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Home My WebLink About207-099 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard Drive data drop 1H-111 50-029-23581-00 217133_1H-111_IPROFWFL_03JUL2023 1H-114 50-029-23584-00 217136_1H-114_IPROF_17Oct23 1H-115 50-029-23605-00 218053_1H-115_IPROF RSTWFL_09May2022 1H-116 50-029-23594-00 218012_1H-116_IPROFWFL_05Jul2023 1H-117 50-029-23602-00 218032_1H-117_PPROF-WFL_06July23 218032_1H-117_WFL_18Oct23 1H-119 50-029-23591-00 217178_1H-119_WFL_07Jul2023 1J-102 50-029-23317-00 206110_1J-102_RPPG_18Jul2023 1J-107 50-029-23366-00 207107_1J-107_PPROF_10May2022 1J-162 50-029-23360-00 207080_1J-162_LDL_03May2022 1J-170 50-029-23310-00 206062_1J-170_Temp-Pres_11Jul2023 1J-176 50-029-23364-00 207099_1J-176_LDL_11May2022 4of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38340 T38341 T38342 T38344 T38343 T38345 T38346 T38347 T38348 T38349 T38350 2/29/2024 1J-176 50-029-23364-00 207099_1J-176_LDL_11May2022 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:34:11 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1J-176 KUPARUK RIV U WSAK 1J-176 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 1J-176 50-029-23364-00-00 207-099-0 W SPT 3159 2070990 1500 452 452 452 452 156 169 157 156 OTHER P Guy Cook 8/21/2022 MITIA post patch per sundry 322-314. Testing was completed with a Little Red Services pump truck and calibrated gauges. 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-176 Inspection Date: Tubing OA Packer Depth 1100 1990 1930 1915IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220821061754 BBL Pumped:3 BBL Returned:2.6 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 MITIA post patch per sundry 322-314. James B. Regg Digitally signed by James B. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1J-176 (PTD 207-099) Report of suspect annular communication Date:Friday, April 15, 2022 3:15:34 PM Attachments:image001.png From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, April 11, 2022 12:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 1J-176 (PTD 207-099) Report of suspect annular communication Chris, KRU 1J-176 (PTD #207-099) initial diagnostics were completed and DHD was unable to complete an MIT-IA due to the inability to reach test pressure. An IA liquid leak rate was established at 7.5 gallons per minute at 950 psi. Additional diagnostics will be conducted to investigate the failure mechanism. Depending on the results of the diagnostics, the proper paperwork for continued injection or repair will be submitted at that time. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF1 & CPF3 Sent: Thursday, April 7, 2022 1:20 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1J-176 (PTD 207-099) Report of suspect annular communication Chris, KRU 1J-176 (PTD 207-099) is exhibiting unexplained IA pressure increase. DHD was preparing the well for state witnessed testing by bleeding the IA pressure down, but the IA immediately repressurized post bleed. The well will be shut in and freeze protected as soon as possible. The plan is for DHD to perform initial diagnostics including an MITIA and pack off testing after which a plan forward will be determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1J-176 (PTD 207-099) Report of suspect annular communication Date:Friday, April 15, 2022 3:19:10 PM Attachments:AnnComm Surveillance TIO for 1J-176.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Thursday, April 7, 2022 1:20 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1J-176 (PTD 207-099) Report of suspect annular communication Chris, KRU 1J-176 (PTD 207-099) is exhibiting unexplained IA pressure increase. DHD was preparing the well for state witnessed testing by bleeding the IA pressure down, but the IA immediately repressurized post bleed. The well will be shut in and freeze protected as soon as possible. The plan is for DHD to perform initial diagnostics including an MITIA and pack off testing after which a plan forward will be determined. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 1J-176 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1J-176 2022-04-02 1177 940 -237 IA Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.124 Top (ftKB) 44.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 94.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.415 Top (ftKB) 43.7 Set Depth (ftKB) 3,792.4 Set Depth (TVD) … 2,299.1 Wt/Len (l… 68.00 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE 10.75x9.875"@2080' OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 40.5 Set Depth (ftKB) 11,000.0 Set Depth (TVD) … 3,250.7 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-m Casing Description D-SAND LINER HH OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 10,236.8 Set Depth (ftKB) 10,634.2 Set Depth (TVD) … 3,209.3 Wt/Len (l… 15.50 Grade L-80 Top Thread BTC-m Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,236.8 3,162.1 81.82 HANGER Baker Model 'B-1' Hook Hanger 9 5/8" x 7" (Inside csg) 7.510 10,257.8 3,165.0 82.20 HANGER Baker Model 'B-1' Hook Hanger 9 5/8" x 7" (Outside csg) 6.290 10,264.1 3,165.9 82.31 XO BUSHING Crossover Bushing 4.920 10,410.1 3,183.4 83.08 ECP RTD-2 ECP 4.650 10,602.3 3,205.5 83.22 XO Reducing Crossover 5-1/2" BTC box X 4-1/2" 3.930 Casing Description B-SAND LINER OD (in) 5 1/2 ID (in) 4.900 Top (ftKB) 10,457.7 Set Depth (ftKB) 17,880.0 Set Depth (TVD) … 3,206.4 Wt/Len (l… 15.50 Grade L-80 Top Thread Hyd 521 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,457.7 3,189.1 83.29 PACKER MLZXP Liner Top Packer 9-5/8" ( 8.43" ODx 7.50" ID) 7.500 10,478.9 3,191.6 83.44 HANGER FlexLock Liner Hanger 7" x 9-5/8" ( 8.30" OD x 6.19" ID) 6.190 10,484.2 3,192.2 83.48 XO BUSHING XO Bushing, 7" hyd 563 x 5-1/2" Hyd 563, (7.65" OD x 4.85" ID) 4.850 10,485.4 3,192.3 83.49 SBE 190-47 Casing Seal Bore Ext., Hyd 563 B x P, (6.26" OD x 4.75" ID) 4.750 Casing Description D-SAND LINER LEM OD (in) 4 1/2 ID (in) 3.958 Top (ftKB) 10,210.2 Set Depth (ftKB) 10,496.3 Set Depth (TVD) … 3,193.5 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT-m Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,210.2 3,158.3 82.09 PACKER BAKER TORQUEMASTER PACKER 813-47 x 38 (9.625") 3.950 10,222.7 3,160.1 81.87 HANGER LEM Above Hook Hanger 4 1/2" x 7 5/8" x 9 5/8" 3.960 10,236.8 3,162.1 81.82 HANGER LEM Inside Hook Hanger 4 1/2" x 7 5/8" x 9 5/8" 3.688 10,294.7 3,169.8 82.86 NIPPLE CAMCO DB NIPPLE 3.562 10,493.0 3,193.2 83.55 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.958 Top (ftKB) 35.8 Set Depth (ft… 10,219.8 Set Depth (TVD) (… 3,159.7 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-m Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 35.8 35.8 0.00 HANGER Vetco Gray 11" x 4-1/2" w/ 4.909" MCA Top Connection 3.900 504.5 504.0 5.47 NIPPLE 4-1/2" Camco "DB-6" Nipple w/ 3.875" No-Go Profile 3.875 10,112.2 3,146.2 83.36 SLEEVE Baker 4.5"CMD Sliding Sleeve w/ Camco 3.812" 'DB' Profile CLOSED 3-25-14 3.812 10,191.0 3,155.7 82.43 LOCATOR Seal Assembly Locator O.D. 5.24" I.D. 3.88" 3.880 10,195.0 3,156.3 82.36 PBR Baker Polish Bore Receptacle O.D. 8.27" I.D. 3.88" 3.880 10,213.6 3,158.8 82.03 ANCHOR Baker Anchor Seal Assy. Crossovers 6.02" O.D. I.D. 3.86" 3.860 10,215.8 3,159.1 81.99 SEAL ASSY Baker "ML" Anchor Seal Assy. I.D. 3.86" 3.860 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 11,046.0 11,498.0 3,253.9 3,260.1 WS B, 1J-176 9/14/2007 32.0 SLOTS Entire Liner Alternating slotted/solid pipe 2.5" x .125" in 4 circumferential rows/ft 3" centers staggered 18 deg, 3' non-slotted ends 11,788.0 12,239.0 3,258.0 3,254.4 WS B, 1J-176 9/14/2007 32.0 SLOTS 12,520.0 12,964.0 3,248.6 3,247.3 WS B, 1J-176 9/14/2007 32.0 SLOTS 13,246.0 13,717.0 3,246.7 3,242.5 WS B, 1J-176 9/14/2007 32.0 SLOTS 14,011.0 14,479.0 3,244.8 3,243.2 WS B, 1J-176 9/14/2007 32.0 SLOTS 14,780.0 15,250.0 3,243.5 3,239.2 WS B, 1J-176 9/14/2007 32.0 SLOTS 15,510.0 15,985.0 3,237.7 3,242.7 WS B, 1J-176 9/14/2007 32.0 SLOTS 16,241.0 16,717.0 3,241.7 3,229.8 WS B, 1J-176 9/14/2007 32.0 SLOTS 16,975.0 17,365.0 3,224.7 3,227.1 WS B, 1J-176 9/14/2007 32.0 SLOTS 17,621.0 17,837.0 3,222.6 3,209.1 WS B, 1J-176 9/14/2007 32.0 SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 2,318.2 1,902.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2007 Comment SSSV: NIPPLE1J-176, 4/3/2014 12:29:03 PM Vertical schematic (actual) B-SAND LINER; 10,457.7- 17,880.0 SLOTS; 17,621.0-17,837.0 SLOTS; 16,975.0-17,365.0 SLOTS; 16,241.0-16,717.0 SLOTS; 15,510.0-15,985.0 SLOTS; 14,780.0-15,250.0 SLOTS; 14,011.0-14,479.0 SLOTS; 13,246.0-13,717.0 SLOTS; 12,520.0-12,964.0 SLOTS; 11,788.0-12,239.0 SLOTS; 11,046.0-11,498.0 INTERMEDIATE 10.75x9.875"@2080'; 40.5- 11,000.0 D-SAND LINER HH; 10,236.8- 10,634.2 D-SAND LINER LEM; 10,210.2- 10,496.3 SEAL ASSY; 10,215.8 ANCHOR; 10,213.6 PBR; 10,195.0 LOCATOR; 10,191.0 SLEEVE; 10,112.2 SURFACE; 43.7-3,792.4 GAS LIFT; 2,318.2 NIPPLE; 504.5 CONDUCTOR; 44.0-80.0 HANGER; 35.8 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: SHOW SLEEVE CLOSED Last Mod By lehallf End Date 4/2/2014 KUP INJ KB-Grd (ft) 43.41 Rig Release Date 10/4/2007 Annotation Last WO: End Date 1J-176 H2S (ppm) Date ... TD Act Btm (ftKB) 17,940.0 Well Attributes Wellbore API/UWI 500292336400 Field Name WEST SAK Wellbore Status INJ Max Angle & MD Incl (°) 94.09 MD (ftKB) 17,683.99 Notes: General & Safety End Date Annotation 10/4/2007 NOTE: MULTI-LATERAL WELL - 1J-176 (B-SAND), 1J-176L1 (D-SAND) 8/17/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 1J-176, 4/3/2014 12:29:04 PM Vertical schematic (actual) B-SAND LINER; 10,457.7- 17,880.0 SLOTS; 17,621.0-17,837.0 SLOTS; 16,975.0-17,365.0 SLOTS; 16,241.0-16,717.0 SLOTS; 15,510.0-15,985.0 SLOTS; 14,780.0-15,250.0 SLOTS; 14,011.0-14,479.0 SLOTS; 13,246.0-13,717.0 SLOTS; 12,520.0-12,964.0 SLOTS; 11,788.0-12,239.0 SLOTS; 11,046.0-11,498.0 INTERMEDIATE 10.75x9.875"@2080'; 40.5- 11,000.0 D-SAND LINER HH; 10,236.8- 10,634.2 D-SAND LINER LEM; 10,210.2- 10,496.3 SEAL ASSY; 10,215.8 ANCHOR; 10,213.6 PBR; 10,195.0 LOCATOR; 10,191.0 SLEEVE; 10,112.2 SURFACE; 43.7-3,792.4 GAS LIFT; 2,318.2 NIPPLE; 504.5 CONDUCTOR; 44.0-80.0 HANGER; 35.8 KUP INJ 1J-176 ... 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 1J-170 50-029-23310-00 906951584 West Sak Injection Profile Field & Processed 30-Jan-21 0 1 2 1J-176 50-029-23364-00 906948912 West Sak Injection Profile with TMD3D Field & Processed 29-Jan-21 0 1 3 1J-180 50-029-23329-00 906811709 West Sak Injection Profile with TMD3D Field & Processed 27-Jan-21 0 1 4 1Y-19 50-029-22391-00 906880907 Kuparuk River Packer Setting Record Field- Final 3-Jan-21 0 1 5 2H-09 50-103-20050-00 906910408 Kuparuk River Multi Finger Caliper Field & Processed 8-Jan-21 0 1 6 2H-09 50-103-20050-00 906960677 Kuparuk River Packer Setting Record Field- Final 3-Feb-21 0 1 7 2N-333 50-103-20525-00 906882125 Kuparuk River Multi Finger Caliper Field & Processed 21-Dec-20 0 1 8 3A-08 50-029-21445-00 906879883 Kuparuk River Leak Detect Log Field- Final 20-Dec-20 0 1 9 3B-06 50-029-21336-00 906905927 Kuparuk River Leak Detect Log Field- Final 5-Jan-21 0 1 10 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: 2070990 E-Set: 34728 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 14 2019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L] Plug PerforaticL] Fracture Stimulate ❑ Pull Tubing ❑ /-Xk0A2tAtdwn ❑ Performed: Suspend ❑ Perforao Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New PcL1 Repair Well ❑ Re-enter Susp Well ❑ Other: Convert WINJ to WAG Q 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development p ❑ Stratigraphic ❑ Exploratory ❑ Service [Z 207-099 3. Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23364-0000 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25662, 25661, 25663, 385172 i<Ru 1 J-176 9. Logs (List logs and submit electronic and printed data per 20AA(;25.071): 10. Field/Pool(sg Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17,940 feet Plugs measured None feet true vertical 3,202 feet Junk measured None feet Effective Depth measured 17,837 feet Packer measured 10,216 feet true vertical 3,209 feet true vertical 3,159 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' Surface 3,748' 13.375" 3,792' 2,299' Intermediate 10,959' 9.625"x10.75" 11,000' 3,251' Liner 7,422' 5.5" 17,880' 3,206' Perforations: Horizontal slotted liner Measured depth: 11,046-17,837' feet True Vertical depth: 3,254'-3,223' feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 10,220' MD 3,160' TVD Packers and SSSV (type, measured and true vertical depth) Baker "ML" Anchor Seal Assembly 10,216' MD 3,159'TVD SSSV TYPE - NA NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 7000 1200 515 Subsequent to operation: 10 1000 0 1700 11550 14. Attachments (required Per 20 nq0 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and Correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-433 Authorized Name: Sydney Autry Contact Name: Sydney Autry Authorized Title: Production Engineer Contact Email: sydney.autry@cop.com Au[aorized Signature: Date: 117J/et Contact Phone: 907-265-6813 /6 /W1611, 4BDMSe'LjNoy 14 2019 Form 10-404 Revised 4/2017 Submit Original Only 1J-176 Description of Well Events Date Event Summary 10/26/2019: Convert to WAG ConocoPhillips Aieska, Inc. W3 LET: SURFACE. 437-3 SO 4� SLEEVE, 10.1122 ..E: 10,Ind osnxD KUP INJ WELLNAME U-176 WELLBORE Jell Attributes Max Anal cid N.—Wellbore APUUWI WellGorestatua Ids°) r noose ent BBV: NIPPLE H251pine, gnnoianon End Dale^ 4 Laxt W0: e est Tag Annobnon Depin mx0) ens wre 1st TO, on N pi -ii ast Rev Reason JOJ Valve Annomtion Part31u Eno -i:v Reason: SHOW SLEEVE CLOSED 422014 iJ-17 asing Strings --IT-o- slog oesnxpsmn )NOUCTOR oO9n1 20 type mon) 19.12 omxa) 44.0 sen oepm mkD) 80.0 seroepm (TVDL.. wI B0.0 94 sing oescrlptlon OO 133( in.) 13318 CAMCO ID nnl Y241 Top mKBl 43.7 Mpm mNBlaNDeptn 4 RVDL.RFACE 2,299.1 6B ang oezcxpuon TERMEDIATE .]54.8]5"I@2080' oD Bn) 9518 0.0 m8n) 8.83 183,7Z Top (xKB) 40.5 seroepm mics) 11,000.0 set oepm jNlo... WI 3,250) 40 slugDLINE on BAND LINER HH 51Q 5112 IDIMI 4.95 i0P.21i 10,236.8 Sln'gpm meal 10,634.2 3N Oepm RVDL. Wt 3,209.3 15 ner Details Top Red) To7(1dllnKBl Topincll°) xem Des Com 10,236.8 3,162.1 1 81.82 HANGER Baker MD6eIW1—H-0.'kHanger9 csg) 10,2578 3,165.0 82.20 1 HANGER Baker MDgel'B-1 ook Hanger TY, csg) 10,264.1 3,1659 1 82LW XO BUSH ING Crossover Bu3hing 10,4101 3,1834 83.08 ECP RTD -2 ECP 10,602.3 3,205.5 I 8322 jX0 Reducing Crossover 5-1IP'BTCboxX 4-1? In, Description LINER oo 9n1 512 ID(ip Topm ) set DegnmKal aN Deptn lNol... m;AND 49O 10,457] 1],880.0 3,206.4 15. Ter Details Top mess Top "us Red) Top In=119 I Ile-oes Com 10,457.] 3,189.1 83.29 PACKER Mi Liner Top —-Packer 10,478.9 3,191.6 83.44 HgNGER FlexLock mer Hanger "x I8" IDI 10,484.2 3,1922 83.48 XO BUBHING XD ushm9.T'hyg56 x5-12"Hy x4.85 -IDI 10,485.4 3,192.3 83.48 SBE 1904acing NEI Bum Ext, Hy OD x 4.75" ID) ngoes-lpU.n AND LINER LEM OD lin) 412 mono) TOPM-) 3N DepIM1 mKBI 3Moepm lTVo)._ Wilt 3.96 10,210.2 10,496.3 3,1 935 12.1 Ier Details ron (nKB) Top (TVD)ORKs) Topmdfl nem Des cum 10,2102 3,158.3 82.09 PACKER —8 BAI RTORGUEMA TERPACKER (9.625") 10,222.7 3,160.1 87 HANGER LEM Above Hook Hanger 412"x7! 10,236.8 3,162.1 81.82 HANGER CEM Inside Hook Hanger 4117 x 75 10,294.7 3,169.8 82.86 NIPPLE CAMCOD NIPPLE 10,493.0 3,1932 8355 FSIEALASSV BAKER SEALASSEMBLV Ding Strings +e Dee=I pti=n string mi ING 4112 1D (in) IT Inks) cel Depen (n.. set oepm ITvol 1... wrylbmi 396 35.8 102198 31597 1260 repletion Details Top(Nol (nKe) mxR) Top In=I P) m Im oos Com & Slots 1J-176 st ad on N TopfND) JOJ Valve Duch Part31u TRO Run Tap lnKBl need)Mahe MMeI aery Type type gni opal)Run Palo Com 1 2,3182 1,902.1 CAMCO KBMG 1 GAB LIFT DMV BK -5 LOW 0.0 10132007 Conocof'F►illips KUP INJ WELLNAME 1J-176 WELLBORE 1J-176 1'"''' AAaska, 1 u -ire, IRISS0191 N CNPM Notes: Genera l&Safety Vaticalstlwnayc facNap Entl Oatr pnnotetlon ASS..L1 " "- RANCER ase.... ...__....._ 10/42007 NOTE'. MULTI -LATERAL WELL-iJ-1]fi BSAND (- ). (- I DSAND Bl1 ]/2010 NOTE: VIEW SCHEMATIC wIAlaska SCM1emaGc9.OREV cONDucroa', a4.oa9.6 NIPPLE, 5045 OASLIFT, 23162 SURFACE, 4373792.4, SLEEVE, 10,112.2 LOCATOR;10,19f0 PBR; 10195,0 ANCHOR, f0, 215.6 3EAL ASSY', 10,215.8 OSAND LINER LEM,102192- 10g983 0 -SAND LINER IN, 10,236.6 10,9342 INTERMEDIATE 1075 S75®2090':405 fi W30 SLOT6, 11p49,IY1 I-------- SLOTS'.11, 7WIU122390� — SLOTS, 12,5 TIZVI SLOTS, 13246.6137170 SLOTS, 14011D1447ID0 — SLOTS, 14 SOL .-I529.0� SLOTS) ".s100-15,9550 SLOTS, 1SN1416.71TC0 SLOTS, 16, 975.61] 365.0 SLOTS: 17 621 V 78370_ _ S SAND LINER, 10%7S_ J KUP INJ WELLNAME 1J-176 WELLBORE 1J -176L1 ConoeoPhrlhps 1,.f' ell Attributes Max Angle &MD TD 1In Alaska, Inc. FieM W¢IlCon ppVOWI W nw. SlNus nil°) MOIttKB) pal Blm lttKB) SMAI 5.10 12,496.19 V,820.0 K2B 1ppinl OHa pnnofatlan EnSD.Ie FSGSeill Rip Rekesa Date SEEVeN NIPPLE Last WO: 43,41 10/4/200] u-1ffiLI, nr131A1e 14OR., Last Tag ( AnneYtbn DeWh(nKBI End W wenEon Last mW By .............................Vveolcmemv5c .................Last HANGER: 35.8 Tag: 1J-1]611 Imosbor Last Rev Reason AnnWatbn End Dale Welke msemW By Rev Reason: SHOW SLEEVE CLOSED 3l15I2014 1J-1]611 M1ipshkf roR;uoe3.o Casing Strings NIPPLE:04.5— Deeedpibn OD(s) mOn) T.1drK6) set Depm (nxB) seL Depm [1vo1... wuLen p... creae rop Thread '-SAND LINER 4112 348 10,601.1 17,783.5 3,141.6 11.60 L-80 BTC Liner Details Top lnKBl ToplrvDl lnRel rop ma (°) Item Des NominnllD n1 CASLIFT 23162 10,fi01.1 3,196.1 87.07 SLEEVE J.0"Baker"HR"Liner Seting Sleeve wi 6'TSR 6280 6 I 10,609) 3,196 6 87.25 XO Reducing XO Sub T Hytl 521 X 5-12" Hyd 521 4.900 ; 4.7-3,7924_ 10,5562 3,1984 88.21 XO Reducing 1,2' 521 Box X 4 Ir Hyd5 I Pin X0(39" 3.920 15 EiIE 10,1122 Perfocations B$tots - TOR;,O,I9tA PBR10,155,0OR; 102136 10,215.9 TopINO) BM1nINDI Oens111 HH; to a Top lflKB) Stm(SKS) (BKS) (flKB) LinkedZ ne DablshoCllt 10,661.0 11,118. 3,19883,198.6 W J- 91812007 320 SLOTS Entire lineraheme0ngTERMEoIALEsonedlso gig 5" id e2®mea•, 4os 11, See %.125In 4 CPWmferentim EM. 10,210]rOwelX, S' centers L).463 staggere018 deg, 3' non stoned ends 11,367.0 11,868.0 3,200.4 3,202.1 ws D, 1J- 9282007 32.0 SLOTS 17611 _ 12,126.0 12,642.0 3,1979 3,175.7 W D, 1J -. 92820W-320 SLOTS 1]611 '— 12,899.0 13,3]00 3,1)0] 3,1]26 WS D, 1J- 9281200] 32.0 SLOTS SLOTS: m.e9ln11.1ieo= _ 7GL1 _ 13,6290 14,139.0 3,173.4 3,169.1 WS D, 1J- 9282007 32.0 SLOTS 8Li 14,398.0 14,867.0 3,169.3 3,1684 WE D, J- 9261007 32.0 SLOTS _ _ 17811 15,123.0 15,6430 3,168.4 3,157.1 W 92812007 32.0 SLOTS 176L1 $tors', n,3n.o-1,,eee.o— _ 15,8910 16,362.0 3,166.4 3,162.6 WE , J-9182007 32.0 SLOTS 176L1 18,621.0 17,138.0 3,162.3 3,149.3 WS J- 9/282007 32.0 SLOTS 176L1 17,3510 17,7380 3,1433 3,141.9 ,1J- 92&2007 32.0 SLOTS 1]611 SLOTS I 12,120U12.64L— Notes: General & Safety — — End D. Annotabon 101312007 NOTE:MULTI-IATERAL WELL -1J -176(0 -SAND), U-17611 (D -SAND)) 8/171010 NOTE. VIEW SCHEMATIC w/Alaska ScM1ematic9.OREV .Lora; 12990013,320.0— SLOTS meet/ O1a139.o� SLore, 10,860.14,8670 SLOLS 161COY109i &LOTS, i6e9101a3fi20� aLOTa', 18, 621.01],1360�.� .LOTS; 17,3510-17.739,0 0.5ANO ONES; 10.8011- f n'.7835� THE STATE °fALASKA. GOVERNOR MIKE DUNLEAVY Sydney Autry Senior Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU U-176 Permit to Drill Number: 207-099 Sundry Number: 319-433 Dear Ms. Autry: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, � V, tM. Price Chair DATED this day of October, 2019. ABDMS `'OCT 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 SEP z W 2019 x e--� =, IAC) 1. Type of Request: Abandon LJ Plug Perforations U Fracture Stimulate LJ Repair Well Ll Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Convert to WAG INJ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stmtigraphic ❑ Service ❑' 207-099 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23364-0000' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑� 1 J-176 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25662, 25661, 25663, 385172 1 Kuparuk River Field /West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total DeptF TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 17'1 '3Z�3,206' 17,837 3209 1708 None None Casing . �; Length Size MD TVD Burst Collapse Conductor 80' 20" 80' 80' Surface 3,748' 13.375" 3,792' 2,299' Intermediate 10,959' 9.625"x10.75" 11,000' 3,251' Liner 7,422' 5.5" 17,880' 3,206' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slots: 11,046'-17,837'MD Slots: 3,205-3,260'TVD 4.5" L-80 10,220' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = Baker "ML" Anchor Seal Assembly, SSSV = NONE Packer= 10,216' MD/3,159'TVD, SSSV = N/A 12. Attachments: Proposal Summary 0 Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati na hic g p ❑ Development ❑ Service ❑� ' 14. Estimated Date for 15. Well Status after proposed work: 1 -Oct -19 Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑' GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sydney Autry Contact Name: Sydney Autry Authorized Title: Production Engineer Contact Email: sydney.autry@cop.com Authorized Signature: Date: 1,2d d0lq Contact Phone: 907-265-6813 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 101 - L1 3 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: flTo 20 � RBDMSI�OCT 10 Post Initial Injection MIT Req'd? Yes ❑ No 2019 Spacing Exception Required? Yes F-1NoSubsequent Form Required:—tf%Lt- ' APPROVED BY Approved by:1 COMMISSIONER THE COMMISSION Date: O 117'1- /o/.fl/ 9 ORIGINAL Fornh4-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate `/ ConocoPhillips September 20, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 1J-176 from Water Injection service to Water Alternating Gas Injection service. 1J-176 was completed as an injector on 10/4/2007. No rig workovers have been completed at 1J-176 since being drilled & completed. Enclosed you will find 10-403 Applications for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1J-176, and 1J -176L1 (PTD 207-099 and 207-100). Also attached are supporting documentation, including a map of the target injection area. Well integrity testing since completion includes: • IA & OA MIT to 3000 psi, Tbg & IC PO tested to 5000 psi, OCPO tested to 1000 psi (on rig) • 02/29/08 — Passing MITIA (Waived SW) to 3000 psi • 05/24/09 — Passing State Witnessed MITIA to 1980 psi • 05/22/10 — State Witnessed MITIA Inconclusive due to high volume to fill annulus • 06/04/10 — Passing State Witnessed MITIA to 1900 psi • 03/14/14 — MITIA Failed, unable to pressure up above 950 psi o 03/25/14 — Coil shifted CMD sleeve closed (was discovered open during diagnostics), MITIA passes to 2500 psi post shifting sleeve • 05/15/14 — Passing State Witnessed MITIA to 2000 psi • 10/09/14 — Passing MITIA to 3000 psi • 04/17/18 — Passing MITIA to 1700 psi • 05/09/18 — Passing State Witnessed MITIA to 1800 psi Sincerely, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 1J-176 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J-176 (PTD# 207-099) from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1J-176 was completed as an injector on 10/4/2007 to provide waterflood support in the D and B West Sak sands to offset producers 1 J-178 and 1 J-174. The top of the Ugnu C sand was found at 5,830' MD / 2,586 TVD The top of the Ugnu B sand was found at 7,209' MD / 2,772' TVD The top of the Ugnu A sand was found at 7,989' MD / 2,875' TVD The top of the West Sak D sand was found at 10,236' MD / 3,162' TVD Area Map with Y< mile radius around target injection zone (see attached): The map attached shows that there are two wells (1J-160 and KRU State 2) that have penetrations in the West Sak interval located within a 1/4 mile radius of the 1 J-176 penetrations of the West Sak interval. Offset producers 1J-174 and 1J-178 are also reviewed in the AOR detail. . `-- ------- - ----on -- - n -of. -...------------n --- --- ------------------------- 11-1 ----------- 0..---- ... Mechanical Condition of Well to be Converted: The mechanical condition of West Sak injector 1J-176 is good. The injection tubing/casing annulus is isolated via a TorqueMaster packer located at 10,210' MD (3,158' TVD). The last state -witnessed MITIA was performed on May 9, 2018 to 1800 psi. CBL and interpretation of the cement quality: See attached AOR detail for offset well condition. The 20" Conductor was cemented with 326 sx of AS1 The 13-3/8" Surface casing was cemented with 630 bbls 10.7ppg Lead cement, followed by 99 bbls 12.Oppg Tail ement, 245 bbls of cement to surface. The 9-5/8"x10-3/4" Intermediate casing was cemented with 921 sx 12.5ppg DeepCrete. TOC determined to be at 7830' MD per CBL. S Conditions for approval (if applicable): § , - - Ir °( ° {\/{i T11NR10E T10NR10E 33 9 1J-176 Open Interval — 1J-1761-1 Open Interval 1/4 Mile Radius 1J-176 01 1/4 Mile Radius 1J -176L1 01 Well Pad Wells within Radii r Kuparuk PA _ _ CPA] Leases ADL025660 ADL025663 U-174 1J -174L1. IJ -174P21. 1J-174PS2 ADL385172 34 1J-160, 1J -160L1: -1600; W-1600101 1J -176L1' 1,1-176 1rnu STATE 2 iJ-158. 1 }15801 1J -i 78 1-0L1 N 0 0.1 0.2 0.3 0.4 0.5 Miles ADL025661 Kuparuk PA ConocoPhillips Alaska, Inc. U-176 10-403 Sundry Date: 12/21/2016 projects\GRA Wells\iJ_176\iJ_176_sundry_I F KUP INJ 1J-176 1...VlIVt.1.71-11111I(1J wen Attributes Max Angle $MD TD wau,ore APvuvn Fol wine wellmm shlos rid pl MD mKBI Ad 500292336400 WEST SAK INJ 94.09 1],683.99 _ Btm mKI 1],9400 Comment H291ppmf Dale S65V: NIPPLE pnuh[lon End Data LastWO: K Gplryl RIB Relvbae Data 43.41 10/41200] uan,43'30ta limos pM HARDER; 358vinsual ma Ammumbon CepIM1 mK) Entl peq Last Tag: Fenotalbn les[Motl By End Dah Rev Reason: SHOW SLEEVE CLOSED lehallf 4/22014 as ng ngs COVODC OR; a,v09a.D Mpple. 501.5 CasN.Dxen ptlan OD (in) CONDUCTOR 20 ID lin, Top gmid li Depfn(XKB) 19.124 44.0 80.0 Set Deptn INO1... 80.0 WGLen 9... Grade 9d 00 H40 Top TMead WELDED Casing Description OD llnl SURFACE 133A ID(inl Top mKBl Set pepin mKB) 12.415 43.] 3,792.4 yl Depin (N01._ 2,299.1 WIILen (L.. Gra]e 68.00 L-tw TapTM1reatl ETC GSIng Deecdptlon OD lin) INTERMEDIATE 95/8 i0.)Sx9.875'@2050' ID pnl Top (XKBI Sat Dep[n (XKBI 8.835 605 11,000.0 Set epm lN01... 3,250.] wvLen p... Gram 40.00 L-80 Top IDrxtl Si GASLFT:2.SN2 Casing 0xcrlplion OD (nl MANG LINER HH 512 ID (in) iep lXKB) Set'a"7KBI 4.950 10236.8 t0,fi34.2 Set"T's (NDI... 3,209.3 Wlllan (I... GrMe 15.50 L-80 TDp nreatl BTGm Liner Details SURFACEQ.]17gi SLEENE, 10,1132 Top pti Top (WIN (NNER Topmcl p) nem Dx Com Nominal IS (m) 10,236.8 3.162.1 81.82 HANGER Baker Model'B-1' Hook Hanger 998" x]°(Inside 7.510 LP.R;1.1810 ag) peR110.sed 10,257.8 3.165.0 82.20 HANGER Baker Model 3-1- Hoak Hanger 996' x 7' (Orvieto 6.290 PL NOR,'0.21.a oag) sFAAssT, 10.2158 10,264.1 3,165.9 82.31 XO BUSHING Crossover Bushing 4.920 10,410.1 3,183.4 83.08 ECP RTD -2 ECP 4.850 10602.3 3,205.5 83.22 XO Reducing Crossover 5-11 "BTC box X4.112" 3.930 Cesingpxcripnon Oplinl 1(ml Top meB) Set Dept, XXKBI Set Depth(N%... ear -am (... Gram TOP TM1rxtl B -SAND LINER 512 4.900 10457.7 17,880.0 3,206.4 15.50 L-80 Hytl 521 Liner Details Top RIKB) TOPI1VDUARTH TOpincin Item DesWm Nominal IS nt (in 104577 3,189.1 83.29 PACKER MLZXPUner Top Packer9-518"(8.4XODx750"10) 7.500 10,478.9 3,191.6 83.44 HANGER FlexLock Liner Hanger ]'x9-518"(8.30"ODx6.19" 6.190 DSAND LINEN LEM: 10210.2 ID) 1A.a 10,484.2 3,1922 83.48 XO BUSHING XOEN"m,]'hyd 563 x 5-1a' Hyd 563,(7.65' OD 4.850 DsgrvD LINER HH 10239.3 ..9342 x 4.85" ID) 0,4:5.4 3,192.3 83.49 SBE 190-07 Casing Seal Bore Ext., Hytl 563 e x P, (6.26' 4.750 IMEfl MEDIATE -Din 01 1075Ki.BT4'®.... kEp - - _ _ ming OD 9n)(inf Top Set Depth BI am Depth NDf... We an (I Grine 0 -SAND LINER LEM 412 3.958 10,210.2 10,496.3 3,193.5 12.601-80 Tap T,reatl IBT-m SLOTS, 11045611.4880 - 1 -mer DOiaiIB Top (Mob Top (ND)mHBI Top Incl pf Ilam Oes Cam Nominal lD n) -- - 10,210.2 3.158.3 82.09 PACKER BAH ERTOROUEMASTERPACKER813d7x38 3.950 - - (9.625") - - 10,222.7 3,160.1 81.8]HANGER LEMAbove Hook Hanger412"x7518"x SEE. 3.960 SLOTS, 11,)89.0.12.239.0-- 10,2368 3,162.1 81.82 HANGER TEM Inside Hook Hangar 4112"x7 Mi. x998" 3.688 - 10,2947 3,169.8 82.86 NIPPLE CANDO DB NIPPLE 3D52 10,493.0 3,193.2 83.55 SEALASSY 9ERSEALASSEMBLY 3.880 Tubing Strings - Trans; Cason ion Siring Ma... ID(Inl Top IKKB) Sel Oeptn m.. set Depl, (Npl (... W[(ICXt) Grade IToConnec,an TUBING 412 3.958 35.8 10,219.8 3,159.] 12.60 L-80 IBT-m Sl01sn2.520.0-12 Sai 0-- - Completion Details " Toplei Ihm Dx COLO Nominal i0 Onl To, IRK.) T;ggaSy. - - - 35.6 0.00 HANGER Venal Gray 11"x412"w14.909" MCA Top Connegion 3.900 - - 504.5 5.4] NIPPLE 4112'Cam. "DB-6"Nipple w/3.8 NNOGaPWIe 3.875 10,112.2 83.36 SLEEVE Saker4.5"CMD Sliding Sleeve w/Gemco 3.812"'DE' 3.812 SLOTS; 13,M5013,)1T0� Profile CLOSED 3-25-14 - 10,191.082.43 LOCATOR Seal M.cer yLanai O.D. 5.24"ID. 3.88" 3.880 10,195.0 82.36 PBR Baker Poli anBore passes ,a 0. D. 8.27"LD. 3.88" 3.880 - - 10,213.682.03 ANCHOR Baker Anchor Seal Assy. Crossovers 6.02' O.O. I.D. 3.86° 3,860 SLOTS 14,011 Ci 10,215.861.99 SEAL ASSV Baker"ML" Anchor Seal Asay. LD. 3.88° 3.860 Perforations & Slots - - Dens Dens - - - - '- - Top MIN B1m1rv01 Top(XKB) Btm WKIR mKel (XKBI Zone Data b Type Co. -498 11,046.0 0 3,253.9 3,2fi0.1 WSB7J-tJ6 9114200] --U7 SLOTS Enilze Liner Akemeting smrS 14Pea.0.15,2'A.O� :laded/solid pipe 2.5" 125" in d 4rcumferenlialmws103- centersslaggeredl8 deg. 3' non -sloped ends _ _ 11,]88.0 12,239.0 3,258.0 3,254.4 WS B, 1J -D6 91141200] 32.0 SLOTS SLOTS, 1. IS beta o- '- 12,520.0 12,964.0 3,248.6 3,24].3 WS B, 1J-1]6 91141200] -2 0 SLOTS - - 13,24fi.0 13,]1].0 3,246) 3,242.5 WSe1J-1]6 9114200] 528 SLOTS 14,011.0 14479.0 3,244.8 3,243.2 WS B, 1J-176 91148007 32.0 SLOTS _ 14,780.0 15,250.0 3,243.5 3,239.2 AS B. 1J-176 911412007 32.0 SLOTS 15,510.0 15,985.0 3,23]] $242.] WSB, 1J-076 911412007 32.0 SLOTS sLoisafl241 ut9,n)a- _ 10241.0 1Q]9.0 3,241] 3,229.8 WS B, 1J-176 91142007 32.0 SLOTS _ - 16,975.0 17,365.0 -3224 7 3, 22 7.11 WS B, 1J-1 76 91148007 32.0 SLOTS -17n7 - _ ],621.0 0 3,222.6 3,209.1 W8 P. 1J-1]6 911412007 32.0 SLOTS Mandrel Inserts SLOTAR.Shisa,1).3ai - St as - - - - _ N Top IXKBI Top IND) mKBI Make Moral �Oj Sery Valx Type Los Type Pan 3,e fnl TRO Run (Psi) Run Data Com 2,3182 1,902.Y CAMCO KBMG 1 GAS LIFT DMV BWS 0.000 0.0 1013/200) SLOTS:17.62161).83T0�- BLAND LINER, 1OA67T- 1],8900 KUP INJ r ...,.. a.•m_ 1J-176 ..w Nf•VL L PLE I IIIIr kE 1A1M,UVMUQ1 ,NO eNca a e me- HPNOER:3B� o s: enom a corv0Uci0R; 4aom.o � Em ome A tO14200J NOTE:MULTI -LAI ERAL WELL-IJ-D6(BSAND), 1J -176L1 -1JEL1 (MSAND) ulvvlE: 504 5— eli A2010 NOTE: VIEW SCHEMATIC WAE;Wk SCFematic9.CREV SASLIFI;23182 SUWALE,43]3.i924. SLEEVE;101122 LOCATOR; 10,1910 PSR 10115.0 ANCHOR: 102135 SEILASSY: 10.215& OSANO LINER LEM; 10.2102 1o,495a o.fiauo uxER NN; 1o.z3as 1o.m42 IMERMEOIATE 10TS90>5"®2N0'; 40.5 11.W00 SLOTS:11,0450.114SE O� SLOTS. 11 MS 12,239.0 SLOT6; 125A,6129640� SLOTS', 13.24S.S1a,7170� SLOTS: 14.0110,14, 4M 0 - SLOTS 141.. S.250.0� SLOTS; 15,510615...0 SLOTS; 16241046.7120� SLOTS; 1&, 9)501], 3 O -- SLOTS I7 6N a17,&R0- S-SMD LINER, 10.45]]- 1J,m00'_ Hgm 23� ae Y y� uooK ooy v°p n Am 'Ud S-mia mE ono w� � 3e pao .. o :n oa o on o_Ey r g3ao 3 ®o u =S"se a ad F€A Oji ;n O �3a xK N r m3 m d ° m �8 4 y � 3 z n m Y lRZ a6 m m n m 3 _ - 3 ;s3 A..- myy 9a lKi H E 3 Rab o 'sa a Zai F - ¢' p �a um¢ = J y < ;s CO //�� 1 1 tn a 00 og aim _ %, _ ar o a CCD 3 �� ifl m N 6}"i � Q �• m 10 mo � a m n o soap N moog x 3€5 G 779 F9 rCLm " g a0 g° _ �en �T. `� I-__✓ �_S , O _baa �t �'o -. � _� Y cm pS��. ' --pp,Victoria T (CED) From: Autry, Sydney <Sydney.Autry@conocophillips.com> Sent: Thursday, October 3, 2019 3:16 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]West Sak wells: Conversion from WI to WAG 11-118, 1J-176 Victoria, Regarding your note below, the AIO allowing WAG injection at West Sak is AIO 2B (Conservation Order 406). For well 1J-176, there are no offset Kuparuk wells are two Kuparuk wells in the AOR (1J-03 & 1D-36). • 1D-36 4 Surface casing is set at 7,047' MD below the top of the West Sak D sd) • 1J-03 4 Surface casing is set at 7,784' MD below the top of the West Sak D sd) in the AOR. For 1J-118 there (reaching 1,243'MD/618'TVD (reaching 1,612'MD/673'TVD Please let me know if you have any additional questions. Thanks, Sydney Autry West Sak IE/1J Drillsite Engineer ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 + GKA RWO Coordinator From: Autry, Sydney Sent: Saturday, September 28, 2019 6:33 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Victoria, Sorry for the slow reply - I have been on the slope the last few days and will be up here until Wednesday. I am aiming to send you an updated AOR in the next couple days. Thank you, Sydney Autry From: Loepp, Victoria T (CED) <victoria.loeppPalaska.aov> Sent: Wednesday, September 25, 2019 10:55 AM To: Autry, Sydney<Svdnev.AutryC@conocoohillios.com> Subject: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Sydney, For any Kuparuk wells identified in the AOR of these wells, is the surface shoe above or below the WSak? 1 Please identify which AIO allows this WAG injection. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria LoeopPalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victorio.Loepg@alaska.aov -2500 3000 500292336400 2070990 KRU U-176 1686 FSL 2461 FWL TWP: 11 S - Range: 10 E - Sec. 35 for 1 AOGCC Sept. 23, 2019 -2500 -3000 - L _ 3 3900 _ 4000 4100 42 00 4300 4400 " _ � 4500 4600 n0o 40D 9 WOO 5000 5100 5200 530 5W 555W 5600 5]W 5W 5990 000 6100 6] W c 6300 640 650 MW —U C 660 -IT 7000 ]000 _—. ]zW 730 7,830' MD: Operator's 740 . pic ]500 .00 n cement top from CBL. mudstone 8100 n u A 63UG s -- " 6400 6500 660 6600 690 Mo _ ---o ` Cement isolates Ugnu sands __-95 � from underlying West yak �mud5tone 9600 sago sands injection intervals. x._ mudstone im000000o tazoo West ak K WESi�AKD 0409 __- Infection intervals in -_._, IWO 10600 _ _ 1741 for 1 AOGCC Sept. 23, 2019 -2500 -3000 • MEMORANDUM S State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 14,2018 TO: Jim Regg512.1i P.I.Supervisor (Reip 1 SUBJECT: Mechanical Integrity Tests c G CONOCOPHILLIPS ALASKA,INC. 1J-176 FROM: Lou Laubenstein KUPARUK RIV U WSAK 1J-176 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK IJ-176 API Well Number 50-029-23364-00-00 Inspector Name: Lou Laubenstein Permit Number: 207-099-0 Inspection Date: 5/9/2018 .- Insp Num: mitLOLI80510145340 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1J-176 - Type Inj W .[TVD 3159 Tubing 566 566 - 566 ' 567 - PTD 2070990 Type Test SPT 1Test psi 1500 IA 1175 1800 - 1765 - 1755 - BBL Pumped: 2.6 BBL Returned: 2.1 OA 160 - l 166 - 161 - 160 Interval 4YRTST P/F P Notes: SCANNED JUN J 42018 Monday,May 14,2018 Page 1 of 1 der 1--- • 0 in X ra 0 O i V �W Doo U -0O +0 1 'CO > NC W 4- Y O a) 0 al JM CO p + U O o S 03 v, tli Y a C O � CO 'd a � � a > a Fs. n n n n +-, a) N 0 ;3- m E +, O n J O R ca CVS m CO �- -O *'' L , c13 tn w C t0 U N G N ~ CD -. 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N C ap• (Y in CM �, E U 5 to v gm , Y d' C C L XX Z Q n N U) t0 O N u i-- a r o n CO +_+ E 0p rd i d MINIM aQ o o � � � £ z ln ..Y caei U g t6 W CO O CM 0 a _ E= a a Q • s Image Project Well History File Gover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original fife, may be scanned during a special rescan activity or are viewable by direct inspectionnof the file. - ~~y Well History File Identifier Organizing (done) RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: o,,ea iiiiuumiiuim DIGITAL DATA ~iskettes, No. , ^ Other, No/Type: o Ae,v~~„d~ iuiiiuiaiiiiiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: j ^ Other:: BY: Maria Date: ~- { l D ~ lsl Project Proofing III II'III IIIII II III BY: Maria Date: ' j /s/ Scanning Preparation S x 30 = SQ + ~_ =TOTAL PAGES~~ (Count does not include cover sheet) BY: Maria Date: ~ a ' ~ D ~ /s/ Production Scanning Stage ~ Page Count from Scanned File: _~_~(Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: ~ ~ ~ I ~g /s/ ~M Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO ' r BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II II II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked I~I II~~II ~II (~~~ II p 10!6/2005 Well History File Cover Page.doc • • 1 k 1 - 11 Regg, James B (DOA) From: CPF1 Prod Engr [n1269 ©conocophillips.com] Sent: Saturday, February 18, 2012 3:10 PM Z I i8 h To: CPF1 Prod Engr; 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; Gauer, Jenn L; Jensen, Marc D Gau L; Subject: LPP /SSV Returned to Service for 1J -176 on 02/18/2012 Jim, The low pressure pilot (LPP) on injector 1J -176 (PTD# 207 -099) was returned to service late on 02/18/2012 after the wellhead injection •ressure stabilized above the settin• of the low •ressure •ilot. Current wellhead pressure is 541 psig; injection rate is 1161 bwpd. This pilot had been defeated on 09/23/2011 in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Daniel Bearden /David Lagerlef CPF1 Production Engineers n1269(a�conocophillips.com 907 - 659 -7493 &AWNED FEB 2 3 2012 pager 907 - 659 -7000 #765 'rod Engr January 08, 2012 2:50 PM coder @alaska.gov'; 'jim.regg @alaska.gov' 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; Gauer, Jenn L; Jensen, Marc D PP /SSV Returned to Service for 1J -136 on 01/07/2012 Tom / Jim, The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155)) was returned to service late on 01/07/2012 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 591 psig; injection rate is 537 bwpd. This pilot had been defeated on 01/06/2012 in accordance with "Administrative Approval No. CO 406B.001." The LPP on injector 1J -176 (PTD# 207 -099) remains defeated; it is currently operating at a wellhead pressure of 463 psi with an injection rate of 1186 bwpd. We will notify you when it is returned to service. Please let me know if you have any questions. David Lagerlef /Dan Bearden CPF1 Production Engineers n1269(cr�conocophillips.com 659 -7493 pager 659 -7000 765 'rod Engr ieptember 23, 2011 9:44 AM !nn L; 'tom.maunder @alaska.gov'; 'jim.regg @alaska.gov' 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 PP /SSV defeated on 1J -136 & 1J -176 1 Tom and Jim • The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155) was defeated on 09/23/2011 when the injector was returned to service after being shut in since July 14, 2011. As of 0940 hrs on 09/23/2011, wellhead injection pressure is 383 psi; injection rate is 906 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." Also, the low pressure pilot (LPP) on injector 1J -176 (PTD# 207 -099) was defeated on 09/23/2011 when the injector was returned to service after being shut in since August 1, 2011. As of 0940 hrs on 09/23/2011, wellhead injection pressure is 174 psi; injection rate is 313 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 on either well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Daniel Bearden /David Lagerlef CPF1 Production Engineers n1269(a�conocophillips.com 907 - 659 -7493 pager 907 - 659 -7000 #765 2 • <2lif iJ -ice Regg, James B (DOA) pTh 2612 g9Oi From: CPF1 Prod Engr [n 1269@conocophillips.com] Sent: Sunday, January 08, 2012 2:50 PM To: 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; Gauer, Jenn L; Jensen, Marc D Subject: LPP /SSV Returned to Service for 1J -136 on 01/07/2012 Tom / Jim, The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155)) was returned to service late on 01/07/2012 after the wellhead injection pressure stabilized above the setting of the low pressure pilot. Current wellhead pressure is 591 psig; injection rate is 537 bwpd. This pilot had been defeated on 01/06/2012 in accordance with "Administrative Approval No. CO 406:.01." The LP' o in' -ctor 1J -176 (PTD# 207 -099 emains defeated; it is currently operating at a wellhead pressure of 463 psi with an injection rate of 1186 bwp•. rfe will notify you when it is returned to service. Please let me know if you have any questions. David Lagerlef /Dan Bearden ��) CPF1 Production Engineers �' r D FEB n1269(u7conocophillips.com 659 -7493 pager 659 -7000 765 I, Marc D y, January 05, 2012 4:09 PM ender @alaska.gov'; 'jim.regg @alaska.gov' 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; Gauer, Jenn L; CPF1 Prod Engr PP /SSV Defeated for 1J -136 on 01/05/2012 Tom and Jim: The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155) was defeated on 01/05/2012 when the injector was returned to service after being shut in since December 14, 2011. As of 1600 hrs on 01/05/2012 , wellhead injection pressure is 390 psi; injection rate is 530 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 on either well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Marc Jensen West Sak Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 907 - 265 -6573 1 marc .d.jensen(a�conocophillips.com 1 • • Page 1 of 1 Maunder, Thomas E (DOA) From: CPF1 Prod Engr [n1269 @conocophillips.com] Sent: Friday, September 23, 2011 9:44 AM To: Gauer, Jenn L; 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 Subject: LPP /SSV defeated on 1J-136 & 1J-176 Tom and Jim The low pressure pilot (LPP) on injector 1J -136 (PTD# 206 -154 and 206 -155) was defeated on 09/23/2011 when the injector was returned to service after being shut in since July 14, 2011. As of 0940 hrs on 09/23/2011, wellhead injection pressure is 383 psi; injection rate is 906 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." Also, the low pressure pilot (LPP) on injector 1J -176 (PTD# 207 -099) was defeated on 09/23/2011 when the injector was returned to service after being shut in since August 1, 2011. As of 0940 hrs on 09/23/2011, wellhead injection pressure is 174 psi; injection rate is 313 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 on either well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Daniel Bearden /David Lagerlef CPF1 Production Engineers n1269 @conocophillips.com g `` ` 907 - 659 -7493 pager 907 - 659 -7000 #765 I I 9/23/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~ Repair w ell r plug Pertorations ^ Stimulate [~ Other ~ isolate B Sand Alter Casing ~ Pull Tubing ~ F>3rforate New Wol [ j Waiver ~j Time Extension ~ ~ ("'~ Change Approved Program ~ Operat. Shutdow n ~ perforate ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Status: 5. Permit o Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory ~ ~ 207-099 3. Address: Stratigraphic ~ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 ~ 50-029-23364-00 7. Property,Des~gnatiorti;, 8. Well Name and Number: ~ ADL 25661, 25662, 25663, 385172 ' 1 J-176 9. Field/Pool(s): ~. Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 17940 feet Plugs (measured) 10295 true vertical 3202 feet Junk (measured) None Effective Depth measured 17880 feet Packer (measured) 10216 true vertical 3206 feet (true vertucal) 3159 Casing Length Size MD ND Burst Collapse CONDUCTOR 36 20 80 80 0 0 SURFACE 3749 18 3792 2299 0 0 D-SAND LEM 286 9.625 10496 3193 0 0 INTERMEDIATE 10960 10.79 11000 3251 0 0 B-SAND LINER 7422 8.43 17880 3206 0 0 Perforation depth: Measured depth: Slots: 11046-11498; 11788-12239; 12520-12964; 13246-13717; 14011-14479; 14780-15250; 15510- 15985; 16241-16717; 16975-17365; 17621-17837 True Vertical Depth: 3254-3260; 3258-3254; 3250-3247; 3247-3243; 3245-3243; 3244-3239; 3238-3243; 3242-3229; 3225- 3226; 3224-3209 rj ~l ;; r ~ A Tubing (size, grade, MD, and TVD) 4.5, L-80, 10220 MD, 3160 TVD Packers & SSSV (type, MD, and TVD) SEAL ASSY -BAKER "ML" ANCHOR SEAL ASSY. I.D. 3.86" @ 10216 D SAFETY VLV - 4-1/2" Camco "DB-6" Nipple w/ 3.875" No-Go Profi _ D 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~-~ ~% ~ Q 1, (~ Treatment descriptions including volumes used and final pressure: „ ~, ~- ~ r,~x ~7~risslon ~ ~ " ; ,t' n : ; ~ v 12. Representative Daily Average Production or Injection Data ; •;p-.rq.~r ~~ Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 983 1230 1311 Subsequent to operation 425 866 707 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory ~ Development ~ Service n 15. Well Status after work: Oil r Gas r WDSPL Daily Report of Well Operations X ` GSTOR r WAG n GASINJ n WINJ ~ SPLUG rj 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact Bob Christensen/Darrell Humphrey Printed Name Ro ert D. Christensen Title Production Engineering Specialist Signature ~ Phone: 659-7535 Date q / ~ D { G RBDMS SEP 0 9 2010 ~~~"' l.. ~ `~-r3-Cd ~>~/a Form 10-404 Revised 7/2009 Submit Original Only 1 J-176 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/30/10 INSTALL 3.562 RBP W/ 3.5 PX PRONG @ 10295 RKB, FP W/70 BBL SD `,, , . ConocoPhillips A1~lsica. In: Well Confi - 1J-178 9/52010 5:00:02 PM Schematic -Actual HANGER, 36 --~7fi:. :-..7~r CONDUCTOR, 44-80 SAFETY VLV, 504 GAS LIFT, 2,318 SURFACE, 44-3,792 SLEEVE, 10,112 LOCATOR, 10,191 L PBR, 10,195 ANCHOR, ~- 1o,z1a L SEAL ASSY, 10,216 PLUG, 10 295 D-SAND LINER LEM, 10,210-10,486 D-SAND LINER 10,237-10,634 NTERMEDIATE 10.75x9.875", ~ 1 40-11,000 _ ~ slots, a 11,046-11,498 ;~ I~ _ slots, 11,788-12,239 ' ~I I ~' ~ Slots 12,520-12,984 Slots, 13,246-13,717 Slots, 14,011-14,479 : a slots, 14,780-15,250 i slots. 15,510-15,985 Slots, 16,241-18,717 slots, 18,975-17,385 slots, 17,821-17,837 B-SAND LINER, ~~ 10,456-17,880 1E , TD (iJ-178), 17,940 li KUP 1J-176 Well Attributes Max An le & MD TD Wellbore API/UWI 500292336400 Fieltl Name WEST SAK Well StaWs INJ Incl (°) 94.09 MD (RKB) 17,683.99 Act Btm (ftK6) 17,940.0 Comment N2S (ppm) SSSV: NIPPLE Date Annotation Last WO: Entl Date KB-Grtl (R) 43.41 Rig Release Date 10/4/2007 Annotation Last Tag: Depth (ftK6) Entl Date A nnotation Rev Reason: Correct Perf Zones B Liner, Set Last Mod By Imosbor End Date 9/5/2010 Casin Strin s Casing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 44.0 80.0 80.0 94.00 H-40 Casing Description SURFACE String 0... 13 3/8 String ID ... 12.415 Top (ftK6) 43.7 Set Depth (f... 3,792.4 Set Depth (TVD) ... 2,298.6 String Wt... 68.00 String ... L-80 String Top Thrd BTC Casing Description INTERMEDIATE 10.75x9.875" String 0... 95/8 String ID ... 8.835 Top (RKB) 40.5 Set Depth (f... 11,000.0 Set Depth (TVD) ... 3,247.6 String Wt... 40.00 String ... L-80 String Top Thrtl BTC-m Casing Description D-SAND LINER HH String 0... 5 1/2 String ID ... 4.950 Top (ftK6) 10,236.8 Set Depth (f... 10,634.2 Set Depth (TVD) ... 3,209.3 String Wt... 15.50 String ... L-80 String Top Thrtl BTC-m Liner Details Top (RKB) Top Depth (TVD) (RKB) Top Incl (°) Item Description Comment Nomi... ID (in) 10,236.8 3,163.9 83.81 HANGER Baker Model 'B-1' Hook Hanger 9 5/8" x 7" (Inside csg) 7.510 10,257.8 3,166.1 83.72 HANGER Baker Model 'B-1' Hook Hanger 9 5/8" x 7" (Outside csg) 6.290 10,264.1 3,166.8 83.69 XO BUSHING Crossover Bushing 4.920 10,410.1 3,183.4 82.95 ECP RTD-2 ECP 4.650 10,602.3 3,205.5 83.22 XO Reducing Crossover 5-1/2" BTC box X 4-112" 3.930 Casing Description B-SAND LINER String 0... 5 1/2 String ID ... 4.900 Top (RKB) 10,457.7 Set Depth (F... 17,880.0 Set Depth (TVD) ... 3,206.4 String Wt... 15.50 String ... L-80 String Top Thrtl Hyd 521 Liner Details Top (RKB) Top Depth (TVD) (ftK6) Top Incl (°) Item Description Comment Nomi... ID (in) 10,457.7 3,189.7 84.07 PACKER MLZXP Liner Top Packer 9-5/8" (8.43" ODx 7.50" ID) 67.5... 10,478.9 3,191.8 83.95 HANGER FlexLock Liner Hanger 7" x 9-5/8" (8.30" OD x 6.19" ID) 6.190 10,484.2 3,192.4 83.91 XO BUSHING XO Bushing, 7" hyd 563 x 5-1/2" Hyd 563, (7.65" OD x 4.85" ID) 4.850 10,485.4 3,192.5 83.91 SBE 190-47 Casing Seal Bore Ext., Hyd 563 B x P, (6.26" OD x 4.75" ID) 4.750 Casing Description D-SAND LINER LEM String 0... 4 1/2 String ID ... T 3.958 op (RKB) 10,210.2 Set Depth (f... 10,496.3 Set Depth (TVD) ... 3,193.6 String Wt... 12.60 String ... L-80 String Top Thrd IBT-m Liner Details Top (RKB) Top Depth (TVD) (ftK6) Top Incl (°) Item Description Comment Nomi... ID (in) 10,210.2 3,158.4 82.09 PACKER Baker Torquemaster Packer 813-47 x 38 (9.625") 3.950 10,222.7 3,160.1 81.87 HANGER LEM Above Hook Hanger 4 1/2" x 7 5/8" x 9 5/8" 3.960 10,236.8 3,163.9 83.81 HANGER LEM Inside Hook Hanger 4 1l2" x 7 5/8" x 9 5/8" 3.688 10,294.7 3,170.0 83.57 NIPPLE Camco4-1/2"'DB' Nipple I.D. 3.562" 3.562 10,493.0 3,193.3 83.86 SEAL ASSY Baker Seal Assembly 4-1/2" STL Box up 3.880 Tubin Strin s Tubing Description TUBING String 0... 