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185-283
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-15 KUPARUK RIV UNIT 3A-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3A-15 50-029-21491-00-00 185-283-0 W SPT 5903 1852830 1500 2875 2875 2875 2875 20 130 130 130 4YRTST P Austin McLeod 8/4/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3A-15 Inspection Date: Tubing OA Packer Depth 120 2000 1890 1860IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250804190921 BBL Pumped:2.6 BBL Returned:2.4 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 9 999 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:34:36 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2V-04 50-029-21041-00 183165_2V-04_LDL_31May2023 2V-11 50-029-21311-00 185049_2V-11_Patch_13Jul2022 185049_2V-11_PPROF_28Jun2023 2W-14 50-029-21253-00 184237_2W-14_Patch_21Jun22 2W-16 50-029-21255-00 184239_2W-16_IPROF_12May2023 2X-13 50-029-21197-00 184174_2X-13_PPROF_04Jul2023 2X-18 50-029-22608-00 195160_2X-18_Patch_02Jan2023 3A-15 50-029-21491-00 185283_3A-15_IPROF_17Jan2023 3B-12 50-029-21370-00 185116_3B-12_WFL_30Mar2023 3B-13 50-029-21286-00 185023_3B-13_RCT_02Oct2022 3B-14 50-029-21287-00 185024_3B-14_SCMT_23Jun22 3G-02 50-103-20146-00 190137_3G-02_GR-CCL_02Feb2022 3G-08 50-103-20128-00 190065_3G-08_RPB_25Mar2023 8 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38383 T38384 T38385 T38386 T38387 T38388 T38389 T38390 T38391 T38392 T38393 T38394 2/29/2024 3A-15 50-029-21491-00 185283_3A-15_IPROF_17Jan2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:01:58 -09'00' MEMORANDUM TO: Jim Regg�p/ P.I. Supervisor " �(� (2�L FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3A-15 Insp Num: mitBDB210825103615 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 26, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3A-15 KUPARUK RIV UNIT 3A-15 Sre: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-21491-00-00 Inspector Name: Brian Bixby Permit Number: 185-283-0 Inspection Date: 8/24/2021 Thursday, August 26, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-15 Type Inj w -'TVD 5903 Tubing 2880 _ 2880 - 2880 2880 - PTD 1852830 Type Test SPT'Test psi 1500 IA 450 1990 1900 1880 - 13BL Pumped: 2 BBL Returned: 2 OA 80 - 250 250 - 250 - Interval 4vRTST �- p/F P ✓ Notes: Thursday, August 26, 2021 Page 1 of 1 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3A-15 Run Date: 9/3/2019 18 52 83 3 136 4 October 17, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3A-15 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21491-00 RECEIVED OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@�halliburton.com Date: 1 V rjCq Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing E] Change Approved -Program ❑ Plug for Redrill ❑ •erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: SH repair 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service 0 185-283 3. Address: P. 0. BOX 100360, Anchorage, Alaska 6. API Number: 99510 5002921490000 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025631 KRU 3A-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NA Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,160 feet Plugs measured None feet true vertical 6,341 feet Junk measured None feet Effective Depth measured 7,988 feet Packer measured 7514, 7537, 7771 feet true vertical 6,223 feet true vertical 5903, 5918, 6076 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 feet 16" 104' MD SURFACE 3,651 feet 9 5/8" 3,681' MD PRODUCTION 8,121 feet 7" 8,151' MD JEWELERYTYPE Measured depth feet Tubing (size, grade, measured and true vertical depth) 2.7/8" J-55 7,791' MD 6,089' TVD Packers and SSSV (type, measured and true vertical depth) CAMCO HRP-1SP RETRIEVABLE PACKER 7,514' MD 5,903' TVD BAKER HB PACKER 7,537' MD 5,918' TVD BAKER 1 B PERMANENT PACKER 7,771' MD 6,076' TVD OTIS FMX SEREIS 10 SAFETY VALVE 1,830' MD 1753 TVD 12. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA INA NA INA Subsequent to operation: NA NA INA INA INA 14. Attachments (required per 20 n C 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations D Exploratory ❑ Development ❑ Service 121 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status afterwork: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 2 GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Well Integrity Contact Email: N1927@conocoohillios.coln �ty Authorized Title: g Field Supervisor Contact Phone: 907-659-7506 Authorized Signature: Date: 9/22/19 Form 10-404 Revised 4/2017 VTL 1,1113 1,I4V I O//V,//I )BDMS SFP 2 5 2019 submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 22, 2019 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the Braiden head repair KRU 3A-15 (PTD 185-383). Please contact Roger Mouser or me at 659-7506 if you have any questions. Sine rely �'v vim'✓�, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. 3A-15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/091191 Prep BH for repairs 09117/191 Purge OA with N2 - bring Braiden head up to temp and seal weld. 09/20/19 1 Norm up jewelry and MITOA to 1800 psi (passed). i :! _ � 1 This Photog gh is prow` �--. :�Wrmi§don:tu copy for its for arty other purpose or 6y any Prohibited, without the express c ConocoPlullips Alaska, Inc." Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Monday, July 15, 2019 1:02 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 3A-15 (PTD 185-283) Bradenhead Dampness Attachments: 3A-15 MIT -OA 10-426 Form 7.13.19.xlsx Hi Chris, I just started writing my reply to update you on the status of KRU injector 3A-15 (PTD 185-283) when I realized that I only sent the notification to our Wells Superintendent and left you off as a recipient of the message. I apologize for my mistake! Please see below for my message that was originally intended for you on 7/12/19. On 7/13/19 DHD performed passing positive and negative inner casing packoff tests, torqued the inner casing gland nuts and lock down screws, then performed an MIT -OA to 1800 psi. The MIT -OA (see attached form with test results) passed pressure testing criteria, but fluid wept from the bradenhead connection while testing. As a result, CPAI plans to progress a bradenhead weld repair and will submit appropriate sundry documentation when the repair is complete. We intend to leave the well on water injection while we progress the weld package and prove -up barriers for the welding work. Please let me know if you have any questions or disagree with the plan forward. Sincerely, SarwCa CA& (HeA;w) /tache lKa.utk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisleCalcop.com From: Well Integrity Compliance Specialist WNS & CPF3 Se riday, July 12, 2019 7:07 PM To: CPA We <n1030@conocophillips.com> Subject: KRU 3A-15 (P 283) Bradenhead Dampness Hi Chris, KRU injector 3A-15 (PTD 185-283) had external dam pness>oWd yesterday at the bradenhead (connection between the surface casing and wellhead). The well integrity team cleaned andlibspizcted the area today. We intend to perform diagnostics including a MIT -OA and will monitor the well to understand if i ' residual stain, or in need of repair. If an issue is identified, we will follow up with you on the plan forward, otherwise we w ntinue to treat the well as a normal injector. Sincerely, , STATE OF ALAS ALASSOILAND GAS CONSERVATION COMMIS RECEIVED N REPORT OF SUNDRY WELL OPERATIONS NOV 0 9 2017 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate El Pull Tubing❑ Operations shutdown ❑ Performed: Suspend El Perforate ❑ Other Stimulate ❑ Alter Casing❑ CharAGGIGen ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: DAD Acid Stimulation 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConoCOPhillips Alaska, Inc. Development❑ ' Exploratory❑ 185-283 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-21491-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3A-15 ADL 25631 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8,160 feet Plugs measured None feet true vertical 6,341 feet Junk measured None feet Effective Depth measufed 8,063 feet Packer measured 7514, 7537, 7771 feet true vertical 6,274 feet true vertical 5903, 5918, 6076 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 73 feet 16 " 104' MD SURFACE 3,651 feet 9 5/8 " 3,681'MD PRODUCTION 8,121 feet 7 " 8,151'MD Perforation depth Measured depth 7694-7730,7834-7852,7864-7908,7922-7952 feet � ���® � 2017 True Vertical depth 6023-6048,6118-6130,6138-6168,6178-6198 feet Tubing(size,grade,measured and true vertical depth) 2.9" J-55 7,791'MD 6,089'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-CAMCO HRP-ISP RETRIE\i 7,514' MD 5,903'TVD PACKER- BAKER HB PACKER 7,537'MD 5,918'TVD PACKER- BAKER 1B PERMANENT P/ 7,771' MD 6,076'TVD SAFETY VLV-OTIS FMX SEREIS 10 5 1,830' MD 1,735'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A 1630 150 2828 Subsequent to operation: N/A N/A 2087 150 2820 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-263 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells Engineer �\ �Ark\s_�� P J `' ' L Contact Phone: (907)265-6097 Authorized Signature:\ �, ��L1h t Date: �� 7 Form 10-404 Revised 4/2 7 id-1 /2!71/9- 4{ /-/�I (yfy�9 RE Di S L�e, j — 9 Le iubmit Original Only ///!!! / �i Li i 4�3 Y t3 • • 3A-15 DAD ACID STIMULATION DTTMST,JOBTYP SUMMARYOPS 10/8/17 ACID ATTEMPT TO PRIME PUMP FOR PRESSURE TEST, UNABLE TO PRIME PUMP. HIGH VISCOSITY GELLED PLUG FOUND IN SLICK DIESEL SUPPLY HOSE. ATTEMPT TO BLOW HOSE BACK TO TRANSPORT, 2 ATTEMPTS NEEDED TO VOID HOSE OF GELL PLUG. PUMP TO TANK TO CLEAR PUMP AND LINES. CALL/WAIT FOR FRESH SLICK DIESEL TRANSPORT. FRESH SLICK DIESEL TRANSPORT ON LOCATION. PRESS TEST= 300, BOWEN 0-RING LEAK @ STUFFING BOX, REPLACE 0-RING. REPEAT PRESS TEST = 844/4460-GOOD TEST CONTINUE RIH. START PUMPING DAD ACID TO LOAD CT, 0.8 BPM@ 4400 PSI CHOKE OPEN WHP = 925 PSI. PUW @ 4100' = 5.7K, PUW @ 6550' = 9.7K„ PUW @ 7200' = 12K, PUW @ 7600' = 15.5K, PUW @ 7820' = 15K..TIH TO 7960' 100 BBL DAD AWAY, PUMP 5 BBL H2O SPACER, DISPLACE CT WITH 32.5 BBL SLICK DIESEL.. STOP PUMPING. i KUP I 3A-15 ConocoPhillips a Well Attributes . Max Angle& .. TD Al 19/4 R,I3'{; Wellbore API/UWI Field Name Wellbore Status incl C) MD(ftKB) Act Btm(ftKB) Gorlocoehghpz 500292149100 KUPARUK RIVER UNIT INJ 48.74 7,500.00 8,160.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-15,11/7/20171130:00 AM SSSV:TRDP Last WO: 8/19/1991 3540 12/18/1985 Vertical schemaeo(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,005.0 8/7/2009 Rev Reason:DRILL DATES/PROD CSG RKB osborl 10/15/2012 HANGER;22.1 .m.� _arm Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)... Wt/Len g...Grade Top Thread CONDUCTOR 16 15.062 31.0 104.0 104.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 30.6 3,681.1 3,147.4 36.00 J-55 BTC `jj '� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len g...Grade Top Thread I [i PRODUCTION 7 6.276 30.0 8,151.3 6,335.3 26.00 J-55 BTC PONIPIVIII C� " Tubing Strings ^11-. Tubing Description String Ma... ID(in) Top(kKB) Set Depth(ft..I Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection CONDUCTOR,31.0-104.0 ► TUBING 2 7/8 2.441 22.1 7,525.5 5,910.6 6.50 J-55 EUE AB-MOD Completion Details Nominal ID Top(MB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) SAFETY VLV;1,829.7 22.1 22.1 0.07 HANGER FMC GEN III TUBING HANGER 2.875 I 1,829.7 1,753.5 33.90 SAFETY VLV OTIS FMX SEREIS 10 SAFETY VALVE 2.313 7,497.5 5,892.2 48.74 SBR CAMCO OEJ SBR 2.313 I 7,514.0 5,903.1 48.66 PACKER CAMCO HRP-1SP RETRIEVABLE PACKER 2.347 • • 7,522.9 5,908.9 48.61 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 2.347 Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING Original 27/8 2.441 7,525.5 7,791.8 6,089.6 6.50 J-55 EUE 8RD Completion Details SURFACE.306368`1 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) 7,525.5 5,910.6 48.60 PBR BAKER PBR 2.890 I 7,537.1 5,918.4 48.53 PACKER BAKER HB PACKER 2.890 GAS LIFT,744621 7,681.8 6,015.1 47.48 BLAST RICKERT BLAST RINGS(2) 2.441 RINGS 7,769.7 6,074.6 47.36 LOCATOR BAKER LOCATOR SUB 2.441 7,771.1 6,075.6 47.36 PACKER BAKER 18 PERMANENT PACKER 2.347 it 7,783.4 6,083.9 47.37 NIPPLE CAMCO D NIPPLE NO GO 2.250 SBR;7,497.5 I 7,790.9 6,089.0 47.37 SOS BAKER SHEAR OUT SUB 2.441 PACKER;7,514.0 Perforations&Slots • SEAL ASSY;7,522.9 Shot Den Top(TVD) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (kKB) (ftKB) Zone Date ft) Type , I 7,694.0 7,730.0 6,023.3 6,047.7 C-4,C-3,C-1, 1/14/1986 12.0 IPERF X90 deg.phasing;5"Csg PBR;7,5255 __..) UNIT B,3A- Gun 15 PACKER;7,537.1 .,�u_• 7,834.0 7,852.0 6,118.2 6,130.4 A-3,3A-15 1/14/1986 4.0 (PERF 90 deg.phasing;4"Csg T. Gun 7,864.0 7,908.0 6,138.5 6,168.5 A-2,3A-15 1/14/1986 4.0 IPERF 90 deg.phasing;4"Csg INJECTION;7,575.1L. Gun 7,922.0 7,952.0 6,178.0 6,198.5 A-1,3A-15 1/14/1986 4.0 IPERF 90 deg.phasing;4"Csg Gun INJECTION;7,043.9 Mandrel Inserts I St 0-e on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com IPERF;7,894.0-7,730.0 ( 1 7,446.2 5,858.3 MERLA TGPD 1 1/2 GAS LIFT DMY TG 0.000 0.0 9/6/1991 2 7,575.1 5,943.6 MERLA TMPD 1 INJ HFCV BTM 0.000 0.0 9/16/2009 I 3 7,643.9 5,989.5 MERLA TMPD 1 INJ DMY BK 0.000 0.0 8/19/1991 4 7,752.9 6,063.3 MERLA TMPD 1 INJ DMY BTM 0.000 0.0 9/29/2008 INJECTION;7,752.9 Notes:General&Safety End Date Annotation I 3/10/1997 NOTE:Suspect LEAK between 7500"8 7516"(See WSR 3/10/97) 9/16/2009 NOTE:UNABLE TO LATCH DMY @ 7644'DUE TO PRESENCE OF JUNK t 118/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;7,789.7 y u.. PACKER;7,771.1 rr I ; NIPPLE;7,783.4 I SOS;7,790.9 ila (PERF;7,834.0-7,852.0 (PERF;7,884.0-7,908.0 (PERF;7,822.0-7,952.0-- . PRODUCTION;30.08,151.3 • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 10,2017 TO: Jim Regg P.I.Supervisor ( 13(71, 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3A-15 FROM: Chuck Scheve KUPARUK RIV UNIT 3A-15 Petroleum Inspector SCANNED =RR, Src: Inspector Reviewed B, P.I.Supry —I 1t512— NON-CONFIDENTIAL Comm Well Name KUPARUK RN UNIT 3A-15 API Well Number 50-029-21491-00-00 Inspector Name: Chuck Scheve Permit Number: 185-283-0 Inspection Date: 8/3/2017 , Insp Num: mitCS170806082923 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-15 ` Type Inj W •TVD 5903 Tubing 2880 2880 2880 - 2880 - PTD I 1852830 (Type Test SPT Test psi 1500 - IA 910 2000 • 1910 • 1900 - BBL Pumped: 1.3 BBL Returned: 1,2 - OA loo • 120 120 - 120 Interval 4YRTST P/F P Notes: Thursday,August 10,2017 Page 1 of 1 • •oF • 4 4'*A. THE STATE Alaska Oil and Gas �►'i���, o ALA S KA. Conservation Commission }#_= 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAr��� Fax: 907.276.7542 www.aogcc.alaska.gov Jason BurkeF Iti101 . .�Cl 7 Staff Wells Engineer scoop ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3A-15 Permit to Drill Number: 185-283 Sundry Number: 317-263 Dear Mr. Burke: 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, Daniel T. Seamount, Jr. Commissioner DATED this Z d' ay of June, 2017. RBDMS LI— JUN 2 7 2017 • • RECEIVED STATE OF ALASKAJiJ 201.1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A OGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate Pull Tubing ❑ Change Approyed Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing ❑ Other: Acid Stimulate 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 185-283 ` 3.Address: Stratigraphic ❑ Service 0 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21491-00- 7.If perforating: 8.Well Name and Number: L What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 3A-15 `/7c, (4, 7 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25631' Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 8,160' . 6,341' • 8063 6274 2976psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 73' 16" 104' 104' Surface 3,651' 12" 3,681' 3,147' Intermediate Production 8,121' 7" 8,151' 6,335' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7694-7730,7834-7852 6023-6048,6118-6130 2.875" J-55 7,792' 7864-7908,7922-7952 6138-6168,6178-6198 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-CAMCO HRP-1SP RETRIEVABLE PACKER MD=7514 TVD=5903 PACKER-BAKER HB PACKER MD=7537 TVD=5918 PACKER-BAKER 1B PERMANENT PACKER MD=7771 TVD=6076 SAFETY VLV-OTIS FMX SEREIS 10 SAFETY VALVE MD=1830 TVD=1754 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0• 14.Estimated Date for 7/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com Contact Phone: (907)265-6097 Authorized Signature: ____. Date: `� I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3I7— Z(4, 3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ F- (011.61k4 Other: Post Initial Injection MIT Req'd? Yes 0 No I<J Spacing Exception Required? Yes ❑ No IY1 Subsequent Form Required: /Q 404- RBDMS t`- JUN 2 7 2017 APPROVED BY Approved b COMMISSIONER / THE COMMISSION Date: 6,`A6 l 0 ❑ j1Vd4IA.cILI / L�`Z`4Submit Form and Form 10-403 Revised 4/2017 Rvalid for 12 months from the date of approval. attachments in Duplicate • • • ConocoPhillips Alaska,Inc. ry Drilling&Wells ConocoPhillips Well Intervention Alaska 3A-15 Acid Treatment (TBD) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with • dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble v minerals and remove oil paraffinic deposits. Target areas can be tubulars,perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations . ✓ to increase injectivity • Coiled Tubing: Spot 100 bbl of DAD into formation 1. MIRU 1.5" CT, MU 5 port wash nozzle BHA 2. Begin RIH down to 7960' MD. 3. When CT has reached depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH to 7790'. Continue injecting DAD into formation and it out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 4. After an additional 5 bbl of fluid has been injected behind the treatment POOH 5. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HCl H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal June 7,2017 3A-15 Well Work Procedure Page 1 of 1 KUP 3A-15 ConocoPhillips "e•ft.4 WellAttribut MaxAngl -_ . D TD • Wellbore API/UWI Field Name Wellbore Status incl(°) MD(kKB) Act Btm(ftKB) AdSkd'InC. CoewcpMlillips 500292149100 KUPARUK RIVER UNIT INJ 48.74 7,500.00 8,160.0 ' ... Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3A-15,6/13120173:40:41 PM SSSV:TRDP Last WO: 8/19/1991 35.40 12/18/1985 Veronal schematic(actual) Annotation •Depth(kKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,005.0 8/7/2009 Rev Reason:DRILL DATES/PROD CSG RKB osborl 1005/2012 HANGER;22.1 ��� ® ,__ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread • • CONDUCTOR 16 15.062 31.0 104.0 104.0 62.58 H-40 WELDED • • Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread SURFACE 95/8 8.921 30.6 3,681.1 3,147.4 36.00 J-55 BTC 11. '� Casing Description 'OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade 'Top Thread [� PRODUCTION 7 6276 30.0 8,151.3 6,335.3 26.00 J-55 BTC .U•Lea.Tubing Strings Tubing Description String Ma...ID(in) Top(kKB) Set Depth(ft..I Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection CONDUCTOR;31.0-104.0 ; TUBING 27/8 2.441 22.1 7,525.5 5,910.6 6.50 J-55 EUE AB-MOD • • Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 0 Item Des Com (in) SAFETYVLV:1,829.7 ' 7.•I:: 22.1 22.1 0.07'HANGER FMC GEN III TUBING HANGER 2.875 I 1,829.7 1,753.5 33.90 SAFETY VLV 'OTIS FMX SEREIS 10 SAFETY VALVE 2.313 7,497.5 5,892.2 48.74 SBRCAMCO OEJ SBR 2.313 I 7,514.0 5,903.1 48.66 PACKER CAMCO HRP-ISP RETRIEVABLE PACKER 2.347 7,522.9 5,908.9 48.61 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY • 2.347 : • Tubing Description String Ma...ID(in) Top(kKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING Original 2 7/8 2.441 7,525.5 7,791.8 6,089.6 6.50 J-55 EUE 8RD Completion Details • SURFACE,30.6-3,681.1-. Nominal ID Top(81KB) Top(ND)(MB) Top Incl(°) Item Des Com (in) 7,525.5 5,910.6 48.60 PBR BAKER PBR 2.890 I 7,537.1 5,918.4 48.53 PACKER BAKER HB PACKER ' 2.890 GAS LIFT,74412III 7,681.8 6,015.1 47.48 BLAST RICKERT BLAST RINGS(2) ' 2.441 III RINGS 7,769.7 6,074.6 47.36 LOCATOR BAKER LOCATOR SUB ' 2.441 II7,771.1 6,075.6 47.36 PACKER BAKER 1B PERMANENT PACKER 2.347 II7,783.4 6,083.9 47.37 NIPPLE CAMCO D NIPPLE NO GO ' 2.250 009;7,497.5 1 7,790.9 6,089.0 47.37 SOS BAKER SHEAR OUT SUB 2.441 PACKER;7,514.0 1'-` Perforations&Slots teShot SEAL ASSY;7,522.9 Dens Top(TVD) Btm(ND) (shots/ Top(kKB) Btm(kKB) (ftKB) (kKB) Zone Date ft) Type Com 7,694.0 7,730.0 6,023.3 6,047.7'C-4,C-3,C-1, 1/14/1986 12.0 IPERF 90 deg.phasing;5"Csg PBR;7,525.5 = UNIT B,3A- 15 Gun PACKER;7,537.1 7,834.0 7,852.0 6,118.2 6,130.4 A-3,3A-15 1/14/1986 ' 4.0 (PERF '90 deg.phasing;4"Csg Gun • 7,864.0 7,908.0 6,138.5 6,168.5'A-2,3A-15 '1/14/1986 ' 4.0 IPERF '90 deg.phasing;4"Csg INJECTION;7,575.1 i Gun 7,922.0 7,952.0 6,178.0' 6,198.5 A-1,3A-15 1/14/1986 4.0 (PERF '90 deg.phasing;4"Csg Gun INJECTION;7,643.9 Mandrel Inserts St ' • ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com IPERF;7,694.0-7,730.0-.1 1 7446.2 5,858.3 MERLA TGPD ' 11/2 GAS LIFT DMY TG 0.000 0.0 9/6/1991 ( 2 7,575.1 5,943.6 MERLA TMPD 1 INJ HFCV BTM 0.000 0.0 9/16/2009 3 7.643.9 5,989.5 MERLA TMPD 1 INJ DMY BK 0.000 0.0 8/19/1991 4 7.752.9 6,063.3 MERLA •TMPD • 1 INJ DMY BTM 0.000 0.0•9/29/2008 INJECTION;7,7529 Notes:General&Safety End Date Annotation 3/10/1997 NOTE:Suspect LEAK between 7500"8 7516"(See WSR 3/10/97) Ij 9/16/2009 NOTE:UNABLE TO LATCH DMY @ 7644'DUE TO PRESENCE OF JUNK 11/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;7,789.7 PACKER;7,771.1 NIPPLE;7,783.4 SOS;7,790.9 (PERF;7,834.0-7,852.0 (PERF;7,864.0-7,908.0 44- 4 /PERF;7,922.0-7,952.0- PRODUCTION;30.0-8,151.3 4 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3A-15 Run Date: 8/12/2009 October 14, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3A-15 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-21491-00 Injection Profile Log ~,~~~~ [~~~ ~ $ 2009 50-029-21491-00 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BI' SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com Date: ~fj!; ~~ Signed: ~~ ~~ • • ConocoPhillips -- 1 ~ .