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HomeMy WebLinkAbout189-029CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPG-01 (PTD# 1890290) - Shut in for 4 year AOGCC MIT-IA Date:Thursday, October 31, 2024 8:11:15 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, October 30, 2024 4:05 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPG-01 (PTD# 1890290) - Shut in for 4 year AOGCC MIT-IA Mr. Wallace – PWI well MPG-01 (PTD# 1890290) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM Jim Regg ` q TO: / P.I. Supervisor FROM: Bob Noble Petroleum Inspector Well Name MILNE PT UNIT G-01 Insp Num: mitRCN20101815355I Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 26, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC G-01 MILNE PT UNIT G-01 Ste: Inspector Reviewed By: P.I. Suprv, Comm API Well Number 50-029-21927-00-00 Inspector Name: Bob Noble Permit Number: 189-029-0 Inspection Date: 10/17/2020 Packer Well G-01 Type Inj VV, TVD PTD 1890290 " Type Test. SPT" Test psi BBL Pumped: 0.7 BBL Returned: Interval 4YRTST P/F Notes: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3691 Tubing 796 - 794 796 796 1500 - IA 378 2052 - 2005 1994- 0.7 ---OA - 190 399 - 406 - 409 P Monday, October 26, 2020 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS on A AC oc non RECE:mmr DEC 16 2019 07-S A ^C�(9i� 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tutting Qo Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Cahange-out Q 2. Operator Name: 4. Current Well Class 15. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 189-028 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-21926-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT G-02 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025906 MILNE POINT/SCHRADER BLUFF OIL = 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 5,714' 4,701' 5,614' 4,609' 903 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor110' 13-3/8" 110' 110' N/A N/A Surface 2,856' 9-5/8" 2,856' 2,485' 6,870psi 4,760psi Production 5,694' 7" 5,694' 4,683' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2-7/8" 6.5 / L-80/ 8rd EUE 4,602 See Schematic See Schematic 2-7/8" 6.5 / L-80 / 8rd El E 5,110 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): SC -1 L & Model D Perm/ and N/A 4,669' MD/ 3,770' TVD & 5,110' MD/ 4,143' TVD and N/A 12. Attachments: Proposal Summary � Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/8/2020 - OIL ❑� WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: David Haakinson Authorized Title: Operations Manager Contact Email: dhaakinSon hl Or .Coln .J Contact Phone: 777-8343 Authorized Signature: Date: 12/16/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test I/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Z 5-00 111'j c, /I e)P /�� L RBDMS I�''`'�DEC 19 2019 Post Initial Injection MIT Req'd? Yes F] No EJ,] U Spacing Exception Required? Yes ❑ No O Subsequent Form Required: APPROVED BY Approved by: 1 . COMMISSIONER THE COMMISSION Date: t y r G1 (' ORIGINAL / ',2-191'f Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. /Submit Form and Attachments in Duplicate U lrilmm Alaska, LU ESP Change -Out Well: MPU G-02 Date: 12-16-19 Well Name: MPU G-02 API Number: 50-029-21926-00 Current Status: Shut-in ESP Producer Rig: ASR #1 Estimated Start Date: January 8`^, 2020 Estimated Duration 3 Days Reg. Approval Req'd? Yes Date Reg, Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189-028 First Call Engineer: David Haakinson (907) 777-8343 (0) (307) 660-4999 (M) Second Call Engineer: Ian Toomey (907) 777-8434 (0) (907) 903-3987 (M) AFE Number: Job Type: ESP Swap Current Bottom Hole Pressure: 1,255 psi @ 3,717' TVD Maximum Expected BHP: 1,275 psi @ 3,717' TVD MPSP: 903 psi Max Inclination 48° @ 2,700' MD Max Dogleg: 4.1"/100ft @ 3,600' MD BPV Profile: 2-1/2" CIW Type H Downhole Gauge: 1 -month PBU (12/5/19) 16.49 PPG 2 -Month PBU Extrapolation 1 6.6 PPG Gas Column Gradient (0.1 psi/ft)' Brief Well Summary: MPU producer G-02 was drilled and completed as a gravel -packed N -Sand producer in 1989. The well has had a history of RWOs related to tubing leaks and motor failures. The tubing leaks appear to be related to the installation of downhole heat trace and thus the heat trace will be removed. Regarding historical motor failure, producer G-02 has evidence of past calcium carbonate scaling leading to high motor temperatures. As part of the well kill, a scale squeeze will be pumped on the well. The average ESP run -life has been approximately seven years, not accounting for the last two workovers due to tubing leaks. The last two ESP pulls have indicated sand in the pump, indicating a failure of the screens. After the RWO, the suction pressure target will be raised from 500 psig to 600 psig to limit sand production. Notes Regarding Wellbore Condition • The 7" production casing passed an MIT to 1,500 psig from 4,651' MD on 10/31/17 • The well has tubing leaks at 1,065' MD and 1,101' MD • Offset Injector Support o G-01: Shut-in Injector Obiective• • Pull 2-7/8" Tubing String, ESP, and 100 HP motor. • Install new Baker Hughes motor, Flex7 ESP, and new 2-3/8" tubing. Pre -Rig Procedure: -3 — 1 1. Ensure tubing patch and gas -lift valve slickline work is complete prior to the well -kill. 2. RU LRS and PT lines to 3000 psi. 3. Bullhead 70 bbls of 8.3 ppg source -water down tubing, taking fluid out the IA to a returns tank. 4. Bullhead 40 bbls of 8.3 ppg source water down tubing to the formation. 5. Bullhead 300 bbls of 8.3 ppg source -water down IA to the formation. 6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 McOH. a. Freeze protect is up to the discretion of the Wellsite Supervisor depending on timing for arrival of the ASR. ESP Change -Out Well: MPU G-02 Ilil..m Alaska, LLi Date: 12-16-19 7. RD Little Red Services. 8. Clear and level pad area in front of well. Spot rig mats and containment. 9. RD well house and flowlines. Clear and level area around well. 10. RU crane. Set BPV. ND Tree.�nspect the tubing hanger lift thread and note any damage) 11. NU BOPS. RD Crane. 12. Spot mud boat. Brief RWO Procedure: 13. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to returns tank. 14. If needed, bleed off any residual pressure off the IA. Check for pressure and if 0 psi, pull BPV. If needed, kill well w/ 8.3 ppg produced or source -water prior to pulling BPV. 15. Set TWC. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per "ASR 1 BOP Test Procedure" dated 11/03/2015. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram on 2-3/8" and 2-7/8" testjoints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Contingency: If BOPE test fails a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. A email explaining the wellhead situation prior to performing the rolling test. send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure m Regg (AOGCC) via AOGCC may elect to c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 18. Bleed any pressure off casing to 500 bbl returns tank. Pull TWC. Kill well w/ 8.3 ppg produced or source -water as needed. 19. Rig up spoolers to pull heat trace, 3/8" capillary string, and ESP #2 RD cable. a. Baker Hughes representative should be onsite for ESP pull. 20. MU 2-7/8" landing joint or spear, BOLDS and PU on the tubing hanger. 1 {�, a. The PU weight= 40K and SO= 281(for the November 2017 ASR #1 RWO. 1✓ b. Circulate (long or reverse) pill with heated source water, and baraclean pill prior to laying down the tubing hanger. 21. Recover the tubing hanger. n IIil..P Ah.kx, LL ESP Change -Out Well: MPU G-02 Date: 12-16-19 Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. a. Evaluate pulled tubing hanger for possible damage. If any damage is found, dispose of tubing hanger and contact well head specialist for replacement. 22. POOH and lay down the 2-7/8" tubing spooling ESP cable. Lay down ESP and motor. a. Tubing will not be reused. Send all tubing to G&I for washing and disposal, as necessary. b. Dispose of Heat Trace and 3/8" Capillary String c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. The completion has the following amount of clamps/guards/cap-string: i. 508 Heat Trace Cannon Clamps (every 5') ii. 119 Dual Channel Cross Collar Cannon Clamps iii. 24 Cross Collar Cannon Clamps iv. 5 Pump Clamps v. 3 Protectolizers vi. 2 Flat Guards 23. PU new ESP and RIH on 2-3/8" 4.7# L-80 tubing. Set base of ESP assembly at 4,520' MD. (� \� a. Check ESP cable conductivity every 1,000'. b. Optimum tubing make-up torque: 1,200 ft -lbs i. Minimum: 950 ft -lbs. Maximum: 1,400 ft -lbs. a. Base of ESP centralizer @ ±4,520' MD b. Motorgauge c. 100 HP Baker Hughes 562XP Motor d. Baker Hughes 126 stage Flex7 ESP e. Downhole gauge for discharge temperature and pressure. i. Connected with a jumper from the lower sensor. Does not require a separate tech -wire. f. 3 joints of 2-3/8", 4.7# L-80 Supermax tubing g. Lower 2-3/8"x 1" Side -pocket GLM @ ±4350' MD with DV h. 2-3/8", 4.7#, L-80, Supermax tubing i. Upper 2-3/8"x 1" Side -pocket GLM @ ± 200' MD with 0.25" OV j. 2-3/8", 4.7#, L-80, Supermax tubing 24. PU and MU the tubing hanger with landing joint. 25. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack -off weights on tally. 26. Set TWC 27. RDMO ASR. Post -Rig Procedure: 28. RD mud boat. RD BOPE house. Move to next well location. 29. RU crane. NO BOPE. 30. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. H Ilik.n, Al.&.. LL, 31. Pull TWC. 32. RD crane. Move returns tank and rig mats to next well location. 33. Replace gauge(s) if removed. 34. Turn well over to production. RU well house and flowlines. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic ESP Change -Out Well: MPU G-02 Date: 12-16-19 n Hileorp Alaska, LLC NB GeV.: ]9.3' AN'WU UEV.: 28.0 AMSL I 11,101' SLM 5/20/2019 1� B-5/8" 111 1I �r Ce•rNlifthaattace C� 7 k13,417 I' Es[ImatedTOC 2 MN ID= 2205" @4.505' 3 4 5 6 7&6 9 3B'SS Capstnng ' LU 10 11 '12 13 SSadvMsatler"N'f 14 15 "16 17&18 r. 1 TD=5,714' (MD)/TD=4,701'(TVD) PBTD =5,614' (MD) / PBTD=4,609'(TVD) SCHEMATIC Milne Point Unit Well: MPU G-02 Last Completed: 11/2/2017 PTD: 189-028 TREE & WELLHEAD Tree SM FMC 2 -9/16 - Wellhead 11- SM FMC w/2-7/8" WKM Tbg. Hngr., w/2-7/8"8 rd top, 2-7/B" lower, 2-1/2" CIW H BPV profile OPEN HOLE /CEMENT DETAIL 13-3/8" 60 bbls of Arcticset to surface In 3D" Hole 9-5/8" 1 171 bbls of 12.3ppg PF "E"/ 123 bbls of 15.8 ppg Prem. "G" in a 12-1/4" Hole 7" 1 65 bbls of 15.6 ppg Prem. "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 13-3/8" Conductor 48/H-40/etrs 12.715 Surface 110' 0.157 9-5/8" Surtace 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/e[rs 6.184 1 Surface 5,694' 0.0372 TUBING DETAIL 6.5/L-80/Brd EUE 2.441 Surface 6.5/L-80/8rd EUE 1 2.441 1 4,669' WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle =48 deg. Max Hole Angle through perforations = 27 deg. JEWELRY DETAII Nod Top (MD) Item 1GLM Btm (TVD) STA #2: CAMCO 2-7/8" x 1" Side pocket W/ Dmy 1/6/19 2 Status GLM STA q3: CAMCO 2-7/8" x 1" Side pocket w/ Dmy 1/6/193 5,022' 5,046' XN Nipple W/ 2.205" No- Go ID4 4,086' 1 24 Discharge Head: FPD155 Open NB Pump: FLEXER/H6SXD6 5,076' 4,095' Gas Separator: GRS FER N AR7 20 See Below Upper Tandem Seal: GSB31)BUTSB/SB PFSA 8 4,583' Lower Tandem Seal: GSB3DBUTSB/SB PFSA 9 4,590' Motor: CLS/XP-100HP, 1,820V, 34A 10 4,598' Sensor: Welll-lft Type E w/ Centralizer- Bottom @ 4,602' 11 4,669' Baker SC -1L Packer 7002-40-4,0"ID 12 4,678' Sliding Sleeve -4.0" ID 13 4,704' 2-7/8" Shear out Safety Joint w/ 44K Shear- 2.43" ID 14 5,001' Bakerweld 2-7/8" 0.012" Ga.Screen 96' w/ 2.44" ID 15 5,097' O -Ring Seal Sub 16 5,098' Bakerweld 2-7/8" 0.012" Ga. Tell Tale Screen -11' w. 2.44" ID 17 5,109'Baker 5-22 Snap Latch Seal Assembly 18 5,110' Baker Model D Permanent Packer PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 1 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 1 20 See Below Open NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly -245PF Executed on 3/30/1990 & 4/7/1990 WELLSTIMULATION Gravel Pack: 5,022'to 5,094' GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141 -8/29/1989 Perforate, Gravel Pack & Test by Pool #102-5/10/1990 Completed with ESP by EWS Rig 44 -11/20/1990 ESP Change -out by Nabors 4ES -2/15/1999 ESP Change -out by Nabors 3S -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Change -out by ASR#1-11/2/2017 Revised By: TDF 8/21/2019 K corn Al..", LLC KB Elev.:59.3' AMSL/61- Bev.:2&6'AMSL TD = 5,714' (MD) / TD=4,701'(IVD) PBTD= 5,614' (MO)/ PBT[)= 4,609'(IVD) Milne Point Unit Well: MPU G-02 PROPOSED Last Completed: 11/2/2017 PTD: 189-028 TREE & WELLHEAD Tree SM FMC 2-9/16" Wellhead 11 5M FMC w/2-7/8" WKM Tbg. Hngr., w/2-7/8"8 rd top, 2-7/8" lower, 2-1/2" CIW H BPV profile OPEN HOLE / CEMENT DETAIL 13-3/8" 60 6615 of Arcticset to surface in 30" Hale _ 9-5/8" 171 bbls of 12.3ppg PF "E"/ 123 6615 of 15.8 ppg Prem "G" in a 12-1/4" Hole 7" 1 65 bbls of 15.6 ppg Prem. "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top 1 Btm BPF 13-3/8" Conductor 48/H-40/Btrs 12.715 Lsurface 1 110' 1 0.157 9-5/8" Surface 47/L-80/Btrs 8.681 Surface 2,856' 0.0732 7" Production 29/L-80/Btrs 6.184 Surface 5,694' 0.0372 TUBING DETAIL 2-3/8" Tubing 4.7/L-80/Superman 2.441 Surface 14,520' 0.0039 WELL INCLINATION DETAIL KOP @ 500' Max Hole Angle = 48 deg. Max Hole Angle through perforations = 27 deg. g JEWELRY DETAIL No Depth Btm (MD) 1 ±20 2-3/8" Crossover 2 ±200 A N2: 3 ±4,3S0' A NI: jGal�n�ramr 4 ±4,455' e Head: 5 ±4,460' aker Hughes 126 stage FIex7 ESP 6 ±4,475' 4,113' 7 ±4,480' andem Seal: 8 ±4,490' LowerTandem Seal: 9 ±4,500' Motor: Baker Hughes 1001-1p 562XP 30 ±4,518' Sensor: Motor Gauge w/ Centralizer - Bottom @ ±4,520' 11 4,669' Baker SC -1L Packer 7082-40-4,0"ID 12 4,678' Sliding Sleeve -4.0" ID 13 4,704' 2-7/8" Shear out Safety Joint w/ 44K Shear -2.43"JD 14 5,001' Bakerweld 2-7/8" 0.012" Ga.Screen 96' w/ 2.44" ID 15 5,097' 0 -Ring Seal Sub 16 5,098' Bakerweld 2-7/8" 0.012" Ga. Tell Tale Screen - 11' w. 2.44" ID 17 5,139' 1 Baker 5-22 Snap Latch Seal Assembly 18 5,110' I Baker Model D Permanent Packer PERFORATION nFTAII Sands Top (MD) Btm (MD) Top (ND) Elm (ND) FT Date Status NA 5,022' 5,046' 4,064' 4,086' 24 See Below Open NB 5,056' 5,076' 4,095' 4,113' 20 See Below Open NB/NC 5,085' 5,094' 4,121' 4,129' 9 See Below Open Perforation Charge Detail: 4-5/8" Vann Gun Assembly- 24SPF Executed on 3/30/1990 & 4/7/1990 WELL STIMULATION Gravel Pack: 5,022' to 5,094' GENERAL WELL INFO API: 50-029-21926-00-00 Drilled and Cased by Parker 141-8/29/1989 Perforate, Gravel Pack & Test by Pool #102 -5/10/19 9 0 Completed with ESP by E WS Rig p4 -11/20/1990 ESP Change -out by Nabors 4ES - 2/15/1999 ESP Change -out by Nabors 3S -12/8/2008 ESP Change -out by Doyon 14 - 3/24/2013 ESP Change -out by ASR#1-11/2/2017 Revised By: TDF 12/13/2019 Milne Point ASR Rig 1 BOPE 2019 11" BOPE Updated 5/14/2018 VBR Pipe Rams lind ,es STATE OF ALASKA ALL OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Li Pull Tubing LJ Operations shutdown H Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:CT FCO-Nitrogen Q 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development ❑ Exploratory ❑ 189-029 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service 0 6.API Number: AK 99503 50-029-21927-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025906 MILNE PT UNIT G-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 4,950 feet Plugs measured N/A :RECEIVED true vertical 4,584 feet Junk measured N/A feet JUN 16 2017 Effective Depth measured 4,629 feet Packer measured 3,848&4,250 feet true vertical 4,455 feet true vertical 3,691 &4,084 feet AOGCC Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,618' 9-5/8" 2,618' 2,514' 6,870psi 4,760psi Production 4,729' 7" 4,729' 4,550' 8,160psi 7,020psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED ` ''I j `'' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 4,252' 4,086' Baker SC-1 Packers and SSSV(type,measured and true vertical depth) Baker D N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 769 360 864 Subsequent to operation: 0 0 663 400 841 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory❑ Development❑ Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q 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: 317-046 Authorized Name: Bo York Contact Name: Stan Porhola Authorized Title: Operations Manager Contact Email: sporhola@hllcorp.com .: r Authorized Signature, Date: IL .w. 0- Contact Phone: 777-8412 7/C—30%7 Form 10-404 Revised 4/2017 0�1((l / RMS ` JUN 2 6 2017 Submit Original Only • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP G-01 CTU 50-029-21927-00-00 189-029 6/6/17 6/6/17 Daily Operations: 5/31/2017 -Wednesday No activity to report. 6/1/2017-Thursday No activity to report. 6/2/2017 - Friday No activity to report. 6/3/2017-Saturday No activity to report. 6/4/2017-Sunday No activity to report. 6/5/2017- Monday No activity to report. 6/6/2017-Tuesday MIRU SLB CTU #8 with 1.5" CT. Well on injection.T/I/0 =850/320/120. Fluid pack coil and drift with 1" steel ball. Coil fill with 29 bbls. Perform BOP test. Recover ball. MU C/O BHA- 1.5" CTC, DBPV, 2 x 5.5' stingers, 1.5" OD DJN. OAL= 12.95'. Stab on well. PT. Change out chiksan. PT. Shut in well at wing valve. Open well.T/I/O =780/75/33. RIH with 1.5" OD DJN. Choke closed.TAG initially at 4,350' ctmd. PU clean at 9.3k. RBIH and pass tag depth. 2nd TAG at 4,478' ctmd. Clean out from 4,300' t 4,62 ctmd. Hard tag at 4,629' (Bottom perf at 4,398'/ PBTD at 4,725' MD) Unable to get deeper. Performed FC ith Slick water and gel sweeps- 1.3 - 1.7 bpm/3,800psi CTP/300psi WHP. Pump 15 bbl gel sweep off bottom and chase OOH. POOH from cleaning out to 4,629' ctmd. Pumping 1.8 bpm. Maintained full returns during operation. Recovered heavy schmoo and solids. Saw every gel sweep arrive at surface.At surface. Close swab. Remove fusible cap from SSV. Start RD. Pumped 261 bbls Slick 1%water/33 bbls gel/ Returned ' 267 bbls Leave location.Turn well over to Pad Op to put back on injection.Job Completed. • Milne Point Unit Well: MPU G-01 SCHEMATIC Last Completed: 2/03/1992 Hiliwrp Alaska,LLCPTD: 189-029 TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Tree 2-9/16"-5M WKM 13-3/8" 485 sx Permafrost in a 30"Hole Wellhead 11"5M WKM w/11"x 2-7/8"tbg.Hanger,2.5"'H' 9-5/8" 200 bbl Perm E&96 bbl Class'G'in a 12-1/4"Hole BPV profile and 8rd EUE threads top and bottom 7" 50 bbl Class'G'in a 8-1/2"Hole Orig.KB Elev.:59.3'/Orig.GL Elev.:28.6' CASING DETAIL RKB-4 Hanger:29.95'(Parker 141) r ) Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13-3/8 ir. 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 110' 0.1570 9-5/8" Surface 47/L-80/BTC 8.525 Surface 2,618' 0.0732 lc 7" Production 29/L-80/BTC 6.059 Surface 4,729' 0.0371 TUBING DETAIL .' 2-7/8" Tubing 6.5/L-80/EUE 2.347 Surf 4,252' 0.00579 )?', 2-3/8" Tubing 4.7/L-80/EUE 1.901 4,252' 4,260' 0.00387 WELL INCLINATION DETAIL N KOP@700' t u ' Max Hole Angle=23 deg.f/2,300'to TD ~; Hole angle thru perfs=12 deg. DLS=4 deg./100'f/1,400 to 1,500' k. JEWELRY DETAIL i; 1L%' No Depth Item 9-5/8" 1 3,847 Baker S-22 Seal Locator Assy. 2 3,848' Packer:7"Baker SC-IL Size 7OB2-40 ID=4.000" 3 3,882' 2-7/8"Blank Pipe(8 jts) 4 4,151' 2-7/8"Screen:Bakerweld 12 ga.ID=2.441" Est.TOC@3,250 5 4,237' Polished Bore Receptacle:ID= 2.062" I 6 4,239' 2-7/8"Screen:Bakerweld 12 ga.Lower Tell Tail '+41 7 4,249 Baker S-22 Snap Latch Seal Assy. ' 8 4,250' Packer:Baker'D'Sump ID=3.250" 9 4,253' 2-3/8"Pup Joint 10 4,259' 2-3/8"XN Nipple:Otis-ID=1.791"No Go t 11 4,260' 2-3/8"WLEG-Bottom @ 4,261' F PERFORATION DETAIL r 1 Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 4505 ._ NB"Sands 4,164' 4,186' 4,000' 4,020' 22 10/27/89;11/13/90 Open NC"Sands 4,196' 4,202' 4,030' 4,037' 6 10/27/89;11/13/90 Open "N E"Sands 4,216' 4,228' 4,051' 4,062' 12 10/27/89;11/13/90 Open "OA"Sands 4,305' 4,342' 4,140' 4,176' 37 10/07/1990 Open Aw "OB"Sands 4,380' 4,398' 4,213' 4,231' 18 10/07/1990 Open '�^ 'N'Sands 4-1/2"TCP Perfd w/32gm 12 spf&24 gm 12 spf.;'O'Sands WL Perfd w/37gm 5 spf NB ??LH"; STIMULATION SUMMARY 4 NC 'N'Sands Gravel Packed w/20/40 Sand ?;% 'O'Sands Frac'd w/83,086 lbs of YF140 �:%,' NE 40 a GENERAL WELL INFO l .' API:50-029-21927-00 Drilled and Cased by Parker 141-8/22/1989 '� Completed w/Gravel Pack and Frac and ESP w/EWS#4-11/17/1990 '8 WINJ Conversion w/EWS#4-2/03/1992 i 10 l-, ec° I Ill t" y All @ l Fi % OA 4,629' 'ls 6/C6/17 t TD=4,740'(MD)/TD=4,563'(TVD) Revised By:STP 6/12/2017 PBTD=4,725'(MD)/PBTD=4,548'(TVD) • • SOF G;w\��\�yyy�s� THE STATE Alaska Oil and Gas _� � ofLs JL`tel 1 Conservation Commission 333 West Seventh Avenue w� 1. GOVERNOR BILL WALKER -----•..„An,i„orage, Alaska 99501-3572 OF e. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager SCANNED MAR 0 9 2017, Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU G-01 Permit to Drill Number: 189-029 Sundry Number: 317-046 Dear Mr. York: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /317/24.41-73.- Cathy . Foerster Chair DATED this 2- day of February,2017. RBDIVIS - F - 3 2017 RECEIVED STATE OF ALASKA JAN 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION Oc7 2/Z�/ APPLICATION FOR SUNDRY APPROVALS AOGCC� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ CT FCO❑., Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Coil-Nitrogen❑l 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 189-029 r 3.Address: El Service Q . 6.API Number: Stratigraphic 3800 Centerpoint Dr,Suite 1400 50-029-21927-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑., MILNE PT UNIT WG-01 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025906 MILNE POINT/SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 4,950' . 4,584' . 4,725' ' 4,548' • 1,412 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 13-3/8" 110' 110' N/A N/A Surface 2,618' 9-5/8" 2,618' 2,514' 6,870psi 4,760psi Production 4,729' 7" 4,729' 4,550' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic / See Attached Schematic 2-7/8" 6.5#/L-80/EUE 4,252 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker SC-1L;Baker D and N/A 3,848'(MD)&3,691'(TVD); 4,250'(MD)&4,084'(TVD)and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., 14.Estimated Date for 15.Well Status after proposed work: 2/6/2017 Commencing Operations: OIL ❑ WINJ ❑✓ 'r WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Stan Porhola 5%P Email sporhola@hilcorp.com Printed Name Bo York Title Operations Manager Signature Phone 777-8345 Date IS 1!33/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry I k-l— 6y Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 44SF .2.12_1‘4 Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 _z.loy` RBDMS LL- FEB - 3 2017 APPROVED BY Approved by: /�q 1ev11/2O15 p 99..„/„._... COMMISSIONER THE COMMISSION Date: a •2 —/oftrtem.4 rForm 10-403 slid for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis • Well: MPU G-01 Bilcon)Alaska,Lb Date: 1/23j2017 Well Name: MPU G-01 API Number: 50-029-21927-00 Current Status: Water Injector Pad: Milne Point G-Pad Estimated Start Date: February 6th, 2017 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 189-029 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE N ' j,h''''' Io S Type 1',I,dG oili yam Cleanout ¢.. Current Bottom Hole Pressure: 1,812psi @ 4,000' TVD (Last BHP measured 6/29/2004) Maximum Expected BHP: 1,812 psi @ 4,000' TVD (No new perfs being added, EMW= 8.71 ppg) MPSP: 1,412 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary: MPU G-01 was drilled in 1989 using Parker 141 and in 1990 ran a gravel pack using EWS #4 in the Schrader Bluff OA, OB, NE, NC, and NB sands with an ESP. The completion was pulled and changed out in 1992 using EWS#4 and the well converted to a water injector. Notes Regarding Wellbore Condition • Max deviation at the base of the permafrost (max angle 23.0° @ 1,800'). • Casing last tested to 2,000 psi for 30 min down to 3,848' on 10/16/2016. • Deviation at perfs is 12.0°. • Tubing below gravel pack is 2-3/8". Min ID is 1.791" thru XN profile. • Last Fill Depth:4,351' MD tagged on 8/25/2012. Objective: The purpose of this work/sundry is to cleanout fill across the OB perfs using a nitrogen foam cleanout. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/8.5 ppg 1% KCI. 2. Pressure test BOPE to 3,500 psi Hi 250 Low, 5 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. cg- c. Submit 10-424 form within 5 days. 3. RIH w/1.50" coil w/1.5"to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 4,725' MD (in 7" casing). POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/friction reducer. Pump 5-10 bbl Gel Sweeps to help remove solids from the 7" casing. b. Contingency: If unable to wash down with nozzle, RIH w/1.5"to 1.75" reverse circ BHA and reverse circulate (see Reverse Circulating diagram). to PBTD at+/-4,725' MD (in 7" casing). POOH. • • Well Prognosis Well: MPU G-01 Hilcorp Alaska,LU Date: 1/23/2017 c. Contingency: If unable to reverse circulate, RIH w/ 1.5" to 1.75" mill and motor BHA and cleanout to PBTD at+/-4,725' MD (in 7" casing). POOH. 4. RIH w/ 1.50" coil w/1.5"to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 4,725' MD (in 7" casing). POOH. a. Circulate out fill using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. b. Contingency: If unable to wash down with nozzle, RIH w/1.5" to 1.75" mill and cleanout BHA and cleanout to PBTD at+/-4,725' MD (in 7" casing) using 8.5 ppg 1% KCI w/liquid foamer and mix with Nitrogen. POOH. 5. RIH w/ 1.50" coil w/1.5" to 1.75" max OD wash nozzle and cleanout BHA and cleanout to PBTD at+/- 4,725' MD (in 7" casing). Circ 30 bbl of heated diesel with Barascrub (to remove schmoo) and displace w/ 1% KCI to surface. POOH. 6. PU to 2,200' and freeze protect well. POOH w/coil. 7. RD Coiled Tubing and ancillary equipment. 8. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen & Foam Flow Diagram 5. Reverse Circulating Flow Diagram 1111 Milne Point Unit . II 11110 Well: MPU G-01 SCHEMATIC Last Completed: 2/03/1992 Ham.Alaska,LLC PTD: 189-029 TREE&WELLHEAD OPEN HOLE/CEMENT DETAIL Tree 2-9/16"-5M WKM 13-3/8" 485 sx Permafrost in a 30"Hole Wellhead 11"5M WKM w/11"x 2-7/8"tbg.Hanger,2.5"'H' 9-5/8" 200 bbl Perm E&96 bbl Class'G'in a 12-1/4"Hole BPV profile and 8rd EUE threads top and bottom 7" 50 bbl Class'G'in a 8-1/2"Hole Orig.KB Elev.:59.3'/Orig.GL Elev.:28.6' CASING DETAIL RKB-Hanger:29.95'(Parker 141) Size Type Wt/Grade/Conn Drift ID Top Btm BPF 13 3/8" '_. '\ 13-3/8" Conductor 48/H-40/N/A 12.559 Surface 110' 0.1570 .s 9-5/8" Surface 47/L-80/BTC 8.525 Surface 2,618' 0.0732 7" Production 29/L-80/BTC 6.059 Surface 4,729' 0.0371 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 2.347 Surf 4,252' 0.00579 c'0, 2-3/8" Tubing 4.7/L-80/EUE 1.901 4,252' 4,260' 0.00387 WELL INCLINATION DETAIL ;*:r KOP @ 700' Max Hole Angle=23 deg.f/2,300'to TD Hole angle thru perfs=12 deg. DLS=4 deg./100'f/1,400 to 1,500' JEWELRY DETAIL A i, No Depth Item 9-5/8" 1 3,847' Baker S-22 Seal Locator Assy. 2 3,848' Packer:7"Baker SC-IL Size 70B2-40 ID=4.000" 3 3,882' 2-7/8"Blank Pipe(8 jts) 4 4,151' 2-7/8"Screen:Bakerweld 12 ga.ID=2.441" Est.TOC @ 3,2505 4,237' Polished Bore Receptacle:ID= 2.062" 6 4,239' 2-7/8"Screen:Bakerweld 12 ga.Lower Tell Tail 7 4,249 Baker S-22 Snap Latch Seal Assy. 8 4,250' Packer:Baker'D'Sump ID=3.250" 9 4,253' 2-3/8"Pup Joint rfi, 10 4,259' 2-3/8"XN Nipple:Otis-ID=1.791"No Go 11 4,260' 2-3/8"WLEG-Bottom @ 4,261' PERFORATION DETAIL _ 1 Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status •" ,1.,. +2 "NB"Sands 4,164' 4,186' 4,000' 4,020' 22 10/27/89;11/13/90 Open 4 "NC"Sands 4,196' 4,202' 4,030' 4,037' 6 10/27/89;11/13/90 Open r i "NE"Sands 4,216' 4,228' 4,051' 4,062' 12 10/27/89;11/13/90 Open 'y "ON'Sands 4,305' 4,342' 4,140' 4,176' 37 10/07/1990 Open "OB"Sands 4,380' 4,398' 4,213' 4,231' 18 10/07/1990 Open N'Xi 'N'Sands 4-1/2"TCP Perf'd w/32gm 12 spf&24 gm 12 spf.;'O'Sands WL Perf'd w/37gm 5 spf �7$M1• NB 0 „ STIMULATION SUMMARY 'N'Sands Gravel Packed w/20/40 Sand 'O'Sands Frac'd w/83,086 lbs of YF140 r NE ..,.._0111.1E:1 GENERAL WELL INFO i4 API:50-029-21927-00 ' Drilled and Cased by Parker 141-8/22/1989 l. Completed w/Gravel Pack and Frac and ESP w/EWS#4-11/17/10 - �" CIE 8 WINJ Conversion w/EWS#4-2/03/1992 9 ' *Mg 10 a a 11 Fill @ . 4,351 �� = 8/25/12 C1 rCO langr C13 , ' 7 j "s "* lY' TD=4,740'(MD)/TD=4,563'(TVD) Revised By:STP 6/08/2016 PBTD=4,725'(MD)/PBTD=4,548'(TVD) • e Point Unit COIL BOPE MPU G-01 1/23/2017 1111..,e1,,rt, iia. 9,IJ(. MPU G-0l 13% x9%x 7x278 Coil Tubing BOP To injection head i 1.50"Single Stripper Lubricator e 0 4 ee ,0m 27 i 1111)1111 Blind ® 1/16 15 M.- Ella Blind I1I/'•\ 11)I6F•1111 Shear F= immix Shear 1111 •IJ 111.111111- •'111 Slip -111111 � �.. Slip ,I,'• ;11111111M IIIIIIIIIIII;;: 0.1111111 Pipe =� Pipe Mall � eft Crossover spool 4 1/16 15M X 4 1/16 10M est Crossover spool epi 4 1/16 10M X 4 1/16 5M ee .'pt Pump-In Sub 1 1 • I°° 11 4 1/16 5M •MI ; • • DM ... o d U K Z d' V K z K .�+ G r U I l.1 a .. • .. " • .. W• > PI .a .G W '6 < OUE 0 < OUp d 2 LLw 3 LLL '' i €` K N 2 b° a bDQ a a o A. y j > 3 3 > > c O > r+= m m L-:, 7' > 83 x �W o m m o C7 • v gi E":b z o o _ W B > c 'o,0 ' as a '^ }• .a w C7 0.1 U C..)WC) ..r 1- 3 o E i -V ks g • V(���:� 7.47.1e I Z § V A .. Alk 3 — y 17 Li t I 'SIN 7 : 1 IF ° ai 17......... 0 n n.. ,� .�i 1111::: :: 1191 9_ .; . ; ® as?o G C w Y L N Z W w Q 9 Lite' a LL U v v `v � V O O O O m w m ~ O c9 L^ a V ► Z ► m z I-"' w a a < 3 o Z o I- I- 2 m m R O D° m m O 0 a .• • 0 001 r> < I § § Prl ' • 1 Pe 0 74 - pg u u ce Zce d o Zo '6 2.:x0 ,.) E , - = ,....., ....... E „ 1- i = ,,,,„.7,--.e r-- ••• -g ''> It e • - F 5 tie - a. a. - 4 7 u -• w . o b -6 ,i, =E7, a• co cc, on .. . . . . 44 , . Z 73.E a i , a) 2 V f•-• • -DoioTatai— 4 P•.1 Pl. Z 1r VA .•4 OP. / NT-7 2 -Beitymoi-- . V t . ,111014006.1 7 1 0 i 1 0 i- f i_ --e?ri: X •- ' I . ' ...-.. '""'"•:;-= 1 , .1111 it In Mil .., siT tr 6COIV ' IMI 1 .*: 1111111E :-'b , -° L-. MU ill MN lull . T , , . -. r.1 Z LLI < i ..• .. ... .. lil , O. CC ''- ''l 1J U o 03 Ij2 03 0 0 ce LII p_ V Y Z .1 I- 2 co co o o ,.n 0;-- • • STANDARD WELL PROCEDURE FIileorpAlaska,LIC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,November 01,2016 TO: Jim Regg P.I.Supervisor \ 11(4"I1 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC G-01 FROM: Chuck Scheve MILNE PT UNIT SB G-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB G-01 API Well Number 50-029-21927-00-00 Inspector Name: Chuck Scheve Permit Number: 189-029-0 Inspection Date: 10/16/2016 Insp Num: mitCS161016145147 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well G-01 Type Inj W'TVD 3691 Tubing 881 - 880 880 878 PTD 1890290 Type Test SPT Test psi 1500 ' IA 197 2021 1955 1936 ------ ----- - --- ------- Interval 4YRTST P/F P '' OA 66 301 302 L 299 , Notes: SUMSf- ' k 2017 Tuesday,November 01,2016 Page 1 of 1 Im~roject Well History File Cov~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RES(~AN DIGITAL DATR [] Color items: [] Grayscale items: ~/' Poor Quality Originals: OVERSIZED (Scannable) [] Diskettes, No. [] Maps: [] Other, No/Type [] Other items scannable by large scanner [] Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERYL~/~INDY OVERSIZED (Non-Scannable) ~ ~rOf variOus kinds Scanning Preparation I,.-~ x 30= ~ O/O + c~.~ = TOTAL PAGES ~/~'~ I Production Scanning S~..e ~,~,~ oou.,,,o. ~.~..~..,..'- q / PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES~ NO BY: BEVERL~INCENT SHERYL MARIA WINDY DATE,~ Stage 2 IF NO iN STAGE 1, PAGE(S) DISCREPA~.~VVERE FOUND: ,¢:~_~YES ~ NO RESCANNEDBY; BEVERLY F~OBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (do.~) 12/10/02Rev3NOTScanned.wpd • • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: / ~~ ~~~~ FILE # ~ ~e To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission 1333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 yFax (907) 276-7542 1VIEl0~I®RA1~IDUM To: Jim Regg ~~ ~ I~~ ZLI ~r:~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector Mate of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 15, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC G-01 MILNE PT UNIT SB G-01 Src: Inspector NON-CONFIDENTIAL Reviewed By,~ P.I. Suprv ~ ~ - Comm Well Name• MILNE PT UNIT SB G-0 [ Insp Num: mitCS08 1 0 1 00 6445 5 Rel Insp Num: API Wett Number: 50-02 9-2 1 92 7-00-00 Permit Number: 189-029-0 -' Inspector Name: Chuck Scheve Inspection Date: Ioi9i2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j G-01 Type Inj. i w' ~ TVD I 3691 IA I soo I uao ~i zoso zoso ~ P T I Is9oz9o TypeTest I SPT Test psi Isoo OA j zao j azo I azo azo ~ Interval aYRTST P/F P -~ Tubing ~ Iooo ~ Iooo j Iooo ~ Iooo I ~ Notes' Pretest pressures observed and found stable. Well demonstrated good mechanica] integrity. ~ n~ ~~ r'1~ r1~it~^ Wednesday, October ] 5, 2008 Page 1 of 1 MEMORANDUM TO: Dan Seamount ~_..~ Commissioner THRU: Blair Wondzell P.I Supervisor FROM: John Crisp'~ ..Je~,~. ~,~.. Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: October 1, 2000 SUBJECT: Mechanical Integrity Tests BPX F & G Pads F-83i, G-01i,03i,05i,07i Milne Point Unit Milne Point Field NON- CONFIDENTIAL . Packer Depth ' Pretest Initial 15 Min. 30 Min. WellI F-83i [Typelni.! S [ T.V.D. I 6425 I Tubing [2200 [ 2200 12200 I 2200 [Interval P.T.D.I 2001030 ITypetestl P I Testpsil 1606 I CasingI 1900I 2680I 2660 ,I,,1265o I P/F I .P.P- Notes: ~,.,~,~,~ .............. . . · · . we,I G-03i IType,ni.I S IT.V.D. 1379~ ~oI ~o I ~'=° I ~'=° , P.T.D.I 18'{)0280,Typ~'te.stI 'P.. ITestpsil 948 ,ICasingl 950 I 2190 I' 2180 1'"121,75 Notes: WellJ G-05i I Typelnj. J S I T.V.'D. I 3929'J Tubing.J' 900 ] 900 I 900 I 900 'llntervalJ 4 P:T.D,]'.11~90460 ]TYpetest] P. ]TestpsiI 982 ]Ca~ingI 0' .] 1775 I 1750 I.. 1730 .] P/F ] P_., Notes: WellI G-07i I Typelnj.]. S I T.V.D. l'3963"1 Tubing[' 2000. I '2000 I 2000 I 2000 ]lnterva'lI 4 ]Typetestl P 'lTest psiI 991 ' 'Casingl 620 '1 2500 2480 2480' P/F P , P.T.D.I 189045.0 . , I . . I . I... I ~..I .- Notes: Type INJ. Fluid, Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER IN J, N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test I witnessed 5 successful IV[IT's ~ BP's MPU. Test's Details Interval I= Initial Test 4-- Four.Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) .I.T.'s performed: Attachments: Number of Failures: _0 Total Time during tests: 2 hrs. cc.' MIT report form 5/12/00 L.G. MIT MPU F & G Pads 10-01-00jc.xls 10/3/00 ORIgiNAL Conoco inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-76O0 February 13, 1992 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: Well Completion Report Dear Mr. Johnston: Attached please find a Well Completion Report for Well G-1. This well is located on the Milne Point Unit. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, Bob Soptei Environmental Coordinator RJS/bgs Attachments CC G-1 Well File Chevron Occidental Hal Stevens/Van Heare, MPOC (w/o attachments) \FUS\AOGCC29.RJS RECEIVED FEB 7 9 · a'8~Ojj & Gas Cons. (~ornmission Anchorage f ..... STATE OF ALASKA 0 R I 6 I N A L ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE IX3 I-~rv.,~,.r4,.~- Water Injection .... 2. Name of Operator VE,~.}F]~ 7. Permit Number Conoco Inc. ~..,.~ ~ 89-29 3. Addressg.H. ~ ~'~'~'~"i 8. APl Number Pouch 340045, Prudhoe Bay, Alaska 99734 ~i 50-029-21927 4. Location of well at surface COMPLETION 9. Unit or Lease Name 3644' FNL, 3346' FEL, SECTION 27, T13N, R10E, U~ A~='§~ Milne Point Unit At Top Producing Interval ,. ~/;Z..?'12.._ 10. Well Number 4610' FNL, 3294' FEL, SECTION 27, T13N, R10E, G-1 At Total Depth 11. Field and Pool 4760' FNL, 3250' FEL, SECTION 27, T13N. R10E. UM Kuparuk River/ 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Schrader Bluff KB 59.3' = 59.3 NSLI ADL 25906 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore 16. No. of Completions 8/11/89 08/19/89 11/~[ ~/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVO) 19."-DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 4950'/4584' ~725'MD/4548'TVD, YES [~ NO []] N/A feet MD] --+1800' 22. Type Electric or Other Logs Run DLL/ ~SFL/ LSS/ CF/ LDT/ CNL/ HR Dipmeter/Sidewall Cores/AND ~ud Logs/ GYro/ TDT-P 23. CA.SI'NC, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3.8" 48 H-40 SURFACE ll0'RKB 30" ARC. SET TO SURF. NONE ,, ','.i"',, 9..-5/8" 47 L-80 SURFACE 2618'RKB 12-1/4" 200 BBL PERMF .'E' NONE 96 BBL CLASS 'G' NONE 7" 29 L-80 SURFACE ~729'RKB 8-1/2" 50 BBL CLASS 'G' NONE "24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N SANDS 4164' (4002TVD) - 4228' (4064TVD) 2-7/8" 3848' 3848' 24 SPF BLANK' 4186 - 4196' .., 4202 - 4216' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC." DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,, , 0 SANDS 4305 (4140TVD)-4322 (4156TVD) N, 4164 - 4228 G~AVEL PACK 4322 (4156TVD)-4342 (4176TVD) 0 4305 - 4398 FRAC 1290 BBLS GELLED ... 5SPF 4380 (4213TVD)-4398 (4231TVD) WATER 83.086 LBS PROPPANT 27. PRODUCTION TEST Date First Production /Method of Operation (Flowing, gas lift, etc.) N/A (SUrface Modificationsl)~ N/A Date Of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO ITEST PERIOD , Flow Tubing Casing Pressure !CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. ' ..... cOI~'E DATA .... ..... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED N/A FEB 1 9 1992 Alaska Oil & Gas Cons. ~ohorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ GEOLOGIC MARKERS NAME Top Upper Ugnu Top Upper Ugnu Top West Sak MEAS. DEPTH RKB 3650' 3887' 4303' TRUE VERT. DEPTH RKB 3502' 3733' 4141' 30. , ORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS DailM Well ActivitM._R_~ports, Well sketch, Gyro Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Date 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 cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28: If no cores taken, indicate "none". Form 10-407 .t b,4'-- 4 1 ~f.,,' 4~,:,'- 4o ~~ ..t ~,c,'- 4z.,~z' 4.o~'- 4"o-~qr ztc/- qz.z.$' 4Cst'- RECEIVED FEB 1 9 t99~ Alaska 0il & Gas Cons. Commission Anchorage ! AOGCC GEOLOGICAL MATERIALS INVENTOHY LIST COMPLETION DATE form"received receiVed date ...... comments ................. ................................... 407 no report 403 --~ye s no sundry, application 404 ~ yes no report of sundry, application Open required received Cased required received Productior required received hole log hole log ,, .log ., DlUSFL ~ ~ CNL ...... P-nOD ~ CEll' PRESS BHC/SL CET SPIHNER ........ ,J .......... , ........................ ~.~.. ~ _~.J~_~ ...................... ~ ..................... BHCIAC E~ OTrtER DATA I_SS ~ ~~ nEC ~ ~ ~ ~~" .... , ................... _ , . ,, SSS PACKER Digital ~ ~ Data FDC- Well "FD~ RW'D .cquireJ-'" rcce~ ~PL~s 'r'equi,ed received LDT!CNL ~, ~ ~4~ ~ ~~ d. ditch .,, CYBER g¢~~ ~ ~ core [oo[ ~ ~ ~'~, . ~ ~ .~,,~w.~ .... ................... ..... --L--,..& .................... & .............. I I I I ............................ l-.-I ........................ J FEB 10 .'$~ 11:i5 FROM CONOCO RNCHORRGE , TO 46484 PRGE. 00E/0 ! 0 Hilne Point G No.~. i - WORKQVER.. API .No.: ~0-029-~927 Loomtion: Milne Point Field - SCHRADER BLUFF POOL ~FE ~Hb~: 10-61-1457 ~p~OV~: 12-12--91 AFE ~aotmt= $484,000 gross Cost to D~te= $ 478,996 gross Conoco Chevron OXY 0.5942340 0.3764866 0.0292794 obzieo~ives: Schrader Bluff Pool Rig, EWS;4 Rig Release Date: Drilling Completion Days: Workover Da~o: Test Planned Actual 14 Depth: N/A N/A I ECEi.VED _~_e , ~u*rent O~atio~$: Shows laSka Oil & ons. ommissio Anchorage 1/2o/g2: Continue moving Rig to G-1. A good portion of the Rig was snowed in due to a recent storm and most of the snow had to be removed by hand, which prolonged Rig move. Start heating 180 BBLS of 8.6/12% methanol brine for clean out. Continue rigging up. R/U lubricator and pull BPV. R/U and start circ 150 degree 8.6/12% methanol brine down the backside to surface. Taking returns to 300 BBL tank. Transport oil returns to ORT. Pump rate I BBL/min at 275 PSI. Complete circ. Set BPV and start N/D tree. ND tree and NU BOP and test to 3500 PSI. Contacted AOGCC Anch. GOt waiver from B. Wonzell for witness of BOP test. Could not get response on Slope. Notified Supv. System Specialist and Centralift service rep. Hold pre-job safety meeting with all hands before pulling pump. Give tour of rig to Russian visitors. POOH to top of floor with TBG hanger and test penetrator and power cable. RU cable sheave and continue to POOH with .ESP. Cut 250 cable bands. ESP at rig floor. Check motor for rotation. Motor ok. Pump and gas separator froze up .with frac sand. Take oil samples and make all required test and log on check sheets. Lay down ESP pump, seal amd motor. PU and RIH with Model S-22 Locater seal assembly w/4 add. Seal units size 80-40 on 2-7/8 EUE 8rd TBG. Sting into gravel pack packer at 3848'. PU 2' break circ. Pu~p 30 BBLS of 8.6 brine to clean top of packer, sting into packer. R/U wl unit RIH with 1-1/4" bailer. Tag fill at 4298' WI/~. POOH and RD WLU (Bailer showed frac sand). Press test back side and packer to 1500 PSI. Call out coiled TBG unit. Start getting equipment staged for clean out. 1/22/g2: Fracmaster on stand-by to complete clean-out of Frac sand above perforations with 1-1/2" coiled tubing. Unable to rig up on FI~B 10. '~gE I 1 : 16 FROI~! CONOCO RNCHORRGE TO 46484 PRGE.003/010 well due to temperature restrictions at -44 F. Filter diesel to 3 micron. Continue routine rig maintenance. Temp. has risen to -35 F and rising. Called out Fracmaster for hook-up of coiled tubing unit. Wait to rig up coiled tubing unit due to weather and crane limitations. Peak on the way with 140 ton crane. Fracmaster working on hook-up with EWS. Temperature still -34 F and rising. Temperature up to -30 F. Peak crane broke down. Oil line leak. Held pre-job safety and planning meeting. Remove guidelines from monkey board. Fold back monkey board from derrick. R/U Fracmaster using Peak 140-ton crane. Had to remove snow next to reserve pit in order to position crane. continue R/U on G-1 with coil tubing. Pressure test to 4000 PSI. No leaks. Temperature is back down to -30 F. Wait on approval to RIH with coil. Standby for weather break, Temperature -39 F. Continue with Rig maint, and clean-up. Held pre-job safety and planning meeting (temp. - 32 F). RIH with 1-1/2# coiled tubing to 1215' Having problems with fluid to pump. Ice plug in suction line from EWS pit volume tank. Found water in diesel. Replace hardlines and thaw out soft suction line. Drain water frombrine tanks untilclean diesel at suction. Coil displaced with methanol. RIH and established pump rate of .5 BBL/M and displace to 2000'. RIH dow~ to 3840' at top of Baker packer and pump at a..rate of .25 BBL/M through the XN nipple to 4270'. RIH at 15 ft./M. Rate at .25 BBL/M to 4317'. No indication of fill. PU to re-entry guide and increase rate to 1.3 BBL/M rate with 3735 PSI of pump pressure with good returns to surface. Pump 58 BBL of diesel down tubing up annulus with very little indication of sand (cup full). Continue to RIH at 15'/M taking 10' to 15' bites and picking up 50' checking for weight increase. Work down to 4400' and POOH to 4100' through the XN nipple with ID of 1.791". Still no indication of frac sand or a~ more formation sand across shaker. RIH at 15'/M with 1.3 BBL/M rate with pressure on back side of 50 PSI while taking returns. Continue to work coil back and forth slowly with good returns. No indication of fill. POOH from 4600' at rate of 25'/M with pump rate of 1.3 BBL/M. Lost returns at 457§'. POOH to 4526' before taking weight. PU to 23,000 lbs. and slack off to 0. Unable to reciprocate 1-1/2" coil. Continue to pump at 1.3 BBL/M while working pipe, total loss to formation 13 BBLS. Unable to get returns. S/D operation. Call out 10 BBL lite-sal pill and 8.6 PPG NACL. Will displace with diesel and squeeze into perforations to establish circulation. Transfer diesel from pill tanks in order to take pill. Clean pill tanks and vac out lines exposed to cold temperatures. Displace lite-~al pill (21 BBLS) down coil at .5 BBL/M rate. Spot pill in 7" through coil nozzle at 4526' Displaced pill with diesel. Slowly attempted to squeeze in perfs at .25 BBL/M. Saw very little indication of pressure build up. Annulus is in communication with perfs. Pressure increase from 0 to 10 PSI with valve on back side closed. Continued to squeeze pill at min rate down to .15 BBL/M. Pump total of 17 BBLS of 9.4 $ lite-sal pill in perfs and let set for 1 hour. Open valve on'back side, pressure bled to zero. FEB !O' '~E ! 1: 1G FROM CONOCO ANCHORAGE , TO 46484 PRGE. 004/0 ! 0 Slowly stage pump rate from .25 BBL/M to 1.3 BBL/M with no returns. Work coil PU to 17,000 over string weight and slack off to 10,000 lbs. with no pipe movement. Pum~a total of 70 BBLS. Continue to pressure up on Annulu~ to 2000 PSI and bleed off. Starting to pack-off on back side. Only able to bleed off to 1100 PSI. Bleed to zero, and stop operation. Order another 20 BBLS lite-sal pill to isolate the perfs if at all possible. Wait on pill delivery. Pump 20 BBL Lite-sal pill down coil and spot across perfs. Pump at .75 BBL/M rate. No indication of pressure build-up. Let set for four hours. Pressure up pill and squeeze into formation. Pressure building up ~mmediately. Press up to 2600 PSI and holding. Perfs are isolated. 