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197-045
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-10-24_22131_KRU_3O-20_ArcherVividAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22131 KRU 3O-20 50-029-22750-00 Archer Vivid Acoustic LDL 24-Oct-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 197-045 T38142 11/21/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 11:43:05 -09'00' Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-06 50-029-21336-00 906905927 Kuparuk River Multi Finger Caliper Field & Processed 6-Jan-21 0 1 2 3B-06 50-029-21336-00 906953734 Kuparuk River Packer Setting Record Field- Final 1-Feb-21 0 1 3 3K-03 50-029-21602-00 906961911 Kuparuk River Multi Finger Caliper Field & Processed 9-Feb-21 0 1 4 3K-27 50-029-22751-00 906880550 Kuparuk River Packer Setting Record Field- Final 22-Dec-20 0 1 5 3M-17 50-029-21729-00 906892184 Kuparuk River Packer Setting Record Field- Final 29-Dec-20 0 1 6 3M-17 50-029-21729-00 906892184 Kuparuk River Temperature Record Field- Final 30-Dec-20 0 1 7 3N-02A 50-029-21527-01 906798653 Kuparuk River Packer Setting Record Field- Final 31-Dec-20 0 1 8 3O-20 50-029-22750-00 906941859 Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-21 0 1 9 3N-07A 50-029-21539-01 906604302 Kuparuk River String Shot Record Revised 16-Jul-20 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 1970450 E-Set: 34744 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: 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 attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 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 ❑ Change Approved Program ❑ Plug for Redrill ❑ •erforate New Pool ❑ Repair Well ❑✓ Re-enter Susp Well ❑ SC repair El 2. Operator ConocoPhilllps Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: DevelopmentEz ❑ Exploratory ry ❑ Stratigraphic ❑ Service ❑ 197-045 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-22750-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRL) 30-20 ADL0026519 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,400 feet Plugs measured None feet true vertical 6,836 feet Junk measured 10300' feet Effective Depth measured 10324' feet Packer measured 7875' feet true vertical 6787' feet true vertical 4947' feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 121' MD SURFACE 6,266 feet 7 5/8 " 6,308' MD PRODUCTION 10,351 feet 5 1/2 " 10,390' MD JEWELERY TYPI MD epth feet Composite Tubing (size, grade, measured and true vertical depth) 3.511 L-80 7,876' MD 4,948' TVD Packers and SSSV (type, measured and true vertical depth) SEAL ASSY - BAKER 80/40 SEAL ASS 7,859' MD 4,938' TVD PACKER - BAKER 5.5" FA -1 PACKER 7,875' MD 4,947' TVD ANCHOR SEAL ASSY - BAKER KBH -2 7,875' MD 4,947' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Pressur Casing e Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA INA INA NA 14. Attachments (required per 20 AAC 25.070, 25.071, 825.283) 15. Well Class after work: Daily Report of Well Operations ❑� Exploratory ❑ ❑ Development A Service p ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑' Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: 318-142 Authorized Name: Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@conocophilljps.com Authorized Signature: 31Contact Phone: 907-659-7506 yLq� Dale: VrL- 3/15//1 /Vp -';4 / Form 10.404 Revised 4/2017 RBDMS.i�-'"' MAR 0 6 2019 Submit Original Only ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 1, 2019 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 Commissioner French: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 30-20 (PTD 197-045) for surface casing repair. If you need additional information, please contact us at your convenience. Sincerely, Roger Mouser / Roger Winter Well Field Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7506 tWELLS TEAM Carw z>fvllips 30-20 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/11/19 SC REPAIR: CUT WINDOWS AND REMOVE CEMENT AND SEALANT FOR SC 02/12/19 SC REPAIR: REMOVED THE CONDUCTOR AND CLEANED SC. IDENTIFIED A LEAK 02/22/1 DISC REPAIR (IN -PROGRESS) WELDED A AND B COLLARS TO SC (COMPLETE) RETURN IN MORNING TO INSTALL SLEEVE. A band (0.500" 5L -X65 pipe, 4"x1.75" layered). B band (0.500" 5L -X65 pipe,6"x3" layered) 02/23/19 02/25/1 SC REPAIR (IN PROGRESS) INSTALLED 18'3.5" SC SLEEVE, BEGAN WELDING OF SLEEVE. RETURN IN THE AM TO COMPLETE WELDING PROCESS. FOR PRESSURE TESTING. 18'3" 11.375" diameter 0.50" 5L -X65 9 SC REPAIR (IN PROGRESS) AOGCC INSPECTOR LOU LAUBENSTEIN EMAILED TO PROCEED WITHOUT WITNESS. SCLD PASSED. INSULATORS DENSO WRAPPED SC 02/26/19 SC REPAIR (IN -PROGRESS) FIT AND WELDED 21'2" OF 16" 62.5 POUND H-40, 0.256 02/27/19 SC REPAIR COMPLETE REMOVED STAIRS AND SHORINGING BOX ROADS AND PADS BEGAN BACKFILLING EXCAVATION Copyright 2019. All rights reserved. This ph6tc raph is provided o the AOGCC with permission to copy fors -ids sawn use. Copying x any other purpose or by other party is prohibited with ON 0 1 1 4 xpress consent of ConocoPhillips Alaska, Inc." I Fl� P Copyright 20iY,� provided,to the use. Copying fb p I rohibji4M�h� P Alaska,! I nt."r Vii. -;A4 A reserved. *s P ,ith permission td 7"purpose or by o press cWsent of y` k .. ti's • ✓ ��_ L ""Olt. T S_• ilk ilk Copyright 2019. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by other party is prohibited without the express consent of { ConocoPhillips Alaska, Inc." i I "Copyright 2019. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by other party is prohibited without the express consent of ConocoPhillips Alaska, Inc." k:. /\ 1 i 1 li Lrl0 a) sr I— r r r > . . . . . . r r r O ; N o 3 N. O O 0L,,, N .0 Q O _� ( i 0A (6 > ro VI Y O a) CO a) CTI O C U h 4 > p ro O 0 a) 1j s-- CN v a a C C }, o i C 75 w i.,• C La Q - c t"• iC, O o ou >' al Q p — r, w CO Co co ao 0o CO CO CO CO CO CO *' Q) `- 0Q O- CO Qs � L N 7 4 LsqOaroaaaaaaaa + O -o +' ,_ v, ' J E E Q Q Q Q Q Q Q Q Q c L ro N C ,. F N M M f� f� O r N CO Ti- lf) o +-, c I 0a) C U Z g E > -a a) • O c i co (31 -ON u 0,10 0 0 0 0 0 0 0 0 p p 0 O ` IV Q L J J J J J J J J J J J O0 C i� O y W W W W W W W W W W W v, 0.) 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H fY4 r r L C a Q Q N -1 r N M c 42 am- M co OM OM = _ _ Z aJ r6 VI ,--iCD OCM 0. 3a �� F 0 E• -<"? • • OF zhr 401**1 yy�s� THE STATE Alaska Oil and Gas Of A LA CK k Conservation Commission t 5 }{: � 333 West Seventh Avenue ' c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 "7 Main: 907.279.1433 41LA614' Fax: 907.276.7542 www.aogcc.alaska.gov Roger Mouser Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. NED P.O Box 100360 �A� Anchorage,AK 99510-0360 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 30-20 Permit to Drill Number: 197-045 Sundry Number: 318-142 Dear Mr. Mouser: 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, Hollis S. French Chair DATED this D day of April, 2018. RBDMS(APR 0 6 2018 • • RECEIVED STATE OF ALASKA Daps 20180"45 1 l 8/ ALASKA OIL AND GAS CONSERVATION COMMISSION ,/i► OGCC APPLICATION FOR SUNDRY APPROVALS �1 20 AAC 25.280 1.Type of Request: Abandon H Plug Perforations U Fracture Stimulate LJ Repair Well U Operations shutdown U Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: SC RepaiL ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 2 • 197-045' 3.Address. Stratigraphic ❑ Service H 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 500292275000 • 7.If perforating: N/A` 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? �( • Will planned perforations require a spacing exception? Yes ❑ No W KRU 30-20 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025519 . 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): ' 10,400' ' 6,836' , 10,324' , 6,767 10,300' Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 121' 121' N/A N/A Surface 6,266' 7.625" 6,308' 4,130' N/A N/A Intermediate Production 10,351' 5.5" 10,390' 6,287' N/A N/A Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,116'-10,165'' 6,580'-6,624' 3.500" L-80 10,011' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER 5.5"FA-1 PACKER MD=7875 TVD=4947 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG H 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: Roger Mouser Contact Name: Roger Mouser/Roger Winter Authorized Title: Well Integrity Field Supervisor Contact Email: N1927@conocophillips.com Contact Phone: 907-659-7506 Authorized Signature: 61/20-1a/R4 Date: .314U f COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/3 I yz Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / / Ph ofb Glo cr. vvi r— 1-- A t i 5- 1—f7)_S Post Initial Injection MIT Req'd? Yes ❑ No ®' Spacing Exception Required? Yes ❑ No V Subsequent Form Required: J(i — 4o 4- 809 j APPROVED BY 9 I S IIS Approved by: COMMISSIONER THE COMMISSION Date: (�,LxI`�,�', likA INtr ,* 01K r T-1- 115/`e. RBQMS APR fns V J` tt �� /'1f1� 0 96b� ��mand l0 Form 10-403 Revised 4/2017 Approved applicatio v li f r h f ate of approval. Attachments in Duplicate • March 30, 2018 Commissioner Hollis French Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Hollis French: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 30-20, PTD 197-045 for repairing surface casing leak. Please contact me at 907-659-7506 if you have any questions. Sincerely, le/71//147it Roger Mouser ConocoPhillips Well Integrity Field Supervisor Enclosures: Description Summary of Proposal 10-403 Application for Sundry Approvals 30-20 Wellbore Schematic • • ConocoPhillips Alaska, Inc. Kuparuk Well 30-20 (PTD 197-045) SUNDRY NOTICE 10-403 APPROVAL REQUEST March, 2018 This application for Sundry approval for Alpine well 30-20 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate,well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to—22'. 4. Install nitrogen purge equipment for the conductor and OA(if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. IMS a h ee. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test(Open OA shoe)to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to injection. 13. File 10-404 with the AOGCC post repair. ti - UP PROD 30-20 ConocoPhillips /A Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status Inc)7) MD(ftKB) 'Act Btm(ftKB) rnweoPnlup. 500292275000 KUPARUK RIVER UNIT PROD 63.25 6574.84 10,400.0 ... + Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-20,3/7/20172:22:41 PM SSSV:NONE 140 12/26/2013 Last WO: 41.00 3/29/1997 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _ r Last Tag:SLM 10,142.0 12/27/2015 MISSINGRev on:GLV CORRECTION(4)WAS pproven 3/7/2017 HANGER;37.0 i1llh,,a ( Casing Strings Casing Description OD 9n) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED -' "" ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 41.6 6,308.0 4,130.3 29.70 L-80 BTC 1 �I Casing Description OD( in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread J` PRODUCTION 51/2 4.950 38.8 10,390.0 6,826.9 15.50 L-80 LTC-MOD 5.5x4.5@10,031 `^Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) I Set Depth(ft..Set 4,947.7 Set Depth(TVD)I...Wt(11n/ft) Grade Top Connection TUBING UPPER 3 1/2 2.992 37.0 7,876.2 9.30 L-80 EUE 8rd CONDUCTOR;42.0-121.0 s RWO 2015 Completion Details Nominal ID Top(6/011) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 37.0 37.0 0.00 HANGER Tbg hanger 3.000 7,858.5 4,938.0 56.75 TOR tor sub 3.010 7,858.9 4,938.2 56.76 Ba 3.010 11.I 7,860.9 4,939.3 56.80 PRSEAL ASSY Baker80/40 R r 80/40 Seal assembly 10 ft 8010 GAS LIFT;3,153.4 'i 7,874.5 4,946.7 57.03 ANCHOR Baker KBH-22 Anchor Seal Assembly 3.000 SEAL ASSY • Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING RWO 2015 31/2 2.992 7,874.7 10,019.0 6,491.7 9.30 L-80 EUE 8rd (Lower Packer) GAS LIFT;5,479.8 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Corn (in) 7,874.7 4,946.8 57.03 PACKER Baker 5.5"FA-1 Packer 3.620 7,878.5 4,948.9 57.10 XOVER 3.5 NU X 3.5 L-80 rd Xover 2.980 2.812 9,981.8 6,457.8 24.47 NIPPLE 3.5 X 2.812 DS nipple 10,003.2 6,477.3 24.61 LOCATOR Locator sub 3.000 ID(in) 3.000 10,003.7 6,477.8 24.62 SEAL ASSY Baker 80/40 seal assembly Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl SURFACE;41.e-8,308.0 + - Top(ftKB) (ftKB) (°) Des Com Run Date 10,300.0 6,745.6 25.39 FISH PERF GUN PART 8"NOSE STRIP OF PERF GUN 9/25/2005 LOST 9/25/2005 GAS LIFT;6,924.1 Perforations&Slots IIStot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zane Date t) Type _ Com 10,116.0 10,131.0 6,579.6 6,593.1 A-3,30-20 4/12/1997 4.0 (PERF 180 deg ph;oriented(1-/ GAS LIFT;7,800.1 C!� -)f/lowside;2-1/8"EJ 10,140.0 10,165.0. 6,601.3 6,623.8 A-2,30-20 9/25/2005 ' 6.0 APERF 2-1/8"Spiral EJ,45 deg. phase Mandrel Inserts LOCATOR;7,858.5 St. ati SEAL ASSY;7,858.9 I:l. N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB)_ (ftKB) _ Make Model OD(in) Sery Type Type (in) (psi) Run Date Com PBR;7,860.9 1' 3,153.4 2,491.0 Camco KBG 1 GAS LIFT GLV INT 0.156 1,307.0 11/23/2015 2 5,479.8 3,699.5 Camco KBG 1 GAS LIFT GLV INT 0.156 1,282.0 11/23/2015 ANCHOR SEAL ASSY;7,874.5 I,. .i PACKER;7.874.7 l:i:l 3 6,924.1 4,432.8 Camco KBG 1 GAS LIFT GLV INT ' 0.188' 1,309.0 11/23/2015 %OVER;7,878.5 4 7,800.1 4,905.6'Camco KBG 1 GAS LIFT OV INT I 0.188' 0.0 11/23/2015' Notes:General&Safety End Date Annotation 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;9.981.8 - LOCATOR;10,003.2 SEAL ASSY;10,003.7 IPERF;10,116.0-10,131.0 APERF;10,140.0-10,165.0 FISH;10,300.0 PRODUCTION 5.5x4.50)10,031;38.8-10,390.0 • 19` 7 -095 209553 WELL LOG TRANSMITTAL#902875854 To: Alaska Oil and Gas Conservation Comm. December 10, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 in iaour K BENDER RE: Tubing Cut Record: 30-20 Run Date: 10/30/2015 and 10/31/2015 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 30-20 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22750-00 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 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: d---rte �__4e iniTE OF ALASKA KRU 30-20 • AKA OIL AND GAS CONSERVATION COM SION R REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations f.. Fracture Stimulate fi Pull Tubing F Operations Shutdown Performed. Suspend Perforate Ii Other Stimulate P 'l 1...... Alter Casing F Change Approved Program Plug for Redrill f Perforate New Pool I..... Repair Well [Iv Re-enter Susp Well ...... F- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I.v., Exploratory 1 197-045 3.Address: 6.API Number: Stratigraphic E Service r P. 0. Box 100360,Anchorage,Alaska 99510 50-029-22750-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25519 KRU3O-20 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10400 feet Plugs(measured) None true vertical 6836 feet Junk(measured) 10300 Effective Depth measured 10324 feet Packer(measured) 7875 true vertical 6767 feet (true vertical) 4947 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 0 0 SURFACE 6266 7.625 6308 4130 0 0 PRODUCTION 10351 5.5 10390 6627 0 0 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 10116-10131, 10140-10165 True Vertical Depth: 6580-6593, 6601-6624 SCANNED APR 0 8 2016' Tubing(size,grade, MD,and TVD) 3.5, L-80, 10019 MD, 6491 TVD RECEIVED Packers&SSSV(type, MD,and TVD) PACKER-BAKER 5.5" FA-1 PACKER @ 7875 MD and 4947 TVD DEC 0 9 2015 SSSV: None ADCC 12.Stimulation or cement squeeze summary: Intervals treated(measured): none 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 Shut In Subsequent to operation waiting fac hookup 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations f Exploratory IIW Development k Service F".. Stratigraphic F- Copies of Logs and Surveys Run fl 16.Well Status after work: Oil f� Gas P WDSPL F- Printed and Electronic Fracture Stimulation Data I-- GSTOR I WINJ I— WAG F GINJ P 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: 315-502 Contact Andrew Beat @ 265-6341 Email Andrew.T.Beat@conocophillips.lcom Printed Name Andrew Title Sr. Wells Engineer Signature /�+� Phone:265-6341 Date // " 1710/ -D 16 v7L-- 3li7-/iU RBDMS`� L�� 0 91U�5 Form 10-404 Revised 5/2015 A6) `7`y Submit Original Only • i 0 . 