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178-021
David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 07/15/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well: PBU 06-07 PTD: 178-021 API: 50-029-20299-00-00 Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/22/2024 Main Folder Contents: Please include current contact information if different from above. 178-021 T39199 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.16 08:06:48 -08'00' 11209, 11263, 11432 7000 / 7740 / 8430 4990 / 6280 / 7500 Drilling Manager 05/02/24 Monty M Myers By Grace Christianson at 12:22 pm, May 02, 2024 SFD 5/3/2024 DSR-5/2/24 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112(i) approved for alternate plug placement with fully cemented liner on upcoming sidetrack and window exit within the PB oil pool. * Window to be milled below the PB oil pool confining zones. MGR13MAY24 10-407 JLC 5/16/2024 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz CTD Engineer Date: May 1, 2024 Re: 06-07 Sundry Approval Request Sundry approval is requested to plug off the 06-07 production as part of the preparation, drilling and completing the proposed 06-07A coiled tubing sidetrack. Proposed plan for 06-07A: Prior to drilling activities, Slickline will drift for a whipstock and run a caliper, E-line will perform a tubing punch just below the packer at ~10341' MD. Service coil will then lay cement from ~11,003' MD in the 9-5/8" casing and brought up inside the 4-1/2" tubing tail to ~10,341' MD in preparation for a 2.74" pilot hole and whipstock. A coil tubing sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will mill a 2.74" pilot hole to ~10,800', run a caliper to confirm contact with the 9-5/8" casing, then run and set the 3-1/4" whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and drill an S-shaped well through Zones 2, 3, and 4 to TD. The proposed sidetrack will be completed with a 2-3/8 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will target isolating and abandoning the parent Ivishak perfs. This Sundry covers plugging the existing perforations via the packer whipstock, liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in May 15, 2024) Reference 06-07 Sundry submitted in concert with this request for full details. 1. Slickline : Set DGLVs, Drift, Caliper 2. E-Line : TBG Punch just below packer at 10341 MD 3. Coil : Lay in ~38 bbls of 15.8 ppg Class G cement from ~11003 to 10341 for pilot hole. 4. Valve Shop : Pre-CTD Tree Work 5. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in September 3, 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 psi). 2. Mill 2.74" pilot hole to ~10,800' MD and Caliper. 3. Set 3-1/4" whipstock at ~10,722' MD and mill 2.74 Window. 4. Drill production lateral: 3.25" OH, ~2104' (12 deg DLS planned). 5. Run 2-3/8 13Cr liner to TD, release off liner and POOH. 6. RIH and sting into ORCA valve. Pump primary cement job: 18 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig perforate (~30) and RPM. Ryan Ciolkosz CC: Well File CTD Engineer (907)244-4357 Joe Lastufka This completionp , p will target isolating and abandoning the parent Ivishak perfs. PTD 224-043 Sundry 324-266 Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Choke Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Sundry Application Well Name______________________________ (PTD _________; Sundry _________) Plug for Re-drill Well Workflow This process is used to identify wells that are suspended for a very short time prior to being re-drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on the Form 10-403. Geologist 2 If the Abandon box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that checkbox and instead, check the "Suspended" box and initial those changes. Geologist The drilling engineer will serve as quality control for steps 1 and 2. Petroleum Engineer (QC) 3 When the RA2 receives a Form 10-403 with a check in the "Plug for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." Research Analyst 2 4 When the RA2 receives Form 10-407, they will check the History tab in RBDMS for the IPBRD code. If IPBRD is present and there is no evidence that a subsequent re-drill has been completed, the RA2 will assign a status of SUSPENDED to the well bore in RBDMS. The RA2 will update the status on the 10-407 form to SUSPENDED, and date and initial this change. If the RA2 does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. Research Analyst 2 5 When the Form 10-407 for the redrill is received, the RA2 will change the original well's status from SUSPENDED to ABANDONED. Research Analyst 2 6 The first week of every January and July, the RA2 and a Geologist or Reservoir Engineer will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all Plug for Redrill sundried wells have been updated to reflect current status. At this same time, they will also review the list of suspended wells for accuracy and assign expiration dates as needed. Research Analyst 2 Geologist or Reservoir Engineer PRUDHOE BAY UNIT 06-07 SFD 5/3/2024 324-266 SFD 5/3/2024 178-021 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 06-07 Set Plug w/ Cement Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 178-021 50-029-20299-00-00 11610 Conductor Surface Production Scab Liner Liner 9339 92 2706 11565 8130 10362 20" 13-3/8" 9-5/8" 5-1/2" x 4-1/2" 8327 25 - 117 26 - 2732 23 - 11588 2085 - 10378 25 - 117 26 - 2732 23 - 9320 2085 - 8340 11209, 11263, 11432 470 2670 4760 6280 10362 1490 4930 6870 7740 10815 - 10835 4-1/2" x 3-1/2" 13Cr80 21 - 10110 8684 - 8700 Structural BKR S-3 PKR 10032 / 8078 10032 8078 Bo York Sr. Area Operations Manager Ryan Thompson Ryan.Thompson@hilcorp.com 907.564.5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028311 None Installed 21 - 8137 None Installed 136 552 24402 36752 1146 290 668 1995 472 892 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 1:17 pm, Oct 26, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.10.25 15:54:52 -08'00' Bo York SFD 10/26/2021 DSR-10/26/21MGR26OCT2021 RBDMS HEW 10/28/2021 ACTIVITYDATE SUMMARY 9/4/2021 ***WELL SI ON ARRIVAL*** DRIFT & TAG WITH 22' OF 2.66" DUMMY GUN @ 11244' MD Completed ***WELL LEFT SI*** 9/13/2021 T/I/O= 2500/1000/0. LRS 72 Assist E-Line (PERFORATING) Pumped 220 bbls of KCl and 40 bbls of crude into the TBG. Final T/I/O= 40/1100/0 9/15/2021 ***WELL SHUT IN ON ARRIVAL****** (JOB SCOPE: ZONAL ISOLATION/DUMP CEMENT/ADPERF) RIH W/ 9-5/8'' NEO T-TBP. CORRELATE TO SLB RST LOG 06-MAY-2007. SET NEO T-TBP BASKET AT 11,020'. CCL TO BASKET OFFSET=18.8', CCL STOP DEPTH=11001.2'. MANLIFT NOT WORKING. RIH W/ 2.5" X 20' DUMP BAILER W/ BEADS & CSG CLEANER. SET DOWN AT XN-NIP AT 10356'. UNABLE TO GET THRU. POOH W/ BAILER. BAILER EMPTY AT SURFACE. ***JOB IN PROGRESS*** 9/16/2021 ***JOB CONTINUED FROM 16-SEP-2021*** RUN 3: RUN W/ 30X2.5" BAILER W/ MULE SHOE. TAGGED EARLY AT 10338' RUN 4: RUN W/ 2.125" DRIFT. UNABLE TO MAKE IN PASS 10338'. POOH FOR SLICKLINE TO TROUBLESHOOT ***JOB IN PROGRESS*** 9/18/2021 ***WELL S/I ON ARRIVAL*** RAN 2.72" BARBELL, 2.68" LIB TO 10,321' SLM (impression of shear stud) RAN 2.72" CENTRALIZER & 2.5" BLIND BOX TO 10,321' SLM, PUSHED PLUG DOWN TO 11,209' SLM ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 10/1/2021 T/I/O = 2400/1140/0, (Assist E-line with load and kill) Pumped 250 bbls of 1% KCL down tubing, Pumped 38 bbls down tubing for FP. FWHP = 0/1300/0 SW, WV, SSV = closed IA, OA = OTG 10/4/2021 ***WELL SHUT IN ON ARRIVAL****** (JOB SCOPE: ZONAL ISOLATION/DUMP CEMENT/ADPERF) RIH W/ 9-5/8'' NEO T-TBP. CORRELATE TO SLB RST LOG 06-MAY-2007. DHD FIND FLUID LEVEL AT 1920'. SET NEO T-TBP BASKET AT 11,020' MD. CCL TO BASKET OFFSET=18.8', CCL STOP DEPTH=11001.2' RUN #1= W/ 2.5" X 30' OF BAILER W/2 GALLONS OF BEADS & 3GALLONS OF CSG CLEANER. RUN # 2= W/2.5'' X 30' OF BAILER W/5 GALLONS OF CEMET 17 PPG DUMP 5 GALLONS OF CEMENT 17 PPG ON NEO T-TBP. ***JOB CONTINUED ON10/05/2021*** 10/5/2021 *** JOB CONTINUE FROM 10/04/2021)*** JOB SCOPE : ZONAL ISOLATION/DUMP CEMENT ESTIMATED TOC AT 11018.3' ELMD FROM 10/4/21 RIH W/ 30' X 2.5" BAILER W/5 GALLONS OF CEMENT 17 PPG. 1.65' PER RUN MADE 5 BAILER (6 TOTAL) RUNS AND DUMPED 25 GALLONS (30 GALS TOTAL) OF 17 PPG NEO SUPER SLURRY CEMENT. FINAL ESTIMATED TOP OF CEMENT @ ~11010' ELM, ***JOB CLOPLETE WELL S/I,ON DEPARTURE WILL RETURN TO FULL RIG DOWN AND MOVE THE EQUIPMENT *** 10/10/2021 ***WELL S/I ON ARRIVAL *** Job Scope: Perforate DHD SHOT FLUID LEVEL AT 1957'. RUN 2.5'' X 20' CONNEX GUN 6SPF 60 Deg PHASE, GUN CORRELATED TO SLB RST LOG 06-MAY-2007. TAG TOC @ 11003'. SHOOT ADDPERF'S FROM 10815' - 10835' W/2.5'' CONNEX 6 SPF 60 Deg PHASE CCL TO TOP SHOOT=10.1' CCL STOP DEPTH=10804.9 ***JOB COMPLETE / TURN OVER TO DSO TO POP*** Daily Report of Well Operations PBU 06-07 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday,June 03, 2015 10:12 AM To: AK, OPS FS3 OSM;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;G GPB FS3 Drillsites;Warner, Scott;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, OPS FF Well Ops Comp Rep;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; Regg, James B (DOA) Subject: OPERABLE: Producer 06-07 (PTD#1780210) MIT-IA Passed Attachments: image001.png; image002.png All, Producer 06-07(PTD#1780210) passed a MIT-IA on 06/02/2015 following slick line work. The passing test confirms two competent barriers in the well. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed • A SSSV is not required Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid expansion. Thank you, Kevin Parkst�[��N�� I���, L �� ,litt1„ !, 11!!list 1t'!1!;.` CN BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, May 22, 2015 7:50 PM To: AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Glasheen, Sean; AK, OPS FS3 Facility OTL Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, OPS FF Well Ops Comp Rep; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; Pettus, Whitney; Weiss, Troy D Subject: UNDER EVALUATION: Producer 06-07 (PTD #1780210) Inner Annulus exceeded MOASP All, Producer 06-07 (PTD#1780210) inner annulus exceeded MOASP on May 19, 2015. Pressures were found on May 20, 2015 to be T/I/O =2440/2210/vac. A subsequent cold and warm TIFL failed, demonstrating a lack of two competent 1 barriers in the wellbore.At this time,the well has been reclassified as Under Evaluation for additional diagnostics. The well may remain online throughout the diagnostic period. Plan Forward: 1. Downhole diagnostics:Cold TIFL—FAILED 05/20/15 2. Downhole diagnostics: Warm TIFL—FAILED 05/21/15 3. Slickline: Dummy valves 4. Fullbore: MIT-IA 5. Well Integrity Engineer:Additional diagnostics as needed. A copy of the TIO plot and wellbore schematic have been included for reference. Please call with any questions or concerns.Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator Uvv U4yti. I.lt o't WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 ' cNj i If) .:••:.&i „.4., U f-. 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' ---- - - i-lo re: 1- m 2 1.14i u .:(3 A 2 2c vl 0 1J."11, xxxxxxxxxxxxxxxxxx I-• 44 1,1. 0 o p- , 4 — , . . . . • 1- mii, :0E, 0 1 4 0 = :1•1•4,It 0 0 4:2 t= 0 0 :s em..._ g 9... (7, g ; c.--w ,T .,2 6 Lue..= e.- v'.. e.- ST' S.' V.' 4... _ C43 a p 0 , %, 0 , _ 000000000109 aq- com 02 ? ....,u 'ia -,;;.- cemeoccomoimo9 ,999 ,80 0_ , o''' coQc, 9999999 -1- 0 -7 0 u 0., C) C g P:. 3;,4 W W co co to to co (.0 (/) to W U) U) U) -0 C2) V= ,... ';.; :.i,.;, XXXXXXXX ›- Xem - ZCOCOCC « x C) 00 m ' -.0 ti al ,:olt m on o:k wit OM 0) 0,03 CO kt- 030000M ci33 8: ai o mC 0 -1 - 00ID Ln ._ Et cn r•-• — - a; - !'zi:-.-,r, m ._ ., ffiL, R, __ F., 4:,,,,. , < < 40 ,- , 0 --- ODQQ0QCC4ri„ El'' 71-1 ':t - ',41,'1. 1:4R1,6161Malf7MMM010= CAMC:2 'eIA (--1„, 0 0 c .m - -E2E8Ew' 't1..-14c444 , 4—eq? .J .gcL ,... eu -07, 0 mr° ,11- ccD ,c4= QcocDo o -di C a) , 0Li.J :E' ._.... • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ,~~. 4... bP Mr. Tom Maunder . ,~ I ~ k ~" Alaska Oil and Gas Conservation Commission `~'~~ ~ `~ ~Ri~ ~ ~ ~~ ~~ 333 West 7th Avenue Anchorage, Alaska 99501 ({ g - ~ ~- I ~~~ Subject: Corrosion Inhibitor Treatments of GPB DS 06 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 06 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-06 Date: 12/10/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 06-01 1750490 50029201720000 NA Sealed NA os-o2 1770780 50029202820000 NA Sealed NA os-o3A 1951520 50029201990100 NA Sealed NA os-oaA 2001020 50029201790100 NA Sealed NA os-05 1780200 50029202980000 NA Sealed NA o6-06B 2050980 50029202010200 NA Sealed NA os-o7 1780210 50029202990000 NA Sealed NA os-o8A 1951950 Soo29203000100 NA Sealed NA 06-09 1790730 50o292oaoooooo NA Sealed NA o6-1oA 1981960 50o292oao2oloo NA Sealed NA 06-11 1791100 50o292oa28oooo NA Sealed NA os-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 06-13A 2061020 50029204570100 NA Sealed NA os-148 2090120 500292oa5802o0 NA Sealed NA 06-15 1800320 50029204590000 NA Sealed NA 06-16 1800330 50029204600000 NA Sealed NA 06-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009 06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009 06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009 06-21 B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 06-22A 1930570 50029208060100 NA 1.5 NA 5.10 10/4/2009 06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009 o6-24A 2000960 50029208220100 NA Sealed NA OPERABLE: 06-07 (PTD #1780210) Tubing integrity restored Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, July 24, 2008 2:48 PM "~`J- To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Roschinger, Torin T.; Kaminski, Alice; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 06-07 (PTD #1780210) Tubing integrity restored Follow Up Flag: Follow up Flag Status: Purple AI I, Well 06-07 (PTD #1780210} passed aMIT-IA on 07/24/08 after dummying off the gas lift valves proving integrity has been restored. The well has been reclassified as Operable and may be brought an line when convenient for operations. Please be prepared far the IA pressure to increase due to thermal expansion as the IA is liquid packed. From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 17, 2008 7:31 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Winslow, Jack L.; Kaminski, Alice Subject: UNDER EVALUATION: 06-07 (PTD #1780210) Sustained Casing Pressure due to TxIA Comm All, Well 06-07 (PTD #1780210) has been found to have sustained casin he IA. The TIO pressures were SSV/2300/0 psi on 07/15/08. A TlFL failed on overnight uild-up rate on 07/16/08 confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to build pressure or return the well to production while Under Evaluation. The plan forward for the well is as follows: 1. D: TIFL -FAILED 2. SL: Set DGLVs 3. FB: MITIA to 3000 psi A TIO plot and wellbore schematic have been included for reference. Please call with any questions. 10!27/2008 OPERABLE: 06-07 (PTD #1780210) Tubing integrity restored • Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Page 2 of 2 10/27/2008 PBU 06-07 PTD 178-021 400G ........................ .............................................. 7~' 7~2ez=,~ • 2.000' ~~ ~~r' s 04116/0^ Odi?8/02 05103/CY' 66110109 05/17i0P., 0/2d08 05/31109 06/07/09 06J1.1./OE 061?7/D9 06/28/09 07i0i/0^.-. 07!12.!08 TREE = FMC GEN 1 WELLHEAD = FMC AC CUA i UR - _ AXELSON KB. ELEV - 6~' ~ "" -..-.. -~ ~ BF. ELEV = -___..,-,..~,~ e.. KOP = 2900' Max Angie = 52 @ 6200' TOP OF 5-112" SCA 2102' Datum MD ~ 1103T " " Datum TV D = 8800' SS 7 x 9-518 Baker ZXP L.NR 1 C3P PKR ~" x 9- i8" F1KR FLFXI..:,sK I.Iv'R ViANGE}~ 2112' TOP OF 7-5J8" LNR 2226' 7-518" SCAB LNR, 29.4#, NT-95HS, ID = 6.875" 2700' 13-318" CSG, 72#, N-80, ID = 12.347" 2732' 06-07 ..r S NOTES: **"CF3RtDME "I`St"*** 200$' --) 4-112" HES X NiP, ID = 3.813" 201$' 4-112" X 3-1(2" XO 2231' -iBAKER SPH MODIFIED LNR PKR, ID = 6.875" 2$94' BAKER 3-D HGR FKR. ID = 6.825" GAS LIFE MANDRELS 3-112" TBG, 9.2#, '13CR-84 (-{ 10110' BOTTOM OF 5-112" SCAB LINER ~-~ 10215' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3414 3394 21 KGB-2-9 DOME INT 16 06125/07 3 6702 5703 48 KGB-2-9 SO INT 20 06(25/07 2 8554 F3cz,}3 42 KGB-2-9 DMY 1NT 0 06I07J07 1 9493 7692 45 KBG-2-9 DMY tNT 0 06107107 10001' I--j3-112" HES X NIP 10032' 5-1J2" x 3-112" BAKER SABL-3 PKR 100$T 3-1J2" HES X Nip 10322' SAKER PBR; iD = 5.875" 10341' 9-518" X 4-1(2° BAKER SB-3 PKR, ID = 3.83" 10355' 4-112" HES XN NIP, !D = 3.725" 4-112" TBG, 12.6#, L-80..0152 bpf, !D = 3.958" 1037$' PERFORATK7N SUMMARY REF LOG: BHCS ON 08121/78 ANGLE AT TOP PERF: 35 @ 11103' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-318" 4 11103 - 11156 S 08/10/95 ? 4 11172 - 11186 S 06!11(87 3-3I8" 2 11186 - 11192 ~ 01(28(96 ? 4 11192 - 11194 S 06/11187 ? 4 11204 - 11206 5 06/11/87 3-318" 4 11206 - 11216 cF 11/02189 3-318" 4 11216 - 11217 S 10117189 3-318" 4 1 i 226 - 11255 C 11 /02/89 3-318" 4 11255 - 11256 S 10/17/89 PBTD -~ 11490" 9-518" CSG, 47#, N-80, ID = 8.681" 115$$° TD 11610" 1037$' ~ 4-1/2" TBG TAIL WLEG, iD = 3.958„ 10352' ELMD TT LOGGED 07104195 11432` ~'~{ 3" JDC DOG LEFT IN HOLE (06/15/95) DATE REV BY COMMENTS DATE REV BY COMMENTS 08126178 ORIGINAL COMPLETION 02(11/07 RCT/PAG GL\/ CIO 06113195 LAST WOfiKOVER 02114107 JPKIPAG GLV CORRECTIONS (02;04107) x9'14/01 RI~L`TP CORRECTIONS 03108!07 ALHIPAG SET XXN @ 10339' (02!03107) 08/19!03 CMO(TLP PERF ANGLE CORRECTION v. 01.f27?07 KSBITLH GLV CIO 06/29/07 JLJiSV GLV CIO 0204107 GJFITLH GLV CIO PRUDHOE BAY UNIT WELL: Os-a7 PERMIT No: 1780210 API No: 50-029-20299-QO SEC 2; T10N, R14E, 670.37' FEL & 4555.7' FNL BP Exploration (Alaska) .' I STATE OF ALASKA .~? ALA KA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUL 1 2 2007 Alaska Oil & Gas Cons. Cammission 1. Operations Performed: o Abandon ~ter Casing lit ftJI.. o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): "" ,>t T,~ 181 Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Re-Enter Suspended Well o Other 99519-6612 o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: 181 Development 0 Exploratory 178-021 --- o Service 0 Stratigraphic 6. API Number: 50-029-20299-00-00 / 64' / 9. Well Name and Number: PBU 06-07 / 8. Property Designation: ADL 028311 . 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11610 " feet true vertical 9339 y feet Plugs (measured) 10339 Effective depth: measured 11490 feet Junk (measured) 11432 true vertical 9239 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 20" 117' 117' 1490 470 Surface 2732' 13-3/8" 2732' 2732' 4930 2670 Intermediate Production 11588' 9-518" 11588' 9320' 6870 4760 Liner Scab Liner 474' 7-5/8" 2226' - 2700' 2226' - 2700' Scab Liner 8143' ~2" 2072' - 10215' 2072' - 8216' 7740 6280 "rI¡ "I ,"\ SCANNED JUL 1 8 2007 Perforation Depth MD (ft): 11186' - 11255' Perforation Depth TVD (ft): 8987' - 9044' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 4-1/2", 12.6# x 3-1/2",9.2# II. 4-1/?" 1? R# 5-1/2" x 3-1/2" Baker 'SABL-3' packer; 9-5/8" x 4-1/2" Baker 'SB-3' packer 13Cr80 I -AO Surface - 10110' 10032' 10341' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut tubing and pull from 10208'. Run ~~-1/2" Scab Liner, cement with 379 Bbls Class 'G' (2128 cu ft /1,834 sx). Run 4-1/2" x 3-1/2" Chrome tubin . A '" Re resentative Dail Avera e Production or In'ection Data Gas-Mcf Water-Bbl Casin Pressure 18592 112 575 2773 127 1400 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 13. Tubin Pressure 230 248 Oil-Bbl Prior to well operation: 1324 Subsequent to operation: 1474 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations Printed Name T~rrie Hubble Signature /ÍtJ Title Technical Assistant Form 10-404 Revised 04/2006 0 R , G , N A L o 7 / ~ / Prepared By Name/Number: Date II £1 07 Terrie Hubble, 564-4628 ),..~ h.'\. ¿ 7/~7 Submit Original Only Digital Wellfile . . Page 1 of 1 Well: 06-07 Well Events for SurfaceWell - 06-07 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS3 -> 06 -> 06-07 Date Range: 17/Apr/2007 to 28/May/2007 Data Source(s): AWGRS Events Source Well ~WGgS 06-07 AWGRS 06-07 AWGRS 06-07 AWGRS 06-07 ~WGRS 06-07 Date OS/28/2007 OS/23/2007 OS/23/2007 OS/20/2007 OS/20/2007 AWGRS 06-07 05/18/2007 AWGgS 06-07 05/18/2007 AWGRS 06-07 AWGRS 06-07 AWGRS 06-07 A WGRS 06-07 AWGRS 06-07 AWGRS 06-07 AWGRS 06-07 AWGRS 06-07 AWGRS 06-07 A'NGRS 06-07 AIJ1GRS 06-07 05/17/2007 05/17/2007 05/16/2007 05/15/2007 05/06/2007 05/06/2007 04/22/2007 04/21/2007 04/20/2007 04/18/2007 04/17/2007 Description PULL BPV / RIG MOVED ON T/I/O=O/O/O. Temp=SI. No AL. Monitor WHP's (Pre-RWO). SET BPV / PRE RIG T/I/O= 720/600/0 Temp= 5/1 Circ-Out (RWO Prep) Pumped 5 bbl neat meth spear followed by 296 bbls of 2% KCL, 742 bbls of 9.2 ppg NaCI brine capped with 67 bbls of diesel for freeze protect, U-tube diesel from tubing to the IA for 1 hour. Bleed WHP's. Freeze protect flow line with 10 bbls of neat methanol, 67 bbls of crude and a 10 bbl diesel tail. Final WHP's = 0/0/0 T/I/O = 710/580/20. 51. Bleed WHPs to 0 psi (pre-Rig). AL spool disconnected, IA with integral, 2" hardline connected to IA and "5" Riser (flowline). Bled TBGP & lAP to 100 psi to bleed trailer (2 hrs), all fluid (12 bbls), OAP decreased to 0 psi during bleed. Called 5104 for Vac truck, bleed trailer at max cap. TBGP increased 610 psi & lAP increased 480 psi and OAP increased 20 psi in 10 min. RDMO. Final WHPs = 710/580/20. T/I/O= 50/600/20 [Pre RWO] Assist E-line. Pumped 4 bbls diesel down tubing- Pressure tested plug to 3500 psi. PASSED- Bleed Tubing FWHP's= 20/600/20 ***JOB CONTINUED FROM 05/17/07 WSR*** INITIAL T/I/O = 100/600/0. SET HES 4-1/2" COMPOSITE FASDRILL PLUG AT 10,362 (MIDDLE OF SECOND 10' PUP JOINT BELOW PACKER). JET CUT TUBING AT 10,205':-IN THE MIDDLE OF THE THIRD FULL JOINT ABOVE THE BAKER (SB-3) PACKER WITH SWS 3.65" O.D. POWER CUTTER. FINAL T/I/O = 800/580/0. *****JOB COMPLETE***** INITIAL T/I/O = 100/600/0 SET HALLIBURTON 4-1/2" FASDRILL COMPOSITE BRIDGE PLUG ME @ 10,362 FT PREPARE TO JET CUT THE TUBING AT 10,205 FT ***CONTINUED ON 05/18/06 WSR*** T/I/O= 50/600/0 Temp= 5/1 MIT-OA (PASSED) @ 2000 psi. (RWO Prep) Pumped down OA 3.6 bbls. 50* crude to reach test pressure of 2000 psi. OA lost 80 psi. in 1st 15 min. and lost 40 psi. in 2nd 15 min. for a total loss of 120 psi., Bleed OAP, Final WHP's 50/600/0 T/I/O = 30/580/VAC. TBG & IA FL ( Pre E-Line). TBG FL @ 150' (4 BBLS) , IA FL @ surface. T/I/0=80/600/0. PPPOT-T (PASS), PPPOT-IC (PASS). Pre-RWO. PPPOT-T: Stung into test void to check pressure (0 psi). Pressured test void to 5000 psi for 30 min test, 4875 psi 15 min, 4800 psi 30 min (PASS). Functioned LDS, all moved freely, no sign of bent or broken pins. PPPOT-IC: Stung into test void to check pressure (0 psi). Pressured test void to 3500 psi for 30 min test, no change in pressure (PASS). Functioned LDS, all moved freely, no sign of bent or broken pins. TAGGED TD AT 11255'. LOGGED THREE REPEATABLE SIGMA PASSES FROM 10500' - TD AS PER PROGRAM. PUMPED TOTAL OF 427 BBLS DEAD CRUDE FOR JOB, 370 AT 5 BPM TO KILL WELL. LEFT WELL SHUT IN W/ SSV CLOSED AS PER DSO. ***Job complete*** T/I/O = 1100/600/0 Assist E-line w/ RSTlog. Pumped 426bbls crude down tubing. FWHP's = 50/600/0 *****JOB COMPLETE***** ***CONTINUED FROM WSR 4/21/07***(PRE-RST) TAG TAIL @ 10366'SLM, -4' CORRECTED TO ELM 10362'ELM. TAGGED BOTTOM @11324'ELM (68' OF RAT HOLE ALL PERFS OPEN) ***NOTIFIED DSO LEFT WELL 5/1, SSV OPEN PER DSO*** ***CONTINUED FROM WSR 4/20/07*** RAN 3" PUMP BAILER W/ NOGO BOTTOM (FLAPPER) S/D@10349' (RECOVERED 2 GAL SAND & 4 PEICES OF SHEER STOCK) PULLED 4.5 XXN PLUG @10352'SLM ***CONTINUED ON WSR 4/22/07*** ***WELL 5/1 ON ARRIVAL *** RIG UP SLICKLINE ***CONTINUED ON WSR 4/21/07*** *** CONT FROM 4-17-07 WSR*** (pre rst) ATTEMPT 3.0 W/ 3.5" NO-GO MAGNET, NO RETURNS ATTEMPT 10' 2.25" PUMP BAILER W/ FINGER BASKET (FLAPPER), RECOVERED +/- 1/2 GAL. SAND RAN 3.0 LIB, CAME BACK WITH 3 STRONG GOUGES ON THE OUTSIDE, NO MARKS ON THE FACE. ***WELL 5/1, SSV NORMALED UP, STBY FOR WEATHER*** *** WELL 51 ON ARRIVAL *** ( pre rst ) ATTEMPTED TO EQUALIZE XXN @ 10344' SLM, NO SUCCESS ATTEMPT TO PULL 4.5" XXN @ 10350' SLM, NO RECOVERY ATTEMPT TO PULL 4.5" XXN @ 10350' SLM, NOT ABLE TO LATCH. SUSPECT POSSABLE BK LATCH JUNK IN PLUG. ***CONT ON 4-18-07 WSR*** hUp:/ / digitalwellfile. bpweb. bp.com/W ellEvents/Home/Default.aspx 7/10/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-07 06-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/21/2007 Rig Release: 6/7/2007 Rig Number: Spud Date: 8/2/1978 End: 5/28/2007 21 :00 - 23:30 2.50 MOB P PRE PJSM- Move Rig Off DS 6-16, to Well DS 6-07. 23:30 - 00:00 0.50 MOB P PRE Spot and Shim Rig. 5/29/2007 00:00 - 01 :00 1.00 RIGU P DECOMP RlU Double Annulus Valve, Spot Slop Tank, RlU for Pre-Spud Check List. Held Pre-Spud Meeting in Dog House with Rig Crew. 01 :00 - 02:00 1.00 RIGU P DECOMP RlU Lines from OA to Slop Tank, RlU #2 Mud Pump. 02:00 - 02:30 0.50 RIGU P DECOMP RlU DSM Lubricator and Pull BPV, RID DSM, IA=3 psi, OA=O psi, Tubing=10 psi. 02:30 - 05:00 2.50 KILL P DECOMP Pressure Test Circulation Lines to 3,500 psi, PJSM with Rig Crew, Mud Engineer, and Truck Drivers. Circulate Out Freeze Protection, Pump 20 bbl Safe Surf 0 Pill, Followed by 20 bbl Hi-Vis Sweep, Followed by 698 bbls of 120 deg 8.5 ppg 1 % KCL Water. 05:00 - 06:00 1.00 KILL P DECOMP Monitor Well for 30 minutes Well Flowing Slightly, Shut Well in For 15 minutes, Pressure Increased to 180 psi. Bleed Off Pressure and Circulate on Choke. Begin Venting OA to Slop Tank. 06:00 - 07:30 1.50 KILL P DECOMP Circulate Bottom Up at 6 bpm with 440 psi Through Jet Cut at 10,205'. Pumped at This Rate Due to Surging of Returns. 07:30 - 12:00 4.50 KILL P DECOMP Monitor Well Bore, Flowed back after 10 minutes. Shut Well in Pressure increased to 180 psi in 30 minutes. Weight up pits. 400 bbls to 9.3 ppg 12:00 - 14:00 2.00 KILL P DECOMP PJSM Well Bore has 170 psi, Lined up on Choke Manifold Circulate 9.3 ppg 1 % KCL Water at 8 bpm with 660 psi. Circulated in 700 bbls and Shut Down Pumps. 14:00 - 14:30 0.50 KILL P DECOMP Monitor Well for 30 minutes. No Flow. 14:30 - 15:30 1.00 WHSUR P DECOMP Blow Down Surface Lines, Set BPV, Test From Below to 1,000 psi for 10 minutes. Blow Down and RID Lines. 15:30 - 17:00 1.50 WHSUR P DECOMP Bleed Down Control Lines, N/D Production Tree, N/D Adapter Flange, Install Blanking Sub, 9 Right Hand Turns to Make Up. 17:00 - 18:30 1.50 WHSUR P DECOMP N/U BOPE and Flow Riser. 18:30 - 22:00 3.50 WHSUR P DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Lou Grimaldi. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Annular Preventer, HCR Kill, HCR Choke, Upper IBOP. Test #2-Manual Choke, Manual Kill, Lower IBOP. Test #3- Choke Valves 1,12,13,14, TIW. Test #4- Choke Valves 9, 11, Dart Valve. Test #5- Choke Valves 5,8,10. Test #6- Choke Valves 4,6,7. Test #7- Choke Valve 2. Test #8- Choke Valve 3 and Blind Rams. Test #9- Lower Rams with 4" Test Joint. Test #10- Lower Rams with 5.5" Test Joint. Accumulater Test- 2,900 psi Starting Pressure, 1,850 psi After Actuation, First 200 psi in 19 seconds, Full Pressure in 1 Minute 14 Seconds. 5 Nitrogen Bottles at 2,200 psi. 22:00 - 22:30 0.50 WHSUR P DECOMP RID Test Equipment Pull Blanking Sub BID Lines. 22:30 - 00:00 1.50 PULL P DECOMP RlU to Lay Down 5.5"x4.5" Completion. Set Lubricator Printed: 6/11/2007 11:18:34 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-07 06-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/21/2007 Rig Release: 6/7/2007 Rig Number: Spud Date: 8/2/1978 End: 5/29/2007 22:30 - 00:00 1.50 PULL P DECOMP Extension in Rotary Table While Waiting on DSM. 5/30/2007 00:00 - 01 :00 1.00 PULL P DECOMP RlU DSM Pull BPV, RID DSM, UD Lubricator. 01 :00 - 01 :30 0.50 PULL P DECOMP M/U Double Spear Assembly with Pack Off for 5.5",17# Tubing and Engage Hanger. 01 :30 - 02:30 1.00 PULL P DECOMP BOLDS, Pull Hanger to Rig Floor, Unseated Hanger at 150,000# Up Weight, Max Overpull175,OOO# Up Weight. UD Spear Assembly and Hanger. 02:30 - 04:00 1.50 PULL P DECOMP RlU Circulation Lines and CBU, at 8 bpm with 740 psi, On Initial Circulation Well Bore took 7 bbls to Fill Hole. RlU Camco Control line Unit on Rig Floor. 04:00 - 07:00 3.00 PULL P DECOMP Monitor Well, Pull and UD 5.5"x 4.5" Completion F/10,205'. Well Bore Taking Calculated Displacement. UD SSSV and XO, RID Camco Control Line Spooler, Recovered 48 out of 56 SS Bands. M/U 4.5" NSCT Floor Safety Valve, RlU 4.5" Handling Equipment. 07:00 - 10:30 3.50 PULL P DECOMP Continue to UD 4.5" Completion String, Monitor Well Bore, Well Out of Balance. String Pulling Wet. 10:30 - 11 :00 0.50 PULL P DECOMP Mix and Pump 15 bbl Dry Job. 11 :00 - 14:00 3.00 PULL P DECOMP Continue to UD 4.5" Completion String. UD 226 Joints, Cut Joint Lenght=18.37', Cut Joint had Clean Cut Flared to 4 3/4", 48 out of 56 SS Bands Recovered. Over All Condition of Tubing Good Internally and Externally. Slight Corrosion at Top of Bevel on Coupling. Ring of Corrosion on The Pin End at Top of Coupling. 14:00 - 14:30 0.50 PULL P DECOMP RID Tubing Handling Equipment, and Clear and Clean Rig Floor. 14:30 - 15:30 1.00 CLEAN P DECOMP Set Wear Ring and Change Out Saver Sub on Top Drive. 15:30 - 16:30 1.00 CLEAN P DECOMP M/U Scraper Assembly, BHA Consists of 8.5" Bit, 95/8" Scraper, Bit Sub, Bumper Jar, XO, 9 - 4 3/4" Drill Collars. 16:30 - 18:30 2.00 CLEAN P DECOMP RIH Picking Up 4" HT-38 Drill Pipe from Pipe Shed. RIH to 2,226". Tagged top of 7 5/8" 2,226' Drill Pipe Measurement. 18:30 - 19:00 0.50 CLEAN P DECOMP CBU at 10 bpm, 660 psi. 19:00 - 19:30 0.50 CLEAN P DECOMP Reciprocate Scraper across Packer Setting Depth 4 Times from 2,226' to 2,020' POOH. 19:30 - 20:00 0.50 CLEAN P DECOMP Rack Back 4 3/4" Drill Collars, UD Scraper BHA. 20:00 - 20:30 0.50 CLEAN P DECOMP P/U and M/U 95/8" RTTS Assembly. 20:30 - 21 :30 1.00 CLEAN P DECOMP RIH to 2,150'. 21 :30 - 22:30 1.00 CLEAN P DECOMP Set RTTS at 2,150' and Test Casing to 3,500 psi for 30 Charted Minutes. Good Test. Released RTTS. 22:30 - 23:30 1.00 CLEAN P DECOMP POOH. 23:30 - 00:00 0.50 CLEAN P DECOMP Rack Back 4 3/4" Drill Collars, UD RTTS Assembly. 5/31/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP MIU Dress off assembly, BHA consists of: Dress off shoe, 2-TSS extensions, wash over junk basket, xo, 2-Junk baskets, bit sub, bumper jar, oil jar, XO, 9-4 3/4" drill collars. BHA=323.26'. 01 :00 - 01 :30 0.50 CLEAN P DECOMP RIH w/20 stds drill pipe from derrick. 01 :30 - 09:00 7.50 CLEAN P DECOMP PIU and RIH with 4" HT-38 drill pipe from Pipe Shed from 3,173 to 10,205'. 09:00 - 12:00 3.00 CLEAN P DECOMP Tagged Tubing Stub at 10,205', Mill with 5-10,000# wob, with 5-7,000 ft-Ibs Torque, Pumping at 4 bpm, with 440 psi, Dress Stump to 10,206'. Can not Get On and Off Stump Without Rotating. 12:00 - 14:00 2.00 CLEAN P DECOMP Pumped 40 bbl Hi-Vis Sweep at 10 bpm with 2,660 psi for 80 Printed: 6/11/2007 11:18:34 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-07 06-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/21/2007 Rig Release: 6/7/2007 Rig Number: Spud Date: 8/2/1978 End: 5/31/2007 12:00 - 14:00 2.00 CLEAN P DECOMP bbl. Then Reverse Circulated at 11 bpm with 3200 psi. 14:00 - 15:00 1.00 CLEAN P DECOMP Slip and Cut Drilling Line. 15:00 - 17:30 2.50 CLEAN P DECOMP POOH to BHA 17:30 - 19:00 1.50 CLEAN P DECOMP Stand Back Drill Collars, Service Junk Baskets Approx 1 gal of Metal Cuttings and Two SS bands in Junk Basket, Total of 50 Out of 56 bands Recovered. Guide Shoe Mill Showed Evidence of Being Off Center and Hanging Up on Tubing Stub. This Cut into the Two of the Guide Shoe Water Courses Approx 4" up Into the Guide Shoe. 19:00 - 22:30 3.50 CLEAN P DECOMP Discussing Options with Anchorage Based Engineers. Waiting on Baker Fishing Machine Shop to Modify Guide Shoe for Next Run. Loading 5.5" Liner In Pipe Shed, Drifting and Preparing Tally. Held a Fire Drill In Conjuction with Rig Evacuation Drill, with Excellent Response with A-Crew. 22:30 - 23:30 1.00 CLEAN P DECOMP M/U Dress off assembly, BHA consists of: Dress off shoe, 1- TSS extensions, wash over junk basket, xo, 2-Junk baskets, bit sub, bumper jar, oil jar, XO, 9-4 3/4" drill collars. BHA=320.09' . 23:30 - 00:00 0.50 CLEAN P DECOMP RIH to 1,529'. 6/1/2007 00:00 - 02:30 2.50 CLEAN P DECOMP Continued to RIH f/1,529' to top of tubing stub at 10,206'. Obtain parameters, up weight=180,OOO#, down weight=140,OOO#, rotating weight=160,OOO#, free torque=5,OOO ft-Ibs, 4 bpm at 430 psi. 02:30 - 04:00 1 .50 CLEAN P DECOMP Unable to slide over tubing stub, Pick up 5' and begin rotating drill pipe. Guide shoe went right over tubing stub, continued slacking off and milled 2' off of tubing stub. New top of stub at 10,208'. Pulled up above stub and slacked off without pumping or rotation, guide shoe swallowed tbg stub. Confirmed second time with same results, on third attempt we had to rotate pipe slightly to get over tbg stub. 04:00 - 05:30 1.50 CLEAN P DECOMP RlU and reverse circulated 20 bbl Hi-Vis sweep at 8 bpm and 1990 psi 05:30 - 06:00 0.50 CLEAN P DECOMP Blow down RID reverse circulating lines and prepare to POOH. 06:00 - 06:30 0.50 CLEAN P DECOMP Service draworks, monitor well. 06:30 - 07:00 0.50 CLEAN P DECOMP Pump 15 bbl dry job blow down top drive. 07:00 - 08:00 1.00 CLEAN P DECOMP POOH stand back 32 jts drill pipe. 08:00 - 14:00 6.00 CLEAN P DECOMP POOH laying down drill pipe to pipe shed. 14:00 - 15:00 1.00 CLEAN P DECOMP Lay down drill collars and dress off assembly. 15:00 - 17:00 2.00 CASE P TIEB1 RlU to Run 5.5" liner. 17:00 - 00:00 7.00 CASE P TIEB1 M/U and Run 5.5",17#, L -80, BTC-M Liner to 4,272'. 6/2/2007 00:00 - 06:30 6.50 CASE P TIEB1 Continue to run 5.5",17#, L-80, BTC-M tie back liner. 06:30 - 07:30 1.00 CASE P TIEB1 Circulate 208-Bbls of 9.3-ppg KCI through Liner at 5-1/2-BPM, 330-psi. Break off and UD circulating line and TIW valve. 07:30 - 11 :30 4.00 CASE P TIEB1 RIH with 21-stands of DP from Derrick. P/U 2-single joints and RIH. M/U cementing head to string and tag stub at 10,208'. P/U wt 170K, S/O wt 142K. Slip easily over stub and see shear pins with 10213' of pipe RIH. See good shear with 15K-lbs off weight and continue on in to bottom out at 10217'. P/U to 10215' and park the string. Veco truck sprayed antifreeze/coolant onto pad-osee Remarks tab for more information. 11 :30 - 13:00 1.50 CASE P TIEB1 RlU Schlumberger cementers to cementing head and pump-in swivel. Hold PJSM with 4-Veco drivers, MI Mud Engr, Printed: 6111/2007 11:18:34 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-07 06-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/21/2007 Rig Release: 6/7/2007 Rig Number: Spud Date: 8/2/1978 End: 61212007 11 :30 - 13:00 1.50 CASE P TIEB1 6-Schlumberger crewmen, Doyon rig crew, Tool Pusher, and Wellsite Leader. PIT lines to 4500-psi. 13:00 - 14:45 1.75 CASE P TIEB1 Start pumping cementing program: 5-Bbls freshwater; PIT line to 4500-psi; 20-Bbls Mud Push; 379-Bbls class G cement slurry @ 15.8-ppg and -850-psi. 14:45 - 15:30 0.75 CASE P TIEB1 Drop dart and turn over to use rig pumps for displacement. Catch cement with 50-Bbls of displacement 9.3-ppg KCI. Kept surface pump pressure under -2200-psi. Bumped the plug at 2442-strokes or 209-Bbls. Let pressure build to set Liner Hanger Packer and see it set @ 3720-psi. Continue to let pressure climb to 4000-psi and hold for 2-minutes. 15:30 - 16:00 0.50 CASE P TIEB1 Bleed off pressure to 1000-psi and slack off to DP string weight of 30,000-lbs plus blocks of 40,000-lbs and rotate 15-tums left to release C-2 Running Tool. Pump 40-Bbls Biozan sweep. Circulate displacement fluids at 8-BPM, then add 2nd pump and increase rate to 12-BPM. RID Schlumberger cementers. See cement at Shakers at 700-strokes or 60-Bbls. Returns clean up at 1650-strokes or 140-Bbls, which is 4-Bbls more than calculated well bore volume to 2000'. Returns were taken to the cuttings tank. 16:00 - 17:00 1.00 CASE P TIEB1 Break off and UD cementing line and pump-in swivel. RlU to reverse circulate 140-Bbls KCI brine and returns are clean, but the first 30-Bbls were taken to the cuttings tank and the remainder to the Pits. 17:00 - 18:00 1.00 CASE P TIEB1 POOH and SIB DP in Derrick, break off and UD the Liner Running Tool assembly. 18:00 - 18:30 0.50 CASE P TIEB1 M/U stack washer, flush stack of cement retums. UD stack washer. 18:30 - 19:00 0.50 CASE P TIEB1 Pull wear ring, set test plug. 19:00 - 20:00 1.00 CASE P TIEB1 Change pipe rams from 3"x 6" VBR, to 2 7/8" VBRs. 20:00 - 21 :30 1.50 CASE P TIEB1 RlU to and Test 2-7/8"x 5" VBRs to 250 psi low test and 3,500 psi high test. RID test equipment pull test plug, install wear ring. 21 :30 - 23:00 1.50 CASE P TIEB1 RlU double stack tongs and CIO to 2-7/8" slips and elevators. P/U BHA to Rig Floor 23:00 - 00:00 1.00 CASE P TIEB1 M/U 4-3/4" Mill tooth bit, XO, 2-3-3/4" Junk baskets. 6/3/2007 00:00 - 00:30 0.50 CASE P TIEB1 Continue to P/U Drill Out Assembly. BHA Consist of: 4-3/4" Bit, 5.5" CSG scraper, XO, 3-junk baskets, bit sub, bumper jar, oil jar, XO, 9 2-7/8" drill collars. BHA=311.55'. 00:30 - 09:30 9.00 CASE P TIEB1 P/U 2-7/8", 1 0.4# Drill Pipe from Pipe Shed 1 x1. 09:30 - 10:30 1.00 CASE P TIEB1 RIH with 10-stands of 4" HT38 DP from Derrick. PIU wt 143K, SIO wt 103K. 10:30·11 :30 1.00 DHB P TIEB1 PU and MU RTTS Packer and Storm Valve to DP, RIH and set one stand below Rig Floor. Test to 1000-psi for 10-minutes. 11 :30 - 13:00 1.50 BOPSU P TIEB1 Blow down lines. Pull wear Ring. Hold PJSM to N/D BOPE. N/D BOPE. 13:00 - 15:30 2.50 WHSUR P TIEB1 BOLDS on Tubing Spool. Remove and replace Tubing Spool and replace packoffs. Call Veco Valve Shop to bring out and install blanking plug due to possible interference of side outlet valve with Rig Cellar. Install blind flange over VR plugged outlet. Call Pad Operator to verify positions of the side outlet valves--he wanted them rolled 180-degrees. 