41/2 String ID ... T 3.958 op (ftK6) 35.8 Set Depth (f... S 10,219.8 et Depth (TVD) ... 3,159.7 String Wt... 12.60 String ... L-80 String Top Thrd IBT-m Com letion Details Top (RKB) Top Depth (TVD) (ftK6) Top Incl (°) I tem Description Comment Nomi... ID (in) 35.8 35.8 -0.14 HANGER Vetco Gray 11" x 4-1/2" w/ 4.909" MCA Top Connection 3.900 504.5 504.0 5.39 SAFETY VLV 4-112" Camco "DB-6" Nipple w/ 3.875" No-Go Profile 3.875 10,112.2 3,146.4 83.82 SLEEVE Baker 4.5"CMD Sliding Sleeve w/ Camco 3.812"'DB' Profile(OPEN) 3.812 10,191.0 3,156.0 82.43 LOCATOR Seal Assembly Locator O.D. 5.24" I.D. 3.88" 3.880 10,195.0 3,156.5 82.36 PBR Baker Polish Bore Receptacle O.D. 8.27" I.D. 3.88" 3.880 10,213.6 3,158.9 82.03 ANCHOR Baker Anchor Seal Assy. Crossovers 6.02" O.D. I.D. 3.86" 3.860 10,215.8 3,159.1 81.99 SEAL ASSY Baker "ML" Anchor Seal Assy. I.D. 3.86" 3.860 Other In Hole W ireline retrievable lu s, valves, um s, fish, etc. Top (RKB) Top Depth (TVD) T (ftK6) op Incl 1°) Description Comment Run Date ID (in) 10,295 3,170.0 83.56 P LUG 3.562" RBP w/ 2.3" x4.40' PX PRONG 8/30/2010 0.000 Perforations & Slots Top (RKB) Btm (RKB) Top (TVD) (ftK6) Btm (TVD) (RKB) Zone Date Shot Dens (sh-•• Type Comment 11,046 11,498 3,253. 5 3,259.5 WS B, 1J-176 9/14/2007 32.0 Slots Entire Liner Alternating slotted/solid pipe 2.5" x .125" in 4 circumferential rowslft 3" centers staggered 18 deg, 3' non-slotted ends 11,788 12,239 3,257. 8 3,254.4 WS B, 1J-176 9/14/2007 32.0 Slots 12,520 12,964 3,249. 9 3,247.3 WS B, 1J-176 9/14/2007 32.0 Slots 13,246 13,717 3,246. 7 3,242.5 WS B, 1J-176 9/14/2007 32.0 Slots 14,011 14,479 3,244.3 3,243.2 'vJS B, iJ-176 9/14l20u7 32.0 Slots 14,780 15,250 3,243. 5 3,239.2 WS B, 1J-176 9/14/2007 32.0 Slots 15,510 15,985 3,237. 7 3,242.5 WS B, 1J-176 9114/2007 32.0 Slots 16,241 16,717 3,241. 9 3,229.0 WS B, 1J-176 9/14/2007 32.0 Slots 16,975 17,365 3,224. 7 3,226.4 WS B, 1J-176 9/14/2007 32.0 Slots 17,621 17,837 3,223. 7 3,209.0 WS B, 1J-176 9/14/2007 32.0 Slots Notes: General & Safe Entl Date Annotation 10/4/2007 NOTE: MULTI-LATERAL WELL - 1J-176 (B-SAND), 1J-176L1 (D-SAND) Mandrel Details Stn Top (RKB) Top Depth (ND) (ftK6) Top Incl (°) Make Model OD lint Serv Valve TYPe Latch TYPe Port Size (t") TRO Run (Psi) Run Date Com... 1 2,318.2 1,899.2 65.84 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2007 ,_,, ~\ KUP 1J-176 ConocoPhillips al.a,ka. In~. KB-Grd (ft) Rig Release Date "' 43.41 10/4/2007 Well Conf - iJ-176 9!52010 5:00:02 PM Scftematic -Actual = HANGER, 36 : ----------- S - -T7P - -- - Notes:General~Safe Entl Date Annotation 8/17/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.OREV CONDUCTOR, 44-60 SAFETY VLV, 504 GAS LIFT, 2,318 SURFACE, 44-3 792 SLEEVE, 10,112 LOCATOR, 10,191 PBR, 10,195 ANCHOR, 10,214 SEAL ASSV, 10,216 PLUG, 10,295 D-SAND LINER LEM, 10,210-10,498 D-SAND LINER HH, 10,237-10,634 ~ INTERMEDIATE J ' 10.75x9.675", 40-11,000 3~ Slots, ~ 11,046-11,498 s Slots, 11,768-12,239 ® I _ I I Slots, 12,520-12,964 ~ I ~~ Slots, ~~ 13,246-13,717 S I I ~ ~ Slots, 14,011-14 479 i r ~. Slots, 14,760-15,250 ® l~ ~ ~ Slots, 15,510-15,985 I Slots, 16,241-16,717 +! i Slots, ~ 18,975-17,365 i Slots, ~ 17,821-17,837 B-SAND LINER, I I 70,458-17,880 TD (1 J-178), ~ l 17,940 I WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile /Water Flow Log: 1J-176 Run Date: 8/18/2010 August 27, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J-176 Digital Data in DLIS/LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-23364-00 Water Flow Log 1 Color Log 50-029-23364-00 Injection Profile Log 1 Color Log 50-029-23364-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wo ~ 1,,' ~ c rn. ~~q~ ~~~ s Date: '°:!~ li a3 ~ ~' iu fi Signed:. ~i- c~°~, .~ MEMORANDUM • Sate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I Cpl ~ ~ ~Z, ~ tp P.I. Supervisor FROM: John Crisp Petroleum Inspector DATE: Tuesday, July 13, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-]76 KUPARUK RIV U WSAK ]J-176 Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK iJ-176 API Well Number: 50-029-23364-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523105833 Permit Number: 207-099-o Inspection Date: 5/22/2010 Rel Insp Num: MITOP000003046 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well a-176 ype Inj. N TVD 3159 ~ IA 832 1700 1600 1560 P.T.D 2070990 ypeTest SPT Test psi 1500 ~ OA 164 165 163 163 Interval Four Year Cycle p/Ii Fail ~ Tubing 582 582 581 581 Notes: Due to C/P & Little Red hot oil services scheduling problems the MIT took 3 hours. 11.4 bbl's were pumped into the well to achieve test pressure. This well had been shut in for diagnostics because of the amount of fluid needed to fill the annulus on a previous State witnessed MIT. ] would not pass the test, but since it took so much time to pressure it up I wanted to witness a pressure test on this well. Tuesday, July 13, 2010 Page 1 of 1 Page 1 of 1 Maunder, ThQrnas E (DOA) From: NSK Problem Well Supv [n1617 c@conocophillips.cbrn] Sent: Sunday, June 13, 2010 7:02 PM To: Brooks, Phoebe t_ (DOA).; Regg, James B (DOA); Maunder, Thomas E DOA); DOA AOGCC ':Prudhoe Bay Cc: Schwartz, Guy L (DOA) Subject: RE: May MfT's 1 J-176 & 1 C-174 Attachments: KRU 1 J-176 06-04-10.x1s; KRU 1 J-176 05-22-1 fl.xls; KRU 1 C-174 05-22-10. x(s Phoebe, Attached are the MIT forms for 1J-176 that were performed on both 05-22 and 06-04-10 retest. Also attached is the test form for 1 C-174 that was performed on 05-22-10. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 it ,, e rf 4j~t1 From: &ooks, Phoebe t_ (DOA) [mailto:pt~oebebrooks@alaska.gov] Sent: Friday, June 11, 2fl10 9:05 AM To: NStC Problem Well Supv Cc: Rem, James B {IAA) Subject: May M1Ts v-176 & C-174 0rerrt/ Nl a rti n, I does not appear we received the MIT report for 1J-176 PTD #2070990 dated 5/22/10; we also do not have the MIT reports for 1C-174 PTD #2030270 dated 5/21/10 (F) and 5/22/10 (P). Please submit these reports.. If you have any questions please let me know. Thank you, Phoebe Phoebe Brooks Statistical Technician IV Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 7-2.76-7542 7/4/2010 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.prudhce.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1J _~. 06/04110 Ives /Mouser - AES Robert Noble Packer Pretest Initial 15 Min. 30 Min. We11 1J-176 T In". W TVD 3,159' Tub/ 6,51 651 651 652 Interval 4 P.T.D. 2070990 T test P Test ~ 1500 Casi 1,100 1,910 1,880 1,880 P/F P Notes: OA 170 170 170 170 Well T In'. TVD Tu ~ Interval P.T.D. T test Test C P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test Casi P/F Notes: OA Well T In'. T1/D Tu ~ Interval P.T.D. T test Test Casi P/F Notes: OA Well T In". TVD Tubi Interval P.T.D. T test Test ~ C P/F Notes: OA TYPEINJ 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 = Intemal Radicective TracEv Survey A = Temperature Anomaly Survey D =Differential Temperature Test ~ r~l~ INTERVAL Godes 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-176 06-04-10.x1s • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phcebe.brooks~alaska.gov; tom.maunderl@alaska.gov; dce.aogcc.prudhce.bay~alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Kuparuk /KRU / 1J DATE: ~~ 05!22/10 OPERATOR REP: Golee 1 Pfiillips - AES AOGCC REP: John Crisp Packer Pretest Initial 15 Min. 30 Min. We11 1J-176 T In~. W TVD 3,159' Tubin 582 582 581 581 Interval 4 P.T.D. 2070990 T test P Test ~ 1500 Cali 832 1,700 1,600 1,560 P/F F Notes: OA t64 165 163 463 AOGCC dec~red test a failure due to the 11.4 bbls aired to orm test. Well T In'. TVD TutH Interval P.T.D. T test Test ~ Casi P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test ~ Casi P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test P/F Notes: OA Well T In'. TVD TutH Interval P.T.D. T test Test Casi P1F Notes: OA ~"W ~(~`~ TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R = Interval Radioactnre Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11!27/07 KRU 1J-17605-22-10.x1s • MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~~' ~,'I~~IO FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, June 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-176 KUPARUK RIV U WSAK 1J-]76 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv 7P>~ Comm Well Name: KUPARUK RIV U WSAK 1J-176 API Well Number: so-oz9-23364-00-0o Inspector Name: Bob Noble Insp Num: mitRCN100607102642 Permit Number: 207-099-0 Inspection Date: 6/4/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WeII~IJa7 ype Inj. W TVD~' sls9 ~ IA ~ Iloo y- 9io ~ ~ ~ Iaso lsso P.T.D. 2070990 LTypeTCSt SPT ! Test psi ~ 1910 ' QA i 170 II 17~ I7o t7o 6sI 652 p~F P ~ Tubing Interval a~rxTST 65] 652 _ _ Notes: This well took 2.1 bbls to pressure it up. The last time I witnessed it a few weeks ago it took 33 bbls. ~~1,' Thursday, June 10, 2010 Page 1 of 1 Page 1 of 1 lUlaunder, Thomas E {DOA) From: Brooks, Phoebe L (DOA) Sent: Tuesday, June 01, 2090 3:07 PM To: NSl{ Problem WeA Supv Cc: maunder, Thomas E {DOA); NSK DHD Tech Subject: RE: 1J-176 (PTD 207-099) Status. Hi MJ, l do not have this one. The most recent reaort l have for 1J-176 was dated 5/14/10 (include irkthe MIT KRU 1J Pad 05-14-10 file). Thanks for looking ~ntothis. Phoebe Phoebe Brooks Statistical Technician II Alaska Oii and Gas Conservation C.omm~ssion Phone:9U7-793-142 fax: 907-X76-754 From: NSK Problem Well Supv [malto:n15i7Ca~conorophillips.ocxn] Sent: Saturday, May 29, 2010 3:17 PM To: Brooks, Phoebe L (DOA) Cc: Maunder, Thomas E (DOA); NSK DHD Tech Subject: 13-~.~~ (PTD ~0~-09'9.) stat~.fs. Phoebe, Were you sent the M1T1A form completed 5!22110 on 1J-176 (PTD 207-099) and witnessed try John Crisp? I`m attempting #o back track some poor record keeping. Please advise.. Thanks MJ Loveland Well Integrity Project Supervisor ConocoPhillps Alaska, Inc. Office (907) 659-704.3 Ceil (907) 943-1687 7/4/2fl 10 Page 1 of 1 • Maunder, Thomas E ~~A) From: NSK Problem Well Supv [n1617~cono~phillips.com] Sent; Wednesday, May 19, 201010:58 AM To; Maunder, Thomas E {DOA) Subject: RE: 2010 1J-Pad State Witnessed MiTIA's Attachments; 1J-176 12 month TIO plot.jpg Tom, We are scheduled to complete 1 C-Pad along with 1 J-176 on Fri/Sat weather permitting. As to the operating history of this well and why the voidage, I can not answer. I have attached a 12 TIO plot of 1J-176. Russ Colee PWS from; Maunder, Thomas E {DOA) [mailto:tommaunder@ataska.gov] Seat: 1lVednesday, May 19, 2010 10:24 AM To: Colee, Russell (ASRC Energy Services); tVSK Problem Well Stapv Cc: Regg, James B (DOA); Brooks., Phoebe L (DOA); DOA AOGCC Pr~lhce Bay Subj+eck; RE: 2010 iJ-Pad State Witnessed M1TIA's fftussn Bien rtirr, en is it plan l~ plisl'~ ltrttlT on 1.1-176 X207 )"? Is a arryi in "ng h` give a €~ue as to ~ihy anr~ularv~` develolred2 yon have a TlE3 _ Thanks in aeivance_ Tam Maunder, PE AOOCO From: Colee, Russell (ASRC Energy Services) [rnail~:RussellC.olee~contradut'.conocophillips.] Sent: Tuesday, May 18, 2010 5:19 PM To: Regg, James B (DOA); Brooks, Phoebe L {DOA); Maunder, Thomas E (DC3A); DOA AOGCC Prudhoe Bay Cc: IVSK Problem Well Supv Subject: 2010 1J-Pad State Witnessed M1TIA's Resutts from last Fridays {5114110) 1J-Pad State Witnessed MITIA's. Sate repn=sentative (Bob Noble) l# you have any questions concerning the results don`t hesitate to call Russ Colee PWS 7/4/2010 ~~H~Y~~ F~'tP F"~fi M,~P ;~ _ __-____ . - . ~ 1~ .. .. .. .. +~ ~.~ ~ . ... .. ... .. .. .. ~ ~ _' i E ~' i ~E ~ . ~ P h . ~ _. I~y'1-~LJI ~_~~4 ~1-r 14J~~~y! 1-~'~1.~~~ iJ le:~~~~4r~~ i~l-~^r. ~t''~ o~~-~r~1-1~ jj ii ~R~R~ t ~, ~ .3 yA4. s s -.~y +BtYa A' y~ i ~ r 4', e ~ v4y'a ~i5 •-~ ~~ ..MICROFILMED 6/30/201 ~ DO Nt~T PLACE .ANY NEW MATE RIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • MEMORANDUM To: Jim Regg P.I. Supervisor ~~' k'(2 ~ 1V FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 02, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHII.LIPS ALASKA INC 1J-176 KUPARUK RIV U WSAK 1J-]76 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~' ~- Comm Well Name: KUPARUK RIV U WSAK 1J-176 API Well Number: 50-029-23364-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100516152817 Permit Number: 207-099-0 Inspection Date: 5/14/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ---T--- YP J _ Well IJ-176 ~T a In•. ~ W ~TVD i zo~o99o~ SPT ~ 3159 j,~ ~ _ ~ 1268 ~ __ ~~ TypeTest P.T.D Test si i I p i ]soo ~ UA --1------ ]~o Interval aYRTST p~ F ~ Tubing 66s ~ _ Notes: 10 barrels were pumped with only 100 psi in crease. A fluid level was shot and fluid was found to be 342' down (23.5 bbls). I ask them to do some ~agnostw work on the well. ` h Wednesday, June 02, 2010 Page 1 of 1 • Maunder, Thomas E (DOA) From: Noble, Robert C (DOA) Sent: Wednesday, May 19, 2010 10:30 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: 2010 1J-Pad State Witnessed MITIA's . ~'~,;;~~~.:.:.~~% ~}-~~''' f ~~ ~~~1. Page 1 of 1 Tom I witnessed the MIT on 1J-176. Pretest T/I/0=665/1268/170. 10 barrels were pumped with only 100 psi increase. Fluid level was shot and top of fluid was found at 342' or 23.5 bbls down. I talked to Brent Rodgers and I told him to do some diagnostic work on the well because I was wondering where 33.5 bbls of fluid went in a closed system in one year. Bob From: Maunder, Thomas E (DOA) Sent: Wednesday, May 19, 201010:24 AM To: Colee, Russell (ASRC Energy Services); NSK Problem Well Supv Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: 2010 1J-Pad State Witnessed MITIA's Russ, Brent/Martin, When is it planned to accomplish the MIT on 1J-176 (207-099)? Is there anything in the operating history that would give a clue as to how/why the annular voidage developed? Do you have a TIO plot? Thanks in advance. Tom Maunder, PE AOGCC From: Colee, Russell (ASRC Energy Services) [mailto:Russell.Colee@contractor.conocophillips.com] Sent: Tuesday, May 18, 2010 5:19 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: 2010 1J-Pad State Witnessed MITIA's Results from last Fridays (5/14/10) 1J-Pad State Witnessed MITIA's. State representative (Bob Noble) If you have any questions concerning the results don't hesitate to call Russ Colee PWS 5/19/2010 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD (UNIT /PAD: Kuparuk /KRU / 1J DATE: 05/14/10 OPERATOR REP: Colee /Phillips - AES AOGCC REP: Bob Noble 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 Type test P Test psi 1500 Casing 1,098 1,850 1,840 1,840 P/F P Notes: OA 527 527 527 527 Well 1J-156 Type Inj. W TVD 3,410' Tubing 628 625 623 620 Interval 4 P.T.D. 2060670 Type test P Test psi 1500 Casing 1,147 1,900 1,890 1,890 P/F P Notes: OA 206 206 206 205 Well 1J-160 Type Inj. W TVD 3,212' Tubing 626 626 626 ~ 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 ~L` J V V MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s ~~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubing 580 578 576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P/F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 1,866 1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubing 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casing 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P/F P Notes: OA 165 220 178 172 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test 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 ~~~ j~~~~~, 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 CONOCOPHII,LIPS ALASKA INC 1 J-176 KUPARUK RIV U WSAK 1J-176 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~'~ Comm Well Name: KUPARUK RIV U WSAK 1J-176 Insp Num: mitRCN090526121202 Rel Insp Num: API Well Number: 50-029-23364-00-00 Permit Number: 207-099-0 Inspector Name: Bob Noble Inspection Date: 5/24/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well IJ-176 Type Inj. ~ W TVD 3159 IA 1400 1980 1930 1920 P.T.D 2070990 TypeTCSt SPT Test psi 1980 QA 166 167 168 166 Interval 4YRTST per, P / TUbing 646 645 645 645 Notes: `;~~d .t~T : ~~C}'i ~~ Wednesday, May 27, 2009 Page 1 of 1 • WELL LOG TRANSMITTAL To: State of Alaska -~ - May 18, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~, t , ~; ~A, RE: MWD Formation Evaluation Logs: 1J-176+L1 AK-MW-5126703 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-176+L1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: Color Log 50-029-23364-00,60 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: Color Log 50-029-23364-00,60 Digital Log Images 2 CD Rom 50-029-23364-00,60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Bryan.Burinda@halliburton,~.com ~~ UzG 2.~~-- C~g9 l ~~S ~: ~ ~~~ i_ " _ ~ ~ ~1 Date:_~ 2009 Signed: C ~} ~ ~ ~D~- ~ ! D C) ~ ~ ~~ s ~mmissio~ ~~ iii Cas Rnc~cra~~ 9 DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2070990 Well Name/No. KUPARUK RIV U WSAK 1J-176 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23364-00-00 MD 17940 TVD 3202 Completion Date 10/4/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/RES, CBL, USIT Well Log Information: Log/ Electr Data Digital Dataset Tvne Med/Frmt Number Nama Sample Interval Set Start Stop Sent Received Number Comments og Sonic 5 Col 1 5930 10111 Open 10/19/2007 USIT-Maxtrac 17-Sep-2007 D Asc Directional Survey 40 17940 Open 12/3/2007 pt Directional Survey 40 17940 Open 12/3/2007 C 15983 Induction/Resistivity 3769 17940 Open GR, FET, RPM, RPD, RPS, RPX, ROP Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? / N Chips Received? ~.jV \ Analysis / N Received? Comments: Samples No Directional Surv Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Daily History Received? Formation Tops ~/ N Compliance Reviewed By: ~~,~ Date: ~ h IU16v oW`~l~ . ~ • • • ConocoPh i I I i ps Alaska - P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission ~~v7,,,. ~ 333 West 7~' Avenue, Suite 100 ~ / Anchorage, AK 99501 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`h,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 1 J-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 1 J-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 1 J-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 1 J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1 J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9!6/2008 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 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 1 J-122, 1 J-164, 1 J-176 LPP's b,~ck in service Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Wednesday, March 26, 2008 11;24 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr, Rodgers, James T Subject: 1J-122, 1J-164, 1J-176 LPP's back in service Tom/Jim, Page 1 of 1 We got behind with reporting the following low pressure pilots (LPP) defeat status changes. The LPP on the following wells were returned to service on the indicated dates after injection pressures increased to above 500 psi. 1J-122 (PTD 207-070, 207-071, 207-072). Returned to service 3/12/08. Current injection rate/pressure: 1317 bwpd @ 550 psi. 1J-164 (PTD 205-144, 205-145, 205-146). Retumed to service 2/28/08. Current injection rate/pressure: 865 bwpd @ 588 psi. 207-100). Returned to service. Current injection rate/pressure: 1731 bwpd @647 psi. This note is in reference to "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Regards, Hai Hai Hunt /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 3/26/2008 Kuparuk River Unit MITIAs Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.com] "?~ Sent: Saturday, March 01, 2008 10:34 AM ~ ~ _ L ~ ~`~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk River Unit MITIAs Attachments: MIT KRU 1J-122 02-29-08.x1s; MIT KRU 3K-22A 02-29-08.x1s; MIT KRU 1J-176 02-29-08.x1s «M1T KRU 1J-122 02-29-08.x1s» «MIT KRU 3K-22A 02-29-08.x1s» «MIT KRU 1J-176 02-29-08.x1s» All, Attached for your records are the MITIAs conducted on 2/29/08. Please contact myself or Brent Rogers if you have any questions or comments. Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. 907-659-7224 3/3/2008 ~~~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc Kuparuk / KRU / 1J I \~~ ~3 d ~ 02/29/08 Z Greenwood/Johnson waived by Bob Noble Packer De th Pretest Initial 15 Min. 30 Min. Well 1J-176 T pe In'. W TVD 3,159' Tubin 415 415 415 415 Interval I P.T.D. 2070990 Ty etest P Test si 1500 Casing 1,350 3,000 2,975 2,970 P/F P Notes: OA 175 175 175 175 Well Type In'. TVD Tubin Interval P.T.D. Type test Test si Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test si Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test si Casing P/F Notes: OA Well T e In~. TVD Tubing Interval P.T.D. T etest Test psi Casing P/F Notes: OA 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 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 2008-0229_MIT_KRU_1J-176.x1s LJ WELL LOG TRANSMITTAL l~ To: State of Alaska February 6, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-176 AK-MW-5126703 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23364-00 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 i ~~ ~_~ ~~ V ~ Date: ~ ~ ~' ~ ~~1~'~ ~_~~ . , Signed: 2(~'~"'09~ ~ i5a`~s3 R ~~ ~.- ~. ~~.~ ~~~~~ ;~~ .~~ ~.4 a aF~ 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~B ~ ~ ~QQ$ REPORT OF SUNDRY WELL OPERATIfi~011~5 pil R (s1c Cnns_ ('.nmmissian 1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ ;, Ott,{~CI10f4~ Pre-Prod to Inj Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^ Exploratory ^ 207-099 3. Address: Stratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23364-00 ` 7. KB Elevation (ft): 9. Well Name and Number: - RKB 121' 1J-176 8. Property Designation: 10. Field/Pool(s): ALK 25661,25662,'25663, 385172' Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 17940' feet true vertical 3202' ' feet Plugs (measured) Effective Depth measured 17880' feet Junk (measured) true vertical 3206' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3671' 13-3/8" 3792' 2299' INTERMEDIATE 1959' 10-3/4" 2080' 1794' INTERMEDIATE 8920' 9-5/8" 11000' 3251' D-SAND WIND01 1' 7-5/8" 10239' 3162' B-SAND SLOTTED LINER 7423' 5-1/2" 17880' 3206' Perforation depth: Measured depth: 11046' - 17837' true vertical depth: 3222' - 3260' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10219' MD. Packers &SSSV (type & measured depth) PKR =Baker Torquemaster 813-47, MLZXP Li ner Top Pkr PKR = 10210', 10458' SSSV= NIP SSSV= 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1045 320 30 789 274 Subsequent to operation 2238 1511 237 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ - WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-355 Contact Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature ~ ~ / ~~~~ Phone 659-7535 Date t /Z ~ /~ `~` ,~ ,.~p 'al'b' ~' s•ZZ.~~ Form 10-404 Revised 04/2004 ~ /~' jha `Y`~ Submit Ori ' (t~ e 1 J-176 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/21/08 Commenced Water Injection LPP/SSV defeated on 1J-17b • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Thursday, February 21, 2008 2:28 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Rodgers, James T; NSK West Sak Prod Engr Subject: LPP/SSV defeated on 1J-176 Tom /Jim, The low pressure pilot (LPP) ors 1~ !Tl~ 207-100) is defeated as of 2/2112008, when injection was initiated after a 31-day pre-production period. urrent wellhead pressure is 39 psi; injection rate is 2100 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC wi8 be notified when the injection pressure has increased to above 500 psi and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please tet 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 2/21/2008 ConocoPhillips January 29, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: • J. Eggemeyer Engineering Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 ~;;~<. ' a~~~~ ~~ n~ ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 3Q-11, 1 J-137, 1 C-104, 1 E-29, 1 J-176 1 J-176L1, 1 J-107 and 1 J-107L1 you requested. These summaries will replace the shorter summaries already submitted with the completion reports for these wells. If you have any questions regarding this matter, please contact me at 265-6049. w~.~~ 5.~~~c~.c'R~ 5 ~~~Q s-~rc• c~ Sincerely, ~"~~ ~` ~0 '~~~''~ . Eggemeyer Engineering Team Leader CPAI Drilling JE/skad Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, December 12, 2007 10:27 AM To: Eggemeyer, Jerome C. Subject: 1J-176 (207-099) and 1J-1761.1 (207-100) Jerome, Further to our discussions, would you please provide the detailed operations reports for the following well (s)/operations. 1J-176 (207-099) One copy of the full summary (-176 & -176L1) 1J-176 (207-100) Summary for lateral (-176t_1) only Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC ~,~1ct~ ~°~~o~ 2/4/2008 ConocoPhillips November 9, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-176 and 1J-176L1 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1J-176 and 1J- 176L1. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, { R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad ~~~ N~~ 1 5 Z~~~ Atesk~ C1~I ~ Cis Cons. ~biYtwilgs~:i9(~ Anchorage ~~~~~ ~ STATE OF ALASKA ~ ~~~ ~ ~ ~oD7 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOF~~~~-~I~~ a on ' ~oimm~ssio>Y 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: October 4, 2007 ~ 12. Permit to Drill Number: 207-099 / ~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: August 17, 2007 13. API Number: 50-029-23364-00 ` 4a. Location of Well (Governmental Section): Surface: 1686' FSL, 2461' FEL, Sec. 35, T11N, R10E, UM ' 7. Date TD Reached: September 8, 2007 ~ 14. Well Name and Number: 1J-176 Top of Productive Horizon: 377' FSL, 1832' FWL, Sec. 3, T10N, R10E, UM 8. KB (ft above MSL): 41' RKB Ground (ft MSL): 122' AMSL - 15. Field/Pool(s): Kuparuk River Field Total Depth: 1326' FNL, 1872' FWL, Sec. 15, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 17880' MD / 3206' ND West Sak Oil Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558751 j y- 5945498 ~ Zone- 4 10. Total Depth (MD + ND): `' 17940' MD / 3202' TVD ~ 16. Property Designation: ALK 25661, 25662, 25663, 385172 TPI: x- 552543 y- 5938863 Zone- 4 Total Depth: x- 552645 - 5931882 Zone- 4 11. SSSV Depth (MD + ND): nipple @ 504' MD / 504 ND 17. Land Use Permit: 471, 2177, 472, 2181 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost ('fl/D): 1537' TVD 21. Logs Obtained (List all togs here and submit electronic and printed information per 20 AAC 25.071): GR/RES, CBL, USIT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE I G COR AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENT N RE D PULLED 20" x 34" 78.6# H-40 41' 120' 41' 120' 42" 326 sx AS 1 13.375" 68# L-80 41' 3792' 41' 2301' 16" 800 sx Class G, 210 sx Class G 10.75" x 73.2# L-80 41' 2080' 41' 1793' 12.25" 921 sx DeepCRETE 9.625" 40# L-80 2080' 11000' 1793' 3250' 12.25" included above 5.5" 15.5# L-80 10457' 17880' 3189' 3206' 8.5" slotted liner 23. Open to production or injection? Yes ^ No / If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 10220' 10458' blank and slots alternating from: 10457'-11046', 11497'-11788', 12239'-12519', 12963'-13245', 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13717'-14011', 14478'-14780', 15250'-15509', 15985'-16241', DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 16717'-16975', 17365'-17620' MD na 26. PRODUCTION TEST Date First Production November 5, 2007 Method of Operation (Flowing, gas lift, etc.) pre-produced injector -gas lift oil -shares production with 1 J-176L1 Date of Test 11/6/2007 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1024 GAS-MCF 1268 WATER-BBL 36 CHOKE SIZE 40 Bean GASOIL RA7lo 1137 Flow Tubing press. 397 psi Casing Pressure g61 Calculated 24-Hour Rate -> OIL-BBL 2032 GAS-MCF 2256 WATER-BBL 73 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.07x._. , . +4iv ~c 11L.:7 • c~ NONE 1.'=~IAl~il~ --,~-'~~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE Q R ~ G 1 N A L ~~ ~~~ ~` ~~ ~' l)4 ~~ ~ ~ 1007 ~ ~~~ ~ ~'~/~ G r1 28. GEOLOGIC MARKERS (List all formations and mar rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1730' 1537' needed, and submit detailed test information per 20 AAC 25.071. T3 3750' 2289' K15 3750' 2289' Ugnu C 6682' 2700' Ugnu B 7850' 2858' Ungu A 8222' 2905' K13 9153' 3023' West Sak D 10236' 3162' West Sak B 10952' 3247' West Sak A 17940' 3202' N/A Formation at total depth: West Sak B 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet, cement detail summary 31. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 omas Title: Drillino Team Leader Printed Napxe.~~, Rand Th ryry [ry ~ ~ Si nature ~~,~ g , t~',>~-~-~----~ Phone 2, ~ _ S_.. E- ~, j ~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 Halliburton Company Survey Report Companp: ConocoPhillipsAlaska Ina Uatc 10/11/2007 Timc: '11:23-59 Pa~c I ficl~l: Kuparuk River Unit ('u-ordinate(\t.) kefcrencc: Well: 1J-176, Tru e NoRh Si[e: Kuparuk 1J Pad ~crtical (T~'I)) Ra ferencc: 1J-176 Actual RTE 121.5 Well: 1J-176 Sectiun (~S) Iterer ence: Well (O.OON,O.OO E,1g0.00Azi) Wellpath: 1J-176 tiui~c} CakulationMethod: MinlmumCurvat ure Db: Orade Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-176 Slot Name: API 50-029-23360-00 Well Position: +N/-S -421.31 ft Northing: 5945498.05 ft Latitude: 70 15 42.114 N +E/-W -42.35 ft Easting : 558750.89 ft Longitude: 149 31 30.239 W ~ Position Uncertainty: 0.00 ft Survey l1D Incl ~tim TVI) SvsTVD VlS t:,~~ MapN n~lapt: Tool ft deg deg ft` ___ ft ___ ft ft ft ft 40.55 0.00 0.00 40.55 -81.00 0.00 0.00 5945498.05 558750.89 TIE LINE 50.00 0.28 140.37 50.00 -71.55 -0.02 0.01 5945498.03 558750.90 CB-GYRO-SS 112.00 0.38 147.90 112.00 -9.55 -0.31 0.22 5945497.74 558751.11 CB-GYRO-SS 182.00 0.56 148.16 182.00 60.45 -0.80 0.52 5945497.26 558751.42 CB-GYRO-SS 243.00 1.10 164.35 242.99 121.44 -1.61 0.84 5945496.44 558751.74 CB-GYRO-SS ~ 300.00 1.00 188.94 299.98 178.43 -2.63 0.91 5945495.43 558751.82 CB-GYRO-SS 370.00 2.98 200.56 369.94 248.39 -4.94 0.18 5945493.11 558751.10 CB-GYRO-SS 465.00 5.08 214.90 464.70 343.15 -10.70 -3.10 5945487.33 558747.88 CB-GYRO-SS 507.85 5.50 213.54 507.36 385.81 -13.97 -5.32 5945484.04 558745.68 MWD+IFR-AK-CAZ-SC 603.13 8.60 229.53 601.92 480.37 -22.40 -13.26 5945475.55 558737.80 MWD+IFR-AK-CAZ-SC 698.04 12.17 234.19 695.26 573.71 -32.86 -26.78 5945464.98 558724.37 MWD+IFR-AK-CAZ-SC ~ 792.82 14.51 233.23 787.48 665.93 -45.82 -44.39 5945451.89 558706.86 MWD+IFR-AK-CAZ-SC 887.72 16.43 228.96 878.94 757.39 X1.75 -64.04 5945435.81 558687.34 MWD+IFR-AK-CAZ-SC ~ 983.88 20.94 224.92 970.01 848.46 -82.86 -86.45 5945414.53 558665.10 MWD+IFR-AK-CAZ-SC 1079.22 22.55 224.50 1058.57 937.02 -107.96 -111.29 5945389.23 558640.46 MWD+IFR-AK-CAZ-SC 1174.35 25.37 225.31 1145.49 1023.94 -135.31 -138.57 5945361.68 558613.39 MWD+IFR-AK-CAZ-SC 1268.88 29.96 223.89 1229.19 1107.64 -166.58 -169.35 5945330.17 558582.86 MWD+IFR-AK-CAZ-SC 1364.04 32.74 224.46 1310.45 1188.90 -202.08 -203.85 5945294.41 558548.64 MWD+IFR-AK-CAZ-SC 1455.53 37.35 225.23 1385.33 1263.78 -239.30 -240.90 5945256.90 558511.88 MWD+IFR-AK-CAZ-SC ~ 1554.45 40.75 227.35 1462.15 1340.60 -282.32 -285.97 5945213.53 558467.16 MWD+IFR-AK-CAZ-SC ~ 1648.79 44.27 227.79 1531.68 1410.13 -325.32 -333.02 5945170.18 558420.45 MWD+IFR-AK-CAZ-SC ~ 1744.01 49.20 226.53 1596.92 1475.37 -372.47 -383.82 5945122.63 558370.02 MWD+IFR-AK-CAZ-SC 1840.11 52.92 225.69 1657.31 1535.76 -424.29 -437.67 5945070.40 558316.59 MWD+IFR-AK-CAZ-SC 1936.10 54.46 226.69 1714.15 1592.60 -477.83 -493.49 5945016.43 558261.19 MWD+IFR-AK-CAZ-SC 2030.77 56.87 227.77 1767.55 1646.00 -530.90 -550.88 5944962.92 558204,22 MWD+IFR-AK-CAZ-SC 2125.41 61.13 227.77 1816.28 1694.73 -585.41 -610.93 5944907.94 558144.60 MWD+IFR-AK-CAZ-SC 2220.83 63.29 231,20 1860.77 1739.22 -640.22 -675.11 5944852.64 558080.86 MWD+IFR-AK-CAZ-SC ~ 2316.40 66.40 232.08 1901.39 1779.84 -693.89 -742.93 5944798.45 558013.46 MWD+IFR-AK-CAZ-SC 2410.66 69.11 233.32 1937.07 1815.52 -746.75 -812.33 5944745.06 557944,49 MWD+IFR-AK-CAZ-SC Wellpath: 1J-176 Drilled From: Well Ref. Point API 50-029-23360-00 Tie-on Depth: 40.55 ft Current Datum: 1 J-176 Actual RTE: Height 121.55 ft Above System Datum: Mean Sea Level / Magnetic Data: 8/10/2007 Declination: 23.23 deg Field Strength: 57616 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.55 0.00 i 0.00 180.00 Survey Program for Definitive Wellpath Date: 9/8/2007 Validated: Yes Actual From To Survey Version: 7 Toolcode Tool Name ft ft 50.00 465.00 1J-176 Gyro (50.00-465.00) CB-GYRO-SS Camera based gyro single shot 507.85 17910.60 1J-176 IIFR+MS+SAG (507.85-179 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Halliburton Company Survey Report Cun,psim: ConocoPhilllps Alaska Inc. Ikitr. 1 0/1 112 007 Time: 11'23'59 Pa~c: 3 Pirid: Kuparuk River Unit C~u-o rdin;itc(~F:) Reference: Well: 1J-176, True North Sitc: Kuparuk 1J Pad ~crtiail II~~~U) Nefcri~nce: 1J-176 Actual RTE: 12.1.6 1~ell: 1J-176 Section I~~S)lteCereua^: Well (O.OON.O.OOE 180:OOAzi) ~1`cllpath: 1J-176 Suiticq CakulatianDlethud: Minimum Curvature Dh: Oracle ~ur~ c~ - --- --_ J1U Incl lzim TVD Sc,T~D \rS G,i~~ 11apti MapE ~I'o~il ft deg deg ft ft ft ft ft ft 2505.98 72.48 232.27 1968.43 1846.88 -801.17 -884.01 5944690.08 557873.24 MWD+IFR-AK-CAZ-SC 2601.29 75.13 231.63 1995.01 1873.46 -857.59 -956.08 5944633.11 557801.62 MWD+IFR-AK-CAZ-SC 2696.35 74.79 230.65 2019.67 1898.12 -915.18 -1027.56 5944574.97 557730.60 MWD+IFR-AK-CAZ-SC 2791.94 73.94 231.29 2045.44 1923.89 -973.15 -1099.07 5944516.45 557659.55 MWD+IFR-AK-CAZ-SC ~ 2886.58 74.74 228.96 2070.99 1949.44 -1031.57 -1168.99 5944457.49 557590.09 MWD+IFR-AK-CAZ-SC I 2982.65 74.24 229.16 2096.68 1975.13 -1092.23 -1238.92 5944396.29 557520.65 MWD+IFR-AK-CAZ-SC 3076.93 74.05 229.47 2122.43 2000.88 -1151.35 -1307.70 5944336.64 557452.34 MWD+IFR-AK-CAZ-SC 3171.43 75.02 227.38 2147.63 2026.08 -1211.79 -1375.82 5944275.68 557384.70 MWD+IFR-AK-CAZ-SC 3263.31 75.47 227.26 2171.03 2049.48 -1272.02 -1441.14 5944214.94 557319.86 MWD+IFR-AK-CAZ-SC 3363.06 76.88 227.45 2194.87 2073.32 -1337.64 -1512.39 5944148.78 557249.13 MWD+IFR-AK-CAZ-SC 3455.78 75.34 228.39 2217.13 2095.58 -1397.96 -1579.19 5944087.95 557182.81 MWD+IFR-AK-CAZ-SC 3550.86 75.70 230.18 2240.90 2119.35 -1458.01 -1648.96 5944027.36 557113.51 MWD+IFR-AK-CAZ-SC 3646.36 76.34 231.10 2263.98 2142.43 -1516.78 -1720.61 5943968.04 557042.33 MWD+IFR-AK-CAZ-SC ~ 3741.68 75,54 229.96 2287.13 2165.58 -1575.55 -1791.99 5943908.72 556971.42 MWD+IFR-AK-CAZ-SC ~ 3766.00 76,36 230.27 2293.04 2171.49 -1590.68 -1810.09 5943893.45 556953.43 MWD+IFR-AK-CAZ-SC 3859.44 79.65 231.46 2312.45 2190.90 -1648.35 -1880.98 5943835.23 556883.01 MWD+IFR-AK-CAZ-SC 3955.16 81,94 231.91 2327.76 2206.21 -1706.93 -1955.11 5943776.09 556809.34 MWD+IFR-AK-CAZ-SC 4049.94 82.72 230.90 2340.42 2218.87 -1765.52 -2028.53 5943716.92 556736.39 MWD+IFR-AK-CAZ-SC 4144.42 81.41 231.87 2353.46 2231.91 -1823.92 -2101.64 5943657.96 556663.75 MWD+IFR-AK-CAZ-SC 4240.65 81.34 232.00 2367.89 2246.34 -1882.58 -2176.54 5943598.73 556589.31 MWD+IFR-AK-CAZ-SC 4335.58 81.41 232.32 2382.13 2260.58 -1940.16 -2250.67 5943540.58 556515.65 MWD+IFR-AK-CAZ-SC 4430.82 80.73 234.18 2396.91 2275.36 -1996.45 -2326.05 5943483.71 556440.71 MWD+IFR-AK-CAZ-SC ~ 4526.77 81.71 233.64 2411.56 2290.01 -2052.31 -2402.67 5943427.26 556364.53 MWD+IFR-AK-CAZ-SC 4621.32 81.04 233.61 2425.74 2304.19 -2107.75 -2477.94 5943371.24 556289.71 MWD+IFR-AK-CAZ-SC 4716.18 81.60 231.97 2440.05 2318.50 -2164.45 -2552.62 5943313.96 556215.48 MWD+IFR-AK-CAZ-SC 4809.82 82.82 232.97 2452.75 2331.20 -2220.97 -2626.19 5943256.87 556142.36 MWD+IFR-AK-CAZ-SC 4907.74 82.04 234.17 2465.65 2344.10 -2278.61 -2704.29 5943198.63 556064.72 MWD+IFR-AK-CAZ-SC 5002.74 83.69 234.71 2477.44 2355.89 -2333.43 -2780.97 5943143.22 555988.48 MWD+IFR-AK-CAZ-SC 5098.08 82.22 235.66 2489.14 2367.59 -2387.45 -2858.65 5943088.60 555911.23 MWD+IFR-AK-CAZ-SC 5193.62 82.41 234.48 2501.91 2380.36 -2441.66 -2936.27 5943033.79 555834.04 MWD+IFR-AK-CAZ-SC ~ 5288.38 82.40 233.42 2514.44 2392.89 -2496.93 -3012.21 5942977.93 555758.54 MWD+IFR-AK-CAZ-SC i 5383.52 81.97 232.70 2527.38 2405.83 -2553.58 -3087.55 5942920.71 555683.65 MWD+IFR-AK-CAZ-SC 5478.65 82.03 232.98 2540.62 2419.07 -2610.48 -3162.62 5942863.22 555609.03 MWD+IFR-AK-CAZ-SC 5573.99 82.72 233.76 2553.27 2431.72 -2666.86 -3238.46 5942806.26 555533.65 MWD+IFR-AK-CAZ-SC 5668.39 82.66 233.72 2565.28 2443.73 -2722.24 -3313.96 5942750.30 555458.59 MWD+IFR-AK-CAZ-SC 5763.67 83.03 232.73 2577.15 2455.60 -2778.84 -3389.68 5942693.12 555383.32 MWD+IFR-AK-CAZ-SC 5858.54 81.65 232.25 2589.79 2468.24 -2836.09 -3464.26 5942635.29 555309.19 MWD+IFR-AK-CAZ-SC 5954.56 82.48 232.77 2603.05 2481.50 -2893.97 -3539.72 5942576.83 555234.19 MWD+IFR-AK-CAZ-SC 6049.78 83.09 232.64 2615.01 2493.46 -2951.21 -3614.87 5942519.02 555159.50 MWD+IFR-AK-CAZ-SC 6144.85 82.22 233.75 2627.16 2505.61 -3007.69 -3690.36 5942461.95 555084.46 MWD+IFR-AK-CAZ-SC 6240.06 81.78 234.89 2640.41 2518.86 -3062.68 -3766.95 5942406.37 555008.31 MWD+IFR-AK-CAZ-SC i 6334.76 82.89 235.01 2653.04 2531.49 -3116.58 -3843.78 5942351.87 554931.91 MWD+IFR-AK-CAZ-SC 6428.04 82.40 234.81 2664.98 2543.43 -3169.76 -3919.48 5942298.11 554856.64 MWD+IFR-AK-CAZ-SC 6523.51 81.60 234.71 2678.27 2556.72 -3224.31 -3996.69 5942242.96 554779.86 MWD+IFR-AK-CAZ-SC i 6618.77 82.53 233.15 2691.42 2569.87 -3279.86 -4072.95 5942186.83 554704.04 MWD+IFR-AK-CAZ-SC 6713.92 82.34 231.36 2703.95 2582.40 -3337.60 -4147.53 5942128.52 554629.92 MWD+IFR-AK-CAZ-SC ~, 6808.96 82.34 231.19 2716.62 2595.07 -3396.52 -4221.02 5942069.03 554556.91 MWD+IFR-AK-CAZ-SC I 6904.50 82.47 231.42 2729.24 2607.69 -3455.73 -4294.93 5942009.25 554483.46 MWD+IFR-AK-CAZ-SC 6997.91 82.47 231.92 2741.49 2619.94 -3513.16 -4367.57 5941951.26 554411.28 MWD+IFR-AK-CAZ-SC 7093.21 81.52 231.96 2754.76 2633.21 -3571.34 -4441.88 5941892.51 554337.44 MWD+IFR-AK-CAZ-SC 7187.59 81.79 233.26 2768.45 2646.90 -3628.04 -4516.07 5941835.24 554263.70 MWD+IFR-AK-CAZ-SC 7283.87 81.16 234.99 2782.73 2661.18 -3683.84 -4593.22 5941778.84 554186.99 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Comp>~~~~: ConocoPhiltips AlasNa Inc- Datc: 10!11/2007 l~imc 1123-59 Pa~c 3 Fietd: Kuparuk River Unit Co-ordiuate(]f-) Refa~ence: Welly 1J-176, True North Site: Kuparuk 1J Pad Vertical (TVl)> Reference: 1J-17o Actual RTE: 121.5 Well: 1J-176 Section (VS) Keferencc: Weil (O.OON,O.OOE,180.OOAzi) R'ellpaUi: 1 J-176 Survey Calculation tVle~lhod: Minimum Curvature I)b: Orade Suncc _-__ SID Inc! lzim f~'D SysT~D \i5 F./~1 D1apY )1apE fool ft deg deg ft ft ft ft ft ft 7378.39 81.61 236.06 2796.89 2675.34 -3736.74 -4670.26 5941725.35 554110.38 MWD+IFR-AK-CAZ-SC 7474.55 82.34 235.52 2810.31 2688.76 -3790.27 -4749.00 5941671.21 554032.06 MWD+IFR-AK-CAZ-SC 7568.95 82.79 235.87 2822.53 2700.98 -3843.03 -4826.32 5941617.86 553955.16 MWD+IFR-AK-CAZ-SC 7663.86 82.90 235.48 2834.35 2712.80 -3896.13 -4904.09 5941564.16 553877.81 MWD+IFR-AK-CAZ-SC 7757.92 82.85 235.27 2846.02 2724.47 -3949.16 -4980.90 5941510.53 553801.43 MWD+iFR-AK-CAZ-SC 7851.65 82.78 232.81 2857.74 2736.19 -4003.76 -5056.16 5941455.35 553726.60 MWD+IFR-AK-CAZ-SC 7948.47 82.90 231.82 2869.81 2748.26 -4062.49 -5132.19 5941396.04 553651.05 MWD+IFR-AK-CAZ-SC I 8043.22 82.03 232.35 2882.23 2760.68 -4120.21 -5206.29 5941337.75 553577.40 MWD+IFR-AK-CAZ-SC ~ 8138.71 82.90 232.54 2894.75 2773.20 -4177.91 -5281.34 5941279.47 553502.81 MWD+IFR-AK-CAZ-SC 8233.34 82.29 233.46 2906.95 2785.40 -4234.38 -5356.28 5941222.41 553428.32 MWD+IFR-AK-CAZ-SC 8328.89 83.21 233.41 2919.01 2797.46 -4290.85 -5432.41 5941165.36 553352.64 MWD+IFR-AK-CAZ-SC 8424.16 82.78 232.69 2930.63 2809.08 -4347.69 -5507.98 5941107.94 553277.53 MWD+IFR-AK-CAZ-SC 8518.47 82.29 229.54 2942.88 2821.33 -4406.38 -5580.76 5941048.69 553205.21 MWD+IFR-AK-CAZ-SC 8613.89 83.33 227.84 2954.83 2833.28 -4468.88 -5651.86 5940985.65 553134.60 MWD+IFR-AK-CAZ-SC 8710.11 83.72 224.95 2965.68 2844.13 -4534.81 -5721.09 5940919.18 553065.91 MWD+IFR-AK-CAZ-SC ~ 8804.60 81.66 224.02 2977.70 2856.15 -4601.67 -5786.76 5940851.82 553000.77 MWD+IFR-AK-CAZ-SC ; 8899.48 81.35 222.58 2991.72 2870.17 -4669.96 -5851.11 5940783.04 552936.95 MWD+IFR-AK-CAZ-SC ~ 8995.13 83.19 221.78 3004.58 2883.03 -4740.19 -5914.75 5940712.31 552873.87 MWD+IFR-AK-CAZ-SC 9088.93 83.41 218.53 3015.53 2893.98 -4811.38 -5974.81 5940640.66 552814.37 MWD+IFR-AK-CAZ-SC 9185.04 82.28 215.28 3027.50 2905.95 -4887.62 -6032.07 5940563.98 552757.71 MWD+IFR-AK-CAZ-SC 9280.71 81.97 211.28 3040.62 2919.07 -4966.83 -6084.06 5940484.38 552706.34 MWD+IFR-AK-CAZ-SC 9375.66 83.20 208.19 3052.87 2931.32 -5048.58 -6130.75 5940402.28 552660.30 MWD+IFR-AK-CAZ-SC 9470.78 82.77 204.05 3064.50 2942.95 -5133.33 -6172.31 5940317.22 552619.41 MWD+IFR-AK-CAZ-SC 9562.91 82.10 200.51 3076.63 2955.08 -5217.82 -6206.93 5940232.46 552585.45 MWD+IFR-AK-CAZ-SC I 9661.87 83.15 195.76 3089.34 2967.79 -5311.06 -6237.46 5940139.00 552555.65 MWD+IFR-AK-CAZ-SC 9756.53 81.85 191.76 3101.70 2980.15 -5402.20 -6259.79 5940047.70 552534.04 MWD+IFR-AK-CAZ-SC 9851.38 82.34 188.40 3114.75 2993.20 -5494.68 -6276.23 5939955.10 552518.32 MWD+IFR-AK-CAZ-SC 9946.55 83.21 185.17 3126.72 3005.17 -5588.42 -6287.38 5939861.29 552507.91 MWD+IFR-AK-CAZ-SC 10041.69 83.21 180.76 3137.97 3016.42 -5682.74 -6292.26 5939766.94 552503.76 MWD+IFR-AK-CAZ-SC i I~ 10135.44 83.41 177.64 3148.90 3027.35 -5775.83 -6290.96 5939673.87 552505.78 MWD+IFR-AK-CAZ-SC 10231.12 81.72 177.78 3161.28 3039.73 -5870.63 -6287.17 5939579.11 552510.31 MWD+IFR-AK-CAZ-SC 10326.78 83.43 177.57 3173.64 3052.09 -5965.41 -6283.32 5939484.38 552514.90 MWD+IFR-AK-CAZ-SC ~ 10421.81 83.03 177.90 3184.84 3063.29 -6059.70 -6279.59 5939390.13 552519.37 MWD+IFR-AK-CAZ-SC 10517.13 83.72 177.95 3195.84 3074.29 -6154.32 -6276.16 5939295.55 552523.53 MWD+IFR-AK-CAZ-SC ~ 10611.81 83.16 179.09 3206.66 3085.11 -6248.35 -6273.73 5939201.55 552526.70 MWD+IFR-AK-CAZ-SC 10706.40 82.71 177.18 3218.29 3096.74 -6342.16 -6270.68 5939107.77 552530.48 MWD+IFR-AK-CAZ-SC 10802.15 82.53 176.79 3230.59 3109.04 -6436.99 -6265.69 5939012.99 552536.22 MWD+IFR-AK-CAZ-SC 10897.47 84.18 177.57 3241.62 3120.07 -6531.55 -6261.03 5938918.48 552541.61 MWD+IFR-AK-CAZ-SC 10980.52 85.43 178.83 3249.14 3127.59 -6614.22 -6258.43 5938835.85 552544.85 MWD+IFR-AK-CAZ-SC ~ 11071.43 86.47 177.59 3255.56 3134.01 -6704.85 -6255.60 5938745.24 552548.39 MWD+IFR-AK-CAZ-SC ~ 11169.00 90.37 177.07 3258.25 3136.70 -6802.26 -6251.06 5938647.88 552553.69 MWD+IFR-AK-CAZ-SC 11264.62 90.80 178.91 3257.28 3135.73 -6897.81 -6247.70 5938552.37 552557.79 MWD+IFR-AK-CAZ-SC 11360.87 89.38 177.81 3257.12 3135.57 -6994.02 -6244.95 5938456.20 552561.30 MWD+IFR-AK-CAZ-SC 11455.02 88.27 178.45 3259.05 3137.50 -7088.10 -6241.88 5938362.16 552565.10 MWD+IFR-AK-CAZ-SC 11550.43 89.53 181.09 3260.89 3139.34 -7183.48 -6241.49 5938266.79 552566.23 MWD+IFR-AK-CAZ-SC 11645.25 91.49 183.07 3260.04 3138.49 -7278.22 -6244.93 5938172.03 552563.53 MWD+IFR-AK-CAZ-SC 11740.31 90.55 184.31 3258.35 3136.80 -7373.07 -6251.05 5938077.15 552558.15 MWD+IFR-AK-CAZ-SC 11835.01 90.06 183.53 3257.85 3136.30 -7467.54 -6257.52 5937982.64 552552.41 MWD+IFR-AK-CAZ-SC 11929.98 90.37 183.00 3257.49 3135.94 -7562.36 -6262.93 5937887.79 552547.75 MWD+IFR-AK-CAZ-SC 12024.85 90.55 180.21 3256.73 3135.18 -7657.18 -6265.59 5937792.96 552545.83 MWD+IFR-AK-CAZ-SC 12120.06 90,30 177.00 3256.02 3134.47 -7752.34 -6263.27 5937697.82 552548.89 MWD+IFR-AK-CAZ-SC j 12215.45 91.09 177.84 3254.86 3133.31 -7847.63 -6258.98 5937602.59 552553.93 MWD+IFR-AK-CAZ-SC 12309.74 91.72 179.79 3252.55 3131.00 -7941.86 -6257.03 5937508.38 552556.61 MWD+IFR-AK-CAZ-SC ----- -- Halliburton Company Survey Report CurEipauy: Conoco Phillips Alaska Inc. Date:. 10/11/2007 Timc: 112359 Pair. -1 Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-176, True North Site: Kvparuk 1J Pad Vertical (TVD)Reference: 1J-176 Actual RTE: 121.5 WeIL• 1J-176 .Section (VS)12eference: Well (0-OON,O.OOE,180.OOAzi) ~VeRpatt+: 1J-176 Survey Cakula[ion 1ldhod: Minimum Curvature Dh: Oracle Sai n c~ )~II) Lul laim ~I'VD SysT~D V/S Ei~~ 11apV A1apE l'onl ft deg deg ft ft ft ft ft ft 12404.87 90.36 178.46 3250.83 3129.28 -8036.96 -6255.58 5937413.30 552558.80 MWD+IFR-AK-CAZ-SC 12499.83 91.63 178.82 3249.18 3127.63 -8131.88 -6253.32 5937318.41 552561.80 MWD+IFR-AK-CAZ-SC 12594.36 91.29 179.86 3246.77 3125.22 -8226.37 -6252.24 5937223.94 552563.62 MWD+IFR-AK-CAZ-SC 12689.80 89.87 179.73 3245.80 3124.25 -8321.80 -6251.89 5937128.52 552564.71 MWD+IFR-AK-CAZ-SC 12784.55 90.06 178.99 3245.86 3124.31 -8416.55 -6250.84 5937033.80 552566.51 MWD+IFR-AK-CAZ-SC 12879.25 89.56 179.90 3246.17 3124.62 -8511.24 -6249.92 5936939.13 552568.16 MWD+IFR-AK-CAZ-SC 12973.73 88.82 178.18 3247.51 3125.96 -8605.69 -6248.34 5936844.70 552570.48 MWD+IFR-AK-CAZ-SC 13069.18 89.49 178.88 3248.92 3127.37 -8701.10 -6245.89 5936749.32 552573.67 MWD+IFR-AK-CAZ-SC 13164.20 91.07 179.03 3248.45 3126.90 -8796.10 -6244.15 5936654.35 552576.15 MWD+IFR-AK-CAZ-SC 13259.00 91.48 178.99 3246.34 3124.79 -8890.86 -6242.52 5936559.61 552578.52 MWD+IFR-AK-CAZ-SC 13353.50 92.15 178.98 3243.35 3121.80 -8985.30 -6240.84 5936465.20 552580.93 MWD+IFR-AK-CAZ-SC 13448.75 89.81 177.02 3241.72 3120.17 -9080.47 -6237.52 5936370.07 552585.00 MWD+IFR-AK-CAZ-SC 13544.58 89.87 176.48 3241.99 3120.44 -9176.14 -6232.09 5936274.45 552591.18 MWD+IFR-AK-CAZ-SC 13638.81 89.81 176.63 3242.25 3120.70 -9270.20 -6226.42 5936180.45 552597.57 MWD+IFR-AK-CAZ-SC 13734.46 89.75 178.06 3242.62 3121.07 -9365.75 -6221.99 5936084.95 552602.75 MWD+IFR-AK-CAZ-SC 13829.88 90.00 179.85 3242.83 3121.28 -9461.15 -6220.25 5935989.57 552605.23 MWD+IFR-AK-CAZ-SC I I 13924.90 89.44 180.64 3243.29 3121.74 -9556.16 -6220.66 5935894.57 552605.57 MWD+IFR-AK-CAZ-SC ~ 14020.04 88.45 178.65 3245.04 3123.49 -9651.28 -6220.07 5935799.47 552606.90 MWD+IFR-AK-CAZ-SC 14115.02 88.94 180.96 3247.21 3125.66 -9746.23 -6219.75 5935704.53 552607.96 MWD+IFR-AK-CAZ-SC 14209.52 90.87 183.01 3247.36 3125.81 -9840.66 -6223.02 5935610.09 552605.43 MWD+iFR-AK-CAZ-SC 14304.80 90.86 181.42 3245.93 3124.38 -9935.86 -6226.70 5935514.87 552602.49 MWD+IFR-AK-CAZ-SC 14399.61 91.17 180.97 3244.25 3122.70 -10030.63 -6228.68 5935420.10 552601.25 MWD+IFR-AK-CAZ-SC 14495.71 90.12 180.72 3243.16 3121.61 -10126.71 -6230.10 5935324.02 552600.58 MWD+IFR-AK-CAZ-SC 14590.84 89.56 182.27 3243.43 3121.88 -10221.81 -6232.58 5935228.91 552598.84 MWD+IFR-AK-CAZ-SC 14685.55 89.81 181.72 3243.95 3122.40 -10316.46 -6235.88 5935134.25 552596.29 MWD+IFR-AK-CAZ-SC 14780.76 90.78 180.20 3243.46 3121.91 -10411.65 -6237.47 5935039.06 552595.43 MWD+IFR-AK-CAZ-SC I 14876.07 90.43 178.49 3242.45 3120.90 -10506.94 -6236.38 5934943.78 552597.27 MWD+IFR-AK-CAZ-SC 14970.83 90.49 178.29 3241.69 3120.14 -10601.66 -6233.72 5934849.10 552600.67 MWD+IFR-AK-CAZ-SC 15066.26 90.43 179.20 3240.93 3119.38 -10697.07 -6231.63 5934753.72 552603.50 MWD+IFR-AK-CAZ-SC 15161.67 90.74 179.12 3239.95 3118.40 -10792.46 -6230.23 5934658.35 552605.64 MWD+IFR-AK-CAZ-SC 15256.37 90.24 178.54 3239.14 3117.59 -10887.14 -6228.30 5934563.70 552608.32 MWD+IFR-AK-CAZ-SC 15351.35 89.93 178.86 3239.00 3117.45 -10982.09 -6226.14 5934468.78 552611.21 MWD+IFR-AK-CAZ-SC 15446.02 90.72 177.18 3238.47 3116.92 -11076.70 -6222.87 5934374.20 552615.22 MWD+IFR-AK-CAZ-SC 15541.06 90.61 178.18 3237.36 3115.81 -11171.65 -6219.02 5934279.29 552619.81 MWD+IFR-AK-CAZ-SC 15636.13 88.88 177.54 3237.79 3116.24 -11266.65 -6215.48 5934184.33 552624.10 MWD+IFR-AK-CAZ-SC 15731.16 89.13 178.90 3239.44 3117.89 -11361.62 -6212.52 5934089.40 552627.79 MWD+IFR-AK-CAZ-SC 15826.66 89.32 180.71 3240.73 3119.18 -11457.11 -6212.20 5933993.93 552628.86 MWD+IFR-AK-CAZ-SC 15922.10 89.19 181.90 3241.97 3120.42 -11552.51 -6214.37 5933898.52 552627.43 MWD+IFR-AK-CAZ-SC 16016.83 89.69 182.55 3242.89 3121.34 -11647.17 -6218.05 5933803.85 552624.49 MWD+IFR-AK-CAZ-SC 16112.01 90.83 183.97 3242.46 3120.91 -11742.19 -6223.46 5933708.80 552619.82 MWD+IFR-AK-CAZ-SC 16206.74 89.93 182.51 3241.83 3120.28 -11836.76 -6228.82 5933614.19 552615.21 MWD+IFR-AK-CAZ-SC 16301.80 91.62 182.84 3240.55 3119.00 -11931.70 -6233.25 5933519.23 552611.51 MWD+IFR-AK-CAZ-SC 16397.43 92.09 182.17 3237.45 3115.90 -12027.19 -6237.43 5933423.72 552608.08 MWD+IFR-AK-CAZ-SC 16489.61 91.47 182.55 3234.59 3113.04 -12119.25 -6241.22 5933331.65 552605.00 MWD+IFR-AK-CAZ-SC 16581.78 91.85 181.16 3231.92 3110.37 -12211.33 -6244.21 5933239.55 552602.74 MWD+IFR-AK-CAZ-SC 16673.92 90.43 177.47 3230.09 3108.54 -12303.43 -6243.10 5933147.48 552604.56 MWD+IFR-AK-CAZ-SC ~ 16766.33 90.30 177.18 3229.50 3107.95 -12395.73 -6238.79 5933055.21 552609.59 MWD+IFR-AK-CAZ-SC ~ 16856.70 91.87 178.71 3227.79 3106.24 -12486.02 -6235.55 5932964.96 552613.54 MWD+IFR-AK-CAZ-SC ~ 16948.80 91.29 178.19 3225.25 3103.70 -12578.05 -6233.06 5932872.96 552616.75 MWD+IFR-AK-CAZ-SC 17041.73 91.05 178.52 3223.35 3101.80 -12670.93 -6230.39 5932780.12 552620.14 MWD+IFR-AK-CAZ-SC 17133.93 89.19 177.53 3223.16 3101.61 -12763.07 -6227.22 5932688.02 552624.03. MWD+IFR-AK-CAZ-SC 17225.88 89.44 176.64 3224.25 3102.70 -12854.89 -6222.54 5932596.24 552629.42 MWD+IFR-AK-CAZ-SC /~ Halliburton Company Survey Report CompRny: ConocoPhilllps Alaska Inc. Datc: .1 0 /1 1120 0 7 Iimc: 1 x:23:59 Page_ Field: Kuparuk River Unit Co-ordinate(NE}Reference: Well: 1'J-176, Tr ue North Site: Kuparuk 1 J Pad Vertical ~ 1 ~;Dj Reference: 1 J-176 Actua! P.TE: 121.5 Well: 11-176 Section(VS)Reference: Well (O.OON,O.O OE,130.OOAii) Wellpath: iJ-176 Survey CakulationDleih6il: . __ _ Minimum Curva ture 1}b: Oracle _ ___ 5UR'ey MD iucl Aim l'~D SysTVD ~!S P:!