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Home My WebLink About198-058Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 T41314END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 17000, 17585, 17693 3 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2026.01.13 16:58:56 - 09'00' Sean McLaughlin (4311) 326-025 By Grace Christianson at 8:14 am, Jan 14, 2026 SFD 1/14/2026 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. Open hole window milling not to exceed 15'. J.Lau 1/16/26 10-407 DSR-1/16/26JLC 1/20/2026 01/20/26 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: January 13, 2026 Re:MPI 2-56A Sundry Request Sundry approval is requested to set a whipstock in the MPI 2-56A wellbore as part of the drilling and completion of the proposed CDR2/CDR3 CTD lateral. History: 2-56A was originally completed as a lower Ivishak producer. It made upwards of 1000 BOPD before being shut in and converted into a water injector to support 2-30. It then injected water into the lower Ivishak at about 5000 BWPD. A CIBP was set and the well was recompleted in the middle Ivishak and converted back to a producer. However, the well made significant rates of water comparable to the rates of water that was injected. Channeling was suspected and a water flow log confirmed there was channeling from the base of the middle Ivishak through the top of the Ivishak. The log only went as deep as the CIBP and was inconclusive on channeling down to the lower Ivishak. It is assumed that the channel persists through to the lower Ivishak based on injection and production water rates. The Ivishak was eventually abandoned behind an additional CIBP and converted to a Sag producer. Since then, the Sag pressure has been depleted and the well barely registers flowrates on well tests. CT stuck a milling BHA while attempting to mill through the one-trip retainer and we believe we sidetracked outside the 4-1/2 liner. CT pulled everything above the 2-7/8 jars and parted the jar assy. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock, MIT, and SCMT across the 4-1/2 liner. E-line or coil will mill the XN-nipple. E-line will set a 4-1/2" whipstock. If unable to set the whipstock pre-rig, the rig will perform that work. See 2-56B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR3/CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to pre-rig, the rig will set the 4-1/2" whipstock and mill 3.80" window + 10' of formation. The well will kick off drilling in the HRZ and top set the Sag River with a 3-1/4" pre-perforated liner. CDR3 will then freeze protect the well and rig down move off to 2-74. CDR3 will return to 2-56B, move in, test BOPE and kill the well. The rig will then mill out the 3-1/4" aluminum shoe with a 2.74" mill. The 3.25" lateral will be drilled through the upper and lower Ivishak. The proposed sidetrack will be completed with a 3-1/2"x2-3/8 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in January 23rd, 2026) 1 Fullbore MIT-T and CMIT TxIA (done, passed to 3850 psi/3708 psi respectively) 2 Coiled Tubing Mill XN, FCO 3 Slickline Drift f/ WS, Caliper tbg/liner. Run SCMT CBL from planned KOP to tubing tail. 4 E-Line Set 4-1/2" Whipstock at 16,580' MD at 180 degrees ROHS 5 Valve Shop Pre-CTD Tree Work 6 Operations Remove wellhouse and level pad. Rig Work: (Estimated to start in February 20, 2026) Reference CDR2/CDR3 Permit submitted in concert with this request for full details. 1 MIRU and test BOPE 250 psi low and 4000 psi high (MASP 3610 psi). Give AOGCC 24hr notice prior to BOPE test. 2 Mill 3.80 Single String Window 3 Drill 4.25" OH to Top Sag River, ~150' (15 deg DLS planned). 4 Run 3-1/4" pre-perforated Liner with aluminum bullnose shoe to TD 5 Release off liner, freeze protect well. Close Tree, RDMO to 2-74 6 MIRU and test BOPE 250 psi low and 4000 psi high (MASP 3610 psi). Give AOGCC 24hr notice prior to BOPE test. 7 Mill out aluminum shoe with 2.74" mill. 8 Drill Build section: 3.25" OH, ~134' (15 deg DLS planned). 9 Drill production lateral: 3.25" OH, ~1387' (12 deg DLS planned). Swap to KWF for liner. 10 Run 3-1/2 x 2-3/8 13Cr solid liner 11 Pump primary cement job*: 20 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 12 Only if not able to do with service coil extended perf post rig Perforate Liner with 1" or 1-1/4" CS Hydril 13 Freeze protect well to a min 2,200' TVD. 14 Close in tree, RDMO. * Alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1 Valve Shop Valve & tree work 2 Slickline SBHPS, set LTP* (if necessary). AOGCC Witnessed MIT. Set live GLVs. 3 Service Coil Post rig RPM, CBL, and perforate (~1000) - see extended perf procedure attached. 4 Testing Portable test separator flowback. Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 _____________________________________________________________________________________ Revised By: GP 1/13/2026 SCHEMATIC Endicott Unit Well: END 2-56A Last Completed: 5/28/1998 PTD: 198-058 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30"Conductor N/A / N/A / N/A N/A Surface 160'NA 9-5/8"Surface 47# / L80 / BTC 8.861 Surface 7,0800.0732 7"Intermediate 29# / L80 /BTC 6.184 Surface 15,9580.0371 4-1/2"Liner 12.6# / 13Cr / NSCT 3.958 15,65217,9880.0152 TUBING DETAIL 4-1/2Tubing 12.6#/ L80 / IBM 3.958 Surface 15,1760.0152 JEWELRY DETAIL No Depth Item 1 1,5744-1/2 SSSV Landing Nipple HES HXO, ID= 3.813 Gas Lift Mandrels Detail 4-1/2 X 1 Camco KBG-2-LS Mod 2 5,101ST 6: Dev.= 60, Latch = INT, TVD= 3,546, VLV = Dome, 4/7/05 3 8,748ST 5: Dev.= 62, Latch = INT, TVD= 5,298, VLV= SO, 11/12/05 4 10,902ST 4: Dev.= 61, Latch = INT, TVD= 6,350, VLV = DMY, 5/28/98 5 12,320ST 3: Dev.= 59, Latch = INT, TVD= 7,058, VLV = DMY, 5/28/98 6 13,699ST 2: Dev.= 59, Latch = INT, TVD= 7,757, VLV = DMY, 5/28/98 7 15,040ST 1: Dev.= 59, Latch = INT, TVD= 8,450, VLV = DMY, 5/28/98 8 15,108 HES X Nipple, ID = 3.813 9 15,119 7 Baker S-3 Packer 10 15,142 HES X Nipple, ID = 3.813, pulled baited prong and plug 10/29/2025 11 15,164 HES XN Nipple, ID = 3.725 12 15,175 WLEG, ID = 3.958, Bottom @ 15,176 13 15,652 ZXP Liner Top Packer and Hanger, ID= 4.25 14 17,000 4-1/2 CIBP (5/9/2013) 15 17,585 4-1/2 WFD CIBP (10/29/2005) 16 17,693 4-1/2 BKR CIBP (7/3/2004) PERFORATION DETAIL END Oil Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sag 16,790 16,850 9,488 9,51160 3/31/13 Open Sag 16,890 16,980 9,526 9,56090 3/31/13 Open UPR IVI 17,400 17,420 9,724 9,73320 10/30/05 Closed UPR IVI 17,410 17,430 9,729 9,73720 11/7/04 Closed MID IVI 17,610 17,630 9,814 9,82320 7/3/04 Closed LWR IVI 17,714 17,904 9,861 9,958190 5/25/98 Closed CASING SIZE / CEMENT DETAIL 30Driven 9-5/82,008 sx Lite Lead PF, 250 sx G in 12- 1/4 Hole 7200 sx Class G in 8-1/2 Hole 4-1/2293 sx Class G in 6 Hole WELL INCLINATION DETAIL Max Hole Angle = 68 deg. @ 16,637 Angle at Top Perf = 67Deg @ 16,790 TREE & WELLHEAD Tree 4-1/16, 5,000psi, Cameron Wellhead 11, 5,000psi, Gen. V GENERAL WELL INFO API: 50-029-22863-01-00 Original TD Reached 3/15/1998 Sidetrack TD Reached 5/17/1998 Original Completion 5/28/98 SAFETY NOTES H2S Readings Average 230-260 PPM on A/L & Gas Injectors. Well requires as SSSV. 4-1/2 chrome Nipples and Liner. _____________________________________________________________________________________ PROPOSED SCHEMATIC Duck Island Unit Well: END 2-56B Last Completed: TBD PTD: TBD TD = 1 (MD) / TD = 9,840(TVD) 30 KBE = 54.7, GL = 14.0 7 2 PBTD = 18,250 (MD) / PBTD = 9,841(TVD) 11 9-5/8 3 4 5 6 7 9 10 12 13 8 ES Cementer @ 1,915' 4-1/2 Whipstock @ 16,570 op protection ng at 16,480 MD 3-1/2 x 2-3/8 XO @ 16,470 Mill XN to 3.80 3-1/4 Pre- Perforated Liner (Protection String) at 16,720 TOL/TOC at 16,105 2-3/8 Solid Liner at 18,293 MD 1 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 30"Conductor N/A / N/A / N/A N/A Surface 160'NA 9-5/8"Surface 47# / L80 / BTC 8.861 Surface 7,0800.0732 7"Intermediate 29# / L80 /BTC 6.184 Surface 15,9580.0371 4-1/2"Liner 12.6# / 13Cr / NSCT 3.958 15,65217,9880.0152 3-1/4Protection 6.6# / 13Cr / TCII 16,480 16,720 3-1/2 x2-7/8Liner 9.3#x6.5#/13Cr/STLxH511 16,105 18,300 TUBING DETAIL 4-1/2Tubing 12.6#/ L80 / IBM 3.958 Surface 15,1760.0152 JEWELRY DETAIL No Depth Item 1 1,5744-1/2 SSSV Landing Nipple HES HXO, ID= 3.813 Gas Lift Mandrels Detail 4-1/2 X 1 Camco KBG-2-LS Mod 2 5,101ST 6: Dev.= 60, Latch = INT, TVD= 3,546, VLV = Dome, 4/7/05 3 8,748ST 5: Dev.= 62, Latch = INT, TVD= 5,298, VLV= SO, 11/12/05 4 10,902ST 4: Dev.= 61, Latch = INT, TVD= 6,350, VLV = DMY, 5/28/98 5 12,320ST 3: Dev.= 59, Latch = INT, TVD= 7,058, VLV = DMY, 5/28/98 6 13,699ST 2: Dev.= 59, Latch = INT, TVD= 7,757, VLV = DMY, 5/28/98 7 15,040ST 1: Dev.= 59, Latch = INT, TVD= 8,450, VLV = DMY, 5/28/98 8 15,108 HES X Nipple, ID = 3.813 9 15,119 7 Baker S-3 Packer 10 15,142 HES X Nipple, ID = 3.813 11 15,164 HES XN Nipple, ID = 3.725 Milled XN to 3.80 pre-rg 12 15,175 WLEG, ID = 3.958, Bottom @ 15,176 13 15,652 ZXP Liner Top Packer and Hanger, ID= 4.25 PERFORATION DETAIL END Oil Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status CASING SIZE / CEMENT DETAIL 30"Driven 9-5/8"2,008 sx Lite Lead PF, 250 sx G in 12- 1/4 Hole 7"200 sx Class G in 8-1/2 Hole 4-1/2293 sx Class G in 6 Hole WELL INCLINATION DETAIL Max Hole Angle = 68 deg. @ 16,637 Angle at Top Perf = 67Deg @ 16,790 TREE & WELLHEAD Tree 4-1/16, 5,000psi, Cameron Wellhead 11, 5,000psi, Gen. V GENERAL WELL INFO API: 50-029-22863-02-00 Original TD Reached 3/15/1998 Sidetrack TD Reached 5/17/1998 Original Completion 5/28/98 CDR2 B ST- TBD SAFETY NOTES H2S Readings Average 230-260 PPM on A/L & Gas Injectors. Well requires as SSSV. 4-1/2 chrome Nipples and Liner. 8,300 Well Date Quick Test Sub to Otis - Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular CL Annular Bottom Annular CL Blind/Shears CL Coiled Tubing Pipe / Slips Kill Line Choke Line CL BHA Pipe / Slip CL Coiled Tubing Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR#-AC BOP Schematic CDR Rig's Drip Pan Fill Line Normally Disconnected HP hose to Micromotion LP hose open ended to Flowline (optional) Hydril 7 1/16" Annular Blind/Shear CT Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross CT Pipe/Slips BHA Pipe / Slips nneeeeeceeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/2/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250302 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# CLU 11 50133205590000 206058 2/19/2025 AK E-LINE CBL,CIBP CLU 11 50133205590000 206058 2/13/2025 AK E-LINE CIBP END 1-65A 50029226270100 203212 1/27/2025 HALLIBURTON COILFLAG END 2-56A 50029228630100 198058 2/6/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 2/2/2025 HALLIBURTON PPROF MPU F-29 50029226880000 196117 1/31/2025 HALLIBURTON MFC24 MPU L-02A 50029219980100 209147 2/17/2025 READ CaliperSurvey MPU L-36 50029227940000 197148 1/18/2025 HALLIBURTON MFC24 MPU R-144 50029238090000 224148 2/11/2025 HALLIBURTON WFL-TMD3D NCIU A-21 50883201990000 224086 2/18/2025 AK E-LINE Perf ODSN-25 50703206560000 212030 2/16/2025 READ MemoryLeakPoint PBU 06-05A 50029202980100 224115 1/15/2025 BAKER MRPM PBU 06-15A 50029204590200 224108 12/27/2024 HALLIBURTON RBT PBU 06-16B 50029204600200 223072 1/25/2025 BAKER MRPM PBU B-12B 50029203320200 224133 1/19/2025 BAKER MRPM PBU S-126B 50029233630200 224084 2/7/2025 HALLIBURTON RBT PBU V-105 50029230970000 202131 2/9/2025 HALLIBURTON IPROF PBU W-01A 50029218660100 203176 1/19/2025 AK E-LINE CBL PBU W-01B 50029218660200 224149 1/28/2025 HALLIBURTON RBT PCU 02A 50283200220100 224110 1/24/2025 AK E-LINE CIBP Please include current contact information if different from above. T40161 T40161 T40162 T40163 T40164 T40165 T40166 T40167 T40168 T40169 T40170 T40171 T40172 T40173 T40174 T40175 T40176 T40177 T40178 T40179 END 2-56A 50029228630100 198058 2/6/2025 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.03 10:15:14 -09'00' OF • • IA* I//7THE STATE Alaska Oil and Gas ®f Conservation Commission f 333 West Seventh Avenue ;; GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®� ALAS� Fax: 907.276.7542 www.aogcc.alaska.gov February 28, 2017 Mr. John Barnes Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-16-024 SCANNED � }1� <<j Defeated Safety Valve System Duck Is . •, i' -a a - 'TD 1950190) _ P uck Island Unit 2-56A (PTD 198058 Dear Mr. Barnes: The Alaska Oil and Gas Conservation Commission(AOGCC) has reviewed Hilcorp Alaska LLC (Hilcorp)'s February 23, 2017 letter outlining corrective actions taken in response to the notice of violation for defeated SVS dated September 14, 2016 and subsequent letter dated October 14, 2016. The corrective actions — handover procedures, standardized defeated SVS tags, visual indicators for hydraulic isolation valves, and installation of quarter turn valves for SVS hydraulic isolation — were completed by February 18, 2017. The AOGCC is satisfied with the corrective actions implemented by Hilcorp which are intended to prevent recurrence of this noncompliance. The AOGCC does not intend to pursue any further enforcement action regarding these Duck Island Unit defeated SVS. Sincerely, :z7 4k Cathy /0i. Foerster Chair cc: AOGCC Inspectors(via email) • • Docket Number:OTH-16-024 Defeated Safety Valve System-Closeout February 28,2017 Page 2 of 2 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. Regg. James B (DOA) From: Bixby, Brian D DOA y (DOA) 0I Sent: Thursday, March 02, 2017 5:46 AM ' r 7 To: Regg,James B (DOA) Subject: RE: Hilcorp Corrective Actions in Lieu of Qtr Turn Valves Jim, I made it out to Endicott yesterday afternoon and looked at these bars on the panels with Kendell(Pad Operator). I'm totally comfortable with this design for a good visual to determine the position of the valves. Even if the needle valve is only a couple turns closed the bar will not fit on them.So a quick glance at the bar and you can tell all the valves are fully open if the bar is in place. I reading the letter I thought they had said they installed /turn valves is the only reason I brought up the issue. Should you need anything else please let me know. Thanks, Brian Brian Bixby Petroleum Inspector Cell 509-998-3683 brian.bixby@alaska.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 Brian Bixby at (907) 279-1433 or brian.bixby@alaska.gov. From: Regg,James B (DOA) Sent: Wednesday, March 01, 2017 12:29 PM To: Bixby, Brian D(DOA) <brian.bixby@alaska.gov> Subject: Hilcorp Corrective Actions in Lieu of Qtr Turn Valves Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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, 1 • • 11 Hilcorp Alaska,LLC John Barnes Asset Team Leader ��' Post Office Box 244027 Anchorage,AK 99524-4027 1 I k 2 L7/1117 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 February 23, 2017 '1 ` Phone:907/777-8350 Fax: 907/777-8351 jbarnes@hilcorp.com Cathy Foerster, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Docket No. OTH-16-024 Defeated Safety Valve System Duck Island Unit 3-09A (PTD 1950190) Duck Island Unit 2-56A(PTD 1980580) Dear Commissioner Foerster, HilcorpAlaska LLC, provides follow-up to our November 18, 2016letter regarding proress on corrective action items for defeated safety systems on END 3-09A and END 2-56A. We have included details on the closeout of all remaining corrective actions. All Corrective Actions Complete as of February 18,2017 Handover Procedures Changes—Completed 9/22/16 as detailed in 11/18/16 letter Standardized Defeated SVS Tags—Completed 11/14/16 as detailed in 11/18/16.letter Visual Indicators for Hydraulic Isolation Valves at SVS Panel—Completed 2/18/17 We have completed our work to verify that SVS hydraulic isolation valves have a clear visual indicator of Open/Closed status at the panel. These indicators will prevent oversight of inadvertently defeated SVS components. Endicott: Endicott SVS panels utilize needle valves for hydraulic isolation of the SVS. Installation of"Valve Open Bars" that can only be installed when needle valves are fully open will ensure clear visual indication of operational SVS at the panel. Any new wells or non-operable wells that are returned to service will either have "Valve Open Bars" or quarter turn valves installed on the panel. We completed the installation of bars on all operable producers and injectors by 2/18/17 Northstar: Completed on 10/24/16 as detailed in 11/18/16 letter. Milne Point: Verified as detailed in 11/18/16 letter. • 1110 Docket No. OTH-16-024 February 23,2017 Page 2 of 2 Quarter Turn Valves for SVS Hydraulic Isolation at Well Tree—Completed 2/18/17: Quarter turn valves have been installed exclusively for hydraulic isolation of the SVS at the well tree to prevent oversight of inadvertently defeated SVS components. Endicott: All SSV control lines were verified to have quarter turns already installed for isolation at the tree. All the SSSV control & balance isolation valves were mechanically locked open with a quarter turn valve stacked in line with the needle valve. Substitution of quarter turns on every operational well at Endicott was completed by 2/8/17. Northstar: SSV and the SSSV control line isolation valves were swapped with quarter turn valves on all wells at Northstar by 12/31/16. A single needle valve was left installed in the cellar below ground level but is not used for primary isolation of the SSSV hydraulic line and is not accessible for routine well work. Milne Point: All but 20 wells at Milne Point already utilize quarter turns for SSV isolation at the tree. We completed swapping the remaining 20 wells to quarter turn valves on 11/5/16. Four wells at Milne Point are equipped with surface controlled SSSVs; a quarter turn valve was substituted for hydraulic isolation at the tree on all four of these wells by 1/23/17. We have completed all solutions referenced in the original October 3, 2016, written explanation. If you have any additional questions, please contact Wyatt Rivard at 777-8547 or by email at wrivard@hilcorp.com. ' nce ely, A CORP ALASKA, LLC John Barnes Asset Team Leader • Regg, James B (DOA) From: Regg,James B (DOA) gg tLZta Sent: Tuesday, November 22, 2016 8:48 AMc-217 To: DOA AOGCC Prudhoe Bay Subject: Defeated SVS - Hilcorp Corrective Actions Attachments: Hilcorp OTH-16-024 Defeated SVS DIU 3-09A (PTD 1950190) and DIU 2-56A (P....pdf There were 2 defeated SVS at Endicott recently.Wrote a notice of violation requiring corrective actions. Hilcorp provided the required response dated October 14 summarizing what they intend to do,which I replied that the AOGCC will not close this enforcement until all corrective actions have been implemented. This is work in progress—attached is a copy of a letter highlighting partial completion of corrective actions;for your review. When at Milne, Endicott, and Northstar please confirm the corrective actions are in place. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 1 • 110 Hilcorp Alaska, LLC John Barnes f I Asset Team Leader Post Office Box 244027 i(r Anchorage,AK 99524-4027 3800 Centerpoint Drive )1 r' ° i Suite 100 November 18, 2016 Anchorage,AK 99503 Phone: 907/777-8350 Fax: 907/777-8351 Cathy Foerster, Chair jbarnes@hilcorp.com Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Docket No. OTH-16-024 Defeated Safety Valve System Duck Island Unit 3-09A (PTD 1950190) Duck Island Unit 2-56A (PTD 1980580) Dear Commissioner Foerster, Hilcorp Alaska, LLC, responds to your October 14, 2016, letter regarding the defeated safety systems on END 3-09A and END 2-56A. We provide information regarding our progress on corrective actions as of November 18, 2016, along with updated timelines for the remaining corrective actions. Progress of Corrective Actions as of November 18, 2016 Handover Procedures Changes—Completed 9/22/16 We have fully rolled out procedural changes to utilize and document function tests of the SVS following wellwork in all three North Slope fields as of 9/22/16. Mandatory function tests following wellwork ensure that inadvertently defeated SVS components are identified and either normalized or properly tagged prior to the well being brought online. Standardized Defeated SVS Tags—Completed 11/14/16 The use of standardized tags will ensure that defeated SVS components are tagged with consistent information as required as by 20 AAC 25.265(m). The bright yellow tags provide a clear indicator of the defeated system and standardization avoids the ambiguity of other types of flagging or caution tags. We have provided and implemented the new tags in all three fields as of 11/14/16. Visual Indicators for Hydraulic Isolation Valves at SVS Panel—In Progress We are continuing our work to verify that the valves used for hydraulic isolation of the SVS system at the panel have a clear visual indicator of Open/Closed status. These indicators will prevent oversight of inadvertently defeated SVS components at the panel. • 1110 Docket No.OTH-16-024 October 3,2016 Page 2 of 3 Endicott: Endicott SVS panels utilize needle valves for hydraulic isolation of the SVS. Installation of"Valve Open Bars" that can only be installed when needle valves are fully open will ensure sure clear visual indication of operational SVS at the e panel. We completed the installation of bars on all operable producers on 11/9/16. We anticipate completion of the installation on remaining operable wells by 1/1/17. Northstar: Northstar SVS panels also utilize needle valves for hydraulic isolation of the SVS. We completed the installation of"Valve Open Bars"on all Northstar wells(with the exception of suspended well NS-26)on 10/24/16. We provide pictures of bars installed on each well panel in Attachment 1. Milne Point: Milne point SVS panels already utilize quarter turn valves for hydraulic isolation. Quarter turns provide clear indication of Open/Closed status. Quarter Turn Valves for SVS Hydraulic Isolation at Well Tree—In Progress: Quarter turn valves will be used exclusively for hydraulic isolation of the SVS at the well tree to prevent oversight of inadvertently defeated SVS components. Endicott: We have begun the process of mechanically locking open the SSSV control & balance isolation needle valves and substituting with quarter turn valves on every operational well at Endicott. We anticipate completion of the installation by 2/1/17. All SSV control lines already have quarter turns installed for isolation at the tree. Northstar: We have begun replacing both the SSV and the SSSV control line isolation valves with quarter turns at the trees at Northstar. We anticipate completion of the replacements by 2/1/17. Milne Point: All but 20 wells at Milne Point already utilize quarter turns for SSV isolation at the tree. We completed swapping the remaining 20 wells to quarter turn valves on 11/5/16, and include the service reports in Attachment 2. Additionally, we will swap the three wells at Milne Point with surface controlled SSSVs to quarter turns for isolation at the tree. We anticipate completion of the replacements by 12/1/16 We will continue providing updates until we have completed all solutions referenced in the October 3, 2016, written explanation. If you have any additional questions, please contact Wyatt Rivard at 777-8547 or by email at wrivard@hilcorp.com. Sincerely, IL ORP LASKA, LLC ohn Barnes Asset Team Leader Docket No.OTH-16-024 October 3,2016 Page 3 of 3 Attachments: 1) Northstar SVS Panel "Valve Open Bar"Photos 2) Milne Point Quarter Turn Well Service Reports „k,ttsichnntnt Wrthstar SVS Pan& "V;Iive OF. Bar” Ph.t.s . .....,..... .,_ ., piCER 0 , . . PRODUCER • f ELL ''-:,. 7:: ' , : ''.- 1 € 1 i I I - 0S ''..:,:- • A'l• N S 0 (7 L.__ •-.''''''.- .7'''F '.' ' t '. -'-':,,- ''.-.. ;,l'.'-_:.,"„--r.,:,.,'",1"'--;.-----2 „" . :. ,- , ''.,.., . -. , , ., ,- , , -,4. -..' ' - - -.;:;.-..'",' --,-•'-''...""1--""';,:f...-.1-, 4 .' - . ' . .., 1,1'''. ---t: ..;:'4,;:.•;:'..1),.....;!--- 4,;,„,r,4;ioi. ,,,,--,;.--°----vg41 . . . , _ . :- . :.-.',.,..,,,,-- -''' ..,1:)5.,::,',.‘,., ,.'.:'',/,,e ,,, ,-., .';'-. --- .._,-=. ----- - •,,,..'''.---' \"-: '; ' '-'i - ''' ., . ' ,-.,-, ',:..`;=----.-tel:•(14 rillk )!' 1'''' ''-•, ''. 6 0 wit ',,,, , , ' , , '1 .., . ( . (Al 10),-.;: ;',,.-•!-.:::, - ;'-: ' . . • -.",„_#!. N --- - -,w.t, i•.!-IF 111:;,,,•.-z.' . , ,,,,,.,,,,r7,-•„,,..„.,:. , • --- - --‘, .....,,,,,;,..., r,,,,,,,,, •,,,,, ---r- ,...-rJ,.--rem:, '-i;,-,----,-;7:-;•,,.....'.... , - . .„.„,. .,, , 4; tie''' .ovr' 6,T.04 voiiii.14,,..1%. •! i „ •,,. A 1 , 1 .,,, ,: ____•-•••,„,„„,...,---- r . . ,.. ... V . r .. . . . , • F ... .. . 1 ELLHOU' L A_ - WE.L110 . CONTROL PANEL • CONTROL214,EL. WELLHOUSE UB-53773C8ILIB-S3-f3o1 ' ' CONTROL PANEL • PRODUCER • . : - ', ' , PRODUCER IJB-S3-„10 . 1 --- ---R- PANEL 1 . PANEL . . '-' INJECTOR , ,....'"4 7"'"---------"----- .I !,..''i• , ',', ,„ : .-,..'3' '..:12,, ;.,,:,,fik''',;rZi't:'.' ;911717:77:711 . ., 1, , r , , ....:?: ,•,,:,,:;,--,,,,.,,,,/,,,,,,-,!„,‘....--2,-;:,,,,,,..1.1 .,:r. .'.:.', ;),- NS- 0 -1,,q,i,k,-:,,-;.,,.k.,,, ;:,-.-,.•,t...'-', / \ . — , .--.. . ., . ...._.,... ,,, • - - \ 0 ':- . .., ,_, I r = I I=I 1 . i4 ' ---.•--.: '. 44... ; i ' ;1. ... , , . - UMW PRODUCER-PANEL' •. • ;i 4•''',.. ... :. ..:-.„Ill COl'INTWO111_°Plj -ASNEL '. ,„........-0. : - - .. ; .. „„1- $'i,41:44t1"..' WB-S3-7312 ',..:".--,T. -4 ., 1 :., -' ''''''.'.i f:\ ' ,'','r,''''''.'.f'r•ir' ;' ' r'rr '''...: 4 ' • ” ''. r ij '1..'''.- ' •,?4,.. P T:14.J.--.E-R .,..,:-, • - ,. ---I . ,: .,, _,,.., \r,.,.,,,,, t . -1-,. '-,;•''',., ' . .i i WELL i'-:=0,!`k:, , , \ I •- -i' ,. ; ', i ir';1,-.,,.,... ,.,....,!, ,,.::i NS-12 ...y . '. - ',i•4.-',,,---.',1.: ' f,4'...;',4i1'44,,-4.4.., .*:"'t.t. k%•'?I'''11"7 ' ' • ;:'"Ii.t.',T.-* ' '.'"-.t.;....',,,,-- r‘_..., •4"., . . 4.. '''' li.",4:,•'' tit.,''.'i...',Ai* ,t,,e;1!,1,;,.4,::--' ., 41 . '.,, -- -.'' , I, f . 440: tt.'&.34). :'4'•".;, .,. lit lit 4t ':-, a :,..„, ..._ . . , Page 1 of 4 Attachment Sorthstar v'SVS Panel "Va or. Bar" Photos ' TRDL PA EL`j — LIB-S3-7314 -I ( C2%;17=:._ ;� ,E_ PRODUCER 5 S E ' PANEL PRODUCER PRv"LCER PANE � z r ,� J k '4.,.'''', 1 � PAIJEL (` at 1- . 3- r rt p + aF r ...,., -- `c 4%, iiii*.- 1,,,',. - `--: ---; I. , : .,a....,,' #_ ,`'r -..v. 'ty v ew.7".* •row' .t4`'t, f \ -I \ w.wrR` . 4r 4 , , � " WELL HOUSE PRODUCER : PRODUCER C©NTROL PANEL PANEL '. PANEL IJB-S3-7317 c :. WEL LWELLINJECTOR ',,NS1PANEL N . texititosi- -1 f6 „. P. t * 0 O . 4 it, , :ifefir., : • N2t k,: PRODUCER PANEL,:5 • PRODU ER WELL 4 1 - PANES ' ,: x �, ' i' • 1 t � -2 - - � _ G b - {.F�� tear wata ,min_. —..-_ Zit ,,.:;a. '. Page 2 of 4 IA'ttachm _,nt i orthstar SVS Pan& "Valve Glip Bar" Photos r3pt+r. ., r---,-- --_. WEU-ioUSE k PRODUCE“NEL CONTROL PANEL : 1,3B=S3 7325 INJECTOR i PANEL --, $f.,. . . , , , _ . .., . , , ... . , .2.-,-...,_---,.--- ...-........4.„.„.n.„--,.- t.,,..,, , ,, ...,.,..:;,,,.., ... . _. __ . ,. . , ,., , , - , L ii-;:ft: '..-,';'.'",-,11-i-;`,J.,'1:1, 11 ‘ l- ,, 1 • .. —: . ,,,�,, .� ,r --- NS-28 GAS INJ �� _- NS-29 s; f6 4 (' WELL HOUSE 1.15-S 2S a� t t '',7', a r, 4 � � wis � s .C i , , -; i' 0 INJECTOR a x 'ti .. j 3 un PANEL 1 . .0 1 ,t -- ' - '' "-''''' liCrit::::311-- --. .2'-. , '11,... -'.(4k, , '', ' . - WELL , �� PRODUCEk PANEL•• �v e,...„....„..,,,,,..,,,,,.,..,0.,,—,,,,,-,,,, NS-31 i WELLHOUSE CONTROL PANEL IJB—S3-7335 I INJECTOR PANEL # } v emu $ ''''0 r t �'..1..'i.:41%4,444 4;.4 r' a 00 EA t ti voanox e{ Page 3 of 4 Attach rn-nt Fthstar SVS Pa ,e1 "Va[ve ® ;ar" Phtt.s -T??DJCERPf.NE. P.RODUCER.PANEL^" } ti 44, Page 4 of 4 Attachment eine Point Quarter Turn Weil twice Reports Well Service Report lideora Alaska.LLC Well B-23 Field Milne Date 11/3/2016 Job Scope Installed Swagelok Quarter Turn Valve WSM Bill Kruskie Crew Supervisor Cody York Service Pr AES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested on wells B-23, B-10 B-09, B-18, B-21, B-15, B-05, B-04, B-03. Fluid Level Tag Operations Log Initial Tbg/IA/OA Press Time Depth Operation Entry Final Tbg/ IA/ OA Press Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 1 of 5 Attachment ine P•int Quarter Tar; ' Jell Qrvice Reports We l l Service Report Hilcorn Alaska.LLC Well F-79 Field Milne Date 11/5/2016 Job Scopl Installed Swagelok Quarter Turn Valve WSM Bill Kruskie Crew Supervisor Cody York Service Provider AES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested (passed) on wells. F- 79, F-86, F-87, F-89, F-90, F-91, F-93, F-94 Fluid Level Tag Depth Operations Log Initial Tbg / IA/ OA Press Time Depth Operation Entry Final Tbg / IA/ OA Press Job Costs Service Company/Equipment Daily Cost Cumulative Total Total Field Estimate Page 2 of 5 Attachment Iilne Poi; ,t Quarter Turn Well frvice Reports Well Service Report11 Hilcorp Alaska,LLC Well G-17 Field Milne Date 11/3/2016 Job Scopl Installed Swagelok Quarter Turn Valve WSM Bill Kruskie Crew Supervisor Cody York Service Provider AES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested. Fluid Level Tag Depth Operations Log Initial Tbg /IA/OA Press Time Depth Operation Entry Final Tbg / IA/ OA Press Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 3 of 5 yttachn e Ie6 <<_ P',int Quarter Turn Wellervice Reports , S-rvsce Report Ililcorp Alnsku.LLC toI_ Imo•P �rcoo 1-1/6. Irieiu Iiviuuiic Iuate I 111.)ILUits Job Scope Installed Swagelok Quarter Turn Valve WSM Bill Kruskie Crew Supervisor Cody York Service Provider AES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested. Fluid Level Tag Depth Operations Log Initial Tbg /IA/OA Press Time Depth Operation Entry Final Tbg / IA/OA Press Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 4 of 5 ttachmentIelne Point Quart-r Turn Well�ervice Reports r ell Service Report Hileorp Alaska,I Well J-18 Field Milne Date 11/3/2016 Job Scope Installed Swagelok Quarter Turn Valve WSM Bill Kruskie Crew Supervisor Cody York Service Provider AES Daily Summary Installed new Swagelok cold temp quarter turn valve/valves on the SSV and function tested. Fluid Level Tag Depth Operations Log Initial Tbg / IA/OA Press Time Depth Operation Entry Final Tbg/ IA/ OA Press Job Costs Service Company/ Equipment Daily Cost Cumulative Total Total Field Estimate Page 5 of 5 .: ?_ ..-._�, _.' ; = r- -r- T ‘,1 1// ' THE STATE Alaska Oil and Gas i.,.� ; Of r c1Hfl - set fiCll!li Commission I �5 y 333 West Seventh Avenue ' 'c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `'� Main: 907.279.1433 ®'1`'ALAW' Fax: 907.276.7542 www.aogcc.alaska.gov October 14, 2016 Mr. John Barnes Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-16-024 Defeated Safety Valve System Duck Island Unit 3-09A (PTD 1950190) Duck Island Unit 2-56A (PTD 1980580) Dear Mr. Barnes: The Alaska Oil and Gas Conservation Commission (AOGCC) reviewed Hilcorp Alaska, LLC (Hilcorp)'s October 3, 2016 written explanation regarding the safety valve system violations on Duck Island Unit (DIU) wells 3-09A and 2-56A.' AOGCC became aware of the DIU 2-56A violation (failure to install a subsurface safety valve; failure to tag the well) after issuance of the DIU 3-09A notice of violation(defeated safety valve system)and advised Hilcorp representatives during a September 19,2016 meeting that it would not issue a separate notice of violation.Instead, Hilcorp was instructed to address the DIU 2-56A violation in its response to the DIU 3-09A notice of violation. In its responses to numerous past notices of violations Hilcorp committed to complete corrective actions to prevent recurrence of the violations at the DIU wells. Recent examples of its commitment include Hilcorp's responses to the defeated safety valve system at Northstar 15 in February 2015,two defeated alternate safety valve systems at Soldotna Creek Unit rod pump wells (January 2014), and the defeated safety valve system at Sterling 43-09X (April 2013). AOGCC closed out these violations based on Hilcorp's commitment to complete corrective actions. Evidence suggests that Hilcorp's emphasis on training its operating personnel and other corrective actions have been ineffective at preventing recurrences at Hilcorp. Hilcorp now indicates that corrective actions may take up to six months to complete. AOGCC intends to monitor implementation of Hilcorp's corrective actions as outlined in the October 3, 2016 response to the notice of violation for safety valve system violations at DIU. For the present, AOGCC will take no action. However,unless Hilcorp has demonstrated to AOGCC's satisfaction by April 15, 2017 that corrective actions sufficient to prevent recurrences of these violations have been implemented, the AOGCC will move forward on this matter. ' Both wells are located on Endicott Satellite Drilling Island • • Docket Number:OTH-16-024 Defeated Safety Valve System October 14,2016 Page 2 of 2 Please direct any questions you have regarding this to Jim Regg at (907) 736-1236. Sincerely, Cathy P. Foerster Chair cc: AOGCC Inspectors (via email) RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. Y • • Hilcorp Alaska, LLC John Barnes Asset Team Leader Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 100 October 3, 2016 Anchorage,AK 99503 Phone:907/777-8350 7-8351 Cathy Foerster, Chair Fax: es©hil907/7orp.co jbarnes@hilcorp.com Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 F Re: Docket No. OTH-16-024 Defeated Safety Valve System Duck Island Unit 3-09A (PTD 1950190) Duck Island Unit 2-56A (PTD 1980580) Dear Commissioner Foerster, Hilcorp Alaska, LLC ("Hilcorp") responds to your September 14, 2016, letter regarding the defeated safety system on END 3-09A. In addition, as per our meeting with Jim Regg on September 19, 2016, we also provide details regarding the removed but untagged subsurface safety valve on 2-56A. Description of Events Duck Island Unit 3-09A Endicott well 3-09A is a gas lifted producer that was shut-in on July 29, 2016 in conjunction with scheduled Endicott plant maintenance that occurred from July 29th to August 20th. During the plant shut-down, a Static Bottom Hole Pressure Survey (SBHPS) was run which required removing the surface controlled subsurface safety valve (SCSSSV) on August 15th The SCSSSV was reinstalled on August 22nd. At 9 am Operations was notified that the well was ready to put on production. The well was then brought online and stabilized quickly. The AOGCC inspector was already onsite to witness SVS and MIT testing on nine other wells. Hilcorp decided to also test END 3-09A at the same time. At around 2 pm, the well was shut in for testing and the Pressure Safety Low (PSL) detection device was bled down until it tripped at 193 psi. Upon tripping the PSL, the Surface Safety Valve (SSV) closed and held differential pressure but the SCSSSV stayed ed ressure y p d up. The SSSV Control Supply Z Valve was found to be blocked in at the panel. The AOGCC inspector was notified and then the panel was normaled and the SVS system retested successfully. Duck Island Unit 2-56A Endicott well 2-56A is a low rate gas lifted producer that was shut-in on March 20, 2016. The well's SCSSSV was pulled on May 24th in preparation for a SBHPS that was logged during the plant shut-down. The valve could not be reinstalled immediately due to lack of redressed valves. The well's wing valve was tagged on May 25th as needing an SVS performance test once returned to production but the SCSSSV was not tagged. On September 9t the well was returned • • Docket No. OTH-16-024 October 3,2016 Page 2 of 5 to production but it was not recognized that the SCSSSV had been removed. An AOGCC performance test was scheduled and the witnessed waived test was performed on September 12th. The SSV tested successfully and then the pressure was bled down above the SCSSSV. There was no increase in tubing pressure and SCSSSV was recorded as a pass on the SVS test form. The operator then attempted to open the SCSSSV but could not pressure back up suggesting a loss of control line integrity. The well was left shut-in and on September 14th operations determined that SCSSSV had not been reinstalled and that what appeared to be a passing test was actually the well dying without the assistance of gas lift. The AOGCC was notified on September 14th of the removed but untagged valve and on 16th . September 16 a SCSSSV was successfully installed. A asset AOGCC witnessed was obtained on September 16th passing SVS test Cause of Incidents Both incidents resulted from failures in the well handover process following downhole well work. When control of the wells' SVS was given back to operations from wireline, the SCSSSV should have been either confirmed as operational or properly tagged as defeated prior to the wells being brought back online. This failure to confirm the SVS system can be attributed to a combination of operational oversight and a lack of a formal procedure. The SVS systems on both END 3-09A and END 2-56A utilize needle valves for the purposes of hydraulic isolation. The open/closed status of needle valves is not immediately apparent and it is possible to mistakenly leave the system in a defeated state. The best way to verify that a SVS system is not defeated is to perform a function test that demonstrates that the PSL, control panel and the safety valves operate. If any SVS component is to be left defeated, our procedure is that it must be properly tagged with the information required by 20 AAC 25.265(m). This did not happen in this case. A function test would have quickly identified the defeated SSSV Control Supply Valve on END 3-09A. Similarly, a function test on END 2-56A following the removal of the SCSSSV would have confirmed the function of the SSV while ensuring the SCSSSV was properly tagged as defeated. Despite the value of a function test following wellwork,there was no formal process in place at Endicott to conduct and document these tests. Prevention of Future Occurrences We have implemented or are in the process of implementing a combination of administrative and engineering solutions across all three North Slope fields to prevent future occurrences: Incident Review Hilcorp has prepared and distributed incident reports of the failures to field operations personnel at Northstar, Endicott and Milne Point on August 31St and September 16th for END 3-09A and END 2-56A respectively. Docket No.OTH-16-024 ! • 16 024 October 3,2016 Page 3 of 5 Use of Hilcorp Alaska Defeated SVS Tags Northstar, Endicott and Milne Point will begin using a standardized tag for defeated safety valve systems. The tag includes all of the information required as per 20 AAC 25.265(m). The tag is already in use in Hilcorp's other Alaska fields. Wellwork Handover Processes Including Function Test of SVS In both incidents, a function test of the SVS system following wellwork would have identified defeated systems that were missed otherwise. Going forward, a formal process has been either implemented or verified to be in place for all three North Slope fields: Endicott Endicott's "Hilcorp Well Release Form" (See Attachment 1) is now required to be used after every wellwork handover. The one page checklist includes a function test of safety system components. If any components are left defeated,they must be tagged. - The form was created following the END 3-09A incident but was not in use during the 2-56A well handover in May. - The form has been rolled out with training provided to both shifts of field personnel on September 16th and September 22nd - Form was used on September 16th and September 17th to check every well at Endicott. Operations verified no other systems were left inadvertently defeated during turnaround well work. Northstar Function testing was the main action item from the defeated SSV incident on NS-15 on January 17, 2015. Following that incident, the "NSI Prod Well Turnover"procedure was modified to include a function testing step. - The procedure was revised again following the incidents at Endicott with the function test also added to a quick reference checklist within the procedure. Milne Point Unlike Northstar and Endicott, Milne Point experiences a high volume of wellwork over many well pads during both day and nighttime operations. To help assist with communicating defeated SVS between pad operators, the existing daily read sheets or "Pad Shift Logs"were modified to include tracking of SVS defeated for wellwork. - Well Numbers are recorded on the logs when wellwork is being conducted and SVS are defeated. - Records of wells with defeated SVS are transferred from one shift log to the next as the pad is passed between day/night operators. - Only when the wellwork is complete and the SVS is function tested, does the record come off of the shift log. • • Docket No.OTH-16-024 October 3,2016 Page 4 of 5 Engineering Solutions for Identification of Defeated SVS Components Operational oversight of defeated/removed SVS components contributed to both incidents. Going forward, engineering fixes will be implemented at all three of Hilcorp's North Slope Fields to help with simple, visual verification of open and operational SVS components. Endicott Endicott has identified several engineering solutions to either improve identification of needle valve position or to install quarter turn valves to be used instead of needle valves. Additionally, Endicott control room software has been modified to track SSSV status. - Needle valves that are used for SCSSSV control and balance line isolation at the well tree will be mechanically locked open and an additional quarter turn valve will be stacked and used for better visual indication of open/closed status. SSV hydraulic lines are already isolated with quarter turn valves. - SVS control panels will have a"Valve Open Bar" (see Attachment 2)installed behind the SSSV Control Supply, SSV Control Supply and Wing Valve Control Supply needle valves when the valves are open. This solution provides a clear visual guarantee that SSV, SCSSSV and wing valve are operational at the panel. o Endicott panel needle valve stems offer —.35" inches of clearance when open and the 5/16" bar will only fit behind the valve handles when valves are fully open(See Attachment 3). o When the well is online, the panel will either have the bar installed or a defeated tag explaining why. o With this solution, needle valves need not be swapped out at the panel to get a visual indication. Needle valves are preferable at the panel for precision control during actuator diagnostics and to prevent crushing hydraulic filters and shocking actuators when opening/closing valves. - Endicott control room board operators now have an"SSSV"or"No SSSV"option for each well in their software. When an SSSV is removed "No SSSV" is selected. If the well is brought online in this state, it flags the operator with a warning regarding the missing SSSV. Additionally, a 14 day software timer can be set as a reminder while waiting on installation of a downhole valve. Northstar Northstar also utilizes needle valves for hydraulic isolation of the safety valves at both the panel and the tree. Identification of isolation valve position can similarly be achieved by installing and utilizing quarter turn valves instead of the needle valves at the tree and utilizing a"Valve Open Bar"at the panel. - Needle valves used for both SCSSV and SSV hydraulic isolation at the tree will be swapped to quarter turn valves for better visual indication cation of open/closed status. - As with Endicott, SVS control panels will have a "Valve Open Bar" to provide a clear, fail-safe indication that SVS and wing valve are operational. Exact dimensions/thicknesses may vary from Endicott design. When the well is online, the panel will either have the bar installed or a defeated tag explaining why. • • Docket No. OTH-16-024 October 3,2016 Page 5 of 5 Milne Point Safety valve panels at Milne Point are already equipped with quarter turn isolation valves for good visual indication of valve position. Any existing needle valves used for hydraulic isolation of the SSV at the tree will be swapped for quarter turns. - Some SSV hydraulic tie-ins for wireline currently utilize needle valves for isolation. These will be swapped for quarter turns. - There are only 3 wells with SCSSSV's at Milne point: MPE-02, MPE-03 and MPF- 99. Any isolation valves on the SCSSSV control lines will also be replaced with quarter turn valves at the tree. Timeline for Corrective Actions Handover Procedures Changes Procedural changes to utilize and document function tests of the SVS following wellwork have been fully rolled out in all three North Slope fields. The distribution and use of standardized Defeated SVS tags is expected to take four weeks. SVS "Valve Open Bar" Installation The fabrication and installation of bars for all well SVS panels at Endicott and Northstar is expected to take three months. Installing Quarter Turn Valves For SVS Isolation at Tree Distribution and installation of quarter turn valves for SVS isolation at the tree on every well at Endicott, Northstar and Milne Point is expected to take six months. Once corrective actions are implemented, a follow-up letter will be provided to the AOGCC confirming completion. If you have any additional questions, please contact Wyatt Rivard at 777-8547 or by email at wrivard@hilcorp.com. Sincerely, LCORP ALASKA, LLC hn Barnes Asset Team Leader Attachments: 1) Hilcorp Well Release Form 2) "Valve Open Bar"Installation at Endicott 3) Open/Closed Needle Valve Measurements at Endicott • • Attachment 1: Hilcorp Well Release Form HILCORP WELL RELEASE FORM Location: Well#: Date: Company: Operation: Contact Info; Personnel: Brief Job Discription: PRE SITE INSPECTION: Location Clean: SIMOPS: Well On line: Visible Spills: Well House Condition: Well Cellar Clean: SVS System On Line: POST SITE INSPECTION: Location Clean: SIMOPS: Well On Line: Visible Spills: Well House Condition: Well Cellar Clean: Roof Doors Closed: Safety System Check List: SVS Panel Operational: Master Valve Open: Main Supply&Return Valves Open: Swab Valve Closed: SSSV Supply Open: Tree Cap Installed&Tested: SSSV Vent Closed: SSSV Tree Control Open&Zip Tied: SW Supply Open: SSW Tree Balance Open&Zip Tied: SSV Vent Closed: IA Gate Valve Open: SSV Three Valve Lined Up To Panel: IA Gauge Valve Open: SSV Fusable Removed: OA Gate Valve Open: PSI.Switch In Normal: OA Gauge Valve Open: PSI.ROOT Valve Open: OOA Gate Valve Open: SSSV Installed and Pretested: OOA Gauge Valve Open: SVS Pre-Test Function Complete: All Bleeds Closed: SVS Panel Valve Open Bar In Place: Any Defeated SVS Are Tagged: REMARKS: Operations Signature: Date: • 0 , ca CI. x ' * CO) x`r. f • .V 3 " w, Y a, W C _ ,.r..r..., r e I 'C CSS i r fe." fa MSIz alb /10,106.101.11111111 Z CO /yMN1wAM� !k rZ 4..4.PT �IWl W1000 1! *"'f FSI 1 '. ' ; ' - o N ..4:,.,,,,.. +�'r ,.a j` U era - ' ( ' ' ill '-'-- 0 s 1` a 15 Tz 4.4 so rinW 44 in a o • • r 4 e. *wl\^\1t 1"11/111;' Pdf/11it",-,_ Cd ` r cu �p w a ''`�sr,(,, OI n 1 A eu > o CC i. v CI Q.) CDm I tr co s w E y �l/t�> 5 .43> U CI -.; :130a:)a ^ i c u u z '' ' ..0.