1Daily Operations Summary 0 0 30-20 conceit rHips Rig: NABORS 7ES Job: RECOMPLETION Daily Operations Start Date Last 24hr Sum 10/26/2015 MIRU Take on 12.6#mud. RU Kill lines and test to 3500 psi.circulated 300 BBLs of 12.6#mud Monitor well. 10/27/2015 Condition mud to 12.6 ppg and circulate at 2 bpm,lost 65 bbls to formation. Decision made to use 9.9 ppg brine. Haul 12.5 ppg mud to 1 B pad and displace well with 9.9 ppg brine. Shut well in and monitor for pressure increase. Decision made to increase 9.9 ppg to 11.1 ppg brine. Wait on trucks to off load 12.5 ppg mud from pits and to haul 11.1 ppg brine from 1B pad and the MI mud plant. 10/28/2015 Attempt to kill well with 11.1 ppg brine. Monitor well,still flowing. Increase brine weight to 11.4 ppg. Monitor well for flow,well static. Install BPV and N/D Tree. N/U BOP's and install choke and kill lines. 10/29/2015 N/U BOP's. Perform annual choke/kill line test. Test BOP's. Pull Tubing Hanger off seat and attempt to pull seal assembly free. Seal assembly would not pull free,waiting on Halliburton E-line to cut tubing. 10/30/2015 Run in the hole with CCL string shot. Fire string shot at 9967'and POOH. Run in the hole with a RCT cutter and cut Tubing at 9967'. POOH and lay down RCT cutter. Pull several times on completion string,would not pull free. Run in the hole with RCT cutter#2 and cut Tubing at 9969'. POOH and pull several more times on completion string,still would not pull free. Run in the hole with Free Point and magnet. 10/31/2015 Run in the hole with Free Point. Make-up and run in hole with string shot. Make-up RCT cutter and run in the hole to 8,285'and cut Tubing. Circulate and monitor well. POOH.single down 3 1/2" completion string. 11/1/2015 Pull and single down 3 1/2"completion. Make-up BHA#1 /Spear Pack-off Assembly. Run in the hole with BHA#1 on 2 7/8"HT PAC drill pipe to Spear fish at 8,285'. 11/2/2015 Run in the hole with BHA#1 and Spear Fish at 8,285'. Jar Fish free and circulate well clean. Pull out of the hole with Fish and lay it down. Run in the hole with BHA#2/Overshot for Fish at 9,969',(Seal Assembly). 11/3/2015 Run in the hole to 9,969'and tag fish. Pull Fish and Seal Assembly free. Circulate surface to surface and pump dry job. Stuck pipe due to packing off. Cross-Over pin failed and dropped completion string just below blind rams. Conduct Cross-Over investigation. Conduct Safety Stand UP with both crews on Cross-Over Pin Failure and Plan Forward. Repair and inspect Top Drive and equipment. 11/4/2015 Repair Top Drive and inspect Derrick. P/U Over-Shot and engage Fish/2 7/8"DP. POOH with BHA#2/remainder of Completion. L/D DP and service all breaks. Run 25 stands of DP in the hole and come out laying down to service all breaks. 11/5/2015 L/D all 2 7/8"DP and service tool joint connections. P/U BHA#4/Mill&Casing Scraper and RIH on 2 7/8"DP to 2000'. P/U Storm Packer and set at 100'.Test BOP's. 11/6/2015 Test BOP's. Release Storm packer. Single in the hole with 2 7/8"DP to 9,450'. 11/7/2015 RIH and Tag SBE at 10,009'. Spot 25 bbl Brine pill. POOH and lay down BHA#4. RIH with test Packer. 11/8/2015 RIH with Test Packer. Test Casing to locate hole, Casing held pressure at 7,917'. POOH and lay down Test Packer. RIH with Lower Completion. 11/9/2015 RIH with Lower Completion on 2 7/8"DP.Attempted to engage seal assembly into SBE.Got 3 ft of seal in and stacked weight. Unable to work any deeper. POOH with lower completion from 10,000'to 2,143'. Lay down Baker Premier Packer and running tool. Continue POOH with lower completion from 2,122'to 1,425'. 11/10/2015 Continue to POOH with Lower Completion standing back 8rd string. RU 2 3/8"handling equipment. Picked up mule shoe and 10 jts of 2 3/8 EUE 8rd tbg for clean out run. RIH with PAC drillpipe.Tagged fill @ 9998 ft KB(2 ft inside SBE top).PU cleared tbg of plug. Broke circulation at 3 BPM @ 2400 psi. 10034 ft RKB. Kick rate up to 4.5 BPM @ 3600 psi.Circulated 1.5 hole volumes. Mix and pump 30 bbls of CI treated 11.5 ppg brine. Flow check 15 min.Rig maintenance.Serviced top drive.POOH with clean out assembly from 10,021'to muleshoe. 11/11/2015 Lay down muleshoe.Change out handling equipment and clean rig floor. Pick up seal assembly and X-nipple with PXX plug and prong installed. RIH with lower completion. Replaced joints#7,#25,and#64-66. Fill up pipe every 5 stands.Pick up packer,setting tool,and bumper sub. Continue RIH with drill pipe from 2,170 ft to 7,370 ft filling every 5 stands.Service top drive.Continue RIH with drill pipe from 7,370 ft to 9,984 ft filling every 5 stands. Engage seals at 9,999 ft but could not go past 10,000 ft.Set 20k down but could not go down. Decision made to POOH. POOH wet with drill pipe racking back from 10,000 ft to 6,250 ft. 11/12/2015 Continue POOH wet with drill pipe racking back.Lay down packer,setting tool,and bumper sub. POOH wet with tubing racking back.Seals look good. Service and inspect top drive. RIH with lower completion with DS nipple with RHC plug profile. Engage seals and fully locate. No issues. Space out 2 ft and pressure up drill pipe to 2,500 psi for 10 minutes and increase to 3,000 psi for 5 minutes to set packer.Good set. Pressure test IA to 1,500 psi for 10 minutes. Release setting tool.Swap well over to seawater. Pump a 30 bbl viscous pill ahead of seawater at 3 BPM. 11/13/2015 Continue displacing 11.5 ppg brine with seawater. Pumped 243 bbls of seawater.Well still out of balance. Pump 1.5 hole volumes at 4.5 BPM. Well static.Slip and cut drill line. Lay down 2 7/8 PAC drill pipe. RIH with drill pipe in the derrick and lay down.Service top drive& inspect. Finish laying down 2 7/8 PAC drill pipe. Break out and lay down bumper sub and packer setting tool.Clean and clear rig floor. RIH with 23 stands of old 3 1/2 tubing in derrick. Lay down old 3 1/2 tubing. Lay down 2 7/8 equipment. Pull wear ring.Wash BOP stack. 11/14/2015 RIH with Upper Completion.Latched up anchor assembly. Pulled 20K over to validate latch. Dropped ball&rod. PT IA to 1000 psi for 10 mins. Good test.Space out tbg and install hanger. Pumped 162 BBL's of CI sea water. Prepared cellar and wellhead. Land hanger and RILDS.PT tubing and IA. Bleed tubing to shear SOV.Set BPV. Pump down IA to test BPV to 1,000 psi for 10 mins. Lay down 3RD party tools.Clean rig. Remove Koomey lines.Offload fluid from pits. Nipple down BOPE and rack back. 11/15/2015 Nu Tree.And test 250/5000 psi. Freeze protected well with 45 BBL's of diesel. Let well equalize.Set BPV.secured well. Rig Released @ 09:00 hrs. Page 1/1 Report Printed: 11/30/2015 1.-, , KUP IrD 30-20 COnocoPhilhlp5 1 Well Attribu Max Angle MD TO • Alaska,Inc . Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) CanocoPhilOps..�> 500292275000 KUPARUK RIVER UNIT PROD 63.25 6,674.84 10,400.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 30-20,12/9/20156.05t335M SSSV:NONE 140 12/26/2013 Last WO: 41.00 3/29/1997 Vertical schematic.(actua) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,142.0 9/25/2014 Rev Reason:WORKOVER lehallf 12/2/2015 HANGER;37.0 Milt Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED uuuw:uuu nomo.ai ;\*i .--=.i cu+u+.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread s .i SURFACE 7518 6.875 41.6 6,308.0 4,130.3 29.70 L-80 BTC 11I 4. I Casing Description SURFACE (in) ID(in) lop(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len p...Grade Top Thread -■■■ ,ll - PRODUCTION 51/2 4.950 38.8 10,390.0 6,826.9 15.50 L-80 LTC-MOD 5.5x4.5Qa 10,031 ' F Tubing Strings 111 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection I g TUBING UPPER 31/2 2.992 37.0 7,876.2 4,947.7 9.30 L-80 EUE 8rd CONDUCTOR;42.0-121.0 1 RWO 2015 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) nem Des Corn (in) 37.0 37.0 0.00 HANGER Tbg hanger 3.000 7,858.5 4,938.0 56.75 LOCATOR Locator sub 3.010 7,858.9 4,938.2 56.76 SEAL ASSY Baker 80/40 Seal assembly 10 ft 3.010 7,860.9 4,939.3 56.80 PBR Baker 80/40 PBR 4.010 GAS LIFT;3,153.4 7,874.5 4,946.7 57.03 ANCHOR Baker KBH-22 Anchor Seal Assembly 3.000 SEAL ASSY Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING RWO 2015 31/2 2.992 7,874.7 10,019.0 6,491.7 9.30 L-80 EUE 8rd (Lower Packer) GAS LIFT,5.479.8 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Mel(°) Item Des Com (in) 7,874.7 4,946.8 57.03 PACKER Baker 5.5"FA-1 Packer 3.620 r 7,878.5 4,948.9 57.10 XOVER 3.5 NU X 3.5 L-80 rd Xover 2.980 9,981.8 6,457.8 24.47 NIPPLE 3.5 X 2.812 DS nipple 2.812 10,003.2 6,477.3 24.61 LOCATOR Locator sub 3.000 ^ I 10,003.7 6,477.8 24.62 SEAL ASSY Baker 80/40 seal assembly 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;411-8,308.0-. l Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(In) 10.300.0 6.745.6 25.39 FIST PERF GUN PART 8"NOSE STRIP OF PERF GUN 9/25/2005 LOST 9/25/2005 GAS LIFT;8,924.1 Perforations&Slots Shot I1. Dens Top(ND) Btm(ND) (shots/ lop(ftKB) Stet(ft/(13) (ftKB) (ftKB) Zone Date ft) Type Com 10,116.0 10,131.0 6,579.6 6,593.1 A-3,30-20 4/12/1997 4.0 IPERF 180 deg ph;oriented(+/ -)f/Iowside;2-1/8"EJ 10,140.0 10,165.0 6,601.3 6,623.8 A-2,30-20 9/25/2005 6.0 APERF 2-1/8"Spiral EJ,45 deg. phase I Mandrel Inserts LOCATOR;7,858.5 St _ at! SEAL ASSY;7,858.9 - on Top(ND) Valve Latch Port Size IRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sero Type Type (in) (psi) Run Date Com 1 3,153.4 2,491.0 Camco KBG 1 GAS LIFT DMY SDK- 0.000 0.0 11/14/2015 1A ANCHOR SEAL ASSY;7,874.5 - 2 5,479.8 3,699.5 Camco KBG 1 GAS LIFT DMY SDK- 0.000 0.0 11/14/2015 PACKER;7,874.7 1A P 3 6,924.1 4,432.8 Camco KBG 1 GAS LIFT DMY SDK 2 0.000 0.0 11/14/2015 XOVER;7,878.5 -9 4 7,800.1 4,905.6 Camco KBG 1 GAS LIFT SOV DCK- 0.000 0.0 11/14/2015 IS 3 SOV Notes:General&Safety End Date Annotation NIPPLE;9,961.8 _.1 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;10,003.2 SEAL ASSY;10,003.7 IPERF;10,118.0-10,131.0 APERF;10,140.010,185.0 FISH;10,300.0 PRODUCTION 5.5x4.5010,031; ° 38.8-10,390.0 • Dri' Operations Summary (with Timelog Depths) &Wells Mw� 30-20 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/26/2015 10/26/2015 3.00 MIRU MOVE MOB P De-Mob off 30-06. 00:00 03:00 10/26/2015 10/26/2015 4.00 MIRU MOVE MOB P Move matting to 30-20 and set 03:00 07:00 herculite at well head and pits. Hang Tree in the Cellar. 10/26/2015 10/26/2015 1.50 MIRU MOVE MOB P Spot Rig over Well. 07:00 08:30 10/26/2015 10/26/2015 1.00 MIRU MOVE MOB P Spot Rig Pits. 08:30 09:30 10/26/2015 10/26/2015 3.00 MIRU MOVE RURD P Berm Rig and Pits. Spot Cuttings Bin. 09:30 12:30 Hook up interconnect from the Pits. Install hand rails. Prep Pits to take on 12.7 lb/gal Mud. 10/26/2015 10/26/2015 3.50 MIRU WELCTL RURD P Accept Rig at 12:30 hrs. Begin taking 12:30 16:00 on fluid in Pits. Install Secondary Annulus Valve. Rig up Circulating Manifold. Begin rigging up floor. Rig up Hardline,Choke Skid,and Kill Tank. 10/26/2015 10/26/2015 2.00 MIRU WELCTL MPSP P Pick-up Lubricator. Pressure test 16:00 18:00 same to 3,000 psi. Pull BPV. Record pressures as follows: Tbg=900 psi, IA= 1,050 psi,OA=300 psi. Lay down BPV and Lubricator. (SIMOPS continue to off-load 12.7 lb/gal Mud in Pits). 10/26/2015 10/26/2015 1.50 MIRU WELCTL RURD P RU Kill lines. 18:00 19:30 10/26/2015 10/26/2015 3.75 MIRU WELCTL KLWL P Circulated 300 bbls of 12.6#mud 19:30 23:15 down tubing out IA holding back pressure ICP= 980 Psi FCP=850 psi. Loss rate= 100 BPH @ circulation pressure. 10/26/2015 10/27/2015 0.75 MIRU WELCTL OWFF P Flow check Tbg started small flow. 23:15 00:00 continue to monitor. 10/27/2015 10/27/2015 2.50 MIRU WELCTL OWFF P Continue to Observed well.small flow 00:00 02:30 up tubing.SIW Check pressure.Tbg built up to 40 psi. IA on vacuuum.well appers to be out of balance.let well stabilize.Still small flow.) 10/27/2015 10/27/2015 1.00 MIRU WELCTL COND T Condition mud back to 12.6# 02:30 03:30 10/27/2015 10/27/2015 1.50 MIRU WELCTL CIRC T Circulate @ 2 BPM @ 660 psi. a 03:30 05:00 tubing volume=88 BBL's. 1.5 BBIs to get circulation.Lost 65.2 BBIs to formation.Shut in tubing. built up to 40 psi in 15 min's 10/27/2015 10/27/2015 1.00 MIRU WELCTL WAIT T Discuss options with town Engr. 05:00 06:00 10/27/2015 10/27/2015 6.50 MIRU WELCTL WAIT T Decision made to cut-back to 9.9 06:00 12:30 Ib.gal Brine. Begin to haul 12.5 lb/gal Mud from Pits to 1-B storage. Call out clean Brine Vac Trucks an 1 Returns Vac Truck from Peak(ASRC...no Vac. All on other jobs). Haul clean Brine from MI Plant. Begin to clean Rig Pits once the 12.5 lb/gal Mud has been sucked off. Page 1/14 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) &Wel s 30-20 ConocoPhiiilips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/27/2015 10/27/2015 1.75 MIRU WELCTL COND T Peak Vac Truck arrive on Location. 12:30 14:15 Stage same. Mix Deep Clean Pill. Mix Hi-is Sweep. 10/27/2015 10/27/2015 0.25 MIRU WELCTL SFTY T PJSM. Discuss the hazards 14:15 14:30 associated with chemicals, pressure, and fluid transfers. Review pumping schedules and flow paths. 10/27/2015 10/27/2015 3.00 MIRU WELCTL CIRC T Shut in pressures 0 psi. Begin 14:30 17:30 pumping a 50.8 bbl Deep Clean Pill at 3.0 bpm/1,070 psi..Begin pumping a 50.0 bbls Hi-Vis Sweep at 2.5 bpm 1,150 psi. (Note:got returns after 60 bbl pumped. Weight= 12.5 lb/gal). Continue to displace 12.5 lb/gal Mud with 9.9 lb/gal Brine at 1.7 bpm/1,185 psi. Final rate=1.7 bpm/525 psi. Total Brine pumped 210 bbls. Returns =9.9 lb/gal. Total 12.5 lb/gal Mud lost today= 187 bbls. Cum Mud lost to date=367 bbls... 10/27/2015 10/27/2015 1.00 MIRU WELCTL OWFF T Shut in well and monitor pressures for 17:30 18:30 1 hour. ISITP 400 psi and ISICP 400 psi. Pressure increase in 30 minutes SITP=400-480 psi,SICP=400-480 psi. Pressure increase in 1 hour SITP =400-520 psi,SICP=400-520 psi. Pressure stabilized at 513 psi. 10/27/2015 10/28/2015 5.50 MIRU WELCTL WAIT T Decision made to wait up from 9.9 ppg 18:30 00:00 brine to 11.1 brine(kill weight fluid). Off load 720 bbls of 12.5 ppg mud from pits and take it to 1B pad. Haul 290 bbls of 11.1 ppg brine from 1B pad and another 290 bbls of 11.1 ppg brine from the MI mud plant. Peak trucks hauling brine from 1B pad and mud plant.