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Home My WebLink About195-0721. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Cement Perfs, Mill Out 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,300'N/A Casing Collapse Conductor N/A Surface 2,470psi Production 8,180psi Production 8,180psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng See Schematic See Schematic 5/21/2025 4-1/2" 7-5/8" x 4-1/2" Bkr S-3 Packer and 4-1/2" HES HXO SVLN 9,524 MD/ 8,880 TVD and 1,503 MD/ 1,501 TVD 7-5/8" 4,417' 6,072' 5,156' Perforation Depth MD (ft): 5,140psi 4,335' 10,304' 4,455' 11,265' 6,109' 5,914' 5,140psi PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0312828 195-072 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22562-00-00 Hilcorp Alaska LLC DUCK IS UNIT MPI 1-31 ENDICOTT / ENDICOTT OIL 50.0842 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 12.6# / 13CR-80 / NSCT 9,614' 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY aras.worthington@hilcorp.com 907-564-4763 Authorized Title: Operations Manager Aras Worthington 10,332' 11,181' 10,237' 3,076 N/A Length Size 110' 110' TVD 71' 30" BurstMD N/A 5,210psi 7-5/8" 10-3/4" ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Grace Christianson at 7:53 am, May 01, 2025 Digitally signed by Justus Hinks (3691) DN: cn=Justus Hinks (3691) Reason: I attest to the accuracy and integrity of this document Date: 2025.04.30 16:31:07 -08'00' Justus Hinks (3691) 325-272 10-404 JJL 5/7/25 DSR-5/1/25A.Dewhurst 14MAY25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.05.14 11:56:23 -08'00' 05/14/25 RBDMS JSB 051425 _____________ Cmt Sqz, Perforate K-1C END 1-31 PTD: 195-072 Current Bottom Hole Pressure:3,970 psi @ 8,944’ TVD (SBHPs 8/8/16; 8.6 ppge) Max Proposed Surface Pressure: 3,076 psi Gas Gradient (0.1 psi/ft) Max Deviation: 37.5 deg at 10,900’ MD Minimum ID:3.725” XN @ 9,602’ MD Last Tag:11,121’ ELM w/ 3.7” LIB (3/31/22) SBHT:184 Deg F @ 9,601’ MD (SBHPS 8/8/16) History Drilled and completed in 1995 as a producer. Latest well test: 14 bopd, 744 bwpd, 17.1 MMSCFD Fgas, 98.1% WC (3/13/25). Objective Execute a cement squeeze of the existing perforations. Clean-out or mill to PBTD and perforate the K-1C. Slickline:(Non-Sundried work) 1. PT PCE to 250 psi low, 3500 psi high. 2. Pull SSSV. 3. Fish Downhole Choke that swiveled off (3/26/22). ¾There have several attempts to fish the choke from 3/26/22 – 3/31/22. 4. MU TEL and bailer, locate Tubing Tail, tag TD and get corrected PBTD. 5. Set DSSSV. Well Name:END 1-31 API Number:50-029-22562-00 Current Status:Ivishak Producer PTD #195-072 Estimated Start Date:5/21/2025 Rig:SL / EL/ CT Reg.Approval Req’std?Yes –403 Estimated Duration:One week First Call Engineer:Aras Worthington (907) 564-4763 (O) (907) 440-7692 (M) Reservoir Engineer:Gavin Dittman (907) 564-5246 (O) (907) 903-1903 (M) Geologist:Brock Rust (907) 777-8394 (O) (615) 306-9509 (M) _____________ Cmt Sqz, Perforate K-1C END 1-31 PTD: 195-072 Coiled Tubing: 6. PT PCE to 250 psi low, 3500 psi high. 7. Drift to TD with ~2.0” cementing nozzle (WSS discretion). Tag TD, pick up 10’ and flag pipe for depth control. 8. Liquid pack well with diesel by pumping down the coil tubing and up the backside or bullhead (WSS discretion). ¾Tubing volume: 145 bbls ¾Liner volume: 70 bbls ¾Total WBV:215 bbls 9. Perform pre-cement injectivity test. 10. Lay 50 bbls 15.8 ppg Class G cement @ 1:1 from flag depth. a. Minimum thickening time = 10 hours. i. 1 hour mixing at surface. ii. 1.5 hours pump down coil assuming 1 bbl / minute iii. 0.5 hour cement placement assuming 0.5 bbl / minute iv. 2 hour squeeze time v. 2 hour contingency b. Expected bottom hole temperature 200 degF 11. Hesitation squeeze for ~2 hours targeting 2500 psi squeeze in 250 psi increments. Hold each pressure for 5-15 minutes. c. Hold max squeeze pressure for target of 45-60 minutes. 12. If hesitation squeeze is successful cleanout cement with frequent gel sweeps down to PBTD. Thoroughly jet and cleanout at TD, particularly if the LIH choke was not recovered. If it gets cemented in place it will prevent milling past it or may act as a whipstock on the next rig up of CT. d. First contamination pass should be no later than 2/3 of thickening time. 13.Contingent If well is unable to build squeeze pressure, over displace cement by 2-3 bbls and prepare to repeat squeeze attempt once cement has reached compressive strength. Or consider leaving cement to set up and under-reaming cement with Hailey Under reamer & mill. 14. After cement has reached 1000 psi compressive strength perform post cement PT to 500 psi for five minutes. 15. Pull DSSSV. Try straight pulls to open the lock before jarring and jar gently if at all to avoid splitting the FN on the lock. 16. MU a motor and mill ¾If the choke assembly was fished with SL consider using Hailey Underreamer behind mill ¾If the choke assembly was not fished use a mill ~3” OD (clearance past the 3.79” OD choke in 6.875” ID casing is 3.085”) 17. Mill down to a target depth of 11,170’ MD (top of float collar is 11,180’ MD). _____________ Cmt Sqz, Perforate K-1C END 1-31 PTD: 195-072 Slickline 18. PT PCE to 250 psi low, 3500 psi high. 19. Drift for 2-7/8” guns – deepest perforation is 11,149’ MD. Eline (Sundry Required) 20. PT PCE to 250 psi low, 3500 psi high. 21. Tie in to Atlas GR/CCL jewelry log dated 6/15/95. 22. Perforate 11,130’ – 11,149’ MD w/ 2-7/8” 6 spf, 60 phase Geo-Razor (or similar). Slickline 23. PT PCE to 250 psi low, 3500 psi high. 24. Set SSSV. Attachments: 1. Current Schematic 2. 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The well's flow rate is being artificially restricted with a flowing wellhead pressure of approximately 1300 psi due to flowline erosion velocity limitations. Hilcorp requests the use of a second flowline attached to MPI 1-31 to enable the well to flow at full rate into the 300 -psi production header. The "twin" flowline will be tied into the existing flowline of long-term shut- in well MPI 1-29 (PTD 18618 10) which is adjacent to MPI 1-31, carrying the extra well flow into the production header. The production tree of MPI 1-29 is isolated from its flowline. The MPI 1-31 automatic safety valve system is configured as follows (in the direction of flow): a subsurface safety valve in the tubing, surface safety valve in the vertical run of the production tree, and low-pressure detection devices in each flowline linked to the existing safety valve control panel. Detection of a low-pressure situation in either of the flowlines closes the surface safety valve, the actuated wing valves on both flowlines, and the subsurface safety valve. Performance testing of the MPI 1-31 safety valve system involves independently actuating the low-pressure switches to verify regulatory compliance. As an alternate method of well testing, Hilcorp proposes the summation of the individual well tests of each of the MPI 1-31 flowlines. Those individual tests will be performed back-to-back to ensure consistent plant conditions and sufficient accuracy for allocation purposes. The Alaska Oil and Gas Conservation Commission APPROVES Hilcorp's request to use the alternate well testing methodology and to install, maintain, operate, and test the twin flowline safety valve system as described in its application, with the following conditions: - The low-pressure detection devices and surface safety valve for the twin flowlines must be uniquely identified and labeled; Docket Number: OT14-20-036 May 11, 2020 Page 2 of 2 - Hilcorp must submit separate test reports for the twin flowline safety salve system tests. Any questions regarding this approval should be directed to Jim Regg at 907-793-1236 (email: I im.regg c@alaska.gov). Sincerely, U v l'"` Jeremy M. Price Chair, Commissioner Email: AOGCC Inspectors H Hilcarp Alnaka, LLC May 7, 2020 Mr. David Roby Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8301 Re: END 1-31 (PTD # 1950720) Request for Approval of Well and SVS Testing Changes In Support of Twinned Flowline Dear Mr. Roby, Hilcorp Alaska, LLC (HAK) requests approval to use alternative well testing and safety valve testing methods on well END 1-31 (PTD # 1950720) in support of a flowline twinning project. Background END 1-31 is an Endicott natural flow producer completed in the Kekiktuk formation in the S2A3 and S2A1 sands. The well has been on steady state production since 1995 and is one of the field's producers with a GOR (^'90,000 scf/bbl) and Water Cut ('95%). Production is currently restricted with a flowing tubing pressure of 1,300 psi due to flowline erosion velocity limitations. To allow the well to flow at full rate to the —300 psi production header, we would like to connect a 211 "twin" flowline to the tree to carry a portion of the production from END 1-31 to the flowline of adjacent long term shut-in well END 1-29 (PTD#186181). END 1-29 is disconnected and would remain completely isolated from the twinned flowline. Justification Twining END 1-31 in this configuration will allow for increased production as well as accurate well testing and allocation within the operating limits of the Endicott MPI test separator. Additional well drawdown is expected to encourage additional S2A3 and S2A1 contribution which will help GOR as FTP decreases. Well Testing Methodology Hilcorp would utilize an alternate method of well testing if acceptable to the commission as per 20 AAC 25.230(a). END 1-31's well tests would be obtained through a summation of individual tests of the original (1-31) and twin (1-318) flowlines. Currently Endicott wells receive a minimum of monthly tests. With the addition of testing from the twinned (1-3113) flowline, a minimum of two tests would be taken to Pugc 12 ensure one combined 1-31 well test per month. Individual tests from the original and twin flowlines would be completed back to back to ensure as consistent plant conditions and back pressure as possible. Typically the test separator and production header pressures track closely, within +/- 10 psi. Daily production allocation methodology would remain the same utilizing individual tests and flowline On/Off times as determined by the wing valves' open/closed position. Production values for each flowline would then be combined and reported as a single value for END 1-31. This methodology would result in no change or disruption to 1-31's well testing or production reporting. Safety Valve System Low Pressure Switch Configuration Hilcorp would operate and test the SVS systems with the addition of a second low pressure switch to protect against a pressure drop in the twinned (1-3113) flowline. The second low pressure switch would be connected from the twinned (1-3113) flowline to END 1-31's safety valve panel. END 1-31's surface and subsurface safety valves would remain unchanged, and the overall safety valve system functionality would be unaffected. When the low pressure switch from either flowline was tripped, both END 1-31's surface and subsurface safety valves would actuate. Additionally, actuated wing valves on either side of the flow cross would close on a low pressure trip. Once installed, this configuration would be function tested and an AOGCC witnessed performance test would be requested. As part of the performance test, each flowline low pressure switch would be tripped independently to verify the correct system actuation pressure for the respective flowline. If you have any additional questions, please contact me at 777-8333 or dgorm@hilcorp.com. Sincerely, David Gorm \ Operations Engineer Hilcorp Alaska, LLC CC James Regg Attachments - END 1-31 Wellhead Twinning Concept Diagram - END 1-31 & END 1-31B Redlined P&ID's - MPI Wells General Layout Id r. 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PMC 31 I 3 IM m M31 m) 31 I I xa p N 3 14 M1F11 mA FC Nw xP mm P I q 036 xmto® CSO CtlNw M PRCE SET O,OC P9C qFC py b I Y Y 'i i FrHP ;, MN 1 mm wxAOl N1FF'rw,� (c) 1 i 731 SET r emC PSIS xC r s g 1� I I I n I I ( I 1 I I /ASv xwullL (aPWu� I I I I N I ssv135sT' MP (awSE)i- n N II I /J1 � Fon I SSYnSY n3T (WFII)�`+-�I� � I I 11" I I I I I I I I I m; sn o saw PSM y Fw 1 sa, I Fsr-," I I ® IPF IS MM m 35 1 " EH -2" -Ino Tr i% "51 HM I I I I I o -u I I ABOVE GROUND DOL UNDER GROUND C PRODUCINGWELL (4"-5000J API 7REE) R6FPOKt w.v.fi5 NA Mff Pfl1x1[M 00 11 11 FCPEAEPT41350558-05 RW NS12 AFMSED PEA El'1 41350578 -OS KC NS02 0A 14 REMSED PER On 42338821-01 NS PJI lliPWO • • RECEIVED Post Office Box 244027 3 0 q Anchorage,AK 99524-4027 Hilcorp Alaska,LLC JUL2015 3800 Centerpoint Drive Suite 100 A®occ Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 SCANNED 2 r =T. Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 193 0 7c9— Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "/" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig • New API_WeliNo PermitNumber WellName WeIlNumber WeIlNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/J19 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/J18 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 7 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/026 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/021 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/J22 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/L15 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/114 2-22 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /'(:~ ~ -O7 ~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] [:3 [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: ~ '7 Poor Quality Original - Pages: Other - Pages: DIGITAL DATA [] Diskettes, No. D Other, No/Type OVERSIZED r~ Logs of various kinds r~ Other COMMENTS: Scanned by: Beve~ Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 f, May 22, 2012 Mr. Jim Regg 5.—O7- 6 / Alaska Oil and Gas Conservation Commission 333 West 7 Avenue 1 3 r Alaska Anchorage, 99501 9 Subject: Corrosion Inhibitor Treatments of Endicott Row 1 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 1 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 altemate, Gerald Murphy, at 659 -5102. Sincerely, / G U Mehreen Vazir BPXA, Well Integrity Coordinator II • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Endicott Row 1 Date: 09/24/2010 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal END1 -01 /J -19 1880370 50029218010000 1.5 0.3 0.5 9/2/2010 0.85 9/23/2010 END1 -03 / P -16 1951500 50029226018000 4.0 3.5 0.5 9/2/2010 5.10 9/23/2010 END1-05 / 0 -20 1861060 50029216050000 0.3 NA 0.3 NA 1.70 9/23/2010 END1 -09 / L -21 1970290 50029217430100 6.0 5.0 0.5 8/28/2010 3.40 9/23/2010 END1 -15 / P -25 1930560 50029223610000 4.0 3.0 0.5 9/2/2010 6.80 9/23/2010 END1- 17/I -17 1961990 50029221000100 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -19 /1-18 1950930 50029225690000 7.0 9.3 0.5 9/2/2010 4.25 9/23/2010 END1 -21 / K -25 1900020 50029220050000 2.5 1.5 0.5 9/2/2010 1.70 9/23/2010 END1 -23 / 0 -15 1941280 50029225100000 12.0 12.5 0.5 9/2/2010 1.70 9/23/2010 END1 -25 / K -22 1970750 50029217220100 5.0 1.5 0.5 9/2/2010 5.10 9/23/2010 END1 -27 / P -20 1870090 50029216930000 8.0 4.3 0.5 9/2/2010 2.55 9/23/2010 END1 -29 / M -25 1861810 50029216690000 2.0 1.3 0.5 9/2/2010 1.70 9/23/2010 ___-7END1 -31 / M -21 1950720 50029225620000 5.0 1.8 0.5 9/2/2010 13.60 9/23/2010 END1 -33 / L -24 1982550 50029225770200 1.5 0.3 0.5 9/2/2010 3.40 9/23/2010 END1 -35 / 0-25 1861840 50029216720000 8.0 4.8 0.5 9/2/2010 3.40 9/23/2010 END1 -37 / P -24 1870900 50029217480000 0.5 NA 0.5 NA 4.25 9/23/2010 END1 -39A / N -16 2061870 50029218270100 0.5 NA 0.5 NA 6.80 9/23/2010 END1 -41 / 0-23 1870320 50029217130000 8.0 5.2 0.5 9/2/2010 4.25 9/23/2010 END1 -43 / P -26 1881050 50029218640000 2.0 0.5 0.5 9/2/2010 3.40 9/23/2010 END1 -45 / Q-26 1891240 50029219910000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -47A / M -20 1972030 50029216250100 1.0 0.1 0.5 9/2/2010 3.40 9/24/2010 END1 -49 / P -21 1880780 50029218410000 1.0 0.8 0.5 9/2/2010 3.40 9/24/2010 END1 -51 / V -20 1921190 50029223040000 1.5 0.3 0.5 9/2/2010 1.70 9/24/2010 END1 -53 / Q-20 1941120 50029225010000 9.0 4.2 0.5 9/2/2010 1.70 9/24/2010 END1 -55 / R -25 1880210 50029217880000 1.3 0.1 0.5 9/2/2010 1.70 9/24/2010 END1 -57 / R -23 1881140 50029218730000 3.0 1.3 0.5 9/2/2010 5.10 9/24/2010 END1 -59 / 0-24 1960220 50029226440000 3.0 1.3 0.5 9/2/2010 0.85 9/24/2010 END1 -61 / Q-20 1941420 50029225200000 8.0 6.8 0.5 9/2/2010 2.55 9/24/2010 END1 -63 / T -22 1890060 50029219050000 8.0 4.1 0.5 9/2/2010 2.55 9/24/2010 END1 -65A / N -27 2032120 50029226270100 8.0 5.8 0.5 9/2/2010 3.40 9/24/2010 END1 -67 / T -20 1891140 50029219850000 0.5 NA 0.5 NA 1.70 9/24/2010 END1 -69 / V -19 1900290 50029220200000 15.0 10.3 0.5 9/2/2010 0.85 9/24/2010 STATE OF ALASKA ALASKA OAND GAS CONSERVATION COMMISSICO REPORT OF SUNDRY WELL OPERATIONS 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 0 Perforate le Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ - 195 -0720 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 22562 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 312828 1- 31/M -21 10. Field /Pool(s): ENDICOTT FIELD / ENDICOTT OIL POOL 11. Present Well Condition Summary: Total Depth measured 11300 feet Plugs (measured) None feet true vertical 10332.27 feet Junk (measured) None feet Effective Depth measured 11181 feet Packer (measured) 1503 9524 feet true vertical 10236.5 feet (true vertical) 1501 8880 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 71' 30" 39 - 110 39 - 110 Surface 4417' 10 -3/4" 45.5# L -80 38 - 4455 38 - 4335 5210 2480 Intermediate 6072' 7 -5/8" 29.7# NT80 37 - 6109 37 - 5914 6890 4790 Production 5156' 7 -5/8" 27.7# NT95 6109 - 11265 5914 - 10304 8180 5120 Liner Liner 1 26 i Perforation depth: Measured depth: SEE ATTACHED - .rr> • _ True Vertical depth: _ _ - - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR80 36 - 9614 36 - 8954 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BBE SSV 1503 1501 4 -1/2" BKR S -3 PKR 8880 �V • EC iG2q 2Z 12. Stimulation or cement squeeze summary: Intervals treated (measured): innadOOGO Treatment descriptions including volumes used and final pressure: ,, ,C . 4 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 59 6445 1290 2123 Subsequent to operation: 436 5134 535 2125 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 .0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .. IO Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na = ; - Lastufka - I Title Petrotechnical Data Technologist Si natur 1 Phone 564 -4091 Date 8/26/2011 NW RBDMS AUG 2 9 2011 ere '" Form 10 -404 Revised 10/2010 do e G riir( Submit Original Only 1-31/M-21 . 