-'441." , a O RiCEIVED SPP 19 2016: Incident Description f. -- Improperly Defeated SVS - Et 1 - Event Date: 26 August 2016 HiIcorp Alaska, LU. u Location: END 3-09A, Endicott Description: The sub surface safety valve (SSSV) was pulled from END 3-09A in support of a bottom hole pressure survey conducted during the Endicott turnaround. The SSSV was reinstalled with Slickline on 8-26-16 and, at 9 am, Operations was notified that well could be brought online. AOGCC was already onsite to witness mechanical integrity testing and Safety Valve System (SVS) tests for nine other wells. 3-09 was brought online while regulatory testing was ongoing and stabilized quickly. It was decided to test 3-09 along with the other wells while AOGCC inspectors were onsite. At around 2 pm, well was SI for testing and PSL was bled down until it tripped at 193 psi. Upon tripping the PSL, the SSV tripped and held DP but the SSSV stayed pressured up. The SSSV was found to be blocked in at the panel needle valve. The AOGCC inspector was notified and then the panel was normaled and the SVS system retested successfully. What Went Wrong: SSSV needle valve was left blocked in or inadvertently blocked after well was released from Slickline. The blocked in needle valve resulted in SSSV being improperly defeated at the panel with the well online for 4-5 hrs, without a tag as required by 20 AAL 25.265. Corrective Action: When a well is released following well work, an SVS function test should be performed to confirm that the SVS is `' , , operational. The function test verifies that a trip r Y; of the low pressure pilot initiates valve closure. It _fi is important to distinguish this "function"test from a State witnessed "performance" test which is done after the well is online and includes 200 psi differential pressure testing of individual SVS valves. I40. , ,I ..,,,1, �: "' N.-, ..r , I. ., At Endicott, following well work, the "Hilcorp Well Release Form" will be filled out by the operator and filed with the lead operator. The form includes a function test. Additionally, Endicott SVS , 4' test procedures have been modified to include a ` `M1: confirmation of function test prior to the performance test if the well had work done. Figure 1:SSSV Defeated at Panel -- .- 0 5 0 0 0 0 0 • zzzz ciiU 0 4.4 v) i cl co) cj >, >" )-, 00 tt d 00O N 00 OD M M N N W C ww V] = Qa C/A k. O O O O 00 N N 00 ��d cop c 'l ® a ti O O N O 0 00 N O C1 00 M 01 0) - 1:1 CID C O. h V .o u v U �° d • 3 . Q 0 .500000 o a� °�' `er •� CO o cQ1.4 -• 4. o 0AQ a = > an c a� � a w n c y A, A o1 v, d wy y o a. O 0.; A ® - o es1 003 a� ,� ❑ O O. '� Q N v O P. 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'v‘ f.. . ill \r,, a lir, 4 "!a �1 (J Q •J �Q "i U O ° 'c, `�`, --) to I a,NS sf+, cz, a) r''' ' s'" L1-- c ho 1:1 tr4".•••4 # as esk (0 40 0 Air:: ni ) z . 4-, ai `� �' ai •' Q ai Q ai Q it) a Q ai ¢ • ai Q O d n# ai 7k 0 ai )- 4 .a ai ) a) +; of L ofi 0 ai i it 0 ai y� a ai -a a0 . a) E a j gi ID fl-, . CD a- m° a7) E ¢- 11°. 0 a OJ E o. co ai E a m w E a a) in I- 0 i— 0 1-- car= 0 1— C i- O 1--. C11-7 0 1---. 0 i= O j 1- Ci {- 0 1- op O 1- ci i- 0 .� g.� ,EP 192016 AOGGC incident Description Well Flowing - SSSV Removed/Untagged Event Date: 12 Sep 2016 Hilcorp Alaska., LLC Location: END 2-56A, Endicott Description: SSSV was pulled on 5/24/16 from END 2-56A in support of a bottom hole pressure survey conducted during the Endicott TAR. The SSSV was not immediately reinstalled due to a lack of redressed valves. Well's wing was tagged as "Needs SVS Test" but SSSV was not flagged/tagged at panel. A note to "State test @ POP" was also left on the state test tracking whiteboard. Well was POP'd on 9/9/16 and an AOGCC SVS performance test was scheduled. The witnessed waived test was performed on 9/12/16. SSV tested good and then tubing pressure was bled down. Tubing did not pressure up indicating a passing SSSV which was recorded on the SVS test form. The operator then attempted to open the SSSV but could not pressure back up suggesting loss of control line integrity. Well was left shut-in and on 9/14/16 operations determined that SSSV had not been reinstalled and that what appeared to be a passing test previously was the well dying. What Went Wrong: SSSV was removed but no tag or flagging was left on the panel. Well was returned to production without either a function test or a tag on the panel for the removed SSSV with the information required by 20 AAC 25.265.m (See Figure 1 for Example Tag Information). Well was AOGCC tested without an SSSV in the hole. Dying well was misinterpreted as a passing SSSV test and submitted to OUT O F SERVICE state as such. Findings/checklist from failure three weeks prior had not yet been fully rolled out. Defeated Equipment/SVS: ® ssv O Detection Device O SSS.J Corrective Action: As with previous failures on END 3-O9A Other: and NS-15, an SVS function test, and the subsequent Reason Out of Service: attempts to "open"the missing SSSV would have revealed the missing valve prior to bringing on the well and state testing it. Because END 2-56A was handed over in May, the "Hilcorp Well Release Form" was not yet in use at the time. Going forward the release form will be used on every well handover and will be used to check the ^35 wells that were worked on over the Endicott TAR to ensure there Date: were no other handover gaps. Additionally, Northstar and Name: Milne Point are instituting processes for ensuring SVS functionality following defeat for wellwork. Figure 1: Example of tag information required for defeated/removed SVS components • • O a o z U . a y N G9 ti etV M bD N C �.m W . c„ "b c/D d O R pu pu , MO i^ C Q+ i.a N Q a it E 0 0 ti 3 ou 0o ii c _ ii a w ts O A g o ;, L....( 0, rt o Cg AO t 4.1 5 c 5 Q N GI a> V H CV M .moi Z a E ' co) Ct CL CA d . ' p CO O G, v, cC ' C% V1 �d .C4 M w ti .4 go N e6 ,b as V) QO o W o a t °J s, n ami o o^ N o > x C4 V) U 3 is 1E0 a). a. , o .� ooE ;. 00 — Oa' • Z N Q O L O o a Z N di r S a� z 6 U .--i © N t r� M la R N W • �a x, F O � Gd as 1114.4 114 ® ay 'V O •-t d *a q Qn ‹_ yg O �U 4 kj N a © a a N E.., C7 � 0 3U rx O C7 O p a a 6 rD al) y w � .d — ,--1w I) O Aa o to ca a) Co ti a w Pb A c CA O a4 CIO Z O• F . tea w '� a a) O ,- Vj O r. F U• v f� �'� ren ^o i w 4) 0 t, O ® a Vim et ? H•ORP WELL RELEASE FOR• Location: ' Well#: Date: Company: Operation: Contact Info: Personnel: Brief Job Discription: PRE SITE INSPECTION: Location Clean: SIMOPS: Well On Line: Visible Spills: Well House Condition: Well Cellar Clean: SVS System On Line: POST SITE INSPECTION: Location Clean: SIMOPS: Well On Line: Visible Spills: Well House Condition: Well Cellar Clean: Roof Doors Closed: Safety System Check List: SVS Panel Operational: Master Valve Open: Main Supply&Return Valves Open: Swab Valve Closed: SSSV Supply Open: Tree Cap Installed &Tested: SSSV Vent Closed: SSSV Tree Control Open &Zip Tied: SSV Supply Open: SSSV Tree Balance Open &Zip Tied: SSV Vent Closed: IA Gate Valve Open: SSV Three Valve Lined Up To Panel: IA Gauge Valve Open: effilSSV Fusable Removed: OA Gate Valve Open: PSL Switch In Normal: OA Gauge Valve Open: SSP PSL ROOT Valve Open: OOA Gate Valve Open: SSSV Installed and Pretested: OOA Gauge Valve Open: SVS Pre-Test Function Complete: All Bleeds Closed: REMARKS: Operations Signature: Date: � E-PAD SHIFT LOG 9/16/2012 Day0 ator:Valle/v Night Operator: Fo r ESP PRODUCTION safe y •WELL CK/HT DT/HR FBHP HZ AMPS FTP I/A 0/A Temp Supported aRp REMARKS System By TARGET E-04S/N 792 57 54 183 a0520,e 800 _ 4 E-06 S/N 1228 50 44 188 5-07 1200 4 E-08 SN 2413-05 700 J 1E-09 S/N 1135 59 56 184 I E-05,E-23 1100 Ni E-10 S/N 24 B-05 1300 4 E-11 S/N 955 57 41 191 E-05,E-23 900 RECE{ VE - E-14 S/N 24 E-07 800 E `/ E-15 S/Y 24 N/A E-13B 700 E-18 SA' 1541 62 21 185 9-25 700 SEF 1 9 201b E-19 SN 814 51 15 185 E-26 800 J h•, r E-20 S/N 24 E-1355 1150 `- IV E-22 S/N 1464 48 39 214 E-05,E-23 1200 E-32 S/N 1098 45 28 206 E-12 1000 system Well CK/HT DT/HR PF Rate Pump IN PSI Pump DIS PSI FTP I/A 0/A Flowing Temp PF Target Suppaoyrted ,E-24A S/N 2571 1299 2048 201 2573 2450 BWPD E-29,S-01SS y E-31 S/N 422 1365 1806 189 2721 300BWPD/ B-02.0-2755 2000 psi . . ,.. . ,, INJECTION _ Salary WELL Choke/ DT/HR RATE FTP I/A 0/A TEMP Supports Target REMARKS System String BWPD/PSI •1 E-02i S 24 XXXX xxxx NI E-03i S 8029 3370B-04•B 0 3 MMCF/D J E-05i W 1223 2018 E-09,11,22 1400/4470 4 E-07i S 2558 2347 8-14,E-07 3000/3000 q E-12i S 276 1073 E-31,E-32 250/1300 li E-13Ai S/SS 24 220 500/1100 J E-13B1 S/LS 24 C-41 600/1250 4 E-16i W 24 B-01513-09 XXXX '1 E-17i S 3804 2551 14-02,K-05 4700/3000 Ni E-231 W 2752 1839 8-09,11,22 2500/3500 J E-25 S 24 N/A E-20 XXXX J E-261 S 956 1855 E-19,B-22 1000/3550 q E-29i S 467 917 E-24 500/1250 LTSI Safety WELL# I/A 0/A safety WELL# I/A 0/A Safety system WELL# I/A 0/A sarety WELL# I/A 0/A System system System E-21 0 N/A ,1 E-Y8 200 60 _ \I E-30 40 N/A N E-33 0 N/A PRODUCTION HEATERS saretyy� Equipment Run VD Hours REASON FOR UNIT BEING DOWN System Hours _ Ni H-4510A 24 _ H-45108 24 1Visual storm water run-off,prod/source WI lines and ADEC 3-phase pipeline inspections by: This includes environmental pad check,visual inspection of well house cellar condition,safety systems valve alignment and check of all piping and tubing for leaks,inspection of berms on pad,daily checks of all overland flowlines that are visable from MPU roads Air volume tank blown down? TIOs entered? Time: Comments: Bot.Left: EB Well Work Safety Syste pass(WSDP,Pilot,SSV,SSSV). Bot.Center: EB WELLS REASON. ' • RETURN V: i 0 NORMAL: SVS FUNGI ION TEST COMPLE I i Bot.Right: EB WELLS REASON: RETURN WELL TO NORMAL: SVS FUNCTION TEST COMPLETE! Top Left: SI WELL# REASON: RETURN WELL TO NORMAL: SVS FUNCTION TEST COMPLETE! Top Right: EB U Document Title: Oduction Well Turnover Following 3rd Partyctivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential Authority: Foreman Custodian: Operations Lead Tech Document Administrator: Document Controls Scope: Production Turnover issuing Group: Operations Nest Review Date: 04/28/2018 1 o0 Purpose/Scope This procedure describes the steps necessary to ensure the well has been left in a safe condition following turnover from a 3rd party and is ready for operations to assume control and monitoring of the well for safe operation and regulatory compliance. As it pertains to this procedure, 3rd party activity is defined as anytime the control of the well is transferred from operations to another entity that may include but is not limited to drilling, wireline, well services, well integrity group, valve crew, grease crew, corrosion group, wellhead vendor, island maintenance, heavy equipment crew, subsidence crew, etc.,. Additionally, 3rd party activity is defined as anytime a person or group of persons works on or operates any component of the well or wellhead system when they are not under continuous visual supervision of the area operator. Mechanical Integrity Testing (MIT) requires the annulus to be liquid packed and pressured up. Following an MIT the annulus pressure is bled down but the annulus remains liquid packed. A liquid packed annulus poses an imminent hazard during a well start up due to thermal expansion of the liquid in the annulus. Intensive local and remote pressure monitoring and a means to bleed annulus pressure are required prior to well start-up. Bleeding of various well gases and fluids occurs on a regular basis during well integrity work. Bleeding of annular fluids to a tank is typically used when the wellbore or annulus must be bled below common line pressure. Bleeding of well pressures to a flowline is the preferred method for safety and environmental reasons. A bleed tank is only to be used when bleeding to the production system is not an option. Return all wellhead valves to their normal positions. If a piping component or valve has been removed and replaced a Pre-Startup Safety Review (PSSR) is required prior to well start-up in addition to this procedure. If the well is to be placed into production, NP-2000 Production Well Normal Startup after TA or ESD shall be used, in addition to this procedure. If work was done from the Master Valve downhole all workers must be SEMS trained and JSA must be conducted prior to beginning work. Document Number: NSI-NP-4100 Page 1 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/Filejrail/ it - DocumentTitle: P ction Well Turnover Following 3rd Party levity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential 2.0 Acrony, l°.s/Definitions TA Turnaround ESD Emergency Shutdown SDS Safety Data System 3.0 Specific Requirements 3.1 Envir•nment.1, Health & Safety Concerns 3.1.1 Environmental Concerns o Follow all company policies, environmental procedures and the "North Slope Environmental Field Handbook". o Use only high-pressure fittings & hoses to bleed pressure from annulus valves. Hoses and fittings must be inspected carefully prior to each use. Hoses with blistering, weather-checking, exposed wire or cloth braid, worn fittings or any other evidence of conditions that may make the hose unsafe must be cut up and discarded. • Always use spill containment materials when bleeding well flowlines. 3.1.2 Health Concerns o Personnel performing these duties shall be familiar with the SDS pertaining to Northstar chemicals. The SDS must be referenced for its properties, hazards, PPE required and the control measures to be taken if physical contact occurs. o For this procedure special consideration should be given to the following: Natural Gas, Crude Oil, Diesel. o See SDS for detailed information and necessary personal protection equipment. The process stream may contain H2S, Benzene or small amounts of process chemicals; however, exposure to a technician performing these activities is not anticipated. 3.1.3 Safety Concerns o Safe work practices in accordance with company policies, procedures and the Alaska Safety Handbook (ASH), are to be understood and followed during the execution of this procedure o High Pressure Document Number: NSI-NP-4100 Page 2 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ •- - Document Title: Production Well Turnover Following 3rd Party ctivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential 3.2 Pre-requisites o All system work permits have been returned to the control room. • All system master cards are closed out 3.3 Equipment, Materials, Tools 3.3.1 Equipment o None unique to this procedure 3.3.2 Materials o None unique to this procedure 3.3.3 Tools o None unique to this procedure 4.0 Key Responsibilities 4.1 Area Operator 4.1.1 Verify valve position checklist is complete. 4.2 Control ':'room Operator 4.2.1 Notify the Foreman that well is in production. 4.3 Safety Advisor 4.3.1 Determine need for Confined Space Entry Permit Procedure Begins on Next Page Document Number: NSI-NP-4100 Page 3 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ tiDocument Title: •uction Well Turnover Following 3rd Partytivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential 5M Procedure/Prot ss I Step Action Signoff 1. Safety Checks 1.1 Ensure that all planned work on the well in question is following 3rd completed and 3rd party workers are no longer Party Activity operating well components. and Turnover 1.2 If the well house is installed, verify the lighting and heat to Operations tracing is working. 1.3 Check the well and cellar area for environmental conditions. Report any findings of non-compliance immediately to the Foreman. 1.4 Check the cellar grating to ensure a safe condition. Working below the grating of the cellar floor constitutes a confined .....\„0 space entry. Consult with the Safety Advisor and the Alaska Safety Handbook for requirements. 1.5 Perform the valve positioning checklist for wells that is attached to this procedure. See Appendix A. 1.6 Flag, tag and note any purposeful valve misalignment on the valve positioning checklist. Communicate the misalignment in shift notes and at shift change. Defeated safety devices are to be logged in the control room. 1.7 Verify the working condition of pressure transmitters with the control room via radio communication. 1.8 Verify the SSSV, SSV and Wing Valve actuates by the open and close buttons at the Well Control Panel and Control room. 2. Post MIT 2.1 Rig up a bleed hose from the annulus to a bleed trailer. Precautions and 2.2 Bleed a sufficient volume from the annulus to ensure Preparation correct valve alignment and pressure gauge and transmitter function and accuracy. 2.3 Verify with the control room that the pressure transmitter is operational and that the alarm points are set and active. Document Number: NSI-NP-4100 Page 4 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ • - Document Title: Production Well Turnover Following 3rd Party ctivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential Attention! Annulus pressure(s) increase with increased flow or with fluid composition changes. Always keep this in mind when adjusting well /CA„T, ' flow or changing the service of a well. Take appropriate precautionary measures to prevent a pressure excursion incident. 2.4 When the well is placed into service, be prepared to monitor and bleed the well continuously until thermal stabilization has occurred. 3. Records 3.1 Sign off this procedure below and hand in to the Lead Tech. END IF PROCEDU, E Technician Signature Date of Completion Supervisor Signature Date of Completion 6.0 Key Documents/Tools/References • PI-S3-ME-0052 sh1 HP Production Wells * PI-S3-ME-0054 sh1 Wells Manifold c Procedures NP-2000/3000/9000 and EP-0300 for production wells c Procedures NP-2015/3015 for well hydraulic ESD system o Valve Positioning Checklist for Wells is located in Appendix A. 7M Comme is Document Number: NSI-NP-4100 Page 5 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ Document Title: •uction Well Turnover Following 3rd Parttivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Normal Procedure Company Confidential Revision/Review Log Annual Authority/ Date Custodian Review Revision Details MOC No. MIApproval 08/01/2013 J Croak J Sharp Version 1 — Latest revision received M Johns J Johnson from BP 0404 03/07/2015 L Kulhavy H Mann Added step to check heat trace and function test SSV and SDV push buttons, removed BP logos references etc 04/28/2015 W Rivard J Stale y Version 2—Convert to Hilcorp: B Bryant y Added 8 checklist items to Appendix A to verify positons of supply/return lines for the SVS hydraulic system 09/01/2016 Bill BryantN Lance Kulhavy 2.1 — Modify step 1.8; added line HAK31-08- items to Appendix A checklist 2016_446 Document Number: NSI-NP-4100 Page 6 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ fl Document Title:•duction Well Turnover Following 3rd Part ctivity Document Number: NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: Version: 2.1 Norma/Procedure Company Confidential Appendix A: VALVE POSITIONING CHECKLIST FOR WELLS All valves to be checked off prior to initial start up and after wireline work. Well Number: Date: Reason for performing check: Valve Position Initials/Date IA 2"lower casing valve Open IA 2"upper casing valve (if there is one) Open IA PT needle valve Open IA PI needle valve Open IA bleed needle valves Closed IA bleed plugs are in place Yes OA 2"lower casing valve Open OA 2"upper casing valve (if there is one) Open OA PT needle valve Open OA PI needle valve Open OA bleed needle valves Closed OA bleed plugs in place Yes Alternate IA Casing valve Closed Alternate IA needle valve Closed Alternate IA plug is in place Yes Master Valve Open Companion Valve Closed Companion bleed needle valve Closed Companion bleed plug is in place Yes Swab valve Closed Swab cap On Tree cap pressure indicator needle valve Open Tree cap bleed plug is in place Yes Manual wing valve on injector Open Choke Closed Flowline PT needle valve Open Flowline PT bleed valve Closed Flowline PT plug is in place Yes Flowline PT root valve Open Flowline PI needle valve Open Flowline PI bleed valve Closed Flowline PI plug is in place Yes Flowline PI root valve Open Flowline highpoint bleed are all valves closed and plugs in Yes place Document Number: NSI-NP-4100 Page 7 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ fl Document Document Title:Number:Suction Well Turnover Following 3rd PartOtivity NSI-NP-4100 Revision Date: 09/01/2016 Document Type: Security Classification: I Version: 2.1 Normal Procedure Company Confidential Is well lined up to the correct header? (producer) Yes Is bleed valve closed and all plugs in place (injector) Yes Are both header valves open (injectors) Yes Hydraulic Supply for Wing Valve Open Hydraulic Return for Wing valve Open Hydraulic Supply for Surface Safety Valve Open Hydraulic Return for Surface Safety Valve Open Hydraulic Supply for Sub Surface Safety Valve Open Hydraulic Return for Sub Surface Safety Valve Open Hydraulic Supply for PSV Open Hydraulic Return for PSV Open Function Test SSSV from the Control Room& Well Control Panel Function Test SSV from the Control Room& Well Control Panel Function Test Wing Valve from Control Room & Well Control Panel Comments /Deviations: (continue at end of next page if necessary) Document Number: NSI-NP-4100 Page 8 of 8 PAPER COPIES ARE UNCONTROLLED.THIS COPY ONLY VALID AT THE TIME OF PRINTING. Print Date:9/16/2016 The controlled version of this document can be found in http://filetrail.hilcorp.com/FileTrail/ • • Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Thursday, September 15, 2016 3:37 PM 9115/1(0 To: Regg,James B (DOA) Subject: Defeated/Removed SSSVs at Endicott Prior to AOGCC SVS Tests Jim, Hilcorp has experienced two recent failures to properly identify defeated/removed SVS components from wells at our Endicott field. If possible, I would like to setup a meeting on Monday morning (9/19/16)to go over the details of these incidents and the corrective actions we intend to put in place. Here is a summary of the two incidents: END 3-09A: Defeated SSSV Supply Valve At Panel Following Wellwork (Pro 1950 VI END 3-09A's SSSV was pulled on 8/15/16 in support of a pressure survey and was reinstalled with Slickline on 8-26-16. The well was brought online at 9am and SVS performance tested at 2 pm.The performance test was witnessed by the AOGCC inspector already onsite to witness an MIT and other SVS tests. Upon tripping the low pressure pilot, the SSV tripped and held differential pressure but the SSSV stayed pressured up.The SSSV was found to be blocked in at the panel needle valve.The AOGCC inspector was notified and then the panel was normaled and the SVS system retested successfully. Defeated valve noted on SVS test form.The well is currently on production. END 2-56A:SSSV Removed But Not Recognized/Tagged Following Wellwork: (PM 1.0*5 v END 2-56A's SSSV pulled on 5/24/16 in support of a pressure survey but could not be reinstalled imm diately due to valve availability. Well was left shut in and tagged for needing SVS test but tag did not mention SSSV.Well was put on production on 9/9/16 but it was not recognized that the SSSV had been removed.AOGCC performance test was scheduled.The witnessed waived test was performed on 9/12/16, SSV tested good and then pressure was bled down above SSSV.There was no pressurization indicating a passing SSSV which was ultimately recorded on the SVS test form. The operator then attempted to open the SSSV but could not pressure back up suggesting loss of control line integrity. Well was left shut-in and on 9/14/16 operations determined that SSSV had not been reinstalled and that what appeared to be a passing test was the well dying. The well remains SI. Corrective Actions: • Well handovers following wellwork will include a function test of the SVS to ensure all valves are properly configured and nothing is inadvertently removed/defeated. • Function tests to be tracked as part of a Hilcorp Well Release Form that is submitted to the Lead Operator after every handover.This Well Release Form was generated following the END 3-09A failure but had not been in use at the time of the END 2-56A well handover on 5/25/16. Use of the release form is now mandatory following all wellwork and will be fully rolled out to all Endicott well operators by the end of the month. • A higher than average volume of wellwork was conducted prior to and during the August Endicott turnaround. The Well Release Form will be used on all wells with work done during or in preparation for the turnaround to verify there were no other gaps in wellwork handovers. • Northstar and Milne Point fields were notified of the defeated valve on 8/31/16. Field specific procedures will be modified to ensure a function test is performed following wellwork to verify the SVS system. Please let me know if Monday morning will work for you or if there is any additional information I can provide now. Hilcorp attendees would be myself and the Endicott/Northstar Operations Manager, Mike Dunn. Thank You, Wyatt Rivard 111':'+If Ito egl E UIfleer 1 0: OM 71-W-.-4,71C: wrivard@hilcorp.com 3800 Ceni.erpoint ,•:,,uit,21400 Ary horz4;e;Al<99503 II p %144,1, 2 .n--r...,:-.. ', .:.°tet..e't': 4*t ..,a-.��: OF 744, 6,1) ITHE STATE Alaska Oil and Gas g _ Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®�, .„;",,, Q. Main: 907.279.1433 ��4� Fax: 907.276.7542 www.aogcc.alaska.gov September 14, 2016 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7142 Mr. Mike Dunn Endicott Operations Manager Hilcorp Alaska LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-16-024 Notice of Violation Defeated Safety Valve System Duck Island Unit 3-09A (PTD 1950190) Dear Mr. Dunn: On August 26, 2016 an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed the well safety valve system tests on Endicott Satellite Drilling Island within the Duck Island Unit pad that were performed by a Hilcorp Alaska LLC (Hilcorp) representative. The safety valve system on well 3-09A was found defeated. Investigation revealed that a valve at the control panel was closed preventing actuation of the subsurface safety valve. The subsurface safety valve did pass the required performance test once the valve was normalized. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system which is a violation of State regulations. Hilcorp is reminded that a producing well must be equipped with a functional safety valve system as described in 20 AAC 25.265: - Paragraph (h)(2) requires a performance test following installation, repair, or replacement of a subsurface safety valve; - Paragraph (j)(1) allows the subsurface safety valve to be removed for a tubing workover, well intervention, or routine pad or platform operation. The subsurface safety valve must be tested within five days after installation; - Paragraph (m) establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was neither a tag observed on Endicott 3-09A that would indicate an inoperable safety system nor was there any reason for the valve to be defeated. Defeating any component of the critical well safety valve system—except as provided in 20 AAC 25.265—will not be tolerated. . • Docket Number:OTH-16-024 Notice of Violation—Endicott 3-09A September 14,2016 Page 2 of 2 Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written explanation of how this event happened, identify when it happened, and describe what has or will be done in the future to prevent its recurrence at Hilcorp-operated fields in Alaska. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue enforcement action in connection with the defeated safety valve system on Endicott 3-09A. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Y A, Cathy '. Foerster Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. 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L.L.:1 ...... rn 5 E r M 41) 1.. . - o < < 0 c < °' = ,a' 0 )...t •• 15 = . -0 lc 7; :...:00 6 • • MEMORANDUM tate of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e elNiic DATE: 8/26/16 P. I. Supervisor FROM: Matt Herrera SUBJECT: Defeated SVS Petroleum Inspector Duck Island Unit 3-09A ' PTD 1950190 • Endicott SDI Hilcorp Alaska LLC On 8/26/16 I traveled out to Hilcorp's Endicott Facility to witness a Mechanical Integrity Test on a well and several miscellaneous Safety Valve System (SVS) tests. Upon beginning the SVS test for Endicott well 3-09A we encountered the subsurface safety valve (SSSV) was "Defeated" on the wellhead shutdown panel. The valve that allows for pressurized hydraulic fluid from the panel to the valve had inadvertently been left closed. The SSSV would NOT have operated in the event the well encountered a "low pressure" situation; the low pressure pilot on this well was set at 190psi which was in compliance with requirements. After documenting infraction and discussing how to prevent future occurrences we tested the well components and all passed without issue. Attachments: None Non-Confidential 2016-0826 SVS Endicott_3-09A Defeated mh.docx 1 ofl U.S. Postal Service" • CERTIFIED MAIL' RECEIPT ru Domestic Mail Only ,-11 For delivery information.visit our website at www.usps.com P- N Certified Mail Fee ca $ rl Extra Services&Fees(check box,add fee as appropriate) 0 Return Receipt(hardcopy) $__ _. in 0 Return Receipt(electronic) $_ __—_—_. Postmark ® ID Certrfied Mail Restricted Delivery $_____ Here CM 0 Adult Signature Required $ C3 0 Adult Signature Restricted Delivery$ ® Postage ._Cl $ `p Total Postage and Fees r..R Mr. Mike Dunn Sent To Endicott Operations Manager rl treetand Apt.No.,or PO Box No. Hilcorp Alaska, LLC CN 3 P.O. Box 244027 ary,Btate,2044a Anchorage,AK 99524-4027 PSI ',, 3600,-", - sr „a., ,.; „ _. ...._,..9. , SENDER: COMPLETE THIS SECTION COMPL ETF THIS SECTION ON DELIVERY 110 Complete items 1,2,and 3. A. Signatur- te.ajefrt It Print your name and address on the reverse X ✓d ' . ,- ❑Addressee so that we can return the card to you. t ® Attach this card to the back of the mailpiece, / D ed by,('''n 4,. Nay.. C of* o, or on the front if space permits. / 2 �' /'' I n.a..to as c� D. Is delivery address different ft m item 1? ■Yes If YES,enter delivery addr s below: 0 No a Dunn 4 ti Mr. Endit� rations Manager i AP 2, 1 2016 Hilcorp.Alaska, LLC P.b. BOx244Q27 i Anchorage,AK 99524-4027 II��ryl 3. Service Type ❑Priority Mail Express® ill'�II�I I II I'I I��I I'�I 1I�I�I �II E��I I 1111 ��I� ❑Adult Signature 0 Delivery MailTR El Adult Signature Restricted Delivery ❑Registered Mail Restricted CWCertified Mail® 9590 9401 0057 5071 0129 35 ❑Certified Mail Restricted Delivery ®'Return Receipt for ❑Collect on Delivery Merchandise 0 Collect on Delivery Restricted Delivery o Signature ConfirmationT"" 2. Article Number(Transfer from service label) tsured Mail 0 Signature Confirmation 7015 1660 ❑®®® 1487 7142 )sured Mail Restricted Delivery >ver$500) Restricted Delivery PS Form 3811,April 2015 PSN 7530-02-000-9053 Domestic Return Receipt i • Regg, James B (DOA) From: Herrera, Matthew F (DOA) Sent: Saturday, August 27, 2016 4:41 PM r To: Regg, James B (DOA) Subject: RE: Endicott Just received email from Endicott Operations I knew one had recently had wireline replacing SSSV and it was this well. Wireline turned the well over to Operations at 0900 8/26/16. 1`) ?C.; 5 From: Regg, James B (DOA) ./ Sent: Saturday, August 27, 2016 11:02 AM NCZ-) perCarm..ce ,frs- 1, + 1 To: Herrera, Matthew F(DOA) Subject: RE: Endicott SVS ��`�� Good memo. Any idea how long this had been defeated? yi,) 555 Me41 te4tAril Per- k TYLAZk. r �V64-roktx dps r � Sent from my Samsung Galaxy smartphone. L „-t.1 k N L-r titdats Original message 14.c(, From: "Herrera, Matthew F (DOA)" <matthew.herrera@alaska.gov> Date: 08/27/2016 6:44 AM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg(cr�alaska.gov> Subject: Endicott Jim Yesterday while SSV testing at Endicott I encountered an SSSV blocked in on a well. I wrote up a Memo for it.The Acronyms are detailed not to insult your intelligence but in the event someone who is not familiar with these terms reads the Memo. Matthew F Herrera Petroleum Inspector Alaska Oil &Gas Conservation Commission Matthew.herrera@alaska.gov 907-659-2714(Slope Office) 907-448-1228(Slope Cell Ph) 907-953-7966(Personal Cell Ph) 1 • • R James ernes B (DOA) RSS Feed: AOGCC Inspection Request Posted on: Wednesday, August 24, 2016 6:59 AM Author: AOGCC Inspection Request Subject: AOGCC Inspection Request - Submission (2016-08-24 06:58:32) Full article link: https://www.jotform.com/submission/347859912451809586 Submission Date : 2016-08-24 06:58:32 IP Address : 107.152.125.154 Type of Test Requested: : MIT SVS Requested Time for Inspection : 08-26-2016 2:00 PM Location : Endicott Name : Larry McBride E-mail : Imcbride@hilcorp.com Phone Number : (907) 7156950 Company : Hilcorp Alaska Other Information: : SSSV's on wells 1-47, 2-58, 2-68, 1-55 & possibly 4-10 were changed out. 1-05 gas injector IA high pressure shutdown switch changed out, and MIT-IA on water injector 3-01. Would you care to witness? View article,.. S,a,i ' ' 3-CgA-- ell- CSr tdc - G,,�x ,45 5 - c1&Iu, • • ct t`/ 1, i Hilcor Alaska, LLC ►` f E 1" � r� -- r John Barn y""44,e ' Senior Vice President ri FEB Post Office Box 244027 C �_ {� 1� Anchorage,AK 99524-4027 February 18, 2015 C� , (thfA6 w-, 4f1 &Ns Commissioner Daniel T. Seamount 174,1 k ICbf , '6441Cil Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 C v(& v c .c Anchorage, AK 99501 _ u in i l Re: Docket No. OTH-15-004 +, urete Defeated Safety Valve System fttff Northstar 15 (PTD 2020540) > !die Pcfi 1. . o,-- tuff Dear Commissioner Seamount: Irl .� 4 We respond to your February 4, 2015, letter regarding the referenced matter. Description of Events NS-15 is a naturally flowing producer that had been shut-in due to a leak in the surface casing since March 28, 2009. On Jan 17, 2015, we initiated preparations to return NS-15 to production including slickline installation of the surface controlled subsurface safety valve (SCSSSV). As per SOP, the surface safety valve (SSV) hydraulic supply line was temporarily blocked during the slickline wellwork. Because of the ongoing well work activities, the valve was not required to be tagged. 20 AAC 25.265 (m). We completed the slickline wellwork on January 21, 2015. As part of the "NSI Prod Well Turnover" procedure, the well operator checked the openlclosed status of SSV supply line needle valve. The valve does not give visual indication and must be manually rotated to check. The operator felt resistance in the valve handle and believed it to be open. He added an orange tie wrap to the valve. Local SOP is that valves that have an orange tie wrap are in the open position. NS-15 was brought on production and notification was made for an inspection. On January 23, 2015, the SVS system was performance tested in the presence of an AOGCC Inspector. The Inspector requested the test be done with the well flowing. The pilot was tripped and SCSSSV subsequently closed but the SSV failed to close. Further inspection of the SSV revealed that the hydraulic supply line was blocked in by the needle valve that was incorrectly tie wrapped to indicate an open valve. The needle valve was then opened and SSV performance tested successfully. The SCSSSV passed the performance test but, in the process of closing against the flowing well, appears to have come off-seat from nipple enough to lose control line continuity. NS-15 has remained and will continue to be left shut-in until the SCSSSV can be reset and SVS system retested. • • Commissioner Daniel T. Seamount February 18,2015 Page 2 of 2 Cause of Incident We determined that a procedural gap exacerbated by an operational oversight caused the failure of the SSV to be in position to close on NS-15. The procedural gap was the absence of a function test to verify proper operation of the SVS components after completion of well work. The operational oversight was a failure to recognize the correct valve configuration. Prevention of Future Occurrences We have undertaken the following steps to prevent future occurrences: Field wide Incident Review: We prepared and distributed an incident report of the failure at NS-15 on February 18, 2015, to field operations personnel at Northstar, Endicott and Milne Point. Turnover Procedure Modification: We found the "NSI Prod Well Turnover"procedure had no provision for a function test of SSV and SCSSSV after verifying valve position. A function test is the best way to verify that the system is returned to an operational state after turnover wellwork. We have now modified the "NSI Prod Well Turnover" to include function testing in step 1.8 as well as eight additional valve positioning checklist items to prevent re-occurrence of this in the future. Training Review: As we did for our Cook Inlet operations, we are preparing a slide deck on SVS care and operation. We will use the slide deck in a supplemental training session to reach all our North Slope operators within the next six weeks. Then we will include the SVS module in our regular training cycle. If you have any additional questions, please contact Wyatt Rivard at 777-8547 or by email at wrivard@hilcorp.com. Sincerely, HILCORP ALASKA, LLC fp/ r ,„— Z.,...,4 ci.,...--____, John Barnes Senior Vice President • . n. 1 44 'rt! th r GS - v i e * � .vrn � ,Mifi 0,4„.„, ,;..t.v 1 Hileorp Alaska,LLC 3 Event Date: 23 January 2015 Location: NS-15, Northstar Island Description: Slickline completed work on NS-15 on Jan 21, 2015. As part of the turnover,the s well operator checked the valve positions including open/closed status of SSV supply line needle valve. The operator felt resistance in the valve handle and believed it to be open. 1 NS-15 was returned to production and4. on January 23, 2015 the SVS system w was performance tested in the 1 . presence of an AOGCC Inspector.The I pilot was tripped and SSSV ., subsequently closed but the SSV failed 3 A to close. Further inspection of the SSV revealed that the hydraulic supply line 11 was blocked in by the needle valve. NS-13 Defeated SSV ;I This constitutes an untagged, .-.,_._-- �- improperly defeated safety system and is a violation of AOGCC regulation 20 9 AAC 25.265. A What Went Right: Operator followed "NSI Prod Well Turnover" procedure and examined r the valve positions prior to returning well to production. 1 What Went Wrong: Needle valves used to isolate safety systems do not give a visual I indication of open/closed status. Every effort must be made to ensure valve is in fact open and not just tight. What Can Be Done to Make it Right: Once all valves are believed to be in normal operating state, a function test of the system provides final verification. "NSI Prod Well i 1 Turnover" procedure has been modified to include SSV and SSSV function test as a final check. G-1 J v j l .. .�i f:,.z,..i,_�.,_. -_.._.._� --..--e...«.w._._.u.—'2-:,. ....`�.�...._' „l Y. w.'t....a. .._..RCL-r';`,11.4_,It TY p T'F ._ • • Hileorn Alasi a, LLC Post Office Box 2-4077 000 - Anchorage,AK 99 524-402 7 3800 Centerpoint Drive Suite 100 Mem") �laa:�,LII Anchorage,AK 99503 Phone:907/771-8300 January 30, 2014 Fax: 907/777-8301 Ms. Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation.Commission State of Alaska 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Re: Swanson River Field (SRF), Soldotna Creek Unit(SCU) SCU 12A-04 (P'TD 1740210) and SCU 41 A-08 (P l'1) 1940850) Safety Valve Systems (SVSs) SCU 24A-09(PTD 1750220) Outer Annulus Pressure Gauge Dear Chair and Commissioner Foerster: We respond to your letter dated January 14,2014, regarding the matters noted above. Your letter directed 1-Iilcorp as follows: - Install an appropriate outer annulus pressure gauge on SCU 24A-09; - provide AOGCC with an explanation of how these non-compliances happened and what has been or will be done in the future torevent p recurrence at Hllcorp operated well sites in Alaska. SCU 24A-09 Outer Annulus Pressure Gauge We are a bit puzzled by the report that SCU 24A-09 was observed to be without a pressure gauge to monitor the outer annulus. SCU 24A-09 did have and has had an outer annulus pressure gauge on it since the well was worked over in January of 2013. I•Iilcorp monitors and records this pressure on a daily basis. We enclose a pressure plot of this well showing the inner and outer annuli pressures for each day. We have noted that our report submitted with the SVS test did not correctly report the reading for this outer annulus at 200 psi on December 9, and we will be submitting a corrected report. Rod Pump Well SVSs Both SCU 12A-04 and SCU 41A-08 are rod pump wells. SVSs were installed on these wells at the time of the rod pump installation in March (SCU 41 A-08) and July (SCU 12A-04) of 2013. Because these wells are both no-flow wells, the SVSs work by shutting down the motor to the pump, rather than closing a valve. The AOGCC witnessed (by Lou Grimaldi) the operation of the SVSs on these two wells in September. As noted in your letter, by letter dated September 24, 2013, the AOGCC approved a • • Ms.Cathy Foerster January 30,2014 Page 2 of 5 variance for all Swanson River Unit wells that are equipped with rod pumps allowing them to operate with an alternate surface safety system, requiring the use of functionally equivalent components designed for rod pump wells which will automatically terminate production. These controllers have two modes: automatic and manual. In automatic mode, the controllers sense the weight on the rod pump rod, translates that to fluid volumes, and adjusts the rate of the pump accordingly. In manual mode, the controller is set to cycle the pump a certain number of times per minute regardless of the fluid volumes. It appears when the respective manufacturers installed them, the controllers were programmed to work with the automatic mode, but were not properly programmed to operate in manual mode. The failures on the two rod pumps were two different kinds of failures, but both were programming failures on the two different types of controllers. SCU 12A-04 Rod Pump Well SVS SCU 12A-04 rod pump is a Lufkin beam style pump with a Lufkin controller. The SVS failure on this well was a programming error in the controller where the shutdown was bypassed in the Programmable Logic Controller(PLC). Hilcorp has not determined how the proper pump motor shutdown operation was disabled in the PLC programming. (To disable this feature, it requires someone with a programming background as it is not a simple switch that can be turned on or off) A function test of this well was performed 4-days prior to the failure and the system acted properly. The PLC was reprogrammed immediately after the failure to properly turn the pump motor off on low pressure at the flow line. All Lufkin controllers have been reviewed to ensure that the proper programming is completed in the respective PLCs. SCU 41A-08 Rod Pump Well SVS SCU 41A-08 well is a Weatherford Rotoflex unit with a Weatherford controller that controls the unit and has the shutdowns programmed in this device. On December 8, 2013, Hilcorp personnel set the controller in manual mode for the first time since its installation in March of 2013. Cold temperatures had caused the wellhead to build paraffin in the tree, slowing how fast the rods ran into the well. The counter weight used on this style of pump was trying to fall faster than the rods. This situation created the risk of surface damage to the equipment. The unit was put in manual mode to slow the speed of the pump. The SVS was tested on the following day(December 9),and the controller did not trip the motor on the low pressure. This was found to be a programming error committed when the manufacturer originally set up the controller. In auto mode, the tag was enabled to shut in the unit on low pressure; however, this feature was never originally programmed for manual mode. This feature has been activated on this controller as well as the other rod pump controllers in the field,to ensure that the low pressure shutdowns work in both manual and automatic. * * * • • Ms. Cathy Foerster January 30,2014 Page 3 of 5 We think it is important to note that neither SVS was "defeated" through the voluntary conduct of the operators or anyone else. The programming errors which were discovered were not created by anyone at Hilcorp or its contractors making a conscious decision to defeat the SVSs. Neither were the SVSs taken out of service during well work, and then left defeated and untagged. We have corrected the programming errors, and reviewed and revised the programming for other similar equipment. I Iilcorp has developed a standard SVS regulatory awareness training curriculum that was rolled out to our field operators in December. This training includes information and operating instructions for the SVSs on the rod pump wells. As with any training program, we have completed the training module for most workers. However, there remain a few individuals who have not yet received the training. We have listed them and directed our field foremen to complete their training. If any additional information for this event/occurrence is required, please contact me and I will get more information as soon as possible. Hilcorp will continue to work diligently with AOGCC to ensure that all the well work we perform will be safe. Sincerely, HILCORP ALASKA, I,LC 07/4 Chad Helgeson Operations Manager,North Kenai Asset Team cc: Luke Saugier Attached: Photo of SCU 24A-09 Outer Annulus Pressure Gauge SCU 24A-09 Outer Annulus Pressure Gauge Readings • • Regg; James B (DOA) From: Bruce Hershberger <bhershberger@hilcorp.com> Sent: Tuesday, September 10, 2013 7:28 PM To: Regg, James B (DOA) Subject: KGSF#1 Non Complince Safety Defeated Device Attachments: SSV- Actuator Photos.docx Mr. Regg On Monday September 2, 2013 Mr. Louis Grimaldi was out to witness our SRU quarterly SSV testing. During this testing KGSF#1 was found to have a needle valve in the closed position causing this safety device to be defeated, we have taken immediate action to replace this needle valve with a quarter turn valve, this valve was missed when we standardized our tubing and valves to provide a more visual approach to help our operators identify a defeated safety device. This well had been SI since spring and in July a leak in the flowline was identified and all piping at the wellhead was closed. The well was brought back into production on Friday August 30th. The SSV was tested on the 2"a The photos show the before and after valve change. We take the SSV system seriously, and we at Hilcorp continue to train and educate our people on the importance of a correctly operating system. Sincerely, Bruce Hershberger Hilcorp Production Foreman Swanson River Beaver Creek Sterling West Fork Wolf Lake West Side • • llilcarp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-402/ 3800 Centerpoint Drive Eii eorp.