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194-049
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 3-19 DUCK IS UNIT SDI 3-19 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2025 3-19 50-029-22463-00-00 194-049-0 W SPT 9837 1940490 2459 2182 2090 2110 2095 164 385 381 375 4YRTST P Kam StJohn 6/7/2025 4 Year 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT SDI 3-19 Inspection Date: Tubing OA Packer Depth 457 2744 2697 2681IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250607162749 BBL Pumped:4.5 BBL Returned:4.5 Friday, July 25, 2025 Page 1 of 1 MEMORANDUM To: Jim Regg P.I. Supervisor 2�1' FROM: Guy Cook Petroleum Inspector Well Name DUCK IS UNIT SDI 3-19 Insp Num: mitGDC210622120714 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 22, 2021 SUBJECT: Mechanical Integrity Tests Hilcoip Alaska, LLC 3-19 DUCK IS UNIT SDI 3-19 Src: Inspector Reviewed By: P.I. Supry y Comm API Well Number 50-029-22463-00-00 Inspector Name: Guy Cook Permit Number: 194-049-0 Inspection Date: 6/22/2021 Well 3-19 Packer iType Inj W '-;TVD Depth 9837 Tubing' Pretest Initial 15 Min 30 Min 45 Min 60 Min 2198 2262 2263 223t - PTD 1940490 -,'Type fest SPT Test psi 2459 IA 1407 3002 2990 298 BBL Pumped: 2 3- BBL Returned: 2.3 ' OA 160 - 300- 300 _ 300 Interval 4YRTST [P/IF P Notes: Testing done with a tripex pump, bleed trailer and calibrated gauges. ✓ Tuesday, June 22, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,June 29,2017 Jim Regg P.I.Supervisor 4tet 711(i7 7 SUBJECT: Mechanical Integrity Tests • HILCORP ALASKA LLC 3-19 FROM: Lou Laubenstein DUCK IS UNIT SDI 3-19 Petroleum Inspector Src: Inspector Reviewed By: P.L Supry-See— NON-CONFIDENTIAL Comm Well Name DUCK IS UNIT SDI 3-19 API Well Number 50-029-22463-00-00 Inspector Name: Lou Laubenstein Permit Number: 194-049-0 Inspection Date: 6/26/2017 ✓ Insp Num: mitLOL170627055316 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3-19 'Type Inj W "TVD 9837 - Tubing 2255 2249 - 2243 - 2254 - PTD 1940490 Type Test SPT Test psi 2459 IA 1050 2595 - 2580 - 2576 - BBL Pumped: 2.5 - BBL Returned: 2.4 - OA 180 • 300 _ 300 300 Interval 4YRTST P/F P ✓ --- Notes: I't'S�—Glume 6170‘i SCANNED AUG 2 22Q17 Thursday,June 29,2017 Page 1 of 1 • • RECEIVEDPost Office Box 244027 /� �Lgy Anchorage,AK 99524-4027 Hilcorp Alaska,LLC U V 3 :' 3800 Centerpoint Drive Suite 100 AOG CC Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777.-8301 July 29, 2015 Commissioner Cathy Foerster - 04-q Alaska Oil & Gas Conservation Commission J' 333 West 7th Avenue, Suite 100 \L1n-3,- p 7 Anchorage, AK 99501 Re: Duck Island Unit Well Renaming Request $CANN U 2 16 Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD# 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp • Orig • New API_WeIINo I PermitNumber' WellName I WellNumber I I WellNumber 50029219460600 2032160 DUCK IS UNIT SDI 3-17F/K30 3-17F 50029224630000 1940490 DUCK IS UNIT SDI 3-19/R28 3-19 50029217140000 1870330 DUCK IS UNIT SDI 3-21/L34 3-21 50029217149500 1980190 DUCK IS UNIT SDI 3-21AK35XX 3-21AXX 50029216450000 1861550 DUCK IS UNIT SDI 3-23/N32 3-23 50029221250000 1901820 DUCK IS UNIT SDI 3-25/M27 3-25 50029221250100 2010200 DUCK IS UNIT SDI 3-25A/N24 3-25A 50029221250200 2030210 DUCK IS UNIT SDI 3-25B/L27 3-25B 50029215860000 1860830 DUCK IS UNIT SDI 3-27/M33 3-27 50029221060000 1901560 DUCK IS UNIT SDI 3-29/132 3-29 50029228380000 1972270 DUCK IS UNIT SDI 3-31/K32 3-31 50029216680000 1861800 DUCK IS UNIT SDI 3-33/K37 3-33 50029216680100 2032150 DUCK IS UNIT SDI 3-33A/J35 3-33A 50029217010000 1870200 DUCK IS UNIT SDI 3-35/L36 3-35 50029225540000 1950510 DUCK IS UNIT SDI 3-37/L35 3-37 50029217640000 1871160 DUCK IS UNIT SDI 3-39/J39 3-39 50029217640100 1970910 DUCK IS UNIT SDI 3-39A/I37 3-39A 50029218780000 1881260 DUCK IS UNIT SDI 3-41/139 3-41 50029224160000 1931700 DUCK IS UNIT SDI 3-43/P36 3-43 50029218110000 1880510 DUCK IS UNIT SDI 3-45/M39 3-45 50029215690000 1860640 DUCK IS UNIT SDI 3-47/Q35 3-47 50029217350000 1870600 DUCK IS UNIT SDI 3-49/140 3-49 50029217350200 1970570 DUCK IS UNIT SDI 3-49A/M40 3-49A 50029217359500 1950350 DUCK IS UNIT SDI 3-49A140XX 3-49AXX 50029217890000 1880220 DUCK IS UNIT SDI 4-02/028 4-02 50029219680000 1890860 DUCK IS UNIT SDI 4-04/T26 4-04 50029219680100 2090190 DUCK IS UNIT SDI 4-04A/T30 4-04A 50029217230000 1870430 DUCK IS UNIT SDI 4-06/Q32 4-06 50029217230100 1961660 DUCK IS UNIT SDI 4-06A/030 4-06A 50029216920000 1870080 DUCK IS UNIT SDI 4-08/P27 4-08 50029224640000 1940500 DUCK IS UNIT SDI 4-10/M28 4-10 50029224640100 2022380 DUCK IS UNIT SDI 4-10A/L28 4-10A 50029218630000 1881040 DUCK IS UNIT SDI 4-14/R34 4-14 50029218630100 2080120 DUCK IS UNIT SDI 4-14A/S-37 4-14A 50029218960000 1881490 DUCK IS UNIT SDI 4-18/S30 4-18 50029216400100 1861730 DUCK IS UNIT SDI 4-20/1v135 4-20A 50029216400000 1861500 DUCK IS UNIT SDI 4-20/T34 4-20 50029218350000 1880720 DUCK IS UNIT SDI 4-26/034 4-26 50029218700000 1881110 DUCK IS UNIT SDI 4-28/N37 4-28 50029225590000 1950690 DUCK IS UNIT SDI 4-32/K38 4-32 50029227050000 1961550 DUCK IS UNIT SDI 4-34/038 4-34 50029224820000 1940740 DUCK IS UNIT SDI 4-38/K34 4-38 50029222650000 1920420 DUCK IS UNIT SDI 4-40/P43 4-40 50029217310000 1870560 DUCK IS UNIT SDI 4-42/P38 4-42 50029222540000 1920190 DUCK IS UNIT SDI 4-44/M44 4-44 50029222549500 1970470 DUCK IS UNIT SDI 4-44AM40XX 4-44AXX 50029219570000 1890690 DUCK IS UNIT SDI 4-46/N39 4-46 50029219720000 1890970 DUCK IS UNIT SDI 4-48/K43 4-48 50029219400000 1890440 DUCK IS UNIT SDI 4-50/K41 4-50 .', XHVZE Pages NQT Scanned in this Well History File 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. /~/~/~/7/~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] . Diskettes, No. [] Other, No/Type OVERSIZED . . 0. Logs of vadous kinds [] Other COMMENTS: Scanned bY': Bevedy Dianna(~~athan Lowell Date: [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • 4 • • 1. , OF O ������s 9 THE STATE Alaska Oil and Gas ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O TR:' Anchorage, Alaska 99501 -3572 ALAS P Main: 907.279.1 433 2'°13 Fax: 907.276.7542 SCANNED MAR 15 David Reem Engineering Team Leader /� BP Exploration (Alaska), Inc. 1 �-t' V ` J P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Endicott Field, Endicott Oil Pool, 3- 19/R -28 Sundry Number: 313 -007 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7 _ Cathy P. oerster Chair DATED this ? J 1 s4 day of January, 2013. Encl. . STATE OF ALASKA gl, RECEIVED ALASKA OIL AND GAS CONSERVATION COMMFION I Al �✓ G APPLICATION FOR SUNDRY APPROVAL y' JAN 0 Z 13 20 AAC 25.280 3 1. Type of Request: C ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Convert to WIND 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 194 -049 • 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 22463 -00 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? planned perforations require a Spacing Exception? 3- 19/R -28 Will p p q p g p 0 No 9. Property Designatior 10. Field / Pool(s): ADL 047502 Endicott Field / Endicott Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft)• Effective Depth TVD (ft): Plugs (measured): Junk (measured). 13152' ' 10370' •13030' 10271' 11834' Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 30" 40' - 130' 40' - 130' Surface 2684' 10 -3/4" 42' - 2726' 42' - 2667' 5210 2480 Intermediate 13101' 7 -5/8" 41' - 13142' 41' - 10362' 8180 5120 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 12666' - 12929' 9977' - 10190' 3 - 1/2 ", 6.73# / 9.2# HS - 70 / L - 80 11863' Packers and SSSV Type: 3 TRDP SSSV Packers and SSSV 1497' / 1488' 7 - 5/8" x 3 - 1/2" Baker FB - 1 Packer MD (ft) and TVD (ft): •11810' / 9320' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal • ® BOP Sketch 0 Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation February 15, 2013 ❑ Oil ,® WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin, 564 -4387 Printed Name: D jd Reem Title: Engineering Team Leader Email: Sean.McLaughlin @bp.com Signature: Phone: 564 - 5743 Date: !_fib _20/3 4 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ❑ Plug Integrity ta'BOP Test Mechanical Integrity Test ❑ Location Clearance 1 F ier MS FEB 01 it Other: �U P - ! G'�� to 35"� � �� s r ,' j / rlA- re-it/iv-Ed u r S/ 617 / icS In cf n i` V / �i - ac f. op ci, t/ vv� cI cr' ,4X0 o2/. `� c 00C , Spacing Exception Required? ❑ Yes iNo Subsequent Form Required: /0 -4-04- / / APPROVED BY Appr ved By: / CO MMISSIONER THE COMMISSION Date: /- 3/— /3 For OR Its d 0 r's A pprove d app i s v 'd for 12 months from the date of approval Submit In Duplicate �,,, • • bp Sundry Request: Convert well to water injector and swap tubing Well: END 3 -19 Date: 01/06/2013 Engineer: Sean McLaughlin MASP: 2257 psi Well Type: Injector Estimated Start date: February 15 2013 History: Well 3- 19/R -28 was drilled and completed in June 1994 in the FII, FIII, FIV and FV subzones. The well produced at high watercut from the initial pop and two water shut off squeezes were performed on the FII with no success. The well was shut in from 1995 to December 1998 when it was pop'd and perforations added in the Fill in 1999 which also proved to be high watercut. The well produced through February 2001 before being classified as not operable with pressure communication from the tubing to the inner annulus in August 2001 which caused the well to remain shut -in pending remediation of the annulus communication. Pack off testing passed in October of 2008, indicating the communication is down hole. A 2001 caliper indicated the coiled tubing completion was in good condition with isolated pitting (35 %) at 8811' right above GLM4 and significant ovality above each GLM and at the bottom of the coil from 11550' to 11770,' as well as corkscrew buckling of the pipe. A 2009 caliper showed similar results. Sundry number 309 -315 was approved 9/21/2009 to patch the tubing and convert the well to a produced water injector. The well then failed CMIT -TxIA tests 9/25/2009 with plugs set below known leak depths, indicating more holes in the tubing. A second attempt was made in September 2010 to set plugs below possible leak depths picked from the leak detect log run in March 2009 which again failed CMIT - TxIA's. The well passes CMIT - TxIA's with a TTP set in the tailpipe. Due to the poor shape of tubing and being unable to find all tubing holes to patch, a RWO is required to restore tubing integrity. Scope of Work: Pull 3 -1/2" coiled tubing completion. Remove packer and tailpipe. Run 4 -1/2" L -80 completion. Pre Rig Prep Work: S 1 Drift for jet- cutter to '11800'md. F 2 CMIT -T x IA to 3,500 psi. MIT -OA to 2,000psi. Record LLR as necessary. W 3 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. E 4 Power Jet cut the 3 -1/2" 9.2# pup -jt just below the bottom GLM (the FB -1 packer will be milled up during RWO). (Reference Doyon -15 /Nowcam 4907 tubing tally of 5/4/94) Post cut CMIT -TxIA to 1,000 -psi. Circulate the well to seawater. ✓ 5 Set a BPV in the tubing hanger. Secure well. O 6 Remove the well house & flow line. Level the pad as needed for the rig. Will likely require two well houses on either side of End3 -19 to be removed as well ... Doyon-14's Tool- pusher and WSL to confirm. C�7�i L W��� �J �a"v05 � l l D (ti��e� CUt . Conte/ i /1e� 7 c� w �/��✓ (_Unc,u/'. / V e C ft�� S4iorrlo ( fr o ,, IeCC - b04 74 ,,�� . t" • • Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 3- 1/2" x 6" VBR's, blind shears, mud cross and 3 -1/2" x 6" VBR's). Test the VBR's and annular to 3,500 psi. . /Vo h f 4 cc 24- lir5 a i a ; 2. Pull and lay down coiled tubing to the jet cut. 3. Fish the bonded seals out of the packer. 4. Mill and retrieve packer and tailpipe. 5. Scrape 7 -5/8" casing. 6. Swap mandrel inner casing pack off. 7. Run 7 -5/8" test packer to 12,550' and test casing to 3,200 psi. 3° fr".'''''''/I C ha • State to witness MIT 8. Run new 4.5" L -80 completion with 7 -5/8" x 4 -1/2" HES TNT packer. MIT -T & MIT -IA to 3200 psi. • SSSV at -1,500' • Packer set at 12,490' (within 200' of top perforation) 9. Set a BPV and RDMO. Post rig Work S 1 Pull ball -n -rod, pull RHC seat O 2 Install well house, S riser and instrumentation S 3 Install SSSV, POI W 4 MIT -IA w /AOGCC post -POI Isolation Information A Segmented Bond Log run in 01- Jun -94 shows 16' of good cement (12,650'- 12,666') directly above the top perforation and above the proposed injection interval. 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I M VIII ...MME N111 1111111111111 j 1111111 - _ i _.., II IRI�11ii111111IIYtI1I11111LV B1!lIIU111UI .ii'i0U11U1h1!1•111 1111111111111111111111111111111111111 �1��1� 1 _ 11. 1. 1 .111111111111111111111 11111r► _- ... lI 11� 1R1 �11111111111111i 111111 1I1111111111!11111 11111111111111111111111111111111111111 !111111111111111I i 11111111111111111111111111111111111111 111111111111111111 111111111111111111111111111111111111111 111111111111111111 I1U IRI1•IINIIII11111111111111 111111111111111111 ' 1 12300 12400 11111 1111111111IIIU111 11111111: 11111111111111111111111111111 11. 1IIr11111111n111111n1 ' 11111111111111411111111 i111i11:i 11111111111111► J1111111h111111111111i�11111111111111 i 111 .1i111111111111111111h11111111 1 111111111 1111111111, 1111111111111111111111 0511111111111111111111111 _111111111111111111111111 i11111111111111N1 Il 11111111ii111i 111111111111111111111111111111111111111111111111 } 111111111111111111111111111111111 L111L'ill111 1111111111115111111111111111111111111111111111111111111114111 I 111111111111111111/111 1111111' 1111111 11II111111111111111111111111�111n11i11111Dt11 ' 111111111111iii1111L!1111 ttlMIO1111111111111 111111111111111' 111�11111l111111111111I1111111PP1 15i'11►4IL11�Y' lHI111II111 1111/1111 �111111111rillllii1111 il11 �1�1111111111�1ii1111111111111111111111111111111111111111 11111111111111111111111111111111111111111R IN 11151111111;11111$11111111111111111111111111111111111111111111 . 1 'I!!i :11%11111111il 1111111111111111111111 II 1 • ID Area of Review - Endicott DIU 3- 19/R -28 (194 -049) Current Status End 3- 19/R -28 is a gas lifted oil producer with TxIA communication that has been shut in since 2001. The TXIA communication was noted while pulling out of the hole on a slick -line operation in 19- Ju1-07. Subsequently in 23- Jul -07 an MIT -IA failed with 2 bpm at 3,000 psi from tubing to inner annular space and a CMIT T -IA passed. A caliper ran in 22- Feb -09 indicated the tubing was still in good condition and a patch drift was successfully completed in the same job. Recently in 6- Mar -o9 a LDL confirmed leaks at 8,787' and 8,99o' MD. The reservoir management plan forward is to convert END3-19 to Upper Sub Zone (USZ) water injection as a replacement for former water injector 4 -04 /T- 26. Completion 3- 19/R -28 (PTD 194049 completion crossed the Kekiktuk formation at 12,615' MD; the production packer is 805' above the top Kekiktuk at 11,810' and the tubing tail is 753' above the top Kekiktuk at 11,862'. A 7 5/8" casing was run from surface to TD at 13,142'MD. It was cemented with 227 bbls Econolite 11.1 ppg Cement and 61 bbls of 15.8 ppg class "G" cement with no recorded losses. A Segmented Bond Log run in o1- Jun -94 shows a minimum of 34 ft of isolating cement behind the 7 5/8" casing above the proposed injection zone in interval 12,326'- 12,36o'. It also shows good cement at 12,650'- 12,675' interval to contribute on zonal confinement. The Fv, Fiv, Fiii and Fii are perforated and contributing in the current completion of the well. The lower Fii intervals 12,929'- 12,940' and 12,945' - 12 ,9 6 5' were perforated but squeezed in Jan 1995. • • FV Structure Map illustrating the AOR 1 ta `s 4O .3? • i1nN,• 11, $ � �' ' " :aatrtNrat , 4 t '' A� . t �' • 4900 t bt16N.'7f Y1IKb R " J watas , . atoxx 7 f .per ) t.orj..n * :' • - '. °atT i n' ' '*,, .a...��" .. � ,, ' 'vim �T3 `ti, a a+r. "''� -'103 `* i tUt K .. t '`' -f 4aNat a..c _«wn • 1i _` .{x.35 " FV Structure Grid (2005) i Depth 11,5i -17/4 .1trit7 - 9920 4505 ',.. 2000 0 2000 4000 6000 R Fl Tops 1 :27529 • FV Tops TREE= 4 -1/16" CTV1/ • SA NOTES: H2S READINGS AVE32AGE230 - 260 • WBLI EAD = 13 5/8" FMC END 3 -19 PPM ON AL & GAS INJECTORS'"` WELL REQUIRES ACTUATOR = BAKER A SSSV*** TBG NOT ANCHORED ""' RKB. BE/ = 55.8" I I BE REV = 14.5" KOP = 7? ' 1497' — 3-1/2" TRDP SSSV NIP, D = 2.812" Max Angle = 46° @ 8327' (FLAPPER TYPE VALVE), LOCKED OUT Datum ND= 12765' (10/30/12) Datum 10000'SS GAS LET MANDRELS I 10 -3/4" CSG, 45.5#, NT8OS BTC, — I 2726 ST MD I TVD DEV TYPE VLV LATCH PORT DATE 111 6 3840 3566 41 CA DMY RK 0 07/08/07 5 6684 5675 44 CA DMY RK 0 09/01/01 4 8966 7286 45 CA DMY RK 0 07/08/07 3 10114 8099 44 CA DAY RK 0 07/08/07 3-1/2" COL SPLICE, 92#, L -80, ID= 2.99" (14') —) 5136' 2 11098 8814 44 CA DMY RK 0 09/10/94 1 11775 9295 46 CA DMY RK 0 09/01/01 3 -1/2" TBG, 6.73 #, HS -70 CM, H 11785' .0095 bpf, D = 3.12" 11795' H 3-1/2" HES X NIP, ID = 2.75" 11807' BKR GHB -22S LOCATOR & Minimum ID =2.75" @ 11795' BONDED SEAL ASSY,10 =2.99" 3-1/2" HES X NIPPLE 2 i �/ 11810' H 7 -5/8" X3 -1/2" BKRFB -1 PKR, ID= 4.00" 11813' —I BKR SEAL BORE EXTENSION, D = 4.00" El 11834' —13-1/2" FES X Nom, D = 2.75" 11834' - 13 -1/2" PX PLUG (11/06/12) 3-1/2" TBG, 9.2#, L -80 NSCT, H 11863' (` 11855' — I3 - 1/2" HES X NP, D = 2.75" .0084 bpf, D = 2.94" PERFORATION SUMMARY \ REF LOG: LWD - CON ON 05/28/94 11863' —13-1/2" WLEG, D = 2.94" ANGLE AT TOP PERF: 36° @ 12666' 11862' H E3_MD LOGGED ON ? ? / ? ? / ?? Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL OPN/SQZ DATE 12541' I -17 -5/8" MARKER JONT 2 -1/8" 4 12666 - 12724 0 06/29/95 I 1- 11/16" 4 12766 - 12772 0 08/11/99 2 -1/8" 4 12775 - 12782 0 06/20/95 ' ' ? —I FISH - 4 SPINNER BLADES (01/07/99) 1- 11/16" 4 12788 - 12814 0 08/11/99 ' 1- 11/16" 4 12822 - 12828 0 08/11/99 2 -1/8" 4 12842 - 12848 0 06/05/95 ' 1- 11/16" 4 12894 - 12898 0 08/11/99 ' 2 -1/2" 4 12924 - 12929 0 02/10/95 2 -1/8" 4 12924 -12940 S 01/09/95 2 -1/2" 4 12924 - 12944 S 01/09/95 a 2 -1/2" 4 12929 - 12944 S 01/12/95 ' 2 -1/8" 4 12945 - 12965 S 01/12/95 I I PBTD —I 13066' I - v . - 4 - • - ∎ 13030' ELMD H TD 7 -5/8" LNR, 29.7 #, NT -95HS NSCC, — I 13142' "••• ipA .. 0459 bpf, ID= 6.875" �•�••••••�•• DATE REV BY COMMENTS DATE REV BY COM EN TS ENDICOTT UNIT 06/26/94 D15 ORIGINAL COMPLETION 02/02/12 PJC DRAWING CORRECTIONS WELL: 3-19 / R-28 10/07/09 PJC CONVERT TO CANVAS 02/03 /12 VVECJ PJC DRAWING CORRECTIONS PE2MT No: 1940490 09/22/10 SVVC/PJC PULL PX FLUG (09/11/10) 11/20/12 DLW /JMD LOCKED OUT SSSV /PULL PLUG (10/30/12) API No: 50- 029 - 22463 -00 09/22/10 SWC/PJC SET PX RUG (09/14/10) 11/20/12 RCT /JMD RESET PX RUG (11/06/12) SEC.8, T11 N, R17E, 2524' FNL & 789' FEL 02/17 /11 MB/JMD SSSV SAFETY NOTE 08/15/11 DW /JMD FPS SAFETY NOTE BP Exploration (Alaska) TREE= 4 -1/16" CIW J ELLFEAD = 13 - 5/8" FMC nu r b: rubi KLAUI w AV t gtlat L3u - Lbu ACTUATOR = BAKE C E ND 3 -19 PPM ON A/L & GAS INJECTORS WELL REQUIRES A RKB. REV = 55.8" SSSV. *** TUBING NOT ANCHOR *** WARNING: 3F. ELEV = — 14.5" Proposed RWO I I MAINTAIN 5000 PSI ON CONTROL LINE DURING WELL — APFRA TIf)N *** KOP = Max Angle = 46° 9 @ 7572" 7ratum 12764' ®-... 1 1 - -- 4 -1/2" SSSV, ID= 3.813" — 1,500' DatumTVD= 10000'SS 10 -3/4" CSG, 45.5 #, NTBOS BTC H 2726' A 1 Minimum ID = 1 1 4 -1/2" X NIP, ID= 3.813" 4 -1/2 x 7 -5/8" HES TNT Packer X ID= 3.88" @ 12,490' 4 -1/2" Tbg, 12.6 #, L -80 TCII 1 1 4 -1/2" X NIP, ID= 3.813" 0.152 bpf, ID= 3.958" @12,620' 1 1 4 -1/2" XN NIP, ID= 3.725" 12541' H 7 -5/8" MARKER JOINT / PERFORATION SUMMARY REF LOG: LWD - CDN ON 05/28/94 ANGLE AT TOP PERF: 36° @ 12666' Note: Refer to Production DB for historical pert data ???? H FISH - 4 SPINNER BLADES (01/07/99) SIZE SPF INTERVAL OPN/SQZ DATE * 2 -1/8" 4 12666 - 12724 0 06/29/95 1- 11/16" 4 12766 - 12772 0 08/11/99 2 -1/8" 4 12775 - 12782 0 06/20/95 1- 11/16" 4 12788 - 12814 0 08/11/99 1- 11/16" 4 12822 - 12828 0 08/11/99 O 2 -1/8" 4 12842 - 12848 0 06/05/95 1- 11/16" 4 12894 - 12898 0 08/11/99 2 -1/2" 4 12924 - 12929 c 0 02/10/95 CI 2 -1/8" 4 12924 - 12940 S 01/09/95 ' 2 -1/2• 4 12924 - 12944 S 01/09/95 , 2 -1/2" 4 12929 - 12944 S 01/12/95 2 -1/8" 4 12945 - 12965 S 01/12/95 I I 13030' ELMD H TD _iiiiiiii�i. PBTD 13066' e'"- e • • " "' •�i�i�i�i�i�i�i 7 -5/8" CSG, 29.7 #, NT -9511S USCG, H 13142' .