195 -072 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 1- 31/M -21 6/16/95 PER 11,037. 11,060. 10,121.04 10,139.41 1- 31/M -21 6/16/95 PER 11,105. 11,115. 10,175.42 10,183.43 1- 31/M -21 8/14/95 SQZ 11,037. 11,060. 10,121.04 10,139.41 1- 31/M -21 8/14/95 SQZ 11,105. 11,115. 10,175.42 10,183.43 1- 31/M -21 8/20/95 RPF 11,110. 11,116. 10,179.43 10,184.24 1- 31/M -21 10/4/95 APF 11,036. 11,042. 10,120.24 10,125.03 1- 31/M -21 10/14/95 APF 10,890. 10,910. 10,004.03 10,019.91 1- 31/M -21 10/30/96 SQZ 11,105. 11,116. 10,175.42 10,184.24 1- 31/M -21 10/30/96 SQZ 10,890. 10,910. 10,004.03 10,019.91 1- 31/M -21 10/30/96 SQZ 11,036. 11,060. 10,120.24 10,139.41 1- 31/M -21 11/4/96 RPF 11,040. 11,048. 10,123.43 10,129.82 1- 31/M -21 11/4/96 RPF 11,105. 11,115. 10,175.42 10,183.43 III 1- 31/M -21 10/4/97 APF 11,066. 11,076. 10,144.21 10,152.21 1- 31/M -21 1/25/98 APF 10,922. 10,932. 10,029.44 10,037.38 1- 31/M -21 8/3/11 APF 10,821. 10,840. 9,949.12 9,964.26 1- 31/M -21 8/4/11 APF 10,811. 10,821. 9,941.15 9,949.12 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 • 1 1 � • • 1- 31/M -21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY a 8/3/2011 ***WELL FLOWING ON ARRIVAL * ** PERFORATING INITIAL T /I /O 2000/525/450 PERFORATION RUN 1= 10821'- 10840'. JEWELRY LOG PERFORMED FROM PBTD- 11130FT TO 9200 FT ;WING =C, SWAB = C,SSV =C, MASTER =O, TREE CAP ON AND TESTED. ** *JOB CONTINUES 08/04/11 * ** 8/3/2011T/I/O = 2000/520/450. Temp =120 °. WHPs (UIC Monitor). AL is SI @ casing valve. ALP =150 psi. SLB E -Line on location to perforate well. SLB SI well to stack -out ;pressure. Obtained TBG FL @ 5800' (between sta #5 & sta #6, 90 bbls). Post SI I W HPs= 2800/520/450. SLB E -Line in control of well valves. 8/4/20111 ** *WELL SHUT IN ON ARRIVAL * ** PERFORATING :CONTINUED FROM 08/03/11 WSR ;INITIAL T /I /O 2800/350/200 :PERFORATION RUN 2 SHOT FROM 10811 -10821 FT. BEFORE PERF T /I /O 3000/350/200, AFTER PERF T /I /O 3000/360/200 FINAL T /I /O 2980/360/200 'WING =C, SWAB =C, SSV =C, MASTER =O, TREE CAP ON AND TESTED. ! ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL TREE = CM/ SAFETY N H2S READINGS AVERAGE230 - 260 WELLHEAD = FMC JMD D RAF END 1 -3 1 PPM ON W GAS INJECTORS. WELL REQUIRES A ACTUATOR = BAKER C SSSV. *""4 -1/2" CHROM E TBG ** *I NNER ANNULUS KB. ELEV = 55.85' I 1 FLUIDS & STIM ACID MUST CONTAIN CORROSION BF. ELEV = 14.5' INHIBITORS. KOP= I 1503' H 4 - 1/2" HES HXO SVLN (3.813" MIN ID) I Max Angle = � 37° @ 10900' Datum MD = 10955' Datum TVD = 10000 SS GAS LIFT MANDRELS ST MD TVD DEV VLV LATCH PORT DATE 7 3559 3478 17 DMY BK 0 07/17/98 6 5472 5306 17 DMY BK 0 07/17/98 110 -3/4" CSG, 45.5 #, L -80 BTC, ID = 9.950" H 4455' 5 6711 6488 18 DMY BK 0 07/17/98 4 7502 7205 33 DMY BK 0 06/16/95 3 8362 7918 34 DMY BK 0 06/16/95 2 9178 8592 34 DMY BK 0 06/16/95 7 -5/8" LNR, 29.7 #, NT80 NSCC XO -1 6109' 1 X 1 9367 8749 34 DMY BK 0 06/16/95 NT95 NSCC Minimum ID = 3.725" @ 9602' ( 9513' 1--14 -112" HES X NIP, ID = 3.813" 4 -1/2" HES XN NIP 9524' 1 —I 7-5/8" X 4 -1/2" BKR S -3 PKR w /K- ANCHOR, ID= 3.875" 1 9591' 1-14-1/2" HES X NIP, ID = 3.813" I 9602' H 4 -1/2" HES XN NIP, ID = 3.725" I 1 4 -1/2" TBG, 12.6 #, 13CR -80 NSCT, -1 9614' I-- 9614' 1-14 -112" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" 9595' I-1 ELMD TT LOGGED ON 08/03/11 1 PERFORATION SUMMARY REF LOG: DLL -GR on 06/08/95 ANGLE AT TOP PERF: 37° @ 11040' Note: Refer to Production DB for historical perf data 1 SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 10811 - 10840 0 08/04/11 ✓ 3 -3/8" 6 10890 - 10910 S 3 - 3/8" 6 10922 - 10932 0 ® 4 11037 - 11060 S 1 3 - 3/8" 4 11040 - 11048 0 3 - 3/8" 6 11066 - 11076 0 11105 -11115 S 1 11105 - 11115 0 11110 - 11116 S I I P B T D 1 11161 ' . e . ,. a . A . A . �. a y �. . A e . 7 -5/8" LNR, 29.7 #, NT95 NSCC, —1 11265' .0.0.0.0.0.0, .0459 bpf, ID = 6.875" DATE REV BY COMMENTS DATE REV BY COMMENTS ENDICOTT UNIT 06/16/95 SGK INITIAL COMPLETION 08/12/11 DW /JMD ADDED H2S SAFETY NOTE WELL: 1 -31 / M-21 10/04/95 JTP ADD PERFS 08/14/11 SRD/ PJC ADPERFS/ ELMD TT (08/04/11) PERMIT No: 1950720 11/05/96 JTP SQUEEZE & REPERF API No: 50 -029- 22562 -00 01/26/98 DAV ADD PERFS SEC 8, T11N, R17E, 2533' FNL & 858' FEL 02/17/11 MB /JMD ADDEDSSSV SAFETY NOTE 03/28/11 ?JMD REFORMAT BP Exploration (Alaska) ~; 07/20/09 Scht~ber~r , > ~ ~~~; i,,Nl~o 8~19 Alaska Data & Consultin Services ;' ~~ '~t.~ ~~~M ~~" •~~' ~' ~ :~ ~`' ~` ~ ~ ~ ~~ ~~ 9 ;~"c« Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken AT7N: Beth 333 West 7th Ave, Sui4e 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 4-04A/T-30 AYTO-00023 PRODUCTION PROFtLE 06/30/09 1 1 L3-31 AXBD-00030 MEM INJECTION PROFILE / 07/01/09 1 1 G-31 B ANHY-00100 LDL ( 07/07/09 1 1 Z-32BL1 AV1H-00018 SBHP RVEY ~ 07/02/09 1 1 14-10 AY3J-00033 PRODUCTION PROFILE ~'a(o 07/01/09 1 9 A-20 AV1H-00021 SBHP SURVEY - '~ 07/07/09 1 1 01-30 AY3J-00034 LDL {0 07/04/09 1 1 M-26A BOCV-00021 PRODU TION LOG 07/12/09 1 1 06-23C AXBD-00031 MEMORY PROD PROFILE - 07/03/09 1 1 L3-31 BOCV-00019 PRODUCTION LOG 07/09/09 1 1 L2-20 AYKP-00031 LDL / - 07/10/09 1 1 E-09B B04C-00064 SCMT 07/01/09 1 1 04-33 AY3J-00036 USIT 1 07/07/09 1 1 WGI-07 1-31/M-21 BOCV-00020 B148-00063 USIT PRODUCTION PROFIL~" 07/11/09 pg/iWpg ~ 1 1 ' L3-02 AZCM-00028 RST - 06/15/09 1 9 1-31/M-21 B14B-00063 RST ~'- 06M7/09 1 1 18-18B ANHY-00097 RST 'a - 06/09/09 1 1 DI Cnec erir~inun cnn_c oc rc~or ov ~~nu wn wun nrT~..,.~..~.. .. --- ------- - - - --------- -•--- ---. _._...._~. ~..~ ..... . r....... .... BP Exploration (Alaska) Inc. Petrotechnicai Data Center LR2-1 ~ 900 E. Benson B~vd. /rV i` ~;.. _. .~ ~,...,t Alaska Data & Consulting Seroices 2525 Gambell Street, Suite 400 Anchorage,AK 99503-2838 ~I1I u ~1 L J 07/20/09 ~7Yq~llr~r~~~ ,, , 1,~N}O; r5~`-19 a. ~.. ~.~,"a~,~,'~.'} _ t`t i, i ~ ~>1 ~`-.F:.~:'F Alaska Data & Consulting Services ~~~~' ` ~ ~ Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comrre Anchorage, AK 99503•2838 Attn: Christine AAahnken ATTN: eeth 333 Wes4 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 4-04A/T-30 AYTO-00023 PRODUCTION PROFILE O6/30/09 1 1 L3-31 AXBD-00030 MEM INJECTION PROFILE / 07/01/09 1 1 G-318 ANHY-00100 LDL ( 07/07/09 1 9 Z-32BL1 AV1H-00018 SBHP RVEY 07/02/09 1 9 14-10 AY3J-00033 PRODUCTION PROFILE ~"a(o 07/01/09 1 9 A-20 AV1H-00021 SBHPSURVEY - 07/07/09 1 1 01-30 AY3J-00034 LDL 07/OM09 1 1 M-26A BOCV-00021 PRODU TION LOG 07/12/09 1 1 06-23C AXBD-00031 MEMORY PROD PROFILE - 07/03/09 1 1 L3-31 BOCV-00019 PRODUCTION LOG ~ 07/09/09 1 1 L2-20 AYKP-00031 LDL / - 07/10/09 1 1 E-09B 804C-00064 SCMT - 07/01/09 1 1 04-33 AY3J-00036 USIT ( 07/07/09 1 1 WGI-07 BOCV-00020 USIT 07/1~/pg 1 ' 1-31/M-21 B146-00063 PRODUCTION PROFIL;,E ~ O6/16/09 1 1 L3-02 1-31/M-21 AZCM-00028 B14B-00063 RST ~ RST ' 06/15/09 O6/17/09 1 1 1 1 W 18-186 ANHY-00097 RST a~ ' 06/09/09 1 1 OI CACC Af`IlAIAi~/1 Gfl/±C ~G I~C~LfT ~V ~+II~~~~ a~A w _ -____-'__""_'"___~_"___" . ~.....................r..v.........av..~vvr~ ce~vn ~v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ ~__ ' _.! ~_..: ! Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ LJ ~ U Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Well 1-31/M-21 \ q,- C7:J.. 07-34A ) \JC . OJ J 15-14A ;).Ù4 - ;;tJ. ~ y -23B ). () J .~ i ~ '1 N-08A ,. \¡:..:. .. t crt K-08A '^ ~ ~ '- J &.( C W-26A 'C\í - t~ \ L5-09 \ q D ~ j J.. '1 OWDW-NW í C c .. J... '1 \:;, C-34 / 9 g ~ 0 ¡ ~- 01-12A ';2 ~).. - i Cq DS05-41A )3J ,·-1 ~/~ 02-26C ). Û > - 0 \ C\ Job# 10980540 11001051 10913003 10913024 10919802 10942219 11051066 11051031 10980531 10831309 10928620 10115311 10928619 RST (REVISED)* RST (REVISED)* PEX-DSI-AIT PDC-GR LDL MEM PPROF LDL RST RST RST MCNL MCNL MCNL *REVISED TO CORRECT API# ON DIGITAL DATA Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 'J ~71t-· ?v~~ \- ~Çf\NNE[ Date 04/14/05 04/26/05 01/16/05 06/09/05 09/24/04 06/24/05 06/23/05 04/21/05 03/26/05 01/09/04 04/03/05 01/21/04 03/20/05 SEP o ? 2005 NO. 3433 IQ&-07 f)..-. 07/14/05 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 1th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL CD 1 1 1 1 - Color I ~ 133 ;3^~Y /1 ÁJç-- I J 1-j ~. 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 13 23 7 /3 ),18 i J JJ c:¡ ) > )..'-Il\ j3~;"¡1 i);)..4¡ '-' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anch~rage, AK 7l~ 07.2838 , ATTN. Beth ~ Ó Received by: t \.~.t.. oJJJ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser,~6'' Commissioner FROM: John Crisp, Petroleum .Inspector. DATE: SUBJECT: May 20, 2001 Safety Valve Tests Duck Island Unit Endicott MPI 1 & 2 May 20 ,l,20,0,1: I traveled to BP's Duck Island Unit Endicott Field to witness Safety Valve System tests. Mark Souve was BP's Rep. in charge of SVS testing. Testing was condUcted in a safe & efficient manner. I witnessed one failure, the SSSV on well 1-19 failed to pass the DP test. The AOGCC test report is attached for reference. I inspected 25 well houses on MP! Row 1 & 2 w/no problems witnessed. SUMMARY: ! witnessed SVS testing in BP's Endicott Field. 17 wells, 51 components tested. 1 failure witnessed. 1.96% failure rate. 25 well houses inspected. Attachments: SVS DIU 5-20-01jc CC; NON-CONF!D._ENT.IAL SVS DILl 5-20-0 l jo Alaska Oil and Gas Conservation Commi~o.on Safety Valve System Test Report Operator: BPX Operator Rep: Mark Souve AOCJCC Rep: John Crisp. Submitted By: John Crisp Field/Unit/Pad: Endicott DIU MPI Pad Separator psi: LPS 235 Date: 5/20/01 HPS 'Well Permit Separ Set L/P Test Test Test Date oa. WAG, GIN J, Number Number PSI PSI Trip. Code Code Code Passed GAS or CYCLE 1-01/J19 1880370 235 150 125 p p P OIL 1-03/P16 1951500 235 150 135 p p P OIL , , i 1-05/020 1861060 , 1-09A/L2 1970290 235 150 130 P P P , OIL 1-15/P25 1930560 , , , , ,, , 1-17A/Il 1961990 1-19/11'8 1950930 235 150 125 P' e 9 1-21/K25 1900020 ,I , , '1'25MK2 1970750 235 150 150 p p P OIL 1-27/P20 ' 1870090 235 150 135i' P e p ' OIL 1-29/M25 1861810 1-31/M21 1~50720 235 150 125 p e ' p' oIL 1-33B/L2 1982550 235 150 145 p p p oIL 1-35/O25 1861840 235: 150 135 p P P OIL , 1-39/P17 1880630 1-45/Q56 1891240 , , 1-47A/M2 1972030 1-49/P21 1880780 235 150! 130 P ' P P oIL 1-~5/R25 1880210 235 150 145 P P P OIL 1-57/R23 1881140 235 150 140 P P P OIL 1-61/,.Q20 1941420 235 150 135 p P p " 'OIL 1-63/T22 i 8~00601 235 150 145 p P P OIL , , 1-65/N25 1951880 235 150 150 P P P OIL , 2-04/M19 1860820 2-06/J22 1870180i ..... I ' 2-08/K1~5 1880040! 2-1.2/Q16 1921170 , . 2-14/016 1861490: 2-18/L16 19004301 , , 2-20/L15 1900600 2-26/N14 1880550 , ,, 2-28/P19 1880860i 3.-30A/E1 i981880 ' ' 2-32/SN3 1901190 2-36/oi4 1900240 2-38/SN1 1901290 , Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GI~J, Number Number PSI PSI ,Tfi, P Code C0,de Code Passed GAS or CYCLE 2-42/P13 1881450 2-44A/Q1 1970710 2-46B/S1 1971370 2-50)U08 1930670 235 150 ' 145 P P P ....... OIL. 2-52/s 4 870920 2'56A/EI 1980580 2-58/S09 1900520 I .... 2-60FLI13 1930830 235 " 150 '130 e P ..... P 'oil , , , , ,,, 2-62/Q17 1861580 ...... 2-68/s 17 1880970 , , , ,, ,, , 5-01/SD7 1801200 , , Wells: 17 Components: 51 Failures: 1 Failure Rate: 1.~5% Ul9o ~av Remarks: RJF 1/16/01 Page 2 of 2 SVS DIU 5-20-01jc og. ggFo W C :l.,Og..lXlV~ field.DO C STATE OF ALASKA .... ALA?~--''' OIL AND GAS CONSERVATION COMMI~ ,",! REPORT (.,P SUNDRY WELL OPERATIONS ,. Operations performed: Operation shutdown __ Stimulate Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 3225' NSL, 2109' WEL, Sec. 36, T12N, R16E At top of productive interval 2835' NSL, 3465' WEL, Sec. 31, T12N, R17E At effective depth 2753' NSL, 3051' WEL, Sec. 31, T12N, R17E At total depth 2739' NSL, 2983' WEL, Sec. 31, T12N, R 17E 5. Type of Well: Development .. Exploratory __ Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-31/M-21 9. Permit number/approval number 95-072/Not required 10. APl number 50- 029-22562 11. Field/Pool Endicott Field/Endicott Off Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 71' 4416' 11226' measured true vertical 11300 feet 10304' BKB feet 11181 feet 10237' BKB feet Plugs (measured) Junk (measured) Size Cemented Measured depth BKB 30" Driven 110' 10-3/4" 716xc 'E', 461 sx 'G' 4455' 7-5/8" 723 sx Class "G" 11265' ^ (.~ /! 1QCIO ~as~ Oil ~ ~a~ Cons. Commissi~r T Anchorag~ rue vedica~ depth BKB 110' 42~9' 10890' - 10910'; 11037' - 11060'; 11110'-11116' (Squeezed) 10922'-10932';11040' - 11048'; 11,066' - 11,076'; 11105' - 11115' (Open) (Subsea) 9948'-9964'; 10065'- 10083'; 10123'- 10128' (Squeezed) 9973'-9981'; 10067'- 10074'; 10,098'- 10,096'; 10119'- 10127' (Open) Tubing (size, grade, and measured depth) 4 1/2" 13CR80 tubing set at 9614' 10248' Packers and SSSV (type and measured depth) 7-5/8" Bakerpacker set at 9524'; 4 1/2 SSSV set at 1503' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORiGiNAL 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1211 16712 3447 0 Tubing Pressure 1911 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~..,¢d'-'!4_~--;,. ~,~Ec~ Title s~ni, r T~.hn,c~, A-,sistant IV Date 7/30/98 SUBMIT IN DUPLICATE,~ 'T. ELEV = 6S.86' ~. ELEV = 14.5' ,...JAX DEV = MD = 10~.~4', 4S.6ff/fl, L.80 7-6/8", 29.7 t~ NTB0 XO Io NT~$ 1%q. EE: 4.1/18" / 5000 psi/CIW/BAKER CAC ACT'JATORS WELLHEAD: 13-~8" / ~003 pst / FMC SLIM HOLE SSSV LANDING NIPPLE ~' l~n~' HES 'HXO' (3,813' I,D,) ,^~,<cR P,oJEcT I 31/H-2'i ENDICOTT -- r -- 4.1/2", l~.$P/fl, 130R-80, NSOT Note: Inner Annulue Fluld~ And Stimulation A~d Must Contetn Cofroatofl Iflhlbltora GAS UFT MANDRELS HES MODEL TMPDX 1' DE LATCH MD-BKB 'I'VD.SS J ST LOG ' ,~zu_NEW~,'~,8-~ NARI<E'R LOGS fHAAS) : 50: 5~ ' 6EPTH UNIT -FEET ~OHPIFhl._~.I.I.I.I.I.I.~jT,.__~_tO~E ERFORATING ~%IMMARY Log: DIL-GR 10890'- 10910' 11037' · 11105'- 11115' 11110'- t 1040'- 11048' I t 105' - 11115' 11086'-1107§' 10922'-10932 ~.~ 4-112' 'X' NIPPLE HES (3.813" I,D.) ~ 7-5;8" BAKER PACKER SABL-3 w/K-ANCHOR ~ 4-1/2', 12,8~/11, CR13-80, TAILPIPE ~ 4-I/2' '×' N~PPLE HES (3,813' I.D.| 4-1/~" 'XN' NIPPLE HEB (3.725" I.D.) ~ 4-1/2" WLEG ELMD SQZ LEAKING AT 11106-07' 7-~/8", 29,711~1, ~ NT~S/NTa0 NSCC ~ Comments Initial Complellon ADD PBRF8 SQUEEZE & RE-PERF ADD PERP.q PBTD ELMD J 11134'I 8/18195 E ' - I -2 N . 0- 2 -22 OMPLETI D M B.P, EXPLORATION (ALASKA) INC, ~..' ~ 7/97 WELL NAME LO~31DATE ZONE TOP ~,D, BOTM.D, H TOPTVD BOTTVD SPINNER 8/1 ~/95 1.31/M-2'I GR/DIL 2A 10890 10910 20 9948 9964 SQUEEZED 6/8/95 U2A 10922 10932 10 9973 9981 '2A 11037 11060 23 10065 10053 SQUEEZED 2A .11040 11048 8 10067 10074 2A 11066 11076 10 10088 10096 2A 11105 11115 10 10119 10127 i i · i ¢8/17/97 SPINNER . 10/22/95 SQUEEZED SQUEEZED JUL 2 ! 1998 Alaska Oil & Gas Cons. Cor~"' STATE OF ALASKA ALASKA ~J~L AND GAS CONSERVATION COIViMISSION APPLICATION FOR SUNDRY APPROVAL t. Type of Request: [~Abando" · Name of r- BP'" BPX Endicott Production Engineering Department DATE: 7/19/98 WELL N°: 1-13/M-21 BP EXPLORATION REP: D. Williams SERVICE COMPANY: HB&R MIT on IA DATE/TIME OPERATIONS SUMMARY 0914 0921 0934 0941 0942 0950 1002 .. 1014 ,.. 1026 1030 1033 1103 MIRU to IA. PT hard line to 3800 psi. Start pumping diesel down IA @ 2.4 bpm 20 bbls away, @ 2.5 bpm 250 psi. 40 bbls away, @ 2.5 bpm, 0 psi. 42 bbls away, Switch to seawater. 20 bbls away, @ 2.5 bpm, 0 psi. 50 bbls away, @ 2.5 bpm, 0 psi. 80 bbls away, @ 2.5 bpm, 0 psi. 110 bbls away, ¢__. 2.5 bpm, 0 ps~. 121 bbls away, @ 2.5 bpm, 500 psi. 126 bbls away, @ .5 bpm, 3500 psi. Held for 30 m~ns. Held 3500 psi for 30 mins. Good test. RDMO. SUMMARY: * Pumped a total of 2 bbls of meth. 42 bbls of diesel, 126 bbls of seawater. · Held 3500 psi for 30 mins. Good test. h. ared ices rilling To: Jeff Eckstein / Dan Robertson Endicott PE Supervisors From: Jeff Hupp MB8-1 Subject: Endicott lVIPI 1-31/lVI-21 Pre-Rig P&A Pre-Rig Work Detailed Procedure Date: July 16, 1998 Confirm with Jeff Hupp or Chris West that the AFE has been approved and P&A Sundry Notice have been approved by the AOGCC prior to commencing P&A operations. Notify AOGCC prior to commencing with plug-back operations. NOTE: If any problems with the 7-5/8" packoff are observed during pre-rig, contact the wellhead manufacturer to initiate repairs. If repairs are not possible, the TTRD sidetrack will be halted, and an alternative sidetrack method used. COMMENTS 1. The 7-5/8" x 4-1/2" production packer is a Baker permanent packer with a K-anchor assembly. The packer and 4-1/2" tubing will be left in place. 2. The existing perforations will be plugged with cement. 3. The 3.8" od sidetrack window will be milled off of a fiber cement plug. 4. The most recent BHP of 4450 psi on 8/7/97@ 10000' TVDss. The static BHT is 216° F. PRE-RIG OPERATIONS 1. Test 4-1/2" tbg hanger void area to 3500 psi. Test 7-5/8" packoff to 3500 psi. , RU slickline, Pull the WL SSSV. Dummy off gas lift mandrels and drift tbg to w/3.80" od drift to XN nipple @ 11186'. 3. Slick line drift to PBTD wi 3.65" OD drift. Correct PBTD to TBG Tail ELM depth. 