=11a.ka.!AA Suite 100 Anchorage,AK 99503 Phone:907/777-8300 April 25, 2013 Fax 907/777-8301 Ms. Cathy P. Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission State of Alaska 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Re: Response to Defeated Safety System Sterling Unit 43-09X Dear Ms. Foerster: Hilcorp Alaska LLC (Hilcorp)has prepared this response to your letter dated April 11, 2013 in regards to the Sterling well 43-09X not passing the state witnessed safety valve system(SVS)test on March 15, 2013. This well was a newly acquired well from Marathon (February 1st, 2013). The well had not been on production and did not have a current SVS test (within the last 6 months) and therefore required a SVS test as required by 25 AAC 25.265. The investigation into this incident found the following results: Hilcorp was attempting to bring the Sterling 43-09X gas well onto production as it had over 1,500psi of shut-in tubing pressure and there was a need for additional gas. The well history provided by Marathon from the acquisition indicated that this well had a tendency of loading up with water and did not sustain daily production. A Ililcorp operator attempted to see if they could get sustained production from this well with management's support. When the I-Iilcorp operator originally tried to flow the well on March 5th, it was determined that the flowline was full of ice and the production separator needed some PLC and instrumentation work to be completed. The flowline was treated with methanol, the PLC and instrumentation work was completed and the well was capable of production on March 7th. On March 11,a I{ilcorp Production Foreman contacted AOGCC about performing an SVS test to be witnessed by the state. The well was put into production and the tubing pressure bled down to the pipeline pressure (approx. 630 psi), however did not sustain any recordable production. In accordance with 20 AAC 25.265(h)(4) which allows for a new well to be put into production for 5 days before a performance test is completed following these regulations, the well was left open to production in an attempt to gain sustained production. The operator had tested the valves ability to hold pressure back prior to bringing the well onto • • Ms.Cathy Foerster April 25,2013 Page 2 of 2 production on March 7`h, however a full SVS performance test was not performed by the operator prior to production. On March 15th, the AOGCC inspector came to witness the testing of the SSV on Sterling 43-09X with a Hilcorp production operator and a contract instrument tech. As stated in your letter the inspector immediately identified upon ;�efrakerf arrival to the well that the SSV pneumatic pilot had been pinned opened (bypassed)and therefore defeating the function of the SVS. The operator released the pins attempting to take the bypass out of the system. This did not resolve the bypassed condition. The well was manually shut-in. The system had an electrical system bypass in the PLC that was C 2— not appearing as an alarm in SCADA. The SCADA technician was contacted to help troubleshoot the system. The SCADA modifications were made and the SVS was retested. The following outcomes were found during the investigation into this event. • The newly hired Ililcorp operators that worked these assets were from legacy Chevron and Marathon fields and were not familiar with the SVS testing procedures or the SVS regulations. • Marathon who previously operated this field had one individual assigned to testing the SVS and many of their operators were not familiar with all the aspects of the SVS. • We found several operators working in other onshore fields were also not familiar with the SSV regulations and testing requirements. As a results of these findings Hilcorp is preparing a SVS training that will be developed by field operators, reviewed by management and then implemented and trained to all Hilcorp operators and contract operators working the producing leases. This will initially be delivered by a field operator during the month of May. This training will also become one of the core training curriculums for all field operators. Included in this training will be a checklist of items that need to be checked prior to bringing a well onto production and leaving it unmanned,to prevent violating paragraph (m) of the SVS regulations, as well as proper identification(tags)of any defeated SVS. If any additional information for this event/occurrence is required, please contact me and I will get more information as soon as possible. Hilcorp will continue to work diligently with AOGCC to ensure that all the well work we perform will be safe. Sincerely, HILCORP ALASKA, LLC _41:464,ZlG1i� l.4'ti t c Luke Sau ier Asset Team Leader. North Kenai Team • Prtt iggo5c0 Regg, James B (DOA) From: Larry McBride <Imcbride@hilcorp.com> K7 Sent: Thursday, November 12, 2015 1:14 PM S 742(/o, To: Regg,James B (DOA) Subject: Deficiency Reports Attachments: CORRECTED DEFICIENCY REPORTS.pdf +� Mr. Regg, Guy Cook asked me to pass these directly to you. Thanks Larry McBride Hilcorp Endicott Pad Operator Office: 907-659-6530 Control Room: 907-659-6700 SCANNED ' 2 ,) a.hJ State of Alaska Oil and Gas Conservation Commission Deficiency Report it46- Location: Endicott MPI Date: 1. PTD: 1980580 Operator: Hilcorp LLC Type Inspection: SVS Operator Rep: Larry McBride Inspector: Guy Cook Position: Pad Operator Op. Phone: 907-659-6700 Correct by(date): 11117/2015 Op. Email: lmcbride@hilcorp.com Follow Up Required: yes Detailed Description of Deficiencies Date Corrected 2-56A has a leak from the fittings installed into the termination sleeve of the wellhead adapter. These fittings are connecting the SSSV to the hydraulic panel. „11; Lt.: 6. Operator Rep Signatures: /,/ A, /� � C s•-•c A, AOGCC Inspector ray4• *After signing,a co6 f this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the "Date Corrected”and attach supporting documentation for each corrective action implemented to address the deficiencies. if a follow-up inspection was performed by AOGCC,include the date and name of inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to nnfnrrromrAr,Ir Revised 3/9/2015 • • RPost Office Box 244027 Anchorage,AK 99524-4027 Ji Hilcorp Alaska,LLC L 3 0 20h3800 Centerpoint Drive Suite 100 AOGCAnchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 scpst4E l AUG 2 $ LU itl Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 iq S'-0 SI? Anchorage, AK 99501 5 / „ Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp _ I • Orig • New API WeIINo PermitNumber WellName I WeIlNumber I WellNumber 50029224180000 1931730 DUCK IS UNIT MPI 2-24/M12 2-24 50029218150000 1880550 DUCK IS UNIT MPI 2-26/N14 2-26 50029218470000 1880860 DUCK IS UNIT MPI 2-28/P19 2-28 50029218470100 2010180 DUCK IS UNIT MPI 2-28A/O19 2-28A 50029218470200 2030060 DUCK IS UNIT MPI 2-286/019 2-28B 50029222280000 1911400 DUCK IS UNIT MPI 2-30/009 2-30 50029222280100 1981880 DUCK IS UNIT MPI 2-30A/EI-02 2-30A 50029222280200 2081870 DUCK IS UNIT MPI 2-30B/ME-01 2-30B 50029220840000 1901190 DUCK IS UNIT MPI 2-32/SN3 2-32 50029216620000 1861720 DUCK IS UNIT MPI 2-34/P14 2-34 50029220140000 1900240 DUCK IS UNIT MPI 2-36/014 2-36 50029220900000 1901290 DUCK IS UNIT MPI 2-38/SN1 2-38 50029225270000 1941520 DUCK IS UNIT MPI 2-40/S22 2-40 50029218920000 1881450 DUCK IS UNIT MPI 2-42/P13 2-42 50029217670000 1871190 DUCK IS UNIT MPI 2-44/R12 2-44 50029217670100 1970710 DUCK IS UNIT MPI 2-44A/Q11 2-44A 50029219210000 1890230 DUCK IS UNIT MPI 2-46/Q15 2-46 50029219210100 1961810 DUCK IS UNIT MPI 2-46A/R10 2-46A 50029219210200 1971370 DUCK IS UNIT MPI 2-466/513 2-468 50029226120000 1951660 DUCK IS UNIT MPI 2-48/013 2-48 50029223670000 1930670 DUCK IS UNIT MPI 2-50/U08 2-50 50029217500000 1870920 DUCK IS UNIT MPI 2-52/S14 2-52 50029222180000 1911220 DUCK IS UNIT MPI 2-54/Q12 2-54 50029228630000 1980240 DUCK IS UNIT MPI 2-56/EID 2-56 50029228630100 1980580 DUCK IS UNIT MPI 2-56A/EID01 2-56A 50029220410000 1900520 DUCK IS UNIT MPI 2-58/S09 2-58 50029223750000 1930830 DUCK IS UNIT MPI 2-60/U13 2-60 50029216480000 1861580 DUCK IS UNIT MPI 2-62/Q17 2-62 50029220550000 1900770 DUCK IS UNIT MPI 2-64/U10 2-64 50029220819500 1901130 DUCK IS UNIT MPI 2-66/U12XX 2-66XX 50029223740000 1930790 DUCK IS UNIT MPI 2-665D12 2-66 50029218580000 1880970 DUCK IS UNIT MPI 2-68/517 2-68 50029218990000 1881530 DUCK IS UNIT MPI 2-70/U15 2-70 50029205180000 1801200 DUCK IS UNIT MPI 5-01/SD7 5-01 50029206400000 1811180 DUCK IS UNIT MPI 5-02/SD10 5-02 50029206390000 1811170 DUCK IS UNIT MPI 5-03/SD9 5-03 50029216780000 1861900 DUCK IS UNIT SDI 3-01/N29 3-01 50029223060000 1921210 DUCK IS UNIT SDI 3-03/J33 3-03 50029216240000 1861300 DUCK IS UNIT SDI 3-05/029 3-05 50029219110000 1890120 DUCK IS UNIT SDI 3-07/N28 3-07 50029219110100 1981470 DUCK IS UNIT SDI 3-07A/L29 3-07A 50029217800000 1880020 DUCK IS UNIT SDI 3-09/L28 3-09 50029217800100 1950190 DUCK IS UNIT SDI 3-09A/L28 3-09A 50029218480000 1880870 DUCK IS UNIT SDI 3-11/M30 3-11 50029217510000 1870940 DUCK IS UNIT SDI 3-15/K33 3-15 50029219460000 1890530 DUCK IS UNIT SDI 3-17/J30 3-17 50029219460100 1940460 DUCK IS UNIT SDI 3-17A/J30 3-17A 50029219460200 1971080 DUCK IS UNIT SDI 3-17B/M31 3-178 50029219460300 1980210 DUCK IS UNIT SDI 3-17C/M31 3-17C 50029219460400 1982080 DUCK IS UNIT SDI 3-17D/M31 3-17D 50029219460500 2022470 DUCK IS UNIT SDI 3-17E/K30 3-17E XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available inthe original file and viewable by direct inspection. / ~'~-~--~-~""File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: ~[ Poor Quality Original'- Pages: [] Other- Pages: DIGITAL DATA ~ Diskettes, No. [] Other, No/Type OVERSIZED Logs of various kinds D Other COMMENTS: Scanned by: Beverly Mildred Daretha~~ell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is/ • STATE OF ALASKA a 't ^ . ' - " Ao s 1 - _ xm . AWKA OIL AND GAS CONSERVATION COMMOON REPORT OF SUNDRY WELL OPERATIONS .r 2'1'' 1. Operations Abandon Li Repair Well Li Plug Perforations ✓ Perforate Li Other L Performed: Alter Casing ❑ Pull TubingD Stimulate - Frac ❑ Waiver ❑ Time Extension❑ V — F hf14 /1 Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc , Development 0 • Exploratory ❑ 198 -058 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029- 22863 -01 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034634 EIDR 2- 56A/E101 ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted ENDICOTT, EIDER OIL . 11. Present Well Condition Summary: Total Depth measured 17988 feet - Plugs measured See Attachment feet true vertical 10006.97 feet Junk measured See Attachment feet Effective Depth measured 17000 feet Packer measured See Attachment feet true vertical 9567.66 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20" 94# H-40 38 - 117 38 - 117 1530 520 Surface 7039 9 -5/8" 47# L -80 41 - 7080 41 - 4501.52 6870 4760 Intermediate None None None None None None Production 15919 7" 29# L -80 39 - 15958 39 - 9024.75 8160 7020 Liner 2336 4 -1/2" 12.6# 13Cr80 15652 - 17988 8810.88 - 10006.97 8430 7500 Perforation depth Measured depth See Attachment feet SCANNED JUN 1 8 2013 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 36 - 15176 36 - 8522.56 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" HES HXO SSV 1574 1528.04 SSSV 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: 1 1 3860 1590 380 Subsequent to operation: 525 18369 62 2170 26 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratori❑ Development El N Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil El . Gas L] WDSPIJJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 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: N/A Contact Nita Summerhays Email Nita.Summer BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatu ��'� ® /Z�� f �� !ft Phone 564 -4035 Date 6/4/2013 rte h 6? BBDY4S JUN - 7 10 Form 10 -404 Revised 10/2012 1144 Submit Original Only • • Daily Report of Well Operations ADL0034634 rt SUMMARY ASRC lest Unit 1 ** on inue rom n e we 1 B - • ®u e we END 2 -52 CTU R /U, Tripping in hole Assist CTU W /FCO & Milling 5/8/2013 CTU #9 1.75" coil Job Objective: Milling, Set CIBP «Cont'd from 05- 07 -13» RU, Rih with: 3.13" x 0.94' CTC, 3.13" x 1.57 DBPV, 3.16" x 7.80' Dual Acting Jar, 3.38" x 1.53' Disconnect (7/8" Ball), 3.13" x 1.15' Dual Circulation Valve (3/4" Ball), 3.13" x 10.57' X -treme motor, 3.13" x 0.43' Xrossover, 3.70" x 0.85' Mill; OST = 24.84'. Displaced methanol from coil on the way down. Light tag on 16600. Can go through but PU weight erratic. Dressed area between 16589' to 16583' CTM, Dry drifted. Rih w /PDS carrier (GR /CCL) w13.66" Nozzle to 17150' CTM, Seen no issues at trouble area. Perform coil flag log. Flag pipe (Brown w/ yellow /white) at 17049.8' Electronic 17081' Mechanical. Pooh up to 15,100' CTM at 40' /min. On surface, downloaded the log, made a correction +21'. Rih with: 3.13" x .94' CTC, 3.13" x 1.57' DFCV, 3.38" x 1.53' Hyd Disc (7/8" Ball), 3.09" x .051 X -over, 2.62" x 6.05' Hydraulic Disconnect (1/2" Ball), 3.50" x 1.08' WLAK, 3.59" x 1.70' CIBP. OTL = 13.38'. 5/8/2013 «Job in Progress» ASRC Test Unit 1***Continue from WSR 5/8/13 Inlet well END 2 -56 Outlet well END 2 -52 CTU R /U, Tripping in hole Assist CTU W /FCO & Milling, Pop and Flow well 5/9/2013 Perform 4hr Piggyback after F/O CTU #9 1.75" coil Job Objective: Milling, Set CIBP « Cont'd from 05- 08 -13» Rih with: 3.13" x .94' CTC, 3.13" x 1.57' DFCV, 3.38" x 1.53' Hyd Disc (7/8" Ball), 3.09" x .051 X -over, 2.62" x 6.05' Hydraulic setting tool (1/2" Ball), 3.50" x 1.08' WLAK, 3.59" x 1.70' CIBP. OTL = 13.38'. At flag, corrected depth from 17049.91 to 17071.58, PU to 17000, at the depth, Launched 1/2" ball, Pumped 33.7 bbl until) set the plug. Saw good indication of CTP build. Rih to tag, Stacked 4K on plug. Good set. POOH. 1/2" ball recovered. RD. Left location. 5/9/2013 «Job complete» FLUIDS PUMPED BBLS 238.3 60/40 METH 285 2% SLICK KCL W /SAFELUBE 523.3 TOTAL • • 1 Packers and SSV's Attachment ADL0034634 SW Name Type MD TVD Depscription 2- 56A/EI01 SSSV 1574 1473.34 4 -1/2" HES HXO SSV 2- 56A/EI01 PACKER 15119 8437.03 4 -1/2" Baker S -3 Perm Packer 2- 56A/E101 PACKER 15652 8756.18 5" Liner Top Packer WELLHEAD: // 5000 G en.V END 2 -56A BF ELEV. 16.6' MAX. DEV. = 68 degrees. Ave hole angle 60 degrees 9 5/8" CSG, 47 #, L -80 BTC, 0 SSSV LANDING NIPPLE 1574 HES "HXO" (3.813" ID) ID = 8.681" 7080' , SAFETY NOTES: H2S READMOS AVERAGE 230 - 260 PPM ON AR- & GAS *MOTORS. WELL REQUIRES A SSSV. **°•4-1/2" CHROME MPPLES & LNR GAS LFTMANORB.S (CAMCO-4908.2 -LS) ST MO 1VO DBV VLV LATCH FORT DATE 6 5102 3545 60 DOME INr 18 04/07/05 5 8748 5299 62 SO HT 22 11/12/05 4 10902 6350 61 DMY M 0 05/28/96 3 12320 7058 59 (A M 0 05/28/96 2 13699 7758 59 DMY 14T 0 05/28/96 1 15040 8450 59 (MY Nor 0 0928/96 NOTE ALL OLV HAVE BTM WRBiRAL LATCHES PERFORATION SL819MRY IRff LOG: SPBRRY MIND GR MR ON 05/19/96 ANGL.EATTOPPERF. 6r ® 16790' Iota: Refer to Roduclion DB for historical perf data I I 4-1/2" "X" NIPPLE 15108 SZE SPF INTERVAL OPNMSQZ DATE (HES) (3.813" ID) 2" 6 16790- 16850 0 03/31/13 2" 6 16890 -16980 0 03/31/13 7" BAKER S -3 PACKER 15119 2.5" 6 17400 -17420 0 10/30/05 Baker (3.875" I.D.) 2" 6 17410 -17430 0 11/07/04 2' 6 17610 -17630 C 07/03/04 2 -7/6" 6 17714 -17904 C 0525198 4-1/2" "X" NIPPLE 15142 (HES) (3.813" ID) 4 -1/2" "XN" NIPPLE 15164 (HES) (3.725 ID) 15176 / 4 -1/2" WLEG 15176 4 1/2" TBG, 12.6 #, L -80 BTC, ELMD 15172 .0152 bpf, ID = 3.958" • ZXP Liner Packer & Hgr, 15652 4 -1/2" CIBP (05/09/13) I 17000 �ID = 4.25" F . heel from- rollers�err� 7" Top of 7 window 15958 (03/28/13) ? ? ?? WFD CIBP (10/29/05) 17585 7" CSG, 29 #, L -80 BTC, 15958 FISH, 4"x1.75" 87M NOSE -1 ?77 ID = 6.184" FROM PfRiF GUN (11/07/04) —BKR CIBP (07/03/04) 17693 PBTD 17899 4 1/2" LNR, 12.6 #, 13 -CR NSCT, 1..„,,.) X X .0152 bpf, ID = 3.958" 17988 041E REV BY COMMENTS DATE REV BY - COMMENTS ENDKpTT LINT 05/27/98 GM ORGN4AL COMPLETION 04/23/12 PG/JMD CORRECTS) AR # WBi: 2-56A / E101 07/03104 Batt ADD PT3RF/SET EP 01/1913 FAA'.NND ORG CORRECTIONS PF3RSIT No: 9980580 11/17/04 MOCd1U4 ADD FEW & RSH 04/08/13 AQ/J1D ADPERF&RSH (03131 /13 AR No: 50-029-22863-01 05/10/05 IMFYILH GLV 00(04/07/M) 06/0913 U.YJM) SE74 -12" CEP (05/09/13) SEC T N R E +08/1911 CN1MJrD ADDEDI12SSAFETY y II BPEcpbralion(Alaska) F • • O w �� \ \ I % % r� s9 THE STATE Alaska Oil and Gas h" �� o f L ®Y�S��y Commission �SSI ® KA �. *h; GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS 5. Main: 907.279.1433 Fax: 907.276.7542 Josiah Igwe SCANNED MAR 0 2013 Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 I9) as'� Anchorage, AK 99519 -6612 Re: Endicott Field, Eider Oil Pool, EIDR 2- 56A/EI01 Sundry Number: 313 -069 Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, 1 P9644- Cathy P. roerster Chair DATED this P� day of February, 2013. Encl. RECEIVED • • STATE OF ALASKA FEB 1 X 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION j27.5 2 /3 APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 z : ( 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Poo ;L• ( epair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations Perforate [v�' Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development 0 • Exploratory ❑ 198-058 -0 • 3. Address: Stratigraphic El Service 0 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 22863 -01 -00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? 449 " EIDR 2- 56A/EI01 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0034634 ' ENDICOTT, EIDER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17988 - 10007 17585 9803 17693 See Attachment Casing Length Size I MD TVD Burst Collapse Structural 1 Conductor 79 20" 94# H-40 38 - 117 38 -117 Surface 7039 9 -5/8" 47# L -80 41 - 7080 41 - 4501.52 6870 4760 Intermediate None None None None None None Production 15919 7" 29# L -80 39 - 15958 39 - 9024.75 8160 7020 Liner 2336 4 -1/2" 12.6# 13Cr80 15652 - 17988 8810.88 - 10006.97 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4 -1/2" 12.6# L -80 L -80 36 -15176 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths 4 -1/2" HES HXO SSV 1574', 1528.04' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program is BOP Sketch ❑ Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil 12 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Email Josiah.laweaBP.com Printed Name Josiah Igwe Title PE Signature _ �` Phone Date 564 -4753 2/11/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number )l 3' CYD Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: ' J FIBDAAS FEB 15 2013 Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / Q — 404., APPROVED BY Approved by: P )6,t4-4--- COMMISSIONER THE COMMISSION Date: . - / &j — / 3 O oIudE ivN 11 1 Approved application is valid for 12 months from the date of approval. Submit in Duplicate /' . U` /= 2/13 /13 /7 End2 -56 Adperfs • • AFE# AEINRWOS bp I. m arp �e Memorandum To: J. Bixby /C. Olsen: Well Serv. Ops TL Date: 02 -01 -2013 J.Bixby /R.Liddlow Wire Line TL From: Josiah Igwe Pad Engineer AFE: AEINRWOS Subj: End2 -56 Adperfs IOR: 350 1. S Pull SSSV / Drift and Tag TD with Dummy gun /Caliper Tubing and Liner 2. E Set Halliburton 4 -1/2" Evo Trieve plug /Adperfs 3. S Set SSSV Well Details Current Status SI due to low oil production Last Ink 12/24/09: 1 bopd, 3860 bwpd, 100% WC Max Deviation 68° at ft Min ID 3.813" at 4 -1/2" HES X Nipple Last Tag: 6/30/2012: Tag TD at 17581' sim Last Downhole Op: 6/30/2012: Slick ran static BHP Latest H2S value: 12/24/2009: 150 ppm SBHP/T @10,000 SS 6/30/2012: 4370 psi / 193° NOTES: Endicott is classified as an Elevated Risk pad. . History: • 2 -56 and 2 -56A and its associated plugbacks were all drilled in pursuit of an Ivishak target in an isolated fault block • 2 -56A (Eider) was the only commercially successful well of the bunch, coming online in 1998 at roughly 3,000 BOP /d • By 1999 the Eider well rate had declined to roughly 1,000 BOP /d and was then converted to injection for regulatory reasons. < ? • In 2004 Eider was brought back online as a producer but its previous production rate was never achieved again. The existing perfs were squeezed off and new perfs were added in the upper Ivishak in 2005. In spite of that, water cuts continued to rise until the well became uncompetitive and was LTSI in 2007. • 1 . End2 -56 Adperfs • • AFE# AEINRWOS Plan: • Not all fault blocks in this area contain Sag River, but when they do, they are usually • productive (ie. SD -08, 2 -30B Minke) • The Sag River in the Eider well does not appear to have been tested but the cuttings from that depth had some fluorescence; also the open -hole resistivity response is • indicative of oil Obiective: Is to isolate the Ivishak perforations with a plug and shoot Sag perfs to make this well • competitive again. . 444 41 a eeiA � . PL ® ,c. ./G` i ce/ kt-,7 1:64 44e7 Contact: Josiah Igwe Wells Engineer Office / CeII: 564 - 4753/590 -0610 Converted injector to producer > 05/04/04: Set LGLV design > 10/31/04: Drifted tubing with 2.5" cent > 10/28/05: CT noted IA appeared to be tracking tubing during job > 10/29/05: Calipered tubing, indication of possible TxIA comm during CT job; 382 jts 0 -10% > 11/04/05: TIFL Failed, IA inflowed > 11/12/05: C/O OGLV sta #5 > 11/17/05: TIFL Passed > 02/08/07: TIFL Passed > 02/11/07: TIFL Passed 1.S -Line Procedure 1. MIRU Slick Line 2. Retrieve SSSV at 1574' and 3. Drift and tag TD with dummy gun and 4 -1/2" Evo Trieve plug / TEL. 4. Caliper tubing and Liner from TD to surface 5. RDMO 2. E -Line Perforation Procedure 1. MIRU E -Line. 2. MU tool string with Halliburton 4 -1/2" Evo Trieve plug 3. Log up hole and set plug at 17,000' md. • Tie to SLB CBL Dated 27- Feb -1999( please the note 7' correction with the reference log) • Note that the Evo -Trieve plug max OD is 3.668" 4. At surface MU tool string with Perforating Gun /GR /CCL 2 End2 -56 Adperfs • • AFE# AEINRWOS 5. RIH w /BHA, 30' gun 2506 PowerJet Omega HMX, 6 SPF 60 deg phasing. o Note Max. diameter of gun in liquid /gas after shot is 2.787 ? ? ". ( Make sure there is enough fluid at the shooting depth since there is no record of it expansion in gas) 6. Log up hole to correlate depths. 7. Perforate interval (16,790' — 16,820'), POOH • Note any tubing pressure change in the AWGRS summary • Tie to SLB CBL Dated 27- Feb -1999( please note the 7' correction with the reference log) 8. At surface MU and RIH SLB 30' gun, 2506 PJ Omega HMX, 6 SPF 60 deg phasing. 9. Log up hole and perforate the interval (16,850' - 16,820'), POOH 10.At surface MU and RIH SLB 30' gun, 2506 PJ Omega HMX, 6 SPF 60 deg phasing. 11. Log up hole and perforate the interval (16,920' - 16,890'), POOH 12.At surface MU and RIH SLB 30' gun, 2506 PJ Omega HMX, 6 SPF 60 deg phasing. 13. Log up hole and perforate the interval (16,950' - 16,920'), POOH 14.At surface MU and RIH SLB 30' gun, 2506 PJ Omega HMX, 6 SPF 60 deg phasing. 15. Log up hole and perforate the interval (16,980' - 16,950'), POOH 16. POOH, RD E -Line. 3.S -Line Procedure 1. MIRU Slick Line 2. Set SSSV at 1574' and 3. RDMO 3 • End2 -56 Adperfs • • AFE# AEINRWOS mollINIIIIIIIIIIINIM mom G, _ Eli - - M - - . Elinor li NINUNINININNINNIMINIMININNIum my** -. INININNIMINI NM= NNW 11 NINNEU M WI.' 1 al21.1=== El t 1 -. - -_— . - - - -- - �. -� - -_ mama __- -_.. —_ 1 1 IINNIM=140111111 UM UM NM MIN INNUA MIEN INNMMM MN 111111=NIMINNIN IN mama as INN 111111.11101111011111111111.1S NM ININ ... Er - -�� It -- - - -_ -� _1 INNEINNINNII MOM INN - �� I ' Mims ININIONNI INNINNINNIM NON r ........momMimilami asap- NM 111111111111 MIN MININININIIIIII IMIONINMININ _ _- -- -- - - - - - - _ Ir_ {r I— ---- - - - --. .... Tie In Log: SLB CBL Dated I�in gar - -- ir - - - -- - iii s w 27-Feb-1999 16, 790' - -� - - - -- i 16,850' - - - m - - mi n - �MI N MI ' . INIMINNIIININ IMINI .N-- -- __ -- imm - -"" ° - MN -- -NM- "' mainimpum ...... _I I MN MUM 111 1 ENE 1111111 ENV NINN MN 10111111111111111111NIN NI •1111111111111111St NE NM NMI EMI MIN 111111M1111111111Min EN um IHIN MI 'AMMON'S El 1111111111111111111111111111M INIMININININ MUM INN INN MI NM MN NNW mu MIN MUM NIMUM NMI mu mu um MN II N - - - - Nib - = MUM ----- -mana1 11111.1111111. _ • __ - - ant - - -- - --� - um - -___I -- -- Imo_ R - - - - - -- __mil - -N --- ___ - -_f . --- _— r��ll-- _ -- - -___I Imm NM NM WM an UNIMMI MIN -� -L ------ N-- -__- _I—__- - I- _ -_ -- -_ -I - - -- - - - - - -- I__ -_ ..... r!" - - - i --- .�.—_ -- ---- -____. -- - - - --- -- _MI -- - -- _ — M - NM MUM - - - - - - - -_ _ WM UN -- - -- --_ -- — - - - -- - _--- - - -- - - M UM — r _= _ sw__ -E um Ns —um me mum as an am umsameamme rte ININUMNINIMININI NOM= NOM NM INN NW NM NW moNIIIIIIIIIIIIIIIM IIM moNNIMI r....- - -_M --MI -- - - - -- ,rte.. ■I_I_ --"— - - -� -NAM c M_. — .. - _.�M - - - s I- �i -- - -� Liiii -iii - �rl -�a�_ -rm— -- - _ - - - - -R - -- �_irr - -- r NMI -- — - - --- - - - - MM. -- -- MN NOM NINININNINNIMINUNIN MINIMUM. IMININININNIMMIUMN NIMININIININNINI INNUNNUNININIM NM 51111111111111 MINIM . IMim NA INIIINNIONIMOINIt 11111111111N MOM ummonsimm um mum man am 111111NIIIMINUM, - —___fit - - -- - - - - -N� - - -- - _ _. w= - - a = - - =€ _ - - - - - alma - g- 4 End2 -56 Adperfs • • AFE# AEINRWOS 11111111■1111111111111111111111111 MI I= MI 1211111111Iwm MN 1111111111111111111111M111111 iml11111111111111■11111111111111111111111111mo ..._ —iii -i — S � __ = -- - - - - =M - - -- -_ "'MIS _-- __ _ ∎amam" mo nu� Oc..... T ��.. Miss= um = __ —_ -- nalammo .._ . g ___ l imum11111111111111111111NIK11111 1111111111111111111111111111•11111111111 NUM - -- =_ - - -- - -M �� IIIM NNE I IIIIII NM MIN MI 1 — -�� :mss =� � MI MINN _It _ ____ M_On M NM __ - - - - - -- x� _ _I_..�� M - --- — ---- - -- - -- -- El El u.__ ____ MIll MI INN - =1111111.11111111111111111111111 111 111 orniommuseam NEE _. === Tie In Log: SLB CBL Dated : . C � au in" 27- Feb - 199916, 890' - - - 1 6, 980' •—___ : = ■ • 111111111111111111111111111111111111611111111111111.111 ___ _ MNIMIIIIIIIIIIII MEN i �___�r___ � __ 11111111111111111111/1/ NMI =�� -� , �� -- -- _ s NMI MN ��_�� a Ems 111111111111111M14111111111111111111111111. Mt MIMI= IIIIII*IIIIIM MI 11111111111111111111111111 =�= s_ ___ NMI r no ors —wp Halliburton Evo Trieve plug in B -_� _..:_ , - - to be set at 17,000' = C"� �i __ —_ !� „4, - Mis___1_= ��r � i fi - - -_ __ _ r: au -- - -- -- - -- -� - - - - - :: - - -- '-- =Mg MEM _ _ ___ VIM 1111111111111111111111111111 _ __ --- .1111111_ - -- .. MIN ES MIIIII NM 1111111111111111111111111•111111111 IIIIIIIII MU Mil NM um am IIIIM _ _.�1a._, EMIR= a_____Mali IIIIIIIIIIIIIIIIIIIIIMINNIM/11111111 iii lg. IIIMINIIII=ImiN0 MA 1111111 M11111.11111INE MIN MINIM Mil WII MB SE MIMI - - - --- - -- - -- .. � NS mommiiiIIIIMEMINSIMMIIIIIIIIIIP mmo� - - -� - - -" -- -1- -- ��MI �z - - - - -- : MUM IIIIIIIIIIIIIM MI EMIIIM MOW I M11111111MINNI 111111111 MEIN IMINI MI MI EMI me _Mir - --- -__ 5 End2-56 Adperfs • 410 AFF.-- AEINRWOS ' COM PA il T: BP EXPLORATION (ALASKA), INC. 1 ' WELL: 2-56A/EIDER-01 , FIELD: ENDICOTT BOROUG H: NORTH SLOPE STATE: ALASKA CEMENT BOND LOG 1--- -K S ,__. SLIM CEMENT MAPPING w .. Sclikatterger L.. TOOL, 27-FEB-99 F 31M' F8L A "....UT I EL AI f..;(1r1F.20:1C. EIFA... KB. ;IL. 14' 0.) _ 2 ..,.., E 1 .2..,-, r 8 [....' ... .r-- tr J.F. M.7 r .-- P9ml.un9rit Datum - I ng Illeaskrteri r/ccra: 54.7 F n.: love Perm. ..)5.1urn i 1. ..D :;. c ;Alarm': Mee.cmit-.J Fro •r . AKA -I b u _ , , ____ _____ E 0 . ti k's , c, .( API Snrj3.1 140 FEGTION TCTIUNSHIP I-AWE ,-.' 6 : -, 5; 0 bl 35 12N 1GE Loggi ng 0.1xe. 27-FF. ' . ... .....,.... RUn Numbs, 1 _ * ... 17nryth Urper 1 F *gear Popt., 17e..66' 4-*".4.--..... iulf nP11,-,NI Intiritil I /BM r — - 7:1114AL — ' 4 ropiog intmfil CI t . CASIN, Fluid fypc SEPAYA I PR DenWv _ . . _ . _ _ _. _ ____ ___ 1 id Leif.; , erricosiNG,TI.eiNG ST R 'NG __ __ — _ ilit Sle OX IN _ RINI T.." CasingTubing $14 _ __...... ____ ■3(ct i ' Weit _ _ _ - 2.0 LIPP Grlde iirvEti _.. _ Fri= 1 I 9:1%1 To iTAA _ mason urn ReeexclOd rernPer**K 1. ower On Bon I Tulle 27-1:EB- liFtr/ , 13 I_ Ira Nirrn ber . noacluri 2- x PRIJUIHOF EU 1 — - flared 5. I Au...DRE Wirrie_sed P.R1..1 I 6 End2 -56 Adperfs • • AFE# AEINRWOS TREE: d. u 1ff' r 6000 p sd catmint., au ELEV.. 60.1' TE I1 IEA t1 p1iil r,1/ EN D2 -56A aF Elmo. 14,10' II MA1( t)EV. 06 degree.. Am he angle 00 ! 5IW C5ETii 471, L40 DTC, O Sssv LANDSIGIO1PLE 1574 FES IOC' (asea ID) ID= L661" 1 I SAFETY NOTE&F REA�ICB AVERAGE 234 - 261 PPM OH AIL L GAS MB[`T1096. WELL REQUIRES A My. ''•4 - 112' CHROME 1EPPLES 6 UR. OA 51.1-1 1441104.L131 CAMCQ11131122.8) 51 1.0 TVO LLV YLV LA1 PORT DATE 5 510 205 60 T1 T" 11f 12 DiNR10 5 7 5 SO 08 <05 82 SO 117 2"a 71!1205 4 ;11503 63511 61 M( INT 0 1501; 3 ' 12310 1051 51 W! 111 4 5322191 2 `;1369 7759 59 CAR erf 6 05126/95 1 .15440 8450 59 Dor e1T 0 551 'S& 1137E ALL QUi WAVE BT INIH3RAL LATCHES TERTOLb11ION SWARM' 1 LTG( 5143134( 1ASM3R 0R i]N ce(19191 AM4LEAf ISW I4 0t: 6B'¢4114001 I 1 Note Refer to FTVtlur km DC Tor 18slatpad 4 l p dab I I 3C wpm 55105 ALE 511- !M U& CAW *A2G LATE (4ESS) csIST D) 25" 6 17400 17436 0 19131015 2' 6 1741D -17430 0 1110701 ® T 00111PACKER tt S 3 PAC I 6 17615 -17530 C 57 Sekw(3 2,417 6 1(714 -1(954 !: 113,RIl96 I I 4407 PIPIT 1 15142 414ES) (3.612r ID) I I 4,-or nor NIPPLE I 161 SS I r 41 ') °) 13178 4!176 r 1A" TED,1141 LA! BTC, EWD 15172 .013'1 6pf, tQ stair 270P LilerPaliuer i Mgr, 1 13652 I d :433" 204, L ° B1c,, 1 -'11 �riaw 143636 1 r ID 11 &164" I WFD CEP (I 0(18105) I 17315 I 4fibr fL°.1 e , 4':175'OTLI NftRF o ?a = I FROM PEW CAIN 111e0,4614:, r, 1 - ' 4 . (07103$4) I 7 PRID 171106 n (\ 4 V31'U*, 13.Ctt NWT, K 5C k .0152 bpi, ID :1950" 17860 fATF FFV SY nl1s.FFr1.5 114TF 14V RV CIAI FNIS RJXX1ITIA4T ._ . 05227,16 GA 'OFJC.WALCOMP.EI1014 08 ;1511 TOMEI ADOED1ESSAFET( WELL. 2{8111('_101 minx 4 I3101L ADD 1454 5EI 13' 0410(1217IJAV 001453.7Fil A S Fli AI M: 10 FJe11250 1171flc4140e7TIJ ADD PERT MC 2111:.113 RAND D13300Fd'SO/101Ca AR Na: - Q33.22003 -01 05004E fall L91l GI V Cfl 0107405) : T N R T 11113126 CAV.P.r.CI V CA7 OP PsOLYaSIn 11.611ka> _. 7 • End2 -56 Adperfs AFE# AEINRWOS PERFORATING PROCEDURE ROW E n 2 -56A Well: d API #: 50 -029- 22863 -01 Date: 2/01/2013 Prod Engr: Josiah Igwe .............. „ Office Ph: 564-4753 H2S Level: ....... . ... . Home Ph: 590 -0610 Cont Fax: 12/24/09 150 ppm CC or AFE: AENINJEC WBL Entries IOR Type Work Desciption 350 S Drift to TD with Dummy gun/ Caliper tubing and Liner 350 E Set Ew Trieee Plug /ADPERFS Well Obiectivesand Perforating Notes: ADPERFS 16,790' - 16,850' and 16890' - 16,980'. Attachment: Reference log with proposed perfs annotated, 5/100' scale. Reference Log Tie in Log Add /Subtract 7 feet Log: MWD CBL tie -in log to be on Date: 5/14/1998 2/27/1999 depth with the reference log. Company: Sperry-SUN SLB Depths (from -to) Depths (from -to) Feet SPF Orient Phasing Zone Ad /Re /Iperf 16,790' 16,850' 60' 6 random 60° SAG Adperf 16,890' - 16,980' 90' 6 random 60° SAG Adperf Requested Gun Size: ' 2.5" Charge: PJ Omega 2506, HMX Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessary Preferred Amount of Drawdown /Suggestions to Achieve Drawdown N/A Last Tag: 17,581 ft MD on 6/30/2012 Est Res. Pres. @ 17,338' MD is 4,370 psi Perforation Summary Summary Dist Well: End2 -56A Town: Date: API #: 50- 029 - 22863 -01 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf O / B/ U - 2.5" random 6° 60° SAG Adperf O / B / U - 2.5" random 6° 60° SAG Adperf O/B /U 0 /B /U - O /B/u O /B /U - O/B/U - O /B /U O /B /U 8 • • Perforation Attachment ADL0034634 Well Date Perf Code MD Top MD Base TVD Top TVD Base 2- 56A/EI01 10/30/05 APF 17400 _ 17410 9725 9729 2- 56A/EI01 10/30/05 APF 17410 17420 9729 9733 2- 56A/E101 10/30/05 APF 17420 17430 9733 9737 2- 56A/E101 10/29/05 BPS 17610 17630 9814 9823 2- 56A/E101 10/29/05 BPS 17714 17744 9861 9875 2- 56A/E101 10/29/05 BPS 17744 17774 9875 9890 2- 56A/E101 10/29/05 BPS 17774 17804 9890 9905 2- 56A/EI01 10/29/05 BPS 17804 17904 9905 9958 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0034634 Well Facility Type MD Top Description TVD Top 2- 56A/E101 SSSV 1574 4 -1/2" HES HXO SSV 1528 2- 56A/E101 PACKER 15119 4 -1/2" Baker S -3 Perm Packer 8492 2- 56A/EI01 PACKER 15652 5" Liner Top Packer 8811 • • SW_NAME MEAS_DEPTH MEAS_METHOD_CODE RUN_DATE SUBSEA_DEPTH TVD 2- 56A/E101 8839 JUNK 36764 5286 5341 2- 56A/E101 17692 JUNK 38298 9797 TREE: 4-1/16" / 5000 p eron WELLHEAD: 11" / 5000 p Gen.V EN D2 -56A BF ELEV= 16.6' MAX. DEV. = 68 degrees. Ave hole angle 60 degrees 9 5/8" CSG, 47 #, L -80 BTC, 0 SSSV LANDING NIPPLE 1574 HES "HXO" (3.813" ID) ID = 8.681" 7080' 4 SAFETY NOTES: H2S READINGS AVERAGE 230 - 260 PPM ON AIL Nt GAS MOTORS. WELL REQUIRES A SSSV. "'4-1 /2' CHROME NIPPLES & LNR. GAS LFTMAN S (CAMCO403B -2-LS) ST MD TVD DEV VLV LATCH PORT DATE 6 5102 3545 60 DCAiE INT 16 04/07/05 5 8748 5299 62 SO INT 22 11/12/05 4 10902 6350 61 GAY INT 0 05/28/98 3 12320 7058 59 EMT M 0 05/28/98 2 13699 7758 59 DIN M 0 05/28/96 1 15040 8450 59 MAY INT 0 05/28/98 NOTE ALL OLV HAVE BTM INTEGRAL LATCH PEFFORAT1ON SLPJ# RY REF LOG: SFERRY MM) GR MR ON 05/19/98 ANGLE AT TOP FEiiF:66° @ 17400' Note: Refer to Ftoduction DB for historical pert data I I 4-1/2" "X" NIPPLE 15108 SIZE SPF INTERVAL OPhYSoZ DATE (HES) (3.813" ID) 2.5" 6 17400 - 17420 0 10/30/05 2" 6 17410 -17430 0 11/07104 �( 7" BAKER S -3 PACKER 15119 2" 6 17610 -17630 C 07/03/04 � Baker (3.875" I.D.) 2 -7/8' 6 17714 - 17904 C 05/25198 4 -1/2" "X" NIPPLE 15142 (HES) (3.813" ID) 4 -1/2" "XN" NIPPLE 15164 (HES) (3.725 ID) 15176 I / 4-1/2" W LEG 1 15176 4 1/2" TBG, 12.6 #, L -80 BTC, ELMD 15172 .0152 bpf, ID = 3.958" ZXP Liner Packer & Hgr, 15652 ID = 4.25" Top of 7" window 15958 7" CSG, 29 #, L -80 BTC, 15958 17585 ID = 6.184" � WFD CIBP (10/29/05) E FISH, 4 x1.75' BTM NOSE ? ?? I t FROM PBiF GUN (11/07/04) . CIBP (07/03/04) 17693 PBTD 17899 4 1/2" LNR, 12.6 #, 13 -CR NSCT, X X X .0152 bpf, ID = 3.958" 17988 DATE REV BY COIMENTS DATE REV BY COSAENTS B4DCOlTUNT 05/27/98 GM ORIGINAL CCWIETION 08/15111 DWJM) A00® ICS SAFETY 1NB_L: 2 -56A / E101 07/03104 BJMcL ADD FERFISET BP 04/23/12 PGIJ60 CORRECTED AR # PERMT No: '1980580 11/17/04 MJC/TLH ADD PERF & FISH 01/15113 RMJ4O DRG CORRECTIONS AR No: 50-029-22863-01 05/10/05 RMi/1LH GLV 00 (04/07/05) SEC T N R E 11/12/05 DAV/PJC GLV CYO BP Expbra$ion (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 OR i 1 GVZ ° 5 May 22, 2012 Y Mr. Jim Regg *WOOED SEF • 2 1 'zU1C Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Endicott Row 2 Date: 03/28/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END2 -02 / P -18 1860630 50029215680000 15.0 3.0 0.5 8/28/2010 1.70 9/29/2010 END2 -04 / M -19 1860820 50029215850000 4.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -06 / J -22 1870180 50029216990000 2.0 1.0 0.5 8/28/2010 1.70 9/29/2010 END2 -08 / K -16 1880040 50029217710000 1.5 0.1 0.5 9/2/2010 3.40 9/29/2010 END2 -12 / 0-16 1921170 50029223020000 0.5 1.0 0.0 9/2/2010 NA 3/28/2012 END2 -14 / 0-16 1861490 50029216390000 2.5 3.0 0.5 9/2/2010 1.70 9/28/2010 END2 -16 / M -16 1881340 50029218850000 2.0 0.5 0.5 9/2/2010 1.70 9/28/2010 END2 -18 / L -16 1900430 50029220320000 2.0 0.3 0.5 9/2/2010 2.60 9/28/2010 END2 -20 / L -15 1900600 50029220480000 5.0 3.0 0.5 8/28/2010 3.40 9/28/2010 END2 -22 / L -14 1890340 50029219310000 5.0 5.0 0.5 8/28/2010 6.80 9/28/2010 END2 -24 / M -12 1931730 50029224180000 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -26 / N -14 1880550 50029218150000 2.0 1.8 0.5 9/2/2010 1.70 9/28/2010 END2 -28B / 0-19 2030060 50029218470200 0.5 NA 0.5 NA 1.70 9/28/2010 END2 -30B / ME-01 2081870 50029222280200 3.0 3.0 0.5 8/28/2010 2.60 9/28/2010 END2 -32 / SN-03 1901190 50029220840000 3.0 2.0 0.5 8/28/2010 2.60 9/28/2010 END2 -34 / P -14 1861720 50029216620000 1.0 NA 1.0 NA 12.80 9/25/2010 END2 -36 / 0 -14 1900240 50029220140000 5.0 3.0 0.5 8/28/2010 2.55 9/25/2010 END2 -38 / SN -01 1901290 50029220900000 3.0 4.0 0.5 8/28/2010 1.70 9/25/2010 END2 -40 / S -22 1941520 50029225270000 15.0 13.0 0.5 9/2/2010 4.00 9/25/2010 END2 -42 / P -13 1881450 50029218920000 5.0 4.0 0.5 8/28/2010 2.55 9/25/2010 END2 -44A / 0 -11 1970710 50029217670100 0.5 NA 0.5 NA 22.10 10/5/2010 END2 -46B / S -13 1971370 50029219210200 4.0 1.0 0.5 9/2/2010 3.40 9/25/2010 END2 -48 / 0 -13 1951660 50029226120000 2.0 2.0 0.5 8/28/2010 1.70 9/25/2010 END2 -50 / U-08 1930670 50029223670000 2.0 1.0 0.5 8/28/2010 1.70 9/25/2010 END2 -52 / S -14 1870920 50029217500000 1.0 0.3 0.5 9/2/2010 0.85 9/25/2010 END2 -54 / 0 -12 1911220 50029222180000 4.0 3.0 0.5 8/28/2010 1.70 9/25/2010 - ? END2 -56A / E101 1980580 50029228830100 0.5 NA 0.5 NA 25.50 9/25/2010 END2 -58 / S-09 1900520 50029220410000 7.0 5.0 0.5 8/28/2010 3.40 9/25/2010 END2 -62 / 0-17 1861580 50029216480000 10.0 7.0 0.5 8/28/2010 8.50 9/25/2010 END2 -64 / U -10 1900770 50029220550000 2.0 1.0 0.5 8/28/2010 2.55 9/25/2010 END2 -66 / SD -12 1930790 50029223740000 0.3 NA 0.3 NA 1.70 9/24/2010 END2 -68 / S -17 1880970 50029218580000 2.0 3.0 0.5 8/28/2010 1.70 9/24/2010 END2 -70 / U -15 1881530 50029218990000 0.7 NA 0.7 NA 3.40 9/24/2010 Date: 03-30-2005 Transmittal Number: #91588 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtoiohnsoih@bp.com SW Name Date Contractor '2(ß - NS25 02-19-2004 SCH {C?C¡,. NS08 '202-·0'2-( 1'f6-~ß 2-56/E101 09-01-2004 SCH Lo 18364 1 4650 5600 16980 17695 iö, RST SIGMA BORAX CARBON " .' OXYGEN LOG; :!¡l Æ·' 13D5,/-/ ~ ~3 ./<1 .DCo ~ 7 ULTRA SONIC IMAGING TOOL; Lt.' TUBING PATCH RECORED; / .// 01-29-2005 SCH j t Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Esther Fueg MB3-6 Attn: Ken Lemley MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin Dirks (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 .... l\ r___' 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 <BI:tu"[!f~ a WI.. wv"", """"I Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Anc"hoflue Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 1;11 Exploratory 1~ .~ 3. Address: P.O. Box 196612 Stratigraphic D Service D 6. API Number: Anchorage, AK 99519-6612 50-029-22863-01-00 7. KB Elevation (ft): 9. Well Name and Number: 54.7 KB 2-56A/E101 8. Property Designation: 10. Field/Pool(s): ADL-034634 ENDICOTT Field/ EIDER OIL Pool 11. Present Well Condition Summary: Total Depth measured 17988 feet Plugs (measured) 17693 true vertical 10006.89 feet Junk (measured) None Effective Depth measured 17930 feet true vertical 9973.19 feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 94# H-40 38 - 117 38 - 117 1530 520 Surface 7042 9-5/8" 47# L-80 37 - 7079 37 - 4500.91 6870 4760 Production 15922 7" 29# L-80 36 - 15958 36 - 9024.68 8160 7020 Liner 2336 4-1/2" 12.6# 13Cr80 15652 - 17988 8810.8 - 10006.89 8430 7500 Perforation depth: Measured depth: 17410 - 17430 17610 - 17630 17714 - 17904 True Vertical depth: 9728.76 - 9737 9814.34 - 9823.28 9861.38 - 9958.4 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 34-15176 .._..~,-- .- ',-. Packers and SSSV (type and measured depth) 4-1/2" Baker S-3 Perm Packer 15119 4-1/2" Baker ZXP Packer 15652 12. Stimulation or cement squeeze summary: 5CANNEC DEC 1 9 2005 Intervals treated (measured): RBDMS 8FL DEC 0 6 Z005 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: 32 5410 6026 0 445 Subsequent to operation: 20 6683 1975 0 352 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development 1;11 Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil 1;11 Gas D WAG D GINJ D 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: 305-315 Contact Sharmaine Vestal Ph,w' N,me Sh,=,',e Ve,w' _ ~ Title Data Mgmt Engr Phone 564-4424 Date 11/30/2005 Signat~ _ STATE OF ALASKA a ALA. OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVED DEC 0 {) 2GG5 asiol Form 10-404 Revised 04/2004 14L Submit Original Only e e ... 2-56A/EI01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I'ÄCTIVITYDATE I SUMMARY 10/26/2005 CTU #5, Dummy WS drift/Caliper/Mem GR-CCL/CIBP/Add Perf; MIRU and perform weekly BOP test. Continued on WSR 27-0ct-05 ... 10/27/2005 CTU #5, Dummy WS/Caliper; Continued from WSR 26-0ct-05... MU and RIH to drift with WFD 3.69" OD dummy WS. Sat down at 16620' ctmd (target depth was 17690'). Several attempts to get deeper were unsuccessful. Overpulls acted as if tools were being pinched. POOH w/ dummy WS. RIH to drift with 2.885" OD dummy perf gun. RIH to 17500' at which point no further progress could be made due to excessive pickup weights. PUH to 15441'. Continued on WSR 28-0ct-05 ... 10/28/2005 CTU #5, Dummy WS/Caliper; Continued from WSR 27-0ct-05... Kill well with 18 bbls 60/40, 425 bbls 1 % KCL to flush gas from wellbore. Follow with 10 bbls 60/40 and 260 bbls dead crude to help reduce drag. RBIH, tagged bottom with 2-7/8" dummy gun at 17709' ctmd. PU @ 17698' ctmd. Flagged pipe at 20' off bottom. POOH. RIH with PDS memory caliper. Log from 17700' ctmd up to 3900' ctmd. POOH. Have good data. Continued on WSR 29-0ct-05 ... WIE - NOTE: IA pressure appeared to be tracking the tubing pressure at several points during the job. Diagnostics should be performed at the end of this work program to evaluate this problem. CT - NOTE: Wellbore conditions are critical to being able to reach TD and stay within allowable yield limits on pickup for 1-3/4" pipe. The well was liquid packed with Endicott crude for this program. 10/29/2005 CTU #5, Caliper/Mem GR CCL; Continued from WSR 28-0ct-05... MU PDS caliper for second run and RIH to 5500' and log caliper to surface. MU PDS mem GR/CCL and RIH. Log GR/CCL up from 17708' ctmd to 17200' ctmd. Flag pipe at 17525' ctmd. POOH. RIH with WFD 4 1/2" CIBP. Correct depth at flag. Set CIBP (top) @ 17585' corr. POOH. MU 2.5" x 20',6 spf Power Jet Omega Perf Guns and RIH. Continued on WSR 30-0ct-05 ... 10/30/2005 CTU #5, Perforating; Continued from 29-0ct-05... RIH to flag, correct to top shot and perforate from 17400'-17420'. Good indication that guns fired. POOH. All shots fired. RD DS CTU #5. Hand well over to Pad Operator to put on production. *** Job Complete *** FLUIDS PUMPED BBLS 390 60/40 MeOH 737 1 % KCL 260 Crude 5 Diesel 1392 TOTAL ) ) ';:::"<~::J f':"[:J ;; ¡.! · L..:¡¡ ': illl ",,~. :~ FRANK H. MURKOWSKI, GOVERNOR AIfASIiA. OIL AlÐ) GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Sr. Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 q¡ 056 \q J Re: Endicott 2-56AjEIOl Sundry Number: 305-31 ~Ç^NNE~) ~\~O'f (] 8 2005 Dear Mr. McMullen: 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. Please provide at least twenty-four (24) hours 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 thisJ.å,day of October, 2005 Encl. qq /0 f} Or:: W~l+' RI!~~d('((;;'-¡D STATE OF ALASKA ... Of \ ~ ~ / \:;1:', V t:1 ALA ÌA OIL AND GAS CONSERVATION COMMI,- ,DNO/ /.3;S OCT 1 .2 2005 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations [2] Perforate New Pool D 4. Current Well Class: Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 " Alaska Oil & Gas Cons. Cprornission :erforateL:J t' Waiver U Anchora~Wer U Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 198-0580 / 1. Type of Request: Suspend U Repair well D Pull Tubing D Development ~ Stratigraphic 0 / Exploratory 0 Service 0 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 54.7 KB 6. API Number: 50-029-22863-01-00 ~ 2-56A/E101 / 8. Property Designation: ADL-034634 11. Total Depth MD (ft): 17988 10. Field/Pools(s): ENDICOTT Field / EIDER OIL Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 17930 9973.19 Total Depth TVD (ft): 10006.89 Casing Length Size MD ./ TVD Conductor 79 20" 94# H-40 38 117 38 Surface 7042 9-5/8" 47# L-80 37 7079 37 Production 15922 7" 29# L-80 36 15958 36 Liner 2336 4-1/2" 12.6# 13Cr80 15652 17988 8810.8 Plugs (measured): Junk (measured): 17693 17690 Burst Collapse 117 1530 520 4501 6870 4760 9025 8160 7020 10007 8430 7500 Tubing Size: 4-1/2" 12.6# Tubing Grade: L-80 Tubing MD (ft): 34 - 15176 13. Well Class after proposed work: Exploratory 0 Development ~ 15. Well Status after proposed work: Oil ~ / Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Perforation Depth MD (ft): 17410 - 17430 17610 - 17630 17714 - 17904 Packers and SSSV Type: Perforation Depth TVD (ft): 9728.76 - 9737 9814.34 - 9823.28 9861.38 - 9958.4 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer Packers and SSSV MD (ft): 12. Attachments: Descriptive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 10/25/2005 Date: Commission Representative: 17.. I hereby certify that th~or~Oi ~tJ a correct to the best Of. my knowledge. Contact Pnnted Name J n ull , /.., Title Sr. Production Engineer Signature r/ ¡Y c.- Phone 564-4711 Date " COMMISSION USE ONLY Notify Commission so that a representative may witness 15119 15652 / Service 0 Abandoned 0 WDSPL 0 John McMullen 10/11/2005 Sundry Number: ~5 ~ 315 Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: RBDMS BFL 0 CT J 4 2005 APPROVED BY THE COMMISSION Date IrJ¥Ó5 Form 10-403 Revised 11/2004 Submit in Duplicate ) ) Eider Production Well 2-56A/E101 Proposed Add Perfs; Plug October 11, 2005 Approval is requested to use extended length service coil in Eider horizontal well 2-56A/E101 to set a millable CIBP to shut-off production from current perforations and then reperf/addperf ,,--- shallower in the upper Ivishak sand. Summary procedure: 1. Prepare 1-3/4" coil tubing reel to reach 18400', 2. RU slickline, Pull SSSV. 3. RU coil unit. Drift well to TD with dummy whipstock. Run memory caliper in the 4-1/2" liner and tubing from TD to surface. 4. Set CIBP at ,...,17,590'. 5. Perforate the well as follows (one run): . 17,400' - 17410' (add perfs) // . 17,410' - 17,420' (reperfs) ( 6, RD coiled tubing. 