~a ~F~ ~ Alaska P.0. BOX 100360 A p ~ ~ t~ f (? e, ;~ ANCHORAGE, ALASKA 99510-0360 @@~~ P ~~ 434 ~ ~:?t~,. ~.reii:., .,~ ~I~COt« April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission .. ~.,,- ~ , ~~ , ~ ~ ,~ - { , .., - 333 West 7th Avenue, Suite 100 ~''~"'~'~~~~~ !~`~'~~ ~ ~`'`'~' , j -- ~.~'~ Anchorage, AK 99501 ~ ~ ~ .¢~ ~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry~Kleinr ConocoPhillips Well Integrity Projects Supervisor ~~ C~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 KRU 3A-15 (PTD# 185-283) ~ort Of TxIA Communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] -~ Sent: Tuesday, February 03, 2009 2:11 PM ~~~~~ 4 ~ ldrr~~ To: Regg, James a (DOA); Maunder, Thomas E (DOA) -~-- Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs; Edwards, Reid T Subject: KRU 3A-15 (PTD# 185-283) Report Of TxIA Communication Attachments: 3A-15 TIO Plot.jpg; 3A-15 Wellbore Schematic.pdf ~ ~P~~S Tom/Jim, Kuparuk injector 3A-15 (PTD# 185-283) is suspected of having TxIA communication based upon a failing MITT during the course of routine slickline work. The well has been shut in since 05/118 due to reservoir pressure management for offset drilling. ConocoPhillips intends to inject as necessary to conduct diagnostic work to locate and repair the communication. The well will be added to the monthly report and we --"' will submit a 10-403 as necessary or apply for administrative relief to continue injection. Attached is a 90 day TIO plot and Wellbore schematic. «3A-15 TIO Plot.jpg» «3A-15 Wellbore Schematic.pdf» Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 4/16/2009 KRU 3A-15 PTD 185-283 2/3 /2009 T10 Pressures 400 T/l/0 P I of - 3A-15 200 300 ~ 200 100 0 150 a E as 100 ~ Y O t U 50 01-Dec-08 Date 01-Jan-09 ~~ 0 01-Feb-09 ~, ~~ KUP ConOGOPllillips ~ ~ wellAmibutes 4~I.i.~a I ' WeIIDOre APVUWI Fleltl NamE - ~ 500292149100 KUPARUI ... CommerA f. p. CONDUCTOR, 0.1 Safttq Vilvc, 1,830 0-3.881 I~I jP:'Gi Tnp locl To RIt P. IX r; E'I I'7 1,830 1,753.3 34.2 cAS uFL 7,446 5,6584 49.0! PBR. PBR. 7,535 104,"~~~~ V 104A NO GO PACKHt, T RKB Blm RKB (ftKEl In I(BJ Zme Date 7,537 7,fi94 7,730 6,023.3 6,047.7 C-0, G3, G•1, 1!14!1986 7.575 IPERF, 7,8947,730 - 7,771 NIP, 7,783 PLUG, 7,787 SOS, 7,791 TTL. 7,7D4 IPERF, 7,6347,854 IPERF, 7.8847,908 IPERF, 7.D44-7.D54 - iODUCTION, 0.8,198 TD. 8.180 STA 2 TA 3 STA 4 90 deg. 3A-15 9f1991 ALL L _~ ~'" 7"I~,gl1/~l1/1/T7"a4L ,.,. ----- - ~. -- ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hale/Mechanical Logs and /or Tubing Inspection(Catiper / MT17 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~4»~~~~k , ~~~ ~; ~~ ~p Suite C Anchorage, AK 99518 Fax (907) 245.8952 1) Caliper Report 05-Feb-09 3A 15 1 Report / E~ 50-029-21491-00 ~59~ ,~ _,~ ~.~ 2) i.3T(~ !~ s -~'3 ~ ! Signed Print Name: '~r,~~ Date 0 ; PROACTIVE DIAGNOSTIC SERVICES, INC., 730 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAt~ : Ia~~al~c~~r~c8~ ct~.I~e~€az}I~r~.ctsa~a~ WEBSITE : ~,~,a~~®r4>~ac C:\Documents end Settings\Owne[1Des}SOp\TTanbmit Conoco.docx 1 • Memory Multi-Finger Catiper Lag Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3A-15 Log Date: February 5, 2009 Field: Kuparuk Log No.: 7296 State: Alaska Run No.: 1 API No.: 50-029-21491-p0 Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE MOD Top Log Intvll.: Surfaces Pipet Use: Tubing Bot. Log tntvl1.; 7,764 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage inspection COMMENTS This caliper data is tied into the tap of GLM 4 ~ T,T53' (Oriller's Depth). This log was run to assess the condition of the 2.875" tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 2.875" tubing logged is in good to fair condition, with a maximum wall penetration of 23% recorded in an area of shallow apparent wear in pup joint 245.3 (7,760'). No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the interval logged. The caliper recordings indicate slight buckling, increasing in severity from _2,200' to the end of the interval logged (7,764'). MAXIMUM RECORDED WALL PENETRATIONS Shallow Apparent Wear (23%) Jt. 245.3 ~ 7,760 Ft. (MD) No other significant wail penetrations (> 19°k) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas of cross-sectional wall loss (> 11%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS No significant I.D. restrictions are recorded. Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. j P.Q. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: (281} 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field OfFice Phone: (907} 659-2307 Fax: 1907) 659-2314 vac ~~s5`-~3 ~ ~s~d • • Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 2.875 in (3.2' - 7758.2') Well: 3A-15 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 5, 2009 i~eil A pprox. lool De viation ~ l~ ppro~. f~urclio le Profil e 752 1 527 2330 3108 3890 ~ L _ fl., C1 0 4670 5447 622 5 7004 GLM 1 ia~ ~ I NJ 4 245.3 7758 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 245.3 1 25 50 75 100 v ~ 125 Z ._ C O ~' 150 175 200 ~ 225 . i' • PDS Report Overview ~, ~µ Body Region Analysis Well: 3A-15 Survey Date: February 5, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 & 218527 Company: ConocoPhillips Alaska, Inc Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 2.875 ins 6.5 f -55 EUE MOD 2.441 ins 3.085 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ,-~ metal loss body 250 200 150 100 50 0 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of ~oints anal se d total = 252 pene. 6 221 24 loss 215 36 1 1 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general Gne ring hole /puss pitting corrosion corrosion conosion ible hole Number of 'oints dams ed total = 3 0 3 0 0 0 Damage Profile (9'o wall) ~ penetration body ,.u~i,;; metal loss body 0 50 100 n rnir v . INJ 4 Bottom of Survey = 245.3 Analysis Overview page 2 • PDS REPORT JOINT TABS Pipe: 2.875 in 6.5 ppf )-55 EUE MOD Well: Body Wall: 0.217 in Field: Upset Wall: 0.322 in Company: Nominal I.D.: 2.441 in Country: Survey Date: • ~ LATI O N SHEET 3A-15 Kuparuk ConocoPhillips Alaska, Inc. USA February 5, 2009 Joint No. Jt. Depth (Ft.) I'~~n. I11„~~t Ilrn.) Pen. Body (Ins.) I'en. `% V1c~tal Lust `;~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 3 u 0.0 11 I 2.40 P P 1 7 t~ 0.01 i U 2.41 3 U 0.00 1 n 2.4 3 70 U .01 ~ t i 2.41 4 10 ~~ .01 ~ ~~ 4 5 132 U .02 f3 ~~ 2.41 6 16 U 0.0 ~~ t~ 2.42 7 19 (1 0.01 3 I 2.41 8 225 l) 0. ~) a .4 9 2 56 l) .0 3 I .41 10 287 u 1 ~ u 2.4 1 319 11 0.0 '~ U 241 1 49 u 0 01 ~ u 2.41 13 380 (~ 0.02 ~~ i I 2.41 14 41 t ~ 0.0 8 1 2.4 15 44 U 0.02 t3 t 1 2.41 16 73 l~ 0.01 6 t~ 2.41 1 0 I t 0.0 a .41 1 535 t? 0.01 4 t ~ .41 19 566 t ~ 0.01 ~ I 2.41 0 597 t ~ OA t3 I 2.4 21 628 t ~ 0.0 t3 I 2.41 2 659 t ~ .00 1 I 2.41 23 690 U 0.01 6 I 2.41 4 (l 0.01 4 I .41 25 752 U 0.01 3 I 2.42 6 7 3 (~ 0.01 3 1 .4 27 814 t~ 0.01 3 0 2.42 8 845 i t 0. 6 l~ 2. 2 29 876 n 0.01 3 U 2.41 0 907 t ~ 0.02 ~) I .41 31 938 t~ 0.01 ~ 1 2.41 2 969 U 0. 7 I 2.41 33 1000 a 0.01 4 n 2.42 4 1031 a 0. 2 i3 n 2.41 35 1062 U 0.01 7 U 2.41 36 1093 ~ ~ 0.01 3 t I 2.42 37 1124 t~ 0.01 I 2.41 8 1155 a .01 -i 1 .41 39 1186 O 0.01 ~~ I 2.41 121 a 0.01 t1 2. 1 41 1248 a .01 3 t ~ 2.42 42 127 U 0.01 ~ I .4 43 1309 ti 0.01 3 1 2.42 1341 U 00 4 t) 2.4 45 13 72 t ~ 0.02 8 t ~ 2.41 46 1403 t~ 1 4 t~ 2.4 47 1434 c ~ 0.01 ~ t ~ 2.41 14 5 i~ 0.01 t, ~~ 2.4 49 14 6 0.01 -1 2.41 ~ Penetration Body Metal Loss Body Page 1 i PDS REPORT JOINT TABI, Pipe: 2.875 in 6.5 ppf J-55 EUE MOD Well: Body Wall: 0.217 in Field: Upset Wall: 0.322 in Company: Nominal I.D.: 2.441 in Country: Survey Date: • ELATION SHEET 3A-15 Kuparuk ConocoPhillips Alaska, Inc. USA February 5, 2009 Joint No. Jt. Depth (Ft.) I't~n. U{~s<~t (Ir».) Pen. Body (Ins.) Pen. % ~I<~I,il Loss `7~, Min. LD• (Ins.) Comments Damage Profile (°!o wall) 0 50 100 50 152 7 U 0.01 3 U .41 51 1558 c) 0.01 G c1 .42 52 1589 t ~ 0.01 6 u 2.40 53 1621 t ~ 0.01 6 I 2.41 54 1 52 (I 0. 1 4 I 2.42 5S 16 3 u 0.0 1 u 2.4 56 1714 t ~ 0.02 9 I .41 57 1745 t ~ 0. 1 4 I 2.4 8 1775 t~ 001 3 1 2.40 8.1 1 05 U .04 1 F3 1 .40 PUP Shall w arent w gar. 58.2 1 15 t) 0 l) (~ .31 O ~ MX' r'es 0 SSSV 58.3 1822 U 0.03 13 2.39 PUP al w arent w ar. 59 183 l) 0.02 11 5 2.38 60 18 3 l ~ 0.01 6 I 2.41 61 1894 tl 0.01 ~ tl 2.4 62 192 5 (I 0.01 4 I 2.41 63 1956 U 0.01 4 1 2.41 64 1987 t~ 0.01 3 tl 4 65 2 1 tl 0.01 ~ I .41 66 49 t ~ 0.01 (i 1 .41 67 20 1 ~ ~ 0.01 4 t 1 2.41 68 21 2 U 0.01 i u .41 6 214 U 0. 1 ~ u 2.41 70 2174 U 0.01 7 ~~ 2.40 1 U 1 ,' a c' 72 2236 1 1 0.01 i t l 2.41 73 267 t ~ .01 I 74 2299 t~ 0.02 ~) I 2.40 SI' ht Bucklin . 5 2 3 tl 0.01 4 i 2.41 76 2361 t t 0.01 c, I 2.40 77 392 t ~ 0.01 4 I 2.41 Sli ht ucklin . 78 2423 n 0.01 ~ I 2.40 79 2454 t ~ 0.01 i 1 2.41 80 2485 U 0.01 (~ I) 2.41 Sli h Buckli 81 2516 t) 0. 1 7 1 .41 82 2547 U 0.01 t) 2.40 83 2578 t ~ 0.01 t, 1 2.41 84 2609 t ~ 0.01 1 2.40 Sli ht BucMin . 85 2640 U 0.01 (> 1 2. 1 86 2671 t ~ 0.01 (~ I 2.40 87 27 a 0.0 -1 I 2.41 88 2734 tl 0.01 4 I 2.40 8 765 U 0.01 (, I 2. Sli ht Buckli 90 2796 ti 0.01 4 1 2.40 91 2827 (~ 0.01 b tl 2.41 92 2858 a 0.01 4 1 2.41 3 2889 t ~ 0.01 4 I 2.41 94 2920 i ~ 0.01 { ! ~ 2.41 95 2952 0.01 - 2.41 Sli ht B cM'n . 96 29f3'~ 0.01 2.41 Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 2.875 in 6.5 ppf J-55 EUE MOD Well: Body Wall: 0.217 in Field: Upset Wall: 0.322 in Company: Nominal I.D.: 2.441 in Country: Survey Date: ~ CATION SHEET 3A-15 Kuparuk ConocoPhillips Alaska, Inc USA February 5, 2009 Joint No. )t. Depth (Ft.) I'c~n. t 11 „~,! (ln~.) Pen. Body (Ins.) Pen. `~~ Met.il Lcri~ °~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 97 3014 O .O1 4 1 2.3 98 3045 O 0.01 4 ~) .4 99 3077 l) 0.01 ~ ~? 2.41 Sli ht cklin . 10 3108 ~) 0.01 (> I 2.41 101 139 U .01 7 U 2.40 102 3170 (1 0 01 3 1 2.40 103 3202 ~) 0.01 U 1 2.41 104 3233 a 0.01 1 2.40 I' ht Buckli 10 3 64 U .0 V 1 .41 106 3295 U 0.0 7 1 2.41 107 3326 O 0.01 i 1 2. 1 108 3358 a 0.01 4 1 2.40 1 9 33 9 ~) 0.01 i 1 2. 1 110 34 0 ~) 1 4 I 2.4 1 1 3451 !) 0.01 6 1 2.41 112 482 U .01 4 I 2.41 113 3 13 U 01 7 I 2.40 114 354 U 0.01 ~ 1 2.41 S i t c in 115 3576 O 0.01 < <) .40 116 3607 ~) 0.01 ~ I .41 117 363 ~~ 0.01 -1 1 .41 118 3670 a 0.01 3 ! 2.40 119 370 U 0.01 i ~) 2.39 120 3733 O 0.01 ~ ~) 2.41 Sli ht Bucklin . 1 1 76 U 0 1O I 122 3796 U 0.01 7 U 2.41 123 3827 t) 0.03 13 tl 2.41 124 3858 O 0.01 6 I 2.40 12 3890 U 0.0 E~ ~) .40 126 3921 )) 0.01 ~ 1 2.40 127 3 52 !) 0. 1 4 I 2. Sli t klin . 128 3983 )) 0.01 7 (i 2.41 129 4014 l) 0.01 ~ I 2.41 130 4045 !) 0.01 1 U 2.41 131 4076 U 0. 2 13 1 2.39 132 4107 ~) 0.01 ~~ 2.40 133 4138 ~) 00 4 1 .40 134 4170 ~ ~ 0. 1 U 1 2.40 135 4201 U 0.01 t n 2.41 136 4232 a 0.01 4 I 2.40 137 4263 a 0.01 ~ U .41 138 4294 (> 0.01 (~ a 2.40 139 4326 U 0.01 ~ I 2.40 140 4357 O 0.01 4 l1 2.41 141 4 8 U .01 6 t) .41 142 4420 l) 0.01 7 U 2.40 Sli ht Bucklin . 143 4451 ~ ~ 0.01 6 1 .41 144 4482 i) 0.01 (, 1 2.40 145 451 ~ } 0.01 I 2.41 146 4545 U 0.01 2.41 Sli ht BucMin . _ Penetration Body Metal Loss Body Page 3 • PDS REPORT )DINT TABI, Pipe: 2.875 in 6.5 ppf J-55 EUE MOD Well: Body Wall: 0.217 in Field: Upset Wall: 0.322 in Company: Nominal I.D.: 2.441 in Country: Survey Date: • iLATION SHEET 3A-15 Kuparuk ConocoPhillips Alaska, Inc USA February 5, 2009 Joint No. Jt. Depth (Ft.) I'c~n. Upset (Ins.) Pen. Body (Ins.) Pen. % 1Ac~t,~l I os5 `~'~~ Min. LD• (Ins.) Comments Damage Profile (%wall) D 50 100 14 S77 ~~ 0.01 ~ I .41 48 46 8 t ~ 0.0 ~) 4 149 4 t 1 0.01 E~ 40 5 46 0 O .01 b I .4 51 4 01 U 002 1U 1 2.41 1 2 47 t l 0.01 4 I 153 4763 0 0.01 E~ I 2.42 1 4 4795 (~ 0.01 7 I 2.41 1 48 U 0. 1 1 I 56 56 cl 0 1 4 I 40 157 488 ~) .O1 4 1 41 i t cklin . 1 91 (1 0.01 3 ' 2.40 159 4 49 t ~ 0.0 (~ I 2.41 160 498 t ~ 0.02 I 1 2.40 1 501 t? 0.0 ti) I 241 162 50 2 i 1 ~ I 1 1 5074 U 0.01 7 I 2.41 4 5105 a 0.0 I I I .38 1 5 513 U 0.02 U 2.40 166 5 67 l1 0.01 ~1 1 .39 167 519 t~ 0. t~ .3 Sf ht uckli 168 5228 t) .00 1 I 2.40 169 60 U 0.01 ~ I 40 170 5290 U 0.01 4 I 2.40 171 53 2 U 0 1 6 1 4 I' ht c I' 172 5353 (~ 0.01 ~ 1 2.41 173 5 8 ~i 0.01 4 ~ 241 174 5416 t) 0.03 Il ? 2.40 175 5447 U 0.01 6 1 2.41 i uc li 176 5478 t~ 0.01 0 1 .40 177 5510 U 0. 2 I U 1 .41 178 5541 (1 0.02 f~ 1 2.39 79 557 U .0 1 1 1 .41 Sli t Bucklin 180 5603 t t 0.02 I 1 _' 2.40 181 5635 u D 01 (~ I 2.42 182 5665 t~ 0.02 t3 1 2.39 18 569 t1 0.01 4 I .40 1 5729 U 0 01 6 2.39 185 5759 l) .0 ~) I uck in . 186 5790 U 0.01 4 2. 8 1 7 5821 u 0 4 1 2.40 188 5852 t~ 0.01 t., ? .39 189 5884 U .01 ~ I 2.38 c lin 190 5914 U 0.00 I I 2.38 191 5 45 U 0.01 (~ a .3 192 5976 tl 0.01 ~1 1 2.40 1 3 6008 t~ 0.01 4 1 .39 cklin . 194 6040 ! 1 0.02 1 1 2.41 195 6 70 ~~ .03 1~ I 242 196 6101 ! 0.02 11 2.38 _ Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABI. Pipe: 2.875 in 6.5 ppf J-55 EUE MOD Well: Body Wall: 0.217 in Field: Upset Wall: 0.322 in Company: Nominal I.D.: 2.441 in Country: Survey Date: • ELATION SHEET 3A-15 Kuparuk ConocoPhillips Alaska, Inc. USA February 5, 2009 Joint No. Jt. Depth (Ft.) I'c~n. UI~,E~t (Ins.) Pen. Body (Ins.) I'en. % Mct,~l L~,s~ °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 197 613 O 0.01 6 2 .41 Buck in . 198 6163 (I 0.02 11 1 2.37 199 6195 O 0.01 6 1 2.40 200 6225 U .01 i ~' 2.39 201 6257 U 0.01 4 _' 2.40 Bucklin . 02 288 (! 0.01 4 1 .39 0 6319 a 00 7 2.41 04 6350 t) 0.01 3 1 2.40 205 63 0 ~) 0.02 ~ I ,3 206 6412 11 0.01 E~ 4 8 20 6 U 0.01 t I 2.40 208 6474 c) 0.01 i 1 .38 B c in . 09 6506 (! 0.01 i I 2. 8 10 65 6 i) 0.01 7 I 2.37 211 6568 O 0.0 9 I .38 12 6599 U 0.00 1 i! 2.37 Buc lin . 213 9 (> 0.01 V ti 2.37 214 6660 U 0.0 1l) I 2.38 215 6692 U 0.02 1U O 2.37 16 6723 c) 0.01 7 _' 2. u k' 7 6755 a 0.01 6 t) 8 1 67 5 (! 0.02 ti 2. 9 219 681 U 0.01 7 1 .39 220 6848 U 0.01 b I 2.39 1 68 ~) 0. 1 ; a uck in . 222 6910 U 0.02 t3 2.40 22 6941 a 0.01 6 1 2. 9 224 6971 U 0.03 12 I 2.39 225 7004 O 0.01 ; I 2.40 B k 226 7035 (! 0.03 14 1 2.38 227 06 O 0.01 7 ~ 2.3 228 7096 a 0.02 ~) I 2.38 229 7127 U 0.01 b _' 2.39 230 7159 a 0.01 4 I 2.39 Bucklin . 231 7189 l) .02 )) U .38 232 7221 a 0.02 1l) a 2.38 2 3 7252 a 0. 1 4 I .3 234 7283 c! 0.01 4 I 2.39 35 7314 a 0.0 l U I 2.39 ucklin . 236 7345 t) 0.02 1 ~! ~! 2.37 37 7377 (! 0.02 lU I 2.39 238 7409 U 0.02 ll) I 2.37 238.1 7439 U 0.01 4 .3 UP Bucklin . 238.2 7446 t) 0 U U N A GLM 1 Latch ®8:00 38.3 7454 U 0.01 5 Z PUP 239 460 O 0.01 6 I 2.39 39.1 7490 t) 0 0 O 2.31 Ca co'OE' PBR 239.2 7516 n 0 O (! 2.35 Camco'HRP-1 SP' Packer 239.3 7 21 ! 0 i! 2.50 PBR 239.4 7535 0 !! 3.00 'Fi6' Packer _ Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABI, Pipe: 2.875 in 6.5 ppf )-55 EUE MOD Well: Body Wall: 0.217 in Eield: Upset Wall: 0.322 in Company: Nominal I.D.: 2.441 in Country: Survey Date: • i CATION SHEET 3A-15 Kuparuk ConocoPhillips Alaska, Inc. USA February 5, 2009 Joint No. Jt. Depth (Ft) I'c~n. l ~I~;r"t iln>.; Pen. Body (Ins.) Pen. % ~1c~t,il I ~~s5 "~~ Min. LD• (Ins.) Damage Profile Comments (%wall) 0 50 100 240 7545 i) .04 1 t3 2. 8 Buckli 240 1 7576 U 0 t~ u A n ection Mandr I L ®9:0 241 7581 c! 0.04 19 ~ .38 24 7612 U 0.03 14 ~ .40 ucklin . 4 .1 7643 tt 0 l) t~ N A In" ti n andrel 3 Latc ~ 7:00 243 7650 (~ .04 1 ti ~i 2.38 244 7681 (~ 0.03 12 _' .40 45 7714 U 0.0 1 Z 2.41 Bucklin . 245.1 7743 a 0.04 1 t) 2.36 PUP 245."? ??>3 O N/,'1_ __Inj~ cfi<~n_M~n_clrc~l__ 4 {L.~tch_n Fi_00 ~~_i ._S i i it f ~ ~~.t~.i - _ _ ~.~~ _ _ I't ~I' ~Il.l ilUl~ .l~)})~i~( Ilt ~1 ~_'_I__ ~ Penetration Body Metal Loss Body Page 6 ~~ ~ PDS Report Cross Sections Well: 3A-15 Survey Date: February 5, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 212330 & 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 2.875 ins 6.5 f •55 EUE MOD Analyst: C. Waldrop Cross Section for Joint 245.3 at depth 7760.3 ft Tool speed = 43 Nominal iD = 2.441 Nominal OD = 2.875 Remaining wall area = 88 Tool deviation = 54 ° Finger 24 Penetration = 0.05 ins Shallow apparent wear 0.05 ins = 23% Wall Penetration HIGH SIDE = UP ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ w ~ ~ ^~ • ~ ~ ~ J Cross Sections page 1 KUP 3A-15 ~01'I000PF'II~~IPS ~ WeN Att YYeflbwe ribut es eM Name W R nt Max A le ~ MD k1tl TD Act (I[IO! AL7v.~1 -n ~ 500292149100 KUPARUK RIVER UNR INJ S7M 48.74 7,500.00 8,180.0 t ~.._. _. Conmgt SSSV: TRDP 0 7/12008 Last WO: &1911991 35.40 p R e 1217&7985 (1d® aM Last Tag: 7,994.0 92912008 Rev Reason: SET PLUG, GLV GO 1/J02009 Ces SUI 9 Bet Set ) arYg YM ~y Bnl pr7) Top Phi 191 8~q mad e T Thrd coNwcTOa. 7 0 CONDUC TOR 1 6 16.062 0.0 101.0 104.0 62.58 FF40 0 SUR AC E 95 /8 8. 65 0.0 3,681.0 3,1474 36.00 J35 PRODUC TION 7 6.1 1 0.0 8, 45.0 6.331.0 2 .00 Jb5 sdarvrVa. I s3o w O Tubi Strf ~e ~ sN rwago ewtgl on Pcl ~1 rop peel p~G Imslq cran e T ltrd TUBING 27 /8 2.441 0.0 7,792.0 6.089.7 6.50 J35 EU MOD s""F3~~i' Otlter I n Hol e A ll Je7ne 1 : Tu Ruh d R Fish ete. Top IND ) Top Y7G T ptKal (') on Commart Run Date 8) oas uFr, ~ 046 1,830.0 1,7 .3 34.24 S atiety Valve 6s'FMX' Series 10 8l1 1991 2.3 3 7.446. 5, .4 49.04 G AS LIFT M aP .5IDMY/TGI/! Carvr~etN : SfA 1 9/611991 2.375 7,496.0 5, 48.75 'OFJ' &79!1991 2.313 7, 14.0 5,90 3. 4 ,92 P A Camco'HRP-1SP' 19/1991 2.347 Pea. T,ase 7,525. 5,910. 48.83 P BR BOT 19/7997 2. 0 7,537.0 5, 1 8.8 48]2 P ACKER O ACKER &19/199f 3.000 7 .0 5, .5 48.40 IN J ON E /11DMV TMIl1 Comment: A 2 1/7/2009 .3 t 7,844.0 5,98 9.4 4 .29 IN JECTION MERLA/TMPDII MYIBKI//Connnenk STA3 811917991 2.375 PACKeR,zs74- 4 53. 6, .3 47. 51N J O ME PD/t/DMYIB /IConarkn t A4 9292008 2. 7,771.0 ,07 5.6 47.38 P BOT iB PE MANENT PACKER &19/1997 2.34 7,783.0 6,08 3.6 4 .3 N IP 'D' NypYe NO GO 8119/1991 2.250 7,7 .0 6,08 .6 47.3 P LUG 2.25' CA-2 PLUG 1252 9 0.000 PeR. 7s2s 7, 91. 6, .0 47.37 5 05 BOT 1917981 2.44i 7,792.0 6. .7 I .36 8/18/1 1 2.441 Parfora tlons ~ PACI(F37. 7,537 I - I T a0a TI~V (1~ (alm) ~77rV•71 OtKal Zmw Date mae Dell{ ~•- Clm inlolt 7,694.0 7,730.0 6.023.3 6.047.7 C -4. G3, G1, 1/1M1986 12.0 IPERF 90 deg. phasig; 5' Csg Gun U NR B, 3A-15 IN,£CTION. 7.834.0 7,85 2.0 6,1 i8.4 6,130. A , 3A-15 1/14/1086 4.0 IPERF 90 deg. phesilg; 4' Csg Gun 1.575 7,864.0 ,90 8.0 6, 38.6 6.168.5 A -2, 3A-15 7114/1966 4.0 IPERF 90 deg. phaS~Ylg; 4 Cag Gun 7,9220 7,95 2.0 6.178.0 ,198.6 A -1, 75 1/tMi 4.0 IPERF 90 deg. pfmsilg; 4'Csg IN.ECTION. 76M IPEStF. 7,891-7.730 HJ,ECTION, 7.753 t i PACKER, l,7Tt ~ ~ 1 1 NIP, 7,783 PLUG. 7,183 SOS, 7 ]Bi ~ TTL, 7,792 IPERF, 7,8%-7,852 IPERF, 7.884-1,908 IPERF, T.92i-1,952 PROIXJCTION, 8.145 ms~so ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Ker¡ ~(I~loç DATE: Monday, September 12,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A-15 KUP ARUK RIV UNIT 3A-15 Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector Src: Inspector Well Name: KUPARUK RIV UNIT 3A-I5 Insp Num: mitJJ050909122318 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-21491-00-00 Permit Number: 185-283-0 Inspector Name: Jeff Jones Inspection Date: 8/30/2005 15 Min. 30 Min. 45 Min. 3360 3350 410 410 2750 2750 Packer Depth Pretest Well 3A-15 'Type Inj. W TVD ---I 5903---'---T-iA--I---s6õ--T _ ~~:~r!~8:2::T;ypeTe;~ =_:;_t_PSi I 14752--{u~~1- ::~_ i Notes 3.1 BBLS diesel pumped. 1 well house inspected; no exceptions noted. Initial 3390 410 2750 '''E''~ fi,"'f."P 0 f¡¡ 20l1Sì .~"...\,;;-.k \L\'~." ~ .''\'l ¡c' i, v ~ .I¡r.~ï ,.,'" 1',,/ '«., - ~;:; 11 ~I" ~ Monday, September 12, 2005 lJ ' rD63 \tt Reviewed By~ P.I. Suprv -:J 611- Corom 60 Min. -_..~._--- Page 1 of 1 Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well /9t¡~¿)7z.1 D-11 I ~"...;¿'!;1 3A-11 I "fi: Of?' 2U-06 llf$2-'ð ~ 3A-15 rK.f -O?'i' 3C-12 77z -ðl? 1A-15 f q,.., -z.u 1 L-09 f Iv..ee,fl - Job # 10922472 10922478 10922477 10922479 10922482 10922481 10802915 Log Description INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE PROD PROFILEIDEFT (REDO-W~LL SKETCH) -. .¡;k~CANNEDDEC ~ 8200: Date 10/11/04 10/16/04 10/15/04 10/16/04 10/19/04 10/18/04 07/26/04 NO. 3241 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: DATE: Kuparuk BL Color CD 1 1 1 1 1 1 1 /(J /¿rf t¡- Please sign and return 0 e opy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. /<¿S-28'?; 1 0/22/04 ~ ~ MEMORANDUM TO: Julie Heusser :~ Commissioner THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 21, 2001 Tom Maunder P.I. Supervisor John Crisp Petroleum Inspector SUBJECT: Mechanical Integrity Tests Phillips Alaska 3A Pad 3A-11,14,15 GKA Kuparuk River Field N. ON- CONFIDENTIAL Packer ,Dep~ Pre~est Initial 15 Min., 30 Min. _ Well! 3A-11 IType~nj.I S I T.V.D. I ~o4 I Tubingl z2sol ~soi 2~soi zzao I~.te,~l 4 'P.T.D.I 1852380 ITypetestl P ITe~,~l ~47.'S I Ca.~r~l 2r~OI 3O0O I 3OOO ! 30pO. i P~: ! E we,! 3A-~4 P.T.D.I ~85_~0 WalI 3A-15 P.T.D.i 4852830 I T~3e~nj.I S I T.V.D. I 6004 ITubingl 27001 2820 I ~,8oo i 2820 I~,~,.v=q 4 Type't~l[P I Testpsil ~ Ic~.~l .,~2s I 2.~2s ! :z400 I 2400 I P/F I_e Typelnj.I N '1 T.V.D.I 59o3 ITubingl 1700 I' 17001 1700 'l 1700I,~1 '4' Ty~t~I p IT~psiI ~47~ I C~'~I ~ I 2'~50 i 2~1 2~01 P~ ! P-. W~,i ' P.T.D. I we#I P.T.D.I Type Inj. I ! T.~.D. I I Tubin(.:j I ! I I !',','~'~i Type testI I Test ~1 I C.~,~ I ! ! ' I !P/F ! ITY,~r,j.! ' i T.V.D. I I Tubir~l I I ! I Type t~I ITest ~i I ,c~,,g I I ! I ! P/F ! Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Suney A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workmer O= Othe~ (describe in notes) Te~t's Details 3 MIT's performed, no failures. Annulus pressures were high on the injecting wells. The wells were bled down the day before State testing. Passed the Standard Annular Pressure tests. M.I.T.'s performed: 3 Attachments: Number of Failures: 0 Total Time during tests: 2 HRS. cc,: MIT report form 5/12/00 L.G. MIT KRU 3Ab 7-21-01jc.xls 7/23/01 ./97 TUE 11 '58 UNOC~'" .,SSET 6¢tS 6R? F¢~× NO, 90726~.'°. ,4 P, 04/04 p ' , : Temperature Survey..Procedure' .~'.,4,~(_ To ensure that ail injected fluids remain within the pe/~mltt~d Injection interval. Because the step rate testing will be done at lower rates and pressures than what the well is currently operating at, the temperature survey will be run independently from the Injectivity testing. Pre-job operations: Make slickline gauge ring (2.3") run to top of fill. Make boiler run and obtain a fill sample. 1) Shut-in well for at least 12 hours prior to performing step rate testing. 2) Fill a 500 bbl tank with produced water and allow it to cool to -40° - 450 F. 3) Rig up pump truck to wellhead, Need to be able to pump at least 5 BPM. Rig up E-line and pressure test lubricator. If necessary. fill lubricator above the swab valve with methanol to prevent freezing while waiting in the lubricator. 4) 5) 6) Run in hole with CCL/temperature survey for base pass logging from the surface to top of fill. Tie in to tubing tail with CCL/Temp Survey run'10/14/89. ~ ~C.~" Run Repeat log over bottom 500' of the Interval. J t/,~D Alaska Oil & 8a.s Cons POOH with logging tools to -200'MD. 4n,chor:~,~ii Begin injecting cold fluid at 900 psi surface injection pressure. While pumping the last 300 bbl of water begin logging tn hole at 30 FPM to the top of fill, Time being back on bottom Just as the last of the water is 9_.. 275' Ir. -I hour). Shut down injection when on bottom wlth logging tools. Allow wellhead pressure to bleed down and the well to go static. 8) POOH logging at 30 FPM to 1,000'. 9) to) Thirty minutes after shutting down pumping, log in the hole at 30 FPM from 1,000' to top of fill. POOH logging to 1,000'. Repeat logging runs after I hour, 2 hour and 3 hour since pumping ceased. Make additional runs if required. Return the well to injection or continue with the step-rate testing below. 0 R I 6 I 1. ALASKA OIL AND G/~ CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 11. Operations performed: Operation Shutdown Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well Other 2. Name of Operator ARGO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development Exploratory Stratigraphic Service 4. Location of well at surface 865' FSL, 838' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1161' FNL, 3717' FEL, Sec. 7, T12N, RgE, UM At effective depth 916' FNL, 3941' FEL, Sec. 7, T12N, R9E, UM At total depth 895' FSL, 3959' FEL, Sec. 7, T12N, RgE, UM 12. Present well condition summary Total Depth: measured true vertical 8160' 6340' feet feet 6. Datum elevation (DF or KB) 71' RKB. 41' PAD 7. Unit or Property name Kuparuk River Unit 8. Well number 3^-1,5 9. Permit number/approval number 85-223/#261 10. APl number 50-029-21491 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 8063' true vertical 6274' feet feet Junk (measured) Top of fill 7931' tagged 2/3/89. Casing Length Size Structural 8 0' 1 6" Conductor Surface 3657' 9 - 5/8" Intermediate Production 81 21 ' 7" Liner Perforation depth: measured Cemented 171 Sx AS II 1510 sx AS III & 310 sx Class G 450 sx Class G & 175 sx AS I Measured depth True vertical depth 104' md 104' tvd 3681' md 3147' tvd 8145' md 6331' tvd 7952'-7922', 7908-7864', 7852'-7834', 7730'-7694' true vertical 6199'-6178', 6168'-6139', 6130'-6118', 6048'-6023' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55 tbg @ 7792' Packers and SSSV (type and measured depth) REC£ VF.C) 0CT ?- 5 1991 Alaska Oil & Gas Cons. ¢.;o~~'~ss~ Anc.~0rage 'I-B' Perm Pkr ~ 7771', 'HB' Ret Pkr ~ 7537', Camco 'HRP-1SP' Ret Pkr ~ 7514', Otis 'FMX- 10' SSSV ~ 1830' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil __ Gas Suspended Service ;io~~'-4~4 ~e~' 75/~7,8; "~ "'- - -f Area Drilling Engineer SUBMIT IN DUPLICATE ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: 3A-15 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT FIELD: KUPARUK RIVER FIELD LEASE: ADL 25631 ALK 2565 API: 50-029-21491 PERMIT 85-283 APPROVAL: Conservation Order #261 ACCEPT: 08/16/91 17:00 RELEASE: 08/20/91 00:00 OPERATION: WORKOVER RIG: NORDIC 1 AFE: AK5849 WI: 55.347699 08/16/91 ( 1) TD: 0 PB: 8063 SUPV:DB/DS 08/17/91 ( 2) TD: 0 PB: 8063 SUPV:DB/DS 08/18/91 ( 3) TD: 0 PB: 8063 SUPV:DB/DS 08/19/91 ( 4) TD: 0 PB: 8063 SUPV:DB/DS MOVING RIG TO WELL MW: 0.0 MOVING RIG FROM 2A PAD TO 3A PAD. CAMP SPOTTED @ 0330 HRS. DAILY: $1,808 CUM: $1,808 ETD: $1,808 EFC: $364,000 MU LANDING JT MW:12.4 THXL CONT MOVE RIG FROM 2A PAD TO 3A PAD,ACCEPT RIG AT 1700 HRS 8/17/91,MU CHOKE & KILL LINES,MU HARD LINE,PULL BPV, FILL PITS AND CONDITION THIXSAL, SITP=1000 PSI SICP=800 PSI,BLEED OFF CSG/TBG,MONITOR, NO FLOW, KILL WELL BY PUMPING DOWN TBG UP ANNULUS,PUMP 45 BBLS 9.9 PPG VISCOUS BRINE SWEEP,FOLLOWED BY 300 BBLS 12.4 PPG THIXSAL, SET BPV, ND TREE,NU BOPE,CHANGE PIPE RAMS TO 2 7/8",SET TEST PLUG, TEST BOPE, PULL TEST PLUG MU 2 7/8" LANDING JT. DAILY:S89,835 CUM:$91,643 ETD:S91,643 EFC:$364,000 RIH W/SEAL ASSY,RTTS ON DP MW:12.4 THXL MU 2 7/8" LANDING JT ON TBG HGR, TEST PIPE RAMS AND ANNULAR TO 3000 PSI,PULL TBG HGR TO FLOOR, SEAL BORE PULLED FREE W/36K# PU WT,CBU @ 113 SPM/1500 PSI,MIX AND PUMP DRY JOB,RU TO CHANGE OUT COLLARS WHILE PULLING TBG, POH W 2 7/8" TBG, CHANGING COLLARS TO AB MOD,POH W BOT SEAL ASSY,NO SIGNS OF LEAKAGE OR FLOW CUT SCARS,LD SEAL BORE ASSY,RACK AND TALLY 3 1/2" DP,WHILE RACKING DP CLOSE BLINDS AND PRESSURE TEST CSG TO 2900 PSI,LOST 200 PSI IN 3 HRS 45 MIN, SLIP AND CUT DRLG LINE,CHANGE PIPE RAMS TO 3 1/2",SET TEST PLUG, TEST PIPE RAMS TO 3000 PSI, SET WEAR RING, PU/MU TEST SEAL ASSY AND RTTS,RIH ON 3 1/2" DP DAILY:S34,456 CUM:$126,099 ETD:S126,099 EFC:$364,000 RIH W/2 7/8" COMPLETION MW:12.4 THXL CONT RIH W/BOT SEAL ASSY & RTTS ON 3 1/2" DP,TAG PBR @ 7517'DPM, STING INTO PBR TEST SEAL ASSY TO 2850 PSI F/30 MIN LOST 240 PSI,NO FLOW UP ANNULUS,REPRESSURE DP TO 2930 PSI LOST 35 PSI IN 30 MIN, NO FLOW UP ANNULUS,BLEED OFF DP AND CLOSE ANNULAR, PRESSURE UP ANNULUS TO 2850 PSI,LOST 100 PSI IN 30 MIN,NO FLOW UP DP, PU OUT OF PBR AND SET RTTS,PRESSURE UP ON DP TO 2850 PSI W/ANNULUS OPEN F/30 MIN, LOST 90 PSI BLEED OFF DP,PRESS UP ANNULUS TO 2920 PSI F/30 MIN, LOST 70 PSI RELEASE RTTS AND CIRC,MIX AND PUMP DRY JOB,POH, LD DP/RTTS/SEAL ASSY, REDRESS BOT SEAL ASSY,PULL WEAR RING, SET TEST PLUG, CHANGE PIPE RAMS TO 2 7/8",TEST PIPE RAMS TO 3000 PSI,PULL TEST PLUG, RU TO RUN 2 7/8" COMPLETION ASSY,PU CAMCO 2 7/8" HRP-1-SP RET PKR, MU BOT SEAL ASSY,CAMCO PKR W/OEJ, JT 2 7/8" TBG,MERLA 2 7/8" X 1 1/2" GLM W/CV, RIH W/SAME DAILY:S36,347 CUM:$162,446 ETD:S162,446 EFC:$364,000 RECEIVED OCT 2 5 !99! _Oil & Gas Gens. ,3o~:~mis¢0¢ WELL: 3A-15 OPERATION: WORKOVER RIG: NORDIC 1 PAGE: 2 08/20/91 ( 5) TD: 0 PB: 8063 SUPV:DB/DS RIG RELEASED MW: 0.0 Diesel CONT RIH W/2 7/8" COMPLETION, SPACE OUT 1' ABOVE PKR, MU TBG HGR, LAND TBG, RILDS, SET PKR W/3500 PSI,BLEED TBG TO 1500 PSI BOLDS,PU AND SHEAR PBR W/64K#,RELAND TBG, RILDS,PRESS TEST ANNULUS TO 2500 PSI F/15 MIN, OK, BLEED TBG AND ANNULUS TO 1000 PSI,CLOSE SSSV, BLEED TBG TO 500 PSI,TEST SSSV w/500 PSI DIFF. PRESS F/15 MIN, EQUALIZE AND OPEN SSSV, BLEED OFF REMAINING PRESS,LD LANDING JT, INSTALL BPV ND BOPE,NU TREE AND TEST SAME TO 5000 PSI,CHANGE OUT LEAKING WING VALVE RETEST PULL TEST PLUG, DISPLACE WELL W/DIESEL, SET BPV SITP=900 PSI,SICP=0,SIAP=325 PSI RELEASE RIG @ 2400 HRS,MOVE RIG TO 3K-12 DAILY:S60,943 CUM:$223,389 ETD:S223,389 EFC:$364,000 SIGNATURE:_ DRILLIN~SOPERINT~DENT DATE: _//~/~ ~//~./ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Pull tubin.._g - Alter casing 2. Name of Operator _ ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 ORI61NA . Stimulate Plugging Perforate Repair well Pull tubing 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 865' FSL, 838' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1161' FNL, 3717' FEL, Sec. 7, T12N, R9E, UM At effective depth 916' FNL, 3941' FEL, Sec. 7, T12N, R9E, UM At total depth 895' FNL, 3959' FEL, Sec. 7, T12N, R9E, UM Present well condition summary Total Depth: measured true vertical 8160' 6340' feet Plugs (measured) feet Other X 6. Datum elevation (DF or KB) RKB 72' 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-15 9. Permit number/approval number 85-223/8-982 10. APl number 50-029-21491 lt. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 8063' true vertical 6274' feet Junk (measured) feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 3657' 9 5/8" Intermediate Production 81 21 ' 7" Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 2.875", J-55, 7785' Packers and SSSV (type and measured depth) SSSV: Cemented Measured depth 171 SX AS II 1 04' 1510 Sx AS III & 3681 310 Sx Class G 450SxClassG& 8145' 175 Sx AS I True vertical depth 104' 3147 6331' 7922'-7952', 7908'-7864', 7834'-7852', 7694'-7730 61 78'-6199', 61 68'-6139', 6118'-6130', 6023'-6048' MD-RKB Baker FVL 1804', Packer: Baker FHL 7530', 7764' r- ' MD TVD 12. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A 14. Treatment description including volumes used and final pressure Tubing Pressure Prior to well operation ReBresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure SI Subsequent to operation 0 1000 15. Attachments Copies of Logs and Surveys run X Daily Report of Well Operations X 430 2000 1450 16. Status of well classification as: Service Water Injection Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date /' ~/~' ',~ SUBMIT IN DUPLICATE Sit, ned .'.,~ (_~_ .-f~ 'L.,.~.--'*F'¢ - ,.' ..~.,.....-~-~'"'/ Title ',,.) ' ~t ~.; /" -, ~,", /- -1,.' -~'" , ~ / Form 10-404 Ce~ 06/15/88 3A-15 RADIOACTIVE TRACER SURVEY EVALUATION & SUMMARY 2/3/89 , Baseline GR Lo(] vs fOIIow-uD GR Logs: No "hot spots" in GR Icg, no indication of leakage. , Ra Tracer Iniection Velocity_ check through entire tubing: TOTAL VELOCITY EVENT I;)~PTH TIME FROM INJ POINT Eject Tracer Shot 189' 1 0:36 Detect 1909' 11:02 66.1 FPM Detect 5009' 11:50 65.1 FPM Detect 7 0 0 9' 1 2:1 9 66.2 FPM Detect 7789' 12:31 66.1 FPM B) Result' Velocity ranges are within +/- 1%. No leakage detected. ! Check Cement Intearitv between A and C sands: A) Procedure: B) Result' Inject Ra tracer slug @ 7810' (Above A Sand perfs). No GR kick detected while waiting for 30 minutes, indicating no fluid flow behind 7" casing between A and C sands. Check for Leakage across PBR/UDDer Packer: A) Procedure: B) Result' Inject Ra tracer slug @ 7507' (Above PBR), move detector to 7559' (below top packer) to look for possible leak through PBR/across top packer. See only immediate GR kick from fluid traveling in tubing, do not see subsequent GR kick indicating PBR/Upper Packer leak. 5. Check for Leakaae across Lower Packer: - A) Procedure: B) Result' Inject Ra tracer slug @ 7763' (Above Lower Packer), monitor for flow out tubing tail, traveling uphole through potential leak in bottom packer. No GR kick detected while waiting for 15 minutes, indicating no fluid flow across lower packer. Ra Tracer Iniection Velocity checks at various Points' A) Procedure: Inject Ra tracer slugs at various points, and monitor for travel time between detection of tracer slug by top and bottom detectors. Velocity change indicates potential leakage. Detectors are 7.6 feet apart. LOCATION Between btm PKR & TT Between btm & top PKR Between btm & top PKR Between btm & top PKR Between GLM & top PKR Above GLM & top PKR DEPTH DELTA-T VELOCITY 7772' 7.2 sec 1.05 fps 7700' 7.1 sec 1.07 fps 7600' 7.2 sec 1.05 fps 7560' 7.4 sec 1.03 fps 7510° 7.0 sec 1.08 fps 7400' 7.2 sec 1.05 fps B) Result' Velocity ranges are within +/- 2%. No leakage detected. 7 Check for Leakaoe from GLM #1 (7474') to 'C' Sand Perfs (7734')' _ A) Procedure: B) Result' Inject Ra tracer slug @ 7400' (Above GLM #1), monitor @ 7734' for any leak entering C Sands. Detect main tracer slug passing 5.1 minutes later (51 fpm). Continue monitoring, no GR kick detected while waiting for 10 minutes, indicating no fluid flow into C sands. SUMMARY: No indication of injected water going anywhere except into the A sand as intended. W~LL T~ME ~g~ .... iiiiiii i i i iii £ ', sE~J~ o~ Even's ~/~ '"/~'-'-, OPERATION ?. F,'~/-¢ X~ ~ / z~. /W/R 81. tw.,~ ,~,,,.-~'"' i ii DATE iii i715' l~bO i¢3o b ¢:~.o',,.,.. 7¢¢,~ Ct, 7 qNo ARCO Alaska, Inc. Date: Internal Correspondence December 19, 1988 File code: Well 3A-15 Subject: Procedures for Timed-Run Radioactive Tracer Survey in Well 3A-15 From/Location: J.A. Rugen ATO-1154 Telephone: To/Location: 263-4761 J. Moore/G. Doles The AOGCC has amended Rule 6 of the Area Injection Order No. 2 to include, under some circumstances, timed-run radioactive tracer surveys (RTS) as an alternate method for demonstrating mechanical integrity in injection wells. The modification to the normal pressure-monitoring MIT was granted so that there would be an alternate method to demonstrate that all of the water being injected in the well is going into the designated zone. On 8/26/88, injection well 3A-15 failed an in-house MIT run in accordance with State guidelines for wells on active injection. Subsequent testing, pursuant to a Sundry Notice issued by the AOGCC on 9/2/88, has indicated a leak across the top packer, with the possibility of other leaks in the completion. Since the withdrawals from the supported producers are from the A Sand, the well was to have been returned to A Sand only injection after the well had been worked-over. The State has indicated that if the well can pass an RTS which shows that all injected water is going into the A Sand, they will grant a variance to allow injection into the A Sands without repairing the well. Running a timed-run radioactive tracer survey consists of tracking a slug of RA tracer material down the well. As outlined in Part I of the attached procedure, measuring the travel time of the slug between various points in the wellbore will allow calculation of the fluid rate. If that rate is consistent throughout the tubing, then it is assumed that all the water injected at the surface is arriving at the A Sand peals. Please note that baseline and follow up GR logging is called for to check for residual hot spots which may indicate tubing leaks. Part II of the procedure is to test for leaks across the packer separating the A and C sands and for water channeling from A to C outside the wellbore. If upward migration of fluid is seen after the tracer slug is released above the A Sand perfs, the tool should be pulled up hole to track the slug. Even if the packer or cement sheath is leaking, there is a possibility of getting a variance if the upward migration does not continue past the C Sand perfs. Part Ill of the procedure involves the ejection of a slug above the PBR and tracking it to see if any tracer ends up on the backside. This area of the tubing has been a suspected source of communication in the past. Part IV of the procedure provides for further troubleshooting in the event that the previous steps indicate a possible leak. The Sundry Notice issued 9/2/88 to allow injection while diagnostic testing was being conducted has been closed out. A new Sundry Notice to cover injection and RA tracer testing is being applied for. The new Sundry should be approved by the State and the State should be notified 24 hours prior to conducting the RTS test. In the meantime, ARCO has been granted a verbal waiver to inject into 3A-15 A Sand in preparation for the RTS testing. Operations Engineering recommends J. Moore/G. Doles December 19, 1988 Page 2 that the well be placed on A Sand only injection at 400 BWPD at least one week prior to conducting the test. Prior to the test, KDGS should be monitored to ensure that a stable rate/pressure relationship has been established. It is important that there be no rate fluctuations during the RTS test. Please call if you have any questions regarding the above procedure. Operations Engineer Attachments D. Burford/B. Sossamon J. Currier/B. O'Dell M. L. Hagood H. G. Limb T. Pedersen/L. Lash G. K. Phillips NSK ~Mailed ATO- 1120- ATO- 1148 ATO- 117O ~ to NSK L~/JI~/.~ b~- Radioactive Tracer Survey KRU Well 3A-15 Cost Code 230DS36AL Objective: To determine if KRU Well 3A-15 has injection integrity (ie., does not have injection outside of the approved Kuparuk injection interval). This condition must be met prior to returning this shut-in well to injection. Well Data: Completion: 2-7/8", 6.5#, J-55, EUE to 7785' MD Minimum Restriction: 2.25" I. D. at 7776' MD -- Camco 'D' nipple Tag Fill: 7938' MD (1/2/88 - 153' below tubing tail) Tubular Volume: 45.1 bbl (0.00579 bbl/ft - NOTE: At 400 BPD injection rate, injectant will travel 48 ft/min) RA Tracer: Iodine 131 (8 day half life, no detection after 60 days) Procedure: NOTE: Prior to performing this survey assure that the State has approved the associated Application for Sundry Notice (Contact Jeff Rugen, 263-4761) and notify the State 24 hours prior to test. Part I MIRU slickline unit. Pull A-2 blanking plug from Camco 'D' nipple at 7776' MD. Tag fill. RD slickline unit. Establish a stabilized injection rate of 400 BWPD into well. It is recommended that injection start at least 7 days prior to the RTS test so that the rate will be stable for the test. 3) Prior to the test, check KDGS to make sure that the injection rate and pressure are stable..During the test, have KDGS print out injection rates and pressures every minute. Submit the KDGS data with the survey results. 4) MIRU conductor line unit. RIH with CCL/RA tracer tools to top of fill. RA tracer tool should be the shortest, smallest OD tool available and should have at least one ejector with a gamma ray sensor above and below the ejector. Tie-in log. (Note: The short casing joints, located at 7805 to 7767, are partially covered by the tubing). Run baseline gamma ray/CCL from top of fill to surface. 5 ) RIH to 200' and park tools. Record Gamma Ray on time drive. Radioactive Tracer Survey KRU Well 3A-15 Page 2 6) 7) 8) 9) 10) 11) 12) Eject a one second RA slug at 200' and immediately RIH as fast as possible to 1900' (below SSSV). Record time when large "hot" Gamma Ray kick is detected. After noting the arrival time of the initial "hot" kick, immediately RIH as fast as possible to 5000' (intermediate tubing stop). Record time when large "hot" kick is detected. RIH as fast as possible to 7000' (intermediate tubing stop). Record time when large "hot" kick is detected. RIH as fast as possible to 7525' (below PBR and above top packer). Record time when large "hot" kick is detected. RIH as fast as possible to 7780' (below bottom packer). Record time when large "hot" kick is detected. Allow the RA cloud to completely pass the detector (5 to 10 minutes) and then monitor for approximately another 25 minutes for a secondary "hot" kick which would indicate RA tracer movement behind tubing and/or casing. If results from Steps 4-11 indicate that fluid-loss is occurring within the tubing, set-off another RA tracer slug from 200' and immediately RIH as fast as possible to 1900' and then to 7780', recording the arrival time of the "hot" kick at each depth. Once the RA slug has exited the perforations, run a repeat Gamma Ray/CCL log from top of fill to surface noting any new "hot" spots from the baseline Gamma Ray log. Part II 13) RIH and position bottom detector at 7810' (below tubing tail and above A Sand perfs) and eject a one second RA slug. Monitor for a secondary "hot" kick with log film on time drive for approximately 30 minutes. The purpose of this step is to look for a channel from the A Sand up to the C Sand behind the 7" casing and/or in the 7" casing across the bottom packer. · If a secondary kick is detected, immediately pull up to 7755' (above bottom packer) to confirm that the secondary kick at 7810' was due to an "up" channel and not turbulence in the 7" casing behind the tubing tail below the bottom packer. If a kick is not seen at 7755', go to Part III. · If a kick is seen at 7755', immediately pull up to 7650' (above C Sand perfs) to check for flow above the C Sand. Radioactive Tracer Survey KRU Well 3A-15 Page 3 1 4 ) Pull up to 7485' (above PBR) and eject a one second RA slug and immediately RIH to 7550' (below top packer and above GLM2). Monitor for a secondary "hot" kick with log film on time drive for approximately 30 minutes. The purpose of this step is to look for a PBR/upper packer leak. 1 5) If results from Steps 4-9 and 11 indicated a tubing leak does NOT exist in this well, go to Step 17. If a leak was indicated, determine which interval(s) may have a leak(s) from the data obtained in Steps 4-9 and 12. 16) Using RA tracer slugs ejected from the logging tool, determine the velocity of injectant at different intervals within the leaking interval(s) to determine the leak location(s). For example, if the velocity at 5000' (Step 6) was greater than the velocity down to 7000' (Step 7), determine the velocity at the point halfway between (6000') using RA tracer velocity shots. Repeat this procedure as needed to narrow-in on the leak location(s). 1 7) POOH and RD conductor line unit. WELL: 3A-15 API #: 500292149100 ADL LEAS~ 25631 PERMIT #: 85-283 SPUD DATE: 12/11/85 COMPLETION DATE: 01/14/86 SURFACE LOCATION: 865'FSL,838' FEL,SEC7,T12N,RgE TOP OF KUPARUK: 1161'FNL,3717'FEL,SEC7,T12N,RgE TD LOCATION: 895'FNL,3959'FEL,SEC7,T12N,R9E ORIGINAL RIG RKB: 71 MSL PAD: 41 MSL REVISION DATE:03~05/86 TUBING SPOOL: 2¢ MSL 16" 62.5# H-¢O La 104 SSSV: BAKER FVL ID La 1804 9.625" 36# J-55 La 3681 SBR: BOT PBR ID La 7518 PKR. BOT H8 7530 BLAST JOINTS PKR: BOT 18 NOGO: CAMCO 'D' NIPPLE 2.25" ID (a 7776 SHEAR OUT: BOT 7764 7784 7" 26# J-55 La 814.5 / _._1 XXX X,~Xl XXX XXX ,. '111111111 IIIIIIIII I I_ GLM1 La 7474 / 1.5" GLM2 La 7568 / 1.0" GLM3 La 7637 / 1. TI 7694 - 7730 12 SPF GLM4 La 7746 / 1.0" 2. 