15:30 - 16:00 0.50 BOPSU P TIEB1 N/U BOP Stack to Tubing Spool. Printed: 6/11/2007 11:18:34 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-07 06-07 WORKOVER DOYON DRILLING INC. DOYON 16 17:00 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 20:00 0.50 BOPSU 0.50 DHB 0.50 CASE 1.50 DRILL TIEB1 TIEB1 TIEB1 TIEB1 20:00 - 21 :30 1.50 CASE P TIEB1 21 :30 - 23:00 1.50 CASE P TIEB1 23:00 - 00:00 1.00 DRILL P TIEB1 6/4/2007 00:00 - 00:30 0.50 DRILL P TIEB1 00:30 - 02:00 1.50 CASE P TIEB1 02:00 - 03:30 1.50 CASE P TIEB1 03:30 - 05:00 1.50 CASE P TIEB1 05:00 - 10:00 5.00 CASE P TIEB1 10:00 - 11 :00 1.00 CASE P TIEB1 11 :00 - 17:00 6.00 CASE P TIEB1 17:00 - 18:00 1.00 CASE P TIEB1 18:00 - 19:00 1.00 CASE P TIEB1 19:00 - 20:00 1.00 DHB P TIEB1 20:00 - 20:30 0.50 BOPSU TIEB1 20:30 - 00:00 3.50 BOPSU TIEB1 6/5/2007 TIEB1 TIEB1 TIEB1 TIEB1 1.00 BOPSU P TIEB1 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 06:00 0.50 BOPSU 0.50 BOPSU 1.00 DHB 3.00 DRILL Start: 5/21/2007 Rig Release: 6/7/2007 Rig Number: Spud Date: 8/2/1978 End: Fill BOP stack void and test Tubing Spool and packoffs to 5,OOO-psi for 15-minutes--solid test. Set test plug and perform BOP body test, test to 250 psi low and 3,500 psi high--solid test. RID BOP test equipment. Install wear bushing. P/U stand of 4" DP and retrieve RTTS at 97'. UD RTTS. RIH with 4" HT38 DP from derrick. Tag cement at 9,931'. Establish parameters, Up weight 150,000#, Down weight 107,000#, Rotating weight 126,000#, 3,500 ft-Ibs rotary torque at 40 rpm. Drill cement from 9,931' to 10,117' 13,000 WOB, 5,000 - 6,000 ft-Ibs of rotary torque at 50 rpm, 3,550 psi pump pressure at 5 bpm. Circulate bottoms up. 3,550 psi at 5 bpm. Test casing to 3,500 psi for 30 minutes. Good test. Drill cement and float equipment to 10,118' Drill out float equipment and cement from 10,118' to 10,175' 5,000 ft-Ibs rotary torque with 45 rpm, 4.5 bpm with 3,680 psi pump pressure, 13,000# WOB. Pump 20 bbl High Vis sweep around. 4.5 bpm with 3,820 psi. Displace well to clean seawater. 2,710 psi at 5 bpm. POOH from 10,175' to 8,358', standing back 4" HT38. RlU 2-718" Power Tongs and continue to POOH from 8,358' and SIB 2-7/8" HT-PAC DP in Derrick. UD 2-7/8" DCs and the 4-3/4" mill tooth bit BHA. P/U and MIU 3-5/8" Mill and BHA components to finish cleanout from 10,175' through the Baker Ball Seat at 10,195' and to mill and push the FasDrill plug from 10,362'. Slip and cut Drilling Line. RlU BOP test equipment. Set HES 9 5/8" RTTS and Storm Valve at 102'. Test from above to 1,000 psi for 10 minutes. Good test. Pull wear bushing and set test plug. Test BOPE, Choke Manifold, Floor Valves and Top Drive IBOP Valves to 250 psi low and 3,500 psi high. Each test was held for 5 minutes. No Failures. AOGCC witness of BOPE test was waived by Chuck Scheve. Test was witnessed by BP WSL and Doyon Toolpusher. Test BOPE, Choke Manifold, Floor Valves and Top Drive IBOP Valves to 250 psi tow and 3,500 psi high. Each test was held for 5 minutes. No Failures. AOGCC witness of BOPE test was waived by Chuck Scheve. Test was witnessed by BP WSL and Doyon Toolpusher. RID BOP Test Equipment. Pull test plug and install wear bushing. Retrieve HES 9 5/8" RTTS at 102'. UD RTTS Stop at 10,115', establish parameters, Up weight 160,000#, Down weight 108,000#, Rotating weight 126,000#, 4,000 ft-Ibs torque at 50 rpm, 3,600 psi pump pressure at 4.5-BPM. Continue RIH and tag Cement at 10,175'. Drill float equipment at 10,193' and drillout bits of junk down to the FasDrill plug @ 10,362'. Drill up and push FasDrill out bottom of Tbg stub at 10,378'. Lost retums. Was able to regain returns after pumping 28-Bbls and establish a 4-BPM pumping loss rate of 270-BPH. Printed: 6/11/2007 11 :18:34 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-07 06-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/21/2007 Rig Release: 6/7/2007 Rig Number: Spud Date: 8/2/1978 End: 6/5/2007 03:00 - 06:00 3.00 DRILL P TIEB1 Decide to provide constant hole fill rate of 60-BPH. 06:00 . 09:30 3.50 DRILL P TIEB1 Blowdown Top Drive, test and set 4" Air Slips. POH and UD 4" DP. 09:30 - 11 :00 1.50 DRILL P TIEB1 RlU to POH and UD 2-7/8" DP. Resume POH and UD DP. 11 :00 - 11 :30 0.50 DRILL P TIEB1 Circulate to get hole fill volume: 17-Bbls. Resume POH and use constant hole-fill rate of 60-BPH. 11 :30 - 18:30 7.00 DRILL P TIEB1 Resume POH and UD 2-7/8" HT-PAC drillpipe. UD 2-7/8" DCs at 1700-hrs. Breakout and UD Millout BHA. Clear and Clean Rig Floor. 18:30 - 19:00 0.50 RUNCO P RUNCMP PIU test joint and pull wear ring. RlU floor for running completion. RlU Torque Turn equipment with compensator. All tubing and jewelry rabbited before picking up. 19:00 - 00:00 5.00 RUNCO P RUNCMP P/U and RIH with 3-1/2", 9.2#, 13Cr80 Tubing. All joints Baker-locked below SABL-3 PKR. All joints doped with "Jet Lube Seal Guard". Average torque 2900 ft-Ibs. Stabbing guide was used on all connections. Losses at 30 BPH. 6/6/2007 00:00 - 09:30 9.50 RUNCO RUNCMP P/U and RIH with 3-1/2", 9.2#, 13Cr80 Tubing. All joints doped with "Jet Lube Seal Guard". Average torque 2900 ft-Ibs. Stabbing guide was used on all connections. 09:30 - 10:00 0.50 RUNCMP C/O Tubing handling equipment from 3 1/2" to 41/2". 10:00 - 14:00 4.00 RUNCMP PIU and RIH to 10,083' with 41/2",12.6#, 13Cr80, Vam Top tubing. Run all joints with compensator. All connections Torque Turned. M/U torque 4,400 ftllbs. Used Jet Lube Seal Guard pipe dope on threads. 14:00 - 14:30 RUNCMP PIU FMC tubing hanger and TC-lIlanding joint. Land tubing at 10110'. Tubing string weight without blocks Up weight 82,000#, Down weight 63,000#. 14:30 - 15:00 0.50 RUNCMP Run in Lock Down Screws. Torque to 450 ftllbs. 15:00 - 18:00 3.00 RUNCMP PJSM. Reverse in 105 bbls of 140 degree seawater followed by 205 bbls of 140 degree inhibited seawater, 2 bpm with 150 psi. 18:00 - 19:30 RUNCMP RlU and set Baker SABL-3 PKR with 4500 psi. Continue testing tubing to 4500 psi for 30 charted minutes. RlU and test Annulus to 3500 psi for 30 charted minutes. Test were witnessed by BPX WSL. 19:30 - 20:00 RUNCMP Shear DCK valve with 2450 psi on annulus. Confirm communication by reverse circulating 3 bpm with 2000 psi and 1120 psi at 3 bpm circulating long. 20:00 - 21 :30 1.50 WHSUR P RUNCMP RID landing joint and set TWC valve. Test TWC with 1000 psi from above and below. Test results were charted and witnessed by BPX WSL. 21 :30 - 22:30 1.00 WHSUR P RUNCMP C/O pipe rams to 4-1/2" x 7" variables. 22:30 - 00:00 1.50 WHSUR P RUNCMP N/D BOPE and secure. Clean and prepare wellhead for FMC adaptor flange. 6/7/2007 00:00 - 02:30 2.50 WHSUR P RUNCMP Install FMC adaptor flange and tree. Torque to specs. All studs nippled up with full nut plus 2-3 threads. Test adaptor flange to 5000 for 30 minutes. Test charted and witnessed by BPX WSL. 02:30 . 03:30 1.00 WHSUR P RUNCMP RlU and test production tree to 5000 psi. Hold and chart test for 30 minutes. 03:30 - 04:00 0.50 WHSUR P RUNCMP RlU DSM lubricator and equipment. Pull TWC valve. RID DSM. 04:00 - 06:00 2.00 WHSUR P RUNCMP RlU LRHOS. PJSM with LRHOS and rig crew. Pressure test Printed: 6/11/2007 11 :18:34 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 06-07 06-07 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 5/21/2007 Rig Release: 6/7/2007 Rig Number: Spud Date: 8/2/1978 End: 06:00 - 07:30 07:30 - 08:30 1.50 WHSUR P 1.00 WHSUR P RUNCMP circulating lines to 1200 psi. Reverse circulate 145 bbls of diesel freeze protection at 3 bpm. RUNCMP RIU lines and U-tube diesel freeze protect. RUNCMP Install BPV and test from below to 1,000 psi for 10 minutes. Good test. RUNCMP N/D secondary annulus valve. Secure tree and cellar. Rig released at 09:00 hours. 6/7/2007 04:00 - 06:00 2.00 WHSUR P 08:30 - 09:00 0.50 WHSUR P Printed: 6/11/2007 11:18:34 AM 'fREE = , WELLHEA D = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = FMC GEN 1 FMC AXELSON 64' FROM DRLG . DRAFT 06-07 2900' 52 @ 6200' 11037' 8800' SS I TOP OF 5-1/2" SCA 7" x 9-5/8" Baker ZXP LNR TOP PKR 7" x 9-5/8" BKR FLEXLOK LNR HANGER 1 TOP OF 7-5/8" LNR I 7-5/8" SCAB LNR, 29.4#, NT-95HS, ID = 6.875" I 113-3/8" CSG, 72#, N-80, ID = 12.347" I 13-1/2" TBG, 9.2#, 13CR-80 I I BOTTOM OF 5-1/2" SCAB LINER 10110' 10215' 2008' --i 4-1/2" HES X NIP, 10 - 3.813" 2018' - 4-1/2" X 3-1/2" XO I 2231' -j BAKER SPH MODIFIED LNR PKR, 10 - 6.875" 2694' -i BAKER 3-D HGR PKR, 10 = 6.825" I GAS LIFT MANDRELS ST MO TVO OEV TYÆ VLV LA TCH PORT DATE 4 3414 3394 21 KGB-2-9 DOME INT 16 06/25/07 3 6702 5703 48 KGB-2-9 SO INT 20 06/25/07 2 8554 6993 42 KGB-2-9 OMY INT 0 06/07/07 1 9493 7692 45 KBG-2-9 OMY INT 0 06/07/07 -b-1/2" HES X NIP -i 5-1/2" x 3-1/2" BAKER SABL-3 PKR 3-112' I-fSX~ BAKER PBR, 10 = 5.875" -j 9-5/S" X 4-1/2" BAKER SB-3 PKR, 10 = 3.S3" 1 0356' --j 4-1 /2" HES XN NIP, 10 = 3.725" 14-1/2" TBG, 12.6#, L-SO, .0152 bpf, ID = 3.958" H 10378' I ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/21/7S ANGLEATTOPÆRF: 35 @ 11103' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 3-3/8" 4 11103 - 11156 S 08/10/95 ? 4 11172 -111S6 S 06/11/87 3-3/S" 2 11186 - 11192 C 01/28/96 ? 4 11192-11194 S 06/11/87 ? 4 11204 - 11206 S 06/11/87 3-3/S" 4 11206 - 11216 C 11/02/89 3-3/S" 4 11216-11217 S 10/17/S9 3-3/8" 4 11226 - 11255 C 11/02/89 3-3/8" 4 11255 - 11256 S 10/17/89 DATE 08/26/78 06/13/95 09/14/01 08/19/03 01/27/07 02/04/07 1 PBTD I 9-5/8" CSG, 47#, N-80, 10 = 8.681" I REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER RNfTP CORRECTIONS CMO/TLP ÆRF ANGLE CORRECTION KSB/TLH GL V C/O GJF/TLH GL V C/O 11490' 11588' 11610' 10378' - 4-1/2" TBG TAIL WLEG, 10 - 3.958" I 10362' H ELMD TT LOGGED 07/04/95 I 11432' -J 3" JDC DOG LEFT IN HOLE (06/15/95) I OA TE REV BY COMMENTS 02/11/07 RCT/PAG GLV C/O 02/14/07 JPK/PAG GLV CORRECTIONS (02/04/07) 03/08107 ALHlPAG SET XXN @ 10339' (02/03/07) 06/0S/07 JDMfPAG DRLG DRAFT CORRECTIONS 06/29/07 JLJ/SV GLV C/O PRUDHOE BA Y UNrr WELL: 06-07 ÆRMrr No: '17S021 0 API No: 50-029-20299-00 SEC 2. T10N, R14E, 670.37' Fa. & 4555.7' FNL BP Exploration (Alaska) Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth t1-if- Q'd ( 05/29/07 NO. 4249 15/~d Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, SuitE! 100 Anchorage, AK 99501 SCANNED MAY 3 1 2007 MAY 3 1 20m (»ff"\j\\¡: ;~1,( i' Field: Prudhoe Bay D BL CI . Well Jo og escript on ate o or CD 06-24A 11637328 RST 04/16/07 1 1 L2-16 11414768 RST 10/07/06 1 1 06-07 11637123 RST 05/06/07 1 1 06-21A 11628766 MCNL 04/09/07 1 1 F-09A 11657123 CBL 05/06/07 1 09-15 11630475 CEMENT IMAGE LOG 05/06/07 1 03-36A 11745217 USIT CORROSION 05/03/07 1 03-36A 11745217 USIT CEMENT 05/03/07 1 b# L D . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. ~~"¡è ¡;¡: C'J~\ tþ: I \/E: ry Petrotechnical Data Center LR2-1 (~~J';"',. J~""'" § ......",.,! ,. 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth fl. /?/ Received by: C" ¿l A. ........... ""7- v . rm \It á-~ ß UL ffi\ ~ [ß . / / I ( SARAH PALIN, GOVERNOR A"~~1iA. OIL A1Q) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 o~\ \\~-' Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-07 Sundry Number: 307-162 Dear Mr. Reem: ~MAY 1 e Z007 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this/~ay of May, 2007 Enc!. 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension Anchorage o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development D Exploratory 178-021 - 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20299-00-00 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 06..Q7 ,¡ Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): - ADL 028311 / 64' I Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUMMARY .> > Total Depth MD (ft): Total Depth TVD (ft):IEffective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): Junk (measured): 11610 / 9339 / 11490 9239 10339 11432 Casino Lenoth Size MD TVD Burst Collaose Structural Conductor 117' 20" 117' 117' 1490 470 Surface 2732' 13-3/8" 2732' 2732' 4930 2670 Intermediate Production 11588' 9-5/8" 11588' 9320' 6870 4760 Liner Scab Liner 474' 7-5/8" 2226' - 2700' 2226' - 2700' Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11186' - 11255' 8987' - 9044' 5-112",17# x 4-1/2", 12.6# L-80 10378' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker 'SB-3' packer I Packers and SSSV MD (ft): 10341' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory 181 Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina Ooerations: May 21,2007 181 Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-5254 Printed NaT'David Reem Title Drilling Engineer Prepared By Name/Number: Signature A ,/ ( J? fli:.4"Ÿ'-- Phone 564-5743 Date 5/~l r.) ¡- Terrie Hubble, 564-4628 Commission Use On Iv I Sundry Number: ( .~t") - 110 h2 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity I){BOP Test D Mechanical Integrity Test D Location Clearance Other: ~_SÖO ~..;\~" ~.-=.\- Subsequen' Form Required, ~" ~tu APPROVED BY S"r -d1- Aooroved By: / 7 COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 V ~. , RBDMs 8Ft MAY 1 4 1007 Submit In Duplicate . STATE OF ALASKA f/I I>-rfJ". .f/%,¡ RECEIVED ALASKAOILANDGASCONSERVATION~OM.ION J.,;{t"':J. ~y 102007 APPLICATION FOR SUNDRY APPROVALO'7.S 5"'15/7 20 MC 25.280 Alaska ir& Gas Cons. Commissiol Cfi~~\. . . 6-07 Rig Workover Scope of Work: Pull 5-%" x 4-%" completion, run 5-%" scab liner and fully cement same, run 4-%" x 3-%" 13Cr80 completion. MASP: 2372 psi Well Type: Producer Estimated Start Date: May 21 , 2007 Pre-ri S 1 E 2 F 3 0 4 0 5 0 6 re work: Pull 4-%" XXN lu at 10339' SLM. Drift 4-%" tub in to the WLEG at 10362' ELMO. Set HES 4-%" composite bridge plug at 10362' MD, in the middle of the second ten foot pup joint below the packer. Jet cut 4-%" tubing @ -10165' MD, in the middle of the first full joint above the Baker SB-3 acker. Circulate well with -8.5 ppg seawater and cap with diesel thru the cut. MITOA to 2000 psi. Bleed WHPs to 0 si. No CMIT re uired due to leakin roduction casin . Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. Set a BPV in the tubin han er. Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure v 1. MIRU. NO tree. NU BOPE with 3-1/2" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5- W' x 4- W' tubing string to the cut. 3. Fish seal stem out of Baker PBR. 4. Run and fully cement new 5- W' casing from 10322' to -2100' MD. 5. Cleanout 5-%" scab liner. 6. Drillout 4- W' composite plug. 7. Run 4-%" x 3-%" 13Cr-80 completion with Baker SABL-3 packer. Position packer at -10200' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. NO BOPE. NU and test tree. RDMO. TREE - FMC GEN 1 . I I WELLHEAD,= FMC 06-07 . SAFETY NOTES: ACTUA TOR = AXELSON KB. ELEV - 64' BF. ELEV = KOP= 2900' Max Angle = 52 @ 6200' -i I Datum MD = 11037' 2161' 5-1/2" HES HRQ SSSV NIP, ID = 4.562" Datum TVD = 8800' SS . 15-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" l-i 2174' I -i 5-1/2" X 4-1/2" XO I TOPOF 4-1/2" TBG H 2174' 1 2174' TOP OF 7-5/8" LNR I ~ I 2231' - BAKER SPH MODIFIED LNR PKR. ID = 6.875" I 2226' :J F I 7-5/8" SCAB LNR, 29.4#, NT-95HS, ID = 6.875" I I 2694' -i BAKER 3-D HGR PKR, ID = 6.825" I 2700' ..... I2S 113-3/8" CSG, 72#, N-80, ID = 12.347" I 2732' ~ ~ GAS LIFT MANDRELS - ST MD TVD DEV lYÆ VLV LA TCH PORT DATE --1J 1 3052 3048 15 HES-MPDX DMY BK 0 02/04/07 2 5847 5157 50 HES-MPDX DMY BK 0 02/04/07 Minimum ID = 3.725" @ 10356' 3 7821 6466 49 HES-MPDX DMY BK 0 02/04/07 4-1/2" HES XN NIPPLE 4 10169 8181 44 HES-MPDX DMY BK 0 02/11/07 L 10322' - BAKER PBR, ID = 5.875" 1 ~ 10341' -i 9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3.83" I 2S. 10339'SLIIr1- 4-1/2" HES XXN SET (02/03/07) I ----r 10356' - 4-1/2" HES XN NIP, ID = 3.725" I 14-1/2" TBG, 12.6#. L-80, .0152 bpf, ID = 3.958" 1 10378' 10378' -i 4-1/2" TBG TAIL WLEG, ID = 3.958" I 1 10362' H ELMD TT LOGGED 07/04/95 I ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/21/78 ANGLE AT TOP ÆRF: 35 @ 11103' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11103 - 11156 S 08/10/95 ? 4 11172 -11186 S 06/11/87 3-3/8" 2 11186 - 11192 C 01/28/96 ? 4 11192 - 11194 S 06/11/87 ? 4 11204 - 11206 S 06/11/87 3-3/8" 4 11206 - 11216 C 11/02/89 3-3/8" 4 11216 - 11217 S 10/17/89 3-3/8" 4 11226 - 11255 C 11/02/89 3-3/8" 4 11255 -11256 S 10/17/89 I 11432' H 3" JDC DOG LEFT IN HOLE (06/15/95) I I PBTD 1 11490' I 9-5/8" CSG, 47#. N-80. ID = 8.681" 1 11588' I ~ ~ 11610' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 08/26/78 ORIGINAL COM PLETION 02/11/07 RCT/PAG GL V ClO WELL: 06-07 06/13/95 LAST WORKOVER 02/14/07 JPKJPA G GLV CORRECTIONS (02/04/07) ÆRMIT No: '1780210 09/14/01 RNlTP CORRECTIONS 03/08/07 ALHlPAG SET XXN @ 10339' (02/03/07) API No: 50-029-20299-00 08/19/03 CMOITLP ÆRF ANGLE CORRECTION SEC 2, T10N, R14E, 670.37' FEL & 4555.7' FNL 01/27/07 KSBITLH GL V ClO 02/04/07 GJFITLH GL V ClO BP Exploration (Alaska) TREE = FMC GEN 1 6-0' Proposed WELLHEÄD~ FMC Campl.an ACTUATOR = AXB...SON KB. B...BI = 64' BF. B...BI = KOP= 2900' Max Angle = 52 @ 6200' I H I Datum MD = 11037' . -2000 4-1/2" HES X NIP, ID - 3.813" Datum TVD = 8800' SS 14-1/2" TBG, 12.6#, 13CRBO I '\ / H 4-1/2" X 3-1/2" XO I 1 TOP OF 5-1/2" SCA -2100 I ~ 1 TOP OF 7-5/S" LNR I ~ I 2231' -i BAKER SPH MODIFIED LNR PKR. ID = 6.S75" I 2226' ~ ¡2S 1 7-5/S" SCAB LNR, 29.4#, NT-95HS, ID = 6.S75" I I 2694' -i BAKER 3-D HGR PKR, ID = 6.825" I 2700' 113-318" CSG, 72#, N-SO, ID = 12.347" I 2732' -¡.j ~ GAS LIFT MANDRB...S 1 5-1/2" SCAB LNR, 17#, L-80, ID = 4.S92" I I ~ ST MD TVD DBI TYÆ VLV LA TCH PORT DATE U 13-1/2" TBG, 9.2#, 13CRBO I I I . H 3-1/2" HES X NIP I ~ -10200 H 5-1/2" x 3-1/2" BAKER SABL-3 PKR 1 I · H 3-1/2" HES X NIP I I BOTTOM OF 5-1/2" SCAB LINER I 10322' I 10322' - BAKER PBR, ID = 5.S75" I ::. 10341' -1 9-518" X 4-1/2" BAKER SB-3 PKR, ID = 3.S3" 1 I . 1 0356' H4-1/2" HES XN NIP, ID = 3.725" I 14-1/2" TBG, 12.6#, L-SO, .0152 bpf, ID = 3.95S" l-i 10378' J", ÆRFORA TION SUMMARY "'-I 10378' - 4-1/2" TBG TAIL WLEG, ID = 3.95S" I REF LOG: BHCS ON OS/21/7S 1 10362' H B...MD TT LOGGED 07/04/95 I ANGLEATTOPÆRF: 35 @ 11103' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/S" 4 11103 - 11156 S 08/1 0/95 II ? 4 11172 -111S6 S 06/11/87 3-3/S" 2 111S6 - 11192 C 01/2S/96 ~ ? 4 11192 - 11194 S 06/11/S7 ? 4 11204 - 11206 S 06/11/S7 I! 3-3/S" 4 11206-11216 C 11/02/S9 3-3/S" 4 11216-11217 S 10/17/89 3-3/8" 4 11226 - 11255 C 11/02/S9 3-3/8" 4 11255 - 11256 S 10/17/S9 11432' -i 3" JDC DOG LEFT IN HOLE (06/15/95) I I PBTD I 11490' I 1 9-5/8" CSG, 47#, N-SO, ID = S.681" I 11588' I C§] 11610' DATE REV BY COMMENTS DATE RBI BY COMMENTS PRUDHOE BA Y UNrr 08/26178 ORIGINAL COM PLETION 02/11/07 RCT/PAG GL V ClO WB...L: 06-07 06/13/95 LAST WORKOVER 02/14/07 JPKlPAG GLV CORRECTIONS (02/04/07) ÆRMrr No: "1780210 09/14/01 RNITP CORRECTIONS 03/OS/07 ALHlPAG SET XXN @ 10339' (02/03/07) API No: 50-029-20299-00 08/19/03 CMOITLP ÆRF ANGLE CORRECTION SEC 2. T10N, R14E, 670.37' FB... & 4555.7' FNL 01/27/07 KSBITLH GL V ClO 02/04/07 GJFITLH GL V ClO BP Exploration (Alaska) 1'..t;. r Jt;-J J1:; pJ~p VVVlr.. au\.! ':>UU\.!l) UPPU"'UUVH>.J Paul and Dave, I just spoke with Cathy and she agrees that pre-rig work such as cutting the tubing in this case may proceed without having the sundry in hand. Call or message with any questions. Tom Maunder, PE AOGCC \ 't<ö -0 d-- \ Chan, Paul (PRA) wrote, On 5/15/2007 3:22 PM~MS> MA'( 1 á 2001 Tom, Do we need to have the Form 10-403 Application for Sundry Approval on producing wellworkovers approved before we can do pre-rig preparation work that would alter the mechanical condition of the well (in the vast majority of cases we would like to cut the production tubing)? The question has been raised on the PBU 06-07 RWO on this producer (PTO 178-021) Thanks for your help Paul Chan workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) I of I 5/15/2007 3 :52 PM E', 'co E-~'"ev" 7FD,', . ~ . ,'/ .~-~ a ." IJ~ '._ 04/16/07 Scblumberger APR ~:, u Z007 NO 4214 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~a Oil & Gas Cons. commi$sIoo Andmrage Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~-I / . '''',r:\ j ,"O-Ua! Field: Prudhoe Bay Well Job# Loa Description Date BL olor D 02-15 11661130 MEM PROD PROFiLE 02/25/07 1 U-06B 11469946 MEM PROD PROFILE 02/24/07 , P-09L 1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL 1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL 1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11 B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37 A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y -06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20/07 1 , 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 C C . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. SCANNED APR 2 5 2007 Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: é)( 06-07 (PTD #1780210) Classified as Problem Well . All, Well 06-07 (PTD #1780210) has been found to have sustained casing pressure on the IA. The lAP was reported at 2050 psi on 01/21/07. A TIFL Failed on 07/22//07. /" The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: GL V c/o 3. DHD: Re-TIFL s~ FEB 2 6 Z007 A wellbore schematic has been included for reference. «06-07.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you - Jack L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 Content-Description: 06-07.pdf 06-07.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 l/24/2007 11: 14 AM TREE = FMC GEN 1 I I WB..LHEAO = FMC 06-07 SAFEiY NOTES: ACTUATOR = AXELSON KB. ELEV = 64' BF ELEV- KOP= 2900' Max Angla - 52 @ 6200' DatumMO- 11037' 2161' 5-1/2"HESHRQ SSSV NIP, 0=4.562" OatumTVD = 8800' SS . 15-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" H 2174' I - 5-1/2" X 4-1/Z' XO ITOPOF4-1/2"TBG H 2174' I 2174' TOPOF7-5/8" LNR 2226' ho ~ I 2231' -lBA KER SA-! MODIFIED LNR A<R, ID = 6.875" I I 7-5/8" SCAB LNR, 29.4#, NT-95HS, 0 = 6.875" I Ü I 2694' BAKER 3-D HGR A<R, ID = 6.825" I 2700' I = ~ 113-3/8" CSG, 72#, N-80, 10 = 12.347" I 2732' ~ ~ GAS LIFT MANDRELS - ST MD TVD OEV lYPE VLV LA TCH PORT DATE ...J 1 3052 3048 15 HES-MFÐX BK-2 2 5847 5157 50 HES-MFÐX BK-2 I Minimum ID = 3.725" @ 10356' I 3 7821 6466 49 HES-MFÐX BK-2 4-1/2" HES XN NIPPLE 4 10169 8181 44 HES-MFÐX BK-2 L 10322' BAKER PBR, 0 = 5.875" 1 8 10341' 9-5/8" X 4-1/Z' BAKER SB-3 PKR, ID = 3.83" ~ I . 10356' 4-1/2" HES XN NIP, ID = 3.725" 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 10378' I 10378' 1-1 4-1/2" TBG TAIL WLEG, ID = 3.958" I I 10362' H ELMO IT LOGGED 07/04195 I ÆRFORA TION SUMMA. RY REF LOG: BHCS ON 08/21/78 ANGLEAT TOP PERF 35 @ 11103' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11103 - 11156 S 08/10/95 ? 4 11172- 11186 S 06/11/87 3-3/8" 2 11186 - 11192 0 01/28/96 ? 4 11192-11194 S 06/11/87 ? 4 11204- 11206 S 06/11/87 3-3/8" 4 11206 - 11216 0 11/02/89 3-3/8" 4 11216- 11217 S 10/17/89 3-3/8" 4 11226- 11255 0 11/02/89 3-3/8" 4 11255 - 11256 S 10/17/89 I 11432' 3" JOC OOG LEFT IN HOLE (06/15/95) I AnD I 11490' I I 9-5/8" CSG, 47#, N-80, 10 = 8.681" 11588' I UQJ 11610' DA.TE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNrr 08/26/78 ORIGINAL COMPLETION WELL: 06-07 06/13/95 LAST WORKOVER PERm No: 1780210 09/14/01 RN/W CORRECTIONS API No: 50-029-20299-00 03/22/03 KB/KAK PERF CORRECTIONS SEC 2, T10N, R14E, 670.37' FB.. & 4555.7' FNL 08/19/03 CMO/1LP PERF ANGLE CORRECTION BP Exploration (Alas ka) . 06-07 (PTD #1780210) Classified as Problem Well ) ) Subject: 06-07 (PTD #1780210) Classified as Problem Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 31 Jul2005 18:15:58 -0800 To: "Yancey, Alex N" <Alex.Yancey@BP.com>, "GPB, FS3 DS Ops Lead" <GPBFS3DSOpsLead@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "NSU', ADW Well . Operations Supervisor" <NSUADWWe1l0perationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jim.;.1egg@admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us>. "NSU, ADW WL& CQmpletion Supervisor" <NSUADWWL&CompletionSupervisor@BP.com>, "GPB, OpsMgrU <GPBOpsMgr@BP.com>,IIGPB, FS3 AreaMgr"<GPBFS3TL@BP.com> .... ' CC: "NSU,ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com>,· "Hughes, Andrea (VECO)II <hugha4@BP.com> 'TxJ=A All, Well 06-07 (PTD #1780210) has sustained casing pressure on the IA and is classified as a Problem well. TIOls on 07/28/05 were 2410/2410/0+. The well failed a TIFL on 7/28/05. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Caliper Tbg, Change-out OGLV 3. DHD: Re-TIFL /' Attached is a wellbore schematic. Please call if you have any questions. «06-07.pdf» Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907 -659-5102 907-659-5100 #1923 pgr SCANNED AUG 0 9 2005 Content-Description: 06-07.pdf Content-Type: application/octet-stream Content-Encoding: base64 {ksS;Je S SCP }.)\3~ P ~ }-lJ<-( P R...epctl t.$ 'f IA'1 "<? of j ~!?/~( oL ~ Co 4~l. .::r-A Z410¡s, 601~ 35 'to ~f{ B/ zfoç- 01\ o ~~ ';3 fJofc;, 1 of 1 8/2/2005 1 :51 PM TREE = WB.LHEAD = A CTUA TOR = KB, ELEV = BF. ELEV = KOP= Max Ange = Datum MD = DatumTVD = ) FMC G8\l1 FMC AXELSON 64' 2900' 52 @ 6200' 11037' 8800' 55 15-1/2" TBG, 17#, L-80, ,0232 bpf,lD =4,892" 1--1 TOPOF 4-1/2" TBG 1-1 TOPOF7-5/8" LNR 1 7-5/8" SCAB LNR, 29.4#, NT-95HS, D = 6,875" ( 113-3/8" CSG, 72#, N-80, ID= 12,347" 1--1 2732' 2174' 2174' 2226' Minimum ID = 3.725" @ 10356' 4-1/2" HES XN NIPPLE 14-1/2" TBG, 12,6#, L-80, .0152 bpf, ID = 3,958" [)A. TE 08126/78 06/13/95 09/14/01 03122/03 08119/03 F£RFORA 1l0N SUVlI\ILl\ RY REF LOG: BHCSON08/21178 ANGLE AT TOP PERF: 35 @ 11103' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11103-11156 S 08/10/95 ? 4 11172-11186 S 06/11/87 3-3/8" 2 11186 - 11192 0 01/28/96 ? 4 11192-11194 S 06/11/87 ? 4 11204-11206 S 06/11/87 3-3/8" 4 11206-11216 0 11/02/89 3-3/8" 4 11216 - 11217 S 10/17/89 3-3/8" 4 11226 - 11255 0 11/02/89 3-3/8" 4 11255-11256 S 10/17/89 I FB1D 9-5/8" CSG, 47#, N-80, ID= 8,681" 1 11588' ~ REV BY COMNENTS ORIGINAL COMPLErION LAST WORKOVER RNITP CORREC1l0NS KBlKAK PERF CORRECTIONS CMOffiP PERF ANGLE CORRECllON DATE 06-07 ) I SAFETY NOTES: (I --I 5-1/2" HES HRQ SSSV NIP, D = 4,562" -I 5-1/2"X4-1/2"XO BAKERSA-i MODIFIED LNR A<R, ID= 6.875" BAKER 3-D HGR A<R, ID = 6.825" GAS LIFT MANDRELS ST MD TVD DEV lYPE VLV LATCH PORT DATE 1 3052 3048 15 HES-MAJX BK-2 2 5847 5157 50 HES-MAJX BK-2 3 7821 6466 49 HES-MAJX BK-2 4 10169 8181 44 HES-MAJX BK-2 BAKER PBR, D = 5,875" I 9-5/8" X 4-1/2" BAKER SB-3 PKR, ID = 3,83" 4-1/2" HES XN NIP, ID = 3,725" 4-1/2" TBG TAIL VVLB3, ID = 3,958" 1 ELMD IT LOGGED 07/04/95 I 3" JDC DOG LEFT IN HOLE (06/15/95) REV BY COMNENTS PRUDI-K)EBAY UNIT \^ÆLL: 06-07 PERMIT No: 1780210 API No: 50-029-20299-00 SEC 2, T10N, R14E. 670,37' FB. & 4555.7' FNL BP Exploration (Alas ka) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging~ Pull tubing Alter casing M Repair well Perforate~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 20' NSL, 1040' WEL, SEC. 2, 510N, R14E At top of productive interval 719' NSL, 1156' WEL, SEC. 1, TION, R14E At effective depth At total depth 684' NSL, 674' WEL, SEC. 1, TION, R14E 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KBE = 62.3 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-07 9. Permit number/approval number 78-21 10. APl number 50- 029-20299 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 117' Surface 2668' Intermediate 11524' Production -- Liner 469' Perforation depth: measured 11610 feet Plugs (measured) 9338 feet 11547 feet Junk (measured) 9286 feet Size Cemented Measured depth 20" 270 sx AS 117' 13-3/8" 5400 sx PF II 2732' 9-5/8" 1300 sx Class 'G' 11588' 7-5/8" N/A, Scab Liner 11204' - 11214', 11224' - 11253' true vertical 8979'- 8987', 8995'- 9019' True vertical depth 117' 2732' 9297' 2226'- 2700' 2700' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Butt at 2174'; 4-1/2', 12.6#, L-80, NSCTat 10378' Packers and SSSV (type and measured depth) 7-5/8" Baker SPH Modified packer at 2231', 7-5/8" Baker 3-D Packer at 2694'; 5-1/2" HES HRQ SVLN at 2161'; Baker SB-3 packer at 10341' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED MAR 2 6 1996 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data '-" ......... Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report o~Well Operations X 17. I hereby ce~if~/l~at the forf~-~lO'FCg i~)true Form 10-404 Rev 06/15/88 16. Status of well classification as: Oil X Gas Suspended Service and correct to the best of my knowledge. Title Senior Drillin~l En~lineer Date'} ,-- 'Z/-~7 .¢.~ SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE ~-- DAILY OPERATIONS ~ PAGE: 1 WELL: DS 6-7 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 05/25/95 10:30 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 05/26/95 ( 1) TD:ll610 PB:11547 05/27/95 ( 2) TD'll610 PB:11547 05/28/95 ( 3) TD:11610 PB:11547 KILLING WELL MW: MOVE T/DS. LEVEL RIG/ACCEPT @ 22:30 ON 5/25. TOOK ON SEAWATER. RU T/CIRC. BLED OFF 13-3/8 X 9-5/8" ANNUL. ON VACUUM. RU LUBRICATOR. PULL BPV. RD LUB. HAD 800 PSI ON TB. BLED OFF GAS THRU CHOKE. CIRC DOWN ANNUL. CIRC @ 30 SPM/300PSI T/KILL WELL. CIRC BU MW: 0.0 CBU. RECEIVE CRUDE, GAS & ARCTIC PACK ON RETURNS. RU T/9-5/8" X 13-3/8" ANNULUS. DISPLACED CA T/7.7 PPG 60:40 METHANOL. WATER TAKING RETURNS ON IA. SI CA. CIRC HOLE VOL. DOWN TBG CONVENTIONALLY. MONITORED WELL-STATIC. RD MANIFOLD IN CELLAR. REMOVED TREE CAP. SET 5-1/2" RBP @ 26' RT.TEST T/1000. OK. ND XMAS TREE ADAPTOR FLNG. NU BOPE.TEST BOP STACK. SHEAR RMAS. HAD A LEAK BY THE TBG HNGR. SUSTAINED 5000PSI BY IDLING THE TEST PUMP. RAN LNDG JT. COULDN'T ENGAGE THE HNGR. RAISED THE STACK. RETESTED THE BODY. PULLED RBP W/ANNULAR CLOSED ON PULLING STRING. NO GAS, PRESS NOTED UNDER PLUG. LD RBP. CIRC CONVENTIONALLY. BULLHEAD SEAH20 T/PERFS MW: 0.0 CIRC HOLE CLEAN. CONT. T/GET MIGRATING CRUDE IN RETURNS ON IA. RU SCHLUMBERGER, LUBRICATOR. CHEM CUT TBG STRING @ 2371-WLM. MID JT OF 1ST FULL JT ABOVE COLLAPSE POINT. RD SCHLUMBERGER, LUB. CBU. MONITOR WELL. STATIC. MU 4" SPEAR ASSY. W/4.805" GRAPPLE. ENGAGE TBG BELOW THE HNGR. BOLDS. PULLED HNGR LOOSE & LD 2 JTS OF 5.5" TBG, CL. CUT BANDED CL T/TBG. MU BAKER 9-5/8" STORM PAKR T/STRING. SET PACKER @ 50' RT. TEST T/500. OK. RAN TEST PLUG. TEST BOPE T/250/5000 PSI. ANNULAR T/250/2500. LD TEST PLUG. RAN WB. TEST WAIVED BY JOHN SPAULDING W/AOGCC. RETRIEVED STORM PKR. NO PRESS UNDER PKR. MONITORED WELL-STATIC. POOH W/COMP STRING. RD TBG PULLING EQUIP. PU OVERSHOT MU BHA. HAD SOME MIGRATING CRUDE OIL W/A SMALL AMT OF GAS IN THE BELL NIPPLE. BULLHEADED SEAWATER T/PERFS T/ENSURE THAT THE WELL WAS DEAD. RECEIVED MAR 2 6 1996 Alaska Oil & Gas Cons. Commission Anchorage WELL : DS 6-7 OPERATION: RIG · DOYON 16 PAGE: 2 05/29/95 ( 4) TD:11610 PB:11547 05/30/95 ( 5) TD:ll610 PB:11547 05/31/95 ( 6) TD:ll610 PB:11547 06/01/95 ( 7) TD:ll610 PB:11547 RIH W/6.25" SWAGE MW: 0.0 MONITOR WELL AFTER BULLHEADING SEAWATER T/PERFS.--STATIC. RIH W/O'SHOT ASSY PU 5" DP T/TOF @ 2381DPM. ENGAGE FISH. PU T/300K. SHEARED PBR. WORKED SS OUT OF PBR 29'. STRING PARTED WHEN WORKING PIPE W/PULL OF 225K. HAD ABOUT 2K EXTRA WT AAFTER STRING PARTED. CBU. MONITOR THE WELL -STATIC. POOH W/OS ASSY. RECOVERED CUT OFF JT. 5.5" TBG. 1 FULL JT OF 5.5" TBG. 1 COLLAPSED JOINT OF 5.5" TBG. RELEASED OS. LD FISH. TOF IS NOW @ 2485 W/BOX UP. RIH W/REDRESSED OS ASSY. COULD NOT GET PASSED 2453. SUSPECT COLLAPSED CASG. POOH T/INSPECT OS. MODIFIED THE BELL NIPPLE. PU 6" LIB. COULD NOT GET PASSED 2453. PU MULE SHOE. RIH ON 3.5" DP. AT TOF -- OD OF MULE SHOE DP BOX IS 5". POOH LD MULE SHOE. PU 6.25" SWAGE. MU BHA. RIH. CBU MW: 0.0 RIH W/SWAGE T/2453. BROKE CIRC. GAS T/SURF. CIRC OUT THRU CHOKE. WELL STATIC. SWAGED OUT CASG T/2466. NOTED GAS IN BELL NIPPLE. BULLHEADE TBG. W/CSG VOL. BELOW PKR INTO PERFS. FINAL RATE WAS 1.2 BPM @ 1550PSI. POOH W/SWAGE. PU 7" SWAGE & RIH T/2452. CBU MONITORED WELL--STATIC. POOH W/7" SWAGE. PU 8.5" SWAGE RIH T/2453.WORKED THRU SECTION--GAS T/SURF. CBU THRU CHOKE, MONITORED WELL--STATIC. TAGGED TOF @ 2485. CBU. POOH W/SWAGE. PU O'SHOT. RIH W/6" GRAPPLE. ENGAGE FISH. POOH W/OS. MU CIRC HD. LINES. CBU F/7875 T/ENSURE STRING CLEAR. RU T/LD TBG. PUMP HAD GAS T/SURF. CBU THRU CHOKE. PU 5" DP MW: 0.0 COMP. CBU THRU CHOKE WHILE RU T/LD TBG. MONITOR WELL-SMALL AMT OF GAS IS STILL PRESENT. CIRC ONE COMPLETE CIRC. & MONITOR WELL--STATIC. POOH LD 5.5" COMP. STRING. RECOVERED ALL TUBULARS 7 COMPONENTS. INCLUDING THE SS SEAL ASSY. RD TBG EQUIP. CLEANED FLOOR AREA. PU TAPERED STRING MILL. MAX OD 8.6" MU BHA RIH T/1393. SLIP & CUT DL. CON'T RIH W/STRING MILL T/2453. MU KELLY. ROTATE THRU. DRESSED OFF SECTION T/2461. CBU. MONITOR WELL--STATIC. POOH W/STRING MILL. LD HWDP 7 MILL. NO WEAR OFF OD NOTED ON THE MILL/PU 8.125" OS BOWLS W/6" GRAPPLES & RIH T/PU 135 JTS OF DP. CIRC BOTTOMS UP MW: 0.0 TRIP IN HOLE W/ OVERSHOT. ENGAGE PBR, ROTATE PBR OUT. CIRC BOTTOMS UP GAS PRESENT. TRIP OUT W/ PBR. SLM. LD PBR AND OVERSHOT ASSEMBLY. PU MILLING AND PRT ASSEMBLY, TRIP IN HOLE. KELLY UP, BREAK CIRC. CHK WTS. TAG FISH @ 10369', STING IN W/ PRT MILLING PKR F/ 10369 - 10372' PU DP. CHASE PACKER TO 11375' CIRC BOTTOMS UP. WELL : DS 6-7 OPERATION: RIG : DOYON 16 PAGE: 3 06/02/95 ( 8) TD:ll610 PB:11547 06/03/95 ( 9) TD:ll610 PB:11547 06/04/95 (10) TD:ll610 PB:11547 06/05/95 (11) TD:ll610 PB:11547 TRIP IN W/ HALIB RBP MW: 0.0 CIRC BOTTOMS UP. GAS PRESENT. CIRC THRU CHOKE TILL DEAD. TRIP OUT W/ PACKER AND TAIL PIPE. WORK THRU, SOME TIGHT SPOTS. L/D FISHING TOOLS AND PKR AND TAIL PIPE. RIG UP ATLAS WIRE LINE TOOLS RUN #1 GAUGE RING AND JUNK BASKET TO 2460', WOULD NOT GO BELOW THIS DEPTH. R/D ATLAS WIRELINE. CLEAN BOOT BASKETS. PU TAPERED MILL AND RIH TO 447' INSPECT FAST LINE SHEAVE ON CROWN. BEARING HAS MOVED. CHECK FOR CRACKS. TRIP IN TO 2455'. ROTATE AND WORK MILL THRU. CALLAPSED SECTION OF CSG F/ 2455 - 2459' TRIP OUT L/D MILLING ASSEMBLY. MAKE UP HALLIBURTON RETRIEVABLE BRIDGE PLUG AND TRIP IN HOLE. TIH W/CMT RETAINER MW: 0.0 TIH W/RBP. SET @10389. TEST CASG T/2000. TOOH. PU RTTS. SET TOOL @2990. TEST CASG T/3500/30 MIN. OK. TOOH. LD RTTS TOOLS. RU ATLAS WL. RUN 8.5" GAUGE RING & JUNK. STOPPED @2454. RUN VERTILOG F/2420 T/SURFACE. RD ATLAS. SLIP & CUT DL. MU RBP ON DP. SET @2550. DUMP 40 50# BAGS OF CARBILITE ON RBP. PU 9-5/8" EZSV CMT RETAINER. TIH. TIH W/REV. BASKET MW: 0.0 TIH W/EZ DRILL RETAINER & SET @2300. PRESS 9-5/8" ANNUL T/1000. PUMP 5600 GALLONS DIESEL T/9-5/8" X 13-3/8" ANNULUS. TEST CMT LINES T/3000. CMT W/59 BBLS. 345 SX. COLD SET 2. @ 14.9 PPG. DISPLACED W/41 BBLS. SEAWATER. POOH RU T/REPLACE 9-5/8" PACKOFF. CHANGE OUT & TEST T/4000/15 MIN. OK. TEST BOPE RAMS F/250/5000. ANNUL F/250/2500. INSTALL WEAR RING. TEST WAS WITNESSED BY AOGCC REP: LOU GRINWALD. PU BIT & TIH T/2260. TAG CMT @ 2297. DRILL CMT T/2300 @ TOP OF RETAINER. DRILL T/2440. WASH T/2500. TRIP OOU & TRIP IN W/REVERSE BASKET. MU REV. BASK. TIH MW: 0.0 TIH W/REV. BSKT. REV. CIRC T/2506. TOOH. TIH W/BOOT BASK. TAG SAND &JUNK @2506. CLEAN OUT T/2516. TOOH. LD BIT & BB. TIH W/RBP RETRIEVING TOOL. WOULD NO GO BELOW 2548. RERUN TOOL. --NO GO. RE-TRIP W/RBP T/2544. WOULD NOT GO ANY FURTHER. TOOH. MU REV. BASKET & TIH. WELL : DS 6-7 OPERATION: RIG : DOYON 16 PAGE: 4 06/06/95 (12) TD:ll610 PB:11547 06/07/95 (13) TD:ll610 PB:11547 06/08/95 (14) TD:ll610 PB:11547 06/09/95 (15) TD:ll610 PB:11547 06/10/95 (16) TD:ll610 PB:11547 06/11/95 (17) TD:ll610 PB:11547 TIH & TAG CASG MW: 0.0 TIH & TAG FISH @2549. CBU/ROTATE. REVERSE BU TOOH. PU O'SHOT W/3-3/8" GRAPPLES. TIH WORK @ 2549 & TOOH. MU BOX TAP. WORK TAP -- NO FISH. RE-RUN TAP/CHASE DOWN HOLE T/2636. PU KELLY. REV. CIRC & CHASE RBP T/2667. TIH & CHASE T/9953. TOOH PULLED TIGHT @ 2450. LD BOX TAP. MU OVERSHOT ASSY. TIH W/ASSY & TAG CASG @ 2455. WORK THE O'SHOT. REVERSE CIRC @ BTTM MW: 0.0 TIH W/O'SHOT T/9953. FISH RBP - DIDN'T ENGAGE. SLIP & CUT DL. PU SHORT CATCH O'SHOT & RIH. ENGAGED RBP @10331 PUSHED 15K DOWN. TOOH DRAGGING 35K THRU THE CASG--RECOVERED RBP & BTTM OF EZ DRILL RETAINER INTACT. SEVERAL PIECES OF METAL F/EZ DRILL WERE STUCK IN RBP. PU REV. BASK & TIH T/10344. DISPLACE T/ SEAWATER MW: 0.0 REV. CIRC T/10383. TOOH. LD REV. ASSY. TIH W/RET. TOOL ON DP. BRK. CIRC REV. F/10383 T/10389. REV. BTTMS UP. KELLY UP. ENGAGE RBP. RELEASE. OBSERVE THE WELL. TOOH W/RBP. LD RBP. PU BIT TRIP IN HOLE T/4492. SLIP & CUT DL. TIH T/10363. WAST T/11490. DISPLACE THE WELL T/CLEAN BRINE T/11490. GAS ON BTTMS UP CIRC THRU CHOKE. TIH W/REV. BSKT MW: 0.0 TOOH LD BIT. PU 8.5" TAPERED MILL. TIH T/2455. RUN MILL THRU SWEDGED OUT SECTION. TOOH. RU T/RUN TAIL PIPE & PACKER. ATTEMPT T/WORK PAST OBSTRUCTION. WOULLD NOT GO PAST. TOOH W/PKR & TAIL PIPE ASSY. SLOW/WET. PU REV. BASKET & TIH. LD DP MW: 0.0 TIH W/REV. BASKT T/11480. RECOVERED PARRIFIN & GAS. TOOH T/RUN TAIL PIPE & PACKER. RECOVERED 2 PIECES OF IRON. PU TAIL PIPE & PACKER & TIH ON DP. FILL PIPE & SLM T/10309. SET PACKER @ 10340 W/3500. SHEARED PBR. HELD PRESS F/30 MIN. OK. PRESS ANNUL. T/200/15 MIN. OK. TOOH. LD DP. SLIP & CUT DL. LD DP. RUN COMPLETION MW: 0.0 LD DP T/2700. RU T/DISPLACE DIESEL T/2700. TOOH T/RUN SCAB LINER/7-5/8". TIH W/LINER. CIRC 150 DEG. SEAWATER. RETURNS 110 DEG. FOLLOWED W/DIESEL. SPOT DIESEL BEHIND LINER. SET SLIPS ON LINER & PACKOFF. WELL : DS 6-7 OPERATION: RIG : DOYON 16 PAGE: 5 06/12/95 (18) TD:ll610 PB:11547 06/13/95 (19) TD:ll610 PB:11547 MU HGR MW: 0.0 CIRC DIESEL IN PACKER AREA. SET BTTM SLIPS & PACKER. TEST PACKER T/800. TEST LINER T/3000/30 MIN. CBU. LD DP & DCS. RU T/RUN 4.5" COMPLETION STRING. PULL WEAR BUSHING. RUN 12.6#$ L-80 NSCT 4.5" TBG. TEST T/5000. RIH W/5.5" 17# BUTT MODIFIED. CBU & ADD INHIBITOR T/SEAWATER. SPACE OUT & PU 5" PUP. MU TBG HANGER. TEST T/5000. LAND COMP. STRING. RELEASE THE RIG MW: 0.0 LAND TBG. ND BOPE. NU ADPTR FLG. & TREE. TEST T/5000/30 MIN. TEST ANNULUS T/3000/30 MIN. SHEAR OUT RP @3000. PUMP 150 BBLS DIESEL T/ANNULUS, U-TUBE T/TBG. SET BPV. RELEASE RIG @ 1800 HRS ON 6/12 SIGNATURE: (drilling superintendent) DATE: · STATE OF ALASKA ALASKA C AND GAS CONSERVATION COl ISSION REPORT el SUNDRY WELL OPEi AT[ NS 1. Operations performed: Operation shutdown Stimulate Pluggi.g Pull tubing Alter casing Repair well Other 6. Datum of 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 20' N & 1040' W of SE cr Sec 2, T10N, R14E, UM. At top of productive interval 719'N & 1156' Wof SE cr Sec 1, T10N, R14E, UM. At effective depth At total depth 684' N & 674' W of SE cr Sec 1, T10N, R14E, UM. 5. Type of Well Development , X Exploratory Stratigraphic .. Service ., 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-7 9. Permit number/approval number 78-21 10. APl number 50 - 029-20299 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11610 feet 9338 feet Plugs(measured) PBTD Tagged @ 11225' MD (1/27/96) Effective depth: measured 11225 feet true vertical 8996 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 117' 20" 270 Sx AS 117' 117' Sudace 2668' 13-3/8" 5400 Sx PF II 2732' 2732' Production 11524' 9-5/8" 1300 Sx Class G 11588' 9297' Perforation depth: measured 11186 - 11192'; 11204 - 11214'; 11224- 11253' true vertical 8964 - 8968'; 8979 - 8987'; 8995 - 9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, BUTT-MO Tbg @ 2174' MD; 4-1/2", 12.6#, L-80, NSCT Tbg @ 10378' MD. Packers and SSSV (type and measured depth) Baker SB-3 Packer @ 10341' MD; 5-1/2", HES HRQ SSSV. ~.;~F~I' MD. 13. Stimulation or cement squeeze summary - Intervals treated(measured) see Attached l'~,~ ~ '~ 3'~J~J6 Treatment description including volumes used and final pressure ~.