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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 13, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 16-02 PRUDHOE BAY UNIT 16-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/13/2025 16-02 50-029-20544-00-00 180-150-0 W SPT 8492 1801500 2400 1862 1868 1876 1868 353 587 582 574 REQVAR P Josh Hunt 1/16/2025 2-Year MIT-IA to 1.2 x max anticipated well pressure required by AIO 4E.014. Good test. 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:PRUDHOE BAY UNIT 16-02 Inspection Date: Tubing OA Packer Depth 392 2663 2617 2602IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250116134349 BBL Pumped:4.5 BBL Returned:4.6 Thursday, March 13, 2025 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 9 2-Year MIT-IA to 1.2 x max anticipated well pressure AIO 4E.014. James B. Regg Digitally signed by James B. Regg Date: 2025.03.13 10:22:02 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, February 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 16-02 PRUDHOE BAY UNIT 16-02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 02/17/2023 16-02 50-029-20544-00-00 180-150-0 W SPT 8492 1801500 2123 1809 1813 1811 1810 547 752 751 754 REQVAR P Adam Earl 1/3/2023 MIT-IA Tested as per AIO 4E.014 to 1.2 x's MAIP 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: PRUDHOE BAY UNIT 16-02 Inspection Date: Tubing OA Packer Depth 626 2705 2639 2613IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230106105144 BBL Pumped:4 BBL Returned:4 Friday, February 17, 2023 Page 1 of 1 MIT-IA Tested as per AIO 4E.014 to 1.2 x's MAIPMIT-IA Tested as per AIO 4E.014 to 1.2 x's MAIP MEMORANDUM TO: Jim Regg r &&jj �I91?�1 P.I. Supervisor / "I FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 21, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 16-02 PRUDHOE BAY UNIT 16-02 Sm: Inspector Reviewed Bi+• P.1. supry Zl?J2 Comm Well Name PRUDHOE BAY UNIT 16-02 API Well Number 50-029-20544-00-00 Inspector Name: Lou Laubenstein Permit Number: 180-150-0 Inspection Date: 1117/2021 IBsp Num: mi[LOL2101I8171106 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 16-02 -TypeInj w•TV6 8492 Tubing 1129 - nn nza- 1724 PTD 1801500 Type Test SpT Test psi 2123 to 320 2552 - 2516 2504 ' BBL Pumped: 4.7 BBL Returned: 4.6 OA 383 602 596 592 " Interval IREQYAR PIF P Notes: MIT -[A every 2 years to maximum anticipated well pressure = 1900 psi per AA 4E.014 Thursday, January 21, 2021 Page I of I Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:180-150 6.50-029-20544-00-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10795 10748 9363 9745 10743, 10790 None 8492 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 35 - 115 35 - 115 1530 520 Surface 2653 13-3/8" 34 - 2687 34 - 2687 5380 2670 Intermediate 10055 9-5/8" 32 - 10087 32 - 8783 6870 / 8150 4760 / 5080 Liner 1027 7" 9763 - 10790 8507 - 9400 8160 7020 Perforation Depth:Measured depth:1020 - 10430 feet True vertical depth: 888 - 9083 feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# x 4-1/2" 12.6#, L-80130 - 9819 30 - 8555 9745 8492Packers and SSSV (type, measured and true vertical depth) 5-1/2" Baker SAB Packer Liner 560 3-1/2" 9801 - 10361 8540 - 9022 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2464086819 13552 652 1337 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Richards, Meredyth Meredyth.Richards@bp.com Authorized Name:Richards, Meredyth Authorized Title: Authorized Signature with Date:Contact Phone:+1 9075644867 Treatment descriptions including volumes used and final pressure: 13. Petroleum Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9405 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Mill CIBP Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028332 PBU 16-02 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Meredyth Richards Digitally signed by Meredyth Richards Date: 2020.04.28 07:24:30 -08'00' By Samantha Carlisle at 8:12 am, Apr 28, 2020 ACTIVITYDATE SUMMARY 3/26/2020 CTU 8 1.75" CT Job Scope: Pull WRP/Mill CIBP MIRU. Make up and RIH JetBlaster with 2.800" drift ring. ***Job Continued on 3/27/20*** 3/27/2020 CTU 8 1.75" CT Job Scope: Pull WRP/Mill CIBP Make up and RIH JetBlaster with 2.800" drift ring. Tagged at 10283 and begin jetting hot diesel. Could not get deeper jetting hot diesel. POOH. MU and RIH with 2.70" venturi junk basket. Tag at 10,290', venturi down to 10,350'. POOH. Make up and RIH with WRP pulling tool and fishing string. Tagged/worked at 10335CTM, POOH. No fish. Inspect fishing tools, make back up and RIH with same BHA. ***Job Continued on 3/28/20*** 3/28/2020 CTU 8 1.75" CT Job Scope: Pull WRP/Mill CIBP RIH with WRP retrieval BHA. Tagged 10337 and made hole to 10357. OOH with fishing BHA and have the WRP and all elements intact. Make up and RIH with venturi/burnover shoe BHA. Unable to mill CIBP after 12 stalls. POOH. Make up and RIH with 5-blade junk mill. Tagged CIBP at 10353. Established pattern, POOH for ventrui and burn over shoe. ***Job Continued on 3/29/20*** 3/29/2020 CTU 8 1.75" CT Job Scope: Pull WRP/Mill CIBP RIH with venturi and burn over shoe. Tag CIBP at 10358 and mill CIBP. Continue milling down 12', to out of tubing tail. RIH and dry tag at 10474CTM. POOH. 1 slip recovered, venturi packed off with schmoo. Make up and RIH with slim clean out BHA. Tag at 10,473', could not get deeper. POOH jetting hot diesel across casing/liner. Pump 60/40 down tubing for freeze protect. RDMO *** Complete *** Daily Report of Well Operations PBU 16-02 MEMORANDUM TO: Jim Regg p P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 23, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-02 PRUDHOE BAY UNIT 16-02 Sre: Inspector Reviewed By: P.I. Supry lz� Comm Well Name PRUDHOE BAY UNIT 16-02 API Well Number 50-029-20544-00-00 Inspector Name: Jeff Jones Insp Num: miU1190118140410 Permit Number: 180-150-0 Inspection Date: 1/3/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 16-02 Type Inj TVD 8492 Tubing 1 -1 89 1789 1789 ' 1788 PTD 1801500 Type Test SPT ITest psi 2123 - IA 16� 2602 2537 2580 — BBL Pumped: s.a $BL Returned: 5 OA v1 Sae ' 386 346 Interval REQVAR P/F P v Notes: AA 4E.014; IA x OA communication. I well inspected; no exceptions noted - Wednesday, January 23, 2019 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,January 06,2017 P.I.Supervisor , l(617 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 16-02 FROM: Guy Cook PRUDHOE BAY UNIT 16-02 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 16-02 API Well Number 50-029-20544-00-00 Inspector Name: Guy Cook Permit Number: 180-150-0 Inspection Date: 1/3/2017 Insp Num: mitGDC170103142550 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 16-02 , Type Inj W TVD 8492 • Tubing 16651670, J 1677 . 1678 PTD 1801500 Type Test SPT Test psi 2123 - IA 335 2579 ! 2551 - 2544 _ ------- ------- InterVal `IREQVAR % IP/F P OA 288 486 _ , 482 484 . Notes: AIO 4E.014 APR 0 5 Z017 SCAtitiV Friday,January 06,2017 Page 1 of 1 HE STATE i LeZ,( Cf: 73/a 2, 333 West Seventh Avenue GCSA ERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 Mnai : 907 279 1433 AF � Fc, 90/ 270.7542 50i°) JUS 2 2 2014. Spencer Morrison Production Engineer BP Exploration(Alaska), Inc. ,. 1 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 16-02 Sundry Number: 314-093 Dear Mr. Morrison: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED thisGI day of February, 2014. Encl. RECEIVED • STATE OF ALASKA FEB 1 9 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION Z/2I //ic APPLICATION FOR SUNDRY APPROVALS ADCC 20 AAC 25.280 1.Type of Request: AbandonPlugfor Redrill Perforate New Pool Repair Well ChangeApproved Program YP q E ❑ ❑ eP ❑ o9 ❑ Suspend❑ Plug Perforations❑Q . Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 180-150-0 3.Address: Stratigraphic ❑ Service ❑✓ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-20544-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 16-02 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028332 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10795 . 9405. 10350 9012 10350 10747 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 34-114 34-114 Surface 2657 13-3/8"72#L-80 31 -2688 31-2687.81 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 1028 7 29#L-80 9762-10790 8506.41-9400.41 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 5-1/2"Baker SAB Packer Packers and SSSV MD(ft)and ND(ft): 9745,8491.86 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑✓ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Spencer Morrison Email Spencer.Morrison@BP.Com Printed Name Spencer Morrison Title Production Engineer Signature � Phone 564-5773 Date2/iq/1U Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. j \Li.-"""Li.-""" q O \:2 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS MAY 11 2014 Other: 7 Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: /0 — 4,0 /' / /) APPROVED BY Approved by: , / T-1'"--- COMMISSIONER THE COMMISSION Date:e2—j/, V /'2/2/ /1° Form 10-403 Revised 10/2012 c3fri1 Slit,pc It for 12 months from the date of approval. Submit Form and Attachments in Dupli l\� LO -0000 °) 000 m O co 0 ao ao a0 0 = J J O J Z J U) a) U) 0 0 0 0 0 0 0 N N (0r- O co O f� O QO O O O N p 1- st O N N- CO COQ) CO O� O C) C) c 7 C CO N O NT N- 03 ,- - m ,- CO CO CO O f- N O N C) O O m 0 I-- co co O O 1-- I-- CO O O N. co (NI co co Q ~ CN O O r 00) 0) Q Cr) CO C7 � Cr) V' N CO N 00 mc000co co N.- = O m 0 co cs N 0) 0) Ci) 0 Q Q ~0 CN CN 0 C8 M• Cr)CO M N 0) O 0) O co° 000 O o co O O J Z co i co J 0 J v) Nco4t N rn v N N 00 CV N N- 4-5C C? 0) c 0) O N LI) I� CO Q)O N (0 0) O 0) co co co co co I- J '- co N 0) Z Z 0 O O rnH HHw U ✓ C1 CLO 0 ui Z Z Z w 0 0 r m m OZCLCLDDD 0 aaCf) F- 1- Perforation Attachment ADL0028332 Well _ Date Perf Code MD Top MD Base _ TVD Top TVD Base 16-02 7/6/97 RPF 10200 10220 8880 8898 16-02 7/6/97 RPF 10220 10240 8898 8915 16-02 7/6/97 RPF 10240 10250 8915 8924 16-02 7/30/96 SQZ 10294 10334 8963 8998 16-02 - 9/1/06 BPS 10400 10416 9056 9070 16-02 9/1/06 BPS 10416 10430 9070 9083 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF To: Date: 18 February 2014 From: Spencer Morrison - DS 16 & 17 Pad Engineer Code: APBINJEC Subject: 16-02i Profile Modification • IOR:_ Reviewed: Michael Hibbert Est. Cost: 1. S Set WRP Current Status: Operable Last Test: 02/05/2013 WHIP=1,790 psi, Inj vol 15,297 BBLS Max Deviation: 41° @ 9,804' MD Minimum ID: 2.991 at 9,804' ELMD Last Downhole Op: 08/12/2010 IPROF Last Drift/Tag: 08/12/2012 10350' MD with 2.5" sample bailer Tie-in Log Latest H25 Value: None None, Injector Comments, well history, background information An IPROF was run on 16-02 on 8/21/2010 indicating 40% of flow is going beneath the CIBP set at 10,350'. The CIBP was set in 2006 to prevent flow from going into zone 2. . Offset producers to this injector recover most of their oil from Zone 4 where only 60% of injection is going and recover most of their water from zone 2 and 3 where 40% of injection is leaking into. By setting WRP at 10,318' (specific depth to avoid setting on collar) we will know if it was only the CIBP leaking and allowing for injection to go into lower zones, or if water is getting into lower zones from channelling in the scab liner. 16-02i Procedure Drift and tag CIBP with sample bailer. Run a SCMT log from tag to top of liner (9,800' MD). Tie into XO at 9,804' MD when setting 3.5" WRP at 10,318' MD Page 1 of 2 I hlo 0 Minilog for Well Tec9 Prowl Psiu_WP 16-02 ,it,., LAURAJ,%ANSON sc47. iso Last IPROF 8/2010 :0«?l17r1012 Injector well: 16-02 km 1100212004400 00..000.72 • 72310002 00•1 S0,.C•0iT. 1003-01-1000a00OO Cov,l., 0NA Shed"am* 1602 tl..asrw,datum 0 r 1172241.31..1 conOt.tc.•a.t. 111111.02.01 01000-00 frau 10110IIO1 Lop.a..tr 0110.LL711100002 Taal d.0ct,-.10701 10.04.001-14022714 ',r tan >ta. Almelo rce,drmit•a'atom 101027 MT UCSW..70.2000» Gwata 0014 ( .'w, IOTA oy 3_ 'M s2r;lt Writ l.' Of J'A .7 TVO19 MO • a.Nre..a Ole eauLlna i !°f =. c4u nn 400 PE Comments ; ..a ir, `fes 1 5! IL Al MIT! 1150 1 410 : _ 1 L"'� 40 ..0 r.. 1 art. .a.t ron.-. . Jr HIIIIIT.III.d 3a e2.tire t etv.. 11irr..a.4r11_� ... P,t ,e.— X' "n b01 0m...0• r 10700•1100 3-1/2"scab T. "" finer 9801'- ". 60% a t 10361'toshut S. off Z3 thief r t 4211 , 7/28/96 . Set W RP at 10,318' 1:4 r f,oleo• 41. MQ to avoid setting ANSI 411.11 y10 in collar. Ja. ? I JJ.. CIBP at 103S0' rr ` '~ set 9 06 to .$ '' a.�. shut off 27P so. o ,�A�1 i sr. 1000. and provide 1Q. 10't40% �'- injection to Z4, found leaking - : :,,.. n, i 8/21/10 441 •10500— , � Mt ...mmilillik 2 1100 . JI 22114 7111 y 0' 7^r*a. . TW 1,41. j I 1100 Page 2 of 2 TREE FMC GEN 2 Si Y NOTES: H25 READINGS AVERAGE 125 ppm 1/ 1.LFEAD= FMC _O WHEN ON MI.WELL REQUIRES A SSSV WHEN ON ACTUATOR= AXELSON I. KB.ELEV= 72' BF.ELEV= KOP 3231' 2266' 5-1/2"OTIS ROM SSSV NP,D=4.562" Max Angie= 41°@ 7300' CAS LFT MANDRELS Datum MD= 10191' ST MD ND DEV TYPE VLV LATCH FORT DATE Datum ND= 880(7SS • 1 2886 2886 3 CAMCO DMY RA 0 04/20/94 20I] "CONDUCTOR,94#,I+40,D=19.124" 110' 2 5109 4823 39 CAMCO DRAY RA 0 04/20/94 3 6787 6127 40 CAMCO DMY RA 0 04/24/94 13-3/8"CSG,72#,L-80 BTC,D=12.347" —1 2687' la 4 7990 7047 40 CA MCO DMY RA 0 03/15/98 5 8606 7534 36 OTIS DMY RO-3 0 11/27/92 6 8680 7595 34 OTIS DMY RO-3 0 11/27/92 Minimum ID = 2.991" 9804' 7 9103 7950 32 OTIS DMY RA 0 11/27/92 8 9177 8013 32 OTIS DMY RO-3 0 11/27/92 4-1/2" X 3-1/2" XU 9 9445 8238 33 OTIS DMY R0-3 0 11/27/92 10 9520 8300 34 OTIS DMY F3 0 11/27/92 11 9594 8362 32 OTIS MY RO-3 0 11/27/92 12 9664 8423 31 M RLA DMY E-3 0 11/27/92 5-1/2"TBG PC,17#,L-80,.0232 bpf,D=4.892" 9724' r 9730' 1 13-1/2"BKR PBR ASSY,D=-7?—I 9745' 9-5/8"X 5-1/2'BKR SAB PKR D=4.75" 9750' r MLLOUT EXTENSION,D=?" 1 9757' 7"X 4-1/2"XO,D=3.958" TOP OF 7"LNR l—{ 9763' 1II 9801' 4-1/2"G SEAL SUB TOP OF 3-1/2"SCAB LNR I I 9801' 1 ill '' ANL L ENTRY SKRT,D=3.00" 9804' 4-1/2"X 3-1/2"X0,D=2.991" 7 9817' 4-1/2"OTIS XN NP,D=3.725" 4-1/2"TBG PC,12.6#, L-80, H 9819' I. ` BEHIND ♦ tik, 9818' 4-1/2'BKR S/O SUB,D=3.958" 0152 bpf,D=3.958" �♦ 1 9819' —14-1/2"TUBING TA I_D=3.958" CT LNR 9-5/8"CSG,47#,SO095/L-80, 10087' ♦ �� ♦ �♦4 9806' H.MD TT LOGGED 02/04/81 .0732 bpi,ID=8.681" ♦♦ ♦� PERFORATION SUMMARY ♦♦ •♦• REF LOG: BHCS on 01/26/81 ♦: : ANGLE AT TOP PERF: 29°@ 10200' ! :og Note: Refer to Production DB for historical pert data ♦� - SIZE SPF INTERVAL Opn/Sqz SHOT SQZ ♦♦ 3-1/8" 4 10200- 10250 S 07/13/81 12/31/12 ♦ ��. 3-318" 4 10202-10242 0 01/27/90 ♦ _ +!� 10350 2-1/2"BKR CEP(09/01/06)l ! 2-1/2' 6 10202-10252 0 07/06/97 ♦4 il 2-5/8" 0.5 10240-10250 0 01/27/90 ♦ :'' 3-1/8" 4 10292-10332 S 07/13/81 12/31/12 ♦♦� *I 2-1/8" 11 6 10400-10416 C 08/16/96 •♦• �•� I 10361' 1 1-3-1/2"DAVIS LYNCH FLOAT-B-1- 3-3/8" 6 10402- 10432 C 04/11/95 2-1/8" 6 10416- 10430 C 08/16/96 ' 3-3/4" 4 10220- 10240 0 01/27/90 1 3-1/2"SCAB LNR,9.3#,L-80 FL4S, --{ 10361' ' .0087 bpf,D=2.992" 10790' 1 12"JDC(LOST 09/30/90)1 PBTD —1 10748' j 1 7"LNR,29#,L-80 BUTT,.0371 bpf,D=6.184" 10790' DATE 1 REV BY COMMENTS DATE REV BY 1 COMMENTS PRUDHOE BAY UNIT 02/01/81 ROWAN 35 ORIGINAL COMPLETION 02/14/11 MB/JMD ADDED SSSV SAFETY NOTE WELL: 16-02 07/30/96{ CTU CTU 3-1/2"SCAB LNR 01/17/12TMN/JMD ADDED H2S SAFETY NOTE PERMIT No:'1801500 08/26/06 RRDRLH ADPERF(07/06/97) 06/25/12 AM/JMD SCAB LNR CORRECTION API No: 50-029-20544-00 09/01/06 , RRD/PAG SET BKR GBP @ 10350' 08/20/12 PJC PERF CORRECTION SEC.24.T1ON,R15E. 1034'FWL& 1420'FNL 05/30/08 1 P.P/PJC DRAWING CORRECTIONS 08/21/12 GC/PJC SHIFT PERF DEPTH 2'DEEPER 06/04/08 PJP/PJC DRAWING CORRECTIONS 1 BP Exploration(Alaska) . ill • p,3,./(. lb --C2- PTO i `s0® Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] 1 ( " 7 . , / / Sent: Thursday, January 31, 2013 4:18 PM ( To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: Climer, Laurie A Subject: January 2013 AOGCC MIT Forms Attachments: January 2013 MIT Forms.zip Jim, Phoebe, Chris, Please find attached MIT forms for January 2013. Sent Previously L -105 (PTD #2020580) - sent in 01/30 with reclassification Enclosed in .zip file 04 -08 (PTD # 1760100) 12 -21 (PTD # 1840480) AP_ 1. 2013 16 -02 (PTD #1801500) SCANNED 03 -13 (PTD #1790710) 04 -45 (PTD #1940340) 14 -35 (PTD # 1831420) R-11A (PTD # 1982060) V -222 (PTD # 2070590) P -06B (PTD #2051380) Please let me know if I can be of further assistance. Thank you, Mehreen Vazir BP Alaska - Well Integrity Coordinator GVV Global Wells Organization WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator PBP.com 1 . • STATE OF ALASKA r ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.repq(rDalaska.gov; doa .aogcc.nrudhoe.bavAalaska.gov; phoebe.brooksc alaska.gov; tom.maunderI alaska.aov OPERATOR: BP Exploration (Alaska), Inc. „� _ . ( 13 FIELD / UNIT / PAD: Prudhoe Bay /PBU /DS -16 i4 1 1 DATE: 01/06/13 OPERATOR REP: Mehreen Vazir AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16 -02 / Type Inj. W / TVD ' 8,492' Tubing 1874 1863 1859' 1858' Interval V P.T.D. 1801500 ✓ Type test P Test psi ' 2500 Casing 207 ' 2529' 2506 2498' P/F P Notes: AIO 4E.014 for slow IA x OA OA 163 - 355 • 352 351 Pumped 4.3 bbls methanol to reach test pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. _ Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) 2013 0106_MIT_PBU_16 02.xlsx • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, February 09, 2011 TO: Jim Regg P.I. Supervisor ) e 1 Neert Zf (OI ►I SUBJECT: Mechanical Integrity Tests !!!! BP EXPLORATION (ALASKA) INC 16 -02 FROM: Chuck Scheve PRUDHOE BAY UNIT 16 -02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ,j'= -- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 16 - 02 API Well Number: 50 029 - 20544 - 00 - 00 Inspector Name: Chuck Scheve • Insp Num: mitCS110207130142 Permit Number: 180 - 150 - Inspection Date: 2/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16 -02 ' 1 Type Inj. W' TVD 8492 ' IA 600 2500 2470 2470 ✓ P.T.D 1801500 I TypeTest SPT Test psi i 2123 OA 520 700 700 700 Interval REQVAR - p/F P ✓ Tubing 1600 1600 1600 1600 Notes: f 0 Z 014 kAwai APR 3. 3 Z D 1 i Wednesday, February 09, 2011 Page 1 of 1 MEMORANDUM To~ Jim Re I l_~~ ~ ~- ~~' ~ P.I. Supervisor ~ I /I (~ FROM: 7Cr ~C ~ i Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, October 30, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-02 PRUDHOE BAY UNIT 16-02 Src: Inspector N(lN_C'(1NFT11F,NTTAL Reviewed By: P.I. Suprv J Comm Well Name: PRUDHOE BAY UNIT 16-02 API Well Number: s0-029-20544-00-00 Inspector Name: JCr Insp Num: mitJCr091029134643 Permit Number: 180-1s0-0 Inspection Date: 10/2s/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 16-02 8492 IA ~ Well Type Inj. ~' TVD -~- i _ P.T.D lsolsoo TypeTest srT Test psi _2123 .' OA ~ ~_ ~, Interval aYRTST P/F P Tubing s60 2s00 ~ _ 6so soo - laso ~ laso 2460 ~ 24s0 ~ _ _ soo soo laso ~ laso Notes: 4 bbl's pumped for test. ,4:ic~ 4 ~ ,~, tq- 1 ~,ry ~~ ~~ J~~~ ~ ~Y ~tWi i ~~: ~~6 Friday, October 30, 2009 Page 1 of 1 OPERABLE: 16 -02 (PTD #1801500) UIC MITIA complete Page 1 of 2 • Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer @BP.com] Sent: Tuesday, October 27, 2009 10:24 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS2 /COTU OTL; GPB, FS2 DS Ops Lead; GPB, FS2 DS Operators; Rossberg, R Steven; Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Phillips, Patti J Cc: Quy, Tiffany; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: OPERABLE: 16 -02 (PTD #1801500) UIC MITIA complete All, Well 16 -02 (PTD #1801500) passed an AOGCC witnessed MITIA on 10/25/09. The well is now compliant and had been reclassified as Operable. The AOGCC test form will be sent to the AOGCC with the normal end of the month submission. Please let us know if you have any questions. Thank you, Anna Du6e, �. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group MAR (� u Phone: (907) 659 -5102 Pager: (907) 659 -5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, September 27, 2009 7:25 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA) ; 'Schwartz, Guy L (DOA) ; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS2 /COTU OTL; GPB, FS2 DS Ops Lead; GPB, FS2 DS Operators; Rossberg, R Steven; Engel, Harry R; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Phillips, Patti J Cc: Quy, Tiffany; Holt, Ryan P (ASRC); Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 16 -02 (PTD #1801500) Ready to return to injection for UIC M1TIA All, The Drill Site 16 water injection header has been repaired. Well 16 -02 (PTD #1801500) has been reclassified as Under Evaluation so that it may be returned to injection and a 4 -year MITIA may be conducted for AA compliance. Please let us know if there are any questions. Thank you, Anna Du6e, ln.� (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659 -5102 Pager: (907) 659 -5100 x1154 3/1/2011 c.C>w I - OPERABLE: 16 -02 (PTD #1801500) UIC MITIA complete Page 2 of 2 a • From: NSU, ADW Well Integrity Engineer Sent: Sunday, January 11, 2009 8:46 AM To: GPB, Area Mgr East (FS1 /2 /COTU /Seawater); GPB, FS2 /COTU OTL; GPB, FS2 DS Ops Lead; GPB, FS2 DS Operators; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Philips, Patti J I Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Holt, Ryan P (ASRC) Sub'ect: NOT OPERABLE. i6 -02 PTD #1801500 Needs AOGCC 4 -year MIT -]A I ( ) All, Well 16 -02 (PTD #1801500) has been reclassified as Not Operable. The well needs a 4 -year AOGCC MIT -IA by 01/013/09 to remain Operable, but is currently shut -in for surface repairs. Once the repairs are complete, the well can be reclassified as Under Evaluation to place the well online and obtain the required test. Please contact the WOE when the work is complete. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659 -5102 Pager: (907) 659 -5100 x1154 3/1/2011 • ~ ~ ~ ~ ~S ~~ ~ ~~~ ~~~~ ~rL ~~f ~_- ~ `tom ~LASIiA OIL A1111) GA,S COlYSERQ.~~'I011T CO1~II~IISSION • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 995013539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL, AIO 4E.Q14 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~~~~ Jl~~ ZDD RE: PBU 16-02 (PTD 1801500) Request for Administrative Approval Deaz Mr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO") 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. PBU 16-02 exhibits slow IA x OA pressure communication when operating. AOGCC Ends that BPXA has elected to perform no corrective action at this time on PBU 16-02. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU 16-02 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in PBU 16-02 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform anMIT-IA every 2 years to 1.2 times the maximum anticipated well pressure; 4. BPXA shall limit the well's OA pressure to 1000 psi; S. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; AIO 4E.014 January 30, 2007 Page 2 of 2 • 6. after well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 7. The MIT anniversary date is January 13, 2007. Please note that PBU 16-02's status is changed from WAGIN to 1 WINJ. 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. DONE at Anchorage, Alaska and dated January 30, 2007. ;~ Cathy . Foerster Com issioner ~~ °~ ~d ~ ~ ~, a ~- <~~ ~~~~ V11GL11111GLL1 1. Operations Performed: Abandon 0 Repair Well 0 Pluç¡ PerforationsD Stimulate 0 Otherli) CIBP Alter CasingO Pull TubingD Perforate New PoolO waiverO Time ExtensionO Change Approved programO Operation ShutdownD Perforate 0 Re-enter Suspended WellO 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryO 1Øl1.1M 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceŒ 50·029·20544-00-00 7. KB Elevation (ft): 9. Well Name and Number: 72.00 16-02 8. Property Designation: 10. Field/Pool(s): ADL-028332 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 10795 feet true vertical 9405.0 feet Plugs (measured) CIBP set @ 10350 (09/01/2006) Effective Depth measured 10748 feet Junk (measured) None true vertical 9363.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 100 20" 94# H-40 44 - 144 44.0 . 144.0 1530 520 SURFACE 2644 13-3/8" 72# L-80 43 . 2687 43.0 - 2687.0 4930 2670 PRODUCTION I 10045 9-5/8" 47# L-80 42 - 42.0 . 6870 4760 PRODUCTION 9-5/8" 47# SOO-95 10087 8783.0 9410 7330 LINER 1027 7" 29# L-80 9763 . 10790 8507.0 - 9400.0 8160 7020 SCAB LINER 560 3-1/2" 9.3# L-80 9801 - 10361 8540.0 - 9022.0 10160 10530 Perforation depth: Measured depth: 10200·10250,10398-10430 sf A Tfo,'Nt~~, ~~V' IJi,ti ':~~.~ True vertical depth: 8880·8924, 9054-9083 Tubinç¡ (size, ç¡rade, and measured depth): 5-1/2" 17# L·80 @ 39 . 8788 4-1/2" 12.6# L·80 @ 8788 . 9819 Packers & SSSV (type & measured depth): 9·5/8" Baker SAB Packer @ 9745 5·1/2" Otis RQM SSSV @ 2266 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft 0 CT 1 j 2006 Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -- -.. 14490 380 1173 Subsequent to operation: ... ..- SI 0 0 14. Attachments: 15. Well Class after proposed work: Exploratory(] DevelopmentD ServiceŒ] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilO GasD WAG 0 GINJD WINJŒ) WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature ~~ At? y,. f Phone 564-5174 Date 1 0/6/06 Form 10-404 Revised 4/2004 U ~ I G II\J A L ~ R~:f¡d¥f:D . ""'t~'~ ,- OCT 1 0 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TI~~ Oil & Gas Cons. Commission Anchorage . STATE OF ALASKA . . 16-02 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/05/2006 Inj Press, psi: Type: PW Vol: 09/01/2006 SLB E-LlNE SET PLUG @ 10350' (CENTRAL ELEMENT). RIH WITH 2.562 BAKER CIBP TO 10394'. PAD OP NOTIFIED UPON DEPARTURE T/I/O: 0/500/0 ***WELL LEFT SHUT IN*** ***** JOB COMPLETE***** 08/31/2006 ***WELL SHUT IN UPON ARRIVAL*** (set cibp) T/I/O: 0/500/0 RIGGING UP E-LlNE. 08/10/2006 (pre cibp) RIG DOWN SLlCKLlNE. *** LEFT WELL SHUT IN *** 08/09/2006 ***WELL S/I ON ARRIVAL*** (pre cibp) PULLED WRDP-2 SSSV (SER# H2S-261) (BALANCE OPERATED). DRIFTED W/2 7/8" DMY GUN, SD @ 9786' SLM, UNABLE TO WORK PAST. DRIFTED W/2.75" SWEDGE, 1.75" SAMPLE BAILER, TAGGED TD @ 10441' SLM, STICKY BOTTOM. SAMPLE BAILER RECOVERED SHMOO. BBLS 2 2 FLUIDS PUMPED I Diesel --- PT Surface Equipment TOTAL Page 1 . ~ TREE = FMC GEN 2 WB..LHEAD = FMe 16-02 ACTUA TOR = AXB..SON , KB. B..EV = 72' BF. B..EV = KOP= 3231' 2266' 1-1 5-1/2" OTIS RQM SSSV NIP, 10 = 4.562" Max Angle = 41 @ 7300' . GAS LIFT MANDRELS Datum MD = 10190' ST MD TVD DEV TYÆ VLV LA TCH PORT DATE Datum TV 0 = 8800' SS 1 2886 2886 2 CAMCO DMY RA 0 04/20/94 2 5109 4823 39 CAMCO DMY RA 0 04/20/94 J ~ 3 6787 6127 40 CAMeO DMY RA 0 04/24/94 113-3/8" CSG, 72#, L-80, 10= 12.347" I 2687' 4 7990 7047 40 CAMCO DMY RA 0 03/15/98 I 5 8606 7534 36 OTIS DMY RO-3 0 11/27/92 L 6 8680 7595 34 OTIS DMY RO-3 0 11/27/92 7 9103 7950 32 OTIS DMY RA 0 11/27/92 Minimum ID = 2.991" @ 9804' 8 9177 8013 32 OTIS DMY RO-3 0 11/27/92 9 9445 8238 33 OTIS DMY RO-3 0 11/27/92 4-1/2" X 3-1/2" XO 10 9520 8300 34 OTIS DMY RO-3 0 11/27/92 11 9594 8363 32 OTIS DMY RO-3 0 11/27/92 l I 12 9664 8422 31 MERLA DMY E-3 0 11/27/92 I 9730' 1-1 5_1/2" BKRPBRASSY I ; 18 .,...". 