875 6.5# J-55 EUE TUBING TAIL La 7785 '1 7834 - 7852 4 SPF '1 7864 - 7908 4 SPF 7922 - 7952 4. SPF PBTD 8063 , PBTDSS 6202 Drill Site 3A A SAND WATERFLOOD PATTERNS 3H-14 RTS SURVEY 31-14 31-08 A 3J-12 3H-11 3H-04 3H-03 3A-15 3A-11 3A-06 3A-02 3A-13 / ' 03 3A-14 3 16 3A-10 3A-12 3A-07 3A-05 3A-04 3A-01 3J-05 3J-01 3B-02 A 3B-01 3F-16 3F-13 3F-07 3F-05 3B-16 PRODUCER WATER INJECTOR PATTERN BOUNDARY JAR 12/1 9/88 KUPRRUK R I VER WELL 31::1- 1E; UNIT MERSURED DEPTH F~FI~T F~T CUTOFF NET 2. tOO. tOO. COd/II LO0. ~0- OT ~C cMrlr ~ .00 UNIT O · . i , C2~4 INTER. UNIT B . . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~MISSlON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate __ Plugging Perforate __Pull tubing Alter casing Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska, In(;;, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service ~IL 4. Location of well at surface 865' FSL, 838' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1161' FNL, 3717' FEL, Sec. 7, T12N, R9E, UM At effective depth 916' FNL, 3941' FEL, Sec. 7, T12N, R9E, UM At total depth 895' FNL, 3959' FEL, Sec. 7, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8 1 6 0' feet Plugs (measured) 6340' feet 6. Datum elevation (DF or KB) RKB 72 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-15 ~ ~(~ ~o^ 9. Permit number/approval number 8-682 10. APl number 50-029-21491 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 0 6 3' feet Junk (measured) true vertical 6274' feet Casing Length Size Cemented Measured depth Structural Conductor 80' 1 6" 171SxASII 1 04' Surface 3657' 9 5/8" 1520 Sx AS III & 3 681 ' Intermediate 310 Sx Class "G" Production 8 1 2 1 ' 7" 450 Sx Class "G" 81 4 5' Liner 175 Sx AS I Perforation depth: measured 7922'-7952', 7864'-7905', 7834'-7852', 7694'-7730' true vertical 6178'-6199', 6139'-6168', 6118'-6130', 6023'-6048' Tubing (size, grade, and measured depth) 2.875", J-55, 7785' MD-RKB Packers and SSSV (type and measured depth) SSSV: Baker FVL 1804'; Packer: BOT HB 7530', BOT lB 7764' 13. Stimulation or cement squeeze summary True vertical depth 104' 3147' 6331' 14. Intervals treated (measured) Treatment description including volumes used and final pressure :-~Sk~ 0ii & Gas Cons.C0mn:[; Rer~resentative Daily Averaoe Production or Iniection Dala- Prior to well operation Subsequent to operation OiI-Bbl Shut-in Shut-in Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil _ Gas Suspended Service Water Injec. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 ¢~ev' 06/15/88 f Date SUBMIT IN DUPLICATE DAILY REPORT OF WELL ~PERATIONS 3A-1~i DECEMBER 14, 1988 REF: Sundry Approval 8-682 (9/7/88) to continue diagnostic work to identify the nature and location of tubing x 7" casing communication. 1 0/1 8/88: Replaced circulating valves at 7746', 7637', and 7568' MD with dummy valves to isolate the C Sand. Set A-2 blanking plug in Camco 'D' nipple at 7776' MD to isolate the A Sand. PRESSURE TESTING: Diesel in tubing and casing during pressure testing 1 0/1 9/88: Bled tubing pressure from 1400 psig to 0 with 1400 psig on 7" casing. Tubing pressure increased to 1400 psig in 25 minutes. During this time, the casing pressure dropped to 1350 psig and then increased and stabilized at 1450 psig. 1 0/21/88: Bled tubing pressure from 1200 psig to 0 with 1200 psig on 7" casing. Tubing pressure increased to 1350 psig in 2 minutes and casing pressure remained constant. 1 0/28/88: Bled casing pressure from 1100 psig to 500 psig with 1200 psig on tubing. Casing pressure increased to 1150 psig 75 minutes. During this time, the tubing pressure dropped to 1100 psig and then increased and stabilized at 1200 psig. Bled tubing from 1200 psig to 0 with 1150 psig on 7" casing. Tubing pressure increased to 1200 psig in 15 minutes and the casing remained constant. 10/29/88: Bled 7" casing from 1100 psig to 500 psig with 1200 psig on tubing. Casing pressure increased to 1100 psig in 60 minutes. During this time, the tubing pressure dropped to 1100 psig and then increased and stabilized at 1200 psig. Pumped up the 7" casing from 1100 psig to 2500 psig with 1200 psig on tubing. Casing pressure gradually dropped back to 1150 psig over 15 hours. These tests indicate that the upper packer is leaking and suggest that the tubing is good. The tests were not designed to determine whether the lower packer is still holding. 0il & G~* Cons. ARCO Alaska, Inc. ~ :).':f.ce Box ~00~60 ~ --,_,r,~Qe Aias~a 995!0-0360 ~-L~-~o~- 907 276 121~ December 21, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on Kuparuk well 3A-15. Approval is requested for water injection in the A sand. If you have any questions, please call me at 265-6840. Sincerely, G. B. Sm~llwood Senior Operations Engineer GBS:kjr Attachments CC: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 AL, . ~A OIL AND GAS CONSERVATION COMM~,....,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate __ Pull tubing _ Variance _ Perforate _ Other X 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic 4. Location of well at surface 865' FSL, 838' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1161' FNL, 3717' FEL, Sec. 7, T12N, R9E, UM At effective depth 916' FNL, 3941' FEL, Sec. 7, T12N, R9E, UM At total depth 895' FNL, 3959' FEL, Sec. 7, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8160" feet Plugs (measured) 6 3 4 0' feet 8063' feet Junk (measured) 6 2 7 4' feet Casing Length Structural Conductor 8 0' Surface 3 6 5 7' Intermediate Production 81 21 ' Liner Perforation depth: measured 7922'-7952', None 6178'-6199', Tubing (size, grade, and measured depth 2.875", J-55, 7785' MD-RKB Packers and SSSV (type and measured depth) Size Cemented 16" 171 SxASII 9 5/8" 1510 Sx AS III & 310 Sx Class G 7" 450 Sx Class G 175 Sx AS I 7864'-7905', 7834'-7852', true vertical 6139'-6168', 6118'-6130', SSSV: Baker FVL 1804; Packers: BOT HB 7530', BOT lB 7764' 6. Datum elevation (DF or KB) RKB 72 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3A-15 9. Permit number 10. APl number 50-02921 491 11. Field/Pool Kuparuk River Oil Pool Measured depth True vertical depth 104' 104' 3681' 3147' 8145' 6331' 7694'-7730' 6123'-6048' 13. Attachments Description summary of proposal X Problem description, proposal, and MIT'S 14. Estimated date for commencing operation December 1988 16. If proposal was verbally approved Name of approver Date approved Detailed operation program_ 15. Status of well classification as: Oil Gas BOP sketch Service Water Injector Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Approved by the order of the Commission Form 10-403 Rev 06/15/88 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ ,A~.T. Mechanical Integrity Test ,,_¥ Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH 10- -/~zr Commissioner , ,-,-'~v"d Copy Returned IApproval N O ~,.._,~,~;.,,~ SUBMIT IN TRIPLICATE ATTACHMENT TO APPLICATION FOR SUNDRY APPROVAL WELL 3A-15 DECEMBER 15, 1988 Well History and Problem DescriDtion Well 3A-15 was converted to water injection 1/16/88. A pressure-type mechanical integrity test was performed on 1/15/88 (attached) and passed in accordance with AOGCC rules. Fluctuations in the 7" casing pressure (tubing/casing annulus) raised concern about an improperly seated or leaking dummy gas lift valve. The dummy valve in the single gas lift mandrel above the packer was replaced three times but the problem persisted. An MIT (attached) was performed in accordance with AOGCC guidelines for wells on active injection. The well failed the second part of the MIT performed August 26 (Casing Pressure = Minimum Test Pressure - 1000 psig). Subsequent diagnostic testing indicated that the top packer and possibly the PBR are leaking (see attached wellbore schematic). The well currently is shut-in with the C Sand dummied off and an A-2 blanking plug in the D nipple isolating the A Sand. Proposed Course of Action After reviewing the waterflood performance of the A and C Sands in the pattern of this injector, continued injection into the C Sand is not currently necessary but injection into the A Sand is still required to support the three pattern producers. ARCO Alaska, Inc. proposes to pull the A-2 blanking plug and re-initiate injection into the A Sand while keeping the C Sand dummied off. After attaining a stable injection rate into the A Sand, a timed-run radioactive tracer survey will be performed in the well (see attached procedure) to verify that all of the injected fluid is entering the approved Kuparuk interval (per amended Rule 6 of AOGCC Area Injection Order No. 2). If out-of-zone injection is detected with the survey, the well will be shut-in and appropriate remedial action will be taken. If out-of-zone injection is not indicated, water injection will continue and the radioactive tracer survey will be repeated every two years to confirm injection is taking place only in the approved Kuparuk interval. Radioactive Tracer Survey KRU Well 3A-15 Cost Code 230DS36AL Objective: To determine if KRU Well 3A-15 has injection integrity (ie., does not have injection outside of the approved Kuparuk injection interval). This condition must be met prior to returning this shut-in well to injection. Well Data: Completion: 2-7/8", 6.5#, J-55, EUE to 7785' MD Minimum Restriction: 2.25" I. D. at 7776' MD -- Camco °D' nipple Tag Fill: 7938' MD (1/2/88 - 153' below tubing tail) Tubular Volume: 45.1 bbl (0.00579 bbl/ft - NOTE: At 400 BPD injection rate, injectant will travel 48 ft/min) RA Tracer: Iodine 131 (8 day half life, no detection after 60 days) Procedure: NOTE: Prior to performing this survey assure that the State has approved the associated Application for Sundry Notice (Contact Jeff Rugen, 263-4761) and notify the State 24 hours prior to test. Part l 1) MIRU slickline unit. Pull A-2 blanking plug from Camco 'D' nipple at 7776' MD. Tag fill. RD slickline unit. 2) Establish a stabilized injection rate of 400 BWPD into well. It is recommended that injection start at least 7 days prior to the RTS test so that the rate will be stable for the test. 3) Prior to the test, check KDGS to make sure that the injection rate and pressure are stable. During the test, have KDGS print out injection rates and pressures every minute. Submit the KDGS data with the survey results. 4) MIRU conductor line unit. RIH with CCL/RA tracer tools to top of fill. RA tracer tool should be the shortest, smallest OD tool available and should have at least one ejector with a gamma ray sensor above and below the ejector. Tie-in log. (Note: The short casing joints, located at 7805 to 7767, are partially covered by the tubing). Run baseline gamma ray/CCL from top of fill to surface. 5 ) RIH to 200' and park tools. Record Gamma Ray on time drive. Radioactive Tracer Survey KRU Well 3A-15 Page 2 6) 7) 8) 9) 10) 11) 12) Eject a one second RA slug at 200' and immediately RIH as fast as possible to 1900' (below SSSV). Record time when large "hot" Gamma Ray kick is detected. After noting the arrival time of the initial "hot" kick, immediately RIH as fast as possible to 5000' (intermediate tubing stop). Record time when large "hot" kick is detected. RIH as fast as possible to 7000' (intermediate tubing stop). Record time when large "hot" kick is detected. RIH as fast as possible to 7525' (below PBR and above top packer). Record time when large "hot" kick is detected. RIH as fast as possible to 7780' (below bottom packer). Record time when large "hot" kick is detected. Allow the RA cloud to completely pass the detector (5 to 10 minutes) and then monitor for approximately another 25 minutes for a secondary "hot" kick which would indicate RA tracer movement behind tubing and/or casing. If results from Steps 4-11 indicate that fluid-loss is occurring within the tubing, set-off another RA tracer slug from 200' and immediately RIH as fast as possible to 1900' and then to 7780', recording the arrival time of the "hot" kick at each depth. Once the RA slug has exited the pedorations, run a repeat Gamma Ray/CCL log from top of fill to surface noting any new "hot" spots from the baseline Gamma Ray log. Part II 13) RIH and position bottom detector at 7810' (below tubing tail and above A Sand perfs) and eject a one second RA slug. Monitor for a secondary "hot" kick with log film on time drive for approximately 30 minutes. The purpose of this step is to look for a channel from the A Sand up to the C Sand behind the 7" casing and/or in the 7" casing across the bottom packer. · If a secondary kick is detected, immediately pull up to 7755' (above bottom packer) to confirm that the secondary kick at 7810' was due to an "up" channel and not turbulence in the 7" casing behind the tubing tail below the bottom packer. If a kick is not seen at 7755', go to Part III. · If a kick is seen at 7755', immediately pull up to 7650' (above C Sand perfs) to check for flow above the C Sand. Radioactive Tracer Survey KRU Well 3A-15 Page 3 Part III 1 4 ) Pull up to 7485' (above PBR) and eject a one second RA slug and immediately RIH to 7550' (below top packer and above GLM2). Monitor for a secondary "hot" kick with log film on time drive for approximately 30 minutes. The purpose of this step is to look for a PBR/upper packer leak. 1 5) If results from Steps 4-9 and 11 indicated a tubing leak does NOT exist in this well, go to Step 17. If a leak was indicated, determine which interval(s) may have a leak(s) from the data obtained in Steps 4-9 and 12. 46) Using RA tracer slugs ejected from the logging tool, determine the velocity of injectant at different intervals within the leaking interval(s) to determine the leak location(s). For example, if the velocity at 5000' (Step 6) was greater than the velocity down to 7000' (Step 7), determine the velocity at the point halfway between (6000') using RA tracer velocity shots. Repeat this procedure as needed to narrow-in on the leak location(s). 1 7) POOH and RD conductor line unit. WELL: 3A-15 API #: 500292149100 ADL LEASE: 25631 PERMIT #: 85-283 SPUD DATE: 12/11/85 COMPLETION DATE: 01/14/86 SURFACE LOCATION: 865'FSL,838'FEL,SEC7,T12N,R9E TOP OF KUPARUK: 1161'FNL,3717'FEL,SEC7,T12N,R9E TD LOCATION: 895'FNL,3959'FEL,SEC7,T12N,RgE ORIGINAL RIG RKB: 71 MSL PAD: 41 MSL REVISION DATE:03/05/86 TUBING SPOOL: 24 MSL 16" 62.5# H-4O ca lO4 SSSV: BAKER FVL ID ca 1804 9.625" 36# J-55 ca 3681 SBR' BOT PBR ID ¢ 7518 PKR' BOT HB 7530 BLAST JOINTS PKR: BOT lB NOGO: CAMCO 'D' NIPPLE 2.25" ID ca 7776 SHEAR OUT: BOT 7764 7784 7" 26# J-55 ca 8145 / XXXI XXX XXX XXX IIIIIIIII IIIIIIIII I I_ GLM1 Ca 7474 / 1.5" GLM2 Ca 7568 / 1.0" GLM3 Ca 7637 / 1.0" '1 7694 - 7730 12 SPF GLM4 ca 7746 / 1.0" 2.875 6.5# J-55 EUE TUBING TAIL ca 7785 _'1 7834 - 7852 4 SPF -I 7864 - 7908 4 SPF _'1 7922 - 7952 4 SPF PBTD 8063 , PBTDSS 6202 AAZ [~Pang[ BXVEB UJfl~T · , ,HECBA#ICA_t, ZNT~G...nX~ I I I I I II pa&.1,1t3,T! ,STill'ii 15 IIZll. . I I I I I C&sIBG I I ~ TXHE II 3OHX' Ii l~ I I Il[Il I I Ill Ill ~onn.u~l~l UTI lTeo ITII:ST ~ ;.G .,,., ;,.,,,, ,,., ,~. ,~.~,,,,,, I~ I~ , . Coftt... C_nf. Pr~_ oo ~ · Pr__m_ · ¢OIOlEll'r~ ,,~--I I ~.., ,,-,-~ , ,/...-~--., ,, ,,,o [ ' l ,-~:: '~ ~,oo' .j,,,l I I I t" I 1'-~-- I II I " 1- I _.___1 I I I .~! . ,_1 , I I I 1 ____.1 I I I ....I _ I _1 I I I _ I I I I 1 I: _1 I I:: I .. I I I I_.___1 _ I _.1 I .. . I .I ~1 I I I~1 I I I I .1 I I I. ,I I I I I .... I _ I I I I., I _ _1.._ I I I I ..__..__1 I I I _ I _1. I I I I 1 I I I 1 1 I I I I I I I I I 1 I 1 I /..;,9o.. I./,r'f~, I I_/_~'~o. l I I t I I I I I I 1 I I I I I I 1 I I I I [ I I I _ I I I I I I I I I I I I I 1 ! I I I I I J I I 1 I I I I I I I t .I I I I I I _1 I ... I I I I I I I I I I I .t _ P · IPl~odmoe Water XmJ. :s . :Stair tiler lmJ. G = Gu loJ. I · lot XmJeettn( Ammul&r Fluid: Glyool :Sail. Muter Drilltns b Other OLbe~ Company llep. $lflmt~Are: IJjle t ~ UaL , , .,,, ............. . i .... i ' ' i i i i . i , , [. Il mill , 'm I I m I I I I I ~,~ · . I m I I I I I II I I . , .. .i . i 411B11~ I)LIEL'IT~ FI,U/D: S - SI~ I,~ 1]U I~ - mSCl~ I ' ~J~CrOl; · II - NC/[' 20 ~ 3) MC 2O Am: 25.2'j2(d) 3A-15 PRESSURE TESTING OF ANNULUS and TUBING EVENT < ..... TI M E .... > <--CASING PRESSURE---> <--TUBING PRESSURE---~ (Csll-Tbg) DATE /TEST BEG ! END I ,~HR BEG ! END I /~P I,~P/,~'I BEG I END I ,*,P ,~P//~'I BEG END REMARKS MIT IN ACCORDANCE WITH GUIDELINES FOR WELLs ON INJECTION--C SAND OPEN Well on injection, diesel in cs_cl. 8/26 MTPoncscj=2120 8:40 9:10 0.50 2120 2100 ~-20 -40 1570 1590 20 40 33 -7 On injection, Q=1134 BWPD. Bleed csg to1100 9:20 9:50 0.50 1100 1700j 600 1200 1590 1600 10 20 -1007 -417 Oninjection~ Q=1250 BWPD. · .- -- _ PRESSURE TESTING W/ C SAND DUMMIED OFF AND A-2 BLANKING PLUG IN D NIPPLE Diesel in tbcl. and cscj. Charts used to record pressures 10/19 Bleedtbgto0 9:35 10:00 0.42 1400 1450 50 120 0 1400 1400 3360 1400 50 -Csg dropped to 1350#before stabilizing at 1450 # 10/21 Ble~dtb.cjto0 23:45 23:47 0.03 1200 1200 0 0 .0 1350 1350 40500 1200 -150 '-Csgremainedconstant@ 1200" 10/28 E~leedcsgto500 1:45 3:00 1.25 500 1150 650 520 1200 1200 0 0 -700 -50 -Tbg dropped to 1100 #before stabilizing at 1200 # 10/28 Bleedtb;ito0 8:45 9:00 0.25 1150 1150 0 0 0 1200 1200 4800 1150 -50 -Csgremainedconstant@ 1150 10/29 ~ Bleed csg to 500 4:30 5:30 1.00 500 1100 600 600 1200 12'00 0 0 -700 -100 -Tbg dropped to 1100 #before stabilizing at 1200# 10/29 Pump csg to 2500 8:15 23:00 14.75 2500 1150. -1350 -92 1200 1200 0 0 1300 -50 -Csg gradually dropped back to ~· 1150 # over 15 hrs. JAR 12/12/88 Drill Site 3A A SAND WATERFLOOD PATTERNS 3H-14 31-14 31-08 3J-12 3H-11 3H-04 3H-03 3A-15 3A-13 3A-14 3 16 3J-05 A I I I I 3A 09 ' ' I I ! I 3^-05 3A-11 3A-10 3A-12 3J-01 A 3A-07 3A-05 3A-06 3B-02 3 3 - 3A 01 I -01 i ' 3F-05 3B-16 3F-16 3F-13 3F-07 PRODUCER WATER INJECTOR PATTERN BOUNDARY JAR 9/2/88 WELL: 3A-15 API #: 500292149100 ADL LEASE: 25631 PERMIT #: 85-283 SPUD DATE: 12/11/85 COMPLETION DATE: 01/14/86 SURFACE LOCATION: 865' FSL, 838' FEL, SEC7, T12N, RgE TOP OF KUPARUK: 1161'FNL,3717'FEL,SEC7,T12N,RgE TD LOCATION: 895' FNL,3959'FEL,SEC7,T12N,RgE ORIGINAL RIG RKB: 71 MSL PAD: 41 MSL REVISION DATE:03/05/86 TUBING SPOOL: 24 MSL 16" 62.5# III H-40 Ia 104 _111 I_ II SSSV' BAKER FVL II,. / ,, ID (a 1804 ' 9.625" 36# J-55 L'a 3681 -x~i'~ (Tq') -GLM1 ¢ 7z~74 / SBR: BOT PBR L4-/,~.~ PKR: BOT HB Ia 7530~X~XXIIIXXX}/?~ ~~1/"~1 GEM2 La 7568 / _~ I( ['~1 GEM3 e 7637 / ~ B~~;S~e;:::~Z,,j I~l 7694 - 7730 SPF I~1 I I ~~1~.; I 2.875 6.5~ ~-55 EUE ........ ~ ~wz~ ....................... ': Z I 78~S P F _1 7864 - 7908 4 ~1 7922 - 7952 4 SPF 7" 26~ J-55 ~ 8145 /////////I PBTD 8063 , PBTDSS 6202 /////////! WELL: 3A-15 API #-500292149100 ADL LEASE: 25631 PERMIT #- 85-283 SPUD DATE. 12/11/85 COMPLETION DATE' 01/14/86 SURFACE LOCATION. 865' FSL, 838' FEL, SEC7, T12N, RgE TOP OF KUPARUK' 1161'FNL,3717,FEL,SEC7,T12N,R9E TD LOCATION. 895' FNL,3959' FEL,SEC7,T12N,R9E ORIGINAL RIG RKB' 71 MSL PAD' 41 MSL RE~i'S I ON DATE' TUBING SPOOL· 24 MSL o~ ~ -- .03/05/86 16" 62.5# H-40 ca 104 SSSV: BAKER FVL ID ca 1804 9.625" 36# J-55 ca 3681 SBR' BOT PBR ID ca Z~l_8 PKR: BOT HB ca 7530 PKR' BOT lB ca 7764 NOGO. CAMCO 'D' NIPPLE 2.25" ID @ 7776 SHEAR OUT' BOT ca 7784 7" 26# J-55 Ca 8145 XXXl IXXXl I* I- _1 I- I__ I IIIIIII1~ !11111111 -- GLM1 Ca 7474 / 1.5" GLM2 ca 7568 / 1.0" GLM3 ~ ~ 7637 " :1 7694 - 7730 12 SPF GLM4 ca 7746 / 1.0" ~ r..~,,~,,,,v-.~ ~',~../j . · 875 6.5# 'J-55 EUE TUBING TAIL ca 7785 · 1 7834 - 7852 4 SPF I 7864 - 79O8 4 SPF '1 7922 - 7952 4 SPF PBTD 8063 , PBTDSS 6202 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CPM M I,..,,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ RePair we~t v/ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugg~gg __ Time extension __ St~rnulate __ Pull tul~r'~:J ~ Variance __ Perforate __ Other __ 2. Name of Operator ARCO A1 aska . I nc . 3. Address P. 0. Box 100:360~ Anchorac. l.ea AK 99510 4. Location of well at surface 865' FSL, 8:38' FEL, Sec.7, T12N, R9E, UM At top of productwe interval 1161 ' FNL, 3717' FEL, Sec.7, T12N, R9E, UM At effective depth 916' FNL, :3941 ' FEL, Sec.7, T12N, R9E, UN At total depth 895' FNL, 3959' FEL, Sec.7, T12N, RgE, UH 12. Present welt condition summary Total depth: measured true vertical 81 60 ' MD feet 6:340'TVD feet I5. Type of Well: ~ Development Exploratory Stratigrapn~c 0:3 60 Service Plugs (measured) Effective depth' measured 806:3 ' M D feet Junk (measured) true vertical 6274. ' T V B feet Casing Length S~ze Cemented Structural Conductor 80' 16" 171 sx AS I I Surface :3657' 9-..5/8" 1510 sx AS I I I & Intermediate 310 sx Class C Production 8121' 7" 450 sx Class G & L~ner 1 75 sx AS I Perforation depth: measured true vertical 6. Datum elevabon (DF or KB) RKR 72 ' 7. Umt or Property name Kuparuk River Unit feet 8. Well number 3A-15 9. Permit number Rc,-2R~ 10. APl number 50-- 029-21491 11 Field/Pool ~one Pool N o n,..~k~.0il & Gss Cons, Commission -'~. A,'~chorage Measured depth True vertical depth 1 04 ' MD 104 ' TVD 3681 'MD 3147'TVD 8145'MD 6331 'TVD 7922'-7952'MD, 7908'-7864'MD, 7834'-7852'MD, 7694'-7730'MD 6178'-6199'TVD, 6168'-6139'TVD, 6118'-61:30'TVD, 602:3'-6048'TVD Tubing (size, grade, and measured depth) 2.875", J-55 tubing with tail ~ 7785'ND Packers and SSSV (type and measured depth) 555V Baker FVL 1811'; pkrs: B0T HB 75:37', B0T lB 7764.' 