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188-142
From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 12-30 (PTD #1881420) Lapse 4 year MIT-IA Date:Tuesday, October 5, 2021 3:35:13 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 5, 2021 3:30 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector 12-30 (PTD #1881420) Lapse 4 year MIT-IA Mr. Wallace, Injector 12-30 (PTD #1881420) will not be online for 4 year AOGCC MIT-IA this month. The well is now classified as NOT OPERABLE and will remain shut in. Please call with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 8:46 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 12-30 (PTD #1881420) Lapse 4 year MIT-IA From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 5, 2021 3:30 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector 12‐30 (PTD #1881420) Lapse 4 year MIT‐IA Mr. Wallace, Injector 12‐30 (PTD #1881420) will not be online for 4 year AOGCC MIT‐IA this month. The well is now classified as NOT OPERABLE and will remain shut in. Please call with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,November 27,2017 TO: Jim Regg (7 P.I.Supervisor N q l�(` i 17 SUBJECT: Mechanical Integrity Tests 6 BP EXPLORATION(ALASKA)INC. 12-30 FROM: Brian Bixby PRUDHOE BAY UNIT 12-30 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ,p� NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 12-30 API Well Number 50-029-21891-00-00 Inspector Name: Brian Bixby Permit Number: 188-142-0 Inspection Date: 11/9/2017 Insp Num: mitBDB171109143538 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 12-30 Type Inj W`TVD 8475 - Tubing 700 701 • 701 - 701 • PTD 1881420 -Type Test SPT Test psi 2119 - IA 10 2402 - 2364 - 2349 i BBL Pumped: 5.5 ' BBL Returned: ' 4.5 - OA ' 10 ` 28 29 28 Interval 4YRTST P/F P Notes: SCANNEVs Monday,November 27,2017 Page 1 of 1 Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Tuesday, October 01, 2013 1:13 PM 2 l�l,( 3 To: Faul, Randy(ORION ENGINEERING) ell 1� Cc: Regg, James B (DOA) Subject: RE: Revision 1 BPXA/ DOYON 14/ DS-12-30I 5.5"x 9.625" MIT Attachments: MIT PBU 12-30 09-28-13.xls Randy, Attached is a revised report for MIT PBU 12-30 09-28-13 adding the well name of 12-30, PTD# 1881420, and including the waived information in the notes (on MIT forms the AOGCC Rep field should include an inspector's name if witnessed or is left blank if waived). Please update your copy. Thank you, Phoebe Phoebe Brooks SCANNED DEC 1 0 2013 Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: Faul, Randy (ORION ENGINEERING) [mailto:RANDY.FAUL@bp.com] Sent: Sunday, September 29, 2013 6:01 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Cc: AK, D&C Rig 14 Well Site Leader; Abigail.Warren@bp.com Subject: Revision 1 BPXA/ DOYON 14/ DS-12-30I 5.5" x 9.625" MIT Regards, s_.. C hone: .. 4/13 1 • S bp From: Faul, Randy (ORION ENGINEERING) Sent: Sunday, September 29, 2013 5:58 AM To: 'jim.regg @alaska.gov'; 'AOGCC.Inspectors @ alaska.gov'; 'phoebe.brooks @alaska.gov'; 'chris.wallace @alaska.gov' Cc: AK, D&C Rig 14 Well Site Leader; Warren, Abigail M (Abigail.Warren@�bp.com) Subject: BPXA/ DOYON 14/ DS-12-30I 5.5" x 9.625" MIT Please see attached. Regards, -3P W 1. di Dnyort 14 C '' ...'. a"> " �.�: � [e y q¢h ;4,-.1L)01,gym_a.��.� bp „,,!!, ■.• 2 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaaCci7alaska.aov: AOGCC.InspectorsCcialaska.aov; phoebe.brooks(Dalaska.aov chris.wallace(Dalaska.00v OPERATOR: BP Exploration Alaska geff 40(1(i 3 FIELD/UNIT/PAD: GPB/Doyon 14/DS12 i` DATE: 09/28/13 OPERATOR REP: Randy Faul AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 12-30 - Type lnj. W ' TVD '8,476' Tubing ' 4,100 "4,070 '4,062 Interval p P.T.D. 1881420 ' Type test P ' Test psi ' 2119 Casing '4,100 4,075 '4,070 P/F P Notes: 5.5"x 9.625"MIT prior to DEMOB of rig. ✓ OA Chuck Scheve waived witness 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. TVD 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 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU 12-30 09-28-13.xls • • OF To 0).' I%%�sv THE STATE Alaska Oil and Gas °fA LAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue rh pF p. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 ty - `.n=r Fax: 907.276.7542 Dave Bjork Engineering Team Leader QQ BP Exploration(Alaska), Inc. C7 0 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-30 Sundry Number: 313-418 Dear Mr. Bjork: 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, • G . Cathy P Foerster Chair DATED this � day of August, 2013. Encl. 4.. • STATE OF ALASKA • W� RECEIVED lJ . ALASKA OIL AND GAS CONSERVATION COMMISSION (3 AUG 0 1 2013 APPLICATION FOR SUNDRY APPROVAL Q,o� 07s f1f 5113 20 AAC 25.280 A0000 1. Type of Request: 14,f-41141(3 ❑Abandon ❑Plug for Redrill ❑Perforate New Pool i5 Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate ®yull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ' Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 188-142 • 3. Address: ❑Development ®Service . 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-21891-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 12-30 Will planned perforations require a Spacing Exception? ❑Yes ®No 9. Property Designatior 10.Field/Pool(s): ADL 028330&028331 ' Prudhoe Bay/Prudhoe Bay • 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): 11650' . 9245' • 11603' 9204' 10864' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3455' 13-3/8" 3455' 3195' 3450/4930 1950/2670 Intermediate 11193' 9-5/8" 11193' 8850' 6870 4760 Production Liner 783' 7" 10867'-11650' 8573'-9245' 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11196'- 11432' 8853'-9057' 5-1/2", 17#x 4-1/2", 12.6# L-80 10903', 11242-11275' Packers and SSSV Type: 9-5/8"x 5-1/2" Baker SB-3A Packer; Packers and SSSV 10789'/8509' 7"x 4-1/2" Brown 2-B Packer MD(ft)and TVD(ft): 11242'/8893' 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ❑Development _∎ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation August 25,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ®WAG ❑SPLUG ❑Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Abby Warren,564-5720 Printed Name: Dave Bjork Title: Engineering Team Leader Email: Abigail.Warren @bp.com Signature: %� fi *, Phone: 564-5683 Date: c ( p/1,3 �` Commission Use Only _ Conditions of approval: Notify Commission so that a representative may witness )� L( 1 �j Sundry Number ` L( L U ❑Plug Integrity El/BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: 23,6 t-z-6- k fo +-0D6 p S RBDMS SEP 1 '7 Spacing Exception Required? ❑Yes 121 No Subsequent Form Required: /t If-U 4. 2 / APPROVED BY / Approved By: , 0 C�—t/.r COMMISSIONER THE COMMISSION Date: 8-1s--(� Form 10-403 Revised 1 /2012 Approv i v i f 1#months from the date of approval ri Duplicate J 4) • • bp Sundry Request for casing repair Well: 12-30 Date: 7/16/2013 Engineer: Abby Warren MASP: 2387 psi Well Type: Injector Estimated Start date: August 25th, 2013 History: Well 12-30 was drilled in 1989 as a producer and converted to injection in 1999. It is a Sag and upper Zone 4 vertical injector in the southeast of Drillsite 12. The well was completed with a 5-1/2"x 4-1/2 tubing and 7"liner. It's original L-80 tubing is still in place. The well also has two AVA POGLMs with dummies installed. The POGLMs were installed in 1993 while the well was a producer. The dummies were installed in 1999 when the well was converted to injection. In addition to the ten years of pre-production the well has seen produced water, MI, and seawater injection. By December 2009 the well had injected 13 mmbbls of water and 20 BSCF of MI. Well 12-30i provides support to wells 12-14A/L1, 17-03A, 17-02, 17-05, and 17-19A(all operable and online). The recommended rate of injection for this pattern is 9,000 bwpd. The well began experiencing integrity issues in November 2009 when the IA pressure rose and failed an MIT-IA to 3680 psi with a LLR of 0.6 bpm. A caliper run on 12/11/09 found no holes with the worst joint having 47% penetration. A LDL done on 12/26/09 identified a leak at 4295' at the upper POGLM. The original plan was to pull the POGLM to set a tubing patch to cover the leaking area; however, slickline was unable to pull the POGLM after several attempts. The coil unit also attempted to retrieve the leaking POGLM 2 times. During the first coil attempt the pull and retrieve tool (PRT) broke after jar 41 to 40k. The second time coil spotted 10 bbls of 12% HCL to try to dissolve rust in the tubing before jarring 150+times to 40k with no POGLM movement. On 02/12/2011 CMIT-TxIA failed to reach test pressures and showed a LLR of 2.8 bpm @ 1250 psi and an MIT-OA to 1300 psi failed with a LLR 5 bpm. A LDL ran on 03/06/2011 confirmed the IBP was holding, confirmed the TxIA leak at 4,299'MD and indicated a packer leak. With no viable non-rig options left to pursue, 12-30i needs a RWO to replace its original 5-1/2" L-80 tubing to restore TxIA communication and repair the packer leak. Scope of Work: Pull 5-1/2" L-80 completion. Scrape 9-5/8" casing, swap tubing spool, and install new 9- 5/8" packoff. Mill and retrieve old packer and tailpipe. Run new 5-1/2" L-80 tubing Pre Rig Prep Work: S Drift to top POGLM for 5-1/2"jet-cutter. Drift thru lower POGLM and thru SB-3A packer for 2-1/8" IBP. E Shoot a 2-strand (160-grain total) string-shot across the to g of the first full joint(10742') above the 5- '/2" pup-joint at (based on 3/19/89 tubing tally and attached log*). This string-shot is requested in case a blind back-off is required during the de-completion. E Set 2-1/8" IBP at—10,795' and (middle of SB-3A packer's seal-bore based on tubing tally dated 3-17- 89), load tubing w/seawater and PT IBP to 1000 psi. E Jet cut 5-1/2" tubing at —4,263' and (intent is to leave at least a —15' collar-free stub of 5-1/2" tubing above the POGLM for fishing). F Circulate wellbore with seawater, CMIT T x IA to 1000 psi to ensure jet cut did not nick the casing and to verify the packer/IBP as a mechanical barrier, freeze protect to 2000'md with diesel. MIT-OA to 2000 psi NOTE: During the MIT-OA test ensure that the void is monitored to verify the primary seals on the IC are not failing (the IC secondary seals have failed) O Check the tubing hanger LDS for free movement. Completely back-out and check LDS for breakage. PPPOT-T to 5000 psi f/30-min and PPPOT-IC to 3500 psi f/30-min. ✓ Set BPV • • Proposed RWO Procedure: 1. MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 2- 7/8" x 5"VBRs, blind shears, mud cross and 3-1/2"x 6"VBRs). Test the pipe rams to 4000 psi and annular to 3,500 psi. 2. Pull and lay down tubing to the jet cut 3. Spear 5-1/2"tubing stub and jar seals from SB-3A packer. 4. Scrape 92/8" casing. 5. Run 9-5/8" RBP to 10,750'md and test casing to 4,000 psi. Swap tubing spool and install new 9-5/8" pack-off. 6. Recover 9-5/8" RBP. 7. Mill and retrieve 95/8" SB-3A packer and tail-pipe. 8. Run new 5-1/2" 17#/ft, L-80 TC-lI or(VamTop HC)completion with 95/8"x 5-1/2" HES TNT packer. MIT-T& MIT-IA to 4000 psi. 9. Set a BPV and RDMO. Post ri Work V 1 Pull BPV S 2 Pull ball and Rod, Pull RHC seat TREE 14 McEV OY GEN 4 • WELLHEAD= McEVOY O SA NOTES: H2S READINGS AVERAGE 125 'ACTUATOR= AXELSON ppm WHEN ON MI.WELL REQUIRES A SSSV ORIG.KB.ELEN, 74' WHEN ON ML ORIG BF.aEV= - 1 KOP= 1600' Max Angie= 49° 5 00' 20"CONDUCTOR —I 110' Li @ 91.5#,h-40, 2189' H5-1/2"CAM BAL-OSSSV NIP,ID=4.562" Datum ND= 11220' 0 Datum TV D= 8800'SS ID=19.24" 13-3/8"CSG,68#,L-80/K-55,ID=12.415" -] 3455' 4278' I—{5-1/2"AVA POGLM,ID=2.34" GAS LIFT MANDRELS Minimum ID = 2.34" @ 4278' LI ST MD TVD DEV TYPE VLV LATCH PORT DATE Top of AVA POGLM 1 4299 3811 45 POGLM DMY BK 0 01/25/99 2 7822 6252 44 POGLM DMY BK 0 02/05/99 DZI 7801" —I5-1/2"AVA POGLM,ID=2.34" g g 10789' —19-5/8"X5-1/2"BKR SB-3A Ft(R 5-1/2"TBG,17#,L-80,.0232 bpf,ID=4.892" —1 10809' \ / 10809' —15-1/2"X 4-1/2"XO N 10864'ELMD —12-1/8"BKR IBP(02/07/11) TOP OF 7"LNR — 10867' I I 10891' —14-1/2"OTIS X NIP,ID=3.813" 4-1/2"TBG,12.6#,L-80,.0152 bpf,ND=3.958" —I 10903' / \ 10903' —14-1/2"TUBING TAIL I 10898' —1 ELAND TT LOGGED 12/29/89 — 9-5/8"CSG,47#,L-80,0=8.681" —I 11193' I---• ■ 11242' —17"X 4-1/2"BROWN 2-B PKR I 2K I ' 11272' H4-1/2"OTIS XN NP,ID=3.725" 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" — 11275' / \ 11275' —14-1/2"WLEG PERFORATION SUMMARY REF LOG:BHCS ON 01/04/89 ANGLE AT TOP PERF:30°@ 11196' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11196-11214 0 06/01/89 3-3/8" 2 11320-11326 0 06/01/89 3-3/8" 2 11338-11360 0 06/01/89 3-3/8" 4 11338-11358 0 08/11/93 3-3/8" 2 11374-11432 0 06/01/89 PBTD — 11600' .A.egre,v,ve, 7"LNR,29#,L-80,.0371 bpf,®=6.184" -I 11650' ���•�•A•���•A•. DATE REV BY COMMENTS DATE REV BY COMVH'fTS PRUDHOE BAY UNIT 01/07/89 ORIGINAL COMPLETION 02/09/11 MB/JM) ADDED SSSV SAFETY NOTE WELL: 12-30 03/17/89 LAST WORKOVER 02/12/11 AW/PJC SET IBP(02/09/11) FERMI-No: 188-1420 12/17/00 SIS-SLT CONVERTED TO CANVAS 01/13/12 TNN/JMD ADDED H2S SAFETY NOTE API No: 50-029-21891-00 02/23/01 SIS-LG FINAL SEC 18,T1 ON,R15E 4857.94 FEL 2536.24 FNL 01/06/02 RN/TP CORRECTIONS BP Exploration(Alaska) -MEE McEVOY GEN 4 • 12 Alit WELLHEAD= McEVOY - NOTES: H2S READINGS AVERAGE 125 ;3 0 ACTUATOR= AXELSON ppm WHEN ON MI.WELL REQUIRES A SSSV ORIG.KB.EL& 74' Post RWO WHEN ON MI. ORIG BF.ELEV= Li MaxAngle= 49°@ 5800' 20"CONDUCTOR I 110' • • 2200' H5-1/2"N Nipple ID=4.582 Datum MD= 11220' 91.5#,h-40, Datum TV D= 8800'SS ID=19.24" 13-3/8"CSG,68#,L-80/K-55,ID=12.415" —I 3455' • - 10719' —15-1/2"X Nipple ID=4.562 1 IK I 10750' I-19-5/8"X 5-1/2"HES TNT Packer • •__. , __. 10785' —I5-1/2"X Nipple ID=4.562" I • • H5-1/2"XN Nipple ID=4.455" TOP OF 7"LNR —I 10867' 5-1/2"TBG,17#,L-80,.0232 bpf,ID=4.892" H I 10925' I / 9-5/8"CSG,47#,L-80,ID=8.681" —I 11193' IA I. 11242' H7"X 4-1/2"BROWN 2-B PKR S ' r— 11272' H4-1/2"OTIS XN NIP,ID=3.725" 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" H 11275' / \ 11275' —14-1/2"WLEG PERFORATION SUMMARY REF LOG:BHCS ON 01/04/89 ANGLE AT TOP PERF:30°@ 11196' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11196-11214 0 06/01/89 3-3/8" 2 11320-11326 0 06/01/89 3-3/8" 2 11338-11360 0 06/01/89 3-3/8" 4 11338-11358 0 08/11/93 3-3/8" 2 11374-11432 0 06/01/89 PBTD — 11600' .�.A.A.�•�.�.�. 7"LNR 29#,L-80,.0371 bpf,E)=6.184" —I 11650' *1�1�1�1�.A.• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/07/89 ORIGINAL COMPLETION 02/09/11 MB/JMD ADDED SSSV SAFETY NOTE WELL: 12-30 03/17/89 LAST WORKOVER 02/12/11 AW/PJC SET IBP(02/09/11) PERMIT No: 188-1420 12/17/00 SIS-SLT CONVERTED TO CANVAS 01/13/12 TMN/JlvE) ADDED H2S SAFETY NOTE AR No: 50-029-21891-00 02/23/01 SIS-LG FINAL SEC 18,T1 ON,R15E 4857.94 FEL 2536.24 FNL 01/06/02 RN/TP CORRECTIONS BP Exploration(Alaska) • • McEvoy Gen 4 CAMERON I --:. 16'. API-5000# i t s—- ma •a= 6 4 11', API-5000# i ;7 , . JIM .�■ - lit■ i u - 1■1 11 . 13-5/8' API-5000# ‘�`- II -NI 1 _ Ii IN; 11101111Nti ' ii lO 1 11 i i ' 20' I 13-3/8' I 9-5/8' JTIC RICHFIELD CONTROL LINE I CONTROL LINE I 1' x 13-3/8' x 9-5/8' x 7' 7' flu. 500att McEvoy Gen 4.ppt Page 1 of 5 s McEvoy New Standard CAMERON w 4.;., IP 1.III1_ Jr ....___ ___ , „....=:, 1111 c 110 hC 1:: 1111 01 _ -- _ • b ::i i j j • -- _ 11$ ' ' i 0 I ' ' ' .LN r se. i I .=1` tg U 212:11 - 12E11 I McEvoy New Standard.ppt Page 1 of 4 2,-3J (If-kw— (2-W0 ■ 03/24/11 Steger NO. 5709 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -20 BBSK -00054 PRODUCTION PROFILE rjjVIOINIUMINIM' ' PT,M.f!) 1 09-46 BMSA -00006 PRODUCTION PROFILE • j .11111=1111 ' ' 1Mn l 1 14-05A BBKA -00090 l:U1U1fe3ile7J9ae111A411/ -- 1 12 -30 BBSK -00855 ' 11rI Lei! •; 74 1 D -22C BCRD -00088 F-.l 7 :! ' '. -- • !y - r�0 _ 1 09 -02 BBSK -00052 PRODUCTION PROFILE S ' _ _ 'x Il. 1 09-41 BBSK -00053 PRODUCTION PROFILE i� )�C Y • rX r 1 15 -05A BCRD -00084 IZEN111111=111MLIMMIL111111011■111=111111 1 H -15 BCRD -00083 USIT — C1 02111/11 6 , 'f 1 1 III F -35 BG4H -00037 PRODUCTION PROFILE ) 0 Y I 02/22/11 1 + Q , 1 Z -31 BJOH -00009 INJECTION PROFILE J r ._ V 02/12/11 1 t! -4/i, �. ■ 1 06 -16 BCRD -00090 eel Nile}�83:UlylA�r;l �'S! e k 1 X -17 BJOH -00008 r7 4 1 LL 'I 11,* H -20 BBSK -00051 RST - 02113111 1 i �,5. 1 06 -20A BNWP -00003 RST ;0105 0 .9' 02/17/11 1 to( 'Y I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 e t, °, i \ � _ , c '. L J SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Josiah Igwe Production Engineer BP Exploration (Alaska), Inc. ~ ~,`. P.O. Box 196612 (~,~ ~ Anchorage, Alaska 99519-6612 ~ !t! Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-30 Sundry Number: 310-021 ~~~ ~~~ ~~ ~~ 20~ Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~,~~ Daniel T. Seamount i7~ Chair DATED this day of January, 2010 Encl. ,~~ o STATE OF ALASKA ~, ~'` RECEIVEQ~a~ ~ >Q ALAS~IL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS JAN ~ 2 X010 9f1 AAC 95 9R(1 u__~__ nv s n-- n-_- ~ -- 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well ^~ - ngg~~_pprove rogram ~ Alter casing ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ nCtlR~e Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ ^ Other: PATCH - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 188-1420 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service Q ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21891-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ ^ PBU 12-30 Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028331 PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11650 - 9244 ~ 11437 9061 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 32 142 32 142 Surface 3423 13-3/8" 68# L-80 33 3455 33 3194 4930 2270 Intermediate 11161 9-5/8" 47# L-80 34 11193 34 8850 6870 4760 Production Liner 783 7"29# L-80 10867 11650 8573 9244 8160 7020 Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L-80 SURFACE 10809 - - 4-1/2" 12.6# L-80 10809 10903 - - 4-1/2" 12.6# L-80 11242 11275 Packers and SSSV Tvae: 9-5/8"x5-1/2" BAKER SB-3A PKR Packers and SSSV MD and TVD (ftl: 10789 8509 7"X4-1/2" BROWN 2-B PKR 11242 8893 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/4/2010 Oil ^ Gas ^ WDSPL ^ Plugged ^ 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 Josiah Igwe Printed Name Josiah Igwe Title Wells Engineer Signature '^ Phone Date ~~ 564-4753 1/21/2010 Prepared by Ga Preble 564-4944 COMMISSION USE ONLY Numb Sund t ti it C diti f l N tif C i i th t er: ~~ C „~ ~(1 , ry a represen ve may w ness on ons o approva : o y omm ss on so a a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ©~ Location Clearance ^ Other: Subsequent Form Required: J ~ ~ yQ APPROVED BY Approved by: COMMISSIONER THE COMMISSION ~ ~ 0/0 Date: Ae~s~'~e o l~~ R i G 1~~ L i~ZS.~a - Form 10-403 Revised 12/2 9 ~ Submit in Duplicate .~ ~/~s~o 12-30 188-142 PFRF ATTArI-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 12-30 6/1/89 PER 11,196. 11,214. 8,852.87 8,868.4 12-30 6/1!89 PER 11,320. 11,326. 8,959.86 8,965.04 12-30 6/1/89 PER 11,338. 11,360. 8,975.4 8,994.38 12-30 611/89 PER 11,374. 11,432. 9,006.47 9,056.52 12-30 8/11/93 RPF 11,338. 11,358. 8,975.4 8,992.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE i Memorandum To: Jerry Bixby/Clark Olsen Date: January 13, 2010 ADW Well Operations Supervisors From: Josiah Igwe, Wells Engineer ; (w: 564-4753; c:) Subject: 12-30i Pull AVAPOGLM, Patch AFE: PBD12WL30-N IOR: 160 Please perform the following work on: 1 S Brush & Flush, Pull leaking POGLM and drift w/dummy Patch 2 E Set Lower Parker 3 S Set U er s acer i e and Packer 4 F MIT-IA to 3500 si Well Detail Current Status: Shut in injector, not operable due to failed MIT-IA Last Injection: 12/6/09: 8000 bwpd (seawater injector) Max Deviation: 49° C~ 5800' MD Deviation at top pert: 30° C~ 11196' Min. ID: 2.34" at 4278' MD top of first AVA POGLM Last Tag: 09/18/09 11418' MD, sticky bottom w/Slick Line Last Downhole Ops: 12/26/09: LDL Latest H2S value: injector with possibility for H2S in returns Job Objective The objective of this well intervention is to restore tubing integrity by pulling a leaking POGLM from 4,299' and setting a 5.5" tubing Patch to cover the leaking area. Well History 12-30 has original L-80 tubing in it which was installed in 1989. The well also has two AVA POGLMs with dummies installed. The POGLMs were installed in 1993 while the well was a producer. The dummies were installed in 1999 when the well was 12-30i Pull POGLM /Set Patch AFE#~D12WL30 converted to injection. In addition to the ten years of pre-production the well has seen produced water, MI, and seawater injection. Contacts: Trina Cooper Production Engineer Off/Cell: 564-4212/240-4212 Josiah Igwe Wells Engineer Off/Cell: 564-4753 Discussions: A recent IA pressure rise was noted on 11/26/09 and then an MIT-IA failed on 12/7/09 with a liquid leak rate of 0.6 bpm at 3680 psi. A caliper run on 12/11/09 found no holes with the worst joint having 47% penetration. A LDL done on 12/26/09 identified a leak at 4295' at the upper POGLM. Snapshots of the recent caliper, the recent LDL, and the well work log from the 9/21/93 installation of this leaking POGLM are attached. Slickline: 1. Pull AVA POGLM at 4,299' MD. 2. Brush and Flush tubing with crude to depth determined by S/Line PE 3. Drift with dummy patch to ~ 4,450' MD. 4. RDMO. Patch Specs 5-1/2" WDF Patch - L-80 2 run system. Use manufacturer's recommended setting procedure. Patch Depth All depths tie to the SLB Log POGLM setting /Tubing Punch Record on 09/21/1993 Patch Setting Depths are 4,270' - 4,305' ELMD Patch Length: 35' from element to element. Leak is at ~ 4295' ELMD. Leaking around the POGLM. (Intent is to patch over entire area previously covered by the POGLM). E-line 1. RU EL and tie into SLB POGLM setting record log dated 09/21/1993. 2. Set lower Parker at 4,305' ELMD per manufacturer's recommendations. 3. RDMO. Slick Line G~`~,C? 2 12-30i Pull POGLM /Set Patch AFE~D12WL30 1. RU Slick Line 2. Run spacer w/packer and set @ 4,270' ELMD with HES firing tool. 3. RDMO Fullbore 1. RU fullbore. 2. MITIA to 3500 psi, LLR IF FAILS 3. RDMO. If you have any questions or comments regarding this procedure, please call Trina Cooper at (W) 564-4212 or (C) 220-4212 or Josiah Igwe (W) - 564-4753. cc: w/a: Well File 3 12-30i Pull POGLM /Set Patch AFE~D12WL30 Cliem: BP Alsska Lease: WOA Atldnaas: Flsltl Prudhoe Pansh f~* Q eJ~ W th l d Patch ea er ur PlaMOnn: Cpm~an Men Joalah Drilling 8 Intervention Well Number: DS 12 -l0 Phone 3erviceS T d O anon: 20' Patch w/ 4.5 " OD 480 Cr E R Pseken Item ('/I' to Surface 'fool Descri dun Tool (1/D Tool I/D Len th De th (:onnetdon .(sset No. l: 80 Weatherford J.500 3.000 1.98 Top o(Pac 3 12 IOrd tiU box F:R PACker RP 550001 2 r SA00 M Release o I '._~ ~ j.l J.3U Crnterof F_Irm<ni j:,~ 1 to Tor r.r rather r SetlinR Otp16 10280 3 ~_ I Spacer Pipe 3.500 2.992 29.00 3 I/2 10 rtl NU pin t 3 I/2 10 rd NU pin I.engih Between {{ F:lemenb 35.10 3 C 1. AO SnAp La1rh !.5011 2.900 1.12 3 I/2 10 rd NU bos Seal\asemhly f' J Blh <5017 . 1 fqk.. ~I T2UU a R<Ira,r 1. AO Weatherford 1.500 3.000 1.98 F:R Packer Itr G5I1a51 e r x ' r' 1,,,1 ~ L~-{ i ~ I~ ~~ YNUII N Releasr Setdnc Dept h DRILLING !INTERVE NTION SERVICES THRU TUBING PACKE R INTERVENTION Trial Len ih of B. N. A. :- 12,21 (Metes 10.00 Peel B.H.A Propared by Date Faaw cote Ta at'rn'r +M'n4a~aaar omwa,uM rr e~awm oery B. M.A. 1e1 Run t M) Aaron McOOneu h 18JUn•10 12-30i Pull POGLM /Set Patch • AFE~DI2W L30 s~~lioo~ _ F -. cc _--- 4200 - I - SCHLUMBERGER - POGLM Setting Record. Tubing Puncher Record. Dated: September 21, 1993 '~ -- __ cc '.n __ i ,J ._ ._ _ J M ~ - AT (RING DEPTH ~ J N-1- --- - ___ '-- - - - _ . _ - --- eo LARD i 4300 - 5 12-301 Pull POGLM /Set Patch Well Work Loo AFE~D12WL30 Date 9/22/93 Typo of Work Actlvit!(~ f1 '/~ 9.S-Wril S 12-30 Dosk:riptloa Set U POGLM •~~ 8tsa 5 1 /2 - 4 1 /2 SSSV Putlad SSSV Pulled Sar. No. SSSV Ran SSSV Ran Sar. Na SSSV Nipple Carrlar Carrier Ssr. No. Tagged PBTD 31TP a AAIn. RastJ papth 5 1 /2" cA eal-O Rscov~rabla Olawl Non-R~cov. Dlesal 9 5J8" PSI O 1S 318" PSl O FTP / RP na ' SSS1- ~~ Total Hra. Tubular or CaaMg Problems Cost~~ S i~1 ~llbl5 `" Cos~t~ ats llt2 lobo Cost Eatlmats #!3 Av, ~- 360 Coat Estimate *4 ,~~~- ~J3~ Cost EsNmaN *8 .UIrM B5 ~ AFE No. 3B3010 CC * 21DS121PW CMss ' ~ctT" Total Fluids: 25 8 Tlma ~ ~ 07:80 RJ 08:40 PT, RIH w/ 1 tt of 1&11/16" tubin ncher,4 shots, oran a toad 4' from CCL to to shot 09:10 Tie-in to fla at 4400' 3 'Corr and collar dated 8121/93 09:20 PUH and shoot holes in Lubin from 4292'-4293', CCl at 4288' 4' above •to shot . 10:00 11:20 OOH, Pum in 9 5/8" at 3 BPM 1100 si oonflrmin communicatlon 25 B . PT RIH w/ CC BST 20 & AVA POGLM. CCL. to seal 13.25'. Tot tool 41.5', POGLM 26', OD 4.5: 12:05 Tie-in to fl 3' oorr , I into sftion ark CCE. at 4269' 13' above to seal . • - To of POGLM = ~ 4278' - To seal = 4282' - Bottom = 4298' - GL.M = 4299' 12:12 Set POGLM #'l POOH PT 9 5!8" to 3000 si for 30 min., ass 13.15 POCH RDNp Summa for To • Parted tubin and set u er POGLM w/ dum at 4278', 95/8" PT held. • Mininmum ID of POGt.M is 2.325" - Two Da Job Summa • Install two POGLMs w/ Dummies • Pressure test 9 5!8" to 3000 i, confirmin that both are holdin . • Mininmum ID of 2.325" for both POGt.Ms U er Lower Tubi r(s 4292-4293' 7814-7815' T of POGLMs x278` 7801' GLV Pockets 4299' 7822' Signed MadGU. yo/raon Page No. of 1 1 12-30i Pull POGLM /Set Patch Wefl Work Lea AFEZ~D12WL30 Date Type of Work vActivity DS.WNt 9/21 !93 El. DS 12-30 Description Tbg/TT Slses Install 2 POGLMs in r ress 5 1/2' - 4 t!2' SSSV Pulled SSSV Puked Ser. No. SSSV Ran SSSV Ran Ser. No SSSV Nipple 5 t/2" CA B81-O Carrlsr Carrier Ser. No. Tagged PBTD SITP Mln. Rest) Dsptb 3.725" @ 11272 Recoverable Dleael Non•Racov. DEessl 95/6" PSi 18 318" P81 FTP / RP 0 si 0 si 50 Psi SSSV ~~~ Total Hrs. Tubular or Casing Problems OOH Cost Estimate •t ~5~ S 5~' '~ Coat Estimate i2 Cost Estimate 53 Cost Estimate tR4 Cost Estimate /5 AFE ~ 3B03i0 CC 5 21DS121PW Class Total Fluids: Ttme ~ L Entry . 09:00 10:45 12:00 12:20 13:20 13:20 MlRU SWS 8290 -Jack Rather DSM um on location to fill and PT 9 5/8" PT 9 5/8" ~ 3000 i, for 30 min. Pass. 81eed off 9 5/8" to zero. PT, RIH w! 1 ft of 1&11/16" tubin uncher,4 shots, oran a load, 4' from CCL to to shot Tie-in CCL to SSSV in down PUH and shoot ho~essn tubin from 7814-7815', CCL at 7810' 4` above to shot . Fla 11ne at 7700'. POOH I i collars to SSSV for future tie-in. 13:25 Pum in 95/8" at 3 BPM 1300 t confirmin communication 25 B 15:40 ~ 8:05 . PT RIH w/ CCL BST 20 & AVA POGLM. CCL to seal 13.25'. Tot tool 41.5', POGLM 26' OD 4.5; PUW above SSSV ni 455 Ibs, d thru n' le no blem i 7:00 Tie-in to fla 1' corr , i into itian, rk CCL at 7792' 13' above to seal . - To of POGLM = 7801 - To seal = 7805' Additional E uf list • Bottom seal = 7821' q p. 5 1/2" Otis BOPS 17:07 19:00 Set POGLM ff2 POOH. tie line 4400' PT 95/8" to 3000 si for 30 min. as RD for hi h winds. BST 20 Extra Lubricator 7"x5' u below BOP SUMMARY: Shot circulatin holes and set one POGLM w/ dumm .Held ressure. • RD for hi h winds. Signed ?. ?. SIQcn/M O. ,9oftsswt Page No. o! _ 1 1 12-30i Pull POGLM /Set Patch AFE~D12WL30 Tension Gamma Ray (GR) (TENS) _ _ _ _ _ .. _ .. WeII Tem_peraturelWTEP) _ _ _ _ _ _ ^ _ ^~„ ,. „~w TREI E= Mr.EVOY GBJ 4 WELLHEAD = McEVOY ACTUATOR= AXELSON KB. REV = 74' B F. ELEV = KOP = 1600' Max Angle = 49 @5800' Datum MD= 11220' DatumTVD = 8800' SS 12-30 13-3/8" CSG, 68#, L-80/K-55, ID = 12.415" H 3455' Minimum ID = 2.34" @ 4278' Top of AVA POGLM 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ 10809' TOP OF 4-1/2" TBG 10809' - TOPOF7" LNR 10867' ' 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" 10903' • s-s/8" csG, a7#, L-80, ID=8.681" 11193' TOP OF 41/2" TBG 11242' ' 4-1 /2"TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 11275' Pff2FORATION SUMMARY REF LOG: BHCS ON 01/04/89 ANGLEATTOP PERF: 30 @ 11196' Note: Refer to Roduction D8 for historical oerf data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 4 11196-11214 O 06/D1/89 3-3/8" 2 11320-11326 O 06/01/89 3-3/8" 2 11338-11360 O 06/01/89 3-3/8" 4 11338-11358 O 08/11 r93 3-3/8" 2 11374-11432 O 06/01/89 PBTD 11600' 7"LNR 29#, L-80, .0371 bpf, ID = 6.184" 11650' I I SAFETY NOTES: 2189' H5-1/2" CAM BAL-O SSSV NIP, D =4.562" '2"AVA PDGLM GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 2 4299 7822 3811 6252 45 44 AVA PDGLM AVA POGLM BK BK 7801' ~5-1/2"AVA POGLM~ 10789' 9-5/8" X 5-1/2" BAKB~ SB-3A FKR 10809' 5-1/2" X 4-1/2" XO i 10891' ~--I4-1/2" OT1S X NIP, ID= 3.813" 10903' 4-1/2" TUBING TAIL 10898' ELMD TT LOGG® 12/29/89 11242' 7" X 4-1/2" BROWN 2-B PKR 11272' 4-1/2" OTIS XN NO-GO NIP, ID = 3.725" 11275' 4-1/2" WLEG DATE REV BY COMMENTS DATE REV BY COMMENTS 01/07/89 ORIGINALCOMFLETION 03/17/89 LAST WORKOVER 12/17/00 SIS-SLT CONVERTED TO CANVAS 02/23/01 SIS-LG FINAL 01/06/02 RN(TP CORRECTIONS PRUDHOEBAY UNIT WELL: 1230 PERMfT No: 188-1420 API No: 50-029-21891-00 SEC 18, TION, R15E 4857.94 FEL 2536.24 FNL BP Exploratlon (Alaska) Schlum~~r~er ~ska Data & Consulting Services ?5 Gambell Street, Suite 400 chorage,AK 99503-2838 TN: Beth Well Job # NO. 5385 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 02-31A 17-09 12-30 17-09 13-27A JX-02A 6148-00087 63S0-00042 B9RH-00003 AWJB-00047 BALL-00009 AWJI-00065 SCMT ~ TBG. CUT/FLOW DETECTION _ LDL MEM LDL USIT MEM LDL - 12/24/09 01/05/10 12/26/09 01/03/10 12/31/09 12/29/09 1 1 1 1 1 1 1 1 1 1 1 1 MPJ-19A L-103 AP3~-00075 BALL-00010 USIT RST/WFL ~- C 12/29/09 01/06/10 1 1 1 1 W-217 AYKP-00056 CH EDIT PDC USIT _ 11/27/Og 1 12-05AL1 V-224 D-14A 11-27 3-27/M-33 B2NJ-00025 AYKP-00059 AWJI-00060 AP3O-00068 68K5-00012 MCNL _ CH EDIT PDC USIT MCNL - C RST '$ - ~ RST 09/29/09 12/14/09 11/15/09 11/06/09 11/16/09 1 1 1 1 1 1 1 1 1 ASE ACKNOWLEDGE aFC G~~T wv c~r_ww r_ wun oc~r~ ~ownun_ ~u~ n.~..,.. ~..... ~.. :xploration (Alaska) Inc. technical Data Center LR2-1 E. Benson Blvd. r v~.~ vvr ~ cna.n ~ v: .-- ~~ Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ,~ , , ~ ~~a ~ ~ ~o~a C Schluiherner NO. Alaska Data Consulting Services Cor 2525 Gambol! Street, Suite 400 3 Anchorage, AK 99503 -2838 w �,r� p; n L. OJ ATTN: Beth 'Ye Well Job Log Description Date BL H -26 BOCV -00028 PRODUCTION LOG /'is, a /IA 10/06/09 1 12 -3i 1314B -00076 INJECTION PROFILE t)T_(a i 4 3 10/12/09 1 P2 -21 BOCV -00029 PRODUCTION LOG J 94 j.