebly. 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 & grade bit @ 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 Continue 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 = 117.7T, 02:00 02:15 0.25 117 211 PROD3 DRILL TRIP P Trip in hole with BHA #12 from 117' - 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 . ~'ae 71 of 87 --- Time Low _ _ Date From To Dur S epth E_ De th Phasc Codc Subcode _ T _ COM __ __ ____ 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 07:15 125 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 (7.87'), 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'. ~~ e ~ P:~rJe 72 of 87 ___ _ - -- 'Time Lois __ __ From To Dur S: cpth E Depth Date Subccda Phase Code T COh~1 _ __ __ _ 06/28/2006 19:45 21:00 1.25 5,082 5,082 PROD3 _ 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 1 OK 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 PROD3 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 whipstock. Discuss options with BOT rep. Decision to RIH with Retrieving Hook for run#2. Inspecf 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 drilF string evry 25 stands. Observe ro er hole fill. Page 73 of ~7 Time Logs --- - - -- _ --_-- --~ Date From To__ --- Dur S. Depth, E_ Depth Phase _ _-- Code_ -- SUbcodc T COf~~ 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 @ 5087 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 than 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. l~~c~e T~ at 87 - -- _ -- - -- - Time Logs Date from To Dur S. e th E De th Phase Code Subcodc T CUM _ __ 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 & lay 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. i~~ge T~ of ~7 Time Lo s Date From To Dur ~e th E. De th Phase Code Subcode ,OM 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 (7.8T), 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. ~~ I'~~e T ~ ref 87 - - _ _ _- Time Lo s th Date From To D ur S: De th E. De Phase :..Cede- Sut;code T Oh~9. _ 06/30/2006 _ 09:15 09:30 _ 0.25 D _ 312 PRODS -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 (7.8T), 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 PRODS 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 PRODS 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 PRODS 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 PRODS FISH TRIP T POOH from 5089' - 312'. Observe ro er hole fill 15:45 16:00 0.25 312 0 PRODS 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 PRODS 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 (7.8T), 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 PRODS 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 PRODS FISH TRIP T Continue trip in hole with BHA #7 from 2681" - 5084'. Observe proper hole fill, fiflin drill strip on bottom. 20:00 20:15 0.25 5,084 5,084 PRODS FISH FISH T Make Top Drive Connection. Obtain parameters. UP WT = 170K, SO WT = 150K. Pum s 26 SPM - 270 PSI. P~~e ?7 cif 87 Time Logs - --- _ __ ..Date From To Dur epth E_ Depth Phase Code Subcode_ _T OM 06/30/2006 20:15 22:00 1.75 5,084 5,099 PRODS 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 the first 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 PRODS FISH TRIP T POOH from 5084' - 339'. Observe ro er hole fill. 07/01/2006 00:00 00:15 0.25 339 0 PRODS 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 PRODS 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 PRODS RIGMN SVRG T Rig up, Slip & cut drilling line. Inspect brakes,. Service To Drive. 02:45 03:30 0.75 0 320 PRODS 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 PRODS 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 PRODS FISH TRIP T POOH from 1441' - 320'. Observe ro er hole fill. 05:15 06:00 0.75 320 0 PRODS 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 PRODS 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 PRODS RIGMN SVRG T Service Rig. Greasing draw works, etc. Retrieving Hook being sent from Deadhorse Sho . Page T3 s~f P7 Tune Logs Date Fro m_ To__ Dur _5_ _~epth E_ Depth Phase ___Code Subcode ,OM _ __ 07/01/2006 07:00 07:15 0.25 0 0 PROD3 FISH SFTY T Held 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 ON!! 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'. acre 79 at II7 Time Log s ---- ~ Date - _ _ From To Dur e~th E. De th _ Phase Code Subcode ~~OM 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 dama 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 = 311.47'. 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. rage ~Q ©t 87 - - Time Los _ Hate Fmm Tn nur S e~~th F neoth Phase Cn~ie ~ubc~~ie T ~;C~M 07/01/2006 22:30 00:00 1.50 5,074 5,177 PROD3 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 PROD3 FISH CIRC NP Monitor well-"static. 00:15 02:45 2.50 5,177 311 PROD3 FISH TRIP NP POOH from 5177' - 311'. Observe ro er hole fill. 02:45 03:30 0.75 311 0 PROD3 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 (7.8T), 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 PROD3 FISH PULD NP Clean & clear rig floor area, send tools out. 03:45 04:15 0.50 0 349 PROD3 FISH PULD NP Make up BHA # 11. Dummy seals. Make up 4 3/4" Seals (3.2T), 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 PROD3 FISH TRIP NP Trip in hole with BHA #11 from 349' - 3440'. Observe Proper Hole fill. Crew Chan e. 06:00 07:45 1.75 3,440 5,142 PROD3 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 PROD3 FISH FISH NP Obtain Parameters. UP WT = 175K, SO WT = 150K, Pumps @ 85 GRM'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 PROD3 FISH TRIP NP Monitor well -static. No fluid lost while um in . 09:00 11:30 2.50 5,177 349 PROD3 FISH TRIP NP POOH with BHA #11 from 5177' - 349'. e~ E'~~}e 81 of II7~ Time Lo s Date From To Dur S. egtt; E Depth Phase Ccde _ Suhcede T COM 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 (.6T), 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 merit 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. r ~a~e 32 of E37 Time Lo~c s Date From To Qur S. e ~±h E. De th Phase Code.... Subcode T _ _ ,OM 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 3.25 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 PRODS 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 . P~pP 8:3 caf 37 -- - _ __ Time Logs -- - - _- - --- --- Date__ From To Dur epth E De th Phase Code Subcode T UM f 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 (6.31 T). 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 pressures. 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 CASIN( 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. Pull 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 RPCOh 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 RPCOti 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 RPCOh RCST P Continue RIH w/ 4-1/2" 12.6 ppf L-80 I BT com letion f/ 4700' to 5058' ~~g~ £t~ ofi ;7 i~e Logs _ 'Date From To Dur e th E De th Phase Code Subcode i OM 07/04/2006 08:30 09:15 0.75 5,058 5,058 COMPZ RPCOh HOSO P Space out. UD 3joints, 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 RPCO( ti 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 drillers 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 ~' age ~~ cif 37 Time Logs __ _ _ _ _ _ _ .Date From To Dur e th E. Depth Phase Code Subcode l _.~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 wl 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 L/D 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'a€~e ~~ of 87 --- Time Logs Date From.. To Du_ r ~e th ,_E. De th Phase Code... Subcode -I 'OM -- - -__ 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 WELC7 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 RPCOti 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 7-5/8" annulus, taking returns throu h o en slidin sleeve 4983'. 06:30 08:30 2.00 0 0 COMPZ RPCOti 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 RPCOh 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 Pepe t37 of ~7 08/09/06 Sehberger ~~~~ NO. 3910 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,`,vC ~ 0 2006 -?.'~~ ~~ ;~ Gas ins. C~mmissi~r~ ,arc~tGrage Well Job # Log Description Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1J-127 11216302 USIT 06/05/06 1 1 D-119 11249924 INJECTION PROFILE 07/05/06 1 2L-321 11235382 LDL 07/24/06 1 2V-13 11235385 SBHP SURVEY 07/26/06 1 1Q-13 11249936 INJECTION PROFILE 08/02/06 1 1Q-26 11249937 PROD PROFILE W/DEFT 08/03/06 1 1R-14 11235386 PROD PROFILE W/DEFT 08/03/06 1 1G-09 11249938 INJECTION PROFILE 08/04/06 1 3N-16 11235389 SBHP SURVEY 08/05/06 1 1E-112 11285935 MEM INJECTION PROFILE 08/05/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Re: 1J-127 A Lateral Geo]ogical Sidetrack PB~ Subject: Re: IJ-127 A Lateral Geological Sidetrack PB2 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, OSJun 2006 14:13:41 -0800 7'0: "Reilly, Patrick .i" ~-Patrick.J.Reil]~'i~r~conocohhilli~~s.com~~ Thanks Pat. I will put a copy of this message in the file. Tom Reilly, Patrick J wrote, On 6/5/2006 1:27 PM: Tom, Here we go again. The details of the sidetrack are as follows: • Well: 1 J-127 • Rig: Doyon 15 • Date: 6/2/06 • Time: 0115 hrs • Last Casing: 6,428 • MD of abandoned section: 10,620' - 10,939' ~o~-o w~ We exited the top of the formation due to geologic uncertainty. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. If you need any additional information please contact me. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907} 265-1535 FAX Patrick.J. Reilly(c?conocophillips. com «Patrick.J.Reilly(c~conocophillips.com.vcf» 1 of 1 6/5/2006 2:14 PM Re: 1 J-127 A Lateral Geological Sidetrack PB 1 Subject: Re: 1J-127 A Lateral Geological Sidetrack PBl From: Thomas Maunder <tom maunder cr,admin.state.ak.us> Date: Wed, 31 1\1av 2006 14:5:1:16 -0800 'Tv: "Reill~~, Patciek,I" < 'atrick.J.Reilly«t;conocohhiliips.cc~m~~= Hi Pat, Thanks for the information. Your plans are appropriate. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 5/31 /2006 2:46 PM: Tom, The details of the sidetrack are as follows: • Well: 1 J-127 • Rig: Doyon 15 • Date: 5/31 /06 • Time: 0530 hrs • Last Casing: 6,428 ', MD of abandoned section: 10,100' -10,373' .] ~o~-o~~ We exited the top of the formation due to geologic uncertainty. We made a low side sidetrack. We are planning to isolate the sidetrack by allowing it to collapse. If you need any additional information please contact me. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilly(t~conocophillips.cam «Patrick.J. Reilly~conocophillips.com.vcf» 1 of 1 5/31/2006 2:54 PM Re: 1J-170we11-diverter regulation waiver Subject: Re: 1J-170we11- diverter t-c~ulation waiver From: Thomas Maunder ~~_to~rl maunder~cr.admin.state.ak.us> Date: Thu. ?~ I4lati 'OU6 U9:=18:3ti -0~!)0 To: "Nu~cnt, Davicl Arnold" David.A.Nu~entra'conocophillips.com= c~~ "-~~ David, ~~~ P~ ~~ With all the improvements and tight spacing on the new pads, avoiding conflicts is difficult. I understand the intent of angling 141's diverter line away from 15's rockwasher. From your description and the drawing, the "bend" does not appear to be abrupt. Dramatic changes in direction are of concern if the diverter were to be needed. The angled layout you propose is acceptable. Again, a copy of this message should be available on both rigs. Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 5/25/2006 8:46 AM: Tom, We had to make a change on our diverter drawing we sent you the other day. We found out it was longer than we thought, and we decided to angle it away from the rock washer for Doyon Rig 15. I attached the new drawing showing the diverter line for Doyon 141 for the 1 J-170 well. We have about a 15 degree bend in the line. We are requesting a waiver as before. We should. be releasing Doyon 141 around 1800 hours today to move to the 1 J-170 well. I will call you shortly to discuss. Thanks. David A. Nugent -----Original Message----- from: Thomas Maunder [mailtoaom_maunder@admin.state.ak.us] Sent: Wednesday, May 24, 2006 8:45 AM To: Nugent, David Arnold Subject: Re: 1J-170we11 -diverter regulation waiver David, It is acceptable to site the rigs as you have diagrammed. The "encroachment" is small and you have a contingency plan in place for communication and coordination between the rigs. Also, as you note gas has not been seen in the surface holes of the wells recently drilled on 1 J. A copy of this message should be sent to both rigs. Call or message with any questions. Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 5/22/2006 4:46 PM: 1 of 2 5/26/2006 7:09 AM Re: IJ-170we11-diverter regulation waiver Subject: Re: 1J-171)~~-ell -diverter regulatiotYwaiver From: Thomas Maunder 'tom maunder~a!.admin.state.akus? Date: Wed, 24 i\Tav ?i)O(; i)~:.~~:?0 -0`~OU To: "Nugent, David <<lrnold" <David.A.~ugcnt(~r~.conocophilli~s.com> David, ~~~~~ It is acceptable to site the rigs as you have diagrammed. The "encroachment" is small and you have a contingency plan in place for communication and coordination between the rigs. Also, as you note gas has not been seen in the surface holes of the wells recently drilled on 1 J. A copy of this message should be sent to both rigs. Call or message with any questions. Tom Maunder, PE AOGCC Nugent, David Arnold wrote, On 5/22/2006 4:46 PM: Tom, We will be moving the Doyon 141 rig to the 1J-170 location in the next few days (Permit number 206-062).. I am attaching a drawing of how Doyon 141 and Doyon 15 rigs will be situated on the 1J pad. Doyon 15 is currently drilling the 1J-127 well. The red circle on the drawing between Rig 141 and Rig 15 is a 75' radius circle centered at the end of the diverter vent line from Rig 141 when the rig is on location ready to drill the 1J-170 well. Regulation 20 ACC 25.035 (c) (1) (C) (i) states that the diverter vent line must extend to a point at least 75 feet away from a potential source of ignition. As seen from the drawing, the vent line from Doyon 141 is at least 75 feet away from Doyon 15 everywhere but on one corner of the rig. However, it does barely touch the corner of Doyon 15, and we request a waiver of this section of the regulation so Doyon 141 can work from this location. We have drilled 8 wells from the J pad and have seen no evidence of gas in the surface hole portion of these wells and are not expecting any gas in the surface hole of the 1J-170 well. We have phone communication and radio communication between the two rigs, and Doyon 15 would be notified immediately if the 1J-170 well was put on diverter. If you have any questions, please contact me. I will be at the Doyon 141 rig tomorrow, and can be contacted via a-mail or cell at 244-5946. I will be back in the office on Wednesday. «1J Site Plan June 1.pdf» Thank you. David A. Nugent Staff Drilling Engineer ConocoPhillips Alaska 907-265-6862 (office) 918-662-6886 (fax) 1 of 1 5/24/2006 8:53 AM vos• o• ~ ~ .