~F ~tup~ MapE Tool. ft deg deg ft ft ft ft ft ft 17315.44 88.39 174.68 3225.95 3104.40 -12944.17 -6215.76 5932507.03 552636.90 MWD+IFR-AK-CAZ-SC 17410.42 89.36 176.90 3227.82 3106.27 -13038.87 -6208.79 5932412.39 552644.60 MWD+IFR-AK-CAZ-SC 17501.09 91.53 180.17 3227.11 3105.56 -13129.49 -6206.48 5932321.80 552647.63 MWD+IFR-AK-CAZ-SC 17592.76 92.45 181.33 3223.93 3102.38 -13221.09 -6207.68 5932230.20 552647.14 MWD+IFR-AK-CAZ-SC 17683.99 94.09 181.52 3218.72 3097.17 -13312.14 -6209.94 5932139.14 552645.59 MWD+tFR-AK-CAZ-SC 17775.09 93.39 180.77 3212.78 3091.23 -13403.03 -6211.76 5932048.26 552644.48 MWD+IFR-AK-CAZ-SC ~ 17867.55 93.58 180.12 3207.16 3085.61 -13495.32 -6212.47 5931955.98 552644.49 MWD+IFR-AK-CAZ-SC 17910.60 93.76 179.14 3204.41 3082.86 -13538.28 -6212.20 5931913.02 552645.10 MWD+IFR-AK-CAZ-SC ..17940.00 93.76 179.14 3202.48 ~ 3080.93 -13567.61 -6211.76 5931883.70 552645.77 PROJECTED to TD 1J-176 B Lateral liner Well: 1J-176 1~.VI~IOC4 ~ ~~f ~I~~ 5.5", 15.5 ppf, L-80, BTC-m and Hyd 521 slotted and blanks Date: 9/14/07 Alaska; lnc •~ ~>~~: Rig: Doyon 15 Depth Jt Number N ~~of Well Equipment Description•and Comments Page 1 Length Tops ..:.::..::.:.;:.;::.::.::.:;:.;:::.:..:.;:.;::.::.:.:;.:.;:.;:.;:.;:.;:.;:.:::;:.;:::.;:...:...:: .::::. .::: ~~;~::.::::>:: ;: ~»: •.;::;.» :::>:::;::;.»;::.:.:;:.:;;;:.;:.;:.;:.; 10446.97 Liner Running Tool 5" (Does not stay in hole) 10.71 10446.97 MLZXP Liner Top Packer 9-5/8" (8.43" ODx 7.50" ID) .21.24 <U8 FlexLock Liner Hanger 7" x 9-5/8" (8.30" OD x 6.19" ID) 5.29 10478.92 XO Bushing, 7" hyd 563 x 5-1/2" Hyd 563, (7.65" OD x 4.85" ID) 1.18 10484.21 190-47 Casing Seal Bore Ext., Hyd 563 B x P, (6.26" OD x 4.75" ID) 19.65 10485.39 XO Pup Jt. -Hydril 563 X Hydri1521, (6.05" OD x 4.93" ID) 3.87 10505.04 Jts 162 to 174 13 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 537.17 10508.91 Jts 161 to 161 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 42.09 11046.08 Jts 160 to 160 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 41.67 11088.17 Jts 159 to 159 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 39.31 11129.84 Jts 158 to 158 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 42.16 11169.15 Jts 157 to 157 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 40.94 11211.31 Jts 156 to 156 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 41.52 11252.25 Jts 155 to 155 1 Jts 5-1/2" 15.5 ppf, L-80, Hydri1521, Slotted Casing 41.76 11293.77 Jts 154 to 154 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 40.07 11335.53 Jts 153 to 153 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 41.95 11375.60 Jts 152 to 152 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 41.89 11417°55 Jts 151 to 151 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 38.47 11459.44 Jts 14 0 50 4 t 1 7 Jts 15-; :.::.;:.:.:.::..: ;:..:;::::.;:: ;: 1/2... ; .::.::;:::: . ~,~Y il.. 2'1..61 :::G s ::.::<:.<;<::»::>::;»::>»»»>::»::>::>::>::»::»>::»::>::::::»>::>::>::>::>::»:<:»;:<:»<:: 1.~.~~. f .L-80 .. . fit` ~ ~.... »>:::::. ::... ; :>::> >::... ;::> :::: Jts 143 to 143 1 Jts 5-1/2:' 15.5 ppf,. L-80, Hydril 521, Slotted Casing 40.58 11788°35 Jts 142 to 142 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 40.68 11828.93 Jts 141 to 141 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 42.19 11869.61 Jts 140 to 140 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 40.02 11911.80 Jts 139 to 139 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 41.94 11951.82 Jts 138 to 138 1 Jts 5-112" 15.5 ppf, L-80, Hydril 521, Blank Casing 41.31 11993.76 Jts 137 to 137 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 39.89 12035.07 Jts 136 to 136 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 41.48 12074.96 Jts 135 to 135 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 41.84 12116.44 Jts 134 to 134 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 38.88 12158.28 Jts 133 to 133 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 41.93 12197.16 Jts 6 0 3 12 t 1 2 7 Jts - :::::::::::.:::::..:..:.3:::::::.::::: ~: :t~ri.l: X21:. ~)~i~tEc.;fir'~..:::::...::::::::::.::::::.:::.::.:::...~:::.::::::.:::::::.::.:::.:::::::::::.: :::.: ~~~:7~..: : ~~~3;~. Jts 125 to 125 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 42.10 12519.82 Jts 124 to 124 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 41.49 12561.92 Jts 123 to 123 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 40.15 12603.41 Remarks: Ran total of 175jts Csg = 7,369.54' (Inc Shoe) / 56jts Slots = 2362.76' / 119jts Blank = 5006.78' (Inc Shoe) Ran Total 143 SpiroGliders Floating 1 Per joint (None on Constrictor joints or the last 13 jts) Up Wt 290K Used Run-N-Seal thread compound on all connections. Dn Wt 70K Drifted casing to 4.825" w/ teflon rabbit. Block Wt 70K Torque Rings Installed in joints #49 Thru #106 = 58 torque rings Rot Wt 170K Su ervisors: Mike Thornton / Scoft Heim ~' ~ Jt Number um of J COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 122 to 122 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 38.19 12643.56 Jts 121 to 121 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 40.29 12681.75 Jts 120 to 120 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 38.51 12722.04 Jts 119 to 119 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 40.66 12760.55 Jts 118 to 118 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 41.64 12801.21 Jts 117 to 117 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 39.09 12842.85 Jts 116 to 116 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Blank Casing 41.99 12881.94 Jts 115 to 115 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 39.70 12923.93 Jts 08 1 to 114 : Yi: :.::::.. .. : : . 7 Jts ;< ~~. / 9 .......................................................................... .................... ..... _.... Jts 107 to 107 1 Jts 5-1/2" 15.5 ppf, L-80, Hydril 521, Slotted Casing 37.32 13245.55 x-over 5-1/2" 15.5 ppf, L-80, Hydril 521x 5-1/2" 15.5 ppf L-80 BTC (5.713" x 4.9") 1.55 13282.87 Jts 106 to 106 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.39 13284.42 Jts 105 to 105 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 42.68 13327.81 Jts 104 to 104 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.39 13370.49 Jts 103 to 103 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.62 13413.88 Jts 102 to 102 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.35 13457.50 Jts 101 to 101 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.45 13500.85 Jts 100 to 100 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.62 13544.30 Jts 99 to 99 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.14 13587.92 Jts 98 to 98 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 42.80 13631.06 Jts 97 to 97 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.30 13673.86 Jts 90 to 96 7 J s '.=:.::.<.... . t ~ ........ ''~..::..1..~•x.5r..:.:. ~ .: L.: $~ .: BTG::~1~11 k. C~S~#'I::::~: t~ ...: r.~~1 .::::::.:::::.::::.; :::::...:::::.::::::::.::::.::.::.:::..:. :.::::.:294.:31.. :::::x:3.71.7>:1:8 Jts 89 to 89 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 39.09 14011.47 Jts 88 to 88 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 42.64 14050.56 Jts 87 to 87 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing wl torq Ring 43.09 14093.20 Jts 86 to 86 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.52 14136.29 Jts 85 to 85 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.75 14179.81 Jts 84 to 84 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.38 14223.56 Jts 83 to 83 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 38.35 14266.94 Jts 82 to 82 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.41 14305.29 Jts 81 to 81 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.18 14348.70 Jts 8o to 80 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.33 14391.88 Jts 79 to 79 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.52 14435.21 t 72 t 7 7 t ~.: "1.1~...: ~ ~~,~.~>:... f : L-~€~ :~'~`~C:::~Ian.l~.~~[:~~~ :1hil:l;t~t~ >:t~~ ..:::::::::::::::.::::::::::::::::::::::::::::::::::::::::::::: .............~..............~~.s............~.............::::::::::::::::.::::::::::..:~.:::::::::::::::::.::::::::.~.:::::::::::::::::::.:::.:::::::::::::::::::::::::::::::::::::: :::::::.303..33.: :.::::::::::::::::::::::: ::14~F'~g:'~3 :::::::.:::::::::::::. Jts 71 to 71 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.45 14780.06 Jts 70 to 70 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 39.71 14823.51 Jts 69 to 69 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 42.97 14863.22 Jts 68 to 68 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 41.89 14906.19 Remarks: ~' ~ Jt Number um of J COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 67 to 67 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.36 14948.08 Jts 66 to 66 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.43 14991.44 Jts 65 to 65 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 42.20 15034.87 Jts 64 to 64 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 43.65 15077.07 Jts 63 to 63 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.31 15120.72 Jts 62 to 62 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 42.57 15164.03 Jts 61 to 61 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.50 15206.60 Jts 55 to 60 6 J is ~:<; ;:.. ~::'kl~..::>1.5 :. :. ~ ..............p . f~: L: ~~,: ~~~.: B.I.~~t.I~:.Casi~g :~vf..~~r...;~~.:::::.::;::<:.:::,:::::::::::.::<:.;:::.;:,:::;;.;;:;:;<.:;.;:.:;:.;:.;: g ::.;::;:~~9,:~9: ;::~;~~~t~.; Jts 54 to 54 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ torq Ring 43.33 15509.89 Jts 53 to 53 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ torq ring 41.12 15553.22 Jts 52 to 52 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ Torque Ring 43.26 15594.34 Jts 51 to 51 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ Torque Ring 43.37 15637.60 Jts 5o to 50 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing w/ Torque Ring 43.39 15680.97 Jts 49 to 49 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing w/ Torque Ring 43.44 15724.36 Jts 48 to 48 9 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.74 15767.80 Jts 47 to 47 1 Jts 5-112", 15.5 ppf, L-80, BTC Blank Casing 43.57 15811.54 Jts 46 to 46 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.45 15855.11 Jts 45 to 45 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.18 15898.56 Jts 44 to 44 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.37 15941.74 Jts 38 0 3 t 4 6 J is :. ::F::..... .: .:. . 'i.::. .:<.::.... . 5.:.1...x;:.::1.....,5:::..f :~»8€~`<<BT~::13I~ ::.:::;: s . .::::.:::::.:::::::::::::::::::::..::::..:::::.:::::.:.::::::::::::::::::::::::::::::::::::::: ::::::. 66.. ....:.:.> :. Jts 37 to 37 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 42.19 16241.50 Jts 36 to 36 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.62 16283.69 Jts 35 to 35 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.30 16327.31 Jts 34 to 34 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.63 16370.6'1 Jts 33 to 33 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 42.44 16414.24 Jts 32 to 32 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.66 16456.68 Jts 31 to 31 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.49 16500.34 Jts 30 to 30 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.38 16543.83 Jts 29 to 29 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.43 16587.21 Jts 28 to 28 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.35 16630.64 Jts 27 to 27 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.02 16673.99 Jts 21 to 26 6 J s f 5... f <:: <:~0 .. ...... 1 Jts 20 to 20 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.23 16975.38 Jts 19 to 19 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.60 17018.61 Jts 18 to 18 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 42.93 17062.21 Jts 17 to 17 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.58 17105.14 Jts 16 to 16 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.53 17148.72 Jts 15 to 15 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.15 17192.25 Remarks: Jt Number um of J COMPLETE DESCRIPTION OF EQUIPMENT RUN .Page 4 LENGTH TOPS Jts 14 to 14 1 Jts 5-112",15.5 ppf, L-80, BTC Slotted Casing 43.48 .17235.40 Jts 13 to 13 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.20 17278.88 Jts 12 to 12 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.09 17322.08 Jts 6 to 11 6 J is ;~. 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'::. :::; ~: /rr/////~~~''..... ~~>:/~.y~:.:}[:..y/;~~:; . ;:.;>,,~_. ]~: :::;:>::>::::»::::::«::::<;;>:::<:::>:::::::;::»::;:>:>:::::;::»::: ~:~:::;:<::;::.;:;::;:::>:<::;;;;;:;.:»::>::>:.><: .~v.~.T#T... ..~~~~:. .. ..~ :.M!~V :.1K.~.4:.Y..: ~~RI.I.l1::~!~~~17.~ :. ~::::.: ~ :::::::: ::::.:n ~:::::. ~::: :•:::::.: ~::::.: ~:.~ :::::::v...:::::. ~: ::v.:.........:. .:..... ~...:.......:v, .. 1......... x .: ....................:................:..... ..........:.:..::.:.................::::v:....:.::..:::::::::..: :...; ......::::..:.......:..: ,:,.,. ., .......:.. ::;:><::::255:.:7~# ....::..........:....... :........:.:............ :.:1.'~ .....;.:.:.; ......~ 51.7 .....:..:. ~...5......: .:.:v. :...............: Jts 5 to 5 1 Jts 5-112",15.5 ppf, L-80, BTC Slotted Casin g 43.32 17620.87 Jts 4 to 4 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.57 17664.19 Jts 3 to 3 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.37 17707.76 Jts 2 to 2 1 Jts 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 43.15 17751.13 Jts 1 to 1 1 Jts 5-1/2",15.5 ppf, L-80, BTC Slotted Casing 43.24 17794.28 5-1/2", 15.5 ppf, L-80, BTC Blank Casing 40.54 17837.52 5-1/2" Silver Bullet Shoe 1.94 17878.06 Bttm of Shoe =_> 17880.00 17880.00 17880.00 Top of liner 10,457.68 17880.00 Top Of Window planned 10236' = 221.68' above TOL 17880.00 TD 8-1/2" hole 17,940.00' MD / 3202.48' TVD 17880.00 5-1/2" Shoe 17,880' MD / 3206' TVD 17880.00 (60.0' RatHole) 17880.00 Run 1 SpiroGlider per joint floating on the BTC S< Hyd 521 17880.00 On jts #1 thru #161 Total of 143 (None on Constrictor joints) 17880.00 17880.00 68 Jts Hydril 521 (Blanks/Slots) = 2,773.96' 17880.00 Torque Rings in joints #49 thru #106, 58 total = 2,483.38' 17880.00 17880.00 17880.00 Installed 18 Constrictors 17610', 17385', 16974', 16730', 16240', 17880.00 15995', 15499', 15265', 14750', 14500', 13999', 13750', 13240', 13000', 17880.00 12499', 12250', 11750', 11507'. 17880.00 17880.00 Baker Stab-In insert installed 1' up in the pin end of Jt #1 @ 17,836'. 17880.00 17880.00 17880.00 17880.00 17880.00 17880.00 17880.00 17880.00 Remarks: s ~s Time Lo s ..Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/17/2007 06:00 12:00 6.00 0 0 MIRU DRILL RURD P Held PJSM with crew. Discuss saftey & hazard recognition issues. Discuss picking up and racking back stands of drill pipe. Begin racking back stands. Pick up 78 joints. Obtain SLM. Prep S ud mud, and rime mud um s. 12:00 14:15 2.25 0 0 MIRU DRILL RURD P Continue pick up 5" DP from shed and rack back stands for a total of 78 stands in derrick. Tag well bottom 110'. Perform Koomey draw down test. Pressure to 200 PSi in 24 seconds, with full pressure @ 2 min, 38 sec. Witness of Diverter test waived by , ~AOGCC Chuck Sheave. Observed 34 seconds for annular & knife valve to function fully. Pull lift subs and equipment to rig floor. Change out fairlead on DS to er. 14:15 14:30 0.25 0 0 MIRU DRILL SFTY P Held PJSM with crew, Sperry sun reps. Discuss safety & hazard recognition issues. Discuss making u BHA #1. 14:30 18:00 3.50 0 0 SURFA DRILL PULD P Make up BHA#1, with 16" Hughes MX-1, and 8" SperryLobe motor with 1.83 deg bend. Continue making up S ud BHA. Crew chan e. 18:00 18:30 0.50 0 0 SURFA DRILL PULD P Continue make up BHA #1 as per DD & MWD. Bha len th = 105' fors ud. 18:30 19:15 0.75 0 0 SURFA DRILL SFTY P Held PJSM with crew. Flood conductor with water and check for leaks on system. C-ose IBOP & perform surface pressure test to 3000 PSI. No leaks. Bleed ressre. 19:15 19:30 0.25 0 0 SURFA DRILL REAM P Wash & ream conductor with water from 110' - 120'. Displace well with 300+ visc s ud mud. 19:30 00:00 4.50 0 317 SURFA DRILL DRLG P S ud well 1930 HRS. Drill from 120' - 317', utilizing GYRO surveys as DT = 2.73 HRS. Bit HRS = 2.73 HRS. 08/18/2007 00:00 06:00 6.00 317 736 SURFA DRILL DDRL P Continue directional drill 16" surface hole form 317' - 736' MD. TVD = 732'. ADT = 2.32 HRS. Bit HRS = 6.67. Observed clean surveys at 413' MD as er S er Sun. Crew Chan e 06:00 12:00 6.00 736 1,008 SURFA DRILL DDRL P Continue directional drill 16" surface hole form 736' - 1008' MD. TVD = 995'. ADT = 2.40 HRS. Bit HRS = 9.07. Rig down Halliburton G ro unit. 12:00 18:00 6.00 1,008 1,403 SURFA DRILL DDRL P Continue directional drill 16" surface hole form 1008' - 1403' MD.TVD = 1341'. ADT = 3.08 HRS. Bit HRS = 12.15. Crew Chan e 18:00 21:45 3.75 1,403 1,593 SURFA DRILL DDRL P Continue directional drill 16" surface hole form 1403' - 1593' MD.TVD = 1489'. ADT = 1.89 HRS. Bit HRS = 14.04. ~a~e 2 0~ 53~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T> COM 08!18/2007 21:45 23:00 1.25 1,593 1,593 SURFA DRILL REAM P Perform reaming operation to knock down dogleg from 1498' - 1593' while circulate & condition mud @ 770 GPM's - 2000 PSI. 23:00 00:00 1.00 1,593 1,593 SURFA DRILL REAM P Back ream from 1593' - 1438' MD @ 5 ft/min with 700 GPM's - 1540 PSI, circulating & conditioning mud as needed. Observed surveys indicating questionable "B" totals. Obtain 4 point checkshot surveys. Send info to town to obtain QC checks from town on tool. 08/19/2007 00:00 00:45 0.75 1,593 1,593 SURFA DRILL REAM P Continue back ream from 1438' - 1216' MD @ 5 ft/min with 700 GPM's - 1540 PSI, circulating & conditioning mud as needed. Observed surveys indicating questionable "B" totals. Obtain 4 point checkshot surveys. Send info to town to obtain OC checks from town on tool. 00:45 01:00 0.25 1,593 1,593 SURFA DRILL TRIP P Trip back to 1593' MD'. Observed good clean hole conditions. 01:00 01:30 0.50 1,593 1,593 SURFA DRILL CIRC P Circulate & obtain 4 point check shots surveys for comparison of "B" totals. Send info to town for repeat QC checks. QC check indicated tool is ro erl workin . 01:30 06:00 4.50 1,593 1,955 SURFA DRILL DDRL P Continue directional drill 16" surface • hole from 1593' - 1749' MD. Obtain check shot surveys every 30'. Observed surveys cleaned up and "B" totals satisfactory. Continue drilling from 1749' - 1955' MD. ND = 1723'. ADT = 2.46 HRS. Bit Hrs -16.5 Crew Chan e 06:00 12:00 6.00 1,955 2,335 SURFA DRILL DDRL P Continue drilling from 1955' - 2335' MD. ND = 1909'. ADT = 2.95 HRS. Bit Hrs - 19.45 12:00 18:00 6.00 2,335 2,800 SURFA DRILL DDRL P Continue drilling from 2335' - 2800' MD. ND = 2047'. ADT = 3.32 HRS. Bit Hrs - 22.77 Crew Chan e 18:00 00:00 6.00 2,800 3,211 SURFA DRILL DDRL P Continue drilling from 2800' - 3211' MD. TVD = 2157'. ADT = 2.66 HRS. Bit Hrs - 25.43 08/20!2007 00:00 03:00 3.00 3,211 3,401 SURFA DRILL DDRL P Continue drilling from 3211' - 3401' MD. ND = 2202'. ADT = 1.86 HRS. Bit Hrs - 27.29 HRS 03:00 06:00 3.00 3,401 3,401 SURFA DRILL REAM P Observed inclination increase of to 77.4 deg. Attempt to reduce inclination bylnvashing & ream~g to the low side. Pumps @ 525-580 GPM's - 1750-2000 PSI. 50 RPM's. Crew Chan e 06:00 12:00 6.00 3,401 3,401 SURFA DRILL REAM P Continue work drill string to reduce inclination by washing & reaming to the low side. Pumps @ 525-580 GPM's - 1750-2000 PSI. 50 RPM's. Time Lo s Date From To Dur S . De th E. De th P hase Code Subcode T COM 08/20!2007 12:00 13:00 1.00 3,401 3,401 S URFA DRILL REAM P Continue work drill string to reduce inclination by washing & reaming to the low side. Pumps @ 525-580 GPM's - 1750-2000 PSI. 50 RPM's. 13:00 13:15 0.25 3,401 3,430 S URFA DRILL DDRL P Continue drilling from 3401' - 3430' MD. ND = 2211'. Obtained survey, i ndicating slight reduction in i nclination. 13:15 16:30 3.25 3,430 3,430 S URFA DRILL REAM P Continue work drill string to reduce i nclination by washing & reaming to the low side. Pumps @ 525-580 GPM's - 1750-2000 PSI. 50 RPM's. 16:30 18:00 1.50 3,430 3,610 SURFA DRILL DDRL P Continue drilling from 3430' - 3610' MD. ND = 2255'. ADT = 1.12 HRS. Bit Hrs - 28.51 HRS Crew Chan e 18:00 21:00 3.00 3,610 3,805 SURFA DRILL DDRL P Continue drilling from 3610' to TD section @ 3805' MD. ND = 2302'. ADT = 1.59 HRS. Bit Hrs - 30.10 HRS 21:00 00:00 3.00 3,805 2,834 SURFA DRILL REAM P Pump 40 BBL sweep at TD, BROOH at 30 min/stand until sweep returned. Increase back ream rate to 10 min/stand pulling to 2834' MD. Back ream rate at 850 GPM's - 2100 PSI. Observed hole unloadin . 08/21/2007 00:00 03:00 3.00 2,834 1,692 SURFA DRILL REAM P Continue BROOH @ 10 min/stand pulling to 1692' MD. Back ream rate at 850 GPM's - 2100 PSI. Observed hole unloading. Slowed pump rate to 500 GPM's on the last stand. 03:00 04:30 1.50 1,692 3,805 SURFA DRILL TRIP P Trip back in hole to TD. Work drill string through 3403' - 3498' with no issues. Repeat 2 times. Observed clean hole. 04:30 06:00 1.50 3,805 3,805 SURFA DRILL CIRC P Circulate bottoms up to clean up well & condition mud. Recipriocate & rotate drill string. Pumps @ 800 GPM's - 2200 PSI. 50 RPM's - 7K torque. Observed no significant increase in cuttings across shakers when swee returned. Crew Chan e 06:00 08:30 2.50 3,805 1,575 SURFA DRILL TRIP P Monitor well -static. POOH on elevators from 3805' - 1640'. 08:30 09:00 0.50 0 SURFA DRILL REAM P Observed hole swabbing with overpuli @ 1640' - 1575' MD. Wash & ream through area with pumps on & off to veri clean. Observed ro er hole fill. 09:00 10:30 1.50 1,575 360 SURFA DRILL TRIP P Continue POOH on elevators from 1575' - 360' MD. Observed proper hole fill. 10:30 13:00 2.50 360 0 SURFA DRILL PULD P Breakout & lay down BHA as per DD & MWD. Inspect & grade bit to 1 /1 /MIT/A/E/I/ST/TD. 13:00 14:00 1.00 0 0 SURFA DRILL PULD P Clean & clear rig floor of tools & equipment. Held PJSM with crew & GBR reps. Discuss safety & hazard recognition issues. Discuss rigging up casin a ui ment. Pzne 4 ai 53 Time Lo s Date From To Dur S. De th E. De #h Phase Code Subcode T COM 08/21/2007 14:00 16:00 2.00 0 0 SURFA CASIN( RURD P Pull tools to rig floor. Rig GBR casing equipment. Held PJSM on running order & rocedure to run casin . 16:00 18:00 2.00 0 505 SURFA CASIN( RNCS P Make up Ray Oil tool Sitver Bullet Eccentric Float Shoe with 13 3/88" shoe track joint & Float collar. Continue run casing to 505' MD. Make up torque = 8K ft/Ibs. Observed proper hole fill. Crew Chan e 18:00 20:30 2.50 505 1,410 SURFA CASIN( RNCS P Continue run casing from 505' - 1410' MD. Make up torque = 8K ft/Ibs. Observed ro er hole fill. 20:30 00:00 3.50 1,410 1,413 SURFA CASIN< RNCS T bserved brid a in hole at 1410'. Work ~._ casing string beating down on bridge with 3' of success to midnight. Pump rates = 3-7 BPM, with UP WT = 195K, SO WT = 145K. 08/22/2007 00:00 05:00 5.00 1,413 1,417 SURFA CASIN( RNCS T Continue work casin tying beating down on bridge at 1410' MD. Normal movement up pulling free & clean. observed possible hanging up on bottom of conductor with casing collars. Pump rates = 3-7 BPM, with UP WT = 180K, SO WT = 150K. Attempt to wash hole with 10 BPM, 690 PSI. Continue to beat down. After an hour, observed pressure increase of 100 PSI when shoe on bottom. Prior to this, no increase in pressure had been seen when shoe on bottom. Discuss options with engineer. Total foots a made = 6-7'. 05:00 06:00 1.00 1,417 1,417 SURFA CASIN( RNCS T Ri in u to pull 13 3/8" casing out of . hole from 1417'. Mix & pump 60 BBLS, 12 PPG d 'ob. Crew Chan e 06:00 12:00 6.00 1,417 900 SURFA CASIN( RNCS T Continue rig up to pull 13 3/8" casing. Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to breakout & lay down casing. POOH, breakout 8~ lay down 13 3/8" casing. Breakout torques 9-10K FUlbs. Observed ro er hole fill. 12:00 15:30 3.50 900 120 SURFA CASIN( RNCS T Continue POOH, breakout & lay down 13 3/8" casing. Breakout torques 9-10K Ft/Ibs. Observed 4 blades off of the bows yin centralizers left in hole. Observed ro er hole fill. 15:30 17:00 1.50 120 0 SURFA CASIN( RNCS T Rig up. Obtain Hot work permit. Cut Shoe track joint above each collar. Lay down same. Rig down cutting e ui ment. 17:00 18:00 1.00 0 0 SURFA CASIN( RURD T Clean & clear rig floor of mud, tools, and casin a ui ment. Crew chan e 18:00 19:30 1.50 0 705 SURFA DRILL PULD T Make up BHA #2, 16" Ghost reamer with bullnose assembly and HWDP. . Total len th = 705.71' i i _ e'GS,~E 5 OS F.'1 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/22/2007 19:30 20:15 0.75 705 1,753 SURFA DRILL TRIP T Trip in hole with BHA #2 from 705' to 1450'. observed no tag or any i ndication of obstruction. Work assembly through area of 1400' - 1753'. Clean hole. 20:15 21:00 0.75 1,753 1,753 SURFA DRILL CIRC T Circulate & condition mud @ 1753', pumping 300 visc mud around, and dis lacin out 60 BBL d 'ob. 21:00 21:30 0.50 1,753 705 SURFA DRILL TRIP T POOH from 1753' to 705'. Rack back HWDP. 21:30 22:15 0.75 705 0 SURFA DRILL PULD T Break out & lay down remaining BHA. Observed hole opener ascked off with cuttin s. 22:15 23:00 0.75 0 0 SURFA DRILL PULD T Clean & clear rig floor area. Pull tools to ri floor for next BHA run. 23:00 23:45 0.75 0 308 SURFA DRILL PULD T Make up BHA #3. Hole opener assembly. Stiffened assembly with Non mag flex drill collars and 2 stands of 5" HWDP. Added a 15.9" OD Sleeve e stabilizer. Total Ien th = 308.32'. 23:45 00:00 0.25 308 SURFA DRILL TRIP T Trip in hole with BHA #3 from 308' - 879'. Observed ro r hole fill. 08/23/2007 00:00 02:00 2.00 879 3,805 SURFA DRILL TRIP T Trip in hole with BHA #3 from 879' - 1410' MD. Did not see any obstruction at the 1410' depth. Work hole operner through area, with no indication of obstruction. Disuss options with Rig engineer. Continue trip in hole to 3805' MD, observe tag up on spots @ 2239', 2402'-2497' and 3226' & tagging bottom on depth. Work hole opener through until clean at each depth. Observed proper hole fill. 02:00 03:45 1.75 3,805 3,447 SURFA DRILL CIRC T Circulate with pumps @ 600 GPM's - 960 PSI while BROOH at 10 ft/min to condition mud. BROOH from 3805' - 3447', until mud properties of 250 Visc, 9.5 PPG mud weight. No significant increase in cuttings across shakers. 03:45 06:00 2.25 3,447 1,000 SURFA DRILL TRIP T Continue POOH from 3447' to 1000'. Observed proper hole fill. Hole looked clean. Crew Chan e 06;00 06:30 0.50 1,000 0 SURFA DRILL TRIP T Continue POOH from 1000' to BHA. 06:30 08:45 2.25 0 0 SURFA DRILL PULD T Obtain hot work permit. Breakout & lay down BHA. Cut welded straps of off bullnose to hole o ener. 08:45 09:15 0.50 0 0 SURFA DRILL PULD T Clean & clear rig floor of tools & equipment. Prepare rig floor for casing run. 09:15 10:30 1.25 0 0 SURFA CASIN ( RURD T Pulls tools & equipment to rig floor. Ri u GBR casin a ui ment. Nape 6 of ~3 l Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/23/2007 10:30 12:00 1.50 0 0 SURFA CASIN( RURD T Complete rig up of GBR equipment. Held PJSM with crew, and GBR reps. Discuss safety & hazard recognition issues. Discuss procedure to run 13 3/8" casing. Make up Weathertord 303 Sure Seal float shoe & joint, with threadlock joint, and 402 Float collar & joint. Baker lock threads. MU TQ = 8K ft/lbs. Fill i e & check floats. Good. 12:00 13:15 1.25 0 1,410 SURFA CASIN( RNCS T Run 13 3/8" casin to 1410' with no issues. 13:15 15:15 2.00 1,410 2,600 SURFA CASIN( RNCS P Continue run 13 3/8" casing from 1 X10' - 2600'. Obtain T&D parameters as per ri en ineer. 15:15 16:00 0.75 2,600 2,600 SURFA CASIN( CIRC P Circulate & condition Mud @ 2600' MD. Recip_ r_ ocat string Pumps @ 215 GPM - 390 PSI. UP WT = 255K, SO WT = 95K. Obtain T&D parameters as er ri en ineer. 16:00 17:30 1.50 2,600 3,744 SURFA CASIN( RNCS P Continue run casing from 2600' - 3744' MD. No hole issues. Obtain T&D parameters as per rig engineer. Observed ro er di lacement. 17:30 18:00 0.50 3,744 3,792 SURFA CASIN( RNCS P Make up hanger with landing joint. UP WT = 300K, SO WT = 145K. Slack off to land casing hanger on depth wits hoe 3792' MD. Crew Chan e 18:00 19:00 1.00 3,792 3,792 SURFA CEME~ CIRC P Reciprocate casing string while rig down all casing running equipment. Rig up long landing joint, and make up cement head & lines. 19:00 23:00 4.00 3,792 3,792 SURFA CEME~ CIRC P Circulate & condition mud while reci rotate casin strip in 15 foot _~ increments. Pre treating properties = 9.4 PPG, 300 Visc, PV=43, YP =52 and Gels @ 45 / 112. Pre cement properties = 9.4 PPG, Visc = 70 PV - 36, YP - 18, with gels @ 5/7. Drop volume in pits for cement job. Position & rig up trucks. Held PJSM with crew, Vac truck drivers & Dowell cementer crew. Discuss safety & hazard recognition issues. Discuss procedure for um in cement 'ob. 23:00 00:00 1.00 3,792 3,792 SURFA CEME~ DISP P Tum over to Dowell. Pump 10 BBIs CW 100. Test lines to 3000 PSI. pump 40 BBIs of CW 100. Continue with 50 BBIs of 10.5 PPG MudPush @ 4 BPM - 200 PSI. Good, full reci rocation.Dro bottom lu . i=~ge 7 of ~3 E ~ • Time Lo s Date From To Dur S: De th E. De th Phase Code Subcode T COM ... 08/24/2007 00:00 01:30 1.50 3,792 3,792 SURFA CEME~ DISP P Continue pumping with Dowell Pumping a total of 630 BBIs of 10.7# Lead cement followed with 99.1 BBIs of 12.0# Tail cement. Drop Top plug, and flush lines with 10 BBIs of water. Continued with good reciprocation of string in 15 ft increments. UP WT = 300K, SO WT = 145K 01:30 03:30 2.00 3,792 3,792 SURFA CEMEI~ DISP P Tum over to rig pumps. Displace cement with 7 BPM - 830 PSI ICP, continue reci rotation until observed string weight falling to 95K and losing movement with 65 BBLs of Lead on annulus. Set casing on hanger, continue to displace observing mud push returns with 165 BBLS pumped, 10.4 PPG cement with 187 BBLS pumped, 10.7 PPG cement returns at 408 BBIs pumped, for a total of 245 BBLS of cement retums to surface. Slow pumps at 4400 stks, and observe plug bump @ 4604 stks = 543 BBLS as calculated with FCP @ 3 BPM - 800 PSI. Pressure to 1300 PSI, hold for 10 minutes. Bleed pressure and check floats. Floats held. CMIP 0315 HRS. 03:30 04:30 1.00 0 0 SURFA CEME~ RURD P Rig down cement equipment, lines and head. Blow down all lines. Back out and to down landin 'oint. 04:30 06:00 1.50 0 0 SURFA WELCT NUND P Flush out & nipple down diverter system, flowlines, and buoy line. Crew Chan e 06:00 10:15 4.25 0 0 SURFA WELCT NUND P Continue nipple down diverter system, flowlines, and buo line. Clean its. 10:15 11:15 1.00 0 0 SURFA WELCT NUND P Nipple up Vetco Gray Multibowl tree as per rep. test packoffs to 250 / 5000 PSI. 11:15 14:30 3.25 0 0 SURFA WELCT NUND P Nipple up BOP stack, choke & kill lines. Install double block valves on annulus. Attach flowlines, fillup lines, and hose. perform housekeeping in cellar area. 14:30 15:30 1.00 0 0 SURFA WELCT BOPE P Install test plug with 5" testjoint. Fill BOP stack & choke manifold with water. Charge hydraulic lines on Koomey. Function test HCR's. Begin takin on`LSND mud. 15:30 18:00 2.50 0 0 SURFA WELCT BOPE P est BOP stack i e r~s HCR' and mauals. test Choke manifold and ' . i valves. All tests to 250 / 3000 PSI. Test witnessed by AOGCC rep John Cris .Crew Chan e Page ~ aS 53 1 C Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/24/2007 18:00 20:15 2.25 0 0 SURFA WELCT BOPE P Continue test BOP stack & valves to 250 / 3000 PSI. Test pipe rams with 5", 5 1/2" and 9 5/8" test joints. perform Acumulator draw down test. Observed 200 PSI increase in 42 seconds, with full 3000 PSI at 2 minutes, 59 seconds. Pressure avg in nitrogen bottles @ 2300 PSI. Test wintenessed by AOGCC rep John Cris . 20:15 21:30 1.25 0 0 SURFA WELCT BOPE P Rig down BOP test equipment. Blow down lines including choke manifold, choke & kill lines. Line up choke for drilling. Pull test plug. Install wear bushing as per Vetco Gray rep. RILDS. 21:30 22:00 0.50 0 0 SURFA WELCT OTHR P Clean & clear rig floor of tools and e ui ment. Pull tools to ri floor. 22:00 22:15 0.25 0 0 SURFA DRILL SFTY P Held PJSM with crew & Sperry sun reps. Discuss safety & hazard recognition issues. Discuss procedure to make u BHA #4. 22:15 23:15 1.00 0 76 SURFA DRILL PULD P MAke up BHA #4. Make up 9600 Geo-Pilot with 12 1/4" Security FMFH3643ZZ bit. Make up Non mag flex drill colalr, smart stabilizer and float sub.MAke u MWD assembl . 23:15 00:00 0.75 76 76 SURFA DRILL OTHR P Plug in and Upload MWD assembly. 08/25/2007 00:00 00:15 0.25 76 76 SURFA DRILL OTHR P Complete upload of MWD assembly. 00:15 01:15 1.00 76 365 SURFA DRILL PULD P Make up remaining BHA #4. MU Non Mag flex drill collars, drilling jars, and HWDP. Total len th = 365.92'. 01:15 02:45 1.50 365 1,991 SURFA DRILL TRIP P Trip in hole picking up 5" DP singles from i e shed to 1991' MD. 02:45 03:00 0.25 1,991 1,991 SURFA DRILL PULD P Make up 12 1/4" Ghost reamer on top of stand # 17. 03:00 03:45 0.75 1,991 1,991 SURFA DRILL OTHR P Perform shallow pulse test on MWD assembly. Trouble shoot connections. Pump & rotate drill string to break in seal bearin son Geo-Pilot. 03:45 05:30 1.75 1,991 3,703 SURFA DRILL TRIP P Contiue trip in hole picking up singles form pipe shed. to 3607' MD. Picked up a total of 102 joints. Continue trip in from derrick to 3703'. Observed proper dis lacement. 05:30 06:00 0.50 3,703 3,703 SURFA RIGMN SVRG P Service Top Drive & draw works. Crew Chan e 06:00 08:00 2.00 3,703 3,703 SURFA DRILL CIRC P Circulate & condition mud plus 2 bottoms up with pumps @ 770 GPM's - 1500 PSI. 30 RPM'S. UP WT - 155K, SO WT -100K, ROT WT - 125K. 08:00 08:45 0.75 3,703 3,703 SURFA DRILL DHEQ P Ri u and test c sin - 30 Min Ri down test a ui ment. Fade 3 ci ~3 ~~ . Time Lo s Date From To Dur S. De th E. De th Phase Cade Subcode T COM 08/25/2007 08:45 09:45 1.00 3,703 3,708 SURFA CEME~ COCF P Drill out Float equipment tagging float collar on depth @ 3708' MD with pumps @ 750 GPMs-1500 PSI. 5-10K WOB. 09:45 10:45 1.00 3,708 3,805 SURFA CEMEt~ COCF P Drill cement in the shoe track & show from 3708' -3792', then open hole to 3805' MD. 5-18K WOB with pumps @ 750 GPMs-1500 PSI. 5-10K WOB. 10:45 11:00 0.25 3,805 3,825 SURFA DRILL DDRL P Drill 12 1/4" hole from 3805' - 3825' for 20' of new hole. 11:00 12:00 1.00 3,825 3,825 SURFA DRILL CIRC P Circulate Mud displacing hole with 9.0 PPG LSND @ 770 GPM's - 1400 PSI. FCP = 1040 PSI. 12:00 13:00 1.00 3,825 3,825 SURFA DRILL LOT P Rig up equipment & perform LOT test. as er Co. man to a 14.3 PPG EMW.~„_,: Record on chart. 3825 MD, TVD = 2305'. Bleed pressure and rig down test equipment. Obtain Clean hole ECD at 9.3 PPG. 13:00 18:00 5.00 3,825 4,823 INTRM1 DRILL DDRL P Directional drill 12 1/4" INT hole from 3825' - 4823' MD. TVD = 2455'. ADT = 3.51 HRS, Bit HRS = 3.67. ECD = 9.66 PPG. Crew Chan e 18:00 00:00 6.00 4,823 5,758 INTRM1 DRILL DDRL P Directional drill 12 1/4" INT hole from 4823' - 5758' MD. ND = 2577'. ADT 4.18 HRS, Bit HRS = 7.85. ECD = 9.89 PPG. 08/26/2007 00:00 06:00 6.00 5,758 6,743 INTRM1 DRILL DDRL P Directional drill 12 1/4" INT hole from 5758' - 6743' MD. TVD = 2706'. ADT = 3.96 HRS, Bit HRS = 11.81. ECD = 10.07 PPG. Obtain Slow pump rates. Crew Chan e 06:00 12:00 6.00 6,743 7,883 INTRM1 DRILL DDRL P Directional drill 12 114" INT hole from 6743' - 7883' MD. TVD = 2861'. ADT = 3.19 HRS, Bit HRS = 15.0. ECD = 10.26 PPG. 12:00 18:00 6.00 7,883 8,816 INTRM1 DRILL DDRL P Directional drill 12 1/4" INT hole from 7883' - 8816' MD. TVD = 2977'. ADT = 3.31 HRS, Bit HRS = 18.31. ECD = 10.43 PPG. Obtain Slow pump rates. Crew Chan e 18:00 23:00 5.00 8,816 9,690 INTRM1 DRILL DDRL P Directional drill 12 1/4" INT hole from 8816' -9690' MD. TVD = 3095'. ADT = 3.63 HRS, Bit HRS = 21.94. ECD = 10.81 PPG. Slowed penetration rate to less than 200 ft/hr at 9450' MD for the K-13 transition. 23:00 00:00 1.00 9,690 9,690 INTRM1 DRILL CIRC P Circulate 40 BBLS sweep at 1050 GPM's - 3350 PSI, while reciprocate & rotate drill string. Observed no increase in cutiings when sweep returned as per calculated strokes plus 4000 stks. Observed ECD's drop forma 10.81ppg to 10.50 PPG after circulation. ;tea JA 2 g cf 53 i • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/27/2007 00:00 01:00 1.00 9,690 9,690 INTRM1 DRILL CIRC P Continue circulate 40 BBLS sweep at 1050 GPM's - 3350 PSI, while reciprocate & rotate drill string. Observed no increase in cutiings when sweep returned as per calculated strokes plus 4000 stks. Observed ECD's drop forma 10.81 ppg to 10.50 PPG after circulation. 01:00 06:00 5.00 9,690 10,218 INTRM1 DRILL DDRL P Continue directional drill 12 1/4" INT hole from 9690' - 10218' MD. TVD = 3158'. ADT = 3.50 HRS, Bit HRS = 25.44. ECD = 10.56 PPG. Continue drilling with slowed penetration rate to less than 200 ft/hr for the K-13 transition. Crew Chan e 06:00 12:00 6.00 10,218 10,776 INTRM1 DRILL DDRL P Continue directional drill 12 1/4" INT hole from 10218' - 10776' MD. TVD = 3227'. ADT = 3.79 HRS, Bit HRS = 29.23. ECD = 10.41 PPG. Continue drilling with slowed penetration rate to less than 200 ft/hr for the K-13 transition to 10350' MD. Obtained slow um rates at 10355 MD. 12:00 14:15 2.25 10,776 11,010 INTRM1 DRILL DDRL P Continue directional drill 12 1/4" INT hole from 10776' to TD section at 11010' MD. TVD = 3251'. ADT = 1.65 HRS, Bit HRS = 30.88. ECD = 10.40 PPG. 14:15 16:00 1.75 11,010 11,010 INTRM1 DRILL CIRC P Circulate & condition mud while reciprocate drill string. Pumps @ 1025 GPM - 3100 PSI. RPM's - 150 with 16K TO off bottom. Pumpe 45 BBLS Hi-Visc weighted sweep observing slight increase in cuttings when sweep returned to shakers. 16:00 18:00 2.00 11,010 10,700 INTRMI DRILL REAM P BROOH at 1-3 FT/MIN from 11010' - 10700' MD at drilling rates. Crew Chan e 18:00 21:30 3.50 10,700 10,264 INTRMI DRILL REAM P Continue BROOH at 1-3 FT/MIN from 10700' -10264' MD at drilling rates. Pumped a total of 6 bottoms up, and shakers clean. Observed ECD @ 10.05 PPG.. 21:30 22:30 1.00 10,264 9,313 INTRM1 DRILL TRIP P POOH on elevators from 10264' - 9313'. Observing overpull. Work drill string, and BROOH as needed from 9378' - 9313' MD. 22:30 00:00 1.50 9,313 8,647 INTRMI DRILL REAM P BROOH from 9313' - 8647' MD with pumps @ 1025 GPM's - 2900 PSI. 150 RPM's. Observed hole unloading, and occasional overpulls, working drill strin each time throu hover ull s ot. 08/28/2007 00:00 06:00 6.00 8,647 5,986 INTRM1 DRILL REAM P Continue BROOH from 8647' - 5986' MD with pumps @ 1025 GPM's - 2900- 2540 PSI. 140 RPM's w/ 9-11 k ft Ibs of torque. PU wt 160k, SO wt 100k, Rot wt 130k. ~ ?~g~e ~ F e~ ~3 r~ • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/28/2007 06:00 11:30 5.50 5,986 3,703 INTRM1 DRILL REAM P Continue BROOH from 5986' - 3703' MD with pumps @ 1050 GPM's 2540-2330 PSI. 120 RPM's w/ 12k ft Ibs of torque. Attempted to pull on elevators @ 5416' pulled tight, so kept backreamin . 11:30 14:15 2.75 3,703 3,703 INTRM1 DRILL CIRC P Circ, pumping 1050 gpm w/ 1740 psi. Rotate 120 gpm w/ 7k ft Ibs of torque. Pumped two sweeps. (1) 45 bbl 11 ppg/ 250 vis, brought back 50% increase in cuttings. (2) 45 bbls 10.7 ppg/ 300 vis, brought back an increase of 20% of cuttin s. 14:15 15:30 1.25 3,703 3,703 INTRMI RIGMN SVRG P Slip and cut 114' of 1 3/8"drilling line. 15:30 16:00 0.50 3,703 3,703 INTRMI RIGMN SVRG P Service top drive and crown. 16:00 16:30 0.50 3,703 3,703 INTRM1 DRILL CIRC P Monitor well, static. Pump dry job. ins ect saver sub, OK. 16:30 18:00 1.50 3,703 365 INTRM1 DRILL TRIP P POOH on elevators. Hole took proper dis lacement. 18:00 19:15 1.25 365 74 INTRM1 DRILL TRIP P Work BHA, Lay down worn stabilizer. 19:15 20:00 0.75 74 74 INTRM1 DRILL OTHR P Download MWD. 20:00 20:15 0.25 0 INTRM1 DRILL SFTY P PJSM on laying down BHA. 20:15 21:30 1.25 74 0 INTRM1 DRILL PULD P Lay down BHA # 4. Grade bit. 21:30 22:00 0.50 0 0 INTRMI DRILL OTHR P Clear and clean floor w/ blind rams shut. 22:00 23:45 1.75 0 80 INTRM1 DRILL PULD P PU/MU BHA #5 (12.25" Hole opener) 23:45 00:00 0.25 80 80 INTRM1 DRILL OTHR P Upload Sperry Sun MWD. 08/29/2007 00:00 00:15 0.25 80 80 INTRM1 DRILL OTHR P Continue to upload Sperry Sun MWD. 00:15 00:30 0.25 80 80 INTRM1 DRILL SFTY P PJSM w/ Sperry Sun and crew on loadin Nuke sources. 00:30 00:45 0.25 80 80 INTRM1 DRILL OTHR P Load Nuke sources. 00:45 01:15 0.50 80 370 INTRM1 DRILL TRIP P Continue to PU/MU BHA # 5 (hole o ener. 01:15 05:30 4.25 370 6,600 INTRMI DRILL TRIP P Trip in the hole. Record PU and SO wt's every 10 stands in casing, fill eve 20 stands. 05:30 17:30 12.00 6,600 9,050 INTRM1 EVALFI DLOG P Logging w/ Neutron Density. 360-450 ft/hr. Pumping 1050 gpm w/ 2690-2850 psi. Rotating 150 rpm w/ 8-14k ft Ibs of for ue. 17:30 18:30 1.00 9,050 10,250 INTRM1 DRILL TRIP P Trip in the hole. PU wt 195k, SO wt 95k. Page h e of ~3 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/29/2007 18:30 00:00 5.50 10,250 10,875 INTRM1 EVALFI DLOG P Logging w/ Neutron Density. 200 ft/hr. Pumping 1050 gpm w/ 3010 psi. Rotating 150 rpm w/ 14-16k ft Ibs of torque. Rot wt 135k, Total gas 110 units. 08/30/2007 00:00 01:15 1.25 10,875 11,008 INTRM1 EVALFI DLOG P Logging w/ Neutron Density. 200 ft/hr. Pumping 1050 gpm w/ 3230-3240 psi. Rotating 150 rpm w/ 16-18k ft Ibs of torque. PU wt 195k, SO wt 95k, Rot wt 140k final. 01:15 07:30 6.25 11,008 10,455 INTRM1 DRILL CIRC P Circ 6 BU's. Pumped a sweep after 1+ BU, then another sweep after another BU, then 4 more BU. Total of 66470 strokes (7857 bbls). Rotate 150 rpm w/ 16-17k ft Ibs of torque. PU wt 195k, SO wt 95k, Rot wt 135k. Pumping 1050 gpm w/ 3080 psi. Sweep #1:50 bbl, 11.4 ppg/ 300 vis-- no increase in cuttings. Sweep #2: 50 bbl, 11.4 ppg/ 300 vis- no increase in cuttin s. 07:30 07:45 0.25 10,455 10,455 INTRMI DRILL OWFF P Monitor well 07:45 08:45 1.00 10,455 8,652 INTRM1 DRILL TRIP P POOH on elevators. Hole taking correct fill. No overpull. Hole is in good sha e. 08:45 09:00 0.25 8,652 8,652 INTRM1 DRILL CIRC P Monitor well, static. Pumpadryjob. 09:00 11:15 2.25 8,652 3,703 INTRM1 DRILL TRIP P POOH on elevators. Hole took 20 bbls over calculated displacement. No overpull. Record PU and SO wt's every 5 stands f! the Ri en ineer. 11:15 12:45 1.50 3,703 3,703 INTRM1 DRILL CIRC P Circ and condition mud and hole (casing). Pumping 1050 gpm w/ 1900 psi. Rotate 150 rpm w/ 7k ft Ibs of torque. Circulate a total of 2124 bbls (4.4 BU's). Pumped a 45 bbl sweep (11ppg/300 vis) with no significant increase in cuttin s after the first BU. 12:45 13:15 0.50 3,703 3,703 INTRM1 DRILL CIRC P Pump and spot outside of the drill string a 72 bbl steel tube pill. Pumped 72 bbls of volume of pill (7% by volume steel tube= 4 drums), chased w/ 34 bbls of mud and then a 20 bbl dry job, followed w/ 10 bbls chase. 13:15 14:30 1.25 3,703 370 INTRMI DRILL TRIP P POOH on elevators. Hole took another 20 bbls over calculated displacement for a total of 40 bbls over calculated. 14:30 15:30 1.00 370 80 INTRM1 DRILL TRIP P Work BHA. 15:30 15:45 0.25 80 80 INTRM1 DRILL SFTY P PJSM on removing Nuke sources. 15:45 16:00 0.25 80 80 INTRM1 DRILL OTHR P Remove Nuke sources. 16:00 16:30 0.50 80 80 INTRM1 DRILL OTHR P Download Sperry Sun MWD. ._ - F`&~2 `~ c~~ b~ r • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/30/2007 16:30 17:15 0.75 80 0 I NTRM1 DRILL PULD P Lay down BHA. 17:15 17:30 0.25 0 0 I NTRM1 DRILL OTHR P Clean rig floor. 17:30 18:30 1.00 0 0 I NTRM1 WELCT OTHR P With the blinds shut, change out the top pipe rams from 3-1 /2" x 6" varaibles to 10-3l4" casin rams. 18:30 20:00 1.50 0 0 INTRM1 WELC7 OTHR P Back out lockdown screws, remove Vetco Gray wear bushing. Install Vetco Gray test plug. RU chart recorder and testin a ui ment. 20:00 21:00 1.00 0 0 INTRM1 WELCT BOPE P Test top pipe rams to 250 psi low and 3000 si hi h. Hold test f/ 5 min. OK. 21:00 21:30 0.50 0 0 INTRM1 WELCT OTHR P Pull test plug and rig down testing e ui ment. 21:30 21:45 0.25 0 0 INTRM1 CASIN( SFTY P Pre job safety meeting on rigging up to run intermediate casin . 21:45 23:45 2.00 0 0 INTRM1 CASIN( RURD P Rig up to run 9-5/8" x 10-3/4" intermediate casin strin . 23:45 00:00 0.25 0 0 INTRM1 CASIN< SFTY P PJSM on running intermediate casing per the detail. Note: Hole taking about 1bbl/hr static. 08/31/2007 00:00 05:00 5.00 0 1,966 INTRM1 CASIN( RNCS P Run 9-5/8" 40 ppf L-80 BTC-m casing per casing detail. After jt # 40- Record PU and SO wt's eve 10 'ts. 05:00 05:30 0.50 1,966 1,966 INTRM1 CASIN< CIRC P Circulate bottom's up. Circ 3 bpm w/ 180 psi, 19% flow, after observing no losses increase to 4 bpm w/ 190-200 si, 22% flow. Circ total of 134 bbls. 05:30 06:00 0.50 1,966 2,228 INTRM1 CASIN( RNCS P Continue running 9-5/8" 40 ppf L-80 BTC-m casing. Record PU and SO wt's every 10 jts. Monitor returns using pit #4. At 1996': PU wt 150k, SO wt 140k. 06:00 11:00 5.00 2,228 4,989 INTRM1 CASIN( RNCS P Continue running 9-5/8" 40 ppf L-80 BTC-m casing. Record PU and SO wt's every 10 jts until) jt # 98, then every 5 jts in open hole.. Monitor returns using pit #4. Hole dis lacement is correct. 11:00 12:45 1.75 4,989 5,065 INTRM1 CASIN( CIRC P Circ 2 jts in the hole f/ 4989' to 5065'. Circulate 4 bpm w! 270 psi and 22% flow. No losses. Circulate a total of 290 bbls, a bottom's u . 12:45 15:30 2.75 5,065 7,300 INTRM1 CASIN( RNCS P Continue rurining 9-5/8" 40 ppf L-80 BTC-m casing. Record PU and SO wt's every 5 jts. Monitor returns using it #4. Hole dis lacement is correct. 15:30 16:15 0.75 7,300 7,300 INTRM1 CASIN ( CIRC P Circulate 4 bpm w/ 290 psi and 23% flow. No losses. Circulate a total of 150 bbls, a o en hole volume. 16:15 18:30 2.25 7,300 8,913 INTRM1 CASIN ( RNCS P Continue running 9-5/8" 40 ppf L-80 BTC-m casing. Record PU and SO wt's every 5 jts. Monitor returns using it #4. Hole dis lacement is correct. Page ~4 a€ 53 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM-, 08/31/2007 18:30 19:00 0.50 8,913 8,913 INTRM1 CASIN( CIRC P Circulate 4 bpm w/ 340 psi and 24% flow while moving down. No losses. Circulate a total of 176 bbls. Change single joint elevators to 10-3/4". PU wt 255k, SO wt 97k. 19:00 19:45 0.75 8,913 8,940 INTRM1 CASIN( RURD P Change out Frank's fillup tool to 10-3/4"and segments in the elevators to 10-3/4". MU 9-5/8" x 10-3/4" x-o 't. 19:45 21:00 1.25 8,940 8,940 INTRM1 CASIN( CIRC P Circulate 4 bpm w/ 400 psi and 24% flow while moving down. No losses. Circulate a total of 256 bbls. Changing segments in the slips to 10-3/4", change tong heads to 10-3/4", UD fillup tool f/ 9-5/8". Change floor safety valve to 10-3/4" size. PU wt 230k, SO wt 120k. 21:00 00:00 3.00 8,940 9,900 INTRM1 CASIN( RNCS P Runnin 10-3/4" 73.2 ppf L-80 BTC-m casin .Checking MU torque. To make up to MU mark 17-18k ft lbs. Settle in on MU torque of 14k ft lbs. Record down wt's every 5 jts. PU wt 300k, SO wt 125k. 09/01/2007 00:00 03:00 3.00 9,900 10,975 INTRM1 CASIN( RNCS P Running 10-3/4" 73.2 ppf L-80 BTC-m casing. Record down wt's every 5 jts. Drop the 3.5" ball to convert the flog t collar to conventional a ui m # 282. 