100 PSI increase on the annulus. Pressure up on annulus to 2000 PSI and dump to 0 several times. No luck. Pressure up on coil to 4000 PSI. Formation holding like a rock. Pressure back up on annulus to 2000 PSI and dump to 0. Bleed pressure off of annulus to 0. Pull up to 27,000 lbs. with coil several times, would not give (20,000 Lbs. over string weight). Standby for Alaska Pipe Recovery to run free point, string shot and cutter (jet or chemical). RU 20' of scaffolding on rig floor in order to make cut on 1-1/2" coil in the morning. Held pre-job meeting with all parties. Cleanup and Rig maintenance. RU tie downs to injection head. Pull back monkey board. Release blocks from injection head, spot crane over injector and lift in order to cut 1-1/2" coil above Fracmaster BOP'S. Install clamp and set slips on BOP'S. cut coil in neutral position and RD injection unit off rig floor. Hold pre-job safety meeting prior to E-line rig up. Compete RU of E-line and 1" free point tool string. RIH with 1" tool string with 1" free point assembly. Checked free point in neutral position at 3000' (pipe free). Spot free point at 4000' and set tool. Pick-up 2000 lbs. above string weight. Indication shows pipe is free. RIH to 4249' at Baker S-22 snap latch with ID of 1&~9". Set tool and pick up 2000 lbs on coil, pipe is free. RIH to 4259' and set tool at Otis XNNipple with ID of 1.791w. Pick up 2000 lbs over string weight, pipe is free. RIH to 4360' and set tool at middle of "0# sand perfs. Pick-up 2000 lbs over string weight and saw slight bump at surface. Continue to POOH with 1-1/2" coil indicting a total of 17,000 lbs which include EWS Rig blocks. Pipe is free. Set up and make another cut on coil above the BOP'S. Set clamp an4 cut coil to keep from swabbing diesel above the wind walls. POOH with HLS E-line and 1" free point ass-mhly. RU blocks on clamp of coil and continue to POOH with 1-1/2" coil. POOH in 30' sections dragging 5,000 to 10,000 lbs. over string weight (cutting coil and laying back every 30'). POOH with 150' of 1- 1/2" coil before stacking out at 21,000 lbs over string weight. Micrometer indicates 1.482" OD on the coil. Close pipe rams and pressure up on annulus. Pipe rams will not hold. $/D operation. Call out chem. cutt. wait on 1-1/16" chemical cutter from Dresser. Repair seals on pipe rams of BOP'S. Will RIH and cut off check and 1.65" bull nozzle of coil. Hoping to establish circulation either on tubing or annulus. Ambient temperature is now a -38 P. Hold pre-job safety meeting. RU FEB .10' '~ II :18 FROM CONOCO RNCHORRGE TO 4~484 · PAGE .00~/0~0 Dresser Atlas with 1-1/16" chemical cutter. Cut off all radio communication. Replace slips in Fracmasters BOP'S. Set coil in neutral positionand remove clamps. Cut coil prior to pack- off installation. Had problems stabbing chemical cutter in coil due to slight bend in coil. RIH with 1-1/16" chemical cutter with CCL and tag at 4351', 91' from wireline entry guide at 4260'. Pickup 15' to 4336' and spot chemical cutter. Will let set for 1.5 hours in order to obtain recommended temp's. Exposed to ambient temp's, of -38 F for Min of .5 hour. Spot 1-1/16" chemical cutter at 4336'. Wait on approval to cut at depth. Fired cutter, coil. pressure increased to 225 PSI at surface. Saw no pressure on annulus 2-7/8" x 1.5". Attempted to POOH with E-line CCL and tool string. Unable to POOH. Worked back and forth. Pulled 1700 lbs over hang weight before it broke free. POOH with 1-1/16" tool string. Rig down Dresser Atlas. Start rigging up to install tubing clamps in order to POOH with coil. Started getting returns on the 2-7/8" x 1-1/2" annulus. S/D a~d monitor. Rig up lubricator on top of BOP's with pack off. Hook up lines to try to pump down both the tubing and the annulus. Attempted to pump down back-side at 750 PSI, without success. Switch to tubing and pump at 1/4 BBL/M at 650 PSI. Pump 12 BBLS of diesel down tubing. Switch back to the annulus and pump to 750 PSI. Pressure bleeds to 250 PSi in i min. Continue to rotate back and forth trying to establish circulation. Annulus still flowing. Check pressure on the 7" x 2-7/8", gauge indicates 800 PSI. Bleed pressure from annulus, and pressure up, unable to pu~p. Pressure apparently not bled off from packer test last week. Continue to pressure up on the 2-7/8" x 1-1/2" annulus to 1000 PSI and bleed back to 700 PSI. Total 8.6 PPG brine pumped down the annulus is 3 BBLS. S/D and monitor returns. Returns starting to slow dOwn to a min. Continue to pump down the backside. Temperature is now -43 F. Unable to rig up Inj. head. Increase pump pressure on annulus to 1200 PSI and bleed to 1000. Continue to pump down the backside. Diesel migrating to t~e surface. Starting to pack off on backside. Pressure up to 1400 PSI and s/d for 15 min. Bled to 1300. S/D check flow on annulus. Flow on annulus has increased. Total BBLS down backside of 8.6 PPG is 3 BBLS. RU and pump 7 BBLS down coil tubing at 1/4 BBL/M (550 PSI) with annulus open, no increase in flow. Increase to .60 BBL/M, pressure (800 to 650 PSI), lite- pill is breaking down. Still getting brine returns on the annulus. S/D and evaluate. A~bient temperature is still -43 F. S/D due to ambient temperature -45 F. Routine rig maintenance. RD Dresser Atlas and send to Deadhorse until temperature breaks. Will make chemical cut above the gravel packer in order to establish cir. and balance hole. Send the Peak 140 ton crane back to Deadhorse, along with Fracmaster. Ail equipment is now on standby rates. Open annulus, flowing on backside. Routine rig maintenance, temperature is still -44 F. Attempt to pump down the annulus at 1400 PSI with little success. Able to pump I BBL before packing off. Well is still giving up fluid on the annulus. Isolate annulus. Temperature -44 F. FEB !0. '5IF. 1 1 : 151 FFROM CONOCO RNCHORR6E 1'0 415484 , ,~' PRGE.OOG/O10 Continue to pump down the 2-7/8" x 1-1/2" annulus at 1400 PSI w/min rate. Pumped 6 BBLS down the annulus before rate increased and pressure decreased. Checked the 7" casing. Pressure had built up to 900 PSI. Apparently seal assembly is now leaking. Opened up 7" and pump down the 2-7/8" x 1-1/2" at 1/4 BBL/M. Returns now on 7". Have pumped a total of 16 BBLS down the tubing and coil annulus. S/D and open the annulus and check for flow, well is dead. Monitor for one hour, still no flow. Start setting up equipment to rig up POOH with 1-1/2" coil tubing. RD lubricator and install 2 - 1-1/2" clamps, release slips and pipe rams after latching elevators. Held pre-job safety and planning meeting. POOH with 1-1/2" coil. Initial pull was 2,000 lbs over string weight, max has been 10,000 lbs where nozzle apparently broke off. Pulling out of hole above the XN nipple with the 1.791" ID with string and block weight only. Have pulled 540' for a total of 685' since we stacked out on Friday. Bottom of coil is at 3827' which is 71' above the Baker gravel pack assembly, includes the 15' we cut off and dropped in the 7" casing below the packer. Held safety meeting with new crew. Continue to POOH with 1-1/2" coil tubing. Still pulling string weight w/3100' left in the hole. With 34 cuts made for an average of 37'/cut. Continue to POOH 1-1/2" coil. Have made 56 tubing cuts for a total of 2072'. Break for lunch. Continue to POOH with 1-1/2" coil. Have made 81 cuts with 1158' left in the hole. 1-30-92: POOH with 1-1/2" Coiled tubing. Total cuts made (121) with a length of 4512'. Rig down Fracmaster. Pressure up on 7" x 2- 7/8" annulus to 1500 PSI for 20 minutes. Held like a rock. HOOk-up and pump down the tubing. Pump 1.125 BBLS down tubing before pressure stacked out at 1400 PSI. Apparently bridged off down hole above the "N" sand perfs, or the screens are plugged off and the XN nipple is bridged over. Pumped 20 BBLS down the coil 2 days ago at I BBL/M rate at 650 PSI. Work on removal of coil tubing out of pipe shed and rig maintenance. S~ng out of packer at 3848' and reverse cir. tubing and casing volume. Repair seal on Fart Tongs; leaking oil. Load 1-1/4" CS hydril in pipe van with working toolm. Work on Fart Tongs. Load pipe on racks. POOH with 2-7/8" EUE 6.59/ft, tubing and Baker seal assembly. Complete weekly BOP test, AOGCC did not attend. RIH with 434' of 1-1/4" CS hydril, XO to 2-7/8" 6.5~/ft tubing to top of Baker packer at 3848'. Break circulation in order to establish a rate on returns before entering seal bore. Increase rate to 2 BBL/M. 01-31-~2: Reverse cir. a total of 156 BBLS of 8.6 NACL to balance hole. Some returns as light as 7.3 PPG, apparently part of the lite- sal pill and diesel mixture. RIH with 1-1/4" CS hydril and 2- 7/8" EUE tubing into 'sealbore of gravel pack packer, slowly making hole w/rate of 2.5 BBL/M taking returns across the shaker. Make 5' of hole and pick-up 30' Increase pu~ap rate to 3.2 BBL/M at bottom of each tool ~nt., for bottoms up returns. Pump press up to 800 PSI. Mule shoe down 120' below the top of the Baker gravel pack packer. Continue to RIH reverse cir. at a rate of 2.5 to 3.5 BBL/M and taking retUrns over shaker. Little sand down to 4120'. 44' from top set of FEB. 10' 'S~ Il:IS FrOM CONOCO ~NCHOR~GE TO 46484 Pt::IGE. 007/010 "N" sand perf *s. ~rocess of filtering 8.6 PPG NACL to 10 Micro while circulating. Work on ~hawing out line to slop tank. Will cir. HEC 3. $#/BBLS pill at 4262 ', 4 ' below entry guide. Changed out shaker screens to 80 x 120 mesh, both upper and lower. Ambient temperature is -46 F. Formation now taking fluid, press ~roppe~ from 800 PSI at 3.0 BBL/M rate to 600 PSI at same. Total fluid loss to formation once through the UN" sand perf is 80 BBLS. POOH w/1-1/4' CS hydril and place mule shoe 30* above top of Baker gravel packer at 3818'. L~t set for a couple of hours before RIH and tag. RIH .slowly, did not tag any sand. Set mule shoe on bottom of 1-1/4" CS at 4262', 2' below the entry guide. Reverse circulate bottoms up with no sand returns. Mix 5 BBL 3.5~/BBL HEC pill and reverse c~r at 2.0 BBLS/M. Total fluid circulated 170 BBLS. Received pill across the shaker with carbolite and formation sand. Roughly 20 LBS of sand mainly carbolite. PU 30' out of XN Nipple, pipe is free. RIH and set mule shoe back at 4262'. Reverse cir another 5 BBL HEC pill, total cir. 170 BBLS at 3 BBLS/M. Received 15 lbs of carboli~e with small amounts of formation san~. Total fluid loss during last cir. was 50 B~LS of 8.6 PPG NACL. PU 30~ out of XN nipple, pump down the tubing at a rate of 2.0 BBL/M at 450 PSI. RU to POOH with 1-1/4" CS hydril 2-7/8" EUE slowly. Press up one more time once above the ~aker packer to make sure hole is clear. 02-01-92~ POOH to top of ~aker gravel Pack packer at 3848* and pump 2 BBL/M rate at 300 PSI in formation. Increase p~mp rate to 3 BBL/M at 4§0 PSI. Internal packer clean. POOH and lay down 1- 1/4" CS hydril (14 joints). PU Baker seal assembly and 2-7/8" 6.5#/ft tubing and RIH to sting into gravel pack ~acker at 3848'. Test 7" annulus to 1500 PSI before spacing out tubing hanger and seal assembly. Space out tubing hanger. Start circ 8.6 with 12% methanol brine with packer ~luid at 1-1/4 BBLS at 160 PSI, no returns. Landing joint and kelly hose froze up before getting returns. Break out joint and replace kelly ho~e steam out TIW valve & rig back up. Continue circ brine methanol. ~-tube methanol but could not blee~ press to 0 to s~ing into packer and lan~ tubing hanger. Got with ~ruce Augustine to talk over alternatives. We decided to blee~ off methanol & try diesel. Circ. methanol out of hole. Pl.~p 75 BBLS diesel down CSG. R/U and U-tube diesel back to tubing. CSG & tubing equalized at 100 PSI. Cannot sting into packer and land tubing with this press on well. Note: Got Frac sand back when we circ. methanol out. 02-02-92= Continue to try and get pressure off CSG and tubing. Both are equalized at 100 PSI and are trying to flow back. Continue thawing out Kelly hose and stand pipe on rig. R/U to bullhead 11 PPG brine down tubing to kill well. Start pumping 11 PPG · brine down tubing at I BBL/M at 250 PSI. Pump away 6 BBLS down tubing at 225 PSI, CSG 200 PSI. At 10 BBLS away tubing was 175 PSI, CSG 250 PSI. At 14 BBLS away, tubing was 50 PSI, CSG 300 PSI. At 25 BBLS away, tubing was 0 PSI, CSG 350 PSI. Stop pumping at 1320 hrs. Press coming down on CSG very slow. Pressure continuing to drop by 1530 hrs; CSG at 0 pressure. Check CSG for flow; very little. R/U to sting into packer and land tubing. RIH try to sting into packer at 3848'. Coul4 not FEB .IO "~ ll:ZO FROM CONOCO ~NCHORRGE TO 464134 P~GE .008/010 sting in. Rotate tubing to try and sting in. After several attempts we damaged the ~eals and also lost a piece of the snap ring on tubing hanger. Piece went down hole. Snap ring piece 1/8" round by 7" long. POOH and lay down tubing hanger and re- dress. RIH to check that we can still sting into packer. Had to rotate to get in, but no problem. P/U tubing hanger RIH and sting into packer & land hanger. Run in lock down screws. R/U & p~st CSG side to 150_0_~. Bri_ng up_to 1500 PSI in ~~-g-'"~JT';' .............. ~e-t--g~i%/. ~)D BO-----~' N/U t----~ee. Set two way check & test to 5000 PSI. Test ok. Remove two way check and set BPV. Pump 15 BBLS of diesel down tubing for freeze protection. Start rigging down to move to G-3. Note: held safety meeting for all EWS hands and also Baker & WKM hands. STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLI'CATTON FOR SUNDRY APPROVALS OR IGIN 1. Type of Request: Abandon Suspend m Alter casing Repair well Change approved program Operation shutdown Re-enter suspended well Plugging __ Time extention . . Stimulate Pull tubing X Variance Perforate Other X Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 3644' FNL, 3346' FEL, Sec. 27, T13N, R10E, U.M. At top of pmduclJve interval 4610' FNL, 3294' FEL, Sec. 27, T13N, R10E, U.M. At effective depth 5. Type of Well: Development X Exploratory StralJgraphic NSB AK NSB AK At total depth 4760' FNL, 3250' FEL, Sec. 27, T13N, R10E, U.M. NSB AK 6. Datum elevation (DF or KB) KB 59.3' (MSL) , 7. Unit or Property name Milne Point Unit 8. Well number G-1 9. Permit number 10. APl number 50-029-21927 11. Field/Pool Kuparuk River/Schrader Bluff feet 12. Present well condition summary Total depth: measured true vertical 4740' feet Plugs (measured) feet None Effective depth: measured 4641' feet Junk (measured) true vertical feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 75' 13-3/8" Surface 110' 110' surface 2583' 9-5/8" Surface 2618' 2514' Intermediate Production 4691' 7" See Attached 4726' 4549' Perforation Depth: measured 4164'-4186', 4196'-4202', 4216'-4228', 4305'-4342', 4380'-4398' true vertical 4000'-4022', 4031'-4037', 4051'-4063', 4138'-4174', 4211,~f12_:~9' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EuE, 3789' MD Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal X Detailed operations program m BOP sketch 14. Estimated date for commencing operation I 15. Status of well classification as: January 15, 1992 16. If proposal was verbally approved Oil X Gas Suspended Name of approver Date approved Service ~ '''/~ c3 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ']~.Z~- ~~B. G. Augustine Title Sr. Production Engineer FOR COMMISSION USE ONLY Conditions of approval: NOtify Commission so representative may witness Plug integrity BOP. Test Location clearance Mechanical Integrity Test ~.~ Su---'bsequent form required 10- [Approval No. 9 / - ~.~ ~' SIGNED ORIGINAL / .~ ! Approved by order of the Commission Commissioner Date /C;~ -- ~, Form 10-403 Rev 06/15/88 LONNIE C. SMITH '' SUBMIT IN TRIPLICATE LOCATION TWP. OIL BPi). WATER ," lIFO.GAS MCFD 'R~D: 01~ ~BPO. WATKR' BPD.~S , EMP . fJ ,4P ' AND SiZE WELL DATA .- ~O..TY ~,F.r~ .r'~ .ATE NEW FLIGHT SIZE FRO~ TO M~XIMUM PSm USED ALLOWABLE ~BING OPEN HOLE SHOTS/FT. PKRFORATIONS PIRFORATIONS ' ,. . PERFORATIONS DATA . .. - CALI.~D OUT ., --. ON LOGA~TION STARTED MATERIALS . .. ·: :, .,-, PERSONNEL AND SERVICE UNITS UNIT NO. 8~ TYPE LOCATION CUSTOMER ,LS ' REPRESgNTATIV& OPERATOR ....]..¥..~' ,~' ,:"'. .:' CEMENT DATA PRi SUMMARY VOLUMES ~ / 'J' ' PAD: '~B~ L*'GAi :. : ,. HyDRAULI REMAR KS CEMENT '~' FOR FIELD OFFICE '*'~PUMPS~. -':?'PRI~SSTJRIK (PSI} ~TUBING CASING , .. DESCRIPTION OF' OPI~RATION AND MATE~RIAI-S CASING AND CEMENTING · Ground Elevation: RKB- Grd. E].ev.:. ~.~.'77 TOD of ltanger-RKB: ~-~-"~.~ (ft) Maximum Recorded Temperature from Logging Runs 55 "F Casin~... Ta. lly . ~O~'C~-~ ~¢ No.. pieces Size - Weight - Grade -.Thread -..Etc. .Length ~Depth_ / ........ H~ Toe% ~ 28.69 ~ , , , _ · , _ _ Centralizers and Spacing / 2~kO 0¢~ 6~V ~ 3¢,,,,,r,, ~/~..!0~ ~0 ~ I Zl %q4,-{ O.Ol~ ~.,c~- kal / ' cement (sta~e zz) ~s o¢,, ,~ ~or I~C,cM6c~.. ,. "Time Started Circulation Stage I Stage II ~/~ '------- Displacement @ OF Time Completed Rate (BPM) PSI (max.) 2~% ~ -7 fi'cc> · Z~Sq 7 '7 __ i~1 a% , (Why Stopped) C~33~3'{T ,a-~c~-hfC ~, No) Bottom Plug: Total Pumped Di~j~ I-~ (bbls) Floats Held: ~ No) Full Returns: ~, No~ Cement Returns to Surface: (Yes, No) Initial String 'Weight:_.l~ ~ (lbs) Final Landing Weight : ~_~ Servi. ce Co..~. ,~(-t-t~C}~-~(>~ Perfo~.anv: ~%, Fair, Poor) Date. C~//Z//a.~ Supervisor... ~.., ~,~R ,. Top Plug: ~ No) Bumped Top Plug: e~s~.~ ~':o) 'ZcX~iS_.psi ~ 0 BBLS (lbs) ~LNE POINT UNIT ~-~ CONVERT TO ~N~ECT~ON S~Y PROCEDURE 1. MIRU EWS #4 rig. 2. Kill well with 8.5 ppg NaCl. ND production tree. NU BOPE and test. 3. POOH with tubing, ESP, and ESP cable. LD ESP and cable. 4. RU slickline unit and RIH with wireline tools. Tag fill. 5. POOH with wireline and RD unit. 6. RIH with seal assembly on 2-7/8" tubing and sting into gravel pack packer at 3848'. Pressure test annulus to 500 psi. 7. RU coiled tubing unit. RIH with coiled tubing and circulate out fill to PBTD. 8. POOH with coiled tubing and RD coiled tubing unit. 9. Pull out of gravel pack packer. Space out tubing. Circulate in packer 'fluid. Sting back into gravel pack packer and land tubing hanger. Pressure test annulus to 500 psi. Pressure test hanger to 500 psi. RDMO rig. 10. ND BOPE and NU production tree. 11. Prepare well for injection. BGA- 11/21/91 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 July 8, 1991 Mr. David Johnston Commissioner, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Johnston: RE: Sundry Approval Application Attached please find Applications for Sundry Approvals for Wells G-1 and G-4 at the Milne Point Unit. If you have any questions or require additional information please contact me at 564- 7617. Yours very truly, Bob Soptei Environmental Coordinator RJS Attachments cc Well G-1 File Well G-4 File RECEIVED JUL 1 1 1991 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend Operation shutdown Re-enter suspended well Alter casingL Repair well m Plugging__ Time extenfion Stimulate__ Change approved program__ Pull tubing __ Variance Perforate Other X Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5. Type of Well: Development Exploratory Stratigraphic Location of well at surface 3644' FNL, 3346' FEL, Sec. 27, T13N, R10E, Umiat Meridian At top of productive interval 4610' FNL, 3294' FEL, Sec. 27, T13N, R10E, Umiat Meridian At effective depth 4730' FNL, 3254' FEL, Sec. 27, T13N, R10E, Umiat Meridian At total depth 4760' FNL, 3250' FEL, Sec. 27, T13N, R10E, Umiat Meridian 7, 8o 10. 11. Datum elevation (DF or KB) (KB) 59.3' feet Unit or Property name Milne Point Unit Well number G-1 Permit number 89-29 APl number 50-029-21927 Field/Pool Kuparuk River/Schrader Bluff 12. Present well condition summary Total depth: measured 4950' feet true vertical 4584' feet Plugs (measured) None Effective depth: measured 4647' feet true vertical 4472' feet Junk (measured) None Casing Length Structural Size Cemented Measured depth True vertical depth Conductor 110' 13-3/8" Surface 2618' 9-5/8" Intermediate Production 472~ 7" Uner Arctic Set to Surface 200 bbl Perm F 'E" 96 bbl Class "G" 50 bbl Class "G" 110' 2618' 472~ 110' 2514' 4552' Perforation Depth: measured 4164'- 418~ 4196'- 4202' 4216'- 4228' 4305" 4342' true vertical 4000'- 4022' 4051'- 4063' 4031'- 4037' 4137'- 4174' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 3803' with ESP Packers and SSSV (type and measured depth) 4211'- 4229' REEEIVED J U L 1 1 t991 Alaska 0il & Gas Cons. CommissiOn Anchorage 13. Attachments None DescriPtion summaryof proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation July 30, 1991 16. If proposal was verbally approved 15. Status of well classification as: Oil X Gas__ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~, ~.l~~B. G. Augustine FOR Title Senior Production Engineer COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test m Location clearance Mechanical Integrity Test ~ Subsequent form required 10-'~r ORIGINAL SIGNED BY Approvea Copy Approved by order of the Commission LONNIE C, SMITH J=teturped "7//'~/~/. Co__mmissioner Form 10-403 Rev 06/15/88 ..... ' IApproval No. SUBMI'r IN T~IPLICATE (~ C~ I~ILNE POINT UN'rT AN OUT FILL ~ RUN NEW E[ PROCEDURE 1. MIRU EWS #4 rig. 2. Kill well with 8.6 ppg NaCl. ND production tree. NU BOPE and test. 3. POOH with tubing, ESP, and ESP cable. LD ESP and cable. 4. RU slickline unit and RIH with wireline tools. Tag fill. 5. POOH with wireline and RD unit. 6. RIH with seal assembly on 2-7/8" tubing and sting into gravel pack packer at 3848'. Pressure test annulus to 500 psi. 7. RU coiled tubing unit. RIH with coiled tubing and circulate out fill to PBTD. 8. POOH with coiled tubing and RD coiled tubing unit. 9. POOH with 2-7/8" tubing and seal assembly. 10. PU new ESP, motor, and cable. RIH with ESP assembly and tubing. of pump at 3815'. 11. ND BOPE and NU production tree. RDMO rig. 12. Return well to production. Set bottom RECEIVED dUL 1 19 1 Alaska Oil & Gas Cons. Commission Anchorage 12051 RIVERA ROAD SANTA FE SPRINGS. CA.90670-.2289 Pr~S ~ S A M P L REQUEST DATE: ORIGINATOR: CORP: ~o~o ~ o WELL: C-/ FIELD: /~/~£ Pr ADD SHIP CHANGE RECEIVE (circle one) J.O. # : GEO/ENG: E TRANSACTION DATE: TRANSFER PERSON: SAMPLE DESCRIPTION: T' CURRENT LOCATION TRANSFER TO: ~ ATTN (LAB/P'ERSON) N S F QT~~LETS : LOCATION: T. C K E T SHIPPING CO. SERVICE TYPE AIR: TRUCK Rush Express SHIPPING BILL NO. COST: WEIGHT · · PHONE: Next Day 2nd Day Standard Refrigerated (circle one) DATE: Economy Castiac PREPAID: COLLECT: STA.'~E OF ALASKA (' ALASKA(~i'L AND GA~ CONSERVATION coMMIssION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL.% GAS ~ SUSPENDED L~ ABANDONED [] SERVICE · _ 2. Name of O.ator I LOCATIONSI CONOCO INC. VER'IFIED I 340045 PRUDHOE B&Y, ~K 99734 4. Loca,lon of well at ,urface '-'~'~',,,~i 3644w FNL, 3346' ~ B~C~ZOM 27~ ~13~ At Too Producin~nterval 4610' FNL, 3294' FEL~ At Total Depth 4760w FNL, 3250' FEL, Classification of Service Well SECTION 27, T13Nv R10E, OM 7. Pe~it Number 89-29 8. APl Number 500_29-21927 9. Unit or Lease Name 10. Well Number G-1 11. Fieid and Pool KUPARUK RIVER FIELD SCHRADER BLUFF POOL SECTION 27, T13N, R10E, OM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease D~ignation and Serial No. KB 59.3 ~ = 59.3 MBL I ADL25906 12. Date Soudded ! 13. Date T.D. Reacted I 14. Date Comp., Susp. or Aband. i 15. Water Depth, if offshore i 16. No. of Completions o8/11/89 I 08/19/89 I 11/17/90 I ' 17. Total Deoth (MD+TVD) /18.Plug Back Deoth IMO+TVD)I 19. Directional Survey I 20. Del=th where SSSV set I 121. ThicKness of Permafrost -- I N/A 4950'/4584' f725 ' MD,/4548 ' ~F{;~s~ NO[] feet MD I'['1800 ! 22. T¥l=e Electric or Other Logs Run DLL/ MBFL/ LBS/ GF/ LDT/ CNL/ HR Dipmeter/Sidewa11 Cores/AMD Mud Logs/ 23. CASING, LINER AND CEMENTING RECORD ~yro/TuT- SETTING DEPTH MD ! TOP BOTTOM HOLE SiZE CEMENTING RECORD AMOUNT PULLED , 00 BBL NONE TUBING RECORD PACKER SET (MD) 4250' CASING SIZE WT. PER FT. GRADE 7" L-80 A E' i729' 24. Perforations open to Production (MD+TVD of To~ end Bottom and interval, size and number) N SAt~"DS 4164' (4002TVD) - 4228' (4064T¥ 24SPF BLANK~ 4186 - 4196' 4202 - 4216 (4156TVD) (4176TVD) (4231TVD) 25. SIZE 1 DEPTH SETIMD) D)"-2 7/8h'I 3803 N 4164 -4228 3848' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) i AMOUNT & KIND OF MATERIAL USED GR~VEL PACK (4140TVD) -4322 (4156~¢D) -4342 (4213~¢D) -4398 i t O S]~TDS 4305 t 4322 5SPF 4380 127. 0 4305 -4398 PI:~C 1290BBLS GELLED WATER 83t086 LBS PROPPANT PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.), 10/27/89-11/01/89 Electrical Submersible Pump DST' S IOI L GRAVITY-APl (Corr) 'Flow Tubingpress. 70 II casing Pre"ares0 124-HOuRICALCULATEDRATE I~' OIL-BBL GAS-MCF WATER'BBLI 15.0 28. CORE DATA Brief description of iithoiogy, porosity, fractures, apparent dips and presence of oil, gas or wale r. Submit core chips. · · · Core chips wz11 be delzvered separately. Bee attachment for discription p, ECEIVED DEC 2 61990 Form 10407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC NAME Top Upper Ugn~ iTop Lower Ugnu Top West Sak MEAS. DEPTH RKB 3650t 3887t 4303~ TRUE VERT. DEPTH RKB 3502 3733 41410 31. LIST OF ATTACHMENTS Gyro Log, Daily Reports, Core Description FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 32. I hereby certify that the foregoing Is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and tog 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 cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 NILNE POINT G-1 CORE DATA Core Cored Actual Rec ~1, ~ Sand Silt 1 20 15.6 46 54 2 31 30.0 18 82 3 31 20.3 25 75 4 30 24.7 22 78 5 28 29.7 48 52 6 30 15.6 0 100 7 15 14,8 16 84 8 2 6.6 0 84 9 32 27.6 44 56 10 26 28.0 81 19 11 30 11.0 0 100 12 17 30.8 23 77 13 30 23.1 6 94 14 14 3.6 0 100 15 18 24.6 0 12 Clay 88 DEC 261990 N~,~i! .& Gas ~us. mmlss! n Activity: ~ u 1,1 ~ 5 i::> Zone(s) Open: ,' ~ '"' ., ,,, Weather: Wind: ow ~ @ Kts.; Gusts To: Kts.; Temp: -2' <3 °F/ oF WC; Visibility: ~ ~ Mi. From To Daily Operations ,~¢~;/~:o~P-.T.~ ~., ~Th Esi:' '~.'/3 FT )~o ,/,/o,=7' ,/_/-/- ,¢'{/~, /~ - ~o l~o wt oF' Esi:' f~'T 3 ~ 6 3 , 3'~ 'F1' i~.UR S'le'~v'~ Well Bore Fluid, Prope~ies: Type ~ ~ [ ~ ~/~/~-~ ~/ Weight: ~. ~ M~ / ~//z ~/~ ~ Total Fluid Produced: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Visc. Sec. .,,,., BPV~Out SSSV: Open/Clos~ N o V~ I u¢ Downhole Plug: Yes Depth Type Se~ice Personnel: t% ~ ~ / ~ ~ = ~ / ./ ~¢ ~0 Rig: ~ ~ ~ ~ I Supe~isor: ~. ~ ~ ~ % ~--(~ Daily Cost Estimate: $ ~S1~5o ~ Cum. Well/Activi~Cost:$ 9~15/~ I Auth. Amt:$ ~Z ~, Co, noco, Inc. ( Daily Well Activity Repo(, ~ Alaska Activity: ~/Zvq-,c) ~ I ~t/~, ~_t~,L Zone(s)Open:'~ J~J," I~N.(~ "CD" ,.-~'~',-~, t~ ~ Weather: Wind: I,,.J @ /~3 Kts.; GustsTo: l o Kts.; Temp: /~ OF/ ~ oYWC; Visibility: C~ Mi. From To Daily Operations T~'-5'7-~- 0 o ,~' ~-4r~, o uT /,./,5,'-/~J 5~,,~//u,,~./$~.-~,- /~ ~ ' . /^, ,/-?//-'-~=,~1~ T' 7'o /~/z..,,~,//,~. ~/,,,'~-~ /~,g~.~7' /),~'/," Well Bore Fluid, Propenies: Type /~/~//~/~-~ / Weight: ~, 7 ~ m~ / ~/ Total Fluid Produced: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Visc. S~. Total Fluid Lost: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. BPV: In ~ ~~~ Downhole Plug: Yes Depth Type SewicePersonnel: I ~ ~/ ~ ~c~/u~~ ~ ~~ - T~c/+ ~ Rig: ~s ~ ~ ~ Supewi~r: ~ ~u~~ Daily Cost Estimate: $ 191 ~ 0 ~5 ~ Cum. Well/Activi~Cost: $ E~ ~ ~ ~ ~ Auth, Amt:$ ~~, Conoco,, inc. Daily Well Activity Rep Alaska Weather: Wind: @ Kts.; Gusts To: Kts.; Temp: °F/ oF WC; Visibility: Mi. FromTo Daily Operations · tt~b "-l'~A,,w6 PO,P T5 · Pu & ' ,~,,~b 4' Pt, tp d Td To · _ o~ t~q.¢o f~,~",5,pq,~,e' 6lP c~ -Fn 15'~m PS/ "fo "F~T P/dP. ~z~ 7~.-r. · //,,6' Iz~$ ~ ,~r ~~'/ P~/( C/~-~/~1 ~ ¢ ~ ~/ Well Bore Fluid, Propeflies: Type Weight: Total Fluid Produc~: Last 24 Hfs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hfs. BBLS, Cum. BBLS, Type , Weight PPG, Visc. S~. .,, ~ ~ Downhole Plug: Yes Depth Type , SewicePersonnel: I~~. /H ~Ii~~O~, ~Y~ ~P~) ~ ~~ , Rig: ~,~ ~ ~ ~ ISupe~is°r: d, ~--~~ I I" Daily Cost Estimate: $ ~ o/ ~ ~ Cum. WelllActivi~Cost:$ ~OZS~ Auth. Amt:$ ~ ~ ~ ~~... ~Conoco,, Inc. Daily Well Activity Rep~'rt( Alaska Well: tqQ I'~ (~-I ! Date: '/,/' ' ~"',/~/) I AFE/Facility: ~Y'~Ic''~:~ / ~ 0 ¢~ ICum' Days fOr Activity: Activity:~/Z}q~:::71 ~"~iA~C..lC' Zone(s)Open: /~ y~-Nb '~0~ ~ i~L'I~ Weather: Wind: @ Kts.; Gusts To: Kts.; Temp: OF/ oF WC; Visibility: Mi. From To Daily Operations ,~x,,' ,~"/~,/b ,/~.z~.~x,' ,,~,u',,3 ,D~-.s~ ~,,/z~ 7-~ 7-. ~ o o F p_.e Po,~T b~-r~ , DEC 2 81990 , ,,,,,, ~aSEa Oil & '' ~chora~ Well Bore Fluid, Properties: Type Weight: Total Fluid Produced: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Visc. Sec. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Visc. Sec. BPV: In/Out SSSV: Open/Closed Downhole Plug: Yes Depth Type /No Service Personnel: Rig: I Supervisor: ! I Daily Cost fistimate: $ I Cum. Well/^¢tMty Cost: $ I ^uth. ^mt: $ ..... f Conoco~ inc. Daily Well Activity Rep~"rt Alaska - T m · Well: /7/p~ G-/ J oate: II/,.,~//qo J AFEIFacility: ~"~=' /,~Oe m cum. oaysforActi~: Weather: Wind: ~ ~ ~ ? Kts.; Gusts To: ? Kts.; Temp: W OF/ --~ oF WC; ~sibil~: 7 Mi. From To D~ly O~rations -- O~~, ~2/~/ - Well Bore Fluid, Propenies:Type Ra,~ /~e OH Weight: f, ? p~ ~aC I ~//~% Total Fluid Pr~uced: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Visc.. S~. ~ut ~ Downhole Plug: Yes Depth Type , / ) I Rig: ~ ~ ~ / ~ ~ Supewisor: H, & TZ V5~5 ) ) -Conoco, Inc. Daily Well Activity Rep~,,t Alaska Activity: Zone(s) Open: , Weather: Wind: @ Kts.; Gusts To: Kts.; Temp: oF/ oF WC; Visibility: Mi. From To Daily Operations . _ 2~ ~ RIH oN 2~1,° ?~G , ~~r~ T~ ~H~~ ,, ,, I Well Bore Fluid, Propeflies: Type Weight: ,, Total Fluid Pr~uced: Last 24 Hrs. BBLS, Cum. BBL8, Type , Weight PPG, Vi~. ~. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~. BPV: In/Out SSSV: Open/Clos~ Downhole Plug: Yes Depth Type /No i ii Se~ice Personnel: --,, I Rig: I Supewisor: .... I I Daily Cost Estimate: $ ~ Cum. Well/Activity Cost: $ I Auth. Amt: $ .. Conoco, inc. ('~ Daily Well Activity Re~,urti~ Alaska P,95£ , ,9 p. 2.. · i i ,ct~,w: Rz-P[eFoR4~ 'W" ~~ Zon~s)O~.: ~'~¢ ~" Weaher: Wind: 5 ~ ¢ ~ Kts.; Gusts To: ~ Kts.; Tamp: 3 OF/ -- ~ oF WO; ~sibiliW: ~ Mi. FromTo Daily O~raions ~ moo D~eP ~~ . Mo I~A/~ T/~ oF ~/~ ~ 173oI~I ~lY ~/ ], P.G// LII~ , T~ ~ Y~ q~/ ~L~, bF Well Bore Fluid, Properties: Type ~ { ~¢~Z /~/M~ Weight: Total Fluid Pr~uced: Last 24 Hrs. ¢ BBLS, Cum. BBLS, Type , Weight PP6,. Vi~. S~. Total Fluid Lost: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. Sec. ,! ~ S?'"~""°'"'~ OownholePlug~ Depth 9~P Ty~ /No Rig: ~ ~ ~ ~ ~ Supe"isor: E, 5~~5 . Daily Cost Estimate: $ ~3,/~.~ ~ Cum. WelllActivi~Cost:$ ~/.~? ~ Auth. Amt:$ ~, ~~ ' C(=noco, Inc. Daily Well Activity Report Alaska · · Well: m P/,/' t~ '-- [ I Date: /]/! '~//¢] O I AFEI Facility: /~ ,F',~'"/.'=j'Z~) :~ I Cum. Days for Activity: ( O Activity: Zone(s) Open: Weather: Wind: @ Kts.; Gusts To: Kts.; Temp: °F/ °F WC; Visibility: Mi. ii From To Daily Operations , ,, D~= F/~//u~. ., , ,, i Well Bore Fluid, Properties: Type Weight: Total Fluid Produced: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Visc. Sec. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight . PPG, Visc. Sec. BPV: In/Out SSSV: Open/Closed Bownhole Plug: Yes Bepth Type /No Service Personnel: _ Rig: I Supervisor: . , Daily Cost Estimate: $ I Cum. Well/Activity Cost: $ I Auth. Amt: $ _ Conoco; inc. ( Daily Well Activity Re rt Alaska Activity: ~,N ,~U,~P P,("/~///¢£- Pz'RF'~e,47'£ Zone(s)Open: ,b,~,M.,O ,~/~ n Weather: Wind: 55/4/' @ /b-" Kts.; GustsTo: 30 Kts.; Temp: J ~ OF/ --~Zl/ oFWC; Visibility: ,.~ Mi. From To Daily Operations w - - . -- R,~ ~n No b~~ PooH. Total Fluid Pr~uced: Last 24 Hrs, ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, risc. ~PV: ~/Ou~ - ~ Downhole Plug: Yes Depth Type , Se~ce.ersonne~= / ~~Sj ~ ~~ ~ ~~~X~, / Daily~ostEstimate:$ ~, ~ ~ Cum. Well/~ctivi~Cost:$ ~ ~ ~ Auth. Amt:$ ~,~ _ Conoco, inc. Daily Well Activity Rel~urt Alaska Activity: Zone(s) Open: Weather: Wind: @ Kts.; Gusts To: Kts.; Temp: OF/ oF WC; Visibility: Mi. From To Daily Operations 1")~-~i,13~2 .D~RI$ ,ff~'z5 I,¢/15~,,e~"/c, lP ~,,,¢K, ~#~¢~-~z' 5,~,'=~rP' 5~)'~. C./I,,~ml2 3 P/<'R, t?T'7-,5"'5,,~f.z'=7¥ UT') t3i~..dotlN , Well Bore Fluid, Prope~ies: Type Weight: Total Fluid Produced: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~; S~. BPV: In/Out SSSV: OpenlClos~ Downhole Plug: Yes Depth Type INo JR Sewice Personnel: Rig: ~ Supewisor: .. I ~a,~ Cos~ ~s~a~e= ~ ~ C~. ~e,~c~v~ Cos~= ~ ~ ~u~,. ~= ~ Conoco, inc. Alaska Activity: - Weaher: Wind: ~ ~ ~ Kts.; Gu~sTo: ~ Kts.; Temp: --/~ OF/ --/~ oFWC; ~sibilW: , ~ Mi. From To Daily O~rations . , . - , ¢ , , Total Fluid Produc~: Last 24 Hrs. ~ BBL8, Cum. BBL8, Type , Weight PP6, Vi~. S~. Total Fluid Lost: Last 24 Hrs. {O BBLS, Cum. BBL8, Type , Weight PP6, Visc. S~. . .... BPV: In/Out S88V: Open/Closed Bownhole Plug: Yes Depth Type INo i Se~icePersonnek / ~m-~; ~ ~~3 ~ ~r O;z 5~U . Rig: ~~ Daily Cost Estimate: $ Conoco, Inc. Alaska Activity: ?~,~'7" ~'--~/~_ ~,~-~/~)--~6/-~ Zone(s)Open: ~~D ~~.~ Weather: Wind: ~5 ~ ® /~ Kts.; Gu~sTo: /~ Kts.; Temp: --/~ OFI -~ oFWC; Visibil~: /~ Mi. From To D~ly Q~rations - ~ /H ~ ~ ~2~~ .~ ~ . C~~/ ~/u~ Well Bore Fluid, Prope~ies: Type fl~/~./~ OH Weight: f, 4 Total Fluid Pr~uc~: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Visc. S~. Total Fluid Lost: Last 24 Hrs. . ~. BBLS, Cum. BBLS, Type , Weight PPG, Vi~.. S~. ~t ~u. ~-~_ ~,--~ Downhole Plug: Yes Depth Type III Rig: ~~ R'~1Supe.i~r: F, ~V~/W, Da,yCo~Es~=,~e:S ~, ~/~ ~ Cu~.We,/,o~i~Co~:S ~, ?~ l,u~.,m~:~ ~. ( Conoco, Inc. Daily Well Activity Re'port Alaska · , i Well: /r~p/_,,( ~ -/ IDate: 1!//~//~¢'2 [ AFEIFacility: ~F~/~ ~ ] Cum. Days for A~i~: ~ A~ivi~: F~~ ~" ,~~5 Zon~s)O~n: ~ o ~ ~ n Weaher: Wind: ~ ~ ~ / ~ Kts.; Gusts To: / ~ Kts.; memp: -~ ~ OF/ - ~ 0F WC; ~sibili~: ~ Mi. , ..... From To Da~ O~raions ~7~qz~' LO~ ~2~~ T~ ~-~'.. ~ ~b ~P - Well Bore Fluid, Prope~ies: Type ~ t ¢ 4 / ¢ e ~ Weight: ¢, ¢ pp~ Total Fluid Pr~uc~: Last 24 Hrs. BBLS, Cum. BBLS, Type ,-Weight PPG, Vi~. S~. Total Fluid Loa: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vim. S~. ,, BPV: In/Out SSSV: Open/Olos~ Downhole Plug: Yes Bepth Ty~ /No ii Daily Cost Estimate: $ ~3,9a? I Cum. Well/Activi~Cost:$ ~n~, /~ ¢ J Auth. Amt:$ ~Z, Conoco, Inc. Daily Well Activity Re'port Alaska ?,ee4= 2,~F- 2 Activity: Zone(s) Open: Weather: Wind: @ Kts.; Gusts To: Kts.; Temp: °F/ oF WC; Visibility: Mi. il FromTo Daily Operations , 51TP '= ~ 5/¢P ---_&z:) , C ,~ ~ ,F'x.o~,'/4,,~ . . ~.~ ~ ¢ ~ P o o I-I ~, I ~ '7/e " 7"/3 ~ ,, , ,,,, Well Bore Fluid, Properties: Type Weight: Total Fluid Produced: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~c. Sec. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Visc. Sec. BPV: In/Out S$SV: Open/Closed Downhole Plug: Yes Depth Type /No Service Personnel: ,, Rig: J Supervisor: I i Daily Cost Estimate: $ J Cum. Well/Activity Cost: $ J Auth. Amt: $ 15. Pump the frac job as follows, or as re-design indicatesz iii ii~ii Stage Fluid Prop Pump Stage Cam. Stage Cum. Name Name Conc Rate Vol. Vol. Time Time ppg BPM bbl bbl min min Pad YF140 0 25 762 762 30.5 30.5 '~Slurry YF140 2 25 104 866 4.1 34.6 Slurry YF140 4 25 185 1051 7.4 42.0 Slurry YF140 8 25 180 1231 7.2 49.2 Flush WF140 0 25 28 1259 1.1 50.3 When pumping the frac treatment have the rig pump lined up to pump brine down the casing. Pump brine at minimum rate during frac treatment. Monitor pressure. 16. Shut down. Allow the pressure to bleed off into the formation. Record the ISIP, and pressure for 30 minutes. Close all surface valves and leave the well shut in. Monitor the break time of the last sample collected. Rig down pumping equipment. 17. After adequate break (based on surface s~mples) release packer and allow fluid level to stabilize. Reverse circulate the tubing until clean brine returns are stable. POOH. Fill hole when pulling tubing to compensate for the tubing removed from the well only. Do not attempt to keep the hole full to surface. This may result in large volumes of fluid lost to the formation. 18. After the frac treatment there is a possibility of proppant in the wellbore. Rig up slickline and RIH with a sinker bar to insure the perforations are clear. Tag bottom to identify the amount of proppant in'the casing. Rathole should be sufficient to prevent proppant from covering the perforations. If the bar tags proppant in the perforation interval then GIH with bailer to remove proppant from the well to clear the perforation interval. Use the tubing bailer with sufficient barrel length. Rig down slickline unit when complete. Conoco, Inc. Daily Well Activity R urt Alaska Activity:~~ ~,. ~)~ 'r,~ /L"'/~('~ t~) ,, Zone(s) Open: \ N / 5 ~ ~ CI<'~ ~'~' Weather: Wind: ,,~ ~ @ ~ Kts.; Gusts To: g Kts.; Temp: - f~ i/ OF/ -- j~/ OF WC; Visibility: /O Mi. From To / ',-,~ Daily Operations ~',~ ~/~~,~ ~~ o~ ~,"T~.: ~_,~~, ~"~s - . - . Well Bore Fluid, .rope.ies: Type Weight: LS~ Total Fluid Pr~uced: Last 24 Hrs. BBLS, Cum. BBLS, Type. , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. , ~ -~88v: Ops~/g~cscd Downhole Plug: Yes Depth Type _ Daily Cost Estimate: $ ~ ~ ~ I Cum. Well/Activi~Cost:$ ~, ~.~ I ~uth. Amt:S ~,~., Conoco, Inc. Daily Well Activity Re~ort Alaska Activity: Zone(s) Open: Weather: Wind: @ Kts.; Gusts To: Kts.; Temp: °F/ oF WC; Visibility: Mi. From To Daily Operations , , ~ P~ P5 / ~Pm P~ y~/~o ~~ ~ ~,~ ~P~ ~~ - ~9~,~ P~I ,,, ,,, , ,, , ,.,, Well Bore Fluid, Prope~ies: Type Weight: Total Fluid Produc~: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. , Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. BPV: In/Out SSSV: Open/Clos~ Downhole Plug: Yes Depth Type /No Sewice Personnel: ., Rig: ~ Supewisor: _ ~a,~ cos~ ~s~a~e: ~ ~ Cu~. We,~c~v~ Co~: ~ J ~u~. ~: ~ . *Conoco, Inc. Alaska Activity: ~,__..,,.~ O. OT ~ u...t~'~~e:~-- W~ther: Wind: ~ ~. ~ { q Kts.; GustsTo: Kts.; Tempe I OF/ ~ ~oFWC; ~sibi,~: 7 Mi. From To Da~ O~rations I Well Bore Fluid, Prope.ies: Type Total Fluid Produced: Last 24 Hrs. / BBLS, Cum. / BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. BPV: In/Out SSSV: Open/Clos~ Downhole Plug: Yes Depth Type /No a i Se.~oe,e~.onne.: i~ ~~ Rig: 6~S ~~ ~q J Supewis0r: d. Fo N .l Daily C°s' Estimate: $ lB. ftl J Cum. Well/Aotivi~ Cost: $ Conoco, Inc. ( Daily Well Activity Ref~' . t Alaska Activity: %~t(..C. C)oT ~__..~V ~'~~64~=~ Zone(s)Open: \ J~ ! Weather: Wind: ,,,, ~ @ ~ Kts.; Gusts To: q ~ Kts.; Temp: [~', OF/--~ oF WC; Visibility: ~ Mi. From To Daily Operations ,,,,, , ,, Well Bore Fluid. Prope.ies: Type ~C'/~~ S~,.~ Weight: ~/~, ~~ ~.~~ . Total Fluid Pr~uc~: Last 24 Hrs. ' BBLS, Cum. BBLS, Type , Weight PPG, Vi~..... S~. Total Fluid Lost: Last 24 Hrs. BBLS, Cum. BBLS, Type , Weight PPG, Vi~.... S~. ~ 3SSV; Ow,,/C;o~ Downhole Plug: Yes Depth Ty~ Se~icePersonnel: ~ ~~ ~ ~~ ~ ~~., . . Conoco, Inc. Daily Well Activity RePort Alaska _../ / Weather: Wind:~ ~ ~ ~t Kts.; Gusts To: 3~ Kts.; T emp= ~ OF, --S ~WC; ~,N,~ ~ Mi. From To DNN ~mt=ns , , Well Bore Fluid, Prope~ie~: Type ~. Total Fluid Pr~uoed: L~t ~4 Hm. ~ BBLB, Oum. BBL8, Type. , W.ight PP~, Vi~.. 8~. Total Fluid Lorn: L~8t ~4 Hm. ~ BBLB, Oum. BBLB, Typ~ , W~ighl PP~, Vi~. / ~ ~ Dow~hole Plu~ Depth q II O Ty~ C~ ~ /No ~a,,Cost ~t~a,e:; I Z ~ 0 Conoco, Inc. Daily Well Activity R oft Alaska Well: p\t t...["4~,"'~(~£ i'-t'~' ~'- I I Date: I ~/(~3~)/(~(~ I AFEIFac,I~: ~ ~ ~ I Cum. Days for Act~: [ Weather: Wind: ~ ~ I~ Kts.; GuasTo: ~q Kts.; Temp: ~70Fi ~ oFWC; ~b,l~: S/q Mi. From To D~ly O~mtions i / ' ~ ' , , i We, Bore F~uid, Propsaies: Type q. ~ 7~ Nq~ ~/Weight: Z~ ~ ~ e ~~ .. Total Fluid Pr~uc~: Last 24 Hrs. ~ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. Total Fluid Lost: kast 24 Hrs. ~/ BBLS, Cum. BBLS, Type , Weight PPG, Vi~. S~. BPV: In ..... ~ .... ~--~,0,, i Ciuaud Downhole Plug Depth ~ O¢ Ty~ ~ ~ /No STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION RECEIVED: DATED: Copy sent to sender YES NO ~ 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 SAMPLE ACTIVITY RECORD P.T.S. HOUSE RE. CE VED DE~, 0 i t989 RECEIVED SHIPMENT TRANSFER ~ DELIVERY PRE PAID COLLECT NORMAL ~'/ DEADLINE: uuNTAINERS: * * * * * * * * * * PALLETS. · * * * * * * . * * * * * * * * * * * * * , DELIVERY BY: DATE SHIPPED o¥: .. DATE: FINAL DISPOSITION OF MATERIAL RETURNED TO COMt~az'~z CONSUMED STORAGE: AMBIENT COOL FRO ::, O? q7 t LI" %? t L. ( '?:,i"'-~} '.'3) · l.~/~g ~ '39) 75) 1111 ' .:;~.?,./ - . · .... ..~ , '.. ~ 8> :HHH'2" %> 80) " ' " , - :.~ ' ,, / ' , ~ " . , ~,~) ~4~" ~t) ..... 8~) , . ~g) ,. , ..: - ~2)':' q ~ ~t,~ '- ~8) , .- , 8~) . ,, · ..,./ zs).: '~l~ ~ ~ 49), .~5) .'. ,~) . . - k~2) ~ q g~ .58). · '. .,..'. 94): N23). M;,! .('.~ ,, , 59) .... 955 ~ .... 975 . 1335 _ . .' ;.l.q &l -". ., s~. ... ~ - - . : " . · ~- ' · . . '~? ,~,~: :,:'::: 28~-., ~.... H- H' ~ ~. .-. . ,.,.,,,, . ~... , . , . ,68) 69) 70) · ......~ \ ., _103,) 10.4) 105) 106) 1'073 . · ' ios) 144) · I : . ~1~'1 -1 LI! .gl 36) :¢ 144) .. · Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 November 9, 1989 Alaska Oil and Gas Cc, nservation Com~lission 3001 Porcupine Dr. Anchorage Alaska, 99501 Attention: Mike Minder Mike, Enclosed please find Completion Repc, rts for- Mi lnm Point wei Is G-2, G-3 & G-4 i n duplicate wi th appropriate a t t achment s. I have also included a Report of Sundry Well Operations for well ~ As we di s~cussed on Thursday, Nc, vmr,~ber 9, this well was perforated, flow tested and then ~~ were~hut down as per Sundry Applications sub~itted in late October and early November. I have enclosed some infor~ation on the results of the flow test for you and Russ Douglas to lc, ok at. If you would like ~orm data please feel frme to contact me or Steve Rossberg. Mr. Rossberg has told ~e that this infor~ation and so~,~e additional ~cts should be co~ing to you with a Petition for Pool Rules for this producing interval. I can be reached at Mi Ine Point. My phone number is 659-6452. Steve Rossbmrg can be found in Anchorage at 564-7637. Si ncc. tel y, Steve Brady, Sr. Production Specialist RECEIVED NOV 2 1989 AJaska.Oil &/;as Cons. Comm/ssffor~ '~ Anchora~ . i STATE OF ALASKA CONFIDENTIAL A(, (A OIL AND GAS CONSERVATION COMI~ "ION REPORF OF SUNDRY WELL OPL.C. TIONS 1. Operations performed: Operation shutdown -X. Stimulate __ Plugging __ Perforate ~ 0 J'"~ ~ ~ Pull tubing __ Alter casin~ __ Repair well ~ Other 2. Name of Operator CONOCO INC. 3. Address ~01 C ST.: .~TF.. 2NN; 4. Location of well at surface 5. Type of Well: Development __ Exploratory --X- Stratigraphic __ Service __ 3644' FNL, 3364' FEL, SEC 27, T13N, RIOE, U.H. At top of productive interval 4620' FNL, 3300' FEL, SEC 27, T13N, RIOE, U.N. At effective depth N/A At total depth 4779' FNL, 3293' FEL, SEC 27, T13N, RIOE, U.N. 6. Datum elevation (DF or KB) KB 28 7. Unit or Property name 8. Well number 9. Permit number/approval number 10. APl number 50-.. 029-21927 11. Field/Pool feet Upper Cretaceous - SOS 12. Present well condition summary Total depth: measured 4740' true vertical 4563 ' Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 13 3/8 2590' 9 5/8 4698' 7 measured 4164'-4186', true vertical 4004'-4025', Tubing (size, grade, and measured depth) 2 7/8", feet feet Plugs (measured) Junk (measured) Cemented Measured depth 100 CF 200 bbls E 96 bbls G 50 bbls G 108' 2618' 4726, 4196'-4202' 4216'-4228' 4034'-4040', 4054'-4066' 6.4 #/ft, L-80, EUE e 4170' Packers and SSSV (type and measured depth) EZ Drill Bridge Plug e 4110' True vertical depth 108' 2513' 4548 ' RECE!vED,,, 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure .Oil.& Gas Cons, Com~i$$1.ot~ ~ '-Anchora~ : 14. Prior to well operation Subsequent to operation Representative Daily Average.production or Injection Data Oil. Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure See attached flow test summary Installation of Bridge Plug & S/D Operations 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations -X- 16. Status of well classification as: Oil--.X. Gas __ Suspended __ Service 17. i hereby cedify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE DAILY DRILLING REPORT Anchorage Division 10-30-89 FINALS ON COMPLETED DRILLING WELLS None DRILLING WELL COMMENCEMENTS None DRILLING WELLS None DRILLING WELLS COMPLETING RECEIVED NOV 2 1989 0/1 & Gas Cons. Commission ' 'Anchorag~ Kuparuk river - SOS - North Slope Borough, Alaska W.I. 1.000000% Milne Point G No. 1 (SOS REW) CONFIDENTIAL AFE 10-61-1203 Location: 3420' FEL, 4060' FNL, Sec. 27, T13N, RiOE, Umiat Meridian Bottom hole location: 3,281' FEL, 4,707 FNL, Sec. 27, T13N, R10E, Umiat Meridian Objective: 4,660 MD - Shallow Oil Sands 10-27-89: RU E-Line Unit, RIH log w/GR and CCL from 4025' to 3500'. Space out tubing, set packer at 4093' MD. RU E-Line Unit, RIH log w/GR and CCL to verify setting depth of perforating guns. RU flow lines to tubing. Drop bar and detonate perforating guns, perforate w/12 spf 4164'-4186', 4196'-4202' and 4216'-4228'. SI pressure 240 psi after 15 min. Open well up to test separator, intermitten flow rates, recovered 51.4 BBLs of total fluid. EWS 94 (0-13-3) AUTHORIZED COST: $2,922,000 COST TO DATE: $1,287,123 10-28-89: Continue flow test, flow rate 14.45 BLPD w/0.2% to 2 % water with trace of solids to 0.2%, Gravity 15.03 to 15.5 API at 60 degrees F. Attempt to RIH with HP pressure gauge, could not get to bottom. Cycle Omni valve reverse out fluid in tubing with 9.0 ppg brine. SI well for bottom hole pressure build up. Recovered 60 BBLs of total fluid on initial flow test, total of 24 hrs. EWS 94 (0-13-4) AUTHORIZED COST: $2,922,00 COST TO DATE: $1,321,747 10-29-89: Continue 24 hr. shut in for bottom hole pressure build up. Release packer, circulate 9.0 ppg brine, POOH with tubing, lay down BHA and perforating guns. Preparing to pick up Centrilift pump. EWS 94 (0-13-5) AUTHORIZED COST: $12,922,000 COST TO DATE: $1,343,747 DAILY DRILLING REPORT Anchorage Division 10-31-89 FINALS ON COMPLETED DRILLING WELLS None DRILLING WELL COMMENCEMENTS None DRILLING WELLS None DRILLING WELLS COMPLETING Kuparuk river - SOS - North Slope Borough, Alaska W.I. 1.000000% Milne Point G No. 1 (SOS REW) CONFIDENTIAL AFE 10-61-1203 Location: 3420' FEL, 4060' FNL, Sec. 27, T13N, R10E, Umiat Meridian Bottom hole location: 3,281' FEL, 4,707 FNL, Sec. 27, T13N, R10E, Umiat Meridian ObjeCtiVe: 4,660 MD - Shallow Oil Sands 10-30-89: Fill hole w/30 bbls. 9.0 ppg brine. PU Centrilift pump, motor, seal and gas separator. RIH w/centrilift equip, and tubing. Set pump at 4096' MD, splice cable, tie into tubing hanger and land in wellhead. N/D BOP, N/U tree. start pump, present rate is 440 BLPD on 24/64 choke. EWS 94 (0-13-6) AUTHORIZED COST: $2,922,000 COST TO DATE: $1,396,747 FINALS ON REMEDIALS None FINALS ON RECOMPLETIONS None REMEDIAL/RECOMPLETION WORK None PLUG AND ABANDONMENTS None FINALS ON PLUG ABANDONMENTS None RECEIVED NOV 2 ~ 1§89 ,~:<~iasl¢a Oi~ & Gas Cons. Commission Anchorag~ DAILY DRILLING REPORT Anchorage Division 11-01-89 FINALS ON COMPLETED DRILLING WELLS None DRILLING WELL COMMENCEMENTS None DRILLING WELLS None DRILLING WELLS COMPLETING Kuparuk river - SOS - North Slope Borough, Alaska W.I. 1.000000% Milne Point G No. 1 (SOS REW) CONFIDENTIAL AFE 10-61-1203 Location: 3420' FEL, 4060' FNL, Sec. 27, T13N, R10E, Umiat Meridian Bottom hole location: 3,281' FEL, 4,707 FNL, Sec. 27, T13N, R10E, Umiat Meridian Objective: 4,660 MD - Shallow Oil Sands 10-31-89: Continue to flow test; 1407 psi BHP, 360 BLPD. Increase pump speed; 1398 psi BHP, 661 BLPD. Continue at same speed, sand production increased to 20%, water cut 15%, and 230 BLPD. RU to kill well. ND tree, NU BOP. Test BOP to 3000 psi. Start pulling tubing. EWS 94 (0-13-7) AUTHORIZED COST: $2,922,000 COST TO DATE: $1,469,210 FINALS ON REMEDIALS None FINALS ON RECOMPLETIONS None REMEDIAL/RECOMPLETION WORK None PLUG AND ABANDONMENTS None FINALS ON PLUG ABANDONMENTS None DAILY DRILLING REPORT Anchorage Division 11-02-89 FINALS ON COMPLETED DRILLING WELLS None DRILLING WELL COMMENCEMENTS None DRILLING WELLS None DRILLING WELLS COMPLETING Kuparuk river - SOS - North Slope Borough, Alaska W.I. 1.000000% Milne Point G No. 1 (SOS REW) CONFIDENTIAL AFE 10-61-1203 Location: 3420' FEL, 4060' FNL, Sec. 27, T13N, R10E, Umiat Meridian Bottom hole location: 3,281' FEL, 4,707 FNL, Sec. 27, T13N, R10E, Umiat Meridian Objective: 4,660 MD - Shallow Oil Sands 11-01-89: Continue to POOH. Lay down Centerlift pump, etc. RIH to tag fill. Fill tagged at 4148' (20' above top perf). This will be the last report until the permanent completion is run in this well; approximately in the summer of 1990. EWS 94 (0-13-8) AUTHORIZED COST: $2,922,000 COST TO DATE: $1,493,110 FINALS ON REMEDIALS None FINALS ON RECOMPLETIONS None REMEDIAL/RECOMPLETION WORK None PLUG AND ABANDONMENTS None FINALS ON PLUG ABANDONMENTS None DAILY DRILLING REPORT Anchorage Division 11-03-89 FINALS ON COMPLETED DRILLING WELLS None DRILLING WELL COMMENCEMENTS None DRILLING WELLS None DRILLING WELLS COMPLETING Kuparuk river - SOS - North Slope Borough, Alaska W.I. 1.000000% Milne Point G No. 1 (SOS REW) CONFIDENTIAL AFE 10-61-1203 Location: 3420' FEL, 4060' FNL, Sec. 27, T13N, R10E, Umiat Meridian Bottom hole location: 3,281' FEL, 4,707 FNL, Sec. 27, T13N, R10E, Umiat Meridian Objective: 4,660 MD - Shallow Oil Sands 11-02-89: RIH and tag fill at 4156'. POOH. RIH w/ bridge plug and set at 4110' test to 2000 psi POOH to retrieve setting tool EWS 94 (0-13-9) AUTHORIZED COST: $2,922,000 COST TO DATE: $1,525,110 FINALS ON REMEDIALS None FINALS ON RECOMPLETIONS None REMEDIAL/RECOMPLETION WORK None PLUG AND ABANDONMENTS None FINALS ON PLUG ABANDONMENTS None TIME 0650 0700 0 750 ,08C$O (:)850 0900 0950 10Cx) 1030 110(~ 1150 1200 1300 1530 14 () 0 1450 1500 1550 1600 16~0 1700 1750 1800 1850 1900 1930 ;2050 2100 2150 ": 2230 2300 ~"~ 2530 2400 0130 0200 '02~0 0500 0550 0430 ()500 W. H, (DEG. f'EMF' F ) ,,..., $ 6 C) 58 57 58 56 58 58 59 6(") 59 ~'.