~..,. ~, ......moo l J ~~ ° ~ _ _ ,i ! ~.~ ,. ~ I'. II 1, 11 - I ,~ x e.ao ~! ~.r ~ I ~~~ _ ~ Doyon DAIIIng Rig #141 ~ 1 ~ ~ i Sole, ANSI B Sla: n' • e01N1 ''®I r_ - ~~~ I stele. aNSlo sla: l•. eB e»r - ,e... I _.r I ;. 1 ~ ~ ~ ~ e e.ro . . ® I I ~~ ~ _. ® ~ j ~ '--- a I ~I a 9.00 s ~ a ~~ , a ,, I ~ I ° ..~ ' ~ d! • ~ _ ...... ~_~~ r_. ..«. I _o........... __....; * ~, I ~ b..a... ,.oe i i I •I ----ns ~- - .... ~ y (~ ~ .~9 Doyon Drilling Rig #15 ~^._ >. y " 0 . ~,-..e '.. Scats, ANSI B Sla: X' • b MI a ~ 14r1an6(( ~ i sw.. aNSlBSiu: r.ao l..r ~ff2 01..,,4.. i ~{ T >.,n ~..~..,1 T.. ~~, ... ~M° s +.ao 0.r,..ru<,.n - .. p. e,. M T t Om;~. eo. 5 ~_ Rp u1 0 i wlu,ln ~~~~.~ Legend .. y s ~.°° j ' ~. Bw stial ,~~.~a ,.mld.„ Cordudor i. s•r • nl. - R~i'y z a .uree ~ aemlere o Green SManO IMk.ba ~ ~ ~ ~ ~ _ e ..pp w.u N Gml.a ~""'~"''~ ' C'rWCNUm.nl nticasa I ^ .Ili $ O Rq 1.1 DreBp ON.r ~}'~_~.~~•• usi Greta LNbr rtWC.Ya ~ ~ S e•oe Ry 15 OriBiB OrC.r L ,:a;a..m. n,~; • vsu.lypal. ~ (7 ~ ~,.,,,, -- roome.~r-r _~ Gam,:.-.>:.,..L aeo.. aaa •~.awuadl 1:..~._t.~ ~(a..taM ~ S e.ee I I I S ).Oe ~- ~acfNortFi ~ ~ I ~U9999 oe9aea.ea dwervonm ~~~~~ I I _~I €~ ~ s e.o9 51a ~ ~~ ~ . JI; I 31 I ;I~ I 0 75 150 225 J00 , ~ r-sa n a~sz n~ . Scale: __ _ ANSI B: 1/2 inch = 75 ft ANSI D: 1 inch = 75 R conaocron m a.r ror aen.m«;n d.cx rots ~' corou<m..»m,p m ama,. a. a..a an.a.e ~ w.an. .. - „ .. Comowe.a aes b» aea am« ah.eae nYSd.w. `/ 1J Pad West Sak Drilling ConoeoPhillips June 1, 2006: Rig 141 on 1J-170, Rig 15 RaCarstl BY Sfew~ilNkK:. :~ fi Srm Opt Sds Ran Curnnr. vad on 1J-127 ~~°°° Alaska DrIIH oraer or 1/17105 1W. 1V-'TV JUl1Ul.l. Vlitlll.ll L--1L-1 J'T GJ WC~11~ • Subject: RE: 1D-40 Surface Cement--1D-134 as well From: "Reilly;Patrick J° <Patrick.J.Reilly rz~conocophillips.com> Date: Fri, 07 Apr 2006 14:36:40 -0800 To:Thomas Mau7lder<tommaunder car adnlin.state.aka~s> Tom, I have reviewed the records. The details from the operations summaries and cement reports indicate that both 1D-40 and 1D-134 had good returns throughout the cement jobs and cement to surface. I have compiled the reports and highlighted the information related to the cement jobs. I have edited the documents to remove proprietary contractor data. My schedule for this afternoon is full. I will follow up on Monday with electronic or hard copies of the documents. Thanks again for your help. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Pa~,ricic. J. Reilly:~~,~conorophiiii,>s . c;om ~S ~~~~t VF ~7~ ~~ ~`\rc.S ., -----Original Message----- From: Thomas Maunder [maiito:t:om maunder:~.adrrin.state.ak.~s] Sent: Thursday, April 06, 2006 10:13 AM To: Reilly, Patrick J Subject: Re: 1D-40 Surface Cement--1D-134 as well Pat, Could you also provide information on 1D-134 as well? The summary is about as thin as for 1D-40. Thanks much. Tom Thomas Maunder wrote, On 4J6/2006 10:06 AM: Pat, I am reviewing the close wells to 1J-127. Would it be possible to get some "detailed" information on the surface cementing operations for 1D-40. That is the casing that would be across the west Sak. The information submitted with the completion report is pretty brief. No problems are indicated, but interpretation is difficult when all that the summary says is "Run 9-5/8" casing. Break circ @ 2300' & 4300', good returns. Finish running 9-5/8" casing with shoe @ 6978', FC @ 6897'. Circulate and condition mud for cement job. Held PJSM. Cement 9-5/8" casing. N/D diverter system." It is noted that they drilled soft cement and wound up running a RTTS to test the casing. Formation test once out of the shoe looks OK at 13.8 EMW. Thanks for your help on this matter. Tom Maunder, PE AOGCC 1 of 1 4/10/2006 12:13 PM 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 • ALASFiA OIL AIQD GAS CO1~IS~RQATI011T COl-Il~'IISSIOIQ Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 ',~~ FRANK H. MURKOWSKI, GOVERNOR r~ ''i 333 W. 7"' AVENUE, SUITE 100 f ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-127 ConocoPhillips Alaska, Inc. Permit No: 206-047 Surface Location: 1739' FSL, 2324' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 51' FSL, 579' FEL, SEC. 23, T11N, R10E, 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this~day of April, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips r Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com March 31, 2006 d' MAR ~ ~ zoos ,AI~S@c~ ~5.4~~~ ~ ,~ ~ ~0;; ~~. ~08~;r'~'p~''18@ z"~~~~r Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injectors, 1J-127, 1J-127L1, 1J-127L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a trilateral ' horizontal well in the West Sak "A2", "B"and "D" sands. The main bore of the well will be designated iJ- 127, and the lateral bores of the well will be designated 1)-127L1 and iJ-127L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-127 is April 17, 2006. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION !~'- PERMIT TO DRILL ~~t~ 20 AAC 25.005 1 a. Type of Work: Drill Q - Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service ^/ ~ Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: .r Blanket Single Well Bond No. 59-52-180 , 11. Well Name and Number: 1J-127 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12090' ND: 3869' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1739' FSL, 2324' FEL, Sec. 35, T11 N, R10E, UM ` 7. Property Designation: ADL 25661 & 25650 West Sak Oil Pool ' Top of Productive Horizon: ~ 280' FNL, 574' FEL, Sec. 35, T11 N, R10E, UM ;. 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 4/17/2006 Total Depth: 51' FSL, 579' 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-40A , 1042' [~ 6000 16. Deviated wells: Kickoff depth: 1600 '' ft. Maximum Hole Angle: 96.6° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1741 psig ~ Surface: 1315 psig ' 18. Casing Program S if ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including 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 5617' 6472' 3732' ~ 12089' ~ 3869' 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 Conductor/Structural Surface Intermediate Production ~ ~j @0 ~?~ ~ °°' ~,, :_~, Liner o Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch ^ Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and cerrect to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~~,;_; ~ `~~"~!`~~,> Phone "Li, ~` ~ ~,} ~ Date '~ /3 i /p~ P h n AlI D Commission Use Only Permit to Drill ,~, / Number: ~ -'C.~' ~ API Number: ~T L 50- ~ Z.9 ' Z ~ ~c,.~ p "~ Permit Approval Date! See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed met ane, gas hydrates, or gas contained in shales: M~~~ ~~~G~``~ ~©~ Samples req'd: Yes ^ No ud log req'd: Yes ^ No []~ Other: C~H2S measures: Yes ^ N ct nal svy req'd: Yes [/~ No ^ 3dn ~ @so ~CjP ~~ ~-c>-s ~ \cir~-cJ _~~s O~ APPROVED BY THE COMMISSION DATE: JJ ,COMMISSIONER i Form 10-401 Revised 12/2005 ' ~ ~ ~ Submi in Duplicate • ~ation for Permit to Drill, Well 1 J-127 Revision No.O Saved: 31-Mar-06 Permit It -West Sak Well #1J-127 •~°~ r.^ +~l App/ication for Permit to Drill Document '1~~cW~ll F1ldximixg V~ell Value Table of Contents 1. Well Name ............................................................................................................:.... 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ........., ......................................................................................... 2 Requirements of 20 AAC 25.050(b) ............................................................. ................. 3 3. Blowout Prevention Equipment Information ................ .................................... .... 3 Requirements of 20 AAC 25.005(c)(3) ..........................................:........................................................ 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ..................................................................~--~-~----....................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals ........................................... 5 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 ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 1J-127 PERMIT IT Page 1 of 8 Printed: 31-Mar-06 • ~ation for Permit to Drill, Well 1J-127 Revision No.O Saved: 31-Mar-06 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c) (13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) .............................................._................................................. 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ............................................................................................................... 8 Attachment 2 Drilling Hazards Summary .............................................................................................. 8 Attachment 3 BOP Schematic .........................................................•--.................................................... 8 Attachment 4 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 5 Well Schematic ....-•-• ..........................................•-••--••--•--................................................. 8 Attachment 6 % Mile Radius Effect for Injector ..................................................................................... 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each weA/ must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2tI AAC 25.040(b). For a we// with multiple wef/ branches, each branch must sr`milar/y be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-127. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dril! must be accompanied by each of the fo/fowing items, except for an item already on file with the cammission and identified in the application: (2) a plat identifying the property and the property`s owners and showing (A)the coordinates of the proposed location of the we/l at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (8) the coordinates of the proposed location of the we/l at the sun`ace, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the Natiana/ Oceanic and Atmospheric Administration; (C) the proposed depth of the wet/ at the tap of each objective formation and at total depth; Location at Surface 1739' FSL & 2324' FEL -Sec 35 - T11N - R10E ASPZone 4 NAD 27Coord/nates RKB Elevation 121' AMSL Northings: 5,945,552 Eastings: 558,887 Pad Elevation 81' AMSL Location at Top of Productive Interval West Sak °A2" Sand 280' FNL & 574' FEL -Sec 35 - T11N - R10E ' ASP Zone 4 NAD 27 Coordinates Measured De th, RKB,' 6,472 Northings; 5,948,826 Eastings: 560,608 Total ~ertica/De th, RKB: 3,733 Total ~ertica/ De th, SS.• .3,623 Location at Total De th 51' FSL & 579' FEL -Sec 23 - T11N - R10E ° ASP Zone 4 NAD 27 Coordinates MedSUred De th, RKB: 12,090 Northings: 5,954,436 Eastings: 560,553 Total Vertica/De th RKB: 3,869 Total I/ertical De th, SS.• 3,760 1J-127 PERMIT IT Page 2 of 8 Printed: 31-Mar-06 o~~~~~~~ • and (D) other informat/an required by 2D AAC 25. D5D(1); ~ation for Permit to Drill, Well 1J-127 Revision No.O Saved: 31-Mar-06 Requirements of 20 AAC 25.050(b) If a we// is to 6e intentiona//y deviated, the app/ication for a Permit to Drill (Form 1 D-4DI) mast (I) include a p/at, drawn to a suitab/e scale, showing the path of the proposed we//bore, inc/udh~g a//adjacent we!/bores within 20D feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for a!/ wells withr"n 2DD feet of the proposed we//bore (A) list the n,~mes of the operators of those we!/s, to the extent that those names are known or discoverable in pub/ic 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 on/y affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fo/%wing /terns, except for an item already on fr/e with the commission and k/entifted in the app/ication; (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 2D AAC25. D35, 2D AAC 25.D36, or 2D 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 1J-127. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity,. blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled °Doyon 15 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more thzln 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will Ibe tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test tFie shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed <~nd tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Ha~:ards Information Requirements of 20 AAC 25.005 (c)(4) An appl/canon 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 app/ication.• (4) inforrnat/on on. drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potentia/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). These 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 A2 sand formation is 1,315 psi, calculated: i MPSP =(3,869 ft ND)(0.45 - 0.11 psi/ft) =]x,315 psi r (B) data on potentia/gas zones; The well bore its not expected to penetrate any gas. zones. and (C) data concerning potentia/ causes of hole prob/ems such as abnormal/y geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; 1J-127 PERMIT IT Page 3 of 8 Printed: 31-Mar-O6 ORIGINAL • Please see Attachment 2: iJ-127 Drilling Hazards Summary. ~ation for Permit to Drill, Well 1J-127 Revision No.O Saved: 31-Mar-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dri// must be accompanied by each of the fo/%wmg items, except for an item already on ~/e with the commission and identified in the application: (5J a description of the procedure far conducting format/an integrity tests, as required under ZO AAC 25.03t?(t), 1J-127 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 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. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application; (6) a complete proposed casing and cementing program as required 6y 20 AAC 25 030, and a description of any slotted liner, pre- perforated liner, or screen to be insta/led; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD _O_D_(in in t Ib/_ft1 Grade Connection ft ft ft Cement Pro ram . 20 x 34 42 94 K55 Welded 80 40 / 40 120 / 120 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,183 40 / 40 2,223 /2,193 440 sx ASLite Lead, drift 120 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 6,432 40 / 40 6,472 / 3,732 3,112' MD / 2,724' TVD. Cemented w/ 380 sx Dee CRETE 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 d Lateral (1J-127) 4-1/2 - 4 an 1 - TM 6,562 5,522/ 3,571 12,084 / 3,712 Slotte - no ce Slotted Lateral (iJ-127 Ll) 4-1/2 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 (iJ-127 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fallowing items, except far 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 ZO AAC 25.035(h)(Z); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of iJ-127. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app!/catian for a Permit to Drill must be accompanieed by each of the following items, except for an /tem a/ready on fi/e with the commission and ldentr`fied in the application: (8) a drilling t7uid program, including a diagram and description of the driAling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-127 PERMIT IT Page 4 of 8 Printed: 31-Mar-06 C~~~L • Surface Hole Mud Program (extended bentonite) ~tion for Permit to Drill, Well 1J-127 Revision No.O Saved: 31-Mar-06 Spud to Base of Permafrost Base of Permafrost to 10-3/4" Casio Point Initial Value Final Value Initial Value Final Value Density (pPg) 8.9 9.2 9.5 9.6 Funnel Viscosity 150 250 200 300 seconds Yield Point 50 70 30 50 cP Plastic Viscosity 20 45 15 20 Ib/100 s pH 8.5 9.0 8.5 9.0 API Filtrate NC 8 0 5 0 7 0 cc / 30 min . . . *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4" Cs Shoe to 7-5/8" Cs Point Value Density (ppg) 9.0 - 9.1 Funnel Viscosity- - 45 - 60 seconds) Plastic Viscosity (Ib/100 s 12 - 18 Yield Point 26 - 35 cP) API Filtrate 4 - 6 cc / 30 min Chlorides (mg/I) <500 pH 9.0 - 9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals Value Densit pp 8.6 Plastic Viscosity 15 - 25 Ib/100 sf) Yield Point cP 18 - 28 HTHP Fluid loss (ml/30 min @ 200psi & <4.0 150° Oil /Water Ratio 70 / 30 Electrical Stabilit >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application; (9) for an exp/oratory or stratigraphic test wel/, a tabulation setting out the depths of predicted abnorma!!y geo pressured strata as requr"red by 2D,4,~iC25.(I33(~; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Dri// must be accompanied by each of the fo//awing items, except For an item already on file with the commission and identified in the application: (i0) for an expioratory or stratigraphic test wel% a seismic refraction or ret7ection analysis as required by 20 AAC 25,C161(a); Not applicable: Application is not for an exploratory or stratigraphic test well ORIGINAL 1J-127 PERMIT IT Page 5 of 8 Printed: 31-Mar-06 • ~ation for Permit to Drill, Well 1J-127 Revision No.O Saved: 31-Mar-06 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on fi/e with the commission and identified in the application,• (11) for a well drilled from an offshore platform, mobi/e bottom-founded structure, jack-up rr`g, or floating driflr`ng vess% an analysis ofseabed conditions as required by 20 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/ication for a Permit to L7ril! must be accompanied by each of the following items, except for an item a/ready on fi/e with the commission and identified in the application; (12) evidence showing that the requirements af20A,4C2s.02s {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 Drill must be accompanied by each of the fallowing items, except far an item a/ready on fi/e with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 120' RKB. Install _landing_ring_on condtctor. ___ 2. Move in /rig up Doyon Rig 15. Install 21-1/4"Annular with 16"diverter line and function test. ~ s 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,223' MD / 2,193' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi{annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean. out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 6,472~MD / 3,732' TVD, the prognosed top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 3,112' MD / 2,724' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment.: Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 12,089' MD / 3,869' TVD as per directional plan. 1J-127 PERMIT IT Page 6 of 8 Printed: 31-Mar-06 ORIGINAL ~ation for Permit to Drill, Well 1 J-127 Revision No.0 Saved: 31-Mar-06 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oit based mud. POOH on elevators. 16. Run USIT log for cement bond. ~ 17. PU and run 4-1/2" slotted liner. ~ ` `~ 4 \ ~~~~ 18. Land liner, set liner hanger @ +/- 5,600' MD / 3,504' TVD. POOH. Note: Remaining operations are covered under the 1J-127L1 Application for Permit to Drill, -and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 5,522' MD / 3,571' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pickup 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at 12,084' MD / 3,712' TVD, as per directional plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil- based mud. POOH on elevators. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the iJ-127L2 Application for Permit to Drill, and are. provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of 5,300' MD / 3,520' TVD, the top of the D sand. 30. Mill 6-3/4" window. POOH. 31. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at 12,301' MD / 3,661' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 4-1/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. POOH. 38. 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. 39. POOH, laying down drill pipe as required. 40. PU completion as required and RIH to depth. Land tubing. Set BPV. 41. Nipple down BOPE, nipple up tree and test. Pull BPV. 1J-127 PERMIT IT Page 7 of 8 ~„ ~ ~ Printed: 31-Mar-06 • 42. Freeze protect well with diesel. 43. Set BPV and move rig ofF. ~ation for Permit to Drill, Well 1J-127 Revision No.0 Saved: 31-Mar-06 44. Rig up wire line unit. Pull BPV. r 45. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days (flowback cleanup). Shut well in. 46. 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 app/icatian for a Fermit 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: (14) a genera/ description of hoiv 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, f780 for an annu/ar dispasa/operation in t/~e wel%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal. well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal ~. _ operations.. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP Schematic Attachment 4 .Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 % Mile Radius Effect for Injector 1J-127 PERMIT IT Page 8 of 8 Printed: 31-Mar-O6 ORIGIN4L • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-127 Plan: 1J-127 (wp03) Proposal Report 31 January, 2006 • 1J-127 L2 (wp03) @ 12302'MD _ _ 1 1J-127 L1 (wp03) @ 12084'MD _ _ _ _ _ _ _ 1J-127 (wp03) @ 12090'MD - - - `~~ CASING DETAILS No TVD MD Name Size 1 120.00 120.00 16 16 2 2193.20 2223.51 10 3/4" 10-3/4 3 3732.52 6472.12 7 5/8" 7-5/8 4 3869.0012089.88 4 1 /2" 4-1 /2 Geo-Steer in Upper Lobe Across Fault, 9456ft MD, 3775ft TVD c_ O O 0 r 0 Z t O N DD Polygon defines a 100' wide corrido along the entire lateral length - allowabl deviation from plan is +/-50' Geosteer in Lower A2: 6980.89ft MD, 3762.95ft TVD Build ~ 4.00°/1008 to 84.00° lint - 6682.13 ft MD, 3754.48 ft TVD - - ' - 7 5/8" @ 6472ft MD, 3733ft TVD _ _ _ Continue Build @ 4/100ft , 6372ft MD, 37198 TVD Sail @ 80° Inc : 5522ft MD, 3571ft TVD Continue Build ~ 4°/100ft , 5422ft MD, 3550ft TVD -' - - Project: Kuparuk River Unit :12090ft MD, 3 VD i Site: Kuparuk 1J Pad Well: Plan 1J-127 ~' Wellbore: Plan 1J-127 ,' Plan: 1J-127 (wp03) --~- ' 41/2" i 1J-127 T14 (Lower Toe)(wp03) 1J-127 T13 (Lower) (wp03) 6 1J-127 T12(Lower)(wp03) 60° - --------------- _ 1J-127 T11 (Exit Drop Pt #5)(wp03) 1J-127 T10 (Exit Drop Pt fk4)(wp03) ----~ -------------------- 1J-127 A2-Projec'ed Fault Crossing ----------------------- 1J-127 T9(Upper)(wp03) 1 J-127 TS (Exit Build Pt #3)(wp03~ 1J-127 T7 (Exit Drop Pt #2)(wp03) ------------------------ 1J-127 T6NPPef)(wP03) 1 J-127 T5 (Exit Build Pt #1)(wp03) 60° - - - - - - - _ 1J-127 T4 (Lower)(wp04) ----- - - - - - - - - - 1 J-127 T3 (ILower) (wp03) 1J-127 T2 (A2 Landing)(wp03) 360° II Sail @ 76° Inc : 5122ft MD, 3478ft TVD 360° ----------------- 0° Continue Build ~ 4.50/100ft , 4004ft MD, 3089ft TVD 3 0 )(wp03) Sail ~ 66° Inc : 2919ft MD, 2646ft TVD 10 3l4" Casing @ 2224ft MD, 2193ft TVD T z~uths to True Norih ~° , , agnetic North: 24.54° - -' Magnetic Field ~ - Strength: 57578.1 nT _ - - ' ~ KOP :Begin Build @ 5°/100ft, 1600ft MD, 1600ft TVD Dip Angle: 80.72° _ _ - ' ~ _ _ - - - - - r~,.~. ~r~,, Date: 11/18/2004 _ _ _ _ - - - - - - ~ - - <.4JI I~OrI ll~~lPS Model: BGGM2004 ~ _ _ _ _ _ - - - SHL @ 1739ft FSL 8 2324ft FEL -Sec 35 - T11 N - 810E i .'•3 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 West - /East + 1000 ft/in d M O N N O C ~ r fn rh~ N d '~ ' r f!1 ~ M ~ et 07 ~ Q 2~°n W t7 ~o°in~OO Z ~ O M N 000 N rN t~ON U SON 1N0 ~OMNQf NOf MtO rrn00 N M M O Z r N M ~ C ~a n yan~M ] N O 'rte O. r Y Y ~'--- C 3 i ~ C ~ N d r a as = C r Y Y ~' .. ya ~;;~ ~ `° N ~a Q a z O O `o O N CO d O Y J H W a H Z ~_ H a LL m M C 7 00 O R C E Aa ~Uma YYY € N ~+ _ ~ ~~,aaa t~LmFM-YH»>Y~~~QQQ L Orin rOOnO)N T10 t0NN ~ONe}1t1MnOrM00001 t0 W! d O M N M N O N M n n t D r n~ D ~ to t~0 0~1 N tO M M O r M O n 0 M r r r N M ~ ~ ~7' uY In ~ In 1w7 t0 (n r N O0 N rn n 07 n N 01 /D r n~ ~O~MaNrer tO 00 ~tYnMO B M W 00 O 01 'a 00 M O ~tl f0 O N tnNONO>MO NOOfMr r 00N 000rN ~~~OtO r N M M M M M M M M tooooornnrnnornmrna -' O N M N N r~' t 0 O ~Y e T n M 0 aoritirirn00Mt~r'V'cT W00 aaMONO~r0M1D O'UN ~1n ~O O1r0NNM V 1L11A t0mn r r r N N M M M M M M M M M ~ °r~~a Z r N M~ t p t O n O D 0 r r O 0 M O ~ N N M N ~ O ~ o . 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I- ..................................~..__ LLJ ...........................a Z_ I ~ Q U N MODN ~ ~ ~ r ~ N ~' ~ M OD (V X00 Ln~ Z~~r~v ~ O ~ ~ N O M N ~ r N V O N(ON r Q O O N O ON~tn ~OMN00 ~ N ~ N M M O Z r N M V' '' ~ ~ ~ ~ " Halliburton Energy Service s -~A~Lilgu~ ty tOGt)P~11IIl~JS CQt Planning Report -Geographic - -- Alaska Sparry tlrrlllit~ Serrvices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 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 Welibore: Plan 1J-127 Design: 1J-127 (wp03) 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 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 Welibore Plan 1 J-127 l Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) 1°I (nT) bggm2004 11/18/2004 24.54 80.72 57,578 -- __. Design 1 J-127 (wp03) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) lft) (ft) (°) zs.oo o.oo o.oo o.oo 1/31/2006 11:40:29AM Page 2 of 12 COMPASS 2003.11 Build 48 c ~e``y~ #6 i~ ~~.r°' ~ fi f ~QiCtOC~~'1[~~IpS Alaska Halliburton Energy Services Planning Report -Geographic ~~+-ILILi~IuATOrvi Sperry Drilling Servtees _Y Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 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 Design: 1J-127 (wp03) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-g +E/.W Rate Rate Rate TFO (ft) (°) (°) lft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 1,600.00 0.00 0.00 1,600.00 0.00 0.00 0.00 0.00 0.00 0.00 2,918.50 65.93 52.28 2,646.24 415.05 536.70 5.00 5.00 0.00 0.00 4,003.78 65.93 52.28 3,088.95 1,021.21 1,320.53 0.00 0.00 0.00 0.00 5,122.12 76.00 359.82 3,477.65 1,935.64 1,750.71 4.50 0.90 -4.69 -88.49 5,202.12 76.00 359.82 3,497.00 2,013.27 1,750.46 0.00 0.00 0.00 0.00 5,422.12 76.00 359.82 3,550.22 2,226.73 1,749.79 0.00 0.00 0.00 0.00 5,522.12 80.00 359.82 3,571.01 2,324.53 1,749.49 4.00 4.00 0.00 0.00 6,372.12 80.00 359.82 3,718.61 3,161.61 1,746.86 0.00 0.00 0.00 0.00 6,472.12 84.00 359.82 3,732.53 3,260.61 1,746.55 4.00 4.00 0.00 0.00 6,682.12 84.00 359.82 3,754.48 3,469.46 1,745.89 0.00 0.00 0.00 0.00 6,827.87 89.83 359.82 3,762.32 3,614.94 1,745.43 4.00 4.00 0.00 0.00 6,980.89 89.69 359.89 3,762.95 3,767.95 1,745.04 0.10 -0.09 0.05 153.23 7,176.52 89.69 359.89 3,764.00 3,963.58 1,744.67 0.00 0.00 0.00 0.00 7,329.11 88.80 359.87 3,766.01 4,116.16 1,744.34 0.59 -0.59 -0.02 -178.50 7,376.58 88.80 359.87 3,767.00 4,163.61 1,744.23 0.00 0.00 0.00 0.00 7,416.27 89.00 359.85 3,767.76 4,203.30 1,744.13 0.50 0.50 -0.04 -4.31 7,650.01 89.00 359.85 3,771.85 4,437.00 1,743.52 0.00 0.00 0.00 0.00 7,779.89 95.49 359.82 3,766.76 4,566.71 1,743.14 5.00 .5.00 -0.03 -0.29 7,826.30 95.49 359.82 3,762.32 4,612.90 1,743.00 0.00 0.00 0.00 0.00 7,956.34 88.99 359.84 3,757.24 4,742.78 1,742.61 5.00 -5.00 0.02 179.81 8,226.34 88.99 359.84 3,762.00 5,012.74 1,741.86 0.00 0.00 0.00 0.00 8,378.33 89.66 359.81 3,763.79 5,164.71 1,741.40 0.44 0.44 -0.02 -2.28 8,400.54 89.66 359.81 3,763.92 5,186.92 1,741.32 0.00 0.00 0.00 0.00 8,543.45 82.52 359.83 3,773.66 5,329.41 1,740.87 5.00 -5.00 0.01 179.90 8,573.95 82.52 359.83 3,777.63 5,359.65 1,740.78 0.00 0.00 0.00 0.00 8,711.02 89.37 359.82 3,787.32 5,496.28 1,740.36 5.00 5.00 0.00 -0.05 9,150.02 89.37 359.82 3,792.15 5,935.26 1,738.98 0.00 0.00 0.00 0.00 9,294.05 96.57 359.85 3,784.69 6,079.00 1,738.56 5.00 5.00 0.02 0.21 9,316.19 96.57 359.85 3,782.15 6,101.00 1,738.50 0.00 0.00 0.00 0.00 9,455.62 89.60 359.84 3,774.65 6,240.14 1,738.12 5.00 -5.00 0.00 -179.94 10,000.62 89.60 359.84 3,778.46 6,785.12 1,736.60 0.00 0.00 0.00 0.00 10,214.57 88.53 359.75 3,781.94 6,999.04 1,735.84 0.50 -0.50 -0.04 -175.35 10,413.01 88.53 359.75 3,787.02 7,197.41 1,734.99 0.00 0.00 0.00 0.00 10,486.61 84.86 359.88 3,791.26 7,270.88 1,734.75 5.00 -5.00 0.17 178.01 10,574.98 84.86 359.88 3,799.18 7,358.89 1,734.57 0.00 0.00 0.00 0.00 10,665.47 89.38 359.82 3,803.73 7,449.25 1,734.34 5.00 5.00 -0.07 -0.78 10,915.47 89.38 359.82 3,806.44 7,699.23 1,733.55 0.00 0.00 0.00 0.00 1/31/2006 11:40:29AM Page 3 of 12 COMPASS 2003.11 Build 48 ~' ~ Halliburton Energy Services ~OfIOCa~~~~IpS Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-127 Wellbore: Plan 1J-127 Design: 1J-127 (wp03) [~i.l.t~3 U RT~?t'~1 SpsRyr Drilling Services Local Co-ordinate Reference: Well Plan 1J-127 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28p MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) North Reference: True Survey Calculation Method: Minimum Curvature 11,037.53 83.28 359.82 3,814.25 7,820.98 1,733.17 5.00 -5.00 0.00 179.99 11,103.46 83.28 359.82 3,821.97 7,886.46 1,732.97 0.00 0.00 0.00 0.00 11,225.52 89.38 359.82 3,829.78 8,008.21 1,732.59 5.00 5.00 0.00 -0.01 11,425.52 89.38 359.82 3,831.95 8,208.20 1,731.96 0.00 0.00 0.00 0.00 11,556.75 88.08 0.01 3,834.85 8,339.39 1,731.77 1.00 -0.99 0.15 171.56 11,680.68 88.08 0.01 3,839.00 8,463.25 1,731.79 0.00 0.00 0.00 0.00 11,892.90 84.99 0.79 3,851.81 8,675.05 1,733.27 1.50 -1.45 0.37 165.92 12,089.89 - 84.99 0.79 3,869.00 , 8,871.27 1,735.98 0.00 0.00 0.00 0.00 1/31/2006 11:40:29AM Page 4 of 12 COMPASS 2003.11 Build 48 ' ~ ~ ' ~-- ~ ' Hallibu rton Ener gy Serv ices HA ~;t~BUI ~T COI ~QC t3P~11I~I[~ 3S Plann ing Report - Geographic nrtcea~ S Aiwa 5B-erry Grilling e Database: EDM 2003.11 Sin gle User Db Local Co-ordinate Reference: Well Plan 1J-1 27 Company: ConocoPhillips A laska (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 Calculatio n Method: Minimum Curvature Wellbore: Plan 1J-127 Design: 1J-127 (wp03) Planned Survey 1J-127 (wp 03) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section Ift) (°) (°) lft- (ft) Ift) (ft) lftl (ft) (°/100ft1 (ft) 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5,945,552.30 558,887.50 0.00. 