(All ASRC trucks busy or no drivers.) 10/28/2015 10/28/2015 3.25 MIRU WELCTL WAIT T Clean pits while waiting for brine 00:00 03:15 trucks from 1 B pad and MI mud plant. 10/28/2015 10/28/2015 0.25 MIRU WELCTL SFTY T PJSM for well kill. 03:15 03:30 10/28/2015 10/28/2015 2.50 MIRU WELCTL KLWL T Begin well kill with 11.1 ppg brine. 03:30 06:00 Open choke and bled gas cap off. Well still flowing about a 4 inch stream. Opened choke and started pumping at 2 bpm slow pump rate. Continue circulating well until clean 111 lb/gal recovered back to Pits. 10/28/2015 10/28/2015 1.50 MIRU WELCTL OWFF T Monitor Well. Tubing"0"psi, no-flow. 06:00 07:30 IA"0"psi flowing 5 gal x 15 minutes. Well continues flowing from the IA at same rate. Shut in IA...Well started to flow from the tubing at the same rate. Discuss plan forward with Anchorage Engineer. Decision made to bump brine weight up to 11.4 lb/gal. 10/28/2015 10/28/2015 3.75 MIRU WELCTL COND T Weight up and condition the 11.1 07:30 11:15 lb/gal Brine in the Pits to 11.4 lb/gal. Page 2/14 Report Printed: 3/15/2016 ! • C>Ir�ll Operations Summary (with Timelog Depths) &Wells 30-20 Conoccehillips g, Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/28/2015 10/28/2015 0.25 MIRU WELCTL SFTY T PJSM. 11:15 11:30 10/28/2015 10/28/2015 2.50 MIRU WELCTL KLWL T Circulate and kill Well with 11.5 lb/gal 11:30 14:00 Brine at 2.0 bpm/470 psi. Final returns=11.5 lb/gal. End Pump. ISIP = 100 psi and dropping. 10/28/2015 10/28/2015 4.00 MIRU WELCTL OWFF T Shut in well x 10 minutes. Open Well. 14:00 18:00 Tbg=80 psi. IA=52 psi. Bleed IA down to"0"psi. Tubing went on a vacuum. Continue to monitor a "pencil"stream from the IA getting gradually weaker. Shut in the IA x 15 minutes and record SIP(on a 300 psi gauge). Recorded"0"psi after the 15 minute shut-in. Open Well observe a slight flow then quite. Monitor well with no flow from the tubing or the IA x 30 minutes. 10/28/2015 10/28/2015 0.50 MIRU WHDBOP MPSP P Install IS-A BPV. Take pictures of 18:00 18:30 Tree orientation. 10/28/2015 10/28/2015 3.00 MIRU WHDBOP NUND P N/D Tree. 18:30 21:30 10/28/2015 10/29/2015 2.50 MIRU WHDBOP NUND P Install DSA, N/U BOP stack and 21:30 00:00 install choke/kill lines. 10/29/2015 10/29/2015 1.50 MIRU WHDBOP NUND P Complete BOP N/U and installing 00:00 01:30 choke and kill lines. 10/29/2015 10/29/2015 2.00 MIRU WHDBOP BOPE P Perform annual Choke and Kill line 01:30 03:30 test. (Test to 5000 psi). Good. 10/29/2015 10/29/2015 9.00 MIRU WHDBOP BOPE P Perform the initial BOPE test as per 03:30 12:30 ConocoPhillips/AOGCC requirements at 250/3,500 psi with a 3 1/2"and a 2 7/8"Test Joint. Record tests on the chart. Test Gas Alarms. Perform the Koomey drawdown test. The State's right to witness the test was waived by AOGCC Field Inspector,C.Sheve. 3 Manual valves failed on the initial test:CMV#11,Manual Choke valve and Manual Kill valve. All 3 valves were greased,retested and past. 10/29/2015 10/29/2015 1.00 MIRU WHDBOP RURD P Blow down lines. Rig down test 12:30 13:30 equipment. 10/29/2015 10/29/2015 2.75 MIRU WHDBOP RURD T Pull the Blanking Plug. Having 13:30 16:15 troubles pulling the BPV...bent pulling tool. Wash Stack. Suck out stack. continue to work to latch and pull BPV. Finally got it...! 10/29/2015 10/29/2015 2.00 COMPZN RPCOMP PULL X Make-up Landing Joint. BOLDS. Pull 16:15 18:15 Tubing Hanger off seat.Attempt to pull seal assembly free. Cycle at 80%= 142K(includes Blocks). Continue to work. 10/29/2015 10/29/2015 1.00 COMPZN RPCOMP PULL X Cleared to pull 90%. Attempt to pull 18:15 19:15 seal assembly free. Cycle at 90%= 159K(includes Blocks). Continue to work. Page 3/14 Report Printed: 3/15/2016 • S Wiling Operations Summary (with Timelog Depths) =___y &Wens 30-20 ConocoFhili[ps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 10/29/2015 10/30/2015 4.75 COMPZN RPCOMP WAIT X Pull 159K, slacked off to 150K and 19:15 00:00 set brake holding pipe in tension. Cycle every 2 hours while waiting on Halliburton E-line to cut Tubing. E-line crew is timed out and can't be called out before 01:00 hours 10/30/2015. 10/30/2015 10/30/2015 3.00 COMPZN RPCOMP WAIT X Wait on Halliburton E-line to cut 00:00 03:00 Tubing. (Called Halliburton 01:00 hours) 10/30/2015 10/30/2015 3.00 COMPZN RPCOMP ELNE X R/U Halliburton E-line to cut Tubing. 03:00 06:00 10/30/2015 10/30/2015 2.75 COMPZN RPCOMP ELNE X Run in hole with CCL/String Shot. Tie 06:00 08:45 -into the"D"Nipple at 10,002-ft (completion tally). Make a(+)31-ft correction. Log up and record a jewelrypass across GLM#1 and GLM #2. Drop back down and double check the"D"Nipple...no further correction needed. Position the center of the 5-ft String shot at 9,967-ft (String Shot 2.5-ft above the target cut depth+3-ft CCL to the top of the String Shot=Odometer at 9,961.5- ft).Fire String Shot. Good. Pull out of the hole. 10/30/2015 10/30/2015 3.25 COMPZN RPCOMP ELNE X Make-up the Radial Cutting Torch 08:45 12:00 Cutter. Run in hole. Log tie-in pass and correlate to GLM#2. Make a(+) 34-ft correction. Drop back down to the"D"Nipple. No further correction. Position RCT Cutter to cut at 9,9967- ft.(target cut at 9,967-ft+10.5-ft to the CCL...Odomenter at 9,956.5-ft). Set Anchor Arms. Fire RTC. Looked good in the Unit...however,no"tubing jump"on the rig floor. Had to jar x 3 to get the Anchor Arms to release. Pull out of the hole. 10/30/2015 10/30/2015 1.00 COMPZN RPCOMP ELNE X Lay down RCT tool string. Detonated 12:00 13:00 cutter look normal as expected. Set back E-Line equipment. Pull on completion string. Pulled several times up to 159K...no-joy. Tubing not free. Notify Anchorage Engineer. 10/30/2015 10/30/2015 5.00 COMPZN RPCOMP ELNE X Set E-Line back on Well.(set tubing in 13:00 18:00 the slips with 30K overpull). Make-up RCT Cutter#2. Run in the hole. Log tie-in pass and correlate to GLM#2. Make a(+)27-ft correction. Drop back down to the"D"nipple. No further correction needed. Position the Cutter at 9,969-ft. Set Arms. Fire. Saw indication on the panel that the cutter fired. However,no line jump or tubing movement. Pull out of the hole. discuss plan forward with Anchorage Engineer. Order out free-point tool and additional cutters. Page 4/14 Report Printed: 3/15/2016 • • Operations Summary (with Timelog Depths) =! &Wells 30-20 ConocoPhitups At kn Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKE) 10/30/2015 10/30/2015 2.00 COMPZN RPCOMP ELNE X R/D E-line. Pull several more times 18:00 20:00 on completion string...No GO. Wait on Halliburton Free Point tools and crew coming out of Deadhorse. 10/30/2015 10/31/2015 4.00 COMPZN RPCOMP ELNE X Rig up Halliburton E-line. Run in the 20:00 00:00 hole with Free Point with magnet to 9969'. Magnetize Tubing and establish baseline reading for Free Point. 10/31/2015 10/31/2015 2.50 COMPZN RPCOMP ELNE X Run in the hole with Free Point and 00:00 02:30 magnet to 9969'and establish baseline readings,POOH. Reciprocate completion string from 75K neutral weight to 159K maximum pull. 10/31/2015 10/31/2015 4.00 COMPZN RPCOMP ELNE X Run back in the hole with Free Point 02:30 06:30 tool without magnet and identify free point. Could see cuts at 9967'and 9969'. Pull out of the hole and saw no separation in readings from baseline until—8,325-ft. Continue finish POOH. 10/31/2015 10/31/2015 1.00 COMPZN RPCOMP ELNE X Lay down Free point tool. Down load 06:30 07:30 log data and discuss field interpretation with logging engineer. E -mail log to Anchorage ConocoPhillips and Halliburton Engineers. Discus findings with Anchorage Engineer. Agree that the top of the"free point"is at 8,300-ft. Plan for a 3 1/2"tubing cut at 8,285-ft,middle of the first full joint above the free point. 10/31/2015 10/31/2015 5.25 COMPZN RPCOMP ELNE X Make-up and run in the hole with 5-ft 07:30 12:45 String Shot(160 gr det-cord)to 8,400- ft. Log tie-in pass up to 7,700-ft at 50 ft/min. Make a(+)43-ft correction to GLM#4. Drop back down to 8,403-ft. Log up and place the String Shot across the target cut depth of 8,285-ft. (Odometer=8,279.5',top of the String Shot 8,282.5',bottom of the String Shot at 8,287.5'). Fire. Good. Pull out of the hole. Lay down tools. 10/31/2015 10/31/2015 1.00 COMPZN RPCOMP ELNE X Make-up RCT Cutter and run in hole. 12:45 13:45 Set down at 8,275-ft. Attempted to pass by several times(assume debris from String Shot). Pull up hole to 8,230-ft. Bring pump on line at 1.0 bpm/160 psi x 5 bbls. End pump. Drop back down to 8,350-ft. Log a tie- in pass up to 7,780-ft. Tie-in to GLM #4. Make a(+)30-ft correction. Drop back down(debris gone)to 8,350-ft Log Cutter into place at 8,285-ft. (Odometer=8,275.7',CCL to Cutter 9.3',Cutter at 8,285'). Set Anchors. Fire Cutter. Good...observe Tubing jump on the rig floor and a 6-ft collar shift down hole. Anchor released. Pull out of the hole. Page 5/14 Report Printed: 3/15/2016 • • Drilling Operations Summary (with Timelog Depths) } &Wells 30-20 C OnocoPhill ps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 10/31/2015 10/31/2015 3.00 COMPZN RPCOMP ELNE X Finish out of the hole. Lay down tools. 13:45 16:45 Set back E-Line. Pull on tubing...free and L/D hanger. Rig down and release E-Line. (SIMOPS: Begin to circulate Well,call out Weatherford). 10/31/2015 10/31/2015 2.25 COMPZN RPCOMP CIRC P Continue to circulate the well at 3.8 16:45 19:00 bpm/1,020 psi from the cut depth (8,285-ft). Pump a 30 bbl Hi-Vis sweep. Chase back to surface at 4.5 bpm/1,225 psi. Brine Lost to Formation while circulating=70 bbls. 10/31/2015 11/1/2015 5.00 COMPZN RPCOMP OWFF P Observe well for flow in 30 minute 19:00 00:00 increments: 30 minutes= 1.5 bbls back. 30 minutes=1 bbl back. 30 minutes=.3 bbls back. 30 minutes= 1.8 bbls back. 30 minutes= 1.5bbls back. 30 minutes=.9 bbls back. 30 minutes=.8 bbl.back. 30 minutes =.7 bbls back. 30 minutes.2 bbls back. 30 minutes.1 bbl back. Total bbls back 8.8. 11/1/2015 11/1/2015 2.00 COMPZN RPCOMP PULL P POOH from 8,285'to 8,000',rotate 8,285.0 6,133.0 00:00 02:00 completion string, PUW=75K,SOW 58K. Pipe rotated at 2600 ft lbs.of torque, (3 1/2"9.3#L-80 EUE 8rd make up torque=2900 ft lbs).Pull 3 1/2" completion string. Stand back a total of 23 stands in the derrick to make a belly rack for the 2 7/8"HT PAC drill pipe. 11/1/2015 11/1/2015 9.00 COMPZN RPCOMP PULL P Pull and single down 3 1/2"completion 6,133.0 0.0 02:00 11:00 string. At Jt#253 starting seeing corrosion pits,corroded couplings, and small/big holes. Continue to single down to the RCT cut(textbook perfect cut). Clear and clean floor (SIMOPS:prep for fishing ops. Recovered Completion to date: Nipple Assembly,256 Jts x 3 1/2" Tubing,6 Jts x 2 7/8"Tubing,Cut-off Stub OAL=15.02-ft. 11/1/2015 11/1/2015 0.25 COMPZN RPCOMP SFTY X PJSM. Discuss making up the BHA 0.0 0.0 11:00 11:15 and the hazards associated with same. 11/1/2015 11/1/2015 1.00 COMPZN RPCOMP BHAH X Make-up BHA#1 as follows: Spear 0.0 215.0 11:15 12:15 Pack-Off Assembly,2 11/16"ITCO Spear,Spear Ext,Stop Sub,XO Sub, Bumper Sub,Oil Jar,3 3/4"Drill Collars, Int Jar,XO Sub,XO Sub. 11/1/2015 11/2/2015 11.75 COMPZN RPCOMP PULD P Single in BHA#1 with 2 7/8"HT PAC 215.0 7,650.0 12:15 00:00 Drill Pipe from the Pipe Shed. (make- up torque=4,800 ft/lbs. 215'to 7,650'. Page 6/14 Report Printed: 3/15/2016 • Operations Summary (with Timelog Depths) { &Wens 30-20 ConocoPhitftps ,4.tcasks Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/2/2015 11/2/2015 2.25 COMPZN RPCOMP PULD P Continue to single in BHA#1 with 2 7,650.0 8,285.0 00:00 02:15 7/8"HT PAC Drill Pipe from the Pipe Shed. (make-up torque=4,800 ft/lbs, tag fish at 8,285'. 11/2/2015 11/2/2015 0.25 COMPZN RPCOMP FISH X Tag fish at 8,285', Up Weight= 123K, 8,285.0 8,285.0 02:15 02:30 Down Weight=45K, Neutral Weight 108K. Attempt to circulate,NO GO. 11/2/2015 11/2/2015 0.75 COMPZN RPCOMP JAR X Pull up to 150K and set Jars off. Fish 8,285.0 8,285.0 02:30 03:15 would not pull free. Pull up to 160K and set Jars off,still would not pull free. Pull up to 175K,set Jars off and pull up to 210K. Fish came free at 210K,coming down to 150K. Picked back up with 150K to 135K drag to 8,260'. 11/2/2015 11/2/2015 2.25 COMPZN RPCOMP CIRC X Circulate until well is clean as 8,285.0 8,260.0 03:15 05:30 possible. Start circulating at1 bpm. Step circulating rate up to 2 bpm/1,175 psi while monitoring fluid loss. Returns had several light spots and even a little diesel once in a while. Finial results...11.5 lb/gal in and out. Very little solids recovery,if any. 11/2/2015 11/2/2015 0.50 COMPZN RPCOMP OWFF X Monitor Well x 30 minutes. Well 8,260.0 8,260.0 05:30 06:00 remains static. 11/2/2015 11/2/2015 6.25 COMPZN RPCOMP TRIP X Trip out with BHA#1,standing back 8,260.0 215.0 06:00 12:15 the 2 7/8"PAC Drill Pipe in the Derrick (install nubbins). Up weight=135K (25K gain in string weight...fish on...I) 11/2/2015 11/2/2015 1.00 COMPZN RPCOMP BHAH X Lay down BHA#1. Release Spear 215.0 0.0 12:15 13:15 from Fish. 11/2/2015 11/2/2015 3.75 COMPZN RPCOMP PULL X Continue to single down the remaining 1,684.0 0.0 13:15 17:00 completion to the next fish. Recovered the partial RCT cut at 9,967-ft and a complete RCT cut at 9,969-ft. New fish top 9,969-ft. Clean and clean floor. (Note: Most of the tubing from 8,285-ft to 9,969 have minor to very large scale build up. Also many joint had hole in them). Notified the Corrosion folks to come back in the morning to take pictures and samples. 11/2/2015 11/2/2015 1.25 COMPZN RPCOMP BHAH X Make-up BHA#2 as follows:Cut lip 0.0 210.0 17:00 18:15 guide,4 11/16"Overshot bowl,4 11/16"Extension, Drive sub,3 3/4" Bowen LBS,3 3/4"Bowen oil jar,6 ea 3 3/4"DC,3 3/4"Bowen INT jar,XO sub,XO sub. 11/2/2015 11/3/2015 5.75 COMPZN RPCOMP TRIP X Run BHA#1 on 2 7/8"DP racked in 210.0 8,311.0 18:15 00:00 the derrick to 8,311'. 