7. RU slickline. Reset SSSV. TREE: 4-1/16" /5000 psi lran WELLHEAD: 11" /5000 PSI I \.:Ien.V )ELEV= 55.1' SF ELEV= 16.6' MAX. DEV. = 68 degrees. Ave hole angle 60 degrees END2-56A /' 9 5/8", 47#, L-80 BTC Casing I 7079' 7",29#, L-80, BTC Casing 41/2",12.6#, L-80 BTC Tubing PERFORATION SUMMARY REF LOG: SPERRY MWD GR MR ON 05/19/~)8 ANGLE AT TOP PERF: Note: Refer to Production DB for his torical perf data SIZE SPF INTERV AL DATE 2" 617410-174300 11/07/04 2" 6 17610 - 17630 0 07/03/04 2-7/8" 6 17714 - 17904 C OS/25/98 .. KEY: 0 = OPEN / C = CLOSED 1 SQZ=SQUEEZED 41/2", 12.6#, 13 Chr, NSCT Liner PBTD 6" bit on btm of liner 17930 17988 o ~ SSSV LANDING NIPPLE 11574 HES "HXO" (3.813" ID) ~ GAS LIFT MANDRELS (CAMCO-KGB-Z-LS) ST MD TVD VLV LATCH PORT DATE 6 5"102 3490 DOME INT 16 04/07/05 5 8748 5242 SO INT 24 04/07/05 4 10902 6294 DMY INT 0 3 12320 7002 DMY INT 0 2 13699 7702 DMY INT 0 1 15040 8394 DMY INT 0 NOTE: ALL GLV HAVE BTM INTEGRAL LATCHES . I 4-1/2" "X" NIPPLE 15108 (HES) (3.813" ID) ~ ~- 7" BAKER S-3 PACKER 15119 Baker (3.875" I.D.) } \ 115142 115164 115176 ELMD 115172 4-1/2" "X" NIPPLE (HES) (3.813" ID) 4-1/2" "XN" NIPPLE (HES) (3.725ID) 4-1/2" WLEG ZXP Liner Packer \15652 115958 ??? I Top of 7" window .. E I FISH, 4"x1.75" BTMNOSE H ~ FROM PERF GUN (11/07/04) I ~BKR CIBP ^ ^ ^ , AX X X >~ DA TE REV BY COMMENTS DA TE REV BY 05/27/98 GM ORIGINAL COMPlETION 07/03/04 BJMcL ADD PERF/SET IBP 11/17/04 MDCITLH ADD PERF & FISH 05/10/05 RMH/TLH GLV C/O (04/07/05) 117693 - ;:: COMMENTS ENDICOTI UNIT WELL: 2-56A 1 EIDER-01 ÆRMIT No: API No: 50-029-22863-03 SEC T N R E BP Exploration (Alaska) bp .-~--. ".: .... .':!$I. 6___'" .4f ( ( Date: 08-01-2005 Transmittal Number: 10202718307 ì q3-0~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com SW Name Date Contractor Log Run Top Depth Bottom Depth Log Type RESERVOIR SATURATION TOOL RST 2-56A/EI01 05/12/2004 SCH 17100 17,800 SIGMA/POROSITY 11 J)~ yj- ;1, / ! /, / í1~- OßvJ Please Sign and Return one copy of this transn1ittal. Thank You, James H. Johnson Petrotechnical Data Center SCß4NNED SF!? 0 8 ?OD5 Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 (qð- O~r3 F,'/t 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Stimulate D OtherO WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 198-0580 6. API Number Stratigraphic D Service D 50-029-22863-01. -00 9. Well Name and Numb..er: ~ ~~^ 2-56ALSM" €IÐ ' ~~ l :.Ell' 10. Field/Pool(s): D vtlJ Endicott Field I Eider 011 Pool £: C 1 (J 2004 A/a'k, Oil & G as Con,. Co . Anchors rnmlS8ion Plugs (measured) 1~3 ) STATE OF ALASKA) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate ŒJ 4. Current Well Class: Development Œ] 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 54.70 8. Property Designation: ADL-034634 11. Present Well Condition Summary: Total Depth ExploratoryD measured 17988 feet Effective Depth true vertical 10006.9 feet Junk (measured) measured 17693 feet true vertical 9851.8 feet Casing Conductor Liner Production Surface Length 79 2336 15922 7042 Perforation depth: Size 20" 94# H-40 4-112" 12.6# 13Cr80 7" 29# L-80 9-5/8" 47# L-80 MD TVD 38 117 38.0 - 117.0 15652 - 17988 8810.8 - 10006.9 36 - 15958 36.0 - 9024.7 37 - 7079 37.0 - 4500.9 Burst 1530 8430 8160 6870 Measured depth: 17410 -17430,17610 -17630 True vertical depth: 9728.76 - 9737,9814.34 - 9823.28 @ 34 SCANNED DEC 1. 3 2004 15176 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 3.2 1911 340 3.6 4643 340 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations - ! @ 15119 @ 15652 Oil-Bbl 19 80 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil [!] Gas D DevelopmentŒ) ~~ CJ....... ",,,,.fJ~ \C\ fJ 8839 Collapse 520 7500 7020 4760 Tubing Pressure 302 372 ServiceD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-396 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Title Production Technical Assistant Signature )j C{ð C.¿;ct.~ Phone 564-4657 Form 1 0-404 Revised 4/2004 RBDMS BFL DEC 1 0 2004 Date 12/8/04 ) ) 2-56A1EI01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/07/04 Perforate 174101-17430' 6 SPF FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL Page 1 . '\ TREE: 4-1/16" /5000 pSI,0ameron WELLHEAD: 11" / 5000 psi / Gen.V 9 5/8", 47#, L-80 BTC Casing 1 7079' I 7",29#, L-80, BTC Casing 41/2",12.6#, L-80 BTC Tubing PERFORATING SUMMARY Referenee log : Sperry MWD Dual GRlElec Mag Resist Dated 5/19/98 Date Size SPF Status INTERVAL 713/04 2" 6 Open 17610-17630 5/25/982 7/8 6 Closed 17714 - 17904 41/2", 12.6#, 13 Chr, NSCT Liner 0 ) II RT ELEV= 55.1' SF ELEV= 16.6' MAX. DEV. = 68 degrees. Ave hole angle 60 degrees SSSV LANDING NIPPLE 11574 HES "HXO" (3.813" ID) . ALL GLV's HAVE BTM INTEGRAL LATCHES CAMCO 4.5" X 1" KGB-2-LS MD TVD ss Angle 6 5102 3490 60 5 8748 5242 62 4 1 0902 6294 61 3 12320 7002 59 2 1 3699 7702 58 1 15040 8394 58 ~ . 4-1/2" "X" NIPPLE (HES) (3.813" ID) 115108 I 115119 I ~ ~- 7' BAKER 8-3 PACKER Baker (3.875" 1.0.) / ~ 115142 I 115164 I 115176 I ELMD 115172 I 4-1/2" '')('' NIPPLE (HES) (3.813" ID) 4-1/2" '')(N'' NIPPLE (HES) (3.725ID) 4-1/2" WLEG ZXP Liner Packer \15652 I 115958 \ Top of 7" window ê ~BKR CIBP 117693 I ;;;; PBTD 117930 I 6" bit on btm of liner 117988 I AX X X ~ ^^^'^ Date By Comments 5/27/98 g m COMPLETION 7/3/04 BJMcL Adperf/Set CIBP . ENDICOTT WELL: 2-56a/Eider-01 API NO: 50-029-22863-03 COMPLETION DIAGRAM .. BP EXPLORATION (ALASKA), INC ¡ ) ~~~7Œ 2)~ !Æl!Æ~æ!Æ AItASKA OIL AND GAS CONSERVATION COMMISSION John McMullen Senior Production Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Endicott 2-56AÆIO 1 Sundry Number: 304-396 Dear Mr. McMullen: ') FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. 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. BY ORDER OF WE COMMISSION DATED this~ day of October, 2004 Enc!. ~Cl\NNED NO\J 0 ~) 2004 .' ) ) \tICA- JOlt. {lz-COtf STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION E EI ED APPLICATION FOR SUNDRY APPROV Akr 2 2004 20 AAC 25.280 1. Type of Request: Abandon 0 AJter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool '0 4. Current Well Class: ~aSka un & bas t;ons. Commission Perforate(i] w~ftf.QraftruJar DlsposaJD StimulateD Time ExtensfonD OtherD Re--enter Suspended WellO . 5. Permit to Drill Number: 198-0580 / / Development IX) Exploratory 0 Stratigraphic 0 Service 0 9. Well Name and Number: 2-56AIE101 / 10. FleldlPooI(s): Endicott Field I Elder 011 Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 17940 9924.3 MD TVD BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 54.70 KB 8. Property Designation: ADL-034634 "11. Total Depth MD (ft): 17988 Casing Total Depth TVD (ft): 10006.9 Length Size Condu~or 79. Liner 2336 Production 15922 Surface 7042 Perforation Depth MD (ft): 17610 - 17630 . Packers and SSSV Type: 4-1/28 Baker S-3 Perm Packer 4-1/2'1 Baker ZXP Packer top bottÇ)m top 38 117 15652 17988 . 36 15958 37 7079 Tubing Size: 4.5 8 12.6 # Packers and SSSV MD (ft): 208 94# H-4O 4-1/2" 12.6# 13CrSO 78 29# L-80 9-51811 47# L-80 Perforation Depth TVD (ft): 9814.34 9823.3 38.0 8810.8 36.0 37.0 12. Attachments: Description Summary of Proposal ŒI Detailed Operations Program 0 BOP Sketch 0 ./"'1 ~ Date: bottom 117.0 10006.9 9024.7 4500.9 Tubing Gfcide: L-80 15119 15652 6. API Number /' 5c;»-029-22863..o1..oo Plugs (md): Junk (md): 17693 8839 Burst Collapse 1530 8430 8160 6870 Tubing MD (ft): 34 520 7500 7020 4760 15176 / 13. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD 14. Estimated Date for , Commencing Operation: 16. Verbal Approval: Commission Representative: 15. Well Status after proposed work: 011 [!J Gas 0 PluggedD AbandonedD ' WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name ;PtJOhn M ulJIIf/7 # ~ . Ti~e Signature . ( ~ t j'T/L--- Phone . Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness Mechanclallntegrlty Test 0 BOP TestD Other: t Subsequ t Form, equ Approve f: Contact John McMullen Sr Production Engineer 564-4711 Location Clearance 0 10/28104 I Sundry Number: , . / 3DV-3Ý0 BY ORDER OF THE COMMISSION Date: frf ORIGINAL Form 10-403 Revised 0612004 BfL OCT 2 9 Înnl, SUBMIT IN DUPLICATE ) ) " = j, To: John Smart/Doug Cismoski Well Operations Supervisors Date: 10/27/04 From: John McMullen (w: 564-4711 c: 529-9129, h: 345-5260) Ahmed Shoreibah (w: 564-5062) Endicott PEs Subject: Eider 2-56A Add Perfs JUSTIFICATION: / . It is recommended to add perfs 17,410' - 17430' MD in Eider well 2-56. This well was recently converted from a Lower Ivishak water injector to an Upper Ivishak oil producer. High water cut production from the Upper Ivishak prompted running a carbon oxygen log, which identified the oil column shallower than expected. The proposed add perfs will target this oil column. WELL DETAIL: Current Status: Last TD tag: Latest Drift: Shut-in high water cut gas lifted produc~r. cmp set at 17693' ELMD' / History of drift problems witb overpuHs in tbe vicinity of 16,600' (dogleg or liner damage ).AI)proacb this area slowly and assess how sticky it is before taking a run at it. The most recent E-line tool string for an RST log had tbree 2.60" roller subs and a 2-118" weight bar. They did set down at this depth, but were able work through without overpuUs. .Also, no overpulls were noted while POOH through this spot. The contingency for not getting the 2-118" guns down is to run 1-1.1.11.6" guns. Min ID (w/SSSV out): 3.725" ID thru XN. Integrity Issues: None. Max Deviation: 68° starting at 16600'. Note that the well is 60 deg or greater from 3000' to TD. / PROCEDURE: 1. RU E-line. PT lubricator. Make sure well is SI. Bleed well to production if well is stacked out with lift gas. MU and RllI with 2-1/8" guns on rollers. Tie-in log to 5/19/98 Sperry MWD. Position guns on depth and perforate the following with the well SI: Zone Top Ivish 17,410 Bottom 17,430 Length 20' Gun Type 2" P J SPF 6 Phasing 60 // 2. POOH and RD E-line. POP well. ) . TREE: 4-1/16" 15000 psi ICameron WELLHEAD: 11" 15000 psi I Gen.V 95/8", 47#, L-80 BTC Casing I 7079' I 7", 29#, L-80, BTC Casing 41/2", 12.6#, L-80 BTC Tubing PERFORATING SUMMARY Reference log : Sperry MWD Dual GRlElec Mag Resist Dated 5/19/98 Date Size SPF Status INTERVAL 7/3/04 2" 6 Open 17610 -17630 5/25/98 2 7/8 6 Closed 17714 - 17904 41/2",12.6#,13 Chr, NSCT Liner 0 ~ ~ ') RT ELEV= 55.1' SF ELEV= 16.6' MAX. DEV. = 68 degrees. Ave hole angle 60 degrees SSSV LANDING NIPPLE 11574 HES "HXO" (3.813" ID) .. ALL GLV's HAVE BTM INTEGRAL LATCHES CAMCO 4.5" X 1" KGB-2-LS MD TVD ss Angle 6 5102 3490 60 5 8748 5242 62 4 10902 6294 61 3 12320 7002 59 2 13699 7702 58 1 15040 8394 58 .. 4-1/2" ''X'' NIPPLE (HES) (3.813" ID) 115108 I 115119 1 PBTD I 17930 I ^ ^ ^ I' 6" bit on btm of liner 117988 I AX X X ~ Date By 5/27/98 g m Comments COMPLETION 7/3/04 BJMcL Adperf/SetCIBP 2?J- 7' BAKER 8-3 PACKER Baker (3.875" I.D.) ~ 4-1/2" ''X'' NIPPLE I 15142 I (HES) (3.813" ID) 4-1/2" ''XN'' NIPPLE 115164 I / (HES) (3.725 ID) 4-1/2" WLEG 115176 I ELMD 115172 I ZXP Liner Packer 115652 I ~ Top of 7" window 115958 1 8Þ ---BKR CIBP / 117693. II - - I. = . ENDICOTT WELL: 2-56alEider-01 API NO: 50-029-22863-03 COMPLETION DIAGRAM BP EXPLORATION (ALASKA), INC .. /"' ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION J~1=CEIVED REPORT OF SUNDRY WELL OPERATIONS- 1 . Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD Repair Well 0 PluQ PerforationslK] Pull TubingD Perforate New Pool 0 Operation Shutdown 0 Perforate I!] 54.70 8. Property Designation: ADL-o34634 11. Present Well Condition Summary: 4. Current Well Class: Development 0 StratigraphicO 9. Well Name and Number: 2-56AIE101 10. Field/Pool(s): Endicott Field / Eider Oil Pool ExploratoryD ServiceŒ Stimulate 0 OtherŒ Convert to Producer WaiverD Ti~M~ibRtjas Cons. Commission Re-enter Suspended wellÓ"chorage 5. Permit to Drill Number: 1 6. API Number 50-029-22863-01-00 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 17988 feet true vertical 10006.9 feet Effective Depth measured 17693 feet true vertical 9851.8 feet Plugs (measured) Junk (measured) 17693 8839 Casing Conductor Liner Production Surface Length 79 2336 15922 7042 Size 20" 94# H-40 4-1/2" 12.6# 13Cr80 7" 29# L-80 9-5/8" 47# L-80 MD TVD Burst Collapse 38 117 38.0 - 117.0 1530 520 15652 - 17988 8810.8 - 10006.9 8430 7500 36 - 15958 36.0 - 9024.7 8160 7020 37 - 7079 37.0 - 4500.9 6870 4760 Perforation depth: Measured depth: 17610 - 17630 True vertical depth: 9814.34 - 9823.28 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 34 15176 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer @ 15119 @ 15652 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure 0 0 -3875 130 2393 70 3.1 2275 314 Copies of Logs and Surveys run - Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] ServiceD 14. Attachments: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-151 Title Production Technical Assistant Phone 564-4657 Date 9/21/04 ORIG\NAL RBDMS Sf L SEP 2 '7 'Jonh Form 10-404 Revised 4/2004 /"' ~. 2-56A1EIO1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/02/04 CTU #5: JEWELRY LOG/DRIFT FOR CIBP AND PERF. ***WELL SHUT-IN UPON ARRIVAL*** RIH W/ 3.65" JSN AND PDS LOGGING STRING. NO TROUBLE PASSING THROUGH HISTORICAL TIGHT SPOT AT 16,600'. «<CONTINUED ON WSR 7/3/04.»> 07/03/04 Perforate 17610'-17630' 6 SPF 07/03/04 SET CIBP @ 17693' 07/04/04 Start Producing FLUIDS PUMPED BBLS 259 2% KCL 6 50/50 Methonal 265 TOTAL Page 1 /'"". TREE: 4-1/16"/5000 psi ICameron WELLHEAD: 11"/5000 psi 1 Gen.V 95/8",47#, L-80 BTC Casing 1 7079' I 7",29#, L-80, BTC Casing 41/2",12.6#, L-80 BTC Tubing PERFORATING SUMMARY Referenee log : Sperry MWD Dual GRiElec Mag Resist Dated 5/19/98 41/2",12.6#,13 Chr, NSCT Liner PBTD 1 17930 I 6" bit on btm of liner 117988 I Date 5/27/98 7/3/04 Comments COMPLETION Adperf/SetCIBP By gm BJMc 0 ~ RTELEV=55.1' BF ELEV= 16.6' MAX. DEV. = 68 degrees. Ave hole angle 60 degrees SSSV LANDING NIPPLE HES "HXO" (3.813" ID) 1574 ALL GLV's HAVE BTM INTEGRAL LATCHES CAMCO 4.5" X 1" KGB-2-LS MD TVD ss Angle 6 5102 3490 60 5 8748 5242 62 4 10902 6294 61 3 12320 7002 59 2 13699 7702 58 1 15040 8394 58 4-1/2" "X" NIPPLE (HES) (3.813" ID) 7' BAKER S-3 PACKER 115119 I Baker (3.875" I.D.) 15108 115142 1 4-1/2" "X" NIPPLE (HES) (3.813"ID) 4-1/2" "XN" NIPPLE (HES) (3.725ID) 4-1/2" WLEG 15176 ELMD 115172 15164 ZXP Liner Packer 115652 I 115958 I Top of 7" window BKR CIBP 117693 1 ENDICOTT WELL: 2-56a/Eider-01 API NO: 50-029-22863-03 COMPLETION DIAGRAM BP EXPLORATION (ALASKA), INC 1'""""'\ I - I STATE OF ALASKA Oczy -1--/2'1 ¿¡ ALASKA Oil AND GAS CONSERVATION COMMISSION r--- APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~ 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 Repair Well D Pull Tubing 0 Operation Shutdown D Plug Perforations ŒJ Perforate New Pool D 4. Current Well Class: BP Exploration (Alaska), Inc. Development D Perforate!] WaiverO Annular Disposal 0 StimulateD Time ExtensionD OtherŒ ,.- Re-enter Suspended Well 0 Convert to Producer 5. Permit to Drill Numl:5er: 198-0580 / Exploratory D 6. API Number /' 50-029-22863-01-00 P.o. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 54.70 KB 8. Property Designation: ADL-034634 3. Address: StratigraphicD Service ŒJ 9. Well Name and Number: 2-56A1é1e1 75 D Wtlk 10. Field/Pool(s): Endicott Field I Eider Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): IEffective Depth MD (ft): Effective Depth TVD (ft): 10006.9 17940 9924.3 Length Size MD TVD Plugs (md): None Burst Junk (md): 8839 Collapse 11. Total Depth MD (ft): 17988 Casing Conductor 79 Liner 2336 Production 15922 Surface 7042 Perforation Depth MD (ft): 17714 - 17744 17744 - 17774 17774 - 17804 17804 - 17904 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 12. Attachments: Description Summary of Proposal ŒI 20" 94# H-40 4-1/2" 12.6# 13Cr80 7" 29# L-80 9-5/8" 47# L-80 Perforation Depth TVD (ft): 9861 9875.4 9875 9889.9 9890 9905.0 9905 9958.4 top bottom top bottom 38 117 38.0 117.0 1530 520 15652 17988 8810.8 10006.9 8430 7500 36 15958 36.0 9024.7 8160 7020 37 7079 37.0 4500.9 6870 4760 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5" 12.6 # L-80 34 15176 Packers and SSSV MD (ft): 15119 15652 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D ExploratoryD DevelopmentŒl ServiceD 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Date: 15. Well Status after proposed work: Oil ŒJ GasD WAG D GINJD PluggedO AbandonedO WINJD WDSPLD Prepared by Garry Catron 564-4657. May 10,2004 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John McMullen :~~~:~:am/JO ~~ W- ;~:. :~~~clion Engineer 4fl61O4 Commission Use Only IS. undry Number: Conditions of approval: Notify Commission so that a representative may witness ..3 ó c..j - / a I 1/ Plug Integrity 0 MechanciallntegrityTest D Location Clearance D kf:CEIVED m:;~'Ç' ""1~,' ~ . APR 282004 .. 1[J;::¿) Û1! = Wâ\ 2 ,~ - 4- ~ ~ ' . AiaSkaO¡I&Gr:S ~. BY ORDER OF rn.!,S. K9 ~ THE COMMISSION Date: A r~ () r Other: Form 10-403 Revised 12/2003 0 R , G ~ ~~ A L SUBMIT IN DUPLICATE .: ~ ~ Eider Water Iniection Well 2-56A/EI01 Proposed Conversion to a Producer 04/26/04 Eider water injection well 2-56A/EI01 is the only injector in the Eider pool supporting the /' only producer 2-30A/EI02. The well has been on continuous water injection since early 2001 and is currently injecting at about 4500 BPO; 2600 psi. Pressure surveillance in the area since the start of injection indicates negligible support for 2-30A and therefore is of no value as a continued water injector. It is recommended to convert the well back./ to a producer and add perfs in a sand above the currently completed interval. Summary procedure: 1. SI injection. 2. AU slickline. Pull injection safety valve. Drift well to TO. Install gas lift design. 3. AU E-line. Set retrievable bridge plug at 17700' MD (above existing perfs). // 4. Perforate 17640' - 17660' . 5. Complete facility conversion (injector to producer) /' 6. Put well on production. ~ A TREE: 4-1/16"/5000 psi /heron WELLHEAD: 11"/SOOOp. en.V 95/8",47#, L-80 BTC Casing I 7079' I 7",29#, L-80, BTC Casing 41/2",12.6#, L-80 BTC Tubing PERFORATING SUMMARY Reference log: Sperry MWD Dual GRlElec Mag Resist. Dated 5/19/98 Date Size SPF Status INTERVAL 5"""127181' 10"'" 17714 - 17904 i 41/2",12.6#,13 Chr, NSCT Liner PBTD 1 17930 1 6" bit on btm of liner 117988 1 Date By 5/27/98 g m Comments COMPLETION ~ ~T ELEV= 55.1' ..>F ELEV= 16.6' MAX. DEV. = 68 degrees. Ave hole angle 60 degrees 0 SSSV LANDING NIPPLE 11574 HES "HXO" (3.813" ID) .. ALL GLV's HAVE BTM INTEGRAL LATCHES CAMCO 4.5" X 1" KGB-2-LS MD TVD ss Angle 6 5102 3490 60 5 8748 ..5242 62 4 10902 6294 61 3 12320 7002 59 2 13699 7702 58 l' 15040 8394 58 z . 4-1/2" "X" NIPPLE 1 15108 (HES) (3.813" ID) V - 7" BAKER S-3 PACKER 115119 I Ó Baker (3.87S" I.D.) I 115142 I I 15164 115176 ELMD 115172 I \ 4-1/2" "X" NIPPLE (HES) (3.813" ID) 4-1/2" "XN" NIPPLE (HES) (3.725 ID) 4-1/2" WLEG ZXP Liner Packer 115652 I 115958 I Top of 7" window .. - - / ^^^¡I' AX X X >-, ENDICOTT WELL: 2-56a/Eider-O1 API NO: 50-029-22863-03 COMPLETION DIAGRAM BP EXPLORATION (ALASKA), INC ¡> ,-- -- ... r"" ~ .. BP Exploration (Alaska) Inc. Post Office Box 196612 900 East Benson Blvd Anchorage, Alaska 99519-6612 ò April 26, 2004 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 Subject: Eider WeIl2-56A/EI-01 Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for Eider water injection well 2-56A/EI-01. Approval is requested to convert the well from an injector to a producer. A summary of the proposed work and wellbore schematic are attached. If you require any additional information or clarification, please contact John McMullen at 564-4711. Sincere, r%~ John C. McMullen, P.E. Sr. Petroleum Engineer Attachments RECEIVED APR 2 8 2004 Alaska Oil & Gas Cons. Commission Anchorage OR'G!~~AL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ACIDIZE FORMATION 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2086' FNL, 2333' FEL, Sec. 36, T12N, R16E, UM At top of productive interval 2954' FNL, 4501' FEL, Sec. 27, -I-12N, R16E, UM At effective depth 3075' FNL, 4977' FEL, Sec. 27, T12N, R16E, UM At total depth 3099' FNL, 5055' FEL, Sec. 27, T12N, R16E, UM 12. Present well condition summary Total depth: Operation shutdown_ Plugging_ Perforate Pull tubing _ Repair well _ Other _ Stimulate _X Alter casing _ 5. Type of Well: Development __ Exploratory__ Stratigraphic__ Service X (asp's 258869, 5982334) (asp's 246289, 5987164) (asp's 245810, 5987059) (asp's 245731, 5987038) 6. Datum elevation (DF or KB feet) RKB 55 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 2-56A/El-01 9. Permit number / approval number 198-058 10. APl number 50-029-22863-01 11. Field / Pool Duck Island measured true vertical 17988 feet Plugs (measured) 10007 feet TD Tag @ 17888' (05/23/2002) Effective depth: measured true vertical Casing Length Conductor 117' Surface 7039' Intermediate 16412' Liner 2336' 17888 feet Junk (measured) 9950 feet Size Cemented 30" Driven 9-5/8" 2008 sx lite lead PF, 250 sx 'G' 7" 200 SX Class 'G' 4-1/2" 293 sx Class 'G' Measured Depth 160' 7080' 16451' 15562' - 17988' True Vertical Depth 160' 4502' 9346' 8752' - 10007' Perforation depth: measured Open Perfs 17714' - 17904', Re-Perfs 17714' - 17804'. RECEIVED true vertical Open Perfs 9861'- 9959', Re-Perfs 9861'- 9905'. Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 15119'. Tubing Tail @ 15176'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 PKR @ 151 19'. ZXP Liner Packer @ 15652'. 4-1/2" HES HXO SSSV LN @ 1574'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 05/18/2OO2 OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 3776 Casing Pressure Tubing Pressure 2443 Subsequent to operation 05/26/2002 15. Attachments 3181 16. Status of well classification as: 2477 Copies of Logs and Surveys run__ Daily Report of Well Operations __ Oil__ Gas__ 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~e~~_~~~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Suspended _ Service Water Injection Date May 28, 2002 Prepared by DeWar/ne R. Schnorr 564-5174 SUBMIT IN DUPLICATE.. 2-56A/El-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05~22~2002 ACTD' ACI'D TREATMENT 05/23~2002 ACID' ACI'D TREATMENT EVENT SUMMARY O5/22/O2 MIRU DS CTU #5. PUMP BALL FOR DRIFT. BOP TEST. PU 3" JSN. BLEED WHP TO GET INTO WELL. RIH. O5/23/O2 RIH TO BTM. TAG, RETAG @ 17888' DOWN/17878' UP. JET 40 BBLS NH4CL FROM 17868' -17694'. JET HCL 17694' - 17890'. COIL STUCK COMING OFF BTM. SD ACiD PUMPING. FLOW BACKSIDE TO REDUCE WHP WORKED FREE. PULLED TO 17684'. PUMPED REMAINING HCL (TOTAL OF 155 BBLS). PUMP 76 BBLS 9-1.5 MUD ACID @ MAXIMUM RATE. PUMP 42 BBLS NH4CL, PULL TO TT, PUMPED TO DISPLACE ACID. RIH TO PERFS AND PUMP REMAINING NH4 WATER. WHP DECREASED TO 1560 PSI @ 1.5 BPM WITH MUD ACID ON PERFS, THEN STEADILY INCREASED TO 1950 PSI @ 0.7 BPM ON DISPLACEMENT. PRESSURE DROPPED FROM 1950 TO 900 AFTER 1 HOUR SHUT-IN. FINISHED DISPLACEMENT. POH. RD. NOTIFY PAD OPERATOR TO RETURN WELL TO INJECTION. <<<JOB COMPLETE>>> FLUIDS PUMPED BBLS 0 DIESEL FOR PRESSURE TESTING SURFACE PRESSURE CONTROL EQUIP ' 82 NH4CL ACID 155 HCL ACID 76 9-1.5 MUD ACID 313 TOTAL , Page I ~OANNED J UN 2 A 2002: 2-56A/EIO1 AOGCC 10-404 Report Subject: 2-56A/EIO1 AOGCC 10-404 Report Date: Fri, 13 Oct 2000 13:25:40 -0500 From: "Millholland, Madelyn A" <millhoma@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Weiss, Troy D" <WeissTD@BP.com>, "Robertson, Daniel B" <RobertDB@BP.com>, "Ambrose, Jim G (PRA)" <AmbrosJG@BP.com> Dear Tom, Per our discussions this morning regarding Eider well 2-56A/El01 (APl 50-029-22863-01 ) - - a state witnessed MIT was completed on this well on 3/21/00 and a 10-404 Sundry was submitted to AOGCC on 04/19/00. - a reperferation job was completed on 8/28/00 and a 10-404 was submitted to AOGCC on 8/10/00. Casing pressure and tubing pressures prior to and subsequent to this well operation are shown at the top of the attached well work telex. They are: Initial Inner Annulus- 400 PSI; Final Inner Annulus- 600 PSI; Initial Tbg Press - 1500 PSI; Final Tbg Press- 1100 PSI. - Permit number br this well is 198-058. Please let me know if you have any further questions. Madelyn Millholland BP Exploration (Alaska)Inc. ACT Business Unit Phone: (907) 564-5234 email: millhoma@bp.com 1 of 1 lO113/00 10:44 AM ~ I/& I t- UI- /&L/&~I%/& AL,~ ..... Oil AND GAS CONSERVATION COMMI? -~"[ REPORT SUNDRY WELL OPcr ATIONS 1. Operations performed: Operation shutdown__ Stimulate Plugging__ Pull tubing__ Alter casing ~ Repair well__ Perforate X Other__ 2. Name of Operator BP Ex¢!oration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 3193' NSL, 2333" WEL, Sec. 36, T12N, R16E, U~ At top of productive interval 2326' NSL, 4501' WEL, Sec. 27, T12N, R16E, UM At effective depth 2194' NSL, 5009' WEL, Sec. 27, T12N, R16E, UM At total depth 2191' NSL, 5055' WEL, Sec. 27, T12N, R16E, UM 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) 54.7 7. Unit or Property name Duck Island Unit 8. Well number 2-56a/Eider-O 1 9. Permit number/approval n 10. APl number 50- 50-029-22863-01 11. Field/Pool Duck Island feet 12. Present well condition summary Total depth: ' measured true vertical Effective depth: measured true vertical 17,988 feet 10,007 feet 17,930 feet 9919 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth BKB 117' 30" Driven 80' 7, 039' 9 5/8" 2008 sx lite lead PF, 250 sx 'G' 7, 079'; '6,412' 7" 200 sx class 'G: 15,958' 2,336' 4 1/2" measured 17714'- 17804' true vertical (subsea) 9806'-9850' 293 sx class 'G' True vertical depth BKB 80' 4,501' 6,408' 8811' - 6121' Tubing (size, grade, and measured depth) 4 1/2" 12.6#, L-80 to 15176' Packers and SSSV (type and measured depth) HES (3.813") HX at 15747 7" Baker S-3 Packer (3.975"1D) at 15,119', ZXP Liner Packer at 15,652' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure OEiGli" AL 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 0 0 0 1306 2198 2184 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations X Oil__ Gas__ Suspended 17. I hereby certify that the foregoing is true and correct to^the best of my knowledge. Signed ¢,,~,, Title S~nior T~chnic~l Assistant IV Form 10-404 Rev 06/15/8~ Service W~fc, r Ini.~.nfnr Date 8/10/00 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department WELL SERVICE REPORT P1(END2-56(W4-6)) WELL JOB SCOPE JOB NUMBER END2-56 PERF(ADD-PERF) 0827002050.5 DATE DAILY WORK UNIT NUMBER 08/30/00 PERFORATE 90 FEET 2150 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 2 YES YES SWS-CLASPER SUAVE I~IELD AFC# CC# DAILY COST ACCUM COST Signed ESTI MATE N 10256 $24,988.00 $24,988.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1100 PSI 1300 PSI 600 PSI 300 PSII 0 PSII 0 PSI DAILY SUMMARY IPERFORATED 60 FEET. 2 ENERJET GUNS, 6 SPF, 0 PHASING, ORIENTED TO LOW SIDE OF HOLEINTERVALS: 17744-17774, 17714-17744.JOB COMPLETED TIME LOG ENTRY 07:45 ARRIVE ON LOCATION SWS CREW. ENG. K.CLASPER. 08:10 PT BOP/RISER TO 300 PSI FOR 5 MIN AND 3000 PSI FOR 10 MIN 08:30 RIH W 30 FT 30 LOADED 6SPF. TOTAL TOOL STING LENGTH 48.5 FT. TOTAL TOOL STRING WEIGHT 230 LBS. 09:20 LU TO PICK TOOL WEIGTH AND CORRELATE W GLM AND JEWELRY. LD 09:45 STOP AT FLAG. LU TO CHECK POSITION. STOP AT 17500 TO FLOW WELL AND WAIT FOR STABILIZATION. 10:00 LU TP INTO SHOOTING POSITION TO CORRELATE. 10:10 STOP CCL AT 17731 FT.GUN SHUT AT 17744 FT. SHUT IN THE WELL. POOH. 11:00 RD. AT SURFACE CONFIRMED ALL SHOTS FIRED. CHECK TOOLS. RIG NEXT GUN 11:30 RIH W 30 FT GUN LOADED 6SPF. TOTAL TOOL STRING LENGTH 48.5 FT. TOTAL WEIGHT TOOL 230 LBS. 12:15 LU TO PICK TOOL WEIGHT AND CHECK POSITION W GLM AND JEWELRY. LD. 12:30 STOP AT FLAG AND LU TO CHECK POSITION. 12:40 STOP AT 17500 FT. START TO FLOW THE WELL. WAIT FOR STABILIZATION. 12:50 LU INTO SHOOTING POSITION. SHUT THE GUN. SHUT IN THE WELL. POOH 13:50 AT SURFACE CONFIRM ALL SHOTS FIRE.START TO RIG DOWN. 15:00 LEFT WELL SHUT IN. LEAVE LOCATION SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL SCHLUMBERGER $24,988.00 $24,988.00 TOTAL FIELD ESTIMATE $24,988.00 $24,988.00 BPX Endicott Production Engineering Department WELL SERVICE REPORT P1(END2-56(W4-6)) WELL JOB SCOPE JOB NUMBER END2-56 PERF(ADD-PERF) 0827002050.5 DATE DAILY WORK UNIT NUMBER 08/29/00 ATTEMPT PERFORATING 2150 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR I NO NO SAUVE FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTI MATE N 10256 $0.00 $0.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY JOB CANCELED DUE TO WEATHER CONDITION.JOB INCOMPLETE, CONTINUED ON 08/30/00. TIME 10:15 10:45 11:00 LOG ENTRY ARRIVE ON LOCATIONSWS CREW. JOB CANCELED DUE TO WEATHER CONDITION. LEAVE LOCATION. SERVICE COMPANY-SERVICE SCHLUMBERGER IDAILY COST I ACCUM TOTAL $0.00 $0.00 TOTAL FIELD ESTIMATE I $0-00 1 $0.00 BPX Endicott Production Engineering Department WELL SERVICE REPORT P1(END2-56(W4-6)) WELL JOB SCOPE JOB NUMBER END2~56 PERF(ADD-PERF) 0827002050.5 DATE DAILY WORK UNIT NUMBER 08/28/00 90 FT INTERVAL PERFORATE 2150 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 NO NO K. Clasper SUAVE FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTIMATE N 10256 $0.00 $0.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann , Initial Outer Ann , Final Outer Ann DAILY SUMMARY IPERFORATED 30'. 2 1/8" GUNS ENERJET 6 SPF O PHASING.INTERVAL: 17774-17804 FTINCOMPLETE, JOB CONTINUED ON 08/29/30 TIME 08:30 10:00 10:30 11:00 12:00 12:30 12:45 14:15 14:30 15:45 16:30 17:00 17:15 17:30 17:40 18:00 19:00 20:00 20:40 21:00 22:24 23:20 LOG ENTRY ARRIVE SWS UNIT 2150, ENG. CLASPER. RIG UP. HOLD SAFETY MEETING. ARM GUN PRESS TEST BOP/RISER TO 300 PSI FOR 5 MIN. PRESS TEST TO 3000 PSI FOR 10 MIN RIH W 30 FT GUN LOADED 6SPF .TOTAL TOOL STRING LENGTH 48.5 FT. TOTAL TOOL STRING WEIGHT 230 LBS. LU TO PICK UP TOOL WEIGHT AND CORRELATE WITH GLM AND JEWELRY. LD. LU TO CORRELATE THROUGH LINER TOP. LD STOP AT 17500. STAR TO FLOW WELL. WAIT FOR STABILIZATION. CORRELATE INTO POSITION. FLAG THE LINE. STOP CCL AT 17761.8 FT. SHUT GUN AT 17774 FT. SHUT IN THE WELL.POOH. RD FIRST GUN.AT SURFACE CONFIRMED ALL SHOTS FIRED. CHECK TOOLS. RU SECOND GUN. RIH W 30 FT GUN LOADED W 6SPF. TOTAL TOOL STRING LENGTH 48.5 FT. TOTAL TOOL TRING WEIGHT 230 LBS. LU TO PICK TOOL WEIGHT AND CORRELATE WITH GLM AND JEWELRY. LD SAT DOWN AT 17100 FT. WENT TROUGHT IT ATFER SECOND ATTEMP. STOP AT 17800 FLAG AND LOG UP TO CHECK POSITION. STOP AT 17500 FT, START TO FLOW THE WELL. WAIT FOR STABILIZATION. CORRALETE INTO POSITION. GUN MISFIRE.WELL SHUT IN. POOH. RIG DOWN SECOND GUN. INSPECT AND CHECK TOOLS AND GUN. ESIC FAILURE DETERMINED. CHANGE ESIC AND GUN. RIG UP. RIH W 309 FT GUN LOADED W 6SPF .TOTAL TOOL STRING LENGHT 48.5 FT. TOTAL TOOL STRIN WEIGHT 230 LBS. LU TO PICK TOOL WEIGHT AND CHECK POSITION WITH GLM AND JEWELRY. LD STOP AT FLAG AND LU TO CHECK POSITION. STOP AT 17500 .START TO FLOW. WAIT FOR WELL STABILIZATION. CORRELATE INTO POSITION. GUN MISFIRE. WELL SHUT IN.POOH. RIG DOWN.CHECK TOOLS. EFI FAILURE DETERMINED. LEAVE LOCATION. SERVICE COMPANY - SERVICE DALLY COST ACCUM TOTAL SCHLUMBERGER $0.00 $0.00 TOTAL FIELD ESTIMATE $0.00 $0.00 '-well c 0mpii-anCe Report File on Left side of folder 198-058-0 MD 17988 DUCK IS UNIT Mpi .... 2-56A~ID 50~' 029-22'863-01 'BP EXPLORATION TVD 100_0~6_ Completion Date: 5/28/98 Completed Status: I-OIL Current: T Name C 9230 D 8777 L 8470 L BRIDGE PLUG L DGR/CNP/SLD-MD DGR/CNP/SLD-MD DGR/CNP/SLD-TVD L DGR/CNP/SLD-TVD L DGR/EWR4-MD L DGR/EWR4-MD DGR/EWR4-MD DGR/EWR4-TVD L DGR/EWR4-TVD DGR/EWR4-TVD L JWL RST RST/S L SCMT R SRVY RPT R SRVY RPT R SRVY RPT T 8500 T 8562 T 8563 T 9046 Interval Sent Received T/C/D t2--26 FINAL ~.-I~A L ~'I~-A L FINAL r-.~A L Ct~AL ~qNAL t~-FINAL ¢h~ 0-17886 ., ~PERRY 15861.93-17988. ~'~ERRY 16390.78-18340. PB1 ~SPERRY 15861-17775. PB2 ~3¢I~4 SPERRY MPT/GR/EWR/CNP t~-5 SPERRY MPT/GR/EWR4 r~3<-26 SPERRY MPT/GR/EWR4/CNP PB2 t~ SCHLUM RST SCHLUM RST SPERRY MPT/GR/EWR4/CNP/SLD SPERRY MPT/GR/EWR4/CNP/SLD 15988-16400 7100-18240 PB1 7100-17775 PB2 4512-10071 4512-10064 PB2 7100-18240 PB1 7100-17988. 7100-17775 PB2. 4512-10071 4512-10007 4512-10064 PB2 0-17886 16106-18104 PB1 0-17886 CH 6/14/99 6/14/99 OH 10/27/98 10/27/98 OH 6/30/98 7/2/98 CH 5 6/14/99 6/14/99 OH 5/8/98 5/11/98 OH 7/28/98 8/3/98 OH 5/8/98 5/11/98 OH 7/28/98 8/3/98 OH 5/8/98 5/11/98 OH 7/28/98 8/3/98 OH 7/28/98 8/3/98 OH 5/8/98 5/11/98 OH 7/28/98 8/3/98 OH 7/28/98 8/3/98 CH 5 4/19/99 4/21/99 CH 5 6/14/99 6/14/99 CH 5 5/21/99 5/24/99 OH 5 4/19/99 4/21/99 OH 7/1/98 7/1/98 OH 7/1/98 7/1/98 OH 7/1/98 7/1/98 OH 5/8/98 5/11/98 OH 7/28/98 8/3/98 OH 7/28/98 8/3/98 CH 5/21/99 5/24/99 Monday, May 01,2000 Page 1 of 2 Was the well cored? yes no Comments: Are Dry Ditch Samples Required?~ no And Received? yes no Analysis Description Received? yes no Sample Set # Monday, May 01, 2000 Page2 of 2 BP EXPLORATION Date:6-14-1999 Trans#90565 BP/Eider CASED HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name Rec Type Desc Log Type Desc Rec Date Company Code Comments 2-56A/PB1 CD RESERVlOR SATURATION 04-Apr-98 SCH TOOL (CARBON/OXYGEN) 2-56A/PB1 CASED HOLE RESERVIOR SATURATION 04-Apr-98 SCH LOG TOOL (CARBON/OXYGEN) 2-56A/El01 CASED HOLE BRIDGE PLUG PULL OR SET 16-Apr-98 SCH BAKER SETTING LOG TOOL BRIDGE PLUG RECORD COLLAR LOG Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center CH LOGS Madellyn Millholland MB 3-6 AOGCC DNR .:~Jasb3 61.;l & .Gas co~s. Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION Date: 5-21-1999 Trans#90520 BP/Eider CASED HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name Rec Fype Log Type Desc Rec Date Company Code Comments 2-30NEI02 CH CASING COLLAR LOG 18-Apr-99 PDS GAMMA RAY 2-56NEI01 CH RESERVIOR SATURATION TOOL 27-Feb-99 SCH SIGMA MODE (CARBON/OXYGEN) 2-56NEI01 TAPE RESERVIOR SATURATION TOOL (CARBON/OXYGEN) 27-Feb-99 SCH 2 RST MONITOR PASSES AND AVERAGE Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center CH LOGS Madellyn Millholland AOGCC DNR Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION Date: 4-19-1999 Trans#90357 BP/Eider CASED HOLE LOGS Enclosed are the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name Rec Type Log 1-ype Rec Date Company Comments Code 2-56A/El01 CH CBL 27-Feb-99 SCH CEMENT BOND LOG - SLIM CEMENT MAPPING TOOL 2-56AJEI01 CH GR 27-Feb-99 SCH GR CCL JEWELRY LOG Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center CH LOGS Madellyn Millholland AOGCC DNR MB4-2 Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION, Alaska Date: 1/27/99 Trans# 90200 BP/ENDICOTT DIRECTIONAL SURVEY Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-5929. Sw Name 'Rec Date ComDany Code Comments 2-56/EI-01 01/20/98 GYRODATA GYRO SURVEY W/DISK 2-56/EI-01 03/15/98 SPERRY MWD SURVEY W/DISC FINAL 2-56A/EI01 05/17/98 SPERRY MWD SURVEY~W/DISC FINAL 2-56A/PB1 04/05/98 SPERRY MWD SURVEY W/DISC FINAL 2-56A/PB2 04/29/98 SPERRY MWD SURVEY W/DISC FINAL Please sign and return one copy of this transmittal letter. Thank-you, David W. Douglas Petrotechnical Data Center AOGCC - ATTN' Howard Okland RECEIVED JAN 2.8 1999 Na a0il&GasCons. Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION Date: Trans# 10-27-98 89262 BP/ENDICOTT LOG DATA Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166. ~ ~' ~5'-Z3 Sw Name Company Log Type RecType Rec Date Comments 2-56NPB2 SPERRY 'MWD GR DISK 29-Apr-98 MWD MPT GR EWR4 CNP SLD ROP Please sign and return one copy of this transmittal. Thank-you, Carla H. Mclntosh Petrotechnical Data Center OH/CH LOGS Madellyn Millholland MB7-1 DNR Tim Rhyherd RECEIVED OCT 2~ ~998 Alaska 0i~ & Gas Cons. Commission And~o~e Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION Date: 07-28-98 Trans# 89350 BP/ENDICOTT CASED HOLE LOGS BP/ENDICOTT OPEN HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166. Sw Name 'Log Type Rec Type, Rec Date Comments' 2-56A/PB2 MWD DGR/CN0 OH 30-Apr-98 TVD - DGR CN0 SLD 2-56A/PB2 MWD TAPE 29-Apr-98 MWD MPT GRC EWR CNP RHOB DGPJEWR ROP 2-56A/PB2 MWD OH 30-Apr-98 TVD- MWD DGR EWR4 DGR/EWR 2-56A/PB2 MWD OH 30-Apr-98 MWD ROP DGR EWR4 DGR/EWR 2-56A/PB2 MWD DGR/CN0 OH 30-Apr-98 MWD DGR CN0 SLD Please sign and return one copy of this transmittal. Thank-you, /-% Nadene Reichert .,~-,~r---. j~ ! ~/~ Petrotechnical Data Center '--.~ ~ ¢,~/~~ ) ¥- (~ · OH/CH LOGS MAGTAPES STATE REPORTS '~IRECTIONAL AOGCC AOGCC Madellyn Millholland MB7-1 Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION ~-~/ Date: -~ ~ Trans# BP/ENDICOTT CASED HOLE LOGS BP/ENDICOTT OPEN HOLE LOGS 07-28-98 89348 Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166. Sw Name Log Type Rec Type Rec Date Comments 2-56A/El01 MWD OH 19-May-981TVD - MWD DGR EWR4 DGR/EWR 2-56A/El01 MWD OH 19-May-981MWD ROP DGR EWR4 DGR/EWR 2-56A/El01 MWD TAPE 17-May-98iMWD MPT GRC EWR ROP DGR/EWR Please sign and return one copy of this transmittal. Thank-you, Nadene Reichert ~2~, ~ Petrotechnical Data Center '-- ~ OH/CH LOGS MAGTAPES STATE REPORTS DIRECTIONAL AOGCC AOGCC Madellyn Millholland MB7-1 Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION coMMIssI~ CO FJDENTIAL WELL COMPLETION OR RECOMPLETION REPORT AND LOG !,¥ ,.:...'~...?, _~.~. 1. Status of Well Classification of Service Well [] Oil [~ Gas I-~ Suspended [] Abandoned [] Service ..... r' 2. Name of Operator 7. Permit Number "%.','?:'~¢ (//:/p ,, BP Exploration (Alaska)Inc. 98-58 · ~.-.(;,~, ?., 3. Address 8. APl Number -4/~,-,,?~& ' ~lU h~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22863-01 'cE~ 4. Location ofwell at sudace ~ r ~::~.'-~' :-~;'~; ~ ~ ~~~~~ 9. Unit or Lease Name 3193' NSL, 2333' WEL, SEC. 36, T12N, R16E, UM "¢/~ ~ Duck Island At top of productive inte~al~. ~.- -+.ff ~:.. ~ · 10. Well Number 2326' NSL, 4501'WEL, SEC. 27, T12N, R16E, UM -::~ ';~;¢~;:~:~,~" i t~~ 2-56~Eider-01 At total depth /~ ~ ;'~ 11. Field and Pool 2191' NSL, 5055 WEL, SEC. 27, T12N, R16E, UM ~'t'~";"'-"7"~7':':¢~~ Duck Island 5. Elevation in feet (indicate KB, DF, etc.) ]6. Lease Designation and Serial No. KBE = 54.7'I ADL 034634 12. Date Spudded3/21/98 I 13' Dat° I'D' "°ached I 14' Date C°mP" 8usp" °r ~band'll 5' Wator d°pth' 'f °ffsh°m ~ 1 ~' ~°' °f O°mpl°fi°nSs/17/98 5/28/98 ~' - 12' ~8~, O~ ~ 7. lotal ~epth (MD+~D) ~18. ~u~ 8ack Depth (MD+WD)~ ~. Dirocfional Su~ey ~20. ~opth wh~re SSSV sot [2~. lhickn~ss of ~ermafrost 17~88 1000~ F~I ~7~40 ~7~ F~ ~Yos ~o~ ~574' ~ ~4~5' (Approx.) 22. Typo Bectdc or Other ko~s ~un MWD, LWD/FE, RST, GR/CCL ~ ~ : _ :-- - .~ ~ i 23. CASING, LINER AND CEMENTING RECORD ~ [ ~ ~ ~ ~ 1 ~ i [ CASING SE~ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOSOM SIZE CEMENTING RECORD AMOUNT PULLED 30" 94¢ L-80 43' 160' Driven 9-5/8" 47¢ L-80 41' 7080' 12-1/4" 2008 sx Lite Lead PF, 250 sx 'G' 7" 29¢ L-80 39' 16451' 8-1/2" 200 sx Class 'G' 4-1/2" 12.6¢ 13CR 15652 17988' 6" 293 sx Class 'G' 24. Pedorations open to Production (MD+~D of Top and 25. TUBING RECORD Bottom and inte~al, size and number) S~ZE DEPTH S~ (MD) PACKER S~ (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6¢, L-80 15176' 15119' MD ~D MD ~D 17714 - 17904 9861' - 9959' 26. AC~D, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See Attachment "A" 27. PRODUCTION TEST Date First Production ]Method of Operation (Flowing, gas lift, etc.) June 1, 1998~ Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE J GAs-OIL ~TIO TEST PERIOD ! Flow Tubing Casing Pressure CALCU~TED OIL-EEL ~GAs-MCF WATER-EEL O~L G~w~-API (CORR) Press. 24-HOUR R~TE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Base HRZ 16785' 9486' Shublik 16990' 9564' Ivishak 17338' 9699' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I herebYsigned certify that the f~going"'% ~/ is true,end__ correct to the best of my knowledge Lowell Crar~eZ' ,~¢~~ i¢¢ ~Title Drilling Engineering Supervisor Date 2-56A/EiU,e(-01 98-58 Prepared By Name/Number: Carol Withey, 564-4114 Well Nurb~er Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL NAME: 2-56A/Eider-01 Attachment "A" for Section #26 of Form 10-407 Section #26 Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) EZSV at 15988' 16199' 15845' Amount & Kind of Material Used Freeze protect with 17 bbls diesel Cement plug, 23 bbls 'G' sqeezed to 2500 psi Cement plug, 39.5 bbls 'G' Cement plug, 22 bbls 'G' Whipstock at 15983' Sperry- Sun WELL 2-56/EI-01 PERFORATION SUMMARY DATE 5/25/98 SIZE 2 7/8" SPF STATUS 6 OPEN INTERVAL 17714 - 17904 Progress Report Facility End MPI Well 2-56/EI-01 Rig Page 7 Date 25 June 98 Date/Time 2 ! Mar 98 22 Mar 98 21:00-22:00 22:00-00:00 00:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00- I 1:30 I 1:30-12:30 12:30-15:00 15:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-08:30 08:30-08:45 08:45-09:00 09:00-10:00 10:00-10:15 10:15-10:30 10:30-11:00 1 ! :00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 Duration l hr 2 hr 6 hr 1/2 hr 1/2 hr 2 hr 2-1/2 hr 1 hr 2- I/2 hr 3 hr 1/2 hr 1 I-I/2 hr 1/2 hr 2 hr I/4 hr 1/4 hr 1 hr 1/4 hr 1/4 hr 1/2 hr 6 hr I hr I/2 hr I/2 hr Activity Drilled cement to 16456.0 ft Circulated at 16450.0 ft Pulled out of hole to 515.0 ft Held safety meeting Pulled BHA Made up BHA no. 11 R.I.H. to 9261.0 ft Serviced Block line R.I.H. to 16456.0 ft Drilled to 16471.0 ft Held safety meeting Drilled to 16622.0 ft Held safety meeting Drilled to 16650.0 ft Pulled out of hole to 16450.0 ft R.I.H. to 16650.0 ft Drilled to 16658.0 ft Flow check Pulled out of hole to 16450.0 ft Circulated at 16450.0 ft Pulled out of hole to 645.0 ft Pulled BHA Held safety meeting Downloaded MWD tool Facility Date/Time 23 Mar 98 24 Mar 98 25 Mar 98 26 Mac 98 27 Mar 98 End MPI Progress Report Well 2-56/EI-01 Rig Page Date Duration Activity 19:00-19:30 19:30-21:00 21:00-02:30 02:30-05:30 05:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-21:00 21:00-22:30 22:30-22:45 22:45-23:00 23:00-03:00 03:00-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-11:30 11:30-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-11:30 11:30-12:30 12:30-12:45 12:45-13:00 13:00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-22:00 22:00-22:30 22:30-00:00 00:00-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-11:00 11:00-18:00 18:00-18:30 18:30-01:30 01:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-10:00 10:00-10:30 1/2 hr 1-1/2 hr 5-1/2 hr 3 hr 1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 1/4 hr 1/4 hr 4 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1 hr 1/2 hr 1 hr 1/2 hr 5 hr 1/2 hr 11-1/2 hr 1/2 hr 3 hr 1 hr 1 hr 1 hr 1/4 hr 1/4 hr 4hr lhr 1/2 hr 1/2 hr 3 hr 1/2 hr 1-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 3 hr 7 hr 1/2 hr 7 hr 1-1/2 hr lhr 2 hr 1/2 hr 3-1/2 hr 1/2 hr Pulled BHA Made up BHA no. 12 R.I.H. to 16560.0 fi Reamed to 16658.0 ft Drilled to 16665.0 ft Held safety meeting Drilled to 16803.0 ft Held safety meeting Drilled to 16815.0 ft Circulated at 16815.0 ft Pulled out of hole to 13965.0 ft Flow check Circulated at 13965.0 ft Pulled out of hole to 646.0 ft Pulled BHA Made up BHA no. 13 R.I.H. to 1600.0 ft Held safety meeting R.I.H. to 15481.0 ft Serviced Block line Serviced Top drive R.I.H. to 16721.0 ft Washed to 16815.0 ft Drilled to 16854.0 ft Held safety meeting Drilled to 17038.0 ft Held safety meeting Drilled to 17090.0 ft Circulated at 17090.0 ft Pumped out of hole to 16450.0 ft Pulled out of hole to 14238.0 ft Flow check Circulated at 14238.0 ft Pulled out of hole to 650.0 ft Pulled BHA Held safety meeting Retrieved Wear bushing Tested All functions Installed Wear bushing Made up BHA no. 14 R.I.H. to 16450.0 fi Serviced Block line Held safety meeting R.I.H. to 16900.0 ft Reamed to 17090.0 ft Drilled to 17195.0 ft Held safety meeting Drilled to 17282.0 fi Circulated at 17282.0 ft Pulled out of hole to 16450.0 ft Pulled out of hole to 12000.0 ft Held safety meeting Pulled out of hole to 650.0 ft Pulled BHA 8 25 June 98 Facility Date/Time 28 Mar 98 29 Mar 98 30 Mar 98 31 Mar 98 01 Apr 98 Progress Report End MPI Well 2-56/EI-01 Page 9 Rig Date 25 June 98 10:30-11:00 11:00-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-20:00 20:00-06:00 06:00-06:30 06:30-10:30 10:30-12:00 12:00-13:00 13:00-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:30 21:30-02:00 02:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-07:00 07:00-08:45 08:45-09:00 09:00-10:00 10:00-15:30 15:30-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-01:30 01:30-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-10:30 10:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-21:30 21:30-23:00 23:00-01:00 Duration 1/2 hr 5 hr 1 hr lhr 1/2 hr 1-1/2 hr 10hr 1/2 hr 4hr 1-1/2 hr 1 hr 5hr 1/2 hr 1 hr 1 hr 1 hr 4-1/2 hr 1 hr 1 hr 1 hr 1 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1/2 hr 1-3/4 hr 1/4 hr 1 hr 5-1/2 hr 1 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 6 hr 1 hr 1/2 hr 3hr 1/2 hr 4 hr 7-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3 hr 1-1/2 hr 2 hr Activity Made up BHA no. 15 R.I.H. to 16450.0 ft Serviced Block line ~ R.I.H. to 17081.0 ft Held safety meeting Reamed to 17282.0 ft Drilled to 17435.0 ft Held safety meeting Drilled to 17480.0 ft Circulated at 17480.0 ft Pumped out of hole to 16450.0 ft Pumped out of hole to 3000.0 ft Held safety meeting Pulled out of hole to 655.0 ft Pulled BHA Made up BHA no. 16 R.I.H. to 16450.0 ft Serviced Block line R.I.H. to 17390.0 ft Reamed to 17480.0 ft Drilled to 17495.0 ft Held safety meeting Drilled to 17645.0 ft Held safety meeting Drilled to 17765.0 ft Held safety meeting Drilled to 17770.0 ft Circulated at 17770.0 ft Flow check Pulled out of hole to 16450.0 ft Pulled out of hole to 650.0 ft Downloaded MWD tool Pulled BHA Made up BHA no. 17 Held safety meeting Made up BHA no. 17 Serviced Top drive R.I.H. to 16400.0 ft Serviced Block line R.I.H. to 17135.0 ft Logged hole with LWD: Formation evaluation (FE) from 17178.0 ft to 17400.0 ft Held safety meeting Logged hole with LWD: Formation evaluation (FE) from 17400.0 ft to 17770.0 ft Drilled to 17791.0 ft Held safety meeting Drilled to 17855.0 ft Held safety meeting Drilled to 17985.0 ft Held safety meeting Drilled to 18013.0 ft Circulated at 18013.0 ft Pumped out of hole to 16300.0 ft Progress Report Facility End MPI Well 2-56/EI-01 Rig Page 10 Date 25 June 98 Date/Time 02 Apr 98 03 Apr 98 04 Apr 98 05 Apr 98 06 Apr 98 01:00-01:30 01:30-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-09:30 09:30-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-20:30 20:30-01:00 01:00-02:00 02:00-02:30 02:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-09:30 09:30-12:30 12:30-15:00 15:00-16:00 16:00-18:00 18:00-18:30 18:30-20:00 20:00-22:30 22:30-23:30 23:30-01:30 01:30-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-12:00 12:00-13:00 13:00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 Duration 1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 3 hr 1/2 hr 5 hr 1/2 hr 2 hr 4-1/2 hr lhr 1/2 hr 3-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3hr 3hr 2-1/2 hr lhr 2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 1 hr 2hr 4 hr 1/2 hr 1/2 hr 2-1/2 hr 3 hr 1 hr 4hr lhr 1/2 hr 1/2 hr 1-1/2 hr 5hr 2 hr 1 hr 1-1/2 hr 1/2 hr 2 hr 1/2 hr 8 hr 1 hr 1/2 hr 1 hr Activity Serviced Top drive Pulled out of hole to 13205.0 ft Circulated at 13205.0 ft , Pulled out of hole to 1200.0 ft Held safety meeting Pulled out of hole to 232.