•■•■•■• •■•■•■•■•' 77777 hpf r). DATE REV BY COMMENTS DATE REV BY COMMENTS E NIDICOTT UNIT 06/26/94 D15 ORIGINAL COMPLETION 09/22/10 SWC/PJC PULL PX PLUG (09/11/10) WELL: 3-19 / R-28 03/18/08 JIMTLH PLUG CORRECTION 09/22/10 SWC/PJC SET PX PLUG (09/14/10) PEDW(T No: ° 1940490 10/01/09 BSE/SV PULL TIP (09/27/09) 02/17 /11 MB/JND ADDED SSSV SAFETY NOTE AR No: 50- 029 - 22463 -00 10/04/09 ? /PJC SET PX RUG (09/27/09) 07/08/11 AW /JM) PROPOSED RWO 2524' FNL & 789' FE 10/04 /09 RGPJC FISH (01/07/99) 10/07/09 PJC CONVERT TO CANVAS BP Exploration (Alaska) RIG FLOOR 33.7 ' AGL n I 00 �W� VALVE LEGEND � �� ©�© ©TAZin 1 BYPASS i I 2 KILL rt- 3 CHOKE 4 BOTTOM RAMS /J 5 BLIND RAMS c\ P 6 TOP PIPE RAMS • in ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION 7 ANNULAR 13 5/8', 5000 PSI, HYDRIL ANNULAR BOP, TRIPLEX PUMP: 575 VAC, 30 HP STUDDED TOP /FLANGED 801108 AIR PUMP: 1, NL SHAFFER O O O -- RANGED TOP 'M E i MM. 13 5 /8', 5000 PSI, 10' MPL OPERATORS, HYDPoL PIPE RAM 3 1/8" 5000 PSI SIDE OUTLET \ 111111111 giNEEEMI=EDMEEMEIEMIKEMEMEME3 � 3" CHOKE UNE .0111 IIM • HY 13 5/8", 5000 PSI, 14' MPL OPERATORS, C OPoL BLAND SHEAR RAM Q [ - : : _ _ - - BY PASS • • STUDDED BOTTOM BX 160 ■ N El 3 1/8" 5000 PSI HER VALVE • 1500 3000 U , a: 111 I II , /III.II, 1II ■L 1II' 2" KILL UNE / 3 I/O" 5000 PSI GATE VALVE :. • • A — CLOSE 3 1/8' 5000 PSI HER VALVE) / N • • 3 I/O" 5000 PSI GATE VALVE �� " KIII •M.11111111W SINGLE 13 5/8", 5000 P51, 10" NPL OPERATORS, r ` D ri n' ^ ^ / H PIPE RAM I n — ' 8"T n 811 I • • Mill ACCUMULATOR BOTTOM/FLANGED TOP ex 180 ACCUMULATOR MANIFOLD ' EI 0 :... - POW - 1 0. 4I _ +- as -1 18 BOTTLES, 10 GALLONS EACH • I • ,, .. I RIIN __ • • M — OPEN CLWL c \ • • CHOKF BOP STACK ELEVATION [ = : - REMOTE PANEL IN DOGHOUSE • I 1 I AND UTII ITY MODULE =g ------ NITROGEN BACKUP BOTTLES 21 1/4', 2000 PSI, 18' 150 P51 HYOR. NSP HYDRIL BOP /DIVERTER OPERATED KNIFE GATE VALVE ■ STUDDED TOP /FLANGED BOTTOM 1" C/W PLUG 11■1111111=1 FLANGE /FLANGE RX 73 a lIR w A PPOPKflan NU 1 70 001 A 81,10 AA xsal w POwusaE NU s xmlolmn x er oorox 16' FWD VENT UNE ///��� \� - -- - -- --- �� o1 /te /ae 5 - -- --- \ \ I J J 136/13 LEA W WTE BOP STICK IDI �� P1 801 RIG 14 __ 03/05/01 A OVB LEA UPDATE BOP STACK ■■ GE 01/31/00 3 owe LEA ME 04080/511J. IVES 11RE BOP SYSTEM 12 -20-0C 2 DM LEA LIME VP STAG! AND CONTROL SURFACE DIVERTER CONFIGURATION 11 -28-90 I J111 £8 OWN TO wow D ii 28/98 CNE RPR � *PROM °Y LEA �'5 001 E W V 'Er 0°0RP1p1 NTS JTHH .8. 14BOPSYS&CONTROL 1 r age 1 U1 1 • • Schwartz, Guy L (DOA) I °P(/- OLfq From: Schwartz, Guy L (DOA) Sent: Wednesday, January 09, 2013 4:03 PM To: ' Lastufka, Joseph N'; Fisher, Samantha J (DOA) Cc: Igwe, Josiah; McLaughlin, Sean M; Ramos, Tania ((Udelhoven Oilfield System Services (UOSS)) Subject: RE: PTD #194 -049 Will do ... Consider 309 -315 withdrawn. Guy Schwartz AHNW APR 1 2 13 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Lastufka, Joseph N [mailto:Joseph.Lastufka @bp.com] Sent: Wednesday, January 09, 2013 3:39 PM To: Schwartz, Guy L (DOA) Cc: Igwe, Josiah; McLaughlin, Sean M; Ramos, Tania ((Udelhoven Oilfield System Services (UOSS)) Subject: PTD #194-049 Guy, Please withdraw sundry number 309 -315 for 3- 19/R -28 PTD #194 -049. We will be submitting a new sundry later this week / early next week to replace it. Please let me know if you have any questions. Thank you, Joe Lastufka Alaska Wells Technologist Cell: (907) 227 -84961 Office: (907) 564 -4091 x Description: Description: custom %2Oheader BP Exploration AlaskaI900 E. Benson Blvd.IRoom: 788DIAnchorage, AK 1/9/2013 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 22, 2012 f'12. Mr. Jim Regg a / " (- kg Alaska Oil and Gas Conservation Commission i 333 West 7 Avenue � 3 ! F Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Endicott Row 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from Endicott Row 3 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, / Mehreen Vazir BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Endicott Row 3 Date: 10/03/10 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 END3-01 / N -29 1861900 50029216780000 7.0 4.4 0.3 9/6/2010 1.70 10/3/2010 END3-03 / J-33 1921210 50029223060000 8.0 6.1 0.3 9/6/2010 2.55 10/3/2010 END3 -05 / 0 -29 1861300 50029216240000 3.0 2.0 0.5 9/6/2010 3.40 10/3/2010 END3-07A / L -29 1981470 50029219110100 2.0 0.5 0.3 9/6/2010 1.70 10/3/2010 END3 -09 / L -28A 1950190 50029217800100 0.1 NA 0.1 NA 1.00 10/3/2010 END3 -15 / K-33 1870940 50029217510000 0.1 NA 0.1 NA 1.00 10/3/2010 END3 -17F / K-30 2032160 50029219460600 1.5 0.5 0.5 9/6/2010 2.55 10/3/2010 ,--4 END3 -19 / R -28 1940490 50029224630000 10.0 17.0 0.3 9/6/2010 1.70 10/3/2010 END3 -21 / L -34 1870330 50029217140000 23.0 14.5 1.1 9/6/2010 13.60 10/3/2010 END3 -23 / N -32 1861550 50029216450000 1.5 1.0 0.5 9/6/2010 3.40 10/3/2010 END3 -27 / M -33 1860830 50029215860000 1.0 0.1 0.6 9/6/2010 2.55 10/2/2010 END3 -29 / J-32 1901560 50029221060000 2.0 1.0 0.6 9/6/2010 3.40 10/2/2010 END3 -31 / K -32 1972270 50029228380000 2.0 3.0 0.5 9/6/2010 3.40 10/2/2010 END3 -33A / J -35 2032150 50029216680100 0.5 NA - 0.5 NA 3.40 1012/2010 - END3 -35 / L -36 1870200 50029217010000 10.0 7.0 0.4 9/6/2010 3.40 10/2/2010 END3 -37 / L -35 1950510 50029225540000 8.0 7.3 0.3 9/6/2010 1.70 10/2/2010 END3 -39A /1-37 1970910 50029217640100 1.0 0.8 0.7 9/6/2010 3.40 10/2/2010 END3 -49A / M-40 1970570 50029217350200 0.4 NA 0.4 NA 1.70 10/2/2010 ~ ~' ~ ~ c, a~ - ev~, {k ~.`@ ~ ~ ~~ P '~ ~ ~ ~ ~ ~ ~~ ~" ~~ '~ '~ ~ °`~ ~ ~ ~ ~C E6 ~ ~ ~,~ k ~ ~~', ~ ~ ~ ~ ' ~k N 6~ ~ # yf ~~ ~ ~ ~ ~ ~ ~ y 5 ,; ~ ~ ~ gR ~~~~ ~~ ~ ~ 4 n 4~ ~.,~,~ ~ ; ~~ ~ ~~ < u ~ ~ ~ e~i , F y g @ ~ A P ` g ~~a v3 ~ °'ii ~ ~fi ,+, ~ ~ ~..~.~.~ ~ ~ a, f ~ ~ ~ g ~! ,y n . ~ ~,.~ '~.4' ~.~ ALASSA OIL A11TD G~S CO1~T5ERQATIOl~T CODIl-IISSIOr1T Mr. Jose Soto Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Endicott Field, Endicott Oil Pool 3-19 / R-28 Sundry Number: 309-315 ;~~ ~~. ~a : ~ ~~T Dear Mr. Soto: ~ .. ~~ `~~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, S~ Daniel T. Seamount, Jr. Chair DATED this~f day of September 2009 • s~ y n~ ~ SEAN PARNELL, GOVERNOR ~ ~ 333 W. 7th AVENUE, SUITE 100 ~' ANCHORAGE, ALASKA 99501-3539 x PHONE (907) 279-1433 ~ FAX (907) 276-7542 Encl. _ _ _ , ~~ "`"~ , .» ~,~+'~~ y~y ~ ~ STATE OF ALASKA ~ 9 f,j.Of , ~,..; ' " ALASKA L AND GAS CONSERVATION COMMIS - ~ `~' ~ =~ ~ APPLICATION FOR SUNDRY APPROVALS ~n nnr. ~~ ~Rn _ . ,. ,_. _ _ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ^ Other ^~ Alter casing ~ Repair well ~ Plug Perforations ~ Stimulate ~ Time Extension ~ TUBING PATCH Change approved program ~ Puli Tubing ~ Perforate New Pool ~ Re-enter Suspended Well ~ _ CONVT TO WI 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ M Exploratory ~ 194-0490 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22463-00-00~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or iandownership changes: Spacing Exception Required? Yes ^ No ^ 3-19/R-28- 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADLO-047502 - 55.8 KB ~ ENDICOTT Field / ENDICOTT OIL Pool ~ 2• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13152 - 10370.14 13066 10300.52 NONE NONE Casing Length Size MD ND Burst Collapse Structural Conductor 90 30" Surface 130 Surface 130 Surface 2684 10-3/4" 45.5# NT-80 Surface 2726 Surface 2611 5210 2480 Intermediate 13101 7-5/8"29.7# NT-95HS Surface 13142 Surface 10306 8180 5120 Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 3-1/2" 9.2# L-80 Surface -11863' Packers and SSSV Type: Baker FB-1 PKR Packers and SSSV MD (ft): 11810' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ~ BOP Sketch ~ Exploratory ~ Development ^ Service ^~ - 15. Estimated Date for 16. Well Status after proposed work: Commencing Operafions: 9/10/2009 Oil ^ Gas ^ Plugged ^ Abandoned ~ 17. Verbal Approval: Date: WAG ^ GINJ ~ WINJ Q- WDSPL ~ Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact ~ose Soto Printed Name e S to Title petroleum Engineer Signatu e Phone Date 564-4972 9/4/2009 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:~~~~~5 Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ~ Other: er.,~ ~ ~ T d ~~ .L C ~ i 2 ~ ~' ' . ,, i ~ ~ c s.e cs.G ~ S~. c pe~/~ ~ W ~ ~- L b~ ~i z~~ i ~ : a . ~ S~' ~d- ~ ~ ~r~• ~a "~ ~ ~, -v ~T ,I~ ~,z,. f -",, ~=I ~ .,,,, ~~s r ~~~ ~ re Subsequent Form Required: ~ ' r~~~s~ ~~~. ;~ ; ~ f~ ~oa~ ~ Y U ~ APPROVED BY A r d b z~ ~ pp ove y: C MMISSIONER THE COMMISSION Date: _ __ _ _ '_ _ _ __ ..___~__" ~ ~ ~ ~ ( ~ V ~ L. t~~~'/L-.., ~/'~r,:;Q~-. __,... ~ l' ~ ~~ 3-19/R-28 194-049 PFRF OTTOC:HMFNT i • 'r Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 3-19/R-28 6/26/94 PER 12,924. 12,944. 10,185.57 10,201.76 3-19/R-28 8/5/94 RPF 12,924. 12,944. 10,185.57 `` 10,201.76 3-19/R-28 8/6/94 SQZ 12,924. 12,944. 10,185.57 10,201.76 3-19/R-28 8111/94 RPF 12,924. 12,940. 10,185.57 10,198.52 3-19/R-28 9/9/94 RPF 12,945. 12,965. 10,202.57 10,218.76 3-19/R-28 9/16/94 SQZ 12,924. 12,944. 10,185.57 10,201.76 3-19/R-28 9/16/94 SQZ 12,945. 12,965. 10,202.57 10,218.76 3-19/R-28 9/20/94 RPF 12,924. 12,940. 10,185.57 10,198.52 3-19/R-28 12/8/94 RPF 72,924. 12,940. 10,185.57 10,198.52 3-19/R-28 1/9/95 SQZ 12,924. 12,940. 10,185.57 10,198.52 3-19/R-28 1/12/95 RPF 12,924. 12,929. 10,185.57 10,189.61 3-19/R-28 2/10/95 RPF 12,924. 12,929. 10,185.57 10,189.61 3-19/R-28 6/5/95 APF 12,842. 12,848. 10,119.19 10,124.04 3-19/R-28 6/20/95 APF 12,775. 12,782. 10,064.95 10,070.61 3-19/R-28 6/29/95 APF 12,666. 12,672. 9,976.71 9,981.56 3-19/R-28 1/11/99 APF 12,766. 12,772. 10,057.66 10,062.52 3-19/R-28 1/11/99 APF 12,788. 12,814. 10,075.47 10,096.52 3-19/R-28 1/11/99 APF 12,822. 12,828. 10,102.99 10,107.85 3-19/R-28 1/11/99 APF 12,894. 12,898. 10,161.28 10,164.52 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STQ STRADDLE PACK, OPEN OH OPEN HOLE ~ ap ,- , ~ To: Jerry Bixby / Clark Olsen Well Operations Team Leader From: Jennifer Julian, Wells Engineer Subject: END3-19/R-28i Set Two Patches Please perform the followinq procedure(s): ~ Date: Apri1 20, 2009 AFE: ENR03WL19-C Est. Cost: $100M IOR: 200 1. S Pull TTP. 2. E Set two 25' L-80 carbon steel single-run Baker patches 3. F MIT-IA. Establish LLR if it fails (post patch) Current Status: Non-Operable Producer. TTP set 7-19-07 Last Production: 02/25/2001 - Oil : 22 bopd, Water : 4363 bwpd, whp: 425 psi, FGOR : 19,531 scf/stb Max Deviation: 46.22° C~ 11,860' MD Min ID: 2.75"@ 11855, 11835, 11796' MD on X nipples Minimum ID above patch setting depth is 2.812 at TRDP. Last Tag: 10/05/06: 10591' SLM Last Down hole Op: 07/19/07: LDL, caliper, patch drift. Latest H2S Value: 1600 ppm (03/02/99) Job Obiective: Run two 25' carbon steel Baker single set patches over confirmed leaks in this coiled tubing completion. Well Historv: Well END3-19 is a gas lifted producer with TxIA communication. A caliper was run in 16-Aug-01 indicating the coiled tubing completion is in good condition with only one isolated pit of 35% wall penetration at 8,811' right above GLM4 and significant ovality above each GLV and at the bottom the coil from 11,550' to 11,770'. Although the well had been shut in since 2001 when this caliper was run, an updated caliper indicated the tubing was still in good condition. An attempt to pull GLV #6 occurred in 2001 and SL was unable to latch the valve. GLV #4 was pulled and the valve was flow cut across the packing. The valve was replaced with a DGLV with extended packing stacks. All GLM's were dummied off on 7/8/2007, with a successful MIT-IA to 3000psi. Strangely enough, a few days later, while SL was pulling the prong from the TTP on 7/19/07, they noticed Txl communication while pulling out of the hole. They reset the prong and the subsequent CMIT T by IA (07/23/07) passed to 3000 psi but the MIT IA failed to 3000 psi with a LLR of 2 bpm at 3000 psi while pumping through tubing and taking returns from IA to flow line. Recent Ann Com History: r~ ~' ~ ~ A LDL run 03-06-09 confirmed two leaks in the coiled tubing completion near a GLM. Leaks are at 8787' and 8990'. The 2009 caliper indicates the tubing is in good condition. The 2001 caliper indicated isolated a 35% penetration at 8811' which when corrected to the LDL (8785') is very near the leak identified at 8787' (there is a very tiny bobble on the CCL there as well. A patch drift was completed 2-22-09. Please don't hesitate to contact Jennifer Julian with any comments or suggestions at 240-8037 (cell) or 274-0929 (home). ," ' , ~ Discussion: ~ Note from SL job 3/21/09: RAN FLAPPER CHECKER TO TRDP Q 1373' SLM...VALVE APPEARS STUCK OPEN. Note from 3-06-09 LDL: TAGGED PLUG AT 11834', MAY BE SUSPECT OF BEING SET IN WRONG XNIP ACCORDING TO WELLSKETCH. Patch drift done 2-22-09. The caliper recordings indicate slight buckling in joints 134 (6,646'), 151 to 155 (7,480' to 7,650'), and 177 (8,790'), however there were no problems with the patch drift. It will be a bit challenging to tie-in because this is a coil tubing completion with no collars. Luckily, both leaks are near a GLM, so after a rough tie in to the GLM is made, a GR can be used to refine the tie in. Please run two L-80 carbon steel Baker single-run patches for this injector (chrome corrodes in the presence of oxygen and should not be run in injectors). S-line: Pufl TTP 1. Pull TTP. Eline Set two 25' tubinq patches All depths are referenced to LDL 3-06-09 Anomaly Pass Down at 40 FPM. NOTE from LDL 3-06-09: ALL JEWELRY ABOVE GLM AT 11098' IS ABOUT 100' OFF DRILLER'S DEPTHS, EXCEPT SSSV IS ON DEPTH AT 1387'. 2. RIH w/ CCL, GR, and Baker patch #1. 3. Tie into 13' long GLM at ~ 8883' (Note on tubing tally the GLM depth is noted at 8966' DD) 4. RIH, tie in with GR and set patch across the leak at 8990 as per manufacturer recommendations. Element depths: 8975 to 9000 5. RIH w/ CCL, GR, and upper Baker patch #2. 6. Tie into 13' long GLM at ~ 8883' (Note on tubing tally the GLM depth is noted at 8966' DD-see note above) 7. Pull up hole, tie in with GR and set patch across the leak at 8787' as per manufacturer recommendations. Element depths: 8775 to 8800 Full-bore Post Patch 8. MIT-IA to 3000 psi, LLR if it fails. ~ ~ WELL SERVICE REPORT WELL JOB SCOPE UNIT END3'1 9 LEAK DETECTION LOG SWS 2128 DATE DAILY WORK DAY SUPV 3/6/2009 LEAK DETECTION LOG DOSHIER COST CODE PLUS KEY PERSON NIGHT SUPV ENR03WL19-I SWS-DICKINSON KIRK MIN ID DEPTH TTL SIZE 2.75 " 11796 FT 3.5 " DAILY SUMMARY `""`WELL SHUT-IN ON ARRIVAL*"" SSV CLOSED, INITIAL PRESSURES 250/150/100. RU ELINE, PT TO 3K PSI, BASELINE DOWN PASS AT 120 FPM, TOOL LENGTH = 37', MAX OD = 1.69" TAGGED PLUG AT 11835'. LRS PUMPING 2.2 BPM, 2800 PSI, KCL DOWN IA, RETURNS TO FLOWLINE, CHOKE FULL OPEN AT 176 UP PASS FROM 11800', 120 FPM, UNABLE TO LOG ACROSS GLM #2 AT 120 FPM, TOOL STUCK AT 11074', PASSED THOUGH AT 80 FPM. LOG UP FROM 11050' AT 120 FPM. ""JOB CONTINUED ON 7-MARCH-2009'*" LOG ~_ Init Tbg, IA, OA -> ~ 250 ~ 150 100 TIME COMMENT 08:00 MOVED OVER FROM END4-04, SNOW REMOVAL IN PROGRESS 08:30 SLB CHANGE OUT W/ DAY CREW 09:00 C/O COMPLETE, SNOW REMOVAL ALMOST DONE. 09:30 SNOW REMOVAL COMPLETE, SPOT UNIT, OBTAIN NEW PERMIT, DSO SIGNED PERMIT. 10:00 START RU 10:30 LUBE HANGING, RE-HEAD WITH NEW WEAKPOINT AFTER JET CUTTER ON PREVIOUS WELL 12:00 RE-HEAD COMPLETE, PICK UP TOOLS AND CHECK AT SURFACE 13:00 TOOLS CHECK GOOD, SLB SAFETY ON LOCATION, UNIT AUDIT 13:45 AUDIT COMPLETE, STAB WE~L, START PT. 14:15 PT 300 LOW, 3500 HIGH, PT GOOD, LOWER HEAT SOCK, OPEN SWAB, RIH AT 120 FPM FOR BASELINE TEMP PASS. RIH W/ HEAD, SWIVEL, 2- 1.69" WEIGHTS, PBMS, GRADIO, PI~S, PFCS W/ TURBINE SPINNER. MAX OD = 1.69", LENGTH = 37' 15:30 LRS ON LOCATION, SIMOPS, SPOT LRS UNIT. 16:06 ON BOTTOM, TAGGED UP AT 11810', PICK UP 10' OFF TAG AND LET LRS CMIT T x IA. TO 3000 PSI. 18:00 LRS RIGGED UP, SAFETY MEETING ON PUMP SCHEDULE, LRS PT LINE TO 3500, PT GOOD, LRS DONE HEATING DIESEL PRIOR TO PUMPING IN IA AS PER PE REQUEST. 18:20 LRS START PUMPING FOR FLUID PACK. 18:45 UP TO 2840 PSI ON TUBING STOP PUMPS, START CMIT 19:15 CMIT PASSES, CALL DSO TO LINE UP WELL TO FLOW RETURNS OUT TUBING FOR LDL LOG, LRS BLEED WELL PRIOR TO OPENING FLOWLINE FOR RETURNS 19:45 SLB NIGHT CREW ON LOCATION, C/O MEETING. 21:31 WELL TENDER OPEN FLOW LINE, CHOKE FULL OPEN 176, NOTIFY LRS TO START PUMPING. 21:44 LRS START PUMPING, METH SPEAR FOLLOWED BY WATER, TUBING PRESSURE = 290 PSI, MAX RATE 2 BPM, MAX PRESSURE = 3K PSI 21:49 LRS AT 2 BPM, 1700 PSI, TUBING AT 290 PSI 21:50 START UP PASS, 120 FPM, FROM 11800', PUMP RATE 2.1 BPM, 2800 PSI, KCL, SEE PUMPERS REPORT 22:20 TOOL STUCK, STOP LRS PUMPING, TRY TO FREE TOOL, DEPTH = 11074' 22:47 TOOL FREE DROPPING BELOW, ATTEMP TO PULL THROUGH AGAIN. PULLED 200 LBS BELOW MAX SAFE TENSION 22:57 TOOL PULLED THROUGH GLM AT 11074', 23:03 LRS RESTART PUMPING KCL 23:12 RATE = 2.2 BPM, PRESSURE = 2800 PSI, START UP LOG ABOVE GLM #2, 120 FPM, TUBING PRESSURE = 300 PSI 23:29 TUBING PRESSURE = 240 PSi, INCREASE PUMP RATE TO 2.2 BPM 23:57 LRS RATE 1.9 BPM, 2800 PSI _23:58 "*' JOB CONTINUED ON 7-MARCH-2009"`*'` WELL SERVICE REPORT . ~ WELL END3'19 JOB SCOPE UNIT LEAK DETECTION LOG SWCP #10 DATE 2/22/2009 DAILY WORK DAY SUPV CALIPER TUBING; DRIFT TUBING JONES COST CODE PLUS ENR03WL19-I KEY PERSON NIGHT SUPV SWCP-FELLOWS ATKINSON MIN ID 2.75 " DEPTH 11796 FT TTL SIZE 2.992 " DAILY SUMMARY '""CONTINUED JOB FROM 2-21-09 WSR"* FINISHED LOGGING PDS 24-ARM CALIPER FROM TTP (~ 11,810' SLM TO SURFACE, RECEIVED GOOD DATA. RAN 10' x 2.80" BAR-BELL DRIFT TO X-NIP C~ 11,768' SLM/ 11,796' MD, NO PROBLEMS. `""WELL S/I ON DEPARTURE, DSO NOTIFIED"" LOG ENTRIES Init Tb , IA, OA -> 460 160 120 TIME COMMENT 00:00 CONT FROM 2-21-09 TS= .125 SS WIRE, 8' 1-7/8" STEM, SSS 00:05 CONT LOGGING PDS 24 ARM SONDEX CALIPER FROM 11,810' SLM TO SURFACE 02:30 OOH W/ CALIPER, STBY FOR DATA 03:00 RECEIVED GOOD DATA, C/O TS TS= .125 SS WIRE, 8 1-7/8" STEM, OJ, LSS 03:10 RIH W/ 2.79" CENT, 10' 1-1/2" STEM & 2.80" CENT (157" OAL) C~ 150 FPM TO SIMULATE E-LINE AND 60 FPM THROUGH ALL JEWELRY..S/D ON X-NIP C~ 11,768' SLM / 11,796' MD..POOH 05:15 OOH W/ TOOLS, INSTRUCTED TO R/D, TGSM 05:25 BEGIN R/D, TREE CAP ON AND PRESSURE TESTED. 07:00 R/D COMPLETE..CASING VALVES OPEN TO GUAGES W/ EXCEPTION OF AL, MASTER OPEN, SWAB & WING SHUT, SSV DUMPED & TURNED OVER TO PANEL, SSSV PRESSURED UP TO 5000 PSI AND BLOCKED IN AT TREE sssv & al valves both fia ed 07:20 CREW C/O TO NOSKO,STAND BY FOR WELL TENDER TO COME SIGN OFF ON PERMIT.WELL TENDER IN TRAINING CLASS 08:15 PERMIT SIGN OFF. 08:59 TRAVEL TO MPI -TURN IN PERMIT. Final Tb , IA, OA -> 460 160 120 ~ • : '~ i REM ID OD LENGTH TOP BOTTOM WLEG 2.94 4.00 1.26 11,861.74 11 863.00 3-i/2" 9.2#L-80 PUP JT 2.94 4.00 6.13 11,855.61 11,861.74 'X' NIPPLE 2.75 3.94 1.00 11 854.61 11,855.61 3-1/2" 9.2#L-80 PUP JT 2.94 4.Q0 9.70 11,844.91 11,854.61 3-1/2" 9.2#L-Sd PUP JT 2.94 4.00 9.69 11,835.22 11 ,844.91 'X'NIPPLE 2.75 3.94 1.00 t1 834.22 11,835.22 3-1/2" 9.2# L-80 PUP JT 2.94 4.00 6.14 11,828.08 11,834.22 BOTTOM SUB 2.94 5.63 0.61 11 ,827.47 11,828.08 BAKER SEAL 80RE EXT 4.00 5.00 14.38 11,813.09 11 ,827.47 BAKER F.B: 1 7-5l8" PACKER 4.00 6.50 3.20 71 809.89 11,813.09 rraiar,ta~arra,~ri~~ar+ifritii+airar~~rrtswa -rr~raiw ~i~ffa+ ~tairtra+atri rraat*ai+raiir +,~,trta~srrtr COILED TUBING STINGER ASSEMBLY STINGER LOCATED lNSIDE SEAL BORE RATCHEfING WLEG 2.99 3.95 1.32 11,825.11 11 826.43 BONDED SEAL ASSEMBLY 2.99 3.95 15.22 11 ,809.89 11,825.11 PICK UP ABOVE PACKER 3.00 11 806.89 11,809.89 +r~~-t~~~~*i*fr*,r3i*fi*trr:itttiattrf+-~e~+~*arra*ritit*f:ti~tttis~~:ta~++as:i~si~+*iwrai-#r~t+ COILED TUBING ASSEMBLY ID OD LENGTH TOP BOTTOM "GBH-22S" LOCATOR 4.26 0.83 <,:;:'~:;'~; $.0.6!:~~:::::»: 71 806.89 3-1/2" 9.2# L-80 PUP W/ CENTR. 