11/3/2015 11/3/2015 3.25 COMPZN RPCOMP PULD X Single in the hole with 2 7/8"DP from 8,311.0 9,969.0 00:00 03:15 the pipe shed,from 8,311'to 9,969'. Page 7/14 Report Printed: 3/15/2016 Mining Operations Summary (with Timelog Depths) :,r aWeils 30-20 C.CIMOcoPhi€tips Rig: NABORS 7ES Job: RECOMPLETION Time Log Star;Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/3/2015 11/3/2015 0.25 COMPZN RPCOMP FISH X Tag Fish at 9,969', PUW= 142K SOW 9,969.0 9,972.0 03:15 03:30 =67K. Break circulation and establish pump pressure. Pump 1 bpm at 365 psi. When on top of Fish at 9969' pump pressure increased to 448 psi. Slack off to 60K and swallowed 3'of Fish. 11/3/2015 11/3/2015 0.50 COMPZN RPCOMP JAR X Pull up to 170K and set Jars off, 9,972.0 9,941.0 03:30 04:00 weight dropped back to 142K. Pull up to 256K and set Jars off,weight dropped back to 100K,Seal Assembly came free. Pull Seals from Seal Bore, 145K drag. 11/3/2015 11/3/2015 3.00 COMPZN RPCOMP CIRC X Circulate Surface to Surface 2 times 9,941.0 9,941.0 04:00 07:00 hole volume @ 2 BPM @ 1205 psi. clean well and even brine weight out, 11.5 ppg. 11/3/2015 11/3/2015 0.50 COMPZN RPCOMP CIRC X Pump 10 bbl 11.9 ppg dry job, Lay 9,941.0 9,941.0 07:00 07:30 down 1 joint of DP and blow down the Top Drive 11/3/2015 11/3/2015 2.50 COMPZN RPCOMP JAR XT Picked-up to drag weight of 145K, 9,941.0 9,941.0 07:30 10:00 pipe would not pull free at drag weight. Pull up to 250K and came back to neutral weight of 108K. Pull up to 250K and still no movement. Attempted to circulate and pressured up on pipe,no circulation.Slack off to 50K down weight and came back up to 250K and set Jars off. Repeated setting Jars off and gained 6'. Consulted with completion engineer and a decision was made to reciprocate pipe while rotating and attempt to circulate. Reciprocate pipe 16' rotating pipe with 6.5 Torque,at 3200 psi, No Go. Called the engineer back and a decision was made to reverse circulate and attempt to circulate. Stage the pump up to 1 bpm 780 psi and pumped brine into the formation. Shut down pumps and called the engineer. He wanted to verify what the maximum torque that could be put on the drill pipe. Consulted with Baker Rep and 8600 ft lbs of torque is maximum. He said the Baker tools had 3 1/2"IF connections and were only good to 4200 ft lbs of torque. The Baker Rep consulted with his supervisor and a decision was made to pull 10%more to maximum pull weight. The torque limit was set at 10.0 and he pulled 275K up weight. The completion string parted at the 2 7/8"HT PAC XO on the Top Drive and fell into the hole,stopping below the Blind rams. Page 8/14 Report Printed: 3/15/2016 • Operations Summary (with Timelog Depths) &W ens 30-20 CotIocoPhitkps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/3/2015 11/3/2015 7.50 COMPZN RPCOMP OTHR XT CPAI Superintendent,CPAI Field 9,941.0 9,941.0 10:00 17:30 Supervisor,CPAI Engineer,and CPAI Safety were notified. Nabors Superintendent,Toolpushers,CPAI Drilling Supervisor and CPAI Field Supervisor went to the rig and conducted a preliminary Cross-Over Pin Failure investigation. From the investigation a Plan Forward was developed.A Safety Stand UP will be conducted with crews discussing the Cross-Over Pin failure and the plan forward. 11/3/2015 11/3/2015 0.50 COMPZN RPCOMP SFTY XT CPAI Drilling Supervisor,CPAI 9,941.0 9,941.0 17:30 18:00 DrillingField Supervisor.CPAI Safety, Nabors Superintendent,and Toolpushers conducted a Safety Stand UP with both crews. The meeting entailed a review and discussion of the Cross-Over Pin Failure and the Plan Forward. 11/3/2015 11/4/2015 6.00 COMPZN RPCOMP RGRP XT Repair Top Drive lube pump,and 9,941.0 18:00 00:00 handler pump. TUBOSCOPE inspection of the Gripper block, Link Tilt cylinders,Bails and Derrick. Inspect drilling line before picking up pipe. 11/4/2015 11/4/2015 3.00 COMPZN RPCOMP OTHR T Continue top drive repairs and 0.0 0.0 00:00 03:00 inspection.Derrick inspection 11/4/2015 11/4/2015 0.50 COMPZN RPCOMP BHAH T Made up#3 0.0 0.0 03:00 03:30 11/4/2015 11/4/2015 1.50 COMPZN RPCOMP FISH T Engage fish Pick up to 250K weight 26.0 9,909.0 03:30 05:00 dropped off to 145K Down wt=60K. pulled top jt of 2 7/8 PAC drill pipe. and laid it down. 11/4/2015 11/4/2015 0.50 COMPZN RPCOMP RURD P RU Weatherford handling equipment. 9,909.0 9,909.0 05:00 05:30 11/4/2015 11/4/2015 5.50 COMPZN RPCOMP TRIP XT POOH with BHA#2 standing back 9,909.0 5,000.0 05:30 11:00 drill pipe. 11/4/2015 11/4/2015 5.50 COMPZN RPCOMP PULD XT Continue to pooh laying down drill 5,000.0 2,123.0 11:00 16:30 pipe to service all breaks. 11/4/2015 11/4/2015 2.50 COMPZN RPCOMP BHAH XT Lay down BHA#2 and GLM 21,230.0 0.0 16:30 19:00 Completion. 11/4/2015 11/4/2015 0.50 COMPZN WELLPR SVRG P Service Top Drive. 0.0 0.0 19:00 19:30 11/4/2015 11/4/2015 2.50 COMPZN WELLPR TRIP XT Run 25 stands of 2 7/8"DP in the hole 0.0 2,325.0 19:30 22:00 11/4/2015 11/5/2015 2.00 COMPZN WELLPR PULD X Lay down 2 7/8 P{AC drill pipe 2,450.0 1,050.0 22:00 00:00 11/5/2015 11/5/2015 2.00 COMPZN WELLPR PULD XT Lay down 2 7/8"DP to service 1,050.0 0.0 00:00 02:00 breaks. 11/5/2015 11/5/2015 2.00 COMPZN WELLPR TRIP XT RIH with last 25 stands of 2 7/8"PAC 0.0 2,450.0 02:00 04:00 DP. 11/5/2015 11/5/2015 3.50 COMPZN WELLPR PULD XT Lay down remaining PAC pipe to 2,450.0+ 0.0 04:00 07:30 service breaks.kick out a total of 6 jts. Two that were plug with scale and four that took 8600 ft lbs to break out. 11/5/2015 11/5/2015 0.50 COMPZN WELLPR SVRG X Service and inspect top drive. 0.0 07:30 08:00 Page 9/14 Report Printed: 3/15/2016 0 • Miffing Operations Summary (with Timelog Depths) ,M &Well 30-20 comcoPhitiips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/5/2015 11/5/2015 1.00 COMPZN WELLPR BHAH X Pick up BHA#4,Junk mill,5.5" 0.0 211.0 08:00 09:00 casing scraper assembly. 11/5/2015 11/5/2015 4.00 COMPZN WELLPR PULD X Pick up drill pipe&RIH with BHA#4 211.0 2,000.0 09:00 13:00 11/5/2015 11/5/2015 0.25 COMPZN WELLPR SFTY X Well control drill:well secured 37 2,000.0 2,000.0 13:00 13:15 sec's,CRT 89 sec's. crew conducted AAR. 11/5/2015 11/5/2015 0.50 COMPZN WELLPR CIRC X Reverse circulate at 2 bpm,240 psi. 2,000.0 2,000.0 13:15 13:45 11/5/2015 11/5/2015 1.50 COMPZN WHDBOP 'MPSP X Pick-up 1 stand of 3 1/2"tubing make- 2,000.0 2,000.0 13:45 15:15 up Storm packer. Set Storm packer at 100'and rack back the stand of tubing. 11/5/2015 11/5/2015 0.50 COMPZN WHDBOP MPSP X Pressure test Storm packer to 1000 2,000.0 2,000.0 15:15 15:45 psi for 5 minutes. 11/5/2015 11/5/2015 1.75 COMPZN WHDBOP RURD X R/U to test BOP's: Remove ware 2,000.0 2,000.0 15:45 17:30 bushing,fill stack and manifold with water.prep BOP's for test. 11/5/2015 11/5/2015 1.00 COMPZN WHDBOP SFTY X Conducted safety stand up with both 2,000.0 2,000.0 17:30 18:30 crews and service providers 11/5/2015 11/5/2015 1.00 COMPZN WHDBOP RURD X Continue to rig up testing equipment 2,000.0 2,000.0 18:30 19:30 and shell test BOPE to 250/3500 psi 11/5/2015 11/6/2015 4.50 COMPZN WHDBOP BOPE X Test BOP's and Choke manifold 2,000.0 2,000.0 19:30 00:00 250/3500 psi for 5 minutes.Test Annular Preventer to 250/2500 psi for 5 minutes. All tests are charted. 11/6/2015 11/6/2015 5.00 COMPZN WHDBOP BOPE P Test BOP's and Choke manifold 2,000.0 2,000.0 00:00 05:00 250/3500 psi,Annular Preventer 250/2500 psi. Fail/pass test on Choke valves 8&9, and manual kill.grease and re-test. 11/6/2015 11/6/2015 1.00 COMPZN WHDBOP RURD P RD testing equipment 2,000.0 05:00 06:00 11/6/2015 11/6/2015 0.50 COMPZN WELLPR RURD P Install wear ring 06:00 06:30 11/6/2015 11/6/2015 0.50 COMPZN WELLPR PACK P Released storm packer. 06:30 07:00 11/6/2015 11/6/2015 0.25 COMPZN WELLPR OWFF P Flow check for 15 min's. 07:00 07:15 11/6/2015 11/6/2015 0.75 COMPZN WELLPR 'PULD P Lay down storm packer. 07:15 08:00 11/6/2015 11/6/2015 8.50 COMPZN WELLPR PULD X Continue to pick up and RIH with 2 7/8 2,000.0 7,000.0 08:00 16:30 PAC drill pipe.Reverse circulating every 1000 ft to clear pipe of loose scale to 5000 ft. Well began taking fluid,continue to RIH. 11/6/2015 11/6/2015 2.00 COMPZN WELLPR SLPC P Slip and Cut drilling line at 7,000' 7,000.0 7,000.0 16:30 18:30 11/6/2015 11/6/2015 1.25 COMPZN WELLPR PULD X Continue to pick-up 2 7/8"DP and RIH 7,000.0 8,430.0 18:30 19:45 to 8,430'. 11/6/2015 11/6/2015 0.50 COMPZN WELLPR CIRC XT At 8,400'2 7/8"DP singles were 8,430.0 8,430.0 19:45 20:15 difficult to drift,pipe had dirt and scale. Pumped down drill pipe at 8,430'to check and clear DP. 11/6/2015 11/6/2015 3.25 COMPZN WELLPR PULD X Continue to pick-up 2 7/8"DP and RIH 9,450.0 9,450.0 20:15 23:30 to 9450'. Page 10/14 Report Printed: 3/15/2016 • i ,_, Drilling Operations Summary (with Timelog Depths) ) ;K &Welds 30-20 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/6/2015 11/7/2015 0.50 COMPZN WELLPR PULD X Pump down DP at 9450'to check and 9,450.0 9,450.0 23:30 00:00 clear pipe. 11/7/2015 11/7/2015 1.50 COMPZN WELLPR PULD X Single in the hole to 9,986'. Tag SBE 9,450.0 10,009.0 00:00 01:30 at 10,009', PUW= 135K,SOW=65'. 11/7/2015 11/7/2015 2.00 COMPZN WELLPR CIRC X Circulate well bore clean and pump Hi 10,009.0 10,009.0 01:30 03:30 -Vis Sweep. 11/7/2015 11/7/2015 1.00 COMPZN WELLPR CRIH P Spot 25 bbl CI brine pill at 10,009'. 10,009.0 10,009.0 03:30 04:30 (DP volume 45 bbls,780 strokes.) 11/7/2015 11/7/2015 0.50 COMPZN WELLPR OWFF P Monitor well for flow.30 min's 10,009.0 10,009.0 04:30 05:00 11/7/2015 11/7/2015 6.50 COMPZN WELLPR TRIP X POOH with BHA#4.Scraper 10,009.0 1,826.0 05:00 11:30 assembly 11/7/2015 11/7/2015 0.50 COMPZN WELLPR SFTY P Conducted safety stand down with 1,826.0 1,826.0 11:30 12:00 crew on rig incidents. 11/7/2015 11/7/2015 0.50 COMPZN WELLPR SVRG P service and inspect Top drive. 1,826.0 1,826.0 12:00 12:30 11/7/2015 11/7/2015 3.00 COMPZN WELLPR WAIT T Rig on standby until 10 pad safety 1,826.0 1,826.0 12:30 15:30 issue is resolved. 11/7/2015 11/7/2015 2.00 COMPZN WELLPR TRIP X Continue to POOH with BHA#4 1,826.0 215.0 15:30 17:30 11/7/2015 11/7/2015 2.00 COMPZN WELLPR BHAH X Lay down BHA#4/Mill&Scraper. Pick 215.0 0.0 17:30 19:30 -up Test Packer. 11/7/2015 11/7/2015 1.50 COMPZN WELLPR TRIP P RIH with 2 7/8"DP to 1000'and test 0.0 1,000.0 19:30 21:00 Packer. 11/7/2015 11/7/2015 0.50 COMPZN WELLPR PACK P Test Packer to 1000 psi for 5 minutes. 1,000.0 1,000.0 21:00 21:30 (Good Test) 11/7/2015 11/8/2015 2.50 COMPZN RPCOMP TRIP P Continue RIH with Test Packer. 1,000.0 4,200.0 21:30 00:00 11/8/2015 11/8/2015 4.00 COMPZN WELLPR TRIP P Continue to RIH with 5.5"Test packer 4,200.0 8,900.0 00:00 04:00 11/8/2015 11/8/2015 5.50 COMPZN WELLPR PRTS P Begin attempting to locate good 8,900.0 7,917.0 04:00 09:30 casing above hole @ 8890 RKB. Set packer @ 8900 FT RKB test failed. Move above know hole and continue to test. Unable to get a test @ up to 8610 ft KB. Pulled 10 stands to 7760 ft.Continue to test.Passed 2500 psi. 10 min's Released packer RIH to 8232.0 Failed. Pulled packer to 7948.0.Got pressure to 2500 psi dropped right off to 1300 psi.pulled packer to7917 ft pressured up to 2500 psi for 15 min's Dropped 25 psi. 11/8/2015 11/8/2015 8.50 COMPZN WELLPR TRIP P POOH and lay down Test Packer. 7,917.0 0.0 09:30 18:00 11/8/2015 11/8/2015 4.50 COMPZN RPCOMP RCST P Pick-up and run Lower Completion in 0.0 2,145.0 18:00 22:30 the hole to 2,145'. 11/8/2015 11/9/2015 1.50 COMPZN RPCOMP RCST P Make-up Baker Hydraulic Setting 2,145.0 2,145.0 22:30 00:00 Assembly 11/9/2015 11/9/2015 12.00 COMPZN RPCOMP RCST P RIH with Lower Completion on 2 7/8" 2,145.0 10,000.5 00:00 12:00 DP. 11/9/2015 11/9/2015 1.50 COMPZN RPCOMP RCST T Attempted to engage seal assembly 10,000.0 10,000.0 12:00 13:30 into SBE. Got 3 ft of seal in and stacked weight. Unable to work any deeper. 11/9/2015 11/9/2015 4.50 COMPZN RPCOMP TRIP T PJSM.POOH with lower completion 10,000.0 6,320.0 13:30 18:00 from 10,000'to 6,320'. Page 11/14 Report Printed: 3/15/2016 • • `= Drilling Operations Summary (with Timelog Depths) '" Drilling 30-20 - iUps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 11/9/2015 11/9/2015 5.00 COMPZN RPCOMP TRIP T PJSM.Continue POOH with lower 6,320.0 2,143.0 18:00 23:00 completion from 6,320'to 2,143'. 11/9/2015 11/9/2015 0.50 COMPZN RPCOMP PULL T Lay down Baker Premier Packer and 2,143.0 2,143.0 23:00 23:30 running tool. 11/9/2015 11/10/2015 0.50 COMPZN RPCOMP PULL T Continue POOH with lower completion 2,143.0 1,425.0 23:30 00:00 from 2,122'to 1,425'. 11/10/2015 11/10/2015 2.00 COMPZN RPCOMP TRIP T Continue to POOH with Lower 1,425.0 0.0 00:00 02:00 Completion standing back 8rd string 11/10/2015 11/10/2015 0.50 COMPZN RPCOMP RURD T RU 2 3/8"handling equipment. 0.0 02:00 02:30 11/10/2015 11/10/2015 1.00 COMPZN RPCOMP PULD T Picked up mule shoe and 10jts of2 0.0 350.0 02:30 03:30 3/8 EUE 8rd tbg.for clean out run. 11/10/2015 11/10/2015 7.50 COMPZN RPCOMP TRIP T RIH with PAC drillpipe. 350.0 9,998.0 03:30 11:00 11/10/2015 11/10/2015 2.50 COMPZN RPCOMP WASH T Tagged fill @ 9998 ft KB(2 ft inside 9,998.0 10,021.0 11:00 13:30 SBE top). PU cleared tbg of plug. Broke circulation at 3 BPM @ 2400 psi. 10034 ft RKB.Kick rate up to 4.5 BPM @ 3600 psi.Circulated 1.5 hole volumes. 11/10/2015 11/10/2015 1.25 COMPZN RPCOMP CRIH T Mix and pump 30 bbls of CI treated 10,021.0 10,021.0 13:30 14:45 11.5 ppg brine. 11/10/2015 11/10/2015 0.25 COMPZN RPCOMP OWFF T Flow check 15 min. 10,021.0 10,021.0 14:45 15:00 11/10/2015 11/10/2015 0.50 COMPZN RPCOMP SVRG T Rig maintenance.Serviced top drive. 10,021.0 10,021.0 15:00 15:30 11/10/2015 11/10/2015 2.50 COMPZN RPCOMP TRIP T POOH with clean out assembly from 10,021.0 7,438.0 15:30 18:00 10,021'to 7,438'. 11/10/2015 11/11/2015 6.00 COMPZN RPCOMP TRIP T Continue POOH with clean out 7,438.0 31.0 18:00 00:00 assembly from 7,438'to muleshoe. 11/11/2015 11/11/2015 0.50 COMPZN RPCOMP TRIP T Lay down muleshoe.Change out 31.0 0.0 00:00 00:30 handling equipment and clean rig floor. 11/11/2015 11/11/2015 5.50 COMPZN RPCOMP TRIP T Pick up seal assembly and X-nipple 0.0 2,130.0 00:30 06:00 with PXX plug and prong installed. RIH with lower completion.Replaced joints#7,#25,and#64-66.Fill up pipe every 5 stands. 11/11/2015 11/11/2015 0.50 COMPZN RPCOMP TRIP T Pick up packer,setting tool,and 2,130.0 2,171.0 06:00 06:30 bumper sub. 11/11/2015 11/11/2015 7.50 COMPZN RPCOMP RCST T Continue RIH with drill pipe from 2,170 2,171.0 7,370.0 06:30 14:00 ft to 7,370 ft filling every 5 stands. 11/11/2015 11/11/2015 0.50 COMPZN RPCOMP SVRG P Service top drive. Daily inspection 7,370.0 7,370.0 14:00 14:30 and service. 11/11/2015 11/11/2015 3.00 COMPZN RPCOMP RCST T Continue RIH with drill pipe from 7,370 7,370.0 9,984.0 14:30 17:30 ft to 9,984 ft filling every 5 stands. 11/11/2015 11/11/2015 0.50 COMPZN RPCOMP HOSO T Engage seals at 9,999 ft but could not 9,984.0 10,000.0 17:30 18:00 go past 10,000 ft.Set 20k down but could not go down.Decision made to POOH. 11/11/2015 11/12/2015 6.00 COMPZN RPCOMP TRIP T POOH wet with drill pipe racking back 10,000.0 6,250.0 18:00 00:00 from 10,000 ft to 6,250 ft. 11/12/2015 11/12/2015 9.00 COMPZN RPCOMP TRIP T Continue POOH wet with drill pipe 6,250.0 0.0 00:00 09:00 racking back. Lay down packer, setting tool,and bumper sub.POOH wet with tubing racking back.Seals look good. Page 12/14 Report Printed: 3/15/2016 • • :, Operations Summary (with Timelog Depths) ,, DriIliwsg -., &Wells it-: 30-20 ConocoPhillips AL,Sii.5 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/12/2015 11/12/2015 1.50 COMPZN RPCOMP SVRG T Service and inspect top drive.Clean 0.0 0.0 09:00 10:30 rig floor. 11/12/2015 11/12/2015 11.50 COMPZN RPCOMP RCST T RIH with lower completion with DS 0.0 10,012.0 10:30 22:00 nipple with RHC plug profile 11/12/2015 11/12/2015 1.50 COMPZN RPCOMP HOSO P Engage seals and fully locate. No 10,012.0 10,012.0 22:00 23:30 issues.Space out 2 ft and pressure up drill pipe to 2,500 psi for 10 minutes and increase to 3,000 psi for 5 minutes to set packer.Good set. Pressure test IA to 1,500 psi for 10 minutes.Release setting tool. 11/12/2015 11/13/2015 0.50 COMPZN RPCOMP CIRC P Swap well over to seawater. Pump a 10,012.0 10,012.0 23:30 00:00 45 bbl viscous pill ahead of seawater at 3 BPM. 11/13/2015 11/13/2015 4.00 COMPZN RPCOMP CIRC P Continue displacing 11.5 ppg brine 7,867.0 7,867.0 00:00 04:00 with seawater. Pumped 243 bbls of seawater.Well still out of balance. Pump 1.5 hole volumes at 4.5 BPM. Well static. 