— (x'S`3 10/07/09 1 12 -35 B2NJ -00029 MEM PROD PROFILE '26 ,C6 3. 10/04/09 1 12 -30 B3S0 -00030 INJECTION PROFILE 0 i3O j_/-l. /V8 10/11/09 1 K -19AL1 B69K -00028 LDL (9n --JQ/ 0 .6-15 10/18/09 1 C -19B B5JN -00016 SCMT2 -b 6 10/11/09 V -105 AYS4 -00100 INJECTION PROFILE J I c� o (3 I ti_ j' 10/05/09 1 OWDW -SE 1369K-00021 RST U p 09/23/09 1 OWDW -NW B69K -00022 RST /00 /o qf �3 09/24/09 1 OWDW -SW B69K -00023 RST 1 .3 t Co 09/25/09 1 04 -26 B5JN -00014 RST 09/26/09 1 12 -05A 40015441 OH M D/L D EDIT, S r 6, 07/26/07 2 M -19B 09AKA0028 OH MWD /LWD EDIT ,b15-- j'3 01/29/09 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 1 BP Exploration (Alaska) Inc. A 1 Petrotechnical Data Center LR2 -1 900 E. Benson Blvd. A' MEM012ANI)IJM TO: Jim Regg --7 P.I. Supervisor ~ ~~ ~ ~ ~1 /~ ZC'J`~~' FROM: John Cnsp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, December 15, 2008 SliBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) NC 12-30 PRUDHOE BAY UNIT 1 Z-30 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `..~~~'` Comm Well Name• PRUDHOE BAY UNIT 12-30 API Well Number: 50-029-21891-00-00 Inspector Name: John Crisp Insp Num: mitJCr081211053507 Permit Number: 188-142-0 Inspection Date: 12/6/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 12-30Type Inj. ~ W ~ TVD ~ 8509 i jA ~ 180 ~ 4000~ 3900 ~ 3880 -'~ i P.T. ~ lasl oza TYPeTest ; SPTLTest psi ztn.zs ~I OA ~ zso zso ~ zso zao j Interval 4YRTST p~F P _ __ Tubing 460 460 i ~ 460 ~ 460 i _ Notes: 8.6 bbl's pumped for test due to 4,000 psi. test. No problems witnessed. ~ 'dlonday, December 15, 2008 Page 1 of I MEMORANDUM TO: Jim Regg ~J(,~ l 12~7(uC P.I. Supervisor C FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 03, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-30 PRUDHOE BAY UNIT 12-30 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv_, ~ e~'j' Comm Well Name• PRUDHOE BAY UNIT 12-30 Insp Num• mitCS081125072036 Rel Insp Num: API Well Number' S0-029-2 1 89 1-00-00 Permit Number: 188-142-0 Inspector Name: Chuck Scheve Inspection Date' 11/24/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 12-30 Well ~ IiType Inj. ~ `N ~ TVD aso9 IA zao s9so ~ ~ P.T.D~ Isalazo jTypeTest I sPT I Test psi zl2zzs pA ~ _~; z6o zao I ~ -~ Interval aYRTST p/F Tubing i zao ~ z6o ' I I rted due to multi le leaks on ca in head and annulus valve. Notes: Test abo p s g Wednesday, December 03, 2008 Page l of I ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ( 0ße- \1.., r31D 4-- Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us \.~.:7....t~V OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / OS-12 12/04/04 Joe Anders Packer Depth Pretest Initial 15 Min. 30 Min. Well 12-30 Type Inj. WAG TVD 8,509' Tubing 600 600 600 600 Interval P.T.D. 1881420 Type test P Test psi 4,000 Casing 420 4,000 3,980 3,980 P/F Notes: MITIA to 4000 psi pre-MI swap. This is the second test, first test IA lost 100/60, so it was repressured and repeated. 0 P v Well 12-33 Type Inj. WAG TVD 8,566' Tubing 480 480 480 480 Interval 0 /' P.T.D. 1890100 Type test P Test psi 2,250 Casing 300 2,250 2,200 2,180 P/F P Notes: MITIA to evaluate high IA pressure. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: AOGCC inspector Chuck Scheve declined witness. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting 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 0 = Other (describe in notes) Nores: . If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. SC¡:\NNE[J, DEe 2 1 2004 MIT Report Form Revised: 06/19/02 MIT PBU 12-30,33 12-04-04.xls BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp March 6, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 12-30 (PTD 1881420) Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for well 12-30. This request is for approval to continue WAG injection. A description summary of proposal and wellbore schematic are included. If you require any additional information or clarification, please contact either John Cubbon or me at (907) 659-5102. Sincerely, ~oe ^riders, ~.£. Well Integrity Engineer Attachments · . , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ ~ Iniection .. ,__. Alter casing _ Repair well _ Variance ~./~r Change approved program_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 4881' FNL, 5' FEL, Sec. 18, T10N, R15E, UM At top of. productive interval 2428' FNL, 4983' FEL, SEC 21, T10N, R15E, UM At effective depth 2471' FNL, 4943' FEL, Sec. 21, T10N, R15E, UM At total depth 2540' FNL, 4859' FEL, Sec 21 T10N, R15E, UM Operational shutdown _ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _X Perforate _ Other _ 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 5. Type of Well: Development Exploratory _ Stratigraphic M Service._X true vertical Casing Length Size Conductor 110' 20" Surface 3423' 13-3/8 Production 11161' 9-5/8" Liner 783' 7" (asp's 697606,5930730) (asp's 703270, 5928052) (asp's 703311,5928010) (asp's 703397, Perforation depth: measured O true vertical Open 11650 ~et 9244 ~ 11437 ~et 9061 ~et Plugs 6. Datum elevation (DF or KB RKB 74.0 feet 7. Unit or Property name Prudhoe Bay Uni 8. Well number 12-30 9. Permit nu~ number 0-029-21891-00 Field / Pool e Bay Field / Prudhoe Bay Oil Pool 11~ (01/25/1999) Meast Depth V 'X~ True vertical Depth 142' ~,, 142' 3S III, 600 sx ~:~ ) sx CS I 3455' 3194' .sxClass'G' ~ / ~19/37 / 8850' sxC,ass' ' / 16'-11214', 11320'-11326', 11338'-11360', 11374'-114~~ 8853'-8868',8960'-8965',8975'-8994',9006'-9056'. Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 13. Attachments Description 14. Estimated date for commencing NOVEMBER, 200 16. If proposal was verbally Name of approver 5-1 17# L-80 TBG @ 10809'. 5-1/2" x 4-1/2" XO @ 10809'. 4-1/2" 12.6# L-80 TBG @ 10903'. 4 12.6# L-80 TBG Isolation Assembly @ 11242' to 11275'. x 5-1/2" Baker SB-3A PKR @ 10789'; 9-5/8" x 4-1/2" Brown 2-B PKR @ 11242'. 5-1/2" Camco BAL-O SSSV Nipple @ 2189'. of proposal __X Detailed operations program BOP sketch __ Date approved 15. Status of well classification as: Oil __ Gas __ Service WAG INJECTOR ~'' Suspended __ 17. I hereby Signed Conditions of ~is true and correct to the best of my knowledge. Title: ADW Well Intergrity Engineer FOR COMMISSION USE ONLY Notify Commission so representative may witness Plug integrity ~ BOP Test _ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Questions? Call Joe Anders @ 659-5102. Date Prepared by DeWa},ne R. Schnorr 564-5174 IApproval no. order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 '~ ~ r~ ~ S B F L / 7 ?~m SUBMIT IN TRIPLICATE 12-30 Description Summary of Proposal 03/04/03 Problem: Class "A" WAG Injector Well History and Status Well 12-30 (PTD# 1881420) has been labeled as a "Class A" WAG injection well and requires Sundry approval to be put back on injection. The well has undergone thorough diagnostic testing since it was shut-in. No indications of T x IA or IA x OA ,~' communication have been identified. Recent events: > 09/28/02: MIT-IA Passed to 3000 psi ~. > 12/07/02: PPPOT-T Passed, PPPOT-IC Failed (State Notified) ~ > 1/13/03: MIT-IA Passed to 2500 psi (AOGCCC wit) ~ well. This Sundry request is to allow for continued WAG injection of this C1 "' The following supports the request: · A MIT-IA passed on 01/13/03 to 2500 psi, demonstrating competent tubing and production casing. · Pressures and injection rates will be monitored daily and checked for indications of a tubing leak. · A MIT-IA will be conducted every 4 years to confirm tubing and production casing integrity. Proposed Action Plan 1. Allow well to continue WAG injection. 2. Monitor wellhead pressures and injection rates daily. 3. Perform a MIT-IA every 4 years. 4. Stop injection and notify the AOGCC if there is any indication of loss of tubing or production Casing integrity. ( TREE= McEVOY GEN 4ISAFETY NOTES : I .AGTL~TOR = AXELSON KB. B_EV = 74' BF. ELEV '" KOP = 1600' MaxAngle= 49@5800' I 2189' HS-1/2"CAMBAL-OSSSV NIP, D=4.562" Datum MD = 11220'~ I DatumTVD = 8800' SS ST MD '[VD DEV TYPE VLV LATCH PORTI DATE 1 4299 3811 45 AVA POGLM BE Minimum ID 2.34" 4278' ~ L 2 7822 6252 44 AVA POGLM BE Top of AVA POGLM I i78°1' X ~ I' 10789' Hg-5/8"XS-1/2"BAKERSB-3AI:KP, I ITOP OF 4-1/Z' 'rBG H 10809' LNRH 0.7' !" I' 10891' H4-1/2"OTISXNIP, ID=3.813"I PERFORATION SUIVIVIA RY REF LCX3: BH~ ~ 01/04/89 ANGLEATTOP PERF: 30 @ 11196' Note: Refer to Produclion DB for hisk)rical perf data SIZE SPF INTERVAL Opn/Sqz D~,TE 3-3/8" 4 11196-11214 O 06/01/89 , 3-3/8" 2 11320-11326 O 06/01/89 , ,3-3/8" 2 11338-11360 O 06/01/89 ' '3-3/8" 4 11338-11358 O 08/11/93 3-3/8" 2 11374-11432 O 06/01/89 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOEBAY UNIT 01/07/89 ORIGINAL COMR. ETION WELL: 12-30 03/1 7/89 LAST WORKOVER PERIVlT No: 188-1420 12/17/00 SIS-SLT CONVERTED TO CANVAS APl No: 50-029-21891-00 02/23/01 SIS-LG FINAL SEC18, TION, R15E 4857.94 FEL 2536.24 FNL 01/06/02 RN/TP CORRECTIONS BP Exploration (Alaska) i SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 11196-11214 O 06/01/89 3-3/8" 2 11320-11 326 O 06/01/89 3-3/8" 2 11 338-11360 O 06/01/89 3-3/8" 4 11 338-11358 O 08/11/93 3-3/8" 2 11374-11432 O 06/01/89 DATE REV BY COMMENTS DATE REV BY COMMENTS 01/07/89 ORIGINAL COMFLETION 03/1 7/89 LAST WORKOVER 12/17/00 $1S-SLT CONVERTED TO CANVAS 02/23/01 SlS-LG FINAL 01/06/02 RN/TP CORRECTIONS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / Drill Site 12 01/14/03 Chuck Sheve We11112'3° I Type Inj. P'T'D'I1881420 I Type test Notes: Test required to return c Welll I Type Inj. P'T'D'I I Type test Notes: Welll I Type Inj, P.T.D.I I Type Notes: WellI Type Inj. P.T.D.I Type Notes: WellI Type Inj. P.T.D.I Type Notes: Packer Depths (ft.) on Pretest Initial 15 Min. 30 Min. j. Test Details: Class "A" Well. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting 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) MIT Repod Form Revised: 06/19/02 12-30 MIT PBU 01-14-03 WELLHEAD PACKOFF TESTING FORM WELL: BP WelID.S.12-30 DATE: 121712002 TESTED BY: CFW TEST FOR: TYPE & GEN McEvoy IV Well Status: TBG: CONTROL: INITIAL PRESSURE DATA TYPE: 1800 IA: 1500 1850 BALANCE: 2700 OA: 0 Tubinq Hanger Test PASS FAIL Pressured To: 5000 Press. @ 15 min: 5000 Press. @ 30 min: 5000 Test Port Press. @: 900 Bled to 0 Psi YES / NO Were Lockdown Screws Tightened ? YES / NO Torqued to 600 ft/~bs Comments: Bled off test void pressure to 0, Rig up and test tubing hanger void to 5000 psi, for 30 minutes. Pressure Test Good. Note; State man was notified for test, Inner Casing Hanger Test PASS FAIL Pressured To: Press. @ 15 min: Press. @ 30 min: Test Port Press. @: 1500 Bled to 0 Psi YES / NO Were Lockdown Screws Tightened ? YES / NO Torqued to 600 fi/lbs Comments: Test void pressure would not bled down, Re-torque LDS pressure still would not bleed down, Y-B seal has been packed off with green packing unable to re-pack seal, Suggestion; Bleed O,A, and I,A, down so we can try to purge old plastic from seal and re-energize with new plastic, Wavier Check List Date: Order(s): Item YfN Comments 1. Notified of pressure communication or leakage? 2. Diagnostics planned/nm? Method? 3. Form 10403 submitted requesting waiver? 4. Alternate MIT passed? Method? AOGCC witnessed? 5. MIT Part II verified? How? 6. Area or Review examined? Definition of Terms T OA MIT CMIT LLRT Tubing Inner Annulus (tbg x csg) Outer Annulus (csg x csg) Mechanical Integrity Test Combined test of annular spaces Leak Loss Rate Test Integrity # Barriers Condition AOGCC Notification Enhanced Operational Restrictions Category Affected Requirements Monitoring Requirements1 Normal 0 Full wellbore integrity MIT - 4 years Water, slurry, gas, MI upon approval' .. TxlA communication (tubing Next business day if 200 psig Annual MITIA/LLRT 3 .. 1 leak; packer leak quantifiable) change'in annulus pressure CMIT TxlA - 2 yrs Water only IAxOA communication Annual M1TIA & CM1T IAxOA Water only; annulus PSV w/alarms & set points 2 1 Production casing leak MIT Tubing - 2 yrs ' for ESD < MIYP of next outer casing TxlAxOA communication ,, Kill well; submit Sundry (10403) Outlining 1 >1 Release beyond wellbore ' Next business day Daily reports until well secured · repairs, ~In addition to Monthly RepOrt of Daily Operating Parameters; Annulus Pressure Monitoring Matrix applies to the following well configuration: 1. Conventional completion per regulations; monobore on case by case basis , 2. Production casing designed ,for shut-in tubing pressure 3. USDW exemption or finding of no aquifer Reviewing Engineer: Recommended Action: Integrity Category: waiver 'ehklst.doe: 8/2/2002 RE: 12-30 Sundry Notice Subject: RE: 12-30 Sundry Notice Date: Fri, 14 Mar 2003 17:45:06 -0600 From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> To: Winton Aubert <Winton_Aubert~admin. state.ak.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> Winton, As per our phone conversation this afternoon and your e-mail request below, we do wish to cancel our sundry application for the 12-30 well (No. 303-070). We agree that there is no evidence of communication at this well. The reason that we submitted this sundry was to comply with condition 1 of the commission's letter to Mr. Randy Frazier, dated October 29, 2002 concerning the return of class A/B3 injectors to service. Thank you for your verbal approval to immeditately return of this well to injection and for waiving the requirement for an approved sundry to operate this well. Sincerely, John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 ..... Original Message ..... From: Winton Aubert [mailto:Winton Aubert@admin.state.ak.us] Sent: Thursday, March 13, 2003 8:53 AM To: NSU, ADW Well Integrity Engineer Subject: 12-30 Sundry Notice RE: DS 12-30 Sundry Notice requesting variance for WAG inj. ection. AOGCC sees no reason for this variance, as no tubing or annular communication exists in 12-30. We believe WAG injection can continue without variance. Accordingly, please cancel in writing the Sundry Notice dated 3/4/03 (No. 303-070). E-mail is acceptable. you for your attention to this matter. Winton Aubert AOGCC 793-1231 Thank MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill ~ DATE: January 14, 2003 Commissioner /~¢¢~~o~ SU BJECT: Mechanical Integr it yT es ts THRU: Tom Maunder BPX P.I. Supervisor . 2\~ DS 12 PBU FROM: Chuck Scheve Prudhoe Bay Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D. 179-032 TypetestI P Test psi 2121 Casing 175 2 0 2 0 2 0 P/F P Notes: A/B3 well. Required 41.6 bbls to fill IA WellI 12-23 ITypelnJ. I, N [ T.V.D. I 8380 Tubing 0 0 0 0 Interval O P.T.D. 184-058 Type testI P Test psi 2095 Casing 50 2480 2360 2240 P/F _F OA 100 2480 2400 2340 Notes: A/B3 well. Required 61 bbls to fill IA WellI 12-30 ITypelnj.I N I T.V.D.I 8509 I Tubingl 1700'I 1700 I 1700 I 1700 Ilntervall O P.T.D. 188-142 IType testI P Test psi 2127 Casing 20 2500 '2430 2420 P/F I P Notes: A/B3 Well., Required 22 bbls to fill IA WellI I Type Inj. I T.V.D. P'T'D'I IType testl I Test psiI [Tubing Notes: I I Type Inj. I T.V.D. IType testl I Test psil ITubing P.T.D. P/F I' Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover' O= Other (describe in notes) Test's Details I traveled to BPXs Drill Site 12 and witnessed MITs on Wells 12-02, 12-23 and 12-301 Wells 12-02 and 12-30 appeared to have mechanical integrity during the 30-minUte pressure test: Well 12-23 has known IA .x OA communication and this test was performed with IA and OA in combination. The test was held for an additional 15-minute'period showing the OA pressure loss stabilized at 60 psi and the IA at 100 psi per 15-minute period. M.I.T.'s performed: _3 Number of Failures' 1_ Attachments: Annular Communicstion History Total Time during tests: 8 hours cc: MIT report form 5/12/00 L.G. 030114-MIT PBU DS 12 A B3 CS.xls $CANT ED I' AR } O 200:] 2/17/20O3 Annular Communication History Well 12-02 Type WAG Problem: T x IA Communication - AOGCC Sundry (slight) IA x OA Communication (slow) *** Class B3 - Well SI and Secured Arctic Pack plugs annular valve ' Status: SI--B3 well. OUTDATED: Waiver Date 05-17-00 Waiver conditions: WAG allowed; IA to max-2500 psi, OA to 2000 psi > 06/21/98: MITIA Passed for pit dewatering; MITOA @ 2000 psi Passed for WC > 07-19-98: DSO Called can't bleed OA. May be thick arctic pack problem. > 07-24-98: MITOA Passed. IA x OA PO bled to 0 psi. > 03/17/00: DSO called, OA tracking IA, OA pressure 1500 psi, not waivered for service over 1000 psi. > 03/29/00: PPPOT-IC Passed (AC EVAL). > 04/22/00: DHD bled 5 bbls Artic Pack from well; charged with diesel > 05/21/00: Distributed waiver; IA @ 2500 psi, OA @ 2000 psi > 06/27/01: MITIA Passed > 05/20/02: MITIA Passed, AOGCC witnessed > 09/24/02: .MIT IA. to 3500 psi Passed MIT-OA failed. > 11/26/02: NFT-OA Passed > 12/07/02: PPPOT & PPPOT-IC Passed (State witnessed). Planned Action: **'137-B3 Well .... Obj: Eval IAxOA comm 1. FB: MIT-OA to 3000 psi - FAILED 2. DHD: Pressure IA to 2000# with gas, NFT-OA, monitor OA BU (use chart).- PASS 3. DHD: Bleed IA and OA. Shoot IA FL. 4. DHD: AOGCC witnessed MbT-IA. 5. WIE: Submit Sundry for WAG injection. OUTDATED WAIVER REQUIREMENTS: Waiver for Slow TxlA comm on MI, Req Tests: Annual MITIA Annual MITOA Date Comment, 1/13/20O3 1/12/2003 12/7/2002 11/26/2002 11/22/2002 11/20/2002 11/18/2002 11/18/2002 11/17/2OO2 11/17/2002 11/16/2002 10/14/2002 10/5/2002 9/24/2002 1/14/2003 TIO= Vac/150/120 Prep for MITIA (Monitor Post IA bleed), lAP increased 70 psi; OAP increased 40 psi from yesterday. TIO= Vac/900/700 Prep for MITIA. IA FL @ 1350' (35 bbls), OA FL near surface. Bled lAP to 80 psi and bled OAP down to 80 psi. Final WHPs= Vac/80/80 TIO = 200/1250/720 PPPOT-T PASSED. (Witnessed by AOGCC inspector John Crisp) Bled off test void pressure to 0 psi. Rig up and'test tubing hanger void to 5000 psi for 30 mins. Lost 100 psi in first 15 rains, 0 in second 15 mins, total of 100 psi in 30 mins'- Passed. PPPOT-IC PASSED. Bled off test void pressure to 0 psi. Rig up and test casing hanger void at 3000 psi. Lost 100 in first 15 mins, 0 psi in second 30 mins, total for 100 psi in 30 mins - Passed. T/I/O = SI/1500/900. NFT - OA PASSED. (Waiver Eval). OA FL 30'. Pressured IA to 1960 psi. OAP increased to 950 psi. Bled OA from 950 psi to 07 psiin 55 min. Mostly gas with some fluid. Initial Gas Rate = 720 scf/ph at 7 psi. Started'3 hour test. Final Gas Rate = 21 scf/ph at <1 psi. Conducted 3 hour test with 1900 psi on IA. Monitored pressures for 30 min. Bled lAP to 1500 psi.. Final WHP's = SI/1500/4 T/I/O = 200/1640/760. Monitor OA BUR. OAP increased 50 Psi since 11/20/02.' RD Chart Recorder, test Completed. T/I/O=0/1680/710 Monitor OA BUR (21:05)..OA pressure increased 180 psi in 2 days T/I/O=SI/1640/480. Monitor WHP's. (Monitor OA BUR). Pressured IA to 1880 psi with AL'gas. OAP increased to 530 pSi. Final WHP's=SI/1880/530. T/I/O=SI/1800/620. Monitor WHP's. (Monitor OA BUR). T/I/O=Slii620/420 Monitor WHP's ( OA bulld rate ). T/I/O=SI/1670/390. Monitor WHP's. (Monitor OA BUR). T/I/O=SI/100/100. (Monitor OA BUR). RU 3 pin recorder #9. (Green to IA), (Red to OA). IA FL @ 425'. OA FL @ surface. Pressured IA to 1840 psi in 30 minutes with AL gas from 12-03. OAP increased 330 psi. Final WHP's=SI/1840/430. TIO= VAC/240/320 (OA Project) T/I/O = VAC/150/450. Monitor WHP's [post MIT] T/FO = 200/160/0. MITIA TO 3500 Psi (PASSED); MITOA TO 3000 PSI (FAILED). OA PRESSURED UP Page 1 of 5 Date Comment 9/23/2OO2 9/20/2002 8/29/2002 TO 3000 PSI FOR 3 MINUTES THEN FELL QUICKLY TO 900 PSI. ESTABLISHED LLR OF .5 BPM @ 1000 PSI DOWN OA. NOTIFY DSO OF STATUS - WELL LEFT SHUT IN. FINAL T/I/O = 200/100/810 T/I/O = VAC/140/0 IA FL @ 120'. T/I/O = 0/200/60 (Prep for MITOA) OA FL @ 30'. ***Continued from WSR 08-28-02*** 8/29/2OO2 8/29/2OO2 8/28/2002 Pump 22 bbls 50/50 meth/water down I/A @ 5 bpm/400 psi. See pressure increase to 1350 psi w/22 bbls away. F/P flowline & tubing w/140 bbls (total) 50/50 meth/water. Shut in & monitor.. Bleed IA & OA, monitor OAP during well kill and secure FREEZE PROTECT TUBING & FLOWLINE W/140 BBLS METH-WATER FROM MINI-MOD Rig up Dowell pump unit. PJSM. Pressure test hardline to 3500 psi, secondary valve leaking at.stem, call valve crew. 8/28/20O2 8/28/2002 8/27/2002 5/21/2002 ,5/2O/2OO2' 5/20/2O02 5/20/2002 10/20/2001 6/27/2001 6/27/2001 12/30/2000 5/20/2000 5/13/2OOO 5/13/2000 4/27/2OOO 4/25/2OOO 4/22/2000 1/14/2003 ***Job Continued on WSR 08-29-02'** T/I/O = SI/210/60 Bleed IA & OA, monitor OAP during well kill and secure. Initial OA FL @ 20' (1 bbl). Bled OA from 60 psi to 0 psi in 5 mins (all gas), monitored for 15 mins and it increased to 50 psi, repeated two times with similar results. Initial IA FL @ 710' (18 bbls). Bled IA from 210 psi to 100 psi in 1.5 hrs (gas & 1 bbl of fluid). Schlumberger loaded IA with 22 bbls of methanol and pressured to 1300 psi. Bled IA from 1300 psi to 90 psi in 2 hrs (gas & 3 bbls). LRS pumped from skid to freeze protected F/L (40 bbls) and pumped 93 bbls of 50/50 methanol down the TBG, SI pumping at 0322 hrs WHP's =vac/120/40. Started 4 hr monitor. 0422 hrs=vac/90/40. 0522 hrs WHP's=vac/120/40. 0622 hrs=vac/130/40. 0722 hrs W H P's=vac/140/40 T/I/O = SI/500/150 Monitored WHP's. Bled OA from 150 psi to'20 psi. OA increased from 20 psi to 100 psi in'l hr. Bled IA from 500 psi to 150 psi, would not bleed below 150. Final WHP's = SI/150/100 T/I/O =SI/600/200. Well is SI. (IA FL for Judy Golding). IA FL @ 210' (13 bbls). T/FO = 1450/750/1200. Monitor WHP's. (Post AOGCC MIT - iA). AOGCC MIT - IA to 2380 psi PASSED. (4 - Year Routine Test, AOGCC Witnessed, Chuck Scheve) T/I/O = 1450/1320/1240 Prep for MITIA. IA FL at 60' (1.5 bbls). T/I/O = 1500/1300/1300. AOGCC MIT - IA to 2380 psi. PASSED (4 Year Routine Test, AOGCC Witnessed, Chuck Scheve). Pressured IA to 2380 psi and started 30 min test. IA lost 30 ps! in 15 rain and a total of 30 psi in 30 min. Bled IA to 700 psi. Final'WHP's = 1500/700/1300. DRIFT W/5.95 GAUGE RING TO 2200'. RIH W/SLGS, PRONG. LATCH SSSV. LOST SPANGS. RIG UP LRS. puMp METH/WATER. FREED UP, SHEARED OFF. PUMPED 80 BBLS SCHMOO B GONE WHILE BRUSHING TBG TO 2200'. FLUSHED W/30 BBLS ME'TH/WATER. PULLED 7"CA.WRDP-2 SSSV SER#HES-921. SET 7"CA.WRDP-2 SSSV SER#HDS-29. CLOSURE TESTED FROM 1350-1000PSI, GOOD TEST. PUT WELL BACK ON INJECTION. MIT-IA TO 2500 PSI. (PASSED) [Ann Comm] T/I/O = 1400/1150/1000. Temp = Warm. MIT- IA to 2500 psi for WC. PASSED. IA FL @ 225'. (5.7 BBLS) Bled IA from 1150 psi to 250 psi in 2 hours. Bled gas then somefluid then gas again. Post bleed FL @ 540' (14 BBLS). Pressured IA to 2500 psi with 35 bbls of diesel. Started 30 min test. IA lost 10 psi in 15 min and a total of 10 pSiin 30 min. Bled IA to 300 psi. Final WHP's = 1400/300/1000 PUMP 447 BBLS OF SCHMOO-B.@ 2.5 BPM Updated waiver for IA service to 2500 psi, OA to 2000 psi, annual MITIA @ 3000 psi, MITOA @ 2000 psi w/IA < 500 psi. Dropped PPPOT; no evidence of leaking. MITIA PASSED/MITOA PASSED/PPPOT-IC PASSED [Ann Comm, MIT, pT Tbg-Csg] T/I/O = 1930/680/200 MITIA to 2500 psi PASSED; IA FL was at 180' (4.5 bbls). Bled IA from 680 psi to 500 psi in 4 hrs (10 bbls). MITIA lost 40 psi in 15 mins and a total of 50 psi in 30 mins. Pumped 30 bbls of methanol down IA. MITOA to 2000 psi PASSED; OA FL was near sUrface. Bled OA from. 200 psi to 60 psi in 5 mins. Bled IA to OA. OA pressure was 1700 psi. Pumped 0.25 bbls to raise OA pressure from 1700 psi to 2000 psi OA lost 20 psi in 15 mins and 40 psi total in 30 mins. PPPOT-IC to 3000 psi PASSED; lC PO was at 0 psi. Pressured lC-PO to 3000 psi lC-PO lost 50 psi in 15 mins and a total of 50 psi in' 30 mins. FINAL WHPs=1930/400/20 T/I/O = 2850/1300/350 Monitor WHP's post OA bleed. IA increased from 1150 psi to 1300 psi in 2 day. OA increaSed from 220 psi to 350 psi. T/I/O = 2900/1150/220 Monitored WHP's post OA bleed. OA increased from 100 psi to' 220 psi in 3 days. ClRC OUT ARCTIC PACK IN OA [Ann Comm, CIRC OUT ARTIC PACK] Page 2 of 5 Date Comment 4/22/2000 4/22/2000 4/12/2000 4/12/2OOO 4/11/2000 4/9/20OO 3/29/2OOO 7/28/1999 7/9/1999 6/25/1999 6/23/1999 · 6/23/1999 1/23/1999 7/29/1998 7/28/1998 7/26/1998 7/24/i 998 7/19/1998 1/14/2003 T/I/O = 3000~850~300 Arctic Pack ClRC-OUT; CA FL @ surface (Arctic Pack). R/U 1" hose to CA. Started bleeding CA to open top tank while slip streaming diesel in. Bled CA to 100 psi. Pressured CA to 2000 psi. Monitored CA for 15 mins, CA increased 100 psi. Bled CA to 50 psi ( diesel and Arctic pack). Hose plugged off, removed hand full of rocks from fittings. Repressured CA to 2000 psi, monitored CA for 30 rains, CA pressure increased to 2100 psi. Bled CA back down to 100 psi getting back clean returns. DSO brought well BOL when we first started job. Pumped a total of 15 bbls of diesel. Final WHP's = 3000/100/120. TAG TD W/2.60" CENT @ 12,276' ELM = 24' ABOVE TARGET. [Tag] BLED CA (PURGED ARCTIC PACK WITH DIESEL) [Ann Comm] T/IlO = 3000/1400/1650 BLEED CA (arctic pack); Bled CA from 1650 psi to 1500 psi (plugged up) then pumped diesel into CA. Repeated bleed and pump procedure many, many times. Bled a total of 1 bbl of arctic pack and pumped a total of 6 bbls of diesel. Final WHP's = 3000/1400/500. JET PAST SLICKLINE TAG OF 1880' W/O SEEING OBSTRUCTION. SPOT 5000# SAND. TAG AND COMPACT SAND TOP AT 12,295'. FREEZE PROTECT TUBING 200'. RETURN TO INJECTION [FCO] TAG IRON SULPHITE AT 1882' SLM W/3.25 CENT. [Tag] T/I/O = 3050/1500/1500 AC evaluation IA x CA communication: lC hanger: PPPOT-IC to 3000 psi PASSED: Test port @ 0+ psi. Flushed through got good returns. Pressure lC hanger to 3000 psi lost 50 psi in 30 mins. POT-lC PASSED:monitored test port during IA and CA bleed doWn with no increase in pressure on test port. Packoffs do not appear to be IA x CA communication problem. IA FL @ surface. Bled IA from 1500 psi to 900 psi in 10 mins..CA FL @ surface (Arctic pack). DSO has been bleeding CA. Bled CA from 1500 psi to 420 psi in 30 mins. Mostly arctic pack and slugs of gas. Had to keep pressuring up on CA with gas, hose kept plugging off. May need to stage a open top tank and bleed off arctic pack. Monitored CA pressure for 30 mins With no increase in pressure. IA increased 100 psi. Final WHP's = 3050/1000/420. SPLITS:11952'-11992'=10%, 12102'-12120'=0%, 12128'-12140'=0%, 12155'-12165'=35%, 12170" 12203'=0%, 12204'-12214'=0%, 12222'-12240'=0%, 12257'-12291 '= 10%, 12301 '-12314'=45%, 12324'-12331 '=0%. DRIFT TO 12,372' CORR TO ELM W/2.056" CENT. [Tag] DRIFT TO 12274' ELM W/2.625" CENT. 84' FILL (PRE-IPROF) [Tag] MITIA TO 2500 PSI PASSED. MITOA TO 2000 PSI PASSED. IA X CA PKO'S OK. [Ann Comm, MIT] T/I/O = 1500/900/650 MBA to 2500 psi PASSED (Waiver Compliance); IA FL @ 35' ( 2 bbls). CA FL @ surface. Bled IA from 900 psi to 500 psi in 15 mins, (FTS). MITIA lost 30 psi in 15 mins, 10 psi in the second 15 mins, for a total of 40 psi in 30 mins. Pumped a total of 6 bbls of methanol down the IA. Bled the IA into the CA post MITIA. MITOA to 2000 psi PASSED; MITOA lost 20 psi in 15 mins, 0 ps! in the second 15 mins, for a total 20 psi in 30 mins. Pumped a total of 1 bbl of methanol down the CA.. IA X CA Hanger; Stung into test port had 30 psi,. bled to O psi. Flushed through test port with hydraulic fluid and got back good returns. Monitored test port during MIT's, with no increase in pressure. Final WHP's = 1500/350/160. T/I/O = 1550/1550/1400 Monitored WHP's. Post CA bleed. WL ran 'TT Plug in straddle assy, reran SSSV? T/I/O = 1300/900/230 MITIA to 2530 psi PASSED post Pit De-watering: IA FL @ surface, CA FL @ near surface. Bled IA from 900 ps to 400 psi. Started pumping down the IA. MITIA lost 20 psi in 15 mins, 10 psi in second 15 mins, 30 psi total. Pumped 6 bbls of methanol total. Bled CA from 250 psi to 60 psi in 5 rains. Final WHP's = 1300/350/60. T/I/O = 1.300/1000/80 Monitor WHP's. T/I/O = 900/1350/1300 AC Eval IA x CA; IA.FL @ surface, CA FL @ surface. IA X CA Pack-offs: Test port @ 100 psi' bled to 0+ psi. Monitored test port during bleed down and MITOA. With no increase in pressure. No indication of leaking pack-offs. Bled CA from 1300 psi to 200 psi plugged off 1/2" hose. Rigged up 1" hose to 40 bbl open top tank. Bled CA to open top while slip-streaming diesel down 1" hose. Bled back 5 bbls of Arctic Pack into tank. MITOA to 2000 psi PASSED: MITOA lost 30 psi in 15 mins, 0 psi in second 15 mins, 30 psi total. Pumped 3 bbls to do' MITOA. Pumped 15 bbls of diesel total. Open top tank has 20 bbls of diesel and Arctic Pack. Final' WHP's = 900/1350/20. T/I/O =1700/1540/1220 IA FL @ surface.. CA FL @ surface. (Fluid/Arctic Pack). Page 3 of 5. Date Comment 7/12/1998 T/I/O = 1250/1750/1375 R/D 3 pen chart recorder (post de-water inj) 7/7/1998 6/30/1998 6/25/1998 6/23/1998 6/21/1998 6/20/1998 8/1/1997 7/31/1996 7/21/1996 7/20/1996 7/15/1995 7/14/1995 2/12/1995 7/3/1994 10/21/1993 10/16/1993 10/12/1993 10/11/1993 9/28/1993 9/27/1993 9/26/1993 9/25/1993 9/17/1993 9/11/1993 7/11/1993 1/14/2003 T/I/O = 1300/1760/320 Changed 3-pen chart T/I/O = 1300/1850/250 Monitored WHP's pit De-watering support. 