-.i~'.' L b. :i. .UEL. L G-1 FLOW TEST' OCTOBER 28,.::~"- 29 i989 TBG,. PRESS (F:'SIG) ~,DEG. AF' I) (BP~:,) I 0 t. 5.4 i 9 % I,,.~A"['ER % SOL I DS 1 0.2 15. J; /' ':.,:. 2 0. 1 15. :l. !. 1 C". 7 0. 1 10 5 11 10 10 15. ]. 2(]) 0.6 C). 1 15. 1 25 0.4 0 ,J 1 '"' = (') o 15. 1 4(:) 15. 1 62 7 0.2 15. 1 4(-') 7 0 ''.~ ,-,. 1 62 6 15. 1 14 10 ~. I 1 () 0.4 0.2 2 (-) RECEIVED NOV 2 4 1989 Naska 0il & Gas Cons. Commissiort , ~ ~nchorag~ ' ,~.T IME .., 01 O0 0200 0300 0400 0500 0600 0700 O.800 0900 1000 11 O0 1200 1300 ~ 1400 ~ 500 . 1600 ~ 1700 1800 ~900 2000 W.H. (DEG. TEMP F) 20 20 18 17 16 22 32 28 28 26 26 26 26 20 20 2() 22 26 MF(" ~ELL G-1 F'UMP "I-EST OCTOBER 31,1989 TBG. PRESS GRAVITY RATE % WATER % SOLIDS (PSIG) (DEG. AP1) (BF'D) 10 15.1 324 94 0. '.2 10 15.1 890 100 0 10 15 · 1 ~-:'T ': 1 (:x') t r ac e 198 15.1 5(.)8 50 ('-). 2 260 15.1 441 20 0.1 · ?.-]0 15 1 421 52 O. 230 15.1 .321 17 0.2 54 ~5.1 361 12 O. 1 53 15. I 481 73 1.5. 1 :360 4 ,L.). "2 ¢ 45 15.1 521 20 O. 6 40 15.1 401 50 0.8 4O 15. 1 5e 1 .30 15. 1 561 25 1.5 ._~J 15 1 521 · , 1.2 15 15.1 281 20 3 10 15. 1 200 19 3 12 15 ! '.~.?r) :50 :-:_'~.~ 18 15. 1 440 :55 15 RECEIVED ~igdre ]), Estimated compressive strenaths ~n ~r'~m ](~O ~o 700 ps~. Jhe well w~,~ perforated a t'u~l cu~umn ot diesel, providing ~pprox~mately completion was in accordance with PER rmcomme~da~O~S 278.1 md-ft/cn ...... ~ :~r laboratory ana:-;¢~s Sand samples we~' :o .-,:r:':~v~r.~:.:; .. '.,'om Painter November 6, 1989 Page 4 ~..,,~..S~,_~P. Pump Test Approximately 150 bbls of 9.0 ppg NaBr/Methanol brine were the welt. The completion string was tripped out of the hole run. The test unit consisted of test. .,':iq. ) 5 . I 0 l :].. 15. : 1' . 1 15. 1 1:~. i i 5. t 15.1 "5 ,. $ . I 0 7 O0 0800 1 1 O0 1 ~ O0 14 O0 1500 17,) 0 l 1.%. i t=.,. I 15.1 15.1 ',5.1 1~..i IE,.1 11.~. I r~ 15. t ~'._. L 1.75 '-' '.72L L ~,69L. !,66 SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS '77251-2175 l(I)¥ I ~ lggo CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Ltneberger ~SE REPLY TO SCHLUMBERGER WELL ~ICESPouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bern/e/Shelley Gentlemen: Enclosed ore_2_BL_prints of the Compony CONOCO, Inc, Well . Mtlne Point I]n'Jt Field M:I ine Poi nt Additionol prints ore being sent to: I BL prints CONOCO, Inc .... 600 Nort.h Dairy Ash. ford. Houston, TX 77079 Attn: George Lamb - OF 2018 PEK Gravel Pack Log (TDT-P), Run 1, 11/15/90 , on: _ County North S]ope Stote Alaska ~rints, 1RF Sepia .1000.South Pine Ponca City, OK 74603 .Attn: Log Library I BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Mt d !_~ n__d_~d .._T_X. ........ 7 9_7_ L0, Attn: John Carrol *(915/685-5600) ~rints, I RF Sepia Chevron U.S.A. =,11111 South WJlcr~t. _ _Houston.. T~ 77~qq Attn: Priscilla MacLeroy ,'713/561-3652 I BL 1RF Ala 011 & Gas ;ion Porcupine Drive ge, AK 99501 tn: John Bo* prints prints prints RECEIVED ,IU ~ t/ , ,,~,v 2 I i990 The film is returned to Conoco, Log Library. We oppreciote the privilege of serving you. ReceJ ved by; .......... Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M. Saalwaechter DISTRICT MANAGER SWS-- 13274' A(,_, STATE OF ALASKA ,ON ,$KA OIL AND GAS CONSERVATION COMM ;...., APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon __ Susoend __ Operation shutdown __ Re. enter susoendecl well __ . Alter camng __ Rel3a~r well Plugging __ l~me extensIon £tirnulate A. Change approved Drogram __ -- Pull tulmng __ Variance __ P'~'orat( z~ O-~r ~ 2. NameofOperator · Conoco Inc. Addre~ 3201C St, Suite 200, 99503I Anchorage, AK 4. Location bi well at suflace 3644' FNL and 3346' FEL Sec. 27, T13N, ~pofproducti~inte~al 4610' FNL and 3294' FEL Sec. 27, T13N, ~effecti~depth 4610' FNL and 3294' FEL Sec. 27, T13N, ~tot~depth 4760' FNL and 3250' FEL Sec. 27, T13N, 12. Present well condition summary Total depth: measured true vertical 4740 feet 4563 feet 5, Type of Well: Development X ExDIoratorv __ Strat~gral3mc __ Se~ce __ RIOE, U.M. R10E, U.M. RiOE, U.M. R10E, U.M. 6 Datumelevat~on(DForKB) KB = 59.3' MSL feet Z UnitorPropertyname Milne Point Unit 8. Well number 9. Permit number 89-29 10. APl numOer 5O-- 029-21927 11. Field/Pool Wes t Upper Cretaceous- Sak Plugs (measured) P BTD Bridge Plug 4725' 4110' Effective depth: measured 4164 true vertical 4000 feet feet Junk (measured) Casing Length Size Structural Conductor 51 ' ' 13-3/8" Surface 2559 ' 9-5/8" Intermediate Production 4667 ' 7" Liner Perforation depth: measured N/A true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A Cemented Measureddepth ~uevedlcaldepth To surface 110' ll0' 200 bbl PERMF F~ 2618' 2513' 96 bbl Class G 50 bbl'Ciass G 4726' 4548' RECEIVED NOV 1 9 .QI.& Co.s, 13. Attachments Description summary of proposal __ Detailed operaUons program ~ BOP sketch __ 14. Estimated date for commencing operation i 15, Status of well classification as: November 3, 1990 I 16. llproposalwasveroallyappro.vedl) ,"~ I{[~"'l~ 10il..~_ Gas__ Suspended__ Signed k_)(j~~ /~'/j~l~ Title Production Engineer FOR COMMISSION USE ONLY Concl~bons of aoDrovat: Notify CommissIon so representa,ve may w~tness Plug mtegnty __ BOP Test __ Location clearance Mecnamcai Integnty Test __ Subsequent form required 1"~-/ ~-o q' Date Nov. 2, 1990 [Approvai No. 2~:~ "" ;~- __ -- ['-,oorovedby. order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commiss~oner Form 10-403 Rev 06/15188 - 43 - Approved Copy SUBMIT IN TRIPLICATE ~It~O~38ED ~OXPZ~TZO~ RZZ,]~ POZZ?~ I~Z~ gZr.'r. Novez~ez' ~.~ 1990 This completion procedure involves a fracture completion in the lower "0" sand and a gravel pack completion in the upper "N" sands of the Shrader Bluff Pool (Shallow Oil Sand). There are existing perforations in this well in the "N" sand, as listed in the general well information section. Care must be taken to maintain well control and prevent excessive fluid loss to this interval as the completion operation proceeds. Hold a pmejob safety m~.~.ting with all rig personnel to discuss the general safety hazards of the operation (completion zluids, treatment, radioactive materials, gravel pack, perforating, etc.). Page '1 COMPLETe'ON _CDntentB Page 3 Page 4 Page 7 Page 8 Page 12 Page lS Attach I General Well Information Wellbore Cleaning Stage Perforation Stage "O" Sand Fracture Treatment Gravel Pack Treatment ESP Running Procedure Baker Sand Control Procedure with drawing. RECEIVED NOV 1 91990 .Oil & Gas Cons. Commissio.~ '~ ~chorage Page 2 Casing'. Workstring: Perforations: 7" 29 # ID ~ 6. 184 # Drift = 6.059" Capacity = 0.0371 bbl/ft - 0.2086 £t3/ft 2 7/8" 6.4 # Tubing Capacity - 0.00579 bbl/ft Annular capacity (tbg x csg) = 0.0302 bbl/ft 4164- 4186 ("N" Sand) MD 4196 - 4202 ("N" Sand) 4305 - 4342 ("O" Sand) 4380 - 4398 ("0" Sand) Page GIH to 4050 ftMDwith bridge plug retrieving tool and scraper on workstrln~. There is a bridge plug currently sct at 4110 ft MD. Scraper must be checked to insure blade OD ia correct for the ?" 29# casing. Brine density for the completion operation is designed based on BHP plus minimal overbalance (30 to 50 psi maximum) to prevent fluid loss to the formation. Required brine density is 8.6 ppg. Methanol (at a concentration of 12% by volume) will be used for freezing point suppression. The basic recipe for brine mixing is to use 8.9 ppg NaC1 brine with 12% by volume methanol, for a final brine density of 8.6 ppg. Maintain at least 150 bbl of fluid in the pits at any time. Any less will make it impossible to circulate through the three pits and filter unit and have fluid left to pump into the well. Maintain the filtration system during this operation. No fluid goes into the volume tank without passing through the filter unit. The system consist of a DE press and appropriate guard filters. The two micron absolute filter should be the last filter in line before the fluid enters the pit. Turbidity measurements are to be made as a QC check of fluid solids concentration. A reading of 20 NTU in the volume tank i~ ac~D~mhl-. Th~ wall can ~ a~um~ t~ ~9 ~l~n when returns are below a 50 NTU reading. Operators of the filter unit should be given the responsibili~y of checking brine volumo and density during. deliveries and maintaining a record of each. Any discrepancy should be reported immediately. Low density or contaminated fluids should not be added to the volume tank. 2. Reverse circulate the following at maximum rate (4 BPM): a. Bottoms up with brine. b. 20 bbl Dirt Magnet solution (use a caustic pill at 3 # per bbl if Dirt Magnet is not available) c. 20 bbl brine. d. 20 bbl chemical wash (see e. Bottoms up with brine. Only clean, filtered brine should be pumped into the well at any time during the completion operation. Page 4 · . . e · · When circulating, take returns ~o the shaker tank and pump this tank into the filter tank. Keep the level in the shaker tank as low as possible. When the chemical wash returns to the shaker stop pumping from the shaker tank to the filter tank. Collect all of the chemical wash and spacer fluids in the shaker tank (see steps 4b to 4d above). Have an empty vac truck on site during this operation to remove the chemical wash fluids from the pit during the circulation. When the brine cleans up after the chemical wash stages divert it directly to the filter tank. Use minimal quantities of this fluid to rinse the shaker tank as the vac tr~ck removes all of the chemical wash fluids. Make sure all of the chemical wash stages are cleaned from the pits before continuing the operation. Shut down the fluid circulation after returns clean up to do this if necessary. Perform QC check on return fluid sample at this time. If it is acceptable then continue with the procedure. If it is not acceptable then repeat step 4.a. through step 4.e. Filter maximum volume of brine in the pit system before continuing the operation. Continue in hole with the scraper/retrieving tool and latch on to the bridge plug. POOH slowly to prevent any swab effects. Fill hole when pulling tubing to compensate for the tubing removed from the well only. Maintain accurate pit straps so that fluid los~ or gaine~ may me =racked. Continue with thi~ practice throughout the completion operation· Do not attempt to keep the hole full to surfac~. This may result in large volumes of fluid lost to the~formation. If at any time during the completion operation this step in the procedure appears to cause an unacceptable influx of formation fluids, the procedure must be revised· An influx will be indicated by pit gain and contamination of the brine with oil during subsequent circulations. Appropriate well control procedures should be followed any tame conditions indicate an influx. The 8.6 ppg brine may be contaminated with oil or other fluids trapped under the bridge plug. Appropriate precautions should be taken. GIH with bit on workstrinq to tag fill somewhere below the previous bridge plug set depth (4110 ft MD). Existing perfs are 4164 - 4186, 4196 - 4202, and 4216 - 4228 ft MD. It is probable that this interval is sanded up and washing will be required. The wellbore must be cleared to a point below 4398 Page 5 ft MD to allow for the lower completion. Rathole below this point is desirable to allow for excess frac proppant. If circulation conditions permit wash out to at least 4448 ft MD. Reverse circulation is preferable i~ lost circulation conditions permit. If fluid loss occurs then circulate down the workstring to minimize pressure against the formation. The filter unit will be required at maximum capacity during this operation. Make sure it has a clean precoat before beginning this phase. Make sure the pit'volume is at the maximum working capacity before starting the wash operation. Page ~arfor. a_t~on Sta~e . Rig up Schlumberger-to perforate the "O" sands at 4305 to 4342, a~d 4580 to 4398 ft MD. Perforutc 5 SPF, 37 gm, deed penetrating charge. This will require three wireline runs as listed below. Utilize gsmma ray and CCL for depth correlation on th~ first run, CCL for depth correlation on the second and third run. Tho g~a ray will be used as the prefra~, baseline. It must be run and cover a distance 100 ft above and below the entire perfora=ed interval. Run I - perforate 4380 - 4398, Gamma ray, CCL Ru~ 2 - perforate 4322 - 4342, CCL Run 3 - perforate 4305 - 4322, CCL Hold safety meeting with all personnel before starting the perforating operation. . POOH with the perforating guns. Note fluid level in well and any loss or gain. Rig down Schlumberger. · 4~ RIH with squeeze tool (Halliburton). Make up an Otis XN nipple in the string one joint above the packer. Set the tool above the existing pe.rfs at a depth, of 4100 and pressure .:_.test the annulus to 500 ps~. ~ ~a~_ Cm~ ~ Unget the tool and move it to 4248~ MD. This is 20 ft below the existing "N" sand perforations. Appropriate care must be taken when moving through the perforations to preVent surge and swab. 5~ Pull test the packer to insure set. Page 7 RECEIVED NOV 1 91990 .Oil & Gas Cons. Commission Anchorage Spot six 500 bbl frac tanks on location (to be supervised by DS). Elevate the rear of the tanks approximately 8" if necessary. Visually inspect the interior of the tanks for cleanliness. DO NOT ENTER THE TANKS. Fill each tank with 475 bbls clean injection water filtered to 10 microns absolute. The water should be heated and maintained at 75 to $0 degrees F to insure proper hydration of the gelling agent. Water from the central facility, carried in clean transports is acceptable. 2. Rig up Oowell Schlumberger to perform Lhe £rac treatment. Note. the following: Use of threaded connections, crossovers, swedges, etc. in the treating line is not acceptable. Use two in-line densitometers. Use two shut-off valves on the wellhead. Set the backup pumps for the crosslinker and diesel. Standby pumps (50%) are required. These pumps must he manned and primed to come on line immediately if needed. A standby blender should be hooked up and ready to come on line in case of primary blender failure. Tank bottoms are included in the volume listed in step #1 above. Use the in-line densitometer during the treatment. Record rate, pressure, and density on a chart. Take samples of the crosslinked gel during the treatment. Place these samples in a bath at 80 F. the actual break time. Note DO NOT OVERDISPLACE THE TREATMENT UNDER ANY CIRCUMSTANCES . . Batch mix 475 bbl gelling agent at 30 lb/1000 gal and additives as prescribed in the material detail for preparation of the WF30 DataFRAC fluid. Use one of the frac '~' tanks with a second as back-up if more volume is needed. Fluid design is based on lab testing with representative water samples. ~old on-~ite ~afety meeting with ri~ p~rsonnal to communicate hazard~ of the operation. Page 5. Rig up the slick line unit and RIH with slickline and set a plug in the nipple. Pressure test the surface lines to 5000 psi. After a successful test pressure test the tubing to 5000 psi. Retrieve the plug from the well and rig down slickline unit. The automatic pressure shut-down on pump should be set at 5000 psi. 6. Rig up Schlumberger to run wireline during the DataFRAC. ,~\~-~ ~--Utilize gamma ray/CCL run from depth correlation of first ~,. , perf run as baseline gamma ray log across the perforated ~intervals. It must include a minimum of 100 ft above the top iset of perfs and 100 ft below the bottom set of perfs. RIH with the wireline pressure gauge/temperature measurement tools, Run through %he entire interval plus 100 ft above and below to establish baseline temperature, Set tool assembly at mid-perf. Monitor pressure and temperature, . Load the hole with WF30 being sure not to exceed the frac pressure. · Pump the following schedule for the step rate test: Fluid Pump Barrels Cum, Pump Cum. Type Rate Pumped BBLS Time Pump (BPM) (E,a,. StageI Pump.ed .. {rain) Ti.m.e wF30 4.0 8.0 8.0 2.0 2.0 WF30 6.0 12.0 20,0 2.0 4.0 W-F30 8 . 0 16.0 36,0 2 . 0 6.0 WF30 10.0 20.0 56.0 2.0 8.0 WF30 12.0 24.0 80.0 2.0 10.0 WF30 14.0 28.0 108.0 2 . 0 12 . 0 WF30 l~, O 32.0 140.0 2.0 14.0 WF30 18.0 36.0 191.0 2.0 16.0 WF30 20.0 200.0 391· 0 10.0 26.0 Page 9 Stop the pumps and monitor pressure vs square root of time for a minimum of 15 minutes to determine closure. If closure is not obvious, repeat the 20 BPM stage for 5 minutes and observe the pressure for closure. 10. For the calibration test batch mix two of the frac tanks (47S bbl each) with gelling agent at 40 lb/1000 gal for preparation of t. he YF140. Pump 500 bbl at 25 BPM with RA tracer material in the first 475 bbls. RA tag supplied by Pro Technics International. It must be added in the suction of a high pressure pump. It must not be dumped into the blender. Contact in Houston is David Krantz or Doug Elliot (713-496-3734). They will need 48 hours notice to have men, equipment, and materials on the slope. Flush to the bottom perf with WF40. Hold safety meeting with all personnel to discuss hazards of radioactive materials on location. 11. Monitor pressure until 500 psi below the determined closure 12. Run post DataFRAC temperature and gamma ray survey to include aminimum of 100 ft above and below the top and bottom perforations. Analyze data to determine the approximate fracture height. 13. Utilize the DS FracCADE computer program to input the new' information and optimize the frac design. 14. In the remaining frac tanks, batch mix gelling agent at 40 lb/1000 gal and additives as prescribed in the material detail for preparation of the main frac treatment (or as the new design indicates, based on DataFRAC results). ~-,. Particulate fluid loss additive should be added in the pre- pad and pad fluids only. Diesel and crossllnker activator are the only additives that ~hould be mixed on the fly. Sand (Carbo-Lite) will be added in the prescribed stages through the blender. Page lO 15. Pump the frac job as follows, or as re-design indicates: i . ii i i. i II I i i i I Stage Fluid Prop Pump Stage Cum. Stage Cum. Name Name Conc Rate Vol. Vol. Time Time ppg BPM bbl bbl min min waa ¥~'~40 0 55 ?62 762 30.S Slurry YF140 2 25 104 866 4.1 34.6 Slurry YF140 4 25 185 1051 7.4 42.0 Slurry YF140 8 25 180 1231 7.2 49.2 Flush WF140 0 25 28 1259 1.1 50.3 When pumping the frac treatment have the rig pump lined up to pump brine down the casing. Pumpbrine at minimum rate during frac treatment. Monitor pressure. 16. Shut down. Allow the pressure to bleed off into the formation. Record the ISIP, and pressure for 30 minutes. Close all surface valves and leave the well shut in. M°nitor the break time of the last sample collected. Rig down pumping equipment. 17. After adequate break (based on surface samples) release packer and allow fluid level to stabilize. Reverse circulate the tubing until clean brine returns are stable.' POOH. Fill hole when pulling tubing to compensate for the tubing removed from the well only. Do not attempt to keep the hole full surface. This may result in large volumes of fluid lost the formation. ~. After Ch- £~== L~:atm%n~ ~ha~a {s a ~o:oibility o~ proppant in the wellbore. Rig up $1ickline and RIH with a sinker bar to insure the perforations are clear. Tag bottom to identify the amount of proppant in the casing. Rathole should be sufficient to prevent proppant from covering the perforations. If the bar tags proppant in the perforation interval then GIH with bailer to remove proppant from the well to clear the perforation interval. Use the tubing bailer with sufficient barrel length. Rig down slickline unit when complete. Page 11 ~ravel Pa_cc_It Stags 10. 0. · · · GIH and set Baker Model "D" size 84-32 sump packer set at 4253 ft MD. Rig up Schlumberger to run tubing conveyed perforating. safety meeting with all. personnel before the perforation operation starts. Hold GIH with perforating gun (TCP) set-up to perforate as follows: 12 SPF at: 4164 - 4186 ¢1~ - 4216 - 4228 Omni valve should be in the well test position while RIH. Perforate under balanced with a drop bar/isolation disc mechanism run with an OMNI valve above the tool to allow for underbalance in a previously perforated well. Utilize a seal unit attached to the bottom of the gun assembly that stings into the sump packer. The length of the assembly (+/- 25 ft) must be designed to place the guns in the proper position after the seal unit is in place· Run a collet locator in the seal unit for a positive indication of position. Snap into and out of the collet to insure position. Design the assembly to allow a pick up out of the collet while maintaining the seals in place· Shift the Omni valve to the circulate position and circulate diesel down the tubinq to obtain underbalance. Have the diesel in the pill tank. After pumping the correct volume of diesel follow it with 10 bbl brine from the trip tank to insure all lines are clear of diesel. Make sure not to pump the diesel past the Omni valve, Set packer. Test with annular pressure to 500 psi. Recheck underbalance calculations and fluid fill. Rig up high pressure lines at surface through choke manifold for fluid flow after perforating. Set choke at full open. Line up through the choke to the disposal tank and prepare to fire guns, Walk line to insure proper flow path. Strap the disposal tank. Fire guns by dropping bar. Allow well to flow 20 bbl or one hour, whichever comes first. Do not flow formation fluids to surface. Shut in at surface. Apply 1500 psi pressure on annulus to cycle OMNI valve to Page 12 1,3 . . . circulate position. Reverse circulate workstring clear. Flow fluids into the disposal tank on location. Check for clean brine returns before taking returns to the pit and unsetting the packer. Unset packer, monitor fluid level. Pick up one stand and wait 30 minutes. Drop back to bottom and snap back into the sump packer to insure it is clear of debris. If this indicates fill at the sump ~acker then perform the wash trip as described in step #? below. If no fill is seen complete this step then proceed to step #8. POOH when stable. Fill hole when pulling tubing to compensate for ~he tubing removed from'the well only. Do not attempt to keep ~he hole full to surface. This may result in large volumes of fluid lost to the formation. G£H with wash extension £ur the sump packer. If fill in tho hole prevents reaching 4253 then reverse circulate to remove fill. If fluid loss occurs then circulate down the tubing to minimize pressure against the formation. Tag bottom and allow the extension to go into the sump packer bore to insure no fill in the packer. This is the extension made at the rig during the G-3 completion. POOH. GIH with the gravel pack assembly as follows: a. Baker Model -S-22" Snap Latch Seal Assembly, size 80-32, with 2 additional seal units. b. Isolation disc sub. 11 ft of = 7/8" Baker-weld wire wrapped 12 gauge stainless steel lower tell tale screen. ~ . d. Seal Dore receptacle, I f= length. e. 84 ft of 2 7/8" Baker-weld wire wrapped 12 gauge stainless steel screen, weld on centralizers every 15 ft. f. 252 ft of 2 7/8" blank pipe, centralizers every 15 ft. g. Run a 6 ft polished stinger and 1.9" tubing (length as required) inside screen as washpipe. h. 19 ft length Baker Model "s" Gravel Pac~ Extension with a G.P. sliding sleeve, and upper extension size 80-40. Page 13 l' i. Baker Model "SC-l" gravel pack packer, size 70B2-40. J. ~aker crossov-.r I ,,,,1. Note, Items (h) through (j) are picked up as one unit. use screen table over rotary when running screen. Hang off screen in the screen table on collar shoulder. No slips or clamps allowed on the screen. Hang off blank pipe in rotary table with 2 7/8" slips. NO EXCESS PIPE DOPE ON ANY CONNECTIONS. DOPE PIN ENDS ONLY. Rabbit pipe as RIH. Leave the pup joint off the packer assembly to make it easier to lift to the rig floor. . Run the gravel pack assembly into the well slowly, space the workstring out prior to snapping into the sump packer to obtain a safe working height at the rotary table. Do not space out any connections at or near the wellhead assembly. Record pick-up and slack off weights. Set 15000 lbs weight down to snap the snap latch seal assembly into the sump packer to verify slip anchorage. Snap out and back in =o verify position. 10. Rig up Otis Sand Control on location. High pressure lines on all but the return line. The line from the manifold to the pit can be a high pressure hose (5000 psi RWP). No valve is to be connected to the hosa. Rig up squeeze manifold appropriately. A flow meter must be installed in the return line from the annulus to the manifold (to measure fluid flow to the manifold). A ball catcher should be used on the rig floor to prevent complications from the setting ball returning to surface at any time during the operation. 11. Hold a pre-job safety meeting for all personnel on location that could be exposed to hazards of the treatment. The two main points of concern to be stressed are material hazards and pumping pressures. Discuss general safety precautions and first aid procedures (location of eye wash, responsible personnel, etc). 12. Test lines to 5000 psi. Includes all treating lines, gauges, manifold, etc. Page 14 13. With the workstring in the neutral position, circulate 5 bbls of filtered clean brine at 2 BPM. This is to insure that the ball seat and the tubing are clear of any potential debris. 14. Drop the I 7/16" Kirksite setting ball and allow time for the ball to gravitate down. Set SC-1 by pressure increase to 2500 psi (by 500 increments, proper timing). Test by pulling 15000 lbs over string weight and pressure testing annulus to 700 psi. This in turn will actuate the hydraulic release feature in the setting tool. 15. Release from the SC-1 packer by picking straight up, and then position and test the crossover tool in the squeeze, lower circulating, upper circulating and reverse positions. Position the crossover tool in reverse position and circulate the following: a. 10 bbl gel fluid (brine with 60 lb HEC/1000 gal).' b. 200 gal Super Pickle c. 300 gal 15% Hcl with inhibitor, iron sequestering agent, surfactant. c. Brine. At acid approximately i bbl from crossover, shut down and reverse circulate acid back to surface. Pump acid down and back out at 4 BPM. Have tank at surface ready to accept acid flowback before pumping acid into well. Have material in tan~ to neutralize acid. It is acceptable to mix soda ash in the pump truck' (mix tank) and pump it through the line to the disposal tank to neutralize the pickle acid. 16. Establish rate and pressure at each position. Take measurements at 0.5, 1, 2, and 3 BPM. Pump only enough fluid to establish a stable pressure at each rate. ~- Establish injection with minimal volume of brine. Do not exceed fracture gradient of 0.7 psi/ft. 17. Wellbore ready for gravel pre-pack. Circulate to packer, shift to squeeze and inject prepack slurry as follows: a. 10 bbl prepad (2% KC1 with 60 lb/1000 HEC) b. 9 bbl slurry at 2 ppg 20-40 mesh gravel (2% KC1 with 60 lb/1000 HEC). c. 5 bbl postpad (2% KCl with 60 lb/1000 HEC) Carrier fluid to contain appropriate breaker concentration, added just prior to pumping. Page 15 ,- ~,,5 2 ..3i6 18. 19. 20. Carrier fluid preparation includes shear/filter to 10 micron absolu%e. Perform QC test on gravel and carrier fluid. Gravel test consist of spot check of sieve analysis. Test on carrier fluid includes break test at BHST and filterability. Injection rate to be determined based on injection test. Rate should be at least 2 BPM. over displace the slurry from the annulus. Do not shut down with slurry in the annulus. If there is no pressure response during prepack slurry injection consider another batch. Go to reverse circulate position and reverse (minimum of 1.5 tbg volu~es) while preparing gravel pack fluid. Establish circulation in the lower tell tale position, Shift the tool to the reverse position and circulate the gravel pack down as follows: a. 20 bbl pre-pad b. 20 bbl slurry, 8 ppg gravel ¢. 10 bbl post-pad d. brine displacement Base fluid is 2% KCl at 60 # HEC/1000 gal, sheared and filtered through 10 micron absolute filter. Fluids can be mixed at the Otis Sand Control shop, but must be filtered again (10 micron absolute) between the transport and blender. For the pad and slurry fluids mix e~tra carrier to allow for minimal tank bottoms. Excess must be dumped after the treatment. Fluid, both slurry and pad, to contain appropriate breaker concentration, added just prior to pumping, after establishing circulation through lower tell tale. Pump down at 4 BPM. When pre-pad is 3 bbl above the crossover stop pumping and shift tool to lower circulation position (tell tale screen). Try to maintain 3 BPM during placement. Monitor return rate at all times. Data recorder~' to include turbine flow meter in the treating line between the squeeze manifold and annulus, set up to measure return rate. Screen out tell tale to 1000 psi if possible (actual will be about 500 psi). As screen-out occurs shift tool to upper circulation position. Page 16 If returns drop off but pressure does not increase, shift tool. Screen out the main screen with a 1000 psi increase. Attempt to maintain a 3 BPM rate through the placement process. If no screen out is seen overdisplace the slurry and repeat from step 19 with 10 bbl of pad, 10 bbl slurry, and S bbl post pad. 21. 8hSft to the reverse position and reverse out until all excess slurry has returned. Measure sand volume. Continue reverse circulating bottoms up several times. Wait on break time (assume 4 hours unless testing indicates otherwise). 22. After appropriate break time place tool in main screen circulation position and pressure up. If rate/pressure indicates exposed screen then pump another batch of gravel following the same directions. If rate/pressure indicate the screen is still covered then prepare to POOH. 23. Before POOH insure the fluid level in the well is stable. 24. 25. POOH with running tool. Fill hole when Dulling tubing to compensate for the tubing removed from the well only. Do not attempt to keep the hole full to surface. This may result in large volumes of fluid lost to the formation. Run gravel pack evaluation log with pack repair tool (WID). Reciprocate WID several times and relog if pack efficiency is questionable. Be prepared to run new running tool and repack if log indicates poor pack efficiency in perforation area and repair efforts fail. 26. Before POOH drop down on the glass disc and attempt to break out. .. 26. POOH with log. 27. If unable to break out glass disc with log tool (see step 25) then rig up slick line and run in hole with a sinker bar to break the isolation disc. POOH. Page 17 . · 4~ · GIH with ESP assembly as follows: a. ESP with standard centralizer for 7" 26# casing b. One joint 2 7/8" 6.4# Tubing c. AVA Ported Nipple d. 2 7/8', 6.4# Production Tubing to surface RIH with ESP no faster than 30 ft/minute. Run WITHOUT sleeve or oheckvalve in the AFA nlpple. Before startup of ESP the appropriate item will be run on wireline. Attach two cable bands per tubing joint. Attach additional cable bands above and below cable splice. Locate the bottom of the ESP to maintain at least 30 ft between the,pump and the gravel pack packer (set at +/- 3867 ft). This spots the bottom of the pump at a maximum depth of +/- 3837 ft. Do not space out with pup joints at surface. Spot the pump with a tubing connection at the wellhead for ease in NU tree. Pump sufficient diesel down annulus, allowing it to "u tube" back into the tubing, to fill to a depth of 2000 ft for freeze protection· ND BOP stack. NU production tree. Rig down to move. The following steps are important in maintaining a successful producing gravel pack completion. The gravel packed zone must be brought on line at low rates. It is important to increase the flow rate slowly and not apply more than 500 psi pressure drop across the gravel pack completion. ~ The rate should be maintained at the lowest rate possible on the ESP until production is all oil. Each time the rate is increased (by choke or ESP) the pressure should be allowed to stabilize (for 6 to 12 hour minimum) before increasing the choke size again. Page 18 4100 4300 4500 · -t i I 'I- o-! I0 o~ z~ SAND CONTROL I LO 6.0 &.Il [ FNFdRNIA'I'tON: PA'SE 0 1 o · ,_., I 7 i IINFOKMATION ~0 ~o.~ : ~375 SAND CONTROL 6 'bk'm* B't~Ol, Ud m,*un7 I RE£EiV NOV ~ .Oil & Gas ~ Rnohorac~ F:AGE. P~ 12 ,_ LENTRILIFT EQUIPMEh("i QUOTA'r:iON A Bake? Hughe~ ¢oml3any 200 W, Stuart Roosa Dr. · Claremore, Oklahoma 74017 s (918) 341-9600 DATE QUOTATION NO. 8-02-9O D2213-06'2'2-3180 PRESENTED BY S. HesCer CAPACITY TOTAL HEAD FREQuENCY CONOCO Post Office ]~ox 340045 ....... · -- -- ,,n ,,,,,, AI-FN: Van Lineberger WELL NAME. G- [ FIELD NAME; Milne Point: LOCATION: Prudhoe Bay, Alaska SP. GR. , PERFS SETTING DEPTH 3850 B.H.T, PRIMARY VOLTAGE 480 RED. SURFACE VOLTAGE REQUIRED KVA G.D.R. CASING O.D. WEIGHT TUBING SIZE THREAD NET LIFT SURFACE PSI FRICTION LOSS T,D,H, FREQUENCY 3 60 HERTZ ~ 50 HERTZ MOTOR H.P. 65 VOLTAGE [250 AMPERAGE 30 NO. PCS. 1 RATING SERIES 562 MODEL ~ LENGTH 9.1 671 eUMPSTAGES TYPE ~ HSG. NC), 8 NO. PCS. i57 SERIES Z~00 MODEL I~PU LENGTH 13.2 PUMP INTAKE ~ERIES MODEL ~ LENGTH ~ - Gas Separator , , ,, ,. , ,,1,1, i _ _' __ PUMP DSCHRG. SER~ES MOOEL LENGTH CONN. 263 GAS SEPARATOR SERIES MODEL I,,E NGTH SEAL SECTION SERIES 513 MODEL GSB LENGTH 6.3 POWER CABLE AWG TYPE LENGTH Ai~MOR FLAT CABLE SEP. i£S TYPE LENGTH ~; RMOR FLAT GUARDS CABLE $AODLE5 CABLE BANDS CABLE ::)$ ~WAGED NIPPLE CHECK VALVE DRAIN VALVE EQUIPMENT COATING: MOTOR CONTROLLER ACCESSORIES INCLUDE; TYPE LENGTH MOD E L SIZE VOL. TAG E OVERLOAD r' UNDERCURRENT S.D. ~ RECORDING AMMETER ~ AUTO RESTART ---. LIGHTING ARRESTER [3 OTHER VARIABLE FREQUENCY CONTROLLER'. 130 KVA ICS Mode TRANSFORMERS SIZE TYPE --PRIMARY TAPS 480 ..... VARIABLE FREQUENCY TRANSFORMER [30 KVA JUNCTION SOX NENTED.,&AFETYI SECONDA;~YTAP$ 750 ' 3000 Multi Tap Wet, Isolation TUBING HEAD Inductor Package~ A~aptor 400 x 513 Conoco Mods for ICS Drive CABLE GUIDE CABLE REEL NO, REEL SUPPORT SHIPPING CASE QTY. SIZE SHIPPING CASE QTY. SIZE SHIPPING CASE QTY,, SIZE SHIPPING CASE QTY. SIZE NOTE: SERVICING EQUIPMENT MAY 8E RETURNEO FOR 100% CREOITWITHtN 6 MO.. SUBJECT TO A REPAIR CHARGE EQUAL, TO 25% OF THE LiST PRICE. i$coun~ CONOCO -¥SC'System Performance ~~ :. ft I-- I--t I-4 MI hp I O0 200 , :. ~00 400 ;~,I~00 ~H I). OCRJLO 600 700 dSO0 900 1000 I t _riO_1200 PUHP 157 stage MOTOR (60 Hz ratlnq) 562 slrte~ 65 hp 1 ~0 volt 1~500 BPD SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON, TEXAS 77251-2175 NOV ! 4 tgtO PLEASE REPLY TO SCHLUMBERGER WELL ~,ERVICE$Pouch 340069 Prudhoe ~aT, ~ 9973~-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberser Gentlemen: Enclosed ore 2 BI. prints of the. Company CONOCO, Inc, Well Milne Point Unit G-1 Sump Packer Setting Record, Run 1, 11/11/90 on: Field MJlne Poi nt Additional prints ore being sent to: I BL prints CONOCO, Inc .... 600 North Dairy Ashford Houston., TX 77079 ..Attn: George Lamb - OF 2018 PER County Wnrth S]ope State Alaska _l_BL_prints, I RF Sepia CONOCO; Inc~ __!000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, I RF Sepia OXY U.S.A., Inc, 6 Desta Drive Mldland. TX :79710 Attn: John Carrol *(915/685-5600) _l_JlL_~rints, 1 RF Sepia ...Chevron U.S.A. =_11111 SOuth Wilcre.~t =_Hou.~ ton; T~wm~ 770qq Attn: Priscilla MacLeroy ~'713/561-3652 /~. Alask~a Oil & Gas CpnservattonX'~ / ' commission ...... ,,~ ( .3001 porcupine Drive ' ~ :AnChorage,.'. AK.. 9'9501 : John Boyle ~~.-~ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. prints ~prints prints RECEIVED KI~I 1-~ ,~AAA ,~J v , U I;3;3U Alaska Oil & Gas Cons. Commission Anchorage Received by: Very truly yours, SCHLUMBERGER WELL SERVICES _.David M. Saalwaechter DISTRICT MANAGER SWS-- 1327-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 KEAI[ REPLY 1'0 8CHLUIdBERGER WELL SERVICES J~OV 1 ~ ?~.,. Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberser Gentlemen: Enclosed ore 2 RI. prints of the. Company CONOCO, Inc, Well Perforating Record/Data Frae: Press-Temp-GR/CCL, Run 1, 11/7/90 on: Milne Point Unit G-1 Field . Milne PoJnt ,, Additional prints are being sent to: 1 BL prints _CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER ,,.County North Slope State ...... Alaska _l_Bi,_prints, I RF Sepia C~NOCO; lnc~ _1000 Sout. h Pine Ponca City, OK 74603 Attn: Log Library I BL prints, I RF Sepia OXY U.S.A., Inc. 6 Desta Drive Mid!~nd. TX 797~0_ Attn: John Carrol *(915/685-5600) _lJlL_prints, 1 RF Sepia Chevron U.S.A. 11111 South_Wilcre.~t. _-- Hou,~ inn.; T~w~ 77~c)9 Attn: PrJscJlla MacLeroy J'713/561-3652 -- ~ask'a Oil & Gas Conservation ..x~ 'Commission ~ ~300i' porcupine Drive ~ ~chorage," AK 9'9501 ' -/ At~ John Boyle ,_/ The film is returned to Conoco, Log Library. We appreciate the privilege of serving you. .... prints _prints prints RECEIVED 1990 ^!aska 0il & gas Cons. Commission Anchorage _Recei ved by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES David M,. Saalwaechter OISTR IC:T MANAGER SwS-- 1327-F 12051 RIVERA RD. · SANTA FE SPRINGS, CA 90670-2289 TELEPHONE (213) 698-0081 · PANAFAX (213) 693-0947 October 2, 1989 Mr. Michael Zotzky Conoco, Inc~' 3201 C Street, Suite 200 A~chorage, AK 99503 Dear Mr. Zotzky: Re: Core Analysis File No.: 70068 Enclosed is a final core analysis report for routine core analysis, 90 degree horizontal core analysis, and vertical permeability tests performed on material from Point Milne G-1 well, north slope Alaska. Laboratory procedure's have been included for your reference. We appreciate this opportunity to be of service and trust these data prove beneficial to the development of this reservoir. Sincerely, Petroleum Testing Service, Inc. Peter T. Schuyler PreSident PTS:rdl Encl. RECEIVED , ev - 9 ~:,'~j~sks OiJ & Gas Oons. Commission Anchorage Client: Conoco, Inc. Well: G-1 Field: Milne Point File: 70068 Date: Oct. 2, 1989 ROUTINE CORE ANALYSIS AND 90 DEGREE HORIZONTAL CORE ANALYSIS 1. Drill 1" diameter sample plug using liquid nitrogen as cutting fluid, trim to right cylinder. 2. Package with preweighed aluminum foil, teflon tape and fit with 200 mesh stainless steel end screens. 3. Seat package to sample in a Hassler-type sleeve using 275 psi as confining stress. 4. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volumes. 5. Vacuum dry at 150°F until stable and weigh to 0.01 grams. . Cool samples in dessicator to room temperature and measure sand grain volume using a Boyle's Law helium porosimeter. Calculate grain density. 7. Mount sample in a hydrostatic Hassler-Type sleeve using a confining stress of 275 psi. 8. Measure pore volume using a Boyle's Law helium porosimeter, determine porosity and fluid saturations. 9. Measure permeability with nitrogen gas using a calibrated'flow tube-type permeameter. VERTICAL PERMEABILITY 1. Follow steps one through ~five .of the procedure above. · Mount sample in a 'hydrostatic Hassler-type sleeve using a confining stress of 275 psi. Measure the permeability with nitrogen gas using a calibrated flow tube-type permeability. RECEIVED Oii& ~,as Oo~s. Oommissio~ ~c~orage ORIGII~AL CONOCO, INC. WELL: G-1 FIELD: MILN£ POINT ROUTINE CORE ANALYSIS OCTOBER 1989 FILE 70068 iqov -~1.989 Anchorage COI4PANY CONOCO, INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE ~ TYPE MATER BASE PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS AIR HELIUM PERMEABILITY OIL MATER TOTAL DEPTH POROSITY md. O/W SATN SATN SATN ft. PERCENT HORZ. VERT. RATIO ~PV ~PV Y, PV 4107.8 39.2 1610. 0.00 0.0 80.4 80.4 4111.1 36.2 597. 0.00 0.0 81.0 81.0 4112.25 36.6 757. 0.00 0.0 81.0 81.0 4113.4 36.6 756. 0.00 0.0 ?6.2 76.2 4137.2 36.1 404. 0.18 8.8 48.5 57.3 4138.0 36.7 294. 0.65 28.4 43.6 4152.2 38.3 549. 0.82 35.7 43.4 4168.8 16.0 55. 1.21 30.8 25.5 4169.7 8.8 3.8 0.15 6.4 43.8 4169.7 3.5 4170.5 25.2 588. 2.23 41.9 18.7 4171.9 42.6 7910. .98 36.3 37.0 4172.7 42.4 >10000.. 1.29 38.3 29.7 4184.7 43.5 >10000. 0.66 37.6 57.1 4184.7 43.1 7860. .99 47.9 48.6 4180. APPARENT SAND ORAl N DENSITY om/cc 2.64 2.63 2.65 2.64 2.64 72.0 2.63 79.1 2.63 56.3 2.62 50.2 2.62 4185.T 36.1 2870. 4185.7 4185.8 33.4 110. 60.6 2.63 73.3 2.64 68.0 2.62 94.7 2.61 96.5 2.63 1.48 45.6 30.? ?6.3 2.60 Page No. FiLe No. Date 1 7OO68 C~tober UELL G-1 FIELD MILNE POINT CCX,JNTY ' ' STATE ALASKA LITHOLOGY Sst; gry, vfg, stty, n odor, n stn, n fluor Sst; 9ry, vfg, shty, n odor, n stn, n fluor Sst; gry, vfg, stty, n odor, n stn, n fluor Sst; gry, vfg, sLty, n odor, n stn, n fluor Sst; gry, vfg, stty, sh tm, fnt odor, m 8tn, d[ gtd fluor Sst; gry, vfg, shty, fr odor, mstn, dt gid fluor Sst; gry, vfg, stty, fr odor, matn, d[ gid fluor Sst; brn, vfg, stty, wt cmt, fr odor, mstn, dt gtd fluor Sst; bm, vfg, arty, ~t cmt, fr odor, mstn, dt gtd fluor 2, 1989- 0.45 28.2 62.5 90.7 2.66 Sst; brn, vf-fg, sity, gd odor, mstn, dt gid fluor Sst; brn, vf-mg, gd odor, mstn, dt gtd fluor Sst; bm, mg, gd odor, mstn, d[ gLd fluor Sst; bm, mg, gd odor, mstn, dL g[d fluor 90° NORIZ: Sst; bm, eg, gd odor, mstn, dL gLd fluor Sst; brn, ag, sh tm, ltd odor, ·stn, dt gtd fluor 90° HORIZ: Sst; brn, mil, shty, fr odor, matn, dt gid fluor CONPANY CONOCO, INC. CORE TYPE & INCH FIBERGLASS SLEEVE HUO TYPE MATER BASE PETROLEUI4 TESTING SERVICE, INC. CORE ANALYSIS MELL G-1 FIELD #ILNE POINT COUNTY ' STATE ALASKA Page No. FiLe No. Date 2 70O68 Octol~r 2, t989 AIR HELIUH PERHEABILITY OIL MATER TOTAL DEPTH POROSITY md. O/g SATN SATN SATN ft. PERCENT HORZ. VERT. RATIO ~r~V XPV' ..o.o.. o....... ............. . .... 4166.6 44.7 4570. 0.80 38.4 48.3 86.7 4200.6 40.1 3430. 1.37 45.7 33.3 79.0 4201.2 41.7 3780. * 1.32 45.2 34.3 79.5 4217.8 33.1 500. 0.80 36.6 45.9 82.5 4225.5 35.7 256. 2.31 53.2 23.0 76.2 4226.65 38.3 316. 1.14 38.6 34.0 72.6 4227.4 36.7 419. 1.97 46.5 23.6 70.1 4228.7 33.5 230. 1.16 41.2 35.4 76.6 4229.5 36.0 437. 1.77 46.1 26.1 72.2 4230.7 34.2 256. 1.97 50.1 25.4 75.5 4231.25 46.1 2410. * 0.48 31.1 64.8 95.9 4232.5 32.9 131. 1.11 42.1 37.8 79.9 4233.9 33.4 136. 0.79 34.2 43.4 77.6 4234.9 35.1 287. 1.68 46.0 '27.4 73.4 4235.9 34.2 743. 0.94 38.3 40.6 i'8.9 4236.9 33.8 189. 0.92 38.6 42.0 60.6 4237.9 26.8 37. 0.06 4.7 81.0 85.7 FRACTURED APPARENT SAND GRA I N DENSITY gm/cc 2.63 2.64, 2.63 2.64 2.64 2.65 2.65 2.66 2.65 2.64 2.65 2.64 2.66 2.66 2.64 2.64 LITHOLOGY Sst; bm, mM, Mci odor, mstn, dt gtd fluor Sst; bm, fo, gd odor, matn, dt old fluor Sst; bm, vf-fg, gd odor, matn, di gtd fluor Sst; bm, vfg, arty, MCI odor, matn, di Mid fluor Sst; grysh brn, vfg, sLty, gd odor, mstn, di g[d fluor Sst; grysh bm, vfg, arty, gd odor, mstn, d[ g[d fluor Sst; bm, vfg, MCI odor, mstn, d[ Mid fluor Sst; brn, vfg, arty, gd odor, matn, dt gtd fluor Sst; brn, vfg, sheLL frag, gd odor, mstn, dt gtd fluor Sst; brn, vfg, arty, sh tm, Md odor, mstn, d[ g[d fluor Sst; brn, vfg, stty, lld odor, mstn, d[ Mid fluor Sst; bm, vfg, aLLy, shty, gd odor, mstn, dt gtd fluor Sst; brn, vfg, sity, sht¥, gd odor, mstn, di Mid fluor Sst; bm, vfg, s[ty, gd odor, matn, d[ g[d fluor Sst; brn, vfg, arty, gd odor, mstn, dL gLd fluor Sst; bm, vfg, ably, gd odor, matn, d[ gtd fluor Sst; bm, vfg, ably, sheLL fraM, fnt odor, mstn, dL gLd fluor PETROLEUM TESTING SERVICE, INC. Psge No. FiLe No. Date 3 7OO68 October 2, 1989 COIqPANY CONOCO, INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE IqUO TYPE UATER BASE CORE ANALYSIS AIR HELIUH PER#EABILITY OIL UATER TOTAL DEPTH POROSITY mci. O/U SATN SATN SATN ft. PERCENT HORZ. VERT. RATIO Y, PV Y. PV XPV 4310.6 35.3 587. 