~ 0~.~ & ~'~ CO~$. C'~i~s~°~ 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1998 1670 0 -- 303 Subsequent to operation 1970 // 1506 0 -- 231 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas~ Suspended...._. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~,,.x /~'l,q. ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date .2_/2 7/~'~ SUBMIT IN DUPLICATE 6-07 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1/27/96: RIH & tagged PBTD at 11225' MD. 1/28/96: MIRU & PT equipment. RIH w/perforating guns & shot 6' of reperforations as follows: Reperforated: 11186 - 11192' MD (Z2) Ref. Log: BHCS 8/21/78. Used a 3-3/8" carrier & shot 2 spf at 0 degree phasing at underbalanced pressure. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. STATE OF ALASKA ALASKA , AND GAS CONSERVATION CC /IISSION REPORT SUNDRY WELL OPE-RATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 20'N & 1040' Wof SE cr. Sec. 2, T10N, R14E, UM At top of productive interval 719'N & 1156' Wof SE cr, Sec. 1, T10N, R14E, UM At effective depth At total depth 684'N & 674' Wof SE cr, Sec. 1, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-7 9. Permit number/approval number 78-21 10. APl number 50 - 029-20299 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical Casing Length Conductor 117' Sudace 2668' Production 11524' 11610 feet Plugs(measured) 9338 feet 11547 feet 9286 feet Junk(measured) Size Cemented 20" 270 SX AS 13-3/8" 5400 sx PF II 9-5/8" 1300 sx CI 'G' Measured depth True vedicaldepth 117' 117' 2732' 2732' 11588' 9297' Perforation depth: measured 11204-11214'; 11224-11253' true vertical 8979-8987'; 8995-9019' 0CT I i995 Alask~t .0il .& Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, BUIT-MO Tbg @ 2174' MD; 4-1/2", 12.6#, L-80, NSCT Tbg @ 10378' MD. Packers and SSSV (type and measured depth) 5-1/2", HES HRQ SSSV @ 2161' MD; Baker SB-3 packer @ 10341' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 1244 32877 0 Tubing Pressure 1463 1911 1267 39 -- 298 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~,,,~ ~/~1 · ~ Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 Kamiso cc: KZ, JWP SUBMIT IN DUPLICATE 6-7 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 8/4/95: RIH & tagged PBTD at 11438' MD. 8/7/95: MIRU CTU & PT equipment. RIH w/CT & pumped 66 bbls of gelled sand slurry containing 10654 lbs of sand, to spot an isolation sand plug across the lower open perforation intervals located at: 11204 - 11214' MD (Z2) 11224 - 11253' MD (Z2) Ref Log: BHCS 8/21/78. Made a top of sand plug tag at 11166' MD. POOH w/CT. Rigged down CTU. RIH w/dump bailer and tagged sand at 11158' MD. Made runs w/bailer & dumped 8 gallons of high density sand to raise the sand plug to 11156' MD. POOH w/bailer. Rigged down. 818195: An Acid Wash was performed as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/CT & while pumping 51 bbls of Seawater, then reciprocated an acid wash across the leaking squeezed perforations located above the sand plug at: 11103 - 11156' MD (Z2: Sqzd/Leaking) 11172 - 11192' MD (Z2: Sqzd) Ref Log: BHCS 8/21/78. Pumped 15 bbls 12% HCI w/10% Xylene, followed by Seawater Flush. Shut in choke & squeezed acid into formation. POOH w/CT displacing w/Meth Water. Rigged down. 8/1 0/95: A CTU Cement Squeeze for Gas Shutoff was performed as follows: MIRU CTU & PT equipment. RIH w/CT & fluid packed the wellbore w/Seawater, then pumped cement to squeeze the leaking squeezed perforations (listed above) located above the sand plug. Pumped 33.5 bbls of Latex Acid Resistive cement & placed 3 bbls of cement behind pipe at 3500 psi max squeeze pressure, held for 1 hour. Contaminated cement w/biozan & jetted cement from wellbore to 11175' MD. POOH w/CT. Rigged down. 8/1 4/95: RIH & tagged PBTD at 11171' MD. 8/29/95: RIH w/CT & jetted a sand plug fill cleanout w/biozan to 11315' MD, to uncover the open perforation intervals (listed above). POOH w/CT. Rigged down. Placed the well on production & obtained a valid welltest. GeeQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTIJ: Sherrie NO. 9628 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8/9/95 Field: Well Job # Log Description Date BL Prudhoe Bay ~ Floppy RF Sepia DIR MWD Disk D.$. 6-7 ~ ~ CJ O- I PROD PROFILE 950724 1 1 D.S~, 12-30 ~ ~ JL~ ~Z~ PRESSURE BUILD UP 950721 1"' 1 " D.$. 14-29 <~ ! j PROD PROFILE 950721 I 1 D.S. 15-14 ~ I I-3 ~ PERFRECORD 95072.1 I I . D.S. 15-24 ~ I . /.'2_~ LEAK DETECTION 950721 . . I 1 D.S. ,,, 15-36 ¢~ ~ ~ 7."7---- PERF RE.CORD 95 07 2 4 1 I ....... D.S. 18..-2A ~ ~ .(~ :~ 4::) . .. PROD PROFILE 95071 6 I 1 D.S..,15.-25~ ~'J~'O 95261, DUAL BURST TDT'P ~7 ,~ ~ 950725 1 D:S. 11-3A c~./.!~ 95260 CNTD ,~._<Z~7~_~¢~/, 950718 1 D..S. 15-1 ~':Z'~ 95262 DUAL BURST TDT-P~a'~ j7~~ 950726 1 , , , ,, Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9510 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 6/7/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date ElL RF Sepia DIR MWD Disk ~'LJ-I,~,'~ D.~, 05-16A .... .. 95111 sLIM1MWDGR ........ . 110794. . ....... 1 .... ·'i~/Y D.S. 4-16 ,,CNTD ,, , 052295 1 1 ~4~-~7/ D.S. 4-19 .... . . . DUAL BURST'TDT-p 052895 I "' 1 ~'t/.,~) D.S. 4-47 DUAL BURST TDT-P 052595 I I ..... D.S. 6-7 CHEMICAL CUTI'ER RECORD 05 2 7 9 5 I 1 ~.S. 9-37 DUAL BURST TDT-P "I" 0~2495 ' 1 1 .... D.S. 18-20 PRODUCTION PROFILE 052695 I 1 .... D.S. 15-14 PERFORATION RECORD 052695 1 1 ................. ,, , _ ............ , ...... SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: JUN 0 9 3995 ~,a t3t & ~a~ teas, Commission ,.. MEMORANDUM TO: THRU: David Johns '~t~ Chairman'~__.,x Blair Wondzell~r P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 3, 1995 FILE NO: AGIJFCCD.DOC FROM: Lou Grimaldi,~/,~ SUBJECT: Petroleum Inspector BOP test Doyon rig #16 Arco well # DS 6-7 Prudhoe Bay Field PTD # 78-21 Saturday, June 3, 1995: I witnessed the weekly BOP test on Doyon rig #16 which was.working over Arco well # DS 6-7 in the Prudhoe Bay Field. The test was started at 1300. A Iow/high test of 300/5000 psi was put on all BOPE with the exception of the annular preventer which was tested to 300/2500 psi. A recharge test was performed that showed the accumulator was in satisfactory shape. The choke manifold was tested with all valves operating properly and holding their pressure test of 300/5000 psi. The gas detection system was tested. All components functioned properly although the high alarm on the methane detectors somehow during the testing was disabled and gave the electrician some trouble in getting it to sound again. This problem was resolved and the rest of the detectors were tested. I found the condition of the rig to be in very good shape. SUMMARY: I witnessed the weekly BOP test on Doyon rig #16. Test time 2 hours, no failures. Attachments: AGIJFCCD.XLS CC: Scott Sigurdson/Tom Horten STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Workover: X DOYON Rig No. 16 PTD # ARCO ALASKA Rep.: PBU DS6-7 Rig Rep.: Set {~ Location: Sec. Weekly X Other DATE: 6/3/95 78-21 Rig Ph.# 659 - 4610 Everett Potter Jim Willingham 2 T. 1ON R. 14E Meridian UM ~llSC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Standing Orders OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK PTD N/A Test Quan. Pressure 1 300/2500 I 300/5000 I 300/5000 P I 300/5000 P I 300/5000 P 2 300/5000 P I 300/5000 P N/A N/A N/A P/F P P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Gas Detectors OK OK H2S Detectors OK OK TEST DATA FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 300 / 5000 P 300/5000 P 300/5000 P 300/5000 P CHOKE MANIFOLD: No. Valves 14 ,, No. Flanges 36 Manual Chokes Hydraulic Chokes Test Pressure 300/5000 300/5000 Functioned Func~oned P/F P P P P ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 1,800 I P 200 psi Attained After Closure minutes 29 System Pressure Attained 1 minutes 35 Blind Switch Covers: Master: OK Remote: Nitgn. Btl's: 6 BOTTLES 2300 Psig. sec. sec. OK TEST RESULTS Number of Failures: ,Test Ti~e: '2 'Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to :he AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector FI-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FCCD.XLS Louis R Grimaldi GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk ,D.S. 6-8 "~. O-~..~-. DUAL BURST TDT-P (6-15-94)(j t~, ~-'__~ 1 ,D.S. 6-12A~-"~ -G~ ~ DUAL BURST TDT-P (5-29-93) ~ ~ ~ 1 ,D.S. 6-13 ~ ~~ DUAL BURST TDT-P (4-27-93) ~ ~% 1 D.S. 6-14A/ CNTD (2-14-93) '~ ... 1 D.S. 6-22A ~ ~'-~7 CNTD (5~22-94) ~ ~ 7/ ... 1 D.S. 7-4A O-O~7 CNTD (5-21-94) (~q <~_ ... 1 D.S. 7-17~. -~~ DUAL BURST TDT-P (8-5-94)~' "~~ 1 D.s. ~-~ ~ ~- ~ 'C.~D (S-=~-~) ~ ~ ~ =.S. ~-~= ~ c~ ~,, ~ 'C.T= (S-~0-~) ~ H G( D.S. 9-37i ~ C~ ~ CNTG (8-27-94) 1 D.S. ~-~/ 0 {- O DU~ SU.ST T=T-P (S-~-~4) ..... ~ ~~ ,_ D.S. 11-20i ' O~~ CNTG (5-al-94) Tn~':F~ 1 DUnL SU.ST TDT-P (S-~-~4) ~ ~ D.S. 12-26 CNTD (6-22-93) ~ 5rgW . ~ % L J V : 1 D.S. 14-3 7~-~~ CNTD (3-28-94) .. .~'~ ~,, ~. _ I Please sign and retrun one copy Naska Oil & Gas Con~. Comr~is;ion ~0mge DATE: Page 3 F~0 W. lrrtemaflonal Ai~ Road Anchorage, Al( 99~18-1199 ' ATIN: $~ertie NO. 8852 Company: Alaska Oil & Gas Cons Oomm , Attn: Lam,/Grant : 3001 Porcupine Drive Anchorage, AK 99501 8/10/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar A ~ - P~ 'f.. I D.S. 4-26 .. LEAK DETECTION (7-15-94) ..... 1 1 '~--C,. ~ D.S. 4-2 BAKER IBP (7,17-94) 1 ...... 1' ~ D.S. 12.10A PERF RECORD (7-15-94) I " 1 '" ~"'~ ...~ ? D.S. 13-27 PROD PROFILE (703-94) . 1 1 ..... ~7-7~-Q t_ D.S. 7-01 PROD PROFILE (7-13-94) ... 1 ... 1 re//~ ') ~ D.S. 17-8 . INJECTION PROFILE (7-19-94) ..... 1 ' 1 ~o~!~.'~_~ D.S. 16-16 ..... INJECTION PROFILE (7-14-94).. 1 . . . 1 ~ ~'"¥ 7 D.S. 5-5 TUBING CRJTTER RECORD .(7-17-94) 1 1 '~A -, ~ f _ D.S. i7-11'9, . "' ' PROD PROFILE (7-16-94) 1 ......... 1 '2 ~"- 1.1 _D.S. 6-7 DUAL BURST TDT-P (7-]3-94) 1 1 .......... "L/.) .... '~qt /t'", ' I: SIGNED: DATE: PI~ ~ ~d ream one copy~f ~ia ~a~miflal to SheMe ~ the a~ve adding. ~k you. ALASKA~ INC. BOX ~O0~6O ANCHORAGE~ ALASKA DATE · 8-7-cZ t REFERENCE: ARCO CASED HOLE FINALS 6~.~t_,B.. 4-'7-9t F'ERF' RECORD i-7' 7-i7-9i DIFFERENTIAL 'I'EMP i -7~ 7-t 7-9t F'DK-t O0/GR/CCL t-22' 4-t4-9t PERK RECORD ** 2-3 z 7-2 t -9 t COLLAR/F'ERF d~ J-~,'7 4-37" 7-20-9t COLLAR " _-~,(~-36/ 7-t8-9t GR-CCL d~ J '('/5-36' 7-i 9-9i F'ERF-F'ACKER 6-4' 6-7-9i F'ERF RECORD 6-7~ 4-t0-9t PERF RECORD 7-33- 4-28-9t COLLAR/F'ERF 9-9' 7-i 7-9i VERTILOG ~.. 9-34.~ 7-6-9t F'ERF RECORD 42, 7-3-9t PERF RECORD tt-t' 5-t2-9t F'ERF' RECORD ~t-3' 5-t8-9t PERK RECORD 't t-5 - 7-t 2-9t F'ERF' RECORD t 3-2A¢ 7- t 5-9 t JEWELRY-F'ERF t 6-24- 7-8-9t COLLAR t7-3- 7-7-9t PERF RECORD t 7-t t- 4-24-9i COLLAR i 7-i t' 7-t 9-9t COLLAR/PERF RUN t, 5" RUN i, 5" RUN t, 5" RUN i, 5" RUN t, 5" RUN t, 5' RUN t, 5" RUN i, 5" RUN t, 5" RUN i, RUN t, 5' RUN t, RUN t, 5' RUN t, 5" RUN t, 5" RUN t, 5' RUN t, 5" RUN RUN RUN RUN RUN t, 5" PLEASE SIGN AND RETUR RECEIVED B¥~_~ HAVE A NICE DAY! $ONYA WALLACE AT0-i529 N THE ATTACHED COPY AS RECEIPT OF DATA. DISTRIBUTION 'CENTRAL FILES ~ 'I' CHEVRON D & M EXTENSION EXF'LORATION ~ EXXON ~ MARATHON MOBIL APF, ROvED~ F'H ILL I F'S 4nChor~;' ~/**1~ F'B WELL F'ILE~ R & D BPX ~I'ATE OF ALASKA TEXACO HL$ ATLA~ A~LA~ HL~ AI'LAZ ATLAS $CH $CH HLS HL$ HL$ ATLA~ HL$ HL$ HLS HLS HL$ HL$ ATLAS HL~ HL~ ATLA~ * THE CORRECTED AF'I$ FOR t-tB I$ 50-029-2t007-0t ** THE CORRECTED AF'I~ FOR 2-3 IS 50-e29-2Ge, 77. ARCO ALASKA, INC. P,.O. BOX t00~66, · ANCHORAGE, ALAYKA DATE ' _,~- :)')- 9 i-... F.:EFERENCE' ARCO CA£'ED HOLE F-'iNAL_~ 3-22 t 2-28-90 GR 5-'.)~ 4-2'~-o t ?BL 6-7 t 2-5-9,3 TEMP.."'$F' INNER 7-28 5-4--91 LEAK DETECT. ~-S, i -~-i,...."z - cO, CORR GR 9-45 t 2-t O-90 TEMF' t ")-~ t,:.."':" _--)o_o r..,,:..,... , ,.. GR t "~'-"' ., ,... ,. I V . ILOG ~ U[~ ~--i o_o ERT i,....'-~-i 8_..':'--- 3- ° i, , PROD , F'r4'OFILE., t.,..?--")'°.-, ..~ -- ':': -- ":-' i_. . F'ROD , F'ROFILE i4-i3 5-t -9t IN J, F'ROF"ILE t 6-6 5-6-91 COLLAR/PERF t 6-9A. ..,-~-~-":" t_.. , CBT t6-9A ~-~-9t CET t6-9A 5-6-9t F'ACKEER REC. 18-!t 5-4-9t 6A~ DETECTION F'LEA£E 216N AND RETURN THE ATTACHED 'COF'Y /-- F..:ECEIVED BY. HAVE A NICE DAY! SUNNY WALLACE ATO-:i 529 RUN i , 5' RUN t , 5' RUN t, 5' RUN t , 5" RUN t , 5' RUN t, ~ Ri'*J i , ~' RUN i , ~' RUN t, ~.~'" RUN t, ~" RUN i, %" RUN t , 5' RUN i, ~' RUN !, ~' HR£' A'i-t_A2' HRI~~. CAMCO HR2 HR2 H,R,S' A TI_.A:-7. CAMCO CAMCO CAMCO A]'LA~? £CH ~"C!--! ,S'CH CAMCO AS RECEIPT OF DATA. ' ............"TRAN$-'~APPRO'V'ED91 ~ ........... i D I 'Z,' T R I BUT I ON ~ CENTRAL FILE2 '"-..CFtEVRON D & M ~ EXTEN£'ION EXPLORATION .,,.~E;./..XON HARATHON ~ MOBIL ~ RHILLIF'2 F'B WELL F'IL.E,~: R & rD ~'" BF'X ~ 2TAi'E OF ALAZ.'KA TEX,~CO THE AF'I$ FOR 5-20 I2 RECEIVED MAY 2 5 1991 Alaska 0il & Bas Cons. Commj~ion .......... Anchorage ~lAllr_ UI- ALASKA ALASKA , AND GAS CONSERVATION CC fISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repairwell Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 20' N & 1040' W of SE cr, Sec. 2, T10N, R14E, UM At top of productive interval 719'N & 1156' Wof SEcr, Sec. 1', T10N, R14E, UM At effective depth At total depth 684' N & 674' W of SE cr, Sec. 1, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic , . Service 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-7 9. Permit number/approval number 78-21/90-518 10. APl number 50 - 029-20299 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11610 feet Plugs(measured) 9338 feet Effective depth: measured true vertical 11547 feet 9286 feet Junk(measured) Casing Length Conductor 117' Surface 2668' Production 11524' Size Cemented 20" 270 sx AS 13-3/8" 5400 sx PF II 9-5/8" 1300 sx CI 'G' Measured depth 117' 2732' 11588' RECEIVED True vertical depth 117' 2732' 9297' Perforation depth: measured 11204-11214'; 11224-11253' true vertical 8979-8987'; 8995-9019' Alaska 0ii & 6as Cons. C0m~ss't0~ '..Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 10431' MD; 4-1/2", 12.64t, N-80, NPCT tail @ 10550 M D Packers and SSSV (type and measured depth) 5-1/2", Camco Bal-0 SSSV @ 2215' MD; Baker SAB packer @ 10419' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 419 488 6 -- 203 Subsequent to operation 1394 896 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas Suspended. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~' ~ Form 10-404 Rev 06/15/88 Service Title Sr. Area Operations Engineer 224 703 JWS c: D. Warner, ATO-1479 SW JWP Date SUBMIT IN DUPLICATE DS 6-07 DESCRIPTION OF WORK COMPLETED STRESS FRAC TREATMENT, HYDRAULIC FRAC TREATMENT, & POGLM INSTALL 8/1 0/9 0 .' MIRU & PT equipment to 3500 psi. 11204 - 11214' MD (Z2) 11224 - 11253' MD (Z2) Performed a Stress Fracture Treatment of open perforations at: Ref. Log: BHCS 8/21/78. Made two runs in hole w/tools & shot tool twice at 11242 - 11254' MD, followed by runs to shoot once at 11230 - 11242' & once at 11205 - 11217' MD. RD. 12/5/90: MIRU & ran Temp/Spinner Logs. through perforations at: 11204 - 11214' MD (Z2) 11224 - 11253' MD (Z2) PT to 6000 psi, then pumped a Perforation Breakdown Treatment Ref. Log: BHCS 8/21/78. Pumped: a) 200 bbls 10# Gel, @ 20 bpm, followed by b) Shutdown. ISIP @ 2000. Ran Temperature/Spinner Logs. Rigged down. 12/14/90: MIRU & PT equipment to 8600 psi. 11204 - 11214' MD (Z2) 11224 - 11253' MD (Z2) Pumped a Propped Fracture Treatment through pedorations at: Ref. Log: BHCS 8/21/78. Pumped: a) 150 bbls 50# Gelled Pre Pad, @ 20 bpm, followed by b) Shutdown. ISIP @ 2542. Resumed pumping: c) 150 bbls Gelled Pad w/Scale Inhibitor, @ 20 bpm, followed by d) 85 bbls Slurry w/proppant concentrations of 5 to 15 ppg, followed by e) Meth/Water Flush, due to blender problem_.. Placed a total of 3,300 lbs of proppant into the formation. Rigged down. 12/17/90: MIRU & PT equipment to 8700 psi. 11204 - 11214' MD (Z2) 11224 - 11253' MD (Z2) Pumped a Propped Fracture Treatment through perforations at: Ref. Log: BHCS 8/21/78. R ¢EiVED Pumped: a) 150 bbls 50# Gelled Pre Pad, @ 20 bpm, followed by b) Shutdown. ISIP @ 2247. Resumed pumping: c) 150 bbls Gelled Pad, @ 20 bpm, followed by d) e) Gas Cons. Anchorage 85 bbls Slurry w/proppant concentrations of 5 to 15 ppg, followed by 247 bbls Flush. Placed a total of 13,000 lbs of proppant into the formation. Rigged down. 4/10/91: RIH w/per/orating gun and fired shots at 3887' MD & 7730' MD. POOH w/gun. RIH w/POGLM assemblies & set across perforated holes. Performed PT on annulus. Rigged down. Returned well to production & obtained a valid production test. ARC(] AL. ASI<A, INC. F',O. I-.'-:I)X ~ 00S60 ,-., ~ ,~., ~,~ A N (] H (] R A (.:, c ~ L_ A ,::. k A , ~ i 0 D A T E · i '2 .- :2 8 -- ? 0 F' J._ E A ,5' E ,~: I G. iq ~':':i N l) F;,' F.'_:: "1" I_! F;.] N T I"I[E A i" T A C 1--i ti:: D C 0 F' '( l;,' I-i: E: LEI V iT)i, :,'2-:"( .~~_.~ .... I'-{ A ",/' E (.", i'-,! l C: E D A ',,'" ! [) I ':d T F;.: i B ij ]" I 0 Fi t. :2: i..I ".., ':. L.: i"i ," L, L.. i ) RECEIVED JAN 9 1991 Alaska 0il & aas Cons. Commission Anchorage ARCO ALASKA, INC F'.O. BOX i00560 ANCHORA[;E, AL. ASKA 995t6' F: E 1-- E R E N C E ' ARCO CASED HOLE F"]'NAL_£' / i'-i(:) ii .... 24-90 DUAl.. BURST TDT-F'' I -i,.. ''~ i i -"~3-°;:'... . , ,, PDK- i 06'/f:..R/CCL.. i --i 2; i i -24-9(:) PDK -t O0/C;I;:/CC1../TEHP S-'~'.. :_,'" i i _.~ ;'~_ c.:,-:;.. , ._. CO L. L. AIR / P Et;:I:: / 6--7 i i.-.2'.i:.-'-;;'¢ DLJAI_. BUF;,'.'?T TDT-F' '"" 7-29 i i -i 7-9(::, CCL/F'ERF" c;'---5 t i '-.'~2-9¢ vr-rRT It_r~E; 9-4 t i i .-'2'"-90 CBT 9 .... 4 i i i --")2-':;'¢:..,.. , . CET "~ o,. _ ..4 '"~.._i i -'- ''~,... t - 9 n,, C B T .."" 9-'.42 i i ""-~ t~._ -':~6', CET/ 9-'4:.,': t i .... ,:.'-~"~-~;:'"~. , ,, CB'r, -' (::..... ~') ,. ....,. · .,..._, i i -- 22-9 (:,', C Er i" i i ..-23 i i .... i 9--9;5 TEHP SURVF. E"{-.-- i "~--~"-' I i-i 8--'.:;'¢ f":F'.'l /PERF: i":'-.°B.. ...,... t¢-2'.''--°;:',~. , ,,CCL STRIP i5 .... 2 i i-2--90 i"EHF:' SUF..'VEY i~ 4 i t--i':= ""- ~ "-'' ""' _.- . ..;.-90 uuL.,_~-~R/PERF iI::' .., ,~ .... ~'" -...* _., 2i i":" ,:'~1-9;"; fEi'it::' SURVEY i 6-! 9 f t --t 7-90 F'EF;:.F: P. ECORD I"tA V E A i"'J. ~. :.,~...T c, ~::- D A Y ! 1'" AT C !"1 '""' RECE I F'-f' RUN 9, D" RIJN i, 5" RLIN i , _:.~'" RUN t, __.,~" RUN I, ..¢'"'" RUN f, 5" I:;,'IJN i , 5:' RUN, 2, 'x.,. RUN 2, ~' RUN 2 ~' RUN i, 5:" 1%. ~.,-/., ": i ..' RLJN. i , _,'":-'" RUN i, 5 ' RUN i , _,.~:"" F:UN t, 5' RUN i, ...-~'" UP t)Al A. A F:' F' R 0 V E i) ~~~ T F.. ~-~ Iq.'. -,~ 9'7'4 6 2 2CH ¢~'r I_ A ATLAi: ATLAS $CI.-t A "F I.. A 2' Al'LAS 2 C H 2CH 2CH ~., I--I ~'[" L. HRS ~TL..AS HL.S HRS A f'l..AS HI.(S ~' C H DISI'RIBUTION i: CFN'¥RAL FILES ~: C I.-I E V R U t'~ D & M ,,-~" FX'f'E'NSIOi'4 EXPLORATION ~ E X X 0 N · ~r . HAF;,'ATHON "~ H (] B I L TI'-IIE AF:'I¢: FOR tO-8B I¢. 50-0"~°'-2n432'--02 F'FII LI_ I F'$ F'B WELL FILES R & D BPX STATE OF ALASKA TEXACO RECEIVED DEC 5 1990 Alaska 0il & Gas Gons. 6ommission Anchorage D A T E ' 8 .- i 7 - 9,3 REFERENCE' ARCO CAS'ED HOLE FINAL~' ,,i -".2 8- i (-)--90 F'ERF RECORI) 4-i 8.-i3--9;3 DUAL BUR.?T TDT-P ~' ii 8 7 9('} COLI_AI~:/F'ERF ~-i '1 '7-i i -9¢, DIAGNO~,~]-I;'' F'H '.5- i 4 8-i i --'9~3 PEF;.'.F RECORD ,6-7 8-i i -9':) COL_L..AR/F'ERI:" 6 - ':2 ,t, ~,° ... 9 "- (N', 6, C N L -' G._ p.. / F:_ F:_ L -'~,' ' 2 ? '?-27-9() INJECTION. PROF'ILE -"F-SS 8-'i i-.90 C:OL. LAR/PERf:' ~: F'-.,..c~-, ¢' INJECTION F'ROF_rI_E ~ 9--4'-' 8--- 5--- ~'":) CBi' --9 - 42 8 -5 '- 9 ,:3, C E '/' i i 4 o .... ':~'--- '-';'":; C N L..-- G R /C C L ,r' ~ k..' ; ,' '-' i t '-2,'5 8- i 2-9:) CC~LI..AF:/F'EF:F' · -'- i "2 '- ¥ 2 } ..... 2 .¥' "- 9 '::) !:' R 0 !-:' LJ C T ]] 0 iq, P R 0 F' l L E ..t-.3--- 7 8-5-',;',:') PERF' REC!3RD ~ 3-i ':2 ';:- 26-. 9 ;.~:, [.:, I A G NO:::;l' i C FH j ,3'-t 2 8-4'-9(:} PERF" RECORD ...i ...... ,' -- c, ,, - ...,c) ...... ~:.... c? F:~ F'R 0 D U C: ]' Z 0 N P R 0 F' I I_ E · ,..,,..4;;'WDWi '-'") 8-'7-96' CCI_ F'LEA;2E J:.'IGi'4 ANi)RE-f'URN THE ATTAC:HIEI)C:OPY RECEIVED H A V E A N I CIE D A ";". / A U G ~, ALL. Y H I.'] F"F E:J C K E:'R A T 0 - t .5 '2 9 N88J~ .811 .& RLIN i RUN RUN i , RUN i; i ',2' RLJN i RUN. R U N RUN RUN i RUN RUN i RiiN RUN i, 5 RUN RUN i, 5 RUN i , O: _:' i:;:iJN i , '5" RUN ~, 5" A."3-' RE:CE]:F'T OF' DATA, A F' P R 0 V E i:." .V.,Z~/_~ 'i'RAN~::~ 9':.~ ~.3 i ' ,5" ~CH ,~'CH A'rLAS' CA~'iCO 3'CH A TI_ A,'.? A'T L A,~;' CAMCO A'¥LA~S' CAMCO 5'CFt ~JCH A'f'LA:¢ ATI_AZ CAMCO '~ C H CAMCO CAMCO DI3'TRIBUTION _,ENTRAI_ F ILE6' C H E V R 0 N D & M EXTENSION EXPLORATION EXXON M A R A 'f' H 0 N · '" MOB I L F' H I I_ L. I F'.? F'B WELL. F'IL. ES R & D BF'X STATE OF ALASKA TEXACO * THE AF'I~: FOR it-23 I~7 5¢-0'29--2i6iF-2, ** THE CORRECTED AF'I~ FOR t3-7 IrS' 50-~29-20656), 1. Type of Request: Abandon Suspend Operation shutdown STATE OF ALASKA ALASK~--~IL AND GAS CONSERVATION APPLICATION FOR SUNDRY A'r--PROVA'[.S Re-enter suspended well 2. Name of Operator ARCO Alaska, Inc. Alter casing Repair well Time extension Stimulate X Change approved program Perforate Other 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 20' N & 1040' W of SE cr, Sec. 2, T1 ON, R14E, UM At top of productive interval 719' N & 1156' Wof SE cr, Sec. 1, T10N, R14E, UM At effective depth Plugging Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-7 9. Permit number 78-21 10. APl number 50 - 029-20299 11. Field/Pool Prudhoe Bay Oil Pool At total depth 684' N & 674' Wof SE cr, Sec. 1, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical 11610 feet Plugs(measured) 9338 feet 11547 feet 9286 feet Junk(measured) Size Cemented 20" 270 sx AS 13-3/8" 5400 sx PF II 9-5/8" 1300 sx CI 'G' Measured depth 117' 2732' 11588' True vertical depth 117' 2732' 9297' Effective depth: measured true vertical Casing Length Conductor 117' Sudace 2668' Production 11524' Perforation depth: measured 11204-11214'; 11224-11253' true vertical 8979-8987'; 8995-9019' "~. ~chora~ Tubing (size, grade, and measured depth) 5-1/2", 17~, N-80, NPCT~ 10431' MD; 4-1/2", 12.6~, N-80, NPCTtail ~ 10550' MD Packers and SSSV (type and measured depth) 5-1/2", Camco Bal-0 SSSV @ 2215' MD; Baker SAB packer @ 10419' MD Description summary of proposal x Detailed operations program BOP sketch x 13. Attachments 15. Status of well classification as: Suspended Date ~///~/~) Approval No.~2~ _~,~---~ ~ 14. Estimated date for commencing operation July 1990 16. If proposal was verbally approved Oil X Gas Name of apl)rover Date al)proved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/-'' ~ Title Sr. Area Operations Engineer FOR COMMIR~ION H~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Original Stgr~ecl By David W. Johnston Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Commissioner Approved Copy I~etu[ned _ Date SUBMIT IN TRIPLICATE 417 JWS cc: J. Gruber. ATO-1478 P1(6-7)W1-3 Drill Site 6-7 ARCO Alaska, Inc. intends to perform a STRESSFRACTM treatment on DS 6-7. The treatment will be performed as follows: 1. Make a gauge ring run with wireline. 2. Rig up Electric line. RIH with STRESSFRACTM tools and ignite opposite perforations at 11,204' to 11,214' and 11,224° to 11,253' in three tool runs. 3. Rig down Electric line. 4. Return well to production and obtain stabilized test. Note: STRESSFRACTM is a service of Servo-Dynamics Inc. of Calgary, Alberta. 6 ,5 4 2 COILED 'I'UBtNt~ UNIT BOP E~U ! PHENT 1. ~ PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAJAS 3. ~)00 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~ PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 2 H]REL]NE BOP EQUIPMENT 1. 5000 PSI '7" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELIN£ RAtaS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARCO Alaska, Ir~ Prudhoe L.~ Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 8, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' DS 6-7, Approval No. 9-828 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 6-7)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASK' OILAND GAS CONSERVATION MMISSION ~ REPOR',--OF SUNDRY WELL OPERATION 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 20' N & 1040' W of SE cr, Sec. 2, T10N, R14E, UM At top of productive interval 719'N & n1156' W of SE cr, Sec. 1, T10N, R14E, UM At effective depth At total depth 684' N & 674' W of SE cr, Sec. 1, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-7 9. Permit number/approval number 78-21/9-828 10. APl number 50 - 029-20299 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11610 feet Plugs(measured) 9338 feet Effective depth: measured true vertical 11547 feet 9286 feet Junk(measured) Casing Length Condu~or 117' Sudace 2668' Production 11524' Size Cemented 20" 270 sx AS 13-3/8" 5400 sx PF II 9-5/8" 1300 sx CI 'G' Measured depth 117' 2732' 11588' True vertical depth 117' 2732' 9297' Perforation depth: measured 11204-11214'; 11224-11253' true vertical 8979-8987'; 8995-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 10431' MD; 4-1/2", 12.6#, N-80, NPCT tail 10550' MD Packers and SSSV (type and measured depth) 5-1/2", Camco Bal-0 SSSV @ 2215' MD; Baker SAB packer @ 10419' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 2034 14475 97 Tubing Pressure 1145 Subsequent to operation 502 672 29 -- 231 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~--~ ~~' ~C~ ~ ~.~; Z'¢~f~c.__Title Operations Engineering Manager Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 307 D. C. Reem DS 6-7 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 10/15/89: MIRU CTU & Stimulation Equipment. PT equipment to 4200 psi. RIH w/CT, loaded well w/270 bbls of Crude, and washed perforations at: 11204 - 11214' MD Ref. Log: BHCS 8/21/78. 11224 - 11227' MD 11227 - 11247' MD 11247 - 11253' MD Pumped the following treatment: 55 bbls 12% HCI w/10% Xylene, followed by, 55 bbls 12-3% HC1-HF, followed by 54 bbls 12% HC1, followed by, 5 bbls Diesel. Displaced w/21 bbls Meth-Water. POOH. Rigged down. 10/17/89: The Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/441 bbls of seawater. Pumped 74.2 bbls of cement, squeezing perforations : 11204 - 11214' MD Ref. Log: BHCS 8/21/78. 11224 - 11227' MD 11227 - 11247' MD 11247 - 11253' MD Placed 7 bbls of cement behind pipe at 3000 psi squeeze pressure. Contaminated cement with 150 bbls contaminant. POOH. RD. 10/18/89: Jetted out contaminated cement from wellbore. 10/19/89: MIRU, and RIH to make tag run to 11476' MD. POOH. RD. 1 1/1/8 9: Reperforated: 11204 - l1214'MD 11224 - 11253' MD Ref. Log: BHCS 8/21/78. 11/5/89: N2 lifted well to flow. Returned well to production and obtained valid production test. Oil rate decreased by 1532 BOPD, but the decrease in the gas rate provided an incremental rate benefit of 1725 BOPD, resulting in a net oil benefit of 193 BOPD. ARCO ALA~TK A, P.O. BOX ANCHORAGE, ALA~'KA 995 DATE' tt-8-89 REFERENCE' ARC(] CASED HOLE FINAL~ 3-:2 t 0-t 3-89 EPILOG 5-t t 0-28.-89 COLLAR/PERF 5-t8 t0-28-89 PRODUCTION F'ACKE:R 6-7 t t-2-89 COLLAR/PERF 9-t ~ i t -5-89 COLLAR/PERF i 4-33 i ~-29-89 COLLAR/F'ERF i 5-i S t i --S-89 COLL. AR/F'ERF' t 5-t 7 ~ ¢-27-89 CNL-GAMMA t 5.-20 t 0-28-89 CF'E i 5-20 t 6,-29-89 PAL HAVE A NICE DAY! D I S'I'R I BUT iON RUN~" i&2, 5" RUN t , '5" RUN t , ...,~" RUN t , '~'...," RUN t, 5" RUN i, 5' R. IJN. i, _.,'=-'" F.:UN i, 5 ' RUN i , i/2'&i" RUN ~, ..,"~'" - CENTRAL FILES T ~ PH ILLIF',? ..-"'CHEVRON PB WELL F'ILE3' D & M R & D ~ EXTEN~?ION EXF'LORATION T ~ BF'X ~,- EXXON -,.'":gl'ATE OF ALA3'KA MARATHON '-~- TEXACO * MOBIL A'FL. A3~ ATLAS7 A FLAJ' ATLAS' A T I.. A .'_'._',' ATI..A;~7 A 'l' L.. A A'f'L.A~: £;C1-1 ,S' C H * THE CORRECTED API~ FOR t~-i7 IS ~(.~ ,.~oo .z, 4t26 ARCO Alaska, Inc. Prudhoe Bay _ .,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 13, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 6-7 Permit No. 78-21 Dear Mr. Chatterton' Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 6-7)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B - 6132-C STATE OF ALASKA ALASK/--"tL AND GAS CONSERVATION C MISSION APPLIC (ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 20' N & 1040' W of SE cr, Sec. 2, T10N, R14E, UM At top of productive interval 719' N & 1156' W of SE ct, Sec. 1, T10N, R14E, UM At effective depth At total depth 684' N & 674'W of SE cr, Sec. 1, T10N, R14E, UM Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate X Other X 6. Datum of elevation(DF or KB) 64 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-7 9. Permit number 78-21 10. APl number 50 - 029-20299 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 117' Surface 2668' Production 11524' 11610 feet Plugs(measured) 9838 feet 11547 feet 9286 feet Junk(measured) Size Cemented 20" 270 SX AS 13-3/8" 5400 sx PF II 9-5/8" 1300 sx CIG Measured depth True vertical depth 117' 117' 2732' 2732' 11588' 9297' Perforation depth: measured 11204-11214'; 11224-11227'; 11227-11247'; 11247-11253' ..- '.. true vertical 8979-8987'; 8995-8997'; 8997-9014'; 9014-9019' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 10431' MD; 4-1/2", 12.6#, N-80, NPCTtail @ 10550' MD Packers and SSSV (type and measured depth) 5-1/2", Camco Bal-0 SSSV @ 2215' M D; Baker SAB packer @ 10419' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation September 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby c/~irtify that the foregoing is true and correct to the best of my knowledge. Signed _,~ ~..~ ,~~~,.¢.~.~_ Title Operations Engineering Manager FOR I~OMMI~ION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- 15. Status of well classification as: Oil x Gas Suspended Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE ¢,. SMITH I Approval No. /~. ~,~ ~. Approved Copy · RGturned -¢ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE D.S. #6-7 CTU GSO Cement Squeeze PRELIMINARY PROCEDURE Objective: Acid wash the perforated intervals. Cement squeeze all perforations. Reperforate well and return to production. 1. RU slickline. Surge well with 2000 psi differential. Tag fill. 2. RU CTU and acid equipment. Acid wash all perforations. Flowback acid load and production test well. 3. RU CTU and cementers. Cement squeeze all perforations. Cement volume will be sufficient to cover all perforations. The intervals to be squeezed are as follows: (Ref BHCS dated 8/21/78) Perforations, MD 11,103'-11,156' 2 11,172'-11,187' 2 11,187'-11,192' 2 11,204'-11,214' 2 11,224-11,253' 2 Zone Comments Leaking Sqz Perfs Sqz Perfs-Holding Sqz Perfs-Holding Open Open 4. Hold 3000 psi surface squeeze pressure for one hour. 5. Dilute cement in wellbore with mud. 6. Cleanout diluted cement. 7. WOC for one week. 8. Reperforate well as follows: (Ref BHCS dated 8/21/78) Present Perfs, MD Zone Comments 11,103'-11,156' 2 Leaking 11,172'- 11,187' 2 Squeezed 11,187'- 11,192' 2 Squeezed 11,204'-11,214' 2 Open 11,224'-11,253' 2 Open Proposed Perfs, MD Density C0mment~ 11,187'-11,192' LSD Re-perf ? 11,204'-11,214' FSD Re-perf 11,224'-11,253' FSD Re-perf Denotes contingency perfs that will be shot only if well performance is poor after reperforating and testing the lower two intervals. 9. Return well to production. Test well frequently until well's performance is established. 6 4 2 COILED TUBING UNIT BOP EDU ! PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" I'IYE)~L~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. ~)00 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX HIRELINE BOP EOUIPMENT -- i iiii ii i 1. 5000 PSI 7" W£LLHEAI~ CONNECIOR rLANG£ 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW 1UB£ PACK-Orr . AFb'CF) Al.. A.~K A :. F'. O~ BOX ~ ANCHORAGE: AI...A..~KA 9951 DATE RF"FETF;,'FNCI::i- AF;,'Cr] f]AXFI') H01..F. FI'NAt.. 6- ? S --. t 6 .... 8 8 C fi H F' 0 ,~,' .T 'f' I:-!: F' R fi f) ~ I P, T ]: fi N F:' ~' CI F." I I. F F-? I I N ~ . 5" 6-'1 6 ,.A-I 7--tRR CI-~HF:'[q.~"]"f'F:' F'R'FIDllRT1t'~N F'R'rIFTI F F..'IIN 'i . ':~" ,", '-~ :;:~ ,'?:'~-t 6--8R Cf]MPO.S']'TF: F'RFIDI.IC. TI'[)N F'RFIF'I:I .F:' R'IIN 1 : ~ · 1:;'-..'?. ."4-2¢,-~,R .,~,~l.~~]l')F'F'F~'FOR'AT]'N,; I. ,],'; I-.i',,N'i. ,' F:'I..E:.'AXE',?.Tr,;N ANT) R '~' ~-'~f'" . CEIF:'Y A,~," I:?F ..... P'I" (IF DATA. RFCE'.I VFD ~Y ........................... HAVE: A W]:.r:F DAY' F:' I!? [; f.., Y BE'NNF. TT A'I" 0-- 'f ~ ,?9 AF'F'ROVE:DT'RAN'~ ¢.:~,2%:,_,,~/t ~ ............. ......... ___._ ................. D ? ,~' T I:? T ~! I]" '1' r: F A R F. F A R F,I-. . N T.-, A F' .'I: I .F",S' CFIFVF.'ON .F.. ¥ TI.:.: N,~' T 0 N F YF:'I. MA. F,'~THON F't"I T I.. I.. T F' .? F'..1F~ l,,I r---I t F' ]: 1 I::: .,,.'"- ¢ ~TATF OF AI...A,g'KA ~: TFYAC['i ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4274 Robert Iden Engineering Manager Prudhoe Bay Field March 25, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 6-7 Approval No. 78-21 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. Very truly yours, D. F. Scheve P Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 6-7)Wl-3 ~,r~ci~orage WELL S / 76 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRichfleldCompany STATE OF ALASKA -~ ALAb,,A OIL AND GAS CONSERVATION CON,.,,~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO A1Rsl~: Tnt,_ 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 20' N & 1040' W of SE Cr. Sec. 2, T10N, R14E, UM At top of productive interval 719' N & 1156' W of SE Cr. Sec. 1, T10N, R14E, UM At effective depth At total depth 684'N & 674' W of SE Cr. Sec. 1, T10N, R14E, UM 5. Datum elevation (DF or KB) RA ' RWB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 6-7 (44-1-10-14) 8. Approval number 78-21 9. APl number 50-- 029-20299 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11610 feet 9838 feet Plugs (measured) Effective depth: measured true vertical 11547 feet 9286 feet Junk (measured) Casing Structural Conductor 117 ' Surface Intermediate Production Liner Perforation depth: measured 11207-11217'; 11227-11256' true vertical 9003.8-9012'; 9020.3-9044' Length Size Cemented 20" 270 Sx AS 2732' 13-5/8" 5400 Sx PF II 11588' 9-5/8" 1300 Sx Cl C Tubing (size, grade and measured depth) 5½", 17#, N-80, 4½" 12.6#, N-80 @ 10550' MD Packers and SSSV (type and m_ easured depth) Camco Bal-O SSSV @ 2215' MD, Baker SAB packer @ 10419' MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure Measured depth True Vertical depth 117' 117' 2732' 2732' 11588' 9296.7' 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3300 29,370 0 -- 1000 600 0 Tubing Pressure 250 1900 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Submit in Duplicate 6/3/87 6/11/87 6/12/87 7/12/87 9/12/87 9/1 7/87 1 0/18/87 Drill Site 6 - 7 Coiled Tubing Unit Cement Squeeze Gas Shut Off Rig up coiled tubing unit. Acid wash perforations with the following volumes plus additives: 1000 gal Xylene 1000 gal 17%HCl 1000 gal 7.1% HC1:1.5% HF 1000 gal 17%HCl Pump 55 bbls of cement through the coiled tubing. Obtained 1600 p~J squeeze pressure and held for 50 minutes. Contaminated cement. Shut well in overnight. Jetted out contaminated cement. Shut in well. Perforate. Reference Log ' BHCS 8/21/78 11207 - 11217 4 spf 11227 - 11256 4 spf Flowed well. Reperforate. Reference Log 'BHCS 8/21/78 11207 - 11217 4 spf 11236 - 11256 4 spf Flowed well using artificial lift system. Nitrogen lifted well to flow. Rigged up coiled tubing unit. Acid washed perforations with the following volumes plus additives: 25 bbls Xylene 48 bbls 6% HC1:1.5% HF Flow well. R I::' I:;' I::: R E N C I::: ' 'f'AI::'IE..? kl/I :l:.?T:f hlf:; f'} I::' 1) A'f A .. 'RF:'CIE]'t/IED BY ............................................................................. I--IA",!I:; A NJ: F~I::: T')AY ! I::'I:::(:;!:;Y A'T'O .... t 5;29F:' · r ,.: ,.., ,.~ ,;, .,,.o, AF:'I::'F;~OVli!iD ............. .'!~/ ............................. DJ' YTI:;:I BUT ! rikl ~ Alu~kU 011 & Ga~ Oong. Oommlsslon R E C E I V E D Anchoraga AF;.'.C('I ALAS/K (.:~, ]' I-.J.C ,. I:;.'.li:: C Ii!: I V Iii: D B Y I-.IAVI!!; A NJ:CE I) AY! F:' I!:i (; (.; Y l=;: E N i'.! I!'.'. T T l) A T A., I) 15"F R I B I.I'F I F)~...J · ~ C I..I ;~'CH ,? C H Y C H YCH 5: [.'. I-.I ,.~ C H DATE: 44-9-87 REFERENCE: ARCO Cased Hole Final. 4-3 9-5-87 Co[ 4-7 8-22-87 Co[ 4-4t 7-44-87 Col 4-42 7-tt-87 Cot t-2G 7-4t-87 Co[ 2-42 7-22-87 Col. 4-22 7-24-87 5-4 8-2t-87 Col. 5-43 7-2&-87 Col 5-t7 9-23-87. 6-7 7-42-87 Col 7-44 7-t0-87 Collar 9-2 4G-45-87 Collar 9-34 8-2t-87 Collar 44-2& 7-34-87 ~oll~r tt-27 6-22-87 Col. l. nr 4t-27 7-34-87 Collar t2-88 9-3-87 Collar 42-~5 7-40-87 Col [ar t 2-t 5 9-~-87 Co [ I.~r t 3- 4 8-34 -87 Co [ [ a r 4J-40 9-3-87 Co[Jar 43-44 8-47-87 Co[[ar lar (Perforafion log) tar (Perforation Log) la)- (F'erfornfion Log) I. ar (P~.rfora~ion Log) [ar (Perforation Log) I. ar (Perforation Log) [~r (P.erforafion Log) I. ar [ar(Perforation [..o~ ) ~i I. og Jar (Perforation Log) (Perforation I..o~) (Perforafi~n I..o~) (F'er fm-a f ion (Perforaflon Log) Per foratton Log) (Perforation Log). (Perforaf. ioY~ I. og) Per forafion Log) P~rforafion Log) Per forafion Log) PI. ea.~e sign and return (be a_~j;a$-.bed copy a.~ receip Received By .... ~ HAVE A NICE DAY()% /Alasgau/-'' 4l'&Ga~Cons. Commission ~ '. ~chomge Peggy Bennett ., ATO-t 529 TRAN$ ~876G6 ~ Approved .... DISTRI~I.ITION Ro.n 4, Run t , 5" Run t , ~" Ru.