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Repaired Top drive Held safety meeting Made up BHA no. 18 R.I.H. to 16450.0 ft Serviced Block line R.I.H. to 18014.0 ft Drilled to 18050.0 ft Held safety meeting Drilled to 18229.0 ft Held safety meeting Drilled to 18300.0 ft Held safety meeting Drilled to 18340.0 ft Circulated at 18340.0 ft Pumped out of hole to 16421.0 ft Rigged up sub-surface equipment - Formation logs Conducted electric cable operations Held safety meeting Conducted electric cable operations R.I.H. to 16103.0 ft R.I.H. to 18340.0 ft Conducted electric cable operations Conducted electric cable operations Retrieved Formation logs Held safety meeting Rigged down sub-surface equipment - Formation logs Serviced Block line R.I.H. to 18340.0 ft Circulated at 18340.0 ft Pumped out of hole to 17000.0 ft Held safety meeting Pumped out of hole to 16450.0 ft Pulled out of hole to 11640.0 ft Pulled out of hole to 221.0 ft Pulled BHA Rigged up Casing handling equipment Ran Liner to 400.0 ft (4-1/2in OD) Held safety meeting Ran Liner to 2168.0 ft (4-1/2in OD) Circulated at 2168.0 ft Ran Drillpipe in stands to 16431.0 ft Rigged up sub-surface equipment - Setting tools Held safety meeting Ran Drillpipe in stands to 18255.0 ft Facility Date/Time 07 Apr 98 08 Apr 98 09 Apr 98 10 Apr 98 Progress Report End MPI Well 2-56/EI-01 Page 11 Rig Date 25 June 98 19:30-23:00 23:00-01:30 01:30-02:30 02:30-03:30 03:30-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-11:00 11:00-14:00 14:00-14:30 14:30-17:30 17:30-18:00 18:00-18:30 18:30-20:30 20:30-23:00 23:00-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-11:00 11:00-13:00 13:00-14:00 14:00-15:30 15:30-17:30 17:30-18:00 18:00-18:30 18:30-22:00 22:00-23:30 23:30-00:30 00:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-11:00 11:00-15:00 15:00-15:30 15:30-17:30 17:30-18:00 18:00-18:30 18:30-22:00 22:00-23:30 23:30-00:00 00:00-02:00 02:00-03:30 03:30-05:30 05:30-06:00 06:00-06:30 06:30-11:30 11:30-12:30 12:30-13:30 Duration 3-1/2 hr 2-1/2 hr 1 hr lhr 2hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 3hr 1/2 hr 3 hr 1/2 hr 1/2 hr 2 hr 2-1/2 hr 3-1/2 hr 2hr 1-1/2 hr 1/2 hr 4-1/2 hr 2 hr 1 hr 1-1/2 hr 2 hr 1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1 hr 4 hr 1 hr 1/2 hr 1/2 hr 2 hr 2 hr 1/2 hr 4hr 1/2 hr 2 hr 1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 2 hr 1-1/2 hr 2 hr 1/2 hr 1/2 hr 5hr 1 hr 1 hr Activity Washed to 18263.0 ft Circulated at 18263.0 ft Mixed and pumped slurry - 50.000 bbl Displaced slurry - 115.000 bbl Circulated at 16095.0 ft Pulled Drillpipe in stands to 15000.0 ft Held safety meeting Pulled Drillpipe in stands to 15000.0 ft Ran Drillpipe in stands to 16095.0 ft Circulated at 16095.0 ft Pumped out of hole to 13200.0 ft Circulated at 13200.0 ft Pulled Drillpipe in stands to 6595.0 ft Rigged down sub-surface equipment - Other sub-surface equipment Held safety meeting Pulled Drillpipe in stands to 0.0 ft Laid down 602.0 ft of Liner Fished at 16730.0 ft Made up BHA no. 19 R.I.H. to 2500.0 ft Held safety meeting R.I.H. to 16340.0 ft Circulated at 16340.0 ft Washed to 16460.0 ft Circulated at 16460.0 ft Pumped out of hole to 10600.0 ft Circulated at 10600.0 ft Held safety meeting Pulled out of hole to 779.0 ft Pulled BHA Made up BHA no. 20 R.I.H. to 16400.0 ft Serviced Block line R.I.H. to 16460.0 ft Held safety meeting Circulated at 16468.0 ft Pumped out of hole to 13202.0 ft Circulated at 13202.0 ft Pulled out of hole to 518.0 ft Pulled BHA Made up BHA no. 21 R.I.H. to 3423.0 ft Held safety meeting R.I.H. to 16450.0 ft Washed to 16720.0 ft Circulated at 16720.0 ft Reamed to 16720.0 ft Circulated at 16720.0 ft Pumped out of hole to 13800.0 ft Circulated at 13800.0 ft Held safety meeting Pulled out of hole to 541.0 ft Pulled BHA Made up BHA no. 22 Progress Report Facility End MPI Well 2-56/EI-01 Rig Page 12 Date 25 June 98 Date/Time 11 Apr 98 12 Apr 98 13 Apr 98 13:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-21:00 21:00-00:30 00:30-02:00 02:00-02:30 02:30-03:30 03:30-04:00 04:00-05:30 05:30-06:00 06:00-06:30 06:30-09:30 09:30-10:00 10:00-11:30 11:30-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-21:30 21:30-23:30 23:30-00:00 00:00-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-11:00 11:00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-22:30 22:30-00:30 00:30-01:00 01:00-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-08:00 08:00-09:30 09:30-15:30 15:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-21:00 21:00-21:30 21:30-23:00 23:00-23:30 23:30-03:30 Duration 4-1/2 hr 1/2 hr 1 hr lhr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 3hr 1/2 hr 1-1/2 hr 6 hr 1/2 hr 1/2 hr 1 hr 2hr 2 hr 1/2 hr 4 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 2-1/2 hr 2hr 6 hr 1 hr 1/2 hr 1/2 hr 3-1/2 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr 3 hr 1/2 hr 1-1/2 hr 1-1/2 hr 6hr 1/2 hr 1 hr 1 hr 1/2 hr 1/2 hr 2hr 1/2 hr 1-1/2 hr 1/2 hr 4 hr Activity R.I.H. to 13017.0 ft Held safety meeting R.I.H. to 16000.0 ft Serviced Block line R.I.H. to 16720.0 ft Milled Liner at 16727.0 ft Circulated at 16727.0 ft Pumped out of hole to 16400.0 ft Pulled out of hole to 13500.0 ft Circulated at 13500.0 ft Pulled out of hole to 9000.0 ft Repaired Draw works Repaired Draw works Pulled out of hole to 458.0 ft Pulled BHA Made up BHA no. 23 R.I.H. to 16450.0 ft Circulated at 16450.0 ft Held safety meeting Washed to 16630.0 ft Circulated at 16450.0 ft Pulled out of hole to 13500.0 ft Circulated at 13500.0 ft Pulled out of hole to 677.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Held safety meeting Tested BOP stack Made up BHA no. 24 R.I.H. to 16037.0 ft Serviced Block line Held safety meeting R.I.H. to 16727.0 ft Reamed to 16727.0 ft Circulated at 16727.0 ft Pulled out of hole to 16300.0 ft Pulled out of hole to 13500.0 ft Circulated at 13500.0 ft Pulled out of hole to 541.0 ft Held safety meeting Pulled BHA Made up BHA no. 25 R.I.H. to 16450.0 ft Washed to 16713.0 ft Circulated at 16713.0 ft Fished at 16727.0 ft Held safety meeting Fished at 16727.0 ft Circulated at 16727.0 ft Pumped out of hole to 16300.0 ft Pulled out of hole to 14000.0 ft Circulated at 14000.0 ft Pulled out of hole to 689.0 ft Progress Report Facility End MPI Well 2-56/EI-01 Rig Page 13 Date 25 June 98 Date/Time 14 Apr 98 03:30-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-12:00 12:00-13:00 13:00-14:00 14:00-15:30 15:30-18:30 18:30-21:30 21:30-01:00 15 Apr 98 01:00-04:00 04:00-06:00 06:00-06:30 06:30-10:30 10:30-11:30 11:30-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-01:00 16 Apr 98 01:00-02:00 02:00-06:00 06:00-06:30 06:30-07:00 07:00-11:30 11:30-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-19:30 19:30-19:45 19:45-20:00 20:00-21:00 21:00-22:00 22:00-22:30 22:30-04:30 17 Apr 98 04:30-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-14:00 14:00-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-02:00 18 Apr 98 02:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 Duration 1 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 5 hr lhr lhr 1-1/2 hr 3 hr 3 hr 3-1/2 hr 3 hr 2hr 1/2 hr 4 hr lhr 4 hr lhr 1-1/2 hr 1/2 hr 6-1/2 hr 1 hr 4hr 1/2 hr 1/2 hr 4-1/2 hr 1 hr 1/2 hr 5hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 1/4 hr 1 hr 1 hr 1/2 hr 6 hr 1-1/2 hr 1/2 hr 4hr 1/2 hr 3hr 4hr 1/2 hr 1 hr 1/2 hr 6 hr 2hr 1/2 hr 1-1/2 hr 1/2 hr Activity Pulled BHA Serviced Drillfloor / Derrick Made up BHA no. 25 Held safety meeting Made up BHA no. 25 R.I.H. to 16004.0 ft Serviced Block line R.I.H. to 16718.0 ft Circulated at 16718.0 ft Fished at 16727.0 ft Fished at 16727.0 ft Circulated at 16727.0 ft Rigged up Rigging equipment Conducted electric cable operations Held safety meeting Conducted electric cable operations Pulled out of hole to 0.0 ft Conducted electric cable operations Rigged down Logging/braided cable equipment Circulated at 16716.0 ft Held safety meeting Pulled out of hole to 699.0 ft Rigged up Logging/braided cable equipment Conducted electric cable operations Held safety meeting Installed Cement retainer Set downhole equipment (wireline) Rigged down Logging/braided cable equipment Serviced Draw works Ran Drillpipe in stands to 15988.0 ft Held safety meeting Rigged up High pressure lines Stung into Cement retainer Injectivity test - 12.000 bbl injected at 2500.0 psi Tested High pressure lines Mixed and pumped slurry - 23.000 bbl Displaced slurry - 110.000 bbl Circulated at 15988.0 ft Circulated at 15988.0 ft Pulled out of hole to 0.0 ft Repaired Draw works Held safety meeting Repaired Draw works Serviced Top drive Made up BHA no. 27 R.I.H. to 13300.0 ft Held safety meeting R.I.H. to 15983.0 ft Functioned downhole tools at 15983.0 ft Milled Casing at 15987.0 ft Circulated at 15987.0 ft Flow check Pulled out of hole to 11800.0 ft Held safety meeting Facility Date/Time 19 Apr 98 20 Apr 98 21 Apr 98 22 Apr 98 23 Apr 98 End MPI Progress Report Well 2-56/EI-01 Rig Page Date Duration Activity 06:30-09:00 09:00-10:00 10:00-11:00 11:00-11:30 11:30-14:30 14:30-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-19:00 19:00-06:00 06:00-06:30 06:30-10:00 10:00-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-18:30 18:30-21:00 21:00-21:30 2-1/2 hr 1 hr lhr 1/2 hr 3 hr 1 hr 1/2 hr 2 hr 1/2 hr 1/2 hr llhr 1/2 hr 3-1/2 hr 5-1/2 hr 1 hr 1/2 hr 1 hr 1/2 hr 2-1/2 hr 1/2 hr Pulled out of hole to 670.0 ft Pulled BHA Made up BHA no. 27 Tested M.W.D. tool - Via string R.I.H. to 11670.0 ft Serviced Block line Serviced Draw works R.I.H. to 15958.0 ft Held safety meeting Set tool face Drilled to 16066.0 ft Held safety meeting Drilled to 16081.0 ft Pulled out of hole to 185.0 ft Pulled BHA Retrieved Wear bushing Tested Choke manifold Held safety meeting Tested All functions Installed Wear bushing 21:30-22:30 22:30-23:00 23:00-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-23:30 23:30-01:00 O1:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-08:30 08:30-09:00 09:00-11:00 11:00-12:00 12:00-15:00 15:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-21:30 21:30-23:30 23:30-00:00 00:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:00 lhr 1/2 hr 4hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 5 hr 1-1/2 hr 5 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 2 hr lhr 3 hr 3 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3 hr 2 hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr Made up BI-IA no. 29 Tested M.W.D. tool - Via string R.I.H. to 15900.0 ft Serviced Block line R.I.H. to 16081.0 ft Drilled to 16106.0 ft Held safety meeting Drilled to 16253.0 ft Held safety meeting Drilled to 16333.0 ft Circulated at 16333.0 ft Pulled out of hole to 184.4 ft Held safety meeting Pulled BHA Serviced Draw works Made up BHA no. 30 Tested MWD - Via string R.I.H. to 8805.0 ft Serviced Block line R.I.H. to 16333.0 ft Drilled to 16363.0 ft Held safety meeting Drilled to 16490.0 ft Held safety meeting Drilled to 16654.0 ft Held safety meeting Drilled to 16674.0 ft Circulated at 16674.0 ft Pumped out of hole to 15958.0 ft Pulled out of hole to 185.0 ft Pulled BHA Held safety meeting Pulled BHA Serviced Top drive 14 25 June 98 Progress Report Facility End MPI Well 2-56/EI-01 Page 15 Rig Date 25 June 98 Date/Time 24 Apr 98 25 Apr 98 26 Apr 98 27 Apr 98 08:00-09:00 09:00-10:30 10:30-11:30 11:30~12:00 12:00-13:00 13:00-13:30 13:30-14:00 14:00-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-21:30 21:30-23:30 23:30~00:30 00:30-06:00 06:00-06:30 06:30-16:30 16:30-18:00 18:00-18:30 18:30-20:30 20:30-02:00 02:00-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-13:30 13:30-16:00 16:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-19:30 19:30-21:00 21:00-03:00 03:00-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-10:00 10:00-11:00 11:00-15:00 15:00-16:00 16:00-16:30 16:30-17:00 Duration 1 hr 1-1/2 hr 1 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 2hr lhr 5-1/2 hr 1/2 hr 10hr 1-1/2 hr 1/2 hr 2 hr 5-1/2 hr 1-1/2 hr 1/2 hr 1 hr 1 hr 1/2 hr 4-1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 2hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 1 hr 1-1/2 hr 6hr 1-1/2 hr 1/2 hr 1 hr 1/2 hr 2 hr 1/2 hr lhr 1 hr 4 hr 1 hr 1/2 hr 1/2 hr Activity Made up BHA no. 31 Serviced LWD tool R.I.H. to 3000.0 ft Tested M.W.D. tool - Via string Pulled out of hole to 213.0 ft Pulled BHA Made up BHA no. 32 Serviced LWD tool Tested M.W.D. tool - Via string R.I.H. to 10268.0 ft Held safety meeting R.I.H. to 15900.0 ft Serviced Block line R.I.H. to 16590.0 ft Washed to 16674.0 ft Took MWD survey at 16664.0 ft Drilled to 16747.0 ft Held safety meeting Drilled to 16840.0 ft Circulated at 16840.0 ft Held safety meeting Logged hole with LWD: Formation evaluation (FE) from 16674.0 ft to 16450.0 ft Pulled out of hole to 213.0 ft Downloaded MWD tool Pulled BHA Made up BHA no. 33 Serviced LWD tool Held safety meeting R.I.H. to 14765.0 ft Serviced Block line R.I.H. to 16664.0 ft Washed to 16840.0 ft Drilled to 16858.0 ft Held safety meeting Drilled to 17058.0 ft Held safety meeting Drilled to 17154.0 ft Held safety meeting Drilled to 17175.0 ft Circulated at 17175.0 ft Pulled out of hole to 213.0 ft Pulled BHA Retrieved Wear bushing Tested Choke manifold Held safety meeting Tested All functions Installed Wear bushing Made up BHA no. 33 Serviced LWD tool R.I.H. to 15900.0 ft Serviced Block line R.I.H. to 16575.0 ft Washed to 16725.0 ft Facility Date/Time 28 Apr 98 29 Apr 98 30 Apr 98 01 May 98 02 May 98 Progress Report End MPI Well 2-56/EI-01 Page 16 Rig Date 25 June 98 17:00-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-10:30 10:30-12:30 12:30-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-00:30 00:30-02:00 02:00-02:30 02:30-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-11:30 11:30-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-01:00 01:00-02:00 02:00-02:30 02:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-10:00 10:00-13:30 13:30-14:30 14:30-18:00 18:00-18:30 18:30-21:00 21:00-23:30 23:30-06:00 06:00-06:30 06:30-07:30 07:30-14:00 14:00-15:00 Duration 1/2 hr 1/2 hr 1/2 hr lhr 10-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 4 hr 2 hr 2 hr lhr 2-1/2 hr 1/2 hr 3 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 2 hr 1/2 hr 2 hr 2 hr 1 hr 5 hr 1 hr 1/2 hr 1/2 hr 1 hr 5-1/2 hr 1 hr 1/2 hr 3-1/2 hr 1/2 hr lhr 1 hr 1-1/2 hr 3-1/2 hr 1 hr 3-1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 6-1/2 hr 1/2 hr 1 hr 6-1/2 hr 1 hr Activity R.I.H. to 17066.0 ft Reamed to 17155.0 ft Held safety meeting Reamed to 17175.0 ft Drilled to 17270.0 ft Held safety meeting Drilled to 17470.0 ft Held safety meeting Drilled to 17720.0 ft Held safety meeting Drilled to 17775.0 ft Circulated at 17775.0 ft Pulled out of hole to 15958.0 ft R.I.H. to 16900.0 ft Logged hole with LWD: Formation evaluation (FE) from 16900.0 ft to 17195.0 ft Held safety meeting Logged hole with LWD: Formation evaluation (FE) from 17195.0 ft to 17500.0 ft R.I.H. to 17775.0 ft Circulated at 17775.0 ft Pulled out of hole to 15900.0 ft R.I.H. to 16518.0 ft Pulled out of hole to 15900.0 ft Circulated at 15900.0 ft Pulled out of hole to 9630.0 ft Held safety meeting Pulled out of hole to 223.0 ft Pulled BHA Made up BHA no. 34 R.I.H. to 15900.0 ft Serviced Block line R.I.H. to 16514.0 ft Held safety meeting Washed to 16534.0 ft Pulled out of hole to 180.0 ft Pulled BHA Made up BHA no. 35 R.I.H. to 10700.0 ft Held safety meeting Serviced Block line R.I.H. to 16438.0 ft Washed to 16514.0 ft Washed to 16531.0 ft Circulated at 16531.0 ft Washed to 16580.0 ft Held safety meeting Washed to 16595.0 ft Drilled to 16562.0 ft Pulled out of hole to 164.0 ft Held safety meeting Pulled BHA Ran Drillpipe in stands to 15850.0 ft Serviced Block line Facility Date/Time 03 May 98 04 May 98 05 May 98 06 May 98 End MPI Progress Report Well 2-56/EI-01 Rig Page Date Duration Activity 15:00-15:30 15:30-16:30 16:30-18:00 18:00-19:00 19:00-19:30 19:30-21:00 21:00-21:30 21:30-02:30 02:30-03:00 03:00-06:00 06:00-06:30 06:30-11:30 11:30-12:30 12:30-13:00 13:00-13:30 13:30-14:30 14:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-23:00 23:00-03:00 03:00-06:00 06:00-06:30 06:30-09:00 09:00-10:00 10:00-10:30 10:30-16:00 16:00-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-20:30 20:30-22:30 22:30-03:30 03:30-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-11:30 11:30-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-19:30 19:30-01:00 01:00-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-01:00 1/2 hr 1 hr 1-1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 5 hr 1/2 hr 3hr 1/2 hr 5 hr 1 hr 1/2 hr 1/2 hr 1 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1 hr 2 hr 4 hr 3 hr 1/2 hr 2-1/2 hr 1 hr 1/2 hr 5-1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 2 hr 5 hr 1 hr 1-1/2 hr 1/2 hr 3 hr 1 hr 1 hr 4 hr 1/2 hr 2 hr 1/2 hr lhr 5-1/2 hr 5 hr 1/2 hr 11-1/2 hr 1/2 hr 6-1/2 hr Serviced Top drive Ran Drillpipe in stands to 16580.0 ft Circulated at 16580.0 ft Mixed and pumped slurry - 47.500 bbl Pulled out of hole to 15685.0 ft Circulated at 15685.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Retrieved Wear bushing Tested BOP stack Held safety meeting Serviced Annular preventor Tested Annular preventor Installed Wear bushing Serviced Iron roughneck Made up BHA no. 36 R.I.H. to 9263.0 ft Held safety meeting R.I.H. to 15664.0 ft Washed to 15950.0 ft Washed to 16219.0 ft Circulated at 16219.0 ft Pulled out of hole to 8000.0 ft Held safety meeting Pulled out of hole to 170.0 ft Pulled BHA Serviced Top drive Ran Drillpipe in stands to 15880.0 ft Serviced Block line Ran Drillpipe in stands to 16227.0 ft Circulated at 16227.0 ft Held safety meeting Circulated at 16227.0 ft Mixed and pumped slurry - 22.000 bbl Pumped out of hole to 15808.0 ft Circulated at 15808.0 ft Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 37 R.I.H. to 6400.0 ft Held safety meeting R.I.H. to 15000.0 ft Serviced Block line R.I.H. to 15845.0 ft Drilled cement to 15983.0 ft Pulled out of hole to 15948.0 ft Circulated at 15948.0 ft Held safety meeting Circulated at 15948.0 ft Drilled to 16010.0 ft Drilled to 16060.0 ft Held safety meeting Drilled to 16207.0 ft Held safety meeting Drilled to 16269.0 ft 17 25 June 98 Progress Report Facility End MPI Well 2-56/EI-01 Rig Page 18 Date 25 June 98 Date/Time 07 May 98 01:00-01:30 01:30-03:00 03:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-09:30 09:30-12:00 12:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-06:00 08 May 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-22:30 22:30-00:30 09 May 98 00:30-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-16:30 16:30-18:00 18:00-18:30 18:30-21:30 21:30-23:30 23:30-00:30 10 May 98 00:30-02:30 02:30-06:00 06:00-06:30 06:30-08:30 08:30-11:00 11:00-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-22:00 22:00-06:00 11 May 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-23:30 23:30-01:30 12 May 98 01:30-02:30 02:30-03:30 03:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 13 May 98 06:00-06:30 06:30-08:30 08:30-10:00 Duration 1/2 hr 1-1/2 hr 3 hr 1/2 hr 1-1/2 hr lhr 1/2 hr 2-1/2 hr 5 hr 1 hr 1/2 hr 1 hr 10-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 4 hr 2hr 5-1/2 hr 1/2 hr 1 hr 1-1/2 hr 7-1/2 hr 1-1/2 hr 1/2 hr 3 hr 2 hr 1 hr 2 hr 3-1/2 hr 1/2 hr 2 hr 2-1/2 hr 3-1/2 hr 1/2 hr 3 hr 1/2 hr 3-1/2 hr 8 hr 1/2 hr 11-1/2 hr 1/2 hr 5hr 2hr 1 hr 1 hr 2-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 2 hr 1-1/2 hr Activity Pulled out of hole to 15950.0 ft Circulated at 15950.0 ft Pulled out of hole to 4100.0 ft Held safety meeting Pulled out of hole to 170.0 ft Pulled BHA Serviced Mechanical brake Made up BHA no. 38 R.I.H. to 15856.0 ft Serviced Block line Held safety meeting R.I.H. to 16269.0 ft Drilled to 16431.0 ft Held safety meeting Drilled to 16123.0 ft Held safety meeting Drilled to 16719.0 ft Circulated at 16719.0 ft Pulled out of hole to 176.0 ft Held safety meeting Pulled BHA Made up BHA no. 39 R.I.H. to 16446.0 ft Reamed to 16607.0 ft Held safety meeting Reamed to 16650.0 ft Pulled out of hole to 14650.0 ft R.I.H. to 16460.0 ft Reamed to 16680.0 ft Reamed to 16710.0 ft Held safety meeting Pumped out of hole to 16446.0 ft Circulated at 16446.0 ft Reamed to 16542.0 ft Repaired Top drive Reamed to 16607.0 ft Held safety meeting Reamed to 16719.0 ft Drilled to 17055.0 ft Held safety meeting Drilled to 17209.0 ft Held safety meeting Drilled to 17397.0 ft Circulated at 17397.0 ft Pulled out of hole to 15973.0 ft R.I.H. to 17397.0 ft Drilled to 17445.0 ft Held safety meeting Drilled to 17502.0 ft Held safety meeting Drilled to 17600.0 ft Held safety meeting Drilled to 17621.0 ft Circulated at 17621.0 ft Progress Report Facility End MPI Well 2-56fEI-01 Rig Page 19 Date 25 June 98 Date/Time 10:00-10:30 10:30-11:00 11:00-12:00 12:00-12:30 12:30-13:00 13:00-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-22:00 22:00-22:30 22:30-03:30 14 May 98 03:30-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-08:30 08:30-09:00 09:00-09:30 09:30-12:00 12:00-17:30 17:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-20:00 20:00-06:00 15 May 98 06:00-06:30 06:30-13:30 13:30-14:30 14:30-15:00 15:00-15:30 15:30-18:00 18:00-18:30 18:30-19:00 19:00-06:00 16 May 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-04:00 17 May 98 04:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-10:00 10:00-11:30 11:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-20:30 20:30-02:00 18 May 98 02:00-03:00 Duration 1/2 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 2 hr 1/2 hr 5 hr 1/2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 1/2 hr 2-1/2 hr 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 10hr 1/2 hr 7hr lhr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr llhr 1/2 hr 11-1/2 hr 1/2 hr 9-1/2 hr 2 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 6-1/2 hr 1/2 hr 1/2 hr 1 hr 1/2 hr 5-1/2 hr lhr Activity Flow check Pulled out of hole to 16064.0 ft R.I.H. to 16698.0 ft Reamed to 17018.0 ft R.I.H. to 17621.0 ft Drilled to 17644.0 ft Circulated at 17644.0 ft Held safety meeting Circulated at 17644.0 ft Pulled out of hole to 14500.0 ft Circulated at 14500.0 ft Pulled out of hole to 187.0 ft Downloaded MWD tool Pulled BHA Retrieved Wear bushing Tested All functions Held safety meeting Tested All functions Installed Wear bushing Serviced Top drive Made up BHA no. 40 R.I.H. to 15866.0 fi Serviced Block line Held safety meeting Set tool face R.I.H. to 16680.0 ft Pulled out of hole to 16440.0 ft Washed to 16706.0 ft Held safety meeting Reamed to 16827.0 ft R.I.H. to 17610.0 ft Reamed to 17620.0 ft Pulled out of hole to 17517.0 ft Reamed to 17617.0 ft Held safety meeting Reamed to 17644.0 ft Drilled to 17730.0 ft Held safety meeting Drilled to 17922.0 ft Held safety meeting Drilled to 17988.0 ft Circulated at 17988.0 ft Held safety meeting Circulated at 17988.0 ft Circulated at 17988.0 ft Pulled out of hole to 15900.0 ft Circulated at 15900.0 ft Rest hole at 15988.0 ft Held safety meeting R.I.H. to 16455.0 ft Reamed to 16914.0 ft R.I.H. to 17988.0 ft Circulated at 17988.0 ft Circulated at 17988.0 ft Facility End MPI Progress Report Well 2-56/EI-01 Rig Page Date 20 25 June 98 Date/Time 19 May 98 20 May 98 21 May 98 03:00-04:30 04:30-06:00 06:00-06:30 06:30-12:00 12:00-14:00 14:00-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:30 22:30-23:00 23:00-02:30 02:30-03:30 03:30-04:00 04:00-04:15 04:15-05:00 05:00-06:00 06:00-06:30 06:30-10:30 10:30-11:00 11:00-11:30 11:30-12:30 12:30-14:30 14:30-15:30 15:30-16:00 16:00-18:00 18:00-18:30 18:30-21:30 21:30-22:00 22:00-23:30 23:30-00:00 00:00-00:30 00:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-13:00 13:00-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-20:30 20:30-23:30 23:30-00:00 00:00-05:00 05:00-06:00 06:00-06:30 06:30-07:00 07:00-09:00 09:00-09:30 Duration 1-1/2 hr 1-1/2 hr 1/2 hr 5-1/2 hr 2hr 4 hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 1/2 hr 3-1/2 hr lhr 1/2 hr 1/4 hr 3/4 hr 1 hr 1/2 hr 4hr 1/2 hr 1/2 hr lhr 2hr 1 hr 1/2 hr 2 hr 1/2 hr 3 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 4hr lhr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 3 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 3hr 1/2 hr 5 hr 1 hr 1/2 hr 1/2 hr 2 hr 1/2 hr Activity Pulled out of hole to 15900.0 ft Rest hole at 15900.0 ft Held safety meeting Rest hole at 15900.0 ft R.I.H. to 17988.0 ft Circulated at 16988.0 ft Held safety meeting Circulated at 17988.0 ft Circulated at 17988.0 ft Pulled out of hole to 14500.0 ft Circulated at 14500.0 ft Pulled out of hole to 179.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Liner to 2300.0 ft (4-1/2in OD) Ran Drillpipe on landing string to 6000.0 ft Held safety meeting Ran Liner on landing string to 15900.0 ft Circulated at 15900.0 ft Ran Liner on landing string to 16678.0 ft Washed to 16678.0 ft Circulated at 16678.0 ft Pulled Drillpipe in stands to 15900.0 ft Circulated at 15900.0 ft Pulled Drillpipe in stands to 11400.0 ft Held safety meeting Pulled Drillpipe in stands to 2326.0 ft Rigged up Casing handling equipment Laid down 2326.0 ft of Liner Rigged down Casing handling equipment Made up BHA no. 41 R.I.H. to 15958.0 ft Serviced Block line R.I.H. to 16543.0 ft Held safety meeting Reamed to 16750.0 ft R.I.H. to 17988.0 ft Circulated at 17988.0 ft Pulled out of hole to 15000.0 ft Circulated at 15000.0 ft Pulled out of hole to 1905.0 ft Held safety meeting Pulled out of hole to 179.0 ft Pulled BHA Rigged up Casing handling equipment Ran Liner to 2326.0 ft (4-1/2in OD) Rigged down Casing handling equipment Ran Liner on landing string to 15910.0 ft Circulated at 15910.0 ft Held safety meeting Ran Drillpipe on landing string to 16552.0 ft Washed to 16750.0 ft Ran Drillpipe on landing string to 17988.0 ft Facility Date/Time 22 May 98 23 May 98 24 May 98 25 May 98 Progress Report End MPI Well 2-56/EI-01 Rig Page 21 Date 25 June 98 09:30-15:00 15:00-15:30 15:30-15:45 15:45-16:00 16:00-16:15 16:15-17:00 17:00-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-20:30 20:30-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-07:00 07:00-10:30 10:30-11:00 11:00-11:30 11:30-18:00 18:00-18:30 18:30-19:00 19:00-19:30 19:30-20:00 20:00-20:30 20:30-00:00 00:00-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-09:30 09:30-11:30 11:30-16:00 16:00-18:00 18:00-18:30 18:30-22:30 22:30-23:00 23:00-03:30 03:30-06:00 06:00-06:30 06:30-07:00 07:00-13:30 13:30-15:30 15:30-16:00 16:00-17:00 17:00-18:00 18:00-18:30 18:30-22:30 22:30-23:00 23:00-03:30 03:30-04:30 04:30-06:00 06:00-06:30 Duration 5-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 6-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 1-1/2 hr lhr 1/2 hr 1 hr 2 hr 2 hr 4-1/2 hr 2 hr 1/2 hr 4hr 1/2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 6-1/2 hr 2 hr 1/2 hr lhr 1 hr 1/2 hr 4 hr 1/2 hr 4-1/2 hr 1 hr 1-1/2 hr 1/2 hr Activity Circulated at 17988.0 ft Held safety meeting Tested High pressure lines Pumped Water spacers - volume 20.000 bbl Mixed and pumped slurry - 60.000 bbl Displaced slurry - 140.000 bbl Set Liner hanger at 15663.0 ft with 2800.0 psi Circulated at 15664.0 ft Held safety meeting Circulated at 15664.0 ft Rigged down Cement head Pulled Drillpipe in stands to 0.0 ft Retrieved Wear bushing Tested All functions Held safety meeting Rigged up Drillstring handling equipment Made up BHA no. 42 Rigged up Drillstring handling equipment Circulated at 2275.0 ft R.I.H. to 17800.0 ft Held safety meeting Washed to 17896.0 ft Tested Casing - Via string Drilled installed equipment - Landing collar Drilled cement to 17930.0 ft Circulated at 17930.0 ft Serviced Fluid system Circulated at 17930.0 ft Circulated at 17930.0 ft Held safety meeting Circulated at 17930.0 ft Cleared Flowline Circulated at 17930.0 ft Rig waited · Equipment Filter Brine Held safety meeting Filter Brine Flow check Pulled out of hole to 2275.0 ft Pulled BHA Held safety meeting Installed Tie back packer Ran Drillpipe in stands to 15663.0 ft Set packer at 15663.0 ft with 3200.0 psi Tested Casing - Via string Serviced Block line Pulled out of hole to 13400.0 ft Held safety meeting Pumped out of hole to 0.0 ft Held safety meeting Installed Gun assembly Rigged up sub-surface equipment - Retrievable packer Ran Drillpipe in stands to 5800.0 ft Held safety meeting Progress Report Facility End MPI Well 2-56/EI-01 Page 22 Rig Date 25 June 98 Date/Time 26 May 98 27 May 98 06:30-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-14:00 14:00-14:15 14:15-14:30 14:30-15:00 15:00-15:30 15:30-16:00 16:00-16:30 16:30-16:45 16:45-18:00 18:00-18:30 18:30-19:00 19:00-19:15 19:15-19:30 19:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-09:00 09:00-09:30 09:30-10:00 10:00-10:15 10:15-10:30 10:30-11:30 11:30-18:00 18:00-18:30 18:30-03:00 03:00-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-11:30 11:30-13:00 13:00-16:00 16:00-18:00 18:00-18:30 18:30-19:30 19:30-21:30 21:30-22:30 22:30-23:30 23:30-01:00 Duration 5-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1-1/4 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 9 hr lhr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1 hr 6-1/2 hr 1/2 hr 8-1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr 1 hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 3 hr 2 hr 1/2 hr 1 hr 2 hr 1 hr 1 hr 1-1/2 hr Activity Ran Drillpipe in stands to 16611.0 ft Rigged up Drillfloor / Derrick Ran Drillpipe in stands to 15480.0 ft Set packer at 15480.0 ft with 0.0 psi Held safety meeting Rigged up High pressure lines Tested High pressure lines Perforated from 17714.0 ft to 17904.0 ft Monitor wellbore pressures Bullhead well Reverse circulated at 15480.0 ft Flow check Circulated at 15480.0 ft Held safety meeting Pulled Drillpipe in stands to 14530.0 ft Flow check Circulated at 14530.0 ft Laid down 12075.0 ft of 3-1/2in OD drill pipe Rigged down sub-surface equipment - Retrievable packer Rigged up Drillstring handling equipment Held safety meeting Rigged down sub-surface equipment - Gun assembly Rigged down Handling equipment Removed Wear bushing Rigged up Tubing handling equipment Held safety meeting Installed Permanent packer Ran Tubing to 6764.0 ft (4-1/2in OD) Held safety meeting Ran Tubing to 13589.0 ft (4-1/2in OD) Installed SCSSSV nipple assembly Tested Dual control line Ran Tubing to 15139.0 ft (4-1/2in OD) Held safety meeting Installed Tubing hanger Reverse circulated at 15175.0 ft Set packer at 15119.0 ft with 4000.0 psi Installed Hanger plug Removed BOP stack Installed Xmas tree Held safety meeting Removed Hanger plug Freeze protect well - 17.000 bbl of Diesel Installed Hanger plug Serviced Fluid system Skid rig Endicott Alaska State Plane Zone 3 Endicott MPI 2-56~Eider #~ As-Built- 2-56A/EIO~ i% 'RECEIVED JUN 2.6 1998 BPXA PDC CONFIDENTIAL S UR VEY REPORT ORIGINAL 23 June, 1998 Your Ref: AP1-500292286301 Last day of survey 17-May-98 Job# AKMM80134 KBE - 54. 70' ORII--LINI3 SERVICES Survey Ref: svy430 Endicott Measured Depth (ft) 15861.93 15958.46 15996.27 16029.36 16061.66 16092.98 16125.95 16157.06 16186.97 16221.24 16252.56 16282.46 16316.93 16348.25 16378.09 16412.44 16446.88 16474.18 16507.44 16539.36 16569.20 16604.98 16637.01 16666.08 16734.26 16764.93 16860.64 16956.52 17051.22 17146.99 Incl. 45.190 38.840 43.070 46.660 46.680 47.450 48.400 47.670 48.220 48.530 49.350 50.550 51.990 53.320 53.920 55.280 55.980 57.600 60.470 62.350 65.400 67.300 68.430 68.220 67.640 67.280 67.630 68.190 68.250 67.670 290.290 291.040 291.040 291.040 289.800 288.620 287.390 286.240 285.150 284.900 282.980 278.770 272.960 269.820 266.600 264.470 266.070 266.950 265.720 266.000 264.670 263.560 259.840 257.590 256.210 256.500 256.100 257.100 257.080 257.600 Sub-Sea Depth (ft) 8897.93 8969.62 8998.17 9021.61 9043.78 9065.11 9087.21 9108.01 9128.05 9150.81 9171.38 9190.63 9212.20 9231.21 9248.91 9268.81 9288.25 9303.20 9320.31 9335.59 9348.73 9363.08 9375.15 9385.89 9411.51 9423.26 9459.96 9496.02 9531.16 9567.09 Vertical Depth (ft) 8953.43 9025.12 9053.67 9077.11 9099.28 9120.61 9142.71 9163.51 9183.55 9206.31 9226.88 9246.13 9267.70 9286.71 9304.41 9324.31 9343.75 9358.70 9375.81 9391.09 9404.23 9418.58 9430.65 9441.39 9467.01 9478.76 9515.46 9551.52 9586.66 9622.59 Sperry-Sun Drilling Services Survey Report for 2-56~Eider #1 As-Built- 2-56A/ElO1 Your Ref: API-500292286301 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 4478.76 N 11510.71W 5987180.96 N 247508.84 E 12329.52 4501.52 N 11571.14W 5987205.66 N 247449.17 E 6.599 12394.02 4510.42 N 11594.26W 5987215.29 N 247426.34E 11.188 12418.76 4518.80 N 11616.04W 5987224.37 N 247404.84E 10.849 12442.06 4526.99 N 11638.06W 5987233.27 N 247383.10 E 2.793 12465.53 4534.54 N 11659.72W 5987241.51 N 247361.70 E 3.695 12488.46 4542.10 N 11682.99W 5987249.81N 247338.68 E 3.996 12512.93 4548.79 N 11705.13W 5987257.22 N 247316.76 E 3.614 12536.05 4554.80 N 11726.51W 5987263.91 N 247295.59 E 3.271 12558.25 4561.44 N 11751.25W 5987271.34 N 247271.07 E 1.056 12583.83 4567.12 N 11774.17W 5987277.76 N 247248.35 E 5.312 12607.39 4571.43 N 11796.64W 5987282.79 N 247226.03 E 11.500 12630.10 4574.17 N 11823.37W 5987286,38 N 247199.40 E 13.793 12656.38 4574.76 N 11848.25W 5987287.78 N 247174.55 E 9.030 12680.25 4574.01 N 11872.26W 5987287.80 N 247150.53 E 8.917 12702.87 4571.83 N 11900.17W 5987286.52 N 247122.56 E 6.420 12728.77 4569.48 N 11928.50W 5987285.09 N 247094.17 E 4.340 12755.01 4568.10 N 11951.30W 5987284.43 N 247071.34 E 6.518 12776.29 4566.27 N 11979.76W 5987283.52 N 247042.84 E 9.193 12802,81 4564.24 N 12007.71W 5987282,40 N 247014.84E 5.940 12828.80 4562.06 N 12034.41W 5987281,08 N 246988.09 E 10.976 12853.54 4558.70 N 12067.01W 5987278.77 N 246955.39 E 6.022 12883.54 4554.41 N 12096.36W 5987275.43 N 246925.92 E 11.322 12910.16 4549.13 N 12122.85W 5987271.00 N 246899.27 E 7.229 12933.76 4534.81 N 12184.39W 5987258.67 N 246837.31 E 2.060 12987.94 4528.13 N 12211.92W 5987252.87 N 246809.58 E 1.463 13012.10 4507.19 N 12297.80W 5987234.71 N 246723.07 E 0.532 13087,42 4486.60 N 12384.22W 5987216.92 N 246636.03 E 1.129 13163.37 4466.96 N 12469.94W 5987200.04N 246549.72 E 0.066 13238.93 4447.50 N 12556.55W 5987183.38 N 246462.53 E 0.787 13315.41 Comment Tie-on Survey Window Point Alaska State Plane Zone 3 Endicott MPI Continued... 23 June, 1998 - 7:56 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 2-56~Eider #1 As-Built - 2-56A/EIO1 Your Ref: API-500292286301 Endicott Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 17242.70 65.950 258.760 9604.78 9660.28 17337.97 65.790 258.810 9643.73 9699.23 17428.54 65.640 259.260 9680.98 9736.48 17476.51 65.030 258.840 9701.00 9756.50 17528.97 64.570 259.320 9723.33 9778.83 17579.29 63.740 257.980 9745.27 9800.77 17662.10 63.130 255.610 9782.31 9837.81 17714.31 62.660 255.540 9806.10 9861.60 17811.93 59.080 255.070 9853.61 9909.11 17867.10 57.300 253.370 9882.69 9938.19 17907.67 55.870 252.540 9905.03 9960.53 17931.08 54.480 252.820 9918.40 9973.90 17988.00 54.480 252.820 9951.47 10006.97 4429.48 N 12642.65W 5987168.13 N 246375.89 E 2.114 13391.84 4412.56 N 12727.94W 5987153.98 N 246290.10 E 0.175 13467.83 4396.86 N 12808.98W 5987140,89 N 246208.59 E 0.482 13540.16 4388.58 N 12851.78W 5987133.99 N 246165.55 E 1.500 13578.36 4379.59 N 12898.39VV 5987126.50 N 246118.68 E 1.206 13619.97 4370.68 N 12942.79W 5987119.03 N 246074.01 E 2.909 13659.50 4353.76 N 13014.89W 5987104.44 N 246001.40 E 2.664 13722.94 4342.19 N 13059.90W 5987094.32 N 245956,04 E 0.908 13762.23 4320.56 N 13142.38W 5987075.36 N 245872.92 E 3,691 13834.11 4307.82 N 13187.49W 5987064.08 N 245827.42 E 4.155 13873.14 4297.90 N 13219.87W 5987055.20 N 245794.74 E 3.917 13900.91 4292.18 N 13238.21W 5987050.07 N 245776.22 E 6.018 13916.62 4278.49 N 13282.47W 5987037.82 N 245731.54 E 0.000 13954.55 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 287.855° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 17988.00ft., The Bottom Hole Displacement is 13954.55ft., in the Direction of 287.855° (True). Comment Projected Survey Alaska State Plane Zone 3 Endicott MPI Con~nued... 23 June, 1998 - 7:56 - 3 - DrillQuest Endicott Sperry-Sun Drilling Services Survey Report for 2-56~Eider #1 As-Built- 2-56A/EIO1 Your Ref: API-500292286301 Alaska State Plane Zone 3 Endicott MPI Comments Measured Depth (ft) 15861.93 15958.46 17988.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8953.43 4478.76 N 11510.71 W 9025.12 4501.52 N 11571.14 W 10006.97 4278.49 N 13282.47 W Comment Tie-on Survey Window Point Projected Survey 23 June, 1998.7:57 - 4 - DrillQuest .ORIGINAL Endicott Alaska SEtnad~ecoP~a~;'lZ°ne'3 CONFIDENTIAL 2-56~Eider #~ As-Built- 2-56A/PB~ S UR VEY REPORT RECEIVED JUN 2 6 1998 BPXA PDC 23 June, 1998 Your Ref: AP1-500292286370 Last Survey 5-April-98 Job Number AKMMSO134 KBE - 54.7' spemm~-sun DRILLING c; E RV I C: E c:; Survey Reft svy399 Endicott Measured Depth (ft) Incl, Azim, Sub-Sea Depth (ft) Vertical Depth (ft) 16390.78 25.670 294.460 9338.43 9393.93 ' 16456.00 25.040 294.967 9397.37 9452.87 16475.17 28.190 290.360 9414.51 9470.01 16508.42 33.190 284.230 9443.10 9498.60 16539.39 38.840 279.960 9468.14 9523.64 16571.38 45.210 276.470 9491.90 9547.40 16603.68 50.140 273.610 9513.64 9569.14 16634.57 54.020 267.490 9532.63 9588.13 16665.24 59.940 264.450 9549.34 9604.84 16699.29 67.720 260.160 9564.35 9619.85 16730.74 74.290 255.160 9574.59 9630.09 16758.68 80.390 252.630 9580.71 9636.21 16795.24 83.680 246.530 9585.78 9641.28 16824.63 89.410 246.690 9587.55 9643.05 16856.86 88.860 248.240 9588.04 9643.54 16890.07 88.060 246.510 9588.93 9644.43 16918.28 87.160 246.820 9590.11 9645.61 16952.89 86.300 244.580 9592.08 9647.58 16986.56 84.720 243.160 9594.72 9650.22 17018.17 64.380 242.190 9597.72 9653.22 17046.28 82.880 242.760 9600.64 9656.34 17081.41 80.880 241.150 9605.80 9661.30 17113.73 80.870 241.400 9610.93 9666.43 17144.78 81,450 243.110 9615.70 9671.20 17177.58 80.820 243.810 9620.75 9676.25 17208.64 80.700 242.860 9625.74 9681.24 17245.94 80.340 242.690 9631.88 9687.38 17278.64 80.310 241.000 9637,41 9692.91 17309.29 80.240 242.800 9642.56 9698.06 17340.39 79.860 241.490 9647.93 9703.43 Sperry-Sun Drilling Services Survey Report for 2-56~Eider #1 As-Built - 2-56A/PBl Your Ref: API-500292286370 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 4586.18 N 11778.14W 5987296.94 N 247245.00 E 12595.72 4597.86 N 11803.51W 5987309.42 N 247220.02 E 1.022 12623.36 4601.15 N 11811.44W 5987312.97 N 247212.20 E 19.634 12631.90 4606.12 N 11827.63W 5987318.46 N 247196.17 E 17.722 12648.84 4609.89 N 11845.43W 5987322.80 N 247178.50 E 19.954 12666.98 4612.91 N 11866.62W 5987326.49 N 247157.42 E 21.203 12688.15 4614.98 N 11890.39W 5987329.33 N 247133.73 E 16.605 12711.53 4615.18 N 11914.74W 5987330.31 N 247109.40 E 20.042 12734.93 4613.35 N 11940.37W 5987329.31 N 247083.72 E 21.012 12758.99 4609.22 N 11970.62W 5987326.16 N 247053.36 E 25.488 12786.82 4602.85 N 11999.64W 5987320.72 N 247024.15 E 25.729 12812.83 4595.28 N 12025.81W 5987314.01 N 246997.75 E 23.551 12835.78 4582.65 N 12059.72W 5987302.47 N 246963.45 E 18.813 12864.70 4571.01 N 12086.63W 5987291.70 N 246936.17 E 19.503 12887.20 4558.66 N 12116.40W 5987280.32 N 246906.03 E 5.103 12912.23 4545.89 N 12147.04W 5987268.54 N 246874.99 E 5.737 12937.98 4534.73 N 12172.92W 5987258.21 N 246848.77 E 3.374 12959.62 4520.51 N 12204.41W 5987245.02 N 246816.83 E 6.922 12985.78 4505.73 N 12234.54W 5987231.21 N 246786.24 E 6.301 13010.47 4491.28 N 12262.50W 5987217.67 N 246757.83 E 3.239 13033.17 4478.37 N 12287.27W 5987205.57 N 246732.66 E 5.704 13053.25 4462.02 N 12317.96W 5987190.22 N 246701.46 E ' 7.280 13078.04 4446.69 N 12345.95W 5987175.79 N 246672.99 E 0.764 13100.51 4432.40 N 12373.10W 5987162.39 N 246645.39 E 5.754 13122.49 4417.92 N 12402.09W 5987148.85 N 246615.95 E 2.852 13146.17 4404.16 N 12429.49W 5987135.98 N 246588.12 E 3.043 13168.53 4387.33 N 12462.21W 5987120.21 N 246554.89 E 1.065 13195.12 4372.03 N 12490.80W 5987105.83 N 246525.81 E 5.065 13218.19 4357.90 N 12517.27W 5987092.56 N 246498.90 E 5.831 13239.55 4343.58 N 12544.36W 5987079.12 N 246471.37 E 4.325 13261.46 Comment Tie-on Survey Window point (cement Plug) Alaska State Plane Zone 3 Endicott MPI Continued... 23 June, 1998 - 6:34 - 2 - DrillQuest Endicott Measured Depth (ft) 17373.22 17402.12 17436.24 17469.30 17501.30 17529.95 17564.72 17597.71 17626.10 17661.06 17692.57 17731.55 17764.29 17798.62 17827.42 17858.93 17892.78 17922.12 17954.65 17971.50 18002.32 18030.80 18066.46 18100.14 18128.63 18163.59 18193.56 18223.90 18276.43 18340.00 Incl. 78.600 76.570, 74.680 73.690 74.140 75,290 75.860 74.930 74.42O 74.230 74.320 74.08O 73.080 71,600 68,720 67.210 65.510 64.860 66.110 66.77O 67.450 66.560 64.150 62.160 61.620 60.190 59.400 58.780 55.200 55.200 Azim. 243.210 242.210 242.860 242.710 242.790 243.170 243.310 242.630 243.550 243.880 244.750 245.860 246.680 244.080 244.620 246.300 247.170 247.280 247.160 247.830 247.800 249.040 250.010 248.82O 249.260 248.500 247.400 246,750 248.660 248.66O Sub-Sea Depth (ft) 9654.07 9660.28 9668.75 9677.76 9686.63 9694.18 9702.84 9711.16 9718.66 9728.11 9736.65 9747.26 9756.51 9766.93 9776.70 9788.53 9802.10 9814.41 9827.91 9834.65 9846.63 9857.76 9872.63 9887.84 9901.26 9918.26 9933.34 9948.92 9977.54 10013.82 Vertical Depth (ft) 9709.57 9715.78 9724.25 9733.26 9742.13 9749.68 9758.34 9766.66 9774.16 9783.61 9792.15 9802.76 9812.01 9822.43 9832.20 9844.03 9857.60 9869.91 9883.41 9890.15 9902.13 9913.26 9928.13 9943.34 9956.76 9973.76 9988.84 10004.42 10033.04 10069.32 Sperry-Sun Drilling Services Survey Report for 2-56~Eider #I As. Built - 2-56A/PBI Your Ref: API-500292286370 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section . (ft) (ft) (ft). (ft) (°/t00ft) (ft) 4328.62 N 12572.92W 5987065.08 N 246442.34E 6.420 13284.59 4315.68 N 12598.00W 5987052.96 N 246416.85 E 7.795 13304.97 4300.43 N 12627.33W 5987038.67 N 246387.05 E 5.838 13328.75 4285.89 N 12655.61W 5987025.04N 246358.31 E 3.026 13351.74 4271.81 N 12682.95W 5987011.85 N 246330.54 E 1.427 13373.95 4259.25 N 12707.57W 5987000.09 N 246305.53 E 4.213 13393.99 4244.09 N 12737.64W 5986985.90 N 246274.99 E 1.685 13418.51 4229.58 N 12766.07W 5986972.32 N 246246.10 E 3.453 13441.66 4217.19 N 12790.49W 5986960.72 N 246221.30 E 3.605 13461.54 4202.29 N 12820.67W 5986946.79 N 246190.65 E 1.059 13486.25 4189.14 N 12848.00W 5986934.53 N 246162.91 E 2.673 13508.72 4173.47 N 12882.08W 5986919.97 N 246128.35 E 2.808 13536.94 4160.83 N 12910.82W 5986908.26 N 246099.21 E 3.886 13560.91 4147.21 N 12940.56W 5986895.60 N 246069.05 E 8.406 13585.55 4135.48 N 12964.98W 5986884.67 N 246044.27 E 10.154 13605.64 4123.35 N 12991.55W 5986873.40 N 246017.32 E 6.884 13627.66 4111.10 N 13020.03W 5986862.07 N 245988.46 E 5.546 13651.49 4100.79 N 13044.59W 5986852.56 N 245963.59 E 2.242 13672.11 4089.33 N 13071.87W 5986841.98 N 245935.94 E 3.857 13695.02 4083.42 N 13086.14W 5986836.53 N 245921.49 E 5.350 13707.02 4072.70 N 13112.43W 5986826.66 N 245894.87 E 2.208 13729.18 4063.06 N 13136.81W 5986817.81 N 245870.19 E , 5.082 13749.82 4051.72 N 13167.17W 5986807.45 N 245839.48 E 7.196 13775.70 4041.16 N 13195.30W 5986797.80N 245811.03 E 6.697 13799.68 4032.17 N 13218.77W 5986789.57 N 245787.28 E 2.334 13819.62 4021.16 N 13247.27W 5986779.49 N 245758.45 E 4.510 13843.82 4011.44N 13271.27W 5986770.54N 245734.14 E 4.124 13864.07 4001.30 N 13295.25W 5986761.18 N 245709.85 E 2.749 13884.18 3984.58 N 13335.99W 5986745.78 N 245668.59 E 7.466 13918.49 3965.58 N 13384.61W 5986728.36 N 245619.39 E 0.000 13959.71 Comment Projected Survey Alaska State Plane Zone 3 Endicott MPI Continued... DrillQuest 23 June, 1998- 6:34 -3- Endicott Sperry-Sun Drilling Services Survey Report for 2-56~Eider #1 As-Built - 2-56A/PB1 Your Ref: API-500292286370 Alaska State Plane Zone 3 Endicott MPI All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. ~ertical Section is from Well and calculated along an Azimuth of 286.503° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 18340.00ft., The Bottom Hole Displacement is 13959.71ft., in the Direction of 286.503° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 16390.78 9393.93 4586.18 N 11778.14 W Tie-on Survey 16456.00 9452.87 4597.86 N 11803.51 W Window point (cement Plug) 18340.00 10069.32 3965.58 N 13384.61 W Projected Survey 23 June, 1998.6:34 - 4 - DrillQuest Endicott Alaska State Plane Zone 3 Endicott MPI 2-56~Eider #~ As-Built- 2-56A/PB2 SURVEY REPORT 23 June, 1998 Your Reft API-500292286371 Last day of Survey 29-April-98 Job # AKMM80134 KBE - 54.70' DRICLING SERVICES RECEIVED BPXA PDC ORIGINAL T/AL Survey Reft svy428 Endicott Measured Depth (ft) 15861.93 15958.00 16009.52 16044.83 16076.32 16104.96 16140.22 16171.29 16203.04 16235.67 16267.48 16303.30 16338.53 16369.39 16400.29 16431.63 16463.75 16494.03 16528.52 16560.04 16588,42 16613.89 16655.68 16686.97 16714.76 16750.83 16780.18 16812.42 16848.79 16879.69 Incl. 45.190 38.870 36.160 35.490 34.940 36.040 37.030 37.770 36.860 36.520 35.460 35.170 36.000 35.700 38.190 41.280 44.450 47.770 51.520 55.190 58.030 61.040 62.210 63.330 64.500 63.680 64.560 62.230 59.780 58.120 290.290 291.030 289.390 288.240 287.200 286.240 285.040 283.970 282.870 281.730 279.150 272.910 268.870 262.720 261.570 256.810 254.380 252.380 250.190 243.790 237.190 233.970 228.430 224.350 219.570 213.890 210.210 205.380 203.180 201.470 Sub-Sea Depth (ft) 8897.93 8969.26 9010.12 9038.75 9064.48 9O87.80 9116.13 9140.81 9166.06 9192.23 9217.97 9247.21 9275.86 9300.88 9325.58 9349.68 9373.22 9394.21 9416.54 9435.36 9450.99 9463.91 9483.78 9498.10 9510.33 9526.10 9538.91 9553.36 9570.99 9586.92 Vertical Depth (ft) 8953.43 9024.76 9065.62 9094.25 9119.98 9143.30 9171.63 9196.31 9221.56 9247.73 9273.47 9302.71 9331.36 9356.38 9381.08 9405.18 9428.72 9449.71 9472.04 9490.86 9506.49 9519.41 9539.28 9553.60 9565.83 9581.60 9594.41 9608.86 9626.49 9642.42 Sperry-Sun Drilling Services Survey Report for 2-56~Eider #1 As-Built - 2-56A/PB2 Your Ref: API-500292286371 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 4478.76 N 4501.41 N 4512.26 N 4518.93 N 4524.46 N 4529.24 N 4534.90 N 4539.62 N 4544.09 N 4548.24 N 4551.63 N 4553.81N 4554.12 N 4552.80 N 4550.26 N 4546.48 N 4541.03 N 4534.78 N 4526.34N 4516.43 N 4504.75 N 4492.34N 4469.30 N 4450.11N 4431.56 N 4405.57 N 4383.20 N 4357.71N 4328.73 N 4304.24 N 11510.71W 5987180.96 N 247508.84 E 12303.60 11570.87W 5987205.54N 247449.43 E 6.599 12367.70 11600.30W 5987217.33 N 247420.37 E 5.606 12398.99 11619.86W 5987224.63 N 247401.03 E 2.690 12419.64 11637.16W 5987230.71 N 247383.92 E 2.584 12437.79 11653.08W 5987236.00 N 247368.16 E 4.306 12454.41 11673.29W 5987242.30 N 247348.14 E 3.462 12475.40 11691.56W 5987247.61N 247330.03 E 3.170 12494.26 11710.28W 5987252.68 N 247311.46 E 3.553 12513.49 11729.33W 5987257.45 N 247292.56 E 2.333 12532.94 11747.71W 5987261.43 N 247274.30 E 5.815 12551.53 11768.28W 5987264.27 N 247253.81 E 10.099 12571.89 11788.77W 5987265.24 N 247233.34 E 7.075 12591.65 11806.77W 5987264.50 N 247215.31E 11.708 12608.57 11825.17W 5987262.55 N 247196.84 E 8.363 12625.52 11844.83W 5987259.40 N 247177.07 E 13.831 12643.34 11865.98W 5987254.64 N 247155.75 E 11.129 12662.13 11886.88W 5987249.06 N 247134.66 E 11.952 12680.45 11911.76W 5987241.42 N 247109.52 E 11.900 12701.99 11935.00W 5987232.27 N 247085.97 E 20.016 12721.53 11955.59W 5987221.26 N 247065.01 E 21.837 12738.04 11973.69W 5987209.43 N 247046.52 E 16.072 12751.95 12002.32W 5987187.33 N 247017.17 E 11.994 12773.01 12022.46W 5987168.80 N 246996.42 E 12.133 12786.98 12039.14W 5987150.79 N 246979.16 E 16.011 12797.81 12058.53W 5987125.45 N 246958.94 E 14.344 12809.18 12072.54W 5987103.53 N 246944.22 E 11.672 12816.38 12085.99W 5987078.50 N 246929.96 E 15.218 12822.17 12099.07W 5987049.94 N 246915.95 E 8.565 12826.63 12109.13W 5987025.79 N 246905.10 E 7.165 12829.45 Comment Tie-on SurveY Window Point Alaska State Plane Zone 3 Endicott MPI Continued,.. 