1.37 51.1 37.2 88.3 4311.6 36.1 748. * 0.72 35.1 48.6 83.7 4314.6 38.8 650. 0.77 37.3 48.4 85.7 4315.3 33.5 224. 0.75 40.2 53.8 94.0 4315.6 731. 4316.3 984. 4316.35 35.9 650. 0.38 25.3 66.5 91.8 4317.3 37.6 1060. * 0.30 19.7 64.9 84.6 4318.3 36.6 509. 0.27 17.5 65.0 82.5 4318.3 38.0 1160. 0.46 26.8 57.7 84.5 4319.2 378. 4319.3 37.2 630. 0.24 16.8 70.0 86.8 4320.3 35.1 155. 0.69 36.7 53.0 89.7 4321.3 33.0 132. 0.70 34.1 48.4 82.5 4325.4 30.1 64. 0.31 19.9 64.3 64.2 4326.8 35.0 105. 0.50 27.2 54.9 62.1 4326.95 43.9 ,10000. 0.66 39.5 59.6 99.1 432?.9 35.0 221. 0.46 26.8 58.0 64.8 FRACTURED APPARENT SAND GRAIN DENS i TY gm/cc 2.62 2.66 2.64 2.66 2.65 2.64 2.65 2.66 2.66 2.67 2.66 2.64 2.65 2.71 2.65 tELL G-1 FIELD #ILNE POINT · COUNTY STATE ALASKA LITHOLOGY Sst; grysh brn, fg, stty, gd odor, m stfl, dt gtd fluor Sst; grysh bm, vfg, shty, fr odor, m stn, d[ gtd fluor Sst; brn, vfg, stty, fr odor, m stn, dL gtd fluor Sst; brn, vfg, shty, gd odor, m stn, di gid fluor Sst; brn, vf-fg, stty, fr odor, m stn, dL gLd fluor Sst; brn, vf-fg, sity, fr odor, m stn, dt gLd fluor Sst; bm, vf-fg, stty, fr odor, m stn, dt gid fluor 90e HORIZ: Sst; brn, vf-fg, slty. fr odor, · .tn, dt gLd fluor Sst; bm, vf-fg, stty, fr odor, m stn, d[ gid fluor Sst; bm, vf-fg, stty, shty, fr odor, m stn, d[ gLd fluor Sst; bm, vf-fg, sity, shiy, fr odor, m stn, dL gtd fluor Sttst; grysh brn, vf-fg, shty, fr odor, m stn, d[ gtd fluor Sst; brn, vfg, 8[ty, 8h tm, fr odor, m stn, dt gLd fluor 90' HORIZ: Sst; brn, vfg, stty. sh tm, fr odor, m stn, dt gtd fluor Sst; bm, vfg, arty, fr odor, m stn, d[ gtd fluor COMPANY CONOCO, INC. CORE TYPE & INCH FIBERGLASS SLEEVE MUO TYPE UATER BASE AIR HELIUM PERMEABILITY OIL WATER DEPTH POROSITY ind. O/W SATN SATN ft. PERCENT HORZ. VERT. RATIO Y. PV ~LoV 1...o.o .oo.o... ...........o .o.o......oo o.o.. .... 4327.95 134. 4328.8 34.5 107. 0.49 26.8 54.4 4329.9 26.5 12. 4331.3 35.4 66. 4331.3 4332.3 32.2 72. 4333.3 33.1 94. 38. 0.00 0.0 88.2 0.51 26.2 51.? 0.6? 32.8 48.7 0.45 26.3 59.0 4333.3 32.8 95. 0.39 24.1 61.? 4334.3 35.3 385. 4335.6 35.? 440. 4335.? 36.4 376. 0.00 0.0 85.1 0.00 0.0 81.4 0.00 0.0 73.1 4335.? 4336.0 36.3 518. 4337.35 31.5 41. 4337.? 32.5 44. 4338.? 32.5 38. 440. 0.02 1.3 76.1 0.38 24.7 64.3 0.29 19.6 66.3 0.45 25.3 56.8 PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS APPARENT TOTAL SAND GRAIN SATN DENSITY tLoV gm/cc 81.2 2.66 88.2 2.62 77.9 2.65 81.5 2.66 85.3 2.68 85.8 2.68 85.1 2.67 81.4 2.67 73.1 2.66 77.4 2.66 89.0 2.68 85.9 2.67 82.1 2.69 Page No. FILe No. Date 4 70O68 October 2, 1989 gELL G-1 FIELO MILNE POINT, COUNTY STATE ALASKA LITHOLOGY Sst; grysh brn, vfg, arty, shty, fr odor, m 8tn, dt gtd fluor Sst; grysh brn, vfg, sity, sheLL frog, n odor, n stn, n fluor Sst; grysh brn, vfg, sity, shLy, fr odor, m stn, dL gtd fluor Sst; grysh bm, vfg, stty, shty, fr odor, m stn, dt gtd fluor Sst; grysh brn, vfg, sLty, shiv, fr odor, m stn, dL gLd fluor 90° HORIZ: Sst; grysh brn, vfg, stty, shLy, fr odor, m stn, dt gtd fluor Sst; bm, vfg, stty, n odor, m stn, n fluor Sst; bm, vfg, stty, n odor, m stn, n fluor 90° HORIZ: Sst; brn, vfg, stty, n odor, n stn, n fluor Sst; bm, vfg, stty, fnt odor, m stn, di gLd fluor 90° HORIZ: Sst; brn, vfg, stt¥, shLy, fr odor, m stn, di gLd fluor Sst; brn, vfg, sLty, shLy, fr odor, m stn, dL gid fluor Sst; brn, vfg, stty, shty, fr odor, m stn, dL old fluor COt4PANY CONOCO~ INC, CORE TYPE 4 INCH FIBERGLASS SLEEVE HUD TYPE WATER BASE AIR HELIUH PER#EABILITY OiL WATER DEPTH POROSITY md. O/W SATN SATN ft. PERCENT HORZ. VERT. RATIO ~LDV ~LDV 4339.35 102. 4339.7 33.2 7O. 0.35 20.6 59.6 4340.6 34.1 172. 0.08 6.2 76.0 4341.4 34.9 308. 0.06 4.2 69.9 4343.0 35.1 490. 0.00 0.0 82.5 4343.7 36.4 446. 0.00 0.0 79.4 4344.4 36.6 1110. * 0.00 0.0 85.5 4345.7 37.0 ?53. 0.00 0.0 78.8 4346.6 36.9 588. 0.00 0.0 84.9 4347.4 602. 4347.6 36.7 748. 0.00 0.0 78.9 4348.5 36.4 961. 0.02 1.7 77.3 4393.45 38.1 508. * 0.66 30.6 46.2 4393.6 35.3 234. 0.85 37.0 43.4 4393.9 262. 4394.1 37.4 410. 1.27 41.3 32.5 4395.1 38.0 91. 0.10 4.9 51.5 4395.6 40.4 177. * 0.69 27.2 39.2 FRACTURED PETROLEUM TESTING SERVICE~ INC. CORE ANALYSIS APPARENT TOTAL SAND GRAIN SATN DENSITY ~Lov gm/cc 80.2 2.69 82.2 2.68 74.1 2.68 82.5 2.66 79.4 2.67 85.5 2.67 78.8 2.65 84.9 2.65 78.9 2.65 79.0 2.64 76.8 2.67 80.4 2.66 7I .8 2.67 56.4 2.66 66.4 2.65 PaGe No. FiLe No. Date 5 7OO68 October 2, 1989 UELL G-1 FIELD #ILNE POINT . . COUNTY : STATE ALASKA LITHOLOGY Sst; bm, vfg, sity, shiy, fr odor, mstn, dt gtd fluor Sst; brn, vfg, stty, shly, fr odor, matn, di Bid fluor Sst; brn, vfg, sity, shiy, fr odor, mstn, di Bid fluor Sst; brn, vf-fg, stty, shty, n odor, n stn, n fluor Sst; brn, vfg, sity, n odor, n stn, n fluor Sst; bm, vfg, sity, shell frag~ n odor, n stn, n fluor Sst; brn, vf-fg, ally, n odor, n sin, n fluor Sst; brn, vf-fg, arty, n odor, n sin, n fluor Sst; brn, vf-fg, $ity, n odor, n stn, n fluor Sst; brn, vf-fg, fnt odor, mstn, dl Bid fluor 90' HORIZ: Sst; bm, stty, fr odor, m sin, di gtd fluor Sst; brn, vfg, sity, fr odor, mstn, dl Bid fluor Set; bm, vfg, arty, fr odor, matn, dL gLd fluor Sst; brn, vfg, sity, shiy, fr odor, · atn, di Bid fluor Sst; bm, vfg, sity, shiy, fr odor, · atn, di Bid fluor COMPANY CONOCO, INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE MLIO TYPE MATER BASE PETROLEUM TESTING SERVICE, INC. CORE ANALYSIS AIR HELIUM PER#EABILITY OIL MATER TOTAL DEPTH POROSITY md. O/M SATN SATN SATN ft. PERCENT HORZ. VERTo RATIO ~LoV ~LoV XPV .... ..o ... .... . ....o..o.... ..o...oo.... ..... .... ..... 4395.8 35.2 90. 1.04 42.8 41.0 83.8 4396.4 35.1 192. 0.82 34.? 42.3 T?.0 4400.4 38.9 709. 0.11 7.4 67.2 74.6 4401.7 35.1 367. 0.31 19.3 62.1 81.4 APPARENT SAND GRAIN DENSITY gm/cc 2.67 2.67 2.67 2.67 MELL G-1 FIELD #ILNE POINT · . COUNTY : STATE ALASKA Page No. 6 Fire No. 70068 Date October 2, 1989 LITHOLOGY 90° HORIZ: Sst; brn, vfg, stty, shty, fr odor, m stn, di gtd fluor Sst; bm, vfg, stty, shty, fr odor, mstn, dt gtd fluor Sst; bm, vfg, fnt odor, mstn, dL gid fluor Sst; bm, vfg, sLty, fnt odor, mstn, dL gtd fluor TYPE OF EXTRACTION - DEAN STARE TOLUENE EXTRACTION CONFINING PRESSURE ON THE'PERMEAMETER · 27~ psi OIL GRAVITY SUPPLIED BY CUSTOMER · 16 A.P.I. ~ .. ~4~ ~ ..... . , , ' . 0 O / , 0 t /! { / 0 4//7 ¢ "a .............. ' 0 o ' ~ I ' ~ ~~ 0 _ 46......... 0 ..... i i t....... "~, 4 ~....... .................. , o ....... % ', ~ ...... ~ ~ 0 ~ I ' ~,~ ~,~?:m, ~ ( X F~tUre O~un A Abundant Company ..... ~ice Oompany .~~ ~ With Oil C ~ommon ~: .~. ..... ~, ..... ~_ O ' ~ s ~ ~ With Oil Staining R Rare Lo~fion: ~ ~P ~ O~ribedBy...~~~~ ~ ~ ..... ~o~ ~o~ ~ IP In Pan S Sightly or Slight . .... m ~ ' X = Y= D~ribed Date ...... ~. /~. ~ .......... M M~erately N No Orig.: .... . V Ve~ " , ,. . . ..,,, , , , ,, ~ ..~,,,~ , . ,, ,,,, ,. ,., .., ............ -- .......... ~inted in U.S.A. ' .... PRO-356 (CO-12-79) I~ir~t~,~l in U.S.A. ' .... PRO. 356 co' ~ogo¢o / / / / ~ / / / / / // ~ / ~, ~ ~ - , ...... ~ //.~o~ / / ~~~ // ~,.~ / / / ~/// ~ / ~ld~-~l~3~~~~ ~ .. " ~ X x ~ :d/~ X '~ X~ ~ ~ ~ ,, ~ ~ / ~ O' - 0 .... 0 ,, ~17~.5' X ~ 5 ~ )', ~ ,'~ ~ X~ '~~~ O' ~/7~.~ x ~ X ~ ~ x x ~ ~,~ ,~, ~ ~o ~, 0 , ~ ....... .... ~ ~ - 0 ~ ~ i ~l . I ~ ~ ~ ,,, ' ~~~ . ,,,, ~ .... .......... -- ~'~:--'~' ~o~"- / ~~ ~ .~ X Feature Occurs A Abundant Company .... :=':: ~ --' --';_ .......... . . ~ ~ ~ ~<. ~.~ ~ With.. Oil C COmmon cc: .... ~mple uesc?,ptm~~ ~ ~ With OilStaining R. Rare Lo~tion: ~ ~P ~ Described By ~~ ~ IP In Part S Slightly or Slight ...... Shot Date Orig.: X = Y= DeScribed Date ... ~./~ ~ M Moderately N No . ,. .... ..... . V Very i i i i , r i i i i Ill' I II II ~int~ in U.S,A. I ~C~ PR0-356 {C~12-79) //// .- ~, ,, y X: ~ , ,, ~ 0 0 " 0 0 ' 0 ..... ;0 .... ~ ~ X Feature Occurs A Abundant 'Company ~7':-- t, ;-; j~ ~o!~~d¢~ ¢ ..... With Oil C Common cc: ~mple Descriptio~ ~ ~. _.. ~ -- 0 With Oil Staining R Rare ........ Loation: ~ ~ ~ Described Byr~~ ',~~ _~ ; . e IP In Part S Slightly or Slight , , Shot ,Date ~ ~ Described Date ~./~ ~ ~ Moderately N No Orig.: ,, ' ' '' V Very ~ ~ ,, Printed in U.S.A. w,,, ,-?,-~ .,,. .... /-;/~,L.~~' / ~,.p'-/..?' /..p'/_.p- / _.~ ~ T---7 ~ /' ~---~ ,~ ....... ~ ...... ~z~/. ~ ~, ~ ~ vs _~___~__z__ ;~......&~ ?~.~; ~ .... 0 ' ..... _....._..... , .... --~--- . --- _- _ ........ ~ X fi~atur~ Oeeur~ ~ ~bundant Company ...... ~':-- S , -V ~o~ ~ ~~ ~ ~ ~ With Oil C Common cc: Lo~tion: ~ ~ ~ ' Described By~ ~~ ~ - ~ IP In Part S Slightly or Slight Shot Date M Moderately, N No Orig.: ,,, ~ , . ~ ~= Described Date ~'/~' ~ V Very Printed in U.S.A. . 0 I ., 0 '' ' 0 ' 0 . ~ ;~ 0 ,, ~ r~ 0 ,, , ~ , ~ ~ , .... 0 ' " ~' ~ ......... 0 ~ . ,, , . X Feature OccurJ Company ~T_'!tz ~ __ ,-;~ __ ~~~! ~ 8~¢ ~ ~ With Oil ~ Oo~mo. ~: ....... [o~tio.; ~ ~P ~ Described ~y .... -- '~ ~ IR I. Raft ~ Sli~htl~ or Slight . Shot Date . X = Y= Described Date, R./~. ~ .... M Moderately N No Orio.: , . V Very Il I I II ..... Print~ in U.S.A. PR0-356 {C~12-79) k.~~o,~// ///~-/~/ / / / / //~'/~~-~ ~~ ~ "~.~ ~ - , ¢~s.~ ~ ~z- s_ x~ ,- ..... ~ ,, , ' 0 .... -- O 0 ......... ,,, '- 0 - O ~ ,. .... ~ ~ '~ ~- ~M ,. ~ X Feature Occurs A Abundant Company ~-':-:: ~ , ~~~~/°Z/' ~~~ 7 ~ With Oil C Common cc:_ Lo.don: ~ ~ ~ .... .e,cribed Bye,:.,~',~2: ;~ ' ~ IP In Part 8 Slightly or Slight Shot Date Orig.: ~ ~= Described Date ~ /~. ~ M Moderately N No ' ' .......... V Very - ' ~ ~ PR0-356 (C~12-79 Printed in U.S.A. Weft ~-/ _ , ~o~. ~~~_~._~/ ~,~'- / ~~ ~'/~/~'/~e~ / ~,~' /~ ./ ~ ,~,,, 0 0 0 , ~ . 0 ,,, ,,,, 0 0 , , 0 ........ 0 .... 0 0 , , 0 ~0m~an~ ~':'- ~-W ~oz~ ~~ ~ X F~atur~ Occur~ A Abunflant · ............. '__ ~ ..... ~ With Oil C Common cc: Lo~tion: ~ ~P ~ Described By .... ~ _~ ? * Shot Date, ~ IP In Part S Slightly or Slight DesCribed Date. R.//~. ~ M Moderately N No Orig.: ........ ~= ,Y= , . - ~ . V Very ~ ~= ~~ , II [ I I II I i i iiiii I II IIII I II I I I Print~l in U.S,A. PRO-356 (CD-12-79) ' ~o~ ~ .. ~ ~ .~ Rema Oep~ Remarks , _ ,, , ~ ,,, 0 0 , , 0 ' 0 0 ' 0 0 ' X Feature Occurs A Abundant . Company ~7:=.:: :_ , _7 ~o/~ ~~ ~ With Oil C Common cc: ...... Lo~tion: ~ ~ ~ Described By . .... -' ~ IP In Part S Slightly or Slight Shot Date M Moderately N No . Orig.: X = Y= Described Date ~' ' ~ ~ V Very ,, ' ' ' ' ' ' PR0-356 IC~12-79] Printed in U.S.A. ,,,. c~~_~z~/~ .." / ~ "7 ~," /."/ ~" / ,*" /~,.,, ~ ,/-~-~ ,.~: / ~.~ t~ ~ 5, ~ j. X: x z / ~ )¢ X' ~'~ ~ , ~: 5 X'°~ ' ~ ,- ~~ "~ ,, . 0 0 ~,; .... ~~z ~ ~~~/6 X Feature Occurs A Abundant Oomp.ny ................ ' -%~ ~ With Oil ~ O°mmon cc: ~m~le Descriptio.s /~ ~ = ~ With Oil Staining fl Rare - ko~tion: ~ ~p ~ Des:dbed BV ~~ ~' ' ~ IP In P~rt ~ 8lightly o~ ~li~ht , ,, Shot Date ~*,-~~ 45~~/~~,~~s,/ ~ · ,,, , , . , ~ ~ Mod~r~t~ly N No Orig.: ...... .- = . - V Very , ,, ~ , ,, , Printed in U.S.A. occ. ~CC¢~,~irc~//9/.g.y, PRO-356 (CD-12-79) Page / of ~ .~ ~ ~%~ ~3~ - ~~ ~- .. 0 .. 0 0 0 ...... ,0 ~' 0 ~ 0 . ,, ~ ~ 0 ~ , ,, ., , ,, ~ ~ _~ __ ., ~ t~ ,, ' ' . - 0 ~ I. ... ~. , ,. ,, X Feature Occurs ~ Abundant Company ................... ~TJ:.__ ~_ . /___~~°~ ~~ ~1[ ~ With Oil C Common cc: , - ...... Location: ~ ~ ~ Described By - '~ ~ IP In Part S Slightlyor Slight ~ , Shot Date, ' Described Date ~. 1~. ~ .., ..... M Moderately N No Orig.: X~ Y' ,. .,. V Very ~ ~ ~$-r~ i iii i iiii i i i i i i i i i Printed in U.S.A. PRO-356 (CD-12-79) 0 , .. , 0 .0 ,, ' ..... 0 , .. , ~ 0 X Feature Occurs A Abundant Company ....... ~': " 2 :~ , ~og ~ 0~~ ~/~ ~ With Oil C Common cc: ~mple Descriptio~ ~ Lo~tion: ~ ~P ~ Described By __ "~ ~ ~ ~ ~ With Oil Staining R Rare Shot Date ~ IP In Part S Slightly or Slight - " Described Date ~./~. ~ M Moderately. N No Orig.: ........ .' X= Y= , ~~~: /2,3~ ~o5~ ~~ V Very ~ , _ , ,, ,i Printed in U.S.A. .~'~v'~-,.V'/c.~ ~,.~, C..,c> g'"~,,. , ~ (~)C~_a51~4(C~_/3 PRO-356 (CD~12-79) . Dep~ ~ ~ ' Remarks og X ~ ~ ~ X~ ,( i~ / A ;, ~( ~~ ~ ~ 25.1 ~ ~ ~ ~ ~ u: :< I 2< y ~ w ~ ~ 0 0 ..... ' '"' '0 ~ ' :1 ....... 0 ,, ' 0 ' ........ 0 ".., · . ~ , ,, 0 . .... · X Feature Occurs ~ AbUndant Company .................... ~:_'k:~ , : ~/o// ~~ ~~ ~ With Oil C Common cc: [o~tion: ~ ~ ~ ~e~erib~d B~ .... ~ ~ With Oil 8tainin~ -~ ~ IP In Part S Slightly or Slight Shot Oate~ X = Y= Described Date , ~./~. ~ M Moderately N No Orig.: . ~. V Very Printed in U.S.A. PRO-356 (CD-12-79) Page / of_..Z__~', e ~ ¢~- ¢~ .. q~o iX~ " ~-~. X X~ : ~ 0 0 0 , 0 0 ,,, 0 , , ~ ~ ~ L ~ , .... ~ G ~ ..... ,, Company ~='=-- ~ :","":~, ~o~ ~~ ~/~ X Feature Occurs A Abundant ..........~~ ~ With Oil C C0m~on cc: . . ~mple Oe,=riptio~~ ~ ~ With Oil 8raining R Rare Lo~tion: ~ ~ ~ Described BY~~ ~ IP In Part S Slightly or Slight Shot Date . . , . , ,, '. ~ = y= Described Date. ~ /~. ~.. . M Moderately N No Orig.: .... Prin,ed in U.S.A. ~-~ ¢~/. ~g~.~iz ~.~ ~_~_<._ :~ /-~. PROo356 (CO-12-79) ,, . , , , , , ~. ' , ~ O~ ~ X ~ ~ ~ X ~ ~uc. ., " ~ ~ ~~- ...... ' 0 . 0 ........... ,. i0 '0 .... .... 0 ..... , i,, 0 ,'0 '" J'O Company ......... ~_'~:: C., _~ ,__r~;/E~e~:?~°~ 0~~ ~/~ ~ With Oil C Common cc:j ,, ,,.. Lo~tion: ~ ~ ~ Described By_~~"--'. '~ ~ IP In Part S Slightly or Slight ...... Shot Date ....... 0 rig.: Described Date ~./~. ~ M Moderately N No x= ....... Y= ......... :, ~.~ ~.~,/~>~ ~ ~-/~ v vew ~ ~ ~- ......... . ............ Printed in U.S.A. Mr. John Boyle Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 9°.,503 (907) 564-7600 November 6, 1989 Dear Mr. Boyle' Enclosed please find the following log data and samples from the Milne Point Unit G-1 well (API Serial Number 50-029-21927-00)- Mud Log Mud Log 2,635' to 4,745' MD same Blackl ine Print Sepia Print '~Dry Cuttings ~2,.700' to 4,745' MD ~ ~Well site Core Description Routine Core Analysis SHDT ~J 2,625' to 4,735' MD SHDT '%-/same 4,102' to 4,469' MD 4,108' to 4,402' MD 52 envelopes (2.5" x 4") 6 pages Color Computer Log Plot Film SHDT SHDT SHDT 3,495' to 4,734' MD ~2,625' to 4,736' MD same Tabulated Computations LIS Tape (7" reel) with Verification Listing LIS Tape (10" reel) with Verification Listing These materials should complete your files for this well. Should you have any questions, please call me at 564-7640. Sincerely, (/~' J'7/'~"~ ~ ~f/__-ff,~,~,~_~~ c-- J~ S-~ ~~ ~3 ~~ ~~.~ Stephen . Davies ~~~ Staff Geologist ~~ / ~ cc: G-1 well file ~~_ N~ Oil & Gas Cons. Commi~O~ R E C t ALASKA OIL AND GAS CONSERVATION COMMISSION 0 R I 6 I J~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Alter casi n g __ Change approved program __ Pull tubing __ Variance 12. Present well condition summary Total depth: measured true vertical Suspend __ Repair well __ 2. Name of Operator I 5. Type of Well: ~ Development OONOOO INO · ~ Exploratory ~ 3. Address ~ Stratigraphic_ . . _ _ .... Q ~ ~ tl '~ Service 4. Location of well at surface ' 3644' FNL, 3364' FEL, SEC 27, T13N, R10E, UM At top of productive interval 4620' FNL, 3300'FEL, SEC 27, T13N, R10E, UM At effective depth N/A At total depth 4779t FNL, 3293' FEL, SEC 27t T13Nt R10Et UM Plugs (measured) Operation shutdown ~. Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pedorate __ Other _. 6. Datum elevation (DF or KB) KB 28' Effective depth: measured true vertical feet 4740' feet 4563' feet feet Junk (measured) 7. Unit or Property name feet MIT-NE POINT UNIT 8. Well number 9. Permit number ~i9-29 i0. APl number 50-- 11. Field/Poo~' .... UPPER CRETAC~,,OUS -' SOS Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ~ngth Size 80' 13 3/8 2590' 9 5/8 4698' 7 Cemented Measured depth True vertical depth 100 CF 108' 200 BBLS E 2618' 96 BBLS G 50 BBLS G 4726' 108' 2513' 4548' measured 4164'-4186', true vertical 4004'-4025' , 4196'-4202', 4034'-4040', 4216'-4228' 4054'-4066' t ECEIv£b Tubing (size, grade, and measured depth) 2 7/8", 6.4 #/FT, [,-80, EUE @41,~3~$~ Oil.& ~as Con& Com~i~/o~ Packers and SSSV (type and measured depth) E~ Drill Bridge Plug ~ 4110' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation Nov~_mh~. ~' 9 _ !",, Igill[.._ Gas __ 16. If proposal was ver6ally approved 11/02 / 89 RUSS Doualas Name of appr6~'er Date approved Service 17. I hereby certify thane foregoing is true and correct to the best of my knowledge. Title FOR C61~I~ISSION USEONLY 15. Status of well classification as: Suspended __ Conditions of approval: Notify Commission so representative may witness [ Approval No. ¢_ ¢7'~- Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~,~-v~,d CoPY Original S~gned By Approved by order of the Commission D~vid W. Johnston Commissioner Date //- 7-'J/~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE · shutdown of the g-1 well until _ o erat~_°^nal~nitial flow testing has been ~ estS an P 99u- ConOCO ~e__qu~ ~uarter of ~ ' ~o ~000 ~s~- · ~. pick up tubing ~nd l~nd in hanger 3. install back pressure v~lve' 4. ND BOP st~ck- 5. NU tree and move off riq. he G · well : _ erataon~ design ann and Pru~rm 407 wa= wellS. ~0/~/s~- RECEIVED NOV 0 '.,. 19iI© Anchorag~ Made By Checked By Date Page of Catculatiort Sh, eet Title Job No Field State '~' -.,.. STATE OF ALASKA ALASKA~ .AND GAS CONSERVATION C(~..,MISSlOIIiJ J{ ] G IN A WELL COMPLETION OR RECOMPLETION REPORT AND LOCi 1. Status of Well Classification of Service Well OIL ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ~=-~=] ..... LJUlllt~l I I,~ 2. Name of Operator 7. Permit I~umber cnuncn TNt 89-29 37 ~,~t~J-re-s; ..... 8. APl Number P:0: Box 34-0045. p.'C,,dhn~ Ray; Ak qq7~4 50- n:)q-plC197 4. Location of well at surface 9. Unit or Lease Name 3644' FNL, 3346' FEL, Sec 27, T13N, RIOE, U.H. Milne Point Unit At Top Producing Interval 10. Well Number 4610' FNL, 3294' FEL, Sec 27, T13N, R10E, U H ~--~ At Total Depth ' ' 1'1. ~:ield and Pool 4760' FNL, 3250' FEL, Sec 27, T13N, R10E, U.H. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KR = R_q_3' HRIJ An -?Rql')tl Ilnn~_~' C~'~taCC_AH~-Wp$~. $~k 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband, r15. Water l~e~p~h; if offshore 116. No. of Completions ~3R/1 I /RQ ~fl/1Q/flQ hR/')9/flQ M/A feet MSL MAma l~."fo~a~'D~l~th (MD+TVD) l~'~g'l~a'c~'Eepth (MD+I'VD) 1E.-dir~fo~Ji Survey J 20. Del~[A ~here SSSV set 21. Thicl~r~'s's'~f Permafrost 4740'MD,4563'TVD 4725'ND,4548'TVD YESE~x NO~J N/A feetMD +1800' 22. Type Electric or Other Logs Run DLL/HSFL/LSS/GF/LDT/CNL/HR Dipmeter/Sidewall Cores/AMD Hud Logs/Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 13 3/8" 48 H-40 Surface 110'RKB 30" Arc. Set to surf. None · g 5/8" 47 L-80 Surface 2618'RK[ 12 1/4 200 bbl~ Permf 'E' None 96 bbls Class 'G' 7" 29 L-80 Surface 4726'RK[ 8 1/2 50 bbls Class 'G' None · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. "~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED None · 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not tested Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-CmL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED.~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE · 28. COP E DATA , ,, Brief description of lith01ogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core chips will be delivered separately. See attachment for descriptions. RECEIVED 0 3 1989 ~asRa Oil,& ~as Cons. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29.~ ~i, ~'~ ~ i,~ ~ ~ ~ 30. GEOLOGIC MARKERS FORMATION TESTS ,, NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T/Shallow 0il 3650' 3502' None Performed Sands (Upper Ugnu) T/Lower Ugnu 3887' 3733' T/West Sak 4303' 4141' , tore uescrlprl on, Dai l y Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 12051 RIVERA RD. · SANTA FE SPRINGS, CA 90670-2289 TELEPHONE (213) 698-0081 · PANAFAX (213) 693-0947 October 2, 1989 Mr. Michael Zotzky Conoco, Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 Dear Mr. Zotzky: Re= Core Analysis File No.= 70068 Enclosed is a final core analysis report for routine core analysis, 90 degree horizontal core analysis: and vertical permeability tests performed on material from Point Mllne G-1 well, north slope Alaska. Laboratory procedures have been included for your reference. We appreciate this opportunity to be of service and trust these data prove beneficial to the development of this reservoir. Sincerely, Petroleum Testing Service, Inc. Peter T. Schuyler President PTS:rdl Encl. Client: Conoco, Inc. Well: G-1 Field: 'Milne Point File: 70068 Date: Oct. 2, 1989 ROUTINE CORE ANALYSIS AND 90 DEGREE HORIZONTAL CORE ANALYSIS 1. Drill 1" diameter sample plug using liquid nitrogen as cutting fluid, trim to right cylinder. 2. Package with preweighed aluminum foil, teflon tape and fit with 200 mesh stainless steel end screens. 3. Seat package to sample in a Hassler-type sleeve using 275 psi as confining stress. 4. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volumes. 5. Vacuum dry at 150°F until stable and weigh to 0.01 grams. 6. Cool samples in dessicator to room temperature and measure sand grain volume using a Boyle's Law helium porosimeter. Calculate grain density. 7. Mount sample in a hydrostatic Hassler-Type sleeve using a confining stress of 275 psi. 8. Measure pore volume using a Boyle's Law helium porosimeter, determine porosity and fluid saturations. 9. Measure permeability with nitrogen gas using a calibrated flow tube-type permeameter. VERTICAL PERMEABILITY 1. Follow steps one through five of the procedure above. · Mount sample in a hydrostatic Hassler-type sleeve using a confining stress of 275 psi. Measure the permeability with nitrogen gas using a calibrated flow tube-type permeability. CONOCO, INC. WELL: G-1 FIELD: MILNE POINT ROUTINE CORE ANALYSIS OCTOBER 1989 FILE 70068 PETROLEUM TESTING SERVICE, INC. Pmge No. FILe No. Dmte 1 7OO68 October 2, 1989 COI4PANY CONOCO, INC. CORE TYPE & INCH FIBERGLASS SLEEVE HUO TYPE I, IATER BASE CORE ANALYSIS AIR HELIUM PERHEABILITY OIL blATER TOTAL DEPTH POROSITY md. O/U SATN SATN SATN ft. PERCENT HORZ. VERT. RATIO ~LoV ~°V ~°V .0..... .......e ....0....0.. ............ .0... .0.. ..... 4107.8 39.2 1610. 0.00 0.0 80.& 80.4 4111.1 36.2 597. 0.00 0.0 81.0 81.0 4112.25 36.6 757. 0.00 0.0 81.0 81.0 4113.4 36.6 756. 0.00 0.0 76.2 76.2 4137.2 36.1 404. 0.18 8.8 48.5 57.3 4138.0 36.7 ~94. 0.65 28.4 43.6 72.0 4152.2 38.3 549. 0.82 35.7 43.4 79.1 4168.8 16.0 55. 1.21 30.8 25.5 56.3 4169.7. 8~8 3.8 0.15 6.4 43.8 50.2 4169.7 3.5 4170.5 25.2 588. 2.23 41.9 18.7 60.6 4171.9 42.6 7910. .98 36.3 37.0 73.3 4172.7 42.4 >10000. 1.29 38.3 29.7 68.0 418~.7 43.5 >10000. 0.66 37.6 57.1 94.7 418~.7 43.1 7860. .99 47.9 48.6 96.5 4180. 1.48 45.6 30.7 76.3 0.45 28.2 62.5 90.7 4185.7 36.1 2870. 4185.7 4185.8 33.4 110. APPARENT SAND GRAIN DENSITY gm/cc 2.63 2.65 2.64 2.64 2.63 2.63 2.62 2.62 2.63 2.64 2.62 2.61 2.63 2.60 2.66 I~ELL G-1 FIELD #ILNE POINT COUNTY STATE ALASKA LITHOLOGY Sst; gry, Yfg, aLLy, n odor, n stn, n fluor Sst; gry, vfg, ably, n odor, n stn, n fluor Sst; gry, vfg, aLLy, n odor, n stn, n fluor Sst; gry, vfg, aLLy, n odor, n mtn, n ftuor Sst; gry, vfg, sLty, sh tm, fnt odor, ~stn, dL gLd fluor Sst; gry, vfg, shty, fr odor, m mtn, dt gtd fluor Sst; gry, vfg, sLty, fr odor, mstn, dL gid fluor Sst; bm, vfg, sity, wi c3,t, fr odor, m mtn, di gtd fluor Sst; brn, vfg, stty, wi cmL, fr odor, mstn, dt gtd fluor Sst; brn, vf-fg, aLLy, gd odor, mstn, di gid fluor Sst; bm, vf-mg, ltd odor, mstn, dL gLd fluor Sst; bm, mg, gd odor, mstn, dt gid fluor Sst; bm, mg, gd odor, mstn, dt gtd fluor 90° NDRIZ: Sst; bm, mg, gd odor, ~ mtn, di gid fluor Sst; brn, mg, sh tm, gd odor, m mtn, dt gLd fluor 90° HORIZ: Sst; brn, mg, shLy, fr odor, m 8tn, di gtd fluor PETROLEUH TESTING SERVICE, INC. Page No. FILe No. Date 2 7OO68 October 2, 1989 CGI4PANY CONOCO, INC. CORE TYPE & INCH FIBERGLASS SLEEVE HUD TYPE WATER BASE CORE ANALYSIS AIR HELIUI4 PERHEABILITY OIL I~ATER TOTAL DEPTH PO~OSLTY md. O/V SATN SATN SATN ft. PERCENT HORZ. VERT. RATIO XPV XPV XPV III!111 iIilllll ii1111111~!1 I!I!iii!i111 Illll IIII Ii111 4186.6 44.7 4570. 0.80 38.4 48.3 4200.6 40.1 :3430. 1.37 45.7 33.3 79.0 4201.2 41.7 3780. * 1.32 45.2 3~.3 ~217.8 33.1 500. 0.80 36.6 45.9 4225.5 35.7 256. 2.31 53.2 23.0 4226.65 38.3 316. 1.14 38.6 34.0 4227.4 36.? 419. 1.97 46.5 23.6 4228.7 33.5 230. 1.16 41.2 35.4 &2~9.5 36.0 437. 1.77 46.1 26.1 4230.7 34.2 256. 1.97 50.1 25.4 4231.25 46.1 2410. * 0.48 31.1 6~.8 4232.5 32.9 131. 1.11 42.1 37.8 4233.9 33.4 136. 0.79 34.2 43.4 423~.9 35.1 287. 1.68 46.0 27.4 4235.9 34.2 743. 0.94 38.3 40.6 4236.9 33.8 189. 0.92 38.6 42.0 423?.9 26.8 37. 0.06 4.? 81.0 APPARENT SAND GRAIN DENSITY gm/cc 2.60 2.63 MELL G- 1 FIELD HILNE POINT COUNTY STATE ALASKA LITHOLOGY Sst; brn, mg, sad odor, m arm, dL gLd fluor Sst; bm, fg, gd odor, matn, dL gLd fluor 79.5 2.6~ Sst; 82.5 2.63 Sst; 76.2 2.6~ Sst; 72.6 2.6~ Sst; 7O.1 2.65 Sst; 76.6 2.65 Sst; 72.2 2.66 Sst; 75.5 2.65 Sst; 95.9 2.6~ Sst; 79.9 2.65 Sst; 77.6 2.6;, Sst; 73.4 2.66 Sst; 78.9 2.66 Sst; 80.6 2.6~ Set; 85.7 2.6~ Sst; bm, vf-fg, gd odor, matn, dL gLd fluor bm, vfg, aLLy, gd odor, mstn, dL gtd fluor grysh bm, vfg, arty, gd odor, mstn, dL gLd fluor grysh bm, vfg, aLLy, gdoclor, matn, dt gLd fluor bm, vfg, Iici odor, matn, dL gLd fluor bm, vfg, aLLy, gcl odor, matn, dL gid fluor bm, vfg, sheLL frag, ed odor, matn, dt gtd fluor bm, vfg, sLty, sh tm, gd odor, matn, d~ gid fluor bm, vfg, aLLy, gd odor, mstn, dL gLd fluor brn, vfg, aLLy, shLy, ltd odor, matn,, dL gLd fluor bm, vfg, stty, shLy, gd odor, mstn, dL gLd fluor bm, vfg, aLLy, ed odor, m 8tn, dL eld fluor bm, vfg, aLLy, gd odor, mstn, dt gLd fluor bm, vfg, shLy, ed odor, matn, dL gLd fluor bm, vfg, shiv, sheLL frog, fnt odor, mstn, dL gLd fluor * FRACTURED PETROLEUH TESTING SERVICE° INC. PsgeNo. FJ[e No. Dste 3 October 2, 1989 ~ANY COHOCO, INC. CC~ TYPE & INCH FIBERGLASS SLEEVE HUD TYPE LMTER BASE CORE ANALYSIS AIR HELI~ PERHEABILITY OIL ~TER TOTAL DEPTH ~ITY 4. O/W SATN SATN SATN ft. PERCENT HORZ. VERT. ~TIO ~V ~V ~V i~llil~ I!!i!!!! II!111111111 iiiliilllill I!111 Illl I!!II 4310.6 35.3 587. 1.37 51.1 37.2 88.3 4311.6 36.1 ?48. * 0.72 35.1 48.6 83.? 4314.6 38.8 650. 0.77 3?.3 q.4 85.7, 43~5.3 33.5 224. 0.75 40.2 53.8 94.0 4315.6 731. 4316.3 984. 4316.35 35.9 650. 0.38 25.3 66.5 4317,.3 37,.6 1060. * 0.30 19.7, 64.9 4318.3 36.6 509. 0.27 17.5 65.0 4318.3 38.0 1160. 0.46 26.8 57.7 4319.2 37,8. 4319.3 37.2 630. 0.24 16.8 70.0 4320.3 35.1 155. 0.69 36.7 53.0 4321.3 33.0 132. 0.70 34.1 48.4 4325.4 30.1 84. 0.31 19.9 64.3 4326.8 35.0 105. 0.50 27,.2 54.9 4326.95 43.9 )10000. 0.66 39.5 59.6 4327,.9 35.0 221. 0.46 26.8 58.0 ~ARENT ~ND ~IN DENSITY ~cc 2.62 2.66 2.64 2.66 91.8 2.65 84.6 2.64 82.5 2.65 84.5 2.66 86.8 2.66 89.7 2.67, 82.5 2.66 8~.2 2.64 82.1 2.65 99.1 2.7,1 8~.8 2.65 UELL G-1 FIELD HILNE POINT -CCXINTY STATE ALASKA LITHOLOGY Sst; grysh bm, fg, sity, gd odor, m sin, di Bid fluor Sst; grysh bm, vfg, shLy, fr odor, m stn, dL old fluor Sst; bm, vfg, sLty, fr odor, m sin, dt old fluor Sst; bm, vfg, shty, gd odor, m stn, dt old fluor Sst; bm, ~f-fg, stty, fr odor, m stn, dt Bid fluor Sst; bm, vf-fg, stty, fr odor, m stn, dL etd fluor Sst; bm, vf-fg, stty, fr odor, . sin, dt Bid ftuor 90~ HORIZ: Sst; bm, vf-fg, 8try, fr odor, m sin, dt gtd fluor Sst; ~n, vf-fg, stty, fr ~r, m itn, dt gtd fluor Sst; bm, vf-fg, sLty, shty, fr ~r, m stn, dL eld fluor Sst; brfl, vf-fg, stty, shty, fr odor, m stn, dt gLd fluor Sttst; grysh bm, vf-fg, shLy, fr odor, m sin, dL gLd fluor Sst; bm, vfg, sLty, sh tm, fr odor, m Itn, dt gLd fluor 90° HORIZ: Sst; bm, vfg, stty, ih tm, fr odor, m 8tn, dt gid fluor Sst; bm, vfg, stty, fr odor, m sin, dL gLd fluor FRACTURED PETROLEUM TESTING SERVICE, INC. Page No. Fi Le No. Date & October 2, 1989 COW)ANY C~OCO, INC. GOSE TYPE & INCH FIBERGLASS SLEEVE HUD TYPE WATER BASE COSE ANALYSIS AIR HELIUH PERNEABILITY OIL WATER TOTAL DEPTH POROSITY Ind. O/W SATN SATN SATN ft. PERCENT HORZ. VERT. RATIO ~:~V ~oV ~oV o.0..-. -.o-0..o -----.-..-.0 ..0......... ..... o.oe ...00 4327.95 13~. 4328.8 34.5 107. 0.49 26.8 54.4 81.2 38. 0.00 0.0 88.2 88.2 0.51 26.2 51.7 77.9 0.67 32.8 48.7 81.5 0.45 26.3 59.0 85.3 4329.9 26.5 12. 4331.3 35.4 66. 4331.3 4332.3 32.2 72. 4333.3 33.1, 94. 0.39 24.1 61.7 85.8 4333.3 32.8 0.00 0.0 85.1 85.1 0.00 0.0 81.4 81.4 0.00 0.0 73.1 73.1 4334.3 35.3 385. 4335.6 35.7 440. 4335.7 36.4 376. 0.02 1.3 7'6.1 77.4 0.38 24.7' 64.3 89.0 0.29 19.6 66.3 85.9 0.45 25.3 56.8 82.1 4335.? 4336.0 36.3 518. 4337.35 31.5 41. 4337.7 32.5 ~. 4338.7 32.5 38. APPARENT SANO GRAIN DENSITY gm/cc 2.66 2.62 2.65 2.66 2.68 2.68 2.6? 2.6? 2.66 2.66 2.68 2.67 2.69 blELL G-1 FIELD NILNE POINT COUNTY STATE ALASKA LITHOLOSY Sst; grysh brn, vfg, ally, 8hLy, fr odor, m 8tn, dt gtd fluor Sst; grysh bm, vfg, sLty, shell frag, n odor, natn, n fluor Sst; grysh bm, vfg, sity, shty, fr odor, matn, dt gid fluor Sst; grysh bm, vfg, ally, shiy, fr odor, matn, dt gLd fluor Sst; grysh bm, vfg, sity, ahiy, fr odor, matn, di gtd fluor 90° HORIZ: Sst; grysh bm, vfg, 8Lty, 8hty, fr odor, m Itn, dt gtd fluor Sst; bm, vfg, ally, n odor, matn, n fluor Sst; bm, vfg, ally, n odor, matn, n fluor 90° HORIZ: Sst; bm, vfg, arty, n odor, n stn, n fluor Sst; bm, vfg, stty, fnt odor, m 8tn, dt gid fluor 90° HORIZ: Sst; bm, vfg, ally, 8hiy, fr odor, matn, dL gLd fluor Sst; bm, vfg, sity, shLy, fr odor, natn, dL gtd fluor Sst; bm, vfg, ally, shty, fr odor, Batn, dL gid fluor PETROLEUH TESTING SERVICE, INC. Page No. Fire No. Dote 5 7OO68 October 2, 1989 CGHPANY CONOCO, INC. CORE TYPE 4 INCH FIBERGLASS SLEEVE HUD TYPE WATER BASE AIR HELIUIq PERHEABILITY OIL WATER DEPTH POROSITY md. O/W SATN SATN ft. PERCENT HORZ. VERT. 'RATIO XPV XPV ....0.0 ..0..... .0...0...... ............ .0... .... ..... 4339.35 102. &339.7 33.2 70. 0.35 20.6 59.6 4340.6 34.1 172. 0.08 6.2 76.0 4~1.4 34.9 308. 0.06 4.2 69.9 4343.0 35.1 490. 0.00 0.0 8?..5 CORE ANALYSIS APPARENT TOTAL SAND GRAIN SATN DENSITY XPV gm/cc ~.00. 00.0...00. 80.2 2.69 82.2 2.68 74.1 2.68 82.5 2.66 4343.7 36.4 446. 0.00 0.0 79.4 79.4 2.67 4344.4 36.6 1110. * 0.00 0.0 85.5 85.5 2.67 4345.7 37.0 753. 0.00 0.0 78.8 78.8 2.65 4346.6 36.9 588. 0.00 0.0 8~.9 84.9 2.65 4347.4 602. 4347.6 36.7 748. 0.00 0.0 78.9 4348.5 36.4 961. 0.02 1.7 77.3 4393.45 38.1 508. * 0.66 30.6 46.2 4393.6 35.3 234. 0.85 37.0 43.4 4393.9 262. 4394.1 37.4 410. 1.27 41.3 32.5 4395.1 38.0 91. 0.10 4.9 51.5 4395.6 40.4 177. * 0.69 27.2 39.2 78.9 2.65 79.0 2.6~ 76.8 2.67 80.4 2.66 73.8 2.67 56.4 2.66 66.4 2.65 WELL G-1 FIELD NILNE POINT COUNTY STATE ALASKA LITHOLOGY .00.0.... Sst; bm, vfg, oity, oh{y, fr odor, motn, di gid fiuor Sst; bm, vfg, arty, 8hty, fr odor, m itn, dt gtd ftuor Sst; bm, vfg, stty, shty, fr odor, mstn, dL gLd ftuor Sst; bm, vf-fg, sLty, shLy, n odor, n stn, n fluor Sst; bm, vfg, sLty, n odor, n stn, n fluor Sat; bm, vfg, sLty, sheLL frog, n odor, n stn, n ftuor Sst; bm, vf-fg, arty, n odor, notn, n fluor Sst; bm, vf-fg, sLty, n odor, n stn, n fluor Sat; bm, vf-fg, sLty, n odor, n 8tn, n fluor Sst; bm, vf-fg, fnt odor, mstn, dL gtd fluor 90° HORIZ: Sst; brn, stty, fr odor, mstn, dL gtd f{uor Sst; bm, vfg, stty, fr odor, m 8tn, dL gLd fluor Sat; brn, vfg, sity, fr odor, mstn, dL gtd fluor Sat; brn, vfg, oLty, shiy, fr odor, mstn, dL etd fluor Sst; bm, vfg, otty, ohLy, fr odor, motn, dt gtd fluor * FRACTURED PETROLEUM TESTING SERVICE, INC. Page No. FI Le No. Date 6 7OO68 October 2, 1989 COLOANY CONOCO, INC. CORE TYPE & INCH FIBERGLASS SLEEVE HUD TYPE LMTER BASE CORE ANALYSIS AIR HELIUM PERHEABILITY OIL UATER TOTAL DEPTH POROSITY md. O/W SATN SATN SATN ft. PERCENT HORZ. VERT. RATIO XPV XPV XPV I!11111 til~ilil lllitlliilli ili!11111111 Ii!!1 Ilil iliti 4395.8 35.2 90. 1.04 42.8 41.0 83.8 4396.4 35.1 192. 0.8?. 34.7 42.3 77.0 4400.4 38.9 709. 0.11 ?.4 67.Z ?4.6 4401.7 35.1 367. 0.31 19.3 62.1 81.4 APPARENT SAM) GRAIN DENSITY gm/cc 2.6? 2.6? 2.67 2.67 bELL G-1 FIELD HILNE POINT COUNTY STATE ALASKA LITHOLOGY 90° HORIZ: Sst; bm, vfg, sLty, 8hLy, fr odor, m stn, dL old fluor Sst; bm, vfg, stty, shLy, fr odor, m stn, dL gtd fluor Sst; bm, vfg, fnt odor, m stn, dL gLd fluor Sst; bm, vfg, sLty, fnt odor, m stn, di gLd fluor TYPE OF EXTRACTION ' DEAN STARK TOLUENE EXTRACTION CONFINING PRESSURE ON THE pERHEANETER "275 psi OIL GRAVITY SUPPLIED BY CUSTONER" 16 A.P.I. 12051 RIVERA RD. · SANTA FE SPRINGS, CA 90670-~.'P89 TELEPHONE (213) 698-0081 · PANAFAX (213) 693-0947 October 4, 1989 Mr. Michael Zotzky Conoco, Inc. 3201 C Street, Suite 200 A~chorage, AK 99503 Dear Mr. Zotzky= Re= Core Analysis File No.= 70068 Enclosed is a final core analysis report for sidewall core analysis test performed on material from Point Milne G-1 well, north slope Alaska. Laboratory procedures have been included for your reference. We appreciate this opportunity to be of service and trust these data prove beneficial to the development of this reservoir. Sincerely, Peter T. Sc~Yuyler ~~President PTS:rdl Encl. Client: Conoco, Inc. Well: G-1 Field: Milne Point File: 70068 Date: Oct. 4, 1989 SIDEWALL CORE ANALYSIS 1. Trim sample to right cylinder. 2. Package with pre-weighed aluminum, teflon tape, and fit with 200 mesh stainless steel end screens. 3. Seat package to sample in a Hassler-type sleeve using 275 psi as confining stress. 4. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volumes. 5. Vacuum dry at 150°F until stable and weigh to 0.01g. e Cool sample in dessicator to room temperature and measure sand grain volume using a Boyle's Law helium porosimeter. Calculate sand grain density. 7. Mount sample in Hassler-Type sleeve using a confining stress of 275 psi. 8. Measure pore volume using a Boyle's Law helium porosimeter, determine porosity and fluid saturations. 9. Measure permeability with nitrgen gas using a calibrated flow tube-type permeameter. CONOCO, INC. WELL: G-1 FIELD: MILNE POINT SIDEWALL CORE ANALYSIS OCTOBER 1989 FILE 70068 RECEIVED oc-r 2,~,~, ~19~9 Gas'Cons. (~omm~ssior~ ~ncho~e PETROLEIJH TESTING SERVICE, INC. P~ge No. FiLe No. DeLe 1 70O68 October 4, 1989 CONPANY L~IOCO, INC. CONE TYPE SIDEWALL SAI4PLES HUD TYPE WATER BASE HELIUH AIR OIL WATER TOTAL DEPTH POROSITY PERIqEABIL]TY O/W SATN SATN SATN ft. PERCENT md. RATIO ~ov ~ov XPV 3893.9 37.1 93. 0.88 &Z.O 47.9 89.9 3931.05 37.1 1200. 0.83 41.7 50.3 92.0 3931.9 34.3 153. 0.81 &3.6 53.7 97.3 3938.12 34.2 134. 0.67 39.1 58.7 97.8 bELL FIELD COUNTY STATE G-1 NILNE POINT ALASKA SIDEWALL CONE ANALYSIS APPARENT SAND GRAIN DENSITY gm/cc 2.65 :~.61 :~.62 2.63 RECOVERED INCHES LITHOLOSY Sst; bm, vfg, stty, gd odor, clk stn, dt Bid fluor Sst; dk bm, f-mB, gd odor, dk 8tn, dL gtd fluor Sst; brn, fg, gd odor, dk stn, dL gtd fluor Sst; bm, fg, gd odor, dk stn, dt g[d fluor TYPE OF EXTRACTION - DEAN STARK TOLUENE EXTRACTION CONFINING PRESSURE ON THE PERHEAHETER · 275 psi OIL GRAVITY SUPPLIED BY CUSTOMER · 11A.P.I. These results must be used uith caution. Side,aLL samples ere obtained by impact coring. This method cen fracture herd forlmtions, therebypossibLy tncreesing the porosity and pomeabitity. In*soft formtions, i~psct coring can cor~act the samples, resulting in decreased porosity and pemeabitity. DriLLing mud.my penetrate frectures and soft fomatfons, thereby effecting the porosity, pomeabitity, fluid seturetion, grein density and cation exchange capacity results. MILNE POINT G-1 CORE DATA Co~e Cored Actual Rec. % Sand % Silt 1 20 15.6 46 54 2 31 30.0 18 82 3 31 20.3 25 75 4 30 24.7 22 78 5 28 29.7 48 52 6 30 15.6 0 100 7 15 14.8 16 84 8 2 6,6 0 84 9 32 27,6 44 56 10 26 28,0 81 19 11 30 11.0 0 100 12 17 30.8 23 77 13 30 23.1 6 94 14 14 3.6 0 100 15 18 24.6 0 12 % Clay 88 RECEIVED NOV o ]98 q ~_A.!~ska.OJ! & Gas Cons~ commission Conoco Inc. {' Daily Drilling Report~ FORMATION: DEPTH: q ? 2~--__.~/ "-~ j) ALASKA FOOTAGE Last 24 Hrs. WEATHER: Wind: Temp.: Visibility: From DA IL Y OPERA TIONS ,¢... O~cco REcEiVED i~ov o 3 DEVlA T/ON ll eackground Gas UnitsIlI Trip Gas Depth Degrees DIREC T/ON Depth Degrees DI REC T/ON Units Connect]on Gas Units MUOPROPERTIES: Type ~,J '~~ OAILYMUDOOST ~ WEIGHT t V/SC ~'V .. ..... I _ I A.P.I. WLI HTHP I 'FILTER _ I _. I CHLO- I Sa,U SOLIDS OIL iT , i ~ i i I , I I I ! STROKE PUMP JEt ' ' DP HYDRAULICS LINER SIZE LENGTH I SPM GPM I PRESSURE VELOCITY I 'DC BHA OFF BOTTOM ROT. WT. S.O. WT. P.U. WT. B.H.A. LENGTH B.H.A. WT. DA YS ON JARS NO. BOP Tested: P~ SERV. PERSONNEL Conoco Inc. FORMATION: ~ ~-~ ~ ~ Daily Drilling Report WEATHER: ALASKA IFOOTAGE Last 24 Hrs. Visibility: ~ & O"ti From OT-CX~ o~o0 ?_leo DAILY OPERA TIONS · '~,~,,,-c~ 7_'5 of' DE VIA TION Depth Degrees DIRECTION Depth I I Background Gas Units Trip Gas Units I Connection Gas Units Degrees DIRECTION Depth Degrees DIRECTION Type ~C-I "'~¢..-, H~ MUD PROPERTIES: WEIGHT t VISC'. I PV . - J ..... I A.p.I.w (PPG) (SEC.) (CP) Y I-' UI:L,~ p~ (CC) I I~ I I ' I HYDRA ULIOS LINER SIZE STROKE L ENG TH WELL CONTROL DALLY MUD COST Iq CUM. MUD COST I I I T DEPTH cr~_I .o~i=~,.o i BIT w.. I ROT. CONDITION IN OUT .... I ...... I ......... I (MLBS.) I RPM T B G I SPM ..... PRESSURE VELOCITY ~ ~v __ __ PSI __ PUMP(S) __ SPM CASING P-LOWS A T FT. PUMP(S) SPM I BHA OFF BOTTOM ROT. WT. S.O. WT. P.U. WT. B.H.A. LENGTH B.H.A. WT. DA YS ON JARS NO. BOP Tested: Conoco Inc. (' Daily Drilling Report( ALASKA · FOOTAGE FORMAT/ON: ~-~L~..~) DEPTH: q ~/--~O (~LI~ ILast 24 Hrs. /, _17oF' DAILY OPERA TIONS ~ To "Cst=. '1 I DEVlATION Background Gas Units Trip Gas Units I Connection Gas Units Depth Degrees DIRECTION Depth Degrees DIRECTION DepthlDegreestDIRECTION MUD PROPERTIFS, Type K(~.~.~/~){-~'~i~[~ ]DALLY MUD COS~TT Zi Z~ CUM. MUD COS~4 ~) ~~ .. ' ~71 I I I I ' STROKE PUMP JET DP/_ HYDRAULICS LINER SIZE SPM GPM LENGTH Ii %70 · PRESSURE VELOCITY ... 'DC WELL cONTROL P-LOWSAT FT. [ PUMP(S) ~ SPM . PSI ~ PUMP(S) __ ___ SPM ~ P~ .~ i_ .,. BHA ~ , . ., - ., / , / / / / o~ ~o=o~,o~. ~. ~ qo Lo. w~. I ~ ~.~. ~._1 ~o ~.,.~. ~A~,. ~v 7 ~.,.* ~. o~,~,,co~, Ssosq co,~.oo~, flOq,mzt ,~,~'P,~-~lql -I~o~v,~o~ d. Conoco Inc. FORMATION: St~ ~ ~) WEATHER: Wind: Daily Drilling Report ALASKA DAILY OPERA TIONS OF,, RECEIVED ¢¢aska Oil & Gas Cons, I I' DEVIATION Background Gas Units Trip Gas Units Connection Gas Units Depth Degrees DIRECTION Depth Degrees { DIRECTION Depth ! Degrees DIRECTION MUD PROPERTIES: Type ~(~/~f'4~ I DAiLYMUDCOST Iq~_.j_ CUM. MUD COST q 3 Z7g , WEIGHT V/SC. [ PV [ ,~ ~ ~_.~ t . IA.P./.W.I HTHP I FILTER I _ I _, t CHLO- I Sand I SOLIDS I OIL ¢~, ¢~c.~ ¢c~* I ~I~'I ~ I ¢c~* Iw'~' Ic~ I~1'1~'~/ BIT ~ , JET SIZE DEPTH BI~' WT ROT ' CONDITION I HYDRAULICS LINER SIZE SPM GPM ' OFF eOTTOM nOT. WT. S.O. WT. P.U;WT. a.H.*. LENGT~ ~¢ ", , &H.A. WT. Conoco Inc. (7 FORMATION: ~ I~ I"-~ t~ WEATHER: Wind: ~.~ q KI'~ oo36 Daily Drilling Report(i' ALASKA DEPTH: Last 24 Hrs. "~'",.;q~°F v,s,,,,,,,; ~ ~, DAILY OPERA TIONS il 0 ~ MUDPROPERTIES: Type KC~/Si~.i*'-tO1DAILYMUDCOST iOB ~ CUM. MUDCOST WEIGHT t V/SC. I PV I ,,- I .... I .. i A.P.I. WLI HTHP I FILTER I _ I ¢-* 1¢~%41¢~, I ~I*~ I~' I¢co, lw.~. I c~ BIT . I ' - JET SIZE DEPTH : BI] HYDRAULICS LINER SIZ LENGTH SPM GPM WELL CONTROL P-LOWSATq~FT. , I PUMP(S qZ SPM ~PSI . PUMP(S) SPM PS Conoco Inc. (~, Daily Drilling RepoT{? FORMATION: 5AI'-'~C) DEPTH: q 5~! I---- ALASKA "/ RIG DA YS: ~ FOOTAGE Last 24 Hrs. WEATHER: From Visibility: % i"~ I DAILY OPERA TIONS ozoo o"750 18~o t~oo DE VIA TION Dep th Degrees DIRECTION MUD PROPERTIES: WEIGHT (PPG) Type HYDRA ULICS LINER SIZE GELS SERIAL NO. PUMPS WELL CONTROL CASING STROKE L ENG TH Depth BHA Degrees DIRECTION Depth Degrees DIRECTION CAKE I I I ~,OES l ~o I ~o < ~ !- 10 I/t~ r~ f ~ JET ,SIZE DEPTH 32ND IN OUT OIL % CONDITION T B G PRESSURE VELOCITY P-LO WS A T FT. PUMP(S) __ SPM __ PS/ PUMP(S) SPM GRADE OFF BOTTOM ROT. WT. P.U. WT,' B.H.A. LENGTH '~--.~0! B.H.A. WT. '/----~'...~}15', . O7.-5O Conoco Inc. FORMATION: ~t 1"-~ 0 Daily Drilling Report(' WEATHER: Wind: DEVIATION Dep th Degrees MUD PROPERTIES: WEIGHT I VISC. 'l (PPG) I (SEC.) [ HYDRAULICS co~~o,I' ~.~ows,~r ~:r. ~u~s~ s~ ~s~ ~ ~u~s~ WELL I ~ ~ T ALASKA FOOTAGE / Last 24 Hrs. 7 ~ ! OFF BOTTOM ROT. WT. S.O. WT. P.U. WT. B.H.A. LENGTH B.H.A. WT. DAIL Y COST ~5 l Z'g- ~ CUM. COST W'Ii ~ ~ .,,~ T~~. I~I j ~u~,v, so, U. Gx DAILY OPERA TIONS 0 Connection Gas Units DIRECTION Depth Degrees DIRECTION Depth Degrees ~ DIRECTION Type ~~~~ DAILY MUD COST ~ ~ CUM. MUD COST ~ ~ ~ ! I A.P. LW:I HTHP I FILTER J - I _. I CHLO- S~.d I S~LIDS OIL (CP) CP ~C7 ~88~ q/~ q~'l Ifil ~ ~ 3~17 G' , LENG TH SPM GPM PRESSURE VELOCITY G (~17 I ~ SPM ~ P5 TOL Conoco Inc. ( ..... Daily Drilling Report( ~-~ k~ Temp.: q S(~F DAILY OPERA TIONS WEATHER: Wind: N From 'gl15 ! ALASKA FOOTAGE / Last 24 Hrs. q '~ -re, C. so I I T<:,/--f 215 ,,. ~?i"~--/oO, G?t~-- / DEVIATION Depth Degrees MUD PROPERTIES: Type WEIGH T (PPG) HYDRAULICS PUMPS WELL CONTROL CASING q' BHA OFF BOTTOt ROT. WT. Background Gas DIRECTION Depth I Units I Trip Gas Degrees DIRECTION Units I Connection Gas Depth 1 Degrees DAILY MUD COST cu~. ~uo cos~3 7 '7_.5 7 Units DIRECTION FIL TEl:{ CAKE SERIAL NO. LINER SIZE P-LOWSAT i STROKE L ENG TH JET SIZE DEPTH 32ND IN OUT SOLIDS OIL % % CONDITION T B G [ PUMP JET Av DP¢c SPM GPM PRESSURE VELOCITY S.O. P.U. WT. B.H.A. LENGTH ~-~ B.H.A. WT. BOP Tested: ~ /1,3 Conoco Inc. FORMA T/ON: .~'~. ~ Daily Drilling Report DEPTH: ALASKA IRIG DA YS: IFOOTAGE Last 24 Hrs. WEATHER: Wind: Temp.: Visibility: DAILY OPERA TIONS DEVIATION Depth I Degrees /oyo MUD PROPERTIES: I Background Gas Units I' Trip Gas Units I Connection Gas DIRECTION Depth 't Degrees I DIRECTION Depth Degrees Type ~'?~,,~ IDAILY U CO ~~'~'CuM. MUDCOST ~ Units DIRECTION (PPG) I (SEC.) I (CP) Y" I ~'~ I p' I (cc) I W.L. I CAKE II~m I~' IR/DES I °×o~ ~ '/o ye I JET SIZE DEPTH B/TWT I ROT. ~ COND/TION BIT I':IZE I MI:G. TYPE I SERIALNO. 32ND liN OUT IFTG' HRS' t FT'/HR'I LENGTH PRESSURE VELOCITY ~C WELL CONTROL P-LOWS A T FT. ~ PUMP(S) SPM PSI ~ ~_ PUMP(S) ~ SPM P~ OF~ eO~OM ~OT. WT. ~ O~ S.O. W~. /~0 ~ P.U. W~. ~~ ~.H.A. LENGTH ~ e.H.A. WT.~~ I ~ I ' ~ ~/ . -- '/ / - CUM COST ~ RIG ~ Conoco Inc. ALASKA Daily Drilling Report ( DEPTH: .,~,_~ ¢~,~ Wind: Temp.: Visibility: WELL NAME: RIGDAYS:d/ FOOTAGE Last 24 Hrs. DAILY OPERA TIONS DEVIATION I Background Gas Units I' Trip Gas Depth I Degrees DIRECTION Depth Degrees DIRECTION 3115/ MUD PROPERTIES: Type I I- I I Units i Connection Gas I IDepth 1 Degrees ~.~_~ /,-/. ? . I A.P.I.W.. I HTHP I =ILTER I _ I -. i CHLO- Sa~ P~ I (CC) I W.L. I ;AKE I ~m t ~r RIDES % ~1!~. I~ I ~ ~, /~,31 ~ ~ JET SIZE DEPTH 32ND IN OUT FTG. HRS. i FT. IHR. I q~ i PUMP GPM PRESSURE WT Units DIRECTION sm d SOLIDS >,5-O OIL % COND/TION B G HYDRAULICS LINER SIZE LENG TH SPM VELOCITY .~ z~ 1.,2~ & ~ 117oo, WELL CONTROL P-LOWS A T FT. 'j PUMP(S) SPM PSI [ PUMP(S) SPM P~. STATE OF ALASKA ALASKA 01L AND GAS CONSERVAT I ON COMM ! SS I ON BOPE Inspection Report ft (general) ~ Well sign ~ousekeeptng ~)/<' R{g -'.MS: -- ;e qttor ~ctors CK: preventer · s u.~"L ams Test Pressure Ins valves~'~ ve - ~'/ /' ne valves~ ...... _ aive ACCUNULATOR $YSTEH= Full charge pressure ~000 _ ps~g Press after closure /~7 ps~g Pump tncr clos press 200 pstg mtn ~_~L.sec Full charge press attained ~ mtn ~ sec Controls= Heater_. Remote ' / Bltnd switch cover~ Upper Kelly Lower Kelly Ball type Inside BOP KELLY AND FLOOR SAFETY VALVES: ~ Test pressure ~' / Test pressure Choke man~ fold ~' / Number valvas Number flanges ~f- Adjustable chokes ............. Hydraulically operated choke Test pressure Test pressure Test pressure // LILTS -- Failures ~/~/~/~ _. Test ttme.__~.~hrs Repair or replacement of failed equipment to be made w~thin and Inspector/Commission office no:tf~ed. days trtbut~on: g - AOCCC Operator Supervisor ev 03/17/89) Inspector= Conoco Inc. FORMATION: WEATHER: Wind: From Daily Drilling Report( /~ALASKA (,~..,c'~,~,~.~ r"v,z;) FOOTAGE DEPTH: A 6 ~' Last 24 Hrs. DAILY OPERA TIONS DE VIA TION Background Gas Units Trip Gas Units Connection Gas Units DIRECTION Depth Degrees DIRECTION Depth Degrees I DIRECTION Depth Degrees MUD PROPER TIES: Type 4 /~,~ DAIL Y MUD COS Ti~'~O 41C TcuM. MUD COS T ~'~ ~ /~-" WEIGHTt VlSC. IPVI,,,, 'T ,,-_- ' ' _ I A.P./.WLI HTHP I FIL'TER I p_ I p. I CHLO- I sa,,d I sOLIDS 01[. BIT ' ' I ' JE~' ~ZE ' DEPTH F FT~/HR BIT WT ROT CONDITION SIZE MFG TYPE SERIAL NO 32ND IN OUT TG HRS (MLB'S' j RP~f T B G STROKE PUMP JET A DP~ HYDRAULICS I LINERSIZE LENGTH I SPM I GPM I PRESSURE I VELOCITY i V 'DC ~ PS BHA OFF BOTTOM ROT. WT. S.O. WT. P.U. WT. __ B.H.A. LENGTH B.H.A. WT. DA YS ON JARS NO. BOP Tested: Conoco Inc. WELL NAME: FORMATION: Daily Drilling RepoT( DA TE: DEPTH: RIG DA YS: FOOTAGE Last 24 Hrs. ALASKA WEATHER: Wind: Temp.: Visibility: From DAILY OPERA TIONS I Depth Degrees DIRECTION Depth Degrees MUD PROPERTIES: Type I DALLY MUD COST WEIGHT I VlSC. I PV t ..- I ...... ' I A.P.I. WL I HTHP (PPG) I (SEC') I (CP) I ~ ~' I ~ Ph I (CC) I W'L' BIT .... ' ' " JE~ SIZE DEPT'H' WELL CONTROL CASING P-LOWSAT FT. Gas Units I Connection Gas Units DIRECTION Depth Degrees DIRECTION CUM. MUD COST '-ILTER -' I -. I CHLO- Sand SOLIDS OIL ;.AKE ~'m t /"~ I RIDES I °/o I % % , I I I T' =T~_ I ,,% t =~,=o I ~l'W.. I F~OT. CONDITION PUMP(S) ~ SPM __ i SIZE I WT. IGRADE ISHOE FRAC. GRAD. PS/ ~ PUMP(S) ~ SPM ~ PS PPG A T FT. I TOL BHA OFF BOTTOM ROT. WT. S.O. WT. P.U. WT. B.H.A. LENGTH B.H.A. WT, DA YS ON JARS NO. BOP Tested: SERV. PERSONNEL DAILY COST I CUM. COST ISUPERVISOR Conoco Inc. Temp.: WELL NAME: ~.. ~ FORMATION: ~14~v~O.~ / WEATHER: Wind: ..~ Daily Drilling Report (' DEPTH: 0~0~ ~/ ~?w L~st 2~ .rs. ALASKA DAILY OPERA TIONS / Zo II/' DE VIA TION Background Gas Units Trip Gas Units Connection Gas Units Depth Degrees DIRECTION Depth Degrees DIRECTION Depth Degrees DIRECTION :~DHTRO:i~RTIES:pv Type E G t sc. I I __ I -~_.'_ I _ I A.P.I. WLI HTHP I FILTER I _ I _. I CHLO- Sand SOLIDS OIL (PPG) I (SEC') BIT ~ I ' ~ JET SIZE DEPTH ' - BI "WT RO~ coNDITION ' STROKE PUMP JET DP HYDRAULICS LINER SIZE LENGTH SPM GPM J PRESSURE VELOCITY A V ~C CASING o~ ~orro~ ~or. ~r. , / DAYS ON JARS NO. ~ BOP Tested: Conoco Inc. ALASKA WEU~AME: _(_~ :~ WEATHER: Wind: Daily Drilling Report DEPTH:,..~O Visibility: RIGDA¥S:.