~ '4 , Run t , ~" Run t , 5" R~ID t 5 ' Run t, 5" Run t, 5" Run t , 5" Run t , 5" Ru.~ t , 5" Rind t , 5" Ru.D t , ~" Run t , 5" Run t , ~" Run t, ~' Run t , 5" At la.~ At I. a ..~ At[ag At la..~ At I.a~ At la..~ A't I.a.~ ~f I.a~ Afla~ ~ I.a~ Afla~ At I.a~ At las At la.~ Atlas At la.~ Af I.a~ Phl I.I. ip~ P~ WeIIL Ft le.~ R& D State of-Al.a.~ka Texaco " ARCO Alaska, In(. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 8, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 6-7 Approval No. 7-553 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/jp Attachment cc: Standard Alaska Production Company Pi(DS 6-7)W1-3 WELLS/76 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany AR3B ~132 C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COk..,~lSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing I] Alter Casing [] Other [] 2. Name of Operator AR~O AI~.~](~ .. 3. Address P.O. Box 100360~ Anchorage, AK 99510 4. Location of well at surface 20' N & 1040' W of SE Cr. Sec. 2, T10N, R14E, UM At top of productive interval 719' N & 1156' W of SE Cr. Sec. 1, T10N, R14E, UM At effective depth 6_~t4tpt ~ d.e p,t b, & b/4' W of SE Cr. Sec. 1, T10N, Ri4E, UM 5. Datum elevation (DF or KB) 64 ' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS-.-.6- 7 (44-1-10-14) ~A'~-Pro~'al n---"~er ~ . 9."'A~ql_p u m be r ~ 50 10. Pool Prudhoe Bay 0tl Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor 117' Surface Intermediate 2732 ' Production 11588 ' Liner Perforation depth: measured 11204-11217'; 11224-11256' true vertical 9001-9012'; 9018-9044' 11610 feet 9838 feet 11547 feet 9286 feet Plugs (measured) Junk (measured) Length Size Cemented 20" 270 Sx AS 13-5/8" 5400 Sx PF II 9-5/8" 1300 Sx C1 G Measured depth Tubing (size, grade and measured depth) 5!~", 17#, N-80, 4!~" 12.6#, N-80 @ 10550' MD Packers and SSSV ftype and measured depth) Camco Bal-O SSSV @ 2215' MD, Baker SAB packer @ 10419' MD True Vertical depth 117' 117' 2732' 2732' 11588' 9296.7' 12. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure Gas Cons. ^,r:h0ra~' 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 107 89 0 -- 306 130 16 0 -- 268 14. Attachments Daily Report of Well Operations [;~ Copies of Logs and Surveys Run I } 15.1hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~[?'--~F Signed Form 10-404 Rev. 12-1-85 WELLS/76 PVL TitleOperations Engineering Manager Date Submit in Duplicate(~/ DRILL SITE 6-7 On September 12, 1987, the following procedure was performed on Drill Site 6-7: 1. MIRU wireline unit. 2. RIH with Schlumberger's Hyperjet II, 3-3/8", 22.7 gm/sht, 4 spf. 3. Pressure up on tubing with artificial lift gas. 4. Open well to achieve drawdown and shoot 11236-11256'. 5. Flow well for 5 minutes. 6. RIH w/guns to 11212'. 7. Charge tubing with artificial lift gas - open well and perforate the interval 11227-11236'. 8. Flow well for 5 minutes. 9. RIH w/guns to 11204.5'. 10. Charge tubing with artificial lift gas - open well and perforate 11207-11212'. 11. Flow well. 12. POOH and rig down. WELLS/764 ARCO Alaska, In¢'~' Prudhoe B~,x ,~ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager August 19, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 6-7 'Permit No. 78-21 Dear Mr. Chatterton: Attached is the Application for Sundry Approval performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/PVL/sd Attachment cc: Standard Alaska Production Company PI(DS 6-7)W1-3 detailing work to be RECEIVED Alaska Oit & Gas Cons. gommission Anchorage WELLS/76 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B 6132 C STATE OF ALASKA -' AL/-. ,A OIL AND GAS CONSERVATION CO,,..dlSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [ii1 Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ½ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P: 0_. nO× ]_r)f1360~ Anr_hora0~~ Al< 4. Location of well at surface 20' N & 1040' W of SE Cr. Sec. 2, TION, R14E, UN At top of productive interval 719' N & 1156' W of SE Cr. Sec. 1, TION, R14E, UM At effective depth At t°ta' I~e~th67 684' 4' W of SE Cr. Sec. 1, TION, R14E, UN 5. Datum elevation (DF or KB) 64' RKB feet 6. Unit or Property name Pr~Jdhn¢, Ray Ilnit 7. Well number DS 6-7 (44-1-10-14) 8. Permit number 78-21 9. APl number 50-- 029-20299 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical 11610 feet Plugs (measured) 9838 feet Effective depth: measured 11547 feet Junk (measured) true vertical 9286 feet Casing Length Size Cemented Structural Conductor 117' 20" 270 SX AS Surface Intermediate 2732' 13-5/8" 5400 Sx PF II Production 11588' 9-5/8" 1300 Sx Cl G Liner Perforation depth: measured 11103-11156'; 11172-11192'; 11204-11214'; 11227-11247' true vertical 8919-9037' (4 intervals) Tubing (size, grade and measured depth) 5½" 17# N-80 4½" 12 6# N-80 @ 10550' MD Packers and SSSV (type and measured depth) Camco Bal-O SSSV @ 2215' MD, Baker SAB packer @ 10419' MD Measured depth 117' 2732' 11588' ~ue Vertical depth 117' 2732' 9296.7' RECEIVED Atasks- Oii d,. ,JaG Cons. Commission Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program L-] BOP sketch 13. Estimated date for commencing operation 9/5/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby/4~ertify that~he.~foregoing is true and correct to the best of my knowledge Signed ~}~~,~~/~--¢_,*'"~-.~' Title Operations Engineering Manager Date Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. F1Plug integrity F1BOPTost F-1L°cati°nclearanc~er~ .... '"~: ;; "'~'~' ~-~ by order of ~: ~,~:;']: '~' "~ '~'~f~;~:~ Commissioner the commission Date ~.' WELLS/76 < Submit in triplicate~ Drill Site DS 6-7 Reperforation Procedure Perforating I nformati on Achieve 1000 psi underbalance before perforating. (Lift off top 3500' out of tubing) Recommended gun size 3-3/8", 16 gram/shot, phasing 90 or 180 degree Perforating the following intervals: Zone Cased Hole Interval R_ef Log- BHCS, 8/21/78 Open Hole Interval* Ref Log- BHCS, 8/21/78 2 11204-11214'MD 11207-11217'MD 2 11224-11227'MD 11227-11230'MD 2 11227-11247'MD 11230-11250'MD 2 11247-11253'MD 11250-11256'MD * Cased hole log Schlumberger, CNL 8/25/78, is 3" deep with open hole log Schlumberger, BHCS 8/21/78. SPF RECE VED ,Alaska u~ ~, das (')ohs. Gommission Anchorage ARCO Alaska, Inc. Prudhoe Bay ~.ngineering Post Office Box 100360 Anchorage, A~aska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 30, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 6-7 Permit No. 78-21 Dear Mr. Chatterton: Attached is the Application for Sundry Approval performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DAR/jp Attachment cc: Standard Alaska Production Company Pi (DS 6-7)W1-3 detailing work to be WELL S / 76 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASIx,.~ OIL AND GAS CONSERVATION COMN,,oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well EJ Alter casing I1 Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [~ Perforate f¢ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK. 99510 4. Location of well at surface 20' N & 1040' W of SE Ct. Sec. 2, T10N, R14E, UM At top of productive interval 719' N & 1156' W of SE Cr. Sec. 1, T10N, R14E, UM At effective depth At total depth 684' N & 674' W of SE Cr. Sec. 1, T10N, R14E, UM 5. Datum elevation (DF or KB) 64 ' RKB feet 6. Unit or Property name Prudhoe Bay Uni't 7. Well number DS 6-7 (44-1-10-].4) 8. Permit number 78-21 9. APl number 50-- 029-20299 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11610 feet Plugs (measured) 9838 feet Effective depth: measured 11547 feet Junk (measured) true vertical 9286 feet Casing Length Size Cemented Structural Conductor 117' 20" 270 Sx AS Surface Intermediate 2732' 13-5/8" 5400 Sx PF II Production 11588' 9-5/8" 1300 Sx Cl G Liner Perforation depth: measured 11103-11156'; 11172-11192'; 11204-11214'; 11227-11247' true vertical 8919-9037' (4 intervals) Measured depth Tubing (size, grade and measured depth) 5~":z , 17#, N-80, 4½" 12.6#, N-80 @ 10550' MD Packers and SSSV (type and _measured depth) Camco Bal-0 SSSV @ 2215' MD, Baker SAB packer @ 10419' MD True Vertical depth 117' 117' 2732' 2732' 11588' 9296.7' 12.Attachments Description summary of proposal ~¢ Detailed operations program Fi] BOP sketch 13. Estimated date for commencing operation 9/5/87 14. If proposal was verbally approved Name of approver Date approved 15. I hereby/certify ths,t the forgoing is true and correct to the best of my knowledge Date Commission Use Only Conditions of approval Notify commission so representative may witness II Approval No...~ ¢~/::;:,¢ / ~ [] Plug integrity [] BOP Test [] Location clearance -- ,.~ Approved by Form 10-403 Rev 12-1-85 Commissioner by order of the commission Date Submit in triplicate WELl, 6-7 CTU CEMENT SQUEEZE WORK OVER PROCEDURE · · · · me e RIH with CTU. Clean fill and wash perforations with half strenp, th mud acid. Fluid pack wellbore with filtered water· Pump 45 bbls of cement and squeeze the following intervals: 11103-11156' MD 11172-11192' MD 11204-11214' MD 11227-11247' MD Ref: BHCS 8/21/78 Contaminate cement with a borax-bentonite mix. Jet/reverse out contaminated cement with gelled water. Perforate as follows: A, Reperf 11227-11247' MD Add perf 11224-11227' MD Add perf 11247-11253' MD Ref: BHCS 8/21/78 B. Test well and evaluate. C. Reperf 11182-11192' MD 11204-11214' MD Ref: BHCS 8/21/78 DAR/110 ~,IIL. -~ i~ ii ii _ i Ill Ilk1 II ~- : II ,, II"lI , [I . 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF NIRELINE BOP EQUIPMENT Ill I I I I Il 6 5 4 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6, 5000 PSI 4 1/16" STUFFING BOX I 1 I COILED ~UBINi~ UNI~ BOP EQUIPMENT ~';~RCO A[a.ska, Inc. :.'~,',".: Ju'r,.e i2 , f986 ,i!,d- S 6 8 7': ~, ftlc~ t..ai' =' i ATf].-I ,~2o..- TRAN$ -~8." ~' a ~ - ~, r ,? ,-r.r.-, m ,r_,t HMYE ~ NZCE '-Dc-.v~ RTO-'i_.-~ .. TRAN,S- ~:::: '" ~ a ,~ ARCO Alaska. Inc. Post Office Box 100360 &nct~orage. Aiast<a 99510 Telephone 907 276 1215 Date: June 21, 1985 Reference- ARCO Pressure Data 6-7/Static Gradient 4-28-85 Camco 9-6 JPBU 5-24/25-85 DA 12-25 q~FO 5-22-85 Camco 14- 35 q~BU 5- 31-85 Camco 14-35~Flowing Gradient 5-30/31-85 Camco 15-~ PBU ~ 9-11-84 sS 15-7/PBU .9-11-84 SS 15-8/'IPBU: 2-29-84 . SS 15-8/PBU 10-20-84 SS 15-8 fPBU 10-20-84 SS 17-5 'PBU 5-29-85 Camco sign as receiPt/~x da~ Received by Alaska 0il & Ga~ ~n~, ~mm~sme.' Anchora~je Pam Lambert ATO 1429C .Tran s 176 · Chevron D&M Expl., Services Ext. ·Exploration Exxon M~rathon Mobil Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO AlasKa. Inc. Post Off~ce Box 100360 Anchorage. AJasKa 99510 Telephone 907 276 1215 DATE: MAY 14, 1985 REFERENCE: ARCO PRESSURE DATA /6-2 STATIC GRADIENT 4-28-85 ,/6-7~ STATIC GRADIENT 4-28-85 7-7A STATIC GRADIENT 4-27-85 13 STATIC GRADIENT 4-27-85 ,/7-14 STATIC GRADIENT 4-27-85 7-16 STATIC GRADIENT 4-29-85 /7-25 STATIC GRADIENT 4-27-85 /13-3 STATIC GRADIENT 4-25-85 /13-4 STATIC GRADIENT 4-25-85 /13-13 STATIC GRADIENT 4-25-85 13-14 STATIC GRADIENT 4-25-85 /13-17 PF0 w/LISTING 10-29-84 jt3-23A FLOWING PRESSURE GRADIENT S j~t3-27 STATIC GRADIENT 4-25-85 f13-29 STATIC GRADIENT 4-25-85 /14-9B ~TATIC GRADIENT 4-26-85 / 14-19 STATIC GRADIENT 4-26-85 j/~-26 STATIC GRADIENT 4-26-85 i' PLEAS' ~ SIGN AS RECEIPT OF DATA, CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO SCH URVEY W/LISTING 10-27-84 CAMCO CAMCO CAMCO CAMCO CAMCO SCH RECEIVED BY PAM LAMBERT AT0 1429C TRAN$ #lO~hevron D& M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & ? Phillips PB Well Files R& D Sohio State of Alaska Texaco ARCO Alaska, Inc. ~ Post Office . 360 Anchorage. Alaska 99510 Telephone 907 277 5637 May 17, 1984 Reference: ARCO Pressure Data D.S. 3-19f' D.S. 3-22/ D.S. 3-23 D.S. 4-1~ D.S. 6-4f D.S. 6-7/ D.S. 6-18 D.S. 6-23 D.S. 7-20 D.S. 7-21 D.S. 7-22 D. S. 7-24 D.S. 7-25/ D.S. 7-26' D. S. 12-7A/ -D.S. 12-15" D.S. 12-18 D.S. 13-13 D.S. 13-15 D.S. 13-16 D.S. 13 33 D.S. 18-7 / 4-9-84 4-9-84 4-9-84 3-17-84 1-25-84 1-25-84 1-15-84 1-15-84 12-27-83 8-11-83 4-18-84 4-29-84 4-20-84 4-20-84 4-20-84 4-21-84 4-22-84 4-28-84 4-14-84 4-14-84 4-13-84 4-13-84 4-15-84 4-16-84 4-12-84 4-t3-84 4-12-84 41-5-84 3-14-84 3-14-84 ~se sign and return Static Camco Static Camco Static Camco Static Camco PBU GO Common Data Base Report PBU GO Common Data Base Report Horner Plots w/listing Sch Horner Plots w/listing Sch PBU Camco PBU DA PBU Camco Common Data Base Report PBU " Camco Common Data Base Report PBU Camco PBU DA PBU Otis Common Data Base Report PBU Camco Common Data Base Report PBU Camco Common Data Base Report Static DA PBU DA Pressure Draw-Down Camco Static DA PBU DA Common Data Base Report the attached copy as receipt of data. Kelly McFar land · ATO- 14 29F Chevron D & M Trans. % 187 Drilling Exp. Services Ext. Exploration Exxon Getty Marathon Have A Nice Day' D.ISTRIBUTION ' !~ Mobil Mobil g & P , ~ Phillips :" Prudhoe Bay Well R& D Carolyn Smith Sohio State of Alaska ARCO Oil and~as Company North Alaskq ~,lrict Post Offico E~,..,, 350 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 3, 1981 Reference: ARCO CASED HOLE FINALS D.S.4-1 8/10/81 CNL Run 2 DS..4-4 81/10/81 CNL Run 2 D.So5-14 1/22/81 TDT Run 1 D.S.6-7 8/7/81 CNL Run 2 D.S.9-3 8/9/81 CNL Run 1 DOS.17-6 2/6/81 CBL/VDL Run 1 1! 5" 5" 5~' 5'~ Please_ sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #567 DISTRIBUTION NORTH GEOLOGY EXXON R & D ~ MOBIL DRILLING GETTY ENG. MANAGER' PHILLIPS D & M SOHIO GEOLOGY MARATHOH STATE OF ALASKA CHEVRON ARCO Od and Gas Cor,~p,~y ,$ a O~v,~,,on of Al!anl,cR chl,eldCompany ARCO Oil and':'Gas Company North Alasl~'I ,istrict Post Office ~,-Ox 360 Anchorage, Alaska S9510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 27, 1981 Reference: ARCO Magnetic Tapes & Lists ~' D.Sol-16 8/8/81 Tape#62100 Run 2 Schlumberger D.S.4-f 8/10/81 Tape#62111 Run 1 " DOS.6-7 ~ ~8/7/81 Tape#62103 Run 2 " DOS.17-10 8/13/81 Tape#62077 Run 1 " 'P~~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #550 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO 0~1 and Gas Company ~s a O~v~slon ol AllanhcR~chl~eldCompany EXXON MOB I L GETTY PHILLIPS SOHIO ,'.-" I ,~' CHEVRON ' ,'; , ~ ; ',{~ , ..'~:)j :~,-;.~ .? N. Febn~a~y 11, 1.980 Re£crence' JLnclo~4 are Pressure Survey. :for the following ARCO wells' D.S. 6-5 5/20-21/79 Camco ;"~i S. 6-7) 8/8-9/79 Camco -*--Di~ ' 5/22- 25/79 Camco D.S. 6-8 10/23/79 Otis ~~ase sign and retrain the attached copy as receip~ of data. K J ~ .. . Sanlstrom North Engineering TPekXSMtTTAi, ~ 08 6 Post Office Dox 3~0 Ancho ;, .t:fa~ka 99510 October 15, 1979 Reference' Enclosed are Cased tlole ,Logs for the following ARCO wells' D,S. 2-3 7/2-3/79 - Spinner 5" D.S. 5-4 S/26/79 " S" . D...S~ 5/28/79 " 5" 8/9/79 " S" D.S, 14-5 8/7/.79 " 5" D.S, !2-2 8/7/79 TDT-K Run 1-A " " " Run 1-B '" " " t~n 1-C 5~' 5" G/Please sign and retm~ the attached cop}, as 'recFipt of.data. K. J, Sahlstrom North Engineering TP&NS~IIT£AL # 403 ARCO Oil and Gas Company Alaska Po~:t Ollic ex Anchorag,c. Alaska 9n~..~.,10 -relepi~on~} 907 277 5637 June 12, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9950 Subject: DS 4-12 Permit No. 78-18 DS 4-13 Permit No. 78-31 DS 6-1 Permit No. 75-49 DS 6-2 Permit No. 77-78 DS 6-3 Permit No. 75-73 DS 6-4 Permit No. 75-62 DS 6-5 Permit No. 78-20 .D.S..~.~.,.....~ --~ Permit No. 76- 20 ~..~.~6~=7.~.~'Per,nit No. 78-21 DS 6-8 Permit No. 78-22 Dear Sir' Enclosed please find a Col,~pletion Report reporting production information for the above-mentioned wells. Very truly yours, P. A. 'VanDusen F'O~ · District Drilling Engineer PAY-cs Attachments AF~CO Oil and Gas Company is a Division of AllarHicFlichlie!dCo,~,pan7 F(~r:n P---7 SUBMIT IN DUx ,,,CATE* STATE OF ALASKA !S~,~oth~,r m- reverse side~ OIL AND GAS CONSERVATION COSMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* · la, TYPE OF WELL: oli, [X-] GAS [~ [~ WELL WELL DRY Other b. TYPE OF COMPLETION: .~E~ []] WOR~ I--l, DEEP-[]] PL~ []] D~. []] Perforated WELL OVER EN BACK RESVR. Other NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESsOF OPERATOR P.O. Box 360 Anchorage, AK 99510 '~. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 20'N & 1040'W of SE cr Sec 2, TION, R14E, UM too prod. interval .reported below ~lg'N & l156'W of SE cr Sec l, TION, R14E, UM At total depth 684'N & 674'W of SE cr Sec l, TION, R14E, UM 5. API N~CAL CODE 50-029-20299 6. LF_.ASE DESdGNATION AND SERIAL NO. ADL 28311 7, IF INDIA.N, A.LLO'i~EE OR TRIBE NAME 8. UNIT,FAiLM OR LEASE NAME Prudhoe Bay Unit 9. WE~,L NO. DS 6-,7 (44-1-10-14) 10. FIELD AND POOL, Oit WII-j)(~AT Prudhoe Bay Field Prudhoe 0ii P0ol 11. SEC., T., R., M., (BOTTOM HOI_~: OBJECTIVE) Sec l, TI ON, R14E, UM 12. P~dVIIT NO, 78-21 8/2/78 J 8/22/78: [8/26/78(perf'd 12/11/[8) 64' RKB a 18. TOTAL DEPTH, MD & TVD[19. PLUG, B~CK MD & TVD~). IF NrULTI~PLE COM~L., 21. ;NTERVALSDRILI, ED BY [ - · [ HOW MANY* ROTARY T_ODLS [ CABI,E TOOLS ll,610'MD 9838'TVD [ 11547~'MD 9286'TVD [ Single All 22. PRODUCING INT~f~RVAL(S),O~ THIS COMPI.~ITIO~N'~'PC>P, BOTTOM, N~q~VIE(1V/D AND ~v-l))* 23. WAS DIRECTIONAL SUH, VEY MADE Top Sadlerochit ~lO,761'MD 8640'TVD ! Yes Base Sadlerochit 11;433'MD 9191'TVD i 24. TYPE EI.F-CTRIC A--ND OTHER LOGS RUN DIL/SP, BHCS/GR, FDC/CNL/CAL/GR, GR/CNL/CCL _ CASING RECORD (Report all strings set in well) 20~;/95":'5 Welded[H-40 mI 11~" ' 30"1270 SX Arcticset cmt 13-3/8 [72~ Butt [N-80 [ 273'2' ,17-1/2" 15400 sx Permafrost II cmt /4"[ 9-5/8" [47~ Butt ./a-80al l~,58g, ~2-~ 1300 sx Class G cmt ' ~ · / s00-9~ , SACKS C~I~T* SC~ (MD) SIZ~ DEPTH SET (MD) ~PACKER SET (MD) 5-1/2" '10,550' ' 10,425' 28. PErOrATIONS OP~ TO PRODU~O~ (interv~ size and number) 29. ACID, SilOT, [gASI URE, C~iENT SQUEXZE, ~C. 11 , 227-11 , 247' ~m~i ~'~v.~ (~) A~O~.~r ~.~ i~NO O~ ~,~'~:.~^~ .:.11,204-11,214' N/A 11,172-11 192' ' 11,103-11,156' w/4 shots/ft. ]V/ELL S~ATUS. (Producing or ~.~sT3/1/79 P~o~ucuo~ ..~°~Uc*~°~FlOwin~m°~ c~ow~g, ~. ~f~, .~m~--~ze ~.d ~ o~ p~m~ ~ . ~*~ .... >. ~.Pro~/,cq ng DATE OF TEST, [HO~S TES~ '[~tOKE SiZE [PROD'N FOR OI~BBL. GA~CF. WA'I'E~BBL. [GAS-OIL i ~/~0/79, I 6.0 ~ i 20 I ~-I ~866I2073 I 26 l~] ~Low~ ~BI~G ICA~G P~8~ JCAL~~ OI~BBL. GA~. W~BBL. [OIL GRAVITY-~I (CO~.) ~' ~49 I -- ! ~ 7463I 829~I ~0.3 27 . 1 31. DISPOSITION OF GAS (Sold, used ]or fuel, vented, etc.) TEST WITNESSED BY Re~ ~j ected 32. LI~T OF ATTACHMENTS 33. I hereby cert~y, that the/f~egoi~and attached information is complete and correct as determined from ali-available records [n neer *(See Instructions and S~ces [or AdditionaJ Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end :log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is usecl as reference (where riot o;herwise shown) for depth measure- ments given in other spaces on this form and in any attachmer'~ts. Items 20, :,nd 22:: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcJuci~.g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv,~l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional ir~te~val to be seperately produce,.:t, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). '34' SUMMAItY (')F FOi'~.N'IATI()N TES'I','4 INi.'I.UI)IN¢; IN'I'I-':.IIV^L, TF~C;'FF.D IHtE,'-LqURE DATA AND HECOVEI{IFZ"; ()F OIL GAS. 35 GEOLOGIC M A R Kl~:t~ WATEI{ AND MUD None ii i i i i i Top Sadl erochit 10,761 ' 8640' Base Sadleroch~t 11,433' 9191' .~n. COllE DATA, ANL~ I)E!{:'EiC'F.Et.) .',;-IN)WS OF OIL, G~.S OR tVA'rEll.. . f , . {, .- ..... , ~'~,- ,, ,-,,, None Box 330 March 29, 1979 Reference' - Enclosed are the following cased hole logs .'] 6~8 -' Dill, Temp. 10/31/78 "'~" 6-5 ~ eCL, 1_~_/18/7s /~.~'/-:-DB 6 - 8' CNL 10 / 30/78 ~~-~S-' 6-'1 v CNL 1.0/2]/78 / zo/ s/7s ~~~ Diff. Temp. '12/ 9/78 ~~GI ~2 ~ CCL w/dunm~y gun 11/21/78 ~~S. 6'6/~ Fluid Density 11/25/78 ~~[m~v z-zZ Diff. ~'emp. -. Please sign ~d return the copy as receipt Sincerely, V.G, Reimers North Engineering TRANSblITTN, #138 1) I STRI BUi'i ON North Geology F-,×xon Drilling Mobil Frog. bIanager (ietty R. & D Sohio Geology ' . ~larathon State of Alaska Phillip.s D & M Chevron Post Office Box 380 Anchorage,/~,~--~!(a 99510 Telephone ~ _77 5837 March 16, 1979 Reference: Enclosed are the following cased hole DS 4-53~ CCL. 12/ 3/78 DS 6-2v' CNL 10/26/78 DS 14-3~ CCL 12/ 1/78 'DS 6-6v CCL 11/25/78 6~~,,~ CNL 12/ 7/78 CCL/GR 12/ 2/78 Please sign'and return the copy as Sincerely, logs' receipt of V.G. Reimers North .Engineering TRANSMITTAL #101 North Geology Drilling Eng. Manager R6D Geology State of Alaska I) & lxl DISTRIBLF£ION }.:,XXO I1 Sohio Mob 51 Marathon Phillips Get ty Norlh ,,),;,-~erico. n Producing Division Norlh Alaska '-"-icl Post Ollice Ancl~o,"age, Alaska 99510 Telephone 9,37 277 5637 Februam/ 16, 1979 Reference' Enclosed are the following Pressure Surveys' DS'l-18 Static.Survey 12/26/78 DS 4-12 Static Survey 12/1/78 DS 4-13 Static Survey 12/3/78 DS 6-3 Static Survey 11/23/78 DS 6-4 Static Survey 11/23/78 DS 6-5 Static ~rvey 12/6/78 'DS 6-7 Static Survey 12/10/78 DS 6-8 Static Survey 12/11/78 DS 7-2 Static Survey 12/16/78 DS 7-4 Static Survey 12/19/78 DS 7-5 Static Survey 12/21/78 DS 9-20 Transient Survey ]2/4/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL # 73 DISTRIBUTION North Geology Drilling Eng. Manager R & D Geology State of Alaska D & M ...... Alas~a [;il ~, (; 'Exxo~ Sohio Mobil Marathon Phillips Chevron Ge t ty Yelephone 907 277 5337 January 22, 1979 Reference' Enclsoed are the foil. owing cased hole~oo~ DS 5-14 Cont. Flow 6/14/7S DS 9-17 Cont. Flow 6/28/78 DS 6--8 Borehole Audio 10/31/78 DS 3-7 Spinner 10/19/78 DS 9-9 Fluid Density 10/29/78 DS 6-2 CCL w/dummy gun 10/29/78 DS 1-4 CR/~ 11/~1/78 DS 6-4 CCg 11/13/78 DS 4-5 CNL 1]/14/78 NGI #2 CCL w/Dummy gun 10/27/78 DS 4-6 CNL 11/12/78 DS 2-1 CNL 11/11/78 NGI #2 CCL w/ Dummy gun 11/23/78 DS 5-12 Cont. Flow 6/10/78 DS 5-2 CNL 11/09/78 ./ / ' p ~.~*" / Please sign and return the copy as receit)t o£ data~/ ,/ ,, Sincerely, V.G. Reimers North Engineering TRANSHITTAL #033 DISTRI]~'UTiON North Geology Drilling Eng. Manager R&D Geology State of Alaska D & H Sohio Mob i 1 Narathon Phillips Chevron Ge t: t y Ai:~an ~if:~:~i'ch~i;~.ld Corn pan y North American Producing DiviMon North Alask~'~istrict Post Office ,. z 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 5, 1979 Reference: Enclosed are the following open hole logs: DS 6-7 DIL 2" 8/21/78 DS 6-7 BHCS 2~' 8/21/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #013 ~lor th Geology Dz'ilii~g Eng. M.~nager R& D Geology State of Alaska D&M DISTRIBUTION Exxon Sohio Mobil Marathon Phillips Chevron Getty AtlanticRichlieidCompany North American Producing Division North Alaskri~strict Post Office B~..., 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 27, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 [: SubjeCt: DS 6-5 Permit No. 78-20 (~ermit No.. 76-20 ermit No. 78-21 DS 6-8 Permit No. 78-22 Dear Sir' Enclosed find a Completion Report along with the Perforating History for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'cs Attachments Form P--.7 SUBMIT IN DUi-~IOATE* STATE OF ALASKA ',se,~ other h~- s~ rL~¢tions on reverse side) OIL AND GAS CONSERVATION COMMITTEE i i i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* b. TYPE OF COMPLETION: .NEW F-~OVERWORK [] £NI)EEP- [~]OAcKPLUO [~] DIFF.nEsvR.~L_J Other' Perforated WELL 2. N&ME OF OPERATOR Atlantic Richfield CoEpany ,. 3. ADDRESS OF OPERATOR P.O. Box 36_0, Anchoraqe, AK 99510 LOCATION OF WELL- (Report location clearly and in accordance with any State requirements)* At surface 20'N & 1040'W of SE cc SEC 2, TION, RI4E, OM At top prod. interval reported below 719'N & 1156'W of SE cr SEC 1, T1ON, R14E, UM At total depth 684'N & 674'W of SE cr SEC 1, T1ON, R14E, UM 5. API NUNLER.ICAL CODE 50-029-20299 6. LEASE DESIGNATION A.ND SERL~L NO. ADL 2831 l 7. IF INDIA.N, AJ-,LOTTEE OR TRIBE NAME '8. UNIT,FAiLM OR LF~kSE NAME Prudhoe Bay Unit 9. W~,I,L NO. DS 6-7 Prudhoe ua Prudhoe 0i2~rlejaPool - 11. SEC., T., R.. M., (BOTTOM HOLE OBJECTIVE) SEC l, T1ON, R14E, UM 12. PERMIT NO. 78-21 8/2/78 [ 8/22/78 . 18/26/78(perf'd 12/11/~8) 64' RKB. 18. TOTAL DEPTH, NIP & TVD~19. PLUG, B&CK MD & TVD~0. IF 1Vi/JLT1PLE CO1ViPL., '[ 21. INTERVAI,S DRILLED BY I I i ~OW~Y ROTARY T00I. R CABI,E TOOL8 ~ n e =. PRODUCING IN~VAL(S), OF ~IS C~MP~TION--~, BO~OM, N~E (~ AND ~)* 23. ~VAS DIREC~ONAL su.wv ~A.~ Top Sadlerochit 'lO,761'MD 8640'TVD Base Sadlerochit ll,433'MD 9191'TVD 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/GR, ,FDc/,S, NL/CAk/GR, GR/CN, L/CCL CASING RECORD (Report all strings set in well) 20" [95.5 Welded] H-401 117' 13-3/8" I 72# Butt | N-80[ 2732'. 9-5/8" ! 47# Butt I N-80[ 11,588' , I I soo-? , LINER !%EC OH/) 26. iiiii i 28. PEtLFORATIONS OPW-iN TO PRODIfC~ON ~interval, size and number) 29. ll ,227-11,247' 11,204-11,214' 11,172-11,192' 11,103-11,156' W/4 shots/ft. 30. PRODUCTION DATE FIRST PI%ODUCTION N/A DATE OF T]~ST, FLOW, TUBING 31. D'ISP0SITION HOLE SIZE I CF~\ILNTING RECOtkD 30" I 270 sx Arcticset cmt. Yes &MOUNT PULLED 17-1/2" I 5400 sx Permafrost II cm' 12-1./4" I 13DD ~x Cla_q~ g cmt I 27. TUBING RECO[kD SCREEN (MD) SIZE DEPTI{ SET (M~D) ~ PACICER SET (MD) 5 I/2" I'O,bbO' ' ] 10,425I 1 i ACID, Si!OT, F~kC'i LrRE, CEaNIENT SQUEeZe, ETC. I DI~TtI INTE2~VAL (MD) [AMOUNF £~ND I:~IND OF M;CI'Ei~/ALUSED N/A 1 'Fi{ODUCTION MEiHOD (Flowh~g, gas lif~, pumping--size and type of pump) I CHOXE SiZE IPROD'AT FOR OIL--BBL. GA~MCF. CA~G P~SSURE ICAL~~ OI~BBL, J24-HOUR RA~ [ oxS (8old, u,ed )or ]uel, vented, etc.) 32. LIST O~' A~kCHMENTS I V¢'ELL STATUS (Producing or g~tut-in) 1WATER~--BBL. ] GAS-OIL I-~A~TIO Iw~-~BL' l OIL GRAVITY-A-PI (COP~R.) TEST WITNESSED BY Perforating History .... 33.'I hereby certify %_bat the fore_going and attached information Is complete and correct as determined from all-avRllable record~ SIGNED ' ~//~ TITLE District Drilling En_9_ineer *(see Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end' log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any atta,-hments. Items 20, and 22:: If this well is completed for separate, prcctuction from more than one interval zone (multiple completior0, so state ~n item 20, and in itc'- ?2 show the p~cJ~c~.t] interval, o: intervals, top(s), bottom(s) and name (s) (if any) for only the interv~l I'et~or~ed ir~ ite~ 30. Submis a separate report (page) on this foim, adequately identified, for each additional interval to be separately produceJ, show- ing the acktitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this forrn for each interval to be separately produced. (See instruction for items 20 and 22 above). .~. c~o~oG~c M~S WAT~/~ AND MUD __ NAIVI~ MEA. S. I I I IIII I -- . . : ri I ..... .............. [ III I[ .... rill .............. - ....... i[ ; Nfl. COItE DATA. A'I'I'ACI{ II~IEF III Ilia III _ DS 6-7 PERFORATING HISTORY API 50-029-20299, ADL 28311, Permit No. 78-21 Began perf operations 12-7-78. Tstd tree, csg & wireline BOP's. Perf'd intervals 11,227-11,247', 11,204-11,214', 11,172-11,192' & 11,103-11,156' w/4 shots/ft. All perf'd depths referenced to BHCS dated 8-21-78. Ran Amerada pres bombs. Flowed well. Ran & set flapper valve. Tstd balance & control lines to 5000 psi, OK. Tstd flapper. Installed & tstd tree cap to 5000 psi, OK. Released well to Production Dept. 12-11-78. AtlanticR~hfieldCompany · North Am,~an Producing Division T~9~ho~e 907 277 5S37 December 12, 1978 Mr. Hoyle H. Hamil ton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 6-5, Permit No. 78-20 ermit No. 76-20 ermit No 78-21 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'jh Enclosures Form ! 0-403 -' Submit "1 ntentions" in Triplicate REV. 1-10~73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-J, for SUch proposals.) O~L I'~ GAS r-1 WELLI~.J WELL L..J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 20'N & 1040'W of SE cr Sec. 2, TION, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 64' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20299 6. LEASE DESIGNATION AND SERIAL NO. ADL 28311 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 6-7 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi eld-Prudhoe 0il Pool 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec l, T1ON, R14E, UM 12. PERMIT NO. 78-21 )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ FRACTURE TREATMENT ~ SNOOTING OR ACIDIZING L_.a (Other) Complete &Perto REPAIRING WELL ALTERING CASING ABANDONMENT* rate (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent ¢let&lls, and give pertinent dates, including estimated date of starting any proposed work. 11/28/78 - Displaced well with CaCl2. Ran gauge completion assembly w/shear sub @ 10,550', pkr @ Ran CCL/dummy gun. Tested tubing. Released rig ring and junk basket Ran 5-1/2" 10,425'. Displaced ~ubing with diesel. on 12/2/78. SIGNED District Drilling Engineer 12/12/78 T IT LE DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.. TITLE DATE See Instructions On Reverse Side Hoyle H. Hamilton~~ Director Chief Petroleum Engineer" Petroleum In~ E~mm%ber 5th, 1978 B.O.P.E. Test on Arco' s W.O. 6-7 ,~.~_24 - I departed my hcme at 6:30 AM for a 7:00 AM and 8:00 AM departltre via Wien flt. 91 for Deadhorse, arriving via Fairbanks at 10:30 AM. I checked with Joe. Mann, Arco's NexT/1 Slope (kxlrd/nator, and it was decided I would stay at R~an Rig $34 for u~g B.O.P.E. tests c~ W.O. 6-7 and DS 7-7, and ball valve tests on four w~lls on drill site $6. %~ather: -16% F, clear ~kies, winds 10 M.P.H. frcm th~ north. ~ annulas pres~ore and tested SSV and tested SSSV cn DS 6-2, the subject of a separate report. S___a~y, N ~_ove~. ~5 - Check~=d ann~ pressure, and tested ~SV's ~ud SSSV~S ~ Wells 6-1, 6-3, and 6-4, the subject of a separate. ~~o~ 26 - Standing by c~ DS 7-7. ~~~,<~~ 27 - B.O.P.E. Tests c~pleted c~ DS 7-7, the subject of a sepera~ report. I arrived at drill site 96 during the afternoc~ for ~g tests c~ %~rkover of Well 6-7. Arco's drilling forenan was Jerry Carpen~ ter and toolpusher cn Nabors Rig %l-ES was Ray Wadley~ Failure of a hydrau- lically operated overhead hoist had delayed tests. Tests began at 8:45 PM. 13 3/8" surface pipe is set at 2732'. An- nular prev~~ ~ to 3000 psig. Lc~r pipe rams and HCR valve in the choke line tested to 5000 psig. Upper pipe rams and inside valve c~ t=he ~ line ~ to 5000 psig. At this point in ~ slope. It was decided to nipple down and utilize the lower spool as the mud cross tests ware suspended at lO :00 PM. Tuesday, November 28 - Tests re~ at 8:30 AM with ten valves '~nd t~enty flanges ~ the choke manifold testing to 5000 psig. The manual adjustable choke was free nxmrlng and the Camerc~ remote cc~- trolled choke actuated ~ open and closed. The check valve and both wing valves ~ the kill line tested to 5000 psig. Both dart and ball type floor valves w~re in place before the dr~morks. Aocumulator pressure was 3100 psig. with the accumulator pumps off~ ~umnular prevent, one set of pipe rams, and HCR v-alve were closed simul~usly. Accum~ulator pressure drc~0ed to 1800 psig. and re~mained. steady. The accumulator pumps ~_re then turned cn and pressure built back to 3100 psig in one minute, ~nty secc~ds. Each of the. tt~ee N2 bottles tested 2000 psig. -2- One sid~ of upper pipe ~ would not retract and it was found the shaft in the pre~nter had parted and no replac~nt was available ~ the slope. Also, tP~ drille~ ~tly closed the blind rsm~ on the test joint~ and tr~ rams ~ not test. Jerry Carpen~ deci~, s4nce the ~ter ~haft ~uld have to be flc~n in fron the lower '48, he ~ould haw tb~ w~shed out spool w~lded and change the s~ back to the original configurati~. Since no ETA all pert~t tes~ be made after ~s and our office be notified. i departed D~adhorse via Wien Flt.#l at 1:50 ~,~. arriving in Anchorag~e at 3:30 PM and at ~f ~ at 4:00 PM. bl~ rams w~re repaired and tested to 5000 pslg before ~ork~_r operations began. Rig is now stacked. In s~mm~y, I witnessed ~ssful B.O.P.E. t~sts c~ W.O. 67. )rlg. Permit No. )perator j~_ _~ _~ ;atisfactory Type Inspection Yes No Item (,-)~Location,General Al~a Oil and Gas Conservation Comm~!~'uee Field Inspection Report dcE,q~')~ Wel 1/flE~=t=f~ Sec ! T/o~-/ R//~(/_=-,./d M Represented by~/2_ _~L~x~-~-dName & Number ~/, 0., ~-~ Satisfactory Type Inspection Yes No Item (~BOPE Tests (~ () () () () () () () 1. Well Sign 2. General Housekeeping t. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data (~t' (') (~- ( ) (-)~ ( ) (~() .15./_~t~Cas i nq set 16. ~'L fluid-( )wtr.-----~ )mUd (*~)~'oil 17. Master Hyd. Control Sys.-~/o~psiQ 18. ~'!2 btls.~oo,.~,,~__psig 19. Remote Controls 20. Drilling spool- ~ "outlets 21. Kill Line-(~-)~Check valve 22. Choke Flowline (*~7'HCR valve () () () () () () () () () () () () () () () () 7. Well Nos.~, 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls~~, , , ( ) Final Abandonment 11. P&A Marker 1Z:. Water well-( )capped( )plugged 13. Clean-up 14. Pad leveled (~" ( ) 23. Choke Manifold No. valvs~_/~o_fl..Qs,~O (~t- ( ) 24. Chokes-(,~)q~emote( )Pos.(~Adj (~-)- ( ) 25. Test Plu~-(~ellhd( )csg( )none (~/- ( ) 26. Annular Preventer~,_ooopsiQ ( ) (1,~- 27. Blind Rams, psiq (~)~ ( ) 28. Pipe Rams.~_~opsiq. C-t) 29. Kelly & Kelly-cocko-ooopsig 30. Lower Kelly valve ~ooopsio 31. Safety Floor val ve~L~';;;~)-BV (*-~Dart Total inspection observation time__~Z hrs/c~m~ Total number leaks and/or eQuip, failures Remarks~/7 ..__r~_. . .... cc'..~-'_,/~/~,~;~.~-~~ ~_Notify in _____days or when read.y~ Inspected by~_~_i,~.~-~_])ate_//-~?-_7__~ North American Producing Division NorU~ Alask',~*%trict Post Office b_., 3S0 Anchorage, Alaska 99510 Telephone 907 277 5537 November 16, 1978 Reference: .Enclosed are the following cased hole logs: Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #570 November 16, 1978 Reference: Enclosed are the following open hole logs: CNFD 5" DIL 5~' BHCS 5" FDC 5" 8/21/78 ~.10/5/7s DIL DIL BHCS BHCS FDC CNFD Please sign and return Sincerely, V.G. Reimers North Engineering TRANSMITTAL f/569 2" 2,~ 5:! 5~, 5~ the copy as rece±pt of data. Norlh Alaska Dis~.r:ct Posi Oflice Anchora§e, A,.,ska 99510 -r~,_.,,~ ..... 907 277 5837 November 15, 1978 Reference: Enclosed are the following Directional Surveys: D.S. #6~8 ..... 10/27/78 SingleshOt .~';~~~'. 7/31/78 Singleshot Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #562 At~anticRichfieidCompany ~ North Ame~an Producing Division Alaska Re 1 Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 20, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subkect· ermi t No. ~IIS'~--~,~ Permit No DS 7-3, Permit No. 78-21 78-10 78-11 Dear Sir: Enclosed please find a Sundry Notice outlining our plans for each of the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB: j h Enclosures Form 10,-403 ~-~ Subml t *°1 ntentlons" In Triplicate REV, 1-10-73 ' & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMll'TEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--~' for such proposals.) 1. OIL ~ GAS F~ · WELLI~--i WELL OTHER 2. NAME' OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 20'N & 1040'W of SE cr Sec. 2, TiON, R14E, UM 13. ELEVATION5 (Sl~ow whether DF, RT, GR, etc.) 64' RKB Check Appropriate Box To' Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20299 6. LEASE DESIGNATION AND SERIAL NO. ADL 28311 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAM'E Prudhoe Bay Unit 9. WELL NO. DS 6-7 '10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Prudhoe Oil Pool 11. SEC.,T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 1, TION, R14E, UM 12. PERMIT NO. . 78-21 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L-~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (or.er) Complete & Perforate SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEs Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. ' DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent detall~, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to install' a 5-1/2" production tubing string in this well. A 13-5/8" 5000 psi BOP stack consisting of one annular, two pipe rams and one blind ram will be used. The BOP equipment will be Pressure tested on installation, once each week thereafter, and operationally tested on each trip. A string of 5-1/2" 17# L-80 tubing with packer and necessary provisions, for subsurface safety equipment will be run. The packer will be set above the SadlerOchit. Non-freezing liquid will be left in all uncemented annuli within the permafrost interVal. Selected intervals within the Sadlerochit will be perforated and reported on'a subsequent report~' A'5000 psi WP wireline BOP and lubricator, tested to working presSure,'will be utilized with all wireline work. The well Will. be flowed to the production facilities'during perforating and testing. The downhole safety valve will be installed and tested upon conClusion of the job. Estimated start 11/7/78. ]6. I hereby certify that the foregoing is true and correct SIGNED · _~. ~~ TiTLEDistrict Drilling Engineer DATE (This space for State offiCe use) APPROVEDBY ~Li, CONDITIONS OF APPROVAL, IF ANY'~ PETROLEUM ENGINEER See Instructions On Reverse Side 09/26/7~ DATE AtlanficRichfieldCompany North American Producing Division Alaska Reg Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 15, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 6-7, Permit No. 78-21 Dear Sir: Enclosed please find a Completion Report along with the Drilling History and Gyroscopic Survey for the above-mentioned well. Very truly yours, F. M. Brown District Drilling Engineer FMB :ml n Attachments F'(~rm P- 7 '. SUBMIT IN DU.. STATE OF ALASKA st ructions on reverse side; OIL AND GAS CONSERVATION COMMITTEE i ii i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* WE LL W ELL DR ¥ Other b. TYPE OF COMPLETION: XEW E~]OvERWOnK ~ Drsr- ~]~x m, CKPLm; [-'l .rr~.ngsvR. E~ OtherSuspended WELL 2. NAME OF OPERATOR ATLANTIC RICHFIELD COMPANY 3. ADDRESS OF OPERATOR P.O. Box 360~ Anchora.qe~ AK 99510 ~. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 20' N & 1040' W of SE cr Sec 2, TION, R14E, UM At top prod. interval reported below 719lAt totalN §epl~156I W of SE cr Sec 1 , TION, R14E, UM 684' N & 674' W of SE cr Sec 1, TION, R14E, UM 13. DATER SPUDDED [14. DATE' T.D. RF-,AC~D 115~ DATE COMP ~USP O~ ABAND. 8/2/78 [ 8/22/78·[ 8/26/78 II]OW 1VI.AN'Y* ROTARY TOOLS 11~610' MD 9338']FVD l1547'MD,9286'T~D Single 1 22. PRODUCING INTERvAL(S), OF THIS COMPLETIO~T~TOP, BOTTOM, NAME (MD AND TVD)' Top Sadlerochit· 10,761' MD 8640' TVD Llase Sadlerochit 11,433' MD 9191' TVD 5. AP1 NU1ViEI~ICAL CODE 50-029-20299 6. LEASE DESIGNATION AXqD SERI-A.L NO. ADL 28311 7. IF INDia_N, AJ~LOTTEE OR TRIBE NAME 8. UNIT,FAlliVi OR LEASE NAME Prudhoe Bay Unit '9. WELL NO. 10 FI?2 {~715r~OL · " , [: I T Prudhoe Bay F~{ eVi ~-?~udhoe n~ ] Pool 11. SEC,, T,, R., M., (BOTTOM HO~.,~ ' OBJECTIVE) Sec l, T1 ON, R14E, UM 12. PEP.WIlT NO. 78-21 16. EILEVATIONS. [DF, RKB. RT. GR, %'rC)* 17. EL,EV. CASINGHEAD · 64'), RKB , DRILLED BY INTERVAI,S [ (,',~:L E TOOLS Ali ! 2:;. WAS DIRECTIONAL ; SUH. VEY MADE ! Yes 24. TIrPE ELECTRIC AND OTHER LOGS RUN DIL/SP, BHCS/GR, FDC/SNL/CAL/GR, GR/CNL/CCL _ _ i , 25, CASING RECORD (Report all strings set in we'{l) C~SIzNG SIZE WEIGI-IT, LB/FT,~, GRanDE [ DEPTH SET (1VLD) 20" 95.5 We]de~ H-40 ] ]]7' 13-3/8" 72# Butt ! N-80 [ 2732' 9-5/8" 47# Butt IN-80 &[ 11,588.' /so0-951 , ,,,, 26. LINER RJEC Ot:LD 28. PERFORATIONS OPEa'q TO PRODUCTION (Interval, size and number) HOLE SIZE [ CEAILNTING RECOIUD ll AMOUNT PULLED 30" [ 270 sx Arcticset cmt. 17-1/2"[5400 sx Permafrost II cm. , 12-,1/4"[1300 sx Class G cmt. 27. TUBLNG RECOF~D SCP~EEN (MD) I SIZE_ [ I ' i DEPTt{ SET i( fi'} j PACI~'ER SET (MD) 29. ACID, Si!OT, Fi%AC~ CTRE, C~.'VIENT sQUeeze, ETC, DI~/~Ii iNT]SRVA_L (MD) ! AM©UNF £dND KiND OF MAI'E~I/AL USED N/A · , ,. , ; i i ' i i i ~ i1' iii ii i · PRODUCTION I:~ODUCTION MEII-IOi:) (Flowh~g, gas lift, pumpilag--size and type of pump) [WELL S'FATUS (Producing or [ 5~lat-Jn) OIL-~BBL. G,~MCF. WA'I'E~BBL. ] GAS-OIL ~XTIO i I I a2. ~,s~ oi~' AT~kCr~rNTS Drillin,g History, GyrOscopic Survey 33. I hereby certify tha~g and attached information is complete and correct as determined from all-available records SIGNE ~iT~,~District F)rlg. Engineer__ DATE ~9_-_LS-7a *(see Instructions and Spaces for AdditiOnal Data on Reverse Side) · DATE OF T~ST, FLOW', TUBING 31. DISPOSITION OF N/A HOURS TESTED ICI-tOKE SIZE [PROD'N FOI~ 2A~ I/~I G pR-ES SUi:LE [ CALCU-L~kq/ED tTESq: PEH't~? I' ,as (Sold, U,ed,orii:;~eT~c.,[OIL--BBL' DATE FIRST Pi~ODUCTION N/A GAS--Id[CF. WA~BBL. [ OIL GRAVITY-AP1 (COl:~.) I TEST WITNESSI~D BY INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion, report end log on all types of lanJs and leases in Alaska. item: 16: Indicate which elevation is used as reference (where riot otherwise showr~) for depth measure- merits given in c, ther spaces on this forr'~ ~3ncJ Items 20, i~nd 22:: If this well is completed for separate: prc:d~zctior~ frorr~ r','~ofe th~3r'~ or'~e ~terval zone (multiple completior0, so state tn item 20. arid ir~ ~te'~; 27 show the: prc;]~(.'~:Cl intcrv~l, or ~l~te~v~'~ls, top(s), bottom(s) and name (s) (if any) for only the interval! re~orted ir~ ~ter, 30 ,~u[-~cr~it a sept]rate report (page) on this form, adequately identified, for each additior~al ir~te~val (~ be seperately produce:i, show- ing the additional data pertinent to such interval. Item26: "Sacks Cer'nent": Attached supplemental records for this well sl-,oulJ show the details of any mul- tiple stage cemer~tir~g and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each ~r~terval to be separately produced. (See instruction for items 20 and 22 above), , ,, , ........ 34. SUMM~I(y 'OF' b'ORMATION TE2S'I'~ IN('L, UI)IN(; INq'EIiV~L T~q'rED. i'HE~SURE DATA ~COVERI~ OF OIL GAS. 35. G~GIC MARK~ WAT~ AND MUD ,,, 36 ('OI1E DATA, A'I'I'A('II I]RIEF D~qC~I~'ONS O~ LITIIOLOGY. PORO~ITF. FRAC~RF~, APP~NT ~- ' AND I)gl'ECtTEi) Mt'I()WS OF' t)lt.. GAS Olk WAT~I. ,,, , ........ DRILLING HISTORY DS 6-7 API 50-029-20299, ADL 28311, Permit No. 78-21 Spudded well @ 0200 hrs 8/2/78. Drld 17-1/2" hole to 2755'. RU & ran 13 3/8" csg w/shoe @ 2732'. ,Cmtd w/5400 sx Permafrost ~I cmt. Drld cmt shoe & 10 new hole & tstd. Drld 12-1/4" hole to 11,565'. Ran DIL/SP, BHCS/GR, FDC/CNL/CAL/GR logs. Drld to 11,610'. RU & ran 9-5/8" csg set @ 11,588' Cmtd w/1300 sx Class G cmt. Opened bottom FO & pumpe~ 300 sx Arcticset II cmt. Closed lower FO. Did Arctic Pack job thru upper FO. Displ mud w/wtr & wtr w/lO.4 CaC12 wtr. NU & tstd tree OK. Ran GR/CNL/CCL log. sUspended well & released rig @ 1~00 hrs 8-26-78. TLA NT I C ,S. 6-7 RICHFIELD COMPA RUDHOE BAY L. ASKA SEP 1 I 1~78 ,' A,~L 11: '.,. ~PERRY-SUN HELL ::. .,,, ANCHORAGEs: AL oKA '~ . ': suRVEY:AUGusT 2~,, 3.778 ' COMp UTA-T'i"O~ ........ D-~"l [ '8-O'$~-~YR'OS-CO-P-I-C ..... SURVEY : ....... JOB NUNBER 8[8S 16300 KELLY BUSHING ELEV, = 54,c~[I F'T, EASURED iEPTH VERTICAL VERTICAL INCLINATION DIRECTION DEPTH DEPTH. DEG MIN DEGREES 'S-E: ~ E-R-i: ~T '¥- -'TCE-CTA-~G-U[-A- R-- CO'O R-~ 'I' 1CATE,. -~ ............ V 'E R T'~ £. '; ;~ [' DE61100 NORTH/SOUTH EAST/~EST SE el' I'O ;" ) 10 , 20 ~00 q. O0 500 299,99 235,99 0 11 N 399,99 335,99 /+99.98 Zt35,98 60O 700 8O0 0 21 S 55, 0 W ,25 2.32 S 0 16 S 64.80 E .54 2.60 S 0 201. $ 6,90 W :, :i:::: A.,65 $ gOO 1000 1100 1.200 1300 1~00. i-5'-0-0 ..... 899.97 999.96 1099,95 1 i299':~ 1.~99,9~ 935.96 '0 qq. $ /t3,10 1035,95 0 Z~9. S 19.50 .25 6.36 S .B1 7.50 S 1G 17 ~k8 19 2O O0 1.599,92 1535,92 0 qO S 24,20 E O0 1699,92 1635,92 0 ,.'36 S 4,/+0 W O0 O0 O0 1799 · cj 1 { 1899 ~' z~8:':: S 61.'1: E..~i! · s ~ 1-3 o:. E :' 2100 2099.89 2035,89 0 10 -~ 29,60--~ D9 E .0 2 . O-'6-'lT - . '2'! .35 ~,~ ,39 ~ -.7] ,~b i.i','i2 'S ,31 11'~'' · 32 12.96 S !'03 1-;'62: E 2.07 2.27 ;...;::" 2 '.95 1.01 '$¥-~ ,: 2200 2199.89 2135,89 0 25 2300 2299,89 2235.89 0 15 2~00 2500 2600 27O 259,~.85" o ',+~ 1,80 E ,29 16,Z~2 S 3,57 35.70 W ,27 1.6.96 S 3,45 3.~'~o E-.:""::':"': .5~.::',/-~:¥;:.~!:::i::.:'~:1~.~ $ ':~'~ ' ~.os 3. G o ~ . ~"~ '2~-os 7. ~-E 6.5 o~ · ~C~ 2~-;-2~--S: . .::,. ~~~ . . ... ,:.... :... 280 2~0 300 2699,8zt 2635,6Zt 0 57 2799,81 2735.81 1 55 2899.4:3 2835,43 : 7 30 2997,78 ::..:.,:.: ~:..::::~::.:: 2 933.78 ~'!:t:?' "' .' 13 7 1.55 3,5~ 14.,~~, 3-2 .' 7% SPERRY-SUN NELL SURVEYING COYiP~Y ANCHORAGE~ ALASKA 'L~b~TIC RICHFIELD CQ~,~PANY DATE OF SURVEY AUGUST UOHOE BAY AUGUST 28~ 1978 dOB NUMBER BOSS 16300 .ASKA KELLY BUSHING ELEV. TRUg__ SUB COURSE COURSE DOG-LEG TOTAL,. 'ASURED VERTICAL TF-'TH OEPTH VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEPTii DEG MIN DEGREES OEG/lrJ~J NORTH/SOUTH EAST/WEST 6~,00 FT, VEPTIC&L, SE. CT 3100 5 O 9 q- · 51 }200 $1.9o.28 &~O0 ~285o65 5221' 7 17 1 55 N'71. N .6~'.50"E N. 67. O. E ,~qO0 ~80.12 5516.12 20 19 N 69.20 E 2,5q. ~500 :S~.7:~.~ 3qOg..'J-6 2i q.~ N 7Z.ZO E Z.57 3BO0 5565,~8 5501..~8 2q 19 N 75.20 E 2.71 ~80~ 57~5.50 5679.~0 29 ~9 N 76, 0 E 2.55 5900 3828.B1 576~.B1 ~2 ~8 N 7B.lO E 3,02 A2DO .q~O0 4500 47 48 ~911.85 ~8~ 7.85 :',5 ............... '~' ................. N .... 7iF;'gfi-F:' ............... 5991,6~ ~927,64 59 5 N 79,50 E q,O7 q067.26 ~005.26 ~2 5a N 80.30 E 5.59 q i-~¢" G'~':'::'." '~",~7~%-~., ,.'. -4-4 ...... 3'7~ ....... NT"79-VS~O-K :.7-J~"6. .. ..' ~.280.27 :.'; "':':~':'" ".q5 55 N 79 sO.E . .:/..:3.' : O0 ~18.25 ~55~.25 ~6 ~7 N 79.90 E O0 q~85.93 q421.9S q8 2 N 79.80 E 1.25 67.32 N 505.85 F 7R,90 N 35q.37 'g-g;~-8-1~ .................... q-O ~"g'9'2 .... F ........... 4.16." I 1.01,26 N q68.10 E 112,71 N 552,50 E '. .... 670.01 E 681..92: N':'' ':'748'1. G E 753 177.23 N 882.55 E r:97.67 190,20 N 955.01 E 97'1.2~I 5000 qB 5100 qG 52 55 55 56 57 59 60 61 O0 O0 O0 O0 O0 O0 OO O0 O0 O0 q7 q8 ~9 50 50 50,61 q686.~I1 50 0 l~,2q q750,2q 50 77,05 ~813,03 51 ~875.6~:::::::.;.: 50 55 39.6~ 51 51 52 65.65' 5001,65/:'''' .51 ' 26 53 N 81.20 E ,8h 2~-9'~'-'2FO'~"lq-- N 82.10 E .96 250.~-8 N N 82. O E ,89 261.2~ N N 82. 0 E :'G-5:.:':'::' .... '-27'~-~-i'0::N .... .3 ~, · 82 31q,85 N · 23 52q,q9 N 27,87 5063,87 51 ~7 90,q9 5126,~9 50 50 53,66 5189,66 50 q9 N. 81,70 E N'82, 0 E N ~-2-g--4-d r_ N A2,70 E N 83, 0 E 1101,67 E 1175',-75 E -~~---F_ 1527,15 E 14.04,23 E 155~o17 E. 1635,18 E 1790.05 E 1866,97 E ., 1119,89 llgq.gq: '1"'2"7l'F-;-9-= lq25.77 --1-5"0~ .--73~ 15~1.22 1659,01 17~2~ ....... 1815.2:: 1-970-J'g: ........ ATLANTIC D,S, 6-7 PRUDttOE ALASKA RICHFIELD BAY C 0 M P A N Y SPERRY-SUN NELL SU"RV-~."?'iNG COMPANY ANCHORAGE~ ALASKA ' AUGUST ..................................... DA'GE ..... 3 ..... DAlE OF .~URVEY AUGLISI 28; lC7~3 --'B-O~.~'S--GYK 0 S C O-PI-C',S UR V EY ........ dOB NUMBER BCSS 16300 KELLY BUSHING ELE¥. = F:4.i~e ~T, MEAS DEPT URED H TRUE SUB-SEA COURSE VERTICAL DEPTI4 VERTICAL INCLINATION DEPTH DEG MIN COURSE -'-D-iR-~'CT I ON DEGREES DOG-.LEG "TOTAL S EVE R I T'Y--~¥L~C-T-A-i~GUL-A-R ...... CO-OR'DTNt-T F. ,S ........... V '-E D T I C A I_ []E.G/1. O 0 NORTH/SOUTH EAST/WESI' S F C T I.:} P..' 6200 G3OO 6400 5378,6~ 5314,6q 5440,54 5376'56 5503,69 ' 5q39o69 6500 6600 6700 5568.83 550q,8~ 5635.28 5571.28 5701,98 5637,98 6800 6~00 5769.05 5705.65 58:36.28 5772.28 52--11 N 84.10 E 51 19 E 50 22 E 48 2 o 'E 48 23 E 47 57 N 79.~0 E 47 q~ N 79.60 E .17 N 83.50 N 81.10 N 78.60 N 79.50 .~-l'5';'~"?'""N ................. 2.'~F7 I";-2'3-" ':.IT/- ............ 2 .) t73. ~.,'7 429,16 N 2544,03 E 2.r:.;77-57 7000 7100 7200 7300 7500 7600 5903,58 5971.1.7 6038,93 6~07.25 62~'~5 6313.38' 5839,58 4-7 ql N 79, 0 E ,45 S'g'fi"?-,-f'?- ......... -4-7 ....... 1-6 ............. N--7-g'TgO ...... E ...................... 5974,93 47 25 N 79,70 E .17 60q3.25 ZIG 24 N 80.1. L1 E 1.06 5' .......... N-T'79;'7'O--E q6. --'. 3~' N .: 79..20 E ¢+6':21 N 78,80 E ' '7'TO-O ...... (_-,-3~'-2'-~ 6 6, 3.1. 8' '5 6" 7800 6~51.71 6387.71 7900 6520.89 6456,89 8000 6590,9t 8100 6661"81 8200 6733'2 8300 6805.66 67ql ,,66 8400 6878.58 681z~-58 4 6 ~6 24' N 7'9.~0 E 46 q N 79.20 E N .79,.90 E. ~3 1.9 N 79.10 q. 3 3 N 79.80 E 8500 8600 8700 8800 8900 6952.29 6888,29 7026,79i..:i!.: 88 7z 77.so 7254,20 7190,20 zi, 1.58 N 80.i0 E ~1 '~-~ .....N 80.30 E . 81 ° 0 . 40 7 N- 81.4-0 E 9000 9100 9200 q42,89 N 2616.70 '4"5'~,';' 57--N ................ 2.6'gg-g'I."2 ..... 469,79 N 2761.46 q82.59 N ,<,~ 33.35 E -~'9~'~'[T" ~29'0"~;~5'-"'~ ................... 2 9 q 3'; ~ t'-: ........ ?':'i:':N' 2.9.76,51 6-3 .........5~6. O 3'"N ..... ~ TI-iT~ ,33 5~9.19 N 3189.57 ,36 562,.60 N 3260,53 ,,.89 .55 624..56 N 1.I0 636.35 N 3016.57 E 3088.85 t: E 3233.0! K 33. 05 ,,0 9 N 81.50 E ,92 689.40 N N 82.70 E 1.08. 698,48 N 29 E 3604,26 E 3670,7.o, E 5,76 3993,8~ 4-059,3~ ~TLAHTIC RICHFIELD CO)~,PANY' 0. So 8-7 PRUOHOE BAY ALASKA SPERRY-SUN k~ELL SURVE'YING CONPANY · ANCHORAGE~ 'ALASKA COMPUTATION DATE AUGUST 28, 1978 DATE OF SURVEY AUC;UST B 0 S S G¥'R-O-S-Cb-P'i-C----gURV FlY dOP NUMBER BOSS 16300 KELLY BUSHING ELEV. T MEASURED VER DEPTH DE RUE TICAL PTH SUB-SEA COURSE COURSE DOG-LEG TOTAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES DEPTH DEG I'4IN DEGREES DEG/'iOD NORTH/SOUTH EAST/WEST '<T' ,.. ,~ L VEk . I'd:'` ......... SE r'T i O !,.~ 9300 75 9,~oo 7~ 9500 76 52., 37 7~88,37 q3 21. 2q,67': 7560o67!:: ~'~' 2 96.05 7632, ~zt 53 9600 77 9700 78 ~800 79 66.2/+ 7702.2q ~5 57 36.38 7772.38 qq 58 07.66 78q3oG6 qq 6 N 83.60 E N 84,30 E N 8~+,50 E N 85,20 N 85.6[~ E N 87, 0 E 9~00 0000 0100 10200 10300 lO400 80 52 N 89.20 E 1,20 81 18 N 89,~0 E ,57 8279.89 8215.89 ~0 26 S 89.60 E 8356.15 8292.1 5 ~ 0 1 1 S 1~8.80 E .57 5~.23 7990,23 29,03 8065,03 :10500 8433.11' ..lOGO0 851 ~!:-'.10700' 859 10800 10900 ilO00 85., 76 E 86,30 E 8671.78 8'607'.78 ...... 36 lO ~ 85..8~ E' 8752.6q 86,S8.6~ 35 55 S 85,,,.90 E .26 8833.80 8769.80 35 3q- S 85,70 E ..37 1100 1.1200 11300 8915.55 8997.8~ 9080'68 111~ 115 116 00-- 9163,70 909~,70 3~ 9 S 85,60 E ,5~'/' O0 92~6,70 91.82,70 3:5 39 S 2;5,70. E ,50 10 9338.27 927q,.27 33 39- S 85.70 E I 7~9.97 N q680,06 E .7'50,8q- N ~i7q. 6,~2 E 750,78 N q877,71 E q~:~.l 74.9.88 N q9~2..39 E' q9'37.2 ,.50 6B,17 E 5121.q6 523'9~ .... 7~3.~ N 52~6.2F, E 5296.71 729.17 N 530~.53 E 5353 7 65 N 708,q2 N 5585,69 E 705,85 N 56q6,~8. E 5~66.21 5521,12 5650.45 5690 THE, HOR IZONTAL.;~[ EE CALCULATION PROCEDURES ARE BASED ON THE USE OF ATLANTIC RICHFIELD COIiPANY 6-7 :'R UDHOF BAY ~[.ASKA ANCHORAGEs ALASKA AUGUST 28~ 1978 COMPA~,:Y' DATE OF SURVEY AUGUST 26, 197P JOB NUMBER ~.OSS 1630J KELLY BUSHING ELEV, = ~.4.,~0 FT, INTERPoLATED'VALUES FOR EVEN 1000 FEET OF ~,E'AS'URED DEPTH TRUE ~!~A~URED VERTICAL DEPTH DEPTH t o o SUB-SEA TOTAL VERTICAL R£CTANGULAR COORDINATES MD-I'VD VERTICAL D EP T H : .. ~'O-~'T~7"~-O O'T'H ......... E-A-$'T'/~ E"S-T":~.-i-FF-E 'RE ~C}_"-~C-OR'R E'C'TIO-N lO00 999,96 955,96 2000 1999.89 1935.89 3000 2997.78 2933.78 ~000 5911,85 ~8~7,85 5000 ~.619,~9 ~.555,e. 9 6000 5255,66 5189,66" ~000 6590 ,~0 6526,90 9000 7330,,15 7266,15 215,73 N iI~l.G? £: ,. 3B0.51 292,36 32~,~9 N 1B66,~7 E ' ,'I~6,3~ 365,85 A~"2"~"'~9 .... i~ .......... 2"6'ii'6,'7"0-"E ....... T'Og..L~-. ~"~ 35-9"~'0'8 ............................................ 575.25 .N 3330.79 E lq09.10 312 689.~+0 N 3993,8~+ E 16~,9.85 260.75 27'5¥9~ ....................................................... 72.9,I7 .. 220 .~ ' :703,~5 · 105.53 lOOO 8833.80:: 1610 9338,27 THE CALCULATION PROCEDURES ARE BASED ON THE: USE OF THREE DIMENSIGNAL RADIUS OF CURVATURE METHOD. SPERR¥'-SUN 'JELL ~'ORvEYIN6 ~TLANTIC RICHFIELD COtq?ANY ANCHORAGE 9 · ALASKA ).S. 6-7 )RUDHOE BAY aLASKA CON, PUTATION DATE AUGUST 28~ 1978 DATE OF SURVEY AUGUST dOB NUI, tRER BOSS ]6500 KELLY E1USHIN$ ELEV. '-' £q.~]O .r':T. .... INTEI~POLA T. ED, V..A].U_E S... ~.O_R_£~E_N TRUE SUB-SEA ~EAStlRED VERTICAL VERTICAL DEPTH DEPTH :< 100 FEET OF SUB-SFA DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VFRTICaL D E P T H .. N 0 R'i~¥7's-60'Tii ..... '-£'A"S-TT'gFST'-lYl]FFEI~-EI~~, 'OIFRETCTI ON 0 0.0 6~ 64.00 0.00 164 164~.00 100,00 2&4 264.00 200.00 36~ 36~o00 56~ 56~,00 664 66zt .00 600 76z~ 764.00 700.00 B64 864.00 800 o00 964 964.00 1064 106~,00 116A 1164.,00! 1264 1264.00 1200.00 136~ 1364.00 1300.00 .O"O .01 .Ol ,00 4.q~ S .37 ~ .03 .00 5.07 S 1464 1464.00 1400.00 10.93 S I.~7 E .07 .01 - - .... ~ · '~'. · - · -. · -. · - .....-. -..- . -. '--~-~ .... --'---%:,.~- ~-~' .-~?'--'-.'~~-~ ,~,-~r~.....::.... ..... _ ..... .. . . .,.. ...... . . .. · - .... · ..... , .. ........ -~ · 15 G ~ 15 6~-. O 0 ~.:.::.;':;"::?~":1'.50..0 ,..:D .O..;~.~:::.~:"~?.: ~.:'~." .. 11' 53' S' '.:...': ..:..~'.::..; ":'..": 90,'.~.::.E:~.~.'~:~'~'~:::~';:::..'::....'~:.:.'; :...:. "'~:::" ...: ~: .. ~ ~ ~ · o o.:::~.~:~ ~:~ ~:.i:.~ :0'0:-.~0:~::?~:~'~.::? ..: ~:.~:.~' ,.::: .'.: :.?.:-.. :', o~'~:~:'~::~..:~. ~: ATL.~ NTIC RICHFIELD [~oS. 6-7 PF:U~HOE ALASKA COHRANY SPERRY-SUN VtELL SURVEYING COMPANY ANCHORAGE~ ALASKA /~UEUST 2L~,,~ i978, . DATE OF SURVEY AUGUST dO~ NUMBER ~eSS 1630~, KELLY BUSHING ELEV. INTERPOLATED VALUES FOR EVEN 100' FEET OF SUB-SEA DEPTH TRU F..[ASURED VERTI DEPTH DEPT 186~ 186~, E SUB-SEA T CAL VERTICAL RECTANGULA H :: .DEPTH.:."::::: O0 1 800"00.::' 15,20 196~ 196Q,00 1900,00 15,79 206~ 206~,00 2000,00 15o8~ 216~ 216~,00 2100,00 16,16 226Q,~ '-~264, O0 2200,00 1"6-'~"'8"4: ..... OTAL R COORDINATES F~D-TVD VERTICAL · ..:. .: :: · . s: ' 2.5~ · ::.:: . :.:::::': ::' .o: S 3,58 E ,'i-1 .'0--1 ...................................................... S 3.68 E ,11 .00 g 3.56 E ,11 ,00 2564 236q,00 2500,00 17,27 S 5,q-O E 2~t6q 2q6zt,O0 2~00o00 ]~8,25 S 4,09 E .............................................256~ 256~-~' ......................... O0 2.500 ~ ............................... O0 i"9"~"q"4" 'S' ................................ 5 ;7 9 ..... E 266~t 2664,00 2600,00 20,53 S 6,72 E 2764 2764,00 2700,00 21,26 S 8.~6 E 2864 2965 296~,00 5068 ~064,00 3277 ~382 3489 3598' '21'6'7'S · "18,50 S SP F_"RRY -SUN WELL ATLANTIC RICHFIELD COMPANY D,S, 6-7 ANCHORAGEs. ALASKA C 0 iq-FTOTA-T"~.-6'I~-- O A T E FF:UDHOE [lAY ALASKA AUG[JST 28, 1978 BATE OF SIIRVEY AUGUST ,JOR NUMBER FLOSS 16700 KELLY' BUSHING ELF. V, - 6q. ~2 FT, IN. TERPOLATSD V.ALU_U_~S FOR E.~ZEN 100 FEET_OF stlB-SEA .DEPTH MEASURED , T' DEP . l', 3823 39 qO 41 ql 64 95 TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDIN DEPTH :' . ?DEPTH. NORTH/SOUTH EAST/ 76 20 q7 q9 5O 67 16 66 5221 5379 5558 5658 6016 617 6537 70' 17 N 315, 386~i,00 5800,00 83,54 N 376,~7 E 3964.D0 .'5900,00 97,2q N 4z;,6,63 E ~O6q,O0 qO00,O0 112.21 N 529,5g E. ~16~.00 ~100,00 129.20 ' 'N ................ -6-2'~-' 05 E A264,00 ~200,00 1~8,02 N 723,86 E ~6~.00 ~00,00 167,02 N 825,87 E q56q.O0 4500.00 205,26 N 1D~0,68 E 466~.00 q600.O0 223.95 N 1151,.0~, E .~7 N 1511.,1'5. £ · -R'~3-7-~'2N 51OO,O0 310,71 N 1757.77 E 5200,00 326,0~ N 1879.56 5 ~'86~,00 516q~o00 526~,00 <21r2 9- 23 ATES MD-TVD VSRTICAL W ES T .. ~Yi"]~ F ER[:..N CE ... 55 E 59'95 ''' lq.,38 T7; '62 177~-7: iOD.76 22.95 131.59 i' ?"0-"72"2 .................... 3'~";~-3 ............................................................ 212.76 256,88 ~]Y3721 352.88 405.00 4q',ll 'q-6'¥3'3 ............................ ~;9 ..67 5D.I2 5-4-TI'~.' ................................................................... 57"9 ~' 59,59 6 9~. .7'52,:37 60 58.5 3 ATLANTIC RICHFIELD COMPANY SPERRY-SUN WELL SURVEYING ANCHORAGE ~ ALASKA .J.S, 6-7 ;r,-.UDHO E ~.LASKA ~AY COMPANY DATE dOB KELLY OF SURVEY AUGUST 2a, lg78 NUMR£R POSS 1630f BUSHING ELEV. = GA.'JO FI. INTERPOLATED VALUES FOR EVEN' 100 FEET OF' SUB- SEA' DEPTH FEASURED DEPTH &6 6792 Ggql 7089 7237 7382 7528 7673 7817 7961 --81 82A2 8."580 TRUE VERTICAL SUB-SEA TOTAL VERTICAL REC'TANGULAR COORDINATES MD-TVD VERTICAL DEPTH~ NORTH/SOUTH E,~$ TTgE. T '-T-D-.~ FF E-~-~C~, ..- COR'-R~CT'iO~] ............................................. s oO,° o' E.'" 979'23 q3~,67 N 257q.01 E 1077.20 455.17 N 2681.qR E 1125.43 qTq,GG N 27~8,.30 E ~9~,08 N 2992,~5 E. 1218,61 512,5~ N 2996,7q E 126~,~0 39q.77 N 2356,76 DEPTH 53'2";"~J'5 ..... N ................. 3'099,"57""'F._ ................... 551,57 N 3202,25 E 1353.~1 570,. 75 N 3304.22 E 1397.92 ¥8-7',-~,'3--'M'"7"T-"~"~-O'2:,;"~::'t'-'E ........... i-4~ 6.0/..t.65 N ,3698,,,26 E.-.- 8515 8781 ~912 91.79 5700.00 5800.00 5900.00 576q.00 5864.00 5964.00 N 3769.13 E 1585.79 N 385g..21 E 1617.92 5'0.53 · '~fg"z25 ......................... q8,72 "qT';'6I q5,56 q5.79 q'zi";'83 q~.59 q~,.11 ....... 34.04 32.12 606~.00 6164.00 626q,00 6000,00 6100.00 6200. O0 6364,00 6300,00 6q64.00 GqO0.OO 6564.00 6500.00 6 6964,0~ 706~,00 7000,00 653,30 716q.00 7100.00 668.03 72 6 ~+, oO ~:::::;~,~ .: ;i/7 2 O0 :..0 0.~?:~:~?~:~'~.~ :.;:?//:':¥~ 0'.~ ;:';'::::~,;~:::..'7 .-O O';,O 0 ;:.'.~.:,?:'?.::?".": 70 ~., O 6 TLA~TIC 6-7 F:UDHO£ LASKA RICiiFIELD COMPANY SPERR Y-SUN w~2-E['--SUR-V"~-Y~.~.NG ANCHORAGE, ALASKA CO?~FUTATI ON DATE BAY AUGUST 28~ 1978 C 0,',~ P ANY :, ,_,qr DATE OF SURVEY AUGUST 2G~ !q7S dOB NUMBER BOSS 1.6300 KELLY BUSHING ELEV, FT. INTERPOLATED vA.LkLF:~ FOR__E..=V_E_DL_!O0 FEEI_~D_F suB. SEA. DgPTH '.EASURED )EPTH ( ,,315 TRUE SUB- SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH ·. DEPTIt NORTH/SOUTH .. 7564.00 7500,00'' ~' ' 715'79 N 0 7600,00 725.61 N 0 7700.00 734,,87 N 0 7800.00 742o90 N 9~5~ 7664,0 9596 77'64,0 m739 7864..0 7900,00 7~7,79 N 8000.00 750,09 N MO-TVD 9877 7964..00 10013 8064-.00 lO14G 8164,00 8100,00 0279 0410 0539 06 0790 OglA 1 ] 1 :. 1 1 8264.00 8200,00 8364.00 8300,00 8464.00 8400.00 ~_,,~ T D!FFERE NC5. EAST/'Wc° VERTICAL· 41+00.78, E 1832.78 4.501.63 E 1875.04 qGSB,81 E 1949,12 1.1.037 11158 ~279 11610 751.18 N 4777.13 E 1982o5A 750.88 ....N ............. q8'"~-~:7 i-7-'~ .................... 2-F1-'5 ."'-1-2 749.7~ f~ ~949.02 E' 2046.27 747.42. N 50:31.39. E. 2075.86 722,,63 N 5395.~7 E 2194.95 717.57 N 5463.,4.~+ E 2215.97 · :..' :' .'.' ': ~'. ': '"'~ ~i:'~ "~ ' -.' :..:: ':'.:'-.:.:.;,::'" :.::':~ '~:;' .:.~':':.':-'; :".:.. :":':':,:,:' ; .?-.~."¥: ::::::::::::::::::::::: ~...~.::~?~:;%;~:~;:::~:~?.:~...:~:~:.:;:~..~..~.;.;~.;:...~.~.:.;:~.~:.;:~:~??.~;:>~:~? >. :':: N. ::..~::'..:'..".:56 ~ 6., q'.8.~;::.:.:E'..,':;.::::::....::..:.:":'-..:;..:.?:L2 2....7.I' 866q.00. 8764,,00 8864., O0 8800,00 89~4.oo 8900.00 9o64.oo 9ooo.oo 36,71 ' ~1.97 42.26 35,29 31.15 29 23". O '¥ 21.83 21.02 :'~',. THE] CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETUEEN THE NEAREST 20 FOOT MD (FROM RADIUS' OF CURVATURE) POINTS 400 8OO 12oo 1600' ~000- 2800 3600 4800 VERTICAL SECTION ATLANTIC RICHFIELD COMPANY SCALE I"= I000' DRILL SITE 6-7 RADIUS OF CURVATURE GYROSCOPIC SURVEY ~ARE TVD 5200 681 7200 HORIZONTAL VIEW ATLANTIC RICHFIELD COMPANY SCALE I"= !000' DRILL SITE 6-7 RADIUS OF CURVATURE GYROSCOPIC SURVEY ALL DEPTHS SHOWN IARE TVD Eastman ~ ~~ Whipsto¢l~ ~ A PETROLANE C,C~PANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY ATLANTIC RICHFIELD COMPANY DS 6-7 WELL NAME NORTH SLOPE,, AK LOCATION JOB NUMBER A778 D0367 SURVEY BY Ken Walker, TYPE OF SURVEY Magnetic Singleshot DATE ?-31-78 John Beardon · OFFICE Eastman P. O. Box 4-19?O/Anchorage, Alaska 99509/(907) 349.4617 TWX 910-881-5066/Cable: ~=ASTCO November 6, 1978 Atlantic Richfield P.O. Box 360 Anchorage, Alaska 99501 Well Number: DS 6-7 Location: North Slope, Alaska Type of Survey: Magnetic Single Shot Method of Computations: Radius of Curvature Date: 7-31-78 Directional Drilling Supervisor: Ken Walker Job Number: A778 D0367 Attn: Bob Hines Dear Mr. Hines; I am enclosing the original and one (1) copy of the Magnetic single shot survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. incerely, _ cc: file enc. JFB:js Directional Driller.~ ,b-Surface Surveyors/Instrument & Tool Renta' · des/Worldwide COMPLETION REPORT NOV 1, 1978 ATLANTIC RICHFIELD COHPANY DS 6-7 RADIUS OF CURVATURE METHOD OF COMPUTATIONS K.B. ELEV. 64 FEET rqAGNETIC SINGLESHOT SURVEY DECLINATION ~1 DEGREES EAST COMPUTED FOR EASTMAN WHIPSTOCK BY F.M. LINDSEY AND ASSOCIATES RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER .... TRUE .. --~EAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG, 0 0 0 0,00 -64,00 N81,00E 2650 0 0 2650.00 2586.00 N81.00E 27!0 0 15 2709.99 2645.99 N81.00E 2813 2 0 28!2,97 27~8,97 S82,00E 2875 5 15 2874.8~ 2810e8~ N86,OOE ..... 2969 !! 0 2967,86 2903,86. N86,00E 3031 1~ 0 3028,38 2964,38 NSO,OOE 3093 17 0 3088,12 302~,12 N72,00E 3254 1S 0 3241.66 3177.66 N~3,50E 3483 22 0 3456,81 3392,8! N68.00E 3780 30 0 3723.54 3659,5~ N73,0UE DOG LE~ ..................... TOTAL COORDINATES C L 0 S U R E S SEVERITY SECTION DISTANCE ANGLE . .D~G/~00FT D M S o.oo s o.oo w o.oo s o -o -ow "o'.0o'0 .... o.oo 0,00 5 0.00 w o.00 s 0 .O.. 0 w 0~000 ..................... Q.~_QO 0.02 N 0.12 E 0.13 N 80 59 59 E 0,~!7 0,03 N 2.14 E 2,1~ N 88 58 58 E 1,699 2.08 0,09 S 6,05 E 6.05 5 89 4 5 E 5~24~ 0,82 N 19,30 E 19,31 N 87 32 38 E . 6~.~7 2,~5 N 32,61 E 32,70 N 85 ~0 56 E ~,872 32.23 . 6.~5 N . 48.67 E ~9.10 N 82 25 55. E. ~e95~ .................... 2~.78 N 93.44 E 96.67 N 75 8 ~7 E 0,800 56,93 N 16~,82 E 174.37 N 70 56 35 E 1.768 173,71 ~00.34 N 267.41 E 304.~2 N 70"45 13' E .... 2;726 .............. ~77.29 N 72 17 3.5 E ..... 2~627 ..................... 536.91N 72 ~5 39 E . . 4,328 839,30 N 73 55 4~ g .1,157 ........ ~.~_~..~9__~ 1210.59 N 74 ~3 3 E 0~16 1378.67 N 7~ 59 ~5 E ....... ~7376 .................. ~.~..~.~.~.~ 1594,55 N 75 16 2 E 0.3~2 1982,58 N 75 54 % 5_ . O~ 51~.25 N 2100,27 E 2162.31N 76 1~ 30 E O.216 2162.76 528.95 N 2159,25 E 2223.09 N 76 1~ 6 5 . 6,227 586.09 N 23~0.~8 E 2412.75 N 75 56 28 E 1.029 ...... 736.58 N 2848.51E 2942.20 N 75 ~0 .... 6 ~ ...... Q,!60 ............ 857.65 N 3285.06 E 3395.17 N 75 22 5 E 0,255 99~,85 N 3B15.57 E 3943,14 N 75 23 11 E 0,510 4090 38 0 3980,33 3916,33 N77,00E 145.1~ N 454.68 E . . 183 42 O 4051,56 3987,56 N76.00E 159,11N 512,79 E ~615 47 0 4359,58 ~295,58 N76,00E 232,3~ N 806,50 E 5115 ~9 0 469~.13 ~630,13 N77,00E 319,08 N- 1167,78 E 5333 52 0 ~832,78 4768,78 N77,00E 356.92 N 1331,67 E 5609 51 0 5004.59 4940,59 N77,00E ~05.50 N 1542.13 E 6109 51 0 5319.25 5255.25 NSO,OOE 482,96 N 1922,86 E 63~0 51 30 5~63,84 5399,84 NBO,OOE 64!8 5! 0 5512,66 5448,66 N72,00E 6667 48 30 5673.53 5609,53 N73.00E 7380 ~7 30 6150,62 6086,62 N74,00E 8002 ~6 0 6576,79 6512.79 N75,OOE 8791 42 0 71~4,23 7080,23 N76,00E 9535 45 0 7683.85 7619,85 N79,00E 1105,67 N 4315,46 E ARCO DS 6-7 NAGNETIC SINGLESHOT SURVEY NOV 01, 1978 RECORD OF SURVEY ALL CALCULATIONS PERFOR~4ED BY I B ~ ELECTRONIC CONPUTER TRUE MEAS. DRIFT VERTICAL SUB DRIFT TOTAL COORD!NATE5 DEPTH ANGLE DEPTH SEA D!REC D M DEG, ~924 45 0 7963,66 7899,6~ N~3,00E 1147,93 N 4582,28 E BOTTOM HOLE CLOSURE 4723,88 FEET AT N 75 56 9 E CLOSURES DISTANCE ANGLE D M DO6 LEO SEVERITY DEG/~OOFT ARCO DS 6-7 MAGNETIC SINGLESHOT SURVEY NOV 01, 1978 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, MEASURED DEPTH 164 264 364 464 564 664 764 TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 164. 264. 364. 464. 564. 664~ 764, 100 0 200 0 300 0 400 0 500 0 600 0 700 0 0 0 0 0 0 0 0 0,00 S 0.00 5 0,00 5 0.00 S 0,00 5 0,00 '5 0.00 S 864 964 !o64 1164 !264 1364 1464 1564 1664 1764 1864 " i964 _ 2064 2164 2264 2364 _ 2464 2564 2664 2764 2864 ........... 2965 ,7' 3068 . 3172 3277 3491 3600 864. 800 964. 900 !064, lO00 1164. 1100 1264~ ~ !200 1364. 1300 1464. 1400 1564. 1500 1664. !600 1764. 1700 1864, 1800 1964, 1900 2064. 2000 2164. 2100 2264, 2200 2364. 2300 2464. 2400 2564. 2500 2664. 2600 2764, 2700 2864. 2800 2964. 2900 3064. 3000 3164. 3100 3264. 3200 3364. 3300 3464. 3400 3564. 3500 0 0 0 0 0 0 0 0 0 0 0 ~ . 0 0 0 0 0 0 0 0 0 0 1 3 8 13 19 26 36 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 2 5 5 6 10 0.00 S 0,00 S 0.00 5 0,00 S 0,00 $ 0,00 S 0,00 5 0,00 5 0.00 5 0.00 S 0,00 5 0,00 5 0,00 5 0,00 S 0,00 5 0.00 S 0,00 S 0.00 S 0.00 N 0,07 N 0.11S 0.77 N 4.49 N 14.56 N 28.01 N 43.17 N 58,06 N 73.71 N 0.00 W .......... 0.00 W 0.00 W 0,00 W 0.00 W 0,00 W 0.00 W ....................... o.oo W ............... 0,00 W 0,00 W ................ 0.00 W 0,00 W 0,00 W, 0,00 W 0.00 W 0,00 .W 0.00 W ',~ 0.00 W 0.00 W 0.00 W 0,00 W 0,00 W ................................................ 0.00 W 0.00 W ......................... : 0.00 W 0.00 E 0.79 E 5.10 E ................................................... 18.55 E 41.85 E ............................. j 70.64 E 99,85 E 131.87 E 167,61 E 208,54 E ARCO DS 6-7 MAGNETIC SINGLESHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3712 3664. 3600 48 12 90.22 N . . 3827 3764. 3700 63 15 107.22 N 3946 3864: 3800 82 19 _ 124:56 N 4069 3964, 3900 105 23 142.25 N 4200 406/+. 4000 135 30 !61.87 N 4336 4164, 4100 172 37'- 184.39 N 4477 4264. 4200 213 41 208e25 N 4621 4364. 4300 257 44 233.40 N 4769 4464. 4400 305 48 259.43 N 4918 4564. 4500 354 49 285,36 N 5069 4664. 4600 405 5~ 311.25 N 5223 4764, 4700 459 54 337.65 N 5383 4864. 4800 519 60 365,77 N 5544 4964: 4900 580 61 394.18 N 5703 5064. 5000 639 ...... 59 ....... 421,59 N 5862 5164. 5100 698 59 447.19 N 6021 5264, 5200 757 59 470,78 N 6180 5364, 5300 816 59 /+92,56 N 6340 5464, 5400 876 60 514e25 N 6499 5564. 5500 935 59 548e10 N 6652 5664. 5600 988 53 582.80 N 6803 5764, 5700 1039 51 615.73 N 6953 5864, 5800 1089 50 647.88 N 7103 5964. 5900 1139 50 679.41 N 7252 6064. 6000 1188 49 7~00 6164. 6100 1236 48 7547 6264. 6200 1283 47 7694 6364. 6300 1330 47 7839 6464e 6400 1375 /+5 7983 6564. 6500 1419 44 8127 6664, 6600 1463 44 8268 6764, 6700 1504 41 8408 6864. 6800 1544 40 8546 6964. 6900 1582 38 8683 7064, 7000 1619 37 255.98 E 310,35 E 372,39 g 442,44 E 614,18 E 709,88 E 810,76 E 916.40 E !024,06 E !134,02 E 1248.20 E 1370.01 E 1493,07 E 1613,39 g 1734,,27 E 1855.56 1977.25 2100,27 2218.73 2329.72 2437,98 2545.!2 2651.59 710,31N _. 2757.39 740.60 N 2862,53 770.17 N 2966,69 798.96 N .3069,69 E 826.97 N 3171.54 854.10 N 3271.85 880.65 N 3371e37 906,14 N 3468,14 930.70 N 3562,60 954,37 N 3654,83 977,16 N 374~.86 ARCO DS 6-7 MAGNETIC SINGLESHOT SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. MEASURED DEPTH 881~ 8953 9090 9227 9367 9507 9648 TRUE VERTICAL SUB MD-TvD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 7164. 7100 1653 7264, 7200 1689 7364. 7300 1726 7464,.. 7400 1763 7564. 7500 1803 7664. 7600 1842 7764. 7700 1984 7864, 7800.. !923 34 999.20 N 36 1020.62 N 37 1041.69 N 37 _ . 1062.21 N 40 1082.28 N 39 ~101,85 N 42 1120,03 N 39 1135,38 N NOV 01, 1978 3833.13 E 3921,57 E 4012,2! E 4104.81 4!99.4! 4296,06 4393.49 4~89,04 ............................. ................... ARCO DS 6-7 MAGNETIC $INGLESHOT SURVEY , NTERPOLATED VALUES FOR EVEN !000 FEET OF MEASURED DEPTH, 2 4 16 18 ,10 . 3] ,, I TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 1000. 936. 2000 2000. 1936. 3000 29gB, 2954. 4000 3908. 3844. 5000 4618. 4554. 6000 5250, 5186~ 7000 5895. 5831. 8000 6575. 6511, 9000 7298. 7234, 0.00 5 0.00 W 0.00 S 0.00 W 1.43 N 25,58 E 132.37 N ~ 402.26 E 299.~5 N ~' 1083.55 E 467.78 N .' 1839.52 E 657.78 N ~ 2578,42 E- 857,27 N; 3283.67 E 1027,95 N 3952,62 E NOV 01, 1978 ...... HORIZONTAL. VIEW ATLANTIC RICHFIELD COMPANY SCALE I" = !000' ............. DRILL SITE 6-7 _ _ . RADIUS OF CURVATURE MAGNETIC SINGLESHOT SURVEY ~. ~, TVD- 7964' ~ 0 0 ~ % o ~ TMD= 9924 t~ % ~~~--''~-~ ARE TVD CO DS 6-'7 ALL ~.t~G,.I ET I C RE'''' ;~ ' OF CALCULATIONS PERFOR/','~E"" ~, BY I iv. UI.T!SHOT SLIRvEY S U k V E Y C 0 ;'.I t:-'; U T E R AUG 25, !976 AS. L)'" !FT ~ T H A ~','. G L F' 'v'r'>; T i CAL OEI'~ Tr.t c; ~7 4:.q 4541 067 49 C 4663,94 1SO 50 O 4724,34 273 50 30 47~:J3.81 366 51 4~ 4842, 5q3 51 .D 4959.70 739 49 45 5077.85 83,7 40 a5 5137.94 925 50 0 5197,87 016 50 45 5257. II1 51 0 5515.~7 204 5() 15 5~7a,87 ~7~... 9"~ 3'~., 543~.I$ 2 50 30 5493,97 ~ 49 45 5553,59 577 49 O 5G14, 669 48 a5 q674.65 76~ 4~ ..... ~.42 47 '~C fig~2,B7 i35 48 0 5985,40 223 47 32' 6047,93 521 47 C 6111,06 415 47 0 6175, 17 538 47 O 623~,59 SUB DR I FT SEA Dt!~EC D E G, 4 ,'~ 77,46 4939,08 N78 4599,94 N77 6660,34 N76 4719,81 N78 477£! · 17 N79 4~36.38 NS0 4~95.70 N76 ~. 954, ~013.65 5073.9~ N'76 b133.87 N78 ~!93.18 NSO 525i.87 5310,87 b~80 5370.1~ t".i 8 1 ~429,97 N77 .. 5'489,59 N73 5550,15 N73 5610,65 5672,79 N75 5734.71 N75 5796.64 N75 5858,~7 N76 5921,40 N77 5983 · 93 N74 80~7~06 N75 6111,17 6174,59 N76 DOG Lt.- % C L (.) S U iR E S SEV';"'~i,:ITY D I £ T A N C i A ¢'4 G L E D E G / I ,J O F 1' D ~x~ ,S .OOE 275.50 ~',I 103t',.83 E 1067.02 I:,~ 75 2 11 E 1.209 · OOE 289,98 ?! 109'Foge, E 1136,58 N 75 13 9 ,OOE 305,20 ~i J 1167,62 E 1206,85 N 75 21 3 E .3,g69 ,COE 321,71 t'.i 1235,3~3 E 1277,55 ['~75 24 52 E 1.247 ,OOE 337,80 ~ 1306,04 E 1349.02 N 75 29 54 E 1,~B9 ,OOE 352,~3 N 1376,99 E 1421,33 N 75 39 5 ,OOE. 3654{+5 A': 1443,30 E 14.93.70 N 75 50 17 E 1,254 ,OOE 380.~t" ;'..! 1519,62 E 1566,56 r4 75 56 19 g 2.964 _.~., :..A ~,..,.. , ,OOE 425 23<,N.~'%~TZg..,5,1~,~, 1781 02 ['~76 11 12 E 3.282 ,00E 441 ~:.~k.,~",...,/.~,~'.:',*c~ u 1852 12 N 76 13 4 E 1.29U ,. .~ ,, .~, , .......... , .. ,O0~ 454 ~9:.~]..~/186E<]~<~'~i'$~j1923 07 N 76 19 17 E 1,m21 · O~)E 467,4.2 N 19'40,16 E 1995,67 t< 76 27 15 E 0,269 · tOE 479.91...~' 2C'10.96 E 20A7',43~ N 76 34 39 E · 0CE 491,73 7< 20E. I,60 E 2135,90 N 76 42 31 E 0.694 · OOE 505,57 ;,.'. 2152,79 E 22il,36 ~< 76 47 2 E 3.283 · OOE 524,03 F.~ 2221,72 E 2282,68 ~'.~ 76 43 41 E 2.632 .OOE 544,67 t,,~ 2289,22 E 2353.12 N 76 36 59' E 0.805 · OOE 564,93 A~ 2355,49 ~ 242k,29 i~ 76 30 46 [ 0.272 ,COZ 584.3~ t..: 2423,29 E 2492,76 N 76 26 30 E 1,223 · ,,OE 602,33 ~'.; 2490,31 E ~26Z.12 N 76 24 10 ,OOE 62G,2~ N 2557.33 E 263. i,48 ;"~ 76 21 57 E C.~36 ,OOE 637,59 t'i ~624,24 E 27C'0,59 ,< 76 20 37 E i,224 · OOE 653.66 N 2691,18 E 2769.42 N 76 20 5~ ,OCE 670,90 ~'~ 2757,82 E 2838 25 N 76 19'37 ,COE 589,15 ,N 2~23,62 E 2906.51 ;i 75 17 2 E .0,787 .OOE 706,94 N 2~'~v.03 = 2075,24 (";76 15 16 E O.'3OO · COE 723,97 N 29~''.,2,~8 E ~043.25 ?,~76 t4 15 E 0,786, ' ::C II J, , '-,IoFAt:C[ AUGUST 25 , C; 5 6- 'i' ! 97 5 VL;': T I C ~,L D L:I~ 'I i"! A N O L O ;v! S 0,00 S 0 0 O ~,,, O,Ot.) 5 0 0 (.; ',', C'.O2 2,03 ,".~ 89~."4 ':i3 E 5,94 a i.}{! 53 12 d 19,21 32,59 N 85 gl 52 E 58,64 117,il i50,51_ ~,~ 71 2,9 52 '~ 186.a2 r~ 71 8 47 225,75 267.69 t'Q 71 i 4.6 E .~12.40 ~62.26 ~'~ 71 416,17 .',~ 72 22 24 E 473,59 533,C;~ ~".~ 73 23 2i 59'5,59 659,85 ;'; 74 2 6 E 72~.51 '7c2,28 '" 860,69' h 74 929.1i N 996,09 N 74 54 3 E .. ...... , 0 · 0 O -64, ~.~ .... ?~ :..', 'C. b 27.)0, O'J 2636,00 ?iL' S 1~: 77,:)~ . oe 2645,a9 '~IS 2 0 2712.97 ~74c,97 ~75 r: ~ ~ 2"'74 84 28 .... ~. . ;69 1! 0 2967.85 2903,56 ~3i 14 0 3(.'°~'' 38 2964,S~ ,. ~.,, I x! 1:., a~' 3124.79 ' ..~n2,10 3238.10 ~!l 22 '3 33;~':, . ~' 3a74,45 34~'3,45 :... 27 :4:', 35~3,:32 }579,02 '~a 3,~ r~ ~72a,55 ~'" .......... :77 S5 ,3 3. ":1;'2,96 }738.96 ~69 57 "3 ~' 77. '~9 55!5,39 )53 58 15 9.951.5a 5~87.24 .56 41 45 4323,07 3959,,37 '.49 43 0 409i~77 4027,77 i42 44 30 415;J.,95 40~3'4,95 ,3D 4~. 3",,. a224, ,7i z'!50,71 '2~ 4.5 }0 a269,31 4225.31 ~22 47 C 4353,72 4289,72 '15 47 45 44i6,70 4352,70 'tip 48 0 4479,08 4415.08 0.00 S 0,00 ';,' '.i ~., w .... ;,J{,,O t,l ,":,02 E C ".02 0. I'l" o"" 5,9 4.~ ,;~i.';.,. ' ~ , ~ i~"' 34.52 ¢,: 1ii.91 [( 47,34 60.37 73,36 ~'.1 219,49 E 87,w_ ;'~ 253,15 E 100,47 ~.; 295,80 E 113,39 N 344,05 E 126.02 ~..1 390.65 E 13 8.9~ 152.57 ~'.,: 516,7E E 166.47 ,',~ 196,27 210.18 i< 763,89 E 225,5~ 242,~2 259,99 N 96~,6~ MMS DO(.) L i!] ,'5 Si'{V~-'" I,..-, TV, ~..; / ! ,., t;t T {,. {; ?. (, (, · .',. ') Z.. · 1 · L :': i; 6,117 4,572 9.C19 1.576 i · ( i: C i · 625 2.iZ8 2.807 5,z, 23 3,763 1,697 'i 1,256 0,999 0,652 . °02. ].. £.77 32,}Z SkO- ~2 u3i · :.)6 057.99 7~3 · 73 L59 · "7 927.a2 ~AGNETIC MULTISHOT SURVEY AUG 25, 1978 RECORD OF SURVEY ALL CALCULATIONS PERFORi',IED BY I B M ELECTRONIC COMPUTER :AS, DRIFT [PTH ANGLE D M ?787 46 a5 78g0 ~6 15 ~066 45 30 3159 44 30 ~2~2 44 30 3346 4~ 45 ~532 42 45 ~625 41 45 3718 41 15 ~811 40 45 ~905 40 0 ~999 41 0 PO~ 41 45 ~281 43 30 ~375 q4 0 ~563 45 30 ~657 ~6 0 R751 44 30 ~845 43 4~ 9939 42 30 D033 41 45 0127 41 30 P221 41 0 TRLJE VERTICAL. SUB DRIFT TOTAL COORDINATES C L 0 DEPTH SEA DIREC DISTANCE DEG, 6302,16 6238,16 N75,00[ 6366,03 6302,03 N74,00E 6429,90 6365,90 N73,00E 6493,92 6429,92 N76.0OE 6558,23 6494,23 N77,00E 6622e98 6558e98 N78.00E 6688.74 6624.74 N76.00E 6755.07 6691.07 N76.00E 6822.55 &758.55 N77.00E 6890.01 6826.01 N72.00E 6958.02 6894.02 N76.00E 7026.86 6962.86 N75.00E 7096.51 7032.51 N77.00E 7166.70 7102.70 N76.00E 7238.31 717a.31 N79.00E 7309.79 7245.79 N77.00E 7380e33 7316.33 N78.00E 7449.91 7385.91 N79.OOE 7518.51 7454.51 NSI.OOE 7586.42 7522.42 NSl,OOE 7653.75 7589.75 NSO.OOE 7720,22 7656,22 NSO,OOE 7785.81 7721,81 N79.00E 7851.98 7787.98 '~:'-NSO,OOE ~ , 79~9.46 7855.46 NSI.OOE 7988.06 7924.06 N83.00E 8057.78 7993.78 N84.00E 8128.05 8064.05 N84.00E 8198.72 8134.72 N85.00E S U R E S ANGLE D M 740.97 N 9021. 3111.12 N 76 759.03 N 3086. 3178.09 N 76 778.23 N 3151. 3246.21N 76 796.26 I'4 3216. 3313.64 N 76 811.94 N 3281. 3380.81N 76 626.39 N 3347. 3447.55 N 76 841.:~8 N 3411. 3513.30 N 76 856'95 N 3474. 3578.48 N 76 872'~3 N 3538, 3643,93 N 76 3707.90 N 76 889,33 N .3599, 906,~1: N' .:3660, 922,~6, N'. ,.::i~721, 937,37 ~ N" ....3790 ,, 951,61 i4' 3840, 59 E 73 E 55 E 54 E 87 E O4. E 11 E 36 E O0 E ~6 E 16'E 72 E 43 E 08 E 02 E 29 E 50 E 19 E 6.5 E 85 E 49 E 03 g 66 E 40 E 09 E 964,79 N 3899. 977,48 N 3959, 990,93 N 4020, 1003,53 N 4082, 1014,69 N 4145, 1024,86 N 4209, 1035.68 N 4274. 1047.23 N 4339. 1059.50 N 4405. 1071,66 N 4471, 1082,46 N 4536, 1091.40 N 4599. 1098,54 .N 4662, 1105,07 N 4724, 1111,01 N 4786, 3771.27 N 76 3833,79 N 76 3895.41 N 76 3956.42 N 76 4017.29 N 76 4078.30 N 76 41q0,41 N 76 4203.56 N 76 ~267.68 N 76 4332,46 N 76 4397,88 N 76 4464.21 N 76 4531,45 N 76 13 17 E 11 5 E 7 44 E 5 45 E 6 14 E 7 51E 8 49 E 8 40 E 9 3 E 7 20 E 5 12 E 4 37 E 4 33 5 4 '56 E 6 14 E 7 56 E 9 10 5 11 17 E 14 ~3 E 19 0 E 22 44 E 25 58 E 28 42 E 4598.11N 76 31 20 E 4663.40 N 76 34 41E 4727.37 N 76 39 6 E 4789.98 N 76 44 29 g 4851.92 N 76 50 5 E 4913.35 N 76 55 52 E DOG LEG SEVERITY DEG/IOOF'T 0,631 0,626 0,631 1,767 0.777 0,974 1,507 0,000 0.946 2,581 2,053 1,176 1.078 0.706 1,541 1.404 0,927 1,171 1,286 0.532 0,746 1.06~ 0,765 1,679 0,946 1,647 0,927. 0,266 0,702 SECTION DISTANCE 3109.04 3170.48 3243.84 3311,15 3378.29 3445.04 3510,78 3575,91 3641,32 3705,18 37~8,41 3830,86 3892.43 3953,42 4014,29 4075,34 4.137.46 42C0,66 4264.89 4329.82 439b.36 4461,80 4529.12 4595,86 4661.26 4725,3~ 4788,17 4850.30 4911,92 CO DS 5-? MAGNETIC MULT!SHOT SURVEY AUG 25, 197B RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTE R AS, DRIFT PTH ANGL F.: D N ~3 ) 4O 3'0 }4b../ 40 15 ~503 39 0 )597 37 45 ~691 37 30 )785 36 o 1879 35 45 }973 35 .30 .067 35 1.5 .161 35 15 ~255 34 45 L349 34 0 L443 33 45 :502 33 30 )T~ HOLE T R U E V~RT I CAL SUB DEPTH SEA 8269.93 a205.93 8.341.94' 8277.54 8413.94 8349.94 8487.65 g423.63 8562.08 ~t498.08 B637.40 8573.40 8713.57 8649,57 8789.97 8725.97 ~866.62 8f~02.62 8943.38 8879.38 9020.38 8956.38 9097,97 9033,97 9176,01 9112.01 9201.83 9137.83 9225,17 ~161,17 DRIFT DIREC DEG, NaS,00E NSI,OOE N84,00E NSB,OOE N87.00E N87.00E Ngo,ooE N88,00E Ngo,ooE N90,OOE N88,00E N88,00E 589.00E sgo.ooE S89.00E CLOSURE 5666,57 FEET AT N TOTAL COORDINATES C L 0 S U DISTANCE DOG LEG R E $ SEVERITY ANGLF DEG/IOOFT D M S 1116,36 N 4847,22 E 4974,11 N 77 1123,78 N 4907,65 E 5034,67 N 77 1131,60 N 4967,07 E 5094.35 N 77 1135,67 N 5025,28 E 5152,00 N 77 113B.17 N 5082.61 E 5208,49 N 77 1141,,~2 N 5138,77 E 5263,94 N 77 1142~i~6 N 5193,83 E 5B18,02 N 77 1143,~1 N 5248.57 E 5371,70 N 77 114~6 N 5302,98 ~ 5425,07 N 77 1144.46 ~.,, 5357.23 E 5478,11 It 77 5531,04 N 78 1147,Z~ ~N~ /~464~'18~'E:- 55~3,32 N 78 1147,56 Fl 5533,73 E 5651,47 N 78 1147.43 N 5549.18 E 5666,57 iN 78 1 49 E 0.532 6 8 E 1.796 9 57 E 1.835 15 55 £ 2.077 22 39 E 0.470 28 48 E 1.596 35 36 E 1.121 42 32 E 0,765 49 17 E 0.757 56 28 E O,O00 2 53 E 0,872 8 32 E 0.798 14 50 E 1.020 17 3 E 1.271 19 2 E 1.971 7~ 19 2 E SECTION DISTANCE 4972.86 5033°54 5093.32 5151.14 5207.79 5263,3~ 5317,59 5371.40 5424.87 54'18,00 5530.98 5583.29 563q,69 5651.46 5666.57 :0 DS 6-? MAGNETIC MULTISHOT SURVEY 45LJRED D~<PTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. AUG 25, 19'78 TRUE M~AsuRFD VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CONRECTION TOTAL COORDINATES 164 164, '100 0 0 26G 264, 200 0 0 364 .364 · 300 0 0 ) 464 464, 400 0 0 564 564. 500 0 0 664 664, 600 0 0 764 764, 700 0 0 864 864. 800 0 0 964 964 · 900 0 ~ 0 1064 1064, 1000 0 0 1164 1164. 