0.00 SHL ~ 1739ft FSL & 2324ft FEL -Sec 35 - T11 N - R10E 100.00 0.00 0.00 100.00 -9.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 120.00 0.00 0.00 120.00 11.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 16 200.00 0.00 0.00 200.00 91.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 400.00 0.00 0.00 400.00 291.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 500.00 0.00 0.00 500.00 391.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 600.00 0.00 0.00 600.00 491.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 700.00 0.00 0.00 700.00 591.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 800.00 0.00 0.00 800.00 691.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 900.00 0.00 0.00 900.00 791.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 1,000.00 0.00 0.00 1,000.00 891.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 1,100.00 0.00 0.00 1,100.00 991.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 1,200.00 0.00 0.00 1,200.00 1,091.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 1,300.00 0.00 0.00 1,300.00 1,191.00 0..00 0.00 5,945,552.30 558,887.50 0.00 0.00. 1,400.00 0.00 0.00 1,400.00 1,291.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 1,500.00 0.00 0.00 1,500.00 1,391.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 1,510.00 0.00 0.00 1,510.00 1,401.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 Base Permafrost 1,600.00 0.00 0.00 1,600.00 1,491.00 0.00 0.00 5,945,552.30 558,887.50 0.00 0.00 KOP :Beg in Build @ 5°l100ft, 1600ft MD, 1600ft TVD 1,643.21 2.16 52.28 1,643.20 1,534.20 0.50 0.64 5,945,552.80 558,888.14 5.00 0.50 T3 1,700.00 5.00 52.28 1,699.87 1,590.87 2.67 3.45 5,945,554.99 558,890.93 5.00 2.67 1,800.00 10.00 52.28 1,798.99 1,689.99 10.65 13.77 5,945,563.06 558,901.19 5.00 10.65 1,900.00 15.00 52.28 1,896.58 1,787.58 23.89 30.89 5,945,576.42 558,918.20 5.00 23.89 1,942.45 17.12 52.28 1,937.38 1,828.38 31.07 40.18 5,945,583.68 558,927.43 5.00 31.07 K15 2,000.00 20.00 52.28 1,991.93 1,882.93 42.28 54.67 5,945,595.00 558,941.83 5.00 42.28 2,100.00 25.00 52.28 2,084.28 1,975.28 65.68 84.93 5,945,618.63 558,971.91 5.00 65.68 2,200.00 30.00 52.28 2,172.96 2,063.96 93.92 121.45 5,945,647.16 559,008.20 5.00 93.92 2,223.51 31.18 52.28 2,193.20 2,084.20 101.24 130.91 5,945,654.55 559,017.60 5.00 101.24 10.3/4" Casing @ 1841 ft FSL & 2193ft FEL -Sec 35 - T11 N - R10E : 2224ft MD, 2193ft TVD - T3 + 550 -10 3!4" 2,300.00 35.00 52.28 2,257.27 2,148.27 126.78 163.94 5,945,680.34 559,050.42 5.00 126.78 2,400.00 40.00 52.28 2,336.58 2,227.58 164.00 212.08 5,945,717.94 559,098.27 5.00 164.00 2,500.00 45.00 52.28 2,410.28 2,301.28 205.32 265.50 5,945,759.67 559,151.36 5.00 205.32 2,600.00 50.00 52.28 2,477.82 2,368.82 250.41 323.81 5,945,805.21 559,209.31 5.00 250.41 2,700.00 55.00 52.28 2,538.68 2,429.68 298.93 386.55 5,945,854.21 559,271.66 5.00 298.93 2,800.00 60.00 52.28 2,592.39 2,483.39 350.50 453.24 5,945,906.30 559,337.94 5.00 350.50 2,900.00 65.00 52.28 2,638,55 2,529.55 404.75 523.39 5,945,961.09 559,407.66 5.00 404.75 2,918.50 65.93 52.28 2,646.24 2,537.24 415.05 536.70 5,945,971.49 559,420.89 5.00 415.05 Sail @ 66° Inc : 2919ft MD, 2ti46ft TVD 3,000.00 65.93 52.28 2,679.48 2,570.48 460.56 595.56 5,946,017.46 559,479.39 0.00 460.56 3,100.00 65.93 52.28 2,720.27 2,611.27 516.42 667.79 5,946,073.87 559,551.16 0.00 516.42 1/31/200611:40:29AM Page 5 of 12 COMPASS 2003.11 Build 48 ~~~ ~~~ 1 , ~ Halliburton Energy Services • ~-tgLL.~BE.i~T~ Colr~toP~ttltp5 Planning Report -Geographic - ----- ---------- waska spent' iiriiiing services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 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 1 J-127 Design: 1J-127 (wp03) Planned Survey 1J-127 (wp03) MD Inclination Azimuth TVD SSTVD +N/-S Ift) (°) (°) (ftl Ift) (ft) 3,200.00 65.93 52.28 2,761.07 2,652.07 572.27 3,300.00 65.93 52.28 2,801.86 2,692.86 628.12 3,400.00 65.93 52.28 2,842.65 2,733.65 683.98 3,500.00 65.93 52.28 2,883.45 2,774.45 739.83 3,600.00 65.93 52.28 2,924.24 2,815.24 795.68 3,612.38 65.93 52.28 2,929.29 2,820.29 802.60 Ugnu C 3,700.00 65.93 52.28 2,965.03 2,856.03 851.54 3,800.00 65.93 52.28 3,005.82 2,896.82 907.39 3,900.00 65.93 52.28 3,046.62 2,937.62 963.24 4,000.00 65.93 52.28 3,087.41 2,978.41 1,019.10 4,003.78 65.93 52.28 3,088.95 2,979.95 1,021.21 Continue Build @ 4.50/1 00ft, 4004ft MD, 3089ft TVD 4,100.00 66.11 47.55 3,128.08 3,019.08 1,077.80 4,200.00 66.46 42.65 3,168.32 3,059.32 1,142.40 4,300.00 66.96 37.78 3,207.88 3,098.88 1,212.52 4,300.75 66.96 37.74 3,208.17 3,099.17 1,213.07 Ugnu B 4,392.07 67.55 33.33 3,243.49 3,134.49 1,281.58 Ugnu A 4,400.00 67.61 32.95 3,246.51 3,137.51 1,287.72 4,500.00 68.40 28.17 3,283.99 3,174.99 1,367.53 4,593.19 69.25 23.77 3,317.67 3,208.67 1,445.63 K15 4,600.00 69.32 23.45 3,320.08 3,211.08 1,451.47 4,700.00 70.37 18.79 3,354.55 3,245.55 1,539.01 4,800.00 71.54 14.19 3,387.20 3,278.20 1,629.62 4,900.00 72.82 9.66 3,417.82 3,308.82 1,722.74 5,000.00 74.20 5.19 3,446.22 3,337.22 1,817.79 5,100.00 75.66 0.79 3,472.23 3,363.23 1,914.19 5,122.12 76.00 359.82 3,477.65 3,368.65 1,935.64 Sail @ 76° Inc : 5122ft M D, 3478ft TVD 5,177.32 76.00 359.82 3,491.00 3,382.00 1,989.20 WSAK D 5,200.00 76.00 359.82 3,496.49 3,387.49 2,011.21 5,202.12 76.00 359.82 3,497.00 3,388.00 2,013.27 1J-127 T1 (Dtop) (wp03) 5,300.00 76.00 359.82 3,520.68 3,411.68 2,108.23 5,357.09 76.00 359.82 3,534.49 3,425.49 2,163.63 WSAK C 5,400.00 76.00 359.82 3,544.87 3,435.87 2,205.26 5,422.12 76.00 359.82 3,550.22 3,441.22 2,226.73 Continue Build @ 4°/100ft , 5422ft MD, 3550ft TVD Map Map +E/_W Northing Easting DLSEV Vert Section (ft) (ft) (ft) (°I100ft) (ft) 740.01 5,946,130.29 559,622.94 0.00 572.27 812.24 5,946,186.70 559,694.72 0.00 628.12 884.46 5,946,243.11 559,766.50 0.00 683.98 956.68 5,946,299.52 559,838.28 0.00 739.83 1,028.91 5,946,355.93 559,910.06 0.00 795.68 1,037.85 5,946,362.91 559,918.95 0.00 802.60 1,101.13 5,946,412.34 559,981.84 0.00 851.54 1,173.36 5,946,468.75 560,053.61 0.00 907.39 1,245.58 5,946,525.16 560,125.39 0.00 963.24 1,317.81 5,946,581.57 560,197.17 0.00 1,019.10 1,320.53. 5,946,583.70 560,199.88 0.00 1,021.21 1,387.77 5,946,640.81 560,266.67 4.50 1,077.80 1,452.60 5,946,705.92 560,330.98 4.50 1,142.40. 1,511.87 5,946,776.49 560,389.70 4.50 1,212.52 1,512.29 5,946,777.04 560,390.12 4.60 1,213.07 1,561.22 5,946,845.93 560,438.50 4.50 1,281.58 1,565.23 5,946,852.09 560,442.46 4.49 1,287.72 1,612.35 5,946,932.26 560,488.95 4.50 1,367.53 1,650.38 5,947,010.65 560,526.37 4.50 1,445.63 1,652.93 5,947,016.51 560,528.87 4.49 1,451.47 1,686.73 5,947,104.31 560,561.99 4.50 1,539.01 1,713.54 5,947,195.11 560,588.08 4.50 1,629.62 1,733.20 5,947,288.37 560,607.01 4.50 1,722.74 1,745.57 5,947,383.51 560,618.64 4.50 1,817.79 1,750.60 5,947,479.94 560,622.91 4.50 1,914.19 1,750.71 5,947,501.39 560,622.85 4.50 1,935.64 1,750.54 5,947,554.94 560,622.26 0.00 1,989.20 1,750.47 5,947,576.94 560,622.02 0.00 2,011.21 1,750.46 5,947,579.00 560,622.00 0.00 2,013.27 1,750.17 5,947,673.95 560,620.96 0.00 2,108.23 1,749.99 5,947,729.34 560,620.35 0.00 2,163.63 1,749.86 5,947,770.97 560,619.90 0.00 2,205.26 1,749.79 5,947,792.43 560,619.66 0.00 2,226.73 1/31/2006 11:40:29AM Page 6 of 12 COMPASS 2003.11 Build 48 • H S i ~ llib t E , a u r on ne rgy erv ces l-tA1 .a~[BIJ RT~iN COC1©CO PI1t~~t~JS Planning Report -Geographic -~---- Alaska 8'P~n'Y EaMriBing Services Database: EDM 2003.11 Sin gle User Db Local Co-ordinate Reference: Well Plan 1J-1 27 Company: ConocoPhillips Al aska (Kuparuk) TV D Reference: Planned RKB @ 109.OOft (Doyon 141 (81 +28)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Do yon 141 (81 +28)) Site: Kuparuk 1J Pad No rth Reference: True Well: Plan 1J-127 Survey Calculation Method: Minimum Curvature Welibore: Plan 1J-127 Design: 1J-127 (wp03) Planned Survey -- 1J-127 (wp 03) _-_ - Map Map MD Inclination Azimuth TVD SSTVD +N!-S +E/-W Northing Easting DLSEV Vert Section (ftl (°) (°) lft) lft) (ft) (ft) {ft) {ft) {°1100ft) Ift) 5,486.86 78.59 359.82 3,564.46 3,455.46 2,289.88 1,749.60 5,947,855.57 560,618.97 4.00 2,289.88 WSAK B 5,500.00 79.11 359.82 3,567.00 3,458.00 2,302.77 1,749.56 5,947,868.46 560,618.83 3.99 2,302.77 5,522.12 80.00 359.82 3,571.01 3,462.01 2,324.53 1,749.49 5,947,890.21 560,618.59 4.00 2,324.53 Sail @ 80° Inc : 5522ft MD, 3571ft TVD 5,600.00 80.00 359.82 3,584.53 3,475.53 2,401.22 1,749.25 5,947,966.89 560,617.75 0.00 2,401.22 5,700.00 80.00 359.82 3,601.90 3,492.90 2,499.70 1,748.94 5,948,065.36 560,616.67 0.00 2,499.70 5,721.96 80.00 359.82 3,605.71 3,496.71 2,521.32 1,748.87 5,948,086.98 560,616.43 0.00 2,521.32 A4 5,800.00 80.00 359.82 3,619.26 3,510.26 2,598.18 1,748.63 5,948,163.82 560,615.59 0.00 2,598.18 5,900.00 80.00 359.82 3,636.63 3,527.63 2,696.66 1,748.32 5,948,262.29 560,614.51 0.00 2,696.66 5,967.62 80.00 359.82 3,648.37 3,539.37 2,763.25 1,748.11 5,948,328.87 560,613.78 0.00 2,763.25 A3 6,000.00 80.00 359.82 3,653.99 3,544.99 2,795.14 1,748.01 5,948,360.75 560,613.43 0.00 2,795.14 6,100.00 80.00 359.82 3,671.36 3,562.36 2,893.62 1,747.70 5,948,459.22 560,612.35 0.00 2,893.62 6,200.00 80.00 359.82 3,688.72 3,579.72 2,992.10 1,747.39 5,948,557.68 560,611.27 0.00 2,992.10 6,300.00 80.00 359.82 3,706.09 3,597.09 3,090.58 1,747.08 5,948,656.15 560,610.19 0.00 3,090.58 6,372.12 80.00 359.82 3,718.61 3,609.61 3,161.61 1,746.86 5,948,727.17 560,609.41 0.00 3,161.61 Continue Buil d ~ 4/100ft , 6372ft MD, 3719ft TVD 6,386.52 80.58 359.82 3,721.04 3,612.04 3,175.80 1,746.81 5,948,741.36 560,609.26 4.00 3,175.80 A2 6,400.00 81.11 359.82 3,723.18 3,614.18 3,189.11 1,746.77 5,948,754.66 560,609.11 3.99 3,189.11 6,472.12 84.00 359.82 3,732.53 3,623.53 3,260.61 1,746.55 5,948,826.16 560,608.33 4.00 3,260.61 7 5/8" ~ 280ft FNL & 574ft FEL -Sec 38 - T11N - R10E : Sail ~ 84° Inc : 8472ft MD, 3733ft TVD - 7 S/8" 6,500.00 84.00 359.82 3,735.44 3,626.44 3,288.34 1,746.46 5,948,853.88 560,608.02 0.00 3,288.34 6,600.00 84.00 359.82 3,745.89 3,636.89 3,387.79 1,746.15 5,948,953.31 560,606.93 0.00 3,387.79 6,682.12 84.00 359.82 3,754.48 3,645.48 3,469.46 1,745.89 5,949,034.98 560,606.04 0.00 3,469.46 Build ~ 4.00°f100ft to 84.00° linc - 6682.13 ft MD, 3754.48 ft TVD 6,700.00 84.71 359.82 3,756.23 3,647.23 3,487.25 1,745.83 5,949,052.76 560,605.84 3.99 3,487.25 6,800.00 88.71 359.82 3,761.96 3,652.96 3,587.07 1,745.52 5,949,152.56 560,604.75 4.00 3,587.07 6,801.71 88.78 359.82 3,762.00 3,653.00 3,588.77 1,745.52 5,949,154.27 560,604.73 4.06 3,588.77 6,827.87 89.83 359.82 3,762.32 3,653.32 3,614.94 1,745.43 5,949,180.43 560,604.44 4.00 3,614.94 Continue Buil d @ 4°/100ft to 89.8°, 6828ft MD, 37 62ft TVD - 1J-127 T2 {A2 Landing) (wp03) 6,900.00 89.77 359.85 3,762.57 3,653.57 3,687.06 1,745.23 5,949,252.54 560,603.67 0.10 3,687.06 6,980.89 89.69 359.89 3,762.95 3,653.95 3,767.95 1,745.04 5,949,333.42 560,602.86 0.10 3,767.95 Geosteer in Lower A2: 6980.89ft M D, 3762.95ft TVD 7,000.00 89.69 359.89 3,763.06 3,654.06 3,787.06 1,745.01 5,949,352.53 560,602.67 0.00 3,787.06 7,100.00 89.69 359.89 3,763.59 3,654.59 3,887.06 1,744.81 5,949,452.51 560,601.70 0.00 3,887.06 7,176.52 89.69 359.89 3,764.00 3,655.00 3,963.58 1,744.67 5,949,529.02 560,600.95 0.00 3,963.58 1J-127 T3 ((Lower) (wp03) 7,200.00 89.56 359.89 3,764.15 3,655.15 3,987.06 1,744.62 5,949,552.50 560,600.72 0.58 3,987.06 7,300.00 88.97 359.87 3,765.44 3,656.44 4,087.05 1,744.41 5,949,652.47 560,599.72 0.59 4,087.05 7,329.11 88.80 359.87 3,766.01 3,657.01 4,116.16 1,744.34 5,949,681.58 560,599.43 0.59 4,116.16 1/31/2006 11;40:29AM Page 7 of 12 COMPASS 2003.11 Build 48 rr-•,. ~ ~ K ~~ w ~ '" ~ • ~ - , Halliburton Energy Service s ~,Iq~L~g~~~-per COCtOCCl ~l1~~I5 Planning Report -Geographic ~ ~~ ~~~~~~ ~~~~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 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 Design: 1J-127 (wp03) Planned Survey 1J-127 (wp03) Map Map MD Inclination Azimuth TVO SSTVD +N/-S +E!