11/13/2015 11/13/2015 1.50 COMPZN RPCOMP SLPC P Slip and cut drill line. 7,867.0 7,867.0 04:00 05:30 11/13/2015 11/13/2015 6.50 COMPZN RPCOMP PULD P Lay down 2 7/8 PAC drill pipe.RIH 7,867.0 5,041.0 05:30 12:00 with pipe in the derrick and lay down. 11/13/2015 11/13/2015 0.50 COMPZN RPCOMP SVRG P Service top drive& inspect. 5,041.0 5,041.0 12:00 12:30 11/13/2015 11/13/2015 5.50 COMPZN RPCOMP PULD P Finish laying down 2 7/8 PAC drill 5,041.0 0.0 12:30 18:00 pipe. Break out and lay down bumper sub and packer setting tool.Clean and clear rig floor. 11/13/2015 11/13/2015 2.00 COMPZN RPCOMP TRIP P RIH with 23 stands of old 3 1/2 tubing 0.0 2,100.0 18:00 20:00 in derrick(used to support 2 7/8 pipe when stood back). 11/13/2015 11/13/2015 2.50 COMPZN RPCOMP PULD P Lay down old 3 1/2 tubing. Lay down 2 2,100.0 0.0 20:00 22:30 7/8 equipment. 11/13/2015 11/14/2015 1.50 COMPZN RPCOMP WWWH P Pull wear ring.Wash BOP stack. 0.0 0.0 22:30 00:00 11/14/2015 11/14/2015 0.50 COMPZN RPCOMP SVRG P Rig service.Daily top drive inspection. 0.0 0.0 00:00 00:30 11/14/2015 11/14/2015 11.00 COMPZN RPCOMP PUTB P PJSM. RIH with Upper Completion. 0.0 7,876.0 00:30 11:30 Pick up PBR and GLM#1. PBR anchored with 6 pins.Verified GLM#1 had SOV. RIH with upper completion. Latched up anchor assembly.Pulled 20K over to validate latch. 11/14/2015 11/14/2015 0.50 COMPZN RPCOMP PRTS P Dropped ball&rod. PT IA to 1000 psi 7,876.0 7,876.0 11:30 12:00 for 10 mins.Good test. 11/14/2015 11/14/2015 1.00 COMPZN RPCOMP HOSO P Shear out seal assembly.Space out 7,876.0 7,856.0 12:00 13:00 tbg and install hanger. Up wt=82K,Dwn Wt=60 K. Pressured up to 1000 psi on tbg. sheared out at 120K 11/14/2015 11/14/2015 1.50 COMPZN RPCOMP CRIH P Pumped 162 BBL's of CI sea water @ 7,856.0 7,856.0 13:00 14:30 3 BPM @ 800 psi. 11/14/2015 11/14/2015 0.50 COMPZN RPCOMP THGR P Prepared cellar and wellhead.Suck 7,856.0 7,856.0 14:30 15:00 out stack. Land hanger and RILDS. Page 13/14 Report Printed: 3/15/2016 • Operations Summary (with Timelog Depths) Drilling 30-20 ConocoPhillps �k�ka Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 11/14/2015 11/14/2015 2.00 COMPZN RPCOMP PRTS P PT tubing to 3,000 psi for 15 mins. 7,856.0 7,856.0 15:00 17:00 Good test. Bleed pressure to 1,500 psi.PT IA to 2,500 psi for 30 minutes. Good test. Bleed tubing to shear SOV. Pump both ways to confrm SOV sheared. 11/14/2015 11/14/2015 1.00 COMPZN WHDBOP MPSP P Set BPV. Pump down IA to test BPV 17:00 18:00 to 1,000 psi for 10 mins.Good test. 11/14/2015 11/14/2015 1.00 COMPZN WHDBOP OTHR P Lay down 3RD party tools. Lay down 18:00 19:00 WFT equipment. 11/14/2015 11/14/2015 4.00 COMPZN WHDBOP OTHR P 'Clean rig.Remove Koomey lines. 19:00 23:00 Offload fluid from pits. 11/14/2015 11/15/2015 1.00 COMPZN WHDBOP NUND P Nipple down BOPE and rack back. 23:00 00:00 11/15/2015 11/15/2015 3.00 COMPZN WHDBOP NUND P Nipple up adapter flange and tree. 00:00 03:00 11/15/2015 11/15/2015 0.50 COMPZN WHDBOP MPSP P Pull BPV and set tree test plug. 03:00 03:30 11/15/2015 11/15/2015 0.50 COMPZN WHDBOP PRTS P Pressure test tree to 250/5,000 psi. 03:30 04:00 Good test. 11/15/2015 11/15/2015 3.50 COMPZN WHDBOP FRZP P Rig up LRS. Pump 45 bbls of diesel 04:00 07:30 down IA. Put IA and tubing in communication and let fluid levels equalize. 11/15/2015 11/15/2015 ' 0.50 COMPZN WHDBOP MPSP P Install BPV 07:30 08:00 11/15/2015 11/15/2015 1.00 DEMOB MOVE RURD P Prep tree. RD lines.Rig released @ 08:00 09:00 09:00 hrs.Well SIP's.Tbg Opsi. IA=0 psi. IA= 160 psi. Page 14/14 Report Printed: 3/15/2016 yga • • prb iqio45-0 Regg, James B (DOA) From: Regg,James B (DOA) Sent: Thursday, November 12, 2015 9:35 AM To: n2364@conocophillips.com Cc: DOA AOGCC Prudhoe Bay Subject: RE:AOGCC Test Witness Notification Request: BOPE, Nabors 7ES, KRU 30-20 Request to defer the BOPE test is approved conditioned on successful install of isolation packer tomorrow. If you have to trip back to surface (installation problems)you will be expected to test BOPER before rerunning. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 SCANNED ' 'r_ Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Alan Romero [mailto:noreplyPformresponse.com] Sent: Thursday, November 12, 2015 6:52 AM To: DOA AOGCC Prudhoe Bay Subject: AOGCC Test Witness Notification Request: BOPE, Nabors 7ES, KRU 30-20 Question Answer Type of Test Requested: BOPE Requested Time for 11-13-2015 11:00 PM Inspection Location Nabors 7ES, KRU 30-20 Name Alan Romero E-mail n2364@conocophillips.com Phone Number (907) 659-7844 Company Conoco Phillips We would like to request a waiver on our weekly BOPE test on Other Information: 11/13/2015. as we will be running our isolation packer today having it set in the early am on 11/13/15. The laying down our drill nine and running our canner comnletion_ Our current time 1 • ! • frame to move is Monday morning. Sundry# 315-502, PTD # 197-045 Andrew Beat has sent a email to Anchorage as well. Thank you Alan Submission ID: 323152733661842899 2 • 'on0�5 • • 2J0g 0 5 WELL LOG TRANSMITTAL#902752957 DATA LOGGED toi24/2O15 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. October 23, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEWED RE: IBP Setting Record: 30-20 OCT 2 8 2015 Run Date: 9/16/2015 OGCC 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 30-20 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22750-00 scow 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 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: la r11. , ,/, OF Tom" Alaska Oil and Gas yw• \��I/j��s� THE STATE .rw '—spa '� of Conservation Commission � _ =__=.=_ �M ALASI�:A '- 11-_---4:;---z:_ 333 West Seventh Avenue =Vrt -, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *ti', Main 907.279.1433 OF ALASV' Fax: 907.276.7542 www.aogcc.alaska gov Andrew Beat Sr. Wells Engineer SC ED SEP O 115 __ D ] m,5- ConocoPhillips Alaska, Inc. 17 `T P.O. Box 100360 1 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Rive Oil Pool, KRU 30-20 Sundry Number: 315-502 Dear Mr. Beat: 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, aity/-21-CA4`L- Cathy P. Foerster Chair sf DATED this 31 day of August, 2015 Encl. 4*-17 RBDMS SEP 0 1 2015 STATE OF ALASKA AL ..,KA OIL AND GAS CONSERVATION COMA ION . APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing LJ'�'' Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing It Change Approved Program r Rug for Redd!! r Perforate New Pool r Repair Well r ' Re-enter Susp Well r Other: I- 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory r Development r. 197-045 , 3.Address: Stratigraphic r Service r 6.API Number: P.0 Box 100360,Anchorage,Alaska 99510 50-029-22750-00 7. If perforating, 8 Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r / KRU 30-20 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25519 • Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured). Junk(measured): 10400 - 6836 10324'- 6767'• none 10300' Casing Length Size MD TVD Burst Collapse - CONDUCTOR 79 16 121' 121' SURFACE 6266 7.625 6308' 4130' RECEIVED PRODUCTION 10351 5.5 10390' 6627' AUL 13 ZU15 c?-s s/30s Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10116-10131, 10140-10165 • 6580-6593,6601-6624 3.5 L-80 10012 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer NIPPLE-CAMCO DS NIPPLE • MD=499 TVD=498 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r• Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/22/2015 OIL r- WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Andrew Beat @ 265-6341 Email. Andrew.T.Beat@conocophillips.com A Printed Name A drew Beat Title: Sr. Wells Engineer Signature Phone.265-6341 Date 6/ /Z6)16 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 31 5– G 0 2 Plug Integrity r BOP Test /Mechanical Integrity Test r Location Clearance r Other: 0 c p ti-5t f a 2 50 O p s,'� (M P 5 P /s 2.6? 6, f)S J , r)nvlar' pc–r✓E v2 tri' fe 5t' ILK) Z 5-67c- 1,5 'S Spacing Exception Required? Yes ❑ No [✓I Subsequent Form Required: /d- 40`- APPROVED BY Q Approved by. i);(-4'21.4"--- COMMISSIONER THE COMMISSION Date: U –3/— 047 (' /S Approved application Is valid tor 12 months trom the date of approval. submit F r and Form 10-403 Revised 5/2015 fi4 �'I� � RBDMS A . _t1inpAcate !TL- ?/3/ / IS ORIGI NAL ,e ms/( . • ConocoPhillips RECEIVED Alaska P.O. BOX 100360 AUG 18 2015 ANCHORAGE,ALASKA 99510-0360 (` August 17,2015 AO G`'C Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Producer 30-20(PTD# 197-045). 30-20 was originally drilled and completed in 1997 as an'A' sand,gas-lifted producer in Kuparuk. It continued to produce until August,2014 when it failed a proactive TIFL and was shut in.A LDL found tubing leaks at 7,890' KB, 7,981' KB,and 8,025' KB.The well also failed a CMIT in October,2014 and a LDL identified a production casing leak at 8,890' KB. The proposed workover scope for 30-20 will cover pulling the existing 3-1/2"completion from the SBE located at 10,011' KB and installing a new 3-1/2"completion with a permanent packer set above the production casing leak for isolation. If you have any questions or require any further information,please contact me at 265-6341. Sincerel Andrew Beat Wells Engineer CPAI Drilling and Wells KUP PROD 30-20 ConocoPhillips m Well Attributes 'Max Angle&MD TD • Alaska,Inc. Wellbore API/UWI Fleld Name Wellbore Status rax (°) MD(ftKB) Act Btm(ftKB) Cmomftil`ps 'i 500292275000 KUPARUK RIVER UNIT PROD 63.25 6,674.84 10,400.0 ... . Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 30-20.10/22/2014 8.02.48 AM SSSV:NIPPLE 140 12/26/2013 Last WO: 41.00 3/29/1997 Vertical schematic(actual) Annotation Depth(BAB) End Date Annotation Last Mod By End Date ---- --Last Tag:SLM 10,142.0 9/25/2014 Rev Reason:PULL PLUG/CATCHER hipshkf 10/21/2014 HANGER;37.0 Y Casing'Strings TCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WE/Len(I...Grade Top Thread 1f$ CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED `r }iy�', Casing Description OD(in) ID(in) Top(ftKB) Set Depth(568) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Er SURFACE 75/8 6.875 41.6 6,308.0 4,130.3 29.70 L-80 BTC '1'.Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 5.5x4 5 512 4.950 38.8 10,390.0 6,826.9 15.50 L-80 LTC-MOD CONDUCTOR;42.0-121.0-. Tubing Strings Tubing Description I String Ma...(ID(in) I Top(ftKB) I Set Depth(ft..1 Set Depth(ND)(...IWt(Ib/ft) 'Grade I Top Connection - NIPPLE;499.1 _r TUBING II 3 1/2I 2.992 37.0 10,011.91 6,485.211 9.30 L-80 EUE 8rd Mod Completion Details Nominal ID i ao Top(ftKB) Top(TVD)(ftKB) Top Ind(*) Item Des Com (in) 37.0 37.0 0.00 HANGER FMC GEN IV HANGER 3.500 499.1 498.4 7.62 NIPPLE CAMCO DS NIPPLE 2.812 XO THREAD;3,333.6 V� 10,002.3 6,476.5 24.61 NIPPLE CAMCO D NIPPLE 2.250 V a 10,010.1 6,483.6 24.65 LOCATOR BAKER GBH 22 LOCATOR w/16'SEALS 3.000 GAS LIFT;3,371.6 r 10,011.4 6,484.7 24.66 SBE BAKER SEAL BORE EXTENSION 2.992 ® Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl XO THREAD;3,415.5 a Top(ftKB) (ftKB) r) Des Com Run Date ID(in) it 10,300.0 6,745.6 25.39 FISH PERF GUN PART 8"NOSE STRIP OF PERF GUN 9/252005 XO THREAD;5,828.5- T. LOST 9/25/2005 a Perforations&Slots GAS LIFT;5,865.8- - Shot arDens Top(ND) Ate,(TVD) (shotslf Top(ftKB) Btm(ftKB) (RAB) (ftKB) Zone Date t) Type Com XO THREAD;5,909.6 + 10,116.0 10,131.0 6,579.6 6,593.1 A-3,30-20 4/12/1997 4.0 IPERF 180 deg ph;oriented(+/ -)hlowside;2-1/8"EJ 10,140.0 10,165.0 6,601.3 6,623.8 A-2,30-20 9/25/2005 6.0 APERF 2-1/8"Spiral EJ,45 deg. e phase Mandrel Inserts St oti N Top(ND) Valve Latch Port Size TRO Run SURFACE;41.66,308.0-- Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Com f 3,371.6 2,602.8 Camco KBMM 1 GAS LIFT GLV BK 0.156 0.0 3/6/2005 XOTHREAD;7,746.4- E 2 5,865.8, 3,903.2 Comm -KBMM 1 GAS LIFT GLV BK 0.188 1,379.0 3/6/2005 3 7,784.5 4,896.7 Comm KBMM 1 GAS LIFT GLV BK 0.188 1,368.0 3/6/2005 GAS LIFT;7.784.5t. 4 8,920.6' 5,564.5 Comm KBMM 1 GAS LIFT OV BK 0.188 0.0 3/6/2005 5 9,593.6 6,1049 Comm KBMM 1 GAS LIFT OPEN BK 0.000 0.0 10/7/2014 6 9,990.1 6,465.4 Comm KBMM 1 GAS LIFT DMY BK 0.000 0.0 3/5/2005 XO THREAD;7,828.3 A Notes:General&Safety II (�j End Date Annotation XO THREAD;8,885.3 ys. f" i 12/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 1 ect 1/30/2011 NOTE:3.5x2.875x3.5 CROSSOVERS ABOVE&BELOW MANDRELS GAS LIFT,8920.6 I ' I XO THREAD;89645 XO THREAD;9,556.6 I GAS LIFT;9,593.6 Ilt XO THREAD;9637.6 i' I' XO THREAD;9,952.1 GAS LIFT;9,990.1 NIPPLE;10,002.3 XO THREAD;10,003.9 . LOCATOR;10,010.1 � I� SBE;70,017.4 1. .l ' I IPERF;10,116.0-10,131.0 APERF.10,140.0.10,165.0 FISH;10,300.0 PRODUCTION 5.504.5;38.8- 10,390.0 30-20 Rig Workover P&R Tubing w/Stack Packer (PTD#: 197-045) Current Status: This well was shut in on August 27,2014 and is currently waiting to be worked over to replace tubing and isolate a production casing leak. Scope of Work: Pull the existing 3-1/2"tubing,install new 3-1/2"completion with a stacked packer to isolate production casing leak. General Well info: Well Type: Producer MPSP: 2,006 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 2,666 psi/6,602'TVD(7.8 ppg EMW)measured on 09/25/2014 Wellhead type/pressure rating: FMC Gen IV,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT-TxIA failed-4/23/2015 Earliest Estimated Start Date: October 22,2015 Production Engineer: Scott Pessetto Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards.Complete the PJSM. 2. RU Slickline. 3. Replace valves with DV's in GLM#1-5 and leave GLM#6 open. 4. RD Slickine. 5. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Workover Procedure 1. MIRU. 2. Pull BPV.Reverse circulate seawater.Obtain SITP&SICP,if still seeing pressure at surface,calculate new KWF,weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/2,500 psi. a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe _ rams will be tested upon pulling the completion. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 3 'h"tubing. 6. RIH with drill pipe and test packer to verify depth of production casing leak. 7. P004'gaud rack back drill pipe. 8. RIH with FA packer and lower completion to just above SBE. 9. Spot a balanced pill of corrosion inhibited brine in the Tbg and IA from the SBE up to the new PBR. 10. Slowly cycle the charge pump and look for pressure increase or lack of returns as the seals engage. Shut down charge pump and space out.Drop the ball and pressure up to set the.FA packer. a. PT the IA to confirm packer set. 11. Release the running tools and POOH laying down drill pipe. 12. RIH with new upper completion and seal assembly. Stab anchor into packer,shear the PBR,space out,mark the pipe,and pull seals from PBR. 13. Install space out pups below the tubing hanger,MU tubing hanger. 