4. Load and pressure test IA (tubing and annulus) to 3,500psi with seawater. . RU Coil tubing unit. RIH w/3.80" (HC Model 331 DB) pilot mill on a 2.875" straight motor assembly.. Tag XN nipple @ 9602' MD. Mill out nipple to 3.80" ID. After milling., PU and slack off through nipple with the pump off to ensure nipple is fully milled. RIH & Tag bottom wi pump off. Flag pipe 100' off btm. POH. LD motor assy. Gauge mill to ensure window is 3.80" ID. . MU fiber cement nozzle. The nozzle should have a large hole to prevent fibers from plugging (0.600" or larger) and jet swirl holes of 6@3/16" to 1/4" for higher rate through 1- 3/4" CT. Run stingers if a small nozzle is used to prevent setting down in gas lift mandrels. MU injector and pressure test lubricator. Open we!! and begin pumping 80° seawater down the backside at maximum rate. Standard pump rates are 3-1/2"=3 bpm, 4-1/2"=4 bpm, 5-1/2"=5 bpm (BPM = tubing size in inches). If unable to achieve sufficient pump rate. RIH and circulate gas out from bottom holding backpressure on the choke to prevent an influx. Tag PBTD and correct CT depth. . After the wellhead pressure is reduced to <1500 psi, RIH and continue pumping at maximum rate down the backside. Monitor annulus pressures while pumping hot fluid and bleed off as needed. Inner annulus Maximum Allowable Working Pres~,r~(l~p~ ED is 2000 psig. Outer annulus MAWP is 1000 psig. JUL 17 1998 MPI 1-31/M-21 Pre-Rig P&A Alaska 0il & Gas Cons. Commission Anchorage , 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. After a minimum of 1-1/2 wellbore volumes are pumped, reduce rate to minimize fluid volume, but it must be sufficient to prevent gas from migrating back into the wellbore; usually 1/2 BPM. Maintain enough rate to achieve positive well head pressure. Tag bottom with nozzle and correct as needed (Note: Do not tag while pumping down the coil as circulating will make it difficult to note the top of fill and could cause incorrect depth correlation). Flag pipe 10' off bottom. If depth correction is questionable, plan to err to the high side with the cement top. Batch mix 34 bbls (5 bbls extra for tank btms) of cement. Typical Dowell Schlumberger (DS) kick-off cement is 17 ppg class "G" with 1% bwoc D-65 dispersant, 0.35% bwoc D- 156 non-retarding Fluid Loss additive (for wells with open perfs below cement to give fluid loss of less than 100 cc/apl 30 minutes at BHCT), .02gps D-47 antifoam, 0.24%bwoc D- 800 retarder based on 170°. Pump time 4hrs 26 min. Add 2.5#/BBL Control 1000 Nylon 6 Fibers to 25 bbls of cement. Blend fibers in to cement.. Thickening time will be measured at BHCT (170°). Measure compressive strength in the UCA using a 30 minute temperature ramp to BHCT and hold until 4000 psi. This will result in a more conservative indication of compressive strength when compared to downhole conditions of gradual temperature increase to BHST. Connect cementer pump to coil. Pump a 5 bbls fresh water spacer ahead of cement to verify tank straps with micro motion meter. Send cement sample to lab for UCA test. Pump 2 bbls neat, 22 bbls fiber cement followed by 2 bbls neat cement. (The neat cement ahead and behind the fiber slurry is to prevent fiber balls forming in the cement/water interface). Follow the cement w/5 bbls fresh water. Displace with seawater. It has been observed that fiber cement is pumped smoother at maximum rate. This will also help control cement fallout. Zero totalizer when cement (density increase) reaches micro motion meter. Continue to Use cementer tank straps throughout job (cement and CT volume flush) to verify micro motion meter. Continue backside injection to maintain positive WHP. Position nozzle at flag as cement reaches nozzle. Allow neat cement top in casing to rise 50-75' (2-3 bbls) above the nozzle before pulling up hole at the same rate as the cement is being laid in. When cement top is at perforations, stop backside injection and prepare to take returns to the 40 bbl open top tank. Monitor returns while cementing. Note: Do not allow "squeeze pressure" to develop when nozzle is below open perfs or leaks. Immediately reduce any annular injection and bleed well head while pulling nozzle above perforations before resuming squeeze. Lay in cement 1:1 until cement reaches at least 10' above the top of perforations. Close choke while continuing pumping down CT until a 500 psi (above final kill pressure) pressure bump is observed (note BPP). At 500 psi, open choke, and maintain 500 psi while taking returns laying in remainder of cement at 1:1. Spot the cement fl 11,134'to 10,500' MD. PU to safety and attempt to squeeze cement with 1000 psi to reduce the amount of cement to clean out. Position coil at cement top as last bbl of cement exits nozzle, adjust pump rate to match CT volume being withdrawn and pull up hole to safety depth (Depth higher than where cement top would be assuming no cement exited the casing). Squeeze cement to 1000 psig and note BBP. Maintain squeeze pressure for approximately 15 minutes while pumping down CT with 1.5#/BBL Biozan. Do not squeeze cement top below 10,550' to allow the window to be cut @ 10600' ELM. Bleed well head pressure to 500 psi over final kill pressure and clean out with Biozan to 10,550', 10' above desired cement top @ 10,560' (40' above kick off point) with nozzle in jetting mode at maximum pump rate. Mark fluid totalizer when nozzle reaches expected cement top and monitor bottoms up returns. MPI 1-31/M-21 Pre-Rig P&A 2 24. 25. 26. 27. 28. 29. Make 2 passes from 10,550' MD to the tubing tail (TT), flag pipe and POH at 80% maintaining 500 psi over final kill pressure. Make up/down/up washing passes through all jewelry and GLM's on the way out of the hole. Freeze protect top 1500' of well with diesel. At surface, SI well with 500 psi while WOC. RD & MO CTU. After allowing cement to set up for 2 days, pressure test cement to 2500 psi for 30 minutes. Contact AOGCC representative to witness test. Document test on pressure chart recorder. RU slickline unit and tag cement top. Record cement plug top in reference to tbg tail. POH & RD SL unit. Contact AOGCC representative to witness test. Set BPV after observing well for 2 days to ensure well is dead. Remove flowline. Level pad and prep for rig move. Chris West Senior Drilling Engineer CC'- Dan Stoltz Susan Brown Brent Voorhecs DS CT supervisor (Deadhorse) MPI-1-3 l/M-21 well file MPI 1-31A/L-24 Well File Doyon 15 Rig Supervisor Attachments Present Schematic Proposed Pre-rig Schematic Approved Sundry Notice Lowell Crane SSD Engineering Supervisor MPI 1-31/M-21 Pre-Rig P&A 3 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI" /N REPORT SUNDRY WELL OP=RATIONS ,. Operations performed: Operation shutdown__ Stimulate m Plugging__ Pull tubing__ Alter casing ~ Repair well__ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc, 3. Address P. O. Box 196612, Anchora.Qe, Alaska 99519-6612 4. Location of well at surface 3225' NSL, 2109' WEL, Sec. 36, T12N, R16E At top of productive interval 2835' NSL, 3465' WEL, Sec. 31, T12N, R17E At effective depth 2753' NSL, 3051' WEL, Sec. 31, T12N, R17E At total depth 2739' NSL, 2983' WEL, Sec. 31, T12N, R17E 5. Type of Well: Development .. Exploratory ~ Stratigraphic __ Service ~ 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-31/M-21 9. Permit numbedapproval number 95-072~Not required 10. APl number 50- 029-22562 11. Field/Pool Endicott Field/Endicott Off Pool 12. Present well condition summary Total depth: measured 11300 feet true vertical 10304' BKB feet Effective depth: measured 11181 feet true vertical 10237' BKB feet Plugs (measured) Junk (measured) Casing Length Structural Conductor 71' S u trace 4416' Intermediate Production 11226' Liner Perforation depth: Size Cemented Measured depth True vertical depth BKB BKB 30" Driven 110' 110' 10-3/4" 716xc 'E', 461 sx 'G' 4455' 4279' 7-5/8" 723 sx Class "G" 11265' 10248' measured 10890'- 10910'; 11037'- 11060'; 11110'-11116'(Squeezed) 10922'-10932';11040' - 11048'; 11,066' - 11,076'; 11105' - 11115' (Open) Tubing (size, grade, and measured depth) 4 1/2" 13CR80 tubing set at 9614' true vertical (Subsea) 9948'-9964'; 10065'- 10083'; 10123'- 10128' (Squeezed) 9973'-9981'; 10067'- 10074? 10,098'- 10,096'; 10119'- 10127' (Open) ORIGINAL Packers and SSSV (type and measured depth) 7-5/8" Baker packer set at 9524'; 4 1/2 SSSV set at 1503' 13. Stimulation or cement squeeze summary Additional Perforation 1/25/98 Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 585 734 5988 0 433 Subsequent to operation 2142 1564 2726 0 680 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 tha/t.~e foregoing is true and correct to the best of my knowledge. Signed ~ Title ~_ni~r 'r~chnic~! A.~.~i_~t~nt IV i Form 10.4~/Rev 06/15/88 - , Date 3/9/98 SUBMIT IN DUPLICATE'~ BPX Endicott Production Engineering Department ADD PERFS DATE: '1125-26/98 WELL N°: 1-31/M-21 BP EXPLORATION REP: VARBLE SERVICE COMPANY: SWS (S. Deckert)) TIME 0900 1030 1100 1300 OPERATIONS SUMMARY MIRU SWS FWHP = 450 lAP = 2200 Make up toolstring. Temp. -36 deg. -80 wind-chill. Weather trending down. Cease operations & monitor temp. Shut down operations due to weather. OAP = 200 1/26/98 O9O0 0920 0925 0930 0950 1140 1145 1300 1330 Rig up. FWHP=450 lAP=2200 Call brradio silence. Posts~gns. OAP=200 Hold safety meeting. Arm gun (10' 3-318") Shut in well & RIH with Gun-GR / 10' gun Tools @ 10500' MD. Lost signal. Trouble shoot. Appears to be a dead short. POOH OOH. Dis-arm gun & trouble shoot toolstring. Gun-GR bad. Repair. 352 410 515 52O 53O 54O 55O 1553 1605 1710 1730 1830 Re- arm gun. RIH with same toolstring. Out of tbg. Open choke to 30 beans to underbalance well. Tie into DIFL dated 8/5/95. Take out 20'. Log confirmation pass. On depth. Log into place & hang CCL @ 10917.5'. (4.5' from CCL to top shot) Shoot gun from 10922'-10932' MD. Small weight loss, did not see a good cap break. Log off. Shut in well & POOH. OOH. Confrim all shots fired. Lift radio silence. POP to 40 beans & request well test ASAP. RDMO. Perforation Summary: Perforation Interval Len_clth Zone 10922'- 10932' MD 10' U2A All perforations were shot w/ 3-3/8" HSD 20.5 gram charges @ 6 spf, 60 deg phasing w/random orientation. STATE OF ALASKA AL,&,;c"~--OIL AND GAS CONSERVATION COMMIS,¢'-'~''~' ~. REPORT SUNDRY WELL OF-.,ATIONS · Operations performed: Operation shutdown__ Stimulate__ Plugging Pull tubing__ Alter casing __ Repair well __ Perforate X Other .. 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. B°x 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 3225' NSL, 2109' WEL, Sec. 36, T12N, R16E At top of productive interval 2835' NSL, 3465' WEL, Sec. 31, T12N, R17E At effective depth 2753'NSL, 3051' WEL, Sec. 31, T12N, R17E At total depth 2739' NSL, 2983' WEL, Sec. 31, T12N, R17E 5. Type of Well: Development .. Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-31/M-21 9. Permit number/approval number 95-072~Not rec~uired 10. APl number 50- 029-22562 11. Field/Pool Endicott Field/Endicott Off Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11300 feet 10304' BKB feet 11181 feet 10237' BKB feet Plugs (measured) Junk (measured) OR161NAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 71' 4416' 11226' Size Cemented Measured depth True vertical depth BKB BKB 30" Driven 11 O' 11 O' 10-3/4" 716 xc 'E', 461 sx 'G' 4455' 4279' 7-5/8" 723 sx Class "G" 11265' 10248' measured 10890'-10910? 11037'-11060';11110'-11116'(Squeeze¢ 11040'- 11048'; 11,066'- 11,0767 11105'- 11115' (Open) true vertical (Subsea) 9948'- 9964'; 10065'- 10083'; 10123'- 10128' (Squeezed) 10067'- 10074'; 10,098'- 10,0967 10119'- 10127' (Open) At,, Tubing (size, grade, and measured depth) 4 1/2" 13CR80 tubing set at 9614' °-4~,~ Packers and SSSV (type and measured dept ) 7-5/8 Baker packer set at 9524; 4 1/2 SSSV set at 1503 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 456 549 4449 0 397 866 625 5233 0 433 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Daily Report of Well Operations × Oil × Gasm Suspended__ 17. I her,.eby, certify that,th~foregoin~l is true and correct to the best of my knowledge. Signe _ Title 5;~nicr T~chnical A_~.~i.~t~nt IV Form 10-4(J4/Rev 06/15/88 J v Service Date 11/14/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department ADD PERFS DATE: 10/4/97 WELL N°: 1-31/M-21 BP EXPLORATION REP: VARBLE SERVICE COMPANY: SWS (C. Yon) TIME OPERATIONS SUMMARY 0800 MIRU SWS FWHP = 400 lAP = 1875 CAP = 0 0900 Hold safety meeting. Call for radio silence. 0915 Arm gun 0945 Shut in well & RIH with GUN-GR/10' GUN with SAFE PKG. 1045 Out of tbg. Log tie in pass. Tie into DIL dated 6/8/95. Add 4' 1100 Open choke & bleed well down for underbalance. 1115 Log confirmation pass. On depth. 1119 Log into place & hang CCL @ 11060'md. (CCL to top shot - 6') 1125 Shoot gun from 11066'-11076' md. No cap break or weight change. Try several more times to shoot. Appears that a panel breaker tripped while shooting first time. Reboot panel & computer. 1140 Log a re-confirmation pass. Take out 1' 1148 Log into place. On depth. Attempt to shoot again. No cap break or weight change. Try several more times. No luck. 1222 POOH 1240 May have solved problem (made adjustments to panels). RIH & tie in. Add 1' 1255 Log confirmation pass. On depth. Log into place & shoot gun. No change. 1302 POOH. 1400 CCH. 1406 All shots fired. POP to FCC with G/L & request test ASAP 1500 RDMO Perforation Summary: Perforation Interval Length Zone 11,066'-11,076' MD 10' 2A All perforations were shot w/ 3-3/8" HSD 20.5 gram charges @ 6 spf, 60 deg phasing w/random orientation. AC;,GCC Ind'ividua'l '¢te1'i ,Sec,'Jog')'ca'l Hat. er"ials Inventory D A 'i"' A 'T D A T A_..P L U S 95-'~ 0'? 2 BHP FZNAL 95-~072 CN/GR/FiNAL 95--072 DZFL/GR 9B .... 0'72 S'SVD/'FINAL. 95.~072 ZDL/CN 9 s .... 0 7 2 ,s R/cc [... 95-~072 GR/CCL 95 .... 072 5BT/GR/CCL 95,,-072 PRO!.} PROFILE 95 ..... 072 GR/:2CI.. 95-~072 PROD PROFILE 95 .... 072 ,"3R/Cr'L. 95..-0?2 GR/CCL 95-~-0'72 F'ERF RCD 95~,-072 671t~ 10 ..... a. o7 ' ~'q.z~08-1125'7 ..~/%a~08 I1239 ~. 9~08---11292 ~q08---11292 ~9599-Ii 159 . ~' 10750,--10960 ~/.~10'~i1292 DIFL/ZDL/CN/GR ~OHPL. ETION DATE ~//~/~/ [3, ate~ 03/I9/97 R U N D A Y E._R E ,S V D 06/16/95 1 06 ,/i 6 / 95 1 06/i6/95 1 06/16/95 1 06/'16//!}5 · 1 ['.) 6, / 26 / 9.5 '1 06/26/95 'l 06/2 6/'95 i 0 7/' 06 / 95 1 0 9/' 'i h~ 95 1 09/ia./95 1 'l 0/2~/95 1 10/2/~/95 FZNAL. 'i i/08/96 06/'~ 6/c, ¢/2 ~/'¢~5/ DAILY WELL OPS ~/"2Z/ ¢)'/ TO 6~IL /°7// q/"A~/''~1~ / Ar"e dr'y d'¥Lcl"~ Was the we'il cot'.ed? Are well We'l 1 'i s C 0 l,,1 i,,I E N T S samp'ies i--'equ-ii-"ed? ',/'es ~And r"ece'ived? y~ yes tests i"equ'¥r'~d?.~/ yes 'in comp'l'¥ance ...... ~ I n 'i '.: 'i a 1 ~_~ Ana'iys'is & descr"-ipt~on r'ece'~~'~ Rece'i ved? yes y e S I'"~ 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISsiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate X Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development X KBE = 56' feet Exploratory __ 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service __ Duck Island Unit/Endicott 4. Location of well at surface 8. Well number 3225' NSL, 2109' WEL, Sec. 36, T12N, R16E At top of productive interval 2835' NSL, 3465' WEL, Sec. 31, T12N, R17E At effective depth 2753' NSL, 3051' WEL, Sec. 31, T12N, R17E At total depth 2739' NSL, 2983' WEL, Sec. 31, T12N, R17E 1-31/M-21 9. Permit number/approval number 95-072~Not required 10. APl number 50- 029-22562 11. Field/Pool Endicott Field/Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11300 feet 10304' BKB feet 11181 feet 10237' BKB feet Plugs (measured) Junk (measured) ORIGI AL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 71' 4416' 11226' measured true vertical Size Cemented Measured depth True vertical depth BKB BKB 30" Driven 11 O' 11 O' 10-3/4" 716xc 'E', 461 sx 'G' 4455' 4279' 7-5/8" 723 sx Class "G" 11265' 10248' 11040'-11048'; 11105'-11115' (all open) (Subsea) 9948' - 9964'; 10065' - 10083'; 10123' - 10128' (all squeezed),, 10067; 10074'; 10119; 10127' (all open) ~ AN 0 2 1997 Tubing (size, grade, and measured depth) 4 1/2" 13CR80 tubing set at 9614' AJaska O~ & Gas Cofi$. Coffi~ ,~U~rage Packers and SSSV (type and measured depth) 7-5/8" Baker packer set at 9524'; 4 1/2 SSSV set at 1503' 13. Stimulation orcement squeeze summary Gas shut off and cement squeeze (10/30/96), add perforations (11/4/96) Intervals treated (measured) 10890;10910'; 11037;11060'; 11040;11048'; 11105'-11115'; 11110'-11116' Treatment description including volumes used and final pressure 11oo bbls fresh sea water, 25 bbls 12% HClJxylene, 85 bbls EW, 17 bbls cement, 36 bbls methanol to FP coil. FSIWHP=1700 psig. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 2915 22653 1133 0 2391 552 665 4966 0 439 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended__ Service 17. I he?by~,certify that the ~'g~oing is true and correct to the best of my knowledge. Signed '",. ,~~; ~v~"~l/'L/~_ ~ ,..,~ Title Senior Technical Assistant lV Form 10-~/4 Rev 06/15/88 Date 12/30/96 SUBMIT IN DUPLICATE Endicott Production Engineering Department OPERATIONS REPORT DATE: 11/4/96 WELL N°-: 1-31/M-21 TYPE OF OPERATION' BP EXPLORATION REP: SERVICE COMPANY: ADD PERFORATIONS POWERS SOS (MAJOR) DATE/TIME OPERATIONS SUMMARY 0900 MIRU ATLAS. 1000 SI WELL. RIH WITH GR/CCL/10' & 8' SELECT FIRE 3-3/8" GUN. SIP=2100 PSIG, lAP=2100 PSIG, OAP=0 PSIG. 11 1 8 DROPED OUT OF TUBING. POP WELL @ 40 BEANS. SIP=2100 PSIG. TIE-IN TO THE DIL DATED 6/8/95. 1 145 HANG CCLAT 11089'. SHOT GUN # 1 FROM 11105'- 11115'. LOST 150 PSIG. LOG OFF. 1 200 CONFER WITH ANCHORAGE ON DEPTH OF 2ND INTERVAL. 1230 TIE-IN. HANG CCLAT 11034'. SHOT GUN # 2 FROM 11040'- 11048'. NO INDICATIONS. LOG OFF. 1245 SI WELL AND POOH. 1 335 AT SURFACE. ALL SHOTS FIRED. RD SOS. 1400 POP WELL WITH LIFTGAS. FWHP: 500 PSIG @ 104 BEANS lAP: 1600 OAP: 250 PERFORATION SUMMARY: Gun # length Interva Sand I 10' 11105-11115' 2A 2 8' 11040-11048' 2A 3-3/8" Hyperjet II (SOS) 4 SPF, 180° phasing, and random orientation BP EXPLORATION PRUDHOE BAY, ALASKA TO: KIMMET/MCBRIDE FROM: POWERS/CLUMP WELL: 1-31/M-21 OPERATION: GSO LOCATION: ENDICOTT DATE: 10/30/96 Initial Well I SIWHP lAP 0AP GLP FLP FLT StatusI (psi) (psi) (psi) (psi) (psi) (o F) II o 2so T I M E OPERATION 11:00 MIRU DS #1. CTV=33 BBLS 12:20 PT LUBRICATOR 12:28 BOP TEST 13:05 RECOVER METHANOL 1330 BEGIN KILL I TIME DEPTH RATE CTP WHP STG BBL REMARKS BPM VOL. RETN. 1400 SURF 5 1400 1200 150 BEGIN TRIPPING IN HOLE DISK ERROR - LOST INFO HERE. HAD PUMP PROBLEMS AND COULD NOT CONTINUE KILL WHILE RIH. 15:36 10000 0 49 290 20K 15:57 11125 0 0 59 290 TAG TD AND CORRECT DEPTH. 23K OFF BO ~ ~ O~ 16:22 11125 1.5 1700 132 302/0 FINALLY START PUMPING AGAIN. BEGIN COOLING SUMP 17:01 2.2 3430 240 92 PUH TO SAFETY 17:24 10500 2,16 3400 315 142 GAS IS MIGRATING TO TOP OFTUBING. START MIXING CEMENT. 17:36 11125 365 170 CONTINUE TO COOL. 17:47 2/1.5 1780 374 190 CEMENT TO WEIGHT. SAFETY ME~- I lNG. 18:22 11125 MAX 3800 440 245/0 STAGE ACID AND PUH 18:34 10850 2.1 3600 544 14 25/O SW TO SW 18:45 2.2 3600 590 ACID AT NOZZLE RIH @ 50 FPM 18:50 11120 2.3 3640 580 22 PUH @ 50 FPM 18:56 10800 2.3 3600 608 37 OVER DISPLACE RIH. 19:05 11120 2.3 3650 630 43 BLEED SOME GAS DOWN FLOWLINE. 19:18 2.3/0 40 200 71 CHECK HYDROSTATICS 19:32 30 MIN FL = 39 ML 19:38 1.5 1600 187 100/0 SWTO EF 19:46 10/0 SW TO CEMENT 19:58 1.7 3700 123 17/0 SW TO EF CIRCULATING GAS TO GREEN TANK 20:07 16 CEMENT AT NOZZLE 20:09 19 PUH 22 FPM - LOST DEPTH CONTROL AND COIL SPEED 2014 500 38 CRACK CHOKES 20:20 10766 PLF 20:23 10500 1 1300 500 AT SAFETY 20:24 1/.5 RAMP PRESURE TO 1000 PSI. RETURNS TO GASSY TO GAUGE. 20:30 1250 1000 RAMP TO 1500 20:33 1500 43 START GAUGING 20:35 44 .75 20:37 45 1.75 GO TO 2300 2300 46 2.0 20:41 47 3.0 20:43 48 4.0 20:46 GO TO 3000 2800 5O 5.5 3000 51 6.5 20:50 52 7.5 20:51 3000 21:12 3000 DROP PRESSURE TO LINE UP AND REVERSE O~ 21:16 10500 0 2075 2045 57/0 BEGIN REVERSE - PUMP PROBLEMS AGAIN. 21:38 1.6 40 2000 BEGIN REVERSING FOR REAL 21:46 10780 54 2077 TOP OF CEMENT ? 21:52 10820 1.5 22 2300 82 REDUCE RATE 22:29 10902 1.3 0 VERY DIFFICULT TO GET REVERSE OUT STABILIZED- NOZZLE PLUGGING? 0:24 11135 1.3 0 1900 ? WAIT FOR BO'I-I-OMS UP. 15 BBLS OF CEMENT RETURNED. 