~ / FOOTAGE Last 24 Hrs. DAILY OPERA TIONS DE VIA TION Depth Degrees MUD PROPERTIES: w~l~,~ I risc. I (PPG) I (SEC.) I I Background Gas Units j Trip Gas Degrees DIRECTION DIRECTION Depth Type (CP) Y P 1.3 I~ ~fAz T~Z Units I Connection Gas Depth I Degrees · IA.P.I.W.I HTHP I I oc, I w.,. I JET SIZE 32ND CUM. MUD COST Pm Pf CHLO- FILTER I RIDES I CAKE 1 Units DIRECTION yo yo % 'Wi.'j RO'I~ J COND/T/(~N .BS.) RPM T B HYDRAULICS _ LINER SIZE WELL CONTROL PUMPS ~ P-LOWS A T SERIAL NO. I STROKE L ENG TH FT. SIZE j WT. SPM GPM PUMP PRESSURE JET VELOCITY __ PUMP(S) SPM __ PSI A V D%C __ PUMP(S) ~ SPM ~ PS JSHOE FRAC. GRAD. CASING GRADE PPG A T FT. BHA OFF BOTTOM ROT. WT. S.O. WT. P.U. WT. B.H.A. LENGTH TOL B.H.A. WT. DA YS ON JARS NO. BOP Tested: SERV PERSONNEL~ ~ ~ ~ DAILY COST ~ CUM COS~ J RIG ' Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 October 6, 1989 John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Please find enclosed the gyroscopic surveys on the Milne Point G-l, G-2, G- 3 and G-4 wells. No LIS tape or floppy disk format directional data is available for these wells. Sincerely, Michael R. Zotzky Senior Reservoir Engineer cc' well files (4) OF:III--L. ING ORIGINAL September 1, 1989 Mr. Steve Rossberg Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 Re: Our Boss Gyroscopic Survey Job No. AK-BO-90088 Well: G-i Milne Pt., Alaska Survey Date: 08/29/89 Operator: D. Harger Mr. Rossberg: Please find enclosed two copies of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunitY to be of service. Sincerely, Ken Broussard District Manager Directional Services 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company CONOCO INC. G-1 MILNE POINT ALASKA COMPUTATION DATE: 3PERRY-SUN DRILLING SERVICE(i' ANCHORAGE ALASKA 9/ 1/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 0 .00 -59.27 100 99.99 40.72 200 199.98 140.71 300 299.98 240.71 400 399.97 340.70 500 499.95 440 600 599.94 540 700 699.93 640 800 799.89 740 900 899.72 840 0 0 0 54 0 39 0 46 0 55 .68 0 46 .67 0 48 .66 0 58 .62 2 13 .45 4 7 1000 999.27 940.00 6 26 1100 1098.35 1039.08 8 58 1200 1196.65 1137.38 12 6 1300 1293.88 1234.61 14 53 1400 1389.52 1330.25 18 59 1500 1483.18 1600 1575.89 1700 1668.32 1800 1760.43 1900 1852.56 PAGE 1423 1516 1609 1701 1793 DATE OF SURVEY: 08/29/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90088 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2000 1944.77 1885 2100 2036.97 1977 2200 2129.14 2069 2300 2221.17 2161 2400 2313.20 2253 N .00 E .00 .00 .00 .00 S 60.10 E .90 .39S .68E .45 S 66.00 E .25 1.02S 1.89E 1.18 S 79.50 E .21 1.38S 3.08E 1.63 N 88.40 E .23 1.48S 4.55E 1.86 .91 21 59 .62 22 .05 22 50 .16 23 0 .29 22 45 N 78.00 E .21 1.31S 6.02E 1.82 N 78.70 E .02 1.03S 7.37E 1.66 S 40.20 E .91 1.54S 8.60E 2.28 S 12.00 E 1.45 4.09S 9.56E 4.90 S 11.00 E 1.89 9.52S 10.65E 10.40 S 6.20 E 2.37 18.63S 11.94E 19.59 S 6.80 E 2.53 31.97S 13.47E 33.00 S 6.50 E 3.12 50.13S 15.58E 51.29 S 6.90 E 2.79 73.31S 18.31E 74.61 S 7.40 E 4.10 102.21S 21.95E 103.72 .5O .70 .87 .90 .93 22 46 22 46 22 '52 23 12 22 50 S 7.70 E 3.00 136.91S 26.56E 138.68 S 7.60 E .05 174.05S 31.54E 176.11 S 6.60 E .90 211.92S 36.26E 214.25 S 6.20 E .22 250.62S 40.60E 253.18 S 5.70 E .32 289.28S 44.63E 292.04 2500 2405.26 2345.99 23 7 2600 2497.32 2438.05 22 50 2700 2589.76 2530.49 22 0 2800 2682.82 2623.55 20 54 2900 2776.90 2717.63 18 40 3000 2871.89 2812.62 17 45 3100 2967.40 2908.13 16 41 3200 3063.37 3004.10 15 56 3300 3159.67 3100.40 15 19 3400 3256.16 3196.89 15 8 6.10 E .16 327.77S 48.60E 330.73 5.50 E .23 366.29S 52.52E 369.44 5.90 E .19 404.89S 56.37E 408.23 5.90 E .32 443.82S 60.39E 447.36 5.80 E .36 482.72S 64.38E 486.46 6.20 E .33 521.55S 68.46E 5'25.50 5.70 E .35 560.39S 72.51E 564.54 5.50 E .83 598.35S 76.23E 602.68 4.70 E 1.14 634.79S 79.49E 639.27 3.40 E 2.28 668.55S 81.90E 673.11 S 3.90 E .93 699.74S 83.89E 704.35 S 3.80 E 1.06 729,27S 85.88E 733.95. S 3.70 E .75 757.31S 87.72E 762.04 S 4.30 E .64 784.18S 89.59E 788.97 S 3.40 E .30 810.39S 91.36E 815.24 OCT 0 Oil & Gas Cons. Gommissio~ SPERRY-SUN DRILLING SERVIC~s ANCHORAGE ALASKA PAGE 2 CONOCO INC. G-1 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90088 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3500 3352.82 3293.55 14 34 S 2.90 E .58 3600 3449.68 3390.41 14 11 S 2.70 E .38 3700 3546.80 3487.53 13 21 S 2.70 E .83 3800 3644.21 3584.94 12 46 S .80 E .73 3900 3741.80 3682.53 12 26 S .70 E .32 835.99S 92.77E 840.86 860.79S 93.98E 865.68 884.58S 95.10E 889.47 907.17S 95.80E 912.04 929.00S 96.09E 933.82 4000 3839.57 3780.30 11 49 S .10 W .65 4040 3878.72 3819.45 11 49 S .00 E .05 4100 3937.43 3878.16 11 53 S .30 W .15 4200 4035.26 3975.99 12 2 S 1.50 W .29 4300 4133.08 4073.81 11 54 S 1.90 W .15 950.02S 96.20E 954.77 958.22S 96.19E 962.93 970.55S 96.16E 975.22 991.29S 95.83E 995.86 1012.03S 95.22E 1016.47 4400 4230.93 4171.66 11 55 S 2.30 W .08 1032.67S 94.46E 1036.97 460 26.24 4366.97 13 12 S 2 80 W .95 1075]62S 92 1079.59 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1079.59 FEET AT SOUTH 4 DEG. 54 MIN. EAST AT MD = 4600 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 175.09 DEG. SPERRY-SUN DRILLING SERVIC~o ANCHORAGE ALASKA PAGE 3 CONOCO INC. G-1 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 JOB NUMBER: AK-BO-90088 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -59.27 1000 999.27 940.00 2000 1944.77 1885.50 3000 2871.89 2812.62 4000 3839.57 3780.30 .00 .00 .00 18.63 S 11.94 E .73 .73 327.77 S 48.60 E 55.23 54.50 699.74 S 83.89 E 128.11 72.88 950.02 S 96.20 E 160.43 32.32 4600 4426.24 4366.97 1075.62 S 92.49 E 173.76 13.32 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVIC~ ANCHORAGE ALASKA PAGE CONOCO INC. G-1 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 JOB NUMBER: AK-BO-90088 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH 0 .00 59 59.27 159 159.27 259 259.27 359 359.27 SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE -59.27 .00 .00 .00 · 00 .08 S .13 E .00 100.00 .83 S 1.46 E .01 200.00 1.27 S 2.54 E .02 300.00 1.49 S 3.90 E .03 VERTICAL CORRECTION .00 .01 .01 .01 459 459.27 559 559.27 659 659.27 759 759.27 859 859.27 400~00 1.43 S 5.48 E .04 .01 500.00 1.15 S 6.82 E .05 .01 600.00 1.02 S 8.16 E .06 .01 700.00 2.56 S 9.23 E .08 .02 800.00 6.67 S 10.09 E .18 .09 959 959.27 1060 1059.27 1161 1159.27 1264 1259.27 1368 1359.27 900.00 14.14 S 11.45 E .47 1000.00 25.84 S 12.74 E 1.17 1100.00 42.59 S 14.71 E 2.59 1200.00 64.51 S 17.25 E 5.01 1300.00 92.30 S 20.68 E 8.88 .30 .70 1.42 2.42 3.87 1474 1459.27 1582 1559.27 1690 1659.27 1798 1759.27 1907 1859.27 1400.00 127.55 S 25.30 E 15.02 1500.00 167.38 S 30.65 E 22.80 1600.00 208.13 S 35.82 E 30.91 1700.00 250.13 S 40.54 E 39.47 1800.00 292.08 S 44.91 E 48.01 6.15 7.78 8.11 8.57 8.53 2015 1959.27 2124 2059.27 2232 2159.27 2341 2259.27 2449 2359.27 1900.00 333.83 S 49.25 E 56.46 2000.00 375.60 S 53.41 .E 64.91 2100,00 417.53 S 57.68 E 73.43 2200.00 460.05 S 62.07 E 82.18 2300.00 502.05 S 66.36 E 90.73 8.45 8.46 8.52 8.75 8.54 · 2558 2459.27 2667 2559.27 2774 2659.27 2881 2759.27 2986 2859.27 2400.00 544.44 S 70.92 E 99.44 8.71 2500.00 586.09 S 75.05 E 107.84 8.41 2600.00 625.82 S 78.75 E 115.52 7.67 2700.00 662.61 S 81.55 E 122.12 6.61 2800.00 695.71 S 83.61 E 127.48 5.36 3091 2959.27 3195 3059.27 3299 3159.27 3403 3259.27 3506 3359.27 2900.00 726.84 S 85.72 E 132.24 4.76 3000.00 756.14 S 87.64 E 136.46 4.22 3100.00 784.07 S 89.58 E 140.31 3.85 3200.00 811.23 S 91.41 E 143.95 3.64 3300.00 837.66 S 92.85 E 147.40 3.45 ANCHORAGE ALASKA PAGE 5 CONOCO INC. G-1 MILNE POINT ALASKA COMPUTATION DATE: 9/ 1/89 DATE OF SURVEY: 08/29/89 JOB NUMBER: AK-BO-90088 KELLY BUSHING ELEV. = 59.27 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3609 3459.27 3400.00 3712 3559.27 3500.00 3815 3659.27 3600.00 3917 3759.27 3700.00 4020 3859.27 3800.00 863.22 S 94.10 E 150.62 3.22 887.54 S 95.24 E 153.54 2.92 910.58 S 95.85 E 156.17 2.63 932.86 S 96.13 E 158.62 2.45 954.14 S 96.19 E 160.86 2.24 4122 3959.27 3900.00 4224 4059.27 4000.00 4326 4159.27 4100.00 4428 4259.27 4200.00 4531 4359.27 4300.00 975.15 S 96.14 E 163.04 2.18 996.41 S 95.70 E 165.28 2.23 1017.55 S 95.04 E 167.49 2.21 1038.65 S 94.22 E 169.70 2.21 1060.24 S 93.24 E 172.01 2.31 4600 4426.24 4366.97 1075.62 S 92.49 E 173.76 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS 1.75 t_ ~'SPERR~,Y-$UN DRLG.f SVCS. HORIZONTAL PROJECTION G-1 HILNE POINT ALASKA 08/29/89 START TVD = 0 FINISH TVD -- 4426.24 SCALE IS 500 FEET/IN SO0 1000 1500 2000 2500 3000 DEPARTURE 500 1000 1500 2000 2500 3000 I , I I I I I ~'. SPERR~Y-SUN VERTICAL 6-1 NILNE POINT ALASKA 08/29/89 DRLG. ( PROJECTION SVCS. START TVD = 0 FINISH TVD = 4426.24 SCALE IS 1000 FEET/IN 1000 2000 8000 4000 5000 0000 7000 - 59 1oho 2oho 8obo 4oho DIRECTION = 0.00 soho eobo Gamma Log CLIENT: CONOCO, INC. WELL: G-1 FIELD: MILNE POINT DATE: SEPTEMBER PTS J.O. ~70068 1989 o 4350. 4400. 4450. 4500. 4550. 4600. Gamma Log CLIENT: CONOCO, INC. WELL: G- 1 FIELD: MILNE POINT DATE: SEPTEMBER 1989 PTS J.O. ¢70068 ~,,,-.-. · _ , ,., z, · __. , , __ ..... . --7-2 ......... ~ ..... ~.. , ~_~ , _ 41 00. 4150. 4200. 4250. 4300. 4350. Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 October 24, 1989 Mr. John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Boyle: Please find enclosed the routine analysis and gamma ray of the G-1 conventional core, analysis of G-1 sidewall cores, and analysis of G-4 sidewall cores. No conventional or sidewall cores were taken in the G-2 and G-3 wells. This data should be held CONFIDENTIAL. Sincerely, Michael R. Zotzky Senior Reservoir Engineer cc: G-1 Well File G-2 Well File STATE OF ALASKA (" ~,SKA OIL AND GAS CONSERVATION CO~" ;SION 0 I~ APPI'i TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ - Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing .;__ Variance __ Perforate ~ Other 2. Name of Operator 5. Type of Well: CONOCO TNC Development__ Exploratory ~ 3. Address 99503 Stratigraphic __ 3201 C Street, Suite 200, Anchorage~ AK Sewice__ 4. Location of well at surface 3644' FNL 3364; FEL Sec. At top of productive interval 4620; FNL, 3300' FEL Sec. At effective depth At total depth 4779' FNL, 3293; FF.T, Sec. 27, 12. Present well condition summary Total depth: measured 4770 ' * (Revisions) truevertica14605,,, (evaluation well) 27, T 13N, ~-10E, UM 27, T 13N, R 10E, UM T 13N~ R feet feet 10E~ UM Plugs(measured) N/A 6. Datum elevation (DF or KB) KB 28 7. Unit or Property name Milne PQ%nt Unit 8. Well number G-1 feet 9. Permit number 89-29 10. APl number 50-- 029-21927 11. Field/Pool Upper Cretaceous-We~t Sac Effective depth: measured N/A true vertical feet feet Junk(measured) N/A Casing Length Structural Conductor Surface 2 5 41 ', Intermediate Production 4 7 4 2 ' Liner Perforation depth: measured Not per f orat e(~rue vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) Size Cemen~d Measureddepth ~ueverticalde~h 13-3/8" 108' 108' 9-5/8" 2569' 2500' N/A 7" 4770' 4605' RECEIVED OCl 1 9 lg 9 Alaska 0il & Gas Cons. C0mmiss]0m Anchorage 13. Attachments Description summary of proposal __~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 10/16/89 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil × Gas Suspended ~ Service 17. I hereby c~rti~at the~regoing is true and correct to the best of my knowledge. Signed/z/~(,~. L~~// Title Senior Foreman FOR COMMISSION USE ONLY Date 10/13/89 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test ~ Subsequentform required 1-~'- ~ Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner J Approval No. Approved Copy . Returned Date Form 10-403 Rev 06115/88 SUBMIT IN TRIPLICATE COMPLETION PROCEDURE MPU Well G-I Milne Point Unit Surface Location: 3,420' FEL, 4,060' FNL, Sec. 27, T13N, R]OE, UM Depths: All depths are measured from KB datum. Casing: Surface- 9 5/8', 36#/ft, K-55, btrs., set at 2,525'. Production- 7" 26#/ft L-80 btrs Capacity: bbl/lO0' Burst Pressure: 7,240 psig Tubing: 2-7/8", 6.5#/ft, EUE, L-80, @ Capacity: 0.579 bbl/lO0' Capacity of tubing/casing annulus: 3.02 bbl/lO0' Burst Pressure: 10,160 psig (no safety factor) Objective: Complete well G-1 in the SOS. Conduct a flow test and pressure buildup survey. >~/~. o,l/ ~~ Recommended Procedure: 1) 2) Hold a meeting at Milne Point with all contractors involved with the completion prior to the job. The objective of the meeting should be to discuss procedural aspects of the completion and safety. Rig up electric line company to run gauge ring, gyro survey and a GR/CCL. Correlate GR/CCL with the MWD logs run while drilling. The hole will contain 9.2 ppg KCL brine which was used as a displacement fluid on the primary cement job. Rig down the electric line company. Hold a safety meeting with perforating company on location prior to rigging up the guns. Make up perforating/completion assembly from bottom up as fol 1 ows: (See Figure 1) NOTE: Measure O. D., I. D. and length of all tools to be run in the hole. Insure that all tools are free from obstructions. Measure and record distance from top shot on gun assembly to R. A. marker. Distribution' TRP, JDC, PMS(2), MPU Senior Foreman .Completion Proce(' ,. MPU Well G-I May 18, 1989 Page 2 ITEM DESCRIPTION I.D. O.D. LENGTH DEPTH Vann lime Delayed Firing Hd. N/A Bottom Shot of Guns 4 5/8" 12 SPF W/25 gm. DP CH. N/A Top Shot of Guns Mod. 2 Extended Mech.2 Firing Head N/A 3.37" 8.00' 6 2-3/8" 8rd Tubing Joint 1.99" 2.38" 30.00' 7 3-1/2" 8rd. B X 2-3/8" P Xover 1.99" 4.05" 1.35' 8 3-1/2" 8rd. Isolation Tool 3.00" 4.25" 2.41' 9 3-1/2" 8rd. Tubing Sub 2.99" 4.50" 10.00' 10 Pressure Activated Release 1.81" 4.10" 1.70' 11 3-1/2" 8rd. Tubing Sub 2.99" 4.50" 10.00' 12 3-1/2" IF B X 3-1/2" 8RD P Xo 2.44" 3.48" 1.35' 13 3-1/2" IF Shock Absorber Sub 2.25" 5.03" 5.00' 14 2-7/8" B X 3-1/2"IF P X-over 2.50" 4.75" 0.85' 15 7"X 26# Champ 3 Pkr. 2.37" 5,75" 3.56' 16 3-1/2"IF B X 2-7/8" 8RD B Xo 2.44" 4.50" 1.50' 17 Safety Joint 2.25" 5.00" 10.00' 18 Hydraulic Jars 2.25" 5.00" 10.00' lg Drill Collars as Needed 20 Full Flow Bundle Carrier 2.18" 5.37" 7.97' 21 APR OMNI Circulating Valve 2.25" 5.03" 20.85' 22 2-7/8"8rd,B X 3-1/2"IF B X-O 2.44' 4.75" 1.50' 23 2-7/8" 8RD L-80 JOINT 2.44" 3.67" 30.00' 24 2-7/8" 8rd N-80 VANN R/A Sub 2.44" 3.67" 6.00' 25 2-7/8" 8rd N-80 To Surface 2.44" 3.67" 3.38" 4.63" 2.50' 6) Strap in the hole with perforation/completion assembly on 2-7/8" tubing. OMNI tool is run with the ball andcirculating valves closed {Position 15- 1/2). Fill the first 3,000'of string with diesel while tripping in the hole, which will provide approximately ],000 psig underbalance for perforating. Hang packer at ......'(Based on measured depths). 7) Rig up electric line company and run GR/CCL. Correlate with the GR/CCL previously run. Use the radioactive locator sUb to position guns at top shot depth. If guns are off depth, mark off feet of tubing on surface required to place top perforation shot on correct depth. Position guns on depth and rerun GR/CCL to confirm gun position. Repeat if necessary. 8) Set packer by applying 1/4 turn to the right and setting approximately 20,000 lbs. on packer. 9) Nipple down BOPs. Nipple up wellhead and flow lines to the temporary test facility. Pressure test surface lines to 5,000 psig. Proce~ ~MPU Well G-1 May 18, 1989 Page 3 10) Pressure up annulus to '~'pp'roximately 1,500 psig to cycle OMNI valve to position 2-1/2, which will open the ball valve and leave the circulating valve closed. This will also serve as a packer test. 11) Rig up 20'lubricator and shot detection equipment. dropping roller bar. Detonate guns by 12) Flow test the well and perform a pressure buildup as follows: NOTE: The objectives of the flow test and pressure buildup test are to obtain data for preliminary ESP sizing, assess potential sand production problems and to determine skin effects. Therefore, it is very important that accurate data be collected and that any evidence of sand production be noted and immediately reported to engineering. If positive skin exists, engineering will recommend an acid procedure prior to pump testing. a) Bring the well on slowly with choke set at 6/64. Allow well to cleanup gradually byopening choke 2/64 every two hours to a maximum choke setting of 32/64. Closely monitor the separator for evidence of sand production. Obtain a stabilized 48 hour flow period with the choke set at 32/64. Report stabilized fluid rates, cuts and GOR to the Anchorage office. b) Rig up wireline, lubricator and pressure recorder with surface readout. RIH with pressure gages making 15 minute gradient stops at 1,000' intervals. Set gage at ..... ' and obtain a flowing pressure survey. If it is necessary to shut-in the well to run gauge, make the shut-in period as short as possible. Once the gauge is on bottom the previous rate should be re-established and main- tained until the flowing bottom-hole pressure stabilizes. Rates for the initial flow period should be the same as the stabilized 48 hour test rate. After the flowing bottom-hole pressure stabilizes, begin opening the choke in increments of 4/64 to a maximum of 64/64. Allow the well to flow at each choke setting long enough for the rate and flowing bottom-hole pressure to stabilize. At each choke setting record the following data: 1) Stabilized flow rates converted to barrel per day equivalent (i.e. bbl./hour * 24 hours/day). 2) Fluid cuts (i.e. oil, water and gas). It is very important to note any evidence of sand production. 3) Stabilized flowing bottom-hole pressure at each choke setting. 4) Flowing surface tubing pressure and separator pressure at each choke setting. 5) Flowing wellhead temperature and separator temperature at each choke setting. Completion Procei~ ~. MPU Well G-1 'May 18, !989 ~ Page 4 c) Flow well at the 64/64 choke setting for a minimum of 48 hours or until the flow rate and botom-hole pressure stabilize. Record the data outlined in steps bl-b5 every six hours. During the open flow period the separator should be continuosly monitored for evidence of sand production. After the flow rate and bottom-hole flowing pressure stabilize at the 64/64 choke setting, shut-in the well at the surface making sure there are no leaks. Obtain a pressure buildup test and report pressure data to the Anchorage office. Engineering will terminate test when sufficient data has been collected. POOH with gauge making 15 minute gradient stops at ],000' intervals. ]3) Cycle OMNI tool to position ]1-]/2 to open circulation valve. Reverse circulate -- bbl. of clean (filtered to 5 microns) 9.2 ppg KCL brine to ktll well. 14) Nipple down tree and nipple up BOPs. Release packer and POOH. ]5) An E.S.P. design and pump test procedure will be provided by engineering based on the initial flow test and pressure buildup data. Prepared By: R. S. Rossberq Production Engineer Approved By: Supervising Prod. Eng. Field Superintendent t CI I~! I I_1_1 I~ G S I::: I~ U I r' I::: S TO: Mr. John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DATE: TRANS.#: August 29, 1989 89-0815AK REFERENCE: CONOCO Milne Point G-1 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad. ENCLOSED INFORMATION SUMMARY Well G-1 MD: 1 Each Blueline; Total 3 I Each Sepia; Total 3 1 Each Blueline; Total 1 1 Each Sepia; Total 1 Digital: ~ -c Tape LIS Tape Verification Listing O- 0-p_Ss O- Received By: A.O.G.C.C. / Date 8537 Corbin Drive (99507) · P.O. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company SCHLUMBERGER WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 COMPANY ATTENTION COMPUTING CENTER PRINT CENTER WELL NAME · J'ii~Li'~~ 201i,iT dt",!iT ~J;-'l SERVICES · I 01'4 LIS TA?,< i LSS/'~i? FiEL[:) TAPE COPY NO. OF BOXES' 0 t',! E JOB NO. · 7., 4 4 2 ADD'LTAPES · '~'S£~ A~OV~ , WELL NAME · SERVICES · WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES ' WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES: JOB NO. ' ADD'L TAPES · 'CHLUMBERGER COURIER:~ DATE DELIVERED: WELL NAME · SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · RECEIVED BY: Conoco, Inc. SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON, TEXAS 77251-2175 PLEASE REPLY TO AUG I 5 ~ SCHLUMBERGER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Rick Wheeler Gentlemen: Enclosed ore 3 BLprints of the Raw Data/SHDT/Cyberlook, Run 1, 8/20/89 Company Conoco, Inc, Well Milne P°int Unit G-1 DLL/LSS (Delta Time)/LSS (Waveforms)/Porosity/ .on; Field Milne Point Additional prints ore being sent to: 1 BL prints Conoco, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attn: Marc Shannon 1BL prints, 1RF Sepia Conoco, Inc. 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints Conoco, Inc. 600 North Dairy Ashford HOuston, TX 77079 Attn: George Lamb, OF 2018 PER .County North Slope State Alaska _l_BL__prints, 1RF Sepia Chevron, U.S,A. P. O. Box 5043 San Ramon, CA 94583-0943 Attn: ?rJ~c~]la Mmcleroy  1RF Sep~ Gas Conservatio% // Conm,ission ' ~ ( 300! Porcupine Drive / .. \ Anchorage, AK 99501 _/ x Attn: John Boyle __~_~/ ~prints 1 BL nrints, 1 RF Sepia OXY, O.S.A. P. O. Box 12011 Bakersfield, CA 93389-2011 Attn: Jim Conners prints PLEASE SIGN AND RETURN ONE COPY OF THIS TRANSMITTAL. TMANK YOU~ The film is returned to Conoco, Anchorage. We appreciate the privilege of serving you. Received by: Very truly yours, SCHLUMBER( !LL ~.~::~ i~ ~- David M. Saalwaechter DISTRICT MANAGER .~W$-- 1327-F MEMORANDUM State ,of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C. Smi DATE: August 17, 1989 Commissioner / FILE NO: D. ADA. 0 6 7 THRU: FROM: TELEPHONE NO: Michael T. Minder '. · SUBJECT: Sr. Petroleum Engineer Doug Arno s:~,~.--',,; ......... Petroleum Inspector BOP Test Conoco MPU G-1 Permit No. 89-29 .Mi-l~-~t. Field Sunday, August 13, 1989,_ I traveled this date from AAI KRU to c0n0c0's ~U G'I Well to stand by for the BOP test. This test commenced at 8;15 am and was concluded at 11:15 am. There were no failures and I filled out an AOGCC BOP Inspection report which is attached. While witnessing the BOP test, I inspected the choke and kill lines for threaded connections. I found threaded connections on the kill line at the stack flange and downstream of the swivel ell at the stack. I informed Steve Brady, Conoco Rep. of these problem areas and all areas were welded. In summary, I witnessed the successful BOP test at Conoco's MPU G-1 well on Parker Rig No. 141 and inspected the choke and kill lines for .L."I ....... 'II '~ .., ~--~ ..... Attachment 02-001A (Rev. 8!85) . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report Operator Well Location: Sec Drlg contrctr Location (general) General housekeeping Reserve pit MUD SYSTEMS: Visual Trip tank 0/~ Pit gauge ~/~ Flow monitor C)/<' Gas detector, ~0~/~ Audio BOPE STACK: Annular preventer Pipe rams'~L~ Blind rams ~ Test Pressure Choke 1 i ne valves HCR valve Kill line valves Check valve It Rig # DATE Representative Permit # ~_~ :~//~ t! Casing //~/ Rep ACCUMULATOR SYSTEM: ft Full charge pressure ~ (~)C:)~:) psig Press after closure /~OO psig Pump incr clos press 200 psig min ~Z~ sec Full charge press attained ~ ...... min ~ sec N2 ~ ~/~OC)1 ~0 psig ~ Control s: Master ~ Remote ' ~ Blind switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly ~f~ / Lower Kelly ~-~ [, Ball type u~' / Inside BOP ~l~/ Choke manifold ~ ! Number valves Number flanges Adjustable chokes Hydraulically operated choke Test pressure Test pressure Test pressure Test pressure Test pressure TEST RESULTS: Fai lures /~J. ~/~/~ Test time ~.~ hfs Repair or replacement of failed equipment to be made within and inspector/Commission office notified. __ days Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) Inspector: Hay 5, 1989 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay~ AK 99734 (907) 659-6300 Mr. D. Johnston Alaska Oil an Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE' Milne Point Unit; Wells G-l, G-2, G-3, and G-4 Dear Mr. Johnston' With reference to Bob Soptei's conversation with Mr. Bob Crandell on May 5, 1989 and the AOGCC mud logging and sampling requirements returned with the approved subject permits dated March 21 and April 21, please be advised that Conoco agrees to mud log Well G-1 and take mud samples on Wells G-1/2/3/4. No mud logs are planned on Wells G-2/3/4. Conoco regrets any confusion that may have occurred when we informed you we were planning to mud log all the subject wells. If you should have any questions please call Bob Soptei or Hal Stevens at (907) 659-6327. Yours very truly, D. F. Rainwater/E. L. Robinson Seni or Producti on Foreman RJS cc Field Superintendent, Anchorage Safety & Compliance Coordinator Senior Production Specialist RECEIVED ~AY . ,.;, Tom Painter Division Manager co.=,.=. ORIGIiV; ! 3201 C Street Suite 200 Anchorage, AK 99503 April 12, 1989 Mr. C. V. Chatterton Chairman of the Commission Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- RE' PERMITS; MILNE POINT UNIT; WELLS G-l, G-2, G-3 AND G-4 Enclosed you will find Applications for Sundry Approvals for Milne Point Unit Wells G-1 and G-2 (original drilling permits approved by your office on March 6, 1989) and Permit to Drill Applications for Wells G-3 and G-4. A check for $200 is included for the Drilling Applications. If you should have any questions, please contact Bob Soptei or Hal Stevens at 659-6327. RJS/jah File 500.21.04 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ' ' Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension Change approved program X Plugging .~ Stimulate ~_} Pull tubing . Amend order .r' Perforate [; Other 2. Name of Operator Conoco Thc. 3. Address 3201 C Street, Suite 200, Anchorage, AK 99503 4. Location of well at surface Revised Locations 3644' FNL, 3346' FEL Sec. 27, T 13N, R 10E, UM At top of productive interval 4620' FNL, 3300' FEL Sec. 27, T 13N, R 10E, UM At effective depth N/A At total depth 4779' FNL, 3293' FEL Sec. 27, T 13N, R 10E, UM 5. Datum elevation (DF or KB) KB 28 6. Unit or Property name Milne Point Unit 7. Well number G-1 8. Permit number 89-29 9. APl number 50-- 029-21927 10. Pool feet Upper Cretaceous-West Sac 11. Present well condition summary Total depth: measured ([evlslons) true vertical 4770'* feet 4605'* feet Effective depth: measured N/A feet true vertical feet Casing (Revisions) Length Size Structural Conductor 13-3/8" Surface 2541 ' 9'5/8" Intermediate Production 4742 ' 7" Liner Perforation depth: measured To be determined after logging. true vertical Tubing (size, grade and measured depth) To be determined at a later date, Packers and SSSV (type and measured depth) Plugs (measured) N/A Junk (measured) N/A Cemented Measured depth True Vertical depth No Change 108' 2569'~ 108' 2500' 4770' 4605' RECEIVED APR 1 Alaska.Oil A Gas Cons, C0mmissi0r~ · ~'~ ~ ~ . ' 12.Attachments Description summary of proposal © Detailed operations program Ri BOP sketch 13. Estimated date for commencing operation August 1989 14. If proposal was verbally approved Name of approver ~-' N/_A..A Date approved Signed15' I hereby~~,/~.g~.~cert' at t foreg in is true and correctTitle to theDivisionbest of mYManagerknOwledge Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test ~ Location clearance~ Approved by ORIGINAL SIGNED BY LONN1E C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Returned Commissioner by order of .,.~_.,/~ ~ the commission Date " '~ Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR SUNDRY APPROVALS CONOCO MILNE POINT UNIT G-1 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 I · Casing and Cementing Program A® The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±486 sacks of Permafrost "E" cement followed by ±404 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The primary cementing job will consist of ±129 sacks of Permafrost "E" and ±256 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of ±409 saCks of Permafrost Type "C" cement followed by ±60 barrels of Arctic Pack, pumped down the 7" x 9-5/8"annulus. II. Drilling Fluid Program A· Be Ce 0-3605' 9.0 ppg freshwater spud mud. 3605'-3825' 9.2 ppg KC1 mud. 3825'-4770' 9.4 ppg KCl mud. III. Drilling Program REC:EiVED APR 1 ,Oil & Gas Cons'. Commissio~ ~ ~ ~chorage Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River field (Upper Cretaceous-West Sac). The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.4 ppg. A low solids KCl mud will be used in the production hole. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. BOP's, choke manifold, Upper and Lower Kelly will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The well will be flow tested after the rig is released. Arctic Pack will be placed in the 7" x 9-5/8" annulus after disposing of test oil and excess drilling fluids. ao Drill a 30" conductor hole to ±80' and set 13'3/8" conductor. Be Drill a 12-1/4" surface hole to +2500' TVD (2569' MD) and set 9-5/8" casing. Co Drill a 8-1/2" production hole to 4770' MD and set 7" casing. TVD MD FORMATION BIT 0' 0' 2500' 2569' 3605' 3646' 3825' 3870' 4085' 4133' 4255' 4306' 4605' 4770' MUD WT YP PV VIS FL Gravel 1-1-4 9.0 32 20 90 15 Sand/Clay 1-1-4 9.0 25 20 65 15 "K" Sand 1-1-4 9.2 8 12 35 6 "M" Sand 1-1-4 9.4 8 12 35 6 "N" Sand 1-1-4 9.4 8 12 35 6 "O" Sand 1-1-4 9.4 8 12 35 6 TD 1-1-4 9.4 8 12 35 6 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. CONOCO, !no. , i Pad G, Nel I N° 1 Revlieed Pr'opoieal · ' MI Ine Point Un!l~, Not,hi Slope, ~laeka ':I KO, .v~,eoo .~ ~E"-O ~ : [ 3 BUILD 3 ~e ~ 1000 · ~R ~ FT ~ ~ ! : ~ - ~ ~s'EOB TVD-1158 THD"i166 DEp"83~ .... ~ ~ g ~8- cso Pr~ rVD"~SO0t r~-,seg e~P-4g3. ~ ~ H SNDS TVD"3825 T~"3955 DER"898 ~ 4000 ~ ~ ' ~ . ' ' . ~ ' ~ _ TARGET / N 'SNDS TVD ~5-T~~ 4~'"D~gTT ~000 .. o ;~ ooo 2000 VERT]:OALI SECTXON 0 SNDS i TVD-4255 !TIID-4404 I~P.,1029 ~ ' TD / ?" CSG PT iTVD-4605 :~11D-4770 DEP-I136 PERH! TTED DEPTH TVD-4goc TI'ID-50?g DEP-1226 ~JRF~ ,.~,44' FILL, 3346' FEL ~EC. 27. T131t. RIOE PERH[TTED DEPTH LOCAT[OI4~ FILL. 3288' FEL 1000 O i 1 000 _ 2000 _ ~000 . HOR I ZiON T AL PROJECT ! O.N SCALE 1 IN. - 1000 FEET CO#OeO. I n o · ~ Ped O; Well i~:~ 1. R, ~..d Pro, t!lne Point It No~'[ Slope, ~ ~EST~EAST ~ 2000 ~ooo 0 ~ i i i i . Aleebe S 2 DEO 977' ; (TI::] iO00 42-'~]:N T AROET ) ~000 TARO~T / N 8ND8 TVI)-4OOS i'11Dm4227 DE'P-GI~ 80UTH G?5 EAST 46 TARGET LOCATION' 4~0' FgL. 3300' FEL ~EC. 27. TI3N. RIOE TD: LOOATIOI4 ~ 47'7'0' FNL. 3~3' FEI. SEC. ~'7'. T13N. RIOE ~350 _ 3400 _ ~;450 _ ~500 _ ;55O _ ;600 _ ;650 _ 700 _ 750 _ 3500 I 3450 I I "' i I '1 3500 3450 3400 I 3400 I 1 200 1100 1000 900 800 600 3350 I 3300 / 1100 /°~ 000 //900 .-~'oaoO o 3250 3200 300 200 ! 600 800 19oo I ~ 1 000 _ 335 ~_.~J 340 _ 345 _ 350 355~ _ 370~ _ 375~ I 1 200 3350 3300 3250 3200~ · { 1100 I I ~ 3601 I - I ~°"1 ;3.00 t~xx~L " 365~ ! w/ I I NOTES: 1. ,STATE PL,4u'~ COORDINATES ARE ZONE 4 N.A.D. 1927 Z t < BAS~ ON PRO~ACT~ VALES OF ~ S~T~N COR~ POST~L ~ MILNE PT. VICINITY MAP ~ O ' i~~ --[--1- LOCATION IN : ~ ~b SEC. 27, T13N, R1OE, UMIAT MERIDIAN : ~' ~ W~L FROM NOR~ L~ ~OM ~8T L~ ,- ~ ~'~- 7 G-1 3644' 3346' ~ : ~ G-4 ~ ~ ~ ~ ~ G-2 3~8~' 33~4' = . ~ ~ G-3 382~' 3362'  ' " G-2 ," ,.~.t 7G-1 I ~:~ STATE PLANE COORDINATES-ZO~ 4 , b '~ I ~L ~R~ ~8T ' ~ ~ I ~ , : G- 1 6,014, O71.302 557,260.513 :' JL G-2 6,O14,130.704 557,252.065 G-3 6,O14,190.106 557,2~.616  , ' G-4 6,O14,249.509 557,235.167 _~O'_~_ , 80' ~_ ~eO' . ~ ~' GEODETICAL ~POSlTIONSLA~ NAD~sT1927 L~ G-1 70' 26'~6.6828' 149' 3r~8.2867 ~~ ~?/~:.:f.::~::~?.::~::~:/~?.:::::~:;~?.:::::~:~:f.~l g G-2 70' 26'~7.2677 149' 31'~8.~214 G-3 70- 26'~7.8~26 149- 31'58.7~61 G-4 70- 26'~8.4374 149- 3r~8.9908  TYPICAL ,SECTION NO 8C~E ' I II II I " ~~A~ ~. ~~~ , TO ~L o~ ~ o~ ~S ~ C~T. ~--~--~-~,~ cc o ~ ~ ~ ~ F~D BOOK ~ ~ ~ SCALE 1"=2~' JOB ~. 890~ I ~.~l~ ~ ' ' '~' March 21, 1989 Telecopy= (907)276=7542 T. R. Painter Division Manager Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Milne Point Unit No. G-1 COnoco Inc, Permit No. 89-29 Sur. Loc. 3420'FEL,i060'F~, Sec. 27, T13N, Btmhole Loc. 3281'FEL,iT08'FNL, Sec. 27:, T13N, Dear Mr. Painter Enclosed is the approved application for pemit to drill the above re£erenced well. To aid us in scheduling field work, Please notify this office 24 hours prior to co~nclng installation of the blowout prevention casing shoe is drilled. Rare a diverter system is required, please also notify this office 24 hours prior to co~encing installation so that the CommisSion may witness testing drillint below the ·shoe of the: conductor pipe. C. V. Chairman of Alaska Oil and 'Gas Conse~ation Cmmmtssion BY O~ER OF THE C~!SSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. March 10, 1989 Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-63(X) Mr. C. V. Chatterton Chairman of the Commission Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: RE: Permits to Drill, Milne Point Unit, Wells G-1 and G-2 Attached you will find certified plats for the Conoco Inc., Milne Point Unit, Well G-1 and G-2 Permit to Drill Applications submitted to your office on March 3, 1989. These certified plats replace the plats submitted with the permit applications. If you have any questions you can call Jim Fox or Steve Brady at 659-6322. Yours very truly, D. F. Rainwater/E. L. Robinson Senior Foreman RJS MAR 1 ~ :L% :'~ ,fiji.' ' ~' Ga, Cons. Comm.%siot~. Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 March 2, 1989 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE' Milne Point Unit; Permits to Drill; Wells G-1 and G-2 Dear Mr. Chatterton' Attached please find Permit to Drill Applications for the Milne Point Unit, Wells G-1 and' G-2, Property ADL-25906. A check for $200 is included. If you have questions please call Jim Fox or Steve Brady at (907) 659- 6322. Your v .Division Manager JDC/cl Attachment RECEIVED Alaska Oil & Gas Cons. Commissio~ AnChorage ALAS¥' la. Type of work Drill Re-Entry 2. Name of Operator Conoco Inc. STATE OF ALASKA OIL AND GAS CONSERVATION~ ~MMISSION PER,iT TO DRILl' 20 AAC 25.OO5 Redrill IZ]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Deepenl-I{ Service [] Developement Gas [] Single Zone [] Multiple Zone 3. Address 3201 C Street, Ste 200, Anchorage, AK 9950 4. Location of well at surface 3420' FEL, 4060"FNL SEC 27, T13N, R10E, UM At top of productive interval , 3300' FEL, 4620 FNL SEC 27, T13N, R10E, UM At total depth ¥2~f 3281' FEL, Z~BFNL SEC 27, T13N, R10E, UM feet 13. Distance to nearest well 1st Well on Pad feet 12. Distance to nearest property line @ Target 3300 16. To be completed for deviated wells Kickoff depth 600 feet Maximum hole angle 10 * 5. Datum Elevation (DF or KB) KB 28 feet 6. Property Designation ADL-25906 7. Unit or property Name Milne Point Unit 8. Well nurpber G-1 9. Approximate spud date August 1989 14. Number of acres in property 2560 10. Field and Pool Kuparuk River Field 11. Type Bond (see 2~ ^^c 28.0251 Blanket Number 8086-15-54 Amount $200,000 15. Proposed depth (MD and TVD) 4660MD*/4600TVD* feet 17. Anticipated pressure (see 2o sc 25.o38 (eX2)) Maximum surface 2200 psig At total depth (TVD) 2300 psig 18. Casing program size 'HOie' 30" ' i2~" Specifications Casing Weight[GradeiCoupling Leng't'h 13-3/8" 48#'{H-40 I Weld 80' 9-5/8" 36# ~K-5~ BTR'S 24,97' r 8 ~ ' '7" 2.6i/I ! 1 ,-8,ol 4'632' .... 19. To be completed for Redrill, Re-entry, and DE;ePen O Present well condition summary Total depth: measured true vertical Setting D,epth Top Bottom 28' ! 28'1 108'1 1,, ~erations. feet Plugs (measured) feet Quantity of cement TVD (include stage data) 108' 2500' 4600' +485 SKS Permafrost C ~486 SKS Permafrost E +404 SKS Class G +129 SKS Permafrost E +256 SK$ Class G +409 SKS Permafrost C +60 Bbls. Arctic Pak Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth 20. Attachments Filing fee. ~ ?..~9~erty plat [~ BOP Sketch I~ Diverter Sketch [] Drilling program [] Drilling_ fluid program, .-~L'~m'e"~s,, dept~plot,,,, ,_[] Refraction, analysis ...... [] Seabed report. [] 20 AAC 25.050 requirements .-~ 21. I hereb~at the~oregoing~~d correct t~e best of my knowledge Signe~ /~ , -' ~ Title Division Manager Date 3-2-89 Commission Use Only ' 'number ~ j ApprOval date } PermiLNu~ber I See cover letter ~? ~.~ J -- O~ ? - /?~7 J 0:~/2, i.'/~9~ ~ J for other requirements Conditions of approval Samples r~quire'd ~Yes ~ No Mud log required ~'Yes ~:No Hydrogen sulfide measures D Yes .~No Directional su~ey required ~ Y~s D No Other: / by order of Approved b~ ~ ,/- ~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in ~ripli~ate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT G-1 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 I · Casing and Cementing Program ae The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks of Permafrost Type "C". Be The 9-5/8" surface casing will be cemented with ±486 sacks of Permafrost "E" cement followed by ±404 sacks of Class "G" cement. A top job Will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The primary cementing job will consist of ±129 sacks of Permafrost "E" and ~256 sacks of Class "G" cement pumped around the casing shOe. The secondary cement job will consist of !409 sacks of Permafrost Type "C" cement followed by ±60 barrels of Arctic Pack, pumped down the 7" x 9-5/8"annulus. II. Drilling Fluid Program A· Be 0-2525' 9.0 ppg freshwater spud mud. 2525'-3646' 9.2 ppg KCl mud. RECEIVED C. 3646'-4660' 9.4 ppg KCl mud. III. Drilling Program Aiaska DJI.& Gas Cons· Conoco Inc. proposes drilling the subject well as a production well in the Kuparuk River field (Upper Cretaceous). The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.4 ppg. A low solids KCl mud will be usedin the production hole. Mud weight at TD will be 9.4 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hOle. A 13-3/8", 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure test will be performed as per State Regulations. BOP's, choke manifold, Upper and Lower Kelly will be tested to 500 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The well will be flow tested after the rig is released. Arctic Pack will be placed in the 7" x 9-5/8" annulus after disposing of test oil and excess drilling fluids. A® Drill a 30" conductor hole to ±80' and set 13'3/8" conductor. Be Drill a 12-1/4" surface hole to +2500' TVD (2525' MD) and set 9-5/8" casing. Ce Drill a 8-1/2" production hole to 4660' MD and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV VIS FL 0' 0' Gravel 1-1-4 9.0 32 20 90 15 2500' 2525' Sand/Clay 1-1-4 9.0 25 20 65 15 3605' 3646' "K" Sand 1-1-4 9.2 8 12 35 6 3825' 3870' "M" Sand 1-1-4 9.4 8 12 35 6 4085' 4133' "N" Sand 1-1-4 9.4 8 12 35 6 4255' 4306' "O" Sand 1-1-4 9.4 8 12 35 6 4600' 4660' TD 1-1-4 9.4 8 12 35 6 *The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300 feet TVD, a Sundry Notice will be submitted. Pad O, I~el Ao~ 1 Propoeed HI Ine Point Unit. North Slope. Alaeke 0 . RKB ELEVATION, 1000. 2000 - 3000 _ 4000 _ 5000 _ KOP TVD=600 TMD=600 DEP=O BUILD 3 DEO PER 100 FT TVD=925 TMD=926 DEP=28 EOB AVERAGE ANGLE 9 DEG 47 H[N t 9.5/8~ CASINO PT TVD=2500 TM =2525 gE 299 K sNDS TVD 3605 THO 3646 DEP=490 TARGET / N SNDS TVD=4085 TMD=4133 DEP=573 0 sNDs TVD=4255 TMD=4306 DEP=602 PERHITTED DEPTH TVD 4900 TMD 4960 DEP 0 1000 VERTICAL SECTION HORIZONTAL SCALE 1 !N. PROJECTION - 1000 FEET CONOCO, ,I. =. Pad G, Well .1~11 Ina Poln.t Not 1 Prop~eed Unit, North lope. Alaska SURFACE LOCAT l ON t 4060' FNL, ,3420' FEL SEC. 27, TI3N. RIOE z ---I ..1- I c: .-I -r- 1000 1000 2000 WEST-EAST 1000 0 1000 I I SUR TD LOCATION' 4708' FNL, 3281' FEL SEC. 2T, T13N. RIOE 2000 TARGET / N SNDS TVD=408$ THD=4133 DEP-573 SOUTH 560 EAST 120 TARGET LOCATION' 4620' FNL. 3300' FEL SEC, 27, TI3N. RIOE PERHITTED DEPTH LOOATION~ 4757' FNL, 32Z1" FEL SEC. 27, T13N, RIOE S 12 57:3' DEG 6 HI N E (TO~ TARGET)~ DEVELOPMENT WELL WELL NAME: WELL G-1 06-Feb-89 CONDUCTOR SETTING DEPTH: 80 SURFACE CASING SETTING DEPTH: 2,525 INTERMEDIATE CASING SETTING DEPTH: 0 PRODUCTION CASING SETTING DEPTH: 4,660 DEPTH 0 0 ( ,s2s) (2,525) (2,s2s) (2,s25) (2,s2s) (2,5 5) (2,625) (4,070) (4,070) (4,080) (4,660) (4,660) (4,660) (4,660) (4,660) (4,660) (4,660) (4,660) (4,660) (4,660) (4,660) OPERATION: HOUR DAYS A RIG MOVE: 0 0.00 B RIG-UP; SET CONDUCTOR: 12 0.50 C DRL/SURVEY SURFACE HOLE: 45 1.86 D SURFACE HOLE LOGGING: 0 0.00 E CONDITIONING TRIP: 3 0.11 F RU/RUN SURFACE CASING: 9 0.38 G RU/CEMENT SURFACE CASING: 6 0.25 H CHNG BOPs; PU BHA; RIH: 9 0.36 I DRL OUT; TEST; TOOH; RIH: 9 0.37 J DRILL PRODUCTION HOLE: 32 1.33 K OPENHOLE DST SOS "M" SDS: 36 1.50 L CORE "N" & "0" SANDS: 144 6.00 M FINISH PRODUCTION HOLE: 16 0.67 N OPENHOLE LOGGING OPERATIONS: 24 0 CONDITIONING TRIP: 9 P RU/RUN PRODUCTION CASING: 14 Q RU/CEMENT PRODUCTION CASING: 5 R CASED HOLE LOGGING: 16 S PERFORATING: 6 T RUN COMPLETION STRING: 8 U ND BOPs; NU TREE: 12 V "N" & "0" SDS FLOW TEST & GP: 336 W RIG-DOWN; MOVE RIG: 0 1.00 0.36 0.58 0.19 0.67 0.25 0.33 0.50 14.00 0.00 CUM DAYS 0.00 0.50 2.36 2.36 2.46 2.84 3.09 3.45 3.82 5.15 6.65 12.65 13.32 14.32 14.68 15.25 15.45 16.11 16.36 16.70 17.20 31.20 31.20 TRACT 14 DEVELOPMENT WELL G-1 1000 0 -1000 -2000 -3000 -4O00 -5000 .......................... ~:....: .......... .. ............ I",: .......................... ! ............................ t ............................ ~ .............................. ~ .............................. ~, ; ; ,,,; , , · 0 5 10 15 20 25 30 35 DEPTH DRILLING RIG DAYS iii i ii ii i i iiii i ii i iii~ i i i i. _ii iii i .... Utl~ fOiSt UNIT l~ MILNE PT. VICINITY MAP ~ 0 I 6 MILE8 _ II I I ~ SEC. 27, T13N, R1OE, UMIAT MERIDIAN .......... W~L FROM ~R~ L~ FROM ~ L~E ,,, .... G-I 4,060' ~,420" ....... ! ~ ' · G-I 6,OI3,655.3OO 667,190.418 RE~. Pff I : ...... ~V~1 Pti :W~L' Nm~ LATI~E ~ST L oNGIT'm~ ~,, O PAD G-~ ~ 70' 26'~2.~8' 14Q'32'OO. 439' _T~ ..... ..il i imll i .i i II I I I I II, II I' I ' I I II IIII II I II 'tim I IIIII F. Rober~ '/eeeeeeee eeeeeeeeeeeeeeeeeeeee~. ~ ~ 6URVEY~ FOR: ~~ ,~ ~~.... ,o. ~,, ....~. , D,~ ~8, G-1 LOCATION ~ ~ ~m ~ ~D ~OOK ......... i i ii LUll I I I I L[ I I I~ II II I I I I , I I II I III I AJX.-255 C~ 2_K_~_ 7 ~3 T 13/4 R 10 E 1 ? 13 N R 1 1 E i 3 ADt..-31971 1265 AC ~i CONOCO'ET A~,- 11 12 3' 8 AD:..-4Y¢ 3= AC:; ..~DL.~7432/~. E8 AC ®I conoco 13 · 10 I AOL-2$S 18 2S~O AC _ . _ 31 32 AOt--28231 255,5 ,KC .... MILNE POINT UNiT (~ OefloL®a t~'~cl. It,~mb,e~& 2 ~~~ ~ U~I~ ~o~ary 6/84 CONOCO £T AL. lB 2! 22 AOL-47429 A~[,-31584 I~ 1280 AC 1280 AC EX~t~tT A MILN~. POINT UN[T AREA 0 1 ~"" i t ,,,,t : ,, ~cale U CONOCO, INC. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING · FL011 LINE "----'---I~¥1' APl 80004 ~ RAM BOP APl 5000 ~ ,&PI ~000~ APl $000 SIDE OUTLET8 APl ~0004 RAM BOP I~g/i' APl $000d · '11' APl ~000 (2) (3) II · APl ~000 ~ (6) R.O.P. stack size rating meets API RP 53 & spec 6A for class 5N with clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 sallon accumulator and reservoir unit and auxiliary energy source for. system activation. Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. Choke and kill manifolds shown separately to meet AP1RP 53 class 5H requirements. CONOCO,( DIVERTER STACK FOR 13 318' ,..CONDUCTOR ~'ILL UP LINE -- ~0' BELL NIPPLE FLOW LINE APl ~000 t~li AI~NUL~R PREVENTER RELIEF VALVE OIVERTER QUICK CONNECT ASSEMBLY SAVER 'SUB ASSEYBL. Y .... - - START INO I'l[AO · ...... 13 3/~' CASING '/' · · ° :%' . .,, o 1. The hydraulic contpol syste~ will be in accordance with specifications a~d AOGCC 2. The HC8 valve will ope~ ~he~ the preve~tep closes. Fl si~Ble tO" relief line will ~un off of the dpillinB spool HC8 valve a~d will have a tap§eted do~st~eam tee foe d~i~d dive~io~. Valves o~ ~th sid~ of the t~ ~ill ~ full o~ning a~ linked togethe~ to ~ble o~ to al~ays ~ open a~ the othe~ to ~ clued. ~ i i i i! i~ i ii i VA PiT i i _ i i · ~t..A N K · 500O MANUAl.. CHOKE ~50C~ tO, O00 PS~ HYI~ C t-tOK[ II II I ii II III I I I I I i ill __I I L ,STATE PLA'NE COORDINATES ARE ZONE 4 2. ALL GEODETIC PO~TION,S ARE BASED ON ~ men N.A.D. 1927' ~Z< m~ ~~~~~~ BAS~ ON PROTRACT~ V~8 OF T~ /I ~CT~N COR~ POS~ I MILNE PT. VICINITY MAP ~ ~ I~ 60' 12~ ~ ~ ,~~~ ...... ' '~~~ LOCATION IN ~ WELL FROM ~R~ LINE FROM ~l L~E 30' - ~ ........  G-1 4,060' 3,420' ~'~ ~ s~E PL~.E COO.D~N~ES-ZO~  ............. ,,= ,=, ,,, , ~ W~L ~TH  , ..... , I ! G-I 6,O13,655.310 557,190.417 ~ _ ~. I~L G-2 6,O13,715.293 557,189.845 G PAD ~O' GEODETIC POSITIONS NAD 1927 ~60'~ ~ 80' _~ ,~80' ~ ~ W~L NOR~ LATIT~E ~T LOUISE ~ G-I 70' 26'52.5Q59' 149' 32'OO.43QO ~~~"'.~: ~ G-2 70* 26'53.1859 149' 32'00.4423 I  TYpICAl SECTION NO SCALE , ,,, , , ~.~rt~o~ ~.v~m: .... ~ - I ~i C~T~Y ~T I AM PROPERLY REGISTERm A~ ~_ r. Robert- ~L~ ~ T~T T~S PLAT R~RE~ENT8 A LOCATION ~[.~ .... :'1 ~ ALL DUEN~N8 A~ OTH~ DETAL8 ARE CORRECT. ~~~..~.~.~ ' 8 U R VEY ED FOR: ' ~ ' ....... ~ - ~ ~ ~~ , ~~~ ~E~ DLR MAR . ~ ~ ~' FIELD ~OOK ~ J -- SCALE 1':2OO' JOB NO, 89OO9 ssior~ Anchorage CHECK LIST FOR NEW WELL PERMITS ITEM A~.PROVE DATE (2' thru 8) .... I (8) · '(9-thru i5)- ' 10. z- 11. (10 and 13) 12. 13. (4) Casg ~.~t~. Z-7-87 (14 thru 22) (23 thru 28) com By No.  NO R~S I th pe~it f ttach d s e ee a e ....... .~ ...... ........~.................. 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~- Does the well have a unique name and number ......................... ~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water .................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ~ eeee.eeeeeeeeeeeeeeeeeee®eee.......®®.. , ,. Is the drilling fluid program schematic and list of equipment adequate.~ Are necessary diagrams.and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure ratin§ - Test to ~ooo psig .. ~4~ Does the choke manifold comply M/A~I RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. . ~ (29 thru .. (6) Add: Geology :,. E~si~eeri~g: .. DWJ ~ LcS rev: 01/30/89 6.011 For 29~ 30. 31. 32. exploratory and Stratig~aphic wells: ~re.data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,,, , , , , , , Additional Remarks: o ~z 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. CG ~ANY NAME ~b~ NA~E ., ILNE P~I~T UNiT FIE~D NAM~ :MILNF 'POINT OROUGH NOR~-~ ~ATE . ALASKA ' A~I NUN~E~ · 50:. 