03:00 03:30 0.50 10,975 10,990 INTRM1 CASIN< RNCS P MU landing jt and establish circulation w/ Frank's fillup tool. Pumping 2 bpm w/ 420 psi, 3bpm w/ 440 psi, 4 bpm w/ 480 psi and 23% flow. Circ the landing joint down and circ 135 bbls total. No mud loss to the formation on casin run. 03:30 04:00 0.50 10,990 10,990 INTRM1 CASIN( RURD P Remove Frank's fillup tool. Rig down tongs, scaffolding, single joint elevators. 04:00 04:15 0.25 10,990 10,990 INTRM1 CEMEI~ RURD P RU Dowell cementing head and lines. 04:15 06:00 1.75 10,990 11,002 INTRM1 CEMEI~ CIRC P Circ and condition mud and hole for cement. Reciprocate 30' stroke. PU Wt 320, SO wt 150k. Establish circulation w/ 3bpm w/ 330 psi and 22 flow, increase to 4 bpm w/ 360 psi and 22% Flow. Pumping the 3.5" ball to seat on the Davis Lynch Float Collar. No mud losses. Pumped a total of 636 bbls 3/4 of volume to FC . 06:00 08:15 2.25 11,002 11,002 INTRMI CEME~ CIRC P Continue to circ and condition mud and hole for cement. Reciprocate 30' stroke. PU Wt 320, SO wt 150k . Slowed pump rate to 2 bpm w/ 210 psi and 20% flow. Pumping the 3.5" ball to seat on the Davis Lynch Float Collar. No mud losses. s rage 15 of 53 ~- Time Lo s Date From To Dur S. IIe th E. De th Phase Code Subcode T COM 09/01/2007 08:15 10:30 2.25 11,002 11,002 I NTRM1 CEME~ CIRC P I ncrease pump rate to 7 bpm w/ 400 psi and 28% flow, then slow to 6 bpm w/ 320 psi w/ 27% flow. While pumping: PU wt 305k, SO wt 155k. With pumps off: PU wt 330k, SO wt 157k PJSM on cementjob while circulating. Mud properties prior to circ 9.0 ppg in, 9.2 ppg out, Vis 43, PV 12, YP 16, 10 min gel 9, Mud properties after conditioning 9.05 ppg in, 9.05 ppg out, Vis 39, PV 10, YP 12, 10 min el 5. 10:30 13:00 2.50 11,002 11,002 INTRM1 CEME~ OTHR P Turn over to Dowell and cement as per plan: 10 bbls CW 100 at rate of 5.5 bpm @ 300 psi, Test lines to 3000 psi - OK, 90 bbls CW100 (8.34ppg) at rate of 5.0 bpm @ 200 psi, 75 bbls mud push (11 ppg), drop bottom plug, Mix & Pump 921 sxs, 370.8 bbls cement (12.5 ppg) DeepCRETE Cement w/ 31 % D 124, 24% D 178, .60% D46, .20% D167, .07% D185, .06% D110 w/ Yield of 2.25 ft3/sk, Mixed in 1.2 ppb CemNET while mixing cement, Drop top plug, Kick plug out w/ 5.0 bbls fresh water, Had full returns while `ix & pump (No losses), Then turn over to the ri for dis lacement. 13:00 15:30 2.50 11,002 11,002 INTRMI CEME~ DISP P Displace w/ 8.5 ppg MOBM. Pumping 6 bpm w/ 190 psi initial and 630 psi final before slowing down pumps to 3 bpm after 744.5 bbls pumped. Pumping 3 bpm w/ 500 psi and 17% flow, Bumped plug w/ 846.8 bbls 8.5 ppg MOBM. Reciprocated pipe w/ 30' strokes working down to 5' strokes as cement rounded shoe, Stoppeifrpipe on de th after 144.5 c ent ar un shoe due to pipe gettin tight, ad good returns thru out jo w/ no observed losses. CIP @ 1530 hrs 9/1/2007. Shoe @ 11,000' MD / 3,251' TVD, Float collar 10,909'. 15:30 16:00 0.50 11,002 11,000 INTRMI CEME~ OTHR P Pressure up to 1000 psi (500 over circ rate pressure), held f/ 5 min. Bleed off pressure and check floats. Floats n_ot holdin .Pressure back up to 1000 psi, hold for 2 min, bleed off again. Floats still not holding. Pressure up a third time to 1000 psi and hold. Waiting on cement to set up while holding 1000 si on the casin strin . 16:00 19:30 3.50 11,000 11,000 INTRM1 CEME ~ WOC T Waiting on cement to set-- Floats not holding in the Davis Lynch auto fill Type 713-MP-LP Float collar. Preparing to PU stack. Cleaning pits and rockwasher. Pace 5 ~ c~ 53~ • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/01/2007 19:30 20:00 0.50 11,000 11,000 INTRM1 CEME~ OTHR T Check floats/cement set after bumping plug 4 hrs ago. Bleed off pressure. Still appears to be leaking a small amount back. 20:00 22:30 2.50 11,000 11,000 INTRM1 CEME~ WOC T Repressure back up to 800 psi and hold pressure while WOC. Rig up to perform infectivity test on 13-3/8" x intermediate casin 9-5/8" x 10-3/4" 22:30 23:45 1.25 11,000 11,000 INTRM1 CEME~ LOT P Perform infectivity test on 13-3/8" surface casing x 9-5/8" & 10-3/4" intermediate casing with annular closed on the 10-3/4" casing. Chart test. Mud in the annulus = 9.0 ppg. Pump a total of 20 bbls. Bleed back 5 bbls. EMW is 12.8 ppg w/ 460 psi _ leak off point. Shoe of 13-3/8" is at 2301'TVD. 23:45 00:00 0.25 11,000 11,000 INTRM1 CEME~ OTHR T Bleed off 800 psi on the casing string and check floats/ cement set. No flow back. OK. 09/02/2007 00:00 00:30 0.50 11,000 11,000 INTRM1 CEMEI~ RURD P Rig down cementing equipment. 00:30 01:45 1.25 11,000 11,000 INTRMI WELCT NUND P Nipple down BOP stack in preparation to set emergency slips and packoff. Use rig vacuum system to suck oil base mud from inside of the landing 'oint. 01:45 02:00 0.25 11,000 11,000 INTRM1 WELCT SFTY P PJSM on PU BOP's and setting slips. 02:00 02:30 0.50 11,000 11,000 INTRM1 WELCT OTHR P Increase PU wt f/ 260k to 315k. Attempt to install slips. Would not fit around the 10-3/4" casing. OD of the casing measured 10.81" which is within allowable range of 1% over (reference section 8.11.3 Mass, API 5CT: Jul 2005. 02:30 05:30 3.00 11,000 11,000 INTRM1 CASIN( OTHR NP Work on slips to fit around the 10-3/4" casing. The slips were a little out of round. 05:30 06:00 0.50 11,000 11,000 INTRM1 CASIN( OTHR NP Install emergency slips and slack off to block wt of 70k. Wt of 245k on the sli s. 06:00 08:45 2.75 11,000 0 INTRM1 CASIN< OTHR P Prepare pipe cutting/ beveling machine and cut the 10-3/4" casin . 08:45 09:15 0.50 0 0 INTRM1 CASIN( RURD P Lay down cut off jt and landing joint. Install vetco/Gra ackoff. 09:15 10:45 1.50 0 0 INTRM1 WELCT NUND P NU Vetco Gray Multibowl wellhead and Doyon Rig 15 BOPE. Test connection to 5000 psi. Witness of test b Vetco Gra and driller. 10:45 11:15 0.50 0 0 INTRM1 WELCT OTHR P Pick up the 5" test joint and Vetco Gra test lu .Set test lu . F~:~P `7 of 53 i • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM " 09/02/2007 11:15 12:00 0.75 0 0 I NTRM1 WELCT OTHR P Change upper rams from 10-3/4 casing rams to 3-1/2" x 6" variable rams. A near miss occured wTien the ram block on the driller's side fell about 10' while closing the rams to change ram blocks back to the 3-1/2" x 6" variables.. 12:00 13:30 1.50 0 0 INTRMI DRILL OTHR P The rig flushed the 13-3/8" x 9-5/8" & 10-3/4" annulus with 181 bbls of additional water. Pump rate 2 bpm w/ 500 psi average pressure. SIP 410 psi. Litlle Red freeze protected w/ 80 bbls of diesel later while rig was picking up drill pipe. Pumping 1 bpm w/ 600 psi max. Final ressure 500 si. 13:30 16:45 3.25 0 0 INTRM1 DRILL PULD P Pickup/makeup stand back in the derrick 14 stands of 5" drill pipe from the pipe shed. This makes 15 stands on the driller's side. SLM from the derrick. 16:45 18:00 1.25 0 0 INTRM1 RIGMN SVRG P Slip and cut 68' of 1-3/8" drilling line. 18:00 21:00 3.00 0 0 INTRM1 RIGMN SVRG P Changeout the saver sub and dies in the grabbers for the top drive. Inspecting Hydril top pipe ram door on the driller's side with a Hydril rep Mark Mazur . 21:00 21:30 0.50 0 0 INTRM1 RIGMN SVRG P Service top drive, blocks and drawworks and inspect chains on the drawworks. Working on the upper ram door- driller's side w/ a H dril re . 21:30 22:00 0.50 0 0 INTRM1 RIGMN RGRP T Change out the clutch on the door of the driller's side of upper pipe rams. Function the rams. A ears OK. 22:00 23:00 1.00 0 0 INTRM1 WELCT OTHR P Tighten bolts on the doors of the top i e rams. Ri u testin a ui merit. 23:00 23:30 0.50 0 0 INTRM1 WELCT BOPE P Test u er i (3-1/2" x 6" variables). Test to 250 psi low and 3000 psi high. Hold test 5 min each. Chart test. 23:30 00:00 0.50 0 0 INTRM1 WELCT OTHR P Rig down testing equipment. Set Vetco/Gray wear bushing, run in lockdown screws. Blow down choke and kill lines. 09/03/2007 00:00 00:30 0.50 0 0 INTRM1 DRILL OTHR P Install Vetco/Gray 13-3/8" x 9" ID wear bushing (3.16' long) and secure w/ two lockdown screws. 00:30 00:45 0.25 0 0 INTRMI DRILL SFTY P PJSM on PU/MU BHA #6. 00:45 02:00 1.25 0 78 INTRM1 DRILL PULD P PU/MU BHA #6 02:00 02:30 0.50 78 78 INTRM1 DRILL OTHR P Upload Sperry Sun MWD 02:30 03:30 1.00 78 350 INTRM1 DRILL PULD P Continue to MU BHA#6. Page ~~ Q ~3 • • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/03/2007 03:30 04:00 0.50 350 350 INTRM1 CASIN( CIRC P Shallow test MWD tools. Pumping 350 gpm w/ 1480 psi. rotate and break in seals on the GeoPilot w/ 35 rpm and 1 k ft Ibs of torque. Rotating wt 100k. 04:00 05:30 1.50 350 1,944 INTRM1 DRILL PULD P PUJMU/RIH w/ 5" drill pipe f/the pipe shed. Drift w/ 2-7/8" rabbit. 05:30 08:00 2.50 1,944 6,988 INTRMI DRILL TRIP P Continue RIH w/ 5"drill pipe f/ the derrick. Fill every 25 stands. Record PU and SO wt's every 10 stands. Rotate to break in seals when filling pipe. 2700' :210 gpm w/ 320 psi. Rot wt 120k. Rot 35 rpm w/ 3k ft Ibs of torque. PU wt 120k, SO wt 110k. 6988' :375 gpm w/ 1100 psi.. Rot 35 m w/ 5k ft Ibs of for ue. 08:00 08:30 0.50 6,988 6,988 INTRM1 DRILL CIRC P Fill pipe, pumping 375 gpm w/ 1100 psi. Rotate 35 rpm w/ 5k ft Ibs of torque. Rotate to break in seals when fillip i e. 08:30 12:00 3.50 6,988 10,726 INTRM1 DRILL PULD P PU/MU/RIH w/ 5"drill pipe w/super sliders f/ the pipe shed. Drift w/ 2-7/8" rabbit. Fill pipe every 25 stands. Record PU and SO wt's every 10 stands. 12:00 12:30 0.50 10,726 10,894 INTRM1 DRILL TRIP P Trip in the hole w/ BHA #6. PU wt 210k, SO wt 85k. 12:30 14:00 1.50 10,894 10,894 INTRMI DRILL CIRC P Circulate bottom's up. Pumping 680 gpm w/ 3460 psi. Rotate 80 rpm w/ 10k ft Ibs of torque. Rotating wt 125k. Circulate a total of 770 bbls. 14:00 15:00 1.00 10,894 10,894 INTRM1 DRILL DHEQ P RU and test 10-3/4" & 9-5/8" casing .t4 3000 psi usin to i e rams. Not holdin . Leakin abo 1 15:00 15:30 0.50 10,894 10,894 INTRM1 DRILL CIRC P Circulate bottom's up. Pumping 650 gpm w/ 3210 psi. Rotate 80 rpm w/ 10k ft Ibs of torque. Rotating wt 125k. Circulate a total of 351 bbls. 15:30 16:30 1.00 10,821 10,821 INTRM1 DRILL DHEQ P RU and test 10-3/4" & 9-5/8" casing to 3000 psi using top pipe rams. Not . . Idin .Leaking about 100 psi per min. 16:30 17:00 0.50 10,821 10,821 INTRMI DRILL OTHR P _Test surface equipment to 3500 psi. Good test. ~~ 17:00 17:15 0.25 10,821 10,821 INTRM1 DRILL OWFF T Monitor well, OK. 17:15 17:45 0.50 10,821 10,726 INTRMI DRILL TRIP T POOH, SLM. PU wt 210k, 85k down wt. 17:45 18:00 0.25 10,726 10,726 INTRM1 DRILL CIRC T Pump a 25 bbl dry job (10.5 ppg/ 103 vis . Pum in 210 m w/ 500 si. 18:00 23:15 5.25 10,726 78 INTRMI DRILL TRIP T Pull out of the hole. Monitor hole on the trip tank. Record PU and SO wt's eve 10 stands. SLM. 23:15 23:30 0.25 78 78 INTRM1 DRILL OTHR T Downlaod MWD. Turn off batteries. =ache ~ 9 c€ 53 t r Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/03/2007 23:30 00:00 0.50 78 0 I NTRM1 DRILL TRIP T Stand back bit and GeoPilot. No correction on drill i e SLM. 09/04/2007 00:00 00:30 0.50 0 0 I NTRM1 DRILL DHEQ T RU to test 10-3/4" x 9-5/8" i ntermediate casin . 00:30 01:15 0.75 0 0 I NTRMI DRILL DHEQ T Test 10-3/4" x 9-5/8" casing to 3000 psi with the blind rams shut. Pumping through the kill line. Pump 6-8 strokes per minute. Pump a total of 134 strokes. Lost 500 si in 6 minutes. 01:15 01:30 0.25 0 0 INTRM1 DRILL SFTY T Bleed off pressure. PJSM on PU/MU Baker "EA" Retrievamatic acker. 01:30 02:00 0.50 0 11 INTRM1 DRILL PULD T MU Baker "EA" Retrievamatic to a stand of 5" drill i e 02:00 03:00 1.00 11 2,103 INTRM1 DRILL TRIP T Trip in the hole w/ Baker "EA" Retrievamatic to test casin . 00 03 03:30 50 0 103 2 103 2 INTRM1 DRILL DHEO T Test the 10-3/4" casing by setting the . : . , , acker in the first joint of 9-5/8 Pressure up to 3050 psi. Lost 50 psi in 5 min. OK. Note: Did not try to get all of the air out of the s stem. 03:30 06:15 2.75 2,103 6,478 INTRM1 DRILL TRIP T Trip in the hole w/ Baker "EA" Retrievamatic to test casin . 15 06 06:45 50 0 478 6 478 6 INTRM1 DRILL DHEQ T Test the 10-3/4" casing by setting the __ : . , , acker in the 'oint #118. Pressure up to 3050 psi. Lost 40 psi in 5 min. OK. Note: Did not try to get all of the air out of the s stem. 06:45 09:30 2.75 6,478 10,885 INTRM1 DRILL TRIP T Trip in the hole w/ Baker "EA" Retrievamatic to test casin . 09:30 10:45 1.25 10,885 10,885 INTRM1 DRILL DHEQ T Test the 10-3/4" casing by setting the packer below the box of joint #3. Pressure up the annulus to 3055 psi. Shut in pumps with 3040 psi, Iost.100 psi in 30 min. Held 96.7% of pressure. Charted test f/ 30 min. 10:45 11:00 0.25 10,885 10,861 INTRM1 DRILL CIRC T Unseat packer turning to the right. Pump a 20 bbl dry job (10.3 ppg/73 vis . Pum in 125 m w/ 280 si. 11:00 16:30 5.50 10,861 11 INTRM1 DRILL TRIP T POOH w/ Baker "EA" retrievamatic acker. 16:30 16:45 0.25 11 0 INTRM1 DRILL PULD T Lay down Baker "EA" retrievamatic acker. 16:45 17:30 0.75 0 0 INTRM1 WELCT OTHR P Pull Vetco/Gray wear bushing. 17:30 18:00 0.50 0 0 INTRM1 WELCT OTHR P Ri up to test BOPE. Test was due on 9-7/2007. Install upper test plug, fill stack with water, ri u chart recorder. F~ge 2~ of ~3 • • Time Lo s .Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/04/2007 18:00 23:45 5.75 0 0 INTRM1 WELCT BOPE P • TestAnnularand upper pipe rams (3-1/2" x 6"), floor safety valves, upper IBOP, lower IBOP, choke line and kill line and choke manifold to 250 psi low and 3000 psi high. Hold each test 5 min. Chart test. Witness of test waived by AOGCC inspector Jeff Jones. Tested annular w/ 4-1/2" & 5". Upper pipe rams were tested w/ 4-1/2", 5" and 5-1/2" test joint. Koomey test: 5 bottles avg 2300 psi. Operated all stations, final of 1550 psi, 200 psi increase in 42 seconds, full char a in 3 min 2 seconds. 23:45 00:00 0.25 0 0 INTRM1 WELCT OTHR P Rig down testing equipment. Install Vetco Gray wear bushing (13-3/8"OD x 9" IDx 38" Ion . 09/05/2007 00:00 00:30 0.50 0 0 INTRMI DRILL OTHR P Blow down choke and kill lines, drain oor bo de asser. 00:30 00:45 0.25 0 0 INTRM1 DRILL SFTY T PJSM on PU/MU BHA #8. 00:45 02:00 1.25 0 352 INTRM1 DRILL PULD T Make up BHA #8. 02:00 02:30 0.50 352 352 INTRM1 DRILL CIRC T Shallow test MWD and break in seals on the GeoPilot. 02:30 08:15 5.75 352 10,821 INTRM1 DRILL TRIP T Trip in the hole w/ BHA #8. Record PU and SO wt's every 10 stands. Fill eve 20 stands. 08:15 09:30 1.25 10,821 10,821 INTRM1 RIGMN SVRG P Slip and cut 75' of 1-3/8" drilling line. 09:30 10:00 0.50 10,821 10,821 INTRM1 RIGMN SVRG P Service rig (Drawworks, crown and top drive . 10:00 10:45 0.75 10,821 10,900 INTRM1 DRILL TRIP T Make a top drive connection, establish circulation, work down to TOC @ 10900'. 10:45 14:45 4.00 10,821 11,010 INTRM1 CEME~ DRLG P Drill cement @ 10900', two wiper plugs, Davis Lynch autofill (Type 713-MP-LP) float collar @ 10909', cement, Davis lynch guide shoe (Type 601) @ 10998' to 11000', then clean out rat hole to 11010'. 14:45 15:15 0.50 11,010 11,030 INTRM1 DRILL DDRL P Drill 20' of new hole. 15:15 16:30 1.25 11,030 11,030 INTRMI DRILL CIRC P Circulate 1036 bbls. Rotate 80 rpm w/ 10k ft Ibs of for ue. 16:30 16:45 0.25 11,030 10,976 INTRM1 DRILL OTHR P Rig up to perform Leak Off Test. 16:45 17:45 1.00 10,976 10,976 INTRM1 DRILL LOT P Perform LOT. Apply 800 psi w/ 8.4 ppg MW, TVD 3251'= 13.1 ppg EMW. Pum ed 7.6 bbls, bleed back 3.5 bbls. 17:45 18:00 0.25 10,976 10,976 PROD1 DRILL OTHR P Rig down equipment. ~' Fage ~1 c#53 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/05/2007 18:00 18:30 0.50 10,976 11,030 PROD1 DRILL CIRC P Perform PWD baseline test w/ 8.45 ppg mw, PV/YP 13/15. Rotating t orque 12-13k ft lbs. Pumping 600 gpm w/ 2590 psi: 90 rpm - 10.05 ppg, 120 rpm --10.08 ppg, 150 rpm -- 10.14 ppg. 650 gpm w/ 2970 psi: 90 rpm - 10.17 ppg, 120 rpm -- 10.21 ppg, 150 rpm -- 10.29 ppg. 700 gpm w/ 3390 psi: 90 rpm -- 10.30 ppg, 120 rpm -10.34 ppg, 150 m -- 10.42 18:30 00:00 5.50 11,030 11,580 PROD1 DRILL DDRL P Directional drill "B" lateral. 09/06/2007 00:00 06:00 6.00 11,580 12,569 PROD1 DRILL DDRL P Directional drill "B" lateral. 06:00 12:00 6.00 12,569 13,501 PROD1 DRILL DDRL P Directional drill "B" lateral. 12:00 18:00 6.00 13,501 14,525 PROD1 DRILL DDRL P Directional drill "B" lateral. 18:00 00:00 6.00 14,525 15,700 PROD1 DRILL DDRL P Directional drill "B" lateral. 09/07/2007 00:00 06:00 6.00 15,700 16,534 PROD1 DRILL DDRL P Directional drill "B" lateral. 06:00 12:00 6.00 16,534 16,997 PROD1 DRILL DDRL P Directional drill "B" lateral. 12:00 14:00 2.00 16,997 17,136 PROD1 DRILL DDRL P Directional drill "B" lateral. 14:00 15:30 1.50 17,136 17,136 PROD1 RIGMN RGRP T Backream f/ 17236'to 16982' (154') while working on mud pump # 2. Rotate 120 rpm w/ 16-17k ft Ibs of torque. Pumping 451 gpm w/ 2100 psi. PU wt 260k, Rot wt 145k. 15:30 18:00 2.50 17,136 17,354 PROD1 DRILL DDRL P Directional drill "B" lateral. 18:00 00:00 6.00 17,354 17,820 PROD1 DRILL DDRL P Directional drill "B" lateral. 09/08/2007 00:00 04:45 4.75 17,820 17,940 PROD1 DRILL DDRL P Directional drill "B" lateral. 04:45 07:00 2.25 17,940 17,710 PROD1 DRILL CIRC P Pump a 50 bbls Hi vis weighted sweep (10.2 ppg/ 200 vis), Backream slow-slow (1-2'/min) while circ sweep out of the hole. Rotate 125 rpm w/ 18 k ft Ibs of torque. Pumping 600 gpm w/ 3840 psi. ECD's prior to sweep 11.25 ppg-- after sweep is out of the hole 11.6 07:00 08:30 1.50 17,710 .17,230 PROD1 DRILL REAM P Backream 40' min. Rotate 120 rpm w/ 18 k ft Ibs of torque. Pumping 600 gpm w/ 3900 psi. PU wt 270k, SO wt 72k, Rot wt 145k. 08:30 10:15 1.75 17,230 16,614 PROD1 DRILL REAM P Backream 15' min. Rotate 120 rpm w/ 17 k ft Ibs of torque. Pumping 455 gpm w/ 2300 psi. PU wt 265k, SO wt 72k, Rot wt 145k. Replace API ring on #1 mud pump- discharge side of pump- therefore onl one um available. €=2~e c2 of ~3 ~ Time Lo s Date From To Dur S. De th E: De th Phase Code Subcode T COM 09/08/2007 10:15 12:00 1.75 16,614 15,859 PROD1 DRILL REAM P Backream 40' min. Rotate 120 rpm w/ 17 k ft Ibs of torque. Pumping 675 gpm w/ 4000 psi. PU wt 260k, SO wt 72k, Rot wt 145k. 12:00 15:00 3.00 15,859 14,053 PROD1 DRILL REAM P Backream 40-45' min. Rotate 120 rpm w/ 14 k ft Ibs of torque. Pumping 700 gpm w/ 3600 psi. PU wt 220k, SO wt 72k, Rot wt 140k. 15:00 18:00 3.00 14,053 12,145 PROD1 DRILL REAM P Backream 40-45' min. Rotate 120 rpm w/ 14 k ft Ibs of torque. Pumping 700 gpm w/ 3280 psi. PU wt 210k, SO wt 72k, Rot wt 135k. 18:00 20:15 2.25 12,145 11,008 PROD1 DRILL REAM P Backream 40-45' min. Rotate 120 rpm w/ 10 k ft Ibs of torque. Pumping 700 gpm w/ 3100 psi. PU wt 220k, SO wt 72k, Rot wt 135k. 20:15 20:30 0.25 11,008 10,913 PROD1 DRILL TRIP P POOH to inside of intermediate casin . 20:30 23:45 3.25 10,913 10,913 PROD1 DRILL CIRC P Pump a 50 bbls Hi vis weighted sweep (10.0 ppg/ 220 vis), Pumping 700 gpm w/ 3100 psi. Rotate 120 rpm w/ 10 k ft Ibs of torque.ECD's prior to sweep 10.29 ppg- after sweep is out of the hole 10.22 ppg. A little increase in cuttings on BU. Continue to pump 4+ more bottom's up f/ a total of 3238 bbls pumped. Final circ rate 700 gpm w/ 3100 psi. Rotate 120 rpm w/ 11 k ft Ibs of for ue.Final ECD's 10.11 23:45 00:00 0.25 10,913 10,913 PROD1 RIGMN SVRG P Service the rig: Grease TD, traveling equipment and crown. Inspect saver sub. OK. 09!09/2007 00:00 00:45 0.75 10,913 10,913 PROD1 RIGMN SVRG P Finish servicing the rig: Grease TD, traveling equipment and crown. Ins ct saver sub. OK. 00:45 01:00 0.25 10,913 11,018 PROD1 DRILL TRIP P Trip in the hole. Lost down wt. 01:00 06:00 5.00 11,018 16,427 PROD1 DRILL REAM P Ream in the hole. Pumping 210 gpm w/ 750 psi. Rotating 50 rpm w/ 17k ft Ibs of torque. Pu wt 250k, SO wt 72k, Rot wt 135k. 06:00 08:30 2.50 16,427 17,940 PROD1 DRILL REAM P Continue to ream in the hole. Pumping 210 gpm w/ 750 psi. Rotating 50 rpm w/ 17k ft Ibs of torque. Pu wt 250k, SO wt 72k, Rot wt 135k. 08:30 10:45 2.25 17,940 17,940 PROD1 DRILL CIRC P Displace from 8.4 ppg mineral oil base mud to 8.4 ppg solids free oil base mud. Pumping 421 gpm w/ 2400 psi. Rotate 50 rpm w/ 17-18 k ft Ibs of torque before & 19-21k after. PU wt 265k before & 300k after, SO wt 72k both before and after, Rot wt 145k before & 150k after. 10:45 11:00 0.25 17,940 17,940 PROD1 DRILL OWFF P Monitor well. Static. rage ~3 e 53 i l ~ Time Lo s Date From To Dur S. De ih E. De th Phase Code Subcode T COM 09/09/2007 11:00 12:00 1.00 17,940 17,074 PROD1 DRILL TRIP P POOH w/ BHA#8, on elevators. Hole swabbing. Record PU and SO wt's every 5 stands in open hole. Hole swabbin . 12:00 18:00 6.00 17,074 12,817 PROD1 DRILL TRIP P POOH w/ BHA#8, pumping 20 spm w/ 160 psi to avoid swabbing. Record Pu and SO wt's every 5 stands in o en hole. 18:00 21:00 3.00 12,817 10,910 PROD1 DRILL TRIP P Continue to pump out of the hole. Pumping 20 spm w/ 160 psi. Record PU and SO wt's eve 5 stands. 21:00 21:15 0.25 10,910 10,910 PROD1 DRILL OWFF P Monitor well, OK. 21:15 23:15 2.00 10,910 9,203 PROD1 DRILL TRIP P Continue to pump out of the hole. Pumping 20 spm w/ 160 psi. Record PU and SO wt's eve 10 stands. 23:15 00:00 0.75 9,203 8,442 PROD1 DRILL TRIP P POOH w/ BHA #8.Record PU and SO wt's every 10 stands. Note: Did not have any Slack Off wt until 7200'. 09/10/2007 00:00 03:30 3.50 8,442 353 PROD1 DRILL TRIP P Continue to POOH on elevators w/ BHA #8. Note: Did not have any Slack Off wt until 7200'. 03:30 03:45 0.25 353 353 PROD1 DRILL SFTY P PJSM on laying down BHA #8. 03:45 04:15 0.50 353 56 PROD1 DRILL PULD P Lay down part of BHA #8. 04:15 05:45 1.50 56 56 PROD1 DRILL OTHR P Download Sperry Sun MWD 05:45 07:45 2.00 56 0 PROD1 DRILL PULD P Lay down BHA #8. Note: on trip out: Overall 4.28 bbls more than calculated for hole fill. Calculated 97.14 bbls, actual 111 bbls. 07:45 08:15 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 08:15 09:45 1.50 0 0 COMPZ RIGMN RGRP T Remove shot pin assembly from the to drive, so that it can be rebuilt. 09:45 10:15 0.50 0 0 COMPZ EVALVI SFTY P PJSM on RU Schlumbergerwireline. 10:15 11:30 1.25 0 0 COMPZ EVALVI~ RURD P RU Schlumbergerwireline 11:30 12:30 1.00 0 2,600 COMPZ EVAL ELOG P RIH w/ Schlumberger USIT and (2) tractors. Tool string length 75.5'. Max OD of tools 6.69" 12:30 20:30 8.00 2,600 8,283 COMPZ EVALVI , ELOG P Schlumberger start tractoring in the hole f/ 2600' to 8283' (5683'). Speed of travel 1800' to 1150'/ 20:30 21:45 1.25 8,283 0 COMPZ EVALVI ~ ELOG P POOH w! Schlumberger WL and USIT tools. Note: Well gained fluid amount greater than the .39" line displacement. Gained 15.3 bbls of fluid in 12 hrs. Avg and steady gain of a rox 1.275 b h. ~d~e ~E_ o~ ~~ • Time to s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/10/2007 21:45 23:00 1.25 0 0 COMPZ EVALVI~ RURD P Lay down 75' of Schlumberger tools, Ri down Schlumber er wireline. 23:00 00:00 1.00 0 0 COMPZ RIGMN RGRP T Replace shot pin assembly on the Varco to drive. 09/11/2007 00:00 00:30 0.50 0 0 COMPZ RIGMN RGRP T Replace shot pin assembly on the Varco top drive. While working on top drive, shut the blind rams and monitored the wellbore pressure. Shut the blinds @ 2230 hrs on 9/10/2007. Monitored the pressure every 15 min with no pressure until midnight -- 2.5 si. 00:30 01:15 0.75 0 0 COMPZ WELCT PULD T MU BHA # 9 (8-1/2" Hole opener) 01:15 01:30 0.25 0 0 COMPZ WELCT OWFF T Open well to poor boy degasser with 11 psi on the well. Well had been shut in f/ 2.75 hrs. No immediate returns. Open the annulus valve in cellar to drain some fluid and check f/ pressure. No pressure. Open blind rams. 01:30 01:45 025 0 318 COMPZ WELCT PULD T Finish MU BHA #9. 01:45 03:30 1.75 318 3,170 COMPZ WELCT TRIP T RIH w/ BHA #9. Fill pipe @ 2000', RIH to 3170'. 03:30 04:00 0.50 3,170 3,170 COMPZ WELCT CIRC T Circulate 2.5 BU (525 bbls) @ 700 gpm w/ 1000 psi. Max gas 186 units. Mud wt 8.1 to 8.4 04:00 05:30 1.50 3,170 5,640 COMPZ WELCT TRIP T RIH filling pipe every 10 stands. 05:30 06:00 0.50 5,640 5,640 COMPZ WELCT CIRC T Circulate and condition mud. Pumped 1.5 BU @ 815 gpm w/ 1950 psi, 38% flow. Rotate 120 rpm w/ 8k ft Ibs of torque. PU wt 130k, SO wt 95k, Rot wt 125k. Crew Chan e 06:00 07:30 1.50 5,640 7,358 COMPZ WELCT TRIP T Continue trip in hole from 5640' - 7358'. Fill drill strin eve 10 stands. 07:30 08:15 0.75 7,358 7,358 COMPZ WELCT CIRC T Circulate while reciprocate drill string with 815 GPM's - 2380 PSI. UP WT = 165K, SO WT = 90K, ROT WT = 130K. 08:15 12:00 3.75 7,358 9,540 COMPZ WELCT WASH T Continue wash & ream from 7358' - 9540'. Pumps @ 400 GPM = 930 PSI. 50 RPM's at 40-50 ft/min. 12:00 14:00 2.00 9,540 10,937 COMPZ WELCT WASH T Continue wash & ream from 9540' - 10937'. Pumps @ 400 GPM = 1050 PSI. 50 RPM's at 40-50 ft/min. 14:00 16:30 2.50 10,937 10,937 COMPZ WELCT CIRC T Circulate while reciprocate drill string with 400 GPM's -1050 PSI. 16:30 17:45 1.25 10,937 10,937 COMPZ WELCT OWFF T Monitor well observing 2-4 BBLS /HR GAIN. Pick up 6 joints of HWDP and rack back in derrick. 17:45 18:00 0.25 10,937 11,256 COMPZ WELCT WASH T Continue wash & ream from 10937' - 11256'. Pumps @ 190 GPM = 320 PSI, 50 RPM's at 40-50 ft/min. Crew chap e l P~:ge 2^ os:~3 ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/11/2007 18:00 20:30 2.50 11,256 13,349 COMPZ WELCT WASH T Continue wash & ream from 11256' - 13349'. Pumps @ 175 GPM = 450 PSI. 50 RPM's at 40-50 ft/min. UP WT = 230K, SO WT = 70K, ROT WT = 135K. 20:30 23:15 2.75 13,349 13,349 COMPZ WELCT CIRC T Circulate while reciprocate drill string staging pumps from 300 - 500 GPM's - 1940 PSI at 500 gpm's. 120 RPM's with 17K ft/Ibs of torque. Observed well unloading with shakers 100% full of sand for first 2000 stks. Pump 30 BBL Hi Visc sweep around observing 50% increase in cutting across shakers. Circulate until cleaned up. Observed a total of 36 BBL loss while circulatin . 23:15 00:00 0.75 13,349 13,349 COMPZ WELCT OWFF T Monitor well for gains. Observed gains of 2.8 BBL / HR for first 30 minutes, slowing to 1.2 BBLS / HR last half hour. Monitor ains throw h tri tank. 09/12/2007 00:00 00:15 0.25 13,349 13,349 COMPZ WELCT OWFF T Continue monitor well for gains. Observed gains of 1.2 BBLS / HR last half hour. Monitor gains through trip tank. 00:15 02:45 2.50 13,349 15,628 COMPZ WELCT WASH T Continue wash & ream from 13349' - 15628'. Pumps @ 250 GPM = 700 PSI. 60 RPM's at 40-50 ft/min. UP WT = 230K, SO WT = 70K, ROT WT = 135K. 02:45 05:30 2.75 15,628 15,628 COMPZ WELCT CIRC T Circulate while reciprocate drill string staging pumps from 300 - 400 GPM's - 1250 PSI at 350 gpm's. 120 RPM's with 20K ft/Ibs of torque. Observed 50% increase in cuttings after 1600 stks. Pump 30 BBL Hi Visc sweep around observing 50% increase in cutting across shakers. Circulate until cleaned up. Observed a total of 5 BBL loss while circulatin . 05:30 06:00 0.50 15,628 15,628 COMPZ WELCT OWFF T Monitor well for gains. Observed gains of 2.4 BBL / HR, slowing to 1.6 BBL / NR last half hour. Crew Chan e 06:00 10:15 4.25 15,628 17,940 COMPZ WELCT WASH T Continue wash & ream from 15628' - 17940'. Pumps @ 210 GPM = 710 PSI. 70 RPM's at 40-50 ft/min. UP WT = 300K, SO WT = 70K, ROT WT = 150K. 10:15 12:00 1.75 17,940 17,940 COMPZ WELCT CIRC T Circulate while reciprocate drill string staging pumps from 300 - 400 GPM's - 1950 PSI at 350 gpm's. 120 RPM's with 24K ft/Ibs of torque. Circulate until cleaned u . 12:00 12:15 0.25 17,940 17,940 COMPZ WELCT OWFF T Monitor well, observin well flowing. F~ge ~5 of ~3 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/12/2007 12:15 15:45 3.50 17,940 17,940 COMPZ WELCT CIRC T circulate while recipro&ate drill strincV staging pumps from 300 - 400 GPM's - 1950 PSI at 350 gpm's. 120 RPM's with 24K ft/Ibs of torque. Pump 30 BBL Hi Visc sweep, Circulate until cleaned up. Observed little increase in cuttings when sweep across shakers. UP WT = 300K, SO WT = 70K, ROT WT = 135K. 15:45 17:00 1.25 17,940 17,940 COMPZ WELCT OWFF T Monitor well.Observed well with gains at 2.4 BBL I HR in first 15 minutes, slowing to .8 BBLS / HR in the next 15 minutes and dropping off to no flow and zero ain for the next hour. 17:00 17:15 0.25 17,940 17,776 COMPZ WELCT TRIP T POOH on elevators from 17846' - 17776'. Monitor well via trip tank observe well swabbing. Obtain T&D arameters as e r ri en ineer. 17:15 18:00 0.75 17,776 17,041 COMPZ WELCT TRIP T Make Top Drive conection and begin pumping out of hole frpm 17776' - 17041'. pumps at 50 SPM - 580 PSI. Observed proper hole fill while pumping out. Attempts to pull on elevators unsuccessful due to swabbing and drag. Obtain T&D parameters as per rig engineer. Crew Chan e 18:00 00:00 6.00 17,041 13,064 COMPZ WELCT TRIP T Continue pumping out of hole frpm 17041' -13064', pumps at 50 SPM - 580 PSI. Observed proper hole fill while,pumping out. Attempts to pull on elevators unsuccessful due to swabbing and drag. Obtain T&D arameters as er ri en ineer. 09/13/2007 00:00 03:45 3.75 13,064 10,974 COMPZ WELCT TRIP T Continue pumping out of hole frpm 13064' -10974, Pumps at 3 BPM - 360 PSI. Observed proper hole fill while pumping out. Attempts to pull on elevators unsuccessful due to swabbing and drag. Obtain T&D parameters as per rig engineer. 9 BBL Loss while pumping out of hole. UP WT = 250K, SO WT = 70K, ROT WT = 145K. 03:45 05:30 1.75 10,974 10,974 COMPZ WELCT CIRC T Pump 30 BBL Hi Visc sweep at the shoe at 300 GPM's - 820 PSI, while reciprocate & rotate drill string @ 120 RPM's - 14K TQ. . 05:30 06:00 0.50 10,974 10,974 COMPZ WELCT OWFF T Monitor well via trip tank. Observed .8 BBL gain in 15 minutes, slowing to .4 BPM - 15 minutes. Crew Chan e 06:00 07:45 1.75 10,974 10,306 COMPZ WELCT TRIP T Continue pump out of hole from 10974' - 10306' M D. 07:45 08:00 0.25 10,306 10,306 COMPZ WELCT OWFF T Monitor well -static. P80e ~:! QS' ~~ • a Time Lo s Date From To Dur S: De th E. De th Phase Code Subcode T COM 09/13/2007 08:00 08:15 0.25 10,306 10,306 COMPZ WELCT SFTY T Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to slip & cut drilling line & procedure to change out saver sub on To Drive. 08:15 09:15 1.00 10,306 10,306 COMPZ RIGMN SVRG T Slip & cut 178' of drilling line. Inspect & adjust brake linkage on draw works. Inspect Crown - matic, auto driller. Continuning to monitor well via trip tank. Observed well flowing at 1.4 BBLS / HR. 09:15 10:30 1.25 10,306 10,306 COMPZ RIGMN SVRG T Rig up and change out saver sub on Top Drive. Continue monitor well via trip tank. Well continue with 1.4 BBL / HR ain. 10:30 11:15 0.75 10,306 10,306 COMPZ RIGMN SVRG T Continue service Top Drive & rig. Grease TD, blocks, & crown. Continue monitor well observing a total gain of 5.8 BBLS in 3 HRS while service ri . 11:15 12:45 1.50 10,306 10,306 COMPZ WELCT OWFF T Continue monitor well through trip tank. Observed a total gain at this time of 7 BBLS in 4 3/4 HRS. Overall average of 1.47 bph for the 7.0 bbls in 4 3/4 HRS. 12:45 13:45 1.00 10,306 10,306 COMPZ WELCT OWFF T Shut in well closing top pipe rams. Continue monitor pressure increase of 14 PSI on the choke in 45 minutes. Bleed pressure to poor boy degasser, open pipe rams as per Co. Man, Close HCR valve. Decision to trip back in hole, Note Notified AOGCC Lou Gramaldi of shuttin well and intentio of testin i e rams when out of hole. 13:45 14:00 0.25 10,306 10,937 COMPZ WELCT TRIP T Wash & rotate drill string into hole from 10306' - 10937' MD. (Shoe de th . Pum at 3 BPM - 500 PSI. 14:00 16:30 2.50 10,937 10,937 COMPZ WELCT CIRC T Circulate while reciprocating 8~ rotating drill string, with pumps at 350 GPM's - 920 PSI. Observed when attempting to pump more than 350 GPM's, fluid losses becoming excessive. Weigh mud with both pressurized cup, and non pressurized cup, verifying gas cut mud of .3 PPG ut t .Obtain bottoms up - 7500 strokes. observing gas cut mud. Mud weights of 8.7+ PPG with visc over 140 on mud flow into pits. Also observed Crude oil on bottom's u . Pz;ge 2i3 0€ ~3 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/13/2007 16:30 18:00 1.50 10,937 11,541 COMPZ WELCT TRIP T Continue wash & rotate in hole from 10937' - 11541' MD. Pumps at 126 GPM's - 410 PSI, 50 rpm's with no indication of dirty hole while tripping. Continue monitoring well, observing pushing mud away to the formation while tripping. Crew Change NOTE: Total fluid loss to this point = 88 BBLS of SFMOBM. 18:00 18:30 0.50 11,541 12,493 COMPZ WELCT TRIP T Continue wash & rotate in hole from 11541' - 12493' MD. Pumps at 126 GPM's - 410 PSI, 50 rpm's with no indication of dirty hole while tripping. Continue monitoring well, observing pushing mud away to the formation while tripping until fluid losses excessive. (Pushing away 3 to 4 bbls er 5 stands 18:30 19:30 1.00 12,493 12,493 COMPZ WELCT CIRC T Circulate while reciprocating & rotating drill string with pumps @ 200 Gpms'- 540 PSI. When attempting to increase pump rate observed fluid losses, of 9 BBL loss in 30 minutes. Volume of SFMOBM in pits and on hand became critical, discussing options with rig engineer. Decision to pump out of hole to shoe, then circulate bottoms up, pull to 10300' MD, and displace well with 8.8 PPG MOBM. 19:30 20:30 1.00 12,493 12,681 COMPZ WELCT CIRC T Wash & rotate in hole from 12493' - 12681' verifying assembly would run past area in hole where we circulated, with no issues. Observed good hole conditions. 20:30 23:00 2.50 12,681 10,974 COMPZ WELCT TRIP T Pump out of hole from 12681' - 10974' MD.(Shoe Depth). Pumps at 3 BPM - 840 PSI. Observed fluid losses of 9.4 BBLS. Observed no hole issues while pumping out. UP WT = 230K, SO WT = 70K, ROT WT = 145K. 23:00 00:00 1.00 10,974 10,974 COMPZ WELCT CIRC T Circulate while reciprocating & rotating drill string staging pump rates from 200 Gpms'- 350 Gpm's - 910 PSI. Circulate for bottoms up. Observed .3 ppg mud cut only for a short period of time, and viscosity of 110. Continue circulate to bring viscosity down to 80. Mud wei ht in/out = 8.6 09/14/2007 00:00 01:00 1.00 10,974 10,974 COMPZ WELCT CIRC T Continue circulate while reciprocating & rotating drill string with pump rates 350 Gpm's - 910 PSI. Circulate for bottoms up. Observed .3 ppg mud cut only for a short period of time, and viscosity of 110. Continue circulate to bring viscosity down to 80. Mud weight in/out = 8.6 Pcce ~9 of 53 s 1 J Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/14/2007 01:00 02:00 1.00 10,974 10,300 COMPZ WELCT TRIP T Pump out of hole from 10974' - 10300' MD. Pum sat 3 BPM - 285 PSI. 02:00 06:00 4.00 10,300 10,300 COMPZ WELCT CIRC T Break circulation, held PJSM with crew & vac truck drivers. Designate Spill Champion. Discuss procedure to displace well with MOBM. Continue circulate & displace well with 8.6 PPG MOBM at 3 BPM - 510 PSI. Reciprocate & rotate drill string. Continue circulating to increase mud weight to 8.8 PPG trickling in spike fluid. Crew Chan e 06:00 09:00 3.00 10,300 10,300 COMPZ WELCT CIRC T Continue circulating to increase mud weight to 8.8 PPG trickling in spike fluid while reciprocate & rotate drill string. Mud pumps @ 250 GPM's - 510PSI. 09:00 10:00 1.00 10,300 10,300 COMPZ WELCT OWFF T Monitor well for 1 hour. Static. 10:00 12:00 2.00 10,300 8,408 COMPZ WELCT TRIP T POOH on elevators from 10300' - 8408' MD. Monitor displacement via trip tank. Pro er hole fill. 12:00 12:15 0.25 8,408 8,408 COMPZ WELCT OWFF T Monitor well -static. Decision to monitor well eve 2000' on TOH. 12:15 15:45 3.50 8,408 8,408 COMPZ WELCT CIRC T Attempt to pump 25 BBL dry job using spike fluid. Chase with 10 BBL OBM. Observed pill locked up, with excessive viscosity. Continue circulate pill out of hole with pumps at 250 GPM's - 460 PSI, while reciprocate & rotate drill strin . 15:45 16:00 0.25 8,408 8,408 COMPZ WELCT OWFF T Monitor well -static. 16:00 16:45 0.75 8,408 8,218 COMPZ WELCT TRIP T POOH on elevators from 8408' - 8218' MD. Observed hole swabbing.Obtain T&D arameters as er ri en ineer. 16:45 18:00 1.25 8,218 7,450 COMPZ WELCT TRIP T Pump out of hole from 8218' - 7450' MD. Pumps at 120 GPM's - 170 PSI. Crew Chan e 18:00 18:45 0.75 7,450 6,500 COMPZ WELCT TRIP T POOH on elevators from 7450' - 6500' MD. Monitor proper hole fill through trip tank. Obtain T&D parameters as er ri en ineer. 18:45 19:00 0.25 6,500 6,500 COMPZ WELCT OWFF T Monitor well -static. 19:00 19:15 0.25 6,500 6,500 COMPZ WELCT CIRC T Pump dry job utilizing spike fluid. 19:15 20:30 1.25 6,500 4,500 COMPZ WELCT TRIP T POOH on elevators from 6500' - 4500' MD. Obtain T&D parameters as per rig engineer. UP WT = 170K, SO WT = 90K, ROT WT = 125K. Observed ro er hole fill. 20:30 20:45 0.25 4,500 4,500 COMPZ WELC T OWFF T Monitor well -static. P~c1e ,',4 of ~3 l J Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/14/2007 20:45 21:45 1.00 4,500 2,040 COMPZ WELCT TRIP T POOH on elevators from 4500' - 2040' MD. Obtain T&D parameters as per rig engineer. UP WT = 120K, SO WT = 108K.Observed ro er hole fill. 21:45 22:00 0.25 2,040 2,040 COMPZ WELCT OWFF T Monitor well -static. 22:00 22:30 0.50 2,040 318 COMPZ WELCT TRIP T POOH on elevators from 2040' - 318'. Observed ro er hole fill. 22:30 23:15 0.75 318 0 COMPZ WELCT PULD T Break out & lay down BHA #9. Gauge Hole opener to 1 /2" under as it was run. Stand back HWDP and lay down drillin 'ars. 23:15 23:45 0.50 0 0 COMPZ WELCT OWFF T Monitor well -static. Clean & clear rig floor of tools and OBM. 23:45 00:00 0.25 0 0 COMPZ WELCT ROPE T Make up test joint & test plug. Pull wear bushing. RIH, set test plug. Operation to test upper pipe rams and blinds as per AOGCC regulation after well control issue. 09/15/2007 00:00 03:00 3.00 0 0 COMPZ WELCT BOPE T t BOP~'s,.,Test Upper Pipe rams abnd Blind rams as per AOGCC regs after well control issue. Change out failed test plug rubber. Recored tests on chart. Rig down test equipment & install wear bushing. RILDS. 03:00 03:30 0.50 0 0 COMPZ CASIN( RURD P Pull tools to rig floor. Rig up GBR casin a ui ment and tools. 03:30 03:45 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with crew, BOTand GBR reps. Discuss safety & hazard recognition issues. Discuss procedure to run 5 1/2" Slotted /Blank liner. 03:45 06:00 2.25 0 1,700 COMPZ CASIN( RUNL P Make up 5 1/2" Silver Bullet shoe joint, and continue run 5 1/2" Slotted /Blank liner as per detail to 1700'. Make up Torque = 5K ft/Ibs on BTC casing. Observed proper displacement. Obtain T&D parameters as per rig engineer eve 10 'oints. Crew Chan e 06:00 11:00 5.00 1,700 7,366 COMPZ CASIN( RUNL P Continue run 5 1/2" slotted liner form . 1700' - 7366' MD. Make up Torque = 5K ft/Ibs on Hydril 521 casing and 5500 ft/Ibs on Hydril 521 with torque rings. Observed proper displacement. Obtain T&D parameters as per rig en ineer eve 10 'oints. 11:00 12:15 1.25 7,366 7,423 COMPZ CASIN( RUNL P Make up Casing seal bore extension with pup & XO. Make up MLZXP packer & liner hanger assembly. Monitor well indicating a 4.8 BBL loss since start of casin run. 12:15 12:45 0.50 7,423 7,423 COMPZ CASIN( RURD P Rig down GBR casing running equipment. Clear floor of all tools and e ui ment. w Time Logs Date From To Dur S. De ih E. De th Phase Code Subcode T COM .. . 09/15/2007 12:45 16:00 3.25 7,423 12,445 COMPZ CASIN( RUNL P Continue run liner on drill pipe from 7423' - 12445', on elevators. Observed proper displacement. Obtain T&D parameters as per rig engineer every 10 stands. Fill drill string every 20 stands. UP WT = 185K, SO WT = 75K, ROT WT = 130K. 16:00 18:00 2.00 12,445 14,564 COMPZ CASIN( RUNL P Continue rotate 5 1/2" liner in hole from 12445' - 14564' MD. Obtain T&D parameters as per rig engineer every 10 stands. Fill drill string every 20 stands. UP WT = 205K, SO Wf = 75K, ROT WT = 120K with 14.5K FT/LBS of for ue. Crew Chan e 18:00 23:00 5.00 14,564 17,946 COMPZ CASIN( RUNL P Continue rotate 5 1/2" liner in hole from 14564' to tag bottom @ 17946' MD. Obtain T&D parameters as per rig engineer every 10 stands. Fill drill string every 20 stands. UP WT = 290K, SO WT = 75K, ROT WT = 170K with 24.5K FT/LBS of torque. Crew Chan e 23:00 23:15 0.25 17,946 17,880 COMPZ CASIN( RUNL P Pull back up hole, rack back 1 stand. Drop 1 3/4" ball. Slack off and set liner with top at 10457', and shoe at 17880' as planned. Rotate to allow string to relax. sto rotation. 23:15 00:00 0.75 17,880 17,880 COMPZ CASIN( CIRC P Pump ball down at 3 BPM as per BOT rep. 8.8 PPG mud in /out while pump ball down.Visc = 68. 09/16/2007 00:00 00:30 0.50 17,880 10,457 COMPZ CASIN( CIRC P Continue pump ball down at 3 BPM as per BOT rep. 8.8 PPG mud in /out while pump ball down.Visc = 68. Observed ball seating with 1630 strokes pumped. Continue increase pressure to 3450 PSI, for pusher tool, and up to 4200 PSI to set packer assembly. Bleed pressure. Pull up to neutral osition. 00:30 01:15 0.75 10,457 10,457 COMPZ CASIN( DHEQ P Rig down lines chart recorder, and close annular. Test down annulus to test acker at 2500 PSI for 5 minutes s per procedure. Good test. Bleed pressure & rig down test equipment. Pull out of packer, allowing "dogs" to kick out. Attempt to tag top of liner, observing dogs kicking in, not allowing set down. Liner top set on depth as tanned. Fade 32 of 59 i~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/16/2007 01:15 03:15 2.00 10,457 10,457 COMPZ CASIN( CIRC P Circulate & condition mud, monitoring weights with both weight cups. Observed on bottoms up, mud weights 8.8 PPG with pressurized cup, 8.5 PPG with non pressurized scale, and viscosity up to 113, indicating gas cut. Continue checking and circulating until mud weights in /out at 8.8+ and viscosities at 90. 03:15 03:30 0.25 10,457 10,457 COMPZ CASIN( OTHR P Monitor well -static. Observed no flow increase, only slight movement of mud in stack. Mud weight 8.8+, Viscosity 90. 03:30 04:15 0.75 10,457 10,457 COMPZ CASIN( RUNL P Continue criculate & condition mud obserrving mud weights stable in lout at 8.8+ PPG, and viscosi 85-90. 04:15 04:30 0.25 10,457 10,457 COMPZ CASIN( OTHR P Monitor well -static. 04:30 06:00 1.50 10,457 9,400 COMPZ CAS1N( RUNL P Attempt to pull out of hole on elevators, observing hole swabbing. Pump out of hole from 10457' - 9400' MD. Pumps @ 126 GPM - 225 PSI. Observed proper displacement. obtain T&D parameters as per rig engineer. Crew Chan e 06:00 06:30 0.50 9,400 8,989 COMPZ CASIN( RUNL P Continue. Pump out of hole from 9400' - 8989' MD. Pumps @ 126 GPM - 225 PSI. Observed proper displacement. obtain T&D parameters as per rig en ineer. 06:30 10:15 3.75 8,989 8,989 COMPZ CASIN( CIRC P Continue circulate & condition mud adding LVT to bring mud weight down to 8.8 PPG, and vicosity to 70. Pumps at 500 GPM's 1350 PSI. 10:15 10:30 0.25 8,989 8,989 COMPZ CASIN( OTHR P Monitor well -static. 10:30 11:15 0.75 8,989 8,038 COMPZ CASIN( RUNL P POOH on elevators from 8989' - 8038' MD. String speed slow, as per swabbin issues. 11:15 11:30 0.25 8,038 8,038 COMPZ CASIN( OTHR P Monitor well -static. 11:30 11:45 0.25 8,038 8,038 COMPZ CASIN( CIRC P Pump 25 BBLS 11.8 PPG slug, and chase with 10 BBLS 8.8 OBM. 11:45 16:30 4.75 8,038 47 COMPZ CASIN( RUNL P Continue POOH on elevators from 8038' - 47'. Observed proper displacement. obtain T&D parameters as r ri en ineer. 16:30 17:15 0.75 47 0 COMPZ CASIN( RURD P Held PJSM. Breakout & lay down BOT liner running & setting tools. Inspect same. 17:15 17:30 0.25 0 0 COMPZ CASIN( OTHR P Clean & clear floor of tools and OBM. La down tools to beaver slide. 17:30 17:45 0.25 0 0 COMPZ EVAL1/~ SFTY P Held PJSM with crew, and SWS reps. Discuss safety & hazard recognition issues. Discuss procedure to rig up and run USIT to in tools. ~ ~a~e 33 ai 53 • • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/16/2007 17:45 18:00 0.25 0 0 COMPZ EVALVI, RURD P Rig up SWS wireline tools. Hang sheaves. Pull logging tools to rig floor. Crew Chan e 18:00 19:15 1.25 0 0 COMPZ EVALIA RURD P Continue pull tools to rig floor, and make up USIT logging tools as per SWS reps. Wireline in hole to 200'. Attempt to function test observing tool failure. WLOH. Monitor wellbore via trip tank -static. No loss while rigging u. 19:15 20:30 1.25 0 0 COMPZ EVALVI~ ELOG P Disassemble logging tools and trouble shoot roblem. Assemble tools. 20:30 00:00 3.50 0 0 COMPZ EVAL ELOG P Wireline in hole with tractor assembly from surFace to 6000' MD. Monitor well for losses observing 2.52 BBLS loss since be innin of run. 09/17/2007 00:00 06:00 6.00 0 0 COMPZ EVALVI~ ELOG P Wireline in hole with tractor assembly from surface to 8150' WLM. Monitor well for losses observing 0 BBLS loss since Midni ht. Crew Chan e 06:00 12:00 6.00 0 0 COMPZ EVALV~ ELOG P Contiune wireline in hole with tractor assembly from surface to 8150' - 10105' WLM. Monitor well for losses observing 0 BBLS loss since 0600 HRS. 12:00 17:30 5.50 0 0 COMPZ EVALVI~ ELOG P WLOH loc in with USIT assembly from 10105' -5930' WLM. POOH to surface. 17:30 18:00 0.50 0 0 COMPZ EVALV~ RURD P Breakout & lay down wireline tools. Rig down SWS wireliners. Observed 0 BBLS loss since 1200 HRS. 18:00 18:45 0.75 0 0 COMPZ EVAL1l~ RURD P Continue breakout & lay down wireline tools. Rig down SWS wireliners. Observed 0 BBLS loss since 1200 HRS. 18:45 19:30 0.75 0 0 COMPZ WELCT BOPE P Pull wear bushing. Rig up to test BOP's. Set test plug, fill BOP's, choke manifold and Top drive with water. Annulus valve o en to monitor well. 19:30 23:15 3.75 0 0 COMPZ WELCT BOPE P Test BOP's. Test All rams, and annular. Test HCR's and manual valves. Test Choke manifold and valves, all Floor valves and rams tested with 5", and 4 1/2" test joints. All test recored on chart and tested to 250 / 3000 PSI. Pwerform Accumulator draw down test. First 200 PSI in 50 secs, and full 3000 PSI in 3 min, 6 secs. Witness of BOP test waived b AOGCC re Bob Noble. 23:15 00:00 0.75 0 COMPZ WELCT BOPE P Rig down all test equipment. Blow down all lines and choke manifold. Pull test plug and install wear bushing. RILDS. 09/18/2007 00:00 00:30 0.50 0 0 PROD2 STK OTHR P Clean & clear rig floor. r2C@ ~~~ OFrJ.~i. _I ~ \i~ :~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/18/2007 00:30 01:15 0.75 0 0 PROD2 STK PULD P Pull all whipstock assembly tools & equipment to rig floor as per BOT rep. Held PJSM with crew, BOT, and SPerry reps. Discuss safety & hazard recognition issues. Discuss procedure for making up whipstock and space out assembl . 01:15 04:45 3.50 0 522 PROD2 STK PULD P Make up whipstock and space out assembly as per BOT & Sperry Sun re s. Total len th of BHA = 522.00" 04:45 05:30 0.75 522 522 PROD2 STK PULD P Plug in and Up load MWD. 05:30 06:00 0.50 522 522 PROD2 STK PULD P Continue make up 3 Non-Mag flex drill collars. Crew Chan e 06:00 06:15 0.25 522 522 PROD2 STK PULD P Continue make up BHA installing Bum er'ar and 5" HWDP. 06:15 06:30 0.25 522 522 PROD2 STK CIRC P Pulse test MWD assembly with pumps at 400 GPM's and 580 PSI. Good test. 06:30 12:00 5.50 522 8,800 PROD2 STK TRIP P Trip in hole with whipstock assembly at 2 minutes /stand as per BOT rep from 522' - 8800' MD> Fill drill string every 25 stands. Observed proper dis lacement. 12:00 12:30 0.50 8,800 9,391 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 8800' - 9391' MD. Fill drill strip . 12:30 13:00 0.50 9,391 9,461 PROD2 STK OTHR P Perform MAD PASS form 9391' - 9461' as per Geologists. Pumps @ 593 GPM's - 2900 PSI. UP WT = 190K, SO WT = 82K. 13:00 14:00 1.00 9,461 10,456 PROD2 STK TRIP P Continue trip in hole with whipstock assembly from 9461' - 10456" MD. Fill drill string every 25 stands. Observed ro er dis lacement. . 14:00 14:30 0.50 10,456 10,458 PROD2 STK WPST P Orient whipstock face to 12 Deg Left of high side. Pumps @ 430 GPM's - 1990 PSI. UP WT = 225K, SO WT = 100K. Slack off & tag top of B lat liner t 10458' DPM' and set seal into liner to .Continue slack off to set bottom tri anchor with 18K. Pull 10K over upweight to verify set. Set down 35K to shear bolt as planned. Top of whi 14:30 16:30 2.00 10,237 10,237 PROD2 STK CIRC P Diplace well with 8.3 PPG MOBM at 510 GPM's - 2300 GPM's. Circulate to ` get balanced mud weights at 8.4 `' PPG. 16:30 17:00 0.50 10,237 10,237 PROD2 STK CIRC P Monitor well -static. .-~-° 17:00 18:00 1.00 10,237 10, , ROD2 STK WPST P Obt~tn rotation of drill string, and mill window from 10238' - 10240' with 516 GPM's - 2300 PSI. Obtained slow Pump rates before milling ~ window.Mllling at 80 RPM's with 14K ~ TQ on btm. WOM = 2K. Crew Chan e Page 35 of 53 J Time Lo s .. Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/18/2007 18:00 22:30 4.50 10,240 10,290 PROD2 STK WPST P Continue mill window from 10240' - 10254' with 516 GPM's - 2300 PSI, at 80 RPM's with 6K TQ on btm. WOM = 6K. Milled window in 3.45 HRS, continuing milling open hole from 10254' -10290' in 1.58 HRS. Total open hole made = 36'. Pump sweep at bottom of window, and also at the bottom of o n hole. 22:30 23:45 1.25 10,290 10,290 PROD2 STK CIRC P Work mills through window area to clean same while pumping 40 BBL Hi Visc sweep at 600 GPM's - 2870 PSI. UP WT = 220K, SO WT = 140K, ROT WT = 160K, at 80 RPM's with 11 K TQ. Work mills through window without pumps or rotation to verify clean as er BOT re . 23:45 00:00 0.25 10,290 10,290 PROD2 STK CIRC P Mpnior well -static. 09/19/2007 00:00 00:30 0.50 10,290 9,850 PROD2 STK TRIP P Pull 5 stands on elevators observing well, no swabbing, with correct hole fill. 00:30 00:45 0.25 9,850 9,850 PROD2 STK CIRC P Pump dry job. 00:45 04:45 4.00 9,850 522 PROD2 STK TRIP P POOH on elevators from 9850' - 522. Observe well before ull BHA. 04:45 05:45 1.00 522 0 PROD2 STK PULD P POOH, racking back HWDP & DC"S.Breakout, Inspect & lay down mills. Mill gauged to full gauge of 8 1/2" as er BOT re . 05:45 06:30 0.75 98 98 PROD2 STK OTHR P Plug in and download MWD assembl . 06:30 06:45 0.25 0 0 PROD2 STK OTHR P Clean & clear rig floor of equipment & OBM. Rig up to Flush stack. Crew Chan e 06:45 07:30 0.75 98 0 PROD2 STK PULD P Breakout, Inspect & lay down mills. Mill gauged to full gauge of 8 1I2" as per BOT rep. Total fluid loss on TOH = 13 BBLS.Crew Chan e 07:30 09:15 1.75 0 75 PROD2 DRILL PULD P Held PJSM with crew, DD &MWD reps. Discuss safety & hazard recogniiton issues. Discuss procedure to make up BHA #11. Makeup Geo-Pilot assembly with 8 1/2" Security FMF3643Z bit. Make up MWD assembl with float sub. 09:15 09:45 0.50 75 75 PROD2 DRILL PULD P Plug in and Upload MWD assembly. 09:45 10:15 0.50 75 352 PROD2 DRILL PULD P Make up remaining BHA including Non Mag flex drill collars, drilling jars and HWDP. Total BHA len th 10:15 10:30 0.25 352 352 PROD2 DRILL CIRC P Run 1 stand, and perform pulse test with pumps @ 600 GPM's -1300 PSI. Rotate drill string to break in bearings on Geo- ilot. ~ ~~ Pu e ~u ofi 5~ ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/19/2007 10:30 15:30 5.00 352 10,150 PROD2 DRILL TRIP P Trip in hole with BHA #11 from 352' - 10150'. Observed proper displacement. Fill drill string every 25 stands. Obtain T&D parameters as per rig engineer. UP WT = 185K, SO WT = 105K. 15:30 16:00 0.50 10,150 10,150 PROD2 RIGMN SVRG P Service draworks & top drive. 16:00 16:30 0.50 10,150 10,290 PROD2 DRILL CIRC P Establish drilling parameters at top of window. Work drill string through window area with no issues. Tag bottom at 10290' DPM. 16:30 17:45 1.25 10,290 10,442 PROD2 DRILL DDRL P Directional drill 8 1!2" D lateral from 10290' - 10442' MD. TVD = 3185'. 17:45 18:15 0.50 10,442 10,442 PROD2 DRILL CIRC T Observed "noise" in MWD assembly with failed pulses. Trouble shoot all surface equipment, isolating pumps, and pressure testing. While trouble shooting, observed 1000 PSI loss in ressure in drill strin . 18:15 18:45 0.50 10,442 10,238 PROD2 DRILL TRIP T Pulled 2 stands to get back into cased hole above window. Continue trouble shoot, with indication that surface equipment fuctioning correctly. Crew Chan e 18:45 19:00 0.25 10,238 10,238 PROD2 DRILL TRIP T Continue trouble shoot, with indication that surface equipment fuctionin correct) . 19:00 19:15 0.25 10,238 10,264 PROD2 DRILL TRIP T Trip back in hole with drill string to attempt to tag bottom. Observed tagging high, at 10264', with no increase in drill string pressure. When tagging up, observed increase in for ue u 22-24K ft/Ibs. 19:15 23:15 4.00 10,264 0 PROD2 DRILL TRIP T Pump dryjob, POOH on elevators from 10264' -surface. Observed proper hole fill, with 3 BBLS loss. 23:15 00:00 0.75 0 PROD2 DRILL PULD T Observed that the Dailey Combo drilling jars had parted 17' down from he to of the connection, leaving 13' of jars in hole and remaining BHA. Total BHA left in hole = 181.45. Obtain pictures, Breakout and laydown jars. Discuss issues with rig engineer. Call for BOT fisherman. 09/20/2007 00:00 02:15 2.25 0 338 PROD2 FISH WOSP T Make up 1 joint of 5" HWDP, Bumper sub and Oil jars with Float sub. Wait on BOT for 1/2 HR. Pull remaing tools to rig floor. Strap tools & Dress 8 1/8" over shot with 6 1/4" grapple & packoff. Make up Overshot. Adjust DP tall . 02:15 06:00 3.75 338 9,948 PROD2 FISH TRIP T Trip in hole with BHA #12, from 338' - 9948'. Observed proper displacement. Crew Chan e 06:00 06:15 0.25 9,948 10,238 PROD2 FISH TRIP T Continue trip in hole from 9948' - 10238' MD. r=aae 3% o~` 5~ ~~ - Time Lo s Date From To Dur S. De th E. De th Phase .Code Subcode T COM 09/20/2007 06:15 07:15 1.00 10,238 10,238 PROD2 FISH FISH T Obtain Fishing parameters with UP WT = 180K, SO WT = 105K. Pumps at 2.5 BPM - 440 PSI. Attempt to work 8 1/8" Overshot assembly over top of whipstock. Observed setting down on whipstock top. Rotate to aloes free travel with no success. Set down weights from 10-30K. No success in getting O.S. past whipstock top. Suspect "lipped "over constricting the ID. 07:15 07:45 0.50 10,238 10,238 PROD2 FISH CIRC T Monitor well for 15 minutes. Static. Pum d ~ob. 07:45 11:45 4.00 10,238 338 PROD2 FISH TRIP T POOH on elevators from 10238' - 338'. Observed ro er dis lacement. 11:45 12:15 0.50 338 0 PROD2 FISH PULD T Rack back HWDP. breakout & lay down Overshot assembl . 12:15 12:30 0.25 0 0 PROD2 FISH PULD T Clean & clear rig floor of tools, and OBM. 12:30 13:00 0.50 0 348 PROD2 FISH PULD T Make up BHA # 13, Tapered mill assembly with upper watermelon mill. Make up string magnet. Total BHA - 348.66'. 13:00 17:15 4.25 348 10,145 PROD2 FISH TRIP T Trip in hole with fishing assembly - BHA 13 from 348' -10145' MD. Fill Drill string every 25 stands. Observed ro er dis lacement. 17:15 18:00 0.75 10,145 10,240 PROD2 FISH MILL T Obtain milling parameters. Slack off and tag top of whipstock at 10238' MD. UP WT = 180K, SO WT = 105K, ROT WT = 145K. Pumps at 4 BPM - 600 PSI. Dress top of whipstock from 10237' -10240' DPM.with 45 RPM's observing free torque at 9K, and milling torques to 14K. Observed mills cleaned up top of whipstock,allowing free travel of 8 1/2" mills through top of whi stock. Crew Chan e 18:00 18:30 0.50 10,240 10,240 PROD2 FISH MILL T Continue dress top of whipstock from 10237' - 10240' DPM.with 45 RPM's observing free torque at 9K, and milling torques to 14K. Observed mills cleaned up top of whipstock,allowing free travel of 8 1/2" mills through top of whi stock. Free travel - no rotation. 18:30 19:30 1.00 10,240 10,240 PROD2 FISH CIRC T Pump Hi visc sweep and circulate 600 GPM's - 1890 PSI. Observed increase in iron cuttings when sweep at surface. 19:30 20:00 0.50 10,240 10,240 PROD2 FISH OTHR T Monitor well -static. Obtain slow um rates. Pum d 'ob. 20:00 00:00 4.00 10,240 348 PROD2 FISH TRIP T POOH on elevators observing proper dis lacement from 10240' - 348'. Page 3~ of 53 ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/21/2007 00:00 00:45 0.75 348 0 PROD2 FISH PULD T Rack back HWDP, breakout & lay down milling assembly. Inspect mills - good. No junk cuts. Observed string ma net with a roximatel 10 LBS of { iron cuttin s. 00:45 02:15 1.50 0 340 PROD2 FISH PULD T Make up 8 1/8" overshot assembly with 1 joint of DP above Jars. Rig up and attempt to bend 5" DP joint to aid overshot going over top of whipstock as recommended. Observd joint bent 10' above pin end approximately 1". Total BHA = 340.14' 02:15 06:00 3.75 340 9,664 PROD2 FISH TRIP T Trip in hole with 8 1/8" Overshot ftom 340' - 9664. Observed proper displacement. Fill drill string every 25 stands. Crew Chan e 06:00 06:30 0.50 9,664 10,235 PROD2 FISH TRIP T Continue trip in hole from 9664' - 10235' DPM. 06:30 07:30 1.00 10,235 10,264 PROD2 FISH FISH T Break circulation. Establish fishing parameters. UP WT = 183K, SO WT = 107K. ROT WT =138K. Pumps at 3 BPM - 300 PSI. Wash down through windo no tag, continuing down to tag top of fish @ 10260' MD, washing over fish to 10264'. Rotating at 30 RPM's with 8K TQ. Observed pump increase to 520 PSI, with increased torque to 12K. Stop rotation. Pull up to 245K verifying catch, and bring pumps to 420 GPM's - 1700 PSI to observed MWD ulses. Slow um s to 4 BPM. 07:30 08:00 0.50 10,264 10,140 PROD2 FISH FISH T Pull assembly to bring bit above top of whipstock at 10140'. Pumps at 3 BPM - 600 PSI to wash and clean hole as we pulled into casing. Observed max pull of 280K, indicating drag. Monitor well -static. Pum d ~ob. 08:00 12:00 4.00 10,140 900 PROD2 FISH TRIP T POOH with fish from 10140' - 900'. Observed ro er hole fill. 12:00 12:30 0.50 900 340 PROD2 FISH TRIP T Continue POOH from 900' - 340'. 12:30 12:45 0.25 340 181 PROD2 FISH PULD T Rack back HWDP, and lay down bent ~oint of 5" DP. 12:45 13:00 0.25 181 181 PROD2 FISH PULD T Breakout & lay down fishing assembly with fish in it to the bottom of the drillin 'ars. 13:00 14:30 1.50 181 0 PROD2 FISH PULD T Continue POOH, breakout & lay down ish. Fish = 181' _Breakout & lay down Flex drill collars, MWD assembly and Geo-Pilot. Inspect & gauge bit to full gauge and ready for rerun. Plugged in and downloaded MWD. Page 39 az 53 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/21/2007 14:30 16:00 1.50 0 0 PROD2 FISH PULD T Pick up fishing assembly that was l ayed down, Breakout Overshot, and fish. Lay down same. Observed recovery of most of the inner spring of failed jar, and no inner bushing. Junk left in hole. 16:00 17:30 1.50 0 345 PROD2 FISH PULD T Make up 7 7/8" Reverse circulating basket with string magnet and float sub. Total BHA len th = 345.80'. 17:30 18:00 0.50 345 2,050 PROD2 FISH TRIP T Trip in hole with BHA # 15 from 345' - 2050' DPM. Observed proper displacement, filling drill string every 25 stands. Crew Chan e 18:00 21:30 3.50 2,050 9,860 PROD2 FISH TRIP T Continue trip in hole with BHA #15 from 2050' - 9860' DPM.Observed proper displacement, filling drill string eve 25 stands. 21:30 22:45 1.25 9,860 9,860 PROD2 RIGMN SVRG T Held PJSM with crew, Discuss safety & hazard recognition issues. discuss procedure to cut & slip drilling line. Cut & slip drilling line with no issues. Monitor well -static. 22:45 23:00 0.25 9,860 10,235 PROD2 FISH TRIP T Continue trip in hole from 9860' - 10235'. 23:00 00:00 1.00 10,235 10,444 PROD2 FISH FISH T Establish fishing parameters. Break circulation. UP WT = 175K, SO WT = 104K. ROT WT = 135K. Pumps at 6 BPM - 6500 PSI. Wash down through _ 'ndow no to Observed pump pressure increase to 2470 PSI, indicating ball seated in reverse basket. String rotation at 30 RPM's continuing to wash from top of whipstock to bottom of hole at 10442' with rate increase to 8 BPM - at 10260'. Allow approximately 6" -1' of cut on bottom to 10444' DPM. Observed no obstructions or issues ettin basket to bottom. 09/22/2007 00:00 00:15 025 10,444 10,235 PROD2 FISH TRIP T Pumps off. POOH from 10444' -to above whi stock at 10235' . 00:15 00:45 0.50 10,235 10,235 PROD2 FISH TRIP T Monitor well -static. Pump dry job 00:45 04:30 3.75 10,235 345 PROD2 FISH TRIP T POOH from 10235' - 345'. Observed proper displacement. Total of 5 BBLS loss on TOH. 04:30 05:15 0.75 345 0 PROD2 FISH PULD T Breakout & lay down fishing BHA. Breakout reverses basket observing recovered 3 rocks, and a brass iece approximately 3" x 4". Picture taken and sent to town. 05:15 05:45 0.50 0 0 PROD2 FISH OTHR T Clean & clear rig floor of tools and OBM. 05:45 06:00 0.25 0 0 PROD2 DRILL SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss prcedure to make up 8 1/2" Drilling BHA. ~a,e ~0 of 53 { Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09!22/2007 06:00 07:00 1.00 0 77 PROD2 DRILL PULD P Make up BHA #16.8 1/2" Drilling BHA. MU 8 1/2" Security FMF3643Z bit with 7600 series Geo-pilot. Make u MWD assembl and Float sub. 07:00 07:45 0.75 77 77 PROD2 DRILL PULD P Plug in and Upload MWD assembly. 07:45 08:30 0.75 77 352 PROD2 DRILL PULD P Conttnue make up BHA #16 picking up Non mag flex drill collars, HWDP and Dailey combo drilling jars. Total BHA len th = 352.49' 08:30 08:45 0.25 352 352 PROD2 DRILL CIRC P Perform shallow pulse test. Pumps at 510 GPM's - 900 PSI. Rotate drill string to break in geo-pilot bearings as er DD. 08:45 13:15 4.50 352 10,156 PROD2 DRILL TRIP P Trip in hole from 352' - 10156'. Fill drill string every 25 stands. observed ro er dis lacement. 13:15 13:45 0.50 10,156 10,156 PROD2 RIGMN SVRG P Service & inspect Top drive. 13:45 14:45 1.00 10,156 10,442 PROD2 DRILL TRIP P Continue trip in hole from 10156' - 10266' DPM. Observed tagging up at 10266'. Repeat attempts to pass through 10266' with straight slack off, no go. Success with rotation, continuing rotate in hole to 10300'. Pumps at 600 GPM's - 2700 PSI. UP Wf = 190K, SO WT = 98K, ROT WT = 130K. Stop rotation & slack off to to bottom 10442' MD. 14:45 18:00 3.25 10,442 10,782 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 10442' - 10782' MD. TVD = 3200'. ADT = 2.74 HRS. Bit HRS = 2.74. ECD = 10.14 PPG. Crew Chan e 18:00 00:00 6.00 10,782 11,267 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 10782' - 11267' MD. TVD = 3199'. ADT = 4.66 HRS. Bit HRS = 7.40. ECD = 10.71 PPG. 09/23/2007 00:00 06:00 6.00 11,267 11,858 PROD2 DRILL DDRL P Directional drill 8 112" D lateral from 11267' - 11858' MD. TVD = 3202'. ADT = 4.19 HRS. Bit HRS = 11.59. ECD = 10.78 PPG. Crew Chan e 06:00 12:00 6.00 11,858 13,019 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 11858' - 13019' MD. TVD = 3170'. ADT = 4.06 HRS. Bit HRS = 15.65. ECD = 11.75 PPG. 12:00 18:00 6.00 13,019 14,162 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 13019' -14162' MD. TVD = 3169'. ADT = 3.73 HRS. Bit HRS = 19.38. ECD = 11.85 PPG. Crew Chan e 18:00 00:00 6.00 14,162 15,282 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 14162' - 15282' MD. TVD = 3171'. ADT = 3.66 HRS. Bit HRS = 23.04. ECD = 12.20 PPG. 09/24/2007 00:00 06:00 6.00 15,282 16,042 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 15282'-16042' MD. TVD = 3162'. ADT _ 3.11 HRS. Bit HRS = 26.15. ECD = 12.05 PPG. Crew Chan e Fage 41 c~ 63 ^ .Time Lo s Date From To Dur S. De ih E. De th Phase Code Subcode T COM 09/24!2007 06:00 08:15 2.25 16,042 16,232 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 16042' -16232'MD. TVD = 3163'.Pump Hi Visc swee . 08:15 09:30 1.25 16,232 16,232 PROD2 DRILL CIRC P Circulate & condition mud while pump Hi Visc sweep out of hole. Pumps @ 620 GPM's - 3520 PSI. Reciprocate & rotate drill string,at 120 RPM's - 20K TQ. ECD=11.98 PPG. 09:30 12:00 2.50 16,232 16,423 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 16232' -16423 MD. TVD = 3163'. ADT = 3.09 HRS. Bit HRS = 29.24. ECD = 12.09 PPG. 12:00 18:00 6.00 16,423 16,984 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 16423' -16984' MD. TVD = 3152'. ADT = 3.96 HRS. Bit HRS = 33.20. ECD = 11.99 PPG. Crew Chan e 18:00 00:00 6.00 16,984 17,444 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral from 16984' - 17444' MD. ND = 3141'. ADT = 3.65 HRS. Bit HRS = 36.85. ECD = 12.14 PPG. 09/25/2007 00:00 06:00 6.00 17,444 17,820 PROD2 DRILL DDRL P Directional drill 8 1/2" D lateral. Max gas 235 units. Pumped a 40 bbls sweep (8.8 ppg/ 240 vis) while drilling at 17810'. 06:00 07:45 1.75 17,820 17,820 PROD2 DRILL CIRC P Circulate 3 BU after sweep back to surface. Sweep showed no appreciable amount of increase in cuttings. Pumping 600 gpm w/ 3980 psi. Rotate 150 rpm w/ 19ik ft Ibs of torque. ECD's 12.06 ppg. Rotating wt 145k. 07:45 12:00 4.25 17,820 16,140 PROD2 DRILL REAM P Backream out of the hole. Pumping 640 gpm w/ 3900 psi. Rotate 150 rpm w/ 17k ft Ibs of torque. Pulling speed 40-45 ft/min. 12:00 18:00 6.00 16,140 12,623 PROD2 DRILL REAM P Backream out of the hole. Pumping 700 gpm w/ 3750 psi. Rotate 150 rpm w/ 14k ft Ibs of torque. Pulling speed 40-45 ft/min. 18:00 00:00 6.00 12,623 10,339 PROD2 DRILL REAM P Backream out of the hole. Pumping 700 gpm w/ 3750 to 3300 psi. Rotate 150 rpm w/ 14 to 10k ft Ibs of torque. Pulling speed 40-45 ft/min. PU wt @ 10339': 200k, SO 80k, Rot wt 135k. 09/26/2007 00:00 00:15 0.25 10,339 10,228 PROD2 DRILL TRIP P Pull out of the hole, pumping 700 gpm w/ 3300 psi. PU 200k, SO 80k. Calculated fill 73 bb-s, actual 114 bbls Runnin centrifu e . 00:15 02:30 2.25 10,228 10,228 PROD2 DRILL CIRC P Pump a 50 bbl sweep (9.9 ppg, 200 vis). Pumping 700 gpm w/ 3470 psi. Rotate 120 rpm w/ 10-11 k ft Ibs of torque. Rotating weight 135k. Slight increase in cuttings on returns of sweep. Continue to circulate a total of 1932 bbls. Fade 42 of 53 l Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/26/2007 02:30 03:00 0.50 10,228 10,150 PR0D2 DRILL OWFF P Monitor the well. Static. Service the blocks and top drive while monitoring well. Blow down to drive. 03:00 05:15 2.25 10,150 10,150 PR0D2 RIGMN SVRG P Change out the saver sub on the top drive. Change dies in the grabbers. Circulate over the top of the hole. Service the drawworks and crown. 05:15 06:00 0.75 10,150 10,722 PR0D2 DRILL TRIP P Trip in the hole on elevators. Record PU and SO wt's every 5 stands. PU wt 200k, SO wt 80k. 06:00 12:00 6.00 10,722 15,665 PROD2 DRILL REAM P Start reaming in the hole. Pumping 126 gpm w/ 360- 560 psi, rotate 50 m w/ 10-21 k ft Ibs of for ue. 12:00 12:15 0.25 15,665 15,665 PROD2 DRILL CIRC P Circulate @ 640 gpm w/ 3800 psi. Rotate 150 rpm w/ 21 k ft Ibs of torque to final of 17k ft Ibs of torque. Pumped a total of 220 bbls to help get into the hole. 12:15 15:30 3.25 15,665 17,820 PROD2 DRILL REAM P Ream in the hole. 30 rpm w/ 17k ft Ibs of torque, torque on bottom was 20k ft lbs. Pumping 126 gpm w/ 520 psi to final of 680 psi. Tagged bottom on depth. Hole took 7 bbls over calculated on tri in. 15:30 19:45 4.25 17,820 17,820 PROD2 DRILL CIRC P Circulate and condition mud. Pumping 590 gpm w/ 4000 psi. Rotate 150 gpm w/ 19k ft Ibs of torque. PU wt 255k, 155k rot wt, no down wt. ECD's 12.12 ppg, initial and 11.94 ppg final. Circulated a bottom's up, then pumped a 9.2 ppg /220 vis sweep with no a reciable increase in cuttin s. 19:45 21:30 1.75 17,820 17,820 PROD2 DRILL CIRC P Displace w/ 8.6 ppg/ 71 vis SFOBM. Rotate 120 rpm w/ 19k ft Ibs of torque. Start off Pumping 500 gpm w/ 3340 psi, increase to 525 gpm w/ 3460 psi, and final of 200 gprn w/ 890 psi. PU wt 290k, 155k rot wt, no down wt. 21:30 22:15 0.75 17,820 17,725 PROD2 DRILL OWFF P Obtain SPR's. Record PU and SO wt's. Stand back a stand of 5" HWDP. Monitor well, Well is static. Drop a 2.33" OD rabbit w/ 156' of tail. 22:15 22:45 0.50 17,725 17,539 PROD2 DRILL TRIP P Pull 2 stands of 5" HWDP. Incorrect hole fill, swabbin . 22:45 00:00 1.25 17,539 16,710 PROD2 DRILL TRIP P Pump out of the hole. Pumping 126 gpm w/ 440 psi. Monitor returns using pit #5. Record PU and SO wt's per Rig engineer's directions. PU wt 285k, SO wt none. Note: A total of 4 bbls was lost to the hole while displacing to SFOBM, then an additional 7 were lost while pumping out, up to midnight. Total of 11 bbls. Fade 43 of 5s_ l J Time Lo s Date From To Dur S. De th E De th Phase Code Subcode T COM 09/27/2007 00:00 06:00 6.00 16,710 12,527 PROD2 DRILL TRIP P Pump out of the hole. Pumping 126 gpm w/ 440 psi. Pumping 85 gpm w/ 200 psi. Monitor returns using pit #5. Record PU and SO wt's per Rig engineer's directions. PU wt 245k, SO wt none. Note: A total of 21 bbls were lost while um in out, u to 6 am. 06:00 09:45 3.75 12,527 10,227 PROD2 DRILL TRIP P Pump out of the hole. Pumping 126 gpm w/ 340 psi. Monitor returns using pit #5. Record PU and SO wt's per Rig en ineer's directions. 09:45 11:00 1.25 10,227 10,227 PROD2 DRILL CIRC P Circulate, pumping 600 gpm w/ 2850 psi. Rotate 110 rpm w/ 15k ft Ibs of torque. Circulated a total of 850 bbls. Pumped a 40 bbl a sweep (8.6 ppg/ 200 vis . Sli ht increase in cuttin s. 11:00 11:15 0.25 10,227 10,227 PROD2 DRILL OWFF P Monitor well. Static. 11:15 13:00 1.75 10,227 10,227 PROD2 DRILL CIRC P Displace 8.65 ppg SFOBM w/ 8.8 ppg SFOBM w/ 776 tube. Purring 400 gpm w/ 1400 psi. Rotate 50 rpm w/ 15k ft Ibs of torque before and 13k ft Ibs of torque after displacement. PU 200k, Rot 135k, SO wt 78k. After displacement: 188k PU, 140k rotating wt and 101 k down wt. 13:00 13:15 0.25 10,227 10,227 PROD2 DRILL OWFF P Monitor well. Static. 13:15 17:30 4.25 10,227 352 PROD2 DRILL TRIP P POOH on elevators. Mud losses after displacement, on trip out, was 6 bbls. Record PU and SO wt's per Rig Engineer. Retrieved 2.33" rabbit on top of'ars. 17:30 18:00 0.50 352 169 PROD2 DRILL TRIP P Work BHA #16: Stand back 1 stand of 5" HWDP, UD Dail 'ars. 18:00 19:15 1.25 169 55 PROD2 DRILL PULD P Continue to UD BHA #16. 19:15 20:00 0.75 55 55 PROD2 DRILL OTHR P Download Sperry Sun MWD. 20:00 21:00 1.00 55 0 PROD2 DRILL PULD P Continue to L/D BHA #16. Grade Bit. Note: Losses on the trip: TD to the shoe lost 30.5 bbls. Shoe to surface 18.16 bbls. Total losses for the trip = 49 bbls over calculated. 21:00 21:30 0.50 0 0 PROD2 DRILL OTHR P Clean floor. 21:30 22:00 0.50 0 0 COMPZ CASIN( RURD P RU to run the Slotted/Blank liner f/ the "D" lateral. 22:00 22:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" Plop and drop liner f/ the "D" lateral. 22:15 00:00 1.75 0 1,705 COMPZ CASIN ( RNCS P Run 40jts of4-1/2" 11.6 ppf L-80 BTC slotted/blank liner, per the detail f/ the "D" lateral. PU and SO wt 90k. e-~yE 44 0~ 53 l J Time Lo s Date From To Dur S. Qe th E. De th Phase Code Subcode T COM 09/28/2007 00:00 04:30 4.50 1,705 7,190 COMPZ CASIN( RNCS P Continue to run 4-1/2" 11.6 ppf L-80 BTC slotted/blank liner, per the detail f/ the "D" lateral. Monitor well using the trip tank. Record PU and SO wt's per Rig Engineer. PU wt 110 k, SO wt 90 k. 04:30 05:00 0.50 7,190 7,190 COMPZ CASIN( RURD P Rig down casing tools. 05:00 06:00 1.00 7,190 9,094 COMPZ CASIN( RUNL P Run liner on 5" drill pipe. Fifl pipe w/ 20 stands in the hole. Record PU and SO wt's per Rig Engineer. PU wt 140k, SO wt 105k, Rot wt 122k, Rot for ue 3-4k ft/ lbs. 06:00 07:00 1.00 9,094 10,232 COMPZ CASIN( RUNL P Continue running the 4-1/2" liner on 5" drill pipe. Record PU and SO wt's per Rig Engineer. Above the window: PU wt 157 k, SO wt 100 k, Rot wt 115, Rot for ue 4-5 k ft /Ibs. 07:00 09:15 2.25 10,232 13,567 COMPZ CASIN( RUNL P Continue running the 4-1/2" liner on 5" drill pipe. Record PU and SO wt's eve 5 stands in o en hole. 09:15 16:15 7.00 13,567 17,758 COMPZ CASIN( RUNL P Rotate liner in the hole due to no down wt. Record PU and SO wt's every 5 stands in open hole. Fill pipe every 25 stands. 16:15 18:00 1.75 17,758 17,783 COMPZ CASIN( RUNL P Tag the bottom of the hole @ 17820'. PU wt 260k, SO wt 75k, Rotating wt 155k, rotating torque 16k ft Ibs of torque. Set back a stand, work pipe to setting depth. Drop the 29/32" ball and pump 5 bpm w/ 740 psi for 130 bbls, then slow to 2 bpm w/ 160 psi after a total of 170 bbls pumped, then slow to 1.5 bpm w/ 110 psi till ball was on seat @ 213 bbls pumped. Increase pressure to 3200 psi and release the liner. PU wt 230k, SO wt 120k. Tag top of liner @ 10601' (shoe @ 17783'). Pressure up to 4450 psi to shear circ sub. 18:00 18:15 0.25 17,783 10,601 COMPZ CASIN( RURD P Bleed off pressure. Rig down test pump lines. Line up mud pumps. Note: Total fluid lost while RIH w/ liner was 26 bbls. 18:15 18:45 0.50 10,601 10,240 COMPZ CASIN( OTHR P POOH from 10601' to 10240' to wash the slot on the whi stock. 18:45 19:45 1.00 10,240 10,240 COMPZ CASIN( CIRC P Circulate 405 gpm w/ 1280 psi, then 500 gpm w/ 1800 psi, then 600 gpm w/ 2460 psi, washing the retrieval slot on the whipstock. Circulate bottom's u . PU wt 215k, SO wt 90k. 19:45 20:00 0.25 10,240 10,240 COMPZ CASIN( OTHR P Monitor well. Slight flow. Mud out of balance. Fac~c 4b cf ~3 a l Time Lo s . .Date From. To Dur S. De th E, De th Phase Code Subcode T COM 09/28/2007 20:00 20:45 0.75 10,240 10,240 COMPZ CASIN( CIRC P Continue to circulate to even out mud weight. Pumping 500 gpm w/ 1790 psi. Circulate a bottom's up. Note: 14 bbls was lost to the hole while circulatin . 20:45 21:00 0.25 10,240 10,075 COMPZ CASIN( OTHR P Pull 2 stands out of the hole with Baker runnin tools. 21:00 21:15 0.25 10,075 10,075 COMPZ CASIN( OTHR P Monitor well. Static. 21:15 00:00 2.75 10,075 3,356 COMPZ CASIN( OTHR P Pull out of the hole with the Baker running tools. PU wt 125k, SO wt 108k. Record PU and SO wt's every 10 stands. 09/29/2007 00:00 02:00 2.00 3,356 30 COMPZ CASIN( OTHR P Pull out of the hole with the Baker running tools. PU wt 125k, SO wt 108k. Record PU and SO wt's every 10 stands. Loss of 9 bbls on trip out. Calculated 102 bbls, actual 111 bbls. 02:00 02:30 0.50 30 0 COMPZ CASIN( OTHR P Lay down Baker liner running tools. 02:30 03:00 0.50 0 0 COMPZ FISH PULD P Clean floor, PU Baker whipstock retrievin tools to floor. 03:00 03:15 0.25 0 0 COMPZ FISH SFTY P Pre job safety meeting on PU/MU fishin BHA. BHA #17. 03:15 04:30 1.25 0 259 COMPZ FISH PULD P MU BHA #17 (Retrieve the whipstock assembl 04:30 06:00 1.50 259 3,584 COMPZ FISH TRIP P RIH w/ BHA #17, filling pipe every 20 stands. Record PU and SO wt's every 10 stands. PU wt 120k, SO wt 110k. 06:00 09:00 3.00 3,584 10,106 COMPZ FISH TRIP P Continue to RIH w/ BHA #17, filling pipe every 20 stands. Record PU and SO wt's every 10 stands. 9 bbl loss of fluid to hole on tri in the hole. 09:00 10:15 1.25 10,106 10,106 COMPZ RIGMN SVRG P Slip and cut 110' of drilling line. 10:15 11:15 1.00 10,106 10,106 COMPZ RIGMN SVRG P Service rig and top drive. Check brakes on drawworks.. 11:15 11:30 0.25 10,106 10,244 COMPZ FISH TRIP P Continue trip in the hole. 11:30 14:15 2.75 10,244 10,416 COMPZ FISH FISH P Establish circulation above whipstock, pumping 400 gpm w/ 2210 psi. PU wt 220k, SO wt 105k, w/ pumps off PU 233k, SO 105k. Engage whipstock w/ etrieval hook 10246' Overpull to 330k and set off jars. PU TO 340K and set off jars again.. Wash slot again w/ 400 psi and 2210 psi. Pick up and saw 50k over ull. 14:15 16:00 1.75 10,416 10,416 COMPZ FISH CIRC P Circulate BU @ 10201' (bottom of whipstock assembly @ 10416'). Pumping 400 gpm w/ 2210 psi. Mud weight at bottom's was 8.3 ppg (.5 light). Circulated a total of 780 bbls to get 8.8 ppg in and out. Note: lost 5 bbls to the hole when whi stock was ulled free. Page ~5 of 53 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/29/2007 16:00 17:15 1.25 10,416 10,416 COMPZ FISH OTHR P Monitor well, flowing. Rate of flow (gains), calculates to be 1.3 to 1.5 b h. 17:15 18:15 1.00 10,416 10,416 COMPZ FISH CIRC P Circulate 400 gpm w! 2210 psi, weighting up f/ 8.8 ppg to 8.9 ppg. Circulate a total of 592 bbls. Note: 14 bbl gain due to additions of wei ht material. 18:15 18:45 0.50 10,416 10,403 COMPZ WELCT OTHR NP Appeared to have a gain in the pits. Shut to i e rams, open HCR to choke. Monitor wellbore pressure of 20 si at the choke. Rig supervisor and toolpusher were notified. Verified that there was no pressure. Opened top pipe rams. Note: Trip tank was pumped out to active pits. Chuck Sheave w/ AOGCC was notified of the rams bein shut. 18:45 21:30 2.75 10,403 10,403 COMPZ WELCT CIRC NP Circulate until 8.9 ppg MW was acheived in and out. Circulate 400 m w/ 2090 si. Circulate 1340 bbls. 21:30 22:00 0.50 10,403 10,403 COMPZ WELCT OWFF NP Monitor well, slight breathing- to just about static. 22:00 23:15 1.25 10,403 10,046 COMPZ FISH TRIP P Pull out of the hole w/ Whipstock assembly. First stand pulled on elevators swabbed, then pumping out 3 stands (3 bpm w/ 280 psi). Swabbed a total of 11 bbls + should have taken 6 bbls = 17 bbl gain. PU wt 240k, dra in to 270k. 23:15 00:00 0.75 10,046 10,046 COMPZ FISH CIRC P Circulate a bottom's up. Pumping 500 gpm w/ 3180 psi. Circulate a total of 562 bbls. Mud weight 8.9 ppg in and out. 09/30/2007 00:00 00:15 0.25 10,046 10,046 COMPZ FISH OTHR P Monitor well, static. 00:15 01:45 1.50 10,046 9,772 COMPZ FISH OTHR P POOH with Baker retrieving hook and fish (whipstock assembly). Hole swabbing. Rotate while picking up trying to free up, no luck. Then reciprocate up and down trying to free up. Swabbing up, pushing mud back in the hole on the down stroke. Finally quit swabbing, hole taking fluid. Set back stand. Pull a stand with hole takin fluid. PU wt 240k. 01:45 02:00 0.25 9,772 9,772 COMPZ FISH OTHR P Monitor well, fluid falling slightly. 02:00 03:00 1.00 9,772 9,772 COMPZ FISH CIRC P Circulate bottom's up. Circulate a total of 552 bbls. Pumping 500 gpm w/ 2980 psi. Lost 26 bbls to the hole while circulatin . 03:00 03:15 0.25 9,772 9,772 COMPZ FISH OTHR P Monitor well, static to slight breathing. ( P~ ge ~? cf 53 • s Time Lo s Date From To Dur S. De ih E. De th Phase Gode Subcode T COM 09/30/2007 03:15 06:00 2.75 9,772 4,500 COMPZ FISH TRIP P POOH w/ Baker retrieval hook and fish (Whipstock assembly). Monitor well on the trip tank. Hole taking extra fluid over calculated. 06:00 08:30 2.50 4,500 276 COMPZ FISH TRIP P Continue to POOH w/ Baker fishing assembly with the fish (Whipstock assembly). Calculated hole fill 93.8 bbls, actual hole fill 93.8 bbls. 3 bbls over calculated. 08:30 09:45 1.25 276 185 COMPZ FISH PULD P Lay down Baker fishing assembly to the pipe shed. Break and lay down fish: Whipstock, debris sub, drain sub, string magnet, safety disconnect, bottom tri anchor, blank sub. 09:45 10:30 0.75 185 185 COMPZ FISH OTHR NP After breaking off 5"drill pipe under the blank sub, there was a uncontrolled release of fluid into secondary containment. Estimated 10 gals of OBM w/ crude. This release was due to trapped pressure in the remaining 5 joints of drill pipe under the blank sub. Pressure due to mi ratin as and oil. 10:30 12:00 1.50 185 0 COMPZ FISH PULD P Continue to lay down and back off space out pup and 5 jts of 5" drill pipe, unloader, crossover sub, no go sub and seal assembl . 12:00 12:45 0.75 0 0 COMPZ FISH PULD P PU/Break and lay down fishing assembl . 12:45 13:15 0.50 0 0 COMPZ FISH OTHR P Clean and clear rig floor. 13:15 14:00 0.75 0 0 COMPZ WELCT OTHR P Rig up to test ROPE. Drain stack, pull wear bushin ,fill with water. 14:00 19:00 5.00 0 0 COMPZ WELCT BOPE P Test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Tested to 250 psi low and 3000 psi high. Test each f/ 5 min. Chart test. Test upper pipe (3-1/2" x 6"variables w/ 5.5" and 4.5". Tested annular w/ 4.5". Tested all floor safety valves, upper and lower IBOP on the top drive, kill and choke line valves, choke manifold. Test Komme . 19:00 20:00 1.00 0 0 COMPZ WELCT OTHR P Rig down testing equipment. Drain stack. Set wear bushing. Blow down and line u choke manifold. 20:00 21:00 1.00 0 0 COMPZ CASIN( RURD P Rig up to run the 4-1/2" hook Hanger assembl . 21:00 21:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running the 4-1/2" Hook Han er assembl f/the "D" lateral. 21:15 22:30 1.25 0 364 COMPZ CASIN ( RNCS P PU/MU/RIH w/ 4-1/2" hook hanger assembl f/ the "D" lateral. 22:30 00:00 1.50 364 364 COMPZ CASIN ( OTHR P MU inner string tools w/ Sperry Sun Slim MWD. 156' of inner strip 10/01/2007 00:00 00:45 0.75 364 364 COMPZ CASIN ( OTHR P MU inner string tools w/ Sperry Sun Slim MWD.(156' of inner string). Orient to Baker hook hanger. Note orientation of bent 'oint to hook. P~c;e ~8 e~ >3 C~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 10/01/2007 00:45 01:15 0.50 490 490 COMPZ CASIN( RURD P Rig down GBR tongs. Rig down Baker small tools f/ the 2-3/8". 01:15 01:45 0.50 490 490 COMPZ CASIN( CIRC P Shallow test MWD. Pumping 120 gpm w/ 490 psi. Did not get a good test. Tried both pumps. Pump # 2: 120 gpm w/ 500 psi. 130 gpm w/ 540 psi. Pum # 1" 120 m w/ 470 si. 01:45 03:00 1.25 490 2,781 COMPZ CASIN( RUNL P RIH w/ Hook Hanger assembly on 5" drill pipe. Filling every 25 stands. Record PU and SO wt's every 10 stands. PU wt 120k, SO wt 100k. 03:00 04:15 1.25 2,781 2,781 COMPZ CASIN( OTHR P Work to get MWD detection. Pumping 115 gpm w/ 680 psi. Acheived a good toolface. 04:15 06:00 1.75 2,781 5,633 COMPZ CASIN( RUNL P RIH w/ Hook Hanger assembly on 5" drill pipe. Filling every 25 stands. Record PU and SO wt's every 10 stands. PU wt 155k, SO wt 105k. Fill and check MWD @ 5158', pumping 120 m w/ 680 si. Good test. 06:00 07:00 1.00 5,633 7,538 COMPZ CASIN( RUNL P Continue to RIH w/ Hook Hanger assembly on 5"drill pipe. Filling every 25 stands. Record PU and SO wt's every 10 stands. PU wt 120k, SO wt 100k. 07:00 07:30 0.50 7,538 7,538 COMPZ CASIN( CIRC P Fill and check MWD @ 7538', pumping 120 gpm w/ 680 psi. Good test. 07:30 09:30 2.00 7,538 10,162 COMPZ CASIN( RUNL P Continue to RIH w/ Hook Hanger assembly on 5" drill pipe. Filling every 25 stands. Record PU and SO wt's every 10 stands. Total of 3 bbls loss while RIH. 09:30 11:45 2.25 10,162 10,623 COMPZ CASIN( RUNL P Orient MWD to 30L @ 10162', then RIH to 10505' (no go in the B lat), POOH to 10162', tum string 90 deg right. Work torque, then trip back to 10505' (tagged out again). POOH to 10162', turn string another 90 deg. Work torque and trip in to 10623'. Sucessfully went out the window on the 3rd attem t. 11:45 12:15 0.50 10,623 10,623 COMPZ CASIN( OTHR P Orient hook hanger to 10 left. Pumping 120 gpm w/ 820 psi. PU 248k, SO wt 105k with um son. 12:15 12:45 0.50 10,623 10,257 COMPZ CASIN( OTHR P PU wt 250k, SO wt 100k. RIH to 10257' and hook w/ 30k on Hook. Hooked @ 27 right. POOH to 10234', orient 1801eft then RIH to 10272' to confirm hook @ 10257'. POOH to 10234' and orient to 10 Left. PU wt 250k, SO wt 100k. RIH and hook @ 27 ri ht w/ 30k on hook. ~z~e ~9 cr 53 • Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 10/01/2007 12:45 14:30 1.75 10,257 10,257 COMPZ CASIN( OTHR P Drop and pump 29/32" ball. Pump @ 120 gpm w/ 810 psi. Slow down to 88 gpm after 1400 strokes. Pumping 88 gpm w/ 420 psi. Ball on seat @ 200 strokes (200.8 bbls). Pressure uj~ to 2800 si to inflate ECP, ressure bleed down to zero. While pumping 30 spm (298 gpm) was able to pressure to 4000 si and blow ball seat. 14:30 15:00 0.50 10,257 9,928 COMPZ CASIN( OTHR P Pull out of the hole on elevators with the inner strin f/ 10408' to 9928'. 15:00 16:15 1.25 9,928 9,928 COMPZ CASIN( CIRC P Circulate a bottom's up. Pumping 7 bpm w/ 750 psi, final pumping rate 9 b m w/ 1150 si. 16:15 16:45 0.50 9,928 9,928 COMPZ CASIN( OTHR P Monitor well. Breathing to static. 16:45 21:30 4.75 9,928 154 COMPZ CASIN( OTHR P Continue to POOH w/ Baker running tools. Monitor well on tri tank. 21:30 21:45 0.25 154 154 COMPZ CASIN( OTHR P Lay down Hook Hanger running tools. 21:45 22:15 0.50 154 154 COMPZ CASIN( OTHR P Break Sperry Sun MWD to change out ulsar. La down MWD. 22:15 23:30 1.25 154 0 COMPZ CASIN( OTHR P Lay down Hook Hanger running tools. Calcualted fill 94.5 bbls, actual fill 110.5 bbls. Hole took 16 bbls over calculated. 23:30 00:00 0.50 0 0 COMPZ CASIN( OTHR P Lay down Baker pups, clear/clean floor. Shut blind rams. 10/02/2007 00:00 00:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running LEM f/the "D" lateral Hook Han er. 00:15 01:30 1.25 0 276 COMPZ CASIN( RNCS P Pickup/ Makeup LEM f/ the "D" lateral er the runnin order. 01:30 02:15 0.75 276 296 COMPZ CASIN( OTHR P Makeup inner string w/ Sperry Sun MWD. MU Baker Torquemaster to strip .Orient too enin of LEM. 02:15 02:45 0.50 296 391 COMPZ CASIN( OTHR P PU/MU stand of 5"drill pipe. Shallow pulse test MWD. Pumping 118 gpm w/ 650 si. Good test. 02:45 10:30 7.75 391 10,420 COMPZ CASIN( RUNL P RIH w! LEM on 5"drill string. Fill pipe every 25 stands. Recording PU and SO wt's every 10 stands. RIH 30' per min. Fill pipe @ 2645': pumping 105 gpm w/ 650 psi. Good test. Fill pipe @ 6954': pumping 115 gpm w/ ??? psi, Fill @ 8572' :pumping 115 gpm w/ 730 psi. PU wt 225k, SO wt 115k. Calculated displacement 104.5, actual 103.5 bbls. Note: 5" drill pipe: Ran 40 stands w/ super sliders, 50 stands slick, then 17 stands of 5" HWDP, then a working stand to settin de th. 10:30 10:45 0.25 10,420 10,420 COMPZ CASIN( CIRC P Establish circulation w/ 100 gpm w/ 730 psi. Orient to 9 right. PU wt 225k, SO wt 115k. P~.ge 5~ a~ 53 ~ - i ~- Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 10/02!2007 10:45 11:15 0.50 10,420 10,496 COMPZ CASIN( RUNL P Continue to RIH w/ LEM on 5" drill pipe. Pumping 100 gpm w/ 730 psi and collet latched in. Slacked off to 70k (45k below down wt), PU to 250k (25k over PU wt) to confirm latched in. Slack back off to block wt of 70k. LEM in lace w/ MWD readin 21 ri ht. 11:15 13:00 1.75 10,496 10,496 COMPZ CASIN( CIRC P Drop the 29/32" ball, pump down @ 109 gpm w/ 870 psi. till 160 bbls pumped, then slow to 84 gpm w/ 720 psi. Ball on seat after pumping 203 bbls. Pressure to 4400 psi and release and shear ball f/ seat. 13:00 13:45 0.75 10,496 10,496 COMPZ CASIN( DHEO P Establish circulation throught the kill line. Using the top pipe rams (3-1/2" x 6" variables), hest the 9-5/8" &._ 10-3/4"casin and Baker Tor uemaster Packer 813-47 x 38 to 2500 si f/ 30 minutes. Chart test. Lost 75 si. Good test. 13:45 14:30 0.75 10,496 10,134 COMPZ CASIN( OTHR P Pull out of the hole. PU wt 220k, SO wt 115k. 14:30 15:45 125 10,134 10,134 COMPZ CASIN( CIRC P Circulate @ 294 gpm w/ 840 psi, adding lubricant 776 to increase concentration to 3%. Circulated a total of 507 bbls. 15:45 16:15 0.50 10,134 10,134 COMPZ CASIN( OTHR P Monitor well. Slight breathing to static. 16:15 16:30 0.25 10,134 9,981 COMPZ CASIN( CIRC P Establish circulation pumping 28 gpm w/ 440 psi. Pump a 20 bbl dry job (10.1 ppg/72 vis). Then drop the Haggard ID wiper inside of the drill i e. 16:30 16:45 0.25 9,981 9,981 COMPZ CASIN( OTHR P Blow down the choke and kill lines, to drive too. 16:45 17:00 0.25 9,981 9,981 COMPZ DRILL SFTY P PJSM on laying down 5" drill pipe. 17:00 00:00 7.00 9,981 2,800 COMPZ DRILL PULD P Lay down 5"drill pipe to the pipe shed. Remove super sliders from the 5" drill pipe w/ POOH. At 2800' : PU wt 105k, SO wt 95k. Remove 6" liners and install 6-1/2" liners in #2 m . 10/03/2007 00:00 02:30 2.50 2,800 50 COMPZ DRILL PULD P Lay down 5"drill pipe to the pipe shed. Remove super sliders from the 5"drill pipe w/ POOH. Calculated fill 101 bbls, actual 109 bbls. 02:30 03:00 0.50 50 50 COMPZ DRILL PULD P Remove super slider hardware from the floor. Clean floor. 03:00 03:15 0.25 50 50 COMPZ DRILL OTHR P RU to UD LEM running tool w/ Sperry Sun slim MWD. 03:15 03:30 0.25 50 50 COMPZ DRILL SFTY P PJSM on laying down LEM running tool. 03:30 04:15 0.75 50 0 COMPZ DRILL PULD P Break and UD Baker running tool f/ the LEM. Break and UD inner string (Sperry Sun MWD). Totaf loss on trip 7.8 bbls. Page 51 0~ 53 • Time Lo s Date From To Dur S. De ih E. De th Phase Code Subcode T COM 10/03/2007 04:15 04:30 0.25 0 0 COMPZ DRILL OTHR P Drain stack, pull Vetco wear bushing and remove from the floor. 04:30 05:15 0.75 0 0 COMPZ DRILL RURD P Rig dowm LEM handling tools. Clean floor. 05:15 05:45 0.50 0 0 COMPZ RPCOh RURD P Rig up to run 4-1 /2" injector com letion. 05:45 06:00 0.25 0 0 COMPZ RPCOI~ SFTY P Pre job safety meeting on running com letion. 06:00 16:30 10.50 0 10,199 COMPZ RPCOh RCST P P /RIH w/ 4-1/2" 12.6 oaf L-80 IBT-m completion assembly. Record PU and SO wt's every 10 stands. Change liners in #1 mp to 6-1/2". PU 130k, SO 88k. 16:30 17:00 0.50 10,199 10,219 COMPZ RPCOh RCST P Five foot in the hole to set Baker Anchor Seal assembly into the Baker Torquemaster packer (RIH on dp @ 10210') (tubing tally is 5.57' shorter, so by tubing tally 10215.80'), latch in. PU to 130k, then pull 40k over to shear 4 ins in the PBR. 17:00 17:15 0.25 10,219 10,122 COMPZ RPCOh TRIP P POOH to 10122' to space out. Total of 325 'ts in the hole. 17:15 18:00 0.75 10,122 10,122 COMPZ RPCOA OTHR P Figure space out to be approx 4' from fully inserted in PBR. Pups will allow f/ 3.42' space out. Used pup jts 7.79', 7.79', 3.8', 5.8'. Blow down choke and kill lines and the to drive. 18:00 19:00 1.00 10,122 10,219 COMPZ RPCOh HOSO P MU space out pups, then 1 full jt (JT # 326), then MU Vetco Gray MB 222A hanger w/ 4.909" MCA top connection. Total fluid lost on trip in w/ tubing = .7 bbls. 19:00 19:30 0.50 10,219 10,219 COMPZ RPCOA DHEO P RILDS. Test upper and lower tubing hanger body to 230 psi low and 5000 psi high. Hold each test 10 min. OK. Witness b Ri Su ervisor. 19:30 23:15 3.75 10,219 0 COMPZ RPCOh NUND P Pull the 4-1/2" landing joint. Rig down the flow line, hole fill, choke and kill lines. Remove flow nipple, PU BOP stack and set back. PU high pressure riser and set back. Continue cleaning pits. Changing liners and swabs in # 1 m to 6-1/2". 23:15 00:00 0.75 0 0 COMPZ RPCOh NUND P NU Vetco Gray 4-1/8" 5m horizontal injector tree w/ 9-1/2" 4TPIOtis tree ca 4.125" ID. Continue cleanin its. 10/04/2007 00:00 00:30 0.50 0 0 COMPZ RPCOh NUND P Continue to NU Vetco Gray 4-1/8" 5m Horizontal injector tree w/ 4-1/8" actuated valve. 00:30 01:15 0.75 0 0 COMPZ RPCOh DHEQ P Test tubing hanger void to 225 psi and 5000 psi. Hold f/ 10 min. Good test, witnessed b Ri Su ervisor. 01:15 03:00 1.75 0 0 COMPZ RPCOh DHEQ P Pull BPV, then set two way check. fill tree w/diesel. Test to 240 psi and 5050 psi. Hold each test f/ 10 min. Good test. Witness by Rig Supervisor. Pull two wa check. P~~e ~2 os 53 C~ J Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 10/04/2007 03:00 03:45 0.75 0 0 COMPZ RPCOA RURD P RU to freeze protect well w/diesel (185 bbl) to 2920' before "U" tubing and 2270' (1882' TVD @ 65 deg) after "U" tubin diesel. 03:45 04:00 0.25 0 0 COMPZ RPCOA SFTY P PJSM f/ freeze protecting well using ASRC um truck. 04:00 06:30 2.50 0 0 COMPZ RPCO FRZP P ASRC pump 2 bbls, pressure test lines to 2500 psi. ASRC start off pumping 2 bpm w/ 300 psi @ the well, 750 psi @ the pump truck. Pumped 70 bbls w/ no losses, then increase rate to 3 bpm w/ 360 psi @ the well, 1050 psi @ the pump truck. While pumping 180 bbls wellhead pressure was 475 and pump truck pressure was 1050 psi. Pumped a total of 185 bbls of diesel w/ a total of 185 bbls returned to the pits. Final static pressure was 310 psi. Note: 8 bbls pumped before fluid to the bottom of the gas buster. 24.5 bbls pumped till fluid out the discharge of the gas buster. 16.5 bbls to fill gas buster. Note: Layed down 45 joints of 5"drill pipe from the derrick while pumping, via the mouse hole. 06:30 07:30 1.00 0 0 COMPZ RPCOh FRZP P "U" tube diesel f/ the annulus to the tubing. Initial pressure on the annulus was 310 psi, final pressure was 280 psi. Note: Continue to lay down 5" drill pipe from the derrick, using the mouse hole. Continue cleanin its. 07:30 11:45 4.25 0 0 COMPZ DRILL PULD P Continue to lay down 5" drill pipe from the derrick, using the mouse hole. While laying down drill pipe, observed an extra 20-30000 ft Ibs of torque required to break connections. RU rig tongs and snub line to keep from bendin 'oints. Move rock washer. 11:45 13:15 1.50 0 0 COMPZ RPCOh OTHR P RU lubricator and set BPV. Tubing pressure 210 psi, 10-3/4" & 9-5/8" x 4-112" tubing (IA) was 220 psi, 13-3/8" x 10-3/4" & 9-5/8" casing (OA) was 125 psi. Bleed pressure to zero above BPV. 13:15 15:00 1.75 0 0 COMPZ RPCOh OTHR P Cleaning up cellar box, secure well. Prepare rig floor to skid rig (pin back beaver slide), blowing down steam and water lines, disconnect air steam and mud lines. Page 53 d€-53 1 `~ Cement Summary 1J-176 13 3/8" Surface casing, casing, 8/23/2007 23:00_ Cementing Start Date Cementing End Date Wellbore 8/23/2007 8/24/2007 1 J-176 Evaluation Method Cement Evaluation Results Returns to Surface Comment Turn over to Dowell. Pump 10 BBIs CW 100. Test lines to 3000 PSI. pump 40 BBIs of CW 100. Continue with 50 BBIs of 10.5 PPG MudPush @ 4 BPM - 200 PSI. Good, full reciprocation.Drop bottom plug.Continue pumping with Dowell Pumping a taotal of 630 BBIs of 10.7# Lead cement followed with 99.1 BBIs of 12.0# Tail cement. Drop Top plug, and flush lines with 10 BBIs of water. Continued with ood reci vocation of strin in 15 ft increments. UP WT = 300K, SO WT = 145K. Turn over to rig pumps. Displace cement with 7 BPM - 830 P I I P, continue reciprocation untl_observed string weight falling to 95K and losing movement with 65 BBLs of Lead on annulus. Set casing on hanger, continue to displace observing mud push returns with 165 BBLS pumped, 10.4 PPG cement with 187 BBLS pumped, 10.7 PPG cement returns at 408 BBIs pumped, for a total of 245 BBLS of cement returns to surface. Slow pumps at 4400 stks, and observe plug bump @ 4604 stks = 543 BBLS as calculated with FCP @ 3 BPM - 800 PSI. Pressure to 1300 PSI, hold for 10 minutes. Bleed pressure and check floats. Floats held. CMIP @ 0315 HRS. 1, 0.0-3000.OftK6 Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (bbl) Top Plug? Bottom Plug? 0.0 3,000.0 No i 1 4.0 Yes Yes Initial Pump Rate (bbllmin) Final Pump Rate (bbllmin) Average Pump Rate (bbllmin) Final Pump Pressure (psi) Plug Bump Pressure (psi) 7 7 7 630.0 800.0 Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) i Yes 15.00 1 No Depth tagged (ftKB) Tag Method !Depth Plug Drilled Out To (ftKB) ~ Drill Out Diameter (in) Drill Out Date Lead Cement _ _ _ Fluid Type Fluid Description Amount (sacks) ~ Class Volume Pumped (bbl) Lead Cement 800 G 630.0 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft'Isack) J. Mix H2O Ratio (gallsack) 0.0 3,000.0 250.0 4.56 21.70 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 10.70 10.00 Cement Fluid Additives ~~a ~ ryF,~ ~ Plug ',.Plug (Antifoam Antifoam 'Antifoam Antifoam D31 Barite B809 Cement CW 100 Chemical wash Dispersant Dispersant ID962 Lite Crete D970 ' Mudpush 11 iD110 Retarder Uniflac Uniflac 2, 3,000.0-3,805.OftKB ............. _............____. i op In:nesl esonom tr[nesl ruu rcemm r ~.mnc ra:rn iooq i op rmg r ovavm rmg.• 3,000.0 3,805.0 No No No Initial Pump Rate (bbllmin) Final Pump Rate (bbl/min) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) 7 7 ( 7 709.0 Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) No ~ No Depth tagged (ftKB) ~ Tag Method Depth Plug Drilled Out To (ftKB) i Drill Out Diameter (in) I Drill Out Date Tall Cement Fluid Type Fluid Description Amount (sacks) ~ Class Volume Pumped (bbl) ' Tail Cement 210 G 99.1 V Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft /sack) ~ Mix H2O Ratio (gal/sack) ~ 3,000.0 3,805.0 ! 35.0 2.49 8.46 Free Water (%) Density (Ib/gag Plastic Viscosity (cpj Thickening Time (hrsj 1st Compressive Strength (psi) 12.00 ~ 3.75 ~ 1 Cement Fluid Additives ads ryr° r;,,,~ -- ~ \ Cement Summary 1 J-176 9-518" x 10-3/4" Intermediate, casing, 9/1/2007 10:30 _., Cementing Start Date Cementing End Date Wellbore 9/1 /2007 9/1 /2007 1 J-176 Evaluation Method Cement Evaluation Results Comment 1, 6,184.0-11,0OO.OftKB Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (bbl) Top Plug? Bottom Piug? 6,184.0 11,000.0 Yes Yes Yes Initial Pump Rate (bbllmin) Final Pump Rate (bbllmin) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) 5 3 5 500.0 1,000.0 Pipe Reciprocated? Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated? Pipe RPM (rpm) Yes 30.00 1 ~ No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date 10.900.0 I Drill Bit i 8 1/2 CW 100 Fluid Type Fluid Description Amount (sacks) Class Volume Pumped (bbl) CW 100 100.0 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft /sack) Mix H2O Ratio (gal/sack) 3,097.0 4,840.0 I Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) i Thickening Time (hrs) 1st Compressive Strength (psi) 8.34 Cement Fluid Additives a~~~ T;~e c-,n~ Mud Push Fluid Type Fluid Description Amount (sacks) (Class ~Voiume Pumped (bbi) Mud Push 75.0 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft /sack) Mix H2O Ratio (gal/sack) 4, 840.0 6,184.0 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 11.00 Cement Fluid Additives ad-.~ T~;re a~~~ 0.061 A ntifoa m D046 0 6 (Retarder D110 0 07i Extender ID124 31.O) iFluid Loss Control D167 j Silica I, D178 24.0' Dispersant __ _ _ D185 __ 0.21 Cement Fluid Type Fluid Description Amount (sacks) ` ' V Class Volume Pumped (bbl),v, Cement 921 DeepCrete 370.8 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) Yield (ft (sack) ~ Mix H2O Ratio (gal/sack) ~ 6,184.0 11, 000.0 35.0 2.26 7.60 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) 1st Compressive Strength (psi) 12.50 6.70 Cement Fluid Additives Add Typc Cere Daily Operations Summary Report 1 J-176 Job: DRILLING ORIGINAL Start Dt~ N E^d Dale Last tar- Sum 18/16/2007 8!17/2007 Demob rig from 1J-162. Move to 1J-176. Rig up_ Rig accepted @ 2300 HRS 8-16-07 I 8/17/2007 8118/2007 Complete rig up. C/O Saver sub, Slip & cut drilling line. Take on mud. Rack back DP. MU BHA #1. Spud well. Drill 16" surface hole to 31 T TD. ND = 317'. 