14. Circulate well full of corrosion inhibited brine. 1 30-20 Rig Workover P&R Tubing w/Stack Packer (PTD#: 197-045) 15. Land the tubing hanger,RILDS. 16. PT the tubing,bleed tubing,PT the IA,and record.Bleed the IA to zero,then tubing.Ramp up the IA pressure quickly to shear the SOV. 17. Pull the landing joint,install BPV.Pressure test the BPV from below. 18. ND BOPE. 19. NU tree.Pull BPV and install tree test plug.Test tree and pull test plug. 20. Freeze protect well with diesel. Set BPV. 21. RDMO. Post-Rig Work 1. Pull BPV. 2. RU Slickline to pull SOV and run gas lift design. 3. Reset well house(s)and flowlines of adjacent wells. 4. Turn well over to operations. 2 • ✓ 30-20 ConocoPhillips KRU Producer P&R Tubing, Stack Pkr Well Details: PROPOSED API: 500292275000 COMPLETION PTD: 197-045 Wellhead: FMC Gen IV 5M Tree: Calico 3-1/8" 5M Casing/Tubing Details: 16"62.5#H-40 Conductor to 121' KB 7-5/8"29.7#L-80 Surface to 6,308' KB 5-1/2" 15.5#L-80 Production to 10,011' KB 4-1/2" 12.7#L-80 Production Tail to 10,390' KB 3-1/2" 9.3#L-80 Tubing to 10,011' KB Misc Details: Max Inclination: 63.25° Max Dogleg:4.38 °/100' ONO — Camco 3-1/2" x 1" KBG GLM's Last Tagged Fill: 10,142' KB Total Depth: 10,400' KB Mai MIN Perforation Details: 10,116'-10,131' KB—A 3 Sand I:' 8,780' - Baker 80-40 PBR 10,140'-10,165' KB—A 2 Sand -8,800' - Baker FA Packer ,..=" -8,890'- Production Casing Leak -9,000' - 2.813" Camco DS Nipple Ui 10,011' - Baker SBE w/ GBH-22 Seals Q Production Casing XO 5-1/2" to 4-1/2" A Sand Perfs Date: August 17,2015 I Drawn By: Andrew Beat o 4-t5 2-5110 WELL LOG TRANSMITTAL DATA LOGGED S/2a/2015 M.K BENDER To: Alaska Oil and Gas Conservation Comm. May 4, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEWED MAY 0 6 2015 RE: Plug Setting Record: 30-20 Run Date: 4/21/2015 AOGCC 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 30-20 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22750-00 sCM4KED ,i UN 1 5 2 015 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 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: _ Signed: "d2,2-0.14476...eiveet Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~ ~'- oL/~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items- Pages: [] GraYScale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Odgina!- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type 'OVERSIZED [] .Logs of various kinds Other COMMENT~: Scanned bY: Se~w~j M~dred-D~re~ I~ Lowell Date.: ~ / TO RE-SCAN Notes: Re-Scanned bv: Beverly Mildred Daretha Nathan Lowell Date: /si ) ConocciPhillips ~~C~/(/¡ 4/8.1'.{: ì 21 72'D aOi/ßt 2005 Gas C 4"c. úì¡J,'~ C 'hafer; "oll1l1J.. itff'(J '8sio¡¡ October 18, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ) Mike Mooney Wells Group Team Leader Drilling & Wells P. o. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 Subject: Report of Sundry Well Operations for 30-20 (APD # 197-045) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforations operations on the Kuparuk well 30-20. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ¡/ ¡i~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells SC/-\NNED NO\! 0 1 2005 MM/skad 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPh iIIips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): Rig RKB 41', Pad 23' 8. Property Designation: ADL 25519, ALK 2555 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF. CASING PROD. CASING PROD. CASING Perforation depth: ) ) r\t:L,t:M Vr:O OCT 2 4 Z005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commissiol REPORT OF SUNDRY WELL OPERATIONS Anchorage RepairWell 0 Pull Tubing 0 Ope rat. ShutdownD Stimulate 0 Waiver 0 Other o o o Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Time Extension Re-enter Suspended Well Exploratory 0 Service 0 5. Permit to Drill Number: 197-0451 6. API Number: 50-029-22750-00 9. Well Name and Number: 30-20 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 10400' feet true vertical 6836' feet measured 10204' feet true vertical 6659' feet Length Size MD 80' 16" 121' 6267' 7-5/8" 6308' 9990' 5-1/2" 1 0031' 359' 4-1/2" 10390' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4130' 6502' 6827' Measured depth: 10116'-10131',10140'-10165' true vertical depth: 6579'·6593', 6601'·6624' Tubing (size, grade, and measured depth) 3-1/2" , 2-7/8", L-80, 10012' MD. RBDMS 8Ft 0 cr .2 5 2005 Packers & SSSV (type & measured depth) no packer SSSV= Cameo 'OS' nipple 499' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 55 mmscfld 480 923 524 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Oil-Bbl 200 325 Casinç¡ Pressure Tubinç Pressure 152 157 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact Printed Name Signature WDSPL 0 Mike Mooney @ 263-4574 Mike Mooney ~4w~ Title Phone Wells Group Team Lead ~ / ' Date /~ZcJ/¿~ ,. _-__.-- Preoared bv Sharon AI/suo-Drake 263-4612 o RIG I N A LI ¡ Submit Original Only Form 10-404 Revised 04/2004 ) 30-20 Well Events Summary ) Date Summary 09/12/05 DRIFT WITH 18.5' OF 2.125" STEM TO 10,204' RKB. [Tag] 09/25/05 [Perf] - PERFORATE A2 SAND - 10140 -10165 FT MD. GUN SYSTEM - 2 1/8" POWER SPIRAL ENERJET - 6SPF 45 DEG PHASING. ZONE SHOT IN TWO RUNS GUN1=BTM 15FT (10150 - 10165), GUN2=TOP 10FT (10140 - 10150 FT). 8" BTM NOSE STRIP SECTION LEFT IN HOLE (NOT ON GUN STRIP AT SURFACE) AFTER SHOOTING GUN2. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 962' FNL, 1979' FWL, Sec. 22, T13N, R9E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic __ Service__ (525616, 6021857) 6. Datum elevation (DF or KB feet) RKB 41' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 30-20 At top of productive interval 1123' FNL, 1083' FWL, Sec. 26, T13N, R9E, UM At effective depth At total depth 1273' FNL, 1164' FWL, Sec. 26, T13N, R9E, UM 9. Permit number / approval number 197-045 / 10. APl number 50-029-22750-00 11. Field / Pool Kuparuk River Field / Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 80' 16" Surface 6267' 7.625" Production 9990' 5.5" Production 359' 4.5" 10400 feet Plugs (measured) 6836 feet 10110 feet Junk (measured) feet Cemented 290 sx AS 1 410 sx ASLW, 530 sx Class G, 65 180 sx Class G included above Measured Depth True vertical Depth 80' 121' 6308' 4130' 10031' 6502' 10390' 6827' Perforation depth: measured 10116'- 10131' true vertical 6579' - 6593' ]'ubing (size, grade, and measured depth) 3.5"x 2.875", 9.3 x 6.5#, L-80 @ 10012' Packers & SSSV (type & measured depth) No packer No SSSV 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 OiI-Bbl Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Oil__ X Gas__ Suspended__ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~--~~,,~~~ Title: Wells Team Leader Peter Nezaticky ~ J Form 10-404 Rev 06/15/88 · Questions? Carl Peter Nezaticky 659-7224 .te Prepared b)/ Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLICATE PHILnIPS Alaska, ThC. KUPARUK RIVER UNIT WELL SERVICE REPORT :K1 (30-20 (W&-6)) WELL JOB SCOPE JOB NUMBER 30-20 ANN-COMM 0727021646.20 DATE DAILY WORK UNIT NUMBER 07/28/02 CEMENT TOP JOB DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES DS-CULPEPPER NEZATICKY FIELD AFC# CC# DALLY COST ACCUM COST Signed ESTIMATE WCW.K02.KR9 $6,400.00 $6,550.00 9.30 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSI 0 PSII 0 PSI DALLY SUMMARY PUMPED 2 BBL OF ARTIC SET 1CEMENT INTO THE SURFACE PIPE X CONDUCTOR ANNULUS.[WH Maintenance] TIME 12:40 12:45 12:50 LOG ENTRY RIGGED UP TO WELL . PUMPED 2 BBL OF ARTIC SET 1 CEMENT - 15.8 PPG. WASH UP. RDMO '~-.~--~/ ''a~/ ~ HIL IP PETR M NY NIPPLE (~ 0D:3,500) i TUBtNG (0-3334, -- OD:3.500, ]D:2.992) MandrelNalve 1 (3372-3373, OD:4,507) Gas Lift Mandrel/Valve 3 (7784-7785, OD:4.507) Gas Lift Mandrel/Valve 4 (892%8922, OD:4.507) Gas Lift Mandrel/Valve 5 (9594-9595, OD:4,507) Gas Lift Mandrel/Valve 6 (9990-9991, OD:4.507) NO GO (10002-10003, 0D:2.875) LOCATOR (10010-10011, OD:3.500) Ped (10116-10131) Descdption i 2.812 2.25~1 Baker 'GBH-22' w/16' seals I 2.992 Baker t 2~92 . ............ ,,PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY NIPPLE (499-500, -- OD:3.500) TUBING (0-3334, -- OD:3.500, ID:2.992) Gas Lift -- MandrelNalve 1 (3372-3373, OD:4.507) Gas Lift MandrelNalve 3 (7784-7785, OD:4.507) Gas Lift MandrelNalve 4 (8921-8922, OD:4.507) Gas Lift MandrelNalve 5 (9594-9595, OD:4.507) Gas Lift MandrelNalve 6 (9990-9991, OD:4.507) NO GO (10002-10003, OD:2.875) LOCATOR (10010-10011, OD:3.500) Perf - (10116-10131) KRb 30-20 APl: 500292275000 SSSV Type: Camco 'DS' Nipple Annular Fluid:I Reference Log: Last Tag:110110 LastDate: Tao ] 9/3/00 CONDUCTOR Well Type: SURF. CASING Orig Compltn: Last W/O: Ref Log Date: PROD 3/29/97 PROD. CASING TD: 10400 ftKB Max Hole Angle: i-All: : PROD. CASING s: Ail:: 10031 10390 3.500 2.875 3.500 2.875 3.500 2.875 I 3.500 63 deg@6675 TUBING TUBING TUBING TUBING TUBING TUBING TUBING TUBING TUBING TUBING TUBING TUBING TUBING P~:rati~h~ SdmmarY Interval 10116 - 10131 0 3334 3415 5828 5910 7746 7828 2.875 8885 3.500 8964 2.875 I 9557 3.500 9638 2.875 9952 3.500 10004 Angle @ TS: Angle @ TD: Rev Reason: Last Update: TVD Wt Grade 121 62.50 H-40 4130 29.70 L-80 65021 17.00 L-80 6827 12.60 L-80 Boffom TVD 3334 2584 3415 2626 5828 3883 5910 3925 7746 4876 7828 4920 8885 5539 8964 5596 9557 6073 25 deg@10002 25 deg@10400 Update Last Tag; by JWP 11/8/00 Thread 9638 6145 9952 6431 1OOO4 6478 100121 6485 Wt IGrade I 9.30 I L-80I 6.50 I L-80I 9.30 I L-80 6.50 L-80 9.30 L-80 6.50 I L-80 9.30 J L-80 6.50 [ L-80 9.30 L-80 6.50 I L-80 I 9.30 I L-80I 6.5O L-80 9.30 L-80 Thread EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD EUE 8RD EUE 8RD MOD TVD Zone Status Ft SPF Date Type Comment 6579- 6593 A-3 15 4 4/12/97 PERF 180 deg ph; oriented (+/-) f/Iowside; 2-1/8" EJ V Mfr V Type GLV DV GLV GLV GLV OV ;GaS Lift Mandrels/Valves TVD 2603 3902 4896 Man Man Mfr Type Camco 27/8X1 KBMM Camco 27/8X1 KBMM Camco 27/8X1 KBMM Camco 2KBMM7/8 × 1 Camco 2KBMM7/8 X 1 Camco 2KBMM7/8 X 1 5565 6105 6465 ;quip, etc.)- JEWELRY v OD 1.0 1.0 1.0 1.0 1.0 1.0 MD 3372 5866 7784 8921 9594 9990 Description NIPPLE Camco 'DS' Nipple NO GO I Camco'D' Nipple LOCATORI Baker 'GBH-22' w/16' seals SPACE OUT SBE Baker Latch Port I TRO Date Vlv I I Run I Cmnt BK 0.156 1355 i 4/20/97I BK 0.000_ 0 3/29/97I BK 0.188 1366i 4/20/97 BK 0.250 1459 4/19/97 BK 0.250 1444 4/19/97 BK 0.188 0 4/19/97 2.250 3.000 2.992 12.992 SUNDRY NOTICE 10-404 Phillips Kuparuk Well 30-20 Annular Cement "Top-Job" July 28, 2002 Phillips Alaska, Inc., Kuparuk well 30-20 top of cement between the surface pipe and conductor (9 5/8" x 16") was measured at 11 feet below grade. Arctic Set I cement (15.8 ppg) was pumped into the annular void (2 bbl) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor casing. The State Inspector was notified of the cement job and waived attendance, but will inspect the wellhead post cementing. The field Well Service Report is attached. MEMORANDUM T O' Julie HeusSer, CommiSSioner THRU- State of Alaska AlaSka Oil and Gas Conservation Commission ~J~ DATE: January 26, 2001 Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 30 Pad F. ridav, January 26,, 2.001. ! traveled to the Kuparuk River Field and witnessed the 90-day retest of the safety valve systems on 30 Pad. As the attached AOGCC safety Valve SYstem Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Low pressure pilOt on WAG injector'30,05 tripped beloW the required set point. This pilot was retested and passed at the the time of this test. Eamie Barndt Conducted the testing today he demonstrated good test procedure and was a pleasure to work with - All the wellhouses entered at this location were Clean and all related equipment appeared to be in good condition, Summary:. I witnessed the cj0-day SVS testing at 30 Pad in the Kuparuk River Field.. KRU 30 Pad, 12wells, 24 components, 12 welihouse inspections Attachment: SVS KRu 30 Pad 1-26-01 CS I failure '4.1% failure rate X UnclaSsified Confidential (Unclassified if doc. Removed) SVS KRU 30 Pad 1-26-01CS.doc AlaSka Oil and Gas Conservation Commission Safety Valve SYstem Test Report Operator: ,Pbil!!ps Operator Rep: Earnie Barndt AOGCC Rep: Chuck Schcve Submitted By: Chuck Scheve Field/Unit/Pad: Kupamk / KRU / 30 Separator psi: LPS 67 Date: 1/26/01 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI, ;, PSI Trip Code Code Co~e,L Passed GAS orCYCLE .30-01 ' 18~0730' 67 70 80 P P OIL 30-02 1880740 6~! '' 70 60 P I P .... OIL ,30-03" 188'0J50 67 70 '60 p P ............. OIL 30-04 1880620 ' 67: 70 65 "13 ' P " OIL 30-06 1880600 30-08 1880~4'0 '67 70 70 P' "P " OILI 30-09 1880610 67 70 ' ' 40 P P 0IL 30-11 185042b 6~ 70! " 1~0 p ~'p ........ OIL 30-13 1880400 67 70 6~j' e p' .... oIL 30'14 1880390 - 30-15 '1880310' ' 67 70 -" 70 'P ' 1~ .... OIL 30-18 18~0260 6:7 "70' ' 55 ' P P ...... 30-2'0 ' i9;/04~0 67 " 7b 60" P 'P'" Om 36,05' 18807.60! " 3750' 2600 1100 ....3 p " '1/26/01 WAG Wells: 12 ComponentS: 24 Failures: 1 Failure Rate: 4.17% 1-190 Day Remarks: Pilot on WAG injector 30-05 tripped below required set pressure. Pilot was retested and p.a~ed this date. RJF 1/16/01 Page 1 ofl SVS KRU 30 Pad 1-26-01 CS.xls ON OR BEFO C:LOi~LM.DOc PERMIT DATA 97-045 DGR-TVD 97-045 DGR/RES-MD 97-045 7975 97-045 MWD SRVY 97-045 SRVY CALC 97-045 GAS LIFT-BHP AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~%ff~i35-6836 L~318-10400 ~pE~Y MPT/G~/~ES/~O~ .-1400. LEX 121.-10400. ~00-10125 Page: 1 Date: 04/07/99 RUN RECVD FINAL 05/07/97 FINAL 05/07/97 3 05/07/97 06/11/97 06/23/97 FINAL 12/18/97 T D BOX lO-4O7 ~%OMPLET¢ON DATE O Wf2 H~/ DAILY WELL OPS -'~~/l~ ~7/ TO ~/~/ Are dry ditch samples required? yes ~___~_received? Was the well cored? yes ~~A~..alysis & description received? Are well tests required~} yes ~Re,ceived? ~'~~' Well is in compliance ~ Ihitial COMMENTS 12/1 0/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11632 Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 3F-5 ~ ~ - c.Oc) ~ PRODUCTION PROFILE 971124 I 1 3 F-10 ,';~ .~ ~ c~-? I PRODUCTION PROFILE 97111 9 I 1 3F-15 ~.z~.. c~,~ ,~IC._., INJECTION PROFILE 971014 I 1 3G-03 E~'(.~- ID~' PRODUCTION PROFILE 971016 I 1 3 G-03 ',~-" PRODUCTION PROFILE 971 026 I 1 3H-01 '~"/- II 0 PRODUCTION PROFILEW/DEFT 971030 I 1 3 K- 22 ~ ~/ - O ~ ~_,[ ~ C_~ PRODUCTION PROFILE 9711 26 I 1 3 K-23 ~ "'/- O~/~ PRODUCTION PROFILE 971127 I 1 i30-20 C~-'!- ©(_/~'- GAS LIFT SURVEY 971026 I 1 3Q-08A ~--~ - {(~'"~ BRIDGE PLUG SE'n'iNG RECORD 971015 I 1 3R-18 c~J~._ C)I'-~ GAS LIFT SURVEY 971025 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ARCO Alaska, Inc. Post Office Box 10036~ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 20, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 30-20 (Permit No. 97-45) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 30-20. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad ORI$1NAL STATE OF ALASKA - - ALAS,,,-~ OIL AND GAS CONSERVATION ~ .;MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-045 3. Address P. O. Box 100360, Anchorage, Alaska 9951 4. Location of well at surface 962' FNL, 1979' FWL, Sec. 22, T13N, RDE, UM At top of productive interval 1123' FNL, 1083' FWL, Sec. 26, T13N, RDE, UM At total depth 1273' FNL, 1164' FWL, Sec. 26, T13N, RDE, UM Elevation in feet (indicate KB, DF, etc.) Rig RKB 41', Pad 23' 6. Lease Designation and Serial No. ADL 25519, ALK 2555 8. APl Number 50-029-22750 9. Unit or Lease Name Kuparuk River Unit 10. Well Nu-m--6~ 30-20 11. Field and Pool Kuparuk River 12. Date Spudded3/20/97 ii13' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re l~ 6' N°' °f C°mpleti°ns3/27/97 4/12/97 N/A MSL] One 17. Total Depth (MD+TVD)i18: Plug Back Depth (MD+TVD)I19. Directional SurveyI20. Depth where SSSV set~21. Thickness of Permafrost 104006836 F11 10324 6767 FT~ l~Ves E~No j~ .... N/A MDJ 1650' (Approx.) 22. Type Electric or Other Logs Run GR/Res, GR/CCL/SLTJ 23. CASING SIZE WT'. PER FT. 16" 62.58# 7.625" 29.7# 5.5" 15.5# 4.5" 12.7# L-80 10031' CASING, LINER AND CEMENTING RECORD SE-FI'lNG DEPTH I HOLE Do'n-oM ~ .... S!Z_E _ 121' ~290SxASl 6308' J__9_:__8~_~i'__. 10031' ~ 180 Sx Class G 10390' I 6.75" GRADE TOP H-40 Sud. L-80 Sud. L-80 Sud. 24. Perforations open t° ProductiOn (MD+TVD of Top and Bottom and interval, size and number) MD TVD CEMENTING RECORD AMOUNT PULLED MD TVD 10116'-10131' 6579'-6593' 4 spf 410 Sx ASLW, 530 Sx Class G, 65 sx ASI 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 1 0012' 10011' 26. Ac~D FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10116'-10131' 221,112# in perfs w/12# ppa 10/14 at perfs 27. Date First Production 4/21/97 Date of Test iHours Tested 5/7/97 i 9.5 PRODUCTION TEST 'iM~'th°d of Operation (Flowing, gas lift, etc.) Gas Lift GAS-MCF WATER-BBL 1537 13 PRODUCTION FOR I OIL-BBL TEST PER,OD" .j .......... 1_?_!_7 CALCULATED · IOIL-BBL ~_4-HOUR RATE ] 785 Flow TubinglCasing Pressure GAS-MCF WATER-BBL Pres. s. 19~ 1347 948 5 '~8. CORE DATA i-CHOKE 0SIZE GAS-OIL RA~I26 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Ma' ---' ~ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Total pump volumes for this event: Category 1. 11740 Category 2. 100 Top Kuparuk C 10002' 6476' Category 3. 0 Bottom Kuparuk C 10035' 6506' Total: 11840 Top Kuparuk A 10104' 6569' Bottom Kuparuk A 10232' 6684' Total To Date: 11840 Annulus left open - freeze protected with diesel. §1. 'f'ist of Attachments ..................... Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge .............. Title T"~r-~.\;~ ~-....~...;v~ee.," Date G 7_0 l ~'~l"- ................................ ,r _'':'r~ ..... Prepared~ By Name/Number: ............ INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 5/2/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:30-20 RIG:PARKER 245 WELL ID: AK8717 TYPE: AFC: AK8717 AFC EST/UL:$ 1300M/ 1500M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:03/20/97 START COMP: WI: 0% SECURITY:0 API NUMBER: 50-029-22750-00 FINAL:03/29/97 03/18/97 (D1) TD: 121' (121) SUPV:DCL DAILY:$ 03/19/97 (D2) TD: 121'( 0) SUPV:DCL DAILY:$ 03/20/97 (D3) TD: 818' (697) SUPV:DCL DAILY:$ 03/21/97 (D4) TD: 4247' (3429) SUPV:DCL DAILY:$ 03/22/97 (D5) TD: 6318' (2071) SUPV:DCL DAILY:$ 03/23/97 (D6) TD: 6318' ( 0) SUPV:DCL DAILY:$ 03/24/97 (D7) TD: 6566' (248) SUPV: DCL DAILY:$ 03/25/97 (D8) TD: 9101' (2535) SUPV: DCL DAILY: $ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG (DM @ CPF-3) Held safety meeting. Move camp, utility module and drill module. 103,556 CUM:$ 103,556 ETD:$ 0 EFC:$ 1,403,556 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PU DRILL PIPE Held safety meeting. Move rig and utility modules to 30 pad. Accept rig at 0000 hrs. 3/20/97. 25,028 CUM:$ 128,584 ETD:$ 0 EFC:$ 1,428,584 MW: 8.9 VlSC: 75 PV/YP: 22/22 APIWL: 9.2 DRILLING Function test diverter. Drilling 9-7/8" hole from 121' to 818'. 81,200 CUM:$ 209,784 ETD:$ 296,914 EFC:$ 1,212,870 MW: 9.2 VISC: 61 PV/YP: 20/18 APIWL: 8.5 DRILLING @ 4892' Drilling from 818' to 4247'. 81,902 CUM'$ 291,686 ETD:$ 508,039 EFC:$ 1,083,647 MW: 9.4 VISC: 47 PV/YP: 19/15 APIWL: 6.8 POH TO RUN CASING Drilling from 4247' to 4429' Gas and oil cut mud to surface. Circ out. Check flow. OK. Drilling from 4429' to 6318' 71,64~ CUM:$ 363,334 ETD:$ 676,808 EFC:$ 986,526 MW: 9.5 VISC: 43 PV/YP: 12/11 APIWL: 7.0 MU BHA Held prejob safety meeting. RIH with 7-5/8" casing to 6308'. Pump cement. 214,351 CUM:$ 577,685 ETD:$ 676,808 EFC:$ 1,200,877 MW: 8.4 VISC: 42 PV/YP: 9/12 APIWL: 13.4 DRILLING Test BOPE to 300-3000 psi. Drill out cement and ES cementer. Drill out cement to 6162' Drill out cement, float equipment and 20' new formation to 6338'. Perform LOT, 12.2 EMW. Drilling from 6338' to 6566'. 120,436 CUM:$ 698,121 ETD:$ 716,732 EFC:$ 1,281,389 MW: 9.2 VISC: 48 PV/YP: 19/21 PREP FOR WIPER TRIP Drilling from 6566' to 9101' 79,570 CUM'$ 777,691 ETD:$ 1,124,826 EFC:$ AP IWL: 5.8 952,865 Date: 5/2/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 03/26/97 (D9} TD:10006' (905) SUPV: DCL DAILY: $ MW: 10.6 VISC: 56 PV/YP: 23/24 APIWL: 4.6 DRILLING Drilling from 9101' to 9711'. Performed open hole FIT, 11.6 EMW at TD. OK. Drilling from 9711' to 10,006' 88,469 CUM:$ 866,160 ETD:$ 1,270,517 EFC:~ 895,643 03/27/97 (D10) TD:10400' (394) SUPV:DCL DAILY: $ MW: 10.6 VISC: 56 PV/YP: 24/26 APIWL: 4.4 RIH W/5.5 CASING Drilling from 10006' to 10,400'. Held pre-job safety meeting. RIH w/4.5" & 5.5" casing. 75,239 CUM:$ 941,399 ETD:$ 1,271,000 EFC:$ 970,399 03/28/97 (Dll) TD:10400' ( 0) SUPV: DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIH W/3.5" COMPLETION RIH w/5.5" casing to 10390' Pump cement. Freeze protect 7-5/8" x 5.5" annulus. 121,335 CUM:$ 1,062,734 ETD'$ 1,271,000 EFC'$ 1,091,734 03/29/97 (D12) TD:10400' ( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED RIH w/3.5" completion assembly. Release rig @ 21:30 hrs. 3/29/97. 175,391 CUM:$ 1,238,125 ETD:$ 1,271,000 EFC:$ 1,267,125 End of WellSummary for Well:AK8717 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(30-20(W4-6)) WELL JOB SCOPE 30-20 FRAC, FRAC SUPPORT DATE DAILYWORK 04/12/97 INITIAL PERFORATIONS DAY OPERATION COMPLETE [ SUCCESSFUL 1 YES ] YES Initial Tbg Press ] Final Tbg Press ] Initial Inner Ann 0 PSI[ 375 PSII 0 PSI DAILY SUMMARY JOB NUMBER 0408971021.3 UNYF NUMBER KEY PERSON SUPERVIS OR SWS-BAILEY BLACK/BRADLEY Final Inner Ann [ Initial Outer Ann ] Final Outer Ann 375 PSI'[ 0 PSII 0 PSI PERFORATE FROM 10116' - 10131' W/2-1/8" ENF_.RJE~ GUNS, 4 SPF, +/- 90 DEGREES FROM LOW SIDE. UNABLE TO GET SLTJ THRU 2- 7/8" GLM'S. TIME LOG ENTRY 07:30 MIRU SWS E-LINE UNIT. HELD SAFETY MEETING. PT TO 3000g. 08:45 RIH W/2-1/8" WT BAR, CCL, GR. TIE INTO SPERRY MWD LOG DATED 3/27/97. LOG FROM 10288' (PBTD) TO 9370'. POOH. 11:15 RIH W/CCL, SLTJ. UNABLE TO PASS FIRST GAS LIFT MANDREL AT 3372'. POOH AND ADD WT BAR. STILL UNABLE TO PASS BY 3372'. POOH. 14:00 RIH W/CCL, MI'D, WT BAR, GUN #1: 2-1/8" ENERJET, BIG HOLE CHARGES, 2 SPF, ORIENTED AT +90 DEGREES FROM LOW SIDE. TIED INTO GR/CCL LOG RAN ABOVE THAT WAS CORRELATED TO MWD LOG DATED 3/27/97. PRESSURE UP TUBING TO 1000g (CALCULATED 200g OVERBALANCE). PERFORATE FROM 10116' - 10131'. WHP CAME UP TO 1050 AND THEN BEGAN DROPPING. POOH. TUBING PRESSURE WHEN OUT OF HOLE = 700g. ASF. 16:45 RIH W/GUN #2 AS ABOVE. TIE IN. TUBING PRESSURE = 700g. PERFORATE SAME INTERVAL ORIENTED -90 DEGREES FROM LOW SIDE (2 RUNS AT 2 SPF = 4 SPF TOTAL AT 180 DEGREE PHASE). WHP CONSTANT AT 700g. POOH. WHP WHEN OUT OF HOLE = 375g. ASF. 18:00 BEGIN RD SWS. 19:00 SWS RIGGED DOWN. TURNED WELL OVER TO DSO TO BE LEFT SI PENDING S/L. SPEF -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KRU / 30-20 500292275000 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 9/97 DATE OF SURVEY: 032797 MWD SURVEY JOB NUMBER: AK-MM-70071 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA, INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL D I RE CT I ON RE CTANGULAR COORD I NATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -64.00 121.00 121.00 57.00 268.00 267.99 203.99 374.98 374.89 310.89 462.52 462.07 398.07 0 0 0 0 0 45 3 33 6 41 N .00 E .00 .00N .00E .00 N .00 E .00 .00N .00E .00 N 58.00 E .51 .51N .82E .12 N 79.96 E 2.69 1.46N 4.68E 1.82 N 89.11 E 3.70 2.01N 12.47E 6.30 560.79 559.38 495.38 651.25 648.51 584.51 742.55 737.90 673.90 835.27 827.85 763.85 927.12 915.95 851.95 9 9. 10 35 12 55 15 10 17 41 S 86.98 E 2.56 1.69N 26.01E 15.09 S 72.30 E 3.19 1.22S 41.12E 26.88 S 60.71 E 3.63 8.77S 58.03E 43.41 S 51.54 E 3.40 21.39S 76.58E 64.90 S 44.66 E 3.46 38.80S 95.80E 90.54 1018.44 1002.20 938.20 1110.98 1087.94 1023.94 1202.42 1171.06 1107.06 1296.64 1256.02 1192.02 1390.80 1340.56 1276.56 20 37 23 35 25 36 25 37 26 37 S 43.94 E 3.23 60.25S 116.72E 120.38 S 38.66 E 3.85 86.46S 139.61E 155.15 S 38.83 E 2.21 116.14S 163.43E 193.21 S 38.33 E .23 147.98S 188.83E 233.94 S 37.84 E 1.09 180.61S 214.40E 275.39 1484.66 1424.11 1360.11 1578.04 1506.03 1442.03 1670.54 1585.05 1521.05 1764.62 1663.04 1599.04 1857.52 1737.69 1673.69 27 36 29 44 32 52 35 7 37 54 S 38.37 E 1.08 214.27S 240.79E 318.15 S 38.47 E 2.29 249.36S 268.63E 362.94 S 40.71 E 3.61 286.36S 299.28E 410.99 S 41.93 E 2.50 325.85S 334.02E 463.54 S 43.08 E 3.09 366.58S 371.38E 518.71 1951.47 1809.72 1745.72 2045.15 1877.73 1813.73 2140.11 1943.86 1879.86 2233.14 2006.32 1942.32 2326.76 2065.82 2001.82 41 57 44 57 46 45 48 51 52 13 S 44.32 E 4.38 410.15S 413.05E 578.80 S 42.84 E 3.38 456.83S 457.44E 643.02 S 42.36 E 1.94 506.98S 503.55E 711.03 S 42.46 E 2.26 557.86S 550.03E 779.83 S 41.58 E 3.66 611.56S 598.40E 852.01 2420.34 2122.05 2058.05 2515.05 2175.87 2111.87 2608.43 2224.50 2160.50 2702.51 2269.43 2205.43 2975.94 2401.14 2337.14 53 56 60 62 59 54 49 23 32 5O S 40.54 E 2.00 667.96S 647.51E 926.75 S 39.87 E 3.15 727.47S 697.80E 1004.65 S 40.99 E 3.95 788.13S 749.50E 1084.33 S 41.70 E 2.39 850.16S 804.10E 1166.91 S 42.32 E 1.01 1028.19S 964.43E 1406.18 3253.86 2542.16 2478.16 3528.39 2684.13 2620.13 3805.01 2821.63 2757.63 4167.17 3001.67 2937.67 4446.81 3153.46 3089.46 59 10 58 32 61 50 58 31 55 43 S 39.20 E 1.00 1209.55S 1120.78E 1645.54 S 38.38 E .35 1392.69S 1267.98E 1880.50 S 37.16 E 1.25 1582.41S 1414.94E 2120.41 S 37.85 E .93 1831.67S 1606.19E 2434.46 S 35.54 E 1.22 2019.90S 1746.56E 2669.06 ORIGINAL dUN lq 1997 Alask8 r~t & Gas ,,;oDs, Anchora§e SPEK -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KRU / 30-20 500292275000 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 9/97 DATE OF SURVEY: 032797 MWD SURVEY JOB NUMBER: AK-MM-70071 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA, INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATE DEGREES DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. 4817.17 3351.60 3287.60 5096.49 3498.13 3434.13 5375.72 3645.48 3581.48 5654.91 3792.48 3728.48 5922.82 3931.81 3867.81 59 34 57 8 59 9 57 17 60 1 S 36.04 E 1.05 2273.63S 1929.53E S 38.69 E 1.19 2462.63S 2073.76E S 39.40 E .75 2646.79S 2223.15E S 40.03 E .69 2829.35S 2374.77E S 41.16 E 1.08 3003.06S 2523.68E 2981.36 3219.00 3456.13 3693.43 3922.14 6235.92 4092.51 4028.51 6489.80 4222.78 4158.78 6674.82 4310.67 4246.67 6856.73 4397.96 4333.96 7045.50 4497.34 4433.34 58 13 60 1 63 15 59 23 57 4 S 37.78 E 1.09 3210.40S 2694.51E S 36.54 E .82 3384.04S 2826.09E S 37.40 E 1.79 3514.09S 2924.01E S 36.34 E 2.18 3641.72S 3019.76E S 38.64 E 1.60 3769.07S 3117.40E 4190.80 4408.53 4571.20 4730.64 4891.04 7231.43 4595.43 4531.43 7419.20 4695.80 4631.80 7599.76 4794.63 4730.63 7786.05 4897.49 4833.49 7971.12 4998.00 4934.00 59 13 56 9 57 28 55 30 58 41 S 38.99 E 1.16 3892.10S 3216.38E S 39.39 E 1.64 4015.08S 3316.63E S 39.27 E .73 4131.96S 3412.39E S 36.57 E 1.60 4254.44S 3507.86E S 37.35 E 1.75 4378.57S 3601.29E 5048.95 5207.62 5358.71 5513.97 5669.23 8151.17 5093.59 5029.59 8246.00 5144.15 5080.15 8339.42 5194.13 5130.13 8430.96 5245.67 5181.67 8520.78 5299.07 5235.07 57 10 58 23 56 55 54 31 52 30 S 38.03 E .90 4499.30S 3694.56E S 37.70 E 1.32 4562.64S 3743.80E S 38.83 E 1.88 4624.60S 3792.67E S 39.64 E 2.72 4683.18S 3840.49E S 39.28 E 2.26 4738.92S 3886.38E 5821.74 5901.95 5980.85 6056.47 6128.68 8614.70 5357.28 5293.28 8707.23 5417.05 5353.05 8800.23 5479.67 5415.67 8892.59 5544.22 5480.22 8986.72 5612.32 5548.32 50 53 48 37 46 42 44 35 42 41 S 39.44 E 1.73 4795.91S 3933.12E S 39.88 E 2.48 4850.27S 3978.18E S 39.11 E 2.14 4903.31S 4021.91E S 39.28 E 2.29 4954.49S 4063.64E S 37.41 E 2.45 5005.42S 4i03.95E 6202.37 6272.98 6341.72 6407.76 6472.70 9081.16 5682.79 5618.79 9172.81 5753.21 5689.21 9265.30 5826.49 5762.49 9358.81 5902.97 5838.97 9449.50 5979.29 5915.29 40 46 38 47 36 21 33 50 31 31 S 34.96 E 2.67 5056.12S 4141.07E S 35.39 E 2.17 5104.05S 4174.84E S 35.88 E 2.66 5149.89S 4207.70E S 35.81 E 2.68 5193.47S 4239.18E S 34.95 E 2.62 5233.38S 4267.54E 6535.46 6593.96 6650.25 6703.92 6752.78 9541.55 6058.75 5994.75 9632.51 6139.35 6075.35 9817.72 6307.59 6243.59 10001.06 6475.10 6411.10 10188.44 6644.68 6580.68 29 6 26 4 23 21 24 36 25 44 S 33.19 E 2.79 5271.85S 4293.58E S 31.81 E 3.41 5307.36S 4316.24E S 31.62 E 1.47 5373.21S 4356.94E S 29.14 E .88 5437.48S 4394.57E S 28.51 E .62 5507.30S 4432.98E 6799.06 6840.90 6917.68 6991.28 7069.69 SPE~ -SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. KRU / 30-20 500292275000 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 9/97 DATE OF SURVEY: 032797 MWD SURVEY JOB NUMBER: AK-MM-70071 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA, INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10323.65 6766.69 6702.69 25 18 S 27.49 E .45 10400.00 6835.72 6771.72 25 18 S 27.49 E .00 5558.74S 4460.34E 7126.86 5587.69S 4475.40E 7158.83 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7159.02 FEET AT SOUTH 38 DEG. 41 MIN. EAST AT MD = 10400 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 140.89 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 10,400.00' MD SPE~ ~SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KRU / 30-20 500292275000 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 9/97 DATE OF SURVEY: 032797 JOB NUMBER: AK-MM-70071 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA, 64.00 FT. INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -64.00 .00 N .00 E 1000.00 984.91 920.91 55.64 S 112.27 E 2000.00 1845.37 1781.37 433.86 S 435.89 E 3000.00 2413.24 2349.24 1043.60 S 978.40 E 4000.00 2916.31 2852.31 1717.93 S 1518.32 E .00 15.09 15.09 154.63 139.54 586.76 432.13 1083.69 496.93 5000.00 3446.37 3382.37 2398.66 S 2023.38 E 6000.00 3970.64 3906.64 3053.59 S 2567.22 E 7000.00 4472.79 4408.79 3739.02 S 3093.62 E 8000.00 5013.01 4949.01 4398.19 S 3616.26 E 9000.00 5622.08 5558.08 5012.57 S 4109.42 E 1553.63 469.94 2029.36 475.73 2527.21 497.85 2986.99 459.78 3377.92 390.93 10000.00 6474.14 6410.14 5437.10 S 4394.35 E 10400.00 6835.72 6771.72 5587.69 S 4475.40 E 3525.86 147.94 3564.28 38.42 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPER -SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA INC. KRU / 30-20 500292275000 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 