029-2~927 RFFERENCE NO : 73443' , ~S¢~lUmDerger Alaska ComPuting Center S~VICE NA~E ~ GEO~IS DATF , 89/08/28 O~I:GIN : FhlC REEl MA~E : 73443 CGNTI~UAIION # : Ol PREVi{~bS REEL : COM~E~i : P~IEDT,CONOCO M1LNE **~ TAPE ~EADER **** 8E~¥I(!M NAME : GEOL18 DA'IF : 89/08/28 F ~ TAPE NA~E : 73443 CONTINUATION # : 01 PREVIOUS TAPE : COMMENT : 73443 POINT UNiT **** F!I.,~ HEADER **** Elbe N~ME : $ Di ,001 ATF 002£0 NAX ~EC 6IZE : 4096 FILE TYP~ : PS LAST FILE COMPANY NA~E: WELL: FIELD: OROU~H: ~ATE: AFI NUMBER: LOCAIIO., . SECTION: CDNOCU iNC. MILNE POINT ~II, NE POINT NORTH SLOPE ALASKA 50-029-21927 3644' FNL, & 3346'- rE' .... b 27 TOW~?SHIP: 13N RANGE: IOE 4745' PH: 7'5 . TC~'AB'I07 ' CO~PUTI. G CENTER RE~ARKS= ED FOR 31 T N .......... ' ~ ~ -~2~):F:ILE-SHD: .-O0!:CONTAI, S-FAST AND SLO C iA~NES~DA-IA OF FIBSD.BLUELINE FILE #40 FRO~ 4736' TO 3491' OF FIELD BLUELINE FILE ~4U FRO~ 4,')FIbE SHDT,O03 CONTA~ S ~$T~ND S~O~ CH~N~Eb DAT.A O~ ~ELD ~LUELINE FiLE #44 (~AIN'LOG)F'RD~ 4736' T0'2625' - '~ ~' (MAIN LOG) ¥ : _ :. : : - . DEFI ' ZELD bOCATION API SERIAL NUMBER COMPANY NAME  ELL NAME IELD NAME  TATE OR PROVINCE DUNTY  OUNTRY ATION SECTION ¢ TOWNSHIP · ~ RANGE ...... mmmmmmmmmmmmmmmmmmm.mmmmmmmmmmmmmmmm MR~ DEGF 85~ ~ITNESS'S NAME .... AXI~UM RECORDED TEMPERATURE DATE - MONTH DATE - DAY DATE YEAR RUN N~ R : . . ; : . _: · : . ~. - :' *6' .mmmmm~mmmmmmmmmmmmmmmm--m. MAGN£?IC DEC~INA?ZON STRATIGRAPHIC HIGH REfiOLUTIO~ FAST CHANNEL DEPTH DEFINITION STAND-OFF ~F THE TOOL STRING TABLE TYPE : CURV DEFI DB,! DIP BUT%ON 1 DB2 DIP BUTTON 2 D~2~ DIP BUTTON 2A SPEED- BUTTO~ 2 P3 DIP BUTTON D~4A 8DE 8 ND.;~ D£VIA~ION HAZY ~!~LE AZI~'UTH R-~- :. RELATIYE BKA-RIN. G P~A~ PAD ~ AZIMUTH GNOR GRAV~IY NOR~. FNO'R MAGNETIC FIg5D NORM  -N~ ~AGNETIC. FIELD INCLINATION ~V~ ' DEVI~.TION ~ ENEX 'VObTAGE .. E~× CURRENT ** DATA FOR~{AT SPECIFICATION RECORD ** ** SET TYPE ' 64EB ** ..-,---....,................,,. TY, E RF.P~ CODE ' VAL --;--.- ....  66 1 66 8 73 16 9 65 1IN i1 66 { 12 68 lumber..e A: sKa Com utlng Center oo o: 0~4 SHSC oo 04 ~ DF4~ ~S~ O0 ~10 I 10 . I 64 68 10 14 i ,6 I 64 68 .~v .'s.sc v o1 ooo oo ~ ~ ! ,~ i ~ ~8 OCE$ 0100000000 0100000000 00000000 glO0000000 0100000000 0100000000 0100000000 0100000000 0100000000 0100000000 0100000000 0100000000 0100000000 O1OOO0OO0O ~I ~H$C C1 $~SC !~ 0 000 g ~ 686~ g O 000 O0 O 1 :1 ~ 4 68 0 060 O0 0 I l 4 68 76 62 Ol ~ i 4 Ol OOO O0 I 4 68 1 000 O0 I 4 0 280 I3 ~ i i 4 6~ · 0100000000 0100000000 0100000000 0100000000 0 00000000 0~00000000 0100000000 0100000000 68 01000000~0 ** DEPTH= 4735,842 FEET 5B1,$~SC DBI,$SSC 77.0~0 86.957 ~6,~I6 8'7.463 91,479 91,639 9!.006 88.b0~ ~6,475 ~7,034 87,358 8:8,85 7 97,735 90,471 91;013 ~8;023 82,990 85.537  0,585 90 443 90,506 97.244 89.196 91,153 87,153 86.808 90 66B 91507 94,239 ~1,561 8i,507 ~1.500 ~1.796 80,94? 74,628 65.567 60,uOl 63.595 67.039 68.502 71,244 76.607 gB~872 99.662 ' 58,73 ' I 60 399 6~ 078 78,541 54. 43 ~ , 80.22 81,099 Rl '207 ~lO, 176 78.074 75. 327 71,181 75,563 ~1,943 81,690 ~ {..cblumbergel~ las~a Computing Center DB2A.$MSC 62,568 53.376 49.950 51;922 65,869 67.929 SB2, SHSC D~3,SMSC u B4. SMSC P A~ .SHSC 53,677 56:82 6.927 9,618 47.168 62,721 56.541 62,728 63.155 63. 326 63.078 62,063 62,288 62,599 6.2'982 (~.4 82~ 65,830 §5,589 65,791 65;532 64178I 6'3:246 58,665 '59.623 60,907 60,646 56,134 57;183 60,614 60,955 58;902 58;317 58,~15 58.373 64,652 67.816 67.459 66.741 66~409 66.69~ 6b,uT~ 66,457 64.7~5 64.995 65~238 6~;406 6,075 93,649 93,297 9~.30 7,5~4 87.120 86,480 8. ;451 91.96I 90,776 89,288 86.146 94,591 ]01,590 99,84'6 9~,349 99'740 102;529 2,732 SDEV.S~SC ~ 5 21 ,887 GNGR,SM$C 15,176 ~v.SH$C 3,827 ** DEPT~ : 4699.975 FEET 102,383 93,520 94.147 103.035 !0~.502 15.074 ~!AZI.SgSC , 998 FNO~:,SMSC ..73~ FI.SM$C 63,56t 62,982 62,520 ~2.058 69,3~8 59,590 59,00t 58.454 5'?,5.0-0 57,105 56,6~3 56.~59 S~I .SHSC , ..,'~26 83 593 ~ 84 53~1 ~4 I~ . ~ 8][ 4~ 80'635 79,930 '~'lJ , ';31 77,407 76. 564 75,78.3 75. 060 61,124 57.08'1 66,372 65.963 91.~53 91' 29 102.862 95.034 181.o(.)9 0,574 0.000 61,479 58,054 82 ~29 78:616 60 438 55:374 65.463 b4,443 DB2.SHSC 344 92:042 101.304 96.107 RB $H$C f'INC~$HSC Cl,SHSC 60,947 57.774 82 022 78:001 80,075 79.065 78,407 77.750 77 102 76.671 7 ,299 75 736 75.288 74,708 74~082 73.356 7~,767 7~:387 71,844 7!,!.44  808 52 192 50 5!0 49 676 56,826 55 29 53, . . 49,080 48:81 48.8~3 48.895 48:644 48.456 33.943 81.512 3'975 ~ $-¢hIum~erger Alaska ComPuting Center 48.142 47.967 47.630 4'7.125 DB2A,SHSC 58,228 56,253 45,557 43;051 35,5!5 35,188 54,322._ 52.278 4i'!41 39.432 34.903 3:4.650 SB2.SHSC 30,9!.8 28.640 24;942 24.428 25;606 25.887 27,7~7 27.!52 24,334 2:4,429 26;i01 26.248 D83,S~SC 58,273 56,576 40.670 36.52~ 26,980 27.124 2, 27, DB3A.SgSC 62 980 60.430 58,505 56,790 199 50,164 48,60i 47,22~ 508 4~.378 40'184 3B~91 DB4.SM$C B3,276 82,69~ 78,317 76.93 71,629 70.814 78~ 096 81,393 '932 75.04~ 69,~62 60,753 86.258 85,525 .0~3 ,403 ;081 75,379 85,076 8'4.617 80,052 794'196 7:4,591 73~700 ~EV,SHSC PtA~'SHSC SHSC DFVI,.. C2,Si,~SC SMSC 3,069 SDEV,~HSC 2 ' 12,555 GNOR, ~4,62i ~V.S~SC 3.853 14.5i4 HAZI.SH$C ,9 98 FNOR~SH6C .0:69 E'I:.SHSC ** DEPTM = 4599.975 FEET SRI. S~4SC 1t, 732 11,449 I1. 308 11. 215 11.083 1! ~ 087 11 .~{38 10. 954 J,O~ 957 1 ~. 018 11,206 11 .~76 DB1 .SH$C I~,546 15 24.~ 15,742 15,366 948 15~3I I4;999 12,767 i 3.12 ! 1, 3 ~425 13,495 DSlA.SHSC ~2,737 I2,717 ~2,439 i2.229 10,931 t0~733 11,440 12.881 14~722 13,758 13.005 1-2,62~ 49,765 37'914 26.237 24,721 47,~33 27; 69 54 695 45:686 919 83.758 78~195 180,693 0,573 0,000 11.152 !.1,072 14 '174 13:344 11.930 14'317 47.638 36,439 25.519 25,149 43 789 27:005 53,432 43.996 79,100 72.657 83 105 77:0~7 RB.SHSC ['INC,SHSC Cl.SHSC 11 139 101886 14 8 1.1.436 14.776 31,035 81.337 3,919 ~ $Ch'lum'berqe-r.~ . AlasKa Computing Center DB2, SN,SC '~324 12,364 1,2,4'51 I2'452 1 ,1 99 .313 li ,953 i3,051 12~333 11,974 ,_B2.SgSC 379 I~,24 1 I,t396 1J,702 11.220 ~53A.SgSC tl,907 12;596 12.378 DB4.SH$C 12.~8.8 12,336 4,370 15.385 !0~614.10.426 12,~43 12' 33 D;34A,S~SC 12,20~ !2,079 12 31 l~.gV. SH,.. c P!AZ, SHSC s~SC D~¥i,s 12,089 12,034 12,245 12,232 12,207 14,518 !3,3!8 13.700 !4.188 15.366 16.603 17 418 i7~103 15,10g 13.675 12,695 12,390 12:663 1.2,717 1~.84 !2,777 12,426 16.688 12~643 13,912 17 1. tl 13'071 10,544 .269 3 091 1 5,7~0 13,963 3'5~7 i4,068 !3'499 12,965 0,744 2i3 581 13 417 8 457 GNOR SHSC _.o~C 10,092 ~.35~ 1.'1~901 11'253 12,'3~0 I1'433 i4,110 ,744 16,465 i6.379 15,208 15,336 16'536 i6;555 F~ ** DEPTti - 4499.975 . EET 16.265 16.456 tb,36! 15,163 16;144 16,398 8.146 88,052 .~,131 ~ 314 8,694 .495 ;21.4 ;95P 8,256 9,064 I 0.052 ll , 222 8,990 9,166 9.712 10,052 ,163 8,~35 ~,862 99 4:38 t)Bl 12,553 14,720 !.4 607 11~478 179 833 0~572 0,000 16,148 15,585 ,~07 .832 9 13 ~ ~ %.. 11 936 14:768 15 786 11:896 RB.SHSC FINC $HSC C1~8H$C 32,942 81,574 8,403 15 725 15~861 8,692 7.873 9.267 9.447 Pb2A, 8gSC SB2.SHSC DR3,SHSC DB 4. S~SC PE¥, SHSC DE¥.I,SHSC [)B 1. SHSC OBIA.SHSC , 4 ~ ~05 15, !qT~ 14 521. 14°.82 14, i 3,022 11 o 644 11 ' 058 10; 78. . 1i ,424 11.6q0 11,~96 12,210 12,556 ~4,526 ~I,796 3;01~ ~0,41~ 13,615 13 645 ] .624 2'802 t0,3i8  5,09~ 0,992 14 180 14.~28 15,460 15.705 15,210 930 12.715 12 343 3,208 12, , 1~i94 11,07q 11,890 12,337 12.54i I~254 10,3!9 10,410 9.751 10,342 11. 234 12. 311 1~,386 1,4.829 2 875 1:758 13.222 14,273 3 11,125 11.652 !2.352 13,048 1.3,6~0 t3.620 13,516 1'3~397 12,035 12.072 ~1,553 1~,080 13,006 11,102 13 784 13;292 13,499 13,090 1.0. 822 I0,424 9.926 9. 368 8,927 8.695 8.430 8,1~9 a;zO2 ~ ~88 ~,323 ~.4~3 6,786 9.517 10;492 II :81I ' I~,085 .,774 12,9!3 GNoSDE~SHSC' ,SHSC EV,SHSC ,69! ;672 12,603 4399.975 FEET !o ;~o3 lo 108i I0.5~3 13, ~ 89 HAZI,SMSC 0; 99~ F.NOR;SHSC 0;998 EI~SHSC 9,347 8 8b03 B Y98 8,901 8; 950 9: 06 9 ~ 349 9 ~ 592 9,465 go 5~4 9,706 t0, [ 80 0,998 186.481 1'82,488 ' . 509 DEPTH : 17~,735 ,570 0.000 8,994 9,645 !3,918 9,595 343 14 796 9 ~$ 10 71~3 16.254 972 10'~q5 16.580 ~ 915 9,628 1~,025 RB,$HSC FINC,SHSC CI,SHSC 8 977 9:589 12.932 9,386 ~2.022 2!,96~ 21,904 21.911 21,90g 21,775 ' 20~680 024 19;190 1,582 2!.2~ 20. ! 206 7,543 81.673 8,575 ~ 'S. CMlumberger. AlasKa Computing Ce'mter 968 .1.5. 478 13. 846 1l . 957 14,650 i5 69~ 115,042 16'08. 18.027 18,125 i 5,435 1!'4,680 16,859 17~521 18,182 1:?,912 PB2A.$HSC 441 634 696 1. 352 9,713 lo;o07 10,859 I0.289 .9, b58 9 i 5.7 I0,3:55 t0; 76 900 ~,653 190 g, 648 , ...12 9,523 ,934 9;953 9,i69~ <9.351 DB3 t0,366 10,530 9,085 9,164 ! i ,228 i!.577 :1.0,646 ,370 1~,635 10. 270 9,62i DB3A,$HSC 11,498 il,498 II,440 ! ! ~936 t2,1.62 1 ,,533 17,057 17,78! ; 8,266 11,462 3.090 118.~84 11,598 _ .995 12,899 I4,099 11,385 11,041 ~21186 12,408 13.017 "51~ ,428 12,243 1~,564 10,098 9,205 9,314 !-78 10,29 ! 354 10; 442 .486 _9 ~ 6:38 ~EvI,SH$C C2.S~{sC ,141 1~,628 ** DEPTH - 4299.975 FEET 11,979 !1.618 1.0'253 10'IOI 9.398 9.565 1~,299 10.971 .948 9 ~ 74 9,858 1-0,485 [)BI Mu'--' 1_3.776 15.218 16,103 16.477 !7,225 17,58! 1'1,941 18,068 i 5,803 i 3.77~. I 1 , 7-0~ t0,264- 13,999 17.766 9.751 9,569 9 592 10:252 804 11,528 14,1].0 I3.305 11,932 , 649 ,955 17~,320 ,572 0.000 665 190:529 1.6.656 17.888 14 399 17~944 9.646 9,564 9,743 10.448 9 359 101553 11,701 15,568 12.377 11.945 9,493 9.466 FINC. SC C 1. SHSC 0.444 19.327 16,912 17.242 25.641 81.692 8,748 i ' ~ - · : -~ ' -. . · ~ . _ .. - : : . ~. . ~:- .. :~.: : _ ~16,266' : 16,796 17; 164 i6~ 969 3 ~-?. [382'5HSC ~ .9" 1'4~ - 9,52~ -~0~'~02:1' ~ · '.:1:~'400 ~ 1 ~i82 1 ! 1730 12~ 9,0t6 ,119  .~,990 ,291 14,178 12,599 1:2,529. 10;962 7,878 13'8o8 15,617 17,184 10,926 12.908 9.246 12,478 13 425 12~270 14.137 12,514 12,116 10.877 7 763 14:165 590 21 : 0'000 9,276 12'906 RB,SHSC FINC,SHSC CI,SH$C 19,596 81.651 9,562 , 709 .951 7,891 7.959 7,338 7,443 7,545 7.298 ~ Schlumberger. . A~asKa Computinq. Center 6,198 6.34~ 0 768 44~) 7,201 6,89! ~ , ,836 . 6,387 6. 800 7,213 7,433 7,213 5'553 7,898 7.77~ 75'548 6.912 6.996 DB2, .8HSC 826 7,306 260 ,689 ?. 1.26 .6,232 6 ' 4~7 6 ;50 ~ 7~118 7;2.19 :923 592 D~3A. SqSC 6.377 6.731 '618 .. IIi - · ~ "" · 6 ~()9 6 760 ~, '42 6.492 6 323 ~,~ 6.20~ 0~,!94 ~,378 6.603 . 7.52 .,726 ;~64 921 ;869 4;855 . .04 6,480 6,532 6'196 5o 407 79~ 6,7~6 6 481 6,279 6.105 5.975 863 6.03 6,831 6.794 4.372 ,!33 ;914 2.095 8. 97 12;~50 8,5t5 SDFV.SRSC GNOR,$HS DB4A.S~.~SC 4099.975 FEET 2,518 9.210 ,731 ~.590 6.830 PEV. SHSC .P :1 Ai,,,., .. ~, H $ C DEV~ ;S~SC C~,$MSC 5,06'5 5 · 599 '730 ,052 12.068 EAZI,$MSC 9': 7 FNOR., :SHSC :,:-- DEPTH = SB1., S}.~SC [)8 'l .SHSC 18.707 ,425 ,57 , 10 5,821 4,909 182 392 0~582 0.000 21.810  t,240 9.439 23.178 23,999 20;037 19,182 10;606 7,740 6.408 5,852 7,364 6.559 6.763 6.294 6.886 4 869 5:881 6.070 6.360 5 789 6~778 5.553 5.268 RB,SHSC FINCoSHBC CI.SHSC 23,928 18.914 19.273 18.8~ 19.410 20,509 2~,828 23.030 9_3;~77 23,02 23.7~0 23,305 ~2.475 21.669 186.199 80,446 8,571 Schlumberger AlasKa Computino Center' 21.154 20.783 20.592 20.417 19,814 i. 9.669 ~9,953 20.327 21,537 21.593 21,~65 2:1,271 20.297 ~0~. 991 ~0.280 20;541 20,~76 ~9,773 20;675 20 396 19d817 ~8:973 SB2.SHSC 19 ~43: 20,,211 20' ~_,255 20~269 ~9.3~I 19,183 18,904 i8,797 !9.456 19.60 19 502 19~299 ~8,740 18}60~ ' _ I8,349 18~15g 18,7.11 19,40~ 202466 19;73 18,198 18,300 020 21 ......... 19,322 18,954 tU.303 18,197 DB3A.SHSC lO,ll4 10,t46 ~0,581 2'1,016 19,963 19,42~ 19,244 i9,027 17,007 16;748 16'904 !7~!96 OB4.. c H,SC 20,541 20.235 21,377 21.591 19,246 19.375 19,808 19,88~2 ~,3Oo 2oi~96 900 2-0; 342 2I.,025 21.452 21,6t9 21.385 21'085 20: ~ 19,970 19~76 P. EV. SHSC C~, 5H$C 0,811 SDPV.SiiSC 3:15,264 GNOR SHSC 12~044 EV'EN~C 8°460 ** DEPTH = 3999.975 FEET I2,714 ~iAZI.SHSC ,998 FNOR,S . 15:203 15,2~! 15,209 i5.059 21,335 18i801 20.8~9 20,860 18.909 19.023 579 8:500 21.020 18,540 0,278 0,304 21.033 22.470 183.094 ~:579 000 !5,221 !5,184 21.208 18.709 21.331 20,437 2O 8O8 20:425 1g.266 18,819 21 129 181143 2O 483 21.009 19.482 2O.785 21,870 RB,SHSC FINC,SH6C CI,SHSC 15,420 15,164 132.878 81'055 8.498 2:0.054 ~5,67 .- :~.: - . . ' _ . : : '_ ~_ : ~B1A,6HSC 13,01~ I3,917 t4,.:~3~: - :1~4 500 ]3;431 13~092 13;0'I5 1'3' 15~ . ..13;047 . ]3;3f3 -!.:3..:~781 ; 1~3,926 15. 757 ~, 354 f'6.960 -' .13,35I i4:,. 157 15-, !7.2. · 1~:5,836 ' 14;007 i'1:.390 15;21.3 · ' .::' : DB3.:$HaC 16,6:69 -16.874 -17.013 17;740 17'8~0 I8~;'065 1~894 19,029 ~ I9-197- ~.52 ,07 , ,267 20,048 14;848 14 77 ' 58 16,208 16,090 18 ' 09 16:~77 13.9q5 15,119 ~7 ~45 8:82 18,78i 19'474  0,107 0,291 t9,21.3 19,374 I812 381 19,770 14.416 !3 I 16,807 16,145 17,676 i5,238 13.311 14.271 1],523 1 ,680 18,780 19,690 20,114 20,371 19 234 19~428 RB,SHSC FINC SHSC Cl:SHSC 88,674 81,535 8,841 034 I0.662 9.772 10,303 10,007 !~,687 ,385 1~.795 .357 ,721 12,815 13 136 12:493 13,065 12,304 12,153 11,89'8 2,077 2.034 12,385 i2.949 i3,054 12.174 IO 435 9: 94 I2,23] 12,372 12,343 ll;804 I1.074 10.695 11.011 10o702 .071 3,225 SDE¥,SHSC~ 13,4~.3 . ~AZI~.SI-t~ 1800,861 271;01.0 ~ GNORi~HSC '0;999 FNO:R;~S:HSC .576 9,23I DEPTH =: 3799,975' "' FEET *:-';:* ~;': - - ;~ ' 11,017 10,049 RB SH$C FINC:SHSC CI.SH$C 90,152 81. 51 8,768 I Schlum.,er'ger AlasKa Computing Center DB 1, St~$C i)B2. SHSC oB ~. g.n,.:C DB3. SH6C DB4~.. St-{ $ C ,27 ~A t... %.. p 1 AZ, S.-.tSC DEV7 SHSC: C2.8HSC 11,7B6 1~.52g 11,i79 10.959 !1.040 !l,BO0 12.336 t2.755 12,744 I2,205 10,612 9.821 9,277 8,88't 11 280 11~491 I1.7~3 1t.2 ~ 12,170 12 ~48 i!,916 298 12,996 388 12,512 11,976 12~9-48 ~ I ,973 15,011 14.632 13,839 19...946 ,57i 13.041 !2,741 !2~602 !.4.466 13 871 13,V85 12.]71 t2,039 I2[005 I!;876 I]. ;760 11. 848 12,003 11 ;888 11.56g 10.69~ g 4~ 10,710 10,582  ,!58 8,880 10.599 ,790 2,093 2,465 !,2.610 14,078 12 24 !0,354 8.823 15,799 10,89] 16,26I 16.267 ~1~,228 16,065 14'792 13,998 ~.027 11'784 9,797 10,259 11 , 432 12.860 12. 7 12 629 13:992 12 073 11:712 I0.13~ 8,827 15,444 10.219 11,322 11,517 11.703 12.204 12.581 13 030 1.3'089 1 14 28~ 14 981 15,8'18 16,585 171328 18 167 q'00 19' . .... .4!9 19~665 6,658 ~ 179 9,146 I.. '861 12,916 12,703 9 330 10:455 1.81,549 0.579 0.000 7: 1:~.078 ,541 io 3 12,870 8,842 a.797 ~ 32 9,!.i8 9,489 q,574 9 70! 10'076 1 I, 342 1 ~, ~08 1 2' _ _ ,084 12.I25 13.8!6 HAZI.SgSC l ), 99 FN 1,i02 $08,427 131071 8,685 SDEV,$HSC GNOR.SH~C 6.27! 12.425 9,412 10,846 RB.SHSC FINC,SHSC CI,SHSC 127,689 80.992 8,832 AlasKa Computtn~ Cen%er · ~ D~P~H = 3699,975 FEE~ ~* 9;761 9,792 I0~I78 I0~794 SHSC '1~2,155 17 · 22~ 9,939 9~970 10, 35 831 16,656 1 . ~ - 11,243 !1,143 11~'O60,- - i1~024 10.340 9.852 13,788 10.428 14,317 11.613 9 611 11~345 9,258 9,435 l:g, 3 ? 0 10; 561 10;004 ,885 ' .836 9.544 10.692 10.26t 9.820 g 962 9. 848 ,394 10,858 I0~523 024 777. :9,569 1~,403 1~.a95 10,798 10,468 15,856 16;174 16,t1 13.868 2'64 12.445 5 ~.E~,o~oC U,8.84 SDEV.~SC 14.747 HAZI.SHaC 177.683 PIAZ,~ESCrq ~ 359;839 GNOR;$}iSC ·0'998 FNOR';SHSC 0,582 -:~. :...._ .. . : . 9.657 8.920 10,640 10.403 15 399 16:829 3.640 2.19~ RB SHSC FINC:SHSC 182,084 80.518 Schlumberger AlaSKa Computing Center DFVT.S~ C 13.403 EV.SHSC C~.Sfi$C 10. 985 ~,8~4 Ei.SHSC 0,000 Pl,,~ 1 A ..S. HSC ~,- 10.058 q.47o I0.057 10,813 9,372 10,561 12,413 13'~34 11,748 i0,856 ~0.300 10~613 ~1.820 12.2~5 12,759 SB~.S,:.SC 11,730 10.20l 12,716 I~.938 12,947 12.861 12,808 I 547 12~ 201 12.525 12:559 12. 562 D~3A. SHoC 47! }2,519 1~.,564 1 497 295 12.. 21 12,~'35 12.442 [)B4 . S ~'.'!~ C 3.i01 D b 4 A, S H~);. ~- C !. ". ! '~'838.. 8,b51 9,979 1] ,299 1t.085 10,94o 10.87t 10.41o i3.500 27 12,827 12,223 12.49~ 12,449 ~.1.807 12,340 !1.204 I.~..22! 11,190 11.~61 11,214 11,131 11.9!§ !0'i~99 I0,818 10,763 10,779 10.925. ~1,1I~ 1!,385 12,255 12,459 12,616 !2.568 12.259 12,273 2 b7.9 t2.612 .2 531 1.2,46~ 12 293 12'3-1g 574 1i,437 11,270 11.226 ,580 ' ~ 7 790 1~:., i1 !! , . 11,96~ !2.i. t6 ~2.262 i2.35 12,67U 398 11,246 1i,8~8 076 :9O7 CI.$HSC 9.555 12.806 12,329 12,077 12,873 12,420 12.458 12.379 11.056 X2,97! 8,390 11o350 11.203 10,736 12 658 12~317 11.412 11.856 10,851 11.072 12.040 P~A~,~HSC ~ 2 1,055 GNOR ot~C '~'"' s~sc ~ 4. 066 ~V ~, - ' C,:. · SHSC 9,258 DEPTH = 3499.975 FEET DB~ .8HSC 180,116 0,580 0,000 FINC SHSC C115H$C 11) 82A . 5{.5,756 13.286 ~0.087 7.349 7,653 9,757 ,20'1 13,.,, 2 12, 743 9;42_ I0,210 10'~97.. 10.778 lO.fl ~ 13;520 13.4~ 12,544 12,859 D[~ 3. SU, 8C I1 027 11,417 121553 il.6B6 12,951 1<~,974 1~,825 1~.2i0 12,~7 11.830 ,570 ,225 5,!18 6,314 10,408 I .422 t0,439 I1,07~ DB4,S~SC II, 21 Dt~4A, 6H$C 11,005 8,389 10,~5983 112,021 12.378 t, 2 348 1-2,197 I ;092 10;899.. I0'789 I0,793 10;627 10,480 101329 10,257 438 lo. Isa lo.3o8 1'o.311. 10 441 Ji01691 1('),789 1.0'~37 10,886 i01880 802 1. fi i 785 10,7! 1 I0.604 ~ ~ 992 9 286 9,102 ,bgo , . 9~044 9.3~6 ,393 9. 186 9,177 9.125 9iO7,i 9.260 q,228 9.200  589 9 66~ ,549 g 555 ;840 O' ' ,840 9,849 9.903 7.959 9,223 9.325 9,732 9,808 9,930 9,677 9 687 9 715 ~ 797 9;793 9~ 730 9,769' .871 9 ~ 883 9,818 9,'184 9.820 11,395 11,~1.4 11,217 11.073 10,949 10,692 10,644 10,615 10,605 10,614 I0,682 ~.0.773 t0,818 10~835 Or` 9 . ;002 I0,974 1U,7157 10,95 ii 0_9 11,226 lo,930 147,840 80,782 9.845 1 058 9.814 9.810 437 10~720 10,520 10,841 8.295 9.192 9.471. 9,801 9,839 9,941 10 823 10~638 11 175 10~879 I-SchlttmbergeI' AlasKa ComputlBct Ceoter I 0,, 8-34 1. O. 821 REv, S~l..qC !. 272 5DEV. P1AZ SHSC 344*460 GNOR .~'~SC t4;665 C~,S~{SC 8.579 ** I)EPTH = 3493.042 ['g .1 DB1.6HSC I 0. ~40 10. 857 i5.470 HAZi.;SHSC 0'999 .,vN ' ~HSC T)blA. SHSC DB2.~H~C 6.266 7.426 7.029 7,064 ~,949 .6. 216 ~,347 710 9,6'!1 10,340 10,209 573 6, a27 6,673 6,74 ' 7 1.34 7.~93 7,2 2 6.826 DB3.SH$C b, 540 5. 596 5,005 5,592 DB 36. ;569 6.598 ~;6!! o,6~ I.'..". ~ 4. SHSC o,3:2~ ,26 6.38 346 .. ,24 6,353 6.398 6,500 6.659 6,q68 6.46~ 6,455 i5.425 6,294 6 2'13 ~,270 ~,.291 6'50I 6:568 ,644 '63tq 7.188 7 100 0,971 6.RO 7 6,,491 614'~9 6.496 6,510 6,70t 6,791 0,873 6,~48 7,387 7.3 36 7,297 7,243 ~,'1~4 7.07 ~,075 ~ 151. 179 062 0~581 0.000 6.359 6,313 9.700 6.826 6.153 3.868 ,079 .399 6.489 6.548 6,261 6,284 6.392 6,353  649 548 7,228 7,217 RB.SMSC FINC,SHSC CI.SHSC 5,843 6,707 8,558 6.901 6.135 2.793 5 O4O 5:50! 6.495 6,545 6 25O 6~325 6.332 6,440 6,531 6.615 7,198 7,262 165.906 80 754 9:037 -/': -6~085 6~125 - 6 :, !-:7~- 6-229 - . . ~ · ~ ': . ,~ ~ ( - .: DEVT.SHSC 14,725 EV.SHSC O"OBO EI'*SHSC 6,084 6,280 I78 741 .000 6.065 6.383 RB,SHSC FINC,SH$C Cl,SHSC 18 , 95 9,161 DEFI .API ~0--029-21927 aPI SSaXAn C" CONOCO-'iNC COMPANY WELL NAME FIELD NAME TATE OR PROVINCE OUNTY COUNTRY NATION SECTION TOWNSHIP $c:bl.Umber.'.ger AlasK:a C'omPutlD'g- CeDter T!!NT VALU DEFI TYPE ~ CONS TADLE rYPE . CONS TUNI VALU DEFI ..... .. ...... ...............,,------------.- MAGNETIC DECI. INATION 8~D$ ~ ~TRATIGRAPHIC HIGH RE$ObUTION FCD~ FAST CHA[!NFh DEPTH DEFXNITION '' STAND-OFF OF THE TOOL STRING -$OF[ IN TYPE : CU~V DATA FORMAT SPECIFICATID~ RECORD ** SET TYPE - 64EB TYPE REPR CODE 66 o 2 66 3 79 4 66 1 5 66 6 73 7 65 A ~ 73 9 65 It 0 !~ ~6 1~ 6b 0 I 65 ~T 15 66 68 16 66 1 0 66 I ** SET'.IT.¥.'PE'" - CNAN ** --....-...-...-..-.-.-.-.,,,.............,-..,-. .. .... ........... NA~4E SEPV [INIT SEPVICEhr, ~ , ' "' APl APl I I F'~L~'~:~'~'~'REPR PROCESS 1D O~<,~R ~ hOG TYPE CL $ gOD N.DMB SggP :.E~Eg CODE (HEX) :. ......... . 0~00000000 DATA DF.PT. S}4SC 4735,842 GR,S}~SC 93,250 DFPT,SHSC 4699,842 GR, $['{GC ~0.875 DFPT,S}~SC 4599,842 GF~. SHSC 101.500 DF.P~'.SMSC 4499,842 GB,S~8C !O!.938 DF'PT. $~iSC a399.842 (;R.8~8C ~7,~75 DFPT, S}iSC 4299,S42 GR. fi~!6C 103.188 DFPT,S};SC 4199.842 ~R.SHSC 56,094 DEPT,S~SC 4099,842 CR.SHSC 74,5~3 DFP~.S}<SC 3999.841 DEPT,SHSC 3899.841 GR.S[~6C 59,313 DFpT.SHSC 3799.8~1 G[~. SHSC 71.750 D~PT.SHSC 3q93.34I GR, SPSC 48,313 ** END OF DATA III ii1 ii:] Il! [:-1 FL ~ : · :364:4' .,ENL<:& 3346' FEL g P IN 50,02 9' 2 i g :27 : CONOCO INC,: NIL~.'E POINT UNIT ~' : AL A8 K g ' STAT . -1~ I LNg COON . NO~T}~ SLOPE CTRY ~ FIELD LOCATION API SERIAL NUMBER COMPANY NAME WELL NAME FIELD NAME STATE OR PROVINCE CO.NT¥ COUNTRY NATION SECTION TOWNSHIP RANGE ~AXIMUM RECORDED DATE - MONTH DATE - DAY DATE - YEAR TEMPERATURE . .-i -,.,- .,,,. ,,, DEFI :i ..... ':'~-'~ .... ':~' ' "~ ~' ~ RUN NUMBER · .~- . ·.. ~ - ~-~. .. . _, ' _ ~ :~, ~. '~:. ::. - ~.:-.: r.' '-x. :s- ....~:~-...~ · -- :- .-~ · ~ ~ -~ ~gRMANENT .DATUM BOVE PERMANENT DATUM " N '~' r'~ - -5B~ EbEVATION aP DERRICK ~500R ~: .;.-:.: ? · , .-ELEVATION OF GROUND . ~: - ~ ~ . c ~ ~ . - : _ . ~: .-- STRATIGRAPHiC HIG~ RE&OLUTION A ST CHANNEb DEPTH TAND'OFF or THE TOOL STRING . ':;: :'..:-F'~ : -.: -,_ :L.*''. '. ~ ..- . T . .- _ - - .o : .: : . :..:}.:.. ? ~ .7~?. - : :: . D:Bi : DiP:'B'UTTON iA D':B3 DIP :BUTTON 3 ~):":.~.: '~.~ :~.A : D::~;':~ ~', DO:4' ~:~ BUTTON4 : PIAZ PAD ; DF;VT DA,A (;'OR,tAT 8PECIFICATIOI~, RECORD ** 8ET T~PE - 64EB ** TYPE R~PR CODE YABUE 1 66 0 2 66 O 5 66 ~ 7~ 7 65 8 73 16 9 65 11 66 12 68 13 66 1 4 65 I~ --a '" s,~ ~ERVlCE APl apl ,API a~! F~L~ NUMB NUmB SIZE ~EPR PROCE$ ID .RDE~ # bOG TY~E (~LAS8 ~OD N~MB SgNP ELEN CODE (HEX) $.!ii $t-~8C O0 ' 61: 10 '; 16 ' I 64 68 0100~00  !, ~.SC O0 61 t! 01 0 ~ I~ ~ 64 68 0100000  B2 8MSC oO 6!0 02 0 3 16 I 64 68 0100000 ~2~. sase oo 6lo ~p o 3 ~.6 i 64 6~ o~ooooo -~' s~jsc o' 68 o ooooo 8-~,2 O0 610 20 0 16 ; l 64 1 DE3 S[-~SC O0 6t0 03 16 1 64 6~ 0100000 DB3~DB4 ~S~'~:8C~8C 000066. lO00413 O0 33 1616 11. 6464 6868 O01000oolO0000 RFV 5 SC V O! nOO O0 ~ 4 6R 0100000 sD~;.v s~,~sc o~:~ oo ooo oo o ~ ~ 1 4 ~8 olooooo H~.ZT SI{SC DEG ~6 630 61 0 1 1 4 6~ 0100000 RE ,~NSC LEG 76 631 Ol O t 4 6g 0100000 P!AZ SHSC DEG 76 632 01 0 ~ ~ I. 4 68 0~00000 G ~OR 8HSC O0 000 OO 0 I t 4 68 0 00000 FNOR 8~8C tiER O0 O00 60 0 ~ ! a 6~ O 00OO0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 ~Chlumbe~ger AlasKa ComPuting Center ID ORDER # LOg IYPE CLASS ~,i~B '~ '~ e'~.~ -.,i .~'-' .... dU~.3 ,.,a.-,P EL~ .... CuDE (.HEX) '~7~['~'~[ ........... ~---;;~--~;-,-,~------- ............. DEV! 8I,{~C D~G 76 620 O1 0 t I 4 68 0100000000 ~v~ s s" ~.~,.c ~ oiooo ooo ~ , 4 s~oloooooooo c~: s,s~ ~ o~ooo oo o ~ ~ i ~so~oooooooo ~ SHS IN 70 ~0 13 0 1 ~ 68 0100000000 C..~ SHSC IN 0 280 24 0 1 I 4 ~8 0000000 ** DEPT3 : 4735.692 FEF, u ** 22.195 1.9.411 19.405 19.856 19,616 19.50b 20.082 71 I t9.qSa 407 20,30~ 20,026 0Sa 2I. 759 21,74o ~.t. 18'703 I'~.783 1 '"61 20.3i0 20,723 ~9, 20,814 2.0,523 2 O0 21.213 20,393 20 ~ 296 2V,.~35 20,624 ?0.136 2!.787 21..429 2'I.075 20.736 20.416 20.093 !? 063 17~b98 i6,631 17.795 19,699 ~l,~i ~.' ' " .682 2i 2570 201833 14.1(,)3 i~.,039 18,U94 i7.770 iT. 08 5 !4:.6~4 204~ i4.755 15. 802 1.6,~90 116~584942 438 16, b21 ! 6,bg8 1:5,869 D}52~%. SF;SC 21. 392 ~. 5I 3 6,937 7. 782 11. 933 15. 658 17,279 15 153 12,518 It 176 11,8'10 13.220 4 [.',r~3. SHSC 17.1 q I 15. 473 15,067 ! 4. 634 I 4. 392 14. 320 4 285 lI.482 I~;7t3 14,aOS 14,b84 14,549 ~4~447. I .;,SlO ~4;841 14;qaa.. DB3A.SHSC 29.124 16 ~48 16,~20 15,916 14,689 14.250 14;165 14[ .90 14.494 14,760 15.103 15.337 AlasKa Compt.~tino Center I 5. I10 }. 4.87~ I zi. 643 !4.409 }4,920 13,8~4 5.6~9 13,4.5 17,996 I'/-967 ~ r~ O -,.. 15, t7 ~546 P1AZ,:c~SC DEVT~SHSC C2.$hSC I 062 SDEV ~).~SC 205,141 GNGR,oh8$ 14'8~2 EV'S!{S_ 8,020 ** DEPTH . 469=.~5.~ ~EET S~i.S~-~SC  3,351 13.733 3.005 15,o1~ 1'i,987- 18,081 17.~08 17,41g 17~74~ 17.924 17.049 I:6,70g 15.430 ~AZ:I~SH$C ,999 FNOR,SH$C .,062 E!,SHSC D~I A.S~{SC DB2. ~ HSC 15 "5~ 16:~20 I7.315 18,045 ~ . MH6C 814 16 584 17~981 17.321 18.017 RB,SH$C FINC,SHSC CI.SHSC t. 0,643 7.I77 4.228 3.758 4.541 5.769 ~.,297 ~ 3~' ,~,.a17 ' 370 5.2~,9 5.273 9,a01 2~961 7,115 6.664 ;724 ~.0~70 ."7o5 ~' ~ · ,116 3.02t 3.24'8 3,229 3. 020 t~,28b t~,199 1~,879 9,823 "~48 . ,047 ~186 5,568 5 482 5,056 b,202 ,~.8~ 10.943 2,738 8.630 4.547 6 496 5:731 '1,122 l'.. ~04 1~,'~51 ~. 455 8.017 6,192 6 , 343 ~ i96 , 872 7,384 0.045 15.537 16.J6~ 1~.578 6,533 5,b77 ~,686 .991 10. 549 9 ~015 .44? 4,2~8 3.9{)4 4,166 4. 424 16.220 16,189 15,633 15.52~ ~6,397 15.438 13;887 12,213 9.488 4.806 15.518 16.468 24,524 81,373 7,883 SChlUmberger AlasKa Computing Center na3A. 5NSC 14.505 15.451 16,538 i7.220 DB4.S...SC ,~2,67 12 404 7~23 5.892 4,769 7,450 D~4A. 5H$C 12~110 11,717 4;10.4 3,413 9~'161 10,90] PEr. SHSC P I A Z , H St, DEV~ * SHSC C~ ~S~SC . ,353 16,406 !.844 5,162_ 0,962 SDE¥.SHSC 210,928 GNOR,SM$C 8.419 ** DEPT[{ = 4599.958 FEET i5,108 ~AZI.oHoC 01.0.'00 FN ~i, SB1 ,SHSC 406 I ?. 623 12-. 794 13. 001 1~,i85 13,269 I~,2.20 1.2,963 ,834 i2;B30 12,824 i. 2.R48 PBIA,$H6C 13,687 ~I3.223 12;038 ,..2~.,1.77 11,921 lt.828 12,784 12.45~ 744 1!, 768 17.395 16,356 SB2.GH$C 944 4.572 7.079 1.78,871 0~571 0.000 13.072 12.927 1.2, ~0'?0 12, 60 12,724 12.839 12,~65 12.814 12,5~9 !2,171 Ii,928 11,44! 1-0,857 10,524 !0~45I 1 0~738 1i'010 11.233 ' '7 ' !54 .4; 1 ~0 14; 056 .1.3 ~ 82§ 865 ~,4. 327 15; !67 1-5 ~ 849 !2,1~0 12,242 12,3!0 12.332 1.2,820 i3.I18 1~,218 12.995 12.494 ~.2,593 12;678 12,868 14,..324 1~ 380 13,257 t3,470 12, 60 1~.869 13'514 13'598 13,45_.8 I .~,443 i~,~!~ 181,919 10.0~ ,418 ,582 .642 12,428 12,754 I13,401 ,912 13.290 11.181 16.921 14,863 9.328 3.257 3.959 9,972 RB.SH$C FINC,SHSC CI.SHSC 31,158 81.493 8.657 13,157 12.852 12.025 11.997 12.426 10.281 14,100 13,722 12.580 12.477 12,948 11.894 13,378 10,578 .114 . :. "' · 1.1*80.2. i!,969 I1,9t6 12;087 I2,265 ' ~ 881 13, I. 1 t 1 ~, 046 ,6~'5 Y'i'~ ~95 i~. 227 · .- tl,392 · 11,427 17~,247 .569 o'ooo 9"00I 9; 0i6 ' ' " 6'088 16 ~ 696 14,760 · 1~,413 16;599 I5;748 14"5a7 12,9I~ · . . · ~ - ' .-: 437 !.1,601 13.898 17,146 I, 864 .064 13,621 15.548 11,670 11,795 12 848 11:350 FINC,$MSC CI,$HSC 9,142 9,081 14.224 16,964 11 787 14~798 429 -14,472 14 13! 13.781 13.745 ,.o · 4'9013..094 594 12.342 1~,016 ~679 92594 ~.853 10,,064:10,064 585 '968 15.52a 15.430 15.149 1~,998 13"897 13,422 1].730 33,603 81,439 8,528 13',201 12,924 12,688 10,694 I0;051 9.603 -Sc'hIumberg r AlasKa Computlnq Cente~ 9,407 9.560 9,709 9.927 10 ~,.02 l'[ 439 1,],059 1~671 Ji,745 l'[,i50 D84. 5.31 13,189 t2'393 12 556 12, 10,829 10,960 DB4A,$HSC !3,790 1].066 11,945 10,802 1.9'4325 10,387 !2'203 t:4,733 .408 it,469 i3.749 13.054 ~,vo9 9.1o7 ,556 8,014 12,715 I2'845 RE.V,SHSC 1,019 P.1AZ.$HSC 185.297 GNO OEV'[ SHSC 12,431 EV,SHSC DEPTH = 4]99 ~58 FEET SBt. $H8C D}31A,S~SC Dt~2A.MHSC 10,608 1~,625 9,536 .366 12,154 12,882 9,074 8.739 9,426 9.217 10.874 l.!..570 , 255 8,82~ ; 790 I0" 278 12~686 12.459 ,99'9 FNOR; aP. SC 1,019 _ EIb, S[ Mt~ 02 ' !3,689 14,32 8,592 8 884 i~,965 01 .70 ,936 8.417 9,059 ~,447 ~377 g,316 9;464 .655 10,971 11.614 11'979 12'135 14,723 15.814 11,727 12,03~ 12,4.33 11.53 9,993 10,202 10,592 I0~619 :10,485 tl,746 15,171 13,604 10~984 I01536 10288 10,213 1029_4 9~56~ · · f 12 ;560 13,14,)  3,396 2,764 I0,299 t5,770 17~,163 ,572 0,000 105 lo°':s.9 9.250 9,248 9,656 9,894 12,240 13.815 ~2.407 12. O1 !2,061 .1~873 1t, 83 It. 13,319 12,410 9.813 15.926 7,709 12,205 RB,SHSC Ci,SHSC 9779 11:367 9.511 10,036 9,496 10.407 11.665 13,340 10,322 9,705 12,737 12,102 6,948 81,209 8.673 AlasKa Compu.tinq CeDter E{,634 8,571 a.493 8,533 8,708 8.83.~ ~9,039 9 017 ~.510 g,64 ,875 ~'.094.. _ 555 1:~ 558 1.'1. 095 17 684 ~o,~31 ~:9o~ ,432 :333 5'30 18. 8512 1-9.,421 19. 816 ~E V, ~)tSC DB:VI, ~tSC c~,i~is~ ,..89 1~4 ,i18 ,t~ '878 .715 . .495 7,8~2 8,598 8,998 9,235 1.217 SDEV,SH5C 203,235 GNOR.8i-)SC 12,120 ~V,SHSC 8'645 DEPTH : 4~99.95@ FEET 9,056 ~i2~1.6 14.670 ~ 7 15 034 SBi.$HSC 12,848 !i000 FNOR,S~SC 1,217 8,729 .912 t3;301 i],867 15~U~9 t6,3,35 !2.a21 11 856 11.51 !} 1'l 401 19,'168 9 346 8,523 __7,897 7 , 000 6 ~ 938 6. 957 -/. O00 US2A.SNSC 17.246 17.]22 1b,962 16.7~0 16,271 16', 33 16,075 16.119 t6,671 16,978 17,214 17,432 SB2.SI-.{SC ~3.608 I3.107 12.535 I~.480 14,005 13.7_93 13.294 il2.597 ,I.5~7 1.1 448 ,1.443 11.590 12.442 12.790 3, 139 i2,912 11~,643 · . 11.7'70 57 II:736 12.897 1.2'282 12.485 I . 8.597 8.890 5,18b 0.0]2 17.864 21.890 34 _. 575 0 000 221 !1,183 7.458 6,266 !2.916 395 ~962 13,2.t3 12 304 !1,32~ ig,34~ 9,745 9i890 18:004 9;9~2. , 72 8.630 8.660 12,937 13,080 21,917 21,506 8,070 7.491 RB SHSC FINC:SHSC CI,SHSC 10 292 14:448 10.748 7,187 16 34q 161457 13,504 I1,800 11,858 12,132 13.748 9.765 25 327 8,829 ', lumberoer AlasKa ComputlnQ Center 12 955 12.g3~ 13,049 13.139 131443 13'46_~ 13,510 13,620 13,935 13.980 13'833 13,58t :} i.t 3 a . SHSC D84.SHSC REV,SHSC P .AZ.SH$C PEV I .~HSC C2-~NSC 10.0~0 t0,246 t0,457 10.639_ ~,184 l~.31g 11,508 1,!,693 _ .,,122 1 .208 12;3!0 1.2.454 ~3,374 t~,07g 14,~96 1~,675 13,533 1 13,412 11,804 I0~319 t0,943 ~2,155 ~3.51g 14.523 14,616 I3,69~ 13,755 13'886 1~,075 14~633 14,555 I3.809 12,83~ 1,254 SDEV.SHSC 196,569 GNOR,SM$C I2,038 EV.SNSC 8,881 ** L)BPTH m 4199.958 F~ET SBI.SHSC DBI.SHSC 9BIA.SgSC DS2,,S.~SC DB2A.SHSC s82.S~SC 2-54 5,635 5.498 5.4'92 5.563 ~87 ,466 806 6:00 ,373 6,200 6;.18.3 6,666 6;6il : 28% 745 !0.906 !1,871 14,568 14.704 14.324 14,323 176,386 §,575 .OOO 5.529 5,758 k,71 , 09 13.393 13,845 11.076 12.010 14,~20 14. 57 13.g62 14,514 RBoSH$C FINC SHSC Cl:SHSC 5.224 5,789 6 0O9 5,989 5.959 5.BIO 5,602 5,44.3 5.328 6,087 6.195 6' 5' ,136 .976 ~,957 .837 ,617 5 25g ~,024 ,9681 4,237 4. 134 4,t51 4,358 6,171 6 249 6.217 6.096 5,895 b.136 19,711 81,46~ 9,832 4,999 4,506 5,67g 5,072 6.445 6.490 ~,tt47 ~,3149 6,114 5,858 5;582 5,29~ ,960 ,72 4.537 4.407 Schlumberger AlasKa ¢omPu~.~Center 4.323 4,273 4.251 ~,34i ],672 ,706 .,7i5 3,592 3.429 3,123 2,904 5;524 5;550 3,424 -3;517 4,714 4.349 4 145 4. 165 ,811 604 ,668 959 ~ 929 · 894 ., 864 5, 742 5,42.4 5,333 5, 5.486 ~.700 ' ,091 995 3.80! DEPTH = 40 g ...... 99.~58 FEEI ~V.SHSC P!AZ,SHSC DEvIiSHSC C2.SHSC 18 750 2 076 8 314 20 353 21 074 18 538 SB! .$HSC DB2,SHSC !.8.819 18,919 23'067 23.054 20,105 19.842 5.863 6 131 t ,e66 3.61 I2.884 HAZI.$HSC ,998 FNOR,S~SC 22,066 22 960 19:,B24 18~809 18.694 18,880 DB2A.SgSC 19.5445 20,66~ 22,6~ 2~ ~ 94 ~9,753 19.570 21,534 z 372 20,9B9 2'0.691 19,92'1 19,~67 1B,472 1-8,0874 17,§94 171 26 18.024 18.42 9.o4o o:ss8 19,313 19;260 19.300 10.129 19,818 19,496 18'665 17~814 19,)16 t9,669 20,259 ~"9;99~ 19,~36 1:9,779 19,394 I9,780 19,414 19,49~ !7.55I IR~OI 2,873 4,293 O0 6.402 4,520 183 t78 .000 22,957 18,156 1 O0 20,612 18,008 20,130 19.631 20.034 19,701 3.088 4.098 4 448 4:g12 6 290 6:055 6 564 4:221 RB.SHSC FINC,SH$C CI,SHSC 22.635 !8.109 22.637 20.50! 20,403 17,984 20.484 19.411 20.058 19,453 185.510 80,448 8,6~0 S82. SHSC 18 .1..7 DB3 · SHSC 785 18 472 699 18:770 931 ~7.73E .f~.30 1~, 40-! 4'61 17.433 18.294 18.160  8.86! I~,740 20,~14- 2~,028 20,630 9'285 18,778 18;353 17;934 17,542 27;557 17,674 - :171594 L7,615 DB3A,SHS'C 18.663 19.732 9,:022 !8,71~ 6;250 t6~24 20,559 20.658 20,148 18;50.0_ i?$,080 17,414 I6;533 16.727 DB4.$H$C 9,461 I9 010 1;9,027 19,549 O, 392 20:302 19; 393 18. 782 18. 108 18.486 19i221 DB4A.SHSC 20.567 20.642 .555 !9;02 ~EV,SHSC SH$C C?~S 'SC 0.803 SDFV.S}~SC ,039 8.544 ** DEPT~ = 3999.958 FEET 2o,4'4 2O.o5s .702 ,999 ~ -FNOR~,~MSC ,803' EI~,SH$C 19.778 20,995 I83.!74 000 SB1,SHSC $Bi ,SH'SC 19.849 0,504 i;!8. i .0,466 4.0~8 2.3,040 19.830 ~9o~73 19.995 20.~58 ~{0,608 20,090 20,832 20,950 13 108 16,719 20,412 2~,477 24~074 23,964 23~874 ~,645 2~ 064 21,617 2~,582 :z,: ~B1A.'SHSC 12.833 13.704 14,882 15,962 16,057 14,685 13,96! 13'~62 1;3~464 13,093 12.653 i2.629 12~'29~ 11;677 082. 1i,965 12,164 14.253 626 9. 906 98 13 ~ 295 13,556 I3. 405 14,035 13, t>94 13.573 OB2A,SHSC i5,316 t7,472 16,313 16,068 15.532 18.577 18.054 2~,001 I .420 19 569 16:565 20,088 18.129 19,684 20,221 RB,SHSC FINC,$H$C C1,SHSC 20,342 21,069 23.746 23.376 15.637 12,715 10,788 13.853 I6.623 t7,100 17.465 16,290 16.276 16,340 132,827 84-,293 ,582 !'-? ~'I IHill eI:-] {[: [:-]~ - Scbl. um~etger ^lasKa Computing Center ~V DEVI C? SB2.S~SC i)B3,SNSC DB4.$H$C 1.4.6i7 15~675 4,165 11,630 141377 '7' 2,539 4,737 10.471 tl , 966 i. 3'260 DB4A,$N8C 16 15 ,6t8 ,672 8t7 i4 613 1I. 763 15 6.764 995 g,620 6.334 10.706 t2.242 13,446 7,506 .6;495 15,77-2 ,SMSC 0,789 SDE~,MRSC oF$C iS~SC 274;716 g~O~;e' 8M$C I ~274 'KV,SM$C ** DEPTH = 3899.958 FEET 14,310 14 052 13;'457 I:4:97~ 14,928 1~,697 I5. soo i5:804 1'0.224 10.863 t~,690 13,163 1'5.972 DBi.SHSC DB2A,SHSC  , 853 ~ . 365 848.30 i0.807 10 963 I1,306 12;~.36- ~,621 13,6~7 i3;87~ 7,344 17, 6;304 16.197 6' ' 15,714 i5, 32 12.997 1.000 ' 0,7.89. ELi, 16,861 16,8~4 1.6,~95 16,941 7,237 I7,324 I7~378 17,343 16,483 15,943 15,225 14,364 19. 786 20,055 20. 229 20,247 19,463 19,12t IB,783 1:8;376. 17.088 16;645 I6'I98 I5.92 14,169 14,429 14,450 14; 164 ,789 ;134 16,182 6,46 11,528 12,796 15.960 13,z.2 I6,4t2 17.74~ 7,22 16,939 t6.071  0~1 18 .. .575 0.000 18 033 16.476 i6,531. 12,044: 1:3. !55 16 ~291 I'6,178 17,770 17 , 820 ~6.907 i6,798 ]6 98 20,i26 !7'979 15,020 i4,031 15.985 14,594 17 I6:761 12 217 16~084 11,283 13,753 2,162 3,583 710 12:992 16 808 15:929 RB,SHSC FINC,SHSC CI.SHSC !7,131 16.885 19.843 17.5~6 14 951 13~911 14,669 16,014 17,698 16,855 92, 24 "-Schi~mberger Alas'Ka Computln.. Center. I7.004 17.10l !7.165 17.!_£1 ~3,263 ~I.032 9,b85 9.449 .2,205 .036 t3,~!2 i3;68,1. 14.036 14.152 14,067 13,887 15,718 15,475 I5,315 15.286 ~4!5'009. 643 14 i41687860 14'763 I4.60i' I4.66314;573 DB3A,6~6C 13~.952 13;643 ~,615 t3,613 13.566 ~10 t3.7~2 13'613 13~62R 1.3, . 13,~.96 13,44t 13.120 13,212 13 359 13.4~3 326 I ~. 312 I-3~43l 1:3 '483 13,551 1..~474 !3,391 DB4A.S~$C 2. 47 12.503 13.057 13.315 27~.~36 .977 GNO. DRPTN = 3799.95G FEET 12,t66 12,218 12;565 I'2;59~ 13;~38 '13'49o ..,000 ~NOR.S~SC 3; 63:6 E~, SHSC SB1.S~SC DDI.S}ISC 16,2475 1~ 41~ lb,Tll 1:7,t74 17, 10 I :30 17,4:08 17;819 17.453 t5. 954 13; 390 10,695 179 17.612 1.9,$57 19.7~5 !7,~_7 17;7~o 65 15.242 14,614 i~,"~4432 t3.411 13,517 12,331 12.677 180 383 0:574 0,000 IG.068 19.718 16,957 17.110 t7.211 I7.275 18,620 18,982 t8'~33 18.548 1.8.157 I7.987 I7~58! 17~374. 17,491 18,197 11 357 13~875 15.155 14.599 13 693 13~634 13.368 13.564 12,400 12.864 RB SH8 CI,SH$C 17 703 18~1.96 1~,524 19.486 17 245 1~244 18.004 1~.230 92,667 81,518 8,783 J- ~'SchlUmbe'rger Afask:a Computing Center PB2A.6N~C 1.1,631 I t.947 1~6, ~77 18 048 1~,~73 i~9,8~1 ~9~763 18:94! 14.165 20.262 14,05 t 1~4.9 ~, 7 I.'9; 544 19,4C O 20, 2{56: 20,761 .279 D83.S}{SC 16.042 i6. ~.~z2 15.973 15.986 16 369 I~,659 18,227 I~,729 I~8,608 17,202 . .561 12.72'~ ,95~ I5,086 DB3A.S~SC 1~ ,589 !6,7 33 16, '17--~ 17,076 i7,~64 .17' 1.6,675 - I6.153 · 15,9:67 16,7_ ! 3 i7 ' 4'68 16,042  6,750 7,328 14.464 14 435 14,512 !4,57~ 14,827 14~835 14~872 t~,897 14.774 I~.57'8 14,~15 1~.400 ~4.635 14,898 DB4A.$N$C 13,959 13. 990 14,06'5 i4, ! 13 SDE DFPT~: = 3699.958 FEET t4,118 14'43~3 18~,964 ,580 0,000 SBI ~3,,- ,.~73 8 848 9,514 9,' 2 8,888 8,845 ~ '639 ;750 ~, ' 8 8,139 ,032 8;439 8.887 ,847 ;467 PP 1. $.~,.~$C 8.308 8..351 8-380 8.354 ~:~ ~.:137 98,~50 ~, 397 .., 4.8 , . 0'0 8.311 8,596 DB1A,$~SC ,345 r .4.53 9'449 9,2t8 9,..~27 , lz2 8.9 ~ 9 .!,~ 9,23 9,640 DB2. $~-~8C 9.3'73 I0. 029 9,586 8,656 7.315 ,166 ,2'2. , 7,031 7.392 ,232 ,463 15.453 20.309 17 953 191353 16 932 1 105 14.738 14,898 14.164 14,412 RB.SHSC FINC.$HSC Ci,$HSC 8,879 8.266 8,911 9 171 9:200 6 594 7~711 8.850 Schlumberger 'AlasKa Computing CeDter - DB2A,SHSC 76,~49 7!763 ~,790 · ,266 6 8,29 ,424 ~.9~ ~,852 ~ 971 9,U46 ~- 9,095 DB3A.SgSC REV, SHSC P:tA~Z SHSC , SHSC 7.771 7.715 7.667 7.~9~ 8,0.1. 5 8. 290 8,556 12 9.769 I0,~18 ..10:6'8(' I~:8276 12,185 1~.~56 12,~52 !2,822 13.899 !4.162 15,!65 15-359 !.6,010 ~2,353 12,006 10 422 I1 5 '2 10 909 10.614 ].667 1,724 8.26~ SDEV,SH$C 5.921 GNOR,~ 13~527 9.951 ** DEPTh = 3599,958 FEET S~ 1. SHSC DBI.6HSC D~;2.5HSC ~0.530 10.253 12,793 12,443 ~2~39 !2~645 13,671 ~3,746 12,257 11,993 383 1 0,949 14,4!5 549 15 , 715 .!6~173 t6.~45 12,104 12,568 15.7!6 15,90o 6 ~ !..,420 16,463 lO 11 :I2 8 o 3 I:'l, 012 552 ~3 14,814 HAZI.SWSC 999 3, (~5.6 ~3. 295 ~:11290 11~846 12 587 I3.301 .13.304 I3.I37 , - !1.987 ]! 022 1~,i63 1'0,156 7.516 7,935 I4.844 15,828 II,231 I0,b96 177.37I 0 58,3 o1 oo 12.602 12,315 12, 905 21131 12.968 10,682 5,849 8.659 7.454 8.172 9,417 11,901. 15.008 15.927 1~.402 16.~18 10.469 RB.SHSC ~INC,$H~C C1.SHSC 12 944 i2:805 12,550 11.892 188.269 80,898 11,.762 12.756 12.320 I--$cblUfftberoer.. .. hi. ....aska Comptltt~q. Center 9,192 g, ~2o ! O, go8 I J. 027 17,877 ~7.620 lt~.998 1.7.042 l.Z", 373 1.2. I i~6 10,938" !.0,737 ! 0,948 l 1,1 96 DB3~.$D~C 379 i 7,177 06I - 1 ~, 093 15,514 I5.232 509 13,2-2 I.)B4a.S~SC S 1i,333 11.297 1i,242 t1,179 , 266 t0,012 10 709 10,561 9~789 9,900 ~ 0.403 IO. 356 %,322 SDE¥,RH~C !3'942 ~ c' ,'~'~ 3499,958 FEEY 10,386 !0,450 228 l~,OB2 1'~,37t,. . ,357 .322 EI-,8~SC DBI,$H$C g,307 · ,996 I4.830 13,01.1 I 1 300 10:481 11,160 !0.709 10,546 9,870 178,690 0,583 0,000 18.093 16.982 14,476 12,969 11,1.22 lO.686 11 ,068 1(>,,701 10.823 9,741 10.514 9.7q0 RB,$H$C FINC,$HSC CI.SH$C 14.i.!1. 1.3.961 ~3.1~56 1.3.966 14.432 14.791 1~,8 ~9 I 14,710 14,887 14,964 15.0!5 !5,119 1.5,z83 15~293 i4,09a ' 1 853 11,555 I1 ~t~a 11,570 11,75I 11;799 !~ ;- ~'~ ..- 8~: 111,~74s ti;692 12,413 13. O18 13,~40 14. 178 ~5.257 9,430 11 862 1.5.114 9,680 166,744 80,986 10,320 oI~$C .. P,b 3/~, SHSC DB~A.SH$C PI'AZ,SHSC DFV'!,S}i~C !2.109 .1. 2.1.. J2 ' "' } I"' 14 066 i.O. 1i 12 1.0. 956 .!i~ I1, ii , 453 -<3 !1 .009 10, ... 1i,~30 11,84 I2,943 1'2. 522 1!"935 .: 12,,060 10.966 !0.854 11,450 1'1.939 J.~,620 1i i31 t0,7:65 10;419 i0.500 IO,~a4 iI1410 , . 11.~3( ~.1.943 12,111 12-270 13 659 ~3.667 1~,497 I3,2,.0 024 1 90O ~. , 98O 12,676 13,204 12,032 13,:~7.0 13,769 !__, 991. .1.2,091 .I 2,303 ?.2,3g9 2 12'35~ 12,639 12; ~70 I9.99. 1.245 SDEV.S~SC 341,361 GNOR, 14,6!7 8,590 DEPTH = 3399.958 FEET SBI.SESC 439 }]AZ'/, SHSC .,000 245 " EI",SHSC 16,408 15.990 .~.5 005 i5,.. 72 I04 .719 DBIa., SHSC I~,2. 2 14 742 1.46 16~.054 19.0.15 ~6,195 ]7.277 !7.760 19.370 17,230 ~7,778 1.4 7 20 23 !6, 20,353 ~B,~08 20'0~5 10,944 1 i 956 12,223 t0. ,940 J2.702 12,305 i, OJ. 5 ~917 I2,41.7 Ii,724 17~!170000581 14,797 11,952 4.366 17.o00 t7.,72~ 11.147 10,933 11,254 11,775 12,091 10,464 12.862 11.830 12.347 12,335 11,994 12.214 12.329 12,006 RB.SHSC FXNC,SHSC CI,SH$C 13.783 10,670 17 740 14:171 16,547 17.171 162,795 80,~47 g, 57 I. SCblU.· mbel'Cler_ AlasKa ComPu%inq Center SB2, DB3. SPSC DF 4. SH$C P]AZ.$HSC C2. ,523 ~ 2.072 13,217 i3.202 19. 884 19. 947 20.133 19.  2~4 13 .52 12,433 15, !ii '~5 2~279 10,362 J2,515 13,669 13,973 13,220 13.27~ J3,404 I3.5&4 12,737 ~2,05q 11,297 10,81! . 41I 3 144 7.580 5 780 3, . . 7,400 8-004 ~,771 ~ 614: 9,833 g: 78~ ,, ' 952 ~,964 7.18~ 7 gl~ .7,546 ..096 10.13 ~i'553, 12,49g. 13,744 i3,357 i2,788 11,913 390 11,399 1.4,033 ] _ 2 . 8 O4 I3 415 799 2 155 !9.390 1~'; 628 15.307 442 13 ,. 14' 2O5 Iz,u 7 11,565 10,669 lO,lj.~ 350, 85 CNOR,SHSC .000 ~ 5,165 Eli,SHSC t ,484 a,70~ ** DEPTf; = 3299.95fl FEET F!, 11,6oo 1o.}o4 9,~18 1.o.,IVS ] 3. ~. 3 ~ 2.981 12,668 I2,007 D~I.Si.~SC Dt~IA. SHSC 10.250 1'2...113 13.363 1.4.370 241 15 665 1.4,~99 I~, 73.~ 1.6, 1.5,!.07 14~g83 .~.5.5'00 .. ,50 ,926 18.749 11.850 13 743 13~467 4.282 10,331 7.761 13.295 9.766 11,034 14,405 I~,299 17~,781 .579 0,000 1 - 042 15.372 15,304 12 486 1.1:669 17.100 11.527 13 418 13~217 6. 421 I 0. 387 8 299 131762 9.025 13,110 806 13~786 FINC,SHSC CI.SHSC 12,877 13.463 16.1.47 15,522 171,924 80,696 9,166 14,270 ~a ~14 15,]~72 I5.5~0 I5.82b 15 909 55 ~b~2~i 15.633 t4,66{) 13~26 12 383 12:9!7 I,,506 ..233 10,346 9.822 ~ 9;'I 8...2 B"597 .--,5 4 15.636 16,460 11. 50 12.368 13,298 12,204 12,284 12,125 9,762 10 836 8:842 15.574 16,768 15,125 15,664 FINC,SHSC CI,SHSC 80, 8,714 7,390 7 151 11:746 7,182 19,325 ~.872 31,735 · DB2,SB$C: ' 13,331 I3,,358:1,3 :8::~. <?; :1~2,~7'54 -}2,326 .... 11;735 1i"684 1:1;'804 fl;791 ~[I,3~2~. ' _ : ' 10~.344 I0~406 1.0:~951 -. - t~1,460 -' 12;'80~ j'3~ 01 i3";-5t4'~' .... '108 9,944 37,008 11,892 10,767 15 874 12:636 12 59 I4,207 9,430 ;:' -', :' DS3A."S[i'$C 14,975 18'051;~ ~-; ' 8~113' 9, ~23 ~ I1 ~4'8i'~ 15 ~4 ~6;610 -~' :; ' ~ DP4,S~SC' ~ '14,567 ~ : ]3,840 ~ '~ ~ 13.;~::4';..1 ~'y::~ ';<' ':": ?--13,655 ;'~ : '14,224 ~.:. ::."..::, .: : i4,8tl '-14-548 : :$~$:'?6~ -' 14,218 ':-' I5;07~ i5;093 : ,:'::-" ::DB4A, SHSC:: I0,'67-~ :. '~ 1'2;935 14;033 1'4;:'.:55 ' i~-;283 ";2q6 13,592 6,965 9 584 16:640 I4 878 14:672 1i,757 15,376 RB,SHSC FINC,$HSC CI,SHSC 346,683 80,952 9,042 ' * b ' obi <. _:--_ SB:-I.,S~SC' 1-0-913 : 11-237 '1 ~,'45~: I'8;~8 ~'7';:569 i6;673 i5.506 ; :::< : : ' .13,::011 I2'.951 - 1:2,!18 .. : 12,.170 18 635 14:535 10 530 18:311 L. IIIII I 11,b78 1!. t -~720 ' !$'~ ~.1.8:.~ ? . ;242 11,418 11;630 i'~'i~, 726 '.'~ : - [- 9.543 £~.g70 I~70 ~799 Il,1 99 .863 9,622 10,9, 2 ,85O 7,,527 ~7.249 10,458 ,461 9.999 11,689 8 04 15 403 111716 11,592 13.424 .942 11,474 10,301 7,102 9,,307 ,88i ~,635 ~2.299 '324 ',899 1.2, i 50 9,453- I75,514 ,575 ,000 .816 ?2,263 , 055 15,272 ,'943 , ~ ' 5' 5' GiiO~ $~C ii OGt FNO'R- .;: .:: _ '-C-2',..SHSC' - 9 ~ 195 ~ : : : .,: .- : 20,712 15,448 RB.$HSC f'INC.$H$C C1.8HSC · :f~. 067 10,929 1:t ,841 , ,. 12,679 12,699 802 I1,584 11,442 ~59~ I0'271 10,009 412 11,777 14,854 I3.686 047 12,413 11,712 15,079 13,438 13,015 0,6 84 0.733 11,607 IO,13B I$,61 19 794 t8:418 I75,q13  ,575 ,000 13 056 13:252 10.717 10.557 11.570 9,706 19,375 18.359 19,654 17,936 RB,SH$C C1 HSC 76,041 8t,848 .489 1'5,334 14'503 . j<. ::.i:- ..i!,i.- :.: . ~ :. :: ::>. -. ::::.->: :' .: .:::: :-:: ,: :-: .. :- . > :' ::, 16:7994 11- 07 ,471 .73B 90' ~ :' DB~A,S~SC 20,674 18,368 ' -' 20 ~969 18,-7'55 14 _ - ~ lt,535 12-929 18 694 1~ 503 ,~ ~ DB2A, 5H.~C- 16~953 1~,:677 ' 14; 35~ 13; :-~:::- --~7;084 ~3,727 26,355 3~'~96 - ~2.297 ;7,'~7~ ' 37 ~.~= : ~ ' ' '67'I29' 72'1~2 77 18,015 22 66; 0 09 :<-: · . _ · ; .' : :. '~' ': DB.4:, SM'SC 46 ,lO? 45,702 ~: 44;134 43.737 43 i 7.982 i5'~34 I5 ,SHat ~HSC ,-,.~>- : ** DEPTH.~ 2799,958 FEET . .653 20'5 42-3 ;so5 42~ BOO::- -:.~6,60 7 ~:200' ,::2-9 9:8~2' 214 I44 ~8,877 ~776' ;'6'I~0 ~:3.453 925 < ~:5,76I 'B65 ~5.57 O ;S24 t:~6'; 221 ;'943- : ~I:~; S~SC 14,010 16,378 ,428 15,663 I4,746 ~:.~6 '678: 16,486 ~"6:<"' ;'6'05' 18,372 26.27I 37,174 18,160 53;442 38,683 '81,415 44,990 43.471 16,083 t5,o9o t78.036 ,58! .000 13,398 20.880 20,591 14 054 15:428 15 26,870 38,071 19,284 61.803 48 187 85:269 44,620 43.595 I5.859 14.833 RB 8H8C FINC:SHSC C1.8H$C 181,789 80,~80 9, 27 12 163 !2,284 I'2. 455 090 13.357 .. _501 12.703 14,041 12 942 13~813 14 992 16,428 16,404 16,327 16,296 7.419 9.072 692 3O6 10,753 10.887 8.605 ~,456 7.986 8,461 9,58.3 I0;038 8.238 8.612 9,876 10.040 8.025 8,207 ,2 58 ~,366 579 0,000 257 8:144 8,292 8.362 ~B,SHSC FINC.SH$C CI'.$HSC 172,363 80,681 10.397 . 88 O63 21.144 . .2,434 577 777 21 348 22;580 2 93 ,288 13. 173 12 910 445 12.462 12:435 362 259 031 ,362 354 9 .., 380 !73 9,216 959 ,68~ '9I [ 3,355 1.734 9.263 9.214 9,532 8,908 650 9,433 9 371 2~7 9.154 9:014 619 14,603 375 13.174 165 855 14,948 740 14~654 6O] '$HSC 0,578 SHSC o.o00 14 388 12:824 14,920 14.493 RB,$HSC f'INC,$HSC Ci.SHSC 151.714 80.~67 10. 36' 12~09i 12 68? 13~143 378 14.131 g, 34 , 09 12,952 14.257 12 40 ~1.380 $7.769 9,652 12;641 12 864 13:471 8 793 9:617 13 096 14~214 12,J80 17, 74 21 067 16:777 ,83b .g28 I:2.010 13~072 18 247 18;996 12,158 13,104 10,441 II,519 RB.$HSC FINC,SHSC 5,329 82.355 0.000 C1,SH~C 10,3R9 DEFI F~~ F~Z~ API 8ERIAb NUMBER COMPANY NAME  ELL NAME IESD NAME STATE OR PROVINCE COUNTY COUNTRY ~?I0' SECTION TOWNSHIP · _ iii~ ~-:~' DEF'! :~:'T~ ': ' ' ':' ZOTZ::gY:~ FOX':-:'~ : ~ITNES$'$ NAME ~AXIM..UM RECORDED TESPERATURE ~ DATE M~NTH DAT~ - RUNN UMMEE LOG PARAMETER~ TO BE RECORDED . ' ~ -~ .~ , . - : . . : .... _ . _ . ~. . . . .. - .-..-~ · DEFI 'MD'EC DEG - .. . ~ MAGNETIC DECLINATION MTRATIGRAPHIC HIGH REMObUTION FAST CHANNEb DEPTH DEFINITION · ': ..80~:~' ~N.-. : - : .~..,, ~ .. ; STAND'Of'F OF THE TOOL STRING -' - '. :L':: · ' ' : : :: - ~.:_ :~ '--T~BI.,E .TYPE , CURV : . -::::::- -_ DEFI : , .: : : · ' : : · . . -:., : . :- ~-:~:~BP'T · DBPTH 'CHANNEb NANE - GD GAMMA RAY ' · :.. .: _ - . . - · .. . . ~ ' _ :J _ : : ~:: . .; ~ ~ . ' : . _ - . :-_ 1 66 u -. :. . ~...-_ -: - _: : :.:: ::: ..: ~:: U ':'~- : 4 .. : _. ::':' :~: ~: ~.: : . , : : :- : :: ~ : :: . · ~ · : : . · _ :):_ .; :.: .~:'..;. :~ .:::.-:f-:¥:r:-:> -~ ~::::.: :: '-:- _ _ : ? · . . S~I. CE: Nh~E . G~OLIS ~RZ~IN , FDIC ~EL NA~E : 73443 NTiNUATION ~ : 0i PEViO~S REEL : COMMENT . RESOLT,CONOCO NILNE P6II~7 UN.I:T' G-t,50 .029-21927 **** TAPE HEADER DATE : 89/08/28 O~ I(; I ~ : FDIC TAPF NA~E ~ 73443 CONTINUATION ~ : PREVIOUS TAPE CO~:~ENT · 3 , 7 443 **** FILE ~EADER **** FI-LE:/NA~E ~ SMDT ,001 SERVICE ' GEOL!S . 002~04 D~TF : 89/08/~8 AXRC "IZE ~ ILF TYP~ IF~24 LA!ST' FILE : ~S D,MSDOUT.O01 ***************************************************-**************************** ,:, : ** SCMLUMBERGE~ ~MLL SERVICES * ************************************************************************************ ************************************************************************************** O~CO INC. COMPANY NAME: C'N ....... -'WFLL. ~ILNE POINT UNIT ~. ELD~ MILNE POINT S~UOH: NORT~ SLOPE 6,,ATE. Ab.A~K~ A.rI NU~BER: 50-029"21927 LOCATION: 3644' FNL, & 3346" FEL 6ECTION~ 27 TOWNS'MIPI RANGE PRRN. ANEN~i DATU~ ~,SL _ ELgYA!ION.: ~' " " G~' LOG 'MEA~URED'FRON RMB 59.3' ~BOVF,. PgRM-AN~!,;T DATU~ o CORRECTED FOR 31 ~GNETIC DECLINATION- . . : . .: 00I CONTAINS 4' X 2' X 30 5~SD :'DATA'OF FIELD BLUELINE FILE ~736 ~0 3491- - '00~ CO~TAINS £~A~!~A RAY 'DATA OF Fi[~LD BLUEL!NE FII, E #40 FRO~. D BLUELINE FILE #44 (MAIN ~G) ~RO~ 41~6: iT[ 2625 - 5,)FII,ESHDT'O04 CONTAINS GAMMA RAY ~ATA OF FIEIi[)BI;UEI,INK FILE #44 (~AIN -: FROM 4736~ ~O 26~5.~ ~ ' ' LOG) DEFI ~'F£:" ~' ~ ' 3644~-; ~':::'"~:~'~'NL & :~':' 3346~"'~:' -~ ~'"';~;~':~,L FIELD~ h OC AT COMPANY NAME  ES~ NAME iELD NA~E MT ~fE, O~ PROVINCE COUNTY' NATION SECTION TOWNSHIP - ~ ~ - . - . :. .~-.~ - ~ · NAXI~U~ RECORDED TEMPERATURE  ATE - MONTH ATE - DAY  ATE - ~'EAR UN NUMBER , · ~ ~OG PARAMETER~ TO B~ RECORDED · : - ~. 2. ~ . . . -:.- , > ~'~ ' .- ~ TU~I ~ ~ . - .¥ALO~.~~ ~: ~-- DEFI ~A~NETIC DECLINATION TRATIGRAP~IC HIGH RESOLUTION FAST CHANNEb DEPTB DEFINITION STAND-OFF ~F THE TOOL STRING · .. ~, -~ ~ -~ .~ . , AZI~. AZI~biH 0t' IFAD 1 R8 RELA~.~¥E .BEARING C'] CALIPER ] ' 3 LO COMBI~E~ uL Abl. Ti o12 SbDT DI SPL~CE~;EN~ $4A1: 8~DT DI&Pb/~CE~ENT 4A - SI3~ S[~DT DISPLACEb~EN~: J - 3A 0C 6PEL[ CO~ECTION R~D~ F~ADIUS 1 ~AD2 ~ADIU~ 2 F:AD3 RADIUS 3 ~D4 ~A:DIUS 4 DPL1 DIP PLANE COEFFICIENT I (~EDT) DPL~ PI.P ~bAm~ COEfF1C~E~.T 2 DDGP DiP DISPERSION OUAblT:' F;ATI~C DATA FORe, AT SFECIF?CATION RECORD SET TYPE - b4EB ** Type ~EP~ CODE 'VALUE .  6 6 0 79 104 12 I3 6b 0 la 65 FT ~ 66 0 A TYPE ID ORDER ~ bOG TYPE CbA88 MOD -NLiN~--~A~,P -.EDE~I CODE CHEX) mm mm ~m ~mm DPTP ~8DO DFG 94 61! Ol 0 ~ 68 0 00000000 [)Pk~ ?~,:[:O DEG 94 ~ 68 OlO0000000 O[]AF ~;r:'O 00 0C 0 oo .... HLgX RSI/'¢ DFG O0 000 O0 ~ !i ~i 44 6868 ~{0000000000000000 (:C~: (~svo 94 935 oo u ~ ~. z 4 o~ o~oooooooo A~] ~sr:(; D~:~ oo ooo oo o I i 4 6e o~oooooooo ~ ~svo ~ 76 ~3~ 9~ o oooooooo . 