13. Attachments Description summary of proposal v" Detailed operations program __ BOP sketch v/ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: ! Oil ' Gas__ Suspended__ Service. f~ct ¢e¢ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. / FOR COMMISSION USE ONLY Conditions of approval'. Notify Commission so representative may witness (JWB) SA4/025 I Approval NO. Plug integrity I BO.P/Test __ Location clearance __ Subs¢~luent form required 10- Mechanical Integrity Test .~ Approved Copy ORIGINAL SIGNED BY Approved byorderoftheCommissioner LONN1E C. SMITH ~ ... ~rn . . ,..,o,m,n';, ,iSS~O ne r Form !0-403 Rev 06/15/88 SUBMIT IN TRIPL!CATE KRU 3A-15 General Procedure REPLACE TOP PACKER Pre-Rig Ooerafions E_nsure that a plug is still set in the 'D' nipple and obtain C sand BHP. Cut tubing with chemical cutter below the second GLM between the packers. Rio Ormrations -- 1. MIRU Nordic. Pull the dummy valve from the first GLM above the top packer. 2. Kill well with a Temblok pill and 10.9 ppg brine. 3. ND the tree. NU and test BOPE. 4 POH w/tbg, changing out couplings to AB MOD. 5. GIH with pkr retrieving tool, picking up drill pipe. Retrieve pkr and tbg down to the cut made below the second GLMin pre-rig operations, 6. GIH with an overshot and fishin~ BHA on 3-1./2" tbg. Fish blast joints. 7. Make a clean out run with 1-1/4 CS Hydril tail pipe, Run a csg scraper to the _permanent pkr and enough 1-1/4" to clean out any fill on top of the D nipple. 8. GIH with a packer on 3-1/2" DP to +/-7525. Test csg for 30 minutes. 9. POH LDDP. 10. Run new completion with steel blast jts and 1-1/2" GLM's across the C sand, Completion Fluid = Expected BHP = ;~1~o ~,' Anticipated Start = ANNULAR PREVENTER 6 PIPE RAPI$ 4 BL I ND RAI'IS '5 TUBIIm HEAD 16' C(~XJCTOR SWAGED TO 2. 11'-$000 PSI STARTING HEAD 3. I 1 *-3000 PSI X 7- I / ! 6'-$000 PSI TUBING HEAD 4. 7-1 / 16' - 5000 PSI P~PE S. ?- 1 / 16' - 5000 PSi BLINO laAIqS 6. 7-1 / 16' - 5000 PSI ANNULAa .0il & G~ L~o~s~c,m~is~io~L i CAPACITY TEST I. CHECK AND FILL ACCLeIULATOR RESERVOIR TO ~R LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT AC~ATOR I:~:~S~ iS 3000 PSI WITH 1500 PSI ~TI~A/'I ~ THE I~(~LATOR. 3. 0~S~RVE rlr'lE. TH~N CLOSE ALL UNITS $11~ULTANE~Y REC01~ THE TII~ ANO I:~ESSUI~ REPIAINII~ AFTER ALL UNITS ARE CLOSED ~TH ¢HARGIN~ ~ ~F. 4. REC01~ ON ~ IADC I~Ja(~T,. THE ACCEPTABLE LCTW~R LIr'IIT I$ 4~ SECGI~S CLOSIN~ TII'IE AND 1200 I~1 Rf. PIAINING PRESSURE. BOP STACK TEST 1. FILL BCX~ STACK AND I'IANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-0OWN SCDEWS AI~ FULLY I~TRACTED. PREDETERI'I~NE DEPTH THAT TEST ~LUG WILL SEAT Al, CO SEAT tN WELLHEAD. I~UN IN LOCK-OOWIq $CRLrWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND ,:HOKES ANO BYPASS VALVE5 ON THE r'IANIFOLD. 4. TEST ALL C0t~0NENTS TO 2S0 PSi AND HOLD FOR 10 MINUTES. 5. iNCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 ~INUTES. BLEED TO Z~I~O PSi. 6. CX~N ANMJLAR PREVENTER AND CLOSE PIPE 7. INCREASE I~ESSURE TO ~5000 PSI ANO HOLD FOR 10 r'IlNUTES. B. CLOSE VALVES 01RECTLY UPSTREArl OF CHOKES. BLEED DOWNSTREAM PI~S$1.11~ TO 7FRO PSI TO TEST VALVES. TEST REf'IAINING UNTESTED I'IANIFOLD VALVES. IF ANY. WITH 3a:X)O PSI UPSTREAPI ~ VALVE ANO WITH 7~RO PSi 0(::k~STREA~. BLEED SYSTEI~ TO ~RO PSI. g. Olin PlI~ RAt'IS. BACKOFF RUNNING JOINT ANO PULL OUT (~ HOLE. CLOSE BLIN0 RAMS AND TEST TO 5000 PSI FOR 10 I~tlNUTES. BLEED TO ZgaO PSI. 10. OPEN BLIND RAftS ANO RECOVER TEST PLUG. MAKE SURE rlANIFOLD AND LINES AI~E FULL C~ AaCT:C DIESEL AND ALL VALVES ARE SET ~N rile DRILLING I 1. TEST STANOPIPE VALVES TO 3000 t2. TEST KELLY COCKS AND INSIOE BOP TO :5000 PSi WiTH KO0t~Y IoUr~P. 13. RECOR0 TEST INFORUAT1ON 0N BL0W(~T PREVENTER TEST FORM. ANO SEN0 TO 0RILLiNG SUPERVISOla. 14. IoERFORI~I C0eqPLETE COPE TEST ONCE A W~EK AND FUNCTIONALLY OPERATE BOPE 0AtL¥. dO ,JULY 28, 1986 ARCO Alaska, Inc. Post Office Box !0, 360 Anchorage. Alask~ '~9510-0360 T,._~lephone 907 27(- October 18, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. Well Action 3 A- 1 5 Conversion 3 A- 1 4 Conversion 3 A- 0 6 Conversion 3Q- 1 5 Fracture 3 I- 03 Fracture 1 Y-1 5 Conversion If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber ATO 1478 M. L. Hagood ATO 1120 S. P. Twiggs ATO 1130 KOE1.4-9 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 865' FSL, 838' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1161' FNL, 3717' FEL, Sec. 7, T12N, R9E, UM At effective depth 916' FNL, 3941' FEL, Sec. 7, T12N, R9E, UM At total depth 895' FNL, 3959' FEL, Sec. 7, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8160' 6340' feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 72' 7. Unit or Property name Kuparuk River Unit feet 8. Wetl number 9. Permit number/approval number 85-223 / 7'-?'~' · 10. APl number 5~-029-21491 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 0 6 3' true vertical 6274' feet feet Junk (measured) Casing Length Size Structural Conductor 8 0' 1 6" Surface 3657' 9 5/8" Intermediate Production 81 21 ' 7" Liner Perforation depth: measured true vertical Cemented Measured depth 171 SXASII 104' 1510 Sx AS III & 3681 310 Sx Class G 450SxClassG& 8145' 175 Sx AS I 7922'-7952', 7908'-7864', 7834'-7852', 6178'-6199', 6168'-6139', 6118'-6130', Tubing (size, grade, and measured depth) 2.875", J-55, 7785' MD-RKB Packers and SSSV (type and measured depth) SSSV: Baker FVL 1804', Packer: Baker FHL 7530', 7764' True vertical depth 104' 3147 6331' 7694'-7730' MD 6023'-6048' TVD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaae Production or iniectton Dam OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 138 9O 0 1450 225 Subsequent to operation 750 22OO 1 7OO 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run m Daily Report of Well Operations ~ Oil Gas Suspended · 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 R~v ' 06/15/88 - ! Service Water Iniection Date SUBMIT IN DUPLICATE ARCO Alalka, Inc. Date / - 19me ~w oQ DrilleJte :~/4 Orlllelte Morning Report Prod~ We{I Statul Choke I Tamp Last 1H2S I CSG Pmeaure PSI 1 I I I ,, I ; GM ~, Tamp Gaa Lift Statua Shut-In ] Ini. Rate Hrl ~ Mete~ Total MSCFO i !Stmue! l,q~H~.~ 14'~ Injection Well Status We~l (31, ~i [In~~m ~1 ~m C~ke C~ Pr~ure PSI] Met~ [ In~ Rate i~ ~ I 1~ ~,,~ ~,~,,~, , ~ b~.~o ~ ~ h~~ Shut-In Reason SWl Tot~ 1 "'~.~ ~ PWI Tot~ i Ehgll~lte i Co~l TemperatUre °F" Coil Preaeure PSI ' Bath I Blanket Heate~ Prod I Teat i Prod ' Te~ ' Temp.t Ga~PSI Run Time ou, /&g J/79 - /oo i Chemicals i (3al/Day Heeclecm I Production Water Injection Injection Commenl:l ARCO Alask,., ,nc. Dr~ll$ite Morning Rep(3rt Status pro(3uCtlOn Well Sta[ws Sas ',. '~ Status WelI~P T, or l TP ChoKei TemD Last HzS CSG Pressure PSI Gas ,n. ~a~e ' SI Zone~ PSI Beart ' ~F wCO,~ PPM! 7" ,0' Temp Me,,er Tota~ MSCFD ,',rs Reascr Status - ectonWe, ~'a!~s Srmt-,~ .'red Gl PW !rlect Pressure PSI 're,.~o~ C?o.e CSG ='ess~re PSi Meter ~,ect~on ~ate - or SW Zon~ AIIowaDle Actual SWI Total ) '-~: "~ 3 _~ PWI Tctal 733 t~rtllSlte Cotl Temperature oF Co, P,essure PSI ~atn 8tan~et Heater Prod Test Prod "est -e~"o Gas PSI Clun T,me Chermcais ~eaders P,oduct~on ,*Cater ~r'lect~on .3as injec::or' ..~as L,ll ese, ARCO Alaska. Inc. .: .... ~ September 2, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 2 X- 1 3 Fracture September, 1 988 3A- 1 5 Failed MIT September, 1 988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown . Re-enter suspended well . AFter casing T~me extension Change approved program Plugging ' Stimulate .' Pull tubing Amend order ' Perforate Other 2 Name of Operator ARCO Alaska~ Inc. 3 AddFess P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 865' FSL, 838' FEL, Sec. At top of productive ~nterval 1161' FNL, 37[7' FEL, Sec. At effective depth 9]6' FNL, 3941' FEL, Sec. At total depth 895' FNL, 3959' FEL, Sec. 7, T12N, R9E, UM 7, T12N, R9E, UM 7, T12N, R9E, UM 7, T12N, R9E, UM 5. Datum elevation (DF or KB) RKR 72 feet 6. Unit or Property name Kuparuk River Unit 7. Well number 3A-15 8. Permit number 85-223 9. APl number 5O-- 02921491 10. 'P°°[Kuparuk River 0il Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3657' Intermediate Production 8!21' Liner Perforation depth: measured 8160' 6340' feet feet Plugs (measured) 8063' feet Junk (measured) 6274' feet Size Cemented 16" 171 Sx AS II 9-5/8" 1510 Sx AS I I I & 310 Sx Class G 7I' 450 Sx Class G & 175 Sx AS I 7922' -7952', 7908' -7864', 7834' 8063' Measured depth True Verticai depth 104' 104' 3681' 3147' 8145' 63311 -7852', 7694'-7730' MD true vertical 6178'-6199', 61681-6139', 6118' Tubing (size, grade and measured depth) 2.875", J-55, 7785' MD-RKB PackeFs and SSSV (type and measured depth) SSSV: Baker FVL 1804', Packer: 12.Attachments Description summary of proposal 2~ Problem description, proposal, and MITs. 13. Estimated date for commencing operation September 1988 -6130'R 'dVD BakPr FHI 7~.':10.' _~,I~,l & Oas Cons. Detailed operations program 14. If proposal was verbally approved Mike Minder Name of approver 8/30/88. Date approveo 15. I hereby certify that the f~regoing is true and correct to the2st of.,rny knowledge Signed .::i~_/7 ~ /,~~~?~~itle .¥,~/, ~;,rC.,.j~q,¢..~.,.~.~,' ~'..~ Commission Use Only '~'/ Date Conditions of approval Approved by Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval No. '- Plug integrity '- BOP Test % Location clearance~ ~ --~"~ Approved Copy Returned ,~, LONNIE C. SMITH by order of Commissioner the commission Date Submit in triplicate ATTACHMENT TO APPLICATION FOR SUNDRY APPROVAL WELL 3A-15 AUGUST 31, 1988 Well History and Problem Description Well 3A-15 was converted to water injection 1/16/88. A mechanical integrity test was performed on 1/15/88 (attached) and passed in accordance with AOGCC rules. Fluctuations in the 7" casing pressure (tubing/casing annulus) raised concern about an improperly seated or leaking dummy valve. The dummy valve in the single gas lift mandrel above the packer was replaced three times but the problem persisted. Diagnostic testing indicates that the PBR and possibly the top packer (see attached well bore schematic) are leaking. An MIT (attached) was performed in accordance with AOGCC guidelines for wells on active injection. The well failed the second part of the MIT performed August 26 (Casing Pressure = Minimum Test Pressure - 1000 psi). Mike Minder of the AOGCC was notified of the problem August 30 and granted verbal approval to continue to inject water into 3Ao15 for one week, pending submission of this Application for Sundry Approval. Pr~)Do~;ed Course of Action ARCO Alaska, Inc., proposes to pursue investigating said problem to further identify the nature and location of the leak(s). Upon satisfactorily locating the leak(s), a corrective course of action will be pursued or a variance to continue to operate with acceptable monitoring activity will be sought. The current Application of Sundry Notice seeks permission to continue injection while investigating this problem. c WELL: 3A-15 API #: 500292149100 ADL LEASE: 25631 PERMIT #: 85-283 SPUD DATE: 12/11/85 COMPLETION DATE: 01/14/86 SURFACE LOCATION: 865'FSL,838'FEL,SEC7,T12N,R9E TOP OF KUPARUK: 1161'FNL,3717'FEL,SEC7,T12N,RgE TD LOCATION: 895'FNL,3959'FEL,SEC7,T12N,R9E ORIGINAL RIG RKB: 71 MSL PAD: 41 MSL REVISION DATE:03/05/86 TUBING SPOOL: 24 MSL 16" 62.5# I H-40 ca 104 _1 SSSV: BAKER FVL ID ca 1804 9.625" 36# J-55 ca 3681 SBR' BOT PBR ID ca 7518 PKR- BOT HB ca 7530 BLAST JOINTS PKR: BOT lB NOGO: CAMCO 'D' NIPPLE 2.25" ID ca 7776 SHEAR OUT: BOT ca 7764 ca 7784 XXX xxx. I I I I- XXX XXX I I_ - GLM1 ca 7474 / 1.5" GLM2 ca 7568 / 1.0" GLM3 ca 7637 / 1.0" 7694 - 7730 12 SPF SLM4 ca 7746 / 1.0" 2.875 6.5# J-55 EUE TUBING TAIL ca 7785 7" 26# J-55 ca 8145 IIIIIIIII IIIIIIIII 7834 - 7852 4 SPF -I 7864 - 7908 4 SPF 7922 - 7952 4 SPF PBTD 8063 , PBTDSS 6202 011. Alll} GMiS, ~ATIOI (X)HISSIOI DIESEL Stat talkTl~ lmTI l.'ll~ In) 20 AAC 25.0:)0(a) 20 AdkC 2,%.&12(c) 20 At, d; 25.252(d) Location: Drillalte: =: 3~__ ...t~ I I I ,,,.,' '[ If I ..__..__ I I I . I ~ I l ~1 I I I I 1 ~1 I 1 . 1~ =1 I I I I · . I J . 1 I I I ~I___L_I ~1 I 1 _1_ I _1 ~1 I I _ _ _1 _1... 1 I I I _ I I I $ ', I I I~_ I I I 1 1_ I 1 I I I I._~ I ! I 1 I I~1 1 I I I I 1 I _.1 I I I I I .I I I I I 1_ 1_ I COIgl~S I I. I i I I I I I I I I I I I I I I I I I ! I 1, I I I i ~ I .1 l I ..... I I I I I 1 I I I I I I I ! I ! I I I I I I I I I I I I I 1 I I I I I L __. 1 I I I I I I I I i I 1 I I I I I I I I I I I _. I _ = _ ~mular Fluid: Glycol Salt 1dater Drlllln~ I~d Other OLher Gradient: Company Rep. $Ignatur®: Date: ARCO Alaska. Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1988 Transmittal #: 7094 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-8 1G-16 3H-9 3A-6 Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Data Frac Pressures BHP Data Worksheet Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) 12-23-88 Static 2-8-88 Static 'C' Sand 1-15-88 1-3-88 #94225 1-15-88 Static 'A' Sand 1-15-88 Static 'C' Sand HAPPY VALENTINE'S DAY Receipt Acknowledged' DISTRIBUTION' D &M State of Alaska Chevron Mobil SAPC Unocal STATE OF ALASKA ALA~, \ OIL AND GAS CONSERVATION CON .~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown Re-enter suspended well Alter casing Time extension Change approved program - Plugging % Stimulate Pull tubing Amend order Perforate Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska: In¢, RKB 72' feet 3. Address 6. Unit or Property name P.O. Box 100360~ Anchorage~ Alaska 99510 Kuparuk River Unit 4. Location of well at surface 7. Well number 865' FSL, 838' FEL, Sec. 7, T12N, R9E, UM 3A-15 At top of productive interval 8. Permit number 1161' FNL, 3717' FEL, Sec. 7, T12N, R9E, UM 85-223 At effective depth 9. APl number 916' FNL, 3941' FEL, Sec. 7, T12N, R9E, UM 5o- 029-21491 At total depth 10. Pool 895' FNL, 3959' FEL~ Sec. 7~ T12N~ R9E~ UM Kuparuk River Oil Pool 11. Present well condition summary Total depth' measured 8160' feet Plugs (measured) 8063' R E [ E I V E D true vertical 6340' feet Effective depth' measured 8063 ' feet Junk (measured) '-' ' · ' '~ ,~ true vertical 6274' feet Alaska Oil & Gas Cons. C0mmissi0F., Casing Length Size Cemented Measured depth Arlc'~ijSg~ertical depth Structural Conductor 80' 16" 171 SX AS II 104' 104' Surface 3657' 9-5/8" 1510 Sx A.S. III 3681' 3147' Intermediate 310 Sx Class "G" Production 8121' 7" 450 Sx Class "G" 8145' 6331' Liner 175 Sx AS I Perforation depth: measured 7922-7952, 7908-7864, 7834-7852, 7694-7730' MD true vertical 6178-6199, 6168-6139, 6118-6130, 6023-6048' TVD Tubing (size. grade and measured depth) 2.875", J-55, 7785' MD-RKB MD Packers and SSSV (type and measured depth) S$SV: Baker FVL 1804', Packer: Baker FHL 7530', 7764'. 12.Attachments Description summary of proposal _~_ Detailed operations program BOP sketch Convert to water injection. 13. Estimated date for commencing operation December, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the fo. zregoing is true and correct to the. best of, my knowledge Signed. ~:L,4. ?~1f .,l.-w. ~,,t,~'/ Title /~~~...,~.~.! .~ Commission Use Only Conditions of approval Date 7 (~ ~/ ~ ? Approved by ; · Notify commission so representative may witness I Approval No. - Plug integrity ~ BOP Test _- Loc. ati.on c. lea~rance[ ¢- '~/~/ ,-' by order of ~ ~,~ ~ . ~,~ - Commissioner the commission Date /Lr': - -- ~ Form 10-403 Rev 12-1-85 Submit in triplicate ROUTING AND TRANSMITTAL SLIP TO: (Name, office symbol, room number, , J InitiMs J Dlte building. Agency/Post) , ~t,on I /~:"e Approval ,~s Requested Circulate Comment Coordination I~EMARKS I i For Clearance I I For Correction I IF°r Your Iniormatlon ,I ',1'nvestlgate I IJusti,fy I Note and Return IPer Conversation I Prepare Reply i See Me ,Islgnetur" , __--..z,:~' c~/~,o~, ---: / , . z..,-~ ~~ /~'"""" ~' . ~/ L. ".' . this fo~ as a RECORD of approvals, concuffences, dle~als, ~. clearances, and similar actions ' Fr~OM: (Name, org. ~.ymbol, Agency/Post) ~3,11-102 ' au.s. GPO: 1116.--491-247/40002 . Room No.--Bldg.. Phone No. OPTIONAL FORM 41 (Rev. 7-76) P~'ll¢lillld Ill SSA IrpMR (41 CFR) 101.1 !.208 THURSDAY 9 12 3 j ', .., ~°%4 ~. . ... / I~ 2 NOON r 11 , /' ~.~4uRsDAY 10 ~oo~ 2 ~ ~O~o~ C) mmmm,, mmm ? ~'~. / ' ~--~.~ ": ~ i .~.~ .~-7-. ........ -, :/., ~.-' .-. ...... · - ~' ,'.~ .' '.. i'"',.: '/ "/ · ,~' '.,t ' '' / ' I '. ' · " I ' ' ' ¢' '¢ "~' ' " ' ". "~ I', ~ '% / ,, /. '- . ¢~ '", !"..; '". ~" '! ~ '! ,t' ' ~ " , '.l '/' ~'.. ".,~ '' ".,' ¢ · / -.~ "- '~ " "' ' '"' ~' "'t '¢ ,. . , ., . . , . . ~,. . x'~--.~ . . .,~ ~ ', ..... / ". i'. ''..' . . ."' , .. .'.::-:L'~:_,:' .' ". ', '" 7" .',,, ". ,. ~ ',.: "" ·. /.· . ¢ . -~ "-,,,,~ ",. ,"..,' ""..... ..... /'"./"..,: "'/' ," ,' .' .' . '/". "-.'/~'.. "'.'- ."'X':.~ ~ .--.',.~':-:.~ , .' -, ' ~ '."",-< t. ,~. , · , ,,., , ', . ..... ,, . , . .; . ,, ~ ... ~ ----~,,;~-..- . · .. · . .... ~.. ., ,. ' -,,,'/""./" .... ".; "',... ". ,'. -" ' , . ' ,'.' ."./.','~. "Cx .'~-' ~., · ' ~'. ~..~ ;., '" ,,". ,"~-4' ,' ....... :"'.,'.. 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'..~ '~ i ~ '" , ~ ,, ~. ,' ,y..,~, ~, ,'. ~ , . , ~ ; .., ,,.,, ~ /' , ~' t ~, . /, , // . / ~ /' '"' . /, , ,, / / ,. ,'x.x' ,'. ,' ,, //, / /" , ,, /'.// / '/ 7, , ,' , / / //,, .,', / ,/, ./' ,.,. ,,' / ', ~ / , ." ,/. ~ ." / / ,/ :,' , i // / /', ,,,"' ,,' ,/ , /' /,! / / /~ / / II .// /' /. IR- j' NIGHT / lI'. ,, .',, /, ',,,/ ., ',/ ,/ ~ , ,. ,'.. / , . I · '~ /' '' '"" '""'t"'"'"' '".4'. "/,,. '., ! "'; .". ., '" ' %1 ,"! ' · ','" "', ~ .... '' l' ', · , ".1 "., '.1 ~.,. ,. ". , ",. ' ',~ ! ".1 ; ' . ' · · I,,,. / ' . Y'.,,,: ~,, j ',,,,., , ,,, ~ · [. [. ', ,. , , ~ , ,"'-. ,' ."".,..,/ ".... .... I, ! ... ' . ' ". ' ,. . .'"'<..~"~ ..... '." ...'....,.:.7"/..i'i,. ...... Z;.....:.'.. ...... '..:,'..'..... . l'.,..., ,.,Z~.",,.!...,t' '.., ...... ,"...i ..... .. '.. '. ..... ,. ., · · "':.... ~'. ;'~ ..... :. : ....... .... .... .. ,. .,' '. ....... : ':,,.../ :~ : "i..,." .,,.,. ' ...... · ..' ... · '." " ....'"'1 ~"~'"- ' : .... ' .... ' ' ' "' '. ' il',..~ ~ 'lll~. %~lj I ' i . . ' ..... I I JI I ' ' J I l .......... : .".....;, .: '! .,..... ~"~, · ..... ... .. '.. ~.. .. 't'" .1 " '' .... . ' '~'"-; '" ' "'" ". ' .... ! I""'- ' ......... ' ......' ........ iii ' ..... i ":"":....I....i.'I'."'"'i .......... ,7'. ~ ...... ::::::.::::..: -.".':-.-' .... ' .. ': ...... :----L-.4 ................... · ... ":'- ..~- ..L_. ,_.'. ........ ; .............. . ..~,. ............ ;-.--"... L _',. _:~ ..: _..,_...~ ............... . 3,.: · -. ,..t....'i.: ' ' -"..---". ...... ' ~ , ~ · .. . .... , \ , ,, NOON A¥OS~IFIH.L ,. . £ ~,t 6 ,%, THURS,)4), 9 12 ~9 / / . ,, . .~, ARCO Alaska, Inc. Post Office B( .)0360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal ~5806 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: CET/CEL 10-12-85 Run ~2 8600' CET/CEL 10-13-85 Run #3 8550' CET/CEL 10-02-85 Run #1 6795' CET/CEL 10-01-85 Run ~1 7550' CET/CEL 10-01-85 Run ~1 6680' CET/CEL 10-01-85 Run #1 6080' CET/CEL 12-30-85 Run ~2 6400' CET/CEL 12-30-85 Run ~2 7300' CET/CEL 10-!5-85 Run fl 5887 CET/CEL 10-15-85 Run ~1 3995 CET/CEL 10-!7-85 Run ~1 7000 ,CET/CEL t2-19-85 Run ~1 5166 CET/CEL 12-19-85 Run ~! 6950 CET/CEL 10-05-85 Run ~1 6860 CET/CEL 10-19-85 Run ~1 7000 CET/CEL 12-18-85 Run ~1 36 - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 - 6678 Receipt Acknowledged: .. ~--~.~ ' ' ';" D'a t~ .-1~8~___~_~_. ~ n~ ~ +. ~ ~,, - / / \ A',~k~ Oil & ~.~s Co,~. ~om,,~,i~i~n. K Drillino Vault(1 film) Inc. I$ 2 Subs~c,ar? o< Ali~,nhcRt(.hf~-.dCOmpan) STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Ci,,ss~f~cat~on of Se'~c,' ,',,,I, OIL ..... --XX GAS -- SUSPENDED -- ABANDONED -- SERVICE -- 2. Name of Operator ARCO Alaska, Inc. I 7. Permit Number I 85-283 3. Address i 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 : 50 029-21491 4. Location of well at surface 9 Uqlt or Lease N,~me 865' FSL, 838' FEL, Sec.7, T12N, RgE, UN Kuparuk River Unit At Top Producing Interval 1161' FNL, 37!7' FEL, Sec.7, T12N, RgE, UPI At Total Depth 895' FNL, 3959' FEL, Sec.7, T12N, R9E, UPI 5. Elevation in feet !indicate KB, DF, etc./ ] 6. Lease Designation and Serial No. 72' RKB I ADL 25631 ALK 2565 12. Date Spudded 13. Date T.D. Reached 12/11/85 12/17/85 17. Total Depth (MD-TVD~ 18.Plug Back Depth(MD-TVD) 8160 'ND,6340 'TVD 8063 'ND,6274 'TVD 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 10. Well 'X~um!)er 3A-15 _ I 1. F~el(~ dn(~ Pool Kuparuk River Field Kuparuk River 0il Pool 14. Date Comp., Susp. or Aband. [ 15. Water Depth, ,f offshore Z 16 '~'~ of C.')mp ,~':'on* 12/18/85' I N/A ~eet MSL 1 19. Directional Survey I 20. Depth ,.*,here SSSV set 21 Thick. ness of Pc're,i!' -.,st YES ~ NO _-- [ 1811 feet ;,ID 1550' (approx) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD , ,, CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE ! CEMENTi%G RECORD A,MOUNT PULLED 16" 62.5# H-40 Surf 104' 24" ' 171 sx AS , 9-5/8" 36.0# J-55 ' Surf ! 3681 ' 12-1/4''I 15!0 sx AS III & 310 sx Class G , 7" ~ 26.0# J-55 I Surf i 8145' 8-1/2" 450 sx Class C & 175 sx AS 24. Perforations open to Production (MD-TVD of Top and Bottom and interval, size and number) 7922' - 7952' 7908' - 7864' w/4 spf 7834' - 7852' 7694' - 7730' w/12 spf 25. TUBING RECORD SIZE ! DEPTH SET ,:',,1D, PACKER SET 2-7/8" 7785' 7537' & 7764' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH iNTERVAL ~,*,.!D~ i AMOUNT & KIND OF MATERIAL USED See attached Addtndum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production Date of Test Flow Tubing Press. Method of Operation (Flowing, gas lift, etc.