9745' 1-1 9-5/8" X 5_1/2" BKR SAB A<R I ð. 5-1/2" TBG PC, 17#, L-80, .0232 bpf, 10 = 4.892" ---1 9756' 9756' 1-1 5-1/2" x 4-1/2" XO I ITOPOF 4-1/2" TBG-PC 1- 9756' 1 TOP OF 7" LNR 1- 9763' ~ . I 9801' 1-1 4-1/2" G SEAL SUB W/ WLE SKIRT I TOPOF 3-1/2" SCAB LNR I (, ~ ! 9804' 1-4 4_1/2" X 3_1/2" XO, 10 - 2.991" I 9801' I r I 9817' -I 4-1/2" OTIS XN NIP (BEHIND LNR), 10 = 3.725" I 1---1 9818' 1-1 4-1/2" BKR S/O SUB (BEHIND LNR) I 14-1/2" TBG PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 9819' -I- ¡....- 9819' 1-1 4-1/2" TUBING TAIL (BEHIND LNR) I I 9806' 1-1 B..MD TT LOGGED 02/04/81 I I 9-5/8" CSG, 47#, L-80, .0732 bpf, 10 = 8.681" I 10087' 1---4 ... PERFORA TION SUMMARY ¡ I REF LOG: BHCS on 01/26/81 [ ANGLEAT TOP PERF: 29 @ 10198' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE I 2-1/2" 6 10200 - 10250 0 07/06/97 3-3/8 " 0.5 10200 - 10250 0 01/27/90 - I 10350' 1-1 2-1/2" BKRCIBP(09/01/06) I 8 10200 - 10250 S 07/13/81 8 10294 - 10334 S 07/13/81 2-1/8" 12 10400 - 10416 C 08/16/96 2-1/8" 12 10416 - 10430 C 08/16/96 3-3/8" 6 10398 - 10428 C 04/11/95 I 3-1/2" SCAB LNR, 9.3#, L-80, .0087 bpf, 10 = 2,992" I 10361' .. 10361' 1-1 3-1/2" DAVIS LYNCH FLOAT SHOE IPBTD I 10748' I -, I 10790' 1-1 2" JDC (LOST 09/30/90) I 17" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1-1 10790' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 02/01/81 ORIGINAL COMPLETION WB..L: 16-02 07/29/01 RN/KAK CORRECTIONS PERMIT No: 80-150 02/09/03 ATD/TP DB..ETEWANERSAFETY NOTE API No: 50-029-20544-00 08/26/06 RRD/TLH ADPERF (07/06/97) Sec. 24, T10N, R15E, 820.67 FB.. 4076.35 FNL 09/01/06 RRDlPA G SET BKR CIBP @ 10350' BP Exploration (Alaska) e e Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska) Inc. Prudhoe Bay 1 PBU 1 OS 16 02/20106 Anna Oube Packer Depth Pretest Initial 15Min. 30 Min. Well 116-02 I Type Inj. I W TVD 8,491 ' Tubing 1,100 1,100 1,100 1,100 Interval I 0 P.T.D.11801500 I Type test I P Test psi 2122' Casing 250 2,500 2,470 2,450 P/FI P Notes: MIT-IA to apply for AA and waiver. OA 380 600 600 600 Witnessing declined by AOGCC representative. Weill I Type Inj. I TVD I Tubing Interval p.T.D.1 I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval 1 P.T.D./ I Type test I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test ps¡ Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval p.T.D.1 I Type test I Test ps¡ Casing P/FI Notes: OA AOGCC rep. Chuck Scheve declined to witness on 02119/06 TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) >'~CA~t~4j¡:':ifl. '" . 4 "''' '"., "'....'""" ',,'..-.. '~i MIT PBU 16-02 02-20-06-1.xls ~7 ?1Z-4-{D~ \\0" \'SO // MEMORANDUM TO: Jim Regg '\(ÎiA \' ..j 'í P.I. Supervisor' ''''rl ,z, t ií1 Õt\ Chuck Scheve L Petroleum Inspector FROM: Well Name: PRUDHOE BAY UNIT 16-02 Insp Num: mitCS041208090702 Rei Insp Num: ') State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 09,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-02 PRUDHOE BAY UNIT 16-02 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-20544-00-00 Permit Number: 180-150-0 Packer Depth Pretest Initial Well 16-02 Type Inj. P TVD 8491 IA 200 2990 P.T. 1801500 TypeTest SPT Test psi 2122.75 OA 110 310 Interval OTHER P/F P Tubing 1000 1000 Notes: Test performed due to possible slow IA x OA communication. Thursday, December 09,2004 SCANNED DEC 2 t4Î 2004 ') \~l9Ü Reviewed By: P.I. Suprv crg,e. IZI,.3/otf- Comm Inspector Name: Chuck Scheve Inspection Date: 12/7/2004 15 Min. 30 Min. 45 Min. 60 Min. 2940 2940 310 300 1000 1000 Page 1 of I MEMORANDUM TO: Jim Regg. y?"ti 1z\I3IM P.I. SupervISor \ -,; l"t Chuck Scheve Petroleum Inspector FROM: Well Name: PRUDHOE BAY UNIT 16-02 Insp Num: mitCS041208091345 Rei Insp Num: State of Alaska ) Alaska Oil and Gas Conservation Commission DATE: Thursday, December 09, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 16-02 PRUDHOE BAY UNIT 16-02 \\.~ "cr¡" , Src: Inspector Reviewed By: P.I.Suprv~ Comm NON-CONFIDENTIAL API Well Number: 50-029-20544-00-00 Permit Number: 180-150-0 Inspector Name: Chuck Scheve Inspection Date: 12/7/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 16-02 Type Inj. P TVD 8491 IA 200 310 310 310 310 P.T. 1801500 TypeTest SPT Test psi 2122.75 OA 130 2410 2350 2310 2300 Interval OTHER P/F P Tubing 1000 1000 1000 1000 1000 Notes: MITOA Thursday, December 09,2004 SCANNED DEC 2 20rH Page 1 of 1 RE: Well 16-02 (PTD 1801500) Failed MITIA ) ') ~ Fï1J l &J.- IgD Subject: RE: Well 16-02 (PTD 1801500) Failed MITIA From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Fri, 10 Dec 2004 15:27:43 -0900 To; :-"AOGCC- Jim Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOGCC- Winton Aubert (E-mail)..<wintoll_aubert@admin.state;ak.us> .. .. . CC: "Rossberg,R Steven" <RossbeRS@BP .com>, "GPB, FS2/COTU Area Mgr". . <QPBFS2TL@BP.com>, "GPB,FS2 .DS. Ops Lead" <GPBFS2DSOpsLead@BP~com>, .1fNSU~.. ADW We.ll Operations Supervisor" <NSUADWWel1OperationsSupervisor@BP.com>, "Lee, Timothy" . <Tjrnotþy.Lee@BP . com>, "Engel, Harry Rtf <EngelHR@BP . com>, "Mielke, Robert L. ,. <robert.mielke@BP.com>, "NSU,ADW.Well Intëgrity Engineer" . ..' <NSUADWW ellIntegrityEngineer@BP.com>. Hello Jim & Winton. This is an update on testing being conducted on injection well 16-02 to evaluate slow IAxOA communication. On 12/6/04, an MITIA passed to 3000 psi and an MITOA passed to 2400 psi. Recent events: lO/31/03: OART - FAILED to 1900 psi, monitored until 11/27 ll/29/04: Email to Aubert & Regg for slow IAxOA comm l2/06/04: MITIA Passed to 3000 psi. MITOA passed to 2400 psi. OA pressured up 200 psi during MITIA. Current plan is to submit an AA to request continued operation with slow IAxOA corom. Please call if you have any questions. Joe Anders 65~-5102 -----Original Message----- From: NSU, ADW Well Integrity Engineer Sent: Monday, November 29, 2004 8:57 PM To: AOGCC - Jim Regg (E-mail); AOGCC - Winton Aubert (E-mail) Cc: Rossberg, R Steven; GPB, FS2/COTU Area Mgr; GPB, FS2 DS Ops Lead; NSU, ADW Well Operations Supervisor; Lee, Timothy; NSU, ADW Well Integrity Engineer; Engel, Harry R; Reeves, Donald F Subject: Well 16-02 (PTD 1801500) Failed MITIA Hello Jim & Winton. Well 16-02 (PTD 1801500) appears to have slow IAxOA communication. pressured to 1600 psi and the OA pressure was observed to increase approximately 70 psi/day. The attached TIO plot illustrates the OA characteristics. The IA was at a rate of repressure Plan is to conduct an MITIA and MITOA, then evaluate for an Administrative Approval. Attached is a wellbore schematic and TIO plot. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADWWelllntegrityEngineer@bp.com ',' t' ÎIo.H"'ÎE."~.j [-) E (.. '" -i t)C.' r\ /1 ~\,11< -\nH~ .=r.. ... ..p 2 J. L ..)', 1 of 1 12/13/2004 11:19 AM Well 16-02 (PTD 1801500) Failed MITIA ') SuJ>ject: Well 16-02 (PTD 1801500) Failed MITIA From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Mon, 29 Nov 2004 20:56:32 -0900 ~o!: "AOGCC - Jim Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOGCC - Winton Aubert (Eimail)" <\vinton_aubert@admin.state.ak.us>, '.' :. . CC: "Rossberg, R Steven" <RossbeRS@BP.com>, "GPB, FS2/COTU Area Mgr"., . . <GPBFS2TL@BP.com>, "GPB, FS2DS Ops Lead" <GPBFS2DSOpsLead@BP.com>, "NSU~ ADW W~ll Operations Supervisor" <NSUADWWellOperationsSuperv-isor@BP.com>, "Lee, Timothytl .' <Tpnothy.Lee@BP.com>, "NSU, ADW Well Integrity Engineer", . . . . <N'SUADWWellIntegrityEngineer@BP.com>, "Engel, Harry R" <EngeIHR@BP.com>, ItReeves, DonaldF" <ReevesDf@BP.com>' , , .' , ) . Q/:!t, J ~ f; .7J;f!fj~.".i. aU . Hello Jim & Winton. Well 16-02 (PTD1801500) appears to have slow IAxOA communication. The IA was pressured to 1600 psi and the OA pressure was observed to increase at a rate of approximately 70 psi/day. The attached TIO plot illustrates the OA repressure characteristics. Plan is to conduct an MITIA and MITOA, then evaluate for an Administrative Approval. Attached is a wellbore schematic and TIO plot. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUAm~WellIntegrìtyEn9ìneer@bp.com «16-02.pdf» «16-02 TIO Plot 11-29-04. Content-Description: 16-02.pdf Content-Type: application/octet-stream Content-Encoding: base64 16-02 TIO Plot Content-Description: 16-02 TIO Plot 11-29-04.jpg Content-Type: image/jpeg Content-Encoding: base64 SCANNED DEC 0 1 200lJ. 1 of 1 11/30/2004 8:08 AM TREE = FMC GEN 2 WB..LHEAD = FMC ~~.~~~~~~~_A~~~~~'" ACflJl\ TOR = AXELSON """ ~ --.~-~~ ~ KB. ELEV = 72' BF. ELEV = kop = 3231' MãX."Än'g~'=...''''.''41 @"7àõóï DatUm ~rD ;.--,.,,- 1019a Dãtum TVD";;-~ÕÕ' SŠ ) 113-318" CSG, 72#, L-80, ID = 12.347" 1-1 2687' r---4 Minimum ID = 2.991" @ 9804' 4-1/2" X 3-1/2" XO 15-1/2" TBG FÇ, 17#, L-80, 0.0232 bpf, ID = 4.892"- 9756' 1 TOP OF 4-112" TBG-PC - 9756' ITOPOF 7" LNR l-¡ 9763' ITOP OF 3-112" SCAB LNR H 9801' 14-1/2" TBG Fe, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l--i 9819' 19-5/8"CSG,47#,L-80,0.0732bpf,ID=8.681" l--f 10087' ~ PffiFORATION SUrvTv1ARY REF LOG: BHCS on 01/26/81 ANGLEATTOPÆRF: 29 @10198' Note: Refer to Production DB for historcal perf data SIZ E SPF INlERV AL OpnlSqz I)A. TE 8 10200-10250 S 7/1311981 3-3/8" 0.5 10200-10250 0 1/27/1990 2-1/2" 6 10200-10250 0 7/6/1997 8 10294-10334 S 7/13/1981 2-1/8" 12 10400-10416 0 8/16/1996 2-1/8" 12 10416-10430 0 8/16/1996 3-3/8" 6 10398-10428 0 4/11/1995 16-02 L :8: ... / ~ _J 8 L J ~ 2266' STA 1 2 3 ~ 4 5 6 7 8 9 10 11 12 9730' 9745' 9756' ) SAFETY NOTES: T X IA COM M ON MI. POSSIBLEIA x OA COMM AND/OR OA X FORM. H 5-112" OTIS RQM SSSV NIP, ID =4.562" 1 GAS LFT MA.NDRELS MD TVD DEV TYPE LATCH 2886 2886 2 011S RÞ. 5109 4823 39 011S RÞ. 6787 6127 40 011S RÞ. 7990 7047 40 011S RÞ. 8606 7534 36 011S RO-3 8680 7595 34 011S RO-3 9103 7950 32 011S RÞ. 9177 8013 32 011S RO-3 9445 8238 33 011S RO-3 9520 8300 34 011S RO-3 9594 8363 32 011S RO-3 9664 8422 31 011S 6-3 H 5-112" BKR PBR ASSY 1 H 9-5/8" X 5-1/2" BKR SA B PKR H 5-112" X4-1/2"XO .. I 9801' H 4-112" G SI:AL SUB W/ WLESKRTI \ I 9804' H 4-1/2" X 3-1/2" XO, ID = 2.991" I II l 1 9817' 1---1 4-1/2"011SXNNIP(BEHINDLNR),ID=3.725" I ---- 9818' - 4-112" BKRS/OSUB (BEHINDLNR) 9819' - 4-112"1UBINGTAIL(BEHINDLNR} 1 1 9806' H ELI\¡[) IT LOGGED 02104/81 13-112" SCAB LNR, 9.3#, L-80, .0087 bpf, ID= 2.992" H 10361' ~ .. ~ 10748' I ~ r7" LNR, 29#, L-80, 0.0371 bpf, ID=6.184" H 10790' r------.4.~ DA.1E REV BY COI\i1VlENfS 02101/81 ORlGINI\L COMPLETON 01/02101 SIS-QAA CONVffilED TO CAM/AS 02121/01 SS-LG REVISON 07/29/01 RN'KAK CORROCTONS 02109/03 A 1DrrP DELETE WA IVER SA ÆlY NOTE DA. TE REV BY I .. ~ ~ I 10361' H 3-112" DA.VIS LYNCHFLOATSHOEI I 10790' H 2" JDC (LOST 09/30/90) 1 CO I\i1VIENTS ffiUŒlOE SAY UNT WB..L: 16-02 ÆRMITNo: 80-150 API No: 50-029-20544-00 Sec. 24, T10N, R15E, 820.67 FB.. 4076.35 FNL 8P Exploration (Alaska) ~"~I STATE OF ALASKA ' AL KAOILAND GAS CONSERVATION COMMISSI ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown_ Stimulate~ Plugging_ Per~orate _X Pull tubing __ Alter casing _ Repair well _ Other _ 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage~ AK 99510-0360 4. Location of well at surface: 1420' FI,IL 1034' FWL, Sec 24, T10N, R15E, MM. At top of productive interval: 1064' FSL, 1068' FEL, Sec 13, T10N, R15E, MM. At effective depth: At total depth: 1202' FSL, 822' FEL, Sec 13, TION, R15E, UM. 5. Type of Well: Development _ Exploratory _ · Stratagrapic _ Service _X 6. Datum of elavation (DF or KB feet): 72' RKB 7. Unit or Property: Prudhoe Bay Unit 8. Well number: 16-02i 9. Permit number/approval number: 80-150 10. APl number: 50-029-20544 11. Field/Pool: Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective Depth: measured .true vertical Casing Length Conductor 100' Surface 2615' Production 10015' Liner 1027' Scab Liner 560' Perforation Depth measured 10795 feet Plugs (measured) 9405 feet 10443 feet Junk (measured) 9094 feet PBTD Tagged at 10443' MD (6/26/97). Size Cemented Measured depth True vertical depth 20" 348 Sx AS II 100' 100' 13-3/8" 3000 Sx Fondu, 2687' 2687' & 450 Sx PF 9-5/8" 500 Sx Class G 10087' 8783' 7" 400 Sx Class G 10790' 9400' 3-1/2" 15 Bbls LARC 10361' 9022' 10200-10250';10398-10430' true vertical 8880 - 8924'; 9054 - 9082' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9756' MD; 4-1/2", 12.6#, L-80, PCT @ 9819' MD. Paokersand SSSV (type and measured depth) Baker SAB Packer @ 9745' MD; Otis RQMSSSV @ 2266'MD. R~E~E~ VE D 13. Stimulation or cement squeeze summary Intervals treated (measured) Intervals treated (measured) see attached ORI61NA 14. Prior to well operation Oil-Bbl Representitive Daily Average Production or Injection Data Gas-Mcf Water-Bbl 8519 Casing Pressure Tubing Pressure - 1377 Subsequent to operation 15. Attachments 116. Status of well classification as: I Copies of Logs and Surveys run _ Daily Report of Well Operations _ X Oil _ Gas _ 17. I hereby certily that the foregoing is true and correct to the best of my knowledge. Signed ~_~ ~1/1. ~ 'l'itle: En~lineering Supervisor Form 10-404 Rev 06/15/88 9778 1367 Suspended _ Service _X SUBMIT IN DUPLICATE 16-02i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/6/97: MIRU & PT equipment. RIH w/perforating gun & shot 50' of reperforations as follows: Reperforated: 10200- 10250' MD (Z4) Ref. Log: BHCS 1/26/81. Used 2-1/2" carriers & shot 6 spf at 60 degree phasing at balanced pressures. POOH w/perf guns. Rigged down. Returned the well to produced water injection & obtained a valid injection rate. STATE OF ALASKA ALASKA C~ ')AND GAS CONSERVATION COl~ ~SSION REPORT OF SUNDRY WELL OPERATIONS Stimulate ~ Plugging ....-- Perforate X 1. Operations performed: Operation shutdown Pull tubing ~ Alter casing .---- 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1420' FNL, 1034' FWL, Sec 24, T10N, R15E, UM. At top of productive interval 1064' FSL, 1068' FEL, Sec 13, T10N, R15E, UM. At effective depth Repair well 5. Type of Well Development Exploratory Stratigraphic At total depth 1202' FSL, 822' FEL, Sec 13, T10N, R15E, UM. Other 6. Datum of elevation(DF or KB) 72 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-02i 9. Permit number/approval number 80-150 10. APl number 50 - 029-20544 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10795 feet 9405 feet Plugs(measured) PBTD Tagged @ 10449' MD (8/7/96). Effective depth: measured true vertical Casing Length Conductor 100' Surface 2615' Production 10015' Liner 1027' Scab Liner 560' 10449 feet 9099 feet Junk(measured) ORIGINAL Size Cemented Measured depth True vertical depth 20" 348 Sx AS II 100' 100' 13-3/8" 3000 Sx Fondu & 450 Sx PF 2687' 2687' 9-5/8" 500 Sx Class G 10087' 8783' 7" 400 Sx Class G 10790' 9400' 3-1/2" 15 Bbls LARC 10361' 9022' Perforation depth: measured 10398 - 10430' RECEIVED true vertical 9054- 9082' 5 ~-~ 1 9 1996 Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC Tbg @ 9756' MD; 4-.1/~)" 1 Alast{aOil &"Ghs ~0C~: b't0'!~8~' @ 9819' MD. Ancl~erage Packers and SSSV (type and measured depth) Baker SAB Packer @ 9745' MD; Otis RQM SSSV @ 2266' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Represente, tive Daily Averaqe production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - 733 -- 1941 Subsequent to operation - - 2099 -- 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil=._. Gas __ Suspended _._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 2024 Injector Signed- '~(.,~ ~., Form 10-404 Rev 06/15/88 CC: JWP. Title Engineering Supervisor Date '~-' SUBMIT IN DUPLICATE~=~ 16-02i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 8/1 6/96: MIRU & PT equipment. Added Perforations: 10398 - 10400' MD (Z3) Ref. Log: BHCS 1/26/81. Reperforated: 10400 - 10428' MD (Z2) Ref. Log: BHCS 1/26/81. Used a 2-1/8" carrier & shot 6 spf at 90 degree phasing at balanced pressure. POOH w/perf guns. Noted all shots fired. Rigged down. RIH w/perforating gun & shot 30' of perforations as follows: Returned the well to produced water injection & obtained a valid injection rate. RECEIVED SEP 19 1996 Alaska 011 & Gas Cen~. ~lam~ ST^T ALASKA (. ')AND GAS CONSERVATION CON, _~iSSlON REPORT OF SUNDRY WELL OPERATIONS Operation shutdown Stimulate Pull tubing Alter casing 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1420' FNL, 1034' FWL, Sec 24, T10N, R15E, UM. At top of productive interval 1064' FSL, 1068' FEL, Sec 13, T10N, R15E, UM. At effective depth Plugging Perforate At total depth 1202' FSL, 822' FEL, Sec 13, T10N, R15E, UM. 12. Present well condition summary Total depth: measured 10795 feet true vertical 9405 feet Repair well Imm*,* 5. Type of Well Development Exploratory Stratigraphic o~r ~ 6. Datum of elevation(DF or KB) 72 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-02i 9. Permit number/approval number 80-150 10. APl number 50 - 029-20544 11. Field/Pool Prudhoe Bay Oil Pool feet Plugs(measured) PBTD Tagged (~1~~~~). Effective depth: measured 10449 feet true vertical 9099 feet Junk(measured) Casing Length Size Cemented Conductor 100' 20" 348 Sx AS II Sudace 2615' 13-3/8" 3000 Sx Fondu &450 Sx PF Production 10015' 9-5/8" 500 Sx Class G Liner 1027' 7" 400 Sx Class G Scab Liner 560' 3-1/2" 15 Bbls LARC AUG 1 6 996 ~&~lkmm~lb)n~EiM~P~,(~) depth 100' Anchorage 100' 2687' 2687' 10087' 8783' 10790' 9400' 10361' 9022' Perforation depth: measured 10400 - 10430' true vertical 9056 - 9082' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PC Tbg @ 9756' MD; 4-1/2", 12.6#, L-80, PCT @ 9819' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 9745' MD; Otis RQM SSSV @ 2266' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaoe Production or InjectiQn Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure - - 17209 -- 1481 - - 733 -- 1941 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil..._ Gas__ Suspended...._ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~'~ '~-~'~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 CC: JWP. SUBMIT IN DUPLICAT~,, 16-02i DESCRIPTION OF WORK COMPLETED CT CONYEYED SCAB LINER INSTALLATION FOR PROFILE MODIFICATION 7/25/96: MIFIU CTU & PT equipment. POOH w/nozzle. RIH w/nozzle & jetted schmoo cleanout passes down to 10703' MD. 7/26/96: RIH w/nozzle & pumped 29 bbls of gelled sand slurry containing 7200 lbs sand to spot an isolation sand plug over the lower open perforation interval at: 10400 - 10430' MD (Z2) Ref Log: BHCS 1/26/81. Reversed off top of sand plug down to 10370' MD. POOH w/nozzle. MU 3-1/2" Liner assembly. 7/27/96: RIH w/Scab Liner & landed the liner on top of the sand plug at 10360' MD. Pumped 15 bbls of Latex Acid Resistive cement to set the Scab Liner assembly from 9801' to 10361' MD, and to isolate the upper thief perforation intervals at: 10200 - 10250' MD (Z4: Open) 10294 - 10334' MD (Z4/3: Sqzd/leaking) Ref Log: BHCS 1/26/81. Displaced cement by liner shoe w/Seawater & squeezed cement behind pipe at 1000 psi maximum squeeze pressure held for 1 hour. Contaminated liner cement w/33 bbls biozan & POOH. WOC. RDMO CTU. 7/28/96: W~. 7/29/96: WOC. MIRU CTU & PT equipment. RIH w/milling BHA. PT cement to 2000 pSi; had no leakoff. Tagged cement at 10262' MD, then drilled cement from liner to 10363' MD. POOH w/BHA. 7/30/96: RIH w/milling BHA to mill past the cement/sand interface, then washed through the sand plug to 10410' MD & circulated out sand/fill to uncover the lower perforation interval (listed above). POOH w/BHA. RIH w/jetting nozzle & circulated sand/fill from well w/biozan to 10535' MD. POOH w/nozzle. RDMO CTU. 8~7~96: RIH & tagged PBTD at 10449' MD. Placed well on produced water injection & obtained a valid injection rate. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 AT'TN: Sherrie NO. 10120 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 4/9/96 Field: Prudhoe Bay ,~-'-.~ Anadrill Anadrill Anadrill Well Job # Log Description Date BL RF Sepia Survey Program Performance Calculation Letter D.S. 1-11 ~ .DUAL BURST TDT-P BORAX 9 6 0401 I 1 D.S. 5-07 -' 'GCT DIRECTIONAL SURVEY 9 6 0 3 31 I 1 D.S. 13-29 ~--PRODUCTION PROFILE 9 6 0 31 3 I 1 .D.S. 13-29 ~.~ DIGITAL ENTRY FLUID TOOLS~/-~ ' 96031 3 I 1 D.S. 14-3 ~,~RODUCTION PROFILE 960322 1 1 D.S. 14-43 ~:PRODUCTION PROFILE 960323 I 1 D.S. 16-2 / ~INJECTION PROFILE 960326 I 1 D.S. 16-8 ~ PRODUCTION PROFILE 96031 5 1 1 ..D.S. 16-8 ,/i DIGITAL ENTRY FLUID TOOL 9 6 0 31 5 I 1 , SIGNED' ~ DATE: Alaska Oil & Gas COn~. Commission Anchorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9930 Company: 12/1 5/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 4-13 .-7_~. ~1 INJECPRORLE 951109 I 1 O.S. 4-17'~ ~..O INJECPROFILE 951118 I 1 D.S. 4-19 ~'~ ~. ti/ DUAL BURST TDT-P 951112 I 1 D.S. 4-28 ~ ~' :2.-~:::~ INJECTION PROFILE 95111 0 I 1 D.S. 5-4'~ ~'/ ~'-C/ PROD PRORLE 951115 I 1 D.S. 9-04A~ "~,~ !PROD PROFILE . 951110 I 1 D.S. 14-16 ~'1t. . PROD LOG WlTH DEFT 951107 I 1 D.S. 14-19 ST1 ~ ~'~ PRODPRORLE 951119 I 1 D.S. 16-02 ~' { %"'(~ MI INJECTION PROFILE LOG 951119 I I . D.S. 18-23A ~ '~I LEAK DETECTION LOG 951114 I 1 , , , , , 1 , SIGNED:~~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9762 Company: 9/27/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Floppy RF Sepia DIR MWD Disk D.S. 1-28 ~,-O~' "' pRODUCTION PROFILE 950921 I · 1 D.S. 1-31 ~'/o ' ! ~ 'Z- PRODUCTION PROFILE 950 92 0 I 1 D.S. 2-15 ~'(.~- OJ¢~ PRODUCTION PROFILE 950920 I 1 D.S. 9-3 '7~- 0~'" BAKER INFLATABLE BRIDGE pLUG 950917 I 1 D.S. 9-4A ~ ~'o 0~.~. PERFORATION RECORD 95091 8 I 1 D.S. 12-15 ~'~ -D~ ~- BAKER INFLATABLE BRIDGE PLUG 950921 I 1 D.S. 16-02~O'1 ~"O INJECTION PROFILE 950921 I 1 D.S. 17-21 ~.-12-5'" PERFORATION RECORD 950919 I I SIGNED' ' ~ Please s g a d re u n one copy of this transmittal to Sherrle at the above address. Thank you. ,Oc? .... , STATE OF ALASKA ALASKA' ~AND GAS CONSERVATION CC '~IlSSION REPORT OF SUNDRY WELL OPE IATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1420' FNL, 1034' FWL, Sec. 24, T10N, R15E, UM At top of productive interval 1064' FSL, 1068' FEL, Sec. 13, T10N, R15E, UM At effective depth At total depth 1202' FSL, 822' FEL, Sec. 13, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 72 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-2i 9. Permit number/approval number 80-15O 10. APl number 50 - 029-20544 11. Field/Pool Prudhoe Bay Oil PoOl feet 12. Present well condition summary Total depth: measured true vertical 10795 feet 9405 feet Effective depth: measured 10600 feet true vertical 9233 feet Plugs(measured) Junk(measured) Casing Length Size Conductor 100' 20" Surface 2615' 13-3/8" Production 10015' 9-5/8" Liner 1027' 7" Cemented 348 Sx AS II 3000 Sx Fondu & 450 Sx PF 500 Sx CI 'G' 400 Sx CI 'G' Measured depth 100' 2687' 10087' True vertical depth 100' 2687' 8783' 9400' Perforation depth: measured 10200-10250'; 10400-10430' true vertical 8880-8924'; 9056-9082' SEP 05 1995 _Ala.$~ .0il & Gas Cons. C0mmissi_0n '.' ~chomge ' Tubing (size, grade, and measured depth) 5-1/2", 17#, PCT @ 9756' MD; 4-1/2", 12.6#, L-80. PCT tail @ 9819' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9745' MD; 5-1/2", Otis RQY SSSV @ 2266' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Re0resentative Daily Averac~e Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure - 24542 10001 Tubing Pressure 1707 3149 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. , FSiogr nme~0 ,_404~/88~ ~'~ AJB/RHL cc: KZ, JWP Title Engineering Supervisor SUBMIT IN DUPLICATE<~ 16-02i DESCRIPTION OF WORK COMPLETED MARCIT GEL SQUEEZE FOR INJECTION PROFILE MODIFICATION 4/3/95: RIH & tagged PBTD at 10400' MD. 4/9/95: MIRU & RIH w/CT milling BHA to mill & circulate out liner fill w/biozan to 10695' MD. RD. 4/10/95: RIH & tagged PBTD at 10713' MD. 411 1/95: Added perforations: 10400 - 10430' MD (Z2) Ref. Log: BHCS 1/26/81. Used 3-3/8" carrier & shot 6 spf at 60 degree phasing at overbalanced pressure. ASF. RD. 4/12/95: MIRU CTU & PT equipment. RIH w/CT to bottom & pumped 43 bbls of gelled sand slurry to spot an isolation sandplug across the lower open perforation interval (listed above). Made final top of sandplug tag at 10347' MD. POOH w/CT. Rigged down. 611195: RIH & tagged top of sandplug at 10335' MD. 8/12/95 - 8/14/95: A CTU MARCIT Gel Squeeze for Injection Profile Modification was performed as follows: MIRU equipment & PT equipment. RIH w/CT mounted Inflatable Packer & inflated packer to set at 10271' MD. Pumped MARCIT Gel sequences to squeeze the open perforations located above the packer at: 10200 - 10250' MD (Z4) Ref. Log: BHCS 1/26/81. Pumped: a) 1106 bbls of 3000 ppm Polymer Gel @ 3.0 - 3.5 bpm, followed by b) 2500 bbls of 4500 ppm Polymer Gel @ 3.2 - 3.5 bpm, followed by c) 2585 bbls of 6000 ppm Polymer Gel @ 2.7 - 3.0 bpm, followed by d) 935 bbls of 7500 ppm Polymer Gel @ 2.4 - 2.7 bpm, followed by e) 980 bbls of 9000 ppm Polymer Gel @ 1.5 - 2.4 bpm, followed by f) 10 bbls Diesel Flush, followed by g) Shutdown. Deflated & POOH w/packer. Rigged down. SEP 05 1995 Alask~ 0il & Gas Cons. Commission Anchorage 8122/95: MIRU & RIH w/CT to jet a gel & sandplug fill cleanout down to 10600' MD, to uncover the lower open perforation interval (above). POOH w/CT. Rigged down. Returned the well to miscible gas injection & obtained a valid injection rate. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9443 Company: 5/3/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 3-27 ~c~-~_-1,, TBG. PACKFRRECORD 041295 I 1 D,S, 4-12 '~ (~- ~ TBG. PUNCHER RECORD 032695 I 1 D,S. 4-37 ~[- {p~ PERF. RECORD 041495; I 1 D,S. 6-17 -' ~/,-C~O PERF. RECORD 041595; I 1 D.S. 14-3 -- 57 IFAKDETECTION 041095 I 1 D,S. 16-2 -~ ~.~:~O~~ PERF. RECORD 0411 951 I 1 D,S, 16-3 '- ~/- /! PERF, RECORD 041095 I 1 D,S, 16-14 "-- ~ ! -,,~_JBRIDGEPLUGRECORD 0413951 I 1 D.S. 18-15 - ~7'~ ;~ CHEMiCALCUTrER 0413951 I 1 D,S, 2-24 95154 CNT-D 0406951 ~_,[ 1 D,S. 18-02A 951 59 PDC 041 895 '~r~ 1 D.S. 15-17 95155 CNT-G 040595 '~ I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: iviAY 0 4 i995 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: August,3, 1994 ARCO Cased Hole Finals Karla Zuspan/ATO- 1529 (907) 265-6547 Distribution P.O. Box 100360, A,,v~orage, ,. Transmittal #: 94068 AK Weil Log Date Tool Type Contractor' Number (M-D-Y) /(~ 01-03 ~-4-94 Leak Det I ' SCH ~.~ ~'~ 03-12 7-2~94 ' !nj Prof 1 SCH " ~'~"?~. 03-i9 7-7-94 Prod Prof' I ' SCH - ~qJ 03-25A '7-7-94 Perf Record I ..... SCH , C3 '04-02 7-3-94 " Leak Det I SCH ~_??_ *04-07 sT1 7-8-94 Perf Record I SCH )¥-).z. ' 05-01 7-9-94 ' Tubin9 cutter I ..... SCH ~' 05-11 7-9-94 PerfRecord I " SCH f~-.,,,~o "06.11 ' 7.2.94 "' Dual Burst"TD'l'-p I ' SCH ' ~ 06-21 7-1-94 Prod Pmf I SCH ,, r~ -5" ? 06-22A, 7-4-94 Perf Record 1 . SCH ~"rC,-~ 07-02 7-4-94 Prod Log I SCH ~i 0..9.-3.1A'.i"'' 7-8-94 GR/Collar '1 '.....' SCH , -- (/~ i 09-32 7-7-94 Dual Burst TDT-P I SCH ~ 15-01 7-2-94 Prod Prof 1 SCH ,,5'O 16-02 '"7-5-94 "' Inj Prof 1 ' sCH ' ~ '¥6-~'0 '.".' 7-6-94 ' InjProf ' ' I "scH _ 16-24 7-3-94 Perf Record 1 SCH - c~c_,i 17-07 7-5-94 Leak Det ' I .... SCH *The correct APl number for 04-07 ST1 is 50-029-20189-00. Number of Records: 19 / Kal'la Zuspan Distribution: Central Files Phillips ANO-8 Geology BPX Exxon State of Alaska Mobil Pleas y signing and returnin,g~/~;~y ~'~t~ns~~ ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS 70_.