18/18/2007 8/19/2007 Directional Drill 16" Surface hole from 317' - 1593'. TVD = 1489'. ADT = 9-69 HRS I '8!19/2007 ',8/20/2007 Directional Drill 16" Surface hole from 1593' - 3211' MD ND - 2157'. ADT = 11.39 HRS 8/20/2007 ~ 8/21/2007 I Directional Drill 16" Surtace hole from 3211' - 3805' = TD. TVD = 2302'. Observed "ledge" at 3400' MD +/-, and 'continue knock down ledge. Continue drill to TD well @ 3805 MD, TVD = 2302'. BROOH, pumping Hi Visc sweep. I BROOH to 2834' @ 10 min/stand. 8121/2007 8!22/2007 Continue BROOH to 1692' MD. Trip back to TD. Circulate & POOH on elevators. lay-dn BHA., RU& run 13 3/8" casing to 1410' MD Hit bridge at 1410' MD Work casing string atempting to make hole. (8/2212007 8!23/2007 Continue work casing string through bridge @ 1410' MD. No success. Rip up and POOH laving down casiaa._ make hole operner BHA and trip in hole.POOH. MU Hole operner BHA #2. ~ 8!23/2007 8!2412007 ',Run Hole opener BHA to TD, Circulate & condition mud whole BROOH at 10 ft/min. POOH. RU ~ run 13 3!3" asing to set on depth. Circulate 8 condition mud. Rig up & turn over to Dowell for tint job. 5c~ CMS ~~ r? ~;~t( 18/24/2007 ~ 8/25/2007 ~ Nipple down Diverter system. NU BOP's 8 test same. Make up BHA #4, 12 1/4" drilling assemb~y- ~t ~t~ 8/25/2007 ; 8/26;2007 Upload MWD. MU remaining BHA. TIH, picking up singles from pipesh2d. MU 12 1/4" Ghost reamer. Perform ', Pulse test. TIH. to tag FC. CBU. perform casing test to 3000 PSI. Oril(out Shoe track. perform LOT to 14.3 pp~_ ', Drill 12 1/4" INT_ Hole to 5758' MD. 2577' ND $/26/2007 8/27/2007 Drill 12 114" Intermediate hole to 9690' MD- TVD = 3095'. Circulate sweep & condition mud, Circulate to control ECD's 8/27/2007 8/28/2007 ',Drill 12 1/4" Intermediate hole to TD. CBU x 4, until hote clean, and POOH:on eleva#ors. 18/28/2007 8129/2007 BROOH CBU x 5 at the shoe, slip and cut drilling line, continue POOH, lay do BHA #4. MU Hole opener BHA #5, upload same. ~ 8/29/2007 3130/200,' 'Finish upload of fM~'VD, finish MU 8HA #5'.' RIH to 6600', Log f! 6600' to 905D' (360-450 ftlhr). RIH to 10250', Lag'1 ~f/ 10250' to 10875' (200 ftlhr). 8!30/2007 8/31/2007 Log f/ 10875' to 1 1010' (200 ft/hr), backream (11010'- 10455') slow while circ 6 BU's, monitor well, POOH on ( elevators f/ 10455' to 8652', monitor well, pump a dry job, POOH f/ 8652' to 3703', Circ casing clean, spot steel tube pill, POOH, remove sources, download, UD BHA #5, clean floor, change top pipe rams to 10-3l4", test rams, RU f/ casin PJSM on running 9-5/8" casing. I '8131!2007 9/112007 ~ Run 5-518" casing. CBtJ @' 1966', con't RIH w/ casing. circ 290 bbls (a BU} @ 5000', continue running casing, circ 150 bbls (OH volume) @ 7300'. continue running casing,circ 176 bbls @ 8913' while changing over equipment f/ 10-3/4", install x-o jt. circ 256 bbls while changing equipment, continue running casing to 9900' @ midnight. 19/1/2007 9/2/2007 Running 10-3/4" casing f/ 9900' to 10975, circ down landing joint to 11092', circ 135 bbls, remove Frank's filiup too;, RIH to 11002', install Dowell cement head, reciprocate 30' while circulating and conditioning muss prior to cementing, Cement casing, displace w/ SFOBIGi, ump plug, floats did not hold, repressure to 1000 psi, still not i holding, re-pressure to 800 psi WOC, Conduct infectivity test on 13-3/8" by 10-3/4" & 9-5/8" annulus, bleed off pressure on 10-3/4" casing-- cement set up with no bleed back. ,9/2/2007 9/3/2007 Rig down cement head and Imes, nipple down to PU BOP stack and Set emergency slips, work on slips to ft around 10-aid" casing. set 315k on wt indicator on the slips, cutoff 1 G-3/4" casing. install packoff, NU Vetco/Gray ' wellhead. test packoff. remove 10-314" rams f/ top pipe. PU/MU 14 stands of 5" HWDP Hydril rep look @ ram shaft of off driller's upper pipe rams, change out clutch inside of BOPE, change upper rams to 3-112" x 6", test l rams, rig down testing equipment. ~ 9/3/2007 9/4/2007 Install VetcoiGray wear bushing and secure same, PJSM, PU/MU BHA #6, shallow test, PU/RIH w/ 17 stands of f dp f! the pipe shed, Run stands f/the derrick, Run 40 stands w/ super sliders f/ the pipe shed, circ BU @ 10894', RU and test casing to 3000 psi, not holding, circ BU, test casing, not holding, test surface equipment- OK, ;monitor well, POOH w/ BHA #6, SLM. I 9/4/2007 9/5/2007 RU/test intermedaite Casing With blinds shut, no test. MU Baker retrievamatio, R1H t0 2103', test casing to 3000 psi- 5 min- good test ,RIH to 6478'_ test casing to 3000 psi- 5 min- good test, RIH to 10835', test casing to 3000 ~ '~ BOPE w/ f~ g Viand test psi f/ 30 min- chart test- good test, pump dry job.. POOH, L/D tool, Pull wear bus m 4-112", 5" and 5-112" test~oint, R/D testing equipment. set Vetco Gray wear bushing. ~ 9/5/2007 9/6/2007 I Blow down kilt/ & choke lines, PJSM on PU/MU BHA #8, PU/MU/RIH w/ BHA #8 to 10821', slip and cut drilling ' , rat line, service rig, make connection and drill cement, wiper plugs, FC @ 10909', cement, guide shoe @ 11000 ~ i hole to 11010', 20' of new hole to 11030', circulate, perform LOT (calculated to 13.1 pp~,_Rig down testing !equipment, perform PWD baseline, directional drill "~ atT era~to 115 0'. 19/6/2007 '~ 9/7/2007 Directional drill "13" lateral f/ 11580' to 15700'. ~ 9/7/2007 Directional drill "B" lateral f/ 15700' to 17136'_ BROOH to 16982' while work on # 2 mud pump, directional drill f/ 9/8/2007 17136' to 17820'. 9/8/2007 ~9/9120D7 'Directional drill "B''' lateral fl 1782D' to 17940', pump a sweep and BROOH to i 1 G°0'. POOH to the casing shoe. ;circ a sweep surf-surf- then 4+ BU's (3238 bblsj to clean casing. Service Rig. ~ Page 113 Report Printed: 11/9/2007 Daily Operations Summary Report 1 J-176 Job: DRILLING ORIGINAL Sart Gate End Date _-- - ___ Last 2 ,hr Sum 9/9/2007 9/10/2007 Finish servicing rig, RIH f/ 10913' to 11018', Rotate and ream in the hole to TD @ 17940', Displace to 8.4 ppg SFOBM, monitor well, POOH on elevators to 17074', pump out to shoe, continue to pump out to 9203' ,POOH to 8442' @ midnight. 9/t0i2007 9/1 112007 iii.. POOH w/ BHA #8 f/ 8442' to 353, PJSM.. UD part of BHA # 8, downlaod MWD, Continue UD BHA #8, clean '!..flour, remove shot pin assembly on the top drive, PJSM. RU Schlumberger WL to run USI, Run in hole to 2600', ',tractor to 8283', POOH w/ WL tools. UD WL tools, install shot pin assembly on the top drive. 9/11/2007 9/12/2007 Finish working on the top drive, MU BHA # 9- cleanout run, TIH to shoe. the TIH to 13400' MD Circulate each ~ .depth, monitor well with gains of 1.2 - 2.8 BBLS / HR. I 9/12!2007 '; 9/13/2007 Continue wash ~ ream into hole to TD fc~ 1794D' MD. Circulate & condition mud monitoring well for flow. Pump Hi ' Visc sweep, and monitor we(I until no flow observed. Pump out of hole to 13064' MD, with proper hole fill. 9/13/2007 9/14/2007 'Continue Pump out of hole to shoe. Sweep hole, and pull to 10300'. Displace well with SFMOBM with 776 Lube at 3%, POOH. RU SWS for USIT logging run. 9/14/2007 '.9/15/2007 Pull to 10300' MD. Displace well with 8.8 PPG MOBM. Monitor well. POOH. Monitor well every 2000' on TOH. 9/15/2007 9/16/2007 Rig up and test upper rams & blind rams as per AOGCC regs. Rig up & Run 5 1/2" B lateral liner. Tag bottom @ 17946' with shoe. Pullup to set TOL on depth as planned. Drop ball and pump down same. 9/16/2007 9/17/2007 Set & release from 5 1/2 liner assmbty. Test casing c~ packer to 2500 PSI. CBU ~ condition mud. POOH. RU & run USIT log. 9Y17l2007 9/18/2007 Complete USIT logging run. RD SWS. Ria uo Test BOP'c MLl t,~~,t0~}5,3~~nly„ 9/18/2007 9!19/2007 Make up whipstock assmy, TIH, and set whipstock. Displace wet/ with 8.4 PPG OBM. Mill window, Circulate '.sweep until clean. Monitor well 9/19/2007 9/20/2007 POOH, Breakout & lay down Milling BHA. Flush BOP stack. Make up 8 1/2" Dulling BHA. TIH. Directional dhll from 10290' - 10442' MD. ND = 3185'. Observed 1000 PSI loss of pressure. Trouble shoot. POOH to surface ~`~.-`~ ~ r'~ `~~_~~ observing. Drilling jars twisted off. 9/20!2007 9!21/2007 MU Overshot fishing BHA, TIH ,Could not get'overshat assembly over top of whipstock. Repeat attempts. POOH, lay down BHA, MU Milling BHA, TIH to dress top of whipstock area until clean. Circulate a sweep around ',with increased cuttings, at surface. POOH. 9/21/2007 9/22/'2007 IMU Overshot fishing BHA, TIH, Tag & catch fish. pullover to verify, pump to gain MWD pulses. POOH, lay down BHA. 8~ fishing BHA. MU Reverse Circulating basket. TIH. Wash down to TD @ 10444'. 9/22/2007 9/23!2007 POOH, lay down Fishing BHA. MU 8 1/2" Drilling BHA, TIH. Continue drill D lateral from 10442' - 11267' MD. ND I = 3199'. ADT = 7.4 HRS. ' ~ 9/23/2007 ~ 9/24/2007 Directional Drill D lateral to 15232' MD. ND = 3171'. ADT = 15-64 HRS. Bit HRS=23.04_ ECD = 12.2 PPG 9!24/2007 9/25/2007 Directional Drill D lateral to 17444' MD. TVD = 3141'. ADT= 13.81 HRS. Bit Hrs = 36.85. ECD = 12:14 PPG 9/25/2007 9!26/2007 Directional Drill "D" laterai to TD @ 17820', circulate sweep and 3 BU, BROOH to 10339' @ midnight ~ 9/26/2007 9!27/2007 POOH w/ pumps f/ 10339' to above the window, pump 50 bbds weighted/hi vis sweep + 3 BU, monitor well, change out saver sub, se,vice rig, trip in on elevators to 10722', ream in to 15665`; circ 220 bbls, continue to ream to TD @ 17820', circ BU, pump sweep around plus a BU, displace to 8.6 ppg SF~BM, monitor well, POOH total of 3 stands HWDP, pump out of the hole to 16710' @ midnight. '9/27/2007 19/28/2007 Continue to pump out of the hole f/ 16710' to 10227', monitor well, circ a sweep, displace casing to 8.8 ppg ' SFOBM w/ 776 tube, POOH on elevators, UD BHA #16, clean floor, RU/Run 4-1/2" slotted liner f/ the "D" lateral ~ to 1705'. 9/28/2007 9/29/2007 ',Continue running 4-1/2" slotted liner f/ the "D" lateral f/ 1705' to ?194', rig down casing tools, RIH w/ liner on 5" 'drill pipe to 13567, rotate liner to TD (~ 17820', PU and put liner on depth, drop 29%32" ball pump to seat, release -.from liner, blow ball seat, POOH to wash the slot on the whipstock @ 10240'. CBU, monitor well, CBU, POOH 2 !,stands. monitor well, POOH w/ Baker running tools to 3356' @ midnight. ~9i29/2007 9/30/2007 (Continue POOH w/ Baker running tools from 3356', UD running tool, PU/MU/RIH with tools f/ retrieving Hook ' , slip and cut drilling line, RIH~enac~e whipstock, pull free, circ, monitor well, weight up to 8.9 Hanger to 10106 'ppg, shut top pipe rams w/ 20 psi on choke, teed-off, circ, monitor well, POOH to 10046', hole swabbing, circulate. 9/?0!2007 ',1011/2007 Mon'stor well, POOH grid try to free up whipstock assembly to pass fluid. work 10046' to 9955', finally started taking fluid. CBU, monitor well, POOH w/ Baker retieval hook and fish (,Whipstock assembly). L/D fishing tools to pipe shed, LSD whipstock assembly, PU fishing assembly, break and UD fshing assembly, clean foor, RU to test ', BOPS testing BOPS. set wear bushing, RU/RIH w/ "D" lat Hook hanger assembly, MU inner string. 110/1/2007 10/2/2007 MU inner sthng f/ Hook Hanger assembly, ohent MWD with the Baker Hook Hanger, R/D tongs and 2-318" handling tools, RIH one stand, shallow test MWD, RIH w/ hook hanger to above window (10162'), RIH and tag B lat no go, POOH, turn 90 deg, RIH and tag again, POOH turn 90 deg, RIH -out the window. Hook window @ ~ 10257', PU turn 180, slack off past, PU, Hook window @ 10257', pump ball down to release and inflate ECP, ECP I opened @ 2800 psi but could still circ, blow ball seat, POOH to 9928', circulateBU, monitor well, POOH w/ i ;running tools, UD running tools, clean floor, prepare to PU LEM. 'i ' Page 2/3 Report Printed: 11/9/20071 Daily Operations Summary Report 1J-176 Job: DRILLING ORIGINAL Ssrt Oac~ End DaL Last 24n~ Sum --`- ~ 10/2/2007 (10/3/2007 PJSM on picking up 4-1/2" LEM f/ the "D" lateral, PUiMU/RIH w/ LEM, shallow test, RIH on 5" dp to mule shoe i depth of 10496', latch in w/ final orientation of 21 right, pump down 29/32" ball, set Trorquemaster packer w/ top @ 10210', test to 2500 psi f/ 30 min, POOH to 10134', circulate and freshen up the SFOBM w/ 776 lubricant to 3%, pump a 20 bbls dry job, drop the Haggard ID wiper, POOH Laying down 5" drill pipe. Depth of 2800' @ i midnight. '10/312007 10/4;2007 C©ntinue to POOH Laying down 5" drill pipe f/ 2800', Break and L/D Baker running tools and inner string, remove super slider hardware and misc. from rig floor, clean floor, Pull Vetco wear bushing. RU to run 4-1/2" completion.. PJSNt, Pt)/RIH w' 4-1/2" 12-6 ppf L-80 IBT-m tubing. space gut and land same w/ BPV set. N/D/NU tree. 10/4/2007 10/5/2007 NU Vetco Gray 4-1/8" Horizontal injector tree, test hanger void low and high, test tree low and high, freeze protect by pumping down the 10-3/4" & 9-5/8" x 4-1 /2" to 2920' ,then "U" tubing 185 bbls diesel back to the 4-1/2" tubing, this should equalize @ 2592' MD (1992' TVD). Install BPV. secure well. Release rig @ 1500 hrs. Note: Layed down 5" dp f/ the derrick while freeze protecting and cleaning pits. Left 34 stands of 5" in the derrick w/ 2 stands of HWDP f/ next well Page 3/3 Report Printed: 11/9/2007 • ~~ r' - ~ ~~ ~ ~ C~ ~ ~ ~ SARAH PALI ~) N, GOVERNOR CQ~S~i~FA~O n ~~ 333 W. 7th AVENUE, SUITE 100 t.•~•Tu'ii-7a 01s ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert D. Christensen Production Engineer Technician Conoco Phillips Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-176 Sundry Number: 307-355 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisd~ day of November, ~~~, Encl. Sincerely, j ~l - ~'f,~ R~CEiV~D Q / ~ STATEI OF ALASKA ~ 2 DV 2DQ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APP'LICATIOI~ FO6'~ SUNDRY APPROV~N~ka Oil & Gas fans, Gommis$ion - 20 AAC 25.2so Anci~oraue 1. Type of Request: Abandon ^ ~ Suspend ^ ' Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram 9 Pp p 9 ^ Pull Tubing ^ Perforate New Pool ^ Re-enter S Producer to uspended Well ^ Injector 2. Oper2for Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 207-099 - 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 9910 50-029-23364-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: ..Spacing Exception Required? YeS ^ h!0^ 1J-176 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ALK 25661, 25662, 25663, 385172. RKB 121' ~ Kuparuk River Field l West Sak Oil Pool 12. PRESENT WELL C^"~!DiTat~N SUMIL~IARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17940' .~ 3202' 17880' 3206' C<^sing Length Size MD TVD Burst Collapse CONDUCTOR 120' 20" 120' 120' SURFACE 3671' 13-3/8" 3792' 2299' INTERMEDIATE 1959' 10-3/4" 2080' 1794' INTERMEDIATE 8920' 9-5/8" 11000' 3251' D-SAND WINDOW 1' 7-5/8" 10239' 3162' B-SAND SLOTTED LINER 7423' 5_1/2" 17880' 3206' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11046' - 1783T 3222' - 3260' 4-1/2" L-80 10219' Packers and SSSV Type: Packers and SSSV MD (ft) PKR =Baker Torquemaster 813-47, MLZXP Liner Top Pkr PKR = 10210', 10458' SSSV= NIP SSSV= 504' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Dec. 10, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name ob rt D. Christ SOtI Title: Production Engineering Technician Signature ~ Phone 659-7535 Date C®mmission Use OnSy Sundry Number: Conditions of approval: Notify Commission so that a representati ve may witness 3~ ~" 355 Plug. integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~~ t~,~~ ~, , - ~ 100% APPROVED BY R Approved by: TONER THE COMMISSION Date: J ! ~~0 Form 10-403 Revised 06/2006 `'~ ~~, ~ ~'~) (J ~ Submit in Duplicat 1J-176 DESCRIPTION SUMMti1RY O Fro u~;=, ConocoPhillips Alaska Inc. requests approval to begin` Water Injection service in West Sak Dual-lateral Well 1J-176. This well has been pre-produced for approximately 30 days in order to recover Oil based drilling fluids prior to putting the vveil on injection. 1J-17G wiil provide pressure support for the West Sak B sands. The 13-3/8" Surface casing (3792" and / 2299' tvd) was cemented with 800 sx Class G followed by 210 sx Class G. The 9-5/8" Intermediate casing (11000' and / 3251' tvd) was cemented with 921 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand Baker Torquemaster 813-47 packer located @ 10210' and / 3159' tvd, Upper 3 sand MLZXP 7" x 9- 5/8" Liner Tcp Packer Iccated @ 10458' and / 3'i ~~' tvd. The top of West Sak D sand was found at 10236' and /'3162' tvd. D sand Lateral window top is located @ 10238' and / 3162' tvd. The top of West Sak B sand was found at '10952' and / 3247' tvd. i j I c~ k 1 9 • • ConocoPhillips Alaska, Inc. KRU 1J-176 TUBING (0-10219, OD:4.500, ID:3.958) PBR ;10195-10213, OD:8.270) HANGER ;10237-10238, OD:8.500) PACKER ;10458-10479, OD:8.430) HANGER ;1oa7s-loaea, OD:8.300) 1J-176 API: 500292336400 Well Type: SVC Angle @ TS: d SSSV Type: NIPPLE Orig Com letion: 10/4/2007 Angle @ TD: 94 deg @ 17940 Annular Fluid: Last W/O: Rev Reason: NEW WELL Reference Lo : 43.32' RKB Ref L Date: Last U date: 11/2/2007 Last Ta TD: 17940 ftKB Last Ta Date: Max Hole An le: 94 d 17684 Casln Strin -ALL 3TI~NGS Descrfptfon Slze To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 120 120 94.00 . H-40 _ , WELDED I ~ SURFACE _ 13.375 0 3792 2298 68.00 L-80 BTC _ INTERMEDIATE 10.750 0 2080 1793 73.20 L-80 BTCM INTERMEDIATE 9.625 2080 11000 3251 40.00 L-80 BTCM D-SAND WINDOW 9.000 10238 10239 3162 0.00 B-SAND SLOTTED LINER ~ 5.500 10457 17880 3206 15.50 L-80 BTCM _ ~ Tubin Strin - TUBING I Size . _ Top Bottom TVD Wt _ _ _ _ Grade __ _ Thread __ 4.500 _ 0 . _ . 10219 _ _ __ 3160 12.60 L-80 IBTM Pertorations Summar r~ - - - Interval TV D Zone Status Ft SPF Date Type Comment - 11046 - 11498 _ 3254 - 3260 WS B 452 32 9/14/2007 Slots Entire Liner Alternating slotted/solid pipe 2.5" x .125" in 4 circumferential rows/ft 3" centers staggered 18 d , 3' non-slotted ends 11788 - 12239 3258 - 3254 WS B 451 32 9/14/2007 Slots 12520 - 12964 _ 3249 - 3247 WS B 444 32 9/14/2007 Slots 13246 - 13717 3247 - 3243 WS B 471 32 9/14/2007 Slots 14011 - 14479 3245 - 3243 WS B 468 32 9/14/2007 Slots 14780 - 15250 3243 - 3239 WS B 470 32 9/14/2007 Slots 15510 - 15985 3238 - 3243 WS B 475 32 9/14/2007 Slots 16241 - 16717 3241 - 3230 WS B 476 32 9/14/2007 Slots 16975 - 17365 3225 - 3227 WS B 390 32 9/14/2007 Slots __ 17621 - 17837 3222 - 3209 WS B 216 32 9/14/2007 Slots Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run _ Vlv Cmnt 1 2318 1902 CAMCO ~ KBMG DMY 1.0 BK-5 0.000 0 10/3/2007 Other lu s equi etc .1-COMPLETION ___ De th_ _TVD Type Descrfptfon __ _ _ _ ___ ID I I _. 1 36 36 HANGER VETCO GRAY TUBING HANGER 4.500 504 504 NIP CAMCO 'DB-6' NIPPLE w/3.875 NO GO PROFILE 3.875 10112 3146 SLEEVE-O BAKER CMD SLIDING SLEEVE w/CAMCO 3.812" DB PROFILE OPEN 3.812 10191 3156 LOCATOR BAKER LOCATOR/SEAL ASSEMBLY -SPACED 4' OFF PBR 3.880 10195 3157 PBR BAKER PBR 3.880 10210 3159 PACKER D-SAND BAKER TOROUEMASTER PACKER 813-47 3.950 10213 3159 ANCHOR SEAL BAKER ANCHOR SEAL ASSY CROSSOVERS/ML 3.860 10223 3160 HANGER D-SAND LEM ABOVE HOOK HANGER 3.960 10237 3162 HANGER D-SAND LEM INSIDE HOOK HANGER 7.510 Other luq s, equip. etc. - 6-SAND LINER DETAIL ! De th _ TVD . - Type -- Descrlptfon ID _ 10458 - 3189 _ _ PACKER - - B-SAND MLZXP LINER TOP PACKER 7.500 10479 3191 HANGER B-SAND FLEXLOCK LINER HANGER 6.190 10484 3192 XO Bushing B-SAND CROSSOVER BUSHING 7" TO 5.5" 4.850 10485 3192 SBE B-SAND 190-47 CASING SEAL BORE EXTENSION 4.750 17878 3206 SHOE B-SAND SILVER BULLET SHOE 0.000 General Notes Date .Note 10/4/2007 NOTE: MULTI-LATERAL WELL - 1J-176 B-SAND 1J-176L1 D-SAND a-©'Z -p~ I~'C=3ArIICAL INTEGRITY . ~~'QRT ~ ~ ~ c~O t~ °UD L_. _ ~ : x`.1'1 _'4`1 QPER ~ FIELD C~~S ~~:~ o~cJ~~. ~~'~~ -.c r~~~~..~.. i~~5-0~ hiLL NtTMEER 1S-\ '~~ -L'~ _~ ~ LL DA T ~_ TD : ?~.. '?'V~D ; ? BTD : ? iD I'VD i,~,si~g:~~g Shoe. ~~VOI~ ~ID 3~TVD; D~I. 1.11 ?~ tJl~ -?~r~ -==ie= • Shoe . '~ _~ ~1 -:~o - ~ '~ Packer 1c~a~D '~ ole S«e ~ ~~ ~~ and `?'STD ; .Cr . }-S~ .."r'D T'~TD; Sep ~~ ' PeTfs L~ wt tom IOaS'Z ~_ :."r'.~?~IC~.T, _NTEGR=TY - PART # %Eliiuli:S '-~reSS Test: _'~ ; 15 II1Il ; _iQ min Comments '.~'CHANIC~ ~. 1NTEGRT'I'`~ - PART #2 ~-~ 3~\ ~~~5 Ceslent Volumes :. Amt. Liner Cs~ ~,a~ ~~ DV ~~ e 3020 ~S v C.~t Jol to Cave= oer s ~,~ ~~~.s ~aa~l s1F~ ~'O COaIcC- ~~~ W~I~OV~ _~~ s Sip' _@ $O`ZA a ~ TCC ~~~1 Ces2ent Band Lag (Yes ar No)~,_; In AOGCC File~~~_ p ~ CBL `~plua o~x'~.b ~-~ ,• tot~~ -~ ne above per_s ~ ~~"-l0 tQ~ - ejOQv Production 'Log: '?'yve Evaluation i 3 { COI~C-LJSIOt1S : Part l I : . ? a r ~ f L : ~~ ~__.l 24-Oct-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-176 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 40.55' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 17,940.00' 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 ~'~ ~ ~:~"~ Si ned 0~~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~,i- ~~q ~.,,~k - Schlumbe~ger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/15/07 2N-343 (REDO) 11745232 MEM INJECTION PROFILE ~ G - 08108/07 1 16-14 11837493 PRODUCTION PROFILE 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE Q- 08/30107 1 1Y-18 11837499 PRODUCTION PROFILE C - 08130/07 1 1G-14 11839652 INJECTION PROFILE ~~, ~j- !_f 08/31107 1 1A-01 NIA USIT - 08131107 1 1Y-04 11839653 INJECTION PROFILE f'~ ~ 09101107 1 1Y-32 11839655 PRODUCTION PROFILE '~ - 09/02/07 1 2T-TAB-01 11839656 INJECTION PROFILE C - ~ 09/03/07 1 2K-25 11846439 INJECTION PROFILE (~ = f - 09/06/07 1 2K-18 11846440 INJECTION PROFILE t 09107/07 1 1B-18 11846441 PRODUCTION PROFILE ~ - (p 09/08107 1 2T-20 11846442 PRODUCTION PROFILE ~ '~ - 09/09107 1 2N-310 11850433 SONIC SCANNER 7~~-U 27 09116/07 1 2N-310 11850433 SONIC SCANNER-FMI "~ - C`~ (~ 09/16/07 1 1J-176 11846443 USIT "3 _p 09/17107 1 1E-29 NIA UCI f - ~ 09/19107 1 3F-21 11837503 RST/ WFL 09120107 1 2B-10 11839661 INJECTION PROFILE ~ - 09122107 1 1G-05 11837506 INJECTION PROFILE v=C 09123/07 1 2H-13 11839662 INJECTION PROFIL L - 09/23107 1 16-05 11837508 INJECTION PROFILE .;LL's . 09/24107 1 3H-08 11839663 PRODUCTION PROFILE - (~ 09/24107 1 1Y-31 11839664 PRODUCTION PROFILE ~ ~i - 09/25107 1 1G-06 11839665 INJECTION PROFILE 09/26/07 1 2Z-01A 11837512 USIT - ~ ( 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER ~~~ _ 09/28/07 1 1G-11 11837513 PRODUCTION PROFILE - 09/29/07 1 1Y-22 11837515 PRODUCTION PROFILE b 09/30/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. FW: 1J-176 USIT • • Maunder, Thomas E (DOA) Page 1 of 2 From: Maunder, Thomas E (DOA) ~~j`~,-~~~ Sent: Friday, September 21, 2007 2:43 PM To: 'Hartwig, Dennis D'; Davies, Stephen F (DOA); Davies, Stephen F (DOA); Regg, James B (DOA) Subject: RE: 1J-176 USIT Dennis, This confirms our discussion earlier today. I concur with the assessment of the USIT. Isolation of the West Sak was the primary goal of the operation and that appears to have been successfully accomplished. The Ugnu intervals, as noted, are generally wet but also do not have any energy to flow. Not raising the cement to as high as planned will not cause waste. I do not see a need to perform any remedial work. Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, September 17, 2007 7:12 PM To: Davies, Stephen F {DOA); Davies, Stephen F (DOA); Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) Subject: FW: 1J-176 USIT Gentlemen, Attached for your review is the recent cement bond log for the 1J-176 Intermediate casing. The top of the West Sak reservoir (West Sak D-Sand) is at approximately 10,236'MD. Unfortunately we were only able to get the SLB tractor conveyed USIT log down to around 10,110' MD. On the bright side, the log indicates excellent bond /isolation above the West Sak reservoir from 10,110'MD up to 9,130'MD. From 9,130'MD up to 7,800'MD we see indications of increased channeling with a very abrupt cement top at ~ 7,800'MD. The cement job went smoothly with full returns, and a subsequent FIT of 13.lppg. Planned top of cement was approximately 6,182'MD (500' above the Ugnu C) pumping 35% excess cement to attain the proper height. It is now apparent that we experienced more hole washout than normal and thus the top of cement deeper than planned. Normally we attempt to cover the UGNU sands plus 500' in order to meet the AOGCC requirements of covering significant hydrocarbon bearing zones or abnormally geo-pressured strata. However, in the case of the 1J-176, the Ugnu Intervals from 6,682'MD - 9,153'MD are generally wet. The only noticeable Hydrocarbon show in the Ugnu A appears at 8,900-8,930'MD (~STVD) but is not considered significant by our geology team. My question to the AOGCC -Does this cement job warrant remediation or a possible cement squeeze? I have contacted our CPAI wells group and am formulating a plan in the event that remediation is our plan forward. Due to the uncertainty of getting a good squeeze job combined with the risk of compromising the integrity of casing with perforations I am hopeful that further remediation is not necessary. I will contact you tomorrow morning to discuss the issue. 9/21/2007 Regg, James B (DOA) • Page 1 of 2 From: Grimaldi, Louis R (DOA) Sent: Sunday, September 16, 2007 9:39 AM ~q ~ ~ t~' d To: Regg, James B (DOA) ~ / Cc: Davies, Stephen F (DOA) Subject: RE: 1J-176 I spoke wi#h Mike Thornton again yesterday evening and op's went as described to me earlier. They tripped back in the hole and raised MW 2 points to 8.$, after a hole volume was pumped the well was silent. They conditioned the hole and were running liner. I think this was handled onsite as well as could be expected Lou From: Regg, James B (DOA) Sent: Friday, September 14, 2007 7:51 AM To: Grimaldi, Louis R (DOA) Subject: RE: iJ-176 Many people from our side involved; got a message from Steve Davies that described what you said - he was apparently contacted by Dennis Hartwig (engineer). Sounds like you have the best info and contact so keep tracking and let me know if you need some followup. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Grimaldi, Louis R (DOA) Sent: Thursday, September 13, 2007 5:46 PM To: Regg, James B (DOA) Subject: RE: 1J-176 I spoke with Mike Thornton @1300 hrs and got the infa !sent you. Sounds like somebody is out of the loop. From: Regg, James B (DOA) Sent: Thursday, September 13, 2007 3:35 PM To: Grimaldi, Louis R (DOA) Subject: RE: 1J-176 Thank you; I spoke with engineer this morning about the need to test BOPE after use. I was under the impression that the well was calm after raising MW and shutting in offset injector(s). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Grimaldi, Louis R (DOA) Sent: Thursday, September 13, 2007 1:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) 9ilsizoo~ ao~--c~~,9 • Page 2 of 2 Subject: iJ-176 Jim, I have been following a small incident on KRU 1 J-176 for the past couple of days. The early morning of the 12th Fred Herbert (night man) called to let us know that they had a little flow while they were out of the hole. There next step was a cleanout run in prep to run casing (production). Fred told me they would shut the well in and it would not build pressure but if they opened the well it would flow about 1 bbl/hour. We discussed the op's and he wanted to stage in open ended to circulate the well and weight up if necessary. We also discussed shutting in injectors local to their flank. 1 felt this was most likely the best scenario if monitered closely during their trip in. This was accomplished. I just got off the phone with Mike Thornton (day man) who let me know they were at the shoe and the well was still giving them fit's, flow is fluctuating 1.8 down to nothing and then back up again. At least one injector has been shut-in and freeze protected but that may take awhile to help if that is the problem. Mike said he was going to raise from 8.6 to 8.8 and try to get this stopped. He will stay in touch to let me know how things go. He will also be testing the pipes and annular when he comes out of the hole. If you need any more info let me know. Lou 9/18/2007 FW: Current Operations on Doyon 15 : iJ-176 • Maunder, Thomas E (DOAj From: Regg, James B (DOA) Sent: Thursday, September 13, 2007 4:59 PM To: Davies, Stephen F {DOA); Roby, David S (DOA); Foerster, Catherine P {DOA) Cc: Maunder, Thomas E (DOA) Subject: RE: Update: Current Operations on Doyon 15 and 1J-176 Page 1 of 3 Lou is in contact with company man on Doyon 15 and monitoring the situation. At least one of the offset injectors has been shut in. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Davies, Stephen F (DOA) Sent: Thursday, September 13, 2007 4:37 PM To: Regg, James B (DOA); Roby, David S (DOA); Foerster, Catherine P (DOA) Cc: Maunder, Thomas E (DOA) Subject: Update: Current Operations on Doyon 15 and 1J-176 FYI Dennis Hartwig phoned at 1:50 to say that 1J-176 started flowing again at a rate of about 1-1/4 bbls per hr. The well was shut in, and pressure increased to 10 psi over 30 minutes. CPAI is currently tripping into the hole to circulate and condition the mud and raise the weight from 8.6 to 8.8 ppg. I told him to call again if they have further problems. Steve D. From: Regg, James B (DOA) Sent: Thursday, September 13, 2007 9:58 AM To: Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: Current Operations on Doyon 15 : iJ-176 Called Dennis and told him testing is required Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Davies, Stephen F (DOA} Sent: Thursday, September 13, 2007 9:32 AM To: Regg, James B (DOA); Roby, David S (DOA) Subject: FW: Current Operations on Doyon 15 ; iJ-176 9/21 /2007 FW: Current Operations on Doyon i 5 : i J-176 Page 2 of 3 • Jim, Dennis Hartwig phoned with an update on 1J-176 and with a question you'll have to answer. Status: The tripped back to the TD of the well, raised the mud weight from 8.4 to 8.6, pumped out of the hole to casing shoe, and monitored the well. It is static. Question: Yesterday, when they shut in the well, they did it by closing the blind rams for 2-1/3 hours and had an 11 psi pressure build up. Now 20 AAC 25.035 (e)(9}(C) says that "if any BOP equipment components have been used for well control or other equivalent purpose, the components used must be function pressure tested, before the next wellbore entry, to the required working pressure specified in the approved permit to drill..." Dennis wants to know if this applies, since the pressure build up was only 11 psi. He apparently doesn't think this is worth testing the BOPE. Now that I read the regulation, seems perfectly clear to me. I don't see a way around the requirement to pressure test the BOPE. But I'm not an engineer, so I thought I'd run this by you. Am 1 missing something here? Do you want to contact Dennis, or should I? Let me know. He's at 265-6862. Thanks, Steve D. From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Thursday, September 13, 2007 9:19 AM To: Davies, Stephen F (DOA); Davies, Stephen F (DOA) Subject: FW: Current Operations on Doyon 15 : iJ-176 Steve, Attached is my original Email, I botched your Email address on the first attempt. We are currently inside intermediate casing at approximately 10,300'MD with an 8.6ppg mud weight. The well has been static for the last hour while the rig is cutting and slipping drill line. Regards... Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 9/21 /2007 FW: Current Operations on Doyon l5 : 1J-176 Page 3 of 3 • -----Original Message----- From: Hartwig, Dennis D Sent: Wednesday, September 12, 2007 5:39 PM To: Thomas Maunder'; 'steve.davies@admin.state.ak.us' Subject: Current Operations on Doyon 15 : iJ-176 Tom, Steve The lower B-Sand La#eral of the 1J-176 was drilled to a #otal depth of 17,940'MD on 9/8!2007. (Planned Depth of 17,733'MD) Subsequent operations which included; back reaming #o the intermediate casing shoe at 11,000'md, tripping back to bottom, displacing the well to 8.4 ppg solids free obm, pumping /tripping out of the hole and laying down the drilling BHA, all included periodic well monitoring with indications of s#a#ic hole conditions. While running in the hole with a SLB tractor conveyed USIT (9/10/07) the well began flowing at an average rate of 1.275 bbl/hr. The offset injector, 1 J-160, was shut-in as a precaution and the tractor was pulled. Over the last two days we have staged back in the hole circulating and conditioning the mud to a consistent 8.6ppg in and out. A# approximately 17:00 hrs #oday, after circulating on bottom with a consistent 8.6ppg MWI/MWO the well was monitored for approximately 1.5 hours. In the first hour, gains decreasing from 2.4 bbls down to 0.4 bbls were observed. The last 30 minutes no flow was observed and the well was static. We are currently pulling /pumping out of the hole. We are planning to monitor the well for ano#her leng#hy period at the intermediate shoe. Please contact me if any questions or concerns arise. Regards... Dennis Dennis Hartwig Drilling Engineer ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 9/21 /2007 r . Page 1 of 1 Mahnken,:Christine R (DOA) From: Davies, Stephen F (DOA) Sent: Wednesday, September 12, 2007 10:23 AM To: Foerster, Catherine P (DOA); Regg, James B (DOA); Roby, David S (DOA) . Cc: Mahnken, Christine R (DOA); Maunder, Thomas E (DOA) Subject: Slight flow encountered while logging KRU 1 J-176 All, (Christine -pledse file) Since Tom is out, Randy Thomas calved me to report a minor flow incident. CPAI experienced very minor flow from KRU 1 J-176 while running a tractor USIT log to evaluate the cement around the intermediate casing string. They noticed a 1 bbl per hour-flow fhat:was persistent. Theypulled the tractor out of the hole, circulated and conditioned the mud, and recovered some oil with solids. Offset injector 1J- 160, about 500' north, was on injection at the. time. CPAI believes #hat this slight flow is the result of toe-to-heel response to the injection. Injection was slopped in 1 J-160. They have 8.4 to 8.5 ppg oil-base mud in .the well. ...They plan.to bump.tke mud weigh# up to 8.5 tp 8.6 ppg and-run 5-.1 /2" slotted,liner: 1J-176 is planned as adual-lateral. They will drill the drill the D-sand lateral next. Randy will notify AOGCC if there are further problems with the well. Steve D. cc: Well. file 2070990 .. ,~a. G.. - i ., .tea,.... -•r'` <Ieo.:: r .. ~. F... .:: .~.. .. ~ t.,: _ • f o a a ~ ~ SARAH PAUN, GOVERNOR L>•i!A-7~ OII/ ~ ~7 333 W. 7th AVENUE, SUITE 100 C011TSERQ~7`I011T COl~'II~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage,. AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-176 ConocoPhillips Alaska, Inc. Permit No: 207-099 Surface Location: 1686' FSL, 2461' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1209' FNL, 1887' FWL, SEC. 15, T10N, 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). Si cerel , Dan T. Seamount Commissioner DATED this ~ day of July, 2007 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com ]une 8, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1J-176 and 1J-176 Li Dear Commissioners: ~~.~~/~® ..j~~ ~ ~ ~~~~ Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injection well, a horizontal well in the West Sak "B"and "D" sands. The main bore of the well will be designated iJ-176, and the lateral bore of the well will be designated iJ-176L1. We draw your attention to this well as it is different than wells in the immediate area. This well has a 10.75" x 9-5/8" tapered casing string. -- 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-176 is August 1, 2007. If you have any questions or require any further information, please contact Dennis Hartwig at 265-6862.. Sincerely, ~ -' Randy Thomas Greater Kuparuk Area Drilling Team Leader t ` _::- +..ur. ~ N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~~~ 20 AAC 25.005 ~J(~ U 3 zOQ7 ~~ ~ ~c7S !u®RS. ~OfirT11S$-0f1~^ 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 ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-176 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 17733' ~ TVD: 3206' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1686' FSL, 2461' FEL, Sec. 35, T11 N, R10E, UM - 7. Property Designation: 3gs'~?~ ADL 25661, 25662, 25663, ~•~ '7'i~West Sak Oil Pool Top of Productive Horizon: 333' FSL, 1833' FWL, Sec. 3, T10N, R10E, UM 8. Land Use Permit: ALK 471, 2177, 472, 2181 13. Approximate Spud Date: 8/1/2007 Total Depth: 1209' FNL, 1887' FWL, Sec. 15, T10N, R1 OE, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558751 y- 5945498 Zone- 4 10. KB Elevation (Height above GL): 121' AMSL ~ feet 15. Distance to Nearest Well within Pool: 1J-162L2 , 514' 16. Deviated wells: Kickoff depth: 250' ft. Maximum Hole Angle: 91° deg 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.035) Downhole: 1430 psig ~ Surface: 1062 psig 18. Casing Program S ifi ti Setting Depth Quantity of Cement Size pec ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" x 34" 94# K-55 Welded 80' 40' 40' 121' 121' 326 sx AS 1 16" 13-3/8" 68# L-80 BTC 3800' 40' 40' 3800' - 2298' ~ 700 sx AS Lite, 220 sx DeepCRETE 12.25" 10.75" 73.2# L-80 BTCM 2000' 40' 40' 2000' 1689' 870 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 8910' 2000' 1689' 10910' 3250' see above 8.5" 5.5" 15.5# L-80 BTC 7286' 10447' 3198' 17733' . 3206' , slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redril! and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee BOP Sketch ^ Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ~ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dennis Hartwig @ 265-6862 Printed Name Randy Thomas Title Drilling Team Leader Signature ~ Phone ~ ~6.t~ ~a Date ~ i'2~$ lD ha All u D ke Commission Use Only Permit to Drill Number: r ?~' API Number: S0- Q~i9~ ~ 33(p~-~ Permit Approval Date: ~ • 1 • ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: 30~ ~ye,;~ 17~ 6 ~~- Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [/~ Other: ~T "" mot, `` ~ H2S measures: Yes ^ No ~ Directional svy req'd: Yes [[]~ No ^ t b3 jv"~ ~t~lg' ci~*St r~ coi~nS, t`e5,v-cc~c . ~ 1}~Nw~ o ~CC-ty- `~ors~t• cacc~ "''/ A ~© t~ C~ APPROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ~'~=~/!~~ Submit in Duplicate ~li~J 7• /~'.o'? ~ation for Permit to Drill, Well 1 J-176 Revision No.O Saved: 8-Jun-07 Permit It -West Salo Well #1J-176 •~°~ r.~ i~ Application for Permit to Drill Document •,;~ f~laxell MpxirriizE tM~l l V41u e Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 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 Sun`ace Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil ease) ........................................................................... 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-176 PERMIT IT Page 1 of 8 Printed: 8-Jun-07 (1R161NAL • Ap ion for Permit to Drill, Well 1 J-176 Revision No.O Saved: 8-Jun-07 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 ....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 Attachment 5 1/4 Mile Radius Effect for Injector ......................................................................8 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as iJ-176. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained ,by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1,686' FSL, 2,461' FEL Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 121.0' AMSL - Northings: 5,945,498 Eastings: 558,751 Pad Elevation 81.0' AMSL - Location at Top of Productive Interval 333' FSL, 1,833' FWL, Section 03, T10N, R10E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 10 910' Northings: 5,938,820 Eastings: 552,545 Total Vertical De th RKB: 3,250' Total Vertical De th, SS: 3,129' Location at Total De th 1209' FNL 1,887' FWL, Section 15, T10N R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 17,733' Northings: 5,931,999 Eastings: 552,659 Total Vertical De th, RKB: 3,206' Total Vertical De th SS: 3 085' 1J-176 PERMIT IT Page 2 of 8 Printed: 8-Jun-07 ation for Permit to Drill, Well 1 J-176 Revision No.O Saved: 8-Jun-07 and (D) other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(6) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan iJ-176 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (HOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J- 176. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. If required both 10 3/4" and 9 5/8" Rams will be installed while running the tapered intermediate string. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identifred in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ area are 0.44 psi/ft, or 8.4 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 B sand formation is 1,062 psi, calculated thusly: MPSP = (3,250 ft TVD)(0.44 - O.il psi/ft) = 1,062 psi (e) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-176 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items; except for an item already on file with the commission and identified in the application: 1J-176 PERMIT IT Page 3 of 8 Printed: 8-Jun-07 ORIGINAL • Ap ion for Permit to Drill, Well 1J-176 Revision No.0 Saved: 8-Jun-07 (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); 1J-176 will be completed with a 10 3/a" x 9-5/8" tapered intermediate casing landed at the top of the West Sak B sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.O05(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ider.~tified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed, Casing and Cementing Program ,•~' «~ See also Attachment 3: Cement Summa Hole Top Btm CsglTbg Size Weigh Length MD/TVD MD/TVD OD (in) (in) f Ib/ft Grade Connection (ft) ft) (ft) Cement Program 20 x 34 40 94 K55 Welded 80 40 / 40 121 / 121 Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8 16 68 L-80 BTC 3,800 40 / 40 3,800 /2,298 700 sx ASLite Lead, 220 sx DeepCRETE Tail Top of tapered 10 3/a" x 9 5/8" 10 3/4 12-1/4 73.2 L-80 BTCM 2,000 40 / 40 2,000 / 1,689 See 9 5/8" Program in next row Cement Top planned @ 6,088' 9-5/8 12-1/4 40 L-80 BTCM 8,910 2,000 / 1,689 10,910 / 3,250 MD / 2,632' TVD. Cemented w/ 870 sx DeepCRETE ~ 5_1/2 81/2" B Sand 15.5 L-80 BTC 17,733 10,447 / 3,198 17,733 / 3,206 Slotted- no cement slotted Lateral (i]-176) 4-1 and 11.6 L- BTC 17,730 10,347 / 3,185 ,133 Slotted-no cemen slotted Lateral (1J-176 Ll) 7. Diverter System Information Requirements of 20 AAC 25.OO5(c)(7) An application for a ~°ermit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and d~sscription of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-176. 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 application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-176 PERMIT IT Page 4 of 8 Printed: 8-Jun-07 '~'~ • ~ation for Permit to Drill, Well 1J-176 Revision No.0 Saved: 8-Jun-07 Surface Hole Mud Program (extended bentonite) S ud to Base of Permafrost Base of Permafrost to 13-3/8" Casin 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 Viscostiy 20 45 15 20 (Ib/100 sfJ PH 8.5 9.0 8.5 9.0 API Filtrate NC 8 0 5 0 7 0 (cc / 30 min)) . . . Intermediate Hole Mud Program (LSND) 13-3/8" Cs Shoe to 9-5/8" Cs Point Value Density (ppg) 9.0 - 9.2 Funnel Viscosity 45 - 60 (seconds Plastic Viscostiy 12 - 18 (Ib/100 sf) Yield Point 26 - 35 (cP) API Filtrate 4 - 6 (cc / 30 min)) Chlorides (mg/q <500 pH 9.0 - 9.5 MBT <20.0 i Lateral Mud Program (MI VersaPro Mineral Oil Base) B & D sand laterals Value Densit (pg) 8.4 - 8.5 Plastic Viscostiy 15 - 25 (Ib/100 st) Yield Point 18 - 28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 70 / 30 Electrical 650 - 900 Stabilit .~ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application. for a Permit to Drill must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1J-176 PERMIT IT Page 5 of 8 Printed: 8-Jun-07 ORIGINAL • Ap ion for Permit to Drill, Well 1 J-176 Revision No.O Saved: 8-Jun-07 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (li) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061 (b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 121' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Install 21-1/4" Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,800' MD / 2,298' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP`s as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" bit and 8"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 9-5/8" casing point at 10,910' MD / 3,250' TVD, the prognosis top of the B sand. 9. Run 10 3/a" 73.2# L80 BTC Mod x 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 6,088' MD / 2,632' ND 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 10 3/a" packoff and test to 5000 psi. 11. Flush 13-3/8" x 10-3/4"/9-5/8"annulus with water, followed by diesel. 12. PU 8-1/2" PDC Bit and 6-3/4"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 8-1/2" lateral modeled to be less than 11.0 ppg). 14. Directionally drill 8-1/2" hole to TD at +/- 17,733' MD / 3,206' TVD as per directional plan. 1J-176 PERMIT IT Page 6 of 8 Printed: 8-Jun-07 ~ ~~ ~ ~~ ~ ; ~,~~Yl"~ ~. ~ % ' ~ ~ ~ation for Permit to Drill, Well 1J-176 Revision No.O Saved: 8-Jun-07 15. POOH, back reaming out of lateral to 9-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. Run USIT log to evaluate cement bond on intermediate casing. ~~;~g aeP~JC~. 17. PU and run 5-1/2"slotted liner. C 18. Land liner, set liner hanger @ +/- 10,447' MD / 3,198' ND. POOH. Note: Remaining operations are covered under the 1J-176L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 10,347' MD / 3,185' TVD, the top of the D sand. ~,20. Mill 8-1/2" window. POOH. ^bv 21. Pick up 8-1/2~"drilling assembly with LWD and MWD and PWD. RIH. ~, 22. Drill to TD of sand lateral at +/- 17,730' MD / 3,185' 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. RIH and set Seal Bore diverter 26. PU and run 4-1/2" slotted liner with Baker Oil Tools RAM Hangar system. 27. RIH, rotate self orienting liner hanger into window and land hanger. 28. Release hanger running tool. POOH. 29. 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. 30. POOH, laying down drill pipe as required. 31. PU injection completion and RIH to depth. Land tubing. Set BPV. 32. Nipple down BOPE, nipple up tree and test. Pull BPV. 33. Freeze protect well with diesel. 34. Set BPV and move rig ofF. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 1J-176 PERMIT IT Page 7 of 8 Printed: 8-Jun-07 ORIGINAL • 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic Attachment 5 % Mile Radius Effect for Injector Ation for Permit to Drill, Well 1 J-176 Revision No.O Saved: 8-Jun-07 1J-176 PERMIT IT Page 8 of 8 Printed: 8-Jun-07 ~'~!` .. ~'.~» .~ + r _b _,., ConocoPhillips Alaska C] Plan: 1J-176 (wp05) Sperry Drilling Services Proposal Report -Geographic 06 June, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-176 (Q2 Phase 2) 1J-176 Local Coordinate Origin Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-176 (02 Phase 2) Doyon 15 @ 121.OOft (D15 (40+81)) N True API - US Survey Feet Il-tp-I~L1IB TN Sperry Drilling Services ~41,INAL HALLIBURTON Sperry Drilling Services -2500 -2000 -1500 -1000 -500 ANNOTATIONS TVD MD Annotation 40.00 40.00 SHL @ 1686' FSL, 2461' FEL-Sec35-T11N-R10E 3250.61 10910.63 9 5/8" @ 10910' MD, 3251' TVD: 333' FSL, 1833' FWL-Sec 3-T10N-R10E 3206.30 17733.59 BHL @ 17734' MD, 3206' TVD: 1209' FNL, 1887' FWL-Sec 15-T10N-R10E Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-176 (Q2 Phase Wellbore: 1 J-176 Plan: 1 J-176 (wp05) WELL DETAILS: Plan IJ-17G (Q2 Phase 2) NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level: g1.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945498.05 558750.89 70°15'42.ll4N 149°31'30.239W SHL @ 1686' FSL, 2461' FEL-Sec35-T11 N-R10E ~0° c_ 500 0 t~ 1000 1500 2000 i` ~ 2500 F- 3000 3500 5500 6000 \\~~ j SA FORMATION TOP DETAILS No. TVDPath TVDSS MDPath Formation 1 1537.22 1416.22 1729.59 Pfrost 2 1640.92 1519.92 1905.30 T3 3 1935.14 1814.14 2686.23 K15 4 2143.69 2022.69 3326.80 T3+550 5 2696.91 2575.91 6588.15 Ugnu C 6 2856.85 2735.85 7796.50 Ugnu E3 7 2944.79 2823.79 8460.90 Ugnu A 8 3078.45 2957.45 9492.66 K 13 9 3185.20 3064.2 10347.37 W Sak D 10 3231.26 3110.26 10719.10 W Sak C 11 3248.00 3127 10880.63 W Sak B CASING DETAILS No MD TVD TVDss Name Size+ 1 3806.92 2300.00 2179 13 3/8" 13-3/ 2 10910.63 3250.61 3129.61 9 5/8" 9-5/8 3 17733.59 3206.30 3085.3 51/2" 5-1/2 200p0 Pfrost 3p 0 O ~~ O T3 D _ - - -_ _ _ - ti,~o ho° 0 --- `~ 9 5/8" @ 10910' MD, 3251' TVD: 333' FSL, 1833' FWL-Sec 3-T10N-R10E K15 ' --- -- ~o° o _'~-~-o---- -- - ~ -- - ------ ----~------- ---------- ----------------- --- T3+550 c ~ o° o0 0 _ ~ - _ _ - - - - - - _ - - _ _ _ - - - - - - - - _ - ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - - - - - O Q _O _ _ ~ ~ ~ 0 T Ugnu C . to h 13 3/8„ ' ~ `o ~ o ~ o ~ ~ p t oo ~ o° t o ~ ~ ~ - ------ =--'UgnuA- - - --------------- - - - - - - - ---- - - - - --- ----~-vii-_--cry-ur-- o---------------r-----------------------------~ - - - - - - - - - -^- ~ s - - - - - --K13-- - - - - - - - - - --------------- ---- w ~ -r A - - - - - - - - - - ~ - - - - - - - ---------- -- -- ~ - - -- - - - - - - - - - ~r -- - - -= = coon _ kD - =WS --------------- ---- -o~_ ~o ------°_______°=_=--~ o o ~ ~ o o ~-- ~ -=~- -- o W\ a o o ~ °0 0 0 .