1 4 68 0000000 ' ~ '~ , ~ .. Ii2 ?aDO IN 70 2~0 24 ~ I 4 08 0100000000 KNX ~S~O O0 OOO O0 I ~ I 4 6R 010000o000 co cs o oo o,: o oo o ] I .8 oloooooooo S~ 2 ~SD[3 On 0(.~0 oo O i . 68 010oo00000 g ' ~" · '~ ~ t ~ 68 OlOOOO0000 .. 4. ~,', - } I 68 0100000000 ,~3,A .:aEC O0 000 O0 0 i RAD~ ~SC'G IK 70 2~30 4] ~ 4 68 0100000000 "' ' i I 4 68 0~00000000 CPI,~ N~$~ iN 70 44 ~ } 1 4 68 1 oo oo o oooooooo DPL2 ~?SDO O0 000 O0 ~ i i I 4 68 0100000000 DDOF: ~5DO O0 000 O0 0 .. I i 4 68 0100000000 DFPT. P:SD[2 4733 640 D[ ?. R. ~-~SDO 54.1P0 DPAZ, F~;Dn 317.000 DE~VI,NSD[)~ MSDi. j. 3714 ~ 000900.. Hb~Z,~i~DOct ,~.ISDO !~,0.00~000 CCRg.,P!SDOc2~MSD[) -99~a,2bO. 800 "0, c9 0 ' C ~ ~lSDO ~.OO0 S!2,aSDO -9~..9:.O 823'H-,HSDO 2,000 NSDO -909~900 S13Ai~iSDO ~q99;900 SC,MSDO 12410 84A1 ~N~:D ~D2, ~o,0 I 900 RAD3~tqSDO 2,.,000 RAD~t-.aSt'O..... I 900 DPI,? ~Sr'O ~,.31 DDOR. hSDO ~4;200 h. ND OF DATA QUAF.MSDU Agll,M~DD DKgX,MSDO $]4A,M~DO RAD~,~SDO DP~J,N6DO QUAF,MGDO AZI1.MSDO LKMX.MSDO S34A,NSDO RADI,MSDO DPL1,M~DO 2,000 219,000 30.008 2,80 2,000 -9,723 2O 000 350[000 47,000 2,500 4,500 0,093 DEFT : :'- r~.:, - - · ::. : ~4'4,::'~,~L~:&:'': ~3.~-~:, r~:h F~:~,r~ API S~RIAb COMPANY NAME FN -T~NF., POINT WELb NAME FIELD NAME STATE OR PNOVINCE COUNTY COUNTNY NATION M~CTION TOWNSHIP RANGE ITNE~S'$ NA~E ~XIMUM RECORDED TEMPERATURE DATE - MONTH DATE - DAY DATE ' YEAR RUN NUMBER DEFI . LOG PARAMETERS TO BE RECORDED .~ ' ."'~ ' : >. ~ ~...:.: ,. ~mm~m~m~~~~~~ DEFI : D~P DE'P~H CHANNEL NAME G~ ~AM~:~A RAY ' ' · : ;:, ::: ; : } : ; : : :: ::: : { :, _4 ~_FNL & 3346 ~E5 FIEbD 50CATION · ~':::':: :' : ': -" : i':: ~ ~?::::::-di~:~::!.'~: ?.:.: :: :>:.-: APl 8~RIAk NUMBER .... ......... ~ ' COMPANY NA~E :::: :-~:'~WN ' " M ' ' ' ' ' '~ Wgb6 NAME r. hILNE' PO'INT:::" '-~: :- FIELD NAHE COUNTY COUNTRY NATION IUW J. BM~ ........ ~ T - .::~.:~':' ~ .::::~ : ~-:.:.. : RANGE mr~'x ~.r;~r' '- ' ': MAXIMUM, RECORuED TEMPERATURE: DATE - MONTH DATE ~ DAY DATE YEA~ RUN NUMBER .... · . . ~. TRATIORAPHIC HIGH TABLE ~' F IYP,. ; CURV DEF 17 DPTI::. IP TR[JE DPA~. DIP A~,I~.,[ ~H OI,AF 0U~I.,ITY FACTOP: (SIiDT) l,a7 PEV!ATION AZItqt. JTH CCR~ CORRELATION CURVE RE~iSJ!VITY A~I] AZIMUTH OF FAD RELATIV~ BEARING I CALIPE~ 1 '  CALIPER 2 " 4 F~,~ ~A~ I~IJM LIKENESS CO COMBINP:D OU~LtTY S~2 8HDT DISPI, ACE~;F~T S~3.~. 8HDT DISPBACE~E~T 2 3g 834~ SHDT DISPLACEmEnT 3A - 4A $4AI 5HDT DISPLACEMENT '4A - 1 8!3~ SBDT DISPI, ACEgE~T I -3A sc RADI ~PELD CORRECTIO~ ADIUS I RAD2 RADiU8 'RAD3 ~ADIUS ~A.D4 Rg[,Ib~ 4 [ .... '. . DFL] DIP PLANE C.,EP~ICiENT 1 f~HDT) 'P'' D..b2 IP Pb~E C~EFFICiE~T 2 D~O~ ~IP BiSFERSION CUALITY ** r3ATA F[:P, MAT SPECIFICATION RECOPD ** SET TYPE - 64EB ** . YPE, I ~04 4 66 S 66 6 73 ? 6B ~:;..:.-- .:-'. OR.DE~R LOG TYPE CL:A~$ . · CODE : ,oooooooo, OOOOOOOO 'ou~'~ ~s~ · o~ '~~ ' ~' ~"~ ~"~ ~ ~'~ ~s o~°°°°°°oooooo ~-~' '" D~V~"~SDO 'DEG 76 6~0 ..0~ 0 ~ ~3~: ~.~1 '~-i . :~ ~8 0~00000000 hLAZ M'SDO DEG O0000 ~OO - 0-3 ~' : ~:' 1~ ''~ ~ ~80100000000 ~<_'~~~~:~: ~~~,'~',':~:. ~~- ~.~: ~"~~~~~ ~~~' ~~ ~<~'~:,~:~ ~~~~,~ '?-~ ~- ~.~':~ ~ oooooooo~I°°°°°°°° 100000000 ol ~.: ~2 ~SDO IN. : 70 .280 24 ~ ~: -~ .~1 '~: ~ ~.~x ~SD'O oo o00 O0 0 :a' :'~ ~ ~ di°°°°°0°°oooooooo NSDO O0 '000 O0 -O: :3 I '~- '~ 68 O0100000000100000000 :::. :':':~,,r~':,,~;::,~.~: '~'~"~'~'J : -' ' ' ]' ~:-: '"'~': "* ~ ~2~ ' ~- '~ -- :'~:~ ':~':: ~ ~ 6B68 0100000000010000000~ 'S1"3~' ~'~SDO 00' '000 O003 ' ~ 4 68 0100000000 -~-- ~,~ sc, ~-~o - 0.0 ooo oo o ~,: t ~ ~ ~ ~ os o~oooooooo R'~DI ~5DO IN 7o 286 '4i ~ ~:~--3: · 1 :4 6e o o00ooooo ~:': '::,~-~:D2 ~SDO- IN ~0,- 28042 ~ >3: ~,-1 ~: t 68 0~00000000 R'~D3 MSDO iN ~0 ~80 ~ < 0 '3 ': 6~~ ~0~00000000 IN:--70~ 28-0: ~4 -O- ~:~ I -1 4- · 68 0~00000000 DPL:J: ~SDO O0 OhO O0 : 3' ~' '~ i 4 68 OzO0000000 DD'O~ ~SDO 00' 060 '60 ~0 '~-'3 '~. ::'i ~zO0000000 ,200 LK~X.MSDO , 6.00$34A .o~o~.D~:~ap°spo 2,000 ,000 -4~:~oo 000 L~"~ II1 mil *I:-1 ~SDO MSDO 4.100 256 000 -999 25O 400 DPL1.MSDO QUAF.HSDU AZI! ~SDO bKMX S34A MSDO RAD1 DPL! MSDO 4,168 14,000 35.000 43,000 -999.900 6,200 1,353 DEF! APl SERIA6 NUMBER COMPANY NA~E G- :, 1 W~66 NA~E FIELD NAME STATE OR PROVINCE COUNTY COUNTRY NATIO~ DEF'I RANGE DEFI - WiT'~)" : ::' "- ' ~- 'ZOTZK¥::&:~FOX WITNESS'S,,AME ;~:'d~ -:'::: ~T D}BG.F -: : : '~8:5:~: _--:.x::~:.-.~.::; .?':'.: ~?-; MAXIMUM RECORDED TEMPERATURE NON'T 08 .... DATE - MONTH ATE - EAR ~ .~ RUN NUMBER LOG PARAMETERS TO BE RECORDED DEFI DEg': ' - ::' :-:"' ' · ~31~ '~<-:'~-'?~<~::~:-'~'~'x~ :: -- MAGNETIC DECLINATION ~ STRATIGRAPH~C H~GH RESOLUTION FAST CHANNEL DEPTH DEFINITION ,OF ~HE TOOL STRING mmmmmmmmm~mmmmmmmmmmmmmmmmmmm! T~P~ REP~ COD~ VALUE . ** SET TYPE - CHAN ** mmmmmmmmmmmm~mmmm mmmmmmm~mmm~mmmmmmmmmm~mm'~m~ mm~m{-~ ' ~mmmmmmmmmmmmmmmmmmmm~mmm '~ ~ } 4 68 0!00000000 DEPT SHSC FT O0 636 21 ~ - GP SHSC G~PI 30 310 Ol O 4 } 4 68 0100000000 ** DATA ** DFPT.SHSC 473S,b94 GR. 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SHSC 4000,195 GR,SHSC 77-500 DMPT,SHSC 3900,195 GR.SHSC 56,094 DFPT,SHSC 3800.195 GR.SH$C 67.188 DEPT. ~qHSC 3700,195 GR,SHSC 4~, 156 : ' DOFI ED : 35'75 84 ~,7 21 15,4 !79 9,6 9.8 C 86 I~,,6 263 i5.3 .~79 84 7~,0 284 15'3 179 84 ~ 6 84. 50 8 ,84 20 8424 3613 84 3'615 84 84 6 : 3637 3639 : 3643 ** ~. 3~47 · 365t *- 3653 84 37 84. 24 4 10 84 4 ~ 84 17 a4 19 84. 6 ,.. 101 io,2 180 9 5 8 .4 39 15;2 180 9,6 !~ ,9. 8 .6 l~ 0 238 i5 :~ '7 147 15.0 178 7 280 15~J ".,9 .4 359 i5.o 1~0 to ~0 278 15,o i~o ~: 271 1~.9 180 8 132 i4;9 i80 9  353 14,9 180 162 i5'0 180 8 300 1 ~ 85 ia. 49 14 304 I a 155 14 ~ , .- -180 9 ~7 fSO 8 7 180 9 7 179 8 7 179 9 7 178 9 7 178 9 7 178 9 (} ':227 14 7 I78 9 .0 96 14:7 179 9 ,0 11 14.7 I79 9 .0 344 i~-,7 i79 9 ,2 340 14.7179 9 .2 341 14;~ 178 9 3 ******************************** AGE 6-FILE 1 12-FILE 1 C -*'DEPTH .D~P 'DIE¥- DIAt';~ DIA!'4:-':' '~- ~- *********************************************-********-************************* · ~ ~[~_IP D~P~ * D~V... :,~...D~:,¥:, '::'.~:. ~O~"A:M~;- -~-' :D~.'AM,. *- Q. 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' - 3-1~7-~. ·- -- 14. 9~ ~18:1'~ ~, ~ ~ 4'~Q, - ' · 3:~8 O * ..... . ~. ~ . _ : :. - ::~ · : · . , . _ ~::: · 4 4 ! 3- I 120 150 210 : 2 ' 2 1 I I 1 2 4 1 I 5 1 2 3 i 2 I 1 1 2 2 2 3 2 i 4 3O 6 7 2 7 5 3 5 10 1 2 3o 6 3 7 11 10 2 7 14 2 2-4 * * · *************************************************************************, · 3a9B.84 5.0 152. i5.6 I78. 9,1 8.6 A * 54,1 317, i4.9 !81, 4,0 3,8 O ************************************************-*************************** FND OF LSF - VERSIi~]-~',1 007.E06 ~7-fi!3(.~-~9 - (~)(i:341 PROGRAM : ,Sf" '~ DATE : !7-AUG-8' TI~E : ~7147:'459 * HiGH DIPMETLR X 2' CONPANY wELL ,, F I E L !) : COUNTRY DATE LOGGED REFERENCE X 30 ~SD LIS~ING CONOCO !NC, ~iLNM POINT UNIT ~ILNE POINT USA 20 - AUG -89 73443 G-I OF FIEI,D BLUELI.J~ ~ILE #44 (MAI~ LOG) , , , , , , , , , , :, * * :, :, , ******************************************************************************** ":.'2 * 3227, 69 I 302 i : 0 : :: A. . ~,,~. ******************************************************************************************* ** ** **,,, ***, *** ** ~ ~ **, **, **.***, · ~,~ *** ~', ~ **~** ** **.** *** ****** ***** ** ·,, , , , , , , , , * * , , , , , , , , , , * , , , , , , , , , , , , , , ** PAGE 15-FIRE * DEPT~i! 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PP~;$ENTATION 3o 4600,, 470© 3 a700- 4.733 ? 6O 3 I 120 5 POINT I~:~IT G-I PlO 240 W 300 ~ ! 2 4 4 1 I 2 2 330 N 9 1 30 7 1 7 I 7 : 5' ~13 5 2 3 7 2 6 5 2 3 4 2 3 3 8 b 5 4 1 7 4 8 13 12 4 ,5 8 3O 4733 I t~C. 30 3 6O E 3 I 120 6 150 Pt3 I.t~ T UNIT 210 240 ~ 300 330 ? 9 4 4 I I 2 2 tO 2 30 DIP D ~Z~ * AZ~ ~'3' 2~4 * * , IP * D~V ~-~--DIAM ~ ~ DiAM * QUAh * ************************************************************************* ' - · 2627,69 17,5 ~56, 15,2 194, : ~O~iOM * ~ 4733.69 15,2 134. 15.4 17'.:~, 8,~ ~,2 O * ** S C H L :U M B E R G E R ** LIS TAPE VERIFICATION LISTING COPY OF FIELD LSS WAVEFORMS JOg NUMBER 73442 COMPANY NAME WELL NAME FIELD NAME COUNTY STATE API NUMBER CONOCO INC. MILNE POINT UNIT G-1 MiL'NE POINT NORTH SLOPE ALASKA 50-029-21927 RUN NUMBER ONE gATE LOGGED 20-AUG-89 SERVICE ORDER NUMBER .54B~36 DATE COMPUTED 30-AUG-89 FILE 6 = LOG FILE SCHLUMBERGER OFFSHORE SERVICES ALASKA D'I'VISION COMPUTER CENTER 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE~ ALASKA 99518 907/562-2654 SCHLUMBERGER LIST MTAO:['3LISA.DAT; 30-AUG-89 09:21=11 PAGE 3 REEL HEADER _] __ ** REEL HEADER SERVICE ~NAME : CGTS DATE : BO/08/20 ORIGIN : CSU REEL NAME '[ TAPE HEADER ** TAPE HEADER SERVICE NAME = DATE : 89/08/20 ORIGIN : CSU TAPIR NAME : CONTINUATZON #: ~1 -- PREVIOUS TAPE : COMMENT : SCHLUMBERGER WELL SERVICES CSU TAPE (EOF) FILE HE~OER 5TS .006 ** FILE HEADER ** FILE NAME : GTS .006 SERVICE NAME : LOG VERSION # : 32.2 DATE : 89/08/20 MAX. REC. 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DAT: 3 -1 -10 16 -3 16 -19 6 -23 16 -2 19 5 -11 -- 18 -1 11 -I7 11 -16 14 -12 18 110 62 62 62 62 46 46 4.6 62 62 62 62 62 78 78 78 78 78 94 78 78 78 78 78 78 '78 78 78 78 78 78 78 78 78 62 62 62 62 62 62 62 62 62 62 62 62 78 6.2 62 62 62 78 62 62 62 62 78 62 62 78 62 62 62 78 62 62 62 78 62 62 62 78 62 62 62 62 78 62 62 62 78 02 382 446 46 -498 -882 26 -530 62 14 14.22 1086 70 -162 222 94, 1422 942 06 -2034 -1938 70 84.6 702. 38 -2514 -2322 94 1302 7_558 26 -818 -1090 18 2670 3102 30 -898 -1522 26 1278 1774 06 -2098 -2914 06 -514 382 18 -850 -1586 78 1246 2302 54 846 -82 62 574 1294 34 286 -626 30 -978 -98 50 366 -546 18 -802 110 38 766 -18 66 -676 46 22 1326 654 62 46 46 62 62 78 78 78 78 78 78 62 62 62 62 62 .62 78 78 62 62 62 62 62 62 62 62 94 478 -1234 638 670 686 334 -1570 254 -1794 2462 -lOlO 3150 -1762 1870 -3394 1022 -ZO 50 3086 -786 1870 -1442 '/66 -1394 974 -754 798 -114 30-AUG-89 09:21:11 62 46 46 62 62 78 78 78 78 78 78 78 78 62 62 62 78 62 62 62 62 62 62 78 62 62 62 110 462 -1474 1134 222 1182 -322 -1010 -402 -1010 2030 -562 2766 -1618 1566 -3458 1310 -2130 3438 -1154 2190 -2050 1422 -2018 1630 -1314 1438 -802 62 46 46 62 62 78 78 78 78 78 78 78 62 62 78 78 62 62 62 78 78 62 62 62 62 62 62 158 350 -1538 1486 -146 1550 -978 -370 -1154 -82 1342 142 2030 -1074 894 -3122 1198 -17'~6 3310 -1138 2158 -2306 1742 -2306 1934 -1618 1886 -1298 PAGE 62 46 62 62 62 78 78 78 78 78 62 62 62 62 62 62 62 62 78 62 62 62 62 62 62 62 62 222 142 -1378 1646 -354 1742 -1538 238 -1842 878 54`2 1022 1054 -306 -50 -2418 718 -962 2.734 -770 1806 -2210 1630 -2146 1870 -1586 2014 -1490 10 SCHLUMBERGER LIST MTAO:[ -1346 -$98 -226 1694 1182 462 -t538 -1090 -434 1374 974 398 -1266 -930 -418 1150 830 3150 -110!6 -770 -258 t374 1086 670 -658 -434 -66 638 350 -18 -1026 -834 -530 814 750 574 -3 54 -242 -2 1246 1038 654 -738 -498 -t46 926 606 174 46 46 46 &6 30 46 46 WF3D ~4688.017 WF4D 4688.991 WF3N TT1 1280 TT2 1058 TT3 CBL 0.03467 TO 5. SRAT TTSL O. OTL 112.5 DT RSP 79.56 30-AUG-S9 09:21:11 PAGE 558 1246 -322 -1026 286 926 -242 -802 158 686 -178 -690 302 846 174 -274 318 622 · -418 -754 -162 222 318 62 334 718 190 -258 286 686 -274 -658 4,6 46 30 30 0.025 WF4N 0.025 1508 TT4 1286 0.4297 TT O. 112.5 SP -56.94 1726 1886 -1506 -1682 1358 1518 -1218 -1378 1070 1230 -1042 -1186 1246 1422 -594 -738 798 814 -978 -1090 526 734 -162 -306 1054 1230 -594 -770 958 1054 -866 -194 46 46 30 46 ITT 5.6Z4389E-05 AMPL 4.465 CBSL O. RSPA 0.625 11 DaTA RECORD. TYP::: ~ 0 DEPT 504120 .1 ---- 85 8.5 TOD 304074404 DIFF 0.55 TENS 3570. GR 80.44 STSG 176 MT~M 77.13 ~MT5 25.09 RIO RIi SMNO SMIN 333.5 343. IN 4201. FT 1280.4648 M TIME 1389. MARK 67.44 HTEN 1209 DTEM -1102 331.8 887-5 874. 894.5 0.8491 0.8608 O. 753.4 O. 75 SRTS 1 SPMV RSVO 2.141 RSIO SIO 811.5 OBCA MSFL MSFC 88 -136.5 810.5 22.97 2.908 2.947 27 4.269934 1735 2.189 2.2 DLCS 36 LLD PD 2152 PS WF2 108 44 44 44 6O 44 44 0-8008 0.7046 DV1 -0.05811 DVO 3.211 SBCA 34.22 2. 889 2.174 CLLD 234.4 ETIM 1500.821 IHV 226.1 RHTE 1209 RCAS 13.6'7 RDVO 3.186 010 670. CALS 9.125 LLS 3.821706 6O 44 44 44 6O 44 44 44 44 44 44 44 CS 1296 RGR 82.81 MRES 0.2422 RDIO 664. SVO 2.139 LLG -0.0766845 44 44 44 44 44 44 44 6O SCHLUMBERGER LIST MT AO: E 6O 6O '76 76 76 76 6O 6O 60 60 6O 6O 6O 6O 412 412 -6212 8636 1117 -5028 492 -1524 3020 -4948 8956 -6836 -4660 15916 -12996 11580 -11828 -t4~660 22668 -2,2084 9084 -2356 1~484 -23876 -5332 14988 -5268 -16452 22668 ,-10548 19052 380 -2740 -8468 -2916 -6308 -3332 10892 4140 -3796 6636 5628 ]LISA.OAT; 60 60 76 92 76 76 6O 60 6O 60 60 60 60 60 716 -772 -5684 9612 -643 -4420 92 -484 1932 -3236 7116 -7268 -2724 14588 -15028 16620 -18708 5?2 21996 -14564 -98,44 10908 1630'0 -27396 8476 2620 1580 -17172 24556 -139'72 20780 -1412 -7860 -5508 -1988 -12596 5964 348 13564 -10900 13180 -980 60 76 76 76 76 76 60 60 60 60 60 60 60 76 1084 -2052 -4180 9660 -2083 -3460 -644 796 444 -532 4300 -7300 11404 -14964 18492 -21460 13932 20124 4684 -17508 15180 15916 -28292 14076 -?428 6492 -16854 25356 -15556 21420 -644 -12356 -3444 -276 -18020 14556 -10228 18364 -14388 ! 7564 -7188 6O 60 76 76 76 76 76 60 60 60 44 60 60 76 1484 -3284 -1812 8860 -3236 -2308 -1428 20 76 -1332 2716 1148 -7108 4076 6812 -12804 18908 -22468 19020 2828 12092 -20244 16828 14940 -28196 16588 -14084 7404 -16100 25596 -15364 20172 1516 -15,204 -2452 1644 -20628 18908 -15620 20028 -14-420 19196 -11860 30-AUG-89 60 6O 76 76 76 6O 60 60 6O 60 6O 6O 6O 92 1772 -4388 1100 7324 -4228 -1124 -2052 3116 -3172 5884 -1796 -6804 8444 1484 -8676 16588 -2 2644 21292 -12356 14508 -21588 17564 11004 -28052 17964 -16916 3644 -12212 25372 -5764 16268 3500 -15908 -2324 2780 -20052 20620 -17476 18316 -11908 18540 -14148 09:2 60 76 '76 76 76 76 60 60 60 60 60 60 60 140 1756 -5332 4108 5293 -4900 -164 -2340 3676 -4692 8300 -4180 -6404 12460 -4036 -2900 10332 -22148 22476 -17924 15708 -21732 17484 140 -27844 18604 -16004 -4180 4876 17612 5084 10636 3804 -14580 -2692 2044 -16932 21164 -15188 12796 -7092 15948 -13812 1:11 PAGE 6O 60 76 76 76 76 6O 6O 6O 60 6O 6O 6O 236 1292 -6004 6748 3165 -5188 412 -2180 3644 -5412 9404 -5860 -5780 15164 -9124 4140 92 -20964 22860 -20772 16332 -19556 15324 -14628 -23428 187O0 -11764 -12676 18076 -1972 14108 4764 1596 -I1796 -3044 -1076 -11252 18156 -6020 4860 -564 11532 -11092 12 SCHLURSERGER 'L~ST ~T~O: E3LIS~. OAT:J -6420 -500 4732 -3636 -9044 -68 9596 2940 -13044 -6724 ?622 1980 -5620 828 10940 5260 -12420 -8772 69,40 5484 28 -308 -516 -708 -148 -116 -20 5788 -12692 ~892 -4644 412 -4180 7708 -852 -4084 3852 -340 -580 --84 !38 90 90 74 90 74 74 74 74 74 74 74 9O 90 90 90 90 90 !06 106 106 90 106 t06 106 90 106 90 106 106 90 90 90 74 90 74 74 90 90 90 74 74 74 74 74 90 74 90 90 90 90 74 90 90 74 '74 90 '74 74 74 74 90 74 90 74 74 74 74 74 90 122 186 730 698 522 -1750 -2214 -2534 170 1242 2266 33'70 2746 2010 -1014 -1350 -1558 -14 78 -1382 -1302 -710 -486 -262 1866 2490 3034 650 -981 -2549 -3782 -2502 -998 4442 43-46 3818 -1350 -1910 -2166 -246 2 98: 778 1338 1050 714 -582 -856 -1158 .-118 282 570 314 186 1'38 11164 -19268 14252 -11876 6908 -9524 13596 -6596 652 2476 28 -452 -68 9O 74 74 9O 90 106 106 106 9O 9O 9O 9O 74 74 9O 74 90 9O 74 74 74 74 74 266 218 -2566 3114 1274 -1686 -1238 26 3370 -3909 538 2906 -2118 1162 426 -1286 '/30 218 30-A~UG-89 09:21:11 14140 -21428 16332 -16964 11356 -12724 17004 -11156 4524 1532 732 -340 -52 14060 -20228 16764 -18708 12940 -13044 17420 -13796 6908 924 1500 -276 -36 90 74 74 '74 90 90 106 106 90 gO 74 74 9O 90 90 90 74 90 9O 74 9O 74 74 394 -182 .-2294 3674 554 -1718 -1158 362 3386 -4805 1978 1770 -1830 1450 170 -1222 762 3?8 -6 -17 38 -16 -10 7 29 -50 31 5 -13 15 -- -9 6 5 9O 74 74 9O 9O 106 106 106 9O 9O 74 9O 9O 74 74 74 74 74 90 90 74 ? 4 74 38 62 18 98 70 7O 46 62 61 78 86 66 78 54 66 66 PAGE 10892 -16100 14380 -17268 11564 -10532 15244 -14212 7612 460 1964 -212 -20 9O 74 9O 9O 106 106 106 9O 9O 74 9O 74 74 9O 9O 9O 9O 74 9O 90 74 9O 666 -1206 -854 3786 -598 -1574 -902 1274 1994 -4646 4042 -486 -822 1546 -294 -566 506 618 13 S:CHLUM~BERGER LIST MTAO'[]LISA. 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DATJ 94 94 62 1~2 126 126 3O ~6 62 94 78 62 ~6 62 94 '78 46 46 94 94 78 78 78 94 62 78 78 78 94 78 14 X4 14 62 62 46 62 94 lid 94 46 46 78 94 94 94 94 94 46 30 30 78 78 94 94 78 62 62 62 78 78 78 94 78 62 62 62 62 62 46 62 62 46 62 62 94 78 78 62 62 62 62 62 78 126 126 142 142 110 46 -754 -850 -866 990 1422 1726 5 90 126 -306 -8,66 -706 -514 -114 -66 30 846 830 702 -674 -738 -674 494 606 574 -690 -738 -594 974 926 734 -242 -130 62 958 878 670 -610 -482 -226 158 -146 --4B2 -642 -338 14 110 -178 -402 -50 126 318 318 -66 -322 1102 :1214 1054 -402 -322 -178 62 46 14 -562 -482 -210 782 350 -210 -530 -98 286 110 -5:0 -146 222 462 654 62 I10 94 30 126 46 78 94 62 78 30 62 126 46 94 78 46 110 62 94 78 78 62 46 T8 46 94 142 -50 -722 1806 -642 -354 190 462 -514 414' -274 446 302 366 94 -754 302 -514 542 718 -18 -50 158 -722 526 -162 718 62 78 110 30 142 62 78 78 62 62 46 62 126 46 94 78 62 110 62 94 62 78 62 46 94 78 110 158 -194 -450 1710 -866 -242 366 142 -258 142 126 126 558 35O -914 494 -498 75O -66 270 78 -I?B 558 -1026 590 -162 67O -AUG-89 09:2 94 46 126 30 1Z6 78 78 78 78 30 46 46 126 62 94 62 78 110 62 110 78 78 62 46 94 62 46 126 158 -386 -34 1454 -978 -194 574 -210 3O -178 510 -114 782 -322 462 -962 526 -402 B14 350 -114 110 -338 862 -1090 494 -114 542 1:11 PAGE 110 30 126 46 94 94 94 62 78 14 62 62 110 62 94 62 78 94 62 110 78 78 46 46 110 62 46 142 158 -594 478 1054 -978 -162 ?50 -482 286 -482 830 -242 910 -562 398 -850 382 -242 670 782 -354 110 -498 958 -898 302 14 398 34 SCHLUMBERGER :LIST MTAO:[]LISA.DAT; 30-AUG-89 09:21:11 PAGE 35 WF3D Ti1 CBL TTSL RSP ---- 238 126 1054 1.214 334 142 30 -290 222 356 94 '78 3O 2553.905 WF4D 725. TT2 0.0004883 TO O. DTL 20°72 FILE TRAILER GTS .006 ,** FILE TRAILER ** FILE NAME : GTS ,006 SERVICE NAME :'. LOg VERSION ~ : 32.2 DATE : 89/08/20 MAX., REC. LEND: 8192 FILE TYPE :: CR NEXT FILE : 2555.0~3 615.5 ¢, 580.5 46 62 222 494 814 1278 1246 1134 926 622 62 94 174 238 206 -690 -1106 -1410 -1586 -1586 302 238 190 158 126 62 62 46 46 46 WF3N 0.025 WF4N 0.025 TT3 1912 TT4 729. SRAT 0.248 TT O. DT 119.5 SP -115.4 ITT AMPL CBSL RSPA 0.2661459 0.5229 O. 0.6875 FI:LE SUMMARY ~LR ~PR aENC --~-------m, ,..,,-- ---- ~-- --.--.---- -- ,,...---- 4322 43.27 0 #DR ~FM 4293 4293 DEPT DEPT DEPT PI_UNITS MAXPI MINPI .lIN 568140 310620 F 4734.5 2588.5 M 1443.0756 788.97~8 (EOF) FILE HEADER GTS ~- FILE HEAOER FILE NAME SERVICE NAME VERSION ~ DATE MAX. REC. LEN.: ~ILE TYPE PREVIOUS FILE .007 GTS .007 LOG 32.2 89/08/2O 8192 CR FILE TRAILER GTS .007 SCHLUMBERGER LIST MTAO':[]LISA. OAT; 30-AUG-89 09:21:11 PAGE 36 #* FILE T~AILER '~, FILE NAEE : GTS .007 SERVICE NAME : LOG VERSION ~ : 32.2 DATE : 89/08/20 MAX. REC. LEN.: 8192 FILE TYPE : CR NEXT FILE FILE SUMMARY ~LR ~PR ~ENC #DR ~FM 27 (EOF) (EOD) TAPE SUMMARY 32 0 FILES 2 4350 4360 PI PI_UNITS MAXPI MINPI REEL SUMMARY FILES TAPES ~LR 2 i 4351 4361 L~U SUMMARY FILES TAPES REELS ~LR ~PR 2 ! I 4351 43.6I ! ENO OF LISTING MTAO:[]LISA.DAT; 1 COMP:~N¥ NAME : CONOCO INC. WELL NAME : MILNE POINT UNIT FIELg NAME :' MILNE POINT BOROUGH : NORTH SLOPE STATE : AL,~SKA AP! NU~ER .' 50-029-21927-00 REFERENCE NO : 73~42 G-1 LIS TAPE VERIFI'CATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 30- AUG--198:9 10:'45 PAGE: · *~ REEL HE,~DER ~$~ SERVICE NAME : EDIT DATE : 89/08/30 ORIGIN : FLIC REEL NAME : 73442 CONTINUATIDN ~ : PREVIOUS REEL : COMMENT : CONGCO INC.,MI~NE POIN:T,~LNE P~INT UNiT G-1,50-ozg-zIg27-O0 SERVICE NAME : EOIT DATE : ORIGIN : FLOC TAPE NAME : 7.3442. CONTINUAT ION PREVIOUS TAPE : COMMENT : CONOCO INC.~MILNE POINT,MILNE POINT UNIT G-1,50-029-21927-00 *:*** FILE HEADER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : OOIA02 DATE : 8 9/0-~/3:0 MAX RE:C S~ZE : FILE TYPE : LO LAST FILE : SCHLUMbErGER WELL SERVICES · COMPANY NAME: CONOCD INC. WELL: MILNE POZNT UNZT G-! FIELD: MILNE POINT BOROUGH: NORTH SLOPE STATE: AL6, SKA API NUMBER: ~0-029-21927-00 LOCATION: 3644' FNL~ ~ 3346" FEL SECTION: 27 TOWNSHIP: 13N RANGE: PERMANENT OATUM: MSL ELEVATION: 0 LIS TAPE YERIFICAT!ON LISTING SCHLUMBERGER ALASKA COMPUTING CENTER PAGE: LOG MEASURED FROM RKB 59.3 ABOVE PERMANENT DATUM ELEVATIONS KS: 5g.3 GL: 2g.5 DATE LOGGED: 20-AUG-BO RUN NUMBER: ONE TD DRILLER: 4?45 TD LOGGER: 47~0 CASING: 9 5/8" 47 L~ @ DRILLER DEPTH OF 261B BIT SIZE: 8 1/2" TYPE FLUID I-N HOLE: KCL/BLAND DENSITY: 9.1 VISCOSITY: 52 PH: 7.5 :FLUID LOSS: 4.2 MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVSTY: 0.289 @ 68 0.237 @ 68 0.3F~4 @ 68 TIME CIRCULATION ENDED: 02:00 20-AUG TIME LOGGER ON BOTTOM (DLL/LSS PASS): 08:40 20-AUG TIME LOGGER ON BOTTOM (LDT/CNL ~ASS): 15:20 20-AUG MAXIMUM TEMP ~ECORDED: 83 LOGGING DISTRICT: LOGGING ENGINEER: WITNE.SS: P~UDHOE BAY SARBER ZOTZKY/FOX TOaL N.UM~ERS (DLL/LSS PASS): ELECT RODE AMM-AA 712 SGC-SA-50 SLS-ZA-587 DRS-C-4942 DLS-F-7S9 SPAA TCC-B.-,?. 8 ! SLC-UA-278 SRE-D-7g7 DLH-C B-2927 DLE-E-7$9 TOOL NUMBERS (LDT/CNL PASS): AMM-A~ 712 SGC-SA-50 NSC-E 80! TOM-AB !07 TCC-B-28! CNC-H 340 DRS-C 4908 FIELD REMARKS: DRILLING FLUID WAS CHAN~ED WHEN DRILLER WAS AT DEPTH OF 4100'. OLD MUD PROPERTIES: MUD TYPE = SPUD MUD cgo0 PPM CHLORIDES), DENSITY = B.g PPG, VISCOSITY NEU'TRON MATRIX : SANSTONE, HOLE CORRECTION = CALIPER~ DENSITY MATRIX = 2.65 G/CC, FLUID DENSITY = 1o0 G/CC. DATE JO8 STARTED: 2g-~UG-Bg JOB REFERENCE NO: 73~42 ~LDP/ANA: J. KgHRING LIS TAPE VERIFICATION LISTING 30.-AUG-lOB9 10:45 SCHLUMBERGER ALASKA COMPUTING CENTER PAGE: FILE - EDiT.O01 CONOCO INC. MILNE POINT MILNE POINT UNIT G-I 50-029-21927-0D MAIN PASS LOG D~TA DATA SAMPLED EVERY -.5000 FEET DATA I'NCLUDED - TOOL EXTENSION TOOL TYPE USED NAME OLL .DLL DUAL LATEROLOG 4725' TO 2618' LSS .LSS LONG SPACED SONIC 4684' TO 2618* LOT .LOT LITHO DENSITY ?+735' TO 2615' CNT-A/O/H .CNL COMPENSATED NEUTRON 4715' TO 2618" CN'T-A/D/H .CSG CASING CNL 2618~' TO 1486' TABLE TYPE : CONS TUNI VALU DEFI CN CONOCO INC. COMPANY NAME FN MILNE POINT FIELD NAME WN MILNE POINT UNIT G-1 WELL NAME APIN 50-029-21927-00 API SERIAL NUMSER FL 3644' FNL, & 3346' FEL FIELD LOCATION SECT 27 SECTION TOWN 13N TOWNSHIP RANG IOE RANGE COUN NORTH 'SLOPE COUNTY S'TAT ALASK..~ STATE OR PROVINCE NATI USA NATION ENGI SARBER ENGINEER'S NAME WITN ZDTZKY/FOX WITNESS'S NAME SON 548,4.36 SERVICE ORDER NUMBER PDAT MSL PERMANENT DATUM EPD FT O. LMF RK.B LOG MEASURED FROM APO FT 59.3 EKB FI 59.3 LIS TAPE V!ERIEICATION LISTING SCHLUMBERGER ~LASKA COMPUTING CENTER TUNI 30-A~UG-1989 EOF FT EGL FT TOD FT BLI FT TLI FT TCS TLAB VALU 5~. 29.5 4745. 4684. OZ:O0 20-AUG 08:40 20-AUG PAGE: DEFI BOTTOM LOG INTERVAL TOP LOG INTERVAL TIME CIRCULATION STOPPEO TIME LOGGER AT BOTTOM TABLE TYPE : CURV DEPT LLS LLD C AL S SP GR TENS MTEM MRES HTEN DT OTL TT! TT2 TT3 TT4 SP GR CALS TENS MTEM MRES HTEN DPHI RHOB DRHO PEF Q.L S QSS LS LU LL LITH SSI SSZ L SHV SSHV S1RH LSRH DEFI DEPTH CHANNEL NAME LATERO-LOG SHALLOW (RESISTIVITY) LATERO-LOG DEEP (RESISTIVITY) SONIC CALIPE~ SPONTANEOUS POTENTIAL GAMMA RAY TENSION MUD TEMPERATURE MUD RESISTIVITY HEAL TENSION DELTA-T DELTA T LONG SPACING TRANSIT TIME Z TRANSIT TIME 2 TRANSIT 'TIME 3 TRANSIT TIME 4 SPONTANEOUS POTENTIAL GAMMA ~AY SONIC CALI~E~ TENSION MUD TEMPERATURE MUD RE.SISTIV~TY HEAD TENSION DENSITY POROSITY 6ULK DENSITY OELTA ~HO PHOTO-ELECTRiC FACTO~ QUALITY CONTROL OF LONG SPACING FOR LOT QUALITY CONTROL ON SHORT SPACING FO~ LOT LONG SPACING COMPU'TED COUNT RATE (LL+LU/Z) LONG UPPER 1-Z WINDOW COUNT RATE (LUI+LUZ) LONG LOWER WINDOW COUNT RATE LITHOLOG WINDOW COUNT RATE SHORT SPACING I WIN~OW COUNT RATE SHORT SP.~CING Z WINDOW COUNT RATE LONG SPACING HIGH VOLTAGE OUTPUT SHORT SPACING HIGH VOLTAGE LOOP OUTPUT SHORT SP~CING ! DENSITY LONG SPACING RHO~ (UNCORRECTED) SCHLUMBERGER ALASKA COMPUTING CENTER 30-AUG-lOS9 10:~5 PAGE: LURH C A,L I GR TENS MTEM MAES HTEN NPHI TNPH TNRA NPOR RCNT RC FT CNTC CFTC GR CALI TENS MRES MTEM HTEN NPHI ?NPH T N:R A NPOR RCNT RCFT -CNTC CFTC GR TENS MAES MTEM HTEN DEFI LONG UPPER RHO~ CALIPER GAMMA RAY TENSION MUD TEMPERATURE MUD RESISTIVITY HEAD TENSION NEUTRON POROSITY THERMAL NEUTRON POROSITY CALIBRATED THERMAL N~UTRON RATIO NEUTRON POROSITY OUTPUT FROM AN ,APPLICATION PROGRAM RAW CORRECTEiD NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS GAMMA RAY CALIPER TENSION MUD RESISTIVITY MUD TEMPERATURE HEAD ?ENSION NEUTRON POROSITY 'THERMAL NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTEO NEAR THERMAL COUNTS CORRECTED FA~ THERMAL CaUNTS GAMMA RAY TENSION MUD RESISTIVITY MUD TEMPERATURE HEAD TENSION DATA FORMAT SPECIFICATION RECORD ~ SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 292 4 66 5 66 6 73 B 68 0.5 HLUMBERGER ALASKA COMPUTING CENTER 30-AUG--1989 10::45 PAGE: TYPE REPR CODE VALUE 9 .,65 FT 11 66 3 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 SET TYPE - CHAN ~ NAME SERV ID UNIT SERVICE API API API API FILE NUMB NUMB SIZE ORO~R ~ LOG TYPE CLASS MOD NUMB SAMP ELEM DEPT FT :LLS DLL OHMM LLD DLL OHMM CALS DLL IN SP DLL MV GR DLL GAPI TENS DLL L 8 MTEM DLL DEGF MRES DLL OHMM HTEN DLL L B DT LSS US/F DTL LSS US/F TT1 LSS U S T T2 LSS US TT3 LSS US TT4 LSS US SP LSS MV GR LSS GAPI CALS LSS IN TENS LSS LB MTEM LSS OEGF MRES LSS OHMM HTEN LSS LB DPHI LDT PU RHOB LOT G/C3 DRHO LOT G/C3 PEF LOT QLS LOT QSS LOT LS LOT CPS LU LOT CPS LL LDT CPS LITH LOT CPS SS1 LDT CPS SS2 LDT CPS LSHV LDT V SSHV LOT ¥ 548436 O0 000 O0 0 I I I 4 5484:36 11 ZZO 09 0 I I i 4 548436 11 ~20 10 0 I I 1 4 548436 11 ;!80 01 0 1 1 I 4 548436 11 010 O1 0 1 1 I 4 548436 11 310 :01 0 1 t I 4 548436 11 635 21 0 1 1 1 4 548436 11 000 O0 0 1 1 ! 4 548436 11 0:00 O0 0 1 1 1 4 548436 11 000 O0 0 1 1 I ~ 548436 11 520 80 0 ! I 1 4 548436 t 1 :520 81 0 1 t 1 4 548436 11 522 83 0 1 1 1 4 548436 11 522 83 0 1 1 1 4 5,48436 11 522 8:3 0 1 1 1 4 548436 11 522 83 0 1 1 1 4 548436 11 010 O1 0 1 i I 4 5.48436 i1 310 O1 0 1 1 I 4 548436 11 310 O1 0 1 1 1 4 5484.36 I1 6.35 21 0 1 t 1 4 548436 11 000 O0 0 1 1 ! 4 548436 1t OOO O0 0 I I ! 4 548436 tl 0:00 O0 0 1 1 1 4 548436 42 890 01 0 1 1 I 4 548436 4Z :3.50 02 0 1 1 I 4 548436 42 356 Ol 0 1 1 I 4 548436 42 35~ O1 0 1 1 I 4 548436 42 354 O1 0 ! 1 I 4. 548436 42 3.54 O1 0 1 t 1 4 548436 42 35:4 Ol 0 1 1 I 4 548436 4.2 354 O1 0 I i 1 4 548436 42 354 O1 0 1 1 1 4 548436 42 354 O1 0 1 I I 4 548436 42 35~+ OZ 0 1 1 1 4 548436 4.2 354 02 0 I 1 I 4 548436 42 354 O0 0 1 I I 4 5.48436 42 354 gO 0 I 1 ! 4 REPR CO DE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 6~ 68 68 68 68 68 68 68 68 68 68 68 PROCESS CHEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00.00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000OO0 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 30-~UG-1989 10:45 PAGE: NAME SERV UNIT SERVICE ID ORDER ~ LOG T AP[ API API YPE CLASS MOD ~ILE NUMB NUMB SIZE REPR PROCESS NUMB SAMP ELEM CODE CHEX) S1RH LDT G/C3 548436 42 LSRH LDT G/C3 548436 42. LURH LOT G/C3 548436 42. ,CALl LOT IN 548436 42 GR LOT GAPI 548436 42 TENS LDT LB 548436 42 MTEM LDT DEGF 548436 &Z MRES LDT ~HMM 54-~4'36 42 HTEN LDT LB 548436 42 NPHI CNL PU 548436 42 TNPH CNL PU 54-g436 42 TNRA CNL 548436 42 NPOR CNL PU 548436 42 RCNT CNL CPS 548436 42 RCFT CNL CPS 548436 42 CNTC CNL CPS 548436 42 CFTC CNL CPS 548436 42 GR CNL G~PI 5484'36 42 CALI CNL IN 5484~.6 42 TENS CNL LB 548436 42 ~MRES CNL ~HMM 548436 42 MTEM CNL DEGF 5-48436 42 HTEN CNL L~ 548436 42 NPHI CSG PU 54~436 42 TNPH CSG PU 548436 42 TNRA CSG 548436 42 NPOR CSG PU 54~436 42 RCNT CSG CPS 54~436 42 RCFT CSG CPS 548436 42 CNTC CSG CPS 5484~6 42 CFTC CSG CPS 548436 42 GR CSG GAPI 548436 42 TENS CSG L8 548436 42 MRES CSG ~HMM 548436 42 MTEM CSG DSGF 548436 42 HTEN CSG L~ 548436 42 350 02 0 350 02 0 350 02 0 2~0 O1 0 310 O1 0 63:5 21 0 000 O0 0 000 O0 0 000 O0 0 890 O0 0 890 O0 0 42O 01 0 890 O0 0 ¢20 01 0 420 O1 0 420 01 0 420 O1 0 310 Ol 0 280 01 0 635 21 0 000 O0 0 000 O0 0 000 O0 0 890 O0 0 890 O0 0 420 OI 0 890 O0 0 420 Ol 0 ,¢20 01 0 420 O1 0 420 01 0 310 O1 0 635 21 0 000 O0 0 000 O0 0 000 00 0 1 1 i 4 68 0000000000 1 1 1 4 68 0000000000 1 1 I 4 68 0000000000 1 1 I 4 68 0000000000 ! I I 4 68 0000000000 I .1 I 4 68 0000000000 I 1 ! 4 68 0000000000 1 1 I 4 68 0000000000 1 1 I 4 68 0000000000 1 1 I 4 68 0000000000 I 1 I 4 68 0000000000 1 1 1 4 68 0000000000 I 1 I 4 68 0000000000 1 1 1 4 68 0000000000 I 1 1 4 68 0000000000 1 1 1 4 68 00000.00000 1 1 I 4 68 0000000000 I 1 I 4 68 0000000000 I 1 I 4 68 0000000000 1 1 1 4 68 0000000000 I 1 I 4 68 0000000000 1 1 1 4 68 0000000000 1 i 1 4 68 0000000000 ! 1 I 4 68 0000000000 I I I 4 68 0000000000 I 1 1 4 68 0000000000 I I I 4 68 0000000000 I I 1 4 68 0000000000 I 1 1 4 68 0000000000 i 1 I 4 68 0000000000 1 I 1 4 68 0000000000 1 1 1 ~ 68 0000000000 t 1 1 ¢ 68 0000000000 1 I 1 4 68 0000000000 1 1 1 4 68 0000000000 1 1 I 4 68 0000000000 DATA DEPT. ~753.500 LLS.DLL SP.D'LL -999.250 GR.DLL MRES.DLL -999.250 HTEN.DLL 'TTI.~SS -999.250 TTZ.LSS SP.LSS -999.250 GR.LSS MTEM. LSS -999.250 MRES.LSS RHOB. LDT 2.243 DRH0.LDT QSSoLDT 0.000 LS.LOT LITH.LDT 110.875 SSI.LOT SSHV.LDT 13ZI.OOO S1RH..LDT -999.250 LLD. DLL -999,250 CALS.OLL -999,250 TENS,DLL -999,250 MTEM, DLL -999. 250 DT.L S.$ '-99 9,250 DTLoLSS -99g. 250 TT3.LSS -999°250 TT4.LSS -999.250 CALS.LSS --999.250 TENS.LSS -999.250 HTEN.LSS .-999.250 DPHI.LDT O. 01~+ PEF.LDT 2.994 QLS.LDT 386..500 LU.LDT 356.75'0 LL.LOT 219.750 SS2.LOT 330-250 LSHV.LDT 2,174 LSRH,LDT 2,229 LURH,LDT -999.250 -999.250 -999.250 -999.250 -999.250 24.685 -0.004 208.125 1405.000 2.238 LIS TRPE YERIFICRTION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER CALI.LDT 7.707 GR.LDT MRES.LDT O,. 256 HTEN.LDT TNRA.CNL 3. 593 NPOR.CNL CNTCoC'NL 2068.95'7 CF'TC.CNL TENS.CNL 11550.000 MRES.CNL NPHIoCSG -999. 250 TNPH.CSG RCNT.CSG -999o2~0 RCFT.CSG GR.CSG -999.25.0 TENS.CSG HTEN.CSG '-999.250 DEPT. ¢700. 000 LLS.DLL SP.OLL -56.8?5 GR.DLL MRES.DLL 0.235 HTEN.DLL TT1.LSS !250. 000 TT2.LSS SP.LS$ -56. 875 GR.L$S MTEM. LSS 80.t25 MRES.LSS RHD6oLDT 2-338 ORHO.LDT QSS.LDT O. 035 LS.LDT LITH.LDT 88.438 SS1.LDT SSHV.LDT 1321. 000 SIRHoLDT CALI.LDT 8-625 GR.LDT MRES.LDT 0.2.59 HTEN.LDT TNRA.CNL 3.164 NPOR.CNL CNTC.CNL 2015.764 C:FTC.CNL TENS.CNL 2724.0D0 MR!ES.CNL NPHi. CS.S -999.250 TNPHoCSG RCNToCSG -999.250 RCI=T.CSG GR.CSG -999.250 TEN-S.CSG HTEN.CSG -999. 250 DEPT. ,4600.0 O0 LLS.DLL SP.DLL -102. 938 GR.DLL MRES.DLL 0.237 HTEN.DL~L TT1.LSS 1242. 000 TT2.LSS SP.LSS -102.938 GR.LSS MTEM.LSS 80.250 MRES.LSS RHOB.LDT 2°284 ORHO.LDT QSS.LDT 0.025 LS.LDT LITH.LDT 109.688 SS1.LOT SSHV.LDT 1321.000 SZRH.LDT CALI.LDT 8.711 GR.LDT MRES.LDT O. 243 HTEN.LD'T TNRA. CNL 3.413 NPOR.£NL CNTC.CNL 1889.635 CFTCoCNL TENS.CNL 2754.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -9'99.250 RCFT.CSG GR.CSG -999.250 TENSoCSG HTENoCSG -999.250 DEPT- 4500. 000 LLS.DLL SP.DLL -102.750 GR.DLL MRES.DLL 0.234 HTEN.DLL TTloLSS 12:41. 000 TTZ.LSS SP.LSS -IOZ.?50 GR.LSS 30-AUG-1989 10:45 89.375 TENS.LOT 4°078 NPHI.CNL 43.439 RCNT'CNL 584.127 GR.CNL O. 256 MTEM.CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999. 250 MRES.CSG 6.160 LLD. DLL 97.188 TENS.DLL 1199.000 DT.LSS 1058.000 TT3'LSS 97.188 CALS.LSS 0-235 MTE:N.LSS 0.010 PEF.LDT 324. 000 LU.LDT 21'1. 875 SS2.LDT 2.287 LSRH.LDT 101.375 TENS.LOT 653.500 NPHI.CNL 36.294 )~CNT.CNL 632.807 GR.CNL 0.259 MTEM. CNL -999.250 TNRA.CSG -999.250 CNTC. CSG -999.250 'MRES.CSG 2.617 LLD.DLL 97. 375 TENSoOLL 1205o000 DT.LSS 101.8.000 TT3.LSS 97.375 CALS.LSS 0.:237 HTEN.LSS 0.002 PEF.LDT 353. 750 LU.LDT .ZlOo O00 SS2.LDT 2. 273 LSRH.LDT 89. 750 TENS.LOT 667. 500 NPHI.CNL 3,9.. 788 RC NT. C NL 563.695 GR.CNL 0.243 MTEM.CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999. 250 MRES.CSG 3.654 LLD. DLL 103.938 TENS.OLL 1190. 000 DT.LSS 1026.000 TT3.LSS 103.938 CALS.LSS 1560.000 46.069 2151.324 89.375 81.375 -999.250 -999.250 -999.250 6.150 3874.000 112.500 1508.000 8.273 1199.000 3.084 301.750 297.750 2.326 36.874 2162.431 101.375 81.500 -999.250 -999.250 -999.,250 2.686 3760.000 I08.500 1470.000 8.469 [205.000 2. 695 325.250 301.750 2.281 2754.000 41.293 1984.315 89.750 82.125 -999.250 -999.250 -999.250 3.668 3664.000 108.000 1455..000 8.500 MTEM.LDT TNPH.CNL RCFT.CNL CAL I. CNL HTEN.CNL NPI~R.CSG CFTC. CSG MTEM. CSG CALS.DLL MTEM. DLL DTL.LSS TT4. LSS TENS.LSS DPHI.LDT QLS.LDT LL. LDT LSHV.LDT LURH.LDT MTEM. LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN. CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM. DLL DTL.LSS TT4.LSS TENS. LSS OPHIoLDT QLS.LDT LL.LDT LSHV.LDT LURM. LDT MTEM.LDT TNPH. CNL RCFT.CNL CALI.CNL HTEN. CNL NPDR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM. DLL DTL.LSS TT4.LSS TENS.LSS PAGE: 81.375 43.439 553.951 7.707 ¢.078 -999.250 -999.250 -999.250 8.273 80.125 112.500 1286.000 3874.000 18.906 0.000 173.000 1406.000 2.338 81.500 37.651 615.865 8.625 653.500 -999.250 -999.250 -999.250 8.469 80.250 108.250 1245.000 3760.000 22.179 0.011 191.125 1406.000 2.293 82.125 40.241 526.667 8.711 647.500 -999.250 -999.250 -999.250 8°500 80.500 107.750 1245.000 366¢.000 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASK:~ COMPUTING CENTER MTEM. LSS 80.500 MRES.LSS RHOB. LD'T 2.3 32 DRHO.LgT QSS.LDT 0. 028 LS.LDT LITH..LDT 94. 250 SS1.LDT SSHV.LDT 1321.000 SIRH.LDT CALI.LD'T 8. 828 GRoLDT MRES.LDT Oo 2413 HTEN.LDT TNRA.CNL 3.273 NPOR.CNL CNTC.CNL 1757.528 CF'TCoCNL TENS.CNL 2674.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT..CSG -999.250 RCFT.CSG GR.CSG -999.250 TENS.CSG HTEN.CSG -999.250 DEPT. 4400o 000 LLS. DLL SP.DLL -104.125 GR. DLL MRES.DLL 0.236 HTEN.DLL TT1.LSS 1313. ODD TT2.LSS SP.LSS -104.125 GR.LSS MTEM.LSS 79. 500 MRES.LSS RHDS.LDT 2.2-46 DRHD.LDT QSS.LDT O- 018 kS.LOT LITH.LDT I15.938 SS1.LOT SSHV.LDT 1321.000 SIRH.LDT CALI.LOT 8. 797 GR.LD~T MRES.LDT 0.245 HTEN.LDT TNRA.CNL 3.278 NPOR.CNL CNTC.CNL 1749.692 CFTC.CNL TENS.CNL 2630.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999.250 RCFT.CSG GR.CSG -999. 250 TENS.CSG HTEN.CSG -999.250 DEPT. 4300. DO0 LLS.DLL SP. DLL -94.750 GR.DLL MRES.DLL 0.238 HTEN.DLL TT1. LSS 1299. 000 TTZ.LSS SP.LSS -94. 750 GR.LSS MTEM.LSS 78.438 MRES.LSS RHO8. LD'T 2.2.82 DRHO.LDT QSS.LDT O. 026 LS.LDT L ITH.LDT 111. 313 SSI.LDT SSHV.LDT 1321.000 SIRH.LDT CALI.LDT 10. 203 GR.LDT MRES.LDT 0.249 HTEN.LDT TNRA.CNL 3.346 N'PDR.CNL CNTC.CNL '1546.801 CFTC.CNL TENS.CNL 2710.000 MRES.CNt. NPHI.CSG -999.250 TNPH. CSG RCN'T.CSG -999.250 RCFT.CSG GR.CSG -999.250 TENS.CSG HTEN.CSG -999.250 30--1&UG-1989 10:45 0.234 HTEN. LSS 0.013 PEF.LDT 330.000 LU. LOT 214.125 SS2.LDT Z. 266 LSRH.LDT 10!. 875 TENS.LOT 617.000 NPHI.CNL -42.401 RCNT.CNL 531.18! GR.CNL O. 243 MTEM.CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999.250 MRES.CSG 4.183 LLD.OLL 92.438 TENS.OLL 1149.000 DT.LSS lOBl. O00 TT3.LSS 92.438 CALS.LSS 0.236 HTEN.LSS O.OOO PEF.'L DT 376. 750 LU.LDT 211.125 SSI.LOT 2.244 LSRH.LDT 83.688 TENS.LOT 630.000 NPHI.CNL 39.590 RCNT.CNL 523. 710 GR.CNL 0.245 MTEM.CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999.250 MRES.CSG 4.439 LLD.OLL 102.1BB TENS.OLL 1216.000 DT.LSS 1087.000 TT3.LSS IO2.1BB CALS.LSS 0.238 HTEN.LSS 0.028 PEF.LDT 371.250 LU.LDT .~22.750 SS2.LDT 2. 170 LSRH.LDT 97.31:3 TENS.LOT 65-4.000 NPHi.CN:L 37. 294 RCNT.CNL 479. 820 GR.CNL 0.249 MTEM. CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999.250 MRES.CSG 1190.000 3.125 304.250 304.250 2.318 2674.000 38.561 1716.013 101.875 $2.125 -999.250 -999.250 -999.250 4.425 3634.000 110.250 1541.000 B.633 1149.000 2.674 351.000 308.750 2.244 2630.000 38.691 1835.542 83.688 81.688 -999.250 -999.250 -999.250 4.490 3690.000 109.750 1497.000 9.461 1216.000 2.816 347.000 320.500 2.252 2710.000 37.831 1602.573 97.313 80.500 -999.250 .-999.250 -999.250 DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM. LDT TNPH.CNL RCFT.CNL C AL I. CNL HTEN.CNL NPQR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM.DLL DTL.LSS TT4.LSS TENS.LSS OPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI.CNL HTENoCNL NPOR. CSG CFTC.CSG MTEMoCSG CALS. DLL MTEM. DLL DTL .LSS TT4.LSS TENSoLSS DPHI.LDT QLSoLDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPHoCNL RCFT.CNL CALI.CNL MTEN.CNL NPOR.CSG CFTC.CSG MTEM. CSG PAGE: 19.270 0.014 177.875 1407.000 2.334 82.125 39.459 528.989 8.828 617.000 -999.250 -999.250 -999.250 8.633 79.500 109.250 1316.000 3634.000 24.468 -0.015 201.375 1406.000 2.248 81.688 39.996 467.394 8.797 630.000 -999.250 -999.250 -999.250 9.461 78.438 111.000 1297.000 3690.000 22.310 -0.018 197.750 1407.000 2.254 80.500 37.136 452.779 10.203 654.000 -999.250 -999.250 -999.250 LIS TAPE VERI~'ICATION LISTING SCHLUMBERGER ~LASKA COMPUTING CENTER DEPT. 4200. 000 LLS.DLL SP. DLL -151.8'75 GR.DLL MRES.DLL 0.243 MT:ENo DLL TT1.LSS 1443. OOO TT2.:LSS SP.LSS -151. 875 GR.LSS MTEM. LSS 77.000 MRES.LSS RHOBoLD'T 2.090 DRHg. LOT QSSoLDT O. 041 LS.LOT LtTH.LDT 192. 500 SSi. LOT SSHV. LD'T 1321. DO0 S1RH.LDT CALI.LDT 8. 594 GR.LDT MRES.LDT 0.254 HTEN.LDT TNRA,CNL 3,049 N.POR. CNL CN'TC.CNL 1916.802 CFTC.CNL TENS. CNL 2560.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999.250 RCFT.CSG GR.CSG -999.250 TENS.CSG HTEN. CSG -999.250 DEPT. 4100.0 OD LLS.DLL SP. DLL -146. 625 GR.DL:L MRES,DLL 0.246 HTEN.. DLL TTI.LSS 13 54. OOO T'T2.LSS SP.LSS -146.625 GR.LSS MTEM.LSS 75.688 MRES.LSS RHOS,LDT 2,144 DRHO,LDT QSS.LD'T 0.036 LS.LDT LI'TH.LD'T I60. 875 SS1.LDT SSHV.LDT 1321. 000 S1RH.LDT CALIoLDT 9,211 GR,LDT MRE'S.LDT 0.258 HTEN.LOT TNRAoCNL 3.473 NPOR.CNL CNTC..CNL 1619.654 CFTC.CNL TENS.CNL 24'70. 000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999.250 RCFT.CSG GR. CSG -999.250 TENS.CSG HTEN.CSG -999.250 DEPT. 4000,000 LLS,DLL SP,DLL -143. 500 GR, DLL MRES.DLL 0.249 H'T EN. DLL TT1.LSS 1404. 000 TT2.LSS SP. LSS -143.500 GR.LSS MTEM. LSS 74.688 MRES.LSS RHOBoLDT 2. 178 DRHO.LDT QSS,LDT 0.022 LS.LgT LITH.LOT 151.750 SSI-LOT SSHV.LDT 1321.000 S1RH.:LD'T CALI.LDT B, 7 50 GR.LDT MRES.LDT 0..260 HTEN. LOT TNRA. CNL 3.3 66 NP OR .CNL CNTC.CNL 1884.299 CFTC.CNL 30-AUG-1989 10:45 13. 500 LLD.DLL 53.156 TENS.DLL 1184.000 DT.LSS 1190o000 TT3.LSS 53.156 CALS.LSS 0.243 HTEN.LSS 0.014 PEF,LDT 519.500 LU.LDT 228.875 SS2.LOT 2. 018 LSRH,LDT 50,188 TENS.LOT 636. 500 NPHI.CNL 36.406 RCNT.CNL 597.436 GR.CNL O. 254 MTEM.CNL -999:.250 TNRA.CSG -999.250 CNTC.CSG - 9:99. 250 MRES.CSG 2.468 LLD.DLL 88.500 TENS..OLL 1157.000 DT.LSS 1131.000 TT3.[SS 88.500 CALS.LSS 0.246 HTEN.LSS 0.028 PEF.LDT '479,750 LU,LDT 230.750 SS2.LDT 2.03! LSR:H.LDT 81.375 TENS.LOT 639,500 NPHI.CNL 42.922 RCNT.CNL 479.383 GR.CNL 0.258 MTEM. CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999.250 MRES.CSG 2. 701 LLD.DLL 72. 188 TENS.OLL 1t44.000 DT.LSS 1151.000 TT3.LSS 72,188 CALS.LSS O. 249 HTEN.LSS 0.001 P E F. L D T 430. 250 LU.LOT 215.000 SS2.LDT 2.. 174 LSRH.LOT 68.625 TENS.LOT 622. 500 NPHI.CNL 38.189 RCNT-CNL :567. 435 GR.CNL 16.555 3530.000 123.250 1675.000 8.375 1184.000 2.441 476,000 334.500 2.074 2560.000 34.803 2068.817 50.188 79.313 -999.250 -999.250 -999.250 2.698 3460.000 120.500 I558.000 8.617 1157.000 2,988 438.750 336.500 2.113 2470.000 41. 645 1593.59'7 81.375 78.000 -999.250 -999.250 -999.250 2.814 3490.000 124.250 1659.000 8.469 1144.000 2.121 394.000 316,500 2.176 2434.000 40.374 2026.551 68.625 CALS.DLL MTEM. DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS,LDT LL,LDT LSHV,LDT LURM,LDT MTEM.LDT TNPH.CNL RCFT,CNL CALI.CNL HTEN.CNL NPOR,CSG CFTC,CSG MTEM.CSG CALS.DLL MTEM.DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS.LOT .LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH. CNL RCFT,CNL CALI.CNL HTEN.CNL NPDR.CSG CFTC.CSG MTEM.CSG CALS,DLL MTEM. DLL DTL .LSS TT4,LSS TENS.LSS DPHI.LDT QLS .LOT LLoLDT LSHV,LDT LURHoLDT MTEM.LDT TNPH,CNL RCFToCNL CALI.CNL PAGE: 8.375 77.000 121.500 1446.000 3530.000 33.944 -0.015 281.250 1405.000 2.074 79.313 38.034 570.796 8. 594 636.500 -999,250 -999.250 -999.250 8.617 75.688 116.500 1353.000 3460.000 30.697 -0.008 260.500 1406.000 2.119 78,000 40.308 442.690 9.211 639.500 -999.250 -999.250 -999.250 8.469 74.688 124.500 1405.000 3490.000 28.634 -0.003 233.125 1406.000 2.180 77,000 39.711 535.490 8,750 10 LIS 'TAPE VERIFICATION LISTING SCHLUMBERGER ~LASKA COMPUTING CENTER TENS.CNL 2434.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT,CSG -999,250 RCFT,CSG GR.CSG -999,250 TENS.CSG HTEN.CSG -999,250 DEPT, 3900.000 LLS,DLL SP,DLL -138.250 GR,DLL MRES,DLL 0,251 HTEN,DL:L TTI.LSS 1422.000 TT2.LSS SP.LSS -138.250 GR.LSS MTEM.LSS 74°000 MRESoLSS RHOS,LDT 2,135 ORHD,LOT QSS.LDT 0.034 LS,.LDT LITH, LDT 163.000 SS1.LDT SSHVoLDT 1320.000 S1RH.LDT CALI,LDT 9,570 GR,LOT MRES,LDT 0,262 HTEN,LDT TNRA.CNL 3.536 NPOR,CNL CNTC.CNL I784.935 CFTC.CNL TENS.CNL 2344.000 MRESoCNL NPHI.CSG -999,250 TNPH.CSG RCNT.CSG -999.250 RCFT,CSG GR.CSG -999,250 TENS.CSG HTEN.CSG -999,250 DEPT. 3800. 000 LLS.DLL SP.DLL -129. 000 GR.DLL -MRES.OLL 0.252 HTEN.DLL TT1.LSS 1348.0 OD TT2.LSS SP.LSS -129.000 GR.LSS MTEM.LS,S 73,4'38 MRES.LSS RHOB.LDT 2.18.1 DRHD.LDT QSS.LDT O. 005 LS.LDT LITH,LDT 1.37.625 SSI .LOT SSHV.LD'T 1320.000 S1RH.LDT CALlo LOT 8, 852 GR,.LOT MRES,LDT 0,265 HTEN,LDT TNRA.CNL 3.4 68 NPOR.CNL CNTC.CNL 1775.098 CFTC.CNL TENS.CNL 2354.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999. 250 RCFT.CSG GR.CSG -999o 250 TENS.CSG HTEN. CSG '-999.250 DEPT. 3700.000 LLS.DLL SP.DLL -tD5.438 GR.DLL MRES. DLL O. 2.54 HTEN.DLL TTI.LSS 14 79. 000 TT2. LSS SP, LSS -t 05,438 GR.LSS MTEM.LSS 72,500 MRES.LSS RHO~,LDT 2. 084 ~R'HO,LDT QSS.LDT O. 029 LS.LOT LITH.LDT I94.2:50 SSI.LOT 30-AUG-19B9 10:45 0.260 MTEM.CNL -999.250 TNRA,CSG -999.250 CNTC,CSG -999,250 MRES.CSG 12-992 LLD,DLL 58,313 TENS,DLL 1148.000 DT,LSS 1192.000 TT3oLSS 58,313 CALS.LSS 0.251 HTEN.LSS 0.002 PEF,LDT 466,000 LU. LDT 218.250 SS2.LDT Z.123 LSRH. LDT ~7...406 TENS.LDT 526. DOD NPHIoCNL 43. 440 RCNT.CNL 506. 274 GR.CNL O. 262 MTEMoCNL -999.250 TNRA.CSG -999,250 CNTC.CSG -999,250 MRES.CSG 4.52.4 LLD-DLL 72,250 TENS.DLL 1171.000 DT.LSS 1107,000 TT3.LSS 7~.. ~50 CALS.LSS O, 252 HTEN.LSS -0,010 PEF'LDT ¢1 8. go0 LU,LDT 208,375 SSZ.LDT 2. 229 LSRH.LDT 66.625 TENS.LOT 5'30.000 NPHI.CNL 39. 734 RCNT.CNL 535,905 GR,CNL 0,265 MTEM,CNL -999,250 TNRA,CSG -999,250 CNTC.CSG -999.'250 MRES.CSG 34.493 LLD.DLL 38.656 TENS.DLL 1159.000 DT.LSS !222.000 TT3.LSS 38.656 CALS.LSS O. 254 HTEN.:LSS -0.004 PEF.LDT .50~-000 LU.LDT ZI6.750 SSZ.LDT 77,000 -999.250 -999.250 -999.250 12.865 3370.000 124.000 1656.000 9.227 1148.000 2.293 426,750 319.000 2.131 2344.000 42.258 1817.443 57,406 76,000 -999,250 -999,250 -999.250 4.889 3]350.000 118.000 1582.000 8.703 1171.000 2,727 387,000 3'I 3. 750 2.189 2364.000 42,. 094 1836.412 66.625 ?4.°938 -999.250 -999.250 -999.250 35°787 3464.000 125,500 1746.000 12.234 2.184 465,750 321.500 HTEN.CNL NPOR.CSG CFTC.CSG MTEM. CSG CALS.DLL MTEM,DLL DTL.LSS TT4,LSS TENS.LSS DPHI,LDT QLS,LOT LL,LDT LSHV,LDT LURH, LDT MTEM.LDT TNPH.CNL RCFT.CNL C&LI.CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM.DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM. LDT TNPH.CNL RCFT.CNL CALI,CNL HTEN,CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM.OLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSH¥.LDT PAGE: 622,500 -999,250 -999,250 -999,250 9,227 74.000 123,000 1427,000 3370.000 31.229 -0,009 252,500 1405.000 2.135 76.000 42.424 481.894 9,570 626.500 -999,250 -999,250 -999.250 8.703 73.438 118.500 1351.000 28.446 -0,015 224,625 1405.000 2.191 ?4.938 39,502 506,516 8.852 630.000 -999.250 -999.250 -999.250 12,234 72,500 125,250 1479,000 3464,000 34,285 -0.013 275.000 1405.000 11 LIS T~PE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER SSHV.LDT 1321.000 SIRH.LDT CALI.LDT 12.078 GR.LDT MRES.LDT O. 272 HTEN.LDT TNRA.CNL 3.408 NPOR.CNL CNTC.CNL 1711.292 CFTC.CNL TENS.CNL 23,34.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG R£NT..CSG -999.250 RCFT.CSG GR.CSG -999.250 TENS.CSG HTEN.CSG -999..250 DEPT, 3600. OOO LLSoDLL SP.DLL '-89,81.3 GR.DLL MRES, DLL 0.254 HTEN,DLL TT1.LSS 1356. 000 TTZ.LSS SP.LSS -89,813 GR.LSS MTEM. LSS 72,000 MRES.LSS RHOB.LDT 2.094 ORHO,LDT QSS.LDT 0.016 LS.;LDT LITH..LDT 182.2.5'0 SS1.LDT SSHV.LDT 1321.000 S1RH.LOT CALI.LDT 10.2:66 GR.LOT MRES,LDT 0.279 HTEN,LO'T TNRA.CNL 3. 532 NPOR. CNL CNTC.CNL 1674.980 CFTC.CNL TENS.CNL 2284.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999.250 RC~ToCSG GR.CSG -999.250 TENS.CSG HTEN. CSG -999.250 DEPT, 3500,000 LLS.gLL SP,DLL -89,813 GR.DLL MRES.DLL 0.259 HTEN.DLL TT1.LSS 1478,000 TT2.LSS SP.LSS -89.813 GR.LSS MTEM.LSS 71.2 50 MRES.LSS RHOS.LDT 2.173 DRHO.LDT QSS.L'DT 0.002 LS.LDT LITH.LDT 135. 500 SSt.LOT SSHV.LDT .t3.21.000 S1RH.LDT CALI.LDT 9.016 GR.LDT MRES.LDT 0.283 HTEN.LDT TNRA.CNL 3.963 NPDR,CNL CNTC.CNL 1655.610 CFTC.CNL TENS..CNL 2340.000 MRES.CNL NPHi. CSG -999.250 TNPH.CSG RCNT. CSG .-999.250 RCFT.CSG GR.CSG -999. 250 TENS.CSG HTEN.CSG -999.250 DEPT. 3400.000 LLS..DLL SP.DLL -89. 938 GR.DLL MRES. DLL O. 260 HTEN. DLL TTI.LSS 1¢48.000 TT2.LSS 30-AUG-lgS9 10:45 2.105 39. 344 634.500 38.535 491.158 0.272 -999. 250 -999.250 -999.250 LSRH.LDT TENS.LOT NPHI.CNL RCNT. C NL GR.CNL MTEM.CNL TNRA.CSG CNTC.CSG MRES.CSG 10.910 5¢.000 1165.000 1121.000 54.000 0.254 -0.010 492.750 212.750 2.143 52. 844 630.000 41.357 :476.420 0,279 -999.250 -999.250 -999.2'50 LLD.DLL TENS.DLL DT.LSS TT3.LSS CALS.LSS HTEN. LSS PEF ,LDT LU.:LDT SS2.LDT LSRH. LDT TENS.LOT NPHI.CNL RENT. CNL GR.CNL MT EM. C NL TNRA.CSG CNTC.CSG MRES.CSG . 1143. 1209. 81. O. Z08. 81. 645. 48. 430. -999. -999. -999. 723 375 000 000 375 259 010 250 75O Z21 813 000 612 512 283 250 25O LLD.OLL TENS.DLL DT.LSS TT3.LSS CALS.LSS HTEN.LSS PEF.LOT LU.L DT SS2.LDT LSRH.LDT TENS.LDT NPH'I,CNL RCNT,CNL GR.CNL MT EM. C NL TNRA.C SG CNTC.CSG MRES.CSG 6.244 72.500 1163o000 llgO. O00 LLD.OLL TENS.OLL DT.LSS TT3.LSS 2.088 2334.000 37.576 1842.505 39.344 73.375 -999.250 -999.250 -999.250 12.171 3330.000 122.000 1590.000 9.961 1165.000 2.057 444.000 320.500 2.104 2284.000 41.t54 1757,778 52.844 71.. ZSO -999,250 -999.,250 -999,2.50 6.553 3224,000 128.750 1750.000 8,898 1143.000 2.752 385.T50 316.000 2.182 2340.000 50.920 1702.838 81.813 69.688 -999,2.50 -999,250 -999.250 7,037 3244.000 127.000 1696.000 LURH. LDT MTEM,LDT TNPH,CNL RCFT, CflL CALI.CNL HTEN,CNL NPOR.C'SG £FTC.CSG MTEM.CSG CALS.DLL MTEM. DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS.LDT LL,LDT LSHV,LDT LURH,LDT MTEM, LDT TNPH,CNL RCFT,CNL CALI,CNL HTEN,CNL NPgR,CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM.DLL DTL. LSS TT4.LSS TENS.LSS OPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS,DLL MTEM, OLL DTL.LSS TT4.LSS PAGE: 2.086 73.375 40.118 454.145 12.078 634.500 -999.250 -999.250 -999.250 9.961 72.000 120.500 1364.000 3330.000 33.676 0.010 270.500 1405.000 2.113 71.250 41.792 462.918 10.266 630.000 -999,250 -999.250 -999.250 8.898 71.250 128.750 1486.000 3224.000 28.930 0.002 229.875 1404.000 2.191 69.688 48.036 399.797 9.016 645.000 -999.250 -999.250 -g99.250 8.781 70,500 126.000 1454.000 12 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASK~ COMPUTING CENTER SP.LSS -89.,938 GR.LSS MTEM.LSS 70.500 MRES.LSS RHOB.LOT 2.178 DRHO.LDT QSS.LDT O. 002 LS.LOT LITH.LDT 13¢. 