~_~1-4 12-17-92 Prod Profile Run 1, 11 12-18-92 InJ Profile Run 1, _~~_~f3-9~.7 ~- 12-28-92 Prod Profile Run 1, 5" -~~ _12-16 12-26-92 Leak Detect Run 1, ~'&~' ~~~.2~2~ 12-2292 InJ Profile Run 1, 1-4-93 Leak Detect/Nolse/Temp Run 1, 2'&~' 11-3-92 Prod Profile Run 1, 12-18-92 Prod Profile Run 1, C~L~a. ~6-31~ 11-3-92 Pump-In Flowmeter Run 1, Pleue sign and return the attached co~y u receipt of data. RECEIVED. BY_~~ Have A Nice Day! ~/.,~,') Sonya W. llnce AP P R O VE D_ _ ~/~,~ __ ATO-1529 Trans# 93040 Camco Camco Camco Camco Camco Camco Camco Camco C~tmco C,~_mco # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILIAPS PB WELL FILES R&D # BPX # STATE OF ALAS~. TEXACO STATE OF ALASKA ALASKA ~ '~AND GAS CONSERVATION CC REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1420' FNL, 1034' FWL, Sec. 24, T10N, R15E, UM At top of productive interval 1064' FSL, 1068' FEL, Sec. 13, T10N, R15E, UM At effective depth 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 72 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 16-2~t 9. Permit number/approval number 80-150/9-1089 10. APl number At total depth ~ ~''{' ~ 0 '~0~~ 11. Field/Pool50- 029-20544 1202' FSL, 822' FEL, Sec. 13, T10N, R15E, UM .. _,.,,..,,,~ Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10795 feet Plugs(measured) 10404' MD; 9060' TVD true vertical 9405 feet feet Effective depth: measured 10404 feet true vertical 9060 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 100' 20" 348 sx AS II 100' 100' Sudace 2615' 13-3/8" 3000 sx Fondu & 450 sx PF 2687' 2687' Production 10015' 9-5/8" 500 sx Cl 'G' 10087' 8783' Liner 1027' 7" 400 sx Cl 'G' 10790' 9400' Perforation depth: measured 10200-10250' true vertical 8880-8924' Tubing (size, grade, and measured depth) 5-1/2", 17#, PCT @ 9756' MD; 4-1/2", 12.6~, L-80, PCT tail @ 9819' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9745' MD; 5-1/2", Otis RQY $SSV @ 2266' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Avera(3e Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure .... 13796 -- 6755 Tubing Pressure 578 1359 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas~ Suspended ~ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 705 REK c: D. Warner, ATO-1479 SW JWP SUBMIT IN DUPLICATE ~- DS 16-02i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE : INJECTION PROFILE MODIFICATION 12/31/89: A CTU Cement Squeeze for Injection Profile Modification was performed as follows: MIRU equipment & PT equipment to 4500 psi. RIH w/CT to tag bottom, then packed wellbore w/15 bbls of 16.7 lb/gal mud, followed by 688 bbls of seawater. Pumped 44 bbls of sand laden cement slurry, squeezing perforations at: 10200 - 10250' MD (Z4) 10294 - 10334' MD (Z4/3) Ref. Log: BHCS 1/26/81. Placed 14 bbls of cement behind pipe at a maximum squeeze pressure of 2000 psi. Contaminated cement with contaminant. POOH. Rigged down. 1/1/90: RIH &jetted contaminated cement from wellbore. RD. 1/27/90: Reperforated: 10200 - 10250' MD (Z4) Ref. Log: BHCS 1/26/81. 3/6/90: RIH w/underreamer & underreamed fill down to 10404' MD. POOH. Returned well to seawater injection and obtained a valid injection test,. RECEIVED MAY 0 t99t Alaska 0il & Gas Cons. C0mm'tssiO~ Anchorage RD. P,.O, BOX t,3()S6(') A N C H C? R A G F ~ A L. A ~' K A 995 t 0 DATF ' R E F F R E N C E ~ 4-4-9t · ARCO CASED HOLE I::INAL,'~,' ": ..... t 9 'S.-.'..'~ .S..-4 'S .... t(') 4- 26 6....2i 7 .... ~6 ; .... .:':, 4 t ~~--9 t t--28 t ".~' -"~ Fj · .o.' . t S-.-2SA t '.:3 .... Ii t62 2-" i i - ';,' t F' F. 0 D U C ] I 0 N F:' I::,' C) F I i... E 1:;: U N S.-. 'i 6- 9 t L. IE A K D I'Z"I' E C T I 0 N I';: U N t , t ..... i f.'.~---'.'? t ;~'F'I NNEF;:/TEiql::' RUN t , S - t 7- 9 t I N J E C"I' I 0 N I;: t.J N t , 3 - t 7 --- 9 t .T. N J E C T I 0 N F;..' LIN i , i -!5- 9 t P I T ;~ F:.'. I...! N t .. S-'-6'"-9 i F' I T~' RUN "'~ ...'. S .... i4-9t F'IT;.~;' RUN t , S .... i 5 -9 t I N,.J E C"I" I C) N.,."" T E M F' F:..' LJ N i , t .... '?""9t F'IT$ RUN 'i, i .... ~ 2- 9' t F:' R 0 D U C'. "[' I ('3 N F:' R 0 F: I L. E F;.: L.I N t , 'S - t 6 - 9 t I N ,J F' tS 'l" I 0 N R U N 3 .... t7""9t INdECTION RUN t S-t 6'"9t INdECTION RUN 2-'t 3-9t F'ERF BF;~EE~K""DC)WN RUN t , ,... _ '"., ,...~. ')-2S-9 t ,S'F' INNER/ I N,JE'.L,T i ON RUN t ,: S'"8-9t F' I T,S' RUN 5" 5" 5" 5:" 5" 5" 5' 5:" '3" 5" .5 ' F'L IF.A SE S I C- N R IE C E I V E: D B Y HAVE A NICE AND RETURN 'I'HE ATTACHED COPY AS RF:'CEIF'T OF' DATA., .... ..... ...... ',"i ;-' i_ iTM' D~Y] ,.~. .... DISTRIBUTION · ......... ~~ ........ j ......... ,, ~(- 'T'HE CORRECT ~F'[~ FOR'-4'6~2. ]~ 50-029-20544. . 1"1 !:;,' CAMCO F'I I:;.'. C A M C 0 C A i'q C 0 H R ;~ t I': ':' t"J ;'~.. C A H C 0 C A H C 0 H F;..' g' CAHCO CAHCO C A M C 0 I"t R ,? H I:: ;~,'. I"iR$' ARCO ALASKA: INC~, P.O~ BOX i (')(')36(~) ANCHORAGE: ALASKA DATE · 2-i -98, REF!--F,'ENCE' ARCO CASED HOLE FINALS 5-":.2¢¢' t - 2'~- 9':') COLLAR/F'EF;:.F 4-i ~'...- 4-28 I -6-9':'} 'f' E i'iP 6 '- 2 i - 2 F:, - 9 ,.'-) C. 0 L L A R -.. t -.0,..')-or:;,_.., ,- .., ;'ERTi'LO~_ 7-8 ' -,~ ~.~.-':?,":~pR~'-.~;:,l ~:."'r'rOk~ REF':ORD 9- ~ o, _ 1 i 'i - i 7 - 'iF' 0 V I.::.'. R T I L 0 G "'7" ",, ii-6 i0-'7-89 PERF RECORD i 2-i 8 t '::.;,--'7-89 COt_LAR TO SET AVA F'ATCH, i ~;-26 t -t ¢.-e¢:', PZTS'!SF:'INNIEF;: t .3-S2 ! -.-7-9¢ CCL t 4-':3i t-i 4'-9¢ F'ERF REC. ORD i 6-2 ! -27'-9¢ C. OI_LAR/PERF" RUN '~, , _.-="" RUN i; ...=:" i:;:UNi, .,~;" F;.'.LJN i , ?::" RUN i ,, 5-" F;-.' U N. i , ..,-':::" RI ihii c..-. F;..'t..ti'~.'"";' i &2, i;:UN ~, "~" F;.:tJ. N i , ..,'~" RUN t, .5" RUN i, .,~'" RUN i, 5" PLEASE SIGN AND RF'TURN THE ATTAE:HED COPY AS' F,,'ECEIF'T 01::' DATA, RIF. CEI VED BY HAVE A NICE DAY! SALLY i-tOF'FECKER ATO- ! 529 FEB - 9 1990 Oil & Gas Gons. Go fC s'tq D'r ~'~'C'IBUTION~.~ ,,-, CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL A P F'ROVii:.:D I'RAN~':~ F'H' i - I,_LIF ,., PB WELL FILES R'& D BPX STATE OF ALA,?I<A TEXACO A 'i' L A HRS HRS A T i.. A ,':-;:. A 'F L A £ $ C H A f'L..AS A'i"LA ~: i-.iL S' HR;;' SCH A Fi_A£' :ARc~ Alaska, Inc. Prudhoe Bay ,.... ineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager December 19, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 16-2, Permit No. 80-150 Dear Mr. Chatterton' Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/REK/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 16-2)W1-3 RE¢£1V .D Alaska Oil & Gas Cons. C0mm~ss~ei~:' ;Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA AND GAS CONSERVATION C( vllSSION [, APPLICA ,'ION FOR SUNDRY APPROVA 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate _ _. Change approved program Pulltubing Variance Perforate X Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X_, Exploratory ~ Stratigraphic Service 6. Datum of elevation(DF or KB) 72 RKB 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 1420' FNL, 1034' FWL, Sec. 24, T10N, R15E, UM At top of productive interval 1064' FSL, 1068' FEL, Sec. 13, T10N, R15E, UM At effective depth At total depth 1202' FSL, 822' FEL, Sec. 13, T10N, R15E, UM 8. Well number 16-2 9. Permit number 80-150 10. APl number 50 - 029-20544 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10795 feet Plugs(measured) 9405 feet Effective depth: measured true vertical Casing Length Conductor 100' Sudace 2615' Production 10015' Liner 1027' Perforation depth: 10748 feet 9363 feet Junk(measured) Size Cemented 20" 348 SX ASII 13-3/8" 3000 sx Fondu & 450 sx PF 9-5/8" 500 sx CI 'G' 7" 400 sx CI 'G' measured 10200-10250'; 10294-10334' true vertical 8880-8924'; 8963-8998' Measured depth 100' 2687' 10087' RECEr rcD True vertical depth 100' 2687' 8783' 9400' DEC 11989 Oil & Gas Cons. 60~. ,_t~[s$~¢J Ancfiorage Tubing (size, grade, and measured depth) 5-1/2", 17#, PCT @ 9756' MD; 4-1/2", 12.6#, L-80, PCT tail @ 9819' MD Packers and SSSV (type and measured depth) Baker SAR packer @ 9745' MD; 5-1/2", Otis RQY SSSV @ 2266' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation December 1989 16. If proposal was verbally approved Oil x Name of apl)rover Date approved Service 17. I hereby,~ertify that t~ foregoing is true and correct to the best of my knowledge. Signed ~¢;~ ~----~~~ Title Operations Engineering Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- -~4 Date JApproval No. 15. Status of well classification as: Gas Suspended Approved by order of the Commissioner gRIGINAL SIGNED BY LONNIE C. SMITH Commissioner Form 10-403 Rev 06/15/88 240 R. E. Krause SUBMIT IN TRIPLIC ,TE Well 16-02i Coiled Tubing Unit Cement Squeeze Project AFE #APl131 Subcomponent AFE #KS1231 Preliminary Procedure Objective: Perform a CTU cement squeeze to shut off a channel to a Zone 3 injection thief. 1. Perform a full strength mud acid perforation wash. Perform a fill cleanout if necessary. 2. RIH with CT. Pack the well with filtered seawater. 3. Pump 98 bbls of cement followed by 2 bbls of fresh water. Squeeze off the following perforations: Zone 4 4/3 Present Interval Shot Density 10200-10250 8 SPF 10294-10334 8 SPF 4. Pump 200 bbls of contaminant following the fresh water and dilute the cement in the wellbore. 5. Jet or reverse out the contaminated cement 24 hours later. 6. Reperforate the following interval two weeks later: Zone Present Interval Shot Density 4 '10200-10250 1/2 SPF 7. Put the well back on injection. *Additional interval (10294-10334) to be added later upon evaluation of post-squeeze injection profile. Other well information: Current status: On MI injection--23.8 MMSCFPD at 2591 psig ITP. Expected static bottomhole pressure: 3850 psi at 8800' SS Expected fluid in wellbore at reperforation: seawater. 5 4 2 CO~LE*D TUB]~NO UNIT BOP EOu I PIENT 1. ~N)00 PSi ?" WELLHEAD CONNECTOR £LAI~G[ 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" Sl-I~ RAMS 5. 5000 PSI 4 1/6" BLIND RAIDS 6. 5000 PSI 4 1/16" STUFFING BOX 2 HIREL]NE BOP EOUIPHENT 1. 5000 PSI ?" WELLHEAD CONNECIOR FLANGE 2. 5000 PSI WIRELINE R&US (VARIABLE SIZE) ,3.5000 PSI 4 1/6" LUBRICA'I'OR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr ARCf'J ALASKA, !NC.. ) ANCHORAGE, ALASKA 995t0 DATE: 2-t~-RR REFERENCE:' ARCO CASED HOLE FTNAI. pR,PRFI...E/FM/TP/FD/W FiOWMETER PRD,PRFLE/FM/TP/FD/W 5" PRD.,PRFLF/HPFM/TFMP/DFN pRD,PRFL. E/HPFH/TEHP/DEN/WH/IT P~T~/TEMP PITE/CR/TEMP PIT2 PIT$/TEMP P~T$ FI_OWMETER PITE/TEMP pRD~PRFLE/HPFM/WHL~oit&G~Co.ns. Com~RIJN ~, 5" F, RD,PRFL. E/HPFM/W~[~?CRA.qchomGe RUN RI.IN RIIN RI.IN RI IN RIJN RIIN RI.IN RUN ~ ~ .5 · RUN t ~ 5' RUN t / 5' RI,.INt , 5; · RLIN t , 5" RUN ~ , 5' RUN t, ~' RUN ~, 5' RUN I ~ ~" GAMMA RAY PR~,PRFL. E/H. PFM PRD,PRFLE/$PIN/TEMP/WHUT IN,J,PRFLE/FM/TP INJ,PRFLE/HPFM/TEMP PIT$/TEMP PRODUCTION PROFILE PRD.PRFLE/HPFH/GR/~HUT INJ,PRFLE/HPFM nAMCO n~Mnn CAHCn CAMCn CAMC~ ~AH~O CAH~O CAMCO CAMCO CAM~O CAMCO CAH~D CAMCO CAMCO CAMCO C~H~D CAMCO CAMCO ~--~t 7 I .~ L,,Y-25-88 INJ,PRFLE/HPFM RI,JN i , 5 · CAMCO PLEASE SIGN AN~ RETURN' THE ATTACHET~ COPY A,.~ RECE!PT~A.. ' ~. RECEI VE.~ BY ....... PEGGY BENNET ,.;:~:~u, "- ' CENTRAL F[LE~ CHEVRON f EXTENSION EXPLORATION ~ SAF'C ~ ~. f EXXON f ~TATE OF ANCHORAGE, ALASKA 995 t 0 DATE: 2-t6-88 REFERENCE: ARCO CASED HOLE FINAl.. ~ -4 t -22-88 ~-t 6 t-2t-88 ~-4 9 4-20-88 4 -23 ~ -2(~-88 t -23 ~ -24-B8 4-~ 2-4-88 4-~ 8 2-3-88 ~-22 ~ -29-88 7-~ 3 2-~-88 9-34 ~ -23-88 ~ t-t 8 t-3e-88 ~3-~ ~-24-88 ~3-5 ~-23-88 ~3-28 ~ -22-88 ~4-22 ~-27-BB ~ 6-~ 9 2-t-B8 ~ 6-t 9 ~ -28-88 ~ 6-2e ~ -29-88 ~ T,2 ~-3t-88 ~ ?-8 ~ -25-B8 ~ 7-~ ~ t-25-88 PR,PRFLE/FM/TP/FD/W RLIN FL. OWMETER RIIN PRD.PRFLE/FM/TP/FD/W RUN PRD.,PRFL. E/HPFM/TEMP/DEN RI. IN PRD,PRFI..E/HPFM/TEMP/DEN/WHI.IT RUN PITE/TEMP RI. IN PITE/GR/TEMP RI.IN PITS RLIN PITE/TEMP RUN PIT£ RLIN FLOWMETER RI.IN PIT$/TEMP RLIN PRD,PRFLE/HPFM/WHLIT RUN PRD,PRFL. E/HPFM/WHUT/~R RUN GAMMA RAY RUN PR~PRFLE/HPFM RUN PRD,PRFLE/$PIN/TEMP/WHUT RUN IN,J,PRFLE/FM/TP RUN INJ,PRFLE/HPFM/TEMP RLIN PITE/TEMP RUN PRODUCTION PROFILE RUN PRD,PRFL. E/$PIN/TEMP/GR/WHUT RUN PRD,PRFLE/HPFM/GR/WHUT RUN ~NJ~PRFL. E/HPFM RUN INJ,PRFLE/HPFM RUN PLEASE ,,~;.'[GN AN]) RETI.II;~ THF_~TTACHED COPY A,.~ R~I:'T OF ])ATA HAVE A NI CE [. ~ Alaska Oil I ~_a_s~o_m~. Commisslo[1 PEGGY BENNE'T~li,,,,,=~~ ...... ADchorag8 ATO-t 529 APPROVED ...... DI£TRIBUTION '" CENTRAl_ FILE~ '" PHIl_LIPS' · ,,-'"' CHEVRON PB WELL D & M R & D ., EXTEN2ION EXPL. ORATION Q SAPC ~- EXXON ~ STATE OF AL.A£KA MARATHON ~ TEXACO ~L ~ MOBIL CAMCO CAM~O CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ~AMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAM~O CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ARCO P, O. BOX ANCHORAGE, AL. ASKA 995 DATE: 2-~ 6-88 REFERENCE: ARCO CASED HOLE FINAl.. t -4 t -22-88 'i-~ 3 t-22-RR t-i6 ~-2~-88 ~-~ 9 t-20-88 t -23 t -20-88 ~ -2~ ~ -24-88 4-~ 2-4-88 4-~8 2-~-88 4-22 ~ -29-88 ?- ~ ~ 2-~-8B g-~4 ~ -25-88 ~ ~-~ 8 ~-~-88 ~ ~-~ ~ -24-88 ~ 3-5 ~ -23-8R ~3-t7 t-23-88 ~ 4-22 t-27-~8 ~ -25-88 ~ 6-5 ~ -28-88 ~ 7-2 ~-3~-88 PLEA£E SI RECEIVED HAVE ANI PR,PRFI...E/FM/TP/FD/W F[.OWMETER PRD,PRFLE/FM/TP/FD/W PRD.,PRFLF/HPFM/TEMP/DFN PRD,PRFLE/HPFM/TEMP/DEN/WHI.IT PITE/TEMP PTT~/GR/TEMP PITE PIT~/TEMP P~T£ FI_OWMETER PIT~/TEMP PRD.PRFLE/HPFM/WHI.IT PRD.PRFL.E/HPFM/WHIlT/~R GAMMA RAY PRD.PRFL. E/HPFM PRD.PRFLE/$P[N/TEMP/~HI.IT IN,.J~PRFLE/FM/TP INJ,PRFI..E/HPFM/TEMP P~T£/TEMP PRODUCTION PROFILE PRD.PRFLE/$PIN/TEMP/GR/WHUT PRD.PRFLE/HPFM/GR/WHUT INJ~PRFLE/HPFM INJ,PRFLE/HPFM RI.IN RIIN RI.IN RI. IN RUN RI. IN RI.IN RLIN RI.IN RIlN RI.IN RlIN R.I.IN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RECEIPT OF DATA CAMCO ~AMCO CAMCO CAMCn CAMCO CAMCO CAMCO CAMCD CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO PEGGY BENNETT AT0-i529 TRAN~ ~88iG5 APPROVED DTSTRIBL.ITION '=- CENTRAl_ FILES · ", CHEVRON D& M .~ EXTENSION EXPLORATION ,~ EXXON MARATHON ~ MOBIl_ PHIl_LIPS PB WELL FTI E.~ R & D SAPC STATE OF ALASKA TEXACO ARCO ALASKAe IN£o P.O.,. eux loo]eo~ .., ANCHORAGE' ALASKA' 995]-0 OR TE: Al~Gl~'~~'~"].i~:i?," ' REFEgENCE=~?~7~RCO'CAS:EO HOLE FZ AL ~,..?. 7~',~v:-~., ?-? ..-:- ~:: ~-~7 7-2~;'8Y ~' "FLoP'~RO~. LOG ~-Z4 T-g~~ ~7 FLOW.! .... PLEASE 'Si'~,~'~qD'R! RUN Lt. 5" FJ-SCH RUq It 5" ATLAS RUN It 5" FJ-SCH Alaska 011 & Gas Cons. Commission Anchorage -. ' ..... RECEIVED SY HAVE A NICE ROSANNE P AT0-152 0 ISTR! bUT'[ ON TRANS ¢;~ _~ APPROVED._.__ CENTRAL FII_ES ,,- CHEVRON EXTENSION ~XPLORATION ~ X X 0 N ~AEATHO~ PHILLI PS . PB WELL FILES R & D STATE :':'UF ..ALASKA .... TEXACO .. ARCC) AI.a.s'ka, Inc. F",. 0. Bo × i (.)¢;,~6r.~ 995 ~ () I) ATE' December S i, i986 K E:. F E:. !',. E N C E :' A R C 0 C a '.; e d I.'1 o I. e F' i n a L t -' 8 t 2 -- t 2- 86 I n .j e c t i o n F' r o f i I. e I::.: u n t,5:" S -. t ? t 2--- t ¢,~-- 86 I n .j e c: i' i o n F' r o f i I. e R u n ~ , 5" "~. 'l :' t ''~-. 5: .,. tS-86 In.jec'l:ion F'rofi I.e Run t, 4 .... 2~ t2--4-86 FLopetrol. F:'rod, I_oggin~ Run 9-4 12-1S..-.86 Temp/Spinner(Leak Detection) Run 9-.t6 t2-tt-68 In.jection F'rofi I.e Run t, 5" tS-t9 t2-t9-..86 FI. ope~roL F'rod. L. ogging Run 16'2 t2-t4--86 'reml~/~pinner(Leal~ Detection) Run CafliCO C; a m c o Can~co F L(:)petro Camco C a m c o F [ o p e C a r~ c, o fRANS ~:86859 DISTRIBUI'ION Centra L Fi Les Chevron D & M Extens ion Exp Lorat i on Ex XOl'l Marathon Mob i [ Phi LLips F'B WeLL F'i Les R & D $ohio State of ALaska Texaco ARCO ALaskm, Inc. P,O. Box iOOS60 Anchor@ge, ALaska 995i0 DATE' December I t, 1986 · F,'EFERENC E' ARCO C.a.sed HoLe F'inaL 'T'_mp/~pin/WaterhoLd Up Run t, 5" Spin/Temp Run t, 5" Temp/FLowmeter ,S'u.r',-/ey Ru.n t , 5:" Temp.,. Log Run I, 5" 'f'emt.':, .,. Survey Run . i , "2" Inj. F'rofi Le/]','emp.. .?urvey Run t, CCL. Tie in Lng.. Run i , .;'=' TemF..'. Log Run t, .5' F",.!mp-I1] Temp.. ."¢Ul-vey Ru.n I., "'...=:" Product ion F'rofi [e Run i, F'Leas._--. s i~n o¢ da*a,,. ~ Cer.,tra[ Fi Les -.- ;_.r: =_ vr ,-,'n ~-B W=,.L Fi Le~ .. r~, & r'., ..Ii. ~ 4. -,- ~_~:=.'o'? ,~ .-.±a±e o1:' ALa.~ka '" -- ' ' ARCO Ala~l<a, Inc P.` O. Box t 8(.):36(.) Anchorage, Alaska 9951(.) DAI'E' ,S ep i: emb er .,,.6, t 986 RE. FI~=RE:NCE]: ARCO Ca.s"ed Hole Fina I. ~ S-iO 9-.t 8-86 Step Rate Inj, Profi Le/GR ~4--.t 5)-.2t-86 Pr'oduc't ion Pr'ofi te ~-4-..9 9--i 0-86 Temp, Log/Inj, F'rofi te ~4-.9 9-t 5-86 In], F'r'ofi le ~4-..~e 9-"~-'86 Temp, Log ~4-.~ 9-'~5-86 In j, Profi[e ~9-.~2 9-.~/~2....86 ~pinner/Inj, Profi Le ~ ~ 2 9-..~ ~/~,,..-.86 l'emp. Log ~9-..~ 2 9-.~ 5-86 Temp, Log ~~-~7 9.-~-86 Inj, Profi ~e ~9-..~ 7 9.--~ ~-86 Temp, Log ~9-2e 9-~2-86 Inj, Profi Le ~9-~5 9-28-86 Inj F'rofi Le ~t~-2 9-.~4-86 Spinner/Temp, Survey -._ ~--86 Spinner Log ~~-.-~ c2--~3/~4--.86 Ypinner/F'roclucl'ion F'rofi Le 9-.~5-86 Temp, Log Leak De~ection Run t, 5" Run t, .5' R un t, 5" Rurl t, 5' · Run t, 5" Run t, 5" Run ~, 5" Run t , ~" Run t, Run i, Run t, 5' Run i , S' R u n Run i , 5" Run i, S" C a m c: o C a m c o Ca mc: o C~ mc o C a m c: o C a m c c) ' £; a m cz (:) Camco C a m c: o Ca I'flc o C a I'll C; 0 Camco C a m c (:) Camco C a J~l c: o Ca mc o F,./~. , /~ ~a,ska Oil & Gas R o ~ a n ne/, ree. K / Anchorage ATO-t 5~ I'RANS ~86597 DISTRIBUTION Central Fi Les 'It Chevron ~- Extension Exploration' 'II' Exxon Marathon Hob i l . Phi ttips F'B Well Fi Les R & D Soh i o State of Alaska Texaco Max. Injection Rate During Well Last 3 Months ~ (BWPD) 3-11 A/~ ? 8000 3-12 M~d-P 330O0 3-17 pl,~i,rc 19000 9-12 ?~ 16000 INJECTION WELLS WITH ANNULAR COMMUNICATION EOA - PRUDHOE BAY FIELD Surface Pressure at Maximum Rate (psig) Tbg 9-5/8" Cs9 13-3/8" Csg 1200 1200 0 1100 1100 400 800 800 100 900 900 0 9-14 mef P 36000 1300 1300 200 9-17 ~P 27000 1100 1100 0 9-19 ~ofP 28000 Probability of Passing State Test ~/~Low ~x~4edium 1200 1200 0 i~Medium 16-2 p/'o.~ 7000 800 1200 0 i~ione (m~Low 16-11 ?1~ 7000 High (~Medium 1100 1400 200. ~Low Comments 9-5/8" pressure responds immediately to changes in tubing pressures Bled 9-5/8" pressure from 875 to 455 pstg in 3 minutes, built up 80 psi in 1 hour, built back up to 860 psi in 20 hours. Bled 3 Bbls otl and gas from 9-5/8"in 10 minutes, pressure decreased from 1050' ,, to 200 psi, built up 120 psi in 1 hour built back to 1000 psi in 18 hours. Bled 9-5/8" pressure from 795 to 350 psi, built up 200 psi in 1 hour, built back to .800 psi in 5-1/2 hours. Parted tubing at 13' ,,-'f"~ ~''~ '"'~"~'~ (/ Bled 9-5/8" pressure from 625 to 250 pstg, butlt back to 625 psi in I hour. Bled 10 gals of H~O from 9-5/8", pressure decreaseU from 220 to 0 pstg, built up 80 psig in 4 hours. Bled 40 gals diesel from 9-5/8", pres- sure decreased from 880 to 500 pstg, ~'~ built up 50 psi in 1 hour, butlt back to 850 pstg in 10 hours· Has gas ~ lift mandrelS. 9-5/8" pressure responds immediately to changes in tubing pressure. Has gas lift mandrels. R,1N4/16 W(LL: SURFACE LOCAT~OH: -ALL O(~S ~[ R~ HO 2266* OCt S RQY 2687* ~3 3/8', TVO 2886' 2886' 5109' 4823* 6787* 6127' 7990' 7047' 8606' 7534* 8680' 75gS* 9103' 7950* 9177' 8012' 9445' 8238' gB20' 8301° ~594' 8383' 9664* 8422* 16-2 1420' FNL, 1034' 1202' FSL, 822'FEL 72' 10198' RK~ TO HOLE MGLE THROUGH S~J)L£ROCHZT: C~I~PLE1'ZOg RUN: ...... 1/31'/81 AP! f~S0-029-20544 5~". 17~, L-8O Plastic CA&ted 5~" x 9 518' Annulus Fluid: S$SV Ntpple [0 4.562' 72l, L-80 u/3450 sx' v SPUD ~TE: 1/10/81 OCT HAN;~ 28.5' 290 g.6 ~C1 A Diesel ST_.AA P~NOREL VALVE-LATCH 1 Otis * Dumuy- RK 2 Otts' C~lCO CEV°* 3 Otts* Dumy- RK 4 Otis * DUBlin- RK S Otis * Dummy. RK 6 Otts* ~my- RK 7 Otis · Oulm~o RK 8 Otis ' :umw- RK 9 Otis *' ~Zml~o RK 10 Otts' Dulillyo RK 11 0its * Oumey. RK 12 0tis * Eq 0umy*R£D * 21145605 "*.S" bore - w/C-Lock PORT'SZ. PtroO6OOF 9730' Baker PBR Assemb!¥ 9745' Baker SM Packer 9763' Top of Liner 9817' Otis X-N Nipple ID 3.813' 9818' Baker Shear Out Sub- g819' Bottom of 4¥', 12.6P, N-80 TailDipe 10087' 9 5/8", 47#. L-80/Soo-BS w/500 sx DATUN: 10191' ~D · 8872' TVD · 8800' SS aEF ZON~ ~. ~pr COMMENTS 10200'-10250' 8HC$ 1/2~'7~'1T:--~-r T Perf'~--TTT~I 10294'-10334' " " 4,~ ~0' 8 " " 107~8' PBTD I0790' 7", 29#, L-80 w/40C sx 10795' TO 3/84 RECEIVED AUG- 5 1986 INJECTION WELLS~WITH ANNULAR COMMUNICATION EOA - PRUDHOE BAY FIELD Naska 011 & Sas Cons. Commission Anchorage Max. Injection Rate During Well Last 3 Months (BWPD) J3-11 8000 Surface Pressure at Maximum Rate (psig) Tbg 9-5/8" Cs9 13-3/8" Cs~) 1200 1200 0 Probabi 1 i ty of Passing State Test Low Comments 9-5/8" pressure responds immediately to changes in tubing pressures 3-12 33000 1100 1100 400 Medium Bled 9-5/8" pressure from 875 to 455 psig in 3 minutes', built up 80 psi in I hour, built back up to 860 psi in 20 hours. 3-17 19000 800 800 100 Medium Bled 3 Bbls oil and gas from 9-5/8" in 10 minutes, pressure decreased from 1050 to 200 psi, built up 120 psi in I hour built back to 1000 psi in 18 hours. 9-12 16000 ~9-14 9-17 9-19 16-2 ~16-11 36000 27000 28000 7000 900 900 0 Low 1300 1300 200 .. 1100 1100 0 1200 1200 0 · 800 1200 0 7000 1100 1400 , . 200 -: _ · . None Low High Medium Low Bled 9-5/8" pressure from 795 to 350 psi, built up 200 psi in I hour, built back to 800 psi in 5-1/2 hours. Parted tubing at 13'. Bled 9-5/8" pressure from 625 to 250 psig, built back to 625 psi in I hour. Bled 10 gals of H~O from 9-5/8" pressure decrease~! from 220 to ~ psig, built up 80 psig in 4 hours. . Bled 40 gals diesel from 9-5/8", pres- '~,, sure decreased from 880 to 500 psig, built up 50 psi in I hour, built back to 850 psig in 10 hours. Has gas ~ \ 1 ift mandrel s. -- ......... - 9-5/8" pressure responds immediately to changes in tubing pressure. Has gas lift mandrels. ARCO ALaska, Inc,. .F',O, BOx ~0036e An.c h o'r a g e, .. A L a .~ k a' 995i0 DATE: March 27 t,8o REFERENCE' ARCO C.a..~ed Hole Final. DS i 4-J J (.~-24--85 C'NL DS i4-J t0-24-85 Ep i Log DS i 4- r 2-S-85 CE, DS i4-i0 i2 o 85 .-'~..6- D ~ ff Temp DS i4--i5 i° ,~-- ,~ ~.-~m--8_ D iff Temp DS t 4-24 i i-9--85 Ep i log DS ~ ~~ it-9--85. CNL ~,~, ~ DS i4-28 i2-'2t-85 Di'ff Temp ' DS i4-29 i"2-2~-85 D iff Temp Run t Run i Run t Run t Run i Run t Run i Run t Run i DS i 5-7 2.-20'86 ,'.<,'p inner Run DS i6-2 2--'22-86 Spinne~ .... Temp Run DS' i 6-3 3-6-86 Sp inner-l"emp Run D£' i 6--i 3 2--t 9-.86 £'p i nne.,r-GF:.'. F:un DJ.; J 6--i 5 i 2-28-85 ACBI.../VDL/,S' i g/GR F;,'un DS i6.-J6 2 .... ~9-.86 Wa+.er Injec:+.ion I:~:u)'~ D,? J 6---~ ~ J -J -86 ACBL./VI)L./.:,; i g/GR F..'un _r~:-::,. i 6-20 I .-o'-F:'".,:.. ..,,., ACBL/VDL./S;i g/GR Ru.n {{ .5:" 5" 5 ' 5" 5" 5" DA I) A Sc: h DA I)A I) A DA I) A C 8 rn c o C a m c: o C a m c o [;amco I) A [)t i~ I) A DA PI. ease '=:ign and ret'urr~ the at'fached c:opy az receipt' of Received By .... R.. { D HAVE A NICE DAY! I r ma Ca r L in ~ AJaslal 011 & Gas Cons, Commissloll ATO- t 42~F Anchorage I'RAN$ ~:862JS d a i' a, DISTRIBUTION Central Fi Les Ch err on D& M Ex$.ension Exploration $ Ex xon Marathon ~ Mob i I, Phi LLips F'B WeLL Fi Les R & D $ohio S'~ale of Al,aska Texaco ARCO Alaska, Inc. Prudhoe Bay E ~heering\ Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil 'and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 DS 3-7 DS 3-10 DS 3-18 DS 4-6 DS 4-8 DS 4-11 DS 4-14 DS 4-15 DS 9-8 DS 9-10 DS 9-12 DS 9-14 DS 9-15 DS 9-16 Permit # 76-60 Permit # 76-53 Permit # 79-21 Permit # 79-103 Permit # 76-42 Permit # 76-10 Permit # 78-6 Permit # 78-36 Permit # 78-37 Permit # 76-70 Permit # 76-82 Permit # 77-7 Permit # 77-25 Permit # 77-36 Permit # 77-37 DS 9-18 DS 9-17 DS 9-19 DS 9-20 DS 11-2 DS 16-1 DS 16-2 DS 16-3 DS 16-5 Permit # 77-39 Permit # 77-38 Permit # 77-40 Permit # 77-41 Permit # 81-128 Permit # 80-136 Permit # 80-150 Permit # 76-83 Permit # 81-37 DS 16-10 Permit # 80-04 DS 16-11 ~Permtt # 80-118 DS 16-16 Permit # 80-127 DS 17-6 Permit # 80-132 DS 17-8 Permit #'81-74 DS 17-10 Permit # 81-97 Dear Mr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/mjb R E EI V E O At tachment s JAN 2 5 1g(15 cc: Sohio Alaska Petroleum Company Alaska Oil & Gas Cons. Commlsslon /~ch0raoe ARCO Alaska, Inc. I. a Subgldlary of AtlantlcRIchfleldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLI[] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-150 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20544 4. Location of Well 1420' FNL, 1034' FWL, Sec. 24, T10N, R15E, UM (Surf) 1064' FSI,, 1068' FEL, Sec. 13, T10N, R15E, [~ (Top Prod) 1202' FSL, 822' FEL, Sec. 13 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB × T10N, R15E, UM (TD) 6. Lease Designation and Serial No. ADL 28332 12. 9. Unit or Lease Name Prudhoe Bav Unit 10. Well Number DS 16-2 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] StimUlate [] Abandon [] Stimulation [] Abandonment [] . Repair Well [] Change Plans [] Repairs Made [] Other ~] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 16-2 to water injection service. The well is part of the Flow Station 2 waterflood project. The well began receiving water on June 24, 1984. REC ' VED JAN 2 ,1985 Alaska 0il & Gas Cons. C0mmJssJ0n Anc:'~orag~ 14. I hereby c,p~tify that the foregoing is true and correct to the best of my knowledge. Signedf/~ .~~~~ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate F;.: Iii: F:' E F;.: E N C Iii: ' A R C O F:"r' ;~.:.:, :ii: :i; u. 'r' e D a 4' a S 4' a i: i ,.':: S' u. '.," ,.:; e '.i S t' a i' i ,.':: S u. 'r' v e y ;:..;: -i.: a 't' i c S'. u.'r' v,:.:.:,'::; Ca mc o Ca mc o ... L.: .:':/fitC C) ,..., .:':i fli C 0 (il: a m (:: o T F;.: A N £ .. ' :1~ ,3 70 D I .? 'f' I:;:. 1[ B U 'T' 11 O N C h e v 'r' c', ',q D & M E x I::' !. o'r' a ".r i ,.'::, n S e'r v i c: ,,'-~ -~: Ii:_' × i: e',."~ :!i: i c,'n Iii: x p I. o'r' a t: i ,::.',',"., Ex x on [.'-,-et t¥ H a 'r a +. h o'n Mol.-., i I. Hobi I I!:: & P F'hi l l i p.".~ F'¥'udhoe Bay We l. I. R * '13 ~..~: ... 5.'oh i o ';~':.~'a:t'e .-~-tL..A [ a -.'~ !< a Fi Les ARCO Alaska, Inc. P.O. Box iOOS6G Anchorage, Alaska DATE: September t2, t984 REFrERENCE'": ARCO Cas'ed Hol. e Fina L.s 4-7 ~./ '?-26-84 Temperature Log 4-2~ 7-28--84 Temperature Log ~.. 6-6 / 8-4-84 CH CNL 9-~ ~.-3---26-84 Tempera~ ute L. og ~4-~9/~.8-~-84 Fi. uid Den~fi Y ~ 4-~ 6 ~ 8-J ~-84 DDT/NLL/GR ~ 4-24 ~ 5.-~ 7-84 ,S'p inner Log ~6-2" ~,.9/3~-.-84 InJection F'rofi Le Log Ran t Run t Run t Run 7 Run t Run 2 Run t Run t ii 5" 5' 5" 5' 5" 5' 5" p~e~~$e ~ign and return the attached copy as receipt Recei red HAVE A Kelly McFarland ATO- t 42~F TRANS. ~322 of da ta. DISTRIBUTION Chevron Exploration Services Extension Exploration Exxon Getty Marathon Hob i l Mobil E & F' Phi llip~ Prudhoe Bay Well R & D $oh i o Strafe of AI.a~ka Fi Lea: ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 16-1 DS 16-2 DS 16-3 DS 16-5 DS 16-10 DS 16-11 DS 16-16 Permit No. 80-136 Permit No. 80-150 Permit No. 81-11 Permit No. 81-37 Permit No. 80-04 Permit No. 80-118 Permit No. 80-127 Enclosed are the Sundry Notices for Change of Well Status for the. proposed Drill Site 16 Water Injectors. Ver~ truly yours, D. F. Scheve DFS:WT:kg Enclosures cc: SOHIO Alaska Petroleu~ Co. File P1 (DS 16-1)Wl-3 File P1 (DS 16-2)Wl-3 File Pl (DS 16-3)Wl-3 File P1 (DS 16-5)Wl-3 File P1 (DS 16-10)Wl-3 File Pl (DS 16-11)Wl-3 File P1 (DS 16-16)Wl-3 ARCO Alaska, Inc. Is a Subsidiary of Atl~,ntlcRIchfleldCompany -~ STATE OF ALASKA ALASKA ,. L AND GAS CONSERVATION CC )vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-150 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20544 OTHER [] 4. Location of Well 1420' FNL,. 