1100 0 0 1266 1264. 1200 0 0 1364 1.364. 1300 O 0 1464 1464. 1400 0 1764 1764, 1700 0 0 186~+ 1864. 1800 0 0 1964 1964. 1900 0 0 2064 2064, 2000 0 0 )2164 2164, 2100 0 0 2264 2264, 2200 0 0 2364 2364. 2300 0 0 2464 2464. 2400 0 2564 2564, 2500 0 0 2664 2664, 2600 0 0 2764 2764. 2700 0 0 286~+ 2864, 2800 0 0 2965 2964, 2900 1 1 3068 3064, 3000 3 2 3172 3164, 3100 8 5 3277 3264, 3200 13 5 3384 3364, 3300 20 7 3493 346/-+ e' . 3400 28 8 3603 3564, ... ~500 38 10 0.00 S 0,00 W 0.00 $ 0.00 W 0,00 $ 0,00 W 0.00 S 0,00 W 0,00 S 0,00 W 0,00 S 0,00 W O,O0 $ 0.00 W~ 0.00 S 0,00 W 0.00 $ O,OO W 0,00 5 0,00 W 0,00 S 0.00 W 0.00 5 0,00 W O.O0 5 0,00 W 0.00 $ 0.00 W ..... ~ 0.00 S 0,00 W · 0,00 S 0,00 W 0,00 S 0.00 W 0.00 S 0,00 W 0,00 S O,O0 W 0,00 S 0,00 W 0,00 S 0,00 W 0'.00 S 0,00 W 0,00 S 0.00 W 0,00 S 0,00 W 0,00 S 0.00 W 0,00 $ 0,00 W 0,05 N 0,68 E 0.13 $ 4.99 E 0,79 N 18,44 ~ ~,48 N 41.49 E 15,45 N 68,68 E 29,02 N 99,1~ g 43,57 N 133,61 E 58,77 N 172,45 E 74,15 N 215,80 E s ,CO DS ~ASURED 6-7 DEPTH AND OTHER D A T A · MAGNETIC MULTISHOT SURVEY FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, AUG 25, ,~EASUR ED DEPTH TRUE VERTICAL DEPTH SUB MD-TVD DIFFERENCE VERT ! CAL CORRECTION TOTAt. COORDINATE$ 3715 3930 3952 407B 4211 4349 4491 4637 4785 4935 5087 5242 5401 5560 5717 5872 6028 6187 6500 6653 6804. 6954 7103 7252 7398 7545 7691 7B36 7981 8124 8264 8403 8540 8675 3664. 3764. 3864, 3964. 4064. 4164. 4264. 4364, 4464. 4564, 4664, 4764, 4864, 4964, 5064, 5164, 5264. 5364~ 5464~ 5~64. 5664, '5764. 5864, D964, 6064, 6164, 6264, 6364, 6464, 6564, 6664, 6764, 686~, 6964e 7064, 3600 3700 3800 3900 4000 4100 4200 4300 4400 450O 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 65O0 6600 6700 680O 6900 7OOO 5O 66 88 114 147 185 227 273 321 ~70 423 477 653 ?08 764 ~23 880 · 1040 1090 1139 1188 1234 1281 1327 1372 1417 1460 1500 1539 1576 1611 12 16 22 26 33 38 42 48 ~4 60 56 59 57 56 51 50 49 49 46 47 46 45 45 43 40 39 37 '.3.5 90,55 106,84 123,71 141,03 160,67 182,66 204,62 228,26 255,82 280,76 305,20 3~2,69 357,39 381,88 407,49 4,~2,40 456,24 477,63 493,01 527,62 561,38 592,30 621,26 648,25 675,68 703,72 730,60 758,43 788,17 813,23 835,38 858,97 882,09 908,12 930,70 263,64 318,80 386,71 461,65 546,73 639,15 737,73 841.29 947,06 1055,56 1167,62 1282,70 1403,99 1524,77 1643,54 1759,21 1876,74- 1998,05 2117,22 2233,44 2343,86 2452,88 2560,95 2668,05 2774,64 2878,02 2982,09 3084,64 3185,74 3287,50 3387,19 3482,52 3576,04 3665,88 3753,10 E E E E E E E E E E E E' E E E E E E E E E E E E E E E E E E E E E CO DS 6'-7 ASUF~ED DFPTH AND OTHER DATA FOR MAGNETIC MULT!SHOT SURVEY EVCRY EVEN i00 FEET OF SUB SEA DEP TH, 1978 TRUE ~,~,E A SU R RD VERT I (:AL DEPTH DEPTH SUB MD-TVD SEA DIFFERENCE VERTICAL CORRECI'ION TOTAL CC)ORD INATES 8807 7164. 8938 7264. 9071 7364, )9206 7464, 9344 7564. 9483 7664. 9625 7764, 9768 7864, 9906 7964e lOOZ~l 8064. 10175 8164, 10307 8264. 10g38 8364. 10567 8464. 1069~ 8564, lOB18 8664. 10941 8764, 11064 8864, 11186 8964~ 1308 9064, 1428 9164. 71.00 1643 7200 1674 7300 1707 7400 1742 7500 1779 7600 1819 77O0 1861 7800 1904 7900 1942 8000 19'77 8100 ~011 8200 20~3 8300 2074 8400 2103 8500 2129 8600 2154 8700 2177 8SO0 2200 8900 2222 9000 22~b 9100 2264. 32 .31 33 3'1 4O 42 43 38 35 34 · .3.1~ ,. 2~ 23 22 2O 950,98 968,99 987,80 1005,95 1021,4'8 1037,39 10~5,1~ 107~,69 1088,54 1099.10 1108.24 1115.90 :i:!126'55 .1134.83 1142,97 1144,46 1144,53 1146.45 1147,82 N 3837,74 N 3920,59 N 4005,79 N 4094.70 N 4188,1B N 4283,87 N 438~,27 N 4483,09 N 4577.46 N 4667,60 N 4795.90 N 4842,04 N 4926.10 N 5006.86 N 5083.82 N 5158.04 N 5229,98 N 5301.12 N 5371,64 N 5441.13 N 5508,23 ~CO DS 'E'RPOLATED VALU£~S FOR TRU MEASURED VERT DEP TH PEP T EVEN E AL H 1000 1000, 2000 2000, 3000 2998, 4000 3902 , 5000 4607, 6000 5245, 7000 .5894, 8000 6576, 9000 7310, 10000 803.3, I1000 8811, 1000 SUB SEA 1936, 2934. 3838, 5181, 5830, 6512, 7246, 7969, 87~7, MAGNETIC MULTISHOT SURVEY FEET OF MEASURED DEPTH. TOTAL COOf,]D I NATES 0.00 5 0.00 w 0.00 S 0.00 W 1.41 N 25,47 E 130,23 N 414,89 E 290.93 N 1103,41 E 452,43 N 1555,40 E 629.96 lq 2594,11 E 816.27 N :~300,B5 E 977,6~ N 3960,07 f 1096,17 N 4640,40 E 114~.~ N 5264,23 E AUG 2.5, HORIZONTAL VIEW ATLANTIC RICHFIELD COMPANY SCALE I"- I000' DRILL SITE 6-7' RADIUS OF CURVATURE MAGNETIC MULTISHOT SURVEY IARE TVD ALL DEPTHS SHOWN 4OO 8OO 1200 1600 2000- 2400. 2800. 3600 VERTICAL SECTION ATLANTIC RICHFIELD COMPANY SCALE I"= I000' DRILL SITE 6-7 RADIUS OF CURVATURE MAGNETIC MULTISHOT SURVEY I ALL DEPTHS SHOWN ARE TVD 44( 5200 5600 . TVD = 9225' TMD= I 1,502' Post O~'ficc.--P. ox 360 Anchorag das,ka 99510 Te]e. phona 907 277 5537 September 7, 1978 Reference: Enclosed are Gyroscopic Surveys for the following wells: / r~... s .__.T.776.:~s. #7-3 Also enclosed are Magnetic Multishot Surveys for the followi~g wells: D.S. #7-3 ,.~0. S. ¢/6-7 · Please sign and return the copy as receipt of data. Sincerely, R.A. Logue North Engineering TRANSMITTAL #443 DEP~ OF ~SI/RAL RES(YfRCES Division of Oil and C~s Cc~serv~tion Imnnie C. Smith Chief Petrol~ Augu. st 8, 1978 BOPE Test, Arco's DS 6-7 Friday, ~!u-~ 4, 1978 - I departed my hcme at 9:30 AM for a 10:00 AM S~ ~n~-~]ii':o'o~-~- de~parture via wien flight ~9 to ~ Bay, arriving at 12:50 PM. I was met at Arco strip by Julius Drenzek, Arco drilling f~, and we proceeded to Drill site 96 where we met with Tcm Black, Parker Rig #141 toolpusher. T~mperature +70© F, light wind, high overcast. Operator w~s doing a top job c~ 13-3/8" casing set at 2732'. Saturday, ~ 5:19~8 - Tests began at 12:45 PM utilizing Kocmey ~r-ipiex ~ and' diesel with upper pipe rams, inside valves ~n the lower cross, check valve in the kill line, lower kelly valve and two valves in the choke manifold te~ to 5000 psig. Outside valve on lc~mr cross, ~ ~nside wing valves on the kill line, inside 5000 psig. The remaining six valves and sixteen valves in the choke manifold tested to 5000 psig. S~mco super~e was actuated both fully open and fully closed and man~ adj~le choke %~s free mov~_ng. Both dart and ball ~ floor valves w~re in place before the ~so Bottom pipe rams ~ to 5000 psig and annular .preventer tested to 3000 psig. While pullir~ ~he test joint to test blind rams I toured the location which was w~ll organized, reserve pit ~_11 built, rig in ~ood repair, and the well sign w~s in place. Blind ra~ then tested to 5000 psig. Accxmulator pressure was 3000 psig and N2 backup bottles tes+~fl to 1800, 1800, 1800, and 1800 psig. We turned the ac~~a~ pump off and closed all ram type and annular preventers simultaneously. The acct~ulator pressure dro~ to 1250 psig and ~jned steady. The accumu~lator pump. was then turned cm and accumulator pressure returned to 3000 psig in seven minutes. Tests were concluded at 2:40 PM and a field inspection report prepared with a copy given to Julius Dre_nzek, a copy mailed to Bob Hines, and the original att~ched to this report. Arco DS 6-7 2- August 8, 1978 I departed ~ strip at 9:45 PM via Wien flight #20, arriving in Anchorage via Fai~ at 11:50 PM and at my hc~e at 12:20 AM. In ~: I witnessed ~ful ~ tests c~ Arch's DS 6-7. Attar ~ Al~)a Oil and Gas Conservation Commi~)e ~,~' Field Inspection ,Report ..Drlg":, Permit No. ~.--2_/ ~_~g~- Well/l~t~i~:[~ Sec/ ..T/~,/'R~_z:,/~-,-U M Operator~~.~ Represented by ~,~-~/~-~_. Name & Number~-~ Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item (~Location,General Yes No Item (~;~130PE Tests 1. Well Sign (~7~ ( ) .15./_~2~,Casing set 2. General Housekeeping (~ ( ) 16~---~-~-. Tes, fluid-( )wtr.-~--~ )mud (~}~oil ~. Reserve Pit-( )open( )filled (~ ( ) 17. Master Hyd. Control Sys.-~?'o~psi~ () () () () () () 4. Rig ( ) Safety Valve Tests ( ) ( ) 5. Surface-No. Wells ( ) ( ) 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , 9. BS&W , , , ( ) ( ) 10. Gr. Bbls. ( ) Final Abandonment ( ) ( ) 11. P&A Marker 18. ~'!2 btls./~_,/~ ~m v~-~psi9 19. Remote Controls 20. Drilling spool-~ "outlets 21. Kill Line-(~Check valve 22. Choke Flowline (~;;~HCR valve 23. Choke Manifold No. va~vs~flgs~_ 24. Chokes-( ~/t~emote( )Pos.(-~j 25. Test Plu~-(~ellhd( )csg( )none 26. Annular Preventer~_~opsiQ 27. Blind Rams..~psi~ 28. Pipe Rams~-m~opsiq~/-~) ( ) ( ) lZ. Water well-( )capped( )plugged (~ ( ) 29. Kelly & Kelly-cock.~,~psig ( ) ( ) 13. Clean-up (~)~' ( ) 30. Lower Kelly valve~_~_psi~ ( ) ( ) 14. Pad leveled (~ ( ) 31 Safety Floor valves-(~q~V /~w~Dart Total inspection observation time~/~hrs/d~=j~ Total number leaks and/or equiP, failures ~ Remarks days or when ready Inspected by _.~_~.~~_ ~ate~~_-_~_~? i· ~ 3, 1978 Pruf~0e Bay [~it D~ 6-7 Atlantic Richfield ~ State P~_rmit ~. 78-21 P. O. ~ 360 knc~, ~ 99510 ~~ is ~ approved applicatiom for permit to. drill the above refer~~ well ~ a location in ~ 1, T~hip 10N, Bange 14E, ~11 samples, core chips ~ a m~. ~ are not sunny is requ/n~. A directional ~uly ri~ in Alaska ~ hheir drainage~ systems have be~n classified as i~qom'~t for ~ spa~ or migzation of an~~ fish. Operations Ln the~ areas are ~ject to AS 16.50.870 and the .regulations prnmulgated, thereur~er (Title 5, Alaska ~strative Code). Prior to omnrencing operations ~ n~y t~ con~ ~ th~ ~mbitat Coordinator's office, De~t of Fish and C~mT~. Polluticm of amy waters of the State is prd~ibited by AS 46, Chaptar 03, Art~ 7 and ~e 'regula~~ ~xamzlgat_md_ tharmznder (Title 18, Alaska Admirzlstrative CctV, Cb~r 70) ar~ by the Federal ~.ter Pollution Corfarol ~, as am~.~. Prior to ~~ncing operat~ you n~y be ~cted by a ~esentative of ~ De~t of Env~tal Conservation. Pur~t to ~ 38.40, ~ F~ire Under State I~es, the Ala~ca Department of Labor is ~ing notifkt of ~ is~ of this permit tm drill. To aid t~ in sd~sdulir~ field ~rk, %~ ~ould ~iate your noti~dng, this office within 48 ~ after the well is Spt~. l-.4e %,~uld also like to be ~fied so t~t a representative of the Division ~m~y be ~resent to witness testing of blowout p~ter ~i~txmmnt before surface caszng ~ is drilled. F. M. Brc~ 2- March 3, 1978 P. B. ~ 6-7 P In ~ ~ of ~e~o~ or ~t please gi~ this office adequate ad~~ n~tlficat/~ ~ tha% ~ may h~4~ a witness present. Very truly ~, O. K. Gi~, Jr. Alaska Oil ~ ~ Ccmsexvatt~ Oc~ttee cc: De~ of Fish ~ ~, Habitat ~ w/O encl. Dep~rUmmt of ~ C~=va~ w/o e~cl. DeparU~mt of ~, 9a~xvi~=, Zabor ~ C~pli~ Divisi~ w/o en~l. At~!anticRichfieidCompany --' North Americ-.~ Producing Division North Alask~ ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 27, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 6-7 Dear Sir: Enclosed herewith is our Application for Permit to Drill DS 6-7, a $100.00 filing fee and the required survey plat. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Form 10-401 REV. 1-1-71 SUBMIT IN TRI. rTE (Other instructions on reverse si~e) STATE OF ALASKA OIL AND GAS CONSERVATION COMMI~EE ..~. ', . ~.~ PERMIT TO DRILL OR DEEPEN. DL:3k:-~ DEEPEN [] ~. TYPE OF woR~ DRILL ['~ b. TYPE OF WELL . WELL ,[~ 2.. NAME OF OPERATOR SINGLE MULTIPLE OTHER ZONE ~r~ ZONE [--] Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, AK 995Z.0 API No. 50-029-20299 6. LEASEDESIGNATIONANDSERIALN~ i ADL - 28311 7. IF INDIAN, ALLOTrEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. 4. LOCATION OF WELL ! l.'~ O ' At surface. ~,../ 20'N& IOT~6:'W SE cr Sec.. 2, TION, R14E, UM At proposed p,od/~o~_ '~ '- (~ 8800'.ss), 1~2.0.'N & 1070'~ of SE cr Sec. ~, T10N,. R14E',..UH .. 13.DIST~CE IN MIL~ ~D DI~ON N~OM N~ TO~ O~ ~ST O~IC[" App~ox~mate]j 4 m~]es N~ of Deadhorse I0. DS 6-7 i5IELD*~8~x Wp~o~~d ruon v Prudhoe Oiq SEC., T., R., bi., (BOTTOM HOLE OBJECTIVE) Sec. 1, TION, R14E,.UM 14. BOND INFORMATION: ~E Statewide Sure.~/or~o. Federal Insurance Co. #8011-38-40 Amount $100,000 15. DI STANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 16. No. OF ACRES IN LEASE 1070' 2560 19. PROPOSED DEPTtt 2700' 9300' +_TVD 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 21,ELEVATIONS (Show whether DF, RT, CR, etc.) 64' RKB, 38' Pad Elevation (Gravel) 17. NO, ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 4-23-78 23. PROPOSED CASING AND CEMENTING'PROGRAM SIZE OF HOLE SIZE OF CASING~ WEIGttT PER FOOT [ GR_S. DE SETTING DEFT" Quantity of cement '32" .... 20" 94 lb.I' H-40 lO0'+[ID 270 sx A~ctic Set to surface 17'1/2"' 1'3-3/8" '" 72 lb. MN-80 2700'+MD Circ to surface -'Approx 5500 sx.. 12-!/4". 9'-5/8'" '. ".'.47 lb. 8.0~95 , ; ll800'+_MD. 1500"+ cmt column on 1st. staqe . ........ . .... (Appr.ox 1000~ sx) Dl.us 300'+ colun on 2nd staqe (Approx 300 SX-) . . Atlantic Richfield COmpany proposes to directionally drill this well to +11800'MD, +9300'TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and operationally tested each trip. A string of 5-1/2" 17# N-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit interval will be perforated, and reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. Well will be flowed to production facilities during perforating and testing. The downhole safety valve will be installed and tested upon conclusion of job. hN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If propolal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dixectionally, ~ve pertinent data on sub~u, rface locations and measured and t~ue vertical depths. Give blowout preventer pro~. am. 24. I her~.~,, ify that the Foreg~'~ 'I'~;.xnd,~Correct DATE 2-22-78 TiTLEDistrict Drlg..Engineer Cf his spa.ce for State office us~) SAMPLES AND CORE CHIPS REQUIRED [] YES ~ NO DIRECTIONAL SURVEY REQUIRED ~ YES [] NO MUD LOG [] YES PERMIT NO. APPOVED BY 78-21 CONDITIONS OF APPROVAL, IF ANY: OILIER REQUIREMENTS: NO A.P.I. NUMERICAL CODE . APPROVAL DATE TITLE Chairman *See Instruction On Reverse Side 50-029-20299 }~arch 3, 1978 DATE ~arch 3,, 1978 t vVELL NC) I ALASKA STATE PLANF ZONE 4 LAT 70o.4 40.73 Y 5 94 3. 7 8~ LONG. 148°~9'57 22" x 685 783 73 WELL NC:'.2 LAT. 70c 14' 3D 5 7" y = 94~ 20~ 36 LONG. 148:: 29' 56.4B X 685 8 t 7 66 WELL LAT LONG N C,. 3 7C°14 3~.4 ' v 5 94. C'~409 . 48°~9 ~ ?-' x 685845.36 WE~L LAT. NOd 70° 14' $7.2~6'' Y 5 940967 54 148°29' 5506" X 685 872 80 WELL LAT.. LONG. NO. 5 70°14' 36.11" Y 5940 851.18 14 8°29' 54.34" X 685 900.32 WELL LAT. LONG. NO. 6 70° 14' 34.96" Y 5 940 735.11 148° 29' 53.61" X 68-5 928.21 WELL NO. 7 LAT. 70° 14' 33.80" Y 5 9~0 617.42 LONG. 148° 29'52.87" X 685'956.53 WELL NO. 8 LAT. 70° 14' 32.64" LONG. 148° 29' 52. 15" Y 5 940 500.66 X 685 984.2 I ..... ., well "13 '~ ; !"-- .3~0' '~...' 1090 -& . N 6 . · c, WeB Welt II 12 CERTIFICATE OF SURVEYOR' HL~EuY,~ER FYTH~I AN~ FN(PERLf ...... AND LICENSED TO PRACtiCE NOV. 23, 1977 NOTE ELEVATIONS ( M.L.L.W. DATUM) ON TOP WOOD CELLAR WELL NO. 4 36.7 WELL NO. 5 36.9 WELL NO. 6 36.8 AFE 2a EXISTING WELL CONDUCTOR Aq BI:LT ATLANTIC RICHFIELD CO. WELL NO. 7.g 8 L LC. AT E,., ~.',i )E I/4 'c PR~ TqACTE, qEC,., ~ NE I/40F PROTRACTED SEC. 11~ TION, R t4E ~ UMIAT MERIDIAN HE ~%: T Z ,' [ (),.JtjSBUR'( & ASSOC. / -~r~ NOVEMBER 1977 ', sc-L~ Nr T~.. iCHK~ bY_ i~ ........... Fit. ,.~K 77--46 Yes I,lo Re,,marks 3 Is a registered survey plat attached . 4 is well located croper distance from property line ....... zu'~_~ 5 Is well lc, c~=,=d s:-oper distance from other wells . 6 Is sufficient u ~'~diuau~d acreage available in this pool 7 Is well to be 4e'.'iau~d 8 Is operator tile oral,/ af=~^' ,~uu~u party Can permit be aT. proved before ten-day v;ait . 10. Does operator ha. vea bond in force . Il. Is a conservau,cn order needed . ,. ,l. i~ =/ministrat~ve approval needed ............ 13. Is conductor st'ring provided ............. 34. Is enouch ce;".ent used to circulate on conductor and surface . ... ]5. Will cen;ent tie in surface and intermediate or production strings 16. Will ce~':ent co"er ali knov,'n productive horizons ' . 17. Will surface casino protect fresh water zones . .- .... 13. Will all cas:n~ ~i,,,e adequate safety in collapse, tension & burst ~9, . De~s~ SLOPE ,h,:'''~.~ suffic~er, t. pressure rafina~ ~ - Test to ~~ psig -... "~ Plan of Operau~on . o.q Has D~I, · /.;~ditional ,,~ir-eze~-.ts A?p'r'eval Recommen~u ~eo~ c, g~v - Engi neer~ rig_: -- dCM HWK/~,~ LCS ?,AD Revised 11/17/76 Well Histo.ry 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. DIRECT DIGITAL LOGGING COHPU TER PROCESSED ANALYS~$ W,~ 1 1 DS 6-7 L.H; _.hi'.:; Fi~td PRUDHOE BAY DATE OF ,JOB,' 05 .... 01 ",:.:..~ Count.s, NORTH SLOPE ALASKA Countr? USA CLIENT FORMAT DATA TAPE LOG I NFORMAT I ¢' T AND ARD ....~ FORMAT ( L , I , S , ) Well No,: mR..O Depths: t0702,00 to t150~,00 Nmmm: DS 6-7 CH/CNS Field: PRUDHOE BAY DATE OF JOB ~ 0..,.- Ui TAPE RECORDS Datm' 2 ,ilINE lg:~6 ~ 26 PM MON, TimeI ~: Page: 1 *** REEL HEA~) ER' **** Service name: &GSFO1 Prmviou:s. rmell Date: 86/06/02 Commmnts: HEADER Or. igin: RECORDS. Pag~ Cont. inuation ~: 01 Sar. vice name: &GSF01 Pcmviou~ tape: Date: 86/06?02 Commmnts: Origin: Tap~ name: Continuation ~: O1 ::+, EiDF *** Fii,~ nmme; C~GSFO~ ,O:OJ HEADER RECORDS or, #: Date: Page Maximum length: 1024. .File type: LO Previou~ ¢ilm: CN WN FN COUN 'STAT CTR¥ SECT 'TOWN RANG EK8 EDF EGL PD LMF DMF RUN LOC: ~ON LUN FL LUL ENGI WiTN DD DL TLI 8Li TCS TLA8 BHT HRT liT HSS HVIS RM RMF MFST HFSS RMC MCST MCSS INFORMA CONTEN ~ .., ARCO ALASKA IHC, DS 6-7 CH?CNS PRUDHOE BAY NORTH SL. OPE ALASKA USA iON 14E .... 64,0:00, 63,0 O0, 3-2,0 O0, , 30 363683 . 7208 SLOF'E' NORTH SLOPE ROEDER FIFE 11475 000, , , 1148 i 0 O O, iOTO0 O00, , , ii479 500, , O, :OOO Q,OOO ...... 0.,000 ...... 0,000 CRUDE DATE OF JOB : 6'666.. . ............... O.O00 ........................ '0,000 ............................. 0 .-OOO ................................. '666 ................................. I I I i I I I I I I ~ ; I I I ;~ I I t I I I I I I I I I ] I ] I I 1 [I I '0 0 0 .................................. TION RECORDS l&llllll:llllllll UNIT TYPE CATG SIZE COOE 0 0 40 65 0 I0 4 0 65 0 0 40 65 0 0 20 6.5 0 0 _'> 0 6=._, 0 0 20 65 0 0 2 65 0 0 .¥ 65 0 0 3 65 FT 0 .3 4 68 FT 0 .~ ',4,. 68 FT O .'5 4. 68 O -~ 0 "= 0 .:, ,=: 65 0 :3 ,~° 65 0 0 2 79 0 0 2 79 0 0 1 0 65 0 0 iO 65 0 0 2 0 ~,.~ 0 0 20 '= ,~O 65 0 0 20 65 FT 0 3 4. 68 FT 0 3 4 ~'"'o FT 0 3 4 68 FT 0 3 4 68 HR 0 '2 4 68 HR O 4 4 68 DEGF' O i 4 68 DEGF 0 i 4 68 0 2 2 0 65 0 2 20 6 5 CP 0 2 4 68 OHMM 0 2 st 68 OHMM 0 2 4 68 DEGF O 2 4 68 0 2 i2 65 0 H M M !"~ 2 ,4 68 DEGF 0 '2 4. 68 0 2 i '2 6 5 Fa~e COMMENT RECORD This LIS tmpm wa...--., writtmn bp Gmar. har-t Indus'trims Wirmlinm Smr'~icm~, All cur~,'m mn.d tool mnmmonics u~md ar~ thosm which mo~t closmly match Qmmrhar. t curvm and toot mnmmonics, GEARH~R[ TO .... SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT GR MERGE GAPI GR MERGE GAPI CCL MERGE MV CCL MERGE MV FCNL MER~E CPS FcNL. bIERGE NC.NL MERGE CPS NCNL MERGE CPS NPHS COMPUTED S .... ~FU NPHI ~MPUT PU RAT COMPUTED NRAT COMPUT ~V~ COMPi;TED AVG COMPUT Page DATA ENTRY BLOCKS ENTRY ~*** EN,R'~ BLOCK LEGEHD TYPE DESCRIPTION FORMA TYPE ,~PECIFICATIONS SIZE CODE 0 1 66 Page 0 Terminator .( no mor~ ~ntrims DATA FORMAT SPEC I F I CAT IONS DATUM SPECIFiCATiON BLOCKS SERVICE SERVICE MNEM ID ORDER # AP1 AP1 AP1 AP1 FILE UNIT LOG TYPE CLASS MOD PRC SiZE LVL SMPL RC PROCESS INDICATORS DEPT GR MERGE CCL MERGE FCNL MERGE NCNL MERGE NPHI COMPUT NRAT .COMPUT AVG COMPUT 363683 FT ~8~ GAPi 363683 MV 36368~ CPS ~G3683 CPS 363683 PU ~6~683 .... 0 0 0 0 O 0 54 i 0 0 0 i 50 i 0 0 0 78 31 0 0 0 78 30 0 0 0 i 22 :~ 0 0 0 O O O 0 0 0 0 0 0 4 0 1 6,q 4 0 i 6:n~ 4 0 i "~' 4 0 I 68 4 0 1 68 4 O 1 68 4 0 i 68 4 0 I 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT ~503.000 t 140.3,000 i13:03.'000 11203. ::0 00 i ii 03,000 003.0 O0 i 0903.0 00 DATA RECORDS GR CCL FCNL NCNL NPHI NRAT AVG 0.000 0,000 0,000 0,000 41 ,550 -999,250 -738 39,000 ,320 i 74.4-00 211.700 26.150 1.255 26 46,200 ,56 0 230,700 272.000 24.500 1.236 46,200 .330 378,000 460.:2:00 24,670 1,256 24 2,3,60,8 07:0 422 , 900 487.100 22.640 1,200 22 22.40'0 ,830 522,600 545,300 I 7. 086 I . 038 17 22.700 ,680 343,7.00 4`39.900 30,570 1,3i3 28 863 858 705 757 608 202 760 080.3,0.00 24.7:00 ,600 456,500 509, t00 20.880 I ,120 20 320 FILE TRAILER name: &GSF0J _ Maximum tmnqth: 'J' <' TRAILER RECORDS Version Dmtm: Film typm: LO Next ~ile: Page EOF ~*** FiL. E HEADER File name.: &GSF01,002 Maximum l~ngth: '1024 HEADER RECORDS Version File t~pe: LO Previous f'ile: Date: Pag~ I NFORMAT I ON RECORD© Page M N E H CONTENTS UNiT TYPE CATG SIZE CODE CN WN FN COUN STAT CTR¥ SECT TOWN RANG EK8 EDF EGL PD LMF DMF RUN LCC SON LUN FL LUL · ENG ~ WITN DD DL TLI 8Li TCS TLR8 MRT MT MSS MVIS RM RMF MFST MFSS RMC MCST MCSS ARCO ALASKA INC, DS 6-7 CH?CNS PRUDHOE BAY NORTH SLOPE ALASKA USA tON i4E ..... 64.0 O0 , 63,0'00 , ~. 000 ~ KB ....... 363683 . ?208 . NORTH SLOPE NORTH SLOPE ROEDER F I F E 1I 475. 000 i'148i , 000 107 OO. 00 O I 1479,500 0,000 O. 000 .... O. 000 .... O. 0 00 .... CRUDE 6'666 O,OOO O, 0'00 0.000 O, 000 DATE OF JOB 05-0'i -86 ...... 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 6~-o 0 0 2 65 0 0 ~ 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT O 3 4 ~.o' '~' 0 3 2 65 0 3. 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 20 6,5 FT 0 ,..~ 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 PbUF- 0 i 4 68 DEGF 0 i 4 68 0 2 20 65 0 2 20 65 CP O 2 4 68 OHMM O 2 4 68 OHMM 0 .-"~ 4 68 DEGF 0 2 4 68 0 2 i '2 65 OHMM 0 2 4 68 DEGF O '2 4 68 0 ~_'~ t ':'~. 65 COMMENT RECORDS Thi~ LIS tap~ was wr. ittmn bp Gmachact Industcims Wic~linm Smcvicms, All cuc~ and tool mnmmonic~ u~d acm tho~ which mo~t cto~ly match ~marh~rt curvm and tool mnmmonic~, GEARHART TO SCHLUMBERGER MNEM oERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT GR1 MERGE GAPI GR MERGE GAPI CCL'~ MERGE MV CCL MERGE MV FCNLt MERGE CPS FCNL MERGE CPS NCNL1 MERGE CPS NCNL MERGE CPS NPHS1 COMPUTED $SPU NPHI COMPUT PU RATI COMPUTED NRAT COMPUT Page DATA ENTRY *** ENTRY BLOCK LEGENO **** TYPE DESCRIPTION 0 Tmrminator ( no morm mntrims ) FORMA T c'PEC 1 F I CA TYPE SIZE CODE 0 1 66 TIONS DATA FORMAT .. SPECIFICATIONS P~ge 'i 4 DATUM SPECiFICATiON BLOCKS SERVICE SERVICE APl AP1 MNEM ID ORDER # UNiT LOG TYPE AP1 APl FILE CLASS MOD ~ PRC SIZE LVL SMPL RC PROCES~ iNDI~HFLR.. DEPT 363683 FT 0 0 GR MERGE 363683 GAPi 0 54 CCL MERGE 363683 MV 0 150 FCNL MERGE 363683 CPS 0 78 NCNL MERGE 363683 CPS 0 78 NPHI COMPUT 36~683 PU NRAT COMPUT 363683 0 0 0 0 I 0 i t 0 .30 O i ~ 0 i 0 0 i 4 0 i 68 4 0 i 68 4 0 ~ 68 000000 '000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 RECORDS DEPT GR CCL FCNL NCNL 114~3,000 0,000 0,000 0 000 0,000 NPHi ,890 NRAT -999 250 15 30,i.00 ,190 i 58 3;00 i95,700 27,510 i 248 ii293,:00.0 43,800 271 O00 298,900 20,670 1'1193,0:00 S0,500 1.5S0 488 000 547,308 20,980 1 200 t 1093. '000 23. 200 1 . 190 539 000 587,300 18.608 I 153 i 0993. 000 21 .,400 ,940 500 555.500 17.623 1 tO0 0893, O0.O 23,900 ,830 351 0793. 000 23,400 7,580 407 000 439.200 25.760 400 479 . 300 22,71 0 1 278 1 202 *** FILE TRAILER **** File Maximum length: "1024 TRAILER RECORDS File type: LO N~xt Version #: ?ilm: P~g~ i6 EOF *** Fil~ name: &~SF~I Maximum length: 1024 HEADER, RECORDS Ver'~ion 45: File 'type: LO Previous ~il~: Date: Pagm !7 MNEH CN WN FN COUN STAT CTRY SECT TOWN RANG EKB EDF EGL PD LMF DMF RUN LCC SON LUN FL LUL ENGI W I TN DD DL TLI 8L I TCS TLAB BHT MRT MT MSS MViS RH RMF MFST MFSS RMC MCS'F biCSS CONTENTS ARCO ALASKA D.S G-7 CH?CNS PRUDHOE BAY .NORTH SLOPE ALASKA USA t~N... J4E... 64. 000 63,0'00 32,00'0 KB, 3:0 72'08 HOP, TH SLOPE NORTH SLOPE ROEDER FIFE 11475,00.0 ~ ~ 0~00,000. 0,00 0 ..... 0,00 0 O, ~000 ..... O, -000 ..... CRUDE INC, O,OOO, , O. O00.. 0, O00, . O, 000, , I NFORMA 05-0 -86 TION I · RECORDS UNiT TYPE CATG I~I SIZE CODE 0 0 40 65 0 0 '40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 '-" 0 65 0 0 2 65 0 0 3 65 0 0 .3 65 FT 0 3 4 68 FT 0 .3 4 68 FT 0 ~ 4 68 0 :g 2 65 0 7 2 65 O ,3 2 65 0 0 2 79 0 0 2 ,'.. 0 0 i0 's 0 0 iO 65 0 0 20 e..,'~ 0 0 20 65 0 0 20 65 0 0 20 65 FT 0 .3 4 68 F'F o 3 4 ,6,8 FT O 3 4 6,8 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF O i 4 68 DEGF 0 i 4 68 0 '> '":' 0 6~ 0 2 20 65 CP 0 2 4. 68 OHMH O 2 4 68 OHMM 0 2 st 68 DEGF 0 2 4 68 0 '2 12 6,5 OHMM O 2 4 68 [EuF 0 2 4 68 0 2 i2 6,5 Pag~ 1,8 COMMENT RECORDS mm Thi~ LIS tmpm was writtmn by Gmarhact Indostrim~ Wirmlinm Smrvicms, mm mm All curvm and tool mnmmonics osmd ~arm thosm which most closml~ match mm mm-Gmarhart curve and tool mnmmonicz, mm GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MHEM SERVICE UNIT DEPTH FEET DEFT FT GR2 MERGE GAPI GR MERGE GAPI CCL2 MERGE MY CC[,, MERGE MV FCHL. 2 MERGE UP~ FCNL MERGE CPS NCNL2 MERGE CPS NCNL MERGE C~S NPHS2 COMPUTED SSPU NPHi COMPUT PU RAT2 COMPUTED NRAT COMPUT Pagm DATA ENTRY 8LOCKS EN TRY *mm ENI:R¥ BLOCK LEGEND TYPE DESCRIPTION 'FORMA T SPEC I F I CA T 10NS TYPE SIZE CODE 20 0 Terminator .< no more mntrims ) DATA FORMAT SPEC I F I CAT IONS Page 2i DATUM SPECIFICATION 8LOCKS ~** ************************************* MNEM SERVICE SERVICE AP1 APt AP1 APl FILE ID ORDER # UNIT LOG TYPE CLASS MOD ~ PRC ~ SIZE LVL SMPL RC PROCESS INDICATORS DEPT 363683 FT :0 0 0 0 0 GR MERGE 363683 GAPI 0 54 i 0 2 CCL MERGE 363683 MV 0 t50 i 0 2 FCNL MERGE 36J683 CPS 0 78 31 O 2 NCNL MERGE 36J683 CPS :0 78 30 !O 2 NPHi COMPUT 3GJ683 PU ,.O i2~ 2 O 2 NRAT COMPUT 363683 O ~iO 0 O 2 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 4 0 i 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DATA RECORDS DEPT GR CCL FCHL NCNL NPHI NRAT Ji492.500 0.000 0,000 O,O00 0,000 24 600 -999.250 11.392,500 28,6:08 ,500 I58,500 201,500 27 292,, 500 4i ,,400 ,230 277,6'00 306.800 20 1 70 1.i38 92,500 34. 000 I .270 488,300 566.000 2i 480 i ,225 11092,50:0 t8,30:0 ,570 515,300 571 .808 940 1.198 10992,580 24,600 .390 516,100 556,800 t8 388 t ,123 '1 08.'.-.32,500 26,000 · 920 .340,000 430,700 25 580 1 .306 0792,508 22,800 4, 180 416,600 485,500 23 390 I ,172 FILE TRAILER File name: &G~s, FO~ .003 Maximum lmngth: 1024 TRAILER RECORD'"' Vmr-zion ~: Film typm: LO Next ?ilm: Datm: EOF *** EOF *** bis VErIFICAtION I,ISTIMG V~R~ I O~,'~ ~ : DATE : AAXi~C~?~ L~;NGTH : 102~ FI~g I~YPE PRE:~'IObS FILE ** I~iFOR~ATIOS RECORDS ** PRgS: C(,~LOOIF UNI~ TiPg CATg SiZE CODE OoO 000 022 0~5 000 000 006 065 000 000 012 065 000 000 UO~ 065 000 000 004 065 000 000 001 065 000 000 008 065 000 000 006 065 000 000 006 065 Ui~IT S:¥P~ CATg $IZ~ C~DE 0 U 0 U 0 0 00 7 0 6 5 LV? 0o9. PAGE 2 10550 TYPE: 047 ** DEPT FC~L DEPT FCNL FC~b D£PT FC~6 DEPT' FC~h D£P'f FC~ 11505.500 NPHi. 292.000 369.250 G~ ll400,O00 292,250 GR 11300.000 NP~i 11200,000 ~52.500 Ga 11100,000 NPHI elO.O00 GR API AP1 AP1 API FILE bOG TYPE CLASS i'~OD NO. 0 68 2 0 0 0 42 1 0 0 0 3 % 92 0 0 0 3~. 93 0 0 0 3I 32 0 0 35.254 62.094 30.762 NR~T 62,094 33.496 ~RAT 26.I8~ 32,764 N~AT ~2,90~ 30.~59 NRA~ 20.654 ~R~T 17.?03 i 60 0 SiZE PROCESS SAMPLE REPR LEV'EL (]ODE ~ 0 1 68 4 0 1 b8 ~ 0 I 68 , 0 i 68 4 0 i 68 ~ 0 1 68 3,336 NCNL 1039,000 3.092 NCNb 1060.000 3,240 NCNb 972,000 3.201 NCNb 1.438.0OO 3.094 NC'ab 216~.000 2,525 NCNb 2q32,000 977 . 000 GR 20. 850 ~RAT i5.633 i0900.000 NP?i! 026 · 000 GR 19.766 DEPT lO~OO.O00 NP~i FC':~ b 062. 500 G6, 30.273 700 , 000 ~ F r, l 477,250 Gk 55,875 DEPI lOeOO.,qO0 N k,~.l. FC~L, 413. O00 Gi-! 63,844 10500,000 495,750 41,250 63,656 FC~ 439.500 36.330 ~!~AT 60.936 ** FI~C TRAILER FiL~; ~A~iE :SEAVIC.O0! SERVICE D&Tg : MAXi~Ui~ LEF!GTH : 1024 FILE 'I:Y PF : NEX'I FILi] EOf ** ]A~:~C ?RAILER *~ SERViCZ ~A~4E :SERVIC DATE: :81/08/14 ORIGI;'+~ :1070 TAPE ;~: ,A ~ '=' ~',m ~62103 NEXT ~iAPE ~}A~E : CO.~!.YE~:,-.TS :TAPE COMME[~TS ********** gO[ 2.539 3,053 3.~37 4.039 M C f,! b 203~.000 2035,000 2202.000 lw~7.000 1736.00u 1857.000 1691,000 VE[~IFICA~I, ON LISTING ** TAPE SE~VICF DATE :~7/12/ 6 ORIGI iv :7251 TAPE PREVIOb~ C(]~PE~',T8 :EP'rT P R U t." H r'~['' bAY D,$. 6-7,APl g 6-7 AP1 50-029-2o299 50-02c~-20299 VE~'SICb DATE ~AX lgljr,' FILE T~PE PRBV IOlJS Flbg .COl : 1024 CN : ARC6 ~ N : D. S, 6 ''" 7 RANG: 14E SECT: 2 UNIT ~¥P~ CATE SIZE CODE 000 000 000 000 000 0 O 0 000 0 0 0 T~PE 000 000 000 000 000 0 O0 0 O0 000 000 CATE 000 01.6 OlO 012 003 O03 001 012 0O6 004 SiZE 001 065 065 065 065 065 065 065 065 065 CODE 065 CO~,P.A~Y = ARCO ALAbE~, APl ~ = 50-629-2029q ~OTE: t.,) FILE El ir 001 COi~7'Ali~S CA$~;D t,tOhg Cu~,PEN6AIE, D NEIJTRON DATA OF ) LVP OjO.i{02 ¥tLPiI?'I£,AII,[,~,~ LISTIh<; PAGE 2,) F]~E: gDIT,()02 COI-iTAt~,~S CASI~,~G COLLAR ~OCATOR DATA fjF PAS~ 1.~ PA~S 2~ FAS~ I [P~I) DATA AVA].bABLg: I~558'?T0 10594' PASS 2 (PS2) PASS 3 fPS3) OATA AVA!b~B~E: 11.350'~T0 1,0594' ) ) 9 bLOCKS DEPT ? 'Y GR PS1 GAP1 riPHI ~R~T ~ ;'~h PSi NC~L PS1 FCNL PSi CPS TENS PSI LB GR PS2 G~-P1 NRAT P~ 2 R~RA PS2 ~'~C~L PS2 CPS ~ CPS FC ,L PS2 TE~'5 ~52 I~ GR PS3 (;APl ~'aRA PS',~ NCNL, PS3 CPS FCt~'L P63 CPS TENS PS3 hPHI DEPT RNRA NPHI D~PT OR FC~b GR I~CNL FC L LOG TYPE CI.AblS MOD CO 3t0 Oi 0 C () 890 O 0 0 O0 420 O1 0 (, 0 000 0 U O0 330 31 0 0 n 330 30 O0 635 21 0 00 3 j 0 0 ~ O 00 890 0 t~ 0 UO 4Yu Ol 0 O0 000 O0 0 O n 330 3 l 00 3~0 30 0 UO 635 21 0 O0 310 O1 0 O0 89t; 0(, O0 420 Ol 0 60 OnC uO 0 O0 330 31 0 O r) 330 '~ o 0 O0 635 21 0 0 f) 890 ,) 0 0 -P99.2 -999.2 -999~2 -999.2 -999.2 47 8 1498:0 -~,'~9.2 -999,2 32.5 -999 2 -999.2 -999.2 50O 500 50O 50O 500 5 o, O0 500 500 500 625 5o0 50 u 5 O0 5O 0 mPhI NRAT N P n i FC~L F C ,"¢ i, 73 65 60 .lin 1 0 SIZE SPI, REPE CODE 4 I b8 4 I 68 4 I 66 4 I 68 4 1 68 4 I 68 4 I 68 4 1 68 ~ 1 68 4 1 68 4 i 68 4 1 68 4 I 66 4 1 68 4 1 68 4 1 68 4 I 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 -9~)9,2500 NRAT -9<39,2500 T£NS -999~2500 RNRA -999,2500 GR -999.2500 PROCESS (OCTAL) O000oo00000000 00000000000000 O00000000000OO O0000OO0000000 O0000OO0000000 00000000000000 00000000000000 00000000000000 00000000000000 O00OO000000000 O000UO00000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 -999,2500 -~99,2500 -999,2500 -999,2500 -999,2500 3.9824 990,0000 -999,2500 :999,2500 999,2500 3.4453 1090.0000 -~99,2500 2*99,2500 999,2500 .) DEPT 112(]0, {,f'(l'J NCNb 2013,0000 kPHI 31 ,1523 FCNL 696, o,'Ci'~ h 2640.00 00 FC~L 1097.O000 47.2813 2210.0000 FCNL 694,0000 it 15.000fl 18 g437 2(>32 0000 17 2363 i1 14 2 41AO 1085 FC~L ~PHI 30.9570 NRAT 479,2500 2.8750 RNRA 100.uu00 3.6660 NCnL 31.9336 29.73 6 3 ~', R h T 720.0000 TENS 3.0020 1110,0000 GR 3.05h6 ~9.931a 29.4922 NRAT g(~8.0000 TENS 1 0oO0 GR 2.9668 28.2227 19.3359 N~AT 1064,0000 TENS 2.2969 RN~A IO90.0000 2. 3203 22.0215 NRAT 2.b133 RNRA 090. OOuO (;R ' 2,548~ NCNb 24.3164 ~.iKAT 852.0000 TENS 2.5a59 i075.0000 22,4609 37.5000 NRAT 541.0000 TENS .'3.4844 R~IRA 1075.00u0 3.5215 NCNb 37.9395 46.6~09 ~RAT 4:3t~, 2500 'fENS 3.8516 R~RA 06{:. 0000 GR 3.i016 5 6875 1695,0000 3,0332 111~,0000 ,9004 45,2500 2~34,0000 3,0215 ltO5,O000 2,92~8 18,2187 2418,0000 2,4395 I11~,0000 .3691 20,8125 254b,0000 2,6094 1095.0000 2,6563 19.2813 2312o0000 2.7383 1100,0000 2,5742 21,2031 2272.0000 ~,4609 Io80,0000 3,5547 64.4375 1962,0000 3.9609 1080,0000 3,9785 70,2500 SEPT 105~5. O0 R~.IRI~ -999,25 GR -999,25 ~ClvI, -999 NP~T -999,25 ~' Ch.b -999,25 0ot PAGE 1 553.000O -999. 2500 -999,2500 '999,2500 -'499,2500 -999,2500 ** FJbE HEADER 8ERglCg ;'~ A ~g : VERSTO~ ~ DATE : ~'AXI~,I~, I.,Er~GT,~ : 1024 FILE TYPE PREVIa)US FILE ** DAT~ f Okt~';AT RECOR[ E~TRY PLOCKS DATUM SPECIFICATION ~NEiq SF'R¥ 1CE ONFT CCI, CCL CCL PS3 CE:PT ~ 1, 5:,0 , 9160 CCh 2 4 9 0 .SLQCKS fi' 1 4 4 1 i REPR COD~: 73 AP1 AP1 AP,L AP1 FILE LOG TYPE Cf,ASS MOD NO. 0 :) 000 00 0 {] O0 150 O1 0 0 30 I 50 o 1 0 0 0<) 150 O1 O 0 ENTRY 0 10 SIZE SPb RE:PR CODE 4 i 68 4 1 68 4 t 68 -999. ?500 CCL PROCESS (OCTALO) 0000000000000 00000000000000 00000000000000 00000000000000 '999.2500 .) DEPT ! !500,2500 CCh D~.:PT I1400,250(~ CCh DF, PT I i100,2500 CCL OEPT 11000,25Q0 CCL DEPT 10900.2500 CCh DEPT 10800.2500 CCh DEPT 107V0.2500 CCh DEPT I0690,2500 CCh DEPT 10585.0020 CCh FILE ,~ Aide :gO~ .002 DATE : ~AXI~iJ~ LENGTH : 1024 0.06 ~ o C C b 0,127{, -0,ut95 CCL 0.3904 CCL 0.036~, COb o, 065~ CCL '0,0073 CCL 0.1953 CCL 0.1685 CCL '999,2500 CCi, -999.2500 CCL -999.2500 CCL 0,2026 CC~ -0.3906 CCD 0,t294 CCL ~0,2100 CCh ~0o2124 CCL 0,2002 COb ~0,0391 CCL 0,0220 CCL '999.2500 CCL -999,2500 -999,2500 0.1611 '0,2271 0,1709 0,0049 0.0781 0,1172 0,0244 0.1611 -999,2500 ** TAP~, TF:AIbE~ DATE :~7/t2/ 6 ORIGIa :725i CON~iE~STS :EOIT LIS,~NCO PkUDHOE BAY D.$. b-7,API 5C-029-20299 50"(,29'20299 ,) RECEIVED JAN 9 1991 Ataska Oil & Gas Cons. Commissior~ Anchorage PAGE t 9-L'-'!:~C-I 99.,q 'J2: 1. 1. (;!: 37' 1 t 3dO ' ',, T T N F': S $: ********************************************************************************** F'I'LF - EhT:"?.O01. ARCrV) ALASKA, 9,S, 6-7 50'029'20299 ~ch.].u~'.e:~et',~er .~]ask. a COmout ina 1 g-0~. (..'.--1 9 9 0 PAGE: T~i~!,!L' fYPP. : CO;!& C~, !~CD Al ~SKA, I~:C. ComDaDv Name w~, D.S. 6-7 Well kame ~m!~ 50-029-29?99 AP1 Serial Number Fr~ 20' FSb & 1. O65' PE:L Field Location S~Cq 2 Section TO~,:',~ ! O~i Township ~;~G 146 Ranae COUP, ffORiH $ [~OP~] County ST~T ALASKA State or Province ~!~,~ :~o~!S / CCPnbb~$ *it. ness' ~ame $9,.~ 404438 Service Order ~u~ber Pga? ~S[, Permanent datum ~;Pt~ FT O,. ElevatioD o~ Perm. Datum !.~F RK~ Log ~easured From AP!? FT 64, A~OVE PER~ANE4T DATUM E~;~ 'FT 64, ElevatioD Of Kelly Bllshl~ E[~F F:? i::3. Elevation of Derr~c~ Floor E6I..~ VT 32. Elevation of Ground Level t[>!> eT ~1300, Total Depth - Driller 7~!..~ ~T ~1.270, 6ottom Lo~ Interval ,, , ...... - - ... FT ODU~EiD F[.,t~I[,S Or l!inq Fluid Type {)epth Channel, ?:.iame $ioma (~,ieutron Capt~;!re Cross Sectior:.) Status of TOT TDT POrOSitY TOT Snt.lDt C~trrent Siama formatioa - ~ar detector (TDTP) sia~a formation - near detector SS~ma boreNo!e - far detector Sierra borenole - r~ei~r detector (TC, TP) ~ar ~rDT~'~'~ Count Rate .~ ~.ouDt Rate - far detect, or (Tf)TP) a.m~l,.ltude formatio~ : Far ~'let. ect:or Ar~'~r;~],, it, ude borehole - P.[GE; _ ',' ,~'[:, . ude for t C.,n r~ r erector _ ) Ac .~r ~,~n]. ltuc~ Foreno! e --* near ~et ector ( ] DT'P) sic,, Correctj. ot~ ':.orehole sicma (Correct'eo) -- Tr~TP "'~nitro~ mode n, enitor ratio r[~m Patlo Iota] Co~:~ut:atien 1 6tandard deviation of ~.~o~a-for..':~tiop ~,ac;-:aroond, ~,~ear Gates ?oral counts ane~vzed - eear detector Total cou. nts analyzed - far detectoz Tc)t~l Coupt. s - near datector ~rotal co~qts - far detector (TD'IP) ~e!.ected u~tes cou~t rate - near detector (TDTP) Selected cat:es count rate - far detector ~e,e!ast:ic countin~ rate - near detector Inelastic cou~tjn~ rate - far detector (TL)TP) Paw ~.~ear ~st Gate ?a~. ~?ear 2r, d Gate {~aw r~ear' 3~'c~ Gate F:aw ~:ear ~tn Gate Raw ?~ear 5th (~ate ~'aw ~<ear 6tn Gate Paw ,~ear 7tn Gate Ra~,' [~ear 8t'.h Gate Raw Near 9tn Gate ~aw ~:~ear lt.,th Gate ~qa~ ~.~ear tltt Gate ~'~ ~:~ea~ !3th Gate Raw ~,,]ear ].4th Gate ~;ear ],Sth Cate Near lGth Gate rat ].st, Gate Far 2nC Gate ;~ar 3rd ~ate Far 4t, h Gate Par 5th date ~aw Far 7th Gate Raw ~ar 8th Gate Ra~, Far 9th Gate Pa~ Far 1.0th (;ate Paw Far ~ltn (;ate ~aw ~ar 12th Gate ~a~ Far 13tn Gate Raw Far ].at:~'~.,(;ate ~a~, Far ]Stb Gate Raw ~ar 1.6tn Cate Tens ion CCL Am~t~.tude 1e-,r)CC-199a ('~. :1 i PAGE: ** SET T~P~ - 64EF ** TYP~ 1 ~6 0 7 !] 66 3 1~ 66 O 14 65 ~T 1.5 1~ 0 66 0 ........... '" ' .....' .......... ICg . ., I ~.tl, t.J~.~ ZE RL[.[. ~OCgSS OR[)~;R ~ LOG TYF'E CheSS ~(]D Nt.~;~, SA~P Ehg~ CODE (NEX) ;"";'il ..... '"',','""'"'"'"'",' ..... '"~ ........ ';;'a;;'"" 3g O0 000 O0 0 1 1 1 4 68 0000000000 PSl 4C~ ,a. 438 O0 PSl PU 404438 00 PS 1 V 40~,t38 O0 PSI CU 404438 O0 [:'S] CU 404438 O0 PS I C[.I 4:04q 38 PS~ CPS 404:i38 OO PSi, CPS 4044:38 PS1 CPS 404438 00 PS:I CPS 404438 oo PSl 404438 O0 P S 1 4 G 4 ,~! 3 '~ 0 o ~,~ ~:~ .......... , 0000000000 0000000000 OOO0000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000OO0 0000000000 0000000000 0000000000 0000000000 O0000OO000 0000000000 0000000000 0000000000 0000000000 0000000()00 ~1~. Tere :er~,~icatie~ l,istj, nd T("~~' PS1 4(i443~ ,r'q,,:p PSt CPS TCFP PSI (,-PS 404438 't $C i; PSI CPS ?$C~'' PS1 CPS 4,04439 ! ~' ,,', ~ PS! C~$ 404438 Itt:KB [':"Si CPS 40,-i43~ [.~ a~ 1 F'S1 CPS 4.04438 [.',' 2 PSi Cr~S 404438 p ,,", :~ Psi CPS ao4a-3a F:~'4 PS1 cr~s 404~38 k ;:* 6 P S 1 C P S 4 ~} 4 o, ], 8 f~,7 PS) CPS 404:438 P"* ~ PS 1 CPS 40443 ar' 0 PSi CPS 404438 R~,;~i o PSI CPS 404438 P ~: 1 '1 PSt C~S 4. a 4439: ~i'~ !, 2 PS1 CPS ~' 13 P8~ CPS 404.~138 [4 t...~ !. 4 PS1 CPS 404439 R~15 P81 CPS 40443g Rr'16 PS1 CPS ~ ] PS 1 C P $ 4 RF2 PS1 CPS 404438 p F -~ P $ .t C o $ 4 o 44:3 RF4 PS1 CPS 404438 ~F5 PS1, CPS 404438 R~O PS1, CPS 404439 RF7 PSI CPS 404438 RF9 PSI CPS 4O4i]g ~FIC P~I Ct'8 404438 RF:!} PSi C~S 40t4,18 kF12 PS1 CPS 404438 RF] 3 PSI CPS 404438 ~'~:14 PS1 C~$ 404438 RP!5 PSI. CPS 404438 R~ I, ~ P81 CPS 404438 (:;~ PS1 (;~PI 404438 TF: ~.~ S PSI bP, 404438 CC!, P81, ~ 404438 mill II~II! II II ~?,P gf.:E ¢ CODE ¢~KX} 1 .. 68 00 0 . O00 1 1 4 68 0000000000 1 1. 4 68 0000000000 1 i 4 68 0000000000 I ! 4. 68 0000000000 1 1 4 6~ 0000000000 I t 4 68 0000000000 ! 1 4 68 0000000000 i I 4 6~ 0000000000 1 l 4 6R 0000OO0000 I ! 4 68 O000OC0000 1 I 4 68 0000000000 ! l 4 68 0000000000 1 !. 4 6~ 00000000O0 1 1 4 68 0000000000 ! 1 4 68 0000000000 I ! 4 68 0000nO0000 ! ! 4 68 O0000OO000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I 1, 4 6e 0000000000 1 1 4 68 0O00000000 ! I 4 68 0000000000 I 1 4 6~ 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4: 68 0000000000 1, I 4 68 0000000000 ! 1 4 68 0000000000 !, I 4 68 0000000000 I 1 4 68 0000000000 ~ I 4 68 00000e0000 1 l 4 6~ 0000000000 I t 4 6~ 0000000000 i ! 4 68 0000000000 ~. I 4 68 0000000000 1 i 4 68 0000000000 I ! 41 68 0000000000 ! t 4 68 0000000000 1 I 4 68 0000000000 1. 1 4 68 0000000000 1, 1 4 68 0000000000 1 I 4 68 0000000000 alaska. Com~-'.ut:i~q. (:~nter. .... . I$~!.'. PS1 41 ,65,~ ,qF~ ~?. P31 103. 200 2h'~. pS 1 ~VT,PS1 6~ .~20 PF].PS1 PF~. P:41 5q~. 958 RF7. PS ] E~IO,V'SI 69~,70q PF'I 1 PT Iq. PS1 416.667 aP1 5..781 q'F~",S. PS 1 aqo, o r)0 CCL, PS 1 ! 1309.000 966 .. ~ '.. ~ ~ p 8 ! 20 ~. 572 ?: ¢,! f:~ P, P $1 p~ 23,590 BACK, ... ,:' o ..,~ P PS! 1, 03. 200 R~3, PS 1. PS1 1713,542 ps !, 953, !, 25 ~ ql 1., PS I ~'.~: 1 ~. PS ! 1!14,583 PSI 61,. 920 RF3. ¢81 FSI 598. 958 RF7. PS1 PS1 (~97.7()8 ..~ .. . , pSl 4 ~ b. ~67 afl5, PSi PSI I ! 