'Changed chart. T/I/O =1400/1750/200 Monitor WHP's. T/I/O = 1500/700/300 Staged 3 pen #8 for pit De-watering. T/I/O =1500/180/300 MITIA to 2500 psi PASSED (Pre de- watering); IA FL @ 1230'. OA FL near surface. Bled IA from 180 psi to 1 hr 30 mins. MITIA lost 20 psi in 15 rains, 10 psi in the second 15 mins, for a total of 30 psi in 30 mins. Pumped a total of 38 bbls of methanol down the IA. Final WHP's = 1500/200/100. MITOA @ 2000 psi Passed T/I/O = 1500/900/900 Bleed Prep for MITIA: Well is on line injecting Water. IA FL @ 210' (5.5 bbls), OA FL @ near surface. Bled IA from 900 psi to 80 in 6 hrs. Bled back 10 bbls of fluid. Bled OA from 900 psi to 200 psi, could not bleed pressure off of OA because of arctic pack plugging. Tbg x IA PACK OFFS; Test port @ 5000 psi. Bled to 0 psi. IA x OA Packoffs: Test port @ 100 psi bled to 0 psi. Monitored during bleed down with no increase of decrease in pressure. Final IA FL @ 300' and still falling out. IA pressure increased from 80 psi to 150 psi in 15 rains. Final WHP's = 1500/150/300. T/I/O=400/880/800. PPPOT IA X OA PASSED; Test port @ 200 psi, bled to 0 Psi and flushed through. Pressured to 3000 psi and lost 0 psi total in 30 mins. MIT-IA PASSED; MIT-IA to 2470 psi lost 40 psiin 15 mins. and 55 psi total in 30 mins. Initial IA FL @ 130' (3.3 bbls), bled IA from 880 psi to 350 psi in 1 hr (all gas). Pumped 8 bbls of methanol total down IA. MIT-OA PASSED; MIT-OA to 2000 psi lost 35 psi in 15 mins. and 50 psi total in 30 mins. Initial OA FL near surface, bled OA from 800 psi to 150 psi in 30 mins (all gas). Pumped 2 bbls of methanol total down OA. Final WHP's = 400/350/150. T/I/O=1450/620/400 PPPOT IA X TBG PASSED; Stung into TBG X IA hanger test port pressure at 10 psi. bled to 0 psi. Pressured PO to 4000 psi. PO lost 140 psi in 30 rains. PPPOT IA X OA PASSED; Test port pressure at 50 psi bled to 0 psi. Test port pressured to 3000 psi. Test port lOst 130 psi in 30 mins. FINAL W HPs= 1450/620/400 T/I/O=1400/450/500. MIT-OA PASSED for Waiver Compliance. Bled OA from 500 psi to 440 psi. Pumped 1 bbl of diesel to.pressure OA to 2010 psi. OA lost 50 psi in 30 mins. FINAL WHP's = 1400/520/250. T/I/O=930/650/500. MIT-IA PASSED for annual required Testing. Bled IA from 650 psi to 300 psiin 5 minsl Pumped 8 BBLs methanol to pressure IA to 2300 psi. IA lost 40 psi in 30 rains. FINAL WHPs=1000/325/500 T/I/O=1800/1150/900. MIT-IA PASSED; Bled IA from 1150 psito 300 psi 30 min. Pumped 9 BBLs methanol pressured IA to 3000 psi. IA lost 10 psi in 30 minutes. MIT-OA PASSED; Bled OA from 900 psi to 0 psi in 15 min. Bled IA to OA (2000 psi) Lost 260 psi in 15 min. restarted test. Pumped .5 BBLs of methanol to' pressure OA to 2000 psi Lost 40 psi in 30 minutes. Final WHPs=1800/550/500. Annual waiver compliance work comPlete. T/I/O=3250/1125/900. PPPOT IA X OA PASSED; Pressured test port to 2010 psi lost 50 psi in 30 min. IA FL @ 165' (4.25 BBLs) OA FL near surface. Will finish MIT-OA/MIT-IA tomorrow for waiver compliance. T/I/O=1100/850/820 Tbg x IA PPPOT Passed. Zero loss of pressure in 30 min. IA x OA PPPOT Passed. Lost 100 psi in 30 min. Initial prep: Flushed through with clean hyd. and pressured to 3000 psi. 'Performed State witnessed MIT-IA to 2980 psi: PASSED. -20 psi/30 min. In house waiver approved. Allows continued WAG injection & 2500 psi max on IA. Circulated inhouse Waiver to allow well's IA to operate at a max preSs of 2500 psi while on MI. Mailed Form 403 SundrY Notice to AOGCC. AAI WWN will be prepared & circulated for approval. Notified AOGCC of Tbg x IA Communication: Verbal approval granted to continue WAG injection, with IA operating up to 2500 psi. SundrY notice will be filed\ AAI waiver tofollow. T/I/O=700/900/300. Shut in water injection and let TP drop to zero. Loaded IA & performed 3000 psi MIT-IA: PASSED. Lost 100 psi/30 min. Ready to notify AOGCC &issue internal waiver. T/I/O=700/900/300, SWI. MIT-OA to 2000 psi PASSED, loSt 50 psi/30 min. Tbg x9 PPPO'E to 4000 psi PASSED, lost 70 psi/30 rain\ 9x13 PPPOT to 3000 PASSED, lost 120psi/30 min. Planning MIT-IA today, then notify AOGCC. T/I/O=750/950/340. Rigged down 3 pen recorder following confirmation of Tbg x9 communication\ planning MIT-IA & packoff test, then report to AOGCC. T/I/O=550/900/300 on SWI. Changed 3 pen chart. Tbg x9 communication confirmed and documented. 9-5/8" casing pressure builds from 300 to 800 psi in -25 hrs whenbled. Tbg pressure was averaging 800. psi at the time. T/I/O=1000/1150/350, well On water injection. Changed 3-pen chart. The IA was oPerating. @ 1150 psi thru week with no bleed downs noted. It is recommended to bleed IAto below 500 psi.when its press goes above 1000 psi sO that build up can be recorded on the 3-pen. T/I/O=1050/1000/350. Rigged uP 3 pen recorder to evaluate for UIC qtrly reporting. Known Tbg x9 problem on MI. T/I/O=1275/1400/350. Changed 3 pen chart. Page 4 of 5 Date Comment 7/8/1993 7/4/1993 6/28/1993 6/14/1993 6/10/1993 6/9/1993 6/8/1993 6/7/1993 T/I/O=1250/1150/350. Checked 3 pen chart. T/I/O=1250/1250/300, injecting water. Changed 3 pen chart. 9-5/8" stayed -1400 psi\ tbg -1000 psi for the whole week\ no bleeds. T//9/13=1000/1400/300, well on water injection. Changed 3-pen Chart. 9 was at a constant 1400 psi press. T/I/O=1100/900/350,well on water injection. Changed 3-pen chart. Prior to the MIT the 9 was tracking the tbg. After the MIT the well was injecting at a reducedrate for 3 days & no abnormalities were noted. When the inj rate was increased the 9 started to climb from 600 psi to 950 psi. T/I/O=500/1020/400, well injecting water. MIT on 9-5/8" passed to 3000 psi. The dP/dT=-95 psi/30 min. Prior to test the 13 was bled to 200 psi(all gas). Final pressafter bleed down: T/I/O=0/460/300. T/I/O=1250/1300/450, Well on water injection. Check 3-Pen. T/I/O=1300/1280/400, injecting water. Stung into Tbg x9 packoff, had zero psi. Changed buttonhead fitting & performed PPPOT to 4000 psi: PASSED. -140 psi/30 min. Rigged up 3 pen recorder. IA FL @ surface. Planning MIT-IA. DSS notified us of Tbg x9 problems. Will perform AC screening. Last MIT-IA 7/18/91 Passed. 1/14/2003 Page 5 of 5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown- Stimulate _X Plugging _ Perforate _ SCHMOO-BE-GONE Pulltubing_ Altercasing_ Repairwell_ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development- RKB 74 feet 3. Address Exploratory- 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Senrice_X Prudhoe Ba Unit 4. Location of well at surtace 8. Well number 4881' FNL, 5' FEL, Sec. 18, T10N, R15E, UM (asp's 697606, 5930730) 12-30 At top of productive interval 9. Permit number /approval number 2428' FNL, 4983' FEL, Sec. 21, T10N, R15E, UM (asps 703270, 5928052) 18&142 At effective depth 10. API number 2471' FNL, 4943' FEL, Sec. 21, T10N, R15E, UM (asp's 703311, 5928010) 50-029-21891-00 At total depth 11. Field /Pool 2540' FNL, 4859' FEL, Sec. 21, T10N, R15E, UM (asp's 703397, 5927944) Prudhoe Bay Field / Prudhoe Ba Pool 12. Present well condition summary Total depth: measured 11650 feet Plugs (measured) PBTD tagged ~ 11437' (01/25/1999) true vertical 9244 feet Effective depth: measured 11437 feet Junk (measured) true vertical 9061 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 2150 Ibs Poleset 142' 142' Surface 3423' 13-3/8" 2000 sx CS III, 600 sx'G' 3455' 3194' & 200 sx CS I Intermediate 11161' 9-5/8" 500 sx Class 'G' 11193' 8850' Liner 783' 7" 350 sx Class 'G' 10867' -11650' 8573' - 9244' Perforation depth: measured Open Perfs 11196' - 11214', 11320' - 11326', 11338' - 11360', 1137 r' ~~~~~ Y ~D true vertical Open Perfs 8853' - 8868', 8960' - 8965', 8975' - 8994', 9006' - 9056' N1AR 2 ~ 2C~tt? Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tubing C~ 10809'; 5-1/2" XO 4-1/2" C~ 10809', 4-1/2", 12.6#, L-80, Tubing Tail ~ 10898'. (~~(~(~~ Packers &SSSV (type & measured depth) 9-5/8" x 5-1/2" Baker SB-3A Packer @ 10789'. 5-1/2" Camco Bal-O SSSV @ 2189' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Rearesentative Daily Averaoe Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 02/28/2002 10763 2751 Subsequent to operation 03/08/2002 16856 3020 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations - Oil _ Gas _ Suspended _ Service WAG In'ector 17. I~hereby certify that the foregoin is true and correct to the best of my knowledge. ~ /v -x ~,~,,~ ~~i~ Title: Technical Assistant Date March 13. 2002 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 "n t A r - 1 SUBMIT IN DUPLICATE • 12-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/05/2002 SCHMOO B GONE: SCMOO-B-GONE EVENT SUMMARY 03/05/02 SCHMOO-B-GONE TREATMENT WITH MEOH BREAK OVER AND SALT WATER FLUSH AFTER 3 HOURS SOAK. Fluids Pumped BBLS 275 50% METHANOL WATEE 266 SCHMOO-BE GONE 275 SEA WATER 816 TOTAL Page 1 .. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown _ Stimulate_ Plugging _ Perforate _ Conversion to Pull tubing _ Alter casing _ Repair well _ Other _X WAG Injector 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development._ RKB 74 feet 3. Address Explorato~._ 7. Unit or Property name P. O. Box 100360 Stratlgraphic_ Anchorage, AK 99510-0360 service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 400' FSL, 6' FEL, SEC. 18, T10N, R15E, UM 12-30i At top of productive interval 9. Permit number / approval number 2429' FNL, 296' FWL, SEC. 21, T10N, R15E, UM 88-142/399-043 At effective depth 10. APl number 50-029-21891 At total depth 11. Field / Pool 2536' FNL, 430' FWL, SEC. 21, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 11650 feet Plugs (measured) PBTD tagged @ 11437' MD (1/25/1999) true vertical 9244 feet Effective depth: measured 11437 feet Junk (measured) true vertical 9061 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 2150 lbs Poleset 110' 110' 2000 sx cs III, 600 sx class G, & Surface 3381' 13-3/8" 200 Sx CS ~ 3455' 3194' Production 11119' 9-5/8' 500 sx Class G 11193' 8850' Liner 783' 7" 350 Sx C~ass G 11650' 9244' RECEiVE Perforation depth: measured 11196'- 11214'; 11320'-11326'; 11338'- 11360'; 11374'- 11432'. true vertical 8853' - 8868'; 8960' - 8965'; 8975' - 8994'; 9006' - 9056'. Alaska oiJ & Gas Cons. C0mmissii Anchorage Tubing (size, grade, & measured depth) 5-1/2", 17#, L-80 Tbg @ 10809' MD; 4-1/2", 12.6#, L-80 Tbg @10908' MD; 4-1/2', 12.6#, L-80, Tbg @ 11242' MD. Packers and SSSV (type & measured depth) 9-5/8" x 5-1/2' Baker SB-3A Packer @ 10789' MD; 5-1/2" Camco BAL-0 SSSV @ 2189' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Injection D~ta OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) Subsequent to operation 8000 - 840 15. Attechments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations mX Oil m Gas __ Suspended _ Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Erin Oba ~1~ , ~ T~tie Arco Engineering Supervisor Date Prepared by Paul Rau. f 265-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICAT~ DESCRIPTION OF WORK COMPLETED CONVERSION FROM PRODUCER TO WAG INJECTOR Date Event Summary 1/2511999: 2/0611999: 2/19/1999: 6/13/1999 - 7/30/1999: 8/03/1999: RIH & tagged PBTD @ 11437' MD. C/O Sta #1 DGLV, pulled Sta #2. Ran DGLV to Sta #2. MITIA passed to 3000 psi. Various surface facility modifications were completed. Well put on produced water injection. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Conversion to WAG 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 400' FSL, 6' FEL, SEC. 18, T10N, R15E, UM At top of productive interval 2429' FNL, 296' FWL, SEC. 21, T10N, R15E, UM At effective depth At total depth 2536' FNL, 430' FWL, SEC. 21, T10N, R15E, UM 5. Type of Well: Development __X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB feet) RKB 74 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 12-30 9. Permit number / approval number 88-142 10. APl number 50-029-21891 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Caalng Length Size Conductor 110' 20' Surface 3381' 13-3/8" Production 11119' 9-5/8' Uner 783' 7' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 11650 9244 11437 9061 PBTD tagged @ 11437' MD (9/22/1998) feet Plugs (measured) ;::; Junk(measured) ORIGINAL feet Cemented Measured Depth True vertical Depth 2150 lbs Polesst 1 1 O' 11 O' 2000 Sx CS III, 600 Sx Class G, & 3455' 3194' 200 Sx CS I SOO Sx C~ass G 11193' 8850' 3S0 Sx Cass G 11650' 9244' 11196'-11214'; 11320'-11326'; 11338'-11360'; 11374'-11432'. 8853' - 8868'; 8960' - 8965'; 8975' - 8994'; 9006' - 9056'. ~1~", 17¢, L-80 Tbg ~ 10~¢ MD; 4-1~", 12.6¢, L-80 Tbg ~ 10908' MD; 4-1~", 12.~, L-80, ~g ~ 11242' M~. 9-5/8" x 5-1/2' Baker SB-3A Packer @ 10789' MD; 5-1/2" Camco BAL-0 SSSV @ 2189' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation March 26, 1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __X Gas _ Suspended _ Service 17. I hereby cerllly that the foregoing Is true and correct to the best of my knowledge. Questions? CallAndy Parker 0 265-1614 Signed Er,~ O~f,~ ~'J~. ~ Title: AAI Wellwork Dasign & Optimization Supervisor Date Prerne!ed b~/ Paul Rauf 263-4990 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- J'~ O~ I Appr°val n°¢~c~ '~'~'~-~ ..... .Approved by order of the Commission Form 10-403 Rev 06/15/88 · ,JP,.IGINAL SIGNED BY Robert N.. Chdstenson .,n~o,~ed GOP~ commissioner SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Post Office Box" Anchorage, Alaska 99510-0360 DS12-30 conversion to WAG injector The conversion of 12-30, from a shut in producer to a WAG injector, will provide support to periphery horizontal wells 17-03A and 12-14A, as well as updip wells 12-07A and 17-02. All four of these wells are currently on-line and in need of pressure support as evident by recent reservoir pressure measurements. Reserve benefits will be realized from the injection of MI into this new pattern. Well 12-30 was originally drilled and completed as a pre-produced injector in 1989. Because of the incomplete development of its offset producers, it was decided in 1993 to leave the well as a producer. A Zone 4 fracture stimulation was performed in 9/93 resulting in an oil rate increase from 1,000 bopd to 10,000 bopd. Prior to being shut in for TGOR this January, Well 12-30 was producing 85 bopd, 95% wc and 4800 GOR. The reservoir pressure in this area ranges from 3150 to 3250 psia which is Iow compared with producers in other nearby waterflood patterns averaging 3450 psia. The facility work necessary to convert 12-30 to water injection service involves: cutting and capping the existing flow line to the production manifold building, connecting a new water injection well line from the existing 12-30 well line with the existing water injection mini-module, re-equipping the existing water injection slot with a choke, check and drain valves, and reusing the existing downcomer. The facility work necessary to convert 12-30 to MI injection service involves: cutting and capping the existing gas lift well line to the gas lift manifold building, connecting the 12-30 MI well line (formerly the 12-30 gas lift line) to the MI injection well line to well 12-02, and installing a new 2,500# MI lateral line and C-spool to well 12-30. Installation of power to the well house heater and lights will also be required. Wellwork will include obtaining an injection profile once the well is on injection. An outer annulus down squeeze may be necessary since the well was not Arctic packed if it is found that the inner by outer annulus leaks MI. Well 12-30 has 2 POGLMs which were recently dummied for testing purposes. The well has since passed a MITIA and a PPPOT indicating tubing by inner annulus and inner by outer annulus competence. ARCO Alaska, Inc. I;. Subsidiary of AtlantlcRIchfleldCompany GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATrN: Sherrie NO. 9628 Company: - Alaska Oil & Gas Cons Comm Attn: Larry Grant - .: 3001 Porcupine Drive Anchorage, AK 99501 8/9/95 Well Job # Log Description Date Field: Prudhoe Bay ~ Floppy BL RF Sepia DIR MWD Disk D.S. 2-19 ~ [ I :~( ~ PEHFRECORD 950723 1 1 D.S. 6-7 -~. ~' (J~T~_-I -- PRODPRORLE 950724 1 1 D.S. 12-30 .~ J~ ~ PR~URE BUI~ UP 950721 I 1 D.S. 15-14 ~ I I~ ~ ~RFRE~RD 950721 1 1 D.S. 15-24 ~ ~ / ~ L~KDETECTION 950721 I 1 D.S. 15-36 · ~ ~ 7~ ~RFRE~RD 950724 1 1 D.S. 18-2A q ~ ~ ~ ~ PROD PRORLE .. 95 0716 I 1 O.S. 15-25~ ~o 95261 DUAL BURST TDT-P ~ ~ ~ 950725 1 D.S. 11-3A ~l.l~ 95260 CNTD [~ ~/ 950718 1 D.S. 15-1 ~.6~ 95262 DUAL BURST TDT-P /~ ~ 950726 I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. . STATE OF ALASKA , ALAS(' , OIL AND GAS CONSERVATION(' )MMISSION REPOR'! OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate . X Plugging Perforate ,, 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 400' FSL, 6' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2429' FNL, 296' FWL, Sec. 21, T10N, R15E, UM At effective depth 2522' FNL, 412' FWL, Sec. 21, T10N, R15E, UM At total depth 2536' FNL, 430' FWL, Sec. 21, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 20" Sudace 3422' 13-3/8" Production 11160' 9-5/8" Liner 783' 7" 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED MAY 1 6 1995 AlaS~ Oil & Gas Cons. Commission /ach0ra!:ie 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-30 9. Permit number/approval number 88-142 10. APl number 50 - 029-21891 11. Field/Pool Prudhoe Bay Oil Pool feet 11650 feet 9244 feet Plugs(measured) 11432 feet 9056 feet Junk(measured) Cemented Measured depth True vertical depth 2150# Poleset 110' 110' 2000 sx cs iii & 600 sx class G - Top job w/200 sx CS U 3455' 3194' 500 SX Class G 11193' 8850' 350 sx Class G 10867-11650' 8573-9244' Perforation depth: measured 11196-11214'; 11320-11326'; 11338-11360'; 11374-11432' true vertical 8853-8868'; 8960-8965'; 8975-8994'; 9006-9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 10809' MD; 4-1/2", 12.6~, L-80, Tbg @ 10908' MD; 4-1/2", 12.6~, L-80, Tbg @ 11242-11275' MD Packers and SSSV (type and measured depth) Baker SB-3A Pkr @ 10789' MD; Brown 2B Pkr @ 11242' MD; Camco BaI-O S$SV @ 2189' 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 Representative Daily Average Production or Injection DatR OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1633 879 1870 - Tubing Pressure 233 Subsequent to operation 1775 1279 2606 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FSiogr nj~0.40 e~v 06/15~/88 ~ Title Service 235 Engineering Supervisor KRF cc: KZ, JWP Date '~/~/~'~'"' SUBMIT IN DUPLICATE 12-30 DESCRIPTION OF WORK COMPLETED FULLBORE ACID STIMULATION TREATMENT 4/6195: RIH & tagged PBTD at 11401' MD. 4/11195: Pumped a Fullbore Acid Stimulation for scale damage removal as follows: MIRU CTU & PT equipment. Pumped treatment fluids fullbore to treat the open perforation intervals located at: 11196 - 11214' MD (Sag) 11320 - 11326' MD (Z4) 11338 - 11360' MD (Z4) 11374 - 11432' MD (Z4) Ref. Log: BHCS 1/4/89. Pumped: a) 50 b) 50 c) 10 d) 50 e) 10 f) 50 bbls 1% KCI Water @ 6 bpm, followed by bbls 50% Diesel/50% Xylene @ 6 bpm, followed by bbls Crude w/2 ppg Rocksalt Diverter @ 4 bpm, followed by bbls 7% HCI w/10% Xylene, followed by bbls Crude w/2 ppg Rocksalt Diverter @ 7 bpm, followed by bbls 7% HCI w/10% Xylene, followed by g) 10 bbls Crude w/2 ppg Rocksalt Diverter, followed by h) 50 bbls 7% HCI w/10% Xylene, followed by i) 200 bbls 1% KCI Water Overflush @ 8 bpm, followed by j) 240 bbls Crude displacement, followed by K) Shutdown. Rigged down. 4/21/95: Pumped a scale inhibition treatment. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED MAY ] 6 1995 Naska 0il & Gas Cons. Commission Anchora? ARCO .A!.~1~-: IIlC. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-21-93 DEC 0 ? 199~ /. -16A 9-25-93 SBT/GR/CCLI~b-llllo Run 1, 16A 9-26-93 Collar ¢¢-rr.b ~os~o-lo~l o Run 1, 3-29 9-19-93 Production '~q0o-c~':i'-/' Run 1, 4-1 9-23-93 CNL ~]-~0-~,~-/ Run 1, 4-4 9-17-93 . PerfRecord ~s~o-~a~so Run 1, 4-78T 9-19-93 PerfRecord ~-~z~ Run 1, 4-8 9-23-93 Inj Proflle]sf~olT~l?.~.~J~_Run 1, ~-q~ 4-16 9-13-93 Leak Detectm~l~,~/~ Rim 1, 9-5A 9-16-93 Production/sn~o~)~ Run 1, 9-29 9-15-93 Leak Detect/~5]7~'~]~n Run 1, /9-35A 9-17-93 PerfRecord~ul~-II~ Run 1, ~9-35A 9-18-93 Perf Record ~ql~-~lo?~ Run 1, \..~-$5A 9-19-93 Prod ProfllelS~qJ~~ R,- 1, 9-42 9-14-93 Prod Profllei~.l~:~/~ Run 1, ~0-lbb 9-44 9-15-93 Prod Profile /,12-22 9-25-93 Jewelry I~Rl clLRun 1,1' \12-22 9-26-93 Perf Record ~00~ R,- 1, 12-30 9-22-93 POGLM Set/TBG Punch Run 1, 70-53 14-4 9-24-93 PerfRecord 112~~11 Run 1, 14-31 9-20-93 Production ~-qf~o Run 1, 15-2 9-14-93 Prod Profllel~lT~l~A Run 1, 5" ~~ Sch ~z-~ 15-18 9-21-93 B-ker Inflatable Packer R;m 1, 5"l~0z~-l~oSch f2--~ 16-29A . . 9-24-93 Productioni~l~l~Run 1, 5"~-17~ZSch ~¢-2¥517-12 9-22-93 Productioni~ni~i~~un 1, 5" ~1~o-~1773 8ch ~-~5 18-25 9-20-93 Prod Profile u~0~-t~o R,_;n 1, 5" 8ch Have A Nice Day! Sonya Wallace ATO- 1529 Please sign and return the attached copy as receipt of data. RECEIVED BY__~_~ / ~PPROVED_.~_,~___ Trans# 93118 # CENTRAL FH,ES # CHEVRON # BPX # STATE OF ALASKA # PmLLIPS # LILLIAN TIULANA # EXXON # MOBIL STATE OF ALASKA ALASKA REPORT FANDGAS CONSERVATION Cq IISSION SUNDRY WELL OP 'HATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate 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 400' FSL, 6' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 2429' FNL, 296' FWL, Sec. 21, T10N, R15E, UM At effective depth 2522' FNL, 412' FWL, Sec. 21, T10N, R15E, UM At total depth 2536' FNL, 430' FWL, Sec. 21, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic RECEiVE OCT 7 199 Alaska 0il & Bas Cons. Comm'~ss'~o° Anchorage 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number ~_~ 12-30 '~ 9. Permit number/appr~umber 88-142 10. APl number 50 - 029-21891 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Sudace 11650 feet 9244 feet Production Liner Plugs(measured) Fill @ 11432' MD (9/14/93) 11432 feet 9056 feet Junk(measured) Length Size Cemented Measured depth True vertical depth 80' 20" 2150# Poleset 110' 110' 3422' 13-3/8" 2000 sx CS III & 600 sx Class 3455' 3194' G - Top job w/200 sx CS II 11160' 9-5/8" 500 sx Class G 11193' 8850' 783' 7" 350 sx Class G 10867-11650' 8573-9244' Perforation depth: measured 11196-11214'; 11320-11326'; 11338-11358'; 11358-11360'; 11374-11432' true vertical 8853-8868'; 8960-8965'; 8975-8993'; 8993-8994'; 9006-9056' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 10809' MD; 4-1/2", 12.6~, L-80, Tbg @ 10908' MD; 4-1/2", 12.6#, L-80, Tbg @ 11242-11275' MD Packers and SSSV (type and measured depth) Baker SB-3A Pkr @ 10789' MD; Brown 2B Pkr @ 11242' MD; Camco BaI-O SSSV @ 2189' 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 Averaoe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 0 16 -- 10820 ~ 8791 249 -- Tubing Pressure 179 3OO 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 1057/6 DTK cc: SW, JWP 12-30 ~' DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENTS OF SAG/ZONE 4 & POGLM'S INSTALLATION 912193: RIH & tagged bottom at 11497' MD. 913193: MIRU & PT equipment. RIH w/CT & pumped 27 bbls of gelled sand slurry containing 20/40 sand, to isolate the lower perforation interval at: 11374 - 11432' MD (Z4) Ref. Log: BHCS 1/4/89. 914193: RIH & tagged top of sand plug at 11362' MD. 916193: MIRU & PT equipment. Performed a Datafrac, followed by a Hydraulic Fracture Treatment, using 16/20 mesh preppant, through the open perforations located above the sand plug at: 11196 - 11214' MD (Sag) 11320 - 11326' MD (Z4) 11338 - 11358' MD (Z4) 11358 - 11360' MD (Z4) Ref. Log: BHCS 1 / 4 / 8 9. Pumped Datafrac consisting of 50 bbls 20# Pre-Pad Gel @ 35 bpm, followed by Shutdown. ISIP 1730. Resumed pumping 145 bbls 30# Crosslinked Gel @ 30 bpm, followed by 83 bbls 20# Flush @ 30 bpm, followed by 35 bbls 20# Flush @ 5 bpm, followed by 140 bbls 20# Flush @ 30 bpm, followed by Shutdown. ISIP 1940. PumPed Fracture Treatment consisting of 75 bbls Pad @ 30 bpm, followed by 270 bbls Cross Linked Slurry @ 1-12 ppg, followed by 98 bbls Flush, followed by Shutdown. formation. Rigged down. 918193: Performed a proppant fill cleanout down to 11344' MD. 9111193: Ran bailer & bailed sand plug down to 10360' MD. 9/13193: Placed 15,000 lbs of proppant into the OCT 2 7 1993 Alaska 0il & Gas Cons. ~;ommissto~ Anchorage MIRU & PT equipment. Performed a Datafrac, followed by a Hydraulic Refracture Treatment, using 16/20 mesh proppant, through the open perforations located above the sand plug (listed above). Pumped Datafrac consisting of 160 bbls 30# Crosslinked Gel @ 5 bpm, followed by 260 bbls 20# Flush @ 30 bpm, followed by Shutdown. ISIP 1520. Pumped Fracture Treatment consisting of 50 bbls 30# Crosslinked Pad @ 30 bpm, followed by 285 bbls Cross Linked Slurry @ 1-10 ppg, followed by 256 bbls Flush, followed by Shutdown. Placed 55,000 lbs of proppant into the formation. Rigged down. 9114193: Performed a proppant fill cleanout down to 11435' MD. 9/21193 - 9122193: MIRU & PT equipment. RIH w/tubing puncher & shot circulation holes in 5.5" tubing at 4292' & 7814' MD. POOH w/puncher, then RIH w/POGLM assembly & set at 7805 - 7821' MD (seat to seal). Ran & set upper POGLM assembly at 4282 - 4298' MD (seal to seal). PT 9-5/8" @ 3000 psi/30 minutes OK. Rigged down. Returned well to production & obtained a valid welltest. ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 9-9-93 VS-~ 1-58T ~-I~Z 1-24A ~o31-25 ~-~t(/2-10 \2-10 ~-o~ 2-13 2~~ 2-21 ~-~ 3-1~ 71-11 4-4 ~-~ 4-38 ~9-29 ~~7 11-9 -~ 11-22 ~ 12-28 't~E 12-30 8-14-93 Production ilo%--!~..~0 R~_lVt 1, 5" Sch 8-6-93 Perf Recordi~?/~' ~ Run 1, 5" Sch 6.6.93 PerfRecord~lo~o~ia~ R;m 1, 5" Sch 8-13-93 CNL ~oo-~1 Run 1, 5" Sch 8-13-93 Prod Profile~o ~a5 R,m 1, 5" Sch 8-14-93 Prod Profile%~-q~ r"T R,m 1, 5" Sch 6.9-93 PerfRecord ~o~-~l~zo Run 1, 5" Sch 8-9-93 PerfRecord~?~~to R~m 1, 5" 8ch 6.6.93 CNL ~:~oo-~c~ R;m 1, 5" Sch 6.6.93 Perf Record ~0-11~0 R,m 1, 5" Sch 8-11-93 Inj Profile ~taoo-tl~ ~ R~_m 1, 5" Sch 8-1 6.93 Production q~- ~2~ Run 1, 2"&5" Sch 8-14-93 Baker IBP 2~- ~o~,tz Run 1, 5" _~h 8-5-93 TBG Patch Set Record Run 1, 5" q~o-i~h 6.15-93 Leak Detect ~o - I~ Run 1, 5" Seh 8-7-93 Perf Recordt~-)~ Run 1, 5" Seh 8-11-93 Perf Record ~1o?0,it~0 Run 1, 5" Seh ~(~-~'7., 13-12 8-11-93 TBG Patch 23~v-~to Run 1, 5" ~1~ tVl 14-13 8-15-93 Inj Pro~/2~-?a~?-~Run 2,'5" /16-29A 8-7-93 Perf Record tt~0o-I~~ Run 1, 5'" ~hh - /16-29A 8-8-93 Mtcroi~_-!_amic Survey R~ 1, 5" t~-l~ HI~~ i6-29A 8-9-93 ~J ~o~a?m-w~f~ R~ 1, 5" r~~ '~~ ~6.29A 8-10-93 ~~sei~mtc S~~ R,m 2, 5" 1~o- ~ ~o ~l-ql 17-16 6.12-93 PeffReco~ ~~ R~ 1, 5" ~ 17-21 6.16.93 Completion~%~o-~5~o Run 1, 5" Seh o/dat~ Sonya Wallace ATO-1529 APPROVED_~__ Tmn~ 93100 * The correct APl# for 1-5ST is 50-029-20076-00. ARC(] ALASI<A: INC. F'. O, BOX ANCHORAGE, ALA3'KA DATE' 3-2i-9e REFERENCE' ARCO F'RE$SURE DATA 2-22 ~ -24-90 BHF'--STATIC HRS 4-6 2-5-9(} BHF'--$TAT IC GRADIENT CAMCC) 4.-28 i ..- ~'-9(-} BHP--£TATIC GRADIENT CAMCO 4-3~ 2-'f'~- 9 ~) BHF ....STATIC GRADIENT CAMC[) 4-3~ ~.- .~-9~ BHF'--£TATIC GRADIENT CAMCO 4-32 2~90 BHF'--STATIC GRADIENT CAMCO 9-8 ~ -2(}-9~ BHP--£TATIC GRADIENT CAMCO 9-3(~ 2-~ 0-9~) BHF'--STATIC GRADIENT CAMCO 9-,32 2-~ ~-9~ BHP--STATIC HRS ~ 2--~ 8 ~JH---26-89 BHP--STATIC GRADIENT CAMCO ~2-~ ~-25-89 BHP--STATIC GRADIENT CAMCO t2-~4 ~2-4-89 BHP--STATIC GRADIENI' CAMCO ~ 2--~ 8 2-~ 4-9(} BHF'--£TATIC GRADIENT CAMCO ~2-~(} ~2-29-89 BHP--FLOWING GRADIENT CAMCO ~ 3-2? 2'-'~ 6-9(} BHP--FLOWING GRADIENT CAMCO ~-~0 2-~5-90 BHP--FLOWING GRADIENT CAMCO ~ 3-33 2-~ 5-9(} BHP--STATIC GRADIENT CAMCO ~ 6-~ ~ -~ ?-?(} BHP--SI'AI'IC GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIF'T OF DATA RECEIVED RECEIVED BY _~__.__~ ? i 90 FIA V E A N I C E D A Y ! Alaska.0il .& Gas Cons. G~m~t~ ~ StiLLY HOFFECKER ~c~Q~.~ APPROVED(~__ AT0-~529 TRANS~ 9eWt7 DISTRIBUTION CENTRAL FILES ~ ~ F'HILLIP$ CHEVRON F'B WELL FILES D & M ~ R & D EXTENSION EXPLORATION ~ ~ BF'X EXXON ~ STATE OF ALASKA ~ . MARATHON ~~ TEXACO MOBIL ARCO ALASKA, INC. i'-'-'., 0. BOX i 9(~36(~ ANCHORA6E: ALASKA DATE' 'i-i8-90 REFERENCE' ARCO CASED HOLE FINALS 3-i2 i2-28-89 ViZ INJECTION PROFILE RUN i, ,'~ -,'-,,, ,"~,'-, R U N i , 5-25 i .--~-u~ 7 CE'F 5--25. i-8-90 COLLAR/PERK RUN i, 7-9 i2-27-89 PRODUCTION f"i:..'OFILE RUN i, 7-i 8 i 2-27-89 .~F'INNER/Tli:'i~F' C'AF' RUN i , 4 'l t 5 t2-'~7-89 NOISE/TEMF' RUN i , I i ~m ~ii t 2-29 i-7-9~ COI. LAR/F'ERF RLIN i , t 2-~5..9 i 2-'29-8? PRODUCTION PROF".EL. IE RUN i , t 5'-t i t 2-t 8-89 COLLAR RUN i , i 5-t 3 ' t-9-9¢' COt. I_AR/I:'ERI-- RUN i , i5-2t i2-3t-8~ F'RODUCTION F'ROFILF RUN t, t'?-~.~ i2-3~-89 PRODUCTION F'ROFII-.E/PITS RUN 2, F'i...EASE SIGN AND RETURN THE ATTACHEI) L;.)FY AS RECEIF'T OF DATA, RECEIVED BY HAVE A NICE DAY! SALLY HOF'FECKER A'¥O--' i 529 DISTRIBUTION "' CENTRAL FILES ¢,- PHIl_LIPS · ~' CHEVRON F'B WELL Fl:LES D & M R & D ~ EXTENSION EX'F'LORAT I ON ~" BF'X · ,ii, 'Il' .il. "Il' ~ EXXON ,.gTAI'E OF ALASKA oil. MARATHON '"'... TEXACO ~ MOBIL .'II' C A t-i C 0 ,'~ C H C: A ¢i C 0 i.-t i.;~ ,S' ,?;' C i.-I ~.':.~ 'i" L A C ¢4 h'", C 0 C A M L; 0 ATi_A CAMCO CAM~O , t STATE OF ALASKA (' ' /~'/' '" ALASKA'~IL AND GAS CONSERVATION COMMISSION (~ WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well OIL~ GAS '~ SUSPENDED ~ ABANDONED '--'1 SERVICE [71 .'" '"'''i'njec~-~'~ C) ;2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-142 , . 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21891 4. Location of well at surface 9. Unit or Lease Name 400' FSL, 6' FEL, Sec.18, T10N, ELSE, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 2429' FNL, 296' FWL, Sec.21, TION, R15E, UN 12-30 At Total Depth 11. Field and Pool 2536' FNL, 430' FWL, Sec.21, T10N, R15E, UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i l Poo] RKB 74'I ADL 28331 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offshore 116. No. of Completions 12/17/88 01/04/89 06/01/89'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey ! 20. Depth where SSSV set 121. Thickness of Permafrost l1650'MD/9244'TVD l1603'MD/9204'TVD YES [] NO [] 2189' feet MD 1900' (approx) 22. Type Electric or Other Logs Run B IL/BHCS/GR/SP, CNL/Z-Ben/GR/CAL, CET/CBT, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE' WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 110' 30" ;~150# Polesel; 13-3/8" 68.0#/72.0.~ K-55/L-8( Surf 3455' 17-1/2" 2000 sx CS III & 600 ~x Class G Too ich w/200 sx CS II · 9-5/8" 47.0# L-80 .. Surf 11193' 12-1/4" 500 sx Class G 7" 29.0# L-80 10867' 11650' 8-1/2" 350 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) 120° Phasing 5-1/2" 11276' 10790' & 112~2' 11196'-11214'MD/8853'-8868' 'TVD ~ 4 spf 11320'-11326'MD/8959'-8964' TVD ~ 2 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11338'-11360'MD/8975'-8994' TVD @ 2 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED l1374'-l1432'MD/9006'-9056'TVD ~ 2 spf N/A ., 27. N/A "', pRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Dat~ of Test Hours Tested "'... PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE alF 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips· ~ /4IT' ~) Alaska Oil .& Gas Cons. C0mmisS (Dani) WC6/063 , ~~nch0rage '., --. , 0Q Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Sadlerochit HOT OWC GEOLOGIC MARKERS MEAS. DEPTH 11309' 11452' 11491' TRUE VERT. DEPTH 8950' 9073' 9107' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, anct tIme of each phase. N/A 31. LIS'r, OF ATTACHMENTS mone . 