1034' FWL, Sec. 24, T10N, R15E, UM (Surf) 1064' FSL, 1068' FEL, Sec. 13, T10N, R15E, UM (Top Prod) 1202' FSL, 822' FEL~ Sec. 13, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6, Lease Designation and Serial No. 72' RKB I ADL 28332 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-2 12. · 1 1. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other I~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to change Well 16-2 status from oil producer to water injector. It will be operated as part of the Prudhoe Bay Waterflood Project. Sttbseq. uent Work Reporte~l' RECEIVED JUN ! 81984 Alaska 0il & Gas Cons, Commission Anchorage 14. I herebv~ertify that,the foregoing is true and correct to the best of my knowledge. Signed ~/. ~~~~ Title Regional Eng'i Beer The space below for Commission use Date Conditions of Approval, if any: Approved by ORI~IN,kl. SIGNED BY LONNIE IL $1111Til Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev, 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ! ARCO Alaska, In( ) Prudhoe Ba~,~ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer April 3, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: ~ i6~,121 DS 16-11 Permit No. 80-150 Permit No.80-118 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File Pi(DS 16-2,11)W1-3 t ECE VED APR ~ 9 ~984 Alasl(a Oil & Gas C~ns Air;hora[l'~ Commission ARCO Alaska, Inc. is a Subsidiary of AtlanflcRIchfleldCompany STATE OF ALASKA ALASK. ~IL AND GAS CONSERVATION L'-)MMISSION ,SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-150 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20544 4. Location of Well 1420' FNL, 1034' FWL, Sec. 24, T10N, R15E, UM (Surf) 1064' FSL, 1068' FEL, Sec. 13, T10N, R15E, UM (Top Prod) 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-2 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 1202' FSL, 822' FEL, Sec. 13, T10N, R15E, UM (TD) I 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72' RKB ADL 28332 12r. Check ApPropriate Box To Indicate Nature of Notice, Report, o'r Other Data SUBSEQUENT REPORT OF' NOTICE OF INTENTION TO' . (Submit in Triplicate) ~it in Duplicate) . Perforate ~ Alter Casing [] Perforations (~ Altering Casing Stimulate [] Abandon [] Stimulation Abandonment Repair Welt [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The work stated in the Intention Sundry filed March, 1984 was never performed. Work was suspended due to water influx found in the zone to be perforated. A new Intention Sundry will be filed before the operation is resumed. APR .... 91:984 ~/,,,, · Alaska 0ii & Gas C~;r~s. Comm~szi0a 14. I hereby c.,~tify that the,~egoing is true and correct to the best of my knowledge. Signed ~~// _~F_~*//~~ Title Regional Engineer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc ~'~) . . Prudhoe Bay ,-ng~neerlng Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 1, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 16-1 i.~Ds 16-2 DS 16-5 DS 16-11 DS 16-16 DS 17-6 DS 17-8 Permit No. 80-136 Permit No. 80-150 Permit No. 81-37 Permit No. 80-118 Permit No. 80-127 Permit No. 80-132 Permit No. 81-74 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlanflcRIchfieldCompany ALASK,')O STATE OF ALASKA IL AND GAS CONSERVATION ,, ~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 80-15.0 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20544 4. Location of Well 1420' FNL, 1034' FWL, Sec. 24, T10N, R15E, UM (Surf) 1064' FSL, 1068' FEL, Sec. 13, T10N, R15E, UM (Top Prod) 1202' FSL, 822' FEL, Sec. 13, T10N, R15Er UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72' RKB ADL 28332 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 16-2 1 1. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 16-2 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. · The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10334-10364' MD 10396-10436' MD Ref: BHCS 1/26/81 RECEIVED MAR 0 fi 1984 Alask:~ Oil & Gas Cons. Commission A,~,.,~,..,?.an~ 14. I hereby.certify that the foregoing is true and correct to the best of my knowledge. Signed ........... / Title Regional Engineer The space below for Commission use Conditions of Approval, if any: BI' LONNIE IL SAtiTJi Approved by COMM ISS ION ER Approved Copy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. -\ Post Office~: 360 Anchorage, ,~l'aska 99510 Telephone 907 277 5637 February 5, 1982 Reference : ARCO Pressure Data D.S.16-2 1/15/82 Pressure Survey Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 944 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON D&M GEOLOGY STATE OF ALASKA ARCO Alaska, Inc. is a SuC~s*u~ary OI Atlant~cF~chl'ie!dCo,--npany ~;~uSl Olllce Box Anchorage. Alaska 99510 Telephone 907 ¥ 5637 February 5, 1982 Reference: ARCO CASED HOLE FINALS D.S.7-6 1/8/82 " D- S.12-4A 1/7/82 . . D.S.12-10 1/3/82 ... D.S.12-12 t/1/82 Collar Log & Perf Log ACBL/VDL/GR Collar Log & Perf Log Collar Log & Perf Log Run 5 5" Run 1 5" Run 1 2"/5" Run 1 2"/5" D.S.12-14 1/27/82 Borehole Audio Tracer Run 1 5" 1/25/82 Cont Flow Survey Run 1 5" ._ --Please sign and return the 'attached copy as receipt of data. Mary F.-Kellis North Engineerihg DISTRIBU.TION Transmitta]~ # 948 NORTH GEOLOGY R&D DRILLING PIIILLIPS SG~lO ' MAP, ATIlON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA RECEIVED Ala3k;tUi,';& L'~. ;" ·" ARCO Oil and Gasf'qrnpany North Alask, ~rict Post Office Anct~orage. A!aska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 3, 1981 Reference: ARCO Cased Hole Finals D.S.15-11 10/4/81 ~',J!~'¢~;~6=2,,,'~'~ 9/26/81 D.S.17-1 10/4/81 D.S.17-1 10/5/81 CBL Run 2 5" Composite Profile/Diff Temp Log TDT Run 1 5" EPL Run 1 5" Run 1 tl Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #706 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON .. ARCO Alaska, Inc. North Slope ~~rict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 12, 1981 Mr Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: D.S. 16-1 Permit No. 80-136 D~$. 16-2 Permit No. 80-150 D.S. 16-8 Permit No. 80-02 D.S. 16-9 Permit No. 81-19 D.S. 16-10 Permit No. 80-04 D.S. 16-11 Permit No. 80-118 D.S. 16-16 Permit No. 80-127 D.S. 17-1 Permit No. 80-55 ~D.S. 17-2 Permit No. 80-70 D.S. 17-3 Permit No. 80-77 D.S. 17-5 Permit No. 80-96 D.S. 17-6 Permit No. 80-132 Dear Mr. Hamilton: Enclosed are our Completion Reports for the above-mentioned weiIs. ~~t r u 1 y you~ _./~. A. Rochon J~R:DAIt:adri Attachments OCT 2 0 0il A Bas Cons. Cornrnis~i~ ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ALASKA, LANDGAS CONSERVATION ~ MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LoG ~ Classification of Service Well 1. Status of Well . . . , . , OIIX~ GAS [] SUSPENDED [] ABANDONED [] sERVICE I--I. , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 80-150 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20544 4. Location of well at surface 9. Unit or Lease Name 1420' FNL, 1034' FWL, Sec. 24, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1064' FSL, 1068' FEL, Sec. 13, T10N, R15E, UM P.S. 16-2 At Total Depth 11. Field and Pool 1202' FSL, 822' FEL, Sec. 13, T10N, R15E, OM Prudhoe Bay Field 5. Elevation in feet (ir~dicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool 72' RKBI Al)T, 28332 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116. No. of Completions 1-10-81 1-27-81 2-1-81 feet MSLI i - 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth'where SSSV set I 21. Thickness of Permafros:t 10795 ' MD 9405 'TVD 10748 ' MD 9363' 1'V~sx~x NO [] 2266 feet MDI 1975 ' (REF: D. S 16 22. Type Electric or Other Logs Run . DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, RFT, CBL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 3'2" 348 sx AS II to surface 13-3/8" 94# H-40 Surf 100 ' ' ~ 72f~ L-80 Surf 2,687' 17 1/2" 3000 sx Fondu & 450 sx Permafrost 9-5/8" 47# L-80 Surf 10~,087!' 12 1/4" 500 sx Class.G S00-95 7" 29# L-80 9763' 10,790' 8 1/2" 400 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD · , .., interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5 1/2" 9819' 9745' 10200-10210' M.D. 10'210~-10230' M.D. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10230~10250 ' M.D. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10294-10314' M.D. '. ...~... N/A ' 10314-10334' M.D. 8880' T.V.D.-8998''T.V.D. 27. PRODUCTION TEST Date, First Producti. on Method of Operation (Flowing, gas lift, etc.) 7-12-81 " Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 8v18-81 12.5 TEST PERIOD ~ 1098 698 536 34I 636 · FIow~ Tubi.~g . Casing Pressure CALCULATED.~ OiL:B.BL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr} Press. 91,4 N/A 24-HOUR RATE ~ 2108 1341 1029 19.6 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 0C7 2 0 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30, · FORMATION TESTS GEOLOGIC MARKERS , . NAME Include interval.tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T. Sadlerochit 10,198' 8878' B. Sadlerochit 10,673' 9297' n/a · ,~ ~.~ ~ '6' , 31. LIST OF ATTACHMENTS , · 32. ! hereby certify that the foregoing is true and correct to the best of my knowledge // . , ¢- TitleDistrict Engineer Date / ~__~"~"~"Jf'-~'~/ 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 interva! (multiple c¢~mpletion), so sta.,,te in item 16, and in item 24 show the producing intervals fq.r 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 S~pplemental records for this well should show the details of a~ny multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 District Operations Engineer August 26, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: D.S. 16-1 Permit Noo 80-136' ~?D~S. 16-2 .Permit No. 80-150 D.S. 16-3 Permit Noo 81-11 D.S. 16-4 Permit No. 81-20 DoS. 16-8 Permit No. 80-02 D.S. 16-9 Permit No. 80-91 D.S. 16-10 Permit No. 80-04 D,S. 16-11 Permit No° 80-118 D.S. 16~16' Permit No° 80-127 Dear Mr. Hamilton: Enclosed are our Sundry Notices of work completed on the above- mentioned wells. Very truly you.rs, .~- J. A. Rochon JAR: DAH: mlc Attachments ," ARCO Alaska. Inc ,s n subsid,ary o! Allanlicl-li(:hf~eldCompeqy SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of Well 1420' FNL, 1034' FWL, Sec. 24, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 72' RKB 6. Lease Designation and Serial No. ADL 28332 Check Appropriate Box To Indicate Nature of Notice, Report, or 12. NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimu late [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing 7. Permit No. 80-150 8. APl Number 50- 029-20544 9. Unit or Lease Name Prl~dhoe Bay Unit 10. Well Number D. $. 16-2 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool )ther Data SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 16-2 Began perforating operation 7/12/81. Tested tubing and annulus. Tested tree. N. U. and tested perform, ting equipment. N. U. and tested wirellne BOP and lubri- cator. Perforated 103~4-34'M.D. with 4 spf. Unloaded to tanks. Flowed to flow station. Perforated 102~L314'M.D., 10230-_5~'M.D., 102____i.Q-30'M.D., 10{00- 10'M.D. with 4 spf. Reperforated 10200-10-M.D., 10314-34'M.D., 10294-314'M.D., 10230-50'M.D., 10210-30'M.D., 10200-10'M.D. with 4 spf. Recorded BHP. Rigged down perforating equipment'~'"., Secured well 7/14/81. RECEIVED AUG 1 1981 · .Alaska Oil & Gas 0ohs, Oommission Anohorag~ 14. I hereby certify that th~s true and correct to the best of my knowledge. The sp ,~l/~e ,belOw for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Oil and Gas '~lnpany North Alaska Jistrict Post Oflice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A, Rochon District Operations Engineer Aug 11, 1981 Reference: ARCO Cased H~le Finals D.S.14-11 6/30/81 D.S.16-1 7/10/81 · ~,~~~i:?,~,~ 7/12/81 D.S.16-4 t/ 7/20/81 D.S.16,4 ~ 7/17/81 D.S.16-4 7/20/81 D.S.16-4 7/20/81 D.S.16-6 7/25/81 D.S.16-8 7/22/81 D.s.16-10 8/5/81 D.S.16-10 7/25/81 Collar Log Collar & Perf Log Collar & Perf Log Diff Temp Log Collar & Perf Log Fluid Density Log Continuous Flow Survey Collar Log Collar Log Collar & Perf Log Collar Log Run 1 5" Run 1 2"/5" Run 1 2"/5" Run 1 5" Run 1,2,3,4 '5" Run 1 5" Run I 5" Run 1 2"/5" Run 1 2"/5" Run 1 5" Run 1 2"/5" ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #503 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL SOHIO ~ MARATHON A!aska Oil & Gas CoDs. Commission CHEVRON AnchoFage ARCO Oil and Gas Company ~s a Diws~on ol AtlanlicR~chfieldCompany ARCO Oil and Gas ~.~mpany North Alask ~istrict P. ost Olfice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer July 30, 1981 Reference: ARCO Pressure Data D.S.16-!6 7/25/81' D.S.16-8 7/23/81 ~ 7/13/81 Pressure Survey-Printout Only Pressure Survey-Printout Only Pressure Survey-Printout Only ~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #471 NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Oiws~on ol AtlanticR~chlieldCompany ARCO Oil and Gas Company North Alask,' '"1~strict Post .Office [ ..,,{ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer June 26, 1981 Reference; ARCO Cased Hole Final Prints D S. 12-10 6-3-81 ACBL/VDL run 1 · D.S. 14-19 6-1-81 ACBL/VDL run 1 / 4-14/15-81 CCL run 1 2" ~/ / D.S. 16-13 6-9-81 CNL run 1 5" ~! D.S. 17-5 6-4-81 D,S. 17-7 6.7-81 CNL~ Gamma Ray Multi-Spaced Neutron run 1 ACBL/VDL Ganxna Ray run 1 5" ~/ Please sign and return the attached copy as receipt of data. Kelly McFarland No ~ Engineering Transmittal # 375 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHGN CHEVRON RECEIVED JUN 0 1981 Oil & Gas Cons. Comm~lon A~ch0rage ARCO Oil and Gas Company is a Div,sion ol AtlanticR~chfieldCompany ARCO Oil and Gas ~mpany North Alask, ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer May 18, 1981 Reference: ARCO DIRECTIONAL SURVEYS D.S.16-2 3/7/81 Gyroscopic Job No. 'A381G0266 D.S.i-3 3/13/81 Gyroscopic Job No.' A381G0280 D.S.14-18 5/4/81 Single Shot Job No. A481DO299 ., ease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #289 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG, MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON Alaska Oil & Oas Cons. Commi~ion tmohorage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office ' ~)360 Anchorage, A~aska 99510 Telephone 907 277 5637 May 13, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservati on Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 1-3 DS 16-2 Dear Sir' Enclosed please find the updated Completion Reports and Gyroscopic Surveys for DS 1-3 and DS 16-2. Also please find the Gyroscopic Survey for WS 1. Sincerely, P, A. VanDusen District Drilling Engineer PAV/KJG'sp Enclosures ARCO Ah~skm, inc. ~S ,~ ,~ubs;di~}~ of Atlantic~ichfleJ,'tCon~p;~n¥ STATE OF ALASKA ), ALASKA ,_ ~ AND GAS CONSERVATION CO,..MISSION WELL COMPLETION OR RECOMPI,. :TION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, ]:nc. 80-150 3. Address 8. APl Number P.0. Box 360, Anchorage, AK 99510 s0_029-20544 4. Location of well at surface 9. Unit or Lease Name 1420' FNL, 1034' FWL, Sec 24, TION, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1064' FSL, 1068' FEL, Sec 13, TION, RI5E, 'UM DS 16-2 At Total Depth 1 1. Field and Pool 1202' FSL, 822' FEL, Sec 13, TION, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe 0i 1 Pool 72' RKB ADL 28332 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1/10/81 1/27/81 2/1/81 --- feet MSL ., 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth whereSSSVse.i I 21. Thickness of Permafrost 10795'MD 9405'TVD 10748'MD 9363'TVD YES]a NO[:::] 2266 feetMDI 1975' (REF' DS 16-1 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, RFT, CBL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 surf 100' 32" 348 sx AS II to sur':ace 13-3/8" 72# L-80 surf 2687' 17½" 3000 sx Fondu & 450 sx Permafrost 9-5/8" 47# L-80 sUrf 10,087' 12¼". 500 sx Class G SOft-95 7,, 29# L-80 9763' 10,790' 8½" 400 sx Class G - 24. Perforations open to Production (MD+TVD of ToP and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5½" 98l 9' 9745' · 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - n/a · .. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED n/a 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) n/a Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA n/a . ~.bs~ O/t & ~as Cons. Cornr~t~sio. Arrc/~ora.~e , Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and tim~ of each phase. ,,. T Sadlerochit 10,198' 8878' B Sadlerochit 10,673' 9297' n/a · · . · ....................... 31. LIST OF ATTACHMENTS Gyroscopic Survey · 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed ,~;:~. ~~ Title Dist. Drlg. Eng. 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 !6 and 24: If this well is completed for separate production from more than one interval (multiple compi~.tion), so state in item 16.,, and in item 24 show the producing intervals for only the inr. erval 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- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. North Slop Strict Post Office .... ,:~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer May 19, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and'Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Hamilton: RE: D.S. 16 D.S. 16 D.S. 16 D.S. 16 D.'S. 16 D.S. 16 D.S. 16 D.S. 16 D.S. 16 -1 Permit No. 80-136 -2 Permit No. 80-150 -3 Permit No. 81-11 -4 Permit No. 81-20 -8 Permit No. 81-02 -9 Permit No. 81-19 -10 Permit No. 80-04 -11 Permit No. 80-118 -16 Permit No. 80-127 Enclosed are our Sundry Notices detailing the work to be done on the above-mentioned wells. Very~tru 1 y yours, ~. ^. Rochon JAR/BBB/mj s Enclosures ARCO Alaska, Inc. is a subsidiary of AtlanticRichfietdCo~'npany STATE OF ALASKA ~[. ALASK, "~IL AND GAS CONSERVATION C~ MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska 80-150 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 so-029-20544 4. Location of Well 9. Unit or Lease Name Prudhoe Bay Unit' 1420' FNL, 1034' FWL,.Sec. 24, TION, R15E, UM ElevatiOn in feet (indicate KB, DF, etc.) 72' RKB 6. Lease Designation and Serial No. ADL 28332 10. Well Number D.S. 16-2 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon r-I stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date'of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for cleanup and production. The perforated intervals will be given in a subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 'working pressure. The SSSV will be installed at the conclusion of the perforating and cleanup operation. Subsequent Wink Rcporte~ On Form No. ~ Dated ~---~/~-~/~-~ RECEIVED. MAY 2 1 1981 · aska 0il & Gas Cons Commissio, 14. I hereby c.e.r~fy that the foregoing is tr~ue and correct to the best of my knowledge. S~gne~ T~t~e District Operations Enqineer The space~(~w for Commission use Conditions of Approval, if any: Date Approved Copy Returned By Ordu, uf ' the Commission Date Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Air, CO Oil and Gas Company North A!"~'.~a District Post Ot ./8ox 360 . Anchora9e, AMska 99'510 Telephone 907 277 563.7 Jerry A. Rochon District Operaiions En§ineer March 20, 1981 Reference: ARCO Magnetic Tapes & Listings D.S.1-17 2/26/81 ~;/27/81 Tape # DDNLL 8914-9794 Tape # CNL/MS 9390-10800 D~S.17-1 3/5/81 Tape # CN 8200-9860 " " Dresser Atlas Dresser Atlas D.S.5-14 1/21/81 TaPe # 61360 Schlumberger / Pl~ease sign and return the attached copy as receipt of data. Mary F. Kellis~ North Engineering Transmittal #135 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and C, J5 Company ~s a D,ws,on ol AllanhcR~chheldCompany ARCO Oil and Gas Company North Ataska District Post ~ Box 360 C Anchor,:,ge, Alaska 99510 Telephone 907 277 5837 Jerry A. Rochon District Operations Engineer March 20, 1981 Reference: ARCO Cased Hole Finals D.S.2-16 2/3/81 Collar Log D.S.3-5 3/10/81 CCL/Cyro D.S.5-16 3/11/81 CCL/Gyro D.S.9-14 3/12/81 Perf & CCL -- D.S.12-2 3/8/81 CCL/Gyro D.S.16-1 3/7/81 CCL/Gyro 3/7/81 CCL/Gyro D.S.16-2 2/6/81 CCL Run 2 Run ! Run 4 Run 2 2"75" ~ame ,log 2"/5" ~ame log 2"/5" sa=e log 2"/5" same log 2"/5" same log 2"/5" same log 2"/5" same, se sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #136 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Od ,1nd O,)s Company ~s a D~v,s,on OI AtlanbcR*chl~eldCompany EXXON MOBIL GETTY PHILLIPS,...-'/( ,?:,'; MARATHON CHEVRON AIBs~,1 ARCO Ala.ka, Inc.~ Post Olfice ( 350 Anchorage, A,aska 99510 Telephone 907 277 5637 March 12, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservati on Commi ss ion 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 16-2 DS 16-8 DS 13-12 DS 14-9 DS 16-3 DS 16-16 DS 15-22 (T-1 CONFIDENTIAL) Dear Sir: Enclosed please find: The Completion reports & Drilling Histories for DS 16-2, DS 16-8, DS 13-12 & DS 14-9. The Gyroscopic Surveys for these wells are presently being rerun. Updated Comple- tion Reports will be submitted as soon as data becomes available. 2) The Monthly Reports for DS 16-3, DS 16-16 & DS 15-21. Please note that DS 15-21 is considered CONFIDENTIAL. Sincerely,~~, ~ P. A. VanDusen District Drilling Engineer PAV/KJG:sp Enclosures AF~CO Alaska, Inc ::; a ~,ub~idiarv of, Atlar~lic[],chf-:,;'J;i'~'~,~;;;~u,~, STATE OF ALASKA ~;~M '~. ' ' A L. AND GAS CONSERVATION O :. ISSION WELL COMPLETION OR RECOMPLETION FiEPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number At]antic Richfield Company 80-]50 3. Address 8. APl Number - P.O. Box 360, Anchorage, Alaska 9950] 50-029-20544 4. Location of well at surface 9. Unit or Lease Name 1420' FNL, 1034' FWL, Sec 24, TION, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well To be submitted DSq.6-2_.) At Total Depth 11. Field and Pool Tn he. ~hmittPd Prudhoe Bay Field 5,~n in f;e~ (i~dica;e--t<B-~ b~;ei~.) 16. Lease Designation and Serial No. Prudhoe 0il Pool RKBI ADL 28332 ..J ~e Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore .16. No. of Completions 1/10/81 1/27/81 / 2/1/81 - feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of P;rmafro-~t 10795MD 10748MD YES[~ NO[] 2266 feetMD 11975' (REF: DS 16-1 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/CAL, RFT, CBL/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZEIWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 2Q" 94# H-40 Surf 100' 32" 348sx AS II to surfa~:e 13-3/8 72# L-80 Surf 2687' 17½" 3000sx Fondu & 450sx Permafrost 9-5/8" 47# L-80 Surf 10087' 12¼" 500sx Fondu S00-95 7" 29# L-80 9763' 10790' 8½" 400sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) '~ . ' ' SIZE DEPTH SET (MD) PACKER SET (MD) 52" 9819' 9745' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED .. · ., · 27. PRODUCTION TEST Date.. First Produ,ction I Method of Operation (Flowing, gas lift, etc.) . " n/a ~'7'O"I' ' ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Fiew Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. . 24-HOUR RATE I~ "' · 28. " CORE DATA of oil, gas Submit chips. Brief description of lithology, porosity, fractures, apparent dips and presence ~//.~~.~orwater.n/a ..... . .. core . · ~ ' '. ': . . A~ohorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE~ / Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH. TRUE VERT. DEPTH GOR, and time of each phase. T Sadi erochit To be submit, ted B Sad] erochit To be submitted n/a · · : 31. LIST OF ATTACHMENTS Drilling History . 32. I hereby certify that the forego~ is true and correct to the best of my knowledge · · INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and Icg 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. I:tem 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 fo.r, 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". DS 16-2 DRILLING HISTORY Spudded well @ 0400 hrs, 1/lO/81. Drld 17½" hole to 2710'. Ran 68 its 13-3/8" 72# L-80 BTC csg w/shoe @ 2687'. Cmtd csg w/3000 sx 11.7 ppg Fondu & 450 sx 15-15.5 ppg Permafrost. Set 13-3/8" pkoff & tstd to 2000 psi f/15 min - ok. NU BOPE & tstd to 5000 psi - ok. Drld cmt, FC, FS & lO' new form to 2720' Tstd form~to 12.5 ppg EMW - ok. Drld 12¼" hole to .~,11~6_'. Circ ~ cond hole for 9-5/8" csg. Ran 218 its L-80 and 30 jts S00-95 47# BTC 9-5/8" csg w/shoe @ 10,087'. Cmtd csg w/500 sx Class G cmt @ 14.0-15.8 ppg..~Set 9-5/8". pkoff and tstd to 5000 psi - ok. Tstd csg to 3000 psi f/15 'min - ok. Drld cmt, FC, FS & 10' new form to 10,126' Tstd form to 12.5 ppg EMW - ok. Drld 8~"2 hole to~ Circ & 6on~ hole for logs. Ran DIL/SP/BHCS/GR f/10,783'-10,087'. Ran FDC/CNL/GR/CAL f/10,781'-2687'. Ran RFT f/lO 229'-10,616' (8 stops). Arctic Packed 9-5/8" x 13-3/8" annulus w/400 ~bls H20, 60 bbls Perma- frost "C" cmt and 131 bbls Arctic Pack while logging. Circ & cond hole for 7" liner. Ran 33 its 7" 29# L-80 & BUTT csg f/9763'-10,790'. Re- ciprocated 7" liner while cmtg w/20 bbl Sepiolite spacer & 400 sx Class G cmt. Drld cmt & FC @ 10,748' PBTD. Tstd liner lap to 3000 psi f/1 hr - ok. Circ & displaced well w/150 bbls H20, 50 bbls high visc pill & 682 bbls salt water.. Tstd liner lap w/3000 Psi f/15 min - ok. Ran CBL/CCL f/10,728-9400 (.static), f/10,728-9400 w/500 psi (dynamic). Ran 5½" compl string w/tbg tail @ 9819' & pkr @ 9745'. Instld ball valve assy & control line, tstd to 5000 psi - ok. ND BOP. NU & tstd tree to 5000 psi - ok. Displaced well. to diesel (650 bbls). Set pkr w/1500 psi & shear out w/3300 psi. Tstd tbg w/3500 psi & ann w/200 psi - ok. Began long term tbg tst. Secured well & released rig @ 0600 hrs, 2/1/81. 2laska Oil &A~cJ~orageaa~ Cons. Commi~8ioa. Eastman / , Whipstock l)~ A PETROLANE COM~NY REPORT SUB-SURFACE DIRECTIONAL SURVEY Arco Oil & Gas COMPANY D.S. 16, Well No: 2 WELL NAME Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER A181D0192 TYPE OF SURVEY Directional Single DATE 2-3-81 SURVEY BY Jerry Cook / Lynn Hensley .. OFFICE Alaska Eastman Whip t q c P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 34~4517 TWX 910-881-5066/Cable: EASTCO February 3, 1981 ARCO Oil & Gas P.O. Box 1479 Anchorage, Alaska 99510 Well Number: D.S. 16, Well No: 2 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: February 3, 1981 Method of. Computation: Radius of Curvature Surveyor: Jerry Cook, Lynn Hensley Job Number: A181D0192 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Directional Single Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, im~Tulnage TM District Operations Manager Alaska DistriCt JT/cfw cc- file enc. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO ALASKA~- 1NC. .....................~ i PRUDHOE BAY~ NORTH SLOPE~ ALASKA Im$$~, 0 - 10795 MDT ..... ImRILLER Jo COOK__& L., .... HENSLEY VERTICAL SECTIDN CALCULATEd? i~~ PLANE~!OFiF'ROPoSAL' "~? cl..."i~ .. RECORD OF SURVEY RAIJ1US OF CURVATURE HETHOD RCO ALASNA, INC. ~' ~ COMPUTATION IS 16,-WELL NO: 2,,~DSS ............ ~ ............................................................................ JOB~NOI~.A181D0192 ...... TIME ,. DATE RUDHOE BAY, NORTH SLOPE, ALASKA 10:48:43 03-FEB-81 PAGE NO. I TRUE - iEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E [IOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION '[VD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI]Y FEET .... D M D M ..... FEET ......... FEET ....... FEET FEET FEET FEET D M DG/IOOFT O, 0 0 0 0 Oo 0,00 0,00 -72,00 ..... 480, ....0 0 0 0 ......... 480+ ....... 480,00 ............ 0,00 408.00 965, 0 0 0 0 485, 965,00 0,00 893,00 1543. 0 45 S 40 0 E 578. 1542.98 -0.21 1470.98 2710, ~ 1 0 S 69 0 E 1167.,~ 2709.85 ....... 3,27 2637,85 0,00 0,00 0,00 0 0 0,00 0o00 ._. 0,00 0,00 0 0 0,00 0,00 0,00 0,00 0 0 0,00 2,90 S 2,43 E 3,78 S 40 0 E 0,13 13.13 S 16.77 E 21.30 S 51 57 E 0.04 2860, 2 15 S 88 0 E 150, 2859,78 5,72 2787,78 2921, - 3 . 0 N 69 0 E 61,.- 2920,72 ..............8,03 2848,72 3006. 4 15 N 4? 0 E 85. 3005.55 13.26 2933,55 3138. 7 15 N 59 0 E 132. 3136.87 26.37 3064.87 ~-3231,- 9 30 N 55 0 E._ .......... 93, .......... 3228,87 ......... 3?,70 3156,87 13.97 S 20.92 E 25.16 S 56 16 E O~-'~'''~ 13.51 S 23.66 E 27.25 S 60 16 E 2.~0 10.76 S' 28.24 E 30.22 S 69 9 E 2.07 3,00 S 38.93 E 39,04 S 85 36 E 2,39 4.38 N 50.28 E 50.48 N 85 I E 2,50 3325, 11 45 N 49 0 E .,3449, .... 150 N..43 0 E 3574, 18 15 N 3? 0 E 3682. 21 0 N 39 0 E , 3807. '25 0 N 40 0 E 15.04 N 63.94 E 84,56 E 34,96 N 61"~94 N~- 108,01E 90.13 N 130.84 E ~127.80 N 161.90 E 65.68 N 76 46 E 91.50 N 67 32 E 124.51 N 60 10 E 158.87 N 55 26 E 206.26 N 51 43 E 3932. 28 0 N 40 0 E 125. 3890.24 260.90 3818+24 : 4053. 31 30 N 40 0 E 121. .... 3995.28 320.50 3923.28 4208. 36 0 N 41 0 E 155. 4124.12 406.06 4052.12 4271. 38 15 N 42 0 E 63. 4174.35 443.91 4102.35 ...4618, ..... 39 45 N.42 O.~E ....... 347.,.. 4444,01 ........... 661,48 4372.01 i 5085, 39 0 N 42 0 E 467, 4805,00 956,66 4733,00 1_5455,.. 39 15 N 42 0 E .370, 5092,04~ 1189,28 5020.04 170,53 N 197,74 E 216,51N 236,33 E 281,98 N 292,24 E 310,45 N 317,44 E 472,73 N 463,55 E 261.12 N 49 14 E 320.52 N 47 30 E 406.10 N 46 I E 444.01 N 45 38 E 662.0? N 44 26 E 692.89 N 866.39 N 661,79 E 958.16 N 43 41 E 818,01 E 1191.54 N 43 21 E 5965. 38 45 N 42 0 E 510. 5488.38 1509.07 5416.38 1104.90 N 1032.76 E 1512.42 N 43 4 E i' 6206. 38 .45 N 43 0 E 241. 5676.33 1659.47 5604.33 1216.12 N 11~14.67 E 1663.26 N 43 I E .~6585. 39 15 N 45 0 E ........ 379., 5970.87 1897.67 5898.87 1387.68 N 1300.35 E 1901.72 N 43 8 E ~ 7110. 40 15 N 45 0 E 525. 6374.51 2233.19 6302.51 1625.06 N 1537.73 E 2237.28 N 43 25 E :..764,0,.._.:.40 0 N 45 0 E ............. 530,.... 6779,7? 2574,57 6707,77 1866,58 N 1779,25 E 2578,73 N 43; 38 E i.--7982, 39 30 N 45 0 E 342. 7042,71 2793.14 6970,71 2021,22 N 1933,88 E 2797,36 N 43 44 E :~ 8479. 36 15 N 45 0 E 497. 7434.97 3098.06 7362.97 22;~I6.95 N 2149.61 E 3102.38 N 43 52 E i...8945, .... 32 30 N 47 30.E ........ 466,.~ 7819,52 ~3361,08 7747,52 2418,84 N 23;39,62 E 3;365,21 N 44 3; E 2.66 2.85 2.76 2.55 3.22 2.40 2.89 2.93 3.70 0.~ 0.16 0,07 0.10 0.26 0.36 0.19 0.05 0.15 0.65 0,86 RCO ALASKA, INC. S 16, WELL NO: 2, DSS " ......... JOB.NO: A181[m0192 RUDHOE BAY, NORTH SLOPE, ALASKA CO~iPUTATION TIME m ' DAI'E : 48: 43 O~I-FEB-81 PAGE NO. 2 TRUE - EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEPTH SECTION 'FVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEUERITY FEET ..... D M D M .... FEET .............. FEET ................ FEET ........... FEET ....... FEET .... FEET D M DG/IOOFT- 9293. 33 0 N 48 0 E 348. 8112.20 3549.32 8040.20 2545.42 N 2478.98 E 3553.10 N 44 15 E 9566. ...... 32 30 N 51 0 E ....... 273, ...... 8341.80 ......... 3696.84 8269.80 ..... 2641.32 N 2591.27 E 3700.17 N 44 27 E 9887. 31 45 N 53 0 E 321. 8613.65 3866.84 8541.65 2746.41 N 2725.77 E 3869.44 N 44 47 E oo 8808.91 3?85.70 8736.91 2817.58 N 2821.95 E 3987.75 N 45 3 E 10116. 31 15 N 54 0 E 10511. 28 30 N 54 0 E 395. 9151.38 4180.92 ?07?.38 2933.22 N 2981.11 E 4182.20 N 45 28 E 0.16 0.62 0.41 0.32 0,70 10795. 26 30 N 44 0 E 284. 9403.28 4311.79 9331.28 3019.14 N 3079,95 E 4312.92 N 45 34 E 1.~''~ FINAL CLOSURE - DIRECTIONI N 45 DEGS 34 MINS 17 SECS E .......... DISTANCE~ ........ 4312.92.FEET ' ' - ........................................... F---~--RRC§ ALASKA, --ZNC. - , ....... ---!,--' .... -! ....... :--: ........ ...... I._--;~DS ' 16,-' WELL';NEI ::'-2;-"DSS ;'-'--!-.-~ · ~;-.--t-;-~---~;'_ PRUDHOE BAY> .... NORTH~-SLOPE',; .... ALASKA ~,, ERSTllRN "i4H iPSTOCK~,i.;_-I NC :-¥.~----¥;;;~;. ~;;.~;~-3.L_.L-.'----'7;~i . . . , '-' , F;3;77-£--..~'Z-'--TZ:--CL;;;;:~';LiE;;~-';Z.i"-.~.~--.-;;~.L------£!E~.~ . I ~ .....± ~ ....... ---=4 ............ ~- .... : ..... - ~- ,i. : ~: '-'-~-- ............... :--~ ........ ~' ...... :--~--~ ............ I i' ; --' ~" ~ :;-~: i i:~ '.', ,' : ' t-:": '-'-~ ~-'----- · L . . . , , ~ ............. -- J ' '-':- ,-I-------- J ........ T~---7'~'-'T--t-'m-?-~ .....l---T---~--t- ':-T---I'-?''-- .......... :-- ........ .~! ~__L_~- .......... i--~- ----I--~--'--- =-A~--~-~--~J~-:- ...... ~------F ........... i ...........T- ............... '~-e'--; .... ~- ............ m ......... ~ ......... 4/ ....... =---p--~--~-- .-. ! .......-~ .......... ~-.~--<--.?-~ .............. ~- ......... x ...... -I--~- .... ~ ..... · ! 0:'/95- ......... 9_ ~ERST 30'79 Eastman / A PETROLANE COMPANY REPORT SUB-SURFACE D IREC Ti ONA L RECEIVED SURVEY ~AY ~ 1 1981 A/aska Oil & Gas Cons, Commission AnChorage · COMPANY D.S. 16-2 WELL NAME PRUDHOE BAY, ALASKA LOCATION JOB NUMBER A381G0266 TYPE OF SURVEY Gyro Multi Shot DATE 3/7/81 SURVEY BY T. Jone s/G. Rutland OFFICE ALASKA Eastman Whipstock A PETF~'OI..ANE May 13, 1981 P. O. Box 4- 1970/Anchorage, Alaska 99509/(907) 34~4617 'TWX 910-881-5066/Cable: EASTCO Arco Alaska, Inc. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: D.S. 16-2 Location: Prudhoe Bay, Alaska Type of Survey: Gyro Multi Shot Date: 3/7/81 Method of Computation: Radius of Curvature Surveyor: T. Jones/G. Rutland Job Number: A381G0266 Attn: Bob Hines Dear Mr. Hines: I am enclosing the original and one copy of the Gyro Multi Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. !!i~/ik~o i sT~ rC~it ca 1 Coordinator Enclosure TJ/kp Directional Drillers/Sub-Sud_ace Surveyors / Instrument & Tool Rentals/Sales / Worldwide ARCO ~ALASKA,INC. DS 16, WELL.. NO: 2, GMS UOB NO: A381G0266 PRUDHOE"' BAY, NORTH SLOF'E, ALASKA GMS, 0- 10600 MD, SURVEYOR; T~ UONES/G,RUTLAND, DATE RUN; 7-MAR-81 GYRO N0:399, 12 DEG A/U N. 0;302,90 DEG A/U N0~'1110, CAMERA N0;1194/1195 SURVEY TAKEN ON WELLHEAD VERTICAL SECTION CALCULATED IN F'LANE.'OF' F'ROPOSAL DIRECTION; ~N 46 DEG, 5~ MINo E RECORD OF SURVEY RADIUS OF CURVATURE METHOD OS 16, WELL NO; 2, GMS , · JOB NO: A381G0266 ' TIME: DATE ' ~'RUDHOE BAY, NORTH SLOF'E, ALASKA /~,~:x-~.~ /c~ ~--' 07:13:36 13-MAY-81 TRUE '4EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE, DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DIS'~ANCE DIRECTION SEVERIT FEET D M D M FEET FEET FEET FEET · - FEET FEET D M DG/100F O, 0 0 0 0 O, 0.00 0.00 -72.00 0000 0.00 0.00 0 0 0.00 .... 100, 0 0 0 0 ....... 100, . .100,00 - 0.00 ..- 28,00 ..... 0o00 ............. 0,00 0,00 0 0 0,00 200. 0 15 S 55 0 W 100. 200.00 -0,22 128.00 0.12 S 0.18 W 0.22 S 55 0 W 0.25 SO0. 0 0 0 0 100. SO0.O0 -0.43 228.00 0.25 S 0.36 W 0.43 S 55 O. W 0.25 400, 0 0 0 0 100, 400.00 -0,43 · S28,00 ·. 0,25-.S ......... 0,36 W 0,43 S 55 0 W 0,00 500, 0 0 0 0 100, 600, 0 15 N 32 0 E 100. 700, 0 0 0 0 100, 800. 0 30 S 72 0 E 100, 900, 0 15 S.42 . 0 E 100, 500,00 600,00 700,00 800,00 900,00 -0,43 428.00 0.25 S 0.S6 W -0.22 528.00 0.06.S. - 0.24 W -0.01 628.00 0.12 N 0.1S W 0.20 728.00 0.02 S 0.29 E 0,36-828,00 .... 0,37 S .... 0,83 E o.4 s' 55 o w : oo 0.25 S 74 54 W 0.25 0.17 N 46 ~0 W 0.25 0.29 S 86 54 E 0.50 0,91 S 66 8 E 0,S1 1000. 1100. 1200. 1SO0. 1400. 1500, 1600, 1700, 1800. 1900. 0 15 8 SS 0 E 0 15 S I OW 0 ~0 S 19 0 E 0 0 0 0 0 SO S 2 OW 0 45 S 23 0 E 0 45 S 5 0 W 0 45 S~ o6 0 E 0 SO S 27 0 E 0 .SO S 29 0 E 100, 999,99 100, 1099,99 100, 1199,99 100, 1299.99 100, 1S99,99 100. 1499,98 100, 1599,97 100, 1 6~.97 100, 1799.96 100, 1899,96 0,31... 927.99 0.12' : 1027~99 -0.25 '1127'99 . . -0,43 1~7,99~ -0,74 1`S27,99 -1.`S2 1427,98 -2,05 .1527,97 -2,74 1627,97 -3,05 1727,96 -`S,28 1827,96 0.71S 1.10 E 1.13 S,~:.. - 1.22 E "'1,77 S'''' ~ : 1.32 E 2.18 S' 1.46 E '2.62 S 1.45 E S,68 S 1,64 E 4.96 s i,85 E 6.24 S 2,08 E 7,71..... S -~, 57 E 7,98 S. 2,98 E 1,31 S 56 57 E 1,66 S 47 11E 2,21 S .S6 40 E ,,~ 63 S `SS 46 E 2.99 S 28 53 E 4,03 S 24 2 E 5.30 S 20 24 E 6,57 S 18 27 E 7,65 S 19 S6 E 8.52 S 20 27 E 0,04 0,15 0,28 0,50 0,50 . 0,36 0,36 0,40 0,25 -~02 2000. 2100. 2200. 2300, 2400. 2500, 2600. 2700. 2900. i 0 S 7`S 0 E 1 30 N 60 0 E 1 .SO N 59 0 E 1 .S0 N 58 0 E I 0 N 74 0 E i 0 S'90 0 E 1 0 S 68 0 E I 0 S 54 0 E I .S0 S 77 0 E 2 45 N 58 0 E 100, 1999,95 100, 2099,92 100. 2199,89 100, 2299,85 100, 2S99,8.S 100, 2499,82 100, ~°~'99,80.~ 100, 2699,78 100. 2799,76 100, 2899,69 -3,11 1927,95 -1.40 ~0~7.92 1.15 2127.89 3,71 9?07 85 5,77 2327.83 7.19 2427,82 8.~1 2527 80 8.74 ~.~7 78 9,57 2727,76 12,58 2827,69 8,78 S `S,97 E 8,54 S 6,08 E 7.22 S 8..S3 E 5.85 S 10.56 E 4,96 S 12.55 E 4,72 S 14,27 E 5.05 S 15,98 E 5,90 S i7.50 E 6,80 S 19,47 E 6,20 S 23,03 E 9.64 S 24 19 E 0,73 10,48 S .S5 25 E 1.10 :[1.02 S 49 6 E ' 0.03 12.07 S 61 2 E 0.03 13.50 S 68 25 E 0,61 15.0~ S 71 42 E 16.76 S 72 27 E 18,47 S 71 23 E 20.62 S 70 46 E 23,85 S 74 56 E 0,28 0.38 0,24 0.70 1.99 Do 16, WELL O: ~, GMS ~PRLJDHOE BAY, NORTH~,eLOPE, ALASKA JOB NO~ A381G0266 CUMi-.'UlA'flON TIME DATE 07:13~36 13-MAY-81 PAGE TRUE . MEASURED DRIF'T DRIFT' COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE~ DEF'I'H ANGLE DIRECI'ION LENGTH DEF'TH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERI" FEET D M D M FEET FEET FEET FEET FEET_ FEET D M DG/100F 3000, 4 15 N 59 0 E 100, 2999,50 18,56 2927,50 3,01S 28,24 E .JlO0... 6 30 N 60 O.E..100. _ 3099.05 27.70..3027.05 ......... 1.74 N ........ 36.31E S200, 9 15 N 61 0 E 100, 3198,10 41,01 3126,10 8,49 N 48,23 E 3300, 11 15' N 65 0 E 100, 3296,~0~ 58,10 3224,50 16,57 N 64,08 E 3400, 14 45 N 54 0 E 100, 3393,92 80,02 3321,92 ...27,96..._N ............ 83,43 E 5500, 16 0 N 49 30 E 100. 3490.34 106,43 3418,34 44,37 N 104,~w E 3600, 19 0 N 48 O E 100, 3585,70 136,48 3513,70 64,20 N .... 126,85 E ~700, 21 30 N 48 0 E 100, 3679,51 171,08 3607.51 87,36 N 152,57 E 3800, 25 0 N 49 0 E 100, 3771.38 210,53 3699,38 113,51 N 182,13 E .3900,. 27 30 N 49 0 E . 100, 3861,06 254,73 ..... 3789,06 142,52 N ..215,51 E 28.40 S 83 55 E 36.35 N 87 15 E 48.97 N 80 1E 66.19 N 75 30.E 88.00 N 71 28 E 1.50 2.25 2.75 2.12 4.27 113,30 N'66 57 E ~73 142,17 N 63 9 E 3,03 175,81 N 60 12 E 2,50 214,61 N 58 4 E 3,52 258,38 N 56 31 E 2,50 4000, 30 0 N 49 30 E 4100. 32 0 N 49 30 E 4200, 36 0 N 50 0 E 4500, 39 0 N 50 SO E 4400, 39 0 N 50 30 E 100, 3948,73::' 302,78 ..3876,73 . 173,92 N 251,95 E 100, 4034.44" 554,23 3962,44 ' 207,.36 N 291,11E 100o 4117,32 410,07j 4045;;32 243,49 N- 333,78 E 100, 4196,65 470,83 4124,65 282,41N 580,58 E 100 4274 37 535 64 4207,37 3~,44 N 429,14 E 306.14 N 55 23 E 357,41 N 54 32 E 413.15 N 53 55 E 475.91 N 53 o~ ~ E 536.77 N 53 5 E 2,51 2,00 4.01 3,02 0,00 4500. 39 0 N 51 O,E 100. 4352.08 596.43 4280.08 4600. 39 JO N 51 0 E 100. 4429.52 659.55 4557.52 4700, 39 45 N 50 0 E 100. 4506.54 723,18 4434.54 4800, 59 30 N 51 0 E 100. 4583.56 786.83 4511,56 4900, 39 30 N 51 0 E' 100, 4660,73. 850,27~ 4588,73 362.26 N 477,87 E 402,07 N 527,04 E 442,64 N 576.25 E 483,20 N 625.46 E 523,23 N 674.89 E 599,66 N 52 50 E 0,31 662,90 N 52 40 E 0,50 726,63 N 52 28 E 0,69 790,37 N 52 19 E 0,69 853,96 N 52 13 E 5000. 39 0 N 51 0 E 5100. 39 0 N 52 0 E 5200. 39 0 N 50 30 E 5300. 39 0 N 53 0 E 5400, 39 15 N 53 0 E 100, 4738,17 913.38 4666,17 563,05 N 100, 4815,88 976,10 4743,88 602,23 N 100, 4893.59 1038,85 4821,59 641,62 N 100. 4971,31 1101.55 4899,31 680,57 N 100, 5048,89 i164,29 4976,89 718,55 .N 724,06 E 917,22 N 52 8 E 0,50 773,31 E 980,15 N 52 5 E 0,63 822,39 E 1043,07 N 52 2 E ~ 0,94 871,81 E 1106,00 N 52 I E 1,57 922,20 E 1169,09 N 52 5 E 0,25 5500. 39 15 N 52 30 E 5600. 39 0 N 53 0 E ~F;700. 38 45 N ~,.~.o 0 E 5800. 38 45 N 52 0 E 5900. 38 30 N 51 0 E 100. 5126.32 1227.23 5054.32 100. 5203.90 1290.00 5131.90 100, 5281,75 1352,46 5209,75 100, 5359,74 1414,81 5287,74 100. 5437,87 1477,02 5365,87 5' .o.84 N 972.57 E 1232.36 N 52 7 E 795.04 N 100~.80 E 1~95.45~ N 52 8 E 833.24 N 1072.59 E 1358.21 N 52 9 E 871,78 N 1121,91 E 1420,81 N 52 9 E 910,64 N 1170,76 E 1483,22 N 52 7 E · 0.32 0,40 0,68 0.00 0.67 ~o 16, WELL NO:~,o GHS ~"RUBHOE BAY', NORTH SLOPE, ALASKA .;oB NO; AS81G0266 ~OhFUIAIION TIME DATE 07:13:36 13-MAY-81 PAGE NO ,. S TRUE qEASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEPTH ANGLE DIRECTION LENGTH DEF'TH SECTIOn4 TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT FEEl' - D M D M FEET FEET FEEl' FEET FEET FEET D M DG/iOOF 6000. 38 45 N 50 30 E 100, 5515.99 1539,30 5443.99 950,13 N 1219,10 E 1545,62 N 52 4 E 6100. 38 45 N 50 30 E .100. 5593,98 1601.77 5521,98 989,94 N ..1267,40 E 1608,19 N 52 0 E 6200, ~8 45 N 50 0 E 100. 5671.97 1664,25 5599,97 1029,97 N 1515.52 E 1670,76 N 51 56 E 6~00, 39 0 N 50 0 E 100, 5749,82 1726.92 5677,82 1070,~1 N 1363,60 E 1733,49 N 51 52.E 6400. 39 0 N 50 30 E 100. 5827.54 1789,75 5755,54 1110.55.~N .... 1411.99 E 1796,39 N 51 49 E 6500, 39 0 N 50 0 E 100. 5905,25 1852.57 5833,25 1150,79 N 1460,37 E 1859,31 N'~51 46 E 6600, 39 15 N 50 0 E 100. 5982,83 1915.58 5910.83 1191.35 N ..-1508.71 E 1922,38 N 51 42 E 6700, 39 45 N 48 0 E 100. 6059.99 1979.14 5987,99 1233,08 N 1556.71 E 1985,91 N 51 37 E 6800, 39 45 N 48 30 E 100, 6136,87 2043,06 6064,87 1275,66 N 1604,42 E 2049,75 N 51 31 E 6900. 40. 0 N 48 0 E .. 100,.-6213,62 2107,15 .6141.62.. 1318,35 N-.1652,25 E 2115.76 N 51 25 E 7000, 40 0 N 48 0 E 7100, 40 0 N 48 0 E 7200, 40 30 N 48 0 E 7300. 40 45 N 49 30 E 7400, 40 30 N 49 30 E 100. '6290.22 2171'42 6218.22 1361,36 N 1700.02 E 2177,93 N 51 19 E 100, 6366,83 2235,69 6294,83 1404o37 N~ 1747,79 E 2242,10 N 51 13 E 100, 6443.15 2S00,29 ' 6371,15 1447,60 N 1795,80 E 2306,61 N 51 8 E 100 6519,05 ~o~,36 6447 05 1490 53 N 1844 75 E 2371 67 N 51 4 E 100, 6594,95 -2430.41 6522,95 1532082 N 1894,27 E 2436,76 N 51 I E 0,40 0,00 0,51 0.25 0,31 O,O~ 1,37 0.32 0.41 0,00 0o00 0.50 1,01 0.25 7500. 40 15 N 47 0 E 100. 6671.13 2495.16 6599.13 1575,95 N 1942.59 E 2501.45 N 50 57 E 7600. 40 0 N 47 0 E 100. 6747 59 2559 61 6675 , . ,~9 1619 90 N 1989 72 E 2565 75 N 50 51 E 7700. 40 0 N 47 0 E 100. 6824.20 2623.89 6752,20 1663,74 N 2036.73 E 2629.89 N 50 45 E 7800. 39 45 N 47 30 E 100. 6900,94 2688.00 6828,94 1707.26 N 2083,81 E 2693,89 N 50 40 E 7900 39 45 N 47 30 E 100 6977 83 .~7~1 94 6905,83 1750.46 N 2150 96 E 2757 73 N 50 36 E 1.64 0,0 0.00 0.41 ~0 8000. 39 30 N 48 30 E 8100. 39 0 N 48 30 E 8200. 38 45 N 48 0 E 8300, 38 0 N 47 0 E 8400, 36 45 N 47 0 E 100. 7054.85 2815.70 6982,85 1793.13 N 2178.35 E 2821.44 N 50 32 E 0.69 100. 7132.29 2878.94 7060,29 1835.06 N 2225.74 E 2884.67 N 50 30 E 0.50 100. 7210.14 2941.69 7138.14 1876.85 N 2272.56 E 2947.39 N 50 27 E , 0.40 100 7288.% . · . . ~4 3003 76 7216,54 1918 79 N 2318 33 E 3009.39 N 50 23 E 0.97 100. 7S68.00 3064.47 7296.00. 1960,19 N 2362.73 E 3069.99 N 50 19 E 1.25 8500. 36 15 N,49 0 E 8600. 36 0 N 50 SO E 8700. 33 ~0 N 51 0 E 8800. 33 45 N 52 0 E 8900. 32 45 N 53 ,0 E 100. 7448.39 3123.93 7376.39 1999.99 N 2406.95 E 3129.42 N 50 17 E 100, 7529.16 3182.81 7457.16 2038,08 N 2451.92 E 3188.37 N 50 16 E 100. 7611.32 3239.68 7539.32 2074.14 N 2496.06 E 3245.36 N 50 16 E 100. 7694.59 3294.87 7622.59 ~108.61N 2539.40 E 3300.7°- N 50 18 E 100. 7778.22 3349.44 7706.22 2141.99 N 2582.90 E 5555.51 N 50 20 E 1.29 0.92 2.52 0.61 1.14 IlS 16, WEL,L NO: 2, GMS ::'RUDHOE BAY, NORTH SLOPE, ALASKA JOB NO; AS81G0266 UOHI:;'UIAtlDN TIME DATE 07:1S;S6 1S-MAY-81 F'AGE NO.. 4 TRUE . '~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLEG DEF'TH ANGLE. DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT' FEET . D M D H, FEET FEET FEET FEET ....... FEET FEET D M DG/100F' 9000. S2 0 N 54 SO E 100. 7862.67 S402.60 7790.67 217S.65 N 2626.08 E 3408.96 N 50 23 E ...9100., S2 .15 N 53 SO E ...100. __7947.S6 S455.S6 ....... 7875.S6 2204.91 ..... N ..... 2669.10 E 3462.0S N 50 26 E 9200. 3o ..... 15 N 56 0 E 100. 80S1.93 3508.oo 7959.9S 2235°70 N 271o.67 E 351='~.24 N 50 30 E 9300. 32 45 N 57 30 E 100. 8116.27 3561.15 8044.27 2265.16 N 2757.60 E S568.66 N 50 S6. E 9400 33 0 N 59 0 E 100. 8200.26 3614.S7 8128.26 229~.72..N ..... 2803.76 E S6~.46 N 50 43 E 9500. 34 0 N 60 0 E 9600. 31 30 N 62 0 E 9700, 31 0 N 63 0 E 9800. 31 15 N 63 0 E 9900. 32-0 N 64 0 E 100. 8283.65 3668.23 8211.65 2321.73 N 2851.31 E 3677.02 N' 50 51 E 100. 8367,74 3720.69 8295,74 2347,96 N .2898,62 E 3730,27 N 51 0 E 100. 8453.23 3770.65 8381.23 2371.91 N 2944.64 E 3781.12 N 51 9 E 100. 8538.84 3820.31 8466.84 2395.38 N 2990.70 E 3831.72 N 51 18 E 100. 8623.99 3870.55 ..8551.99 2418.78 N_._3037.62 E 3882.99 N 51 28 E 1.10 0.59 1 0.95 0.85 2.72 0.72 0.25 0.92 10000. 31 45 N 64 30 E 10100. 31 45 N 66 0 E 10200. 29 0 N 65 0 E 10300. 28 15 N 63 0 E 10400. 28 0 N 61 30 E 10500. 28 15 N 62 0 E 10600. 28 0 N 58 0 E 100. 8708.91 3920.95 8636.91 2441.72 N 3085.18 E 3934.51 N 51 38 E 100, 8793.94- 3970,89 8721.94 2463.75 N 3132,97 E 3985,67 N 51 49 E 100. 8880.21 4018.80" 8808'.21 2484.71 N ' 3178.98 E 4034.81 N 51 59 E 100. 8967.98 4064.59 8895°98 2505.71 N 3222.03 E 4081.68 N 52 8 E 100. 9056.18 4110.04 8984.18 2527.66 N 3263.75 E 4128.09 N 52 15 E . 100. 9144.37 4155.60 9072.37 2549.97 N 3305.27 E 4174.59 N 52 21 E 100. 9~3~ =.56 4~01.50~ 9160.56 2573.54 N 3346.09 E 4221.30 N 52 26 E 0.36 0.79 ~ 80 1.22 0.75. 0.34 1.90 FOLLOWING STATIONS ARE I:'RO,JECTEI] / 10673 MD- BASE SAD 10673. 28 0 N 58 0 E 73. 9297.02 4235.13 9225.02 2591.70 N 3375.15 F 4255.41 N 52 29 E ' 0.00 10748 MD - PLUG BACK '~ 24 . 2610 36 N 3405.01E 4290.46 N 52 32 E 0.00 10748. 28 0 N' 58 0 E /~. 9363. 4269 68 9291.24 10795 MD -- TD 28 0 N 58 0 E 47. 9404.74 4291.33 9332.74 2622.05 N 3423.72 E 4312.43 N 52 33 E 0.00 FINAL CLOSURE - DIRECTION; DISTANCE; N 52,DEGS 33 MINS.E 4312.43 FEET Eastman Whipstock A PETROLANE COMPANY May 13, 1981 P. O. Box 4-1970/Anchorage, Alaska 99509/(90~ 349-4617 TWX 910-881-5066/Cable: EASTCO Arco Alaska, Inc. P.O. Box 1479 Anchorage, Alaska 99510 Well Number: D.S. 16-2 Location: Prudhoe Bay, Alaska Type of Survey: Gyro Multi Shot Date: 3/7/81 Method of Computation: Radius of Curvature Surveyor: T. Jones/G. Rutland Job Number: A381G0266 Attn: Bob Hines Dear Mr. Hines: I am enclosing the original and one copy of the Gyro Multi Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Tom . Dis Technical Coordinator Ala District Enclosure TJ/kp Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO ALASKA,INC. ' I)S 16, WELL. NOI 2, GMS JOB NOI A381G0266 PRLIDHOE BAY, NORTH SLOF'E, ALASKA GMS, 0 - 10600 MD, SURVEYORI T, JONES/GoRUTLAND, DATE RUNI 7-MAR-81 GYRO N0~S99, 12 DEG A/U N01302,90 DEG A/U N0~1110, CAMERA N0~1194/1195 SURVEY TAKEN ON WELLHEAD .... VERTICAL SECTION CALCULATED IN F'LANE'"-OF F'RoPOSAL"'.~-",,~,~:~i';: - OIRECTiON~ 'N 46 DEG. 53""MIN. E ' · .. 5- RECORD OF SURVEY RADIUS OF CURVATURE METHOD ARCO ALASKA,INC. ~ '' I)~ 16, WELL NO: 2, GMS JOB NO~ AJS1G0266 PRUDHOE BAY, NORTH SLOF'E, ALASKA GMS, 0 - 10600 MD, SURVEYOR: T. JONES/G.RUTLAND, DATE RUN: 7-MAR-81 - GYRO N0~599, 12 DEG A/U N0;502,90 DEG A/U N0;1110, CAMERA N0;11~4/11~5 SURVEY TAKEN ON WELLHEAD RECORD OF INTERPOLATED SURVEY DS 18, WEL.I. N6, .~, GMS F'RUr_~HOE BAY, NORTH SLOPE, ALASKA JOB NO; A381GO26& - TIME DATE 07~18;52 13-MAY-81 PAGE -MARKER ........ 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' ' '."-'~'; .... ~ :" ;~7~. :."'~'~:t't':.'77-'?~T'." :."'~ ........ ~ ..... - .... 7"i'~'.';:'.'.' .'~'F':':;_'t'Z'T~tt::-: "~ .... ~ .... ............ , ...~. ~.~. ~ ..... . ........ ~ ..... . . ..... ~_ :-. ............... , ...... :..: ._ ..... ~_: :..~....~...~...: ..... ',.~_.: .:. , . ~ .......... , .... " ' ' ..... . ....... ~ ...... ' .... ~..: .... :..,...: .... :...:,.., .... '. ~F~NRE' STflT~ ' ..... :": ' '' -- . ...... ~..; .... .-...~ ~ ..... :--f-:.-;~--~- .... ~.-~--~--. -.- -' -~ .......... ~ .......... ~.-:-~-~-?,--,---~--~.-~-~--¥.~-f-.'--~--DEPTH-- 10795--HB....- 9404-. ~3.-TVD 4.+.~ ...... ...... '' ' ' ~ ......... ~' · ....... ~ ,' ...... : ..... t~-~- -,--~ --'---4 ......... ~ . _ : ...... ~ ~ , .~ , . ~...~ ..... · .; ,..; :. ....... , ..... ~ ............. , . . ,.. ~.~. i. :..~ :~..~..~ .... ~......:...;.~.~..:.._: .... ~ ..... : .... i ..... ; ..... i-I.-:. L.. ....... ~.-:...k.:.]~..;.-~.:-~.-, ...... , NORTH ~6~.05 ....... ...... 3948 .-~.,. ............. ~ ......................... . ~ ....i ....................... ~. .: ,,~ ............ .:: ~,~:,., .... t-~.~d~, .......... ..~ CLOSURE..431~.~ ...... r ................. ~ ....... ~'~ ..... *'~ ......... ~ ' ........~ ...... ~ ..... ~ ~ ~:.. ,..~ ..... ~_._L.. ........... . ; , ~ : ' ~ ; i~ ~ , ~'-+"" ...... *-: ~ · ~'~" ~' ~"J ................ ,, : ~ , ' ~ ....................... t~ : : ~ ; ~ ~ ......... If~ ~"~ ]: '--, , · , ; , ; , . : ~ : I ~ ~ ~ : : : : t : ~ .... , ........ ~ .. .~ ....... I ........... ~ ............. - ~ ..... ,,+.~_..?~.~.~..j .......... , ..... :...[.~ .... , ........ . ......... ~ ] '~ .... . Check Form for timely compliance with our regulations. Reports and Materials to be received by: ~- ~-~/ Date Completion Report Well History Samples Mud Log dOre Chips Directional Survey Required Yes Yes Date Received Remarks Drill Stem Test Reports Production Test Reports Logs Run Yes Digitized Log Data ( CURVE DATA LOCATED IN THE APPENDIX ARCO Oil and Gas Company North Ala( District Post Offic~'' dox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer February 27, 1981 Reference: ARCO CASED HOLE FINALS D.S.16-2 1/30/81 Run 1 & 2 5" CBL/VDL D.S.16-2 2/4/81 Run 1 5" CNL/Gamma Ray e sign and return the attached copy as receipt of data. Mary 'Kellis North Engineering CONFER: t FtLF: Transmittal #92 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO ~ .,R]~C E I V~E ~ CHEVRON Alaska 0i~ & Gas Cons. Commission Anchorage ARCO Oil ancl Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and Gas Company North Al, l~ka~, District Post Ot~ Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer February 18, 1981 Reference: ARCO DIRECTIONAL SURVEYS D.S.14-9A 1/4/81 Multi-Shot D.S.15-1b (N-l) 1/10/81 Multi-Shot 2/3/81 Single-Shot Job NumberA181GO194 Job NumberA181DO192 '~Please sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal #70 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON FEB 2 0 1981 Alg, sk~ Oil & Gaz Cons. Commission Anchorage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and Gas Company North Alask~ 'istrict Post Office~, x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Feb 5, 1981 ) Reference: ARCO CASED HOLE FINALS D.S.16-2 1/26/81 CNL Run 1 5" ~Please sign and return the attached copy as receipt of data. C..,NF~.R: FILF: Mary Kellis North Engineering Tramsmittal #50 DISTRIBUTION NORTH GEOLOGY R&D DRILL I NG ENG~ MANAGER D&M GEOLOGY STATE OF ALASKA EXXO, GETTY PHILLIPS so, Io MARATHON CHEVRON ARCO Oil and Gas Company is a Division o! AtlanticRichfieldCompany ARCO Oil and Gas Company North Alask~ 'istrict Post Office '~., 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Feb 4, 1981 Reference: ARCO Open Hole Finals D.S.16-2 1/26/81 FDC Run 1 5" D.S.16-2 1/26/81 FDC/CNL Run 1 5" D.S.16-2 1/26/81 BHCS Run 1 D.S.i6-2 1/26/81 DIL/SFL Run 1 2" & 5" 2" & 5" ':CONFER: FtLF: , , D.S.16-2 1/26/81 Cyberlook Run 1 5" D.S.16-2 1/26/81 RFT Run 1 - ~"~~Please sign and return the attached copy as receipt of data~ Mary Kellis North Engineering Transmittal #48 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG~ MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Oivision of AtlanticRichfieldCompany EXXON MOB I L GETTY PHILLIPS SOHIO .ARAT" iii E (;. F_J_V E D Alaska 0il & Gas Cons. Commission Anchorage ARCO Oil and Gas Company North AI,'tska District Post Of '~Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Feb 4, 1981 Reference: ARCO Magnetic Tapes & Listings D.S.7-2 12/21/80 Tape #61272 D.S.7-8 10/5/80 Tape #61055 D.S.16-1 ' 1/2/81 Tape #61307 (corrected copy) 1/26/81 Tape '¢/61363. ease sign and return the attached copy as receipt of data. Mary Kellis North Engineering Transmittal ¢/47 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Division of AllanhcRichlieldCompar~y EXXON MOBIL GETTY PHILLIPS SOHIO .-'~'..:.'/~, .. i~_r-..D~! l V F J:'.-, .://../.../~2'.~...,,_, '".~ -,' ~.,...~.,.~.~ MARATHON F F .... 5 ti] CHEVRON , ,,1,la2l(~'l 0it & ARCO Oil, and Gas Company North Alask=, District Post Offic '):)x 360 Anchorage, ~laska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer Feb 4, 1981 Reference: ARCO Open Hole Finals D. S. 16-2 1/26/81 FDC Run 1 5" D. S. 16-2 1/26/81 FDC/CNL Run 1 5" D.S.16-2 1/26/81 BHCS Run 1 2" & 5" D.S.16-2 1/26/81 DIL/SFL Run 1 2" & 5" D.S. 16-2 1/26/81 Cyberlo. ok Run 1 5" D.S.16-2 1/26/81 RFT Run 1 - lease sign and return the attached copy as receipt of data. · Mary Kellis North Engineering Transmittal fi48 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil and Gas Company is a Division of AllanticRichlieldCompan¥ EXXON MOB I L GETTY PHILLIPS SOHIO MA RAT. H 6%~ CHEVRON" c.-" ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. I{amilton~ Chairman Thru: Lonnie C. Smith Commissioner Harold R. Hawkins Petroleum Inspector January 20, 1981 Witness BOPE Test on ARCO D.S. 16-2 Sec. 13, T10N, R15E, UM Permit No. 80-150. ~Monday January !2, ~1981: I witnessed the tests on Arco D.S. 16-2, in between tests on D.S. 15. There were no failures. I filled out.?an ~?~O.G.C.C. report (attached). In summary, I witnessed the BOPE tests on Drill Site 16-2, that Rowan performed for ARCO. Test's were satisfactory. O&G # 4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E.. Inspection Report rInspecto r /~ ~/~ .~ Date Well Operator :~ ~C'~, Well ?Z - 2 Location: Sec~ ~ ~ Drilling Contractor Representative f~c~y /C~¢~.C~,~, ,. pe rmi t # ~.~ - / ~-~ ~f~Casing Set @2 ~ ~ ft. Representativ~ ~A'~ ~~ .. Location, General Well Sign General Housekeeping, ~.~ Reserve pit BOPE Stack Annular Preventer~ Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure.... _~~9 . psig Pressure After Closure /~ 6--~ psig 200 psig Above Precharge Attained_:/ min~ sec Full Charge Pressure Attained: , min2~ sec Controls: Master Remote ~,/~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly. Test Pressure ,~'~ Lower Kelly Test Pressure :~ ........ 