2.99 3.52 9.73 ~1,796'33 >:3'i 80~sQ~ 3-1/2,• ••X•• NIPPLE 2J5 3.97 0.99 1.~ 795:~4 1'~ 79~:33 :> 3-1/2" 9.2# L-80 PUP W/ CENTR. 2.99 3.52 9.91 ~;1,785 ;~3 ':. i~,~95:;34 >: GLM #1 CAMCO GLM W/ CONN. 2.92 5.97 10.49 '~ 1'~74,:$4 . ."~ 7 785:43 :> 3-1/2" COILED TBG 3.12 3.50 664.05 ~<'1 ~~ 10'89 ~ 1,77~4;94 :` GLM #2 CAMCO GLM W/ CONN. 2.92 5.97 12.46 ~;'1 a98;43 '~9 't16;$9 :: 3-1/2" COILED TBG 3.12 3.50 972.01 ~;Q ~2B;42 <'t7,~98:43.:;: GLM #3 CAMCO GLM W/ CONN. 2.92 5.97 12.49 1U 't13;93 ~:10 126;42 3-1/2" COILED TBG 3.12 3.50 1135.02 8:,978 91 1~ 113:93 .;!! GLM #4 CAMCO GLM W/ CONN. 2.92 5.97 12.98 $i ~65 9~ --:8 ~i8;~~ 3-1/2" COILED TBG 3.12 3.50 2268.99 5;,696 9:4 ;8,9~5 93 :.: GLM #5 CAMCO GLM W/ CONN. 2.92 5.97 13.01 8: 683.93 z~ 6S6i94 _~:. 3-1/2" COILED TBG 3.12 3.50 1533.90 ~,150 '0!3 >6 683;93 ..~> SPUCE 10' Pu w/conn coll on btm 2.99 5.97 14.08 _~~~5 ~`5 a~50';~b3 3-1/2" COIl.ED TBG 3.12 3.50 1283.04 ;:~ $52:9:'t .>5 ~35:95 : GLM #6 CAMCO GLM W/ CONN. 2.92 5.97 12.98 ~ 899 :93- ~ 85~i:9~ .... 3-1/2" COILED TBG 3.12 3.50 2327.06 ;1;,512 8.7 " 3~839 93 :..: 3-1/2" SSSV NIPPLE W/ CONN. 2.81 5.25 15.94 1! 43~ 93 t 51~:;$~' :-: 3-1/2" COILED TBG 3.12 3.50 1454.83 42 'SQ: ,::#,496:93 ; 3-1/2" HANGER/PUP/CONN. 2.99 7.00 3.92 `>~8 '{8:: 42 1;Q HANGER - ASOVE LANDING SHOULDER 2.99 7.00 0.75 37 43: > 3~ :rt;8 R.T. TO TBG HGT LOCK DWN SCREWS 37.43 ;= p 00 ; 37:43 R.T. ELEVATION (56.00 FT A M.S.L.) . ~ ~wiw iemop~ r aw~~ ~`'a~'"'"''~s~c'u~-"°'e~ E wai~ ~r~ooop~r w~cr op. rcn R7_ a~ll . 66l~ HF EIEY ~ 1460 ~M7[OE~I/ . 1/'+ eMO ie.- ~~ese m r,so ~oau:~srr+~. ~r.ao.ar^ao ~~ J -~ i1Ml D~ 2Ta^" A 11TA~ 9+In" X MPPLE N07E 7t~G DD7 AI~CFIOIED ~ •'~ woARtaro ~.r,~r, SoCO p.~ on 6arnrol ~ns A~Inp ira~ apefalhn so~rv (~Q'~) i! ~wur 2at~' ic ~4F+r ~fq+vWrsl a~aa~ix~ a7ss~, Ns.~oc~, s.tr o 4 ~0- p~~4 +u- [t~' wt 4 4 Oi~ 7~ 46 OM WC 4 4 701~ ~ Ii OK Wf ~ 2 99RA 0?~t 4t OM (OC P 1 11'Ti~ ~ 1/ 01Y p1F 0 a+l~ CO~LBPlICE i2~FT, l~Q 2JP D wraau~o~a,~craRS ~~ait~ a~~xNw~ r.~s i76Q' D BN~t'G91ia~ LDCATOR ~ 801~~ ~L/I'i89~Y BAI~t~B.1P~ t1~t0 Im"O E7QBl90N i@~(1N17KM8l~i~lr Ii~ l.~t L1~O~CCMd1 ~'AR AMi~,EAT1't,~FBR ?? ~ 7~ 1 Wt 11dr b I~eln m fQ Wsrfyl sr/ arr •11Nf 4 1TI~.7217~ a x.,~ s ,~s•,zns~ a .,~nr a ,zree-,ae+~ a •~1MI • 11~2-7~RJD 4 ~7~ 4 77~2.71M0 ¢ •11~if 4 17#t-1R~ p x-i+.~' a ta~za-ta1nR P s,~r ~ ,al~-,~r+e a z.~-r a ~s1cx•taw+ 9 airr a ~~p•aaY++ 8 ~a~1r + ~s+6•a~vr3 S PY1p 1l,OeI 7~. ~.7Y~, 13~7f1 rrr~i~e4 ~a B.M TD. ~~' ~~~ ~~}fX?CXI O1 iElf 6Y d1 /6~ 6Y * . iNil~ .LH /.lOA1 V 01 .. .. _ ,RP H~ ~ AO19F BO~iI'TIMT 1MFiL• 8~li+Ni)0 P~MZ !il#A ~RMR ~Al ~` T M R ~ ~ • Area of Review - Endicott DIU ~-1AF/R-28 (194o4Ao) Prior to the conversion of well 3-i9F/R-28 from producer to water injector an Area of Review (AOR) is required. This AOR discuss the wells within 1/a mile of the well's entry point into the Kekiktuk Formation to the bottom of well bore completion. No wellbore enters the AOR of 3-19 at the top of the Kekiktuk. However one wellbore enters the AOR below. The following table illustrates the well within the AOR, its distance from 3-19, completions detail, and any annulus integrity comments based on an in-depth review of each well. Distance Well Name PTD Ft Annulus Inte rity g-19F R-28 194049o TOC calculated to be above injection zone at io,528' MD 4-04 T-26 i89o860 1339 TOC calculated to be above in'ection zone at 9~755' MD Figure i: Wells within AOR Well Name Casing Size Hole Size Vol Cement Kekiktuk De th 3-i9F/R-28 ~ 5/8" 9 ~ 8" ioo bbls i2,6i5' MD 4-o4/T-26 ~" 8 i 2" 99 bbls i3,642' MD Figure 2: Completion Detail Well 4-o4/T-26 (PTD 1890860) was completed in September 1989. The completion crossed the Kekiktuk formation at i3,642' MD. A ~" liner was run to 14,121'MD and hung off at 13,026' MD. The ~" liner was cemented with 99 bbls of class G cement. A Cement Advisor prepared in i8-Sep-89 from a CET/CBT log indicates good cement in interval i3o24-i3io6 (~82') behind the ~" production liner and in interval 12,947-i3,o24 (~~~') behind the g 5/8" intermediate casing. In preparation for a side-track in April 2009 the well was abandoned by cementing all the liner and part of the tubing to 12,482' MD as per 3-Mar-o9 tag additionally a g 5/8" EZSV was set at 8,~39' and a 9 5/8" whipstock at 8,~29' MD. The sidetracked wellbore does not enter the AOR. • • FV Structure M ap illustrating the AO R - ~ ~.} ~: ~ • r,«~..,, ,~.,~,~p.N t-3$ro-n '_~une°" i~rr+m ~. a.oi~-~s ~ .~ . ..~1-65A~P81 ' 3-15M-33 ~',. , _ ,' .~'.~; ", .~ ~ ,~}71M-30 `, : . ~.~ ~ `~/ ~ ~ , 3-Q9~118A }31M-3~ .'3-031L33 t_sr~-n '- '. ~zs a.mv-n ~~nN-ze ,,: : n~n \ ~ }~~~ ' , \ ~-eap-zs : :'~ 3.ssu-3Z ~ ~ ~e~a+ _\ . . ~S - i. ~ 105~-29 ~ .:a:~~-~:.-F':~ 3-33~ ,_ '\ ,,pp~~~ t-+FS/d?6 . l, V377B.M31 `~:3-77.M33'. : • ~ ~ f ~°ytJ ~,p1p.2p _'__" - ' . . '~ i1 , 3.21,1.3{ _i1b~TT-7t- ' . I .__ - ~ ' ~ . ~}7lk433 ,' 337L-35 _ . .}79.R-IB - ~ . ', ' -_` '` .__ . ~ ~ !¢OM-35 . \ ,.\ '__._ ~-• ~-0BM-30. ', ~: . ' i ~.~~~~\~. ~ . ~ .26 . ..-...'\~. , ~'~ ; ~ " 335~1~ ~ ~. D101 ' \. . .~ ~~~ f . , ' •s 4t&5-30~R '^~ ~ ~ ~'N'~ , '~---, , .~ `~is , : .` ~ f ,:- ~' - ,~--t . .'1 ~ > ~3-k9&` ~~ J ..-. -10315 l. ' j"-.... ~~~ix,'fR~ F ' a ...... - ~ J ?~j6 :a i t `~ ~.3+a ~. ~ _z. , , ~.. ; =~ `~-~--~. _.. - '"' __ _'. , _ : - . _ t . ~ ~ ` ~~ ..,,~ , ~:. -. ---_ ~ - - - -"~ . .-.r :::! ~ -"-.• ~ ---.-_. , , =, . ~ ~3-lZ7~15 .. _ '- .~ :, N \, ` ` ''`\ ,, \ :; ~~ ~ '.- ~oaz5 \\~ _, ,.~"-" _ ` \ ~a _ -_ ~ ~~1~:- -~~~ _ - r FV Structure Gnd (?ur5) ~ De pt h -17154 _107a0 -~0330 -9920 -4505 2000 C 2G0~ 4000 6Q00 ft Q FI Tops 1:27529 ~ FV Tops .~ z = • ~ Endicott DIU ~-19/R-28 (19404A0) Current Status End 3-i9/R-28 is a gas lifted oil producer with TxIA communication that has been shut in since 2ooi. The TXIA communication was noted while pulling out of the hole on a slick-line operation in ~g-Jul-o~. Subsequently in 23-Jul-o~ an MIT-IA failed with 2 bpm at 3,00o psi from tubing to inner annular space and a CMIT T-IA passed. A caliper ran in 22-Feb-o9 indicated the tubing was still in good condition and a patch drift was successfully completed in the same job. Recently in 6-Mar-o9 a LDL confirmed leaks at 8,~8~' and 8,990' MD. The reservoir management plan forward is to convert END3-19 to Upper Sub Zone (USZ) water injection as a replacement for former water injector 4-o4/T- 26. We113-19/R-28 will require two (2) patches installed and a passing MIT-IA to 3,00o psi to be in compliance with BP internal well integrity policy for operation. Completion 3-19/R-28 (PTD i94o490) completion crossed the Kekiktuk formation at 12,6i5' MD; the production packer is 805' above the top Kekiktuk at ii,8io' and the tubing tail is 753' above the top Kekiktuk at i1,862'. A ~ 5/g" casing was run from surface to TD at 13,142'MD. It was cemented with loo bbls of 15.8 ppg class "G" cement with no recorded losses. A Segmented Bond Log run in oi-Jun-94 sho~~s a minimum of 34 ft of isolating cement behind the ~ 5/s" casing above the proposed injection zone in interval i2,~26'-12,360'. It also shows good cement at Z2,65o'-12,675' interval to contribute on zonal confinement. The Fv, Fiv, Fiii and Fii are perforated and contributing in the current completion of the well. The lower Fii intervals i2,g29'-12,940' and i2,945'-12,y65' were perforated but squeezed in Jan i995• Plan Forward• i) Obtain Sundry for conversion to water injection 2) Possible re-perforation of existing zones to insure injectivity 3) Patch well and MIT-IA to 3,00o psi 4) Place well on water injection (confirm AOGCC approval prior to injection) 5) AOGCC witnessed MITIA once injection has stabilized ~ ~ ~ ~ ~ I~~-o~~ ~T M~C~ICAI, ~~~KIT1' R~'PORT ~ ~. :gUD D~~=. : ~ B~-9 Y OPER fi F2ELD g~ -~K~~co l~ - - ~ n ~ , S -- ,3 c~ - ~ y i.~.L NUi~93 ER 3 ' I `~ ~ 1~ ° Z ~ ~ Y ^ Z r/ ~1 t ~r f/ • • Y ~~~ ~ . n~LL_~~.T~: , TD: l3lSZ.2~.. /~3G~~'VD.; ~BTD: /~ o~ . ~o?~?VD 7 s~ ~~ C2sir.g : 7 S~ 4~ 5ho ._.........__,_ e : 3ls ~~tID TVD ~ LV : .r - -~1D ~.._ ~ ~~ •'?'4'D ___._r__ ~. .~.. _ ~.. . .. . , - • _._,..._.,,_ - ~ __~___,_.. ____.~___ ~.73;j,~..g: 3~~z`' Pa~~~~ lidi~'r~, Zvn; ~er ~t ~..~ ~ ______ ~~(~ :flle S;~e `~~~ ~ and ; Perf~ /2GG6f to /Z~G~~~s . ~'`~. ' --. -=--~ . . ~~.,P.NZC~.L iNTEGR?'T'Y - ?ART #~ . ......~ - .~..~.. . ~nnuiua 3rass ~est: ~..p s 15 m~,~,~,,,; 30 mi.n ,~~, C Ot1~lLI! t 5: ` (..~ o/.~. o~Pi~: . ti~ f~ t'~c.Y ~~,. . r~rN ~i r~ ~.~i~~r~r~~Y i.r rrir~.~rr~ri ' *iECi~,NiC~S~ x~TEGR=T'F - PART # 2 ' ~Dd sx C/~ss ~> ~..i~~ r.rr.i ^ rr r.~.....~~..r+~.. C Ce~enc Volumes r~,mt. i.:~n~:--- 6sg ~ Z B~S; DV ~ • ~ ~ ~ ..,......~:.:..._..~- Cmz ~ol to cover ges:.s _. ~!D NoT ,ecc: ro~ - /'~ ~~c.~''"'~~`. "~~eoreeical ~'OC /~~ sZ~ M1~ - ~c~u..~ ?~o C C--+ ~L. Zao . ' ~~J , ~...~~r ~riri~~. .r.+~.~rr~irr~~~. ..~~ Cement Bond Log (Ye9 or Ho) - ~~ In ACIGCC File ~~~ C9L ~v~luatioa, ~ zone above perfs ,~~r ~a~a a ~~ ~:- ~M~~ ~Z~~'~ ~ ~ Q ~ 1`~ ' ~/ 9 e~.X ~r ~../~ ~ r Z . ~~ 6- C T"~r ~~e F~ ~ ~~' ~ d jC "~s`~v( Froduation Log: Tppe ' CONCLUSIONS: ?'art # 1 ~~he ' ~~ ,t~/.~ G^ ~•~ ~ar~~ #2: . 7° j Evaluatian ~~ 1 Z~~~'' ~Z~X ' ~ ~ c~ /" ` ~ ~ c t r~ra~c Y ~S t~h S•'~-'~ . ~y~ ~ '~ ~C . ~.~ y, w.~•~-~. vl/ ~L.° Y~"!c.~` s~ ' S-~- ~ i r-; z. ~.~,~•fecrew (~~i~^ ~ N o ~~ • _ d ~ ~ ~ • Page 1 of 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, September 16, 2009 10:37 AM To: 'Julian, Jennifer Y' Subject: RE: 3-19/R-28 Question on injection ( PTD 194-049) Jennifer, I agree with the proposed steps below. You can move forward with the diagnostics as outlined. Be sure to track and report injection pressures and volumes during the temporary injection period. Please send me the results of the IPROF/WFL as soon as possible and obviously as soon as we get the data the well must be shut-in. 1 was also thinking we should do a couple of warmback passes additionally so we can get an idea of the baseline temperature response for the well. Once the well is patched we will only have this option if we want to check again. I am approving the sundry as proposed and will add this email to the record. Can you make sure all this activity gets captured on the follow-up 404 report too? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: ]ulian, Jennifer Y [mailto:Jennifer.Julian@bp.com] Sent: Tuesday, September 15, 2009 2:55 PM To: Schwariz, Guy L(DOA); Soto, Jose A Cc: NSU, ADW Well Integrity Engineer; Garing, John D; Diller, Carl (Northern Solutions) Subject: RE: 3-19JR-28 Question on Injection ( PTD 194-049) Hi Guy, as we discussed, our current plan is to: 1. Fullbore pump perform CMIT (last one in 2007) 2. Slickline pull TTP Run Wireline retrievable plug (WRP) below the lowermost hole (8990') Perform GMIT. If passes, this proves there are no holes below this depth. Pull WRP. Set WRP above the uppermost hole {8787'} Perform MIT-T. If passes, this proves there are no holes above this depth. 3. Put well on temporary injection for a minimum af 7 days (put on injection under evaluation--28 day clock) 4. Eline to run waterflow log to look for channel, and spinner log to identify current injection splits. Underinjecting perf intervals may be reshot. Set two patches to straddle holes 5. M1T-IA. Please let me know if you have any other suggestions. Since this is a planned injection well conversion, Torin, with our Well Integrity Group, plans on discussing this with Jim Regg in the next few days. Jennifer Julian Well Intervention Advisor 9/16/2009 • ~ Page 2 of 4 Alaska Consolidated Team (907) 564-5663 work (907) 240-8037 cell (907) 274-0929 home From: Schwar~, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, September 15, 20Q9 11:11 AM To: Julian, Jennifer Y; Soto, 7ose A Subject: RE: 3-19/R-28 Question on Injection ( PTD 194-049) Jennifer, Good point... I didn't see the Min ID on the patch in the procedure ,.. was thinking it was big enough to run standard PL tools thru. I agree .....a warm back pass will have to do. I wouid rather do that than Inject water without the MIT-IA first. There is a chance you have other issues with the tubing (more holes, patch failure etc} you don't know about and end up fighting that for a while. Assume the Drill Site engineer will want a IPROF soon after injection so either the 1 3/8" or 1" tools would work for the IPROF/warmback. So... my preference would be to do a IPROF/Warmback with little tools after the well is patched and passes the MIT-IA. I will write up the 403 that way. Thanks!! Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: Julian, Jennifer Y [mailto:Jennifer.Julian@bp.com] Sent: Tuesday, September 15, 2009 10:36 AM To: Schwartz, Guy L(DOA); Soto, 7ose A Subject: RE: 3-19/R-28 Question on Injection ( PTD 194-049) Hi Guy! We are struggling with how to run the WFL log because the minimum ID through the patch is going to be about 1.745" so we may have to put the well on injection first ($3~0,000 for surface tie in; well will be popped under eval with a 28 day clock) , run the WFL, and then set the two patches if the WFL looks good. i'm struggling to figure out any other way we can {ook for injection out of zone. The only thing I can come up with is warmback passes-Halliburton has a 1" spinner/temp/gamma ray available on the slope that can pass through the patches. Would that be sufficient? Jennifer Julian Well Intervention Advisor Alaska Consolidated 7eam (907) 564-5663 work (907) 240-8037 cell (907) 274-0929 home 9/16/2009 ~ . Prom: Schwartz, Guy L (DOA) [maiito:guy.schwariz@alaska.gov] Sent: Tuesday, September 15, 2009 10:29 AM To: Soto, Jose A Cc: Julian, Jennifer Y Subject: RE: 3-19/R-28 Question on Injection ( PTD 194-049) Page 3 of A~ Jose, My mistake ... I interpreted the wording incorrectly. Somehow 1 read that sentence as you were going to perforate a new zone at 12326-12360' md. i have looked at the cement mapping and VDL some more and still am going to require a WFL tog to be run after injection is stabilized. (This could be combined with the first IPROF log).Most likely it is isolated but it needs to be verified that there is not channeling upward. Thanks for the clarification. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 From: Soto, Jose A [mailto:jose.soto@bp.com] Sent: Tuesday, September 15, 2009 8:53 AM To: Schwartz, Guy L (DOA) Subject: FW: 3-19/R-28 Question on Injection ( PTD 194-049) Guy The interval 12326-12360 is where the good cement is in the bond log. Also in interval 12,650-12,675. The upper most perforations is 12666-12672 iike yau say. Next, let me present what I wrote versus what I should have written so it would not be confusing. Segmented Bond Log run in O1-Jun-94 shows a nimum of 34 ft of isolating cement behind the 7 5/8" >ing above the proposed injecrion zone in interval ,326'-12,360' Segmented Bond Lag run in O1-Jun-94 shows a inimum of 34 ft of isolating cement in intervai 12,326'- ,3b0' behind the 7 5/8" casing and above the proposed iection zone Regards, Jose Soto PE - Endicott Field - ACT East BP Exploration (Alaska) Inc. Off: 907 56~ 5972 Mob: 907 244 0529 From: Julian, Jennifer Y Sent: Tuesday, September 15, 2009 8:07 AM To: Soto, Jose A Subject: FW: 3-19/R-28 Question on Injection ( PTD 194-049) 9/16l2009 ~ ~ Page 4 of 4 Jennifer Julian Well intervention Advisor Alaska Consolidated Team (907) 564-5663 work (907) 240-8037 celi (907) 274-0929 home From: Schwartz, Guy L {DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, September 09, 2009 4:48 PM To: Julian, Jennifer Y; Soto, Jose A Cc: Roby, David S (DOA) Subject: 3-19/R-28 Question on Injection ( PTp 194-049) Jose, I have a follow-up question regarding the future water injection into 3-19/R-28. You mentioned injecting into a zone above the current perforations at 12,326-12,360' as a Upper Sub Zone (USZ) replacement for 4-041f'-26. The current upper perfed zone is at 12666' md. Can you elaborate a bit more on this ... is this still in the Kekiktuk formation? Are the other perfs going to be isolated at some point . Also, as I emailed to Jennifer earlier, the well will require a WFL after stabilized injection to verify fluids are staying in the approved injection zone. The bond log is not the best is this area. Thanks, Guy 5chwartz Senior Petroleum Engineer AOGCC 793-1226 9/16/2009 ~ ~ Ramirez, Darlene V (DOA) From: Foerster, Catherine P (DOA) Sent: Monday, September 21, 2009 9:17 AM To: Ramirez, Darlene V (DOA) Subject: Re: 309-315 Approve Sent from my iPhone On Sep 21, 2009, at 9:13 AM, "Ramirez, Darlene V(DOA)" <darlene.ramirezC~alaska.gov > wrote: > «S45C-209091808560.pdf» > The message is ready to be sent with the following file or link > attachments: > > S45C-209091808560.pdf 7 > ~ Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C-209091808560.pdf> 03/18/09 ~/B~a~ - rya ~b~ /~O~a a/~ awl?~ ,~~} ~ ~.~~~f N0.5133 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Ea i k~ :'t `° ~` ~'~' ~~ ~, .rL ,.. ~ _ Attn: Christine Mahnken ATTN: Beth ~ 'd"~'~ tit-o.:~x ~ "``~'~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well .Inh !t ~ .... ne J-27A AY3J-00010 CBL - j 02/21/09 1 1 S-107 AWJB-26 MEM L L lJ (- ~ ~- 02/25/09 1 1 09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE 02/23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE . _ (p ~ 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) js . C ~ 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG j L/ 03/02/09 1 1 B-25 AVY5-00023 USIT - j r /~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG p`/S- j~5 j ~ - 03/11!09 1 1 F-18 AVY5-00022 USIT ~ ~% % _ '~- 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL ( (.` • ~ - 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-211 AY3J-00014 (PROF/RST WFL - ~ 03/16/09 1 1 V-2i4 AY3J-00013 IPROF/RST WFL - C 03/15/09 1 1 K-06B AWJI-00017 MCNL ~ - • 01/28/09 1 1 L5-15 12113027 RST - /D ~~} j • 12/09/08 1 1 07-18 12071915 RST 9 ~ (~ 12/01/08 1 1 15-15C AWJI-00015 MCNL _ j 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT 12/07/08 2 1 R-41 40018496 OH MWD/LWD EDIT ~/ j j 01/04/09 2 1 H-18 11999064 RST / - I U `~ 12/03/08 1 1 ~- ~ - ~ • -~--..--.-..••..~...~~.,.,~ r.~..