~ Casing Pressure Hours Tested iiTEsT!PRODUCTION FORIOIL-BBLpERIOD I~ IGAS'MCF ! WATER-BBL i CHOKESIZE I! GAS OIL RATIO 'CALCULATED OIL-BBL i GAS-MCF WATER BBL 24-HOUR RATE ~ 28. CORE DATA OIL GRAVITY APl Icor~. BriefNonedeScription of lithology, porosity, fractures, apparent dips and presence of oil, gas o~ water. Submit coreRECEIV APRO ~ 1.986 Amm~ 0~ & Gas Gens. ~om~ Form 10-407 * NOTE: Tubing was run & well perforated 1/14/86. GRU1/WC13 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. N AM E :, GEOLOGIC MARKERS MEAS. DEPTH Top Kuparuk C 7668' Base Kuparuk C 7732 Top Kuparuk A i 7816' it Base Kuparuk A ii Not logged J 30 TRUE VERT. DEPTH 6005' 6049' 6106' FORMATION TESTS Include interval tested, pressure data. al', ;!u,ds ~ec(,,,~,e(l an[] ,qrdv G©R, ano time of each phase N/A LIST OF ATTACHMENTS Addendum (dated 2/27/86) ! hereby certify that the foregoing is true and correct to the pest o' ~'y ,~no,.~.'ledge Associate Engineer INSTRUr'TiONS. v. General' This form is designed for submitting a comr~ete and correct wel completion re.l~,';r't and all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air inieC/,iorl, sai' 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 .measuren~,ents 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 shov¥ the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this wel should show the details of any multiple stage cement ng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift Rod Pump, Hydraulic Purnp, Submersible, Wat~.~r Ir~ jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Foq',' 10 4Q7 ADDENDUH WELL: 12/30/85 1/02/86 3A-15 Arctic Pak w/175 sx AS I, followed by 63 bbls Arctic Pak. Rn CET log f/8044' ~LM to TOC @ 6500'. Rn GCT gyro. FRACTURE STIMULATION SU]~ARY Begin Frac Work At: 1305 hrs, 2/7/86. AFE: AK0375 Frac Kuparuk "A" sand perfs 7834'-7852', 7864'-7908' & 7922'-7952' in 3 stages per 1/31/86 procedure using gelled diesel w/20/40 mesh sand. Press'd ann to 1420 psi w/diesel. Tst ins to 8500 psi; OK. Pmp'd 45 bbls 5% Musol + 46 bbls diesel prior to Stage 1. Stage 1: 31 bbls gelled diesel pad @ 5.4 BPM w/final pressure of 2980 psi. Stage 2: 24 bbls gelled diesel w/20/40 mesh @ 5.2 BPM w/final pressure of 2930 psi. Stage 3: 45 bbls gelled diesel flush @ 20 BPM w/final pressure of 5320 psi. Pmp'd 4354#, 6 ppg 20/40 in formation leaving 396# 20/40 mesh sand. Job underflush by 2 bbls in 7" csg. Load to recover 199 bbls of diesel. Job complete @ 1415 hrs, 2/7/86. APR 0 3 1988 Drilling S~]perintendent / Irate ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 February 24, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3A-15 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, .. Cruber ^ssoc~ate [n~neer JG/tw GRU13/L151 Enclosures RECEIVED FEB28 1986 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COlwMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well C~Jss~f~cat,on of S(~. ,ici, ~'.t~,, OII --XX GAS ~-- SUSPENDED ~ ABANDONED ~ SERVICE 2. Name of Operator ARCO Alaska, Inc. 7 Permit Num[)e, 85-283 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 8 APl Number 029-21491 5O 4. Location of ;Nell at surface 865' FSL, 838' FEL, Sec.7, T12N, R9E, UN At Top Producing Interval 1161' FNL, 3717' FEL, Sec.7, T12N; RgE, UM At Total Depth 8951 FNL, 3959' FEL, Sec.7, T12N, RgE, LIN 5 Elevation in feet ~indicate KB, DF, etc.! 72 ' RKB i 6. Lease Designation and Serial No. ~ ADL 25631 ALK 2565 12. Date Spudded 12111/85 17. Total Depth (MD-TV'D) 81 60 1ND ,6340 'TVD 13. Date T.D. Reached 1 2/17/85 14. Date Comp., Susp. or ADand. 1 2/18/85* 9. Uqlt o' Le3Se N,in]e Kuparuk River Unit 10. We~i 'x, umhe~ 3A-15 I 1. F,e;~ ,:rllJ Po!~l Kuparuk River Field Kuparuk River Oil Pool 18. Plug Back Depth /MD-TVD) 19. Directional Survey 806~ 'HD,6274 'TVD YES ~ NO _~ 15. Ware~ Depth i~ 9!;shn,e 16 '\ . ¢;' C ,'hi, et ~< I N/A '~e: %~SL 1 20. Depth .Nhere SSS\' set I ? 1 Th,c. ness ,~f Pe' m.~" ms' 1811 fee:MD i 1550' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Ca1, CET, OCT 23. CASING, LINER AND CEMENTING RECORD i SETTING DEPTH MD i CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE t CE'dENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" I 171 sx AS II 9-5/8",1 36.0# . J-55 i Surf i 3681'i 12-1/4'" 1510 sx AS I!I & 310 sx Class C 71' 26.0# J-55 i Surf 24. Perforations open to Production iMD-TVD of Top and Bottom and inter~al, size and numbe~) 79221 - 7952' 7908' - 7864' w/4 spf 7834' - 7852' 7694' - 7730' w/12 spf 8145' 8-1/2" 25. SIZE 2-7/8II 450 sx Class G & 175 sx AS I TUBING RECORD ? I ~ DEPTH SET ,~,.iD~ P.&CKER SET .'.iD', 7785' i 7537' & 7764' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL ~MD~ / AMOUNT & KIND OF MATERI&L USE.J N/A 27. N/A PRODUCTION TEST Date First Production Date of Test Hours Tested WATER-BBL ! CHOKE SIZE ! GAS OIL RATIO i Nlethod of Operation fFIo~,ing, gas lift, etc.~ ! PRODUCTIONiTEST PERIOD FOR lo' L-BBLI~ CALCULATED ' OIL-BBL I GAS-MCr 24-HOUR RATE Flow Tubing Casing Pressure I WATER-BBL OIL GRAVITY APl Ic,'~rr' Press. 28. CORE DATA Brief description of iithology, porosity, fractures, apparent dips and presence of oil, gas or ,.%ater. Submit core ch,ps None RECEIVED FEB 2 8 1986 Al~ka Oil & ~s Cons. Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run & well perforated 1/14/86. DAI4/WC40 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A EOLOGIC MARKERS 7668' 7732 7816' Not logged TRUE VERT. DEPTH ii 6005 ' 6049' :, ~" 6106' ; ? -- 30. FORMATION TESTS Include :ntervai tested, pressure data, all fluids ,et.: GOR, and t~me of each phase N/A 31 L:~qm OF ATTACHMENTS Well History (drilling & completion details~, Gyroscopic Survey (2 copies) 32 I heresy certify that the foregoing is true anc correct to the best o~ mV ~r'z.-.~eoge Associate Engineer INSTRUCTIONS General' This form is designed for submitting a comolete and correct well completion ret orr all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, a!r in!ect,o: su,!t 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 n~easurements 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 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 ;nterval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this wel lng and the location of the cementing tool. should show the details of any multiple stage cemer~t tern 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water !ection, Gas Injection, Shut-in, Other-explain. tern 28: If no cores taken, indicate "none". Form ~94(,7 ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Precare ancl submit the "Initial Rel~ort" on the fi~st Weanesday after a well :s s~ucclec c, worKover cPeranons are star, ecl Daily work prior to sobaclmg shoulcl ~e summarlzec~ cn the forr'~ g~wng ,nc'.uslve ~ates only. District Alaska Fielcl Kuparuk River Auth. or W.O. no AFE AK0375 County Gar,sm or North Slope Borough ILe,se or U.,t ADL 25631 Jritle Completion State Alaska Well '~o 3A-15 Nordic 1 API 50-029-21491 Ooerator ARCO Alaska, Inc. Spuclaed or W.O. begun Complete JDate [Hour 1/11/86 1830 hrs. ARCO W I JPr,o- status ,! a i~ C 56.24% Date ancl depth as of 8:(X} a.m. 1/12/86 thru 1/13/86 1/14/86 Complete record for each clay repoctec~ 7" @ 8144' 8044' PBTD, TIH w/2-7/8" CA 10.0 ppg Accept ri~ @ 1830 hrs, 1/11/86. NU & tst BOPE. RU SOS, perf w/4" gun, 4 SPF f/7922'-7952', 7864'-7908', 7834'-7852' & w/5" gun, 12 spf f/7694'-7730'. Make gage ring/JB rn. Set lB pkr @ 7764'. RU & rn 245 jts, 2-7/8" compl; unable to verify stung into pkr. RU SOS, rn CCL, verify seal assy not in pkr. POH w/tbg to add centralizer. TIH. 7" @ 8144' 8044' PBTD, RIH w/i-I/2" dummy vlv 6.8 ppg diesel in tbg & ann Lnd 244 jts, 2-7/8" 6.5#, J-55 EUE 8RD tbg w/SSSV @ 1811', HB Pkr @ 7537', lB Pkr @ 7764', TT @ 7785'. Set pkr. Tst tbg & ann to 2500 psi. Tst pkr & SSSV; OK. Shear PBR. RU S/L, pull 1-1/2" orifice vlv @ 7481'. Set dummy in GLM, circ. Att to tst tbg. Att to retrv dummy, dummy not in GLM. Set new dummy in GLM. Tst tbg to 2500 psi. Fsh lost dummy; rec'd. Shear out ball, pull dummy in GLM. NU & tst tree. Displ well to diesel. RU S/L, RIH w/I-i/2" d,mmy vlv. RECEIVED FEB 2 8 1986 Alaska Oil & bas Cu~s. t;ommission Anchorage The above is correct For form preparation and ~is~ibution, see Procedures Manual. SectCon 10, Drilling, Pages 86 ancl 87, Drilling Superintendent ARCO Oil and Gas Company Well History - Initial Report - Daily Prepare and submit the "Initial Re~ort" on the first Wednesday after a well is sDudded or wod(over operations are started. Daily wo~ prior to SPudcling should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFl[ AK0375 Parker 141 County. parish Or borough North Slope Borough ILe,,, or Unit 25631 ADL ITitl, Drill IS,ate Alaska IWell no. 3A-15 AP1 50-029-21491 ARCO Alaska, Inc. S~dde4 er W.O. be~m~ - Spudd~ 12/11/85 12/12/86 12/13/85 12/14/85 ].2/16/85 IDms ] Hour 12/11/85 Compiels record for each clay relx3rt~l IARCO WI Prior statu, if a W.O. 56.24% 0915 hrs. 16" @ 104' Accept rig-@ 0415 hfs, 12/11/85.. Nil diverte£ sys. 16" @ 104' 1110', (1006'), DD Wt. 9.3, PV 14, YP 16, PH 9.0, WL 14.8, Sol 5 Spud well @ 0915 brs, 12/11/85. Drl to 1110' 754', 4.0', N43W, 753.91TVD, 5.02 V$, 3..~4N~ 3.35W 912', 8.8°, N32.3W, 910.93 TVD, 22.61VS, 17.68N, 14.11W 16" @ 104' 3700', (2590'), Drlg Wt. 9.5, PV 8, YP 16, PH 9.0, WL 20, Sol 9.4 Drl & surv 12%" hole to 3700'. 1066', 14.1°, N38W, 1061.87 TVD, 53.04 VS, 1563', 27.5°, N42W, 1525.81TVD, 228.34 VS, 2197', 41.5', N36.8W, 2044.64 TVD, 590.55 VS, 2500', 42.5*, N36,3W, 2269.81TVD, 792.78 VS, 3375', 41.2° 42.68N, 31.71W 176.43N, 145.05W 454.34N, 376.66W 617.21N, 497.40W s N37.6W, 2919.69 TVD, 1376.87 VS, 1090.22N, 843.11W 9-5/8 @ 3681' 7562', (3862'), TIH w/bit Wt. 10, PV 9, YP 5, PH 9.5, WL 11.2, Sol 9 C&C hole, short trip, POOH. RU & rn 93 its, 9-5/8", 36~, J-55 HF/ERW BTC cs$ w/FS @ 3681', FC @ 3601'. Cmt w/1510 sx AS III w/10#/sx Kolite, followed by 310 sx Cl "G" w/l% S-1 & .2% D-46. Displ using rig pmp, bump plug. CIP @ 2000 hrs, 12/13/85. ND diver,er. NU & ts, BOPE. TIH w/8½" bit, ts, csg to 1500 psi. DO fl, equip & cmt + 13' new hole. Conduct formation ts, to 12.5 ppg EMW. Turbine drl & surv 8½" hole to 7562'. 3665',40.9°, N37.6W, 3138.39 TVD,1567.05 VS, 1241.11N, 959.31W 3950',41.1°, N36.6W, 3353.48 TVD,1753.57 VS, 1390.24N,1072.10W 4858',41.8°, N36.6W, 4034.24 TVD, 2353.03 VS, 1871.67N,1431.60W 5549',42.5°, N38.4W, 4546.54 TVD,2816.04 VS, 2239.56N,1713.89W 6047',44*, N45.1°, 4909.27 TVD,3157.20 VS, 2494.13N,1941.10W 6542',46.5°, N46.2W, 5257.76 TVD,3507.38 VS, 2739.65N,2192.70W 7070',48.2°' N47.3W, 5615.49 TVD,3893.49 VS, 3005.49N,2475.79W 7487',48.8°, N47.3W, 5891.80 TVD,4203.70 VS, 3217.29N,2705.31W RECEIVED FEB 2 8 1986 Alaska Oil & Gas Cons. Commission Anchorage The above is correct Signature For btm prep&ration and distrib~ion, see Procedures Manual, Sectio~ 10, Drilling, Pages 86 ancl 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim .1 Instructions: This form is used during dri!ling or workover operations If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach descrrpbon of all cores. Work performed by Producing Section will be reported on "Interim" sheets until hnal completion. Report official or representative test on "Final" form. 1/ Submit "lnlerim" 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 of od string until comolebon. District ICounty or Parish I State Alaska North Slope Borough Field ILease or Unit Kuparuk River J ADL 25631 Complete record for each day while drilling or workover in progress Date and deptl~ as of 8:00 a.m. 12/17/85 12/18/85 Alaska JWell no 3A-15 9-5/8 @ 3681' 8035', (473'), TIH w/bit Wt. 10, PV 9, YP 6, PH 9.0, WL 10, Sol 10 Fin RIH, wsh & rm 30' to btm, drl to 8035', C&C, POH. RU Schl, rn DIL/GR/SP/SFL f/8027' - 3700', cont w/GR to 1800'. Log FDC/CNL f/8027' - 7450', 6000'-5800' & 4900'-4650' & CAL f/8027' - 3700'. RD Schl. RIH w/bit. 7828', 47.5°, N43.2W, 6119.31TVD, 4456.89 VS, 3396.12N, 2885.78W 8005', 46.4°, N39W, 6240.14 TVD, 4586.23 VS, 3493.59N, 2970.73W 7" @ 8145' 8160', (125'), Prep to cmt 7" Wt. 10, PV 8, YP 4, PH 9.0, WL 8.4, Sol 13 RIH to csg shoe, wsh & rm 40' to btm, drl to 8160', circ hi-vis sweep, make 10 std wiper trip, POOH, LD DP. Chg top rams to 7" &tst to 3500 psi. RU & rn 187 jts, 7", 26# HF/ERW BTC csg w/FS @ 8145', FC @ 8060'. Circ & prep to cmt. RECEIVED FEB 2 8 1986 AlasKa 011 6, ;,~,~ bo,~ ~,u~i~mlssion Anchorage The above is correct Signature For form preparation and disjnbution see Procedures Manual Secb~>n !0. Drilling, Pages 8§ and 87 Date JTit:e Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report "Final Ref3ort" shouh3 be su~rnitte~ also when _,c, perat~ons are suspenced 'or an mdefimte or acDrec~able ~e~gth of h~e not requirec upon corn=Jet,om reoo~ Somcletmon and reDresen~abve test cata ,n D'OCCS DrowCed The "Final Repo~" ,orm D e ,n t operabon ,f space .s a.a.:aole Account,ng cost center code Distr~ct ICo~nty or Parish S:ate Alaska I North Slope Borough Alaska Field JLease or bmr ]Wel' nO Kuparuk River ADL 25631 3A-15 Auth. or W.O. no ITitle AFE AK0375 I Dr:Lll Parker 141 API 50-029-21491 Operator JAR.Co. W.I. Ic°strT°tal numDer °f wells (act've °r 'nact've) °n th'sIcenter prior to plugging and ARCO Alaska, Inc. 56.24% Jabandonment of this well 12/11/85 / 0915 hrs. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m 12/19/85 Complete record for each day reported 7" @ 8145' 8160', 8063' PBTD, Ri{ 10.0 ppg NaC1/NaBr Cmt 7" w/100 sx C1 "G" w/8% D-20, .2% D-46, .5% D-65 & .5% D-112, followed by 350 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ w/lO.O ppg brine using rig pmps, bum~plu~_g. CIP@ 0815 hrs, 12/18/85. ND BOPE, instl pack-off, NU & tst tree to 3000 psi. Pmp 50 bbls diesel into 9-5/8" ann. RR @ 12/27/85 1200 hrs, 12/18/85. Arctic packed well w/175 sx AS I. RECEIVFD FEB 2 8 1986 Oil & uas Cu~,s. bumrmssion An~orage Old TD INewTO J ~B (Depth 8160' TD J 8063' PBTD Released mg Date JK~n~ of ,ig 1200 hrs. 12/18/85 J Rotary Classifications (oil. gas. etc.) Type completion ~s~ngle. dual. etc) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservmr Producing Interval Oil or gas Test hme Production 0,1 on test Gas per day Pump size. SPM X length Choke raze -= !C.P Water % GOR Grav,ty AHowable ,Effective date corrected The aOove is correct Signature -v -__ JDate JTit~e /., I see Procedures Manual. Section 10. Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company,~,,~, Daily Well History-Final Report Instructions: =,ecare a,~c suer",: t-e "Final Report" c" t"e ' 'st A'ec"escay a':e' a c~a= e ~as zee- ass ~-ec :- ~e s = _c~ec ~ra"~"e~ -, Et ~ recuirec _con com3'e:~c~. 'escff 2omp=e:,oq ard ,ec,esen:a:,,e test: data - : ::,s :'c..cec -"e "Final Report" 'c'- -a~ se ~sed ':- 'et:-' operat'~n 's:ace s a,a ,ac:e Alas~ North Slope Borough Alaska Kuparuk River Auth. cr AFE AK0375 ADL 25631 Completion Nordic 1 API 50-029-21491 Ccerator A R Co W ARCO Alaska, Inc. SpuCced c' ;'CompleteC oegu~, cate 56.24% ,/'Total number of we;,$ ,ac',,ve o- ,nact,ve~ o,"' th,s cost cente, Drlor tO plugg ng and tabandonment of t~,s we!' 1830 hrs. Pr,o, sta:~s,~a*O 1/11/86 Date anc cept:h as cf 8 O0 a ~ 1/15/86 i Comclete record ,or each cay re:or/,ed 7" @ 8144' 8044' PBTD, RR Diesel in tbg & ann Set 1-1/2" dummy vlv in GLM @ 7481' 1/14/86. Set BPV. RR @ 0800 hrs, RECEIVED FEB 2 8 1986 Alaska 0il & Gas Cons. commission Anchorage O~c TD me easec - g 0800 hrs. C:ass[' :a::c~s c, gas et:c Oil m,oc~c ng ~et~cc Flowing Ne~, TZ Date 1/14/86 ~ -: :' ry3e :g--stet c'" s ~g e 2-3 ets Single C"ic a:-ese~.~a~;Suk Sands 8044' PB1-D Rotary :esi [ ' , Pumo size, SPM X ;engtr, Choke s~ze ' = C 2 J ,',ate, =: I The above is correct Signatu,e For form preDara!lon ~nd d~str;Du~:om. see Procedures Manuah Sectio~ 19. Oral!lng. ~=ages 86 and 87 Date T,',~ e Drilling Superintendent UB-$URFACE DIRECTIONAL URVEY r-~ UIDANCE ~]ONTINUOUS ['~ OOL RECEIVED F E B 2 8 1986 Ataska 0il & b~s Co,qs. Commission Anchorage Company Well Name Field/Location ARCO ALASKA INCORPORATED · 3A-15 (865' FSL, 838' FEL, S7, T12N, R9E) KUPARUK, NORTH SLOPE, ALASKA Jol~ Reference No. 71177 Lo¢~cled By: SALAZAR Date 25-JAN-1986 Computed OGDEN GCT 9I~CTI]N&L SURVEY 'UST3MER LISTINS 3~-15 KUm&q~JK ~ETH]]S O: CDMPUT~TIO~ T2OL L2~AT[]N: T&NS5flTI&L- I~TERP]L~Ti2N: LZNE~R VE~TIC&L S~CTI]N: flDRIZ. DIST. :_NSIW'- E~: S~IL~Z&R 4RCO ~L~S~, INC. 3~-15 KJPARJK NSRTH SLOmE,~L~SK~ CO~DUT~TID`4 9~TE: 25-J~N-35 ,:= l' INT=RPOL~TED V4LJES ~OR EVEN 100 ~:T ']; TRU= SJ3-~E4 ~E~SU~E~ V6RTIC~L V~TIC4L ]EPT~ OEPT~ D~FH 0.00 O.O0 -72.00 1DO.OD lO0.O0 23.00 ZO0.O0 200.00 1Z~.O0 300.00 300.30 22~.00 ~DO,O0 400.00 32~.00 500.03 500.00 428.00 500.00 599.~9 527.9~ 700.00 699.97 527.97 ~00.00 799.55 727.~6 ~O0.00 898.79 825.79 IODO.OO 997.25 925.26 ltO0.O0 109~.;0 1022.40 1200.00 1190.09 1118.09 1330.30 128~.52 121Z.52 l~O0.O0 1377.38 1303.38 1500.00 1458.56 13'~5.55 1500.00 1557.98 1485.0~ 1730.00 1643,59 1571.6'~ l~O0.DO 1728.53 1555.63 19~0.00 1811.14 1739,14 2000.00 1890.77 1515.77 2100.90 1958.52 1595.52 2200.00 2044.52 1972.52 2300.00 2118.~6 2045.46 2~30.00 2192.10 2122.10 2500.33 2265.57 Z193.57 2500.00 2339.~3 2267.43 2700.00 2413.30 2341.33 2~DO.3D 2~87.38 2~15.33 2900.00 2561,59 zooo.oo 31~0.~0 3200.00 ZTll. IO 3300.30 2859°90 3~,00.00 3500.00 3010.28 3~00.00 3085.70 3700.00 31~1.35 3800.00 3237.05 3}30.33 3312.~4 COJ~SE V:RTIC4L DEVI4TION AZIMJTH SECTION S=V=RITY DEG MIN DES 0 0 N 0 9 E 0.00 0.00 0 1~ S 15 2~ W -0.22 0.92 0 5 S 12 21 W -9.30 J.2,] 0 6 S 38 5 W -3.37 9.05 0 9 S 39 11 w -~,~0 3.21 0 25 S ~2 53 E -0.73 3.1~ 0 22 S 50 4~ E -1.53 2 35 N 43 ~5 W -0.3~ ~,~J 5 ~0 N ~1 9 W 7,31 3.33 8 56 N 36 10 W 2'3.37 2.23 11 15 18 20 22 25 28 3O 33 35 33 N 35 11 W 37,70 31 N 37 5 N 51,27 3,51 5 N 3H 22 W 90,2? 2.43 2~ N 40 43 N 123,1~ 3,09 38 N ~1 13 W 163.22 2.41 58 N 41 42 J 201.25 59 N ~2 43 J 247,71 2,39 50 N ~2 4~ N 297,66 1,75 3 N 42 l) ~ 3~0,39 2.65 53 N al ~ N 405.~5 3.33 38 39 42 ~2 42 ~2 42 13 N ~,0 I W 457,34 1,3~ 35 N 30 5D ~.~ 530.2C 1,73 39 N ]7 25 .~ -'.'95.11 .2,13 33 N 37 33 W 552. 33 3.22 ~O N ~7 ~,1 ~ 72).~9 3.50 32 N 37 51 w 79F,53 ~0 N 3¢ 1 4 ~.'~7 ?.Il 18 N 3B 3 'J 932,31 7 N 3~ 3 W ~9~.42 ].gl 4 N 37 59 w 1)55,37 3.3~ 2563.95 2638.53 2713.10 2787.90 2863.01 2938.28 3013.70 3089.36 3155.05 3243.44 41 41 41 41 41 41 4O 41 +9 N 37 59 W 1133,15 0.27 ~7 N 37 5~ W 1199,70 3.23 ~4 N 3~ 2 N 1255,25 0,09 25 N 38 7 N 1332,55 D,32 12 N 37 55 W 139~.51 0.23 7 N 37 52 W 145~,27 O.ZZ 0 N 37 43 W 152~.85 3.33 34 N 37 45 W 1595,15 1.77 ) N 37 55 W 1725.06 3.23 3 3JL2R C33R914,~T:~ T ::':T 71. 12a. 15j . 225. 265. 307. 353.25 '4 305.'~7 ~,01.7 ~ :.,I 345.¢5 505.~3 N a25.~ 55~.D'~ N 45~.13 55 ~. ~ 'q 551.15 71 ~. ~2 '] 592.70 772.f3 N 63G.09 325.b~ I 675.35 ~37~. 35 q 716,48 )3'3.57 N 757.47 )-33. ~, 3 ',J 798.43 1~5.55 'q 839.38 1287.57 ~ 880.0~ 113Y,51 q 920.50 ll~l.~.~ N 960,75 1243.25 '4 100'3.5~ 13~6.5~ ~ 13~!.23 ,3 . O0 3,23 9,5~ 3.52. '3. ~ ] I. I .+ 1.?1 9, ~3 7.3~ Z '3. ~ ~ .~7. Il .51.32 9).37 123.3~, 153.27 201,2~ 247.72 2'~.55 '~SO ~0o. ~5 1133,51 1230.12 126o,73 1333.10 13}~.11 1530.3'3 lq ~5. ~5 1~'51.2) 1727.03 a,Z [ ',IU T H 2 ! 3 ~ i H ",, ~) '5 ,~ ~j 4.) 7 ,~ ~ ] ~ ~._ q 33 15 ~ Xl 3? 12 '4 33 55 ,~ q 33 -35 4~C0 4L~SKA, 1.4C. 3~-15 N3RTH SLgPE,~L&SK~ CDMPUT~TIDN DATE: 25-J~N-.q5 3:iT~- ]r- Sj~V'~¥: 33-').-"J-~5 '<~:LLY ~J~-NI",I] ,:~L-_V,.1Ti]'4: 7 ~. O',l.) INTErPOLaTED VALJES FOR ~VEN 100 F~=T C= TRUE SJS-SE~ ~E~SUR~D YERTZ~L VERT['&L DEPTH DEPTf DEPTH ~OOO.3D 3387.59 3315.6~ ¢lDO.O0 3~52.76 3390.76 4ZgO.Og 3537.34 3~65.84 ~300.00 3512.97 3540.97 4~00.00 3687.~6 ~515.96 ~5DO.OD 3752.88 3590.88 4600.00 3837.~4 3765,9~ 4700.03 3912.~0 38~0.90 ~00.90 3987.?1 3~15.71 4)00.00 ~062.36 3990.36 5000.03 %135.B1 &05~.81 5100.00 ~210.3~ ~139.36 5200.00 ~283.58 ~211.5~ 5300.00 ~355.~2 ~23~.92 5%00.00 ~30.2~ ~3~.2~ 5500.00 ~503.88 ~31.83 5600.00 ~577.50 ~505.50 5700.00 4551.05 ~STg.05 5~00.00 ~724.10 ~552.10 5900.0~ ¢797.13 ~725.13 5000.00 ~870.07 ~798.07 6100.00 ~9~Z.ZO ~870,20 6Z00.00 5013.35 ~g~1.35 6300.00 508~.38 501Z.08 6%00.00 5153.09 5081.99 6500.00 5223.~9 5151.00 6500.03 S29~.83 521~.~3 6700.00 5360.86 5280.0§ 6~00.00 5427.~3 5355.73 CSJRSE VEqTID&L 393_EG DEVI~TID.4 AZIMUTH ~ECTION SEV:RITY DES ~IN OEG MIN FEET 0~S/103 41 15 N 37 55 W 1791.85 3.20 41 21 N 3~ O ~ 1~57.83 D.13 41 18 N 38 5 W 1923,31 D.O~ 41 18 N 33 $ W 19.~9.74 ].13 41 30 N 38 1 W 2055.83 3.25 41 24 N 38 9 W ~1~2.00 3.1~ 41 Zl N 38 3 W 21~,01 0.13 61 30 N 38 10 W 2254.1~ 0.23 al 39 N 38 23 ~ Z32O.4a 3.31 41 $3 N 33 24 W !396.93 3.22 42 13 N 3g D W !453.64 2.1~ 42 52 N 40 1~ W 2521.38 3.20 42 53 N ~0 B 4 25~9.49 0.2~ 42 ~8 N 3~ 5~ W 2557.67 3.23 42 %5 N 3g 53 W 2'125.46 3.5~ 42 37 .4 39 ~2 ~ 2793.11 0.33 42 33 .4 39 ~7 N 2950.78 9.25 42 54 N 40 15 W 292~.52 43 4 N ~0 5~ W 2995.~2 0.25 43 5 N 41 ~ W 3055.12 1.45 43 25 N 4~ 3 W 3133.49 3.81 44 21 N 45 2 W 3202.50 3.97 44 ~9 N ~5 25 ,4 ~272.44 3.7~ 45 19 N ~5 41 W 3~2.75 46 1 ~ ~7 3 W 3413.a3 w~ 2~ ~ &7 27 W 3~5.53 ~6 %0 N %7 45 ~ 3557.73 47 10 ~ ~ ~ w 3530.25 6? 38 N ~5 23 4 3703.22 68 i N ~ 3~ g 3775.50 47 51 N 43 47 ~ 3950.38 3.79 48 13 DJ 49 6 4 3723.73 0.33 43 3~ N 49 1) W 3)97.63 3.33 ~8 35 ~ 4? 35 ~ ~071.90 D.77 4.5 32 N ~9 17 w ~1~5.9~ 3.1~ 48 ~4 N 4} ~ W ~220.10 0.2~ 4~ 10 N 47 59 W ~94.40 3.31 47 19 .4 ~ 25 ~ ~3~7.74 1.~5 47 22 N 43 1~ ~ 4~41.3~ 1.32 ~7 5 N 42 ZZ ~ ~51~.77 R ~ - T a N F: d 13 '9 :~. 1~53. 1532. 1354. !~06. 1553. 1710. 17,52. 1~1~. 1 ,,~ 57. 1 ~1 ). 1971. !375. 2127. 2173. 2231. 2293. 233E. 23~. 2%37. 254C. 2334. 23q3. 2532. 2531. 273J. 277-'. 2 -32 "t. "371. 2~75. 3326. 3372. 3121. 3173. 3Z!3. 3:~71 . ~32~ ?,~73. ] T]=PTH 3'JL~R SOLJTq % a S T/,,/'-' S T f :c':T 52 N 1121.59 73 xl 1162.32 ~3 'q 1243. 75 75 '4 12~.32 97 q 1325. 