05, o0('> CCi~. pS 1 !.120~ OOa P S 1 33, (~ 00 8!b~,PS1 51,943 ,PS1 0.707 BAC~'.,PSI ]'~Cg~. PSI 20500,316 TCNg,PSi TSC:~", PS 1 !246,634 P 5 !, 67,725 PS 1 ! 62~1,606 R ~'~ 7. PS i ~:!~,PS] !846,955 a~'::! 4, PS! !1,73,~78 ~ RF3 PSI PS1 21,67z P 81 490.057 R F 7, [' 5 !. I?F'!, O, PSt 667.6!4 RFI!,PS1 }~FI.~ ,PS! 4a7,689 RF!,S.PSI PSi 1 ~.70. 300 CCL. PS 1 22 725 2?,:729 SFr,,:[). PS 1 22.72.5 21,890 AB;,~!,. r~S ! 0.937 -0.028 TCAI.PS1 0.000 13,291 F'F:AC. PS1 4.997 -!71 .680 TCFr~. PS1 -56.360 -0,452 I~C:.PS! -6.170 ..1,042 R~,'a,PS1 947.917 2635.417 ¢~'~12.PS1 2364.58] 479.167 R~'] b,PSI 411.458 348.958 ~F4.PS1 473.958 369,79~ RFa.PS! 359.375 932.292 aFl,.PS1 765.625 2b0.417 RFI.~,PSI 20~.333 0.00 0 22 5~6 SmDT.PS1 194 000 2~:725 SFNg,~S1 22:725 O,OUO NTD<['. PS! 0.000 ,i3,673 AP~'~r', PS! 0.859 ....... 'PSl 0 000 -999,250 Tab. T, .. -099.~50 FBAC.PS1 -999,~50 -999 250 TCF'9, PS1 -999.250 '99~1250 INFD,PSI -999.250 1.20~,333 Ri~4,PSl 1.697,917 901,04~ RNa,PS1 947,9!7 2635,417 R.',bl.~,, ,PSI... 2364,583 348 958 a~.q, psl 473,958 369:792 RF~,PS1 359.375 932.292 aFl,,PS1 765.~5 260. 417 RF',iS, PS 1. 208. 333 0,000 2 ~ r:~ ~ 2 S ~ I;, ::[~. P 81 194.0 o 0 31:7.9 ~W',~O.PS1 34.339 ~,~22 ~ TPT. PSI 23 456 454,,30 A[ia[).PSi 476~790 I ~12 TFt.AT. PS t 1.494 74~,,,30 FFAC,PS!, 18.552 20232,605 'rc~o PS1 6459 813 25~f;,653 15!FO' ' 1173 67a Ck.~l'psl 4~}:724 , .PS1 162 ,,.509 921..4'74 R[~,PSI 895.433 2558,093 PbI'2,PS1 23'71.794 558,~94 R~:!.6, PSI 308,494 3'3~. 542 RF4,PS1 466 383 310 133 aF~} PSI 34810tt 215,'*,,36 RFIf,P81 85,227 TPHI.P81 SB¢F.PSI AF~D.P81 S!GC,PS1 LCOI.PSI TCA~,P81 TSCN,PS1 R~I,P81 R~5,PSI R~ig.P8! Ral3.PS1 aFl.PS1 RFS.P$1 RFg. PS1 RF13.P$1 GR.PS1 TP~il..PS1 $BhF.PS1 AFFD.PS! $IGC.P$1 BCO1.PS1 TCAN,P$! TSCN,P$1 RN1.PSI. RsS.PSl RNg.PS1 RN~:3,P$1 ~FI.PSI CF5.P$1 ~F9 PS1 RF13iP$1 TPM!,PS1 ~FFD,PS1 SIGC.PS1 LCO!.PS1 TCA~.P$1 TSC~.PS1 R~I.PS1 ~NS.PS! 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RNS.P$1 R5~9 ~NI3:PS1 RF1,PS1 RFS,PS! ~FI, 3,PS1 G~.PS1 PAGE: 17.808 29,227 153 004 31007 2 098 1075021344 10384.045 889.275 1726,466 21.18.055 4218 750 ·376:603 584.936 849,359 1760,817 15.906 29 950 33i787 138 790 2.750 2,653 64270,320 6246 661 896 267 1597 222 1992 187 3213 976 391 667 489.583 752'083 1095,833 99.6~8 PAGe: 50-029-P~299 apI serta~ ~quraber 1065' FEL Field Locatlo~ Sec ti, o~ Range State or Province ch].u~eerger .~las.k'a Co~r:uti. nq C~nte.r ! 9-I}-EiC-, 1 990 02;11. P~GE: 11 , Sn~:, t~ ServI Order'~ be . ...... ce U~ r Permanent datum Elevation of Perm. OatU~ Lo~ ~easured From ABOVE PE~ANENT DATU~ ~i!evatlon o~ Kell~ Bushing Elevation o~ Oerrlc~ Floor Elevation of Ground Level Total Depth ~ Driller Bottom Loq Interval Too boo Interval Ortlll. hQ Fluid Type [) E F I !~ pT ~;e~th Cha ] Siq!~a (,::~ieu. tro~ Ca~t.'...~re <:ross Sectl. on) ~'~t at us of: "i:'i::,? Poros i, t y TDT Sh,lnt (.':utrecht Sioroa formation - far detector si~a for~-~atie~ - near ~'~etector ,Sio~a borehole - far detector .Siq:'.~ hero,die - near detector (7:DTP) vdt T!)T/~ Count. ~at:,e :iaar '][)T~/i Count ~ate ~,~:~litude forzation -- far detector (TDTP) ............ · .......ore . le -- ar ~:,etect. or Z~,:~e!ftUde for~r~at, iOn- pear detector ~:¢',nlttude norehole -- near :~etector (TUTP) sIG~' Correction ;~oreho!e si, gr:a (correcte~) -- TDTP Tr~' Patio ~.ac~:'(~rov~d, t:ear (;ares t'otal counts ~nalyz~d - pear ~etector (TD~P) Total counts analvzed- f. ar detector (TUTP) fetal counts - near c~etector · ota]. co~nt.s - far detector (TP'IP) gelected dates count rate - ~oar detector (TPTP) Selected c~ates count rate - iar detector Inelastic courlt~.ne rate - ~ear ~etector Inelastic COUntjDG rate - far detector [:aw 'ear !st Gate ~-3tv ~.~ear 2n,5 ~at~ Ra~,~ ~:ear' ?r,J (;ate !9--D[<C-!.,99() {)2',.11 PAGE ~.~ . ~ , F'~'~7:. 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PS2 ~76.P52 661 .058 --{F7, P82 ~F!.r'.P52 ~39,34:3 PP!I.P52 PFIa'PS2 1668,070 RF'IS,PS? DFp'r' '! (~73F~.0()I) gl . . ,.,, [_'* ~ ~., IS!i~l, PS2 52,5oc' SF'Fn. PS2 SB~ {<, . ['32 41,361 FTDT.PS2 SI~f:.PS2 41 ,.16! SDST. PS2 O, 267 [:.hCa<. P~ 2 TChF,P " ' , , ...... ..~ ~ . ~ , ~ . '.rs C F, ps 2 45 u O. 596 I ;'; '? [3,. PS 2 ~:i2, PS2 I ~ I.. 337 ~:~ 3. PS2 ~F6. PS2 72 1., 154 PF'7. PS2 ~:~'jO.P~2 ~*~5.385 kF'l I,PS2 ~'14.P52 !00,~.567 ~'F15.PS2 TF~ Y.P~2 14dC'.C.,nO C('i~.PS2 ,.1. !. 091. ST!>7.PS2 !94.000 !.4:S7~ SP~',! [), PS2 !.6.9o3 1.7,42a H'f'[::,T . 52 ,il !7! 5 .~ 2. o 45 h P, [~ [), P $ 2 46 q. 229 0,976 TPAT,P82 1,595 " PS2 36.939 32~92,719 TCF"D, PS~ ~2854'781 2582.03R I ~'~F[), PS2 5~9'539 311,632 R[~:~.I 2, P82 3862 847 2702,5~6 R~}:: 16, P82 1445:312 330,529 ¢F4,PS2 472,756 588,942 RFg,DS2 398.638 .1. 292,0~7 RF1 ?.PS2 1532 452 132~.{2S RFl. a,P82 659:054 0, 12,893 8TPq.'.P52 15.61.9 SF!x; t'.). PS 2 1,6,536 NTDT,PS2 566,872 ABi~i!.,, PS2 0,986 TRAT.. 82 !74,~i, 79 FPAC,PS2 31200,758 TCF[),PS2 2580.66g INFO,PS2 1050.000 P~4,PS2 1516,667 RNa.PS2 3327.O83 Rfq 1. 2, P8'2 2483,333 Ralh,O82 346,554 FF4,PS2 596.955 RF~t.PS2 !286.058' RFI2.PS2 119q,920 RF16,PS2 0, aUO 12. C);"g 7 S 15.636 8F~i.), PS2 16,51.5 NTt)T.PS2 5t:.3.219 AB?,'E. P,q2 0,919 ! F'.B. 374 F~C,PS2 30 P 67 3 o 1 2558:778 I~iF[.:. PS2 1091 .7q7 R~4. PS2 15L, O.SO6 F~:~.PS2 333q.343 P~12.P82 22~3.622 3~0.609 RFa,PS2 57~.9!7 t 372.195 RF'I 2. PS2 1'1'13.~78 RFJ6,P8? 194 000 171683 39,462 47 !. 482 1,589 39o456 12299 494 517~ .q52 1470 908i~33 3683 333 [2~2 500 470,753 378 606 ~446~314 566.907 1.94 000 18:469 38 905 4861753 1.506 37.112 12453.535 490.28~ 1552.484 907.452 3693.91.0 1207.933 5!6.~27 368.590 1528.445 50~.811 TPHI.PS2 SB}~F,PS2 AFFD,PS2 $IGC.PS2 LCOI,PS2 'rcA~,P$2 T$C~,PS2 RN1,PS2 R~S,PS2 RN9,P$2 RNI3,PS2 RF!,PS2 RF5 P82 RE9 P$2 RF13 PS2 GR PS2 TPHI.P$2 SB~F,P$2 AFFD.PS2 $IGC.PS2 BCO1,PS2 TCAN,PS2 TSC~,PS2 RN1,P82 RN5,P$2 RS9 PS2 RN1.3:P82 RF1,P82 RF5,PS2 RFg.PS2 RFI3,PS2 GR.PS2 TP~I PS2 $BHFiP82 AFF'D.P52 SIGC,PS2 bC0I,P$2 TCAN.PS2 T$CN.PS2 R~I,P$2 R~5,PS2 RNg,PS2 Rsl3.PS2 RF1,PS2 RFS.PS2 RFg,Ps2 CF13.P$2 GR.PS2 PAGE,: 18 007 25:s9 148,464 2.8.68 2.080 !.09280,20] .!070'545 894~097 1675,347 2022;569 ~264,322 39~,638 562'90~ 809~295 1'194,872 35,094 18,513 28,668 147,34.0 2,695 2,1.08 !00556,266 10142,707 914,583 1637'500 2016,667 4112 500 412:660 592 949 8271324 38.782 1740.563 1.5 957 301960 148,025 3.429 1,994 95009.406 9574,021 915.465 1720.753 2113,381 ]920.272 406,651 602.965 845,353 1698.718 54.656 Center !,9-DFC-I ~90 O~ ..'. t 1, P~GE: 17 ******************************************************************************* Center F' R U D H r'} E i;,~ A Y F i e 1 d N a ~ e lj.~ 6.~7 ~ell Name 50 629 ~()~99 API Serial Number 2o' ~oI., & 106 ~....,L FlelO bocation ............ ,:. Sect I on iON Township l 4.~ Ranoe NORT}4 $ OPE County AL;~SK.A State or Prov!~ce USA Nati on ~iORN,IS / C[?PUU~ ...... (~eo Nltness ' N'ame 40443~ Service Order ~um~er ~< 8 [.~ Permanent datum 0 Elevation of Perm Datu~ FIK'~ bo~ ~easured From 64, ABOVE PERMANENT DATUM 64, Elevation o~ Kelly Bushlno Elevation off Derr c~ Floor 32~ Elevation of Ground Level 1~3n0, Total Depth - [)tiller 1270 Bottom [.,og Interval I~50: Top boa Interva 1 1 P. Rf~DOCED FLU!t)5 Drillln~ Fluid Type TAE,!,,k~ 'rypK : CUrrY r',ept h Chan~e] Sierra (i~eutron Capture Cross section) Status o~ TD~ rOT Sh~ot Current f;~..c~e ~or~'~ation - ~ar detector Sioma for,',ation - near det~-,ctor 5i~:a ~ore~o]e ~ ¢~r ,':~etector 5iq~a ~orenole - ~ear detector [TOT~ ,~c'ar Ti')7~ Cot.]l~t ~,~te ~:'nrlit~]de formation -- far oetector .~?r~l~t.u('~e horeho],e -- Far ~etector ,~r~,!it~de forr~atlon - ~Aar detecter ~plitu4e ~orehnle -- near detector S ! C; :,' Correction ~orehoJe siqma (corr~ct.~) -- '~inj. troq ~'oqe q]onjtor ratio PAGE: S o r: at1.0r'~ o~ $i~*~a*f~o ~ t .on TI'.~:'~: ~C~ ~ack. ar'o~.]r~d, ~.~ear Gates FP~,C ~ar BacKqroond TC~:~ Total counts ar:~alyzed - near detector (TDTP) ?'Cn~' Total counts ~nalYzed ~ fi.:~r detec[t~or (TDTP) Tca~P Total cou~ts near de ~ctor (Tt,T) TCFD Total,. counts - ~:ar detector (TDTP) TACO,;, gel. coted qates count rate - near detector (TDTP) TSCP Selected qates count rate - far detector (TDTP) I:,~<,O Inelastic countino rate - near detector (TDTP) I~':~FD Inelastic countim(:~ rate - far detector (TI')TP) R~'~3 Raw l".~ear !st Gat:e p~'~ Raw ~ear 2n.d (~at.e R~3 Paw ~!ear 3rd Gate [:;:~. Raw qear 4, th Gate RF5 Raw ?'~ear 5th Gate Paw ~,~ear 7th Gate Raw r-~'ear nth Gate ~'aw ~ar 9t.n qate R~t! ~aw ~,~ear ~!.th Gate k~,:l,? ~aw ~'~ear ~2th Gate R~,'.I. 3 Pay,:' t~ear .1. ]t.h (;ate R~,~I4. Raw ~'.~ear 14th Gate [.~]~ ~'a.~? ;".;ear !Sth (;ate P~.~!~. Raw ~'.~ear 16tn Gate RTl. ~,~av,' ~ar J. st Gate ~'2 aaw uar 2nd Gate Pg'3 Pa~.' Far 3rd Gate ~'F4 Ra~: Far ~:tn Gate F'P6 r~aw ~"ar 6ir, (;ate pg7 R.a,,~ Far 7t~ Cate ~'"~ qa~ Far ~th Gate oF9 ~a'~., ~ar 9tn Gate qFll ~aw var l:!,t~'~ (:ate ~!~ ~a:~ ~'ar ! 3th Gate ~'~'14 ~a~ var !4. tt-: (;ate RF15 ~aw Far !St)~ Gate FF!f Raw war l~t~, (late ! 9-Dt:;C-! 9o0 02:!1 - ,, ~,.. , {2. _~ ......... . .... ~ ,, (i ,, k l ,.~ SPt,~' PS3 C~, ~.0a43~ O0 r,o,'-) 63 o F T Fi' m P S .t C P S 4 o 44. 3 ? () <') , '~ (5 ~;o o f') ~ F ~' t~ r' F 3 C P 8 4 r; 443 ~' .3 {) a Fl C: () (; o 3 ~r ~;r? gl33 CPS aC. 443F C,O OOf~ on ~ 3 S!GC PS'! Ct; 4{'~443a o,~ p<)(~ oO 6 3 ,,, e p F P 6 3 4 n 44 ~ 3 f'~ ,', ('} C, (5 00 n 3 7' t~ ~,~ PF3 4,'*~43~ Or', .'~ {; (~ O0 ~, 3 I,CF~ 1 PS3 ,~9443~ CO c~o,, ~¢o ,) 3 · ,1 . . . T C 5. r P F 3 C P 5 4 (.~ 443 ~ ;) ~ ', n n F, 0 {', 0 3 1 1, ~ 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I l ~ 68 0000000000 ~ ~ 4 6R ^nnnOnO000 ! 1 4 68 0000000000 ! 1 4 66 0000000000 1 t 4 68 nO00000000 1 1 O 68 0000000000 1 1 4 68 OOOO000000 1 ! 4 68 0000000060 1 I 4 68 0000000000 1 1 4 6~ 0000000000 1 !. 4 68 0000000000 1, 1 4 68 0000000000 1 1 4 68 0000000000 ! I. 4 68 0000000000 ! 1 4 68 OOOO000000 i I 4 68 0000000000 1 1 4 68 0000000000 1 I 4 6~ 0000000000 ! I 4 68 0000000000 1 t 4 68 0000000000 ! 1 4 68 o000000000 ! 1 4 5~ 0000000000 I ! 4 6~ 0000000000 2O ch!u~ther'~:~er g]asKa .Col,~:ptlt. i~q C~t.:e.r 19-E.,.!:;C-1990 0~:I1 PAGEI 21 TSCr':~ PS3 CP~S 404438 Oi) ~0o O0 O 3 1 1 4 68 00o0000000 TSCF P53 CPS 40~43a O0 00(~ 0~ 0 3 I 1 4 68 0000000000 I ~'t ~:',. [> PS3 CPS .404.<i 3 a OO 000 O0 0 3 I 1 4 6a 0000000000 I~;FD P53 Co8 404:4:38 OO OOO O0 0 3 I 1 4 68 0000000000 k~'a! PS3 CP;S .40,143~ 06 OOO On 0 3 I ! 4 68 0000000000 R t'~' 2 PS3 CPS 4q443~ O0 00() O0 0 3 ! I 4 68 0000000000 P~: 3 PS3 C'P~ 4(~4438 ()0 000 O0 0 3 1 I 4 6B 0000000000 ~ ~.' 4 PS3 CPS 404438 O0 00() O0 0 3 I I 4 68 0000000000 a~5 PS3 CPS 4044:3~ O0 000 f}() 0 3 1 1 4 68 0000000000 P~;6 PS3 CPS 4(:,4438 oO 000 O0 6 3 I 1 4 68 0000000000 [:'. ~'~ '7 PS3 CP~ 404438 O0 000 O0 0 3 1 I 4 68 0000000000 F'~t~ PS3 CPS 404438 Oc, O0[:) O0 0 3 1 ! 4 68 0000000000 ~:O FS3 CPS 404438 O~'~ OO0 nO 0 3 I l 4 68 0000000000 p~.~ ! C P53 CPS 404438 O0 000 O0 O 3 I I 4 68 O0000OO000 [.~ ! } PS3 CPS 4(~44'~a OC, GO0 nO 0 3 1 I 4 68 0000000000 'F~I~ PS3 CPS ~.04438 Of~ 000 0(~ 0 3 ] 1 4 68 0000000000 ~:~..,1~ PF3 CP~ 4(.) 4~3~ OO OO() fly 0 3 1. ! 4 6a 0000000000 R~..i~ PS3 CPS 464438 C)(.> OOC~ O0 0 3 1 1 4 68 0000000000 ?~,~ 15 PS3 CPS 40443~ O0 Oof: O0 0 3 ! I 4 68 0000000000 .R ~.:~ :I 6 PS3 CPS 40443~ O0 O00 0,3 0 3 ! 1 4 68 0000000000 F' F~ 1, PS3 CPS 404.43E. OO OOO O() 0 3 ! 1 4 68 0000000000 P~'2 P~'~3 CP3 404438 O0 OOC. O0 O 3 ! 1 4 68 0000000000 ~4 F".] PS3 CPS 404438 O0 000 O0 0 3 1 I q 68 O00000oO00 r~. PS3 CP,$ 4. (.~'~,13 ~ O0 0o9 nc) 0 3 1 1 4 68 0000000000 !~F 5 PS.~ CPS 404438 0(') 000 Oq ri 3 1 1 4 68 0000000000 R~'6 PS3 CPa 4(,4,~ 0(:, ('~0~ O0 0 3 ] 1 4 68 0000000000 ~:~7 ~[;3 CPS ~0443~ O0 oOr') (:C, 0 3 1 1 ~ 68 0000000000 RF? PS3 CP,S 4044.]~ Oi) 900 0(; 0 3 I 1 4 68 0000000000 ~ ' Ou~, 00000 ~ V :!. C~p ~ 3 (: P ;~ 40,44 3 g 0 n 00 ('~ 00 0 3 1 1. 4 68 00 a 0000000 RF'I I P~?~? CP,S 40443~ c~r: OOO CO 0 3 1. 1. ~ 68 OOOO000000 1~12 P53 CPa 4C4437 Or~ 0~'~r) 0~'~ 0 3 I 1 4 68 O0000000OO ~<~'13 PSt CPS 4("443a 0~ 000 OC 0 3 ] ! 4 68 0000000000 I:~'!~- PS3 Ct~.~ 40~!438 04) 00;3 O0 ~ 3 ! 1 4 68 0000000000 a~15 PS:~ CPS 4()443~ (~0 OaO no 0 ] i 1 4 68 0000000000 ?Fl6 P53 CoS 40d438 OC~ O0(: O0 0 3 ! 1 4 68 0000000000 C:~ Pi~ GA~,~ 404a38 ()C~ OOC~ Ot~ 0 3 1 1 4 68 0000000000 T~,S ~$~ [,~. .a 0-4.4'] ~ 06 ~Ot~ Oc, 0 3 1 1. 4 68 0000000000 15,636 SVr~[.;, PS 3 18,469 SBHF,PS3 !.~.51.5 ~:T~'r. ps.t 3~.905 AFFD,PS3 56~,2i. 9 Ai'~D,PS3 486,753 SIGC,PS3 ] 6a,3'l,t F~AC.PS3 37.112 TCgN,PS3 15,957 30,960 148,025 3,429 1,994 95009.406 1. q,,,t'.'~ ?.:C- 1990 02:!1 ~.~:.; 1 -4, PS 3 !255,20~ R?~.! 5,PB3 932, P.F"~, PS3 56,760 .~:73, P83 317, P F 6, p S 3 4 '! ?. 917 ~ F '7, P S 3 354, ~:P!O o~3 ~35,~33 R:F'!I,OS~ ~22, . ~ ,~ ~_. :~,<. ,., . . ,:'" ~.. ~.:'F ! 4: ' PS 3 479, !67 RFtS,P83 276, 'rF"r:$, PS 3 91 O, 000 CCi, P83 O, I1208,¢'00 $!G',~, P$3 28, 46,000 8FF!>, PS3 31. 775 F 'r D T ,"P o ~' 3 775 ;v~ ~,,~ 0 F, P S :t 0, !189,261 I :'.:!i~ .:), PS 3 2473. 500 ~".~ 3, P83 1097, 15~2,53z,. ~ a~-~7 ~.~e,.,3 !039, a d. i~ P :~ 1 I ' [" t:; 3 25 'i .4, ...... j 1.3~,221 P:'>I 5,PS3 839, i71 RP'~,PS3 304, 25t.~ '~F7. PS3 31 O. 625.000 ~'~'1, !,. PS 3 822. g3 ] RF1. 5, PS3 262. [:F:P'r. !. 1 106,000 SIO:~. PS ! i O. ]SHY,P,53 49.90!., FF~[). PS.~ 12, 5}3 H~':. , PZ. 3 47 , 447 F'I"!.)T, PS3 ! 1 , ..... '~: 0 ~ ~ : '' ;,d t C~ ~ 5~ %: ~ ,. ti, tt. .: ~, ", t.> . ~ ..... , ., ,. Sr~ST,P53 t,.', 245 ~.:~ C;<, P,S 3 '.t: C ,~, F, F 5 ~ 412 ~ 2,20 :! 'I: C t,~ ~>. ~, S 3 206 U 5, Ta('~c. P53 4133,137 t >.i~':. 7,, pS 3 2208, ~t'.'2,pS3 :179,955 ki',~i,PS] 1907, r~ ,,, ~ · 'r, s ~_ 1772.83 t:.; ,..,~ r.~ 7. .,p s .~ 135. 6. 9,~14.ps3 3287,~59 k;:15.~S3 ~648, F F~. PS 3 37. 594 RF3, PS ] 3u5. rp.¢,p.:.53 5~5.93t~ RF'7,PS3 477, ~<.ViC.P~3 670.573 ~11.F:'53 976. ::'~ i4.P5~ 135~,337 :~'F'I 5. PSi !1~4, ?F"~. PS 3 1335. (:,09 CCI.,. PS3 O. 3(;5!. TCFD.P83 12453.535 778 I{'.IFO, P$3 490.288 54'2 F::i",i 4, PS 3 1572 917 083 R~,48, PS3 901i042 500 a~::~ 2, OS3 2286 458 o 9 PS3 932" 292 Z. 2 R?.ll 6, p83 708 R F 4, 46~,750 i 67 RFS. P83 348,958 9i, 7 RF12,PS3 781'250 0~:2 RFla,PS3 276':042 090 189 STDT,P83 410 SFN [:.:., PS 3 21.9 NTD? mS3 16 ~ A B ~, t') ' ,P83 927 '.PR t~T, P83 1.~5 F'BAC, Pa] 137 TCFO,P83 12~ I ~,~F?:::,, PS 3 756 RN4:,PB3 663 R~,8,PS3 0~6 RN12.PS3 343 RN16,PS3 107 EF:4,PS3 417 PP~,PS3 917 RFi2,PS3 500 RF!6,PS3 O00 337 295 SFND.PS3 1 a I ~'rt'~T, PS3 ,., ,~ Bt,,, PS 3 ~70 TRA'T,PS3 31.7 F8~C,P83 211 TCFD,PS3 ~41 INF9,PS3 612 Rh4.PS3 170 RNS.PS3 ~49 R~12,PS3 237 ~90 RF4.PS3 431 RF~.P,S3 5~2 RF12,PS3 ~96 RF1 ~, PS3 O O0 310 STPT, PSi 127 :>iTb r, P83 3i,q A ~. f.~ D, i~S3 079 T~,T, PS3 6!0 FBAC,PS3 ~u2 PCF'9, PSt 1.94..000 34,525 22.858 453 093 41.066 6i53.258 401,935 ~534.455 889.423 2331.730 77!,234 475,000 341,667 818.750 181.250 194,000 1.4,019 27.258 419,583 1.670 42 275 991!~691 411,674 1406.250 qll 458 3624~839 1566.506 449,219 325.521 li. 65.365 644.531 194.000 14.315 3~.424 453.291 1.540 39 0.¢5 1.3975~959 TSCN PS3 R~!.iPS3 R~<!5 PS3 R~ PS3 RFI.P$3 RF5,PS3 RF9 P$3 RF!3iPS3 GR PS3 TPMI,P83 8B~F..PS3 AFFD,P83 $iGC.783 bCOl.,PS3 TCA~.PS3 TSC~,P$3 RN5'PS3 RN9*P83 RN13,PS3 aFb.~S3 ~'9'PS3 PF13,PS3 GR,PS3 TPHI,PS3 8BHF.PS3 AFFD,P$3 S!GC PS3 t, col:Ps3 TCfiN.PS3 TSCN,P$3 RNI,PS3 RN5,PS3 R~9.PS3 RN13.PS3 ~F1.PS3 RFS.PS] RF9.P83 RF~3.PS3 GR,P$3 TPqI,PS3 SBHF.PS3 AWFD.PS3 SIGC.P53 LCOI.PS3 TCAN.PS3 TSC~.PS3 PAGE: 22 9574,021 895,833 1,583.333 1864'583 1890,625 343,750 489~583 70];125 671,875 232,250 8,30:1 4,980 !07,725 3 596 2!530 53407 48 3009,~8! 917 468 1610 577 1854 968 1957 13t 333 333 485 417 683 333 702 083 71,68~ 22,672 37,584 108,935 1.800 2.138 ~8266'813 8837,!91 ~73,397 1510,417 1814,904 3457.532 323,351 460.069 692.274 1391.059 46.594 16,292 30.002 155,943 2,116 1,960 125634,422 12199,313 chlt.~hereer ;l!,8$ka Comr...,utin~ ('enter ig-h?:C-l. 99e 02:! 1 2574,404 I 024..305 !643'5!8 327:!.. 604 3!07 6.39 333 33.3 683 333 1327 083 1.583 333 0,000 t 1,84,8 14,829 17,27 0 539,956 0.934 194,842 3.2110,230 2630,257 :i. OO5. 609 1664,663 2~62'580 31. 4 6 "10 551!215 1 317 2'14 1432,292 0 , 000 12,866 15.965 16.314 549,883 0,913 196.837 30241,621 2606.85! 970 938 1491:1~6 3236.S~2 ~403. 549 328.526 570.9!.~ 1217 949 ll.737 i5.116 15.981 0,931 2aq7.6C, 6 529 891 906°636 161.4,583 483'333 381,250 1585.417 843,750 194 0 41.587 469.861 !. 604 40 387 12746 873 529 038 1452 324 919 47~ 3880 208 1498 397 509,983 427.5!7 1521,267 664,062 1.94. 000 38 600 1.574 42.009 !1~87,504 51.7,511 !4!5.895 929.784 3649.691 1257.716 4~2.77~ 386.6!.9 1490.385 570.913 194.O00 17.699 30.603 4~2.8!8 !.591 43.475 12266.146 5!4.141 RNI.PS3 RN5,PS3 RN9,PS3 RN1.3.PS3 RF! ,PS3 RF5 PS3 RF9 PS3 REt3 PS3 GR PS3 TPHI,PS3 SB~F'PS3 AFFD,PS3 $ldC,PS3 bCO1.PS3 TC'AN.P$3 TSCN.PS] RFi'toPS3 R~:~S.PS3 RN'9,PS3 RN13.PS3 RF1,PS3 RFS,P$3 RFg,Ps] RFI3,PS] GR.PS3 TPMI PS3 SBHF:PS3 AFFD.PS3 SIGC.PS3 LCOI.PS3 TCAN.P$3 TSCN,PS3 k~:l,PS3 RN5.PS3 RNg. P$3 RNI~,PS3 ~" .PS3 R~5.PS3 RFg.PS3 RFI3,PS3 6R,PS3 TPHI.PS3 $BHw. PS3 ~FFD.P83 8TGC.PS3 I,COI.PS3 TCAN,PS3 TSCN.PS3 RNI,PS3 PAGE: 23 968 t64 1628 086 1969 52:1 452 463 43~ 500 600 000 847 917 t956 250 48 063 77¸ o 2 095 114346 7{9 11087 426 935 497 1646 635 1993 t89 4381 009 429'687 577'257 781,250 1803'385 52'435 17,588 31,052 144 341 2 881 2 096 101144 141 9735 479 995 370 1576 003 2019 676 3942,90~ 408,654 542,869 793,269 1680 689 51:188 17 945 32:403 142,523 3.354 2 117 104837i469 10169 641 961.538 !9-0r:.1C-!990 02:11 PAGE: 24 . · ,.-;,3 :1 63 702 RN4 PS3 1540,465 ...... . 1'"' PS3 911,490 ! 57. 452 (~".~ ! 1, P ~ '~ 3457' 5.32 R?O'I. 2, PS3 3992. 388 .. ~ ;.. . , .......... 74:7 1. q5 ~,{FT,P53 598,958 RFS,P[3.'] 390,6 5 ~t5:~, 365 ~F1 !.. PS.~ ] 3d4,086 RFI 2, PS:] !552.4~4 .... ~.. . . ~ .,,, . R~5.PS] RNg,PS3 RNI3.PS3 RF1.PS3 RF5,PS3 RFg,PS3 RFI3,P$3 GR,PS3 1,798 2069 446! 402 594 81.5 1722 77 878 118 644 952 3O4 756 063 D E F I ,. . BAY Field Name Well Name APl Serial Number Field Location Section Townsh~.p Range County State or Province Nation Witness' Name Service Order Number Permanent datum Elevation of Perm, Datum Log ~easured From ~OOVE PERMANENT DATUM Elevation of Kell~ gUShtno Elevat on of Derr cK Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval 'fop Log Interval Dr~lling Fluid Wype .... ~ ......... ' .... .':''r .... LOG TYPL C[,AS8 !~[.)O NUMB 8A~[' EbEM CODE (HEX) 8 .00 O0 4 1 ! 68 000 000000 8 O0 00~:, O0 0 4 1 1 4 ~8 0000000000 8 O0 OOO ~0 o ~ 1 1 4 68 0000000000 PAGg~ 26 0.000 TPH 1. H!..,t~ 1.4.502 22.53i TP~i.~LA ii..015 2~.1.56 TPbl,~{l,~ ~7.539 10,461 TPH I. ~4!.,A 22.41.2 10,3~4 'PPi, ! ,iiLA 15.527 ! i,~4 TP~.I. ~;LA !7.725 24 734 TP~I,~:I,A 34,R63 PAGE: 27 a-,~OV-1904 1~10 5n-o29-20299-00 ! F' ~t 50-029-20290-00 INC. wEIG~aT 72,00 47.00 17,uO 12.60 ~ ] '~C7.= ~ 11 61 .¢ 1~1}4,R ! 10~n ~075~.~ I (}721 .5 !<,715.0 9-.~;uv- 1994 1 :[246.0 t ],?Un.r,{ 1 1 ~Ogg.~, 10q53.0 · 10 P 7 1 , 0 10~43. ~ ~ {~74~,~ PAGE: ! I,~ 'rat'e ¥~rific~tion List.!l~O 9-?~0V-t9o,1 1~:~0 PAGE: 3 ner~t~ sr~iftea ar',d c!fr~tzed curves for each ~ass in separate files, ~I245.0 1U711,0 SWIFTS '-?;PP, Ar'~PLI~{D TO THIS DAT~. $ VALt) OW, FI PRUnHOF i3AY Field Ua~e R -7 Well Name b0-02o-9029o-o0 fiPT Serial Su~:ber Fsi, & ]Q6~' FMG Field Location Section Ranq~ $~A"' AL~gK5 State or Province 6Ou 4~bn3~ Servlce Order Number pnA~ N~inr,~ SRA L~VEI. Permanent datum }:~!~ ri O. Elevation of Permanent Datum APP PT ~4. AbOve Permanent Datum gw5 vi' o4, Elevatiop of Kelly 5ushinq ECL ~:'! 3~ Elevation of Ground Level TDb ~5' ll~b. Total DePth - Driller Tnl~ ~t 11259. Total neDth - Logger PwT DFAD C~HD~ Drllllmg Flutd Type T~'E! E TVPF' .~ Cj~iv~',r ~ic,~:~ (' outror, C~l,ture Cro ,~ i~r,a Corr~c~iop SR}~r norebole 8i~.~.'a - far 4et~c TDpT TDT POrosity ToA'P n~tlon Iotal ?;ear to Far c TgC~' "'oral Selected Counts "ISC~'. TOtal ~,el. ected CO:,ntg. ~ - I ~' Fr' TP, AC ctor (TF)Tp) ounts ar dot~c~or r detecto~ r detectnI dectector ar Detector r ~etector ~ detectnr det~cto~ ear Detector r r~etector Tnelastic cou~t fete - far Packcrounr~ Codnt F:at~ - ~ Gp ApT-Correc~e~ (:8~r~:~ ~av LI~ ~ape Ve~i£ication ~,isti~'~o ~,-FiJ¥-.l. gq~ 1~:10 PA6F,: B APl ~p-r APl ~PT VILE ~ ~W~ NUMB Si~g ~EPR P'~OCESS o,':6H IFTFb OEPTI~ .......... C~,: APCn ~.L,~SKA, I~qC. C.o~D~nV ~;ame AVI~,, 50-02o-~t)299-0q API Serial Nt]~er FL 20' FSI, a 1065' F~L Wield I,ocatloa SwCn 2 Section Tnp~ ]¢~ ~ Township $~"' A[,~$~ State or Province ~\~5I · USA ~at ion ~TI~': r, Avw P~E¢ Witness Name Sni< 4~:03~ Service Order Number p~' bFAh ~;a LEVEf~ Permanent datum EnD FT O. Elevation of PermaDent Datum i.,~F' ~,wL, I,~ gnSHI~,IG boo ~easvred From A~i':) F:' 64, ~ove Permanent Datum E~ P7 t4. Elevation o~ Kelly Bushin~ ECL ~"I' 3~, Elevatlo~ of Ground Level IbP FT 11265. Total Depth - Dr~ller 7'~L r'T 11259. Total ~eoth - booqer DFT DEAD C~I]DE r)rillJt)cl Fluid Type ne~t.h S~GC qin,~ Correction S l ).{;' Corrected r-ioreho! e SvS! ~t~r,a~arJ deviatior~ of TPHT ~'[;'v Porosity TeA~' 'f'OtS1 CO.~t& 8nalyzed - Pear deteceor (Tf*TP) TCAF "'oral co~nt.s ar'~lyz~r~ - ~ar detector [TOTE] T~.~F' q'otal capture counts - ?.ear detector TCFn qo~l ~art,Tr~ Cements - far doct:ectnr TSC~ 'vot..tl RelecteJ Cot, t~t~ - ~'e~r Or.t~CtOr lt,:~,;r, ~hejastic ~ou~t rate - near detector iH~'r'~ l[~]mstic collr, t rate - ~ar detector F'~~ ~,.ac~,iornut.,,-~ Co ]nt ~8tr~ - Vdt t~etector SchlUmbe?".~er Alc~Ska CO, p~,ltinn Center ** MET DrPT F? A~034 n~, 00U OU O ~ 1 1 4 6e 0000000000 STG~''~ q' t:,'P P CP ~0~4 OO Of',O O0 0 2 1 1 4 6g OOO0000000 8~8p TD'*P Cn 4b~'¢23 4 °d Otto nO f) 2 I 1 4 6~ O0000OO000 SDST '~'L)q'~' CU 4 ~ ¢: C, 3,; (~() 000 qO 0 2 ~, 1 4 68 OOOO000000 8~H*~ ~DmP CU 4d~{;~4 t~(-, gOO nO ¢ 2 ! 1 4 6~ gO00000000 8nBV 'rl)'PP C~ 4~au3q. O0 (?00 O0 0 7 1 I 4 6R 0000000000 TCF~ ~1',~ P Ct~5 '~ 8 ~:34 '1~ t)0O 0f n 9 1 1 4 6~ 00000n0000 T~Cp 7' [', T [' cng AbP(;~4 no uflO O0 o 2 I 1 4 6g O0000nooon I~br' 'rfcq P CPS 4, b~i¢~,,t OU 000 ou t~ 2 1 1 4 6e OOO00Oo¢on I~:FP mL, TP C~5 ~ bP, b'~4 oO Of)() nO P 2 1 1 4 6¢ O00OOOO000 B~Cv ~'1 ,rp CpS ~p:',~a 90 0o0 O0 O ? 1 1 4 6~ O000OO0000 F~A¢ ~'~2'~' [; CPS 4;,P;~34 oO OmO O0 0 ~ I 1 4 6~ OOOOO00000 GRC)~ ?b'P~ g~¢l ~-~n,,2'3,} nO 000 O0 o 2 1 I 4 6~ 0000000000 SChl,q~ber<i~r~',~asK~ ~o,~:~u't~n~ Cent~r . S'c:'.i'F, rP 16 4~4 S1GC.TDTo i 205 SDS~ ['[t,'TP 0.5~7 ,~,:}~ '~. TD'I'D 30.~93 SBMF.TD'f~ 26.480 TP[~I.TDTP I~Fn. ~{JT~; '473.90~ n/~CK.TP!'D ]20.~76 FB~C.TDT~ 48.767 GRCM.TDTP 0 000 36:40~ 5975 017 3~.143 TPHI.TD~P TC~D.TDTP I[~3D.TDTP 39.493 38.0~1 24141.519 2070.957 -999.250 44.306 53.231 I~4~2.8~0 ~912.960 -999.250 fer eacr, oass in STOP DEPTH I C, 75~ , n separate files, [,IS ~ame %/~r~£~.cat.~on ~,istir~o q-rgOV-19a4 I~:10 PAGk: ll t247.n 1 i94~.5 ]~27,0 ~lJSa,'~ ~o74. ~ I ] n7~. 5 ] o67.n 1 lnl?,$ ! 10]4.o 0o7~. 5 ~ 0°77.5 0951,~ ~ 0°53,0 {,~lo.n ~ U~1 ~ t>7~a,~ ! 077 I . 0 1077,1. O 07t. 5. n I 076~. 0 0756.0 ~ 0752.5 ~ q~'.O ~ u {,O 96.5 .......... F~,~I~j,~;ALEi~,I'I U.r¢SHIFTF, D DF,,pTR ........ -- SChlU~,berc~r ;~a~ka Cc,~'~ ~tta~ Center DVp~ FT 4 ~5 nO't4 O~ 000 00 0 3 1 l 4 b8 0fi00 noo00 8I(;~: ~r,TF' C~ 4;::~( '~4 i~O 00{: O0 0 3 1 1 4 6a O00nO00000 SlgC '? i_,~' P C~' ao~,34 ~h UOU O0 n 3 1 I 4 6~ OOO0000OOn STaP 'YO~P Ct' 4~a(,34 O0 Oc~() ~0 0 3 1 I 4 6~ 00O0000000 6D$I '~k'P C'~ 4 t~(}34 aU 500 O0 0 3 1 1 4 6R O0000aO000 8Pn~ Ti,,~- C!_~ 4 a ~,', 3,~, o(; Oeo nO o 3 i t 4 6g on0ooo0o0n 'J"~ 'ebq'r' p'~-~ a~]ou3,1 "~) OQ(~ nC 0 3 1 1 4 68 OOO0000000 TP ~,"' "' 9~'t: a ~03,~ or) OOu nO 0 3 1 I 4 68 OnOOO00OO0 Trbr' '~' D'r P CPS zI~o~)34 ,)0 O99 06 O 3 1 I 4 6~ 00OO000000 TC~;'~ ~'~.~ ~' C~S 4 r; ~,.> 3 q ?~u ~nn Ov n 3 1 1 4 6a OOOOOOOnO0 TSC~' ...re, p, ....... CPO 4~o34 au C'f)~ ali C 3 1 1 4 6~ OoOaOnO000. T¢Cr: ~'r. ~o COS ~,b~o~ no ,:~ o ~ Oo n 3 1 I 4 6e 0o00o0000o I N ;,: ~ vi,"r i> CoS 46903~ Of; f;O(: O0 O 3 1 I 4 6q 000~000000 [4flO}~ 'Ti) T P C?,!~ 4a 5: '.~ 3~ at; ,'30n nO o .3 1 1 4 6g O00nOO0000 F~A¢ 'ri:TP C~S 4=~'}44 ~,, L, ou o(~ 0 3 1 1 4 68 00000nO000 GPCp ~',.;'~r:, (;~F~ 4~'~;34 c)O ~;o0 nO n 3 1 1 4 6e O0000nO000 i4.~,~7 $]GC.TDTP 2.964 3a.149 SBRF.TDTP 32.!97 ~0096.09~ TC~F.TDT~ J, 5~ 17.885 "1796.6 .{ o T~Cf .TDT~ 293~.58~ 17q.252 FPAC.TDTP 50.320 2~.3bg SI~C,rDTD 0.~77 30.7'70 SBNF.TDTP 34.56¢ ~1o17.~2~ TCAF.TDTP 7006.546 3nqO.?~q TSCF,TDTp 1~1g.54! ~47.~3 VBAC.T~Tm 33.609 $IBH.TDTP TDBT.TDTP TC~D.~D~P G~C~.TD?P TPHT.TOTP TCND.TDTP I~ND.mDTP GPCU.TDTP 2046,655 -999.250 39 770 18757 176 1978:015 -999,250 av~raUe ~sss t f~r all eI e~ited Passes for Gamma Ray amd bac~rouDd other curves, curves, counts; arithmetic average PPLP 50-0 20' ~ -7 FSL a, 106_~' 34 well Name AP! Sofia! Number Field Location Section TOWDSbfD County State or Province ~itr~ess ~ame Service Order Dumber Permanent ~atum Elevation of Permanent Datum LoG geasured From ADore Permanent Datum ~levation of Kelly Busbin~ ~levatioD of Ground Level Total DePth - Driller Total. DePth - Lo~ger Orillln~ F],u~d TYpe TI6T Cort~,cteH ~'~crehole 5inma ~,orebo]e ~,i-~a - i~r detector 'tb7 Ooroslty TO~al CO~,~ts ~r'~]VZecl - near d~t~ctor 7'or'al cour~ts a~a1vzer~ - ~r Netector TOfa!, Cant ,~r~ COUF,tS - ,~ear detector ~i'oe~ Ca[~.nr~ Co,'l,ts - far dectector TOte] qel["cte~l Cotlnt~ - ~.~emr ISC~' lota~ ,~e]ecte,~ C Es ar I~'t,~? ~'.n~iasfic cour~t rate - near detector I~F~ tn~last~c count rat~ - t~r detector F~AC ~c<c, reu~ Ccu~L R~te - Far r~etector G~Cp ~;.~.n'~a ~, ~n C~St~.,q l~p:~ f! LOC. TYP T3C>:. pt,' Ay F, ACK, p~AV eRC'~q, q-t~,J p I ~, .730 SlGC. Pi,1AV ~ 911 STBH.PNAV 3~.75o SBHF.P"AV 29~732 TPHI 40583.~97 TCaF,Pt,'AV 15542, ~005.770 TSCF. pt,~aV 3066.219 INicB.PNaV , G ,,CU. P~AV 25O -qgo.2bn $IGC.P~AV -099.250 -090.250 KBHF.P~,IAV -999.P50 TPHT.PNAV -~99.2b0 TCAF.PNAV -09q.950 ~CND.DNAV -q99.250 TSCF.P~IAV -999.~50 INblD.PNAV ~Q.71q PbaC.p~hv 27.7b~ 32.~99 25203.461 2097.263 -999.250 -999 250 -909 2~0 -909~250 -999.250 **** FTL~' FTL, F S~Rvtch VFRflrnL ~X ~F'C bIZi~ FTbF 'rfPt : 0,~_/11/ 9 FILF T D q" P '):F]f,r, ~'r~i~G (TOP S<[~P DEPTH 1(371 I .o 13-JUL-9~ 0.0 1800.0 files: raw hacK~roun~ pass in last fi 0.5 ! S~r' Pb~ CTM F~5~ ~ $1 CPS N"'D~' rS1 C~S A~h~ r-~$1 CpS AnN~ PSl CPS 8TGC P5! CTM IF AT oS 1 TC%~.~ PSi CPb y('/.r D~I C1~5 T r t" n - ,:, i (' t:' APl APl ~PT VILK NU~ NU~b SIZE REPR PROCESS :;---;;; .......................................... ; .......... oO o 5 1 i 4 6R () uoOO0000 or, o 09 0 5 1 1 4 OR O0000nO000 000 O0 t) 5 1 1 4 6q 0000000000 Ot, O O0 O ~ 1 1 4 6g OOO0000000 OO(: PO 0 5 1 1 4 69 O000OOOOO0 OhO ~0 r, 5 1 I 4 6g O0000flO00O uP(; r,O n 5 I I 4 68 O00~O00000 (:('0 nU 0 ~ i 1 4 68 O0.Oono000 0o~' ,)o n 5 I 1 4 68 OqOOO00000 OOC' nO o 5 1 I 4 6fl O00OOOO000 One 0~, o 5 1 1 4 6~ 0000000000 O{~g, oV o 5 1 i 4 68 00000000()0 O("fi n{~ 0 5 1 1 4 68 0000000000 · :) 0~ O0 0 5 1 1 4 6P O0000OOO00 00{: 0(' n 5 1 1 4 6R 0000000000 ,~o~ n~, 0 5 1 1 4 68 OOO0000000 u(',) cO 0 5 I 1 4 6q 0000000000 00", .... ~(: 0 q 1 1 4 6R O00000UO00 ~, ~q t 't 4 ~' 0 ., o 0 P 0 n 5 1 I 4 68 000000000 ~ t c'<;q4 ~') VCO ('(~ O 5 I 1 4 bR O0000OO000 ~; ~ t, ~,'~ ~O ,:;cu Ot~ 0 q 1 I 4 6~ 000~000000 8~,3q a(:. t~nu nO 0 ~ I 1 4 bP 000000000~ be, t, $1G!~.F%I z2.007 STDT.P$! 66.000 TPHI.PSI r; e _~, SFFP.PGI 27.725 SFND.PS1 22 725 ~BHV.PS! ~:,63 aFaO,pSl 21 .ago A?~,'D. PS 1 12.222 STGC.PBf 214 '~'qnF. P.~ 1 1.7~7 Tk;'AT. PS1 2.032 SOST.P~;1 7~,2' TCFU.Pgl 9016.06:2 *5Cl~,Pgl 9026.920 'YSCF.DS! U(';~ S,.t,,";. PS 1 zz.6U3 ,~TnT.PSI 156.000 TPHT.PS1 )'~1 gF~'~, p~ ~ 25.¢6~ SFPg. PS1 27.I66 SBHF.PS~ '~nb ~'t'~T.PS 1 ln.37o ~!TDT. PSI 29.844 AFFD,PS] 3ei a ~'r:r~, PSI 415.114 ABUD.PS1 411.168 8IGC.PS1 4t, b ': ,qnF. PG,l, 1.OB5 TRAr. PS1 !.~05 5hfT,P$1 '~ 9 v~SaC. PSI 27.969 ~CAN.PS1 23813.512 TCAF.P81 ;,7~ TCF'D. PSI 6P(,'q, ~k)7 ~SC~.PSl 4992.~99 TSC~,PS1 b4~ Tt';WD, ['~1 4(:0.1 O0 Gt{. PS1 I 17.625 TWNS.PS1 58,110 116,163 30,698 0.000 3,412 17646.309 3283.034 1145.0o0 32.207 31.451 111,989 2,9~3 1.042 a764,934 ~8~7.714 17~0.000 fileS; raw bacKcrouPd pass in last 13-J[ib-9! C.P 11259.0 0.o 2732.n (,q~.,Ft, (F, br;) t LT¢ P'nk;,~ AT F~'~ PPU~HO~: BaY AnI,~, 50-02r~-2029¢4.0{~ F'[ 2~' FSI, SFC'~' Cr~b~~ t', r'~b~ T ~, I., "" ~ KFLI Y Field ~PI Serial humber Field I,ocat lon Section Township County State or Province taat lOD Witness ~,' am e servtce Order Permanent datum WlevatJoD of Permanent Datum Loe ~eas.red From Above Per,arian? natum ~levat~oD of Kelly Flevat~on of Ground Level ST6~? $ioma (,,eutr~n Capture Cross S~~',' Po~e~,o~e Df~,..~,~a - ',~ar 4erector A~Fn r]~r~l~t,~rJ~ horehole -- F~r 4etector AFar, ~,mr~l~t,~,'Je for~;~at.~o~ - near detector (TDTP) An,~:P nmnlttude ;'%orehole -- near ~etector (iDTP) STBP corr~cte~ norehole BaC~' nac~nrnurd Count ~ates - u;ear Detector FBA~ nac~'~roor~'~, Count kate - Far Detector TCA~; 'total cout,~s ,~r,a]vze4 - near d-rector TC~,~m motat ce~tur~ con,uts - ae~r detector TCFD ~ota] C~r)ture CouDts - Jar dectector TSC~ "'ot;~] fe!ect~u CoijDt$ - ~ear [,erector I~,~r, Tn~las~ic cour~t rate - n~r deteetnr I~F'n 'tn~l~stic co,,n~ ~ate - tar detector G~ ~Pl-rorrecte4 ca~,n,a PaV S~q~' ~52 C'I 4F~0~4 TP~,T ~>b2 8P5] PSP Ci~ TCh~~ PS? CPb F' A[~I ~, 'F' I APl APT ~'Ibg N ti ~ }3 ~:U'B $I~E REP ~ ~ "' Sa~~ C ' 2°.327 ,q, TI~T. PS 2 66.~00 TPNI.P82 to.?O6 ~TBT,PS2 53.280 425,133 5~Pi), PS2 4,4] .059 ! .398 TRAT,P~2 ~.~23 8DSI.P82 5 A. 5,~(,,~ TCA~4. P82 47718 055 TCAF.P6~ '~976,~5 wi~C~;. PS2 8~57~180 TSCF,P82 492.r~52 ~.P82 !,OJ .18fl 2f~. 5q6 sTr',£. P$2 6fi.00o ~PHI.P$2 2R.6P6 SFh~L), PS2 2~.546 SgHP.P59 7.6~ NTDI.Pg2 24.562 AFFD. P,S2 3~,l.2ba AB~eg. PS2 387 ~15 8~GC.P5~ !.n~',1 ~RA'f/.PS2 2~-34 SOSl.PS~ 3~.~,~3 ~CAd. PS2 19127.q84 TCAF.PS~ 39~. r~79 ' GR.PS~ 67:688 TE?-}8. P62 54,171 28,61,8 111,380 0o000 1,073 16508.121 2882.195 1430.000 53,231 36,405 93,006 ?:ooo 549 5975.0~7 1271,559 16~0,000 SI)?.~i~('~ .~.' ¢, ~i,..t'.'~, ff.f 'J'rl.~'~ DfjI ~;, J F iD Ff. dT(; ¢Li,~'IT"IV 13 -JUL-9 ~ CP 3t~.2 ~1265.0 11250.0 18no.o 2737.o FAr CCtv.,''~* ;'~F; bn,,~ ;3C,~;,c; {CPS)~ 0 C~ PCN A~¢ASKA, l:~f.. Company Name Well Name APT Serial ~qumber ~Ield Location Section TownsDiD County State or Province Nation witness Name Service rlrder Number Permanent datum mlevatloD of Permanent Datum bod ~easured From ADOre Permanent Datum Elevation nf Kelly Bt)shlDq Elevation of Ground bevel Total l~eDth lller Total Pecth - t, oqger 6YG" ~i,~,aa (~.euti*or Cat,tdre Cross Sectior,) Sqt)~' St~t,,5 of TL'r TPhT TL,,? Poro~if'v 5~t~n ~i~,a fcr~,,;~tlon - far detector SP~~ qi,~,':~ for~;:atJo~ - near detector 8n~',~ ~oreho]e St,;~ - ~,oar ~etector NT[.,T ;.~e~r Tr~'~ d~u-,t /;:ate AVFD Amml!tuoe forn,ation -- far detector ('iDTP) A~FD nmplit~.:{oe horehnle -- Far (~et'ector (TDTp) AFt''n ~,:~:~tft,~,3e fore, at!On - near d~tector fTDTP) A~:,~P ~'~l~tvde qore~o~e -- ~ear detector (i'DTP) STBt' Corr~cte~ f~Oreho] e B~,CF nack'~rou~., Co~t ~ates - ,'~ear netecto~ FP~c aackerou~,O Count Rate - Far ~etector Teat,' 'rota~ tour, ts anal vze~ - ~ear detector 'I'CA~ "'oral. oOt~,t5 aqalvzed - far detecter T~LiP Total car2t,]re coder, ts - .'~eo~ de~ector TCFn To~a! c~r~tnre tort, ts - far c~ectector T~Cw 't OtiS! ,Ce1 ecte.J Cotlnts - Near D~tector TSCr ~'ot/e! Select~'~ Color, ts - F~.~r Detector tn~last~c ~ot]r~t ~ee - far ~et~ctor S~,Ir f ~ce r'cr ~,r,r~l i t ucc C1' PILE ~!U~:t~, N IJI'~B SIZE REPR PEL}CESS h~,, L3 S5'~P ELEM CODE (HEX) 7 i 1 4 b8 O0000oO000 7 1 I 4 8~ ooononOOOn .... .............................................................................. T~C Cpb 4b~, ~,; r~ Of'u O0 ~ 7 i I 4 ~ '1'5 C ~ n53 CPS 4 ~:., ~.~,~ OPO O0 o 7 1 ~ 4 6~ 0000000000 I~,Fr' PS~ CPS ~8P:~4 qc, t,O0 O0 e 7 1 I 4 6P O0000nOeOo G~ PS~ G~PT 4~ ~ y 3,~ 0,) O(:'0 OU 0 7 I 1 4 68 t)O0000000O tFr,,~ P53 r,,a ,t~;~,)3,~ n) ~{~ O0 ~ 7 I 1 4 68 0OOO000000 CCI, nS3 V a ,,; g ~'; ~ q r; ) oO,j nO 0 7 I 1 4 OP OOOO(~O0000 I~n:PS3 ~q. ~;13 SF'Ei_~. PA 3 22.020 S~Hk.PS3 41.~. 37 FID'~'.~3 i,a.?b3 NTnT.PS] 43.004 AFFD.PS3 AnVr'.a53 122.~ A f'~'~ i;'. PS 3 ~2P.370 abtvp. PS3 408.427 S~GC.FS~ SlPr'. ~53 ,41.037 t~4OF. Pa3 I .104 TF, l'i, Pti3 ] .977 S~Sl,PS3 B~CV PS~ 176.,.<75 F~iAC.P83 52.990 TCAh.PS3 4226~.703 TCAF.DS3 TCt,}D [ P~ 3 244~b.34,, '~(:FC:,. ~$ 3 ~1.59.9(3~ TSCN.PS3 7826.910 TSCF.PS3 l~'gr.nS~ 71~.535 T.'wU.P~3 420. ~,55 39.598 34.2~8 84.2~6 4.993 15~R4.650 2941.784 14~5.000 5q-029-20790-00 * ALASKA COMPUTING CENTER * . ............................ . ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA WELL NAME : D.S. 06-07 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292029900 REFERENCE NO : 98391 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/07/31 ORIGIN · FLIC REEL NAME : 98391 CONTINUATION # : PREVIOUS REEL : COF~IENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-07, API# 50-029-20299-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/31 ORIGIN · FLIC TAPE NAME : 98391 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-07, API# 50-029-20299-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: D.S. 06-07 API NUMBER: 500292029900 OPERATOR: ARCO Alaska LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 31-JUL-98 JOB NUMBER: 98391 LOGGING ENGINEER: C Yon OPERATOR WITNESS: A Worthingto SURFACE LOCATION SECTION: 2 TOWNSHIP: iON RANGE: 14E FNL: FSL: 20 FEL: 1065 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 64. O0 DERRICK FLOOR: 63. O0 GROUND LEVEL: 32.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 12. 250 9. 625 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 21-AUG-78 LOGGING COMPANY: SCHLUFIBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 11220.0 11219.0 11213.0 11206.0 11204.0 11199.0 11198.5 11192.0 11188.5 11185.0 11184.5 11177.0 11170.0 11168.5 11167.5 11166.5 11166.0 11162.5 11160.0 11155.0 11143.0 11134.0 11118.0 11117.5 11115.0 11114.5 11105.0 11104.5 11088.0 11078.5 11078.0 11050.5 11050.0 11033.5 11014.5 11011.5 11001.5 11000.0 10999.5 10996.5 10990.5 10975.5 10975.0 10971.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG 88890.0 88888.5 11220.5 11221.0 11213.0 11213.0 11205.5 11205.5 11203.5 11203.5 11199.0 11199.5 11191.5 11187.5 11187.5 11185.0 11185.0 11178.0 11172.0 11169.0 11169.0 11166.5 11166.5 11163.0 11163.0 11160.5 11155.5 11155.5 11144.0 11144.0 11135.5 11135.5 11118.5 11118.5 11115.0 11115.5 11104.5 11104.5 11088.5 11088.5 11077.5 11077.5 11050.5 11050.5 11034.5 11034.5 11016.5 11016.5 11013.0 11013.0 11002.5 11002.5 11000.5 11000.5 10996.0 10992.5 10976.0 10976.0 10971.5 10971.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10962.0 10961.5 10953.5 10953.0 10950.0 10944.0 10943.5 10941.5 10941.0 10936.0 10932.0 10931.5 10928.5 10926.0 10922 0 10918 5 10915 0 10904 5 10904 0 10892 5 10884 0 10883 5 10879 5 10879 0 10875 5 10871 0 10870 5 10869 0 10868 0 10866.0 10865.5 10860.5 10857.5 10857.0 10852.5 10852.0 10848.5 10848.0 10841.0 10837.5 10837.0 10834.5 10830.5 10823.0 10822.5 10820.0 10817.0 10811.5 10802.0 10801.5 10794.0 10793.5 10788.5 10788.0 10786.5 10785.5 10964.5 10954.5 10951.5 10945.5 10941.0 10937.0 10933.0 10930.0 10927.0 10923.0 10919.5 10915.0 10905.5 10894.0 10885.0 10881.0 10877.0 10872.5 10870.0 10867.5 10862.0 10859.0 10851.5 10847.5 10842.5 10838.0 10834.0 10832.0 10825.0 10822.5 10819.0 10813.0 10804.0 10796.0 10791.0 10788.0 10964.5 10954.5 10951.5 10945.5 10941.0 10936.5 10933.5 10929.5 10927.0 10923.0 10919.5 10915.0 10905.5 10894.0 10885.0 10881.0 10877.0 10872.5 10870.0 10867.5 10862.0 10859.5 10851.5 10847.5 10842.5 10838.5 10834.0 10831.5 10825.0 10822.5 10819.0 10813.0 10804.5 10796.0 10791.0 10788.5 31-JUL-1998 15:21 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 10777.0 10779.5 10776.5 10779.5 10766.0 10769.5 10769.5 10763.5 10766.0 10763.0 10765.5 10760.5 10764.0 10760.0 10764.0 10758.0 10760.5 10757.0 10760.5 10754.5 10757.0 10754.0 10757.0 10750.5 10751.5 10751.5 10744.0 10746.5 10746.5 10733.0 10735.5 10735.5 10726.0 10729.0 10725.5 10729.0 10722.5 10724.5 10725.0 10721.0 10722.0 10720.5 10722.0 10716.5 10718.0 100.0 101.5 101.0 REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S DS 6-07 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAMMA RAY, ALSO PASS #1 NPHI AND THE BCS GAMMA RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11225.0 10515.5 CNTG 11228.5 10515.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA THERE ARE ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) DEPT FT 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: NAME SERV UNIT SERVICE API API API API FILE AU3MB NUMB SIZE REPR PROCESS ID ORDER # LOG T~PE CI.~SS MOD NUMB SAMP ELI~ CODE (HEX) EAH~A CNTG 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1160732 O0 000 O0 0 i 1 1 4 68 0000000000 CFEC CNTG CPS 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1160732 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11350.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS 32.989 DEPT. 10515.000 NPHI. CNTG 50.579 ENPH. CNTG 41.675 CPHI.CNTG NRAT. CNTG 4.340 CRAT. CNTG 4.177 ENRA.CNTG 5.765 NCNT. CNTG FCNT. CNTG 390.124 CNTC. CNTG 1704.551 CFTC. CNTG 409.258 CNEC. CNTG CFEC. CNTG 459.225 GRCH. CNTG -999.250 TENS. CNTG 3365.000 CCL.CNTG GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 47.804 1849.791 2647.592 -0.161 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASSNUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~VlARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11223.5 10541.5 CNTG 11228.5 10541.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11220.0 11215.0 11213.5 11211.5 11209.0 11206.5 11199.5 11197.5 11195.0 11192.0 11190.5 11188.0 11185.0 11182.0 11179.5 11173.0 11170.5 11169.5 11165.0 11162.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88888.5 88888.5 11220.5 11220.5 11214.5 11213.5 11211.0 11208.5 11205.5 11199.0 11199.5 11194.0 11192.0 11189.5 11188.0 11185.0 11181.5 11179.5 11171.5 11172.0 11169.0 11165.0 11163.