32. hereby certify 'that the foregoing 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 log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (D.F, KB, etc.). item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 ADDENDUM WELL: 1/24/89 12-30 RU Schl, rn CET/CBT f/11,530'-10,030' @ 0 psi and @ 1000 psi. Rn GR f/11,530'-3350'. Rn GCT f/surf to 11,530'. Drilling Supervy ~UB.~URFACE DIRECTIONAL SURVEY [~]UIDANCE ~]ONTINUOUS [~]OOL Coml~l~y: ARCO ALASKA, INC. III Well Nam®. D.S. ]2-30 (400' FSL~ 6' FELt SEC 18,TlON,R15E,UM) Field/Location PR,,UDHOE BAY, NORTH SLOPE, AL, ASKA Job Reference No. 73174 SCHWARTZ Date 23-JAN-89 Computed KRUWELL GCT DIRECT'IONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. D.So 12-30 PRUDHOE BAY NORTH SLOPEr ALASKA SURVEY DATE: Z3-JAN-89 ENGINEER: SCHgARTZ NETHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZTMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORZZo DIST. PROJECTED ONT~:~'A TARGET AZINUTH OF SOUTH 62 DEG 2 MIN EAST . . ARCO ALASKA XNC. DiS. 1Z-30 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATXON DATE: 8-MAR-89 PAGE 1. DATE OF SURVEY: Z3-JAN-89 KELLY BUSHTNG ELEVATION: 74.00 FT ENGINEER: SCHWARTZ ZNTERPOLATEO VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA .COURSE NbASURED VERTZCAL VERTZCAL DEVZATION AZ~HUTH DEPTH DEPTH 0.00 0.00 XO0.O0 99.95 ZO0.O0 199.95 300.00 299.95 400.00 399.95 500.00 499.95 600.00 599.95 700.00 699.95 800.00 799.94 900.00 899.94 DEPTH Q.~ -74.00 25.95 125.95 -' 225.95 325.95 = -0 6 425.95 0 17 525.95 0 22, 625.95 .:. ..-. 0 72 5.9~ 0 23 8Z5.94 0 3Z OEG MIN N 0 0 E N 41' 26 W 'S 17 14 E N 21 57 W S 60 55 E S 73 54 E S 68 2 E S 73 34 E S 74 22 E S 67 Z E VERTZCAL DOGLEG RECTANGULAR COORDINATES HUR[Z. DEPARTURE SECTZON SEVERITY NORTH/SOUTH EAST/WEST OZST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG M[N 1000.00 999.93 925.93 I 40 1100.00 1099.76 1025.76 4 51 IZO0.O0 1199.22 1125.Z2 6 57 1300.00 1298.37 1224.37 7 53 1400.00 1397.32 1323.32 8 39 1500.00 1496.12 1422.12 9 15 1600000 1594.63 1520.63 10 38 1700.00 1692.72 1618.72 11 36 1800.00 1790.56 1716.56 12 23 1900000 1867.68 1813.68 15 16 S 59 53 E S 50 34 E S 55 9 E S 59 5 E S 62 8 E S 61 17 E S 58 I E S 56 58 E S 56 24 E S 54 43 E ZO00. O0 1983.26 1909.26 18 44 2100.00 2077.02 Z003.02 21 53 ZZO0.O0 2169.08 2095.08 24 0 Z300.O0 Z259.64 2185.64 26 11 Z400.OO 2346.47 2274.47 28 28 ZSO0.O0 Z435.44 Z361.44 30 35 2600.00 ZSZO.7Z 2446.72 32 20 Z700.OO 2604.34 2530.34 34 12 2800.00 2685.92 2611.92 36 27 Z900.O0 2765.30 2691.30 38 21 S 5731 S 61 42 E S 64 15 E S 66 44 S 67 35 E S 66 44 S 65 20 E S 66 51E 5 65 26 E 3000000 2843.7Z 2769.72 38 17 3100.00 zgzz.05 2848.05 38 32 3ZOO.O0 3000.06 2926.06 39 6 3500000 3076.99 3002.99 40 16 3~.00.00 3152.81 3078.81 41 1 3.500.00 3ZZ8.30 3154.30 41 6 3600.00 3303.19 3229.19 41 48 3700.00 3377.35 3303.35 42 27 3800.00 3451.02 3377.02 42 39 3900.00 352~.35 3450.35 43 I S 59 40 E 670.70 S 61 40 E 732.84 S 66 7 E 795.34 S 66 29 E 859.02 S 65 41 E 924.06 S 64 37 E 989.55 S 63 50 E 1055.76 S 63 4 E 1122.83 S 63 14 E 1190.44 S 65 42 ~ 1258.36 0.00 0.00 0.02 0.30 0.04 0.00 0.04 0.00 0.10 0.00 0.~0 0.00 0.98 0.00 1.61 0.00 2.22 0.22 3.05 0.15 4.53 3.45 10.00 3.28 20.15 1.13 33.11 1.19 47.57 0.55 63.01 0.82- 80.15 1.79 99.57 0.52 1'20.14 1.66 143.7Z 3.59 172.87 3.83 Z07.56 Z.57 246.58 2.67 288.90 2.33 334.61 Z.31 383.72 Z.03 435.69 1.96 490.40 2.27 548.08 2.29 608.70 3.73 1.73 2.91 Z.17 1.19 1.00 1.26 1.13 0.70 1.14 1.40 .! 0.00 N 0.00 E 0.01 N 0.03 E 0.04 S 0.03 E 0.08 S 0.00 E 0.09 S 0.06 E 0.18 S 0.35 E 0.37 S 0.92 E 0.62 S 1.50 E 0.77 S Z.10 E 1.05 S 2.90 E 0.00 N 0 0 E 0.03 N 74 7 E 0.05 S 35 50 E 0.08 S 3 ;?7 E 0.11 S 33 52 E 0.40 S 62 43 E 0.99 S 67 55 E '~' 1.62 S 67 38 E Z.24 S 69 52 E 3.08 S 70 5 E 1.65 S 4.25 5.11 S 8.60 11.35 S 16.79 18.41 S 27.71 25.43 S 40.35 32.72 S 53.97 41.35 S 68.80 4.56 S 69 49 E 10.01 S 59 18 E 20.26 S 55 56 E 33.27 S 56 24 E 47.70 5 57 46 E 63.11 S 58 46 E 80-26 S 58 59 E 51.87 S 85.20 E 99.74 S 58 39 E 63.19 S 102.47 E 120.39 S 58 ZO E 76.67 S 122.02 E 144.10 S 57 51 E 93.16 S 1~6.26 E 173.41 S 5? 30 E 110.58 S 176.29 E 208.10 S 57 54 E 128.32 S 211.05 E 247.00 S 58 42 E 145.81 S 249.68 E 289.14 S 59 42 E 163.54 S 292.01 E 334.69 5 60 44 E 182.30 S 337.66 E 383.73 S 61 38 E 202.36 S 385.86 E 435.T0 S 62 19 E -"~-~ 224.79 S 435.89 E 490.44 S 62 43 E 248.29 S 488.71 E 548.17 S 63 4 E 272.45 S 544.52 E 608.87 S 63 25 E 301.4Z S 599.34 E 670.87 S 63 18 E 332.28 S 653.30 E 732.95 S 63 2 E 359.53 S 709.60 E 795.48 S 63 7 E 384.93 S 768.22 E 859.26 5 63 Z3 E 411.37 S 827.82 E 924.40 S 63 34 E 438.96 S 887.32 E 989.96 S 63 40 E '467.64 S 947.04 E 1056.21 S 63 43 E 497.71 S 1007.02 E 1123.30 S 63 41 IE 528.39 S 1067.28 E 1190.92 S 63 39 E 557.58 S 1128.68 E 1258.89 S 63 42 E ARCO ALASKA XNC. DiS. 12-30 PRUOHUE BAY NORTH SLOPE, ALASKA COMPUTATXON DATE: 8-MAR-89 PAGE 2 DATE OF SURVEY: Z3-JAN-89 KELLY 9USH[NG ELEVATZON: 74.00 FT ENGINEER: SCHNARTZ TRUE MEASURED V~RTICAL DEPTH DEPTH ]NTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH 4000.t10 3596.97 4100.00 3668.91 4Z00.00 37~0.25 4~300.00 3811.17 4400.00 3881.64 4500.00 3951.93 3877.93.- 45-38 4600o00 ~021.83 3947.83 :'-~5 4700.U0 &092.ZZ 4018.22 :' &5 '~'~ &800.O0 4~62.71 4088.7~ " 45 4900~00 ~232.80 4158.80 ~5 SUB-SEA-' .T .COURSE VERTTCAL-DEV. AT]:ON AZ']:,qUTH DEPTH ~M~N D~G 3522.97..:[~. S 65 50 E 1326.94 3594.91'~~ S 66 25 E 1396.24 3666.z~~9 s 67 6 e 1~66.06 3737.17i~.~ .... '~ s 66 56 E 1536.30 ~a07.64 :;¢."..S. 10 S 66 18 e 1607.01 S 65 57 E 1677.96 S 65 54 e 1749.32 $ 65 46 E 1820.18 s 65 19 ~ 1890.98 S 65 4 E 1962.21 5000.00 4.302.71 4228.71 4.5 40 5100.00 4,3?2.37 4298.37 4,5 58 5200.00 4441.73 4367.73 46 16 5~100.00 4.510.62 4436.62 46 35 b400.O0 4.5'1'9.18 4505.18 46 56 bSO0.O0 4647.06 4573.06 47 28 5600000 4714.72 4640.72 47 30 5100.00 4781.59 4707.59 48 29 5800.00 4847.60 4773.60 48 41 5900.00 4913.83 4839083 4,8 27 6000.00 4980.77 4906.77 4,7 11 6100.00 5049.19 4975.19 46 40 6200.00 5111.75 5043.75 46 46 6300.00 5186.04 5112.04 47 13 6400.00 5253.41 5179.41 47 4*8 6500.00 5320.67 5246.67 47 34 6600.00 5388.50 5314.50 47 8 6700.00 5656.73 5382.73 46 27 6800.00 5525.89 5451.89 46 11 6900000 5595.?7 5521.77 45 4 1000.00 5661.03 5593.03 44 4 7100.00 5739.09 5665.09 43 51 7200.00 5810.83 5736.83 44 31 1300.00 5881.92 5807092 4.4* 49 7400.00 5952.85 5878.85 44 47 7500.00 6023.68 5949.68 44 56 7600.00 6094.31 6020.31 45 8 ~700.00 6164.97 6090.97 44 48 7800.00 6236.12 6162.12 44 27 7900.00 6307.64 6233.64 44 11 VERTICAL OOGLEG RECTANGULAR COORDiNATeS HORIZ. DEPARTURE SECTION SEVERZTY NORTH/SOUTH EAST/NEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN S 64 39 E 2033.62 S 64* 5 E 2105.30 S 63 Z8 E 2177.30 S 62 54 E 2249.77 S 62 22 E 2322.57 S 61 40 E 2396.00 S 61 26 E 2469.63 S 63 17 E 2543.97 S 63 15 E 2619.07 S 64 9 E 2693.96 S 65 20 E 2768.17 S 65 34 5 2840.96 S 64 54 E 2913.64. S 64 32 E 2986.61 S 65 2 E 3060.44 S 65 28 E 3134.31 S 65 45 E 3207.65 S 66 33 E 3280.57 S 67 7 E 3352.53 S 67 10 E 3423.77 S 66 17 E 3493.70 S 66 19 E 3562.84 5 66 26 E 3632.30 S 66 23 E 3'702.43 S 66 18 E 3772.72 S 66-18 E 3843.11 S 66 21 E 3913.71 S 66 3! E 3984..26 S 66 39 ~ 4054..31 S 66 36 E 4123.98 0 1 .ZO 0.33 0 0.49 0.73 0.65 0.59 0.50 0.19 5,~5.71 S 1191.~0 E 1327.59 S. 63 49 E 613.83 S 1254..89 E 1397.00 S 63 55 E 641.4.1 S 1319.33 ~ 1466.98 S 64, 4 E 668.91 S 1384.26 E 1537.4.0 S 64 12 697.03 S 1449.3'9 E 1608.28 S 64 18 E 725 84 S 1514 42 E 1679 38 S 64 23 E . · o 755.06 S 1579.69 E 1750.87 S 64 27 E 784..07 S 1644.52 E 1821.88 S 64 30 E 813.48 S 1709.07 5 1892.79 S 64 32 E 843.41 S 1773.82 E 1964.12 S 64 34 E 0.56 0.72 0.58 0.58 0.71 0.81 1.23 I .10 1.32 0.24, 873.72 S 1838.58 E 2035.62 S 64 34 5 904.7.3 S 1903.27 E 2107.36 S 64 34 E 936.56 S 1967.89 E 2179.39 S 64 32 E 969.24 S 2032.59 E 2251.85 S 64 30 E 1002.71 S Z097.24 E 2324.6Z S 64 26 E 1037.11 S 2162.12 E 2397.99 S 64 22 E 1072.38 S 2226.76 E 2~71.53 S 6~ 17 E 1106.83 S 2292.63 E 2545.83 S 64 13 E 1160.62 S 2359.72 E 2620.93 S 64 12 E 1173.68 S 2426.95 E 2695.86 S 64 11 E 2.46 0.32 0.55 I .31 I .22 0.99 0.15 2.62 0.85 1.08 1205.69 S 2493.99 E 2770.14 S 64 11 E 1235.77 S 2560.43 E 2843.05 S 64 14 E 1266.21 S 2626.56 E 2915.84 S 64 15 E 1297.37 S 2692.63 E 2988.88 S 64 16 E 1329.04 S 2759.40 ~ 3062.78 S 64 16 E 1359.85 S 2826.68 E 3136.77 S 64 18 E 1390.20 S 2893.60 E 3210.23 S 64 gO E -""~ 14.19.87 S 2960.41 E 3283.30 S 64 22 E 1448.19 S 3026.85 E 3355.46 S 64 25 5 1475.84 S 3092.82 E 3426.90 5 64 29 E 0.69 1503.65 S 3157.23 E 3~97.01 S 64 32 E 0.40 1531.53 S 3220.71 E 3566.31 S 64 34 E 0.51 1559.4.4. S 3284.54 E 3635.94 S 64 36 E 0.30 1587.55 S 3349.01 E 3706.23 $ 64. 38 E 0.25 1615.84 S 3413.57 E 3776.69 S 64 40 E 0.56 1644.20 S 3478.21 E 3847.25 S 64 4,1 E 0.26 1672.64 S 3543.05 E 3918.02 S 64 43 E 1.07. 1700.91 S 3607.91 E 3988.75 S 64 45 E 0.21-. 1728.82 S 3672.41 E 4058.99 5 64 47 E 0~.'~0 1756.54 S 3736.56 E 4128.84 S 64 49 E .~, '. ~_" Al(CO ALASKA INC. 0.5. 1Z-30 PRUDHOE BAY NURTH 5LOPE, ALASKA COMPUTATION DATE: 8-Ma, R-89 PAGE 3 DATE OF SURVEY: Z3-JAN-89 KELLY BUSHING ELEVAI~ON: 74.00 FT ENG~N~ER: SCHN~RTZ INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HURIZ. DEPARTURE MbA~URED VERTICAL VERTICAL DEV-IATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST D~ST. AZ[RUTH DEPTH DEPTH DEPTH .:...: ..... : ...... N 8000.00 6379.48 8ZO0.O0 6451.45 6377.45.'~~..~ 8300.00 6596.06 6522. 8~00.00 6668.60 6594.60 43 27 8~00.00 6741.28 6667o28 '43 12 8600000 6814.78 6740.78 .42 'T 8700000 6889.18 6915.18 41 8800.00 6964.17 6890.17 40 58 8900.00 7039.94 6965.94 40 35 9000000 7116.05 7042.05 40 15 9100o00 7192.64 7118.64 39 42 9200000 7269.64 7195.64 39 37 9300.00 7346.71 7Z72.71 39 30 9400.00 7423.90 7349.90 39 30 9500000 7501.03 7427.03 39 29 9600°00 7578o25 7504o25 39 24 9700000 'r655.62 7581.62 39 13 9800000 7733.09 7659.09 39 7 9900.00 7810.69 7736069 39 14 10000000 78~8.06 7814.06 39 22 10100.00 7965.29 7891.29 39 27 10200o00 8042045 7968.45 39 36 10300.00 8119.47 8045.47 39 31 10400000 8196.97 8122.97 38 46 10500.00 8275.50 8201.50 37 46 10600.00 8355.06 8281.06 36 50 10700°00 8435L71 8361.71 35 42 10800.00 8517.53 8443.53 34 25 10900000 8600.43 8526.43 33 43 11000000 8684.28 8610.28 32 8 11100.00 8769.63 8695.63 30 39 11200o00 8855.73 8781.73 30 22 11500000 8942°02 8868.02 30 20 11400000 9028.33 8954.33 30 20 11500000 9114.63 9040.63 30 20 11600.00 9200.93 9126.93 30 20 11650.00 9244.08 9170.08 30 20 DEG M[N PEET DEG/IO0 S 66 34 E 4193.31 S 66 8 E 4262.55 S 66 19 ~ 4331.48 S 66 18 E 4400.33 S 66 7 E 4468.98 S 65 59 E 6537.49 S 65 22 ~ 4605.16 S 64 55 E 4671.88 S 64 6 E 4737.97 S 63 38 E 4803.20 S 62 50 E 4868.04 S 62 16 E 4932.34 S 62 Z E 4996.14 S 61 37 E 5059.86 S 61 10 E 5123.44 S 60 47 E 5187.07 S 60 28 E 5250.59 S 59 51 E 5313.91 S 59 2 ~ 5377°07 S 58 10 E 5440.04 S 57 6 E 5503.21 S 56 29 E 5566.46 S 55 56 E 5629.75 S 55 3 E 5693.10 S 54 28 E 5755.79 S 54 1 E 5817.14 S 53 33 E 5877°08 S 53 Z E 5935.53 S 52 10 E 5992.24 S 51 44 E 6047.30 S 52 4 E 6100.92 S 51 48 E 615Z.22 S 51 25 ~ 6202o26 S 51 24 E 6251.92 S 51. 24 E 6301.57 S 51 24 E 6351.22 S 51 24 E 6400087 S 51 24 E 6425.70 0.49 0.46 0.Z5 0.24 0.44 0.61 0.76 0.63 0.88 0.48 0.71 0.59 0.31 0.36 0.33 O.47 0.35 0.57 0.79 0.63 0.56 0.35 0.67 0.60 1.14 1.16 0.67 1.20 1.40 0.86 1.91 0088 1 0o00 0.00 0.00 0000 FEET FEET FEET DEG 1784.12 S 3800.42 E 4198.37 S 64 51 E 1812.03 $ 3864.00 E 4267.78 S 64 52 E 1839.92 S 3927.24 E 4336.88 S 64 53 1867.62 S 3990.47 E 4405.89 S 64 55 E 1895.37 S a053.46 ~ 447~.70 S 64 56 E 1923.24 S 4116.24 E 4543.38 S 64 57 E 1951.17 S 4178.02 E 4611.18 S 64 58 E '"~'~ 1979.23 S 4238.66 F. 4677.99 S 64 58 2007.67 S 4298.39 = 4744.14 S 64 57 E 2036.41 S 4356.99 E ~809.39 S 64 56 E Z065.60 S 4414.91 E ~874.Z3 S 64 55 2095.23 S 4471.97 ~ 4938.47 S 64 53 E 2125.00 S 4528.40 E 5002.Z1 S 64 51 E 2155.08 S 4584.58 i 5065.~4 5 64 49 F_ 2185.53 S 4640.39 E 5129.30 S 64 46 E 2216.38 S 6696.05 E 5192.81 S 64 44 E 2247.53 S 4751.43 E 5256.19 S 64 41 2279.01 S 4806.41 E 5319.35 S 64 37 E 2311.16 S 4860.8.6 E 5382.32 S 64 34 E 2363.98 S 4914.72 E 5445.07 S 64 30 E Z377.88 S 4968.24 E 5507.97 S 64 25 E 2612.69 S 5021.37 E 5570,93 S 64 ZO E 2468.02 S 5074.27 E 5633.92 S 64 14 E 2484.18 S 5126.81 E 5696.96 S 64 8 E 2520.64 S 5178.43 E 5759.32 S 64 2 E 2556.78 S 5228.70 E 5820.35 S 63 56 E 2592.60 S 5277.55 E 5879.97 S 63 50 E 2627.9Z S 5324.97 E 5938.12 S 63 ~3 E 2662.83 S 5370.65 E 5994.54 S 63 37 E 2697.30 S 5414.69 E 6049.32 S 63 31 2730096 S 5'457.53 E 6102.6~3 S 6'3 ?.4 E 2763.01 S 5498.59 E 6153.76 S 63 19 E 2794.56 S 5538.49 E 6203.59 $ 63 13 E 2826.08 S 5577.98 E 6253.05 S 63 7 E 2857.59 S 5617.47 E 6302.52 S 63 2 E 2889.11 S 5656.95 E 6352.01 S 62 56 E 2920.62 S 5696.66 E 6401.52 S 62 51 E 0.00. 2936.38 S 5716.18 E 6426.28 S 62 48 E ARCO ALAS&A ZNC. D.$. 12-30 PRUDHOE BAY NORTH SLOPE~ ALASKA COMPUTATION DATE: 8-MAR-89 PAGE 4 DATE OF SURVEY: 23-JAN-S9 KELLY 8USHTNG ELEVATION: 74.00 F'T ENGINEER: SCHWARTZ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL'~DEVZATXON AZZHUTH DEPTH DEPTH OEPTH o.oo o.oo lO00.O0 999.93 925.93 zooo.oo 9oo.ze 3000.00 2843.72 4000.00 3596.97 3522.97 5000.00 ~302.7! ~228.7! ~ ~0 6000.00 4980.77 4906.77 7000.00 5667.03 5593.03 ~.~ 8000.00 6379.48 6305.48 44 0 9000.00 7116.05 7042.05 40 15 10000.00 7888.06 7814.06 39 22 11000.00 8684.28 8610.28 32 8 11650.00 9244.06 9170.08 30 20 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/tO0 FEET FEET FEET DEG MIN N 0 0 E 0o00 S 59 53 E 4.53 S 57 31 E 172.87 S 59 40 E 670.70 S 65 50 E 1326.94 S 64 39 E 2033.62 S 65 20 E 2768.17 S 66 17 E 3493.70 S 66 34 E 4193.31 S 62 50 E 4668.04 0.00 3.45 3.83 1.73 0.48 0.56 2 0.69 0.49 0.71 0.00 N 0.00 E 0.00 N 0 0 E 1.65 S 4.25 e 4.56 S 6.8 ~9 E 93.16 S la6.26 E 173.~1 S 57 30 E 301.42 S 599.34 E 670.87 S 63 18 E 565.71 S 1191.40 E 1327.59 S 63 49 E 873.72 S 1838.58 E Z035.62 S 64 34 E 1205.69 S 2493.99 E 2770.14 S 64 11 E '*~"- 1503.65 S 3157.23 E 3497.01 S 64 32 E 1784.12 S 3800.42 E 4198.37 S 64 51 E 2065.60 S 4414.91 E 4674.23 S 64 55 E S 57 6 E 5503.21 S 52 & E 6100.92 S 51 24 E 6425.70 0.56 1.91 0.00 2377.88 S 4968.24 E 5507.97 S 64 25 E 2730.96 S 5457.53 E 6102.68 S 63 24 E 2936.38 S 5716.18 E 6426.28 S 62 48 E ARCO ALASKA ZNC. U05. 12-30 PRUDHOE BAY NORTH SLOPEr ALASKA COMPUTATION DATE: 8-MAR-89 PAGE 5 DATE OF SURVEY: Z3-JAN-89 KELLY 8USHTNG ELEVATION: 74.00 FT ENGINEER: SCHNARTZ INTERPOLATEO VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUa-SEA ~.. COURSE MeASUReD VERTICAL VERT'rCAL .I~EVtATTON AZIMUTH DEPTH DEPTH OEPTH O~.~, pZ N OEG MIN O.O0 0.00 -7~.00~~~._~ " , N 0 0 E 7~.U5 7~.00 0.00~~ N 7~ 59 E 17~.U5 17~.00 100 O0 .. ~..: S 58 13 E 200:00 N 77 31 N Z14.05 Z74.00 374.05 374.00 300.00 0 ':3 S 72 3 E 474.05 4r4.00 400.00 0. 13 S 77 11 E 5'/4.05 574.00 500.00 ~:": 0 21 S 70 34 E 674.05 674.00 600.00 '0 21- S 68 50 E 1'74.06 774.00 700.00 O-22 S 74 35 E 874.06 874.00 800.00 0 31 S 70 8 E 974.01' 974.00 900.00 I 6 1074.16 1074.00 1000.00 3 57 1174.60 1174.00 1100.00 6 22 IZ75.40 1Z74.00 lZO0.O0 7 40 1376.41 1374.00 1300.00 8 34 1477.60 1474.00 1400.00 9 1 1579.02 1574.00 1500.00 10 20 1680.89 16/'4.00 1600.00 11 30 1783.06 1774.00 1700.00' 12 11 1885.81 1874.00 1800.00 14 46 S 66 33 E S 50 12 E S 53 37 E S 58185 S 61 46 E S 61 34 E S 58 33 E S 57 Z E S 56 34 E S 54 45 E 1990.23 1974.00 1900.00 18 25 Z096.75 2074.00 ZO00.O0 21 48 ZZ05.38 2174.00 2100.00 24 7 2316.03 Z274.00 2200.00 26 32 2429013 2374.00 2300.00 29 · 1545.00 2474.00 1400.00 31 26 2663.48 Z574.00 2500.00 33 27 2185.ZZ 2674.00 2600.00 36 7 Z911.10 27?4.00 2700.00 38 23 3038.61 2874.00 2800.00 38 25 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 3166049 2974.00 2900.00 38 46 3296.09 3074.00 3000.00 40 14 3428.08 3174.00 3100.00 40 58 3560.89 3274.00 3200.00 41 37 3695046 3374.00 3300.00 42 26 3831029 3474.00 3400.00 42 45 3968021 3574.00 3500.00 43 36 4107012 3674.00 3600.00 44 17 4Z47.48 371'4.00 3700.00 44 48 4389015 3874.00 3800.00 45 12 0.00 0.00 0.00 N 0.00 E 0.02 0.16 0.01 S 0.02 E 0..03 0.00 0.03 S 0.01 E 0.05 0.00 0.08 S 0.01 E 0.06 0.00 0.07 S 0.03 E 0.28 0o00 0.15 S 0.24 E 0.82 0.00 0.31 S 0.76 E 1.46 0.02 0.57 S 1.35 E Z.05 0.05 0.72 S 1.93 E Z.81 0.19 0.96 S 2.69 E 3.92 1.54 1.37 S 3.71 E 8.05 2.69 3.84 S ·.08 E 17.21 3.16 9.62 S 14.37 E 29.79 0.92 16.68 S 24.87 E 44.03 0.53 23.77 S 37.23 E 59.45 0.90 31.02 S 50.84 E 76.34 2.24 39.33 S 65.55 E 95.74 0.60 49.77 S 81.97 E 116.57 1.ZZ 140.01 3.49 S 57 0 E 169.77 S 61 36 E Z06.35 S 64 25 E 248.78 S 66 59 E 295.99 S 67 36 E 348.56 S 67 33 E 406.79 S 65 33 E 470.11 S 66 35 E 539.37 S. 64 40 E 615.59 . S 59 46 E 694.65 S 64 57 E 774.32 S 66 31 E 856.51 S 65 23 E 942.46 S 64 21 E 1029.75 S 63 5 ~ 1119.77 S 64 I E 1Zll.66 S 65 50 E 1305.03 S 66 30 E 1401.Z0 S 67 4 E 1499.33 S 66 23 E 1599.34 3.66 Z.63 2.67 2.35 2.15 1.81 2.17 2.53 4.44 1.32 2.91 1.18 1.25 0.88 0.77 2.12 0093 o19 .5! 0~58 ~.:,- 0.00 N 0 0 E 0.02 S 72 11 E 0.03 S 24 54 E 0.08 S 8 40 E 0.08 S 19 21 E 0.28 S 57 Z2 E 0.82 S 67 38 E 1.46 $ 67 16 E 2.06 S 69 28 E 2.84 S 70 15 E 3.95 S 69 44 E 8.06 S 61 29 E 17.30 S 56 11 E 29.95 S 56 9 E 44.17 S 57 26 E 59.56 S 58 36 E 76.44 S 59 I E 95090 S 58 44 E 61.22 S 99.48 E 116.81 S 58 23 E 74.51 S 118.96 E 140.37 S 57 56 E 91.47 S 143.65 E 170.30 S 57 30 E 110.01 S 175.23 E 206.90 S 57 52 E 129.27 S 213.03 E 249.19 S 58 45 E 148.61 S 256.22 e 296.20 S 59 53 E 168.89 S 304.98 E 348.62 S 61 I E 191.11 S 359.10 E 406.79 S 61 58 E 216.36 S 417.39 E 470.13 S 62 35 E ,*'~' 244.83 S 480.69 E 539.45 S 63 0 E 275.42 S 550.74 E 615.77 S 63 25 E 313.49 S 620.04 E 694.78 S 63 10 E 350.80 S 690.44 E 774.44 S 63 3 E 383.93 S 765.90 E 856.74 S 63 22 E 418099 S 844.59 E 942.81 5 63 36 E 456.28 S 923.63 E 1030.19 S 63 ~2 E 496.32 S 1004.29 E 1120.24 S 63 42 E 537.78 S 1086.32 E 1212.15 S 63 39 E 576.72 S 1171.35 E 1305.63 S 63 47 E 615.87 S 1259.45 E 1401.97 S 63 56 E 654.41 S 1350.10 E 1500.34 S 64 8 E 693.94 S 1442.34 E 1600.59 S 64 18 E COMPUTATION DATE: 8-MAR-89 PAGE 6 ARCO ALASKA /NC. D.S. 12-30 PRUDHUE BAY NORTH SLOPEr ALASKA DATE OF SURVEY: 23-JAN-89 KELLY BUSHING ELEVATION: 766.00 FT ENGINEER: SCHWARTZ ZNTERPOLATEO VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE MEASURED VERTICAL VERTICALs, DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/NEST OIST. AZIMUTH 4531.,59 3974.00 3900.00,? .... ~-"' 4674.18 4074.00 4000. OlF:%~ '. 4816o07 41766.00 4100.00'~.- ~ 4958092 66Z74.00 4200000~ b102.35 66374.00 4,300o00~'~,~ 45' S8 524,6o76 666674 o O0 66400.00 4,6:28 5392.662 6651'4.00 4500°00 ~ 46 S:3 5539.83 666766.00 4600°00 --.4r?'~'3 56~8.53 66774. O0 4700.00 4'B 25 5839.91 4874.00 66800.00 48 29 59.89.97 4974.00 4900.00 47 22 6156.17 5074.00 5000.00 666 42 6282028 5174.00 5100.00 667 2 6430.65 527~.00 5200.00 4.7 44 6~78068 53766.00 5300.00 47 9 6'i'25o00 5474. O0 5400. O0 46 166 6869.06 55766.00 5500.00 45 25 7009.72 5674.00 5600.00 43 59 7148.53 5774.00 5700.00 664 8 7288.83 5874.00 5800.00 664 47 7429.82 5974.00 5900.00 664 566 7571oZZ 6074.00 6000.00 665 7 7~12o~Z 61766.00 6100.00 664 666 7853°02 62766.00 6200.00 664 20 799Z038 63766.00 6300.00 466 0 813102~ 6474.00 66600.00 663 663 8269053 6574.00 6500.00 663 37 8407043 6674.00 6600.00 663 28 8544075 67~4.00 6700.00 662 46 86r9.62 68766.00 6800.00 661 50 ~813.01 69766.00 6900.00 660 5Z 8944.81 1074.00 7000.00 660 28 9075.13. 'r1~4.00 7100.00 39 52 9205066 7274.00 7200.00 39 36 9335.36 73766.00 7300.00 39 27 9464°96 74766.00 76600000 39 32 9594050 757~o00 7500.00 39 Z~ ~7Z3073 7674.00 7600.00 39 13 9852.68 7774.00 7700.00 39 3 9981081 78~4.00 7800.00 39 21 DEG NrN FEET DEG/IO0 FEET FEET S 65 51 E 1700.52 S 65 52 E 1801.93 S 65 17 E 1902.40 S 666 54 E 2004.27 S 64 4 E Z106.99 S 63 13 E 2211.13 S 62 25 E 2317.03 S 61 18 E 2425.33 S' 63 14 E 2535.37 S 63 47 E 2648.99 S 65 5 E 21'60.79 S 65 23 E 2867.23 S 64 39 E 2973.63 S 65 25 E 3083.10 S 65 41 E 3192.05 S 66 48 E 3298.59 S 67 20 E 36601.87 S 66 15 E 3500.45 S 66 ZZ E 3596.45 S 66 25 E 3694.58 S 66 18 E 3793.68 S 56 18 E 3893.37 S 66 32 E 3993.19 S 66 37 E 4091.29 S 66 37 E 4188.03 S 66 8 E 4284.12 S 66 ZO E 4379.37 S 66 6 E 44766.07 S 65 41 E 4567.95 S 65 I E 4658.30 S 64 I E 66746049 S 63 17 E 668.32.30 S 62 266 5 4916.80 S 62 I E 4999.76 S 61 27 E 5082.35 S 60 57 E 51666.78 S 60 30 E 5247.10 S 59 38 E 5328.90 S 58 38 E 5410.22 S 57 17 E 5491.71 0.25 0.45 0.47 0.4,8 O.TO 0.58 0.69 0.71 1.23 1.32 2.566 0.668 0.90 0o70 O.IZ 1.54 1.41 0.53 0.80 0.27 0.666 0.16 0.81 0.27 0.50 0.53 0.39 0.46 1.73 0.50 0.67 0.61 0.82 0.32 0.36 0.17 0.32 0°55 0.98 . ~,.69 ., FEET DEG MZN 735.06 S 1535.06 E 1701.97 S 64 Z4 E 776.58 S 1627.83 E 1803.58 S 666 29 E 818.25 S 1719.46 E 1904.22 S 666 33 E 861.20 5 1812.00 E Z006.24 S 64 34 E 905.667 S 1904.79 E 2109.05 S 666 34 E 951.73 S 1998.166 E 2213.22 5 666 31 E 1000.15 S Z092.33 E 2319.09 S 64 27 E"'~' 1051.11 S 2187.89 E 2427.28 S 64 ZO E 1102.97 $ 22~66.95 E 2537.23 S 6& 13 E 1153.97 S 2386.51 E 2650.86 S 666 11 E 1202.55 S 26687.29 E 2762.75 S 666 11 E 1246.69 S 2584.38 E 2869.36 S 666 166 E 1291.79 S 2680.89 E 2975.B9 S 64, 16 E 1338.56 S 2780.01 E 3085.48 S 666 17 E 1383.77 S 2879.35 E 3194.60 S 6½ 19 E 1427.01 S 2977.02 E 3301.36 S 666 23 E 16667.35 S 3072.566 E 3404.966 S 6~ 28 E 1506.37 S 3163.43 E 3503.,77 S 666 32 E 15665°05 S 3251.59 E 3600.00 S 666 35 E 15866.40 S 33~1.80 E 3698.37 S 64 38 E 1624.28 S 3432.83 E 3797.71 S 666 40 E 1664.665 S 3524.36 E 3897.63 S 666 43 E 17066.48 S 3616.13 E 3997.T0 S 666 45 E 17663.53 S 3706.46 E ~096.06 5 666 668 E 1782.01 S 3795.56 E 4193.07 S 6~ 51 E 1820.77 S 3883.78 E 4289.40 S 666 52 E 1859.18 S 3971.22 5 &3666.88 $ 666 54 E ~.-~ 1897.466 S 66058.166 E 4479.81 S 64 56 E 1935.73 S 4144.10 E 4573.90 S 64 57 E 1973.669 S 66226.366 E 66664.660 $ 6& 58 E 2011.39 S 4306.07 E 4752.67 S 666 57 E 20669.41 S 4383.066 E 4838.50 S 64 56 5 2088.02 S 4458.20 E 66922.966 S 666 54 E 2126.69 S 4531.59 E 5005.81 S 6~ 51 E 2165.79 S 4604.366 E 5088.Z9 S 64 48 E 2205o53 S 66676.58 E 5170.56 S 6& 45 E 22665.82 S 66748.39 E 5252.70 S 666 661 E 2286.57 S 66819.38 E 53366.30 5 6~ 37'E 2328.32 S 66889.27 E 5~15.36 S 666 32 E 2371.64 S 4958.54 E 5496.53 S 666 26 E ARCO ALASKA [NC. U.S. 12-30 PRUDHOE BAY NURTH SLOPE, ALASKA COMPUTATTON DATE: 8-MAR-89 · PAGE 7 DATE OF SURVEY: Z3-JAN-89 KELLY BUSHING ELEVATION: 74.00 FT ENGINEER: SCHNARTZ INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HURIZo DEPARTURE MEASURED VERTICAL VERTZCAL'WEVXATZON AZIMUTH SECT[ON SEVERITY NORTH/SOUfH CAST/dEST DIST. AZIMUTH DEPTH DEPTH DEG M£N FEET DEG/IO0 FEET "FEET FEET DEG MXN 10111o28 797a.00 102~0097 807~o00 10370.~7 817~o00 10&98oll 8ZTa.O0 106Z~.60 8374.00 10146099 8474000 8400000 '135 9 10868.20 B57~o00 8500.00 '33 5] 10987-85 8674.00 8600.00 32 2~ 11105°08 87T4.00 8700.00 30 38 11650000 9244.08 9170008 30 20 S 56 26 E 5573.59 S 55 31 E 5655.73 S 54 38 E 5737.40 S 54 2 E 5816.00 S 53 28 E 5891.02 S 52 38 E 5962.~1 S 51 51 E 6029089 S 52 I E 6094.53 S 51 47 E 6154.77 S 5! 24 E 6&25.70 0.32 0.71 0.97 1.17 1.43 I .35 0.34 2005 0.73 0.00 2416.65 S 5027.35 E 5578.03 S 64 19 E 2462.7~ S 5095.88 E 5659.77 S 64 12 E 2509.88 S 5163.~1 E 57~1.02 S 64 4 E 2556.10 S 5227.77 5 5819.21 S 63 56 E 2600.98 S 5288.87 E 5893.84 S 63 48 E 26&4o37 S 53¢6.67 E 596~.86 S 63 41 E 2686.36 S 5400.78 E 6031.99 S 63 33 E ...... 2726.97 S 5452.41 E 6096.32 S 63 25 E 2764.61 $ 5500.63 E 6156.30 S 63 18 E 2936.38 S 5716.18 E 6426.28 S 62 48 5 ARCO ALASKA XNCo Do$o 1Z-30 PRUDHOE BAY NORTH SLOPEr ALASKA MARKER SAG SHUBLIK LAST GCT READING ZONE 4 TOP SAOLEROCH[T HOT ZONb ~ PBID TO COMPUTATION O4T(: 8-RAR-89 KELLY INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCAT]:ON = ~.O0~FSL & : ;? ..:_R. EASURED DEPTH . "~?'" BELOW KB ~::.'.;~~ 118 8.0 0 · ..',~!'~':_:. ~ 1 z ']. T. o o /"'-: "'-" -: '~.~. 112:17.10 .:;" . :r 11309. OO :'.--.:?, ' 11309 °00 ":~ ' .. ~.. ,11~.91. O0 11554.00 11&03.00 11650.00 TVO FROR KB SUB-SEA 8845,.58 8771.38 8870.39 8796°39 8870°48 8796.48 8949.79 8875.79 8949°79 8875.79 9073.Z0 8999.20 9106.86 9032.86 9161.23 9087.23 9Z03.52 9129.52 9244.08 9170.08 DATE 9USHZNG 6" FEL~ SEC18 RECTANG NORTH/ 2790° 2?99° 2799. 2828. 2828. 2:873. 2986° 2906. 2921° 2936. OF SURVEY: ELEVATION: PAGE 8 Z3-JAN-89 74°00 FT ENGINEER: SCHNARTZ t TION~ R15E UM ULAR COORDINATES SOUTH EAST/~EST 77 S 5533.73 E 92 S 5545°Z1 E 95 S 5545.Z~ E 92 5 5581.54 E 92 S 5581.54 E 98 S 5638.00 E Z7 S 5653.40 E 12 S 5678.27 E 57 S 5697°~Z E 38 S 5716°18 E ARCO ALASKA INC. D.$. 12-30 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER SAG SHUBLIK LAST GCT READING ZONE 6 TOP SADLEROCHIT HOT ZONE 3 PBTU TO COMPUTATION DATE: 8-MAR-89 DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: PAGE 9 Z3-JAN-89 7~.00 FT SCHWARTZ f~WW:~WWWWf~4c STRAT]:GRAPHIC SUMMARY ~W:~:~ ~WW~:,'~ ~:,~i!i'#EASURED DEPTH ~'~;,;BELOi KB · ~~'11188 O0 .,:.,~::~.?~:1121T O0 "-,:~-i:'~:'*~¥'11217 10 11309 O0 11309.00 11652.00 11~91o00 1155a.00 11603°0O 11650°00 SURFACE LOCATION = 400'FSL E 6~ FEL, SEC18, TION, R15E UN TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/~EST 8845.38 8771.38 2790.77 S 5533.73 E 8870°39 8796.39 2799°92 S 5565.Z1 E 8870°68 8796,,48 2799°95 S 5565.25 E 894~9.79 8875.79 2828o9Z S 5581o56 E 8949.79 8875°79 282B°gZ S 5581.56 E 9073.Z0 8999.20 2873.98 S 5638°00 E 9106.86 9032.86 2886.27 S 5653.60 E 9161.o23 9087.23 2906.12 S 5678.Z7 E 9203.52 9129.SZ 2921.57 S 5697.62 E 9264.08 9170°08 2936.38 S 5716,,18 E FINAL NELL LOCATTON AT TD: TRUE SU~-SEA MEASURED VERTICAL VERTTCAL DEPTH DEPTH DEPTH 11650.00 9Z~.6.08 9170.08 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 66Z6°Z8 S 6Z 68 E WELL' (400' D.S. FSL, lz-3o (- ( 6" FEL, SEC '.,.t, TION, R15E, UM) HORIZONTAL PROJECTION I~ '7'9194 $C~L~ = 1/1000 IN/FT 0 1000 ~'000 3000 4000 5000 6000 '7000 .. . · I. WELL' (400' .{ ( V ,T C^L ,,O ECT O, FSL, 6" FEL, SEC ,d, TION, R15E, UM) -4000 -~00 0 0 ~ 41:100 6000 __mO00__ l_~mOt'mJ_ ! ~000 i ! I I i ~ i ii i I i' ~ i : I 1 : I I i ; ' i : ' i ! : i · ~ ........ --,-~- , i ....'-,-T,~- - - ' ["?iii ;:,.. I ~,~l ~ ,..-,~.'- -~~' ~-r..?f" ":.*ff..';"'...'"t'tt~.-~"~'f-f*-..-..~-.?:.-T.......'-:-'; ~ ~-~.-+.-.~-..'+.~+.~+.%-.!-~.'.-+;+-;. ,' ! ; i ] , ~ ~ , ~ ; T', ~ : ~: ~ , . : t · : : .-1 , ,t~?'T":-f'r?'? ...... ?T'.I-~ ~il !:~: iiii - " ...... ' .................. i .'. ~ i ] I ! ~ ! ~, 1".~ t. ~ I '.. ,.~'1'T"..'~"?' -1~-1..??.~.-..~-~T.....-..~-~.~.?~`...-~r-~..~.~-~-1...T~?~-?.-r~:-1-t-.. 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' ' ~ I I ~: · I 1 .iiiliiLi~i_~,~il, l]_J_L,~.'.iLi_j, lll Iiii III ~i iI~ ~i~ ili! iiii ~l iii! 111i i; 1-I- ,.~-~,, .~ _l'I'.'!-I ~ i , ii i 1 i i - ! , ' ,: i I ,.' ~_t '' i I i i "-!-' · -~£~T-"'',,-T~-- I j~- ~ ..... -1-~: _...~""'~- ~., '- !-' !:'T~-'- ' ~!~;~-:: !,l, ,,~ ~tll t i11~ .I'_~'-I-! i i ~'.1-??-C,"?r--?~TT--,.~FT'F,~- ,: iii! ii;I ~ ii; ' '!i itli 11: I l; r, ~ .-t 1- ; i , ~ ;,i; :]iT- ~ ~ ~ i' i ~ ~ !: i i ~' ?~:!-: ~T+'~[li] ]1 ..... ~ ~ ....~ ~--.! ' ' ~--~ .... '~.~--i-----~-~.i,-~'~-~-~...~.~-~-~..- J i ! I , : ! I ~ ' ! ' i : ' ' ! ~ ': : ' ': '. : & ' ' '.I ! ~: : . I : : ! _ ~! _," !~--I''_.--~ ! ] i ! ! ! '!". : i i ! i i I : ~ ~ ~ ~ I ~! ~ ~ ? . ' "'.'--." -".'r - " ~ : ~ ','-.'-r..-l"1"- _..'j ! i ~ ~'~ ~ i'1~,'"~'?~ ~ ~ ~ ~ ~ ~ . i ' ' ' i i , i; t I i~ ~ ..~ff"~,"'Y't' i; i i i i!! "i"'~-.+-f--+'."f-ff";?-'-ff.'~:.'-~ ~; [ ,~_,~':_I'?T~! ' ! i-I-_1- -t-~'? 'i"1'I",--1'I"i i I ~-~ ~' ~-~ ~ .-+~,. ..... ..,~ -'-, ~-~-, ~ , '~-+'+'+',, -'~-~"~,: , ~'~"~'"", , '"~"~""-~'-,, '"rT" ...... 1'' "-~. _.,--'r t' ' -'-'"'~',-r...- .?-'-'-- I I i Ii I t ~I I i ii i i i! ! i I" i ! ! i i ~ ~ ~, i i , ~I 'I"1 ~ ! "~ ' : ' i : ---i-..?-r..~- ~ ..~.-...--!-+-~r-?-- ! _". ! ~ ~ _.' I J 1_iii Jill _i ! _.' i I!i! ''': !!"' !!~ i111 l}i'. .I~t :!ii !i'I I ii ! ' I i ,I'~ I i I ii I .1-1- ! i i iI I ! ii ' ' ', ' i ' j. , ,' ' ' ' I ~ ~ , I;; , ' ' I ~ , ,- :- i , , .... ?. ~ ~ ,---r---r-r . ' ' ........ ~"'~'~ i ...... ,~--t, . ...... ' i !." i i ! i I i II i ~ i! i I Ii '. ! ! ' 4-'.I-~-.~'= .4~ '4--,' .i.--'.i-'; ~. -" .i.4..~.';....~-';..4..i..~. ~..~..'~-J-.';-.~..-i....--'. '.~-A..;-. 1~i iiil :ii~ i'~ ~i~11ii~ ,i'll~ill i,~ ~i~i PROJECTION OH ~R~I*'ICI:IL J:q,.l:lf~ 118. - 2~. m IN VERT]Q:L ~F..FTH6 J-~RIZ ,SCd~.£ = 1/2~00 IN/FT SCHLUMBERGER O ~ RECT ~ ONAL SURVE.Y COMPANY ARCO ALASKA INC. WELL O.S. 12-50 FI ELD PRUOHOE BAY COUNTRY USA RUN ONE BATE LOOOEB 25 - JAN - 89 REFERENCE 7S174 ARCO ALASKA, INC. P,O, BOX ANCHORAGE, ALASKA 995i0 DATE' 8-29-89 REFERENCE' ARCO PRESSURE DATA 3-t5 7-'27-89 BHP--$TATIC GRADIENT 3-33 7-t4-89 BHF'--£TATIC GRADIENT 4-2 7-8.-89 BHF'--$TATIC GRADIENI' 7-5 7-~ 9-89 BHP--~'TATIC GRADIENT 7-7A 7-3~ -89 BHF'--PBU 7-8 '?-29-89 BHP--$TATIC GRADIENT 7-~ ~ 8-5-89 BHP---~'TATIC GRADIENT 7- i 4 '7-29-89 BHP---PBU 7-27 7-2~-89 BHP--£TATIC GRADIENT '7-33 7-23-89 BHP--$TATIC GRADIENT 9-24 7/t4-t5/89 BHP-.-X'TATIC GRADIENT 9-38 8-~2-89 BHP--$TATIC GRADIENT ~t-2 7-7-89 BHP--$TATIC GRADIENT ti-7 7-9-89 BHP--$TATIC GRADIENT t i -i 6 7-t (~-89 BHP--£1'AmFIC GRADIENT ti-t7 8-ii-89 BHP--FLOWING GRADIENT t 2-30 '?-2~-89 BHF'--$TAI'IC GRADIENT i4..-i9 8-iG-89 BHP--$TATIC GRADIENT i4-22 8-i7-89 BHP--$TAI'IC GRADIENT i 4-36 7-29-89 BHP--FLOWING GRADIENT t 4-~9 8-i 3-89 BHP--£TATIC GRADIENT tS-t~ 7-2i-89 BHP--STATIC GRADIENT t 6.-t 2., 7-26-89 BHP--$I'ATIC GRADIENT t 6.-2~ 7'-i 3-89 BHP--STATIC GRADIENT. t 8-25 7-.i 3-89 BHF'--$TATIC GRADIENT (W/ATTACH,) PLEA£E SIGN AND RETURN THE AT'FACHED COPY A£ RECEIPT CAMCO CAMCO CAMCO CAMCO HR$ CAMCO CAMCO HR$ CAMCO CAMCO CAMCO CAMCO HRS HR$ HR$ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO OF DATA. DISTRIBUTION CENTRAL FILES CHEVRON D & M 'If EXTENSION EXF'LORAI'I ON ~',, EXXON MARAI'HON ~.. . ' ~ MOBIL ' -- / F'HILLI F'~' PB WELL FILES · . R & D ~ BF'X ~ STATE OF ALASKA ~~ TEXACO ARCO ALASKA, INC, F'.O. BOX i80368 ANCHORAGE, ALASKA DATE: 8-tt-89 REFERENCE: ARCO CASED HOLE FINALS 2-t4 ?-t4-87 PITS RUN 2-22 ?-~6-89 PITS RUN 4-22 8-4-89 COLLAR/PERF RUN 4-26 ?-t2-89 TEMP RUN ?-5 ?-i9-89 GR/CCL RUN io 7-7A 7-38-89 SPINNER/TEMP RUN ?-~4 7-28-89 SPINNER/TEMP RUN 7-~ 7-23-8? COLLAR RUN ~-~8 5-~8-89 TMD RUN ~t-24 5-~7-89 TMD RUN ~-25 7-~2-89 TEMP ~ RUN ~2.-38 7--2~-89 COLLAR RUN ~4-~5 7-28-89 PITS RUN ~4-~6 ?