0:51 11125 1.7 SD FOR PT AND LINE UP FOR JET PASSES. 1:01 275 SQUEEZE IS LEAKING. LINE UP TO JET. 1:06 1.5 3000 1500 BEGIN JET 1:34 1885 1972 43/0 BEGIN FINAL REVERSE OUT 2:04 11125 1.5 0 1600 44 POOH WHILE REVERSING 2:59 3400 1.5 3200 1550 141/0 FP COIL 3:30 SURF 0 1500 1700 37 PUT LIFT GAS ON CAP TO HOLD BACKPRESSUF 4:30 RDMO DS - LEAVE GLT JUMPER ON WELL TO H( PRESSURE OVER NIGHT. Final Well DATE WHP lAP 0AP GLP FLT Status (psi) (psi) (psi) (psi) (o F) II 10/31/96 1700 450 0 1700 SI i! SUMMARY BH killed well with 290 bbls of FSW and lost coil pump. Cooled sump with 245 bbls of FSW with the cementers pump. Layed 25 bbls of 12%HCL/10%xylene across perfs and over displaced with 100 bbls of FSW. There was too much gas in the tubing to determine effectiveness of acid. Injectivity was good at 2 BPM at less than 200 psig WHP. Layed in 17 bbls of cement with chokes closed. Opened chokes at 500 psig and finished laying in cement. Ramped squeeze pressure to 3000 psig over 30 min. Held 3000 psi for 20 min then reduced pressure to 2000 psig for 30 min to work on pump problems. Squeeze was jug tight with cement covering the perfs. LRO'd to 11135 CTMD recovering 15 bbls of cement. Jettted liner and reversed back same. Final PT was (-20 psi/min). Held 1500 psi on well while tripping OOH. Put a gaslift jumper to the wellhead to maintain overbalance as long as possible. 2 bbls behind pipe Squeeze leaking 20 psi/min. 1997 I FLUIDS PUMPED B BLS. DESCRIPTION 1100 FSW 25 12% HCL/XYLENE 85 EW 17 CEMENT 36 METHANOL TO FP COIL BOTTOM-HOLE ASSEMBLY #1 Tool Strin~ Descriptions O.D. I.D. Length Comments TC 3.0 0.46 X-O 3.0 0.38 CNZ 3.50 0.5 TOTAL 1.34' CEMENT DETAILS BJ SERVICES 15.8 PPG Class G Cement containing: .05 gps D47 0.3% D65 O.37 % DS00 1.1% D156 .03 gps Dl10 Thickening Time = 8 hrs 50 min Lab APl Fluid Loss = 38 mi Field APl Fluid Loss -- 39 mi 1 1/7/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10557 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 1 - 31 / M - 21 PERFORATION RECORD 9 61 1 0 4 I 1 1 - 6 7IT- 2 0 PERFORATING RECORD 9 61 0 2 8 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: ht CEiVbu. l~0V 0 8 ]99~ Alaska Oil & Gas Cons. Commission Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska ;.¢~,1A,9~9- ~!% ~i-'- ~-,~ R e c e iv e d'4:L~ ~..! Z,,,,"~~~~//¢~ / / ^bska Oil & Gas Co)~, ~mmissior~ TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 TO: FROM: Wendy Mahan w~ Natural Resource Officer ._~ David W. Johnston, Chair~TM//,,0 [~.~'~ Tuckerman Babcock, Commissit~h~r Leak-OffTests at Endicott DATE: 21 Oct 96 There is a possibility that some leak-off tests within the Endicott Field may not have been properly conducted, q ~.ooSJ Specifically, leak-off tests on 1-3 I, 3-37 and ~ Commissioner Johnston and I have discussed this matter and request that you initiate an investigation to determine whether these tests were properly conducted under our standard of good oilfield engineering practices. Please feel free to rely on Mr. Wondzell and the inspectors for assistance. The allegations are serious and your investigation should be conducted with deliberate speed and tempered by discretion. Commissioner Johnston and I will assist you in any way possible. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 14 December 1995 Transmittal of Data ECC #: 6542.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: ARCO 4-29A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 ZDL/CN FINAL BL+RF Run # 1 1 DLL FINAL BL+RF Run # 1 1 CN FINAL BL+RF Run # 1 1 BH PRO FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 Please sign and return t~~n. Rodney D. Paulson ~4~s Wireline Services 5600B~~e~ / Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: ~-/--~ ~ / /~/~ Date: RECEIVED DEC 7 ? & G.~s Cons. Commissiotl Anchorage STATE OF ALASKA ~-,-,_K.A OIL AND GAS CONSERVATION COMMIS~UN REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Pull tubing Alter casing __ Repair well __ Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3225' NSL, 2109' WEL, Sec. 36, T12N, R16E At top of productive interval 2835' NSL, 3465' WEL, Sec. 31, T12N, R17E At effective depth 2753'NSL, 3051' WEL, Sec. 31, T12N, R17E At total depth 2739' NSL, 2983' WEL, Sec. 31, T12N, R17E 5. Type of Well: Development Exploratory Stratigraphic Service OEtGIi'aAL 6. Datum elevation (DF or KB) KBE = 56' feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-31/M-21 9. Permit nt~'rrlber/app~val number 95-072/Not required 10. APl number 50- 029-22562 11. Field/Pool Endicott Field/Endicott Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 71' Surface 4416' Intermediate Production 11226' Liner Perforation depth: 11300 feet 10304' BKB feet 11181 feet 10237' BKB feet Plugs (measured) Junk (measured) Size Cemented i .~i :-.,; :,.;, .>,.]~i~21':.:',. r-j!] ~,,... ,,:,...::.:, ( r::~;. £','"'*i%t"'-? ~¢-: · Measured depth :'. 'Tfu~-'verbca depth BKB BKB 30" Driven 11 O' 11 O' 10-3/4" 716xc 'E', 461 sx 'G' 4455' 4279' 7-5/8" 723 sx Class "G" 11265' 10248' measured 10890' - 10910' (Open), 11037' - 11060' (Squeezed), 11105' - 11115' (Squeezed), 11036' - 11042' (Open), 11110'- 11116' (Open) true vertical (Subsea) 9948' - 9964' (Open), 10065' - 10083' (Squeezed), 10119' - 10127' (Squeezed), 10064' - 10069' (Open), 10123'- 10128' (Open) Tubing (size, grade, and measured depth) 4 1/2" 13CR80 tubing set at 9614' Packers and SSSV (type and measured depth) 7-5/8" Baker packer set at 9524'; 4 1/2 SSSV set at 1503' 13. Stimulation or cement squeeze summary Water shutoff cement squeeze on 8/14/95 followed by perforating on 8/20/95, 10/5/95 and 10/14/95 Intervals treated (measured) 11037' - 11060', 11105' - 11115' Treatment description including volumes used and final pressure 915 Bbls produced water, 343 Bbls seawater, 20 Bbls fresh water, 21 Bbls cement and 509 bbls produced water/seawater. FSWHP = 1920 psig 14. Prior to well operation Subsequent to operation .Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 3494 2109 3494 0 401 2762 16425 362 0 2427 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 Senior Technical Assistant II Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Endicott Production Engineering Department ADD-PERF DATE: 10/14/95 WELL N°: 1-31/M-21 BP EXPLORATION REP: CLUMP SERVICE COMPANY: ATLAS(BARKER) DATE/TIME OPERATIONS SUMMARY 1600 MIRU ATLAS FWHP = 425 psi. IAP = 2000 psig. OAP = 450 psig. 1700 RIH with Gun #1 (20 feet). 1745 Open wing valve. Open choke to 25 beans. Start tie-in. 1810 Tie-in to SBL 15-June -95(+20). RIH to 10960' MBKB. Log confirmation pass from 10960' - 10750' MDBKB. On depth. Drop down to 10960'. Log in to position. CCL depth 10888' MDBKB. 1835 Shoot Gun #1(10890-10910' MDBKB). Good pressure indication. The FWHP= 730 psi to 880 psi. Log off. SI well. POOH. 1915 OOH. Confirm all shots fired. SIWHP= 940 psi. 1930 RDMO ATLAS. POP well at 40 beans. Nice well. PERFORATION SUMMARY: GUN DEPTH FEET SUBZONE 1 10890-10910 20' 2AU All guns were 3 3/8" HSC's at 6 spf, 60/120° phasing and random orientation. Endicott Production Engineering Department OPERATIONS REPORT DATE: 10/5/95 WELL N-°: 1-31/M-21 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: ADD PERFORATIONS POWERS ATLAS (BRUNER) DATE/TIME OPERATIONS SUMMARY 0900 MIRU ATLAS. 0950 SI WELL. RIH WITH GR/CCL/6' 3-3/8" GUN. SIP=500 PSIG, IAP=1600 PSIG, OAP=250 PSIG. 1045 DROPED OUT OF TUBING. POP WELL @ 40 BEANS. SIP=1100 PSIG. TIE-IN TO THE SBT DATED 6/15/95. 1115 HUNG CCL AT 11034'. SHOT GUN # 1 FROM 11036' - 11042'. NO INDICATIONS. LOG OFF. 1130 SI WELL AND POOH. 1 230 AT SURFACE. ALL SHOTS FIRED. RD ATLAS. 1 300 POP WELL WITH LIFTGAS. FWHP: 500 PSIG @ 104 BEANS lAP: 1600 OAP: 250 PERFORATION SUMMARY: Gun # length Interva S a n d 1 6' 11036-11042' 2 A 3-3/8" Alpha Jet HSC 6 SPF, 60-120° phasing, and random orientation Endicott Production Engineering Department PERFORATE DATE: 8 / 20 / 95 WELL N°: 1-31/M-21 BP EXPLORATION REP: POWERS SERVICE CO: ATLAS (BARBA) DATE/TIME OPERATIONS SUMMARY 9:00 MIRU. FWHP = 320 PSI; lAP = 1400 PSI; OAP = 0 PSI 9:55 RIH WITH PFC, GR, AND 6' GUN, 2.0' FROM CCLTO TOP SHOT. SI WELL 1 0:00 .POP WELL TO 80 BEANS. TAG BTM @ -11134'. TIE-IN TO GR/DIL DATED 8/8/95 (+12'). BLEED TBG DOWN TO 50 PSI. RIH. LOG CONFIRMATION PASS. 1 1:00 LOG INTO POSITION. CCL DEPTH IS 11108' (TS @ 11110' MD). SHOOT GUN #1 FROM 11110'-11116' MD BKB. GOOD INDICATION. LOG OFF. SI WELL AND POOH. 11:30 OOH. ALL SHOTS FIRED. RDMO ATLAS. POP WELL AT FOC WITH NO LIFT GAS. PERFORATION SUMMARY' GUN PERF INTERVAL FEET SUBZONE I 11110-11116' 6 2A THE INTERVALS WERE SHOT USING 3-3/8" ALPHA JET HSC GUNS AT 4 SPF, 60°/120© PHASING AND 0~ ORIENTATION. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE - ANCHORAGE AK, 99501. Date: 30 October 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 GR/CCL FINAL BL+RF .. 1 PLS FINAL BL+RF ECC No. Run ~ 1 5767.02 Run # 1 Run ~ 1 6446.07 Run ~ 1 6467.04 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 18 October 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PERF-FINAL BL+RF' Run ~ 1 1 GR/CCL FINAL BL+RF Run ~ 1 1 PFC/PERF FINAL BLeRF Run ~ 1 1-03/P-16 PH (MPI) 1 FMT/GR FINAL BL+RF Run ~ 1 ECC No. .. 5985.14- 6446.06 6502.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received b~//~ /~~~ ' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 October 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF 1PFC/PERF FINAL BL+RF 1 PFC~PERF FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 ECC No. .. 5958.02 6446.05 6483.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street .. Anchorage, AK 99518 .. ~ Or F~ to (907) 563-~'~ Received b~--~. / ~: ~~ gyro/data Cons, Cornmissio~ B.P. EXPLORATION MDi UNIT', WELL NO. 1-31/M-21 ENDICO~T~IELD, ALASKA Gyro Multis~h_j~~,r~ 4.~5;' tubing Survey date: 1~ 'Jur~e,~,!~95 Job number' AK0695G270 Date.~~'~ SR270.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 June 27, 1995 Ms. Terrie Hubble B.P. Exploration Prudhoe Bay Drilling Department 900 E. Benson Blvd. Anchorage, AK 99508 MB 12-1 Re.' MDI Unit, Well No. 1-31/M-21, Endicott Field, Alaska Dear Ms. Hubble, Enclosed please find one (1) original and three copies (3) of the completed survey of Well #1-31/M-21 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. ~~Robert I. ghoup Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER' AK0695G270 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR270.DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR270.DOC gyro/data DISCUSSION JOB NUMBER' AK0695G270 Tool 080 was run in 1-31/M-21 on ATLAS 15/32" Wireline inside 4.5" tubing. The survey was run without problems. SR270.DOC gywIdata SURVEY CERTIFICATION SHEET JOB NUMBER: AK0595G270 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the weilsite. Checked by :- TIM ANDERSON TOM STODDARD OPERATIONS ENGINEER Anchorage SR270.DOC gyro/data 2. SURVEY DETAILS SR270.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0695G270 CLIENT: B.P. EXPLORATION RIG: LOCATION: ATLAS MDI UNIT WELL: 1-31/M-21 LATITUDE: 70.353 N LONGITUDE: 147.5 W SURVEY DATE: '15-June, 1995 SURVEY TYPE: DEPTH REFERENCE: MAX. SURVEY DEPTH: MULTISHOT IN 4.5" tubing ROTARY TABLE EVELATION 55.85 asl, 14.5' G.L. 11150 SURVEY TIED ONTO: SURVEY INTERVAL: N/A oO, UTM CO-ORDINATES: TARGET DIRECTION: 96.64 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR270.DOC gyro/data 3. OUTRUN SURVEY LISTING SR270.DOC A Gyr oda t a D i r e c t i ona i Survey for Job Number: AK0695G270 B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Run Date: 15-Jun-95 08:53:47 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.353000 deg. N Sub-sea Correction from Vertical Reference: 55.85 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 96.640 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY'DIST. AZIMUTH feet deg./ feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -55.9 0.00 0.0 0.0 ALL MEASURED DEPTHS REFERENCED TO R.K.B. HEIGHT OF 55.85 FEET. 0.0 - 11150.0 FEET; GYRODATA SURVEY OF 4 1/2" TUBING. Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 ~ ) 100.0 .17 85.32 100.0 .1 44.1 .17 .1 85.3 200.0 .11 111.05 200.0 .4 144.1 .09 .4 91.4 300.0 .17 119.38 300.0 .6 244.1 .07 .6 101.0 400.0 1.04 106.63 400.0 1.6 344.1 .88 1.7 105.7 500.0 2.22 106.13 .500.0 4.5 444.1 1.18 4.5 106.1 600.0 3.33 101.14 599.8 9.3 544.0 1.14 9.4 104.6 700.0 4.51 99.37 699.6 16.1 643.7 1.19 16.2 102.7 800.0 4.55 97.56 799.3 24.0 743.4 .15 24.1 101.3 900.0 3.93 98.87 899.0 31.4 843.2 .63 31.5 100.6 1000.0 3.24 98.01 998.8 37.6 943.0 .69 37.7 100.2 1100.0 2.73 98.39 1098.7 42.8 1042.8 .51 42.9 100.0 1200.0 2.75 98.02 1198.6 47.6 1142.7 .03 47.7 99.8 1300.0 2.17 87.11 1298.5 51.9 1242.6 .74 51.9 99.3 1400.0 2.90 83.83 1398.4 56.2 1342.5 .74 56.2 98.2 1500.0 5.28 93.34 1498.1 63.3 1442.3 2.47 63.3 97.2 1600.0 7.18 98.11 1597.5 74.1 1541.7 1.97 74.1 97.1 1700.0 9.45 99.55 1696.5 88.5 1640.6 2.28 88.6 97.4 1800.0 11.65 98.12 1794.8 106.8 1738.9 2.21 106.9 97.6 1900.0 13.51 99.49 1892.4 128.6 1836.5 1.89 128.6 97.8 2000.0 16.04 99.72 1989.0 154.1 1933.2 2.53 154.1 98.1 .01 N .15 E .01 S .38 E .12 S .60 E .45 S 1.61 E 1.25 S 4.34 E 2.35 S 9.06 E 3.55 S 15.79 E 4.71 S 23.60 E 5.76 S 30.92 E 6.69 S 37.11 E 7.43 S 42.26 8.11 S 46.98 E 8.35 S 51.24 E 7.98 S 55.64 E 7.98 S 62.75 E 9.13 S 73.53 E 11.37 S 87.82 E 14.16 S 105.92 E 17.51 S 127.43 E 21.77 S 152.57 E A G y r o d a t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job NUmber: AK0695G270 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 16.99 101.42 2084 2200.0 17.08 101.70 2180 2300.0 17.05 101.34 2276 2400.0 17.02 100.30 2371 2500.0 17.24 97.67 2467 .9 .5 .1 .7 .3 182 211 240 270 299 .4 .6 .8 .1 .5 2029.1 2124.7 2220.3 2315.9 2411.5 1.06 182.5 98.5 .13 211.8 98.9 .11 241.1 99.2 .31 270.4 99.4 .81 299.8 99.4 26.99 S 180.51~ ~ 32.86 S 209 21 .~ 38.73 S 237.96 ~ 44.23 S 266.74 E 48.82 S 295.82 E 2600.0 17.67 95.45 2562 2700.0 17.88 96.13 2657 2800.0 17.93 96.63 2753 2900.0 17.25 97.32 2848 3000.0 17.04 95.63 2944 .7 .9 .1 .4 .0 329 360 390 421 450 .5 .0 .7 .0 .4 2506.9 2602.1 2697.2 2792.6 2888.1 .79 329.8 99.1 .30 360.3 98.8 .16 391.0 98.6 .72 421.2 98.5 .54 450.7 98.4 52.24 S 325.62 E 55.32 S 355.99 E 58.74 S 386.55 E 62.41 S 416.55 E 65.73 S 445.83 E 3100.0 17.10 95.05 3039. 3200.0 17.05 96.08 3135. 3300.0 17.13 96.74 3230. 3400.0 17.07 95.92 3326. 3500.0 16.85 94.53 3422. 3600.0 16.61 93.60 3517. 3700.0 16.39 93.71 3613. 3800.0 16.03 93.85 3709. 3900.0 16.50 94.48 3805. 4000.0 17.99 99.83 3901. 479.8 509.2 538.5 567.9 597.1 625.9 654.2 682.1 710.1 739.7 2983.7 3079.3 3174.9 3270.5 3366.1 3461.9 3557.8 3653.8 3749.8 3845.3 .18 480.0 98.2 .31 509.3 98.0 .21 538.7 98.0 · 25 568.1 97.9 .47 597.2 97.7 .36 625.9 97.6 .22 654.3 97.4 .36 682.1 97.3 .50 710.1 97.1 2.17 739.7 97.1 68.46 S 475.07 E 71.31 S 504.29 E 74.59 S 533.49 E 77.83 S 562.72 E 80.49 S 591.77 E 82.53 S 620.48 ~" 84.34 S 648.82 E 86.18 S 676.68 E 88.21 S 704.61 E 91.96 S 733.99 E 4100.0 18.31 102.81 3996. 4200.0 17.70 103.54 4091. 4300.0 17.08 101.86 4186. 4400.0 16.98 99.29 4282. 4500.0 17.31 99.58 4377. 770.7 801.4 831.2 860.4 889.8 3940.3 4035.4 4130.9 4226.5 4322.0 .98 770.8 97.3 .65 801.5 97.5 .80 831.3 97.7 .76 860.6 97.8 .34 890.0 97.9 98.08 S 764.52 E 105.12 S 794.62 E 111.70 S 823.77 E 117.07 S 852.55 E 121.90 S 881.63 E A Gyro da t a D i r e c t i ona I Survey B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 17.65 98.77 4473.3 4700.0 17.76 96.72 4568.5 4800.0 17.57 95.21 4663.8 4900.0 17.37 94.46 4759.2 5000.0 17.13 95.19 4854.7 919.8 950.2 980.6 1010.6 1040.2 4417.4 4512.7 4608.0 4703.3 4798.8 .42 920.0 97.9 .63 950.5 97.9 .50 980.8 97.8 .30 1010.8 97.8 .32 1040.4 97.7 126.69 S 911.28 130.79 S 941.42 133.95 S 971.60 136.48 S 1001.51 138.97 S 1031.06 5100 . 0 17 . 01 94 . 14 4950 . 3 5200.0 17.32 93.50 5045.8 5300 . 0 17 . 21 92 . 70 5141 . 3 5400.0 17.28 92.49 5236.8 5500.0 17.20 92.94 5332.3 1069.5 1099.0 1128.6 1158.2 1187.8 4894.4 4990.0 5085.5 5181.0 5276.5 .33 1069.7 97.6 .36 1099.1 97.5 .26 1128.7 97.4 .09 1158.3 97.3 .15 1187.8 97.1 141.36 S 143.32 S 144.92 S 146.27 S 147.67 S 1060.31 E 1089.75 E 1119.39 E 1149.00 E 1178.61 E 5600.0 17.20 93.40 5427.9 5700.0 17.07 92.54 5523.4 5800.0 17.20 91.88 5619.0 5900.0 17.17 91.80 5714.5 6000.0 17.17 94.08 5810.1 6100.0 17.48 95.34 5905.5 6200.0 17.45 94.61 6000.9 6300.0 17.59 94.54 6096.3 6400.0 17.42 94.37 6191.7 6500.0 17.26 94.54 6287.1 1217.3 1246.7 1276.1 1305.5 1335.0 1364.7 1394.7 1424.8 1454.9 1484.6 5372.0 5467.6 5563.1 5658.7 5754.2 .14 1217.3 97.0 .29 1246.7 96.9 .23 1276.1 96.8 .04 1305.5 96.7 .67 1335.0 96.6 5849.7 .49 1364.7 96.6 5945.1 .22 1394.7 96.6 6040.4 .14 1424.8 96.5 6135.8 .18 1454.9 96.5 6231.3 .16 1484.7 96.4 149.31 S 150.83 S 151.97 S 152.92 S 154.43 S 156.88 S 159.48 S 161.89 S 164.22 S 166.54 S 1208.14 E 1237.57 E 1267.00 E 1296.53 E 1326.00 E 1355.67 1385.58 E 1415.58 E 1445.57 E 1475.28 E 6600.0 17.48 94.71 6382.6 6700.0 17.63 94.62 6477.9 6800.0 18.00 93.79 6573.1 6900.0 19.87 94.92 6667.7 7000.0 22.32 95.93 6761.0 1514.5 1544.6 1575.2 1607.6 1643.6 6326.7 .22 1514.5 96.4 6422.0 .15 1544.6 96.4 6517.3 .45 1575.2 96.3 6611.8 1.90 1607.6 96.3 6705.1 2.47 1643.6 96.3 168.95 S 171.40 S 173.64 S 176.12 S 179.53 S 1505.04 E 1535.10 E 1565.61 E 1597..97 E 1633.79 E A Gyro d a t a D i r e c t i o n a i Survey - B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7100.0 24.55 96.74 6852.7 7200.0 26.63 97.97 6942.9 7300.0 28.56 98.78 7031.5 7400.0 30.78 99.23 7118.4 7500.0 33.03 98.71 7203.3 1683 1726 1772 1822 1875 .4 .5 .8 .3 .1 6796.9 2.26 1683.4 96.3 6887.1 2.15 1726.6 96.3 6975.7 1.96 1772.9 96.4 7062.6 2.23 1822.3 96.4 7147.5 2.27 1875.1 96.5 183.93 S 1673.31 189.48 S 1716 1[ 196.24 S 1761.97 203.99 S 1810.85 212.23 S 1863.05 7600.0 33.77 98.61 7286.8 7700.0 33.33 98.21 7370.1 7800.0 33.96 97.04 7453.4 7900.0 33.83 97.25 7536.4 8000.0 34.46 94.89 7619.2 1930 1985 2040 2096 2152 .1 .3 .7 .5 .6 7230 . 9 . 74 1930 . 1 96 . 6 7314.3 .49 1985.3 96.6 7397 . 5 . 91 2040 . 7 96 . 6 7480 . 5 . 18 2096 . 5 96 . 