000 S S1.LOT SSHV.LDT 1321. OOO SIRH.'LDT CALI.LDT g. 164 GR.LDT MRES.LDT O. 288 HTEN.LDT TNRA.CNL 3. 877 NPOR.CNL CNTC.CNL 1736.191 CFTC.CNL TENS.CNL 2150..000 MRES,CNL NPHI.CSG -999.2 50 TNPH. CSG RCNToCSG -999.250 RCFT.CSG GR.CSG -999.250 TENS.CSG HTENo CSG -999.250 DEPT. 3300. 000 tLS. DLL SP.DLL -90.938 GR.DLL MRES..DLL 0°263 HTEN.DLL TT1.LSS 1371. 000 TT2.:LSS SP.LSS -90. 938 GR.LSS MTEMoLSS 70.000 MRES.LSS RHOB.LDT 2.135 DRHD.LOT QSS.LDT :0. 019 LS.LOT LITH.LDT 165. 375 SS1.LDT SSHV.LDT 1321.000 S1RH.LDT CALI.LD'T 9. 266 GR.LOT MRES.LDT O. 292 HTEN.LOT 'TNRA..CNL 3.465 NPDR.CNL CNTC. CNL 2051.103 CFTC.CNL TENS.CNL 2420.000 MRES,CNL NPHIoCSG -999.2.50 TNPH. CSG RCNToCSG -999.250 RCFT.CSG GR.CSG -999.250 TENS.CSG HTEN. CSG -999.250 DEPT. 3200.000 LLS.DLL SP,.OLL -89. 625 GR.DLL MRES.DLL 0.264,, HTEN.DLL TT1.LSS 1484. 000 TT2.LSS SP.LSS -99.625 GR.LSS MTEM.LSS 69.188 MRES.LSS RHOB.LOT 2.16'7 'DRHO.LDT QSS.L.DT 0.0t6 LS.LDT LITH,.LDT t31.625 SS1. LDT SSHV..LDT 13,20.000 SIRH.LDT CALI.LDT 9.14t GR.LDT MRES,.LDT 0.294 HTEN.LOT TNRA.CNL 4.229 NPOR.CNL CNTC.CNL 1615.901 CFTC.CNL TENS.CNL 2260,.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999.250 RCFT.CSG GRoCSG -999.250 TENS.CSG HTEN.CSG -999.2.50 30-~UG-t 989 10:45 72. 500 CALS.LSS 0-26,0 HTEN.LSS -0.013 PEF..LDT 416. '750 L;U. LDT 206. 250 SS2.LOT 2.244 LSRH.LDT 80.438 TENS.LDT 642.500 NPHI.CNL 47..?.75 RCNT.CNL ~72.767 GR.CNL 0.288 MTEM.CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999.250 MRES.CSG 6.982 LLD. OLL 60.344 TENS.DLL 1183,000 DT.LSS 1138.000 TT3.LSS 60°344 CALS.LSS 0.263 HTEN.LSS -0.010 PEF.LDT ~56.. 500 LtJ.LDT 210. 875 SS2.LDT Z. 182 LSRH.LDT 59.125 TENS.LOT 711.500 NPHI.CNL 43.107 RCNT.CNL 586. 105 GR.CNL O. 292 MTEM.CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999.250 MRES.CSG 5.157 LLD.DLL 86.500 'TENS. DLL 1157. 000 DT.LSS 122~., 000 TT3.LSS 86.500 CALS.LSS 0.264 HTEN.LSS -0.012 PEF.LDT 42 ~. 500 LU.LDT 207.875 SS2.LDT .2. 225 LSRH.LOT 84.625 TENS.LDT 597. 500 NPHI.CNL 54.096 RCNT.CNL 392.119 GR.CNL O. 294 MTEM.CNL -999.Z50 TNRA.CSG -999.250 CNTCoCSG -999.25:0 MRES.CSG . 1163. Z. 380. 311. 2. 2150. 49. 1729. 80. 68. -999. -999. -999. . 3244. 126. 1614. 8- 1188. 2. 418. 314. 2. 2-420. 2116. 67. -999. -999. -999. 3124. 132.. 1752. 1157. 2. 385. 309. 2. 2260. 55. 1640. 6 6. -999. -999. -999. 781 000 701 25O 75O 189 000 105 701 438 313 250 25O 25O 989 000 25O 000 701 000 355 50O 000 000 430 082 125 188 25O 250 25O 618 000 500 000 930 000 916 750 25O 178 000 590 206 625 125 25O ?.50 250 TENS.LSS OPHI .LDT QLS.LDT LL.LDT LSHV.LDT LURH.LOT MTEM.LDT TNPHoCNL RCF T. CNL CALI.CNL HTEN.CNL NPOR..CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM. DLL OTL.LSS TT4oLSS TENS.LSS OPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL M'TEM. DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LOT QLS.LDT LL.LOT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL C~LI.CNL HTEN.CNL NPDR.CSG CFTC.CSG MTEM.CSG PAGE: 324~.000 28.614 0.006 226.625 1403.000 2.201 68.313 45.091 436.605 9.164 642.500 -999.250 -999.250 -999.250 8.781 70.000 126.500 1378.000 3244.000 31.186 -0.008 247.375 1403.000 2.146 67.188 42.494 ~4B.326 9.266 711.500 -999.250 -999.250 -999.250 8.930 69.188 132.250 1488.000 3124. 000 29.291 0.013 232.625 1403.000 2.193 66.125 52.T22 364.910 9.141 697.500 -999'250 -999.250 -999.250 13 T~PE VERIFICATION LISTING SCHLUMBERGER RLASKA COM.PUTING CENTER DEPT. 3100. 000 LLS.O:LL SP. DLL -118. 500 GR.IDL.L MRES.DLL 0.266 HTEN.DLL TT1.LSS 15 98. 000 TT2.LSS SP. LSS -118..500 GR.LSS MTEMoLSS 68.875 MRES.LSS RHOB.LDT 2.109 DRHD.LDT QSSoLDT -0.00I LS.LDT LITH. LDT 1-¢4.250 SS1.LDT SSHV.LDT 1320.000 S1RH.LDT CALI.,LDT 9. 383 GR.LOT MRES. LDT 0.298 HTEN.LOT TNRA.CNL 4.062 NPOR.CNL CNTC.CNL 1513.656 CF'TC.CNL TENS.CNL 2254.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999.2!50 RCFT.CSG GR.CSG -999.2 50 TENS.CSG HTEN.CSG -999°250 DEPT. 3000.000 LLS.DLL SP.DLL -117.750 GR.DLL M~ES. DLL 0.268 HTEN.DLL TT1.LSS 1638. 000 TT2.LSS SP.LSS -117.750 GR.LSS MTEM. LSS 67.875 MRES.LSS RHOB.LDT 2.032 DRHO.LDT QSS.LDT 0.002 LS.LDT LITH.LDT 172.750 SS1.LDT SSHV.LDT 1320.000 S1RH.'LDT CALI.LDT 9.406 GR.LDT 'MRES.LDT 0.302 HTEN.LDT TNRA.CNL 4.1'96 NPOR.CNL CNTC.CNL ,1306.304 CFTC.CNL TENS.CNL 2140.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCN'T.CSG -999.250 RCFT.CSG GR.CSG -999.250 TENS.CSG HTEN.CSG -999.250 DEPT. 2900. 000 LLS. DLL SPoDLL -91.188 GR.DLL MRE~S.DLL 0.271 HTEN.DLL TTloLSS 1536.000 TT2.LSS SP. LSS -91.188 GR.LSS MTEM.LSS 67.375 MRES.LSS RHOB. LDT 2.155 DRHO.LDT QSS.LDT 0.012 LS.LDT LITH.LDT 112. 063 SS1.LDT SSHV.LDT 1319.000 S1RH.LDT CALI.LDT 9. 875 GR.LDT MRES.LDT 0.305 HTEN.LDT TNRA. CNL 3.914 NPOR.CNL CNTC.CNL 167'7.829 CFTC.CNL 30-AUG-1989 10:45 4.654 89.375 1147. 000 1318.000 89.375 0.266 -O.01B 467.000 206.875 2.199 79.68B 669.000 46.481 400.694 0.298 -999.250 -999.250 -999.250 LLD.DLL TENS.DLL DT.LSS TT3.LSS CALS.LSS H'TEN.LSS PEF.LDT LU.LDT SS2.LDT LSRH.LDT TENS.LOT NPHI.CNL RC NT. C NL GR.C NL MTEM. CNL TNRA.CSG CNTC .CSG MRES.CSG 4.901 105.313 1190.000 1380.000 105. :313 O. Z6B -0. O07 549. 000 217.500 2.066 101.000 700. 000 50-251 327.116 0.302 -999.250 -999.250 -999.250 LLO. DLL TENS.DLL DT. L SS TT3.LSS CALS.LSS HTEN.LSS PEF.LOT LU.LDT SS2.LOT LSRH.LDT TENS.LOT NPHI .CNL RCNT.CNL GRoCNL MTEM.CNL T:NRA.CSG CNTC.CSG MRES.CSG 3.123 64.250 1194.000 1251.000 64.250 0.271 -0.023 421.500 202.125 2.266 75.938 7.05.0~00 46.327 442.045 LLD.DLL TENS.OLL DT.LSS TT3.LSS CALS.LSS HTEN.LSS PEF.LDT LU.LDT SS2.LDT LSRM.LDT TENS.LOT NPMI.CNL RCNT.CNL GR.CNL 5.371 3020.000 132.750 186 7.0:00 9.406 1147.000 2.820 427.500 318.000 2.127 2254.000 52.174 1579.612 79.688 65.375 --999.250 -999.250 -999.250 5. 344 3084.000 154.750 9.742 1190.000 3.029 508.500 338.000 2.037 2140.000 5'4.593 1357.660 101.000 64.500 --999.250 --999.250 -999.250 3.333 3040.000 120.750 1845.000 10..313 1194.000 2.883 390.250 302.500 2.178 2094.000 48.724 1755.065 75.938 CALS.DLL MTEM. DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LOT MTEM.LOT TNPMoCNL RCFT.CNL CALI.CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM. CSG CALS.DLL MTEM. DLL OTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM. LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL NPOR.CSG CFTCoCSG MTEM.CSG CALS.DLL MTEM.DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT ~L$.LDT LL.LDT LSHV.LDT LURH.LDT MTEMoLDT TNPH.CNL RCFT.CNL CALI.CNL PAGE: 9.406 68.875 133.750 1602.000 3020.000 32.788 -0.009 253.125 1403.000 2.133 65.375 46.667 340.238 9.383 669.000 -999.250 -999.250 -999.250 9.742 67.875 1~5.750 1643.000 3084.000 37.470 -0.021 294.750 1402.000 2.037 64.500 50.225 305.240 9.406 700.000 -999.250 -999.250 -999.250 10.313 67.375 119.250 1542.000 3040.000 30.007 -0.016 226.500 1403.000 2.186 63.719 46.634 408.572 9.875 14 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ~LASK~ COMPUTING CENTER TENS.CNL 2094.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999.250 RCFT.CSG GR.CSG -999.250 TENS.CSG HTEN. CSG -999.250 DEPT. 28,00. 000 LLS.OLL SP.OLL -93.688 GR.DLL MRES.OLL 0.275 HTEN.DLL TT1.LSS 1528.000 TT2.LSS SP.LSS -93.688 GR.LSS MTEM. LSS 66.375 MRES.LSS RHOB.LDT 2. 069 ORHO.LOT QSS.LDT O. 005 LS.LOT LITH.LDT 185.125 SS1.LDT SSHV.LDT 1320.000 S1RH.LDT CALI.LDT 10. 555 GR.LDT MRES.LDT O. 305 HTEN.LDT TNRA.CNL 13.333 NPOR.CNL CNTC.CNL 1552.065 CFTC.CNL TENS.CNL 2084.000 MRES.CNL NPHI.CSG -999.250 TNPH.CSG RCNT.CSG -999.250 RCFT.CSG GR.CSG -999.25'0 TENS.CSG HTEN.CSG -999.250 DEPT. 2700. 000 :LLS. OLL SP.DLL .-91. 750 GR.DLL MRES. DLL 0.277 HTEN.DLL TT1.LSS 1666. 000 TTZ.LSS SP.LSS -91. 750 GR.LSS MTEM.LSS 65.625 MRES.LSS RHOB-LD'T 2.074 gRHOo:LDT QSS.LDT -0. 002 LS.LDT LZTH.LDT !73.750 SS!.LDT SSHV.LDT 1319. 000 SIRH.LDT CALI.LDT 10.594 GR.LDT MRES.LDT 0.3'10 HTE:N.LDT TNRA.CNL 3.631 NPOR.CNL CNTC.CNL !548.808 CFTC.CNL T E:N S. CN'L 191 O- 000 M R E S -C NL NPHI.CSG -999.250 'TNPH.~CSG RCNToCSG -999. 250 RCFT.CSG GR.CSG -999.250 ~TENS.CSG HTEN. CSG -999.250 DEP:To 2600- 000 LLS.DL'L SPoDLL -117. 000 GR.DLL MRES.DLL 0.277 HTEN.DLL TT1.LSS 7'23.000 TT2.'LSS SP-LS S -117.. 000 GR. LSS MTEM.LSS 65.250 MRES.LSS RHDB. LDT 1-801 DRHO.LDT QSS..LDT -0.157 LS.LDT L ITH.LDT 17 · 578 S S1 .LOT 30-AUG-1989 10:45 0.305 MTEM. CNL -999.250 TNRA.CSG -999.250 CNTC.CSG -999.250 MRES.CSG 9.950 44.000 1167.000 1254.000 44.000 0.275 -0.014 511.250 211.375 2.139 42.375 673.000 39.744 535.940 0.305 -999.250 -999.250 -999.250 LLD.DLL TENS. DLL DT.LSS TT3.LSS CALS.LSS flTEN.LSS PEF.LDT LU.LDT SS2.LOT L S RH. LDT TENS.LOT NPHI.CNL 'RCNT.CNL GR.CNL MTEM.CNL TNRA.CSG CNTC.C SG MRES.CSG 9.359 39.719 1 192.000 1369.000 39.719 0.277 -0.018 502.250 208.875 Z.160 46.125 649. 500 45.251 510.803 O. 31:0 - 999...250 -999.250 · -999. 250 LLD. DLL TENSoDLL DT.LSS TT3.LSS CALS.LSS HTEN.LSS PEFoLDT L-U.LDT SS2.LDT LSRH.LDT TENS.L~T NPHI .CNL RCNT.CNL GR.CNL MTEM.CNL TNRA.CSG CNTC.CSG MR ES. C SG 0.150 44.844 1 367. 000 514.000 44.844 0.277 -0.935 161.125 54.375 LLD. DLL TENS.DLL DT.LSS TT3 .LSS CALS.LSS HTEN. LSS PEF.LDT LU.LgT SSZ.LDT 63.719 -999.250 -999.250 -999.250 12.7.50 2964.000 133.750 1803o000 10.141 116T. 000 2.428 468.250 324.500 2.082 2084.000 37.079 1963.336 42.375 63.188 -999.250 -999.250 -999.250 12.123 :a 0:04.000 149.750 1968.000 10.352 1192.000 Z. 617 460.500 323.750 2.090 1910.000 42.475 1847.063 46. 125 62'156 -999.250 -999.250 -999.250 0.444 3070.000 57.625 973.000 8.664 1367=.000 23.578 158..250 96.250 HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM. DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QL$.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL NPOR.CSG CF?C.CSG MTEM.CSG CALS.DLL MTEM. DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS.LDT LLoLDT LSHV.LDT LURH.LDT MTEM. LDT TNPH.CNL RCFT. CNL CALI.CNL MTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.OLL MTEM.DLL DTL.LSS TT4.LSS TENS.LSS DPHI .LDT QLS.LDT LL.LDT LSHV.LDT PAGE: 15 705°000 -999.250 -999.250 -999.250 10.141 66.375 132.250 1531.000 2964.000 35.202 -0.009 277.250 1401.000 2.082 63.188 40.634 462.918 10.555 673.000 -999.250 -999.250 -999.250 10.352 65.625 150.250 1670.000 3004.000 34.935 -0.010 272.000 1401.000 2.092 62.156 43.273 478.826 10.594 649.500 -999.250 -999.250 -999.250 8.664 65.250 372.750 728.000 3070.000 51.484 0.110 82.000 1404..000 SCHLUMBERGER ALaSK~e~ COMPUTING CENTER 30-aUG-1989 10=65 SSHV..LDT 1321.000 S1RH.LDT 4.707 CALI.LDT 8. 852 GR.LDT 47.156 MRES.LDT 0.312 HTEN.LOT 709.500 TNRA.CNL 4.437 NPOR.CNL 58.544 CNTC.CNL 11.13..203 CFTC.CNL 256.495 TENS.CNL 1985.000 MRES.CNL 0.312 NPHI.CSG 59.713 TNPH.CSG -goo.z50 RCNT.CSG 1182.639 RCFT.CSG 203.549 GR.CSG 44.219 TENS.CSG 1910.000 HTEN.CSG 696.500 DEPT. 2500.000 LLS.DLL SP.oOLL -999.250 GR. DLL MRES.DLL -999.250 HTEN.DLL TT1.LSS -999. 250 TTZ.LSS SP.LSS -999.250 GR.LSS MTEMoLSS -999.250 MRES.LSS RHOB.LDT -999.250 DRHO.LOT QSS.LDT -999. 250 LS.LDT LITH..LDT -999.250 SSI.LOT SSHV.LD'T -999.250 S1RH.LDT CALI.LD~T -999. 250 GR.LDT MRES. LDT --999. 250 HTEN.LOT 'TNRAoCNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL TENS..CNL -999.250 MRES.CNL NPHI.CSG 51.400 TNPH.CSG RCNT.CSG 12'40.742 RCFT.CSG GR.CSg 30.234 TENS.CSG HTEN.CSG 681o 500 OEP'T. 2400. 000 LLS. DL;L SP.DLL -999.2 50 GR.DLL MRESoDLL -999.250 HTEN.DLL TT1.LSS -999. 250 TT2.LSS SP.LSS -999.250 GR.LSS MTEM.LSS -999.250 MRES.LSS RHOB. LDT -999.250 DRHO.LDT QSS.LDT -999. 250 LS.LDT LITH.LOT -999. 250 SSi. LOT SSHV.LDT -'999.250 S1RH.LDT CALI.LDT -9 99.2 50 GR.LDT MRES.LDT -999.250 HTEN.'LDT TNRA.CNL -999.250 NPDR.CNL CNTC.CNL -999.250 CFTC.CNL TENS.CNL -999.250 MRES.CNL NPHI.CSG 49.336 TNPH.CSG RCNT.CSG 1175.258 RCFT.CSG GR.CSG 27.344 TENS.CSG HTEN.CSG 673.000 - 9'99.250 -999. 250 -999.250 -999.250 -999.250 -999. 250 --999.7.50 -999.250 -999. 250 -999. 250 -999.250 --999.250 -999.250 -999. 250 - 999.250 -999.250 261.524 1875.000 LSRH.LDT TENS.LOT NP HI .:C NL RCNT.CNL GR. CNL MTEN.CNL TNRA.CSG CNTC.CSG MRES.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 · -999.2~0 -999.250 -999.250 -999.250 -999. 250 -999.250 277.158 1870. 000 LLD .DLL TENS.DLL OT.LSS TT3.LSS CALS.LSS HTEN,.LSS PEF.LDT LU. LDT SS2.LDT LSRHiLDT TENS.LOT NPHI.CNL RCNT.CNL O R. C NL MTEM.ENL T:NRA.CSG CNTC.CSG MRES.CSG OEP'T. 2300. 000 LLS.OLL -999. 250 SP.DLL -999. 250 GR.DLL -999. 250 MRES.DLL -999.250 HTEN.DLL -999.250 TT1.LSS -9<)9.250 TTZ.LSS -999. 250 LLDoDLL TENS.DLL DT.[ SS TT3.LSS CALS.LSS HTEN.LSS PEF.LDT LU.LDT SSZ.LDT L S RH. LDT TENS.LDT NPHI.CNL RCNT.CNL GR .CNL MTEM.CNL TNRA.CSG CNTC.CSG MRES.CSG LLD. DLL TENS.DLL DT. LSS TT3.LSS 2.734 1985. O00 59.838 1154.201 47.156 61.313 4. 678 11:06.150 0.313 -999.250 -999.250 --999°250 -999..250 --999.250 -999.250 -999°250 --999..250 -999.250 -999..250 -999.250 -999..250 -999.250 -999.250 '-999.250 1150.193 0.320 -999.250 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999°250 -999.250 4.109 1084o926 0.327 -999.250 -999.250 -999.250 -999.250 LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI.CNL HTENoCNL NPOR.CSG CFTCoCSG MTEMoCSG CAL S. DLL MTEM. DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT ~LSoLDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPHoCNL RCFT. CNL CALI.CNL HTEN. CNL NPOR.CSG CFTC .CSG MTEM.CSG CALS.DLL MTEM.DLL DTL.LSS TT4oLSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURHoLDT MTEM. LDT TNPH.CNL RCFT.CNL C~LI.CNL HTEN. CNL NP~R.CSG CFTC.CSG MTEMoCSG CALS.DLL MTEM.DLL DTL.LSS TT4.LSS PAGE: 2.789 61.313 58.369 261.524 8.852 709.500 -999.250 243.444 62.656 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 266°299 60.500 -999.250 -999.250 -999.250 -999.250 -999.2.50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2~0 -999.2~0 -999.250 277.703 58.906 -999.250 -999.250 -999.250 -999.2~0 16 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER SP.LSS -9gg. 2 SO GR.LSS MTEM. LSS -999. 250 MRES.LSS RHOB.LDT -99'9.250 DRHO.LDT QSS.LDT -999.2 50 LS.LDT LiTH.LDT -999.250 SS1.LDT SSHV.LDT -999. Z50 SIRH.LDT CALI. LDT -999o250 GR.LDT MRES.LDT -999.250 HTEN.LOT TNRA..,CNL -999.250 NPDR.CNL CNTC.CNL -999.2.50 CFTC.CNL TE,NS.CNL -999.250 MRES.CNL NPHI.CSG 59.596 TNPH.CSG RCNT.CSG !I24. 594 RCFT.CSG GRoCSG 40.875 TENS.CSG HTEN.CSG 673.500 O E P'T.,. Z200.0 O0 LLS .DLL SP.DLL -999. 250 GR.DLL MRES.DLL -999.250 HTEN.DLL TTIoLSS -999. 250 TTZ.L SS SP.LSS -999.250 GR.LSS MTEM.LSS -999.250 MRES.LSS RHOB.LDT -999. 250 DRHO.LDT QSS.LOT -999.250 LS.LDT LITH.LDT -999. 250 SS1-LDT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999. 290 GR.LOT MRES.LDT -999.250 HTEN.:LDT TNRA. CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL TENS.CNL -999.250 MRES.CNL NPHI.CSG 56.836 TNPH.CSG RCNT.CSG 1161.281 RCFT.CSG GR.CSG 32.906 TENS.CSG HTEN.CSG 663.000 DEPT. 2100.000 LLS.DLL SP.DLL -999.250 GR.DLL MRES. DLL -999.250 HTEN.DLL TT1.LSS -999. 250 TTZ.LSS SP.LSS -999.250 GR.LSS MTEM.LSS -999.250 MRES.LSS RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999. 2150 LS.LDT LITH.LDT -999. 250 SSl. LOT SSHV.LDT -999.250 SIRH.LDT CALI:.LDT -999.2 50 GR.LOT MRES.LDT -999. 250 HTEN.LOT TNRA. CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL TENS.CNL -999.250 MRES.CNL NPHI.CSG 51.5;3;3. TNPH.CSG RCNT.CSG 1124.594 RCFT.CSG GR.CSG 26.125 TENS.CSG HTEN.CSG 651.500 3 O- AUG-1989 10:45 -999.250 CALS.LSS -999.250 -999.250 HTEN.LSS -999.250 -999.250 PEF.LDT -999.250 -999. 250 LO-LOT -999.250 -999°250 SS2.LOT -999.250 -999. 250 LSRH.LDT -999.250 -999.. 250 TENS.LOT -999.250 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999..250 GR.CNL -999.250 -999. 250 MT EM.CNL -999. 250 -999.2:50 'TNRA..C SG 4.672 243.483 CNTC.CSG 1097.282 1850.000 MRES.CSG 0.328 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2:50 .-999.250 -999.250 228.141 LLD.DLL 'TENS. DLL DT.LSS TT3.LSS CALS.LSS HTEN.LSS PEF.LDT LU.LDT SS2.LDT LSRH.LOT TENS.LOT NPMI.CNL RC NT. C NL OR. CNL MTEM. CNL TNRA.CSG CNTC.CSG MRES.CSG -999.250 - 999. 250 -999.250 -999.250 -999° 250 -999.250 -999.250 - 999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 276.033 17451..000 LLD. DLL TENS.DLL DT.LSS TT3.LSS CALS.LSS HT EN. L S :S PEFiLDT LO.LOT SS2.LDT LSRH.LDT TENS .LOT NPHI. CNL RCNT.CNL GR .CNL MT EM. CNL TNRA.CSG CNTC.CSG MR ES .:C SG -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 4..520 1125.317 0.334 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .-999.250 -999. 250 -999.250 -999.250 - 999. 250 -999.250 -999.250 -999.250 -999.250 11'11.619 0.342 TENS .LSS DPHI.LDT QLS..LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI.CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM. DLL DTL.LSS TT4.LSS TENS.oLSS DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALI. CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM. DLL DTL.LSS TT~..LSS TENS .LSS DPHI.LDT QL S.LOT LL.LDT LSHV.LDT LURH.LDT MTEM. LDT TNPH.CNL RCFT.CNL CALI.CNL MTEN. CNL NPOR.CSG CFTC.CSG MTEM.CSG PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 254.584 57.375 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 246.019 56.625 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 257.411 55.500 17 SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. 2000. 000 LLS. DLL SP.DLL -999. 250 GR.DLL MRES~,DLL -999.250 HTEN..DLL TT1.LSS -999.250 T'T2... L SS SP.LSS -999.2:50 GR.LSS MTEM. LSS -999.250 MR:E. S.LSS RHOB.LDT -999.250 DRH-O.LDT QSS..LDT -999. 250 LS-:LOT LITH.LDT -'999. 250 SS1.LDT SSHV-LDT -999.250 $1RH.LDT CALIoLDT -999.250 S'R.LDT MRES. LDT '-999.250 HTEN..LOT TNRAoCNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL TENS.CNL '-999.250 MRES.CNL NPHIoCSG 52.927 TNPH.CSG RCN'T.CSG 1224.135 RCFT.CSG GR,.CSG 31.406 TENS.CSG HTEN.CSG 669.500 DEPT. 1900.000 LLS.DLL SP.OLL -999.250 GR.DLL MRES.. DLL -999.250 HTEN.DLL TT1.LSS -999.2 50 TT2.LSS SP. LSS -999.250 GR.LSS MTEM. LSS -999.2 50 MRES.LSS RHOS.LDT -999.250 gRHO.LDT QSS.LDT -999. 250 LS.LDT ~LITH.LDT -999.250 SS1.LDT SSHV..LDT -999.250 SIRH.LOT CALI.LDT -999. 250 GR.LOT MRES.LDT -999.250 HTEN.LDT TNRA. CNL -999.250 NPOR.CNL CNTCoCNL -999.250 CFT:C.CNL TENS.CNL -999.25D MRES.CNL NPHI.CSG 51.913 TNPH.CSG RCNT.CSG 1232.438 RCFT.CSG GR.CSG 35.156 TENS.CSG HTEN.CSG 687.500 DEPT. 1800. 000 LLS.DLL SP.DLL -999.250 GRoDLL MRES.DLL -999.250 HTEN.DLL T'Ti.LSS -999. 250 TT2.LSS SP.L$S -999. 250 GR.LSS MTEM. LSS -999. 250 MRES.LSS RHOB.LDT -999.250 DRHO.LDT QSS.LDT -999. 250 LSoLOT LITH.LDT -999. 250 SS1.LDT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999.250 GR.LDT MRE'S.LDT -999o 250 HTEN.LDT TNRA.CNL -999. 250 NPOR.CNL CNTC.CNL -999,250 CFTC.CNL 3 O-AUG-1989 10:45 -999,250 LLD.DLL .-999.250 -999.250 TENS.DLL --999,250 -999. 250 DT.LS$ -999.250 -999.250 TT3.LSS -999,250 -999.250 CALS.LSS --999.. Z50 -999.250 HTEN.LSS -999.250 -999..250 PEF.LDT -9:99.250 -999. 250 LU.LDT --999. 250 -999.250 SS2.LDT -999,250 -999.250 LSRHoLDT -999.250 -999.250 TENS.LOT --999.250 -999.250 NPHI.CNL -999.250 -999. 250 RC NT.:C NE -999.250 -999.2 50 GR.CNL -999.250 -999,.250 MTEM.CNL --999°250 -999.250 TNR~..CSG 4.306 259.755 CNTC. CSG 1169.510 1790. 000 MRES.CSG 0.348 -999.250 LLD.DLL -999.250 TENS.DLL -999.250 OT.LSS -999.2.50 TT3.LSS -999.250 CALS.LSS -999.. 250 HTEN.LSS -999.250 PEF.LDT -999.250 LU.LDT -999.250 SS2.LDT -999. 250 LSRH.LDT -999.25~0 TENS.LOT -999. 250 NPHI.CNL -999.250 RCNT.CNL -99'9. 250 GR.CNL -999.250 MTEM.~NL -999.250 TNRA.CSG 261.524 CNT'C.C SG 1590.000 MRES.CSG -999,250 --999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999..250 -999.250 -999.250 ~.250 1145.726 0.355 -999.-250 LL:D.DLL '-999.250 -999.250 TENS.DLL -999.250 -999. 250 DT.LSS -999. 250 -999.250 TT3.LSS -999.250 -999.250 CALS.LSS -999..250 -999.Z50 HTEN.LSS --999.250 -999.250 PEF.LDT -999.250 --999. 250 LU.LDT -999. 250 -999.250 SS2.LDT -999.250 -999. 250 LSRH. LDT -999.250 -999..250 TENS.LOT -999.250 -999.250 NPHI.CNL '-999.250 -999. 250 RCNT.CNL -999.250 · -999.25'0 GR.CNL -999.25D CALS.DLL MTEM. DLL DTLoLSS TT4.LSS TENS.LSS DPHI.LDT ~LS.LDT LL.LDT LSHV. LO'T LURH.LDT MTEM.LOT TNPH.CNL RCFT. CNL CALI.CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM.DLL OTL.LSS TT¢.LSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURM.LDT MTEM.LDT TNPH.CNL RC FT. C'NL CALI.CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM.DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURHoLOT MTEM. LDT TNPH.CNL E CFT. CNL CALI.CNL PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 268.918 54.125 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 272.052 5~.0~! -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -~99.250 18 SCHLUMBERGER ALASKA COMPUTING CENTER TENS. CNL -999.250 MRES.CNL NPHI.CSG 51o435 TNPH.CSG RCNT..,CSG 1070.494 RCFT.CSG GR.CSG 42.,281 TENS.CSG HTEN. CSG 703.5 O0 DEPT. 1700.000 LLS.OLL SP. DLL -999.2.50 GR. DLL MRES. DLL -999.250 HTEN. DLL TTI.LSS -999. 250 TT2.LSS SP.LSS -999. 250 GR.LSS MTEM.LSS -999.250 MRES.LSS RHOB.LDT -999.250 gRHO. LDT QSS.LDT -999.2 50 LS.LDT LITH.LDT -999.2 50 SSI.LOT SSHVoLDT -999.250 SIRH.LDT CALI.LDT -999. 250 GR.LDT MRES.LDT -999.250 HTEN.LDT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL TENS.CNL ,-999.250 MRES..CNL NPHI.CSG 53.7B8 TNPH.CSG RCNT.CSG 1108.020 RCFT.CSG GR.CSG 32. 000 TENS.CSG HTEN. CSG 682°500 DEPT. 1600.000 LLS.DLL SP.DLL -999. 250 GR.DLL MRES.DLL -999.250 HTEN.DLL TT1. LSS -999. 250 TT2. LSS SP.LSS -999.250 GR.LSS MTEM. LSS .-999.250 MRES.LSS RHOB.LDT -999.2150 DEMO.LOT QSS.LDT -999.250 LS.LOT :LITHoLDT -999. 250 S S1.EDT SSHV.LDT -999.250 SIRH.LOT CALI.LDT -999.2 50 GR.LDT MRES.LDT -999. 2150 HTEN.LDT TNR~.CNL -999'.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL TENS.CNL -999.250 MRES.CNL NPHIoCSG 53.79'3 TNPH..CSG RCNT.CSG 1199.234 RCFT.CSG GRoCSG 38.844 TENS.CSG HTEN. CSG 691.500 DEPT. 1500. 000 LLS.DLL SP.DLL -999.250 GR. DLL MRES.DLL -'999.250 HTEN.DLL TT1.LSS -999. 250 TT2. LSS SP.LSS -999,250 GR.LSS MTEM. LSS -999.250 MRES.:LSS RHOB.LDT -999.250 DRHO.LDT QS S.*LOT -999. 250 LS.LDT LITH.LDT -999. 250 SS1.LOT 30-~UG--1'989 10.45 -999.250 MTEM. CNL -999.2.50 TNRA. CSG 244.049 CNTC.CSG 1690.000 MRES.CSG -999..250 LLD.DLL -999.250 TENS.DLL -999.250 DT.LSS -999.250 TT3.LSS -999.2S0 CALS.[SS -999.250 HTEN. LSS -999.250 PEF.LOT -999.250 LU.LDT -999.250 SS2.LDT -999.250 LSRH.LDT -999.250 TENS'LOT -999.250 NPHI.CNL -999. 250 RCNT.CNL -999. 250 GR.CNL -999.250 MTEM.CNL -999.250 TNR~.CSG 227.215 CNTC.CSG 1610.000 MRES.CSG -999. ~50 LLD.DLL - 999. 250 TENS.OLL -999.250 DT.LSS -999.250 TT3.LSS -999. 250 CALS.LSS -999.250 HTEN.kSS -999.250 PEP.LOT -999.250 LU.LDT -999.250 SS2.LDT -999. 250 LSRH.LDT -999. 250 TENS.LOT -999.250 NPHI.CNL -999. 250 RCNT.CNL - 999.. 250 GRoCNL -999.250 MTEM. CNL -999.250 TNRA.CSG 24~. 049 CNTC.CSG 1625. 000 MRES.CSG -999.250 1109.743 0.362 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2~0 -999.2S0 -999.250 -999.250 -999.250 4.353 1060.2~1 0.365 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 --999.250 -999.250 -999.250 -999.250 4.353 1176. 193 0.365 -999.250 LLD.DLL -999.250 -999.250 TENS.DLL -999.250 -999.250 DT.LSS -999.250 --999.250 TT3oLSS -999.250 -999.250 CALS.LSS -999.250 '-999.250 HTEN.LSS -999.250 -999.250 PEFoLDT -999.250 -999.250 LU.LDT -999.250 -999.250 SSZ.LDT -999.250 HTEN. CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM.DLL DTL.LSS TT4.LSS TENS.LSS DPHI.LDT ~LSoLDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPHoCNL RCFToCNL CALI.CNL HTEN.CNL NPOR.CSG CF?C.CSG MTEM.CSG C AL S. DLL MTEM. DLL OTL.LSS TT4.LSS TENS.LSS DPHI .LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM.LDT TNPH.CNL RCFT.CNL CALZ.CNL HTEN.CNL NPOR.CSG CFTC.CSG MTEM.CSG CALS.DLL MTEM.DLL DTL. LS S TT4.LSS TENS.LSS OPHI.LDT QLS.LDT LL .LOT LSHV.LDT PAGE: -999.250 -999.250 268.796 51.656 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 243.142 51.156 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2E0 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 274.890 50.781 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 '-999.2~0 -999.250 -999.250 19 SCHLUMBERGER ALASKA COMPUTING CENTER SSHV.LD'T -999.250 S1RH.LDT CALI. LOT .-999.2 50 GR.LDT MRES.LDT -999.2~-0 HTEN.LDT TNRA,CNL -999,250 NPOR.CNL CNTC,CNL -999,250 CFTC,CNL TENS,CNL -999.250 MRES,CNL NPHI,CSG 48..9.38 TNPM.CSG RCNT,CSG 1484,295 RCFT.CSG GR,CSG 41.$¢4 TENS.CSG HTEN. CSG 691,5D0 DEPT. 1456.000 LLS.DLL SP.DLL -999. 250 GR.DLL MRES,DLL -999. 250 HTEN.DLL TT1,LSS -999,2 50 TTZ.LSS SP,LSS -999.250 GR.LSS MTEM.LSS -999.250 MRES.LS'S RHDB.LDT -999.250 ORHO.LDT QSS.LDT -999.2 50 LS.LOT LITH.LDT -999. 250 SS1.LDT SSHV.LDT -999.250 S1RH..LDT CALI.LDT -999. 250 GR.LDT MRES,LDT -999.250 HTEN.LOT TNRA.CNL -999.250 NPOR.CNL CNTC.CNL -999.250 CFTC.CNL TENS.CNL -999.250 MRES.CNL NPHI.CSG 46.615 TNPH.CSG RCNT,CSG 1232,438 RCFT,CSG GR,CSG 45.594 TENS.CSG HTEN. CSG 677.000 END OF DATA FILE NAME SERVICE VERSION D A'TE MAX REC SIZE FILE TYPE LAST FILE EDZT .001 FL IC 001A02 1024 LO ***'* F IL E FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE HEADER ~,#, : EDIT .002 : FLIC : 001A02 : 89/08/30 : 1024 .'. LD 30.-~UG.-1989 10:45 -999.250 LSRH.LDT -999.250 TENS.LOT -999.250 NPHIoCNL -999.250 .~CNT.CNL -999.250 GR.CNL -~99. 250 MTEM. CNL -999.250 TNRA.CSG 305.240 CNTC.CSG 1,¢95.000 MRES.CSG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ~. 08'7 1402.253 0..373 -999. 250 LLD.DLL -999. 250 -999.250 TENS.OLL -999.250 -999. 250 DT.LSS -999.2.50 -999.250 TT3.LSS -999.250 -999.250 CALS.LSS -999.250 -999..250 HTEN,LSS -999.250 -999,250 PEF.LDT -999,250 -999.250 LU.LOT -999.250 -999.250 SS2..LD'T --999.250 -999.250 LSRH.LDT -999.250 -999.250 TENS.LOT -999.2.50 -999.250 NPHI.CNL -999.250 -999.250 RCNT.CNL -999.250 -999. 250 GR.CNL -999. 250 -999.250 MTEM,CNL -999.250 -999.250 TNRA.CSG 3.960 303.914 CNTC.C;SG 1206.089 1470.000 MRESoCSG 0.373 LURH.LOT MTEM.LDT TNPH.CNL RCFT.CNL C AL I. CNL MTEN,CNL NPOR.CSG CFTC,CSG MTEM, CSG CALS.DLL MTEM.DLL DTL.LSS TT4.LSS TENS,.LSS DPHI .LOT QLS.LDT LL.LDT LSHV.LDT LURH.LDT MTEM. LDT TNPH.CNL RCFT.CNL CALI .CNL HTEN.CNL NPOR,CSG CFiC,CSG MTEM,CSG PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 332.841 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2~0 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 321.805 50.156 2O LIS TAPE VERIFICi~TION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 30-AUG-1989 10:45 PAGE: 21 FILE - EDIT.O02 CDNDCD INC. MILNE POINT MILNE POINT UNIT G-1 5 0-029-;2192 7-00 4725j TO 2618~ DATA SAMPLED EVERY -.[667 FEET DATA INCLUDED - MSFL ONLY TOOL EXTENSION TOOL TYPE US ED NAME DLL .DLL DUAL LATEROLOG TABLE TYPE : CONS T UN I VAL'U CN CONOCO INC. FN MILNE POINT WN MILNE POINT UNIT G-! APIN 50-029-21927-00 FL 3644~" FNL~ & 3:346" FEL SECT 27 TOWN RANG 10E COUN NOR'TH SLOPE STAT AL/~SKA NAT:I USA ENGI SARBER WITN ZOTZKY/FOX SON 548436 P DA'T M SL EPD FT 0 LMF RKB APO FT 59.3 EKB FT 59.3 EOF FT 5.8. EGL FT 29.5 TOD FT 4745. D6FI --- COMPANY NAME FIELD NAME WELL NAME API SERIAL NUM6ER FIELD LOCATION SECTIaN TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION ENGINEER'S NAME WITNES$'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM LIS TAPE YERI~'ICAT~ON LISTING SCHLUMBERGER aLASKA COMPUTING CENTER 30-:~UG-lgBg 10:45 ~AGE: 22 TABLE TYPE : CURV OEF! D E P T M SFL DEPTH CHANNEL NAME MSFL RESISTIVITY DATA FORMAT SP!EC~FIiCATION RECORD SET TYPE - 64E8 ~'* TYPE REPR CODE VALUE I 66 0 2 66 0 5 66 6 73 T 65 8 68 0.166 11 66 t28 12 68 13 66 0 14 65 ~T 15 66 68 16 66 0 66 1 ~ SET TYPE - CHAN ~ NAME SERV UNIT .SERVICE API API API API FILE NUMB NUMB SIZE REPR ' PROCESS ID ORDER e LOG TYPE CLASS MOD NUM,~ SAMP ELEM CODE (HEX) DEPT FT 548436 O0 0~00 OD 0 2 ! ! 4 68 O0000000OO MSFL DLL OHMM S48.436 11 270 04 0 2 1 I 4 68 0000000000 ,,t. DATA *~ DEPT. 4736.833 MS-mL.DLL 4.332 DEPT. 4700.000 MSFL.DLL 15.500 DEPT. 4600.000 MSFL.DLL 3.283 LIS TAPE YERIEICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. 4500.000 MSFL.DLL DEPT. 4400. 000 MSFL.DLL DEPT. 4300.000 MSFL.DLL DEPT. 4200.000 MSFL.gLL DEP'T. ,4100.000 MSFL.DLL DEPT. 4000.000 MSFL.DLL DEPT. 390D.000 MSFL.DLL DEPT. .3800.000 MSFL.DLL DEPT. 3700.000 MSFL.DLL DEPT. .3600. 000 MsFL.DLL DEPT. 3500.000 MSFL.DLL D EP'T.. 3400. ODD MSFL.DLL DEPT. 3300.000 MSFL.DLL DEPT. 3200.000 MS F~L. C,.,LL DEPT. 3100.000 MS~L.I]LL DEPT. 3000.000 MS~L.DLL DEPT. 2900.000 MSCL.DLL OEP'T. Z8OO'OOO MSFL.DLL DEPT. 2700. ODO MS~LoDLL DEPT. 2600.000 MSFL.OLL DEPT. Z590.500 MS~L.DLL END DF DATA 30-AUG--198'9 10:45 4.167 4.332 4.120 6.637 2.155 3.013 6.046 2.999 7.375 6..484 3.631 2.070 2.63! 3.889 3.143 3.424 4.570 1. '740 1.716 0.270 0.275 PAGE: 23 [.IS TAPE VERIFICATION -LISTING SCHLUMBERGER ~LASKA COMPUTING CENTER 30-AUG-1989 **** FILE TRAILER FiLE NAME : EDIT .002 SERVICE : ~LIC VERSION : OO1A02 DATE : MAX REC SIZE : 1024 FILE TYPE : Lg LAST FILE FILE NAME : EDIT .003 SERVICE : FLIC VERSION : OOIAO2 DATE : 89/08/30 MAX REC SIZE : 10124 FILE TYPE : LO LAST FILE : FILE - EDST.O03 CONOCO INC. MILNE POINT MILNE POINT UNIT G-! 50-029-21927-00 REPEAT PASS LOG DATA DATA SAMPLE~ eVERY;- -.1000 DATA INCLUDED - TOOL EX TENS ION 'TOOL TYPE USED NAME LOT .LDH CNT-A/D./H .CNH L!THO DENSITY COMPENSATED NEUTRON 47 35' TO 3~'B8' ~f+715' TO 3488' LIS TAPE VERIFICATION LISTING SCHLUMBERGER aLASKA COMPUTING CENTER TABLE TYPE : C~NS TUNI 30-AUG-lgBg 10:45 V~_LU DEFI PAGE: 25 CN FN WN APIN FL SECT TOWN RANG COUN STAT NATI ENGI WITN SON PDAT EPD LMF APD EKB EOF EGL T OD FT FT FT FT FT FT CONOCO INC. MILNE POINT MILNE POINT UNIT G-! 50-029-2!927-00 3644' FNL~ & 3346' FEL 27 ! 3N NORTH SLOPE ALASKA SAR~ER ZOTZKY/FOX 548436 M SL O. 59.3 59.3 58. 29.5 4745. COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION ENGINEER'S NAME WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM TABLE TYPE : CU~V OEPT D PHI RHOB DRHO PEF QLS QSS LS LU LL LITH SS! SSZ LSHV SSHV S1RH LSRH LURH CALt GR TENS MTEM DEPTH CHANNEL NAME DENSITY POROSITY 5ULK DENSITY DELTA RHO PHOTO-E'L EC'TR IC FACTOR QUALITY CONTROL OF LONG SPACING FO~ LOT QUALITY CONTROL ON SHO~T SPACING FOR LOT LONG SPACING COMPUTED COUNT RATE (LL+LU/Z) LONG UPPER !-2 WINDOW COUNT ~ATE (LU!+L~U2) LONG LOWER W:.NDOW COUNT RATE LITHOLOG WINDOW COUNT RATE SHORT SPACING 1 WINDOW COUNT RATE SHORT SP~CING Z WINDOW COUNT R~TE LONG SPACING HIGH VOLTAG~ OUTPUT SHOR'T SPACING HIGH :VOLTAGE LOOP OUTPUT 'SHORT SP~C'~NG I gENSITY L~NG SPACING RHOB (UNCgRRECT~D) LONG UPPER RHO~ CALIPER GAMMA RAY TENSION MUD TEMPERATURE LIS TAPE VERIFICATION ~LIST!NG SCHLUMBERGER ALASKA COMPUTING CENTER 30.-~UG-1989 10:45 MRES HTEN NPHI 'TNPH TNRA NPOR RCNT RCFT CNTC CFTC GR CALI TENS MRES MTEM HTEN DEFI MUD RESISTIVITY HE AD TENSION NEUTRON PORDSITY THERMAL NEUTRON POROSI'TY CALIBRATED THERMAL :NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CO~RRECTEO NEAR THERMAL Cg:UNTS RAW CORRECTED ~A~ THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORREC'TED mAR 'THERMAL COUNTS GAMMA RAY CALIPER TENSION MUD RESISTIVITY MUD TEMPERATURE HEAD TENSION PAGE: 26 ~ DA'TA FORMAT SPECIFICATION RECORD · ~ SET TYP~ - 64LB ~ TYPE REPR COOL V~ALUE 1 66 0 2 66 0 3 73 I52 4 66 5 66 6 73 7 5.5 B. 68 0.099 g 65 FT 11 66 6 12 ,68 13 66 0 1~ 65 FT 15 66 68 16 66 0 66 I ,-~ SET TYPE - CHAN NAME SERV UNI'T SERVICE API API API API FILE NUMB NUMB SiZ~ REPR PROCESS iD ORDER .~ LOG T~YPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 54~4 ,'~6 O0 000 O0 0 3 I I 4 68 O00000000O DPHI LDH PU 54~436 42 890 O! 0 3 I I ~ 68 0000000000 RHDB LDH G/C3 548436 42 350 OZ 0 LIS TAPE V~RIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 30-~UG-1989 10:45 PAGE: 27 NAME SERV UNIT SERVICE API ID ORDER ~ LOG T ~PI API A:PI YPE CLASS MOO --e FILE NUMB NUMB SAMP DRHO LDH G/C3 548436 42 356 01 0 3 1 PEF LDH 543436 42 1358 O1 0 3 1 OLS LDH 548436 42 354 01 0 3 QSS LDH ~48436 42 354 01 0 3 1 LS LDH CPS 545436 412 354 01 0 LU LDH CPS 548436 42 354 01 0 3 LL LDH CPS 548436 42 354 01 0 3 1 LITH LDH CPS 548436 42 354 Oi 0 3 1 SSI LDH CPS 548436 42 354 02 0 3 1 SS2 LDH CPS 548436 42 354 02 0 3 1 LSHV LDH V 548436 42 354 O0 O 3 1 SSHV LDH V 548436 4~ 354 O0 0 3 1 S1RH LDH G/C3 548436 42 350 02 0 3 LSRH LDH G/C3 548436 42 350 02 0 3 1 LURH LDH G/C3 S4~436 42 350 02 O 3 1 CALI LDH IN 549436 42 280 O1 0 3 1 GR 'LDH GAPI 54~436 42 310 O1 0 3 1 TENS LDH L~ 540436 42 635 21 0 3 1 MTEM LDH DEGF 548436 42 DO0 MRES LDH GHMM 548436 42 OOO O0 0 3 1 HTEN LDH L~ 5~436 42 OOO O0 0 3 1 NPHI CNH PU 548436 42 890 O0 0 3 1 TNPH CNH PU 548436 42 ~90 O0 0 3 1 TNRA CNH 5.48436 42 420 O! 0 3 1 NPD~ CNH PU 54~436 42 890 OD 0 3 1 RCNT CNH CPS 54~436 42 420 O1 0 3 1 RCFT CNH CPS 548436 42 420 O1 0 3 1 CNTC CNH CPS 548436 42 420 O1 0 3 1 :CFTC CNH CPS 548436 42 420 O1 O 3 t GR CNH G:&PI 548436 42 3~0 O1 0 3 1 CRLI CNH IN 548436 42 280 O1 0 3 1 TENS CNH L8 548436 42 ~35 21 0 3 1 MRES CNH OHMM ~43436 42 000 O0 0 3 1 MTEM CNH DEGF ~43436 42 000 OD 0 3 1 HTEN CNH L8 548436 42 OOO O0 0 3 1 NUMB ELEM 1 1 1 1 1 1 1 ! 1 1 1 1 1 1 '1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 SIZE 4 4 4 4 4 4 4 4 REPR CODE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 PROCESS CHEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA DEPT. 4779.200 DPHI.LOH 24o314 PEF.LDH 2.684 .QLS.LDH -0.056 LU.LDH 438.750 LL.LDH 243.000 SSZ.LDH 3t'5. 500 LSHV.LDH 1407.000 LSRH.LOH 2.129 LURH.LDH 2.119 TEN:S.LDH 1295.000 MTEM.LOH 80.563 NPMi. CNH 49.874 TNPH.CNH 45.934 RCNT.CNH 2113.190 RCFT.CNH 521.465 GR.CNH 112.1.88 CALI.CNH' 6.848 MTEM.. CNH 80. 563 HTEN.CNH -46. 781 RHOO.LDH QSS.LDH LITH.LDH SSHV.LDH CALI. L DH MRES.LDH TNRA.CNH CNTC. CNH TENS.CNH 2.249 0.020 135.375 1321.000 6.848 0.25{3 3.749 2032.283 1295.000 DRHO.LDH LS.LDH SS1.LDH S1RH.LDH GR.LDH HTEN.LOH NPOR.CNH CFTCoCNH MRE$.CNH O.llB 462.500 255.750 1.892 112.188 -46.781 45.934 54g.872 0.258 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. 4700. 000 DPHI.LDH PEF.LDH 2.701 QLS.LOH LU..LDH 311.750 LL.LOH SS2.LDH 303.250 LSHV.LDH LSRH..LDH 2.309 LURH.LDH TENS..LOH .2890.000 MTEM.LDH NPHI.CNH 37.250 TNPH.CNH RCNT.CNH 2060.259 RCFT.CNH G~.CNH 100.063 CALI.CNH MTEM.CNH 81.125 HTEN.CNH DEPT. 4600. 000 DPHI. LOH PEF.LDH 2. 938 QLS.LDH LU. LDH 325.750 LL.LDH SS2.LDH 303.500 LSHV.LDH LSRH.LDH 2.277 LURH.LDH TEN'S.LDH 2730. 000 MTEM.LDH NPHI.CNH 41.6:.53 TN~H.CNH RCNT..CNH 19:29.4:53 ~CFT.CNH GR.CNH 9.2.625 CALI.CNH MTEM.CNH 81.688 HTEN.CNH DEPT. 4500.000 DPHI.LDH PEF.LDH 3.014 qLS.LOH LU.LDH 304. 000 LL..LOH SS2.LDH 307.750 LSHV.LDH LSRH. LDH 2.3.28 LURH..LDH TENS.LDH 2630.000 MTEM.LDH NPHI.CNH ,~2. 894 TNPH.CNH RCNT.CNH 1866.213 RCFT.CNH GR.CNH 108.625 CALI.CNH MTEM.CNH 81.500 HTEN.CNH DEPT. 4400.000 DPHI.LOH PEF.LDH 2.883 ~LS.LDH LU.LDH 363.250 LL.LDH SS2.LDH 318.250 LSHV.LOH LSRH.LDH 2.230 LURH.LOH TENS.LDH 2584.000 MTEM.LDH NPHI.CNH 42.562 TNPH.CNH RCNT.CNH 1833.335 RCFToCNH GR.CNH 89.813 CALI.CNH MTEM.CNH 80.813 HTEN.CNH DEPT. 4300.000 DPHI.LDH PEF.LDH 2.691 ~LS.LOH LU.LDH 343.000 LL.LDH SSZ.LDH 325.250 LSHV.LDH LSRH.LDH 2.254 L:URH.LOH TENS.LDH 2670.000 MTEM.LOH NPHI.CNH 41.689 TNPH.CNH RCNT.CNH 1615.169 RCFT.CNH GR.CNH 96.625 CALI.CNH MTEM.CNH 79.750 HTEN.CNH 30-AUG-1989 10:45 20. 583 RHOB.LDH O- 008 QSS.LOH 1 ~31.. 1375 LITH.LDH 1410.000 SSHV.LDH 2. 318 CALI.LDH 81.125 MRE.S.LDH 36. 009 TNRA.[NH 613.346 CNTC.CNH 8.688 TENS.CNH 725.500 22.465 RHOB.LDH 0.013 QSS.LOH 192.250 LITH.LDH 1410.000 SSHV.LDH 2-291 CALI.LOH 81. 688 M:RES.LDH 39.683 TNRA.CNH 514.726 CNTC.CNH $.711 TENS.CNH 650.090 16.410 RHOB.LOH -0.010 QSS.LOH 172.000 LITH.LOH 1411.000 SSHV.1DH 2 . 334 CAL'[ .LDH 81.500 MRES.LDH 40.751 TNRA.CNH 465.485 CNTC.~NH 8.781 TENS.CNH 631. 000 2¢.622 RHOB.LDH -0.030 QSS.LDH 204. 625 IITH.LDH 1411.000 SSHV.LDH 2.229 CALI.LDH 80.813 MRES.LDH 40.737 TNRA.~NH 548.326 CNTC.CNH 8. 969 TENS.CNH 639.000 21.283 RHOB.LDH 0.000 QSS.LDH 200-. 125 LITH. LDH 1410.000 SSHV.LDH 2. 262 CALI.LDH 79.750 MRES.LDH 39. 968 'TNRA.CNH -~50.923 CNTC.CNH 10.164 TENS.CNH 675.000 2.310 0.011 104.188 1322.000 8.688 0.254 3.190 1992.057 2890.000 2.279 0:. 019 107. 375 1321.000 8.711 O. 237 3.432 1893.101 2730..000 2.379 0.048 89.125 1322.000 8.781 0.239 3.506 1806.559 2630.000 2.244 0.021 118.$00 1322.000 8.969 0.241 3.503 1783.453 2584.0:00 2.299 0.026 119.313 1321.000 10.164 0.246 3.553 1583.408 2670.000 DRHO.LDH LS.LDH SS1.LDH S1RH. LDH GRoLDH HTEN.LDH NPOR.CNH C~TC.CNH MRES.CNH ORHO.LDH LS.LDH SS1.LDH S1RH.LDH GR.LDH HTEN.LDH NPOR.CNH C FTC. CNH MRES.CNH DRHO.LDH LS.LDH SS1.LOH S1RH.LDH GR.LDH HTEN.LOH NPOR.CNH CFTC.CNH MRES.CNH DRHO.LDH LS.LDH SS1.LDH S1RH. LDfl GR.LDH HTEN.LDH NPOR.CNH CFTC.CNH MRES.CNM DRHO.LDH LS.LDH SS1.LDH S1RH.LDH GR.LDH HTEN.LDH NPOR.CNH CFTC.CNH MRESoCNH PAGE: 0.001 337.250 207.875 2.305 100.063 725.500 35.271 645.880 0.254 0.001 355.250 209.250 2.275 92.625 650.000 40.783 570.683 0.237 0.051 324.000 224.000 2.205 108.625 631.000 ¢1.667 533.349 0.239 0.012 386.250 218.500 2.184 89.813 639.000 40.537 525.342 0.241 0.044 371.750 226.625 2.1¢5 96.625 675.000 40.438 465.866 0.246 28 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. 4200.000 DPHI.LOH PEF.LDH 2.088 QLS.LDH LU.LDH 455. 000 LL.LDH SS2.LDH 323.750 LSHV.LDH ~LSRH.LDH 2.096 LURH.LDH TENS-LDH 2544. OOO MTEM.LDH NPHI.CNH 39. 293 TNPH.CNH RCNT.CNH 2152.956 RCFT.CNH GR.CNH 43.188 CALI.CNH MTEM. CNH 78. 500 HTEN.£NH DEPT. 4100.000 OPHI,LDH PEF.LDH 2- 035 QLS.LDH LUoLDH 441.2 50 LL-LOH SS2.LDH 331.2 50 LSHV.LDH LSRH.LDH 2.113 LURH.LDH TENS.LDH 2450.000 MTEM.LDH NPHI.CNH 38.536 TNPH.CNH RCNT.CNH 1808.175 RCFT.CNH GR.CNH 85. 3113 CALI.CNH MTEM.CNH 77.375 HT~N.CNH DEPT. 4000.000 DPHI.LDH PEF. LDH 2. 297 QLS.LDH LU.LDH 401.750 LL.LDH SS2.LDH 316.750 LSHV.LDH LSRH.LDH 2.1 82 LURH.LDH TENS.LDH 2380. 000 MT EM..LgH NPHI.CNH 40.435 TNPH.CNH RCNT.CNH 1929.453 'RCFT..CNH G~.CNH 66.41)8 CALI.CNH MTEM.CNH 76.438 HTiEN.CNH DEPT. 3900.000 DPHI.LOH PEF.LDH 2. 195 QLS.LDH LU.LDH 418. 250 LL.LDH SS2.LDH 320.250 LSHV.LOH LSRH.LDH 2. 127 LURH.LDH TENS.LDH 2330.000 MTEM.LOH NPHI.CNfl 40.736 TNPH.CNH RCNT.CNH 1781.999 RCFT.CNH GR.CNH 52.813 CALI.CNH MTEM.CNH 7.5.438 HTEN.CNH DEPT. 3800.000 DPHI.LDH PEF.LDH 2.514 QLS.LOH LU. LDH 426.2150 LL.LDH SS2.LDH 317.500 LSHV.LOH ~LSRHoLDH 2.145 LURH.LDH TENS.LDH 2384.000 MTEM.L~H NPHI.CNH 3.9..768 TNPH.CNH RCNT.CNH 17t8.918 RCFT.CNH GR.CNH 60.625 CALI.CNH MTEMoCNH 7~.375 HTEN.CNH 30-AUG-1989 10:45 34. 376 RHOB.LDH -0.002 QSS.LOH 272.250 LITH.LDH 1408.000 SSHV.LDH 2.100 CALI.LDH 78.500 MRES.LDH 40. 219 TNRAoCNH 553. 951 CNTC. CNH 8. 563 TENS.CNH 651.000 31.663 ~HOB.LOH -0.006 QSS.LDH 263.000 LITH.LDH 1405.000 SSHV.LDH 2.115 CALI.LDH 77. 375 MRES.LDH 40.4.24 TNRA.CNH 446. 349 CNTC.CNH 8.633 TENS.CNH 629. 000 28.915 RHOB.LDH -0.049 QSS.LDH 222.$75 LITM.LDH 1407.000 SSHV.LDH 2. 170 CALI.LDH 76. 438 MRESoLDH 39.705 TNRA.CNH 571.014 CNTC.CNH 8. 664 TENS.CNH 613.000 32.045 RHOB.LDH 0.038 QSS.LDH 263.250 LITH.[DH 1406. 000 SSMV.LDH Z.146 CALI.LDH 75.438 MRES.LDH 41.020 TNRA.CNH 512.715 CNTC.CNH 9.430 TENS.CNH 613.500 30.379 RHDBoLDH -0.036 QSS.LDH 242.500 LITfl. LDH 1407.000 SSHVoLDH 2.135 CALI.LDH 74.1375 MRES.LD:H 37.075 TNRA.CNH 514.726 CNTC.CNH 8.883 'TENS.CNH 643.500 2.083 0.002 190.375 1321.000 8.5.63 0.250 3.292 1981..579 2544.000 2.128 0.034 180.500 1321.000 8.633 0.254 3.256 1685.788 2450.000 2.173 0.001 137.375 1321.000 8.664 0.257 3.362 1809.071 2380.000 2.121 0.016 179.250 1320.000 9.4.30 0.260 3.4.41 1754.874 2330.000 2.14.9 0.038 158.125 1321.000 8.883 0.264 3.343 1796.695 2384.000 DRHD.LDH LS.LDH SS1.LDH S1RH.LDH GR.LDH HTEN.-LDH NPQR.CNH CFTC.CNH MRES. CNH DRHO.LDH LS.LDH SSloLDH SIRH.LDH GR.LDH HTEN.LDH NPOR.CNH CFTC.CNH MRES.CNH DRHO.LDH LS.LDH SS1.LDH SIRH.LDH GR.LDH HTEN.LDH NPOR.CNH CFTC.CNH MRE$.CNH DRHD.LDH LS. LDH SS1.LDH SIRH.LDH GR.LDM HTEN.LDH NPOR.CNH CFTCoCNH MRES.CNH DRHD.LDH LS.LDH SSloLDH SIRH.LDH GR.LDH HTEN. LDH NPDR.CNH CF?C.CNH MRES.CNH PAGE: -0.015 499.750 210.375 2.154 43.188 651.000 40.064 592.490 0.250 0.013 483.750 226.000 2.061 85.313 629.000 39.277 501.663 0.254 -0.009 423.750 209.000 2.219 66.438 613.000 38.258 545.480 0.257 -0.007 472.500 213.500 2.152 52.813 613.500 40.897 511.252 0.260 455.500 218.875 2.127 60.625 643.500 37.514 568.431 0.264 29 [.~ IAF~ YERIEICATION LISTING SCHLUMBERGER ALASKA CDMPUTING CENTER DEPT. 3700.000 DPHI.LOH PEF.LDH 1. 999 ~LS.LDH LU.LDH 465. 500 LL.LDH SS2.LDH 327.750 LSHV.LDH LSRH.LDH 2.086 LURH.LDH 'TENS.LOH 2304.000 MTEM.LOH NPHI.CNH 39. 867 TNPH.CNH RCNT.CNH 1908.879 RCFT.CNH GR.CNH 36.594 CALI..CNH MTEM. CNH 72.685 HTEN.CNH DEPT. 3600.000 DPHI.LDH PEF.'LDH 2. 369 QL$.LDH LU.LDH 440.000 LL.LDH SS2.LDH 322.000 LSHV.LDH LSRH.LDH 2.107 LURH.LDH 'TENS.LDH 2240.000 MTEM.LDH NPHI..CNH 43. 870 TNPH.CNH RCNT.CNH 1824.09! RC~T.CNH GR.CNH 53.656 CALI.CNH MTEM,.CNH 71.438 HTEN.CNH DEPT. 3500.000 DPHI.LDH PEF.LDH 2.766 QLS.LDH LU.LDH 395. 000 LL.LDH SSZ.LDH 316. 000 LSHV.LDH LSRH.LDH 2.174 LURH.LDH TENS.LDH 2240.000 MTEM.LDH NPHI. CNH ~6.492 TNPH.CNH RCNT-CNH 1707.64.2 RC~T.CNH GR.CNH ~88. 875 CALI.CNH MTEMoCNH 70.063 HTENoCNH DEP'T. 34~97. 900 DPHZ.LOH PEF.LDH 3.279 ~LS.LDH LU.LDH 435.500 LL.LOH SS2.LDH 325.250 LSHV.LOH LSRH. LDH 2.109 LURH.LDH TENS.LDH 2320.000 MTEM.LDH NPHI.CNH 54. 550 TNPH.CNH RCNT.CNH 1474.606 RC~T.CNH GR.CNH 94.250 CALI.CNH MTEM. CNH 70.56.3 HTEN.CNH END OF OA'TA ** 30-~UG-1989 10:45 34.806 -0.005 277.250 1406.000 2.086 72.688 40.448 471.512 12.164 628.500 33. 266. 1405. 2. 71. 42. 10. 29. 231. 70. 45. 440. 9. 643. 33. O. 262. 1~05o 2. 70. 48. 327. 9. 646. 81.~ 008 750 000 117 438 262 098 141 500 673 009 875 000 180 063 584 883 016 000 078 002 250 000 123 563 619 557 000 000 RHOB.LDH QSS.LDH LITH.LDH SSHV.LDH CALI.LDH MRES.LDH TNRA. CNH CNTC,CNH TENSoCNH RHOS.LDH QSS.LDH LITH'LDH SSHV.LDH C~LI.LDH MRES.LDH TNRA. CNH CNTC.CNH TENS.CNH RHOB.LDH QSS.LDH LITH.LDH SSHV.LDH CALI.LDH MR E S -L DH TNRAoCNH CNTC. C NH TENSoCNH RHOB.LDH QSS.LDH LITH.LDH SSHV.LDH CALI.LDH MRES.LDH TNRA.CNH CNTC.CNH TENS.CNH 2°076 0.005 193.000 1320.000 12.164 0.271 3.536 t729.968 2304,.000 2.092 -0.002 172.500 1320. 000 10.141 0.27~ 3.670 1640. 374 2240.000 2.160 -0.003 136o750 1320.000 9.016 0.277 3.722 1704.815 2240.000 2.104 0.009 145. 750 1320.000 9.000 0.277 4.160 1451.087 2320.000 DRHO.LDH LS .LDH SSL.LDH SIRH.LDH GR.LDH HTEN.LDH NPOR.CNH CFTCoCNH MRES.CNH DRHO.LDH LS.LDH SS1.LDH SIRH.LDH GR.LDH HTEN.LDH NPDR.CNH CFTC.CNH MRES.CNM DRHOoLDH LS.LDH SS1.LDH SIRH.LDH GR.LDH HTENoLDH NPOR.CNH CFTCoCNH MRE$.CNH DRHO.LDH LS.LDH SS1.LDH SIRH.LDH GR.LDH HTEN. LDH NPOR.CNH CFTC.CNH MRES.CNH PAGE: -0.010 510.000 213.375 2.127 36.594 628.500 39.678 493.192 0.Z71 -0.017 486.750 208.375 2.176 53.656 614.500 41.825 463.417 0.274 -0.014 429.500 206.875 2.229 88.875 643.000 46.885 0.277 -0.007 480.250 214.000 2.139 94.250 646.000 49.891 373.959 0.277 3O LIS TAPE VERIEICATION LIS?ING SCHLUMBERGER ALASK~ COMPUTING CENTER 30-AUG-1989 10:45 P~GE: 3! · *~X-' FILE TRAILER EILE NAME : SERVICE : FLIC VERSION : 001~02 DATE : 8g/oB/']O MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ~,~:~ TAPE TR AIL E.R~--' ~-*-'._.~..,. SERVICE NAME :EOIT DATE : 89/0~/30 ORIGIN : ~LIC TAPE NAME : 73442 CONTINUATION ~ : ! PREVIOUS TAPE : COMMENT : CONOCO INC.,M~.NE POINT, M~LNE POINT UNIT G.-I,50-O2~-21gZ?-O0 **** REEL 'TRAILER **** SERVICE NAME : EDIT DATE : 89/08/30 ORIGIN : ~=LIC REEL NAME : '7344Z CONTINUATION ~ : PREVIOUS REEL : COMMENT : CR-NOCD INC.,MILNE P~-INT~MILNE POINT UNIT G-1~50-02~-21~27-00 **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 89/09/05 ORIGIN OF DATA: RLL REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 89/09/05 ORIGIN OF DATA: G-1 TAPE NAME: Milne Pt CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE ********** Alaska Oil a aaa Cons~ Commissio;~ Arlchomge ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: MWD REV SERVICE NAME: SSDS VERSION #: REV 2.3A DATE: 89/09/05 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY 255 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# L0G TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 NFO MWD CTS 0 0 0 0 1 4 0 1 68 NFl MWD CTS 0 0 0 0 1 4 0 1 68 NN0 MWD CTS 0 0 0 0 1 4 0 1 68 NN1 MWD CTS 0 0 0 0 1 4 0 1 68 RATE REPEAT FT/H 0 0 0 0 1 4 0 1 68 GRCR REPEAT AAPI 0 0 0 0 1 4 0 1 68 EWRR REPEAT OHMM 0 0 0 0 1 4 0 1 68 FXER REPEAT HRS 0 0 0 0 1 4 0 1 68 NFOR REPEAT CTS 0 0 0 0 1 4 0 1 68 FN1R REPEAT CTS 0 0 0 0 1 4 0 1 68 NNOR REPEAT CTS 0 0 0 0 1 4 0 1 68 NN1R REPEAT CTS 0 0 0 0 1 4 0 1 68 RBR REPEAT G/C3 0 0 0 0 1 4 0 1 68 TVD GYRO FT 0 0 0 0 1 4 0 1 68 NDIS GYRO FT 0 0 0 0 1 4 0 1 68 EDIS GYRO FT 0 0 0 0 1 4 0 1 68 DEVI GYRO DEG 0 0 0 0 1 4 0 1 68 EWR MWD OHMM 0 0 0 0 1 4 0 1 68 FXE MWD HOUR 0 0 0 0 1 4 0 1 68 ROP MWD FT/H 0 0 0 0 1 4 0 1 68 GRC MWD AAPI 0 0 0 0 1 4 0 1 68 CALR REPEAT INCH 0 0 0 0 1 4 0 1 68 CAL MWD INCH 0 0 0 0 1 4 0 1 68 RHOB MWD G/C3 0 0 0 0 1 4 0 1 68 NPSR REPEAT P.U. 0 0 0 0 1 4 0 1 68 NPS MWD P.U. 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY BLOCKS ENTRY DESCRIPTION 255 LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 N~F0 ~{WD CTS NFl MWD CTS NN0 MWD CTS NN1 MWD CTS RATE REPEAT FT/H GRCR REPEAT AAPI EWRR REPEAT OHMM FXER REPEAT HRS NFOR REPEAT CTS FN1R REPEAT CTS NNOR REPEAT CTS NN1R REPEAT CTS RBR REPEAT G/C3 TVD GYRO FT NDIS GYRO FT EDIS GYRO FT DEVI GYRO DEG EWR MWD OHMM FXE MWD HOUR ROP MWD FT/H GRC MWD AAPI CALR REPEAT INCH CAL MWD INCH RHOB MWD G/C3 NPSR REPEAT P.U. NPS MWD P. U. 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 ** 589 DATA RECORDS ** ** FILE TRAILER** FROM 2350.00 TO FILE NAME: MWD REV SERVICE NAME: SSDS VERSION #: REV 2.3A DATE: 89/09/05 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ** TAPE TRAILER** SERVICE NAME: SSDS DATE: 89/09/05 ORIGIN OF DATA: G-1 TAPE NAME: Milne Pt CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT 5000.00 FT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 89/09/05 ORIGIN OF DATA: RLL REEL NAME: CONOCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT