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180-032
L-80/S-95 13Cr80/L-80 Received by J. Brooks on 1/6/2025 at 9:57AM Abandoned 12/9/2024 JSB RBDMS JSB 011325 xGSFD 3/25/2025JJL 5/6/25 DSR-4/7/25 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.03 11:31:58 - 09'00' Sean McLaughlin (4311) ACTIVITYDATE SUMMARY 10/28/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Mill XN, mill CIBP MIRU and make up 2-7/8" Yellowjacket left-handed milling BHA with 3.805" scale mill, 3.805" string reamer, and 3.80" stabilizer / drift. Freeze protect the flowline. Load and kill with well with 1% KCL & safelube. RIH and tag the XN nipple at ~ 8072' CTM / 8069' MD. Mill through the nipple, and make multiple string reamer passes up/down across the nipple. Drift cleanly through with the 3.80" stabilizer /drift down to 8100'. Have to work pipe to get the stabilizer back into the tubing tail. POOH and place a 10 BBL 60/40 cap on the tubing. Gauge mills at surface (scale mill: 3.80" go, 3.79" no- go, string reamer & stabilizer: 3.81" go, 3.80" no-go). Swap out left-handed milliing BHA for standard right-handed BHA & 3.80" junk mill. Shut down for the night. ***Job in Progress*** 10/29/2024 SLB CTU #8, 1.75" Coil, 0.156" WT. Job Objective: Mill XN, mill CIBP RIH with 2-7/8" Yellowjacket milling BHA with 3.80" 5-blade reverse clutch junk mill. Tag the 4-1/2" CIBP at 8882' CTM / 8886' MD. Mill the plug and push down to the lower CIBP at 9065' MD. Dry drift cleanly from the top of the liner at 8200' MD to 9065' MD. POOH and freeze protect the tubing with diesel to 2500' TVD. Gauge the mill at surface (3.81" go, 3.80" no-go). ***Job Complete*** 10/31/2024 ***WELL S/I ON ARRIVAL***(sidetrack) DRIFTED TBG/LINER W/ 20' x 3.70" DUMMY WHIPSTOCK DRIFT, TAGGED CIBP @ 9,041' SLM. ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 11/8/2024 ***WELL SI ON ARRIVAL*** (SET WHIPSTOCK) PT TO 300 LOW AND 2500PSI HIGH. LOG CORRELATED TO SLB PERFORATION RECORD DATED 11-APRIL-2009 WHIPSTOCK SET AT 8960FT TOWS. CCL STOP DEPTH: 8945.9' CCL - TOWS: 14.1' ORIENTATION: -15.9 DEG ROHS WELL LEFT SI. *** JOB COMPLETED*** 11/10/2024 T/I/O=200/0/0. Pre CTD. Install Kill line (#1) on tree companion and 4x7 X-over on SV. PT Flat line test against the SV to 300/5000 psi. (Pass), PT upper tree to 300/5000 psi. (Pass), Install swab platform. DIsconnected S riser and C spool. Installed flanges. Torqued to spec. ***Job Complete*** Final WHP's 0/0/0. Daily Report of Well Operations PBU 06-15 Drilling Manager 07/25/24 Monty M Myers By Grace Christianson at 12:21 pm, Jul 25, 2024 DSR-7/31/24 10-407 * BOPE test to 3500 psi. Annular to 2500 psi. * Variance to 20 AAC 25.112 (i) Alternate plug placement approved with fully cemented liner in upcoming sidetrack. All drilling within the PB Oil Pool. MGR15AUG24 SFD 10/8/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.10.09 08:59:48 -08'00'10/09/24 RBDMS JSB 100924 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: July 24, 2024 Re:06-15 Sundry Request Sundry approval is requested to set a whipstock and mill a window in the 06-15 wellbore as part of the drilling and completion of the proposed 06-15A CTD lateral. Proposed plan: Prior to drilling activities, slickline will drift for a whipstock and run a caliper(if needed), E-line will set a 4-1/2" packer whipstock, E-line or service coil will mill the XN nipple. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will mill a dual string 3.80" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 4 and drill an S-shaped well through Zones 2, 3, and 4 to TD. The proposed sidetrack will be completed with a 3-1/2" x 3-1/4" x 2-7/8" 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 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 work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in Sept. 1st 2024) x Reference 06-15 permit submitted in concert with this request for full details. 1. Coil : Mill XN nipple at 3.80" 2. E-line : Set 4-1/2" Monobore Whipstock at 8960' MD at 0 deg ROHS 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in November 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 psi). 2. Mill 3.80” Window 3. Drill build section: 4.25" OH, ~369' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~1915' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 35 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. Sundry 324-429 24 hour notice to AOGCC for opportunity to witness. PTD 224-108 This Sundry covers plugging the existing perforations Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip 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 PBU 06-15 1324-429180-032 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): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops 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 06-15 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 180-032 50-029-20459-00-00 9540 Conductor Surface Intermediate Liner Scab Liner 9328 80 2648 8595 6603 1241 8886 20" 13-3/8" 9-5/8" 7" 4-1/2" 8676 30 - 110 30 - 2678 28 - 8623 2923 -9535 8198 - 9439 30 - 110 30 - 2678 28 - 8414 2932 - 9323 7994 - 9227 none 470 2670 4760 5410 7500 8886 , 9065 1490 4930 6870 7240 8430 8864 - 9264 4-1/2" 12.6# 13Cr80 25 - 8081 8654 - 9053 Structural 4-1/2" Baker S-3 Perm , 7943 , 7744 No SSSV 7943 7744 Bo York Operations Manager Jerry Lau Jerry.Lau@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 pressure: 13a.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 25 - 7879 605 894 58738 57338 19 0 0 0 1021 962 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Samantha Coldiron at 9:09 am, Mar 08, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.07 14:03:13 - 09'00' Bo York (1248) WCB 2024-06-25 DSR-3/11/24 RBDMS JSB 031324 ACTIVITYDATE SUMMARY 2/7/2024 ***WELL S/I ON ARRIVAL***(drift for e-line) RAN 20' x 3.70" DMY WHIPSTOCK, TAG CIBP @ 9065' MD (no issues) ***WELL LEFT S/I ON DEPARTURE*** 2/10/2024 *** WELL SI ON ARRIVAL *** SPOT EQUIPMENT AND CHECK TOOLS FOR WORK TOMORROW. *** JOB CONTINUED ON 11-FEB-24 *** 2/10/2024 TFS unit 3 assist E-Line as directed ****Job Postponed**** 2/11/2024 *** WELL SI ON ARRIVAL *** (PLUG/ADPERF) PT 250 LP AND 3000 HP THUNDERBIRD PUMP 200 BBL AT MAX RATE THEN 1 BPM WHILE ELINE RIH. PUMP A TOTAL OF 275BBL. RIH WITH 3.5" PLUG FOR 4.5" CASING. SET AT 8886'. CCL - MID ELEMENT: 11' CCL STOP DEPTH: 8875' MIT-IA PASSED AFTER PLUG SET. RIH WITH 14' 3-1/8" HSD GUN. RAZOR 22.7 CHARGES. INTERVAL: 8864-8878' WELL LEFT SI. SWAB AND SSV CLOSED *** JOB COMPLETED *** 2/11/2024 T/I/O= 2450/0/50 TFS unit 3 assist E-Line as directed Pumped 200 bbls of Crude to Load TBG Pumped 75 bbls of Crude to assist E-Line tool string down TBG MITxIA PASSED to 2411 psi. Max Applied Pressure= 2500 psi, Target Pressure 2250 psi. Pressured IA to 2496 psi with 9 bbls of Crude. MITxIA lost 74 psi in the first 15 minutes and 11 psi in the second 15 minutes with a final pressure of 2411 psi on the IA. IA bled to 0 psi. Tags hung, DSL notified and well left in control of E-Line upon departure. Daily Report of Well Operations PBU 06-15 RIH WITH 3.5" PLUG FOR 4.5" CASING. SET AT 8886'. RIH WITH 14' 3-1/8" HSD GUN. RAZOR 22.7 CHARGES. INTERVAL: 8864-8878' CIBP and adperfs are correctly shown on the new WBS, below. -WCB Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:180-032 6.50-029-20459-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9540 7943 none 9065 7744 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30 - 110 30 - 110 1490 470 Surface 2648 13-3/8" 30 - 2678 30 - 2678 4930 2670 Intermediate 8595 9-5/8' 28 - 8623 28 - 8414 6870 / 8150 4760 / 5080 Liner 6603 7" 2932 - 9535 2932 - 9323 7240 / 8160 5410 / 7020 Perforation Depth: Measured depth: 8891 - 9264 feet True vertical depth:8681 - 9053 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 25 - 8081 25 - 7879 7943 7744Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Scab Liner 1241 4-1/2" 8198 - 9439 7994 - 9227 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 266-155878 2344912 -15 0 813 1002 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564 - 5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9328 Sundry Number or N/A if C.O. Exempt: n/a Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028311 PBU 06-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations no SSSV 55 9065 8854 By Samantha Carlisle at 10:45 am, Mar 01, 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: 2021.02.25 16:00:49 -09'00' Bo York MGR01MAR2021 DSR-3/1/21 RBDMS HEW 3/1/2021 ACTIVITYDATE SUMMARY 2/6/2021 ***WELL SHUT IN ON ARRIVAL*** (AK EL - Plug & Perf) SET 4-1/2" GEO DYNAMICS LEGACY LHPBP CIBP AT 9,065'. PERFORATE 8891' - 8911' WITH 3-1/8" x 20' GEO DYNAMICS BASIX (22.7g) RDX PERF GUN. LOGS CORRELATED TO BH RPM LOG DATED 18-May-2018. ***JOB COMPLETE, NOTIFIED DSO TO POP*** 2/6/2021 T/I/O = 1970/200/70. Temp = SI. TBG FL (Pre Eline). ALP = 1400 psi, SI @ CV. OA cemented to surface. TBG FL @ 6490' (between Sta #2 & #3, Dmy's, 99 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:45. Daily Report of Well Operations PBU 06-15 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 06-15 Permit to Drill Number: 180-032 Sundry Number: 320-042 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, W DATED thisJ✓ day of January, 2020. iBDMS/*! / N 3 11010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ jW1ZJ.AQnE1 Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ChaA(3 v dF3kn ❑ � �y Plug for Redrill 0 Perforate New Pool [IRe-enterSusp Well 11 AlterCasing ❑ Other ❑ / 3 0 20 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 180-032 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20459-00-00 1 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 06-15 9. Property Designation (Lease Number): 10. Fieltl/Pools: ADL 028311 i PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9540 9326 9439 9227 2423 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 2648 13-3/8" 30-2678 30-2678 4930 2670 Intermediate 8595 9-5/8" 1 28-8623 1 28 - 8414 !87!/ 8150 4760/5080 Liner 6603 7" 2932 - 9535 2932 - 9323 7240 / 8160 5410/7020 Scab Liner 1241 L 4-1/2" 8198-9439 7994-9227 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9100 - 9264 8889 - 9053 4-1 /2" 12.6# 13Cr80 25-8081 Packers and SSSV Type: 4-1/2" Baker Production Packer Packers and SSSV MD (ft) and TVD (ft): 7943 / 7744 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 5, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 - 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt, Trevor be deviated from without prior written approval. Contact Email: Trevor. Hyatt@bp.cem Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 564 4627 Authorized Title: Engi 0enng Tea Lead - CTD Authorized Signature: Date: 01/7,3z�a. 4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number' 32�-2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: O p E7-Esr —V—C) �arteLv.cre_ 0201EitCZ5 t/2�w,a/9�►xa G�/ !%up��aGe..�w� Post Initial Injection MIT Req'd? Yes ❑ No ❑ // Spacing Exce 'on Required? No !4r/ Subsequent Form Required: qe) AD BYTHE �f N Approved by: COMMISSIONER COMMISSION Date: (/�7 u� ORIGINALIBDWS ''A"3,2020 9'C- I/3o17-U m�QEcj n//02a Submit Form and Form 10-403 Revise(dd 0`4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission 11���IlIIIyyyyy From: Trevor Hyatt .r bp CTD Engineer Date: January 22, 2020 Re: 06-15 Sundry Approval Request Sundry approval is requested to plug off the 06-15 production as part of the preparation, drilling and completing the proposed 06-15A coiled tubing sidetrack. History of 06-15: Proposal to coil sidetrack 06-15 (an original well location on DS -06 in the GDWFI) to add 2 fresh offtake points in the GDWFI oil pad away from the parent well. 06-15 was drilled in 1980. The well has a long history of squeezes (for gas shut offs), perfs, and reperfs, but the well continued to produce from squeezed perfs. There was a Cretaceous leak that was fixed in 2000, and a rig workover in 2008 where a scab liner was placed across the production section. This well has been popped a handful of times since the RWO, though performance has been mediocre, and the well has had very low on-time over the past decade. The poor performance may be due to the GDWFI oil pad moving up and down within the reservoir, or other factors like Cretaceous damage around the wellbore. Sidetracking the well to the south, to the thicker GDWFI oil column, will return this well to a competitive state, recover more resources, thereby adding value to the business. Proposed plan for 06-15A: y (�dGL'/ 'Ylu/ 0_rl o A —2,100' coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The whipstock will be set pre -rig in the 4- 1/2" scab liner. The rig will move in, test BOPE and kill the well. A dual string window exit (4-1/2" x 7") + 10' of rathole will be milled. The well will kick off in the Shublik, build through Zone 4, 3 and 2 to land. Then the well will build back up to Zone 4 at TD. The proposed sidetrack will be completed with a 3-1/2" x 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will completely isolate and abandon the parent Ivishak perfs. This Sundry covers Plugging the existing 06-15 perforations via the Packer whipstock liner cement job or liner too 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 (scheduled to begin February, 2020) 1, Set DGLVs Design and Drift for WS 2. Load IA and MIT -IA 3. Mill XN and Set 4-1/2" Packer Whipstock* 4, Pre -CTD Tree work. Rig Work (scheduled to begin March 2020) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP: 2423 psi). 2. Mill dual string window (4-1/2" x 7") 3. Drill build section: 4.25" OH, ^322' (28 deg DLS planned). 4. Drill lateral section: 4.25" OH, —1804' (12 deg DLS planned). 5. Run open hole logs (Sonic/Den/Neu) — if needed. 6. Run 2-7/8" x 3-1/4" x 3-1/2" 13Cr liner to TD. 7. Pump primary cement job: 32.2 bbls, 15.3 ppg Class G, TOC at TOL (^8,040 MD). 8. Close in tree, RDMO. " Approved alternate plug placement per 20 AAC 25.112(i) SvN4Rn{ Post -Rig Work: 1. V: Valve & tree work 2. 5: SBHPS, set LTP• (if necessary). Set live GLVs. I T: Portable test separator flowback. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 564-4627 TREE = 4-1116' 5M CNV WELLHEAD= FMC ACTUATOR= BAKER C OKB. ELEV = N. BE ELEV = 38.15' KOP = 5200' Max Angle = 28' 5700' Datum MD = 9079' Dahmn TVD = 8800' SS D = 8.681' I7' SCAB LNR 26#, L-80 BTC XO TO I- ] 13CR-80 VAM TOP Minimum ID = 3.725" @ 8069' 4-M" HES XN NIPPLE 3' CSG, 47#, L-80 BTC XO TO 6-95 BTC �, '4-12' TBG, 12.6#, 13CR-80 VAM TOP, 81 .0152 bpf, D = 3.958' TOP OF 4-12- SCAB LNR ITOPOF7-LNR --t 829W 7- SCAB LNR, 26#,13CR-80 VAM TOP, 8305' .0383 bpf, D = 6.276' S-95 BTC, D = PERFORATION SUMMARY REF LOG BRCS ON 0720/80 ANGLEAT TOP PERK 4- @ 9100' Note: Refer to Production DB for historical pert data SIZE SPF I ME RVAL I OpnlSgz I DATE SEE PAGE2 FOR PERFORATION DATA 13CR-80 VAM TOP, L-80 ST 4-12- SCAB LNR 12.69, L-80 BT, I 943W .0152 bpf, D = 3.958' FPB—TD9467' L-80 BTC, 06-15 C_1C SAFETY NOTES: `*`CHROME TBG & LNW** 14-1lL-MLS X NP, D=3.813' 1 2960' 9-5/8' X 7- BKR FLEX LOCK LNR HGR, D = 6.30' GAS LFr MADS STI MD I TVD I DEVI TYPE I VLV ILATCH 8299' PORTT DATE 4 3373 33730 01/14/09 KBG2-1R DOMEJ BK 16 07/04/19 3 5585 5566 23 KBG2-1R SO BK 20 07/04/19 2 7154 6978 19 1®402 -IR DMY BK 0 07/04/19 1 7846 7649 12 K3G2-1R DMY BK 0 07/04119 7912' 4-12'H6X NP. D=3.813' I r- A 4-Ird- BKH S-3 HCR, D= 3.938' I 8081J�4-12' WLEG, D = 3.958' 8198' 7'X5'BKR ZXPLTPw/HMC LNR ORIGINAL COMPLETION & XO, D = 4276' 8299' BOT TEBACK SLV,D=? 8306'9-5/8' X 7- BOT HYDRA LNR HGR. DATE REV BY COMMENTS DATE REV BY COMMENTS 07131180 ORIGINAL COMPLETION 07/31/15 JMM/JMD PULL PLUGSET XN LOCK WIIUD 12NBI90 LAST WORKOVER 05167/18 JMG/JMD PULLED IUD (05105/18) 0621108 D78 RWO 07/10/18 MS/JMD ADPERFS(07/08/18) 01/14/09 RLMSV REPERF(01/13M) 07/15M9 GJB/JMD GLV C/O (07/04119) 05(30/09 ???/rLH PERF 0411 V09 0827119 BTWJMD ADPERFS 0824119 12/17/09 MBM/SV SET PXN PLUG (12109/09) 012220 JNL/JMD ADDED BF ELEV PRUDHOE BAY UNrr WELL: 06-15 PERMIT No: 7800320 API No: 50-029-20459-00 TION, III 4E, 355' FSL a 1753' FEL BP Exploration (Alaska) I PERFORATION SUMMARY REF LOG: BHCS ON 0720/80 ANGLE AT TOP PERF: 4'@ 9100' Nolo: Refer lo Production DB for historical perfdata SIZE SPF INTERVAL n/S z DATE 3-3/8" 4 9100-9104 S 07/17/87 3-1/8" 4 9124-9144 S 10/05/85 3-118" 4 9154-9174 S 10/05/85 3-1 /8" 4 9184-9200 S 0722/90 2-7/8" 6 9195-9200 O 0824/19 3-3/8" 4 9200-9204 S 0820/94 3-3/8" 6 9200-9205 O 07/08/18 3-38" 6 9213-9233 O 04/11/09 3-3/8" 6 9216-9226 S 08/15/91 2-7/8" 6 9225-9250 O 0628/08 3-12" 6 9225-9250 O 01/13/09 3-3/8" 4 9226-9245 S 0620/08 3-318" 4 9248-9263 S 0620/08 3-3/8" 4 9263-9264 S 08/04/91 06-15 DATE REV BY COMMENTS DATE REV BY I COMMENTS 07131180 ORIGINAL COMPLETION 07/31/15 JMM/JMD PULL PLUGSET XN LOCK WAUD 1211880 LAST WORKOVER 05/07/18 JMG/JMD PULLED IUD (05/05/18) 082188 D18 RWO 07/10/18 MS/JMD ADPERFS (07/08/18) 01/14/09 RLM/SV REPERF(01/13/09) 07/15/19 G1B/JMD GLV C/O (07/04/19) 05/30/09 ????LH PERF 04/11/09 0827/19 BTN/JMD ADPERFS 0824/19 12/17/09 MBWSV SET PXN PLUG (12/09109) 012220 JNL/JMD ADDED BF ELEV PRUDHOE BAYUNR WELL: 06-15 PERMR No: 1800320 API No: 50-029-20459-00 T1 ON. R14E. 355' FSL & 1753' BP Exploration (Alaska) TREE _ WELLHEAD= FMC ACTUATOR= Note: Refer to Production DB for Nstorical perf data OKB. ELEV = 68' BF. ELEV = ? KOP = 5200' Max Dakim MD = Datum TVD = 8800' SS 06 15A SAFETY NOTES: WELL ANGLE > 70° @ PROPOSED MAX DLS _° @ _'.' CHROME TBG & LNR""" 1736' 9-5/8" HES CEMENTER 2076' 4-1/2" HES XNP, D = 3.813" 7" SCAB LNR 26#. L-80 BTC XO TO 13CR-80 VAM TOP Minimu:M11 = _" @ _' 47#, IF, _bpf, ID=_' 2" TBG, 12.6#, 13CR-80 VAM TOP, 52 bpf, ID = 3.958" 17"SCAB LNR 26#,13CR-80 VAM TOP, .0383 bpf, D=6.276" 9-5/8" CSG, 47#, 5-95 BTC, D = 8.681" 4-12' KB PACKER WH13STOCK L_J /_j 4-12' SCAB LNR, 12 6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958' 7" LNR, 29#, L-00 BTC, .0371 bpf, D = 6.184" PERFORATION SUMMARY REF LOG: ON ANGLE AT TOP PERF: _° @ Note: Refer to Production DB for Nstorical perf data 12M880LAST WORKOVER INTERVAL I O NS z I DATE 711 4-1/2" HES X NP, D = 3.813" 1,.0079bpf,D=2.85" I PBTD - .0058 bpf, D = 2-41" H X 7" BKR FLEX LO( �S LIFT MANDRELS 3 5585 5566 1 23 KBG2-1R SO BK 20 07/04/19 2 7154 6978 19 KBG2-1R IXvT1' BK 0 07/04/19 1 7846 7649 12 KBG2-1R OMY BK 0 07/04/19 — 7912' DATE REVBY COMMENTS 4-12" HES X NP, D = 3.813" 7943' 12M880LAST WORKOVER 7" X 4-1/2" BKR S-3 PKR ID = 3.938" — 8007' 4-1/2" HES X NP, D = 3.813" )EPLOYMENTSLEEVE,D = ' HES XN NP, D = 3.725" I X NP, 1)=2.31" X 3-1/4" XO. D = 2.786' 7"XS"BKR ZXP CTP w/HMC LNR HGR & XO, D = 4.276" X 7" MILLOUT WINDOW (06-15A) 8815' . ' 133/16"X2-7/8'XO,D=2.377" I DATE COMMENTS DATE REVBY COMMENTS 07/3180ORIGINAL COMPLETION 12M880LAST WORKOVER 0612188RWO NMD _/ /CTD (0645A) 0726719BULT PROPOSED PRUDHOE BAY UNIT WELL: O6 -15A PERMIT No: API No: 50-029-20459-01 T10N, R14E, 355' FSL 8, 1753' FEL BP Fxploratlon (Alaska) CL VERs 12.6 ft CL Pipe/Slips 13.4 ft CL of Top Swab F 16.0 ft F� Swab je T1 CL of Flow Cross 17.4k FIA CL of Master 188 ftLDS LDS O Ground Level 0 T2 Test Pump Hose CDR2-AC 4 Ram BOP Schematic Date 21 -Jan -20 Quick Test Sub to Otis 1.1 ft ------- Top of 7" Otis 0.0 ft —.—.—._._..._.—. ._.—._._. Distances from top of riser -CDR2 Rig's Drip Pan Excluding quick .est sub Top of Annular 7-1/16' 6k Flange X T' Otis Box 6.0 ft dril 7111 Top of Annular Element 6.7k Annular Bottom Annular 8.0 ft CL Blind/Shears 9.3 f[ CL Pipe/Slips PipelSlips B1 az B3 B4 Choke Line Kill Line CL VERs 12.6 ft CL Pipe/Slips 13.4 ft CL of Top Swab F 16.0 ft F� Swab je T1 CL of Flow Cross 17.4k FIA CL of Master 188 ftLDS LDS O Ground Level 0 T2 Test Pump Hose Sundry Application Plug for Re -drill Wells Work Flow 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." Task The initial reviewer will check to ensure that the "Plug for Redrill" box in the upper left comer of Form 10-403 is checked. the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 1 111h "Abandon" box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. The drilling engineers will serve as quality control for steps 1 and 2. then ?Rz8 rl Drilling Engineer (QC) When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat 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." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redril]" code (IPBRD), If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. When the Form 10-4117I for the redrill is received, the Stat Tech will Stat Change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA.-., .,,�, ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WFLL OPFRATInNR 1. Operations Performed 1 19, .rI i". Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑' P Alter Casing ❑ Change Aptgr»Pr$q�r�r Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work 5. Permit [o Drill Number: 180-032 3. Address: P.O. Box 196612 Anchorage, Development Q Exploratory ❑ AK 99519-6612 Stretigraphic ❑ Service ❑ 1 6. API Number: 50-029-20459-00-00 7. Property Designation (Lease Number): ADL 028311 S. Well Name and Number: PBU 06-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Length: Size: MD: TVD: Burst: Conductor Total Depth: measured 9540 feet Plugs measured None feet true vertical 9328 feet Junk measured None feet Effective Depth: measured 9467 feet Packer measured 7947 feet true vertical 9255 feet Packer true vertical 7748 feet Casing: Length: Size: MD: TVD: Burst: Conductor 80 20" 30-110 30-110 1490 Surface 2648 13-3/8" 30 - 2678 30-2678 4930 Intermediate 8595 M/8" 28-8623 28-8414 6870/8150 Liner 1234 7" 8301 -9535 8096-9323 8160 Scab Liner 5373 7" 2936-8309 2936 - 8104 7240 Scab Liner 241 4-1/2" 8202-9443 7998-9231 8430 Perforation Depth: Measured depth: 9195-9250 feet True vertical depth: 8984-9039 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 26-8085 26-7883 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 7947 7748 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Collapse: 470 2670 4760/5080 7020 5410 7500 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 26 3798 496 0 1 242 Subsequent to operation: 24 4072 588 0 268 14.Attachments: (requ,.dper2o A4c25,07026071,&25.263) Daily Report of Well Operations 0 Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 15. Well Class after work: Exploratory ❑ Development p Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Thompson, Ryan Contact Name: Thompson Ryan Authorized Title: Petroleum Engineer Contact Email: RYAN.THOMPSONabo.com Authorized Signature: QQA:,'-n t Date: ry In lie/ Contact Phone: +1 907 564 4535 x i�/ `vl"" RBDMS.Li" SEP 2 0 2019 Submit Original Only Daily Report of Well Operations PBU 06-15 ACTT\/ITV nATC ......... _ ***WELL SHUT IN ON ARRIVAL***(adpert) V V RIG UP ELINE. 8/23/2019 ***CONT ON 8/24/19 WSR*** ***CONT FROM 8/24/2019 WSR***(adpert) PERFORATE 9,196- 9,200' WITH 2.875" 6 SPF, 60 DEGREE PHASING HSC LOADED WITH 175 MAXFORCE HMX CHARGES. CCL TO TOP SHOT OFFSET: 12.7', CCL STOP DEPTH: 9182.3'. CORRELATED TO SLB JEWELRY LOG DATED 11 -APR -2009. 8/24/2019 ***JOB COMPLETE, DSO NOTIFIED*** TREE= 4-1/16"5M CNV D= FMC R= BAKERC O7KB- = 68' RDatumTVD= ? 4-1/2" SCAB LNR 12.6#, L-80 DT,g43W 5200' = 28° @ 5700' = 9079' = 8800'SS 53, D= C D=' 7" SCAB LNR 28#, L-80 BTC XO TO 7793' 13CR-80 VAM TOP Minimum ID = 3.725" @ 8069' 4-1/2" HES XN NIPPLE 9-5/8" CSG, 47#, L-80 BTC XO TO S-95 BTC A� O 4-1/2"TBG, 12.6#, 13CR-80 VAMTOP, I 8081' .0152 bpf, D=3.958" TOP OF 7" LNR 7" SCAB LNR, 26#, 13CR-80 VAM TOP, .0383 bpf, D = 6.276" BTC, ID= PERFORATION SLA"RY REF LOG: BHCS ON 07/20/80 ANGLE AT TOP PERF: 4" @ 9100' Note: Refer to Production DB for historical pert data SZE I SPF I INTERNAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION DATA 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 1 06 15 SAFETY NOTES: -'-cHROME TBG & LNR"` 9-112' HtJ X NP, D = 3.813" 9-5/8" X 7" BKR ZXP LTP, ID = 6.29" 9-5/8" X 7" BKR FLEX LOCK LNR HGR D = GAS LET MANDRELS 23 SO BK 20 12 7846 17649 12 BG2-1R 19 DMY I BK BK I 0 107/04/lE7 -� 7912' 4-1/2" SCAB LNR 12.6#, 13CR-80 VAM TOP, DATE REV BY COMMENTS 071311801 XO TO L-80 8T 7" X 4-1/2" BKR S-3 PKR D = 3.938" - 8007' LAST WORKOVER 4-1/2" SCAB LNR 12.6#, L-80 DT,g43W 06/21108 D16 RWO .0152 bpf, D = 3.958" $069' 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 1 06 15 SAFETY NOTES: -'-cHROME TBG & LNR"` 9-112' HtJ X NP, D = 3.813" 9-5/8" X 7" BKR ZXP LTP, ID = 6.29" 9-5/8" X 7" BKR FLEX LOCK LNR HGR D = GAS LET MANDRELS 23 SO BK 20 12 7846 17649 12 BG2-1R 19 DMY I BK BK I 0 107/04/lE7 -� 7912' REV BY I COMMENTS DATE REV BY COMMENTS 071311801 7943' 7" X 4-1/2" BKR S-3 PKR D = 3.938" - 8007' LAST WORKOVER 4-1/2" HES X NP, D = 3.813" 06/21108 D16 RWO 07/10/18 MS/JMD ADPERFS (07/08/18) $069' 4-1/2" HES XN NP. D = 3.72F ouo 8198' 7"X5"BKRZXPLTPw/HWICLNRHGR & XO, D = 4.276" cul IF AUK JLV, U=7 9-5/8" X 7" BOT HYDRA LNR HGR D = ? 17" MARKER JOINT I DATE I REV BY I COMMENTS DATE REV BY COMMENTS 071311801 1 ORIGINAL COMPLETION 07/31/15 JMM/JMD PULL PLUG/SETXN LOCK w/IUD 12/18/80 LAST WORKOVER 05/07/18 JMG/JMD PULLED IUD (05/05/18) 06/21108 D16 RWO 07/10/18 MS/JMD ADPERFS (07/08/18) 01/14/09 05/30/09 RLM/SV REPERF(01/13/09) ???/TLH PERF 04/11/09 07/15/19 GJB/JMD GLVC/0(07/04/19) 08/27/19 BTN/JMD ADPERFS 08/24/19 12/17/09 MBM/SV SETPXN PLUG (12109109' PRUDHOE BAY UNIT WELL: 06-15 PERMIT No: 1800320 API No: 50-029-20459-00 T10N, R14E, 355' FSL & 1753' BP Exploration (Alaska) PERFORATION SUMMARY REF LOG: BHCS ON 0720180 ANGLE ATTOP PERF: 4"@? 9100' Note: Refer tD Pmdwtion DB for historical rfdata SIZE SPF INTERVAL OpnfSqz DATE 3-38" 4 9100-9104 S 07/17/87 3-1/8" 4 9124-9144 S 108585 3-1/8" 4 9154-9174 S 1010585 3-18" 4 9184-9200 S 072280 2-7/8" 6 9195-9200 O 0824119 33/8" 4 9200-9204 S 082084 3-3/8" 6 9200-9205 O 07/08/18 3-3/8" 6 9213-9233 O 04111/09 338" 6 9216-9226 S 08/15/91 2-7/8" 6 9225-9250 0 06/2888 3-12" 6 9225-9250 O 01113/09 3318" 4 9226-9245 S 0620108 3-3/8" 4 9248-9263 S 06/20108 3-3/8" 4 9263-9264 S 08/04/91 06-15 DATE REV BY COMMENTS DATE REV BY COMMENTS ORIGINAL COMPLETION 0781/15 JMM/JMD PULL PLUG/SETXN LOCK WAUD LAST WORKOVER 8 JMG✓JMD PULLED IUD (05/05118) Al2t17M9 D18 RWO MS/JMD ADPERFS 07/08/18RLM/SV REPERF 01/1389 g07/10118 9 GJB/JMD GLVCAO 07AkU19???/TLH PERF 04/11/09 9 BTN/JMD ADPERFS 0824/19 MBM/SV SET PXN PLUG 12/0989 PRUDHOE BAY UNIT WELL: 06-15 PERMITNo: RI800320 API No: 50-029-20459-00 BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMAII REPORT OF SUNDRY WELL OPERAMJS v L.v i4d6 A 1 1A7$ 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operaliorp a ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing 11Change ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Orill Number. 180-032 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigrephic ❑ Service ❑ 8. API Number: 50-029-20459-00-00 7. Property Designation (Lease Number): ADL 028311 8. Well Name and Number: PBU 06.15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9540 feet Plugs measured None fear true vertical 9328 feet Junk measured None feet Effective Depth: measured 9467 feet Packer measured 7947 feet true vertical 9255 feet Packer true vertical 7748 feet Casing: Length: Size: MO: TVD: Burst: Collapse: Conductor 80 20" 30-110 30-110 1490 470 Surface 2648 13-318" 30-2678 30-2678 4930 2670 Intermediate 8595 9-5/8" 28-8623 28-8414 6870/8150 4760/5080 Liner 1234 7' 8301 -9535 8096-9323 8160 7020 Scab Liner 5374 7" 2936-8309 2936-8104 7240 6410 Scab Liner 1241 4-1/2" 8202-9443 7998-9231 8430 7500 Perforation Depth: Measured depth: 9200-9250 feet SCANNED SP True vertical depth: 8989-9039 feet Tubing (size, grade, measured and true vertical depth) 4-112" 12.6# 13Cr80 26-8085 26-7883 Packers and SSSV (type, measured and 4-1/2- Baker S-3 Penn Packer 7947 7748 true vertical depth) No SSSV Installed 12. Stimulalion or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 69 171 600 338 0 Subsequent to operations No Test Available 375 0 14. Attachments: osquired Per 20 MC 25.07025.071, It 25.2811 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or NIA if C.O. Exempt: WA Authorized Name: Vohra, Prechi Contact Name: Vohra, Prachi Authorized Title: Production Engr Contact Email: Pfachl.VohmAldmoom Authorized Signature:r"v+� Date: "S(� k (g, Contact Phone: +19076644677 Fwm10404Revieed04/2017 117L rye` "R8DMS��G A 21018 ,f 1117//$ SuSmit Original Only STATE OF ALASKA • 3KA OIL AND GAS CONSERVATION COMh1,,,SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubin❑ Operations shutdown ❑ Performed Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casin[ 1 j Change Approved Program ❑ Plug for Rednll ❑>erforate New Pool [l Repair Well n Re-enter Susp Well ❑ Other _Wellock Treatment_ n 2 Operator '4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑' Exploratory ❑ 180-032-0 3 Address. P O Box 196612 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99519-6612 50-029-20459-00-00 7 Property Designation(Lease Number). 8 Well Name and Number ADL0028311 PBU 06-15 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY, PRUDHOE OIL 11 Present Well Condition Summary. C ��� RE ED Total Depth measured 9540 feet Plugs measured 8069 feet true vertical 9327 98 feet Junk measured None feet ,JUN 0 4 2015 Effective Depth measured 8069 feet Packer measured See Attachment feet y� OG CC true vertical 7867 53 feet true vertical See Attachment feet �''r Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 92 20"91 5#H-40 30 28-110 2 30 28-110 2 1490 470 Surface 2650 15 13-3/8"72#N-80 29.78-2679 93 29 78-2679 93 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED ;U, 3 0 'ZGTrue Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 25 46-8084 74 25 46-7882 98 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) 29 78'-2679 93' Treatment descriptions including volumes used and final pressure. 2 GALS WELLOCK 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2076 94136 1314 0 308 Subsequent to operation 0 0 0 0 0 14 Attachments(required per 20 AAC 25 070 25 071,8 25 293) 15 Well Class after work. Daily Report of Well Operations E Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil 0 Gas ❑ WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt 315-181 Contact Nita Summerhays Email Nita.Summerhays(a�bp corn Printed Name Nit- Summerhays / Title Data Manager AV Sig "'"'�%//� �jj.-, / Phone 564-4035 Date 6/4/2015 rv--/14-1/5 RBDMS\1 JUN - 5 2015 Form 10-404 Revised 10/2012 Submit Ongmal Only Daily Report of Well Operations /4, ADL0028311 T/I/O=SSV/202/36. Temp=SI. Shell test to 2500 psi(Well lock). AL spool removed. OA cemented to surface. Integrals installed on OA&OA companion=inspection not current. Due to procedural issues,job postponed. Bled OA from 36 psi to 11 psi(all gas)to slop tank in 1.25 hrs. See log for additional details. Job incomplete. Final WHPs=SSV/200/11 4/5/2015 SV,WV&SSV=C. MV=O. IA&OA=OTG. 1710 hrs. T/I/O=1020/210/50. Temp=SI. MIT-T to 3000 psi&CMIT TxIA to 3000 psi,Cold OA shell test to 2500 psi (Well Lock). AL spool dropped. Tubing FL @ surface. IA FL @ 60'(4 bbls). OA cemented to surface. Heater trunk in wellhouse. Job postponed, discovered tree cap©5000+psi. Valve shop to re-torque affected flanges&PT. Job incomplete. Final WHPs=1020/210/50. 4/13/2015 Grease crew in control of well on departure. T/I/O=20/25/15. Temp=SI. Strap TOC in OA(pre wellock). Al spool removed Bled OAP to 0 psi in 5 seconds. Attempt to strap TOC in OA found cement in both casing valves. See log for details. Job complete. FWPs=20/25/0. 4/21/2015 SV,WV,SSV=C. MV=O. IA,OA=OTG. 12:00 T/I/O=SSV/50/23. Temp=Sl. Cold shell test to 2500 psi for 1 hr. No AL. OA has integral installed=inspection current. OA cemented to surface. Increased OAP to 2500 psi using 1 gal diesel. Appears their is good comunication between OA casing valve and OA companion valve as pressure tracked during LLR. Maintained 2500 psi on OA for 1 hr. LLR=.049 gpm. Bled OAP to 0 psi in—1 min. Monitor during RD,OAP increased 20 psi. Final WHPs=SSV/50/20. 4/29/2015 SV,WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1615. LLR tags hung. T/I/O= Temp=S/I(Obj:Welllock) T/I/O=94/57/4 Pumped 5 bbls neat methanol, followed by 590 bbls 1801 crude down IA,taking returns up TBG and down FL of well 06-14.to warm OA for a WellLock treatment. Bleed IA and OA to starting pressures. Hung info tags on casing valve and wing valve. hung AFE sign on Master valve.SV, 5/3/2015 WV,SSV=closed, MV=open, IA and OA=OTG. FWHP's= 200/50/4 T/I/O=SSV/60/40. Temp=SI. WHPs(Pre Wellock). No AL. 3150 psi above SSV. Heater installed in wellhouse. Rig-up crew on location to rig up hardline to tree cap. Hardline crew will bleed tree above SSV to 0 psi. 5/3/2015 Rig-up Crew in control of well on departure. T/I/O=SSV/60/18. Temp=SI. Wellock treatment. AL spool dropped. Heater is being used to heat well house&is working properly. Bled OAP to 0 psi< 1 min. Pumped 2 gallons of Wellock into cemented OA. Well head temp 92°@ 9 o'clock position. Pumped 1qt Musol into OA&OA companion valves. Job Complete. See log for details. Final WHP's=SSVNAC/80. 5/4/2015 SV,WV, SSV=C. MV=O. IA,OA=OTG. 2100. T/I/O=SSVNAC/40. Temp=SI. WHPs(eval wellock). No AL. Heater installed in well house working properly. Wellhead temp=57°. Well head temp decreased 50°,OAP decreased 20 psi overnight. Close 2nd vent to add more heat to well head. Tree cap @ 0 psi. SV,WV, SSV=C. MV=O. IA,OA=OTG. 23:25. 5/6/2015 FLUIDS PUMPED BBLS 17 METH 941 CRUDE 958 TOTAL FLUIDS PUMPED GALS 2 W ELLOCK 3.95 DIESEL 5.95 TOTAL a, N 0 m N N- O N _ COL1) LOM N NO O Ln Ln L O CD 00 00 CO N- N- I,- r N- r.- Cfl CO CO CO Q M N N (xi N 4 M V r t O MM OD r N 0 a, C) CO OO O) O r N N N O COM M in Ln p CO O) O) C) C) 0 0 0 0 0 0 O O O O O O 00 OO 00 00 00 6) 6) 6) O) O) C) C)) C) O) O) H CC ❑ W Z ❑ ❑ O w 0 H H J a o g g Y U O OO O p w Y Y H H 00 N V (0 N OO m Ln Ln M N N O O Ln _ _ J U U w w t O O A 0 0 ICO u) Z N- N- N- N- N- d d OO M N N ao 4 M d' rr 6 cCO OO QQQw 01 dm ' N- aoOOrrCVN CVMMM to UUUJJw ❑ ❑OmOAT0000000 OOOO O Z ZZ 0 ❑ ❑ J JO p a0 co 00 a0 CO CT O O CA CA O CA O CA 6) « < I000- 1±10- > Q < = ❑ ❑ 0_ H a H U O U W ¢ ❑ H ❑ W W W 0_ H H Q ° Q a) N M t V V V O V CO Ln CO M CO Cn Ln OO O M szt Q O V I- O O r N N COM M V V Ln CO CO C W r N N N N N N N N NNNN N m M O O O CA CA CA 6) CA CA O O CA O O CA E N N a) -C 2 a cn = U O Ln Ir CL e 2 2 2 O w 0 Lan v0i 0 (4-6 Q N a � O c: 0 ~ t O 4 4 4 O M a) Ln CO M O CO Ln 00 O CO Qa,a O N Ln oO O r r N N M M CO �t V Ln CO r r r r N N N N N N N NNNN N }J Q O O CT O O CT O O O CT 6) CA C) CT CA CA CT MI m L a, 0 2 L CD a 130 U c o m V) U) o Cn (n C/) M (n U) O) U) M (n U) U) m m m m O_ m 0 O m 0 m O 0 0 m O 0 y m m m m m m m m m m m m m m m m a 0 t a) a ❑ w J DLU W a WI- 0 a) CT O O O O O m O) O CA O O ° O O O ❑ J 0 0 0 0 0 0 0 0 0 0 0 0 O O C) O O 0 j D U C O O O 0 0 0 0 0 0 0 0 0000 O W J J Z p N N N N N N N CV N N N N N N N N Z L Q. a < NWW N t1 .� O) a M M M OIM M O) M M a O O a • W W W J W W N N N N N N N N N N N N N N N N Z a U U U W W W W p_ r = = = = = = = = r r r r r r r Q ❑ ❑ ❑ J J ❑ ❑ CC a J_ _J O Q Q m m W LL wO o a IY a) E Wa Z Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln Ln co co ; r r r 1 = = = = = = 11111 LL 0_ Ln O a N a' WL CO LO O O m M CO CO O CO O O CO COO CO ma a MO J O O W 0_ C7 0 0 0 C7 0 0 0 0 0 0 0 0 0 0 C7 Q Q m m W W Ln U) a a' 0 Q o O O O o OO O O O O a0 — O N NO I� N- O Ln o CO- In 0 V V LC) Ln N- N- N •U y O O O O O O O O O i O) N- ti LC) CO (O CO M 7 V CO 00 N V • d) V (0 CO Cil ti Cb co V co O N co co N O) co CO N CO CO O) N O) O) O) O CO Ln LC) CO O) (Ni - LP) CO O M N N- CO - N- CO N CO CO CO N- CO CO 0) 6) N N- H O) N- 6) LC) CO CO O CO O) CO CO CO N O M LO LC) O N- L() CO co O) O O) L() co N N- oo O) O O N N N- N N- CO a) O N- N- Lf) 0) CO N- O Lf) Lf) CO N O V CO CO CO O CO CO V Ln CO O CO CO CO 0) O) N CO 4-1 Q CN- O N M O CO Ln CO CO 0 0 0 LC) C) � CO N NCO CD N CD OD CO N N C ▪ O ... e • Q 1- aocorn o co U = J J C/) co O Z CO C 0) 4t *k *k 4# J (.O J N •N to N CO A - O) co co co N - N pp oO in in � � N 0 O O) 4 4 L C3 03 O N , N- V CO Lf) Lf) C CO N CO Ln CO N N CO O d CO - LO N CO J W W W C 0 0 0 y U W W W W ca 22 QCT U c) CC CC CC Z Z W W W W W W 01-' HHZZZDj 0Z Z Z J J J Packers and SSV's Attachment ADL0028311 SW Name Type MD TVD Depscription 06-15 PACKER 2935.69 2935.69 7" Baker ZXP Top Packer 06-15 PACKER 7946.78 7747.58 4-1/2" Baker S-3 Perm Packer 06-15 PACKER 8201.69 7997.95 5" Baker ZXP Top Packer TREE= 4-1/16"5M CAN WELLHEAD= FMC 06-15 0_15 S, .:TY NOTES: ***CHROME TBG&LNR*** • ACTUATOR= BAKER C KB.ELEV= 68' BF.ELEV= ? ( ►.�i j , I KOP= 5200' ��0 •*• 1736' H 9-5/8"HES CEMENTER Max Angle= 28°@ 5700' , , Datum MD= 9079' 2076 —14-1/2"HES X NIP,ID=3.813" Datum TVD= 8800'SS , 2932' H9-5/8"X 7"BKR ZXP LTP, ID=6.29" 9-5/8"CSG,47#, L-80 HYDRIC 563,ID=8.681" -1 1753' 13-3/8"CSG,72#, N-80 BTC,ID=12.347" — 2678' �` 2950' H 9-5/8"X 7"BKR FLEX LOCK LNR HGR, ID=6.30" • GAS LIFT MANDRELS TOP OF 7"SCAB LNR -{ 2932' 01 1 ST MD TVD DEV TYPE VLV LATCH PORT DATE �� • 4 3373 3373 0 KBG2-1R DOME BK 16 10/07/08 A RJ 3 5585 5566 23 KBG2-1R DOME BK 16 10/07/08 �. 2 7154 6978 19 KBG2-1R DOME BK 16 10/07/08 7"SCAB LNR,26#,L-80 BTC XO TO — 7793' ` J 1 7846 7649 12 KBG2-1R SO BK 24 10/07/08 13CR-80 VAM TOP r• 0 I ' 7912' —4-1/2"HES X NIP, ID=3.813" 0. Minimum ID = 3.725" @ 8069' 41 11 # 7943' 7"X 4-1/2"BKR S-3 PKR, ID=3.938" 4-1/2" HES XN NIPPLE 0.�'-' -N. / i ; 8007' 11-1/2"HES X NIP, ID=3.813" 9-5/8"CSG,47#,L-80 BTC XO TO S-95 BTC — 8065' I- 4+1 • s'1 . 1 8069' I-{4-1/2"HES XN NIP, ID=3.725" • 4-1/2"TBG, 12.6#, 13CR-80 VAM TOP, —I 8081' �.� 8069' —4-1/2"PXN PLUG(12/09/09) .0152 bpf, ID=3.958" 41 i ' + 8081' —4-1/2"WLEG,ID=3.958" TOP OF 4-1/2"SCAB LNR 8198' .. N i 8198' —7"X 5"BKR ZXP LTP w/HMC LNR HGR �� 1-" A'►. &XO, ID=4.276" .44 TOP OF 7"LNR 8299' 40. A. i•1� 1St 8299' —BOT TIEBACK SLV,ID=? I 7"SCAB LNR,26#,13CR-80 VAM TOP, - 8305' Le 1. e/r 8305' H9-5/8"X 7"BOT HYDRA LNR HGR,ID=? .0383 bpf, ID=6.276" �� • 1• 1 1• • 9-5/8"CSG,47#,S-95 BTC,ID=8.681" —I 8623' I �� , �. 8827' —I 7"MARKER JOINT PERFORATION SUMMARY 4 1 REF LOG:BHCS ON 07/20/80 �• 1 1 ANGLE AT TOP PERF:4°@ 9100' •4 • Note:Refer to Production DB for historical perf data 4 SIZE 1 SPF 1 INTERVAL Opn/Sqz 1 DATE 1+ SEE PAGE 2 FOR PERFORATION DATA '. I I I I �� Q4,- ; • 06-15 , 41, 1 1 I • • • •• Li • •,� 1 I I . i , • 4 , 4 Al • 1 0� G 1 1 • 0 , 0 , \ , 0 , • 'c•' •PI iH.11 • i •, •e. , PERFORATION SUMMARY • , • • REF LOG:BHCS ON 07/20/80 ,• ANGLE AT TOP PERF:4°@ 9100' • • • Note:Refer to Production DB for historical perf data ,• • SIZE SPF IN I LRVAL Opn/Sqz DATE 4 ,• • L 3-3/8" 4 9100-9104 S 07/17/87 , • 3-1/8" 4 9124-9144 S 10/05/85 •• • 3-1/8" 4 9154-9174 S 10/05/85 •• • 3-1/8" 4 9184-9200 S 07/22/90 • 3-3/8" 4 9200-9204 S 08/20/94 ., 3-3/8" 6 9213-9233 0 04/11/09 • I 3-3/8" 6 9216-9226 S 08/15/91 • 2-7/8" 6 9225-9250 0 06/28/08 •• 3-1/2" 6 9225-9250 0 01/13/09 • 3-3/8" 4 9226-9245 S 06/20/08 •� 3-3/8" 4 9248-9263 S 06/20/08 • 3-3/8" 4 9263-9264 S 08/04/91 •• , , •, , ►. •voce• .•.i 1•,•,•,•,•,•O DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/31/80 ORIGINAL COMPLETION 10/13/08 JLJ/PJC GLV C/O(10/07/08) WELL: 06-15 12/18/80 LAST WORKOVER 10/23/08 PJC DRLG DRAFT CORRECTIONS PERMIT No.:►1800320 06/21/08 D16 RWO 01/14/09 RLM/SV REPERF(01/13/09) API No: 50-029-20459-00 06/25/08 GJB/SV GLV C/O(06/25/08) 05/30/09 ???/TLH PERF(04/11/09) SEC 2,Ti ON,R14E,355'FSL&1753'FEL 06/29/08 JKD/SV ADPERF(06/28/08) 12/17/09_ MBM/SV SET PXN PLUG(12/09/09) 08/27/08 ?/JMD DRLG DRAFT CORRECTIONS BP Exploration(Alaska) OF T "\����js THE STATE Alaska Oil and Gas 0, ;,. , ofALASIc:A Conservation Commission ____ wet t 6 _ 333 West Seventh Avenue `w GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALASY'P' Fax: 907.276 7542 www.aogcc.alaska.gov Jessica Sayers E� ;" , Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 06-15 Sundry Number: 315-181 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 20.1---r4 4-- Cathy P Foerster Chair DATED this Z�d y of April, 2015 Encl. • RECEIVED STATE OF ALASKA MAR 3 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon Plug for Redrill❑ Perforate New Pool❑ Repair Well[ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ ore Extoension i'- 'M Operations Shutdown Re-enter Susp MUD Stimulate Cl Alter Casing❑ Other Well Lock l ran, ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. _Exploratory ❑ Development 0 • 180-032-0 • 3.Address. Stratigraphic ❑ Service ❑ 6.API Number. P O Box 196612,Anchorage,AK 99519-6612 50-029-20459-00-00- 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU 06-15 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL0028311' PRUDHOE BAY, PRUDHOE OIL - 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured). Junk(measured): 9540 • 9328 • 8069 7868 8069 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91 5#H-40 30 28-110.2 30.28-110.2 Surface 2650 13-3/8"72#N-80 29.78-2679.93 29.78-2679.93 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner • See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 25 46-8084.74 Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments. Description Summary of Proposal ❑ 13 Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory El Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/7/15 Commencing Operations: Oil 0 . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date. WINJ ❑ GINJ El WAG ❑ Abandoned ❑ Commission Representative. GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jessica Sayers Email Jessica.Sayers@BP.Com Printed Name Jessica Sayers Title Well Intervetions Engineer Signature hone 564-4281 Date Prepared by Garry Catron 564-4424 (YV- 3/310//S— ( /3%s( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 61-'g I Plug Integrity ❑ BOP Test ❑ Mechanical Integnty Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No I" Subsequent Form Required: / 0 —4 v 2.7APPROVED BY Approved by. , � �(L ei, 7-1.-- 3/31/15— COMMISSIONER THE COMMISSION Date: _2 _/S 0 . I I // 2Form 10-403 Revised 10/2012 Approved application is valid or 1 mont s rAL" ate o proval. Submit Form and Attachments in Duplicate RBDM ADR - 6 2015 /* 3/,/c a) Q o 0 0 0 0 0 0 0 car 1 NOti CI" r� Ln C0 0 LO V Lf) I- N- N U ; o 0 0 0 0 0 0 0 i 0) It) N- N CO M M Mv •,- 0ocoNv0) Ca CO CO CO N- CO CO rn rn LO CO N CO LO CO CO M O Ncb ai co NI- - M Lo O L[) V N- T-- co O r M O O co co 00 — co N I- O) 6) O 0) O) 00 LO CO CO CO O CO CO CV O M LC) N- 6 O co in N- co O O 6) M O N- N () CO N N 00 x- N CO CO C a) CO L() f� V Lo r O O CO Ln O N CO 00 V 00 r M NCO CO N- co CA O N V Q QM LO - CO CO 00 CO O CO Ln CO CO O) 0) O CO co� N- N O) O 0) M N NcoN- C a) co co C) � ci) _1 _IaoocooJZ N 4 J J CO N • • V *k *k N r _ CO CA _ R ao 00 60 CV N _ 00 L[) LC) L) I- ! ch N CA O O co O � C7 N- co V LO C CO ,-,1° N- CO N N CO LI) co J W W Q Q Q I- 000 U W w w w U 0 ( c W Z W W W W W W Q I- I I Z_ Z_ JZ_ UZZZJJU) Perforation Attachment ADL0028311 Well Date Perf Code MD Top MD Base TVD Top TVD Base 06-15 12/9/09 BPS 9100 9104 8889 8893 06-15 12/9/09 BPS 9124 9144 8913 8933 06-15 ' 12/9/09 BPS 9154 9174 8943 8963 06-15 12/9/09 BPS 9184 9200 8973 8989 06-15 12/9/09 BPS 9200 9204 8989 8993 06-15 12/9/09 BPS 9213 9216 9002 9005 06-15 12/9/09 BPS 9216 9225 9005 9014 06-15 12/9/09 BPS 9225 9226 9014 9015 06-15 12/9/09 BPS 9226 9233 9015 9022 06-15 12/9/09 BPS 9233 ' 9236 9022 9025 06-15 12/9/09 BPS 9236 9238 9025 9027 06-15 12/9/09 BPS 9238 9245 9027 9034 06-15 12/9/09 BPS 9245 9248 9034 9037 06-15 12/9/09 BPS 9248 9250 9037 9039 06-15 12/9/09 BPS 9250 9263 9039 9052 06-15 12/9/09 BPS 9263 9264 9052 9053 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCC FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028311 SW Name Type MD TVD Depscription 06-15 PACKER 2935.69 2935.69 7" Baker ZXP Top Packer 06-15 PACKER 7946.78 7747.58 _4-1/2" Baker S-3 Perm Packer 06-15 PACKER 8156.91 7953.88 5-1/2" Baker SAB Packer 06-15 PACKER 8201.69 7997.95 5" Baker ZXP Top Packer , t • To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 03-16-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: 06-15 WeIlLock MicroOA Treatment Objective This program is for treating the micro-annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. The liquid leak rate has been established at 0.05 gallons per minute at 3000 psi. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro-annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A followed by diesel, should be flushed across the OA valves to keep WeIlLock from setting up. Well Detail Current Status: Not Operable — P Previous Test: 12-09-09 MIT-T passed to 2500 psi Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas), highest observable pressure 1250 psi; Last H2S Reading: Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 75°-80° F throughout the entire job Relevant History: > 06-21-08: RWO completed cement OA to surface Well Program: 1 D Pump 870 bbls hot, 180° F, crude down IA to heat up the OA. 2 D Over flush diesel out of OA void with several gallons of 2% KCI, 120° F, using the triplex. Purge void with nitrogen, displacing as much KCI as possible. 3 D *** Switch to diaphragm pump. Pump 1.5 gallon WeIlLock pill. Take returns 1:1 in grounded bucket. 4 D Maintain 3,000 psi for two hours by pumping KCI at signs of pressure fall off. This is to squeeze the WeIlLock into the microannulus. Record pressure and temperature readings on casing every hour. Do not exceed 3,500 psi. 5 D Swap to Musol A in suitcase pump, crack needle valve on returns line to grounded bucket. Maintain 3,000 psi on returns line. Pump 1 gallon of Musol A through pump, across valves to returns. 6 D Shut-in suitcase pump and returns. 7 D Swap to Musol A through triplex. Pump 1 bbl of Musol A across well to returns to durms, maintaining 3,000 psi. Swap to neat meth in triplex. Overflush Musol A with neat meth, maintaining 3,000 psi. 8 D Shut down triplex with 3,000 psi on well for one week. 9 D Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 10 D After seven days, MIT-OA *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period. 2 of 3 • ',i± 4-1/16'51ACIV :v-_,LHEAD- cm,- 06-15 SAFE i Y NOTES "'CHROME TBG 8.L14?"" 140 /1$ I .ij 1736' 9-5.. -t 1.23.ENtH2 I IBlua_u= sort' I i 2076' H4-117-LS XHP,D=3.613'I Collura IVO_ 0300*SS 19-x'CSG,478,1- 0 HYMN_553,ID=8.681' H 1753' f,:' :I 293Z Hg_fir, o14iDPLiP =629' 413 31N'CSG,72f,14 b0 BTC,n=12.317 H 2678' . . 1950" Hg-a18-x r 80RR.@c Loaf Lie I R,D=6_30-I /l1 P' OAS LF1 MI S H 2932' I 1-._r>^. r:,: ., L>a,^ 111 1 111 1 SI w D TVD tEV TYPE VLV LA 01 PORT ATE 4/1 m I� _m 4 3373 3373 0 KBG2-1R DCI1E BC 16 1007/06 14 1 3 55E 5606 23 1.3362-1R DOME 9C 16 1007106 .0 I 2 7154 6976 10 180G2-1R 00E O( 16 1007/06 r SCAB LW,268,L-60 Bit XO TO T793' 1 is 1 71.1% 1649 12 10102-1R 90 9C 24 1007106 13CR-80 VAM TCP f 14 14 1 7912' H, `:IelD fXNP. a3.813'I / ► Minimum ID=3.725"@ 80619" Eli 11 7943' I—Irx4-1.7 fsvcszs�RRD.3me' 4-1/2"HES XN NIPPLE ,41, =1/ A El( 8007' I--I4-1t2.i 111 its xP,o=3.atr I o-51r C94 478,L-60 Bit xO ro 95 s t H 8065' I- :+ , , i11 ".1 8069' •4-117 I-LS X N I�D.3.725' 4-1,7 79G,129I,13CR410 yaw r(x'. H 8081' I.- / NM 1 ...... obi 6069 ;CLQ 1'*P4 PLUG(1209 0152 bpi,D*395fr I 01 8081' 4-112'nt`m.0.3.058 (TOPCF41,7soul LNRFI 8198' V 11 8198' 7'XS'OMR 2WLTPsIHOC LNF:1-G �� .1` &X0,D.4276" 614 61 /1 1� 1 TOPC31=r LAIR 82'99' - 6/111 711 �,;, ,, 8299' HOOT T�UXsLV.D'o?J r SGB LNR,20,130410 YAM TOI J 8305 ,4 I I l 8305 H x r nor HNRYDRA L1C D=? .0363 bpi,D.627W `+ 1 1 1 1 :1 �/ 1 19 ss' 4718 S-05 87[D=d68t' H 8623' ;. 4 • ♦ 1 �1 es'rr HrIMIEBIJOMT FBFdi111a1 SJ ARr ,. a RE LOCO BH(s ON 07P�T60 0 . ANGLEATTOP P$P 4'09100 .1 Nor Refer to Raur>fon OB for hfadllt a1 pert data .1 9IE 18PP I I8I AL I OP1�I LATE �! ISEEPMOE2 FOR F FWORA11a4 DAI.A 1.4 1 i`. 41 ; 1( 4-1,7SCAB LAIR,12116,1WASS VAN TOP, 9359' vp 1 X010 L-110 6T o . h 4-1,7 toms LNR 1261,1-80 BT, I 9439' h 0.0152bpf.D=3958 1I 1 F131139467 +:1i,••••ILA 4/`444 4/4/4 .1111*.111,111114 I r UR,294',1-8D BIC,.0371 bpi,Ds 6.164'J I 9535' 1.43.0-I.6I4 W 7t RE'r L..0.111.1_N`S DATE FEV BY CO4A.12,4'5 F+LI.HUEGAY UNIT 07,31180 ORIGINAL GUMP L ET ON 10/19/06 JL$JC GLV CID(100703) 891: 06-15 12/16180 LA5T WORT J V F. 10/2308 PJC DRLG DRAFT 00116i.:t IC+nt FEW Na 11600320 04121M6 OVA RWO 01/144 R NSV R6ERF(01/13/09) AR Noe 50.029-20458-00 o6/23106 C48/SV OLv Uri;06,25' e".. 05/3009 77T/M-1 PERF(0111/09) =:LC2,00il,R11E.358 FOL a 1753'P$ 06/29106 J COSV A13I134.1-1.€6,2&:o: 12/174 LOWS/ SET PAN F LUO(12/0809) '_:627I06 1,.J1.13 LW.LL;DRAFT'L IZ%r _ i'_>'IS BP Expda atlon)Alas kal 3of3 ~ ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~~~'~~i~l~ JAN ~' ~ 201' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 06 Dear Mr. Maunder, by ~_ ~3~ `~ ~~~~ 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 06-02 1770780 50029202820000 NA Sealed NA os-o3A 1951520 50029201860100 NA Sealed NA os-o4A 2001020 50029201790100 NA Sealed NA 06-05 1780200 50029202980000 NA Sealed NA o6-o6B 2050980 50029202010200 NA Sealed NA os-o7 1780210 500292o2ssoooo NA Sealed NA o6-oaA 1951950 50029203000100 NA Sealed NA os-o9 1790730 50029204000000 NA Sealed NA os-1oA 1981960 50029204020100 NA Sealed NA 06-11 1791100 50029204280000 NA Sealed NA 06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009 06-13A 2061020 50029204570100 NA Sealed NA 06-148 2090120 50029204580200 NA Sealed NA os-15 1800320 5002920a59000o NA Sealed NA 06-16 1800330 5oo29zoasooooo NA Sealed NA os-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 06-218 2080990 50029208020200 NA 6 NA 42.50 12/14/2009 Os-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 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMM ION ~tECEIVE APR 7 Z~Q9 REPORT OF SUNDRY WELL OPERATIONS ~IA~~A n,t Q. r_n., ~~~_ -._~.__. . 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development !- Exploratory ~ 180-0320, 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20459-00-00 , 7. KB Elevation (ft): 9. Well Name and Number: 68 KB PBU 06-15 8. Property Designation: 10. Field/Pool(s): ADLO-028311 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9540 - feet Plugs (measured) None true vertical 9327.98 - feet Junk (measured) None Effective Depth measured 9467 feet true vertical 9255 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 1530 520 Surface 2678 13-3/8" 72# N-80 Surface - 2678 Surface - 2678 4930 2670 Intermediate 8622 9-5/8" 47# S-95 Surface - 8623 Surface -8413 6870 4760 Liner 1236 7" 29# L-80 8299 - 9535 8094 - 9323 8160 7020 Scab Liner 5374 7"26#13CR80 2932 - 8306 2932 - 8101 7240 5410 Scab Liner 1241 4-1/2" 12.6# L-80 8198 - 9439 7994 - 9227 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 24 - 8081 0 0 - Packers and SSSV (type and measured depth) 5-1 /2" Baker SAB Packer 7943 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): •~ "{~~ (n,] fin`{! ~!}~~/~pj~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1869 92220 1320 408 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development ~/ - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~~ Gas WAG GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 4/13/2009 Form 10-404 Revi d 4/2006 ~~ ~~ ay ) ~ Submit Original Only~l{ F ~ F- . ~,. ~ a ~ (2~~~ ~~~ 1 ~~t I it t ' 4 Pig 06-15 180-032 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06-15 1/8/81 PER 9,124. 9,144. 8,913.02 8,932.97 06-15 1/8/81 PER 9,154. 9,174. 8,942.94 8,962.89 06-15 1/8/81 PER 9,184. 9,204. 8,972.86 8,992.81 06-15 1/13/81 APF 9,124. 9,144. 8,913.02 8,932.97 06-15 1/13/81 APF 9,154. 9,174. 8,942.94 8,962.89 06-15 1/13/81 APF 9,184. 9,204. 8,972.86 8,992.81 06-15 1/12/85 RPF 9,154. 9,174. 8,942.94 8,962.89 06-15 1/12/85 RPF 9,124. 9,144. 8,913.02 8,932.97 06-15 10/5/85 SQZ 9,124. 9,204. 8,913.02 8,992.81 06-15 10/7/85 APF 9,184. 9,204. 8,972.86 8,992.81 06-15 10/7/85 APF 9,216. 9,236. 9,004.78 9,024.72 06-15 7/2/87 APF 9,250. 9,264. 9,038.69 9,052.65 06-15 7/3/87 APF 9,100. 9,104. 8,889.08 8,893.07 06-15 7/17/87 SQZ 9,100. 9,264. 8,889.08 9,052.65 06-15 8/5/87 RPF 9,248. 9,264. 9,036.69 9,052.65 06-15 8/5/87 RPF 9,216. 9,238. 9,004.78 9,026.72 06-15 7/22/90 RPF 9,200. 9,204. 8,988.82 8,992.81 06-15 8/4/91 SQZ 9,200. 9,264. 8,988.82 9,052.65 06-15 8/15/91 APF 9,238. 9,245. 9,026.72 9,033.7 06-15 8/15/91 RPF 9,226. 9,238. 9,014.75 9,026.72 06-15 8/15/91 RPF 9,248. 9,263. 9,036.69 9,051.65 06-15 8/20/94 RPF 9,200. 9,204. 8,988.82 8,992.81 06-15 6/9/00 SPS 9,151. 9,467. 8,939.95 9,255.16 06-15 6/22/00 SQZ 9,151. 9,200. 8,939.95 8,988.82 06-15 7/15/00 FCO 9,154. 9,164. 8,942.94 8,952.92 06-15 7/16/00 FCO 9,164. 9,175. 8,952.92 8,963.89 06-15 7/16/00 SPR 9,175. 9,329. 8,963.89 9,117.49 06-15 4/9/08 BPS 8,189. 9,264. 7,985.46 9,052.65 06-15 5/31/08 BPS 8,148. 9,100. 7,945.12 8,889.08 06-15 6/28/08 RPF 9,225. 9,250. 9,013.75 9,038.69 06-15 1/13/09 RPF 9,225. 9,250. 9,013.75 9,038.69 06-15 4/11/09 APF 9,213. 9,233. 9,001.78 9,021.73 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 06-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/11/2009*~*ON LOCATION SSV =OPEN, SWAB =CLOSED, IA/OA =OPEN TO GAUGES, I SWELL SHUT IN*"" j INITIAL T/I/O = 1800/600/0 PSI PERFORATE FROM 9213-9233' WITH 3-3/8" 20' HSD POWER JET GUN FINAL T/I/O = 1800/600/0 PSI 1 LEAVE LOCTION SSV =OPEN, SWAB =CLOSED, IA/OA =OPEN TO GAUGES, I WELL SHUT IN *''''JOB COMPLETE"** ~ FLUIDS PUMPED BBLS 1 diesel 1 METH 2 Total STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVE JAN 2 1 2009 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated S aS Corls. Commjg Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension pgnchorage Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~ 180-0320 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20459-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 68 KB i PBU 06-15 ~ 8. Property Designation: 10. Field/Pool(s): ADLO-028311 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present We{I Condition Summary: Total Depth measured 9540 , feet Plugs (measured) None true vertical 9327.98. feet Junk (measured) None Effective Depth measured 9467 feet _~ ,, ryry ~"i' ~~ ~''r~ ~ ~ ~ ~ ~-~ M Sk ~ ~ }~ {~ f' true vertical 9255 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 1530 520 Surface 2678 13-3/8" 72# N-80 Surface - 2678 Surface - 2678 4930 2670 Intermediate 8622 9-5/8" 47# S-95 Surface - 8623 Surface -8413 6870 4760 Liner 1236 7" 29# L-80 8299 - 9535 8094 - 9323 8160 7020 Scab Liner 5374 7" 26# 13CR80 2932 - 8306 2932 - 8101 7240 5410 Scab Liner 1241 4-1 /2" 12.6# L-80 8198 - 9439 7994 - 9227 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1 /2" 12.6# 13CR80 24 - 8081 0 0 - Packers and SSSV (type and measured depth) 5-1/2" Baker SAB Packer 7943 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1717 77870 1164 585 Subsequent to operation: 1854 92298 1320 480 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas r WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Manager Signature Phone 564-4944 Date 1/20/2009 i®r r°: ,~.. Form 10-404 evised 04/2006 ~ ~ ~-~ ~'~~- r~~F~ ~> i# t~t~`j ~-~~ Submit Original Only 06-15 180-0320 PERF ATTACHMENT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06-15 1/8/81 PER 9,124. 9,144. 8,913.02 8,932.97 06-15 1/8/81 PER 9,154. 9,174. 8,942.94 8,962.89 06-15 1/8181 PER 9,184. 9,204. 8,972.86 8,992.81 06-15 1/13/81 APF 9,124. 9,144. 8,913.02 8,932.97 06-15 1/13/81 APF 9,154. 9,174. 8,942.94 8,962.89 06-15 1/13/81 APF 9,184. 9,204. 8,972.86 8,992.81 06-15 1/12/85 RPF 9,124. 9,144. 8,913.02 8,932.97 06-15 1/12/85 RPF 9,154. 9,174. 8,942.94 8,962.89 06-15 10/5/85 SQZ 9,124. 9,204. 8,913.02 8,992.81 06-15 10/7/85 APF 9,184. 9,204. 8,972.86 8,992.81 06-15 10/7/85 APF 9,216. 9,236. 9,004.78 9,024.72 06-15 7/2/87 APF 9,250. 9,264. 9,038.69 9,052.65 06-15 7/3/87 APF 9,100. 9,104. 8,889.08 8,893.07 06-15 7/17/87 SQZ 9,100. 9,264. 8,889.08 9,052.65 06-15 8/5/87 RPF 9,216. 9,238. 9,004.78 9,026.72 06-15 8/5/87 RPF 9,248. 9,264. 9,036.69 9,052.65 06-15 7/22/90 RPF 9,200. 9,204. 8,988.82 8,992.81 06-15 8/4/91 SQZ 9,200. 9,264. 8,988.82 9,052.65 06-15 8/15/91 APF 9,238. 9,245. 9,026.72 9,033.7 06-15 8/15/91 RPF 9,226. 9,238. 9,014.75 9,026.72 06-15 8/15/91 RPF 9,248. 9,263. 9,036.69 9,051.65 06-15 8/20/94 RPF 9,200. 9,204. 8,988.82 8,992.81 06-15 6/9/00 SPS 9,151. 9,467. 8,939.95 9,255.16 06-15 6/22/00 SQZ 9,151. 9,200. 8,939.95 8,988.82 06-15 7/15/00 FCO 9,154. 9,164. 8,942.94 8,952.92 06-15 7/16/00 FCO 9,164. 9,175. 8,952.92 8,963.89 06-15 7/16/00 SPR 9,175. 9,329. 8,963.89 9,117.49 06-15 4/9/08 BPS 8,189. 9,264. 7,985.46 9,052.65 06-15 5/30/08 BPS 8,148. 9,100. 7,945.12 8,889.08 06-15 5/31/08 BPS 8,148. 9,100. 7,945.12 8,889.08 06-15 6/28/08 APF 9,225. 9,250. 9,013.75 9,038.69 06-15 1/13/09 APF 9,225. 9,250. 9,013.75 9,038.69 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 06-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ~ 1/10/20091T/I/0=20/1130/20. Temp=S1. TIFL-PASSED (pre CT pert/stim). No AL. OA has ~ 3" integral installed. TBG FL @ 30'. IA FL @ 4248'. Stacked out well to ;1410/1130/20 psi in 4.5 hours. TBG FL fell 1932' to 1962' during stack out. Bled 31AP to production from 1130 psi to 250 psi in 3.5 hours. Monitored for 30 ;minutes, WHPs & IA FL unchanged. Final WHPs= 1410/250/20. =SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. . 1/12/2009'CTU #5 w/ 1.75" OD CT. Objective: memory log/pert. MIRU CTU. Load well with 1 %KCL and establish pre-pert injectivity: 1.5 bpm at 1520 psi, 1.0 bpm at ',1260 psi, 0.5 bpm at 660 psi. MU and RIH with PDS memory GR/CCL logging tools with a 3.5" OD SJN for drift.POOH download memory tools. "**""" Job ;Continued on 1/13/09 *""***" 1 /13/2009 CTU #5 w/ 1.75" OD CT. Objective: memory log/pert. **"" Continued From ....1/12/09 "**""* Download memory tools make depth correction of - 6' . MU RIH 25' 3.5" PJ OMEGA 3506 GUNS 6 SPF,3506 PJO CHARGE, 60 DEGREE 'PHASING. Correct depth at flag. Perforate interval 9225' - 9250' elmd (ref: SLB PPROF 10/25/00). Pull to surface. Perform post-perforation injectivity test: 1.5 bpm at 1090 psi, 1.0 bpm at 880 psi, 0.5 bpm at 500 psi. Freeze protect well. RDMO. Release well to operations. Job complete. FLUIDS PUMPED BBLS 144 60/40 meth 110 KCL w/0.6% SAFELUBE 90 KCL 488 Total • s ~~ ~ ,~ ;~•~. tk: _ -e:~ y ProActive Diagnostic Services, Tnc. To: AC!GCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the followln~ • ;, BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (90~j 245-8952 ~~]%> ~i~J)<~i 1) Coil Flag/ Jewelry Log 12,Jan-09 06-15 2) ~, I ~, Signed : ~ ;%~i Print Name: EDE 50-029-20459-00 ~~ .~ Date : `' ~ -~ !,~ ~~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FA1C: (907)x45-88952 E-WAIL : Is~~~nehoracle(a~mr?rrtorVlog carts WEBSITE : uv~;vtia/~r~roerYSa~s~y_Ic~~ .c~p~n _,.. C:\DocumenLS and Settings\Owne~lDesktop\TYans~nit BP.docx -- -~ STATE OF ALASKA~i?~-0- 8' '` " ;~'~ ~~." ~ ~~ `~"" ALr~ OIL AND GAS CONSERVATION COM~ION ,~~1~ ~ 2[]~~ REPORT OF SUNDRY WELL OPERATIONS ~dasr ~. t .~~ 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing - ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development- ^ Exploratory 180-032 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20459-00-00 - 7. KB Elevation (ft): 68, 9. Well Name and Number: PBU 06-15 - 8. Property Designation: 10. Field /Pool(s): _ ADL 028311 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9540' % feet true vertical 9328' ~ feet Plugs (measured) None Effective depth: measured 9467' feet Junk (measured) None true vertical 9255' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2678' 13-3/8" 2678' 2678' 4930 2670 Intermediate 8622' 9-5/8" 8622' 8413' 6870 4760 Production Liner 1236' 7" 8299' - 9535' 8094' - 9323' 8160 7020 Scab Liner 5374' 7" 2932' - $306' 2932' - 8101' 7240 5410 Scab Liner 1241' 4-1/2" 81~~143a;~ 7,9;4' -~2~T2008 8430 7500 ~4~~l11~~ ~1,1L Perforation Depth MD (ft): 9225' - 9250' Perforation Depth TVD (ft): 9014' - 9039' 4-1/2", 12.6# 13Cr80 8081' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer 7943' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing. Cut, pull and dress 9-5l8" off to 1750'. Run 9-5/8"tieback to surface and cement w/ 121 Bbls Class'G' (679 cu ft! 586 sx). Run 7" Scab Liner (26#, 13Cr80); cement w/ 170 Bbls Class'G' (954 cu ft / 823 sx) and 30 Bbls Class'G' (168 cu ft 1 144 sx). Run 4-112" Scab Liner (12.6# / 13Cr80 / L-80) and cement w/ 60 Bbls Class'G' (337 cu ft / 288 sx). Run new 4-1 /2" Completion. Re-Pert (Post-Rig). 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 308-129 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: 0 Signature Phone 564-4628 Date ~ Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 ORIGINAL '~~ ~u~ 2 ~ 2ooa Submit Original Ogly ~ ~ Digital Well File ~ ~ Page 1 of 2 Well: 06-15 Well History Well Date Summary 06-15 4/7/2008 T/IA/OA=480/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre CTD) PPPOT-T RU 2 HP bleed tools onto THA 500 psi bleed to 0 psi. Pressured to 5000 psi for 30 minute test, 4950/ 15 minute, 4950/ 30 minute. Bleed void to 0 psi RD test equipment. Cycle or torque LDS "Standard style" (1) Broke pin all others were in good condition. PPPOT-IC RU 1 HP bleed tools onto IC test void 50 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3400/ 15 minutes, 3400/ 30 minutes. Bleed IC void to 0 psi, RD test equipment. Cycle or torque LDS "Standard style" (1) Broke pin all others were in good condition. *** 2 Broke LDS *** 06-15 4/8/2008 **** WELL SHUT IN ON ARRIVAL **** (pre rwo) DRIFT W/ 4.5" CENT & S. BAILER TO 8037' MD ****CONT ON WSR 4/9/08**** 06-15 4/8/2008 MIT-T to 1500 psi (Pre. RWO). Stand by for Slickline to finish drift run on Tbg. **** Job continued on 4-9- 08 WSR*** 06-15 4/9/2008 Called out to svc Swab and comp valve for Wire-line Bleed off tree cap to 0 psi /returned back to unit to svc and bleed off fora 2nd time around 2:30am. Heater on swab valve is FMC model 75 06-15 4/9/2008 ****CONT FROM WSR 4/8/08**** (pre rwo) DRIFT W/ 4.25" CENT TO 8178' MD ****WELL LEFT S/I TURNED OVER TO LRS UPON DEPARTURE**** 06-15 4/9/2008 *** Job continued from 4-8-08 WSR*** T/I/0= 600/0/0 Temp= SI Assist E-Line, MITT FAILED to 1500 psi (Pre RWO) Attempted to test CIBP to 1500 psi. Pumped 286 bbls crude down -T~na6 eT~o reams maintain test pressure. Final WHPs 100/0/0 *** IA/OA casing valves open to gauges at time of departure 06-15 4/9/2008 ***WELL SHUT IN ON ARRIVAL*** INITIAL T/I/O = 0/0/0. RAN LDL WITH SPINNER AND TEMPERATURE, FOUND PLUG TO BE LEAKING, SET ANOTHER CIBP ~ 8189' (5' ABOVE FIRST ONE), MIT-T FAILED. DID NOT CUT TUBING DUE TO DECISION FROM TOWN. FINAL T/I/O = 0/0/0 ***WELL LEFT S/I*** 06-15 5/30/2008 ***WELL SHUT IN ON ARRIVAL*** RIGGING UP E-LINE UNIT FOR IBP & JET CUT IN PROGRESS. ***CONTINUED JOB ON 31-MAY-2008*** 06-15 5/31/2008 T/I/O = 0/0/0 Assist E-Line MIT-T PASSED to 1500 osi (3rd attemntl {RWO Prep} Pumped total 2.2 bbls crude down Tbg to test IBP. Tbg lost 30 psi in 1st 15 min and 5 psi in 2nd 15 min for a total loss of 35 psi in 30 min. Bled Tbg to 0 psi. Annulus valves open to guages and tags hung. FWP's 0/0/0 06-15 5/31/2008 ***CONTINUED JOB FROM 30-MAY-2008*** INITIAL WHP'S= 0/850/0. SET 3-3/8" IBP AT MIDDLE ELEMENT C~3 8148'. IBP IS 11.6' OAL, HAS (2) 6" SEALING ELEMENT & (1) 1"STIFFENER RING. FISH NECK IS 1-3/4". 5500# UP JAR TO RELEASE, 1840# DOWN JAR TO EQUALIZE. DEPTH CORRECTED TO TBG TALLY. JET CUT TBG ~ 8115' AS PER PROGRAM W/ 4.15" SCP POWER CUTTER. FINAL WHP'S= 750/0/0 ***JOB COMPLETE, WELL LEFT S/I*** NOTE: WATCH FOR POTENTIAL IBP PULLED DURING 6/2008 RWO 06-15 5/31/2008 ***CONTINUED JOB FROM 30-MAY-2008*** INITIAL PRESSURE T/I/O = 0/850/0, RU E-LINE FOR BAKER IBP, 11.6' LONG PLUG 2 X 6" LONG + 1"STIFFENER RING, FISHING NECK 1.75" JDC, 5500# UP JAR TO RELAEASE RELEASE, 1840# DOWN JAR TO EQUALIZE. SET IRP nT Ri aR' MID- ELEMENT DEPTH CORRECTED TO TUBING TALLY. JET CUT TUBING AT $,11.~',T 1~,81b1Ca..IALI Y DEF`'TH`AS PER° 4.15' P P WER CUTTER. DSO NOTIFIED WELL SHUT-IN AND SECURE, JOB COMPLETE, FINAL PRESSURES 750/0/0. 06-15 6/1/2008 T/I/0=1000/20/40 Circ out [Pre RWO] Pumped 11 bbls neat meth, 400 bbls 9.8# NACL, 1 bbl diesel down Tbg through IA taking returns down F/L of 06-16. Pumped 300 bbls 9.8 #NACL, 1 bbl diesel down IA. Flushed jumper line to well #16 with 5 bbls diesel. ***Tags hung & wellhead valves checked for position upon departure*** FWP's=0/0/0 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 7/17/2008 Digital Well File • • Page 2 of 2 06-15 6/1/2008 T/I/0= 800/0/0+. Circ Well (RWO prep) Pumped 5 bbls of meth into the Tbg. Final WHP= 800/0/0. 06-15 6/1/2008 T/I/O = 0/0/0 Set 5 1/8" FMC BPV 06-15 6/1/2008 T/I/0= SSV/0/0. Temp= SI. Prep for LDS drill out (RWO). There is one LDS on the tubing spool piece that is broken ~ the 4 o'clock position (Identified with orange flagging tape), and also one broken on the casing spool piece ~ the 10 o'clock position (Identified with orange flagging tape). ""Note*"' Well house and flow line are removed. Drilling scaffolding installed on well. Cellar has approx 2' of water in it, called for vac truck to remove water. Cellar boards will need to be installed to drill LDS, called well support to have cellar boards delivered. 06-15 6/2/2008 T/IA/OA= SSV/0/0 temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (DRILL OUT 2 stuck LDS) Drill out LDS on tubing head, replaced with blank. "Per Clint Miller JIT FMC " PPPOT (PASS) Drill out LDS on casing head, replaced with blank. "Per Clint Miller JIT FMC " PPPOT (PASS) 06-15 6/2/2008 T/I/O = ONac/0. Temp = SI. Assist w/LDS drill out (RWO). Assist Cameron with LDS drill out. 06-15 6/2/2008 T/IA/OA= SSV/0/0 Staged equipment to rotate IA and OA valves PRE-RIG. Assisted Cameron with LDS drill out and removal....Job ran late and valves will be changed around by CH2MHILL'**'IN PROGRESS""" 06-15 6/3/2008 T/I/O=BPV/0/0. SI. Assist w/ LDS drill out (RWO). Assisted Cameron and FMC with LDS drill out. 06-15 6/3/2008 T/I/O = 0/0/0 Remove companion, move I/A & O/A to backside torque to 480 ft.lbs. test flanges to 3500 psi. Print Date: 7/17/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 7/17/2008 • • BP EXPLORATION Page 1 of 21 Operations Summary Report Legal Well Name: 0 Common Well Name: 0 Event Name: Contractor Name: Rig Name: Datsr 'From - To 6-15 6-15 WORKOVER DOYON DRILLIN DOYON 16 Hours Task INC Code . NPT 6/3/2008 00:00 - 06:00 6.00 MOB P 06:00 - 20:30 14.50 MOB P 20:30 - 00:00 3.50 MOB P 6/4/2008 00:00 - 03:00 3.00 MOB P 03:00 - 04:00 1.00 DHB P 04:00 - 04:30 0.50 KILL P 04:30 - 07:00 2.50 KILL P 07:00 - 12:00 5.00 WHSUR P 12:00 - 15:30 3.50 BOPSU P DECOMP 15:30 - 22:30 7.00 BOPSU P DECOMP 22:30 - 21:30 23.00 BOPSU P DECOMP 21:30 - 23:00 1.50 BOPSU P DECOMP Spud Date: 6/24/1980 Start: 6/4/2008 End: Rig Release: 6/22/2008 Rig Number: Phase Description of Operations PRE R/U for rig move to DS 6-15. Spot rig on H pad and lay Derrick over. Put Booster wheels on. Rig on the move at 0400-hrs. Continue to move off of H-Pad en route to DS 6. PRE Continue moving rig from H-Pad to DS 6. Contact AOGCC John Crisp and gave 24 hr notice of initial BOP test on DS 6-15 at 07:30 hrs. PRE Stage rig on DS 6. R/U and raise derrick and secure. PJSM with GCI and rig crew. install GCI communication antennas. Remove front and rear booster wheels. Bridle down derrick. PRE Move over well 6-15. R/U the double IA valve and secondary valves on OA. R/U circulating lines. Rig up to bleed OA to Slop Tank with 2" circulating line. No pressure on IA or OA. Spot and R/U mud pump #2. Spot and R/U #4 motor. Finish R/U rig floor. R/U Geronimo line. Prepare and load 9.4-ppg NaCI brine. Accept rig at 0200-hrs._ DECOMP P/U DSM lubricator, tools and equipment. R/U lubricator and ressure test to 500- si ood test. Pull BPV. L/D DSM tools and equipment. DECOMP Build 20-Bbl high visc spacer. Pressure test circulating lines to 3500-psi. DECOMP PJSM with rig crew and CH2MHill support. Discuss displacing well to 9.4-ppg NaCI Brine. Start displacement at 7.5-BPM with 530-psi. Pumped 563-Bbls of 9.4-ppg NaCI brine at 8-BPM, 670-psi. Took 30-Bbls to catch up to the fluid for a fluid level at -450'. DECOMP Set and test BPV in Hanger and test to 1000-psi from below with an injection rate of 3.25-BPM. N/D Tree and adaptor flange. Cameron and FMC techs attempt to function all LDS on the Tubing Spool in preparation for Packoff changeout. Function only 6 of 14 LDSs on the lower flange. Will have to Dull the tubing spool and oackoff as a unit after th~$" N/U BOPE. Change out 2-7/8" x 5" VBRs to 3-1/2" x 6" VBRs. P/U 4" and 5-1/2" test joints and place in Pipe Shed. Attempt to test BOPE. Trouble shoot leak oath. Pull blanking plug from hanger profile. Examine and redress. Increase torque on LDS from 450 psi to 500 psi. Install blanking plug back into hanger profile and attempt to retest, no good. Recheck all flow paths on surface. Fill IA and attempt to retest. Fluid coming from IA. Remove 2" hammer union and visually see flow coming from IA. Appears to be coming from below. Suck out test joint and fill with red marker fluid to establish whether the flow is coming by the blanking plug or the hanger. Reinstall 2" hammer union. Pressure up and observe flow coming from IA without red dye. Believe leak is in blanking plug instead of around hanger. en or new an ing p ug. R/U and test upper IBOP and Dart Valve R/U and pull blanking plug from hanger profile. Set new blanking plug as per FMC. P/U 4" test joint and RIH. Attempt to pressure test against VBRs and blanking plug without success. Pull new blanking plug and examine. Drain BOP stack. Redress with new dovetail seal ring and rerun. Filf BOPE and Printed: 7/7/2008 11:51:37 AM ~ • BP EXPLORATION Page 2 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To ~~ Hours I, Task Code NPT Phase Description of Operations 6/4/2008 21:30 - 23:00 1.50 BOPSU P 23:00 - 00:00 1.00 BOPSU P 6/5/2008 00:00 - 02:00 2.00 BOPSU P 02:00 - 04:00 2.00 04:00 - 04:30 0.50 04:30 - 06:00 1.50 06:00 - 11:30 I 5.50 P P P P 11:30 - 12:30 1.00 BOPSU P 12:30 - 13:30 1.00 BOPSU P 13:30 - 14:30 1.00 CLEAN P DECOMP attempt to test without success. DECOMP Consult rig team for options for pulling BPV and set W RP. DECOMP Continue discussing options with rig team. Consult with Jim Willingham of possible options and come up with plan forward. Contact AOGCC State Inspector Chuck Scheve with plan to make a dynamic body test on BOPE against the annular preventer and Dutch System with DSM lubricator to prove the integrity of the BOPE. Will test to 250 psi low pressure and 2500 psi high pressure as per Chuck Scheve. Redress and set blanking plug in hanger profile. Send for SWS slickline unit and DSM. DECOMP PJSM with rig crew and DSM. Discuss plan forward and job assignments. Install blanking plug. Install Dutch System and R/U DSM lubricator. Fill stack and lubricator. DECOMP Test BOP body to 250, 2500 and 3500 psi against annular preventer with Dutch System. All good test for 5 charted minutes. DECOMP Bleed off pressure. R/D DSM lubricator and Dutch System. P/U 4" test joint with doughnut and RIH. R/U BOP testing equipment. DECOMP Test BOPE to 250 psi low pressure and 3500 psi high pressure. Each test was held for 5 charted minutes. AOGCC inspector John Crisp waived state's right to witness BOPE test. Test was witnessed by Doyon Toolpusher, Andrew Honea and BPX WSL Mike Rooney. Test 1-Choke Valves 12, 13, 14, Annular Preventer, HCR Kill, and Upper IBOP Test 2- Choke Valves 9, 11, Manual Kill, Annular Preventer, and Lower IBOP Test 3- 3-1/2" x 6" VBRs with 4" Test Joint Test 4- Choke Valves 5, 8, 10, and Blind Rams Test 5- Choke Valves 4, 6, 7, Blind Rams and Dart Valve Test 6- Choke Valves 2, 4, and 6 Test 7- Choke Valves 1, 3, 4, and 6 Test 8- HCR Choke and TIW Valve Test 9- Manual Choke Test 10- 3-1/2" x 6" VBRs with 5-1/2" Test Joint Accumulator Test- Starting System Pressure- 3050 psi. Pressure after Closure- 1950 psi. First 200 psi Recovery in 15 seconds. Full Pressure Recovery in 75 seconds. 5 Nitrogen Bottles at 2140 psi. DECOMP R/D BOP testing equipment. Blow down top drive, choke line and kill line. Pull FMC blankina of ti a_ DECOMP R/U Dutch System and install DSM lubricator. Test lubricator to 500 psi, good test. Pull BPV, check for 0 pressure. L/D BPV and DSM lubricator and equipment. R/D Dutch System. BPV had several small cement chunks and one partial "O" ring coming from BPV drain hole. DECOMP PJSM with Doyon 16 rig team, Schlumberger control line tech, Baker fisherman, and FMC rep. Discuss engaging and pulling tubing hanger to floor and well control situation. Bleed off pressure from control lines and BOLDS. Insure IA is full. R/U Schlumberger control line spooler. Gather and R/U 5-1/2" Printed: 7/7/2008 11:51:37 AM • • BP EXPLORATION Page 3 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours ', Task 6/5/2008 13:30 - 14:30 1.00 CLEAN 14:30 - 15:00 0.50 CLEAN Code I NPT I Phase P P 15:00 - 15:30 0.50 PULL P 15:30 - 16:00 0.50 PULL P 16:00 - 18:00 18:00 - 00:00 6/6/2008 00:00 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 11:00 11:00 - 11:30 11:30 - 15:30 15:30 - 17:00 Description of Operations DECOMP handling equipment. DECOMP P/U BHA #1 (5-1/2" ITCO Spear) consisting of bull nose, spear packoff, ITCO spear, 2 extensions, and x/o subs. Total length of BHA #1- 13.93' DECOMP RIH and engage FMC tubing hanger with ITCO spear. ,~_ tubin han er free from tubin s ool with 175,000 Ibs_; Up Wt of tubing string 175,000 lbs. Pull to rig floor. DECOMP Terminate control lines at tubing hager and R/U to Schlumberger control line spooler. Break out and UD tubing hager. UD ITCO spear. Change out to 5-1/2" tubing elevators. 2.00 PULL P DECOMP Pump 20-Bbl high visc sweep and chase with 9.4 ppg brine at 10 bpm with 200 psi. Sweep did not bring back any noticeable increase in solids from downhole. No losses to formation while pumping sweep. Shut down pumps and monitor well to be dead. 6.00 PULL P DECOMP POOH with 5-1/2", 17#, L-80 tubing; UD in pipe shed 1x1. Recovered HGR assy, 1 SSSV, 31of 32 Otis Control Line Clamps, 3 of 4 SS bands that were listed in the original tally. But it was not obvious that a clamp had been dislodged or broken from the tubing while POOH. 2.50 PULL P DECOMP Continue POOH and UD 5-1/2", 17#, L-80 tubing 1x1 in pipe shed. Total recovery- 207 full joints of 5-1/2" tubing, 1 cut off joint at 19.47', 1 tubing hanger assy, 1 SSSV assy and control line, 31 Otis Clamps, 3 SS bands, and 1 sliding sleeve assy. Tubing was in good condition without any noticeable external corrosion, however, many of the joints had internal corrosion in the pin ends. Tubing cut was flared out to an average of 6" with one area of the flare to 6.5". A gel-like substance was found in spots beteen the control line and the tubing. A Marasol gel squeeze had been performed in the IA on 6-26-2000. 0.50 PULL P DECOMP Clear and clean rig floor. 0.50 CLEAN P DECOMP P/U Baker dress off tools and BHA. M/U BHA #2 consisting of 8-1/2" bit, 9-5/8" casing scraper, and bit sub. Total length of BHA #2- 6.97' 7.50 CLEAN P DECOMP RIH with BHA #2 on 4" HT-38 drill pipe picked up 1x1 from pipe shed. Joint #95 RIH at 0645-hours. #225 ~ 1010-hrs. Yo-Yo 9-5/8" Scraper -40' to 50' above and below 2100', 4500', 5500', and 8000' while RIH to clean the areas where the RBPs and the RTTS will be set prior to the 9-5/8" Casing cutting operation. 0.50 CLEAN P DECOMP Baker Fishing technician requested verification of the 5-1/2" tubing cut depth. P/U joint #256 and RIH slowly to lightly tag stub to verify cut depth. Set -1000-Ibs on stub at 8111' D-16 4.00 CLEAN P DECOMP Mix HiVis sweep and circulate all the way around. See something like Arctic Pack come across shakers, but in small globules. The returning fluid weight decreased to 9.34-ppg during the circulation, called MI Engineer to assist with getting the weight back up to 9.4-ppg, although did not experience fluid loss or gain. 1.50 CLEAN P DECOMP PJSM to cut and slip drilling line. Cut and slip drilling line, 94'. Inspect draw works an saver sub. Printed: 7/7/2008 11:51:37 AM ~ • BP EXPLORATION Page 4 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task !, Code NPT Phase Description of Operations 6/6/2008 17:00 - 20:00 3.00 CLEAN P DECOMP POOH with scra er assembly standing back 4" HT-38 drill pipe in derrick. 20:00 - 20:30 0.50 CLEAN P DECOMP Clear and clean rig floor. P/U HES 9-5/8" RBP to rig floor and install to drill pipe. Total length of RBP assembly- 24.07' 20:30 - 23:30 3.00 ZONISO P DECOMP RIH with 9-5/8" HES RBP on 84 stands of 4" HT-38 drill pipe from derrick to 8004' 23:30 - 00:00 0.50 ZONISO P DECOMP Establish parameters of Up Wt- 156,000 Ibs; Down Wt- 143,000Ibs. S of RBP at set depth and set with 2 left hand turns. S/O 15,000 Ibs on RB wit s overpu . /O 15,000 on RBP and put 1/2 left turn in work string. P/U off RBP 30' and go through release procedure again to insure the RBP was set. Center of RBP elements at 8004', RBP fish neck at 8000'. 6/7/2008 00:00 - 03:00 3.00 ZONISO P DECOMP POOH with HES RBP running tool. Stand back 4" HT-38 drill pipe in derrick. L/D HES RBP running tool. 03:00 - 05:30 2.50 ZONISO P DECOMP P/U 9-5/8" HES RTTS and RIH on 4" HT-38 drill pipe from derrick to 5528'. 05:30 - 06:30 1.00 ZONISO P DECOMP Establish parameters of Up Wt- 120,000 Ibs; Down Wt- 108,000 lbs. Set RTTS at 5528' with 1/2 right hand rotation, S/O 20,000 Ibs on RTTS. R/U casing testing equipment. Pressure test casin from 5528' to 8004' to 1500 si. Hold ressure for 15 charted minutes, good test. 06:30 - 08:30 2.00 ZONISO P DECOMP POH and S/B DP in Derrick. B/O and L/D RTTS and setting tool. 08:30 - 11:30 3.00 ZONISO P DECOMP P/U RBP and RIH to set at _4,500'. 10-stands RIH at 0915-hours. 25-stands ~ 0945-hrs. Get Set RBP #2 at 4514', center of element at 4518'. Release from RBP and pressure up on casino to 1500-psi. Pressure holds rock-solid for 15 11:30 - 13:00 13:00 - 13:30 13:30 - 14:00 14:00 - 16:30 1.50 0.50 0.50 2.50 ZONISO ZONISO EVAL EVAL P P P P DECOMP DECOMP DECOMP DECOMP POH and S/B DP in Derrick. B/O and UD RBP running tool. Clear and clean rig floor. PJSM with rig crew and SWS E-liners. Discuss rigging up procedures and Doyon safety policies. R/U SWS E-line equipment with line wiper. RIH w/ SWS USIT logging tool to 3020'. Lo u and locate the to f cement t 1 ', R/D SWS E-line equipment. Clear and clean rig floor. 16:30 - 18:00 1.50 EVAL P DECOMP Evaluate USIT log and discuss options with rig team. Pressure test hard line from OA to slop tank to 2000 psi, good test. Weight up brine in pit to 9.8 ppg. 18:00 - 19:00 1.00 ZONISO P DECOMP P/U HES 9-5/8" RBP and RIH to 1850'. 19:00 - 19:30 0.50 ZONISO P DECOMP Load 20/40 mesh sand on rig floor. 19:30 - 20:00 0.50 ZONISO P DECOMP Spot HES 9-5/8" RBP center of elements at 1851'. Placing the top o at 47 . et BP with 2 left turns, S/O 20,000 Ibs on RBP, add 1/4 left turn to lock in set position. Overpull 5,000 lbs. Set 20,000 Ibs on RBP, add 1/4 left turn and pull off RBP. P/U 30' repeat set procedure, no change. L/D single and rack one stand in derrick. 20:00 - 20:30 0.50 ZONISO P DECOMP R/U to test RBP. Pressure test RBP to 1500 psi. Hold test for 15 charted minutes, good test. Bleed pressure and R/D testing equipment. 20:30 - 23:00 2.50 ZONISO P DECOMP R/U sand hopper on top of drill pipe. Dump 44 sacks of 20/40 mesh sand on top of RBP through drill pipe. Chase sand from Printed: 7/7/2008 11:51:37 AM ~ • BP EXPLORATION Operations Summary Report Page 5 of 21 Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date I From - To Hours Task Code NPT Phase Description of Operations 6/7/2008 20:30 - 23:00 2.50 ZONISO P DECOMP drill pipe at 3/4 bpm with 40 psi. Allow sand to settle for 1/2 hour. RIH tao top of sand at 1812'. 23:00 - 00:00 1.00 ZONISO P DECOMP P/U and allow sand to settle 30 minutes. RIH and tag top of sand at 1809'. 6/8/2008 00:00 - 01:30 1.50 CASE P DECOMP Displace wellbore with 9.8 ppg NaCI brine at 5.5 bpm with 350 psi. Route all returns to pit 3, weight up to 9.8 ppg and blend with the rest of pit system. 01:30 - 02:30 1.00 CASE P DECOMP POOH with RBP #3 running tool standing back 4" HT-38 drill pipe in derrick. 02:30 - 04:00 1.50 WHSUR P DECOMP Pull wear ring. N/D BOPE and stand back on BOP stump. BOLDS. N/D tubing spool. R/U top drive to packo pu ing tool. Break tubing spool loose from casing spool with 35,000 Ibs over ull. R/U and remove tubing spool with packoff from cellar. 04:00 - 06:30 2.50 WHSUR P DECOMP 06:30 - 08:30 2.00 BOPSU P DECOMP 08:30 - 10:30 2.00 FISH P DECOMP 10:30 - 12:00 1.50 FISH N DPRB DECOMP 12:00 - 13:30 1.50 FISH N DPRB DECOMP 13:30 - 15:00 1.50 FISH P DECOMP 15:00 - 15:30 0.50 FISH P DECOMP 15:30 - 16:00 0.50 FISH P DECOMP 16:00 - 17:00 1.00 FISH P DECOMP Inspect and clean casing spool. Install 9-5/8" x 13-3/8" packoff Install new FMC 13-5/8" 5M x 13-5/8" 5M tubing spool. N/U tubing spool. FMC test neck seal to 3800-psi for 30-minutes. N/U BOP Stack. Perform BOP body test, 250-psi low, 3500-psi high 5 recorded minutes, each. Set Wear Ring. P/U, M/U Baker 9-5/8" Multi-string Cutter and RIH. When the 13th stand was being RIH one of the cutter fingers worked loose and stacked out the string into the Top Drive. Picked up the stand and S/B in the Derrick. Inspected the Top Drive and decided to change out the Saver Sub. Picked up the 13th stand and M/U to the string and RIH to inspect the box at the top of the stand. The top thread appeared to be rolled over, so POH and B/O and UD and strap that joint. P/U another strapped joint from outside the Pipe Shed and RIH. POH and S/B DP in Derrick to inspect Multi-string Cutter. Find that the protective tape had pulled loose and allowed a cutter finger to swing free. This finger had a small (3/8" across) chunk of carbide missing from one corner. Decide to restrain the cutters with another safety wire and more wraps of duct tape. RIH with Multi-string Cutter BHA, stop at_ 1719' and get parameters: P/U wt 65K, S/O wt 70K, free rotating torque 2K-Ib-ft. Pump rate, 5-BPM at 600-psi. Stop pump and continue in to find collar at 1773', P/U to place cutter at 1750'. PJSM with all personnel from Lil Red (2), CH2mHill (4), Baker Fishing (1), GCI (2), MI (1), and rig crew with TP and WSL to discuss the cutting procedures and the Arctic Pack displacement program. PT Lil Red's line. Place Herculite over the top of the inlet end to the Wells Support flowback tank. Start pump and bring up to 5-BPM ~ 600-psi, bring Top Drive rotation up to 60-RPM, and see torque of 2-5K-Ib-ft. Immediate indication of cutter fingers biting into 9-5/8" casing. Casing cuts through in 2-minutes and had been in tension judging by the thump felt in the rig floor. See pump pressure decrease to 200-psi. Get flow check and open the OA to the flowback tank with good flow of viscous, oily fluid to the tank, pushed by the differential between the 9.8-ppg brine in the DP and DP x 9-5/8" annulus and the OA. Shut-in Hydril, and start Lil Red pumping 80-Bbls of diesel at Printed: 7/7/2008 11:51:37 AM • • BP EXPLORATION Page 6 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date 'From - To ' Hours ', Task Code N'PT Spud Date: 6/24/1980 Start: 6/4/2008 End: Rig Release: 6/22/2008 Rig Number: Phase Description of Operations 6/8/2008 16:00 - 17:00 1.00 FISH P DECOMP 2-BPM, 1000-psi. S/D Lil Red, and bring on rig pump to pump a 20-Bbls Safe-Surf-O pill followed by a DP volume (19-Bbls) of hot 9.8-ppg brine from the Pits. Take 130-Bbls out of the flowback tank during the circulation. 17:00 - 19:00 2.00 FISH P DECOMP Let Arctic Pack cleaning fluids soak in the OA. 19:00 - 20:30 1.50 FISH P DECOMP Line up and pump 20-Bbls Safe Surf O pill followed by 20-Bbl high visc pill. Chase with 9.8 ppg brine at 9 bpm with 1020 psi taking returns up the OA to the slop tank until good clean 9.8 ppg brine returned throughout the OA. Open annular preventer and shut in OA. Continue pumping 1 hole volume with 9.8 ppg brine. 20:30 - 21:00 0.50 FISH P DECOMP Shut down pumps and monitor well to insure well to be dead. Open OA to slop tank and monitor, OA dead. 21:00 - 21:30 0.50 FISH P DECOMP POOH with 9-5/8" casin cutter assembl standing back 4" HT-38 drill pipe in derrick. UD casing cutter. 21:30 - 22:30 1.00 FISH P DECOMP P/U wear ring running tool and R/U. Pull wear ring and UD. P/U 9-5/8" pack-off pulling tool and RIH. Engage pack-off and POOH. UD pack-off. 22:30 - 23:00 0.50 FISH P DECOMP P/U BHA #4 (9-5/8" casing spear assembly) consisting of spear pack-off, bull nose, 9-5/8" ITCO spear, spear extension, stop sub, and x/o sub. Total length of BHA #4- 15.95' 23:00 - 23:30 0.50 FISH P DECOMP RIH and engage 9-5/8" casing hanger with spear. Pull hanger free with 120 000 Ibs, UpWt- 120,000 lbs. Pull hanger to rig floor. 23:30 - 00:00 0.50 FISH P DECOMP Line up and CBU at 6.5 bpm with 50 psi. 6/9/2008 00:00 - 00:30 0.50 FISH P DECOMP Monitor well, well dead. Release spear from casing hanger. UD spear assembly. 00:30 - 01:00 0.50 FISH P DECOMP R/U rig floor to pull and UD 9-5/8" casing. PJSM with rig crew. Discuss UD hanger and UD casing. Discuss hazards related to handling 9-5/8" casing. 01:00 - 02:30 1.50 FISH P DECOMP UD 9-5/8" casing hanger. POOH with 7 joints of 9-5/8", 47#. L-80, BTC casing. Well swabbing while POOH. 02:30 - 03:30 1.00 FISH P DECOMP Stop pulling pipe and R/U to circulate. Stage pump rate up from 6.5 bpm with 320 psi to 13.6 bpm with 1500 psi. Large amounts of gunk mixed with cement chunks was circulated to surface. Allow well to clean up and R/D circulating lines. 03:30 - 07:00 3.50 FISH P DECOMP Monitor well. Continue POOH with 9-5/8" casing with proper hole fill. Average breakout torque +45,000 Ibs. UD 40 full joints of 9-5/8" casin , a cutoff 18.77' in len th and 6 bowspring centralizers. The cutoff was clean and nearly the same diameter as the OD of the pipe. 07:00 - 08:00 1.00 FISH P DECOMP Remove casing handling tools; clear and clean rig floor. 08:00 - 08:30 0.50 FISH P DECOMP B/O casing spear BHA and UD. 08:30 - 11:30 3.00 FISH P DECOMP PJSM f r -5 - .Gather Dress-off BHA components to rig floor and M/U BHA: 12-1/8" OD Dressoff Shoe, Extension, 9-5/8" Dressoff Mill, Drive S-b Boot Basket, 13-3/8" Casing Scraper, String Float, Bumper sub, and Oil Jars; total length, 41.94'. P/U 9-ea, 6-1/4" DCs from Pipe Shed and M/U to Dress-off BHA. 11:30 - 12:30 1.00 CLEAN P DECOMP RIH 9-5/8" dressoff BHA to -1745'. 12:30 - 13:00 0.50 CLEAN P DECOMP POH to 1740', M/U to Top Drive and get parameters: P/U wt 82K; S/O wt 85K; Rot wt at 70-RPM with 3K-Ib-ft torque, 84K; 7.5-BPM, 220-psi. Stop rotating and slowly RIH and see a tag Printed: 7/7/2008 11:51:37 AM • • BP EXPLORATION Page 7 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To '~~ Hours I Task i Code' NPT ' Phase- Description of Operations ~ -- _ - 6/9/2008 12:30 - 13:00 0.50 CLEAN P DECOMP - - at 1748', P/U 5' and start rotating at 70-RPM, pump rate 7.5-BPM ~ 220-psi. Slowly RIH and see tag at 1750' and torque oscillates from 2K to 5K-Ib-ft, continue in for a swallow of 6' and dress-off stub a few inches. P/U while rotating until above stub and slowly RIH and get same swallow with a WOB of -4K-Ibs. P/U and RIH again while rotating to find same tag depth of 1750'. P/U, stop rotating and RIH to tag at 1750', but won't swallow. P/U and make 1-2 rotations at surface, stop rotating and RIH swallowing the stub easily for 6'. P/U and start rotating at 70-RPM and RIH, easily swallowing stub to verify dressed stub periphery. Confirm top of stub at 1750' plus a few, inch 13:00 - 13:30 0.50 CLEAN P DECOMP Pump 40-Bbl Safe-Surf-O sweep and chase out of hole at 11-BPM, 620-psi. Do not see much debris or oily fluid across shakers. Fluid weight in returns is 9.8-ppg. 13:30 - 15:00 1.50 CLEAN P DECOMP POH and S/B DP and DCs in Derrick. 15:00 - 16:30 1.50 CLEAN P DECOMP B/O and L/D Dress-off BHA. Clear rig floor of Baker tools. Clean rig floor. 16:30 - 17:30 1.00 ZONISO P DECOMP RIH 3-stands of 6-1/4" DCs from Derrick. P/U and M/U Halliburton RTTS packer and continue RIH with 5-stands of DP from Derrick. 17:30 - 18:30 1.00 ZONISO P DECOMP Set RTTS at 499' and test underneath to 2100-psi and levels off to 2000- si after 20 recorded minutes. S/I H dril and test from the to to 500- si. Took one stroke to build to 500-psi. S/I and the pressure dropped to 250-psi in 3-minutes. Bump up again to 500-psi and S/I and the pressure drops from 600-psi to 300-psi in 5-minutes. Attempt to slow down mud pump to maintain a steady pressure of 500-psi, but mud pump stalls out. Pump a total of 5-strokes with mud pump over 15-minutes for a total estimated volume of 18-gallons. Attempting to hold pressure at 500-psi for last 5-minutes resulted in a LLR of -1 to 2-gallons per minute. 18:30 - 19:00 0.50 ZONISO P DECOMP POH, S/B DP in Derrick, L/D RTTS, S/B DCs in Derrick. 19:00 - 21:00 2.00 CASE P TIEBi Pull Wear Ring. R/U to run 9-5/8", 47#, Hydril 563 casing. Bring centralizers to rig floor. 21:00 - 22:00 1.00 CASE P TIE61 PJSM. M/U downhole cementing jewelry using Bakerlok on all connections from the XO pup joint above the ES Cementer to the 9-5/8" Bowen Casing Patch. 22:00 - 00:00 2.00 CASE P TIEB1 RIH with 9- 7# - ril ,using Jet Lube Seal Guard pipe dope and 15,800-Ib-ft of torque on each connection. 6/10/2008 00:00 - 02:00 2.00 CASE P TIEB1 Continue to RIH with 9-5/8", 47#, L-80, Hydril 563 Casing. 02:00 - 03:00 1.00 CASE P TIEB1 Obtain parameters: P/U wt 112K, S/O wt 115K. Tag 9-5/8" stub at 1750', slip down 3' over stub to 1753', stack out 20K to No-go, P/U to 10K overpull to confirm slips set on stub. P/U to 250K set sli s M/U Halliburton Cement Head and XO to 9-5/8" Hydril 563 casing. P/U and pull slips, slack off to 210K. 03:00 - 04:00 1.00 CEMT P TIEB1 Pressure t t - " to 2000- si for 30 charted minutes for pod test. Test OA line to Wells support flowback tank to 2500-psi. 04:00 - 04:30 0.50 CEMT P TIE61 Open cementers to 9-5/8" cementing head to begin pumping 9-5/8" casing cementing program. 04:30 - 05:00 0.50 CEMT P TIEB1 Continue to circulate warm 9.8 ppg brine at 6 bpm with 150 psi. Printed: 7!7/2008 11:51:37 AM • • BP EXPLORATION Operations Summary Report Page8of21 Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: - Date -~ From - To Hours Task Code NPT I Phase Description of Operations 6/10/2008 04:30 - 05:00 0.50 CEMT P TIEB1 Hold PJSM with rig crew, CH2MHill support crew, and Schlumberger cement crew. Discuss upcoming cement operation plan and procedures. Assign job assignments and last minute action items. Discuss job safety and stop the job as needed. 05:00 - 07:00 2.00 CEMT P TIEB1 Insure all lines are R/U properly. Pressure test lines to 4500-psi, no good. Change out swing on rig floor. Pressure test to 4500-psi, good test. Mix and pump 121-Bbls of 15.8-ppg Class G cement with .2% BWOC D046 antifoam, .2 gal/sx D047 antifoam, .07 gal/sx D185A Dispersant LT, 1.5 gal/sx D600G GASBLOK, and .2 gal/sx D186 accelerator. Pump cement at 5-BPM with 600-psi. Shut down pumps and dropped dart. Schlumberger flushed lines to rig floor. Switch to rig pump and displace cement with 9.8-ppg brine at 5-BPM with 200-psi. Caught cement after pumping 60-Bbls at 5-BPM where pressure increased to 420-psi. Continue displacing at 5-BPM with 800-psi pressure after displacing 105-Bbls where cement came to surface. Divert returns through choke and maintain 550 - 650-psi back pressure. After pumping 110-Bbls, slowed pump rate down to 2-BPM and 1100-psi maintaining 550 to 650-psi back pressure. Bumped plug at 126-Bbls with 1100-psi at 1/2-BPM. Slowly increase pressure and close ES Cementer at 2100-psi. Increase and hold pressure at 2400-psi. Hold pressure for 4 minutes, bleed pressure and check for flow back. ES Cementer holding. Bleed pressure. CIP at 06:30 hrs. Squeezed off 10 to 15 gallons of cement into casing leak. 07:00 - 10:00 3.00 CEMT P TIEB1 N%D Halliburton Cementing Head. N/D Tree at the Casing Spool/Tubing Spool flanges to prepare for installing slips and cutting the 9-5/8" casing with the Wachs Cutter. Lift up BOP stack for casing cut. FMC install slips, but have some difficulty getting the lineup tabs to engage to the proper spot in the circumferential lineup groove. Set weight down on slips and prepare to make casing cut. 10:00 - 12:30 2.50 WHSUR P TIEB1 M/U Wachs Casing Cutter to 9-5/8" casing and cut casing. Clean Pack Off Area, Check Seal Ring, Change Out Lock Down Screws until) other Pack Off Arrives on Location. R/D Long Bails on Top Drive and R/U Pack Off Running Tool. 12:30 - 13:30 1.00 WHSUR P TIEB1 Set New Pack Off Through Stack /Raise Stack to verify Pack Off in Place. RILDS on Pack Off. 13:30 - 14:00 0.50 WHSUR P TIEB1 N/U BOP's ~ Tubin S o ool Breaks. Install Turn Buckles, Remove Riser and Inspect Air Boots, Alr Up Boots. 14:00 - 15:00 1.00 WHSUR P TIEB1 Test new packoff and attempt to pressure test break between tubing spool and casing spool to 3800 psi for 30 minutes. Test not holding. Increase torque on LDS and repeat test, good test. 15:00 - 16:00 1.00 BOPSU P TIEB2 Open pipe ram doors and inspect lower ram cavity for cement. R/U and test BOP body to 250 psi low pressure and 3500 high pressure. Hold test for 5 charted minutes, good test. 16:00 - 18:30 2.50 BOPSU P TIE62 M/U BOPE washing tool and flush stack. Wait on cement to get to 500 psi compressibility. Gather up next BHA Printed: 7/7/2008 11:51:37 AM • • BP EXPLORATION Operations Summary Report Page 9 of 21 ~ Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date 'From - To Hours Task Code NPT Phase Description of Operations 6/10/2008 16:00 - 18:30 2.50 BOPSU P TIEB2 components. Set wear ring. 18:30 - 19:30 1.00 DRILL P TIEB2 P/U BHA #6 drill out assembly) consisting of 8-1/2" bit, (2) 7' boot baskets, 9-5/8" casing scraper, bit sub, bumper sub, jars, x/o sub, (9) 6-1/4 drill collars, and x/o sub. Total length of BHA #6- 319.13'. RIH with BHA #6 on 4" HT-38 drill pipe from derrick to 1210'. 19:30 - 21:00 1.50 DRILL P TIEB2 Wait on cement samples to reach compressiblity. Install front spreader beam of rig. 21:00 - 21:30 0.50 DRILL P TIEB2 Continue to RIH on 4" HT-38 drill pipe from derrick and tag top of CMT at 1736'. P/U and M/U top drive. 21:30 - 23:00 1.50 DRILL P TIEB2 Establish parameters of Up Wt- 80,000 Ibs; Down Wt- 83,000 lbs; Rotating Wt- 82,000 Ibs at 80 rpm with 2500 ft-Ibs free torque; Pump Pressure- 220 psi at 7 bpm. Drill through wiper plu and ES Cementer with 8000 to 10,000 Ibs WOB and rpm with 2500 to 3000 ft-Ibs torque. Drill through ES Cementer at 22:20 hrs. Drill through cement from 1738' to 1743'. Pump a high visc sweep. Sweep brought back a large increase of cement, rubber, and small aluminum debris to surface. Continue reaming from 1743 to the top of sand at__1807' with a 23:00 - 23:30 0.50 DRILL P TIEB2 Pump 20 bbl high visc sweep at 11 bpm with 650 psi. Sweep brought back and increase in sand and small aluminum debris to surface. 23:30 - 00:00 0.50 DRILL P TIEB2 Dry drill on top of sand for 30 minutes at 40 rpm with 3500 ft-Ibs torque to 1809'. Bring pump back up to 2.5 bpm with 50 psi and drill through sand to 1814' at 60 rpm with 3500 ft-Ibs torque. 6/11/2008 00:00 - 00:30 0.50 DRILL P TIEB2 Continue to dry drill on top of sand at 40 rpm with 3500 ft-Ibs torque to 1809'. Bring pump back up to 2.5 bpm with 50 psi and drill through sand to 1814' at 60 rpm with 3500 ft-Ibs torque. 00:30 - 01:00 0.50 DRILL P TIEB2 Pump 20 bbl high visc sweep at 11 bpm with 650 psi. Sweep brought back an increase of sand and small metal debris to the shakers. Allow shakers to clear up and R/U to POOH. 01:00 - 02:00 1.00 DRILL P TIEB2 Blow down top drive. POOH standing back 4" HT-38 drill pipe in derrick. 02:00 - 03:00 1.00 DRILL P TIE62 POOH with BHA #6. Stand back 3 stands of 6-1/4" drill collars. L/D BHA. Clean out boot baskets. Recovered 3 gallons of cement, sand, and quarter to 1/2 dollar size chunks of alluminum in boot baskets. 02:00 - 05:00 3.00 CASE P TIEB2 R/U to test casing. Close blind rams and ressure test casin r to 3500 si for 30 charted minutes ood test. Bleed off pressure. 05:00 - 05:30 0.50 FISH P TIEB2 M/U RCJB BHA #7. 05:30 - 07:00 1.50 FISH P TIEB2 RIH to 1810 ft. P/U & S/O Wt = 80,000 Ibs. Rot Wt = 85,000 Ibs with 40 rpms and 2,000 ft-Ibs free torque. Pump pressure = 860 psi at 7.5 bpm. 07:00 - 07:30 0.50 FISH P TIE62 Tag Sand at 1814'. Drop Ball for Revs Basket. Wash to 1830 ft at 5.5 bpm and 1885 psi. Rotate at 50 rpms and 2,000 ft Ibs torque. Not seeing anything but sand as washing down hole. Required no WOB to work down hole. 07:30 - 08:30 1.00 FISH P TIEB2 Pump 20 bb High Visc Sweep and Chase Out of the hole with 9.4 ppg brine. Displace Hole to 9.4 ppg Brine at 7 bpm and Printed: 7/7/2008 11:51:37 AM • ~ BP EXPLORATION Page 10 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: I Date From - To Hours Task Code Description of Operations NPT Phase 6/11/2008 07:30 - 08:30 1.00 FISH P TIEB2 2960 psi. Lots of sand comin g back over shakers. 08:30 - 10:00 1.50 FISH P TIEB2 POOH with RCJB Assembly. Stand Back DP and DC's. Break Out and UD RCJB BHA. Found 1 golf ball size piece of aluminum in basket. Boot Baskets had small amount of aluminum, cement and sand. 10:00 - 12:30 2.50 FISH P TIEB2 M/U HES RBP Pulling Tool on 4" DP. RIH with pulling tool to top of sand. 12:30 - 13:00 0.50 FISH P TIEB2 Tag Upon Sand at 1837'. M/U Top Drive and Take Parameters. Wash Down through sand with pulling tool at 12 bpm and 690 psi. Tag Up on RBP at 1847'. Pump 20 bbl High Visc Sweep and Chase out of the hole at 12 bpm and 690 psi. 13:00 - 13:30 0.50 FISH P TIEB2 J into RBP and P/U to O en B Pass. Monitor Hole. Continue to P/U and Unseat RBP with 20,000 Ibs over ull. Circ Bottoms Up at 10 bpm and 460 psi. 13:30 - 14:30 1.00 FISH P TIEB2 POOH with RBP, Stand Back DP. B/O and UD RBP #3. 14:30 - 15:30 1.00 FISH P TIEB2 RIH with RBP Pullin Tool for RBP #2 to 44 15:30 - 16:00 0.50 FISH P TIE62 M/U Top Drive and Wash Down and Tag Up on RBP at 4508'. J into RBP and P/U to O en B Pass. Monitor Hole. P/U nd Unseat RBP with 15,000 Ibs over. Pick Up another 5 ft and the S/O Past 4508' to confirm RBP free. 16:00 - 16:30 0.50 FISH P TIE62 Circulate Bottoms Up at 11 bpm and 1080 psi. Monitor Well. 16:30 - 18:30 2.00 FISH P TIEB2 POOH with RBP #2 standing back 4" HT-38 drill pipe in derrick. B/O and UD RBP #2. 18:30 - 19:00 0.50 FISH P TIEB2 Clear and clean rig floor. 19:00 - 21:30 2.50 FISH P TIEB2 RIH with HES retrieving tool on 84 stands of 4" HT-38 drill pipe from derrick. 21:30 - 22:00 0.50 FISH P TIEB2 Establish parameters of Up Wt- 155,000 Ibs; Down Wt- 145,000 Ibs. J into RBP #1 at 8000 ft and establish a SPR. P/U and open y pass. onitor we . nseat RBP with 10 000 bs. 5. RIH past RBP settin de th to confirm RBP 22:00 - 22:30 0.50 FISH P TIEB2 CBU at 9 bpm with 1400 psi. Bottoms up was clear of any gas or crude. 22:30 - 23:00 0.50 FISH P TIE62 Safety stand down with rig crew. Hold a brief safety meeting with entire rig crew. Discuss the importance of reviewing and using the proper procedures for each job no mater how small or insignificant it seems. Make sure the all the permitting is carried out properly and with no short cuts. Not only is our safety on the line, but it is also a condition of employment. 23:00 - 00:00 1.00 FISH P TIEB2 POOH with RBP standing back 4" HT-38 drill pipe. 6/12/2008 00:00 - 02:30 2.50 FISH P TIEB2 Continue to POOH with RBP standing back 4" HT-38 drill pipe. UD HES 9-5/8" RBP #1. 02:30 - 03:30 1.00 CLEAN P DECOMP P/U BHA #8 (overshot and dressoff assembly) consisting of - overs o wi - gui a an extension, bumper sub, jars, pump out sub, x/o sub, 3 stands of 6-1/4" drill collars from derrick, and x/o sub. Total length of BHA #8- 310.33' 03:30 - 06:30 3.00 CLEAN P DECOMP RIH with BHA #8 on 4" HT-38 drill pipe from derrick. 06:30 - 07:30 1.00 CLEAN P DECOMP Slip and cut 94' of drilling line. Inspect brake linkage and draw works. 07:30 - 08:30 1.00 CLEAN P DECOMP Establish parameters of Up Wt-189,000 Ibs; Down Wt- 155,000 Ibs; Rotating Wt- 165,000 Ibs at 50 rpm with 5,000 ft-Ibs free torque; Pump pressure- 280 psi at 40 3.5 bpm. Continue RIH Pnntetl: 7/7/2008 11:51:37 AM Spud Date: 6/24/1980 Start: 6/4/2008 End: Rig Release: 6/22/2008 Rig Number: BP EXPLORATION Page 11 of 21 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 06-15 06-15 WORKOVER DOYON DRILLING INC. DOYON 16 Date ~ From - To I Hours Task Code NPT Phase 6/12/2008 07:30 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 11:00 11:00 - 13:00 13:00 - 14:00 14:00 - 15:00 15:00 - 19:30 1.00 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 0.50 CLEAN P 2.00 CLEAN P 1.00 CLEAN P 1.00 I CLEAN I P 4.501 CLEAN I P 19:30 - 20:00 0.50 CLEAN P 20:00 - 21:30 1.50 CLEAN P 21:30 - 00:00 2.50 CLEAN P 6/13/2008 100:00 - 00:30 I 0.501 CLEAN I P • Description of Operations DECOMP and tag top of tubing stub at 8111'. Mill on tubing flare at 50 rpm with 7000 ft-Ibs torque, pump rate at 3.5 bpm with 280 psi. DECOMP RIH over tubing stub to 8116' and engage grapple. Jar on fish 3 times at 250 000 Ibs to set ra le. Attempt to rotate out K-Anchor. Grapple broke free. P/U with no overpull. S/O and engage grapple. Attempt to rotate out K-Anchor. Grapple broke free. DECOMP P/U to 8100' and CBU at 11 bpm with 1810 psi. Inspect derrick and top drive. DECOMP Pump dry job and blow down top drive. DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 1300 DECOMP POOH with BHA #8 standing back 3 stands of 6-1/4" drill collars. L/D BHA #8. DECOMP Drain BOPE. Pull wear ring. Clear and clean rig floor. R/U BOPE testing equipment. Set test plug. Fill BOPE and choke manifold with water. DECOMP Test BOPE to 250 si I w pressure. Each test was held for 5 charted minutes. AOGCC witness of test was waived by Bob Noble. Test was witnessed by Doyon Toolpushers Honea and Hansen and BPX WSLs Aivano and Mabeus. Test #1-Annular Preventer, manual choke, manual kill, and upper IBOP Test #2- HCR kill, HCR choke, lower IBOP Test #3- Choke valves 1, 12, 13, 14 and dart valve Test #4- Choke valves 9, 11, and TIW Test #5- Lower pipe rams with 4" Test joint Test #6- Choke valves 5, 8, 10 and blind rams Test #7- Choke valves 4, 6, and 7 Test #8- Choke valve 2 Test #9- Choke valve 3 Test #10- Lower pipe rams with 4-1/2" test joint Accumulater Test- 2875 psi starting pressure; 1900 psi after actuation; First 200 psi recovery in 16 seconds; Full Recovery in 77 seconds. 5 nitrogen bottles at 2165 psi DECOMP Pull test plug and set wear ring. Blow down choke and kill line. Blow down top drive. DECOMP P/U BHA #9 (overshot and dressoff assembly) consisting of 8-1/2" overshot with 5-1/2" guide and 2 extensions, bumper sub, jars, pump out sub, x/o sub, 3 stands of 6-1/4" drill collars from derrick, accelerator jars, and x/o sub. Total length of BHA #8- 325.80' DECOMP RIH with BHA #9 on 82 stand of 4" HT-38 drill pipe from derrick to 8024'. Establish fishing parameters of Up Wt- 180,000 Ibs; Down Wt- 155,000 Ibs; Rotating Wt- 167,000 Ibs at 50 rpm with 4500 ft-Ibs free torque; Pump pressure- 190 psi at 3 bpm. DECOMP RIH and to t bin '. Engage tubing stub with pressure increase to 400 psi. Bleed off pressure and continue to swallow 7' of tubing stub to 8118'. P/U and jar on fish with 250,000 Ibs, dead pull to 325,000 Ibs 2 times. Jar on fish with 275,000 Ibs and dead pull to 320,000 Ibs another 2 times. Jar on fish with 300,000 Ibs and dead pull to 325,000 Ibs 7 more Printed: 7!7/2008 17:51:37 AM • BP EXPLORATION Page 12 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date I From - To Hours Task Code NPT - - -- 6/13/2008 100:00 - 00:30 0.501 CLEAN P 00:30 - 02:00 I 1.501 CLEAN I P 02:00 - 05:30 3.50 CLEAN P 05:30 - 06:30 1.00 CLEAN P 06:30 - 07:30 1.00 CLEAN P 07:30 - 09:00 1.50 CLEAN P 09:00 - 10:00 1.00 CLEAN P 10:00 - 13:00 3.00 CLEAN P 13:00 - 13:30 0.50 CLEAN P 13:30 - 21:30 I 8.001 CLEAN I P I I DECOMP Spud Date: 6/24/1980 Start: 6/4/2008 End: Rig Release: 6/22/2008 Rig Number: Phase j Description of Operations DECOMP times. Jar on fish with 325,000 Ibs one time. Lost all overpull. P/U with 180,000 Ibs Up Wt. Pump at 3 bpm with 190 psi. Continue pumping and slowly RBIH to 8117' without tagging or any increase in pump pressure. P/U to 8116'. DECOMP Circulate 2 bottoms up at 11.5 bpm with 2270 psi. First bottoms up brought back gas in the returns and cleaned up after pumping 80 bbls. Continue circulating without seeing anymore gas. Monitor well to be dead. DECOMP Break out and blow down top drive. POOH standing back 4" HT-38 drill pipe in derrick. DECOMP UD Overshot BHA. L/D Fish. 21.29' of 5-1/2" Tbg, collar on bottom with pin threads broke off inside. DECOMP Clean and Clear Rig Floor of Subs and tools. Discuss option with town. DECOMP Wait on Wash Pipe and Rotary Shoe to arrive from fishing shop. DECOMP /U BHA #10 8-1/2" x 7" Metal Mucher Rota Shoe, 8-1/8" x 7-1/4" Wash Pipe and Extension. Total length of BHA #10- 366.07' DECOMP RIH with BHA to 8063'. DECOMP M/U Top Drive and Fill Pipe. Obtain Parameters, P/u Wt = 180,000 S/O Wt = 155,000 Ibs Rot Wt = 170,000 Ibs at 40 rpm's and 5,000 ft -Ibs free Torque. Pump Rate = 6.8 bpm at 800 psi. 21:30 - 00:00 I 2.50 I CLEAN I P 6/14/2008 ~ 00:00 - 05:00 ~ 5.00 ~ CLEAN ~ P 05:00 - 06:30 ~ 1.50 ~ CLEAN ~ P 06:30 - 09:30 I 3.001 CLEAN I P at 8132'. Burn over 5-1/2" Tbg ue and ~5-7,000 Ibs WOB. Sand bottoms u Continue to burn over Brown PBR with 5-18,000 Ibs WOB and 5-11,000 ft-Ibs Torque and 60-70 rpm's. Very Slow Burning over PBR approximately 1 ft average ROP from 1400 hrs to 1900 hrs. DECOMP Start millin on acl<er at 8156' with initial parameters of 6000 to 7000 Ibs WOB, 6000 ft-Ibs torque at 70 rpm and 640 psi at 6 bpm. Milled off .5' by 22:30 hrs. Increase WOB to 11,000 Ibs with 6000 to 7000 ft-Ibs torque at 70 rpm and 670 psi at 6 bpm. Increase rpm to 80 rpm with 7000 to 7500 ft-Ibs torque. Continue to vary parameters. Milled off .75' by 24:00 hrs. DECOMP Continue milling operations on PKR at 8156' with initial parameters of 6000 to 7000 Ibs WOB, 6000 ft-Ibs torque at 70 rpm and 640 psi at 6 bpm. Milled off .5' by 22:30 hrs. 6/13/2008. Increase WOB to 11,000 Ibs with 6000 to 7000 ft-Ibs torque at 70 rpm and 670 psi at 6 bpm. Increase rpm to 80 rpm with 7000 to 7500 ft-Ibs torque. Continue to vary parameters WOB 7000 to 18,000 Ibs with 6500 to 7500 ft-Ibs torque; Pump Rates- 0 to 3 bpm to 6 bpm with pump pressures from 260 to 660 psi; Milled off 1' b~ nn•19 rc. Milled off 1.5' by 01:15 hrs. Milled off 1.75' by 02:24 hrs. Milled off 2' at 03:14 hrs. Milled 2.25' at 03:45 hrs. Milled 2.25' at 4:30 hrs. Milled 2.25' at 05:00 hrs. Final de th milled- 158'x_.,,,._ DECOMP Pump high visc sweep at 12 bpm with 2220 psi. Sweep brought back a lot of metal scale and fine metal shavings. DECOMP ~ Pump Dry Job, B/O Top Drive and Blow Down, POOH and Printed: 7/7/2008 11:51:37 AM n u BP EXPLORATION Operations Summary Report Page 13 of 21 Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date 'From - To Hours I Task Code NPT Phase Description of Operations 6/14/2008 06:30 - 09:30 3.00 CLEAN P DECOMP Stand Back DP 09:30 - 10:00 0.50 CLEAN P DECOMP Stand Back DC's. B/O and C/O Boot Baskets. B/O Rotary Show and M/U new Rotary Shoe. Rotary Shoe pulled was about 95% lus A small amount or carbide left on about half to the shoe face other half down to bare metal. Inside carbides still in good shape. Recovered about 4 gallons of metal shaving from boot baskets. 10:00 - 14:00 4.00 CLEAN P DECOMP RIH with B rn ) on DP from derrick to 8064 ft. 14:00 - 15:00 1.00 CLEAN P DECOMP Establish Parameters, P/U Wt = 175,000 Ibs S/O Wt = 157,000 Ibs Rot Wt = 167,000 Ibs ~ 20 rpm's and 3,000 ft-Ibs. Pump Rate = 7 bpm ~ 830 psi. Continue in the Hole and Tag Top of Packer at 8156'. Burn Over Packer with 60 rpm's, -10,000 Ibs WOB and 5-11,000 ft-Ibs of Torque. 15:00 - 16:00 1.00 CLEAN P DECOMP Burn Over Packer to 8159', Start seeing fluid loss and some packer and push to 8184'. 16:00 - 17:00 1.00 CLEAN P DECOMP Small amount of gas starting to be seen at surface. P/U and Circulate Bottoms Up. Pumping 7 bpm at 800 psi, fluid loss 1 bpm while pumping. Rubber seen coming over shakers at bottoms u . 17:00 - 18:00 1.00 CLEAN P DECOMP M/U another Stand of DP. RIH to top of packer at 8184', rotate on packer pushing to 8210'. After 8210 ft packer moving 18:00 - 19:00 1.00 CLEAN P DECOMP 19:00 - 23:00 4.00 CLEAN P DECOMP 23:00 - 00:00 1.00 CLEAN P DECOMP 6/15/2008 00:00 - 01:00 1.00 CLEAN P DECOMP 01:00 - 04:00 3.00 CLEAN P DECOMP 04:00 - 04:30 0.50 CLEAN P DECOMP 04:30 - 05:30 1.00 CLEAN P DECOMP Pump 20 bbl High Visc Sweep and Chase out of the hole at 10 bpm and 1350 psi while rotating at 20 rpm and 4000 ft-Ibs torque. Fluid losses down to 40-50 bph while pumping. Small amount of gas in the returns at bottoms up. Sweep brought back chucks of rubber and metal cuttings. Shut down pumps and monitor well. Well loosing 40 bph static. Pump dryjob slug and blow down top drive. POOH standing back 4" HT-38 drill pipe in derrick. POOH and L/D BHA #11 and stand back 3 stands of 6-1/4" drill collars. Recover 2 gallons of metal shavings from boot baskets. P/U BHA #12 (overshot and gragole assemhlvl consisting of overshot with 5-1/2" guide, extension, bumper sub, jars, pump out sub, x/o sub, 3 stands of 6-1/4" drill collars from derrick, and x/o sub back to HT-38 drill pipe. Total length of BHA #12- 310.33' RIH with 83 stands of 4" HT-38 drill pipe from derrick to 8198'. Establish fishing parameters of P/U Wt- 180,000 Ibs; S/O Wt- 155,000Ibs; Pump Pressure- 200 psi at 3.4 bpm. Continue RIH and tag top of fish at 865', pump pressure increased to 220 psi. P/U 10' with no overpull and pump pressure back to 200 psi. S/O with slight right hand rotation and re-tag fish at 8265'. Swallowed top of fish. observe pump pressure come up to 270 psi. Stop rotation and pump. Continue to swallow 5' of fish to 8270', S/O to 8000 Ibs on fish. P/U with 184,000 Ibs up weight. S/O and confirm with no pump, same results. P/U with 184,000 Ibs up weight. P/U 20' and establish pump rate at 3.4 bpm with 300 psi. Drop ball and open pumpout sub with 1380 psi at 2.5 bpm. Printed: 7/7/2008 11:51:37 AM 1.501 CLEAN I P BP EXPLORATION Operations Summary Report Page 14 of 21 Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date 'From - To 'Hours Task '~ Code NPT :__ 6/15/2008 04:30 - 05:30 1.00 CLEAN ~ P 05:30 - 08:30 08:30 - 10:00 3.00 CLEAN P 1.50 ~ CLEAN ~ P 10:00 - 10:30 0.50 CLEAN P 10:30 - 11:30 1.00 CLEAN P 11:30 - 14:30 3.00 CLEAN P 14:30 - 16:00 1.50 CLEAN P 16:00 - 17:30 I 1.50 I CLEAN I P 17:30 - 19:00 19:00 - 19:30 19:30 - 22:30 22:30 - 00:00 • Phase. ~ Description of Operations DECOMP Continue CBU at 11 bpm with 1900 psi. Small amount of gas at bottoms up. Continue to circulate for a total of 1 hole volume, no more gas. Shut down pumps and monitor well. Static loss rate at 20 bph. DECOMP Pump dry job and blow down top drive. ,POOH with fishing assembl standin back 4" HT-38 drill pipe in derrick. DECOMP Stand Back DC's. POOH and UD BHA and Fish. Recovered 5-1/2" Tbg Stub, PBR and Latch. Packer and Tail Pioe still in the hole. Very Significant milling marks along the side of the PBR, basically slabbed one side of it. Fish Measure 26.22 feet. 5-1/2" Tbg Pup filled with Metal Shavings, Sand and Debris. The Top of the IBP Fish Neck found just at the connection of the 5-1/2" Tbg Pup and PBR /Slick Stick. PBR hand never been sheared and slick stick set full down on PBR. Baker Thru Tbg called to recover IBP. DECOMP Clean and Clear Rlg Floor, DECOMP M/U Spear BHA with ITCO Spear with Grapple for 4.75", Bumper Sub, Jars, Pump Out Sub, and DC's. DECOMP RIH with Spear BHA to 8166' on 4" DP from Derrick. DECOMP Slip and Cut 88 tt of 1-1/4" Drilling Line, Service Draw Works, and Dynamatic. DECOMP Establish Paramters; P/U Wt = 184,000 Ibs, S/O Wt = 155,000 Ibs, Pump Rate = 210 psi at 3 bpm, 340 psi at 4 bpm, 1050 psi at 7 bpm. Top of Fish estimated to be 8291'. S/O and Ta U on at 8212' and again at 8214', set down -10,000 lbs. Weight dropped off quickly and were able to continue down the hole. Pump pressure now up to 1200 psi at 7 bpm. Weight indicator showing no real noticable change from Initial Parameters. Tag up again at 8247' Stack 10,000 Ibs again, not moving. P/U with no noticable change in paramters, S/O and Tag Up at same spot. P/U and No Noticable change in P/U Wt. Slow pump rate to 4.0 bpm, presure stabilized at 430 psi. Make 4 left hand turns on pipe (Spear is RT hand Release). S/O and able to go down hole, thinking we have ?? Continue down hole to 8295'. Set down 10,000 lbs. P/U with no noticeable over pull. S/O again and to 8295' with 10,000 Ibs down. P/U with no noticable over pull again. Decide must have it, just to light to see. PUH and see 10,000 Ibs over pull at 8258'. Work up and down and able to pull through 8258' with 51,000 Ibs over pull, did not have to hit the jars. DECOMP PUH and UD Single joint of DP, drop dart for pump out sub. PUH with full stand to see if fish will catch in another spot, pulled cleanly for another 50 ft above 8258'. Circulate bottoms up at 10.3 bpm at 1720 psi. Dynamic fluid losses at 15 b~ No gas at bottoms up. MO 0.50 CLEAN P DECOMP Pump dry job slug, break out and blow down top drive. 3.00 CLEAN P DECOMP POOH standing back 4" HT-38 drill pipe in derrick. 1.50 CLEAN P DECOMP POOH with BHA #13. Stand back 2 stands of 6-1/4" drill collars. L/D BHA #13 with 3 joints of 6-1/4" drill collars. PJSM Printed: 7/7/2008 11:51:37 AM • BP EXPLORATION Page 15 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours I Task Code I NPT I Phase I Description of Operations 6/15/2008 22:30 - 00:00 1.50 CLEAN P DECOMP with Doyon rig crew and Toolpusher. Discuss Doyon's procedure to reduce risk of trapped pressure in fish. Punch tailpipe assembly to relieve the possibility of trapped pressure around the 2 Baker CIBPs installed in tailpipe. L/D fish. Total recovery of WLEG- 0.94'; Landing Nipple with Collar- 1.59'; 1 jt 4-1/2" Tubing- 41.55'; 4-1/2" x 5-1/2" X/O- 0.65'; Mill Out Extension- 6.37'; Remains of Packer- 4.97'. Total length of Fish- 56.07'. The joint of tubing was split vertically in 2 places. 6/16/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Clear and clean rig floor. 00:30 - 01:30 1.00 CLEAN P DECOMP P/U BHA #14 drift and cleanout assembl consisting of 6" used bit, 7" scraper, bit sub, (3) 4-3/4" drill collars, x/o sub, polish mill, x/o sub, bumper sub, x/o sub, x/o sub, (1) 6-1/4" drill collar, x/o sub, x/o sub, 9-5/8" scraper, bit sub, (5) 6-1/4" drill collars, and x/o sub back to 4" HT-38 drill pipe. Total length of BHA #14- 312.65' 01:30 - 04:00 2.50 CLEAN P DECOMP RIH with BHA #14 on 86 stands of 4"HT-38 drill pipe from derrick. Losses average 13 bph while RIH. 04:00 - 04:30 0.50 CLEAN P DECOMP Establish dressing parameters of P/U Wt- 185,000 Ibs; S/O Wt- 155,000Ibs; Rot Wt- 165,000 Ibs at 50 rpm with 6000 ft-Ibs free torque; Pump Pressure C~3 1180 psi with 8 bpm. Continue RIH reaming with WOB at 3-5K. Bottom out at 8404' bit depth/ 8303' reamer depth. Reamed tie back receptacle several times at 50 rpm with 6000 to 8000 ft-Ibs torque. Worked 7" scraper several times from 8325' to 8400'. Worked the 9-5/8" down to 8253'. 04:30 - 05:30 1.00 CLEAN P DECOMP Pump high visc sweep at 11 bpm with 2230 psi. Dynamic fluid losses at 13 bph. Sweep brought back a slight increase in metal across shakers. Monitor well. Static losses at 9 bph. 05:30 - 06:00 0.50 CLEAN P DECOMP Pump dry job stub, B/O and blow down top drive. 06:00 - 08:30 2.50 CLEAN P DECOMP POOH with polish mill standing back 4"HT-38 drill pipe in derrick. 08:30 - 09:30 1.00 CLEAN P DECOMP POOH and L/D polish mill assembly and (6) 6-1/4" drill collars. Stand back 1 stand of 4-3/4" drill collars in derrick. 09:30 - 10:00 0.50 CLEAN P DECOMP Clear and clean rig floor. 10:00 - 11:00 1.00 DHB P TIEB2 M/U HES FasDrill plug and RIH on 3 stand of 4-3/4" drill collars. 11:00 - 14:30 3.50 DHB P TIEB2 RIH with FasDrill plug. Tag Up two times at 8302' with 5,000Ibs down. P/U and make 1/4 turn and able to continue to in the hole to 8359'. 14:30 - 15:00 0.50 DHB P TIEB2 Establish parameters of P/U Wt- 163,000 Ibs; S/O Wt- 145,000 Ibs; Pump Pressure- 80 psi at 1 bpm. P/U and set FasDrill at 8355 ' (Top of Plug) with 25 right hand rotations. P/U to 215,000 Ibs and shear off from running tool. Stack 15,000 Ibs on FasDrill to confirm set. Monitor well. Lossing fluid at 1 bph 15:00 - 18:00 3.00 DHB P TIEB2 B/O an B/D top drive. POOH with HES FasDrill running tool standing back 4" HT-38 drill pipe in derrick. UD running tool. 18:00 - 18:30 0.50 DHB P TIEB2 Clear and clean rig floor. 18:30 - 21:30 3.00 EVAL P TIEB2 M/U 9-5/8" RTTS and RIH with 85 stands of HT-38 drill pipe from derrick. Establish parameters of P/U Wt- 120,000 Ibs; S/O Wt- 120,000 Ibs. RIH to 5512'. Set RTTS with 1 right hand revolution and S/O 20,000 Ibs on RTTS. 21:30 - 23:00 1.50 EVAL P TIEB2 R/U to pressure test and chart casing test from 551~~:5=.- Printed: 7/7/2008 11:51:37 AM • BP EXPLORATION Page 16 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date !From - To I Hours Task Code NPT Phase Description of Operations ~ - 6/16/2008 21:30 - 23:00 1.50 -- _ EVAL P _ TIEB2 _ Pressure test to 2500 si and hold for 15 charted minutes. Swapped pump line up to pumpd down backside and Perform LLR at 500 si for 5 charted minutes with LLR of 0.5b m. Perform LLR at 1000 psi for 5 charted minutes with LLR of 4 ~.,ry„ ~,rfn ~ 00 psi or 5 charted minutes with LLR of 6 b m. Bleed ressure well ave 16 bbls back. 23:00 - 00:00 1.00 EVAL P TIEB2 Unseat RTTS. R/U to CBU and condition brine back to 9.4 ppg. 6/17/2008 00:00 - 02:00 2.00 EVAL P TIEB2 POOH with RTTS, Stand Back DP and DC's. L/D RTTS. 02:00 - 02:30 0.50 CASE P TIEB2 Clean and Clear Rig Floor. 02:30 - 04:00 1.50 CASE P TIE62 PJSM with rig crew and support. Discuss casing running procedures with the use of the new centralizer holder. R/U Doyon Torque Turn equipment, tongs, 7" sidedoor 150 ton elevators with safety pin, and hole fill line. 04:00 - 06:00 2.00 CASE P TIEB2 P/U 7", 26#, Cr80, Vam Top casing BHA consisting of 1/2 cut mule shoe, ported pup joint with oat co ar inserted in box end, 1 full joint with float collar inserted in box end, 1 full joint, 1 full joint with landing collar inserted in pin end, 8 full casing joint, and 1 X/O casing joint 7" Vam Top Pin x BTC Box. Each connection was torque turned to 8300 ft-Ibs, Baker-Lock each connection under landing collar, stabbing guide used on each joint, and Jet Lube Seal Guard thread compound used. Kicked out Jt #s 7, 8, and 9 due to galled threads. 06:00 - 08:00 2.00 CASE P TIEB2 Order out and Wait for replacement VamTop jts. 08:00 - 08:30 0.50 CASE P TIEB2 Load and Tally new VamTop jts. 08:30 - 12:00 3.50 CASE P TIEB2 Replace VamTop jts and Continue to RIH w/ 7" 26# L80 BTC-M Scab Liner to 2 208' md. Make up BTC-M to stamp using Best O Life 2000 thread compound. Fill liner every 5 jts. 12:00 - 17:30 5.50 CASE P TIE62 Continue to RIH w/ 7" 26# L80 BTC-M Scab Liner from 2.208' '. Make up BTC-M to stamp using Best O Life 2000 pipe compound. Fill liner every 5 jts. 17:30 - 20:00 2.50 CASE P TIEB2 MU Baker Liner To Packer assembl to 5 384' md. RIH on 4" DP from 5,384' to 8,300' md. Fill DP every 10 stds. PU wt = 212K, SO wt = 185K. Continue RIH and tag 7" liner top ~ 8.308' md. PU and retag to confirm dept aw o le at 8,303' and and then continued in hole to 8,308' md. 20:00 - 21:30 1.50 CASE P TIEB2 Space out and lay down single. PU 15' 4" DP pup jt and Cement head. RIH and retag 7" liner top ~ 8,308' md. PU to Neutral weight. Circulate with 5 pm psi. 21:30 - 22:00 0.50 CASE P TIE62 PJSM -Cementing 7" Scab Liner with Rig Crew, BP WSLs, Schlumberger cementers and CH2MHILL drivers. Outlined upcoming events and highlighted potential hazards. Assigned crew positions during cement job. 22:00 - 22:30 0.50 CASE P TIEB2 Pump 5-bbls water. Schlumberger pressure test all lines to 4500-psi. 22:30 - 00:00 1.50 CASE P TIEB2 Pum 10-bbls neat 15.8 Class "G" Lead slur f II 10-bbls of .25 Ib/sack Cell-O-FI ke treate lead slur .Continue with 150-bbls of neat 15.8 CI "G" lead slur .All lead slurry mixed on the fly Chase.laad-wtL 30-bbls batch mixed 15.8 ppg tail slurry w/ GasBlok. Shut own and drop Drill pipe wiper dart. Chase dart with 10-bbls fresh water. Swap over to Rig pumps and displace cement with 9.4 ppg brine at 5-bpm. Close Annular preventer and Printed: 7/7/2008 11:51:37 AM C7 BP EXPLORATION Page 17 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/17/2008 22:30 - 00:00 1.50 CASE P TIEB2 open up to choke @ 1400 stks (cement above cretaceous leak C~ 5 000' md). Attempt to hold 500-psi backpressure to squeeze away cement. Able to hold 480- si wit c o e ill closed while pumping at 2.5-bpm. Pump 40-bbls with choke closed, seeing max pressure of 2,100-psi.. Open up choke and continue to pump brine. 6/18/2008 00:00 - 01:00 1.00 CASE P TIEB2 Continue displacing cement w/ 9.4 ppg brine. Plug bumped w/ 3 300- si. Pressure u to 4 200- si and hold to set Liner To Packer. Checked floats -holding. CIP at 12:34 am. Bleed pressure to 1,000-psi and release C-2 running tool. 01:00 - 01:00 24.00 CASE P TIE62 Pump 20-bbl Biozan pill and chase out of hole at 12 bpm / aw very thin cement returns just prior to pill 2,000-psi. S _ returnin . 01:30 - 02:30 1.00 CASE P TIEB2 Flush IA, Cement lines and BOP stack w/ Biozan pill. Blow down all lines. Break out and LD cement head assembly and 2 jts 4" DP. 02:30 - 04:00 1.50 CASE P TIEB2 POH w/ 4" DP f/ 2,900' to surface. Break out and LD C-2 running tool. PU cement head assembly and break out and LD. 04:00 - 05:00 1.00 CLEAN P CLEAN PU Stack washer and flush stack of any remaining cement. Blow down Top Drive. Clean out Drip pan. 05:00 - 05:30 0.50 CLEAN P CLEAN PU 7" Scab liner Drill out BHA. 05:30 - 06:30 1.00 CLEAN P CLEAN Service Top Drive and Iron Roughneck 06:30 - 07:30 1.00 CLEAN P CLEAN R/U to test BOPE, Attempt first test and test plug failed. 07:30 - 08:30 1.00 CLEAN P CLEAN Wait on new Test Plug to be delivered from FMC 08:30 - 09:00 0.50 CLEAN P CLEAN M/U test plug and install in well head. 09:00 - 13:00 4.00 CLEAN P CLEAN Test ROPE to 250 si Low Pressure and 3 500 si Hi Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by John Crisp. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1-Annular Preventer, Choke HCR, Kill HCR, Upper IBOP Test #2- Manual Kill, Manual Choke, Lower IBOP, Test #3- Choke Valves # 1, 12, 13, 14, TIW. Test #4- Choke Valves # 9-11, Dart Valve. Test #5-VBRs on 4" Test Joint, Test #6- Blinds, Choke Valves 5,8,10. Test #7- Choke Valves 4, 6, 7. Test #8- Choke Valve 2. Test #9- Choke Valve 3. Test #10- VBRs on 4.5" Test Joint. Test #11- Hydrill with 5.5" Tbg. Accumulater Test- 2,950 psi Starting Pressure, 1,750 psi After Actuation, First 200 psi in 17 seconds, Full Pressure in 1 Minute 17 Seconds. 5 Nitrogen Bottles at 2,150 psi. 13:00 - 13:30 0.50 CLEAN P CLEAN Pull Test plug and install Wear Ring. 13:30 - 14:30 1.00 CLEAN P CLEAN M/U Drill out Assembl BHA Consists of:6" bit, 2-Junk Baskets, 7" CS Scraper, Bit Sub, 3 - 4 3/4, xo. 14:30 - 18:00 3.50 CLEAN P CLEAN RIH with 4" Drill pipe from derrick to 8,118' md. 18:00 - 18:30 0.50 CLEAN P CLEAN Ta cement strin er at 8118'. Break circulation at 6 bpm / 1000 psi. Rotate at 60 rpm with 4K ft-Ibs of torque. Wash and Ream Printed: 7/7/2008 11:51:37 AM • BP EXPLORATION Page 18 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date 'From - To I Hours Task Code NPT Phase Description of Operations 6/18/2008 18:00 - 18:30 0.50 CLEAN P CLEAN ahead until tagging Liner wiper plug at 8,201' md. 18:30 - 19:00 0.50 CLEAN P CLEAN 1.5x BU bbls at 12 bpm until shakers clean up. Drilled cement seen at bottoms up. Establish drilling parameters: P/U wt: 165k, S/O : 145k 19:00 - 19:30 0.50 CLEAN P CLEAN Clean and clear rig floor. Rig up to pressure test 7" 26# Scab Liner 19:30 - 21:30 2.00 CLEAN P CLEAN Pressure Test New 7" Scab Liner to 3500psi. Good Test. 21:30 - 22:00 0.50 CLEAN P CLEAN RD test equipment. Blow down Kill line. Clear Rig floor. RIH with Drill out assembl to Liner wi er lu 22:00 - 00:00 2.00 CLEAN P CLEAN Begin drilling out shoe track. PU wt = 165K, SO wt = 145K, Rot wt = 155K. Rotate at 70 rpm / 5K free torque. Circulate at 5 bpm / 630 psi. WOB = 12K with 5K on bottom torque. 6/19/2008 00:00 - 03:30 3.50 CLEAN P CLEAN Drill out 7" 26# L-80 BTC-M Scab Liner shoe track from 8,202' and to 8337 'md. Pump 20-bbl Hi Vis sweep once ROP increased when thru landing collar at 8,205' md. Continue to drill ahead thru shoe track to 8,340' md. 03:30 - 04:30 1.00 CLEAN P CLEAN Pump 20-bbl Hi Vis Sweep and Displace well to clean sea water. Pump at 8-bpm / 1,600-psi. Obtain Slow Pump Rates with Mud Pump #2: 30 spm = 250-psi, 40 spm = 350-psi. 04:30 - 05:00 0.50 CLEAN P CLEAN Continue to drill from 8,340' to and drill fast drill lu at 8 35: with 5-10,000# WOB and 70 rpm, 5 bpm with 670 psi. 05:00 - 05:30 0.50 CLEAN P CLEAN CBU at 11 bpm with 2,200 psi. Saw fine debris from FasDrill plug being drilled up. 05:30 - 08:30 3.00 CLEAN P CLEAN RIH from 8 355' and and to to of fill at 9 252' md. Wash and re m to 9 442 m '. 08:30 - 10:30 2.00 CLEAN P CLEAN Pump two 20-bbl Hi Vis Sweeps at 11-bpm / 2200 psi. Saw returns of Frac Sand, Metal and Rubber. 10:30 - 11:30 1.00 CLEAN P CLEAN Blow down top drive. Lay down 34 joints DP from 9442' MD to 8371' MD. 11:30 - 12:00 0.50 CLEAN P CLEAN R/U to obtain LLR 12:00 - 12:30 0.50 CLEAN P CLEAN Perform Liquid Leak Rate Test: 0.6 bom loss ~ 500 osi. 1.8 bom ~ 1000 psi. 3.6 bpm ~ 150 12:30 - 13:00 13:00 - 16:30 0.50 3.50 CLEAN CLEAN P P CLEAN CLEAN 43 total bbls seawater in'ected. Pump 10 bbl dry job. Blow down top drive. POOH from 8,371' to 294' md. Reciprocated casin sc from 8266' to 8171' and from 8076' to 7887' (liner hanger and com letion acker settin de the . Lay down collars and scraper assembly. Recovered -3 gal junk from boot baskets 16:30 - 18:00 1.50 CASE P TIEB3 R/U to run 4.5" 13Cr80 Vam Top liner. Change out bails & e evators. R/U power tongs, Torque Turn equipment, fill up line. 18:00 - 18:30 0.50 CASE P TIEB3 PJSM w/ Baker, Doyon Casing hand, and rig crew on liner running procedures & safety. 18:30 - 21:00 2.50 CASE P TIE63 RIH w/ 36 jts of Condition B, 4.5" 13Cr80 Va floating centralizer / it. Make up monitored with Torque Turn services. Use Jet Lube Seal Guard thread compound and Baker lock shoe track. No rejected joints. RIH to 1211' md. 21:00 - 22:30 1.50 CASE P TIEB3 RD 4 1/2" Vam Top liner handling tools. P/U liner hanger & 1 stand DP. RIH to 1343' md. Pump liner Printed: 7/7/2008 11:51:37 AM • • BP EXPLORATION Page 19 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours I! Task Code NPT Phase Description of Operations 6/19/2008 21:00 - 22:30 1.50 CASE P TIEB3 volume ~ 50 spm ~ 250 psi. Establish P/U & S/O weights: P/U - 60k S/O-60k 22:30 - 00:00 1.50 CASE P TIEB3 Continue RIH w/ w 36 'ts 4.5" liner Baker 5" x 7" ZXP liner to acker & 4.5" HMC Liner han er on DP from 1 343' to 2 220' 6/20/2008 00:00 - 04:00 4.00 CASE P TIE63 Continue RIH w/ w 36 jts 4.5" liner, Baker 5" x 7" ZXP liner top packer & 4.5" HMC Liner hanger on DP from 2,200' to 9,325' md. 04:00 - 04:30 0.50 CEMT P TIEB3 Obtain parameters - PU wt = 180K, SO wt = 155K. P/U & make up cement head. 04:30 - 05:00 0.50 CEMT P TIE63 Break circulation w/ 3 bpm ~ 250 psi. Tag ~ 9442' MD. P/U to neutral lus 2 additional fe t 05:00 - 05:30 0.50 CEMT P TIE63 PJSM w/ Rig crew, SLB cementers, Baker completion hands, & CH2M Hill Vac truck drivers. Begin to batch mix cement and bring to weight. 05:30 - 07:30 2.00 CEMT P TIE63 Switched to Schlumberger, Pumped 5 bbls Water, 2 bpm, 100 psi. Shut in Cement Manifold, Tested Lines to 4,500 psi, OK, Bled Down Pressure. Pumped 60 bbls of Class G Cement with 1.5 gal/sk Gasblock, .200 gal/sk Antifoam, .300% BWOC Dispersant, .320% BWOC Retarder, .150% BWOC Antisetting. At the Following rates: Pumped Rate Pressure 5 bbls 4.5 bpm 384 psi 20 bbls 4.5 bpm 201 psi 40 bbls 4.5 bpm 255 psi 60 bbls 1.1 bpm 40 psi Dro ed To Wi er Plu ,Pumped 5.0 bbls Water 4.50 bpm, 200 psi. Switched to Rig Pumps and Displaced Cement with 95 bbls of Clean Seawater at the Following Rates: Pumped Rate Pressure 25bbls 6 bpm 290 psi 50 bbls 6 bpm 500 psi 75 bbls 3.5 bpm 690 psi 95 bbls 3 bpm 3000 psi Bumped the plug with 95.5 bbls of total dis lacement, held_ pressure or 5 minutes, led off pressure and checked floats , float held. Set Liner hanger and rotated out with 15 turns and Set liner top packer. Cement in place at 06:30 AM and top of liner at 8,197'. 07:30 - 08:00 0.50 CEMT P TIEB3 Circulate 20 bbl Hi-Vis Biozan Sweep at 11 bpm and 2,000 psi. A rox 40 bbls of contaminated seawater back to surface. 08:00 - 08:30 0.50 CEMT P TIEB3 B/O and L/D Cement Head and L/D 2 joints of Drill Pipe. 08:30 - 09:00 0.50 CEMT P TIEB3 CBU at 11 bpm with 2,000 psi. Printed: 7/7/2008 11:51:37 AM BP EXPLORATION Page 20 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date II From - To Hours Task Code NPT Phase Description of Operations 6/20/2008 09:00 - 09:30 0.50 CEMT P TIEB3 Clear and Clean Rig Floor, Flush BOP Stack, Flow line, IA valve with Citric pill. 09:30 - 10:30 1.00 CEMT P TIEB3 Slip and Cut 81' of drilling line. 10:30 - 11:00 0.50 CEMT P TIEB3 P/U Cement head and break it down. 11:00 - 17:00 6.00 CEMT P TIEB3 POOH from 8.197 to Running tools. UD DP 17:00 - 18:00 1.00 BUNCO RUNCMP Drain and flush stack. Pull wear ring. UD liner running tools 18:00 - 19:30 1.50 BUNCO RUNCMP R/U 4-1/2" 12.6# 13Cr80 VamTop tubing handling equipment 19:30 - 20:00 0.50 BUNCO RUNCMP Pressure Test casing to 3500 psi for 30 charted mins. Good test. 20:00 - 20:30 0.50 BUNCO RUNCMP PJSM to discuss RIH 4 1/2" 12.6# 13Cr80 Vam Top completion w/ Rig crew, Doyon casing services and Baker completion 20:30 - 00:00 3.50 BUNCO RUNCMP Begin running in hole with 4 1/2" 12.6# 13Cr80 Vam Top completion. Utilize Torque Turn Services. BakerLok all connections below Packer. Use Jet Lube Seal Guard on all Vam Top connections. At 2,030' and (Packer ~ 1,893' and and GLM #1 C~3 1,785' md.) tagged something and set down 10K. Picked up with 10K overpull. Discuss options and decide to attempt to continue RIH. 6/21/2008 00:00 - 00:30 0.50 BUNCO RUNCMP Continue to RIH with 4-1/2" 12.6# 13Cr80 Vam Top from 2,030' md. Within 5' tag something and set down 10K again. Weight falls off quickly. 00:30 - 01:00 0.50 BUNCO RUNCMP Discuss situation with Workover Engineer. Decide to attempt to RIH. 01:00 - 09:00 8.00 BUNCO RUNCMP Continue to RIH with 4-1/2" Completion. From 2,035' to 2,839' md, completion continues to hang up every 30' indicating collar interference. Weight falls off with 5-10K set down and 1/8 turn to the right. Continue RIH without incident from 2,839' to 6,000' md. 09:00 - 09:30 0.50 BUNCO RUNCMP P/U Landing jt, M/U Tbg Hanger and RIH, RILDS, WLEG at R nRi' nn n narkor at 7 9d'~' P/1 I Wainht = 13n nM-Ihs~ S/(~ weiynt= ico,uuu-ios. 09:30 - 10:00 0.50 BUNCO RUNCMP PJSM with Truck drivers and Rig Crew on displacement procedure and safety concerns, R/U to reverse in Packer Fluid. 10:00 - 12:30 2.50 BUNCO RUNCMP Pressure test lines to 3,500 psi, reverse in 125 bbls of 120 deg seawater followed by 255 bbls of corrosion inhibited seawater at 3 bpm with 180 psi. 12:30 - 14:00 1.50 BUNCO RUNCMP Dropped the ball and rod, set packer and pressured up to 3,50( 'a up on me annuws to s,5uu psi ana neia test 1 minutes. Bleed off tubing pressure rapidly and [ at 1,100 psi tubing pressure. Circulated in both 14:00 - 14:30 0.50 RU 14:30 - 15:00 0.50 RU RUNCMP UD Landing joint and set TWC. RUNCMP Pressure tested the TWC to 1,000 psi from below and 15:00 - 15:30 0.50 BOPSU P RUNCMP Drain BOP stack and blow down surface lines. 15:30 - 16:30 1.00 BOPSU P RUNCMP Nipple down BOPs and R/D the top drive. 16:30 - 18:00 1.50 WHSUR P RUNCMP N/U Adapter Flange and Production Tree. 18:00 - 19:00 1.00 WHSUR P RUNCMP Test Adapter flange and Hanger to 3500 psi. Hold test for 30 minutes. Good test. Fill Tree with diesel 19:00 - 20:30 1.50 WHSUR P RUNCMP Test production Tree to 3500 psi. Hold test for 30 charted minutes. Good test. 20:30 - 21:00 0.50 WHSUR P RUNCMP RU DSM lubricator and pressure test to 500 psi. Good test. Printed: 7/7/2008 11:51:37 AM • • BP EXPLORATION Page 21 of 21 Operations Summary Report Legal Well Name: 06-15 Common Well Name: 06-15 Spud Date: 6/24/1980 Event Name: WORKOVER Start: 6/4/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/22/2008 Rig Name: DOYON 16 Rig Number: Date From - To I~! Hours Task Code NPT Phase Description of Operations 6/21/2008 20:30 - 21:00 0.50 WHSUR P RUNCMP Pull TWC with lubricator. No ressure below TWC. Well on vac. 21:00 - 22:00 1.00 WHSUR P RUNCMP PJSM on circulating freeze protection with Rig crew, FMC hand and Little Reds. RU Little Reds Hot Oil services for circulating diesel freeze protection. Pressure test lines to 3500 psi. Reverse in 150-bbls diesel to freeze protect to _2,200' md. Circulate at 2 bpm / 750 psi. 22:00 - 23:00 1.00 WHSUR P RUNCMP Line up and allow diesel to U-tube for 1 hr. 23:00 - 00:00 1.00 WHSUR P RUNCMP FMC tech T-bar in TWC. Test TWC from below to 1000 psi for ** Ria Released at 0000 h Printed: 7/7/2008 11:51:37 AM Digital Well File ~ ~ Page 1 of 1 Well: 06-15 Well History Well Date Summary 06-15 6/23/2008 T/I/0=0/0/0; Pull 4-1/8" CIW "H" BPV Thru Tree Post Rig; 1-2' Ext Used Tagged @ 102" ***Complete*** (Best/Wortham) 06-15 6/24/2008 ***WELL S/I ON ARRIVAL*** (POST RWO) PULL BALL & ROD FROM RHC PLUG BODY ~ 8069' MD ***CONTINUED ON WSR 06/25/08*** 06-15 6/25/2008 ***CONTINUED FROM WSR 06/24/08*** (post rig) PULLED BALL &ROD FROM RHC PLUG BODY @ 8069' MD , PULLED DGLV FROM STA #3 (5585' MD) & PULLED SHEAR VALVE FROM STA #4 (3373' MD) SET BK-LGLV IN STA#4 (16/64, 1500#) @ 3372' MD & BK-OGLV (20/64) IN STA#3 ~ 5585' MD PULLED 4-1/2" RHC PLUG BODY FROM XN NIP ~ 8069' MD TAGGED TD Cc~ 9326' SLM (+1' CORR. TO 9327' MD) W/ 3-3/8" DMY GUN & SAMPLE BAILER. ***WELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED*** 06-15 6/27/2008 ***WELL SHUT IN UPON ARRIVAL*** INITIAL T/I/O/ = 0/0/0 . AFTER PT WAS DONE, HAD A DIESEL SPILL FROM LUBRICATOR. CALLED SPILL RESPONCE TEAM, PE, SLB OHSE, DSO AND COLLECTED CONTAMINATED GRAVEL. RIH WITH 2-7/8" PJ OMEGA GUN TO PERFORATE 9225-9250' INTERVAL. ***CONTINUED ON 28-JUNE-08*** 06-15 6/28/2008 ***CONTINUE FROM 27-JUNE-2008*** WELL SHUT IN UPON ARRIVAL. RIH WITH 2-7/8" PJ OMEGA GUN TO PERFORATE 9225-9250' INTERVAL. GUN FIRED. FINAL T/I/O = 0/0/0. DSO NOTIFIED UPON DEPARTURE. ***JOB COMPLETED*** Print Date: 7/17/2008 Page 1 of 1 http://digitaiwellfile.bpweb.bp.com/WI Info/Reports/ReportViewer.aspx 7/17/2008 WELLHEAD = ACTUATOR = FMC AXELSON KB. ELEV = 68' BF. ELEV . ..~ KOP - 5200' "'~" Max Angfe = 28 @ 5800' Datum MD = 9079' Datum TV D = 8800' SS 9 5I8" L-80 Hydril 563 1750' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2678' "x 9 5/8" Baker ZXP LNR PKR & Flex Lok LNR HGR I 2932' 0 ~ -15 SA NOTES: ***CHROME TUBING & LINER 2076' I--14-1/2" 9Cr HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3373 3373 0 KBG2 DOME BK 16 06/25/0 3 5585 5566 23 KBG2 SO BK 20 06/25/0 2 7154 6978 19 KBG2 DMY BK 0 06/19/0 1 7846 7649 12 KBG2 DMY BK 0 06/19/0 7912, 14-1/2" 9Cr HES X NIP, ID = 3.813" 7943' 7" X 4-1/2" BKR S-3 9Cr PKR 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" ~ 8081' 5"x7" Baker ZXP LNR PKR & HMC LNR HGR 8198' TOP OF 7" LNR 8299' 7" LNR, 26#, L-80 BTC, ID= 6.276" 8303' 9-5/8" CSG, 47#, L-80, .0732 bpf, ID = 8.681" $622' PERFORATION SUMMARY REF LOG: BHCS ON 07/20/80 ANGLE AT TOP PERF: 4 @ 9100' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9100 - 9104 S 09/17/87 3-1/8" 4 9124 - 9144 S 10/05/85 3-1/8" 4 9154 - 9174 S 10/05/85 3-1/8" 4 9184 - 9200 S 07/17/87 3-3/8" 4 9200 - 9204 S 06/20/08 3-3/8" 6 9216 - 9226 S 08/03/91 2-7/8" 6 9225 - 9250 O 06/28/08 3-3/8" 4 9226 - 9245 S 06/20!08 3-3/8" 4 9248 - 9263 S 06/20/08 3-3/8" 4 9263 - 9264 S 08/04/91 14-1/2" LNR, 12.6#, 13CR 80, ID= 3.958" I $007, 4-1/2" 9Cr HES X NIP, ID = 3.813" 8069, 4-1/2" 9Cr HES XN NIP, ID =3.725 I 9467' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 9535' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNtT 07131/80 ORIGINAL COMPLETION WELL: 06-15 12/18/80 LAST WORKOV ER PERMIT No: 1800320 06/21/08 D16 RWO API No: 50-029-20459-00 06/25/08 GJB/SV GLV GO (06/25/08) SEC 2, T10N, R14E, 1384,16' FEL & 3836.36' FP 06/29/08 JKD/SV ADPERF (06/28/08) RD Fvnlnr~+inn lAl~c4~1 06/11/08 ~4~11111~1~G~~~1_ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~~~ JUN Y ~~ 2008 Well Joh # ~~ 1 nn r)racrrinfinn NO.4745 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 flflfu RI !`nlnr f+il P2-13 11978463 STATIC PRESS & TEMP G! 06/03/08 1 12-05A 11963097 MEM PROD PROFILE 06/01/08 1 1 P2-06 12014018 PRESS & TEMP LOG ~ - 0 06/03/08 1 1 N-14A 12017297 LDL -'~~ ( 06/10/08 1 1 K-12A 11966245 SCMT - 06/06/08 1 1 06-15 11966256 USIT ~ 3 06/07/08 1 1 A-13 12031481 USIT /~~- G G (~ 06/06/08 1 1 P2-45B 40016680 OH MWD/LWD EDIT ~ - ( ~/ ~ 03/13/08 2 1 ra.~e~v~/'~v~v~v YYLGV~TG 11GV Gr'1 Dl X71 L11YIIYV AIYV nC1 Y111VIIVl7 VIVC VVF'T CAl.rl IV: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. , Anchorage, Alaska 99508 Date Delivered: _ ' _ r`. U ~.~..~ `. Alaska Data & Consulting Services 2525 Gambell Street, Sui 400 Anchorage, AK 99503- 38 ATTN: Beth Received by: • • Prudhoe Bay RWO 06-15 • Maunder, Thomas E (DOA) • Page 1 of 2 From: Maunder, Thomas E (DOA) Sent: Thursday, May 29, 2008 10:02 AM To: 'Chan, Paul (PRA)' Cc: Reem, David C; Worthington, Aras J Subject: RE: Prudhoe Bay RWO 06-15 (180-032) Paul, et al, Thanks, I don't see any issue with the proposed reorganization of the procedure steps. Nothing further is needed. I will place a copy of this message in the file. Good move. It is nice to know that the safety and efficiency can be enhanced with a little reorganization. Call or message with any questions. Tom Maunder, PE AOGCC From: Chan, Paul (PRA} [mailto:Paul.Chan@bp.com] Sent: Thursday, May 29, 2008 9:38 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C; Worthington, Aras ] ~~~€Q ~ u~ ~'~ ~' ~~~~ Subject: RE: Prudhoe Bay RWO 06-15 Tom The well has a surface casing leak and the in previous proposed procedure, the 4-112" scab liner was rum first. In the revised procedure, BP would like to fix the 13-318" surface casing leak first by doing a 9-5/8" cut and pull operation. By fixing the surface casing leak first, BP eliminates the 13-3/8" surface casing leak as an issue for maintaining well'bore integrity while performing the remainder of the workover. The efficiency of the workover is enhanced by eliminating the need for vac trucks and manpower that would be needed to monitor the surface casing leak until the leak was repaired. Thanks Paul Chan Intervention Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 29, 2008 9:18 AM To: Chan, Paul (PRA) Subject: RE: Prudhoe Bay RWO 06-15 Paul, Could you comment on how you have changed the steps in the procedure and how safety and efficiency is 5/29/2008 '~ -_____ Prudhoe Bay RWO 06-15 enhanced? Thanks in advance. Tom Maunder, PE AOGCC Page 2 of 2 From: Chan, Paul (PRA} [mailto:PauLChan@bp.com] Sent: Thursday, May 29, 2008 9:14 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C; Worthington, Aras J Subject: Prudhoe Bay RWO 06-15 Tom Ref: PTD 180-032 Sundry Number: 308-129 «06-15 AOGCC Scope of Work Rev 1.ZIP» After further review of the Sundry Application for this well, BP would tike to re-order the sequence of events to enhance the safety and efficiency of the workover. I have attached a revised Proposed Procedure for your review. Please advise if this revised procedure is acceptable. Sincerely Paul Chan Intervention Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) {907) 554-5510 (fax) 5/29/2008 by G~~~~ 06-15 Expense Rig Workover, Rev 1 • Scope of Work: Pull 5-'/z' completion, cut and pull 9 6/8" casing, run and cement 9 5/8° casing to surface, mill and retrieve Baker SAB-3 packer, run and cement 7" scab liner, run and cement 4-1/2" scab liner inside 7" production liner, run 4-''/z" 13Cr-80 tubing with Baker S-3 packer set at 8000' MD. MASP: 2373 psi Well Type: Ivishak Producer Estimated Start Date: June 4, 2008 Production Engineer: Ana Seltenright Intervention Engineer: Paul Chan Pre-riq prep work: S 1 Drift thru 5-'/" tubin for tubin cut. E 2 Set IBP middle element at 8156' in the middle of the PBR assembly. MIT T to 1500 psi. Power Jet cut 5-%2" L-80 tubing at 8115' MD, in the middle of the first full joint above the Baker SAB-3 acker. Reference tubin tall dated 12/18/80. F 3 Circulate well with kill weight fluid and diesel thru the cut. Pertorm L&K if needed so pressures are zero across the board. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaks a check one at a time . PPPOT-T 8~ IC. W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure 1. MIRU workover rig. ND tree. NU and test BOPE pipe rams to 3500 psi. Test annular preventer to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Retrieve 5-'/2" tubing string down to the packer. 3. Set 9-5/8" RBP#1 100' above tubing stub. 4. RIH with 9-5/8" RTTS to 5500' MD and pressure test RBP #1 to 1500 psi. POOH and LD RTTS. 5. RIH and set RBP #2 at 4500' MD. Pressure test to 1500 psi. 6. Run USIT log to determine top of cement in the 9 s/8" casing. 7. Set and test 9 5/s' RBP #3 approximately 100' below estimated TOC. Note: The VBRs in the BOPs will NOT be changed over to 9 5/8" pipe rams as the barriers to the reservoir will be the tested 9 b/e" RBPs. 8. Cut and pull 9 $/8" above TOC. 9. Run and fully cement 9-%" casing to surface. 10. Drillout 9 g/8" shoe track. 11. Retrieve all 9-5/8" RBPs. 12. Mill and retrieve Baker SAB-3 packer at 8161' MD. 13. Run 6" bit, 7" scraper, and 9 5/a" scraper to 9467' PBTD. 14. Set 7" composite plug at 8350' MD. 15. RIH with 9 5/8" RTTS to 6000' MD and pressure test down to the 7" plug. POOH and LD RTTS. C~ 16. Run and cement 7" L-80 scab liner from 3000' - 8299' MD. Note: The VBRs in the BOPs will NOT be changed over to 7" pipe rams as the barrier to the reservoir will be the 7" composite plug. 17. Retrieve 9 5/8" RBP. 18. Drillout 7" shoe track and composite plug. 19. Run and fully cement 4-'/2" 13Cr scab liner from w8200' MD to 9467' PBTD. 20. Run 4-'/" 13Cr-80 tubing with Baker S-3 packer set at 8000' MD. 21. Displace the IA to packer fluid and set the packer. 22. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 23. Set BPV. ND BOPE. NU and test tree. RDMO. 04/25/08 NO. 4673 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ATTN ~ 0 2 ~,,, c~ Attn: Christine Mahnken : Beth ~ I 333 West 7th Ave, SUlte 100 11 ~ ~ C b J ~J Anchorage, AK 99501 won i.,h ~ ~ ~.. .. 2-52/S-14 11846807 PRODUCTION PROFILE (REDO) - 08/18/07 1 1r F-22 12005209 MEM TEMP SURVEY 04/08/08 1 1 MPB-09 11963093 MEM PROD PFOFILE _ ~ 04/13/08 1 1 MPL-33 11963090 MEM INJECTION PROFILE 04/11/08 1 1 MPF-89 11963092 MEM TEMP SURVEY 04/12/08 1 1 L5-29 11963087 MEM TEMP SURVEY Q 04/04!08 1 1 S-26 12071843 SBHP SURVEY > .. 04/03/08 1 i 06-15 11962594 LDL ~- (0 04/09/08 1 1 W-30 12034892 PROD P OFILE J~y~../~ /(,~/.(~ 04!11/08 1 1 L-221 11962592 USIT/CBL ~~~ ~b`71' _ 1 !>°o/ 04!07/08 1 1 4-14A/S-37 11970818 CH EDIT PDC GR JEWELRY ~_ ~ 03/24/08 1 18-326 11978442 MCNL ~i. C 02/26/08 1 1 G-24A 11660525 MCNL ~!t 02/02/07 1 1 ..._ ............ ~.......~ ..~...-.. , .. , ,,,........... n~.v nc ~ vn~.uv~a vw~ a.vr r cr+~.n ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. A Anchorage, Alaska 99508 ~~ANNE6~ APR ~ 9 200 Date Delivered: ` " ~ ~J, , ; ~~~t~3 7 Alaska Data & Consulting Service 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2838 ATTN: Beth Received by: ""~~-~!_ ' v~ • • •.. ~ ~„ ~~"~~ ~ ~~°` ~~ 1 ~+ ~~-~ SARAH PALJN, GOVERNOR O~ A1QD ~irA,S 333 W. 7thAVENUE, SUITE 100 CO1~TSiC' RQATIOI~T CO1~II-TIS5IOrIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 ~ ~ ~~ Re: Prudhoe Bay Field, Prudhoe Ba Oil Pool P Y BU 06 15 Sundry Number: 308-129 ~~~~'~ APR ~ ~ 200 Dear Mr. Reem: 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 iri 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, Daniel T. Seamount, Jr. Chair DATED this~~ day of April, 2008 Encl. ~~~~~a~ ,(~~ STATE OF ALASKA IZ~~/~tVE~ ~~~ ALA OIL AND GAS CONSERVATION COM~SION ' ~ APPLICATION FOR SUNDRY APPROVA APR Q 9 a~\° 20 AAC 25280 w~__~._ .,~~ ~ ,. 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Ext~~iEflOfBQe ®Alter Casing ~ ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 180-032 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20459-00-00 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 06-15 Spacing Exception Required? ^ Yes ®No • 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028311 • 68' • Prudhoe Bay Field / Prudhoe Bay Pool 92. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9540' . 9328' ~ 9467' 9255' 8200' None Ca in L n h Siz MD TVD Burst Colla se Str ctural C n t r 110' 2 11 110' 1 30 52 Surface 2678' 13-3/8" 2678' 2678' 4930 2670 Int rmediate 8622' 9-5/8" 8622' 8413' 6870 4760 Pro i n Liner 1236' 7" 8299' - 9535' 8094' - 9323' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9200' - 9263' 8989' - 9052' 5-1/2", 17# x 4-1/2", 12.6# L-80 / N-80 8223' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 8161' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 11, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby cert' that the foregoing is true and correct to the best of my knowledge. Contact Paul Chan, 564-525a Printed Na a avid Reem Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-5743 Date y $ 0~ Terrie Hubble, 564-4628 Commission. Use Onl Sundry Number; .,, ~~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 7j~~ ~~~ `~©~ ~tcS~ Subsequent Form Required: ~ `1.-` ~ ~~ A roved B : COMMISSIONER THE COMMISSION Date - -- _ -- Form 10-403 Revised 2006 ~ ~ Submit In Duplicate • • by ~'P~P 06-15 Expense Rig Workover Scope of Work: Pull 5-%" completion, mill and retrieve Baker SAB-3 packer, run and cement 7" scab liner, cut and pull 9-s/s" casing, run and cement 9 6/8" casing to surface, run and cement 4-1/2" scab liner ~ inside 7" production liner, run 4-%2" 13Cr-80 tubing with Baker S-3 packer set at 8000' MD. MASP: 2373 psi Well Type: Ivishak Producer \ ~~ Estimated Start Date: April 2008 Production Engineer: Ana Seltenright Intervention Engineer: Paul Chan Pre-rig prep work: S 1 Drift thru 5-%z" tubin for tubin cut. E 2 MIT T to 1500 psi. Power Jet cut 5-%2" L-80 tubing at 8115' MD, in the middle of the first full 'oint above the Baker SAB-3 aaker. Reference tubin tall dated 12/18/80. F 3 Circulate well with kill weight fluid and diesel thru the cut. Perform L&K if needed so pressures are zero across the board. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T ~ IC. W 5 Set a BPV in the tubin hap er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU workover rig. ND tree. NU and test BOPE pipe rams to 3500 psi. Test annular preventer to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Retrieve 5-%2" tubing string down to the packer. 3. Mill and retrieve Baker SAB-3 packer at 8161' MD. 4. Run 6" bit, 7" scraper, and 9-°/8" scraper to 9467' PBTD. 5. Set 7" composite plug at 8350' MD. 6. RIH with 9 $/a" RTTS to 6000' MD and pressure test down to the 7" plug. POOH and LD RTTS. 7. Run and cement 7" L-80 scab liner from 3000' - 8299' MD. Note: The VBRs in the BOPs will NOT ~ be changed over to 7" pipe rams as the barrier to the reservoir will be the 7" composite plus. 8. Run USIT log to determine top of cement in the 9 6/d' casing. 9. Set and test 9 a/s" RBP approximately 100' below estimated TOC. Note: The VBRs in the BOPs will .NOT be changed over to 9-5/e" pipe rams as the barriers to the reservoir will be the 7" composite plug ,and the tested 9- 8 10. Cut and pu - a a ove OC. 11. Run and fully cement 9%" casing to surface. 12. Drillout 9 a/a" shoe track. 13. Retrieve 9-%" RBP. 14. Drillout 7" shoe track and composite plug. 15. Run and fully cement 4--%" 13Cr scab liner from -8200' MD to -9467' PBTD. 16. Run 4-%" 13Cr-80 tubing with Baker S-3 packer set at 8000' MD. .~ • • 17. Displace the IA to packer fluid and set the packer. 18. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 19. Set BPV. ND BOPE. NU and test tree. RDMO. . _ FTAC GEN 2 ,WELLHEAD = FMC 'ACTUATOR= AXELSON KB. ELEV = ~- 68 BF. ELEV = ? KOP = 5200' Max Angle = 28 @ 5800' Datum MD = 9079' Datum TV D = 8800' SS O ~ -15 (C~B. SQZ,)TOP OF MARASEAL IN IA @ 3000' 2275' 5-1/2" CAM BAL-O SSSV NIP, ID = 4.562" 13-3/8" CSG, 72#, L-80, ID = 12.347" 26i Minimum ID = 3.813" @ 8221' 4-1/2" CAMCO LAND NIPPLE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~-1 8178, TOP OF 4-1/2" TBG-PC 8178' ~4-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" ~ 8223' TOP OF 7" LNR 8299' 9-5/8" CSG, 47#, L-80. .0732 bpf, ID = 8.681" 8622' PERFORATION SUMMARY REF LOG: BHCS ON 07/20/80 A NGLE AT TOP PEF;F: 4 @ 9100' Note: Refer to Production DB for historical pert data SIZE SPF INTEF:VAL Opn/Sqz DATE 3-3/8" 4 9100 - 9104 S 09/17/87 3-1/8" 4 9124 - 9144 S 10/05/85 3-1/8" 4 9154 - 9174 S 10/05/85 3-1/8" 4 9184 - 9200 S 07/17/87 3-3/8" 4 9200 - 9204 C 08/20/94 3-3/8" 6 9216 - 9226 S 08/03/91 3-3/8" 4 9226 - 9245 C 08/15/91 3-3/8" 4 9248 - 9263 C 08/15/91 3-3/8" 4 9263 - 9264 S 08/04/91 PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 5-1/2" CAM SLIDING SLV $I 141' I-15-1/2" BOTPBRASSY i 8161' 9-5/8" X 5-1/2" BKR SAB PKF 8178' 5-1/2" X 4-1/2" XO 8200' 4-1/2" BKR CIBP (08/26/06) $221' 4-1/2" CAM D NIP, ID = 3.813" $222' 4-1l2" BKR S/O SUB $223' 4-1/2" TBG TAIL $220' ELMD TT LOGGED 05/27/85, DATE REV BY COMMENTS DATE REV BY COMMENTS 07/31/80 ORIGINAL COMPLETION 03/17/06 JLJ/TLH IBP PULLED (03/10/06) 12/18/80 LAST WORKOV82 08/18/06 COMITLH WAVER SFTY NOTE DELETED 08/16/02 KB/KAK PERF CORRECTIONS 08/26/06 RRD/PAG SET BKR CIBP @ 8200' 12/13/05 KDC/TLH CORRECTION 02/13/06 RRD/PAG SET IBP @ 8156' 03/16/06 COMIPA WAIVERSAFETY NOTE PRUDHOE BAY UNff WELL: 06-15 PEFUuIfT No: 1800320 AFM No: 50-029-20459-00 SEC 2, T10N, R14E, 1384.16' FEL & 3836.36' FNL BP Exploration (Alaska) TREE _ ~ FMC GEN 2 WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 68' BF. ELEV = ? KOP = 5200' Max Angle = 28 @ 5800' Datum MD = 9079' Datum TV D = 8800' SS 065 Proposed ComAetion ^-2100 H4-1/2" HES X NIP, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2678' TOP OF 7" LINER -3000' 7" LNR, 26#, L-80 ~4-1/2" TBG, 12.6#, 13CR 80, .0152 bpf, ID = 3.958" ~ ~TOPOF4-1/2" LNR ~--~ -8200 TOP OF 7" LNR $299' 9-5/8" CSG, 47#, L-80, .0732 bpf, ID = 8.681" $622' 4-1/2" LNR, 12.6#, 13CR-80 PERFORATION SUMMARY REF LOG: BHCS ON 07/20/80 ANGLE AT TOP PERF: 4 @ 9100' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9100 - 9104 S 09!17/87 3-1/8" 4 9124 - 9144 S 10/05/85 3-1/8" 4 9154 - 9174 S 10/05/85 3-1/8" 4 9184 - 9200 S 07/17/87 3-3/8" 4 9200 - 9204 C 08/20/94 3-3/8" 6 9216 - 9226 S 08/03/91 3-3/8" 4 9226 - 9245 C 08/15/91 3-3/8" 4 9248 - 9263 C 08!15/91 3-3l8" 4 9263 - 9264 S 08/04/91 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 2 3 4 J~4-1/2" HES X NIP, ID = 3.813" -8000 7" X 4-1/2" BKR S-3 PKR 4-1/2" HES X NIP, ID = 3.813" 4-1 /2" HES XN NIP, ID = -8100 4-1/2" TBG TAIL DATE REV BY COMMEMS DATE REV BY COMMENTS 07/31/80 ORIGINAL COMPLETION 03/17/06 JLJ/TLH IBP PULLED (03/10/06) 12/18/80 LAST WORKOVER 08/18/06 COMITLH WANERSFTY NOTE DELETED 08/16/02 KB/KAK PERF CORRECTIONS 08/26/06 RRD/PAG SET BKR CIBP @ 8200' 12/13!05 KDClTLH CORRECTION 02/13/06 RRD/PAG SET IBP @ 8156' 03/16/06 COIWPAG WANER SAFETY NOTE PRUDHOE BAY UNIT WELL: 06-15 PERMff No: 1800320 API No: 50-029-20459-00 SEC 2, T10N, R14E, 1384.16' FEL 8 3836.36' FNL BP Exploration (Alaska) From: Chan, Paul (PRA) [Paul.Chan@bp.com] Sent: Thursday, April 10, 2008 9:07 AM ~~ To: Maunder, Thomas E (DOA) ~ Subject: RE: Prudhoe Bay Well 06-15 RWO ~~~ Tam ~~ During the pre-rig prep, the ClBP failed the pressure test. We are now looking at other options to obtain the pressure test. We will be deferring this RWO while we formulate a new plan. Thanks Paul Chan Intervention Engineer Bp Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) From: Chan, Paul (PRA) Sent: Tuesday, April 08, 2008 4:59 PM To: 'Maunder, Thomas E (DOA)' Cc: Reem, David C Subject: Prudhoe Bay Well 06-15 RWO Tom Doyon 16 is currently on well 15-32 to do a tubing swap. Part of the original scope was to do some TCP work, but the TCP will now be done post-rig. No sundry was required on the 15-32 well. The total estimated time for the RWO was 12 days and with the efficiency of the rig and the TCP to be done post-rig, we could be moving the rig to 06-15 by this weekend. I have enclosed the schematics and proposed scope of work for your preview and Terrie is working to get the Sundry App 10-403 to you as soon as possible. Thanks for your assistance. « File: 06-15 Current Wellbore.pdf» « File: 06-15 AOGCC Scope of Work.doc (Compressed) » « File: 06-15 Proposed Completion.pdf (Compressed) » Paul Chan Intervention Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) 4/ 10/2008 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMIt)SION REPORT OF SUNDRY WELL OPERATIONS o D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 68 KB 8. Property Designation: ADL-028311 11. Present Well Condition Summary: Total Depth measured 9540 true vertical 9327.98 Effective Depth measured 9467 true vertical 9255.16 Casing Conductor Surface Production Liner Length 80 2650 8596 1236 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 Perforation depth: Measured depth: 9100 - 9264 True Vertical depth: 8889.08 - 9052.65 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development :~ Stratigraphic D RECEIVED JAN 2 4 2006 Stimulate D AlaaW'ö·[;j Waiver D Time ExtensioJ1:j Cas Cons. (;ommissio 1 Re-enter Suspended Well [JAnchorage 5. Permit to Drill Number: Exploratory I] 180-0320 Service r] 6. API Number: 50-029-20459-00-00 9. Well Name and Number: 06-15 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) 8175 None feet feet MD 29 - 109 28 - 2678 26 - 8622 8299 - 9535 TVD Burst Collapse 29 - 109 1490 470 28 - 2678 5380 2670 26 - 8413.07 6870 4760 8093.79 - 9322.99 8160 7020 Closed Closed 5-1/2" 17# 4-1/2" 12.6# L-80 L-80 24 - 8178 8178 - 8223 5-1/2" Baker SAB Packer 8161 RBDMS 8FL, Jt\N 2 5 2006 n ~\' ~ \C1, 2DÜb SÇANNED ,J f~ b ,~~ (..r ,), - Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 408 x Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 26097 247 0 SHUT-IN 15. Well Class after proposed work: Exploratory C Development R' 16. Well Status after proposed work: Oil R' Gas r' WAG r GINJr Tubing pressure 1882 Service r WINJ r WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Shann~.ne Vestal .' ... . ) _' s,gnatu~%i~~ ~~ Title Data Mgmt Engr Phone 564-4424 Date 1/20/2006 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only ) ') 06-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 12/17/2005 ***WELL FLOWING ON ARRIVAL*** (reg compl) DRIFTED W/ 3.80 CENT & 4 1/2" BLB, BRUSH TBG OUT EOT TO 8300' SLM, CALlPERED TBG FROM 8300' SLM TO SURFACE (GOOD DATA). STANDBY FOR PUMP TRUCK TO FREEZE PROTECT FLOWLINE & LOAD TBG *** JOB IN PROGRESS/ CONT ON 12-18-05 WSR*** 12/17/2005 Continued on 12-18-05 Load glycol from Veco base Load meth. Road to location. 12/18/2005 *** CO NT FROM 12-17-05 WSR *** (reg compl) LRS FREEZE PROTECTED FLOWLINE & LOADED TBG W/ CRUDE, UNABLE TO GET CAMCO DBP PLUG SET, SET WEATHERFORD WRP PLUG @ 8186' SLM - 8200' MD. ATTEMPTED TO MIT-T W/ TRIPLEX, PUMPED APPROX 3 BBLS OF DIESEL & RAN OUT OF FLUID. RDMO NOTE: USE WEATHERFORD OVERSHOT TO EQ & RETRIEVE WRP. *** DSO NOTIFIED, WELL LEFT SI *** PDS CALIPER LOG SHOWS 4.5" TUBING TAIL TO BE IN POOR CONDITION, WITH AN 83% WALL PENETRATION JUST BELOW THE 5.5" BY 4.5" CROSS-OVER. 12/18/2005 Continued from 12-17-05 T/I/O = 2460/180/20 Assist slickline for (REG. COMP.) Pumped 5 bbls meth and 27 bbls glycol and 18 bbls crude to freeze protect flowline. Pumped 2 bbls meth spear and 190 bbs crude to load tubing, slickline didn't get plug to set. 12/20/2005 T/I/O=110/170/0+. Temp=SI. TBG, IA & OA FL. TBG FL @ Surface. IA FL @ 515', OA FL near surface. Note: Cellar has about 20 gallons of clear slushy fluid around the conductor, seems to be more liquid around 8 o'clock position). Collected a sample for the lab. 12/20/2005 T/I/O=500/160/0 MIT T @ 3000 psi ( ) MIT OA @ 3000 psi ( ) (Reg. Comp.) Pumped 200 bbls diesel with no increase in pressure. Cancelled MITxT. Water and ice in cellar called DHD and cancelled MITxOA FWHP,s= 250/175/0 1/2/2006 WF IBP MONTHLY RENTAL FOR 12/22/05 - 12/29/05, MO 1 (partial). NOTE: IBP SET ON 12/18/05. NOTE: as of 01/02/06, step on WBL to pull (TLH) 1/3/2006 *** WELL SHUT IN UPON ARRIVAL***{a/c pressure test,maint} PULLED 4 1/2" WRP @ 8184' SLM. *** WELL LEFT SHUT IN****{pre ibp} 1/5/2006 T/I/O=70/140/0+. Temp=SI. WHP's & T BG FL. (Pre-IBP). TBG FL @ 36' «2 bbl). 1/7/2006 T/I/O= 65/150/4. Temp= SI. Tbg FL (for E-line). Tbg FL unchanged @ 36' (.8 bbls). Tbg pressure decreased 5 psi, lAP decreased 10 psi and OAP increased 4 psi since 01-05-06. Integral flange on the IA. 1/9/2006 SET BAKER 3-3/8" IBP IN MILL OUT EXTENSION OF PACKER @ 8175' MD. MID ELEMENT SET AT 8175' IN MILL OUT EXTENSION. CCL TO MID ELEMENT = 22.6'; CCL STOP DEPTH = 8152.4' TWO 6" SEALING ELEMENTS; ONE 1" STIFFENER RING. 1.75" JDC EXTERNAL FISHING NECK @ 8168' MD. FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL "\ ( STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Suspend D Operation Shutdown 0 Perforate D WaiverD OtherD Alter CasingO Repair WellO Plug PerforationsO Stimulate ŒJ Time ExtensionO Change Approved ProgramO Pull TubingO Perforate New Pool 0 Re-enter Suspended WellO 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 180-0320 Development ŒJ Exploratory 0 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 Service 0 50-029-20459-00-00 7. KB Elevation (ft): 9. Well Name and Number: 68.00 06-15 8. Property Designation: 10. Field/Pool(s): ADL-028311 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9540 feet true vertical 9328.0 feet Plugs (measured) None Effective Depth measured 9467 feet Junk (measured) None true vertical 9255.2 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 29 - 109 29.0 - 109.0 1490 470 Liner 1236 7" 29# L-80 8299 - 9535 8093.8 - 9323.0 8160 7020 Production 8039 9-5/8" 47# L-80 26 - 8065 26.0 - 7863.6 6870 4760 Production 558 9-5/8" 47# S-95 8065 - 8623 7863.6 - 8414.1 8150 5080 Surface 2650 13-3/8" 72# N-80 28 - 2678 28.0 - 2678.0 4930 2670 Perforation depth: ---. Measured depth: 9200 - 9204,9226 - 9236,9236 - 9238,9238 - 9245,9248 - 9250,9250 - 9263 True vertical depth: 8988.82 - 8992.81, 9014.75 - 9024.72,9024.72 - 9026.72, 9026.72 - 9033.7,9036.69 - 9038.69,9038.69 - 9051.65 Tubing (size, grade, and measured depth): 5-1/2" 17# L-80 @ 24 - 8179 RECEIV . 4-1/2" 12.6# N-80 @ 8179 - 8223 ED Packers & SSSV (type & measured depth): 5-1/2" Baker SAB Packer @ 8172 JAN 2 8 2004 12. Stimulation or cement squeeze summary: AI k 0., & G as a J a C 1'" ' , . Intervals treated (measured): S OilS. vOlT/miSSiOn Treatment descriptions including volumes used and final pressure: Anchorage 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2018 71.2 88 250 1230 Subsequent to operation: 1731 66.5 227 489 1167 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown D OilŒJ GasO WAG 0 GINJO WINJO WDSPLO Daily Report of Well Operations. ~ Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correç~ to th~ best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Garry Catron' N/A Printed Name Garry Catron Title Production Technical Assistant Signature Phone 564-4657 Date 1/21/04 ~tÁN~E[) FEa 0 ~ 2004 0 R \ G \, N A L ,," -- ,'Þ;~\ß~ \~) ÆŒl~~} Form 10-404 Revised 12/2003 'E:UI\ I_~.", \1 I~ " i . ( ( 06-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/15/03 Load IA with 38 bbls Flo-pro with 30 ppb LCM and 14 bbls Flo-Pro @ 10.5 ppg displace with 175 bbls inhibited brine and 5 bbls diesel. Bump up treating pressure three times after FLo-pro at perfs. Estimate approximately 15 bbls behind pipe. FLUIDS PUMPED BBLS 5 Diesel 38 45000 LSRV flo pro with 30 ppb LCM @ 10.5 ppg 16 50000 LSRV flo pro @ 10.5 ppg 80 1 % Inhibited KCL 178 10.5 Inhibited brine 317 TOTAL Page 1 . ,. ... ,~ (' ( TREE = FMC Ge.J 2 WB.LHEAD = FMC 06-15 SAFETY NOTES: TOP OF MARASEAL IN IA@3000' ACTUt\ TOR = AXB.SON (CRET GEL SQZ.) *** lAX OA COMM. OPERATING KB. ELEV = 68' PRESSURE OFT HE 13-3/8" ANNULUS MUST NOT BF. ELEV = ? EXCEED 1 000 PSI (06/27/03 WAIVER) *** KOP= 5200' Max AnQe = 28 @ 5800' 5-1/2"CAM BAL-OSSSV NP,ID =4.562" DatumMD= 9079' 8 DatumTVD = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" 5-1/2" CAM SlIIJNG SLV Minimum ID = 3.813" @ 8221' 4-112" CAMCO LAND NIPPLE 8141' 5-1/2" BOT FBRASSY 9-5/8" X 5-112" BKRSAB R<R 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, D = 4.892" H 8178' 1 8178' 5-1/2" x 4-112" XO ITOPOF4-112" lEG-PC H 8178' I -14-1/2" CAM LA NDING NIP, D = 3.813" I I 8222' H 4-1/2" BKR SIO SUB 1 4-112" TBG-PC, 12.6#, N-80, .0152 bpf, D = 3.958" 8223' 8223' 4-1/2" TBG TAIL I 8220' H B.rvD IT LOGGED 05127/851 9-5/8" CSG, 47#, L-80, .0732 bpf, D = 8.681" PERFORA 1l0N SUI'v1MA. RY REF LOG: BHCS ON 07/20180 ANGLEATTOPÆRF: 4@ 9100' Note: Refer toProduetion œ for historieal perf data SIZE SPF INTERVAL OpnlSqz DATE 3-318" 4 9100 - 9104 S 09/17/87 3-118" 4 9124 - 9144 S 1 0/05/85 3-118" 4 9154 - 9174 S 1 0/05/85 3-118" 4 9184 - 9200 S 07/17/87 3-318" 4 9200 - 9204 0 08/20/94 3-318" 6 9216 - 9226 S 08/03/91 3-318" 4 9226 - 9245 0 08/15/91 3-318" 4 9248 - 9263 0 08/15/91 3-318" 4 9263 - 9264 S 08/04/91 7" LNR, 29#, L-80, 0.0371 bpf, D = 6.184" DATE REV BY COtvfv1e.JTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 07/31/80 ORGINAL COI\tPLETION 03122/03 JI\tP/KK SAFETY NOTE CORRECTION WELL: 06-15 1 2/1 8/80 LA ST WORKOV ffi 06/27/03 JCP/1LP WAIVERBJ PERMIT No: 1800320 01/15/01 SIS-QAA CON\!ffiTBJ TO CAN\! AS AA No: 50-029-20459-00 02106/01 S IS- LG REVISION SEC 2, T1 ON, R14E, 1384.16' FB. & 3836.36' FNL 09/13/01 RN'TP CORRECTIONS 08/16/02 KB/KAK PERF CORRECTIONS 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 _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4923' FNL, 1752' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 3885' FNL, 1416' FEL, Sec. 2, T10N, R14E, UM At effective depth At total depth 3836' FNL, 1384' FEL, Sec. 2, T10N, R14E, UM 5. Type of Well: Development __X Explorato~___ Stratigraphic__ Servia.__ (asp's 685235, 5940935) (asp's 685545, 5941982) (asp's 685575, 5942030) 6. Datum elevation (DF or KB feet) RKB 68 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 06-15 9. Permit number / approval number 180-032 10. APl number 50-029-20459 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 110' Surface 2610' Production 8554' Liner 1236' 9540 feet Plugs (measured) 9328 feet Tagged PBTD (7/16/2000) @ 9400' MD. 9400 feet Junk (measured) 9188 feet Size Cemented Measured Depth 20" 300 Sx PF II 110' 13-3/8" 22000 sx Fondu 2678' 9-5/8" 5OO Sx C~ass G 8622' 7" 275 Sx C~ass G 9535' ORIGINAL True vertical Depth 110' 2678' 8413' 9323' Perforation depth: measured 9200' - 9204'; 9226' - 9245'; 9248' - 9263'. true vertical 8989' - 8993'; 9015' - 9034'; 9037' - 9053'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8178' MD; 4-1/2", 12.6#, N-80 PCT @ 8223' MD. ~ackers & SSSV (type & measUred depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8161' MD. 5-1/2" CAMCO BAL-O SSSV @ 2275' MD. RECEIVED JUL Alaska 0i~ & Gas Cons, Commission Anchorage 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 OiI-Bbl ~ ,shutin ~c 3536 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Representative Daily Average Production or Injection Data Gas-Md Water-Bbl Casing Pressure 8416 204 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. Tubing Pressure Title: Disposal / Reg Compliance Engineer 264 Signed Mike Bill Prepared by Paul Rauf 2E$-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE ~.~ 06-15 DESCRIPTION OF WORK COMPLETED ACID WASH / MARASEAL GEL CEMENT SQZ FOR GSO & IA GEL SQZ FOR CRETACEOUS LEAK Date Event Summary 12/26/1999: 3/1312000: 6/09/2000: 6/16/2000: 6/17/2000: 6/19/2000: 6/21/2000 - 6/22/2000: 6/26/2000: 7102/2000: 7/15~2000: 7/16/2000: Ran Borax RST. Detected leaking previously squeezed perfs f/9124'- 9144' MD. Ran Leak Detection Log & diagnosed Cretaceous casing leak (water) @ 5000' MD. MIRU CTU & PT'd equip. Loaded well w/1% KCL Water & Crude. RIH w/CT & tagged PBTD @ 9376' MD, then pumped a gelled sand slurry containing 11600 lbs of 20/40 River Sand to spot an isolation plug across the open perf intervals located @: 9200' - 9204' MD (Zone 2) Reference Log: BHCS 7/20/1980. 9226' - 9245' MD (Zone 2) 9248' - 9263' MD (Zone 2 / HOT) Made a final TOS @ 9151'. POOH w/CT. RD. RIH w/CT & tagged TOS @ 9141' MD. Blasted scale in 2 passes. RIH w/CT & pumped another 350 lb gelled sand slurry. Final TOS tag @ 9151' RIH &tagged TOS @ 9146' MD. Performed a CTU Acid Wash & Maraseal / Cement Squeeze for GSO as follows: MIRU CTU. PT'd equip. Fluid packed well. RIH w/CT &tagged TOS @ 9146'. Reciprocated an acid wash across the leaking sqz'd perfs f/9124' - 9204' MD. Pumped: (a) 2 bbls of Water @ 0.7 bpm, followed by (b) 33.5 bbls of 12% HCL w/12% Xylene @ 1.1 bpm, followed by (c) 15 bbls of Water, followed by (d) 450 bbls of 70° F 1% KCL Water down backside, followed by (e) 67 bbls of Crude displacement Pumped 99 bbls of Maraseal Gel, followed by 50 bbls of 15.6 ppg LARC. Placed all the Gel behind pipe. Attained 1000 psi sqz press when O-ring above BOPE failed. Pipes & slips closed. Contaminated cement w/Biozan & cleaned out to 9100'. Estimated 0.3 bbls of cement behind pipe. POOH w/CT. RD. Left 300 psi on wellhead. Performed a FB Maraseal Gel Squeeze to seal a Cretaceous casing leak @ 5000' MD as follows: MIRU. PT'e equip. Pumped 280 bbls of Maraseal Gel down IA. Placed 190 bbls of Gel behind pipe. Displaced gel w/9.6 ppg Brine & capped w/Diesel. RD. RIH &tagged fill @ 9145' MD. PT'd tbg to 1050 psi - lost 230 psi in 30 minUtes. RIH w/CT & performed FCO to 9164' MD. Hard BTM. RIH & milled cement to 9175'. FCO'd to 9400' MD. N2 lift. Well BOL & put in well test. RECEIVED Page 1 JUL 2. 8 Alaska 0~; & Gas Cons. Commission Anchorage Re: 6-15 Cretaceous leak Subject: Re: 6-15 Cretaceous leak Date: Thu, 16 Mar 2000 08:21:22 -0900 From: Blair Wondzell <blair_wondzell@admin. state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells <P 1041 ~mail.aai.arco.com> CC: Tom Maunder <tom_maunder~admin. state.ak.us> Jerry, Thanks for the information. Since this is a production well, there is nothing further needed at this time. Blair Wondzell PRB Problem Wells wrote: > Blair: ARCO just completed a leak detect log (LDL) on Prudhoe well 6-15. A leak > was found to the cretaceous zone from the IA ~ 5000'. There are no gaslift > valves in this well, and no flow was detected in the tubing. The tubing appears > to be competent. At this time we do not have any repair plans in place. Let me > know if you have any questions. > Jerry Dethlefs > ARCO Problem Wells ,,---.. STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO, ~'llSSION REPORT OF SUNDRY WELL OPERATIONS; 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. Operation shutdown ,,. Stimulate Plugging Perforate X , Pull tubing Alter casing Repair well Other ~. Type of Well 6. Datum of elevation(DF or KB) x 68 RKB 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 323' FSL, 1736' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 1392' FSL, 1416' FEL, Sec. 2, T10N, R14E, UM At effective depth At total depth 1412' FSL, 1366' FEL, Sec. 2, T10N, R14E, UM Development Exploratory Stratigraphic Service 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-15 9. Permit number/approval number 80-32 10. APl number 50 - 029-20459 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 9540 feet true vertical 9327 feet Effective depth: measured 9418 feet true vertical 9206 feet Casing Length Size Conductor 110' 20" Su dace 2610' 13~3/8" Production 8554' 9-5/8" Liner 1236' 7" Plugs(measured) PBTD Tagged @ 9418' MD (8/16/94) OtRJGii AL Junk(measured) Cemented Measured depth True vertical depth 300 sx PF II 110' 110' 2200 sx Fondu 2678' 2678' 500 sx CIG 8622' 8413' R F. ¢ E D Perforation depth: measured 9200-9204'; 9226-9245'; 9248-9263' true vertical 8989-8993'; 9015-9034'; 9037-9052' SEP 23 1994 0il & Gas Cons. Commission Anchor~e Tubing (size, grade, and measured depth) 5~1/2", 17#, L-80, PCT @ 8178' MD; 4-1/2", 12.6~, N-80, PCT @ 8223' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 8161' MD, Camco BaI-O SSSV @ 2275' 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 Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 2570 21207 0 -- Subsequent to operation 2696 ~ 22131 127 -- Tubing Pressure 458 616 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. Form 10-404 Rev 06/15/88 1219114 cc: KZ. JWP Title Engineering Supervisor SUBMIT IN DUPLICATE 6-15 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 8/16/94: RIH & tagged PBTD at 9418' MD. 8/2.0/94: MIRU & PT equipment. Reperforated: RIH w/perforating gun & shot 4' of reperforations as follows: 9200 - 9204' MD (Z2) Ref. Log: BHCS 7/20/80. Used a 3-3/8" carrier & shot 4 spf at 60/120 degree phasing, at underbalanced pressure. POOH w/perf gun. Rigged down. Returned the well to production & obtained a valid welltest. RECEIVED SEP 2 3 1994 Alaska 0il & Gas Cons. Commission Anchor&ye GeoQuest G00 W. international Airport Road Anohorcx:_:je, AK 99G18-1199 ' ATIN: She~e NO. 8923 Company: I I Alaska Oil & Gas Cons Comrn Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/12/94 Field: Prudhoe Bay Well Log Deacdption BL RR Sepia RF Sepia Mylar q F- ~' ~D.S. 1-6 " PROD PRORLE (8-20-94)'.. ' 1 1 ~'6- c,-.$ D.S. 2-13 " PERF RECORD (8-21-94).. ' 1' ' 1' 25'-?~ ' " 1 ~~ D.S. 3-1 PROD PROFI.LE (8' !.9'94) I ..... D.S. 4-4 iPROD PRORLE (8-25-94) ,, , 1 1 ~/'~"'/'~'C D.S. 4-5A PROD PROFI.LE (&-19-94) ... 1 1 ~ ~-'~.3 ~- D.S. 4-29 INJEC PROFILE (8'19-94) , ,, 1 , 1 ~9-?~C D.S. 6-10 PROD PROFILE (8-20-94) 1 1 2c, -~, .~. D.S. 6' 15~ .. PERF RECORD (8-20-94) 1 1 .~¥- 3 ~ D~. 9-26 . LEAK DETECTION (8-23-94) . . 1 1 c/s-2~'"/D.S. 11-24A DUAL BURST TDT-P (S- 19-94) .... 1 I ~.c/_,7o,D.S. 11-33 . DUAL BURST TDT-P (8-25-94) ....... 1 ... 1 ~' - r r"" 1 I~ ~- ~/ D.S. 12-3 PERF REOORD (8-22-94) 1 1 ~ "_ ~ F... I ~l ~7-$~ D.S. 14-15' PERF RECORD (8-20-94) " 1 1 ~1/- ~_..._...~ D.S. 14-20 PROD PROFILE (8-24-94) 1 1 $ :P ~ ~ 1 Ai~<kn Clil /1, Gas Cons: . . 'ED Commission SIGNED: DATE: Please sign and return py of thie trarmmittal to Sherfle at the above address. Thank you. AR~O Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, Anchorage, AK May 24, 1994 Transmittal #: ARCO cased hole Magnetic tape(s) John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 94042 i Well iL°g Datei Tape Type i Run, Contractor Number! (M-D-Y) Footage , . 9600 ~ 6-15 ~02-22-94~ CNT-D ~ 1,9311- Sch ' 8Ol Number of Records: 2 Distribution: Central Files Phillips BPX ~ Exxon ~State of: Alaska.~ Please acknqwledge r~eipt by signing and returning a copy of transmittal. ~a~kaOil 2'~ /:~ :,* ~Chora~' Co~i**io~ ARCO Alaska, Inc. Is a Subsidiary of AtlantJcRIchfleldCompe~/ ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, ~A--~,horage, AK \ Mar 15, 1994 Transmittal #: 94029 ~_ ARkie Finals ~(.~¢ John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510,~ ~ IWell Log Date Tool Type Run, Contractor Number (M-D-Y) Scale l~c~ i 01-02 2-26-94 Prod/Spin/Temp/~,, 1, 5" Schlumber t~ I 01-03 I. 2-19-94 ProdS, BS/Temp~ ~'~ 1, 5" Schlumber ~(~! 01-09~ 3-01-94 Tubing] Cutter {~? 1, 5" Schlumber ~- 01-11 f 2-27-94 Prod Prof/Spin 1, 5" S.chlumber /..-~l 01-18I 2-23-94 Leak Detection 1, l'& 5" Schlumber ?.b"~ 01-25 3-06-94 CNL 1, 5" Schlumber q'4, '=~3-20A 2-17-94 Perf 1, 5" Schlumber ~03-20A 3-03-94 Dual Burst "~;:i~' 1, 5" Schlumber lC)q- 03-32 2-26-94 Leak/Press/Temp 1, 2" Schlurhber ¢~, 03-34A 2-24-94 Prod/PressFl'emp 1, 2"&5" Schlumber q?.. 04-01 2-19-94 Prod 1 ~ 5" Schlumber ~* 04-24 2-22-94 Prod 1, 5" Schlumber ['~t{ 04-40 I 2-22-94 Perf 1, 5" Schlumber ~_ff"4- 04-46i 2-16-94 Rope Perf 1, 5" Schlumber t2~ 1/04-47 2-18-94 v Perf 1, 5" Schlumber ~. 04-47 - 2-15-94 '"' CBT-GR 1, 5" Schlumber i ~,04-47 2-15-94 v CET-GR 1, 5" Schlumber 50 05-06 2-11-94 Perf 1~ 5" Schlumber ~;~. 05-14A 7-11-93 USIT/Cem&Corr (~'~)1, 5" Schlumber cl~ 05-15A 05-15A ~ C~ND/GR-Lw~ ~ 1, 5" Schlumber [~'~ 05-26 3-02-94 Dual Burst 'l'cn (~ 1, 5" Schlumber ~'z. /'06-15 2-21-94 Prod 1, 5" $chlumber \ 06-15 2-22-94 Comp Neutron 1, 5" Schlumber 5~- 06-22A 3-01-94 Perf 1, 5' Schlumber Iio 07-08 3-02-94 Prod~e~ ~ 1, 5" Schlumber IqC~ ! 07-23 3-07-94 Leak/Spin/TemF~i~ 1,5' Schlumber ~ 09-34 2-21-94 Tubing Cutter ~ ' 1, 5' Schlumber 11-02 2-10-94 Inj Pmf/S{~ ~jlre,1, 5" Schlumber 1/'11-04 2-20-94 Tubin~ Cutter t~. 1, 5" $chlumber ~11-04 2-17-94 Tubing ~vt~ H ~v_~l, 5" Schlumber t~ 11-7ST 3-06-94 Inj Prof/Spin ~r.~ I/'~._ 1, 5" Schlumber 11- 2-25-94 Leak/Press/Temp 1, 1"&5" Schlumber ~ 168T /Spin/~c~b ~>---I.~ i~111- 3-08-94 Comp/l~l~table 1, 5" Schlumber 6ST I ZOCO.--- I?.A. lziO C 5" Schlumber ~q 1-17 .2-20-94 Leak 1 ~ 5" 1-17 3-08-94 Prod 1, $chlumber ~t.% 11-23 8-09-91 TMD 1, 5" Halliburton ?.C/4- ~11-24A 3-05-94 Perf/GR/CCL' 1, 5" Schlumber ~! 1-24A 2-22-94 Comp/Perf 1, 5" Schlumber fl ARCO Ala,~,k~ lite. I$ · 8ub~idlary of AtlantlcFIlehfleidCompany ( ( i ! 12-01 i 3-06-94 Schlumber ! "<to D -l CP\OO 13-10 2-24-94 Schlumber ¡ 9ZOb -qt¿,5o ¡ 14-28 1-16-94 Schlumber ¡ ~D?30-lllQfðlo i 14-28 1-16-94 Schlumber I05S0-llloql{ ~ i 14-28 i 1-16-94 Schlumber ! I\Y5"8D--\ \t-'V~\ ;::::- ¡ 14-28 1-16-94 Schlumber ¡ JQS?û--tttoCfL\ \) 14-28 1-19-94 Schlumber ¡ I b1-o0- t l '5€;:i./ ! 14-28 1-23-94 Schlumber \o<6:¡.o-tlSroo :14-28 1-23-94 Schlumber tc<¡s7o-llloo I i 14-24 2-19-94 Schlumber (()-~(d?O €:>1-- \1- ¡ 14-28 3-05-94 Schlumber ¡ ó....q\{ 2...0 B=?- l';'?> 14-34 2-15-94 Schlumber ~'nl~VI\~~ ?ö-ln.'25 6l- tfL 16-08 3-07-94 Schlumber T6Mflp~~ 3(W-'f1oOO q ~- r~s í 17-21 2-24-94 Schlumber 9'?(o~-qq3S 7~- {¡;~ PWDW 2-09-94 Schlumber 02-01 ~l ~ "Ob~'2.-lZ. * Well 4-24 the correct API # is 50-029-21508-00 Number of Records: JJ- tJ/l-~ . .1o'hn E. DeG;;- Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon ',~'§~át~o~~Alask~'\ Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: .+/'f1/~ GA.w Date: RECEIVED MAR 18 19'911 AiJaska,.' ,~, !fjJiJ \& ¡Gas lCQQ$. ~ .' Al1Db~ ~ ARCO ALASKA, INC. F'.O. BOX i00360 ANCHORAGE, ALASKA DATE' i 2-3t-9t REFERENCE' ARCO CASED HOLE FINALS -¢'* t-t ~ . ._ .2- .~~ ~¢"~,.~ ~-~ ~ i 2-22-9i ~ VERTILOG i 2-i 7-9i ~/CNL 8-2-9i '[/ DSN-GR i 2-i 6-9t~ PFC i 2-i 7-9i~y COLLAR-F'ERF t 2-i &-gl "' /,CNL ,, i 2-i S-gl v" COLLRR RUN t , 5' RUN 3, 5' RUN i, _,:~' F:UN t, 5' RUN i, 5" RUN 2, 5' RUN i , 5' APPROVED TR~r,~:,_. :..- c?~ ATO-t 529 ~ CENTRAL FILES ,,- CHEVRON D & M ~ EXTENSION EXPLORATION ~ EXXON ~ARATHON · ~ MOBIL . PHILLIPS F'B WELL FILES R & D BPX STATE OF ~ ALASKA I'EXACO * THE CORRECT AF'I~- FOR i-lB IS 50-~'}29-2t¢~7-,.'91. ** THE CORRECT AF'I~ FOR 2-23ST IS 50-~29-2~795; THERE IS NO SUFFIX. ATLAS SCI.-! HLS ATLAS ATLAS $C1.-! ATLAS RECEIVED JAN 1 0 1992 Alaska Oil & Gas Cons. Commission Anchorage ~ STATE OF ALASKA ALASKA '~ AND GAS CONSERVATION CC~'"~'~ISSION 0 REPORT SUNDRY WELL OPEHATIONS 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 323' FSL, 1736' FEL, Sec. 2, T10 N, R 14 E, UM At top of productive interval 1392' FSL, 1416' FEL, Sec. 2, T10 N, R 14 E, UM At effective depth At total depth 1412' FSL, 1366' FEL, SEC. 2, T10 N, R 14 E, UM 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 68' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 6 -15 9. Permit number/approval number 80 - 32 10. APl number 50 - 029-20459 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9540 feet Plugs(measured) 9327 feet Effective depth: measured 9467 feet true vertical 9255 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 300 sx PF II 110' 110' Surface 2610' 13- 3/8" 2200 sx Fondu 2678' 2678' Production 8554' 9- 5/8" 500 sx CI (3 & 300 sx CS I 8622' 8413' Liner 1236' 7" 275 sx Class G 9553' 9323' Perforation depth: measured 9226 - 9238'; 9238 - 9245'; 9248 - 9263' true vertical 9015 - 9027'; 9027 - 9034'; 9037 - 9052'; Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8178' MD; 4-1/2", 12.64¢, N-80, PCT Tail @ 8223' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 8161' MD; 5-1/2" Camco BaI-O SSSV @ 2275' MD. 13. Stimulation or cement squeeze summary 14,. Intervals treated(measured) See Attached. SEP 1 2 1991 Treatment description including volumes used and final pressure /~l~ka 0il & Gas Cons. C0mt~'tss'tet~ Representative Daily Averaae Production or In!ection Data ~llC, h01'8.g8 OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2035 18023 0 .... 1905 Subsequent to operation 2547 1617 0 .... 226 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 Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 7ztQ 13~.1~ n- .qw .IWP Date ~/'~ ) SUBMIT IN DUPLICATE DS 6-15 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 814/91: An Acid Wash & CTU Cement Squeeze for Gas Shutoff were performed as follows: MIRU CTU & PT equipment to 4500 psi. Loaded wellbore w/309 bbls of 1% KCl Freshwater, then RIH w/CT & acid washed the perforations at: 9200 - 9204' MD (Z2) 9216 - 9236' MD (Z2) 9236 - 9238' MD (Z2) 9248 - 9250' MD (Z2) 9250 - 9264' MD (Z2) Ref. Log: BHCS 7/20/80. Pumped: a) 59 bbls 15% HCI w/10% Xylene, followed by b) 58 bbls 12% HCI - 3% HF, followed by c) 59 bbls 3% NH4Cl Flush, followed by d) 18 bbls Freshwater Flush. Switched to pumping 118 bbls of 1% KCI Freshwater down backside of wellbore, and followed with 10 bbls of freshwater spacer down CT. Proceeded with the CTU squeeze, pumping 47.5 bbls of acid resistive cement, squeezing the perforations (listed above). Placed 4.5 bbls of cement behind pipe at 3500 psi maximum squeeze pressure held for 1 hour. Contaminated cement & jetted out contaminated cement from wellbore. POOH. Rigged down. 8/15/91: Reperforated: 9226 - 9238' MD (Z2) Ref. Log: BHCS 7/20/80. Added perforations: 9238 - 9245' MD (Z2) 9248 - 9263' MD (Z2) Ref. Log: BHCS 7/20/80. Returned well to production & obtained a valid production test. RECEIVED S EP 1 2 1991 Alaska 0ii & Gas Cons. 'Anchorage ARCO ALASKA, INC~ P,.O, BOX i ANCHORAGE, ALASKA 99.5 DATE · 8--S0-.9i " ....... .... AI',~,U CASED HOLE FINALS F,.. I:: 1.. Iii: t:;,' Er N f':: E · ' "' f'" 6.-- i 5: 8--. i 5 .-.. 9 i F.'IE R f:' R E C 0 R D '?-3 8..-t 5-.9i F'ERF' RECORD 7 .... i '." 8- i ''~ ~'" ' ,...-- ,- 1 C C L ( i" !J B I N G C LJ i" TIE R ) '? -- i '? 8 "- 'i '7 ..- 9 tV E F.'. T ]t: L 0 '? .... i'? Ei .... 2i-9i F:'FC 9-'2 8-i 6-9t VER'I'ILOG 9 '--' 4 8 -.. i 8 - 9 i C: 0 L t... A R / P E R F:' 9-.-5 ~--t ,:.-}.--.9i COLLAR/F'ERF (~ .... "') Z "" ..' .. · ..:..o 8--'i ,'-'°i r::OL.I...AR/PE:F~'.F i :5-..i £) ::.~ .... i 4...-9t C:OL.t...AR i 4-4 8-'i i .-.9 t CCL/F:'Et;,'t= i 4 .... i L.'., 8.-.- 2 i -- 9 i F:' E: F.'. F' R E: C 0 R D i '.>-2".Z 8-i S-gl COI_L~aI".:~ 1- E.'_I',~F i 8-i ..'5 8--2i --9i I::'I)K .... t ¢,£.~/GF,'/CC[. i 8- i 6 8--22"-9 i CNL F' t.. E: A,~':' E ,.,'~" I G N A N I.'-' t:;,' E: 1" U R N 'T' !"! E A T l"A C H E I) C 0 P Y HAVE: A NICE DAY! SONYA WAI_..L..ACEi A T 0 .... t ''".),,:. '"' '-W RLIN i , RtJN t, RUN t , RLJN i , RLJN i , RLJN t, RLIN t, RI. JN i , RLIN I , RUN t , RUN i , RUN t, RUN i, RUN i, RLJN t, RUN t, AS,' RE:CEIPT OF I) ATA, i:-'. I~ 5:" D" 5,:" 5" 5" 5" 5" .,.. 5," 5:" 5:" 5:" 5" 5:" ,S' C I..t '<J C i-'t A 'f'l...A S A"t"I.. A $ A"FL.A$ AT!_A$ A'f'I...AS A"I'I_A5' A I't...A,S' 6: C I--! A'T'L.A$ A'I"LA$ ;E.:C H ¢.'~ t" I_ A,S.' Al' L.A:';' S C I-! I) I 5'TR I BUT ]: ON :~ (SEENTF<AL F I LES :',':CHEVRON D & M ~ EXTEEN$ION E. XF. L. LJRATI ON :~ IF'XXON ~4AR~THON · ,- P H I L. L. I F' ,:~ F'D WE:El... FILE:S: i:;.: & D :,",: BF'X ::";'TATiE OF. AI_A,S'K A 'T' E: X A C 0 ARCO AL. AS~KA, INC~ P~O~ BC1X ~00S60 · A N C'. H 0 R A(.'; [':. ~ AL.A~K A DAI"E' ':" ' , AF;,'CO CAS'ED HOLE FINALS' i -' ~'.'. ()4 - 4 - 9 i T E H P E R A 'T' LI R E ,."~ .... i6 a. .... i.."~ ...... 9t LEAK DETECTION · .S .... i7 4--i .3-.9i ,...EAK i),i.:.'i'EC"FION /q, 4 .... ',C:, 4 .... 6-9i !NJEC:TION - ~ -'5 - 2 (9 4 - 2 2 - 9 i C B i- 6 .... i 5 4 -. 8 ---. 9 i F' !.? 0 D U C. T I 0 N 6- ",20 4 .... 6- 9 i F' R 0 D IJ C i" I 0 N 9 - 4 4 .... i S -.- 9 i t... !ii: A K D Ii..'. l" E C T I (.1. N '.? ..-. 9 4 .... 5-9 i !... E A K D tii:"l" Iii: C 'i" I 0 N ~ 0 - Io-1 ;~>-..- 4 :'.,.-: 4 .... 2 i ..... ~:, ,ii::: o L I... A I-:..' /I::' E l-:: F Ol I -- O H '~':'- ';~ ~i~ .,'~ .... 4 .-.. 9 ic; A H H A /,:: C L../J [~: W Iii: L ~:.: Y i i .... t 4 .... 2- 9 i 1... !ii,'.":', K D I!.-'. T Ii" C: T I f.'J N i t .... S 4 .... 2- 9 i L. !ii: A K i) E l" E C'. l I 0 N ti-4 4 .... S""9i PITY/INJECTION i 2- 2 S ,i- "-' 6 -' 9 i I N J Ii.:. C. l' ]: 0 i'-./. i 2'--' 25 4 .... i 4- 9 i I N J E C l" I 0 N ':,(' i 4- 2 S 3 - :5 - 'I;' i P !:;.: t'j D U C T I 0 N t 4-'55 4-'S-9 i C:OLI..AF;: i ","'-i 4--¥-9 i PF;..'ODLJC T I (:IN F:' L. E A 5' ri: c, RI..J N t , R UN t , RUN t, F;:U Ni , I:;..' U N i , RUN t, RUN t, I;,'UNi , RUN t , RUN i , RLJN i , RtJN i, RUN i , RUN. i , RUN ~ , RLJN ~ , RUN ~, N AND I:;:ET'UF('N THE AI"TACHED COPY AS' RECEIPT OF:' I)ATA -,-~::" C A ft C (:.1 .5" .... '-I .... L;¢~I'i .,(.J t" CAMCO ..,.'"~" I.':AM C 0 ..,- 5" C A M C 0 5" CAMCC~ 5" '. C A M C 0 "~" &5" CAHCO ~.'.. 5" ATI_AZ -; L, A f'~ L, 0 5" CAMCO 5" It; A M C 0 , 5" C A M C 0 .,"~:" C A I'i C 0 5" C A M C 0 5" C A ~'i C 0 5" CAdCO ...':':" C A Fi C 0 5" CAMC 0 I--lAVE A NIC:F DAY! i) I .~ T R I B U T I 0 N A F:' P R 0 V E I~ :,": C:IF.: N'¥ I.~' A ! F I L E $ '"' .... · ,~ F' i--I I L L I F' $ ,Jh · ,- CI"IEVROiq PB WEI...L F'ZLES' D & M R & D :,",:E X T E N,.':'.; I 0 N EL X I::' I... 0 R A T I 0 N :.": B F:' X .,. EXXOh! ~ ~l"f~.~l'l:Z OF' ALA,.~;KA i'iARA THON I'E:XACO '"' MOBIL_ x' i" i"11 S' 12 A D LJ F:' L I C: A T E 0 F T i"1E L 0 G Y 0 LJ A L. F;.'. E A D Y R E C E I V E" I), E. X C E: F:"I" T I"1E A I::' I ~: o, % .... ! 'I .... : ' ' ' '"1 . :[~ [.,LJl'~l~,l:t.,1E'..~J, F'L.[.'.EA,S'IE 'I-HROW Ti-lEE F*F;,'EVIOLI;~ COPY WITH THE WRON6 APl:II: AWAY, · \ ARCO ALASKA, INC. F'~O. BOX i8e360 ~NCHORAGE, ALASKA 995t 8 DATE' 9-t5-98 REFERENCE'. ARCO CASED HOLE FINALS i -i A o_' ,., '~ 6-9~3 F'ERF' Rr-'CORD RUN 4--4 7-ii-98 F'IERF RECORD RUN · 4-~ 6, 7--2~-9~ GAMMA CORR~ W/ F'ERF RECORD I:~'.UN - " 5:: '~' RUN 4 i¢ 8--~ 98 F'ERF ~.EUORD 5~-i i 8-i 8-9(-) F'ZT~' RUN ,~-i~ '::. ~¢ - "'~- 9 e,~ PERF F,~';' ¢ C q F D ;~ < RUN Z--3 7-3 i -9,S, PIERF RUN 7-9 7-:~i -ge PERF RECORD RUN 7-i S 8-i 9-9¢ F'ITS RUN ~--~,~-w ~a PERF ~'FCO~'D RUN 9-4i 8-i 5-98 GR/COLLAR RUN ii-4 8-8-98 F'RODUCT :[ ON PROFILE RUN i i -28 8-i 8-9~ COLLAR RUN i'~- i i 7-25-9~ PERF RECORD K"IU N i S--7 8-i 5-9(3 PITS RUN i ~5-7 8-i 7-9G PITS RUN i5-i2 8-i6-9~ PRE-FRAC I'EMP RUN i 4-S 8-2~-9~ COLLAR RUN i6 ~ 8-i7-98 PRODUCTION FR]FILE RUN i 6-28 8-i 8-98 F'IqODUCTZON F'ROF~LE . RUN i6--22 7-6-9~-J GAMMA COLLAR/PERF RECORD RUN PI_EASE SIGN AND RETURN 1-HE ATTACHED COPY AS RECEIPT OF DATA. I;,'!ECEZYED BY )~~____~ RECEIVED SAi_LY i"tOI::'FECK ER ATO'-i 529 SEP 1 9 1990 Alaslm Oil & Gas Cons. Commission Anchorage AF'F'ROVED ~ I'RANS~ 9q~56i DISTRIBUTION CENTRAL FILE£ CHEVRON D & M EXTEN,S'I ON EXPLORATION EXXON MARATHON MOBIL PHILLIPS PB WELL. FILES R & D BPX STATE OF ALASKA TEXACO HLS HL_S HL::...~ CAMC'O .:"'i L :F H L ,S' HI_S CAHCO HL.S CAMCO CAMCO CAMCO HLS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCt] HLS THE: CORRECTED AF'I~ FOR i-i(9 IS 58-829-28169. ~5 1A I I:: Ut' ALA~51~A ALASK~"'~IL AND GAS CONSERVATION ~MISSION REPOR'i SUNDRY WELL O!--RATIONS 1. Operations performed: Operation shutdown ....-- ._.. Plugging ~ Perforate X Pull tubing , 2. Name of Operator ARCO AlaSka, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Alter casing ~ Repair well 5. Type of Well I:)~veloprnent X~ Exploratory Stratigraphic 4. Location of well at surface 323' FSL, 1736' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 1392' FSL, 1416' FEL, Sec. 2, T10N, R14E, UM At effective depth At total depth 1412' FSL, 1366' FEL, Sec. 2, T10N, R14E, UM 01rg./.,l~ltt~__ ! ['1 ! 11 n 6. Bat u ~n o{~ el~{lat~n~ I:1 o~l;81r/ 68' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 6-15 9. Permit number/approval number 8o- 2 10. APl number 50 - 029,20459 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9540 feet Plugs(measured) 9327 feet Effective depth: measured 9467 feet true vertical 9255 feet Junk(measured) Casing Length Size Cemented Conductor 110' 20" 300 sx PF II Sudace 2678' 13-3/8" 2200 sx Fondu Production 8622' 9-5/8" 500 sx Cl 'G' Liner 1236' 7" 275 sx Cl 'G' Measured depth True vertical depth 110' 110' 2678' 2677.8' 8622' 8412.9' 8299'-9553.5' 8093.7'-9322.9' Perforation depth: measured 9200'-9204'; 9216'-9238'; 9248'-9264' true vertical 8989'-8993'; 9005'-9027'; 9037'-9053' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8223' MD; 4-1/2", 12.6#, N-80 Packers and SSSV (type and measured depth) Baker SAB Packer @ 8161' MD, Camco I~1-O SSSV @ 2275' 13. Stimulation or cement squeeze summary -,'. Intervalstreated(measured) See Attached. ~.~ Treatment description including volumes used and final pressure -~":';'"' 14. Reoresentative Daily Avera3e Production or Injection ...... _~,;~,~. ,. · OiI-Bbl Gas-Md Water-Bbl Casing PressBre - Tubigg Pressure Prior to well operation 2167 12149 0 -- 885 Subsequent to operation 2404 11940 0 -- 867 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 Senior Area Engineer Date Form 10-404 Rev 06/15/88 For M.M.Maguire SUBMIT IN DUPLICATE DS 06-15 ADD PERF PROCEDURE REPORT OF WELL OPERATIONS PROCEDURE WORK PERFORMED 7/22/90 1. RIG UP E/L AND TEST LUBRICATOR. 2. RIH WITH PERFORATING GUNS AND TIE IN TO REFERENCE LOGS. , PERFORATE INTERVAL 9,200 - 9,204' MD (BHCS 7/20/80) TO ATTAIN 4 SPF. POOH. 4. R'D AND RELEASE F_/L. 5. RETURN WELL TO PRODUCTION. STATE OF ALASKA ALASI~"'L AND GAS CONSERVATION F"~'~ISSION APPLICA,1ON FOR SUNDRY A,--eROVALS 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 323' FSL, 1736' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 1392' FSL, 1416' FEL, Sec. 2 ,T10N, R14E, UM At effective depth At total depth 1412' FSL, 1366' FEL, Sec. 2, T10N, R14E, UM Operation shutdown ~ Plugging Pull tubing Variance 5. Type of Well Development X Exploratory .i Stratigraphic Service Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) 68' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 6'15 9. Permit number 80-32 10. APl number 50 - 029-20459 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9540 feet 9327 feet Plugs(measured) Effective depth: measured 9467 feet true vertical 9255 feet Casing Length Size Conductor 110' 20" Su dace 2678' 13-3/8" Production 8622' 9-5/8" Liner 1236' 7" Perforation depth: Junk(measured) Cemented measured 9216'-9238'; 9248'-9264' true vertical 9005',9027'; 9037'-9053' 300 SX PF Il 2200 sx Fondu 500 sx CI 'G' ~ 275 sx CI 'G' ~ Measured depth 110' 2678' 8622' 8299-95535' Tubing (size, grade, and measured depth) 51/2" 17# L-80, PCT @ 8223' MD; 4-1/2", 12.64f, N-80 True vertical depth 110' 2677.8' 8412.9' 8093.7-9322.9' Packers and SSSV (type and measured depth) Baker SAB Packer @ 8161' MD, Camco BAL-O SSSV @ 2275' 13. Attachments Description summary of proposal X Detailed operations program __. BOP sketch X 14. Estimated date for commencing operation 7/90 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tit,e 15. Status of well classification as: Gas Suspended Senior Area Engineer FOR COMMI~RION U~I= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location Clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 06/15/88 M.M. Maguire SUBMIT IN TRIPLICATE DS 06-15 Perforation Proposal ARCO Alaska proposes to perforate within the Sadlerochit formation of the Prudhoe Bay Unit in well 06-15. The proposed intervals are shown below. Reft BHCS 07-20-80 Interval, 'MD 9200- 9204 Interval. 'TVD 8989 - 8993 Interval. 'SS 8921 -8925 Zone SPF Comment 2 4 or 6 Reperf This work will be done with formation fluids in the wellbore. All wireline work will be done through a 5000 psi working pressure BOP/lubricator, tested to 1.2 times the maximum expected surface pressure. 5 4 2 COILED TUBINg UN]T BOP EOU ] PME N~ 1. 5000 PSI 7" WELLHEAD O:)NNECTOR IrLANO£ 2. 5000 PSI 4 1/16" PIPE RA~S ~. 5000 PSI 4 1/6" HYD~LtC SLIPS 4. 5000 PSI 4 1/6" ~I£AR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUIrFINO BOX 2 HIREL]NE .... BOP EO,,U]PMENT 1. 5000 PSI 7" WELLHEAD GONNECIOR rLANO£ 2. 5000 PSI WIR£LIN£ RAI~S (VARIABLE SIZE) .3.5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW 1UB£ PACK-OFF F:' ,. 0., B 0 X i (.) (.) :i!; 6 (') A N C I"10 F;,' A (;. iii;., A L. A ,? I< A 9 ? 5 i (') R IFL I::' Iii; F;; E N C: F · A R C 0 C A ,~i; E D I.-I 0 L E F:' :il N A I... ;};' F:' I:;.'. 0,).'.:' LJ C':'t" I 0 N i::' I:;..' 0 i':'I I... Ii!i. ' F:' F;,' 0 D U C 'f' I 0 N F:' 1.;.'. CI F:' I I... iii)' (;-R / "f' Ii.. N F:' F:' F;-.' 0 D U C "1' I 0 ~':~ P R 0 t::' I I... E. P F;.'. 0 D U C: T I 0 N F-' R 0 I= I I... E P F;..' 0 ii;.':, U C: 't" ill 0 iq P F;.: 0 F:' ! L. li'] P l;;..' 0.0 U C: 'i" I 0 N F:' R 0 F:' I I... E F' R 0 il) U C: T' ill 0 iq F:' R 0 F' ill L. E F:' F;.: 0 D U C 't" .1; (i) N P t:;.: il)I:: ill i... E · '1~ "! ...... F:' R 0 D i.J C't" ill 0 N I.. 1-,.. U I-. I t... Iii'. i::' f... Iii: A ,!';; E ~i: ]: ('.;. i'.! A i"-! D R E "F U R N "F H Iii: A 'T' T A C H Iii: D C 0 F:' Y A,.":/ R l!i: C iii: I P 'i' 0 F;' i) A 'T' F:,' E C E :1: V Iii: D B Y ...... ~ HAVIii: A N :i:CIE DA'f! {l ~ ~I C~ ~ ~ D 3'A I''' I''' Y I''1 0 F:' F:' ["' C: K E 1:;,' A'F 0 .... i !5 2 9 A i::' F:' R 0 V F D ..~_ D I ;;..: 'T' R I B LJ T I 0 N "" C E N "f' IR A I... F: ....... i I...1:. ~" "" C I"1 I:;: V R 0 N '11° . . L b & M · ,,.'"' Iii: X 't" [E N 310 N E X P !... 0 R A "F I i'l... N · ~ Iii X v 0 N °Il· /*.. . HARAI'HON '"' N 0 B i1: !_ 'Ir · ,,. F:' 1"t I I.. I...M::' 3' F:'B I,,j Iii; I... I... F' II...I...,..,':;' ~'' R & D .It, · ,,. BI';'X .1:,. · ,,- E; [' A TIE 0 F: ra t_ A 3 t< A :~I: i" Ii/: X A C 0 C; F:'~ M [.; 0 C A H i..; 0 C A H C: 0 C r::; i',': C 0 C A M C: 0 C t::'~ i"i C: 0 ARCO Alaska. Inc. Post Office Bcx 100350 Anchorage. Alaska 99510 Telephone 907 276 1215 February 5, 1990 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas COnservation Commission 3001 Porcupine Drive Anchoragel AK 99501 SUBJECT: DS 2-27, 5-25, 5-26, 5-27, 6.(9-16), L1-15, L1-27, & L1-30 As-Builts Dear Mr. Chatterton: Enclosed are copies of the subject AS-builts for your information. If you have any questions, please call me at 263-4618. Si.i.i.i.~ .c;e. re ly,., /? 'q Danielle Warner Engineering Aide DW RECEI EO ~0 FEB - 6 Q~ Ala.×a Oil & Gas Cons. 'Anchorage ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Con'cany AR3B-6OO1-A ARCO Alasl<a. Inc. is a ¢ o: ~ubsidiar¥ AtlanticRichfieldCompany To F. ROBERT BELL AND ASSocIATES EnGineering and Land Sur~eyir~g 33.35 Arctic Blvd. S,Jite 201 ANCHORAGE, ALASI'O~. 99503 Phone: 561-5257 From: Job # Mo. Day Year SIGNED [] Please reply F'"] No reply necessary O~ ?~0 O~ ~.~0 O& ~00 O~ ~90 06 ~8o 0 '~ ~-~0 0· I CELL 2 NOTES I. ] BASIS OF HOR I ~AL CONTROL I$ ~4:~4ENTS 6-C at~ COORD I ~ ~ ~ at~ ALASKA ~~4. ~-~ILT ~ ~ I0111~. 4./ ~LS ~-~ILT AT ~ ~ 5. ) REFER~ FELD g~ ~ 89HI, Pgs. 42-54. DATE ~ ~~ ~ I-2~ 1~9 A.S.P. COORDFNA TES 5,940,584.44 685 , 31~ . ~0 5,g40,701.40 685,2g0. 5,.q40,814. ?..3 5,941,051.84 GEODETIC POSITION LA TITUOE 70' 14 '30. I~/" 70' !4'31.32~' 148'30' I0. 70' i4'32. 47~' 148'30' I0. 70' i4 '33. ~' 148'~0' I 1. 4.qO' 70°i4'34.78~' 70 ' ! 4 ' 35 . ~41 ' ~*14'~.~' ' 13. SL~ VEY OR S CER TIF'ICA TE i ~BY C~.RTIrY THAT I Att ~Y I~GI, S TERE~ AND ~ ~ ~~ ~ ~ STA~ ~,. ~ BY ~ ~ ~ ~~T ~~ ~ ~ T ~L ~ OT~ ~T~S A~ C~CT S 1289.8~ / E S 1169.77 I £ 3~.31 S 1049.95 I E 3~5.3~ S 92~3.73 / E 329,04 · ®eeeeeeee~ L OCA TK)N IN ~1' F'M. I 1629' FE~ ~C I 115' FM. / 1654' FEZ. ~EC I I~O' F'~L I 47~' ,r~ I · EXISTIN6 ~ A. SSUILT THIS 0 EXISTINO IIEI.L ROBERT BELL & A$$OCIATE$ I NQflTH ~.~I~E DISTRICT - ~ i WELLHEAD AS-BUlL TS I 'DRILL SITE 6- WELLS 9-16 1 ~ !NSDP !0000 IcEA-3?O0-OIO [~v, ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 12, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 6-15 Approval No. 7-199 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 D~S/DMF/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 6-15)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C ~"'"'~, STATE OF ALASKA .:~ ALAS~-,, ')IL AND GAS CONSERVATION COMb, .... SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate J~ Pull tubing [] Alter Casing [] Other g] 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 68' RKB Feet 3. Address P.O. Box 100360~ Anchorage~ AK 99510 4. Location of well at surface 323' FSL, 1736' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 1392' FSL, 1416' FEL, Sec. 2, T10N, R14E, UM At effective depth At total depth 1412' FSIi, 1366' FEL, Sec. 2, T10N, R14E, UM 6. Unit or Property name Pruithoe Bay Unit 7. Well number 6-15 8. Approval number 7-199 9. APl number 50-- 029-20459 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 9540 feet Plugs (measured) 9327 feet Effective depth: measured 9467 feet Junk (measured) true vertical 9255 feet Casing Length Size Cemented Structural Conductor 110' 20" 300 Sx PF II Surface 2678' 13-3/8" 2200 Sx Fondu Intermediate Production 8622 9-5/8" 500 Sx C1 'G' Liner 1236 7" 275 Sx C1 'G' Perforation depth: measured 9216-9238' 9248-9264' true vertical Measured depth 110' 2678' 8622' 8299-9535' ~ueVerticaldepth 110' 2677.9' 8412.9' 8093.7-9322. Tu9005,-9027 ' ,. 903.7-9053' . Ding ts~ze, gra-ae ana measurea depth) 5½", 17f~, L-80, PCT @ 8223' MD, 4½", 12.6If, N-80 Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 3300 31680 0 Casing Pressure 1600 1072 0 ~bing Pressure 2700 400 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 ,J/2¢'~. j~ ~_¢/'- b='*'~ Form 10-404 Rev. 12-1-85 Title Operations Engineering Manager Date Submit in D~plicate Drill Site 6-15 CTU Cement Squeeze Gas Shutoff 7-3-87 7-12-87 7-16-87 7-18-87 8-5-87 Shoot squeeze perforations: (Reference BHCS 7-20-80) 9100-9104 MD 6 spf 9250-9264 MD 6 spf MIRU CTU. Acid wash interval 9184' to 9264' MD with: 20 bbl Xylene 40 bbl 15% HC1 with additives 20 bbl 6% HCl-1/5% HF with additives Flowed well 4 days. Pumped 39 bbls cement with additives through coiled tubing. Cement squeezed perforations: 9184'- 9204' MD. Ref. BHCS 7-20-80. 9216' - 9236' MD. 9250' - 9264' MD. Obtained a squeeze pressure of 1400 psi and held for 1 hour. Contaminated cement in wellbore and shut down overnight. Jetted out contaminated cement. Rigged down CTU. Left well shut-in. Perforated: (Reference BHCS 7-20-80) 9216-9238 MD 6 spf 9248-9264 MD 6 spf Tested well. Determined further perforating or stimulation not required at this time. ARCO ALaska, Inc. P.O. Box t00~60 Anchorage~ Alaska DATE: Augus$ t2, t987 REFERENCE: ARCO Cam'ed Hole Final t..-~A 5/V--~/87 Pu~p in Temp~ Log 6-t .5 8-5-87 CCL/F'erf~ Record '~ S~-~ 8-8.--87 CCL/F'erf. Record Please ~ign and refurn fhe affached copy a.s receipf of dafa. HAVE A NICE DAY~ · , ~ ~chorage T R ~ N 5 ~ 8 7 4 t ~ ARCO ALaska, Inc P.O. Box Anchorage,' ALaska DATE: August 6, lcd8? REFERENC£: ARCO Cased Hote Fi~at 5-.'5 6--8-8'7 Col tar & F'erf, 5-5 7-4-8'7 Col tar & F'er f. 6-t5 7-3-8'7 Cottar & Perf.. 6-t9 7-3-87 Cot tar & Perf. Run t , Run t, Run t, Run t, 5" 5' 5' Gear Gear TRAN$ ~874G7 Approved DISTRIBUTION of data. Central Fi lez F'hi LI ip~ Chevron F'B WeLL Fi Les D & H R & D Extension Exploration ~ Sohio E.X XOY~ State of ALaska. Marathon ~ Texaco Hob i [ ARCO Alaska, Inc f:'.O. Box t0'0360 Anchorage, Alaska 99510 DATE' June t~), t98'7 REFERENCE: ARCO Ca.s'ed Hole Final 4-9 5--t 8-87 GR/Tef.~p Survey 5-~ 3 5-t 3--8'7 CH CNL 6--t5 5-28-87 [;El' 7-t5 5--~5-87 CH CNL t ~-.1 5 5-.t 6-87 CH CNL t3-98 5-38-87 CH CNL-Epi~her~,~a t3-98 5-3~-87 CH CNL-Ther~,~a[ f3-98 5-38-87 CH DIL/~FL t 4-? 5-t5-.87 CH CNL Run t, Run t , Run 2, Run i , Run t , Run 28 Run 28 Run 28 Run t , 5' 5' 5' 5' 5" ** The F~R/Tef, p tog For' D$$ 4-9 i~ a corrected copy, the first tog sen~ on transfait~al. ¢87285 da~ed 6-4-87 was prin~ed as DS~ 9-4, Ca hl~ o Dre~s $ch Dr e.~.~; Dress $ch $ch $ch Dress F'iease sign and return the attached COpy as receip$ of data. Received By HAVE A NICE DAY! Rosanne Peek ATO-t 529 fRANS ~8730t Approved ........ I) 15 TR I IBUT 'i ON Centrat Fi [es Chevron I) & M Extension Exp [orat ion Ex yon Marathon Mob i t Phi trips F'B Well Fi les R & D Sob i o ~tate of Ataska Texaco ARCO Alaska, Inc. Prudhoe Bay' .,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 25, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 6-15 Permit No. 80-32 Dear Mr. Chatterton: Attached is the Application for Sundry Approvals detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/AEC/jp At tachment cc: Standard Alaska Production Company Pi(DS 6-15)W1-3 RECEIVED MAR 2 7' ! 387 Oil & Gas Cons~ Commissio~ Anch:,r" ...... ?, WELL S / 6 3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /'"'~ STATE OF ALASKA ALAS~,.. ,.)IL AND GAS CONSERVATION COMk_ .~,..qlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O, Box 100960. Anchorage, AK 99510 4. Location of well at surface 323' FSL, 1736' FEL, Sec. 2, T10N, R14E, UM At top of productive interval 1392' FSL, 1416' FEL, Sec. 2, T10N, R14E, UM At effective depth At total depth 1412' FSL, 1366' FEL, Sec. 2, T10N, R14E, UM 5. Datum elevation (DF or KB) 68' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 6-15 8. Permit number 71-5 9. APl number 50-- 029-20459 10. Pool Prudhoe Bay Oil Pool feet 11. Present well condition summary Total depth: measured true vertical 9540 feet Plugs (measured) 9327 feet Effective depth: measured 9467 feet Junk (measured) true vertical 9255 feet Casing Length Size Cemented Structural Conductor 110' 20" 300 Sx PF II Surface 2678' 13-3/8" 2200 Sx Fondu Intermediate Production 8622 9-5/8" 500 Sx C1 'G' Liner 1236 7" 275 Sx C1 'G' Perforation depth: measured Measured depth 110' 2678' 8622' 8299-9535' True Vertical depth 110' 2677.9' 8412.9' 8093.7-9322 9184-9204'; 9216-9236 true vertical RECEIVED 973-899 '' 9 5- 02 ' Tu~ing (s,ze, g3ra~e )a0nOd m~aOsuri~d depth) 5½" 17#, L-80 PCT @ 8223' MD, 4~" 12 6# N-80 , , 2 , · , :.i~ska Oil & 6:~ Co~m. Com;n:smor! Packers and SSSV (type and measured depth) R~¢~ .qAR P~¢~ ~ R~ 'wn e.~o~ B~I-O SSSV @ 227~' Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation June 1987 14. If proposal was verbally approved Name of approver Subsequent Woflr Reported on F°rm No./O' f/'OCDated '7//_~../~ Date approved 15. I hereby/~ertify thlilt the foregoing is true and correct to the best of my knowledge Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP ~T~st .,,[~ Location clearance I Date Approved by No. Commissioner the commission Form 10-403 Rev 12-1-85WELLS/63 A. E. Copoulos, ATO-1510, 263-4209 S'ubmit in triplicate ARCO Alaska, Inc. intends to squeeze existing perforations on DS 6-15 using a coiled tubing unit (CTU). After the squeeze, the well will be cleaned and perforated. These operations will be performed in the following manner: · Shoot squeeze perforations 9250-9254' MD and 9110-9114' MD. Ref: BHCS 8121178. 2. Clean out well and load with formation water and diesel. · Pump in cement and squeeze the following perforation intervals: 9110-9114' MD 9184-9204' MD 9216-9236' MD 9250-9254' MD Ref: BHCS 8/21/78 4. Contaminate the cement. 5. Wait 12 hrs and reverse out the contaminated cement from the wellbore. 6. Perforate the following intervals: 9194-9204' MD 9216-9236' MD 9236-9238' MD 9248-9254' MD Ref: BHCS */21/78 7. Test the well. RECE]VED NIAR 2 7 !987 CO,,, Oil & Gas ' .s Commissio~'~ Ao,,h~,r::r o AEC2/697 ,r i ii iii ii~~ i i i i i ii 3 I! 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1~6'* LUBRICATOR 4. 5000 PSI 4 1/6'" FLOW TUBE PACK-OFF H I REL I NE BOP EQU I PM£NT 6 5 4 3 2 ! 1 I 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 COI LED TUBI NI2 UN I T BOP EQUIPMENT ARCO'Alaska, Inc. P.O. Box 100360 Anchorage, ALaska 995"i e DATE' JuLy 29,t9 86 REFERENCE' ARCO 2-i 0 7-i 4-86 4-3 7-5-86 4-24 4-5-86 ~4-30 7-t l/t 2-86 4-3t 7-t0/I t -86 '~6-4 ~-i 5-86 6-9 6-t6-86 ~:6-t 5 7-t6-86 9-°~.., 6-7-86 t t-7 7-t 6-86 i 3-29 7-'i 4-86 ~i5-3 7-7-86 1'"','-~-'"4 7-t 3-86 Ca_ced HoLe FinmL F'o_c~c $.tueeze ~.emp CCL Run I 5" F"roducfion F'rofi le Run ACBLog/VDL/?ign/GR Run t 5" ~pinner Log Run ~ ~" F'roduc~ion Profi Le Run ~ 5" Epi log/LAC Run 2 Epi Log/LAC Run 2 Sp inner Temp Run F'DK't ~e Run Temp Log Run t 5" FLuid Den~i+y Tempe . ~urvey Run t 5 F'roduc¢ion F'rofi Le Run ~ 5" F'~mpin Temp Survey Run t 5' C8 il'lC o C a mc o Dre_cs Ca mc o Ca mc 0 Dres_c Dress C8 mc 0 Ca mc o Camco C8 mc o Ca m~o Please sign and refurn The attached Copy a_c receip$ of da¢.a, Received By_ HAVE A NICE DAY! Linda Hulce AT0-i529 TR AN.'7 ~:86467 DISTRiBUTiON · .-" F'hillip~ F'B Well F'i Les P + r:, '"' ~oh i o ~'---$tate of Alaska -,.- , _ X.:B C 0 ~Jaska Oil & Gms Cons. Co .mmi~ A~¢borage ,~H CO AlasKa, InC. POSt Office Box 360 Anchorage, At/'-'"~ 99510 Telephone 907 ,., 7 5637 December 11, 1985 Reference: ARCO Cased Hole Finals DS 6-1 11-22-85 Spinner/Temperature Run i 5" Camco DS 6-15 11-22-85 Spinner/Temperature Run 1 5" Camco Please sign and return the attached copF as receipt of data. Kel!F McFarland ATO-1429F Trans # 511 DISTRIBUTION Chevron Phillips D&M Prudhoe BaF Files Bxploration Services R & D Extension Exploration Exxon Marathon Mobil Sohio s~,a Oil a Gas Con:;. Commissior~ ARCO Alaska, Inc. ~ Post Office £ 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Dante: November 7, 1985 Reference: ARCO CH Finals ~-2 --CET/ 5-26-85 Run 1 5" Sch ~-15 CEt 5-26-85 1 5" Sch ~-6 -~Perf 7-4-85 1 5" Sch L~-6/CET 5-23-85 1 5" Sch w~-7 ~ CET 5-23-85 ' 1 5" Sch 3 16~Collar/Perf 7-7-85 2 5" Sch 19?Perf record 7-5-85 1 5" Sch ~-13~Perf~record 7-3-85 1 5" Sch .. ~-/6-1 ~' CET 5- 22-85 V~-9- CET 5-10-85 v~-15 ~CET 5-27-85 /11-1 i~CET 7-16-85 ~']:4-5/CET 7-29-85 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 406 Ch err on ' Phi 11 i p s . D & M PB Well Files Expl. Services R & D Ex:. Exploration. Sohio * Exxon. State of Alaska Mara Chon Tsxa co · Mobil . ARCO Alaska, Inc. ,/'~,~ Post Office BoX .c}360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 30, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 2-4 Permit No. 70-17 6-1 75-49 6-15 80-32 9-27 85-28 11-12 84-195 11-15 84-205 Enclosed are the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/dp Attachments CC: SOHIO Alaska Petroleum Co. File Pi(DS 2-4)Wl-3 PI(DS 6-1)Wl-3 Pi(DS 6-15)Wl-3 Pi(DS 9-27)Wl-3 PI(DS 11-12)Wl-3 P1 (DS 11-15) Wl-3 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfleldCompany RECEIVED k,o¥ 0 6 Alaska Oil & Gas Cons. Commission Anchorage : ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 323' FSL, 1736' FEL, T10N, R14E, UM 7. Permit No. 80-32 8. APl Number 50-- 029-20459 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 6-15 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 68' RKB I ADL 28311 12. Check Appropriate B°x To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 10-7-85. RU perforating unit and pressure tested equipment. RIH w/gun #1 to shoot 9216-9236' MD (6SPF). SI well, POOH, all shots fired. RIH w/gun #2 to shoot 9184-9204' MD (6SPF). SI well, POOH, all shots fired. Secured well, RD. Ref: BHCS 7-20-85 RECEIVED Atas~,a 0ii & (;as Of,~ns. 60mm%ssi0~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /}~.~1~::~'/~~;~ Tit~erations Engineering Mgr. The space below for Commission use Conditions of Approval, if any: Date Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10403 Rev. 7-1.80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 3, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 6-15 Permit No. 80-32 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS:JEB:dp Attachment cc: 'SOHIO Alaska Petroleum Co. File PI(DS 6-15)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED ..,~ . 0~t & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0 Box 100360, Anchorage, Alaska 99510 4. Location of Well 323' FSL, 1736',v T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 68' RKB 12. 7. Permit No. 80-32 8. APl Number 50-029-20459 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 6-15 11. Field and Pool Prudhoe Bay Field 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool ADL 28311 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate XX[~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other XX[~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe PropOSed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. intends to 'squeeze existing perforations on DS 6-15 using a coiled tubing unit (CTU). After the squeeze the well will be cleaned and reperforated. These operations will be performed in the following manner' . e Cleanout well and load with formation water and diesel. Pump in cement and squeeze the following perforation intervals: 9124-9144'MD 9154-9174'MD 9184-9204'MD Contaminate the cement. Wait 12 hours and reverse out the contaminated cement from the wellbore. Reperforate the following intervals' 9216-9236'MD 9184-9204'MD 6. Test the well. Ref: BHCS 7-20-80 R E C E IV E D OCT 0 Alas~,a (;~i 6, GaS Cons. Commissiol 14. I hereby c,e, rtify that the foregoing is true and correct to the best of my knowledge. Signed ..... Title Regional Operations Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by_ ~i~,pproved Coi~Y Returne~ O ' "tr' By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate Rev. 7-1-80 ARCO Alaska, Inc. Prudhoe Bay E/~'~ eering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer August 12, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 6-1 DS 6-6 DS 6-9 DS 6-10 DS 6-11 DS 6-12 DS 6-14 Ds 6-15 DS 6-20 DS 6-23 Permit~No. 75-49 Permit No. 76-20 Permit No. 79-73 Permit No. 79-75 Permit No. 79-110 Permit No. 80-29 Permit No. 80-31 Permit No. 80-32 Permit No. 82-124 Permit No. 82-133 Attached are the "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:JEB:pr Attachments cc: SOHIO Alaska Petroleum Co. File P1 (DS 6-1) Wl-3 File Pl (DS 6-6) W1-3 File P1 (DS 6-9) W1-3 File P1 (DS 6-10) W1-3 File P1 (DS 6-11) Wl-3 File P1 (DS 6-12) Wl-3 File P1 (DS 6-14) Wl-3 File P1 (DS 6-15) Wl-3 File P1 (DS 6-20) Wl-3 File P1 (DS 6-23) Wl-3 RECEIVED Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc, Is a Sub.ldlary of AtlanllcRIchfleldCompany / " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL F-I COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 323' FSL, 1736' FEL, Sec. 2, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 68' RKB I 6. Lease Designation and Serial No. ADL 28311 7. Permit No. 80-32 8. APl Number 50-- 029-20459 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12. DS 6-15 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or COmpleted Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate well 6-15 at selected intervals within the Sadlerochit Sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested at 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up opera- tions. Proposed Perforation Intervals: ~'9216' - 9236' MD (20') Ref: . BHCS 07/20/80 AUG I. 0i~ & Gas Cons, comm'~ss'ton 14. I hereby~rtify that t~. for~egoin~q is true and correct to the best of my knowledge. S,gned ~ / Title Regional Operations Engineer The space below for Commission use Date Conditions of Approval, if any: Approved by IRIGIliAL SIGIIED 81' LONttl£ C, SMITH COMMISSIONER Approved Copy /turg~ By Order of the Commission .., Date ~~__/_~ZhJ~ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO ALas'k~, Inc, P,.O. Box ~0~S60 A n c h o r ~',, ,.'..'; e, A L a ~ k ~ 99.5 i / D ,. ;.g ,. i .... i A'// ! (!:,-Si -84 / D,.:ii:~ I-4 i~) .... 22--84 !::' F:' C) ;i{; u. '~" v e y i< e L i. y H c F:' a ',," I. a r,d ATC) .... i4-:29F AlasKa Oii& Gas Oons. Commission Anchorage ";." F;: A i".i ,!i;., :ii: 41 '/' C a r;'J C: C, L...:':':: ill (] C) C a ,,'r,, c .,.':.', ):) ]: ,:'if T i::,:' ]; i.; U "f' ! C)i'..i F'i Amchorage. Alaska 99510 ," ,: Telephone 907~7 5637 May 21, 1982 Reference: ARCO MAGNETIC TAPES & LISTINGS D.S.13-18 5/5/82 D.S.2-20 4/19/82 D.S.2,21 5/5/82 512182 Tape fJ ECC1296 .Tape # ECC1278 Tape ~ ECC1297~ Tape # ECC1294 P~~lease sign and return .the attachedCopy as receipt of data. Mary F. Kellis North Engineering Transmittal # 182 DISTRIBUTION NORTH GEOLOGY .EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON CHEVRON ?·STATE:;:' 0F,~ALASKA Oil & G;,.s Cons. Comrrtiscion Post Office Box 360 · Anchorage, A,J.~ka 99510 Telephone 9~ 77 5637 May 21, 1982 Reference: ARCO CASED HOLE FINAL LOGS D.S.13-18 D. S ..14-30 D.S.2-21 D.S.7-2 5/2/82 CNL Run 2 5" 5/5/82 CNL Run 1 5" 5/5/82 ACBL/VDL/GR Run 1 5" 5/5/82 CNL Run 1 5" 5/2/82 CNL Run 2 5" ~Please sign and return the attached copy as receipt of 'data. Mary F. Kellis North'Engineering Transmittal # 179 DISTRIBUTION R&D ~S ~~0~ D&M GEOLOGY At~..~ka 0il & Gas C0ns._C~0mmt..o, ........... ARCO Oil and Gas Company North Ala$~?strict Post Office x 360 Anchorage, Alaska 99510 i' Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer April 15, 1981 Reference: ARCO PRESSURE DATA D.S.6-9 1-14/15-81 D.S.'6~1---0 11 / 16 /~80 D.S.6-10 11/18/80 B.S.6-15 2/27/81 D.S.7-13 2-11/12-81 Pressure !! Survey 1 ...... ."-"" ;.: r.x-., oL'-~- ~:"5-' I STAT CON:FF-,R: ...... FILF.. .......... / leas e sign-and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal tf191 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON~'': GETTY Alaska Oil& Gas Cons PHI LL I PS 4nChorag~ CommiSsion SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division of AllanticRichf~eldCompany ARCO Alaska, Post Offic. ., 360 Anchorage, Alaska 99510 Telephone 907 277 5B37 PAL-0099 SAMPLE TRANSMITTAL SHIPPED TO: State of Alaska Ak. Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Ak. 99501 Attn: Mr. Wm. VanAllen DATE' March 17,1981 OPERATOR: ARCO SAMPLE TYPE' (core chips../' SAMPLES SENT: Dr-ii'i-'sites: 15-10 11-14 2-14 17-1 15 -21 15-22 (T-i) NAME: see below NUMBER OF BOXES: 67 SEE ATTACHED LJST FOR INTERVALS v UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAlL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 360 ANHCHORAGE, ALASKA 99510 ATTN: R. L. BROOKS RECEIVED DATE' ARCO Ai~,,,;ka. Inc. is a Subsidia~,¢ of Atlant~cqichfieldCompan¥ ARCO Oil and Gas Company North Alasif~-'~istrict Post Office ,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer March 16, 1981 Reference: ARCO PRESSURE DATA D.S.6-15 1/9-11/81 Pressure Survey ~Plelse sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #127 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA _. GETTY /llasl(a Oil & ~as Cons. PHI LL ~ PS ~Chorage CommiSsio~ SOHIO MARATHON CHEVRON ARCO Oil and Gas Company ~s a Division o! Atl'anticRichfieldCompany ARCO Oil and Gas Company North A~"-~ District Post Off, Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer March 13, 1981 Reference: ARCO Cased Hole Finals D.S.13-12 2/27/81 Casing Collar Log D.S.13-12 2/23/81 CBL/VDL · ~ 2/27'/81 EPL Run 3 Run 1 Run 1 2"/5" (same log) 1! 11 ~~ea~e sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #121 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AllanlicRichlieldCompany Alnska Oil & Gos Cons. Commission Anchorage Feb 6, 1981 North Alaska Districl Post OtlicE~'~X 360 Anchorage~ .... laska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Reference: ARCO CASED HOLE FINALS D.S.3-10 2/10/80 D.S.3-10 2/10/80 D.S.3-13 1/11/81 D.S.6-1 1/14/81 D.S.6-9 1/14/81 D.S.6-9 1/16/81 D.S.6-13 1/16/81 D.S.6-14 1/4/81 <~-~ 1/lo/81 D.S.7-12 1/i1/8] D.S.9-18 1/19/81 D.S.13-3 1/15/81 D.S.14-7 1/12/81 D.S.16-16 1/-2/81 D.S.16-16 1/21/81 D.S.16-16 1/13/81 Spectralog CNL/Gamma Ray Collar Log DDNLL Spinner Log DDNLL Sp~nner Log Spinner Log Spinner DDNLL DDNLL DDNLL DDNLL Collar Log/Gyro Corr. CNL/Gamma Ray ACB/VDL z ~lease~ sign and return the attaChed copy as receipt of data. Mary Kellis North Engineering Transmittal #53 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA Run 2 Run 2 Pass#'2 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON 1! 5t' 5t' 5t~ 5~' 5~t 5~t 5~t 2" & 5" (on same log) ,,m /')/'~ -,, -.~ '" ." ~- z . -,' '. .?' --//.'"~'"'1 .,.,' ,-"". .... ' ........ ., .,F_,.<..~...., RECEIVED FEB 1 0 ]981 Alaska Oil & ~as Cons. Commission Anchorage · ARCO OII and Gas Company is a Division of Allan,icRichheldCompany AI~CO Oil and Ga/"-%mpany North Slope ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 2, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservati on Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- DS 2-9 DS 3-13 DS 6'1 5 DS 1 5-21 DS 16-11 Kuparuk B-2 C-2 C-3 Dear Sir- EnClosed please find- 1 ) The 2) The C-3 subsequent Sundry Notices for DS 2-9, DS 3-13 and DS 6-15. Completion RePorts for DS 15-21, Ds 16-11, B-2, C-2 and Please note that the Completion Reports for DS 14-10, DS 15-10, DS 16-1, DS 16-16 and B-1 will follow shortly. Sincerely yours, / ~p. ^. YanDusen D~strict Drillin~ Fn~ineer PAV' sp Enclosures RECEIVED FEB - 1981 Alaska 0il & Gas Cons. Commission Anchorage ARco Oil and Gas Company is a Division of AtlanUcRichfieldCe STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION CL~,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, ;[nc. RECEIVED 3. Address P.0. Box 360, Anchorage, Alaska 99510F£B-:~ ]981 4. Location of Well Alaska 0il & Gas Cons. Commission 323' FSL, 1736' FEL, Sec 2, T10N, R14E, l~ch0rage 5. Elevation in feet (indicate KB, DF, etc.) 68' RKB 6. Lease Designation and Serial No. ADL 28311 12. 7, Permit No. 80-32 8. APl Number s0- 029-20459 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 6-15 11. Field and Pool Prudhoe Bay Field Prudhoe 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing SUBSEQUENT. REPORT OF' (Submit in Duplicate) Altering Casing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] Abandonment Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). DS 6-15: Objective- repair leak in 5½" tubing. Repair operations commenced @ 0100 hrs, 12/14/80. Displaced diesel in 5½" tbg & 9-5/8" annulus w/9.6 ppg NaC1. Pulled 5½" tubing, PBR & K-anchor. RIH w/new PBR & K-anchor. Tested annulus to 3000 psi - ok. Ran 5½" tubing and tested 5½" x 9-5/8" annulus to 3000 psi - ok. ND BOPE. NU tree. Displaced well to diesel. Tested 5½" tbg to 3500 psi - ok. Secured well, began long term tbg tst and released rig @ 0600 hrs, 12/22/80. Began perf operations on 1/8/81. NU & tstd BOP to 5000 psi for 30 min - ok. Tstd lubricator & perfd 9184'-9204' w/4 SPF @ 120o orientation. Flowed well to clean up. Initial FLP 250 psi. SIP 1275 psi. Flow rate approx 3000 BPD on 32/64 'choke.' Released press on 9-5/8" x 5½" ann. Tstd lubricator on all perfs. Flowed well 5 min before & after all perfs. Perfd 9154'-9174' & 9124'-9144' w/4 SPF @ 1209 orientation. Ran CCL/HP/Spinner.~Perfd 9184'-9204', 91~.4'-9174' & 9124'-914,4' w/4 SPF. RIH w/SSSV, set @ 2207' & tstd to 3000 psi - ok. Installed tree & tstd to 5000 psi - ok. Secured well & released to Production Department @ 0600 hrs, 1/13/81. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Report.s" in Duplicate it"~ I""'~ ~..,, ~,,,J L/il dltLJ North Alaska District Post Otl:""'"'%Box 360 Anchoragu,-Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 27, 1981 Reference: ARCO Cased Hole Finals D.S.t-17 1/9/81 ,' D.S.3-8 t/8/81 D.S.3-13 1/17'/81 D.S.6-11 1/18/81 D.S.14-5 8/22/80 D.S.15-10 1/11/81 D.S.15-10 1/11/81 D.S.16-1 1/12/81 D.S.16-1 1/12/81 DDNLL Run 1 5" DDNLL Run 2 5" Collar log Run 1 5" Spinner Run 1 5" Spinner Run 1 5" Collar log Run 1 5'~ DDNLL Run 1 5" Collar log/Gyro correlation Collar log/Gyro correlation CNL/Multi-Spaced Run 1 5" Collar log/Gyro correlation ~Please sign and return the attached copy as receipt of data. 11 BI1 2"/5" (same log) Mary Kellis North Engineering Transmittal #17 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is, a Div,s~on of AtlanhcR~chl eldCompan¥ EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON ~., ; . CHEVRON? ,_..~../ .,..--.~ .,],~... ,.::>_ _.,.,... . ARCO Oil and Gas Company North Alat/~istrict Post Office-dox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer December 23, 1980 Reference: ARCO Cased Hole Finals D.S. 6-15 11/22/80 Diff temp log Run 1 2" & 5" (same 1 ~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #928 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON .0SZL i;~.E r E I V ED PHILLIPS DEC2 9 1980 - '"~~ SOH I 0 Alaska 0il & Gas Cons. Commission MARATHON Anchorage CHEVRON 'ARCO Oil and Gas Company is a Division o! AtlanticRichfieldCompany ARCO Oil and Gas Company North AI~ District Post Offk _~ox 360 Anchorage; Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer December 23, 1980 Reference: ARCO Cased Hole Finals D.S. 2-2 10/30/80 D.S. 2-9 11/12/80 D.S. 2-14 11/10/80 D.S. 6:10 12/15/80 /D.S. 6-15 11/22/80 D.S. 14-4 8/23/80 D.S. 14-8 4/22/80 'D.S. 17-4 11/12/80 D.S. 17-4 11/12/80 D.S,, Z7-4 11/12/80 collar log Run 1 5" collar log Run 1 5" caliper log Run 1 5" continuous flow survey Run 1 5" audio tracer survey 11 continuous flow survey Run 1 5'J .. continuous flow survey Run 1 5" audio tracer survey Run 1 5" diff temp log/audio survey/static run Run 1 2" ase sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #927 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON Alaska 0Il & Gas Cons. C0mmlssi0. Anchorage ARCO Oil and'Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and G~ '~any North Slo~. ,.4.0ict Post Office BOx 360 Aqchorage, Alaska 99510 Telephone 907 277 5637 December 16, 1 980 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject- DS 17-5 DS 6-9 DS 17-6 DS 6-10 DS 16-10 DS 6-11 DS 2-17 DS 6-12 DS 11-14 DS 6-13 DS 15-21 DS 6-14 DS 15-.10 DS 6-16 DS 14-10 Ku pa ru k DS 16-11 C-1 DS 2-9 B-1 DS 2-2 C-2 DS 6-15 E-5 Dear Sir' ..... ! !~'l '1 ENG i · I o 1' STAT TEC'-- STAT TEC-' ...... CONFER: FILF= Enclosed please find: 1. A Completion Report, Drilling History and a Gyroscopic multishot survey for wells DS 17-5, DS 17-6, DS 16-10, DS 2-17, DS 11-14 & C-1. (An updated Completion Report w/Gyro will be submitted for DS 2-17 & DS 11-14 and the gyro for DS 17-5, as soon as data becomes available.) 2. A Sundry Notice-or subsequent report for wells DS 2-2, E-5, DS 6-9 thru DS 6-14 &' DS 6-16. (An updated sub- sequent Sundry Notice will be filed for DS 6-9 thru DS 6-14, DS 6-16 and E-5 as soon as production test data becomes available. ) 3. A MonthlY Report of drilling for wells DS 15-21, DS 15- 10, DS 14-10,-DS 16-11, DS 2-9, DS 6-15, B-1 & C-2. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:sp Enclosures DEC1 8 13 ?0 Alaska Oil &AnchorageSa~ Oon~. C°mrais~io~ ARCO Oil and Gas Company is a Division o! AllanticRichlieldCompany Form No. 10404 REV. 3-1-70 STAT: O'F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-029-20459 6. LEASE DESIGNATION AND SERIAL NO, ADL 28311 7. IF INDIAN'ALOTTEE OR TRIBE NAME WELL WELL OTItER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360, Ancho. rage, AK 99510 DS 6-15 (33-2-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/Prudhoe Oil Pool 4. LOCATION OF WELL 323' FSL, 1736' FEL, Sec 2, TION, R14E, UM 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 2, TION, R14E, UM 12. PERMIT NO. 80-32 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Began perf operations 11/24/80. Tst tubing & annulus, found leak in 5½" tubing @ 100 psi/hr. RIH w/noise temp log to determine leak. Data inconclusive. Sus- ,, pended perf operations 11/24/80. S,GNED· - - · ~.~/_~___ .~,~Z~,~ ~ - T,TLE District Dril 1 ing En~q. DATE ~)~~~_ NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. ARCO Oil and Gas/' ~any North Slope Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 25, 1980 Mr. Hoyl e Hamil ton State of Alaska Alsaka Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 6-15 (32-2-10-14) Permit No. 80-32 Dear Sir: Enclosed is our Sundry Notice detailing the Work to be done on the above mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:sp Enclosure _~j ~ c,~~ o Gr:O i'1ST..~ T~C__i ~!.__S?A5 TEC ] CONFER: . RECEIVED NOV 2 5 ]980 Alaska Oil & Gas Cons. Commission Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 REV. 1-10~73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA 0IL 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--" for such proposals.) NAME OF OPERATOR Atlantic Richf5eld Company ADDRESS OF OPERATOR P.O. ~Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 323' FSL, 1736' FEL, Sec 2, TION, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 68' RKB Z4. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20459 6. L. EASE DESIGNATION AND SERIAL NO. ADL 28311 7. IF INDIAN, ALI_O'i'TEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay Unit 9. WELL NO. DS 6-15 (33-2-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TION, R14E, UM 12. PERMIT NO. 80-32 3ort, or Other Data FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) NOTICE OF INTENTION TO: ~ /~, SUBSEQUENT REPORT OF= . WATER SHUT-OFF L~ REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent crates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to repair a leak in the 5½" tubing. The well has not been perforated yet and perforating will be delayed until the leak is repaired. The tubing will be pulled above the packer, the packer tested, then new plastic coated tubing will be run. A 13-5/8" 5000 psi RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week and operationally tested each trip. Necessary provisions for subsurface safety equipment will be rerun. A non-freezing fluid will be left in all uncemented annul i within the permafrost interval. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. Well will be flowed to production facilities during testing. The downhole safety valve will be installed and tested upon conclusion of the job. Estimated start date' 11/30/80 RECEIVED ~ubsequent Wm'k Reportecl on Forra No. ~ Dated 16. I hereby cer fy at the for go g Is tr and correct SIGNED · TIT~EDistriCt Drilling Eng. (This space for State offi~) ~ ~ ~ A~~~~~J~L[ COM~$~Q~,, See Instructions On Reverse Side NOV 2 5 1980 Almska 011 & Oas Oons. Commission Anchorage DATE DATE Approved Copy i,Returned ARCO Oil and Ga.,,~"-'~.pany North Slope ~ ,rict Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 November 5, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commi ssion 3001 Procupine Drive Anchorage, AK 99501 Sugject: D.S. 6-9 (23-12-10-14) Permit No. 79-73 D.S. 6-10 (33-12-10-14) Permit No. 79-75 D.S. 6-11 (43-11-10-14) Permit No. 79-110 D.S. 6-12 (13-11-10-14) Permit No. 80-29 D.S. 6-13 (11-12-10-14) Permit No. 80-30 D.S. 6-14 (21-11-10-14) Permit No. 80-31 ~ .qT~. -2-10-14) Permit No. 80-32 D.S. 6-16 (13-2-10-14) Permit No 80-33 Dear Sir- Enclosed are our Sundry Notices detailing the work to be done on the above mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'sp Enclosures ARCO OII and ,Gas Company is a Division of AllanticRIchfieldCompany Form ! 0-40 REV. 1-10~73 / Subml t "I ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL 2. NAME OF OPERATOR Atlantic Richfield Company ~ ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 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.) 4. LOCATION OF WELL At surface 323'FSL, 1736'FEL, SeC 2, T10N, R14E, UM 13. ELEVATIONS (Show ~vhether DF, RT., GR, etc.) 68' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL. CODE 50-029-20459 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 6-15 (33-2-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudh0e 0il P001 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, T10N, R14E, UM 12. PERMIT NO. 80-32 ~ort, or Other Data NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (om,r) Perfora to PULL OR ALTER CASING L.iU MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF F'~ REPAI RING WELL FRACTURE TREATMENTF~ ALTERING CASING SHOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompietion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS: (Clearly state all pertinent ~letell$, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to-perforate selected intervals within the Sadlerochit for production. The perforated intervals will be reported on a subsequent report. A 5000 PSI WP BOP/lubricator, tested to working pressure, will be used on all wireline work. The downhole safety valve will be installed and tested upon conclusion of the job. The well will be flowed to the Flow Station for clean up. Estimated start 12/14/80 RECEIVED NOV 7 198D 16. I hereby certify that the foregoing is true and correct SIGNED . ' APPROVED BY CONDITIONS OF APP'~VAL, IF AN~.' TITLE District Drilling Eng. , DATE, 11/5/80 COMMISSIO~'~E-~- //- 7-2o TITLE .... DATE See Instructions On Reverse Side Returned Atlantic Rich[ield Company NORTH SLOP£ DISTRICT .~ T P~A2-',: S:'.I ITTAL Mr. Hoyle Hamilton State of Alaska Oil & Gas,Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date: 9/30/80 Tramsmitted herewith are the following: .. ARCo D. S. 6-15: From: R. W. Core Summary. Cores 1-.14 8726.0'-9448,0' 0ct '8 Date: -.P, eturn receipt to.~/Atlantic Richfield Company // North Slope District . Attn: District Geologist P.O. Box 360 Anchorage, Alaska 99510' Processe~b lyy :, q.. g _'. lVr~.-~_.~o.r ..: ~. ARCO Oil and Gas"'~'"-~any-- North Slope _ l=,,dct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 30, 1980 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Commission 3001 PorcuPine Drive Anchorage, Alaska 99501 -'"~j STA.T TI::-C 1 L~i!.F: .... Re: Core Summary- ARCo D. S. 6-15 Dear Mr. Hamilton: Enclosed please find the Core Summary for ARCo D. S. 6-15, cores 1-14, 8726.0'-9448.0', submitted as Item # 36 on Form P-7 for the above well. ~Please sign and return one copy of the enclosed transmittal. Very truly yours, District Explorationist RWC'JBM Enclosure ARCO Oil and Gas Company is a Division of AllanticRichfieldCompany ARCo Drill~Si~te 6-15 CORE SUMMARY Core # 9 ll 12 13 14 Depths 8726.0'-8761.0' 8828.0'-8887.0' 8887.0'-8920.4' 8920.4'-8980.0' 8980.0'-9039,0' 9039.0'-9089.0' 9089.0'-9104.6' 9104.6'-9123.4' 9123.4'-9182.6' 9182.6'-9241.9' 9241.9'-9295.3' 9295.3'-9354.0' 9354.0'-9413.0' 9413.0'-9448.0' '' Eec'overy , 8.5' 24% 59.0' 100% 33.4' 100% 59.6' 100% 59.0' 100% 43.0' 86% 9.5' 63% 17.4' 93% 56.6' 96% 60.8' 103% 51.7' 97% 58.7' 100% 59.0' 100% 35.0' 100% Litholo$¥ Shale/Siltstone Sandstn/Limestn Sandstn/Siltstn Sandstone Sandstone Sandstn/Conglom Conglom/Sandstn Conglomerate Sandstone Sandstn/Siltstn Sandstn/Siltstn Sandstn/Claystn Sandstone/Shale Shale/Sandstone OOT- 8 Anoi~u~a~j~ ARCO Oil and Gas~ompany North A I a .~-" )istrict Post Office mox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 2, 1980 Reference: ARCO Cased Hole Finala D.S. NGI-7 7/31/80 Spectralog Run~l 5" D.S. 12-2 5/4/80 Carbon/Oxygen Run 1 5" D.S. 11-4 7/26/80 COmpensated Neutron Run 1 5" ~~5~ 8/2/80 Collar Log Run 1 2" & 5" D.S. 6-15 7/25/80 Sonan Run 1 5" D.S. 6-15 8/2/80 Compensated Neutron Run 1 5" D.S. 6-15 7/25/80 Diff Temp Run 1 5" se sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TRANSMITTAL #65~ DISTRIBUTION North Geology R & D Drilling Eng. Manager D & M Geology State of Alaska ARCO Oil and Gas Company ts a Division of Ati,lnhcR,chf~eldCompany Exxon Mobil Getty Phillips Sohio Marathon Chevron ARCO Oil and Ga~.,~.~q,mPany North AI~ 'strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 29, 1980 Reference: ARCO Magnetic Tapes D.S. 6-15 9/2/80 Tape #CN-7850-9480 ease s~gn and return the attached copy as receipt of data. co i ~,~ RES ENO 1_3 I STAT I ~ONFE~= FILF~ ., , , Mary F. Kellis North Engineering TRANSMITTAL#630 DISTRIBUTION North Geology R&D Drilling Eng. Manager D&M Geology :State ~of :Alaska ARCO Oil and Gas Company is a [Division of AtlanhcRichtieldCompany RECEIVED Exxon Mobil/"/_ ,.-~"~ OCT.~~~ ..v AI~,II~ 0il & Gas {,~.s. ~u..'mssmr~ P h i 11 i ps Jj~triji Sohio Marathon Chevron ARCO Oil and'~' "~G,a'"'~°mpany AI~s~ ~? Pos~ ~" ~ ~,,~c:...,,ox 3,30 ,"\nchorcge. Alaska 99,510 %elephone ~}0.7 277 5637 September 3, 1980 Reference: ARCO Directional Surveys D, - 6 . 8/5/80 Gyroscopic (corrected) and return the attached copy as receipt of data. _ ....... K. J. Sahlstrom North Engineering TRANSMITTAL #576 DISTRIBL~ION North Geology Emxon R & D Mobil Drilling Getty Eng. Manager. Phillips D & M Sohio Geology ~.iarathon State of Alaska ~evTon ARCO O,I and Gas Company ,-i a Divis{on of AtlanhcR;chfieldC :,mpany ARCO Oil and Ga/,.Lg, ompany POSl Of~icr. ,,ox S~0 Ancbora~ A~aska 90510 Telephone g07 277 5~37 September 3, 1980 Reference' ARCO Cased Hole Logs D.S. 4-15 6/21/80 CNL Run 4 5" " " 6/26/80 " Run 3 5" D.S. 4-15 7/10/80 " Run 6 5" ~ 7/20/80. CNL Run 1 g~'please sign and return the attached copY as receipt of data. ~' STAT TEC ---LSm m CONFER: K. J. Sahlstrom North Engineering TRANSMITTAL # 577 DISTRIBL~ION North Geology R&D Drilling Eng. Manager Geology State o£ Alaska ~xxon Mob i 1 Getty Phillips Sohio Marathon ~1~0~ ARCO C,;I and Gas Company ~s a Di,lis,on ot All,.Jntic~i~chi'JeidConlpany ARCO Oil and G~".,-~:)mpany Post Office alex 330 Anchorage. Alaska 995~0 Telephone 907 277 5637 September 3, 1980 Reference: ARCO Directional Surveys 8/18/80 Single,Shot 7/31/80 " " D.S. 17-2 8/2/80 Single Shot ~lease sign and return the attached copy.'as receipt of data. ;, , ! I ,¢;rAT TEC ! K. J. Sahlstrom North Engineering TRANSMITTAL #575 DISTRIBUFION North Geology Er~xon R 6 D Mobil Drilling Getty Eng. Manager Phillips D ~ M Sohio Geology Marathon State o£ Alaska Chevron ARCO O;I and Oas Comp,Jny ~$ a Oivis,on ol Atlant*cgichfi:!d~.ompany ARCO Oil and Ga..s,-~mpany ' Al~s~ ~'-: Posl Olfice ~ox xn~,,or,,~ ........... 99510 Te~ephonu 907 277 58S7 September 3, 1980 Reference: ARCO Magnetic Tapes D.S. 2-15 7/2/80 Tape #60645 D.S 7/10/80 Tape #60655 7 /.20/80 Tape #60667 7/31/80 Tape #60717 : /~lease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #581 DISTRIBL~ION North Geology E~xon :R & D ~'Iobil Drilling Getty Eng. Manager Phillips D & ~ Sohio Geology ~Iarathon State o£ Alaska dtevron ARCO Oil and Gas Company ~s ~ Division of Allantic~,ichheiclCompany ARCO Oil and Ga~ npany Al:~s~O Post Office Box 360 Anchorage. Alaska 99510 Te!eghcne 907 277 5537 September 3, 1980 Reference: ARCO Open Hole Logs D.S. 6-15 7/20/80 FDC Run 1 5" " " " FDC/CNL Run 1 5" " " " DIL Run 1 2" & 5" " " " BHCS Run 1 2" & 5" " " " Cyberlook Run~"l 5 ~' " " 7/20/80 Dipmet er Run 1 5" D.S. 6-15 7/21/80 RFT Run t 5" ~Please sign and ret'urn the attached coPy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #578 DISTRIBLrrlON North Geology Exxon R & D Mobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology Marathon State of ~'as'ka Chevron ARCO Oi! aha Gas Company is a Division o! AtlanlicRichfietdCompany ARCO Oil and G~'"~pany Alaska Rag,. Post Olfice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 29, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 I 2 ENO ~ 3 GEQ~ . ~ STAT T~C RI STAT TEC CONF~R~ -FI~F~ Subject' DS 2-16, Permit No. 80-20 DS 6-15,.Permit No. 80-32 DS 11-4, Permit No. 80-60 DS 17-1, Permit No. 80-55 Dear Sir' Enclosed Please find a dri 11 ing h:i~S-l~:or ies, and subject wells. Completion Report, including individual the required gyroscopic surveys for the Very trulY yours,. P. A. VanDusen District Drilling Engineer PAV'cs Enclosures ARCO Oil and Gas Company is a Division of AtlanlicRichfieldCompany Form P--7 ' ' SUBMIT IN D'~ ' ATE OF ALASKA structlons on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OwlELLL~] GAs I-'-1 WELLI I DRY[~] Other b. TYPE OF COMPLETION: NEW ~ WORK DEEP-r--I PLUG r-'l DIFF. r--I WELLIAI OVER r'-] EN I I BACK.I I RESER.I I Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR · P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 323'FSL, 1736'FEL, Sec 2, TiON, R14E, UM At top prod. interval reported below 1392'FSL, 1416'FEL, Sec 2, T10N, R14E, UH At total depth 1412'FSL, 1366'FEL, Sec 2, TION, R14E, UM MULTIPLE 9540'MD ' 9327'TVDI D§~T~7'MD 9255'TVDI 22. PRODUCING INTERVAL(S)~ OF THIS COMPLETION -TOP, BOTTOM, NAME (MD & TVD)* Top Sadlerochit 8855'MD 8645'TVD Base Sadlerochit 9414'MD 9202'TVD ,/ORIGINAL APl NUMERICAL CODE 50-029-20459 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 6-15 (xx-2-10-14) IO.~IELI~ND POOL, OP~t~I LD~C~T vruanoe uay rle/a - Prudhoe CJil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TiON, R14E, UM 12. PERMIT NO. 80-32 16. ELEVATIONS (DF, RKB, RT, GR, ETC)* 68' RKB 21. ROTARY TOOLS AIl 17. ELEV. CASINGHEAD INTERVALS DRILLED BY CABLE TOOLS 23. WAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN ' DIL/BHCS/GR, FDC/CNL/CAL/GR, RFT 25. CASING RECORD (Report all strings set in welll I I i I I 20" 194' Welded IH-40 I 110' I 32"I 13-3/8" 172~ Butt IN-80 I 2678' 17-1/2" 9-5/8" 147~ Butt IL-80 I 8622' 12-1/4" I s-95 I I LINER RECORD 26. SIZE I TOP (MD) 7" I 8299' I 28. PERFORATIONS OPEN TO PRODUCTION BOTTOM (MD) I SACKS CEMENT* 9535' 275 sx ~l. G cmt. (I nterval, size and number) CEMENTING RECORD / AMOUNT PULLED 300 sx Permafrost II tolurf 2200 sx Fondu cmt 500 sx Class G cmt SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) -1/2" 8223' 8167' 29. ' ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) N/A AMOUNT AND KIND OF MATERIAL USED 30. PRODUCTION DATE FIRST PRODUCTION N/A O&~ DATE OF TEST. FLOW TUBING PRESS. IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) HOURS TESTED CHOKE SIZE CALCULATED OIL-BBL. 24-HOUR RATE~ I CASING PRESSURE 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) WELL STATUS (Producing or shut-In) I PROD'N FOR OIL-BBL. TEST PERIO2 I GAS--MCF. ] GAS--MCF. ' ]WATER--BB L. i GAS--OI L RATIO I el L GRAVITY-APl (CORR.) I I TEST WITNESSED BY 32. LIST OF ATTACHMENTS Drilling History & Gyroscopic Survey 33.1 hereby certify t~~oing an~dj~tached,~ormatlon is co[nplete and correct as determined from ,11 available records. ~. ~ ~J~/~4.~~ T,TL. District Drlg. Engineer SIGNED , . . DATE 8/29/80 *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General' This form is designed for submitting a complete a~d correct well completion report and log on all types of lands and leases in Alaska. · Item' 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing in[erval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple 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. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, 35. GEOLOGIC MARKERS WATER AND MUD Nolle NAME MEAS' DEPTH TF~ Top Sadlerochit 8855 Base Sadlerochi 9414 .. · 36. CORE DATA, ATTACH BRIEF DESCRIPI'IONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. Core data to be forwarded by our Geology Department under separate cover. . , , ...... Drilling History DS 6-15 (xx-2-10-14) API 50-029-20459, ADL 28311, Permit No. 80-32 Spudded well @ 0300 hrs 6/24/80. Drld 17-1/2" hole to 2710' Ran 13-3/8" 72# N-80 csg w/shoe @ 2678'. Cmtd csg w/2200 sx Fondu cmt f~llowed by 400 sx Arcticset II cmt. Instld pkoff & tstd to 2000 psi.. NU BOP & tstd to 5000 psi. Drld thru cmt, FC, FS & 10' new hole. Tstd form.to 12.5 ppg EMW. Drld 12-1/4" hole to 8659'. Ran 9-5/8" 47# L-80 & S-95 csg w/shoe @ 8622'. Cmtd csg w/500 sx Class G cmt. Instld & tstd pkoff to 5000 psi. Drld thru cmt, FC, FS & 10' new hole. Tstd form to 12.5 ppg EMW. Dwnsqueeze 300 sx Arcticset I cmt followed by 135 bbls Arctic Pack. Displ well w/oil base mud. Drilled 8-1/2" hole to 8726'. Cored fr/8726'-9448' w/14 core trips. Drld to 9540'. Ran DIL/BHCS/GR & FDC/CNL/CAL/GR logs. Ran RFT. Ran 7" 29# N-80 lnr w/shoe ~ 9535' & top @ 8299'. Cmtd lnr w/275 sx Class G cmt. Press tstd lnr to 3000 psi for I hr. Displ oil faze mud w/NaC1. Ran 5-1/2" tbg w/tail @ 8227' & pkr @ 8171'. ND BOP's & NU tree. Tst tree to 5000 psi. Displ tbg & 9-5/8" x 5-1/2" ann w/diesel. Set pkr. Press tstd tbg to 200 psi on ann, 3500 psi on tbg. Bled to 1500 psi on tbg & 600 psi on ann in 15 min. RIH w/sliding sleeve shifting tool. Closed tool. Press tbg. Did not hold. Ran static temp log & dynamic temp log. Indicated leak @ 7300'-7632'. Ran noise log. Indi- cated leak @ PBR. Opened sleeve, displ diesel w/NaC1. Instl BPV. ND tree, NU & tstd BOP's. POH & LD 5-1/2" tbg. RIH w/PBR retrieving tool. Rotated out k-anchor & PBR. Tstd pkr, 2-1/2 hr bleed off of 500 psi. RIH w/pkr milling assy. Milled on pkr. LD pkr. RIH w/csg scraper. Tstd csg to 3000 psi. Ran gage rng & ink bskt to lnr top. Ran 5-1/2" tbg w/tail @ 8223' & pkr @ 8167'. ND BOP, NU tree & tstd to 5000 psi. Displ tbg & 9-5/8" x 5-1/2" ann w/diesel. Set pkr. Press tstd tbg. Began lng trm tbg tst. Released rig @ 0700 hrs 7/31/80. Whipstock l A PETRO/_ANE COMPANY REPORT , of SUB-SURFACE · D#RECT#ONA£ SURVEY ARCO 0il & Gas COMPANY D.S. 6~ Well #15 WELL NAME Prudhoe Bay, North Slope, Alaska LOCA¥~ON JOB NUMBER TYPE OF SURVEY DATE A780D0391 Directional Single Shot SURVEY BY Jerry Cook, Steve Ratcliff 7-31-80 OFFICE ~laska A t:;.'. C 0 t':) l L Atq I) G A I)S 6, WFLL NC): 1.5 DSS F:'RU[IHOE I-_lAY, NOR'TH SLOF'E:, ALASKA DSS, O--8~,O'?hiI:;, [~RIL. LER; C._,Of,/RATCL. IF'F JOB NO** A780D0391 ............ VERTICAL SECTION CALCULATED IN RECOR.D OP'-SURVEY ........................................................................................................................................................................................... RAI)IUS OF' CURVATURE METHOh ~CO OIL AN. II GAS ; 6, WEL. L. NO: 15 ~L/DF'IOE BAY, NORTH DSS SLOPE, ALASKA COMPUTATION PAGE NO. ..................................... TI ME: ....... DATE .............................. 08: 45; SO 25-AUG-80 :ASLJRED I3RIF--T ) E F' 7' I-.I A N G L E F' E E T D M O, 0 0 -1041, ..... 0 .... 15 1500, 0 0 ~64o, 1 30 S167. 1 1~ 7670, 0 30 4190, 0 30 ,1677, 0 30 4?50, 0 SO ~061, 3 1.5 · - T R U E DRIF:T COURSE VERTICAL. VERT]:CAL. BI F~ECTIOh~ LENGTH DEPTFI SECTION D FEET FEET FEE:T 0 Oo 0,.00 0,00 --N 0 E ............ 1041', t041',00 ......... 2,15 0 459, 1.500,00 3,10 $ 49 E 1145. 2644,86 -2,77 S ?0 E 59~ 3166 71 c-~. 40 E 50~,~ Z669.~o~= N ~5 E 520. .-.4189.63 N 4 W 487, 4676,61 N 40 W 273. 4949.60 --N-19. S LJ B S E A TVD FEET R E: C T A N G U L A R C L 0 S U R E D OGLEC C 0 0 R [-; I N A T E S DISTANCE DIRECTION SEVERI- .................... FEET- ................................... FEET .................D -i'4-- DG./iOOf -68,00 0,00 0,00 0,00 0 0 0000 .... 973~00 ............ 2,-26-"N ..................... 0,00 .................... 2,26- N ....... 0 ........... 0 .................. 0,02 1432,00 3,°. ~.6 N 0,00 3,26 N 0 0 0,05 576.86 6 57 S 11 31 E 13 08 S ~9 50 E 0 13 -t0,32 3098,71 ..............1.6,.78-.S ....... 18.,.33-E ................... 24,85 ..... S~.47-31 ..... E ............ 0.~ -15,44 3601. :~ 23 22 32.22 e.o ,40 S ,15 E S 43 25 E 0.16 --14 06 41'~1,63 . 23,~-...~ .............~.~.,. . ~ '- _~ ~ ~z 07-E ............... 34 92 ....... S- 48...18.E ................ 0+15 -9,90 4608,61 19/21 S 27,19 E 33,29 S 54 45 E 0,07 -.8,10 4881,60 17,04 S 26,31 E 31,34 S 57 4 E 0,1.1 E 111, .......5060,53 ......... 5 05 ,-,-~ ='-- o ,~,= / ................. , 4~2,,~ ~ ............. 1.3 · 62-o ............... ~.o.,-o7-.-..E ............ 29,06 .............. S..62 ......... 3--E ............. 2,.72 5187, 7 .-'30 N 11 E .,~1'2, 112 45 N i2,E: 5437, 17 30 N 7 E ~oo9. 25 0 N 9' E 5900, 27 1.5 N 9 E 6138, 27 0 N 9' 6375, 2--'6 0 N 9 6530, .-."~6 30 N 9 665° 26 ,-, 15 N I0 · 6864.- 24 O' N' 11 2oLd, -237, 1 ':'~-" ,..., .., 12'2, · .......... 2 126j '15185.951 .... . 6,,~. 117,'95 i 2~, ...., .'~'""'"-' ,,.. ovo 96:",'', '~'~o,~.,.., ,' ,..,,-,~:=:: 5240; 96 125, :- 5429 ,60 ........... :60 ;8'0. 'S'""',_.~61.6u" "' ~'-'"~ :' ':: =; 636, '-'' "; ' -' ' --=,'..,, ." :1.3¥~99 ' ~-= ' ' '"'"-" .... ,.,o08, .,~,_,-..' ~ 1'3 i";':061:f N -.- .~ ,, ~. -. 0. ~ :7/: 244'. 815784 ~ 72 ii:::, ', .:' ~.93" =.-~ .... .::..8'~:"":'.~ 6064.54 352.00 5996.54 343,04 N 6276,64 456..46 6208.64 447.49 N 6415,65 524,18 6347,~._ 15 20 N 6524,95 577.79 6456,95 568.65 N 83.25 E: ..... 99.79 E 110,=° 119,46 E 28,81 S 85 33 E 3,42 38.,.32 ......... N--59.-46-.E .......... 4,20. 64.24 N 36 48 E 3,94 140,16 N 20 46 E 3,39 245.-00 .......... N ....... !-5-...42.~E ............... 0,...9~ 353,00 N 13 38 E 0,Ii -~o..~.~ N ..... 1 .... 34 E 0 4~ o4 92 N 19 ' 581.07 N 11 52 E 0,. ~ I~,· ...... 6716,..88 AA/',04 ..... 664~,88 ............:o/,-15-.-..N 13~,.-oo--..E ............ A-7.1--,05 ....... N ..... 1.1 41 .....E ..... 10~ 7019. , ~'~1 30 N 16 E '7205, 17 30 N 17 E 7388, 14 30 N 23 E 7574. 1''~ 45. N 13 E 7700. 12 0 N 13 E i~'' ~06 .,5. 6859,81 ,,. .78 186,- -7035,11 788~83 i83, 7911o00. 839,°1 1°6. ~391076 880 97 126, 7514,83 909,87 6791,~1_ 71='o.49.. N 149,~R'- E 730,94 N 11 50 E '~,04 6967,11 774,93. N .... t67,48 E ........... 792..83 .... N 12 .... t2 E .........2.16 7143 O0 q.-~o ~ ~,~1 N 184,72 E 842,80 N 1° 40 E 1,87 7323.76 863.92 N 198,25 E 886,38 N 12 55 E 1,57 7446,83 890.23 N ....... 204,32 E .......... 91-3.38 .... N. t2-56 E ...... 0.60 7884, 11 30 N 20 E 184, 8073,.- 10 30 N 27 E 189, '8419, 8 30 N 58 c.~ 346, ou,. .' 0 N 71 E 190, 7694,97 947,31 7626,97 7880,50- · 983,i8 7812,50 8'-"~1.-. ;_ ,74 1034.49 815~.74 8410.00 1052.07 834°.. · 00 .. ooz...,..14 N~°14.:~ E 950,76 N. 13 4 E 0.82 959,-19-.N ............ 229,33-.-.E ............ 986,22 ........ N--t3'27-E ...... 0,88 1000.78 N ?67 44 E 1035,90 N 14 ..o E 1.O6 1011,79 N 290,51E 1052,67 N 16 1E 1,21 FINAL CLOSURE -' DIRECTION; N 16 DEGS 1 MINS 13 SECS E DISI'ANCE~ ........... t052,67'--F:EET /' DTrPCmTA~t~T, POP nP IT,r.9 TmF r~-15 r. pti r'ugp P-,Ay IPVrv r,.~mp., o--O--pA., 'Dr~ prpppm,~pp Pr'-~PT?,~(': ,'lPq-OOP COMPLETION REPORT ARCO bIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE HETHOD OF COMPUTATION COMPUTED FOR SDC BY FH LINDSEY & ASSOC 19 AUG 80 DS 6-15 K B ELEV 68,00 JOB NO 4-4.62 'RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 0.00 100 0 0 lO0.O0 200 0 0 200.00 300 0 0 300.00 400 0 0 400.00 500 0 0 500.00 600 0 0 600.00 700 0 0 700,00 800 0 25 799.99 -68,00 N O.OOE 32.00 N O,OOE 132,00 N O,OOE 232,00 N O,OOE 332.00 N O,OOE 432.00 N O.OOE 532.00 N O,OOE 632,00 N O,OOE 731,99 NIO.OOE 900 0 0 899,99 831,99 N O.OOE )0 0 0 999,99 931,99 N O,OOE 100 0 0 1099.99 1031.99 N O.OOE 1200 0 25 1199.99 1131,99 N12.00E 1300 0 0 1299.99 1231.99 N O.OOE 1400 0 0 1399.99 1331,99 N O,OOE 1500 0 0 1499,99 1431,99 N O.OOE 1600 0 0 1599,99 1531,99 N O,OOE 1700 0 0 1699,99 1631.99 N O.OOE 1800 0 25 1799.99 1731.99 N 8,00E 1900 0 15 1899.99 1831.99 N10.00E 2000 0 0 1999.9'9 1931.99 N O,OOE 2100 0 0 2099.99 2031,99 N O.OOE 2200 0 0 2199.99 2131,99 N O,OOE 2300 0 0 2299,99 2231,99 N O,OOE 2400 0 15 2399.99 2331.99 N 9,00E TOTAL COORDINATES 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 O,O0. S 0,00 W 0.00 S 0.00 W 0.00 S 0,00 W 0,36 N 0,03 E 0.72 N 0.06 E 0,72 N 0.06 E 0,72 N 0.06 E 1,09 N 0,10 E 1,45 N 0,14 E 1.45 N 0,14 E 1,45 N 0,14 E 1.45 N 0,14 E 1,45 N 0,14 E 1,82 N 0.16 E 2,39 N 0,25 E 2,61N 0.27 E 2,61 N 0.27 E 2.61N 0.27 E 2,61 N 0,27 E 2-83 N 0,29 E CLOSURES DISTANCE ANGLE D M 5 0,00 S 0 0 0 W 0o00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0,36 N 5 0 0 E 0.73 N 5 0 0 E 0,73 N 5 0 0 E 0,73 N 5 0 0 E 1,09 N 5 19 59 E 1.46 N 5 29 59 E 1.46 N 5 29 59 E 1.46 N 5 29 59 E 1,4.6 N 5 29 59 E 1,46 N 5 29 59 E 1.82 N 5 11 58 E 2,41 N 6 7 10 E 2,63 N 6 1 36 E 2.63 N 6 1 36 E 2.63 N 6 1 36 E 2.63 N 6 1 36 E 2,84 N 5 54 36 E DOG LEG SEVERITY DEG/100FT 0.000 0.000 0.000 0.000 0,000 0,000 0,000 0,000 0-420 0,420 0.000 0.000 0,420 0,420 0,000 0.000 0.000 0,000 0,4.20 0.170 0.250 0,000 0.000 0.000 0,250 SECTION DISTANCE 0.00 0,00 0.00 0,00 0.00 0.00 0,00 0,00 0,35 0.71 0.71 0.71 1,06 1,42 1,42 1.42 1,42 1,42 1,78 2.35 2.56 2,56 2,56 2.56 2,78 ARCh DS b-15 GYROSCOPIC SURVEY JOB NO 4462 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER AUG JO TRUE MEAS. DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG. 2500 0 25 2499.99 2431,99 S49.25E 2600 0 0 2599.99 2531,99 N O,OOE 2700 0 0 2699.99 2631,99 N O,OOE 2800 0 0 2799,99 2731,99 N O.OOE 2900 0 0 2899.99 2831.99 N O.OOE 3000 0 30 2999,98 2931.98 S24,63E 3100 0 0 3099.98 3031,98 N O.OOE 3200 0 0 3199.98 3131.98 N O.OOE 3300 0 0 3299.98 3231,98 N O.OOE 3~00 0 0 3399.98 3331,98 N O,OOE 3500 0 30 3499.98 3431,98 S37.85E 3600 0 0 3599.98 3531.93 N O.OOE 3?00 0 0 3699.98 3631.98 N O.OOE 3800 0 0 3799.98 3731.98 N O,OOE 9 00 0 0 3899.98 3831,98 N O.OOE ..0 0 30 3999.98 3931.98 517.07E 4100 0 15 4099,98 4031.98 N 1,OOE 4200 0 0 4199,98 4131,98 N O.OOE 4300 0 0 4299.98 4231,98 N O.OOE 4400 0 0 4399,98 4331,98 N O,OOE 4500 0 0 4499,98 4431,98 N O.OOE 4600 0 0 4599.98 4531.98 N O.OOE 4700 0 0 4699,98 4631,98 N O.OOE 4800 0 0 4799,98 4731.98 N O.OOE 4900 0 0 4899.98 4831,98 N O.OOE 5000 0 30 4999,98 4931,98 N24.40W 5100 5 0 5099.83 5031,83 N19.77E 5200 8 30 5199.13 5131,13 N13.00E 5300 18 0 5296.35 5228.35 N12.27E TOTAL COORDINATES 2.99 N 0.74 E 3.12 N 1.01 E 3,12 N 1.01 E 3.12 N 1.01 E 3.12 N 1.01 E 3.18 N 1.31 E 3,25 N 1.62 E 3,25 N 1.62 E 3.25 N 1.62 E 3.25N 1,62 E 3.36 N 1,93 E 3.47 N 2.25 E 3.47 N 2.25 E 3.47 N 2.25 E 3.47 N 2.25 E 3,51 N 2,55 E 3.58 N 3,00 E 3.79 N 3.00 E 3.79 N 3.00 E 3.79 N 3.00 E 3.79 N 3.00 E 3.79 N 3.00 E 3.79 N 3.00 E 3.79 N 3,00 E 3.79 N 3.00 E 4.22 N 2.91 E 8.89 N 2.72 E 20-16 N 6.04 E 42,50 N 11.04 E CLOSURES DISTANCE ANGLE D N S 3,09 N 13 56 36 E 3.28 N 17 56 3 E 3.28 N 17 56 3 E 3,28 N'17 56 3 E 3.28 N 17 56 3 E 3.44 N 22 26 59 E 3.63 N 26 31 14 E 3.63 N 26 31 14 E 3,63 N 26 31 14 E 3.63 N 26 31 14 E 3.88 N 29 58 4 E 4.13 N 32 59 51 E 4.13 N 32 59 51 E 4,13 N 32 59 51 E 4.13 N 32 59 51 E 4.34 N 35 59 38 E 4,67 N 40 1 38 E 4,84 N 38 23 6 E 4.84 N 38 23 6 E 4,84 N 38 23 6 E 4e84 N 38 23 6 E 4.84 N 38 23 6 E 4.84 N 38 23 6 E 4,84 N 38 23 6 E 4e84 N 38 23 6 E 5,13 N 34 38 49 E 9.30 N 17 3 1 E 21,05 N 16 40 44 E 43,91N 14 34 20 E DOG LEG SEVERITY DEG/iOOFT 0,170 0,420 0,000 0,000 0,000 0,500 0,500 0,000 0.000 0.000 0,500 0,500 0,000 0,000 0,000 0,500 0.250 0,250 0.000 0.000 0,000 0,000 0,000 0,000 0.000 0.500 4,512 3.503 9,500 SECTION DISTANCE 3.08 3,28 3.28 3,28 3,28 3.44 3,60 3,60 3,60 3,60 3,80 4.00 4.00 4,00 4,00 4,14 4,35 4.55 4,55 4.55 4,55 4.55 4.55 4.55 4,55 4,93 9,30 21.03 43,80 ARC~ DS 6-15 · GYROSCOPIC SURVEY JOB NO 4462 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER 19 AUG 80 TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES { ~'00 16 30 5391,85 5329,85 N 6,20E 30 20 0 5486.81 5418,81 N 6.58E 5600 24 0 5579,51 5511,51 N 6.93E 5700 27 30 5669,56 5601,56 N 8.90E 5800 28 0 5758.06 5690,06 N 8.52E 5900 27 30 5846.56 5778,56 N 8.12E 6000 27 30 5995.26 5867.26 N 8.63E 6100 27 0 6024,16 5956.16 NIO,O2E 6200 27 0 6113.26 6045.26 NlO,53E 6900 27 0 6202.36 6194.36 NiO,17E 6400 26 0 6291.86 6223,86 NIO.50E 6500 26 30 6381.54 6919.54 Nll,OSE 6600 26 15 6471.13 6403.19 N12.47E 6700 26 0 6560,92 6492,9.2 N13,90E 6800 25 0 6651.17 6583.17 N14.50E 6900 24 0 6742.17 6674.17 N14,45E 7000 22 0 6834,21 6766.21 N17,30E ( )0 20 0 6927,57 6859.57 N18,28E 7'200 18 0 7022,11 6954,11 N18,B7E 7900 16 0 7117.74 7049.74 N22,43E 7400 14 30 7214,22 7146,22 N25.85E 7500 19 15 7311,90 7249,30 N20.19E 7600 13 0 7408.6,8 7940.68 N15,49E 7700 12 30 7506.22 7438.22 N20.50E 7800 12 30 7603.85 7535,85 N21.68E 7900 11 30 7701,66 7633,66 N20,85E 8000 11 0 7799,74 7731,74 N24.95E 71,75 N 15,80 E 102.87 N 19,29 E 140.06 N 23.69 E 183.12 N 29.45 E 229.18 N 36.26 E 275,25 N 42,99 E 320-93 N 49,72 E 966.11 N 57,14 E 410.78 N 65.24 E 455.44 N 73.39 E 499.34 N 81.40 E 542.79 N 89.68 E 586.27 N 98.74 E 629.15 N 108.79 E 670.88 N 119,35 E 711,09 N 129.71 E 748.61 N 140,40 E 782.79 N 151,95 E 813,64 N 161.58 E 841,09 N 171.77 E 865,09 N 182,59 E 887.10 N 191.89 E 908,71 N 198.82 E 929,70 N 205,63 E 949,89 N 213,41 E 969,27 N 220,95 E 987,24 N 228.54 E 237,2i E 247,53 E 8100 11 0 7897.90 7829,90 N29,05E 1004.29 N 8200 10 0 7996.23 7928.23 N40.12E' 1019,21N C L 0 S U R E S DISTANCE ANGLE D M DOG LEG SEVERITY DEG/iOOFT 73,47 N 12 25 19 E 104,66 N 10 37 13 E 142,05 N 9 36 7 E 185.47 N 9 8 12 E 232.03 N 8 59 27 E 278,59 N 8 52 43 E 324.76 N 8 48 26 E 370,55 N 8 52 16 E 415.93 N 9 1 27 E 461.32 N 9 9 17 E 505,93 N 9 19 32 E 550.14 N 9 22 55 ~ 594.53 N 9 33 38 E 638.48 N 9 48 37 E 681,41 N 10 5 15 E 722.77 N 10 20 20 E 761.66 N 10 37 21 E 797.23 N 10 56 37 E 829.53 N 11 19 57 E 858.39 N 11 32 36 E 884.08 N 11 54 55 E 907.61 N 12 12 21 E 930,21 N 12 20 30 E 952.17 N 12 28 18 E 973.57 N 12 39 45 E 994,14 N 12 50 90 E 1019,35 N 13 2 4 E 1031,87 N 13 17 24 E 1048.84 N 13 39 4 E 1,578 3.500 4.000 3,512 0.502 0,507 0,235 0.576 0,232 0,163 1.002 0,513 0,369 0.372 1,006 1.000 2e040 2,009 2,000 2.024 1,515 1.286 0.345 0,554 0.255 1.001 0.522 0.782 1.054 SECTION D I STANCE 73,05 103,66 140,92 182,96 Z28.79 274,61 320,06 365.25 ~10,i7 455.11 ~99,26 543.09 587,20 631,04 673,96 715,32 754,35 790,18 822.73 851.95 878,12 902.02 924,72 946.78 968,40 989,!7 1008.62 1027,49 1044,98 ARC'O DS 6-15 GYROSCOPIC SURVEY JOB NO 4462 19 AUG ~0 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES '.30 10 0 8094.71 O0 9 0 8193,33 8500 8 45 8292.14 8600 7 15 8391.16 8700 6 0 8490.49 8800 5 0 8590-03 8900 5 0 8689.65 8026.71 N46,23E 8125,33 N52,27E 8224.14 N60,42E 8323.16 N65.70E 8422,49 N65-OOE 8522-03 N62-OOE 8621,65 N60,52E 9000 4 45 9100 4 0 9200 4 15 9300 4 0 9400 a 0 9500 a 0 8789.29 8721.29 N60.88E 8889.00 8821.00 N71.27E 8988.74 8920.74 N66.60E 9088.48 9020.48 N61.98E 9188.23 9120.23 N66.33E 9287.99 9219.99 N69.72E 1031.87 N 1042.64 N 1051.18 N 1057.49 N 1062.30 N 1066.97 N 1070'-76 N 1074.92 N 1078.01 N 1080'60 N 1083,72 N 1086.76 N 1089.B7 N 259.41 E 271,91 E 284.74 E 297,14 E 307,63 E 316.20 E 323.84 E 331.25 E 338,22 E 344.93 E 351.41E 357.68 E 364.15 E BOTTOM HOLE CLOSURE 1148.62 FEET AT N 18 29 1 E CLOSURES DI STANCE ANGLE D M S DOG LEG SEVERITY DEG/iOOFT 1063.98 N 14 6 42 E 1077.51 N 14 36 59 E 1089.07 N 15 9 23 E 1098.44 N 15 41 41 E 1105.94 N 16 9 i E 1112.46 N 16 90 48 E 1118,67 N 16 49 39 E 1124.81N 17 7 39 E 1129.83 N 17 25 8 E 1134.31 N 17 42 12 E 1139.27 N 17 57 57 E 1144.11N 18 13 5 E 1146.62 N 18 29 1E 1.061 1.011 0.313 1.502 1.250 1.000 0,129 0,250 0,752 0.251 0,251 0.303 0.236 SECTION DISTANCE 1060.76 1074,95 1087.13 1097.06 1104,96 1111.74 1118,15 1124.45 1129.60 1134.18 1139.21 1144.09 1148.62 ARCO DS 6-15 GYROSCOPIC SURVEY JOB NO 4462 MEASURED DEPTH AND'OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 19 AUG ~0 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 7352 7168. 7100 184 4 7455 7268, 7200 187 3 7558 7368, 7300 190 3 7661 7468. 7400 193 3 7763 7568. 7500 195 2 7866 7668. 7600 198 3 7968 7768, 7700 200 2 8070 7868, 7800 202 2 8171 7968. 7900 203 1 8273 8068, 8000 205 2 8374 8168, 8100 206 1 8476 8268, 8200 208 2 8577 8368. 8300 209 1 8677 8468. 8400 209 0 8778 8568, 8500 210 1 8878 8668. 8600 210 0 8979 8768, 8700 211 1 9079 8868. 8800 211 0 9179 896R. 8900 211 0 9279 9068. 9000 211 0 9380 9168. 9100 212 1 9480 9268. 9200 212 0 853.93 N 877.35 N 899.63 N 921.68 N 942.49 N 962.84 N 981.65 N 999.19 N 1015.23 N 1028.59 N 1040.11 N 1049.34 N 1056.31 N 1061.32 N 1065.65 N 1069.85 N 1074.12 N 1077.58 N 1080.03 N 1083.10 N 1086.24 N 1088.92 N 177.19 E 187.91 E 196,09 E 202,67 E 210.36 E 218.30 E 225.79 E 234,31 E 244.33 E 256.03 E 268.64 E 281,49 E 294.35 E 305.36 E 314.46 E 322,16 E 329.66 E 336.78 E 343,49 E 350,07 E 356.36 E 362.83 E ARCO DS 6-'t5 GYROSCOPIC SURVEY JOB NO 4462 INTERPOLATED VALUES FOR EVEN lOOO FEET OF MEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999, 931, 0.72 N 2000 1999, 1931. 2.61N 3000 2999, 2931, 3.18 N 4000 3999, 3931. 3,51 N 5000 4999, 4931- 4,22 N 6000 5935, 5867. 320.98 N 7000 6834. 6766. 748.68 N 8000 7799, 7731, 987,35 N 9000 8789. 8721, 1075,01 N 0,06 E 0.27 E 1,31 E 2.55 E 3.09 E 49.42 E 140,15 E 228.26 E 331,20 E 19 AUG 80 ARCO DS 6-15 MEASURED DEPTH AND'OTHER GYROSCOPIC SURVEY DATA FOR EVERY EVEN 100 JOB NO FEET OF SUB 4462 SEA DEPTH. 19 AUG MEASURED DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SEA DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 3668 3768 3868 3968 4068 4168 4268 4368 4468 4568 4668 4768 4868 4968 5068 5169 5270 5375 5~+80 5587 5698 5811 5924 6037 6149 6261 6373 6485 6596 6708 6818 6928 7036 7143 7248 3668. 3600 0 3768. 3700 0 3868. 3800 0 3968. 3900 0 4068. 4000 0 4168. 4100 0 4268. 4200 0 4368. 4300 0 4468. 4400 0 4568. 4500 0 466~, 4600 0 4768. 4700 0 4868. 4800 0 4968, 4900 0 5068. 5000 0 5168, 5100 0 5268. 5200 2 5368, 5300 7 5468. 5400 12 5568. 5500 19 5668. 5600 30 5768, 5700 43 5868. 5800 56 5968, 5900 69 6068. 6000 81 6168. 6100 93 6268. 6200 105 6368. 6300 116 6468. 6400 128 6568. 6500 140 6668, 6600 150 6768, 6700 160 6868, 6800 168 6968. 6900 175 7068. 7000 180 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 5 5 7 11- 13 13 13 12 12 12 11 12 i2 10 10 8 7 5 3.47 N 3.47 N 3.47 N 3,.56 N 3.38 N 3.77 N 3.79 N 3.79 N 3.79 N 3.79 N 3,79 N 3,79 N 3,79 N 3,99 N 6,57 N 15e98 N 34,19 N 64,64 N 96.21 N 134.93 N 182.27 lq 234,29 N 286.22 N 337,72 N 388,02 N 438.06 N 487.67 N 536.21 N 584.59 N 632,50 N 678,2.4 N 721,94 N 761,29 N 796,40 N 827.33 N 2,25 E 2,25 E 2,25 E 2,39 E 2,95 E 3,00 E 3.00 E 3.00 E 3.00 E 3.00 E 3.00 E 3.00 E 3.00 E 3.03 E 2.52 E 4.88 E 9,19 E 14.85 E 18,37 E 22.66 E 28,86 E 36.98 E 44,54 E 52.19 E 61.00 E 70,05 E 79.08 E 88,18 E 98,17 E 109,56 E 121.18 E 132,52 E 144,32 E 155.79 E 166.29 E ARCO DS 6-15 GYROSCOPIC SURVEY JOB NO 4462 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS 19 AUG 80 CODE NAME TRUE MEASURED VERTICAL TOTAL COORDINATES C L 0 S U R E DEPTH DEPTH DISTANCE ANGLE D M S SUB SEA TOP SAD B E SAD ~C.., G BACK TD 8855 8644.82 1068.86 N 9414 9202.20 1087.15 N 9467 9255.07 1088.58 N v9540 ~9327.47 1089.20 N 320.41 E 358.58 E 361.99 E 370.14 E 1115.86 N 16 41 14 E 8576.82 1144.76 N 18 15 15 E 9134.20 1147.19 N 18 23 37 E 9187.07 1150.37 N 18 46 9 E 9259.47 ARCO DS 6-15 MEASURED DEPTH AND'OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO 4462 FEET OF SUB SEA DEPTH. 19 AUG ~0 TRUE MEASURED VERTICAL DEPTH DEPTH SUB MD=TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 168 168, 100 0 268 268, 200 0 368 368. 300 0 468 468. 400 0 568 568, 5O0 0 668 668, 600 0 768 768. 700 0 868 868. 800 0 968 968. 900 0 1068 1068. 1000 0 1168 1168. 1100 0 1268 1268. 1200 0 1368 1368. 1468 1468. 1568 1568. 1668 1668, 1768 1768. 1868 1868. 1968 1968, 2068 2068. 2168 2168, 2268 2268. 2368 2368. 2468 2468. 2568 2568. 2668 2668. 2768 2768. 2868 2868. 2968 2968. 3068 3068. 3168 3168. 3268 3268. 3368 3368. 3468 3468. 3568 3568. 1300 0 1400 0 1500 0 1600 0 1700 0 1800 0 1900 0 2000 0 2100 0 2200 0 2300 0 2400 0 2500 0 2600 0 2700 0 2800 0 2900 0 3000 0 3100 0 3200 0 3300 0 3400 0 3500 0 0.00 0,00 S 0,00 S 0.00 0,00 S 0.00 0,16 N 0,68 N 0,72 N 0,72 N 0,89 N 1.41 N 1,45 N 1,45 N 1.45 N 1,45 N 1.62 N 2.24 N 2,59 N 2.61 N 2,61 N 2.61 N 2.71 N 3,04 N 3,01 N 3.12 N 3.12 N 3,12 N 3.22 N 3,11 N 3.25 N 3.25 N 3.25 N 3.37 N 3.33 N 0,00 W 0.00 W 0,00 W 0.00 W 0.00 W 0,00 W 0.00 E 0,06 E 0,06 E 0,06 E 0.07 E 0.14 E 0,14 E 0.14 E 0,14 E 0.14 E 0.14 E 0,23 E 0,27 E 0.27 E 0,27 E 0,27 E 0.28 E 0,55 E 1,03 E 1,01 E 1,01 E 1,01 E le14 E 1.64 E 1,62 E 1.62 E 1,62 E le75 E 2,28 E HORIZONTAL VIEW ARCO OIL & GAS DRILL SITE 6- 15 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I"= I000' AUG. 19,1980 9200 7600'~-/ 72oo./-/~ 8~oo ./~,. 6400' / 0~/" ~ 60OO - ~ 5600 ' · TVD = 9288' TMD= 9500' 17~6' T ION, RI4 E,UM 2 I Il 12 ALL DEPTHS ..SHOWN ARE TVD SURFACE IS 52:5' N & 1756' W OF SE COR SEC 2, TION, R 14E, UM 400 - 800 1200 1600 2000 2400 2800 - 3200 - _ 3600 - 4000 - 4400 4800 - 5200 ~000-~ - \ ?000-~ 8000 - 8800 ._ _ _ 9200 TYD= 9~88' .......... TM D= 9500' VERTICAL SECTION ARCO OIL & GAS DRILL SITE 6-15 RADIUS OF CURVATURE GYROSCOPIC SURVEY SCALE I"= I000' AUG. 19, 1980 ALL DEPTHS SHOWNI ARE TVD. STRATIGRAPHIC HIGH RE'SOLUTION DIP METER LOCATED IN THE APPENDLX CURVE DATA LO..CATED IN THE APPENDIX ARCO Oil and Gas. J?~mpany Post Offic, ox 360 ,',n::f;or;~.qe. Alaska 99510 T,:i,:oher:e ii07 277 5637 August 8, .1980 Reference: ARCO Open Hole Logs 7/21/80 Arrow Plot/Cluster Listing Run 1 7/10/80 Arrow Plot/Cluster Listing Run 1 oo P~ease sign and return the attached copy as receipt data. 2 & 5" (same log) 2 & 5" (same log) K. J. Sahlstrom North Engineering TRANSMITTAL #535 DISTRIBLrrlON North Geology Exxon R & D Mobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology Marathon State of Alaska Chevron ARCO Oil and Gas Company is a Division of AtlanticRichlieldCompany ARCO Oil and Gas ¢~,.~pany c-. North Slope'~ 'icl Post Office .. _ ?. 360 Anchorage, Alaska 995I[) Telephone 907 277 5637 July 11, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99507 Subject: DS 2-15, Permit No. 80-19 DS 6-15, Permit No. 80-32 DS 11-4, Permit No. 80-60 DS 17-1, Permit No. 80-55 Kuparuk Well E-3, Permit No. 80-56 Dear Sir' · Enclosed please find Monthly Reports on the above-mentioned wells for the month of June. Very truly yours, P. A. VanDusen District Drilling Engineer PAY'cs Enclosures ARCO Oil and Gas Company is ;, .'):vi'.,ioa of Atlantic,qL':hli,!!dC:,.: ,~p: ny Form No. 10-404 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20459 6. LEASE DESIGNATION AND SERIAL NO. ADL 28311 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfield Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL 323'N & 1736'W of SE cr Sec 2, TiON, R14E, UM 9. WELL NO. DS 6-15 (xx-2-10-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 2, TION, R14E, UM 12. PERMIT NO. 80-32 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for month of June, 1980 Spudded well @ 0300 hrs 6/24/80. Drld 17-1/2" hole to 2710' Ran 13-3/8" 72# N-80 csg w/shoe @ 2678'. Cmtd csg w/2200 sx 'Fondu cmt followed b;400 sx Arcticset II cmt. Instld pkoff & tstd to 2000 psi. NU BOP & tstd to 5000 psi. Drld thru cmt, FC, FS + 10' new hole. Tstd form to 12.5 ppg EMW. As of 6/30, drlg 12-1/4" hole @ depth of 6172'. 14. I hereb~,~at ~regoi~t:ue~a,~d _correct SIGNEDZ--~. ~ _ TITLE District Drlg Engineer DATE 7/9/80 NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee bY the 15th of the succeeding month,unless otherwise directed. ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H, Hamilto.n /~"~.- Chairman/Commisslo~r '~ Thru: Lonnie C. Smith Commissioner Bobby~ Foster Petroleum Inspector June 30, 1980 Witness B.O.P.E. test on ARCO's D.S. 6-15, Sec.2, T10N, R14E, U.M. Permit No. 80-32 Wednesday, June 25, 1980 I traveled this date to Prudhoe Bay to ~i~eSS"-'~'e'uPComi~g-'B.-~.P.E. test on ARCO's D.S. 6-15. Thursday,. June,26,.....1980 Standing by for B.O.P.E. test. Friday, June 27, 1980 The B.O.P.E. test began at 1:30 a.m. and ~as' "conCluded at" 3:3'6 a.m. The results of the test are attached to this report. In summary: I witnessed the B.O.P.E. test on ARCO's D.S. 6-15. The lower Kelly valve failed the test and is to be repaired/replaced and the A.O.G.C.C. office/inspector notified within three days. .J. ply 1.,_ 198_0 Attachment: Mr. Chuck Seveil contacted the A.O.G.C.C. this date and informed Doug Amos the lower kelly valve had. been changed and-tested. 4/8O STATE OF ALASKA A~SKA OIL & GAS' CONSERVATION COF'IMjJSSION B,O.P.E. Inspection Report _I ns pector/~~/~_~_ Operator Location, General 1/~~ Well Sign General Housekeeping Reserve pit Location: Sec ~ T/~4JR/~,.t [,)~ ...-, /~Casing Set @~X 7~ ft. / Drilling Contracto.r ,~/~_ ./~../I.Rig:#/~/ Representativ~/f/~:~ ~.c~-.-~/ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve 3 /. Ten t Pres'sure ._~0 '~ .... 50~'" ACCUMULATOR SYSTEM Full Charge Pressure J~ ~_d3 psig Pressure After Closure/~~) psig 200. psig Above Precharge Attained: -- min~___~se- Full Charge Pressure Attained: ~ min/O sc Controls: Master ~~ Remote .~.~ Blinds switch co. very~-' Upper Kelly . / Lower Kelly . /. Bal 1 Type / Inside BOP / Choke Manifold~Test P No. Valves. ~ No. flanges ~ ~ Kelly and Floor Safety Valves Test Pressure ~'~--~ Test Pressure~ Test Pressure ~ Test Pres sure ressure ' IIAdjustable Chokes / II Hydrauically operated choke / Test Results: Failures I "'! L~ '~e '_~ .... :'~-"--" Repair or Replacement of failed equipmen~~' to be made within -~ ~ days and Inspector/Commission office notified. Remarks: ~/~/ ~~~_ ~/~ . ~/~ ~A~~ ~ ~ .~/~~ j / Distribution orig. - AC&GCC cc - Operator cc - Supervisor ARCO Oil and Ga~ pany Alaska District Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 16, 1980 Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 STAT TEC _l~J. STAT TEC CONFER: FILFi Subject' DS 6.-15, Permit No. 80-32 Dear Sir' Enclosed pleaSe find a Sundry Notice detailing Work planned for the above-mentioned well. Very truly yours, P. A, VanDusen District Drilling Engineer PAV/ms Enclosures ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form ! 0-403 REV. 1-10-3'3 Submit "1 ntentions" in Triplicate & "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--" for such proposals.) 1. Ow~LL WELL'' OTHER 2, NAME OF OPERATOR 'Atlantic Richfield Company 3, ADDRF--SS OF OPERATOR P,0, Box 360 Anchorage, AK 4. LOCATION OF WELL At surface 323'N & 1736'W of SE cr Sec 2, T10N, R14E, UM (@ 8800'ss) 1206'N & 1450'W of SE cr Sec 2, T10N, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 68'RKB, 38' Pad Elevation (Gravel) 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20459 i6. 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 6-15 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fi el d-Prudhoe 0il Pool 11; SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, T10N, R14E, UM 12. PERMIT NO. 80-32 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING L_~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS(Core) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We plan to core the Sag River and Sadlerochit formations in this well. Well logs will be run below 9-5/8" casing. Surface and bottom hole locations are the same as on the original permit. 20" conductor pipe and 17-1/2" surface casing are unchanged. 9-5/8" casing and 7" liner are proposed as follOws: Size Size Wt. per Setting Ho 1 e Cas i ng Foot Grade Depth Quantity of Cement 12-1/4" 9-5/8" 47# 80&95 +8626'MD 500 sx 1st stage & 300 sx 2nd stage 8-1/2" 7" 29# L-80 _+8326' to 400 sx Class G 9494' MD All other information on the original permit remains unchanged We anticipate spud- in on this well about June 22, 1980. 16. I hereby certify that the foregoing is true and correct SIGNE .-- .-- . TITLE District Drlg. Enqineer DATE (This space for Stateo,~u~, se) APPROVED BY . (~/'(~1~ I COMMISSIOlXlEB- ~L~ DATE CONDITIONS OF APPROVAL, ,IF : ' · DE~' ' T~I~ COMMISSION See Instructions On Reverse Side 6/16/80 Approved Cop~ Returned February 20, i9'80 Prudhoe Bay Unit DS 6-15 Atlantic Richfield Company Permit No. 80-32 Sur. LOC.~ 323~N & 1736tW of SE cr Sec 2, T10N, R14E, UN. Bottomhole Loa.z 1206tN & 1450tW of SE cr Sec 2, T10N, R14E, UM. Mr. P. A. VanDu.sen District Drilling Engineer. ARCO Oil and Gas Company P. O. Box 360 ~ahorage, Alaska 99510 Dear Mr. VanDusen = Enclosed~ is the approved application for permit to drill the above referenced well. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape contain- ing the digitized log information on all logs shall be sub- mitred for copying except experimental logs, velocity surveys -and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the-spawning or migration of anadromous fish. operations in these areas are subject to AS 16..50.870 and the regulations pr~lgated thereunder (Title 5, i Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator~s office, Department of Fish and Game. Pollution of any waters of the State is prohibited ~f AS 46, Chapter 3~ Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Prudhoe Bay Unit DS 6-15 -2- · February 20, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Looal Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to dril 1. To aid us in scheduling field ~ 'w°'rk, we would~ a~reciate your no~fyin, g' this. office within 48 'hours after the well is spudded We would also like to be notified so' that a repre- sen.tative of-the commission may 'be present to witness testing of'blowout preventer equipment before surface casing shoe is drilled. _In the' event of .- suspension or abandonment, please give this office ads.ate-advance no~-ification so that we may have a Very truly yours, Alaska Oil & Gas ~nse~atton ~mission EnClosure cc~ Department of Fish & Game, Habitat Section w/o encl. Depar~men.t of Environmental Conservation w/o/eno1. Department of Laborl Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas( '~mpany North Alaska ~.,strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February ll, 1980 Mr. Hoyl e Hami 1 ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 6-12, DS 6-13, DS 6-14 DS'~'6-1 DS 6-16 Dear Mr. Hamil ton: Enclosed herewith are our Applications for Permits to Drill DS 6-12, DS 6-13, DS 6-14, DS 6-15, and DS 6-16, the $100.00 filing fee, and the required survey plat. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:cs Enclosure ' ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-401 ' REV. 1-1-7! SUBMIT IN TR, CATE _(_Other instructions on D ~ ~ E ~rWs~d~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMIT~ j, ~? +~'~,,~,,~.,~ PERMIT TO DRILL OR DEEPEN DRILL ~ DEEPEN ~ k.~¢J9 GAS ~ SINGLE ~ MULTIPLE ~LL ~ OTHER ~NE ~ ~NE la. TYPE OF WORK b. TYPE OF WELL 2.NAME OF OPERATOR Atlantic Richfield Company 3.ADDRESS OF OPERATOR P.O. Box 360 Anchora9e, Alaska 99510 4. LOCATION OF WELL At surface 323'N & 1736'W of SE cr Sec 2, TION,' R14E, UM At proposed prpd. zone (@ 8800'ss) 1206'N & 1450'W of SE cr Sec 2, TION, R14E, UM API #50-029-20459 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 6-15 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Fie]d-Prudhoe 0il 11. SEC.,T, R., M., (BOTTOM Pool HOLE OBJECTIVE) Sec 2, TION, R14E, UM 13.' DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. , .,. . ,~ . .:.. Approximately 4 miles NW of Deadhorse .-.. 14. BOND INFORMATION: r~E Statewide s~tya,d/orNO. Federal.: Insurance Co..#80l 1-38-40 15. DISTANCE FROM PROPOSED * . , i · LOCATION TO NEAREST ' PROPERTY OR LEASE LINE, FT. . : 1206 '~ (Also to nearest drig, unit~ if any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. _+264:0 21. ELEVATIONS (Show whether DF, RT, CR, etc.) I]i ' No. OF ACRES IN LEASE .. .. 2560 PROPOSED DEPTH . : 9325' _+TVD 64' RKB, 38' Pad Elevation (Gravel) 23 ~ pROPOSED. CASING AND CEMENTING PROGRAM Amount .$100,000 17. NO.ACRES ASSIGNED TO THIS WELL .~ .. 160 20. ROTAR5/ OR CABLE TOOLS Rotary 22. APPROX. DATE WORK. WIL, L START 7/]/80 SIZE OF HOLE SIZE OF CASING WEIGHT pER FOOT , GRADE . SETTING DEPTH Quantity of ~ement · 32" 20" 94# .~. .H~40~ llO'.-+MD 300 sx Permafrost II to.surface 17-1/2" 13-3/8" 72# L-80 2700'_+MD Circ to surface - Approx 5500 CF 12-1/4" . 9-5/8" 47~ 80&95 9518'+MD 1500'+ cmt column on 1st stage (annrn× lOfl13~×~ nlu.q 3tiff'+ cnlumr 6n' 2nd stage (~p~rox 300sx). Atlantic Richfield Co. _:prOposes,to..directiona!ly drill this well to +9518'MD, +9325'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 & operationally tested each trip. A string of 5½" 17# L-80 tubing, packer & 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 inter- vals within the Sadlerochit interval will be perforated & reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wire- line work. Well will be flowed to production facilities during perforating & testing. The downhole safety valve will be installed & tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dffectionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program. 24. I hereby certL[v~hat the Fq~going i~i['rue and Correct CIlfis space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] YES ~NO DIILEC~IONAL SURVEY REQUIRED / I~ES [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG ~ [] YES O OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO. gO- 3'1.-. APPROVAL DATE APPOVED BY ~~--~~~ TITLE. Ch~irllk311 BY OnD~c~OF~ C~dl~i$~ll~N *See Instruction On Reverse Side February 20, 1980 DATE, 02/20/80 ~,_Wf~-~-''~'// '~ \\¥ tAT = 70°14~30.344'' ~ // ~ ' LONG'= 148°30'08°033" ', y~ ~,\ W~L~ ~o Y: ~,~o,~.~ ff ~ XXX ' X = 685,4~3.29 ~,~ LONG = 1~8°30~O8.8~O'' ~ ,,~ ~ ~_~ ~,~ X = 68~,382.59 S I~~ "~' ~,~ ~ LAT = 70°14~32.638'' ~ ~ ~ . ~ WELL ~12 Y = S,gbO,601o13 ~ 14~_%~170~ ~ -- X = 685,351.97 ~,~ ~ ~',~ ~ ~A~ = 7o°,~'~8~'' ~ ~ .~', ~..._.~,flx~ ~o.~: ~8°~o'~Oo~S~'' ~ ~ ~ ~F LAT = ~ IO~.15~5' ~ WELL ~14 Y = ~ ]-~ _. ~Y LAT = 70°]'~36,080'' q 15~2' ~ X ~ ~'~ , WELL //15 Y = 5,9~0,9~9.01 ~ ~ /~-~ LAT = 70°14~37o227'' ~ ~/ WELL ~16 Y = 5,9~1,065.~1 ~ ~/ x = 685,229.]7 ~ ~ LAT = 70°1~ ~]8.]79'' ~ /TION)~I~E~., LONG = 1~8°30~1~.69~'' ~~L.:.~-.:7~': "'"~-'~:'??~' I HEREBY CERTIFY THAT I AH ;~-~'L ' ~ ':..~.].' "'? · PROPERLY REGISTERED AND LICENSED ~]']~/~ ~-'?' ~.' :'" -]:~::" .. TO PRACTICE LAND SURVEYING IN ~:-~; ': e ......... ,~E STATE OF ALASKA AND THAT ~'~ .,i.,,...'. ·, ./ .... '-::-~*~:..~ IS PLAT REPRESENTS AN AS- ~ ~:~:~ '"-~' ~ ~j~ .. :.~.~?L:F.¥i:~ ' BUILT SURVEY HADE BY HE, AND ~) ~'~'"" ';:; - :,~- '~-' ' '" : THAT ALL DIMENSIONS AND OTHER . ~ :. -'" ~ . ... ..... DETAILS ARE CORRECT, AS OF: A~,~,.~.~.,..~ -: :~ ";:~":: · :.' ~ '"' "'" DATE 9/2~/7~ D.~. 6, WELL6 ~-I~ A~' ~UILT All~nlicRichfieldCompan~ ~ DATE: DRAWING No: ~O~TH AME~ICA. P~ODUCI.~ DIVlSlO~ ALASKA mST~CT- P~UDHOE BAY CHECK LIST FOR NEW WELL PERMITS l. Is the permit-fee attached .......................................... ~ 2. Is well to be located in a defined pool ............................. ~_~ 3. Is a registered survey plat attached ................................ ~ 4. Is well located proper distance from property line .................. ~ 5. Is well located proper distance from other wells .................... r;D~Z No Remarks Lease & Well No. Item (1) Fee Ap~rov.e Date (2) Loc. ~__ 6. Is sufficient undedicated acreage available in this pool ............ ~ 7. Is well to be deviated ................................ ~ ............... y,t~. 8. Is operator tt~ only affected party .................................. ;~z 9. Can pemt be approved before ten-day wait .......................... ~t~ .0. Does operator have a bond in force .................................. 1. Is a conservation order needed ...................................... (3) / .2. Is administrative approval needed ................................... .3. Is conductor string provided ................................. ~ ...... ~ L6. L4. Is enough cement used to circulate on conductor and surface ......... ~ L5. Will cement tie in surface and intermediate or production strings ... ~ Will cement cover all known productive horizons ..................... ~ (4) Casg. ~ 17. Will surface casing protect fresh ~ter zones ....................... ~ 18. 19. Will all casing give adequate safety in collapse, tension and burst.. Does BOPE have sufficient pressure rating - Test t© ~'~OO psig .. Approval Reccmmended: (5) Additional Requirements: Engin~ring: rev: 12/12/79 Well Histoey 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 APPE .N. DIXi No special'effort has been made to chronologically organize this category of information. HIGH RESOLUTION DIPMETER CLUSTER LISTING ATLANTIC RICHFIELD CO. PRUDHOE BAY NORTH SLOPE , ALASKA D.S. 6-15 RUN NO. ONE JOB NO. CLUSTER RESULTS ONLY 3710 8FT. CORR. - 2 FT.. STEP 30 DEG. X2 SEARCH ANGLE ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 1-FILE ~ FORMATION , BOREROLE * QUAL. · .................. * .................................. * INDEX DEPTH * DIP DIP , DEV. DEV. DIAM ~IAM , 8EST , AZI. * AZI. 1-3 2-4 * :A *****~,,********~#~, 8640 6,1 211 6.9 81 13.1 15.9 8642 2.8 265 6.8 77 13.4 16.2 8644 1.9 268 6.7 77 13.4 16.2 8646 4.,1 275 6.5 78 13.4 16.5 8648 7.,5 230 6.5 79 13.0 16.1 8650 6.4 80 12.2 15.1 8652 6.3 81 11.6 14.0 8654 6.2 80 .11.0 12.6 8656 6.1 80 10.8 12.0 8658 2.,8 256 6.0 79 10.5 11.6 8660 4.3 273 6.1 79 10.0 10.9 8662 3.,5 224 6.1 80 9.6 10.4 8664 10.~8 259 6.2 79 9.1 9.8 8666 14.0 217 6.3 79 8.8 9.5 8668 7.3 225 6.4 77 8.8 9.4 8670 13.,5 210 6.4 75 8.6 9.4 8672 8.9 219 6.4 76 8.5 9.3 8674 11.6 201 6.3 77 8.3 9.3 8676 8..8 240 6.2 79 8.4 9.3 8678 7,1 233 6.0 78 8.4 9.3 8680 8.9 252 5.9 78 8.4 9.3 8682 10.9 263 5.9 77 8.4 9.3 8684 18..1 276 5.9 76 8.4 9.3 8686 16.4 274 5.9 77 8.5 9.4 8688 17.~7 273 5.9 77 8.5 9.4 8690 22.1 276 5.8 77 8.5 9.4 8692 15.9 275 5.7 77 8.6 9.4 8694 14..1 275 5.7 77 8.6 9.4 8696 14.,1 274 5.5 76 8.7 8698 5.4 76 8.7 9.4 8700 5.4 78 8.7 9.5 8702 5.4 78 8.8 9.5 8704 5.4 79 8.8 9.5 8706 5.5 80 8.8 9.5 8708 16.9 276 5.5 79 8.8 8710 19.9 277 5.4 80 8.8 9.5 8712 15.~7 268 5.4 79 9.0 9.6 8714 5.3 79 9.0 9.6 8716 14.3 301 5.3 80 9.0 9.6 8718 5.3 79 9.0 9.6 ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 2-FILE 2 * FORMAIION * BO~EH6LE * QUAL. * .................. ~ .................................. ~EPTH * DIP DIP , DEV. DEV. DIAM DIA~ , BEST . AZI. * AZI. 1-3 ************************************************************************* S720 5.2 80 8.9 9.6 8722 10.3 273 5.1 81 8.9 9.5 D 8724 7.9 257 5.2 80 8.8 9.4 B 8726 8.9 267 5.2 $1 8.7 9.3 D 8728 7.9 271 5.3 80 8.6 8730 7.3 276 5.3 81 8.6 9.3 D 8732 6.5 260 5.3 81 8.6 9.3 D 8734 14.8 219 5.3 79 8.7 9.3 D 8736 5.3 80 8.6 9.3 8738 5.4 81 8.7 9.2 8740 5.5 80 8.6 · B742 19.7 201 5.4 83 8.5 9.2 D 8744 5.4 84 8.4 9.2 8746 8..5 226 5.3 81 8.3 8748 15.0 264 5.3 81 8.2 9.1 D 8750 16.0 266 5.3 81 8.2 8.9 B 8752 15.4 267 5.3 82 8.1 8.7 D 8754 16.1 250 5.2 84 8.0 8.4 D 8756 27.~7 321 5.2 85 8.0 8.2 D 8758 22.9 165 5.2 85 7.9 8760 5.2 85 7.9 8.0 8762 22.3 335 5.2 85 7.9 8.0 D 8764 23..1 3~9 5.2 85 7.9 8.0 D 8766 21.9 328 5.2 84 7.9 8.0 D 8768 23'5 325 5.2 84 7.9 8.0 B 8770 23.2 326 5.~ 84 7.9 8.0 D 8772 22.8 ~50 5.1 85 7.9 8.0 D 8774 5.1 85 7.9 8.0 8776 20..2 ~30 5.0 85 8.0 8.1 D 8778 22.8 131 5.0 85 8.0 8780 19~7 ~30 5.0 84 8.0 8782 20.0 129 5.0 83 8.0 8784 4.6 65 5.0 82 8.0 8.1 C 8786 4.0 89 5.0 82 8.0 8.0 A 8788 2..5 306 4.9 83 8.0 8.0 A 8790 1.~7 274 4.9 83 8.1 8.~ A 8792 2.2 283 ~.9 83 8.1 8.1 A 8794 4..5 297 4.9 83 8.1 8796 1.17 308 4.9 84 8.~ 879S 2.1 310 4.9 84 8.0 ATLANTIC RICHFIELD CO. D.$. 6-15 PAGE 3-FILE ************************************************************************* ~ FORMATIO~ ~ BO~EHOLE * ................... ~ .................................. DEPTH , ~IP DIP * DEV. DEV. DIA~ DIA~ , BEST ~ AZI. ~ AZI. 1-3 2-4 ************************************************************************* 8800 1..8 317 4.9 85 8.0 8.1 A 8802 0~7 311 4.8- 84 8.0 8.1 A 8804 1.0 185 4.8 84 8.0 8.2 A 8806 1.4 181 4°8 84 8.0 8.1 A ~808 3.6 203 4.8 84 8.0 8.1 8810 7~7 204 4.8 85 8.0 8.1 8812 5.3 245 4.8. 84 8~0 8.1 C 8814 11.3 182 4.8 84 8.0 8.1 8816 11.,5 183 4.8 85 8.0 8.1 A 8818 15..5 174 4.8 84 8.0 8.1 8820 14,2 184 4.8 84 7.9 8.0 A 8822 16.~8 261 4.8 84 7.9 8.0 D 882~ 16.:7 ~60 4.8 83 7.9 8.0 D 8826 16.,7 260 4.8 83 7.9 8.0 D 8828 16.9 ~60 ~.8 83 7.9 8.0 D 8830 4.8 83 7.9 8.0 8832 17,1 125 ~.7 83 7.9 8.0 8834 16.8 126 4.7 83 7.9 8.0 8836 16.9 125 4.6 82 7.9 8.0 A 8838 16.9 125 4.6 82 7.9 8.0 A 8840 1.4 215 4.6 81 7.9 8.0 C 8842 3.1 259 4.6 82 7.9 8.0 A 8844 2.9 '93 4.6 82 7.9 8.0 A 8846 2.9 97 4.6 82 7.9 8.0 A 8848 2.1 105 4.6 82 7.9 8.0 A 8850 1.2 79 4.6 83 7.9 8.0 A 8852 2..1 253 4.6 84 7.9 8.1 D 8854 2.i7 274 4.6 85 7.9 8.0 D 8856 4.4 273 4.6 86 7.9 8.0 0 8858 4.6 283 4.6 86 7.9 8.0 D 8860 42.6 223 4.6 85 7.9 7.9 D 8862 42.~7 223 4.6 84 7.9 7.9 D 8864 2.~2 69 4.6 84 7.9 7.9 D 8866 42.0 310 4.6 84 7.9 7.9 8868 32.~7 99 4.6 84 7.9' 7.9 D 8870 33.1 99 4.6 85 7.9 7.9 D 8872 56~7 56 4.6 86 7.9 7.9 D .8874 6.8 71 4.6 87 7.9 7.9 A 8876 6.8 71 4.6 87 7.9 7.9 A 8878 6.9 71 4.6 87 7.9 7.9 A ************************************************************************* ATLANTIC RICHFIELD CO. D.$. 6-15 PAGE 4-FILE ********~***********~***********************************,*************** , , FORMATION ~ ~O~EHOL£ * QUAL. , , .................. , .................................. * INDEX ~ DEPTH , DIP DIP , DE¥ * * AZI. , ************************************ , 8880 6.17 71 4.6 88 ~ 8882 4.5 87 ~ 8884 4.5 87 , 8886 6.2 59 4.5 86 * 8888 6~7 84 4.5. 85 * 8890 6.3 86 4.6 85 , 8892 6.5 87 4..6 85 m 8894 4.6 85 ~ 8896 10~I 76 4.6 85 * 8898 10.4 76 4.6 84 * 8900 10.4 75 4.6 83 * 890~ 10.~5 73 4.6 83 , 890~ 4.5 83 , 8906 10..5 17 4.5 84 ~ 8908 11.1 4 4.4 84 ~ 8910 11.0 4 4.4 84 ~ 8912 10.9 4 4.4 84 * 8914 10.9 344 4.4 85 ~ 8916 8.4 86 4.4 85 * 8918 8.0 97 4.4 85 * 8920 7.9 98 4.4 85 * 8922 9..5 48 4.4 84 * 8924 9.15 49 4.4 $5 * 8926 10..1 64 4.4 85 * 8928 4.4 86 * 8930 4.4 8.6 * 8932 4.4 86 * 8934 4.4 86 ~ 8936 10.8 130 4.4 86 , 8938 10.9 127 4.4 85 * 8940 ~1.4 I46 4.4 85 ~ 894~ 11.2 128 4.4 85 , 8944 4.4 85 ~ 89~6 21.6 211 4.4 85 , 8948 21.8 208 4.4 85 * 8950 24.0 209 4.4 85 * 8952 20.1 211 4.4 85 * 895~ 4.4 85 * 8956 4.4 85 ~ 8958 4.4 85 ************************************************** . DEV. DIAM DIA~ , BEST , AZI. !-3 2-4 , :A , ************************************* 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 8.0 7.9 8.0 7.9 8.0 8.0 8.0 7.9 8.0. 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 8.0 7.9 8.0 7.9 8.0 7.9 8.0 7.9 8.0 7.9 8.0 7.9 8.0 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 *********************** * * FORMATION , * DEPTH , DIP DIP , D * * AZI. , ********************************** ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 5-FILE 2 ************************************************************************* BOREHOLE , GUAL. , .............................. , INDEX , EV. DEV. DIA~ DIAM * BEST , AZI. 1-3 2-4 , =A * *************************************** * 8960 4.4 85 7.9 7.9 * * 8962 4.4 85 7.9 7.9 * * 8964 25.~7 307 4.4 85 7.9 7.9 D * * 8966 4.4 86 7.9 7.9 * 8968 4.4 85 7.9 7.9 * * 8970 19.,5 317 4.4 85 7.9 7.9 D * 8972 4.4 85 7.9 7.9 * 8974 4.4 86 7.9 7.9 * * 8976 4.3 86 7.9 7.9 * 8978 22.8 303 4.3 86 7.9 7.9 D * * 8980 22.,5 302 4.3 86 7.9 7.9 D * * $982 13.8 99 4.3 86 7.9 7.9 D * * 8984 15.8 158 4.3 86 7.9 7.9 D * ~986 17.3 165 4.3 87 7.9 7.9 D * 8988 9.2 181 4.2 86 7.9 7.9 D * 8990 10.~ 156 4.2 86 7.9 7.9 D * 8992 1t.6 154 4.2 85 7.9 7.9 D * 899~ ll.O 138 4.2 85 7.9 7.9 D * 8996 4.2 $6 7.9 7.9 * 8998 4.2 86 7.9 7.9 * * 9000 2.3 211 4.2 87 7.9 7.9 D * 9002 1.~7 183 4.2 87 7.9 8.0 C * 9004 1.~7 200 4.2 87 7.9 8.0 A * * 9006 0.9 212 4.2 87 7.9 8.0 A * 9008 0.~7 138 4.2 88 7.9 8.0 C * 9010 16.4 337 4.2 88 7.9 7.9 D * 9012 16.3 336 4.2 89 7.9 7.9 D * * 90i~ 17.~5 339 4.2 89 7.9 7.9 D * * 9016 15.2 318 4.2 90 7.9 7.9 O * 9018 11.2 323 4.2 90 7.9 7.9 D * * 9020 11.2 109 4.2 90 7.9 7.9 B * 9022 4.2 90 7.9 7.9 * * 9024 11.0 89 4.2 90 7.9 7.9 D * * 9026 17~2 337 4.1 90 7.9 7.9 D * * 9028 4.1 90 7.9 7.9 * 9030 4.0 90 7.9 7.9 * * 9032 4.0 90 7.9 7.9 * 9034 4.0 90 7.9 7.9 * * 9036 4.0 90 7.9 7.9 * * 9038 4.0 90 7.9 7.9 ************************************************************************* ATSANTiC RICHFIELD CO. D.S. 6-15 PAGE 6-FISE ************************************************************************* * FORMATION , BOREHOLE , QUAL. *---- .............. , .................................. , INDEX DEPTH * DIP DIP , DEV. DEV. DIAS DIAS * BEST * AZI. , ************************************ 9040 4.0 9042 4.0 9044 31.17 79 4.0 9046 31.~7 81 4.0 9048 32.4 87 '4.0 9050 4.0 9052 4.0 9054 4.! 9056 9.3 27 4.1 9058 7,8 27 4.1 9060 4'1 22 4.1 9062 3.8 20 4.1 9064 3.9 19 4.1 9066 10.4 326 4.1 9068 10.,5 325 4.0 9070 10.~5 328 4.0 9072 4.0 9076 4.0 9076 4.0 9078 4.0 9080 4.0 9082 9084 4.1 9086 4.1 9088 4.1 9090 4.0 9092 4.0 9094 4.0 9096 4.0 9098 9100 4.0 9102 4.0 9!04 4.0 9106 4.0 9108 4.0 9110 4.0 9112 4.0 911~ 4.0 9116 4.0 9118 4.0 AZI. i-3 2-4 * =A ************************************* 89 7.9 7.9 89 7.9 7.9' .89 7.9 7.9 D 89 7.9 7.9 O * 89 8.0 8.0 D , 90 8.0 8.0 g0 8.0 8.0 90 8.0 8.0 , 90 7.9 7.9 O * 90 8.0 8.0 D * 90 8.0 8.0 B * 90 8.0 8.0 B 90 8.0 8.0 B , 89 8.0 8.0 D * 88 7.9 8.0 O 88 7.9 8.0 D 86 7.9 8.0 * 85 8.0 8.0 * 85 8.0 8.0 , 84 8.0 8.0 83 8.0 8.0 , 81 8.0 8.0 , 78 8.0 8.0 , 75 8.0 8.0 * 74 8.0 8.0 * 73 8.0 8.0 , 72 $ .0 8.0 * 72 8.0 8.0 71 8.0 8.0 * 72 8.0 8.0 , 71 8.0 8.0 * 71 8.0 7.9 71 8.0 7.9 70 7.9 7.9 70 7,9 7.9 69 7.9 7.9 68 7.9 7.9 67 , 7.9 7.9 68 7.9 7.9 * 69 7.9 7.9 * ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 7-FILE 2 ************************************************************************* * * FORMATION' , BOREH. OLE , QUAL. * * * .................. * ................... - .............. * INDEX * , DEPTH , DIP DIP , DEV. DEV. DIA~ DIAM , BEST , * * AZI. , AZI. 1-3 2-4 , :A , ************************************************************************* * 9120 4.0 70 7.9 7.9 * 9122 66..5 312 4.0 71 7.9 7.9 D * * 9124 4.0 71 7.9 7.9 * * 9126 64..5 307 4.0 71 7.9 7.9 B * * 9128 64.,2 307 4.0 71 7.9 7.9 B * * 9130 60.-7 308 4.0 71 7.9 7.9 B * * 9132 4.0 72 7.9 7.9 * 9134 4.0 72 7.9 7.9 * * 9136 29.3 325 4.0 72 7.9 7.9 D # * 9138 28.9 324 4.0 71 7.9 7.9 D * * 9140 26.,1 317 4.0 69 7.9 7.9 D * * 9142 4.0 69 7.9 7.9 * 9144 4.0 70 7.9 7.9 * 9146 4.0 70 7.9 7.9 * 9148 4.0 71 7.9 7.9 * 9150 4.0 71 7.9 7.9 * * 9152 4.0.4 19 4.0 71 7.9 7.9 D * * 9154 37.8 17 4.0 71 7.9 7.9 B , * 9156 4.0 70 7.9 7..9 , 9158 37.4 20 4.0 70 7.9 7.9 D , * 9160 39,1 25 4.0 70 7.9 7.9 D * 9162 34.:5 15 4.0 70 7.9 7.9 D * * 9164 4.0 70 7.9 7.9 * * 9166 4.0 70 7.9 7.9 * 9168 40.9 21 4.0 70 7.9 7.9 D * *. 9170 36..8 7 4.1 70 7.9 7.9 D * 9172 4.1 70 7.9 7,9 * 9174 37.,1 175 4,1 69 7.9 7.9 D , * 9176 4.1 69 7.9 7.9 * 9178 27.i7 177 4.0 70 7.9 7.9 D * * 9180 4.0 70 7.9 7.9 * * 9182 30~7 175 4.0 71 7.9 7.9 D * * 9184 32.3 170 4.0 72 7.9 7.9 D * * 9186 30.9 174 4.0 72 7.9 7.9 D * * 9188 27.2 169 4.0 72 7.9 7.9 D * * 9190 4.0 72 7.9 7.9 * * 9192 30.9 20 4.0 72 7.9 7.9 D * 9194 30.9 20 4.0 72 7.9 7.9 D * * 9196 4.0 72 7.9 7.9 * * 9198 1..5 179 4.0 73 7.9 7.9 O * ************************************************************************* ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 8-FILE ~ FORMATION ~ BORE~OLE ~ QUAL. ~ .................. ~ .................................. ~ INDEX DEPTH ~ DI~ DIP ~ DEV. DEV. DIAM DIAM ~ 8EST ~ AZI. ~ AZI. 1-3 2-4 ~ =A 9200 62,8 283 4.0 73 7,9 7,9 D 9202 62,6 283 4.0 72 8,0 .7.9 D 9204 3,.! 266 4,0 72 8,0 7,9 9206 24,8 2! 4.0 72 8,0 7.9 9208 26.3 15 4,0 73 8,0 7,9 D 92~0 22,.5 25 4,0 74 7,9 7.9 D 9212 1.9 34 4,0 74 7,9 7.9 A 9214 2.3 89 4.0 7~ 7.9 7.9 A 921b 3.6 57 4.0 72 7.9 7.9 A 9218 2.2 5 4.0 72 7.9 7.9 A 9220 37.7 302 4.0 71 7.9 7.9 D 9222 38.0 302 4.0 71 7.9 7.9 D 9224 35.6 304 4.0 7~ 7.9 7.9 D 9226 73,2 251 4,0 71 7,9 7.9 D 9228 4.0 7~ 7.9 7.9 9230 4.0 ~! 7.9 7.9 9232 3.6 21! 4.0 71 7.9 7.9 9234 7..8 303 4.0 72 8.0 7.9 A 9236 8.2 303 4.0 73 8,0 7,9 A 9238 9..4 280 4.0 74 8.0 7,9 A 9240 7,9 147 4.0 74 ~.0 8.0 A 9242 i3.0 131 4.0 74 8.0 8.0 A 9244 '~3,9 128 4.0 74 8.0 8.0 A 9246 10..1 132 4,0 73 8.0 8.0 A 9248 38.6 112 4.0 73 8.0 7.9 C 9250 38.3 11~ 4.0 73 8.0 7.9 C 9252 39.6 112 3.9 73 8.0 7,9 C 9254 38.6 114 3.9 74 8.0 7.9 C 9256 3,9 74 8.0 7.9 9258 3.9 73 8,0 7.9 9260 3.9 73 8.0 8,0 9262 3.9 73 8.0 8.0 9264 3,9 73 8.0 8.0 9266 3.9 72 8.0 8.0 9268 3.9 72 $.0 8.0 9270 4.0 71 8.0 8.0 9272 4.0 72 8.0 8,0 9274 4.0 73 8.0 8.0 9276 4.0 74 8.0 8.0 9278 4.0 75 8.0 8.0 9280 9282 9254 2,1 197 9286 2.8 253 9288 2.9 250 9290 4,2 252 9292 3,9 257 9294 7 .~0 159 9296 7,2 159 929~ 8.~! 155 9300 12.4 163 9302 10,5 136 9304 26..8 199 9306 26,3 203 9308 27.:5 207 9310 29.6 209 93i2 9319 19.3 188 9316 23,4 200 9318 22,0 227 9320 9322 1.2 140 9324 2.5 118 9326 2,5 122 9328 2,6 159 9330 2,9 86 9332 2,2 114 9334 21,1 66 9336 20.2 62 9338 19,9 50 9340 9392 9344 19,5 72 9346 10,6 102 9348 9.0 116 9350 12,1 116 9352 14,3 113 9354 4,3 124 9356 2,~7 88 9358 4,0 232 ATLANTIC RICHFIELD CO, D,S, 6-15 PAGE 9-FILE ~ FORMATION ~ BOREHOLE ~ (~UAL,' ~ ~ .................. ~ .................................. ~ INDEX DEPT~ ~ DIP DIP ~ DEV, DEV, DIA~ DIAN ~ BEST ~ AZI, ~ AZI, 1-3 2-4 ~ =A 4.0 75 8,0 8,0 3,9 75 8,0 8,0 3,9 75 8,0 8,0 A 3.9 75 8.0 8,0 A 3,9 74 8,0 8.0 A 3.9 75 B,0 8.0 A 3,9 75 8,0 8,0 A 3.8 74 8,0 8.0 D 3,8 73 8,0 8,0 B 3,8 72 8.0 8,0 B 3.8 72 8,0 8.0 D 3,8 73 7.9 7,9 0 3.8 73 7,9 7,9 B 3,8 74 7.9 7,9 B 3.8 74 7,9 7,9 B 3.8 74 7.9 7,9 3.8 74 7,9 7,9 3,8 74 7,9 7,9 D 3,8 74 7,9 7,9 D 3.8 74 7.9 7.9 D 3,8 74 7,9 8.0 3,8 74 8,0 8,0 A 3.8 74 8,0 8.0 A 3,8 74 8,0 8.0 A 3.8 74 8,0 8.0 A 3,8 73 ~,0 8,0 C 3.8 73 7,9 7,9 C 3,8 73 7,9 7.9 D 3,8 72 7,9 7,9 D 3,7 72 7,9 7.9 D -3,7 72 8,0 7.9 3,6 72 7,9 7,9 3,6 72 8.0 7,9 D 3,6 72 8.0 7,9 D 3,6 73 7,9 7,9 D 3,6 74 8.0 7.9 D 3,6 73 8,0 8.0 D 3,6 71 8~,0 8,0 B 3,6 69 8,0 8,0 B 3,6 68 8.0 8.0 D ATLANTIC RICHFIELD C~. D.S. 6-15 PAGE 10-FILE 2 ************************************************************************* * * FORMATION * BOREROLE * QU~L. ~ , .................. , .................................. * INDEX * , DEPTH , DIP DIP , DEV. DEV. DIAM DIAM , BEST ~ * AZI. , AZI. 1-3 2-4 * :A ************************************************************************* 9360 3.0 58 3.6 67 8.0 8.0 D 9362 21.3 223 3.6 68 8.0 8.0 D 9369 21'.0 223 3.6 68 8.0 8.0 D 9366 3.6 69 7.9 7.9 9368 3.6 69 8.0 8.0 9370 3.6 69 B.0 8.0 9372 3.6 70 8.0 8.0 9374 29.9 326 3.6 70 8.0 8.0\ 937~ 3.6 71 8.0 8.0 9378 3.6 72 8.0 8.0 9380 26.8 131 3.6 73 8.0 8.0 D 9382 26.9 134 3.6 72 8.0 8.0 D * 9384 26~7 136 3.6 72 $.0 · 8.0 D 9386 0-.~5 3-42 3.6 72 8.0 8.0 C 9388 1.9 95 3.6 71 8.0 8.0 A 9390 0.3 86 3.6 71 8.0 8.0 A 9392 0.4 61 3.6 70 8.0 8.0 A 9394 0..5 85 3.6 69 8.0 8.0 A 9396 18.4 103 3.6 68 8.0 8.0 D 9398 0.17 324 3.6 69 8.0 7.9 C 9%00 7.0 3'57 3.6 69 7.9 8.0 A 9402 5.9 329 3.6 69 $.0 8.0 A 940~ 6.0 328 3.6 70 8.0 8.0 A * 9406 8.4 342 3.6 70 8.0 8.0 C * 9408 3.6 70 8.0 8.0 9410 3.6 71 8.0 8.'0 * 9412 1'.9 103 3.6 70 8.0 8.0 A 9416 3.0 22 3.6 71 8.0 8.0 A 94i~ 2.6 25 3.6 72 8.0 8.0 A 9418 0.9 38 3.6 72 8.0 8.0 A 9620 1.4 37 3.5 72 8.0 8.0 A 9422 1.8 235 3.5 72 8.0 8.0 C 9424 4..8 254 3.5 7~ 8.0 8.0 C 9426 2.0 164 3.5 73 8.0 8.0 A 9428 2.8 133 3.5 73 8.0 8.0 A 9430 2.3 i44 3.4 73 8.0 B.0 A 9432 2.2 136 3.4 72 $.0 8.0 A * 9434 2,4 114 3.4 72 ~.0 8.0 A 9436 ~.3 1.45 3.4 72 8.0 8.0 A 9438 1.6 86 3.4 7~ 8.0 8.0 A , ATLAS!TIC RICHFIELD CO. D.S. 6-15 PAGE ll-FILE ~ FURMATIUN ~ BOREHOLE * .................. ~ .................................. DEPTH , DIP DIP * DEV. DEV. DIA~! DIA~ * AZI. ~ AZI. 1-3, 2-4 9440 ! .9 80 3.4 73 8.0 8.0 9442 i .9 71 3.4 73 8.0 8.0 A 9444 1..7 99 3.4 74 8.0 8.0 A 9446 3.5 250 3.4 75 S.0 8.0 9448 @.0 257 3.4 76 8.0 8.0 D 9450 10.3 255 3.4 76 8.0 8.0 9452 11.9 261 3.4 75 8.0 8.0 D 9454 11.8 84 3.4 74 8.0 8.0 D 9456 3.4 73 8.0 8.0 9458 0.8 190 3.4 73 8.0 8.0 D 9460 2.0 174 3.4 73 8.0 8.0 A 9462 1.9 166 3.4 74 8.0 8.0 A 9464 2.0 147 3.3 76 8.0 8.0 A 9466 }.8 145 3.3 77 8.0 8.0 A 9468 3.5 143 3.3 78 8.0 8.0 A 9470 1..8 172 3.4 79 8..0 8.0 9472 i.~7 175 3.4 79 8.0 8.0 A 9474 1.8 177 3.4 79 8.0 8.0 A 9476 2.2 170 3.4 79 8.0 8.0 A 9478 2.2 163 3.4 79 8.0 8.0 A 9480 2.3 163 3.4 79 8.0 8.0 A 9~82 3.4 140 3.4 78 8.0 8.0 A 9484 3.4 137 3.4 77 8.0 8.0 A 9486 3.3 144 3.4 77 8.0 8.0 C 9488 2.9 142 3.4 76 8.0 8.0 A 9490 2.~7 141 3.4 76 8.0 8.0 A 9492 3..1 150 3.4 76 8.0 8.0 A 9494 3.9 150 3.4 76 8.0 8.0 9496 4..5 147 3.4 77 8.0 8.0 A 949~ 5.0 153 3.4 77 8.0 8.0 A 9500 5.3 148 3.4 77 8.0 8.0 A 9502 5.8 143 3.4 76 8.0 8.0 A 9504 8.3 ~51 3.4 76 8.0 8.0 A 9506 17.3 146 3.3 75 8.0 ~.0 A 950~ 17.2 143 3.3 75 8.0 8.0 A 9510 3.2 75 8.0 7.9 9512 3.2 76 8.0 7.8 9514 3.2 78 8.0 7.8 9516 3.2 81 8.0 7.8 9518 5.3 14~ 3.2 82 8.0 8.0 C ATLANTIC RICHFIELD CC. D.$. 6-15 PAGE 12-FILE ~ FORMATION ~ BOREHOLE ~ QUAL. ~ .................. # .................................. ~ INDEX DEPTh ~ DIP DIP ~ DE¥. DEV. DIA~ DIAM ~ SEST ~ AZI. ~ AZI. 1-3 2-4 ~ =A 9520 4..5 146 3.2 84 8.0 8.0 A 9522 4.7 143 3.2 $3 8.0 7.9 A 9529 5.0 145 3.2 84 8.0 7.9 A DE~TH 86~0 8642 8644 8646 8648 8650 8652 8654 8656 8658 86b0 8662 8664 8666 8668 8670 8672 8674 8676 8678 8680 8684 8686 8688 8690 8692 869~ 8696 8698 8700 8702 8704 8706 8708 87~0 87~2 87t4 87~6 8718 ATSANT£C RICHFIESD CO. D.S. 6-15 PAG£. 1-FILE ************************************************************************* * FORMATION , BOREHOLE . DIP DIP , DEV. DEV. DIA~ DIA~ * AZI. * AZI. 1-3 2-4 ****************************************************** 5.8 244 1'.1 144 3.7 148 ~.~7 i18 23.8 79 11.2 ~81 19.1 104 21.6 106 16.6 99 6.9 202 6.1 202 9.0 201 10.8 202 9.9 206 9.:7 218 8.0 161 5.6 208 20 ..5 275 6.1.7 219 6.9 211 9.0 199 6.5 200 23.9 282 8.3 188 6.1 64 15.6 12.7 6.2 63 15.4 12.9 6.1 64 15.7 13.1 6.2 65 i6.3 13.3 6.1 66 16.7 13.6 6.0 67 15.8 12.8 5.9 67 14.9 12.0 5.8 . 69 13.3 11.3 5.8 70 11.8 10.5 5.9 71 11.3 10.4 5.9 71 10.8 10.1 5.9 69 ],0.1 9.5 5.9 69 9.7 9.1 5.9 68 9.4 8.8 5.9 70 9.2 8.6 5.8 71 9.2 8.5 5.8 70 9.2 $.3 5.7 71 9.1 8.2 5.7 73 9.1 8.2 5.6 77 9.1 8.2 5.5 84 9..2 8.3 5.5 86 9.2 8.3 5.5 83 9.2 8.3 5.5 78 9.2 8.4 5.5 74 9.3 8.4 5.4 73 9.3 8'.4 5.4 74 9.2 8.4 5.3 79 9.2 8.4 5.3 79 9.2 8.5 5.3 83 9.3 8.6 5.3 81 9.4 8.6 5.3 76 - 9.4 8.6 5.4 75 9.4 8.5 5.4 72 9.4 8.6 5.4 75 9.4 8.7 5.4 74 9.2 8.5 5.3 71 9.2 8.7 5.4 69 9.3 8.7 5.4 66 9.3 8.6 5.4 67 9.5 8.7 *OUAL. --, INDEX , BEST , =A D B B D D O D D D D D D D D D D D D D D D D ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 2-FILE 1 **************************************************#********************** * * FORMATION * BOPE~OLE , ~UAL. * . . .................. . .................................. . INDEX * , DEPT~ * EIP DIP , DEV. DEV. DIA~ DIAM , ~EST * * * ~ZI. * AZI. 1-3 2-4 * =A * ************************************************************************* 8720 5.4 68 9.5 8.7 * 8722 7.6 184 5.3 68 9.4 8.7 D * 8724 6.! 217 5.2 68 9.3 8.7 B * 8726 7.0 22~ 5.2 68 9.2 8.7 D * 8728 6.5 219 5.2 68 9.2 .8.7 D ~730 14.1 ~7 5.2 67 9.3 ~.7 D * 8732 11.0 22~ 5.2 66 9.4 8.7 D * 8734 10.7 216 5.2 65 9.4 8.5 D * 8736 7.0 278 5.2 63 9.3 8.5 D * 8735 5.3 64 9.3 8.4 * 8740 5.3 64 9.3 8.4 * 8742 5.3 64 9.3 8.4 * 8744 5.2 65 9.3 8.4 8746 5.7 239 5.0 68 9.2 8.3 D * 8748 7.8 238 4.9 75 9.~ 8.3 B * 8750 4.9 266 4.9 85 9.0 8.2 8752 8.6 257 5.0 94 8.8 8.1 B * 8754 14.~ 299 5.1 101 8.5 8.0 D * 8756 5.2 103 8.3 8.0 8758 5.3 100 8.1. 7.9 * 8760 8..8 84 5.3 94 8.0 7.9 D * 8762 7.9 121 5.2 90 8.0 7.9 D * 8764 ~.3 125 5.2 88 8.0 7.9 D ~766 8.2 ~24 5.2 89 8.0 7.9 D * 8768 4.4 126 5.1 94 8.0 7.9 D 8770 5.1 99 8.0 7.9 8772 5.0 99 8.0 7.9 * 8774 5.0 103 8.0 7.9 * 8776 5.0 104 8.1 7.9 * 8778 5.0 105 8.1 7.9 8780 4.9 107 8.2 8.0 * 878~ 4.9 105 8.~ ~.0 8784 4.8 99 8.~ 8.0 8786 15.1 204 4.8 87 8.1 8.0 D 8788 15.6 201 4.8 79 8.1 8.0 ~ * 8790 3.8 266 4.8 70 8.1 8.0 B 8792 0.6 42 4.8 67 8.2 8.1 B 8794 0.17 136 4.8 69 8.2 8.1 B , 8796 2.6 6 4.8 75 8.~ 8.! B * 8798 2.8 347 4.8 84 8.2 8.0 A * ATLANTIC RICHFIELD CO. D.S, 6-15 PAGE 3-FILk 1 , DEPTH * DIP DIP , DEV. DEV. D . * AZI. . AZI. 4.8 88 8.2 8.0 4.8 97 8.2 8.0 4.8 97 8.2 8.0 4.8 98 8.2 8.0 4.8 101 8.1 8.0 4.8 102 8.1 8.0 4.7 104 8..1 8.0 4.7 104 8.1 8.0 4.7 104 B.1 8.0 4.7 102 8.1 8.0 4.7 100 8.1 7.9 4.7 100 8.0 7.9 4.7 101 8.0 7.9 4.6 100 8.0 7.9 4.6 95 8.0 7.9 4.6 93 8.0 7.9 4.6 86 8.0 7.9 4.6 78 8.0 7.9 4.6 76 8.0 7.9 4.6 69 8.0 7.9 4.6 68 8.0 7.9 4,6 68 8.0 7.9 4.6 69 8.0 7.9 4.6 69 8.0 7,9 4,6 69 8.0 7.9 4,6 70 8.0 7,9 4,6 70 8.1 7.9 4.6 70 8.0 7.9 4.6 71 8.0 7.9 4.6 71 8.0 7.9 4,.6 71 7.9 7.9 4.6 72 7.9 7.9 4.6 74 7.9 7.9 4.6 76 7.9 7.9 4.5 77 8.0 7.9 4.5 77 8.0 7.9 4.5 77 8.0 7.9 4.5 76 8.0 7.? 4.5 75 7.9 7.9 4.4 75 7.9 7.9 * 8800 3.0 335 , 8~02 3.6 333 , 8804 2.6 353 * 8806 1..$ 52 , 8808 1.~5 32 ,' 8810 4.4 144 * 8812 1.1 194 * 8814 6.3 190 , 8816 5.3 203 ~ 8818 6.17 191 ~ 8820 8.6 190 * 8822 8-~ 42 , 8824 8,2 45 * 8826 8.3 44 * 8828 8.0 46 ~ 8830 8.,7 21 ~ 8832 9,9 7 . 8834 0.6 10 ~ 8836 0-5 279 * '8838 0.! 1~ , 8840 8,3 122 * 8842 2 .:7 234 * 8844 3.0 48 * 8846 2.4 61 ~ 8848 2.0 81 . 8850 0.8 166 . 8852 2.9 251 * 8854 4.4 244 , 8856 4,3 252 , 8858 7.3 153 ~ 8860 10.3 154 * 8862 8.1 146 * 8864 * 8866 * 8868 28.1 102 * 8870 64.4 341 , 8872 64,3 343 . 8874 15.2 80 ~ 8876 15.4 80 . 8878 15.,7 88 , QUAL. ..... * INDEX IA~ . BEST 2-4 , =A ************** A A A A A C C A C A D D D D C C C A A A A A A A A A A A B B D D D D A A A ATLANT1C RICHFIELD CO. D.S. 6-15 PAGE 4-FILE 1 ******************************************************,****************** * * FORMATION * BOREHCLE * QUAL. * * * .................. * .................................. * INDEX * * DEPTH * DIP DIP * DEV. DEV. DIAM DIAM * * AZI. * AZI. 1-3 ************************************************************** * * 8S80 15.9 88 * 88~2 , 8884 * 8S88 3.9 106 , 8890 4.2 113 * 8892 4.2 109 * 8894 4.2 109 * 8896 * 8898 10.9 65 * 8900 10.9 64 * 8902 11.0 64 * 8909 11.0 65 , 8906 14.9 , ~908 10.5 1 * 8910 5.8 328 , 8912 8.5 343 , 8914 9.3 347 * 89i6 13.6 80 * 8918 11.5 77 * 8920 10.6 79 * 8922 10.4 79 * 8924 8.9 58 * 8926 8.7 61 * 8928 * 8930 26,7 289 . 8932 26.~7 290 * 8934 27.2 293 , 8936 26.,5 290 , 8938 15..8 129 , 8940 18.1 143 ~ 8942 16.9 137 * 8944 16.8 126 , 8946 30.2 33 * 8948 30.1 33 * 8950 30.3 32 * 8952 30.3 33 * 8954 , 8956 , 8958 , BEST . =A *********** 4.4 74 7.9 7.9 A 4.4 74 7.9 7.9 4.4 74 7.9 7.9 4.4 75 7.9 7.9 4.4 75 7.9 7.9 A 4.4 79 7.9 7.9 C 4.4 81 7.9 7,9 C 4.4 81 7.9 7.9 C 4.4 82 7.9 7.9 4.4 82 7.9 7.9 C 4.4 81 7.9 7.9 C 4.4 81 7.9 7.9 C 4.4 79 7.9 7.9 C 4.4 79 7.9 7.9 C ~.4 83 8.0 7.9 A 4.4 88 8.0 7.9 A 4.4 92 8.0 7.9 A 4.4 92 8.0 7.9 A 4.4 87 8.0 7.9 C 4.4 85 7.9 7.9 A 4.4 88 7.9 7.9 A 4.4 96 7.9 7.9 A 4.4 97 7.9 7.9 C 4.4 96 7.9 7.9 C 4.4 92 7.9 7.9 4.4 91 8.0 7.9 D 4.4 93 8.0 7.9 D 4.4 97 8.0 7.9 D 4.3 94 8.0 ' 7.9 D 4.3 89 8.0 7.9 A 4.2 88 8.0 7.9 A 4.2 86 8.0 7.9 A 4.2 86 7.9 7.9 C 4.3 87 7.9 7.9 D 4.3 88 7.9 7.9 D 4.2 89 7.9 7.9 D 4.2 94 7.9 7.9 D 4.2 98 7.9 7.9 4.2 103 7.9 7.9 4.2 108 7.9 7.9 ATLANTIC RICHFIELD CO. D,S. 6-15 PAGE 5-FILE 1 8960 8962 8964 8966 8968 8970 8972 8974 8976 8978 8980 8982 ~9~ 8986 8990 8992 8994 8996 8998 9000 9002 9004 9006 9008 9010 9012 90Z6 9018 9020 9022 9024 9026 9028 9030 9032 9034 9036 9038 80REHOLE * DEV. DEV. DIA~ DIA~I ~ AZI, 1-3 ~UAL. INDEX BEST 28,2 353 4.2 11! 7,9 7.9 26,3 360 4,2 11~ 7,9 7,9 27,2 3 4,2 104 7,9 7,9 29,4 15 4.2 96 7,9 7.9 27,0 26 4,2 87 7,9 7.9 26 ,.5 29 4,2 8! 7,9 7,9 2(~,.! 27 4,2 80 7,9 7.9 26,:5 28 4,2 80 7,9 7,9 ' 20,8 120 4,2 ~! 7.9 7,9 20,2 12~ 4.2 82 7,9 7,9 4,2 82 7,9 7,9 16,2 ~34 4,2 82 7,9 7.9 ~6,4 133 4,2 82 7,9 7.9 17,0 138 4,2 82 7.9 7.9 17..~ ~50 4.2 82 7,9 7,9 18,6 156 4,2 82 7,9 7,9 18,8 118 4,2 83 7,9 7,9 20,4 115 4.2 84 7,9 7.9 4.2 85 7,9 7.9 4,2 86 7,9 7,9 4,! 87 7,9 7.9 4.1 87 7.9 7.9 ~8,.0 327 4,1 88 8.0 7.9 16..5 '330 4.2 90 8,0 7,9 16.4 332 4,2 91 8,0 7.9 4.2 91 7,9 7.9 4,2 9~ 7.9 7.9 ~5.2 351 4.2 90 7,9 7,9 18,8 353 4,2 89 7,9 7.9 4,2 88 7,9 7,9 4.2 86 7,9 7,9 4.1 86 7,9 7,9 39,3 ~28 4,1 86 7,9 7.9 4,2 86 7,9 7.9 4.2 85 7,9 7.9 4,1 84 7,9 7,9 4,1 83 7,9 7.9 30,5 239 4, ! 8~ 7,9 7,9 32..5 239 4,! 82 7,9 7,9 33.8 23~ 4,! 8! 7,9 7.9 D * D , B , D , D , D . D D D * D , D . D D , D D B D . D D , D , D , D D , D D , D , ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 6-FILE ,*************~********************************************************** , , FORMATION , BOBEHOLE , QUAL. * * .................. , .................................. , INDEX , DEPTH , DIP DIP * DEV. DEV. DIAM · * AZI. * AZI, 1-3 ***************************************************** , 9040 33.9 240 , 90%2 , 9044 ~ 9046 , 9048 * 9050 , 9052 , 9054 * 9056 , 9058 * 9060 , 9062 . 9064 22.8 296 * 9066 20.:7 286 * 9068 20.8 286 * 9070 22~1 280 , 9072 0.7 205 * 9074 28.6 296 * 9076 42,5 127 * 9078 , 9080 * 9082 * 9084 * 9086 ~ 9088 * 9090 22.3 266 * 9092 23.0 265 * 9094 23.0 261 , 909b , 9098 , 9100 * 910~ * 9104 , 9106 , 9108 * 9110 63.5 318 * 9112 * 9114 * 9116 * 9118 4.1 81 ~.1 80 4.1 80 4.2 79 4.2 77 4.2 77 ~.2 76 4.2 76 4.2 77 4.2 77 4.2 76 4.2 76 4.2 75 4.2 -74 4.2 75 4.1 75 4.1 76 4.0 77 4.0 78 4.0 78 4.0 77 4.1 76 4.1 76 4.1 77 4.1 80 ~.1 81 4.0 81 4.0 80 4.0 79 4.0 78 4.0 78 4.0 80 4.0 84 4.0 90 4.0 89 4.0 86 4.0 80 4.0 75 4.0 75 4.0 77 DIA~ , BEST 2-4 * :~ 7.9 7.9 D * 7.9 7.9 * 7.9 7.9 * 7.9 7.9 7.9 7.9 * 8.0 8.0 * 8.0 8.0 8.0 8.0 * 8.0 8.0 , 7.9 7.9 * 8.0 8.0 , 8.0 8.0 , 8.0 8.0 D 8.0 8.0 B , 8.0 8.0 B , 8.0 8.0 D * 8.0 8.0 D * 8.0 8.0 D , 8.0 8.0 D * 8.0 8.0 * 8.0 8.0 , 8.0 8.0 8.0 8.0 8.0 8.0 * 8.0 8.0 , 8.0 8.0 D 8.0 8.0 D 8.0 8.0 D 8.0 8.0 7.9 7.9 , 8.0 8.0 , 8.0 8.0 , 8.0 7.9 * 8.0 7.9 * 7.9 7.9 * 7.9 7.9 D 7.9 7.9 * 7.9 7.9 7.9 7.9 7.9 7.9 *********************** ATLANTIC RICHFIELD CO. D,S. 6-15 PAGE 7-FILE i FORMATION TH ~ DIP DIP , DEV. * ~ZI. * 9120 * 9122 ~ 9124 ~ 9126 , 9128 , 9130 , 9i32 ~ 9134 ~ 9136 * 9138 ~ 9140 ~ 9142 ~ 9144 * 9146 ~ 9148 ~ 9150 ~ 9152 , 9154 ~ 9156 ~ 9158 ~ 9160 , 9162 ~ 9164 * 9166 ~ 9168 ~ 9170 * 9172 * 917~ * 9176 * 9178 ~ 9180 ~ 9182 * 9184 * .9186 * 9188 * 9190 ~ 9192 ~ 9194 ~ 9196 ~ 9198 BOREt~OLE * QUAL. ....................... · INDEX DEV. DIA~ DIA~ , BEST AZI. ! -3 2-4 , mA 63.0 320 4.0 79 63..1 320 4.0 80 4.O 81 4.O 4.0 82 4.O 4.0 81 4.0 81 4.0 81 4.0 81 4.0 81 4.0 82 4.0 83 4.0 83 4.0 91 4.0 98 4.0 103 4.0 102 4.0 96 4.0 89 4.0 84 4.O 84 19.4 31 4.0 81 4.0 79 4.O 78 8.6 58 4.0 77 10.3 315 4.0 -77 13.8 356 4.0 80 13.2 '341 4..0 85 13.3 2 4.0 89 10.0 335 4.0 89 20.~7 41 4.0 86 4.O 82 13.8 81 4.0 79 i2.9 70 4.0 79 13.0 68 4.0 79 9.4 100 4.0 77 4.0 74 14.4 327 4.0 78 12.,5 324 4.0 77 7.9 7.9 D 7.9 7.9 8 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 * 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.g 7.9 7.9 * 7.9 7.9 7.9 7.19 7.9 7.9 7.9 7.9 * 7.9 7.9 * 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 7.9 D 7.9 7.9 7.9 7.9 7.9 7.9 D 7.9 7.9 D 7.9 7.9 D 7.9 8.0 B 7.9 8.0 B '7.9 '7.9 D 7.9 7.9 B * 7.9 7.9 7.9 7.9 D 7.9 7.9 D 7.9 7.9 D 7.9 7.9 D 7.9 7.9 * 7.9 7.9 D 7.9 7.9 D ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 8-FILE * FORMATION ~ BOR~HOLE , ........... . ....... ~ .................................. DEPTH ~ DIP DiP ~ DEV. DEV. DIA~ DIA~ . AZI. ~ AZI. 1-3 2-4 ************************************************************************* 9200 26.3 249 4.0 77 7.9 7.9 ~ 9202 24.8 243 4.0 76 7.9 7.9 D 9204 11..9 230 A.0 70 7.9 7.9 D 9206 9.4 243 4.0 69 7.9 7.9 D 9208 4.0 72 7.9 7.9 9210 4.0 76 7.9 7.9 9212 4.0 78 7.9 7.8 921~ 3.9 81 7.9 7.8 9216 34.6 328 3.9 82 7.9 7.8 D 9218 10.6 238 3.8 81 7.9 7.8 D 9220 10.0 234 3.8 81 7.9 7.9 D 9222 29.1 324 3.8 81 7.9 7.9 D 922~ 11.:7 210 3.8 81 7.9 7..9 D 9226 7..8 98 3.8 81 7.9 7.9 D 9228 24.5 332 3.8 82 7.9 7.9 D 9230 7.3 215 3.8 82 7.9 7.9 9232 3.8 82 7.9 7.9 9234 25.4 352 3.8 82 7.9 7.9 D 9236 24.6 348 3.8 81 7.9 7.9 D 9238 4..1 222 3.8 81 7.9 7.9 D 9240 24.17 348 3.8 81 8.0 7.9 D 92q2 6.5 111 3.8 82 8.0 8.0 D 9244 3.4 100 3.8 82 8.0 8.0 B 9246 3.,5 105 3.8 82 8.0 8°0 9248 3.8 82 8.0 8.0 9250 3.8 83 8.0 7.9 9252 3.8 83 8.0 8.0 9254 3.8 83 8.0 8.0 9256 3.8 83 8.0 8.0 9258 3.8 83 8.0 8.0 9260 3.8 83 8.0 7.9 9262 3.8 83 8.0 8.0 9264 7.6 129 3.8 83 8.0 8.0 A 9266 11.0 142 3.8 83 8.0 8.0 A 9268 8.3 141 3.8 83 8.0 8.0 A 9270 10.2 127 3.9 83 8.0 8.0 A 9272 3.9 83 8.0 8.0 927~ 22.2 229 4.0 84 8.0 8.0 D 9276 3.9 84 8.0 8.0 9278 24.8 215 3.9 85 8.0 8.0 ************************************************************************* ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 9-FILE ~ FORMATION ~ BOREHOLE "'' ................ " .................................. DEPTH ~ DIP DIP , ~EV. DEV. DIAM DIA~ * AZI. ~ ~ZI. ~-3 2-4 9280 24.9 215 3.9 85 8.0 8.0 D 9282 30..1 218 3.8 86 8.0 8.0 D 9284 8.6 213 3.8 86 8.0 8.0 A 9285 6.5 243 3.8 86 8.0 8.0 A 9288 6.6 243 3.8 85 8.0 8.0' A 9290 6~7 245 3.8 86 8.0 8°0 A 9292 6.4 285 3.8 · 86 8.0 8.0 A 9294 7.0 190 3.8 86 8.0 8.0 A 9296 6.9 189 3.8 86 8.0 8.0 A 9298 6.9 193 3.8 86 8.0 8°0 A 9300 15.9 171 3.8 86 8.0 8.0 C 9302 13.9 202 3.8 86 8°0 8°0 C 9304 15.9 201 3.8 86 7.9 7.9 B 9306 19o4 212 3.8 86 7.9 7.9 D 9308 15..5 207 3.8 86 7.9 7.9 B 9310 14.6 207 3.8 86 7.9 7.9 B 9312 16.4 203 3.8 87 7.9 7.9 D 9314 10.2 180 3.8 87 7.9 7.9 D *- 9316 10.15 176 3.8 87 7°9 7°9 D 9318 3.8 86 7.9 7.9 9320 3.8 85 7.9 7.9 9322 10.9 215 3.8 84 7.9 7.9 D 9324 10.3 70 3.8 83 7.9 8.0 C 9326 10.2 72 3.8 83 8.0 8.0 C 9328 13.3 61 3.8 83 8.0 8.0 A 9330 13.:7 55 3.7 83 8.0 8.0 A 9332 13.0 44 3.7 83 8.0 7.9 9334 ~3..1 46 3.6 83 7.9 7°9 ~ 9336 11,6 27 3,6 83 7,9 7,9 9338 31.9 356 3,6 83 7,9 7,9 9340 30,.5 358 3,6 83 7.9 7,9 D 9342 32,2 357 3,6 ~4 7.9 7,9 D 9344 32,3 356 3,6 84 7,9 7.9 D 9346 ~2,3 55 3.6 ~5 7.9 7,9 C 9348 20,0 38 3,6 85 7,9 7,9 C 9350 16,0 69 3.6 85 7,9 7,9 C 9352 16,2 65 3,6 85 7,9 7,9 C 9354 16,4 67 3,6 85 7,9 8,0 C 9356 16,9 68 3.6 84 8,0 8,0 C 9358 13.17 66 3.6 85 8,0 8,0 C ATLANTIC RICBFIELD CO. D.S. 6-15 8AGE 10-FILE i * FORMATION * BOREHOLE ,mmmmmmmmmmmmmmmmmm,mmmmmmmmmmmmmmmmmmmmmm DEPTH , DIP DIP , DEV. DEV. DIA , AZI. , AZI. 1- mmmmmmm M D * * 9360 3.6 85 8.0 * 9362 3.6 86 8.0 * 9364 3.6 87 7.9 * 9366 3.6 86 7.9 * 9368 3.6 86 8.0. ~ 9370 3.6 86 8.0 * 9372 31.6 322 3.6 86 8.0 * 9374 31.~7 322 3.6 87 8.0 * 9376 32.4 323 3.6 88 8.0 * 9378 33.4 320 3.6 88 8.0 * 9380 3.8.0 353 3.6 88 8.0 , 9382 3.5 88 8.0 * 9384 3.5 87 8.0 * 9386 1.4 28 3.4 87 8.0 ~ 938B 5.4 48 3.4 87 8.0 * 9390 4.17 48 3.5 86 8.0 ~ 9392 4.0 39 3.5 86 8.0 * 9394 6,i 44 3.5 85 8.0 * 9396. 6.9 21 3.5 85 8.0 * 9398 13.17 347 3.5 85 8.0 * 9400 3.18 14 3.5 85 7.9 * 9402 3.5 84 7.9 ~ 9404 3.5 84 7.9 * 9406 26.2 6 3.6 83 8.0 * 9408 10.0 4 3.6 83 7.9 * 9410 29,8 355 3.5 84 7.9 ~ 9412 1,2 135 3.5 84 8.0 w 9414 1.3 98 3.4 85 8.0 ~ 9416 3.15 36 3.4 85 8.0 w 9418 3.2 40 3.5 $5 8.0 w 9420 3.3 35 3.5 86 8.0 * 9422 3.4 32 3.5 86 8.0 ~ 9424 0.17 192 3.5 86 8.0 - 9426 1.6 171 3.4 86 8.0 ~ 9428 2,0 175 3.4 86 8.0 ~ 9430 2.15 i38 3.4 86 8.0 * 9432 2.0 144 3.4 86 8.0 * 9434 2,2 154 3.4 86 8.0 ~ 9436 1.17 276 3.4 86 8.0 , 9438 2,! 295 3.4 86 8.0 , OUAL. ..... , INDEX IAM , BEST 2-4 * ****~********* 8.0 8.0 8.0 * 8.'0 * 8.0 8.0 * 8.0 C * 8.0 A , 8.0 C * 8.0 C 8.0 D , 8.0 * 8.0 * 8.0 D , 8.0 D , 8.0 D 8.0 B , 7.9 D * 7.9 D * 7.9 D * 7.9 D 7.9 7.9 7.9 D * 7.9 D 7.9 D * 7.9 B * 8.0 C , 8.0 A , 8.0 A 8.0 A , 7.g A , 7.9 A 8.0 A 8.0 A , 8.0 A 8.0 A , 8.0 A , 8.0 A , 8.0 A , ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE II-FILE * * FORMATIO~ , BOREHOLE # QUAL. * * .................. * .................................. * INDEX * DEPT~! * DIP DIP , DEV. DEV. DIA~ DIA~ , BEST * * AZI. , AZI. 1-3 2-4 , :A ************************************************************************* * 9440 0~5 * 9442 0.~5 * 9444 0.6 * 9446 3,1 , 9448 2.6 , 9450 2.6 ~ 9452 3.6 * 9454 12.2 * 9456 * 9458 * 9460 * 9462 4,1 * 9464 3.9 * 9466 3'5 * 9468 3.3 * 9470 2.17 * 9472 2.9 * 9474 3,1 , 9476 3.2 ~ 9478 2~7 ~ 9480 3,2 * 9482 3.0 ~ 9484 2.9 ~ 9486 4~1 ~ 9488 8.2 ~ 9490 5.2 * 9492 6,6 * 9494 6.2 * 9496 4.15 * 9498 5.6 , 9500 5.1 * 9502 6.3 * 9504 6.6 , 9506 * 9508 * 9510 * 9512 5.3 * 9514 2.8 ~ 9516 * 9518 153 3.4 86 8.0 8.0 C 177 3.4 85 8.0 8.0 C 149 3.4 85 8.0 8.0 A 199 3.4 84 8.0 8.0 A 197 3.4 84 8.0 8.0 A 198 3.4 83 8.0 8.0 A 114 3.4 82 8.0 8.0 C , 255 3.4 80 8.0 8.0 D 3.4 79 8.0 8.0 3.4 77 8.0 8.0 3.4 76 8.0 8.0 164 3.4 75 8.0 8.(: A 159 3.4 75 8.0 ' 8.0 A 147 3.4 74 8.0 8.:J A '* 138 3.4 72 8.0 8.0 A 145 3.4 72 8.0 8.0 C 129 3.4 70 8.0 8.0 A 145 3.4 70 8:0 8.0 A , I46 3.4 70 8.0 8.0 A 142 3.4 69 8.0 8.0 A , 147 3.4 70 8.0 8.0 A 143 3.4 70 8.0 8.0 A * 129 3.4 70 8.0 8.0 A 123 3.4 71 8.0 8.0 A 117 3.4 71 8.0 8.0 A 127 3.4 70 8.0 8.0 A 124 3.4 69 8.0 8.0 A 121 3.4 68 8.0 8.0 A 126 3.4 68 8.0 8.0 A 144 3.4 69 8.0 8.0 A 135 3.4 70 8.0 8.0 C * 127 3.4 70 8.0 8.0 C 129 3.4 70 8.0 8.0 C 3.4 71 8.0 8.0 3.4 70 7.9 8.0 3.4 71 7.9 8.0 * 109 3.4 71 7.9 8.0 D 173 3.4 70 7.9 8.0 D 3.4 70 7.9 8.-0 3.4 68 7.9 7.9 ATLANTIC RICHFIELD CO. D.S. 6-15 PAGE 12-FILE ~ ~'ORMATION * BO~EHOLE ~ .................. ~ .................................. DEPTH ~ DIP DIP ~ DEV. DEV, DIA~ DIAM ~ ~ZI. ~ AZI. 1-3 2-4 9520 3.3 68 7.9 7.9 9522 3.3 68 7.9 7.9 9524 4.2 171 3.2 70 7.9 7,9 B ATLANTIC RICHFIELD CO. D.S. 6-15 SUMMARY , DEPTH ~ DIP DIP , DE~ DEV DIA~ DIAM * * AZM , AZM 1-3 2-4 ~ TOP ~ 8640.0 6ol 211. 6.9 81. 13.1 15.9 ~ BOTTOM * 9524.0 5.0 145. 3.2 84. 8.0 7.9 ~ TOP * 8640.0 36.2 265. 6.! 64. 15.6 12.7 , BOTTO~ ~ 9524.0 4.2 171. 3.2 70. 7.9 7.9 Conpany '. ARCO LIB.~RY IA~E CURVE SPECIFICATIONS ALASKA, INC. Well D.S. 6-15 Field PRL~HOE BAY. County, State N. SLOPE, ALASKA Date 5/2/82 Curve ~ame (Abbrev.) Standard Curve game Logs ~sed Scale GR · CCL LSN SS.X Ga~a Ray Casing Collar Locater Long Spaced Short Spaced Compensated Nuetron CN-Mu 1 t i spac ed I! · , , 0-100, 100-200 0-10 0-1250 0-1000 60-0 1982 Cons. commission PAGE PAGE 2 PAGE PAGE 1 aTLANTIC RICHFIELD .... D S 6-15 PRUDHOE BAY .... NO~TH SLOPE~ALASKA HLAC 6508 50,00 104.~ ~9 ~8 8~6,81 829.55 7~51,00 10~,~0 Xg,0~ 825,~ ~5~,00 112,~1 ~9,70 ~1,~ 8~0,~ ~55.00 105,05 ~6,9~ 8~,~6 8~0,60 ~ .: ............. ...,.~ ......... ~ .......... ~ ............. , ............................................................................ 7864,00 75,86 q.O, 7,67 8.'52,00 PAGE 2 ~L/~NTIC RICHFIELD .... D S 6-1.5 PRUDHOE BAY .... NORTH SLOPE,ALASKA HLAC 6308 7875.50 61,65 ~2.;57 893.25 8~;L,8;5 7876.50 77.59 ~0,42 847,85 829,55 7877,50 85.~7 ~0.22 858.90 8~5,52 7a78.50 87.q~ ~8,87 87~,85 8~9.20 7879.50 91.2~. ~9.82 856.~ 835,69 . ~;:~;:;{ ;:;~} 2;z ~ i;,.~; ~:~,;;;:x: ~: :.:;:E~ ~; }. ~ a ;;s ~:-;~ ~2 ~a~;;; ;~;;::~:; ;~,,~;.~; ;~; ~:~:~<; ~, ;~i;~ ;~ ~;~: ;:~< ,~ ;~;~;:;,~; ~;; ~: ~:~, ~ ~.~ ~:,:; ~ ;.~ ~ ;~ ~ ~ ~, ;;;.:;:: ~a :.~ ~,~ ~,;,,~ ~;;;~ ;~ ~ ~;~ ;~ ;~< ,~ ,::~ ~<~ ~ ,~,~,;,~ .,.:~ ~. ~ ;;; 7880,50 96,~5 ~1,73 8q6.63 819,72 7881,50 96.67 ~3,~5 858,90 813,57 7~82.50 95.07 ~3.61 8~6,63 806,20 78~3,50 88.92 ~3,8~ 830,67 802,52 7885.50 78.57 ~1,66 860,1e 83~,~6 7~89 50 7~90.50 7891.50 85.59 q2.46 829.45 8,06.20 7~92,50 86,2~. ~2,82 826.99 ~02,52 7R96.50 89,90 ~q,Ol 8~8,0~ 8.08,66 : ......... 7899,50 9;5,10 q. 1, O0 822,09 808,6.6 PAGE 3 AI'LANT'IC RICHFIELD----D S 6-15 PRU[])HOF B&Y .... NORTH SLOPE,ALASK'A HLAC 6308 7901,00 90.89 ~2,60 820,8g 795,15 7902,00 89,q~ L~q,68 828,22 793,92 7903.00 93.55 ~4.22 836.81. 80q.98 790~,00 95.69 ~3,65 838,0q. 809,89 7905.00 9~.60 ~2.95 8~8.0~ 809.89 PAGE] ~ ATLANTIC RICHFIELD----D S 6-15 PRUDHOE BAY .... NORTH SLOPE,ALASKA HLAC 6;~08 7926.50 96.80 ~1.q-9 8]2,27 802.52 7927.50 95.~1 ~,3,10 817. ],~0, 792,69 7928.50 96.~3 ~,~ 830.67 80q.98 7929.50 92.28 ~5.22 849,08 820.95 79~0,50 87.93 ~2.93 858,90 820,95 7931.50 77,83 ~2.11 836.8~. 809,89 79~2.50 85.~,q ~2.3g 813.50 797.60 79~,50 90 .~q ~2.2~ 80~.9~_ 792.69 7935.50 90.7¢ ~1.08 809,8~ 80q,98 795~,50 86,0~ ~2,1~ 809,8~ 789,00 79M9.50 79~0 79gl 50 In£ormation Tape The Basic Information Tape (BIT) is a binary, partially multi- plexed tape containing up to 20 data curves. The data samples are represented as' IBM, 52-bit floating point numbers. The tape consists of a 276 byt'e heading record followed.by a series of data records whose 'leng~h is defined in the heading record. The last data record is followed by two end-of-files. The tapes are 9 track, 800 bits per inch. Alaska Oil & ~s ~.~.,~ Heading Record The heading record contains the information necessary to recover the curve data from the data records and some identification information. ' 1. The Epilog Computation Center (ECC) number is a unique number assigned at one of the Dresser Computer Centers. Any questions regarding the data should, if possible, include this number. 2. Company name - Well name. These are free format fields used to identify the well. 3. The number of curves (N) is designated as a 16 bit binary integer number. This number must be less than or equal to 20. It gives the number of curves of data that will be in the data records. 4. Curve names. Each curve is designated by a 4 character name. A list of Dresser Atlas standard names is given in the appendix. These names appear in the order in which the data appears in the data record. 5. The starting and ending depth gives the first depth for which there is data on the tape and the last depth'respect- ively, l.%%en the starting depth is smaller than the ending. depth the data is recorded downward. With field data, the ending depth may be smaller since the data is recorded from the bottom of the well upward. The ending depth may be given as 0 or 99999 when it is not known during record- ing; this occurs on BlT tapes recorded in the field. 6. Level Spacing (L). This field designates the depth increment between the data samples. The data samples are taken at regularly spaced depth increments. 7. Number of samples (F). This field gives the number of samples of each curve recorded in each data record. This number will be less than or equal to 1'25. i. _ ii i ~DATA RECORDS , · The samples in th~ data records are recorded as floating point members (IBM standard). This consists of a sign bit, 7 bit exponent and a 24 bit mantissa normalized to the nearest 4 bits. sign bit. .The exoonent is biased by 40 . Th~s, 41100000 number 1.0. z~ represents the The data record consists of N '. F · 4 bytes of data where N is the number of curves and F is the .number of samples of each curve. The first F samples in the record will be of curve 1, the next F samples will be of curve 2, etc. Each record will contain data for F ---L feet of data, where L is the level spacing. The current standard usage at Dresser data center is- Level spacing = L = .5 feet Samples per record = F = 12S Thus each record represents 62.S ~eet of data. These numbers are given as an example only, however, since L 'and F may vary from tape to tape, and will certainly be different for BIT tapes recorded in_the field. DRF=SSER COMPUTER SERVICES DIVISION FILE DATA SPECIFICATioNS (Continued) DATE 10-6-77 EXHIBIT 1 Page 1 of APPLI CATION Fl LE NAME i , FILE FILE NAME 2 NUMBER t DEHTI FI CATION POSITION CHAR- NO. NO. FI ELD DESCRIPTION - ACTER- OF OF FIELD SUB FIELD START STOP I$TIC$ DECIMALS BYTES . ,,, 'i~ 2 [ i Co_mpany. Name 5 84 AN , 80 , 3 I Well Name .... 85.. i 4 i Nlmher ~F Cl,rves on T~pe 165 166 INT 2 15.Filler . 167 168 2 6 Curve Names 169 246 AN 80 ,, 7 Tape starting depth 247 250 FP 4 ......... 8 , Tape.. ending depth 251 254 FP 4 i "l ,-9 ,. Data level spacing 255 25,.8 FP . 4 ..i 10 Depth column ,~=0),. 259 260 INT t ....... 11 ., Fill.er ,~ 261 262 .2 12 ~urnber of samp!es of each curve 263 266 FP . 4 per record 13 Filler 267 276 8 . -'900- 5~ 4-00 SHEET 2 LIBRARY TAPE CURVE SPECIFICATIONS Company Atlantic Richfield Well DS 6- 15 Field Prudhoe Bay County,State North Slope, Alaska Date 9-2-80 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale iOO-ZOU GR Gamma Ray .. . CN 0-100 NEU Compensated Neutron CN 60-0 SSN-- Short Space Neutro'n , CN 0~2000 LSN ~ Lo.,.n.g Space Neut. ron!--.. I CN, 0-2000 .. . _ , · · _ ,, ., ,, * ALASKA COMPUTING CENTER * ****************************** * ............................ * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. 6-15 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292045900 REFERENCE NO : 98228 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/05/15 ORIGIN : FLIC REEL NAME : 98228 CONTINUATION # : PREVIOUS REEL : CO~4~ENT : ARCO ALASKA INC, D.S. 6-15, PRUDHOE BAY, 50-029-20459-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/05/15 ORIGIN : FLIC TAPE NAME : 98228 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, D.S. 6-15, PRUDHOE BAY, 50-029-20459-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 6-15 API NUMBER: 500292045900 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 15-MAY-98 JOB NUMBER: 98228 LOGGING ENGINEER: DECKERT OPERATOR WITNESS: SARBER SURFACE LOCATION SECTION: 2 TOWNSHIP: 1 ON RANGE: 14E FNL: FSL: 323 FEL: 1736 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 68. O0 DERRICK FLOOR: 67. O0 GROUND LEVEL: 32. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9. 675 8622.0 47. O0 7.000 9535.0 29.00 5.500 8178.0 17.00 4.500 8223.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 20 -JUL- 80 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9375.0 9367.0 9366.5 9361.5 9360.5 9360.0 9355.5 9355.0 9351.0 9349.0 9347.5 9347.0 9344 0 9341 5 9335 5 9335 0 9331 0 9329 5 9329 0 9326 0 9325 5 9320 5 9314 5 9310 0 9307.5 9304.0 93 O1.0 9299.0 9298.5 9297.0 9295.0 9287.5 9281.0 9280.5 9276.0 9275.5 9273.5 9272.5 9270.5 9268.5 9265.5 9260.5 9255.0 9249.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887.5 88889.0 9376.0 9366.5 93 60.5 9355.5 9351.5 9349.0 9347.5 9344.0 9341.0 9335.0 9329.0 9326.5 9320.5 9315.5 9309.5 9304.0 9299.0 9296.5 9295.0 9287.5 9280.5 9276.0 9273.5 9270.0 9268.5 9264.0 9260.5 9254.5 9249.0 9366.5 9363.5 9361.0 9355.5 9347.5 9335.0 9332.5 9329.5 9326.5 9309.5 9301.0 9299.0 9280.5 9275.5 9273.0 9254.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9246.5 9246.5 9245.5 9246.5 9243.5 9242.5 9239.5 9239.5 9239.0 9239.5 9236.5 9235.5 9236.0 9235.0 9215.5 9215.0 9214.5 9215.5 9208.0 9208.0 9204.0 9204.5 9201.0 9202.5 9198.5 9198.5 9194.5 9194.0 9186.0 9187.5 9179.5 9179.5 9178.0 9179.0 9174.0 9175.5 9170.5 9170.5 9164.5 9163.5 9163.0 9163.0 9153.5 9154.0 9151.5 9151.5 9150.5 9151.0 9141.5 9143.0 9140.5 9142.5 9133.5 9134.5 9130.0 9131.0 9119.5 9117.5 9113.0 9115.0 9108.0 9109.0 9104.0 9105.0 9102.0 9104.5 9100.5 9101.5 9095.5 9096.0 9096.5 9085.0 9084.5 9084.0 9084.0 9080.5 9082.0 9078.0 9078.5 9077.0 9077.5 9072.5 9073.0 9073.0 9068.5 9067.5 9065.5 9066.0 9063.5 9064.0 9061.5 9062.0 9059.5 9060.5 9053.5 9054.0 9053.0 9054.0 9051.0 9050.5 9049.0 9051.0 9045.5 9046.0 9044.0 9046.0 9042.0 9042.0 9036.5 9036.5 9036.0 9036.5 9030.0 9028.5 15-MAY-1998 11:42 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9029.0 9028.5 9027.5 9026.5 9021.0 9022.5 9017.0 9017.5 9017.5 9014.0 9014.0 9008.0 9008.5 9007.5 9008.5 9005.0 9005.5 9002.5 9003.5 9001.0 9002.0 8996.0 8997.0 8993.5 8995.5 8992.0 8993.0 8991.5 8993.0 8990.0 8990.5 8986.5 8987.0 8983.0 8984.0 8981.0 8982.0 8978.0 8979.5 '8979.5 8965.0 8964.5 8963.0 8964.5 8957.0 8957.5 8952.0 8952.0 8949.0 8950.0 8950.0 8944.0 8944.5 8940.5 8940.5 8938.0 8937.5 8934.0 8935.0 8935.0 8930.0 8931.0 8925.5 8926.5 8924.0 8925.0 8923.5 8924.5 8922.0 8922.0 8919.0 8920.5 8917.5 8919.0 8919.0 8914.0 8915.0 8915.0 8911.0 8911.5 8909.5 8910.0 8909.0 8910.0 8902.5 8903.0 8902.0 8903.0 8900.0 8901.0 8901.0 8895.5 8895.5 8894.0 8895.5 8891.5 8892.5 8891.0 8892.5 8888.5 8890.0 8886.5 8887.0 8885.5 8887.0 8877.0 8877.0 8876.0 8877.0 8871.0 8871.0 8869.0 8869.0 8868.5 8869.5 8862.0 8862.5 8861.0 8863.0 15-MAY-1998 11:42 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 8859.0 8860.0 8860.0 8854.5 8855.5 8849.0 8849.5 8847.0 8848.0 8841.0 8842.0 8840.5 8842.5 8839.0 8840.0 8832.5 8833.5 8829.0 8830.5 8828.0 8831.0 8823.5 8826.5 8817.0 8818.0 8816.5 8817.5 8813.5 8815.0 8812.0 8813.0 8810.5 8812.0 8810.0 8812.0 8808.5 8810.0 8807.0 8808.0 8806.0 8807.0 8802.5 8804.0 8800.0 8801.5 8799.5 8803.5 100.0 101.5 104.0 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO'S DS 6-15 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS G~ RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAMMA RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/15 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: 0.5000 FILE SUFk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: GRCH 9368.5 8797.5 TDTP 9383 . 0 8800.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME 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 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM TDTP CU 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 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) TPHI TDTP PU-S 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 SBHN TDTP CU 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1064352 O0 000 O0 0 1 i 1 4 68 0000000000 TSCN TDTP CPS 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1064352 O0 000 O0 0 1 i 1 4 68 0000000000 INFD TDTP CPS 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1064352 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9400. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS 39.500 DEPT. 8770. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS. TDTP -999. 250 CCL. TDTP -999. 250 GR. BCS 55.156 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/15 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 NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUF~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9368.0 8796.0 TDTP 9382.0 8798.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.0 88888.0 9376.0 9376.0 9371.0 9370.5 9367.0 9366.5 9365.0 9364 . 0 9362.5 9363.5 9359.5 9359.0 9358.0 9357.5 9356.5 9355.5 9356.0 9356.0 9352.5 9351 . 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 9350.0 9348.0 9347.5 9345.5 9342.0 9330.0 9325.5 9320.0 9313.0 9310.0 9308.0 9305.5 9304.5 9302.0 9300.0 9297.0 9296.0 9292.5 9291.0 9289.0 9288.0 9285.0 9284.5 9281.5 9277.0 9276.0 9273.5 9271.5 9265.0 9264.5 9261.0 9256.5 9255.0 9253.5 9250.0 9249.5 9247.0 9246.5 9244.5 9243.0 9240.0 9236.5 9232 5 9230 5 9230 0 9229 0 9223 5 9221 5 9218 0 9216 0 9215 5 9207.5 9207.0 9204.5 9203.0 9349.5 9347.5 9341.0 9329.0 9326.5 9320.5 9309.5 9304.0 9301.0 9299.0 9296.5 9291.5 9288.0 9283.5 9280.5 9276.0 9270.5 9264.0 9260.5 9255.0 9252.0 9249.5 9246.0 9243.0 9239.5 9231.5 9229.0 9228.0 9223.0 9218.0 9215.5 9206.5 9204.5 9347.5 9344.5 9341.0 9329.5 9326.0 9313.0 9309.5 9304.0 9295.5 9290.0 9286.5 9284.5 9275.5 9273.0 9265.0 9255.0 9249.0 9246.5 9243.0 9239.5 9235.0 9228.5 9219.0 9215.0 9207.5 9202.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 10 9200.0 9195.5 9192.0 9190.5 9184.0 9180.0 9176.5 9172.0 9171.5 9170.0 9164.5 9164.0 9156.5 9153.0 9152.5 9145.0 9142.0 9141.0 9131.5 9130.5 9124.5 9110. 5 9110.0 9104.0 9097.5 9086.5 9085.5 9083.5 9079.0 9078.0 9074.5 9073.0 9070.5 9069.0 9064.0 9054.5 9052.0 9042.5 9036.5 9029 0 9025 0 9021 0 9019 0 9017 5 9013 0 9O08 5 9003 5 9001 5 8994 5 8993 0 8992 5 8990.0 8983.5 8982.5 8972.5 9199.0 9187.5 9183.0 9175.5 9171.5 9168.5 9163.5 9155.0 9152.0 9141.0 9131.5 9109.0 9096.0 9085.5 9084.0 9078.5 9074.5 9069.5 9064.0 9054.0 9051.0 9042.0 9028.5 9022.5 9020.0 9017.5 9008.5 9003.5 8995.5 8993.0 8990.0 8982.0 8972.0 9195.0 9190.0 9179.5 9170.5 9163.0 9151.5 9146.0 9143.0 9131.5 9124.5 9111.0 9105.0 9085.0 9077.5 9073.0 9067.5 9064.0 9036.5 9024.0 9017.5 9013.0 9008.0 9001.5 8995.0 8993.0 8984.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 11 8969.0 8960.0 8957.0 8950.5 8944.0 8935.0 8934.5 8931.0 8926.5 8924.5 8922.5 8918.5 8918.0 8915.0 8914.5 8911.0 8906.5 8903 5 8903 0 8892 0 8885 5 8873 0 8865 5 8862 0 8859 5 8855 5 8854 0 8852 5 8851 5 8849 5 8848 0 8843 5 8839 5 8835 5 8833 0 8830 0 8829 5 8822 0 8820 0 8818 0 8814 5 8814 0 8811 5 8811 0 8809 5 8807 5 8803 5 8801 0 8799 0 100 0 REMARKS: 8957.5 8950.5 8944.5 8935.0 8932.0 8927.0 8925.0 8922.5 8919.0 8914.5 8903.5 8893.0 8887.0 8873.0 8866.0 8860.0 8855.5 8852.5 8848.0 8843.5 8840.0 8833.5 8830.5 8822.5 8818.0 8815.0 8812.0 8810.0 8807.5 8804.5 8801.5 8799.0 100.0 8970.0 8960.0 8950.0 8934.5 8931.0 8927.0 8924.5 8919.0 8914.5 8911.0 8906.5 8903.0 8863.0 8859.5 8853.5 8851.0 8849.5 8843.5 8836.5 8832.0 8822.0 8814.5 8812.5 8803.5 102.5 THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 12 BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 13 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) INND TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1064352 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9382. 000 SIGM. TDTP 14. 591 TPHI. TDTP 31 . 624 SBHF. TDTP 41 . 503 SBHN. TDTP 49. 728 SIGC. TDTP 1.222 SIBH. TDTP 58. 494 TRAT. TDTP 1 . 882 SDSI.TDTP 0.417 BACK. TDTP 124.090 FBAC. TDTP 28.066 TCAN. TDTP 26698.047 TCAF. TDTP 10626.176 TCND. TDTP 22573.148 TCFD. TDTP 6867.049 TSCN. TDTP 5980.864 TSCF. TDTP 2380. 463 INND. TDTP 1476. 469 INFD. TDTP 288. 581 GRCH. TDTP -999.250 TENS. TDTP 1355. 000 CCL. TDTP O. 000 DEPT. 8796. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 44.375 TENS. TDTP -999. 250 CCL. TDTP -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 14 FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUF~IARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9368.0 8795.0 TDTP 9382.0 8798.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 9380.5 9376.5 9370.5 9367.5 9367.0 9364.5 9361.5 9357.0 9352.0 9350.5 9349.0 9348.5 9346.0 9342.5 9340.0 9336.0 9330.5 9319.5 9314.0 9308.5 9306.0 9304.5 9302.5 9302.0 9300.0 9299.5 9297.5 9296.0 9291.5 9289.5 9284.5 9282.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88887.0 88888.0 9366.5 9363.5 9360.5 9355.5 9349.5 9347.5 9339.5 9335.5 9329.5 9315.5 9304.0 9301.0 9299.5 9296.5 9288.0 9283.5 9280.5 9380.5 9376.0 9369.0 9366.5 9361 · 0 9356.0 9351.5 9347.5 9344.0 9341 · 5 9329.5 9318.5 9309.0 9304.5 9301.0 9299.0 9296.0 9290.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 15 9278.0 9276.0 9276.5 9275.5 9271 . 0 9270.0 9266.0 9265.0 9265.5 9264.0 9262.0 9260.5 9259.5 9258.0 9256.5 9255.0 9254.5 9255.0 9254.0 9252.0 9250.5 9249.5 9250.0 9249.0 9247.5 9246.0 9247.0 9246.5 9245.0 9243.0 9240.0 9239.0 9239.5 9239.5 9236.5 9235.0 9235.0 9235.5 9233.0 9231.5 9232.5 9230.5 9229.5 9228.0 9228.5 9228.5 9225.5 9224.0 9223.5 9223.0 9221.0 9219.5 9220.0 9219.0 9218.5 9218.0 9215.5 9215.5 9208.0 9206.5 9207.5 9205.5 9204.5 9203.0 9202.5 9201.5 9201.0 9200.0 9198.5 9196.5 9195.0 9192.5 9191.5 9191.0 9189.5 9187.5 9187.0 9183.5 9185.0 9180.5 9179.5 9177.0 9176.0 9176.0 9175.0 9173.0 9171.0 9172.0 9170.5 9167.5 9166.0 9164.0 9163.5 9163.0 9158.5 9157.5 9157.0 9155.5 9152.5 9151.5 9145.5 9145.5 9142.0 9143.0 9141.5 9141.0 9131.0 9131.5 9124.0 9124.5 9123.0 9123.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 16 9111 0 9104 5 9103 5 9096 5 9092 5 9086 0 9085 5 9078 0 9075 0 9073 5 9067 0 9065 0 9064 0 9058 5 9055 0 9054 5 9053 0 9052 0 9045 5 9043 0 9037 0 9030 0 9028 5 9024 5 9022 5 9019 5 9018 0 9011 0 9010 5 9009 0 9008 5 9004 0 9001 5 8997 0 8993 5 8993.0 8991 0 8988 0 8983 5 8982 0 8976 5 8973 0 8971.5 8969.0 8965.5 8964.5 8960.5 8959.5 8955.5 8950.5 8938.0 8935.5 8935.0 8931.5 8927.0 9110.5 9104.5 9096.5 9084.0 9074.5 9065.5 9063.5 9056.5 9054.5 9050.5 9042.0 9028.5 9020.0 9010.0 9008.5 9003.5 8999.0 8993.0 8990.5 8987.5 8982.0 8970.0 8964.5 8957.5 8950.0 8937.5 8935.0 8931.0 9105.0 9092.0 9085.0 9077.5 9073.0 9064.0 9054.0 9051.5 9046.0 9036.5 9028.5 9024.0 9022.0 9017.0 901 O. 0 9008.0 9001.5 8993.0 8983.5 8976.5 8973.0 8969.5 8965.0 8960.0 8955.0 8950.0 8935.0 8926.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 17 8925.0 8925.0 8924.5 8923.0 8922.5 8919.0 8919.0 8918.5 8919.0 8915.5 8915.0 8915.0 8915.0 8911.5 8910.5 8908.5 8908.0 8906.0 8905.0 8903.5 8903.0 8903.0 8900.5 8901.0 8896.0 8895.0 8894.5 8895.5 8892.0 8891.0 8886.5 8887.5 8885.5 8884.5 8883.0 8881.0 8880.5 8877.0 8881.0 8876.5 8877.0 8875.5 8872.5 8874.5 8874.5 8873.0 8871.5 8866.0 8866.0 8866.5 8863.5 8862.5 8862.0 8863.0 8860.0 8860.0 8859.5 8859.5 8855.5 8855.5 8854.0 8853.5 8853.0 8852.5 8852.0 8851.5 8849.5 8849.5 8849.5 8846.5 8848.0 8844.0 8843.5 8843.5 8843.5 8840.0 8840.0 8834.0 8836.0 8833.5 8833.5 8830.5 8830.5 8830.0 8831.5 8827.0 8827.0 8822.5 8822.5 8818.0 8818.0 8815.0 8815.0 8814.5 8815.0 8812.0 8812.0 8811.5 8812.0 8810.0 8810.0 8806.5 8808.0 8804.0 8804.5 8801.0 8803.5 8800.0 8799.0 100.0 99.0 102.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 18 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 19 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) TCFD TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1064352 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9382 000 SIGM. TDTP 15. O16 TPHI. TDTP 32. 318 SBHF. TDTP 42. 545 SBHN. TDTP 50 748 SIGC. TDTP 1. 384 SIBH. TDTP 60. 425 TRAT. TDTP 1. 878 SDSI. TDTP 0 443 BACK. TDTP 153. 818 FBAC. TDTP 34. 579 TCAN. TDTP 26374. 621 TCAF. TDTP 10414 209 TCND. TDTP 22758.582 TCFD. TDTP 6854. 376 TSCN. TDTP 5930. 611 TSCF. TDTP 2341 745 INND. TDTP 1507.187 INFD. TDTP 289.350 GRCH. TDTP -999.250 TENS. TDTP 1365 000 CCL. TDTP 0. 000 DEPT. 8795 000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999 250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999 250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999 250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999 250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 50. 406 TENS. TDTP -999 250 CCL. TDTP -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 20 FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, TDTP $ 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 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 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 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1064352 O0 000 O0 0 4 1 i 4 68 0000000000 TPHI PNAV PU-S 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 21 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) O0 000 O0 0 4 1 1 4 68 0000000000 SBHN PNAV CU 1064352 SIGC PNAV CU 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN PNAV CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1064352 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9383.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 39.892 FBAC. TDTP 11.021 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 DEPT. 8797.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP 33.063 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 22 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... 9419.5 8795.5 TDTP LOG HEADER DATA DATE LOGGED: 27-DEC-97 SOFTWARE VERSION: CP 42.2 TIME LOGGER ON BOTTOM: 1743 27-DEC-97 TD DRILLER (FT) : 9416.0 TD LOGGER (FT) : 9400.0 TOP LOG INTERVAL (FT) : 8796.0 BOTTOM LOG INTERVAL (FT) : 9382.0 LOGGING SPEED (FPHR): 1800.0 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE- ......................... GR GAMMA RAY TDTP THERMAL DECAY $ 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) : TOOL NUMBER ........... CGRS-A 970 TDT SET 230 9535.0 CRUDE 15.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 23 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): 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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED 7-20-80. PUMPED 370 BBLS CRUDE PRIOR TO LOGGING LOGGED WITH SANDSTONE MATRIX THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 24 ** 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) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1064352 SIGM PS1 CU 1064352 O0 000 TPHI PS1 PU 1064352 O0 000 SBHF PS1 CU 1064352 O0 000 SBHN PS1 CU 1064352 O0 000 SIGC PS1 CU 1064352 O0 000 SIBH PS1 CU 1064352 O0 000 TRAT PS1 1064352 O0 000 SDSI PS1 CU 1064352 O0 000 BACK PS1 CPS 1064352 O0 000 FBAC PS1 CPS 1064352 O0 000 TCANPS1 CPS 1064352 O0 000 TCAF PS1 CPS 1064352 O0 000 TCND PS1 CPS 1064352 O0 000 TCFD PS1 CPS 1064352 O0 000 TSCN PS1 CPS 1064352 O0 000 TSCF PS1 CPS 1064352 O0 000 INND PS1 CPS 1064352 O0 000 INFD PSi CPS 1064352 O0 000 TENS PS1 LB 1064352 O0 000 GR PS1 GAPI 1064352 O0 000 CCL PS1 V 1064352 O0 000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9400.000 SIGM. PS1 25.719 TPHI.PS1 41.461 SBHF. PS1 SBHN. PS1 56.909 SIGC. PS1 2.404 SIBH. PS1 75.288 TRAT. PS1 SDSI. PS1 0.787 BACK. PSi 95.303 FBAC. PS1 25.235 TCAN. PS1 TCAF. PS1 5816.424 TCND.PS1 20337.473 TCFD.PS1 5496.346 TSCN. PS1 TSCF. PS1 933.276 INND.PS1 2158.875 INFD.PSi 361.373 TENS. PSI GR.PS1 16.344 CCL.PS1 0.000 DEPT. 8795.500 SIGM. PS1 29.514 TPHI.PS1 60.766 SBHF. PS1 SBHN. PS1 52.803 SIGC. PS1 1.445 SIBH. PS1 65.974 TRAT. PS1 SDSI. PS1 1.013 BACK. PSi 110.424 FBAC. PSI 21.849 TCAN. PS1 TCAF. PS1 5807.017 TCND.PS1 18278.660 TCFD.PS1 4734.988 TSCN. PS1 TSCF. PS1 879.387 INND. PS1 1542.035 INFD.PS1 267.760 TENS. PSi GR.PS1 39.469 CCL.PS1 0.000 51.339 1.678 16785.020 2493.710 1335.000 45.045 2.015 20310.457 2939.965 1280.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 25 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 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 SUMPIARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9419.5 8793.5 TDTP $ 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 GR GAM~A RAY TDTP THERMAL DECAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 27-DEC-97 CP 42.2 1743 27-DEC-97 9416.0 9400.0 8796.0 9382.0 1800.0 TOOL NUMBER CGRS-A 970 TDT SET 230 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 26 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9535.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED 7-20-80. PUMPED 370 BBLS CRUDE PRIOR TO LOGGING LOGGED WITH SANDSTONE MATRIX THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 27 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN PS2 CU 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 INND PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1064352 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9400.000 SIGM. PS2 27 499 TPHI.PS2 48.532 SBHF. PS2 51.262 SBHN. PS2 57.616 SIGC. PS2 1 362 SIBH. PS2 76.894 TRAT. PS2 1.767 SDSI.PS2 0.845 BACK. PS2 179 470 FBAC. PS2 60.874 TCAN. PS2 15341.971 TCAF. PS2 5166.218 TCND. PS2 20055 328 TCFD.PS2 5341.627 TSCN. PS2 2547.282 TSCF. PS2 898.230 INND. PS2 1985 252 INFD.PS2 358.806 TENS.PS2 1350.000 GR.PS2 81.688 CCL.PS2 0 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 28 DEPT. 8793.500 SIGM. PS2 SBHN. PS2 47.767 SIGC.PS2 SDSI.PS2 0.618 BACK. PS2 TCAF. PS2 9633.430 TCND.PS2 TSCF. PS2 1630.148 INND. PS2 GR.PS2 34.281 CCL.PS2 21.820 TPHI.PS2 2.722 SIBH. PS2 155.285 FBAC. PS2 21018.926 TCFD.PS2 1632.356 INFD.PS2 0.000 35.139 SBHF. PS2 54.551 TRAT. PS2 29.849 TCAN. PS2 6286.932 TSCN. PS2 277.667 TENS.PS2 40. 460 1. 757 26819.297 4300. 443 1285. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE . 98/05/15 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 SUMMARY VENDOR TOOL CODE START DEPTH TDTP 9419.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : STOP DEPTH .......... 8792.0 27-DEC-97 CP 42.2 1743 27-DEC-97 9416.0 9400.0 8796.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 29 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 9382.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~W~A RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A 970 TDT SET 230 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9535.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 30000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS BHCS DATED 7-20-80. PUMPED 370 BBLS CRUDE PRIOR TO LOGGING LOGGED WITH SANDSTONE MATRIX THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 11:42 PAGE: 30 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME 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 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN PS3 CU 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 $IGC PS3 CU 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1064352 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 15-MAY-1998 I1:42 PAGE: 31 ** DATA ** DEPT. 9400.000 SIGM. PS3 14.759 TPHI.PS3 SBHN. PS3 44.596 SIGC.PS3 2.199 SIBH. PS3 SDSI.PS3 0.509 BACK. PS3 174.169 FBAC. PS3 TCAF. PS3 10070.074 TCND.PS3 22941.281 TCFD.PS3 TSCF. PS3 2266.841 INND.PS3 1602.962 INFD.PS3 GR.PS3 87.438 CCL.PS3 0.000 DEPT. 8792.000 SIGM. PS3 SBHN. PS3 47.819 SIGC.PS3 SDSI.PS3 0.686 BACK. PS3 TCAF. PS3 8291.104 TCND.PS3 TSCF. PS3 1955.271 INND.PS3 GR.PS3 39.156 CCL.PS3 18.665 TPHI.PS3 2.988 SIBH. PS3 174.242 FBAC. PS3 22210.844 TCFD.PS3 1580.566 INFD. PS3 0.000 30.534 SBHF. PS3 47.060 TRAT. PS3 71.156 TCAN. PS3 6600.770 TSCN. PS3 256.095 TENS.PS3 31.472 SBHF. PS3 54.065 TRAT. PS3 34.997 TCAN. PS3 6896.469 TSCN. PS3 306.218 TENS.PS3 38.111 1.901 25878.703 5825.468 1350.000 40.886 1.765 21314.266 5026.492 1280.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/15 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/05/15 ORIGIN : FLIC TAPE NAME : 98228 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, D.S. 6-15, PRUDHOE BAY, 50-029-20459-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/05/15 ORIGIN : FLIC REEL NAME : 98228 CONTINUATION # : PREVIOUS REEL COM~ENT : ARCO ALASKA INC, D.S. 6-15, PRUDHOE BAY, 50-029-20459-00 * ALASKA COMPUTING CENTER . ****************************** * ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : DS 6-15 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292045900 REFERENCE NO : 98559 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN : FLIC REEL NAME : 98559 CONTINUATION # : PREVIOUS REEL : COF~ENT : ARCO ALASKA, PRUDHOE BAY, DS 6-15, API #50-029-20459-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN : FLIC TAPE NAME : 98559 CONTINUATION # : 1 PREVIOUS TAPE : COF~ENT : ARCO ALASKA, PRUDHOE BAY, DS 6-15, API #50-029-20459-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 6-15 API NUMBER: 500292045900 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 4-NOV-98 JOB NUMBER: · 98559 LOGGING ENGINEER: J SPENCER OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 2 TOWNSHIP: iON RANGE: 14E FNL: FSL: 323 FEL: 1736 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 68.00 DERRICK FLOOR: 67.00 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 8622.0 47.00 2ND STRING 7.000 9535.0 29.00 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 20-JUL-80 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH .............. 88888.0 9380.5 9379.5 9376.5 9376.0 9368.0 9362.0 9360.0 9349.0 9347.5 9336.5 9332.0 9331.0 9329.5 9311.5 9301.0 9298.5 9297.5 9296.0 9292.0 9290.0 9285.5 9282.5 9278.5 9277.5 9276.0 9263.0 9248.5 9208.0 9206.0 9180.0 9167.0 9157.5 9153.5 9147.5 9141.5 9131.0 9124.5 9114.0 9110.5 9100.5 9092.0 9085.0 9074.0 9O67.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNT 88886.0 88887.5 9378.5 9379.0 9374.5 9376.0 93 66.5 9360.5 9360.5 9347.5 9345.5 9335.5 9332.5 9329.5 9329.5 9310.0 9299.0 9296.5 9299.0 9295.0 9289.0 9287.5 9284.0 9280.0 9284.0 9278.0 9276.0 9276.0 9260.5 9246.5 9246.5 9206.5 9203.5 9179.0 9166.5 9156.0 9151.0 9147.0 9143.0 9131.5 9125.5 9113.5 9109.5 9100.0 9091.5 9084.0 9083.5 9072.5 9066.0 PAGE LIS Tape Verification Listing Schlumberger Alaska Computing Center 9065.0 9063.0 9062.5 9055.5 9054.0 9053.0 9044.0 9038.5 9030.0 9023.5 9016.0 9012.5 9011.0 9009.5 9007.5 9007.0 9005.5 9002.0 8994.5 8992.0 8982.0 8976.5 8966.0 8958.0 8951.0 8949.5 8946.0 8940.0 8936.0 8934.0 8928.0 8926.0 8923.0 8916.0 8914.0 8907.0 8894.5 8888.0 8878.5 8868.5 8866.0 8859.5 8856.5 8854.0 8843 5 884O 5 8834 5 8831 0 8822 5 8818 5 8817.5 8815.5 8813.0 8808.5 8805.0 8794.0 9061.5 9054.0 9052.0 903 6.5 9028.5 9022.5 9010.0 9008.5 9005.5 9001.5 8993.5 8964.5 8957.5 8950.0 8944.0 8935.0 8927.0 8922.5 8915.0 8906.0 8888.0 8869.0 8864.5 8855.5 8852.5 8842.5 8840.0 8833.5 8830.5 8822.0 8817.5 8815.0 8811.5 8808.0 8804.0 8793.5 9065.5 9064.0 9054.0 9045.5 9018.0 9010.5 9008.5 9005.5 8993.0 8982.0 8975.5 8950.0 8940.5 8934.5 8927.0 8924.5 8915.0 8895.0 8879.5 8860.5 8856.0 8818.0 4-NOV-1998 13:51 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 8791.5 8793.5 8784.0 8783.0 8782.0 8783.0 8770.0 8771.0 8764.0 8763.5 8759.5 8759.0 8756.0 8755.0 8749.0 8749.5 8742.5 8743.5 8742.0 8743.5 8735.5 8736.0 8733.5 8733.0 8731.5 8733.0 8725.5 8726.0 100.0 100.5 101.5 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE MCNL DATA AQUIRED ON ARCO ALASKA'S DS 6-15 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAM~iA RAY, ALSO PASS #1 NRAT AND THE BCS GAF~A RAY, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 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: 0.5000 FILE SUM~zARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9384.0 8722.5 CNT 9383.5 8723.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT REMARKS: THIS FILE CONTAINS CASED HOLE MCNL 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 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 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 ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 FCNTCNT CPS O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: DEPT. 9384. 000 NRAT. CNT -999. 250 DEPT. 8722. 500 NRAT. CNT -999. 250 GRCH. CNT GRCH. CNT 46.116 NCNT. CNT 80.809 NCNT. CNT -999.250 -999.250 FCNT. CNT FCNT. CNT -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 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 NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMFIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9384.5 8722.0 CNT 9383.5 8722.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 88888.0 9380.0 9379.5 9377.5 9374.5 9373.0 9369.5 9365.O 9363.0 9359.5 9358.5 9353.5 9350.5 9348.5 9346.5 9339.5 9337.0 9335.0 9331.0 9330.5 9318.5 9315.0 9313.0 9310.5 9305.0 9302.5 9300.0 9298.0 9296.5 9293.0 9290.5 9286.5 9283.5 9281.5 9277.5 9276.0 9274.0 9266.5 9262.5 9256.5 9255.5 9251.5 9247.5 9245.0 9241.5 9238.5 9233.0 9229.5 9228.0 9226.5 9225.0 9223.5 9221.5 9219.5 9211.5 88886.5 88887.5 9378.5 9379.0 9376.5 9372.0 9364.0 9360.5 9358 0 9351 5 9349 5 9347 5 9345 5 9338 0 9335 5 9329.5 9316.0 9311.5 9310.0 9304.0 9301.0 9299.0 9296.5 9295.0 9289.0 9280.5 9276.0 9273.0 9260.5 9254.5 9248.5 9246.5 9243.5 9240.0 9236.5 9232.0 9228.5 9222.0 9220.5 9375.5 9368.0 9363.5 9360.5 9339.0 9336.0 9332.5 9319.0 9296.0 9290.0 9284.0 9278.5 9269.0 9257.5 9236.5 9227.5 9225.5 9223.0 9219.0 9210.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 9210.5 9210.0 9205.5 9203.5 9202.0 9199.5 9198.5 9197.5 9197.5 9196.0 9194.5 9195.0 9192.0 9189.5 9189.0 9185.5 9183.5 9182.5 9179.5 9181.5 9181.0 9175.5 9175.0 9170.5 9171.5 9166.5 9166.5 9162.0 9161.0 9155.5 9153.5 9151.5 9151.0 9148.5 9147.5 9144.0 9142.5 9141.0 9143.0 9129.5 9131.0 9123.5 9125.5 9108.5 9109.0 9096.5 9098.0 9091.5 9091.0 9091.0 9091.5 9085.0 9083.5 9077.0 9077.0 9073.5 9072.5 9071.5 9072.0 9067.5 9068.0 9063.0 9064.0 9062.0 9061.5 9059.0 9060.0 9055.0 9054.0 9053.0 9054.0 9044.5 9043.5 9048.0 9041.0 9043.5 9029.5 9032.0 9024.5 9025.0 9027.5 9016.5 9018.5 9009.0 9008.5 9004.5 9005.5 9002.0 9002.0 9002.5 8991.5 8991.0 8986.5 8987.5 8985.0 8984.0 8978.5 8979.0 8975.0 8976.0 8972.0 8971.5 8971.5 8970.5 8958.5 8959.5 8949.0 8950.0 8946.0 8944.5 8945.5 8947.0 8936.5 8938.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 8935.5 8935.0 8934.0 8934.5 8929.0 8927.0 8926.0 8927.5 8925.0 8925.5 8923.0 8922.5 8922.5 8924.5 8919.0 8919.0 8918.5 8919.0 8915.5 8915.0 8913.0 8915.0 8907.0 8907.0 8903.5 8903.5 8902.0 8900.5 8899.5 8902.0 8895.5 8894.5 8895.5 8891.5 8891.5 8892.5 8887.5 8888.5 8885.5 8886.0 8882.5 8884.0 8881.5 8884.0 8869.5 8870.0 8867.5 8867.0 8866.5 8869.0 8864.0 8864.5 8860.0 8859.5 8859.0 8860.5 8856.0 8855.5 8853.5 8852.5 8851.5 8853.5 8848.5 8851.0 8844.0 8844.0 8840.0 8839.5 8838.0 8840.0 8834.0 8835.5 8832.0 8833.0 8830.5 8830.5 8826.5 8827.0 8825.0 8826.5 8822.5 8822.5 8824.5 8818.0 8817.5 8817.5 8818.5 8813.5 8813.5 8810.5 8810.0 8810.0 8811.0 8808.0 8808.0 8803.0 8803.0 8801.0 8801.5 8800.0 8802.0 8797.5 8798.0 8797.0 8796.5 8792.0 8794.0 8790.0 8789.5 8784.5 8786.5 8783.5 8783.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 10 8777.0 8775.0 8775.5 8770.5 8771.0 8766.5 8765.5 8759.0 8759.0 8758.5 8752.5 8753.5 8751.5 8749.0 8749.0 8747.0 8738.5 8739.0 8733.0 8731.5 8730.0 8730.0 100.0 100.0 $ 8778.0 8760.0 8752.0 8748.0 8733.0 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE MCNL PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NRAT PASS #2 AND NRAT PASS #1, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 o.5 9 65 FT 11 66 51 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 4-NOV-1998 13:51 PAGE: 11 ** 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 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9384.500 GRCH. CNT 37.797 NCNT. CNT -999.250 FCNT. CNT NRAT. CNT -999.250 DEPT. 8722.000 NRAT. CNT 45.430 GRCH. CNT 77.077 NCNT. CNT 2779.140 FCNT. CNT -999.250 78.305 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 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 LIS Tape Verification Listing Schlumberger Alaska Compu ting Center 4-NOV-1998 13:51 PAGE: 12 FILE SUR~J~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9384.0 8721 . 5 CNT 9382.5 8724 . 0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNT 88888.0 88886.0 88886.5 9380.5 9378.5 9380.0 9378.5 9378.0 9376.5 9373.0 9373.0 9365.5 9364.5 9359.0 9358.0 9360.0 9354.5 9353.5 9353.0 9351.5 9352.0 9352.5 9349.5 9349.0 9348.5 9347.5 9345.5 9343.5 9342.0 9341.5 9340.0 9338.0 9339.5 9337.0 9336.0 9331.5 9332.5 9331.0 9329.5 9329.5 9330.0 9319.0 9316.5 9318.0 9319.0 9311.5 9311.5 9311.0 9307.0 9302.5 9301.0 9301.0 9299.5 9298.0 9296.5 9297.5 9299.0 9291.5 9288.5 9285.0 9283.5 9282.0 9280.5 9278.0 9276.0 9278.5 9270.0 9268.5 9268.5 9269.5 9262.5 9260.5 9258.0 9258.0 9257.5 9254.0 9254.5 9252.0 9251.5 9248.5 9248.0 9246.5 9245.5 9243.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 13 9244.5 9241.0 9233.5 9229.5 9233.0 9231.5 9231.5 9227.5 9230.5 9228.5 9230.0 9225.5 9226.5 9223.0 9223.5 9222.0 9220.0 9219.5 9218.5 9217.0 9210.5 9210.5 9205.0 9203.0 9202.0 9199.5 9200.5 9197.5 9189.5 9189.0 · 9183.0 9180.0 9181.0 9181.5 9179.5 9174.5 9173.5 9167.0 9166.5 9162.5 9161.5 9163.0 9148.5 9147.5 9141.5 9143.0 9140.0 9140.5 9137.5 9139.5 9135.5 9137.5 9130.0 9131.0 9128.0 9128.5 9122.5 9125.0 9118.5 9119.0 9109.0 9109.0 9105.0 9104.5 9091.5 9091.5 9083.0 9082.0 9077.0 9076.5 9076.0 9074.5 9074.0 9073.5 9065.0 9064.0 9063.5 9064.0 9060.0 9060.0 9055.5 9054.0 9054.0 9054.0 9044.5 9045.5 9039.0 9037.5 ~ 9028.5 9029.0 9024.5 9026.5 9011.5 9010.0 9010.5 9011.5 9009.5 9008.5 9006.5 9005.5 9005.0 9005.5 9004.5 9004.0 9002.5 9001.5 8991.5 8993.0 8984.5 8984.0 8981.5 8982.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 14 8976.5 8975.5 8972.0 8971.0 8968.5 8967.5 8960.0 8960.0 8959.0 8957.5 8950.0 8950.0 8944.5 8944.5 8939.5 8940.0 8936.0 8935.0 8934.0 8934.5 8926.5 8927.0 8923.0 8924.5 8917.5 8919.0 8915.5 8915.0 8914.0 8915.0 8913.5 8912.0 8906.0 8907.5 8904.0 8904.0 8902.0 8901.0 8901.5 8902.0 8892.0 8892.5 8886.5 8888.5 8880.0 8881.0 8878.0 8878.5 8876.5 8878.0 8874.0 8874.5 8870.5 8870.0 8865.5 8864.0 8860.5 8859.5 8860.0 8860.5 8852.0 8853.5 8844.5 8844.0 8838.0 8839.5 8835.5 8836.0 8831.0 8830.5 8830.0 8830.5 8823.5 8823.0 8825.0 8818.5 8817.5 8814.5 8814.0 8811.0 8810.0 8810.0 8811.0 8805.0 8804.0 8801.5 8802.0 8801.0 8802.0 8797.0 8799.0 8794.0 8793.5 8791.5 8793.5 8790.0 8790.0 8785.5 8786.5 8783.0 8782.5 8781.5 8783.0 8777.0 8778.0 8773.0 8774.0 8771.5 8771.0 8765.0 8763.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 15 8760.5 8761.0 8759.0 8759.0 8755.5 8755.0 8753.0 8754.5 8750.5 8751.0 8750.0 8752.0 8745.5 8748.0 8744.0 8743.0 8736.0 8738.0 8734.0 8733.5 100.0 99.5 102.0 $ REMARKS: THIS FILE CONTAINS CASED HOLE MCNL PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NRAT PASS #3 AND NRAT PASS #1, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 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 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 16 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) NCNTCNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNT CPS O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9384.000 NRAT. CNT -999.250 GRCH. CNT 37.248 NCNT. CNT -999.250 FCNT. CNT DEPT. 8721.500 GRCH. CNT 67.316 NCNT. CNT -999.250 FCNT. CNT NRAT. CNT -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION ' O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01COi DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFIBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMFiARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 17 GRCH 9383.5 8724.0 CNT 9384.0 8724.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9381.0 9378.5 9374.5 9369.0 93 61.0 9359.5 9357.0 9352.0 9349.5 9346.0 9343 5 9339 0 9337 5 9332 5 9332 0 9322 0 9319 5 9312.0 9303.0 9301.5 9298.0 9293.0 9290.5 9286.0 9285.0 9282.0 9278.0 9275.0 9273.0 9270.5 9267.5 9265.0 9263.0 9258.5 9255.0 9252.0 9249.0 9246.0 9238.5 9226.0 9224.0 9221.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNT 88885.5 88888.0 9378.5 9376.5 9378.5 9372.0 9366.5 9360.0 9360.5 9358.0 9355.0 9347.5 9343.5 9341.5 9335.5 9329.5 9321.0 9319.0 9310.0 9299.0 9296.5 9289.0 9287.5 9283.5 9280.5 9276.0 9273.0 9269.0 9264.5 9260.5 9254.0 9252.0 9248.5 9246.5 9243.0 9222.0 9353.5 9345.5 9339.0 9332.5 9302.5 9290.5 9284.0 9275.5 9262.0 9244.5 9236.5 9223.0 9219.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 18 9217.0 9212.0 9211.0 9206.0 9203.0 9200.5 9198.5 9193.0 9190.0 9184.0 9181.0 9171.5 9167.5 9155.0 9153.0 9147.0 9144.5 9142.0 9141.0 9136.5 9132.5 9128.5 9117.0 9114.0 9110.5 9094.0 9087.5 9085.0 9077.5 9076.0 9068.5 9068.0 9063.5 9056.0 9054.5 9053.0 9045.5 9041.0 9031.5 9028.5 9026.0 9025.0 9017.5 9010.0 9008 0 9003 0 9002 5 8992 5 8988 0 8983 5 8976.5 8975.5 8970.0 8969.5 8966.5 9217.0 9208.0 9203.5 9199.5 9197.5 9190.0 9151.0 9142.5 9140.0 9113.5 9093.0 9085.5 9084.0 9075.5 9074.5 9066.0 9054.0 9052.5 9039.0 9029.0 9023.0 9008.5 9001.5 8991.0 8982.0 8973.5 8969.0 8966.0 9210.5 9198.0 9189.5 9183.5 9179.5 9171.0 9166.5 9154.0 9147.0 9143.0 9137.5 9135.0 9128.5 9117.0 9109.0 9077.0 9068.0 9064.0 9054.5 9045.5 9030.5 9027.5 9018.5 9008.5 9002.5 8993.0 8988.0 8975.5 8968.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 19 8964.5 8958.5 8951.5 8947.0 8942.5 8937.0 8934.0 8926.5 8923.0 8920.5 8918.5 8916.5 8914.0 8911.5 8908 0 8905 5 8902 0 8900 5 8895 5 8891 0 8889 0 8883 0 8877 0 8871 5 8861 5 8860 0 8857.0 8854.0 8851.0 8850.0 8845.0 8844.0 8839.5 8838.5 8836.0 8834.5 8833.5 8831.0 8829.0 8824.0 8823.5 8819.5 8819.0 8814.0 8813.5 8811.0 88O6. O 8802.0 8801.0 8796.5 8795.0 8793.0 8792.0 8791.0 8785.5 8957.0 8950.0 8944.5 8940.0 8935.0 8925.5 8922.5 8919.0 8914.5 8911.0 8906.0 8904.5 8900.5 8895.0 8887.5 8874.5 8869.0 8859.5 8855.5 8849.5 8844.0 8839.5 8837.5 8832.0 8830.5 8822.0 8817.5 8811.5 8810.0 8804.0 8801.0 8793.5 8792.5 8789.5 8963.5 8947.0 8934.5 8927.0 8924.5 8919.0 8915.0 8902.0 8892.5 8884.5 8860.5 8856.0 8851.0 8844.5 8840.0 8835.5 8830.5 8824.5 8818.5 8815.5 8811.0 8802.0 8798.5 8793.5 8786.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 8784.5 8783.0 8781.5 8783.0 8781.0 8780.0 8777.5 8778.0 8773.5 8773.5 8774.0 8769.5 8771.5 8765.5 8767.5 8764.0 8763.5 8762.0 8760.5 8759.5 8759.0 8755.0 8755.0 8753.0 8755.0 8752.0 8751.0 8747.5 8749.5 8744.5 8748.0 8741.0 8739.0 8739.5 8743.0 8736.5 8733.5 8735.5 8738.0 8732.0 8733.0 8731.0 8730.0 8728.0 8728.5 8727.5 8727.5 100.0 100.0 100.5 REMARKS: THIS FILE CONTAINS CASED HOLE MCNL PASS #4. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #4 AND GRCH PASS #1, ALSO NRAT PASS #4 AND NRAT PASS #1, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS. $ LIS FORMAT DATA PAGE: 2O ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4~NOV-1998 13:51 PAGE: 21 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 ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNT GAPI O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNT CPS O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNT O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9384.000 NRAT. CNT 23.752 DEPT. 8724.000 NRAT. CNT -999.250 GRCH. CNT -999.250 NCNT. CNT 3893.653 FCNT. CNT GRCH. CNT 87.386 NCNT. CNT -999.250 FCNT. CNT 167.228 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 22 FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INC~ 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, 4, CNT $ REMARKS THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, 3, &4. 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 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 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 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH CNAV GAPI O0 000 O0 0 5 1 1 4 68 0000000000 CVEL CNAV F/HR O0 000 O0 0 5 1 1 4 68 0000000000 NCNT CNAV CPS O0 000 O0 0 5 1 1 4 68 0000000000 FCNT CNAV CPS O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4~NOV-1998 13:51 PAGE: 23 NAME SERV UNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) NRAT CNAV O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9384. 000 GRCH. CNAV 46.116 FCNT. CNAV -999. 250 NRAT. CNAV -999. 250 DEPT. 8722 . 500 GRCH. CNAV 80 . 809 FCNT. CNAV -999. 250 NRAT. CNAV -999. 250 CVEL . CNA V CVEL. CNAV - 999. 250 NCNT. CNAV -999. 250 NCNT. CNAV -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE IVTJMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUI~BER: 1 DEPTH INCREMENT: 0.1000 FILE SUMFIARY VENDOR TOOL CODE START DEPTH STOP DEPTH MCNL 9403.0 8710.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 24 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 ......................... GR GAMMA RAY MCNL MEM COMPENSATED NEUTRON MCNL $ 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 Ti~4PERATURE (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): 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): -40 FAR COUNT RATE HIGH SCALE (CPS): 1060 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22000 TOOL STANDOFF (IN): ~KS: 17-0CT-98 RELOO35D 9394.0 9402.0 8722.0 9384.0 TOOL NUMBER ........... GR 9535.0 THERMAL 1. Depth correalted to SWS BHCS dated 7/20/80. Pass #I depth offset = + 10 feet LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 25 Pass #2 depth offset = + 9 feet Pass #3 depth offset = + 10 feet Pass #4 depth offset = + 11 feet 2. Pumped only one volume prior to logging because well was already on a vacuum from yesterday's pumping. Pumped at 1.5 bbl/min while logging each pass. Pumped 5 bbls methanol and 235 bbls crude prior to logging 1st pass. Pumped another 47 bbls crude prior to logging 2nd pass. Pumped another 43 bbls crude prior to logging 3nd pass. Pumped another 45 bbls crude prior to logging 4nd pass. Pump totals: 5 bbls methanol - 397 bblc crude - 10 bbls diesel (at end). 3. Ail perforations are shown and squeezed except where marked "OPEN". 4. A 4th pass was logged at 60 FPM to compare data to those passes logged at 30 FPM. (See 4 Pass Overlay). 5. Field picked GOC at 9179 feet FID. 6. Tagged TD at 9402 ft ~f19. 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 28 4 66 1 5 66 6 73 7 65 8 68 0.I 9 65 FT 11 66 36 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 4-NOV-1998 13:51 PAGE: 26 ** 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 O0 000 O0 0 6 1 1 4 68 0000000000 CVEL PS1 F/HR O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI O0 000 O0 0 6 1 1 4 68 0000000000 NCNTPS1 CPS O0 000 O0 0 6 1 1 4 68 0000000000 FCNTPS1 CPS O0 000 O0 0 6 1 1 4 68 0000000000 NRAT PS1 O0 000 O0 0 6 1 1 4 68 0000000000 CCLDPS1 V O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9403.000 CVEL.PS1 2.024 GR.PS1 -999.250 NCNT. PS1 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 -999.250 DEPT. 8710.000 CVEL. PS1 -999.250 GR.PS1 -999.250 NCNT. PS1 FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1 85.000 -999.250 -999.250 ** EN~ OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01COi DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 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 NUF1BER: 2 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 27 DEPTH INCREMENT: 0.1000 FILE SOI~FZARY VENDOR TOOL CODE START DEPTH ........................... 9402.0 MCNL LOG HEADER DATA STOP DEPTH 8710.0 DATE LOGGED: 17- OCT- 98 SOFTWARE VERSION: RELOO35D TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 9394.0 TD LOGGER (FT) : 9402.0 TOP LOG INTERVAL (FT) : 8722.0 BOTTOM LOG INTERVAL (FT) : 9384.0 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAM~A RAY GR MCNL MEMCOMPENSATED NEUTRON MCNL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9535.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL 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): -40 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 28 FAR COUNT RATE HIGH SCALE (CPS): 1060 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22000 TOOL STANDOFF (IN): REM=ARKS: 1. Depth correalted to SWS BHCS dated 7/20/80. Pass #1 depth offset = + 10 feet Pass #2 depth offset = + 9 feet Pass #3 depth offset = + 10 feet Pass #4 depth offset = + 11 feet 2. Pumped only one volume prior to logging because well was already on a vacuum from yesterday's pumping. Pumped at 1.5 bbl/min while logging each pass. Pumped 5 bbls methanol and 235 bbls crude prior to logging 1st pass. Pumped another 47 bbls crude prior to logging 2nd pass. Pumped another 43 bbls crude prior to logging 3nd pass. Pumped another 45 bbls crude prior to logging 4nd pass. Pump totals: 5 bbls methanol - 397 bblc crude - 10 bbls diesel (at end). 3. Ail perforations are shown and squeezed except where marked "OPEN". 4. A 4th pass was logged at 60 FPM to compare data to those passes logged at 30 FPM. (See 4 Pass Overlay). 