~~~ ~ .,, vIV11~11Y1'1 /11YY nLl Vn1Y11Y17 VIYC I.VF'i cra~.n ~~: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 3cl ~l- ~ ~ ~ rem f Lu ec~1 3 ~2 ~ r s ~ Copy a`1 Alaska Data & Consulting Services 2525 Gambell Stc~~t,~~ijt00 Anchorage, AK 98~6~2$ 8 „' ATTN: Beth "` °'" ' Received by: 4lr1 ~ Le ,,,, n ~ ~If ;i -~ r ~ t • 01' OR BE ORB ' ~ STATE OF ALASKA ALAS~ AND GAS CONSERVATION COMMISSI~ REPORT oF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown __ Pull tubing__ Stimulate__ Plugging__ Perforate X Alter casing __ Repair well __ Other__ 2. Name of Operator BP Ex~)loration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 2756' NSL, 789' WEL, Sec. 8, TIIN, R17E At top of productive interval 1119' NSL, 1605' WEL, Sec. 6, TIIN, R17E At effective depth 1271' NSL, 1791' WEL, Sec. 6, TIIN, R17E At total depth 1309' NSL, 1839' WEL, Sec. 6, TIIN, R17E 5. Type of Well: Development .. Exploratory __ Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 55.8 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 3-19/R-28 9. Permit number/approval number 94-49/Not Rec/uired 10. APl number 50- 029-22463 11. Field/Pool Endicott Pool 12. Present well condition summary Total depth: measured true vertical 13152 feet 10314 BKB feet Plugs (measured) Effective depth: measured true vertical :, Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 13066 feet 10245 BKB feet Junk (measured) Length Size Cemented Measured depth True vertical depth BKB BKB 90' 30' Driven 130' 74' 2684' 10 3/4 500 sx PF "E"/375 sx "G" 2726' 2611' 13101' 7 5/8" 700 sx Class "G" 13142' 10306' measured 12924'- 12944', 12945'- 12965' (Squeezed) 12666'-12672', 12766'- 12772', 12788'- 12814', 12822'- 12828', 12842'- 12848', 12894'- 12898', 12924'- 12929' (open) true vertical (Subsea) 10134'- 10146', 10146'- 10163' (Squeezed) 9921'-9926', 10002'- 10007', 10020'- 12814', 10047'- 10052', 10063'- 10068', 10105'-10108', Tubing (size, grade, and measured depth) 3 1/2" coiled tubing set at 11,863' Packers and SSSV (type and measured depth) FB-1 Packer set at 11,810'; 3 1/2" SSSV set at 1497' 13. Stimulation or cement squeeze summary Add perforations 1/11/99 Intervals treated (measured) 12849'-12898', 12822'-12828', 12788'-12814', 12766'-12772' Treatment description including volumes used and final pressure A~asI<a OiJ & Gas Cons. Commissi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 107 1074 0 334 Subsequent to operation 34 10 6803 0 358 15. Attachments 16. Status of well classification as: Copies of Logs and sUrveys run __ Daily Report of Well Operations X Oil Gas__ Suspended Service 17. I hereby certify that the foregoing is true a,nd correct to the best of my knowledge. ! Signed ~~ ~~ ~ Title~,ni,~r T,,~hnie~lA.~.~i_~t~nt /fi~.~.fi234) Date 2/10/99 Form 10-404 Rev 06/1.~/~8 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department ADDITIONAL PERFORATIONS DATE: 1110-11199 WELL N°: 3-19/R-28 BP EXPLORATION REP: SERVICE COMPANY: VARBLE SWS (SPENCER) COST CODE: N15319-120 DETAIL CODE: E-line I Add Perfs DATE/TIME OPERATIONS SUMMARY 1/10 1100 1/11 1245 1300 1345 1435 1515 1540 1802 1810 1815 1819 1823 1830 2030 2045 MIRU SWS SIP=1900 lAP= 1150 OAP=0 Install PE check valve & hyd. Hand pump. Pump up TRDP SSSV to 5000 psi. Hold safety meeting. Test fire SAFE system & check all tools. Arm gun # I (4') RIH w/12' 1-11/16" weight bar / Gun- GR / Tool saver / 4' 2-1/8" enerjet gun. OAL - 34' On btm. Log tie ~n pass. Fie into SBL dated 6/1/94 Take out 6'. Log confirmation pass. Flag line. On depth. Log into place & hang CCL @ 12885.5' md. (8.5' from CCL to top shot) Shoot gun # I from 12894' 12898' md. No indication that gun fired. Log off. RIH & log into place. Adjust temperature parameter to allow a little more current through SAFE. Gun most likely fired the first time but will attempt to shoot again to make sure. On depth. Shoot again. Possibly gained 20 lbs. No change ~n.whp. POOH. OOH. No problems coming through SSSV. All shots fired. 2100 0800 0830 0855 0900 0920 1145 1156 1208 1214 1219 1225 1400 1415 1515 1620 1635 1643 1649 LDFN R/U SIP= 1950 Check all tools & test fire SAFE. lAP-100 OAP=0 Hold safety meeting Arm gun # 2 (6') RIH w/16'1-11/16" w. bar/CCL/6'gun OAL=33' At flag. Adjust depth. Log tie ~n pass. rake out 2.5' Log confirmation pass. On depth. Log into position and hang CCL @ 12816.1' (5.9' from CCL to top shot) Shoot gun # 2 from 12822-12828' md. Lost approx 20 #. Log off. POOH OOH. All shots fired. Arm gun # 3 RIH w/26' gun OAL = 40.5' At flag. Adjust depth. Log tie ~n pass. Fake out 7' Log confirmation pass. On depth. Log into position & hang CCL @ 12782.1' md. (5.9' from CCL to top shot) Shoot gun # 3 from 12788'-12814' md. Lost approx. 30 #. 1653 Log off 1700 1815 1830 1900 2014 2030 2036 2038 2040 2045 2150 2300 POOH. OOH. All shots fired. Arm gun # 4 RIH w/gun #4. AOL= 33' At flag. Adjust depth. Log tie ~n pass. Take out 3' Log confirmation pass. On depth. Log into position & hang CCL @ 12760.3' md. (5.7' from CCL to top shot) Shoot gun # 4 from 12766'-12772' md. Lost approx. 35 #. Log off. POOH OOH. All shOts fired. Remove PE check valve, POP & request well test ASAP RDMO SIP-1950 IAP=1100 OAP=0 PERFORATION SUMMARY: GUN INTERVAL FEET SUBZONE I 12894'-12898' 4 FII --- 2 12822'-12828' 6 Fill 3 12788'-12814' 26 Fill 4 12766-12772' 4 FIV All perforations were shot using 1-11116" Enerjet III RDX charges with 4 spf 8 grams, entrance hole = .28", penetration --- 17.96" PERMIT 94, -04.9 94, -04.9 94, -- O,q- 9 94,.-~ 04, 9 94,-04,9 94. -04,9 94.-0,49 9,~.- 04, 9 9L~.- 04,9 94, -*04,9 94,.w Oa. 9 9a w' 04. 9 96 ~' 04, 9 96 ~Oa9 94, '~ 04, 9 96 "-04,9 94.~-04, 9 94,--04,9 94 -04,9 9~-0~9 DATA ~ AOGCC Individual ~ i; iaoiog~ca'i Materials T DATA_PLUS Vie '1 i i nve n ~.-~, y ~,F'FC/GR/C L .~BT/G R/'CC L t,.¢' FC/G R/C L ~g~,.N-N/F ~.--%~O R/CDN ~DR-VER ~,D N ~lCLS ~1~,.' F'c / s TAT/PRE S S ~.--~FC/G R/CC L '"~C/G R/CC L L.-PCCC/G R/CC L v~P Fi:iGR/CCL ...,,,'¢' D L S ~'FC GR/CCL PERF ,.,//¢' F C/G R/C L C.P,,Fis/P E R F up-Cs r~'FC/' P E R F r~'CCL ~F~OD PROFILE L 116'70.-11920 L 11500-~130h2 L 1284,0-12950 L 12524,-.-13153 L '12524,~13153 L 1252/4.-~ 13153 L 12524,-13153 T 12524-'13153~ L 12700-13030 L 12700-13012 L 12800-13000 L 1284,0--12972 L 12800-1300~ L 12800~"13000 L 12800-12995 L 12700'-12971 L 12774,-12988 L 12786~12971 L 3300-12970 L 12760~12920 L 126'78-12900 OH~CDR/CDN Page: Date: R UN 1 1 1 CMPS CMPS CMPS CMPS CMPS 1 1 1 1 1 1 1 1 '1 1 1 1 1 1 1 '1 04/ 10/'96 DATE .....RECVD 06/14,/94, 06/14,/9~. 07/'25/'94, 07/26/94 0'7/26/94, 07/26/9~. 07/26/94, 07/26/9b O7/27/94, 08/17/9~. 08/ 17/'94 10/05/94. 1o/o5/94, 08/25/9a 12/'07/'94, 12/21/94 01/29/95 02/'17/95 02/17/95 06/16/95 06/30/95 07 /'2 ~/'95 07/21/95 PERMIT DATA ~,. AOGCC Ind'fv'i'dual We'l'l '?I ~ i eo'log'i'ca'l Mater"i'als Invert r'y T DATA._P L IJ $ Pa.qe ' ~ Da~e: 04/~0/~8 RUN DATE ...... RECVD Are dry dJ'tch samp'les r'equ~'red? yes ~¢.J And r'ece~'ved? yes no Was tt~e we'l"l cor'ed? yes ~a'lys~'s &. ~d44_EEipt~'on r'e_c_ei'ved? Are we1 1 tests r'equll'~d?. ~yes"'~ " i~ece-f'ved'~-, yes no Weli ~'s ~'n comp'i Inft~a"i COMMENTS ye~ ~ IqO LARRY GRANT ~' Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 July 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: .WELL DESCRIPTION 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 GR/CCL FINAL BL+RF ECC No. Run # 1 6034.06 Run # 1 6217.15 Run # 1 6351.07 Run # 1 6452.04 D Please sign and return to: Attn. Rodne . P~ Atlas Wire~~vices ) °r Received by:/ /~..~//~,_~.~,/// Date : · · JUL 2 4 1995 Alaska Og & ~as ~,o~s. oommiss~.otl ~c~om~e LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 11 July 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1PFC/PERF FINAL BL+RF 1 PLS/STP FINAL BL+RF 1PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # 1 2628.07 Run # 1 3235.06 Run # 1 5669.05 Run # 1 5959.05 Run # 1 6217.14 Run # 1 6412.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~/~ Or FAro (907) 563-7803 LARRY GRANT f ~ ~ .~ate: 26 June 1995 Attn. ALASKA OIL + GAS CONSERVATIONS-~ ~ ~ 3001 PORCUPINE DRIVE ~.. ~ ~-~%~: Transmittal of Data ANCHORAGE ~ ~{~ AK, 99501. ~%% ~ Sent by: PRIORITY MAIL Dear Sir/Madam, ~ Enclosed, please find the data as described below: WELL ~%/0~ # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1PFC/PERF FINAL BL+RF ECC No. Run # '1 6132.05 Run # 1 6217.13 Please sign and return to: Attn. Rodney D. Paulson Atlas Wirel~ ~ ~horage, AK 99518 ___.~ /Or~X to~(~ 563-7803 Received byf /~-~~ /~/~.~/// ~'" Date: p,,, -.- -¥.- (/,---- ,- LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 June 1995 Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL 2-08/K-16 MPI # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF Run#. 1 Run # 1 Run # 1 Run # 1 Run # 1 Run ECC No. 3842.07 6175.03 6175.04 6209.03 6217.12 6355.05 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 ~eturn ~; Petrotechnieal Data Cente~ BP Exploration (Alaska) Ins 900~East Benson Boulevard Anc~ora_xe, Alaska 99908 R D Da~e N~ Oil & Gas'C~s. Co~ion Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 14 February 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear _Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS/STP FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # i 6185.11 Run # i 6217.11 Run # I 6351.03 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 .s~ end l"e¢'u_~n ¢o~, R E C E IV E D LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 9 February 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION -- ~i.~.~ 3-19/R-28 SDI 1 PLS FINAL BL + RF 1 PFC/PERF FINAL BL+RF ECC NO. Run # I' 6192.06 Run # 1 6217.10 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: ~!ease s!a~n and .... _ ............ . ..... ~- {Alaska) ,~ ~ . ......... FEB lW i995 Alaska Oil & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE.DRIVE ANCHORAGE AK, 99501. RECEIVED JAN 1995 Naska 0il & Gas Cons. CommissiOn /mohorage Date: -18 January 1995 RE: Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~"7"' ~:)~) 3-21/L-34 SDI 7-' 5~) 3-21/L-34 SDI ~'"/70 3-43/P-36 (SDI) /R-28 SDI · # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PLS-STP FINAL BL+RF · 1 PLS FINAL BL + RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF Run ~ I Run # 1 Run # i Run # 1 Run $ i ECC No. 5765.07 5765.08 6192.05 6217.09 6296.03 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= LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 13 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ O" --~ /I~ # DESCRIPTION 3-33/K-37 1 PERF/PFC FINAL BL+RF 7¥- Run # 1 Run # i ECC No. 6010.07 6217.08 Please sign and return to: Attn. Rodney~ . P~~aulson~ 2Ol ~ ~horage, ~ 99518 ~ Received by: / / ~4 ~ ~ //~~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: i December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PFC/pERFFINAL BL+RF PLS FINAL BL + RF PFC/PERF FINAL BL+RF LDWG TAPE & LISTER PLS FINAL BL + RF Run # 1 Run # 1 Run # i Run # 1 Run # i ECC No. 6025.01 6217.07 6235.06 6305.00 6310.01 Please sign and return to:~tlas Wirelin~ 99518 \ "-~ Received by:~-/,~'/~f_,w'__.-.~ *..,~.,,..,~...~-~ Date: ~ ~ ~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 September 1994 RE: ~ Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 3-05/0-29 3-17/J-30A SDI 3-19/R-28 SDI I PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PLS/SPNR FINAL BL 1 PLS/SPNR RF SEPIA i PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA ECC No. Run # i 2628.05 Run # i Run # i 6185.06 Run # i Run # 1 6217.05 Run # i Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 //TAnchor.a~, AK 99518 / At~~~D. Paulson Receive~/ ~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 September 1994 RE: ~ Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL · 1-53/Q-20 MPI DESCRIPTION 1 PLS FINAL BL i PLS FINAL RF SEPIA i PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA FINAL BL RF SEPIA RF SEPIA ECC No. Run $ i 5709.03 Run # I Run # i 6185.07 Run # 1 Run # 1 6217.06 Run ~ i Run # 1 Run # 1 Run # 1 Run $ i 6276.00 Please sign and return to: Atlas Wireline Services Received 5600 B Street Suite 201 Anchor, age, AK 99518 At~/~_ ey D. Paulson ~//_/ ,~'~'~ Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 16 August 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ./~ /~ 3-211L-34 SDI ,( DESCRIPTION 1. PDK/GR FINAL BL 1 PDK/GR FINL.RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA 1 COLLAR LOG FINAL BL 1 COLLAR LOG RF SEPIA 1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA ECC No. Run # i 5765.03 Run # 1 Run # 1 6235.01 Run # 1 Run # 1 5765.02 Run # 1 Run # I 4143.05 Run # 1 Run # i 6217.04 Run # 1 Suite 201 Anchorage, AK 99518 ~ ~ ,~ Att~~_ y D. Paulson ~..~ ~ BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 ~eceived ~Y AUG 2. 5 1994 Alaska Oil & Gas Cons. Co~zis~ Anchorage Date ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 10 August 1994 RE: Transmittal of Data ECC #: 6217.03 Sent by: ANCHORAGE EXPRS Data: PL Dear Sir/Madam, Reference: BP 3-19/R-28 SDI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: Prints/Films: 1 PFC/PERF FINAL BL Run # 1 1 PL/STATIC FINAL BL Run # 1 1 PFC/PERF RF SEPIA Run # 1 1 PL/STATIC RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage,. AK 99518. ~%~'~CE/VED Received b' Dmte; ~UG 7 ~ ]99~ ~a$1~a.Oii.& ~as Co.s. Commission AnChorage Please sign and return to: Petrotechnieal Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99508 Received by ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 19 July 1994 RE: Transmittal of Data ECC #: 6217.02 Sent by: ANCHORAGE EXPRS Data: PL Dear Sir/Madam, Reference: BP 3-19/R-28 SDI ENDICOTT NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: ~ Prints/Films: 1 /P~S FINAL BL Run # 1 1 PLS FINAL RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Petroteehnieal Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99508 Received by Date No. BP0036 SCHLUMBERGER GEOQUEST INTERPRETATION AND COMPUTING SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 COMPANY LOCATION ATTENTION WELL NAME SERVICES STATE OF ALASKA AK OIL & GAS CONS. COMM. 3001 PORCUPINE DRIVE LARRY GRANT DATE : 3-19/R-28 WELL NAME · · '~ OH (LWD) LIS TAPE I BLUELINE & I RFOJ.J}ED SEPIA ~gERVICE.~ · EACH OF THE CDR~N, CDN N~/~LOG, ~AND ~ VERY-ENHANCED RESISTIVITY NO. OF BOXES: ONE JOB NO. · 94217 NO. OF BOXES: JOB NO. : 7-26-94 WELL NAME : WELL NAME : SERVICES : SERVICES : NO. OF BOXES: NO. OF BOXES: JOB NO. : JOB NO. : PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING TO: BP .EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 SCHLUMBERGER COURIER: GEORGE'S COURIER SERV!~;E DATE DELIVERED: JUL £ RECEi~By~, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ,aBANDONED [] SERVICE [] 2, Name of Operator 7. Permit Number BP Exploration . . 94-49 3. Address 8. APl Number 4". Location of' well at sudace ' { \ I 9. Unit or Lease Name Duck Is/and Unit/Endicott 2756' NSL, 789' WEL, SEC. 8, T11N, R17E I 10. Well Number 1119'NSL, 1605'WEL, SEC. 6, T11N, R1 ~ V~!Ftl~ -~ 11. Field and Pool At ,T, otal Depth , t ~,~u j, . Endicott Fie/d/Endicott Poo/ 1309 NSL, 1839 WEL, SEC. 6, T11N, R17~~~----~ 5. Elevalion in teet (indicate KB, DF, etc.) {6. Lease Designation and Serial No. KBE = 55.8' I ADL 47502 :1'~. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 5/7/94 5/27/94 6/26/94J 6-12' teet MSL JOne "i'7. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV sol Fl. Thickness of Permatrost 13152' MD/10366' TVD 13066'MD/10297' TVD YES tx] ~ []I 1497' feet MD 11465' (Approx.) '~'2. Type Electric or Other Logs Run GR/CDR/CDN/L WD 23. CASING, LINER AND C EM ENTI NG RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive 40' 130' 30" Drive 10-3/4" 45.5# NT-80S 42' 2726' 13-1/2" 600 sx PF "E'Y375 sx "G" 7-5/8" 29. 7# NT-95HS 41' 13142' 9-7/8" 700 sx Class "G" 24. Perforations open to Production (MD+TVD:oI Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDt PACKER SET (MDI Gun Diameter 2-1/2" 4 spf MD TVD 3-1/2" 11863' 11810' 12924'- 12944' 10183'- 10199' :6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/26/94 J Gas Lift Date et Test iHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD Flow Tubing Casing' Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL DIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lilhology, porosity, fractures, apparent dips, and presence el oil, gas or water. Submit core chips. R C£1V D JUL '~ 9 1994 ~xtaska Ltii & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS ,-,d MATION TESTS NAME Include interval tested, pressure data, all lluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. i , Kekiktuk 12645' 9960' K3B 12898' 10165' "~1. LIST OF ATTACHMENTS ,, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig ne'd~-~~~ Title .OrillingEn.qineerSupervisor 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". RECEIVED Form 10-407 JUL 1 9 1994 Alaska Oil & Gas Cons. Commission Anchorage BP/A~I SHARED SERVICE DAILY OPERATIONS~ PAGE: 1 WELL: SDI 3-19/R-28 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 05/07/94 09:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 05/07/94 ( 1) TD: 0'( 0) MOVING TO 3-19 MOVING TO SDI 3-19/R-28. MW: 0.0 VIS: 0 05/08/94 (2) TD: 1392' (1392) 05/09/94 (3) TD: 2740'(1348) 05/10/94 ( 4) TD: 2740' ( 0) 05/11/94 ( 5) TD: 3935' (1195) 05/12/94 ( 6) TD: 5079' (1144) 05/13/94 ( 7) TD: 6224' (1145) DRILLING MW: 9.2 VIS:170 MIRU. ACCEPTED RIG @ 0900 HRS ON 05/07/94. MIX MUD, NU DIVERTER AND FUNCTION TEST, PU BHA AND ORIENT, RU WESTERN ATLAS & GYRO. CIRC TO ESTABLISH RETURNS. SPUD WELL, DRILL TO 439'. GYRO. DRILL TO 630'. GYRO. DRILL TO 725'. GYRO. DRILL TO 1392'. RUNNING 10 3/4" CSG MW: 9.3 VIS:143 SHORT TRIP TO DC'S, GOOD TRIP, NO FILL ON BOTTOM. DRILLING AND SURVEYING TO 2740' TD. CBU. SHORT TRIP TO DC'S, NO FILL. CIRC HOLE CLEAN. POH; LD BHA. R/U AND RUN 10 3/4" CASING. PICKING UP BHA MW: 9.2 VIS:107 RUN 67 JTS CASING; LAND HANGER WITH NO PROBLEMS. CIRC & RU HALLIBURTON, RECIPROCATING CASING. NO PROBLEMS HANGING UP IN DIVERTER. TEST LINES. TEST CASING. R/D CASING TOOLS, N/D RISER & DIVERTER; CLEAN CEMENT OUT OF CELLAR. N/U SPEED HEAD & TEST; N/U BOPS. TEST BOPS. P/U NEW BHA. DRILLING MW: 9.3 VIS:183 P/U BHA & RIH TO 800'. SERVICE TOP DRIVE & TEST MWD. RIH & TAG FC @2645'. DRILL SHOE TRACK & 5' NEW HOLE. CBU. LOT; 14.4 PPG EMW. CIRC AND COND MUD BEFORE BEGINNING TO DRILL. DRILLING TO 3650'. 10 STD SHORT TRIP; SOME TIGHT SPOTS WIPED OUT FROM 3254-3082'. NO FILL ON BOTTOM. DRILLING TO 3935'. DRILLING MW: 9.5 VIS: 75 DRILL AND SURVEY TO 4604'. CBU. SHORT TRIP 4604-3550'. DRILL AND SURVEY TO 4699'. CIRCULATE. TRIP OUT FOR BIT. CHANGE OUT BIT, MTR & STAB SLEEVES. SERVICE RIG. TRIP IN. REAM TIGHT SPOT @3978'. TRIP IN TO 4699'. DRILL TO 5079'. DRILLING MW: 9.7 VIS: 65 DRILL & SURV. T/5747. SHORT TRIP T/4480. DRILL T/6132. CBU. TOOH F/BHA. REPLACE MUD MOTOR & BIT. TIH T/2725. SERV. RIG. TIH T/6132. DRILL & SURV. T/6224. Al~chorage WELL' : SDI 3-19 OPERATION: RIG : DOYON 15 PAGE: 2 05/14/94 ( 8) TD: 7940'(1716) 05/15/94 ( 9) TD: 8893' ( 953) 05/16/94 (10) TD: 9188' ( 295) 05/17/94 (11) TD:10204' (1016) 05/18/94 (12) TD:11364' (1160) 05/19/94 (13) TD:11495' ( 131) 05/20/94 (14) TD:11722' ( 227) 05/21/94 (15) TD:11883' ( 161) 05/22/94 (16) TD:12141' ( 258) DRILLING MW: 9.7 VIS: 71 DRILL & SURV. T/7178. PUMP HI VIS SWEEP. SHORT TRIP T/6132. OK. DRUKK & SURV. T/7940. DRILLING MW: 9.7 VIS: 67 DRILLING & SURV. T/8132. PUMP VI VIS SWEEP WHILE DRILLING. SHORT TRIP T/7160. OK. DRILLING & SURVEYING T/8893. DRILLING MW: 9.8 VIS: 68 DRILL & SURV. T/8988. SHORT TRIP T.8035. OK. DRILL & SURV. T/9135. CBU. TOOH F/BIT. C/O MUD MOTOR, MWD & BIT. TIH. CUT DL. TIH TEST MWD TRIP T/9135. DRILL W/PDC BIT F/9135 T/9188. DRILLING MW: 9.8 VIS: 74 DRILLING W/PDC BIT T/9664. PUMP HI VIS SWEEP WHILE DRILLING. SHORT TRIP T/9095. OK. DRILL & SURVEY T/10204 MD. DRILLING MW:10.2 VIS: 60 DRLG & SURV. W/PDC BIT T/11076 MD. PUMP HI/VIS SWEEP WHILE DRLG SHORT TRIP T/10045. OK. DRLG & SURV. T/11364 MD. TOP OF TUFFS @ 11076 MD 8798 TVD. TIH W/NEW BIT MW:10.1 VIS: 68 DRLG & SURV. T/11495 MD. PUMP LO/HI VIS SWEEPS. TOOH F/BIT. SLOW ROP. TEST BOPE. REPLACE BIT & STAB BLADE. TIH T/SHOE. TEST MWD. DRILLING MW:10.1 VIS: 59 TIH REAM UNDERGAUGE HOLE 4116 T/4400. REAM T/11495 DUE T/RUNNING NEW FULL GAUGE STAB. DRILL & SURV. 11495 T/11722. TIH W/NEW BHA MW:10.1 VIS: 56 DRLG/SURV T/11883. CIRC. TOOH T/10880. TRIP T/BTTM. CIRC HI VIS SWEEP. TOOH. CHNG BHA. TIH. CUT DL. TRIP IN W/NEW BHA. DRILLING MW:10.1 VIS: 54 TIH W/NEW BIT. T/11883. DRLG/SURV. T/11993. SHORT TRIP T/11085. DRLG/SURV. T/12141 MD. JUL '1 9 '~994 Oi, J & Gas Cons. Commissio~ WELL : SDI 3-19 OPERATION: RIG : DOYON 15 PAGE: 3 05/23/94 (17) TD:12447'( 306) 05/24/94 (18) TD:12526' ( 79) 05/25/94 (19) TD:12717' ( 191) 05/26/94 (20) TD: 12940' ( 223) 05/27/94 (21) TD:13030' ( 90) 05/28/94 (22) TD:13152' ( 122) DRILLING MW:10.1 VIS: 57 DRILL/SURVEY T/12182. PUMP HI VIS SWEEP WHILE DRLG. SHORT TRIP. 10 STNDS T/11229. OK. DRLG T/12373. 