7 7563.3 1.47 2152.6 96.6 220.52 S 1917.47 E 228.60 S 1972.13 E 235.94 S 2027.05 E 242.88 S 2082.38 E 248.80 S 2138.18 E 8100.0 34.48 94.68 7701.6 8200.0 34.47 94.74 7784.0 8300.0 34.28 94.23 7866.6 8400.0 34.22 94.29 7949.2 8500.0 34.31 93.99 8031.9 8600.0 34.47 94.13 8114.4 8700.0 34.31 94.17 8196.9 8800.0 34.56 94.25 8279.4 8900.0 34.39 94.93 8361.8 9000.0 34.17 94.72 8444.5 2209 2265 2322 2378 2434 2491 2547 2604 2660 2716 .2 .8 .2 .4 .6 .1 .5 .0 .6 .9 7645.8 .12 2209.2 96.6 7728.2 .04 2265.8 96.5 7810.7 .34 2322.2 96.5 7893.4 .07 2378.4 96.4 7976.0 .19 2434.7 96.4 8058.6 .18 2491.1 96.3 8141.1 .16 2547.5 96.3 8223.6 .26 2604.1 96.2 8306.0 .43 2660.6 96.2 8388.6 .25 2716.9 96.2 253.52 S 2194.58 E 258.17 S 2251.00 E 262.58 S 2307.28 E 266,76 S 2363.41 E 270.83 S 2419.56 E 274.83 S 2475.90 _' 278.91 S 2532.23 E 283.06 S 2588.63 E 287.59 S 2645.05 E 292.33 S 2701.17 E 9100.0 34.00 94.14 8527.3 2772.9 9200.0 33.71 93.99 8610.3 2828.5 9300.0 33.59 93.61 8693.6 2883.8 9400.0 33.46 93.15 8777.0 2939.0 9500.0 33.84 93.61 8860.2 2994.3 8471.4 .37 2773.0 96.1 8554.5 .30 2828.6 96.1 8637.7 .24 2884.0 96.1 8721.1 .29 2939.2 96.0 8804.3 .47 2994.5 96.0 296.66 S 300.61 S 304.28 S 307.54 S 310.81 S 2757.05 E 2812.61 E 2867.90 E 2923.03 E 2978.34 E A Gyr oda t a D i re c t i ona i Survey B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. 9600.0 34.58 95.08 8942.9 9700.0 33.72 96.67 9025.6 9800.0 33.17 97.97 9109.1 9900.0 33.66 98.98 9192.6 10000.0 33.57 100.13 9275.8 3050.5 8887.0 3106.6 8969.8 3161.7 9053.2 3216.8 9136.7 3272.0 9220.0 1.11 3050.7 95.9 1.24 3106.9 95.9 .90 3161.9 96.0 .75 3217.0 96.0 .64 3272.2 96.1 10100.0 33.77 99.14 9359.1 10200.0 33.18 99.75 9442.5 10300.0 34.04 99.56 9525.8 10400.0 35.27 99.78 9608.0 10500.0 35.21 101.38 9689.7 3327.4 9303.2 3382.5 9386.6 3437.8 9469.9 3494.6 9552.2 3552.1 9633.8 .58 3327.5 96.1 .67 3382.6 96.2 .86 3437.9 96.2 1.24 3494.6 96.3 .92 3552.2 96.4 10600.0 35.55 101.70 9771.2 10700.0 36.33 101.26 9852.2 10800.0 37.03 101.29 9932.4 10900.0 37.47 101.37 10012.0 11000.0 37.13 101.21 10091.5 3609.8 9715.4 3668.3 9796.3 3727.8 9876.5 3788.2 9956.1 3848.6 10035.7 .38 3609.8 96.4 .82 3668.3 96.5 .70 3727.8 96.6 .45 3788.2 96.7 .36 3848.6 96.7 -11100.0 36.80 100.89 10171.4 ~11150 0 36.41 100.88 10211.6 3908.5 10115.6 3938.2 10155.7 .38 3908.5 96.8 .79 3938.3 96.8 Final Station Closure: Distance: 3938.27 ft Az: 96.84 deg. Page HORIZONTAL COORDINATES feet 315.08 S 3034.40 E 320.81 S 3090.2~ ) 327.82 S 3144.91 E 335.94 S 3199.37 E 345.14 S 3253.96 E 354.41 S 3308.62 E 363.46 S 3363.03 E 372.74 S 3417.60 E 382.30 S 3473.65 E 392.89 S 3530.37 E 404.47 S 3587.10 E 416.15 S 3644.62 E 427.83 S 3703.20 E 439.73 S 3762.55 E 451.59 S 3821.98 E ~-.463.12 S 3881.00 468.75 S 673910.27 E A Gyroda t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270SS Run Date: 15-Jun-95 08:53:47 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.353000 deg. N Sub-sea Correction from Vertical Reference: 55.85 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 96.000 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference Anchorage, A Gyro da t a D i re c t i ona i SUrvey B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270SS SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. -55.9 0.00 0.00 0.0 0.0 0.00 ALL MEASURED DEPTHS REFERENCED TO R.K.B. HEIGHT OF 55.85 0.0 - 11150.0 FEET; GYRODATA SURVEY OF 4 1/2" TUBING. CLOSURE DIST. AZIMUTH feet deg. 0.0 0.0 FEET. Page HORIZONTAL COORDINATES feet 0.00N 0.00E 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 100.0 .13 98.91 155.9 .3 .12 200.0 .14 115.15 255.9 .5 .08 300.0 .65 112.22 355.9 1.2 .52 400.0 1.69 106.17 455.9 3.2 .1.04 500.0 2.83 102.95 555.9 7.1 1.15 00.0 3.98 99.75 655.9 13.0 1.16 00.0 4.51 97.94 755.9 20.4 .60 00.0 4.18 97.96 855.9 28.0 .42 00.0 3.52 98.03 955.9 34.8 .66 00.0 2.93 97.84 1055.9 40.4 .59 00.0 2.72 97.92 1155.9 45.3 .23 00.0 2.40 91.50 1255.9 49.8 .44 00.0 2.57 84.86 1355.9 54.1 .74 00.0 4.25 88.89 1455.9 60.0 1.73 00.0 6.36 95.66 1555.9 69.2 2.17 00.0 8.48 98.48 1655.9 82.2 2.14 00.0 10.73 98.20 1755.9 99.1 2.23 00.0 12.75 98.45 1855.9 119.9 2.00 00.0 15.09 99.06 1955.9 144.6 2.29 00.0 16.61 100.31 2055.9 172.9 1.50 .4 88.1 .6 96.1 1.7 103.2 4.5 105.7 9.3 104.9 16.1 103.2 24.0 101.5 31.3 100.5 37.5 100.0 42.7 99.7 47.4 99.5 51.7 99.1 55.9 98.3 63.0 97.3 73.7 96.8 88.1 96.9 106.4 97.1 128.0 97.3 153.4 97.6 181.7 97.9 .01 S .28 E .O6 S .51 E .29 S 1.16 E .88 S 3.12 E 1.82 S 6.95 E 2.93 S 12.79 E 4.06 S 20.13 E 5.11 S 27.65 E 6.04 S 34.32 E 6.82 S 39.90 E 7.50 S 44.79 E 7.91 S 49.24 E 7.77 S 53.56 E 7.57 S 59.50 E 8.17 S 68.74 E 9.86 S 81.63 E 12.31 S 98.37 E 15.31 S 118.92 E 19.10 S 143.39 E 23.89 S 171.39 E A Gyro da t a D i r e c t i ona I Survey B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 16.97 101.06 2155.9' 2200.0 16.97 100.85 2255.9 2300.0 16.94 99.89 2355.9 2400.0 17.13 97.40 2455.9 2500.0 17.55 95.03 2555.9 203 233 263 294 325 .0 .4 .8 .4 .6 .38 210.8 98.3 .12 240.0 98.7 .27 269.1 98.9 .74 298.4 98.9 .79 328.2 98.6 29.49 S 201.05 E · 35.30 S 231.02 ~ ) 40.80 S 261.01 E ' 45.42 S 291.28 E 48.81 S 322.30 E 2600.0 17.79 95.49 2655.9 2700.0 17.83 96.04 2755.9 2800.0 17.15 96.64 2855.9 2900.0 16.97 94.96 2955.9 3000.0 17.01 94.62 3055.9 357 389 421 451 482 .5 .6 .1 .8 .3 .30 358.6 98.3 .18 419.'2 98.1 .71 448.5 98.0 .50 477.7 97.8 .20 506.9 97.6 51.72 S 354.01 E 54.94 S 385.98 E 58.43 S 417.26 E 61.51 S 447.77 E 64.06 S 478.22 E 3100.0 16.98 95.65 3155.9 3200.0 17.04 95.94 3255.9 3300.0 16.92 94.91 3355.9 3400.0 16.68 93.63 3455.9 3500.0 16.44 93.09 3555.9 3600.0 16.15 93.21 3655.9 3700.0 16.17 93.56 3755.9 3800.0 17.19 96.64 3855.9 3900.0 18.08 100.93 3955.9 4000.0 17.85 102.71 4055.9 512 543 574 604 633 663 692 721 753 785 .9 .4 .0 .2 .9 .1 .0 .9 .6 .9 .29 536.1 97.5 .22 565.4 97.4 .31 594.4 97.3 .42 623.0 97.1 .30 651.2 97.0 .28 678.9 96.8 .43 706.7 96.6 1.36 736.2 96.6 1.50 767.1 96.7 .78 797.7 96.9 66.80 S 508.66 E 69.90 S 539.10 E 72.79 S 569.49 E 75.03 S 599.60 E 76.77 S 629.29 E 78.38 S 658.48 E 80.09 S 687.40 E 82.78 S 717.20 E 87.70 S 748.58 E 94.35 S 780.33 E 4100.0 17.20 101.88 4155.9 4200.0 16.93 99.48 4255.9 4300.0 17.14 98.94 4355.9 4400.0 17.50 98.35 4455.9 4500.0 17.66 96.46 4555.9 817 847 878 909 941 .3 .9 .5 .6 .3 .75 827.4 97.1 .77 856.5 97.2 .44 885.8 97.3 .40 915.7 97.3 .59 946.0 97.4 101.10 S 811.19 E 106.81 S 841.33 E 111.70 S 871.56 E 116.39 S 902.39 E 120.49 S 933.80 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. H 0 R I Z O N T A L COORDINATES feet 4600.0 17.51 94.79 4655.9 4700.0 17.29 93.93 4755.9 4800.0 17.05 94.62 4855.9 4900.0 16.94 93.57 4955.9 5000.0 17.22 92.85 5055.9 973.0 1004.3 1035.2 1065.7 1096.4 .51 .31 .32 .32 .36 976.2 97.3 1006.0 97.2 1035.5 97.1 1093.9 97.0 1123.4 96.9 123.62 S 965.34 E 126.01 S 996.59 F '~- 128.30 S 1027.41 E .~ 130.47 S 1057.89 E 132.19 S 1088.58 E 5100.0 17.14 92.12 5155.9 5200.0 17.18 92.01 5255.9 5300.0 17.12 92.49 5355.9 5400.0 17.08 92.61 5455.9 5500.0 17.03 91.80 5555.9 1127.3 1158.1 1188.9 1219.6 1250.2 .23 .10 .15 .17 .26 1152.8 96.8 1182.2 96.7 1211.6 96.6 1240.8 96.5 1270.1 96.4 133.52 S 1119.47 E 134.63 S 1150.33 E 135.84 S 1181.16 E 137.22 S 1211.90 E 138.40 S 1242.56 E 5600.0 17.10 91.30 5655.9 5700.0 17.08 92.19 5755.9 5800.0 17.23 94.11 5855.9 5900.0 17.38 94.42 5955.9 6000.0 17.44 94.02 6055.9 6100.0 17.40 93.89 6155.9 6200.0 17.23 93.94 6255.9 6300.0 17.33 94.12 6355.9 6400.0 17.50 94.10 6455.9 6500.0 17.84 93.40 6555.9 1280.8 1311.5 1342.3 1373.5 1404.8 1436.2 1467.3 1498.4 1529.8 1561.6 .16 .30 .59 .36 .18 .17 .17 .20 .17 .39 1299.4 96.2 1328.7 96.1 1358.3 96.1 1388.2 96.0 1418.1 96.0 1448.0 95.9 1477.7 95.9 1507.4 95.9 1537.4 95.8 .1567.8 95.8 139.22 S 140.15 S 141.86 S 144.19 S 146.49 S 148.66 S 150.79 S 152.97 S 155.22 S 157.31 S 1273.25 E 1303.98 E 1334.79 E 1365.87 E 1397.14 E 1428.46 E 1459.57 E 1490.59 E 1521.88 E 1553.66 E 6600.0 19.50 94.18 6655.9 6700.0 22.01 95.25 6755.9 6800.0 24.45 96.08 6855.9 6900.0 26.72 97.40 6955.9 7000.0 28.96 98.18 7055.9 1595.3 1633.0 1675.8 1723.9 1776.8 1.68 2.41 2.24 2.11 2.02 1600.1 95.7 1635.9 95.7 1718.5 95.7 1764.5 95.7 1813.8 95.8 159.54 162.65 166.88 172.59 179.82 1587.30 E 1624.94 E 1667.52 E 1715.25 E 1767.72 E A Gyrodata B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270SS Dire c It i o n a 1 Survey Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG S EVE R I TY deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. H O R I Z O N T A L COORDINATES feet 7100.0 31.53 98.25 7155.9 7200.0 33.29 97.88 7255.9 7300.0 33.24 97.53 7355.9 7400.0 33.78 96.29 7455.9 7500.0 33.77 96.03 7555.9 1835.2 1898.8 1964.6 2030.6 2097.4 2.23 1.35 .54 .89 .42 1866.3 95.9 1921.1 96.0 1976.1 96.0 2031.2 96.0 2142.6 96.1 188.21 S 1825.55 E ~k 197.11 S 1888.59 t ? 205.95 S 1953.73 E 214.00 S 2019.30 E 221.23 S 2085.72 E 7600.0 34.29 94.04 7655.9 7700.0 34.29 93.96 7755.9 7800.0 34.13 93.58 7855.9 7900.0 34.04 93.51 7955.9 8000.0 34.16 93.28 8055.9 2165.0 2233.2 2301.1 2368.8 2436.4 .93 .08 .29 .06 .18 2198.9 96.0 2255.2 96.0 2311.3 95.9 2423.3 95.8 2479.5 95.8 226.96 S 231.70 S 236.22 S 240.40 S 244.38 S 2153.10 E 2221.12 E 2289.00 E 2356.54 E 2424.15 E 8100.0 34.22 93.43 8155.9 8200.0 34.29 93.47 8255.9 8300.0 34.23 94.10 8355.9 8400.0 33.98 93.97 8455.9 8500.0 33.74 93.46 8555.9 8600.0 33.47 93.18 8655.9 8700.0 33.32 92.64 8755.9 8800.0 33.62 92.88 8855.9 8900.0 34.34 94.57 8955.9 9000.0 33.39 96.45 9055.9 2504.3 2572.3 2640.4 2708.1 2775.1 2841.5 2907.3 2973.2 3040.6 3107.5 .17 .22 .41 .25 .33 .28 .28 .44 1.13 1.15 2535.6 95.7 2591.9 95.6 2648.2 95.6 2760.0 95.5 2815.4 95.5 2870.5 95.4 2925.4 95.4 2980.5 95.3 3092.3 95.3 3147.2 95.3 248.37 S 252.47 S 256.90 S 261.68 S 265.98 S 269.85 S 273.20 S 276.33 S 280.67 S 287.20 S 2492.00 E 2559.92 E 2627.95 E 2695.51 E 2762.45 E 2828.76 E 2894.62 E 2960.58 E 3027.81 E 3094.44 E 9100.0 33.23 97.88 9155.9 9200.0 33.42 99.20 9255.9 9300.0 33.57 98.72 9355.9 9400.0 33.07 99.21 9455.9 9500.0 34.19 99.10 9555.9 3173.1 3238.8 3304.9 3370.5 3437.0 .83 .68 .59 .69 .96 3201.9 95.3 3256.9 95.4 3312.0 95.5 3421.8 95.5 3478.3 95.6 295.42 S 305.17 S 315.59 S 325.81 S 336.39 S 3159.50 E 3224.59 E 3289.89 E 3354.85 E 3420.62 E A Gyroda t a D i r e c't i ona 1 Survey B.P. EXPLORATION WELL: 1-31 / M-21, 4 1/2" TUBING Location: MDI UNIT, ENDICOTT, ALASKA Job Number: AK0695G270SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 9600.0 35.06 100.03 9655.9 9700.0 35.26 101.07 9755.9 9800.0 36.09 100.75 9855.9 9900.0 36.91 100.74 9955.9 10000.0 37.12 100.74 10055.9 3506.2 1.08 3576.3 .53 3647.'7 .79 3721.5 .65 3796.8 .41 3535.6 95.7 3592.9 95.8 3651.1 95.9 3770.4 96.0 3830.6 96.1 347.83 S 360.78 S 374.39 S 388.20 S 402.31 S 3488.93 E 3558.09 [' 3628.43 E 3701.21 E 3775.43 E 10100.0 36.70 100.48 10155.9 10165.1 36.21 100.37 10221.0 3871.7 .36 3919.8 .78 3890.2 96.2 3919.8 96.2 416.15 S 424.90 S 3849.27 E 3896.73 E Final Station Closure: Distance: 3919.83 ft Az: 96.22 deg. gyro/data 4. QUALITY CONTROL SR270.DOC gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0695G270 TOOL NUMBER: 080 MAXIMUM GYRO TEMPERATURE: 83.1c MAXIMUM AMBIENT TEMPERATURE: 102.5 c MAXIMUM INCLINATION: 34.28 AVERAGE AZIMUTH: 95.0 WIRELINE REZERO VALUE: -6.0 add 6.0' REZERO ERROR/K: n/a CALIBRATION USED FOR FIELD SURVEY: 12 MAY 1995 CALIBRATION USED FOR FINAL SURVEY: 23 JUNE 1995 .PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK] · CONDITION OF SHOCK WATCHES -0.39 -.00 -0.40 USED -0.0 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEZ: UPON RETURN TO ATLAS OK OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 11150 36.21 100.41 10221.0 424.90 S 3896.70 E FINAL SURVEY 11150 36.41 100.88 10211.6 468.75 S 3910.27 E SR270.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0695G270 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. fl I 2 3 4 5 11150 36.21 36.21 36.21 AZIMUTH M.D. ft I 2 3 4 5 11150 100.41 100.39 100.37 SR270.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR270.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0695G270 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0094 DATA SECTION A0025 POWER SECTION A0052 BACKUP TOOL No. 136 GYRO SECTION A0099 DATA SECTION A0029 POWER SECTION A0027 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0055 A0079 A0035 A0122 A0032 A0029 A0035 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 15/32 RUNNING GEAR 2 1/2" System w/3" heat shield and eccentric bar, and 3.6" wear bushings. TOTAL LENGTH OF TOOL: MAXIMUM O.D.: 25.5 FEET 3.6 INCHES TOTAL WEIGHT OF TOOL: 250 POUNDS SR270.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0695G270 6/14/95 1800 2200 6/15/95 0715 0830 0925 1115 1345 1450 1530 1730 1800 ATLAS, CHECK TOOLS O.K. UNLOAD TOOLS, RELOAD TOOLS, CHECK GYROS STAND BY LEAVE FOR MDI UNIT. ARRIVE LOCATION, MU TOOL PU TOOL, ZERO. MU LUBRICATOR RIH. 11150' 5500'. LD TOOL. RD ATLAS AND BD TOOL, PROCESS SURVEY. RTN ATLAS CHECK TOOL O.K. TO AIRPORT W/EQUIPMENT FOR JOB AT MILNE POINT. SR270.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS I-I; SUSPENDED [] ABANDONED [] SERVICE [] REVISED: 11/10/95 2. Name of Operator ~~I 7. Permit Number BP Exploration ~ 95-072 3. Address ~.~~ ~,. APl Number P. O. Box 196612, Anchora~te, Alaska 99519-6612 50- 029-22562 i4. Location of well at surface ~¢, ?~.~~r 9. Unit or Lease Name 3225' NSL, 2109' WEL, SEC. 36, T12N, R16E~'~?~ ~~ Duck Island Unit/Endicott At Top Producing Interval ~'~ ..................... r,r-~,-,i ~-~, ,~;~,,: -~.. 10. Well Number ~ ,,~r-,,~-, ,~,,,~:¢. ?.. 1-31/M-21 2835' NSL, 3465' WEL, SEC. 31, T12N, R17E 11. Field and Pool At Total Depth"~ ~-~'~-~--~ ~,' Endicott Field/Endicott Pool 2739' NSL, 2983' WEL, SEC. 31, T12N, R17E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.~~--'~ BKB = 56 ADL 312828 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.,__ /- -- ,~Susp-' or Aband. ,,,~ J15. Water Depth, if offshore 16. No. of Completions 05/22./95 06/07/95 ~ ~',,/~,~,/¢¢;~'/[?'~ 6'-12' feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional S~rv~y/ ' 120. Depth where SSSV set 21. Thickness of Permafrost 11300'MD/10331'TVD 11181'MD/10236 TVD YES [] NO []I 1503 feet MD 1466' 22. Type Electric or Other Logs Run Gyro, MWD, CHT, GR, CN, CDL, DIFL 23. CASING, LINER AND CEMENTING RECORD SE--I-RNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Structure Drive Surface 110' 30" Drive 10-3/4" 45.5# NT8OLHE 42' 4455' 13-1/2" 716 sx 'E', 461 sx 'G' 7-5/8" 29. 7# NT8OLHE 40' 11265' 9-7/8" 723 sx Class 'G' ,. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET/MD) PACKER SET (MD) Gun Diameter 3-3/8" 4 spf 4-1/2", 13CR80 9614' 9524' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11037' - 11060' 10121'- 10139' Freeze Protected 60 bbls Diesel 11105'- 11115' 10175'- 10183' 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 16, 1995 I Flowing -- - Date of Test Hours Tested 3RODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OIL RATIO FEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. l~t~,~it in duplicate % Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. ' GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. HRZ 10100' 9359' Kekiktuk 10472' 9667' K2A 10859' 9979' ._ 31. LIST OF A'I-FACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~~~ ~'~~/~Jc.'-'~' Title Senior Dril/in.cj En,qineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). / Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 _ /AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPI 1-31/M-21 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 05/21/95 02:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 05/22/95 ( 1) TD: 0'( 0) 05/23/95 (2) TD: 4000' (4000) 05/24/95 ( 3) TD: 4465' ( 465) 05/25/95 ( 4) TD: 4465' ( 0) 05/27/95 (5) TD: 5475' (1010) PU BHA T/SPUD MW: 0.0 VIS: 0 MOVE RIG F/SDI T/MPI 1-31. RU ON WELL. TAKE ON WATER, MIX SPUD MUD, RU DIVERTER, RU ROCKWASHER, RU BAGGING UNIT. MIX SPUD MUD, RU INJECTION LINE, PU BHA. DRILLING MW: 0.0 VIS: 0 DRILL & SURVEY F/1650 T/2136. CBU. SHORT TRIP. DRILL T/3191. CBU. SHORT TRIP. DRILL T/4000. RIH W/10-3/4" CASING MW: 0.0 VIS: 0 DRILL & SURVEY T/TD 8 4465 MD. CBU. SHORT TRIP T/3030. CIRC HI VIS SWEEP. POOH. WORK OUT TIGHT SPOT 8 3010. LD BHA. CLEAR FLOOR RU & RIH W/10-3/4" CASING. RIH W/9-7/8" BHA MW: 0.0 VIS: 0 RIH W/10-3/4" CASG. LAND SHOE 84455. CIRC HOLE CLEAN. RU HALLIBURTON. PUMP 10 BBLS WATER, TEST T/3000. PUMP 90 BBLS H20. MIX & PUMP 276 BBLS PF LEAD CMT 8 500PSI/6 BPM, DROP BTTM PLUG. PUMP 94 BBLS 15.8 PPG TAIL CMT. 8 500 PSI/6 BPM. DROP PLUG, 5 BBLS OF WATER. DISPLACE W/RIG PUMP 8 14 BPM 1800 PSI. BUMP PLUG T/2000PSI. 25 BBLS OF CMT BACK TO SURF. FLTS HELD. NO TOP JOB NEEDED. CIP 8 11:23 HRS. LD LNDG JT. CLEAR FLOOR, LD CASG RUNNING TOOLS. ND RISER, DIVERTER, NU STARTING HEAD, SAFETY BOSS SPOOL. NU BOPE. TEST BOP T/5000. INSTALL WEAR RING. SERVICE TOP DRIVE.PU BHA, TEST MWD. PU DP W/NON-ROTATING RUBBER, RIH. DRILLING MW: 0.0 VIS: 0 SERVICE TOP DRIVE. RIH PU 30 JTS DRILL PIPE W/ NON-ROTATING RUBBERS. DRILL OUT FLOAT COLLAR AND 50' OF CEMENT. POH TO RECOVER DRILL PIPE SCREEN, RIH. DRILL OUT CEMENT AND FLOAT SHOE + 10' OF NEW HOLE TO 4475'. CIRCULATE. PERFORM LEAK OFF TEST. DRILL AND SURVEY TO 5389' MONITOR WELL FOR FLUID LOSS. CIRCULATE AND CONDITION MUD W/ LIQUID CSG. DRILL F/ 5389 - 5475' WELL : MPI 1-31 OPERATION: RIG : DOYON 15 PAGE: 2 05/28/95 (6) TD: 6066' ( 591) 05/29/95 ( 7) TD: 6880' ( 814) 05/30/95 (8) TD: 7690' ( 810) 05/31/95 ( 9) TD: 8150' ( 460) 06/01/95 (10) TD: 9363'(1213) 06/02/95 ( 11], TD: 951-5' ( 15-~-) : 06/03/95 (12) TD: 10157' ( 642) 06/04/95 (13) TD: 10432' ( 275) RIH W/ NEW MWD MW: 0.0 VIS: 0 CBU. OBSERVE WELL. POH TO SHOE TO 4465' LEAK OFF TEST. POH TO 2917'. PU 10 STANDS DP W/O NRDPR RIH TO 5475'. DRILL F/ 5475 - 6066' CIRC OBSERVE, PUMP DRY JOB. POH TO CHANGE OUT MWD/NEW BIT. SERVICE RIG. RIH TO 1200' CUT DRILL LINE. RIH PU 36 JTS W/ NRDPR W/ NB #3/ NEW MWD. DRILLING MW: 0.0 VIS: 0 CIRCULATE AND CONDITION DRILLING MUD. DRILL F/ 6066- 6107'_ NEW MWD NOT WORKING. TROUBLE SHOOT MWD SURFACE EQuIpMENT. POH TO 5865' TEST MIND = TOOL FAILURE. POH CHANGE OUT MWD AND ORIENT. RIH TO 1100'. TEST MWD. SERVICE TOP DRIVE AND PUMP STROKE COUNTER. RIH CHECK MWD SURVEYS. DRILL AND SURVEY TO 6880'. DRILLING MW: 0.0 VIS: 0 DRILL AND SURVEY W/ MWD. CIRC HI VIS SWEEP. SHORT TRIP TO 7450 - 4204' DRILL TO 7499' SERVICE RIG. DRILL AND SURVEY TO 76~0' DRILLING MW: 0.0 VIS: 0 DRILL & SURVEY T/7760. CBU. OBSERVE WELL. POOH LD MOTOR & BIT. PU PDC BIT & NEW MTR. RIH --TAKE BENCHMARK SURVEY @5132. RIH REAM F/7640 T/7760. DRILL T/8150. BIT TRIP MW: 0.0 VIS: 0 DRILL AND SURVEY FROM 8150 - 8710'. CIRCULATE SWEEPS AROUND. SHORT TRIP 10 STANDS TO 7726' NO PROBLEMS. DRILL FROM 8710 - 8817' CHANGE LINER AND SWAB IN %1 MUD PUMP. DRILL FROM 8817 - 9363' CIRCULATE SWEEP AROUND. OBSERVE WELL. TRIP OUT OF HOLE FOR BIT. DRILLING MW: 0.0 VIS: 0 TRIP OUT OF HOLE FOR BIT AND BHA. NO PROBLEMS. TRIP OUT OF HOLE WITH BHA. LAY DOWN BIT, MOTOR AND BUMPER SUB. BOPE TEST. MAKE UP BHA %6. ORIENT AND TEST MWD AND MOTOR. SLIP AND CUT 60' DRILLING LINE. TRIP IN HOLE. PICKED UP 36 JTS 5" DP. FILL PIPE @ 4400'. BENCHMARK SURVEY @ 5105' NO PROBLEMS. DRILL FROM 9363 - 9515' DRILLING MW: 0.0 VIS: 0 DRILL & SURVEY F/9515 T/10157. CBU. OBSERVE THE WELL. TOOH F/BIT CHANGE. DRILLING MW: 0.0 ViS: 0 TOOH F/NEW BIT. STAND BACK BHA. LD MM. MU NEW MOTOR & BIT. TIH. SETV. TOP DRIVE. TAKE BENCHMARK SURVEY @5103. FILLED DP @ 4200 & 7100. DRILL & SURVEY F/10157 T/10432. .ELL ' MPI 1-31 OPERATION: RIG ' DOYON 15 PAGE: 3 06/05/95 (14) TD:10710' ( 278) 06/06/95 (15) TD:10904' ( 194) 06/07/95 (16) TD:l1073' ( 169) 06/08/95 (17) TD:ll300' ( 227) 06/08/95 (18) TD: 11300' ( 0) 06/09/95 (19) TD:ll300' ( 0) 06/10/95 (20) TD:ll300~_(_ . o) TIH W/NEW BIT MW: 0.0 VIS: 0 DRILL T/10450. CBU. RAISE THE MUD WT T/10.5 PPG. IN CASE OF ABNORMAL PRESS IN ZONE-3. DRILL T/10653. CHECK FLOW. GAS @ SURF. OBSERVED F/15 MIN. --NO SIGN OF FLOW. CBU. CUT MUD WT T/10.3. CBU. RAISE MUD WT T/10.7. DRILL T/10710. BIT QUIT. CBU & CHK F/FLOW. TOOH F/NEW BIT. BIT TRIP MW: 0.0 VIS: 0 TIH W/BIT %7 T/10710. DRIL T/10725. CBU. CHANGE LINER & SWAB IN %1 PUMP. DRILL T/10904. CBU. TOOH F/NEW BIT & BHA. MU BIT #8 & BHA #9 & TIH T/BTTM. DRILLING MW: 0.0 VIS: 0 REAM T/10904. DRILL T/11073. TOOH F/LOGS MW: 0.0 VIS: 0 TOOH F/LOGS MW: 0.0 VIS: 0 DRILL T/l1300. CBU. CHK WELL F/FLOW. CBU. COAL CAME UP W/SWEEP. MUD WT CUT T/10.2. TIH W/NO PROBLEM. CIRC SWEEP AROUND. CUT MUD WT T/10.4. OBSERVE THE WELL & PUMP DRY JOB. LD 5" DP MW: 0.0 VIS: 0 TOOH F/LOGS. PULL BHA. RU ATLAS E-LINE. RUN CHT-GR-CN-CDL-DIFL-TEMP LOGS. RD ATLAS. PULL WEAR BUSHING & RU T/TEST BOPE. WEEKLY TEST WITNESSED BY DOUG AMOS W/AOGCC. TIH W/BHA #5 T/4445. SERVICE THE RIG. TIH T/10800. CBU. TOOH T/RUN 7-5/8" LONG STRING. RUN 7-5/8 CASG MW: 0.0 VIS: 0 LD 5" DP. PULL WEAR BUSHING INSTALL TEST PLUG. CHANGE TOP PIPE RAMS T/7-5/8" PRESS TEST SEALS & BODY. RU T/RUN 7-5/8" CASG. FILL PIPE & BREAK CIRC @ 10-3/4" SHOE. RUN CASG T/10950. TIGHT @10950. RU, CIRC & RECIPROCATE CASG. ~LL : MPI 1-31 OPERATION: RIG : DOYON 15 PAGE: 4 06/11/95 (21) TD:ll300 PB:11325 06/12/95 (22) TD:l1300 PB:11325 RUN COMPLETION MW: 0.0 RUN 7-5/8" CASG. WORKED TIGHT HOLE @10945. CBU & INCREASE PUMP RATE T/2 BPM WHILE WASHING CASG T/BTTM WHILE ADDING LIQUID CASING. CASING RECIPROCATED FREELY ON THE BTTM. CIRC 2 BPM WHILE INCREASING T/10 BPM W/1500 PSI.