- ~ 0 0 0 0 0 0 0 o a r ` WSakC o o W Sak B 5 1/2"' 6500 iii~iiiiiiiiiiii~iiii~iiii~~~~~~~~~~~~~~~~~~~~~ ~~~ !500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 Vertical Section at 180.00° (1500 ft/in) ConocoPhillips Alaska HALt_iBURT®N Sperry Grilling Services abject: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-176 (Q2 Phase Wellbore: 1 J-176 Plan: 1 J-176 (wp05) YELL DETAILS: Fi176 (02 Phase ®~D 1927 (NADCON CONUS) Alaska Zone 04 7 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945498.05 558750.8970°15'42.114N149°31'30.239W REFERENCE INFORMATION Co-ordinate (N/E) Reference: well Plan 1J-t 7s (oz Fnase z>, True Nortn Vertical (TVD) Reference: ooyon 1s @ 12toon (ots (4o+s1)) Measured Depth Reference: ooyon 15 ~ 1zt.ooa (ots (ao+at)) Calculation Method: Minimum Curvature SHL, @ 1686' FS4 2461' FEI--Sec35-TI IN-RI OE _2 O u, t` t t C 7O C L 7 O 9 5/S" CASING DETAILS No MD TVD TVDss Name Size 1 3806.92 2300.00 2179 13 3/8" 13-3/8 210910.63 3250.61 3129.61 9 5/8" 9-5/8 317733.59 3206.30 3085.3 5 1/2" 5-1 /2 ANNOTATIONS on 1686' FSL, 2461' FEL-Sec35-T11N-R10E ~ 10910' MD, 3251' TVD: 333' FSL, 1833' FWL-Sec 3-T10N-R10E 17734' MD, 3206' TVD: 1209' FNL, 1887' FWL-Sec 15-T10N-R10 -1 VJVV -11200 -11900 -12600 5 I/2" -13300 1 . ~~~~ I J-176 (wp05) T M Azimuths to True North Magnetic North: 23.49° Magnetic Field Strength:57622.OnT Dip Angle: 80.82° Date: 6!4/2007 Model: BGGM2006 -7700 -7000 -6300 -5600 -4900 -4200 -3500 -2800 -2100 -1400 -700 0 700 1400 ~~ West(-)/East(+) (1750 ft/in) Cono~oPh~~~~p5 ,~'. ~':ISr;;.3 ORIGINAL ~-' Halliburton Company ConocoPhillips Compass Proposal Report -Geographic Alaska HALLIBURTON Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Methodt" Minimum Curvature Wellbore: 1J-176 Design: 1J-176 (wp05) Project _a, Kuparuk River Unit. North Slope Alaska, U nited States Map System: Geo Datum: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) System Datum: Mean Sea Level Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-176 ~(~2 Phase 2) Well Position +N/-S 0.00 ft Northing: 5,945,498.05ft Latitude: 70° 15' 42.114" N +E/-W 0.00 ft Easting: 558,750.89 ft Longitude: 149° 31' 30.239" W Position Uncertainty O.OOft Wellhead Elevation: ft Ground Level: 81.OOft WeHbore-., 1J-176 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2006 6/4/2007 23.49 80.32 57,622 Design 1J-176 (wp05) g Audit Notes: Version: Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (TVD) +Ni-S +E/-W Direction (ft) (ft) (ft) (°1, 40.00 0.00 0.00 180.00 6/6/2007 6:55:59PM Page 2 of 12 COMPASS 2003.11 Build 48 ORIGI~!9!- COt'IOCO~'11~~1E35 Halliburton Company HLLi URTN ~~~ Compass Proposal Report -Geographic gp®rry Drilling Services Database: Sperry EDM .11 Local Co-ordinate Reference: '' Well Plan 1J-176 (02 Phase 2) Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (02 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-176 Design: 1J-176 (wp05) Plan Summary Measured Dogleg Build Turn .Depth Inclination Azimuth ND TVDSS +N/-S +E/_yy Rate Rate Rate TFO (ft) (`) (°) (ft) (ft) (ft) (ft) (°l14©ft) ('1140ft) (°/100ft) (') 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 9.00 225.00 598.77 477.77 -16.63 -16.63 3.00 3.00 0.00 225.00 1,669.44 51.78 225.00 1,500.00 1,379.00 -390.34 -390.34 4.00 4.00 0.00 0:00 1,769.44 51.78 225.00 1,561.87 1,440.87 -445.89 -445.89 0.00 0.00 0.00 0.00 2,263.69 71.00 230.31 1,797.58 1,676.58 -735.27 -766.17 4.00 3.89 1.07 15.00 3,806.92 71.00 230.31 2,300.00 2,179.00 -1,667.08 -1,889.05 0.00 0.00 0.00 0.00 4,102.35 82.39 233.54 2,367.88 2,246.88 -1,843.91 -2,115.09 4.00 3.86 1.09 15.81 8,434.14 82.39 233.54 2,941.25 2,820.25 -4,395.45 -5,568.39 0.00 0.00 0.00 0.00 10,060.58 82.88 179.38 ~ 3,149.66 3,028.66 -5,786.40 -6,260.54 3.30 0.03 -3.33 -89.48 10,347.37 82.88 179.38 3,185.20 3,064.20 -6,070.96 -6,257.46 0.00 0.00 0.00 0.00 10,380.32 82.88 180.38 3,189.28 3,068.28 -6,103.65 -6,257.39 3.00 0.00 3.02 90.04 10,752.52 82.88 180.38 3,235.40 3,114.40 -6,472.97 -6,259.81 0.00 0.00 0.00 0.00 10,830.45 85.00 179.38 3,243.63 3,122.63 -6,550.46 -6,259.64 3.00 2.72 -1.28 -25.12 10,880.63 85.00 179.38 3,248.00 3,127.00 -6,600.45 -6,259.10 0.00 0.00 0.00 0.00 10,910.63 85.00 179.38 3,250.62 3,129.62 -6,630.33 -6,258.78 0.00 0.00 0.00 0.00 11,062.32 90.91 178.02 3,256.02 3,135.02 -6,781.82 -6,255.34 4.00 3.90 -0.90 -12.96 11,156.29 90.91 178.02 3,254.52 3,133.52 -6,875.72 -6,252.10 0.00 0.00 0.00 0.00 11,208.91 90.11 179.38 3,254.05 3,133.05 -6,928.32 -6,250.90 3.00 -1.53 2.58 120.60 11,808.91 90.11 179.38 3,252.90 3,131.90 -7,528.29 -6,244.41 0.00 0.00 0.00 0.00 11,873.58 90.71 179.62 3,252.44 3,131.44 -7,592.95 -6,243.85 1.00 0.93 0.37 21.86 12,909.21 90.71 179.62 3,239.60 3,118.60 -8,628.48 -6,236.99 0.00 0.00 0.00 0.00 12,979.69 89.65 179.62 3,239.38 3,118.38 -8,698.96 -6,236.53 1.50 -1.50 0.00 -179.93 13,809.41 89.65 179.62 3,244.40 3,123.40 -9,528.64 -6,231.02 0.00 0.00 0.00 0.00 13,896.84 90.53 179.61 3,244.26 3,123.26 -9,616.07 -6,230.43 1.00 1.00 -0.01 -0.66 15,109.73 90.53 179.61 3,233.10 3,112.10 -10,828.88 -6,222.16 0.00 0.00 0.00 0.00 15,166.34 91.09 179.59 3,232.30 3,111.30 -10,885.48 -6,221.76 1.00 1.00 -0.04 -2.32 16,309.19 91.09 179.59 3,210.50 3,089.50 -12,028.10 -6,213.51 0.00 0.00 0.00 0.00 16,407.72 90.14 179.35 3,209.44 3,088.44 -12,126.61 -6,212.60 1.00 -0.97 -0.24 -166.28 17,733.60 90.14 179.35 3,206.30 3,085.30 -13,452.40 -6,197.62 0.00 0.00 0.00 0.00 6/6/2007 6:55:59PM Page 3 of 12 COMPASS 2003.11 Build 48 '?4!GINAL ti-' Halliburton Company HALLIBURTON ConocoPhillips Compass Proposal Report -Geographic glass Sperry Drilling S®rvices Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1 J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-176 Design: 1J-176 (wp05j Planned Survey LI-176 (wp05) Map Map MD Incl Azimuth ND (ft) TVDSS +N/S +E/-W Northing Easting DLSEV Vert Section (ftl (°) (°) (ft) (ft} (ft) (ft) (ft) (`7100ft) (ft) 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 5,945,498.05 558,750.89 0.00 0.00 SHL @ 1686' FSL, 2461' FEL-Sec35-T11N-R10E 100.00 0.00 0.00 100.00 -21.00 0.00 0.00 5,945,498.05 558,750.89 0.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 0.00 5,945,498.05 558,750.89 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 5,945,498.05 558,750.89 0.00 0.00 400.00 3.00 225.00 399.95 278.95 -1.85 -1.85 5,945,496.19 558,749.05 3.00 1.85 500.00 6.00 225.00 499.63 378.63 -7.40 -7.40 5,945,490.60 558,743.55 3.00 7.40 600.00 9.00 225.00 598.77 477.77 -16.63 -16.63 5,945,481.30 558,734.40 3.00 16.63 700.00 13.00 225.00 696.91 575.91 -30.12 -30.12 5,945,467.70 558,721.01 4.00 30.12 800.00 17.00 225.00 793.48 672.48 -48.41 -48.41 5,945,449.26 558,702.86 4.00 48.41 900.00 21.00 225.00 888.02 767.02 -71.43 -71.43 5,945,426.07 558,680.03 4.00 71.43 1,000.00 25.00 225.00 980.05 859.05 -99.05 -99.05 5,945,398.24 558,652.62 4.00 99.05 1,100.00 29.00 225.00 1,069.13 948.13 -131.15 -131.15 5,945,365.89 558,620.78 4.00 131.15 1,200.00 33.00 225.00 1,154.83 1033.83 -167.56 -167.56 5,945,329.20 558,584.66 4.00 167.56 1,300.00 37.00 225.00 1,236.73 1115.73 -208.11 -208.11 5,945,288.34 558,544.43 4.00 208.11 1,400.00 41.00 225.00 1,314.43 1193.43 -252.60 -252.60 5,945,243.51 558,500.29 4.00 252.60 1,500.00 45.00 225.00 1,387.55 1266.55 -300.82 -300.82 5,945,194.93 558,452.46 4.00 300.82 1,600.00 49.00 225.00 1,455.73 1334.73 -352.52 -352.52 5,945,142.83 558,401.17 4.00 352.52 1,669.44 51.78 225.00 1,500.00 1379.00 -390.34 -390.34 5,945,104.71 558,363.64 4.00 390.34 1,700.00 51.78 225.00 1,518.91 1397.91 -407.32 -407.32 5,945,087.60 558,346.80 0.00 407.32 1,729.59 51.78 225.00 1,537.22 1416.22 -423.76 -423.76 5,945,071.04 558,330.49 0.00 423.76 Pfrost 1,769.44 51.78 225.00 1,561.87 1440.87 -445.89 -445.89 5,945,048.74 558,308.53 0.00 445.89 1,800.00 52.96 225.40 1,580.53 1459.53 -462.95 -463.07 5,945,031.55 558,291.49 4.00 462.95 1,900.00 56.83 226.61 1,638.03 1517.03 -519.75 -521.92 5,944,974.30 558,233.09 4.00 519.75 1,905.30 57.04 226.67 1,640.92 1519.92 -522.79 -525.15 5,944,971.23 558,229.88 4.01 522.79 T3 2,000.00 60.72 227.73 1,689.86 1568.86 -577.86 -584.63 5,944,915.71 558,170.84 4.00 577.86 2,100.00 64.61 228.76 1,735.77 1614.77 -637.00 -650.90 5,944,856.06 558,105.05 4.00 637.00 2,200.00 68.51 229.72 1,775.54 1654.54 -696.88 -720.39 5,944,795.64 558,036.03 4.00 696.88 2,263.69 71.00 230.31 1,797.58 1676.58 -735.27 -766.17 5,944,756.90 557,990.55 4.00 735.27 2,300.00 71.00 230.31 1,809.40 1688.40 -757.19 -792.59 5,944,734.77 557,964.31 0.00 757.19 2,400.00 71.00 230.31 1,841.95 1720.95 -817.57 -865.35 5,944,673.83 557,892.03 0.00 817.57 2,500.00 71.00 230.31 1,874.51 1753.51 -877.95 -938.11 5,944,612.89 557,819.74 0.00 877.95 2,600.00 71.00 230.31 1,907.07. 1786.07 -938.33 -1,010.88 5,944,551.95 557,747.46 0.00. 938.33 2,686.23 71.00 230.31 1,935.14 1814.14 -990.40 -1,073.62 5,944,499.40 557,685.14 0.00 990.40 K15 2,700.00 71.00 230.31 1,939.62 1818.62 -998.71 -1,083.64 5,944,491.01 557,675.18 0.00 998.71 2,800.00 71.00 230.31 1,972.18 1851.18 -1,059.09 -1,156.40 5,944,430.07 557,602.90 0.00 1,059.09 2,900.00 71.00 230.31 2,004.74 1883.74 -1,119.48 -1,229.16 5,944,369.13 557,530.62 0.00 1,119.48 3,000.00 71.00 230.31 2,037.29 1916.29 -1,179.86 -1,301.92 5,944,308.19 557,458.34 0.00 1,179.86 3,100.00 71.00 230.31 2,069.85 1948.85 -1,240.24 -1,374.68 5,944,247.25 557,386.06 0.00 1,240.24 3,200.00 71.00 230.31 2,102.41 1981.41 -1,300.62 -1,447.44 5,944,186.30 557,313.78 0.00 1,300.62 3,300.00 71.00 230.31 2,134.96 2013.96 -1,361.00 -1,520.21 5,944,125.36 557,241.49 0.00 1,361.00 3,326.80 71.00 230.31 2,143.69 2022.69 -1,377.18 -1,539.71 5,944,109.03 557,222.12 0.00 1,377.18 T3+550 6/6/2007 6:55:59PM Page 4 of 12 COMPASS 2003.11 Build 48 ~OC1000~~~~1~?5 Halliburton Company HAt_LIBURTON Alaska Compass Proposal Report -Geographic gperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-176 Design: 1J-176 (wp05) Planned Survey 1J-176 (wp05) Map Map MD Incl Azimuth ND (ft) TVDSS +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (~') (ft) (ft) (ft) 1ft) (ft) (°1100ft) (ftl 3,400.00 71.00 230.31 2,167.52 2046.52 -1,421.38 -1,592.97 5,944,064.42 557,169.21 0.00 1,421.38 3,500.00 71.00 230.31 2,200.08 2079.08 -1,481.76 -1,665.73 5,944,003.48 557,096.93 0.00 1,481.76 3,600.00 71.00 230.31 2,232.63 2111.63 -1,542.14 -1,738.49 5,943,942.54 557,024.65 0.00 1,542.14 3,700.00 71.00 230.31 2,265.19 2144.19 -1,602.52 -1,811.25 5,943,881.60 556,952.37 0.00 1,602.52 3,800.00 71.00 230.31 2,297.75 2176.75 -1,662.90 -1,884.01 5,943,820.66 556,$80.09 0.00 1,662.90 3,806.92 71.00 230.31 2,300.00 2179.00 -1,667.08 -1,889.05 5,943,816.45 556,875.09 0.00 1,667.08 13 3I8" 3,900.00 74.58 231.36 2,327.53 2206.53 -1,723.21 -1,957.98 5,943,759.78 556,806.60 4.00 1,723.21 4,000.00 78.44 232.45 2,350.85 2229.85 -1,783.18 -2,034.50 5,943,699.22 556,730.55 4.00 1,783.18 4,100.00 82.30 233.52 2,367.57 2246.57 -1,842.52 -2,113.22 5,943,639.28 556,652.32 4.00 1,842.52 4,102.35 82.39 233.54 2,367.88 2246.88 -1,843.91 -2,115.09 5,943,637.88 556,650.45 4.00 1,843.91 4,200.00 82.39 233.54 2,380.81 2259.81 -1,901.42 -2,192.93 5,943,579.76 556,573.07 0.00 1,901.42 4,300.00 82.39 233.54 2,394.05 2273.05 -1,960.33 -2,272.65 5,943,520.24 556,493.82 0.00 1,960.33 4,400.00 82.39 233.54 2,407.28 2286.28 -2,019.23 -2,352.37 5,943,460.72 556,414.57 0.00 2,019.23 4,500.00 82.39 233.54 2,420.52 2299.52 -2,078.13 -2,432.09 5,943,401.21 556,335.32 0.00 2,078.13 4,600.00 82.39 233.54 2,433.75 2312.75 -2,137.04 -2,511.81 5,943,341.69 556,256.07 0.00 2,137.04 4,700.00 82.39 233.54 2,446.99 2325.99 -2,195.94 -2,591.53 5,943,282.17 556,176.81 0.00 2,195.94 4,800.00 82.39 233.54 2,460.23 2339.23 -2,254.84 -2,671.25 5,943,222.65 556,097.56 0.00 2,254.84 4,900.00 82.39 233.54 2,473.46 2352.46 -2,313.74 -2,750.97 5,943,163.14 556,018.31 0.00 2,313.74 5,000.00 82.39 233.54 2,486.70 2365.70 -2,372.65 -2,830.69 5,943,103.62 555,939.06 0.00 2,372.65 5,100.00 82.39 233.54 2,499.94 2378.94 -2,431.55 -2,910.41 5,943,044.10 555,859.81 0.00 2,431.55 5,200.00 82.39 233.54 2,513.17 2392.17 -2,490.45 -2,990.13 5,942,984.59 555,780.56 0.00 2,490.45 5,300.00 82.39 233.54 2,526.41 2405.41 -2,549.35 -3,069.85 5,942,925.07 555,701.31 0.00 2,549.35 5,400.00 82.39 233.54 2,539.64 2418.64 -2,608.26 -3,149.57 5,942,865.55 555,622.06 0.00 2,608.26 5,500.00 82.39 233.54 2,552.88 2431.88 -2,667.16 -3,229.29 5,942,806.03 555,542.81 0.00 2,667.16 5,600.00 82.39 233.54 2,566.12 2445.12 -2,726.06 -3,309.01 5,942,746.52 555,463.56 0.00 2,726.06 5,700.00 82.39 233.54 2,579.35 2458.35 -2,784.96 -3,388.73 5,942,687.00 555,384.31 0.00 2,784.96 5,800.00 82.39 233.54 2,592.59 2471.59 -2,843.87 -3,468.45 5,942,627.48 555,305.06 0.00 2,843.87 5,900.00 82.39 233.54 2,605.83 2484.83 -2,902.77 -3,548.17 5,942,567.97 555,225.81 0.00 2,902.77 6,000.00 82.39 233.54 2,619.06 2498.06 -2,961.67 -3,627.89 5,942,508.45 555,146.56 0.00 2,961.67 6,100.00 82.39 233.54 2,632.30 2511.30 -3,020.58 -3,707.61 5,942,448.93 555,067.31 0.00 3,020.58 6,200.00 82.39 233.54 2,645.53 2524.53 -3,079.48 -3,787.33 5,942,389.41 554,988.06 0.00 3,079.48 6,300.00 82.39 233.54 2,658.77 2537.77 -3,138.38 -3,867.05 5,942,329.90 554,908.81 0.00 3,138.38 6,400.00 82.39 233.54 2,672.01 2551.01 -3,197.28 -3,946.77 5,942,270.38 554,829.56 0.00 3,197.28 6,500.00 82.39 233.54 2,685.24 2564.24 -3,256.19 -4,026.49 5,942,210.86 554,750.31 0.00 3,256.19 6,588.15 82.39 233.54 2,696.91 2575.91 -3,308.11 -4,096.76 5,942,158.40 554,680.45 0.00 3,308.11 UgRU C 6,600.00 82.39 233.54 2,698.48 2577.48 -3,315.09 -4,106.21 5,942,151.35 554,671.06 0.00 3,315.09 6,700.00 82.39 233.54 2,711.72 2590.72 -3,373.99 -4,185.93 5,942,091.83 554,591.81 0.00 3,373.99 6,800.00 82.39 233.54 2,724.95 2603.95 -3,432.89 -4,265.65 5,942,032.31 554,512.56 0.00 3,432.89 6,900.00 82.39 233.54 2,738.19 2617.19 -3,491.80 -4,345.37 5,941,972.79 554,433.31 0.00 3,491.80 7,000.00 82.39 233.54 2,751.42 2630.42 -3,550.70 -4,425.09 5,941,913.28 554,354.06 0.00 3,550.70 7,100.00 82.39 233.54 2,764.66 2643.66 -3,609.60 -4,504.81 5,941,853.76 554,274.81 0.00 3,609.60 7,200.00 82.39 233.54 2,777.90 2656.90 -3,668.51 -4,584.53 5,941,794.24 554,195.56 0.00 3,668.51 7,300.00 82.39 233.54 2,791.13 2670.13 -3,727.41 -4,664.25 5,941,734.73 554,116.30 0.00 3,727.41 7,400.00 82.39 233.54 2,804.37 2683.37 -3,786.31 -4,743.97 5,941,675.21 554,037.05 0.00 3,786.31 7,500.00 82.39 233.54 2,817.60 2696.60 -3,845.21 -4,823.69 5,941,615.69 553,957.80 0.00 3,845.21 7,600.00 82.39 233.54 2,830.84 2709.84 -3,904.12 -4,903.41 5,941,556.17 553,878.55 0.00 3,904.12 6/6/2007 6:55:59PM Page 5 of 12 COMPASS 2003.11 Build 48 ORIGINAL / Halliburton Company HALLIBURTON ConocoPhillips Compass Proposal Report -Geographic glass Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference:' Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 cQ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Referent®: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1 J-176 (Q2 Phase 2) Survey Calculation Method: .Minimum Curvature Wellbore: 1 J-176 Design: 1J-176 (wpUS;~ Planned Survey 1 J-1 ; 6 iwp05) Map Map MD. Intl Azimuth TVD (ft) TYDSS +N/-S +Ei-W Northing Easting pLSEV Vert Section (ft) (°) (') (ft) (ft) (ft) (ft) (ft) (°1100ft) Iftl 7,700.00 82.39 233.54 2,844.08 2723.08 -3,963.02 -4,983.13 5,941,496.66 553,799.30 0.00 3,963.02 7,796.50 82.39 233.54 2,856.85 2735.85 -4,019.86 -5,060.06 5,941,439.22 553,722.83 0.00 4,019.86 Ugnu B 7,800.00 82.39 233.54 2,857.31 2736.31 -4,021.92 -5,062.85 5,941,437:14 553,720.05 0:00 4,021.92 7,900.00 82.39 233.54 2,870.55 2749.55 -4,080.82 -5,142.57 5,941,377.62 553,640.80 0.00 4,080.82 8,000.00 82.39 233.54 2,883.79 2762.79 -4,139.73 -5,222.29 5,941,318.11 553,561.55 0.00 4,139.73 8,100.00 82.39 233.54 2,897.02 2776.02 -4,198.63 -5,302.01 5,941,258.59 553,482.30 0.00 4,198.63 8,200.00 82.39 233.54 2,910.26 2789.26 -4,257.53 -5,381.73 5,941,199.07 553,403.05 0.00 4,257.53 8,300.00 82.39 233.54 2,923.49 2802.49 -4,316.43 -5,461.45 5,941,139.55 553,323.80 0.00 4,316.43 8,400.00 82.39 233.54 2,936.73 2815.73 -4,375.34 -5,541.17 5,941,080.04 553,244.55 0.00 4,375.34 8,434.14 82.39 233.54 2,941.25 2820.25 -4,395.45 -5,568.39 5,941,059.72 553,217.49 0.00 4,395.45 8,460.90 82.40 232.65 2,944.79 2823.79 -4,411.38 -5,589.60 5,941,043.63 553,196.41 3.30 4,411.38 Ugnu A .8,500.00 82.41 231.35 2,949.96 2828.96 -4,435.24 -5,620.14 5,941,019.53 553,166.06 3.30 4,435.24 8,600.00 82.44 228.02 2,963.13 2842.13 -4,499.37 -5,695.71 5,940,954.82 553,091.00 3.30 4,499.37 8,700.00 82.47 224.69 2,976.26 2855.26 -4,567.78 -5,767.44 5,940,885.85 553,019.82 3.30 4,567.78 8,800.00 82.50 221.36 2,989.33 2868.33 -4,640.25 -5,835.07 5,940,812.86 552,952.76 3.30 4,640.25 8,900.00 82.53 218.03 3,002.35 2881.35 -4,716.53 -5,898.38 5,940,736.10 552,890.05 3.30 4,716.53 9,000.00 82.56 214.70 3,015.32 2894.32 -4,796.37 -5,957.16 5,940,655.81 552,831.90 3.30 4,796.37 9,100.00 82.59 211.37 3,028.23 2907.23 -4,879.49 -6,011.21 5,940,572.28 552,778.51 3.30 4,879.49 9,200.00 82.62 208.04 3,041.10 2920.10 -4,965.62 -6,060.34 5,940,485.78 552,730.05 3.30 4,965.62 9,300.00 82.65 204.71 3,053.91 2932.91 -5,054.46 -6,104.39 5,940,396.60 552,686.71 3.30 5,054.46 9,400.00 82.68 201.38 3,066.67 2945.67 -5,145.72 -6,143.21 5,940,305.06 552,648.61 3.30 5,145.72 9,492.66 82.71 198.29 3,078.45 2957.45 -5,232.17 -6,174.39 5,940,218.37 552,618.10 3.30 5,232.17 K13 9,500.00 82.71 198.05 3,079.38 2958.38 -5,239.08 -6,176.66 5,940,211.44 552,615.89 3.29 5,239.08 9,600.00 82.74 194.72 3,092.04 2971.04 -5,334.24 -6,204.63 5,940,116.08 552,588.66 3.30 5,334.24 9,700.00 82.77 191.39 3,104.64 2983.64 -5,430.86 -6,227.03 5,940,019.29 552,567.01 3.30 5,430.86 9,800.00 82.80 188.06 3,117.20 2996.20 -5,528.63 -6,243.78 5,939,921.41 552,551.03 3.30 5,528.63 9,900.00 82.83 184.73 3,129.70 3008.70 -5,627.22 -6,254.83 5,939,822.75 552,540.75 3.30 5,627.22 10,000.00 82.86 181.40 3,142.15 3021.15 -5,726.28 -6,260.13 5,939,723.65 552,536.23 3.30 5,726.28 10,060.58 82.88 179.38 3,149.66 3028.66 -5,786.40 -6,260.54 5,939,663.55 552,536.29 3.31 5,786.40 10,100.00 82.88 179.38 3,154.55 3033.55 -5,825.51 -6,260.11 5,939,624.44 552,537.02 0.00 5,825.51 10,200.00 82.88 179.38 3,166.94 3045.94 -5,924.73 -6,259.04 5,939,525.24 552,538.86 0.00 5,924.73 10,300.00 82.88 179.38 3,179.33 3058.33 -6,023.95 -6,257.96 5,939,426.04 552,540.71 0.00 6,023.95 10,344.95 82.88 179.38 3,184.90 3063.90 -6,068.56 -6,257.48 5,939,381.44 552,541.54 0.00 6,068.56 1J-17fi MB_D_Top (04119!07) 10,347.37 82.88 179.38 3,185.20 3064.20 -6,070.96 -6,257.46 5,939,379.04 552,541.59 0.00 6,070.96 W Sak D -1J-176 MB_D_Top (05108107) 10,380.32 82.88 180.38 3,189.28 3068.28 -6,103.65 -6,257.39 5,939,346.35 552,541.91 3.00 6,103.65 10,400.00 82.88 180.38 3,191.72 3070.72 -6,123.18 -6,257.51 5,939,326.83 552,541.94 0.00 6,123.18 10,485.38 82.88 180.38 3,202.30 3081.30 -6,207.90 -6,258.07 5,939,242.12 552,542.04 0.00 6,207.90 1J-17fi MB_B_Toe (04/19/07) 10,500.00 82.88 180.38 3,204.11 3083.11 -6,222.41 -6,258.17 5,939,227.61 552,542.06 0.00 6,222.41 6/6/2007 6:55:59PM Page 6 of 12 COMPASS 2003.11 Build 48 a _,. `,, ~ .~ 4 C011000~'il~~lpS Halliburton company A(aska Compass Proposal Report -Geographic HALLIURT N Sperry Drilling S®rvices Database: Sperry EDM .11 Local Co-ordinate Reference: ----- Well Plan 1J-176 (Q2 Phase 2) Company:. ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-176 Design: 1J-176 (wp05) Planned Survey 1J-176 (wp05) Map Map MD Inc! Azimuth TVD (ft) TVDSS +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (~) (°) (ftl (ft) (ft) (ft) (ft) (°i100ft) (ft) 10,518.47 82.88 180.38 3,206.40 3085.40 -6,240.73 -6,258.29 5,939,209.29 552,542.08 0.00 6,240.73 10,544.29 82.88 180.38 3,209.60 3088.60 -6,266.35 -6,258.45 5,939,183.66 552,542.11 0.00 6,266.35 10,600.00 82.88 180.38 3,216.50 3095.50 -6,321.63 -6,258.82 5,939,128.39 552,542.18 0.00 6,321.63 10,700.00 82.88 180.38 3,228.89 3107.89 -6,420.86 -6,259.47 5,939,029.17 552,542.31 0.00 6,420.86 10,705.70 82.88 180.38 3,229.60 3108.60 -6,426.52 -6,259.51 5,939,023.51 552,542.31 0.00 6,426.52 10,712.96 82.88 180.38 3,230.50 3109.50 -6,433.72 -6,259.55 5,939,016.31 552,542.32 0.00 6,433.72 10,719.10 82.88 180.38 3,231.26 3110.26 -6,439.81 -6,259.59 5,939,010.22 552,542.33 0.00 6,439.81 W Sak C 10,752.52 82.88 180.38 3,235.40 3114.40 -6,472.97 -6,259.81 5,938,977.06 552,542.37 0.00 6,472.97 10,768.32 83.31 180.17 3,237.30 3116.30 -6,488.65 -6,259.89 5,938,961.38 552,542.42 3.00 6,488.65 10,800.00 84.17 179.77 3,240.75 3119.75 -6,520.15 -6,259.87 5,938,929.89 552,542.68 3.00 6,520.15 10,814.75 84.57 179.58 3,242.20 3121.20 -6,534.83 -6,259.79 5,938,915.21 552,542.88 3.01 6,534.83 10,824.50 84.84 179.46 3,243.10 3122.10 -6,544.54 -6,259.70 5,938,905.50 552,543.03 3.00 6,544.54 10,830.45 85.00 179.38 3,243.63 3122.63 -6,550.46 -6,259.64 5,938,899.58 552,543.14 3.00 6,550.46 10,836.91 85.00 179.38 3,244.19 3123.19 -6,556.90 -6,259.57 5,938,893.15 552,543.26 0.00 6,556.90 10,880.63 85.00 179.38 3,248.00 3127.00 -6,600.45 -6,259.10 5,938,849.61 552,544.07 0.00 6,600.45 W Sak B - i J-176 (wp05} Top B 05!04/07 10,900.00 85.00 179.38 3,249.69 3128.69 -6,619.74 -6,258.89 5,938,830.31 552,544.43 0.00 6,619.74 10,910.63 85.00 179.38 3,250.62 3129.62 -6,630.33 -6,258.78 5,938,819.73 552,544.63 0.00 6,630.33 9 518" @ 1091 Q' MD, 3251' TVD: 3 33' FSL, 1833' FWL-Sec 3-T10N-R10E - 9 5/8" 10,963.99 87.08 178.90 3,254.30 3133.30 -6,683.56 -6,257.98 5,938,766.51 552,545.84 4.00 6,683.56 11,000.00 88.48 178.58 3,255.69 3134.69 -6,719.53 -6,257.19 5,938,730.55 552,546.91 4.00 6,719.53 11,062.32 90.91 178.02 3,256.02 3135.02 -6,781.82 -6,255.34 5,938,668.29 552,549.25 4.00 6,781.82 11,100.00 90.91 178.02 3,255.42 3134.42 -6,819.47 -6,254.04 5,938,630.65 552,550.84 0.00 6,819.47 11,156.29 90.91 178.02 3,254.52 3133.52 -6,875.72 -6,252.10 5,938,574.42 552,553.22 0.00 6,875.72 11,200.00 90.25 179.15 3,254.08 3133.08 -6,919.41 -6,251.02 5,938,530.75 552,554.64 3.00 6,919.41 11,208.91 .90.11 179.38 3,254.05 3133.05 -6,928.32 -6,250.90 5,938,521.84 552,554.83 3.00 6,928.32 11,300.00 90.11 179.38 3,253.88 3132.88 -7,019.41 -6,249.92 5,938,430.77 552,556.52 0.00 7,019.41 11,400.00 90.11 179.38 3,253.69 3132.69 -7,119.40 -6,248.84 5,938,330.80 552,558.39 0.00 7,119.40 11,500.00 90.11 179.38 3,253.49 3132.49 -7,219.39 -6,247.75 5,938,230.83 552,560.25 0.00 7,219.39 11,600.00 90.11 179.38 3,253.30 3132.30 -7,319.39 -6,246.67 5,938,130.85 552,562.11 0.00 7,319.39 11,700.00 90.11 179.38 3,253.11 3132.11 -7,419.38 -6,245.59 5,938,030.88 552,563.97 0.00 7,419.38 11,800.00 90.11 179.38 3,252.92 3131.92 -7,519.38 -6,244.51 5,937,930.91 552,565.83 0.00 7,519.38 6/6/2007 6:55:59PM Page 7 of 12 COMPASS 2003.11 Build 48 ~~~i t<~ / Halliburton Company C011000~'ll~~lp~5 Compass Proposal Report -Geographic HALLIBURTON Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Referent®: Welt Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wellborn: ' 1J-176 Design: 1J-176 (wp05) Planned Survey 1J-176 (wp05) Map Map MD' Intl Azimuth ND (ft) NDSS -' +N/S +ELW Northing Easting DLSEV Vert Section (ft) (~) (') (ft) !'' (ft) (ft) (ft) (ft) (°1100ft) (ftl 11,808.91 90.11 179.38 3,252.90 3131.90 -7,528.29 -6,244.41 5,937,922.00 552,566.00 0.00 7,528.29 1J-176 MB_B_CP2 (05/08107) 11,873.58 90.71 179.62 3,252.44 3131.44 -7,592.95 -6,243.85 5,937,857.35 552,567.07 1.00 7,592.95 11,900.00 90.71 179.62 3,252.11 3131.11 -7,619.37 -6,243.67 5,937,830.94 552,567.45 0.00 7,619.37 12,000.00 90.71 179.62 3,250.87 3129.87 -7,719.36 -6,243.01 5,937,730.96 552,568.89 0.00 7,719.36 12,100.00 90.71 179.62 3,249.63 3128.63 -7,819.35 -6,242.35 5,937,630.99 552,570.33 0.00 7,819.35 12,200.00 90.71 179.62 3,248.39 3127.39 -7,919.34 -6,241.69 5,937,531.02 552,571.77 0.00 7,919.34 12,300.00 90.71 179.62 3,247.15 3126.15 -8,019.33 -6,241.03 5,937,431.05 552,573.22 0.00 8,019.33 12,400.00 90.71 179.62 3,245.91 3124.91 -8,119.32 -6,240.36 5,937,331.07 552,574.66 0.00 8,119.32 12,500.00 90.71 179.62 3,244.67 3123.67 -8,219.31 -6,239.70 5,937,231.10 552,576.10 0.00 8,219.31 12,600.00 90.71 179.62 3,243.43 3122.43 -8,319.30 -6,239.04 5,937,131.13 552,577.54 0.00 8,319.30 12,700.00 90.71 179.62 3,242.19 3121.19 -8,419.29 -6,238.38 5,937,031.16 552,578.98 0.00 8,419.29 12,800.00 90.71 179.62 3,240.95 3119.95 -8,519.28 -6,237.72 5,936,931.18 552,580.43 0.00 8,519.28 12,900.00 90.71 179.62 3,239.71 3118.71 -8,619.27 -6,237.05 5,936,831.21 552,581.87 0.00 8,619.27 12,909.21 90.71 179.62 3,239.60 3118.60 -8,628.48 -6,236.99 5,936,822.00 552,582.00 0.00 8,628.48 1J-176 MB_B_CP3 (0 5/08107) 12,979.69 89.65 179.62 3,239.38 3118.38 -8,698.96 -6,236.53 5,936,751.54 552,583.02 1.50 8,698.96 13,000.00 89.65 179.62 3,239.50 3118.50 -8,719.27 -6,236.39 5,936,731.23 552,583.31 0.00 8,719.27 13,100.00 89.65 179.62 3,240.10 3119.10 -8,819.26 -6,235.73 5,936,631.26 552,584.75 0.00 8,819.26 13,200.00 89.65 179.62 3,240.71 3119.71 -8,919.26 -6,235.06 5,936,531.28 552,586.20 0.00 8,919.26 13,300.00 89.65 179.62 3,241.32 3120.32 -9,019.25 -6,234.40 5,936,431.30 552,587.64 0.00 9,019.25 13,400.00 89.65 179.62 3,241.92 3120.92 -9,119.25 -6,233.73 5,936,331.32 552,589.09 0.00 9;119.25 13,500.00 89.65 179.62 3,242.53 3121.53 -9,219.25 -6,233.07 5,936,231.34 552,590.53 0.00 9,219.25 13,600.00 89.65 179.62 3,243.13 3122.13 -9,319.24 -6,232.41 5,936,131.37 552,591.98 0.00 9,319.24 13,700.00 89.65 179.62 3,243.74 3122.74 -9,419.24 -6,231.74 5,936,031.39 552,593.42 0.00 9,419.24 13,800.00 89.65 179.62 3,244.34 3123.34 -9,519.23 -6,231.08 5,935,931.41 552,594.86 0.00 9,519.23 13,809.41 89.65 179.62 3,244.40 3123.40 -9,528.64 -6,231.02 5,935,922.00 552,595.00 0.00 9,528.64 1J-176 MB B_CP4 (0 5108/07) 13,896.84 90.53 179.61 3,244.26 3123.26 -9,616.07 -6,230.43 5,935,834.59 552,596.27 1.00 9,616.07 13,900.00 90.53 179.61 3,244.23 3123.23 -9,619.23 -6,230.41 5,935,831.43 552,596.32 0.00 9,619.23 14,000.00 90.53 179.61 3,243.31 3122.31 -9,719.22 -6,229.72 5,935,731.46 552,597.78 0.00 9,719.22 14,100.00 90.53 179.61 3,242.39 3121.39 -9,819.22 -6,229.04 5,935,631.48 552,599.24 0.00 9,819.22 14,200.00 90.53 179.61 3,241.47 3120.47 -9,919.21 -6,228.36 5,935,531.50 552,600.70 0.00 9,919.21 14,300.00 90.53 179.61 3,240.55 3119.55 -10,019.20 -6,227.68 5,935,431.53 552,602.16 0.00 10,019.20 14,400.00 90.53 179.61 3,239.63 3118.63 -10,119.20 -6,227.00 5,935,331.55 552,603.63 0.00 10,119.20 14,500.00 90.53 179.61 3,238.71 3117.71 -10,219.19 -6,226.32 5,935,231.58 552,605.09 0.00 10,219.19 14,600.00 90.53 179.61 3,237.79 3116.79 -10,319.18 -6,225.63 5,935,131.60 552,606.55 0.00 10,319.18 14,700.00 90.53 179.61 3,236.87 3115.87 -10,419.18 -6,224.95 5,935,031.63 552,608.01 0.00 10,419.18 14,800.00 90.53 179.61 3,235.95 3114.95 -10,519.17 -6,224.27 5,934,931.65 552,609.47 0.00 10,519.17 14,900.00 90.53 179.61 3,235.03 3114.03 -10,619.16 -6,223.59 5,934,831.68 552,610.93 0.00 10,619.16 15,000.00 90.53 179.61 3,234.11 3113.11 -10,719.16 -6,222.91 5,934,731.70 552,612.40 0.00 10,719.16 15,100.00 90.53 179.61 3,233.19 3112.19 -10,819.15 -6,222.22 5,934,631.73 552,613.86 0.00 10,819.15 15,109.73 90.53 179.61 3,233.10 3112.10 -10,828.88 -6,222.16 5,934,622.00 552,614.00 0.00 10,828.88 1J-176 MB_B_CPS (05108107) 15,166.34 91.09 179.59 3,232.30 3111.30 -10,885.48 -6,221.76 5,934,565.41 552,614.84 1.00 10,885.48 15,200.00 91.09 179.59 3,231.66 3110.66 -10,919.14 -6,221.52 5,934,531.76 552,615.34 0.00 10,919.14 6/6/2007 6:55:59PM Page 8 of 12 COMPASS 2003.11 Build 48 ~. • `''' Halliburton Company H LL1BU O ConocoPhilfips Compass Proposal Report -Geographic Alaska Sperry Drilling S®rvic®s Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-176 Design: 1J-176 (wp05) Planned Survey 1J-1.6 (wp05) Map Map MD Inc! Azimuth TVD (ft) TVDSS +N/S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) fftl (ft) (ft) lft) (ft) (,/100ft) (ft) 15,300.00 91.09 179.59 3,229.75 3108.75 -11,019.12 -6,220.80 5,934,431.80 552,616.85 0.00 11,019.12 15,400.00 91.09 179.59 3,227.84 3106.84 -11,119.09 -6,220.07 5,934,331.84 552,618.35 0.00 11,119.09 15,500.00 91.09 179.59 3,225.94 3104.94 -11,219.07 -6,219.35 5,934,231.88 552,619.85 0.00 11,219.07 15,600.00 91.09 179.59 3,224.03 3103.03 -11,319.05 -6,218.63 5,934,131.91 552,621.35 0.00 11,319.05 15,700.00 91.09 179.59 3,222.12 3101.12 -11,419.03 -6,217.91 5,934,031.95 552,622.85 0.00 11,419.03 15,800.00 91.09 179.59 3,220.21 3099.21 -11,519.01 -6,217.19 5,933,931.99 552,624.35 0.00 11,519.01 15,900.00 91.09 179.59 3,218.31 3097.31 -11,618.99 -6,216.47 5,933,832.03 552,625.86 0.00 11,618.99 16,000.00 91.09 179.59 3,216.40 3095.40 -11,718.97 -6,215.74 5,933,732.07 552,627.36 0.00 11,718.97 16,100.00 91.09 179.59 3,214.49 3093.49 -11,818.95 -6,215.02 5,933,632.11 552,628.86 0.00 11,818.95 16,200.00 91.09 179.59 3,212.58 3091.58 -11,918.93 -6,214.30 5,933,532.15 552,630.36 0.00 11,918.93 16,300.00 91.09 179.59 3,210.68 3089.68 -12,018.91 -6,213.58 5,933,432.19 552,631.86 0.00 12,018.91 16,309.19 91.09 179.59 3,210.50 3089.50 -12,028.10 -6,213.51 5,933,423.00 552,632.00 0.00 12,028.10 1J-176 MB B_CP6 (0 5/08!07) 16,400.00 90.21 179.37 3,209.47 3088.47 -12,118.89 -6,212.69 5,933,332.22 552,633.53 1.00 12,118.89 16,407.72 90.14 179.35 3,209.44 3088.44 -12,126.61 -6,212.60 5,933,324.51 552,633.68 1.00 12,126.61 16,500.00 90.14 179.35 3,209.22 3088.22 -12,218.89 -6,211.56 5,933,232.25 552,635.44 0.00 12,218.89 16,600.00 90.14 179.35 3,208.99 3087.99 -12,318.88 -6,210.43 5,933,132.28 552,637.35 0.00 12,318.88 16,700.00 90.14 179.35 3,208.75 3087.75 -12,418.87 -6,209.30 5,933,032.30 552,639.26 0.00 12,418.87 16,800.00 90.14 179.35 3,208.51 3087.51 -12,518.87 -6,208.17 5,932,932.33 552,641.17 0.00 12,518.87 16,900.00 90.14 179.35 3,208.28 3087.28 -12,618.86 -6,207.04 5,932,832.36 552,643.08 0.00 12,618.86 17,000.00 90.14 179.35 3,208.04 3087.04 -12,718.85 -6,205.91 5,932,732.39 552,644.99 0.00 12,718.85 17,100.00 90.14 179.35 3,207.80 3086.80 -12,818.85 -6,204.78 5,932,632.42 552,646.90 0.00 12,818.85 17,200.00 90.14 179.35 3,207.57 3086.57 -12,918.84 -6,203.65 5,932,532.45 552,648.81 0.00 12,918.84 17,300.00 90.14 179.35 3,207.33 3086.33 -13,018.83 -6,202.52 5,932,432.47 552,650.72 0.00 13,018.83 17,400.00 90.14 179.35 3,207.09 3086.09 -13,118.83 -6,201.39 5,932,332.50 552,652.63 0.00 13,118.83 17,500.00 90.14 179.35 3,206.85 3085.85 -13,218.82 -6,200.26 5,932,232.53 552,654.54 0.00 13,218.82 17,600.00 90.14 179.35 3,206.62 3085.62 -13,318.81 -6,199.13 5,932,132.56 552,656.45 0.00 13,318.81 17,700.00 90.14 179.35 3,206.38 3085.38 -13,418.81 -6,198.00 5,932,032.59 552,658.36 0.00 13,418.81 • 17,733.60 90.14 179.35 3,206.30 ~ 3085.30 -13,452.40 -6,197.62 5,931,999.00 552,659.00 0.00 13,452.40 BHL @ 177 34' MD, 3206' TVD: 1209' FNL, 1887' FWLSec 15-T10N-R10E - 5 1/2" - 1J-176 MB_B_Toe ( 05108!07) °" 6/6/2007 6:55:59PM Page 9 of 12 COMPASS 2003.11 Build 48 ORIGINAL ConocoPhiltips Halliburton Company HALLIBURTiDN Alaska Compass Proposal Report -Geographic gperry Drilling services Database: Sperry EDM .11 Local Co-ordinate Referent®: Well Plan 1J-176 (Q2 Phase 2) Company: GonocoPhillips Alaska, Inc. ` TVD Reference: Doyoh 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method:. Minimum Curvature Wellbore: 1J-176 Design: 1J-176 (wp05) Geologic Targets 1J-176 TVD TVDSS Target N'amE +N/-S +E(-W Northing Fasting (ft) (ft) -Shape ft ft (ft) (ft) 3,233.10 1J-176 MB_B_CP5 (05/08107) -10,828.88 -6,222.16 5,934,622.00 552,614.00 - Polygon Point 1 0.00 0.00 5,934,622.00 552,614.00 Point2 -1,199.24 8.65 5,933,423.00 552,632.00 3,185.20 1J-176 MB_D_Top (05/08/07) -6,076.03 -6,254.08 5,939,374.00 552,545.00 - Point 3,210.50 1J-176 MB_B_CP6 (05/08/07) -12,028.10 -6,213.51 5,933,423.00 552,632.00 - Polygon Point 1 0.00 0.00 5,933,423.00 552,632.00 Point 2 -1,424.50 15.89 5,931,999.00 552,659.00 3,184.90 1J-176 MB_D_Top (04/19/07) -5,802.93 -6,261.95 5,939,647.00 552,535.00 - Point 3,202.30 1J-176 MB_B_Toe (04/19/07) -13,944.44 -6,200.46 5,931,507.00 552,660.00 - Point 3,254.30 1J-176 MB_B_CP1 (05/08/07) -6,829.12 -6,254.96 5,938,621.00 552,550.00 - Polygon Point 1 0.00 0.00 5,938,621.00 552,550.00 Point 2 -699.45 10.55 5,937,922.00 552,566.00 3,270.60 1J-176 MB_B_Heel (04/19107) -5,802.93 -6,261.95 5,939,647.00 552,535.00 - Polygon Point 1 0.00 0.00 5,939,647.00 552,535.00 Point 2 -133.08 0.96 5,939,514.00 552,537.00 3,230.50 1J-176 MB_B_CP4 (04/19!07) -8,628.48 -6,236.99 5,936,822.00 552,582.00 - Polygon Point 1 0.00 0.00 5,936,822.00 552,582.00 Point 2 -900.16 5.98 5,935,922.00 552,595.00 3,229.60 1J-176 MB_B_CP6 (04119/07) -10,828.88 -6,222.16 5,934,622.00 552,614.00 - Polygon Point 1 0.00 0.00 5,934,622.00 552,614.00 Point2 -1,199.44 8.65 5,933,423.00 552,632.00 3,209.60 1J-176 MB_B_CP7 (04/19/07) -12,028.10 -6,213.51 5,933,423.00 552,632.00 - Polygon Point 1 0.00 0.00 5,933,423.00 552,632.00 Point2 -1,301.25 8.85 5,932,122.00 552,651.00 3,243.10 1J-176 MB_B_CP2 (04119/07) -6,829.12 -6,254.96 5,938,621.00 552,550.00 - Polygon Point 1 0.00 0.00 5,938,621.00 552,550.00 Point 2 -699.17 10.55 5,937,922.00 552,566.00 3,244.19 1J-176 (wp04) Top B 05/02/07 -6,337.94 -6,260.27 5,939,112.08 552,540.86 - Point 3,237.30 1J-176 MB_B_CP5 (04/19/07) -9,528.64 -6,231.02 5,935,922.00 552,595.00 - Polygon Point 1 0.00 0.00 5,935,922.00 552,595.00 Point 2 -1 300.30 8.86 5 934 622.00 552 614.00 6/6/2007 6:55:59PM Page 10 of 12 COMPASS 2003.11 Build 48 ~' ..~ a ''+ 1 ~ ., , '~ is • Halliburton Company ALLIBURTC]N ConaeoPhillip5 Compass Proposal Report -Geographic qia~ Sperry Drilling 8ervic®s Database: Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-176 Design: 1J-176 (wp05) 3,242.20 1J-176 MB_B_CP3 (04/19/07) -7,528.29 -6,244.41 5,937,922.00 552,566.00 - Polygon Point 1 0.00 0.00 5,937,922.00 552,566.00 Point 2 -1,100.25 7.42 5,936,822.00 552,582.00 3,206.40 1J-176 MB_B_CP8 (04/19/07) -13,329.33 -6,204.66 5,932,122.00 552,651.00 - Polygon Point 1 0.00 0.00 5,932,122.00 552,651.00 Point 2 -615.12 4.20 5,931,507.00 552,660.00 3,206.30 1J-176 MB_B_Toe (05/08/07) -13,452.40 -6,197.62 5,931,999.00 552,659.00 - Point 3,248.00 1J-176 (wp05) Top B 05/04/07 -6,600.45 -6,259.10 5,938,849.61 552,544.07 - Point 3,274.10 1J-176 MB_B_Heel (05/08107) -6,076.03 -6,254.08 5,939,374.00 552,545.00 - Polygon Point 1 0.00 0.00 5,939,374.00 552,545.00 Point 2 -753.40 -0.87 5,938,621.00 552,550.00 3,239.60 1J-176 MB_B_CP3 (05/08/07) -8,628.48 -6,236.99 5,936,822.00 552,582.00 - Polygon Point 1 0.00 0.00 5,936,822.00 552,582.00 Point 2 -900.21 5.98 5,935,922.00 552,595.00 3,252.90 1J-176 MB_B_CP2 (05/08/07) -7,528.29 -6,244.41 5,937,922.00 552,566.00 - Polygon Point 1 0.00 0.00 5,937,922.00 552,566.00 Point 2 -1,100.20 7.42 5,936,822.00 552,582.00 3,244.40 1J-176 MB_B_CP4 (05/08/07) -9,528.64 -6,231.02 5,935,922.00 552,595.00 - Polygon Point 1 0.00 0.00 5,935,922.00 552,595.00 Point2 -1,300.27 8.86 5,934,622.00 552,614.00 3,268.30 1J-176 MB_B_CP1 (04/19/07) -5,935.96 -6,260.99 5,939,514.00 552,537.00 - Polygon Point 1 0.00 0.00 5,939,514.00 552,537.00 Point 2 -893.52 6.04 5,938,621.00 552,550.00 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (n) (ft) f 7 (") 3,806.92 2,300.00 13-3/8 16 10,910.63 3,250.61 9-5/8 12-1/4 17,733.59 3,206.30 5-1/2 8-1/2 6/6/2007 6:55:59PM Page 11 of 12 COMPASS 2003.11 Build 48 r F ~ ~~~ Halliburton Company HALLIBURTON ConoeoPhillips Compass Proposal Report -Geographic Alaska Sperry Driliing Servlcses Database: ..Sperry EDM .11 .Local Co-ordinate Reference: Well Plan 1J-176 (Q2 Phase 2) Company: ConocoPhllips Alaska, Inc! TVD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Project: I~:uparuk River Unit MD Reference: Doyon 15 @ 121.OOft (D15 (40+81)) Site: Kuparuk 1J Pad' North Reference: True Well: Plan 1J-176 (Q2 Phase 2) Survey Calculation Method: Minimum Curvature Wel lbore: 1 J-176 Design: 1J-17h ie•~h05j Prognosed Formation Intersection Points _. _ Measured Depth Inclination Azimuth TVD TVDSS +N/-E (ft) +EI-W (ft) (ft) (°) (°~ (ft)' (ft) Name 1,729.59 51.78 225.00 1,537.22 -423.76 -423.76 Pfrost 1,905.30 57.04 226.67 1,640.92 -522.79 -525.15 T3 2,686.23 71.00 230.31 1,935.14 -990.40 -1,073.62 K15 3,326.80. 71.00 230.31 2,143.69 -1,377.18 -1,539.71 T3+550 6,588.15 82.39 233.54 2,696.91 -3,308.11 -4,096.76 Ugnu C 7,796.50 82.39 233.54 2,856.85 -4,019.86 -5,060.06 Ugnu B 8,460.90 82.40 232.65 2,944.79 -4,411.38 -5,589.60 Ugnu A 9,492.66 82.71 198.29 3,078.45 -5,232.17 -6,174.39 K 13 10,347.37 82.88 179.38 3,185.20 -6,070.96 -6,257.46 W Sak D 10,719.10 82.88 180.38 3,231.26 -6,439.81 -6,259.59 W Sak C 10,880.63 85.00 179.38 3,248.00 -6,600.45 -6,259.10 W Sak B Plan Annotations Measured Vertical Locai Coor dinates Depth Depth +N/-S +E/-W Comment (ft) (ft1 (ft) (ft) 40.00 40.00 0.00 0.00 SHL @ 1686' FSL, 2461' FEL-Sec35-T11 N-R10E 10,910.63 3,250.61 -6,630.33 -6,258.78 9 5/8" @ 10910' MD, 3251' TVD: 333' FSL, 1833' FWL-Sec 3-T10N-R10E 17,733.59 3,206.30 -13,452.40 -6,197.62 BHL @ 17734' MD, 3206' TVD: 1209' FNL, 1887' FWL-Sec 15-T10N-R10E 6/6/2007 6:55:59PM Page 12 of 12 COMPASS 2003.11 Build 48 r"~i~~"',3~~,~~ ~ , ,~,~ ~ 11 y ~ 3 SURVEY PROGRAM Date: 2007-06-U4TOO:U0:00 Validated: Yes Version: Depth FromDepth "Io Survey/Plan Tool 40.00 lOW.00 1J-176 (wp05) C&GYRO-SS 10110.00 3941.00 1J-176 (wp05) MWD+IFR-AK-CA~SC 394LU0 5667.55 IJ-17G(wp05) MWD+IFR-AK-CA~SC lOGll1.UU17733.04 IJ-17G(wn05) NI~VD+IFR-AK-CA2rSC COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conlc Warning Method: Rules Based 1J-170 Rlg Surveys 1J-166 1J-164 1J-158 4 ,, 1 0 -~ tao - - - wsP-2o v~~.o, 30 ] WSP-06 ] 1J-120 I 1 I ] ~ 1 J-127 ~1.~ ] 1J-178 (wp03) 90 1 J-158 l.~].~ )~r ~„~~~ 1J-135 .; ~~ 1J-136 `t ~,` 720 ~l t 1J-14 J'~ r`~ ~~ ,~ , \ 1J-137 Rig I 1 ` 1J-180 1 1J-182 \` 1J-184 Travelling Cylinder Azimuth (TFO+AZI) [°~ vs Centre to Centre Separation [200 tt/ink ~ REFERENCE INFORMATION I From Colour To MD a0 zso zso soo soo zso 7sa loon laoa 1250 lzsa 1500 1500 nso 1750 ----- 2000 2000 2250 2250 "--- 2500 2500 2750 2750 3000 3000 ~-'-_-"~ 3250 3250 3500 3500 3750 3750 4000 4000 4250 4250 4500 asoo also 4750 _- 5000 5000 5250 5250 5500 5500 5750 5750 8000 6000 8500 6500 7000 7000 7500 7500 eooo 8000 8500 8500 -"~-~~~ ~~~-~- 9000 9000 9500 9500 10000 tooao !asoo 10500 [1000 11000 '----- 11500 asoo lzaoo 12000 -°~-~-~--- 12500 12500 13000 13000 13500 13500 14000 laaoa 14500 14500 ~-'----"- 15000 t 5000 -_-- 15500 15500 16000 16000 16500 16500 17000 17000 16000 180 Travelling Cylinder Azimuth (TFO+AZI) 1°~ vs Centre to Centre Separation 135 ft/inl Co-ordinate (NIE) Reference: Well Plan 1J-176 (02 Phase 2), True North Vertical (TVD) Reference: Doyon 15 ~ 121.OOft (D15 (40+81)) NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-176 (02 Phase 2) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: Doyon 15 ~ 121.OOft (D75 (40+81)) Ground Level: 81.00 Calculation Method: Minimum Curvature +N/-S +E1-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945498.05 558750.89 70°15'42.114N 149°37'30.239W WSP-08 60 WSP-09 WSP-10 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 40 To 17733.5956661287 Maximum Range:1968.96574133852 Reference: Plan: 1J-176 (wp05) 90 BECTION DETAILS 8« MD 1« Ab TVD ~WS AEI-W 0.°9 TF«e VSac Tar9N moo °oo o.ao 40.00 0.% o.ao °ae °ao o.ao z 300.00 o.ao oao 3oo.ao a.oo oao °ao a.oo o.ao 3 fi00.00 9.00 22500 5%.]J -1663 .1663 300 225.00 16.63 0 1%941 51.]8 225.00 1500.00 -3%31 .390.34 4.00 0.00 390.30 5 1]6804 51 ]8 225.00 15618] .405.&9 -045.88 000 000 445.89 6 2263.69 ]100 13(1.31 1]9150 .]35.2] -7%.1] 4.00 15.00 ]353] ] 38%.92 ]100 230.]1 23W.00 -1%1% -1%905 0.00 0.00 186].08 8 4102]5 8339 233.50 2%108 -1813.91 -311509 4.00 15.81 100391 9 ed34.14 ax 39 n3.s1 2911 xs <3%.45 -swa.39 000 000 m%<s 10 10060.58 92.88 1]9.38 3149.66 -sJ%40 -6280.50 3.30 ffi.48 s]es.40 11o341n eze6 nv6 nfis ca-w]°%625146 ow ooo wJO% v.-° -_ ,1. _. v<_, t2 tO3B0.32 82.88 180.38 3189.28 610365 -625139 300 9004 610365 1310]52.52 82.88 180.38 3339.40 {4]29] -6259.81 0.00 0.00 W]2.9] 1d 108]0.45 85.00 1]9.38 3243.83 8550.46 -6259.60 300 -25.12 6550.16 510880.63 8500 I]9Jfi ]249006600.45 -625510 000 000 %0045 IJ-116 (vg0')T°p BG'i.0-f 0i 16 10910.83 85.00 1]938 325062 -%3033 -fi358.]8 000 000 8630.]3 1] 11062.32 80.91 1]802 ]256.02 .6]8162 -6255.34 4.00 -1298 6]8182 18 111%.29 90.91 1]802 ]351.52 -68]5.]3 -6252.10 000 0.00 fi8]5.]2 19 11200.91 90.11 179.38 3251.05 6928.31 4250.80 3.00 120.60 6928.32 118%91 9D I1 -9 ]8 ] -,52629 -6 000 000 ]52029 tJ-Ii8 M8_9_CP210508G;~ 21 118]358 90.]1 170.fi2 3153 W -]59'1.95 8143.85 1.00 21 86 1592.% ..13%9.21 90]1 1]5 G2 - -&:2848 623699 000 0.00 862848 tJ~l]6 MB BCP3 (05060':. 23 129]9.69 89.65 1]9.82 3239.38 86%-% 823853 150 -1 A.93 88%W 2413809.41 965 I 5526.646231 03 0.00 000 952804 IJ-1 ]6 MB eCP1 (05060], 25138%84 %.53 1]9.61 3241.26 -%16.0] 8230A3 100 -0% %16.0] 15109.]] %SJ I' 1082008 6222.16 000 000 1%2888 1J~1)6 Me_B_CPS l~~60') '33 10- 2] 1516634 91.09 1]959 3232.30 10885.48 8221.18 1.00 -332 10905,48 '61fi90B.19 9109 1]959 3_1050-12028.10 6213.51 0.00 0.001lO2B.10 1]-176 M8_B CP6 (OS/00/01) 29 1600].]2 9D.11 179K 3209.41-12126.81 8212.60 100 -1 %.28 1212fi 61 301]T39.80 90.14 1]935 3_11510-1546240 -619!.62 0.00 0.00 1]45].40 1J-1 J8 M8_B_T°e (OS~O6b]) • • ConocoPhillips Alaska Plan: 1 J-176 (wp05) Sperry Drilling Services Anticollision Summary 06 Jun, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-176 (Q2 Phase 2) 1 J-176 Local Coordinate Origin: Centered on Well Plan 1J-176 (02 Phase 2) Viewing Datum: Doyon 15 @ 121.OOft (D15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet HAL ' T IIV Sperry Drilling Services if"~~~ ,fit ~~ ~ i~ =amp ~ t ~ Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Datc: 6/21/2007 Time: 10:49:23 Page: Field: Kuparuk River Un it Reference Site: Kuparuk 1J Pad Co-ordinate(NE) Refe rence: Well: Plan 1J-176, T rue North Reference V1'ell: Plan iJ-176 Vertical (T VD) Re[ere uce: Doyon 1 5 (40+g1) 121.0 Reference R'cllpatb: Plan 1J-176 Db: OraCle GLOBAL SCAN APPLIED: All wellpa ths within 200'+ 100/1000 of reference Refe rence: Plan : 1 J-176 (wp05) 8~ NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 40.00 to 17733.59 ft Scan Method: Trav Cylinder North Maximum Radius: 1969.36 ft Error Surface: Ellipse + Casing Casing Points _- A9D 'fVD Diameter Hole Size Acme ft ft in in 3326.80 2143.69 13.375 16.000 13 3/8" 10910.63 3250.61 9.625 12.250 9 5/8" 1733.59 1539.69 5.500 8.500 51/2" Plan: 1J-176 (wp05) Date C omposed: 6/6/2007 Version: 2 Principal: Yes Tied-to: From Well Ref. Point Summary <----------- ------- O ffsct Wellpath -------- - ---------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wcllpath DID D1D Distance Area Deviation AVarning i ft ft ft ft ft Kuparuk 1J Pad 1J-127 1J-127 V7 322.13 325.00 148.12 6.03 142.09 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1 V3 322.13 325.00 148.12 5.90 142.22 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1P61 V3 322.13 325.00 148.12 6.14 141.98 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L2 V2 322.13 325.00 148.12 5.90 142.22 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127P61 V2 322.13 325.00 148.12 6.14 141.98 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127P62 V2 322.13 325.00 148.12 6.14 141.98 Pass: Major Risk Kuparuk 1J Pad 1J-133 1J-133 V3 286.99 275.00 177.17 5.65 171.52 Pass: Major Risk Kuparuk 1J Pad 1J-133 Plan 1J-133 L1 V2 Plan 299.94 300.00 179.73 6.82 172.91 Pass: Major Risk Kuparuk 1J Pad 1J-133 Plan 1J-133 VO Plan: 1 299.94 300.00 178.62 No Offset Errors Kuparuk 1J Pad 1J-135 1J-135 V2 395.74 400.00 201.96 7.20 194.76 Pass: Major Risk Kuparuk 1J Pad 1J-135 1J-135L1 V2 395.74 400.00 201.96 6.83 195.13 Pass: Major Risk Kuparuk 1J Pad 1J-135 1J-135L1PB1 V3 395.74 400.00 201.78 6.87 194.91 Pass: Major Risk Kuparuk 1J Pad 1J-136 iJ-136 V2 318.99 325.00 217.22 5.75 211.47 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1 V3 318.99 325.00 217.22 5.60 211.63 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1PB1 V3 318.99 325.00 217.22 5.75 211.47 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1P62 V4 318.99 325.00 217.22 5.75 211.47 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136P61 V5 318.99 325.00 217.22 5.75 211.47 Pass: Major Risk Kuparuk 1J Pad 1J-137 1J-137 V2 311.81 300.00 232.89 6.19 226.71 Pass: Major Risk Kuparuk 1J Pad 1J-137 1J-137L1 V2 311.81 300.00 232.89 6.19 226.71 Pass: Major Risk Kuparuk 1J Pad 1J-137 1J-137L1P61 V2 311.81 300.00 232.89 6.19 226.71 Pass: Major Risk Kuparuk 1J Pad 1J-137 1J-137L1PB2 V2 311.81 300.00 232.89 6.19 226.71 Pass: Major Risk Kuparuk 1J Pad 1J-14 1J-14 V13 703.05 675.00 232.45 10.09 222.36 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L2 V2 310.76 300.00 420.31 5.78 414.53 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L1 V6 9855.92 13064.00 156.77 146.30 10.47 Pass: Major Risk Kuparuk 1J Pad 1J-160 1J-160L2 V2 9845.75 13067.00 89.75 34.24 55.51 Pass: Minor 1/200 Kuparuk 1J Pad 1J-164 1J-164 V4 358.18 350.00 239.88 6.77 233.11 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L1 V2 358.18 350.00 239.88 6.64 233.24 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2 V3 358.18 350.00 239.88 6.88 233.00 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2PB1 V2 358.18 350.00 239.88 6.77 233.11 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166 V6 335.08 325.00 199.18 5.94 193.24 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1 V4 335.08 325.00 199.18 5.80 193.37 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1P61 V4 335.08 325.00 .199.18 5.80 193.37 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2 V2 335.08 325.00 199.18 5.80 193.37 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2PB1 V2 335.08 325.00 199.18 5.80 193.37 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168 V6 407.44 400.00 159.78 7.60 152.19 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L1 V4 407.44 400.00 159.78 7.47 152.32 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2 V3 407.44 400.00 159.78 7.47 152.32 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2P61 V2 407.44 400.00 159.78 7.47 152.32 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170 V3 286.99 275.00 121.34 5.65 115.69 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L1 V2 286.99 275.00 121.34 5.52 115.82 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L2 V2 286.99 275.00 121.34 5.52 115.82 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB1 V2 286.99 275.00 121.34 5.65 115.69 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB2 V2 286.99 275.00 121.34 5.65 115.69 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180 V4 274.59 275.00 81.33 5.17 76.16 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1 V3 274.59 275.00 81.33 5.02 76.31 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1PB1 V1 274.59 275.00 81.33 5.17 76.16 Pass: Major Risk GRAM ORIGINAL ~Halliburton Com any p Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 6/21/2007 Time: 10:49:23 Page: 2 Field: Reference Site: Kuparuk River Unit Kuparuk 1J Pad Co-ordinate(NE) Reference: Well: Plan 1J-176, Tr ue North Reference yYell: Plan 1J-176 Vertical (TVD) Reference: Doyon 15 (40+81) 12 1.0 l O Db Reference W'ellpath: Plan 1J-176 rac e : Summary <---------------------- Site Offset Wellpath -------- ~~'ell --------------> Wellpath Reference ,14D Offset MD Ctr-Ctr Distance No-Go Area Allowable Deviation _ ~Varuing ft ft ft ft ft Kuparuk 1J Pad 1J-180 1J-180PB1 V1 249.59 250.00 80.84 No Offset Errors Kuparuk 1J Pad 1J-182 1J-182 V3 199.69 200.00 121.43 4.18 117.25 Pass: Major Risk Kuparuk 1J Pad 1J-182 1J-182L1 V8 199.69 200.00 121.43 4.02 117.41 Pass: Major Risk Kuparuk 1J Pad 1J-182 1J-182L1P61 V5 199.69 200.00 121.43 4.02 117.41 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184 V6 599.15 575.00 159.28 8.87 150.40 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184L1 V6 599.15 575.00 159.28 8.72 150.56 Pass: Major Risk Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 L1 V1 Plan 310.92 300.00 188.86 6.43 182.43 Pass: Major Risk Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 L2 V1 Plan 310.92 300.00 188.86 6.43 182.43 Pass: Major Risk Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 V4 Plan: 1 310.92 300.00 188.86 6.59 182.27 Pass: Major Risk Kuparuk 1J Pad Plan 1J-123 Plan 1J-123 Kuparuk Pr 40.00 40.00 176.50 No Offset Stations Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 L1 V1 Plan 322.99 325.00 166.12 6.40 159.72 Pass: Major Risk Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 V3 Plan: 1 322.99 325.00 166.12 6.55 159.56 Pass: Major Risk Kuparuk 1J Pad Plan 1J-129 Plan 1J-129 V2 Plan: U 323.59 325.00 147.39 No Offset Errors Kuparuk 1J Pad Plan 1J-130 Plan 1J-130 V2 Plan: U 323.72 325.00 151.42 No Offset Errors Kuparuk 1J Pad Plan 1J-132 1J-132 V2 Plan: Undefi 323.96 325.00 166.62 No Offset Errors Kuparuk 1J Pad Plan 1J-173 1J-73 Kuparuk Producer 40.00 40.00 59.98 No Offset Stations Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V2 Plan: 672.19 675.00 37.16 11.55 25.60 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 V1 Plan 672.19 675.00 37.16 11.55 25.60 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan 1J-176 L1 V1 Plan 8425.00 8425.