0:~© Ball Type Test Pressure ~//~ Test PresSure Inside BOP Choke Manifold No. Valves ~/ No. flanges, ~ ~ ~dj ustable Chokes ./ Hydrauically operated choke Test Results: Failures Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks :. / Test Pressure ! Test Time 2,, hrs. ------days and Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector December 12, 1980 Mr. P. A. VanDusen District Drilling Engineer ARCO Oil and Gas Company Re: Prudhoe Bay Unit DS 16~2 Atlantic Richfield Company Permit No. 80-150 Sur. Loc.: 1420'FNL, 1034'FWL, Sec 24, T10N, R15E, Bottomhole Loc.: 1320'FSL, 1320'FEL, Sec 13, TION, R15E, UM. Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above referenced well. well samples and a mud log are not required. A directiOnal survey and core chips are required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, ~hapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Prudhoe Bay Unit DS 16-2 -2- December 12, 1980 c~ncing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also lt. ke to be nottfie~ so that a repre- sentative of the uommission may be present to witness testing of blowout preventer equipment before surface casing shoe is In the event of suspension or' abandonment, please give this office adequate advance notification so that we may have a 'witness present. Very truly yours, Hoyll H. Hamilton Chairman of BY ORDER O? Ilia (;;Oi%ll~lSSlOM Alaska Oil i Gas ConserVation Commission Enclosure cc: Department of Fish & Game, Habitat SectiOn w/o eno1. Department of Environmental Conservation w/o/encl. Department Of Labor~ Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas r ~pany Alaska Distric Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 9, 1980 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: DS 16-2 Dear Sir: Enclosed please find our Application for Permit to Drill DS 16-2 and the required $100.00 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore, a proximity plat show- ing the location of the subject well to DS 16-1, and a drawing and description of the BOP equipment and testing procedure, including anticipated pressures. As confirmed in previous correspondence from your office, the require- ment of usin§ a surface hole diverter system on this well has been waived. Very truly yours, j P. A. VanDusen District Drilling Engineer PAV:sp Enclosures t ECEIVED Alaska Oil &AnchorageQas Cons. Commission ARCO Oil and Gas Company is a Divisio~'~ of .AU~.t~:dcRicht[ei.::i{.oi,:?;,i~" Form 10-401 REV. 9-1-78 STATE OF ALASKA SUBMIT IN TRIP ~E (Other instructio,. ,4 ide) ALASKA OIL AND GAS CONSERVATION CO~lO~Imqen la. TYPE OF WORK b. TYPE OF WELL OIL [~] WELL PERMIT TO DRILL OR DEEPEN DRILL ~ DEEPEN ~ Anchorage GAS ' SINGLE MULTIPLE WELL D OTHER ZONE rx] ZONE [~] 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, AK 99510 4. LOCATIO~OF W~LLAt surface 1420'FNL, 1034'FWL, Sec.~24, TION, RIDE, UM At propose.d prod. zone 1320'FSL, 1320'FEk, SecJ~, TION, R15E, UM 13. DISTANCE IN MILES AND DIRF_L~ION FROM NEAREST TOWN OR POST OFFICE* 5 miles ENE of Deadhorse, Alaska API #50-029-20544 5. 6. LEASE DESIGNATION AND SERIAL NO. ADL 28332 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 16-2 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/Prudhoe 0il 11. SEC., T., R., M., (BOTTOM poOl HOLE OBJECTIVE) Sec 13, T10N, R1.DE 12. 14. BOND INFORMATION: r~E' S tatewide Surety and/or No. Federal Insurance Co. #8011-38-40 Amount $500,000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 1320' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 3698'SW of DS 16-1 21. ELEVATIONS (Show whether DF, RT, CR, etc.) Tundra 34' Pad 39' RKB 72' 16. No. OF ACRES IN LEASE · 2512 ' 19, PROPOSED DEPTH 10917' MD ( Da turn MS L) 17. NO,ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START da~luary 5, 1981 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94# H-40 110' MD 300 sx Permafrost II to surface 17½" 13-3/8" 72# N-80 2700"MD 2300 sx Fondu + 400 sx PF II to 1.2~" 9-5/8" 47# L-80 10115' MD 500 sx Class G cmt - 1st sta~e S0095 300 sx Permafrost II - 2nd stage 8½" 7" 29# L-80 9800-10917 350 sx Class G cmt - cover lap urf. Atlantic Richfield Company proposes to directionally'drill this well to 10917'MD (9474'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. The Sadle- -]~gchi~ will be conventio_n~ A 13-5/8" 5000 psi RSRRA BOP stack will be instal)ed and teste--~3--E6-'50~~**~--The BOP equipment will be pressure tested each week and operation- ally tesi~ed each trip. A string of 5½" 17# L-80 tubing, packer and necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all un- cemented annuli within the permafrost interval. Selection intervals within the Sadlerochit to be perforated and reported on a subsequent report, a 5000 psi WP wireline lubricator, test to working pressure, will be used on all wireline work. The packer will be set above the Sadlerochit. The down hole safety valve will be tested and installed upon conclusion of _o.i b ..... m ABO~rE SPACE D~=~CRIBE PROPOSED PR~M-. If propo~ is to deepen ~ve ~ta on. print producQve zone and pro~d new produc~ve zo~If pro~ n to ~ or dee~n ~fion~y, ~ve ~ent da~ on sub.face locations ~d m~u~ ~d ~ue ~ ~ep~ ~lowout pr~enter pro~. 24.1 here~~hat ~.For~e ~me,dd.~t . ---- SIO~D~~' ~~~ DA~ /~/~O ~TLE Dist. Drilling Eng. (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: I SAMPLES .~ REQUIRED MUD LOG ~s ~LNo ] [] Y~S J~LNo DIRECTIONAL SURVEY REQUIRED ~l.~s [] NO PERMIT NO ~ ~ - /~O APPROVAL DATE ~¥ O[i2R'~- 'H~ ~O~"`$$[O*l~ee Instruction On OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE .5.~0- o 'u?- 'z. 03%"?' AW_ _~m_l?~_~' 1 2; 19R0 DATE 12/1 "-'~ ARCO OIL lIND GR$ ~ ...... i ................. .... r,, ....., .., .... :. ''' ~ ' ' - ~ * · · t ..... ' ..... ~ ..... ' ' ' ! ............ DS I6~ WELL NO:i'2 'PROPOSED .... -~ ....... ~ 5CRLE !1 IN. = 1000 FEET · .? ........ PRUDHOE BRY, NORTH SLOPE, RLRSKR : : "L."' . ......................... 'L ................................ ~_-" .--j__L_L2j , ~ --~--. ' " .... i" .... '" ............. ' ...... . i .......... ~.. ~ . . ~ i .......... I ......... ; ........-j ............. ~ .... ! ........ ~' ............ ' .......; .................. ~ ............... i- .........._.____~ ..... ' ........' ...... AVERAGE. ANGLE.'.: 3'7 DES 5- "~ _ iL_i~!...'..L2~L.i ............. i2~£.L~iLL~ L :::'.'.:::::_-~.:-.;_~.: ......... ~ .... ~ -TARGET .... DEP,.40O9 . . ......... jT .......... ~- ............ '&N'46 DE~ 53 HiN E .......................... F .............. l .......... ~------ ..... J-- I ........... T¥~i,,8~5:) fl~O,,9511 n£p,3615 i ._.¥.-_-:I_--~_: .:_~ ........ ~- ......... { ........... i ...... ..... DEP=~Te9 : TVI~8'702 T1~1.9949 DEP-~80 ................................ ~ ........ .................... ~ ........ ~ ......... I .......... ~ ...... ~--[ : qRGET TVD=8872 TI"ID=IOI63 DEP=4009__ ' ............ . ....... .._:f_~_- .... ~_.?._-:_-j~:.:-.'.-. ...... : ......... I ..... : .... ' ......... ? ........... ~ ................ .0~8 _OEP=4094_.__- ' ............................. _L_-- ~-: .... 900OLL~ .................. i-: ..... ~ ..................... ~ ........ -_[ ........................ , ............. , ..... ~ ................ i- ....... OI4C TVl}.gt 4'/ THi3, 1050'/ BEP-4~,'/ ..... ............ L .............. : ....... ~ ............' ....... : ............... ~ ........ i ' ! ~ ..... ---t' ..... i .......... '- - I ..... I .... ~ ..... ' 'I' X BRSE ~ TVD-9~{2 .'"-? .......................... [ ............. ~' -'i ......... _.L_~L'"'L~7__~L_~_L-L_L -TD -TVD=9474-THD=1091-/ DEP=4463 ' {' ....................... ~ - { -' : ! ...... ~' '' l ............ f ...... ; LI. ~. E TVD=964a l~lila8 OEPff4591._ -::r:;::-:-~- --:-----:: -:---:';::!-::::: I-: :':--:--~": ::':: i- :- '-:: -'- ;-:;:--:;:: ~ ;-':': ':;;; :: ;-:-:-i-:':":-:' !"'-:'-:'i"i'~ ---:'::' :--'i":--i..: ._" --!._::'-i..i':-': "" ':;-!-':::_-:::L:; ::;i: "':'-': '-'" .... ' : ...... I , ' ' - - - I .... : .... ..... : .......... ................ :O: .................... ~ ....... ' .................. ~ ...... f--' :-7:: .--?--: ....... : ...... ."1000 .......... ;~000 ' ~ ' ' 3000 --'! ;4000. ' ' 5000 - - · ~ .............. ~ ................. i .... - ...... , ...... i .... ~ .......... ....... ~ ...... VERTICRI-:-SECTION - : ] --' ~ ~' ' _ [' '. ._~._.~.---.-.'T-i'~-- :.-_-~- ~--'F[ '-T/. . . ; _ ............. ', ................. ; ........... : .... i' ''= .... ~ .... : ...... ~ : .................... : ''':' '' ~ .......... ~ .... ~- ......... ~ ............... ~ ............... ~ ..... t ............ ,L ........ ~ .........+ .... -- { -"-~ ................. T ................ i ....... ~- .......~ ........... + .................. ' ..........'.. L_'..._[ __' _i_-L_: ....i : -- - t ........ EASTIIRN I, IHIPSTOCK,~ INC. i ......... ~ .......... J- ~- ~ i' ~ ............ '~'_-~ 300 .... i...i..i~::.~o.o~ ~:~:.~: :--boo. '~.~ur ..... : 20o ?; ~--~';-~too -:- .~:~ o .... :' ~. r :~ ~[oo - :.: ~oo ' ~ ~ ~ .... ~/~_LE ...... ~ ......................... ~ ................... ......................................... t ........................................... I ........................ ~ .............. ................. h ............... ................. ~ ............... i .............. ~--.: .............. ~ ................. .~ ............... L*x ............ ~ ............................. ~ ............. [ .31g5 j . i L----~ ...... u .................... ~ ......~ ............ I .............. ~ ............ ~ ..... :t.--J ....~_U .......... ~ ....... ~._.~_u .............................. [ . _ ...... ~ ............ i ......... 1 : ....... ~ :'J ..... : I'----:"r---'f .......... ......... ~ ...... i ~ ....., .......... ~ ........... ........................................... ~ ............................ ~ ........ : ....... ~ .............. ~ ..... ' ......... f ............. t ...... :"-*':-F*u-: ....... F':-': ....... :"f ......... i LLi L~ L~'_.~ ZZZ' r ...... ' .......... - .. L-Z ~ ................ - ............... J .......................... ~ ........... ::::::::::::::::::::::::::::::::::: ....... . ........ { .......... ' .... eLIND RR~S ¢) P!PE RRHS ! SPOOL . . e e 13-5/8" qP STACK DIAGRAM Accumulator .CapaCi.ty Test le 2, Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time,then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. Record on' IADC report. (The acceptable lower limit is 45 seconds closing time and l~J~O psi remaining pressure.) 13-5/8" BOP STACK TEST Fill BOP stack and manifold with Arctic Diesel or Calcium Chloride Solution. Check that all hold down screws are fully retracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws i n head. PIPE RRHS e 5~ Close annular preventer and chokes and bypass valves on manifold. Test all components to 250 psi and hold for 10 ~linutes. Increase pressure to 3000 psi and hold for minutes. Bleed pressure to 500 psi. Ge t Close top set of pipe rams and open annular preven]ter · - Increase. pressure to 5000 psi and hold for 10 minutes. Bleed pressure to 500 psi. e Close bottom set of pipe rams and valves directly upstream-of chokes, then open top set of pipe rams and chokes. Increase pressure to 5000 psi and hold for 10 minutes. Test' remaining untested manifold valves(if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 10 min. 11. Bleed pressure off all equipment open bh.~l I £mqs. i Make sure manifold & lines are full or' Arctic Diesel and all valves are set in drilling position. psi - Max. anticipated Bottom Hole Pressure' psi -Max. pressure to which :BOP's could be subjected. Calculated by allowing a gas bubble at reser- 12. Test standpipe valves to 5000 psi. -- 13. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 14. ~ Check operation of De Gasser. voir pressure to rise w/o 15. Record test information on Blowout preventer expanding but cooling to 80OF. test form. Sign and send to Drilling Supervisor. 16. Perform complete BOPE test once a week and functional operate BOPE daily. /¢ T/OM, RISE, · 1, X i ~,~'.~: :~' .. X = 719:~,~9x 6. Y = 5,929~055.05 2~ Y = 5,929,524.77 X = 719,810~53 X = 719,911~44 LAT = 70°12 ~35~782'' LAT = 70°12~31~135" LONG = 148°13:38~425'' LONG = 148°13~35~893'' I HEREBY CERTIFY THAT I AM 3. Y = 5,929,407~32 PROPERLY REGISTERED AND LICENSED X = 719,835~80 TO PRACTICE LAND SURVEYING IN LAT = 70°12~34~620'' THE STATE OF ALASKA AND THAT LONG = 148°13~37~790'' THIS PLAT R~PRESENTS AN AS~-_ OF~~ BUILT SURVEY HADE BY HE, ~."" A ~. Y = 5,929,290o09 T~tA.T ALL DIHENSIONS AND ~A"'"' X = 719,861 .18 EAT = 70o12z33~60,., DETAILS~RE CORRECT,-A'S~%~9~ ~ LOHC = 1~8°13'37 lS3" DATE ~'~,~ ..... ~,.' ~'"~ ....... ~ ....... %/"'~ ....... ,'~,','~' -. ....... ~ , . i i iii i L II I · III AtlanticflichfieidCompany ~ DATE' D~AWING No: NO~T.H AMEriCAN P~ODUCING DIVISION /~~ ALASKA DIST~iCT - P~UDHOE BAY , ,,~,,,, , t ~ i CP~CK LIST FOR NEW ;~LL PERMITS Company Item Approve Date Yes (1) Fee ~~~.~ is the permit fee attachedis well to be located in a defined ........ (2) :Loc. 9//.,,~--, (3) Admin.~f/~. ! (4) Cas.,g. ~~ (5) BOPE ~~ Additional Requirements: No 3. Is a registered survey plat attached ................................ , ~/~- property line ........ ~ ~J ! ¢-t U'~_~ 4. Is well located proper distance frcm .......... ./~ _ ~'5. Is well located proper distance frcm other wells ................... '.~ . 6. Is sufficient undedicated acreage available in this pool ............ '~ 7. Is well to be deviated .............................................. ~ 8. Is operator the only affected party "~'"i''"''i 'i i .... ii i ''''''''' .... '/~'~ 9 Can permit be approved before ten-day i' i i '' ~ %q~-F~ 10. Does operator have a bond in force ............... ,,. ~'11. Is a conservation order needed ...................................... ~ 12. Is administrative approval needed ................................... ,. 13. Is conductor string provided. ...................................... 14. Is enough con~nt used to circulate on conductor and surface ....... /~xo~15.,. Will c~nent tie in surface and intermediate or Production strings 16. Will cement cover all known productive horizons ................... 17. Will surface casing protect fresh water zones .... ~' '~n' 'an~'~~.~~~ 18. Will all casing give adequate safety in collapse, si /2-~-~)19. Does BOPE have sufficient pressure rating - Test to 6'~DC)c3 psig ' Approval Reccmmended: Lease & Well No. Remarks Geology: Engi~,~..~ ~g: ~' _J~_ LCS ~' BE~~ / rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special'effort has been made to chronologically organize this category of information. .o V 0.~ c-. LIBRARY TAPE ~'~ ~ ~ CURVE SPECIFICATIONS Company' ........ ^rco' Oil ~ Gas Co. Well DS 16-2 Field Prudhoe Bay County,State North Slope, Alaska Date 2-27-81 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale ~ G_R . Gamma, Ray CNL/MS ,, 0-!00 .'SS ....... Short Spac,e ..... CNL/MS 0_2000 LS Lon~ ,,Spa,ce ~ CNL/MS "i. 0-2000 ...NEU ~. ... C.ompensated Ne.utron CN.,L/M~ ' 60-0 ............ .... ........ CUR LE"EL SPACTNG 0,5000 ~AGE 1. ARCO OIL & GAS- .... P.S. 16-2 HLAC 6?66 PRUDHOF BAY ..... ~!OR'TH SLOPE, ALASKA DATA EVERY I SA~D~£S 9707.00 8~80 9709.00 96.10 845 ~ 971~,00 98.17 8~8,23 82B.~2 971 971~ 971~.00 72 971, 971, O0 G6 9717.00 62 56 952 77 07 971 OO 6 $2 952 'PAGE 2 ARCO OIL & GAS'-'''D.So PRUDHOE BAY ..... NORTH SLOPE, ALASKA DATA EVERY I SADDLES 16-2 HLiAC 676.6 9728~50 51,~6 1055,86 88~.56 9729.50 ~2.~ 1170,13 910,23 973~.50 22.68 1335~3~ 955,~6 9751,50 3.5~ 1233,78 986,03 9732.50 6.22 1100.37' 938,..35 9733.50 13.~1 1017.1~ 8~5.5~ 9734.50 29.76 9~1.25 867.~4 48,38 97:35.50 59,88 895.96 857,66 I+3, q. 9 9736.50 65,73 R8~,95 9737 50 9738 50 9739.50 ~7q.O 97~1.50 55, 25. 42,03 97~e.50 61.83 798,0~ 808.77 ~7,~6 97~3.50 79.7G 80~.16 789.21 97~.50 75,73 859.2~ 805.10 ~2,91 97~o50 65.37 883.72 831.99 .............. .9~Z~ ............ 6~.~88 _~_6.~,o~ 9.?.~ 8, 0..0 ......... 7!....,._..8_...3_ ....... _88_.0_.._0_5 .......... 82_..~_,66_ ............. _4_~ 36 ........... _~..7_~8__,_5_0._ .......... 7._?_,...~.2 ....... _8._.?__~ 51 8 ~ 7,32 ~ 4,38 9_7 q- 9?_0_...0_. .7.!.., .9._5 ..... 9.0_6 ..9._B_ ........... ..8_t_~.,._8_._~ ........ ~_~__6_,.7} ............................................................... ?~ .......... 9_Z_~__9_LS__O_ ........... .7..~..,..~_5 .......... _9_._2_2., 8 9 8 t 2. ~ 3 ~ 8.6 o ............ _?_75_..0__,_5__Q ........ Z2__,.8_o ...... 9_D..2._~ ~ ~ 822,2 z 5 o, q o ~AGE ~- ARCO OIL DRUDHOFT RAY ..... NORTH SLOF~E,ALASKA F '- DATA _V~:.RY I SAMPLES 16-2 HLAC 67 ~,.6 9 7 ? 9, ..5...0_ ...................... ..5.......8_..,.~...~ ....... ~._9._.~ 978! .50 52.9~ 902,08 8~>5.88 9782.50 53o.t7 90~,53 8.~0,.77' 9783.50 51.~+6 910,.65 8q. 1-.77 978~q.. 50 50.00 9785°50 ~9.76 919.22 831.99 ~7.06 978F-,,50 q.G.22 927,78 830.77 q-7,02 9787.50 ~$,66 9~L7,99 8R~.66 ~8.86 q, 2 20 97~9.50 9790.50 9791.50 9792.50 ~8 9794.50 51.~G 903 10 ~5.99 PAGE: ~ ARCO OIL .~ GAS-----D.S. 16-2 HLAC 6766 PRI!DHOF BAY ..... NORTH SLO~E,ALASK.A DATA E~iERY :t SAi~IDLES 97 97& O0 ~ 73 969 8¸8 9761.00 58.54 985,51 8~7 89 49 7 ~ 97& O0 55 85 988 98 8 976 976 9765.00 976& 976' .............. ._9___7_Z~.._.__o_.o_ ........... 6.%.,_6:.s_ ....... ..9_o_.~_,_.5_~_ .... 9 ..7.7.3., 5.0 ....... 6 ~..,_.6_8 ......... ~_9.~ ............. ? .7.7 ~__.,._0..o_. ......... _6...2.._,_6¢. ........... ._8..?._9_~__6~ 977~ ,_.50 62., :52 ............... ~.TZ~_.._..O__O_ ........... .6_!_,.~ .......... .9_.T7 ~.,_5o. ...... 60_..,6..1 ...... _8..9._ .............. 97_Z6__-.___0_0__. __ :5_9__.._2__7_ ...... ........ .!RECEIVED' DEC 1 $1996 * ALASKA COMPUTING CENTER * * . ****************************** * ............................ . * ....... SCHLUMBERGER ....... * * ............................ . ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : D. S. 16-02 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20544-00 REFERENCE NO : 96352 * ALASKA COMPUTING CENTER * ****************************** . ............................ . ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : D. S. 16-02 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-20544-00 REFERENCE NO : 96352 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/12/ 9 ORIGIN : FLIC REEL NAME : 96352 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, D.S. 16-02, PRUDHOE BAY, 50-029-20544-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/12/ 9 ORIGIN : FLIC TAPE NAME : 96352 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 16-02, PRUDHOE BAY, 50-029-20544-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D. S. 16-02 API NUMBER: 5002920544 O0 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 9-DEC-96 JOB NUMBER: 96352 LOGGING ENGINEER: R. WALSH OPERATOR WITNESS: K. ST. GEM~E SURFACE LOCATION SEC TI ON: 24 TOWNSHIP: 1 ON RANGE: 15E FNL: FSL: 420 FEL: FWL: 1034 ELEVATION(FT FROM MSL O) KELLY BUSHING: 72. O0 DERRICK FLOOR: 71. O0 GROUND LEVEL: 34. O0 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 10087.0 47.00 7.000 10790.0 29.00 5.500 9756.0 17.00 4.500 9819.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 26-JAN- 81 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 10443.5 10440.0 10430.0 10425.0 10406.5 10405 5 10363 5 10337 0 10323 5 10301 0 10300 5 10293 0 10287 0 10280.0 10271.0 10255.0 10252.0 10250.5 10244.5 10236.0 10235.5 10217.0 10205.0 10203.5 10200.5 10182.0 10166.5 10162.0 10136.5 10129.0 10107.5 10083.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88887.5 88888.0 10429.5 10422.5 10405.5 10362.0 10322.0 10300.5 10294.5 10279.5 10254.5 10251.5 10244.5 10235.5 10217.0 10207.5 10200.0 99.5 10443.5 10440.0 10405.5 10338.0 10300.5 10289.0 10279.5 10272.5 10251.5 10235.5 10203.5 10181.0 10166.0 10161.0 10136.0 10130.5 10110.0 10084.0 101.0 REMARKS: This tape contains the cased hole edit for Arco Alaska well D.S. 16-02 TDTP/Borax. There are two baseline passes, four borax passes and an average pass. There are also 6 raw data files. **NOTE** The naming convention for the borax passes is different than the blueline. On the tape, the borax passes are named in the actual order that the passes are run. On the blueline the passes were labeled upper passes and lower passes. The depth adjustments shown above reflect cased hole GR PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 to open hole BCS GR and cased hole SIGM to open hole GR. All other TDTP curves were carried with the SIGM shifts. The gamma ray is from BCS GR 26-Jan-81. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10438.0 9700.0 TDTP 10460.0 9700.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REFLARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA No LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: ** 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 1I 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 I 1 1 4 68 0000000000 DEPT FT 500589 SIGM TDTP CU 500589 O0 000 O0 0 1 1 1 4 68 TPHI TDTP PU-S 500589 O0 000 O0 0 1 1 1 4 68 SBHF TDTP CU 500589 O0 000 O0 0 1 1 1 4 68 SBHN TDTP CU 500589 O0 000 O0 0 1 1 1 4 68 SIGC TDTP CU 500589 O0 000 O0 0 1 1 1 4 68 SIBH TDTP CU 500589 O0 000 O0 0 1 1 1 4 68 TRAT TDTP 500589 O0 000 O0 0 1 1 1 4 68 SDSI TDTP CU 500589 O0 000 O0 0 1 1 1 4 68 BACK TDTP CPS 500589 O0 000 O0 0 1 1 1 4 68 FBAC TDTP CPS 500589 O0 000 O0 0 1 1 1 4 68 TCAN TDTP CPS 500589 O0 000 O0 0 1 I 1 4 68 TCAF TDTP CPS 5b0589 O0 000 O0 0 1 1 1 4 68 TCND TDTP CPS 500589 O0 000 O0 0 1 1 1 4 68 TCFD TDTP CPS 500589 O0 000 O0 0 t I 1 4 68 TSCN TDTP CPS 500589 O0 000 O0 0 1 1 1 4 68 TSCF TDTP CPS 500589 O0 000 O0 0 1 1 1 4 68 INND TDTP CPS 500589 O0 000 O0 0 1 1 1 4 68 INFD TDTP CPS 500589 O0 000 O0 0 1 1 1 4 68 GRCH TDTP GAPI 500589 O0 000 O0 0 1 1 1 4 68 TENS TDTP LB 500589 O0 000 O0 0 1 1 I 4 68 CCL TDTP V 500589 O0 000 O0 0 I 1 1 4 68 GR BCS GAPI 500589 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: ** DATA ** DEPT. 10780. 500 SIGM. TDTP SBHN. TDTP -999. 250 SIGC. TDTP SDSI. TDTP -999. 250 BACK. TDTP TCAF. TDTP - 999 . 250 TCND . TDTP TSCF. TDTP -999. 250 INArD. TDTP TENS. TDTP -999.250 CCL. TDTP DEPT. 9699. 500 SIGM. TDTP SBHN. TDTP -999. 250 SIGC. TDTP SDSI. TDTP -999. 250 BACK. TDTP TCAF. TDTP -999. 250 TCND. TDTP TSCF. TDTP -999. 250 INND. TDTP TENS. TDTP -999.250 CCL. TDTP -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 TPHI.TDTP SIBH. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP GR.BCS TPHI.TDTP SIBH. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP GR.BCS -999 250 -999 250 -999 250 -999 250 -999 250 89 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 SBHF. TDTP TRA T. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP SBHF. TDTP TRA T. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 67.188 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 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 INCREMENT: 0.5000 FILE SUM~IARY LDWG TOOL CODE START DEPTH GRCH ~ 10434.0 TDTP 10450.0 STOP DEPTH .......... 9700.0 9700.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PA GE: $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 10445.5 10439.5 10423.0 10421.5 10419.0 10407.5 10406.0 10394.0 10393.0 10383.5 10366.5 10360.5 10338.0 10336.5 10334.5 10322.5 10315.5 10300.0 10299.5 10292.0 10287.0 10286.0 10281.5 10271.0 10266.0 10261.0 10260.0 10254.0 10250.0 10235.0 10234.5 10221.0 10212 0 10202 5 10197 0 10193 0 10191 0 10180 0 10168 0 10161 0 10146.0 10140.0 10128.5 10127.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88890.0 88889.0 10446.5 10440.0 10425.0 10422.5 10407.5 10394.0 10383.5 10365.5 10337.5 10333.5 10322.0 10314.0 10299.5 10294.0 10289.0 10279.5 10270.0 10266.0 10262.0 10254.5 10251.5 10235.5 10222.0 10213.5 10198.0 10195.5 10192.5 10181.0 10168.5 10161.5 10146.5 10127.0 10418.5 10405.5 10391.5 10361.5 10338.0 10300.5 10286.5 10262.0 10254.0 10235.5 10203.0 10140.0 10130.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 10110.0 10104.0 10100.0 10083.0 10082.0 10079.0 10074.0 10069.5 10066.0 10061.0 10057.0 10045.0 10040.5 10037.5 10027.5 10026.0 10010 0 10002 0 9994 5 9983 5 9964 0 9952 0 9940 0 9936.0 9925.0 9921.0 9913.5 9912.0 9909.0 9899.0 9893.5 9890.5 9884.5 9879.5 9873.0 9855.5 9840.5 9828.0 9824.0 9807.0 9803.5 9789.0 9786.0 9763.0 9758.0 9753.5 9747.5 9742.0 9732.0 9729.5 9716.0 9715.0 9709.0 100.0 $ 10110.5 10100.0 10083.5 10065.5 10045.0 10038.0 10027.5 10009.5 10002.0 9964.5 9940.5 9922.5 9914.0 9898.5 9889.0 9884.5 9873.0 9856.0 9824.0 9807.5 9803.5 9786.5 9763.5 9757.0 9754.0 9748.0 9731.5 9716.5 9708.5 99.5 10107.5 10083.5 10081.0 10076.0 10069.5 10064.0 10059.0 10042.0 10027.5 9996.0 9985.5 9960.0 9945.0 9934.5 9918.0 9913.0 9894.5 9881.5 9841.5 9830.0 9808.5 9789.0 9743.0 9731.5 9716.0 101.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: REMARKS: This file contains TDTP Pass #2 (Base Pass #2). The depth shifts shown above relect GRCH Pass #2 to GRCH Pass #1 and SIGM Pass #2 to SIGM Pass #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500589 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 500589 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 500589 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 500589 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 500589 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 500589 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 500589 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 500589 O0 000 O0 0 2 1 I 4 68 0000000000 SDSI TDTP CU 500589 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 9 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) TSCN TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 500589 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 500589 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 500589 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 500589 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10451.000 SIGM. TDTP 14.056 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999. 250 SIGC. TDTP - 999. 250 SIBH. TDTP -999 . 250 TRAT. TDTP -999. 250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS. TDTP -999. 250 CCL . TDTP - 999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 10 DEPTH INCREMENT: 0.5000 FILE SU~FLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9906.0 9700.0 TDTP 9940.0 9700.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 9924.5 9911.0 9903.5 9899.5 9892.0 9886.0 9885.5 9882.0 9878.5 9873.5 9871.0 9866.0 9861.0 9859.5 9853.0 9852.0 9849.0 9842.0 9839.0 9838.5 9836.0 9827.0 9826.5 9820.0 9819.0 9804.5 9800.5 9795.0 9791.0 9785.5 9784.0 9781.0 9774.0 9766.5 9761.5 9760.5 9759.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88891.0 88893.0 9895.0 9889.0 9886.0 9873.0 9863.0 9860.5 9856.0 9852.0 9841.5 9830.0 9824.0 9807.0 9803.5 9797.5 9786.5 9778.0 9769.0 9763.5 9929.5 9918.0 9909.5 9905.0 9891.5 9884.0 9877.0 9871.0 9858.0 9848.5 9841.0 9840.0 9831.5 9823.5 9796.0 9789.0 9782.5 9765.0 9761.