23 June, 1998 - 7:01 - 2 - DriilQuest Endicott Measured Depth (ft) 16908.47 16942.48 16974.41 17004.24 17036.47 17068.79 17099.83 17121.70 17139.94 17170.81 17199.30 17232.40 17265.08 17295.36 17328.69 17360.39 17391.23 17424.38 17455.91 17484.82 17520.00 17551.21 17580.57 17615.19 17647.24 17675,85 17714,34 17775,00 Incl. 57.480 56.690 56.010 56.380 57.280 58.400 58.87O 59.300 60.19o 60.600 61.780 61.770 62.120 62.510 61.890 61.530 63.250 66.080 66.600 66.280 65.850 65.340 65.200 64.620 64.350 64.180 63.610 63.610 Azim. 200,880 202,310 203.920 204,040 205.960 209.990 211.720 211.260 210.670 210,790 210.250 210.460 213.000 213,140 213,720 213,670 214.920 216.340 218.800 219.960 219.830 220.060 219,830 219,120 217.930 218.010 218.110 218,110 Sub-Sea Depth (ft) 9602.26 9620.74 9638.44 9655.03 9672.67 9689.87 9706.03 9717.27 9726.46 9741.71 9755.44 9771.09 9786.46 9800.53 9816.08 9831.10 9845.39 9859.58 9872.23 9883.79 9898.06 9910.96 9923.24 9937.92 9951.73 9964.15 9981,08 10008.05 Vertical Depth (ft) 9657.76 9676.24 9693.94 9710.53 9728.17 9745.37 9761.53 9772.77 9781.96 9797.21 9810.94 9826.59 9841.96 9856.03 9871.58 9886.60 9900.89 9915.08 9927.73 9939.29 9953.56 9966.46 9978.74 9993.42 10007.23 10019.65 10036.58 10063.55 Sperry-Sun Drilling Services Survey Report for 2.56~Eider #1 As-Built. 2-56A/PB2 Your Ref: API-500292286371 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 4281.53 N 12117.93W 5987003.38 N 246895.58 E 2,820 12831.55 4254.98 N 12128.43W 5986977.18 N 246884.23 E 4,225 12834.23 4230.54 N 12138.87W 5986953.09 N 246873.01E 4.707 12837.41 4207.89 N 12148.94W 5986930.78 N 246862.21E 1.285 12840.76 4183.44 N 12160.34W 5986906.71 N 246850.03 E 5,715 12844.88 4159.29 N 12173.18W 5986882.98 N 246836.43 E 11.110 12850.46 4136.54 N 12186.77W 5986860.68 N 246822.11 E 4.994 12857.15 4120.54 N 12196.57W 5986845.01 N 246811.80 E 2,669 12862.09 4107.03 N 12204.68W 5986831.76 N 246803.26 E 5.622 12866,10 4083.96 N 12218.39W 5986809.14 N 246788.81 E 1.370 12872.83 4062.45 N 12231.07W 5986788.06 N 246775.45 E 4.462 12878.99 4037.29 N 12245.81W 5986763.38 N 246759.91E 0,560 12886.11 4012.76 N 12260.97W 5986739.35 N 246743.96 E 6.942 12893.82 3990.29 N 12275.60W 5986717.37 N 246728.61E 1.352 12901.60 3965.69 N 12291.85W 5986693.30 N 246711.59 E 2.414 12910.32 3942.46 N 12307.33W 5986670.58 N 246695,36 E 1.144 12918.70 3919.89 N 12322.73W 5986648.52 N 246679.24 E 6,633 12927.18 3895.54 N 12340.19W 5986624.74 N 246661.01 E 9.374 12937.14 3872.66 N 12357.79W 5986602.44N 246642.68 E 7.334 12947.65 3852.17 N 12374.61W 5986582.50 N 246625.22 E 3.841 12958.07 3827.50 N 12395.23W 5986558.51N 246603.81 E 1.268 12970.98 3805.71 N 12413.48W 5986537.32 N 246584.87 E 1.766 12982.42 3785.27 N 12430.60W 5986517.44N 246567.10 E 0.857 12993.15 3761.07 N 12450.53W 5986493.89 N 246546.40 E 2.501 13005.52 3738.44N 12468,55W 5986471.85 N 246527.66 E 3.455 13016.50 3718.12 N 12484,41W 5986452.06 N 246511.16 E 0.645 13026.05 3690.91 N 12505.71W 5986425.54N 246488.99 E 1.499 13038.91 3648.15 N 12539.25W 5986383.89 N 246464.09 E 0.000 13059.17 Comment Projected Survey Alaska State Plane Zone 3 Endicott MPI Continued... 23 June, 1998 - 7:01 - 3 - DrillQuest Endicott Sperry-Sun Drilling Services Survey Report for 2-56/Eider #1 As-Built- 2-56A/PB2 Your Ref: API-500292286371 Alaska State Plane Zone 3 Endicott MPI All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. 'i, The Dogleg Severity is in Degrees per 100ft. ' Vertical Section is from Well and calculated along an Azimuth of 286.222° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 17775.00ft., The Bottom Hole Displacement is 13059.17ft., in the Direction of 286.222° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 15861.93 8953.43 4478.76 N 11510.71 W Tie-on Survey 15958.00 9024.76 4501.41 N 11570.87 W Window Point 17775.00 10063.55 3648.15 N 12539.25 W Projected Survey 23 June, 1998 - 7:01 - 4 - DrillQuest 2-56A/El-01 Sidetrack SUMMARY PROCEDURE COMMENTS 1. This well will be sidetracked at app. 16,000 feet. ABON. DAMENT OPERATIONS 1. 2. 3. , S IDETR&.CI¢ OPERATIONS (SUMMARY) Run open ended drillpipe to 16,219'. Establish bullhead rate down 3.5" drillpipe and into the open hole. Pump 2§ bbl of class G cement and circulate down the drillpipe, Displace all cement through the OEDP to place TOC at 15,858' MD, Squeeze cement into openhole at up to 1E,00 psi MAX. POOH to above 15,858 and circulate the 3.5" dfillpipe with drilling fluid to remove any cement. . . , , Pick up 6' bit and Sperry 4.75" directional BHA to turn and build as specified by the rig supervisor to CP at 18,104. POOH. (10 days) Run a 4.5" solid liner from 15,800 to 18,104' MD, (2 days), Make a clean out trip with bit and scraper and displace with KW Bdne. Perforate with DPC perfs based on LWD logs. RIH w/7" x 4-1/2" packer, 4-112" L-80 tubing, and 6 GLM to expected setting depth at 15,250 MD. Drift packer, tubing and all iewlery before running. (1 day) Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day) Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). Turn the well over to Production, The above procedure was discussed with B. Wondzell at the AOGCC on 01 and 02 May 1998. Reference AOGCC drilling permit # 98-58 Dated 3/20198. The odginal well was sidetracked for Geological reasons. The first sidetrack was drilled to 18,340' MD and then abandoned after a liner failed and could not be fished from the well. The second sidetrack was drilled to 17,775, and encountered hole instability at 16,500 and was sidetracked during a clean-out attempt_ All three sidetracks will be in dose proximity of each other and will not be re-permitted. The completion 10-403 will be filed when the well is finished 0 5 1998 2-56a/El-01 Sidetrack Drilling Program Directional Plan #16 Nothing is more important than Safety 5/5/98 Page 2 BP EXPLORATION Date: 06-30-98 Trans# 89262 BP/ENDICO'I-F CASED HOLE LOGS BP/ENDICOTT OPEN HOLE LOGS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4166. Ot~.~____~ Sw Name Log Type Rec Type Rec Date Comments 2-56A/PB2' MWD DISK 29-Apr-98 MWD MPT GR EWR4 CNP SLD GR ROP Please sign and return one copy of this transmittal. Thank-you, N adene Reichert -~~:~~N Petrotechnical Data Center OH/CH LOGS MAGTAPES STATE REPORTS AL AOGCC AOGCC Madellyn Millholland MB7-1 Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 BP EXPLORATION 8P Exploration (Alaska} Inr~ ~00 EaSt Benson Boulevard PO, BOX 1965-12 Anchorage, Alaska 99519-6612 (gO'/) S61-.~111 TO: TELECOPY Name: ~ ~--~,z~ Company: '~O 6cC. Location: ~t¥,c~-~ 6~- Fax Number: Z. 9 c., FROM: Name: ~_,kr-, ~ Department: Location: Fax Number: ~,.¥ o s 1998 PAGES TO FOLLO .W) ~~ 2-56A/E 1-01 Sidetrack SUMMARY PROCEDURE COMMENT_S_ 1, This well will be sidetracked at app. 16,000 feet. ABO N DAM EN_T__O.~ E RAT IONS 1, 2. 3, , SIDETRACK OPERATIONS~SUMMARY) Run an EZSV cement retainer to set at 16,000' MD Establish bullhead rate down 3.5" drillpipe and into the open hole. Pump 25 bbl of class G cement and circulate down the drillpipe. Displace ali cement through the EZSV at 16,000' MD. Squeeze cement into openhole at up to 1500 psi MAX. Unsting from retainer and circulate the 3.5" drillpipe with drilling fluid to remove any cement. P/U 7" whipstock and milling BHA and TIH to cut window from 15,990 - 16,000 MD, (2 days) POOH w/mills. (1/2 day) Pick up 6" bit and Sperry 4.75" directional BHA to turn and build as specified by the rig supen/isor to CP at 17,799'. POOH. (12days) Run a 4.5" solid liner from 15,800 to 17,799' MD. (2 days). Make a clean out tdp with bit and scraper and displace with KW Brine. RIH w/7" x 4-1/2" packer, 4-1/2" L-80 tubing, and 6 GLM to expected setting depth at 15,250 MD. Drift packer, tubing and all jewlery before running. (1 day) Pump Corrosion inhibitor. Set the 7" packer. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. (1/2 day} Set the BPV. ND the BOPE, and NU the tree. Shear the RP valve and freeze protect the well. (1/2 day). Turn the well over to Production. The above procedure was discussed with B, Wondzell at the AOGCC on 15 April 1998, Reference AOGCC drilling permit Cf 98-58 Dated 3/20/98 P F~v c; 8 - BP EXPLORATIOH BP Exploralion (Alas~} thC,. 500 E;~t Eenson Boulovara PO. Box 196612 Anchorage, Alask~ ¢J951916612 (907) 561-511t TO: TELECOPY Name: Il/lA_ Company: ~ Location: /~c.~. Fax Number: FROM: Name: Department:. Location: Fax Number: PAGES TO FOLLOW) -r^r,F'~ '~'~Ct~ <.- kTFtTT~ITt"I'A'~";'4' AC; ~'RT~; ~QO I. flR '¥-t/'.4' ~O:~T MEMORANDUM State of Alaska TO: THRU: Blair Wondzell, P. !. Supervisor Alaska Oil and Gas Conservation Commission DATE: March 25, 1998 FILE NO: akhklaee, doc FROM: Chuck Scheve, ¢_ $ SUBJECT: Petroleum Inspector BOPE Test Doyon 15 DIU 2-56NEider-01 PTD # 98-58 Wednesday March 25, 1998: I traveled to BPX's DIU 2-56NEider-01 Well being drilled by Doyon Rig 15 and witnessed the weekly BOPE test. As the attached AOGCC BOPE test report shows the test lasted 3.5 hours with two failures. The full opening floor valve failed to pressure test and the indicator light for the choke HCR valve was giving a false indication in the open position. These two items were repaired and tested by the toolpusher after I departed location. The test went well with good test procedures being employed by the Doyon crews. The rig was clean and all related equipment appeared to be in good working order. Summary: I witnessed the weekly BOPE on Doyon Rig 15 drilling BPXs DIU 2-56NEider-01 Well. Doyon 15, 3125198, Test Time 3.5 hours, 2 failures Attachment: akhkcyfe.xls X Unclassified Confidential (Unclassified if doc. removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Doyon Rig No. 15 PTD # BPX - Rep.: 2-56NEider-01 Rig Rep.: 7" Set @ 16,450 Location: Sec. Weekly X Other DATE: 3/25/98 g8-58 Rig Ph.# 659-6510 James Carlile John Welsh 36 T. 12N R. 16E Meddian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location 'Yes Standing Order Posted Yes Well Sign OK Drl. Rig OK Hazard Sec. OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Press. P/F 25O3OOO P 250/5,000 P F 250/5,000 250/5,000 I 250/5,000 P 2 250/5,000 P f 250/5,000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator ,d p Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/5,000 P 1 250/5,000 P I 250/5,000 F/P 250/5,000 CHOKE MANIFOLD: No. Valves 18 No. Flanges 36 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 250/5,000 P 250/5,000 Functioned Func~oned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure_, 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4(~ 2700 3000 !' 1800 minutes 30 sec. minutes 15 sec. OK Remote: OK Psig. ' Nmnbe'r of Failu're~: ~ ,Test Time: 3.5 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Li~lht on Choke HCR contol ~liv~n~l false indica~fon in open position. Full openin..g floor valve failed to test. Distribution: orig-Well File c - Oper./Rig c - Database c - Tdp Rpt File c -Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W'rtnessed By: akhkcyfe Chuck Scheve TONY KNOWLE$, GOVEi~NOR ALASKA OIL AND GAS CONSERVATION COMMISSION *larch 20. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Steve Shultz Enginccring Supcn, isor BP Exploration (Alaska). Inc. POBox 196612 Anchoragc. AK 99519-6612 Rc' Duck Island Unit 2-56A/Eidcr-Ol BP Exploration (Alaska). Inc. Pcrmit No. 98-058 Sur. Loc. 3193' NSL. 2333' WEL. Scc. 36. TI2N. R16E. UM BtmholcLoc. 1863'NSL. 103'EWL. Scc27. T12N. RI6E. UM Dcar Mr. Shultz Encloscd is thc approvcd application fbr permit to rcdrili the abox'c rcfcrcnccd well. Thc pcrmit to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required pcrmitting dctcrminations arc madc. A xvccklv status rcport is required from thc time thc xvcll is spudded until it is suspended or plugged and abandoncd. Thc report should bca gcncralizcd synopsis of thc xvcck's activitics and is cxclusivclv for thc Commission's intcmal usc. Thc ncw bottom-holc location will rcquirc a spacing cxccption undcr 20 AAC 25.055. You arc not authorized to opcn thc xvcll to production until after thc commission issucs thc spacing cxccption folloxving noticc and opportunity for public hcaring. Should an adjaccnt oxvncr raisc an objcction, thc commission may rcquirc BP Exploration (Alaska). Inc. to plug and abandon thc well. Bloxvout prcvcntion equipment (BOPE) must be tcstcd in accordancc xx'ith 20 AAC 25.035. Sufficicnt notice (approximatcly 24 hours) of thc BOPE tcst pcrformcd bcforc drilling below thc surfacc casing shoc must bc givcn so that a rcprcscntativc of thc Commission may xxitncss thc test. Notice ~lWb-W'mv~n by r,..ontacting thc Commission pctrolcum ficld inspcctor on thc North Da~dW.~Johnston \ Chairman~x.~ BY ORDER OF THE COMMISSION d1171 cC' Dcpartmcnt of Fish &Gamc. Habitat Scction xv/o cncl. Dcpartmcnt of Environmcntal Conscn'ation xv/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Mu!tiple Zone ';2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska)Inc. Plan KBE = 56' Duck Island 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034634 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3193' NSL, 2333' WEL, SEC. 36, T12N, R16E, UM Duck Island At top of productive interval 8. Well Number Number 2S100302630-277 2151' NSL, 785' EWL, SC. 27, T12N, R16E, UM 2-56A/Eider-01 At total depth 9. Approximate spud date Amount $200,000.00 1863' NSL, 103' EWL, SEC. 27, T12N, R16E, UM 03/21/98 12. Distance to nearest property linet 13. Distance to nearest well 14. Number of acres in property 15. PropOsed depth (MD and TVD) "' ADL 312827, 3417'I No Close Approach 2560 18366' MD / 10085' TVD ...... 16. To be completed for deviated wells 17. Anticipated pressure {s'ee 2o AAC 25.035 (e) (2)} Kick Off Depth 16450' Maximum Hole Angle 88° Maximum surface 3713 psig, At total depth C-VD) 9675' / 4680 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 NSCT 2066' 16300' 9300' 18366' 10085' [2.15 sx Class 'G' .... i9."To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 17073 feet Plugs (measured) true vertical 10027 feet Effective depth: measured 17073 feet Junk (measured) true vertical 10027 feet Casing Length Size Cemented M D TVD Structural Conductor 80' 30" Driven 120' 120' Surface 7038' 9-5/8" 2008 sx PF 'E', 250 sx Class 'G' 7079' 4501' Intermediate 16411' 7" 200 sx Class 'G' 16450' 9448' Production Liner RECEIVED Perforationdepth:measured MAR 2 0 1998 true vertical ~l!l~ 0il & Gas Cons. Anchorage 20. Attachments C~' Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25,050 Requirements Contact Engineer Name/Number: Chris West, 564-5089 Prepared By Name/Nu~er: Kathy Campoamor, 564-5122 21' I hereby certify that the i~.~-in-~-g is t~ Ind c,~t t° the best °f mY kn°wledge Signed Steve Shu~t~ //~ ~.~..,.__~) ~/,x~ ~ Title Engineering Supervisor Date J ) - \ ...... ~./ ~omm~ss,on use umy Permit Numberd'~¢:' . <'"~,' IAPl Number 50-029-22863-01 1Appr°val Date/"2..O '~ Isee cover letter / ~ ~' O O'~ /~ for other requirements Conditions of Approval: Samples Required NYes ,.[]No Mud Log Required .~Yes [] No Hydrogen Sulfide Measures []Yes~No Directional Survey Required ,~[Yes BI No Required. C.~.WorkingP_.EressureforBOPE I--12M; •3M; ~[~5M; I-'I10M; []15M Other: [~'~o'~--~~.I ~,t~li~ , ,-,,~ by order of Approved By David W..¢0I,~011 Commissioner the commission Dateo.~ o.~ ~hmit In Trinlie. 2tp. Name: 12-56a/Eider-01 I Redrili Plan Summary IType of Redrill (producer or injector)' PRODUCER RECEIVED MAR 2 0 1998 Alaska 0ii & Gas Cons. Commission Anchorage Surface Location: 3193' FSL & 2333' FEL Sec. 36 T12N R16E 2151' FSL & 785' FWL Sec. 27 T12N R16E Target Location: Bottom Hole Location' 1863' FSL & 103' FWL Sec 27 T12N R16E [AFE Number: 17275oo IEstimated Start Date: 3/21/98 IMD' 118,366' I ITVD: IWell Design (conventional, slimhole, etc.): Rig: I DOYON RIG #15 IOperating days to complete: 10 0,085' IKBE 156 I IHIGHANGLE SIDETRACK I Objective: I IVISHAK ABNORMAL PRESSURE ISpecial design considerations J4680 psi @9675' TVD Mud Program: An 9.8 ppg mud will be used. I Special design NONE considerations Depth Density PV YP INT 10MIN FL OIL SOLID (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) S (%) KOP' 9.8 10 15 5 10 5 0 5 to to ' to to to to to to to 18366 10.2 18 30 15 30 7 0 10 2-56A/Eider-01 Sidetrack Plan Summary Page 1 Directional: I KOP: 116450' (Shoe of 7" casing) Maximum Hole Angle: 188° Close Approach Well:I NONE The above listed wells will be secured during the close approach. Casin.c/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbs O.D. MD/TVD MD/TVD 6" 4 1/2" 12.6 L-80 NSCT 2066' 16,300/9300 18366/10085 N/A 4 1/2" 12.6 L-80 NSCT 15000' 0/0 15000/8430 Cement Calculations: Liner Size: 14 1/2", 12.6#, L-80, NSCT I Basis' 50% open hole excess, 80' shoe joint, 150' liner lap (7"), and 200' excess above liner top. Total Cement Volume: 215 SX"G" 15.8 ppg Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards and Contingencies IMud weights should be kept to a minimum while drilling through the highangle section (_+9.8 PPg) to prevent differential sticking. With 9.8 ppg the hydrostatic is 4966 psi 2-56A/Eider-01 Sidetrack Plan Summary Page 2 SUMMARY PROCEDURE . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. RIH with open ended drill pipe to 17,073' Circulate and condition mud Pump 36 bbls of 17.0 ppg class "G" cement, reverse out, POOH RIH with cleanout assembly and cleanout cement to shoe at 16450', POOH RIH with directional assembly and LWD Directionally drill to new location (see attached) Install 4 1/2",12.6#,L-80,NSCT liner and cement in place. PU cleanout assembly and clean out 4 1/2" liner to landing collar. Test casing to 3500 psi, POOH RIH with drillpipe conveyed perforating assembly and perforate the well. POOH LDDP. Run the .4.-1/2", 12.6#, L-80, NSCT completion string assembly using as much 4-1/2" used tubing and jewelry as possible. Space out and circulate with corrosion inhibitor. Install a BPV and test plug. Remove BOP's. Install and test the production tree to 5000 psi. Pull tree test plug and BPV. Set packer. Test the tubing x casing annulus to 3500 psi for 30 minutes. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release rig. Complete appropriate documentation and hand-over to Production. 2-56A/Eider-01 Sidetrack Plan Summary Page 3 DrillQuest Endicott Alaska State Plane Zone 3 Endicott MP! 2-56/Elder #1 As-Built Scale: 1inch = 40Oft 3800 94o0 9800 - 30200 - ~.~t4 tt~JtF 42~.6~ ~. t2~~ ~ I I t I I 9200 9600 ~ 0000 10~0 ~ 0800 Scale: linch a ~ffi Vedical Secti~rio" ~muth: 2~,3S0' (Tree No~h) 03/19/1998 17:40 907S637252 SPERRY-SUN PAGE 83 Sperry-Sun Drilling Services Proposal Data - 2.56~Eider #1 As-Built - 2-56~Eider #1 ST Wp9 .... ~',.;,,, 16450.00 25,103 294.927 9447.~7 ~4597.64 N i1800~94 W ~ 9272.21 :i~-"'~,,,~;~ .......................................................................................................... ~ ....................................................................................... ..~,.:.~{.,~i~,17320. 97 442.50 88.312 244.190[ 969~.91i 13.034341.31 N-192.57 12518.55 ~-398.18', 0.000[ 0.000 10033.76. o~,': ~,,~,~I oo~,~o VENDOR ALASKAST 14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET HANDLIN~ INST' s/h kathy campoano~ x 5122 · W~ a~a~W~m ~W~ I~ IN PAYMF~ F~R i~M8 D~RIBED ABOVE. ~ffi~ ~ ~ -~ ~ ~ · WELL PERMIT CHECKLIST COMPANY ~~ PROGRAM: ex dev [] re serv [] wellbore seg !] ann. disposal para req GEOL AREA ~:: ~'<:~ UNIT# /~2 ~,_¢"_,,~ ' ON/OFF SHORE : ADMINISTRATION 3. 4. 5. 6. 7. 8. 9. 10. 11. :{ D,~'T E /2 12. ~,~,/~2' 13. REMARKS Permit fee attached ....................... ,,~ N Lease number appropriate ................... ~ N :~ Unique well name and number .................. - _.,_ ' -,. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ ,~,~ .~.]~.,, .... If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Y(~ Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE GEOLOGY 14. Conductor string provided ................... (~ N 15. Surface casing protects all known USDWs ........... (~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... {~.,,N. 17. CMT vol adequate to tie-in long string to surf csg ........ YrJ~ 18. CMT will cover all known productive horizons .......... (~) N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. (~ N i~ ~ '/ 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. (~N 23. If diverter required, does it meet regulations .......... ,-Y----N 24. Drilling fluid program schematic & equip list adequate ..... (~ N N 25. BOPEs, do they meet regulation .... ~ ......... / 26. BOPE press rating appropriate; test to ,~l~.~, psig. ~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. Y DATE 30. Permit can be issued w/o hydrogen sulfide measures. 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. ~3. Seabed condition su~ey (if off-shore).. ~. ~ ....... 34. Contact name/phone for we~kly~ro.ress re~s ....... GEOLOGY: ENGINEERING: COMMISSION.: JDH ~,-~ ~'.-, RNC __.,~~ Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ............................ ....... SCHLUMBERGER ....... * ............................ RECEIVED ?,~IAY 24 1999 Alaska Oil & Gas Cons, Commission An~or~e COMPANY NAIViE : BP EXPLORATION (ALASKA), INC. WELL NAME : 2-56A/EIDER-O1 FIELD NAME : ENDICOTT BOROUGH ·NORTH SLOPE STATE : ALASKA API NUMBER : 500292286301 REFERENCE NO : 99152 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-APR-1999 09:3~_~.. PAGE: * * * * REEL HEADER * * * * SERVICE NAME : EDIT DATE · 99/04/ 5 ORIGIN · FLIC REEL NAME : 99152 CONTINUATION # : PREVIOUS REEL : CO~94ENT · BP EXPLORATION, 2-56A/EIDER-O1, ENDICOTT, 50-029-22863-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE ' 99/04/ 5 ORIGIN · FLIC TAPE NAME · 99152 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : BP EXPLORATION, 2-56A/EIDER-O1, ENDICOTT, 50-029-22863-01 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NAME: 2-56A/EIDER-O1 API NUMBER: 500292286301 OPERATOR: BP EXPLORATION (ALASKA), INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-APR-99 JOB NUMBER: 99152 LOGGING ENGINEER: ALLDREDGE OPERATOR WITNESS: PERUZZI SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 16E FNL: FSL: 3193 FEL: 2333 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 54.70 DERRICK FLOOR: 54.70 GROUND LEVEL: 14.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 6.000 4.500 17988.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (~iEASURED DEPTH) ,~ ~ 5-APR-1999 09:3~ ....· PAGE: 2 LIS Tape Verif~-ation Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 19-MAY-98 LOGGING COMPANY: SPERRY- SUN BASELINE DEPTH .............. 88888.0 17837.0 17833.5 17804.0 17792.5 17783.0 17780.0 17778.0 17776.0 17767.5 17747.5 17742.0 17733.5 17715.5 17715.0 17708.0 17707.0 17702.0 17685.5 17670.0 17666.0 17658.0 17640.0 17639.5 17623.5 17620.0 17602.5 17601.0 17584.0 17583.0 17575.0 17574.0 17551.0 17544.0 17525.0 17524.5 17514.5 17509.5 17498.5 17497.0 17495.0 17492.5 17491.0 17488.0 17487.0 .......... EQUIVALENT UNSH I FTED DEPTH .......... GRCH RST 88886.5 88890.0 17835.5 17835.5 17805.0 17791.0 17791.0 17782,5 17782.0 17779.5 17779.5 17770.5 17745.0 17745.0 17739.5 17739.5 17733.0 17733.0 17714.5 17714.5 17710.0 17710.0 17701.0 17687.0 17687.0 17669.0 17669.0 17666.0 17666.0 17657.0 17657.0 17638.0 17637.5 17620.0 17614.5 17597.0 17596.5 17582.0 17582.0 17571.5 17571.5 17547.5 17547.5 17541.5 17541.5 17519.5 17520.0 17511 . 0 17511 . 0 17506.0 17506.0 17494.5 17491.0 17491.0 17485.5 17485.5 17481.0 17481.0 LIS Tape Veri~-~-U~tion Listing Schlumberger Alaska Computing Center 17484.0 17465.5 17451.0 17450.0 17443.0 17420.0 17405.5 17375.0 17371.0 17363.0 17357.5 17351.5 17346.5 17341.0 17334.5 17325.0 17324.0 17314.5 17299.0 17288.0 17286.5 17273 5 17273 0 17270 5 17264 0 17259 0 17258 0 17250 5 17247 0 17240 5 17239 0 17234 5 17234 0 17226.5 17223.5 17219.5 17218.5 17211.0 17207.5 17202.0 17194.0 17192.5 17188.0 17187.5 17182.5 17177.5 17177.0 17175.0 17174.0 17170.0 17166.0 17165.5 17156.5 17155.5 17131.5 17127.5 17475.5 17457.5 17457.5 17443.0 17443.5 17435 5 17435.5 17411 5 17411.5 17399 5 17399.5 17366 5 17366.5 17361 5 17361.5 17353 5 17353.5 17349.5 17349.5 17342.5 17342.5 17339.0 17339.0 17331.5 17331.5 17324.0 17324.0 17318.0 17318.0 17306.0 17306.0 17290.5 17290.5 17280.0 17280.0 17266.0 17266.5 17263.5 17263.5 17258.5 17258.5 17252.0 17252.0 17244.0 17244.0 17241.0 17241.0 17232.5 17233.0 17226.5 17226.5 17219.5 17219.5 17218.0 17218.0 17213.0 17213.0 17205.0 17205.0 17201.0 17201.0 17195.0 17195.0 17187.0 17187.0 17181.5 17181.5 17175.5 17176.0 17170.5 17170.5 17167.0 17167.0 17162.5 17162.5 17160.5 17161.0 17151.0 17151.0 17132.5 17132.0 17127.5 5-APR-1999 09:3~/ PAGE: 3 LIS Tape Veri~ht'~ation Listing Schlumberger Alaska Computing Center 5-APR-1999 09:3~J~ 17126.5 17123.5 17110.5 17108.5 17106.0 17102.0 17100.5 17097.5 17096.5 17086.5 17077 0 17076 5 17070 0 17063 5 17057 0 17053 5 100 0 $ REMARKS: 17127.5 17124.0 17124.0 17103.5 17103.5 17101.5 17101.5 17099.5 17099.5 17096.0 17093.0 17070.0 17096.0 17093.0 17080.5 17070.0 17063.0 17063.0 17057.0 17057.0 17051.5 17051.5 17045.5 92.0 94.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON BP EXPLORATION'S 2-56A/EIDER-O1 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BASE GAF~VA RAY, ALSO BASE PASS #1 SIGMA AND THE BASE GAFk4A RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 17846.5 17034.0 RST 17855.0 17036.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LIS Tape Verif~ation Listing Schlumberger Alaska Computing Center 5-APR-1999 09:3~_~. PAGE: LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH GRCH RST .............. REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Veri~ation Listing Schlumberger Alaska Computing Center 5-APR-1999 09:3'~i PAGE .. NAME SERV UNIT SERVICE API API API API FILE NUAIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CIRNFIL 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 CRRA RST 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 6004740 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 17855.000 NBAC.RST 2231.292 FBAC.RST 3292.875 SBNA.FIL SFNA.FIL 19.053 SBFA.FIL 47.806 SFFA.FIL 17.535 TRAT.FIL IRAT. FIL 0.476 CIRN. FIL 1.051 CIRF.FIL 2.453 BSAL.RST SIBF.RST 41.845 TPHI.RST 25.051 SFFC.RST 16.988 SFNC.RST SIGM. RST 17.009 DSIG.RST 0.947 FBEF.RST 66.261 CRRA.RST GRCH. RST -999.250 TENS.RST 1698.000 CCL.RST 0.224 DEPT. 17034.000 NBAC. RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF.RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH.RST 34.776 TENS.RST -999.250 CCL.RST -999.250 58.837 0.903 55.693 17.642 2.060 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Veri£~Jation Listing Schlumberger Alaska Computing Center 5-APR-1999 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE lvTJMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 17847.5 17402.0 RST 17854.5 17402.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NIIMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88887.5 88889.5 17848.0 17849.5 17836.5 17836.0 17838.5 17824.5 17826.0 17808.5 17809.5 17804.0 17801.5 17803.5 17805.0 17801.0 17801.0 17795.5 17794.5 17792.5 17791.0 17789.5 17789.5 17780.0 17782.5 17776.0 17779.5 17774.0 17774.5 17769.0 17771.0 17760.5 17761.5 17753.5 17753.0 17751.0 17749.5 17738.5 17738.0 17732.5 17733.0 17722.5 17725.0 ~ 5-APR-1999 09:3~ PAGE: 8 LIS Tape Veri£~ation Listing Schlumberger Alaska Computing Center 17716.5 17713.0 17712.0 17707.5 17702 0 17699 0 17696 5 17694 5 17689 0 17688 0 17683 5 17678 5 17677 0 17676.0 17671.0 17670.0 17666.0 17665.0 17661.0 17660.0 17651.0 17640.5 17639.5 17618.0 17609.0 17601.5 17583.5 17578.0 17574.5 17567.0 17559.5 17550.0 17547.0 17544.0 17542.0 17538.0 17536.5 17536.0 17528 0 17525 0 17524 5 17514 5 17509 5 17500 0 17497 0 17495.5 17491.0 17488.5 17487.5 17482.0 17481.5 17474.0 17460.5 17453.0 17452.5 17719.5 17715.0 17710.0 17699.5 17689.0 17677.0 17669.0 17665.5 17660.5 17648.0 17638.0 17612.5 17597.0 17572.0 17561.5 17556.5 17547.5 17546.0 17541.0 17533.5 17524.0 17520.5 17512.0 17506.0 17495.5 17491.5 17485.0 17481.5 17475.0 17452.0 17442.5 17712.0 17710.5 17701.0 17698.5 17696.5 17690.0 17685.5 17679.5 17675.5 17670.5 17666.0 17660.5 17637.5 17605.0 17582.0 17572.0 17542.0 17534.5 17532.0 17520.5 17491.5 17485.5 17481.5 17473.0 17466.0 17446.5 ~ 5-APR-1999 09:3~--~ PAGE: 9 LIS Tape Veri~-x~ation Listing Schlumberger Alaska Computing Center 17449.5 17443.5 17441.0 17433.0 17432.5 17424.5 17428.0 17420.5 17424.5 17415.0 100.0 90.0 90.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Veri£=wation Listing Schlumberger Alaska Computing Center 5-APR-1999 09:3~-~ PAGE: 10 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) SFFA FIL CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 CIRN FIL 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 BSAL RST PPK 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 CRRA RST 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 6004740 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 17854.500 NBAC. RST SFNA.FIL 21.355 SBFA.FIL IRAT. FIL 0.457 CIRN. FIL SIBF.RST 44.325 TPHI.RST SIGM. RST 19.261 DSIG.RST GRCH.RST -999.250 TENS.RST DEPT. 17402.000 NBAC. RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF.RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST 20.361 TENS.RST 2389 226 49 889 0 828 24 815 0 692 1693 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 FBAC.RST 3166.196 SBNA.FIL 61.371 SFFA.FIL 19.731 TRAT. FIL 0.900 CIRF.FIL 1.976 BSAL.RST 62.451 SFFC.RST 19.188 SFNC.RST 19.894 FBEF.RST 69.093 CRRA.RST 2.058 CCL.RST -0.244 FBAC.RST -999.250 SBNA.FIL SFFA.FIL -999.250 TRAT.FIL CIRF. FIL -999.250 BSAL.RST SFFC.RST -999.250 SFNC.RST FBEF.RST -999.250 CRRA.RST CCL.RST -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSrON · 001C01 DATE · 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~ 5-APR-1999 09:3~=r-~ PAGE: 11 LIS Tape Verif~J~tion Listing Schlumberger Alaska Computing Center **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AffJMBER: 3 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, RST $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Veri£.~tion Listing Schlumberger Alaska Computing Center 5-APR-1999 09:3~~ PAGE: 12 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE lVTJMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT RSAV 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT RSAV 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNRSAV 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF RSAV 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 BSAL RSAV PPK 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RSAV PU-S 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RSAV CU 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RSAV UA 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 CRRA RSAV 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 6004740 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 17855. 000 NBAC. RST 2231.292 FBAC.RST 3292. 875 SBNA.RSAV SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV SIBF. RSAV - 999. 250 TPHI. RSAV - 999. 250 SFFC. RSAV - 999. 250 SFNC. RSAV SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV -999.250 CRRA.RSAV GRCH. RST -999. 250 DEPT. 17034.000 NBAC. RST -999.250 FBAC.RST -999.250 SBNA.RSAV SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV IRAT.RSAV -999.250 CIRN. RSAV -999.250 CIRF.RSAV -999.250 BSAL.RSAV SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF.RSAV -999.250 CRRA.RSAV GRCH. RST 34.776 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** ~ 5-APR-1999 09:3b~' PAGE: 13 LIS Tape Veri~ation Listing Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE · 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUFkqARY VENDOR TOOL CODE START DEPTH RST 17896.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 17010.0 27-FEB-99 8C0-609 1700 27-FEB-99 17988.0 17886.0 17042.0 17853.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAI~4A RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER ........... GR RST-A 6.000 LIS Tape Verif£~tion Listing Schlumberger Alaska Computing Center 5-APR-1999 09:36~-=~ PAGE: 14 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) .. BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) '. FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : 17988.0 SEAWATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: THANK YOU FOR USING SCHLUMBERGER. TIED INTO SPERRY-SUNMWDLOG 14-MAY-98. WELL WAS KILLED PRIOR TO LOGGING WITH SEAWATER. PUMPED 0.5 BBL OF SEAWATER WHILE LOGGING. RAN RST-A WITH PSP FOR TELEM/GR/CCL/PRESS/TEMP. 2 SIGMA PASSES MADE AT 1800 FPM. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 LIS Tape Verif~J~tion Listing Schlumberger Alaska Computing Center 5-APR-1999 09..36`~J PAGE: 15 TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NtC4B SAMP ELEM CODE (HEX) DEPT FT 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CS PS1 F/HR 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 TENS PS1 LB 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 NPHV PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 NPDE PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 NSCE PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 NSCR PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 AQTMPS1 S 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CHV PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CPSV PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CP2V PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CM2V PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RCFR PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RCLC PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RCRC PSl 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RCAK PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RTDF PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 FPHV PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 FPDE PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 FSCE PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 FSCR PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 AQTF PS1 S 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SF6P PS1 PSIG 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 HVPV PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 BMCU PS1 UA 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 GDCU PS1 MA 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 EXCU PS1 UA 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 NBEF PS1 UA 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF PS1 UA 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 NPGF PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 FPGF PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Veri~h=.'~tion Listing Schlumberger Alaska Computing Center S-APR-1999 09:3~ PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) BSTR PS1 6004740 O0 000 O0 0 4 1 i 4 68 0000000000 BSPR PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 MARC PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 XHV PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 XP5V PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 XP2V PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 X~2V PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RXFR PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RXLC PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RXRC PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RXAKPS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SHCU PS1 MA 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL PS1 PPK 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL SIG PPK 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CIRN PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG PS1 CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PS1 CPS 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC PS1 CPS 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA PS1 CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA PS1 CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA PS1 CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA PS1 CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA SIG CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA SIG CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA SIG CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA SIG CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF PS1 CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC PSI CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC PSl CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PS1 CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF SIG CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM SIG CU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT SIG 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 GR PS1 GAPI 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RDIX PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CRNI PS1 KHZ 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CRFI PS1 KHZ 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CTM PS1 DEGC 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 XTM PS1 DEGC 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 TAV PS1 KV 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Veri~-~c~tion Listing Schlumberger Alaska Computing Center 5-APR-1999 09'.3~~,~ PAGE: 17 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) FICU PS1 AMP 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CACU PS1 AMP 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 BUST PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 BUSP PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RSXS PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PS1 PU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI SIG PU 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 CCLC PS1 V 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 RSCS PS1 6004740 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PS1 CM2 V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR.PS1 XPSV. PS1 RXLC. PSl BSAL.PS1 CIRN. FIL IRAT. PS1 SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG GR.PS1 CTM. PS1 CACU. PS1 TPHI.PS1 DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR.PS1 XPSV. PS1 RXLC. PS1 BSAL.PS1 CIRN. FIL 17896.000 1554 071 0 661 -12 309 1 000 2 375 161 377 31 919 37 934 5 069 0 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 270.979 64.941 2.437 -999.250 17010.000 1554.567 0.661 -12.270 0.000 2.288 161.708 30.706 57.433 5.069 0.000 73.191 0.650 CS.PS1 1496.882 TENS.PSi NSCE. PS1 2.706 CRRA.PS1 CHV. PS1 202.308 CP5V. PS1 RCFR.PS1 0.000 RCLC.PS1 RTDF. PS1 0.000 FPHV. PS1 FSCR.PS1 0.036 AQTF. PS1 BMCU. PS1 35.742 GDCU. PS1 FBEF. PS1 65.876 NPGF. PS1 BSPR.PS1 1.046 MARC.PSi XP2V. PS1 12.144 X~2V. PS1 RXRC. PS1 0.000 RXAK. PS1 BSAL.SIG -999.250 CIRN. PS1 CIRF. FIL -999.250 DSIG.PS1 IRAT. FIL -999.250 NBAC. PS1 SBNA.PS1 -999.250 SBFA.PS1 SBNA.SIG -999.250 SBFA.SIG SBNA. FIL -999.250 SBFA.FIL SFFC. PS1 -999.250 SIGM. PS1 TRAT. PS1 -999.250 TRAT. SIG RDIX. PS1 111830.000 CRNI.PS1 XTM. PS1 64.941 TAV. PS1 BUST. PSi 3.000 BUSP.PS1 TPHI.SIG -999.250 CCLC.PS1 CS.PS1 NSCE. PS1 CHV. PS1 RCFR.PS1 RTDF. PS1 FSCR.PS1 BMCU. PS1 FBEF. PS1 BSPR.PS1 XP2V. PS1 RXRC. PS1 BSAL.SIG CIRF. FIL 1869.673 2.709 202.308 0.000 0 000 0 122 34 675 62 670 1 075 12 148 0 000 5 943 1 710 TENS.PSi CRRA.PS1 CPSV. PS1 RCLC. PS1 FPHV. PS1 AQTF.PS1 GDCU. PS1 NPGF. PS1 MARC. PSi XM2V. PS1 RXAK. PS1 CIRN. PS1 DSIG.PS1 588.000 2.064 5.069 0.000 1486. 817 O. 661 60 340 1 004 0 000 -12 407 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 451.394 95.031 3.000 -0.057 1439.000 2.041 5.069 0.000 1491.700 0.661 60.129 0.995 0.000 -12.379 1.000 0.648 1.213 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 2E4V. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC.PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 RSCS.PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC.PS1 FPDE. PS1 SF6P.PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 1560.060 -0.245 12.217 0.000 1478.463 111.183 3.551 1.002 199.400 0.000 43.902 -999.250 -999. 250 -999. 250 -999. 250 -999.250 -999.250 -999.250 -999.250 218.720 2.378 8878.000 8463.000 1555.177 -0.041 12.173 0.000 1481.515 117.323 3.635 0.997 199.937 0.000 46.921 1.703 3011.251 LIS Tape Verif'~Jation Listing Schlumberger Alaska Computing Center 5-APR-1999 09:36 PAGE: 18 IRAT. PS1 0.487 IRAT. FIL 0.486 NBAC.PS1 SFFA.PS1 23.185 SBNA.PS1 55.828 SBFA.PS1 SFFA.SIG 0.435 SBNA.SIG 4.316 SBFA.SIG SFFA.FIL 22.498 SBNA.FIL 62.234 SBFA.FIL SFNC.PS1 23.834 SFFC. PS1 22.264 SIGM. PS1 SIGM. SIG 0.352 TRAT. PS1 0.782 TRAT. SIG GR.PS1 53.631 RDIX. PS1 137215.000 CRNI.PS1 CTM. PS1 69.824 XTM. PS1 67.871 TAV. PS1 CACU. PS1 2.428 BUST. PSi 3.000 BUSP. PS1 TPHI.PS1 17.073 TPHI.SIG 0.543 CCLC. PS1 2303.237 SFNA.PS1 45.764 SFNA.SIG 3.983 SFNA.FIL 46.058 SIBF. PS1 22.256 SIBF. SIG 0.016 TRAT. FIL 448.485 CRFI.PS1 95.021 FICU. PS1 3.000 RSXS.PS1 -999.250 RSCS.PS1 25.405 0.727 25.621 48.306 2.217 0.775 219.741 2.315 8878.000 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~a2~Y VENDOR TOOL CODE START DEPTH RST 17893.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: STOP DEPTH 17381.5 27-FEB-99 8C0-609 1700 27-FEB-99 LIS Tape Verif~tion Listing Schlumberger Alaska Computing Center 5-APR-1999 09:36'-r--~ PAGE: 19 TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 17988.0 17886.0 17042.0 17853.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~fl~A RAY RST RESERVOIR SATURATION $ TOOL NUMBER GR RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6. 000 17988.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEAWATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: THANK YOU FOR USING SCHLUMBERGER. TIED INTO SPERRY-SUN MWD LOG 14-MAY-98. WELL WAS KILLED PRIOR TO LOGGING WITH SEAWATER. PUMPED 0.5 BBL OF SEAWATER WHILE LOGGING. RAN RST-A WITH PSP FOR TELE~I/GR/CCL/PRESS/TEMP. 2 SIGMA PASSES MADE AT 1800 FPM. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. LIS Tape Verif-~-u-~tion Listing Schlumberger Alaska Computing Center 5-APR-1999 09:36TM PAGE: 20 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS2 F/HR 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS2 LB 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 NPHV PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS2 V 6004740 O0 000 O0 0 5 i 1 4 68 0000000000 NSCE PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS2 S 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RCAK PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 FPHV PS2 V 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 LIS Tape Verif;~tion Listing Schlumberger Alaska Computing Center 5-APR-1999 09:36 PAGE: 21 NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) FPDE PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS2 S 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 SF6P PS2 PSIG 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 HVPV PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS2 UA 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PS2 MA 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS2 UA 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS2 UA 6004740 O0 000 O0 0 5 1 I 4 68 0000000000 FBEF PS2 UA 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS2 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 XHV PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 X~2V PS2 V 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 RXFR PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS2 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 RXAK PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS2 MA 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS2 PPK 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 CIRN PS2 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 CIRF PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 CIRF FIL 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PS2 CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS2 CPS 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS2 CPS 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS2 CU 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 SFFA PS2 CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS2 CU 6004740 O0 000 O0 0 5 I 1 4 68 0000000000 SBFA PS2 CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 SFFA SIG CU 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 SBNA SIG CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF PS2 CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS2 CU 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 SFFC PS2 CU 6004740 O0 000 O0 0 $ 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-APR-1999 09:36 PAGE: 22 NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIGM PS2 CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS2 KHZ 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS2 KHZ 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS2 DEGC 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS2 DEGC 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS2 KV 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS2 AMP 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS2 AMP 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS2 PU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS2 V 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PS2 6004740 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 17893.000 NPDE. PS2 1554.185 NSCE. PS2 AQTM. PS2 O . 661 CHV. PS2 CM2V. PS2 -12. 270 RCFR. PS2 RCAK. PS2 0. 