-~7-89 PITS RUN ~4-28 7-2t-89 PITS RUN ~4-24 7-22-8~ PITS RUN PLEA2E SIGN AND RETURN THE ATTACHED COPY A£ RECEIPT OF DATA. 2"&5" 5" 2"&5" 5" 5' 5" 5" 5' 5" 5' 5' 5" CAMCO CAMCO ATLAS CAMCO CAMCO OTIS OTIS CAMCO HL$ HL$ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO Am lomOe DISTRIBUI'ION ~ CENTRAL FILES . ~ PHILLIPS ~ CHEVRON F'B WELL FILES · ' D&M R&D ~ EXTENSION EXPLORATION ~ ~ BPX ~ EXXON ~ ~ STATE OF ALASKA MARATHON ~ ~ TEXACO ~ MOBIL * THE CORRECTED API% FOR t4-~ I$ 50-029-28688, ARCO ALASKA, INC. P.O. BOX i00360 ANCHORAGE, ALASKA DATE: 8-2-89 REFERENCE: ARCO CASED HOLE FINALS i-4 5-26-89 PERF RECORD RUN t-t7 7-3-89 PERF RECORD RUN 2-4 6-24'-89 PERF RECORD RUN 2-t6 7-3-89 F'ERF RECORD RUN 3-9 5-i0-89 COLLAR/PERF RUN 4-5 6-tt-89 PERF RECORD RUN 4-t9 5-3t-89 F'ERF RECORD RUN 7-i6 5-i-89 COLLAR/PERF RUN fi-t3 5--24-89 F'ERF RECORD RUN ff-t6 5-24-89 F'ERF RECORD RUN tt.-28 7-24-89 CBT RUN tt-28 '?-24-89 CE'[ ,. RUN tt-28 7-24-89 GR RUN t2-23 6-4-89 PERF RECORD RUN t2-25 6-t5--89 PERF RECORD. RUN t2-38 6-t-89 PERF RECORD RUNS ~2-35- 6-2=89 .-F'ERF RECORD .......... RUN~.. ~2-3J 6-3-89 PERF RECORD RUNS ~4-2 ?-~-89 PERF RECORD RUN ~4-27 6-29-89 PERF RECORD RUNS ~?-9 6-I6-89 PERF RECORD 'RUN PLEASE SIGN AND.i. RE'FURN- THE ATTACHED COF'Y ,AS RECEIPT OF DATA. RECEIVED BY ....... '' ~ ' ~_-~_'.""' .'_~_."~' ' HAVE A NICE' DAY, ~._~ C~V~~ SALLY HOFFECKER ,:,y~t'" ,,,~,.~,.~...:~..~,~,,-,;~-.,~,," ...... . AT0-i. 529 .... !::-'""""".."- ,~.r~,."'"'.'~.' 'I'RAN,S'~ 89~26 .-~;~ ..... UTC',, :~'~ ' ......... ~:.~ ..... ,~ ..,..~.,..~?.. · ?, ',~ ,, ~D; :.?;~ ·. .'" .... ...: ·. ~.....~, ~ -..,%~,... ~.... · .;- ....~..~,'.',~.( ,~.~ .... .... .... f .........~-. o DI$~RIBU'FION ,~: ~?~" ".4,'. .'-1: ., ~;~ . , ~ .,. ',~;:. -' .,... ,', . ', .. · ,.. CENTRAL:.:"F.I~E"$*... ..... D&M ~~ EXTENSION EXF'LORATION ·,,'~EXXON · MARATHON MOBIl_ PHILLIPS F'B WELL FILES R & D BPX ~ ' STATE OF ALASKA TEXACO , 5" t-6, 5' t-6, 5'. t-3, 5 '"" , 5".' t&2, 5" 2"'"'5~' ...... ~':" HLS i..IL$ i-ILS .41 ¢, FILS' HL$ FILS HL$ HLS HL$ SCH $CH SCH HL$ HLS HLS HLS HL$ HL$ HL~ H£S i" STATE OF ALASKA ;~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate __ Other ~ Compl el:e 2. Name of Operator ARCO Alaska, Inc. 3. Acli~:I~s.s Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 400' FSL, 6' FEL~ Sec.18~ T10N~ R15E, UN At top of productive interval 2429' FNL~ 296' FWL, Sec.21~ T10N, R15E, UN At effective depth 2522' FNL~ 412' FWL~ Sec.21~ T10N~ R15E, UN At total depth 2536' FNL~ 430' FWL~ Sec.21~ T10N, R15E~ UN 5. Type of Well: Development ,," Exploratory __ Stratigraphic ~ Service ~ 6. Datum elevation (DF or KB) RKB 74 ' 7. Unit or Property name Prudhoe Bay Un'it: 12. Present well condition sUmmary Total depth: measured true vertical Effective depth: measured true vertical 11650 'MD 9244 'TVD 11603 'ND 9204'TVB feet feet feet feet Plugs (measured) None Junk (measured) None feet 8. Well number 12-30 9. Permit number/approval number RR-1 ~/q-nLq 10. APl number 50"029-21891 11. Field/Pool i Prudhoe Ba~/ 0il Pool Casing Length Structural Conductor 80 ' Surface 3422 ' Intermediate 11160' Production 783 ' Liner Perforation depth: measured true vertical None None Size 20" 13-3/8" 9-5/8" 7" Tubing (size. grade, and measured depth) 5-1/2"~ L-80~ t;bg w/t:a~'l ~ 11276' Cemented Measured depth True vertical depth 2150# Po1 eset: 110 'ND 2000 sx CS III & 3455 'MD 600 sx Class (~ - Top job w/200 sx CS II 500 sx Class O 11193'ND 350 sx Class G 10867'-11650'MD Packers and SSSV (type and measured dePth) Baker 'SB-3A' pkr ~ 10790'~ Brown '2B' pkr ~ 11242' Camco 'Ba'l-0' SSSV ~ 2189' 13. S~Aulation or cement squeeze summary 110'TVD 3194'TVD 8850 ' TVD 8573 ' -92M+ 'TVD InterVals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run '" Gyro Daily Report of Well Operations ~ w ,, ' Oil ~ ......... ':' Gas ~ Suspended ~ Service 17. I hereby certify that the fore. going is true and correc{'tE~'e'best of my knowledge. _,,"'7'"~. ~ Reg~ onal Dr~ ( · Title ' '11 ~ng Engr. Signed Form 10-404 Rev 06/15/88 I/ 'x'Compl et;J on We11' H~ s'cory (DAM) SW04/028 SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prec:are and submit the "lnitiel Report" on the first Wednesday after a well ;s spudded or workover o;eraticns are started. Daily work prior to spudding should be summarized on the Iorm giving inclusive dates only. District County. parish or ',orougn ARCO ALASKA INC. NORTH SLOPE Field ILease or Unit PRUDHOE BAY I ADL: 28331 Auth. or W.O. no. ITitle AS2491 I COMPLETE API: 50-029-21891 Operator ARCO DS 12-30 I ARCO W I. I 21.0000w.0. I Prior status i~ · 1600 HRS Well no. Spudded or W.O. begun JDate ACCEPT I 03/16/89 Date and depth as of 8:00 a.m. 03/17/89 ( 23 TD:11650 PB:11600 SUPV:RWO 03/18/89 ( 24 TD:11650 PB:11600 SUPV=RWO Complete record for each day repoAed AUDI 4 RUN 8.5" GR/JB 7"~11650' MW: 9.0 NaC1 MOVE RIG FROM 12-33 TO 12-30. ND DRY HOLE TREE AND NO BOP'S. PULL BPV AND SET TST PLUG. TST HOP'S, CHORE MANIFOLD TO 5000 PSI, ANNULAR TO 3000 PSI. RU ATLAS WIRELINE. MADE THREE RUNS W/8.5" GR/JB TO TOP OF 7" LINER @ 10863'. RECOVERED RUBHER AND CEMENT. RIH W/8.5" GR/JB TO TOP OF 7" LINER. RIG ACCEPTED ~ 1600 HRS, 03/16/89. DAILY:S106,554 CUM:$1,941,309 ETD=$1,941,309 EFC:$2,476,000 RIH W/ 5-1/2" COMP ASSY 7"911650' MW= 9.0 NaCl RIH W/ 8.5" GR/JB TO TOL AT 10863'. POOH. RIH W/ 6.0" GR/JB TO 11524'. POOH. MU BAKER 7" 2-B WL PER AND ASSY ON WL. RIH. PER DID NOT SET. POOH. CHNG OUT ~IRING HEAD AND CHARGE. RIH W/ BAKER PKR AND COMP ASSY TO 11242', TAIL @ 11276. SET PER. POOH. RD ATLAS WIRELINE. MU BAKER 9-5/8" X 5-1/2" SB-3A PER, W/ SEAL EXT, MO EXT, 4-1/2" 12.6# PIC JT TBG, OTIS 4-1/2" "X# NIPPLE, 4-1/2" 12.6J L-80 HTC AB-MOD IPC PUP JT, WL RE-ENTRY GUIDE. RIH W/ COMPLETION. PER ~ 10790'. CIRC OUT DIESEL CAP AT 520'. CeNT RIH W/ COMP. CAMCO 'BAL-O' SSSV ~ 2189'. DAILY:S143,554 CUM=$2,084,863 ETD=S2,084,863 EFC:$2,476,000 Title Ori#ln~ Supt AR3B-459-1-D ~Number afl no. prepared for each well. I las they are dally well history forms consecutively Page I ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Pren;)re ;)nd submit the "Final Report" on the hrsl Wednosday after allowable has been assigned or wu. II is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are sus~enced ;or an ~ndehm!e or a~prec~able length ol hme. On worl~overs when a('. ofhcial '.est ~s not requ~rec u~on completion, re0ort completion and representative test ~;);a m b~ocks prowded The "Final Report" form may De used for re~ort,ng tho entire oDerabort d s~ace ~s ava.able. Acco-riling :Dst cetllter coGe District ARCO ALASKA INC. I County or Parish NORTH SLOPE I Lease or Unll PRUDHOE BAY I ADL: 28331 DS 12-30 I Title I COMPLETE Field State JWell no. Auth. or W.O. no. AS2491 API: 50-029-21891 OperatorA~CO IA'R'C°' w'1'21 , 0000 Iaband°nment'c°st[r°tal number of wells (active or inactive} on thiS]center priOrof thist° pluggingwe,, and Spudded or w.o. begun ]Date IHour Prior status if a W.O. ACCEPT I 03/16/89 J 1600 HRS Date and depth Complete record for each day reported as of 8:00 a.m. AUDI 4 03/19/89 ( 2. TD:11650 PB:11600 SUPV:RWO Old TD New TD Released rig Date FINAL REPORT RIG RELEASED 7n@11650' MW: 9.0 NaCl RIH W/ COMPLETION STRING. MU MCEVOY GEN IV 5-1/2'* TBG HGR. CONNECT CONTROL LINES. MU LANDING JT. TEST CONTROL LINES TO 5000 PSI. LND TBG HGR. RILDS. REV CIRC DISP W/ 8.5 PPG SEWATER. PUMP 150 BBL DIESEL CA~. DROP BALL. PRESS UP ON TBG TO 3000 PSI TO SET PKR. TEST ANN AND PKR TO 3000 PSI. BLEED PRESS. PRESS TBG TO 3500 PSI. RE-TEST ANN AND PKR TO 3000 PSi. OK. LD LANDING JT. SET BPV. ND BOPE. NU TREE. SET TEST PLUG. TEST TREE AND CONTROL LINES TO 5000 PSI. RIG RELEASED AT 03:00 HRS, 03/19/89. DAILY:S71,994 CUM:$2,156,857 ETD:S2,156,857 EFC:$2,476,000 JPB Depth Kind of ~lg . Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Off c a reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % (3OR (3ravity Allowable Effective date corrected The above la correct ~ ~ ~/~./,~b J~~~. D~IIi~ Supt. Drilling, Pages 86 and 87. ~ AR3B-459-3-C Number all dally well history forms consecutively as they are prepared for each well. iPage no, Dl¥1alon of AtlantlcRIchlleldComplm) M~R-!?- ~ ~D 07: ~? 5/~ ID:W W 1 TEL NO: 990726~4600 ,.- $IAT£ OF ALASKA ALASKA OIL & GAS CONSERVATION C01iHI$$ION B,O.P,E. Inspection £eport ~743 PO1 Location: Sec_._i_~ _ T~IO~ R_L~M.._~__ Drilli,~.C°n-tract°r..~ ~ ~ '~ .... I',i; _. Location, General_~..~.~. Well Sig~ ...... -- General ~ousekeeptng~Rig~_ Visual / Audio ---. Trip Tank ........... Flow Monitor . . . Oas Detectors ~ ,, · oPz Azmu!lar Preventer Pipe Rams,. Choke Line Valves .... Ii, C, R, Valve Jill Line Valve!_,, Check Valve_._. , . ........... 'Well ........... Rep :es en tat ive_._(b_[ s_~. _~___ Permit # ...... ~.~._- I q~___ __ ~ ~ Representative . ACCU~ATOR SYST~ ........... Full Charge Pressure Al:er Closurel~A-O _ .. Pump incr. elos. p~es. 200 pslg Full Charge Pressure At:ained: Controls: Master Remote / Blinds switch cover Upper telly~es~ Pressur% Lower KeZly ...... _ .... Test Pressure BaXl ~ype ~est Ptessur~ Inside . psig___ ...... _ .......... psig ............... ..... psig ..... : .......... Inspecter ...... . t Il I ......... _ Distribution orig."'- AO&GCC c¢ - Operator ce - Supervisor days and Inspector/ Test Results: Failures. ~{,/a~ .............. Repair or Replacement of failed equipment to be made within Commission of/ice notified, R~C~I~ ~D ~eMarks~ ... · ..~..::_. Test Time ..__i~r.~ Test Ptessure_.~T,~ · Choke Hanifold_~~est P:essure..~~ _ _~ ~o, Valves "%/ ~o, flange~ .... /2~ ..... Adjustable Chokes .... ./__~. ............ ARCO AI..A£KA, INC, {" F',O, BOX JeeS6G ANCHORAGE, ALASKA 995JG DATE' t -3i -89 REFERENCE' ARCO CASED HOLE FINAL£' 4-7 t-23-89 COLLAR/F'ERF ti-3 t-23-89 PDK-tG~ J2-30 i-23-89 CBT t2-38 t-23-89 CET RUN 2, RIJN RUN R~JN i, 2'&5' PLEASE £IGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA, RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 TRAN£ .~89e4~ AF'F'ROVED _ I~.__. FEB - 6 8, Gas Cor,.~. C~mmissio~ .Anchor~ga DISTRIBUTION ATLA~ ATLAS $CH $CH T'"' CENTRAL FILE£ T'"- CHEVRON D & M ~ EXTENSION EXPLORATION 'I' .~ EXXON MARATHON ~~ MOBIL PHILLIPS PB WELL F-ILEI' R & D SAF'C STATE OF ALASKA TEXACO ARCO Alaska, Inc.j [." Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 30, 1989 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat- DS 12 Pad {Wells 24, 30-33) Dear Mr. Chatteron: Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Si~n~erely, . . D. Martin Engineering Aide DM:czm Enclosure If you have GRU13/010 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany ' --2 /, G~' ~ ,~ · II i ~' = VICINITY M~P I% 4000' ~0 , ~ ~ · ~ ' , NOTES: i [ ~e ~ +1 I. COORDINATES ARE A~KA STATE , z~ ~ PLANE ZONE 4 ' aa +~ ~ ELEVATIONS ARE ARCO DATUM '~ i ~ , ~~ · WELLS ARE WITHIN SEC. 17 .~ z~. i T; I0 N.~ R. 15~. ~M. ~~__ ~[ la ~ /~ + EXISTING WELL ~ · WELL AS-BUILT THIS SURVEY I ~ REFERENCE FIELD BOOK= ~ LPB 88'30 Pgs. 46-49 Well A~.R Y A.~.~ X LA~ LONG. SECTION LINE DATA 24 ~, 330, 422.44 696, .93~. O/ POe 12'50.81~" i~o 24' 41. 580" 109' F~L 688' ~gL EEC 18 ~0 ~, 930, X~0. 5~ 69~, 605.52 ~0° 12'~3. 674" /40~ 24' 2/. 85E" 400' FEL ~ FEL EEC 'r 31 5,330,541. X9 636,~2l. OI 70° 12'~1.994" 1~°24' 41.~46" 229'FSL 696"FEL ~gC lO ~2 3,9~1,~63.66 69~,~/~.~4 ~0~ /2'~9.8~" /48~24' 18.080" /030' FEL /25'~L EEC 33 ~,9~0,482.~ 6~6,~27.~ ~0~ 12' ~/. 40~" /~°24' 41.~/5" /69' ;EL 6~2'~E~ ~EC . ' ~~~%~ ~ I berry certify that I am properly registered ~ ~ . · .... '. ~ ~ ~ end license~ to practice land surveying in the Well .Cellar Box Elev. ~ ~~ "' .' ' ': '~?LState of Alaska and th~ this plat represents , " ~ ~ .' '~ ~ .~ ' , ~4. 41. 0 4~C00otu~ ~ , ~..~ .. :., ~ .s '. , ~s-Built survey made by me or under my 30 40.9' , / ~' ~ "'-- "'" ' /.. ~. .... ~' ~ ~ ' ~ ~ ' '~pervision Qnd that all dimensions and other ,, .. "9 t ~:' .".. ...",'2. , ,. .. ~8~0~1~, In~. ~ ~' AS- ~UILT DRILL SITE I O. ~... AS-BUILT ;k ¢.~. ~ ~ I~'l~O'{~'! ~ DA~ ~ISI~S ~ ~',, NSDP- 0000-, CEA- 175 I- 005 ARCO ALASKA, INC P.O. BOX t08360 ANCHORAGE, AL. ASKA DATE' t -t 9--89 REFE~F~E£NCE: ARCO DIRECTIONAL DATA 'i 2--30 t 2-3'1-'88 MWI) DIRECT]:ONAL. SLJRVEY ,JOB.~:6'/4 t4-3'? 9-25-88 MWD DIRECTIONAL S'URVI.:':Y ,JOB~6'54 t 4-38 t 0-2i -88 MWD DIRECTIONAL. ,.?UI:~'.VEY ,JOB~:659 !4-39 t2-8-88 HWD DIRECTIONAL S~JRVIEY ...i0B~669 t4-'4(:.', t t--'2t--88 MWD I)IF;:E]C'I"]iONAI... SLJI:;.'.VEY ,JOB~:664 F'I_EA,~/li" SIGN AND RET[JRN "f'HE AT'FACI.~ED COF'Y ECEI I)A'FA. RECE~IVED BY ................................................................................. HAVE A NICE DAY~ N~ ~1 & Gu Con~. Common S ~ I.. L.. Y H 0 F' F' E C K E R Anchorage ~'TO .... ~ 529 fRANS AF'F'IROVED ..)~.. ............ I) :[ S T R I B U T I 0 N 'Y'EL. ECO I"EI_ECO 'l' Iii: L.. i::' C (] '¥ E I_ E C 0 'l" E i_ E:' C 0 [::E:N'T'I-~AL.. F' ]: LIES CI-II.E' VR []N D & M '~' E:.X T E:.NS I ON EXF:'I...OI:;:ATI ON .,.'"' E.":. X X []N HARATI-.ION HOBII_ F:' I"11 L !... :[ F'S' ,H. p ..,) .,. B W E L.. L.. F:' I L. E S' ( ,:. C 0 F' I E S' ) · ~ ..?AF:'C ~. S'T'AT'F (]1:: AL. AS'KA 1' E X A C 0 STATE OF ALASKA ' AI_(,',,.,KA OIL AND GAS CONSERVATION CoMML,.,iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon w Suspend __ Operation shutdown ~ Re-enter suspended well m Alter casing __ Repair well w Plugging m Time extension __ Stimulate ~ Change approved program ~ Pull tubing ~ Variance ~ Perforate __ Other 2. Name of Operator ARCO Alaska, inco 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 5. Type of Well: Development v. Exploratory ~ Stratigraphic m Service ~ 4. Location of well at surface 399' FSL, 6' FEL, Sec.18, T10N, R15E, UM At top of productive interval 2540' FNL, 250' FWL, Sec.21, T10N, R15E, UN (approx) At effective depth 2498' FNL, 424' FWL, Sec.21, T10N, R15E, UN (approx) At total depth 2514' FNL, 444' FWL, Sec.21, TION, R15E, UM (approx) 6. Datum elevation (DF or KB) RKB 7~f' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 1 ~-?n 9. Permit number 10. APl number 50-- 029-21891 11. Field/Pool Prudhoe Bay 0il Pool feet 12. Present well condition summary Total depth: measured true vertical 11650 'MD feet 9239'TVD feet Plugs (measured) None 11603'ND Effective depth: measured feet true vertical 9199 ' TVD feet Junk (measured) No ne Casing Length Size Structural 80 ' 20" Conductor 3422 ' 13-3/8" Surface Intermediate 111'60' 9-5/8" Production 783 ' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 'None Packers and SSSV (type and measured depth) Nnn~, ' 13. Attachments Description summary of proposal Wel 1 History 14. Estimated date for commencing operation February, 1989 16. If proposal was verbally approved Name of approver Cemented Measured depth True vertical depth 2150# Pol eset 110'MD 2000 sx CS III & 3455 'MD 600 sx Class G - Top job w/200 sx CS II 500 sx Class G 11193'MD 350 sx Class G 10867'-11650'NB llO'TVD 3196' TVD 8853'TVD 8577'-9239'TVD JAN 2 ..... Alas. ,Oil & Gas 'Cons. C0m$iss[0_l 1., 'l ::, '.'~':,~ """ "' Detailed opermions program __ BOP sketch __ 15. Status of well classification as:. Oil ~,' Gas ~ SuSpended Date approved". Service' 17. I hereby certify that~ng is true and correct to the best of my knowledge. Signed "T'~, ~.. ~ Title Reaional Drilling Fngineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity .__ BOP Test __ Location clearance ~ ~,O~ Mechanical Integrity Test __ Subsequent form required 10- ,po~Oved Copy ORIGINAL SIGNED BY Returned LONNIE C, SMITH /"' ~ -~::)~ Approved by order of the Commissioner Commissioner Date ~/2.~ I ^pprov , ,o. Form 10-403 Rev 06/15188 047/$A4 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History- Initial Report- Daily Ioltmotlonl: Prepare end submit the "lnillll Report" on the flmt Wednesday after · well Is spudded or workover operetlone ore stmled. Oally work prior to spudding should b~ summodzed on the form giving inclueIve dotes only. A~CO A~ASKA INC. I NORTH SLOPE t~s~e or unit I ~L: 28331 DS 12-30 PRUDHOE BAY Aut~. o~ W.O. au. ~2491 ~ DRILL Operator A~CO Spudded or W.O. begun IWelt no. IARCO W.I. 21.0000 Prior statue if a W.O. IDate LHour SPUD 12/17/88 1930 HRS Date and depth as of 8:00 a.m. 12/18/88 ( TI): 427' ( SUPV: MDD 12/19/88 ( rD: 887' ( SUPV: MDD 12/20/88 ( rD: 1529' ( SUPV: MDD 12/21/88 ( ?D: 2980' ( SUPV: MDD 12/22/88 ( TD: 3475'( SUPV:JCP 12/23/88 ( TD: 3475'( SUPV:JCP Complete record for each day re~fled N/d~ORS 28E .) 127) :) 60) ~) ;42) 51) 12/24/88 ( 7, TD: 5180'(17)5) SUPV=JCP ) 95)... The above ~ ~orrect ~., , Slgn~_~ For form ~repor-tlon and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D WORK ON ROTARY TABLE 20"8 110' MW: 8.9 VIS:280 FIN RU FLOOR. BUILD SPUD MUD. PU BHA. CHECK CIRC. SYSTEM. SPUD 8 1930 I-IRS, 12/17/88. DRLG FR/ 105-125, FLOW LINE PLUGGED. DRLG TO 427. NORKON ROTARY TABLE. POOH. WORK ON ROTARY TABLE DAILY:S56,331 CUM:$56,331 ETD:S120,000 EFC:$2,412,331 DRILLING 20"8 110' MW: 8.9 VIS:280 REPAIR ROTARY TABLE. THAW OUT JET LINES. WORK ON DHAWWORKS. RIH. DRLG TO 887. DAILY:S41,304 CUM:$97,635 ETD:~180,000 EFC~$2,393,635 DRILLING 20"8 110' MW: 9.0 VZ8=213 DRLG TO 948. SURVEY. POH, CHANGE BHA. RIH. KICKOFF SLIDE TO 1272'. BIT ACTING LIKE ITS LOCKED UP. POOH TO CHECK BIT. C/O BIT. DRLG TO 1529. DAILY;S51,492 CUM=$149,127 ETD:S200,000 EFC:$2,425,127 DRILLING 20"8 110' MW: 9.5 VlS=ll0 DRLG TO 1785', UNABL~ TO BUILD ANGLE FAST ENOUGH. POOH. CHANGE BIT AND BENT SUB. RIH. DRILL TO 2980'. DAILY:S56,805 CUM:$205,932 ETD:S205,932 EFC:$2,476,000 RUNNING 13-3/8 CASING 13-3/8"8 3455' MW: DRLG TO. 3308, SURVEY. POOH CHANGE BHA. DRXLL BO..S~i' POOH TO RUN CASING. RU CASING TOOLS. CABZN~. DA/LY:$46,729 CUM:$252,661 ETD:S400,000 9.5 VIS:106 TO 3475, CIRC. RDlqNING 13 3/8" EFC:$2,328,661 TESTING BOPE 13-3/8"8 3455' MW: 9.6 VIS: 87 FIN RONNZNG 86 JTS OF 72J L-80 13-3/8" BTC. CIRC CA~ OF CASING. TEST LINES. PUMP 100 BBL~ OF WATER, MIX AND PUMP 2000 SXS OF CSlll AT 12.2 PPG. TAIL W/ 600 SXS CLASS G AT 15.8 PPG. BUMP PLUG N/ 2500 PSI. FLOATS HELD, NO CMT. CIP AT 1130 12/22/88. RU AND RUN TOP JOB W/ 200 SX CSll AT 14.9. ND DIVERTER SET SLIPS, CUT CSG, WELD ON MCEVOY GEN 4 HEAD. TEST SAME TO 1500 PSI. NU BOPE TEST SAME. DAILY=S328,805 CUM=$581,466 ETD:S800,000 EFC=$2,257,466 DRILLING 13-3/8"8 3455' MW: 9.5 VIS: 32 FIN TESTING BOPE. INSTALL NEARRZNG. MU BHA. RIH. TAG FC AT 3375. TEST CSG TO 2500 PSI-OK. DRILL FC AND CEMENT TO 3445, KETEST CSG TO 2500 PSI-OK. DRILL FS AND 10' FORMATION TO 3485'. RUN LOT EMW-'15.0 PPG. DRLG W/ DD FR/ 3485-5180. DAILY:S61,404. CUM:$642,870 ETD:S850,000 EFC:$2,268,870 Page no. ' ' " ·~. ~ ,'~.~'~. ~T~%t~' ~ee they em pm;ama mr e~c, well. i. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring. Or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnllrlm" sheets until final completion. Report official or representative test on "Flnel" form. 1} Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which Git string is set. Submit weekly for workovere and following setting of oil string until completion. District JCounty or Parish I IStet~l~K ~;~,CO ~T.,AS[~. INC. I NORTH SLOPE I Field ~Lease or Unit IWell no. PRUDHOE BAY I DS 12-30 I I Date and depth as of 8:00 a.m. Complete record for each day while drilling or workover in progress NABORS 28E 12/25/88 ( TD: 6820'( SUPV:JCP 12/26/88 ( TD: 7660'( SUPV:JCP 12/27/88 ( TD: 8470'( SUPV:JCP 12/28/88 ( TD: 9100'( SUPV:JCP 12/29/88 ( TD: 9640'( SUPV:EEV 12/30/88 ( TD:10288'( SUPV:EEV 12/31/88 ( TD:10945'( SUPV:EEV 01/01/89 ( TD:11195'( SUPV:EEV 8) 1640) ~) 840) ~10) t) 630) ~) 540) 3) 648) 4) 657) 5) 250) DRILLING 13-3/8"@ 3455' MW: 9.4 VIS: 30 DYNA-DRILLED TO 6373'. SURVEYED AND PUMPED PILL. DYNA-DRILLED TO 6820'. DAILY:S43,716 CUM:$686,586 ETD:S900,000 EFC:$2,262,586 DRILLING 13-3/8"@ 3455' MW: 9.5 VIS: 31 DYNA-DRILLED TO 7000'. SURVEY AND PUMP PILL. POH. MU NEW BIT AND TIH. CUT DRILL LINE. FINISHED TIH. CONTINUED DYNA-DRILLING TO 7660'. DAILY:S51,481 CUM:$738,067 ETD:S900,000 EFC:$2,314,067 DRILLING 13-3/8"@ 3455' MW: 9.6 VIS: 34 DYNA-DRILLED TO 7754'. SURVEYED AND PUMPED PILL. POOH. CHANGED OUT STAB. SLEEVE AND TELECO TOOL. MU NEW BIT AND TIH. DYNA-DRILLED TO 8470'. DAILY:S50,764 CUM:$788,831 ETD:S1,000,000 EFC:$2,264,831 DRILLING 13-3/8"@ 3455' MW: 9.8 VIS: 35 DYNA DRILL F/8470 TO 8501. SURVEY, POOH FOR NEW BIT. MU BHA AND TRIP IN HOLE. DYNA DRILL F/8501-9100. DAILY:S55,302 CUM:$844,133 ETD:S1,000,000 EFC:$2,320,133 DRILLING 13-3/8"@ 3455' MW= 9.8 VIS: 37 DYNA DRILL TO 9454'. POOH FOR BIT & BHA. RIH, SLIp & CUT, FIN RIH. DRILL TO 9640'. DAILY:S61,874 CUM:$906,007 ETD:S906,007 EFC:$2,476,000 CIRC AND RAISING MW 13-3/8"@ 3455' MW:10.0 VIS: 42 DRILL TO 10288'. ATTEMPT TO POOH, HOLE TIGHT @ 9261' WASH TO BOTTOM. RAISE MUD WT TO 10.0 PPG. ATTEMPT TO POOH, RAISE MU WT TO 10.2 PPG. DAILY:S50,505 CUM:$956,512 ETD:S956,512 EFC:$2,476,000 DRILLING 13-3/8"@ 3455' MW:10.2 VIS: 38 FIN RAISING MW TO 10.2 PPG. POOH, HOLE TIGHT @ 9261', 9000' & 8710'. REPLACE WEAR BUSHING RZH. WASH & REAM F/ 10194-10288'. DRILL TO 10945'. DAILY:S60,099 CUM:$1,016,61! ETD:S1,016,611 EFC:$2,476,000 POOH ON SHORT TRIP 13-3/8"@ 3455' MW:10.2 ViS: 41 DRILL TO 11195'. POOH FOR SHORT TRIP. DAILY:S51,300 CUM:$1,067,911 ETD:S1,067,911 EFC:$2,476,000 The eb~ve is correct ~,.. ¥ · i ~na r '~t~'~'~' For ;o,., preparation and dlstrihu'tion see Procedures Manual Secflon ?0, Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms as they are prepared for each well. consecutively Page no. ARCO Oil and Gas Company Daily Well History--Interim Inetruelionl: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion, Report official or representative test on "Fleal" form, 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting o! oil string until completion, District A~CO A.T.,ASRA INC. IC°unty°r~c~H SLOPE IStateAK Field PRUDHO;- BAY ILea. or U~; 12-30 Well no. Date end depth as of 8:00 a.m. 01/02/89 ( TD:11215'( SUPV:EEV 01/03/89 ( TD:11215' ( SUPV:EEV 01/04/89 ( TD:11650' ( SUPV:EEV 01/05/89 ( TD:11650'( SUPV:JCP 01/06/89 ( TD=11650 SUPV:JCP 01/07/89 ( TD:11650 SUPV:JCP The above ia correct Slgnat~ For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Complete record f~y v~l~ drilling ..... k ....in progress ,6) 20) .7) o) .8) 435) 9) 0) :o) :1) RNG 9-5/8" CSG 9-5/8"@11193' MW:10.2 VIS: 38 POOH. RIH W/ RERUN BIT, SLIP & CUT, FIN POOH. WASH & REAM F/ 11165'-11195'. DRILL TO 11215'. CIRC & COND, POOH, LD BHA. CHANGE RAMS TO 9-5/8" & TEST. RU CSG, RNG 9-5/8". DAILY:S47,634 CUM:$1,115,545 ETD:Si, ii5,545 EFC:$2,476,000 PO BHA 9-5/8"@11193' MW: 8.6 ViS: 52 FIN RNG 254 JTS, 9-5/8', 47#, L-80, BTC/BTC-MOD. WASHED CSG DOWN TO 11193'. CIRC & COND. PUMP 50 BBLS CLAYTROL SPACER & 500 SX CLASS G, GAS BLOCK CMT @ 15.8 PPG. BUMP PLUG. ND BOPS, NU TBG HEAD & TEST TO 5000 PSI. NU BOPS. LD CSG TOOLS. PU 8-1/2" BHA. DAILY:S324,011 CUM:$1,439,556 ETD:S1,439,556 EFC:$2,476,000 POOH TO LOG 9-5/8"@11193' MW: 8.9 VIS: 33 FIN TSTG BOPS. INSTALL WEAR BUSHING, HAD TO MODIFY RNG TOOL. RIH TO FLOAT COLLAR. CBU, PRESSURE TEST CSG TO 3000 PSI. DRILL CMT TO FLOAT SHOE. PRESS TEST CSG TO 3000 PSI FOR 30 MIN. DRILL SHOE, CMT & 10' FORMATION. PERFORM LOT TO 12.3 PPG EMW. DRILL F/ 11225'-11650'. CBU. SHORT TRIP. CBU. POOH FOR LOGS. DAILY:S62,746 CUM:$1,502,302 ETD:S1,502,302 EFC:$2,476,000 RIH W/ LINER 7"@11650' MW: 9.0 VIS: 36 POOH FOR LOGS. RU WESTERN ATLAS, RUN DIL/BHCS/GR/SP AND CNL/Z-DEN/ GR/CAL. RD LOGGERS. RiH, SLIP & CUT, FIN RIH. CBU. POOH. RU CSG TOOLS, RUN 17 JTS 7"/ 29~/ L-80/ BTC & BOT HGR'. CIRC CAPACITY OF LINER. RIH W/ LINER ON DP. DAILY:S129,783 CUM:$1,632,08~ ETD:S1,632,085 EFC:$2,476,000 L/D 8-1/2" BHA 7"@11650' MW: 9.0 WBM FIN RIH W/ LINER. C&C. PUMP 50 BBLS MCS-A SPACER. BATCH MIXED & PUMPED 350 SX CLASS "G" + 1% EA-10, 0.2% CD-30, 0.4% FL-32, 0.38% A-2, 0.15% R-l, I GHS FP-6L @ 15.8 PPG. BUMP PLUG. SET HANGER, SHOE AT 11650'. POOH W/ RNG TOOL. LD 27 JTS HWDP. PU 8-1/2" BHA & RIH, TAGGED CMT @ 10,467'. WASH & DRILL CMT TO TOL @ 10867'. C&C. POOH & LD BHA. DAILY=S112,050 CUM:$1,744,135 ETD:S1,744,135 EFC:$2,476,000 L/D DRILL PIPE 7"@11650' MW: 9.0 NaCl FIN L/D 8-1/2" BHA. PU 6" BHA & RIH. SLIP & CUT. FIN RIH, TAG CMT @ TOL. DRILL RATTY CMT F/ 10867'-11514'. TEST CSG TO 3000 PSI. DRILL TO FLOAT COLLAR @ 11603'. TEST CSG TO 3000 PSI FOR 30 MIN. CBU a DISPLACE HOLE TO 9.0 PPG BRINE. RETEST CSG TO 3000 PSI. POOH LAYING DO;~N DRILL PIPE. DAILY:S47,720 CUM:$1,791,855 ETD:S1,791,855 EFC:$2,476,000 AR3B-459.,2-B INumber all daily well history forms consecutively IPage no. aa fhey are prepared for each well. 1 , e ( ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abancloned, or Sold. "Final Reporl" should be sul~mitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official teat is not required upon completion, report completion and representative test dale in blocks provided. The "Final Report" form may be used for reporting tho entire operation if space ~s available, Accounting cost center code District ~CO ~LASiU~. INC. Ic°unly °r~(~'~H SLOPE I Stat~ F,e,d P'UD'OE EA¥ lc or~: 28331 .... DS 12_30 Iwe,,~o. Auth. or W.O. ~2491 ]T,tle DRILL I Ai, z: 50-029-21891 Operator ARCO A.R.Co. ~t... 0000 rTotal number of wells (active or inactive) on this, [cost center prior to plugging and I labandonment of this well Spudded or W~.un Date 12/17/88 IHour 1930 H~S 1Prior status if. W.O. Date and depth Complete rec~lL~:~ch2~,.reported as of 8:00 a.m. 2) 01/08/89 ( 2 TD:11650 PB:11650 SUPV:JCP RIG RELEASED 7"@11650' MW: 9.0 NaC1 FiN LD DP. FREEZE PROTECT TOP 400'. PULL ROTARY TO REPLACE BEARINGS. ND BOP INSTALL DUi~4Y HGR, NU DRY HOLE TREE & TEST TO 5000 PS[. FREEZE PROTECT ANNULUS W/ 120 BBLS D~ESEL. RELEASE RIG @ 2000 HRS 1/7/89. DAILY:S42,900 CUM:$1,834,755 ETD:S1,834,755 EFC:$2,476,000 Old TD Released rig Classifications (o11, gas, etc.) ' I New TO PB Depth I Date Kind of rig Type completion (single, dual, etc.) Producing method Offictal reservoir name(a) Potential test data Well no. Date Reservoir Producing Interval OII or gasTest time Production 011 on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and dl.tribution, -/~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber 811 daily wall history forms consecutively I Page no. as they are prepared for each well. I DIvMIm of All~fJcRJchfleldCompll~ ARCO ALASKA, INC. P.O. BOX tGG36G ANCHORAGE, ALASKA DATE' t-t2-8~ REFERENCE' ARCO OF'EN HOLE FINAI..$ t 2"-3~) i'-4-8~ i2-Je t -4.-8~ i 2-'3{) i --'4-89 i 2'-3(} t-4-8S~ BHCA--GAMMA DIF'L-GAMMA CZD-GAMMA (RAW) CZD/CNL-GAMMA (PORO) RLJN ~, 2"&5" RUN RUN RJJN PL. EASF SIGN AND RETURN THE AI'TACHED COPY AS REiCEIF'T OF 'DATA~ ATL..A.'~; ATLA.g' ATLAS AI'LA~' RECEIVED BY ......................... ": HAVE A NICE' I)AY' ~V,'E~~ · all XAL. L.Y HOFFECKER ATO .... i ,.Gas *FRAN~ ~8~ APF:'ROVED .i~ ......... D l ,g I F,: I B U T I 0 N' '"' PHILLIF'S · .. CENTRAL FILES ~.' ,~'"'CHEVRON PB WELl_ FILES "- D&M '" · ~. ~ R & D · .-"' EXI'EN$ l ON EXF:'LC)RAT l ON ~ gAF'C; " EXXON ~ STATE OF ALA~S'KA ~ MARATHON ,,' TE:XACO ., MOBIL ARC[) ALA~'KA, INC. /' P.O, BOX t0036~ ANCFIOF~AGE, AL.A~'K A 995t DATE' t-t 3-89 I",[:.F'E.R£:.NC, E:.: ARCO HAGNFI'IC TAF'E:.'~? W/[..I~?'¥INCf -4-89 OH- D I FI.../BHC/CZD.-.CN/CZD ,J 0 B.,,-,.,,.~65 PLEAS'E: SIGN AN]) RETURN THE A'FTACHE:D C;OF'Y A~' REJCEIF"f' OF DATA, ~a~ t)il & Gas Con~ ~mml~Io~ ALLY HOFF'IECK ER T 0-' t ."~; 2 '1'RAN,? ~-8 9.G..~ APF'ROYED ...... D I ~' T R I B U T I 0 N ATI..A,.? CEN'f'RAI_ FII. ES (Cl.'l) CHEVRON D & M 'I'AMMA~? BROWN (C)l"l) IFXXON HARAI'HON MOBIL. .L · ,,- F'HIL. L. IF'3 F'B WELL. I:'IL.E:,S' R & D .i i '. · "'... ,.~AF C '"' .'~TA'f'F..'. OF AL.A.~KA ~ , TEXACO I D: NABORS ~SE TEL NO: STATE OF ALASF~ OIL & GAS CONSERVATION CO}~!I$$ION B.O.P.E. Inspection Report ~127 POi Insp_ect.o. r --- - ..... _. ~- , ,,,1 , _ Brillfn Contractor CeneraI . ~/ Well Si~n ~ Location, Oeneral aousekeepins~_Rt8 Reserve Pit · ~"~ ...... :."' .' L.':_ ,'_ ,. .... · -, .-- ._...-... .......... ............ X!su ; ....... _ udto Trip Tank Pit ~auge Flow Monitor ........ . ..... f ..... Gas Detectora Blind Rams~ Choke Line Valves~~ H.C.~.. Valve~~ ~i1 Line Valves_.__~~~ Test Results: ~atlures .... . ...... ,. Pump incr. clos. pres, 200 F~II$ Charge Pressure Attained: /' mtn,~,sec. .~ ........ ~-;-'--. ..... ~ ....., ................. ~elly and Floor Saf~7 Valves -.~ Lower ~eilf / ~e~t, ~res~ure_. ~..~ ...................... Ball Type / Test Pressur~._~O'~ .... ~umide BOP · / 'Tesu 'Pzessure_ {-, ..... , ..... Choke Manifold ~;est Pzessur~_~ ~ ~ . Ho. Valves .,J' .......................................... Adjustable Chokes ~esc ~e ~ .hfs . Repair or Replacement of failed equipmeuu to be made within Commission o~fice notified. Remarks: Distribution ora§. - AO&GCC,., ' cc - Supervisor days'and In, sp?ct0r/ MEMORANDUM StateOf Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith DATE: January 9, 1989 Commissioner mtENO: D.BDF.159 TELEPHONE NO: THRU: Michael T Minder ~/'~'~' SUBJECT.' Sr Petroleum Engineer Petroleum Inspector FROM: Diverter Test AAI PBU DS 12-30 Permit. ~88-142 Prudhoe Oil Pool Saturday, December 17, 1988: I traveled this date to DS 12-30 and WitneSsed th'e 'functiOn '~'est and inspected the diverter system on Rig 28E. The system functioned properly, and was installed in a manner acceptable to the AOGCC. In summary, I witnessed the function test and inspected the diverter on ARCO DS 12-30. 02-001A (Rev. 8/85) .... '"' '. ....... ' i' '. ....... 'i'..,.:~ '.' "A'"~;'~"" '" ".~ ' "~"~'~'"'"'?'~'"'"'" " ' .... ~..!w?:' , ........ ARCO Alaska, Ir~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 28 1988 Ms. Patti Wightman AK Dept. of Governmental Coordination Office of Management & Budget 675 Seventh Avenue, Station H Fairbanks, AK 99701 Colonel William W. Kakel .District Engineer U.S. Army Corps of Engineers P.O. Box 898 Anchorage, AK 99506-0898 Subject: Mr. Warren Matumeak Deputy Director, Permitting Section Planning Department North Slope Borough P.O. Box 69 Barrow, AK 99723 Drillsite 12 Auger Hole Disposal of Drilling Waste USCE Beaufort Sea 25, 071-OYD-N-790377 LO/NS 85-47 COMM" COMM ' COMM RES ENG SR ENG . SE ENG ENG AS SR GEOL~ GEOL GEOL ASST[~ STAT TECHI STAT TECH ]-- Dear Ms. Wightman, Mr. Matumeak, and Colonel Kakel:' ~ -~ I ~ -~ ARCO Alaska, Inc, on behalf of the Prudhoe Bay Unit owners, here-by applies for permits and permit modifications related to winter development drilling activities scheduled to be done at Drill Site 12 (DS-12) in the Prudhoe Bay Unit. ADEC solid waste disposal permits are being requested for the permanent disposal of drill cuttings and water-based drilling muds by a below grade freezeback technique. In addition, the proposed activities described in this letter and the attached Plan of Operation (Attachment A) require the following permit modifications: * U.S. Army Corps of Engineers, modifi~tion to Beaufort Sea 25 (071-OYD-N- 790377), ' * North Slope Borough Development Permit, modification of DS- 12 Development Permit, * Alaska Department of Natural Resources,Lease Operations modification to LO/NS 85,47, and * State of Alaska, Office of Management and Budget, Division of Governmental Coordination, Coastal Zone Consistency Determination. By copy of' this letter and attachments, we are also requesting that EPA deem this application as notification of application for a Class V permit under the UIC program. L ARCO Alaska, lnc, is a Subsidiary of AtlanlicRichfieldCompany RECEIVED NOV 3 198g ~laaka 011 & Gas Cons. Commission ~.,...,,. gnohorage Ms. Wightman,{ 11/29/88 Page 2 .. Matumeak, and Col. Kakel The purpose of the project is to provide a winter test of a new procedure for the permanent disposal by below grade freezeback of approximately 3,200 to 4,000 cubic yards of drill cuttings and water based drilling muds from 5 new development wells. The drill cuttings will be disposed of in up to 20 holes (disposal cells) augered into the permafrost soils underlying the DS-12 pad. The cells will be 8 feet in diameter and approximately 120 feet deep. Both the development wells and the proposed augered disposal cells are located in section 17 and 18, T10N, R15E, U.M. The wells are planned to be drilled this winter as soon as the permits are obtained. The desired spud date for the first well is December 1, 1988. However, alternative disposal methods will be utilized until these permits and modifications can be obtained. The proposed augered disposal cells will be drilled through the existing DS-12 gravel pad. The disposal cells will be located at least 200 feet from existing surface waters. In addition, the disposal cells will be located no closer than 60 feet to existing wells in order to avoid any future thawing of the disposed cuttings and muds. Recent studies of the thaw bulbs generated around oil production wells have shown that after 20 years of continued oil production the permafrost could be thawed up to a radial distance from the well of almost 30 feet near the surface (Attachment B). Locating the disposal cells no closer than 60 feet to producing wells gives a safety factor of 2 in terms of distance.. Five pilot holes for drillsite 12 well head conductors have been drilled to -30 feet. Frozen conditions were encountered at all locations. The Harding Lawson report for wells 12-24 and 12-30 will be forwarded as soon as it is available. Drillsite 15 thermal data for existing angered disposal holes Will also be submitted under separate cover. Only drill cuttings and the associated water based drilling muds from the DS-12 development drilling will be placed in the augered disposal cells. This includes the disposal of incidental formation oil mixed with the drill cuttings. The disposal cell. s not be used for the disposal of other materials and fluids including glycols, hydraulic ~uids and o~her oit~. ' .... Up to 20 disposal cells 8 feet in diameter and approximately 120 feet deep will be placed on 18 feet centers on the. DS-12 gravel pad. These cells will be augered using the same techniques as performed on Drill Site 15 (DS-15) in the summer of 1988 (Attachment C). A newly designed 8 feet diameter auger bit will be used instead of the previous 53 inches diameter bit with a hole enlargement adapter which drilled the DS-15 cells. The gravel and overburden recovered from the augering of the holes will be approximately 4,500 cubic yards. The gravel and overburden will be stockpiled in the northeast corner of the existing impoundment area as shown on the attached plans. About 500 cubic yards of the gravel/organic overburden will be used as cap material to bring each cell up to the original ground elevation after disposal of the drilling wastes. An. additional 250 cubic yards of gravel will then be used to fill each cell to the existing pad elevation. Approximately 1,750 cubic yards of gravel is proposed to fill a small impoundment area immediately to the south of the disposal cells. The purpose of this fill is for safety purposes during the movement of equipment and augering of the disposal cells and to allow access to fill the cells with cuttings and mud. RECEIVED NOV 5 ) 19P/! Alaska.Oil & Gas Cons, Commission ~ '".Anchorage Ms. Wightman,~. ,. Matumeak, and Col. Kakel 11/29/88 Page 3 Unused augered gravel will be used to meet general operation and maintenance gravel requirements for future summer construction seasons. All gravel and overburden materials put to beneficial use will be reported under Material Sales Contract, ADL, and a fee of $0.65 per cubic yard will be paid to the Alaska Department of Natural Resources in the annual Material Sales accounting payment. If any drill cuttings and muds are inadvertently spilled during the transfer of thc cuttings from the drilling rigs to the disposal site, they will be cleaned up and placed in the augered disposal cells. Since this is primarily a test .~0 determine thc feasibility of tra..nspo, rting d~i..'lling was.res from the rig to the augered disposal, cells under w.inter con.ditions_, various methods of consolidation, transportation and disposition of the drilling wastes may be tested for practicality and/or economic evaluation. All holes will be covered with plywood covers until they are filled with drilling wastes. All filled holes will be covered with overburden and closed out after they are' filled. Vertical thermistor strings will be installed along the sides of five of the augered cells to monitor the freezeback of the drilling wastes. The temperature measurements will begin at the +2 feet level below the original tundra grade and continue every 2 ft. down to 15 ft. below tundra grade. The thermistors will then be placed at every 20 ft. to the bottom of the cell. The thermistor strings will be monitored monthly in Suly, August, September ' and October 1989 to monitor the freezeback process. If freezeback of the drilling wastes has not occurred by October 1989, then monthly readings of the thermistors will be taken for an additional year. In the summer of 1989 the area will be inspected for subsidence' over the filled disposal cells. If subsidence has occurred, the closed cells will then be brought back to the original pad level. The location of thc holcs will bc survcyed and as - built surveys provided upon completion. A marker will also be placed over each closed disposal cell to indicate where drilling wastes were deposited. This request contains the following supporting attachments: A Plan of operations, B Typical Thaw Progression Around Producing Wells, C Location maps and site plans, D ADEC Coastal Zone Consistency Questionnaire, E ADNR Lease Operations form (modifications), F NSB Development Permit forms (modification), G USCE Section 404 permit form (modification), H ADEC Solid waste disposal permit application, and I Permafrost integrity with respect to a near-by lake. Ms. Wightman,~. 11/29/88 Page 4 .. Mammeak, and Col. Kakel If further information is needed or you have any questions about this application, please contact me at 263-4678. Sincerely, Barbara K. Byrne Permit Coordinator Attachments cc, w/attachments: P. Bateman, ADEC, Fairbanks $. Bridges, USCE, Anchorage C. Hemming, ADFG, Fairbanks C. Johnson, NMFS, Anchorage K. Moitoret, USFWS, Fairbanks Al Ott, ADFG, Fairbanks B. Ross, USEPA, Anchorage John Wharam, ADNR, Anchorage D. Germann, NSB, Barrow Harold Scott, USEPA, Seattle Dan Steinbome, USEPA, Seattle C. V. Chatterton, AOGCC, Anchorage ATTACHMENT A ( PLAN OF OPERATIONS FOR DRILLING WASTE DISPOSAL DS 12 WELLS 24, 30, 31, 32, AND 33 1. The augering equipment (primarily a crane and an auger drive unit) will be moved to and rigged up on the southern end of the DS 12 pad. (See attached drawing). 2. Up to twenty 8' diameter by + 120' deep holes will be augered on18' well centers using the existing gravel pad as a work pad. These holes will be augered using the same techniques as performed on DS 15 in the summer of 1988. (No conductors will be usec~on the augered holes since this is a winter operation and no surface water is expected. Also, a newly designed 8' diameter auger bit will be utilized instead of the previous 53" diameter bit with a hole enlargement adapter.) As-built surveys will 'be performed on the., , work area at this time. ~' z~o ~ h~z ~ £~ ~,/hJ/b~A~-~Sc. 3. After augering each hole, the holes will be covered with hole covers for safety reasons and to prevent drifting snow from entering the augered holes. 4. The gravel and overburden recovered from augering the 8' diameter holes will be approximately 4,500 yds3. Approximately 1,750 yds3 of the gravel recovered will' 'be used to fill in the small impoundment area next to the work. area (see attached drawing). Approximately 2,750 yds3 will be stockpiled on the Pad.next to the impoundment area (see attached drawing)'. Approximately 750 yds3 of this stockpiled overburden and gravel will. be used as cap material' for the augered holes after drilling.waste placement.' The remainder will be used to meet general operation and maintenance gravel requirements for the following summer construction season. '5. As drilling waste is ge...n, erat~d from the above 'cited wells, the material will be deposited into dumosters directly from the ri_n. As each dumpster is filled, the__ ri~.,,forklift will transport the drilling waste in the dumpster~to' the augered holes,and empty the dumpster T into the augered hole. It may be necessary to heat the dumpsters with steam or other suitable means prior to transporting the drilling Wastes to the augered holes. Hole covers will be removed for waste deposit operations and will be placed over the holes when waste disposal operations are not being conducted. 6. The drilling wastes will be placed into the augered holes up to a height not to exceed 10' below original tundra grade. 7. Vertical thermistor strings will be installed along the hole circumference in five of the augered holes to monitor freezeback of the drilling wastes prior to deposition of any drilling wastes. (See attached attached drawing for thermistor placement information.) Temperature measurements will begin at the -2' level below original pad grade and continue every 2' down to the -15' level. The thermistors will then be placed every 20' to the bottom of the hole. 8. Once drilling activities on the pad have been completed, the holes will be capped with sufficient overburden (from the material stockpiled on the pad) to bring the top of the holes back to original tundra grade. The remaining 5' from original tundra grade to the top of the pad will be capped with gravel to fill the holes up to pad elevation. 9. In the summer of 1989, after breakup, the work area will be examined to inspect the holes for subsidence. If subsidence has occurred, the holes will be brought back to original pad level. Any debris found in the .area will be cleaned up as needed. 10. Markers will be placed in the center of each of the holes indicating that drilling wastes were deposited in these areas. 11. Any drilling waste which may be inadvertently s.oille.d during the transfer and disposal process will be allowed t0.~__free~e and then cleaned _~up~ utilizing shovels and buckets for small spills and/or a MAM/plw 2 of 3 11/23~88 frontend loader for large spills. Any wastes recovered in this manner will be disposed of in the 8' diameter holes. Thermistor strings will be monitored at least monthly in July, August, September and October in 1989 to ensure freezeback has occurred in the drilling wastes and to determine the depth of thaw of the gravel and overburden cap. Liquid waste deposition into the augered holes will be kept to a minimum whenever possible. The number of holes to be augered will be determined by permit timing and well activity upon receipt of permits. Since this operation is primarily a test to determine the feasibility of transporting drilling wastes ,from the rig to the augered holes under winter conditions, various methods of consolidation, transportation, and deposition of drilling wastes may be tested for practicality and/or economic evaluation. MAM/plw 3of3 11/23~88 £MERi:, DUMP 130 120 OlOO 90 140 180 22 'O 70 23 · 2~ 0 SO .,. O' PROPOSED. SUI~FACE LOCATIONS REL I EF PIT 01' O2 O3 OS O6 030.; 08 21 29 28 2'7 32 26 2~ ! t DRILL SITE 12 Figure 1, Attachment ATTACHMENT B TYPICAL THAW PROGRESSION AROUND PRODUCING WELLS RECEIVED NOV 3 m J .Oil ,& (las Cons. Commission ~ ~chorage ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: June 6, 1988 Thawbulb Around Well Bore InternalCorres~..,o, -'----lrll~~ll:ES' 'i File code: P. E. Wangstrom/B. W. Santana- PMC 65g-5571 R. E. Bell/H. R. Brooking- PMC The warm fluid flowing in a production or injection well creates a thawbulb radially around the well bore as seen on the attached thaw progression diagram. To avoid encountering these thawbulbs during the large diameter hole experiment, the disposal hole should not be drilled closer than 60 feet from a production/ injection well and not between two wells on the same drill site. If you need more information, call me. P. E..Wangstrom C/S Field Engineer M 88/06/06 6/eng96 Attachment cc: J. E. Hayes/D. C. Kil'and- PMC B..... W. Santana - PHC L. C. Lilly/J. P. Fero- PHC 'V. Manikian - ATO 1708 K. B. Schoen/T. E. Bessette- PRB 42 ARCO Al~kl, Inc. is m Sulmicll~/of AIIin#~RIc. hfleldCOml~lny AR3B--6001-B ~0 I0 1=11.1. _t,__. 13 2 2 Y'- DI IRECTION I0 ! 'I"O~X/AI~ ID AOJ AC.,I~'lq T A~O~ mAID NOTE: THE~kL MODELING FROM DOT PROGRAM DEVELOPED BY POLIUKAAND WILSON USING FINITE ELEMENT I~THOD (1976) ADOPTED FROM WOODWARD~CLYDE CONSULTANTS TYPICAL THAW PROGRESSION AROUND PRODUCING WELLS Application by: ARCO ALASKA INC, I f', ATTACHMENT C ( Location Maps and Site Plans ~ 7 - /~ ~)~.~ ~%7% , ' ALASKA VIClNI~ MAP PRUDHOE BAY VIClNI~ ~, ~ ,, os-~. ,u N .s-~.~ ~ /- ' ,,, .... '-,_, ,,,~--~, x i . -~-,, -,, N I ~ DS-5 / X . ~ FS-2 / LOCATmO~ ~d ~~',~"'-~ e . DS-~=~ ~~ ~ (1 L~GE D~ETER HOLES ~ ~ ~/ ~ NOR~ SLOPE BOROU~ PURPOSE: DRILLING W~ DISPO~L . e ~~~ ~A~ OF ~~ ' ADd~NT ~D O~ER: STA~ OF ~~ Appllc~on ~: ~ AL~KA INC. DATUM: USL s~,t ~ of D~: N~., '88 I I A4.0,5288001 R 1 CONSTRUCTION PAD i ,,~FLOWLINE DS-12 PLAN · i i i i i i NOT TO SCAI. E ! ! ! i DS-12 LARGE DIAMETER HOLES DRILLING WASTE: DISPOSAL PLAN PRUDHOE BAY UNIT NORTH SLOPE: BOROUGH STATE OF ALASKA Application ~by: ARCO ~KA INC. Sheet 2 of D~e: NOV,.'8~, A44:)3288002 R1 W W RESERVE PIT ..' ~' ~ ~.."' ' ~' ~ o..' .... I WE/L .~....~.~.~.... 12-7 PROPOSED LOCATION Of 8' II .. o' DIAMETER AUGERED HOLES I'I 'b" FOR MUD a: CUTTINGS II DISPOSAL. Ii / WELL PROPOSED TOTAL Of 20 ~J / 12-8 HOLES AT 18' SPACING 20 EACH AT 18'-CC ¥ 1' LARGE IMPOUNDMENT AREA IMPOUNDMENT AREA TO BE FILLED IN APPROX. 1 750 C.Y. 'SPINE ROAD LG. DIA. HOLE CUTTINGS STOCK PILE LOCATION LOCATION PLAN ,NOT TO SCALE PROPOSED DS-12 LARGE DIAMETER HOLES DRILLING WASTE DISPOSAL LOCATION PLAN PRUDHOE BAY UNIT NORTH SLOPE: BOROUGH STATE OF ALASKA Application by:' ARCO ALASKA INC, Sheet 3 ofa,- Dc,e: NOV., '88 A4,03288003 R 1 THE STRING · .,. ~.' ~,o.~.' ~, o.d>.' ~,o. b.' ORIGINAL TUNDRA SURFACE FILL CAP OF AUGERED GRAVEL WITH OVERBURC PLACED IN UPPER PORTION ~ EXISTING GRAVEL PAD NOT TO SCALE PROPOSED I~S- 12 LARGE DIAMETER HOLES DRILLING WASTE DISPOSAL TYPICAL SECI10N PRUDHOE BAY UNIT NOR114 SLOPE BOROUGH STATE OF ALAS~ Applicationby ARCO ALASKA INC. Sheet a, of Dote: NOV., :88 A4.O3288004. R ATTACHMENT D CCoastal Project( Questionnaire and Cer[ fication Statement Please answer all questions. Include maps or plan drawings with your packet. An incomplete questionnaire may be returned and will delay the review of your packet. APPLICANT INFORMATIQN 1. ARCO Alaska, Inq. Name of Applicant P.O. Box 100360 Address Anchorager AK 99510-0360 City/State/Zip Code (907) 263-4305 Phone PROJECT INFORMATION 2. Barb Byrne Contact Person P.O. Box 100360 Ad(Jress Anchorage, AK 99510-0360 City/State/Zip Code (907~ 263-4678 Phone 1. Provide a brief description of your project and ALL associated facilities (caretaker facilities, etc.) Drilling of 20 - 8 ft. diameter by 120 ft. deep augered holes into the existing pad of Drill Site 12 for freezeback disposal of drill cuttings starting Date for Project December 1988 Ending Date for Project May 1988 PROJECT LOCATION 1. Please give location of project. (Include nearest community or identifiable body of land or water.) Prudhoe Bayr Deadhorser Alaska Township 10N 2. Is the project on: State Land X Rang? 15E Meridian UMIAT Section 17 & 18 (please mark with ~/ ) Federal Land Private Land 3. Project is located in which region of the state (see attached map): Northern X Southcentral Southeast ~ Aliquot Parts Municipal Land USGS Map., PERMIT APPROVALS 1. Do you currently have any State or federal approvals for this project? (Note: Approval means permit or any other form of authorization.) If yes, please list below. Yes No Aooroval Tvoe AD°royal # . . . . USCE Section 404 modification BS 25 ADNR Lease Operation 85-47 Exoiration Date FEDERAL APPRQVAL~; 1. Will you be placing structures or fills in any of the following: tidal waters, streams, lakes, Yes No or wetlands*? r~ ~-~ · ff you are uncertain whether your proposed project area is in a wetland, contact the Corps of Engineers, Regulatory Branch at (907) 753-2720 for a wetlands determination. If you are outside the Anchorage area, call toll free 1-800-478.2712. If yes, have you applied for or do you intend to apply for a U.S. Army Corps of Engineers (COE) ~ r--1 permit? Please indicate at right and describe below. Modification to BS 25 I^1 DS-12, SWD/CZM~/ll 1 of 5 '. 2. Have you applied for or do yo~' end to apply for a U.S. Environmental P(" =tion Agency National Pollution Discharge Elimination System (NPDES) permit? Please indicate at right and describe below. (Note: Any wastewater discharge requires an NPDES permit.) 3. Have you applied for or do you intend to apply for permits from any other federal agency? If yes, please list below. Aaencv Aooroval Tvoe I::pA Yes No Class V UIC Notification Date Submitted (or intend to submit) 11-12-88 DEPARTMENT OF NATURAL RESOURCES APPROVALS 1. Is the proposed project on state-owned land or will you need to cross state lands for access? 2. Is any portion of your project placed below the ordinary high water line of a stream, river, lake, or other water body? 3. Will you be dredging? If yes, location of dredging is: Township Range Meridian~ Section · Location of disposal site for dredged materials: Township Rang,~ Meridian Section 4. Will you be filling with rock, sand, or gravel? If yes, amount? 1750 cy · Location of source: Township 10N' Range 1~1= · Location of area to be filled: Townshi? l ON Range 15E 5. Do you plan to use any of the following state-owned resources Timber · If yes, amount? · Location of source:Township Range Meridian~ Other Materials · If yes, what material? (Peat, building stone, 'silt, overburden, etc.) ~ Location of source: 'Township Rang,= Meridian 6. Are you planning to use any fresh water? · If yes, amount (gallons per day)? · Source? 7. Will you be building or altering a dam? Yes No Yes Meridian UMIAT Section17& 1~ Meridian HMIAT Section 17 &. 18 Yes Section Section Yes 8. Do you plan to drill a geothermal well? 9. Will you be exploring for or extracting 'coal? ' 10. Will you be exploring for or extracting minerals on state-owned land? 11. Will you be exploring for or extracting oil and gas on state-owned land? 12. Will you be harvesting timber from 10 or more acres? 13. Will you be investigating or removing historical or archaeological resources on state-owned land? 14. Will the project be located in a unit of the Alaska State Park System? r""l i~ If you answered NO to all questions in this section, you do not need an approval from the Alaska Department of Natural Resources (DNR). Continue to the next section. 2 of 5 If you answered YES/'~'~,. ANY questions in this section, co~.'.'..,:ti'- DNR to Identify and obtain necessary application forms. Based on your discussion with DNR, please list (below) the approval type needed and date submitted. Armroval TVOe Date Submitted (or intend to submifl Lease Operations modification 11 - 2 8- 8 8 Have you paid the filing fees required for the DNR permits? If you are not applying for DNR permits, indicate reason below: a. (DNR contact) told me on,.. approvals or permits were required on this project. b. Other DEPARTMENT OF FISH ANO GAME APPROVALS 1. Will you be' working in a stream, river, or lake? (This includes running water or on ice, within the active floodplain, on islands, the face of the banks, or the stream tideflats down to mean Iow tide.) Name of stream or river: Name of lake; If you answered "no," proceed to question #2. If "yes," will you be doing any of the following? a. Building a dam, river training structure, or instream impoundment? b. Using the water? c. Diverting or altering the natural channel stream? d. Blocking or damming the stream, (temporarily or permanently)? e. Changing the flow of the water or changing the bed? Yes No (date) that no DNR Yes No Yes No f. Pumping water out of the stream or lake? g. Introducing silt, gravel, rock, petroleum products, debris, chemicals, or wastes of any type into the water? h. Using the stream as a road (even when frozen), or crossing the stream with tracked or wheeled vehicles, log dragging or excavation equipment (backhoes, bulldozers, etc.)? i. Altering or stabilizing the banks? j. Mining or digging in the beds or banks? k. Using explosives? I. Building a bridge (including an ice bridge)? m. Installing a culvert or other drainage structure? n. Constructing a weir? o. Other in-stream structure not mentioned above? 3of5 2. Is your project located in a State Game Refuge, Critical Habitat Area, or State Game Sanctuary? 3. Does your project include the construction and operation of a salmon hatchery? 4. Does your project affect or is it related to a previously permitted salmon hatchery? 5. Does your project include the construction of a shellfish or sea vegetable farm? I~1 If you answered NO to all questions In this section, you do not need an approval from the Alaska Department of Fish and Game (DFG). Continue to the next section. If you answered YES to any of the questions under I or 2, contact the Regional DFG Habitat Division Office for information and application forms. If you answered YES to questions 3, 4, or S, contact the DFG Private Nonprofit Hatchery Office at the F.R.E.D division headquarters for Information and application forms. Based on your discussion with DFG, please list (below) the approval type needed and date submitted. A.oproval Tyl~e Date Submitted (or intend to submit} If you are not applying for DFG permits, indicate reason below: a. (DFG co.ntact) told me on approvals or permits were required on this project. ~ b. Other DEPARTMENT OF ENVIRONMENTAL CONSERVATION APPROVALS 1. Will a discharge of wastewater from industrial or commercial operations occur? (See #2 in "Federal Permits" section.) (date) that no DFG Yes No . Will your project generate air emissions from the following: a. Diesel generators totaling more than 10,000 hp? b. Other fossil 'fuel-fired electric generator, furnace, or boiler totaling greater than 10,000 hp, or 9000 kWh, or 100,000,000 btu/hr? c. Asphalt plant? d. Incinerator burning more than 1000 pounds per hour? e. Industrial process? 3. Will a drinking water supply be developed that serves more than a single-family residence? 4. Will you be processing seafood? . - 5. Will food se.rvice be provided to the public or workers? 6. Will the project result in dredging or disposal of fill in wetlands or placement of a structure in waterways? (Note: Your application for this activity to the Corps of Engineers will also serve as your application to DEC.) 7. Is sewage or greywater disposal involved or necessary? 4 of 5 . (,' i? Y~ 8. Will your project result in Uae development of a currently unpermitted'tacility for the disposal of domestic or industrial solid waste? E~ 9. Will your project require offshore drilling or vessel transport of oil, or other petroleum products as cargo, or include onshore facilities with an effective storage capacity of greater than 10,000 barrels of such products? 10. Will your project require the application of oil or pesticides to the surface of the land? If you answered NO to all questions in this section, you do not need · permit or approval from the Alaska Department of Environmental Conservation (DEC). Continue to the next section. If you answered YES to any of these questions, contact the DEC Regional Office for Information and application forms. Based on your discussion with DEC, please list (below) the approval type needed and date submitted. ADoroval Tvoe Date Submitted (or intend to subrTlit) Solid Waste Disposal Permit 11-28-88 If you are not applying for DEC permits, indicate reason below: a. (DEC contact) told me on approvals or permits were required on this 'project. (date) that no DEC _...___ b. 'Other CERTIFICATION STATEMENT The information contained herein is true and complete to the best of my knowledge. I certify that the proposed activity complies with, and will be conducted in a manner consistent with, the Alaska. Coastal Management Program. Signature of Applicant or Agent Date B. K. BYRNE To complete your packet, please attach your state permit applications and copies of your federal applications to this questionnaire. 5 of 5 RE£ iVF..D NOV 3 '.i 19. 0il .& Gas Cons, commission , Anchorage a' DO&G 18-84 LO/Form (Revised 10-86) DNR 10-1172 A( ACHMENT E ( _,rURN TO: LEASE OPERATIONS APPLICATION FORM Division Oil & Gas P.O. Box 7034 Anchorage, AK 99510 Atto: Bill Van Dyke Petroleum Manager DATE November 17, 1988 Applicant ARCO Alaska. Itl{;, ADL # 63197 & 65633 (mandatory_) Project DS-12 Drill Cuttines Disr~osal Bond _ Date permit fee paid D(lDEffective 1-1-86 application for plan of operations on leased land requires $50.00 fee payable to State of Alaska, ept. of Revenue; mail check only to Division of Management, P.O. Box 7034, Anchorage, AK 99510). 1) Plan of Operations (include necessary diagrams): Attached (Attach extra sheets if necessary) 2) Location:T 10N , R 1SE , S 17&18 ~U.M. 3) Access: Existine DS-12 Pad -- (Include necessary maps) 4) Proposed operation start-up date: December 1988 5) Expected completion of permit activity/gravel placement: 6) Project Material: A) Amount (pad) 1750 cy (road) B) Acreage covered (pad) (road) C) Material source Augered holes through existing.DS-12 Pad 7) Snow Removal Plan: N/A 8) Is off road navel required? yes no X A) Period of travel M~y 19~9 cy (other) (other) cy B) Equipment 9) Is a Temporary Water USe Permit required?' A) Purpose yes no X B) Sources C) Access D) Maximum withdrawal 10) Is fuel or any other hazardous material stored on site? yes A) Type no X B) Amount C) Handling proposal 11) Pipeline Construction: A) Location/route B) Number/size C) Type D) Construction access E) Construction period Rehabilitation Plan: N/A 12) 1'3) Is any part of this permit confidential? yes Barbara K. Byrne Authorized Contact Signature- DS- 12,SWD/LOA/12 no ,X (907~ 263-4678 Telephone Number Dam ATTACHMENT F NORTH SLOPB BOROUOH PERMIT APPLICATION . . Name of Applicant: Address of Applicant: ARCO ALASKA. INC, P. O.Box 100360 Anchorage. AK 99510 Name & Tiff. of Contact Person: Barbara K. Bymo Phone No. of Contact Person: (907) 263-4678 Type of Permit: Use Permit X Development Permit , . . . PROPOSED DEVELOPMF~ District in which development is proposed: . Conservation Kuparuk Prudhoe Bay Milne Pt. Hemi Springs · W. Mikkelson Pt. Thomson Gwyder Bay Duck Island Legal Description: a. C or RD District (to nearest quarter section): Drill Site 12. Pmdhoe Bav Unit. Ea.~t Operating Area. T10N. R15E. Section 17 SW1/4. Section 18 SE1/4 U.U'.- b. Barrow or Village District: Lot: ~ Block:_._._ City: Development Type: X Construction Change in Use Subdivision into Other (Specify) Drilling Description of Development: Au~erin~ of 20- 8 ft. diameter bv 120 ft. deer holes to be used as drilling waste disposal ~lf~, - - 10. Other names/numbers by which proposal is also known (e.g. State/Fed Permit): LO/INS 855S 25 11. Rationale statement - (explain why this development is necessary or desired): Winter conditions testing of a new freezeback method of drill cuttings distmsal. -- _ SITE PLAN 12. Attach to this Application the following: a. General Vicinity Map b. Specific Location Map (including nearby existing developmenffnamral features) c. Design Plans (including cross-sectional views and prof'des, as appropriate) d. Supplemental Information (include any other information which you feel may be helpful in the review of this application). 816184 DS-12,SWD~sB~M13 13. DEVEI.