-W Northing Easting DLSEV Vert Section (ft- (°) (°) (ft) Ift) (ft) lft) (ft) (ft) (°/100ft) (ft) 7,376.58 88.80 359.87 3,767.00 3,658.00 4,163.61 1,744.23 5,949,729.02 560,598.95 0.00 4,163.61 1J-127 T4 (Lower) (wp04) 7,400.00 88.92 359.86 3,767.47 3,658.47 4,187.03 1,744.17 5,949,752.44 560,598.71 0.50 4,187.03 7,416.27 89.00 359.85 3,767.76 3,658.76 4,203.30 1,744.13 5,949,768.70 560,598.54 0.50 4,203.30 7,500.00 89.00 359.85 3,769.23 3,660.23 4,287.01 1,743.91 5,949,852.41 560,597.67 0.00 4,287.01 7,600.00 89.00 359.85 3,770.98 3,661.98 4,387.00 1,743.65 5,949,952.38 560,596.62 0.00 4,387.00 7,650.01 89.00 359.85 3,771.85 3,662.85 4,437.00 1,743.52 5,950,002.37 560,596.10 0.00 4,437.00 Exit Pt #1 -Build @ 5°/100ft to 95° , 7650ft MD, 3772ft TVD -1J-127 T5 (Exit Build Pt #1)(wp03) 7,700.00 91.50 359.84 3,771.63 3,662.63 4,486.98 1,743.38 5,950,052.35 560,595.58 5.00 4,486.98 7,779.89 95.49 359.82 3,766.76 3,657.76 4,566.71 1,743.14 5,950,132.06 560,594.71 5.00 4,566.71 7,800.00 95.49 359.82 3,764.84 3,655.84 4,586.73 1,743.08 5,950,152.08 560,594.49 0.00 4,586.73 7,826.30 95.49 359.82 3,762.32 3,653.32 4,612.90 1,743.00 5,950,178.25 560,594.20 0.00 4,612.90 Land in Upper A2 @ 5°/100ft & 89°, 7826ft M D, 37 62ft TVD 7,900.00 91.81 359.83 3,757.63 3,648.63 4,686.44 1,742.77 5,950,251.78 560,593.40 5.00 4,686.44 7,956.34 88.99 359.84 3,757.24 3,648.24 4,742.78 1,742.61 5,950,308.10 560,592.80 5.00 4,742.78. Geo-Steer in Upper Lobe , 7956ft MD, 3757ft TVD 8,000.00 88.99 359.84 3,758.01 3,649.01 4,786.43 1,742.49 5,950,351.75 560,592.34 0.00 4,786.43 8,100.00 88.99 359.84 3,759.77 3,650.77 4,886.41 1,742.21 5,950,451.72 560,591.28 0.00 4,886.41 8,200.00 88.99 359.84 3,761.54 3,652.54 4,986.40 1,741.93 5,950,551.69 560,590.22 0.00 4,986.40 8,226.34 88.99 359.84 3,762.00 3,653.00 5,012.74 1,741.86 5,950,578.02 560,589.94 0.00 5,012.74 1J-127 T8 (Up per) (wp03) 8,300.00 89.32 359.83 3,763.09 3,654.09 5,086.38 1,741.64 5,950,651.66 560,589.15 0.44 5,086.38 8,378.33 89.66 359.81 3,763.79 3,654.79 5,164.71 1,741.40 5,950,729.97 560,588.29 0.44 5,164.71 8,400.00 89.66 359.81 3,763.91 3,654.91 5,186.38 1,741.32 5,950,751.64 560,588.05 0.00 5,186.38 8,400.54 89.66 359.81 3,763.92 3,654.92 5,186.92 1,741.32 5,950,752.18 560,588.04 0.00 5,186.92 Exit Pt #2 -Drop @ 5°/100ft to 83° , 8401ft MD, 3754ft TVD - 1J-127 T7 (Exit Drop Pt #2 )(wp03) 8,500.00 84.69 359.82 3,768.82 3,659.82 5,286.23 1,741.01 5,950,851.47 560,586.95 5.00 5,286.23 8,543.45 82.52 359.83 3,773.66 3,664.66 5,329.41 1,740.87 5,950,894.64 560,586.48 5.00 5,329.41 8,573.95 82.52 359.83 3,777.63 3,668.63 5,359.65 1,740.78 5,950,924.88 560,586.15 0.00 5,359.65 Land in Lowe r A2 ~ 5°/100ft 8~ 89°, 8574ft MD, 3778ft TVD 8,600.00 83.82 359.82 3,780.73 3,671.73 5,385.51 1,740.70 5,950,950.74 560,585.87 4.99 5,385.51 8,700.00 88.82 359.82 3,787.15 3,678.15 5,485.27 1,740.40 5,951,050.49 560,584.78 5.00 5,485.27 8,711.02 89.37 359.82 3,787.32 3,678.32 5,496.28 1,740.36 5,951,061.50 560,584.66 5.02 5,496.28 Geosteer in Lower Lo be, 8711ft MD, 3787ft TVD 8,800.00 89.37 359.82 3,788.30 3,679.30 5,585.26 1,740.08 5,951,150.46 560,583.69 0.00 5,585.26 8,900.00 89.37 359.82 3,789.40 3,680.40 5,685.26 1,739.77 5,951,250.44 560,582.59 0.00 5,685.26 9,000.00 89.37 359.82 3,790.50 3,681.50 5,785.25 1,739.45 5,951,350.42 560,581.49 0.00 5,785.25 9,100.00 89.37 359.82 3,791.60 3,682.60 5,885.24 1,739.14 5,951,450.40 560,580.40 0.00 5,885.24 9,150.02 89.37 359.82 3,792.15 3,683.15 5,935.26 1,738.98 5,951,500.40 560,579.85 0.00 5,935.26 Exit Pt #3 -Build @ 5°l100ft to 95° , 9150ft MD, 3792ft TVD - 1J-127 T8 (E xit Build Pt #3)(wp03) 9,200.00 91.87 359.83 3,791.61 3,682.61 5,985.23 1,738.83 5,951,550.37 560,579.31 5.00 5,985.23 9,294.05 96.57 359.85 3,784.69 3,675.69 6,079.00 1,738.56 5,951,644.12 560,578.31 5.00 6,079.00 9,300.00 96.57 359.85 3,784.01 3,675.01 6,084.91 1,738.55 5,951,650.04 560,578.25 0.00 6,084.91 9,316.19 96.57 359.85 3,782.15 3,673.15 6,101.00 1,738.50 5,951,666.12 560,578.08 0.00 6,101.00 Land in Upper A2 @ 5°/100ft & 90 °, 9316ft MD, 3782ft TVD 1/31!2006 11;40:29AM Page 8 of 12 COMPASS 2003.11 Build 48 ~`"~ '~' ~ Halliburton Energy Services ~ i-lAL~iBUR'1't~N' COC~Ca~"1I~~IpS Planning Report -Geographic ------ --- AJaska Sparry Drtilittg Selnricsa Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 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 1 J-127 Design: 1J-127 (wp03) Planned Survey 1J-127 (wp03) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +El-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°f100ft1 (ft) 9,400.00 92.38 359.84 3,775.61 3,666.61 6,184.53 1,738.28 5,951,749.64 560,577.20 5.00 6,184.53 9,455.62 89.60 359.84 3,774.65 3,665.65 6,240.14 1,738.12 5,951,805.24 560,576.61 5.00 6,240.14 Geo-Steer in Upper Lobe Across Fault, 9456ft MD, 3775ft TVD 9,500.00 89.60 359.84 3,774.96 3,665.96 6,284.52 1,738.00 5,951,849.61 560,576.14 0.00 6,284.52 9,600.00 89.60 359.84 3,775.66 3,666.66 6,384.51 1,737.72 5,951,949.59 560,575.08 0.00 6,384.51 9,700.00 89.60 359.84 3,776.36 3,667.36 6,484.51 1,737.44 5,952,049.58 560,574.02 0.00 6,484.51 9,800.00 89.60 359.84 3,777.06 3,668.06 6,584.51 1,737.16 5,952,149.56 560,572.95 0.00 6,584.51 9,900.00 89.60 359.84 3,777.75 3,668.75 6,684.50 1,736.88 5,952,249.54 560,571.89 0.00 6,684.50 10,000.00 89.60 359.84 3,778.45 3,669.45 6,784.50 1,736.60 5,952,349.52 560,570.83 0.00 6,784.50 10,000.62 89.60 359.84 3,778.46 3,669.46 6,785.12 1,736.60 5,952,350.14 560,570.83 0.00 6,785.12 1J-127 T9 (Upper)(wp03) 10,100.00 89.10 359.80 3,779.58 3,670.58 6,884.49 1,736.29 5,952,449.50 560,569.74 0.50 6,884.49 10,200.00 88.61 359.76 3,781.58 3,672.58 6,984.47 1,735.91 5,952,549.46 560,568.57 0.50 6,984.47 10,214.57 88.53 359.75 3,781.94 3,672.94 6,999.04 1,735.84 5,952,564.02 560,568.39 0.50 6,999.04 10,300.00 88.53 359.75 3,784.13 3,675.13 7,084.44 1,735.48 5,952,649.41 560,567.36 0.00 7,084.44 10,400.00 88.53 359.75 3,786.69 3,677.69 7,184.41 1,735.04 5,952,749.36 560,566.15 0.00 7,184.41 10,413.01 88.53 359.75 3,787.02 3,678.02 7,197.41 1,734.99 5,952,762.37 560,565.99 0.00 7,197.41 Exit Pt #4 -Drop @ 5° f100ft to Reacquire Upper Lobe, 10413ft MD, 3787ft TVD -1J-127 T10 (Exit Drop Pt #4)(wp03- 10,486.61 84.86 359.88 3,791.26 3,682.26 7,270.88 1,734.75 5,952,835.82 560,565.18 5.00 7,270.88 10,500.00 84.86 359.88 3,792.46 3,683.46 7,284.21 1,734.73 5,952,849.16 560,565.05 0.00 7,284.21 10,574.98 84.86 359.88 3,799.18 3,690.18 7,358.89 1,734.57 5,952,923.82 560,564.31 0.00 7,358.89 10,600.00 86.10 359.86 3,801.16 3,692.16 7,383.83 1,734.52 5,952,948.76 560,564.06 4.99 7,383.83 10,665.47 89.38 359.82 3,803.73 3,694.73 7,449.25 1,734.34 5,953,014.16 560,563.37 5.00 7,449.25 Geosteer i n Upper Lobe, 10565ft MD, 3804ft TVD 10,700.00 89.38 359.82 3,804.11 3,695.11 7,483.77 1,734.23 5,953,048.68 560,562.99 0.00 7,483.77 10,800.00 89.38 359.82 3,805.19 3,696.19 7,583.76 1,733.91 5,953,148.66 560,561.89 0.00 7,583.76 10,900.00 89.38 359.82 3,806,27 3,697.27 7,683.76 1,733.60 5,953,248.64 560,560.80 0.00 7,683.76 10,915.47 89.38 359.82 3,806.44 3,697.44 7,699.23 1,733.55 5,953,264.11 560,560.63 0.00 7,699.23 Exit Pt #5 -Drop @ 5°/100ft to 83°, 10915ft MD, 3806ft TVD - 1J-127 T11 ( Exit Drop Pt #5)(wp03) 11,000.00 85.16 359.82 3,810.47 3,701.47 7,783.64 1,733.29 5,953,348.51 560,559.70 5.00 7,783.64 11,037.53 83.28 359.82 3,814.25 3,705.25 7,820.98 1,733.17 5,953,385.84 560,559.29 5.01 7,820.98 11,100.00 83.28 359.82 3,821.56 3,712.56 7,883.02 1,732.98 5,953,447.87 560,558.62 0.00 7,883.02 11,103.46 83.28 359.82 3,821.97 3,712.97 7,886.46 1,732.97 5,953,451.31 560,558.58 0.00 7,886.46 Land in Lower Lobe @ 5°/100ft, 11103ft MD, 3822ft TVD 11,200.00 88.10 359.82 3,829.22 3,720.22 7,982.69 1,732.67 5,953,547.53 560,557.52 5.00 7,982.69 11,225.52 89.38 359.82 3,829.78 3,720.78 8,008.21 1,732.59 5,953,573.04 560,557.24 5.01 8,008.21 Geosteer in Lower lo be, 11226ft MD, 3830ft TVD - 1J-127 T12 (Lower) (wp03) 11,300.00 89.38 359.82 3,830.59 3,721.59 8,082.68 1,732.35 5,953,647.50 560,556.43 0.00 8,082.68 11,400.00 89.38 359.82 3,831.67 3,722.67 8,182.67 1,732.04 5,953,747.48 560,555.33 0.00 8,182.67 11,425.52 89.38 359.82 3,831.95 3,722.95 8,208.20 1,731.96 5,953,773.00 560,555.05 0.00 8,208.20 11,500.00 88.64 359.93 3,833.23 3,724.23 8,282.66 1,731.79 5,953,847.45 560,554.31 1.00 8,282.66 11,556.75 88.08 0.01 3,834.85 3,725.85 8,339.39 1,731.77 5,953,904.17 560,553.83 1.00 8,339.39 11,600.00 88.08 0.01 3,836.30 3,727.30 8,382.61 1,731.77 5,953,947.39 560,553.51 0.00 8,382.61 11,680.68 88.08 0.01 3,839.00 3,730.00 8,463.25 1,731.79 5,954,028.02 560,552.89 0.00 8,463.25 1J-127 T13 (Lower) (wp03) 11,700.00 87.80 0.08 3,839.69 3,730.69 8,482.56 1,731.81 5,954,047.32 560,552.76 1.50 8,482.56 1/31/200611:40:29AM Page 9 of 12 COMPASS 2003.11 Build 48 ` ~ ~S '+-' ~ ~ Halliburton Energy Services ~011tKC3~'!!~~l~JS Planning Report -Geographic Alaska Database: EDM 2003.11 Single User bb Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Welf: Plan 1J-127 Wellbore: Plan 1J-127 Design: 1J-127 (wp03) Planned Survey 1J-127 (wp03) HAhLI B U RT(CiMV' Sperry Drilling Services Local Co-ordinate Reference: Well Plan 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 __ 1 Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting (ft) (°) (°) fftl Ift) Ift) lft) Ift) (ft) 11,800.00 86.35 0.45 3,844.80 3,735.80 8,582.42 1,732.27 5,954,147.18 560,552.44 11,892.90 84.99 0.79 3,851.81 3,742.81 8,675.05 1,733.27 5,954,239.81 560,552.72 11,900.00 84.99 0.79 3,852.43 3,743.43 8,682.12 1,733.37 5,954,246.88 560,552.76 12,000.00 84.99 0.79 3,861.16 3,752.16 8,781.73 1,734.74 5,954,346.48 560,553.35 12,089.89 84.99 0.79 3,869.00 3,760.00 8,871.27 1,735.98 5,954,436.02 560,553.89 BHL ~ 51ft FSL & 578ft FEL -Sec 23 - T11N - R10E; 12090ft MD, 388l3ft TVD - 41/2" -1J-127 T14 (Lower Toe)(wp03) DLSEV Vert Section (°/100ft) (ft) 1.50 8,582.42 1.50 8,675.05 0.00 8,682.12 0.00 8,781.73 0.00 8,871.27 1/31/2006 11;40:29AM Page 10 of 12 ~~,~ -. COMPASS 2003.11 Build 48 ~-` ~ • Halliburton Energy Services ConocoP~tt~ltps Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J.Pad Well: Plan iJ-127 Wellbore: Plan 1J-1:27 Design: 1 J-127 (wp03) Geologic Targets Plan 1 J-127 TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,497.00 1J-127 T1 (Dtop) (wp03) 2,013.27 1,750.46 5,947,579.00 560,622.00 - Point 3,787.02 1J-127 T10 (Exit Drop Pt#4)(wp03) 7,197.41 1,734.99 5,952,762.37 560,565.99 - Point 3,764.00 1J-127 T3 ((Lower) (wp03) 3,963.58 1,744.67 5,949,529.02 560,600.95 - Point 3,839.00 1J-127 T13 (Lower- (wp03) 8,463.25 1,731.79 5,954,028.02 560,552.89 - Point 3,762.00 1J-127 DD Polygon (wp03) 3,260.61 1,746.55 5,948,826.15 560,608.33 - Polygon Point 1 -50.00 0.00 5,948,825.76 560,558.34 Point 2 -53.03 1,176.78 5,950,002.37 560,546.10 Point 3 -59.94 3,524.91 5,952,350.14 560,520.83 Point 4 -63.97 4,747.99 5,953,573.04 560,507.24 Point 5 -60.57 5,611.05 5,954,436.02 560,503.89 Point 6 39.44 5,610.27 5,954,436.02 560,603.89 Point 7 36.04 4,747.21 5,953,573.04 560,607.24 Point 8 40.06 3,524.12 5,952,350.14 560,620.83 Point 9 46.97 1,176.00 5,950,002.37 560,646.10 Point 10 50.01 -0.78 5,948,825.76 560,658.34 3,771.85 1J-127 T5 (Exit Build Pt #1)(wp03) 4,437.00 1,743.52 5,950,002.37 560,596.10 - Point 3,806.44 1J-127 T11 (Exit Drop Pt #5-(wp03) 7,699.23 1,733.55 5,953,264.11 560,560.63 - Point 3,829.78 1J-127 T12 (Lower) (wp03) 8,008.21 1,732.59 5,953,573.04 560,557.24 - Point 3,762.32 1J-127 T2 (A2 Landing) (wp03) 3,614.94 1,745.43 5,949,180.43 560,604.44 - Point 3,763.92 1J-127 T7 (Exit Drop Pt#2)(wp03) 5,186.92 1,741.32 5,950,752.18 560,588.04 - Point 3,762.00 1J-127 T6 (Upper) (wp03) 5,012.74 1,741.86 5,950,578.02 560,589.94 - Point 3,792.15 1J-127 T8 (Exit Build Pt #3)(wp03) 5,935.26 1,738.98 5,951,500.40 560,579.85 - Point 3,767.00 1J-127 T4 (Lower) (wp04) 4,163.61 1,744.23 5,949,729.02 560,598.95 - Point 3,869.00 1J-127 T14 (Lower Toe)(wp03) 8,871.27 1,735.98 5,954,436.02 560,553.89 - Point 3,778.46 1J-127 T9 (Upper)(wp03) 6,785.12 1,736.60 5,952,350.14 560,570.83 - Point Local Co-ordinate Reference: Well Plan 1 J-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 HAL>v! B U RTQN __~ ~_ --- Sperry Drgli~ 8~rvicss 1/31/2006 11:40:29AM Page f 1 of 12 COMPASS 2003.11 Build 48 1r~' Colrtc~toP~ilr~ps Alaska Database: 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 Design: 1J-127 (wp03) ~ Halliburton Energy Services Hp~LL~g~~~-~N Planning Report -Geographic -~- -~~~~ Sparry driliiln~ Srenr~ss Local Co-ordinate Reference: Well Plan 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 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 120.00 120.00 16 20 2, 223.51 2,193.20 10-3/4 13-1 /2 6,472.12 3,732.52 7-5/8 9-7/8 12,089.88 3,869.00 4-1/2 6-3/4 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +w_E +~-W (ft) (°l (°) 1ft) lft1 !ft) 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 5,357.09 76.00 359.82 3,534.49 2,163.63 1,749.99 WSAK C 5,486.86 78.59 359.82 3,564.46 2,289.88 1,749.60 WSAK B 5,721.96 80.00 359.82 3,605.71 2,521.32 1,748.87 A4 5,967.62 80.00 359.82 3,648.37 2,763.25 1,748.11 A3 6,386.52 80.58 359.82 3,721.04 3,175.80 1,746.81 A2 1/31/200611:40:29AM Page 12 of 12 COMPASS 2003.11 Build 48 • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-127 Anticollision Summaf*y 31 January, 2006 • HL~..IF~.J R"Il~f Sperry Qrffing Services ,~ .-. ; L ~ZZZO i' 2 C d B. E~~Am Y ~ ~ d E~-«- .~ ~iy CyU 4K a a¢¢~`~ ~d~m8 05 Om uL. 6 G N O ~ ~ O f O .L. y' O~ W ~ °' C A A ~y O N V = U h ` O o' ~~ a. J r m a J W Z b Q q ~ J N n 9 d C TO C ~ C A N (~ x o 6 W m y N Q ~n CN o N 3S ~e ~$ +e 0 wm .. 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F~~ - ' ~ . ~ ,-. ~ m o t ,~ a ~ %~~ ! ; ~ ~ s / ~ ~ !~ ~ ~/~ ~ ~ / / /' L d '~ ~~ a U N C o ~ '~it ~' O \ 1 ~ r N ~ i. ~o a o d 3 3 ~ ~ r r i 3 ~ _ V O ~ N O. ~~ 3 ~ 7 a L } O 04 z ... ... `~ r ~ T O ~a S ~~a~ sQe . W O o ~ F 'mNm~ ~a~zE o -m`o A'c " Sam-af z w X388$ V C c L W ~ ~ ~ ~ y ~ ~r'~~~ LL 7.~1'K ~ K 3 ~ ] d? r 3 ~ 9 V o C H ~ g' ~ ~'" ~ Hallihrton Ener gy Services ~ HAL4.~BtJRTG3iV Car~caP'h~tl~ps Anticollision Report ------------~w__ ----------~-~ Alaska SpsRy iiriUing Services Company: ConocoPhillips Alaska (Kuparuk) Pro~ct: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-127 Well Error: O.OOft Reference Wellbre Plan 1J-127 Reference Design: 1J-127 (wp03) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Databse: Offset TVD Reference: Well Plan 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 Reference Datum Reference 1J-127 (wp03) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referen Interpolation Method: MD Interval 100.