000 RTDF. PS2 FSCE. PS2 2.213 FSCR.PS2 HVPV. PS2 161~621 BMCU. PS2 NBEF. PS2 33.252 FBEF. PS2 BSTR.PS2 41.925 BSPR.PS2 XP5V. PS2 5.069 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 2.660 CRR~.PS2 2 202.550 CPSV. PS2 5 0.000 RCLC. PS2 0 0.000 FPHV. PS2 1491 0.386 AQTF. PS2 36.914 GDCU. PS2 66.872 NPGF.PS2 1.088 MARC.PS2 12.144 XM2V. PS2 0.000 ~.PS2 0 60 1 0 -12 O. 000 SHCU. PS2 CS.PS2 1283.880 TENS.PS2 865 000 NPHV. PS2 1562.501 011 NSCR.PS2 -0.267 069 CP2V. PS2 12.202 000 RCRC. PS2 0.000 700 FPDE.PS2 1481.172 661 SF6P.PS2 118.091 340 EXCU. PS2 3.551 002 FPGF. PS2 1.003 000 XHV. PS2 199.643 407 RXFR.PS2 0.000 41.625 BSAL.PS2 -999.250 BSAI~.SIG -999.250 CIRN. PS2 -999.250 CIRF. PS2 -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS2 -999.250 FBAC. PS2 -999.250 IRAT. PS2 -999.250 IRAT. FIL -999.250 NBAC.PS2 -999.250 SFNA.PS2 -999.250 SFFA.PS2 -999.250 SBNA.PS2 -999.250 SBFA.PS2 -999.250 SFNA.SIG -999.250 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL -999.250 SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS2 -999.250 SFNC. PS2 -999.250 SFFC.PS2 -999.250 SIGM. PS2 -999.250 SIBF. SIG -999.250 SIGM. SIG -999.250 TRAT. PS2 -999.250 TRAT. SIG -999.250 TRAT. FIL -999.250 GR.PS2 663.077 RDIX.PS2 142398.000 CRNI.PS2 445.856 CRFI.PS2 221.701 CTM. PS2 70,801 XTM. PS2 68.848 TAV. PS2 95.031 FICU. PS2 2.397 CACU. PS2 2,432 BUST. PS2 3.000 BUSP.PS2 3.000 RSXS.PS2 8878.000 TPHI.PS2 -999,250 TPHI.SIG -999.250 CCLC.PS2 -2.270 RSCS. PS2 8459.000 LIS Tape Verif~e~'tion Listing Schlumberger Alaska Computing Center 5-APR-1999 09:36~.~/ PAGE: 23 DEPT. NPDE. PS2 AQTM. PS2 CM2 V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XPSV. PS2 RXLC. PS2 BSAL. PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC. PS2 SIGM. SIG GR.PS2 CTM. PS2 CACU. PS2 TPHI.PS2 17381.500 1553.918 1.102 -12.279 2.000 2.229 161.816 32.788 65.988 5.070 0.000 31.968 1.329 0.498 12.365 0 147 12 495 11 299 0 127 85 915 71 777 2 430 15 196 CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 RXRC. PS2 BSAL.SIG CIRF. FIL IRAT. FIL SBNA.PS2 SBNA.SIG SBNA.FIL SFFC. PS2 TRAT. PS2 RDIX. PS2 XTM. PS2 BUST. PS2 TPHI.SIG 1801.763 2.673 202.308 0.000 0.000 -0.074 36. 250 71. 613 1.136 12.152 0.000 3.668 3.587 0.504 55.147 4.192 55.726 11.607 0.747 157819.000 70.150 3.000 0.326 TENS.PS2 CRRA.PS2 CPSV. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC.PS2 2242V. PS2 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRA T. SIG CRNI. PS2 TA V. PS2 BUSP. PS2 CCLC. PS2 1545.000 2 184 5 074 0 000 1501 466 0 661 59 815 0.996 0.000 -12.375 1.000 1.333 -0.314 2328.125 31.960 3.415 35.103 11.593 0.009 443.017 94.974 3.000 -999.250 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC.PS2 FPDE. PS2 SF6P.PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC.PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT.FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 1564.943 -0.216 12.231 0.000 1483.079 120.342 3.367 0.997 199.885 0.000 44.053 3.508 3037.200 13.822 0.299 13. 583 33. 292 1.303 O. 748 202.833 2.376 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/04/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/04/ 5 ORIGIN : FLIC TAPE NAME : 99152 CONTINUATION # : 1 PREVIOUS TAPE : CO~E4ENT : BP EXPLORATION, 2-56A/EIDER-O1, ENDICOTT, 50-029-22863-01 · ~ ~ 5-APR-1999 09:36 ...... PAGE: 24 LIS Tape Verification Listing Schlumberger Alaska Computing Center **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/04/ 5 ORIGIN : FLIC REEL NAME : 99152 CONTINUATION # : PREVIOUS REEL : COGENT : BP EXPLORATION, 2-56A/EIDER-O1, ENDICOTT, 50-029-22863-01 Sperry-Sun Drilling Services LIS Scan Utility Mon Jun 15 17:38:25 1998 Reel Header Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER ENDICOTT MPI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-M~-80134 M. HANIK J. CARLILE 2-56A/PB2 500292286371 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 15-JUN-98 MWD RUN 4 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 5 AK-MM-80134 J. MARTIN J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MM-80134 M. GABEL E. VAUGHN MWD RUN 23 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 24 AK-MM-80134 M. HANIK J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 25 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 26 AK-MM-80134 G. TOBIAS J. CARLILE MWD RUN 26 AK-M~-80134 G. TOBIAS J. CARLILE SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 36 12N 16E 3193 2333 .00 54.70 14.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 30.000 80.0 12.250 9.625 7079.0 8.500 7.000 15958.0 6.000 17775.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 3-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUNS 20 THRU 22, 27 AND 28 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 5. MWD RUN 23 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. 6. MWD RUNS 24 THRU 26 ARE DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO DENSITY (SLD). 7. MWD DATA FROM 16812'MD TO 17499'MD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE RUNNING IN THE HOLE AFTER MWD RUN 26. 8. MWD RUNS 1-5, 20-26,REPRESENT WELL 2-56A/PB2 WITH API#: 50-029-22863-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17775'MD, 10064'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 SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY- SANDSTONE MATRIX FIXED HOLE SIZE TNPS = COMPENSATED THERMAL NEUTRON POROSITY. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR COUNT RATES (CNP). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR COUNT RATES (CNP). CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR COUNT RATES (CTN). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR COUNT RATES (CTN). SBDC = SMOOTHED BULK DENSITY-COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTELECTRIC ABSORPTION FACTOR. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL FACTORS USED IN PROCESSING NUCLEAR LOG DATA: HOLE SIZE: 8.5" & 6" FIXED MUD WEIGHT: 9.8-10.2 PPG MUD FILTRATE SALINITY: 600 PPM CL FORMATION WATER SALINITY: 11500 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC MATRIX: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX PEF DRHO RHOB FCNT NCNT NPHI START DEPTH 7044 0 7088 0 15678 5 15678 5 15678 5 15678 5 15678 5 15696 0 15696 0 15696 0 16366 5 16366 5 16366 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 17731 0 17775 5 17738 0 17738 0 17738 0 17738 0 17738 0 17701.5 17701.5 17701.5 17685.5 17685.5 17685.5 BASELINE DEPTH GR 7044.0 7058.0 15944.0 15958.0 15958.5 15958.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 ~D 4 MWD 5 MWD 6 ~D 23 MWD 24 MWD 25 MWD 26 $ REMARKS: MERGED MAIN PASS. $ EQUIVALENT UNSHIFTED DEPTH MERGE TOP 7100.0 10212 0 11873 0 15692 0 16333 0 16674 0 16840 0 17175 0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 10212.0 11873.0 15958.0 15958.0 16674.0 16840.0 17175.0 17775.0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMS4 4 1 68 RPM MWD OHM~ 4 1 68 RPD MWD OHMS4 4 1 68 FET MWD HOUR 4 1 68 RHOB I~D G/CC 4 1 68 DRHO l~D G/CC 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 7044 17775.5 ROP 3.4021 4717.97 GR 4.4011 429.412 RPX 0.5989 2000 RPS 0.4048 2000 RPM 0.3804 2000 Mean Nsam 12409.8 21464 103.595 21376 77.1864 20717 22.9096 3146 24.1908 3146 28.7305 3146 First Reading 7044 7088 7044 15678.5 15678.5 15678.5 Last Reading 17775.5 17775.5 17731 17738 17738 17738 RPD 0.5587 2000 30.3839 3146 FET 1.0977 68.1264 16.574 3146 RHOB 2.072 3.0668 2.42473 3112 DRHO -0.115 0.8208 0.0860827 3112 PEF 1.0929 10.2362 3.3627 3112 NPHI 8.2 58.83 23.1161 2639 NCNT 634.42 57423.6 35179.2 2639 FCNT 3.94 2403.94 761.694 2639 15678.5 15678.5 15696 15696 15696 16366.5 16366.5 16366.5 17738 17738 17701.5 17701.5 17701.5 17685.5 17685.5 17685.5 First Reading For Entire File .......... 7044 Last Reading For Entire File ........... 17775.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FI LE SUI~LARY PBU TOOL CODE FCNT N CN T NPHI PEF DRHO RHOB GR RPX RPS RPM RPD FET RAT .5000 START DEPTH 16813.0 16813 0 16813 0 16830 0 16830 0 16830 0 16859 5 16866 0 16866 0 16866.0 16866.0 16866.0 16901.5 STOP DEPTH 17414.5 17414.5 17414.5 17430 0 17430 0 17430 0 17456 5 17461 5 17461 5 17461 5 17461 5 17461 5 17499 0 MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: MAD RUN NO. MAD PASS NO. 26 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 17175.0 Name Service Order Units Size Nsam Rep DEPT FT 4 .1 68 NPHI MAD P.U. 4 1 68 FCNT MAD CTS/ 4 1 68 NCNT MAD CTS/ 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RP S MAD OHMM 4 1 68 RPM MAD OPLMM 4 1 68 RPD MAD OHMM 4 1 68 RAT MAD FT/H 4 1 68 FET MAD HOUR 4 1 68 RHOB MAD G/CC 4 1 68 DRHO MAD G/CC 4 1 68 PEF MAD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 MERGE BASE 17775.0 Name Min Max Mean DEPT 16813 17499 17156 N?HI 8 38.58 19.6792 FCNT 269.41 2413.28 930.231 NCNT 25942.4 57446.2 41600.4 GR 11.7291 183.548 45.5401 RPX 1.4387 134.702 29.1027 RPS 2.2004 85.2691 27.7206 RPM 2.6502 78.2159 28.8732 RPD 3.5603 80.8101 32.9446 RAT 21.3419 4521.09 223.03 FET 27.5148 92.8664 60.0858 RHOB 2.1065 3.0187 2.39849 DRHO -0.06 0.7579 0.0612264 PEF 1.2598 8.324 3.09204 Nsam 1373 1204 1204 1204 1195 1192 1192 1192 1192 1195 1192 1201 1201 1201 First Reading 16813 16813 16813 16813 16859.5 16866 16866 16866 16866 16901.5 16866 16830 16830 16830 Last Reading 17499 17414.5 17414.5 17414.5 17456.5 17461.5 17461.5 17461.5 17461.5 17499 17461.5 17430 17430 17430 First Reading For Entire File .......... 16813 Last Reading For Entire File ........... 17499 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7058.0 10167.5 ROP 7102.0 10211.5 $ LOG HEADER DATA DATE LOGGED: 27-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10212.0 TOP LOG INTERVAL (FT) : 7100.0 BOTTOM LOG INTERVAL (FT) : 10212.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 59.6 MAXIMUM ANGLE: 63.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0956CG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.50 45.0 9.6 1600 5.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 42.2 First Name Min Max Mean Nsam Reading DEPT 7058 10211.5 8634.75 6308 7058 ROP 6.5739 377.227 146.525 6220 7102 GR 4.4011 127.552 67.5197 6220 7058 Last Reading 10211.5 10211.5 10167.5 First Reading For Entire File .......... 7058 Last Reading For Entire File ........... 10211.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Nurabe~ ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMlq_ARY VENDOR TOOL CODE START DEPTH GR 10169.0 ROP 10213.5 $ 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 11829.5 11872.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM/ViA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS I~JD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 01-MAR-98 ISC 5.07 CIM 5.46 MEMORY 11873.0 10212.0 11873.0 58.7 62.2 TOOL NUMBER P0956CG6 8.500 8.5 LSND 9.60 46.0 9.4 1300 4.8 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 · 000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 44.2 First Name Min Max Mean Nsam Reading DEPT 10169 11872 11020.5 3407 10169 ROP 6.4328 419.093 128.969 3318 10213.5 GR 22.2284 122.499 66.6233 3322 10169 Last Reading 11872 11872 11829.5 First Reading For Entire File .......... 10169 Last Reading For Entire File ........... 11872 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11830.0 1595~.5 ROP 11874.5 15957.5 $ LOG HEADER DATA DATE LOGGED: 06-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 16020.0 TOP LOG INTERVAL (FT): 11873.0 BOTTOM LOG INTERVAL (FT): 16020.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.8 MAXIMUM ANGLE: 61.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM~tARAY $ TOOL NUMBER P0956CG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.00 48.0 9.4 1000 4.4 .000 .000 .000 .000 51.7 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11830 15957.5 13893.8 8256 11830 ROP 6.3024 2344.92 91.1815 8167 11874.5 GR 19.3321 216.163 86.3957 8256 11830 Last Reading 15957.5 15957.5 15957.5 First Reading For Entire File .......... 11830 Last Reading For Entire File ........... 15957.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE STTkRT DEPTH STOP DEPTH FET 15692.5 15958.0 RPD 15692.5 15958.0 RPD 15692.5 15958.0 RPS 15692.5 15958.0 RPX 15692.5 15958.0 FCNT 15701.0 15958.0 NCNT 15701.0 15958.0 NPHI 15701.0 15958.0 PEF 15710.0 15958.0 DRHO 15710.0 15958.0 RHOB 15710.0 15958.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OH~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 07-MAR-98 ISC 5.07 CIM 5.46 MEMORY 16465.0 16020.0 16465.0 25.7 35.0 TOOL NUMBER P0969CRNLG6 P0969CRNLG6 P0969CRNLG6 P0969CRNLG6 8.500 8.5 LSND 10.20 500.0 9.5 8OO 3.6 2. 000 1.060 62. 8 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 ....................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1.650 2.600 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RPX MWD 6 OHMM 4 1 68 RPS MWD 6 OHMM 4 1 68 RPM MWD 6 OHMM 4 1 68 RPD MWD 6 OHMM 4 1 68 FET MWD 6 HOUR 4 1 68 NPHI MWD 6 P.U. 4 1 68 NCNT MWD 6 CNTS 4 1 68 FCNT MWD 6 CNTS 4 1 68 RHOB MWD 6 G/CC 4 1 68 DRHO MWD 6 G/CC 4 1 68 PEF MWD 6 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 Name Min DEPT 15692.5 RPX 1.1302 RPS 1.1329 RPM 1.1709 RPD 0.9799 FET 28.2892 NPHI 27.9452 NCNT 2160 FCNT 571 RHOB 2.1347 DRHO -0.088 PEF 1.1811 Max 15958 9 0436 8 9429 10 6446 8 7769 39 4337 81 7622 3216 843 2.6876 0.6206 7.1654 Mean Nsam 15825.2 532 3.61111 532 3.73782 532 3.74694 532 3.7106 532 34.2415 532 53.6982 515 2602.23 515 681.737 515 2.46788 497 0.104896 497 3.22188 497 First Reading 15692 5 15692 5 15692 5 15692 5 15692 5 15692 5 15701 15701 15701 15710 15710 15710 Last Reading 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 First Reading For Entire File .......... 15692.5 Last Reading For Entire File ........... 15958 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 23 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 16271.0 ROP 16335.5 $ 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 16610.5 16674.0 22-APR-98 ISC 5.07 CIM 5.46 MEMORY 16674.0 16333.0 16674.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AJqD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 35.7 61.0 TOOL NUMBER PCG 47 6.000 6.0 LSND 10.10 51.0 9.0 600 2.9 .000 .000 .000 .000 53.9 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 23 API 4 1 68 4 2 ROP MWD 23 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 16271 16674 16472.5 807 16271 GR 35.6856 429.412 196.783 680 16271 ROP 3.4021 270.201 19.8749 678 16335.5 Last Reading 16674 16610.5 16674 First Reading For Entire File .......... 16271 Last Reading For Entire File ........... 16674 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 24 .5000 START DEPTH 16366.5 16366.5 16366 5 16394 5 16394 5 16394 5 16431 0 16431 0 16431 0 16431 0 16431.0 16611.0 16642.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : STOP DEPTH 16755.5 16755.5 16755.5 16771.5 16771.5 16771.5 16808.0 16808.0 16808.0 16808.0 16808.0 16801.0 16839.5 24-APR-98 ISC 5.07 CIM 5.46 MEMORY 16840.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAM~uX RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS I'g~D TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 16674.0 16840.0 63.3 64.6 TOOL NUMBER P0997SP4 P0997SP4 P0997SP4 P0997SP4 6.000 6.0 LSND 10.20 52.0 9.2 5OO 2.8 1.200 .725 1.050 .950 58.3 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 24 API 4 1 68 4 2 RPX MWD 24 OHMM 4 1 68 8 3 RPS MWD 24 OHMM 4 1 68 12 4 RPM MWD 24 OHMM 4 1 68 RPD MWD 24 OHMM 4 i 68 ROP MWD 24 FT/H 4 1 68 FET MWD 24 HOUR 4 1 68 NPHI MWD 24 P.U. 4 1 68 FCNT MWD 24 CNTS 4 1 68 NCNT MWD 24 CNTS 4 1 68 RHOB MWD 24 G/CC 4 1 68 DRHO MWD 24 G/CC 4 1 68 PEF MWD 24 BARN 4 1 68 16 20 24 28 32 36 40 44 48 52 5 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 16366.5 16839.5 16603 947 GR 16.3021 111.675 50.5422 381 RPX 3.0724 67.3997 19.5774 755 RPS 3.0749 2000 25.995 755 RPM 3.1619 2000 43.3788 755 RPD 2.7894 2000 41.4159 755 ROP 6.7889 4717.97 113.36 396 FET 2.1276 68.1264 34.7053 755 NPHI 8.2 58.83 29.1624 779 FCNT 3.94 2403.94 606.981 779 NCNT 634.42 57423.6 24153.9 779 RHOB 2.072 3.0668 2.47811 755 DRHO -0.115 0.8208 0.142545 755 PEF 1.2767 10.2362 4.64896 755 First Reading 16366.5 16611 16431 16431 16431 16431 16642 16431 16366.5 16366.5 16366.5 16394.5 16394.5 16394.5 Last Reading 16839.5 16801 16808 16808 16808 16808 16839.5 16808 16755.5 16755.5 16755.5 16771.5 16771.5 16771.5 First Reading For Entire File .......... 16366.5 Last Reading For Entire File ........... 16839.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 25 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 16757 0 NCNT 16757 0 NPHI 16757 0 PEF 16772 5 DRHO 16772 5 RHOB 16772 5 GR 16802 0 FET 16808 5 RPD 16808 5 RPM 16808 5 RPS 16808 5 RPX 16808 5 ROP 16841 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 17091.0 17091.0 17091.0 17106 5 17106 5 17106 5 17136 0 17143 0 17143 0 17143 0 17143.0 · 17143.0 17175.0 26-APR- 98 ISC 5.07 CIM 5.46 MEMORY 17175.0 16840.0 17175.0 56.0 64.6 TOOL NUMBER P0997SP4 EWR4 CTN SLD $ ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE ~D CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: P0997SP4 P0997SP4 P0997SP4 6.000 6.0 LSND 10.20 61.0 9.3 5OO 2.8 1.500 .642 1.000 1.100 70.5 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT GR MWD 25 RPX MWD 25 RPS MWD 25 RPM MWD 25 RPD MWD 25 ROP MWD 25 FET MWD 25 NPHI MWD 25 FCNT MWD 25 NCNT MWD 25 RHOB MWD 25 DRHO MWD 25 PEF MWD 25 FT 4 1 68 0 1 API 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 FT/H 4 1 68 24 7 HOUR 4 1 68 28 8 P.U. 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 G/CC 4 1 68 44 12 G/CC 4 1 68 48 13 BARN 4 1 68 52 14 Name DEPT GR RPX RPS RPM RPD ROP FET NPHI FCNT NCNT RHOB DRHO PEF Min 16757 15 2194 0 5989 0 4048 0 3804 0 5587 4 4676 1 4801 8.95 386.08 29317.9 2.1242 -O.078 1.2748 Max 17175 125.161 2000 2000 214.266 2000 264.253 27.9357 29.62 2113.63 54502.2 2.7643 0.1631 5.8077 Mean Nsam 16966 33 0094 40 8217 39 2853 41 2228 48 1748 22 7968 4.94021 14.6082 1240.09 44826.1 2.38127 0.0372224 2.87905 837 669 670 670 670 670 668 670 669 669 669 669 669 669 First Reading 16757 16802 16808 5 16808 5 16808 5 16808 5 16841 5 16808 5 16757 16757 16757 16772.5 16772.5 16772.5 Last Reading 17175 17136 17143 17143 17143 17143 17175 17143 17091 17091 17091 17106.5 17106.5 17106.5 First Reading For Entire File .......... 16757 Last Reading For Entire File ........... 17175 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 26 .5000 START DEPTH 17091.5 17091.5 17091.5 17107.5 17107.5 17107.5 17136.5 17143 5 17143 5 17143 5 17143 5 17143 5 17177 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : STOP DEPTH 17685.5 17685.5 17685.5 17701.5 17701.5 17701.5 17731.0 17738.0 17738.0 17738.0 17738.0 17738.0 17775.5 29-APR-98 ISC 5.07 CIM 5.46 MEMORY 17775.0 17175.0 17775.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA~ RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 61.5 66.3 TOOL NUMBER P0980SP4 P0980SP4 P0980SP4 P0980SP4 6.000 6.0 LSND 10.20 63.0 9.5 500 2.6 1.000 .514 .890 1.950 70.0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 26 API 4 1 68 4 2 RPX MWD 26 OHMM 4 1 68 8 3 RPS MWD 26 OHMM 4 1 68 12 4 RPM MWD 26 OHMM 4 1 68 16 5 RPD MWD 26 OHM}4 4 1 68 20 6 ROP MWD 26 FT/H 4 1 68 FET MWD 26 HOUR 4 1 68 NPHI MWD 26 P.U. 4 1 68 FCNT MWD 26 CNTS 4 1 68 NCNT MWD 26 CNTS 4 1 68 RHOB MWD 26 G/CC 4 1 68 DRHO MWD 26 G/CC 4 1 68 PEF MWD 26 BARN 4 1 68 24 28 32 36 40 44 48 52 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 17091.5 17775.5 17433.5 1369 GR 15.686 192.03 58.2633 1190 RPX 4.4891 77.0221 23.5497 1190 RPS 3.5994 67.0217 23.6737 1190 RPM 3.0292 67.2085 23.5511 1190 RPD 3.9995 73.9244 25.2698 11'90 ROP 4.5579 234.7 28.6492 1197 FET 1.0977 27.6071 3.732 1190 NPHI 15.96 35.72 23.963 1189 FCNT 292.96 991.94 595.068 1189 NCNT 24701.5 45390.7 37031 1189 RHOB 2.1947 2.8787 2.3972 1189 DRHO -0.081 0.593 0.0699178 1189 PEF 1.0929 8.9619 2.87678 1189 First Reading 17091.5 17136.5 17143.5 17143.5 17143.5 17143.5 17177.5 17143.5 17091.5 17091.5 17091.5 17107.5 17107.5 17107.5 Last Reading 17775.5 17731 17738 17738 17738 17738 17775.5 17738 17685.5 17685.5 17685.5 17701.5 17701.5 17701.5 First Reading For Entire File .......... 17091.5 Last Reading For Entire File ........... 17775.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 26 VENDOR TOOL CODE START DEPTH NPHI FCNT NCNT PEF DRHO RHOB GR FET RPD RPM RPS RPX RAT LOG HE3~DER DATA DATE LOGGED: SOFTWARE 16813 0 16813 0 16813 0 16830 0 16830 0 16830 0 16859 5 16866 0 16866 0 16866 0 16866 0 16866.0 16901.5 SURF%CE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR RE_AL-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 17414.5 17414.5 17414.5 17430.0 17430.0 17430.0 17456.5 17414.5 17414.5 17461.5 17461.5 17461.5 17499.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHM]V~) AT TEMPERATURE (DEGF) MUD AT MFJ~SURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERlV[PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 29-APR- 98 ISC 5.07 CIM 5.46 MEMORY 17775.O 17175.0 17775.0 61.5 66.3 TOOL NUMBER P0980SP4 P0980SP4 P0980SP4 P0980SP4 6.000 6.0 LSND 10.20 63.0 9.5 5OO 2.6 1. 000 .514 .890 1. 950 70.0 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 ...................... -999.25. Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 26 API 4 1 68 RPX MAD 26 OHMM 4 1 68 RP S MAD 26 OHMM 4 1 68 RPM MAD 26 OHMM 4 1 68 RPD MAD 26 OHMM 4 1 68 RAT MAD 26 FT/H 4 1 68 FET MAD 26 HOUR 4 1 68 NPHI MAD 26 P.U. 4 1 68 FCNT MAD 26 CNTS 4 1 68 NCNT MAD 26 CNTS 4 1 68 RHOB MAD 26 G/CC 4 1 68 DRHO MAD 26 G/CC 4 1 68 PEF MAD 26 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPX RPS RPM RPD RAT FET NPHI FCNT NCNT RHOB DRHO PEF Min 16813 11 7291 1 4387 2 2004 2 6502 3 5603 21 3419 27 5148 8 269.41 25942.4 2.1065 -0.06 1.2598 Max Mean 17499 17156 183.548 45.5401 134.702 29.1027 85.2691 27.7206 78.2159 28.8732 80.8101 32.9446 4521.09 222.949 92.8664 60.0858 38.58 19.6717 2413.28 930.762 57446.2 41604.5 3.0187 2.39849 0.7579 0.0612264 8.324 3.09204 Nsam 1373 1195 1192 1192 1192 1192 1196 1192 1202 1202 1202 1201 1201 1201 First Reading 16813 16859.5 16866 16866 16866 16866 16901.5 16866 16813 16813 16813 16830 16830 16830 Last Reading 17499 17456.5 17461.5 17461.5 17461.5 17461.5 17499 17461.5 17413.5 17413.5 17413.5 17430 17430 17430 First Reading For Entire File .......... 16813 Last Reading For Entire File ........... 17499 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Mon Jun 15 17:38:25 1998 Reel Header Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER ENDICOTT MPI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-M~-80134 M. HANIK J. CARLILE Anohorag..e 2-56A/PB2 500292286371 BP EXPLORATION (ALASKA) , INC. SPERRY-SUN DRILLING SERVICES 15-JUN-98 MWD RUN 4 AK-M~-80134 M. HANIK J. CARLILE MWD RUN 5 AK-MM-80134 J. MARTIN J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MM-80134 M. GABEL E. VAUGHN MWD RUN 23 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 24 AK-MM-80134 M. HANIK J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 25 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 26 AK-MM-80134 G. TOBIAS J. CARLILE MWD RUN 26 AK-MM-80134 G. TOBIAS J. CARLILE SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 36 12N 16E 3193 2333 .00 54.70 14.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 30.000 80.0 12.250 9.625 7079.0 8.500 7.000 15958.0 6.000 17775.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 3-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUNS 20 THRU 22, 27 AND 28 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 5. MWD RUN 23 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. 6. MWD RUNS 24 THRU 26 ARE DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO DENSITY (SLD) . 7. MWD DATA FROM 16812'MD TO 17499'MD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE RUNNING IN THE HOLE AFTER MWD RUN 26. 8. MWD RUNS 1-5, 20-26,REPRESENT WELL 2-56A/PB2 WITH API#: 50-029-22863-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17775'MD, 10064'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 SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY- SANDSTONE MATRIX FIXED HOLE SIZE TNPS = COMPENSATED THERMAL NEUTRON POROSITY. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR COUNT RATES (CNP). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR COUNT RATES (CNP). CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR COUNT RATES (CTN). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR COUNT RATES (CTN). SBDC = SMOOTHED BULK DENSITY-COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTELECTRIC ABSORPTION FACTOR. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL FACTORS USED IN PROCESSING NUCLEAR LOG DATA: HOLE SIZE: 8.5" & 6" FIXED MUD WEIGHT: 9.8-10.2 PPG MUD FILTRATE SALINITY: 600 PPM CL FORMATION WATER SALINITY: 11500 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC MATRIX: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX PEF DRHO RHOB FCNT NCNT NPHI $ Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 START DEPTH 7044 0 7088 0 15678 5 15678 5 15678 5 15678 5 15678 5 15696 0 15696 0 15696.0 16366.5 16366.5 16366.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 17731.0 17775.5 17738.0 17738.0 17738.0 17738 0 17738 0 17701 5 17701 5 17701 5 17685 5 17685 5 17685 5 BASELINE DEPTH GR 7044.0 7058.0 15944.0 15958.0 15958.5 15958.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 ~D 5 MWD 6 ~D 23 MWD 24 MWD 25 MWD 26 REMARKS: MERGED MAIN PASS. $ EQUIVALENT UNSHIFTED DEPTH MERGE 7100 10212 11873 15692 16333 16674 16840 17175 TOP MERGE BASE 0 10212.0 0 11873.0 0 15958.0 0 15958.0 0 16674.0 0 16840.0 0 17175.0 0 17775.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHM}4 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 7044 17775.5 ROP 3.4021 4717.97 GR 4.4011 429.412 RPX 0.5989 2000 RPS 0.4048 2000 RPM 0.3804 2000 Mean Nsam 12409.8 21464 103.595 21376 77.1864 20717 22.9096 3146 24.1908 3146 28.7305 3146 First Reading 7044 7088 7044 15678.5 15678.5 15678.5 Last Reading 17775.5 17775.5 17731 17738 17738 17738 RPD 0.5587 2000 30.3839 3146 FET 1.0977 68.1264 16.574 3146 RHOB 2.072 3.0668 2.42473 3112 DRHO -0.115 0.8208 0.0860827 3112 PEF 1.0929 10.2362 3.3627 3112 NPHI 8.2 58.83 23.1161 2639 NCNT 634.42 57423.6 35179.2 2639 FCNT 3.94 2403.94 761.694 2639 15678.5 15678.5 15696 15696 15696 16366.5 16366.5 16366.5 17738 17738 17701.5 17701.5 17701.5 17685.5 17685.5 17685.5 First Reading For Entire File .......... 7044 Last Reading For Entire File ........... 17775.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR RPX RPS RPM RPD FET RAT $ .5000 START DEPTH 16813.0 16813 0 16813 0 16830 0 16830 0 16830 0 16859 5 16866 0 16866 0 16866 0 16866 0 16866 0 16901 5 STOP DEPTH 17414.5 17414.5 17414.5 17430.0 17430.0 17430.0 17456.5 17461.5 17461.5 17461.5 17461.5 17461.5 17499.0 MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: MAD RUN NO. MAD PASS NO. 26 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 17175.O Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 NPHI MAD P.U. 4 1 68 FCNT MAD CTS/ 4 1 68 NCNT MAD CTS/ 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHM~ 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 RAT MAD FT/H 4 1 68 FET MAD HOUR 4 1 68 RHOB MAD G/CC 4 1 68 DRHO MAD G/CC 4 1 68 PEF MAD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 MERGE BASE 17775.0 Name DEPT NPHI FCNT NCNT GR RPX RPS RPM RPD RAT FET RHOB DRHO PEF Min 16813 8 269.41 25942.4 11 7291 1 4387 2 2004 2 6502 3 5603 21 3419 27 5148 2 1065 -0.06 1.2598 Max Mean 17499 17156 38.58 19.6792 2413.28 930.231 57446.2 41600.4 183.548 45.5401 134.702 29.1027 85.2691 27.7206 78.2159 28.8732 80.8101 32.9446 4521.09 223.03 92.8664 60.0858 3.0187 2.39849 0.7579 0.0612264 8.324 3.09204 Nsam 1373 1204 1204 1204 1195 1192 1192 1192 1192 1195 1192 1201 1201 1201 First Reading 16813 16813 16813 16813 16859.5 16866 16866 16866 16866 16901.5 16866 16830 16830 16830 Last Reading 17499 17414.5 17414.5 17414.5 17456.5 17461.5 17461.5 17461.5 17461.5 17499 17461.5 17430 17430 17430 First Reading For Entire File .......... 16813 Last Reading For Entire File ........... 17499 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7058.0 10167.5 ROP 7102.0 10211.5 LOG HEADER DATA DATE LOGGED: 27-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10212.0 TOP LOG INTERVAL (FT) : 7100.0 BOTTOM LOG INTERVAL (FT) : 10212.0 BIT ROTATING SPEED {RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 59.6 MAXIMUM ANGLE: 63.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0956CG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.50 45.0 9.6 1600 5.4 .000 .000 · 000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 42,2 First Name Min Max Mean Nsam Reading DEPT 7058 10211.5 8634.75 6308 7058 ROP 6.5739 377.227 146.525 6220 7102 GR 4.4011 127.552 67.5197 6220 7058 Last Reading 10211.5 10211.5 10167.5 First Reading For Entire File .......... 7058 Last Reading For Entire File ........... 10211.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10169.0 ROP 10213.5 $ 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 11829.5 11872.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 01-MAR-98 ISC 5.07 CIM 5.46 MEMORY 11873.0 10212.0 11873.0 58.7 62.2 TOOL NUMBER P0956CG6 8.500 8.5 LSND 9.60 46.0 9.4 1300 4.8 MUD AT MEASURED TEM?E~TU~E (MT): MUD ~T M~X CIRCULATING TEPd~?EP~TURE: MUD FILTRATE ~T MT: MUD C~KE ~T 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 · 000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 44.2 First Name Min Max Mean Nsam Reading DEPT 10169 11872 11020.5 3407 10169 ROP 6.4328 419.093 128.969 3318 10213.5 GR 22.2284 122.499 66.6233 3322 10169 Last Reading 11872 11872 11829.5 First Reading For Entire File .......... 10169 Last Reading For Entire File ........... 11872 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11830.0 ROP 11874.5 $ 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 15957.5 15957.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA~/~ARAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G}: MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 06-MAR-98 ISC 5.07 CIM 5.46 MEMORY 16020.0 11873.0 16020.0 38.8 61.1 TOOL NUMBER P0956CG6 8.500 8.5 LSND 10.00 48.0 9.4 1000 4.4 .000 .000 · 000 .000 51.7 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 AP1 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11830 15957.5 13893.8 8256 11830 ROP 6.3024 2344.92 91.1815 8167 11874.5 GR 19.3321 216.163 86.3957 8256 11830 Last Reading 15957.5 15957.5 15957.5 First Reading For Entire File .......... 11830 Last Reading For Entire File ........... 15957.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUM~ARY VENDOR TOOL CODE START DEPTH FET 15692 5 RPD 15692 5 RPD 15692 5 RPS 15692 5 RPX 15692 5 FCNT 15701 0 NCNT 15701 0 NPHI 15701 0 PEF 15710 0 DRHO 15710 0 RHOB 15710 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL {FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: STOP DEPTH 15958.0 15958.0 15958.0 15958.0 15958.0 15958 0 15958 0 15958 0 15958 0 15958 0 15958 0 07-MAR- 98 ISC 5.07 CIM 5.46 MEMORY 16465.0 16020.0 16465.0 25.7 35.0 TOOL NUMBER P0969CRNLG6 P0969CRNLG6 P0969CRNLG6 P0969CRNLG6 8.500 8.5 LSND 10.20 500.0 9.5 8OO 3.6 2.000 1.060 62.8 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1.650 2.600 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MWD 6 OHMM 4 1 68 4 2 RPS MWD 6 OHM~ 4 t 68 8 3 RPM MWD 6 OHMM 4 1 68 12 4 RPD MWD 6 OHMM 4 1 68 16 5 FET MWD 6 HOUR 4 1 68 20 6 NPHI MWD 6 P.U. 4 1 68 24 7 NCNT MWD 6 CNTS 4 1 68 28 8 FCNT MWD 6 CNTS 4 1 68 32 9 RHOB MWD 6 G/CC 4 1 68 36 10 DRHO MWD 6 G/CC 4 1 68 40 11 PEF MWD 6 BARN 4 1 68 44 12 Name DEPT RPX RPS RPM RPD FET NPHI NCNT FCNT RHOB DRHO PEF Min 15692.5 1 1302 1 1329 1 1709 0 9799 28 2892 27 9452 2160 571 2.1347 -0.088 1.1811 Max 15958 9 0436 8 9429 10 6446 8 7769 39 4337 81 7622 3216 843 2.6876 0.6206 7.1654 Mean Nsam 15825.2 532 3.61111 532 3.73782 532 3.74694 532 3.7106 532 34.2415 532 53.6982 515 2602.23 515 681.737 515 2.46788 497 0.104896 497 3.22188 497 First Reading 15692 5 15692 5 15692 5 15692 5 15692 5 15692 5 15701 15701 15701 15710 15710 15710 Last Reading 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 First Reading For Entire File .......... 15692.5 Last Reading For Entire File ........... 15958 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Con~nent Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 23 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 16271.0 ROP 16335.5 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (F?) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION {DEG 16610.5 16674.0 22-APR-98 ISC 5.07 CIM 5.46 MEMORY 16674.0 16333.0 16674.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 35.7 61.0 TOOL NUMBER PCG 47 6. 000 6.0 LSND 10.10 51.0 9.0 600 2.9 .000 .000 .000 .000 53.9 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 23 API 4 1 68 4 2 ROP MWD 23 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 16271 16674 16472.5 807 16271 GR 35.6856 429.412 196.783 680 16271 ROP 3.4021 270.201 19.8749 678 16335.5 Last Reading 16674 16610.5 16674 First Reading For Entire File .......... 16271 Last Reading For Entire File ........... 16674 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 24 .5000 START DEPTH 16366.5 16366.5 16366.5 16394 5 16394 5 16394 5 16431 0 16431 0 16431 0 16431 0 16431 0 16611 0 16642 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : STOP DEPTH 16755.5 16755.5 16755.5 16771.5 16771.5 16771.5 16808.0 16808.0 16808.0 16808.0 16808.0 16801.0 16839.5 2 4 -AP R- 9 8 ISC 5.07 CIM 5.46 MEMORY 16840.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 16674.0 16840.0 63.3 64.6 TOOL NUMBER P0997SP4 P0997SP4 P0997SP4 P0997SP4 6.000 6.0 LSND 10.20 52.0 9.2 5OO 2.8 1.200 .725 1.050 · 950 58.3 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 24 API 4 1 68 4 2 RPX MWD 24 OHMM 4 1 68 8 3 RPS MWD 24 OHMM 4 1 68 12 4 RPM MWD 24 RPD MWD 2 ~ ROP MWD 24 FF, T MWD 24 NPHI MWD 24 FCNT MWD 24 NCNT MWD 24 RHOB MWD 24 DRHO MWD 24 PEF MWD 24 OHMM 4 1 68 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 P.U. 4 1 68 CNTS 4 1 68 CNTS 4 1 68 G/CC 4 1 68 G/CC 4 1 68 BARN 4 1 68 16 20 24 28 32 36 40 44 48 52 5 6 7 8 9 10 11 12 13 14 Name DEPT GR RPX RPS RPM RPD ROP FET NPHI FCNT NCNT RHOB DRHO PEF Min 16366.5 16 3021 3 0724 3 0749 3 1619 2 7894 6 7889 2 1276 8.2 3.94 634.42 2. 072 -0. 115 1.2767 Max Mean Nsam 16839.5 16603 947 111.675 50.5422 381 67.3997 19.5774 755 2000 25.995 755 2000 43.3788 755 2000 41.4159 755 4717.97 113.36 396 68.1264 34.7053 755 58.83 29.1624 779 2403.94 606.981 779 57423.6 24153.9 779 3.0668 2.47811 755 0.8208 0.142545 755 10.2362 4.64896 755 First Reading 16366.5 16611 16431 16431 16431 16431 16642 16431 16366.5 16366.5 16366.5 16394.5 16394.5 16394.5 Last Reading 16839.5 16801 16808 16808 16808 16808 16839.5 16808 16755.5 16755.5 16755.5 16771.5 16771.5 16771.5 First Reading For Entire File .......... 16366.5 Last Reading For Entire File ........... 16839.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maxiraum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 25 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 16757 0 NCNT 16757 0 NPHI 16757 0 PEF 16772 5 DRHO 16772 5 RHOB 16772 5 GR 16802 FET 16808 RPD 16808 RPM 16808 RPS 16808 RPX 16808 ROP 16841 STOP DEPTH 17091 0 17091 0 17091 0 17106 5 17106 5 17106 5 17136 0 17143.0 17143.0 17143.0 17143.0 17143.0 17175.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~MMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 26-APR-98 ISC 5.07 CIM 5.46 MEMORY 17175.0 16840.0 17175.0 56.0 64.6 TOOL NUMBER P0997SP4 P0997S~4 P0997SP4 P0997SP4 6.000 6.0 LSND 10.20 61.0 9.3 5OO 2.8 1.500 .642 1.000 1.100 70.5 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DE?T FT 4 1 68 GR MWD 25 API 4 1 68 RPX MWD 25 OHMM 4 1 68 RPS MWD 25 OHMM 4 1 68 RPM MWD 25 OHM~ 4 1 68 RPD MWD 25 OHMM 4 1 68 ROP MWD 25 FT/H 4 1 68 FET MWD 25 HOUR 4 1 68 NPHI MWD 25 P.U. 4 1 68 FCNT MWD 25 CNTS 4 1 68 NCNT MWD 25 CNTS 4 1 68 RHOB MWD 25 G/CC 4 1 68 DRHO MWD 25 G/CC 4 1 68 PEF MWD 25 BARN 4 1 68 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPX RPS RPM RPD ROP FET NPHI FCNT NCNT RHOB DRHO PEF Min 16757 15 2194 0 5989 0 4048 0 3804 0 5587 4 4676 1 4801 8.95 386.08 29317.9 2.1242 -0.078 1.2748 Max 17175 125.161 2000 2000 214.266 2000 264.253 27.9357 29.62 2113.63 54502.2 2.7643 0.1631 5.8077 Mean 16966 33 0094 40 8217 39 2853 41 2228 48 1748 22 7968 4.94021 14.6082 1240.09 44826.1 2.38127 0.0372224 2.87905 First Last Nsam Reading Reading 837 16757 17175 669 16802 17136 670 16808.5 17143 670 16808.5 17143 670 16808.5 17143 670 16808.5 17143 668 16841.5 17175 670 16808.5 17143 669 16757 17091 669 16757 17091 669 16757 17091 669 16772.5 17106.5 669 16772.5 17106.5 669 16772.5 17106.5 First Reading For Entire File .......... 16757 Last Reading For Entire File ........... 17175 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 26 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 17091.5 NCNT 17091.5 NPHI 17091.5 PEF 17107.5 DRHO 17107.5 RHOB 17107.5 GR 17136.5 FET 17143.5 RPD 17143.5 RPM 17143.5 RPS 17143.5 RPX 17143.5 ROP 17177.5 $ 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) : STOP DEPTH 17685 5 17685 5 17685 5 17701 5 17701 5 17701 5 17731 0 17738 0 17738 0 17738 0 17738 0 17738 0 17775 5 29-APR-98 ISC 5.07 CIM 5.46 MEMORY 17775.0 17175.O 17775.O BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~ RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 61.5 66.3 TOOL NUMBER P0980SP4 P0980SP4 P0980SP4 P0980SP4 6.000 6.0 LSND 10.20 63.0 9.5 5OO 2.6 1.000 .514 .890 1.950 70.0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 26 API 4 1 68 4 2 RPX MWD 26 OHMM 4 1 68 8 3 RPS MWD 26 OHM~ 4 1 68 12 4 RPM MWD 26 OHMM 4 1 68 16 5 RPD MWD 26 OHMM 4 1 68 20 6 ROP Fg~D 26 FT/H 4 1 68 FET MWD 26 HOUR 4 1 68 NPHI MWD 26 P.U. 4 1 68 FCNT MWD 26 CNTS 4 1 68 NCNT MWD 26 CNTS 4 1 68 RHOB MWD 26 G/CC 4 1 68 DRHO MWD 26 G/CC 4 1 68 PEF MWD 26 BARN 4 1 68 24 28 32 36 4O 44 48 52 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 17091.5 17775.5 17433.5 1369 GR 15.686 192.03 58.2633 1190 RPX 4.4891 77.0221 23.5497 1190 RPS 3.5994 67.0217 23.6737 1190 RPM 3.0292 67.2085 23.5511 1190 RPD 3.9995 73.9244 25.2698 1190 ROP 4.5579 234.7 28.6492 1197 FET 1.0977 27.6071 3.732 1190 NPHI 15.96 35.72 23.963 1189 FCNT 292.96 991.94 595.068 1189 NCNT 24701.5 45390.7 37031 1189 RHOB 2.1947 2.8787 2.3972 1189 DRHO -0.081 0.593 0.0699178 1189 PEF 1.0929 8.9619 2.87678 1189 First Reading 17091 5 17136 5 17143 5 17143 5 17143 5 17143 5 17177 5 17143 5 17091 5 17091 5 17091 5 17107 5 17107 5 17107 5 Last Reading 17775.5 17731 17738 17738 17738 17738 17775.5 17738 17685 5 17685 5 17685 5 17701 5 17701 5 17701 5 First Reading For Entire File .......... 17091.5 Last Reading For Entire File ........... 17775.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: FILE SUMMARY .5000 26 VENDOR TOOL CODE START DEPTH NPHI 16813.0 FCNT 16813.0 NCNT 16813.0 PEF 16830.0 DRHO 16830.0 RHOB 16830.0 GR 16859.5 FET 16866.0 RPD 16866.0 RPM 16866.0 RPS 16866.0 RPX 16866.0 RAT 16901.5 $ 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: NLAXIMUMANGLE: STOP DEPTH 17414 5 17414 5 17414 5 17430 0 17430 0 17430 0 17456 5 17414 5 17414 5 17461 5 17461 5 17461 5 17499 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MIlD AT NLAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 29-APR-98 ISC 5.07 ClM 5.46 MEMORY 17775.0 17175.0 17775.0 61.5 66.3 TOOL NUMBER P0980SP4 P0980SP4 P0980SP4 P0980SP4 6.000 6.0 LSND 10.20 63.0 9.5 5OO 2.6 1.000 .514 .890 1.950 70.0 NEUTRON TOOL M~TRIX: M~TRIX 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MAD 26 API 4 1 68 4 2 RPX MAD 26 OHM~ 4 1 68 8 3 RPS MAD 26 OHMM 4 1 68 12 4 RPM MAD 2 6 OHMM 4 1 68 16 5 RPD MAD 26 OHMM 4 1 68 20 6 RAT MAD 26 FT/H 4 1 68 24 7 FET MAD 26 HOUR 4 1 68 28 8 NPHI MAD 26 P.U. 4 1 68 32 9 FCNT MAD 26 CNTS 4 1 68 36 10 NCNT MAD 26 CNTS 4 1 68 40 11 RHOB MAD 26 G/CC 4 1 68 44 12 DRHO MAD 26 G/CC 4 1 68 48 13 PEF MAD 26 BARN 4 1 68 52 14 Name DEPT GR RPX RPS RPM RPD RAT FET NPHI FCNT NCNT RHOB DRHO PEF Min 16813 11 7291 1 4387 2 2004 2 6502 3 5603 21 3419 27 5148 8 269.41 25942.4 2.1065 -0.06 1.2598 First Max Mean Nsam Reading 17499 17156 1373 16813 183.548 45.5401 1195 16859.5 134.702 29.1027 1192 16866 85.2691 27.7206 1192 16866 78.2159 28.8732 1192 16866 80.8101 32.9446 1192 16866 4521.09 222.949 1196 16901.5 92.8664 60.0858 1192 16866 38.58 19.6717 1202 16813 2413.28 930.762 1202 16813 57446.2 41604.5 1202 16813 3.0187 2.39849 1201 16830 0.7579 0.0612264 1201 16830 8.324 3.09204 1201 16830 Last Reading 17499 17456.5 17461.5 17461.5 17461.5 17461.5 17499 17461.5 17413.5 17413.5 17413.5 17430 17430 17430 First Reading For Entire File .......... 16813 Last Reading For Entire Pile ........... 17499 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Mon Jul 20 11:00:06 1998 Reel Header Service name ............. LISTPE Date ..................... 98/07/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/07/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Coraments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Corament Record TAPE HEADER ENDICOTT MPI M?~D/MAD LOGS WELL N~E: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-80134 M. HANIK J. CARLILE 2-56A/EIDER-01 500292286301 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 20-JUL-98 MWD RUN 4 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 5 AK-MM-80134 J. MARTIN J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: MWD RUN 32 AK-M~-80134 M. WORDEN E. VAUGHN MWD RUN 33 AK-MM-80134 R. MCNEILL J. CARLILE 36 12N 16E 3193 2333 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD .00 54.70 14.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 30.000 80.0 2ND STRING 12.250 9. 625 7079.0 3RD STRING 8.500 7.000 15958.0 PRODUCTION STRING 6.000 17988.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 3-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUN 29 DID NOT REACH BOTTOM AND IS NOT PRESENTED, AND RUNS 30 AND 31 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 5. MWD RUNS 32 AND 33 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GIEGER MEULLER TUBE DETECTORS AND SLIMHOLE ELECTORMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. RESISTIVITY DATA FROM 15692'MD, 8829'TVD TO 15958'MD, 9025'TVD WAS OBTAINED ON A MEASUREMENT AFTER DRILLING (MAD) PASS WHILE RUNNING IN THE HOLE FOR MWD RUN 6. THIS DATA IS PRESENTED ALTHOUGH MWD RUN 6 WAS NOT MADE IN THIS BOREHOLE. RESISTIVITY DATA FROM 16458'MD, 9329'TVD TO 16719'MD, 9461'TVD WAS OBTAINED ON A MAD PASS WHILE REAMING IN THE HOLE PRIOR TO MWD RUN 32. 7. MWD RUNS 3-5&30-33 REPRESENT WELL 2-56A/EIDER-01 WITH API~:50-029-22863-01. THIS WELL REACHED A TOTAL DEPTH {TD) OF 17988'MD, 10007'TVD. SROP = SMOOTHED RATE OF PENETRATION. 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. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH 7044 0 7O88 0 15678 5 15678 5 15678 5 15678 5 15678 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 7O44.0 15944.0 15958.5 $ MERGED DATA SOURCE PBU TOOL CODE M?~D MWD MWD MWD MWD $ REMARKS: GR 7058.0 15958.0 15958.5 STOP DEPTH 17945 5 17988 0 17952 5 17952 5 17952 5 17952 5 17952 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP 3 7100 0 4 10212 0 5 11873 0 6 15692 0 32 16458 0 33 17648 0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 10212 0 11873 0 15958 0 15958 0 17648 0 17988 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR M~D RPX RPS MWD RPM l~D RPD MWD FET MWD API OHMM OHMM OHMM OHMM HOUR 1 68 1 68 1 68 1 68 1 68 1 68 8 12 16 20 24 28 Name DEPT ROP GR RPX RPS RPM RPD FET Min 7044 2 2787 4 4011 0 5579 1 1329 1 1709 0 9799 0 2999 Max 17988 2344.92 588.007 2000 665.33 2000 2000 60.7285 Mean Nsam 12516 21889 102.96 21801 82 3946 20865 22 7347 3597 23 7656 3597 28 8036 3597 37 1147 3597 16 6024 3597 First Reading 7044 7088 7044 15678.5 15678.5 15678.5 15678.5 15678.5 Last Reading 17988 17988 17945 5 17952 5 17952 5 17952 5 17952 5 17952 5 First Reading For Entire File .......... 7044 Last Reading For Entire File ........... 17988 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7058.0 10167.5 ROP 7102.0 10211.5 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: MA~XIMUMANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA~94A RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA/~DOFF (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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 27-FEB-98 ISC 5.07 CIM 5.46/SP4 5.03/DEPII 2.22A MEMORY 10212.0 7100.0 10212.0 59.6 63.1 TOOL NUMBER P0956CG6 8.500 8.5 LSND 9.50 45.0 9.6 1600 5.4 .000 .000 .000 · 000 42.2 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7058 10211.5 8634.75 6308 7058 ROP 6.5739 377.227 146.525 6220 7102 GR 4.4011 127.552 67.5197 6220 7058 Last Reading 10211.5 10211.5 10167.5 First Reading For Entire File .......... 7058 Last Reading For Entire File ........... 10211.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUI~KARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10169.0 11829.5 ROP 10213.5 11872.0 $ LOG HEADER DATA DATE LOGGED: 01-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): ISC 5.07 CIM 5.46/SP4 5.03/DEPII 2.22A MEMORY TD DRILLER (FT): TOP LOG INTERVAL {FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMH) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frarae Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 11873.0 10212.0 11873.0 58.7 62.2 TOOL NUMBER P0956CG6 8.500 8.5 LSND 9.60 46.0 9.4 1300 4.8 .000 .000 .000 .000 44.2 Narae Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP Ng~D 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 Name Min Max Mean DEPT 10169 11872 11020.5 ROP 6.4328 419.093 128.969 GR 22.2284 122.499 66.6233 First Last Nsam Reading Reading 3407 10169 11872 3318 10213.5 11872 3322 10169 11829.5 First Reading For Entire File .......... 10169 Last Reading For Entire File ........... 11872 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUM}{ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11830.0 15957.5 ROP 11874.5 15957.5 $ LOG HEADER DATA DATE LOGGED: 06-PLAR-98 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: 38.8 MAXIMUM ANGLE: 61.1 ISC 5.07 CIM 5.46/SP4 5.03/DEPII 2.22A MEMORY 16020.0 11873.0 16020.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMH) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : RE?4ARKS: $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P0956CG6 8.500 8.5 LSND 10.00 48.0 9.4 1000 4.4 .000 .000 .000 .000 51.7 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 API 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11830 15957.5 13893.8 8256 11830 ROP 6.3024 2344.92 91.1815 8167 11874.5 GR 19.3321 216.163 86.3957 8256 11830 Last Reading 15957.5 15957.5 15957.5 First Reading For Entire File .......... 11830 Last Reading For Entire File ........... 15957,5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0,0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB,005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMPUkRY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 15692.5 15958.0 RPD 15692.5 15958.0 RPM 15692.5 15958.0 RPS 15692.5 15958.0 RPX 15692.5 15958.