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 11 9747.5 9750.0 9744.0 9748.5 9742.0 9745.5 9738.0 9743.0 9735.5 9738.0 9718.5 9724.0 9714.5 9719.5 9710.0 9711.5 9705.5 9708.5 9705.0 9709.5 9703.0 9706.0 9701.0 9704.0 100.0 103.0 103.0 $ REMARKS: FILE LABELED BORAX PASS #1 UPPER SECTION ON BLUE LINE. This file contains Borax Pass #1 of the TDTP. The depth adjustments shown above reflect Borax Pass #1 GRCH to Base Pass #1 GRCH and Borax Pass #1 SIGMA to Base Pass #1 SIGMA. All other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 1i 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 9-DEC-1996 10:47 PAGE: 12 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500589 SIGM TDTP CU 500589 TPHI TDTP PU-S 500589 SBHF TDTP CU 500589 SBHN TDTP CU 500589 SIGC TDTP CU 500589 SIBH TDTP CU 500589 TRAT TDTP 500589 SDSI TDTP CU 500589 BACK TDTP CPS 500589 FBAC TDTP CPS 500589 TCAN TDTP CPS 500589 TCAF TDTP CPS 500589 TCND TDTP CPS 500589 TCFD TDTP CPS 500589 TSCN TDTP CPS 500589 TSCF TDTP CPS 500589 INND TDTP CPS 500589 INFD TDTP CPS 500589 GRCH TDTP GAPI 500589 TENS TDTP LB 500589 CCL TDTP V 500589 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 I 4 68 0000000000 O0 000 O0 0 3 I 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 I 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 I 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 i 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 I 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 ** DATA ** DEPT. 9945. 000 SIGM. TDTP 36. 831 TPHI. TDTP -999.250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 DEPT. 9700. 000 SIGM. TDTP - 999.250 TPHI. TDTP 44. 520 SBHF. TDTP SBHN. TDTP 81. 644 SIGC. TDTP O. 000 SIBH. TDTP 131 . 402 TRAT. TDTP SDSI. TDTP 2. 035 BACK. TDTP 163. 731 FBAC. TDTP 29. 002 TCAN. TDTP TCAF. TDTP 2340. 644 TCND. TDTP 7952. 535 TCFD. TDTP 2087.285 TSCN. TDTP TSCF. TDTP 176. 621 INND. TDTP 1467. 427 INFD. TDTP 249. 585 GRCH. TDTP TENS. TDTP 1620. 000 CCL. TDTP O. 000 -999.250 -999.250 -999.250 -999.250 -999.250 72.652 1.278 7090.511 499.029 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 13 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 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: O . 5000 FILE SUFm~a~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9906.0 9700.0 TDTP 9940.0 9700.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88891.0 88894.5 9927.0 9933.5 9917.5 9923.0 9914.5 9918.0 9903.5 9908.5 9891.5 9895.5 9886.0 9889.0 9882.5 9886.0 9879.5 9881.5 9877.0 9878.5 9872.0 9875.5 9877.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 14 9862.5 9870.0 9851.0 9853.5 9845.5 9848.0 9837.5 9841.5 9833.0 9839.5 9826.0 9830.0 9825.0 9829.5 9821.0 9824.0 9815.0 9819.0 9801.5 9804.0 9801.0 9805.0 9786.5 9792.5 9785.5 9789.0 9775.0 9783.0 9767.5 9772.5 9766.0 9769.0 9761.5 9763.5 9760.0 9765.0 9750.5 9754.5 9745.0 9749.0 9744.5 9748.0 9739.5 9742.5 9739.0 9743.0 9732.0 9737.0 9731.0 9734.5 9729.5 9731.5 9722.5 9723.5 9717.0 9720.0 9711.0 9715.0 9709.0 9711.5 9708.0 9711.5 9705.5 9708.0 9705.0 9709.0 100.0 102.5 104.0 $ REMARKS: REMARKS: FILE LABELED BORAX PASS #2 UPPER SECTION ON BLUE LINE. This file contains Borax Pass #2 of rhe TDTP. The depth adjustments shown above reflect Borax Pass #2 GRCH to Base Pass #1 GRCH and Borax Pass #2 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT I1 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500589 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 500589 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 500589 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNTDTP CU 500589 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 500589 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 500589 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 500589 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TCANTDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 500589 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 500589 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 500589 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 500589 O0 000 O0 0 4 1 I 4 68 0000000000 ....................................................................................... LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 16 ** DATA ** DEPT. 9946.500 SIGM. TDTP 40.492 TPHI.TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS.TDTP -999.250 CCL.TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFJMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10434.0 10200.0 TDTP 10450.0 10200.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 17 BASELINE DEPTH 88888.0 10443.0 10427.5 10407.0 10406 0 10392 0 10362 0 10353 0 10335 5 10334 5 10320 0 10306.5 10296.5 10291.5 10288.5 1 O285.5 10265.0 10261.0 10251.0 10249.5 10241.5 10234.0 10216.5 10212.0 10207.5 10202.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. 88890.0 88888.5 10429.5 10407.5 10362.5 10352.0 10333.5 10306.5 10291.5 10251.5 10235.0 10212.5 10208.0 100.5 10443.5 10405.5 10391.0 10337.5 10320.5 10298.0 10291.5 10287.0 10267.0 10263.0 10251.5 10242.0 10235.5 10217.5 10203.0 101.0 REMARKS: FILE LABELED BORAX PASS #1 LOWER SECTION ON BLUE LINE. This file contains Borax Pass #3 of the TDTP. The depth adjustments shown above reflect Borax Pass #3 GRCH to Base.Pass #1 GRCHand Borax Pass #3 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 18 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~f CODE (HEX) DEPT FT 500589 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 500589 O0 000 O0 0 5 1 I 4 68 0000000000 TPHI TDTP PU-S 500589 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 500589 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN TDTP CU 500589 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 500589 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH TDTP CU 500589 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 500589 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 500589 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 500589 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 500589 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 500589 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 500589 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10450.500 SIGM. TDTP 16.350 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP -999.250 TENS. TDTP -999.250 CCL. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 19 DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 10200 000 65 638 0 417 7239 342 1558 631 1745 000 SIGM. TDTP SIGC. TDTP BACK. TDTP TCND. TDTP INND. TDTP CCL. TDTP -999 250 1 096 170 584 14451 553 1404 489 0 000 TPHI.TDTP SIBH. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP 34. 971 SBHF. TDTP 94. 991 TRAT. TDTP 27. 373 TCAN. TDTP 4233 . 616 TSCN. TDTP 208. 019 GRCH. TDTP 46.216 1.909 18445.926 3971.409 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE ' FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: O . 5000 FILE SU~mlARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10424.0 10195.0 TDTP 10450.0 10195.0 $ CURVE SHIFT DATA - PASS TO PASS (R~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NU~IBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 20 BASELINE DEPTH .............. 88888.0 10439.0 10417.0 10408.5 10406.5 10405.5 10393.0 10374.0 10365.5 10353.0 10343.0 10335.0 10334.5 10332.0 10324.0 10313.5 10305.5 10299.0 10298.0 10291.0 10285.0 10279.5 10267.0 10253.0 10250.0 10249.0 10245.0 10239.5 10234 0 10219 0 10213 5 10211 5 10202 5 10201 5 10196.5 100.0 $ GRCH TDTP 88891.0 88889.0 10420.0 10410.5 10407.5 10394.0 10365.0 10352.0 10339.5 10333.5 10331.5 10322.0 10307.0 10302.0 10292.0 10279.5 10267.5 10251.5 10247.0 10241.0 10235.0 10220.5 10213.5 10207.5 105.0 10440.0 10405.5 10375.0 10337.5 10315.5 10300.0 10287.0 10254.0 10251.5 10235.5 10215.5 10203.0 10197.0 100.5 REMARKS: FILE LABELED BORAX PASS #2 LOWER SECTION ON BLUE LINE. This file contains Borax Pass #4 of the TDTP. The depth adjustments shown above reflect Borax Pass #4 GRCH to Base Pass #1 GRCH and Borax Pass #4 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 21 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 6 1 1 4 68 0000000000 FT 500589 CU 500589 O0 000 O0 0 6 1 1 4 68 0000000000 PU-S 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CU 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CU 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CU 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CU 500589 O0 000 O0 0 6 1 1 4 68 0000000000 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CU 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 I 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 CPS 500589 O0 000 O0 0 6 1 1 4 68 0000000000 GAPI 500589 O0 000 O0 0 6 1 1 4 68 0000000000 LB 500589 O0 000 O0 0 6 1 1 4 68 0000000000 V 500589 DEPT SIGM TDTP TPHI TDTP SBHF TDTP SBHN TDTP SIGC TDTP SIBH TDTP TRAT TDTP SDSI TDTP BACK TDTP FBAC TDTP TCAN TDTP TCAF TDTP TCND TDTP TCFD TDTP TSCN TDTP TSCF TDTP INND TDTP INFD TDTP GRCH TDTP TENS TDTP CCL TDTP O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 22 ** DATA ** DEPT. 10451 . 000 SIGM. TDTP 14.131 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP -999. 250 GRCH. TDTP -999. 250 TENS. TDTP -999. 250 CCL. TDTP -999. 250 DEPT. 10195. 000 SIGM. TDTP -999.250 TPHI. TDTP 40.274 SBHF. TDTP SBHN. TDTP 71. 322 SIGC. TDTP O. 269 SIBH. TDTP 107. 985 TRAT. TDTP SDSI.TDTP 4.219 BACK. TDTP 178.544 FBAC. TDTP 32.519 TCAN. TDTP TCAF. TDTP 794. 054 TCND. TDTP 8144. 236 TCFD. TDTP 1814. 646 TSCN. TDTP TSCF. TDTP 171. 063 INND. TDTP 1303. 525 INFD. TDTP 177.119 GRCH. TDTP TENS. TDTP 171 O . 000 CCL . TDTP O . 000 62. 983 1. 582 2609. 833 562. 237 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * FILE HEADER * * * * FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001 CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP 1, 2, $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 23 REMARKS: The arithmetic average of passes 1 & 2 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 80 4 66 1 5 66 ~ 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE Cl...~SS MOD NUlVlB SAMP ELi~ CODE (H.~t~) DEPT FT 500589 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PNAV CU 500589 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 500589 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PNAV CU 500589 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPNAV CU 500589 O0 GO0 O0 0 7 1 1 4 68 0000000000 SIGC PNAV CU 500589 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PNAV CU 500589 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 500589 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PNAV CU 500589 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPNAV CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPNAV CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPNAV CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PNAV CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 TSCNPNAV CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PNAV CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape VerificaTion Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 24 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INND PNAV CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PNAV CPS 500589 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 500589 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10460.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI. PNAV -999.250 BACK. TDTP 45.255 FBAC. TDTP 14.034 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 DEPT. 9699. 500 SIGM. PNAV -999. 250 TPHI. PNAV -999. 250 SBHF. PNAV -999. 250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP 67.188 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 25 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE VENDOR TOOL CODE START DEPTH TDTP 10473.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : STOP DEPTH 9695.0 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 ......................... TDTP GAMMA RAY SOURCE TDTP PROD. SONDE CARTRIDGE TDTP TDTP DETECTOR CART. 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): 19-NOV-96 CP 42.2 1235 19-NOV-96 10450.0 10456.0 9700.0 10449.0 1800.0 NO TOOL NUMBER ........... CGRS 863 CPLC 867 TDIC 8337 10087.0 SEAWATER/BORAX 8.60 15.0 THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 26 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 R~IARKS: This file contains raw data from baseline pass #1. TIED INTO SWS BHC DATED JAN-26-1981 ALL PASSES LOGGED AT 30 FPM WHILE PUMPING 2 BPM ONLY LOGGED TWO BASELINE PASSES BECAUSE TOOL STICKING PUMPED 660 BBL TOTAL SEAWATER AND 204 BBLS BORAX LOG INDICATES THAT THE LINER IS NOT LEAKING AT THE TOP NOR BOTTOM BOREHOLE SIGMA INDICATES THAT BORAX IS LEAVING CASING AT BOTTOM OF THE PERFS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500589 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS1 CU 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS1 PU 500589 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS1 CU 500589 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 27 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBHNPS1 CU 500589 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS1 CU 500589 O0 000 O0 0 8 1 I 4 68 0000000000 SIBH PS1 CU 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS1 500589 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS1 CU 500589 O0 000 O0 0 8 1 I 4 68 0000000000 BACK PS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TCANPS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TCND PS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 INNDPS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 INFD PS1 CPS 500589 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS1 LB 500589 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS1 GAPI 500589 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS1 V 500589 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10473.000 SIGM. PS1 22.725 TPHI.PS1 0.000 SBHF. PS1 SBHN. PS1 74.559 SIGC. PS1 0.000 SIBH. PS1 86.932 TRAT. PS1 SDSI.PS1 5.169 BACK. PSI 12.838 FBAC. PS1 12.433 TCAN. PS1 TCAF. PS1 0.000 TCND. PS1 -170.102 TCFD.PS1 -148.127 TSCN. PS1 TSCF. PS1 0.000 INND.PS1 -0.436 INFD. PS1 -0.423 TENS.PSI GR.PS1 33.625 CCL.PS1 0.021 DEPT. 9695.000 SIGM. PS1 41.969 TPHI.PS1 66.890 SBHF. PS1 SBHN. PS1 57.861 SIGC.PS1 1.301 SIBH. PS1 77.449 TRAT. PS1 SDSI.PS1 1.151 BACK. PSi 106.962 FBAC. PS1 21.956 TCAN. PS1 TCAF. PS1 4823.177 TCND. PS1 13678.027 TCFD. PS1 3133.538 TSCN. PS1 TSCF. PS1 303.229 INND.PS1 1395.797 INFD.PS1 238.810 TENS.PSi GR.PS1 69.313 CCL.PSl 0.000 101.685 0.000 0.000 0.000 1275.000 46.157 1.771 19622.016 1119.143 1480.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 28 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE i~JMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SU~9~RY VENDOR TOOL CODE START DEPTH ........................... TDTP 10469.5 $ LOG HEADER DATA STOP DEPTH .......... 9694.5 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 ......................... TDTP GAMMA RAY SOURCE TDTP PROD. SONDE CARTRIDGE TDTP TDTP DETECTOR CART. $ 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 T~PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : 19-NOV-96 CP 42.2 1259 19-NOV-96 10450.0 10456.0 9700.0 10449.0 1800.0 NO TOOL NUMBER ........... CGRS 863 CPLC 867 TDIC 8337 10087.0 SEAWATER/BORAX 8.60 15.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 29 FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: This file~contains raw data from baseline pass #2. TIED INTO SWS BHC DATED JAN-26-I981 ALL PASSES LOGGED AT 30 FPM WHILE PUMPING 2 BPM ONLY LOGGED TWO BASELINE PASSES BECAUSE TOOL STICKING PUMPED 660 BBL TOTAL SEAWATER AND 204 BBLS BORAX LOG INDICATES THAT THE LINER IS NOT LEAKING AT THE TOP NOR BOTTOM BOREHOLE SIGMA INDICATES THAT BORAX IS LEAVING CASING AT BOTTOM OF THE PERFS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 I 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 3O TYPE REPR CODE VALUE .............................. 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 500589 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 500589 O0 000 O0 0 9 I 1 4 68 0000000000 SBHF PS2 CU 500589 O0 000 O0 0 9 1 1 4 68 0000000000 SBHN PS2 CU 500589 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS2 CU 500589 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS2 CU 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 500589 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS2 CU 500589 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TCANPS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TCND PS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 INNDPS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS2 CPS 500589 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS2 LB 500589 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 500589 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 500589 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 10469.500 SIGM. PS2 41.969 TPHI.PS2 66.890 SBHF. PS2 SBHN. PS2 57.861 SIGC. PS2 1.301 SIBH. PS2 77.449 TRAT. PS2 SDSI.PS2 1.151 BACK. PS2 106.962 FBAC. PS2 21.956 TCAN. PS2 TCAF. PS2 4823.177 TCND.PS2 13678.027 TCFD. PS2 3133.538 TSCN. PS2 TSCF. PS2 303.229 INND.PS2 1395.797 INFD. PS2 238.810 TENS. PS2 GR.PS2 77.125 CCL.PS2 0.017 DEPT. 9694.500 SIGM. PS2 45.001 TPHI.PS2 73.729 SBHF. PS2 SBHN. PS2 58.351 SIGC.PS2 0.000 SIBH. PS2 78.560 TRAT. PS2 SDSI.PS2 1.269 BACK. PS2 144.801 FBAC. PS2 28.057 TCAN. PS2 TCAF. PS2 4918.240 TCND.PS2 13770.615 TCFD.PS2 3110.038 TSCN. PS2 TSCF. PS2 275.350 INND.PS2 1372.335 INFD. PS2 224.941 TENS.PS2 GR.PS2 80.500 CCL.PS2 0.000 46.157 1.771 19622.016 1119.143 1665.000 52.135 1.854 20113.703 1156.297 1470.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 31 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SU~WlARY VENDOR TOOL CODE START DEPTH ........................... TDTP 9940.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 9694.0 19-NOV-96 CP 42.2 1406 19-NOV-96 10450.0 10456.0 9700.0 10449.0 1800.0 NO TOOL NUM~ER LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 32 TDTP TDTP TDTP $ GAMFiA RAY SOURCE PROD. SONDE CARTRIDGE TDTP DETECTOR CART. CGRS 863 CPLC 867 TDIC 8337 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 10087.0 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) : SEAWATER/BORAX 8.60 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE CO~ RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REFiARKS: This file contains raw data from borax pass #1. Blueline labeled as borax pass #1 upper section TIED INTO SWS BHC DATED JAN-26-1981 ALL PASSES LOGGED AT 30 FPM WHILE PUMPING 2 BPM ONLY LOGGED TWO BASELINE PASSES BECAUSE TOOL STICKING PUMPED 660 BBL TOTAL SEAWATER AND 204 BBLS BORAX LOG INDICATES THAT THE LINER IS NOT LEAKING AT THE TOP NOR BOTTOM BOREHOLE SIGMA INDICATES THAT BORAX IS LEAVING CASING AT BOTTOM OF THE PERFS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 33 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 10 1 1 4 68 0000000000 DEPT FT 500589 SIGM BX1 CU 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI BXI PU 500589 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF BX1 CU 500589 O0 000 O0 0 10 1 1 4 68 0000000000 SBHN BX1 CU 500589 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC BX1 CU 500589 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH BX1 CU 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT BX1 500589 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI BX1 CU 500589 O0 000 O0 0 10 1 1 4 68 0000000000 BACK BX1 CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC BX1 CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TCANBX1 CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF BXl CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TCNDBXl CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TCFDBX1 CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN BX1 CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF BX1 CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 INNDBX1 CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 INFD BXl CPS 500589 O0 000 O0 0 10 1 1 4 68 0000000000 TENS BX1 LB 500589 O0 000 O0 0 10 1 1 4 68 0000000000 GR BX1 GAPI 500589 O0 000 O0 0 10 1 1 4 68 0000000000 CCL BXl V 500589 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 34 ** DATA ** DEPT. 9940.500 SIGM. BX1 SBHN. BX1 84.353 SIGC. BX1 SDSI.BX1 2.550 BACK. BX1 TCAF. BX1 1651.269 TCND.BX1 TSCF. BX1 134.966 INND.BX1 GR.BX1 474.250 CCL.BX1 DEPT. 9694.000 SIGM. BX1 SBHN. BX1 83.520 SIGC.BX1 SDSI.BX1 1.865 BACK. BX1 TCAF. BX1 2369.961 TCND.BX1 TSCF. BX1 163.508 INND.BX1 GR.BXI 107.188 CCL.BX1 36.831 TPHI.BX1 1.296 SIBH. BX1 331.797 FBAC.BX1 7888.870 TCFD.BX1 1502.130 INFD.BX1 0.021 40.492 TPHI.BX1 1.487 SIBH. BX1 168.224 FBAC.BX1 7682.550 TCFD.BX1 1458.383 INFD.BXl 0.000 67.885 137.547 496.831 1368.175 259.747 44.586 135. 658 28. 629 2043. 035 233. 820 SBHF. BXi TRA T. BX1 TCAN. BX1 TSCN. BX1 TENS. BX1 SBHF. BX1 TRAT. BX1 TCAN. BX1 TSCN. BX1 TENS.BX1 70.297 1.839 6565.720 607.492 965.000 64.989 1.319 7850.452 483.152 1640.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER 11 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 SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... TDTP 9941.0 9691.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 35 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): 19-NOV-96 CP 42.2 1449 19-NOV-96 10450.0 10456.0 9700.0 10449.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP GAMPLA RAY SOURCE TDTP PROD. SONDE CARTRIDGE TDTP TDTP DETECTOR CART. $ TOOL NUMBER ........... CGRS 863 CPLC 867 TDIC 8337 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) .. 10087.0 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) : SEAWATER/BORAX 8.60 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: This file contains raw data from borax pass #2. LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 36 Blueline labeled as borax pass #2 upper section. TIED INTO SWS BHC DATED JAN-26-1981 ALL PASSES LOGGED AT 30 FPM WHILE PUMPING 2 BPM ONLY LOGGED TWO BASELINE PASSES BECAUSE TOOL STICKING PUMPED 660 BBL TOTAL SEAWATER AND 204 BBLS BORAX LOG INDICATES THAT THE LINER IS NOT LEAKING AT THE TOP NOR BOTTOM BOREHOLE SIGMA INDICATES THAT BORAX IS LEAVING CASING AT BOTTOM OF THE PERFS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ...................................... T ................................................ DEPT FT 500589 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM BX2 CU 500589 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX2 PU 500589 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF BX2 CU 500589 O0 000 O0 0 11 1 1 4 68 0000000000 SBHNBX2 CU 500589 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC BX2 CU 500589 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH BX2 CU 500589 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BX2 500589 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI BX2 CU 500589 O0 000 O0 0 11 1 1 4 68 0000000000 BACK BX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 37 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) TCANBX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 TCAFBX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 TCND BX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD BX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN BX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF BX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 INNDBX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 INFD BX2 CPS 500589 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX2 LB 500589 O0 000 O0 0 11 1 1 4 68 0000000000 GR BX2 GAPI 500589 O0 000 O0 0 11 I 1 4 68 0000000000 CCL BX2 V 500589 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 9941.000 SIGM. BX2 40.492 TPHI.BX2 44.586 SBHF.BX2 SBHN. BX2 83.520 SIGC.BX2 1.487 SIBH. BX2 135.658 TRAT. BX2 SDSI.BX2 1.865 BACK. BX2 168.224 FBAC.BX2 28.629 TCAN. BX2 TCAF. BX2 2369.961 TCND.BX2 7682.550 TCFD.BX2 2043.035 TSCN. BX2 TSCF. BX2 163.508 INND.BX2 1458.383 INFD.BX2 233.820 TENS.BX2 GR.BX2 205.250 CCL.BX2 0.021 DEPT. 9691.500 SIGM. BX2 41.623 TPHI.BX2 48.503 SBHF. BX2 SBHN. BX2 85.893 SIGC. BX2 0.054 SIBH.BX2 141.040 TRAT. BX2 SDSI.BX2 1.501 BACK.BX2 168.386 FBAC. BX2 31.828 TCAN. BX2 TCAF. BX2 2157.179 TCND.BX2 7914.770 TCFD.BX2 2093.128 TSCN. BX2 TSCF. BX2 185.342 INND.BX2 1473.421 INFD.BX2 249.390 TENS.BX2 GR.BX2 118.625 CCL.BX2 0.000 64.989 1.319 7850.452 483.152 1380.000 72.517 1. 367 6903. 285 540. 671 1630. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .01I SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 38 **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... TDTP 10473.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10194.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TDTP GAMMA RAY SOURCE TDTP PROD. SONDE CARTRIDGE TDTP TDTP DETECTOR CART. 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) : 19-NOV-96 CP 42.2 1458 19-NOV-96 10450.0 10456.0 9700.0 10449.0 1800.0 NO TOOL NUMBER ........... CGRS 863 CPLC 867 TDIC 8337 10087.0 SEAWATER/BORAX 8.60 15.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 39 FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): i. 0 REMARKS: This file contains raw data from borax pass #3. Blueline labeled as borax pass #1 lower section. TIED INTO SWS BHC DATED JAN-26-1981 ALL PASSES LOGGED AT 30 FPM WHILE PUMPING 2 BPM ONLY LOGGED TWO BASELINE PASSES BECAUSE TOOL STICKING PUMPED 660 BBL TOTAL SEAWATER AND 204 BBLS BORAX LOG INDICATES THAT THE LINER IS NOT LEAKING AT THE TOP NOR BOTTOM BOREHOLE SIGMA INDICATES THAT BORAX IS LEAVING CASING AT BOTTOM OF THE PERFS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 4O TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 500589 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BX3 CU 500589 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX3 PU 500589 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF BX3 CU 500589 O0 000 O0 0 12 1 1 4 68 0000000000 SBHN BX3 CU 500589 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC BX3 CU 500589 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH BX3 CU 500589 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX3 500589 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI BX3 CU 500589 O0 000 O0 0 12 1 1 4 68 0000000000 BACK BX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC BX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 TCANBX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 TCAFBX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 TCNDBX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 TCFD BX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 TSCN BX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF BX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 INNDBX3 CPS 500589 O0 000 O0 0 12 1 1 4 68 0000000000 INFD BX3 CPS 500589 O0 000 O0 0 12 I 1 4 68 0000000000 TENS BX3 LB 500589 O0 000 O0 0 12 1 1 4 68 0000000000 GR BX3 GAPI 500589 O0 000 O0 0 12 1 1 4 68 0000000000 CCL BX3 V 500589 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 10473.000 SIGM. BX3 41.623 TPHI.BX3 48.503 SBHF. BX3 SBHN. BX3 85.893 SIGC.BX3 0.054 SIBH.BX3 141.040 TRAT. BX3 SDSI.BX3 1.501 BACK. BX3 168.386 FBAC.BX3 31.828 TCAN. BX3 TCAF. BX3 2157.179 TCND.BX3 7914.770 TCFD.BX3 2093.128 TSCN. BX3 TSCF. BX3 185.342 INND.BX3 1473.421 INFD.BX3 249.390 TENS.BX3 GR.BX3 72.813 CCL.BX3 0.021 DEPT. 10194.500 SIGM. BX3 46.367 TPHI.BX3 67.739 SBHF.BX3 SBHN. BX3 66.474 SIGC. BX3 1.678 SIBH. BX3 96.988 TRAT. BX3 SDSI.BX3 3.567 BACK. BX3 169.865 FBAC. BX3 27.771 TCAN. BX3 TCAF. BX3 1203.535 TCND.BX3 7825.834 TCFD.BX3 1595.928 TSCN. BX3 TSCF. BX3 131.110 INND.BX3 1227.545 INFD.BX3 174.974 TENS.BX3 72.517 1.367 6903.285 540.671 1270.000 57.315 1.662 4978.739 460.579 1720.000 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 41 GR.BX3 74.000 CCL.BX3 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................... 