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,406.19ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma iurvey Tool Program Date 1/31/2006 From To (ft) (ft) Survey (Wellbre) Tool Name Description 28.00 800.00 1J-127 (wp03) (Plan 1J-127) CB-GYRO-SS Camera based gyro single shot 800.00 12,089.86 1J-127 (wp03) (Plan 1J-127) 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 1/31/2006 1:21:12PM Page 2 of 5 COMPASS 2003.11 Build 48 a $ ~ ., A ~ x } e ~' ~ Hallihrton Ener gy Services C©1'l000~'li~~lpS Anticollision Report Alaska 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 Wellbre Plan 1J-127 Reference Design: 1J-127 (wp03) IH~,t~>I,.tBURSCant Spof~t Qirtitieg Seinrtrc~s Local Co-ordinate Reference: Well Plan 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 Output errors are at 2.00 sigma DataBse: EDM 2003.11 Single User Db Offset TVD Reference: Reference Datum Summary Site Name Offset Well -Wellbre -Design Kuparuk 1 p Pad 1 D-40 - 1 D-40 - 1 D-40 1 D-40 - 1 D-40A - 1 D-40A Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 12,050.32 7,200.00 524.37 12,061.02 7,200.00 539.42 No-Go Aliowale Distance Deviation Warning (ft) from Plan (ft) 144.44 379.93 Pass -Major Risk 143.04 396.38 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/31/2006 1:21:12PM Page 3 of 5 COMPASS 2003.11 Build 48 ~, ~ ~ ~'` ' Hallihrton Ener gy Services HA~..L~QURT©N C4110C0~ 11~~1~3S Alaska Anticollision Report ~~~ ar~u~~ ~ Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1J-127 Progct: Kuparuk River Unit TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Reference Site: Kuparuk 1J Pad MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-127 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbre Plan 1J-127 Databse: EDM 2003.11 Single User Db Reference Design: 1J-127 (wp03) Offset TVD Reference: Reference Datum Summary Reference Offset Centre to No-Go Allowale Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbre -Design (ft) (ft) {ft) (ft) Kuparuk 1J Pad 1 J-03 - 1 J-03 - 1 J-03 887.64 900.00 384.94 16.58 368.36 Pass -Major Risk 1J-101 - iJ-101 - 1J-101 2,640.80 2,500.00 552.62 50.31 502.31 Pass -Major Risk 1J-101 - 1J-101 L1 - 1J-101 L1 2,640.80 2,500.00 552.62 50.89 501.74 Pass -Major Risk iJ-101 - 1J-101 L1 PB1 - 1J-101 L1 PB1 2,640.80 2,500.00 552.62 50.31 502.31 Pass -Major Risk 1 J-101 - 1 J-101 L2 - 1 J-101 L2 2,640.80 2,500.00 552.62 50.89 501.74 Pass -Major Risk 1 J-164 - 1 J-164 - 1 J-164 599.94 600.00 266.77 13.05 253.72 Pass -Major Risk 1 J-164 - 1J-164 L1 -1 J-164 L1 599.94 600.00 266.77 13.05 253.72 Pass -Major Risk 1J-164 - 1J-164 L2 -1J-164 L2 599.94 600.00 266.77 13.05 253.72 Pass -Major Risk 1J-164 - 1J-164 L2 PBi - 1J-164 L2 P61 599.94 600.00 266.77 13.05 253.72 Pass -Major Risk 1J-168 - 1J-168 - 1J-168 299.98 300.00 203.64 6.55 197.09 Pass -Major Risk iJ-168 - 1J-168 L1 - 1J-168 L1 299.98 300.00 203.64 6.55 197.09 Pass -Major Risk 1 J-168 - 1 J-168 L2 - 1 J-168 L2 299.98 300.00 203.64 6.55 197.09 Pass -Major Risk 1 J-168 - 1 J-168 L2 P61 - 1 J-168 L2 PB1 299.98 300.00 203.64 6.55 197.09 Pass -Major Risk Plan 1J-102 -1J-102 -1J-102 (wp04) 4,156.61 3,799.98 129.38 86.31 43.06 Pass -Major Risk Plan iJ-102 - 1J-102 L1 -1J-102 L1 (wp03) 4,118.81 3,799.98 115.79 82.35 33.45 Pass -Major Risk Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp03) 4,118.81 3,799.98 115.79 82.35 33.45 Pass -Major Risk Plan 1J-103 -Plan 1J-103 - 1J-103 (wp01) BHI 600.85 600.00 502.17 12.80 489.37 Pass -Major Risk Plan 1J-111 -Plan 1J-111 - iJ-111 (wp02) 795.78 800.00 317.55 17.25 300.30 Pass -Major Risk Plan 1 J-112 Kuparuk Prelim -1 J-12 E Lateral - 1 J-1 1,697.05 1,699.99 301.43 32.97 268.46 Pass -Major Risk Plan 1 J-112 Kuparuk Prelim - 1 J-12 Pilot - 1 J-12 Pil 1,697.05 1,699.99 301.43 32.97 268.46 Pass -Major Risk Plan 1J-112 Kuparuk Prelim -Plan 1J-12 W Lateral 1,697.05 1,699.99 301.43 32.97 268.46 Pass -Major Risk Plan 1 J-115 -Plan 1 J-115 - 1 J-115 (wp01) 898.00 900.00 .238.93 17.44 221.50 Pass -Major Risk Plan iJ-118 -Plan 1J-118 -Plan 1J-118 (wp01) 798.00 800.00 178.48 15.63 162.84 Pass -Major Risk Plan 1J-120 -Plan 1J-120 - 1J-120 (wp01) 795.33 800.00 128.31 15.57 112.74 Pass -Major Risk Plan 1J-122 -Plan 1J-122 - 1J-122 (wp02) 697.97 700.00 98.46 15.34 83.13 Pass -Major Risk Plan 1 J-123 Kuparuk Prelim -1J-23 E Lat - 1J-23 E 1,286.45 1,299.99 79.74 25.59 54.15 Pass -Major Risk Plan 1 J-123 Kuparuk Prelim -1 J-23 Pilot - 1 J-23 Pil 1,286.45 1,299.99 79.74 25.59 54.15 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat- 1J-23 \ 1,286.45 1,299.99 79.74 25.59 54.15 Pass -Major Risk Plan 1J-124 -Plan 1J-124 - 1J-124 (wp01) BHI 486.92 500.00 58.45 10.58 47.86 Pass -Major Risk Plan 1J-127 -Plan 1J-127 L1 -1J-127 L1 (wp03) 12,088.04 12,084.47 158.15 5,958.18 -5,800.04 FAIL -Minor Risk Plan 1J-127 -Plan 1J-127 L2 -1J-127 L2 (wp03) 12,005.07 11,999.95 225.00 6,388.40 -6,163.40 FAIL -Minor Risk Plan 1 J-129 -Plan 1 J-129 - 1 J-129 (wp02) 387.97 400.00 40.57 8.55 32.02 Pass -Major Risk Plan 1 J-130 -Plan 1 J-130 - 1 J-130 (wp02) 387.97 400.00 60.89 8.55 52.34 Pass -Major Risk Plan 1 J-132 -Plan 1 J-132 -1 J-132 (wp02) 387.97 400.00 101.20 8.44 92.77 Pass -Major Risk Plan 1J-133 - 1J-133 -1J-133 (wp06) 387.97 400.00 121.79 8.55 113.24 Pass -Major Risk Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) 387.97 400.00 121.79 8.55 113.24 Pass -Major Risk Plan 1J-135 -Plan 1J-135 -Plan 1J-135 (wp01) 401.00 400.00 160.06 7.69 152.38 Pass -Major Risk Plan 1 J-136 - 1 J-136 - 1 J-136 (wp03) 301.00 300.00 180.08 6.59 173.48 Pass -Major Risk Plan 1 J-136 - 1 J-136 L1 - 1 J-136 L1 (wp03) 301.00 300.00 180.08 6.37 173.70 Pass -Major Risk Plan 1 J-137 - 1 J-137 - 1 J-137 (wp03) 301.00 300.00 199.65 6.29 193.35 Pass -Major Risk Plan 1 J-137 -1 J-137 L1 - 1 J-137 L1 (wp03) 301.00 300.00 199.65 6.29 193.35 Pass -Major Risk Plan 1J-159 - 1J-159 -1J-159 (wp06) 3,105.21 3,099.99 137.68 55.95 81.73 Pass -Major Risk Plan iJ-159 - 1J-159 L1 -1J-159 L1 (wp06) 3,105.21 3,099.99 137.68 55.94 81.74 Pass -Major Risk Plan 1J-159 - 1J-159 L2 - 1J-159 L2 (wp06) 3,105.21 3,099.99 137.68 55.94 81.74 Pass -Major Risk Plan 1J-166 - 1J-166 - 1J-166 599.96 600.00 232.10 13.15 218.95 Pass -Major Risk Plan 1J-166 - 1J-166 L1 - iJ-166 L1 599.96 600.00 232.10 13.15 218.95 Pass -Major Risk Plan 1 J-166 - 1 J-166 L1 PB1 - 1 J-166 L1 P61 599.96 600.00 232.10 13.15 218.95 Pass -Major Risk Plan 1 J-166 -1 J-166 L2 - 1 J-166 L2 599.96 600.00 232.10 13.15 218.95 Pass -Major Risk Plan 1 J-170 -Plan 1 J-170 -1 J-170 (wp02) 399.97 400.00 178.31 8.66 169.65 Pass -Major Risk Plan 1J-170 -Plan 1J-170 L1 - 1J-170 L1 (wp02) 399.97 400.00 178.31 8.66 169.65 Pass -Major Risk Plan 1J-170 -Plan 1J-170 L2 - 1J-170 L2 (wp02) 399.97 400.00 178.31 8.66 169.65 Pass -Major Risk Plan iJ-173 Kuparuk - 1J-73 E Lateral - 1J-73 E La' 1,088.00 1,100.00 151.23 22.27 128.95 Pass -Major Risk Plan 1J-173 Ku aruk- 1J-73 Ku aruk- 1J-73 W La 1,088.00 1,100.00 151.23 22.27 128.95 Pass - Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/31/2006 1:21:12PM Page 4 of 5 COMPASS 2003.11 Build 48 . ~ Hallihrton Ener gy Services ~ HAirld.IBURTplV ~ C"~1~1OIC0'~'1i~~1~-5 Anticollision Report - --~ Alaska ~RpeRy Drilling Servica-s Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1J-127 Projsct: Kuparuk River Unit TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28}) Reference Site: Kuparuk 1J Pad MD Reference: Planned RKB @ 109.OOft (Doyon 141 (81+28)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-127 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbre Plan 1J-127 Datal~se: EDM 2003.11 Single User Db Reference Design: 1 J-127 (wp03) Offset TVD Reference: Reference Datum Summary Reference Offset Centre to No-Go Allowale Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbre -Design (ft) (ft) (ft) (ft) Kuparuk 1J .Pad , Plan 1 J-173 Kuparuk - 1 J-73 Pilot - 1 J-173 Pilot (wl 1,088.00 1,100.00 151.23 22.27 128.95 Pass -Major Risk Plan 1 J-174 -Plan 1 J-174 -1 J-174(wp01) 200.00 200.00 147.37 4.32 143.05 Pass -Major Risk Plan 1 J-176 -Plan 1 J-176 -1 J-176 (wp01) 300.99 300.00 148.11 5.98 142.13 Pass -Major Risk Plan 1 J-178 -Plan 1 J-178 - 1 J-178 (wp01) 300.99 300.00 158.69 5.97 152.71 Pass -Major Risk Plan 1J-180 -Plan 1J-180 - 1J-180 (wp01) 300.99 300.00 177.89 5.97 171.92 Pass -Major Risk Plan 1J-182 - 1J-182 - iJ-182 (wp05) 301.00 300.00 201.88 6.51 195.37 Pass -Major Risk Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) 301.00 300.00 201.88 6.29 195.59 Pass -Major Risk Plan 1 J-184 - 1 J-184 - 1 J-184 (wp09) 299.99 300.00 232.20 6.60 225.60 Pass -Major Risk Plan 1J-184 - 1J-184 L1 - 1J-184 L1 (wp09} 299.99 300.00 232.20 6.60 225.60 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 2,039.63 2,000.00 318.23 40.84 277.39 Pass -Major Risk WSP-03 -WSP-03 -WSP-03 2,694.38 2,600.00 144.24 71.55 72.69 Pass -Major Risk WSP-04 -WSP-04 -WSP-04 2,111.26 2,100.00 187.39 42.58 144.81 Pass -Major Risk WSP-05 -WSP-05 -WSP-05 1,903.91 1,900.00 154.44 39.04 115.40 Pass -Major Risk WSP-O6 -WSP-06 -WSP-06 1,484.44 1,500.00 97.18 31.73 65.45 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 1,889.31 1,900.00 26.29 1.01 25.28 Pass -Minor 1/10 WSP-08 -WSP-08 -WSP-08 1,903.74 1,900.00 18.99 1.01 17.98 Pass -Minor 1/10 WSP-09 -WSP-09 -WSP-09 1,686.87 1,700.00 88.47 37.21 51.25 Pass -Major Risk WSP-10 -WSP-10 -WSP-10 1,103.87 1,100.00 136.70 26.21 110.49 Pass -Major Risk WSP-11 -WSP-11 -WSP-11 1,286.03 1,300.00 203.75 29.93 173.83 Pass -Major Risk WSP-12 -WSP-12 -WSP-12 1,086.94 1,100.00 265.89 26.82 239.08 Pass -Major Risk WSP-13 -WSP-13 -WSP-13 1,203.99 1,200.00 320.73 23.80 296.93 Pass -Major Risk WSP-15 -WSP-15 -WSP-15 1,486.98 1,500.00 404.19 34.11 370.09 Pass -Major Risk WSP-1S -WSP-1S -WSP-1S 2,416.89 2,400.00 424.63 112.25 312.37 Pass -Major Risk WSP-20 -WSP-20 -WSP-20 1,699.99 1,700.00 285.59 43.03 242.57 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/31/2006 1:21:12PM Page 5 of 5 COMPASS 2003.11 Build 48 ~ - , `, w -127I~illina H ~mmar~ (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Oaen Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate ~ Control drill, Reduced. pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and .Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 9-7/8" Open Hole / 7-5/8" Casina Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates,. reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates mud rheolo LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Low ; 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 { . ~ k 1J-127 Drilling Hazards Summary ~'~`, ~ ~.w- `-_, 3/31/2006 1:17 PM Drill String Valves To be tested to 250 psi and 3,000 psi. at initial installation and every 14 days thereafter. 13-5 Annular ~- To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/" to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves t To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" ~ To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly ~.,.~ ~+~nO~t~P"hil~ps .~c'~5}Cc't Doyon 141 West Sak 3 ksi BOP Configuration ~" ~ ~~ C~ tia r~~x ~uM, 13-5 BOP 3K diagram.vsd Sheet 1 of 1 prepared by Steve McKeever 8/11/2004 CemCADE Preliminary Job Design 10 3/4" SurFace Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 3/20/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martin13@slb.com < TOC at Surface '"' ': ,3 Previous Csg. < 16", 62.6# casing at 120' MD < Base of Permafrost at 1,510' MD (1,510' TVD) < Top of Tail at 1,724' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 2,224' MD (2,193' TVD) Mark of Schlumberger Schlumberge~ Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 1,724' MD. Lead Slurry Minimum pump time: 200 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.6381 ft3/ft x (120') x 1.00 (no excess) = 76.6 ft3 0.3637 ft3/ft x (1510' - 120') x 3.50 (250% excess) = 1769.4 ft3 0.3637 ft3/ft x (1724' - 1510') x 1.35 (35°/d excess) = 105.1 ft3 76.6 ft3 + 1769.4 ft3+ 105.1 ft3 = 1951.1 ft3 1951.1 ft3 / 4.45 ft3/sk = 438.4 sks Round up to 440 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (2224' - 1724') x 1.35 (35% excess) = 245.5 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 245.5 ft3 + 43.2 ft3 = 288.7 ft3 288.7 ft3/ 2.47 ft3/sk = 116.9 sks Round up to 120 sks BHST = 48°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbll (mini CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 347.5 49.6 ' 82.9 DeepCRETE 6,0 51.4 8.6 101.5 Drop top plug 0.0 0.0 5.0 106.5 Water 5.0 20.0 4.0 110.5 Switch to rig 0.0 0.0 5.0 115.5 Mud 7.0 177.2 25.3 140.8 Slow & bump plug 3.0 9.0 3.0 143.8 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv ? 17-21, TY ? 20-25 Centralizers:. Recommend 2 per joint on shoe track and 1 per joint throughout tail slurry ~~j~r f~x x"'" z CemCADE Preliminar Job Desi n Y g 7-5/8" Intermediate ..Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 3/20/2006 Prepared by: Mike Martin Location; Anchorage, AK Phone: (907) 263207 Mobile: (907) 748-6900 email: martin13@slb.com Previous Csg. ~' < 10 3/4", 45.5# casing at 2,224' MD < Top of Tail at 3,112' MD < 7 5/8", 29.7# casing in 9 7/8" ON TD at 6,472' MD (3,732' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 3360' MD annular length Tail Slurry Minimum thickening time: 180 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 3360' x 1.25 (25% excess) = 902.2 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 902.2 ft3 + 20.6 ft3 = 922.8 ft3 922.8 ft3/ 2.25 ft3/sk = 410.1 sks Round up to 420 sks BHST = 88°F, Estimated BHCT = 75°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (mint CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop .bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 75.0 15.0 40.0 DeepCRETE 5.0 164.3 32.9 72.9 Drop top plug 0.0 0.0 5.0 77.9 Water 5.0 20.0 4.0 81.9 Switch to rig 0.0 0.0 5.0 86.9 Mud 6.0 264.5 44.1 131.0 Slow 7 bump plug 3.0 9.0 3.0 134.0 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, Pv ? 19-22; Ty ? 22-29 Centralizers: ?? 3 per 2 joints from shoe to 4992' and (West Sak) ?? 1 per joint from 4992 - 4592' and ?? 3 per 2 joints from 4592 - 3800' and (Ugnu) ~;~~~ ~.