~PER I hereby certify that the foregoing is tree and correct to the best of my knowledge. (Authorized Signature) (Date) Barbara K. Byrne Permit Coordinator (Name) (Title) FOR ZONING ADMINISTRATOR USE ONLY / Fee Paid in the amount of $25.00 (Use Permit) / Fee Paid in the amount of $100.00 (Development Permit) / Fee Paid in the amount of $500.00 (Expedited Review) DECISION / Use P~nit Approved: This proposed development substantially complies with the Master Plan and a use permit is issued, conditioned on compliance with all relevant Master Plan conditions, lease stipulations, and provisions of state and federal law and permits served thereunder. / Development Permit Approved: The proposed development meets all applicable mandatory Policies, represents the Developer's best efforts to implement all relevant best efforts and minimization policies, and, so .long as any conditions set forth in the accompanying letter are complied with, will represent a net public benefit. / Permit Denied for the following reason: / / Mandatory Policy fi.om this policy. · If you wish to proceed, you must' request a variance / / Best Efforts/Minimization Policy / / The Development will not represent a net public benefit. /_.../Use does not comply with Master Plan. (See accompanying letter.) If you wish to appeal this debision you must appear before the Planning Commission on the day of ,198 , at o'clock in the Assembly Chambers, North Slope Borough Building, Barrow, Alaska. Date Land Management Administration Permit Application 816184 - 2- ATrA HMENT H STATE OF ALASKA DEPARTMENT OF ENVIRONMENTAL CONSERVATION SOLID WASTE MANAGEMENT PERMIT APPLICATION FOR DISPOSAL OF DRILLING WASTES PART I - A. BASIC INFORMATION Applicant's Name: Mailing Address: City/State/Zip Code: Phone: ARCO Alaska, lng, P. O. Box 100360 Anghorag¢, AK 99510 (907) 263-4678 Operator's Name: Mailing Address: City/State/Zip Code: Phone: ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510 (907) 263-4678 Facility Owner's Name: Mailing Address: City/State/Zip Code: Phone: ARCO Alaska, Inc. P. O. Box 100360 AnCh0ritge. AK 99510 (907) 263-4678 Landowner's Name: Mailing Address: City/State/Zip Code: Phone: Alit~ka Dept. of Natural Resources P. O. Box 7005 Anchorage, AK 99510 (907) 56t-2020 Facility Location: (Legal description of property_; range, township, and s~ction) Produhoe Bav Unit Sections 17. and 18, T10N, R15E, Umiat Meridian Ap01ication is for: (x) ( ) ( ) ( ) A new facility. An unpermitted, existing facility. Renewal of Permit No. Transfer of Permit No. Applicant is aware of: Ali applicable local ordinancesi All applicable local zoning requirements. Requirements of the Alaska Coastal Zone Management Program, 6 AAC 50, if appropriate Yes' (x (x ( X No 11/28/88 DS-12,SWD-DEC/10- 1 - .(' ACttMENT G APPLICATION FOR DEPARTMENT OF THE ARMY PERMIT OMB APPROVAL A;O. 0702.0~ l~e ~~t of the ~Y ~t ~ i lutho~z~ by ~ion L0 of ~ Ri~ ud ~Mr A~ of 1800. ~m 404 of t~ t~tia a or i~~ u~" RuE of ~b Uni~ Sm~ ~m d~ of dm~ ~ fill m~l into ~mu of ~he U~ SOt ~ ~e ~~ of ~ ~~ f~ ~ho p~ of dump~ it into ~ wean. lnf~mtmu ~dM on ~b ~ ~ ~ ~ e~m~ ~ a~ be a ~t. tnf~mn in ~ha a~U~tmn ~ ~e a ~ of pub~ r~ ~u~ imm of pu~ n~, ~ of ~ infmtmn ~~ a Mi~; ~w~e. ~ dsm ~u~d m n~ in oM~ M ~muh One mt of ~ ~~ or ~ ~u~bb ~pim whieh ~ i~ I~i~n ~d c~~ of ~b ~~ a~i~ty mm ~ at~ m i~ ~mi~n (~ ~pb dmwmp 4nd i~ctio~) ~d ~ sub.tM to i~ D~ E~ M~ j~~n ~ ~he lotion of m ~ i~ty. An ippiiMlion ~t ii not ~mpMM ~ hH ~ ~ nt.d. NAMIA OlqJll UP APPLIGANT ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Ale ( ) A,c (907) 26 -4841 Barbara Ki Byrne P.O. Box 100360 Anchorage, AK 99510-0360 Tmlnoflo no. aurIal ~uemmo nNN &lC (90~) 263-~678 4. OITAILIO DII¢IIIIPTION UP PlqOPOSlO ACTIVITY 44. AGTIVITY T~le' proposed filling of a small i~ou~ent area located on d~e e×isting pad of Drill Site 12. Also, the proposed placement of gravel, fill caps into 20 augered drill cutting disposal cells located on the Drill Site 12 pad. #. PUlqPOti To allow equipment access on Drill Site 12. to proposed drill cuttings disposal cells located Also, the'placeme, nt of fill caps into 20 auger~d d~ill cutting disposal cells for closeout. ' o,sc. Alqat up OntOaUO O. P,L~ MA. lq,AL Approximately 1,750 cy of fill into the small impoundment area and an additional 7S0 cy of fill to cap the drill cuttings disposal cells. ~ · . . ~1' State of & WATInEODY ANO L)OCATION ON WATEIqIOOY WHelql ACTIVITY EXISTS On iS PnoPosIO Mod±£icatio~ o£ Sect±o~ 404 pe~it, ~eau£ort Sea ~5 ~ith~ ?~0N, & 18 U.M. (071-OYD-N-790.577) R15E, Sections 17 ?. ~OCATION ON ~ANO W~lnl ACTIVITY EXISTS O~ Drill Site 12 Prudhoe Bay Unit, East Operation Area Pru~oe Bay, DenS_horse, Alaska COUNTY STATE ZiP CODE North Slope Borough SIGNATURE OP APPLICJI~IT C)ATE SIGNATunE ~?~e appi~ltJon mwt ~)e l~?lGd by the p~rwo, u)ho d~i~l to und~4 th~ p~Md ~Cdu~ (appOint) or Jt ~y be I~ by 4 c ~8 0.S.C. ~n i0Ol ~N t~t: Wh~vff, in iny mnn~ within the juMi~ion of SAy de~mm~ or alen~ of ~~ ~ ~y ~~ ~n~ or ~ up b~ iny m~, Win, ~ d~N I m~ tl~ or ~N any ~M, fi~i~iou PART I (Cont.) g . TYPE OF FACILITY (Check as many as applicable) ( ) Exploratory site ( X ) Production site ( ) Central or commercial disposal facility ( x ) Other (explain) ( ) Single well ( X ) Multiple wells Depth of well(s) 6000'+_ Auger Holes 120' Deep C · GENERAL INFORMATION ABOUT CONTAINMENT STRUCTURE A. Above grade? ( ) Below grade ( X ) B. Size, number, and depth of cells 20 cells, 8 ft. diameter by 120 ft. deep. C. Volume of waste to be disposed of +4.500 cy D. Anticipated date of closure Before May 1, 1989 E. Other wastes/volumes to be disposed of None F. Containment & Monitoring Option (from 18 AAC ~.530(a), Table D) V G. Sizing rationale and calculations PART II . CHECK LIST Check the items which are included with this application. ( X ) The cover letter, requesting permit issuance and containing the information required by 18 AAC 60.210(b)(1). (x) (x) (x) (x) (x) The map or aerial photograph identifying the features specified in 18 AAC 60.210(b)(3). The site plan and cross-sectional' drawings of the facility containing all the information required by 18 AAC 60.210(b)(4). A narrative description of the existing or proposed development, providing all the information required by 18 AAC 60.210(b)(5). (See Note 1.) A narrative description of the topography, geolOgy, climate, surface, and groundwater hydrology as required by. 18 AAC 60.210(b)(6). Except for exploratory wells on permafrost, the information from soil borings as specified by 18 AAC 60.210(b)(7). 11/28/88 DS-12,SWD-DEC/10 -2- " PART II (Cont.) (" ( X ) An evaluation of the potential for generating leachate as required by 18 AAC 60.210(b)(8). (See Note 2.) (x) The option for containment and monitoring selected from 18 AAC 60.530(a), Table D, the certifications, and, if applicable, the fluid management plan required by 18 AAC 60.210(b)(9). (See Note 3.) ( X ) A monitoring plan providing the information specified in 18 AAC 60.210(b)(12). (See Note 4.) ( X ) The closure plan required by 18 AAC 60.210(b)(11). (See Note 5.) (x) Proof that the landowner has received written notice fully describing the activity and a copy of a lease agreement or written consent statement as required by 18 AAC 60.210(b)(12). ) For above-grade disposal options, the baseline water quality data specified in 18 AAC 60.210(c). (See Note 6.) ( X ) For projects located within the coastal zone of Alaska, a completed coastal project questionnaire. Explanation on a separate sheet why any of the above items are missing from the application. PART III - SIGNATURES The cover letter and this form must each be signed by the applicant. I, David A. Heatwole , certify under penalty of perjury, that all of the above information and exhibits are true, con'ect, and complete. Applicant's Signature: / : Date:. 11-29-88 18 AAC 15.030. SIGNING OF APPLICATIONS. All permits or approval applications must be signed as follows: (1) (2) (3) .(4) In the case of corporations, by a principal executive officer of at least the level of vice president or his duly authorized representative, if the representative is responsible for the overall management of the project or operation; In the case of a partnership, bY a general partner; In the case of a sole proprietorship, by the proprietor, and In the case of a municipal, state, federal, or other public facility, by either a principal executive officer, ranging elected official, or other duly authorized employee. 11/28/88 DS-12,SWD-DEC/10 -3 - DRILL SITE 12 SWD LOC~TION MAP Attachment C provides a location map for the project site at a scale of 1 inch = 0.7 miles. Specific items requested in 18 AAC60.210(b)(3) are indicated below: A, Existing roads and structures within two miles of the site are provided on Figure 1, Attachment C. Other pertinent features are provided on the site maps. B. There are no property boundaries within two miles of the facility. C~ There are no residential drinking water wells either existing or in use within one- half mile of the facility boundary. 11/28/88 DS-12 SWD/01 B. DRII.I. SITE 12SWD SITE PLAN The site plan and cross-section for the site are provided on Attachment C, Figures 2, 3, and 4. Specific items requesmd in 18AAC60.210(b)(4) are indicated below: Ae The proposed portions of the facility are indicated on Figures 3. Figure 4 shows conditions upon closure. B~ Because of the presence of underlying permafrost, any surface and ground water flows are expected to be identical. The proposed disposal site is located on an existing pad which has no natural surface water flow. C. Proposed stockpile areas are on existing drillsite gravel pad. Disposal areas are designated on Figure 3. D. Control of drainage onto the site will be provided No stockpile or other special drainage control is required because of the elevated, fiat site conditions on an existing pad. 11/29/88 DS-12,SWD/02 DRILl. SITE 12, SWD PHYSICAL ENVIRONMENTAL CONDITIONS The drill site is located in the Prudhoe Bay Unit on Drill Site 12. Surface water drains as indicated on the attached plans. The closest surface water body is a shallow lake at least ?00 feet northwest of the proposed disposal site. The extensive permafrost (active layer generally less than two feetbelow the origional tundra grade), extending some 2000 feet vertically, precludes accumulation of any significant fresh groundwater in the area. Alluvial gravels, sands and silts extend from essentially the surface through the 2000-foot permafrost interval. Ice lenses/wedges may be present within 20 feet of ground surface. While the alluvial materials could contain fresh water, many were deposited in a marine environment and contain brackish to saline waters, all of which are frozen solid, as pemmfwst, in the upper 2000 feet. The uniformity of alluvial permafrost which exists throughout this area is well understood. There are no subsurface fresh water aquifers in the area. Since all activities will be conducted during the winter freezeup period and on an existing drill site pad, water flow is not a problem. The climate is typical of the North Slope: severely cold temperatures and blowing snow in the winter and mild to warm temperatures during the brief summer. The site on which the disposal cells will be drilled has been previously cleared for any archeological or habitat significance. 11/29/88 DS-12,SWD/03 DRr~.I. SITE 12, SWD GEOTECHNICAL INFORMATION Specific information to describe items requested in 18AAC60.210(b)(7) is indicated below: A. The location is at an elevation of 41 feet (USGS datum). B. The soils conditions generally consist of the following strata: . Stratum 1; 0-5 ft - Contains organic mat typically 0.0 - 2.0 feet subgrade and is classified as Pt (highly organic soils) per the Unified Soil Classification System. Underlying the organic mat to depths of approximately 5 feet are organic and inorganic brown and/or grey silts classified as SM, ML, and OL soils. This material is commonly ice rich and frequently contains massive ice. 2'* Stratum 2:5-15 ft - This stratum consists of silty fine-grained brown and/or grey fine-grained sands with little or no gravel. The material is generally ice rich, containing individual ice crystals or inclusions which can be well- bonded excess ice. These soils are classified as SM and SP soils. . Stratum 3:15-25 ft - This stratum contains silty gravelly sand and is usually the transitional zone between the fine-grained sand above and the gravels and coarse sand below. These soils will range from SP to GM Soils and are ice rich. ,, Stratum 4:25-60 ft - This stratum primarily contains silty sandy gravel, although in numerous borings a silty gravelly sand was encountered. Soils in this stratum are classified OM to OP and contain segregated ice commonly in individual ice crystals or inclusions. This information was obtained by averaging the depths of the numerous borings taken on the North Slope. Site-specific geotechnical information at the time of excavation can be obtained and submitted to ADEC at the Department's request. In the unlikely occurrence of encountering unexpected soils, laboratory investigations will be conducted to ensure the cap design is adequate to maintain stability and insulation of the drill cuttings. C. Investigation of the hydraulic conductivity of frozen soil has been extremely limited due to the difficult procedures and elaborate equipment required. Determination of hydraulic conductivity is beyond the capabilities of most commercial laboratories, and published data and literature is very limited. Williams and Burt (1974) were the first researchers to attempt to measure the hydraulic conductivity of frozen soil. In summary they concluded: (1) frozen soil may have significant hydraulic conductivities; (2) hydraulic conductivity decreases as temperature decreases; (3) ice lenses in soil reduce the hydraulic conductivity; and (4) regardless of the actual mechanics of fluid movement through frozen soil, it appears that D'Arcy's Law can be used to quantify this process. 11/29/88 DS-12,SWD/04 De The saturated hydraulic conductivity for the soils described in Section B above will vary greatly; however, in frozen state the soils are considered impermeable. Based upon the low salinities, typical soil characteristics, and low ground temperatures at the site, it is expected that the hydraulic conductivity of the frozen soils comprising the containment structure is negligible. Thus the potential for migration of fluids through the frozen in sim soils is also negligible. The moisture content of the soils describe in Section B above is as follows: Stratum I Stratum 2 No moisture content tests were performed on organic samples, but based on experience in previous work these soils are fully saturated. Average value - 22.1% over 8 tests with a standard deviation of 8.65%. Stratum 3 Average value - 19.8% over 1 test with a standard deviation of 0%. Stratum 4 Average value - 10.3% over 9 tests with a standard deviation of 1.62%. E. F. Groundwater occurs in an unfrozen state during the summer and fall months and is confined to the active layer which is typically 1 to 2 feet thick in this area. There is no significant active layer at this site since the original active layer is covered by a 5 foot thick pad which insulates most of the original surface from seasonal thawing. Because of the depth at which the drilling wast,swill be buried, no thawing of wastes will occur. 11/29/88 DS-12,SWD/04 DRII.I. SITE 12, SWD FLUID MANAGEMENT PLAN AND CERTIFI~TIONS General The drilling wastes will not contain hydrocarbons as free liquids and the applicable containment and monitoring requirements of 18AAC60.530(a) will be met by freezeback (Option C) at the conclusion of drilling. The disposal cells will contain cuttings from formations, some of which will probably contain hydrocarbons. As such, they may have residual oil adhering to, or contained within, the formation cuttings particles; however, free oil will not be placed in the pits. The containment structure design selected is Option V from Table D which includes (a) site inspection, (b) active thaw zone monitoring, and (c) use of thermistor(s). The drilling waste disposal cells will be augered below the original tundra surface entirely within the permafrost. The following sections describe specific procedures which would be employed as part of the Fluid Management Plan. Fluid Management Plan The following steps will be taken during the course of drilling activities and prior to Closure in order to accomplish the objectives for fluid management. 1. Solids Control While Drilling The mud system on the drilling unit will be equipped with solids control equipment which will expel drilled solids with relatively low fluid content to the disposal pit. This equipment includes high volume shale shakers, de-sander, de-silter or mud cleaner, and a centrifuge. The primary function of this equiPment is to remove drilled solids from the mud in ever-decreasing size fractions as the drilling fluid passes through the system. The net result of this operation is a scavenging of usable drilling fluid and a discharge of low fluid content drilled solids. Fluid Discharges While Drilling 7~ ,/"/m t~$e~¢~ p,'~' ? During the course of any drilling operation, limited quantities of dfillin~ fluids will be discharged to accommodate specific downhole operations. For example, thee cementing of casing strings usuMly ~'esUlts in the disch~e of some cement contaminated mud. Operations requiring a reduction in mud volume to accommodate dilution will also result in .s, omc fluid ~scharges to t,hc reserve~Dit. Surface Water and Groundwater Inflows SUrface water flow will not be a problem at this 'location as all drilling will be done under freezeup conditions. 4. Snow Accumulation After augering each disposal cell, the cells will be covered for safety reasons and to prevent drifting snow from entering the augered cells. 11/17/88 DS- 12,SWD/05 e Accid0ntal Fluid Releases Every precaution will be taken to prevent accidental fluid releases on the drilling pad. Fuel line valves and fittings will be checked for leaks daily. Strict fuel transfer procedures will be observed at all times. Should any minor accidental fluid releases occur, they will be contained on the drilling location or within bermed sumctures around fuel tanks, etc. If it were to become necessary, accidental fluid releases could be pumped or drained into the reserve pit until the problem was corrected. Any emergency discharge of this type would be pumped out as soon as possible; any residual oil separated and non-oily fluids will be finally disposed of through annular injection or other approved means. 11/17/88 DS-12,SWD/05 m" CERTIFICATION: By this application, the undersigned certifies that the site conditions noted herein are accurate and that the containment and monitoring requirements if 18AAC60.530 will be met. In addition, the undersigned certifies that the fluid management plan as described herein is consistent with the requirements of 18AAC60.$30. R$Lgistcred Engineer 11/29/88 DS-12,SWD/05 Dl~11.l. SITE 12, SWD I.RACHATE GENERATION EVALUATION The permafrost throughout this general area is within a few feet of the surface (in most places the active zone is only one to two feet thick). Sands and gravels characteristic of the broad alluvial plain constituting the North Slope extend for thousands of feet but are permanently frozen fi.om the top few feet to 2000 ft +_. The subsurface augered holes to be used for the disposal and ultimate freezeback of the solids, will confine all solids (drill cuttings, mud waste, etc., but no human waste). The confinement will prevent leachate contamination away from the drill site. In addition, an active liquids management program will prevent overtopping during the brief period the disposal cell is open. The drilling wastes will become permanently frozen, encapsulated by permafrost on all sides, by some 2000 feet of permafrost below, and by a permafrost zone within the cap material above. 11/1'//88 DS- 12,SWD/06 DR~L SITE 12, SWD LANI~WNER NOTIFICATION The State of Ahska is the landowner, and surface activities thereon are conducted with the permission of the Department of Natural Resources. This organization has been and will continue to be kept informed of the activities at this time through meetings and phone conversations, their own permit requirements, notices of completion, their own visual inspection, and a copy of this application (with any follow-up submissions). 11/17/88 D$-12,SWD/07 DRILL SITE 12 SWD MONITORING PLAN As required by 18 AAC 60.310 (a), a visual monitoring plan will be conducted to detect: Ii Signs of damage or potential damage from settlement, ponding, leakage, thermal instability, frost action, erosion, thawing of the waste, or operations of the facility; 2. Damage to the above ground portions of thermistors; 3. Visually detectable deviations from permit conditions or regulatory requirements; 4. Escape of waste or leachate or any improper waste disposal; 5. Erosion, cracks or other damage to the disposal cells; Inspectors shall be familiar wkh thc requirements of existing regulation and the permits that are to be issued and with the visual monitoring plan. Observed variations from normal environmental variations requiring remedial action will be reported to ADEC at a frequency as required by 18 AAC 60.315 (a) (2). Thermistor Measurements Vertical thermistor strings will be installed along the sides of five(5) of the augered cells. This will be done to monitor the freezeback of the drilling wastes..The temperature measurements will begin at the -2 ft. level below the original tundra grade and continue every 2 ft. down to the -15 ft. level. The thermistors will then' be placed at every 20 ft. level to the bottom of the cell. The thermistor strings will be monitored monthly in July, August, September and October 1989 to monitor the freezeback process. If freezeback of the drilling wastes has not occurred by October 1989, then monthly readings of the thermistors win be taken for an additional year. If faulty or suspected points are detected when the thermistor data is analyzed, the strings · will be removed from the cell. They will then be recalibrated and if necessary, the faulty beads will be replaced. 11/29/88 DS-12 SWD/08 DRILL SITE 12 SWD CLOSURE PLAN As required by 18 AAC 60.410, the following closure plan will be implemented: The proposed closeout plan is to freeze the drilling waste in place. About 500 cy of the augered gravel/organic overburden will be used as cap material to bring each cell up to the original ground elevation after disposal of the drilling wastes. This cap will be used to fill each cell to the existing elevation of the DS-12 pad. A marker will be placed over each closed disposal cell to indicate where drilling wastes were deposited. 11/18/88 DS-12 SWD/09 ATTACHI~ENT I PERMAFROST INTEGRITY AT DRILL SITE 12 WITH RESPECT TO A NEARBY LAKE Drill Site 12 is located in the midst of the Deadhorse area of Prudhoe Bay with its many service company facilities. The Sag River floodplain is located about 1000 feet to the east. The drill site borders a lake, approximately 100 acres in 'size, on the drill site's north, northwest, and west sides. In fact, by means of gravel fill, the northwest part of the drill site extends about 300 feet beyond the lake's shoreline. There may be concern by some that the lake .may have a substantial thaw bulb which could endanger the permanent freezeback of drilling wastes buried in large-diameter holes at DS 12. As shown in Figure 1, the drill site manifold building, flare pit, and most of the emergency dump pit, along with the gravel pads and flowlines supporting these items, are all located in the lake area. Flowlines from the manifold building to Flow Station 1 cross the lake in a northerly direction for about 1,000 feet. The lines are supported on VSM's installed through a gravel fill. According to AAI topographic data, the lake area near the drill site and'crossing has a shoreline elevation of approximately 35 feet and a bottom elevation of 29 feet, for a maximum depth of 5-6 feet, depending upon the water level. In permafrost terminology, a .lake 5-6 feet deep is considered a "shallow lake". According to Williams (see attachment): The lakes of northern Alaska may be divided into: (1) Those less than 7 feet deep, which normally freeze to the bottom in winter and (2) those more than 7 feet deep which do not freeze to the bottom in winter. The permafrost table beneath the shal-' low lakes that are 2-3 feet deep is generally within 2 feet of the lake bottom, but permafrost tempera- tures beneath the lake are as much as 3 deg C. warmer than those beneath the surrounding tundra. Beneath small lakes that do not freeze to the bottom in winter, the permafrost table is depressed into the shape of a saucer, and an upward indentation is formed in the base of permafrost. The thermal effect of large, deep lakes may form an unfrozen zone that perforates the permafrost. Based upon these guidelines, the shallow lake by DS 12 is expected to have a minimal thaw bulb, perhaps on the order of 5 feet below the lake bottom. This thaw bulb would not be expected to extend horizontally a significant amount beyond the shoreline, maybe 10 or 20 feet, based upon the above reference, and the analogy of a heated building on permafrost, which will cause a thaw bulb to develop below the structure, as depicted in Figure 2. The thaw bulb will not extend much beyond the building because of the physics of heat flow, which can be demonstrated with a flow net showing the shape of the bulb. The large-diameter holes will be at least 700 feet from the lake's shoreline, too far to be influenced by any thawing below the lake. Evidence that the lake's, thaw bulb is limited comes also from the successful installation of several hundred VSM's which employ adfreeze bonding in the permafrost to support the DS 12 flowlines and modules. Reportedly the only thawed ground encountered below the usual active layer was during the installation of several drill rig conductor holes located near the buried shoreline. Beyond the shoreline area, everything was apparently frozen below the active layer. References 1. Sanger, F. $., 1969, Foundations of Structures in Cold Regions, CRREL, Cold Regions Science and Engineering Monograph III-C4, 92 p. 2. Williams,'J. R., 1970, Ground Water in the Permafrost Regions of Alaska, U. S. Geological Survey, Professional Paper 696, 83 p. II o. I I,,i~Cr..i . ~A 550'- 0' // / POINT . t ' . I F,u. ~Jll~J EL. 41~/---;.$~ i. ~ %--.~'" iF.JT;~[ .~~ ,~ . it. i 18 EFFECT OF LOCAL HYDROLO(~IC DIFFERENCES The warming effect of the ocean, a lake, or a river on ground-surface temperature is responsible for large local differences in permafrost tempera- ture, thickness, and areal extent. The hydrologic thermal effects are determined by: (1) The magni- tude of the difference between the temperature of the ground surface adjacent to a body of water and the temperature of sediments immediately beneath the water, (2) the thermal properties of the earth materials, and (3) the geologic history of the body of water. These effects may extend to a depth of several hundred feet (Lachenbruch, 1957a). Differ- ences between ground-surface temperature adjacent 'to and beneath glaciers and thick accumulations of snow cause similar local variations in permafrost characteristics. EIvFF~T OlV ?1~ 0C~tl~ The. effect of the ocean on the configuration of permafrost has been calculated from geotl~_,.e~l data from Barrow, Cape Simpson, and Cape Thompson, Alaska. Near Barrow, ground tempera- ture at a depth of 90 feet increases from beneath the land 350 feet from shore to -0.96°0 in ocean-bottom sediments (Brewer, 1958b, table 1). The indicated depth of permafrost decreases from 1,330 feet S miles from the coast to 1,045 feet at a point 1,200 feet from the coast and to 670 feet at a point Qf land only 400 feet from the beach (Mac- Carthy, 1952). The latter two figures are uncor- rected for the thermal effects of nearby lakes and possible shifts in the shoreline (Brewer, 1955b, p. 24). Ocean temperatures near Barrow are below '0°C, and permafrost may be expected in ocean-bot- tom sediments beneath ocean depths of less than '500-1,000 feet, where the temperatures are above 0°C (Brewer, 1955b, p. 25). However, water in the sediments may be unfrozen if it is saline. From the- oretical consideratiofls, Lachenbruch (1957a) does not expect permafrost to occur at depths greater than 100 feet below the ocean bottom farther than a few thousand feet from shore, except where shore- lines are transgressing. No studies have been made of the thermal effect of the ocean on distribution of permafrost in the discontinuous zone. EFF~ OlV LAKES Studies of the effect of lakes on the thermal regi- men of permafrost have been made in the continu- ous-Permafrost zone of northern Alaska (Lachen- bruch, 1957b; Brewer, '1955a, b; Lachenbruch and others, i962) and of Canada (Johnston and Brown, 1961, 1963; W. G. Brown, 1963). The lakes of GROUND WATER IN THE PERMAFROST REGIONS OF ALASKA northern Alaska may be divided into: (1) Those less than 7 feet deep, which normally freeze to the bottom in winter and (2) those more than ? feet deep which do not freeze to the bottom in winter (Lachenbruch and others, 1962, p. 79?). The per- mafrost table beneath the shallow lakes that are 2-3 feet deep is generally within 2 feet of the lake bottom, but permafrost temperatures beneath the lake are as much as 3°C warmer than those beneath the surrounding tundra (Brewer, 1958b, p. 25). Beneath small lakes that do not freeze to the bottom in winter (fig. 11), the permafrost table is depressed into the shape of a saucer, and an upward indentation is formed in the base of per- mafrost. The thermal effect of large, deep lakes (~g 11) may form an unfrozen zone that perforates the permafrost-.