--NO MUD LOSS. LOST 370 BBLS OF MUD TOTAL DURING OPS. PUMP 20 BBLS H20 & PRESS TEST CMT LINES T/3000. PUMP 70 BBLS SPACER & 148 BBLS CMT. DISPLACED W/CALCULATED 513 BBLS. RECIP. BUMP PLUG W/2000. PRESS TEST T/3500/30 MIN. BLED PRESS. FLOATS HELD. INSTALL 7-5/8" PACK OFF & PRESS TEST T/5000/15 MIN. INSTALL TEST PLUG & CHANGE TOP PIPE RAMS. TEST RAM BODY & DOOR SEALS. INJECT 200 BBLS OF MUD DOWN 10-3/4" X 7-5/8" ANNUL. & FREEZE PROTECT. RU T/RUN 4.5" 13 CR-80 COMPLETION TBG. RIG RELEASED MW: 0.0 RUN COMPLETION. TEST CL T/5000. LAND TBG. ND BOPE, RISER, CHOKE LINES & SFTY BOSS FLANGE. NU ADPTER FLNG & TREE. PRESS TEST T/5000. INSTALL LUB. PULL 2-WAY CHK. RD LUB. DISPLACE WELL W/INHIBITOR TREATED SEAWATER. DROP BALL. PRESS UP TBG & SET PACKR W/4000. HELD F/30 MIN. BLED TBG T/1500. TEST ANNUL T/3500/30 MIN. BLED OFF TBG PRESS & SHEARED RP VALVE @ TOP GLM. DISPLACE W/60 BBL OF DIESEL & U-TUBE. INSTALL BPV. INJECT 200 BBLS OF USED SEAWATER T/FRZ PROTECT ANN. RELEASE THE RIG. SIGNATURE: (drilling superintendent) DATE: horait .?' Date gO(:, '-'" 70.2 ~ '-.."-.~ Z i.-" i ~ Off .~r-..: ,~ ; .-, 7:.--%-: 30 2-.-'-.50 .-.27 274,4~ 4'.'---" <'fi -:-"! ,--...,--= :% ~ ! ? L7 ,.'--'-:' .t .:-:©27 ~ ~.~. O L :%: 369,'.:.: ?'":.-' 4:' 7-3 ~ ~Z :.% ,;; .-..% · :, f<Yq- :. :.F~. ! L.r, vi'!L- ~?M\: ft 0 90 :O :.:-"4: ? VfL:Q :.:::.5:0 ~ l'.;.', '.-'.--'S 608,7'? dem.' IOOft r, c:F. '~.,' .? :$ :: 0~15 0 ~7,'.-. '7,./ 'a'.' , .:,., ~. , * ,.L-: i %-=.--' ~ .L..' .i :iCi ,. ~ ,_, , :-: ._, .': e .J,,.: -!7--6:: :2:5,~ !.O ! 27 +:::.3 ~:' v--, ~ ......... 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AS .. ~9e., "" ....... %',,86 0,7'9 t O~ .20i0,Lt" . . '~A~= "'~ 3672,52 9,q, ~2 1,0i ~t. ,.J+/O - - - · ,",,, ",-,-',a 9:!,,'.77 cv ui,20 ..:; ,:,,,:30 .....- LARRY GRANT Attn. ALASKA OIL + 'GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Date: 24 August 1995 ..... RE: Transmittal of Data Sent by'. 3~I~H.EXPNESS ......... .._ .... Please sign and return to: Attn. Rodney- D. Paulson Suite 201 ~chorage, ~ 99518 - _ . Received by: ~~ 011 & Gas C~s. Commission ~ ~-~ ~ ~chomg~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 23 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, _ Enclosed, 'please find the data as described below: . - .... _ ~, . ..... -_:~.~_~,-., -:- i-=?-.~ - ~-- ~ DESCRIPTION ..~:%;'¥ ',:~ .... ._- _--: ~ - ._-.- ..... _,~- ...... ?..EEC No. . _ .. _.- .:-.~-~.. -~ :- :~-.- -. --_~ ~_.- ........... .~ · _ .... · ~. _ Z~.¥~- · . -. ..... -,~.:':- ?-' -~-. ~ .... -~--.~:-~-_~:~ , ..... ' -- - - - ' :'~-.. ~;~'=Y~ ~--~' -~:Y--z_~~. -' - ' ~- - · -- ' - ~. -'~:~;~:E~;'~:~'~&.~z~-~-~:~:.'~~ -~:-': ~:'- _~9.-'-1--19/I--18_ (~I) -~ --_--. -:1 PFC[PE~ FIN~ BL+~ ~-Run ~ I _..,.:.-~ ..... -.6467~.03_..~~¥ . . = ....... ._. 'Please si~ ~d return to: Attn. Ro~ey D. Paulson '-. Atlas Wireline Se~ices 5600 B Street Suite 201 ~chorage, ~ 99518 - Or F~ to (907) 563-7803 .-RECEIVED Date: Alaska Oil & 6~..~ c,~ r,, · . /~chorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 June 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~'rh # DESCRIPTION 3-05/0-29 . 1 PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF 1-31/M-21 1 SBT/GR FINAL BL+RF ECC No. Run # 1 2628.06 Run # 1 5921.09 Run # 1 6446.01 Run # 1 Run # 1 6446.00 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: 15 June 1995 Transmittal of Data ECC #: 6443.00 ANCHORAGE Sent by: PRIORITY MAIL AK, 99501. Data: OH-LDWG Dear Sir/Madam, ENDICOTT NORTH as SLOPE, AK ~ Enclosed, please find the data described below: Tapes/Diskettes: 1 LDWG TAPE + LIS Please sign and'-~ eturn to: Att odney D. Paulson ~las wireiine Services . J 5600 B Street / Suite 201 /~. Anchorage, AK 99518 ~3 Or ~X to (907) 563-7803 ~/~ Received by~~/ //~..z..~'-=-~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 12 June 1995 Transmittal of Data ECC #: 6443.00 Sent by: PRIORITY MAIL Data: OH-LDWG Dear Sir/Madam, Reference: 01-31/M-21 END I COTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 DIFL/GR/SP FNL BL+RF Run # 1 1 ZDL/CN/GR FNL BL+RF Run # 1 1 CN/GR FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 1 BHP FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and =eturnto$ Petrotechnical Data Cente~ BP Exploration (Alaska) Ine 900 East Benson Boulevard i'v ED JUN .] B ~95_ Anchorage Endicott Production Engineering Department PERFORATE DATE: 6/16/95 WELL N°: 1 - 31 /M - 21 BP EXPLORATION REP: R. CLUMP SERVICE CO: ATLAS (HARPER) DATE/TIME OPERATIONS SUMMARY 8:00 MIRU. SIWHP = 220 PSI; lAP = 0 PSI; OAP = 0 PSI 9:55 RIH WITH PFC, GR, AND GUN #1 (10 FEET), 2.0' FROM CCL TO TOP SHOT! 10:00 TAG BTM @ -11171'. TIE-IN TO GR/DIL DATED 8/8/95 (+12'). BLEED TBG DOWN TO 50 PSI. RIH. LOG CONFIRMATION PASS. 11:00 LOG INTO POSITION. CCL DEPTH IS 11103' (TS @ 11105' MD). SHOOT GUN #1 FROM 11105'-11115' MD BKB. GOOD INDICATION. LOG OFF. WHP= 100 PSI. OPEN TO FLOW IN BLEED TANK. SHUT IN & POOH. 11:30 OOH. ALL SHOTS FIRED. 12:00 RIH WITH PFC, GR, AND GUN #2 (23 FEET). 3.0' FROM CCL TO TOP SHOT. 13:00 OPEN WING VALVE & CK TO 40 BEANS. LOG TIE IN PASS FROM PBTD (+3'). RIH. LOG INTO PLACE @ 11034' CCL DEPTH (TS @ 11037' MD). 13:15 SHOOT GUN #2 FROM 11037'- 11060' MDBKB. GOOD INDICATION. LOG OFF. SHUT IN WELL. POOH. 14:10., OOH. ALL SHOTS FIRED. .' 14:30" RDMO ATLAS. RIG UP POOR BOY GAS-LIFT AND POP WELL. PERFORATION SUMMARY: GUN PERF INTERVAL FEET SUBZONE I 11105-11115' 10 2A 2 11037-11060' 23 2A THE INTERVALS WERE SHOT USING 3-3/8" ALPHA JET HSC GUNS AT 4 SPF, 60°/120° PHASING AND 0° ORIENTATION. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~ Chairman-'"'-- DATE: June 8, 1995 THRU: Blair Wondzell,~'~'- FILE NO: 6 f~- P. I. Supervisor FROM: Doug Am o s ;~o,_~_ SUBJECT: Petroleum Inspector akhhfhcd.doc BOPE Test Doyon #15 BPX DIU MPI 1-31/M-21 Endicott Oil Field PTD No. 95-0072 Thursday, June 8, 1995: I traveled to BPX Endicott MPI 1-31 / M-21 to witness the BOPE Test on Doyon Rig No. 15. As the attached AOGCC BOPE Test Report indicate§ there were no failures. The Accumulator was slower than usual in reaching its operation pressure of 3,000 PSI, even though it did meet the APl requirements of less than 2 minutes for achieving its 200 PSI build up after closure. The pump inlet screen was checked and found to be clogged. The screen was cleaned and the performance test repeated. The Accumulator achieved it's full charge in 2 min. 45 seconds after the cleaning, which is historically the time required for this padicular accumulator. SUMMARY: Witnessed the successful BOPE Test at BPX DIU MPI 1-31 / M-21 well at Doyon Rig No. 15. 2.0 Test Hours, No Failures, 26 Valves tested. Attachment: AKHHFHCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Dr#ling Inc. Operator: BPX Well Name: BPX DIU MPI 1-31/M-21 Casing Size: 10 3/4" Set @ Test: Initial Weekly X Rig No. 15 PTD # Rep.: Rig Rep.: 4,455 Location: Sec. Other DATE: 6/8/95 95-72 Rig Ph.# 659-6510 James Carlile Mike Droddy 36 T. 12N R. 16E Meridian Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign Yes Drl. Rig OK Hazard Sec. Yes Test FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F I 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 1 300/3,000 P f 500/5,000 P f 500/5,000 P I 500/5,000 P f 500/5,000 P 2 500/5,000 P 1 500/5,000 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves 16 No. Flanges Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 500/5,000 P 46 500/5,000 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 ~ 2, 750 3,000 J P 1,250 P minutes 50 sec. minutes 10 sec. YES Remote: YES Psig. Number of Failures: '~0'' ,Test Time:~°urs" Number 0f valves tested .126 .RePair Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to JtheAOGCC Commission Office at: Fax No. 276-7542 North No. 659-3607 or 3687 Inspector Slope Pager If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test everything went smothly. Very good drilling crew. The Accumulator took 30 sec. longer to pressure up than on the last test, you could see on the accumulator pressure gauge that the pump was starving for fluid. The pump internal screen was check and found to be plugged, the screen was cleaned and the preformance test repeated with excellent results. Distribution: odg-Well File c- Oper./Rig c- Database c - Tdp Rpt File c- Insp~.,~D[L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO &ifil Waived By: Witnessed By: FHCD.XLS Doug Amos ~LASKA OIL AND GAS - CONSERVATION COM~IISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX'. (907) 276-7542 May 19, 1995 R. B. Laule Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re .' Duck Island Unit/Endicott 1-31/M-21 BP Exploration (Alaska), Inc. Permit No:-95-72 Sur. Loc. 3225'NSL, 2109'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc. 2622'NSL, 3131'WEL, Sec. 31, T12N, R17E, UM Dear Mr. Laule~ Enclosed is the approved application for permit to drill the-above referenced well. The permit to drill dOes not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field 607 dlf/Enclosures oct Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchora~le, Alaska 99519-6612 ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3225' NSL, 2109' WEL, SEC. 36, T12N, R16E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 2641' NSL, 3249' WEL, SEC. 31, T12N, R17E 1-31/M-21 2S100302630-277 At total depth 9. Approximate spud date Amount 2622' NSL, 3131' WEL, SEC. 31, T12N, R17E 5/27/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 47502-2622' feet No close approach feet 2560 11171'MD/10306' TVD feet 16. To be completed for deviated wells 17. Anticipated~re (see 20 AAC 25.035 (e)(2)) Kickoff depth 1350 feet Maximum hole angle 34 o Maximum surface ~, ~,~UU./ psig At total depth (TVD) 10000'/48_~90 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe Surface Drive 13-1/2" 10-3/4" 45.5# NT80 £Ne~BTC 4480' Surface 4480' 4356' 716sxPF"E"/461 sx "G'Y150sxPF"E" 9-7/8" 7-5/8" 29.7# NT80c'r~ NSCC 11246' Surface 11246' 10306' 510 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate MAY 17 199,5 Production Liner At,SkU 0il & Gas Cons. Commission Perforation depth: measured N~ch0ra? true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed reportl-I 20 AAC 25.050 requirementsl-I 21. I hereby certj,f~ that the, foregoing is true and correct to the best of my knowledge Signed /~",t~, ~'~ ,~x'~_/~ Title Drilling Engineer Supervisor D at e .,,,4"'"---//Y--~'J- ~ commission use only Permit Number APl number Approval Cate., See cover letter ~- ,~?~ 150- O).C]-~,~ ~~~p, ~.~ ~/~'"" for other requ rements Conditions of approval Samples required [] Yes [~No Mud Icg ,,,,'bqu~e~t- /f~l-I Yes [] No Hydrogen sulfide measures ,1~ Yes [] No Directional survey required/ ]~ Yes [] No BQPE .D,],2M; .E~.3M; [~; I-I10M; D15M; Required working pressure for Urlglnal ~51grteduy- Other: by order of ~__./,~/ Approved by David W. Johnston Commissioner me commission Date~ Form 10-401 Rev. 12-1-85 Submit ir ] Well Name: [ 1-3 l/M-21 Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: 3225 FSL 2109 FEL S36 T12N R16E UM Target Location: 2641 FSL 3249 FEL S3 ! T12N R17E UM Bottom Hole Location: 2622 FSL 3131 FEL S31 T12N R 17E UM I AFENumber: 1717495 I I Rig: I DOYON 15 I Estimated Start Date: 1 5-27-95 I I Operating days to complete: 124 IMD: I11171 I I~vD= I10306 I IKBE: I56 [ Well Design (conventional, slimhole, etc.): ] SLIMHOLE Formation Markers: Formation Tops MD TVD (BKB) UPPER SV SHALE 3364 3291 SV-5 4145 4036 TUFFS 9497 8856 HRZ 10149 9396 PUT RIVER Absent Absent KEKIKTUK 10462 9664 4700 psi Zone3A 4626psi Zone2B I~L~L.~ v ,-,-" Anchora, :~ Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MDfrVD MD/TVD 13.5 10.75 45.5 80 BTC 4480 0 4480/4356 9.875 7.625 29.7 80 NSC 11246 0 1124610306 C Logging Program: I Open Hole Logs: I DIL/MSFL/LDT/CNL/GR Well Plan Summary Page 1 Cased Hole Logs: FMT 10-15 points SBT (optional) Mud Program: ]Special design considerations Surface Mud Properties: I SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 to to to to to to to 9.2 100 20-40 15-20 20-30 9-10 15-25 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.8-10.2 50-6- 20-30 12-15 25-30 9.5-10.0 <6 to to to to to to to Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional-. Igor: 11350 I Maximum Hole Angle: 1 34.0 Close Approach Well: None The above listed wells will be secured during the close approach. Deep well intersection guidelines met on 1-25/N-22. Gas Cons. Oommission ~ohora,? Well Plan Summary Page 2 1-31/M-21 Drilling Hazards: 1) Irregular target to avoid faulting to the North west and southeast. 2) Depth uncertainties for formation tops estimated at +/- 15 feet. 3) Distances to nearest 2A injector 5-02/SD-10 (wtr inj) 2050 ft SSW 1-23/O-15 (wtr inj) 3600 ft NW (no inj to date) 2-06/J-22 (gas inj) 3400 ft NE 4) Pressure: The 3A pressure of 5226 psia is a calculated static BHP based on a 4170# wellhead injection pressure on gas injection Well 1- 05/0-20. The gas injector is approximately 1000' from the M-21 target location. Equivalent mud weight of up to 10.5 ppg is possible. 5)Gas:A gas underrun of the K2M is predicted at the top of the 2A3. Base of the underrun is predicted to be approximately 9965' TVDss. The presents of this under run was indicated in the 2/94 CNL in the offset Well 1-05/O-20. 6)Pressure differential of up to 1000 psi are possible between the sands due to ofset production and injection. Zone Pressure (psig) Depth (TVDSS) 3C Truncated 3B Truncated 3A 4700/5226* 9600 2B 4624 9830 2A 4314 9928 1 N/A 10120 Note: These pressures are estimates, based on zonal pressure surveillance in surrounding wells. Original reservoir pressure (4890 psia @ 10000 TVDSS) may be encountered at any point within the Kekiktuk, due to hydraulic discontinuities within the formation. * 5226 psi is the estimated injection pressure at the perforations in well 1-05/O-20. Shut in pressure on well 1-05/O-20 on 2-28-95 was recorded at 3700psi. Estimated BHP is 4670psi. RECEIVED M/~¥ 3 7 1995 ,~taska Oil & Gas Cons. Commission Anchora,¢, 1-31/M-21 CEMENT PROGRAM- HALLIBURTON CASING SIZE: 10-3/4", 45.5# CIRC. TEMP: 40°F 10-3/4" SURFACE CASING /,.t"r 8 o LH~" LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx MIX WATER: 11.63 gps APPROX. SACKS: 716 THICKENING TIME: 5+ hrs TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 461 THICKENING TIME: 4 hfs TOP JOB CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx APPROX. SACKS: 150 MIX WATER: 11.63 gps SPACER: 100 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME The objective is to get cement back to surface 1. Lead slurry w/30% excess over gauge hole. 2. Tail slurry to 3320' w/30% excess over guage hole. 3320 MD = top of SV shale 2. Top job volume 150 sx. 7 5/8" PRODUCTION CASING CASING SIZE: 7-5/8", 29.7# CIRC. TEMP 135°F TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.45% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.0 gps SACKS: 510 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. SPACERS: Pump 20 bbls Fresh Water; 70 bbls NSCI (Halliburton) spacer @ 11 ppg. OTHER CONSIDERATIONS: Batch mix tail slurry. Displace at 14 bpm with rig pumps. CEMENT VOLUME: Tail Slurry to 1000' above the Kekektuk w/50% excess over gauge hole + 80 ft. shoe. The estimated MD of the Kekektuk is 10,350 RECEIVED MAY '1 7 ]995 UII & Gas Cons. Commission Anchora.? 1-31/M-21 OPERATIONS SUMMARY: Dig out cellar, Weld on landing ring. Ensure landing ring is the proper height with Endicott Field personel. MIRU Doyon 15. Hold pre spud meeting with crew. 1. Drill 13-1/2" surface hole. Use gyro for close approach until magnetic interference is past. Check with Anadrill & Gyrodata to insure they are following JORPS. Drill hole to 4356' TVD. 2. Run 10-3/4" 45.5 ppf surface casing 3. Cement surface casing. 4. Perform top job, if necessary with 150 sx Type "E" Permafrost cement. 5. ND diverter. NU Bop's & test. 6. Drill out shoe and perform LOT. 7. Directionally drill production hole to 10,306 TVD. Well site geologist will help pick final TD (175' below lower most possible perforation in 3A). 8. A PDC should be picked up as the second 9-7/8" bit and drill the top 200-300' of the Tuffs. 9. Have sample catchers and well site geologist on site before drilling the Kekiktuk. 10. Use key seat wiper for Tuffs and HRZ. 11. RU E/Line & run open hole logs ("Triple Combo" ).