10 STND TRIP T/11466. OK. DRILL/SURVEY T/12447. ROP IN LIMESTONE = 10FPH. TRIP IN W/LWD TOOL MW:10.1 VIS: 58 DRLG & SURV T/12490. SHORT TRIP. OK. DRLG T/12526. PUMP HI VIS SWEEP. TOOH WORK THRU TIGHT SPOT @9225. LD MWD/PU LWD. REPLACE BIT. LOAD LWD TOOL/TIH. DRILLING MW:10.1 VIS: 56 TIH T/12526. NO FILL. SERV. RIG. DRLG T/12658. SHORT TRIP 10 STNDS T/11731. OK. DRLG T/12717. DRILLING MW:10.3 VIS: 64 DRLG T/12740. RECIP PIPE/WORK ON RIG PUMP. DRLG T/12811. HI VIS SWEEP. TRQ WAS ERRATIC. SHORT TRIP-NO EXCESS DRAG.DRLG T/12930. NUDGED MW T/10.2+. PUMP AROUND HI VIS SWEEP. ROTATE/RECIP. BRING SWEEP UP T/LOWER TRQ. 10 STND SHORT TRIP. OK. DRLG T/12940. ERRATIC TRQ - MIGNT BE UNDERGAUGE. DRILLING MW:10.3 VIS: 59 DRLG T/12954. HIGH TRQ, LOW ROP. POOH AFTER CBU UNLOAD SOURCE/CHANGE BITS. SWAP OUT JARS-LEAKING. LOAD UP SOURCE ON LWD & SLIP DL. RIH T/12777. WASH & REAM T/BTTM. TRQ STALLED SEVERAL TIMES. RE-LOG INTERVAL 12876 - 12954. DRLG T/13030. TOPS COMING IN LOW & TD IS NOW PROBALBE @ +/- 13150 RUNNING CASG MW:10.3 VIS: 60 DRLG T/13152. REACHED 9.875 TD. CIRC HI VIS SWEEP. 10 STD SHORT TRIP. CBU CLEAN HOLE DROP SS SURV. CAME OUT @ 36 DEG. POOH LDDP. STND BCK 80 STNDS. UNLOAD SOURC CHK LWD LOGS- OK. LD BHA CLEAR FLOOR. CHANGE RAMS T/7-~" PULL WEAR RING & TEST SEALS T/3000. RU CASG TOOLS. RUN 7-5/8" CASG. RECEIVED JUL 1 9 1994 A~Ska Oil & Gas Cons. Gom~dssm~, WELL' : SDI 3-19 OPERATION: RIG : DOYON 15 PAGE: 05/29/94 (23) TD:13152 PB:10393 ND BOP'S MW: 0.0 Seawater RUN 7-5/8" CASG NO PROBLEMS GETTING T/BTTM. COULDN'T RECIPROCATE. CIRC & COND MUD GOOD RETURNS. TRIED MOVING PIPE - COULDN'T RECIPROCATE. RU BJ & TEST LINES T/3500. PUMP 20 BBLS SEAH20. 70 BBLS SPACER & 227 BBLS PRE. ECONO. MIX. @ 11.1 PPG. DROPPED BTTM PLUG & PUMP 300 SX PREM. DROP TOP PLUG & DISPLACE W/200 BBLS DIESEL & 400 BBLS. INHIB. SEAH20 @10.5 BPM. BUMP PLUG/RELEASE PRESS. FLOATS HELD. TEST CASG T/3500 F/30 MIN. OK. LD LNDG JT & CLEAR FLOOR. INSTALL & TEST PACKOFF T/5000. INSTALL FALSE BOWL, COILED TBG HNGR & TWC. CHANGE RAMS T/5". INJECT 120 BBLS MUD DOWN ANNUL. ND BOP'S. 05/30/94 (24) TD:13152 PB:10393 SIGNATURE: RELEASE RIG MW: 0.0 Seawater ND BOP'S. NU & TEST DRY HOLE TREE. SECURE WELL & INJECT 90 BBLS DIESEL DOWN INJECTION WELL (3-03) ANNUL. RIG RELEASED @ 11:00 ON 5/29. (drill~t) DATE: RECEIVED JUL 1 9 1994 AlaSka Oil & ~as ~;~s. ~r'. ORIGINAL 2.20 iNCLI~II~ 35~,40 RECEIYED JUL 3 9 1994 Anchorage ~-~ 3-19/R-28 ~t~'V~ C~LCUL~TIONS TARGET STATION AZIPEITH LATITU])E SECTI~ INCI~o N/-S ft dee dee ft 3,83 2.20 351.4C 8,73 3,83 348,63 13,51 14,30 6,23 347,03 21,65 23.26 7,78 334.89 32,77 35.60 9,68 329,51 45.65 I)EF'ARTURE DISPLACEI~HT at AZI~TH E/-W ft ft deg. -1,00 6,08 350,54 -2,37 I3.72 350,04 -4.16 22.05 34%13 -8,14 33,77 346,05 -15,02 48,06 341,79 dea/ lOOft 0.00 1,12 2,53 2,19 2.15 I145.&6 1237.55 1331.65 1426,29 1523,74 96.5 1141,82 91,9 1232,31 94.1 1325.~ 94,6 1418,46 97,5 1514,62 50,15 9,95 325.27 59.50 64,52 10,06 325,47 72,64 78.?I 9,41 324,30 85.66 92,69 9,18 325,9~ 98.20 106,79 9,48 326,94 111,37 -23,89 64,12 338,13 0,80 -32.96 79,77 335,59 0.13 -42,11 95,45 333,82 0,72 -50.85 110,58 332.62 0,38 -59,57 126,30 331,8~ 0.35 1617.15 1712,80 1807,46 1902,7I 1998.26 93.4 1606,74 95,7 1700,97 94,7 1794.03 95,2 1887,33 95.6 1980,56 120.73 9,61 323,9~ 124,12 135,33 10,14 329,05 137,80 150,28 10.92 330,40 152.73 167.25 12,32 324,39 168,84 186.73 13.05 318.11 185.16 -68.36 141.71 331,16 0.55 -77,40 158,05 330,&8 1.07 -8~.1I 175,33 330,59 0.~ -96.48 194,46 330,25 1.94 -109,62 215,17 329,37 1,63 20f~.59 2188,72 2284,32 2378,47 2474,68 ~.3 2073,27 95.1 2165.27 ~5.6 2256,94 94.1 2346.36 96,2 2436,75 208,10 13.90 312.47 200,90 · 231,79 15,57 309,~ 216,81 258.56 '17,39 307.70 233,78 287,81 19,11 305,8C 251,40 320,58 20,92 304.35 270,3I -125,25 L;:~,75 328,06 1.64 -143,47 25%98 326,51 1,89 -164,61 285,92 324,85 2,01 -188.24 314,07 ~F23, t8 1,94 -215.19 345,51 321.48 1,9'5 2570.21 2~.9,03 2803.52 2898.80 2992,24 ~.5 2525,31 98,8 2615,&6 134.5 2736,?0 95.3 2821.82 93.4 2903,85 356,12 23,13 308.~ 291,63 39S,62 24,65 30%11 316.73 453.17 26,63 307,15 352,63 496,11 Z7,30 304,27 377,83 540,73 29,91 902.94 402,57 -243.95 380,21 320,09 2.84 -275,12 419,54 319,02 1,56 -320,92 476,80 317.70 1.60 -356,00 519,13 316.70 1,54 -393,27 562.78 315.67 2,88 3089,01 3184.24 3278,4I 3374,00 346%90 96,8 2986,44 95,2 3065,62 94,2 3141,69 95.6 3216,88 95,9 3290,14 590,98 32,89 305.21 430,84 643.79 34,65 300,67 459,56 699,17 37,59 304,B2 489,63 7~8,00 38.69 303,~ 52~,95 819,57 41,67 306,28 b'5~),55 -435,00 612,25 314,73 3,30 -479,42 664.11 313,79 3.23 -526.03 718,64 312.95 4,06 -574,76 777,07 312,30 1,29 -625,35 838,48 311,77 3,48 3563,51 3658.33 3754,26 3849.87 3?45.74 93,6 3359,76 94.8 3430,28 95,9 3502,19 95,6 3574.04 95,9 3646,05 881,86 42.25 303.~ 594,45 945,15 41,65 301.20 628,48 1008.63 41.26 297,12 659,42 1071,64 41,30 296,86 688,05 1134,83 41.33 295,71 716,07 -676.60 900.64 311,30 1,91 -730.06 963,31 310,72 1,90 -785,48 1025.58 310,01 2,85 -841.70 1087,13 309.26 0.19 -898.45 I148,90 308,56 0,79 4038,67 4137,18 4228,80 4324.05 4420,52 92.9 3715,94 98,5 3790.3? 91.6 ~59.35 95,3 3930.79 96,5 4003,81 1195,98 41,12 296,92 743,22 1260,43 40,68 297,98 772.95 1320.71 41,68 296,74 8(X).66 1383,64 41,15 296,71.. 829,03 1446.47 40,49 293,17 855,64 -953,35 1200.82 307.94 0,89 -1010,59 1272,30 307,41 0.83 -1064.17 1331.73 306.96 1.41 -1120,44 1393,79 306,50 0,56 -1177,57 1455,61 308,00 2,52 IqEASLIR£DINT£RUAL UER?ICAL I)EPTH i)EFfH ft ft ft 4515,55 95.0 4075.68 4715,81 200.3 4226.04 4811,06 ~.3 42?7,07 4906,05 95.0 4367,36 5001,43 95.4 4437,85 ************* AHAb:ILL ****~:~****** SU~JEY CALCL~A?~ON~ TAE~T 9TATIDN ~IMUTH LATITUDE SEL'TIOH INCLN. N/-S ft deg de9 ft 1508,34 41,23 294.76 880,90 1640,3;3 41.45 297,21 938.84 1703,74 42,13 296,78 967,65 1767,47 42.41 294..3'; 995,24 1831.53 42.29 295.92 1022.55 '~ 3-19~-28 I)~q~LIRE DISPLACEMENT at t:/-W ft ft -1234,37 1516.46 -1:353,25 1647,03 -1409.82 1709.95 -1467,44 1773,10 -1525.59 1836,58 AZIMUIH deg 905,51 304,75 904.46 304,15 303.83 DLS deo/ lOOft 1,34 0,82 0.78 1,72 1,09 5096,24 5188,00 5286.50 5378.~ 5476,08 ~4.8 4508.65 91.8 4578.35 98.5 4653.95 92,1 4724,47 97,4 4797.58 1894,42 41,~ 295..04 104%68 1953.90 40,05 294.57 1074.72 2016,81 99,68 294.~ 1101,02 2075.96 40,42 297,55 1127,12 2140.37 42.36 298,~ 1157,60 -1582.51 1898,99 303.56 -1636.69 1958.00 903,29 -1694,10 2020,45 303,02 -1747,31 2079,30 302,82 -1804,06 2143.52 302,69 1,40 1,18 0.38 2,16 2.19 55~B. 19 5663,28 5752,98 5849.45 5948.19 92.1 4864.~5 95,1 4934.30 89,7 5000.52 96.5 5071,60 98.7 5144,02 2203,I8 43,65 298,26 I187,64 2268,17 42.~ 296,53 1217,58 2328,62 42,16 297,63 1245,12 2393.81 42,93 297,24 1275,17 2460.83 42.7I 295,79 1305,13 -1859,23 2206,18 902,57 -1916.98 2270,97 302,42 -1970,85 2331,22 302,28 -2028,75 2396,23 302,15 -2088.81 2463,02 902,00 1,47 1,61 1,01 0,85 1.02 6043.71 61~,35 6230,39 6325,97 6420,35 95,5 5214,11 ~,6 5284,47 91,0 5351.27 95.6 5420.36 94.4 5487.84 2525,53 42,89 294,4C 1332,65 2590.11 42.3? 295:,94 1360.20 2651.81 43,22 294,95 1386.77 2717,60 44,16 294,65 1414,47 2783.39 44,59 29%2?_ 1442,90 -2147,58 ~27,46 301,82 -2206,20 25;91,81 901,66 -2262.06 2653.31 301.51 -2322.00 2718,8~ 301.35 -2381,84 2784,49 301,20 1,01 1,21 1,18 1.00 0.62 6516.33 ~11,61 6707,40 ~03,54 6897,29 96,0 5556.06 95.3 5623.64 95,8 .5691,90 96.1 5760.81 93,8 5827,95 2850,68 44,82 294,64 1470,76 2917.56 44,82 294,04 1498,44 2984.47 44,29 294,42 1526,02 3051,30 44,14 295.58 lb'54,35 3116,64 44,38 297,80 1583.74 -2443.07 2851.61 301.05 -2504,26 2918.33 900,89 -2565,54 2985,08 300.74 -2626,30 3051,80 300,62 -2684.76 3117.08 900,54 0,49 0,45 0,62 0.85 1,67 6996,27 7085,82 7187,81 7282.48 7379,99 ~9,0 5898,77 89,6 5962,86 102.0 6035.71 94,7 6103,04 97,5 6172,15 3185.76 44,25 298,91 1616,58 3248,31 44,36 2"~',80 1647,24 3319,68 44,47 298.30 1681.9'0 3386,23 44.86 29%62 1714.13 3455.00 44,88 297,2.6.- 1746,89 -2745,60 3186,16 306,49 -2800,12 3248,70 900,47 -2862,51 3320.06 300.44 -2920,74 3386,58 300,41 -2981,22 ~,33 300,37 0.00 0,70 1,03 1.06 1.70 7475,48 75-/1.71 7664,43 7760,61 7855.01 95,5 6239,70 96,2 6307,36 92.7 6372,33 ';:6,2 6439,55 94.4 65O5.2O 3522,43 45,08 296.B9 1777,61 3590.83 45,57 298,87 18~:)9.61 3656.95 45,49 296,52 1840,36 3725,67 45,82 298.3~ 1872,07 3793,46 46,06 296,77 1903,47 -3041,32 35;22,71 300,31 -3101,80 3591,08 300,26 -3160,38 3657,17 900.21 -3221.40 3725,86 300,t6 -3281,53 3793.63 900,12 0,35 1,55 1.81 1,44 1.26 7947,16 8~1.41 8137,57 8234.21 8327,37 92,1 6569,14 94.3 6634.~ 96.2 6702.20 96,6 6769,74 ~,2 6834,57 385%00 46,0~ 299,75 1934,89 ~7,38 45,54 299,37 1968,24 3995,99 45,53 301,52 2003,01 4065,04 4%78 302,19 2037,48 4131.80 46,03 304.42. 2076,22 -3337.97 3859,95 300,08 -~'~98.75 3927,53 300.08 -3457,91 ~6.15 300,08 -3516,61 4065.22 300,I1 -3572,52 4132.02 900,t6 2.33 0.65 1.59 0,56 1,74 MMS~ INTI~L Vi~TI~ T~E? STATION ~ZI~]TH LATITUDE I)EF%~TcE<E DISPLACEMENT at ~ZI~UT~ DL~ DEFt'H DEPTH SECTION IltCLN, ft ft ft ft dea de~ ft ft ft de~ lOOft t~127,38 100.0 6~4,34 4203.30 45.50 302.1t~ 2115,56 -3632,40 4203,5~ 300,22 1,69 8523,24 95.9 6971,82 4271.31 45.02 302,57 2152.02 -3689,91 4271,61 300.25 0.59 8618,67 95,4 703%40 4338,61 44.81 30h97 2187,99 -3746,87 4338,94 300,28 0,50 8714.48 95,8 7107.40 4406,01 44,76 303.23 2224.36 -3803.73 4406.38 300.32 0,92 8807.70 93.2 7173.76 4471,40 44.47 301.54 2259.42 -385%02 4471,80 300,35 1,31 8898.48 90.8 7238.54 4534.94 44.48, 302.61 2293.19 -3912.91 4535.37 300.37 0,83 8992.93 v4.5 7305.91 4601.03 44.52 303.27 2329.19 -3968.47 4601,51 300,41 0.49 9091.80 96.9 7376.53 4670.09 44.32 303.05 2367.04 -4026.40 4670.63 .':100.45 0.26 9187,45 95.6 7444.56 4737.15 45.01 304.28 2404.31 -4082.35 4737.75 300,50 1.16 9282.33, 94.9 7511.44 4804,24 45.35 303.74 2441,95 -4138.14 4804.93 300.55 0.54 9377.96 95.6 7578.47 4872.28 45.65 1303.7(; 2479.81 -4194.88 4873,03 300,59 0.32 9471.93,, 94,0 7644.60 4938.87 44.90 303,72 2516.86 -4250.42 4939,70 300.63 0.81 9567,03 95.1 7711,80 5005.99 45.17 303.29 2554.00 -4306.52 5006.90 300,67 0.43 9854.02 97.0 7779.91 5074.85 45.61 304,42 2592.48 -4363.86 .5075.85 300.7I 0.95 9760.31 96.3 7847.57 5143.27 45.13 300.43 2629.21 -4421.67 5144.31 300.74 3.00 9855.63 95,3 7914.63 5210,99 45,~. 301,14 2663.88 -4479.88 5212.06 300.74 0.63 9947.90 92.3 7980,21 5275.88 43.94 298.47 2696.15 -4536.17 5276,94 300,73 2.62 10042.73 94,8 8048.,~ 5341.85 44.23 301,32 2729.03 -4593.36 5342.9'0 300.72 2.11 10138.33 95.6 81t7.20 5408,15 43.61 298.44 2762.06 -4650,84 540%19 300,71 2.19 10233.65 95.3 8186.78 5473.25 42.62 296,69 2792.21 -4708.59 5474.23 300.67 1.63 10328.83 95.2 8256,69 5537.79 42.86 297.87 2821.82 -4765.99 5538.72 300,63 0.88 10424.7r~ 96.0 8326.96 5603.12 42.98 298.45 2852.66 -4823.61 5604.01 300.60 0.43 10519.13 94.3 8395.99 5667.41 42.97 297.87 2883.02 -4880.31 5668,26 300,57 0.42 10616.01 96.9 8466.87 5733,41 42.97 297.88 2913.89 -4938,68 5734.22 300.54 0.03 10711.57 V5.6 8536.53 5798.82 43.43 299.~ 2945.30 -4996,06 579?.60 300.52 1.26 10804.80 93,2 8603.88 5863.29 44.06 299.56 2977.07 -5052.15 5864.06 300.51 0.68 10'902.87 98.1 8674.32 5931.52 44.11 2W.2,!,. 3010.57 -5111.59 5932.28 300.50 0.22 10997.08 94.2 8741,98 5f~7.0~ 44.~ i~,10 3042.53 -5168.83 5997.82 300.48 0.12 11093.58 %+5 8811.11 6064.40 44.41 301.44 3076.48 -5226.98 6065.15 300.48 1.72 11188.81 95.2 8878.91 t,131.23 44.78 300.98 3111,12 -5284.16 /)132.00 300.49 0.51 11281.40 92.6 8944.53 6196.5'5 44.97 299.~. 3144.23 -5340.48 6197.33 300.49 0.84 11376.34 94.9 9011,86 ;6263.48 44.69 301.04 3178.i7 -5398.17 6264.26 300,49 0.89 1147%05 102.7 9085.33 6335.24 43.97 2<;'9.72 3214.48 -5460.08 6336,03 300.49 1.14 115',75,10 96,0 9154.08 6402.28 44.62 302.37 3249,07 -5517.53 6403.09 300.4'9 2.04 11666,97 91.9 9219,31 6466.96 44,93 29%98 3282.56 -5572,89 6467.79 300,50 1.67 11762.21). ?5.3 9286.50 6534.54 45.41 300.40 3316,54 -5631.31 6535.38 300..'50 0.59 11859.93 97.7 9354,56 6604.56 46.22 299.32 3351.40 -5692.04 6605.39 300.49 1.14 11956.7'9 96,9 9422.(:,0 6673.49 44.53 301,09 3386,07 -5751.62 6674.32 300.4? 2.17 12053.12 ~6.3 9492,44 6739.74 42.54 303.9C 3421.68 -5807.59 6740.62 300,51 2.88 12143,84 90.7 9560.29 6799.76 40.62 304.48 3455,51 -5857.3~ 6800,71 300,54 2,15 ~ 3-19/R-2G ************* ANA1)~I~ ****~********* SURreY CALCULATIONS ~,~ CIRCU~ ~C ~~* ~~ I~L ~TI~L T~ ~ATION ~I~H ~TIT~ g~~ gI~LAC~ at AZI~ gLS DE~ D~ S~I~ I~LN. N/-S E/-W ft ft ft ft deq deg ft ft ft deg l~ft 122~.78 96.9 9~.~ ~,15 ~,~, 307,32 ~9~.70 -5~7,44 ~2.21 ~0.57 2.~ 1~38,01 ~7.2 9711.~ 6~.~ 37.0I ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 July 1994 RE: Transmittal of Data ECC #: 6217.01 Sent by: ATLAS WIRELINE Data: PL Dear Sir/Madam, Reference: BP 3-19/R-28 SDI NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 ~FC/GR/CCL FINAL BL 1 PFC/GR/CCL FINAL RF Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) In¢ 900 East Benson Boulevard Anchorage, Alaska 99508 Received by ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 7 June 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION ECC No. 3-19/R-28 SDI ~/SBT/GR/CCL FINAL BL 1 PFC/PACKER FINAL BL 1SBT/GR/CCL RF SEPIA -T'PFC/PACKER RF SEPIA Run # 1 6217.00 Run Run # 1 Run ~ 1 ' 3-25/M-27 SDI /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA Run ~ 1 5614.05 Run 3-17/J-30 1 PLS FINAL BL 1 PLS FINAL RF SEPIA Run # 1 6005.03 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: Attn. Rodney D. Paulson Oil~as.~ Date: Please s i~n and return to: Petrotechnical Data Center BP Exploration (Alaska) 900 East Benson Boulevard Anchorage, Alaska 99508 Received by Date CONSERVATION COMMISSION U~l ~ ' . WALTER J. HIGKEL, GOVERNOR ALASKA OIL AND GAS ^.C.OR^e~, ~L~SKA ~0~-3~ .HO.~: (~ ~-~ T~L~CO.V: (~ March 31, 1994 A. C. Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island/EndicOtt 3-19/R-28 BP Exploration (Alaska), Inc. Permit No: 94-49 Sur. Loc. 2756'NSL, 789'WEL, Sec. 8, TllN, R17E, UM Btmhole Loc. 1267'NSL, 1857'WEL, Sec. 6, TllN, R17E, UM Dear Mr. Clark: 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 inspector on the North Slope pager at 659-3607. S' Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,"7, )'.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill E]llb. Type of w;I-I. Exploratoryr-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenDI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=55.8 feet Endicott Field/Endicott Pool 3. Address 6. Property De~s'ignation P. O. Box 196612~ Anchorage~Alaska 99519-6612 ADL 47502 4. Location of well at surface 7. Unit or property Name 11. Type Bond(-, 20 ~c 25.025) 2756' NSL, 789' WEL, SEC. 8, T11N, R17E Duck Island Unit/Endicott At top of productive interval 8. Well number Number 1108' NSL, 1586' WEL, SEC. 6, T11N, R17E 3-19/R-28 2S100302630-277 At total depth 9. Approximate spud date Amount 1267' NSL, 1857' WEL, SEC. 6, T11N, R17E 4/1/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well t4. Number of acres in property 15. Proposed depth (MO and TVD) property line ADL 34636-3421' feet 3-17/J-30-8'~ 746'MD feet 2560 13477' MD/10248' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (=e, 20 ^Ac 2s.oss (,)(2)) Kickoff depth 2600 feet Maximum hole angle 4a.a~ Maximum surface 3900 pslg At total depth (TV•) 10000Y4890 pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 30" Struct. Drive Pipe 90' Surface 40' 130' 130' Drive 13-1/2" 10-3/4" 45.5# NT80 BTC 2663' 37' 37' 2700' 2696' 455 sx PF "E"/37~ sx "G"/250 sx PF "C" 9-7/8" 7-5/8" 29.7# NT95H$ NSCC 12882' 37' 37' 12919' 9937' 739 sx Class "G" 6-3/4" 5-1/2" 17# NT-80 NSCC 807 12670' 9773' 13477' 10304' 126 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 SurfaceRECEIVED Intermediate Production MAR 2 4 1994 Liner Perforation depth: measured A~sk~. 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program I~l~ime vs depth I:~Ot [] Refraction analysis l-I Seabed report• 20 AAC 25.050 requirements[] 21. I herebxcertify that ~hff~f(;~f~oing is/,/Jrue and correct to the best of my knowledge Signed ~L~ / ~/('~~~ CommissionTitleusoDriilingEngineerSupervis°r Only Date Permit Number IAPI number IApp~al date See cover letter ~"-- .~"~ ]50- ~ ~_ ~'-- Z.. ~_. ~'~'-~I ~' ,~.//--~'~,~' for other requirements Conditions of approval Samples required [] Yes J~ No Mud Icg required [] Yes I~ No Hydrogen sulfide measures [] Yes !~1 No Directional survey required ~ Yes [] No Required working pressure for BOPE []2M; 1-13M; ~5M; I-I10M; ~15M; Other: by order of Approved by Commissioner ~ne commission Date Form 10-401 ReV. 12-1-85 Submit in trii Well Name: ! 3-19/R-28 Well Plan Summary I Type of Well (producer or injector): IPRODUCER ISurface Location: Target Location: I Bottom Hole Location: 2756' FSL, 789' FEL, SEC 8, TI IN, R17E 1108' FSL, 1586' FEL, SEC 6, TllN, R17E 1267' FSL,. 1857' FEL,SEC 6, T11N, R17E IAFENumber: [717488 ] I Estimated Start Date: 1 4/1/94 [ [ Operating days to complete: 1 36 I ]MD: I 13,477' I ITvD: I 10,248'SSl I KBE: 1 55.85' I Well Design (conventional, slimhole, etc.): [ SLIMHOLE / 3-1/2" Coil Tb[[ Completion I Formation Markers: Formation Tops MD TVD (BKB) Permafrost 1471 1471 Surface Cst~ Pt 2700 2696 TUI~YS 11,208 8811 HRZ 12,167 9442 ITKILYARIAK 12,554 9697 KEKIKTUK 12,934 9947 TARGET 13,059 10,029 TD 13,477 10,304 D i:Fl:l~ ~ I., %.,I.. I w ~,~ ~.. 4 i ED ,94 Commission Anchora{]e Casin /Tubin~ ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD Driven 30" Struct. WLD GL Preset 13-1/2" 10-3/4" 45.5# NT-80 BTC 2663' 37'MD 2700/2696 9-7/8" 7-5/8" 29.7# NT-95HS NSCC 12882' 37' MD 12919/9937 6-3/4" 5-1/2" 17# NT-80 NSCC 807' 12670' MD 13477/10304 TBG 3-1/2" 0.19" L-80 12633' 37'MD 12670' MD CT WT Well Plan Summary 3-19/R-28 Page 1 Logging Prog ram: Open Hole Logs: SURFACE DIRECTIONAL (MWD & GYRO) INTERMEDIATE [MWD Directional ' PRODUCTION [ #1-DLL/MSFL/GR; #2-LDT/CNL/GR; #3-10-15 RFT's Cased Hole Logs: [ SBT/CBL f/TD TOC I Gyro (After Ri~ Release) Mud Program: I Special design considerations I Fresh water dispersed mud to TD Surface Mud Properties: [ 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 csg pt. 9.5 100 20-40 15-20 20-30 9-10 15-25 Intermediate Mud Properties: ] Fresh / lightly dispersed Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5-9.8 50 15-25 12-15 25-30 9.5-10 <12 9.8-10.5 50-60 20-30 12-15 25-30 9.5-10 6-8 Production Mud Properties: ] Fresh/lit~htly dispersed Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.2 50 15-25 12-15 25-30 9.5-10 <8 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. RECEIVED Directional'. JKOP: J Nudge @ 600'; KOP @ 2600' I departure = 7405'@ TD J Maximum Hole Angle: [ 48.84 DEG; 300 DEG Azimuthclose Approach Well: M,bq .P. 4 1994 ~,. ,~. ~,, · Gas Cons. Commission Anchorage I Well Plan Summary 3-19/R-28 Page 2 WELL 3-19/R-28(SDI} PROPOSED DRILLING AND COMPLETION PROGRAM Objective Well 3-19/R-28 will be drilled from the Endicott SDI to produce reserves in the Kekiktuk formation. The well will be completed with a 3-1/2" coiled tubing completion. The cost estimate includes the associated coiled tubing running costs and accessories. Operation Execute a rig move and rig-up. Directionally drill surface hole with a 8.5 - 9.5 ppg mud system to proposed depth. Run and cement 10-3/4" 45.5#/ft NT- 80 buttress casing to surface. Pressure test casing. Install BOPE. Drill out casing and 5 ft. of new hole and conduct a formation leak-off test. Directionally drill 9-7/8" hole with a 9.0 - 10.2 ppg mud system to the Kekiktuk formation. At this point the decision will be made to drill ahead to TD and long string the well or set intermediate casing. Hole conditions will be the main concern as to whether to set casing before drilling the producing interval. The long string or intermediate will be 7-5/8" 29.7#/ft., NT95HS, NSCC casing. No abnormal pressures are expected in the 9-7/8" hole section. If the 7-5/8" casing is set above the Kekiktuk, then a 6-3/4" hole will be drilled to TD. Then open hole logs will be run. Run and cement 5-1/2" liner. Clean out liner and displace to brine. Pressure test casing. Nipple up dry hole tree and release Rig. Run SBT/GR/CCL/gyro in the 5-1/2" liner and 7-5/8" casing. Complete well with coiled tubing assembly. A subsurface safety valve will be installed below base of permafrost. Fluids incidental to the drilling of the well will be pumped down the 10-3/4" by 7-5/8" annulus of the well. The 10-3/4" x 7-5/8" annulus will be freeze protected with a non-freezing fluid down to 3000 feet once the rig is released. DKC 3/24/94 RECEIVED MAR ;~4 1994 Anchorage CEMENT PROGRAM -HALLIBURTON 10-3/4" SURFACE CASING CASING SIZE: 10-3/4", 45.5# CIRC. TEMP: 40°F LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: Z. 17 ft/sx gps APPROX. SACKS: 455 THICKENING TIME: 5+ hrs MIX WATER: 11.63 TAIL CEMENT ,TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx 5.00 gps APPROX, SACKS: 375 THICKENING TIME: 4 hrs MIX WATER: TOP JOB CEMENT TYPE: Type 'C' Permafrost ADDITIVES: retarder WEIGHT: 15.6 ppg YIELD: 0.94 ft3/sx MIX WATER: 3.5 gps APPROX. SACKS: 250 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 1. Lead slurry + 375 sx Tail slurry w/40% excess over gauge hole. Z. Top job volume 250 sx. 7 5/8" INTERMEDIATE CASING CASING SIZE: 7 5/8", 29.7# CIRC. TEMP 135°F LEAD CEMENT TYPE: Premium ADDITIVES: 0.5% CFR-3 (Dispersant) + 3% Econolite (Extender) + 0.4% Halad-344 (Fluid Loss) WEIGHT: 11.0 ppg YIELD: 3.;?4 ft3/sx ;?0.4 gps APPROX. SACKS: 539 PUMP TIME: 5+hrs TAIL CEMENT TYPE: Premium ADDITIVES: 0.;?