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 L1 V3 Pla 781.17 775.00 44.66 12.81 31.86 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 V3 Plan: 781.17 775.00 44.66 12.81 31.86 Pass: Major Risk Kuparuk 1J Pad Plan 1J-Q14 (BM) 1J-014 B Lateral VO PI 288.00 275.00 247.95 No Offset Errors Kuparuk 1J Pad Rig 1J-120 Plan 1J-120 L1 V2 Plan 333.37 325.00 216.24 5.69 210.55 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Plan 1J-120 L2 VO Plan 333.37 325.00 216.24 5.69 210.55 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Plan 1J-120 V3 Plan: U 333.37 325.00 216.24 5.98 210.27 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Rig 1J-120 L1 V1 310.82 300.00 216.24 5.73 210.51 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Rig 1J-120 L1P61 V2 310.82 300.00 216.24 5.73 210.51 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Rig 1J-120 L1PB3 V3 310.82 300.00 216.24 5.73 210.51 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Rig 1J-120 L1PB4 V2 310.82 300.00 216.24 5.73 210.51 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Rig 1J-120 L2 V1 310.82 300.00 216.24 5.73 210.51 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Rig 1J-120 L2P61 V1 310.82 300.00 216.24 5.73 210.51 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Rig 1J-120 V1 310.82 300.00 216.24 5.62 210.62 Pass: Major Risk Kuparuk 1J Pad Rig 1J-120 Rig 1J-120L1P62 V3 310.82 300.00 216.24 5'.73 210.51 Pass: Major Risk Kuparuk 1J Pad Rig 1J-158 Plan 1J-158 L1 VO Plan 7550.54 10700.00 436.38 No Offset Errors Kuparuk 1J Pad Rig 1J-158 Plan 1J-158 V3 Plan: 1 322.65 325.00 380.13 No Offset Errors Kuparuk 1J Pad Rig 1J-158 Rig 1J-158L1 V2 7565.41 10775.00 438.82 121.86 316.95 Pass: Major Risk Kuparuk 1J Pad Rig 1J-158 Rig:1J-158 V5 344.84 350.00 379.90 6.10 373.81 Pass: Major Risk Kuparuk 1J Pad WSP-06 WSP-06 V3 344.01 350.00 216.23 8.23 208.00 Pass: Major Risk Kuparuk 1J Pad WSP-07 WSP-07 V2 344.68 350.00 189.65 9.16 180.50 Pass: Major Risk Kuparuk 1J Pad WSP-08 WSP-O8 V3 382.34 375.00 181.29 12.31 168.97 Pass: Major Risk Kuparuk 1J Pad WSP-09 WSP-09 V2 346.04 350.00 190.33 8.00 182.33 Pass: Major Risk Kuparuk 1J Pad WSP-10 WSP-10 V2 386.71 375.00 216.91 8.49 208.42 Pass: Major Risk Kuparuk 1J Pad WSP-11 WSP-11 V2 420.13 425.00 255.48 8.79 246.69 Pass: Major Risk Kuparuk 1J Pad WSP-20 WSP-20 V2 363.01 350.00 242.37 7.17 235.20 Pass: Major Risk Non-Pad KRUST-02 KRUST-02 VO 16141.25 3100.00 639.14 207.98 431.16 Pass: Major Risk 1J-176 ~rillin~ Hazards S~mary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole / 13-3/8" 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, Increase Gravels - mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 12-1/4" Open Hole / 10 3/4" x 9-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. 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 weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 8-1/2" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1J-176 Drilling Hazards Summary prepared by Dennis Hartwig f'°~ ~ ~ 6/4/2007 1:14 PM • Schlumberger CemCADE Preliminary Job Design 13 3/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 6/29/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at SurFace Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,730' MD (1,500' TVD) < Top of Tail at 3,000' MD < 13 3/8", 72.0# casing i in 16" OH TD at 3,800' MD ~,~ (2,300' TVD) s Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 3,000' MD. Lead Slurry Minimum pump time: 320 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1730' - 80') x 3.50 (250% excess) = 2429 ft3 0.4206 ft3/ft x (3000' - 1730') x 1.35 (35% excess) = 721.1 ft3 81.5 ft3 + 2429 ft3+ 721.1 ft3 = 3231.6 ft3 3231.6 ft3 / 4.45 ft3/sk = 726.2 sks Round up to 730 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 230 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3800' - 3000') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520.7 ft3 520.7 ft3/ 2.47 ft3/sk = 210.8 sks Round up to 220 sks BHST = 51 ~, Estimated BHCT = 66`F. (BHST calculated using a gradient of 2.6`1=/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 33.3 Lead Slurry 7 579 82.7 116.0 Tail Slurry 6 97 16.2 132.2 Drop Top Plug 8.0 140.2 Water 5 20 4.0 144.2 Switch to Rig Pumps 5.0 149.2 Displacement 7 511 73.0 222:2 Slow Rate 3 20 6.7 228.9 MUD REMOVAL Recommended Mud Properties: 8.8 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 1 per joint across zones of interest for proper cement placement. ORIGINAL Schlumberger CemCADE*well cementing recommendation for Surface Operator : ConocoPhillips Well 1J-176 Country :USA Field State :Alaska Prepared for :Dennis Hartwig Location 1J pad Proposal No. : V2, wp05 Service Point Prudhoe Bay Date Prepared : 06-28-2007 Business Phone (907-659-2434 FAX No. :.(907) 659-2538 Prepared by :Maureen Torrie Phone 1-907-265-6336 E-Mail Address mtorrieCslb.com ~~~~ ~~ C'~ C `G'~ ~1~, Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good far 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger ORIGINAL • • Client ConocoPhillips Well 1J-176 String Surface District Prudhoe Bay Country USA Loadcase Surface Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :3806.9 ft BHST : 50 degF Bit Size : 16 in ft o~ 0 0 o- Well •• •• ~ • Permafrost .... ~ •••• K15 ','•'•' Csg point Schlumhurg~r Lithology Formation Press. 1J-116 Cement. V2.cfw;~6-29-2007: Loadcase Surface: Version wcs-cem45_89 Page 2 ORIGINAL (x 1000) psi Client ConocoPhillips ~~I~a~l ~~~ Well 1J-176 u String Surface District Prudhoe Bay Country USA Loadcase Surface Previous String MD OD Weight ID ft in Ib/ft in 80.0 20 94.0 19.124 Landing Collar MD :3720.0 ft Casing/liner Shoe MD :3800.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread ft in ft Ib/ft in si si 3800.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTCM Mean OH Diameter :16.000 in Mean Annular Excess :130.4 Mean OH Equivalent Diameter :18.882 in Total OH Volume :1288.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft (in % in 1730.0 16.000 250.0 21.184 3800.0 16.000 35.0 16.822 1J-776 Cement,V2.cfw;06-29-2007; Loadcase Surface; Versionwcs-cem45_89 Page 3 ORIGINAL • Client ConocoPhillips Well 1J-176 String Surface District Prudhoe Bay Country USA Loadcase Surface Max. Deviation Angle : 71 deg Max. DLS :4.066 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 40.0 40.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 3.0 225.0 -3.000 500.0 499.6 6.0 225.0 3.000 600.0 598.8 9.0 225.0 3.000 700.0 696.9 13.0 225.0 4.000 800.0 793.5 17.0 225.0 4.000 900.0 888.0 21.0 225.0 4.000 1000.0 980.0 25.0 225.0 4.000 1100.0 1069.1 29.0 225.0 4.000 1200.0 1154.8 33.0 225.0 4.000 1300.0 1236.7 37.0 225.0 4.000 1400.0 1314.4 41.0 225.0 4.000 1500.0 1387.5 45.0 225.0 4.000 1600.0 1455.7 49.0 225.0 4.000 1669.4 1500.0 51.8 225.0 4.003 1700.0 ~ 1518.9 51.8 225.0 0.000 1729.6 1537.2 51.8 225.0 0.000 1769.4 1561.9 51.8 225.0 0.000 1800.0 1580.5 53.0 225.4 3.999 1900.0 1638.0 56.8 226.6 3.994 1905.3 1640.9 57.0 226.7 4.066 2000.0 1689.8 60.7 227.7 4.003 2100.0 1735.8 64.6 228.8 3.996 2200:0 1775.5 68.5 229.7 3.998 2263.7 1797.6 71.0 230.3 4.004 2300.0 1809.4 71.0 230.3 0.000 2400.0 1841.9 71.0 230.3 0.000 2500.0 1874.5 71.0 230.3 0.000 2600.0 1907.1 71.0 230.3 0.000 2686.2 1935.1 71.0 230.3 0.000 2700.0 1939.6 71.0 230.3 0.000 2800.0 1972.2 71.0 230.3 0.000 2900.0 2004.7 71.0 230.3 0.000 3000.0 2037.3 71.0 230.3 0.000 3100.0 2069.8 71.0 230.3 0.000 3200.0 2102.4 71.0 230.3 0.000 3300.0 2135.0 71.0 230.3 0.000 3326.8 2143.7 71.0 230.3 0.000 3400.0 2167.5 71.0 230.3 0.000 3500.0 2200.1 71.0 230.3 0.000 3600.0 2232.6 71.0 230.3 0.000 3700.0 2265.2 71.0 230.3 0.000 3806.9 2300.0 71.0 230.3 0.000 iJ-17fiCement,V2.cfw;06-29-2007; LoadCaseSurface;Versionwcs-cem45_89 • ~chlrg~r Page 4 • • Client ConocoPhillips Well 1J-176 String Surface District Prudhoe Bay Country USA Loadcase Surface Formation Data MD Frac. Pore Name Lithology ft Ib/ al Ib/ al 1730.0 12.50 8.00 Permafrost Sandstone 1905.0 12.50 8.50 T3 Sandstone 2686.0 12.50 8.50 K15 Sandstone 3810.0 12.50 8.50 Cs oint Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 2 5 0.0 1730.0 1537.5 30 0.3 3806.9 2300.0 50 1.1 3810.0 2301.0 50 1.1 ft o- O O _ N 0 0 0 ~- degF Temperature 0 ~ 6 ~- C >~ F--' ~ O ~ O O X .._. a N Schlumher~~r Hori. Departure Page 5 iJ-176 Cement,U2.cfw;06-294007; LoadCaseSurface;Versionwcs-cem45_89 ORIGINAL (x 1000) ft • • Client ConocoPhillips Well 1J-176 String Surface District Prudhoe Bay Country USA Loadcase Surface Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :3790.0 ft Casing Shoe :3800.0 ft NB of Cent. Used :40 NB of Floating Cent. :0 Schlumdurger Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 3000.0 0 0/0 0.0 3007.1 3800.0 40 2/1 S1104613-13 3/8-8-46 3/16" 32.6 3010.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ibf Ibf S1104613-13 3/8-8- 13 3/8 18.752 14.500 No Houma 17.500 490.08 2214.37 46 (3/16") I (1) -Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications 1J-176 Cement.V2.cfw:06-29-2007; LoadCaseSurface:Versionwcs-cem45_89 O~I~r~~L Page 6 • Client ConocoPhillips ~~Ir~Yr Well 1J-176 String Surface District Prudhoe Bay Country USA Loadcase Surface Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 8.80 Ib/gal Rheo. Model : GINGHAM p~ :45.000 cP At temp. : 80 degF Ty :30.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) MUD Mud Type : WBM Job volume :537.0 bbl Water Type :Fresh CW100 DESIGN Fluid No: 2 Density : 8.33 Ib/gal Rheo. Model :NEWTONIAN At temp. : 80 degF Viscosity :5.000 cP Gel Strength : (Ibf/100ft2) Job volume :75.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 10.50 Ib/gal Rheo. Model : HERSCHEL_B: k : 4.65E-2 Ibf.s^n/ft2 At temp. : 80 degF n :0.344 Ty :9.211bf/100ft2 Gel. Strength : (Ibf/100ft2) Job volume :75.0 bbl ASL DESIGN Fluid No: 4 Density : 10.70 Ib/gal Rheo. Model : HERSCHEL_B. k : 2.52E-2 Ibf.s^n/ft2 At temp. : 64 degF n :0.469 Ty :7.311bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type :Fresh water SLURRY Mix Fluid :21.765 gal/sk Yield :4.56 ft3/sk Porosity :63.8 Density :8.321b/gal Job volume :575.5 bbl Quantity :708.57 sk Solid Fraction :36.2 Base Fluid :21.167 gal/sk 1J-176 Cement, V2.cfw;06d9-2007; LoadCase Surface; Version wcs-cem45_89 Page 7 ORIGINAL • Client ConocoPhillips Well iJ-176 String Surface District Prudhoe Bay Country USA Loadcase Surface • SG~Ir~~r 12.0 ppg DeepCRETE DESIGN Fluid No: 5 Density : 12.00 Ib/gal Rheo. Model : HERSCHEL_B. k : 2.49E-3 Ibf.s^n/ft2 At temp. : 64 degF n :0.999 Ty :14.651bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type :Fresh water SLURRY Mix Fluid :8.459 gal/sk Yield :2.49 ft3/sk Porosity :45.4 Density :8.321b/gal Job volume :92.9 bbl Quantity :209.50 sk Solid Fraction :54.6 Base Fluid :8.369 gal/sk iJ-17fiCement,V2.cfw;06-29-2007; LoadCaseSurface;Versionwcs-cem45_89 a ~ v ~ t _.. ,, Page 8 Client ConocoPhillips Well 1J-176 String Surface District Prudhoe Bay Country USA Loadcase Surface Sc~lrg~r Section 4: fluid sequence Original fluid Mud 8.80 Ib/gal P~ :45.000 cP Tv :30.00 Ibf/100ft2 Displacement Volume 557.0 bbl Total Volume 1375.4 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl ft (ft Ib/ al CW100 75.0 0.0 8.33 viscosity:5.000 cP MUDPUSH II 75.0 0.0 10.50 k:4.65E-2 Ibf.s^n/ft2 n:0.344 Tv:9.21 Ibf/100ft2 ASL 575.5 3000.0 0.0 10.70 k:2.52E-21bf.s^n/ft2 n:0.469 Tv:7.311bf/100ft2 12.0 ppg 92.9 800.0 3000.0 12.00 k:2.49E-3 Ibf.s^n/ft2 n:0.999 Tv:14.65 Ibf/100ft2 DeepCRETE Water 20.0 3586.4 8.32 viscosity:3.000 cP Mud 537.0 0.0 8.80 P~:45.000 cP Tv:30.00 Ibf/100ft2 Static Security Checks Frac 7 psi at 80.0 ft Pore 11 psi at 80.0 ft Collapse 1954 psi at 3720.0 ft Burst 5020 psi at 0.0 ft Cs .Pum out 51 ton Section 5: pumping schedule Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl/min) (bbl) (min) (bbl). Temp. de F CW100 5.0 37.5 7.5 37.5 80 Pause 0.0 0.0 10.0 0.0 80 CW100 5.0 37.5 7.5 75.0 80 Pause 0.0 0.0 5.0 0.0 80 MUDPUSH II 6.0 75.0 12.5 75.0 80 ASL 6.0 575.5 95.9 575.5 80 12.0 ppg 6.0 92.9 15.5 92.9 80 DeepCRETE Pause 0.0 0.0 5.0 0.0 80 Water 5.0 .20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Mud 7.0 517.0 73.9 517.0 80 Mud 3.0 20.0 6.7 537.0 80 Total 04:08 1375.4 bbl hr:mn Dynamic Security Checks Frac 7 psi at 80.0 ft Pore 1 psi at 80.0 ft Collapse 1954 psi at 3720.0 ft Burst 4689 psi at 0.0 ft Temperature Results API BHCT 80 degF I Simulated Max HCT 70(degF) Simulated BHCT 70 (degF) Max HCT Depth 3800 (ft) CT at TOC 59 (degF) Max HCT Time 4:08:25(hr:mn:sc) 1J-176 Cement,V2.ciw;06-29-2007; Load~aseSurface;Versionwcs-cem45_a9 • Page 9 Schlumberger CemCADE Preliminary Job Design 9.625" Intermediate Casin Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 6/4/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb.com Heavy Inter Csg. 10 3/4", 73.2# casing at 1,990' MD Previous Csg. 13 3/8", 72.0# casing at 3,800' MD < Top of Tail at 6,000' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 10,910' MD (3,250' ND) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C formation - (Ugnu C at 6,588' MD, TOC at 6000' MD, 4910' MD annular length). Tail Slurry Minimum thickening time: 310 min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 4910' x 1,25 (25% excess) = 1922.3 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1922.3 ft3 + 34.1 ft3 = 1956.4 ft3 1956.4 ft3/ 2.25 ft3/sk = 869.5 sks Round up to 870 sks BHST = 74~, Estimated BHCT = 60~. (BHST calculated using a gradient of 2.6/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) bbl (min) (min CW 100 5 10 2.0 2.0 Pressure Test 10.0 12.0 CW 100 5 90 18.0 30.0 Drop Bottom Plug 5.0 35.0 MudPUSH II 6 75 12.5 47.5 Tail Slurry 6 348.6 58.1 105.6 Drop Top Plug 5.0 110.6 Water 5 20 4.0 114.6 Switch to Rig Pum s 5.0 119.6 Displacement 5 721.3 144.3 263.8 Slow Rate 3 100.0 33.3 297.2 LCM: 2.0 ppb of CemNET is to be pumped in cement to prevent losses. MUD REMOVAL Recommended Mud Properties: 8.8 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: Recommend 2 perjoint across zones of interest for proper cement placement. ~RIG!Na.L ~ ~ Schlumberger CemCAD E*well cementing recommendation for Intermediate Operator : ConocoPhillips Well 1J-176 Country :USA Field Kuparuk State :Alaska Prepared for :Dennis Hartwig Location 1J pad Proposal No. : V1, wp05 Service Point Prudhoe Bay Date Prepared : 06-07-2007 Business Phone (907) 659-2434 FAX No. :1907) 659-2538 Prepared by :Maureen Torrie Phone 1-907-265-6336 F-Mail Address mtorrie@slb.com 5~~~ ~C/ Cy C ~G 9~V AT E Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger ORIGINrIL • Client ConocoPhillips Well 1J-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate (a) Section 1: well description Configuration :Casing Stage :Single Rig Type :Land Mud Line : 0.0 ft Total MD :10910.2 ft BHST : 75 degF Bit Size : 12 1/4 in ft o- 0 0 o' v 0 0 o- ••••••• Permafrost • • •• K15 •, •, •, • Ugnu B ••••••• U nu A :::. K13 • • ' Wsak D 0 0 0 N Well Lithology • Formation Press. 5 1J~176Cement,V2cfw;06-07-2007; loadCaselntermediatelal;Versionwcs-cem45_89 Schlumdergur Page 2 ORIGINAL (x 1000) psi • • Client ConocoPhillips c~~r~~r Well 1J-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate la- Previous String MD OD Weight ID ft in Ib/ft in 3800.0 13 3/8 68.0 12.415 Landing Collar MD :10830.0 ft Casing/liner Shoe MD :10910.0 >ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread eft) (in) (ft) (Ib/ft) (in) (psi) (psi) 1990.0 10 3/4 40.0 73.2 9.406 L-80 8060 8750 MTC 10910.0 9 5/8 40.0 40.0 8.835 L-80 3090 5750 BTC MD ft Frac. Ib/ al Formation Data Pore Name Ib/ al Lithology 1730.0 12.00 8.00 Permafrost Sandstone 1905.0 12.00 8.50 T3 Sandstone 2686.0 12.00 8.50 K15 Sandstone 6588.0 12.00 8.50 Ugnu C Sandstone 7796.0 12.00 8.50 Ugnu B Sandstone 8460.0 12.00 8.50 Ugnu A Sandstone 9492.0 12.00 8.50 K13 Sandstone 10346.0 12.00 8.50 Wsak D Sandstone 10719.0 12.00 8.50 Wsak C Sandstone 10910.3 12.00 8.50 Wsak B Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1730.0 1535.0 30 0.3 10900.0 3250.0 75 1.5 10910.3 3250.9 75 1.5 Page 3 1J-176 Cement,V2.cfw;06-07-2007; LoadCaselntermediatelal;Versionwcs-cem45_69 ~ ' ~ ~ ~ $ .. • Client ConocoPhillips Well 1J-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate (a) Mean OH Diameter Mean Annular Excess Mean OH Equivalent C Total OH Volume Max. Deviation Angle Max. DLS :12.250 in 25.0 Diameter: 12.823 in :1135.6 bbl (including excess) 85 deg 4.066 deg/100ft MD ft Directional Survey Data TVD Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 40.0 40.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 3.0 225.0 -3.000 500.0 499.6 6.0 225.0 3.000 600.0 598.8 9.0 225.0 3.000 700.0 696.9 13.0 225.0 4.000 800.0 793.5 17.0 225.0 4.000 900.0 888.0 21.0 225.0 4.000 1000.0 980.0 25.0 225.0 4.000 1100.0 1069.1 29.0 225.0 4.000 1200.0 1154.8 33.0 225.0 4.000 1300.0 1236.7 37.0 225.0 4.000 1400.0 1314.4 41.0 225.0 4.000 1500.0 1387.5 45.0 225.0 4.000 1600.0 1455.7 49.0 225.0 4.000 1669.4 1500.0 51.8 225.0 4.003 1700.0 1518.9 51.8 225.0 0.000 1729.6 1537.2 51.8 225.0 0.000 1769.4 1561.9 51.8 225.0 0.000 1800.0 1580.5 53.0 225.4 3.999 1900.0 1638.0 56.8 226.6 3.994 1905.3 1640.9 57.0 226.7 4.066 2000.0 1689.8 60.7 227.7 4.003 2100.0 1735.8 64.6 228.8 3.996 2200.0 1775.5 68.5 229.7 3.998 2263.7 1797.6 71.0 230.3 4.004 2300.0 1809.4 71.0 230.3 0.000 2400.0 1841.9 71.0 230.3 0.000 2500.0 1874.5 71.0 230.3 0.000 2600.0 1907.1 71.0 230.3 0.000 2686.2 1935.1 .71.0 230.3 0.000 2700.0 1939.6 71.0 230.3 0.000 2800.0 1972.2 71.0 230.3 0.000 2900.0 2004.7 71.0 230.3 0.000 3000.0 2037.3 71.0 230.3 0.000 3100.0 2069.8 71.0 230.3 0.000 3200.0 2102.4 71.0 230.3 0.000 3300.0 2135.0 71.0 230.3 0.000 3326.8 2143.7 71.0 230.3 0.000 3400.0 2167.5 71.0 230.3 0.000 3500.0 2200.1 71.0 230.3 0.000 3600.0 2232.6 71.0 230.3 0.000 3700.0 2265.2 71.0 230.3 0.000 3806.9 2300.0 71.0 230.3 0.000 1J-176 Cement, V2.cfw; 06-07-2007 ; Loadcase Intermediate (a) ; Version wcs-cem45_89 • Page 4 `v r z ~ ~ $ t • • Client ConocoPhillips Well iJ-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate (a) MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 3900.0 2327.5 74.6 231.4 3.998 4000.0 2350.8 78.4 232.5 4.003 4102.4 2367.9 82.4 233.5 3.996 4200.0 2380.8 82.4 233.5 0.000 4300.0 2394.1 82.4 233.5 0.000 4400.0 2407.3 82.4 233.5 0.000 4500.0 2420.5 82.4 233.5 0.000 4600.0 2433.8 82.4 233.5 0.000 4700.0 2447.0 82.4 233.5 0.000 4800.0 2460.3 82.4 233.5 0.000 4900.0 2473.5 82.4 233.5 0.000 5000.0 2486.8 82.4 233.5 0.000 5100.0 2500.0 82.4 233.5 0.000 5200.0 2513.2 82.4 233.5 0.000 5300.0 2526.5 82.4 233.5 0.000 5400.0 2539.7 82.4 233.5 0.000 5500.0 2553.0 82.4 233.5 0.000 5600.0 2566.2 82.4 233.5 0.000 5700.0 2579.5 82.4 233.5 0.000 5800.0 2592.7 82.4 233.5 0.000 5900.0 2605.9 82.4 233.5 0.000 6000.0 2619.2 82.4 233.5 0.000 6100.0 2632.4 82.4 233.5 0.000 6200.0 2645.7 82.4 233.5 0.000 6300.0 2658.9 82.4 233.5 0.000 6400.0 2672.2 82.4 233.5 0.000 6500.0 2685.4 82.4 233.5 0.000 6587.9 2697.0 82.4 233.5 0.000 6600.0 2698.6 82.4 233.5 0.000 6700.0 2711.9 82.4 233.5 0.000 6800.0 2725.1 82.4 233.5 0.000 6900.0 2738.4 82.4 233.5 0.000 7000.0 2751.6 82.4 233.5 0.000 7100.0 2764.9 82.4 233.5 0.000 7200.0 2778.1 82.4 233.5 0.000 7300.0 2791.3 82.4 233.5 0.000 7400.0 2804.6 82.4 233.5 0.000 7500.0 2817.8 82.4 233.5 0.000 7600.0 2831.1 82.4 233.5 0.000 7700.0 2844.3 82.4 233.5 0.000 7796.1 2857.1 82.4 233.5 0.000 7800.0 2857.6 82.4 233.5 0.000 7900.0 2870.8 82.4 233.5 0.000 8000.0 2884.0 82.4 233.5 0.000 8100.0 2897.3 82.4 233.5 0.000 8200.0 2910.5 82.4 233.5 0.000 8300.0 2923.8 82.4 233.5 0.000 8400.0 2937.0 82.4 233.5 0.000 8433.7 2941.5 82.4 233.5 0.000 8460.5 2945.0 82.4 232.6 3.297 8500.0 2950.2 82.4 231.3 3.288 8600.0 2963.4 82.4 228.0 3.301 8700.0 2976.6 82.5 224.7 3.301 8800.0 2989.6 82.5 221.4 3.302 8900.0 3002.7 82.5 218.0 3.302 ~cl~r~~r iJ-176 Cement,V2.cfw;06-07-2007; LoadCaselntermediateiai;Versionwcs-cem45_69 Page 5 ~~~~~~~ • • Client ConocoPhillips Well iJ-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediateia) MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 9000.0 3015.6 82.6 214.7 3.302 9100.0 3028.6 82.6 211.4 3.302 9200.0 3041.4 82.6 208.0 3.302 9300.0 3054.2 82.7 204.7 3.303 9400.0 3067.0 82.7 201.4 3.303 9492.1 3078.7 82.7 198.3 3.304 9500.0 3079.7 82.7 198.0 3.298 9600.0 3092.4 82.7 194.7 3.303 9700.0 3105.0 82.8 191.4 3.304 9800.0 3117.6 82.8 188.1 3.304 9900.0 3130.1 82.8 184.7 3.304 10000.0 3142.5 82.9 181.4 3.304 10060.3 3150.0 82.9 179.4 3.308 10100.0 3154.9 82.9 179.4 0.000 10200.0 3167.3 82.9 179.4 0.000 10300.0 3179.7 82.9 179.4 0.000 10346.8 3185.5 82.9 179.4 0.000 10379.3 3189.5 82.9 180.4 2.988 10400.0 3192.1 82.9 180.4 0.000 10500.0 3204.5 82.9 180.4 0.000 10600.0 3216.9 82.9 180.4 0.000 10700.0 3229.2 82.9 180.4 0.000 10718.8 3231.6 82.9 180.4 0.000 10752.7 3235.8 82.9 180.4 0.000 10800.0 3241.1 84.2 179.8 3.004 10830.3 3243.9 85.0 179.4 2.981 10836.5 3244.5 85.0 179.4 0.000 10880.3 3248.3 85.0 179.4 0.000 10900.0 3250.0 85.0 179.4 0.000 10910.2 3250.9 85.0 179.4 0.000 degF (x1000)ft D 0 0 n n c V C 0 C ,... C O5G' F ~_ c X v C C r c c c (~ Schlumber~ur 1J-176 Cement, VZcfw; 06.07-2007 ; Loadcase Intermediate IaI:Version wcs-cem45_89 Page 6 ORIGINAL Temperature Hon. Departure • • Client ConocoPhillips Well 1J-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate la- Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :10900.0 ft Casing Shoe :10910.0 ft NB of Cent. Used :243 NB of Floating Cent. :243 Schlu~a~r~~r Centralizer Placement Bottom MD Nbr. Cent. I Cent. Name Code Min. STO @ Depth ft Joint % ft 1990.0 49 1/1 LODRAG 10 3/4 69.5 390.0 3830.0 46 1/1 LODRAG-9 5/8-5-1.076 0.0 3812.1 ROLLER1225 5950.0 0 0/0 0.0 3830.0 9950.0 100 1/1 HYDROFORM 9625 0.0 5967.0 10910.0 48 2/1 HYDROFORM 9625 80.7 10910.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ib Ibf HYDROFORM LODRA LODRA 10 3/4 12.25 12.250 Yes Weatherfo N.A. G-9 5/8- G 10 0 rd 5-1.076 3/4 ROLLE (1) -Centralizer ft o -, 0 0 0 v 0 0 0 m 0 0 0 N Pipe Standoff N.A. N.A. the current API 10D specifications U I Page 7 1J-176 Cement,V2.chv;06-07-2007; LoadCaselntermediate(a1;Versionwcs-cem45_89 ORIGINAL • Client ConocoPhillips Well 1J-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate (a) Section 3: fluid description Mud DESIGN S~hlr~~r Fluid No: 1 Density : 8.90 Ib/gal Rheo. Model : HERSCHEL_B. k : 1.63E-2 Ibf.s^n/ft2 At temp. : 80 degF n :0.474 Ty :3.891bf/100ft2 Gel Strength : (Ibf/100ft2) MUD Mud Type : WBM Job volume :821.3 bbl Water Type :Fresh CW100 DESIGN Fluid No: 2 Density : 8.33 Ib/gal Rheo. Model :NEWTONIAN At temp. : 80 degF Viscosity :5.000 cP Gel Strength : (Ibf/100ft2) Job volume :100.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 11.00 Ib/gal Rheo. Model : HERSCHEL_B. k : 4.65E-2 Ibf.s^n/ft2 At temp. : 80 degF n :0.344 Ty :9.211bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume :75.0 bbl -- ___ 12.5 ppg DeepCRETE DESIGN Fluid No: 7 Density : 12.50 Ib/gal Rheo. Model : HERSCHEL_B. k : 2.54E-2 Ibf.s^n/ft2 At temp. : 64 degF n :0.675 Ty :11.831bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name ; G Mix Fluid :7.485 gal/sk Job volume :348.4 bbl Dry Density : 199.771b/ft3 Yield :2.24 ft3/sk Quantity :872.95 sk Sack Weight : 94 Ib Porosity. :44.6 % Solid Fraction :55.4 BASE FLUID Type :Fresh water Density : 8.32 Ib/gal Base Fluid :7.465 gal/sk 2.0 ppb of CemNET is to be pumped in cement to prevent losses 1J-176 Cement,V2.cfw;06-07-2007; Load~aselntermediatela~;Versionwcs-cem45_69 • Page 8 t 1 ~ ~ alt ~ • • Client ConocoPhillips Well 1J-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate la- S~l~rg~r Section 4: fluid sequence Job Objectives: To isolate the Ugnu C by bringing cement 500' above the formation top (@ 6588' MD, 2697' TVD). TOC = 6000'MD. 2.0 ppb of CemNET is to be pumped in cement to prevent losses. Original fluid Mud 8.90 Ib/gal k : 1.63E-2 Ibf.s^n/ft2 n :0.474 Tv :3.89 Ibf/100ft2 Displacement Volume 841.3 bbl Total Volume 1364.8 bbl TOC 6000.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al CW 100 100.0 1486.0 3438.4 8.33 viscosity:5.000 cP MUDPUSH II 75.0 1075.6 4924.4 11.00 k:4.65E-2 Ibf.s^n/ft2 n:0.344 Tv:9.21 Ibf/100ft2 12.5 ppg 348.4 4910.0 6000.0 12.50 k:2.54E-2 Ibf.s^n/ft2 n:0.675 Tv:11.83 Ibf/100ft2 DeepCRETE Water 20.0 10566.2 8.32 viscosity:3.000 cP Mud 821.3 0.0 8.90 k:1.63E-21bf.s^n/ft2 n:0.474 Tv:3.891bf/100ft2 Static Security Checks Frac 373 psi at 3800.0 ft Pore 42 psi at 3800.0 ft Collapse 2843 psi at 10830.0 ft Burst 5741 psi at 4924.4 ft Cs .Pum out 76 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Comments Temp. de F CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 CW100 5.0 90.0 18.0 100.0 80 Pause 0.0 0.0 5.0 0.0 80 MUDPUSH II 6.0 75.0 12.5 75.0 80 12.5 ppg 6.0 348.4 58.1 348.4 80 DeepCRETE Pause 0.0 0.0 5.0 0.0 80 Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Mud 5.0 721.3 144.3 721.3 80 Mud 3.0 100.0 33.3 821.3 80 Total 04:57 1364.8 bbl hr:mn Dynamic Security Checks Frac 9 psi at 10910.0 ft Pore 42 psi at 4924.4 ft Collapse 2843 psi at 10830.0 ft Burst 5330 si at 4102.3 ft Page 9 1J-176 Cement,V?.cfiv;06-07-2007; LoadCaselntermediatelal;Versionwcs-cem45_89. OR1~~:~-!~f. Client ConocoPhillips Well iJ-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate (a) Fluid Sequence Ib/gal ft 7.5 10.0 12.5 ~, O O_ O V 0 0 o' O O N 0 0 0 ~o a ui ~ m a o~ c .~ ~~ U O O V C Q 0 200 400 Time (min) Nin. Fydrostatic ~ - Max. Dynartic - Nin. Cynamic Frac ~ Pore 'y ~ Fydroslatic a a ~o N O . • i Dynamic Well Security O 3chlumhcrgcr 0 200 400 Time (min) ~. ,_ __ 0 0.25 0.50 0.75 1.00 1.25 1.50 Pumped Volume (bbl) (x 1000) m m a ~ O ~ O N ~ C C Q Pumped Volume (bbl) (x 1000) Page 10 1J-17fiCement,V2.cfw;06-07-2007; LoadCaselntermediatelal;Versionwcs-cem45_89 ~~1GINAL 1=lUylUlt i j i i ~ i i 0.75 1.00 1.25 1.5( • Client ConocoPhillips Well 1J-176 String Intermediate District Prudhoe Bay Country USA Loadcase Intermediate la- Secti on 6: WELLCLEAN I I Simulator 0 50 100 0 100 0 - Std Betw. Cent. -Mud Contarmation - Cement Coverage - Uncontarmated Slurry o ._ 7 O O W 0 0 0 N • ~chiuulburgur deg Fluid Sequence l .--. ~ ~ l_ Cement Coverage ~ Uncontaminated Slurry Deviatan Fluids Concenkrations Risk Mud on tha Wall ~ ~ ~ a a a a ooa tooo + aoa ~ . .- - t a4o aa4o soao saoa- ~aoo 3400 3444 3004- 3004 ,-. .ooa ~ooa .. r. ~o~o- ~ ~ - •400 ,~ 5000= ~ 5000 5094 -~~ r 5000 ~ 6040- 8000 ~ ~ B000~"'~ 6000 f8 .. -,~ , 4444= aoaa 4444= 4444 9040- 9aoa 9444- 9aoa ~oooa- ta4a4 X0000-_ laooa _ 11000 11400 11000 11000 ~ ~ a` ~ # 6 3 3 ~ Mud Q Water Q 12.5 ppg DeepCRETE D MUDPUSHII =-~ CW 100 (~ High Low ~ Medium Q None Page 11 1J-176 Cement,V2.cfw;06-07-2007; LoadCaselntermediatefal;Versionwcs-cem45_89 ORIGIN~~ • • 10-'/," Casing, 73.2#, L-80, BTCM ~ 2,500' MD 13-3/8" CasShoe,' 68#, L-80, B set ~ 3,800' MD, 2,3 ' ND Tubing String - 4112" 12.6#, L-80, IBTM 3.958" ID, 3.890" Dritt PBR Seal Assembly y TorqueMaster Production Anchor 4.75" Seal OD Lateral Entry Module ILEM) Assembly 7" X 3518" ZXP Liner Top Packer with Hold Downs 7.500" Tieback Ext.ID 6.278" Tool Body ID _` Casing Sealbore Receptacle 4.75" ID, 5.75" OD 20' Length ~~ Orienting Profile Automatic Alignment of LEM Positive Latching Collet Indicates Correct Location Seal Bore for Lateral Isolation - 3.688" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.688" ID ~\ Isolation Seal Asemhly 4.75" Seal OD 3.875" Seal ID 2' Length DB Nipple GLM, Camco, 4112" x 1" KBG-2 / CMD Sliding Sleeve, w/ 3.81" DB Nipple Locating Seal Assembly "Seal OD rqueMaster Packer era/ Entry Module (LEM) D-sand Window at 10,347' MD 3,185 ND'83deg Baker 5-%" ECP 7" 96/8" Seal Bores 3.68" ID 4t "12.6#TUbing 890" Dritt Liner Top ~ 10,450' MD ConocoPhillips 1 J-176 9-5/8" Intermediate Dual Lateral Liner Injector cap-04 'D' Sand Lateral 4112" 11.6a, HYdril d-112" 11.80, BTC, 21, L-80 Sloltetl Liner L-00 Sbtted Liner Every Other Joint Every Other Joint Cro~sover - Hydril 527 xBTC / ..:. ~~s Baker Oil Tools As Planned Lateral Entry Module (LEMI With Di verters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Lakral Dritt) (2.50" ID Mainbore Drift) 'GS' Profile for Cdl Connector fRunning/Relrieving~ (1.00' Length) Snap INSnap Out /Positive Locating rSack Pressure Valve Collet (1.60' Length) Lateral ISOWtfOn ~' .~ Flow-Thru Swivel Seals (1.25' Lengm) Hydraulic / lateral Diverter ! Ramp Disconnect ' ' IsoktioN Mainbore (1.50' Length) Diverter Sleeve ~~ GS Spear ~ (1.50' Lengtn) Lateral Isolation 6 .65 h Approx. Seals OAL' 'Jars may be required in highly deviated 18' Diverter Length 79' Sleeve Length or deep applications (6' approx length). 4112" Guide Slice .___ _.... _..___- _.__.__ _. 41IT' Casing Slice, 11.6#, L-80 BTCM 4112" bent joint shoe bottom Set ~ 17,730' MD, 3,133' ND Tieback Sleeve Seal Assembly ~~ . `~ 4.75" Seal OD B"MLZXP 'B' Sand Lateral Packer wim S ProNe and 5112" 15.Sa, Hytlril 5112" 15.5#, STC, SIIPS 521, LAO Slotted Liner LAO Slotted Liner \ Every Other Joint Every Other Joint 51/2" Guide a Receptacle ID 9-S18" Casin~'9fie~r4GAffiL.Bp~I 10,910' MD, 3,250' ND 85deg ©eak« Hughes zam. mi. e«vmem may not be rroroa«ed or m.mbvted. ~o wnme or m pan. .n n~~y :_~~ -:,:.,, any means elecnonic or m«nanirai, m~lvame phot«opyina. recommv. or by any inrormarm~ :m~.,,:,~ ,~~ ~ rebiev,l araem pow known or n<reaner invemea, wimovt wreren pe,missmn hom eaker H~enes h... 5-1/2" ~guioment Specifications 7" X 9-518" HOOK Hanger Mainbore Drift: 7.00" Mainbore Drif[, wtth diverter: 6.25" Lateral Drift, no diverter or LEM: 6.28" Lateral Dnft, cal diverter, no LEM: 5.12" LaterallMainbore Diverter OD: 8.50" 4-112" Lateral Entry Module Mainbore Drift: 3.68" Mainbore Ddft, w/ isolation sleeve: 2.50" Lateral Drift, cal coil diverter: 3.00" OD of Diverter and Sleeve: */- 3.60" Diverter and Sleeve Length: +l- t9' Shoe Set @ 17,733' MD, 3,206' ND !~ V Closest in POOL ....~• ~'''' i • Closest A roach: Reference Well: 1J-17 6 L1 w 05 Plan Offset Well: 1J-160 L2 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments POOL Min Distance (514.43 ft) in POOL POOL Min Distance (514.43 ft) in (10346.77 - 17729.66 POOL (10346.77 - 17729.66 MD) to MD) to 1J-160 L2 1J-176 L1 (wp05) Plan (8387 - 514.43 10346.77 82.88 179.38 3064.603 5939378.1 552541.5 6070.546 (8387-13067 MD) 13067 91.88 179.17 3069.321 5939890 552490.8 5558.263 13067 MD) Closest A roach: Reference Well: 1J-17 6 L1 w 05 Plan Offset Well: KRU STA TE 02 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 180° Comments De th Incl. An le TRUE Azi. ND E + /W - 180° Comments POOL Min Distance (632.25 ft) in POOL POOL Min Distance (632.25 ft) in (10346.77 - 17729.66 POOL (10346.77 -17729.66 MD MD) to KRU STATE 1J-176 L1 (wp05) Plan (3137 - 632.25 fit 16150 91.06 179.59 3018.567 5933576.5 552629.9 11872.68 02(3137-3650 MD) 3125 18.51 231.41 2982.2 5933578.6 551998.7 80.69 3650 MD) POOL Summary (version 1).xls 6/6/2007 6:48 PM CanocaPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan: 1J-176 L1 (wp05) 1/4 Mile Pool Scan Sperry Drilling Services June 6, 2007 1 i_ • • HALLIBURTON Grilling and Formation Evaluation ORIGINAL HALLIBURTON -Project: KuparukRiverUnit ELL DETAILS:PIan1J-176 (Q2 Phase 2) Sperry Grilling Services Site: Kuparuk 1J Pad Well: Plan 1J-176 Q2 Phase 2 ( Wellbore: 1J-176 L1 Ground Level: 81.00 +NI-S +EI-W Northing Easting Latittude Longitude Slol 0.00 0.00 5945498.05 558750.8970°15'42.114N149°31'30.239W Plan: 1J-176 L1 (wp05) REFERENCEINFORMATION O-Ofdlnate (N/E) Reference: Well Plan 1J-178 (02 Phase 2), True North Vertical (TVD) Reference: Doyon is ~ tzt.oort (ots (ao+at)) Measured Depth Reference: ooyon is @ tzt.oon (Ots (ao+et)) Calculation Method: Minimum Curvature 0 0 0 N + S 1r 7O G t 7 O 10000 -9000 -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 2000 3000 4000 West(-)/East(+) (2000 ft/in) ~'~ ConocoPhillips ~~ska ~ ~ KRU STATE 02 The Kru State 2 West Sak interval falls within approximately 632' of the proposed 1J- 176 West Sak production interval. The Kru State 2 was drilled as a Wildcat well in April of 1990. The Kru State 2 - 9 5/8" Surface casing was set @ 3,954'MD (3,845'TVD), well below the deepest 1J-176 West Sak interval TVD of approximately 3,255'TVD. The following description of the 9 5/8" surface cement job was retrieved from historical well records. o Circulated and conditioned mud 500 psi @ 9.5 BBL/min (1.5 csg volume) o Pumped 80 bbl Water Spacer o Tested lines to 2500psi o Pump 380 bbl, 1100 sx ASIII @ 12.1 ppg o Mixed with 1/4pps D29 o Pump 74 bbl, 360 sx Class G @ 15.8 ppg Tail o Mixed with 2% S1 + .2% D46 + 1/4pps D29 o Displace casing with 299 bbl water + mud o Bump plug with 2000 psi , CIP @ 20:20 4/1/1990 with 11.3 ppg cement returns. o Hold 10 minutes -bleed pressure off with floats holding. All indications are that the KRU State 2 had a good surface cement job and that the 9 5/8" has good cement behind it through the west Sak and Ugnu intervals. oRisitin.~ 6050000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) ..__._. _ _. _.._ _.__ .- __ 1189 ET CONOCOPHALLIP SP_D RAKE ATO 1530 700 G ST. GE AK 99501 ANCHORA f/, ~ ~ ` '~ PAY TO THE ~~~ 1 ti !~ ORDER OF ~U 56-15511441 DATE JCL $ /~ C~~ pp,, ~~~~sa ~" ©~Oa _ DOLLARS lJ a"` /• ~~A,Y Valid Up To 5000 Dollars ~pMorganChase an Chase Bank, N.A. ^~' JPMorg ~, - -- ---- Columbus,OH ______ --- MEMO ? L 9 0? 9 2 7 n' L L 8 9 ,,~.~~ ~;0~,4LL55LL~:528?4 • ~ TRa~vs~[rrT~a~L L~TTE~ c~.EC~cL~sT WELL ~vA.titrE ~'',CGC /.T-/ 7~ PTD# ZQ'~? - Q ~ 1 Development Service Ex lorato Yoa-Coaveatiioaa[ Welt p ~` Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included is Transmittal Letter CHECK w'HAr APPLIES ADD-ONS (OPTIONS) NRiLTI LATERAL ([f last two digits j AP[ number ,' between 60-69) PILOT HOLE [n accordance with 20 A.4C 25.005 (f), a!t records, data and togs ;acquired for the pilot hole ~ must be cleazly differentiated in both ;well name (50- PH) and API numbec i -____) from records, data and logs acquired for wel! SPACING EXCEPTION The permit is approved subject to full compliance with 20 AAC 25 055 . f . Approval to perforate and aroduce /inject is contingent j i upon issu ance of a conservation order approving a spacing ~ ;exception. ' assumes the ~ i liability of any protest to the spacing exception that may occur. i DRY DITCH f All dry ditch sample sets submitted to the-E i i SA!tiiPLE i omm ssion must be in i no greater than 30' sample intervals from below the permafrost or I from where samples are ferst caught and IO' sample intervals !through target zones. i ~ e!! Conventional j Please note the following special condition of this ~ production or production testi f l o ~ ng o coal bed methane is not a wed I for (name of welh until after (Cornnanv h_ame} has designed and implemented a water well testin ro S P gram to provide baseline data I on water quality and ti quan ty. (Company Name) must contact the ~ Commission to obtain advance a r l f pp ova o i such water welt testing Pro3ram. TEXT FOR APPROVAL LETTER I The permit is for a new weltbore segment of existing ~ welt 1° I Permit Yo. ,API No. 50- _ are ~ - , `Production should continue to be reported as a Function of the origins! API number stated above. Rev: [ '2~i06 C:' jody~tractsrreitta!_checklist • • ~~ : : :: : , m o :,: : a~ a : N c o' ~ v ~, _: N, uj: i L. p ~ Q O ~ ~ j ~ ~ ~ ~ ~ c. •~ ~ cc. ~ ~ ~ ~ ~: ~~ ~ ~ LL . ~ ~ ~ ~ ~ tk N a O : : ~ L: w ~ y o o: O p: ~: ~ ~ E O o ~~ ~ ~ >. a~~ ~ ~ ~ ° . 4 . 0 ~ °D ~° o °' _ : ~ ~ 3 a ~ ~ ~ ~ , ~ ~ ~ ~ ~ , O ~ O: O: ~ ~' C 'O~ O' ~ ~ O: ~~ ~ ~ ~ N• ~~ 7 ~ ~~ ~ ~ ~ O L C 3: O' ~ V:a ~: 3 ~ ~ ~ ~ N ~ ~ v' m: ~ v. m ~ c°o ~ ~ ~ L ~: a: - Q. ~: ~: ~ m: ~ E: y: ~ ; : c: ~: v. c: a ~: ~ a`n o ° ~ x : ~ a`r c 3 ~ ~ c, o. ~ c m ~, o ~ = Q O y Qr C ~: ~ ~: ~ ~~ ~: a N . N• a ~ ~ ~ ~ a ~ _ ~ ~ ~ : ~, ~ L YI ~ ~; ~: a~ 3, ~, 3 ~ a Z ~ ~~ ~ ~ ~ N: ~ 0 . a~ 0' > ?> U' O' tq' 1l N~ ~~ ~ ~ ~ ~ ~ j ~T ~ ~ ~ ~ > ~ N O N ~ : L ~ O J D. f6• r~ C• o. ,~ a m. ~ ~ O: ~ n~ ~ ~ ~ d ~ ~ ~: ~ Y: ~i, ~ W: , rn 3. ~ ~ Z ~ d p 3 c, w' c O N ~ ~~ ~: Y: W. 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L . ~: ~ ° a~ a 3: ° O' _ c ~ ~ ~ c o W o d a ~: ~ ~? N, ~ o: ~° 'o ~ .~~ 3; 3, ~ ~: ,~: ..: ~: ` v ~, '~ . -~, a' ~ ~, ~ a o vU, a 'Q ~ ~ o, 3, °~ t °~ ~, ~° U a J -o °' m i : ~ o: ' ~ ~: ~: m ~ ~ o o: ~ o o c m ~~ ~ oo o ar o a o: c Y ~ o: o N, -o ~ ~: o: ~ ~ o~ o, ~ Q ~ U ~ + ~ ~ a a N, v a a ~ ~ ~ ~ a c: : U N a w , « - N ~ ~: `~ ~ N ~ C U • N : c o o' q f ' ~ ~: ~~ ~ N~ p, , ~: ~ : a ~ l6' • . 3. . a' N. p• N' C. L• O a~ d O IO (O ~~ c: C a s N. N T N m. o a~ C, 3. v' rn L, O) c o w a~ C y c Vl ~: O a N N : ~ > ,~ ~ o 0 o a~ >, m lL (~ O' L~ _: 'a, 'O, a~ O ~ c. ~, L, L, L -a w, OA ~ i/Y ~~: N. • N. >~ .~ ~~ L, ~ ~ ~ . O~ ~ U. U. ~ .a, p gip, C, ~. O o, ~, N, ~' «>+ «, ~°, ~ o. L. c c, m, u, 3' ~ o~ ° co o; o; v ~ o' w o' -: 3, a o: N a ~~ f0~ o. ~ m: c a~ c, o. ~ ~ m: ~"' Z o~ ~~ 3: 4- c m: m m. N~ v v v c' m `o' `o' o' m U' E m. v y v' >' v, -, - a;, v =: o, ` ~~ ~ ,~ : d E' - c, v o .~ v m v' a~' ~ c : ~ O o o: • o: o: o a~: ,m c~ m ~ o o o ~ ~ ~: ~ 3: ~ ~ v : ~: •C ° uS: ~ 3 y o: Q ~ ~: J U ~': ~ a ~, ~, ~ ~, a , m, as ~ ~ c ~ 3. ~ c c `ot ~: ~ ~ ' ' .c m `~: ~ ~: c. d; a; o a cLi~ Y` ~; w y, m c. `; f6 ~ a~, c, a °~'; ~ ~, ~ ~; ~' ~' cn ~-; a a ai O' O' a' a~ a' m v - o Q; a' z' ~' o ~, ~; v' cn v ~ , ~ v' v m v, v f6 v, - v - o' O, O, L, m m v o ai y' ~' ~' . a o' vi vi v' ~ , , , , , , , , ; Q, Q, , : w Q O N M R~ f0 I~ OD O O N M V to (p f~ 00 O O N M tY to (O f~ 00 m V O ~ _ N M V ~ CO f~ O m ~ r ~ N _ N N N N N N N N N M M M M M _ M M M M M U r ° O O ~ C C w N r N .tai N U C ~ ~ Q W i ~ Q O 0 M ~ .N N = J N ~ m o~ .J #k Q p c Q ~ g ~ Q p U a a ~ w a ~ ~ a~ • Well History File APPENDIX Information of detailed nature that is not • particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 5 . • 1j-176.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb O1 07:49:34 2008 Reel Header Service name .............LISTPE Date . ...................08/02/01 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library Tape Header Service name .............LISTPE Date . ...................08/02/01 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit, west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: Mw0005126703 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services Scientific Technical Services 1J-176 500292336400 ConocoPhillips Alaska Inc. Sperry Drilling Services 31-JAN-08 MAD RUN 3 MWD RUN 5 Mw0005126703 Mw0005126703 B. HENNINGSE R. FRENCH M. THORNTON F. HERBERT 35 11N l0E 1686 2461 121.55 81.00 Page 1 ~o~-~ ~ c 593 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: ~J OPEN HOLE BIT SIZE (IN) 12.250 8.500 8.500 1j-176.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 13.375 3792.0 10.750 2000.0 9.625 11000.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). MWD RUN 3 WAS A HOLE-OPENER RUN, WHICH INCLUDED DGR, COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). RECORDED MAD POROSITY AND DGR DATA WERE ACQUIRED WHILE POOH AFTER RUN 3. NO FOOTAGE WAS MADE - NO DATA WERE ACQUIRED ON MWD RUN 4. 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 1,2,3,5 REPRESENT WELL 1J-176 WITH API#: 50-029-23364-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17940'MD/3202'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). SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE LITHOLOGY, FIXED-HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). Page 2 ~' 1j-176.tapx PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12.25~~ BIT MUD WEIGHT: 9.1 - 9.2 PPG MUD SALINITY: 200 - 500 PPM CHLORIDES FORMATION WATER SALINITY: 6000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPM FET RPD RPS ROP BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3769.5 3780.0 3780.0 3780.0 3780.0 3780.0 3805.5 STOP DEPTH 17903.0 17895.5 17895.5 17895.5 17895.5 17895.5 17940.5 DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 5 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3769.5 11010.0 11010.0 17940.5 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 Page 3 1j-176.tapx s 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 HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3769.5 17940.5 10855 28343 3769.5 17940.5 RPD MWD OHMM 1.95 2000 44.2315 28232 3780 17895.5 RPM MwD OHMM 0.29 2000 38.7108 28232 3780 17895.5 RPS MWD OHMM 0.13 2000 35.9686 28232 3780 17895.5 RPX MWD OHMM 0.1 2000 33.6933 28232 3780 17895.5 FET MWD HR 0.05 220.83 1.25019 28232 3780 17895.5 GR MWD API 17.55 111.67 66.3637 28268 3769.5 17903 ROP MWD FT/H 1.51 3200.76 294.697 28271 3805.5 17940.5 First Reading For Entire File..........3769.5 Last Reading For Entire File...........17940.5 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 Service SUb Level~Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE NPHI NCNT FCNT and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 6566.5 6566.5 6566.5 STOP DEPTH 10974.5 10975.0 10975.0 Page 4 RHOB PEF DRHO GR RAT MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: 1j-176.tapx 6579.5 10988.0 6579.5 10988.0 6579.5 10988.0 6590.5 10997.5 6604.0 11012.5 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE. BASE 3 1 6566.5 11012.5 MERGED MAD 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 RHOB MAD G/CC 4 1 68 4 2 DRHO MAD G/CC 4 1 68 8 3 GR MAD API 4 1 68 12 4 FCNT MAD CP30 4 1 68 16 5 NCNT MAD CP30 4 1 68 20 6 PEF MAD B/E 4 1 68 24 7 NPHI MAD PU-S 4 1 68 28 8 RAT MAD FPH 4 1 68 32 9 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 6566.5 11012.5 8789.5 8893 6566.5 11012.5 RHOB MAD G/CC 1.089 2.825 2.11508 6408 6579.5 10988 DRHO MAD G/CC -0.106 0.716 0.073062 6408 6579.5 10988 GR MAD API 16.64 107.07 61.9261 6418 6590.5 10997.5 FCNT MAD CP30 467.46 996.69 619.133 6421 6566.5 10975 NCNT MAD CP30 2023.1 3420.37 2345.86 6421 6566.5 10975 PEF MAD B/E 0.36 5.49 1.8591 6408 6579.5 10988 NPHI MAD PU-S -0.75 76.64 41.2299 6418 6566.5 10974.5 RAT MAD FPH -58.77 5103.17 319.666 6417 6604 11012.5 First Reading For Entire File..........6566.5 Last Reading For Entire File...........11012.5 File Trailer Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 Page 5 1j-176.tapx 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.......08/02/01 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3769.5 FET 3780.0 RPx 3780.0 RPS 3780.0 RPM 3780.0 RPD 3780.0 $OP 3805.5 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: STOP DEPTH 10973.5 10966.0 10966.0 10966.0 10966.0 10966.0 11010.0 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): Page 6 27-AUG-07 Insite 74.11 Memory 11010.0 3805.0 11010.0 79.7 85.4 TOOL NUMBER 216262 230192 12.250 2080.0 Fresh water Gel 9.20 51.0 1j-176.tapx MUD PH: g,4 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 3.500 78.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.300 122.0 MUD FILTRATE AT MT: 2.600 78.0 MUD CAKE AT MT: 1.100 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MwD020 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3769.5 11010 7389.75 14482 3769.5 11010 RPD MWD020 OHMM 1.95 2000 17.4712 14373 3780 10966 RPM MWD020 OHMM 0.29 196.96 15.8619 14373 3780 10966 RPS MWD020 OHMM 0.75 128.82 14.7443 14373 3780 10966 RPX MWD020 OHMM 3.42 72.35 12.3212 14373 3780 10966 FET MWD020 HOUR 0.05 112.95 0.724899 14373 3780 10966 GR MWD020 API 17.55 111.67 63.4122 14409 3769.5 10973.5 ROP MWD020 FT/H 1.67 1534.78 294.299 14410 3805.5 11010 First Reading For Entire File..........3769.5 Last Reading For Entire File...........11010 File Trailer Service name... .......STSLI6.003 service Sub Level Name... Page 7 1j-176.tapx version Number. ........1.0.0 Date of Generation.......0$/02/01 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 10966.5 RPD 10966.5 RPx 10966.5 RPM 10966.5 RPS 10966.5 GR 10974.0 ROP 11010.5 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: STOP DEPTH 17895.5 17895.5 17895.5 17895.5 17895.5 17903.0 17940.5 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 r~ L header data for each bit run in separate files. 5 .5000 4 08-SEP-07 Insite 72.13 Memory 17940.0 11010.0 17940.0 86.5 94.1 TOOL NUMBER 97054 96540 8.500 11000.0 Page 8 1j-176.tapx MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 56.0 MUD PH: ,0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 17.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 122.1 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10966.5 17940.5 14453.5 13949 10966.5 17940.5 RPD MWD050 OHMM 9.59 2000 71.9842 13859 10966.5 17895.5 RPM MWD050 OHMM 3.86 2000 62.4072 13859 10966.5 17895.5 RPS MWD050 OHMM 0.13 2000 57.9801 13859 10966.5 17895.5 RPX MWD050 OHMM 0.1 2000 55.8581 13859 10966.5 17895.5 FET MWD050 HOUR 0.11 220.83 1.79496 13859 10966.5 17895.5 GR MWD050 API 26.48 105.45 69.4324 13859 10974 17903 ROP MWD050 FT/H 1.51 3200.76 295.111 13861 11010.5 17940.5 First Reading For Entire File..........10966.5 Last Reading For Entire File...........17940.5 Page 9 1j-176.tapx File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.005 Physical EOF File Header service name... .......sTSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY header data for each pass of each run in separate files. .5000 3 1 VENDOR TOOL CODE START DEPTH NPHI 6566.5 NCNT 6566.5 FCNT 6566.5 DRHO 6579.5 PEF 6579.5 RHOB 6579.5 GR 6590.5 RAT 6604.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CNP SLD STOP DEPTH 10974.5 10975.0 10975.0 10988.0 10988.0 10988.0 10997.5 11012.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMPENSATED NEUTRON STABILIZED LITHO DEN 30-AUG-07 Incite 72.13 Memory 11012.5 6566.5 11012.5 .0 .0 TOOL NUMBER 149206 65396 136422 Page 10 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 1j-176.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 12.250 2080.0 Fresh water Gel 9.20 43.0 9.3 400 4.4 .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 RHOB MAD031 G/CM 4 1 68 4 2 DRHO MAD031 G/CM 4 1 68 8 3 GR MAD031 API 4 1 68 12 4 FCNT MAD031 CNTS 4 1 68 16 5 NCNT MAD031 CNTS 4 1 68 20 6 PEF MAD031 BARN 4 1 68 24 7 NPHI MAD031 PU-S 4 1 68 28 8 RAT MAD031 FT/H 4 1 68 32 9 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 6566.5 11012.5 8789.5 8893 6566.5 RHOB MAD031 G/CM 1.089 2.825 2.11508 6408 6579.5 DRHO MAD031 G/CM -0.106 0.716 0.073062 6408 6579.5 GR MAD031 API 16.64 107.07 61.9261 6418 6590.5 FCNT MAD031 CNTS 467.46 996.69 619.133 6421 6566.5 NCNT MAD031 CNTS 2023.1 3420.37 2345.86 6421 6566.5 PEF MAD031 BARN 0.36 5.49 1.8591 6408 6579.5 Page 11 Last Reading 11012.5 10988 10988 10997.5 10975 10975 10988 s 1j-176.tapx NPHI MAD031 Pu-S -0.75 76.64 41.2299 RAT MAD031 FT/H -58.77 5103.17 319.666 First Reading For Entire File..........6566.5 Last Reading For Entire File...........11012.5 File Trailer Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/01 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/01 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/02/01 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ~J 6418 6566.5 6417 6604 10974.5 11012.5 scientific Technical Services Scientific Technical Services Page 12