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 11160.0 11160.0 11158.5 11159.5 11156.0 11155.5 11149.0 11150.0 11146.0 11147.0 11142.5 11144.5 11140.5 11141.5 11137.0 11137.5 11133.0 11133.5 11131.0 11133.5 11128.0 11130.5 11121.0 11120.5 11117.0 11118.0 11115.0 11115.0 11114.0 11114.5 11107.0 11106.5 11102.0 11101.5 11100.0 11099.5 11099.0 11100.0 11094.0 11094.0 11089.0 11088.5 11086.0 11085.5 11083.5 11083.0 11080.5 11077.5 11073.5 11073.0 11072.5 11071.5 11065.0 11065.5 11056.0 11057.0 11049.0 11049.0 11046.5 11047.5 11046.5 11043.0 11044.0 11044.0 11038.0 11038.0 11033.0 11034.0 11025.5 11026.5 11018.5 11020.5 11015.5 11017.5 11014.0 11016.5 11013.5 11015.5 11011.5 11013.0 11010.5 11011.5 11009.0 11010.0 11005.0 11006.0 11004.0 11005.0 10998.5 10999.0 10994.0 10996.5 10990.5 10992.5 10988.0 10988.5 10984.5 10986.0 10975.5 10975.5 10970.0 10970.5 10967.0 10971.0 10961.5 10964.5 10959.5 10961.5 10962.0 10957.5 10959.5 10957.0 10959.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 10955.0 10953.0 10950.0 10947.0 10946.5 10944.0 10941.5 10935.0 10932.0 10931.5 10928.5 10928.0 10926.0 10922.5 10921.0 10919.0 10917.5 10915.5 10911.5 10907.0 10904.0 10902.5 10892.5 10889.5 10883.0 10879.5 10874.5 10868 5 10860 0 10857 5 10855 0 10854 0 10852 5 10852 0 10849 0 10845 5 10843 5 10841 5 10840 5 10836.5 10831.0 10830.5 10829.0 10826.5 10823.0 10819.5 10817.5 10817.0 10815.5 10809.0 10806.0 10802.5 10801.5 1O800.0 10797.5 10954.5 10951.5 10948.5 10945.5 10942.0 10933.0 10930.0 10927.0 10923.0 10920.0 10917.5 10905.5 10903.5 10894.0 10885.0 10881.0 10876.5 10870.0 10859.0 10855.0 10852.5 10847.5 10844.0 10842.5 10838.0 10832.0 10822.0 10819.0 10804.0 10801.5 10957.0 10954.0 10951.5 10948.5 10945.5 10936.0 10933.5 10929.5 10927.0 10922.0 10915.0 10913.0 10907.0 10903.0 10894.0 10891.5 10881.0 10870.0 10862.0 10859.5 10853.0 10851.0 10847.5 10845.5 10842.5 10831.5 10830.0 10828.0 10824.5 10819.5 10816.5 10811.5 10808.5 10802.5 10800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 10 10793.5 10796° 0 10790.5 10790.0 10792.5 10789.0 10785.5 10782.0 10780.0 10782.0 10778.0 10769.5 10773.0 10767.0 10769°5 10763.0 10765.5 10760.5 10764.0 10760.0 10758.0 10760.5 10754.5 10756.5 10752.5 10751.5 10753.5 10750.5 10751 . 5 10746.5 10748.0 10745.0 10744.5 10746.5 10741.5 10744.0 10739.5 10739.0 10742.0 10736.5 10739.0 10733.5 10735.5 10733.0 10726.5 10729.0 10725.0 10722.5 10725.0 10721.0 10720.5 10722.0 10716.5 10718.0 10715.0 10716.5 10714.5 10711 . 5 10713.0 10710.0 10709.0 10710.5 10706.5 10704.5 10702.5 10703.5 10700.5 10702.0 10699.5 10700.5 10694.5 10696.0 10688.5 10690.5 10685.0 10686.0 10681.0 10682.5 10677.5 10679.0 10673.5 10675.0 10666.5 10667.5 10663.0 10663.5 10656.0 10655.5 10647.0 10648.5 10645.5 10647.0 10642.5 10644.5 10796.0 10792.5 10791.0 10788.5 10783.5 10780.0 10763.5 10756.5 10747.0 10742.0 10735.5 10728.5 10725.0 10722.0 10715.0 10711.0 10707.5 10705.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 11 10639.5 10641.0 10635.5 10637.0 10627.0 10628.0 10623.0 10624.0 10614.5 10616.5 10608.5 10610.0 10603.5 10602.0 10597.5 10597.0 10591.5 10592.0 10586.0 10587.0 10578.5 10578.5 10574.5 10573.0 10562.0 10563.0 10558.0 10559.5 10554.0 10556.5 10549.0 10550.5 10544.0 10545.5 100.0 101.5 $ 101.0 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160732 O0 000 NPHI CNTG PU-S 1160732 O0 000 ENPH CNTG PU-S 1160732 O0 000 CPHI CNTG PU-S 1160732 O0 000 NRAT CNTG 1160732 O0 000 CRAT CNTG 1160732 O0 000 F2VRA CNTG 1160732 O0 000 NCNT CNTG CPS 1160732 O0 000 FCNT CNTG CPS 1160732 O0 000 CNTC CNTG CPS 1160732 O0 000 CFTC CNTG CPS 1160732 O0 000 CNEC CNTG CPS 1160732 O0 000 CFEC CNTG CPS 1160732 O0 000 GRCH CNTG GAPI 1160732 O0 000 TENS CNTG LB 1160732 O0 000 CCL CNTG V 1160732 O0 000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11228.500 NPHI. CNTG 35.724 ENPH. CNTG 37.838 CPHI. CNTG NRAT. CNTG 3.631 CRAT. CNTG 3.362 ENRA. CNTG 5.423 NCNT. CNTG FCNT. CNTG 550.647 CNTC. CNTG 1794.990 CFTC. CNTG 551.459 CNEC. CNTG CFEC. CNTG 465.897 GRCH. CNTG -999.250 TENS. CNTG 3711.000 CCL.CNTG DEPT. 10541.000 NPHI.CNTG 45.921 ENPH. CNTG 46.152 CPHI.CNTG NRAT. CNTG 3.800 CRAT. CNTG 3.922 ENRA. CNTG 6.142 NCNT. CNTG FCNT. CNTG 422.440 CNTC. CNTG 1606.297 CFTC. CNTG 433.541 CNEC. CNTG CFEC. CNTG 425.644 GRCH. CNTG -999.250 TENS. CNTG 3424.000 CCL.CNTG 32.589 1847.925 2526.566 -0.018 39.881 1644.760 2614.307 0.059 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUFk~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11223.5 10586.0 CNTG 11228.5 10582.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 11223.5 11221.5 11219.0 11218.0 11216.5 11211.0 11208.0 11206.0 11204.5 11200.0 11197.0 11194.5 11191.0 11190.0 11187.0 11186.5 11185.0 11181.5 11175.0 11173.5 .......... EQUIVALENT UNSHIFTED DEPTH ........... GRCH CNTG 88888.5 88888.5 11224.0 11222.0 11220.5 11218.0 11216.5 11210.0 11211.0 11208.5 11205.5 11204.0 11200.0 11199.0 11195.0 11194.0 11191.5 11189.0 11187.5 11186.0 11185.0 11181.5 11178.5 11173.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 14 11168.0 11169.0 11167.5 11169.0 11163.5 11164.5 11162.5 11163.0 11160.0 11160.0 11158.5 11159.0 11154.0 11155.5 11146.0 11147.0 11145.5 11146.5 11141.5 11143.0 11140.5 11142.0 11137.0 11137.5 11132.0 11133.5 11130.0 11130.5 11118.5 11120.5 11117.0 11117.5 11115.0 11115.5 11114.0 11116.0 11110.5 11111.0 11104.5 11104.0 11099.0 11099.5 11098.5 11099.5 11091.5 11092.5 11089.5 11090.0 11085.5 11085.5 11084.5 11085.0 11082.5 11083.0 11073.0 11073.0 11072.5 11072.0 11065.5 11065.5 11060.0 11062.0 11056.0 11057.5 11051.0 11051.0 11046.5 11047.0 11047.0 11037.0 11037.0 11033.5 11034.5 11033.5 11030.0 11030.0 11018.5 11020.0 11013.5 11016.5 11013.0 11015.5 11011.0 11013.0 11009.5 11011.0 11004.5 11005.5 11001.5 11002.5 10998.0 10999.0 10994.5 10995.5 10990.0 10992.0 10987.5 10988.5 10984.0 10985.5 10978.5 10980.5 10977.0 10977.5 10971.0 10971.5 10969.0 10970.5 10964.0 10967.5 10961.5 10964.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 15 10959.0 10957 0 10954 5 10952 5 10949 5 10947 0 10943 5 10937 0 10935 5 10931 5 10925 5 10921 0 10915 5 10914 5 10912 0 10906.5 10904.0 10892.0 10889.5 10884.0 10882.5 10879.0 10876.5 10874.5 10874.0 10870.5 10868.0 10863.5 10862.5 10859.5 10857.0 10854.0 10848.5 10844.0 10843.5 10840.0 10839.5 10831.5 10828.5 10822.5 10817.5 10816.5 10814.5 10811.0 10808.5 10802.5 10802.0 10792.5 10790.0 10788.0 10786.0 10778.5 10769.5 10768.5 10767.5 10951.5 10948.5 10945.5 10938.5 10933.0 10927.0 10919.5 10915.0 10905.5 10894.0 10890.5 10884.5 10881.0 10876.5 10872.5 10870.0 10865.5 10859.0 10855.0 10844.5 10842.5 10834.5 10819.0 10812.5 10804.0 10792.5 10791.0 10788.0 10773.0 10771.0 10962.0 10959.5 10957.0 10954.0 10951.5 10945.5 10936.0 10933.5 10927.5 10922.0 10915.0 10907.0 10894.0 10887.0 10878.5 10874.5 10870.0 10864.0 10862.0 10859.5 10853.0 10847.0 10845.5 10841.5 10830.0 10824.5 10819.0 10816.0 10811.5 10805.5 10796.0 10792.5 10780.0 10772.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 16 10766.0 10763.0 10760.5 10759.5 10757.5 10754.5 10751.5 10750.0 10747.5 10746.5 10744.0 10739.0 10736.5 10732.5 10726.5 10724.5 10722.5 10721.0 10720.0 10714.0 10711 5 10710 0 10708 5 10706 0 10702 0 10699 5 10698 5 10692 5 10690 5 10688 5 10688 0 10684 5 10680 5 10680 0 10673 5 10673 0 10668 0 10666.0 10664 5 10662 0 10658 5 10655 0 10653 0 10649 5 10646.5 10645.0 10644.5 10639.5 10626.5 10616.0 10612.5 10604.0 10585.0 100.0 $ 10765.5 10764.0 10760.5 10756.5 10753.5 10751.5 10748.0 10746.5 10742.0 10738.5 10735.5 10729.5 10725.0 10722.0 10713.0 10710.5 10703.5 10700.5 10694.5 10690.5 10686.0 10682.5 10675.0 10667.5 10663.5 10655.5 10648.5 10647.0 10628.0 10613.5 10605.5 10587.0 102.0 10769.5 10766.0 10763.5 10751.5 10746.5 10742.0 10728.5 10722.0 10715.0 10711.0 10707.5 10700.0 10692.0 10689.5 10682.0 10674.5 10669.5 10666.5 10660.0 10657.0 10649.5 10644.0 10641.0 10614.5 98.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 17 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYINGALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SI'ZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TENS CNTG LB 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1160732 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11228.500 NPHI. CNTG 35.085 ENPH. CNTG 38.616 CPHI.CNTG NRAT. CNTG 3.405 CRAT. CNTG 3.327 ENRA.CNTG 5.494 NCNT. CNTG FCNT. CNTG 550.064 CNTC. CNTG 1884.786 CFTC. CNTG 585.394 CNEC. CNTG CFEC. CNTG 487.955 GRCH. CNTG -999.250 TENS. CNTG 3646.000 CCL.CNTG DEPT. 10582.500 NPHI.CNTG 45.648 ENPH. CNTG 43.234 CPHI.CNTG NRAT. CNTG 3.644 CRAT. CNTG 3.907 ENRA.CNTG 5.899 NCNT. CNTG FCNT. CNTG 414.823 CNTC. CNTG 1690.842 CFTC. CNTG 446.714 CNEC. CNTG CFEC. CNTG 449.898 GRCH. CNTG -999.250 TENS. CNTG 3463.000 CCL.CNTG 32.034 1928.981 2680.824 -0.024 41. 220 1735. 620 2654. 034 -0.335 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCRE3~ENT 0.5000 PASSES INCLUDED IN AVERAGE LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 19 LDWG TOOL CODE PASS NUMBERS CNTG 1, 2, 3, $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 EIgRA CNAV 1160732 O0 000 O0 0 4 1 I 4 68 0000000000 NCNT CNAV CPS 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 2O NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CFEC CNAV CPS 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1160732 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11228.500 NPHI.CNAV 35.336 NRAT. CNAV 3.512 CPHI.CNAV CRAT. CNAV 3.341 ENPH. CNAV 37.297 ENRA. CNAV 5.372 NCNT. CNAV FCNT. CNAV 548.352 CNTC. CNAV 1837.436 CFTC. CNAV 568.383 CNEC. CNAV CFEC. CNAV 482.953 GRCH. CNTG -999.250 32.242 1889.447 2593.808 DEPT. 10515.500 NPHI. CNAV -999.250 NRAT. CNAV -999.250 CPHI.CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 ClTTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 61.907 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE i~IMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 21 FILE SUMMARY VEArDOR TOOL CODE START DEPTH CNTG $ LOG HEADER DATA DATE LOGGED: 11255.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 10513.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: 11 -MAY-98 8C0-609 1804 il-MAY-98 11240.0 11242.0 10584.0 11228.0 TOOL NUMBER ........... SGC - SA 12.250 Production Fluids MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COU19T RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 22 IFEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 24000 REMARKS: Thank you for using Schlumberger This log was depth referenced to a SWS BHC log, dated 21-Aug-1978 Ail depth correlation material provided by co. rep. Logging Program: Logged in a SANDSTONE MATRIX Logging interval is (PBTD) 11242' - 10640' THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160732 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1160732 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1160732 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PSi PU 1160732 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1160732 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1160732 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1160732 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1160732 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 23 NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CNEC PS1 CPS 1160732 RCEF PSI CPS 1160732 RCENPS1 CPS 1160732 RCNT PS1 CPS 1160732 RCFT PS1 CPS 1160732 CNTC PS1 CPS 1160732 O0 CFTC PS1 CPS 1160732 O0 NPOR PS1 PU 1160732 O0 GR PS1 GAPI 1160732 O0 TENS PS1 LB 1160732 O0 CCL PS1 V 1160732 O0 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11255.000 NPHI.PS1 30.334 ENPH. PS1 33.579 TNPH. PS1 TNRA.PS1 3.067 RTNR.PS1 3.200 ENRA.PS1 5.020 CFEC. PS1 CNEC. PS1 2570.715 RCEF. PS1 511.260 RCEN. PS1 2349.072 RCNT. PS1 RCFT. PS1 640.123 CNTC. PS1 1975.774 CFTC. PSi 658.542 NPOR.PS1 GR.PS1 28.059 TENS. PSI 2242.000 CCL.PS1 -0.022 DEPT. 10513.500 NPHI.PS1 50.579 ENPH. PS1 41.675 TNPH. PS1 TNRA.PS1 4.177 RTNR.PS1 4.696 ENRA.PS1 5.765 CFEC. PS1 CNEC. PS1 2647.592 RCEF. PS1 432.305 RCEN. PS1 2354.155 RCNT. PS1 RCFT. PS1 405.253 CNTC. PS1 1704.551 CFTC.PSi 409.258 NPOR.PS1 GR.PS1 61.907 TENS.PSi 3405.000 CCL.PS1 -999.250 28. 640 512. 095 2081. 653 28. 640 47.804 459.225 1806.110 47.507 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : OOICO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 24 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG 11252.0 $ LOG HEADER DATA STOP DEPTH .......... 10538.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : il-MAY-98 8C0-609 1804 Il-MAY-98 11240.0 11242.0 10584.0 11228.0 TOOL NUMBER ........... SGC-SA CNT-G 12.250 Production Fluids LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 25 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a SWS BHC log, dated 21-Aug-1978 Ail depth correlation material provided by co. rep. Logging Program: Logged in a SANDSTONE MATRIX Logging interval is (PBTD) 11242' - 10640' THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 26 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 TATRAPS2 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 EIVRAPS2 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1160732 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11252.000 NPHI.PS2 39.943 ENPH. PS2 33.579 TNPH. PS2 TNRA.PS2 3.594 RTNR.PS2 3.750 ENRA.PS2 5.020 CFEC. PS2 CNEC. PS2 2570.715 RCEF. PS2 511.260 RCEN. PS2 2349.072 RCNT. PS2 RCFT. PS2 511.260 CNTC. PS2 1849.448 CFTC. PS2 525.972 NPOR.PS2 GR.PS2 16.835 TENS.PS2 2345.000 CCL.PS2 -0.010 DEPT. 10538.000 NPHI.PS2 46.112 ENPH. PS2 47.114 TNPH. PS2 TNRA.PS2 3.932 RTNR.PS2 3.840 ENRA.PS2 6.220 CFEC. PS2 CNEC. PS2 2661.494 RCEF. PS2 396.965 RCEN. PS2 2518.038 RCNT. PS2 RCFT. PS2 412.422 CNTC. PS2 1615.852 CFTC. PS2 419.831 NPOR.PS2 GR.PS2 73.786 TENS.PS2 3431.000 CCL.PS2 -999.250 36.772 512.095 1948.558 36.772 42.297 427.900 1740.926 41.237 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 27 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE . FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUMFLARY VENDOR TOOL CODE START DEPTH ........................... CNTG 11250.5 $ LOG HEADER DATA STOP DEPTH 10583.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMFLA RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): il-MAY-98 8C0-609 1804 il-MAY-98 11240.0 11242.0 10584.0 11228.0 TOOL NUMBER SGC- SA CNT-G 12.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 28 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : Production Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NE~L~ COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a SWS BHC log, dated 21-Aug-1978 Ail depth correlation material provided by co. rep. Logging Program: Logged in a SANDSTONE MATRIX Logging interval is (PBTD) 11242' - 10640' THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 29 TYPE REPR CODE VALUE .............................. 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SI'ZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH PS3 PU 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 RCEN PS3 CPS 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1160732 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11250.500 NPHI.PS3 31.208 ENPH. PS3 36.606 TNPH. PS3 TNRA.PS3 3.115 RTNR.PS3 3.250 ENRA.PS3 5.309 CFEC. PS3 CNEC.PS3 2762.858 RCEF. PS3 519.562 RCEN. PS3 2524.648 RCNT. PS3 RCFT. PS3 519.562 CNTC. PS3 1624.250 CFTC. PS3 534.511 NPOR.PS3 GR.PS3 39.916 TENS. PS3 2694.000 CCL.PS3 -0.023 29.230 520.409 1711.292 29.230 LIS Tape Verification Listing Schlumberger Alaska Computing Center 31-JUL-1998 15:21 PAGE: 3O DEPT. 10583.500 NPHI.PS3 TNRA.PS3 3.907 RTNR.PS3 CNEC. PS3 2654.034 RCEF. PS3 RCFT. PS3 419.564 CNTC. PS3 GR.PS3 63.205 TENS.PS3 45.648 ENPH. PS3 4.286 ENRA.PS3 452.308 RCEN. PS3 1690.842 CFTC.PS3 3456.000 CCL.PS3 43.234 TNPH. PS3 5.899 CFEC. PS3 2402.359 RCNT. PS3 446.714 NPOR.PS3 -999.250 41.220 449.898 1788.546 41.034 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/31 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/07/31 ORIGIN : FLIC TAPE NAME : 98391 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-07, API# 50-029-20299-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/07/31 ORIGIN : FLIC REEL NAME : 98391 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-07, API# 50-029-20299-00 * ALASKA COMPUTING CENTER . . ....... SCHLUMBERGER . COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 6- 07 FIELD NAME : PRUDHOE BAY BOROUGH .. NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-20299-00 REFERENCE NO : 973 $ 8 RECEIVED AUG 2 8 199T ~mska o(~ & Gas CO, So Commi~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/08/26 ORIGIN : FLIC REEL NAME : 97358 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-07, API# 50-029-20299-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/08/26 ORIGIN : FLIC TAPE NAME : 97358 CONTINUATION # : 1 PREVIOUS TAPE : CO~IENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-07, API# 50-029-20299-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 6-07 API NUMBER: 500292029900 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 26-AUG-97 JOB NUMBER: 97358 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: K. St. GE~E SURFACE LOCATION SECTION: 2 TOWNSHIP: iON RANGE: 14E FNL: FSL: 20 FEL: 1065 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 64. O0 DERRICK FLOOR: 63.00 GROUND LEVEL: 32.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 11588.0 47. O0 2ND STRING 5.500 2174.0 17. O0 3RD STRING 4. 500 10378.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER .. 1 PASS NUMBER: 1 DATE LOGGED: 21 -AUG- 78 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 11225.0 11223.0 11221.5 11210.0 11208.0 11200.0 11196.5 11193.0 11188.5 11186.5 11171.0 11169.5 11167.5 11164.0 11161.5 11160.5 11156.0 11154.5 11147.5 11139.0 11131.0 11123.5 11116.5 11116.0 11112.0 11104.5 11098.5 11087.0 11068.5 11067.0 11066.5 11060.0 11051.5 11044.5 11042.5 11036.0 11024.5 11021.5 11020.5 11016.0 11013.5 11012.0 11001.5 10998.0 .......... EQUIVALENT UNSHIFTED DEPTH ........... GRCH CNTG 88886.0 88888.0 11208.0 11205.5 11199.0 11191.5 11185.0 11168.5 11166.5 11163.0 11161.0 11155.5 11146.0 11115.0 11103.5 11086.0 11067.0 11064.5 11058.5 11051.0 11045.0 11034.5 11020.5 11016.0 11000.0 11225.0 11222.5 11220.5 11195.5 11187.5 11171.0 11163.0 11160.0 11153.5 11138.0 11130.0 11123.0 11115.5 11111.5 11099.5 11066.5 11044.0 11024.5 11020.5 11013.0 11010.0 11000.5 PAGE LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 10993.5 10989.5 10989.0 10986.5 10983.5 10974.0 10968.5 10961.0 10952.0 10951.5 10945.0 10943.0 10941.5 10934.0 10929.0 10927.5 10923.0 10910.5 10907.5 10906.5 10902.5 10896.0 10894.5 10894.0 10891.0 10882.5 10879.0 10878.5 10872.5 10869.5 10862.0 10861.5 10859.5 10859.0 10851.5 10846.5 10842.0 10841.5 10835.5 10832.5 10832.0 10819.5 10818.0 10810 5 10810 0 10794 5 10790 0 10787 0 10782 0 10779 5 10768.5 10765.5 100.0 $ 10994.0 10990.0 10984.0 10976.0 10970.0 10961.0 10951.5 10946.0 10942.0 10941.0 10929.5 10927.5 10911.5 10905.5 10893.5 10882.0 10879.0 10872.5 10870.0 10862.0 10859. 0 10851.5 10842.0 10835.5 10832.0 10819.0 10810.0 10796. 0 10791. 0 10782.5 10779.5 10771.0 102.5 10992.5 10989.5 10987.5 10984.5 10961. 0 10951.5 10945.5 10933.5 10923.0 10907.5 10903.5 10897.0 10894.5 10891.0 10879. 0 10872.5 10862.0 10859.5 10847.5 10842.5 10832.0 10819.0 10810.0 10788.0 10770.0 10766.0 100.5 PAGE: REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 DATA ACQUIRED ON ARCO ALASKA'S D.S. 6-07 WELL. ONLY PASS #2 EPITHERMAL DATA WAS ACQUIRED DUE TO TOOL PROBLEm. THE DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT CASED HOLE PASS #1 GR TO OPEN HOLE BCS GR, AND PASS #1 NPHI TO OPEN HOLE BCS GR CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE I~JMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~FL~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11229.0 10750.0 CNTG 11234.0 10750.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH ........... GRCH CNTG REMARKS: THIS FILE CONTAINS CNTG PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. THE CNTG EPITHERMAL DATA WAS ACQUIRED ON THIS PASS DUE TO TOOL PROBLEM. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PA GE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500751 O0 000 O0 0 1 1 1 4 68 NPHI CNTG PU-S 500751 O0 000 O0 0 1 1 1 4 68 CPHI CNTG PU-S 500751 O0 000 O0 0 1 1 1 4 68 NRAT CNTG 500751 O0 000 O0 0 1 1 1 4 68 CR~T CNTG 500751 O0 000 O0 0 1 1 1 4 68 NCNT CNTG CPS 500751 O0 000 O0 0 1 1 1 4 68 FCNT CNTG CPS 500751 O0 000 O0 0 1 1 1 4 68 CNTC CNTG CPS 500751 O0 000 O0 0 1 1 1 4 68 CFTC CNTG CPS 500751 O0 000 O0 0 1 1 1 4 68 GRCH CNTG GAPI 500751 O0 000 O0 0 1 1 1 4 68 TENS CNTG LB 500751 O0 000 O0 0 1 1 1 4 68 CCL CNTG V 500751 O0 000 O0 0 1 1 1 4 68 GR BCS GAPI 500751 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 11350.000 NPHI.CNTG -999.250 CPHI.CNTG -999.250 NRAT. CNTG CRAT. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG CFTC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS 32.989 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: DEPT. 10710. 000 NPHI. CNTG -999.250 CPHI. CNTG CRAT. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG CFTC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG GR.BCS 240.280 -999.250 NRAT. CNTG -999.250 CNTC. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS I~JMBER : 2 DEPTH INCREMENT: O . 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11229.0 10750.0 CNTG 11234.0 10750.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88884.5 88887.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 11234.0 11233.0 11230.0 11229.5 11227.0 11225.0 11220.0 11218.5 11217.5 11214.0 11213.5 11210.0 11211.0 11208.0 11210.0 11208.0 11199.5 11199.0 11197.0 11195.0 11195.0 11193.0 11191.0 11189.5 11187.5 11189.0 11187.5 11184.5 11183.5 11178.5 11178.5 11171.0 11171.0 11169.5 11168.5 11169.0 11166.5 11164.5 11163.0 11162.0 11161.0 11160.5 11158.0 11157.0 11151.0 11149.0 11149.0 11146.5 11136.0 11134.5 11134.0 11133.0 11131.5 11130.0 11129.5 11128.5 11126.0 11124.0 11119.5 11118.0 11118.0 11117.5 11115.5 11114.5 11113.5 11107.0 11106.5 11095.5 11095.5 11094.5 11092.0 11086.0 11086.0 11076.0 11076.0 11069.5 11068.5 11065.0 11067.0 11060.0 11060.0 11051.5 11052.5 11047.5 11046.5 11037.0 11037.0 11035.5 11034.5 11018.0 11018.0 11016.0 11015.5 11014.0 11013.0 11013.5 11013.5 11012.0 11009.5 11001.5 11000.5 10996.5 10995.5 10994.0 10994.0 10993.5 10993.0 10986.5 10987.0 10983.5 10984.0 10979.5 10980.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 10971.0 10970.0 10961.5 10952.0 10948.0 10945.5 10941.5 10940.5 10937.0 10934.0 10933.5 10930.5 10923.0 10920.0 10912.5 10897.0 10895.0 10894.0 10891.0 10885.0 10879.5 10877.0 10872.5 10870.5 10865.0 10862.5 10862.0 10860.0 10859.5 10847 0 10842 5 10839 5 10837 5 10832 5 10824 5 10819 5 10813 5 10811 0 10805.0 10795.5 10790.5 10782.0 10776.5 10771.5 10765.0 10762.5 10759.0 10757.0 10756.5 10754.0 100.0 $ REMARKS 10971.5 10961.0 10951.5 10945.5 10940.5 10933.5 10930.5 10893.5 10890.0 10877.0 10872.5 10862.5 10859.0 10842.5 10839.5 10819.5 10815.0 10810.5 10806.0 10791.0 10782.5 10773.0 10767.0 10759.0 10756.5 102.5 10971.5 10961.0 10951.5 10948.5 10945.5 10940.5 10937.0 10933.5 10923.0 10919.0 10913.0 10897.5 10894.5 10884.5 10879.5 10870.5 10864.5 10862.0 10859.5 10847.5 10837.5 10831.5 10824.0 10805.0 10795.5 10777.5 10766.0 10762.5 10758.5 10756.5 99.5 THIS FILE CONTAINS CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GRCH PASS #2 TO GRCH PASS #1 AND LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: NPHI PASS #2 TO NPHI PASS #1 CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. THE EPITHERMAL CNTG DATA ON THIS PASS ARE AVAILABLE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500751 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 500751 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 500751 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 500751 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 500751 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 500751 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 500751 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 500751 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 500751 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 500751 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 500751 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTC CPS 500751 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 500751 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 500751 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 500751 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 500751 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 10 ** DATA ** DEPT. 11233. 000 NPHI. ClTTG 37. 865 ENPH. CNTG 41 . 891 CPHI. CNTG NRAT. CNTG 3. 597 CRAT. CNTG 3. 480 ENRA. CNTG 5.784 NCNT. CNTG FCNT. CNTG 418.227 CNTC. CNTG 1547.202 CFTC. CNTG 453 . 046 CNEC. CNTG CFEC. CNTG 396. 624 GRCH. CNTG -999.250 TENS. CNTG 3475. 000 CCL. CNTG DEPT. 10749. 500 NPHI. CNTG 42. 590 ENPH. CNTG 42. 941 CPHI. CNTG NRA T. CNTG 3.660 CRA T. CNTG 3.739 ENRA . CNTG 5.874 NCNT. CNTG FCNT. CNTG 434.839 CNTC. CNTG 1684. 993 CFTC. CNTG 464. 879 CNEC. CNTG CFEC. CNTG 429. 733 GRCH. CNTG -999.250 TENS. CNTG 3110. 000 CCL. CNTG 35.136 1357.399 2294.096 0.003 38.547 1620.827 2524.378 -0.009 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NIIMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~/ZARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 11229.0 10750.0 CNTG 11234.0 10750.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 11 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NIIMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH ........... BASELINE DEPTH GRCH CNTG 88888.0 88884.0 88886.0 11224.0 11220.0 11222.5 11220.5 11220.0 11218.5 11213.0 11210.0 11209.0 11207.5 11207.0 11205.0 11206.5 11204.0 11196.5 11195.0 11192.5 11191.0 11189.5 11188.0 11189.0 11187.5 11186.0 11185.0 11184.5 11183.5 11176.5 11174.5 11172.0 11171.0 11170.0 11168.5 11165.0 11163.0 11164.5 11163.0 11161.0 11160.0 11158.5 11157.5 11157.5 11156.0 11154.5 11153.5 11151.0 11149.0 11149.0 11147.0 11147.0 11145.5 11145.0 11143.0 11136.5 11134.0 11132.0 11130.5 11124.5 11123.0 11119.5 11118.0 11117.5 11115.0 11116.0 11115.5 11113.5 11112.5 11111.0 11108.0 11107.0 11101.0 11102.0 11094.5 11092.0 11089.5 11088.0 11085.5 11085.5 11076.0 11076.0 11069.5 11068.5 11064.5 11064.5 11047.5 11046.5 11045.5 11046.0 11042.0 11042.5 11038.5 11039.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 12 11035.5 11034.5 11019.0 11019.0 11018.0 11018.0 11016.0 11015.5 11014.0 11013.0 11013.5 11013.5 11012.5 11010.0 11010.5 11008.5 11001.5 11000.5 10997.0 10996.5 10993.0 10993.0 10990.5 10990.5 10987.0 10987.5 10984.5 10984.5 10983.5 10984.0 10968.5 10970.5 10964.0 10964.5 10962.0 10961.5 10961.0 10960.5 10959.0 10958.5 10952.0 10951.5 10951.5 10949.0 10948.5 10946.0 10946.0 10945.5 10945.5 10934.0 10933.5 10933.5 10933.0 10930.5 10930.0 10928.0 10928.0 10923.5 10923.0 10922.0 10921.5 10921.5 10922.0 10913.5 10913.0 10894.5 10894.5 10894.0 10893.5 10891.0 10890.5 10889.0 10889.0 10885.5 10885.0 10881.5 10881.0 10877.5 10877.5 10873.0 10872.5 10872.0 10872.5 10864.0 10864.5 10862.5 10862.5 10862.5 10860.0 10860.0 10859.5 10859.5 10850.5 10851.5 10847.0 10847.5 10842.5 10842.0 10842.5 10836.0 10835.0 10831 . 0 10830.0 10827.5 10828.5 10825.5 10824.5 10824.0 10826.0 10811.0 10810.5 10810.5 10810.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 13 10801.0 10800.5 10791.0 10791.0 10784.0 10785.0 10774.5 10774.5 10771.5 10773.0 10765.5 10767.5 10765.0 10766.0 10762.0 10762.5 10759.5 10759.0 10756.0 10759.0 10752.0 10752.0 100.0 103.0 100.0 $ REMARKS: THIS FILE CONTAINS CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT GRCH PASS #3 TO GRCH PASS #1 AND NPHI PASS #3 TO NPHI PASS #1 CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. THE CNTG EPITHERMAL DATA IS NOT AVAILABLE FOR PASS #3 DUE TO TOOL PROBLEM. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 14 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500751 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 500751 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 500751 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 500751 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 500751 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 500751 O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNTG CPS 500751 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 500751 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 500751 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 500751 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 500751 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 500751 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11232.000 NPHI.CNTG 47.333 CPHI.CNTG 39.199 NRAT. CNTG CRAT. CNTG 3.999 NCNT. CNTG 1347.772 FCNT. CNTG 304.881 CNTC. CNTG CFTC. CNTG 411.941 GRCH. CNTG -999.250 TENS. CNTG 3255.000 CCL.CNTG DEPT. 10750.000 NPHI.CNTG 42.138 CPHI.CNTG 37.073 NRAT. CNTG CRAT. CNTG 3.714 NCNT. CNTG 1571.052 FCNT. CNTG 433.966 CNTC. CNTG CFTC. CNTG 458.720 GRCH. CNTG -999.250 TENS.CNTG 3170.000 CCL.CNTG 3.596 1509. 365 O. 000 3.776 1621.441 -0.202 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 15 FILE HEADER FILE NTJMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG $ REMARKS: THE ARITHMETIC AVERAGE OF PASS 1,2, &3 WAS COMPUTED AFTER ALL DEPTH SHIFTS AND CLIPPING WAS APPLIED. ONLY CNTG PASS #2 EPITHERMAL DATA WAS AVAILABLE SO NO AVERAGING OF THOSE CURVES WAS DONE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~f CODE (HEX) DEPT FT 500751 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 500751 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 500751 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 500751 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI~SS MOD NUMB S~'vlP ELt~ CODE (HEX) CRAT CNAV 500751 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 500751 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNAV CPS 500751 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 500751 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 500751 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 500751 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11233.000 NPHI.CNAV -999.250 iVRAT. CNAV -999.250 CPHI.CNAV CRAT. CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV CFTC. CNAV -999.250 GRCH. CNTG -999.250 DEPT. 10750.500 NPHI. CNAV 45.129 NRAT. CNAV 3.844 CPHI.CNAV CRAT. CNAV 3.878 NCNT. CNAV 1625.523 FCNT. CNAV 404.573 CNTC. CNAV CFTC. CNAV 443.939 GRCH. CNTG -999.250 -999.250 -999.250 39.789 1642.176 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 1 7 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH 11234.0 CNTG LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL COLLAR LOCATOR GR GAi~VA RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 10750.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER 17-MAY-97 CP42.2 1702 17-MAY-97 11259.0 11240.0 10750.0 11234.0 1800.0 NO TOOL NUMBER ........... CALY SGH-K 664 CNC-GB-125 11588.0 PUMPED IN CRUDE EPITHERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 18 FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS) '. 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS: CORRELATED TO BHCS DATED 8/21/78. MADE 3 PASSES AT 1800 FPH. GOC AT 11136'. WELL WAS LOADED WITH DEAD CRUDE PUMPED INTO WELL AT 1 BPM WHILE LOGGING. THIS FILE CONTAINS THE RAW DATA FOR CASED HOLE CNTG PASS #1. THE EPITHERMAL DATA IS NOT AVAILABLE FOR PASS #1 DUE TO TOOL PROBLEM. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500751 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 500751 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 500751 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 500751 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI~SS MOD NUMB SAMP ELEM CODE (HE, X) RTNR PS1 500751 RCNT PS1 CPS 500751 RCFT PS1 CPS 500751 CNTC PS1 CPS 500751 CFTC PS1 CPS 500751 NPOR PS1 PU 500751 GR PS1 GAPI 500751 TENS PS1 LB 500751 CCL PS1 V 500751 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11259.000 NPHI.PS1 45.775 TNPH. PS1 42.128 TNRA.PS1 RTNR.PS1 3.977 RCNT. PS1 1745.215 RCFT. PS1 432.380 CNTC. PS1 CFTC. PSI 468.502 NPOR.PS1 42.128 GR.PS1 50.750 TENS. PSI CCL.PS1 0.001 DEPT. 10742.000 NPHI.PS1 21.198 TNPH.PS1 20.454 TNRA.PS1 RTNR.PS1 2.490 RCNT. PS1 2580.239 RCFT.PS1 995.543 CNTC. PS1 CFTC. PSi 1026.231 NPOR.PS1 18.748 GR.PS1 63.469 TENS.PSI CCL.PS1 0.258 3.914 1798.495 2340.000 2.560 2508.242 3255.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 20 FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~NkRY VENDOR TOOL CODE START DEPTH CNTG $ LOG HEADER DATA DATE LOGGED: 11234.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10750.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL COLLAR LOCATOR GR GAM~A RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 17-MAY- 97 CP42.2 1702 17-MAY-97 11259.0 11240.0 10750.0 11234.0 1800.0 NO TOOL NUMBER CALY SGH-K 664 CNC-GB-125 11588.0 PUMPED IN CRUDE EPITHERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 21 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS.. CORRELATED TO BHCS DATED 8/21/78. MADE 3 PASSES AT 1800 FPH. GOC AT 11136'. WELL WAS LOADED WITH DEAD CRUDE PUMPED INTO WELL AT 1 BPM WHILE LOGGING. THIS FILE CONTAINS THE RAW DATA FOR · CASED HOLE CNTG PASS #2. THE EPITHERMAL DATA IS AVAILABLE FOR PASS #2 IS AVAILABLE AND IS PRESENTED FOR THIS PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 22 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500751 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 500751 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 500751 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 500751 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 500751 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 500751 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 500751 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 500751 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 500751 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 500751 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 500751 O0 000 00 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 500751 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 500751 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 500751 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 500751 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 500751 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 500751 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 500751 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 500751 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 11256.500 NPHI.PS2 37.046 ENPH. PS2 34.239 TNPH. PS2 TNRA.PS2 3.435 RTNR.PS2 3.490 ENRA.PS2 5.084 CFEC. PS2 CNEC. PS2 2395.819 RCEF. PS2 442.492 RCEN. PS2 2142.847 RCNT. PS2 RCFT. PS2 513.351 CNTC. PS2 1873.697 CFTC. PS2 556.238 NPOR.PS2 GR.PS2 36.563 TENS.PS2 2360.000 CCL.PS2 0.003 DEPT. 10739.000 NPHI.PS2 16.376 ENPH. PS2 15.061 TNPH. PS2 TNRA.PS2 2.238 RTNR.PS2 2.268 ENRA.PS2 2.934 CFEC. PS2 CNEC.PS2 3011.847 RCEF. PS2 816.444 RCEN. PS2 2858.507 RCNT. PS2 RCFT. PS2 1136.290 CNTC. PS2 2659.784 CFTC. PS2 1189.242 NPOR.PS2 GR.PS2 37.688 TENS.PS2 3215.000 CCL.PS2 .-0.523 34.390 471.237 1818.189 34.390 17.544 1026.370 2622.732 17.106 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 23 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SD?4FiARY VENDOR TOOL CODE START DEPTH CNTG 11234.0 $ LOG HEADER DATA STOP DEPTH 10750.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL COLLAR LOCATOR GR GAlV~LA RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : 17-MAY-97 CP42.2 1702 17-MAY-97 11259.0 11240.0 10750.0 11234.0 1800.0 NO TOOL NUMBER ........... CALY SGH-K 664 CNC-GB-125 11588.0 PUMPED IN CRUDE LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 24 FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) '. WATER CUTS (PCT) : GAS~OIL RATIO '. CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY.. HOLE CORRECTION (IN) '. E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 1.0 REMARKS: CORRELATED TO BHCS DATED 8/21/78. MADE 3 PASSES AT 1800 FPH. GOC AT 11136'. WELL WAS LOADED WITH DEAD CRUDE PUMPED INTO WELL AT 1 BPM WHILE LOGGING. THIS FILE CONTAINS THE RAW DATA FOR CASED HOLE CNTG PASS #3. THE EPITHERMAL DATA IS NOT AVAILABLE FOR PASS #3 DUE TO TOOL PROBLEM. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 25 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500751 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 500751 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 500751 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 500751 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 500751 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 500751 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 500751 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 500751 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 500751 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 500751 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 500751 O0 000 O0 0 7 I 1 4 68 0000000000 TENS PS3 LB 500751 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 500751 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11263.500 NPHI.PS3 35.941 TNPH. PS3 33.393 TNRA.PS3 RTNR.PS3 3.429 RCNT. PS3 1711.795 RCFT. PS3 492.473 CNTC. PS3 CFTC. PS3 533.616 NPOR.PS3 33.393 GR.PS3 50.688 TENS. PS3 CCL.PS3 -0.001 DEPT. 10739.500 NPHI.PS3 18.276 TNPH. PS3 18.979 TNRA.PS3 RTNR.PS3 2.318 RCNT. PS3 2600.369 RCFT. PS3 1062.249 CNTC. PS3 CFTC. PS3 1143.933 NPOR.PS3 18.942 GR.PS3 52.219 TENS. PS3 CCL.PS3 -0.400 3.374 1764.054 2585.000 2.369 2676.318 3210.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 26-AUG-1997 08:48 PAGE: 26 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/26 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/08/26 ORIGIN : FLIC TAPE NAME : 97358 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-07, API# 50-029-20299-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/08/26 ORIGIN : FLIC REEL NAME : 97358 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-07, API# 50-029-20299-00