3~ ~2 ;,~ 13~5.22 37 q 1407. 39 33 N 143~.58 %0 N 1531..J5 31 'q 157'%.5~ 2~ "~ 161'3.52 35 q 1562.32 52 '4 1705.~3 50 '4 17~.2~ 56 q 1792.w~ ~5 '4 1;3.35.03 3~ 'q 18¢9.45 99 ~ 1925.25 55 N 1971.35 1~ N 2023.51 77 N 2371.27 34 N 2122.$~ 2a N 217~.79 30 '~ 2221.97 27 '4 2281.51 25 N 2335.75 ~1 q 24~5.28 1792,¥5 199}. )4 2357.13 2123.33 2 I ? ~. :, O :!255. 2321.)~ 233 ~. ~3 2~5~.23 £322.~7 25')1.95 255).J2 279~.55 2552.32 2~.31 3355.57 31~.35 3~03.57 3273.~1 3f5~.33 3-33.45 ~703.~ 3775.7~ 33 '4 Z501.95 23 '~ 2558.07 J~ N 261~.68 .37 .4 2671.T9 S2 N 2728.72 31 ~ 2785,~,9 ~3 I 2962.13 1~ N 29a5.25 13 't 2993.i3 3530.3'~ 3~23.73 39')7.70 6371.93 4145.36 622}.37 435~.23 3=3 q 3.3 34 4 35 N '4 35 47 ~ ~ 33 50 4 ~ 33 53 ~ ARCO ~L~1Sq~I, I~C. 3~-15 N3~TH SLOPE,&L~SK& C3~PUT~TI]N D~TE: 25-J~N-35 <'LLY qJS'tZN .... L "V2T ~T INTEqPSL~TE3 V~LJES FOR EVE~ 100 TRU: SJB-S--~ ME~'SURE] VERTI'~L Vr-RTIC~L DEPTH DEPTfl 3i~T~ 8000.00 5230.55 5158.55 8100.00 5299.2.5 $227.2~ 8150.09 5340.~8 CDJRSE VZRTIC~L ]EVI~TI]~ ~ZIMJT4 SECTION WIN OEG MI~ mEET 46 ]6 N ~0 58 ~ ~58~.04 46 36 N a3 57 ~ ~5~0.71 46 36 N ~0 57 W ~'?0~.31 FEET SEVERITY 1 3.9? 0.03 MrZASUPED 2,~: P T H qE gT &N3~JL~1 r~ CODRDI~Tz) f,'- T_-' T F E ET ~ :_: F 3932.55 ~ 30~5.0~ W 7~52;).~ '~ 3121. ~1 W 47J,~. ~0 ~ZIqUTH fiRSD a, LfiS<.~, Z~IC. 3&-15 KUPfiRCIK NgRTH SLDPE,fiL~SKA C3~PUT&TI3~ D6TE: :: T TRU-: IE~,SURE3 HERTI3a, L DEPTH DEPTq 0.00 0.00 1000.00 997.26 2000,00 1890.77 3000.00 2635,)6 4000,00 3387.58 5000.00 ~136.31 6000.33 ~870.07 ?330.0} 5561.)3 8000.00 5230.55 8150.03 $3~0.~ Z~T;qPOL~TED V~LJSS FDR :VEN 1003 FE=T 3: SJS-SEfi C]JRSE VZRTiCfiL OD3LE'3 VSRTIC/IL 3EVIa. Ti]~ fiZI'4JT-~ S--CTI3N SEV-RiTf 3EPTH )=.G qIN 05,5 MI~i FEET 3'=3/103 -72,00 925.25 1813.77 ;'563.95 331.5.65 406~. ~11 ~798,07 5158.56 525g,~8 0 0 N O D E 0.00 0.03 Il 33 N 35 11 W 37.70 ~.St 38 13 N 43 1 W 467.34 1.89 41 ~9 N 37 59 W t133.15 0,27 41 16 N 37 55 W 17:)1.85 O.2O 42 13 N 39 O ~ 2453.64 43 25 N ~4 3 W 3133.4) 3,~1 47 51 N 4~ ~1 W 3350.0~ 0.7~ 46 36 N 40 59 W ~5~8.04 13.97 46 36 N ~0 57 ~ ~70~.31 0.00 ~l¢] -T:lq = .':' c' 353. 1393. 2~37. 3~32. 352'3. i,:JL&R C]')q"3I'Ja, T,.: 5 33dT'q T DIST. '3 · 30 ~7. 71 ~57.34 1133.51 1T~2.~5 2~55.25 3.~5J. ]9 :.,. 7 O ~. ") 3 .I_' ,', : 4~C0 ~LA$~A, INC. 3~-15 KJP~RUK N3RTH SLO~E,4L~SK~ COMPUT~TI]~ D~TE: 25-J~N-~5 [NT3~OLATED VALJE3 F3R EVEN 100 TRUE SOB-S~4 ~EaSURED VERTICAL VERTI'AL 3EPTH DEPTH 3EPTH O.OO 0.00 -72.00 72.00 72.00 3.00 172.00 172.00 100.00 27Z.00 272.00 200.00 3?2.00 372.00 300.00 ~.72.00 ~72.00 ~00.00 572.01 572.00 500.00 572.01 572.30 503.00 ??2.22 772.00 703.00 ~72.90 872.30 ~OO.O0 9?4.25 972.00 903.00 1076.79 1072.00 1000.00 1131.02 1172.00 1100.00 1286.57 1272.00 1200.00 13~4.15 1372.00 1300.00 1503.85 1472.00 1409.00 1517.3~ 1572.30 1500.00 1733.07 1672.00 1500.00 1952.17 1772.D0 1?00.00 1)76.15 1872.00 1BO0.O0 2124.52 1972.00 1993.00 2237.00 2072.00 ZOOD.O0 2372.70 2172.00 ZlOJ.OQ 2538.71 ZZ?Z.O0 ZZO].O0 25~4.0~ 2372.00 Z30O.O0 2779.25 2~72.00 2~14.03 2572.00 2500.00 3048.33 2672.00 2500.00 31~2.~ ~??Z O0 2700.00 3316.1~ .872:00 2800.00 COJRSE V:RTI~AL DSSLEG ]EVI~TI04 AZIMUTH SECTION SEVERITY ]=G ~IN DES Mil ;EET 363/100 0 0 N 0 3 ~ '3 O0 0 O0 -- ' · 0 14 S 31 5 : -3.11 0.7~3 0 ~. S 43 5~ W -0.23 3.37 0 5 S 30 52 ~ -0.36 0.1~ 0 9 S 42 32 W -0.40 0.07 0 18 S F+7 37 E -0.54 3.67 0 27 S 51 55 : -1.33 J.35 I 22 N ~(, Z W -1.Z~ ~.07 5 2 N ~+Z ~, N 4,7.5 1.75 8 23 N 37 5 W 15.30 Z.23 10 14 17 2O ZZ 26 19 31 34 37 34 N 35 49 W 32.79 3.q~ ~0 N 35 59 W 55.23 3.95 3~ N 37 5~ W 3~.52 2.38 1 N 40 25 ~ 11~.56 2.77 50 N ~1 17 W 157.92 2.~7 T N 41 47 W 202.9~ 4.25 22 N 42 ~5 W 256.0~ Z.l~ 28 N ~2 2~ W 314.75 2.0~ 28 N ~1 50 W 379.38 2.~ ~2 41 41 ~,0 N 35 45 w 533.08 1.83 13 N 37 21 ,~ 51'~.~, 1.0~ 35 ~ ~7 33 w 711.q4 3.13 23 ~ 3~ i ,~ ~'~.55 0.32 9 N 3~ Z ,4 ~5.51 3.i~ 4 N 3~ 5~ 'N 1075.77 ~.~3 %5 N ~7 57 J 1155.32 ~5 N ~7 5) ~ 125a.57 O.ZJ 23 N 3~ 5 ~ I~3.23 3. 35 ~+1 4O 41 41 ~+1 41 ~+I 41 41 10 N 37 5~ W 1430,~3 3,05 0 N 37 q3 ~ 1517,93 3,33 31 N 37 49 ~ 153~,15 l,Sq 5 N 37 55 W 1690.~0 3.23 13 N 37 55 ~4 1778,10 0,35 Z1 N 35 1 W 1865.~5 ~,O~ l~ N 38 5 J 1)53,7~ 3,0~ 30 N 35 9 W 29~1,71 ~,25 23 N 3~ ) W 2133,03 ~,15 26 N 38 7 W 221~.02 35~1.82 3071~00 3000.00 3113.9~ 31~Z~00 3103.00 33~6.33 327Z.00 3200.00 3~79.1~ 33?2°00 3300.00 4112.31 34T2.90 3400.00 4245.~7 3572.00 3503.00 4378.58 3672.00 3500.00 4512.15 3772.~0 370}.00 45~5.~2 3872.00 3~0~.20 RE'T~N NJRTq/ 3':~TH 3UL~R S ] :J T q T O,00 '3.~ ,3. ~7 0.51 0,7~ O. ~g 1 · ~ 1 i. ~ .5 25,23 43,30 ',1 ~ ) · 02 "~ 122, 59 15o.52 195.55 Z 3 ,~. ~ 3 2d6.70 3 ~ 2 · O 0 1113,19 1182.33 131.5,35 1357,77 1457,10 1525.3~ 15~5.51 1655.1~ 173~.~5 C3.3RJIq~T'=S fiA3T/N:ST FEET 0. () 0 9. O 7 3.15 0.33 3.32 O. '25 O.31 3.~3 11.21 2~.35 ~ 52.1~ w 165,13 w 2q~.47 W 3a7.75 ,,00. ~B 5i3.1-) 625,52 681.15 735.33 791.22 8~5.97 899.94 953.45 1006.22 105g.43 1113.23 1167.33 1221. 55 1275.~2 1330, ~6 1334. 77 'qJqlZ. O,O0 J.ll J..6 O. 53 ].'j -~ 1.56 I.~7 ~.~5 {2.79 55.27 3~.51 203.')1 314.75 37 ) · 3 ~ ~52. 6~ 15J~,)5 15)!,71 177).J9 135T,33 1~,~5 U~_ AR"O aLaS(a, 3~-15 KJP~R]~ N]~TH SLOOE,~L~SK~. CD~4PUT~TI]~ 25 -J ~ q- ~ S TRUE ~EASUREO VERTIS~L ]EPT4 DEPT~ 4778.99 3972.00 4912.92 4072.90 50~7.71 4172.30 51B4.19 ~272.00 5320.5? ~372.20 5456.73 4472.00 5592.54 4572.00 5728.55 46T2.00 5855.54 4772.30 6002.55 6161.83 ~972.00 6282.84 5072.00 6426.01 5172.00 6571.13 5ZTZ.O0 6717.57 5372.00 6855.39 5~?Z.O0 7015.0~ 557Z.00 7155.13 5572.00 7316.40 5772.00 7457.42 587Z.00 7518.58 597Z.00 7756.41 5072.30 7913.83 5172.00 8050.3Z 5272.00 8150.00 53~0.48 INr:~POL~TE3 V&L3ES FOR EVEN 100 :E:T O: VERTICAL CJJRSE ]~VI~TI]N AZIMUTH 3900.00 ~000.00 ~100.00 4203.0O ~30O.O0 4500.00 4503.00 4700.00 4800.90 4900.00 5000.00 5100.00 5Z03.00 5300.00 5400.00 550J.00 5503.00 5703.00 5800.00 44 35 N ~5 1Z ~5 11 N ~5 ~0 46 9 N ~7 7 ~5 35 N ~7 43 ~7 57 N ~ 33 ~8 27 M ~ 14 4~ 30 N 49 35 4~ 39 N ~ 5903.00 5009.00 5103.00 5200.00 5268.43 47 30 N ~3 ~5 47 16 N 4Z 1 l 45 36 N ~C 37 ~5 36 N ~O VERTICAL Og3LEG SECTION :SEVERITY FEET 3E3/103 Z305.68 O.Z5 Z3~5.52 9.30 ~4B5.~6 1.1~ '2378.73 0.27 !671.45 ~.£6 2763.95 3.32 Z~55.73 0.21 ~135.31 3.55 3231.68 9.30 3632.47 3.65 3535.~0 0.3~ 36~3.03 3.51 3751.57 3.58 ~61.13 3.57 3971.82 3.~? ~0~.03 ,3.3~ ~195.~9 3.21 ~30~.20 ~15.53 3..~3 ~5~.~5 ~ 3~ ~531.~7 'J.3~ ~73~.31 /W~:'5T 31~r. ~ZI"IJT~ T =EJr ,3~5~ qlq 32 W 4300.53 gO w ~17.15 ~,~ ,' ~ ~" ~ _ .'+, .;,) A~¢.,O ALA$)(,~, INC. 3~,-15 , KJ~ARJ~ NORTH SL LlP5, ~,L (k S ~ ~. C3MPUTaTI3N D~TE: ZS-J ~IN- ~, 5 ;::'2,7,,;. 7 .'?&T,=' 3."= ;,d4¢dY: 3. r:,-]: :-~.] '<,fLLY CU,i,'ti",13 EL .:v'r. tT.~ ]",: 72.3'3 fOP &4SE I'DP ~BTD fO M6RKER KUP~RUK ' KJO~RUK C ~UP~RUK ~ KJD~RUK .6 ZNT:~POL~TED VALJE5 FOR ~E~SJRED D~DTH BELOW K3 7558.30 773Z.00 7815.D0 8053.93 8160.30 CHOSEN HDR I Z]'J.S 3qIOIq= TVD 5005.43 5048.73 5105.57 5273.R~ 355' ::;L, 5~35.~0 ~7~.75 5335.57 ~57.2i "; 3975.13 ~523.,;4 '~ 31'"!.~1 4~C0 ~L4S~4, I~C. 3A-15 N3~TH ~L3PE, aL4S'~ CO~PJT~TI3~ 25-J'~N-~5 7 '. ') '] ~T TOP TOP B~SE TO M4~KER ~UP&RUK . KJ~RJK C KUP&RUK & KUP&RUK & qE&SJRED DEPTH TVD :IN~L WE~_ L32~TI]N ~T TD: TRJE SJB-S:A MEASJRED VERTICAL DEPTH 9~TH 3EPTH T732.00 50~.7~ 5~75.75 7815.00 5105.'57 53~3. 57 N]T LOG;3:] 2053.00 $273.~ 3160.00 $340.~3 526~.4:9 HORIZgNTAL ]EP~qTUq- DiST4NCE 4ZIMJT, SJRFA' q ':C T '.1 'qGU L. ~33Z.7] .~7.21 ~ _']C~TZ]',~ ~r , , 1£ , , 'J"l 3150.00 53~0.4B 6Z68.g8 4734.90 ~ 41 33 W SCHLUMBERGER O l RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3A-1S FIELD KUPARUK COUNTRY USA RUN TWO DATE LOOOED REFERENCE 00007 ! i ?? WELL: 3A-15 (865' FSL, 838' FEL, ST, £12N, R9E VERTICAL PROJECTION -L:~IO0 -1~ O0 1000- 2~)0 3000 4~ 5000 319. PROJECTION ON VERTICAL PLANE 9~9. - 159. SCPLEO IN VERTICAL DEPTHS HORIZ SCALE = 1/ 1000 [N/FT I~rELL 3A- 15 -- (865' FSL, 838' FEL, S7, T121 X9E 'qORIZONTAL PROJECTION 4OO0 1OOO SOUTH-2000 -SO00 -4ODO -3000 -2000 - l ODD O l DO0 2000 Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR,' WF~L~ NAME AND NUMBER Reports and Materials to be received by: /--/~-- Date Required Date Received Remarks Completion Report Well History Samples Mud Log Core Chips Core Description Registered Survey Plat inclination Survey /~/~ _ - ~/,q__ Directional Survey Drill Stem Test Reports Production Test Reports ~T$ ~C~- Log Run Digitized Data V:~ / ---d~ - :~ ~_~_ ARCO AlasKa. inc. Dost Office Box 100360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 P.ETUP~N TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk A~O !119 P. C. Box 100360 A_nchorage AK 99510-0360 DATE 01-25-8£ TRANSMITTAL = 5522 Transmitted herewith are the following items. Please acknowledpe receip= and return one signed copy of ~nis transmittal. Final Prin~s/ Schl/ Open Hole/ One * of each ¥' 3A-13 5" D!L/SFL-GR 2" DIL/SFL-GR 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu Cyberlook 12-01-85 Run =! 1890-7597 12-01-85 Run ~! 18-_0-7597 (poro) 12-0!-85 Run ~i 51~0-7571 (poro) 12-01-85 Run ~1 5100-7571 (raw) 12-01-85 Run =1 5129-7571 (raw) 12-01-85 Run ~1 51-_9-7571 12-01-85 Run %1 701 C,-7546 ~ 3A-14 =" D~/c=L 2" DiL/SFL 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu Cyberlook 12-09-85 Run ~i 01-.5-7795 12-09-85 Run #I 01-_5-7795 (poro) 12-09-85 R~n -~1 72~0-7770 (poro) 12-09-85 Run #1 7250-7770 (raw) 12-09-85 Run ~! 7250-7770 (raw) 12-09-85 Run ~1 ~z_-~-,~70 12-09-85 Run~=1 73~3-7650 '~j' 3A- L5 5" DiL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu Cyberiook 12-17-85 Run 12-17-85 Run -~! !88 Q-7982 (poro) 12-17-85 Rum #1 46-_0-7956 (poro) 12-17-85 Run .=! 4641,-7956 (raw) !2-17-85 Run =i 46-'_2-7956 (raw) 12-17-85 R'~n 12-17-85 R'~n ~i 74z _,- ,.~ Receipt Ac/cnowiedged: State of Ea~e."? -- ' :~SK Clerk*b! D & M'b! Va ..... -'* ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. ChatteFton' Enclosed are the December monthly reports for the fellowing wei's· 1A-7 2H-6 3A-13 3F-12 3J-11 ~-29 L2-29 1A-!3 2H-7 3A-14 ~F-13 3J-12 !6-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-!9 L3-~9 1H-4 2H-9 3A-16 2F-!5 4-24 16-20 !H-8 2X-8 3F-]1 ~-!0 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, · firuber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN ! !386 Oil & Gas C~r,s. ~,ommm.s/o~ - STATE OF ALASKA ALASKA C,_ AND GAS CONSERVATION CO,,_.,41SSION MONTHLY REPORT OI= DRILLING AND WORKOVER OPERATIONS !1. Drilling wel~ Workover operation 2. Name of operator ARCO Alaska, Inc, ' 7. Permit No. 85-283 3. Address P. 0. Box 100360, Anchorage, AK 99510 8. APl Number 5O 029-21491 4. Location of Well atsurface 865' FSL, 838' FEL, 5ec.7, T12N, RgE, UN i 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. 71' RKB ADL 25631 ALK 2565 i9 Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-1 5 11. F~eld and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of December 19 85 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]] ~ 0915 hfs, 12/11/85. Dr]d 12-1/4" hole to 3700'. Ran, cmtd, & tstd 9-5/8" csg. Dr]d 8-1/2" hole to 8035'. Ran logs. Cont'd dr]g 8-1/2" hole to 8160'TD (12/17/85). Ran, cmtd, & tstd 7" csg. PBTD = 8063' Secured we]l& RR ~ 1200 hrs, 12/18/85. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 104' Cmtd w/171 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3681'. Cmtd w/1510 sx AS Ill & 310 sx Class "G". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8145'. Cmtd w/450 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/8027' - 3700'; GR to 1800' FDC/CNL f/8027' - 7450', 6000' - 5800', & 4900' - 4650' Cai f/8027' - 3700' 16. DST data, perforatingdata, showsof H2S, miscellaneousdata None RECEIVED JAN 1 4 1986 Oil & ~as I.~hS. I.,~~ I 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~//~~ Z~,~,L~4~ TITLE Associate Engineer DATE ~ _ NOTE Report/,~n this form is required for each calendar month, regardless of the status of operations, and must De fried ~n duplicate ,~,,th the AlasKa Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~,04 TEMP3/MR1 2 Submit ,n duplicate ARCO Alaska, inc. - Post Office B~,.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN ~O: ARCO ALASKA, INC o ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 ¢ Transmgtted herewith are the following items. return one signed copy of t~his transmittal. DATE_ 12-31-85 ~" .... ~ # 5495 Please acknowledge receipt ~nd 2H-7 12-18-85 Run #1 2H-8 12-!1-85 Run #1 ---' 3A-15 12-17-85 Run #1 '~ 3B-7 05-25-85 Run #1 ~ 3F-t2 12-!1-85 Run #1 3J-11 12-20-85 Run #1 Open Hole LIS Tapes Plus Listing/ schl/ One of each Cons. Commission Anchorage Receipt Acknowledged: STATE OF AK. Date: ARCO A~m$~I. I~¢. ~t /~ ~ul~s~4ry O! AIl&rtt~cR~cl'~t~elc~CornDar~/, November 25, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Imc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-15 ARCO Alaska, Inc. Permit No. 85-283 Sur Loc 865'FSL, ~38'FEL, Sec v TI?N R9E _ ~084'FWL, Sec. 7, T12N R9E, Btmhole Loc. 1065'~P~=, , . Dear Mr. Kewin: Enclosed ~s 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 l~w from other goverr~ental agencies prior to commencing operations at the well site. To aid us in scheduling field work, olease notify this office 24 hours prior to co~encing instal!ati~n cf the blowout prevention equipment so that a representative of the CommJ_ssion may be present to witness testing of the equipment before the ~urface casing shoe is drilled. I-~ere a diverter system is required, =~ice 24 hours prior to commencin~ please also notify this o~ . equipment installation so that the Co~ission mmv witness testing before drilling below the shoe of the conductor pipe. %~_rx~ trBly~-yours, _~-~ :...._~. ;'~× /. . / / /y ~z,; /..- " :' .;.': C. Iv. Chatterton Chairman of Alaska Oil and Gas Conservstion Commission BY ORDER OF ~vH~E CO,fISSION be Enclosure cc: Department of Fish & G~me, Habitat Section w/e encl. Department of Environmental Conservation w/o enc!. Mr. Doug L. Lowe~, ARCO Alaska, Inc. Post Office Bo,, ,)0360 Anchorage. Alaska 99510-.0360 Telephone 907 276 1215 November 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3A-15 Dear Mr. Chatterton' Enclosed are' C We estimate spudding this well on December ~, !985. If you have any questions, please call me at 263-4970. An application for Permit to Frill Kuparuk 3A-15, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot Diagram and description of the surface hole diverter system Diagram and description of the BOP equipment Sincerely, Regional Drilling Engineer JBK/JFB/tw PD2/L06 Enclosures - STATE OF ALASKA ALASKA _.~L AND GAS CONSERVATION CuMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~X lb. Type of well EXPLORATORY ~ REDRILL _ DEVELOPMENT OIL DEEPEN ~ i DEVELOPMENT GAS . . SERVICE STRATI(~RAPJa lC SINGLE ZONE MULTIPLE ZC~E 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. BOX 100360, Anchorage, Alaska 99510 4. Location of well at surface 865' FSL, 838' FEL, Sec.7, T12N, RgE, UN At top of proposed producing interval 1234' FNL, 1230' FWL, Sec.7, T12N, R9E, UN At total depth 1065' FNL, 1084' FWL, Sec,7, T12N, R9E, UM _ 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 71', PAD 41' i ADL ~ALK 12. Bond information (see 20 AAC 25.025) ~'"~"'"~ I-ed,-Fa-! I n-surance Company Type Stat,ewide Surety and or number #8088-26-27 13. Distance and direction from nearest town I 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles ~1 1065' (~ TD feet 16. Proposed depth IMD & TVD) I 17. Number of acres in lease 7928' ND, 6321' TVD feet I 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 600 feet. MAXIMUM HOLE ANGLE 41 : !lsee 20 AAC 25.035 Ici SIZE Proposed Casing, Liner and Cementing Program Hole Casing 24" 16" CASING AND LINER SETTING DEPTH 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-15 11. Field and pool Kuparuk River Fi eld Kuparuk River 0~1 Pool i Length Weight Grade ! Couplingi 62.5# H-40 Weld 80' MD TOP Amount $500,000 15. Distance to nearest drilltng or completed 3A-14vvell 25' ~ surface feet __ 18. Approxl.~ate sDud date 12 /.¢~/ E5 /t, rtt - 2651 pslg~ 80°F Surface 3047 __ps~g~: 5980~ft. TD (TVD) -TVD ! ,MD BOTTOMTVD 32' 112~ 112' QUANTITY OF CEMENT I~nclude stage data) ± 200 cf 1250 sx CS III & 310 sx Class G 400 sx Class G 32' 12-1/4" 9-5/8" 36.0# J-55/HF-ERW BTC 3667' 32' 32' 3699' 3151' 8-1/2" 7" 26.0# J-55/HF-ERW BTC 7897' 31 31' 7928' 6321' 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7928' ND (6321' TVD). Selected intervals wil~ be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment wi~] be tested to 3500 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2651 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing t,he drilling rig. Non-freezing fluids will be left. ~n uncemented annuli through the permafrost int.erval. 3A-15 will be 25' away from 3A-1~ at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down t.he 7" x 9-5/8" annulus of 'chis well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in t,he disposal process, (continued on attached sheet) 23. I hereby/ /~ ~/ . / /~. · ,.~.~'/ce/~ at t he foregoi ng is tr ue a nd correct to t he D est of my k now ledge SIGNED /~/(.,,;~~~~,.,~.,,~/-~- TITLE Regional Drilling Engineer D~ATE The space b~'~, for ~'o~mrr~ssion use CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required / APl numbe¢ ~YES ~"~LFJO ~YES --~NO ~'~'ES -~NO I 50 '_ b i ' '~ ' Permit number APPROVED BY Form 10-401 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 25, ]985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3A-15 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ARCO ;ALASKA, -INC. ..... ~ ........... ; ..... /1/11' --~ PAD _3A. ~ I,/ELL;~N0,-~ .~ PROPOSED ¥~_-L-7__'_~ ........ KUPARUK-FIELD,!--NORTH Si~OPE, -ALASKA ......... ~-KOPT--TVD=GO0- THD-6OO-DEP=O -- - _. -- - 15 PER 1 O0 FT ........... 21 ...... "- - - D-t 595 -DEP= 254 39 EOC' TVD=1864 TIqD=1982 -DEP=479 -- D=-I-gg-1--T ND=2151-DEP=590- _i TOP w SAK SNDS TVD=2676 TlflD=3065 DEPm1195 .... K-12 TVD=2951 TMD=3432 DEP=1438 __ ...... ~ .... 9: 5/8' CSG PT- -LT--- _ '--~£__---~ /.TVD=3151 THD=3699 DEP=1615 -- _AVERAGE-ANGLE - _K--5___IVD=450! IMD=5500 -DEP=2808 _ _ _ . 7_DOn' T/ ZONE D-TVD=5966:]~THD=7455 DEP=4102 .... : I / - -4-~--- T/ .ZONE A ~- TVD=6068 L:l'lflD=ZSgl DEP=4192 ', '~.' TARGET- CNTR---TVD=B12D THD-:?660 DEP-4238 -\ BASE-KUP ~c~4._D$ TYD=6~ 7! THD_=_7_Z28_DEP=42.B3 .... TD _-(LO_G p~-_-_-__T_V_D=632~t_---_~T!'l!~._T928 LDE__P-44)-5 __ _ ' Y_-'-_-' ' ....... ~ ........... ~ ................................ ........ _1_ I_ . I ------;7 ---::'-. -O-;--; ...... ~O00 ...../~22000 .... - .... :5000 .... 4000 .... --_ _ -+ ............. ~ .......... ~ ...................... ,- .... ~ ................ ~' ..... ~ .... ~ ....................... I .$000~ - ---:--::;::: ---! : ...... ~---HOR t-Z~3 N T-A~---~, R 0 JECT I ON. - ............ ~-- EASTM^N -WH I PSTOCK:.---I NC- ' ........ i ................. WEST-EAsT . _ ............... 4000 ....3000 ....... 2000 '-i_: __ 1000 - . 0 ..... ._~Do- -:L , ~ --_---- , , .... t- ...... :- t 065' -F#L~ -tO~4 -' FIdL -- - .... / ' - S'EC:--7.-T~2M,-RgE ....... ARCO ALASKA. - INC; ~ ......... /Ih,, ....... PAD 3^.2 WELL KUPARUK_FiELD. _NORTH_,, SLOPE_._ALASK_ 1000 I .......... ~,- -~OOD ....... A,...%:2~ .... 'fyi:),-612o ......... · --: ........ ----~--'~- --T----"T'I~7660-~ 'I:~RGET LOCATI:I~I, .... :- - ---:7- :-_::-_7_:__ : : ................ ~ ....... NORTH 3215 --- SEC. 7. TI2N. RgE __ - KUPARUK RI VER UNIT 20" DI VE~TER SCHEMAT I C DE S CR I P T I ON I. I G' CC)hEXJCTOR. 2. TAKI,(O STARTER HEAD. 3. T ANKO SAVER SUB. 4. TANKO LOWER OU;[CK-C~CT ASSY. 5. TAt~O UPPER OU]CK-C~CT ASSY. 6. 20' 2000 PSI DRILLING SPOOL W/lO' OUTLETS. ?. I0' t...ICR BALL VALVES W/lO' DIVERTER LIhESo VALVES OPEN AUT~TICALLY UPON CLOSURE OF At~NJL AR PREVENTER. 8. 20' 2000 PSI AI',t,,LJLAR PREVENTER. IVIAIF NTENANCE & OPERAT ] ON I. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AhI~MLAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE Aht~LAR PREVENTER IN THE EVENT THAT AN It~FLUX OF WELL~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANUALLY OVERRIDE AhlD CLOSE APPROPRIATE VALVE TO ACHIEVE ~IND DIVERSION. DO NOT SHUT IN ~ELL UNOER ANY CIRCUIVEiTA~E$. 7 6 13-5/0" '00 PS] RSRRA EOP STACK I. 16' - 2000 PSI TAN<CO STARTING ~ 2. I1' - ~00 PSI CASING PEAD 3. I1' - 30CD PSI X 1~-5/8' - 5000 PSI SPAC~ SPQDL 4. 13-5/8" - 51300 PSI PIPE ~ 5. 13--5V'8' - ~ PSI DRILLING SPOOL W/O-ICKE AhD KILL LIltS 6. 13-5v'8" - 5CX~ PSI DO.,IBLE RAM W/PIPE ~ ~ TC~, 7. 13-5/'8' - 51300 PSI N,,N..LAR ACCIJVlJLATOR CAPACITY TEST I. (DECK AMD FILL ACCI.MJ_ATOR RES~3~/OIR TO ~ LEVEL WITH HYDRALLIC FLUID. 2. ASSURE THAT ACCLM. J_ATCR PEE~ IS ~)0 PSI WITH 1500 PSI DOWNSTREAM CF T~.E ~EGLLATCR. 3. (:B~I~/E TIldE, TI-EN C[.(DSE ALL IJ~[ITS SIM, JLTA/~E~_t'~__Y AbE) REODRD TiE TIIWE AhD PRESSLRE RffiVlAINING AFTER ALL LJN~TS ARE CLOSED WITH CHARGING PLMD CFF. 4. RECI2RD C~I NADC F~PCRT., TiE ACCEPT~ LClt~R LIMIT IS 45 SE~ CL(~ING Tit4[ AhD 1200 PSI RE)4AIN]NG F'RESSLI~. 5 4 2 13-5/8" BOP STACK TEST FILL ~ STACX AhD C~ btANIFCLD WITH ARCTIC DIESEL. 2. Q-ECK THAT ALL LOCK D~ SCREWS IN I~.LLPEAD ARE FULLY RETRACTED. SEAT TEST PLUG IN ~LLI"EAD WITH Rt.N~IING JT AhD RUN IN LCXSXDOINN lll~ VALVES ADJAClD4T TO BC:P STACK. ALL OTIER VALVES ~ CMO(ES SHOJ_D BE (::PEN. 4. PRESSLRE UP TO 2EDO PS] AhD HOLD FOR I0 MIN. IN-- CREASE PRESSZ,RE TO 3500 PSI AMD HOLD FOR I0 MIN. BLEED PRE~__RE TO 0 PSI. 5. CPEN AhNJ_AR PREVE~ AhD MAM. JAL KILL AhD CHCKE LIllE VALVES. CLOSE TOD PIPE ~ AhD HCR VALVES CN KILL AhD O-EDKE LIliES. 6. TEST TO 250 PSI ~ 3500 PSI AS IN STEP 7. C[~NTIN..E TESTING ALL VALVES, LII',ES, AMD WITH A 250 PSI LON AND 3~%2~_ PSI HIGH. TEST AS IN STEP 4. I~D MDT PR~"~-'LRE TE~T ANY CHOd~ THAT ].