% CFR-3 (Dispersant) + 0.;?% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx 5.0 gps SACKS: 200 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. SPACERS: Pump 20 bbls Sea Water; 50 bbls ARCO spacer @ 11 ppg. OTHER CONSIDERATIONS_.' Continuously mix lead and tail slurries. Displace at 1 ;?-15 bpm with rig pumps. CEMENT VOLUME 1. Lead Slurry based 90% of hole volume to surface casing shoe. 2. Tail Slurry to 750' above shoe w/30% excess + 80 ft. shoe. MIX WATER: MIX WATER: ECEIVED 3-19/R-28 5-1/2" LINER CASING SIZE: 5-1/2", 17# CR-13 ~,J~?~: 140° F CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.5% Halad-344 (Fluid Loss) + HR-5 (Retarder) Retarder (HR-5) concentration to be based on actual lab tests. WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 126 THICKENING TIME: 3 hrs + 1 hour @ surface SPACERS: 20 bbls Sea Water _ 50 bbls ARCO spacer, weighted 1 ppg above MW. 20 bbls Fresh Water 20 bbls Super Flush 20 bbls Fresh Water OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc to 60cc/30 mins. Displace @ 8-10 bpm. LINER CEMENT VOLUME 1. Open hole (6-3/4" X 5-1/2") annulus + 50% excess. 2. 5-1/2" 17# casing capacity below landing collar (80 feet). 3. 150' liner lap (7 5/8" x 5-1/2" liner) 4. 200' of cement on top of the liner in the 7-5/8" casing (without DP in hole). MA, R 2 4 '~994 6as Gons. Gommiss~o~ Anchorage 3-19/R-28 .... P'RUDH'OE' B'AY DRT _LING GROUP ---i · i iii ..__ i i . ! ~ .. iiii ?'3-~9/R-28 (P2) VERTICAL SECTION VIEW , · _ii ii ii ill i . i i _ j Section at; 300.38 TVD Scale.' 1 inch = 1400 feet Scale ~ inch = 1400 feet i i Drawn ..... : 02/1:I/94 I ! ' ~ i /nadri]] SchJumberger. . ~. , I ! Marker ld~nti;ication MD BKB SECTN !NCLN ~ ~00 ~ ' ~ · B} NUDe6 KOP 1.5/100 600 600 -0 0.00 2100- I .E.. - CJ END ~.5/JO0 BUILD ~000 999 ~7 6.00 i I [ I .~ O) CURVE ,/~00 t400 J397 50 .6.00 ~ ~ E) END J/~OO CURVE ~000 ~996' 75 0.00 O~_ i r - , G) ~ND 2/100 CURVE 50~2 4753 ~054 48.94 8800~ I " ~ H) ~RGET ~3059 ~0029 7090. ~8.8~ I [ : i I) fD 13477 ~030~ 7A05 48.84 :$oo~ ..... f-.. ....... ' ...................... j .~ ~ , , 5BO0 -- , ~ I 6300 .......... '- , ' ' I )000-- ! =oo-- ~ .. ~ _" .... - % . , ~.,,E , _ ! ~ [ M a It 2 ~ 1994. f ~ .... ~ .......... 9800 '~?'~r e~o ...... a .......... , ..................... , : iIiii~i~ ~li iiliI~IiiI ii ii ~iii~ ~¢m~" ~ ..... : :~ i ; ..... ~.~~ I - ~40C -700 0 700 1400 2100 ~800 3500 4200 4900 5600 6300 7000 7700 8400 _ Sect lon Deoarture ~;r~Jl iris3 i~.22~ B;.52 ~:~ A,~ ~} . · ' ' , ' .................. PR'UDHO~' BAY OR T_ EL zNe' GROUP - " ii i _il ii iii : ~ ill _ i i i i . ii i _ . · -- J . i iii i i i i - i i i~_. · i iii ._ i ii i --ii EA) ~B o o ~ END ],5/100 BU!LO ,000 19 248 PLAN VIEW ~,, c,.,F~¥~ ,/,oo ~,,oo ~ ........... -. -- . ........... E) ENO-~/lO0 CURVE 2000 87 36 CLOSURE ' 7,405 fee[ at: Azimutr~ 300,82 F) CURVE 2/~00 26o0 87 36 G) t-ND 8/100 CURV~ 50.42 582 88', ;DECLINATION.' 30.000 E HI TAR,SET '~3059 3535 6088 SCALE ' :t inch = 1000 feel )) TD '~3477 3794 8359 DRAWN ' 02/~1/94 ........ i __ ~4nadr ~ ] ] Schlumberger 40OO R :C .I.VED j ~/~XR 2 ~ 1994 ~ f % ~'~aska Oi & Gas C)ns. Corn; tis$ion ~ J , ~' j' '- ., · . ., J. ,,, u ~00 FT TAF ~ET J ...... _ ..... 5500 6000 5500 5000 t500 4000 3500 3000 2500 ~000 i500 1000 500 0 500 .... <- K~ST' EAST -> .~:~rj]] '(~]9J ~J~8~2 8J.52 ~; 4~ ~,~ ~] ...... ' ........................... . WELL PERMIT CHECKLIST 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. ENGINEERING Permit fee attached ................... N Lease number appropriate ................ N Unique well name and number ............... N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary.. N Well locatedproper distance from other wells ...... N Sufficient acreage available in drilling unit ...... N If deviated, is wellbore plat included ........ . N Operator only affected party .............. N Operator has appropriate bond in force ......... i 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 28. 29. dev~ redr11 [] serv [] ON/OFF SaOR~ ~ ~ 15. Surface casing protects all known USDW, ........ 16. CMT vol adequate to circulate on ~ini~ ~ - ~ surf csg. 17. CMT vol adequate to tie-in surf csg to next string .... 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost.. , . 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............ ~_ ........ BOPE press rating adequate; test to ~~ psig.~ Choke manifold complies w/API RP-53 (May 84) ...... Work will occur without operation shutdown ....... Is presence of H2S gas probable ............. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... ¥ .~ ~~ 32. Seismic analysis of shallow gas zones .......... Y/ 33. Seabed condition survey (if off-shore) ......... ~ N 34. Contact name/phone for weekly progress reports ..... N [explorator~ only] ~EOLO~Y: ENGINEERINg: COMMISSION: Comments/Instructions: Z HOW/jo - A:~FORMS~cheklist rev 01/94 Well t-iistory File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * . . ******************~********w** * ............................ . * ....... SCHLUMBERGER ....... * . ............................ . COMPANY NAME : BP EXPLORATION (ALASKA) WELL NAME : 03-19/R-28 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292246300 REFERENCE NO : 98576 RECEIVED NOV 1 3 1998 Alaska 0il & Gas Oons. Commission Anchorage LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 9 ORIGIN : FLIC REEL NAME : 98294 CONTINUATION # : PREVIOUS REEL : COF~_iFT : BP EXPLORATION, 3-19/R-28, ENDICOTT, API# 50-029-22463-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/ 9 ORIGIN : FLIC TAPE NAME : 98294 CONTINUATION # : 1 PREVIOUS TAPE : COMFIENT : BP EXPLORATION, 3-19/R-28, ENDICOTT, API # 50-029-22463-00 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NAME: 03-19/R-28 API NUMBER: 500292246300 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 9-NOV-98 JOB NUMBER: 98576 LOGGING ENGINEER: C. YON OPERATOR WITNESS: D BARBA SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 IN RANGE: 17E FNL: FSL: 2756 FEL: 789 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 55.80 DERRICK FLOOR: 55.80 GROUND LEVEL: 14.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 875 7. 625 13142'. 0 29. 70 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS AU]FiBER: DATE LOGGED: 28-MAY-94 LOGGING COMPANY: BASELINE DEPTH .............. 88888.0 12941.0 12936.5 12930.0 12923 5 12918 0 12917 0 12914 5 12908 5 12907 5 12901 12898 5 12894 0 12887 0 12883 5 12874 5 12874.0 12873.0 12868.0 12867.5 12863.5 12859.5 12858.5 12856.5 12854.5 12853.0 12852.0 12849.0 12848.5 12846.5 12840.5 12839.0 12837.0 12832.0 12831.5 12830.5 12827.0 12826.0 12823.5 12819.5 12818.5 12803.0 12802.0 12800.5 12796.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88880.0 12933.0 12928.0 12919.5 12914.5 12911.5 12904.0 12893.5 12890.0 12883.5 12880.0 12871.0 12869.0 12864.5 12859.5 12855.5 12853.0 12851.0 12848.0 12845.5 12843.5 12838.0 12835.5 1283 O. 5 12828.0 12824.0 12820.0 12816.0 12798.5 88891.0 12933.0 12925.5 12919.0 12904.0 12896.5 12893.5 12871.0 12864.5 12856.0 12851.0 12848.0 12838.0 12835.5 12830.5 12824.5 12816.0 12800.0 12798.5 12792.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 12789 . 5 12785.5 12788.5 12785.5 12782.0 12779.0 12779.5 12776.0 12779.0 12776.0 12772.0 12770.5 12762 . 0 12761.5 12761.5 12761.5 12759 . 5 12758.0 12754 . 5 12753 . 5 12753 . 5 12753 . 5 12749.5 12749.0 12746.5 12747.0 12745.0 12745.0 12742.5 12742.0 12741.5 12742.0 12739.0 12739.0 12736.5 12737.0 12734.5 12735.0 12725.5 12725.5 12719.5 12718.5 12717.5 12718.5 12715.0 12714.5 12714.0 12714.5 12712.0 12711.5 12710.0 12709.5 12707.5 12706.0 12696.0 12695.0 12686.5 12684.5 12681.5 12680.5 12676.0 12676.5 12674.5 12676.0 12667.0 12667.5 12666.5 12666.5 12664 . 0 12663 . 5 12663 . 5 12663.5 12658 . 0 12658.5 12654.5 12654.0 12653 . 0 12654.0 12639.5 12640. O. 12634.0 12633.5 12626.5 12625.0 12626.0 12625.0 12621.5 12621.0 12619.5 12618.0 12619.0 12618.0 12613.5 12612 . 0 12607.0 12607.0 12604.5 12603.5 12603.0 12602.0 12599.0 12598.5 12598.5 12598.0 12596.0 12593.5 12594.5 12594.0 12591 . 0 12590.5 12587.0 12585.5 lO-NOV-1998 10:08 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 12585.5 12574.5 12573.5 12567.5 12567.0 12561.5 12561.0 12557.5 12556.5 12556.0 12553.0 12551.5 12550.5 12549.5 12546.5 12546.0 12542.5 12539.5 12535.5 12532.0 12528.5 12526.0 12522.5 12521.5 12517.0 12516.0 12512 5 12509 5 12507 5 12501 0 12500 5 12494 0 12493 0 12492 0 100 0 $ RE~ARKS: 12584.5 12573.0 12566.5 12560.5 12558.0 12556.0 12552.5 12551.0 12549.5 12546.5 12541.5 12539.0 12534.5 12531.0 12527.5 12520.0 12515.5 12511.0 12507.0 12500.0 12492.5 12491.0 98.0 12573.0 12566.5 12561.0 12556.0 12551.0 12546.5 12531.0 12524.0 12520.0 12515.5 12507.0 12500.0 12491.0 99.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIREDON BP EXPLORATION'S 3-19/R-28 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE MWD GAMMA RAY, ALSO BASE PASS #1SIGMAAND THE MWDGAMIVlARAY, CARRYINGALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 5 FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREmENT: 0.5000 FILE SUMFIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12938.0 12276.0 RST 12960.0 12277.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 6 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 CIRNFIL 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 BSAL RST PPK 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1239887 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12960.000 NBAC. RST 2434.225 FBAC. RST 3321.713 SBNA.FIL SFNA.FIL 19.139 SBFA.FIL 44.233 SFFA.FIL 15.895 TRAT. FIL IRAT. FIL 0.515 CIRN. FIL 1.258 CIRF. FIL 2.692 BSAL.RST SIBF. RST 33.231 TPHI.RST 22.768 SFFC.RST 12.484 SFNC.RST SIGM. RST 12.488 DSIG.RST 0.539 FBEF.RST 28.181 CRRA.RST GRCH. RST -999.250 TENS.RST 1499.000 CCL.RST 0.013 51.184 0.918 31.795 13.410 1.908 DEPT. 12276.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL -999.250 SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL -999.250 IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST -999.250 SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST -999.250 SIGM. RST -999.250 DSIG.RST -999.250 FBEF.RST -999.250 CRRA.RST -999.250 GRCH. RST 100.823 TENS.RST -999.250 CCL.RST -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center lO~NOV-1998 10:08 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREI~ENT: 0.5000 FILE SUF~rn~RY LDWG TOOL CODE START DEPTH STOP. DEPTH GRCH 12939.5 12294.5 RST 12960.5 12295.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR. SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 12934.5 12932.5 12930.0 12925.0 12923.5 12922.5 12917.5 12908.0 12907.0 12901.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88881 . 5 88891 . 5 12926.0 12920.5 12919.0 12914.5 12904.0 12938.0 12933.0 12926.0 12919.0 12904.0 12897.0 LIS Tape Verification Listing Schlumberger Alaska Compu ting Cent er lO-NOV-1998 10:08 PAGE: 12898 0 12894 5 12893 5 12891 5 12887 5 12880 5 12879 0 12874 5 12873 5 12873 0 12868 0 12867 5 12862 5 12859 0 12856.5 12855 0 12~54 0 12853 0 12851 5 12848 5 12848 0 12846 0 12844 0 12840 0 12839 0 12836.5 12836.0 12833.0 12831.5 12829.0 12825.5 12822.0 12819.0 12818.0 12812.5 12812.0 12808.0 12803.0 12801.5 12800.5 12796.5 12789.0 12788.0 12780.0 12778.5 12774.5 12772.0 12770.5 12768.0 12763.5 12762.0 12761.5 12757.0 12748.5 12746.0 12893.5 12890.5 12886.5 12883.5 12876.5 12871.0 12869.0 12864.5 12855.5 12853.0 12851.0 12848.0 12845.5 12843.5 12838.0 12835.5 12830.0 12822.0 12820.0 12816.0 12809.0 12798.5 12785.5 12776.0 12773.0 12769.5 12763.5 12761.0 12749.0 12893.5 12878.0 12871.0 12864.5 12860.0 12853.0 12851.0 12848.0 12843.5 12838.0 12835.5 12830.5 12828.5 12820.0 12816.0 12810.0 12806.5 12800.0 12798.5 12793.0 12785.5 12776.0 12771.0 12767.0 12761.5 12757.5 12747.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 12742. 12737. 12736. 12731. 12727. 12724. 12719. 12717. 12712. 12711. 12707. 12704. 12703. 12700. 12694.5 12690.5 12686.0 12681.5 12679.5 12678.0 12675.5 12672.5 12671.5 12666.0 12664.0 12663.0 12655.0 12652.0 12648.5 12639.0 12636.5 12626.5 12625.0 12620.5 12613.5 12610.0 12609.5 12604.5 12604.0 12598.5 12594.5 12591.5 12591.0 12585.5 12584.5 12582.0 12574.0 12573.0 12570.0 12567.5 12567.0 12563.5 12560.5 12557.5 12556.0 0 12742.0 5 0 12737.0 5 0 5 0 12719.0 5 0 5 12711.5 0 ~ 12706.5 5 12704.5 0 12703.0 5 12695.0 12690.0 12681.0 12678.5 12674.0 12672.5 12667.0 12664.0 12656.0 12649.0 12639.5 12625.0 12612.0 1261 O. 5 12603.5 12598.0 12590.5 12584.5 12580.0 12573.0 12568.5 12566.5 12563.0 12558.0 12556.0 12738.5 12732.5 12728.5 12725.5 12718.5 12712.5 12700.0 12685.0 12679.5 12676.5 12667.0 12663.5 12653.5 12637.0 12625.0 12620.0 12609.5 12604.5 12598.5 12594.0 12591.5 12584.5 12573.0 12566.5 12561.0 12558.0 12556.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lOoNOV-1998 10:08 PAGE: I0 12553.5 12553.0 12550.5 12552.5 12546.5 12547.0 12545.5 12546.5 12543.5 12543.5 12542.5 12543.5 12541.0 12541.5 12536.0 12534.0 12534.0 12534.0 12531.5 12531.5 12530.5 12531.0 12526.0 12524.5 12525.5 12524.0 12522.0 12520.0 12521.0 12520.0 12516.0 12515.0 12516.0 12508.5 12507.0 12503.5 12503.0 12502.5 12502.5 12500.5 12500.0 12499.5 12500.0 12495.5 12494.0 12491.5 12491.0 12489.5 12488.0 12486.5 12486.5 12483.0 12483.0 12479.5 12478.5 12478.5 12477.5 12474.0 12472.5 12466.5 12465.5 12466.0 12465.5 12464.0 12461.5 12459.0 12457.5 12451.5 12451.0 12448.5 12447.0 12447.0 12447.0 12442.0 12442.0 12438.5 12437.0 12436.0 12435.0 12433.5 12433.5 12430.5 12430.0 12428.5 12427.0 12425.0 12423.0 12421.5 12420.0 12420.5 12420.0 12399.0 12397.5 12397.0 12396.5 12396.5 12394.5 12393.0 12389.0 12387.0 12385.0 12382.5 12382.0 12376.5 12375.5 12372.5 12371.5 12371.0 12371.5 12367.0 12365.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 11 12363.0 12361.5 12359.0 12357.5 12352.0 12350.5 12351.5 12351.0 12350.0 12348.0 12347.0 12345.5 12346.0 12345.5 12342.5 12342.5 12339.5 12338.0 12339.0 12338.0 12335.5 12335.5 12332.0 12330.5 12331.5 12330.0 12329.0 12327.0 12325.0 12326.5 12326.0 12322.0 12321.0 12316.5 12314.5 12309.0 12306.0 12300.5 12299.0 100.0 98.5 99.5 $ RI~ARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 12 TYPE REPR CODE VALUE .............................. 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NT]M~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1239887 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. '12960.500 NBAC.RST 2558.251 FBAC.RST 3251.836 SBNA.FIL SFNA.FIL 18.386 SBFA.FIL 36.707 SFFA.FIL 15.571 TRAT. FIL IRAT.FIL 0.520 CIRN. FIL 1.289 CIRF. FIL 2.783 BSAL.RST SIBF. RST 33.757 TPHI.RST 21.496 SFFC.RST 12.138 SFNC.RST SIGM. RST 12.140 DSIG.RST 0.563 FBEF. RST 28.653 CRRA.RST GRCH. RST -999.250 TENS.RST 1494.000 CCL.RST 0.007 DEPT. 12294.500 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT.FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC. RST -999.250 SFNC. RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH. RST 108.238 TENS.RST -999.250 CCL.RST -999.250 51.222 O.900 33.275 12.437 1.915 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 13 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~9~gY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12940.0 12285.5 RST 12961.0 12286.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88882.0 88892.0 12932.0 12926.0 12929.5 12933.5 12923.0 12926.0 12922.0 12919.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 14 12917.0 12919.0 12916.0 12914.5 12914.5 12914.0 12910.5 12909.0 12907.5 12904.0 12906.5 12904.0 12900.5 12897.0 12898.0 12893.5 12894.5 12890.5 12893.0 12893.5 12890.0 12889.5 12886.5 12883.5 12882.5 12880.0 12881.0 12876.5 12876.0 12873.5 12874.0 12871.0 12873.0 12871.0 12872.5 12869.0 12868.0 12864.5 12858.5 12855.5 12856.0 12853.0 12854.0 12852.5 12853.5 12851.0 12851.0 12848.0 12848.0 12848.0 12847.5 12845.5 12846.0 12843.5 12843.0 12843.0 12839.5 12838.0 12836.0 12835.5 12835.5 12835.5 12831.0 12830.5 12829.5 12827.5 12821.5 12820.0 12818.5 12816.0 12817.5 12816.0 12813.5 12810.5 12811.5 12809.0 12810.0 12802.0 12800.0 12800.0 12795.5 12793.0 12790.5 12787.0 12789.0 12786.0 12787.5 12785.5 12779.0 12776.0 12778.0 12776.0 12774.0 12772.5 12771.5 12770.5 12770.0 12769.5 12767.0 12767.0 12765.5 12766.0 12758.5 12758.0 12756.5 12757.0 12753.0 12753.5 12752.5 12753.5 12744.0 12745.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 15 12741 . 5 12742 . 0 12740.5 12742.0 12735.5 12737.0 12734.0 12735.0 12731.0 12732.0 12732.5 12726.5 12728.5 12722 . 5 12725 . 5 12721.5 12723.5 12715.5 12718.5 12713.5 12715.0 12709.0 12709.5 12707.0 12706.5 12704.0 12704.5 12686.0 12684.5 12681 . 0 12681 . 0 12679.0 12679.5 12677.5 12679.0 12675.0 12676.5 12666.0 12667.5 12665.5 12667.0 12663.5 12664.0 12662.5 12663 . 5 12651.5 12653.5 12650.0 12651.5 12644.5 12645.0 12639.0 12639.5 12635.5 12636.5 12628.5 12628.5 12628.0 12628.0 12624.5 12625.0 12620.0 12619.5 12619.5 12612.5 12612.0 12612.5 12610.5 12610.5 12598.0 12598.0 12597.5 12598.0 12595.0 12594.5 12593.5 12594.0 12584.0 12582.5 12584.5 12573.5 12573.0 12572.5 12573.0 12565.0 12565.5 12563.0 12563.0 12560 . 0 12561 . 0 12555.5 12556.0 12553.0 12552.5 12548.5 12549.5 12545.5 12546.5 12545.0 12546.5 12544.0 12544.0 12542.0 12543.5 12541.5 12541.5 12534.5 12534 . 0 12534.0 12534.0 12532.0 12531 . 5 12529 . 5 12527.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 16 12525.0 12521.5 12516.5 12515.0 12500.5 12499.5 12492.0 12491.0 12489.0 12481.0 12479.0 12474.0 12471.0 12468.0 12466.0 12463.0 12456.0 12452.0 12451.0 12448.0 12447.0 12443.0 12441.5 12437.5 12436.0 12430.0 12428.5 12420.5 12411.5 12407.5 12404.0 12400.0 12398.0 12396.5 12395.5 12388.0 12386.5 12382.5 12382.0 12380.5 12371.0 12370.5 12366.0 12362.0 12360.5 12356.5 12352.0 12351.0 12346.0 12345.5 12339.0 12338.0 12334.0 12329.5 12326.0 12515.5 12500.0 12491.0 12488 0 12481 5 12478 5 12472 5 12470 5 12467 5 12465.5 12461.5 12452.0 12447.0 12442.5 12440.5 12437.0 12435.0 12429.5 12427.0 12420.0 12411.0 12407.5 12403.0 12399.0 12397.5 12394.5 12387.5 12385.O 12381.0 12379.5 12370.0 12364.5 12361.5 12356.0 12350.5 12345.5 12337.5 12333.0 12329.0 12325.0 12524.0 12520.0 12515.5 12500.0 12491.0 12456.0 12451.5 12446.5 12442.0 12430.0 12396.5 12388.5 12382.0 12371.0 12360.5 12351.5 12345.5 12338.