~~~., ~~ C~ V ~ 20" 94# x 34" Insulated Conductor, set at+/_ 80' 10-314" x 4-112" Wellhead, 5000 psI 10-314" 68#, Casing ~~ Shoe, set ~ 2231' MD, 2207' TVD / Tubing String 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 5-112" X 7-518" ZXP Liner Top Packer wl Hold Seal Assembly Downs 4.75" Seal OD 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, 4.112" X 1" CMU Sliding Sleeve, wl 3.81" DB Nipple Casing Sealbore Receptacle, 20' Length Lateral Entry Module(LEM) D-sand Window /at 5202' MD, 3497 TVD 4-112" 11.6# L-80 Slotted Liner Swivel Liner Every Other Joint ConocoPhillips West Sak 7-5/8" Injector 1J-127 Tri-Lateral Completion 'D' Sand Lateral Bent Joint ~ 3-112" Guide Shoe 4-112" Liner Shoe, 11.6#, L-80 BTC Set ~ 12301' MD, 3661' TVD 4-112" X 7-518" Seal Bores Model'B' HOOK Hanger 3.68" ID 5-112" X 7518" ZXP Liner Top Packer wl Hold Downs Lateral Entry Module (LEMI Assembly ' ~- 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 t~ Indicates Correct 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 Seal Assembly 4.75" Seal OD Casing Sealbore Receptacle 20' Length 4-112" X 7-518" Model'B' HOOK Hanger / Seal Bores_ 3.68"ID 4-112" 12.6# Tub 3.833" Dritt 3.958" ID 5-112 Lim with Liner Hanger I Packer Assembly at +l- 5400' MD Lateral Entry Module(LEM) B-sand Window /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 --,;,-f'-- l~ _ _3-1/2"Guide Shoe 3.562" DB Nipple 7-5/8" ZXP op Packer dd Downs 5-112" X 7318" \`~ ~- Flex Lock Liner Hanger / , ~/ ~ing Sealbore Receptacle, 20' Length 0 Baker Hughes 2005. This document may not be reproduced or dlstrlbutetl, In whole or In part, In an7 by any means electronic or mechanical, including photocopying, recording, or by any Information s[o and retrieval system now known or herearter Invented, without wdtten permission from Baker Hughes As Planned rGii~ XKIJGiiES Baker Oil Tools Late ral Entrv Module (LEM) With Diverters and Isolation Lateral Access Diverter lateral Isolatlon Diverter GS Running Tool Shing Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbor e Drift) 'GS' Profile for Ceil Connector f Running/Retrieving ~ (1.00' Length) Snap INSnap Out I ~ fPOSilive Locating ~+ r Back Pressure Valve Collet (7.60' Length) I Lateral Isdatbn ~- / Flow-Thru Swivel ~ Seals (1.25' Length) Lateral Diverter ~ ~~ Hydraulic Di t Ramp ~ sconnec Isdadon/Mainbore i (1.50' Length) Diverter Sleeve ~~ Gs spear ' ~ Lateral Isolation (1.50 Length) Seals 6.85 tt Approx. OAL' ' I -Jars may be required in highly devia ted 16.5' Diverter Length 18.5' Sleeve Length or deep applications I6' approx length). 4.1/2" Liner Shoe, 11.6#, L-80 BTC Set ~ 12084' MD, 3712' TVD ~s`i~~ 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 Casing Shoe, Set at ~ NQr 3732' TVD (84 deg) Eauipment Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with divener: 4.63" Lateral Oritt, no divener or LEM: 3.88" Lateral Dritt, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-112" 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 • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-127 r~ L J 1/4 Mile Pool Scan & Summary 01 February, 2006 Sperry Drilling Serv~c~s ;~ ~~~~~ Closest in POOL Closest A roach: Reference Well: 1J-127 03 Plan Offset Well: 1J-101 Coortls. - CooMs. - ASP ASP 3-0 ctrct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E +)NV -) 0 Comments De th Incl. An le TRUE Azi. ND E(+)/W - 0° Comments POOL Min Distance POOL Min Distance (1182.01 ft) in POOL (1182.01 ft) in POOL (3380 - 3760 Subsea (3380 - 3780 Subsea ND) to 1 J-127 1162.01 I I &"+, 10450 86.69 359.82 3679.499 5952800 580585.4 7234.508 ND) to iJ-101 9575 90.79 359.95 3622.822 5952788 559384.8 7231.692 (wp03) Plan Closest A roach: Reference Well: 1J-127 03 Plan Offset Well: 1D-134 Coortls. - Coortls. - ASP ASP 3-D ctrtt ~= Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. : De th Incl. An le TRUE Azi. TVD E + /W - 0° Comments De th Incl. An le TRUE Azi. ND E + /Vy - (0° Comments POOL Min Distance POOL Min Distance (1058.4 ft) in POOL (1058.4 R) in POOL (3380 - 3760 Subsea (3380 - 3760 Subsea ND) to 1 J-127 1056.4 12089.89 84.99 0.79 3759.791 5954437 560553.7 8871.423 TVD)to iD-134 5825 13.31 181.46 3739.988 5955489 560456.3 9923.293 (wp03) Plan Closest A roach: Reference Well: 1J-12 7 03 Plan Offset Well: 1D-40A coons. - Coonls. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) Vew VS Min. Dist. - De th Incl. An le TRUE Azi. ND E(+)/W - 0° Comments De ih Incl. An le TRUE Azi. NO E + /yV - (0' Comments POOL Min Distance POOL Min Distance (1041.71 ft) in POOL ~ (1041.71 ft) in POOL (3380 - 3760 Subsea (3380 - 3760 Subsea ND) to 1 J-127 1041.71 12089.89 84.99 0.79 3759.791 5954437 560553.7 8871.423 ND) to 1 D-40A 6000 66.71 183.47 3755.007 5955447 560810.8 9878.133 (wp03) Plan Closest A roach: Reference Well: 1J-127 L1 03 Plan Offset Well: 1J-101 L1 Coortls. - Coortls. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. ~ De th Incl. An le TRUE Azi. ND E + /W - 0° Comments De th Incl. An le TRUE Azi. TVD E + /W - 0 Comments POOL in rstance POOL Min Distance (1191.23 ft) in POOL (1191.23 ft) in POOL (3380 - 3760 Subsea (3380 - 3760 Subsea ND) to 1J-127 Li 1191.23 8475 89.32 359.82 3508.175 5950842 560587.2 5276.281 ND) to 1J-101 L1 7600 86.63 359.73 3450.877 5950831 559397.4 5274.89 (wp03) Plan Closest A roach: Reference Well: 1J-127 L1 03 Plan Offset Well: 1D-134 Coortls. - Coortls. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. ~ De th Incl. An le TRUE Azi. ND E + /W - 0° Comments De th Incl. An le TRUE Azi. ND E + /W - 0 Comments POOL Min Distance POOL Min Distance (1052 ft) in POOL (1052 ft) in POOL (3380 - 3760 Subsea (3380 - 3760 Subsea ND) to 1J-127 Li 1052 ; J~o-3 12084.47 85.19 355.93 3602.847 5954449 560538.9 8883.507 ND) to 1 D-134 5825 13.31 181.48 3739.988 5955489 560456.3 9923.293 (wp03) Plan Closest A roach: Reference Well: 1J-127 L1 03 Plan Offset Well: 1D-40A Coortls. - Coortls. - ASP ASP 3-D ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /W - 0° Comments De th Incl. An le TRUE Azi. ND E + /W - 0 Comments POOL Min Distance POOL Min Distance (1045.05 ft) in POOL (1045.05 ft) in POOL (3380 - 3760 Subsea (3380 - 3760 Subsea TVD) to iJ-127 L1 1045.05 12084.47 85.19 355.93 3602.847 5954449 560538.9 8883.507 ND) to 1 D-40A 6000 88.71 183.47 3755.007 5955447 580810.8 9878.133 (wp03) Plan Closest A roach: Reference Well: 1J-127 L2 03 Plan Offset Well: 1J-101 L2 CooMS. - Coortls. - ASP ASP 3-0 ctrtt Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /W - 0° Comments De th Incl. An le TRUE Azi. TVD E + /yV- 0° Comments POOL Min Distance POOL Min Distance (1182.49 ft) in POOL (1182.49 ft) in POOL (3380 - 3760 Subsea (3380 - 3780 Subsea ND) to 1 J-127 L2 1182.49 ~'~.t~> ~ 6325 89.27 359.85 3408.378 5948699 560609.7 3133.583 ND) to 1J-101 L2 5450 88.72 354.05 3380.523 5948692 559427.6 3135.378 (wp03) Plan Closest A roach: Reference Well: 1J-127 L2 03 Plan Offset Well: 1D-134 Coortls. - Coortls. - ASP ASP 3-0 ctr-ct Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De th Incl. An le TRUE Azi. ND E + /yy - (0° Comments Depth Incl. An le TRUE Azi. ND E + /W - (0° Comments POOL Min Distance POOL Min Distance (841.83 ft) in POOL (841.83 ft) in POOL (3380 - 3760 Subsea (3380 - 3780 Subsea ND) to 1 J-127 L2 841.83 72307.76 85 359.84 3552.211 5954673 580545.8 9107.483 TVD) to 1 D-134 5825 13.31 181.46 3739.988 5955489 580458.3 9923.293 (wp03) Plan Closest A roach: Reference Well: 1J-127 L2 w 03 Plan Offset Well: 1D-40A Coortls. - Coortls. - ASP ASP 3-0 ctrtt Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. De ih Incl. An le TRUE Azi. ND E + /W - (0° Comments De th Incl. Angle TRUE Azi. ND E + /VJ - 0° Comments POO in Distance POOL Min Distance (842.39 ft) in POOL (842.39 ft) in POOL (3380 - 3760 Subsea (3380 - 3780 Subsea ND) to 1J-127 L2 642.39 ~ ~ 7 5P. t 12301.76 85 359.84 3552.211 5954673 580545.8 9107.463 TVD) to 1 D-40A 6000 88.71 183.47 3755.007 5955447 560810.8 9878.133 (wp03) Plan POOL Summary127.x1s 2/1/2006 10:11 AM ~ -s, 10500 ~ vQ~,~ 1 D-132 _ l/ '"^ 3g0p 10000 9500 ~, ` ` - - 365D 1 D-42 _ _ _ 365D 3g~D 1D-137 - - _ 3650 1D-102 P63 3400 3650 _ _ 1 D-102 3900 3900 1 D-134 1D-102L1 4 1/2" _ _ _ _ ------------ 365 - - 1J-12T 1/4 mile @ Toe T 1J-101 L1 PB1 _ :Mimuths to True PJorth agnetic North: 24.22° Magnetic Field Strength: 57563.1 nT Dip Angle: 80.77° ~ 1D-42L1PB1 i Date: 1/5/2006 i Model: BGGM2005 1D-42L1 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-127 Wellbore: Plan 1J-127 L2 ~' ~ Plan: 1J-127 L2 (wp03) c _ o Wells which violate the 1/4 mile in-pool scan are; 1 J-101, 1 D-40, + 1 D-40A 1 D-134 L O Z s 3 O 1 D-40 - - 1 J-D3 1J-127 1/4mile @ Heel 7 5/s" row 1 1000 --' ConocoPhillips PVa:'ik3 500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 West - /East +) (1000 ft/in ~.~ -a t Ap C O V M N r ~ d r 0 r i _. ~ ~ i N ~ O r ~ i ~ ~ ~~ i ~ ~ ~ ~~ i r ~ N __---- Q ~ _--"- r ~ --- r M ~ ~ C N ~ i J __..-------_ N ~-p JM d l!^ d ~ N ~ r iJ ~ _ d N ~- ~ >,'~~ ~ i~ ~~'~ ~ ~ ~C ~G ~ ~ N , O ~ i = ~ J ' ~ c.Q.aa~ ~ ~ c v >> ~ a _~ N :.~ y0 N 'ate- ~:;?~~ c v O ~ ~ oN ~a ~ ~~~ a ~ ~"~ ~ _~ ~ t ~ ~~+~ d ~° ~~ N dam' R ~ O ~ o .~ . . o a 0 _----- --_"__-- __-- ----- ~ --- O O O ~ ~ ~ ~ O ~ ~ `~ ~ O ~ m • • - 1139 SHARON K. ALLSUP-DRAKE < ~ ~ CONOCOPHILLIPS 1ssi~4~ ATO t53O - DATE ~` 700 G ST. F ANCHORAGE AK 99501 ~ l ~.~} ~~ - PAY TO THE ORDER OF ~~ /Jti~J s~ 6'„ ~ yj !rte - ~ -y-'p~[Al'~S 3 . Valid Up To 5000 Dollars JPMorganChase ~ 1 ,, JPMorgan Chase Bank, N:A. ~ c Columbus, OH MEMO r:044LL55LL~:528747L9D792711'LL39 . ~~~ J.. .. • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~~ ~~/ /Z 7 PTD# ZdIP ' ~ ~~ 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 , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception, assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Compan 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: I /25/06 C: \j ody\transmittal_checkl i st • • ^^ ~ : rn o ~ i , m ~ a N , a~ D v; : o ~ ~ ~ ~ ~ N ~ , ° : 3 a o, .N, ~ m; , : c; ~ ~, O: ~ ~ : c -o. ~ N ?, ~, t a , ai f ~ Q rn c ~ c. .5. ~ ui' aj, ~ ,a. , ~I ~ o. a p t ~ ~~ ~ ~ ~ m. ~ ~ ~ ~ N i .~ ~ ~~ ~ ~~ 4 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ N, . ~ C. f4~ N, N: ~~ ~ , ~, a o o o ~ c o ~ c ~ (fly O 3~ ~, O ~ Q. ~ O ~ ~ ~ ~ N~ ~ ~ ~~ , ~ U, . ~ CO, ' ti' o N' O, fl` _~~ O ( , 0 a: ~ O o0 N. U C: . ~ ~~ f6. ~ ~ ~ ~ ~ ~ ~ ~ ~ OL ~ f6. ~ N ~~ ~ N O) O. 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N. >, a a O ' ' ' .m ~, W ' t~ O, , 3 ~ ~ ~ y. ~ O. y C ' ' . U' O. N (6. S2, C, C, N, _ (6• C. O. ~, f6. "j.._ O N ~ p ;: m. ca. co. aai ° m, E m. 3 p ~ o v, ~ ~° ~° p o - = ~; ~, •° ~ `° ~ c; v, m, rn <o p c J U, E vi a - - -' U. ~ ~, a~: ~~ ~~ c -~ 3; Q' ~ ' ~ c, ~, I-` F- I-' ' ' 'u a~i ~ m > '~, a~ 4-~ o~~ '~~ ~~ ~ ' °: ~~~ ~ ~ ~~~ ~~~ c~~ Y U >' ~ p a; a~~ --~ c ~~~ ~~~ ~; in' a O ~; °_; O d o m ~ ° U - ~ ~', Q a; Q o p, v' ~n ~; ~ ~ v: ~; v m a v Q ~ a, °--; ¢, ~ ._ -, o; 0 O L m m ~ o ai ~', ~'; ~' o: m o-, o a~~ a~~ ~, ~ o v D W a O - N M V ~ CO I~ W O O N ~ M et ~ CO ~ 00 O) _ O N N N N M ~ N N ~ CO N N I~ O N N _ O O N M M N M 'ct M M M tf) CO M M I~ W M M_ d1 M U ~ _- ~' O C w 0 y O 0 N ~ O O O .. C U ~ ~ _ ~ ~ N W 0 i ~ ~ ~ ~ ~~ ~ ~ ~ °•~ a J N o r • y api rn O o _ a ~ ~ a W ~ n~ U ~ ~ a m w a ~ ~ Qcn Q 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 infom~ation, information of this nature is accumulated at the end of the f+le 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 13:32:18 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 n ~,~ Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: 1J-127 API NUMBER: 500292330600 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 26-JUL-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: W-0004376108 W-0004376108 W-0004376108 LOGGING ENGINEER: P. SMITH B. HENNINGSE B. HENNINGSE OPERATOR WITNESS: F. HERBERT F. HERBERT G. WHITLOCK MWD RUN 6 JOB NUMBER: W-0004376108 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: G. WHITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1739 FEL: 2324 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 122.30 GROUND LEVEL: 81.00 WELL CASING RECORD 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 6428.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE ~o~ -oy~ ~ ~yoa~- i • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE 1J-127 PB2 WELLBORE AT 10640'MD/3800'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4,6 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 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 1-4,6 REPRESENT WELL 1J-127 WITH API#: 50-029-23306-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11997'MD/3866'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; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2219.5 11939.5 RPD 2240.0 11946.5 RPS 2240.0 11946.5 RPM 2240.0 11946.5 FET 2240.0 11946.5 RPX 2240.0 11946.5 ROP 2268.0 11997.0 BASELINE CURVE FO R SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH s MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 6 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2219.5 6435.0 6435.0 10100.0 10100.5 10640.0 10640.5 11997.0 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 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2219.5 11997 7108.25 19556 2219.5 11997 RPD MWD OHMM 0.09 2000 34.3532 19414 2240 11946.5 RPM MWD OHMM 0.3 2000 24.9512 19414 2240 11946.5 RPS MWD OHMM 0.08 2000 21.1012 19414 2240 11946.5 RPX MWD OHMM 0.31 933.13 20.3 19414 2240 11946.5 FET MWD HOUR 0.19 370.46 2.60081 19414. 2240 11946.5 GR MWD API 19.39 121.04 71.4429 19441 2219.5 11939.5 ROP MWD FT/H 0.93 1979.89 159.07$ 19459 2268 11997 First Reading For Entire File..........2219.5 Last Reading For Entire File...........11997 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 6386.5 RPD 2240.0 6379.0 RPM 2240.0 6379.0 RPX 2240.0 6379.0 RPS 2240.0 6379.0 FET 2240.0 6379.0 ROP 2268.0 6435.0 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) 6435.0 TOP LOG INTERVAL (FT) 2267.0 BOTTOM LOG INTERVAL (FT) 6435.0 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 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 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 6435 4327.25 8432 2219.5 6435 RPD MWD020 OHMM 0.09 2000 18.9433 8279 2240 6379 RPM MWD020 OHMM 0.3 1888.17 13.0509 8279 2240 6379 RPS MWD020 OHMM 0.08 95.34 11.4718 8279 2240 6379 RPX MWD020 OHMM 0.31 72.2 10.0455 8279 2240 6379 FET MWD020 HOUR 0.19 370.46 3.4998 8279 2240 6379 GR MWD020 API 19.39 118.16 71.4963 8335 2219.5 6386.5 ROP MWD020 FT/H 1.58 490.49 144.91 8335 2268 6435 First Reading For Entire File..........2219.5 Last Reading For Entire File...........6435 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6379.5 10100.0 FET 6379.5 10100.0 RPM 6379.5 10100.0 RPD 6379.5 10100.0 RPS 6379.5 10100.0 GR 6387.0 10100.0 ROP 6435.5 10100.0 LOG HEADER DATA DATE LOGGED: 30-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10100.0 e 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: 6435.0 10100.0 86.2 95.4 TOOL NUMBER 087225 130908 6.750 6428.0 Mineral Oil Base 8.80 63.0 .0 24000 4.2 .000 .0 .000 116.6 .