(Lachenbruch and others, 1962, p. ?98). For example, thermal studies beneath Imikpuk Lake, on~ ,Of the.:small, deep lakes near Barrow "(Brewer, 'i958a, p. 284) sho~r that the 0°C iso- '-g~0therm lies at a depth of 190 feet, but that the unfrozen zone may be even deeper because of -dep'r~ssion of the freezing point of saline ground water 'in bedrock beneath the lake. The history of formation of lakes is especially important because, many are formed by the cave-in or thaw process. The depression occupied by cave-in type lakes was formed initially by collapse of the ground following thaw of ground ice. Many such lake basins have subsequently been filled by peat and organic-rich sediment which become frozen. The basins may be reopened by thawing to form a second-generation lake (Wallace, 1948; Hopkins, 1949). Lakes that occupy abandoned channels of rivers exert a warming effect on ground tempera- tures, which is complicated by the earlier thermal effect of the river and by the time elapsed since the river' abandoned its channel. Progiacial lakes of Pleistocene age may have prevented formation of permafrost and perhaps degraded preexisting per- mafrost (Nichols, 1965, p. 172-175). Although geothermal studies have yet to be applied to lakes in the discontinuous-permafrost zone of Alaska, the same principles are applicable as in the continuous zone. In the discontinuous zone, where permafrost temperature is higher and the permafrost is thinner than in the continuous zone, a greater number of the small, deep lakes may be underlain by unfrozen zones that perforate the per- mafrost, and correspondingly, the unfrozen zone beneath large, deep lakes would be larger. PERMAFROST 19 ]~FF~T OF RIV~3 In the continuous-permafrost zone, only the lar~- est rivers produce a temperature anomaly that is I~at enough to form an unfrozen zone through the permafrost. In northern Alaska, the Colville River has formed an unfrozen zone several hundred feet deep beneath its bed. The unfrozen zone may per- forate permafros~ as suggested by Black (p. 119, in Hopkins and others, 195§). Drilling beneath smaller streams, such as the shallow, braided Shaviovik River (Brewer, 1958b, p. 26, fig. 10) and Selin Creek near Cape Lisburne (Feulner and Williams, 1967) showed that permafrost exists at shallow depths beneath the streambeds. The permafrost temperature beneath the Shaviovik River is 3'°C warmer than that beneath the tundra bordering the str~_~_m_ to a depth of 155 feet (Brewer, 1958b, fig. 10), but Brewer (1958b, p. 26) expects that the temperature curves of permafrost beneath the tundra and beneath the stream will converge below that depth. Shallow, sluggish streams connecting lakes on the Arctic coastal plain are underlain by shallow, linear unfrozen zones and linear indenta- tions in the base of permafrost (fig. 10) (Lachen- bruch and others, 1962, p. 798). In the discontinuous-permafrost zone, unfrozen zones that perforate permafrost lie beneath most large and medium-sized rivers. The minimum size of rivers having such unfrozen zones varies with the heat budl~c of the river and the mean annual ground-surface temperature in the surrounding ter- rain. The minimum size required for formation of an unfrozen zone that perforates permafrost becomes smaller southward, which is consistent with the regional zonation in which permafrost has higher temperature and smaller areal extent and thickness towaid the south. Evidence for the exist- ence of unfrozen zones that perforate the perma- frost beneath rivers in Alaska is limited to data from borings beneath the Tanana River at Blenana (fig. 5) and alonlr riverbanks or on islands in the Kuskokwim, Yukon, Tanana, and smaller rivers. These rivers are discussed in the sections describing ground-water occurrence. Data' needed for calculat- ing the thermal effect of rivers, on permafrost accordirlg to the methods of Lachenbruch and W. G. Brown are not yet available for the discontinuous- permafrost zone of Alaska, Migration of a river across its valley or other shifts in the position of the channel cause migration of the unfrozen zone beneath the river. Not only does the thermal effect of the river influence the extent of the unfrozen zone, but the speed of migra- tion influences the length of time available for the' thermal effects to alter the thermal regimen of the permafrost.. As a river migrates, it erodes the FIGIraS Il.--Schematic representation of the effect of bodies of water on configuration of permafrost in the continuous- permafrost zone. (Modified from Lachenbrueh and others, 1962.) FOUND · IONS OF STRUCTURES IN COLu REGIONS 1.0 .10 ? -G -'1"' -3 0.8 kc 0.7 0.6 0.5 20 · 30 40 -2 ~, ~--~ ~,, ~ .~). BOWL P~OPO~P/O~i$ ' of 5000 ~ef. day~ ~o I I I I t 50 60. 70 80 90 ~OO FEET WIDTH (L=LENGTH) Thaw bowl beneath a heated building on permafrost. FIGUR~ 2 November 29, 1988 Telecopy: (907)276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit DS 12-30 ARCO Alaska, Inc. ' ......... Permit No. 88-142 Sur. Loc. 399'FSL, 6'FEL, Sec. 18, T10N, R15E, UM. Btmhole Loc. 2299'FNL, 702'FWL, Sec. 21, T10N, R15E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. .To aid us.in scheduling, field work,..please notify this office .24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, Where a diverter system is required, · please also notify this office 24 hours prior' to commencing equipment installation so that the .Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA ,- AND GAS CONSERVATION C NrMISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work Drill I~ Redrill d ~b. Type of well. Exploratory [] Stratigraphic Test [] ~)~evelopment Oil [] Re-Entry [] Deepen[]1 Service [~' Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 7/+'~ PAD /+1 'GL feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe 8ay Oil Pool P.O. Box 100360, Anchorage, AK 99510-0360 ADL 28331 ~ TD 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 399'FSL, 6'FEL,Sec.18,TION,R15E,UM Prudhoe Bay Unit Statewide At top of productive interval (~ 8976' TVD) 8. Well nu .tuber Number 25/+0' FNL, 250' FWL,Sec. 21 ,T1 ON,R1 5E,UM DS 12-30 #8088-26-27 At total depth 9. Approximate spud date Amount 2299'FNL, 702 ' FWL,Sec. 21 ,TION,R15E,UM 12/01/88 $500,000 12. Distance to nearest DI,~. I~iL~ta8nBce t~2n, earest well 14. Number of acres in property 115~ Proposed depth(MD and TVD) prope6rt~y line ' 085' ND ~ Surface feet ~ 1378'NB/1376'TVDfeet 2560 960/+'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1000'feet Maximum hole angle ~1 0 Maximum surface 2870 psig At total depth (TVD) 3750 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-mO Weld 80' 30' 30' 110' 110' 2000# Poleset: 17-1/2" 13-3/8" 68# K-55 BTC 20' 30' 30' 50' 50' 2000 sx CS II I & 72# L-80 BTC 3250' 50' 50' 3300' 3000' 600 sx CS II lZ-1/~" 9-5/8" /+7# L-80 ITC/Mod 11170' 30' 30' 11200' 8939' 500 sx Class G 8-i/z" /" z~' L-80 BTC 1185' 10900' 9378' 12085' 960/+' 300 sx Class C 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~u°r~;;;tOr RECEIVED Intermediate Production NOV ~, ~' Liner ~JasJ~, ~il & Gas Cons, .C.o .~b_~ Perforation depth: measured "~l.,;.,.~J]l~Jl..0......i~l~ ~,~ ............ true vertical 20. Attachments Filing,fee [~/'Property plat [] BOP Sketch I~ Diverter Sketch I~ Drilling program Drilling fluid program GK Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [[3/' 21. I hereby certify that t_he f..oregoing is true and correct to the best of my knowledge Signed %~, ~_ Title Re~iional Drillin, Enqineer Date A~p Commission Use Only ~ (GSW) PD3/037 Permit Number I Inumber I Approve, date I See cover ,etter ~E"/'Y ~--- 50-02.?- ~_,'~' ? t 11/29/88 for other requirements Conditions of approval Samples required [] Yes ,,~No Mud Icg required [] Yes ~No Hydrogen sulfide measures [] Y..e.s~No Directional survey required ,,~Yes [] No Required workin~l,-Frb~sure..'~or.,J~3PF_./ J~2M; ~, [] ~M; ~ 5M; [] 10M; [] 15M Other: / /~// /~ Approved b'~,~ ~,'.. ,/'. ~ .~ ~/r/~'.~..~/~F''"~ Commissioner by order of the commission Date Form 10-401 Rev. 12-1-85 Sub~i/~ iiplicate PBU DS 12-30 ('Injector) OPERATIONS SUMMARY 1) MIRU drilling rig. 2) NU 20" annular diverter and function test same. 3) Spud well and drill 17-1/2" hole to 1000'. Kick off and build angle at 2.5°/100' to 41° 15' at S62°02'E. Drill to 3000'TVD/3300'MD. 4) Set 13-3/8" casing and cement same. 5.) Install 13-5/8" 5000 psi RSRRA BOPE stack and test rams to 5000 psi, annular to 3500 psi. 6) Drill float equipment and 10' of new hole. Perform leak off test. 7) Drill 12-1/4" hole to 8939'TVD/11200'MD (10' TVD above Sadlerochit). 8) Set 9-5/8" casing and cement same. 9) Test casing to 3000 psi. Drill out and perform leak off test. 10) Drill 8-1/2" hole to TD of 9604'TVD/12085'MD. Run open hole logs. 11) Run and set 7" liner and cement same. 12) Clean out liner to PBTD. Test liner, liner lap and casing to 3000 psi for 30 minutes. 13) Circulate well to brine, freeze protect and release drilling rig. 14) Run cement evaluation logs and gyro. 15) MIRU completion rig. RIH and set packer. Run 5-1/2" tubing with GLMs and 5-1/2" tailpipe. NU 5-1/2" tree. RD completion rig. 16) Perforate and stimulate as necessary. Install SSSV. PD3/037.2 NOTE: a) b) c) d) e) In accordance with Area Injection Order No. 4, excess non-hazardous fluids resulting from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic pack upon the termina- tion of fluid disposal. Wells within 200' of the proposed well are: DS 12-8B DS 12-8 DS 12-7 DS 12-6 52' @ 1376'TVD/1378'MD 67' @ Surface 57' @ IO00'TVD/MD 181' @ Surface The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi/ft). Based upon previous logs on DS 12, no potential productive zones are anticipated above 4000'TVD. PD3/037.3 tO00 2OOO 3000 4000 5000 6OOO 7000 8000 9000 10000 11000 D8 12-~0 o ooo .ooo (' ooo ooo sooo ( ooo ooo -_ , . , , , . i i , , , . ' ' ~ ' ' ' ' ' ' I I I I [ .... ' ........... ~U- GA~IN~ -Vl~ m 7.5 12.5 ARC 3 AL ,SKA, INC. 22.:) jlOAl~ I IN m lflflD Fl. '~'~3 SHL: 3eI'FSL, e'FE[, 3 EOClVD-2611M3--2660DE, -5.. SEC: 18."10N. R15E. LM . THL: 2540' FNL. 250' F& ~L. IR.R/R" ~A~IlaR ~V~ ~ R~ Mh ~ ~R~ ~ ~ 'laN_ RI~F_ HM till PT(TO ~yERAGe ANGLE K-10 ~D - 7104 ~D - 8870 D~P - 4a78 , K-6 ~YD - 81~0 MD - 10170 DE P - 6631 _ ~U/KING~K TVO -- 8024 MO - 107ill DEP - SAG RIVER TVD - 8840 MD - 11080 OEP -(1127 0-6/8' C,'~SING TVD - 8030 MD - 11200 OEP - (~208 lOP SADLI ~ROCHIT TVD "8949 MD "" 11213 OEP" 6215 "AROET TVD -6000 MD · 11a98 DEP · 9268 . BASE $ADLEROCHI~' TVD - 9526 MD - 11985 OEP - 9724 ~/7' CSO TVD - 9604 MD - 12066 DEP "6766 i , , , , , , , , , , , , , , , , , , , . , , , , , , , , i , , , i , , , , ~ , , , , ~ , i , , , , , , , , , , , . , , , i , , , , , 8000 0 tO00 2000 3000 4000 5000 6OOO 7000 8000 go00 10000 0 1000 2000 3000 4000 5000 8000 7000 VERT I CRL SECT I ON 11000 8000 o -1000 E - M COORDINB~ES 0 1000 2000 :3000 4000 5000 6000 7000 8000 r~ 0 ~J Z -1000 0 1000 2000 3000 4000 5000 6000 7000 8000 E - N COORDINRTES DS ! 2-I E - N O00ROINB"rES o - 1000 0 1000 2000 3000 4000 5000 6000 7000 8000 O , , , i , , , i ! ' ' ' ' I I i i i i i i i i , i , i , , i · , , · , , , ! i , , , i i , , ! , i , , , i , i i i ! i i ! i , , i ! i I i i i i i t i , i $ i t : ~'-s~~ ~ -~7-~u ~' ~ ~o 77~s~6-o~~ 2-~ ~ 7 ~0~1 , ~ - : _,_~,_ , , , , , ~_, , ~ , , , , , , , , , , , , ~ , , , , ~ , , ~ ~ , , , , , , , , , ~ ~ , , ~ ~ , ~ , , , , ~ ~ , , , , , , , , , , ~ ~ , , , . , , ~ , , , ~ o 6~ I I - 1000 0 ! 000 2000 3000 4000 5000 6000 7000 8000 E - N COOROINBTES ~-~00 0 I Z 0 I I £ - W OOOROINRT£S -200 - 0 1 O0 1 300 400 ~ ' ' ' I I ~ ' ' ' ' ' ' ' ' ' ' I ~. L I I I I I , I ! I I I I .I .I I I I I I I I L I I ~ I , , , ~ , , , , ! I , - . t7~ ~~1691 ~13S5 , ~ ~R8 :,,, ~2~[~77 '" - .... ~~~1~ : ~3~ DS [2-30 II -300 -200 - 1 O0 0 1 O0 200 300 E - N O00RDIN~T~S 17 4221 Depth (TVD) Density #/gal DS 12-30 MUD PROGRAM Plas Yield Visc. Point Initial IOM FL (CP) #/100 ft2 Gel Gel CC/30M Oil Surf 8.8 Funnel to to 100- 13-3/8" 9.2 250 Csg Point 13-3/8" Csg Shoe to K-10 40-60 30+ 50+ 25 0 8.8 Minimum 2 2 5 25 to Possible to to to to 9.4 ~ 4 10 10 % Sol ids pH and Type of Mud Gel-Benex Spud Mud 3.5 to 6.5 Low sol i ds/ non-d i sper sed K-10 to TD 9-5/8" Csg Point 9.2 10 6 4 8 8 2 to to to to to to to 10.2 15 10 8 12 4 5 9-5/8" 8.8 Mi nimum 2 2 5 8 Csg Shoe to Possible to to to to to TD 9.2 4 4 10 4 4 to 8 pH 8 Low sol i ds/ non-di spersed Low solids/ non-di spersed pH 8 EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaner and centrifuges PD~/037.4 MUD SYSTEM NABORS 28E MUD CLEANER SAND TRAP 4 BBL8 TRIP TANK PIT I 171 BBL8 130 BBLS I PIT 2 PIT 3 81 BBLS 137 BBL8 I PIT 5 117 BBLS PIT 4 179 BBLS PILL PIT 20 BBLS PIT 6 135 BBLS CAVIEM SB-7 MUD CLEANERS (2 @ 750 GPM EACH) DESANDER 3 X 12" DIAMETER CONES DRILCO DEGASSER BRANDT CENTRIFUGE MUD PUMPS: 2 CONTINENTAL EMSCO FB-1600 DACRO GAS BUSTER JG 8/6/87 NABORS 28E DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL.UP LINE RISER IFLOWLINE 2000 PSI DIVERTER 10' LVE Ic°NDuCT°R NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 RESERVE PIT 10" VENT LINE ., WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. JG 8/6/87 1 5-5/8'00 PSI BOP STACK IA6RAP1 ACCUMULATOR CAPACITY TEST i 'i IANNULAR 1 l BLINDRA"S 1 ¢1 I~"~ ~F~DRI LLI NG SPOOL I PIPER~"S1 DRLG SPOOL CSG SPOOL 15-3/8" STARTING HEAD ALL BOP EC)UIPHENT 5000 PSI RATED 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. $. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TI ME AND PRESSURE REMAI NI NG AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LI HIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REP1AINING PRESSURE. 13;-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH k NON-FREEZING LIQUID. 2:. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING dOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. $. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTIONALLY TEST CHOKES. $. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF :5 MINUTES, THEN TEST AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO 3;000 PSI AND HOLD FOR A PIINIPIUM OF 3; MINUTES. BLEED PRESSURE TO ZERO. ?. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS'. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3; MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAI~I OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO SO00 PSI AND HOLD FOR AT LEAST 3; MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST 3; HINUTES. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PI PE RAMS. BACK OFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO $000 PSI FOR AT LEAST 3; 1'11NUTES. BLEED PRESSURE OFF ALL EOUIPMENT. OPEN BLIND RAI'IS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERATION OF DEGASSER. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE k WEEK AND FuNc- TIONALLY OPERATE BOPE DAILY. OS~d 11/07/88 10. 11. 12. 13;. 14. 15. 16. 17. 18. (8) ' (9 thru 1:..3)- . lo. (10 and 13) 12. 13. (i4 thru ~2)/ (23 chr'a 28) ... Geology: ' En~/~eering: / :Pc, F/,--. LCS </~.F"~z~ ~./ ~ . . Company /~-~.G~o Lease & Well No. - YES NO Is the permit fee attached .......................................... ~ 14. 15. 16. 17. 18. 19. 20. 21. '22. 2. Is well to be located in a def~-'ed pool ............................. 3. Is well located proper distance from proper=7 1/ne .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedfcated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ ?. Is operator the only a~fected party .................... i ............ 8. Can perm/t be approved before fifteen-day.wait ...................... 23. 24. 25. 26. 27. 28. 29. 30. 3I. R~t~S 32. :er: 08/11/88 i. Oli Does opera'or have a bond in force .................................. Is a conservation order needed ...................................... Is adm/nistrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ........................ Is conduc:or sir/rig provided ........................................ Will surface casing protect ail zones reasonably expected to serve as an under,round source of dr/nk/ng water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... WiLl cement cover all known productive hor/zons ..................... Will all casing give adequa:e safe~Z in collapse, tension and burst.. Is Chis well to be k/cked off from an exist/ng wellbore ............. Is old wellbore abandonment.procedure included on 10-403 ............ Is adequate weLIbore separation proposed ' .........ee................. Is a diver:er system required ....................................... Is the dr/.llfng fluid program schematic and list of equipment adequate~ Are necessary diagrams and descriptions of diver:er and ROPE attached.~ Does BOPE have sufficient pressure rating - Test to th ch k man.iX ld mply /APl 53 (Hay 84) ' Does e o e o co w RP- . ................. Is the presence of H2S gas probable ................................. exploratory' and St:rat:igraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ' INITIAL GEO. .UNIT ON/OFF POOL ~o/ro CLASS STAT~S AREA NO. SHOR~ O 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. PROGRAM: LISCAN R=VISiON: 5.1 P~gT Star+, of=~xecution: wed 11 J.AN ?.o, 10:3~,a. **** REEL LIS 88104101 ATLAS 01 H=ADER LIS CUSTOMER FORMAT TAPE' **** TAmE LIS 88/94/01 3663 01 HEADER **** 'OPE'N HOLE (RUN 1): DIFL, BHC/AL, CZO/CN/POR., CZD RAW DATA' FILE ~ 1 ****' FILE HEADER **** MAIN .001 1024 CN : ARCO ALASKA WN : D.S. 12-30 FN : ORUDHOE BAY COiJN : NORTH SLOPE STAT : ALASKA INC. FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 17 CURVES : NAME CODE I CILD 68 ? CHT 68 3 GR 6S 4 RILM 68 SAMPLE# 1 1 1 1 UNIT MMHO AP1 OHMM BYTES 4 4 5 RILD b2 1 OHMM ~ R~OC 65 1 Oi-iMM ? SP9 65 1 FT 8 TT~Ixl ,~. 1 LBS o CAL ~,S, 1 INCH 10 T r-,M P 58 1 11 SP 6~ 1 ,'~V 12 ~C 08 1 US/F 13 .~C~ ~ 1 15 T2Pl ~."3 1 US 16 TlR2 6~ 1 'JS 17 T1 R1 68 1 IJS DATA RECORD DEPTH RILD TEMP T2R1 11663.000 1,774336 173.7827 630.6875 11613.000 2.205413 173.7827 634.9375 11563.000 1.457966 173,3245 561,1875 11513.000 4.037952 173.8119 575.3750 11463.000 11.95666 173.073o 632.6250 11413.000 19.75894 172.3017 688,9375 11363.000 22.54219 171,3684 613,0000 11313.000 16.36978 170.4778 642,31,?,5 11263.000 77,71780 (TYPE# CILD RFOC SP TlR2 563,5913 5.568195 -52,08879 626.8125 453.4299 5.797800 -41.99556 625.8125 685.8872 2,024590 13.78017 560,1875 247.6485 13.63742 -28.16919 582.5625 83.03541 15.88154 -11.85984 632.3125 50.61000 18.34154 -32.60773 689,2500 44.36125 18.00063 2.914022 611.8123 61.08820 30.44536 -9.221336 643.0000 12186706 185.5628 O) 1014 BYTES CHT SPD AC TlR1 199.8863 17.99821 89.38167 452,8750 830.7576 18.39851 8q,15178 452.1875 865.3677 18.40439 76.57183 406,0000 804.4841 18.13571 77.56224 423.3750 858.4270 18.85912 84.02863 454.2500 853.8655 18.79790 98.13892 496.5625 850.5193 19.23389 83.09381 439.6250 849.5234 19,99799 89.25183 466.8750 870.2334 20.90789 GR TTEN 28.74683 3244,875 0.0000000 29.67580 5368.688 0.0000000 18.02528 5448.910 0.0000000 25181914 5369.938 0.0000000 39.91174 5438.609 0.0000000 23,69705 5404.199 0.0000000 60.84044 5346,895 0.0000000 50.32391 5423, Z38 0.0000000 96.03078 5423.074 RILM CAL T2R2 1.650093 0.0000000 451.0625 2.345944 0.0000000 457.3125 1,406163 -0.8526001 409.6875 4.531565 0.1443000 417.7500 11· 877~8~ 0.3428000 454.8750 13.81531 -1.262800 492,1250 17.53410 0.3730000 4'30.8750 18107231 0.3400000E-01 460.8125 58.37367 -1,292600 167.7349 61 .63834 501 .0625 509.5625 11213.000 77.52397 12.RO92X 14.27102 167.6665 21.70685 573.7503 ~7~.0000 11163.900 40.240C2 20.50809 0.3010675 165.0790 -~1.8S387 486.5625 438.1250 63.05392 367.2500 83~.~057 20.9~7S~ 7Q.05342 41~.9~75 82~.1794 20.~978~ ~6.11~26 330.0625 0.0000000 79.20749 5372.840 0.0000000 56.25664 ~282.074 1.000000 364.9375 1C'.93789 -0.4387~00 417.1250 10000.O0 -'3.2322000 322.2500 TOTAL OATA RECORDS : 77 STARTING TAPE DEPTH = 11663.00 ~!L~ TRAILER ENDING TAPE DEPTH 11127.00 FILE # 2 **** ~ZLE HEAD=R **** R:PEAT.O02 1024 FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE OEPTH UNIT : FT 17 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 CILD 68 1 MMHO 4 2 CHT 68 I LB 4 3 GR 68 1 API ~ 4 RILM 65 1 OHMM 4 5 RiLD 68 1 OHMM 4 6 RFOC 68 1 OHMM 4 7 SPO 68 I FT 4 $ TTEN 68 1 LBS 4 9 CAL 68 1 INCH 4 10 TEMP 63 1 DEGR 4 11 SP 68 1 MV 4 12 AC 68 1 US/F 4 13 ACQ 08 I 4 14 T2R2 68 1' US 4 15 T2R1 68 1 US 4 16 TlR2 68 I US 4 17 TlR1 68 1 US 4 * DATA P, ECORD (TYPE# O) 1014 BYTES * DEPTH CILD CHT GR RILM R!LD RFOC SPD TTEN CAL TEMP SP AC ~CQ T2R2 T2R1 TlR2 TlR1 11664.000 55,6. 5002 32P_.3193 34.76364 1.666799 1 · 70.6945 5. 537364 1 7. 99821 2¢ 27. 707 -5. 0000'31 1 78.1 ',P. 23 -7G. 1 4302 980.9177 O. 0000000 526.5025 450.81 25 626. 6253 62.5 · 8! 25 11614.,9C0 2. 072704 5.71 4375 ~ ~ '..~. 750,0 11 564. 003 595. 396: 1. ~ ? c,.-'8 ',6 '2.1 10393 1 70.. 4Z,,{ 1 -21 .2303R 570. 562c., 569.12c0 11 51z, . OCO 23'~. 4507 4.176067 11 .76793 I 76.8411 -4/` .1 425 '.'~ 576.7500 580.1 250 11464.000 .83.28204 lP_.00739 15.90921 176.20,09 -37. 96864 632. 7500 632 . 7500 11414.000 49..33127 20.27112 1~.28085 175.4127 -53.93385 689.5000 659.6875 11364.000 42.01151 23.30377 15.01688 1 74. 5660 -16. 60002 011 .0625 ~10.3125 11314.000 48.77147 20.50378 29.18831 173.299! -33.42813 642.3750 643.0625 11 264. 000 12 · 30313 81.28012 187.7947 171 .4995 32.39438 509.2500 510.3125 11214.000 77.07555 12.97428 14.53968 169.8301 -2.220670 579.3125 578.1250 :~53.1436 ~g.15091 452.7~00 S~6. 396.7 19.'-~9797 77. 9011 '~ 417.1250 843.11o9 20.25899 61.77628 423.~375 864.9463 20.9978~ 82.94244 454.1875 859.6042 20.99789 98.10497 496.4375 850.2275 21.58041 81.31917 439.3750 860.6392 21.99780 89.71266 4~8.9375 868.8Z20 22.99770 63.77628 376.5000 845.1128 23.99171 78.14232 418.0625 39.50414 5'3~3.357 O.OnO0000,., 20.44153 5473.453 0.0009000 50.63Q83 5487.2~3 0.0000000 42.62897 5489.039 0.0000000 24.58065 5478.~81 0.0000000 69.11478 5415.082 0.0000000 55.00560 5499.070 O.O000000 91.29590 5473.309 0.0000000 82.10974 5417.367 0.0000000 2.216509 -5.033001 45g.8750 . ,¢16~5 -3.2040000 411.0625 4.564196 -0.62100005-01 420.3125 11.87782 2.603900 453.3750 13.74693 -0.3292000 492.4375 17.3648~,5 1.725700 430.5000 18.1,8102 -0.5336000 462.2500 51 .39917 -0. 4997001 363.5625 10.72826 O. 21 90000E-01 417.2500 111 64. 000 49.9~136 823.1 794 60. 64841 1 0000. O0 20.31 547 O. 2981 259 23.99762 5355. 266 0.3075001 I 68.01 71 -1 06 · 0074 56 . 51 080 0 . 0000000 323 . 5625 436 . 81 25 438. 8750 329. 5625 TOTAL DAT~ ~ECORDS : STARTING TAPE DSPTH = FILE TRAILER **** 78 11664.00 ENDING TAPc DEPTH = 11120.00 FILE # 3 MAIN .003 **** FILE HEADER **** 1024 FORMAT RECORD (TYPE~t 64) ONE DEPTH m--R FRAME TAPE 'DEPTH UNIT : F! 2O CURVES : NAME COD, 1 gEV 68 2 CAL 58 3 CN ~8 4 CNC 6,5 5 GR 6 SSD 68 7 SSN 65 8 LSN 68 ~ ZCOR 68 10 ZDEN .68 11 SPD 68 12 TTEN ,68 13 ~RD1 68 14 HRD2 15 SETS 63 16 SHR 65 17 RB 63 18 CHT 68 19 PE 20 PORZ 68 E S~MPLE~ UNIT 3 1 OEG 4 1 INCH 4 I PCT. 4 1 OCT. 4 1 AP1 4 I CTS 4 I CTS 4 I CTS 4 1 GMCC 4 1 GMCC 4 1 FT 4 I LBS 4 1 CTS 4 1 CTS 4 1 CTS 4 1 DIM 4 1 DEG 4 I LB 4 I BARN 4 1 PCT 4 YTES * OAT RECORD (TYPE~ O) 1014 BYTES * 11614 24. 2.2 144 25. 11564 2t. 2.3 4.33 17. 11664 26. 2.4 156 9.1 · 000 368 . 3345 8 · 315 386 I 5 · 00000 I 9 . 00000 60918 8745.129 295 . 9705 1 05 . 9894 O. 0000000 99762 20. 03369 3052. 668 1759· 824 2226· 778 1 . 844 0 . 71 I I 741 -1 . 841 252 -1 34. 5936 3 . 000000 05337 · GO0 368 . 3345 8. 740259 1 9.90181 2.3 . 901 81 89911 8437.445 279.5~Z3 1 02. 2459 -0. 79361 5 4E-02 24584 22. 99770 5708..441 I 598. 508 1 879.5 65 2. 161 O. 7824761 -1 · 841 25 2 8Q4.1 091 I . 6604 26 7~279 · 000 368. 3345 8.791 273 1 9. 87024 23. 87024 86043 64,]9. 230 302. 3855 11 ,B. 31 08 -0.71 8106 3 E-02 68027 22. 99770 57'9,8. 887 620.7854 777. 193L;:', · 38.40 0·4886181 -1. 841 252 985.o631 1. 96755 6 0892? DEPTH DEV C~L CN CNC GR SSO SSN LSN ZCOR ZDEN SPD TTEN HRD1 HRD2 SFTS SHR RB CHT PE PORZ 11514.000 3,58.33~5 ,3.73,5'462 2C'. ,50516 24.6051 6 6.~..5921 ~ 5394. 753 273.70z, 8 90.71 452 -0. 5374984E-0! 2' .433026 22 .'~70c0 5648.31 3 653. 7344 556. 7488 50,0.95'.'~3 3.4o750,21 -1 .$wl ,~2 ~31 .'~41g 3.214688 13.1499,,0 11 4~4. SCO 36.3.3~x45 ~. 055769 ZO. 1 ,5759 2~. 1 x759 3~. 4Cl 5 ~ ~45. ~5 ~.~7.6 52~ ~. 641 I 0 -0.1 7Ol ~3 9E-01 2.3~1 ~'77 23. ,3275,] 5~.15. I 05 1 5~8.057 I QAO. 931 1421.793 0.~27~440 -1. ?~1252 914.7532 2. 15.a8~22 11 ~14. OOO 368. 3345 ~,. ~44~31 ~2. 6060~' 2~. 60600 23.1 5~43 8370. 363 ~_6~.635£. ~9. 98751 -0. 1465754E-~1 2.1 65401 22. 99770 5703.0vA 1 630.51 2 1 99,5.463 1~66.175 0.7406932 -1. ~41~_52 911 .942/` 1.915756 29.36966 11 364. 000 368. 3345 8. $46027 2C.4694~ 24. 46948 71 . 66461 7'744 . 227 272.78 20 -?4.55522 -0.5 ~1 2086E-02 2.338~02 22.99770 5605.301 1321.720 1628.636 I 1 87. ~4'P 0.7091 889 -0. 849079.8 869.3~23 3.08~201 18.85439 11 31 4. 000 368. 3345 8. 845003 1 9. 45273 23. 45273 55.89481 7300.680 260. 5828 83.991 52 -0.3610501 E-01 2. 20081 0 23. 99762 5 601 . 297 11 95.1 22 1 481 . 41 6 1 074 . 606 O. 6750,'542 O. 8802595 859.0O,96 1 . 6381 47 ,2.7.22359 11 264. 000 368 . 3345 8. 844231 8. 85411 8 1 2 , 85412 96.41 597 6238.91 8 374. ~565 21 5.91 54 -0.1 788471 E-01 2. 569427 23. 99762 5545. 121 599.8623 830. 1462 472.6863 0.4798660 1.735128 831.0579 4.446939 4.88321,,3 11214.000 3,58.3345 9.086992 24.89804 28. ~9804 98. 09895 7503. 563 255. 7504 86. 52911 -0. 9384358E-01 2.4690P0 23. 99762 5470. 625 1099.1 22 1 356.675 922. 0286 O. 6436870 2. 604724 773. 5293 3. 268332 10.96420 I 11,64. 000 367 . 5562 8. 950001 59.5.0680 63 . 596,~0 59.93! 24 2708. 729 1 38.9861 24.9(~751 -0. 7521 775 1 .93451 8 23 . 99762 555~. 445 511 . 9490 736. 9263 274. 9727 O. 1 999798 3. 282P_3.4 867. 8782 1 4. ,44371 43.36253 TOTAL DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 8,5 11664.00 ENDING TAPE DEPTH = 11152.00 FILE ~ 4 REPEAT.O04 **** FILE HEADER **** 1024 FORMAT ONE PEP ;i ECORD ( T Y P,'-' ~' 6/,) TH PER FRAM-T_ TAP= DEPTH UNIT : :T 20 CURVES : NAME COD ! DEV ~& 2 CAL 6~ 3 CN 6 ~ ~ CNC 6 ~ · ,~ ? SSN ~g 8 LSN 68 ~ ZCOR 53 10 ZDEN 6~ 11 SPD 08 12 TTEN 68 13 HRD1 ~S 14 HR~2 68 15 SFT$ 68 16 SHR 68 17 RB 58 18 CHT ~,8 19 PE 68 20 PORZ 68 - ~ UNIT ~ SANPLE.v 1 BEG 1 INCH 1 PCT. 1 PCT. I AP! 1 CTS 1 CTS 1 CTS 1 GMCC 1 GMCC 1 FT 1 L~S I CTS 1 CTS 1 CTS 1 9IM 1 DEG 1 LB I B~RN I PCT * DATA RECORO (TYPE# O) 1014 BYTES · 11 664. 000 358 . 3345 8 · 30961 6 15 · 00000 1 9. 00000 28,55623 9000,102 292,9707 I 22,9877 0.0000000 2.500069 I 8.99809 2~91 . I 11 1803.820 2202.780 1542.846 0,7299P_71 -1 .841252 233.4610 3.000000 9.087146 11 639. 000 368.3435 8 · 320415 1 7.88660 21 · 88660 28 · 55623 8675.91C 288.51 49 11 4.7378 O. 1 21 7797E-01 2 . 1 74461 20.9'~'789 5341 ,457 1 841 . 097 21 94. 432 I 662 . 349 0 . 7737492 -1 . 849830 734.7026 2.1 85448 28.82051 1 I 61 4. 030 368 . 3345 3. 839233 20. 77576 24. 77576 23. 99246 8241 . 473 267.81 8,.6 98.1 0020 -0. 10825 36E-01 2,220411 22 . 40990 5615 , 31 3 1 585. 233 1 887. 104 1395.071 0.7200749 -1 .841252 944.8611 1,872,.873 26.03566 11 589.000 :368. 3367 8.838B42 1 8 · 54773 22.5,4773 2.3 . 87714 8235 . 789 297,7,881 1 22,0683 -0.411 2832E-02 2,244368 23. 99762 5744,633 I 455,389 1 741 . 5 32 1321.14'8 O,,,,P.,.O61Q~2 -1,8~1252 966.0242 1.:'!00333 24,58376 11564.000 36~. 3345 ~, 00~754 1 e. 1 ~- 6'38 22. I 260,5 27. ~695~ .5530,461 303. 5840 I 25,5 282 -0.188655CE-01 DEPTH DEV CAL CN CNC GR SS3 SSN LSN ZCOR ZDEN SPD TTEN HRD1 HRD2 SFTS SHR RB CHT PE PORZ 2.322824 5!7.2575 115 '~ ~..,'2,?.0 2. '2 '.~ 7077 1S2.5.d'1 2!.99'5.'32 11 .51 ¢. 59.671}? £. 41.~',~11 4S2.2163 14.00537 11489.000 23.79198 2.383717 489.179~ 16.13837 11464.000 34.66571 2.368464 1383.8~5 17.06279 11439.000 33.53067 2.21 932,8 1137.343 26.10132 11414.000 24.088~7 2.163800 1488.632_ 29.46663 11 389. 000 32.65573 2.286922' 1243.204 2~ .00468 11364.000 71.16154 2.349238 1139.407 1 8. 22797 11339.000 2:3.04994 2.239263 1227.202 24.89316 1131C.000 58.77625 2.209852 1~05.094 26.67561 1 I 289. 000 119.9501 . [.' ~. 1 ,F.~ 51 2 0.49406~0 3,.-,~ . 3345 ~';3 ~3.7'33 7'4 · '::. ~ z. 21 '3.737~061 62! '~. 533 23.9'~76., 2 0 ~,'-,. 056 C,''~ m ,.. 368.3345 7142.734 24.56151 0.4122131 368.3345 8262.164 ~3.99762 0.~011570 368.3345 7706.156 24.20372 0.7212309 3,68. 3345 ,~J 4. 71.191 24.15991 0.7517571 368.3345 8087.832 24.23341 0.7803960 368.3345 7715.422 24.59131 0.6794311 368.3345 7952.098 25.49710 0.747523~ 36~.3345 7679.332 24.99751 0.6694442 368.33&$ 6638.891 ... 5 ¢'; ~¢ ?' · 1 95 - 1 . :341 ,.~52 C.,J49,522 55~9.,537 -1.~412~2 8.~33c~1 267.3496 -1.~4125R 8.838461 272.9121 5523.605 -1. ~41~52 9.1 55767 271 .4502 5497.406 -1 .841252 9.050003 293.7852 556~.910 -1.841252 9.07,3190 ,2.65.9519 '5537.598 -1 .841303 8.~53230 259.0146 5561.246 -1.841252 8.944229 276.2666 5460.813 -1.841~52 8.944~29 275.2935 5517.746 -1.841252 8.933430 261.2290 5430.605 -1.841252 8.944229 337.6'394 967.94R5 22.07153 ~7.46461 16~2.036 ~35.5125 22.81091 8e.53300 632.0508 919.8o09 22.e151R 97.03464 627.3882 '~37.2583 21 .40184 103.3~94 1524.307 904.5[~,01 21 .56993 115.2110 1305.325 924.1475 25.59358 89.81642 1658.772 884.8406 24.27245 8[f.21341 1397.188 888.5149 23.94374 98.54329 1331.163 886.7136 22.30356 100.2182 1474.078 894.8335 20.39355 92.70950 1330.914 883.3843 12.'~0041 141 .2669 ~94.5349 2.25137~ ~6.07153 '.~.1 ::~33100E-~ 1 1~89.705 2.054230 26. S10,~1 -0.4762520E-01 827.6228 3.313288 26.9151~. -0. 2880637E-01 ,o, 0.~. 1143 3.82436a 25.40184 -0.1189064E-01 1919.020 2.766572 25. 56993 -0.1439226E-01 1582.215 2.117136 29.593,58 -0.'1 5391 96 E-01 1 969.281 1 .769633 28.27245 -0. 1953256E-01 1661.113 ?..125589 2,.7.94374 -0. 767441 1 E-02 1 6,45. 600 2.489575 26.30356 -0.5287895E-01 1740.812 2.335212 24.39355 -0.2912425E-01 1666.966 1.773031 16.80042 -0. 3537001E-01 · 1!26 o3 2. 5O 3. 112 2 2 1 O. 112 1 2 -1 111 1 2 1 1 111 5 1 2 4 S70632 25,12410 9,4316 0,5081"3.03 810163 560~ .395 -1 ..S41 252 74~.7085 .g,?: 1 . 2939 .~.".R. 2.430 4 3.95725~ ,,: 4 000 368 ~z45 3 944-~pe 10.1926= · '-' ......... 14.19265 .01102 ~21 4. 695 ~70. 222,? 1 ~6.381 8 O. 8341 974=-02 59629~ 24. 99751 ~510.555 ~1~.3201 821 .9211 4.4761 0.~507150 -1 .3364~5 ~.51.2944 4.176671 254920 39. OOO 363.3~45 9. 1202o5 27.51 7.~5 31.51785 2_2.2~31 454o.555 331 .6572 155.7130 -0.1832~02~-01 · 63307,3 24. 99751 55 44.4F_'2 247. 571 4 390. 8090 °.,3. 2344 O. 3708371 -0 . ?,530307 866. 9414 ~ .81 3653 ~696°29 22.23290 89.03799 1052.586 767.7783 14.000 368.3435 9.261539 19.8543 7551.355 25~.3500 · ~25195 24.9~751 5373.1~5 99.7529 0.6249391 0.6736571E-01 0.61798 26.23~_96 0.1493637E-01 1305.336 6.125993 89 . 000 368 . 3545 9 . I 55767 4 S . 1 31 96 52 . 1 31 96 1 6 . I 777 23..R O. 720 1 33. 5085 25 . 37331 -0 . 77602o. 7 .323459 24.99751 5536. 969 344. 4932 572.2493 82.5586 O. 1 948931 O. 904 31 37 B.. 52.0~89 1 7. 26381 9.7'9036 64.000 368.3345 9.155767 53.22989 57.22989 9.94542 2642.735 146.9853 26.99730 -0.7585568 · 953856 24.99751 5550.445 479.9521 697.9302 78.9722 0.1699~31 1.075017 834.4912 12.62951 2.19057 TOTAL DATA RECORDS STARTING TAPE DEPTH FILE TRAILER **** : 171 = 11664.00 ENDING TAPE DEPTH 11152.00 **** TAPE LIS 88/04/01 3663 01 TRAILER **** TOTAL RECORDS IN THIS LOGICAL TAPE : 430 **** REEL TRAILER LIS 88/04/el ATLAS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 431 TOTAL RECORDS IN THIS PHYSICAL REEL: 431 End of execution: Wed 11 JAN .g9 10:4Cla Elaps,gcl exec:ation tim.~ = 1 minut~ , 49.0 seconcls. ,$YSTEi, i RET!J~.N CODE = 0