+ FMT. 12. Run 7-5/8" production casing. Turbolators should be 2 per joint on the bottom 1000' of casing. 13. Run bond logs . (optional dependent on the mechanics of the cement job). 14. Run 4-1/2" 13CR-80 completion with hydraulic set permanent packer with WLEG 350' above the top of Kekiktuk (estimated WLEG @ 10,100' MD). 15. ND Bop's. NU 4-1/16" 5M# tree. Set packer and test. 16. Freeze protect tbg. 17. RD MO Rig. h~m o~ & Gas Cons. comrai~on I i i ii iiii i AnadrY ] ] Schlumberger PLAN VIE~ ! ii CLOSURE ' 3973 feet at Azimuth 96.67 DECLINATION.' ~9.778 E SC~E · I inch = 500 Ceet ORA~N ' 05/I5/~ ' SHAR' D SERVTCES D "I'[.i_TNG mmlmm mllllm II · mi mmllll i il m mi II I Marker Idefltification ~ N/S ~J KB 0 0 0 B) 14UOGE BUILD t.S/tO~ 350 0 0 C) DROP :l/'JO0 750 3 2t D) ENO ~. 5/100 BUILD 750 3 E) END t/~O0 DROP J3~ B 52 F) i((]P BUILD ~.5/]00 ~3~ B 52 G) END 2.5/~1Q0 BUILD 2047 ~0 156 H) ~Uf~rACE CASING 44~ lO~l E~O I] 12 ~ILD 2.5/~00 6836 186 1580 J) EI~) ;~.5/tO0 BUILD 7z99 K) TARSI 10999 445 3809 L) '11) J~246 461 3946 mil -ANA~tL~ - · AKA-DPC FEASIBILITY PLAN = ' ; j NC~T-AI >P'R(jVEE FOIl - , EX[CUrlObl .' -- " )E G = .._ _~ .... I I ~ m, i'tl . : i ~ ~-~ i. IARGFt ~O Fi l~[l)llS {~00 FI' l~) NWl · ~. -~ rn : i I · . "~ ~'- "~ l ,,~ . 1 _, ~_. · ) ~ .... , ~ ........... m ...... ,' _ - ".11 25~ 0 L;~JO 500 750 · !000 1251) ].500 1750 L:¢~OO 2;~) 2500 2750 30~ 3250 3500 3750 41)00 4;250 <- WEST- E~T -> [~ma~"ill k)93 i3I#iUPB B1_5~ 9~ i~ ~M il .C ~c 5: 8 JO800 -. SHARPO--~SE'..R_-V. iI. CES DFI ILL I NG . "i~ -... o .~ ..... i ~ I | 1-J'l / M-r'I I,h't3) , I[ ' ,-- I '.: VERTICAL SECTION VIEN 0 ~- ] -- : ~ i Section at: 96.6z~ ' ; I i TVD Scale. ~ ~nch.= ~200 feet o , i ', ..... ~ Oep Scale,' :l inch = ~200 feet E~ ~ I I Drawn · 05/:t5/95 · ~ i i 0 ............. I ................................. I · · ~ /nadr.~; ]2 Schlumberger 0 .... i ..... 14arker Id~n[if~ca.t~on : 140 6K~ SECTN INCLN ~1 KB 0 0 .0 O. B] NUDGE BUILD :1.5/100 350 350 0 0.00 Cl OROP t/lO0 750 749. ~J 6,0{) 0 ............... B) END ~t.5/~O0 BU:JLD ' ~50 . 7~9 2~ 6,0,0 El END ~/tO0 DROP :~350 !348 52 0.00 '' ~'¢¢¢~¢S~LE'-?~ F] KOP BUILD 2.5/100 ' 1350 J34B 52 O.O0 6) END 2.5/~00 BUILD - 8047 2034 i57- ~7.48 O' '~R-S~.E-~z3 H) SURFACE CASING 4a80 4356 886 ~7.~ 'J ' I) ¢2 BUILD 2.5/~00 6836 6604.' 15Bi 17.42 r ~¢,.~~b~-~ J) END 2.5/~00 BUILD : 2 ' ' ........ i...... K) TARGET ~0999 lOlOJ 3835 34.0~ L) TD )-- i.., I i, · ~ t ,,r t -~ : ~-- ~ ................... ~X~m~r~.,, ' · ~ FE2,SIB! i~ P N ,, )_- , :i ..... ' .. ~ ~ A'D. DD~k,'~'~ ~~ · N;!! ~,EXEGUTION '~r ~" ~'" i ......... q-F .......... ~ ......... ~-~ ..... · ......... )-F -. t -..~-~-~ ............. : ........... ! i ' ~-~ ~t-~.:~ ~ ..... r ' - ' ~ -r ~.~-N- r.=_- .......... :.-.:.-, .... .. .. ..... ~ . ~ .... i~ ,X CEiVE) " "~'~:"'--~ .... ~ .... ' ............................... ;;;& . .... .... ................. ....... :. 0 600 1200 JBO0, B~O0 3000 3600 4200 4800 '5400 8000 6600 7200 78?0 ; Sect ion Departure, - .! m. -; i : ! . I . mm. mm WELL PERMIT CHECKLIST 2,. 2- / o o INIT CLASS WELL NAME GEOL AREA PROGRAM: exp [] der ~ redrll [] serv [] / 0 ~/~-0 oN,OFF SHO~ 0,,~ ADMINISTRATION DATE ENGINEERING 1. 2. 3. 4. 5. 6. · 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. ~ N Lease number appropriate ................ ~N Unique well name and number ............... ~3 N Well located in a defined pool ............. ~ N Well located proper distance from drlg unit boundary.. ~ N Well located proper distance from other wells ...... O N Sufficient acreage available in drilling unit ...... ~ N If deviated, is wellbore plat included ........ ~ N Operator only affected party .............. G N Operator has appropriate bond in force ......... ~ N Permit can be issued without conservation order .... .~ N Permit can be issued without administrative approval.. ~ N Can permit be approved before 15-day wait ........ ~ N DATE 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved.~-N~ 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~Y~ N 26. BOPE press rating adequate; test to _~OO psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown, ...... ~ N 29. Is presence of H2S gas probable ............ N GEOLOGY DATE _3j~mi~an be.. issued w/_o hydrogen sulfide m~asures .... Y ~/ 31. D~nted on potenti~nes ..... Y N 32. Seismic a~w gas zones .......... Y N '~'~.s..~e,, ~o.~.~t*.~nsu=,,ey (~ ....... Y N 34. C s ..... Y N GEOLOGY: ......... ENGINEERING: COMMISSION: Comments/Instructions: .CD HOW/jo - A:%FORM.%-Acheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Tape Subfile 2 is typ. -~LIS TAPE HEADER ENDICOTT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6443.00 BRAD ESARY SEE REMARKS I- 31/M- 21 500292256200 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 14-JUN-95 RUN 2 RUN 3 36 12N 16E 3225 2109 55.85 0.00 14.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 2ND STRING 3RD STRING PRODUCTION STRING 9.875 REMARKS: DIFL/CN/ZDL/GR. 10.750 4455.0 11300.0 CIRCULATION STOPPED @ 06:00, 08-JUN-95. LOGS WITNESSED BY: J. CARLILE & P. BARKER. TOOLS CAME OUT OF THE HOLE CAKED WITH MUD AND FORMATION MATERIAL, MAKING THE TOOL O.D. 8 TO 10 INCHES. NOTE: 1 TO 2 PU SHIFT IN CNC CURVE BETWEEN MAIN AND REPEAT PASSES. ALSO A .5 TO 1 INCH DIFFERENCE BETWEEN MAIN AND REPEAT CALIPER CURVE RESPONSE. CALIPER VERIFICATIONS PERFORMED IN CASING. NOTE: CHT CURVE SPIKING. 4.3% BARITE AT 62.8 PPB. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON~LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DIL SDN 2435 $ depth shifted and clipped curves; .5OOO START DEPTH STOP DEPTH 9410.0 11232.0 9410.0 11292.0 9410.0 11257.0 9410.0 11238.0 GR (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA BASELINE DEPTH LL8 9451.5 9456.5 9464.0 9511.0 9518.5 9522.0 9544.0 9547.5 9550.0 9550.5 9560.0 9563.5 9567.0 9572.5 9573.5 9572.5 9576.5 9577.5 9576.5 9580.5 9582.0 9581.5 9582.5 9592.5 9595.0 9595.0 9604.5 9606.5 9606.5 9608.5 9608.0 9609.0 9611.0 9613.0 9618.0 9618.5 9631.0 9631.5 9643.5 9653.5 9660.5 9664.0 9668.0 9671.0 9680.0 9690.5 EQUIVALENT UNSHIFTED DEPTH ILD RHOB NPHI 9451.0 9456.5 9457.0 9463.0 9543,5 9548.0 9565.0 9572.0 9577.0 9580.5 9595.5 9606.5 9609.0 9511.0 9517.5 9521.5 9549.5 9563.5 9547.5 9551.0 9560.0 9580.0 9582.0 9593.0 9609.0 9610.5 9619.0 9631.0 9661.0 9668.5 9582.0 9592.5 9595.5 9605.0 9613.5 9619.0 9631.5 9644.0 9654.5 9665.0 9671.5 9680.5 9690.0 all runs merged; no case 9703.5 9704 · 0 9705.0 9707.0 9707.5 9715.5 9716.0 9726.5 9740.0 9741.0 9753.5 9759.5 9768.5 9779.5 9780.0 9784.0 9786.0 9788.0 9790.5 9795.5 9796.0 9800.5 9806.5 9807.0 9811.5 9812.0 9814.5 9824.5 9829.5 9871.5 9901.5 9903.5 9918.5 9924.5 9945.0 9945.5 9946.0 9950.5 9951.0 9988.5 9990.5 9992.5 9999.0 10006.0 10019.0 10021.5 10026.5 10045.5 10046.0 10048.5 10050.5 10051.0 10052.5 10071.0 10072.5 10073.0 10081.0 10097.5 10100.0 10115.5 9705.0 9715.5 9740.0 9780.0 9790.5 9806.5 9811.5 9902.5 9946.5 9950.5 9990.0 10005.5 10018.5 10046.5 10051.0 10073.0 10081.5 10100.0 9705.0 9715.5 9740.5 9759.5 9780.0 9790.5 9806.0 9810.0 9824.0 9902.5 9946.5 9950.5 9990.0 10005.5 10018.5 10046.5 10051.0 10073.0 10081.5 10100.0 9703.0 9707.0 9768.0 9783.5 9790.5 9795.0 98o6.o 9811.5 9903.5 9924.5 9944.5 9990.0 10005.5 10022.0 10049.0 10051.0 9704.0 9707.5 9716.0 9726.0 9741.0 9753.5 9779.5 9786.5 9788.0 9790.5 9796.0 9800.0 9806.5 9812.0 9814.5 9829.5 9871.5 9904.0 9918.0 9945.5 9950.0 9988.0 9992.0 9999.0 10006.0 10021.0 10026.5 10045.0 10050.5 10052.5 10071.0 10073.0 10098.0 10115.0 10128. 10136. 10147. 10155. 10155. 10167. 10172. 10176. 10187. 10199. 10202. 10213. 10217. 10226. 10246. 10269. 10275. 10301. 10317. 10317 · 10351. 10352. 10358. 10360. 10366. 10369. 10374. 10390. 10402. 10425. 10441. 10450. 10452. 10460. 10474. 10474. 10476. 10477. 10487. 10488. 10496. 10497. 10498. 10502. 10503. 10505. 10505. 10509. 10516. 10521. 10526. 10526. 10527. 10533. 10537. 10537. 10538. 10546. 10551. 10551. 10269.5 10317.0 10358.5 10402.5 10441.5 10474.0 10476.0 10487.0 10522.0 10526.5 10536.5 10551.5 10269.5 10317.0 10358.5 10373.5 10389.5 10402.5 10441.5 10474.0 10476.0 10487.0 10498.0 10522.0 10526.5 10536.5 10551.5 10128.0 10136.5 10147.5 10156.0 10175.5 10186.5 10201.5 10275.5 10302.0 10352.0 10358.0 10360.5 10367.0 10402.5 10474.5 10477.0 10487.5 10499.0 10503.0 10505.0 10509.5 10522.0 10527.0 10532.5 10537.5 10547.5 10551.5 10155.0 10168.0 10173.5 10188.0 10199.0 10213.5 10217.0 10225.5 10246.0 10269.5 10317.5 10352.0 10370.0 10375.5 10402.5 10425.0 10440.5 10450.0 10453.0 10461.5 10474.0 10476.5 10487.5 10497.0 10503.0 10505.5 10516.5 10525.5 10539.5 10551.0 10557.5 10558.0 10560.5 10561.0 10563.0 10565.5 10657.5 10659.0 10662.0 10672.0 10674.0 10674.5 10675.5 10679.0 10682.0 10686.0 10693.5 10694.0 10695.0 10701.0 10720.5 10721.5 10726.5 10727.0 10738.5 10764.0 10764.5 10777.5 10803.5 10804.0 10809.5 10813.0 10814.5 10817.0 10818.0 10827.0 10833.0 10841.0 10841.5 10844.0 10847.0 10847.5 10854.0 10862.0 10864.5 10876.5 10897.0 10901.0 10921.0 10933.5 10934.5 10940.5 10996.0 ilooo.o 11000.5 11017.0 11028.0 11028.5 11032.0 11033.5 10560.0 10658.0 10673.5 10687.5 10695.5 10721.5 10726.0 10763.5 10777.5 10810.0 10815.0 10845.0 10847.5 10861.5 10864.5 10933.5 10999.0 10556.5 10560.0 10658.0 10673.0 10677.5 10695.5 10722.0 10726.0 10763.5 10777.5 10810.0 10813.0 10818.0 10832.5 10841.5 10845.0' 10847.5 10861.5 10863.5 10933.5 10939.0 10994.5 10999.0 11014.5 10557.5 10561.5 10565.0 10655.5 10671.5 10675.0 10680.0 10682.5 10694.0 10726.0 10738.0 10763.5 10777.5 10804.0 10809.5 10814.0 10816.0 10826.5 10846.5 10854.0 10861.5 10864.0 10875.5 10896.5 10900.5 10934.0 11000.5 11028.0 11030.5 11032.5 10560.0 10658.0 10661.5 10672.0 10674.5 10686.0 10694.0 10701.0 10721.0 10764.0 10778.0 10803.5 10814.5 10840.5 10847.0 10861.5 10865.0 10921.0 10934.5 10999.0 11027.5 11036.0 11039.0 11051.5 11052.0 11059.0 11062.0 11062.5 11063.0 11063.5 11070.0 11092.0 11094.5 11095.0 11101.5 11104.5 11105.5 11114.5 11117.0 11117.5 11118.5 11119.0 11121.5 11122.0 11128.0 11133.0 11133.5 11134.5 11138.0 11148.0 11152.0 11152.5 11155.5 11156.0 11160.0 11163.5 11172.0 11172.5 11175.0 11176.5 11179.0 11179.5 11182.0 11185.5 11187.5 11188.0 11191.5 11192.5 11197.5 11198.0 11209.0 11212.0 11212.5 11223.5 11233.0 11237.5 11264.0 11274.0 $ MERGED DATA SOURCE '~±038.5 11050.5 11062.5 11070.0 11094.5 11101.5 11106.0 11121.0 11125.5 11153.5 11157.0 11177.5 11179.0 11192.5 11197.0 11212.0 11223.0 11038.5 11050.5 11061.5 11070.0 11094.5 11101.0 11106.5 11116.5 11119.5 11124.5 11133.5 11152.5 11156.0 11177.5 11179.0 11192.5 11197.0 11212.0 11223.0 11232.0 11238.0 11264.0 11274.0 11036.0 11052.0 11059.0 11062.5 11069.5 11092.0 11094.5 11102.0 11118.5 11121.0 11122.5 11134.0 11138.0 11151.5 11156.0 11172.5 11179.0 11184.0 11186.5 11197.5 11212.5 11063.0 11117.0 11120.0 11122.0 11127.5 11134.5 11148.0 11153.0 11160.0 11163.5 11172.5 11175.0 11179.0 11181.0 11186.5 11192.0 11199.5 11209.0 11212.5 PBU TOOL CODE GR DIL SDN 2435 $ REMARKS: NO. PASS NO. M. JE TOP 3 9410.0 3 9410.0 3 9410.0 3 9410.0 MAIN PASS. MTEM, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, DI, & SP WERE SHIFTED WITH ILD. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. MERGE BASE 11232.0 11292.0 11257.0 11238.0 CN WN FN COUN STAT / ??MATCH1. OUT /??MATCH2.OUT /??MATCH3 .OUT /??MATCH4.0UT $ : BP EXPLORATION (ALASKA) : 1-31/M-21 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 4 2 LL8 DIL 68 1 OHMM 4 3 ILM DIL 68 1 OHMM 4 4 ILD DIL 68 1 OHMM 4 5 RT DIL 68 1 OHMM 4 6 DI DIL 68 1 IN 4 7 SP DIL 68 1 MV 4 8 MTEM DIL 68 1 DEGF 4 9 TEND DIL 68 1 LB 4 10 TENS DIL 68 1 LB 4 11 RHOB SDN 68 1 G/C3 4 12 DRHO SDN 68 1 G/C3 4 13 PEF SDN 68 1 BN/E 4 14 CALl SDN 68 1 IN 4 15 NPHI 2435 68 1 PU-S 4 16 FUCT 2435 68 1 CPS 4 17 NUCT 2435 68 1 CPS 4 4 08 310 01 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 43 995 99 1 4 43 995 99 1 4 43 995 99 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data RecC ~: 273 Tape File Start Depth = 11311.000000 Tape File End Depth = 9407.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 68563 datums Tape Subfile: 2 663 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type, LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 1 3 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9407.0 11240.5 DIFL 9407.0 11301.0 ZDL 9407.0 11264.0 2435 9407.0 11242.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL KNJT TEMP PCM KNJT DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 08-JUN-95 FSYS REV. J001 VER. 1.1 600 08-JUN-95 1358 08-JUN-95 11300.0 11295.0 9408.0 11292.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517NA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3921NA 1503XA 9.875 4455.0 .0 LSND 10.70 58.0 9.8 4.8 171.3 RESISTIVITY (OH AT TEMPERATURE (DEGF) MUD AT MEASUk~.D TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-31/M-21 : ENDICOTT : NORTH SLOPE : ALASKA 1.330 .562 .960 .000 1.120 .000 THERMAL SANDSTONE 2.65 .000 1.5 68.5 171.3 68.5 .0 65.8 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMH VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU- S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 84 * DATA RECORD ~-i'YPE# 0) Total Data Records: 693 974 BYTES * Tape File Start Depth = 11311.000000 Tape File End Depth = 9407.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 167575 datums Tape Subfile: 3 774 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 4 is typ~. LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASS Composite of all curves and log header data from all tool strings for a single run; Multiple repeat passes for individual tool strings, if they exist, follow in a separate file. Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 1 2 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11000.0 11240.5 DIFL 11000.0 11301.0 ZDL 11000.0 11264.0 2435 11000.0 11242.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS MODL GR CN ZDL KNJT TEMP PCM KNJT DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR KNUCKLE JOINT DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): 08-JUN-95 FSYS REV. J001 VER. 1.1 600 08-JUN-95 1339 08-JUN-95 11300.0 11295.0 9408.0 11292.0 1800.0 TOOL NUMBER 3974XA 3967XA 3517NA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 3921NA 1503XA 9.875 4455.0 .0 LSND 10.70 58.0 9.8 4.8 MAXIMUM RECORD~ ~rEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX- MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1-31/M-21 : ENDICOTT : NORTH SLOPE : ALASKA ,1.3 1.330 .562 .960 .000 1.120 .000 THERMAL SANDSTONE 2.65 .000 1.5 68.5 171.3 68.5 .0 65.8 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 07 310 01 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 995 46 1 4 4 07 120 46 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 660 99 1 4 4 07 635 99 1 4 4 07 635 99 1 4 4 07 636 99 1 4 4 46 350 01 1 4 4 46 356 99 1 4 4 46 358 01 1 4 4 46 280 99 1 4 4 43 995 99 1 4 4 43 995 99 1 4 4 43 890 01 1 4 4 43 334 31 1 4 4 43 334 30 1 * DATA RECORD (TYPE# 0) Total Data Records: 114 974 BYTES * Tape File Start Depth = 11311.000000 Tape File End Depth = 10999.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 96042 datums Tape Subfile: 4 196 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 5 is typE. LIS 95/ 6/14 01 **** REEL TRAILER **** 95/ 6/15 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 15 JUN 95 9:25a Elapsed execution time = 16.81 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * * . ****************************** * ............................ . * ....... SCHLUlV~ERGER ....... * * ............................ . ****************************** COMPANY NAI~iE : BP EXPLORATION WELL NAME : 1-31/M-21 FIELD NA~IE : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292256200 REFERENCE NO : 97395 LIS Tape v~rification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: **** REEL HEADER **** SERVICE NABiE : EDIT DATE . 97/09/ 4 ORIGIN : FLIC REEL NA~E : 97395 CONTINUATION # : PREVIOUS REEL : CO~4~NT : BP EXPLORATION, 1-31/M-21, ENDICOTT, 50-029-22562-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/09/ 4 ORIGIN : FLIC TAPE NAME : 97395 CONTINUATION # : 1 PREVIOUS TAPE CO~!ENT - BP EXPLORATION, 1-3I/M-21, ENDICOTT, 50-029-22562-00 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NAME: 1-31/M-21 API NUM~ER: 500292256200 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLU~iBERGER WELL SERVICES TAPE CREATION DATE: 4-SEP-97 JOB NU~IBER: 97395 LOGGING ENGINEER: S.DECKERT OPERATOR WITNESS: B. CLUMP SURFACE LOCATION SECTION: 36 TOWNSHIP: 12N RANGE: 16E FNL: 3225 FSL: FEL: 2109 FWL: ELEVATION(FTFROM MSL O) KELLY BUSHING: 55.90 DERRICK FLOOR: GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 10. 750 4455.0 45.50 2ND STRING 7. 625 11265.0 29.70 3RD STRING 4. 500 9599.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape v=tification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11: 05 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DIL LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 8-JUN-95 LOGGING COMPANY: ATLAS BASELINE DEPTH 88888.0 11124.0 11109.0 11105.5 11103.0 11099.5 11093.5 11092.5 11076.0 11069.5 11069.0 11065.5 11063.0 11062.5 11059.5 11057.0 11051.0 11050.5 11043.0 11033.0 11028.0 11027.5 10999.5 10972.5 10964.0 10934.5 10933.5 10920.0 10919.5 10908.0 10905.5 10899.5 10884.5 10879.0 10877.0 10864~ 5 10854.5 10853.5 10847.5 10845.5 10842.5 10841.0 10840.5 10827.0 10817.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88889.5 88885.5 11121.5 11110.5 11107.0 11101.5 11098.0 11096.0 11092.0 11076.5 11070.0 11070.0 11067.0 11063.0 11063.0 11059.5 11057.5 11051.0 11051.0 11042.5 11033.5 11028.5 11028.5 11000.5 10973.0 10965.5 10934.0 10934.0 10920.5 10920.5 10908.5 10905.5 10899.5 10882.0 10879.5 10877.0 10864.5 10864.5 10854.0 10854.0 10847.0 10844.0 10842.0 10840.5 10840.5 10826.5 10817.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 10815~5 10815.0 10814.5 10815.0 10813.0 10813.0 10812°5 10813.0 10810.0 10809.5 10808.5 10807.5 10778.0 10777.5 10776.0 10777.0 10764~0 10764.0 10763.0 10764.0 10737.5 10738.5 10737.0 10738.5 10726.0 10726.5 10725.0 10726.0 10722.5 10721.5 10721.5 10721.5 10718.0 10718.0 10715.5 10716.0 10711.0 10710.0 10705.0 10705.0 10702.0 10700.5 10696.0 10693.5 10692.0 10690.0 10688.0 10685.5 10687.5 10685.5 10683.0 10681.5 10680.0 10678.5 10676.0 10674.0 10675.5 10674.0 10673.0 10671.5 10671.5 10662.5 10660.5 10660.0 10659.5 10658.0 10657.5 10657.5 10657.5 10643.5 10642.0 10638.0 10638.0 10629.5 10630.5 10616.5 10618.5 10602.5 10603.5 10595.0 10595.5 10591.0 10591.0 10586.5 10587.0 10582.0 10581.5 10567.5 10567.5 10562.0 10563.0 10560.0 10560.0 10559.0 10560.0 10557.0 10557.5 10554.0 10553.0 10552.0 10551.0 10551.5 10551.0 100.0 99.0 99.5 $ CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON BP EXPLORATION WELL 1-31/M-21. THE DEPTH SHIFTS SHOWN PAGE: LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 ABOVE REFLECT FLOWING PASS #1 GRCH TO GR.DIL; AND FLOWING PASS #1 SIGM TO GR.DIL. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAi~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AU3FiBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NU~iBER: 1 DEPTH INCREFLENT: 0.5000 FILE SU~E~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11126.0 10550.0 TDTP 11136.0 10550.0 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP REMARKS: THIS FILE CONTAINS TDTP FLOWING PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: ** 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 0 ** SET TYPE - CHAN ** N.~IE SERVU'NIT SERVICE ~:>I API API API FILE _NUlVlB~ SIZE I~PR PROCESS ID ORDER # LOG TYPE CLASS MODNUM~ SAMP ELEM CODE (HEX) DEPT FT 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 SBHFTDTP CU 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 SIBHTDTP CU 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TSCNTDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TSCFTDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 INND TDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 TENS TDTP LB 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 CCL TDTP V 1064309 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape 'verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: DATA ** DEPT. 11133.500 SIGM. TDTP 24.809 TPHI.TDTP 41.480 SBHF. TDTP 38.820 SBH1V. TDTP 45.217 SIGC. TDTP 0.654 SIBH. TDTP 45.217 TRAT. TDTP 1.900 SDSI. TDTP 0.702 BACK. TDTP 67.297 FBAC. TDTP 24.125 TCAN. TDTP 30292.223 TCAF. TDTP 10367.820 TCND.TDTP 20503.828 TCFD.TDTP 5982.258 TSCN. TDTP 4281.154 TSCFoTDTP 1465.269 INND.TDTP 1694.684 INFD. TDTP 377.614 GRCH. TDTP -999.250 TENS. TDTP 1385.000 CCL. TDTP 0.000 DEPT. 10549.000 SIGM. TDTP -999.250 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHIV. 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 217.000 TENS. TDTP -999.250 CCL.TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAMi~ : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArO?4~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH GRCH 11126.0 TDTP 11136.0 STOP DEPTH 10550.0 10550.0 LIS Tape ~verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (~iEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NURiBER : 1 BASELINE DEPTH 88888.0 11124.0 11117.5 11105.0 11102.5 11099.5 11092.5 11091.5 11082.5 11069.0 11068.5 11062.0 11047.5 11046.5 11035.5 11034.5 11027.0 11026.5 11022.0 11016.0 11011.5 10999.5 10955.0 10940.0 10933.5 10933.0 10930.0 10918.5 10915.5 10907.0 10898.0 10886.5 10878.5 10875.5 10864.0 10861.5 10857.5 10856.5 10855.0 10849.0 10846.0 10844.0 10842.5 10840.5 10839.5 ......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88890.0 88885.5 11121.5 11116.0 11107.0 11102.0 11098.0 11096.0 11092.0 11083.0 11070.0 11070.0 11062.5 11063.0 11049.0 11047.0 11037.0 11035.5 11028.5 11028.5 11024.5 11017.5 11013.5 11000.5 10957.0 10941.0 10934.0 10934.0 10930.5 10920.5 10916.0 10908.5 10899.0 10887.5 10879.5 10877.0 10864.5 10864.5 10862.0 10858.5 10856.0 10855.0 10851.0 10847.0 10844.0 10842.0 10840.5 10840.5 LIS Tape-verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 10815 0 10814 0 10812 0 10807 5 10804 0 10799 0 10796.5 10791.0 10777.5 10770.5 10762.5 10758.0 10751.0 10731.5 10731.0 10726.5 10724.5 10722.0 10720.5 10718.0 10712.0 10711.5 10707.5 10695.5 10695.0 10688.5 10687.0 10679.5 10676.0 10672.5 10661.5 10659.5 10657.0 10651.0 10642.0 10636.5 10626.5 10624.5 10609.5 10586.0 10573.0 10562.0 10559.5 10559.0 10554.0 100.0 $ 10815.0 10807.5 10803.5 10796.0 10770.5 10758.5 10751.0 10732.5 10726.5 10721.5 10718.5 10711.0 10705.5 10694.0 10685.5 10673.5 10671.5 10657.5 10628.0 10560.0 100.5 10815.0 10813.0 10799.5 10791.5 10777.5 10764.0 10733.0 10726.0 10721.5 10710.5 10693.0 10686.5 10678.5 10671.5 10660.5 10659.5 10657.5 10651.0 10642.0 10635.5 10625.0 10610.0 10586.5 10574.0 10563.0 10560.5 10553.5 99.5 THIS FILE CONTAINS TDTP FLOWING PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT FLOWING PASS #2 GRCH TO FLOWING PASS #1 GRCH; AND FLOWING PASS #2 SIGM TO TO FLOWING PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS Tape 'verification Listing Schlumberger Alaska Computing Center $-SEP-1997 11:05 PAGE: 21 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CALIPER TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 1800.0 NO TOOL NUMBER ........... CAL-UB-299 TDTP SET 23 11265.0 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) : PRODUCED FLUID 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 ATLAS DIL/GR DATED 8-JUN-95. THIS FILE CONTAINS THE RAW TDTP DATA FOR FLOWING PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 22 ** 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 ** NA2qE SERV UNIT SERVICE API API API API FILE NUbfB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUA~ SAMP ELEM CODE (HEX) DEPT FT 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNPS2 CU 1064309 O0 000 O0 0 6 1 i 4 68 0000000000 SIGC PS2 CU 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1064309 O0 000 O0 0 6 1 i 4 68 0000000000 SDSI PS2 CU 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TCFDPS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 INND PS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1064309 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape 'Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 23 ** DATA ** DEPT. 11150.000 SIGM. PS2 SBP~N. PS2 40~818 SIGC. PS2 SDSI.PS2 1.411 BACK. PS2 TCAF. PS2 9602.266 TCND. PS2 TSCF. PS2 854.699 INND.PS2 GR.PS2 213~625 CCL.PS2 31.302 TPHI.PS2 0.582 SIBH. PS2 -999.250 FBAC. PS2 -999.250 TCFD.PS2 -999.250 INFD. PS2 0.000 DEPT. 10542.500 SIGM. PS2 33.873 TPHI.PS2 SBHN. PS2 45.564 SIGC. PS2 1.907 SIBH. PS2 SDSI.PS2 1.303 BACK. PS2 164.592 FBAC. PS2 TCAF.PS2 8339°477 TCND. PS2 15278.557 TCFD. PS2 TSCF.PS2 674.085 INND.PS2 1406.486 INFD. PS2 GR.PS2 247.125 CCL.PS2 0.000 46. 037 40. 818 -999.250 -999.250 -999. 250 48. 782 45.719 92. 347 3992. 960 303. 593 SBHF. PS2 TRAT. PS2 TCAN. PS2 TSCN. PS2 TENS.PS2 SBHF.PS2 TRAT. PS2 TCAN. PS2 TSCN. PS2 TENS.PS2 35.055 1.937 31779.633 2739.974 1110.000 39.626 1.874 29088.227 2178.650 1275.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUgFiBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER : 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11153.5 10542.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 24 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E 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) : 17-AUG-97 CP 42.2 1627 17-AUG-97 11181.0 11133.0 10550.0 11127.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CALIPER TDTP THERMAL DECAY $ TOOL NUMBER CAL- UB- 2 9 9 TDTP SET 23 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 11265.0 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) : PRODUCED FLUID 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 ATLAS DIL/GR DATED 8-JUN-95. THIS FILE CONTAINS THE RAW TDTP DATA FOR LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 25 FLOWING PASS #3. $ 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 I1 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERVUNIT SERVICE API API API API FILE NUMB ~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TCFDPS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 26 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) INFDPS3 CPS 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1064309 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11150.000 SIGM. PS3 27.230 TPHI.PS3 43.106 SBHF. PS3 SBHN. PS3 39.257 SIGC. PS3 1.552 SIBH. PS3 39.257 TRAT. PS3 SDSI.PS3 0.913 BACK. PS3 -999.250 FBAC. PS3 -999.250 TCAN. PS3 TCAF.PS3 13019.359 TCND. PS3 -999.250 TCFD.PS3 -999.250 TSCN. PS3 TSCF.PS3 1154.164 INND.PS3 -999.250 INFD.PS3 -999.250 TENS.PS3 GR.PS3 217.625 CCL.PS3 0.000 DEPT. 10542.000 SIGM. PS3 34.303 TPHI.PS3 50.932 SBHF.PS3 SBHN. PS3 41.906 SIGC. PS3 1.258 SIBH. PS3 41.906 TRAT. PS3 SDSI.PS3 1.451 BACK. PS3 181.529 FBAC.PS3 94.266 TCAN. PS3 TCAF.PS3 7598.382 TCND.PS3 14393.824 TCFD.PS3 3727.964 TSCN. PS3 TSCF. PS3 601.952 INND. PS3 1247.957 INFD.PS3 283.157 TENS.PS3 GR.PS3 232.000 CCL.PS3 0.000 36.421 1.966 42036.852 3580.795 1105.000 34.589 1.969 27488.410 2087.209 1315.000 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/09/ 4 ORIGIN : FLIC TAPE NAME : 97395 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, 1-31/M-21, ENDICOTT, 50-029-22562-00 LIS Tape- verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 27 **** REEL TRAILER **** SERVICE NAME : EDIT DATE · 97/09/ 4 ORIGIN : FLIC REEL NAME : 97395 CONTINUATION # : PREVIOUS REEL : COF~4~J~T : BP EXPLORATION, 1-31/M-21, ENDICOTT, 50-029-22562-00 LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 9 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~ SAMP ELEM CODE (HEX) DEPT FT 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 1064309 O0 000 O0 0 2 I 1 4 68 0000000000 TPHI TDTP PU-S 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN~TP CU 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 TClVD TDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 INFD ~DTP CPS 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 10 NAlV~ SERV UNIT SERVICE API API API API FILE NUMB NUb~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CCL TDTP V 1064309 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11133.500 SIGM. TDTP 24.947 TPHI. TDTP 42.610 SBHF. TDTP 37.344 SBHN. TDTP 43.194 SIGC. TDTP 0.611 SIBH. TDTP 43.194 TRAT. TDTP 1.942 SDSI.TDTP 1.028 BACK. TDTP 148.667 FBAC. TDTP 65.552 TCAN. TDTP 27131.828 TCAF. TDTP 9028.322 TCND. TDTP 17460.176 TCFD. TDTP 5086.940 TSCN. TDTP 3674.742 TSCF. TDTP 1222.798 INND. TDTP 1299.435 INFD. TDTP 320.098 GRCH. TDTP -999.250 TENS.TDTP 1370.000 CCL. TDTP 0.000 DEPT. 10549.500 SIGM. TDTP 15.087 TPHI. TDTP 16.572 SBHF. TDTP SBttN. TDTP 47.224 SIGC. TDTP 1.553 SIBH. TDTP 48.338 TRAT. TDTP SDSI.TDTP 0.374 BACK. TDTP 168.628 FBAC. TDTP 91.342 TCAN. TDTP TCAF. TDTP 21446.344 TCND. TDTP 22409.180 TCFD. TDTP 8496.262 TSCN. TDTP TSCF. TDTP 2978.552 INND. TDTP 1609.070 INFD. TDTP 364.830 GRCH. TDTP TENS.TDTP 1295.000 CCL. TDTP 0.000 33.822 1.482 43001.438 5972.208 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAt4~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUb~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. LIS Tape-verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 11 PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~4~U~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11126.0 10550.0 TDTP 11136.0 10550.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88885.5 11128.0 11125.5 11123.5 11121.5 11117.5 11116.0 11111.0 11110.5 11103.5 11105.5 11102.5 11102.0 11099.0 11098.0 11092.0 11092.0 11088.0 11088.0 11083.0 11083.5 11077.5 11080.0 11076.0 11077.0 11069.0 11070.0 11070.0 11065.0 11067.0 11062.0 11062.5 11061.5 11063.0 11053.0 11053.5 11046.5 11047.5 11037.0 11037.0 11034.5 11035.5 11027.5 11028.5 11027.0 11028.0 11011.0 11011.5 10999.0 11000.5 10994.0 10995.5 10963.0 10965.0 10955.0 10956.5 10945.5 10947.0 10939.5 10941.0 10933.0 10934.0 10934.0 10919.0 10920.5 10906.5 10908.0 10886.0 10888.0 10883.0 10884.5 10881.5 10882.0 10864.0 10864.5 LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11: 05 PAGE: 12 10863.5 10861.0 10849.5 10846.5 10844 5 10842 0 10840 0 10832 0 10825 5 10814 0 10813 5 10811 5 10809 5 10806.5 10800 5 10798 5 10791 0 10780 0 10777 0 10770 5 10768 5 10766 0 10762 5 10761 0 10757.5 10750.0 10741.5 10732.0 10728.5 10726.5 10721.5 10720.0 10718.0 10711.0 10709.5 10704.5 10701.5 10695.0 10694.5 10687.0 10682.0 10679.0 10675.0 10672.0 10667.5 10661.5 10659.0 10656.5 10652.5 10636.5 10626.0 10624.5 10620.0 10609.5 10599.0 10847.0 10844.0 10840.5 10814.5 10813.0 10809.5 10806.5 10798.5 10770.5 10769.0 10764.0 10752.0 10744.5 10727.0 10721.5 10718.5 10710.5 10694.0 10685.5 10671.5 10638.0 10628. 0 10600.5 10864.5 10862.0 10851.5 10842.5 10841.0 10831.5 10826.5 10815.0 10812.5 10799.5 10791.5 10780.0 10777.5 10772.0 10764. 0 10759.0 10733.0 10730.5 10721.5 10710.5 10704.5 10700.5 10693.5 10681.0 10678.5 10674.0 10671.5 10666.5 10660.5 10659.5 10657.5 10653.0 10636.0 10625. 0 10620.0 10610.0 LIS Tape 'verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 13 10586.0 10582.5 10564.0 10561.0 10558.5 10558.0 10556.5 10553.0 100.0 $ 10560.0 102.0 10587.0 10584.0 10565.5 10562.5 10560.0 10557.5 10552.5 99.5 ~S: THIS FILE CONTAINS TDTP FLOWING PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT FLOWING PASS #3 GRCH TO FLOWING PASS #1 GRCH; AND FLOWING PASS #3 SIGM TO FLOWING PASS #1 SIGM. ALL OTHER TDTP 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 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 ** NA~E SERV UNIT SERVICE API API API API FILE NUFiB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape 'verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 14 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C.L~tSS MOD NUIVlB SgMP ELE3I CODE (HEX) SBHF TDTP CU 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TCAlV TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1064309 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11133.500 SIGM. TDTP 23.047 TPHI.TDTP 37.852 SBHF. TDTP 35.881 SBHN. TDTP 43.560 SIGC. TDTP 1.656 SIBH. TDTP 43.560 TRAT. TDTP 1.887 SDSI. TDTP 0.843 BACK. TDTP 190.569 FBAC. TDTP 65.796 TCAN. TDTP 29375.770 TCAF. TDTP 10131.270 TCND. TDTP 19827.234 TCFD. TDTP 5862.041 TSCN. TDTP 4120.502 TSCF. TDTP 1421.100 INND. TDTP 1618.992 INFD. TDTP 365.311 GRCH. TDTP -999.250 TENS. TDTP 1430.000 CCL.TDTP 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NA~4~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 15 **** FILE HEADER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION ' O01CO1 mATE . 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUM~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 INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUM~ERS 1, 2, 3, TDTP THE ARITHMETIC AVERAGE OF THE FLOWING PASSES WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ 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 LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 16 TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CI. dtSS MOD ~ S~a24P ELt~.I CODE (HEX) DEPT FT 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 SIGMPNAV CU 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFPNAV CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 TCFDPNAV CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 IN-ND PNAV CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1064309 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11133.500 SIGM. PNAV 24.265 TPHI.PNAV 40.643 SBHF. PNAV SBHN. PNAV 43.986 SIGC.PNAV 0.974 SIBH. PNAV 43.986 TRAT. PNAV SDSI.PNAV 0.857 BACK. TDTP 67.297 FBAC. TDTP 24.125 TCAN. PNAV TCAF. PNAV 9841.486 TCND.PNAV 19261.820 TCFD.PNAV 5643.183 TSCN. PNAV TSCF. PNAV 1369.585 INND.PNAV 1537.550 INFD.PNAV 354.305 GRCH. TDTP DEPT. 10549. 000 SIGM. PNAV -999. 250 TPHI. PNAV SBHN. PNAV -999. 250 SIGC. PNAV -999. 250 SIBH. PNAV SDSI. PNAV -999. 250 BACK. TDTP -999 . 250 FBAC. TDTP TCAF. PNAV -999. 250 TCND. PNAV -999. 250 TCFD. PNAV TSCF. PNAV -999. 250 INND. PNAV -999 . 250 INFD. PNAV -999. 250 SBHF. PNAV -999. 250 TRAT. PNAV -999. 250 TCAN. PNAV -999. 250 TSCN. PNAV -999. 250 GRCH. TDTP 37.345 1.909 28930.379 4025.063 -999.250 -999.250 -999.250 -999.250 -999.250 217.000 ** END OF DATA ** LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 17 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUFk/M4RY VENDOR TOOL CODE START DEPTH STOP DEPTH 11152.0 10543.0 TDTP LOG HEADER DATA DATE LOGGED: 17-AUG- 97 SOFTWARE VERSION: CP 42.2 TIME LOGGER ON BOTTOM: 1627 17-AUG-97 TD DRILLER (FT) : 11181.0 TD LOGGER (FT) : 11133.0 TOP LOG INTERVAL (FT) : 10550.0 BOTTOM LOG INTERVAL (FT) : 11127.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VEJCDOR TOOL CODE TOOL TYPE CCL CALIPER TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER CAL-UB-299 TDTP SET 23 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 18 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 11265.0 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): PRODUCED FLUID 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 NEJL~ COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REFiARKS: CORRELATED TO ATLAS DIL/GR DATED 8-JUN-95. THIS FILE CONTAINS THE RAW TDTP DATA FOR FLOWING 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 5 66 6 73 7 65 LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 19 TYPE REPR CODE VALUE 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 ** NA~E 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 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PSi CU 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPSi CPS 1064309 O0 000 O0 0 5 1 i 4 68 0000000000 TCAFPS1 CPS 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 TCNDPS1 CPS 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 TCFDPS1 CPS 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1064309 O0 000 O0 0 $ 1 1 4 68 0000000000 TSCF PS1 CPS 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1064309 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11150.000 SIGM. PS1 SB~N. PS1 237.163 SIGC. PS1 SDSI.PS1 4.686 BACK. PSi TCAF. PS1 0.000 TCND.PS1 TSCF.PS1 0.000 INND. PS1 GR.PS1 20.266 CCL.PS1 21.161 TPHI.PS1 0.000 SBHF. PS1 103.157 0.000 SIBH. PS1 300.573 TRAT. PS1 0.000 -999.250 FBAC.PS1 -999.250 TCAN. PS1 0.000 -999.250 TCFD.PS1 -999.250 TSCN. PS1 0.000 -999.250 INFD.PS1 -999.250 TENS. PSi 1040.000 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 11:05 PAGE: 2O DEPT. 10543.000 SIGM. PS1 SBHN. PS1 45.506 SIGC.PS1 SDSI.PS1 1.366 BACK. PSi TCAF. PS1 7188.941 TCND.PS1 TSCF. PS1 603.740 INND.PS1 GR.PS1 221.250 CCL.PS1 34.342 TPHI.PS1 1.693 SIBH. PS1 127.970 FBAC. PS1 14180.523 TCFD.PS1 1259.051 INFD.PS1 0.000 49.877 SBHF. PS1 45.608 TRAT. PS1 83.675 TCAN. PS1 3716.683 TSCN. PS1 272.267 TENS.PSI 39.121 1.889 25322.684 1997.311 1275.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREME~VT : 0.5000 FILE SUMM_ARY VENDOR TOOL CODE START DEPTH TDTP 11152.5 $ 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) : STOP DEPTH .......... 10542.5 17-AUG-97 CP 42.2 1627 17-AUG-97 11181.0 11133.0 10550.0 11127.0