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 MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6379.5 10100 8239.75 7442 6379.5 10100 RPD MWD030 OHMM 2.13 2000 59.4487 7442 6379.5 10100 RPM MWD030 OHMM 3.95 2000 41.926 7442 6379.5 10100 RPS MWD030 OHMM 4.4 2000 34.91 7442 6379.5 10100 RPX MWD030 OHMM 4.26 933.13 34.8777 7442 6379.5 10100 FET MWD030 HOUR 0.19 115.3 2.45639 7442 6379.5 10100 GR MWD030 API 34.37 116.26 67.5536 7427 6387 10100 ROP MWD030 FT/H 1.32 406.02 167.856 7330 6435.5 10100 ~ • First Reading For Entire File..........6379.5 Last Reading For Entire File...........10100 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 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 10100.5 10640.0 FET 10100.5 10640.0 RPM 10100.5 10640.0 RPX 10100.5 10640.0 GR 10100.5 10640.0 RPD 10100.5 10640.0 ROP 10100.5 10640.0 LOG HEADER DATA DATE LOGGED: 31-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10640.0 TOP LOG INTERVAL (FT) 10100.0 BOTTOM LOG INTERVAL (FT) 10640.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6428.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES. (PPM): 24000 • FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 116.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefine d Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefine d 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 MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10100.5 10640 10370.3 1080 10100.5 10640 RPD MWD040 OHMM 4.58 35.97 9.97116 1080 10100.5 10640 RPM MWD040 OHMM 4.3 37.49 9.43112 1080 10100.5 10640 RPS MWD040 OHMM 4.15 30.3 9.03651 1080 10100.5 10640 RPX MWD040 OHMM 3.96 25.86 8.77612 1080 10100.5 10640 FET MWD040 HOUR 0.35 5.69 1.30584 1080 10100.5 10640 GR MWD040 API 51.36 94.41 75.5266 1080 10100.5 10640 ROP MWD040 FT/H 1.82 1979.89 236.17 1080 10100.5 10640 First Reading For Entire File..........10100.5 Last Reading For Entire File...........10640 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10640.5 11946.5 ROP 10640.5 11997.0 RPX 10640.5 11946.5 RPS 10640.5 11946.5 RPD 10640.5 11946.5 GR 10640.5 11939.5 FET 10640.5 11946.5 LOG HEADER DATA DATE LOGGED: 02-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11997.0 TOP LOG INTERVAL (FT) 10640.0 BOTTOM LOG INTERVAL (FT) 11997.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.0 MAXIMUM ANGLE: 92.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6428.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 29000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 115.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet • • Data Reference Point ..............Undefined Frame Spacing .. .......... ..... ....60 .lIN Max frames per record ..... .... ....Undefin ed Absent value ... ........... .... ....-999 Depth Units .... ........... .... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 L 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10640.5 11997 11318.8 2714 10640.5 11997 RPD MWD060 OHMM 6.59 276.87 21.7813 2613 10640.5 11946.5 RPM MWD060 OHMM 5.37 104.22 20.7248 2613 10640.5 11946.5 RPS MWD060 OHMM 5.21 50.15 17.2689 2613 10640.5 11946.5 RPX MWD060 OHMM 4.88 39.69 16.0353 2613 10640.5 11946.5 FET MWD060 HOUR 0.25 42.37 0.698982 2613 10640.5 11946.5 GR MWD060 API 55.47 121.04 80.6886 2599 10640.5 11939.5 ROP MWD060 FT/H 0.93 280.39 148.2 2714 10640.5 11997 First Reading For Entire File..........10640.5 Last Reading For Entire File...........11997 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 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 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 26 16:42:45 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 SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD LJ Scientific Technical Services Scientific Technical Services 1J-127PB1 500292330670 ConocoPhillips Alaska, Inc. Sperry Drilling Services 26-JUL-06 MWD RUN 3 W-0004376108 B. HENNINGSE 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 6428.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE ao~ -o~~- ~~y~~ ~ • PRESENTED. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 3 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL 1J-127 PB1 WITH API##: 50-029-23306-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10373'MD/3781'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; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2219.5 10315.5 RPD 2240.0 10322.5 FET 2240.0 10322.5 RPS 2240.0 10322.5 RPM 2240.0 10322.5 RPX 2240.0 10322.5 ROP 2268.0 10373.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2219.5 6435.0 MWD 3 6435.0 10373.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ........................ Datum Specification Block sub-type ...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2219.5 10373 6296.25 16308 2219.5 10373 RPD MWD OHMM 0.09 2000 37.2399 16166 2240 10322.5 RPM MWD OHMM 0.3 2000 26.1529 16166 2240 10322.5 RPS MWD OHMM 0.08 2000 22.1132 16166 2240 10322.5 RPX MWD OHMM 0.31 933.13 21.3657 16166 2240 10322.5 FET MWD HOUR 0.19 370.46 2.93919 16166 2240 10322.5 GR MWD API 19.39 118.16 69.9528 16193 2219.5 10315.5 ROP MWD FT/H 1.32 497.04 155.724 16211 2268 10373 First Reading For Entire File..........2219.5 Last Reading For Entire File...........10373 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 6386.5 FET 2240.0 6379.0 RPX 2240.0 6379.0 RPS 2240.0 6379.0 RPM 2240.0 6379.0 RPD 2240.0 6379.0 ROP 2268.0 6435.0 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: 23-MAY-06 Insite 66.37 Memory 6435.0 2267.0 6435.0 30.2 86.2 TOOL NUMBER 132482 96540 9.875 2257.0 • Lignosulfanate 9.10 52.0 9.2 600 4.3 2.000 79.0 1.520 106.0 2.000 79.0 2.300 79.0 Data Format Specification Re cord 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 Si ze 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 6435 4327.25 8432 2219.5 6435 RPD MWD020 OHMM 0.09 2000 18.9433 8279 2240 6379 RPM MWD020 OHMM 0.3 1888.17 13.0509 8279 2240 6379 RPS MWD020 OHMM 0.08 95.34 11.4718 8279 2240 6379 RPX MWD020 OHMM 0.31 72.2 10.0455 8279 2240 6379 FET MWD020 HOUR 0.19 370.46 3.4998 8279 2240 6379 GR MWD020 API 19.39 118.16 71.4963 8335 2219.5 6386.5 ROP MWD020 FT/H 1.58 490.49 144.91 8335 2268 6435 First Reading For Entire File..........2219.5 Last Reading For Entire File...........6435 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6379.5 10322.5 RPD 6379.5 10322.5 RPM 6379.5 10322.5 FET 6379.5 10322.5 RPS 6379.5 10322.5 GR 6387.0 10315.5 ROP 6435.5 10373.0 LOG HEADER DATA DATE LOGGED: 30-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10373.0 TOP LOG INTERVAL (FT) 6435.0 BOTTOM LOG INTERVAL (FT): 10373.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type ...0 6.750 6428.0 Mineral Oil Base 8.80 63.0 .0 24000 4.2 000 .0 000 116.6 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6379.5 10373 8376.25 7988 6379.5 10373 RPD MWD030 OHMM 2.13 2000 56.4458 7887 6379.5 10322.5 RPM MWD030 OHMM 3.95 2000 39.9061 7887 6379.5 10322.5 RPS MWD030 OHMM 4.09 2000 33.2834 7887 6379.5 10322.5 RPX MWD030 OHMM 4.02 933.13 33.2486 7887 6379.5 10322.5 FET MWD030 HOUR 0.19 115.3 2.35071 7887 6379.5 10322.5 GR MWD030 API 34.37 116.26 68.3156 7858 6387 10315.5 ROP MWD030 FT/H 1.32 497.04 167.169 7876 6435.5 10373 First Reading For Entire File..........6379.5 Last Reading For Entire File...........10373 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 Next File Name...........STSLIB.004 Physical EOF Tape Trailer 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 • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 26 16:58:31 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 5 SOB NUMBER: W- 0004376108 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: G. WHITLCOK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services 1J-127PB2 500292330671 ConocoPhillips Alaska, Inc. Sperry Drilling Services 26-JUL-06 MWD RUN 3 MWD RUN 4 W-0004376108 W-0004376108 B. HENNINGSE B. HENNINGSE F. HERBERT G. WHITLOCK 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 6428.0 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 IS AN OPENHOLE SIDETRACK EXITING THE 1J-127 PB1 WELLBORE AT 10100'MD/3791'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3-5 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 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 1-5 REPRESENT WELL 1J-127 PB2 WITH API#: 50-029-23306-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10939'MD/3808'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; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2219.5 10882.0 RPD 2240.0 10889.0 RPS 2240.0 10889.0 RPM 2240.0 10889.0 FET 2240.0 10889.0 RPX 2240.0 10889.0 ROP 2268.0 10939.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH L~ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 MWD 4 MWD 5 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2219 .5 6435.0 6435 .0 10100.0 10100 .5 10716.0 10716 .0 10939.0 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 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2219.5 10939 6579.25 17440 2219.5 10939 RPD MWD OHMM 0.09 2000 35.5182 17299 2240 10889 RPM MWD OHMM 0.3 2000 25.1119 17299 2240 10889 RPS MWD OHMM 0.08 2000 21.301 17299 2240 10889 RPX MWD OHMM 0.31 933.13 20.5836 17299 2240 10889 FET MWD HOUR 0.19 370.46 3.035 17299 2240 10889 GR MWD API 19.39 118.16 70.7544 17326 2219.5 10882 ROP MWD FT/H 1.32 1979.89 160.388 17343 2268 10939 First Reading For Entire File..........2219.5 Last Reading For Entire File...........10939 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 he ader 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 6386.5 RPD 2240.0 6379.0 RPM 2240.0 6379.0 RPX 2240.0 6379.0 RPS 2240.0 6379.0 FET 2240.0 6379.0 ROP 2268.0 6435.0 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) 6435.0 TOP LOG INTERVAL (FT) 2267.0 BOTTOM LOG INTERVAL (FT) 6435.0 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 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 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 6435 4327.25 8432 2219.5 6435 RPD MWD020 OHMM 0.09 2000 18.9433 8279 2240 6379 RPM MWD020 OHMM 0.3 1888.17 13.0509 8279 2240 6379 RPS MWD020 OHMM 0.08 95.34 11.4718 8279 2240 6379 RPX MWD020 OHMM 0.31 72.2 10.0455 8279 2240 6379 FET MWD020 HOUR 0.19 370.46 3.4998 8279 2240 6379 GR MWD020 API 19.39 118.16 71.4963 8335 2219.5 6386.5 ROP MWD020 FT/H 1.58 490.49 144.91 8335 2268 6435 First Reading For Entire File..........2219.5 Last Reading For Entire File...........6435 File Trailer Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Next File Name......... Physical EOF STSLIB.002 1.0.0 06/07/26 65535 LO STSLIB.003 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6379.5 10100.0 FET 6379.5 10100.0 RPM 6379.5 10100.0 RPD 6379.5 10100.0 RPS 6379.5 10100.0 GR 6387.0 10100.0 ROP 6435.5 10100.0 LOG HEADER DATA DATE LOGGED: 30-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory • • TD DRILLER (FT) 10100.0 TOP LOG INTERVAL (FT) 6435.0 BOTTOM LOG INTERVAL (FT) 10100.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 95.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6428.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 116.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6379.5 10100 8239.75 7442 6379.5 10100 RPD MWD030 OHMM 2.13 2000 59.4487 7442 6379.5 10100 RPM MWD030 OHMM 3.95 2000 41.926 7442 6379.5 10100 RPS MWD030 OHMM 4.4 2000 34.91 7442 6379.5 10100 RPX MWD030 OHMM 4.26 933.13 34.8777 7442 6379.5 10100 FET MWD030 HOUR 0.19 115.3 2.45639 7442 6379.5 10100 GR MWD030 API 34.37 116.26 67.5536 7427 6387 10100 ROP MWD030 FT/H 1.32 406.02 167.856 7330 6435.5 10100 • • First Reading For Entire File..........6379.5 Last Reading For Entire File...........10100 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 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 10100.5 10665.0 FET 10100.5 10665.0 RPM 10100.5 10665.0 RPX 10100.5 10665.0 GR 10100.5 10658.5 RPD 10100.5 10665.0 ROP 10100.5 10716.0 LOG HEADER DATA DATE LOGGED: 31-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10716.0 TOP LOG INTERVAL (FT) 10100.0 BOTTOM T,OG INTERVAL (FT) 10716.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.5 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6428.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 63.0 MUD PH: .0 • • MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 4.2 RESISTIVITY (OHMM) AT TEMP ERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 116.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10100.5 10716 10408.3 1232 10100.5 10716 RPD MWD040 OHMM 4.58 35.97 10.6013 1130 10100.5 10665 RPM MWD040 OHMM 4.3 37.49 10.0449 1130 10100.5 10665 RPS MWD040 OHMM 4.15 30.3 9.61587 1130 10100.5 10665 RPX MWD040 OHMM 3.96 25.86 9.37358 1130 10100.5 10665 FET MWD040 HOUR 0.35 5.69 1.28227 1130 10100.5 10665 GR MWD040 API 51.36 94.41 75.2886 1117 10100.5 10658.5 ROP MWD040 FT/H 1.82 1979.89 223.852 1232 10100.5 10716 First Reading For Entire File..........10100.5 Last Reading For Entire File...........10716 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10659.0 10882.0 RPM 10665.5 10889.0 RPX 10665.5 10889.0 RPS 10665.5 10889.0 RPD 10665.5 10889.0 FET 10665.5 10889.0 ROP 10716.5 10939.0 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: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn O1-JUN-06 Insite 68.18 Memory 10939.0 10716.0 10939.0 84.6 91.1 TOOL NUMBER 087225 130908 6.750 6428.0 Mineral Oil Base 8.80 72.0 .0 29000 3.2 .000 .0 .000 115.0 .000 .0 .000 .0 • • 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 MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10659 10939 10799 561 10659 10939 RPD MWDO50 OHMM 5.18 35.07 7.14636 448 10665.5 10889 RPM MWDO50 OHMM 4.02 32.08 6.68996 448 10665.5 10889 RPS MWDO50 OHMM 4.44 20.6 6.35096 448 10665.5 10889 RPX MWDO50 OHMM 4.29 17.29 6.15471 448 10665.5 10889 FET MWDO50 HOUR 0.26 34.8 8.47817 448 10665.5 10889 GR MWDO50 API 66.42 113.86 98.7714 447 10659 10882 ROP MWDO50 FT/H 3.32 245.24 151.592 446 10716.5 10939 First Reading For Entire File..........10659 Last Reading For Entire File...........10939 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 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