5. Field picked GOC at 9179 feet ~ID. 6. Tagged TD at 9402 ft 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 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 29 TYPE REPR CODE VALUE 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 ELECt CODE (HEX) DEPT FT O0 000 O0 0 7 1 1 4 68 0000000000 CVEL PS2 F/HR O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI O0 000 O0 0 7 1 1 4 68 0000000000 NCNTPS2 CPS O0 000 O0 0 7 1 1 4 68 0000000000 FCNTPS2 CPS O0 000 O0 0 7 1 1 4 68 0000000000 ArRAT PS2 O0 000 O0 0 7 I 1 4 68 0000000000 CCLD PS2 V O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9402.000 CVEL.PS2 3.006 GR.PS2 -999.250 NCNT. PS2 FCNT. PS2 -999.250 NRAT. PS2 -999.250 CCLD. PS2 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 30 FILE NIIMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.1000 FILE SUM~IARY VENDOR TOOL CODE START DEPTH MCNL $ LOG HEADER DATA DATE LOGGED: 9403.0 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 8711.0 17 - OCT- 98 RELOO35D 9394.0 9402.0 8722.0 9384.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAIV~4A RAY GR MCNL MEM COMPENSATED NEUTRON MCNL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9535.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 31 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -40 FAR COUNT RATE HIGH SCALE (CPS): 1060 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22000 TOOL STANDOFF (IN): REMARKS: 1. Depth correalted to SWS BHCS dated 7/20/80. Pass #1 depth offset = + 10 feet Pass #2 depth offset = + 9 feet Pass #3 depth offset = + 10 feet Pass #4 depth offset = + 11 feet 2. Pumped only one volume prior to logging because well was already on a vacuum from yesterday's pumping. Pumped at 1.5 bbl/min while logging each pass. Pumped 5 bbls methanol and 235 bbls crude prior to logging 1st pass. Pumped another 47 bbls crude prior to logging 2nd pass. Pumped another 43 bbls crude prior to logging 3nd pass. Pumped another 45 bbls crude prior to logging 4nd pass. Pump totals: 5 bbls methanol - 397 bblc crude - 10 bbls diesel (at end). 3. Ail perforations are shown and squeezed except where marked "OPEN". 4. A 4th pass was logged at 60 FPM to compare data to those passes logged at 30 FPM. (See 4 Pass Overlay). 5. Field picked GOC at 9179 feet ND. 6. Tagged TD at 9402 ft MD. 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 3 73 28 4 66 i 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 32 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 ELI~4 CODE (HEX) DEPT FT O0 000 O0 0 8 1 1 4 68 0000000000 CVEL PS3 F/HR O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI O0 000 O0 0 8 1 1 4 68 0000000000 NCNT PS3 CPS O0 000 O0 0 8 1 1 4 68 0000000000 FCNTPS3 CPS O0 000 O0 0 8 1 1 4 68 0000000000 NRAT PS3 O0 000 O0 0 8 1 1 4 68 0000000000 CCLDPS3 V O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. FCNT. PS3 9403.000 CVEL.PS3 5.020 GR.PS3 -999.250 NCNT. PS3 -999.250 -999.250 NRAT. PS3 -999.250 CCLD.PS3 -999.250 DEPT. 8711.000 CVEL.PS3 -999.250 GR.PS3 -999.250 NCNT. PS3 FCNT. PS3 -999.250 1FRAT. PS3 -999.250 CCLD.PS3 85.000 -999.250 ** EArD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 33 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.1000 FILE SUBtLetY VENDOR TOOL CODE START DEPTH ........................... MCNL 9404.0 $ LOG HEADER DATA STOP DEPTH 8712.5 DATE LOGGED: 17-0CT-98 SOFTWARE VERSION: RELOO35D TIME LOGGER ON BOTTOM: TD DRILLER (FT) : 9394. TD LOGGER (FT) : 9402. TOP LOG INTERVAL (FT) : 8722. BOTTOM LOG INTERVAL (FT) : 9384. LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAIV~4A RAY GR MCNL MEM COMPENSATED NEUTRON MCNL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9535.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 34 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): THERMAL 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): -40 FAR COUNT RATE HIGH SCALE (CPS): 1060 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 22000 TOOL STANDOFF (IN): REMARKS: 1. Depth correalted to SWS BHCS dated 7/20/80. Pass #1 depth offset = + 10 feet Pass #2 depth offset = + 9 feet Pass #3 depth offset = + 10 feet Pass #4 depth offset = + 11 feet 2. Pumped only one volume prior to logging because well was already on a vacuum from yesterday's pumping. Pumped at 1.5 bbl/min while logging each pass. Pumped 5 bbls methanol and 235 bbls crude prior to logging 1st pass. Pumped another 47 bbls crude prior to logging 2nd pass. Pumped another 43 bbls crude prior to logging 3nd pass. Pumped another 45 bbls crude prior to logging 4nd pass. Pump totals: 5 bbls methanol - 397 bblc crude - 10 bbls diesel (at end). 3. Ail perforations are shown and squeezed except where marked "OPEN". 4. A 4th pass was logged at 60 FPM to compare data to those passes logged at 30 FPM. (See 4 Pass Overlay). 5. Field picked GOC at 9179 feet BiD. 6. Tagged TD at 9402 ft FiD. THIS FILE CONTAINS THE RAW DATA FOR PASS #4. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 35 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.1 9 65 FT 11 66 36 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 O0 000 O0 0 9 1 1 4 68 0000000000 CVEL PS4 F/HR O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI O0 000 O0 0 9 1 1 4 68 0000000000 NCNTPS4 CPS O0 000 O0 0 9 1 1 4 68 0000000000 FCNTPS4 CPS O0 000 O0 0 9 1 1 4 68 0000000000 NRAT PS4 O0 000 O0 0 9 1 1 4 68 0000000000 CCLDPS4 V O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 9404.000 CVEL.PS4 0.996 GR.PS4 -999.250 NCNT. PS4 FCNT. PS4 -999.250 NRAT. PS4 -999.250 CCLD.PS4 -999.250 DEPT. 8712.500 CVEL. PS4 -999.250 GR.PS4 -999.250 NCNT. PS4 FCNT. PS4 -999.250 NRAT. PS4 -999.250 CCLD.PS4 85.172 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 13:51 PAGE: 36 **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN : FLIC TAPE NAME : 98559 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA, PRUDHOE BAY, DS 6-15, API #50-029-20459-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN · FLIC REEL NAME : 98559 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, PRUDHOE BAY, DS 6-15, API #50-029-20459-00 * ALASKA COMPUTING CENTER . ****************************** . * ....... SCHLUMBERGER ....... . ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 6-15 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292045900 REFERENCE NO : 98560 RECEIVED t~O¥ 06 1998 Alaska Oi~ & Gas Cons. CommJssior~ Anchorage LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN : FLIC REEL NAME : 98560 CONTINUATION # : PREVIOUS REEL : COF~4ENT : ARCO ALASKA INC, DS 6-15, PRUDHOE BAY, 50-029-20459-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN · FLIC TAPE NAME : 98560 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, DS 6-15, PRUDHOE BAY, 50-029-20459-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 6-15 API NUMBER: 500292045900 OPERATOR: ARCO Alaska, inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 4-NOV-98 JOB NUMBER: 98560 LOGGING ENGINEER: PALMER OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 2 TOWNSHIP: ION RANGE: 14E FNL: FSL: 323 FEL: 1736 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 68.00 DERRICK FLOOR: 67.00 GROUND LEVEL: 32.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8.500 7.000 9535.0 2ND STRING 3RDSTRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 20 -JUL- 80 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9375.5 93 66.5 9363.5 9361.5 9360.0 9359.0 9357.5 9355.5 9349.5 9348.5 9347.5 9345.0 9344.0 9341.5 9335.0 9329.5 9326.0 9310.0 93 O1.0 9299.0 9298.5 9297.0 9284.5 9283.5 9281.0 9276.0 9275.5 9273.0 9263.0 9261.0 9253.0 9252.0 9246.5 9246.0 9244.0 9239.5 9239.0 9236.0 9220.0 9207.0 9206. 5 9204.0 9176.5 9176.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88888.0 88888.5 9376.0 9366.5 9363.5 9363.5 9360.5 9358.5 9358.0 9355.0 9349.0 9349.0 9347.5 9345.5 9344.0 9341.0 9341.0 9335.5 9329.0 9329.5 9326.5 9310.0 9301.0 9299.0 9299.0 9296.5 9284.0 9283.5 9280.5 9276.0 9275.5 9272.5 9264.5 9260.0 9253.0 9253.5 9246.5 9246.0 9243.0 9239.5 9239.5 9235.5 9220.5 9206.5 9206.5 9203.5 9176.0 9176.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9164.0 9163.5 9163.0 9163.0 9150.5 9151.5 9150.0 9151.0 9143.0 9144.0 9142.5 9143.0 9130.0 9131.0 9128.5 9129.0 9100.5 9100.0 9098.5 9100.0 9081.0 9081.5 9076.5 9077.5 9074.0 9074.5 9072.5 9072.5 9065.0 9066.0 9063.5 9064.0 9063.0 9064.0 9061.0 9061.5 9053.5 9054.0 9054.5 9047.0 9047.5 9043.5 9045.5 9036.5 9038.5 9036.0 9036.0 9029.0 9028.5 9020.5 9020.5 9017.0 9017.5 9016.0 9016.5 9007.5 9008.5 9008.5 9003.0 9003.5 9000.5 9001.5 8995.5 8996.5 8992.0 8993.0 8991.5 8993.0 8981.0 8982.0 8975.5 8975.5 8958.0 8959.0 8949.0 8950.0 8950.0 8943.5 8944.0 8933.5 8934.5 8926.0 8927.0 8925.5 8927.0 8923.5 8924.5 8923.0 8925.0 8919.5 8920.5 8918.5 8919.0 8917.5 8919.0 8914.0 8915.0 8915.0 8902.0 8903.0 8902.5 8898.0 8899.5 8893.5 8894.5 8886.5 8887.0 8877.0 8877.5 8876.0 8877.5 8867.0 8869.5 8866.0 8868.5 8863.0 8863.0 4-NOV-1998 16:28 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 8859.0 8860.5 8858.5 8859.5 8854.5 8855.5 8851.5 8852.5 8849.0 8849.5 8842.5 8844.0 8841.0 8842.5 8838.5 8840.0 8832.0 8833.5 8829.5 8830.5 8829.0 8830.5 8821.0 8822.0 8817.0 8817.5 8814.5 8816.0 8813.5 8813.0 8811.0 8812.0 8810.5 8811.5 8807.0 8808.0 8803.0 8804.0 8801.5 8803.0 8800.0 8801.5 8792.5 8793.5 8791.5 8793.5 8781.5 8783.0 8781.0 8783.0 8777.5 8778.5 100.0 101.5 101.0 $ REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO'S DS 6-15 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE BCS GAI~iViA RAY, ALSO BASE PASS #I SIGMA AND THE BCS GAMMA RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 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: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: FILE SUMFLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9368.0 8769.5 TDTP 9380.5 8769.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: ** 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 1189 O0 000 O0 0 1 1 SIGM TDTP CU 1189 O0 000 O0 0 1 1 TPHI TDTP PU-S 1189 O0 000 O0 0 1 1 SBHFTDTP CU 1189 O0 000 O0 0 1 1 SBHNTDTP CU 1189 O0 000 O0 0 1 1 SIGC TDTP CU 1189 O0 000 O0 0 1 1 SIBH TDTP CU 1189 O0 000 O0 0 1 1 TRAT TDTP 1189 O0 000 O0 0 1 1 SDSI TDTP CU 1189 O0 000 O0 0 1 1 BACK TDTP CPS 1189 O0 000 O0 0 1 1 FBAC TDTP CPS 1189 O0 000 O0 0 1 1 TCAN TDTP CPS 1189 O0 000 O0 0 1 1 TCAF TDTP CPS 1189 O0 000 O0 0 1 1 TCND TDTP CPS 1189 O0 000 O0 0 1 1 TCFD TDTP CPS 1189 O0 000 O0 0 1 1 TSCNTDTP CPS 1189 O0 000 O0 0 1 1 TSCF TDTP CPS 1189 O0 000 O0 0 1 1 INND TDTP CPS 1189 O0 000 O0 0 1 1 INFD TDTP CPS 1189 O0 000 O0 0 1 1 GRCH TDTP GAPI 1189 O0 000 O0 0 1 1 TENS TDTP LB 1189 O0 000 O0 0 1 1 CCL TDTP V 1189 O0 000 O0 0 1 1 GR BCS GAPI 1189 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 O0 000 O0 0 1 1 i 4 68 0000000000 ** DATA ** DEPT. 9400. 000 SIGM. TDTP -999. 250 TPHI. TDTP -999.250 SBHF. TDTP -999. 250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD.TDTP -999.250 GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS 39.500 DEPT. 8750. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS. TDTP -999. 250 CCL. TDTP -999. 250 GR . BCS 111 . 563 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCRE~: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9367.5 8758.5 TDTP 9380.5 8759.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88888.5 9375.5 9376.0 9369.5 9370.5 9366.5 9367.0 9364.0 9363.5 9362.0 9363.5 9358.5 9358.0 9358.0 9358.0 9355.5 9355.5 9351.5 9351.5 9349.5 9349.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 9347.5 9347.5 9345.0 9345.5 9341.0 9341.0 9338.5 9338.5 9333.0 9333.0 9329.5 9329.0 9329.5 9311.5 9311.5 9301.5 9301.5 9299.0 9299.0 9298.5 9299.0 9297.0 9296.5 9289.5 9290.0 9288.0 9288.0 9287.5 9287.5 9283.5 9283.0 9281.0 9280.5 9275.5 9275.5 9272.5 9272.5 9265.0 9264.0 9263.5 9264.5 9261.5 9260.5 9253.0 9253.0 9246.5 9246.5 9246.0 9246.0 9244.0 9243.0 9239.5 9239.5 9233.5 9234.0 9232.0 9232.5 9229.0 9229.0 9227.5 9228.0 9224.5 9223.5 9222.5 9222.5 9217.5 9219.0 9216.0 9215.0 9214.5 9215.5 9207.5 9206.5 9206.5 9206.5 9201.0 9200.0 9198.0 9197.5 9195.0 9194.5 9187.5 9186.5 9183.0 9181.0 9179.5 9179.5 9171.5 9170.5 9170.5 9170.5 9164.5 9163.5 9163.0 9163.0 9155.0 9156.0 9150.5 9151.0 9144.5 9144.5 9141.0 9142.0 9139.5 9140.0 9130.0 9131.0 9128.0 9129.0 9124.5 9126.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 9123.5 9123.5 9117.0 9117.0 9114.0 9114.5 9108.0 9110.0 9103.0 9104.0 9101 . 0 9100.0 9081.5 9081.5 9077.0 9078.0 9075.0 9075.5 9074.0 9074.5 9072.5 9073.0 9072.0 9072.5 9063.5 9064.0 9059.5 9060.0 9056.0 9056.0 9054.0 9054.5 9051.0 9052.0 9044.5 9045.0 9044.0 9045.0 9036.5 9038.5 9035.5 9036.0 9029.0 9028.5 9018.5 9018.0 9016.5 9017.0 9015.5 9014.0 9007.5 9008.5 9008.5 9003.0 9003.5 9004.0 9001.5 9002.0 8993.5 8994.5 8992.5 8993.5 8983.0 8984.0 8981.0 8982.0 8975.5 8975.5 8971.0 8971.5 8968.5 8968.5 8957.0 8958.5 8955.0 8955.5 8951.0 8952.0 8949.5 8950.5 8936.5 8937.0 8934.5 8935.5 8933.5 8934.5 8926.0 8927.5 8927.0 8924.0 8924.5 8923.5 8925.0 8922.5 8922.5 8919.5 8920.5 8918.0 8918.5 8914.0 8915.0 8915.0 8906.0 8905.5 8902.5 8903.0 8903.0 8900.0 8900.5 8887.0 8887.0 8878.0 8879.0 8876.0 8877.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 10 8874.5 8874.0 8865.5 8867.0 8861.5 8863.0 8858.5 8859.5 8855.0 8855.5 8851.5 8852.5 8849.0 8849.5 8845.5 8847.0 8842.5 8844.0 8842.0 8843.5 8838.5 8840.0 8835.0 8836.5 8832.5 8833.5 8829.5 8830.5 8830.5 8821.5 8822.5 8817.5 8818.0 8814.5 8815.5 8813.0 8812.5 8811.0 8811.5 8809.0 8810.0 8804.5 8806.0 8800.5 8801.5 8800.0 8801.5 8796.0 8796.5 8792.0 8793.0 8784.5 8786.5 8782.0 8783.5 8781.0 8783.0 8777.5 8779.0 8771.0 8771.5 100.0 100.5 101.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 11 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 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 NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU i189 O0 000 O0 0 2 1 i 4 68 0000000000 TPHI TDTP PU-S 1189 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1189 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 1189 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1189 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1189 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1189 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1189 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1189 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1189 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1189 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1189 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9380. 500 SIGM. TDTP 15. 896 TPHI. TDTP 28. 670 SBHF. TDTP 41.931 SBHN. TDTP 50.202 SIGC. TDTP 1.232 SIBH. TDTP 58.971 TRAT. TDTP 1. 753 SDSI. TDTP 0.284 BACK. TDTP 166.385 FBAC. TDTP 34.967 TCAN. TDTP 64068. 898 TCAF. TDTP 26864. 875 TCND. TDTP 24961 . 480 TCFD. TDTP 7938. 679 TSCN. TDTP 6503. 477 TSCF. TDTP 2726. 988 INND. TDTP 1899. 676 INFD. TDTP 361.390 GRCH. TDTP -999.250 TENS. TDTP 1003. 000 CCL. TDTP O. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 12 DEPT. 8758.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 154.013 TENS. TDTP -999.250 CCL. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 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 SUPm~ARY LDWG TOOL CODE START DEPTH sTOp DEPTH GRCH 9368.0 8770.0 TDTP 9381.0 8769.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 13 BASELINE DEPTH 88888.0 9375.0 9366.5 9365.5 9363.5 9361.5 9359.5 9358.0 9357.0 9355.0 9349.0 9346.5 9341.0 9329.0 9326.0 9316.0 9312.0 9311.0 9307.0 9304.5 9300.5 9298.5 9287.5 9287.0 9283.5 9280.5 9279.0 9275.0 92 64.0 9262.5 9261.0 9257.0 9254.0 9252.5 9249.5 9246.0 9245.5 9243.5 9238.5 9238.0 9236.0 9233.0 9231.5 9230.0 9228.0 9224.0 9222.5 9215.0 9214.5 9206.0 9203.5 9200.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88888.0 88889.0 9376.0 9367.0 9365.5 9363.5 9363.5 93 60.0 9358.5 9358.0 9355.0 9349.0 9347.5 9341.0 9341.0 9329.0 9329.5 9326.0 9315.5 9312.5 9311.5 9307.5 9304.0 9301.0 9299.0 9299.5 9288.0 9287.5 9283.5 9280.5 9280.0 9275.0 9275.5 9264.0 9264.5 9260.5 9258.5 9256.0 9252.5 9250.5 9246.5 9246.0 9243.0 9239.5 9239.5 9235.5 9234.5 9232.5 9230.5 9229.0 9223.5 9223.0 9215.0 9215.5 9206.5 9203.5 9200.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 14 9198.0 9194.5 9193.0 9190.5 9181.5 9179.0 9175.0 9170.5 9166.0 9164.0 9162.5 9154.5 9150.0 9147.5 9140.5 9129.5 9128.5 9125.0 9124.0 9122.5 9108.0 9102.5 9082.5 9080.5 9076.5 9073.5 9071.5 9062.5 9O59.5 9053.0 9051.0 9036.0 9034.0 9029.0 9016.0 9013.0 9007.0 9004.5 9004.0 8997.5 8993.5 8991.5 8989.0 8980.5 8978.0 8970 0 8968 0 8957 0 8951 0 8945 0 8933 5 8933 0 8930 0 8923 5 8923 0 9198.0 9193.5 9191.0 9181.0 9175.5 9163.5 9155.5 9149.0 9140.5 9128.5 9126.0 9124.0 9108.0 9083.0 9081.0 9074.5 9064.0 9054.0 9052.0 9034.0 9014.5 9008.5 9005.0 8998.0 8994.5 8991.0 8982.0 8980.5 8970.5 8958.5 8952.5 8935.0 8924.5 9194.5 9190.0 9179.5 9170.5 9167.5 9163.0 9151.5 9131.0 9123.5 9104.0 9078.0 9072.0 9060.5 9054.5 9036.5 9028.5 9017.0 9006.0 8993.0 8968.5 8946.5 8934.5 8931.0 8925.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4~NOV-1998 16:28 PAGE: 15 8921.5 8922.5 8917.0 8919.0 8918.0 8913.5 8915.0 8915.0 8909.5 8910.5 8902.0 8903.0 8903.0 8893.0 8894.5 8887.0 8887.0 8886.0 8887.0 8876.5 8877.5 8875.5 8877.5 8864.0 8866.0 8861.0 8863.0 8859.0 8859.5 8858.5 8860.5 8854.0 8855.5 8851.0 8852.0 8848.5 8849.5 8846.0 8847.5 8842.0 8844.0 8841.5 8843.5 8838.5 8840.0 8834.0 8836.0 8829.0 8830.5 8828.5 8830.5 8821.0 8822.5 8816.5 8817.5 8813.5 8815.0 8813.0 8813.0 8810.5 8812.0 8811.5 8802.5 8804.0 8800.0 8801.5 8795.0 8797.0 8792.0 8793.5 8784.0 8786.5 8783.5 8785.5 8781.0 8783.0 8783.0 8777.0 8778.5 100.0 102.0 101.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189 O0 000 O0 0 3 1 I 4 68 0000000000 SIGM TDTP CU 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1189 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1189 O0 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 1189 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1189 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1189 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1189 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1189 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1189 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1189 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1189 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 17 ** DATA ** DEPT. 9381.000 SIGM. TDTP 15.806 TPHI.TDTP 29.441 SBHF. TDTP 39.488 SBHN. TDTP 47.398 SIGC. TDTP 0.989 SIBH. TDTP 53.129 TRAT. TDTP 1.804 SDSI.TDTP 0.309 BACK. TDTP 191.485 FBAC. TDTP 41.284 TCAN. TDTP 63742.578 TCAF. TDTP 26043.211 TCND. TDTP 24061.793 TCFD. TDTP 7622.515 TSCN. TDTP 6386.243 TSCF. TDTP 2609.218 INND. TDTP 1799.829 INFD. TDTP 332.224 GRCH. TDTP -999.250 TENS. TDTP 986.000 CCL.TDTP 0.000 DEPT. 8769.500 SIGM. TDTP 16.366 TPHI. TDTP 20.363 SBHF. TDTP 35.073 SBHN. TDTP 44.159 SIGC. TDTP 2.921 SIBH. TDTP 45.718 TRAT. TDTP 1.562 SDSI. TDTP 0.368 BACK. TDTP 200.072 FBAC. TDTP 39.874 TCAN. TDTP 66391.391 TCAF. TDTP 30834.063 TCND. TDTP 25183.715 TCFD. TDTP 9051.469 TSCN. TDTP 6722.867 TSCF. TDTP 3122.292 INND. TDTP 1885.012 INFD. TDTP 369.291 GRCH. TDTP -999.250 TENS.TDTP 931.000 CCL.TDTP 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE · 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCR~ENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 18 RblWzARKS: 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 80 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 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 1189 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1189 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1189 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1189 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 1189 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1189 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1189 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1189 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1189 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 TCFDPNAV CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 19 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) TSCF PNAV CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1189 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1189 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9380. 500 SIGM. PNAV 15. 937 TPHI. PNAV 28. 777 SBHF. PNAV 40. 812 SBHN. PNAV 48.999 SIGC. PNAV 1.128 SIBH. PNAV 56.385 TRAT. PNAV 1. 766 SDSI. PNAV 0.276 BACK. TDTP 56.639 FBAC. TDTP 17.812 TCAN. PNAV 64322.602 TCAF. PNAV 26766.492 TCND.PNAV 24805.652 TCFD.PNAV 7867.529 TSCN. PNAV 6461.808 TSCF. PNAV 2689.035 INND.PNAV 1853.007 INFD.PNAV 349.365 GRCH. TDTP -999.250 DEPT. 8769.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 159.004 FBAC. TDTP 29.784 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 20 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... TDTP $ LOG HEADER DATA DATE LOGGED: 9411.0 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 .......... 8722.0 18-0CT-98 8Cl-205 1116 18-0CT-98 9400.0 9400.0 8768.0 9380.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 9535.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) :- FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE OIL 7.50 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 21 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO BHC SONIC OF 20-JUL-1980 RAN ALL NEUTRON LOGS FOR A COMPARISON OF GAS SATURATION LOGGINGWITH DIFFERENT LOGGING TOOLS. WELL SHUT IN AND DEAD BEFORE LOGGING AFTER RUNNING CNTG AND MEMORY CNL ON PREVIOUS DAYS. PUMPED 275 BBLS OF CRUDE TO FLUID PACK. WELL HEAD PRESSURE REFRAINED 400 PSI DURING JOB. PUMPED 1 BPM WHILE LOGGING WITH WHP OF 600 PSI 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 88 ~ 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189 O0 000 O0 0 5 t 1 4 68 0000000000 SIGM PS1 CU 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1189 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 22 NAME SERV UNIT SERVICE API APIAPI API FILE NUMB N73MB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBHF PS1 CU 1189 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 1189 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 1189 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1189 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 1189 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TCND PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1189 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1189 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1189 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1189 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9400.000 SIGM. PS1 13.782 TPHI.PS1 16.498 SBHF. PS1 42.061 SBHN. PS1 50.080 SIGC. PS1 2.524 SIBH. PS1 56.098 TRAT. PS1 1.444 SDSI.PS1 0.265 BACK. PSl 100.830 FBAC. PS1 38.087 TCAN. PS1 54980.742 TCAF. PS1 28423.973 TCND.PS1 24245.941 TCFD.PS1 8373.262 TSCN. PS1 5707.824 TSCF. PS1 2950.833 INND.PS1 1926.037 INFD. PS1 365.320 TENS.PSi 995.000 GR.PS1 189.848 CCL.PS1 0.000 DEPT. 8750.000 SIGM. PS1 16.244 TPHI.PS1 19.114 SBHF. PS1 39.021 SBHN. PS1 43.783 SIGC. PS1 1.737 SIBH. PS1 44.966 TRAT. PS1 1.530 SDSI.PS1 0.274 BACK. PSi 154.856 FBAC. PS1 31.671 TCAN. PS1 77106.375 TCAF. PS1 37053.828 TCND.PSl 28133.027 TCFD.PS1 10358.301 TSCN. PS1 7753.420 TSCF. PS1 3725.942 INND.PSl 1884.801 INFD.PS1 428.390 TENS.PSI 1016.000 GR.PS1 71.425 CCL.PS1 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 23 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 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 INCR~ENT: 0.5000 FILE SUMFiARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9407.0 8711.5 TDTP $ LOG HEADER DATA DATE LOGGED: 18-OCT- 98 SOFTWARE VERSION: 8Cl-205 TIME LOGGER ON BOTTOM: 1116 18-0CT-98 TD DRILLER (FT) : 9400.0 TD LOGGER (FT) : 9400.0 TOP LOG INTERVAL (FT) : 8768.0 BOTTOM LOG INTERVAL (FT) : 9380.0 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER CGRS-A TDT- P 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 24 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) : 9535.0 CRUDE OIL 7.50 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO BHC SONIC OF 20-JUL-1980 RAN ALL NEUTRON LOGS FOR A COMPARISON OF GAS SATURATION LOGGINGWITH DIFFERENT LOGGING TOOLS. WELL SHUT IN AND DEAD BEFORE LOGGING AFTER RUNNING CNTG AND MEMORY CNL ON PREVIOUS DAYS. PUMPED 275 BBLS OF CRUDE TO FLUID PACK. WELL HEAD PRESSURE REMAINED 400 PSI DURING JOB. PUMPED 1 BPM WHILE LOGGING WITH WHP OF 600 PSI THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 25 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** 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 1189 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1189 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1189 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS2 CU 1189 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1189 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1189 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1189 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 'INNDPS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 1189 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1189 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1189 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1189 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 26 ** DATA ** DEPT. 9400.000 SIGM. PS2 14.986 TPHI.PS2 SBHN. PS2 49.897 SIGC. PS2 1.741 SIBH. PS2 SDSI.PS2 0.352 BACK. PS2 234.578 FBAC. PS2 TCAF. PS2 28332.449 TCND.PS2 24077.242 TCFD.PS2 TSCF. PS2 2795.224 INND.PS2 2015.902 INFD.PS2 GR.PS2 0.000 CCL.PS2 0.000 20.757 SBHF. PS2 57.322 TRAT. PS2 58.816 TCAN. PS2 8211.348 TSCN. PS2 316.997 TENS. PS2 42.364 1.551 59127.406 5833.393 925.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE AUIMBER 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: 0.5000 FILE SUMFiARY VENDOR TOOL CODE START DEPTH TDTP 9407.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): STOP DEPTH 8724.0 18-0CT-98 8Cl-205 1116 18-0CT-98 9400.0 9400.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4~NOV-1998 16:28 PAGE: 27 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 8768.0 9380.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CGRS-A TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 9535.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE OIL 7.50 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COU1FT 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): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO BHC SONIC OF 20-JUL-1980 RAN ALL NEUTRON LOGS FOR A COMPARISON OF GAS SATURATION LOGGINGWITHDIFFERENTLOGGING TOOLS. WELL SHUT IN ANDDEADBEFORE LOGGING AFTER RUNNING CNTG AND MEMORY CNL ON PREVIOUS DAYS. PUMPED 275 BBLS OF CRUDE TO FLUID PACK. WELL HEAD PRESSURE REMAINED 400 PSI DURING JOB. PUMPED 1 BPM WHILE LOGGING WITH WHP OF 600 PSI THIS FILE CONTAINS THERAW DATA FOR PASS #3. LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 28 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELl~f CODE (HEX) DEPT FT 1189 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1189 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1189 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1189 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 1189 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 1189 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1189 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1189 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1189 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 1189 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-NOV-1998 16:28 PAGE: 29 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 PS3 LB 1189 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1189 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1189 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9400.000 SIGM. PS3 14.715 TPHI.PS3 21.744 SBHF. PS3 SBHN. PS3 53.620 SIGC. PS3 1.886 SIBH. PS3 64.718 TRAT. PS3 SDSI.PS3 0.361 BACK. PS3 239.831 FBAC.PS3 54.753 TCAN. PS3 TCAF. PS3 25197.883 TCND.PS3 21566.762 TCFD.PS3 6809.223 TSCN. PS3 TSCF. PS3 2406.172 INND.PS3 1626.653 INFD.PS3 281.209 TENS.PS3 GR.PS3 124.306 CCL.PS3 0.000 36.369 1.564 53214.664 5081.523 883.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01COi DATE : 98/11/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN : FLIC TAPE NAME : 98560 CONTINUATION # : 1 PREVIOUS TAPE : COM~ENT : ARCO ALASKA INC, DS 6-15, PRUDHOE BAY, 50-029-20459-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 4 ORIGIN : FLIC REEL NAME : 98560 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, DS 6-15, PRUDHOE BAY, 50-029-20459-00 0%?-- * ALASKA COMPUTING CENTER * . . ****************************** * ........................ ~___* ....... SCHLUMBERGER ....... . . ............................ . COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 6-15 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292045900 REFERENCE NO : 98558 RECEIVED NOV 06 1998 Ala~a Oil & Gas (;o~]$. Oommi~sio~ ~chomge LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC REEL NAME : 98558 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-15, API# 50-029-20459-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC TAPE NAME : 98558 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-15, API# 50-029-20459-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 6-15 API NUMBER: 500292045900 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 3 -NOV- 98 JOB NUMBER: 98558 LOGGING ENGINEER: VETROMILE OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 2 TOWNSHIP: 1 ON RANGE: 14 E FNL : FSL: 323 FEL: 1736 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 68. O0 DERRICK FLOOR: 67. O0 GROUND LEVEL: 32. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING mit SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 9535.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12: 55 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 20-JUL-80 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88887.5 88887.0 9379.5 9378.5 9377.0 9376.5 93 60.5 93 60.5 9359.5 9360.0 9349.5 9349.0 9346.0 9345.5 9341.0 9341.0 9335.5 9335.0 9332.5 9332.5 9332.0 9332.0 9330.0 9329.5 9329.5 9329.0 9327.0 9326.5 9320.5 9320.5 9310.0 9310.0 9304.5 9304.0 9302.0 9301.0 9299.0 9299.0 9294.5 9294.5 9290.5 9289.5 9288.0 9287.5 9284.5 9284.0 9283.5 9284.0 9280.5 9280.5 9279.5 9279.5 9275.0 9275.5 9275.5 9272.5 9272.5 9268.5 9268.0 9261.0 9260.5 9246.5 9246.5 9245.0 9246.0 9244.0 9242.5 9239.5 9239.5 9236.5 9235.5 9220.5 9220.5 9214.0 9215.0 9208.0 9208.5 9207.5 9207.5 9206.0 9206.5 9204.0 9203.5 9198.5 9198.5 9174.5 9173.0 9167.0 9166.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9153.5 9147.5 9147.0 9133.5 9124.0 9118.0 9114.0 9108.5 9104.0 9102.5 9092.0 9091.5 9085.5 9080.5 9074.0 9073.5 9072.5 9062.5 9054.0 9053.5 9045.0 9041.5 9035.0 9028.0 9017.0 9007.5 9004.5 9002.0 8999.0 8993.5 8992 0 8986 5 8981 0 8978 5 8959 0 8958 0 8951 0 8949 5 8948 5 8944.0 8941.0 8934.0 8930.0 8928.0 8926.0 8923.5 8921.5 8917.5 8914.0 8913.5 8908.0 8902.0 8900.5 8895.5 8894.0 8892.0 9154.0 9147.0 9125.5 9105.0 9O94.0 9081.5 9074.5 9054.5 9046.0 9042.0 9036.0 9028.5 9008.5 8995.0 8993.0 8987.5 8982.5 8979.5 8958.0 8950.0 8944.5 8942.5 8935.0 8931.0 8922.5 8919.0 8914.5 8910.0 8903.0 8895.5 9147.5 9134.5 9117.5 9114.5 9109.5 9102.0 9091.5 9084.5 9074.5 9072.5 9063.5 9054.0 9018.0 9008.5 9005.5 9003.5 8999.5 8993.0 8982.0 8960.0 8952.0 8950.0 8935.0 8928.5 8927.0 8925.0 8915.0 8901.0 8895.0 8892.5 3-NOV-1998 12:55 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 8887.5 8888.0 8886.5 8888.0 8876.0 8877.0 8875.0 8877.0 8869.5 8869.5 8869.5 8863.0 8863.0 8862.5 8863.0 8858.5 8860.0 8854.0 8855.5 8851.5 8852.5 8852.5 8846.5 8848.0 8841.0 8842.0 8838.5 8840.0 8838.0 8840.0 8832.5 8833.5 8829.5 8830.5 8829.0 8830.5 8816.5 8817.5 8814.5 8816.0 8813.5 8814.5 8810.5 8812.0 8808.5 8810.0 8801.0 8801.5 100.0 101.5 100.5 REgIARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S DS 6-15 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GAM~A RAY, ALSO PASS #1 NPHI AND THE BCS GAM~A RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 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. PASSNUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~m~ARY LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: GRCH 9378.5 8797.5 CNTG 9382.0 8796.5 $ 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 ** 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~ CODE (HEX) ....................................................................................... DEPT FT 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 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) CPHI CNTG PU-S 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1224652 O0 000 O0 0 1 I 1 4 68 0000000000 CFTC CNTG CPS 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 GRCHCNTG GAPI 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1224652 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9500.000 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 91.063 DEPT. 8700.000 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 103.125 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 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 NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUF~W~gY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9378.5 8796.0 CNTG 9383.0 8795.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 9378.5 9376.5 9375.5 9371.5 9367.0 9364.0 9360.0 9359.5 9357.5 9357.0 9351.0 9349.0 9341.0 9338.0 9332.0 9331.5 9329.0 9311.0 9310.0 93O4.O .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG - 88887.5 88888.0 9378.5 9376.0 9375.0 9372.0 9366.5 9364.0 9364.0 9360.5 9360.0 9358.0 9358.5 9351.5 9349.0 9343.5 9339.0 9332.5 9332.0 9329.0 9311.5 9310.0 9304.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 9298.5 9295.0 9289.5 9287.0 9279.5 9275.5 9274.5 9272.0 9271.0 92 64.5 9259.5 9255.0 9253.0 9252.0 9249.0 9245.0 9243.5 9242.0 9236.0 9233.5 9231.5 9231.0 9228.0 9218.5 9218.0 9215 5 9207 0 9205 5 9203 5 9200 0 9199 0 9198 0 9193.5 9191.0 9187.5 9185.0 9170.5 9166.5 9148.5 9142.0 9141.0 9133.0 9132.5 9122.5 9104.5 9102.5 9091.5 9085.0 9084.5 9080.5 9073.0 9062.5 9053.5 9053.0 9040.5 9299.0 9289.0 9287.5 9280.5 9276.0 9272.5 9264.5 9255.5 9253.0 9250.0 9242.5 9231.0 9228.0 9219.0 9215.5 9206.5 9203.5 9200.5 9198.5 9169.5 9147.5 9142.0 9134.0 9123.0 9102.5 9093.5 9085,0 9081.5 9074.5 9054.5 9042.0 9294.0 9275.5 9272.0 9259.0 9252.5 9246.0 9242.5 9238.0 9233.5 9231.5 9219.0 9208.0 9199.5 9194.5 9190.0 9188.0 9184.5 9166.5 9142.0 9134.5 9104.5 9084.5 9074.0 9063.5 9054.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 9035.0 9029.5 9007.5 9006.5 8997.0 8993.5 8991.5 8986.5 8984.0 8982.5 8980.0 8977.5 8974.5 8968.0 8963.0 8948.5 8946 0 8943 0 8938 5 8933 5 8933 0 8925 0 8922 5 8920 5 8917 5 8913 5 8913 0 8906.0 8901.5 8899.0 8896.0 8895 5 8893 0 8891 5 8883 5 8879 5 8875 5 8869 0 8865 0 8862 5 8862 0 8859 0 8853 5 8851 0 8842 5 8834.5 8829.0 8817.0 8816.0 8814.0 8813.0 8809.5 8800.5 100.0 $ 9036.0 9031.5 9008.0 8999.0 8995.5 8988.0 8982.0 8975.5 8963.5 8950.0 8944.5 8940.5 8935.0 8926.5 8922.5 8914.5 8903.0 8896.0 8885.0 8877.0 8863.0 8855.5 8818.0 102.0 9009.0 8994.5 8993.0 8985.5 8983.5 8979.5 8969.5 8950.0 8946.5 8934.5 8927.0 8925.0 8919.0 8915.0 8907.0 8901.0 8896.5 8894.0 8892.5 8880.5 8869.5 8865.5 8863.5 8860.0 8852.5 8844.0 8836.5 8830.5 8818.5 8816.0 8813.5 8811.0 8801.5 101.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 10 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 ** 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 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1224652 O0 000 O0 0 2 1 i 4 68 0000000000 CFTC CNTG CPS 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1224652 O0 000 O0 0 2 1 I 4 68 0000000000 GRCH CNTG GAPI 1224652 O0 000 O0 0 2 1 I 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) TENS CNTG LB 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1224652 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9383.000 NPHI.CNTG 23.644 ENPH. CNTG 28.865 CPHI.CNTG NRAT. CNTG 2.718 CRAT. CNTG 2.700 ENRA. CNTG 4.543 NCNT. CNTG FCNT. CNTG 623.291 CNTC. CNTG 1834.917 CFTC. CNTG 684.092 CNEC. CNTG CFEC. CNTG 593.002 GRCH. CNTG -999.250 TENS. CNTG 3088.000 CCL.CNTG DEPT. 8795.000 NPHI.CNTG 21.288 ENPH. CNTG 24.199 CPHI.CNTG NRAT. CNTG 2.443 CRAT. CNTG 2.566 ENRA. CNTG 4.036 NCNT. CNTG FCNT. CNTG 809.913 CNTC. CNTG 2196.753 CFTC. CNTG 884.703 CNEC. CNTG CFEC. CNTG 759.144 GRCH. CNTG -999.250 TENS.CNTG 2946.000 CCL.CNTG 25.491 1935.970 2694.021 0.043 22.569 2330.934 3064.015 0.176 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 12 FILE SUFmlARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 9379.0 8792.0 CNTG 9382.5 8791.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 9379.0 9376.0 9371.0 9366.5 93 63.5 9357.0 9351.5 9351.0 9349.0 9347.5 9341.0 9338.5 9335.5 9332.0 9331.5 9329.0 9326.0 9324.5 9320.5 9319.5 9315.0 9311.5 9309.5 9302.0 9298.5 9294.0 9290.5 9289.5 9283.0 9280.0 9278.0 9274.5 92 72.0 9264.0 9261.0 9255.5 9252.0 9249.5 9245.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG .............. 88888 . 0 88887 . 5 9378.5 9376.0 9371.0 9366.5 93 64.0 9357.5 9351.5 9352.0 9349.0 9347.0 9341.5 9338.0 9335.0 9332.5 9332.0 9329.0 9327.5 9326.0 9320.5 9322.5 9316.0 9311.5 9310.0 9301.5 9299.0 9298.5 9294.0 9290.0 9289.5 9284.0 9281.0 9279.5 9275.5 9273.0 9265.0 9261.0 9261.0 9256.0 9255.5 9253.0 9250.0 9246.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 13 9244.5 9246.0 9243.5 9242.5 9238.5 9240.5 9236.5 9235.5 9232.5 9233.5 9231.0 9231.0 9230.5 9231.5 9228.0 9228.0 9224.5 9226.0 9222.0 9222.0 9220.5 9221.0 9213.0 9215.5 9209.5 9209.0 9207.0 9208.0 9205.5 9206.5 9203.5 9203.5 9198.0 9198.5 9194.0 9194.5 9190.0 9190.0 9175.0 9175.5 9174.5 9175.0 9170.0 9169.5 9170.0 9166.0 9166.5 9164.0 9163.0 9161.0 9161.5 9160 . 0 9160 . 0 9156.0 9155.5 9153.5 9153.5 9152.5 9154.0 9149.0 9150.0 9144.5 9144.0 9141.0 9142.0 9139.5 9140.0 9133.0 9134.5 9132.0 9134.0 9127.5 9128.5 9123.0 9125.5 9123.5 9109.0 9108.5 9107.5 9108.5 9104.0 9104.5 9096.5 9096.5 9086.0 9085.0 9080.0 9081.5 9076.5 9077.0 9073.5 9074.5 9073.0 9074.5 9072.0 9072.5 9062.0 9063.5 9053.5 9054.0 9053.0 9054.5 9051.0 9051.5 9050.0 9051.0 9048.0 9048.0 9044.0 9046.0 9039.0 9040.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 14 9016.5 9018.0 9010.0 9011.0 9007.0 9008.5 9008.5 9003.5 9005.5 9002.0 9004.0 9001.5 9003.5 8993.5 8995.0 8991.5 8993.0 8980.5 8982.0 8980.0 8982.0 8978.5 8979.5 8976.5 8976.5 8969.5 8970.5 8959.5 8960.0 8949.5 8950.0 8948.5 8950.0 8945.0 8945.5 8943.0 8944.5 8942.5 8942.5 8938.0 8940.0 8933.5 8935.0 8935.0 8925.5 8927.0 8923.0 8924.5 8922.5 8925.0 8921.0 8922.5 8917.0 8919.0 8918.5 8913.0 8914.5 8909.0 8910.5 8908.0 8910.0 8906.0 8907.0 8901.5 8903.0 8896.0 8897.5 8894.5 8895.5 8891.5 8892.5 8886.0 8887.5 8885.5 8887.5 8879.5 8880.5 8875.0 8877.0 8872.0 8872.0 8869.0 8869.0 8865.5 8865.5 8862.0 8863.5 8859.5 8861.0 8853.5 8855.5 8851.0 8852.5 8852.5 8848.0 8849.5 8846.0 8848.0 8842.5 8844.0 8840.5 8842.5 8837.5 8840.0 8832.0 8833.5 8829.0 8830.5 8828.5 8830.5 8822.5 8824.0 8820.5 8822.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 15 8816.5 8813 0 8810 0 88O8 0 88O4 0 8800 5 100 0 8818.0 8810.0 102.0 8814.5 8811.0 8805.5 8801.5 101.0 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, 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 ** 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 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1224652 O0 000 O0 0 3 i 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 16 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) 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG NCNTCNTG CPS 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 FCNTCNTG CPS 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1224652 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9382.500 NPHI. CNTG 23.928 ENPH. CNTG 28.890 CPHI.CNTG NRAT. CNTG 2.888 CRAT. CNTG 2.715 ENRA. CNTG 4.546 NCNT. CNTG FCNT. CNTG 663.563 CNTC. CNTG 1849.556 CFTC. CNTG 677.922 CNEC. CNTG CFEC. CNTG 603.233 GRCH. CNTG -999.250 TENS. CNTG 3088.000 CCL.CNTG DEPT. 8791.000 NPHI. CNTG 15.274 ENPH. CNTG 18.672 CPHI.CNTG NRAT. CNTG 2.180 CRAT. CNTG 2.160 ENRA. CNTG 3.388 NCNT. CNTG FCNT. CNTG 1212.932 CNTC. CNTG 2513.885 CFTC. CNTG 1194.419 CNEC. CNTG CFEC. CNTG 983.546 GRCH. CNTG -999.250 TENS. CNTG 2913.000 CCL.CNTG 26.175 1859.567 2742.069 0.055 17.200 2610.665 3331.926 0.168 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 17 FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG REMARKS: THIS FILE CONTAINS THE ARITHI~ETIC 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 0.5 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 ELEM CODE (HEX) ....................................................................................... DEPT FT 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1224652 O0 000 O0 0 4 I 1 4 68 0000000000 NRAT CNAV 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 CRATCNAV 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI_~SS MOD NUMB SAMP ELI~I CODE (HEX) ENPH CNAV PU-S 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1224652 O0 000 O0 0 4 1 i 4 68 0000000000 CFTC CNAV CPS 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1224652 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9382.000 NPHI. CNAV 25.273 NRAT. CNAV 2.855 CPHI.CNAV CRAT. CNAV 2.789 ENPH. CNAV 28.470 ENRA. CNAV 4.500 NCNT. CNAV FCNT. CNAV 675.519 CNTC. CNAV 1888.937 CFTC. CNAV 692.296 CNEC. CNAV CFEC. CNAV 608.550 GRCH. CNTG -999.250 DEPT. 8796. 500 NPHI. CNAV 30.205 NRAT. CNAV 3.234 CPHI. CNAV CRAT. CNAV 3. 059 ENPH. CNAV 28. 099 ENRA. CNAV 4. 461 NCNT. CNAV FCNT. CNAV 633.054 CNTC. CNAV 1955.814 CFTC. CNAV 674.510 CNEC. CNAV CFEC. CNAV 663. 390 GRCH. CNTG -999. 250 26.175 1914. 721 2736. 292 28.783 1931.994 2957.641 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 19 FILE HEADER FILENUMBER 1 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~9IARY VENDOR TOOL CODE START DEPTH ........................... CNTG 9407.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 8794.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA 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): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 16-0CT-98 8Cl-205 1912 16-0CT-98 9414.0 9390.0 8790.0 9383.0 TOOL NUMBER ........... SGC- SA CNT-G 8.500 9535.0 CRUDE EPI THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 2O 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): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO SWS SONIC DATED 20-JUL-1980 PUMPED 271 BBLS CRUDE / 80 BBL SEA WATER TO KNOCK DOWN WELL @ 1BBL/MIN. PUMPED 70 BBL SEA WATER DURING LOGGING @ 1BBL/MIN PUMPED 62 BBLS CRUDE DURING LOGGING @ 1BBL/MIN PUMPED 10 BBLS DIESEL TO CLEAR LINES LOGGED THREE PASSES AT 30 FPM TAGGED PBTD AT 9394 '. GOC PICK ESTIMATED AT 9180'. 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 $ 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 3-NOV-1998 12:55 PAGE: 21 ** 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 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 EArRA PS1 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PS1 CPS 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN PS1 CPS 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1224652 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 9407.000 NPHI.PS1 16.300 ENPH. PS1 41.632 TNPH. PS1 TNRA.PS1 2.233 RTNR.PS1 2.286 ENRA.PS1 5.762 CFEC. PS1 CNEC.PSI 2733.570 RCEF. PS1 480.550 RCEN. PS1 2583.916 RCNT. PS1 RCFT. PS1 844.860 CNTC. PS1 1914.340 CFTC. PSi 878.262 NPOR.PS1 GR.PS1 71.068 TENS.PSi 2442.000 CCL.PS1 0.023 DEPT. 8794.500 NPHI.PS1 24.722 ENPH. PS1 26.103 TNPH. PS1 TNRA.PS1 2.759 RTNR.PS1 2.516 ENRA.PS1 4.247 CFEC. PS1 CNEC. PS1 2993.698 RCEF. PS1 759.186 RCEN. PS1 3003.130 RCNT. PS1 RCFT. PS1 850.850 CNTC. PS1 1990.598 CFTC. PSI 788.035 NPOR.PS1 GR.PS1 76.937 TENS.PSI 2960.000 CCL.PS1 -999.250 18.246 474.442 1954.509 18.246 23.194 704.839 2280.185 19.661 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 22 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 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 SUFm~a~Y VENDOR TOOL CODE START DEPTH ........................... CNTG 9419.5 $ LOG HEADER DATA STOP DEPTH 8791.5 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 GAMMA 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) : 16-0CT-98 8Cl -205 1912 16-0CT-98 9414.0 9390.0 8790.0 9383.0 TOOL NUMBER SGC- SA CNT-G 8.500 9535.0 CRUDE LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 23 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): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO SWS SONIC DATED 20-JUL-1980 PUMPED 271 BBLS CRUDE / 80 BBL SEA WATER TO KNOCK DOWN WELL @ 1BBL/MIN. PUMPED 70 BBL SEA WATER DURING LOGGING @ 1BBL/FIIN PUMPED 62 BBLS CRUDE DURING LOGGING @ 1BBL/MIN PUMPED 10 BBLS DIESEL TO CLEAR LINES LOGGED THREE PASSES AT 30 FPM TAGGED PBTD AT 9394'. GOC PICK ESTIMATED AT 9180'. 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 24 TYPE REPR CODE VALUE .............................. 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** 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 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 EArR~PS2 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1224652 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9419.500 NPHI.PS2 19.375 ENPH. PS2 25.235 TNPH. PS2 TNRA.PS2 2.442 RTNR.PS2 2.500 ENRA.PS2 4.152 CFEC. PS2 CNEC.PS2 2466.069 RCEF. PS2 601.612 RCEN. PS2 2331.060 RCNT. PS2 RCFT. PS2 723.048 CNTC. PS2 1792.110 CFTC. PS2 751.635 NPOR.PS2 GR.PS2 38.268 TENS.PS2 2200.000 CCL.PS2 0.042 DEPT. 8791.500 NPHI.PS2 13.575 ENPH. PS2 19.580 TNPH.PS2 TNRA.PS2 2.035 RTNR.PS2 2.066 ENRA. PS2 3.498 CFEC. PS2 CNEC. PS2 3274.303 RCEF. PS2 998.574 RCEN. PS2 3126.801 RCNT. PS2 RCFT. PS2 1254.927 CNTC. PS2 2619.917 CFTC. PS2 1301.011 NPOR.PS2 GR.PS2 47.100 TENS. PS2 2963.000 CCL.PS2 -999.250 21.145 593.966 1829.715 21.145 17. 302 964. 302 2811.296 18.151 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 25 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~M_ARY VENDOR TOOL CODE START DEPTH ........................... CNTG 9416.5 $ LOG HEADER DATA STOP DEPTH 8788.0 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 GAMMA RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 16-0CT-98 8C1-205 1912 16-0CT-98 9414.0 9390.0 8790.0 9383.0 TOOL NUMBER SGC-SA CNT-G 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 26 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) : 9535.0 CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPI 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) : 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 15000 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO SWS SONIC DATED 20-JUL-1980 PUMPED 271 BBLS CRUDE / 80 BBL SEA WATER TO KNOCK DOWN WELL @ 1BBL/MIN. PUMPED 70 BBL SEA WATER DURING LOGGING @ 1BBL/MIN PUMPED 62 BBLS CRUDE DURING LOGGING @ 1BBL/MIN PUMPED 10 BBLS DIESEL TO CLEAR LINES LOGGED THREE PASSES AT 30 FPM TAGGED PBTD AT 9394 '. GOC PICK ESTIMATED AT 9180'. THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 27 ** 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 ELM CODE (HEX) DEPT FT 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1224652 O0 000 O0 0 7 I 1 4 68 0000000000 ENPH PS3 PU 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 ENRA PS3 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS$ CPS 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 1224652 O0 000 O0 0 7 1 i 4 68 0000000000 RCEN PS3 CPS 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR PS3 PU 1224652 O0 000 O0 0 7 I 1 4 68 0000000000 GR PS3 GAPI 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1224652 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-NOV-1998 12:55 PAGE: 28 DEPT. 9416.500 NPHI.PS3 TNRA.PS3 3.321 RTNR.PS3 CNEC. PS3 4546.561 RCEF. PS3 RCFT. PS3 606.171 CNTC. PS3 GR.PS3 49.571 TENS. PS3 DEPT. 8788.000 NPHI.PS3 TNRA.PS3 2.198 RTNR.PS3 CNEC. PS3 3433.121 RCEF. PS3 RCFT. PS3 1171.620 CNTC. PS3 GR.PS3 39.270 TENS.PS3 34.981 ENPH. PS3 3.~00 ENRA.PS3 974.410 RCEN. PS3 2052.616 CFTC. PS3 236I~000 CCL.PS3 15.808 ENPH. PS3 2.110 ENRA. PS3 1071.012 RCEN. PS3 2607.600 CFTC. PS3 2912.000 CCL.PS3 30.634 TNPH. PS3 4 . 726 CFEC. PS3 4297 . 650 RCNT. PS3 630.13 6 NPOR. PS3 O. 420 17.173 TNPH. PS3 3 . 202 CFEC. PS3 3228. 716 RCNT. PS3 1220. 800 NPOR. PS3 -999.25O 34.300 962.024 2095.687 34.300 17.635 1072.043 2713.627 17.112 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC TAPE NAME : 98558 CONTINUATION # : 1 PREVIOUS TAPE '. CO~IENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-15, API# 50-029-20459-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 3 ORIGIN : FLIC REEL NAME : 98558 CONTINUATION # : PREVIOUS REEL : COlVi~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 6-15, API# 50-029-20459-00 * ALASKA COMPUTING CENTER . ****************************** * ............................ * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS 6-15 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292045900 REFERENCE NO : 98571 RECEIVED 1999 At~ Oil & G~'Con$. Commi~ion LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/02/24 ORIGIN : FLIC REEL NAME : 98571 CONTINUATION # : PREVIOUS REEL : COMFiENT : ARCO ALASKA, INC., DS 6-15, PRUDHOE BAY, #50-029-20459-00 * * * * TAPE HEADER * * * * SERVICE NAME : EDIT DATE : 99/02/24 ORIGIN : FLIC TAPE NAME : 98571 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., DS 6-15, PRUDHOE BAY, #50-029-20459-00 TAPE HEADER PRUDHOE BAY' CASED HOLE WIRELINE LOGS WELL NAME: DS 6-15 API NUMBER: 500292045900 OPERATOR: ARCO Alaska, Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-FEB-99 JOB NUMBER: 98571 LOGGING ENGINEER: D.PALMER OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 2 TOWNSHIP: iON RANGE: 14E FNL: FSL: 323 FEL: 1736 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 68.00 DERRICK FLOOR: 67.00 GROUND LEVEL: 32.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT)WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 9535.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 20-JUL-80 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9381.0 9374.5 9363.0 9361.0 9357.0 9348.5 9348.0 9338.5 9328.5 9309.0 9300.0 9298.5 9297.5 9275.0 9274.5 9245.0 9239.5 9237.5 9206.5 9205.0 9163.5 9162.0 9075.5 9071.5 9071.0 9053.0 9052.5 9007.0 9006.5 9002.0 8991.0 8933.5 8933.0 8923.5 8922.5 8913.5 8912.5 8901.0 8860.0 8854.0 8848.5 8847.5 8840.0 8828.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.5 88889.5 9382.5 9375.5 9363.5 9349.0 9339.0 9329.0 9299.0 9275.5 9239.5 9206.5 9163.0 9072.5 9054.5 9008.5 9003.5 8935.0 8925.0 8915.0 8855.5 8850.0 8842.0 93 63.5 9358.5 9349.0 9329.5 9310.0 9301.0 9299.0 9275.5 9246.5 9239.5 9206.5 9163.0 9077.5 9072.5 9054.5 9008.5 9003.5 8993.0 8935.0 8925.0 8915.0 8903.0 8863.0 8855.5 8850.0 8842.0 8830.5 PAGE~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 8821.0 8822.5 8822.5 100.0 101.5 101.5 $ REMARKS: CONTAINED HEREIN IS THE RST SIGMA-MODE DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 6-15 ON 18-0CT-98. THE DEPTH SHIFTS SHOWN ABOVEREFLECT RST SIGMA-MODE PASS #1 GRCH TO THE BASELINE GAF~A RAY PROVIDED BY THE CLIENT (GR.BCS); AND RST SIGMA-MODE PASS #1 SIGM TO GR.BCS. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCRE~fEAUf: 0.5000 FILE SU~IMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9368.0 8808.0 RST 9384.0 8808.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 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 ELEM CODE (HEX) DEPT FT 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1189346 O0 000 O0 0 i 1 1 4 68 0000000000 SFFA FIL CU 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 CIRN FIL 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 BSAL RST PPK 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 CRRA RST 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1189346 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: ** DATA ** DEPT. 9500.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF.FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC. RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH.RST -999.250 TENS.RST -999.250 CCL.RST -999.250 GR.BCS DEPT. 8700.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNAoFIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC. RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF.RST -999.250 CRRA.RST GRCH. RST -999.250 TENS.RST -999.250 CCL.RST -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 91.063 -999 250 -999 250 -999 250 -999 250 -999 250 103 125 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE ' 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 99/02/24 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 NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: GRCH 9366.0 8754.0 RST 9382.0 8754.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS--ER: 1 BASELINE DEPTH 88888,0 9374.5 9363.5 9361.0 9354.5 9340.0 9330.0 9328.0 9299 0 9294 5 9284 0 9274 0 9253 5 9244 5 92280 9218.5 9205.5 9200.5 9178.5 9162.0 9139.5 9101.5 9072.5 9070.5 9054.O 9052.0 9007.0 9006.5 8975.0 8944.0 8934.0 8914.0 8912.5 8890.5 8874.5 8860.0 8857.5 8854.5 8854.0 8852.0 8841.0 8839.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.0 88890.0 9376.5 9363.5 9330.0 9299.0 9283.5 9227.5 9219.0 9200.0 9072.5 9054.5 9008.5 8934.5 8915.0 8855.0 8842.0 9363.5 9356.0 9341.0 9329.5 9296.0 9275.0 9255.0 9246.5 9207.5 9180.0 9163.0 9141.0 9103.5 9072.5 9054.5 9008.5 8977.0 8946.0 8915.0 8892.5 8877.5 8863.0 8860.0 8856.5 88~4.5 8842.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 8818.5 8817.0 8818.0 i00.0 101.0 8820.5 102.0 REFIARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 SIGH TO PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE AU3MB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1189346 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 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) CIRNFIL 1189346 O0 000 CIRF FIL 1189346 O0 000 BSALRST PPK 1189346 O0 000 SIBF RST CU 1189346 O0 000 TPHI RST PU-S 1189346 O0 000 SFFC RST CU 1189346 O0 000 SFNC RST CU 1189346 O0 000 SIGM RST CU 1189346 O0 000 DSIG RST 1189346 O0 000 FBEF RST UA 1189346 O0 000 CRRARST 1189346 O0 000 GRCH RST GAPI 1189346 O0 000 TENS RST LB 1189346 O0 000 CCL RST V 1189346 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 i 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. 9384.000 NBAC.RST 2137.255 FBAC.RST 3574.024 SBNA.FIL SFNA.FIL 23.318 SBFA.FIL 41.319 SFFA.FIL 20.963 TRAT. FIL IRAT. FIL 0.488 CIRN. FIL 0.983 CIRF. FIL 2.071 BSAL.RST SIBF. RST 43.567 TPHI.RST 28.158 SFFC.RST 18.190 SFNC.RST SIGM. RST 18.217 DSIG.RST 1.176 FBEF. RST 60.589 CRRA.RST GRCH. RST -999.250 TENS.RST 1060.000 CCL.RST 0.001 DEPT. 8755.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC. RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH.RST 80.197 TENS.RST -999.250 CCL.RST -999.250 57.097 0.966 60.393 18.854 2.018 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 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 NUM~ER: 3 DEPTH INCREMENT: 0.5000 FILE SUF~r~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9366.0 8776.0 RST 9382.0 8776.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9374.5 9361.0 9356.5 9349.0 9347.5 9334.0 9329.5 9328.0 9309.0 9306.0 9299.0 9296.0 9294.0 9284.0 9280.0 9276.0 9274.0 9270.0 9261.5 9256.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.5 88889.5 9349.5 9329.5 9310.0 9299.0 9296.5 9284.0 9280.5 9275.5 9261.0 9376.0 9363.5 9358.5 9349.0 9335.0 9329.5 9307.5 9296. 0 9275.0 9271.5 9257.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 10 9252.0 9252.5 9244.5 9246.5 9244.0 9243.5 9237.0 9239.5 9236.0 9236.0 9228.0 9228.0 9207.0 9207.0 9206.0 9208.0 9201.0 9200.0 9178.0 9179.5 9165.5 9166.5 9139.5 9141.0 9134.0 9132.0 9104.0 9105.5 9072.0 9072.5 9070.5 9072.5 9054.0 9054.5 9052.5 9054.5 9045.5 9047.5 9007.0 9008.5 9006.5 9008.5 8973.5 8973.5 8967.0 8969.0 8934.5 8935.0 8932.5 8934.5 8924.5 8927.0 8923.5 8924.5 8914.5 8915.0 8912.5 8915.0 8901.5 8903.5 8875.0 8877.5 8872.5 8875.0 8861.0 8863.0 8860.0 8863.0 8858.0 8860.5 8854.5 8855.5 8852.5 8854.5 8841.0 8843.5 8821.5 8822.0 8818.5 8820.0 100.0 100.5 101.5 $ REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTHCORRECTEDDATA FOR RST SIGMA-MODE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 SIGM TO PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** 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 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA FIL CU 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA FIL CU 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT FIL 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT FIL 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNFIL 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 CIRF FIL 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 BSAL RST PPK 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RST CU 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RST PU-S 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RST CU 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RST CU 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM RST CU 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RST 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RST UA 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 CRRA RST 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 TENS RST LB 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 CCL RST V 1189346 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 12 ** DATA ** DEPT. 9383.500 NBAC.RST SFNA.FIL 24.258 SBFA.FIL IRAT. FIL 0.505 CIRN. FIL SIBF. RST 43.845 TPHI.RST SIGM. RST 17.817 DSIG.RST GRCH. RST -999.250 TENS.RST DEPT. 8776.500 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF.RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH.RST 73.064 TENS.RST 2775.401 FBAC.RST 45.369 SFFA.FIL 0.967 CIRF. FIL 27.323 SFFC.RST 1.281 FBEF. RST 1070.000 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF. RST -999.250 CCL.RST 3418.004 SBNA.FIL 20.516 TRAT. FIL 2.036 BSAL.RST 17.801 SFNC.RST 59.997 CRRA.RST 0.000 -999.250 SBNA.FIL -999.250 TRAT.FIL -999.250 BSAL.RST -999.250 SFNC.RST -999.250 CRRA.RST -999.250 53.737 0.953 61.147 19.664 1.991 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 9360.0 RST 9376.0 STOP DEPTH 9128.0 9128.0 24-FEB-1999 13:40 PAGE: 13 LIS Tape Verification Listing Schlumberger Alaska Computing Center $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9371o 0 9374.0 9359.5 9358.5 9363.5 9355 o 5 9358.5 9350 o 5 9352.5 9344 o 5 9347.0 9344 . 0 9347.5 9329° 0 9330.0 9327° 0 9329.5 9305° 0 9307.5 9298 o 5 9299.5 9301.0 9296.0 9299.0 9272 o 5 9275.0 9260 o 5 9261.0 9255.0 9257.5 9243° 5 9247.0 9242° 5 9243.0 9228 o 0 9228.5 9221o 5 9225.0 9217 . 