~ MDT A FULL CLOSING P(]SIT]VE SEAL CHO<E. C~LY F'UNCTIC~ TE~T C)-[DK[S THAT DO MDT FLI. LY 8. OPEN TOP PIPE ~ AND CLOSE BOTT(~I PIPE RAMS. TEST BOTTOM PIPE ~ TO ~ PSI AND 3500 PSI. 9. CPEN BOTTOM PIPE PJ~, BAO< OUT ~NG JT AhD PLJI. L OJT CF H~l.E. I0. CLOSE BLIN~ RA~ AhD TEST TO 250 PSI A~D 3500 PSI. II. OPEN BLIMD ~ AJ~) R~.--TRIFVE TEST PLUG. MAKE SL~ MANIF~ AhD LIhES ARE FULL CF FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAh[~PIPE VALVES, KELLY, KELLY CO0~o DRILL PIPE SAFETY VALVE, AI~ INSIDE BOP TO 250 PSI AhD 13. RECORD TEST I hF'ORIvlATI ON ON BLO~Z,rT PEEVEI~EE TEST F[~I~ SI(~ AJ~ SEI~) TO DRILLING t4. PEEFORM CO~I~LETE ~ TEST AFTER NIPPLING UP ~IEEI~Y THEREAFTER FLNSTI~LY C~"RATE BCPE DAILY. _. I I KUPARUK 16' C ONDUC T OR BOP STACK 5100840C I R6 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3A Pad Wells 1-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, ~J. Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED AUG 5 0 ]~85 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany NOTES 3:ORDINATES ~,RE A.S.P,ZONE 4 2 SECTION _,NE DISTANCES ARE TRUE. 3 HOR'ZONTAL POSITIONS BA3ED CN THE D.S.-3A WEST ~ 3AMID PER LHO 8 ASSOC. 4. VeRTICAL POSITION BASED CN 3A EAST 3A MID PER LHD ~ ASSOC. 5.aG. ELEVATIONS INTERPOLATED FROM S/C CED- RlXX- 3020 rmv. ~ HE~EBYCE~TIFYTHATI .~MPROPESLY~EGISTEREO L',SCENSED rO PRACTICE LAND SURVEYIN~ IN THE~T~TE 9F ALASKA, THAT rH~S ~LAr REPRESENTS A SURVEY MACE UNDER MY OIRECT SUPERV{SION AND THAT ~LL DETAILS ARE CORRECT ~S OF ~UGUST 14,1985 AS 8UILI' CONDUCTORS 1- 16 1- ¥=5,996.860.05 L~T= 70°2~'09.520'' x= 507,712.01 'ONG. 1,,~'}%6''~.©2©'' ~78' :iL, 736' :EL, 36.9 0}, ~0.8 2- Y=5,~96,89~. 17 L~T: 70°7'.' ~. 753'' X: 5J7, 705.57 LON~: l;It ~5' 'g.237'' $03' :SL, 793' ::L, 35.9 '~. -.'.) ~27' :~L, 7~ :EL. ~5.7 Y=5,~§,g32. ~2 ~A~: 70~2~' 13.235'' 5C1' :SL, 756' :EL, 36.7 v:5,~6.)Sfi.61 ~- ~0~' kS..'~'' ~= %0~,696.21 LO~S: 1~g°56' la 7'~" 575'~5L, 762':[L, ~6.$ gq, aO.g PaD O- Y:5,gg6,980.8~ x: $07,67g.66 599' ~SL, 768' x= 507,673.26 523' :SL, ~7~ 8- f=5,gg7,029.03 :,.: 507,566.81 5~7' FSL, 781 9- f=5,997, 101.2~ X= 507,647. 70 720' =~L, 800 10- Y:5,g~, 125.66 ~= 5_ ,6~0.89 744' :'', 806 11- Y=S,gg-, 1~9.8a x= 50',fi3~.~ 768' FSL, 813 [2- Y=s,g97,173.97 x= 507.627.96 792' FSL, 819 13- Y=5,gg7, 199.09 (: ~17' z~_. 925' L~- w=5,~', '22.f~ 9al' F2' . 932' 0 LAT: 70 24' 10.7.09" LONG- 14g°56'1; 963" :EL, 36.5 cAT- 70°2a' 19.~.,:'' LONG= la9°$§' i5 l:i'' ~£L, 36.5 ?';, ',!. l LONG= la~°~J' 15 37~" ~EL, 36.~ LA[= 70°2~' II.8~3'' LONG= 1¢9o56' 15 89§" F£L, 36.30G, ~1.7 LAT= 70°2~'1-.[3~TM LONG= 1~9°~6' 16 9~='' F£L 36.3 9G, :I.§ ~:- L~[= ~0~2~' I2.37I'' LONG= 1~9°56' 16 ~3" FEL 36.2 OG, LA~: 70°2~' 12.50)'' LONG= ~L 36.1 LAT : 70°'-' _. 3~=" ~ L 3§. 0 93, ~ I . :; ' -- Z:L }5.~ LOCATED IN PROTRACT E ARCO Alaska, Inc. DRILL SITE :3 A CONDUCTOR AS- BUILT LOCATIONS Oa,e AUG. 16, 1985 I sco,., l": 3 Drafted by'/_~[ OWg. hal NSK 85-16 · CHECK LIST FOR NEW WELL PERMITS Lease & Well No. /~ J'/.~, (~, 5/~ .... /~ ' ITEM APPROVE DATE (1) Fee (2) Loc (2 thru 8) (3) Admin ~ //",/9-~I 9. (9 thru 12) 10. ? · (10 and 1~) 12. , ,' < 4 ) Casg ?~T'// ,"l~ '~/~-~ (13 thru / t (5) BOrE #,~ '~/'~+,~3 / ' (22 thru' 26) <6> Add //~,d ' /~ / : ! 13. 14. 15. 16. 17. 18. 19. 20. 21. YES NO 1. Is the permit fee attached ......................................... · 2. Is well to be located in a defined pool ............................ 3. Is well located proper distance from property line ................. 'z~_ 4. Is well located proper distance from other wells .... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... 22. 23. 24. 25. 26. REMARKS 27. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... r'2 Is conductor string provided ........................................ f/~ 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 horizons ..................... Will surface casing protect fresh water zones ....................... ~z%/$ Will all casing give adequate safety in collapse, tension and burst . Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ................................. Are necessary diagrams of diverter and ~ equipment attachg~'. . Does BOPE have sufficient pressure rating - Test to ~-z~Z) psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ........................................ Additional Remarks: o Geology: WVA~ JAL ~ Eng~p~e~ring: LCS BEW rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. ,,,t. :~----SCHL~MB E RGER .... ~ LIS T~PE VERIF.IC~TION LISTING RECEIVED JAN 0 8 I986 011 & ~a~ Con~, ~,ornmimm~on Anchorage LVP OlO.H02 VERiFIC&TID~ LISTINS PAGE I '~'~ REEL HEADER SERVICE NAME :EDIT DATE :85/12/22 ORIGIN : REEL NAME :149301 CONTINUATION # :01 PREVIOUS REEL : COMMENTS :LIBRARY TAPE ~ TAPE HEADER ~ SERVICE NAME :EDIT DATE :85/12/22 ORIGIN :0000 TAPE N~ME :1110 CONTINUATION ~ :01 PREVIOUS TAPE : COMMENTS :LIBRARY TAPE · ~ FILE HEADER FILE NAME :EDIT SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : FILE TYPE : PREVIOUS FILE .001 10.24 ~ INFORMATION RECORDS MNEM CONTENTS U!NIT TYPE C.~TE SIZE CODE '" : 3A" 15 000 000 005 065 ,FN t K~P'ARU'K 000 000 008 065 ,R:AN~. 9,E 000 000 002 065 TO~N: 12N 000 000 00~ 065 SECT: ? 000 000 002 065 CO~'N: N. SLOPE 000 000 012 065 ST~T: ALASKA 000 000 006 065 ,CTRY: USA 000 000 00~ 055 MNEM CONTEN'TS ~NIT TYPE CATE SIZE COOE PRES.: E 000 000 DO1 055 · ~ COMMENTS LVP OlO.H02 VERiFICaTION LISTIN~ PAGE 2 SCHLUMBERGER 4~ ALASKA COMPUTING CENTER COMPANY = ARCO ALASKA INC WELL = 3A-15 FI ELD = KUPARUK COUNTY = NORTq SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC: 7111D RUN ~1, DATE LOGGED: 17-DEC-85 LOP: L. B. CUDNEY CASING : 9.625" TYPE FLUID : LSND DENSITY = 10.0 VISCOSITY = 35.0 S PH : 9.5 FLUID LOSS : 11.2 C3 3681 ' BIT SIZE RM RMF RMC RM AT 3HT TO 8035' 4.980 @ 67.0 DF 5.520 @ 67.0 DF 5.300 @ 67.0 DF 2.378 @ 148. DF MATRIX SANDSTONE RECEIVED JAN 0 8 ]98,6 011 & a~ Oon,, Oommlmi~m Anohorage LVP 010.H02 VERIFIC~TIg~ LISTIN$ PAGE 3 HOLE CORRECTION = C4LIPER .~.-~..~ THIS 21T~ HAS N'~T BEEN ~EPTH SHIFTEO - ~VERLIYS FIELD PRINTS SCHLUMBERSER LOGS INCLUDED WITH TqlS MAGNSTIC TAPE: INDgCTION SPHERICALLY FOCUSE~ LOG (OIL) DATA AVAILABLE: 7982.0' TO 3678' FORMATION DENSITY COMPENSATED LOG (FDN) C3MPENSATED ~EUTR]N LOG (FDN) DATA AVAILABLE: 7955.0' TO ~$40' RAY IN CASING (~R.CNL) DAT~ AVAILABLE: 3745' TO 1800' ,,:¢.~-- OAT& FORMAT RECORD LVP OIO.H02 VERIFICATION LISTIN$ PAGE 4 ENTRY BLOCKS TYPE SIZE REPR COlE ENTRY 2 1 66 0 ~ I 66 ~ 4 73 50 ~ 4 65 .lIN 15 1 66 1 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT ~PI API API API FILE SIZE SPL REPR ID ORCER ~ LOG TYPE CLASS MOD NO. CODE DEPT FT O0 000 O0 0 0 4 I 58 SFL~ OIL DHMM O0 220 O1 0 0 4 i 58 IL3 OIL O~MM O0 120 46 O 0 4 1 68 ILM OIL DHMM O0 120 44 0 0 4 1 68 SP DIL M~ O0 010 O1 O 0 4 1 68 GR OIL G~PI O0 310 O1 0 0 4 1 68 GR FDN G~PI O0 310 O1 0 0 4 1 68 CALI FDN IN O0 280 O1 0 0 4 1 68 RHOB FDN G/C3 O0 350 02 0 0 4 1 68 DRH2 FD'N G/C3 O0 356 O1 0 0 4 1 68 NR~T FDN O0 420 O1 0 0 4 1 68 RNRA FDN O0 000 O0 0 0 4 1 68 NPHI FDN PC: 00 890 O0 0 0 4 1 68 NCNL FDN CPS O0 330 31 0 0 4 1 68 ,FCNL FDN CPS O0 330 30 0 0 4 1 68 GR CNL G~PI O0 3.10 O1 O 0 4 I 68 PROCESS (OCTAL) OOOO0000000OO0 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 DEPT 7998.0000 SFLU 12.7988 ILD 14.4853 tLM 11.9707 SP -40.8533 GR 0.8516 GR 0-8516 CALI 8.5020 :~M~B,.~ ...... ',',,',~:~,~',,~,,~~6~:=~,~,,D~~ .......... ......... "~N~,:=,, .... ..... NPHI 4.5.2402 NCNL 38.5367 FCNL 9.6582 GR .-999.2500 DE:' T 7900.0000 SFL~ 10.4¢73 ILO i0 '6 ILMi. 10.~238 'SP -38.8633 GR 86'0.273 GR 86.0; ~3 CALl 8.?20? "R'HDB '2.3420 DRH'O 0,0273 NRAT )4 RNR& 21.8889 NPHt 31.05:4'7 NCNL 22'77.5000 FCNL 787.8: GR -999.2500 DEPT 7~00.0000 SFL2 4.145.B ILO .... 4.32,~0 ILM 4.3054 SP -39.7695 GR 104.3398 GR 104.3398 CALI 9°0098 RHOB 2,,4936 ORH~ 0.0234 NRAT 3.Z05~ RNRA 3.6956 NPHI 37.0117 NCNL 2199.5000 FCNL 594.8125 GR -999.2500 DEPT ?TO0.O000 SEL5 IT.1611 ILO 15.0098 ILM 18.3174 ,SP -49,2383 GR 55..8398 GR 65,.8398 CALI 8.8301 RHOB 2.3850 DRHO 0.000:0 NRAT 2.8499 RNR~ 3.2268 NPHI 31.2500 NCN'.L 2733,5000 FCNL 846.8125 GR -999.2500 DEPT 760.0.0000 SFLO 1.9307 ILO 2.0959 ILM 2.1331 SP -32,,4570 GR 113.5273 GR 113.5273 CALI 9.5566 RHOB 2.3635 DRMO 0.0151 NR~T 3.9065 RNR~ 4.4890 LVP OlO.HO2 VERIFIC4TIDN LISTIN~ PAGE 5 NPHI DEPT SP RH~B NP~I DEPT SP RHOB NPHI DEPT SP RHOB NP~I DEPT SP RH2B NPHI DEPT SP RH3B NPHI DEPT SP RHOB NPHI DEPT SP NPHI DEPT SP R:HOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP 49.023~ NCNL 1838.6875 FCNL 411.6~06 GR 7500.0000 SFLU 3.0315 ILO 2.6721 ILM -35.7595 GR 110.9023 GR. 110.9023 CALI 2.3948 DRHD 0.0034 NRAT 4.I509 RNRA 52.1973 NCNL 2018.5875 FCNL 402.1406 GR 7400.0000 SFLJ 2.9846 ILD 3.1995 ILM -31.6514 GR 134.5625 GR -999.2500 CALI -999.2500 DRH] -9'99.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCNL -999.2500 GR 7300.0000 SFLd 15.2441 ILO 7.0554 ILM -15.2~02 SR 192.3125 GR -999.2500 CALI -999.2500 DRH3 -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCWL -999.2500 GR 7200.0000 SFLd 4.4539 ILD 3.87t3 ILM -40.3008 GR 125.9548 GR -999.2500 CALI -999.2500 OR,D -999.2500 NRAT -999.2500 RNRA -999.2500 NCNL -999.2500 FCNL -999.2500 GR 7100.0000 SFLU 4.0164 ILD 4.2156 ILM -50.6758 GR 140.9375 GR -999.2500 CALI -999.2500 DRH2 -9~9.2500 NRAT -999.2500 RNRA -999.2'500 NCNL -999.2500 FCNL -999.2500 GR 7000.0000 SFLJ 3.9866 ILD 4...2898 ILM -39.2070 GR I09.1523 GR -999.2500 CALI -999.2500 DRH3 -999.2500 NRA'T -99'9.2500 RNRA -999.2500 NCNL -999.2500 FCNL -999.2500 GR 6900.0000 SFLU 2.3594 ILO 2.2559 ILM -999.2500 NCNL -9~99.2500 FCNL -999,2500 GR 6800.0000 SFLg 3.'7D34 ILD 4.0789 ILM -31.2139 GR 120,5273 GR -999~2500 CALI -999.2500 ORHD -999.25'00 NR~T -999,2500 RNRA -999'2500 NCNL: -999,2500 FCNL -999,,2500 GR -999.2500 2.7952 10.5566 5.0203 -999.2500 3.0842 -999.2500 -999.2500 -999.2500 8.7207 -999.2500 -999.2500 -999.2500 3.9260 -999.2500 -999.2500 -999.2500 4.2468 -999.2500 -999.2500 -999.2500 4.3093 -999.2500 -999.2500 -999.2500 2.4866 -999.2500 -999.2500 4.0554 -999.2500 -999.2500 -999.2500 6500.0000 SFLU 4.9656 ILD 4.3523 ILM 4.4070 -42.9883 GR 100.0898 G'R -999.2500 CALI -999.2500 6600.0000 SFLg 4.133'5 ILO 4.0'789 ILM 4.0671 -33.7695 GR 1t4..7148 GR -999.2500 CALI -999.2500 .99'9.2500 'DRY:3 -999.2500 NRAT -999.2500 RNR~ -999.2500 -999.2500 NCNL -999.2500 FCNL -999.2500 GR -999.2500 6700°0000 SFLU 5.12 4.8~45 ZLM' 18 I L D 4.8328 -15.9824 GR 106.9023 GR -999.2500 CALI -999.2500 -999.2500 DRH3 -999. 2500 NRAT -999.25-00 RNR~ -999.2500 -999.2500 NCNL -999.2500 'FCNL -999.2500 SR -999'2500 LVP OlO.H02 VERIFICATiDN LISTIN~ PAGE 8 RH2B -999.2500 DRq2 -999.2500 NR&T -999.2500 RNR& NPHI -999.2500 N~CNL -999.2500 PCNL -999.2500 GR DEPT 6400.0000 SFLd 4.0085 ILD 4.1614 ILM SP -30.2507 GR 99.0273 GR -999.2500 CALI RHDB -999.2500 DRH] -999.2500 NR~T -999.2500 RNRA NPqI -999.2500 NCNL -999.2500 FCNL -999.2500 GR D~PT 6~00.0000 SF~.J ).S~Oa ~.D ).~ SP -37.7070 GR 112.95~8 GR-99g' 2500 CALI R.~ -~.~oo D~ -~.~SO0 ~Z~-~.~00 NPHI -999.2500 NCNL -9g9.2500 FCNL -999.2500 GR DEPT 6200.0000 SFLJ 3.0959 ILD 3.3167 ILM SP -36.3008 GR 117.5898 GR -999.2500 CALI RHDB -999.2500 DRH2 -999.2500 NRAT -999.2500 RNRA NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR DEPT 6100.0000 SFLJ 3.7581 ILD 3.8401 ILM SP -45.1133 GR 109,0898 GR -999.2500 CALI RHDB -999.2500 DRHO -999.2500 NRAT -999.2500 RNR~ NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR DEPT 6000.0000 SFLJ 3.1331 ILD 3.0881 ILM SP .-43.8633 GR 114.6523 GR 114-6:523- CALI R~HDB 2,3342 DRHD -0.0020 NRAT 3.7092 RN'R~ NPHI ~4.0030 NCNL 2000.6875 FCNL 512.3125 GR DEPT 5900.0000 SFLU 3.6741 ILD 4.0203 I:LM SP -41.9258 GR 78.'??73 GR 78.??73 CALI 'OBRH 2.~5T3 DRHD -0,0132 NR~T 3'~260 RNR'~ DEPT 5800.0000 SFLU 2,7756 ILD 2.7893 ILM RHOB 2.3~20 DRHD 0.0054 NRAT 3.4417 RNRA DEP'T 5700'0000 SF.LU: 4.8835 ILD 4.2~20 ILM S'P - 5?. 5508 G R 128 · 3125 G R - g 9 g. 2 ~O 0 'C ~ L I ,RHDB -999,2500 DR,fiD -999.2500 NR'~T '-ggg. 2~500 RNR4 ,~NPHI -999,,°25,00 NCNL -9 ~,9.2500 FCNL - 999..., 2~,~00 GR -999.2500 -999.2500 4.1804 -999.2500 -999.2500 -999.2500 3.7053 -999.2500 -999.2500 -999.2500 3.3831 -999.2500 -9'99.2500 -999.2500 3.8186 -999.2500 -999.2500 -999.2500 3.1213 10.~863 3.9065 -999.2500 4.26251 9.5566 3.6506 -999.2500 2.7991 3.8479 .999°2500 4.2625 -9'99.25'00 .-999.2500 -999..2500 DEPT 5600.0000 S~LJ 2.7893 !LD 3.1038 ILM 3.0334 SP -44.3008 GR 175.9375 GR -999,25:00 CALI -999.2500 RHDB -999.2500 DRH~ -999.2500 NRAT -999.2500 RNRA -999.2500 NP~I -999.2500 NCNL -999.2500 FCNL -999,2~00 GR -999.2500 DEPT 5590.0000 SFLJ 1.9590 ILD 2.051.0 ILM 2.0510 SP 40.8008' GR 130.3125 GR -99.9.25'0'0 CALI -999.2500 RHOB -999.2500 DRHD -999.2500 NRAT -9'99.25'00 RNR~ -999'2500 NPqI -999.2500 NCNL -999.2500 FCNL -999.2500 GR -9'99.2500 DEPT 5400.0000 SF.LJ 2.1135 ILD 2.0100 ILM 2.0237 RECEIVED LVP OlO.H02 VERIFICATI~ LISTiN~ PAGE T SP -34.~883 GR 135.9375 GR -999.2500 CALI RH3B -999.2500 DRH] -999.2500 NR&T -999.2500 RNR~ NPHI -999.2500 NCNL -999.Z500 FCNL -999.2500 GR DEPT 5300.0000 SFLJ ~.0055 ILO 3.9924 ILM SP -54.8533 GR 151.8125 GR -999.2500 CALI RH~B -999.2500 DRHO -999.2500 NR~T -999.2500 RNR~ NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR DEPT 5200.0000 SFLU 3.0315 ILO 2.9~95 ILM SP -47.4883 GR 1.~4.6875 SR -999.2500 CALI RHOB -999.2500 DRH3 -999.2500 NRAT -999.2500 RNR~ NPHI -999.2500 NCNL -999.2500 FC~L -999.2500 GR DEPT 5100.0000 SFLU 2.6487 ILO 2.8772 ILM SP -47.3533 GR 115.3398 GR -999.2500 CALI RHDB -999.2500 DRM3 -999.2500 NR&T -999.2500 R~NR~ NPHI -999.2500 NCNL -999.250'0 FCNL -999.2500 GR DEPT 5000.0000 SFLU 3.3557 ILD 3.5862 !LM SP -44.4258 GR 93.2773 GR -999.2500 CALI RHDB -999.2500 DRHD -999.2500 NRA'T -999.2500 RNRA NPHI -99'9.2500 NCNL -999.2500 FCNL -999.2500 GR DEPT 4900.0000 SFLU 3.1936 ILD 3.3~79 ILM SP -42.3533 GR 120.0'273 GR 120.02?3 CALI RH2B 2.312T DRHO 0.0t5I NR~'T 3.2502 RNR~ NPHI 35.4004 NCNL 1974.6875 FCNL 506.3906 GR ~DEPT 4800.0000 ~FLU 2.9299 ILO 3.1917 ILM SP -~4.5508 G'R 97.8523 GR 97.6523 CALl RHDB 2.3147 DRH2 0.0225 NRAT 3.3909 RNRA NPSI 37.'8~18 NCNL ZO81'SDO0 FC~L 575.3125 GR SP -39.9883 GR NPHI 38' 4?66 NCNL DEPT fi600,O000 SFL3 ~SP -44.613.3 GR ,~H@B -999-2.500 ..... DRH2 :NPHI -999.2500 NCNL DEPT ~500.0000 SFLD SP -46.6?58 GR RH3B -999.2500 DRHD NPHI -'999.2500 NCNL 38.1523 GR 88.1523 CALI 2223-5000 FCNL 558,3125 GR -999.2500 -999.2500 -999.2500 3.9729 -999.2500 -999.2500 -999.2500 2.9299 -999.2500 -999.2500 -999.2500 2.9225 -999.2500 -999.2500 -999.2500 3.6155 -999.2500 -999.2500 -999.2500 3.2620 I0.650~ 3.8987 -'999.2500 3,1213 10~8223 3.6174 -999.2500 10.7832 -999.2 O0 2.6760 ILO 2,9026 ILM 2,7737 90.3398 GR -999.2500 CALI -999.2500 -9,99,,.Z:SQO,,NRAT -999~.25,0,0 R. NR,~.. -999,-1500 -999.2500 FCNL -999.2500 GR -99.9.2500 4.5'750 ILD ~.'7859 ILM 4.6765 ?5.8398 GR -999.2500 CALl -999.250-0 -999.2500 NR~T -999.25.00 RN.RA .-999.2500 -999.2500 FCNL -999~2500 GR -999.2500 DEPT. 4400.0000 SFLU 3 5527 ILO 3.8557 ILM 3.7600 SP -50.0508 GR 103~0273 GR -999.2500 CALl -999.2500 RH2B -999'2500 DRHO -999.2500 NRAT -9'99.2500 RNR~ -999.2500 NPHI -999.2500 NCNL -999'2500 FCNL -999.2500 GR -999.2500 LVP OlO.H02 VERIFICATION LISTING DEPT 4300.0000 SFLU SP -45.89~5 GR RHD5 -999.2500 DRH; NPHI -999,2500 NCNL DEPT 4200.0000 SFLO SP -44.0820 GR RHDB -999.2500 DRq2 NPHI -999,2500 NCNL DEPT ~100.0000 SFLd SP -50.0195 RHDB -999.2500 ORH2 NPHI -999.2500 NCNL DEPT 4000.0000 SFLU SP -50.4258 GR RHOB -999.2500 DRH2 NPHI -999.2500 NCNL DEPT 3900.0000 SFLO SP -45.2070 GR RHDB -999,2500 DRH2 NPqI -999.2500 NCNL DEPT 3800.0000 SFLJ SP -45.9258 GR RH2B -999.2500 DRY2 NPHI -999.2500 NCNL DEPT 3700'0000 SFLU SP --~,6.2383 GR RHDB -999,2500 DRHD NPHI -999,2500 NCNL DEPT 3600'0000 S:FLg RHDB -999,2500 DRHD NPHI -999,2500 NCNL DEPT 3500.0000 SFLU SP -,9,99.,,2.500. GR,, RHDB 999,2500 ,DRHg .NPHI -9.99-2500 NCNL DEPT 3~O0,ODO0 SFLU SP ]~99,2 O0 GR R'HOB -=9'9'2~00 DRM.~ NPHI -999.2500 NCNL DEPT 3300.00,00 S,PLU SP -999,~2500 GR RHOB -999.2500 DRH3 NPHI -999.2500 NCNL 2,8225 ILD 112.2773 GR -999.2500 NRAT -999.2500 FCNL 2.8928 97.9023 GR -999.2500 NRAT -999,2500 FCNL 4.1843 ILD 197.6523 GR -999.2500 NR~T -999.2500 FCNL 4,6414 ILD 129.0625 GR -999,2500 NR~T -999.2500 FCNL 3.6956 ILD 108.2773 GR -999.2500 NRAT -999.2500 FCNL 3.1917 ILD 96.9023 GR -999.2500 NRAT. -999.2500 FCNL 4.0164 ILD 93.7148 GR -999'.2500 NRAT -999.2500 FCNL -9'99.2500 ILD -9 99. 2500 -999.2500 3.0901 ILM -999.2500 CALl -999.2500 RNR& -999.2500 GR 3.1780 ILM 99. O0 RNRA -999.Z500 GR 4.5398 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 4,7468 ILM -99 2500 RNRA 4.3-6'79 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.5706 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 4,8t32 IL'M -999,2500 CALI -999,250'0 RNRA -999,2500 GR -999 2~ iLM CAkt RNRA GR ILO -999.2,5,0,0 ILM GR -9,9.,9~.2,~,~00 'CALI NRAT -999,2500 RNRA FCN'L -999.2500 GR -999.2500 ILD -999,2500 IL4 -999.2500 GR CALI -9'99.2500 NRAT RN'RA -999,2500 FCNL. -999.2500 GR -999,2500 ILO -999,2500 ILM -999:,2500 GR -999.2500 C. ALI -999,2500 NRAT -999.2500 RNR~ 999.2500 FCNL -999.2500 GR 3.0471 -999.2500 -999.2500 -999.2500 3.0334 -999.2500 -999.2500 -999.2500 4.3367 -999.2500 -999.2500 -999.2500 4.5828 -999.2500 -999.2500 -999.2500 4.0671 -999.2500 -99'9.2500 -999.2500 3.3772 -999.2500 -999.2500 -999.2500 4,2546 -999.2500 -999.2500 89,9648 :' ,'~ v: -999.2500 -999.2500 43,9492 -999,.2500 -999° 500 -99,9.~500 56.5430 -999.2500 -999.2500 -999.2500 69°4023 -999,2500 -999,2500 -999.2500 51.8555 LVP OlO.H02 VERIFiC~TI3~ LISTINS PAGE 9 DEPT 3200.0000 SFLJ -999.2500 ILD -999.2500 ILM SP -999.2500 GR -999.2500 GR -999.2500 CALI RHDB -999.2500 DRY2 -999.2500 NRAT -999.2500 RNR~ NPqI -999.2500 NCNL -999.2500 FCNL -999.2500 GR DEPT 3100.0000 SFLJ -999.2500 ILD -999.2:500 ILM SP -999.2500 GR -999.2500 GR -999.2500 CALI RH3B -999.2500 DRH] -999.2500 NR~T -999.2500 RNR~ NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR DEPT 3000.0000 SFLJ -999.2500 ILD -999.2500 ILM SP -999.2500 GR -999.2500 GR -999.2500 CALl RHDB -999.2500 DRH2 -999.2500 NR~T -999.25~0 RNR~ NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR DEPT 2900.0000 SFLU -999.2500 ILD -999.2500 ILM SP -999.2500 GR -999.2500 GR -999.2500 CALI RHOB -999.2500 DRHO -999.2500 NR~T -999.2500 RNR~ NPHI -999.2500 NCNL -999.2500 FCNL -999.2500 GR DEPT 2800.0000 SFLJ -9,99.2500 ILD -999.2500 ILM SP -999.2500 GR -999.2500 GR -999.2500 CALI RHDB -999.2500 DRH2 -999.2500 NR~T -999.2~00 RNR~ NPHI -999.2500 NCNL -999.2500 FC~L -999.2500 GR DEPT 2700.0000 SFLU -999.2500 ILD -ggg.2500 ILM ~SP -999.2500 GR -999.2500 GR -9'99.2500 CALI RHDB -999.2500 DRY2 -999.2500 N'RAT -999.2500 RNR~ NPHI -999.250,0 NCNL -999.2500 FCNL -999.2500 GR DEPT 2600.0000 SFLU -99'9,2.500 ILD -999.2500 ILM SP -999.2.500 GR -999.2500 GR' -999,2500 CALI RHDB -999.2500 DRH2 -999,2500 NRAT -999'2500 RNRA -999.2500 -999.2500 -999.2500 55.5742 -999.2500 -999.2500 -999.2500 55.7148 -999.2500 -999.2500 -999.2500 55.9648 -999.2500 -999.2500 -9~99.2500 49.6680 -999.2500 -999.2500 -999.2500 58.2617 -999.2500 -999.2500 -999.2500 52.5742 -999.2'500 -999.2500 -9'99.2500 DEP'T 2200.0000 SFL~ -999.2500 ILD ,-999.2500 ILM -999.2500 SP -999.2500 GR -999.2500 GR -999.2500 CALi -999.2500 RH2B -999,2500 DRHD -999.2500 NRA'T -999.2500 RNR~ -999.2500 OEPT 2300.000Q SFLO -999,2500 ILD -999,2500 ILM -999.2500 SP -999.2500 SR -999.2500 GR -999.2 500 CALl -999.2500 RHOB -999,2500 DRHD -999-2500 N,R~T -999.2~00 RNR'A -999.2500 NPHI -999.2500 NCNL -999.25.00 FCNL -999,2500 GR 52.536T DE, PT 2400,,,,0,000 SFL~ -999 25,00 IL,D -999-,2500 ILM -999,2500 SP -999-2500 GR -999,250,0 GR -999,2500 CALl -999.2500 RHDB -999.2500 DRH~ -999.2500 NR~T -999.2500 RNRA -999,2500 NPHI -999,2500 NC~L -999.2500 FCNL -999,2500 GR 29'9268 SP -999.2500 GR GR CALI -999.2500 RHDB -999~25D0 DRH2 -999,2500 NRAT RNRA -999.2500 NPHI -999.2500 NCNL -999*2500 F'CNL -999,2500 GR 2'7.7705 LVP OlO.H02 VERIFICATIOq LISTIN~ PAGE NPHI -999.2500 NCNL DEPT 2100.0000 SFLJ SP -999.2500 GR RHOB -999.2500 ORH3 NPHI -999.2500 NCNL DEPT 2000.0000 SFLU SP -999.2500 GR RHDB -999.2500 DRH2 NPHI -999,2500 NCNL DEPT 1900.0000 SFLU SP -999.2500 GR RHDB -999.2500 DRHD NPHI -999.2500 NCNL DEPT 1800.0000 SFLg SP -999.2500 GR RHOB -999.2500 DRHg NPHI -999.2500 NCNL DEPT 1700.0000 SFLJ SP -999°2500 GR RHOB -999.2500 DR~g ~NPHI -999.2500 NCNb; DEPT 1689o0000 SFLU SP -999.2500 ~R RHDB -909,o2~00 DRH2 NPHI -999.2 00 NCNL -999.2500 FCNL -999.2500 ILO -999.250'0 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500' GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NR~? -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -9'99.2500 GR -999.2500 NRAT -999.250'0 FCNL -999.2500 ILO -9~9.2500 GR -999.2500 N:RA'T -999°2500 FiCNL -999.2500 GR -999.2500 ILM -999.~500 CALI 999.2500 RNR& -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.~500 GR -999,2500 ILM -999.2500 CALI -999 ~00 RNR~ 999; O0 GR -999.2500 ILM -999.2500 CALI -999.250'0 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNRA -999°2500 GR 37. -999. -999 · -999. 4-6. -999. -999. -999. -999 · -999. -999. 38. -999 -999 -999 ,45. -999. -999. -999. O. -999 .. -999. -999. O. 9180 2500 2500 2500 5367 2500 2500 2500 5~30 2500 2500 2500 7305 2500 2500 2500 4805 2500 2500 2500 0000 2500 2500 2500 0000 SERVICE NAME : : 1024 NEXT FILE NAME : · ~ TAPE TRAILER g:,g: S~RVI,CE NAME :,EDIT DATE ,$5/12/22 ORIGIN :0000 TAPE NAME :1110 CONTINUATION ~ :01 NEXT TAPE NAME : COMMENTS :LIBRARY TAPE RECEIVED JAN 0 8 198B Oil & Gas Cons. LVP OlO.HO2 VERIFICaTiON LISTZNS PAGE ~c REEL TRAILER ~¢ SERVICE NAME :EDIT DATE :85/12/22 ORIGIN : REEL NAME :1¢9301 CONTINUATION # :01 NEXT REEL NAME : COMMENTS :LIBRARY TAPE