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY 07-MAR-98 ISC 5.07 CIM 5.46/SP4 5.03/DEPII 2.22A MFJ, IORY 16465.0 16020.0 16465.0 25.7 35.0 TOOL NUMBER P0969CRNLG6 EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P09o 8.500 8.5 LSND 10.20 500.0 9.5 8OO 3.6 2.000 1.060 1.650 2. 600 .-.% Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPX MWD 6 OHMS! 4 1 68 4 2 RPS MWD 6 OHMM 4 1 68 8 3 RPM MWD 6 OKMM 4 1 68 12 4 RPD MWD 6 OHMM 4 1 68 16 5 FET MWD 6 HOUR 4 1 68 20 6 First Name Min Max Mean Nsam Reading DEPT 15692.5 15958 15825.2 532 15692.5 RPX 1.1302 9.0436 3.61111 532 15692.5 RPS 1.1329 8.9429 3.73782 532 15692.5 RPM 1.1709 10.6446 3.74694 532 15692.5 RPD 0.9799 8.7769 3.7106 532 15692.5 Last Reading 15958 15958 15958 15958 15958 FET 28.2892 39,4337 34.2415 532 15692,5 15958 First Reading For Entire File .......... 15692.5 Last Reading For Entire File ........... 15958 File Trailer Service name ............. STSLiB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 32 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 16413.5 17602.5 FET 16420.0 17609.5 RPD 16420.0 17609.5 RPM 16420.0 17609.5 RPS 16420.0 17609.5 RPX 16420.0 17609.5 ROP 16719.0 17647.0 $ LOG HEADER DATA DATE LOGGED: 13-P~Y-98 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: 63.7 ISC 5.07 CIM 5.46/SP4 5.03/DEPII 2.22A MF24ORY 17648.0 16458.0 17648.0 MAXIMUM ANGLE: 68.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROPtAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TE~4PERATURE: 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P0980SP4 P0980SP4 6.000 .0 10.60 49.0 9.0 31000 1.8 · 160 .000 ·120 ·190 75.5 · 6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 32 API 4 I 68 4 2 RPX MWD 32 OHMM 4 1 68 8 3 RPS MWD 32 OHMM 4 1 68 12 4 RPM MWD 32 OHMM 4 1 68 16 5 RPD MWD 32 OHMM 4 1 68 20 6 ROP MWD 32 FT/H 4 i 68 24 7 FET MWD 32 HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 16413.5 17647 17030.2 2468 GR 20.6791 588.007 137.001 2379 RPX 0.5579 2000 28.9047 2380 RPS 1.1833 665.33 28.9506 2380 RPM 1.617 2000 35.9936 2380 RPD 3.0195 2000 47.8506 2380 ROP 2.2787 305.859 50.7389 1857 FET 0.2999 54.3832 14.8344 2380 First Reading 16413.5 16413.5 16420 16420 16420 16420 16719 16420 Last Reading 17647 17602.5 17609.5 17609.5 17609.5 17609.5 17647 17609.5 First Reading For Entire File .......... 16413.5 Last Reading For Entire File ........... 17647 File Trailer Service name ............. STSLiB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Coherent Record FI LE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 33 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 17605.5 17945.5 17612.5 17952.5 17612.5 17952.5 17612.5 17952.5 17612.5 17952.5 17612.5 17952.5 17649.0 17988.0 17-MAY-98 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESiS, 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 5.07 CIM 5.46/SP4 5.03/DEPII 2.22A MEMORY 17988.0 17648.0 17988.0 54.5 63.1 TOOL NUMBER P0980SP4 P0980SP4 6,000 6.0 GEM 11.10 50.0 9.2 30000 1.4 .420 .320 .500 72.8 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 33 APi 4 1 68 4 2 RPX MWD 33 OHMM 4 1 68 RPS MWD 33 OHMM 4 1 68 RPM MWD 33 OHMM 4 1 68 RPD MWD 33 OHMM 4 1 68 ROP MWD 33 FT/H 4 1 68 FET MWD 33 HOUR 4 1 68 8 12 16 2O 24 28 Name Min Max Mean Nsam DEPT 17605.5 17988 17796.8 766 GR 12.987 173.959 56.341 681 R?X 4.1527 40.966 16.1617 681 RPS 4.2837 56.3161 21.2842 681 RPM 4.0472 61.6521 23.1806 681 RPD 4.0865 61.099 25.5752 681 RO? 2.9133 203.125 31.7631 679 FET 1.1304 60.7285 8.88244 681 First Reading 17605.5 17605.5 17612.5 17612.5 17612.5 17612.5 17649 17612.5 Last Reading 17988 17945.5 17952.5 17952.5 17952.5 17952.5 17988 17952.5 First Reading For Entire File .......... 17605.5 Last Reading For Entire File ........... 17988 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/07/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Set%ice name ............. LISTPE Date ..................... 98/07/20 Onigin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Mort Jun 15 17:38:25 1998 Reel Header Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Reel Narae ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ....... ~01 Previous Tape Name ....... ~UNKNOWN Cor~nents ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Com~nent Record TAPE HEADER ENDICOTT MPI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPA~qY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-80134 M. HANIK J. CARLILE 2-56A/PB2 500292286371 BP EXPLO~TION (A~S~), INC. SPERRY-SUN DRILLING SERVICES 15-JUN-98 MWD RUN 4 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 5 AK-MM-80134 J. MARTIN J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MM-80134 M. GABEL E. VAUGHN MWD RUN 23 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 24 AK-MM-80134 M. HANIK J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 25 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 26 AK-MM-80134 G. TOBIAS J. CARLILE MWD RUN 26 AK-M~-80134 G. TOBIAS J. CARLILE SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 36 12N 16E 3193 2333 .00 54.70 14.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 30.000 80.0 12.250 9.625 7079.0 8.500 7.000 15958.0 6.000 17775.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 3-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 4. MWD RUNS 20 THRU 22, 27 AND 28 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 5. NFWD RUN 23 IS DIRECTIONAL WITH NATURAL GT~MMA PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. 6. MWD RUNS 24 THRU 26 ARE DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO DENSITY (SLD). 7. MWD DATA FROM 16812'MD TO 17499'MD WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE RUNNING IN THE HOLE AFTER MWD RUN 26. 8. MWD RUNS 1-5, 20-26,REPRESENT WELL 2-56A/PB2 WITH API~: 50-029-22863-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17775'MD, 10064'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED SA/v~vlA 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 SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY- SANDSTONE MATRIX FIXED HOLE SIZE TNPS = COMPENSATED THERMAL NEUTRON POROSITY. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR COUNT RATES (CNP) . SNFA = SMOOTHED AVERAGE OF FAR DETECTOR COUNT RATES (CNP). CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR COUNT RATES (CTN). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR COUNT RATES (CTN). SBDC = SMOOTHED BULK DENSITY-COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTELECTRIC ABSORPTION FACTOR. SFPE = SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL FACTORS USED IN PROCESSING NUCLEAR LOG DATA: HOLE SIZE: 8.5" & 6" FIXED MUD WEIGHT: 9.8-10.2 PPG MUD FILTRATE SALINITY: 600 PPM CL FORMATION WATER SALINITY: 11500 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC MATRIX: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximura Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX PEF DRHO RHOB FCNT NCNT NPHI START DEPTH 7044.0 7088 0 15678 5 15678 5 15678 5 15678 5 15678 5 15696 0 15696 0 15696 0 16366 5 16366 5 16366 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 17731 0 17775 5 17738 0 17738 0 17738 0 17738 0 17738 0 17701 5 17701 5 17701 5 17685 5 17685 5 17685 5 BASELINE DEPTH GR 7044.0 7058.0 15944.0 15958.0 15958.5 15958.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 4 MWD 5 ~D 6 MWD 23 MWD 24 MWD 25 ~D 26 REMARKS: MERGED MAIN PASS. $ EQUIVALENT UNSHIFTED DEPTH MERGE 7100 10212 11873 15692 16333 16674 16840 17175 TOP 0 0 0 0 0 0 0 0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frarae Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 10212 0 11873 0 15958 0 15958 0 16674 0 16840 0 17175 0 17775 0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP I~D FT/H 4 1 68 GR I~D API 4 1 68 RPX MWD OHM~ 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT I~D CNTS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 7044 17775.5 ROP 3.4021 4717.97 GR 4.4011 429.412 RPX 0.5989 2000 RPS 0.4048 2000 RPM 0.3804 2000 Mean Nsam 12409.8 21464 103.595 21376 77.1864 20717 22.9096 3146 24.1908 3146 28.7305 3146 First Reading 7044 7088 7044 15678.5 15678.5 15678.5 Last Reading 17775.5 17775.5 17731 17738 17738 17738 R?D 0.5587 2000 30.3839 3146 FET 1.0977 68.1264 16.574 3146 RHOB 2,072 3.0668 2.42473 3112 DRHO -0.115 0.8208 0.0860827 3112 PEF 1.0929 10.2362 3.3627 3112 NPHI 8.2 58.83 23.1161 2639 NCNT 634.42 57423.6 35179.2 2639 FCNT 3,94 2403.94 761.694 2639 15678.5 15678.5 15696 15696 15696 16366.5 16366.5 16366.5 17738 17738 17701 5 17701 5 17701 5 17685 5 17685 5 17685 5 First Reading For Entire File .......... 7044 Last Reading For Entire File ........... 17775.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Corament Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR RPX RPS RPM RPD FET RAT $ .5000 START DEPTH 16813 0 16813 0 16813 0 16830 0 16830 0 16830 0 16859 5 16866 0 16866 0 16866 0 16866 0 16866 0 16901 5 STOP DEPTH 17414.5 17414 5 17414 5 17430 0 17430 0 17430 0 17456 5 17461 5 17461 5 17461 5 17461 5 17461 5 17499 0 MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: MAD RUN NO. MAD PASS NO. 26 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 17175.0 Name Service Order Units Size Nsam DEPT FT 4 1 68 NPHI MAD P.U. 4 1 68 FCNT MAD CTS/ 4 1 68 NCNT MAD CTS/ 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MuXD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 RAT MAD FT/H 4 1 68 FET MAD HOUR 4 1 68 RHOB MAD G/CC 4 1 68 DRHO MAD G/CC 4 1 68 PEF MAD BARN 4 1 68 Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 MERGE BASE 17775.0 Name DEPT NPHI FCNT NCNT GR RPX RPS RPM RPD RAT FET RHOB DRHO PEF Min 16813 8 269.41 25942.4 11 7291 1 4387 2 2004 2 6502 3 5603 21 3419 27 5148 2 1065 -0.06 1.2598 Max Mean 17499 17156 38.58 19.6792 2413.28 930.231 57446.2 41600.4 183.548 45.5401 134.702 29.1027 85.2691 27.7206 78.2159 28.8732 80.8101 32.9446 4521.09 223.03 92.8664 60.0858 3.0187 2.39849 0.7579 0.0612264 8.324 3.09204 Nsam 1373 1204 1204 1204 1195 1192 1192 1192 1192 1195 1192 1201 1201 1201 First Reading 16813 16813 16813 16813 16859.5 16866 16866 16866 16866 16901.5 16866 16830 16830 16830 Last Reading 17499 17414 5 17414 5 17414 5 17456 5 17461 5 17461 5 17461 5 17461 5 17499 17461.5 17430 17430 17430 First Reading For Entire File .......... 16813 Last Reading For Entire File ........... 17499 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date ef Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Corament Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7058.0 10167.5 ROP 7102.0 10211.5 LOG HEADER DATA DATE LOGGED: 27-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 10212.0 TOP LOG INTERVAL (FT) : 7100.0 BOTTOM LOG INTERVAL (FT) : 10212.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION {DEG MINIMUM ANGLE: 59.6 IqAXIMUM ANGLE: 63.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAM~A RAY P0956CG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frarae Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.50 45.0 9.6 1600 5.4 .000 · 000 · 000 · 000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 42.2 First Name Min Max Mean Nsam Reading DEPT 7058 10211.5 8634.75 6308 7058 ROP 6.5739 377.227 146.525 6220 7102 GR 4.4011 127.552 67.5197 6220 7058 Last Reading 10211.5 10211.5 10167.5 First Reading For Entire File .......... 7058 Last Reading For Entire File ........... 10211.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10169.0 ROP 10213.5 $ 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: M]tXIMUM ANGLE: STOP DEPTH 11829.5 11872.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 01-MAR-98 ISC 5.07 CIM 5.46 MEMORY 11873.0 10212.0 11873.0 58.7 62.2 TOOL NUMBER P0956CG6 8.5OO 8.5 LSND 9.60 46.0 9.4 1300 4.8 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 API 4 1 68 8 3 44.2 First Name Min Max Mean Nsam Reading DEPT 10169 11872 11020.5 3407 10169 ROP 6.4328 419.093 128.969 3318 10213.5 GR 22.2284 122.499 66.6233 3322 10169 Last Reading 11872 11872 11829.5 First Reading For Entire File .......... 10169 Last Reading For Entire File ........... 11872 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11830.0 ROP 11874.5 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 15957.5 15957.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~ RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHM}4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 06-~uXR-98 ISC 5.07 CIM 5.46 MEMORY 16020.0 11873.0 16020.0 38.8 61.1 TOOL NUMBER P0956CG6 8.500 8.5 LSND 10.00 48.0 9.4 1000 4.4 .000 .000 .000 .000 51.7 MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Forraat 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 AP1 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11830 15957.5 13893.8 8256 11830 ROP 6.3024 2344.92 91.1815 8167 11874.5 GR 19.3321 216.163 86.3957 8256 11830 Last Reading 15957.5 15957.5 15957.5 First Reading For Entire File .......... 11830 Last Reading For Entire File ........... 15957.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUI~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 15692 5 15958 0 RPD 15692 5 15958 0 RPD 15692 5 15958 0 RPS 15692 5 15958 0 RPX 15692 5 15958 0 FCNT 15701 0 15958 0 NCNT 15701 0 15958 0 NPHI 15701 0 15958 0 PEF 15710 0 15958 0 DRHO 15710 0 15958 0 RHOB 15710 0 15958 0 LOG HEADER DATA DATE LOGGED: 07-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 16465.0 TOP LOG INTERVAL (FT) : 16020.0 BOTTOM LOG INTERVAL (FT) : 16465.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 25.7 MAXIMUM ANGLE: 35.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GA_MM_A RAY P0969CRNLG6 EWR4 ELECTROMAG. RESIS. 4 P0969CRNLG6 CNP COMPENSATED NEUTRON P0969CRNLG6 SLD STABILIZED LITHO DEN P0969CRNLG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S) : 500.0 MUD PH: 9.5 MUD CHLORIDES (PPM) : 800 FLUID LOSS (C3) : 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.000 MUD AT MAX CIRCULATING TERMPERATURE: 1.060 62.8 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 Frarae Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1. 650 2. 600 Name Service Order Units Size Nsam DEPT FT 4 1 RPX MWD 6 OHMM 4 1 RPS I~D 6 OHMM 4 1 RPM MWD 6 OHMM 4 1 RPD MWD 6 OHMM 4 1 FET MWD 6 HOUR 4 1 NPHI M?~D 6 P.U. 4 1 NCNT M?~D 6 CNTS 4 1 FCNT MWD 6 CNTS 4 1 RHOB MWD 6 G/CC 4 1 DRHO MWD 6 G/CC 4 1 PEF MWD 6 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 Name DEPT RPX RPS RPM RPD FET NPHI NCNT FCNT RHOB DRHO PEF Min 15692.5 1 1302 1 1329 1 1709 0 9799 28 2892 27 9452 2160 571 2.1347 -0.088 1.1811 Max 15958 9 0436 8 9429 10 6446 8 7769 39 4337 81 7622 3216 843 2.6876 0.6206 7.1654 Mean Nsam 15825.2 532 3.61111 532 3.73782 532 3.74694 532 3.7106 532 34.2415 532 53.6982 515 2602.23 515 681.737 515 2.46788 497 0.104896 497 3.22188 497 First Reading 15692 5 15692 5 15692 5 15692 5 15692 5 15692 5 15701 15701 15701 15710 15710 15710 Last Reading 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 15958 First Reading For Entire File .......... 15692.5 Last Reading For Entire File ........... 15958 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/06/15 Maximura Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 23 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 16271.0 ROP 16335.5 $ 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 16610.5 16674.0 22-APR-98 ISC 5.07 CIM 5.46 MEMORY 16674.0 16333.0 16674.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GA14MA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datura Specification Block sub-type...0 35.7 61.0 TOOL NUMBER PCG 47 6.000 6.0 LSND 10.10 51.0 9.0 600 2.9 .000 .000 .000 .000 53.9 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR M~D 23 API 4 1 68 4 2 ROP HWD 23 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 16271 16674 16472.5 807 16271 GR 35.6856 429.412 196.783 680 16271 ROP 3.4021 270.201 19.8749 678 16335.5 Last Reading 16674 16610.5 16674 First Reading For Entire File .......... 16271 Last Reading For Entire File ........... 16674 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximura Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 24 DEPTH INCREMENT: .5000 FILE SUM~dARY VENDOR TOOL CODE START DEPTH FCNT NCNT NPHI PEF DRHO RHOB FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 16366 5 16366 5 16366 5 16394 5 16394 5 16394 5 16431 0 16431 0 16431 0 16431 0 16431 0 16611 0 16642 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : STOP DEPTH 16755 5 16755 5 16755 5 16771 5 16771 5 16771 5 16808 0 16808 0 16808 0 16808 0 16808 0 16801 0 16839 5 24-APR-98 ISC 5.07 CIM 5.46 MEMORY 16840.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STDdqDOFF (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 Frarae Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 16674.0 16840.0 63.3 64.6 TOOL NUMBER P0997SP4 P0997SP4 P0997SP4 P0997SP4 6.000 6.0 LSND 10.20 52.0 9.2 5OO 2.8 1.200 .725 1.050 .950 58.3 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 24 API 4 1 68 4 2 RPX MWD 24 OHMM 4 1 68 8 3 RPS MWD 24 OHMM 4 1 68 12 4 RPM MWD 24 RPD MWD 24 ROP MWD 24 FET MWD 24 NPHI MWD 24 FCNT MWD 24 NCNT MWD 24 RHOB MWD 24 DRHO MWD 24 PEF MWD 24 OHM~ 4 1 68 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 P.U. 4 1 68 CNT S 4 1 68 CNTS 4 1 68 G/CC 4 1 68 G/CC 4 1 68 BARN 4 1 68 16 2O 24 28 32 36 40 44 48 52 5 6 7 8 9 10 11 12 13 14 Name DEPT GR RPX RPS RPM RPD ROP FET NPHI FCNT NCNT RHOB DRHO PEF Min 16366.5 16 3021 3 0724 3 0749 3 1619 2 7894 6 7889 2 1276 8.2 3.94 634.42 2.072 -0.115 1.2767 Max Mean Nsam 16839.5 16603 947 111.675 50.5422 381 67.3997 19.5774 755 2000 25.995 755 2000 43.3788 755 2000 41.4159 755 4717.97 113.36 396 68.1264 34.7053 755 58.83 29.1624 779 2403.94 606.981 779 57423.6 24153.9 779 3.0668 2.47811 755 0.8208 0.142545 755 10.2362 4.64896 755 First Reading 16366.5 16611 16431 16431 16431 16431 16642 16431 16366.5 16366.5 16366.5 16394.5 16394.5 16394.5 Last Reading 16839.5 16801 16808 16808 16808 16808 16839.5 16808 16755 5 16755 5 16755 5 16771 5 16771 5 16771 5 First Reading For Entire File .......... 16366.5 Last Reading For Entire File ........... 16839.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 25 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT 16757 0 NCNT 16757 0 NPHI 16757 0 PEF 16772 5 DRHO 16772 5 RHOB 16772 5 GR 16802 0 FET 16808 5 RPD 16808 5 RPM 16808.5 RPS 16808.5 RPX 16808.5 ROP 16841.5 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAN/qA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES {PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 17091 0 17091 0 17O91 0 17106 5 17106 5 17106 5 17136 0 17143 0 17143 0 17143 0 17143 0 17143 0 17175 0 26-APR- 98 ISC 5.07 CIM 5.46 MEMORY 17175.0 16840.0 17175.0 56.0 64.6 TOOL NUMBER P0997SP4 P0997SP4 P0997SP4 P0997SP4 6.000 6.0 LSND 10.20 61.0 9.3 5OO 2.8 1.500 .642 1.000 1.100 70.5 NEUTRON TOOL I~ATRI X: 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR I~D 25 AP1 4 1 RPX I~D 25 OHMM 4 1 RPS MWD 25 OHMH 4 1 RPM MWD 25 OHMM 4 1 RPD MWD 25 OHMM 4 1 ROP MWD 25 FT/H 4 1 FET I~D 25 HOUR 4 1 NPHI MWD 25 P.U. 4 1 FCNT MWD 25 CNTS 4 1 NCNT MWD 25 CNTS 4 1 RHOB M?~D 25 G/CC 4 1 DRHO MWD 25 G/CC 4 1 PEF MWD 25 BARN 4 1 .0 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name DEPT GR RPX RPS RPM RPD ROP FET NPHI FCNT NCNT RHOB DRHO PEF Min 16757 15 2194 0 5989 0 4048 0 3804 0 5587 4 4676 1 4801 8.95 386.08 29317.9 2.1242 -0.078 1.2748 Max 17175 125.161 2000 2000 214.266 2000 264.253 27.9357 29.62 2113.63 54502.2 2.7643 0. 1631 5. 8077 Mean 16966 33.0094 40.8217 39.2853 41.2228 48.1748 22.7968 4.94021 14.6082 1240.09 44826.1 2.38127 0.0372224 2.87905 Nsam 837 669 670 670 670 670 668 670 669 669 669 669 669 669 First Reading 16757 16802 16808 5 16808 5 16808 5 16808 5 16841 5 16808 5 16757 16757 16757 16772.5 16772.5 16772.5 Last Reading 17175 17136 17143 17143 17143 17143 17175 17143 17091 17091 17091 17106.5 17106.5 17106.5 First Reading For Entire File .......... 16757 Last Reading For Entire File ........... 17175 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 26 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 17091.5 17091 5 17091 5 17107 5 17107 5 17107 5 17136 5 17143 5 17143 5 17143 5 17143 5 17143 5 17177 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 17685 5 17685 5 17685 5 177O1 5 17701 5 17701 5 17731 0 17738 0 17738 0 17738 0 17738 0 17738 0 17775 5 29-AP R- 98 ISC 5.07 CIM 5.46 MEMORY 17775.0 17175.0 17775.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 61.5 66.3 TOOL NUMBER P0980SP4 P0980SP4 P0980SP4 P0980SP4 6.000 6.0 LSND 10.20 63.0 9.5 5OO 2.6 1.000 .514 .890 1.950 70.0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 26 API 4 1 68 4 2 RPX MWD 26 OHMH 4 1 68 8 3 RPS MWD 26 OHMM 4 1 68 12 4 RPM MWD 26 OHM}{ 4 1 68 16 5 RPD MWD 26 OHMM 4 1 68 20 6 ROP MWD 26 FET MWD 26 NPHI lV~D 26 FCNT MWD 26 NCNT I~D 26 RHOB MWD 26 DRHO M-WD 26 PEF MWD 26 FT/H HOUR CNTS CNTS G/CC G/CC BARN 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 24 28 32 36 40 44 48 52 7 8 9 10 11 12 13 14 Name DEPT GR RPX RPS RPM RPD ROP FET NPHI FCNT NCNT RHOB DRHO PEF Min 17091.5 15. 686 4 4891 3 5994 3 0292 3 9995 4 5579 1 0977 15.96 292.96 24701.5 2.1947 -0.081 1.0929 Max 17775.5 192.03 77. 0221 67. 0217 67.2085 73.9244 234.7 27. 6071 35.72 991.94 45390.7 2.8787 Mean Nsam 17433.5 1369 58 2633 1190 23 5497 1190 23 6737 1190 23 5511 1190 25 2698 1190 28 6492 1197 3.732 1190 23.963 1189 595.068 1189 37031 1189 2.3972 1189 0.593 0.0699178 1189 8.9619 2.87678 1189 First Reading 17091.5 17136.5 17143.5 17143.5 17143 5 17143 5 17177 5 17143 5 17091 5 17091 5 17091 5 17107 5 17107 5 17107 5 Last Reading 17775.5 17731 17738 17738 17738 17738 17775.5 17738 17685 5 17685 5 17685 5 17701 5 17701 5 17701 5 First Reading For Entire File .......... 17091.5 Last Reading For Entire File ........... 17775.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maxiraura Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 IqAD RUN NUMBER: 26 MAD PASS NUMBER: FILE SUMMI~RY VENDOR TOOL CODE START DEPTH NPHI FCNT NCNT PEF DRHO RHOB GR FET RPD RPM RPS RPX RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 16813 0 16813 0 16813 0 16830 0 16830 0 16830 0 16859 5 16866 0 16866 0 16866 0 16866 0 16866 0 16901 5 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: MAi{IMUMANGLE: STOP DEPTH 17414 5 17414 5 17414 5 17430 0 17430 0 17430 0 17456 5 17414 5 17414 5 17461 5 17461 5 17461 5 17499 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA_MlVL~ RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 29-APR-98 ISC 5.07 CIM 5.46 MEMORY 17775.0 17175.0 17775.0 61.5 66.3 TOOL NUMBER P0980SP4 P0980SP4 P0980SP4 P0980SP4 6.000 6.0 LSND 10.20 63.0 9.5 5OO 2.6 1.000 .514 .890 1.950 70.0 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 Frarae Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MAD 26 API 4 1 68 RPX MAD 26 OHMM 4 1 68 RPS MAD 26 OHMM 4 1 68 RPM MAD 26 OHMM 4 1 68 RPD MAD 26 OHMM 4 1 68 RAT MAD 26 FT/H 4 1 68 FET MAD 26 HOUR 4 1 68 NBHI MAD 26 B.U. 4 1 68 FCNT MAD 26 CNTS 4 1 68 NCNT MAD 26 CNTS 4 1 68 RHOB MAD 26 G/CC 4 1 68 DRHO MAD 26 G/CC 4 1 68 PEF MAD 26 BARN 4 1 68 Rep Code Offset Channel 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DE?T GR RPX RPS RPM RPD RAT FET NPHI FCNT NCNT RHOB DRHO PEF Min 16813 11 7291 1 4387 2 2004 2 6502 3 5603 21 3419 27 5148 8 269.41 25942.4 2.1065 -0.06 1.2598 Max Mean 17499 17156 183.548 45.5401 134.702 29.1027 85.2691 27.7206 78.2159 28.8732 80.8101 32.9446 4521.09 222.949 92.8664 60.0858 38.58 19.6717 2413.28 930.762 57446.2 41604.5 3.0187 2.39849 0.7579 0.0612264 8.324 3.09204 Nsam 1373 1195 1192 1192 1192 1192 1196 1192 1202 1202 1202 1201 1201 1201 First Reading 16813 16859.5 16866 16866 16866 16866 16901.5 16866 16813 16813 16813 16830 16830 16830 Last Reading 17499 17456.5 17461.5 17461.5 17461.5 17461.5 17499 17461.5 17413.5 17413.5 17413.5 17430 17430 17430 First Reading For Entire File .......... 16813 Last Reading For Entire File ........... 17499 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/06/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Cor~aents ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/06/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Cemments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Mon Apr 20 11:55:20 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER WILDCAT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MM-80134 M. HANIK J. CARLILE 2- 56A/B-~--~t 500292286301 BP EXPLORATION (ALASKA) , INC. SPERRY-SUN DRILLING SERVICES 20 -AP R- 98 MWD RUN 4 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 5 AK-MM-80134 J. MARTIN J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MM-80134 M. GABEL E. VAUGHN MWD RUN 10 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 11 AK-MM-80134 M. HANIK J. CARLILE JOB NUMBER: MWD RUN 12 AK-MM-80134 MWD RUN 13 AK-MM-80134 MWD RUN 14 AK-MM-80134 LOGGING ENGINEER: OPERATOR WITNESS: M. HANIK J. CARLILE M. KA_NIK J. CARLILE M. HANIK J. CARLILE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 15 AK-MM-80134 M. HANIK J. CARLILE MWD RUN 16 AK-MM-80134 M. HANIK CARLILE/VAUG MWD RUN 16 AK-MM-80134 M. HANIK CARLILE/VAUG JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 17 AK-M~-80134 G. TOBIAS E. VAUGHN 36 12N 16E 3193 2333 .00 54.70 14.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 30.000 80.0 2ND STRING 12.250 9.625 7079.0 3RD STRING 8.500 7.000 16451.0 PRODUCTION STRING 6.000 18340.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 3 THROUGH 5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR). 4. MWD RUN 6 IS DIRECTIONAL, DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). DATA FROM 15750'MD, 8876'TVD TO 16020'MD, 9074'TVD IS MEASURED AFTER DRILLING (MAD). 5. MWD RUNS 10 THROUGH 15 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. MWD RUNS 16 AND 17 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND STABILIZED LITHO DENSITY (SLD) . SLD DATA FROM 17068'MD, 9659'TVD TO 17770'MD, 9814'TVD IS MEASURED AFTER DRILLING (MAD) ON THE WAY IN THE HOLE FOR MWD RUN 16. 7. THERE IS A MEASURED AFTER DRILLING (MAD) PASS ON RUN 16 FROM 17102.5'MD, 9665'TVD TO 17769.5'MD, 9813'TVD. THIS MAD PASS IS DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 8. MWD RUNS 1 THROUGH 6 AND 10 THROUGH 17 REPRESENT WELL 2-56A/EI-01 WITH API #: 50-029-22863-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 18340 'MD, 10069 '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. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY. SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY (COMPENSATED). SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORBTION FACTOR. HOLE SIZE: 8.5" & 6.0" FIXED. MUD WEIGHT: 9.8 - 10.1 LBS/GAL. MUD FILTRATE SALINITY: 500 - 600 PPM CL. FORMATION WATER SALINITY: 11500 PPM CL. MATRIX: SANDSTONE. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START GR 7044 ROP 7088 FET 15678 RPD 15678 RPM 15678 RPS 15678 RPX 15678 FCNT 15687 NCNT 15687 NPHI 15687 PEF 15696 DRHO 15696 RHOB 15696 $ BASELINE CURVE FOR SHIFTS: DEPTH 0 0 5 5 5 5 5 0 0 0 0 0 0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH -- 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 ...................... -999.25 Depth Units ....................... Datura Specification Block sub-type...0 TOP MERGE BASE 0 10212.0 0 11873.0 0 16020.0 0 16465.0 0 16658.0 0 16817.0 0 17090.0 0 17281.0 0 17480.0 0 17770.0 0 18014.0 0 18340.0 STOP DEPTH 18275.5 18325.5 18282.5 18282.5 18282.5 18282.5 18282.5 16401.0 16401.0 16401.0 18245.5 18245.5 18245.5 BASELINE DEPTH GR 7044.0 7058.0 16442.0 16456.0 18325.5 18339.5 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE MWD 3 7100. MWD 4 10212. MWD 5 11873. MWD 6 16020. MWD 10 16456. MWD 11 16658. MWD 12 16817. MWD 13 17090. MWD 14 17281. MWD 15 17480. MWD 16 17138. MWD 17 18014. $ REMARKS: MERGED MAIN PASS. $ Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHM}{ 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max Mean Nsam DEPT 7044 18325.5 12684.8 22564 ROP 1.6472 2344.92 100.419 22476 GR 4.4011 382.102 74.4012 22464 RPX 0.4598 2000 25.0553 5209 RPS 0.4773 2000 29.9222 5209 RPM 0.3986 2000 39.6108 5209 RPD 0.396 2000 47.5766 5209 FET 0.7327 39.6994 9.21556 5157 NPHI 24.1011 81.7622 45.0486 1429 NCNT 2160 3216 2514.13 1429 FCNT 517.045 1119.79 690.024 1429 RHOB 1.7482 3.0978 2.40391 3484 DRHO -0.14 0.8029 0.0657726 3484 PEF 0.797 11.7282 3.74028 3484 First Reading 7044 7088 7044 15678.5 15678.5 15678.5 15678.5 15678.5 15687 15687 15687 15696 15696 15696 Last Reading 18325.5 18325.5 18275.5 18282.5 18282.5 18282.5 18282.5 18282.5 16401 16401 16401 18245.5 18245.5 18245.5 First Reading For Entire File .......... 7044 Last Reading For Entire File ........... 18325.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX RAT MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: .5000 START DEPTH 17088.5 17094 5 17094 5 17094 5 17094 5 17094 5 17132 5 STOP DEPTH 17755.5 17755.5 17755.5 17755.5 17755.5 17755.5 17755.5 MAD RUN NO. MAD PASS NO. MERGE TOP 16 17146.5 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 17769.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD AAPI 4 1 68 8 3 RPX MAD OHM~ 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMH 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 Name DEPT RAT GR RPX RPS RPM RPD FET Min 17088.5 37 3596 9 6189 6 1922 9 0818 9 4504 11 9694 31 5642 Max 17755.5 139.543 82.3771 142.483 2000 2000 2000 110.86 Mean Nsam 17422 1335 96 1793 1247 21 5647 1335 49 4395 1323 56 8601 1323 52 9084 1323 57 9128 1323 69 7994 1323 First Reading 17088 5 17132 5 17088 5 17094 5 17094 5 17094 5 17094 5 17094 5 Last Reading 17755.5 17755.5 17755.5 17755.5 17755.5 17755.5 17755.5 17755.5 First Reading For Entire File .......... 17088.5 Last Reading For Entire File ........... 17755.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Con~aent Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7058.0 10167.5 ROP 7102.0 10211.5 $ LOG HEADER DATA DATE LOGGED: 27-FEB-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 5.07 CIM 5.46 MEMORY 10212.0 7100.0 10212.0 59.6 63.1 TOOL NUMBER P0956CG6 8.500 8.5 LSND 9.50 45.0 9.6 1600 5.4 .000 .000 .000 .000 42.2 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7058 10211.5 8634.75 6308 7058 ROP 6.5739 377.227 146.525 6220 7102 GR 4.4011 127.552 67.5197 6220 7058 Last Reading 10211.5 10211.5 10167.5 First Reading For Entire File .......... 7058 Last Reading For Entire File ........... 10211.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10169.0 11829.5 ROP 10213.5 11872.0 $ LOG HEADER DATA DATE LOGGED: 01-MAR-98 S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA/V/vLA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 5.07 CIM 5.46 MEMORY 11873.0 10212.0 11873.0 58.7 62.2 TOOL NUMBER P0956CG6 8.500 8.5 LSND 9.60 46.0 9.4 1300 4.8 .000 .000 .000 .000 44.2 Name Service Order Units Size Nsam Rep Code Offset Channel DE?T FT 4 1 68 0 1 ROP MWD 4 FT/H 4 1 68 4 2 GR MWD 4 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10169 11872 11020.5 3407 10169 ROP 6.4328 419.093 128.969 3318 10213.5 GR 22.2284 122.499 66.6233 3322 10169 Last Reading 11872 11872 11829.5 First Reading For Entire File .......... 10169 Last Reading For Entire File ........... 11872 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Corament Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11825.0 15971.5 ROP 11874.5 16020.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMI4A RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 06-MAR-98 ISC 5.07 CIM 5.46 MEMORY 16020.0 11873.0 16020.0 38.8 61.1 TOOL NUMBER P0956CG6 8.500 8.5 LSND 10.00 48.0 9.4 1000 4.4 .000 .000 .000 .000 51.7 Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 5 FT/H 4 1 68 4 2 GR MWD 5 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11825 16020 13922.5 8391 11825 ROP 6.3024 2344.92 90.2875 8292 11874.5 GR 19.3321 216.163 86.62 8294 11825 Last Reading 16020 16020 15971.5 First Reading For Entire File .......... 11825 Last Reading For Entire File ........... 16020 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 15692.5 RPD 15692.5 RPM 15692.5 RPS 15692.5 STOP DEPTH 16407.5 16407.5 16407.5 16407.5 RPX 15692 5 FCNT 15701 0 NCNT 15701 0 NPHI 15701 0 PEF 15710 0 DRHO 15710 0 RHOB 15710 0 GR 15720 0 ROP 15751 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: NLAXIMUMA/qGLE: 16407 5 16415 0 16415 0 16415 0 16424 0 16424 0 16424 0 16435 0 16456 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GA/V94A RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHM]~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : 07-MAR-98 ISC 5.07 CIM 5.46 MEMORY 16465.0 16020.0 16465.0 25.7 35.0 TOOL NUMBER P0969CRNLG6 P0969CRNLG6 P0969CRNLG6 P0969CRNLG6 8.500 8.5 LSND 10.20 500.0 9.5 8OO 3.6 2.000 1.060 1.650 2.600 62.8 EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 6 FT/H 4 1 GR MWD 6 AAPI 4 1 RPX MWD 6 OHMM 4 1 RPS MWD 6 OHMM 4 1 RPM MWD 6 OHMM 4 1 RPD MWD 6 OHM~ 4 1 FET MWD 6 HOUR 4 1 NPHI MWD 6 P.U. 4 1 NCNT MWD 6 CNTS 4 1 FCNT MWD 6 CNTS 4 1 RHOB MWD 6 G/CC 4 1 DRHO MWD 6 G/CC 4 1 PEF MWD 6 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI NCNT FCNT RHOB DRHO PEF Min 15692.5 6 6835 70 0012 1 1302 1 1329 1 1057 0 9799 0 7327 24 1011 2160 517.045 2.1347 -0.14 1.1811 First Max Mean Nsam Reading 16456 16074.2 1528 15692.5 367.734 90.4059 1410 15751.5 382.102 157.782 1431 15720 9.0436 3.63113 1431 15692.5 8.9429 3.6618 1431 15692.5 10.6446 3.58765 1431 15692.5 8.7769 3.63692 1431 15692.5 39.4337 16.2128 1431 15692.5 81.7622 45.0486 1429 15701 3216 2514.13 1429 15701 1119.79 690.024 1429 15701 3.0449 2.48828 1429 15710 0.6206 0.0765589 1429 15710 9.5992 3.88027 1429 15710 Last Reading 16456 16456 16435 16407.5 16407.5 16407.5 16407.5 16407.5 16415 16415 16415 16424 16424 16424 First Reading For Entire File .......... 15692.5 Last Reading For Entire File ........... 16456 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPX RPD RPM RPS FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 16398 5 16403 5 16404 0 16404 0 16404 0 16434 0 16435 5 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 16620 5 16627 5 16627 5 16627 5 16627 5 16627 5 16657 0 22-MAR-98 ISC 5.07 CIM 5.46 MEMORY 16658.0 16456.0 16658.0 28.2 50.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMlqA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 LSND 10.00 48.0 9.0 5OO 3.3 1.200 .700 .950 1.500 58.9 .4 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 10 AAPI 4 1 68 4 2 RPX MWD 10 OHMM 4 1 68 8 3 RPS MWD 10 OHMM 4 1 68 12 4 RPM MWD 10 OHMM 4 1 68 16 5 RPD MWD 10 OHM~ 4 1 68 20 6 ROP MWD 10 FT/H 4 1 68 24 7 FET MWD 10 HOUR 4 1 68 28 8 Name Min Max Mean Nsam DEPT 16398.5 16657 16527.8 518 GR 14.2492 164.986 69.2558 445 RPX 0.4598 2000 39.3696 449 RPS 0.4773 2000 47.7527 448 RPM 0.3986 2000 162.766 448 RPD 0.396 2000 200.727 448 ROP 3.4394 3951.56 129.443 444 FET 1.1024 6.3596 2.45573 388 First Reading 16398.5 16398.5 16403.5 16404 16404 16404 16435.5 16434 Last Reading 16657 16620.5 16627.5 16627.5 16627.5 16627.5 16657 16627.5 First Reading For Entire File .......... 16398.5 Last Reading For Entire File ........... 16657 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX 11 .5000 START DEPTH 16617 5 16624 5 16624 5 16624 5 16624 5 16624 5 STOP DEPTH 16775.5 16782.5 16782.5 16782.5 16782.5 16782.5 ROP 16660.0 $ 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: 16817.0 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) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 23-MAR-98 ISC 5.07 CIM 5.46 MEMORY 16817.0 16658.0 16817.0 54.0 80.4 TOOL NUMBER P0882SP4 P0882SP4 6.0OO 6.0 LSND 10.00 49.0 9.1 50O 2.8 1.200 .637 1.000 1.500 58.9 .4 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD 11 AAPI 4 1 68 MWD 11 OHM~ 4 1 68 MWD 11 OHM~ 4 1 68 MWD 11 OHMM 4 1 68 MWD 11 OHM~ 4 1 68 MWD 11 FT/H 4 1 68 MWD 11 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 16617.5 13 3817 5 0345 5 6102 5 3301 5 9373 4 1926 2 0548 Max Mean Nsam 16817 16717.2 400 141.555 48.1638 317 68.6543 35.0247 317 74.5946 40.4029 317 64.2567 37.3646 317 66.5312 37.1331 317 280.202 29.5603 315 25.6818 7.58121 317 First Reading 16617 5 16617 5 16624 5 16624 5 16624 5 16624 5 16660 16624.5 Last Reading 16817 16775.5 16782.5 16782.5 16782.5 16782.5 16817 16782.5 First Reading For Entire File .......... 16617.5 Last Reading For Entire File ........... 16817 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files· BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 16688 0 FET 16692 0 RPS 16692 0 RPX 16692 0 RPD 16692 5 RPM 16692 5 ROP 16724 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 17051 0 17058 0 17058 0 17058 0 17058 0 17058 0 17090 0 25-MAR-98 ISC 5.07 CIM 5.46 MEMORY 17090.0 16817.0 17090.0 84.4 89·4 TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 LSND 10.00 48.0 9.2 5OO 3.0 1.200 · 620 .900 1.450 63.3 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .4 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 12 AAPI 4 1 68 RPX MWD 12 OHM~ 4 1 68 RPS MWD 12 OHMM 4 1 68 RPM MWD 12 OHMM 4 1 68 RPD MWD 12 OHMM 4 1 68 ROP MWD 12 FT/H 4 1 68 FET MWD 12 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 16688 14 6141 3 2787 4 9442 4 2071 4 3201 6 9498 1 4309 Max Mean 17090 16889 140.312 32.2944 80.3664 33.2421 89.0477 40.2145 563.522 40.9532 2000 51.0246 2032.6 172.867 27.4679 9.41931 Nsam 805 727 733 733 732 732 732 733 First Reading 16688 16688 16692 16692 16692.5 16692.5 16724.5 16692 Last Reading 17090 17051 17058 17058 17058 17058 17090 17058 First Reading For Entire File .......... 16688 Last Reading For Entire File ........... 17090 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP LOG HEADER DATA DATE LOGGED: SOFTWARE 16967.5 16974 5 16974 5 16974 5 16974 5 16974 5 17013 5 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: 17243 17243 17281 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ STOP DEPTH 17236 5 17243 5 17243 5 17243 5 5 5 5 27-MAR-98 ISC 5.07 CIM 5.46 MEMORY 17281.0 17090.0 17281.0 80.8 82.9 TOOL NUMBER P0882SP4 P0882SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.000 6.0 LSND 10.10 51.0 9.2 5OO 3.2 1.200 .635 .900 1.500 .4 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 AAPI 4 1 68 4 2 RPX MWD 13 OHMM 4 1 68 8 3 RPS MWD 13 OHM~ 4 1 68 12 4 RPM MWD 13 OHMM 4 1 68 16 5 RPD MWD 13 OHM~ 4 1 68 20 6 ROP MWD 13 FT/H 4 1 68 24 7 FET MWD 13 HOUR 4 1 68 28 8 63.3 First Name Min Max Mean Nsam Reading DEPT 16967.5 17281.5 17124.5 629 16967.5 Last Reading 17281.5 GR RPX RPS RPM RPD ROP FET 13 7013 2 2487 3 3677 5 4952 8 4359 6 4516 1 9139 43.343 19.5499 539 80.4945 34.9156 539 2000 47.8789 539 2000 49.134 539 2000 75.3719 539 190.184 28.6914 537 30.6671 13.9789 539 16967 5 16974 5 16974 5 16974 5 16974 5 17013 5 16974 5 17236.5 17243.5 17243.5 17243.5 17243.5 17281.5 17243.5 First Reading For Entire File .......... 16967.5 Last Reading For Entire File ........... 17281.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ 17237 0 17244 0 17244 0 17244 0 17244 0 17244 0 17283 0 LOG HEADER DATA DATE LOGGED: STOP DEPTH 17434.0 17441.0 17441.0 17441.0 17441.0 17441.0 17479.0 28-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... ISC 5.07 CIM 5.46 MEMORY 17480.0 17281.0 17480.0 76.6 80.3 TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 LSND 10.00 48.0 9.5 5O0 3.4 1.300 .687 1.250 1.850 65.6 .4 Datum Specification Block sub-type...0 DEPT GR RPX RPS RPM RPD ROP FET Name Service Order Units Size Nsam FT 4 1 MWD 14 AAPI 4 1 MWD 14 OHMM 4 1 MWD 14 OHMM 4 1 MWD 14 OHMM 4 1 MWD 14 OHMM 4 1 MWD 14 FT/H 4 1 MWD 14 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 17237 17479 17358 GR 12.0279 49.4502 21.9125 RPX 23.8702 70.3372 42.9797 RPS 31.1184 77.2831 52.1115 RPM 33.366 75.518 53.0421 RPD 37.1177 81.0088 59.1245 ROP 6.4788 226.758 25.3523 FET 1.9928 22.8661 6.55696 First Last Nsam Reading Reading 485 17237 17479 395 17237 17434 395 17244 17441 395 17244 17441 395 17244 17441 395 17244 17441 393 17283 17479 395 17244 17441 First Reading For Entire File .......... 17237 Last Reading For Entire File ........... 17479 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: RAW MWD 12 Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 17435.0 17724.5 RPD 17441.5 17731.5 RPM 17441.5 17731.5 RPS 17441.5 17731.5 FET 17442.0 17731.5 RPX 17442.0 17731.5 ROP 17481.0 17770.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMIC) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 30-MAR-98 ISC 5.07 ClM 5.46 MEMORY 17770.0 17480.0 17770.0 73.7 75.9 TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 LSND 10.00 51.0 9.4 5OO 3.6 1.300 .704 1.200 1.800 65.6 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .4 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 15 AAPI 4 1 RPX MWD 15 OHMM 4 1 RPS MWD 15 OHMM 4 1 RPM MWD 15 OHMM 4 1 RPD MWD 15 OHM~ 4 1 ROP MWD 15 FT/H 4 1 FET MWD 15 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 17435 13 8525 21 7129 25 8813 26 2708 32 2955 3 1604 2.117 Max Mean 17770 17602.5 78.022 23.1822 72.6389 45.2713 80.6794 50.7754 104.203 49.7065 145.121 54.2719 199.664 19.67 22.0604 5.77156 First Last Nsam Reading Reading 671 17435 17770 580 17435 17724.5 580 17442 17731.5 581 17441.5 17731.5 581 17441.5 17731.5 581 17441.5 17731.5 579 17481 17770 580 17442 17731.5 First Reading For Entire File .......... 17435 Last Reading For Entire File ........... 17770 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 17700 0 17975 5 RPM 17700 0 17975 5 RPS 17700 0 17975 5 RPX 17700 0 17975 5 GR 17700 0 17968 5 ROP 17700 0 18013 5 FET 17732.0 17970 5 $ LOG HEADER DATA DATE LOGGED: 01-APR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER {FT) : 18014.0 TOP LOG INTERVAL (FT) : 17138.0 BOTTOM LOG INTERVAL (FT) : 18014.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 64.9 FLAXIMUM ANGLE: 74.1 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): TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (P?M) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERM?ERATURE: 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 10.10 55.0 9.4 5OO 3.8 1.500 .778 1.300 2.100 .4 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD 16 G/CC 4 1 68 4 2 DRHO MWD 16 G/CC 4 1 68 8 3 PEF MWD 16 BARN 4 1 68 12 4 GR MWD 16 AAPI 4 1 68 16 5 RPX MWD 16 OHMM 4 1 68 20 6 RPS MWD 16 OHMM 4 1 68 24 7 RPM MWD 16 OHMM 4 1 68 28 8 RPD MWD 16 OHMM 4 1 68 32 9 ROP MWD 16 FT/H 4 1 68 36 10 FET MWD 16 HOUR 4 1 68 40 11 78.7 First Name Min Max Mean Nsam Reading DEPT 17068 18013.5 17540.8 1892 17068 RHOB 2.1369 2.6474 2.33401 1404 17068 DRHO -0.039 0.3118 0.0398907 1404 17068 Last Reading 18013.5 17769.5 17769.5 PEF GR RPX RPS RPM RPD ROP FET 1 4961 13 9172 1 4295 1 7648 2 1885 2 9239 1 6472 1 4264 9.6956 3.20749 1404 132.586 56.165 538 57.2602 19.942 552 70.1111 22.6751 552 61.7453 22.5955 552 76.6116 24.5669 552 1884.38 64.7471 628 39.6994 9.8005 478 17068 17700 17700 17700 17700 17700 17700 17732 17769.5 17968.5 17975.5 17975.5 17975.5 17975.5 18013.5 17970.5 First Reading For Entire File .......... 17068 Last Reading For Entire File ........... 18013.5 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.014 Physical EOF File Header Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.013 Comment Record FILE HEADER FILE NUMBER: 14 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP 17 .5000 START DEPTH 17934 5 17934 5 17934 5 17964 0 17971 0 17971 0 17971 0 17971.0 17971.0 18015.0 STOP DEPTH 18259.5 18259.5 18259.5 18289.5 18296.5 18296.5 18296.5 18296.5 18296.5 18339.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR RF=AL-TIME) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 04-APR-98 ISC 5.07 CIM 5.46 MEMORY 18340.0 18014.0 18340.0 55.2 67.4 TOOL NUMBER P0882SP4 P0882SP4 P0882SP4 6.000 6.0 LSND 10.10 56.0 9.2 500 3.8 1.400 · 629 1.200 1.600 85.5 .4 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 17 AAPI 4 1 68 RPX MWD 17 OHMM 4 1 68 RPS MWD 17 OHMM 4 1 68 RPM MWD 17 OHMM 4 1 68 RPD MWD 17 OHMM 4 1 68 ROP MWD 17 FT/H 4 1 68 FET MWD 17 HOUR 4 1 68 RHOB MWD 17 G/CC 4 1 68 DRHO MWD 17 G/CC 4 1 68 PEF MWD 17 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 Name DEPT GR RPX RPS RPM RPD ROP FET RHOB DRHO PEF Min 17934.5 17 1749 2 2939 2 1805 1 7349 1 7748 4 2398 1 3252 1 7482 -0.127 0.797 Max 18339.5 189.965 50.6079 58.6742 53.1783 54.9725 547.95 35.0561 3.0978 0.8029 11.7282 Mean 18137 68 8637 18 5891 21 8406 20 9221 22 0006 40 3086 8.10203 2.36947 0.097915 4.58202 Nsam 811 652 652 652 652 652 650 652 651 651 651 First Reading 17934.5 17964 17971 17971 17971 17971 18015 17971 17934.5 17934.5 17934.5 Last Reading 18339 5 18289 5 18296 5 18296 5 18296 5 18296 5 18339 5 18296 5 18259 5 18259.5 18259.5 First Reading For Entire File .......... 17934.5 Last Reading For Entire File ........... 18339.5 File Trailer Service name ............. STSLIB.014 Service Sub Level Name... Version NurSer ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.015 Physical EOF File Header Service name ............. STSLIB.015 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.014 Comment Record FILE HEADER FILE NUMBER: 15 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 16 MAD PASS NUMBER: FI LE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 17102 5 17108 5 17108 5 17108 5 17108 5 17108 5 17146 5 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 17769 5 17769 5 17769 5 17769 5 17769 17769 17769 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 01-APR-98 ISC 5.07 CIM 5.46 MEMORY 18014.0 17138.0 18014.0 64.9 74.1 TOOL NUMBER P0882SP4 P0882SP4 6.000 6.0 LSND 10.10 55.0 9.4 MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5OO 3.8 1.500 .778 1.300 2.100 .4 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD 16 FT/H 4 1 68 4 2 GR MAD 16 AAPI 4 1 68 8 3 RPX MAD 16 OHMM 4 1 68 12 4 RPS MAD 16 OHMM 4 1 68 16 5 RPM MAD 16 OHMM 4 1 68 20 6 RPD MAD 16 OHMM 4 1 68 24 7 FET MAD 16 HOUR 4 1 68 28 8 78.7 Name DEPT RAT GR RPX RPS RPM RPD FET Min 17102.5 37 3596 9 6189 6 1922 9 0818 9 4504 11 9694 31 5642 Max 17769.5 139.543 82.3771 142.483 2000 2000 2000 110.86 Mean Nsam 17436 1335 96 1793 1247 21 5647 1335 49 4395 1323 56 8601 1323 52 9084 1323 57 9128 1323 69 7994 1323 First Reading 17102 5 17146 5 17102 5 17108 5 17108 5 17108 5 17108 5 17108 5 Last Reading 17769 5 17769 5 17769 5 17769 5 17769 5 17769 5 17769 5 17769 5 First Reading For Entire File .......... 17102.5 Last Reading For Entire File ........... 17769.5 File Trailer Service name ............. STSLIB.015 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.016 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/04/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/04/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File