0 9216.5 9204 o 5 9207.5 9202° 5 9203.5 9200° 5 9200.5 9196o 0 9199.5 9177 o 0 9179.5 9164o 0 9163.5 9161o 0 9163.5 9151 o 0 9153.5 9138.5 9141 . 0 100.0 99.5 102.5 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88887.0 88891.0 REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR RST SIGMA-MODE PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #4 GRCH TO PASS #1GRCH; AND PASS #4 SIGM TO PASS #1 SIGM. ALL OTHER RST SIGMA-MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 14 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT FIL 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRST PPK 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RST CU 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RST PU-S 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RST CU 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RST CU 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RST CU 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RST 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RST UA 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARST 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1189346 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 15 ** DATA ** DEPT. 9379.000 NBAC.RST SFNA.FIL 23.786 SBFA.FIL IRAT. FIL 0.508 CIRN. FIL SIBF. RST 45.971 TPHI.RST SIGM. RST 20.038 DSIG.RST GRCH.RST -999.250 TENS.RST DEPT. 9127.500 NBAC. RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF.RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST 48.147 TENS.RST 2380.570 FBAC. RST 42.967 SFFA.FIL 0.946 CIRF. FIL 30.408 SFFC.RST 0.621 FBEF.RST 1083.000 CCL.RST -999.250 FBAC.RST -999.250 SFFA.FIL -999.250 CIRF. FIL -999.250 SFFC.RST -999.250 FBEF.RST -999.250 CCL.RST 3041.065 SBNA.FIL 22.874 TRAT. FIL 1.768 BSAL.RST 20.027 SFNC. RST 59.774 CRRA.RST 0.000 -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC. RST -999.250 CRRA.RST -999.250 62.194 0.994 66.908 19.534 1.977 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS RST 1, 2, 3, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 16 REMARKS: THE ARITHMETIC AVERAGE OF PASSES 1, 2, & 3 WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. *NOTE: PASS #4 WAS NOT INCLUDED IN THE AVERAGE BECAUSE IT IS A SHORT INTERVAL. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 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 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC RST CPS 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA RSAV CU 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA RSAV CU 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA RSAV CU 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA RSAV CU 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT RSAV 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT RSAV 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNRSAV 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF RSAV 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL RSAV PPK 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RSAV CU 1189346 O0 000 O0 0 $ 1 1 4 68 0000000000 TPHI RSAV PU-S 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 17 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) SFFC RSAV CU 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC RSAV CU 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM RSAV CU 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG RSAV 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF RSAV UA 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 CRRARSAV 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1189346 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPTo 9385.500 NBAC.RST 3249.130 FBAC.RST 3861.905 SBNA.RSAV -999.250 SFNAoRSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBFoRSAV -999.250 TPHI.RSAV -999.250 SFFC. RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV -999.250 CRRA.RSAV -999.250 GRCHoRST -999.250 DEPT. 8809.500 NBAC.RST 2406.774 FBAC. RST 3265.742 SBNA.RSAV 50.767 SFNA.RSAV 29.334 SBFA.RSAV 43.718 SFFA.RSAV 29.870 TRAT. RSAV 1.089 IRAT.RSAV 0.503 CIRN. RSAV 0.889 CIRF. RSAV 1.613 BSAL.RSAV 30.758 SIBFoRSAV 32.863 TPHI.RSAV 32.564 SFFC. RSAV 27.454 SFNC.RSAV 26.212 SIGM. RSAV 27.367 DSIG.RSAV -0.718 FBEF. RSAV 59.045 CRRA.RSAV 1.933 GRCH. RST 297.657 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 99/02/24 MAX REC siZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 18 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: 1 DEPTH INCREMENT: 0.5000 FILE SUMFLARY VENDOR TOOL CODE START DEPTH RST 9411.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 8712.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESEVOIR SATURATION $ 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): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 18-0CT-98 8Cl-205 1200 10-0CT-98 9400.0 9400.0 8800.0 9395.0 1800.0 NO TOOL NUMBER GR RST-A 8.500 9535.0 CRUDE OIL 7.50 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 19 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO BHC SONIC OF 20-JUL-1980 RAN ALL NEUTRON LOGS FOR A COMPARISON OF GAS SATURATION LOGGING WITH DIFFERENT LOGGING TOOLS WELL SHUT IN AND DEAD BEFORE LOGGING AFTER RUNNING CNTG AND MEMORY CNL ON PREVIOUS DAYS. PUMPED 275 BBLS OF CRUDE TO FLUID PACK. WELL HEAD PRESSURE REMAINED 400 PSI DURING JOB. PUMPED i BPM WHILE LOGGING WITH WHP OF 600 PSI. RAN RSTA WITH PSP FOR TELEM/GR/CCL/PRESS/SPINNER. OIL WATER CONTACT AT 9257' IN WELLBORE AFFECTING C/O RATIOS AND THE TPHI FROM RSTA V'S TDTP. 4 SIGMA PASSES MADE AT 30, 60, 60, & 90 FPM 3 C/O PASSES MADE AT 150 FT/HOUR 9400-9050 FT. THIS FILE CONTAINS THE RAW RST SIGMA-MODE 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 73 364 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 20 ** 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 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS1 F/HR 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 NPHVPS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PSi 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS1 S 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CP5V PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS1 1189346 O0 000 O0 0 6 I 1 4 68 0000000000 RCRC PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RCAK PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS1 S 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS1 PSIG 1189346 O0 000 O0 0 6 I 1 4 68 0000000000 HVPV PS1 V 1189346 O0 000 O0 0 6 I 1 4 68 0000000000 BMCU PS1 UA 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PS1 MA 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS1 UA 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS1 UA 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS1 UA 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 XP5V PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 X~42V PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PSi 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RXAK PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS1 MA 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS1 PPK 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 1189346 O0 000 O0 0 6 i 1 4 68 0000000000 CIRN PS1 1189346 O0 000 O0 0 6 I 1 4 68 0000000000 CIRF PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 21 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) O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS1 1189346 FBAC PS1 CPS 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS1 CPS 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS1 CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS1 CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS1 CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS1 CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS1 CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PSl CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS1 CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS1 CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS1 KHZ 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS1 KHZ 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS1 DEGC 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS1 DEGC 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS1 AMP 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS1 AMP 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PSI PU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS1 V 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS1 1189346 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9411.500 CS.PSI 751.566 TENS.PSI 780.000 NPHV. PS1 NPDE. PSI 1549.875 NSCE. PS1 2.557 C~.PS1 2.036 NSCR.PSl AQTM. PS1 0.661 CHV. PS1 202.792 CPSV. PS1 5.069 CP2V. PS1 CM2V. PS1 -12.211 RCFR.PS1 0.000 RCLC. PS1 0.000 RCRC. PS1 RCAK. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 1489.259 FPDE. PS1 1562.501 -0.955 12.114 0.000 1471.788 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 22 FSCE. PS1 2.030 FSCR.PS1 HVPV. PS1 160.156 BMCU. PS1 NBEF. PS1 28.817 FBEF. PS1 BSTR.PS1 61.398 BSPR.PS1 XPSV. PS1 5.069 XP2V. PS1 RXLC. PS1 0.000 RXRC.PS1 BSAL. PS1 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS1 -999.250 IRAT. FIL SFFA.PS1 -999.250 SBNA.PSi SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -99~.250 SBNA.FIL SFNC. PSl -999.250 SFFC.PS1 SIGM. SIG -999.250 TRAT. PS1 GR. PSI 51. 615 RDIX. PS1 CTM. PS1 89. 356 XTM. PS1 BUST. PS1 3 . 000 BUSP. PS1 TPHI. SIG -999. 250 CCLC. PS1 DEPT. 8711.000 CS.PSI NPDE. PSl 1551.744 NSCE. PS1 AQTM. PS1 1.102 CHV. PS1 CM2V. PS1 -12.231 RCFR.PS1 RCAK. PS1 0.000 RTDF. PS1 FSCE. PS1 1.975 FSCR.PS1 HVPV. PSi 160.677 BMCU. PS1 NBEF. PS1 29.730 FBEF. PS1 BSTR.PS1 63.742 BSPR.PS1 XPSV. PS1 5.070 XP2V. PS1 RXLC. PS1 0.000 RXRC.PS1 BSAL. PS1 28.559 BSAL.SIG CIRN. FIL 0.891 CIRF. FIL IRAT. PS1 0.508 IRAT. FIL SFFA.PSI 29.835 SBNA.PS1 SFFA. SIG 0.527 SBNA.SIG SFFA.FIL 29.413 SBNA.FIL SFNC.PS1 25.954 SFFC.PS1 SIGM. SIG 0.437 TRAT. PS1 GR.PS1 61.775 RDIX.PS1 CTM. PS1 83.740 XTM. PS1 BUST. PSi 3.000 BUSP.PS1 TPHI.SIG 0.883 CCLC.PS1 -0.448 AQTF. PS1 31.933 GDCU. PS1 58.678 NPGF. PS1 1.081 MARC. PSI 12.188 XI¥2V. PS1 0.000 RXAK. PS1 -999.250 CIRN. PS1 -999.250 DSIG.PS1 -999.250 NBAC. PS1 -999.250 SBFA. PS1 -999.250 SBFA.SIG -999.250 SBFA.FIL -999.250 SIGM. PS1 -999.250 TRAT. SIG 47485.000 CRNI.PS1 89.356 FICU. PS1 3.000 RSXS.PS1 -0.057 RSCS.PS1 0.661 59.684 0.996 0.000 -12.368 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 447.308 2.593 8878.000 8459.000 1811.154 TENS. PSI 1013.000 2.510 CRRA.PS1 1.871 202.671 CPSV. PS1 5.060 0.000 RCLC. PS1 0.000 0.000 FPHV. PS1 1496.583 0.074 AQTF. PS1 1.102 33.105 GDCU. PS1 60.055 55.622 NPGF. PS1 1.007 1.097 MARC. PSi 0.000 12.183 XM2V. PS1 -12.378 0.000 RXAK. PS1 0.000 2.778 CIRN. PS1 0.922 1.638 DSIG.PS1 -1.030 0.507 NBAC. PSl 2406.774 48.758 SBFA.PSl 40.266 2.977 SBFA.SIG 3.623 49.529 SBFA. FIL 42.357 27.077 SIGM. PS1 27.075 1.088 TRAT. SIG 0.020 66851.000 CRNI.PS1 444.826 82.682 FICU. PS1 2.541 3.000 RSXS. PS1 8878.000 -999.250 RSCS. PS1 8463.000 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 CACU. PS1 TPHI.PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 CACU. PS1 TPHI. PS1 135.745 3.551 1.003 200.370 0.000 56.259 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 219 678 2.627 -999.250 1566.163 -0.459 12.143 0.000 1481.401 142.688 3.814 1.001 200.143 0.000 38.113 1.647 3265.742 29.409 0.510 29.164 32.084 0.983 1.070 237.761 2.624 30.888 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 23 **** FILE TRAILER **** FILE NAME : EDIT ~006 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 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: 2 DEPTH INCREMENT: 0.5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH RST 9413.0 $ LOG HEADER DATA STOP DEPTH 8657.5 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 GAMiWiA RAY RST RESEVOIR SATURATION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 18-0CT-98 8Cl-205 1200 10-0CT-98 9400.0 9400.0 8800.0 9395.0 3600.0 NO TOOL NUMBER GR RST-A 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 24 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) : 9535.0 CRUDE OIL 7.50 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO BHC SONIC OF 20-JUL-1980 RAN ALL NEUTRON LOGS FOR A COMPARISON OF GAS SATURATION LOGGING WITH DIFFERENT LOGGING TOOLS WELL SHUT IN AND DEAD BEFORE LOGGING AFTER RUNNING CNTG AND MEMORY CNL ON PREVIOUS DAYS. PUMPED 275 BBLS OF CRUDE TO FLUID PACK. WELL HEAD PRESSURE REMAINED 400 PSI DURING JOB. PUMPED 1 BPM WHILE LOGGING WITH WHP OF 600 PSI. RAN RSTA WITH PSP FOR TELEM/GR/CCL/PRESS/SPINNER. OIL WATER CONTACT AT 9257' IN WELLBORE AFFECTING C/O RATIOS AND THE TPHI FROM RSTA V'S TDTP. 4 SIGMA PASSES MADE AT 30, 60, 60, & 90 FPM 3 C/O PASSES MADE AT 150 FT/HOUR 9400-9050 FT. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 25 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 364 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS2 F/HR 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS2 S 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CPSV PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RCAK PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 FPHV PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS2 S 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS2 PSIG 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS2 UA 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 26 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) GDCU PS2 MA 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS2 UA 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS2 UA 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS2 UA 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 X~2V PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS2 MA 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS2 PPK 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS2 CPS 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS2 CPS 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS2 CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS2 CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS2 CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS2 CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1189346 O0 000 O0 0 7 I 1 4 68 0000000000 SBNA FIL CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS2 CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS2 CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS2 CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS2 CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 27 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) ....................................................................................... RDIX PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS2 KHZ 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS2 KHZ 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS2 DEGC 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS2 DEGC 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS2 AMP 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS2 AMP 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS2 PU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS2 V 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS2 1189346 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA DEPT. NPDE. PS2 AQTM. PS2 CM2 V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR. PS2 XP5V. PS2 RXLC. PS2 BSAL. PS2 CIRN. FIL IRAT. PS2 SFFA. PS2 SFFA. SIG SFFA. FIL SFNC. PS2 SIGM. SIG GR. PS2 CTM. PS2 BUST. PS2 TPHI. SIG DEPT. NPDE. PS2 AQTM. PS2 CM2 V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 9413.000 1551.515 0.661 -12 211 1 000 2 036 161 377 30 140 54 139 5 069 0 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 117.014 86.426 3.000 -999.250 8656.500 1552.583 0.661 -12.250 0.000 1.975 160.889 32.238 CS.PS2 557.967 TENS.PS2 NSCE.PS2 2.533 CRRA.PS2 CHV. PS2 202.792 CP5V. PS2 RCFR.PS2 0.000 RCLC. PS2 RTDF. PS2 O . 000 FPHV. PS2 FSCR. PS2 0 . 202 AQTF. PS2 BMCU. PS2 33.398 GDCU. PS2 FBEF. PS2 60.706 NPGF. PS2 BSPR.PS2 1.141 MARC. PS2 XP2V. PS2 12.188 XM2V. PS2 PJfRC. PS2 0.000 PJfAK. PS2 BSAL.SIG -999.250 CIRN. PS2 CIRF. FIL -999.250 DSIG. PS2 IRAT. FIL -999.250 NBAC. PS2 SBNA.PS2 -999.250 SBFA. PS2 SBNA.SIG -999.250 SBFA.SIG SBNA.FIL -999.250 SBFA.FIL SFFC. PS2 -999.250 SIGM. PS2 TRAT. PS2 -999.250 TRAT. SIG RDIX. PS2 73623.000 CRNI.PS2 XTM. PS2 83.984 FICU. PS2 BUSP.PS2 3.000 RSXS.PS2 CCLC. PS2 -0.019 RSCS. PS2 CS.PS2 3621.083 TENS. PS2 NSCE. PS2 2.544 CRRA. PS2 CHV. PS2 201.581 CPSV. PS2 RCFR.PS2 0.000 RCLC. PS2 RTDF. PS2 0.000 FPHV. PS2 FSCR.PS2 -0.010 AQTF. PS2 BMCU. PS2 35.407 GDCU. PS2 FBEF. PS2 61.735 NPGF. PS2 738.000 2.014 5.060 0.000 1494 142 0 661 59 684 1 000 0 000 -12 387 0 000 -999250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 449.573 2.563 8878.000 8459.000 1009.000 1.915 5.069 0.000 1501.466 0.661 59.871 0.999 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC.PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI. PS2 CACU. PS2 TPHI.PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 1572. 267 - O. 021 12.129 0.000 1480.256 146.235 3. 551 1. 000 200.127 0.000 35. 772 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 223.206 2. 622 -999.250 1562 501 0 056 12 114 0 000 1482 316 144 810 2 987 0.994 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 28 BSTR.PS2 81.500 BSPR.PS2 XPSV. PS2 5.072 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 16.529 BSAL.SIG CIRN. FIL 0.703 CIRF.FIL IRAT. PS2 0.507 IRAT. FIL SFFA.PS2 36.137 SBNA.PS2 SFFA. SIG 1.419 SBNA.SIG SFFA.FIL 35.601 SBNA.FIL SFNC. PS2 32.449 SFFC. PS2 SIGM. SIG 0.902 TRAT. PS2 GR.PS2 52.004 RDIX. PS2 CTM. PS2 83.984 XTM. PS2 BUST. PS2 3.000 BUSP.PS2 TPHI.SIG 1.796 CCLC. PS2 1.032 MARC.PS2 12.183 XM2V. PS2 0.000 RXAK. PS2 3.407 CIRN. PS2 1.037 DSIG.PS2 0.503 NBAC.PS2 50.107 SBFA.PS2 4.667 SBFA.SIG 48.823 SBFA.FIL 34.975 SIGM. PS2 1.306 TRAT. SIG 83823.000 CRNI.PS2 83.008 FICU. PS2 3.000 RSXS.PS2 -999.250 RSCS.PS2 0.000 XHV. PS2 -12.393 RXFR.PS2 0.000 SHCU. PS2 0.713 CIRF. PS2 -0.784 FBAC. PS2 2294.352 SFNA.PS2 38.874 SFNA.SIG 6.428 SFNA.FIL 41.141 SIBF. PS2 34.380 SIBF. SIG 0.040 TRAT. FIL 439.197 CRFI.PS2 2.611 CACU. PS2 8878.000 TPHI.PS2 8459.000 200.162 0.000 35.121 0.979 3051.694 31.426 0.980 32.305 27. 858 1.188 1. 304 229.345 2.626 42.890 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RST 9408.0 8676.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 29 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): 18-0CT-98 8C1-205 1200 10-0CT-98 9400.0 9400.0 8800.0 9395.0 3600.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY RST RESEVOIR SATURATION $ TOOL NUMBER GR RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 9535.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~IPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE OIL 7.50 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO BHC SONIC OF 20-JUL-1980 RAN ALL NEUTRON LOGS FOR A COMPARISON OF GAS SATURATION LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 30 LOGGING WITH DIFFERENT LOGGING TOOLS WELL SHUT IN AND DEAD BEFORE LOGGING AFTER RUNNING CNTG AND MEMORY CNL ON PREVIOUS DAYS. PUMPED 275 BBLS OF CRUDE TO FLUID PACK. WELL HEAD PRESSURE REMAINED 400 PSI DURING JOB. PUMPED 1 BPM WHILE LOGGING WITH WHP OF 600 PSI. RAN RSTA WITH PSP FOR TELE~/GR/CCL/PRESS/SPINNER. OIL WATER CONTACT AT 9257' IN WELLBORE AFFECTING C/O RATIOS AND THE TPHI FROM RSTA V'S TDTP. 4 SIGMA PASSES MADE AT 30, 60, 60, & 90 FPM 3 C/O PASSES MADE AT 150 FT/HOUR 9400-9050 FT. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 364 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS3 F/HR 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 31 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) CRRAPS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS3 S 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS3 V 1189346 O0 000 O0 0 8 I 1 4 68 0000000000 CPSV PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RCAKPS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 FPHV PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 FPDE PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS3 S 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS3 PSIG 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 HVPV PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS3 UA 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 GDCU PS3 MA 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS3 UA 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS3 UA 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS3 UA 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 XHV PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 XPSV PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 XM2V PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 R_M_RCPS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RXAKPS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS3 MA 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS3 PPK 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNPS3 1189346 '00 000 O0 0 8 1 1 4 68 0000000000 CIRF PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 DSIG PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS3 CPS 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS3 CPS 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS3 CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS3 CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 32 NAME SERVPIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBNA PS3 CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA PS3 CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA FIL CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA FIL CU 1189346 O0 000 O0 0 8 1 1 4 68 ' 0000000000 SBFA FIL CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF PS3 CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SFNC PS3 CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SFFC PS3 CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS3 CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF SIG CU 1189346 O0 000 O0 0 8 i 1 4 68 0000000000 SIGM SIG CU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT SIG 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT FIL 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RDIX PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CRNI PS3 KHZ 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CRFI PS3 KHZ 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CTM PS3 DEGC 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 XTM PS3 DEGC 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 FICU PS3 AMP 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CACU PS3 AMP 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 BUST PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 BUSP PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RSXS PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS3 PU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI SIG PU 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 CCLC PS3 V 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 RSCS PS3 1189346 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 9408.000 CS.PS3 909.550 TENS.PS3 787.000 NPHV. PS3 NPDE. PS3 1551.706 NSCE. PS3 2.563 CRRA.PS3 2.000 NSCR.PS3 AQTM. PS3 0.661 CHV. PS3 202.792 CPSV. PS3 5.069 CP2V. PS3 CM2V. PS3 -12.191 RCFR.PS3 0.000 RCLC. PS3 0.000 RCRC. PS3 RCAK. PS3 1.000 RTDF. PS3 0.000 FPHV. PS3 1491.700 FPDE. PS3 FSCE. PS3 2.004 FSCR.PS3 -0.329 AQTF. PS3 0.661 SF6P. PS3 HVPV. PS3 160.889 BMCU. PS3 33.691 GDCU. PS3 60.668 EXCU. PS3 NBEF. PS3 30.195 FBEF. PS3 60.399 NPGF. PS3 1.003 FPGF. PS3 BSTR.PS3 58.758 BSPR.PS3 1.083 MARC.PS3 0.000 XHV. PS3 XP5V. PS3 5.079 XP2V. PS3 12.173 XM2V. PS3 -12.407 RXFR.PS3 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 0.000 SHCU. PS3 BSAL. PS3 -999.250 BSAL.SIG -999.250 CIRN. PS3 -999.250 CIRF. PS3 1562.501 0.092 12.114 0.000 1481.019 148.282 3.551 1.000 199.885 0.000 36.097 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 33 CIRN. FIL -999.250 CIRF.FIL -999.250 DSIG.PS3 IRAT. PS3 -999.250 IRAT. FIL -999.250 NBAC.PS3 SFFA.PS3 -999.250 SBNA.PS3 -999.250 SBFA.PS3 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS3 -999.250 SFFC. PS3 -999.250 SIGM. PS3 SIGM. SIG -999.250 TRAT. PS3 -999.250 TRAT. SIG GR.PS3 129.038 RDIX. PS3 89951.000 CRNI.PS3 CTM. PS3 87.402 XTM. PS3 84.961 FICU. PS3 BUST.PS3 3.000 BUSP.PS3 3.000 RSXS.PS3 TPHI.SIG -999.250 CCLC. PS3 -0.019 RSCS.PS3 DEPT. 8675.000 CS.PS3 3616.793 TENS.PS3 NPDE. PS3 1552.812 NSCE. PS3 2.485 CRRA.PS3 AQTM. PS3 0.661 CHV. PS3 202.066 CP5V. PS3 CM2V. PS3 -12.250 RCFR.PS3 0.000 RCLC. PS3 RCAK. PS3 0.000 RTDF. PS3 0.000 FPHV. PS3 FSCE. PS3 1.967 FSCR.PS3 -0.082 AQTF. PS3 HVPV. PS3 160.919 BMCU. PS3 33.545 GDCU. PS3 NBEF. PS3 30.716 FBEF. PS3 61.745 NPGF. PS3 BSTR.PS3 87.476 BSPR.PS3 1.137 MARC. PS3 XP5V. PS3 5.071 XP2V. PS3 12.182 X~2V. PS3 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 BSAL.PS3 24.897 BSAL.SIG 3.537 CIRN. PS3 CIRN. FIL 1.099 CIRF.FIL 2.289 DSIG.PS3 IRAT. PS3 0.542 IRAT.FIL 0.542 NBAC. PS3 SFFA.PS3 21.200 SBNA.PS3 52.414 SBFA.PS3 SFFA.SIG 0.408 SBNA.SIG 4.107 SBFA.SIG SFFA.FIL 21.271 SBNA.FIL 56.662 SBFA.FIL SFNC.PS3 17.496 SFFC.PS3 18.596 SIGM. PS3 SIGM. SIG 0.299 TRAT. PS3 0.887 TRAT. SIG GR.PS3 70.819 RDIX. PS3 99818.000 CRNI.PS3 CTM. PS3 83.008 XTM. PS3 82.642 FICU. PS3 BUST. PS3 3.000 BUSP.PS3 3.000 RSXS.PS3 TPHI.SIG 0.727 CCLC.PS3 -999.250 RSCS.PS3 ** END OF DATA ** -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 447.759 2.568 8878.000 8459.000 1009.000 2.010 5.089 0.000 1508.790 0.661 60.258 0.992 0.000 -12.373 0.000 1 088 -1 110 2347 594 43 932 4 659 45 639 18 574 0 017 435.769 2.561 8878.000 8463.000 FBAC.PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF. PS3 SIBF. SIG TRAT. FIL CRFI.PS3 CACU. PS3 TPHI.PS3 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P. PS3 EXCU. PS3 FPGF. PS3 XHV. PS3 RXFR.PS3 SHCU. PS3 CIRF. PS3 FBAC. PS3 SFNA.PS3 SFNA.SIG SFNA.FIL SIBF.PS3 SIBF. SIG TRAT. FIL CRFI.PS3 CACU. PS3 TPHI.PS3 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 223.846 2.627 -999.250 1562.501 -0 193 12 173 0 000 1482 583 146 044 3 501 1.003 200.158 0.000 37.845 2.243 3085.153 22.653 0.491 22.805 30.791 1.246 0.884 216.780 2.624 18.704 **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 34 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0. 5000 FILE SUA1FiARY VENDOR TOOL CODE START DEPTH ........................... RST $ LOG HEADER DATA DATE LOGGED: 9394.0 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 9087.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~VA RAY RST RESEVOIR SATURATION $ 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) : 18-0CT-98 8Cl-205 1200 10-0CT-98 9400.0 9400.0 8800.0 9395.0 5400.0 NO TOOL NUMBER GR RST-A 8.500 9535.0 CRUDE OIL 7.50 LIS Tape Verification Listing Schlumberger AlaskaComputing Center 24-FEB-1999 13:40 PAGE: 35 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): 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: DEPTH CORRELATED TO BHC SONIC OF 20-JUL-1980 RAN ALL NEUTRON LOGS FOR A COMPARISON OF GAS SATURATION LOGGING WITH DIFFERENT LOGGING TOOLS WELL SHUT IN AND DEAD BEFORE LOGGING AFTER RUNNING CNTG AND MEMORY CNL ON PREVIOUS DAYS. PUMPED 275 BBLS OF CRUDE TO FLUID PACK. WELL HEAD PRESSURE REMAINED 400 PSI DURING JOB. PUMPED 1 BPM WHILE LOGGING WITH WHP OF 600 PSI. RAN RSTA WITH PSP FOR TELEM/GR/CCL/PRESS/SPINNER. OIL WATER CONTACT AT 9257' IN WELLBORE AFFECTING C/O RATIOS AND THE TPHI FROM RSTA V'S TDTP. 4 SIGMA PASSES MADE AT 30, 60, 60, & 90 FPM 3 C/O PASSES MADE AT 150 FT/HOUR 9400-9050 FT. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #4. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 364 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 36 TYPE REPR CODE VALUE 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~I CODE (HEX) DEPT FT 1189346 O0 000 O0 0 9 1. 1 4 68 0000000000 CS PS4 F/HR 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 NPHVPS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 NSCR PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMPS4 S 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CHV PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CPSV PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RCAKPS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 FPHVPS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF PS4 S 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P PS4 PSIG 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU PS4 UA 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU PS4 MA 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 EXCU PS4 UA 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF PS4 UA 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF PS4 UA 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR PS4 1189346 O0 000 O0 0 9 1 i 4 68 0000000000 BSPR PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 37 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) MARC PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 3~HV PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 X~I2V PS4 V 1189346 O0 000 O0 0 9 I 1 4 68 0000000000 RXFR PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RXAKPS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU PS4 MA 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL PS4 PPK 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CIRN PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CIRN FIL 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS4 CPS 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC PS4 CPS 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA PS4 CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA PS4 CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA PS4 CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA PS4 CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA SIG CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA SIG CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA SIG CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA SIG CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA FIL CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA FIL CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA FIL CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SBFA FIL CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF PS4 CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SFNC PS4 CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SFFC PS4 CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS4 CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SIBF SIG CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM SIG CU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT SIG 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT FIL 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RDIX PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CRNI PS4 KHZ 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CRFI PS4 KHZ 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CTM PS4 DEGC 1189346 O0 000' O0 0 9 1 1 4 68 0000000000 XTM PS4 DEGC 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 FICU PS4 AMP 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CACU PS4 AMP 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 BUST PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 38 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) BUSP PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RSXS PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS4 PU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI SIG PU 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 CCLC PS4 V 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 RSCS PS4 1189346 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 9394.000 CS. PS4 NPDE. PS4 1551.553 NSCE. PS4 AQTM. PS4 0.661 CHV. PS4 CM2V. PS4 -12.172 RCFR.PS4 RCAK. PS4 0.000 RTDF. PS4 FSCE.PS4 1.955 FSCR.PS4 HVPV. PS4 160.889 BMCU. PS4 NBEF. PS4 30.229 FBEF. PS4 BSTR.PS4 47.213 BSPR.PS4 XPSV. PS4 5.069 XP2V. PS4 RXLC.PS4 0.000 RXRC. PS4 BSAL.PS4 -999.250 BSAL.SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS4 -999.250 IRAT. FIL SFFA.PS4 -999.250 SBNA.PS4 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC.PS4 -999.250 SFFC.PS4 SIGM. SIG -999.250 TRAT. PS4 GR.PS4 91.011 RDIX. PS4 CTM. PS4 92.285 XTM. PS4 BUST. PS4 3.000 BUSP. PS4 TPHI.SIG -999.250 CCLC. PS4 DEPT. 9086.000 CS.PS4 NPDE. PS4 1554.490 NSCE. PS4 AQTM. PS4 0.661 CHV. PS4 CM2V. PS4 -12.191 RCFR.PS4 RCAK. PS4 0.000 RTDF. PS4 FSCE. PS4 1.945 FSCR.PS4 HVPV. PS4 161.035 BMCU. PS4 NBEF. PS4 30.437 FBEF. PS4 BSTR.PS4 59.947 BSPR.PS4 XPSV. PS4 5.069 XP2V. PS4 RXLC. PS4 0.000 RXRC.PS4 BSAL.PS4 2.496 BSAL.SIG CIRN. FIL 1.515 CIRF. FIL IRAT. PS4 0.567 IRAT. FIL SFFA.PS4 13.482 SBNA.PS4 SFFA.SIG 0.217 SBNA.SIG 5496.184 2.470 202.550 0.000 0.000 -0.197 33.398 59.774 1.056 12.188 0.000 -999.250 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 107203 000 89 356 3.000 -0.010 5419.310 2.512 203.277 0.000 0.000 0.004 34.277 55.132 1.102 12.182 0.000 3. 384 3. 292 0.568 53.602 4.223 TENS.PS4 CRRA.PS4 CPSV. PS4 RCLC. PS4 FPHV. PS4 AQTF. PS4 GDCU. PS4 NPGF. PS4 MARC. PS4 XM2V. PS4 RXAK. PS4 CIRN. PS4 DSIG.PS4 NBAC. PS4 SBFA.PS4 SBFA.SIG SBFA.FIL SIGM. PS4 TRAT. SIG CRNI.PS4 FICU. PS4 RSXS.PS4 RSCS.PS4 TENS.PS4 CRRA.PS4 CPSV. PS4 RCLC. PS4 FPHV. PS4 AQTF. PS4 GDCU. PS4 NPGF. PS4 MARC. PS4 XM2V. PS4 RXAK. PS4 CIRN. PS4 DSIG.PS4 NBAC. PS4 SBFA.PS4 SBFA.SIG 1103.000 1.977 5.109 0.000 1499.024 0 661 60 012 0 994 0 000 -12 368 0 000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 445.364 2.524 8878.000 8463.000 1051.000 1.811 5.050 0.000 1501.466 0.661 59.881 0.998 0.000 -12.356 0.000 1.528 -0.679 2318.239 35.598 4.493 NPHV. PS4 NSCR.PS4 CP2V. PS4 RCRC. PS4 FPDE. PS4 SF6P.PS4 EXCU. PS4 FPGF. PS4 XHV. PS4 RXFR.PS4 SHCU. PS4 CIRF. PS4 FBAC. PS4 SFNA.PS4 SFNA.SIG SFNA.FIL SIBF. PS4 SIBF. SIG TRAT. FIL CRFI.PS4 CACU. PS4 TPHI.PS4 NPHV. PS4 NSCR.PS4 CP2V. PS4 RCRC. PS4 FPDE. PS4 SF6P. PS4 EXCU. PS4 FPGF. PS4 XHV. PS4 RXFR.PS4 SHCU. PS4 CIRF. PS4 FBAC. PS4 SFNA. PS4 SFNA.SIG SFNA. FIL 1564.943 0.160 12.129 0.000 1486.398 151.097 3.945 0.990 200.370 0.000 37.072 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 225.230 2.622 -999.250 1569.825 -0.116 12.026 0.000 1486.970 150.687 3.551 0.993 200.466 0.000 37.593 3.344 3179.181 15.469 0.309 15.230 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-FEB-1999 13:40 PAGE: 39 SFFA.FIL 13.612 SBNA.FIL 51.289 SBFA.FIL SFNC. PS4 8.960 SFFC. PS4 10.447 SIGM. PS4 SiGM. SIG 0.168 TRAT. PS4 0.811 TRAT. SIG GR.PS4 56.920 RDIX. PS4 109742.000 CRNI.PS4 CTM. PS4 91.797 XTM. PS4 91.992 FICU. PS4 BUST. PS4 3.000 BUSP. PS4 3.000 RSXS.PS4 TPHI.SIG 0.511 CCLC. PS4 -999.250 RSCS.PS4 35.473 10.570 0.012 449.935 2.510 8878.000 8463.000 SIBF. PS4 SIBF. SIG TRAT. FIL CRFI.PS4 CACU. PS4 TPHI.PS4 23.011 1.158 0.812 248.400 2.620 13.924 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 99/02/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 99/02/24 ORIGIN : FLIC TAPE NAME : 98571 CONTINUATION # : 1 PREVIOUS TAPE : COF~4ENT : ARCO ALASKA, INC., DS 6-15, PRUDHOE BAY, #50-029-20459-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/02/24 ORIGIN : FLIC REEL NAME : 98571 CONTINUATION # : PREVIOUS REEL : COGENT ' ARCO ALASKA, INC., DS 6-15, PRUDHOE BAY, #50-029-20459-00 COMPANY NAME : ARCO ALASKA, INC, WELL NAME : D6 6-15 FIELD NA~5 : PRUDNOE BAY BOROUGH : NORTH SbOPE STATE : ~LASKA API NUMBER : 50-029-20459~00 REFERENCE NO : 94086 RECEIV'ED MAY 2 7 1994 Alaska 0il & Gas Cons. Commiss~on Anchorage I$ Wa~e Verificat~.on Listing chlumberger Alaska Computing Center 18-APR-~994 17:59 **** REEl, NEADER **** SERVICE NAMR : EDIT DATE : g4/04/!.8 ORIGIN : FLIC REEL NAME : q4086 CONTINUATION # : PREVIOUS REEL : COMMENT : A.CO._R ~ ALASKA INC.,PRUD~OE ..... BAY,DS 6-15,500292045900 **** TAPE HEhDE~ SERVICE NA~ : EDIT DATE : q4/04/18 O~I~IN : FLIC TAP~ NA~i : 94086 gNTINU~TION # REVIOUS TAPE COMMENT : ARC~ ALASK~ INC,,PRUDHOE SAY,DS 6-15,500292045900 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE bOGS WELL NA~E: API NUMBER: OPERATOR: LOGGING COMPANY: TAP~ CREATION DATE: JOB NUMBE~: LOGCING ENGINEEP: OPERATOR WITNESS: SURFACE LOC~T!ON SECTION: TOWNSHIP: RANGE: FSL: FWL: ELEVATiON(FT FRON ESL KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1. ST STRING ~ND STRING 3RD STRING P~ODUCTION STRING DS 6-15 500292045900 ARCO ALASKA INC, SCHLUMB RGER WELL SERVICES 8-APR,~4 94086 D,REEM 14E 323 i736 68,00 67,00 32,00 [)PEN HOLE C~S!NG DRILLERS CASING BIT SIZE (IN) SIZE {IN) DEPTH (FT) WE1G..~r"" ~'' (LB/FT) 9,625 86~2,0 47,00 7,000 9535,:0 ~9'00 ~URVE 8}JIFT DATA ALL PA, ss,.~,,~$ TO STANDARD(MEASURED DEPT~) PAGE: iS Tape Verification 5isting chlumberger AlasKa Computing Center 18-APR-1.994 i7:59 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: 8CS LDWG CURVE CODE: GR RUN NI!~BER: P~SS NU~ER: DATE LOGGED: LOGGING BASELinE DEPTH 8888 0 9301 5 9~85 5 9248 5 9244 5 9209 0 9!33.0 9110 0 9075i0 9056 5 9031.0 9010 5 901o 0 8995 0 8960 5 8952 0 8928 5 8917 0 8905 0 8894 0 8857 0 8844 0 881~5 106' ,0 - ..... ----~QUIVALENT UNSHIFTED DEPTH---------- GRCH 9284.0 9~45.0 9205,5 9~.30,0 9116,5 9072 0 9o5 25 9029,0 9008.5 8993.0 896o,0 8950.0 8927.0 8915.0 8903.0 8890,0 8854.5 CNTD 88~87 9301 9284.0 9245.5 9008,5 8915,0 8841,0 7,0 88~7,5 97.0 THE D.~PTH ADJUSTMENTS SHOWN ABOVE REFLECT CASED HOLE GR TO OPEN HOLE GR, .AND CASED HOLE NPHI TO OPEN HOLE ALb O.T~ER CURVES WERE CARRIED ~!TH THE ~PHI SHIFTS' **** FILE HEADER **** F!b~ NA~E : EO!T ,O0i SERVICE : FLIC VERSION : O0!CO! D~T~ t 94/04/18 ~AX R~C S~ZE : 1024 F!L~ TYPE : LO PAGE: FILM HEADER IS Tape VerJ, ficatlom Listing cblumberger AlasKa Compute, hq Center 18-APR-~994 17:59 EDITED CUPVM$ Depth sh],fted and cl~,pped curves for each pass in separate files, p~SS ~U~BE~: 1 D~PTH INCREMENT: 0.5000 FILF SUMMARY LDWG TOOL CODE START DEPT~ STOP DEPTH GRC~ 81, CNTD 9~00,0 8800.0 CURVE S~IFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LD~G CURV~ CODE: # ----------EQUIVAIENT UNSHIFTE[) DEPTH---------- BASELINE DEPTH PEMA~KS: THIS FILE CONTAINS PASS ONE OF TWO. NO PASS TO PASS SHIFTS WErE APPLIED TO THIS DATA. $ ~!$ FORMAT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EH ** TYPE REPP CODE YALUE 1 66 0 2 66 0 3 73 40 4 66 5 66 7 65 8 68 0 5 9 65 il 66 25 12 68 13 66 0 14 65 15 66 68 t6 66 O 66 0 ,IS Tape Veri. flcati, on Listlnq IS-APR-1994 17:59 ~cblumber~er AlasKa Computln~ Center PAGE: ** SET TYPE - CHAN ** ... ...... --~; ....... ~-~.--- ..... ...:~-.-.---...=..~...--. .... ~AMM SERV ~ IT SER¥ C APl AP1a~ ~ -uI API FIL MB NUMB SiZE REPR PROCESS ID ORDER # LOG TYPE CLASS ~OD NUMB SAMP ELEM CODE (HEX) ... ................. ,-.-........-.,.-...-.-.......-...-..--,,..-.-,,- 480~64 O0 000 0 0 I ~. 4 68 0 00000 00 000 00 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 480664 CRAT CNTO 480664 NRAT CNTD 480664 NCNT CNTD CPS -4B0664 FCNT CNTD CPS 480664 CNTC CNTD CPS 480664 CFTC CNTD CPS 480664 O0 000 O0 0 1 1. O0 000 O0 0 1 1 1 O0 000 O0 0 1 I 1 O0 000 O0 0 i ! O0 000 O0 0 1 ! O0 000 O0 0 1 1 GRCH CHTD GAPI 4~0664 O0 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 IENS CNTD L.B. 480664 O0 00~ ooo oo o ~ , , 4 ~. oooooooooo 2.0 o ~ ,., ~ 6~ oooooooooo ** DATA ** DEPT. 0306.000 NPHI.CNTD NCNT,CNTD ~924.548 FCNT,CNTD NCNT CNTD 2976.500 FCN .C~TD ~ -999 250 TE~$-CNTD G..CH CNTD · . DEPT. 9200,000 NPHI:-CD:IY'D NCNT.CNTD ~847.594 FCNT,CNTD GRCH,fNTD 14.'9~8 TEN$'CNTD DEPT 00 NPHI'CNTD ,~ . · . G~CH,CNTD 14,11.5 T~N$.C TD DEPT, 900 .000 NPHI,CMTD NCNT~CNTD 428~ FCNT ,803 CNTD G~C~'CNTD !7,119 TENS,CNTD DEPT, 8900,000 MPHi,CNTD ~CNT,CNTD DEPT. 8800.000 N~MI~CNTD NCNT.CNTD 4060.737 ~CNT'CNTD G~CM'CNTD 53'250 TEN$iCNTD 30.878 CRAT'CNTD 5 1.50 608.035 CNTCoCNTD 2905:!33 11.05.000 30.624 CRAT,C..TD 5.:120 615,250 CNTC.CNTD 2977.000 1139,414 ' 35,53 CR. AT, Cl~ TD 695 526,1 500 CNTC; 2 1!05.766 19.106 CRA~T~CNTD 3,633 1342,750 CNTC'CNTD 47117.469 1099,750 22.463 CRAT..C L'ID 4.084 1t27,983 CNTC.C, TD 4340~014 i !oo ;0Oo 28,835 CRAT,CNTD : 000 0 5 2iio12 CRAT,CNTD O' 4':7548 90 656 CNTC.CNTD 4. 28. 46 I oS 00o NRAT.CNTD CFTC.CNTD N~AT.CNTD C~TC,CNTD NRAT,CNTO CFTC'CNTD NRAT.CNTD CFTC'CNTD NRAT,CNTD CFTC*CNTD NRAT.CNTD CFTC'CNTD NRAT,CNTD CFTC,CNTD 4.800 573,436 ·. 9 2 2 9:83 3 ? 6 1055. 795.844 ** END OF DATA ** IS Tame Verification Listinq chlumberger AlasKa Computtnq Center 18-APR-~.994 17:59 PAGE~ **** FILE TRAILER **** FILE MA~E : EDIT .001 SERVICE : VERSIO~ : oO~CO1 DATE : 94/04/28 MAX REC SIZE : 1024 FIL~ TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT ,002 SMRVICE : FL!C VERSION : O01CO! DATE : 94/04/18 M~X REC SIZE : 10~4 FILF TYPE hAST FILE FILE HEADER FILM NUMBER: 2 EDITED CUR VES Depth shifted and clip,ed curves for each pass in separate files. P~SS ~U~BER~ 2 DEPTH INCREMENT: 0.5000 FILM suMMARY LD~G TOOL CODE SWART DEPTH STOP DEPTH GRCH 927~.0 9207,0 CNTD 9~9 .0 9207,0 # ' ,[ PASS TO PASS(MEASURED DEPTH) CURVE SHIFT DA ~ - BASELIME CURVE FO~ SHIFTS LDWG CURVE CODE: GRCH P~SS NUMBER: ----------E{}UIVALENT UNSHIFTED DEPTH-'-------- BASELINE DEPTH GRCH CNTD 88888 0 88887.0 ~8887,0 9290.0 5 92855 o 0 9248.5 5 0 5 0 9208,5 0 99.5 9~91 9286 9253 9~49 9247 9~32 9223 9209 ~00 9247.0 9232,0 9223,5 100,0 IS Tare verii~cation Llstlnq chlumberger Alaska ComputinO Center 18-APR-!994 17:59 PAGE: PEMARKS: T~IS FILE CONTAINS PASS TW~ OF TWO. T~E DEPTH ADJUSTMENTS SHOWN ABOVE REFLECT PASS TWO GRCN TO PASS ONE ~RCB AND PASS T~O NPHI TO PASS ONE NPH!. AL5 OTHER CURVES WERE CARRIED ~ITN THE NPH! ADJUSTMENTS. THIS PASS IS SHORTER THAN THE FIRST DUE TO TOOL FAILURE. $ FORMAT DATA ** DATA FORMAT SPECIFICATION ~ECORD ** ** SET TYPE - 64EB ** TY~E REPR CODE VALUE I 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 8 9 6s 1~ 66 1~ 68 ~ 66 0 t4 65 FT 15 66' 68 16 66 0 66 ** SET TYPE - CHAN ** ID ORDE~ # LOG TYPE CLASS ~OD NUVO SAMP EbEM CODE (HEX) DEPT FT 480664 O0 000 O0 0 2 1 1 4 68 NPHI CNTD PU-S 480664 O0 000 O0 0 2 1 I 4 68 CRAT CNTD 480664 O0 000 O0 0 2 i I 4 68 NRAT CNTD ~80664 O0 000 O0 0 2 1 1 4 68 NCNT CNTD CPS 480664 O0 000 O0 0 2 I ! 4 68 FCNT CNTD CPS 480664 O0 000 O0 0 ~ I i 4 ~8 CNTC CNTD CPS 480664 O0 000 O0 0 ~ I i 4 ~8 CFTC CNTD CPS 480664 O0 000 O0 0 2 I I 4 68 G~C~ CNTD GAPI 480664 O0 000 O0 0 ~ 1 I 4 68 TENS C~TD LB 480664 O0 000 O0 0 ~ 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ,IS Tape Verification Listing ,chlumberger AlasKa ComputtnO Center 18-~PR-1994 17:59 DEPT. g296.000 MPHI.CMTD 27.159 CRAT.CNTD NCN~.CNTD 3402.500 FCNT.CNTD 729.000 CNTC.CMTO GRC~.CNTD -909.250 TENS.CNTD 1167.938 DEPT 9207.006 NPHI.CNTD 37 006 CRAT,CgTP NCNT~Ct~TD 2926.000 FCNT.CNTD 538~53! C~TC.CNTD GPCH.CNTD 40.844 TENS. CNTD 1139.750 END OF DATA 4.697 NRAT.CNTD 3407.250 CFTC.CNTD 3071 ;500 CFTC NTb PAGE= 4.483 702.688 6.~05 549. 6] **** FILE TRAILEP FIL~ NA~E : EDIT .002 SFRVICE : FLIC VERSION : OOlC0! D~TE : 94104/18 MAX REC SIZE : 10~4 FIL~ TYPE : LO LAST FILE **** FILE HEADER **** FILM NA~E ~ EOIT ,003 SERVICE : FLIC VERSION : O0~.CO1 DAT~ : MAX REC SIZE : 1024 FIL~ TYPE LAST FILE FILE HEADER FILM AVERAGEn CURVES Compensated Neutron: ~rlthmetic average of edited passes for all curves. PUlsed Neutron: unaveraged edited Pass I Gamma Ra~ add backround counts; arithmetic average of edited statlc baseline Passes for all other curves.~ DEPTH INCREMENT 0.5000 PAS~ES INCLUDED IH AVERAGE LDWG TOOL CODE PASS NUMBERS CNTD $ REMARKS: THE ARITHMETIC AVERAGE WAS PERFORMED AFTER ALL DEPTH ADdUST~ENT$ ~ERE APPLIED, LIS FORMAT DATA ~15 TaDe Vertflcatlo~ Llstlno chlumberqer A. lask8 ComDutino Center 18-APR-1994 17:59 PAGE: DATA FORMAT SPECIF!CATION RECO~D ** SET TYPE - ~4EB TYPE REPR CODE VALUE 1 6~ 0 2 66 0 $ 73 40 4 66 1 5 66 6 7] 7 65 8 68 0,5 9 65 1~ 6b ~5 l~ 68 13 66 0 14 65 FI 15 66 68 16 66 1. 0 66 1 ** SET TYPE - CHAN ** '''''NA.~ ........ SERV ~--~--~-;~;~---------------------------------------~;~--~;-------------A~I API PI APl FILE NUmB N ~B PROCESS ID ORDER # L G TYPE CLASS ~[)D NUmB SA~P ELEH CODE (HEX) mm DE'PT FT 80664 000 O0 ' . 3 I 1 68 0000000000 NPHI CNAV PU-$ ~80664 O0 000 O0 0 3 I I 4 68 0000000000 CRAT CNAV 480664 O0 000 O0 NRAT CNAV 480664 O0 000 O0 NCNT CNAV CPS 480664 00 000 O0 FCNT CNAV CPS 480664 O0 000 O0 CNTC CNAV CPS 480664 O0 000 O0 CFTC CNAV CPS 480664 O0 000 O0 0 3 I I 4 68 0000000000 0 3 i I 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 1 I 4 68 0000000000 0 3 I I 4 68 0000000000 0 3 I I 4 68 0000000000 ** DAT~ ** DEPT mCNT.'C~AV GRCH,CNA~V ~96'0o0 80. :256 7 ~ 7 ' ! 8 {3 ** END OF DATA ** ~!PN!'CNAV {~ CNI ~CNAV TEN.S~C ~ AV 26.098 CRAT'CNAV 756.125 CNTC,CNAV ! 15~.500 4.558 NRAT.CNAV 34042625 CFTC.CNAV 4.3§0 727;188 IS Tape verification Listlnfl chlumberger AlasKa Computln~ Center IB-APR-]9g4 17:59 **** FILE TRAIL£R **** FILE NAmE ! EDIT ,003 SERVICE : FbIC VERSION : 00~C01 D~TM : 94/04/28 MAX RFC SIZE : ~0~4 FILE TYPE LAST FILE **** FILE MEADER **** FILE NAmE ! EDIT ,004 SERVICE : FLIC VERSION : D~TM : 94/04/18 MAX R~C SIZE : 1024 FILE TYPE : LO LAST FILE FILM HEADER FILM NUMBER 1, RaW CURVES Curves and lo~ Leader data ~or e~ch ~ass in semarate P~$S NUMBER: I DMPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD 9306,0 $ L,-G HEADER DATA STOP DEPTH ~800,0 DATE LOGGED: SOFTWARE VERSION: TINE LOGGER ON BOTTOM: TD DRILLER TD LOG~ER{FT): TOP LOG INTERVAL BOTTOM LOG INTERVAL LOGGING SPEED DEPTH CONTROL USED TOOL STRING (TOP TO BOTTOm) VENDOR TOOL CODE TOOL TYPE CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRO~ C~TD COMPENSATED NEUTRON $ BO~E~OLE AND C~SING DATA files; raw background pass in last fi ~2~FEB-94 ]2} 2~'FEB-94 9408,0 0 . oo 9306'0 ~900'0 NO TOOL NUMBER CAL'UO'3~i ATC'CB~433 CNC'DA'IO.~ IS Tape Verification bisttnq cblumberger Alaska Computino Center 18-APR-1994 17:59 OPEN HOLE BIT SIZE (IN): DRIbLEtS CASING D~PTH (FT): LOGGERS CASING DEPTH BOPEHObE CONDITIONS FLUID TYPE: FLUID DENSITY CLB/G): SURFACE TEMPERATURE (DEGF): BOTTOM MOLE TEMmERATU~E (DEGF): FLUID SALINITY WLUID LEVEL (FT): FLUID RATE ~T WELLHEAD ~ATER CUTS GAS/OIL RATIO: CHOKE NEUTRON TOOL TOOL TYPE (EP!THERM~b OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN}: 8622,0 DEAD CRUDE THERMAL SANDSTONE 2.65 BLUEbINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW BASE ~OR~ALIZIMG WIN~OW (FT)~ BbUELINE COON~ RATE SCALES SET BY FIELD ENGINEER FAR COUNT ~ATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS); 43 NEAR COUNT RATE LOW SCALE (CPS): 0 ~EAR COUNT RATE HIGH SCALE (CPS)~ 22 · OOL STANDOFV (IN): REMARKS: TOOL $ # bis FORe, AT DATA lO ** DATA FOR~A? SPECIFICATION RECORD ** SET TYPE - 64EB ** TYP~ REPR COD VALUE I 66 0 2 66 0 ,IS Tape Verification [,!sting ichlumberqer AlasKa Computing Center 18-APR-1994 17~59 PAGE~ 11 TYPE R~P. CODE VALUE 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 ~3 12 68 13 66 0 14 65 FT 15 66 68 16 66 I 0 66 1 '"" ....... ..... ' ' ....... ......... ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) .................D~PT ' FT ~''''''80664 ........ 00 000'' ....O0 '''~''''''''''''''''''''''''''''''''''''''''''''4 ! 1 4 68 0000000000 Pl.) 480664 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI PSI RTNR PS1 TNR~ RCNT PSt. RCFT PS1 CMTC PSi CFTC PS1 GR PSi TENS PSI CCL PSi 480664 O0 000 O0 0 4 I 1 4 68 180664 O0 000 O0 0 4 1 I 4 68 CPS 480664 O0 000 O0 0 4 1 I 4 68 CPS 480664 O0 000 O0 0 4 1 I 4 68 CPS 480664 O0 000 O0 0 4 i I 4 68 CPS 480664 O0 000 O0 0 4 1 I 4 68 GAPI 48066~ O0 000 O0 0 4 1 1 4 68 LB 480664 O0 000 O0 0 4 1 X 4 68 V 480664 O0 000 O0 0 4 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DAT~ ** D~PT, 9 . ,214 RCFT'P81 GR'PS! 57'813 DEPT 9300,000 NPHi~ii:PS1 RCNT:PSI 3088,9]7 RCFT':PSi GR,PS! 57,8~,3 TENS'PSI D~PT, 9200'000 NPHI'PS! RCNT,P$1 2856,536 RCFTi~PSI GR,PS! ~0'188 TENS,PSI 34..574 RTNR,P.Sl 577'540 CNTC,PS1 1090,000 CCS'PSl 27 1659 RTNR,PS1 6~0~ 27 CNTC,PS! 1145.000 CCh'PS1 36,02~ RTNR'PS! 520,607 CNTC,PSI i110.000 5,:333 TNRA.PSt 308~:,~89 CFTC~P$1 ~ooo 4..400 TNRA'PS1 3075~587 CFTC,P:SI 0,000 5,400 TNRAoP$! 2843,094 CFTC.PS! o~ooo 5,,585 552,,505 4. 56 5,7 51 494,755 Tape Verification Listing .chlumberger Alaska Computlnq Center DFPT 9100.000 RCNT:P$! 4862.911. G~,P$1 13.141 NPHI.P$1 RCFT.PSI TENS.PSI MPHI,PS1 RCFT.P$1 TENS. PS1 ~PHI.PS1 RCFT.PS1 TENS.PSi ~PHI.PS1 RCFT,PS1 TENS,PS1 D~PT 8900 000 RCf4T'P$1 4030:4mi GI~:P81 14.375 DFPT 8801.5n0 RCNTiPS1 3295.681 GR PS1 59.563 ** END OF DATA ** 18-APR-~gg4 17:59 13721421 CNTC,PSI i095.000 CCL,PSl 20 ~56 RTNR,PSI 1266:~11 CNTC,PS1 1090.000 CCh.PS1 21 014 RTNR.PS1 tO58i5~8 CNTC,PSI IlO0000 CCL.PS1 32.079 RTNR,PSI 729 642 CNTC,PSI 1075~000 CCL,PS1 3 36'; ' A , ~MR..,PS1 48!2~871 CFTC,PSI 0.000 589 TNRA PS! 452~!933. 000 CFTC:P~i 3672 TNRA.PS! 4165!7800000 CFTC.PSi 4952 TNRA PS1 3350:448 CFTCiPS! 0.000 PAGE: !2 3598 1.316:024 ~,774 1187.459 3 888 1018:660 6795':2945~4 **** FILE TRAILER **** FILE NAME : EDIT ,004 SERVICE : FLIC V~RSION : O01COI DATE : 94/04/18 MAX REC SIZE : t024 FILE TYPE : LO LAST FILE ~ **** FILM HEADER **** FILE NAME : EDIT ,005 SERVICE : FLIC VERSION : O01CO1 DAT~ : 94/04/18 M~X REC SIZE : 1024 FILE TYPE : LO bAST FILE : FILE HEADER FILE NUMBER 5 RA~ CURVES Curves and log header data for each pass in separate files; raw bacKoro'und pass in last P~SS NUMBER: 2 DEPTH INCREMENT: 0,5000 FIL~ SUMMARY VENDO~ TOOL CODE START DEPTH STOP DEPT~ CNTD 9304,0 9206,0 ,iS TaDe Ver~ficatlom Listln~, chlumberger AlasKa Comput~ng Center 1B-~PR-!gg~ 17:59 PAGE: !3 HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME L~GGER ON bOTTOm: TD DRILLER CFI): TD LOGGER(FT): TOP LOG INTERVAL (~T): ~OTTOM bOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPT~ CONTROL U&FD lYES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 22-FEB-94 0 9408.0 0 0 8800:0 9306,0 1900,0 C~TD COMPENSATED N~UTRON . CNTD COMPENSATED NEUTRON CNTD COMPENSATED NEUTRO~ $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY SURFACE TEMPERATURE,(DEGF): MOTTO" HOLE T~iPERAT:URE (DEGF): FLUID SALINITY FLUID LEVEL (FT): FLUID RATE AT WELLHEAD WATER,CUTS GAS/OIL RATIO: CNQKE NEUTRQN TOOL TOOL TYPE (EPITHERNAL OR THERNAb): MATRIX: MATRIX DENSITY: ~ObE CORRECTION (IN):' BLUEb!NE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW (FT) BLUELINE COUNT RATE SCALE$~ SET BY FIELD ENGINEER FAR COUNT RATE bOW SCALE (CPS)~ FAR COUNT RATE HIGH SCA'bE(CPS): NEAR COUNT RATE [,OW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS)~ TOOL STANDOFF (IN): 22-FEB-g4 TOOL NUMBER CAb-Ug- l ATC=CB-433 CNC-DA-iOI 8622,0 DEAD CRUDE T~ERMAb SANDSTONE ~,65 0 0 22 !$ TaDe Verification Listin~ ~cblumherger Alaska Computtnq Center iB-APR-1994 17:59 R~M~RK$: TIED INTO BHCS DATED 7/20/B0 SURFACE PRESSURE BEFORE PUMPING= ~500 P$IG FOUND GAS 1N WELLBORE THEREFORE PU~PED 283 BBL CRUDE & 7 SB~ DIESEL CAP BEFORE BOGGING p~' ~ ONLY ONE PASS BOGGED WlTH A lO0~ RE, EAI DUE TO TOOL $ L~S FORMAT DATA PAGE: 14 DATA FORMAT SPECIFICATION RECORD ~* ~* SET TYPE - 64EL $~ TyPE REPR CODE vALUE ..~.-~...-.~..~.........~---- 2 86 0 3 73 44 4 66 5 66 6 73 7 65 9 65 11 66 23 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ..~.....~..~..~.......~....... ** SET TYPE C AN ,~ " ~ ' SIZE REPR OCES$ NA~, .... SE V UNIT ICE API API AP1 AP! FILE B NUMB ID ORDER ~ hOG ~¥PE ~hg$$ ~OD NUmb SAMP ELEM CODE (HEX) ''''''DEPT ............. FT 4 ;;; 64 ........... O0 000"''''''''''''''''''00 5 1 .... '''''I ......4 '''''''''''''';;;;;''68 0 PU 480664 O0 000 O0 0 5 ! 1 4 5~ 0000000000 NPHI RTDtR P$2 TNRA P$~ RCNT PS~ RCFT P$2 CNTC CFTC GR PS2 TENS CCh 480~64 O0 000 O0 0 5 1 1 4 68 480664 O0 000 O0 0 5 1 1 4 68 CD6 4~0664 O0 000 O0 0 5 ~ i 4 68 CPS 480664 O0 000 O0 0 5 1 I 4 6~ CPS 480664 O0 000 O0 0 5 1 I 4 6B CPS 480664 O0 000 O0 0 5 1 ~ 4 68 GAPI 480664 O0 000 O0 0 5 i I 4 68 LB 480664 O0 000 O0 0 5 I I 4 68 V 480664 O0 000 O0 0 5 i ! 4 68 0000000000 oO00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 , ~IS Tame Verification Listing ,chlumberger A3asKa Computinn Center DMPT. 9303.500 NPHI.PS2 .RCNT.PS2 2905.207 RCFT.PS2 GRoP$2 66.625 T~NS,PS2 DEPT, 0300.000 NPHI.PS2 RCNT.PS2 3029.787 RCFT.PS2 GR.PS2 6~ 0~5 ** END OF DATA 18-~PR-~.994 17:59 27.590 RTNR PS2 640.854 CNTC:PS2 1~95.000 CCtv.PS2 27.068 RTNR.PS2 668.192 CNTC,PS2 !170.000 CCh. PS2 35 857 RTNR,P$2 555:9~7 CNTC.PS2 1140.000 CCh.PS2 4 533 TNRA.PS~. 2910:465 CFTC.PS2 0.000 4,740 TNRA,PS~ 3091.388 CFTC.PS2 0.000 5 313 TNRA.PS2 2979:7~3 CFTCoPS2 0..000 PAGE: 4.747 613.075 4 682 65o: o 372 15 **** FILE TRAILE~ FILE NA~E : EDIT ,005 S~RVICE : FLIC V~RSION : O01COi DAT~ FILF TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : ~2DIT DATE : 94/04/1.8 P E IOUS TAPE COM..~NT : ARCO ALASKA INC,,P~UDHOE BAY,DS 6-15,50029~045900 **** REEL TR.AiLER **** SERVICE NAME : EDIT DATE ~ 94/04/~8 ORIGIN : FLIC R~E[ ~AME : 94086 CONTINUATION # : PREVIOUS-REEL : CON~EN~ : ~.RCO ALASKA iNC.,PRUDHOE BAY,DS 6-~5,500292045900 11:' ' 000000 7777777777 000000 7777777777 11 000000 7777777777 000000 7777777777 1111 O0 O0 77 O0 O0 77 1111 O0 O0 77 O0 O0 77 11 O0 0000 77 O0 0000 77 11 O0 0000 77 O0 0000 77 11 O0 O0 O0 77 O0 O0 O0 77 11 O0 O0 O0 7? O0 O0 O0 71 11 0000 O0 77 0000 O0 77 11 0000 O0 77 0000 O0 17 11 O0 O0 77 O0 O0 77 11 O0 O0 77 O0 O0 77 111111 000000 77 000000 77 111111 000000 77 000000 77 666666 000000 666666 666666 7777777777 b66666 000000 666666 666666 77777777'17 66 O0 O0 66 66 77 bO O0 O0 66 66 7'1 66 O0 0000 66 66 '17 06 O0 0000 66 60 77 66666666 O0 O0 O0 66666666 66666666 77 66666666 O0 O0 O0 66666666 06666666 77 66 66 0000 O0 66 h6 66 66 77 66 66 0000 O0 66 66 66 66 77 66 66 O0 O0 66 66 66 66 77 66 66 O0 O0 66 66 bb 66 77 666666 000000 bb6666 666666 77 6bbbbb 000000 666666 666666 17 CCCC M N CCCC PPPP RRRR U U DDDD H H OOO EEEEE C MM MM C P PR R U U D DH H O O g C M M M C P PR R U U D DH HO 0 g C M N C ..... P. PPP RRRR U U ~ D ..,HH ~ ~ EEEE C .MC P , R U U . D H H ~ ~ g C M M C P R D D H H O O E CCCC M M CCCC P R DDDD H H OOO EEEEE *START* 06ER PCAL [i0707,60667J dOB SHIP SEQ. 1294 DAI'E 24-AUG-80 19:04:54 MONI, TOR S~S KLIOE37 APR-80. *START* *STAR:[* USER PCAL [10707,60667J JOB SHIP SEQ. 1294 DATE 24-AUG-80 19:04:54 MONITOR 6WS KLIOE]7 APR-80. *START* VV VV EE VV VV EL VV VV EE VV VV E~ VV VV LEL~EEEE VV VV EL VV VV LE VV VV EE VV VV EL VV EEEEEEEEEE VV EEEEEEEEEE RRRRRRRR IIIIIi F~P~FFFfFF RRRRRRRH IIIIII RR RR II RB RR 11 Ff RR RR I1 RR RR II ~'~ RR RR I1 RR RR Ii RR RR IIIIIi FF BR RR Iillii XX YY YY Yi YY YY YX YY 000000 000000 11 000000 000000 11 00 00 00 O0 1111 00 O0 00 O0 1111 O0 0000 O0 0000 I1 O0 0000 O0 0000 11 O0 O0 O0 O0 O0 O0 11 O0 O0 O0 O0 O0 O0 11 0000 O0 0000 O0 II 0000 O0 0000 O0 11 O0 O0 O0 O0 11 O0 O0 O0 O0 II 000000 000000 111111 000000 000000 111111 *START* USER PCA6 [10707,606671 dOB SHIP SEQ. MUNI'~[IR 6~$ KblOE.]7 APR-80. ~START* ~'ILE. DS~HlVE~IFY.001<057>[10707.606671 CREATED: PRiN1ED: 24-AUG-80 19:05:08 QUEUL SWITCHES: /FiLEIFORT /COPIES:I /SPAC1NG:I /LIMIT:58 /FORMS:NORMAb 1294 DATE 24-AUG-80 24-AUG-80 19:03:50 19:04:54 SCHLOMBERGE~ COMPUTING CENTER 10707,60667 REEL HEADER LENGTH: 132 B~TES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CUNTINUAXlON NUMBER: 0! PREVIOUS REEL NAME: COMMENTS: LI$ FORMAT CUSTOME~ TAPE DATE: 80/ 8/24 TAPE HEADE~ LENGTH: 132 B~'TES TAPE NAME: 60667 DATE: 80/ 8/24 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 PREVIOUS TAPE NAME: COMMENTS: UN1QUE WELL IDENTIFICATION NUMBER IS 50-029-20459 TAPE COMMENTS DATE LOGGED 20-JUb-80/RUN 0NE/SASlNG 9.625" 47# ~ 8622/B1T SIZE 8.5 ~ 9540tTY FLUID OIL FAZE/DENS ~0.~O/PH O.0/VISC 56'0 fi~C/FLUID LOSS 6.0 ML/RM-RMC-RMF EOF FILE HEADER I,ENGTH: 62 BYTES FILE NAME: EDIT .00! MAXIMUM ~HYSlCAL RECORD LENGTH: PREVIOUS FILE NAME: 1024 BYTES WELL SiTE INFORMATION RECORD LENGTH: COMPANY: WELL: FIELD: RANGE: TOWN: SECIION: COUNTY: STATE: 181BXTES ATLANTIC RICHf'IELD CO. U.S. 6-15 PRUDHOE BA~ ION 2 N. SLOPE ALASKA DATA FORMAT SPECI~iCATION LENGTM: 530 B~TES 5NTH~ PLUCKS: IYPE 0 SIZE REP CODE EN"fR Y 1 66 0 DA'I'UM 6PECI~ICAT1UN BLOCKS: ENTRY lC TOOL ,5VUHDt~ UNITS AP1 AP1 AP1 AP1 FILE# SiZk EXP PROC SAM REP DEPT SHIF'I' 1 DEP~~ 2 ILD DIL ¢ G~ BHC 5 DT BHC 6 GR CNL 7 CALl CNL 8 DRHO FDC 9 NPHI CNL 10 RHOB CNL 11 NRAT CNL 12 NCNL CNL I { PCNL CNL FT 0 0 0 0 0 4 0 0 ! 08 0 0 OHMM 7 12 40 0 0 4 0 0 1 68 0 0 OHMM 7 12 44 0 0 4 0 0 1 b8 0 0 GAPI bO 31 32 0 0 4 0 0 1 68 0 0 US/~' b0 52 ]2 0 0 4 0 0 1 08 0 0 GAPI 42 31 ]2 0 0 4 0 0 1 08 0 0 IN 42 28 1 O 0 4 0 0 I 68 0 0 G/C3 42 44 0 0 0 q 0 0 I b8 0 0 PO 42 68 3 0 0 4 0 0 1 68 0 0 G/C3 42 35 I 0 0 4 0 0 1 68 0 0 CIC 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 b8 0 0 DEPTH 9540.000 9500.000 9400.000 9300.000 9200.000 9100.000 9000.000 8900.000 8800.000 8700.000 8600.000 8502.000 MNEMONIC IbD RHOB GR RHUB ILD GR RHOB ILD GR ILD RHOB ILD GR RHOB IbD GR RHOB ILD GR RHOB ILD GR RHOB ILD ILO GR RHOB iLO GR RHOB VALUE 3.107 115.563 2.469 3.385 108,563 2.662 5.609 37,250 2,498 2.016 40,938 2.172 9,609 14.758 2.184 31.922 22.219 2.340 68.938 23.031 2.246 98.750 20.641 2.334 8.203 95,500 2,533 1.567 102,125 2'516 -999.250 -999.250 -999.250 -999.250 MN EMON1C ibm CALl NRAT IbM CALl NRAT ILM CALl NRAT IbM CALl NRAT IbM CALl NRAT ILM CALl NRAT ILM CALl NRAT iLM CALl NRAT ILM CAb NRA~ ILM CALl NRAT ibm ILM CALl NRAT VALUE 3.135 7.051 2.691 3.457 8.563 2.842 7,219 8.539 2.391 2,174 8.516 2.605 9.977 8.406 2.676 33.813 8.383 2.039 74,250 8.391 2'762 107.500 8,359 2.457 9.430 8.711 2.633 1.728 789 -999.250 -999 250 -999:250 2999 250 999~250 -999.250 MN EMONIC DRHO NCNb GR DRHU NCNb DRHO NCNb GR DRHU NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHO NCNb GR DRHU NCNb VALUE 88,000 0.083 2650.000 91.063 0,027 2592,000 MNEMUNiC VALUE DT 82 NPH1 30 FCNb 900 DT 82 NPHI 31 FCNL 858 39.500 DT 83 0.015 NPHI 24 3368.000 FCNL 1234 27.109 OT 100 -0.013 NPHI 27 2982.000 FCNL 1062 20.109 DT 94 0.001 NPHI 29 2906.000 FCNL 1011 23.313 DT 71 -0.013 NPHI 19 3870.000 f'CNL 1720 31.078 DT 92 -0,003 NPH1 30 2952.000 FCNb 944 25,422 DT 85 0.000 NPHI 25 3188.000 f'CNb 1157 100.563 DT 86 007 NPHI 28 103.125 DT 105 000 FCNL 546 56.031 -999. ,999,~ 50 5O .375 .811 .000 .750 .445 ,000 .563 ' .707 .000 .188 ,979 .000 .750 .150 .000 .750 .b29 .000 .000 .~20 .000 .563 .928 .000 .375 .125 .000 .000 .2! .000 DT -999,250 NPH1 -99925.000 FCNL -999,250 55.344 DT -999 -999.250 NPH1, -99925 -999,250 FCNL -999 .250 .000 .250 , DATA IRECt}RDS NUMBER [J~ EECORDS: 110' I.,ENGTft OF RECORDS: 994 BYTES. LENGTH O["" LAST RECORD: 318 BYTES FiLE IBAiLER LENGTH: 62 BYTES FiLE NAME: EDit .001 MAXIMUM PHYSICAL RECURD LENGTH: NEXT fILE NAME: 1024 BYTES TAPE TRAILER LENGTH: 112 BYTES TAPE NAME: 60~07 DATE: 80/ 8/24 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 NEXT ~APE NAME: C(]NMENTS: UNIQUE WELL IDENTIFICATION NUMBER IS 50-029-20459