10474.0 9681.5 TDTP LOG HEADER DATA DATE LOGGED: 19-NOV-96 SOFTWARE VERSION: CP 42.2 TIME LOGGER ON BOTTOM: 1513 19-NOV-96 TD DRILLER (FT) : 10450.0 TD LOGGER (FT) : 10456.0 TOP LOG INTERVAL (FT): 9700.0 BOTTOM LOG INTERVAL (FT): 10449.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 42 TDTP GAM~A RAY SOURCE TDTP PROD. SONDE CARTRIDGE TDTP TDTP DETECTOR CART. CGRS 863 CPLC 867 TDIC 8337 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10087.0 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) : SEAWATER/BORAX 8.60 15.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): 1.0 REMARKS: This file contains raw data from borax pass #4. Blueline labeled as borax pass #2 lower section. TIED INTO SWS BHC DATED JAN-26-1981 ALL PASSES LOGGED AT 30 FPM WHILE PUMPING 2 BPM ONLY LOGGED TWO BASELINE PASSES BECAUSE TOOL STICKING PUMPED 660 BBL TOTAL SEAWATER AND 204 BBLS BORAX LOG INDICATES THAT THE LINER IS NOT LEAKING AT THE TOP NOR BOTTOM BOREHOLE SIGMA INDICATES THAT BORAX IS LEAVING CASING AT BOTTOM OF THE PERFS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 43 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB S.~IP ELi~ CODE (HEX) DEPT FT 500589 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM BX4 CU 500589 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX4 PU 500589 O0 000 O0 0 13 1 1 4 68 0000000000 SBHF BX4 CU 500589 O0 000 O0 0 13 1 1 4 68 0000000000 SBHN BX4 CU 500589 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC BX4 CU 500589 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH BX4 CU 500589 O0 000 O0 0 13 I 1 4 68 0000000000 TRAT BX4 500589 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI BX4 CU 500589 O0 000 O0 0 13 1 1 4 68 0000000000 BACK BX4 CPS 500589 O0 000 O0 0 13 I 1 4 68 0000000000 FBAC BX4 CPS 500589 O0 000 O0 0 13 1 1 4 68 0000000000 TCANBX4 CPS 500589 O0 000 O0 0 13 1 1 4 68 0000000000 TCAFBX4 CPS 500589 O0 000 O0 0 13 I 1 4 68 0000000000 TCNDBX4 CPS 500589 O0 000 O0 0 13 1 1 4 68 0000000000 TCFD BX4 CPS 500589 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN BX4 CPS 500589 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF BX4 CPS 500589 O0 000 O0 0 13 1 1 4 68 0000000000 INNDBX4 CPS 500589 O0 000 O0 0 13 1 1 4 68 0000000000 INFDBX4 CPS 500589 O0 000 O0 0 13 1 1 4 68 0000000000 TENS BX4 LB 500589 O0 000 O0 0 13 1 1 4 68 0000000000 GR BX4 GAPI 500589 O0 000 O0 0 13 1 1 4 68 0000000000 CCL BX4 V 500589 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9-DEC-1996 10:47 PAGE: 44 ** DATA ** DEPT. 10474.000 SIGM. BX4 SBHN. BX4 66.474 SIGC. BX4 SDSI.BX4 3.567 BACK. BX4 TCAF. BX4 1203.535 TCND.BX4 TSCF. BX4 131.110 INND.BX4 GR.BX4 293.750 CCL.BX4 DEPT. 9681.500 SIGM. BX4 SBHN. BX4 85.265 SIGC.BX4 SDSI.BX4 3.258 BACK.BX4 TCAF. BX4 2087.501 TCND.BX4 TSCF. BX4 215.804 INND.BX4 GR.BX4 539.000 CCL.BX4 46 1 169 7825 1227 0 37. 1. 203. 8040. 1436. O. 367 TPHI.BX4 678 SIBH. BX4 865 FBAC. BX4 834 TCFD.BX4 545 INFD.BX4 021 245 TPHI.BX4 237 SIBH. BX4 751 FBAC.BX4 630 TCFD.BX4 755 INFD.BX4 000 67.739 SBHF. BX4 96.988 TRAT. BX4 27.771 TCAN. BX4 1595.928 TSCN. BX4 174.974 TENS.BX4 48.117 SBHF. BX4 139.616 TRAT. BX4 262.056 TCAN. BX4 2100.785 TSCN. BX4 251.334 TENS.BX4 57.315 1.662 4978.739 460.579 1200.000 68.812 1.444 6493.181 624.330 1595.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/ 9 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/12/ 9 ORIGIN : FLIC TAPE NAME : 96352 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 16-02, PRUDHOE BAY, 50-029-20544-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/12/ 9 ORIGIN : FLIC REEL NAME : 96352 CONTINUATION # : PREVIOUS REEL : COMFiEJgT : ARCO ALASKA INC, D.S. 16-02, PRUDHOE BAY, 50-029-20544-00 RRRRRRR IIIiii R~ RR RR RR II RH RR I'I RRRRRRRR ii ~RRRRRRR RR RR II RR RR II RR RR R RR I~iIII R RR I Iiii ~Y YY YY YY YY ¥~ Y¥ YY Y¥ YY YY ~Y YY 000000 000000 O0 O0 O0 O0 O0 O0 O0 0000 O0 O0 0000 O0 O0 O0 O0 O0 00 O0 O0 00 0000 0O 0000 0000 O0 0000 O0 O0 oo 000000 000000 000000 000000 000000 666666 000000 666666 00 6b O0 66 0000 66 0000 66 O0 O0 66666666 O0 O0 66666666 O0 66 66 O0 66 66 00 66 O0 '6 66 666666 666066 *SIART USER PCAL [10707,01363 T jOB SHIP fiEO. 5025 DATE MONITOR SW$ KLIOE40 NOV-80. )STA * FINE: DSK}{:VERiF~.006<057>[107.07,6.1363] CREATED: 29-dAN-8! PAIN.TED: 29-JAN-8i 05:t2:38 QUEUE S~I. CHES. ~ILE.ftRT /COPIES.1 /SPACING:I /Li~lT:143 /FDRMS.NO~MAL 29-dAN-8! 05:05:08 05:12:12 LIS VERSION 15.HOI 79/03/26 SCHLUMBERGER COMPUTING 10707,61363 CENTER PEEL HEADER LENGTH: 132 BYTES sERve, cE NAM~ EDiT E~L CONTINUATI.ON O! REVtOUS REEL NAMe: m ~ · ATE. 811 1/28 TAPE HEADER bLNGIH~ 132 BYTES TAPE NAME: ~1,363 SERVI~CE NAME~ EDIT TAPE CONTiNUATiON ~U~BER: O1 PRE¥IOUS TAPE NAME: COMMENTS: ~ TAPE COMMEN~S [)IL RUN ~ 1, LOGGED 26-JAN-81-80 DATE: 81/ 1/28 CASING DRILLER 9.65 IN. ~ 10087 FT. BIT SIZE = 8.500 IN. LUID I~ ~HE HOLE = LIGNOSULFONATE ENS = I0.I0 VISC = 40.00 PH = 1t.50 FLUID LOSS : 5 0 ML RM ~ ~EAS TEMP. :1:60 @ 65 F FILE HEADER LENGTH: 62 BYTES PIL~ NAME. EDiT .001 MAXIMUM PHYSIC'AL RECORD LENGTH: PREVIOUS ~IL~ NA~E. FILE COMMENTS OPEN HOLE DATA. COMPANY : ATLANTIC RICHFIELD C WELl, : DRiLLSI~ 16-2 FIELD : PRUDHOE BAY RAN ,L , : 15E TOWNSHIP : 1 ON SECTi[)N : 24 COUNTY : NORTH SLOPE 1024 BYTES DA' fl~]M SPEC1,F,ICA~' ' "ION BLOCK,S: NAME TOOL [.INIT API API AP1 AP1 FIL.E SIZE SAM HEP PHOCEM$ INDICATOR8 DEPT SP DIL ILD DIL ILM OIL .GR DT DIL 8 GR CN~ 9 C LICNL I0 DRHO CNL I~ NPHI CN RHOB CN~ 13 NRAT CNL 14 NCNLCNL 15 FCNL CNL O0,1tMM 7 1 ~ 46 HM~ 7 1 44 uGAPI ~7 31 32 S/F 7' 52 32 CPS 42 34. 93 e8 68 0 0 4 1 ~ 8 0 0 ~4 i 68 68 ~8 8 8 O..0 4 1 68 I 68 1 b8 USER DEFINED OUTPUT ARRAY OUTPOT SP A% 2 OUTPUT' iLD AT OUT}-UT IL A OUTPUT GR AT 5 oOUTPUT DT AT 6 UT'PUT SF. LU AT 7 ! OUTPUT RHOB A~ 1.2 OUTPUT NRAT · AT 13 OUTPUT NCNL A~ 14 OUTPUT FCNL AT 15 DEPTH 10815.000 10800.000 10700.000 10600.000 10500.000 10400.000 10300.000 10200.000 10100.000 10000.000 9900,000 EMONIC P T ORHO NCNL' SP RHO NCNL SP DT DRHO NCNb SP DT DRHO NCNb SP DT DRH.O NCNb SP DT DRHO NCNb SP DT DRHO NCNb SP DT RHO CNL VALUE MNEMONIC VALUE MNEMONIC VALUE ' ~ 000 ib~U 5,699. IbM 6.6~1 ~i ~56] SF 11.227' GR 131.250 -0..002 NPHI.. 35.889 RHOB 2.020 2408.000 FCNL- 77'2~000~ -6.625 ILD 5,691:~ IbM. 6.645 · 2408.000 FCNL 772,000 '~.594 ILD 4.203 ibm 4.469 8~'56] SFBU 5~426~ ' GR 101.625 0..057 RE 2 609 2400;000 -42.250 IbP 5,480: IbM 5.2.38 76.7.50 SFLU 7,008 GR 74 05.01 ' NPHI '17,578-~ RHOB 2.537 3270.O00 FCNL 17t9.000 ' 88.000 SFLH ]'289' GR 40'094 -o.o,o 3048,000 FCNL ! 171.000': . ' -78,000 ILD 12,352,~ IhM 9,680 ~ 000 ~8.F LU 11,6.88 GR 26,188 ~ ]00'5 :NPH-I' 27';686: RH(]B 2,270 35t8..o. oo -78.750 ILD 22,438 ~LM !4,953 90-000 SFLU 17~594:~ GR 42,719 -,0,013 NPHI 21,582- RHOB 2 354 3486.000 FCNL ' i445-000~ " -57.000 ILD 15'039i IbM 14.008 8~,188 SFLU 23,]59 GR 106,313 ;014 NPHI 30"859 RHOB 2,467 3256.000 FCNL 1006,000 - o..o,g I8'49.000 FCNB SP -9-99,250 ILD T '999,.250 SFLU -999 RHO '-999,250 ' NPHI-9'9925 NCNb '999,250 '9999 250 DT -99 ~ 250 DRHO ' 9. 99 250 NCNb -999,250 250 GR -999. 250 000 RHOB:-999,250 250 IbM -999.250 G~ -999.250 RHOB -999 250 MNEMONIC GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CAb[ NRAT VALUE 87.563 8.500 2.848 87.56] 4.973 2.848 88,625 9.891 2.914 63.813 8.641 1.923 39,250 8.586 2.505 43.125 8.7'13 2.609 71.563 8.656 2.191 48,594 8.844 2.826 114.375 14.617 0.621 -999.250 -999,250 -999.250 -999.250 -999.250 -999.25O DEPTH 9800.000 9700.000 96O0,000 9500,000 9400.000 9300.000 9200.000 9100.000 9000.000 8900.000 8800.000 MNEMONIC SP DT VALUE MNEMONIC VALUE i'~NEMONIC VALUE . -999.250 ILD .-999.250- ILM 2999.250 s ,,u -gg 50 - 9 s.ooo NCNL -ggg]]50 FCN~ '9992250 SP -9gg' 250 1LD ILM -gg9,250 T -ggg -ggg.250 RHO -9gg -999.250 NCNL -999. 250 -FCNL -999.250 sm -999.250 1LD -999,250 ILM . -999. 250 DT '9991250 SFLU - -999~50~ GR · 1999 250 NCNL 99.250 FCNL' 999.-250== - BP -999. 250 ILD -999. 250 DT .-999.250 SFLU ,999,250 G~ -999.250 DRHO '999'250 N PHI '99925 ~ 0'00 RHOB -999.250 NCNL =999. 250 FCNL SP '999 ' - 9 - 9 .250 ILD. 99 ,250.- ~LM 9 9.250 DT '9'99,250 'S'FLU -'999"250" G~ ~999.250 DRHO ·-999,250 N.PHI 99925,000 RHOB .999.250 NCNL -999,250 FCNL ~'.999,250: n~SP .o'999'250 iLD _~909'250: ILM -999 250 -9991250 GR -999. 99~250 " 'NPBI 99925~000- RHO8 250 NCNL -999.250 .~CNL '~999,250 ~P .-999. 1L~ -999.250 DT "9992 GR -999.250 DRH. · 999 250.. ~HI -999~5,~00 RH[]B 9 9.250 NCNL '-9991250' ~FCNL- : "999-250- SP '999.250 iLD ' -999.250 ILM -999. 250 D~H'O -999,250 NPHI -99925,.000 ~HOB -999,250 NCNL -99'9'250 FCNL - '999;250 SP -999.250 ILD '999-~50 ' ILM -999.250 DT - 99 9.250 DRHO -999. 250 NCNL -999. 250 SP -999.250 I.,D 999.250 ILM -999.250 DT -999,250 SFLU -999,250 GR -999.250 DRRO -999.250 -999.250 . MNEMONIC GR CALl NRAT GR CALl GR CALl NRAT GR CALl NRAT GR CALl N R AT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CAI, I NRAT G~ CALl NRAT VALUE -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 =999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 D~PTH 87O0.°O00 8600.000 8500.000 8400.000 8]00.000 8200.000 8100.000 8000,000 7900.000 7800.000 7700.000 MNEMONIC VALUE MNEMONIC VALUE MNEM(]NiC SP DT DRH NCN~ .-999 250 iLD -999.250.. 999."250 SFLU: --999.250 GR I ' ' ~999 250 NPH! 99925 000 RHOB 999."250 FCNL -999:250 SP DT DRHO NCNL -_~999.250_~99.250 NS. FLU --999, 250 PH! '99925:000 -999.250 FCNL -999.250 ILM GR RHt3B SP DT DRHO NCNb -999.250 iLD -999.250 -999'250 SFLU -999.250 GR -999.250 NPH! -99925.000 RHOB -999.250 FCNL · -999°250 SP DT DR, HO NCNL -999 250 ILD -999 250 .-999:250 .oFL, 99 250 999 "250 NPHI '9_-~ 25 000~ RHOB -999.250 FCNL -999.250 sP ~ 250 DRHO 99 99.250 ILD -999.250 FL[] '999. 250 NPHI -99925 000 RHOB FCNL ""999~:-250 SP -99'9.250 ILD '999.250 DT -999.25~ SFLU -999.250 GR DRHD --999i25.~ NPH.I '99925~000 RHOB NCNb -999..~250 .FCNL -999.250 SP -999.250 DT '999.250 DRHO '999.250 NCNb '999'250 ILD -999 250 SFLU '-99'9:250'. ' GR PHI-99925000 RHOB CNL -999:250 SP DT DRHO NCNL -999.250 ILD -999.250 iLN -999.250. SFLU -999 2.50: GR I '99925~000 RHOB -999'250 =NPH · '999.250 ~'"CNL -99..qo250 'D SP 999.250 lb 9.99.250 ibm GR 25O DT 2999,250 SFLU . -999, DRHO. -999.25.0 NPHI 99925.000 RHOB NCNb ',999~250 FCNL ' '999-250 SP -999.250 DT -999 258 DRHO -999~25 NCNb -999..250 ILD -999.250 iLM SFLU -999.250 GA NPHI -99925.000 RHOB FCNL -999.250 'SP -999.250 1LD -999 250 DT -999-250 SFLU - '999.'250 DRHO -999.250 NPHI -99925 000 NCNb '999-250 FCNL -999;250 GR VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 99.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2.50 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC GA CAbI NRAT GR CALl NRAT GR CAb1 NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALI NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH 7600.000 7500.000 7400.000 7300.000 7200.000 7100.000 7000.O00 690'0.000 6800.000 6700.000 6600.000 MNEMONIC VALUE SP -999.250 DT -999.250 DRHU · .-999,250 NPH1 -99925 000 NCNb -999'250 FCNL -999~250 SP -999.250 ILD '999.250 DT -999 250 SFLU 999 250- DRHO '999[250 NPH1 '9~925:000. RHOB NCNb -999.250 FCNL -999.250 SP -999,250 ILD --:999 ~50 DT -999;250 SFLi] -999~~ 50 DRHO -999,25.0 . NPHI -_99925,000 NCNb -99:9.250 'FCNL -999o250 SP :999.250 ILD :999.250 T 999,250 SFLU :999.2.50 · RHO '999i250' 'NPHI-99925-000? NCNb -999,250 FCNL -999.250 SP -999,250 DT '999'250 DRHU -999,250 NCNb '999. 250 MNEMONIC .VALUE MNEMONIC iLD -999,250. IbM SFLU -999.250 GR RHOB GR RHOB D - 9 250 IL,, - 99 , SFLU ' -999.250 PHI -99925. 000 :C NL ' 9'99.250 RHOB BP -999.250 ILD ' -999.250 1LM DT -999 250 .SFLU . -999.250 GR DRHU '999~250 NPHI -9-9925,000 RHOB NCNb -999,250 FCNL -999,250 SP -999.250 ILD. ~-999,250 1bM . 250/ GR DT :'999"250 SFLU~,~ :-999.~ 0oo DRHO 999.250 N~HI 99925. NC~L -999~250 FCNL ~-'999.250' sP -999.250 lbo -999,250 PT -999 250 SFLU - --999,250~ GR RHO -999:250 NPHI--99925.000:' D NCNb -999.250 FCNL -99.9.250 -999,250 IbD -999.250 -999.250 SFLU~'999,250~ GR -999,250. NPHI'99925.000 RHOB -999'250 ~CNL -990'~50 -999.250 ILD -999.250 -999.250 SFLU -999.250 GR -999,250 NPHI '99925'000 RHOB -999.250 ~CNL -999 250 . 999'~250 ~FbO -999 000 -999: 250~ DT DRHO NCNb SP DT DRHO NCNL SP DT DRHO NCNb VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 99.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 :9 9. 5o 999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC GR CALl NRAT GR CALl NRAT GR CAbI NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CAI~I NRA]= GR CALl NRAT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH 6500.000 6400.000 6300.000 6200.000 6100.000 6000.000 5900.000 5$O0.OO0 5700.000 5600.000 5500.000 MNEMONIC VALUE .MNEMONIC VALUE MNEMONIC VALUE · ~P .-999,250 iLD - -.999,250 IbM -999,250 T .'999"250 SFLU --999,5.50- GR -999.250 DRHO 1999'250 NPHI ,99925.000 RHoB '999.250 NCNL - 999;250 ' 'FCNL -.999'.250 SP -99.9. 250 ' ILD ' '999.250 1bM -999.250 D~Z -999, -999,250 NCNb - SP -999.250 1LD -999.250 1LM -999.250 DT -999.250 -SFLU - - -999.250' GR -999. 250 DRH(3 -999.250 NPHI -99925.000~ RHOB -999 250 NCNb -999~250 -FCNL ' -999~250 ' ' ,S~ -999. 250 · -ZI''D -"- '999 °250 ILM -999.250 Dr .-999.250 SFLU ~-999.250 . GR -999.250 DRHO .-999 ~ 25'0 -'NPHI:' ~99925:i 000. RHOB -999. 250 NCNL · 999.250 FCNL -999.250 SP -999.250 DT -999.250 DRHU :999..250 NPR1 -9~925.000 RHOB -999 250 NCNL. 999.250 - FCNL .i 999~250: ' SP -999' 250 ' ILL')' '999-'250j: IbM -999,250 -999,250 '999,250 NCNL ~P ~999..250 .!LD -999.250 IbM -999.250 T 999,250 SFLU '9.991250:~ GR -999.250 ORHO -999 250 NPHI -999 5 000 RHOB ' - .... · ' ... ..... 2., ~ ' -999.250 NCNb '999'250 ~CNL- SP -999,250 -ILD -''999~250'; ILN -999,250 DT - -999.250 DRHO -999.250 NCNb I"IU '999 CNG '999 SP , 999 RHO '999 NCNb ~999.250 ..ILD -999.250 iLM -999.250 999.250' SFLU' -999-250¢~ GR -999.250 RHOB -999 250 IbM -999,250 -999.250 HOB -999.250 SP -999.250 ILD -999.250 ILM ~999.250 DT -990~250 SFLU-999;250~ GR -,999.250 DRHO -' RHOB -999.250 NCNb - ~ . MNEMONIC GR CALI NRAT GR CALl NRAT GR CALl NRAT CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH 5400,000 5300.000 5200.000 5100.000 5000.000 4900,000 4800.000 4700.000 4600.000 4500.000 4400. O00 MNEMONIC VALUE MNEMONIC VAL]E MNEMONIC ~-.9.250 IbM DT '999'.250 SFLU -999.250 GR N'HI - 9 DRNO -999,250 P 9 925 000 RHOB NCNL '999,250 FCNL -999~250 SP -999.250 ILD -999.250 iLN T GR RHO RHOB NCNb SP -.999.250 ILD .. -999999:250250 DT 99:9 ~ 250 SFLU.. -' DRHU -999.250. NPHI. 9.9925,000 NCNb -999-250 FCNL 999.250 SP -999.250 DRHO -999. NCNb -999.250 SP -999. 250 DT -999.250 DRHO -999 5°so SP -999. 250 DT -999.250 DRHO -999.250 NCNL -999.250 SP DT DRHO NCNb R RHOB ILO -999.250- ILM SFLU -999 250 GR NPHI '99925~000 RHOB FCNL -999.250 iLD -999 250, ,I, LM SFLU -999 ~ 250- GR NPHI -99925 000 RHQB FCNL -999~250 ILD -999.250 SFLU .. '999,250. GR NPHI -99925.000 RH00 D-999 250 Ih -. 999 250 -999:2S0 SFLU-999:250 --9 .<99,250 NPHI -99925,000 -999.250 FCNL - -999.250 SP -999.250 DT -999.250 DRHO -999.250 NCNb -999.250 P T DRHO NCNb SP DT DRH.O NCNb RHOB ILD -999.250 SFLU. -999.250, GR NPHI '99925-000 RHOB FCNL--999.250 -999 25.0 ILD -999,250 -999 ~ 2'50 SFLU -999 · 250 -999 250 NPHI -99925,000 -99'9~250 FCNL -999'250 -999.250 ILO -999.250 -99.9.250 SFLU , ,999 250 -999~250 ' NPHI 9992-5:000 -99.9.250 FCNL -999.250 GR RHOB DSP 999 250 1LD -999. 250 W -'99'9'~ 250 SFLU -999. 250 DRHD -999,250 NPHI -99925 000 NCNL -9'99~250 'fCN5 ' -999:2'5'0~ GR RHOB GR RH[]B VALUE -999.250 -999.250 -999.~50 -999.250 999.250 -'999.250 -999.250 999.250 '-999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 MNEMONIC GR CALl NRAT GR CALl NRAT CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CAbI NRAT GR CALl NRA~ GR CALl NRAT GR CALl NRAT GR CALl NRAT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 D E P T H 4300.000 4:200. 000 4100.000 4000.000 3900.000 VALUE MNEMONIC VALUE MNEMONIC VALUE :999o250 ILD :999.250 iL~ -999.250 999.250 SFLU 9991250 GR -999.250 DR}JO 2999.250 NPHI -99925.000- RHOB -999 250 NCNL ,999.250 FCNL- '999~-250 SP -999. 250 I. LD _'999.250.: ILM 999. 250 DT :9999.~.50 SFLU -999.250 GR :999.250 99. DRHO 9-9-250 ' :NPHI '9-9925 : 000 - R'H08 '9 250 NCNL -999.250 FCNL ' "' -999.250 · DTSP _-0999 250 ILD -999.250 ~I, LM 999.250 99 ~ 250 SFLU' -999~250-: GR -'999. 250 DRHO -999 250 , PHI 99925.000 RHOB 999 250 NCNL --99'9[ 250 FCNL -999'250 SP -999.250 lind -999.250: ILM -999.250 DT -999,250 SFLU -999.250 GR -999.250 DRHO -999,250 NPHI -9992'5~000:' RHOB '999.250 NCNL -999.250 F"CNL -999.250 SP -999,250 1LD.-999.250,:: ILM -999.250 DT -9.99.250 SFLU .''999~250 GR -999,250 DRHO .-999.250 NPH. I 9~925.000 RHOB -999.250 NCNL 999'250' 'FCNL 999~50 .: - 3800.000 SP ]700,000 ]600.000 3500..000 3400.OOO MNEMONIC SP DT 3300.000 -999.250 NCNL -999.250 ,LP -999. 250 DT -99"9 ~ 250 DRHO -'999 250 NCNL -999 '~ 250 SP -999-250 D T 999.250 D R H O' - 99'9,2'50 NCNL -999.250 SP .-999 250 DT 999:250 DRHO :999 250 NCN5 ' 99-9:250 SP -999.250 DDT =999,250 RHO -99:9 ~250 NCNL -999.250 DSP -999.250 T '999.250 DR O 999.25 NCNL "'999i2-50 .. IL ,~ '999.250 '999.250 '999.250 f'CNL ILO ~999.250~ ILM -999.250 SFLU-999,250 GB -999.250 NPHI.--9~925.000 RHOB -999 250 ~'CNL~ ,999~250: ' ILD '-999'250-i ILM -999.250 ~ 9 ~ ' . SFLU 9,9..250_~ GR 999 250 NPHi'99925'O00 RHOB -999.250 - 9 fCNL 99 .2.50~ ~ ~hD 299.9.250 iL~ -999.250 FLU : "999,:2-50: UR -999.250 NPHi -9~925.000 RHDB -999.250 f~CN5 .,199g'250~ ILD '999"250 :; ILM' -999. 250 SFLU'999.250. GR -999.250 -NPHI '99925.000 RHOB ',999.250 FCNL'.999.250 _ iLD :909.250 ILM -99~.250 SFLU . 999. 250 ~ GR -99 .250 N.HI 99925.000 _ ~H. OB 999.250 FCNL '999.250 -: MNEMONIC GR CALl NRAT CALl NRAT G[~ CALI NRAT GH CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl NRAT GR CALl VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 '999.250 DEPTH 3200.000 .~100.000 3000.000 2qO0.O00 2800.000 2700.000 2690,000 MNEMONIC SP DT DRHO NCNL SP DT DRHO NCNL SP DT DRHO NCNL DT DRHU NCNL SP DT DRHU NCNL SP DT DRHO NCNL SP DT DRMO NCNiJ VALUE -999 250 -999.'250 -999 250 MNEMONIC VALUE iLD -999.250 SFLU -999. 250 NPH!-99925 000 ~CNL -999]250 -999.250 iLD -999.250 -999,250 5FLU , -999,250 -999.250 NPRI 99925,000 -999,250 PCNL -999.250 -999. 250 -999. 250 -999 50 -999,250 -9.99 250 -999: 5o -999.250 -999,250 -999,250 -999,250 -999.250 ILD -999 5° 5O FCNL -999:25~ ILl) -99'9.250 .~FLU -999,250 PHI '99925,000 PCNL -999,250 iLD -999 250 SFLU -99q~250 NPfiI-99925,000 F'CNL -999,250 -999,250 ILD -999.250 -999,250 SFLU , -999.250 -999,250 NPHI 99925i000 -999.250 f'CNL -999,250 -999 25O -999:250 -999 25O -999:25n 1LD -999,250 SFLU -999. 250 NPH! -99925 000 FCNL -999~250 MN~MON IC LM RH00 ILM GR RHOB ILM GR ILM GR RHOB GR RHOB ILM GR RHGB IbM GR RflUB VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 =999.250 MNEMONIC Gf~ CALI NR AT GR CALl NRAT GR CALl NRAT GR CASI NRAT GR CALl NRAT GR CAhi NRAT GR CALl NRAT VALUE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 FILE TRAILER LENGTH: 62 BYTES FILE NAME: .EDIT .001 · MAXIMUM PHYSICAL RECORD'LENGTH: I024 NEXT FILE .NAME: BYTES FILE HEADER LENGTH: 62 BYTES iILE NA~E: EDIT .002 AXIMU~ PHYSICAb RECORD'LENGTH:' PRE~IOU. S FILE E. ILE CO~ENT~ CASED HOLE CNLo DATUM SPEC1FICATIflN BLOCKS: NAME UNIT API APl APl APl FILE SIZE SAM REP PROCESS INDICATORS 1DEPT 2 GR CNL 3 NPHI CNL 4 NRAT CNL 5 NCNL CNL 6 FCNL CNL FT 0 0 0 0 0 4 GAPi 42 ]! 32 0 0 4 PU 42 68 3 0 0 4 C/C 42 42 ! 0 O 4 CPS 42 34 92 0 0 4 CPS 42 ]4 93 0 O 4 I 68 1 68 I 68 1 b8 I 68 I 68 USER DEFINED OUTPUT ARRA~ OUTPUT GR AI 2 OUTPUT NPHI AT 3 OUTPUT NRAT AT 4 OUTPUT NCNL AT 5 OUTPUT FCNL AT 6 DEPTH 10815,000 10800.000 10700,000 !0600,000 10500,000 I0400.000 10300,000 !0200,000 10100,000 IOO00,000 9900,000 9800.000 9700.000 9600,000 9500.000 9400.000 9300.000 92O0.000 9100.000 MNEMONIC FCNb GR FCNL GR FCNL GR FCNL GR FCNb GR ~CNL GR FCNb FCNL GR FCNL FCNL GR FCNL GR FCNL GR FCNL GR FCNL GR FCNL GR FCNL FCNL GR ~-CNb VALUE 164.375 393.250 164.375 393.250 164 37~ 393~25 164.375 393.250 164.375 393'.250 164.375 393.250 64.375 93.250 164.]75 393.250 184.250 386,000 118,813 324.500 58.938 405,750 78.500 354,750 102,063 410.000 61.875 343.500 64.000 374.500 45 656 4s lsoo 4.5 000 19.000 7.17.000 46 406 3852750 MNEMONIC NPHI NPHI NPHI NPHI NPHI NPHI NPiiI NPHI NPHI NPHI NPHI NPHI NPtil NP}tl NPHI NPHI NPHI NPHI NPHI VALUE 4].896 43.896 43.896 43.896 43.896 43.896 43,896 4].896 39,404 50.732 42.334 47.559 40.430 46.484 49.365 37.598 32.383 27.881 4t.213 MNEMONIC NRAT NRAT NRAT NRAT NRAT N~AT NRAI NRAT NRAT NRA'I NRAI' NRAT NRAT NRAT NRAT NRAT NRAI~ NR~T NRAT VALUE 3.744 3.744 3.74q, 3.744 3.744 3.744 3.744 3.74'I 3.494 4.121 3.656 3.947 3.551 3.887 4.047 3.395 3.660 2.818 3.705 MNEMONIC NCNL NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb VALUE 1614.000 1614.000 1014,000 1614.000 1614.000 1614.000 1614.000 1614.000 1594.000 1598.000 1691.000 1601.000 1583,000 1502.000 1604.000 1675.000 1678.000 2050.000 1629.000 DEPTH MNEMONIC 9000,000 GR F-CNL 8900,000 GR FCNL 8800,000 GR FCNL 8700,000 GR FCNL 8600,000 GR FCNL 8500,000 (JR FCNL 8400,000 GR FCNL 8300,000 GR FCNL ~2oo.ooo G~ FC N L 8100,000 GR FCNL 8000,000 GR FC NL 7900,000 GR FCNL 7800,000 GR FCNL 7700'000 GR FCNL 7600,000 ~. GR FCNL 7500,0O0 GR F'CNL 7400,000 GR FCNL 7300.000 GR ~'CNL 7200,000 GP FCNL VALUE 44.813 382,00O 69,188 338,500 56,500 407-000 55-90~ 324,000 64,000 383 ' 2'50 57.094 344,000 59.87~ 360.50. 52,938 344. 000 47,656 34'4-750 48,219 347,000 MNEMONIC VALUE MNEMONIC NPHI 45,557 N~AT NRAT NPH 1 45,605 NPHI 45,850 N PHI 45,654 NRAT NPHI 41, 992 NRAT VALUE 3,836 3.840 3,854 3,842 3,639 MNEMUNIC NCNb NCNb NCNb NCNb NCNb NPH! 43.311 NRAT ].713 NCNb NPHI 42,480 3,666 NRAT 42,285? NRAT NPHI 3.654 NCNb NPHI NCNb 49,756 NRAT 4. 070 NCNb NPHI 44,287 NRAT 3. 766 NCNb NRAT NRAT NRAT 3.588 3.189 3,709 3.979 3.926 3,461 3.344 3.871 ~,426 NRAT NRA~ NRA1' 42.i25 NP}tI 41.113 462.750 28.81~ ~NPHI -33.936 485,000 328~750 41.56~ NPHI 48.I45 313.750 48 969 NPHI 47,168 343~750 24.578 -NPHI ~ 38,818 488.500 38 NPHi 3.b.670 50 52. 031 NPHi 46.19I 324.250 3~ 594 NPti! ]8.135 NRAT NRAT NRAT NCNb NCNL NCNb NCNb NCNb NCNb NCNb NCNb NCNb VALUE 1690.000 145b.000 lb37.000 1492.000 157~.000 1453.000 1442.000 1453.000 1439.000 1396.000 1799.000 1719.000 1502.000 1282.000 1484.000 1891.000 178'7.000 1414.000 1798.000 DEPTH 7100.000 MNEMONIC VALUE GR 38,78.1 FCNL '422,500 7000,000 GR 35,813 FCNL 375,500 6900,000 GR 38 844 FCNL 352~750 6800,0-00 GR 34,875 F:CNL 472,250 6700,000 GR 22,578 ' FCNL 466,250 6600,000 ' GR 24,891 FCNL 347,750 6500,000 GR 27 703 ~-CNb 435~00.0 6400,000 GR FCNL 6]00,000 FCNL 6200,000 GR FCN.L 6~oo.ooo G~ ]8.813 FC'Nb 291.S00 6000.000 OR 42,875 FCNL 216,125 5900,0.00 GR .]2 438 ~cmb 580o.oo0 GR 4].21g ~CNL 282,250 5700,000 Ga .28,359 FCU~ ]I8iO0o 5600,000 GR 46,719 ~CNL 210,000 5500,000 GR 38,71 FCNL 25].62~ 5400.000 GR 31.891 FCNL 5300.000 G~ 25.000 FCNL 38'6,750 MNEMONIC VALUE MN£MONIC VALUE NPHI 37.012 NRAT NPH-I ' 43.066:~ NRAI : NPHI_ ~ 45.654 NRAT NPHI 39'746 NRAT N. PHI ]9.111 . NRAT .N~AT NPH. I 37,451 NRAT _ 40.063 NPHI 52-051~'' NRAT 279.250 42,750 NPHI 55,029 ~ NRAT 258-250 ' 24,563 ' 'NPHI 50,293 ,~ NRAT 329,500 NPHI 48,975 NRAT . 3.361 3.697 3.842 ]-512 3,479 3,979 3,385 4,195 4,363 4.098 4,023 NPHI 4.320 NPHI NPHI 45.410 NP~AT NPHI 3.826 4,895 ~.s~o NPHI- 48.291 NRAT 3.988 NPHI. 3.695 MNEMUN1C NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NC NL NCNb NCNb NCNb NCNb NCNb VALUE 1668.000 1537.000 1497,000 1781.000 1819.000 1459.000 1598.000 1248.000 1175.000 1382.000 1366.000 1153.000 1486.000 1284.000 1399,000 1141.000 1313.000 1570.000 lb03.000 DE;PTN MNEMONIC 5200.000 GR FCNL 51. O0.000 GR FCNL 5000.000 GR FCNL 4900.000 GR FCNL 4800.000 GR PCNL 4700.000 GR FCNL 4600.000 (JR FCNL 450'0. 000 GR FCNL 4400. 000 GR FCNL 43 O0,000 GR FCNL 4200. 000 GR FCNL 4100.000 GR FCNL 4000.000 GR FCNL 3900.000 GR FCNB ]800.000 GR FCNL ]700. 000 GR FCNL J600 o 000 GR FCNL 3500. 000 GR FCNL 3400,000 GR FC NL VALUE 40.344 347.000 51 . 844 NPHI 250.500 40. 750 NPNI 298.250 39, 281 NPH I 317.250 37,844 375~000 44,344 NPH! 285,500 42.156 281. 500 32.188 NPNI 362,750 54,750 299i250 49,3 75 NPHI 315.500 43..156 NPHI 321~00,0 42 · 313 NPHI 331. 750 : ooo 43.8 75 NPHI 218.875 36,3.7 253;6255 35,469 NPH I 265.250 42,250 NPHI 229. 000 40.344 NPH I 213.750 35 50.0 NPHI 254:soo MNEMONIC VALUE NPHI 49.023 MNEMONIC NRAT VALUE 4.027 MNEMONIC NCNb 64.111 NRAT 4.863 NCNB 51.611 NRAT 4. 172 NCNB 49,60g NRAT 4.059 NCNB NPH£ 47.510 3.945 NRA'.[ NCNb 50.781 NRAT 4.125 NCNB NRAT 4.31] NCNb 47.705 NRAT 3. 957 NCNB 4.195 4.023 NPHI 52,051 N~a'r 48.926 NRAT NCNB NCNb 48,926 NRA'£ 4,023 NCNB 49.072 NRAT 4.031 NCNb 3.980 NRAT NPHI . . 48.193 NCNb 64.697 NRAT 4.898 NCNB NPHI 53 , 711 NRAT 4.289 NCNB 51.709 NRAT 4.1'76 NCN6 55.273 NRA~ 4.375 NCNb 68.799 NRAT 5.129 NCNB 57,275 NRAT 4.488 NCNb VA6UE 139/.000 1271.000 1221.000 1521.000 1603.000 1271.000 1248.000 1468.000 1421.000 1467.000 1353.000 1464.000 15b0.000 1188.000 1300.000 1197.000 1200.000 1180.000 12b0.000 DEPTH 3300.000 3200,000 3100,000 3000.000 2900.000 2800,000 2?O0,O00 2690.000 GR FCNL GR FCNL GR FCNL GR FCNL GR FCNL FCNL GR FCNL GR FCNL 26,813 NPHI 5],662 254,125 29 047 NPHI 59.,814 262~750 41,750 NPHI 58.936 243,375 36 344 2s.4 271,75-0 31.32.8 NPHI 243~750 -999.250 NPHI -99925,000 -999,250 NPHI 60,449 55.615 MNEMUNIC N~AT NRAT NRAT NRAT NRAT NRAT NRAI NRAT VALUE 3,859 4,285 4,629 4.578 4,664 4,473 4,391 -999.250 MNEMI]NiC NCNb NCNb NCNL NCNb NCNb NCNb NCNb NCNb VALUE 1263,000 1271.000 1274.000 1249.000 13~8.000 1.343,000 1212.000 -999,250 NUMBER OF RECORDS: 387 LENGI'H OF RECORDS: 1014 BYTES LENGTH OF LAST RECORD: 942 BY~ES ~'ILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .002 MAXIMUM PHYSICAL RECORD LENGTH: NEXT ~:ILE NAME; EOF 1024 BYTES TAPE T~AILER LENGTH: 132 BYTES TAPE'NAME: 6116] SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: 01 NEXT TAP~ NAME: Cf'I~MENTS: DATE: H~/ 1/28 DATA fORMAT SPECIFICATION LENGTH: 610 BYTES ENTR~ BLOCKS: TYPE 0 : ALASKA : 800, DATA E(.)RMA~ 8PECIFICATION LENGTH: 250 ENTRY BLOCKS: TYPE 0 SIZE REP CODE 1 66