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 17 12321.0 12321.0 12316.5 12317.0 12316.0 12317.5 12312.0 12314.0 12305.0 12306.0 12299.5 12298.0 12295.5 12295.0 100.0 99.5 100.5 $ REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1239887 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1239887 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1239887 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA FIL CU 1239887 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 SFNA FIL CU 1239887 SBFA FIL CU 1239887 SFFA FIL CU 1239887 TRAT FIL 1239887 IRAT FIL 1239887 CIRNFIL 1239887 CIRF FIL 1239887 BSAL RST PPK 1239887 SIBF RST CU 1239887 TPHI RST PU-S 1239887 SFFC RST CU 1239887 SFNC RST CU 1239887 SIGM RST CU 1239887 DSIG RST CU 1239887 FBEF RST UA 1239887 CRRARST 1239887 O0 GRCH RST GAPI 1239887 O0 TENS RST LB 1239887 O0 CCL RST V 1239887 O0 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 000 O0 0 3 1 1 4 68 0000000000 000 O0 0 3 1 1 4 68 0000000000 000 O0 0 3 1 1 4 68 0000000000 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12961.000 NBAC.RST 2785.626 FBAC.RST 3373.380 SBNA.FIL SFNA.FIL 18.728 SBFA.FIL 44.263 SFFA.FIL 15.798 TRAT. FIL IRAT. FIL 0.515 CIRN. FIL 1.279 CIRF. FIL 2.758 BSAL.RST SIBF. RST 34.099 TPHI.RST 22.272 SFFC.RST 12.397 SFNC. RST SIGM. RST 12.395 DSIG.RST 0.415 FBEF. RST 29.050 CRRA.RST GRCH. RST -999.250 TENS.RST 1491.000 CCL.RST -0.002 DEPT. ~2285.500 NBAC. RST -999.250 FBAC. RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF. FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC. RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF. RST -999.250 CRRA.RST GRCH. RST 93.226 TENS.RST -999.250 CCL.RST -999.250 48.733 0.908 34.234 12.903 1.901 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 19 **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMFL~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12106.0 11700.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH REMARKS: THIS FILE CONTAINS THE EDITED JEWELERY PASS. THE DATA HAS NOT BEEN SHIFTED SINCE IT IS AT HIGHER INTERVAL THAN THE RST LOG. THE DATA HAS BEEN CLIPPED OF INVALID COUNTS AT FIRST READING AND AT LAST READING. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 20 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1239887 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1239887 O0 000 O0 0 4 1 1 4 68 0000000000 TENS RST LB 1239887 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RST V 1239887 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 12117.000 GRCH.RST -999.250 TENS.RST 1405.000 CCL.RST DEPT. 11700.000 GRCH. RST 95.075 TENS.RST 1350.000 CCL.RST -0. 058 -0.012 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 21 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass i Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, RST $ REMARKS: THIS FILE CONTAINS THE ARITI~4ETIC AVERAGE OF BASE PASSES 1,2, & 3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 22 TYPE REPR CODE VALUE .............................. 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC RST CPS 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC RST CPS 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT RSAV 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT RSAV 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNRSAV 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF RSAV 1239887 O0 000 O0 0 $ 1 1 4 68 0000000000 BSALRSAV PPK 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI RSAV PU-S 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG RSAV CU 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF RSAV UA 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 CRRARSAV 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH RST GAPI 1239887 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12960. 000 NBAC. RST 2434.225 FBAC. RST 3321. 713 SBNA.RSAV SFNA.RSAV 18. 658 SBFA.RSAV 41. 401 SFFA.RSAV 15. 717 TRAT.RSAV IRAT. RSAV 0.512 CIRN. RSAV 1.269 CIRF. RSAV 2. 722 BSAL.RSAV SIBF. RSAV 33. 401 TPHI.RSAV 22. 710 SFFC.RSAV 12.304 SFNC.RSAV SIGM. RSAV 12. 301 DSIG. RSAV 0 . 510 FBEF. RSAV 28. 626 CRRA. RSAV GRCH. RST - 999. 250 51.217 0.916 32.279 12.897 1.908 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 23 DEPT. 12276 . 000 NBAC. RST - 999 . 250 FBAC. RST SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV SIBF. RSAV -999 . 250 TPHI. RSAV - 999 . 250 SFFC. RSAV SIGM. RSAV -999 . 250 DSIG. RSAV -999 . 250 FBEF. RSAV GRCH. RST 1 O0. 823 -999. 250 SBNA. RSAV - 999. 250 TRAT. RSAV -999.250 BSAL.RSAV -999. 250 SFNC. RSAV - 999.250 CRRA. RSAV -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE ' 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~IARY VENDOR TOOL CODE START DEPTH ........................... RST 12988.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): STOP DEPTH 12246.0 07-AUG-98 8C1-205 1208 07-AUG-98 13066.0 12980.0 11700.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 24 BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 12957.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY RST RESERVOIR SATUATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9. 875 13142.0 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 FLUIDS 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): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN) '. RbIMARKS: Thank you for using Schlumberger. This log was depth referenced to Atlas SBL dated O1-Jun-1994. Ail depth correlations and tie-ins witnessed by co. rep. Logging Procedure: SANDSTONE MATRIX Logging interval Of 12300' - 12980 PBTD Three sigma passes made at 1800 FPM Jewelery log made for future reference LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 25 Note: Not much trouble getting down through cork screw section 11550 - 11590'. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS1 F/HR 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 NPHVPS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 AQTMPS1 S 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CPSV PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS1 V 1239887 O0 000 O0 0 6 1 I 4 68 0000000000 CM2V PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PSl 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 26 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~q CODE (HEX) RCAKPS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS1 S 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS1 PSIG 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS1 UA 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PS1 MA 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS1 UA 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS1 UA 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS1 UA 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 XP5V PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 XI~2V PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RXAKPS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS1 MA 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS1 PPK 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CIRN PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS1 CPS 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS1 CPS 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA SIG CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI.~SS MOD NUMB SgMP ELI~ CODE (HEX) SIBF PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS1 CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS1 1239887 O0 000 O0 0 6 I, 1 4 68 0000000000 TRAT SIG 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS1 KHZ 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS1 KHZ 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS1 DEGC 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS1 DEGC 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS1 AMP 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS1 AMP 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS1 PU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS1 V 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS1 1239887 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 12988.000 CS.PS1 1286.633 TENS.PSI 1356.000 NPHV. PS1 NPDE. PS1 1455.194 NSCE. PS1 2.476 CRRA.PS1 1.960 NSCR.PS1 AQTM. PS1 0.441 CHV. PS1 201.339 CPSV. PS1 5.060 CP2V. PS1 CM2V. PS1 -12.191 RCFR.PSi 0.000 RCLC. PS1 0.000 RCRC. PS1 RCAK. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 1406.251 FPDE.PS1 FSCE. PS1 1.753 FSCR.PS1 -0.187 AQTF. PS1 0.441 SF6P.PS1 HVPV. PS1 160.156 BMCU. PS1 34.570 GDCU. PS1 60.996 EXCU. PS1 NBEF. PS1 13.717 FBEF. PS1 26.882 NPGF. PS1 0.987 FPGF. PS1 BSTR.PS1 52.837 BSPR.PS1 1.182 MARC. PSI 0.000 XHV. PS1 XP5V. PS1 5.069 XP2V. PS1 12.114 X~2V. PS1 -12.407 RXFR.PS1 RXLC. PS1 0.000 RXRC. PS1 0.000 RXAK. PS1 0.000 SHCU. PS1 BSAL.PS1 -999.250 BSAL.SIG -999.250 CIRN. PS1 -999.250 CIRF. PS1 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS1 -999.250 FBAC. PS1 IRAT. PS1 -999.250 IRAT. FIL -999.250 NBAC. PS1 -999,250 SFNA.PS1 SFFA.PS1 -999.250 SBNA.PS1 -999.250 SBFA.PS1 -999.250 SFNA.SIG SFFA. SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS1 SFNC. PS1 -999,250 SFFC. PS1 -999.250 SIGM. PS1 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT. PS1 -999.250 TRAT. SIG -999.250 TRAT. FIL GR.PS1 13.358 RDIX. PS1 143637.000 CRNI.PS1 442.786 CRFI.PS1 CTM. PS1 97.168 XTM. PS1 96.191 TAV. PS1 95.031 FICU. PS1 1481.935 1.352 12.129 0.000 1383.287 165.681 23.277 1.000 201.096 0.000 33.820 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 225.936 2.222 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 28 CACU. PS1 2.476 BUST. PSI TPHI.PS1 -999.250 TPHI.SIG 3.000 BUSP.PS1 -999.250 CCLC. PS1 DEPT. 12246.000 CS.PS1 1813.891 TENS.PSI NPDE. PS1 1464.769 NSCE. PS1 2.638 CRRA.PS1 AQTM. PS1 1.322 CHV. PS1 201.339 CP5V. PS1 CM2V. PS1 -12.211 RCFR.PS1 0.000 RCLC. PS1 RCAK. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 FSCE. PS1 1.691 FSCR.PS1 0.024 AQTF. PS1 HVPV. PS1 160.905 BMCU. PS1 35.879 GDCU. PS1 NBEF. PS1 15.512 FBEF. PS1 28.452 NPGF. PS1 BSTR.PS1 72.645 BSPR.P$1 1.084 MARC. PSI XPSV. PS1 5.073 XP2V. PS1 12.084 XM2V. PS1 RXLC. PS1 0.000 RXRC. PS1 0.000 RXAK. PS1 BSAL. PS1 41.139 BSAL.SIG 2.725 CIRN. PS1 CIRN. FIL 0.881 CIRF. FIL 1.423 DSIG.PS1 IRAT. PS1 0.535 IRAT. FIL 0.536 NBAC. PS1 SFFA.PS1 30.632 SBNA.PS1 52.487 SBFA.PS1 SFFA.SIG 0.559 SBNA.SIG 2.789 SBFA.SIG SFFA.FIL 30.385 SBNA.FIL 54.320 SBFA.FIL SFNC. PS1 26.503 SFFC. PS1 27.561 SIGM. PS1 SIGM. SIG 0.478 TRAT. PS1 1.197 TRAT. SIG GR.PS1 105.603 RDIX. PS1 165391.000 CRNI.PS1 CTM. PS1 96.436 XTM. PS1 95.475 TAV. PS1 CACU. PS1 2.468 BUST. PSl 3.000 BUSP.PS1 TPHI.PS1 41.051 TPHI.SIG 1.146 CCLC. PS1 3.000 -0.019 1435.000 1.834 5.055 0.000 1411.134 1.322 60.187 0.995 0.000 -12.379 0.000 0.883 -0.916 2666.895 44.753 3.604 45.384 27.694 0.021 438.479 94.984 3.000 -999.250 RSXS. PS1 RSCS. PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS.PS1 RSCS.PS1 8878.000 8463.0O0 1496.583 0.430 12.165 0.000 1387.864 171.719 22.724 0.995 200.773 0.000 35.642 1.439 3329.590 28.739 0.459 28.889 36.570 0.979 1.170 239.057 2.195 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE ' FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 29 FILE AU]FiBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... RST 12991.0 $ LOG HEADER DATA STOP DEPTH .......... 12263.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMFIA RAY RST RESERVOIR SATUATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 07-AUG-98 8Cl -205 1208 07-AUG-98 13066.0 12980.0 11700.0 12957.0 TOOL NUMBER CGRS-A RST-A 9. 875 13142.0 PRODUCED FLUIDS THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 30 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): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger. This log was depth referenced to Atlas SBL dated O1-Jun-1994. Ail depth correlations and tie-ins witnessed by co. rep. Logging Procedure: SANDSTONE MATRIX Logging interval Of 12300' - 12980 PBTD Three sigma passes made at 1800 FPM Jewelery log made for future reference Note: Not much trouble getting down through cork screw section 11550 - 11590'. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 31 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS2 F/HR 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CRRA PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS2 S 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CP5V PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RCAKPS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 FPHVPS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS2 S 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS2 PSIG 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS2 UA 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS2 MA 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS2 UA 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS2 UA 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 FBEF PS2 UA 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 Xh-V PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 X~I2V PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RXRC PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS2 MA 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS2 PPK 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 32 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~I CODE (HEX) ....................................................................................... DSIG PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS2 CPS 1239887 '00 000 O0 0 7 1 1 4 68 0000000000 IRAT PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS2 CPS 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS2 CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CRNI PS2 KHZ 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS2 KHZ 1239887 O0 000 O0 0 7 I 1 4 68 0000000000 CTM PS2 DEGC 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS2 DEGC 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS2 AMP 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS2 AMP 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS2 PU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS2 V 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS2 1239887 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12991.000 CS.PS2 976.851 TENS.PS2 794.000 NPHV. PS2 NPDE. PS2 1460.534 NSCE. PS2 2.407 CRRA.PS2 1.958 NSCR.PS2 AQTM. PS2 0.661 CHV. PS2 201.339 CPSV. PS2 5.030 CP2V. PS2 CM2V. PS2 -12.152 RCFR.PS2 0.000 RCLC. PS2 0.000 RCRC. PS2 .1489.259 0.673 12.173 0.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 33 RCAK. PS2 0.000 RTDF. PS2 FSCE. PS2 1.736 FSCR.PS2 HVPV. PS2 160.889 BMCU. PS2 NBEF. PS2 13.984 FBEF. PS2 BSTR.PS2 65.022 BSPR.PS2 XP5V. PS2 5.069 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 -999.250 BSAL. SIG CIRN. FIL -999.250 CIRF. FIL IRAT. PS2 -999.250 IRAT. FIL SFFA.PS2 -999.250 SBNA.PS2 SFFA.SIG -999.250 SBNA.SIG SFFA.FIL -999.250 SBNA.FIL SFNC. PS2 -999.250 SFFC. PS2 SIGM. SIG -999.250 TRAT. PS2 GR. PS2 20.188 RDIX. PS2 CTM. PS2 98.145 XTM. PS2 CACU. PS2 2.471 BUST. PS2 TPHI.PS2 -999.250 TPHI.SIG DEPT. 12263.000 CS.PS2 NPDE. PS2 1466.409 NSCE. PS2 AQTM. PS2 0.661 CHV. PS2 CM2V. PS2 -12.231 RCFR.PS2 RCAK. PS2 0.000 RTDF. PS2 FSCE. PS2 1.680 FSCR.PS2 HVPV. PS2 160.889 BMCU. PS2 NBEF. PS2 14.874 FBEF. PS2 BSTR.PS2 66.759 BSPR.PS2 XPSV. PS2 5.076 XP2V. PS2 RXLC. PS2 0.000 RXRC. PS2 BSAL.PS2 18.157 BSAL.SIG CIRN. FIL 0.799 CIRF. FIL IRAT. PS2 0.555 IRAT. FIL SFFA.PS2 32.733 SBNA.PS2 SFFA.SIG 0.688 SBNA.SIG SFFA.FIL 33.814 SBNA.FIL SFNC. PS2 32.677 SFFC. PS2 SIGM. SIG 0.606 TRAT. PS2 GR.PS2 158.353 RDIX. PS2 CTM. PS2 97.168 XTM. PS2 CACU. PS2 2.470 BUST. PS2 TPHI.PS2 47.021 TPHI.SIG 0 000 -0 145 40 136 27 386 1 109 12 114 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 5757. 000 97.168 3.000 -999.250 1851. 382 2. 696 201. 096 0.000 0.000 0.075 39.969 27.097 1.056 12.096 0.000 2.652 1.093 0.559 46.015 3.841 47.596 33.564 1.308 27114.000 95.982 3.000 1.394 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 X~2V. PS2 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI.PS2 TAV. PS2 BUSP. PS2 CCLC. PS2 TENS.PS2 CRRA.PS2 CP5V. PS2 RCLC. PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 XPI2V. PS2 RXAK. PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI.PS2 TAV. PS2 BUSP. PS2 CCLC. PS2 1413.575 0.661 60.668 0.987 0.000 -12.368 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 443.795 94.888 3.000 0.000 1451.000 1.822 5.060 0.000 1416.017 1.322 59.778 1.003 0.000 -12.351 1.000 0.820 -0.388 2631.699 45.310 3.752 44.073 33.451 0.026 439.533 94.990 3.000 -999.250 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 NPHV. PS2 NSCR.PS2 CP2V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS. PS2 1389.428 174.636 29.195 0.999 200.612 0.000 39.674 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 226.610 2.222 8878.000 8459.000 1494.142 0.262 12.187 0.000 1390.077 175.860 27.842 0.999 200.837 0.000 43.507 1.108 3363.920 29.687 0.704 30.995 28. 426 O. 926 1.310 241.278 2.223 8878.000 8463.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 34 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUR~J~Y VENDOR TOOL CODE START DEPTH RST 12992.0 $ LOG HEADER DATA STOP DEPTH .......... 12253.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATUATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 07-AUG-98 8Cl-205 1208 07-AUG-98 13066.0 12980.0 11700.0 12957.0 TOOL NUMBER ........... CGRS-A RST-A 9. 875 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 35 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 13142.0 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 FLUIDS 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): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger. This log was depth referenced to Atlas SBL dated O1-Jun-1994. Ail depth correlations and tie-ins witnessed by co. rep. Logging Procedure: SANDSTONE MATRIX Logging interval Of 12300' - 12980 PBTD Three sigma passes made at 1800 FPM Jewelery log made for future reference Note: Not much trouble getting down through cork screw section 11550 - 11590'. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 3 6 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 $ 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CS PS3 F/HR 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 NPHVPS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 NPDE PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 NSCE PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CRRA PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 NSCR PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 AQTMPS3 S 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CHV PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CPSV PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CP2V PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CM2V PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RCFR PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RCLC PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RCRC PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RCAK PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RTDF PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 FPHVPS3 V 1239887 O0 000 O0 0 8 I 1 4 68 0000000000 FPDE PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 FSCE PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 FSCR PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 AQTF PS3 S 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SF6P PS3 PSIG 1239887 00 000 O0 0 8 1 1 4 68 0000000000 HVPV PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 BMCU PS3 UA 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 37 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) ....................................................................................... GDCU PS3 MA 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 EXCU PS3 UA 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 NBEF PS3 UA 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 FBEF PS3 UA 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 NPGF PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 FPGF PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 BSTR PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 BSPR PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 MARC PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 XHV PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 XPSV PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 XP2V PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 X~2V PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RXFR PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RXLC PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RXRC PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RXAKPS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SHCU PS3 MA 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL PS3 PPK 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 BSAL SIG PPK 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNPS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CIRNFIL 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CIRF FIL 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 DSIG PS3 CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS3 CPS 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 IRAT FIL 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 NBAC PS3 CPS 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA PS3 CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA PS3 CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA PS3 CU 1239887 O0 000 O0 0 8 1 i 4 68 0000000000 SBFA PS3 CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA SIG CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA SIG CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA SIG CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA SIG CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SFNA FIL CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SFFA FIL CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SBNA FIL CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SBFA FIL CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF PS3 CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SFNC PS3 CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SFFC PS3 CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS3 CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SIBF SIG CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM SIG CU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT SIG 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 TI{ATFIL 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 38 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) RDIX PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CRNI PS3 KHZ 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CRFI PS3 KHZ 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CTM PS3 DEGC 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 XTM PS3 DEGC 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 TAV PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 FICU PS3 AMP 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CACU PS3 AMP 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 BUST PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 BUSP PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RSXS PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS3 PU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI SIG PU 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 CCLC PS3 V 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 RSCS PS3 1239887 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 12992.000 CS. PS3 1928.227 TENS.PS3 974.000 NPHV. PS3 NPDE. PS3 1466.333 NSCE. PS3 2.685 CRRA.PS3 1.951 NSCR.PS3 AQTM. PS3 0.441 CHV. PS3 201.096 CP5V. PS3 5.050 CP2V. PS3 CM2V. PS3 -12.211 RCFR.PS3 0.000 RCLC. PS3 0.000 RCRC. PS3 RCAK. PS3 0.000 RTDF. PS3 0.000 FPHV. PS3 1413.575 FPDE. PS3 FSCE. PS3 1.756 FSCR.PS3 -0.511 AQTF. PS3 0.441 SF6P. PS3 HVPV. PS3 161.133 BMCU. PS3 41.015 GDCU. PS3 61.323 EXCU. PS3 NBEF. PS3 15.416 FBEF. PS3 30.082 NPGF. PS3 0.996 FPGF. PS3 BSTR.PS3 47.488 BSPR.PS3 1.130 MARC. PS3 0.000 XHV. PS3 XP5V. PS3 5.079 XP2V. PS3 12.100 X~2V. PS3 -12.426 RXFR.PS3 RXLC. PS3 0.000 RXRC. PS3 0.000 RXAK. PS3 0.000 SHCU. PS3 BSAL.PS3 -999.250 BSAL.SIG -999.250 CIRN. PS3 -999.250 CIRF. PS3 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS3 -999.250 FBAC. PS3 IRAT. PS3 -999.250 IRAT. FIL -999.250 NBAC. PS3 -999.250 SFNA.PS3 SFFA.PS3 -999.250 SBNA. PS3 -999.250 SBFA.PS3 -999.250 SFNA.SIG SFFA.SIG -999.250 SBNA. SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS3 SFNC. PS3 -999.250 SFFC. PS3 -999.250 SIGM. PS3 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT. PS3 -999.250 TRAT. SIG -999.250 TRAT. FIL GR.PS3 166.978 RDIX. PS3 32086.000 CRNI.PS3 461.793 CRFI.PS3 CTM. PS3 98.633 XTM. PS3 95.215 TAV. PS3 94.888 FICU. PS3 CACU. PS3 2.476 BUST. PS3 3.000 BUSP.PS3 3.000 RSXS. PS3 TPHI.PS3 -999.250 TPHI.SIG -999.250 CCLC.PS3 0.019 RSCS.PS3 DEPT. 12253.500 CS. PS3 1806.186 TENS.PS3 NPDE. PS3 1466.409 NSCE. PS3 2.663 CRRA.PS3 AQTM. PS3 0 . 661 CHV. PS3 201 . 339 CP5V. PS3 CM2V. PS3 -12.211 RCFR.PS3 0.000 RCLC. PS3 RCAK. PS3 O . 000 RTDF. PS3 O . 000 FPHV. PS3 FSCE. PS3 1.689 FSCR.PS3 -0.175 AQTF. PS3 HVPV. PS3 160.824 BMCU. PS3 37.519 GDCU. PS3 1412 000 1 835 5 060 0 000 1416 017 1 102 59 793 NPHV. PS3 NSCR.PS3 CP2V. PS3 RCRC. PS3 FPDE. PS3 SF6P. PS3 EXCU. PS3 1499.024 -0.249 12.158 0.000 1388.856 175.915 28.011 1.000 200.854 0.000 39.349 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 236.652 2.188 8878.000 8459.O00 1496.583 -0.075 12.129 0.000 1390.267 176.376 23.934 LIS Tape Verification LiSting Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 39 NBEF. PS3 15.372 FBEF. PS3 BSTR.PS3 52.505 BSPR.PS3 XP5V. PS3 5.071 XP2V. PS3 RXLC. PS3 0.000 RXRC. PS3 BSAL.PS3 31.969 BSAL.SIG CIRN. FIL 0.783 CIRF. FIL IRAT. PS3 0.555 IRAT. FIL SFFA.PS3 33.191 SBNA.PS3 SFFA.SIG 0.641 SBNA.SIG SFFA.FIL 32.679 SBNA.FIL SFNC. PS3 30.260 SFFC. PS3 SIGM. SIG 0.604 TRAT. PS3 GR.PS3 183.224 RDIX. PS3 CTM. PS3 96.191 XTM. PS3 CACU. PS3 2.481 BUST. PS3 TPHI.PS3 46.172 TPHI.SIG O. 47. 4. 46. 30. 1. 54061. 95. 3. 1. 28.205 NPGF. PS3 1.123 MARC.PS3 12.097 XM2V. PS3 0.000 RXAK. PS3 2.724 CIRN. PS3 1.135 DSIG.PS3 555 NBAC. PS3 343 SBFA.PS3 730 SBFA.SIG 823 SBFA.FIL 663 SIGM. PS3 259 TRAT. SIG 000 CRNI.PS3 410 TAV. PS3 000 BUSP. PS3 363 CCLC. PS3 1.000 FPGF. PS3 0.000 XHV. PS3 -12.358 RXFR.PS3 0.000 SHCU. PS3 0.789 CIRF. PS3 -0.337 FBAC. PS3 2759.893 SFNA.PS3 45.890 SFNA.SIG 3.420 SFNA.FIL 43.680 SIBF. PS3 30.686 SIBF.SIG 0.025 TRAT. FIL 441.022 CRFI.PS3 94.984 FICU. PS3 3.000 RSXS.PS3 -999.250 RSCS.PS3 0 997 200 789 0 000 44 574 1 119 3329 533 30 374 0.902 30.695 33.293 0.968 1.256 240.356 2.216 8878.000 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0. 5000 FILE SUMM3~Y VENDOR TOOL CODE START DEPTH STOP DEPTH RST 12155.0 11699.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 40 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 07-AUG-98 8Cl -205 1208 07-AUG-98 13066.0 12980.0 11700.0 12957.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMFiA RAY RST RESERVOIR SATUATION $ TOOL NUMBER ........... CGRS-A RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9. 875 13142.0 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 FLUIDS 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): 5 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger. LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 41 This log was depth referenced to Atlas SBL dated O1-Jun-1994. Ail depth correlations and tie-ins witnessed by co. rep. Logging Procedure: SANDSTONE MATRIX Logging interval Of 12300' - 12980 PBTD Three sigma passes made at 1800 FPM Jewelery log made for future reference Note: Not much trouble getting down through cork screw section 11550 - 11590'. THIS FILE CONTAINS THE RAW DATA FOR THE JEWELERY PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CS TIE F/HR 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 TENS TIE LB 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 NPHVTIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 NPDE TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 NSCE TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CRRA TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 42 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ....................................................................................... NSCR TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 AQTMTIE S 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CHV TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CP5V TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CP2V TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CM2V TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RCFR TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RCLC TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RCRC TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RCAKTIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RTDF TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 FPHV TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 FPDE TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 FSCE TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 FSCR TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 AQTF TIE S 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 SF6P TIE PSIG 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 HVPV TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 BMCU TIE UA 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 GDCU TIE MA 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 EXCU TIE UA 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 NBEF TIE UA 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 FBEF TIE UA 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 NPGF TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 FPGF TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 BSTR TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 BSPR TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 MARC TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 XHV TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 XPSV TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 XP2V TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 XM2V TIE V 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RXFR TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RXLC TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RXRC TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 RXAK TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 SHCU TIE MA 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL TIE PPK 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 BSAL SIG PPK 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CIRN TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CIRNFIL 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 CIRF FIL 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 DSIG TIE CU 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC TIE CPS 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 IRAT FIL 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 NBAC TIE CPS 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 SFNA TIE CU 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 SFFA TIE CU 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 SBNA TIE CU 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 43 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~I CODE (HEX) SBFA TIE CU 1239887 O0 000 O0 0 9 1 1 4 SFNA SIG CU 1239887 O0 000 O0 0 9 1 1 4 SFFA SIG CU 1239887 O0 000 O0 0 9 1 1 4 SBNA SIG CU 1239887 O0 000 O0 0 9 1 1 4 SBFA SIG CU 1239887 O0 000 O0 0 9 1 1 4 SFNA FIL CU 1239887 O0 000 O0 0 9 1 1 4 SFFA FIL CU 1239887 O0 000 O0 0 9 1 1 4 SBNA FIL CU 1239887 O0 000 O0 0 9 1 1 4 SBFA FIL CU 1239887 O0 000 O0 0 9 1 1 4 SIBF TIE CU 1239887 O0 000 O0 0 9 1 1 4 SFNC TIE CU 1239887 O0 000 O0 0 9 1 1 4 SFFC TIE CU 1239887 O0 000 O0 0 9 1 1 4 SIGM TIE CU 1239887 O0 000 O0 0 9 1 1 4 SIBF SIG CU 1239887 O0 000 O0 0 9 1 1 4 SIGM SIG CU 1239887 O0 000 O0 0 9 1 1 4 TRAT TIE 1239887 O0 000 O0 0 9 1 1 4 TRAT SIG 1239887 O0 000 O0 0 9 1 1 4 TRAT FIL 1239887 O0 000 O0 0 9 1 1 4 GR TIE GAPI 1239887 O0 000 O0 0 9 1 1 4 RDIX TIE 1239887 O0 000 O0 0 9 1 1 4 CRNI TIE KHZ 1239887 O0 000 O0 0 9 1 1 4 CRFI TIE KHZ 1239887 O0 000 O0 0 9 1 1 4 CTM TIE DEGC 1239887 O0 000 O0 0 9 1 1 4 XTM TIE DEGC 1239887 O0 000 O0 0 9 1 1 4 TAV TIE 1239887 O0 000 O0 0 9 1 1 4 FICU TIE AMP 1239887 O0 000 O0 0 9 1 1 4 CACU TIE AMP 1239887 O0 000 O0 0 9 1 1 4 BUST TIE 1239887 O0 000 O0 0 9 1 1 4 BUSP TIE 1239887 O0 000 O0 0 9 1 1 4 RSXS TIE 1239887 O0 000 O0 0 9 1 1 4 TPHI TIE PU 1239887 O0 000 O0 0 9 1 1 4 TPHI SIG PU 1239887 O0 000 O0 0 9 1 1 4 CCLC TIE V 1239887 O0 000 O0 0 9 1 1 4 RSCS TIE 1239887 O0 000 O0 0 9 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 12155.000 CS. TIE 2077.323 TENS. TIE NPDE. TIE 1446.573 NSCE. TIE 1.804 CRRA.TIE AQTM. TIE 0.661 CHV. TIE 201.339 CP5V. TIE CM2V. TIE - 12.231 RCFR. TIE O. 000 RCLC. TIE RCAK. TIE O. 000 RTDF. TIE O. 000 FPHV. TIE FSCE. TIE 1 . 684 FSCR. TIE 1 . 303 AQTF. TIE HVPV. TIE 0.000 BMCU. TIE 0.000 GDCU. TIE NBEF. TIE 203.209 FBEF. TIE 147.084 NPGF. TIE BSTR.TIE 0.815 BSPR.TIE 1.125 MARC. TIE XP5V. TIE 5.069 XP2V. TIE 12.114 XM2V. TIE RXLC. TIE 0.000 RXRC. TIE 0.000 RXAK. TIE BSAL.TIE -999.250 BSAL.SIG -999.250 CIRN. TIE 760.000 NPHV. TIE 0.724 NSCR.TIE 5.050 CP2V. TIE 0.000 RCRC. TIE 1403.810 FPDE. TIE 0.661 SF6P. TIE 0.000 EXCU. TIE 0.997 FPGF. TIE 0.000 XHV. TIE -12.328 RXFR.TIE 0.000 SHCU. TIE -999.250 CIRF. TIE 1477 052 3 623 12 143 0 000 1378 938 174 636 3.945 0.998 200.612 0.000 37.398 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 44 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG. TIE IRAT. TIE -999.250 IRAT. FIL -999.250 NBAC. TIE SFFA. TIE -999.250 SBNA. TIE -999.250 SBFA.TIE SFFA.SIG -999.250 SBNA. SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. TIE -999.250 SFFC. TIE -999.250 SIGM. TIE SIGM. SIG -999.250 TRAT. TIE -999.250 TRAT. SIG GR. TIE 235.526 RDIX. TIE 59195.000 CRNI. TIE CTM. TIE 94. 238 XTM. TIE 93 . 750 TAV. TIE CACU. TIE O. 005 BUST. TIE 3. 000 BUSP. TIE TPHI.TIE -999.250 TPHI.SIG -999.250 CCLC. TIE DEPT. NPDE. TIE AQTM. TIE CM2 V. TIE RCAK. TIE FSCE. TIE HVPV. TIE NBEF. TIE BSTR. TIE XPSV. TIE RXLC. TIE BSAL.TIE CIRN. FIL IRAT. TIE SFFA.TIE SFFA.SIG SFFA.FIL SFNC. TIE SIGM. SIG GR.TIE CTM. TIE CACU. TIE TPHI.TIE 11699.000 1440.545 0.661 -12.231 0.000 1.684 0.153 267.450 1.205 5.074 0.000 -999.250 -999.250 -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 98 241 90 332 0 004 -999 250 CS. TIE 3136.723 TENS. TIE NSCE. TIE 1.804 CRRA. TIE CHV. TIE 201.339 CP5V. TIE RCFR.TIE 0.000 RCLC. TIE RTDF. TIE 0.000 FPHV. TIE FSCR.TIE 1.303 AQTF. TIE BMCU. TIE 0.000 GDCU. TIE FBEF. TIE 159.416 NPGF. TIE BSPR.TIE 1.084 MARC. TIE XP2V. TIE 12.116 3~2V. TIE RXRC. TIE 0.000 RXAK. TIE BSAL.SIG -999.250 CIRN. TIE CIRF. FIL -999.250 DSIG. TIE IRAT. FIL -999.250 NBAC. TIE SBNA.TIE -999.250 SBFA.TIE SBNA.SIG -999.250 SBFA.SIG SBNA.FIL -999.250 SBFA.FIL SFFC. TIE -999.250 SIGM. TIE TRAT. TIE -999.250 TRAT. SIG RDIX. TIE 66960.000 CRNI. TIE XTM. TIE 89. 356 TAV. TIE BUST. TIE 3. 000 BUSP. TIE TPHI. SIG -999. 250 CCLC. TIE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.561 0.000 3.000 0.048 1353 000 0 596 5 060 0 000 1398 927 0 661 0 000 1 003 0 000 -12 346 0 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 2.055 0.000 3.000 -999.250 FBAC. SFNA. SFNA. SFNA. SIBF. SIBF. TRAT. CRFI. FICU. RSXS. RSCS. TIE TIE SIG FIL TIE SIG FIL TIE TIE TIE TIE NPHV. TIE NSCR. TIE CP2V. TIE RCRC. TIE FPDE. TIE SF6P. TIE EXCU. TIE FPGF. TIE XHV. TIE RXFR.TIE SHCU. TIE CIRF. TIE FBAC. TIE SFNA.TIE SFNA.SIG SFNA.FIL SIBF. TIE SIBF. SIG TRAT. FIL CRFI.TIE FICU. TIE RSXS. TIE RSCS. TIE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3. 538 0.000 9216.000 8459.000 1472.169 3. 623 12.173 0.000 1375.314 171.342 3. 699 1. 003 200.794 0.000 38.333 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.448 0.001 9216.000 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-NOV-1998 10:08 PAGE: 45 * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/11/ 9 ORIGIN : FLIC TAPE NAME : 98294 CONTINUATION # : 1 PREVIOUS TAPE : COMM~N~f : BP EXPLORATION, 3-19/R-28, ENDICOTT, API# 50-029-22463-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/ 9 ORIGIN '. FLIC REEL NAME : 98294 CONTINUATION # PREVIOUS REEL COF~IENT : BP EXPLORATION, 3-19/R-28, ENDICOTT, API# 50-029-22463-00 O0~::g~B ~6~;00S ~a.. LO:LT iS Tape Verificai:ion blkstir)g .-hlUrt':berger AlasKa Cc)?.~p!,]tlr~o Cente~; CSi{ t~ t; ,& l) o U i: P2ti. iT "I'C {3liT:" 3~.o1' GR Tt} b..tT~ 39.86' R~8 TU DIi': 29.4(4' PAGE: I,' t L,F F:er,,th S;~ifted ~nrl c~ti.' .... ~ed curves; ali bit runs r~;erged DFPTtl. lr~CaE~.{g~',~"l: 0.50(30 1249~. (~ bASF'.bli?N C{.J~¢~ FUR SitfgTS: $'[OP DEPTti 1309~, 0 [$ Tar, e Veriflcat;i. on i.,istino :hlumber~er AlasKa Co~i.~utl, i3q Cent. e~~ 21.,,J[iLI~ 994 17:07 2496,0 ! 2955 2955,0 13 126 2463, o 12955 2955, o 13098 ID :~{D~ ~ bOG TYPE CbASS ?C~D ,,{U~ 5A~ZF EhEh CODE (HEX) D E ['r F T 5 9 ~ ~ 9 3 0 o () o (~ u () u i 1 1 4 6 ~ o o 0 o t) o 0 o () 0 kFu6 ~'.~.'~ ~/C3 bgqbg~ (~0 OUO UO u 1 1 1 ~ 60 {lO00000000 IpRr~O Y,~[) G/C3 b9959'? ¢C; t,C.(, O0 0 I ! 1 4 08 0000000000 [.~ E: f ',,,~ ~, [) Or< / ~: 599o97 UO OuO t)u v I 1 I q b8 O00uO00000 iS T&p~ Yerif~.cat.ior~ t, istI~q 2,1-Jt;L,-]9~4 17:['7 '999.250 -999.250 -999'250 -999.250 3.401 5.459 11.749 -999o250 -999.250 -999.250 -999.250 Tape :,~erJ2icatior.', ListJ. r~q Curves and log i-"~eader data for each bit run in separate D i 24F'2 Ci)~ ! 2402 $ * i E A [.; g !~' i) A T A DATE ~[}GG~jI): 8 T (,] P .P g P T H 1295/.4,5 files. FA8!i 2.5/60GOS 20.4 13 :.t 53.0 12524.0 13153.0 9.875 2725.0 ~iu~t, erger at~sKa 176.0 2. 140 2. 750 S A ?J 0 S 'il U i~! ~,; ~.65 1,688 bB.0 I~S Tape Yer~.~lca'Llen bistinq 2blui!'!ber. ger x~l. as~a (Iompu~ir~g Center PAGE: DBPT T b79597 0~; oO . O 0 ~ i i 4 68 00~0~0 O0 DCAL b,ol i~'., 5~9697 o~ 000 Oo 0 2 1 I q 68 ~D[oE: b;~':l Ftfif~ b99597 oo ooo O0 () ~ 1 i 4 b~ 0000000000 uO00OO0000 0000000000 0000000000 0000000000 0000000000 0(~00000000 0000000000 O0000OO000 0000000000 O00OO00000 0000000000 OOUO000000 0000000000 O000000000 -999.2b0 DPMI,b~I -999.2b0 ORhO.b~l -999.~50 ATR.Lal 30.~71 GR.L~I -999.25o TA~D.L~I .. -999.250 -999,250 1999,:250 -999.250 Tape '4erifi, cac.i, on L.,istir'~g ;Blt~[!~berger i~,,LasKa Co~pu. tin~3 Center Zl~dUb-1994 !7:07 Curves ~nd ioq ~e¢~der data ~or each bit run In separate STgP OEPT~ 13!b5,0 l~lb5,O files, FAST 2.5/bOGOS 13153.0 12524.9 13153.0 46,1 s 9,d75 2725.0 L~qNL~ I O,3t.; 17o.0 2.750 72.0 PAGe: g!~lUi'~t, erger .P.,!as~a Cot'~'~vutiL~a C:enter. 21-.dUb-l'994 i7:07 1.o88 ** ~.h;T 'F .'z .P !:.: - CHA.:",~ ** DEPT ~T b9~)597 O0 (;~)u O0 0 .] 1 i 4 68 0000000000 DR?tP t..,'~2 G/C3 bgg;~97 L'~U ~,UO ~)C) V 3 1 i i O~ OOOOOOOO00 PFF tL, .~ '2 Or" / E b99~97 Ut; O(.'u O0 O 3 1 i 4 08 0000000000 DCA[, L. ;.~ 2 ii' b~gbg? OU t(~u t)u 0 3 1 I ~ o~ OtDOOuOoOOO IS Tape verJtlcati, on t..~isting .-blu, tr~be~ger, AlasKa Co~p~lt2, tiQ Cent, er 1 0 -9~'9,250 -9~9.250 O.O~O 108.~38 ..... , -9~9,25U -999.250 ];ape ~'er]~lcatlon, L;istipg ~nlu~Derger AlasKa C©~p~,~tzr~q CenLer 11