9/97 DATE OF SURVEY: 032797 JOB NUMBER: AK-MM-70071 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA, INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .0 64.00 64.0 164.00 164.0 264.01 264.0 364.07 364.0 -64.00 .00 N .00 E .00 .00 .00 N .00 E .00 100.00 .00 N .00 E .00 200.00 .48 N .78 E .01 300.00 1.34 N 4.06 E .07 .00 .00 .01 .07 464.47 464.00 565.48 564.00 667.02 664.00 769.37 764.00 872.82 864.00 400.00 2.02 N 12.69 E .47 500.00 1.62 N 26.76 E 1.48 600.00 2.20 S 43.92 E 3.02 700.00 11.94 S 63.30 E 5.37 800.00 27.94 S 84.35 E 8.82 .39 1.01 1.55 2.35 3.45 977.80 964.00 1084.95 1064.00 1194.59 1164.00 1305.49 1264.00 1417.01 1364.00 900.00 50.29 S 107.07 E 13.80 10.00.00 78.56 S 133.12 E 20.95 1100.00 113.50 S 161.31 E 30.59 1200.00 150.98 S 191.20 E 41.49 1300.00 189.89 S 221.60 E 53.01 4.97 7.16 9.63 10.90 11.53 1529.76 1464.00 1645.61 1564.00 1765.81 1664.00 1891.23 1764.00 2025.88 1864.00 1400.00 230.75 S 253.85 E 65.76 1500.00 276.19 S 290.63 E 81.61 1600.00 326.36 S 334.49 E 101.81 1700.00 381.91 S 385.84 E 127.23 1800.00 446.94 S 448.21 E 161.88 12.74 15.85 20.20 25.42 34.65 2169.51 1964.00 2323.81 2064.00 2493.58 2164.00 2690.73 2264.00 2901.15 2364.00 1900.00 522.81 S 517.98 E 205.51 2000.00 609.82 S 596.85 E 259.81 2100.00 713.75 S 686.31 E 329.58 2200.00 842.36 S 797.14 E 426.73 2300.00 980.13 S 920.80 E 537.15 43.63 54.30 69.77 97.15 110.42 3100.50 2464.00 3296.48 2564.00 3489.82 2664.00 3685.68 2764.00 3893.61 2864.00 2400.00 1108.58 S 1035.86 E 636.50 2500.00 1237.92 S 1143.92 E 732.48 2600.00 1366.90 S 1247.56 E 825.82 2700.00 1499.42 S 1351.44 E 921.68 2800.00 1644.36 S 1462.03 E 1029.61 99.35 95.98 93.34 95.85 107.94 4094.31 2964.00 4284.58 3064.00 4465.58 3164.00 4648.55 3264.00 4841.58 3364.00 2900.00 1782.37 S 1567.98 E 1130.31 3000.00 1910.73 S 1666.58 E 1220.58 3100.00 2032.53 S 1755.59 E 1301.58 3200.00 2156.97 S 1844.99 E 1384.55 3300.00 2290.60 S 1941.93 E 1477.58 100.69 90.27 81.00 82.98 93.02 SPER SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KRU / 30-20 500292275000 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/ 9/97 DATE OF SURVEY: 032797 JOB NUMBER: AK-MM-70071 KELLY BUSHING ELEV. = OPERATOR: ARCO ALASKA, 64.00 FT. INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5033.10 3464.00 3400.00 2420.76 S 2040.60 E 1569.10 91.52 5217.88 3564.00 3500.00 2542.22 S 2137.50 E 1653.88 84.78 5411.83 3664.00 3600.00 2670.75 S 2242.83 E 1747.83 93.95 5602.20 3764.00 3700.00 2795'.38 S 2346.24 E 1838.20 90.36 5789.83 3864.00 3800.00 2916.57 S 2448.80 E 1925.83 87.64 5986.86 3964.00 3900.00 3044.96 S 2559.86 E 2022.86 97.03 6181.53 4064.00 4000.00 3173.95 S 2665.94 E 2117.53 94.67 6372.23 4164.00~ 4100.00 3302.25 S 2765.45 E 2208.23 90.70 6574.20 4264.00 4200.00 3443.06 S 2870.15 E 2310.20 101.97 6788.55 4364.00 4300.00 3594.22 S 2984.56 E 2424.55 114.35 6983.52 4464.00 4400.00 3728.03 S 3085.05 E 2519.52 94.97 7170.00 4564.00 45-00.00 3851.08 S 3183.17 E 2606.00 86.48 7361.39 4664.00 4600.00 3977.74 S 3286.04 E 2697.39 91.39 7542.79 4764.00 4700.00 4094.77 S 3381.99 E 2778.79 81.40 7726.43 4864.00 4800.00 4215.05 S 3478.16 E 2862.43 83.64 7906.73 4964.00 4900.00 4335.03 S 3568.22 E 2942.73 80.30 8096.59 5064.00 5000.00 4463.17 S 3666.30 E 3032.59 89.86 8283.81 5164.00 5100.00 4588.09 S 3763.50 E 3119.81 87.23 8462.51 5264.00 5200.00 4702.95 S 3856.87 E 3198.51 78.69 8625.36 5364.00 5300.00 4802.29 S 3938.37 E 3261.36 62.85 8777.38 5464.00 5400.00 4890.40 S 4011.41 E 3313.38 52.02 8920.38 5564.00 5500.00 4969.59 S 4075.99 E 3356.38 43.00 9056.35 5664.00 5600.00 5042.84 S 4131.78 E 3392.35 35.97 9186.65 5764.00 5700.00 5111.12 S 4179.87 E 3422.65 30.31 9311.73 5864.00 5800.00 5172.06 S 4223.73 E 3447.73 25.08 9431.57 5964.00 5900.00 5225.70 S 4262.17 E 3467.57 19.84 9547.54 6064.00 6000.00 5274.27 S 4295.15 E 3483.54 15.98 9659.90 6164.00 6100.00 5317.52 S 4322.53 E 3495.90 12.36 9770.11 6264.00 6200.00 5356.91 S 4346.89 E 3506.11 10.21 9879.16 6364.00 6300.00 5393.95 S 4369.71 E 3515.16 9.05 9988.85 6464.00 6400.00 5433.04 S 4392.09 E 3524.85 9.69 10098.88 6564.00 6500.00 5473.14 S 4414.42 E 3534.88 10.03 10209.89 6664.00 6600.00 5515.48 S 4437.43 E 3545.89 11.01 10320.67 6764.00 6700.00 5557.61 S 4459.75 E 3556.67 10.78 10400.00 6835.71 6771.71 5587.69 S 4475.40 E 3564.29 7.62 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS " " SURVEY CALCULATI°N ~ Job No. _0.4__5_0_-..84__26__~2 .... Sidetrack No.. ............. Page ...... 1____ of 3 I~,~[~.~ Company _A__R__C.~.~_S___K~._,....!_N_~:- ............................................................. Rig Contractor & No. P_A_R_K__E.R__D__R_I.L__L_IN_G,CO -_#__2_4_5_ ......................... Field _K_UP___~A.R_U__K._._R_I_..VE_.R__.U_NIT ............................... lJ~~~ Well Name & No. 30:PAD_/3.0.:~2.0.., Survey Section Name _S_ _P_ .E. R_ . .R .Y_ _S U N .............................. BHI, Rep. WELL DATA TargetTVD .................................... _(.F_~ ......................... Target Coord. N/S ............................... SlotCoord. N/S ..... -~96_2_.__00 ....... Grid Correction ........ _0.000_ .............. Depths Measured From: RKB~! MSL['iiI SS!"j Target Dcscription ....................................... Target Coord. E,qN Slot Coord. E/W 1979.00 Magn. Declination 27,970 Calculation Method MINIMUM CURVATURE Target Direction (DM) Build\Walk\DL per: lOOft~ 30m~ 1Omo Vert. Sec. Azim. 140.89 Magn. to Map Corr. 27.970 Map North to: OTHER SURVEY DATA Ii ~urvey~' I '[, ........ ' Total Coordinate I Build Rate ! Walk Rate T _ , . t Su~'ey i Incl. Hole Course Vertical Date _T°°l I Depth Angle I Direction i Length 'rVD ..... U(~)'i'~i:)'"-I I~i~'i'"jW()' DL Build(+) Right(+) ! Comment ...................... ..!_..Y.P__.e_.._J _.. (FT) (OD> ~L (DB) (F-T) t Section o.oo o.oo ~i; .............. ¥.6b- ........................................................................ ' ....................................................... T,E ,N PO~N'r ) ,'E0-:-~i~i:iFr- ~______.._~___.._.._,___:__~._.__:..._...~ .....-' - ~ 1 -O~ ..... ~-~'~'7(5~-I .... ~)'~3~--1- ...... --6'.-~-0-- --1~- oo 121.00 0.00 0.00 0,00 0.00 0.00 18"MAC, 1C-AKO-1.4deg. MWD I 374 98 3 56 79 96 106 98 -~/;.-~ ............. ~..~2- ................. ;"'74'~'-I' ................. ',~'~ ............ '~-~' .......... ~7(~ ......................................................................................................................... :,~:.M...A._~.:.,..~ ......................... 1 ................. : .......... , ........... : .......................... : ................ : .......................... : ................................ : ........................ '-. .................. : .... ' ' : 20-MAR-97 MWD{ 462.52 I 6.70 89.11: 87.54 462.07 6.301 2.01] 1~,~,~'- i .... ~1'77~ ................. -~ .............. -~"~i'~5- .......................................................................20-MAR-97 MWD-~-- 560.79 9,16I 93.02 --- .............................. 98.27 559.39 15.10 J .................... 1.69 t----- 26.01 I .................................................................................................................................................. 2.56 2.50 3.98 :20-MAR-97 MWD 651.25 10.59 [ 107,70 I 90.46 648.53 26,88 -1.22 ............ 4.!...1_.2 ........ _3_.1_9_ 1.58 .............. 1.6_._2_.3 ;'~-(~':~li~:;~ ........ -[~i'~)- ....... -~i'~'.ii .... i"~-i~i"-~ ..... -~-~:'~-'i----~-1~-~ .......... ~-i~".~"-,1- ........ ~-3-7i; .... -8.77 58.03 3.63 2.56 12.69 ...................................................................................... b ....................................... i ..................................................................................................... ~21-MAR-97 MWD ] 835.27 I 15,17 ! 128.461 92,72 827.87 { 64.91 -21.39; 76.58 3.40 2.42 9,89 ................................ ...................................... .............. ............................ ..... 21-MAR-97 MWD 927.12 17.69 ~ 135.34 . 91.85 915.97 [ 90.54 -38.80/ 95.80 3.46 2.74 7.49 ............................... }' .......................................... ~' 21-MAR-97, MWDi 1018.44., 20.63 I 136.06 91.32 1002.22 / 120.38 -60.25 116.72 3.29 3.22 0.79 7 ......................................................... ' - ' ' ' ' ~ ' ~ ' ' ' ' ~ ....... ;'~i~.-~ .......... iSL~7 ...................'~; :G~:~;:TI---G~821-MAR-97 ~- MWD ................................... .... -i-i~Tg'/-i'~-~'i=-'"112°2'42_~t .................................... 25.61 ! ..... 1'-~1.6~-'--~--'141'17 + ........................................ 91.44-;~iSi"~,-~'"'°' .... ,i ..................... ~;~-~-.9-~--199'22 7~T87~6'(~-~-i ]-~- ...... ~-5--' --~3--[----- o~i"~---I ........ ............. -~85~-~-/~i~_~ ............................................................... ............................................ " 2-1-:~A'R:~;~'-I-~''1 --1-i~::~if-'l'--iiii~'-'i ....... ;';,~;7;-~;--~ ...... -~; ...... ~iT, i:i~ .......... ~-~i.~- 7~ii;5:;~7 ',r-- ...... i4;,;i8 ...... .1-i~ ........... ;-.~ii' ......... ;55;~_T ...................... 21-MAR-97 '~ .............. MWD l} ................... 1484.66 [, .................................. 27.60 141.63 : ............................................................. 93.86 1424.14 318.16 -214.27 Jr ........................................................................................................... 240.80 '1.08 1.04 -0.56 ~- ................ .......................... .............................. ' .............................................. ......... ............. ...... ..................................................... 21-MAR-971 MWD, 1578.04129.74 141.53j 93.38 1506.07 362.95 .................................................. } ....... :_ I .... -" ........ " ............... '-- 35,19-I 138.07 94.08 1663.09 ~ 463.56 -325.86 334.03 2.50 2.39 -1.30 ................ -.4- ........................ : ...... t .................... ~ .......... 4-- _21-MAR-9~_ MWD 1857.52 37.91 I 136.92 92.90 1737.75 ~_ 518.73 -366.59 371.39 3.09 3.00 -1.24 ~ --I~,'~5~'/ ~- ~1-~.'~-~ 7~5~ 1---~:~-~ -~-.~-~ 1~4~31~ '~' ~.-~ -507.00 503.57 1.94 1.91 0.51 'i-;'TM;~:iF,-j-''~,-~; ...... -~;;i-~5:i ...... ii~Si-i~ ........... -i.-iifl ................................. 54 93.03 2006.39 779.86 -557.89 550.05 2.26 2.26 -0.11 m i iiiii i ~ i SURVEY CALCULATION AND FIELD WORKSHEET Job No. S detrack No. age Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNI'f' Well Name & No. 30-PAD/30-#20 Survey Section Name SPERRY SUN BHI Rep. ____ _~I~ _ .,; , ....... 7- .......... Target'[VD (FT) Target Coord. N/S Slot Coord. N/S -962.00 Grid Correction 0.000 Depths Measured From: RKB '1 Target DescriptiOn Target Coord. E/W Slot Coord. E/W 1979.00 Magn. Declination 27.970 Calculation Method MINIMUM CURVATURE · Target Direction (DE)) Build\Walk\DL per: lOOftI~[ 30m[-j lOm~ Vert, Sec. Azim. 140.89 Uagn. to Map Corr. 27.970 Map North to: OTHER Sur~ey Date Tool Type 21 -MAR-97 21 -MAR-97 21-MAR-97 21-MAR-97 MWD 21-MAR-97 21 -MAR-97 21-MAR-97 21-MAR-97 21-MAR-97 21 -MAR-97 22-MAR-97 22-MAR-97 22-MAR-97 22-MAR-97 5375.72 22-MAR-97 5654.91 5922.82 SURVEY DATA Survey Hole Course Vertical Depth Direction Length 'I'VD Section (F~ (DD) (DD} (FI-) (FT) 2326.76 138.42 93.62 2065.88 852.04 2420.34 139.46 93.58 2122.12 926.79 2515.05 i 56.83 140.13 94.71 2175.94 1004.69 2608.43 139.01 93.38 2224.57 1084.37 2702.51 138.30 94.08 2269.50 1166.96 2975.94 137.68 273.43 2401.22 1406.23 Total Coordinate N(+) / S(-) E(+) / W(-) (FO (FO -611.59 598.42 -667.98 647.54 -727.50 697.83 -788,15 749.53 -850,20 804.13 -1028,23 964,46 -1209,59 1120,82 22-MAR-97 MWD 25-MAR-e7 --~/D--' 25-MAR-97 25-MAR-97 25-MAR-97 25-MAR-97 25-MAR-97 3253.86159.18I 140.80 277.92 3528.39 ,'-~'~:~5~---!' ..... i-4-~.'~-;~ ......... ~-¢~.-~- --- 3805.01 [_61.84 I 41e7.1 i I 2542.24 1645.59 2684.21 1880.55 142,84 276,62 2821.71 2120.46 142,15 362.16 3001.75 2434.52 -1392.73 1268.02 -1582.451 1414.97 'i' -1831.71 1606.23 -2019,94 T 1746,60 4446,81 279.64 3153,54 2669,12 4817,17 370.36 3351.68 2981,41 -2273,67 1929.56 5098.49 3498,21 3219.05 -2462,67 2073,80 144,46 143,96 141.31 279.32 59.15 140.60 279.23 3645.58 3456.21 57.30 ! 139.97 279.19 3792,59 3693.53 60,02 138,84 267.91 3931.92 3922.25 142.22 313.10 4092.62 4190.90 6235.92 143.46 253.88 4222.90 4408.66 142.60 185.02 4310.79 4571.33 143.66 181.91 4398,08 4730,77 141.36 188.77 4497,46 4891.17 141.01 185.93 4595.57 5049.10 140.61 187.77 4695.93 5207,77 140.73 180.56 4794,77 5358.86 6489,80 6674.82 6856,73 7045.50 7231.43 7419.20 7599.76 -2646.85 -2829.43 -3003.14 -3210.48 2223.20 2374.84 2523.74 2694.58 -3384.14 2826.18 -3514.19 2924.09 -3641.82 3019.85 -3769.16 3117.48 -3892.21 3216.47 -4015.20 3316.73 -4132.07 3412.49 Build Rate Walk Rate I Build (+) Right (+) Comment Drop (-) Left (-) 3.59 0.94 1.80 1.11 3.09 0.71 3,81 -1.20 2.30 -0.75 -0.99 -0.23 -0.24 1.12 -0.23 0.30 8"MACH 1C-AKO-1,2 DEG. 1.19 0,44 -0.91 -0.19 -1.00 0.83 1.04 -0.14 -0,87 -0.95 '" ...... ~L.~;': ~ ......................... -0.66 -0.23 ~ .................. ~¢= ........................... 1.02 -0.42 :~{ ~;~ ......... ~,~. -0.57 ~ 1.08 TD 631~D 4136'~D , ... 0.71 0.49 4 3/4"MACH 1XL-AKO-1.2 DEG. 1.75 -0.46 -2.12 0.58 -1.22 -1.22 1.15 -0.19 -1.63 -0,21 0,73 0.07 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0_4__50_-.84__2_6__2. .... Sidetrack No.. ............... Page __3_ ..... of .... .3. ..... Company :~,.R.~.?__..~:_L~.S.,_KA_..!,_N_?_: Rig Contractor & No. __P,_A..~E.R ._D,R_~I_L_.L_[~_G;_C.O_..-_?_..2.4_.,_5. ....................................... Field .K_U_..P_A_R_..UK~..R!.V__E__R.__U..N_.!_T, Well Name & No. 30tPAD/30;.#2.o' survey Section Name SPERRY SUN BHI Rep.. .................................................... WELL DATA Target TVD ............................ _(E~_ ......................... Target Coord. N/S ................................................. Slot Coord. N/S ............. 7.9_6_2:..0_0. ...... Grid Correction .......... _o..:..o..o_o_ ................ Depths Measured From: RKB ~'J MSL ri'! ssi-' Target Dcscription ................................................ Target Coord. E/W .................................. Slot Coord. E/W ..... _19__7..9.:_0.0__ .......... Magn. Declination ...... _2_7,9___7_0 .......... Calculation Method _M!_N..!_M_U_U_M__C_U.R__VA_T__.U..FI....E_ Target Direction ....................... (___D.9)_- ...... Suild\Walk\DL per: lOOftE~ 30mE'] lOmL~ Vert. Sec. Azim. 140.89 Magn. to Map Corr. 27.970 Map North to: OTHER ........................... SURVEY DATA ......................... T,~-'--- T f ....... '~ ............. ' ................................. urvey ' Survey I Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section ~(+i']'~(:i .......... ~i'~i"/W(:)" DL Build (+) Right (+) Comment Type (F-r) (OD) I .... ._(_D_D) ......... (_F_-~)_. .......... (.__~_ ........ (FT) (FT) (Per 100 FT)_. Drop (-) Left (-) _.~%~_?Z__~_vw_ ..... ~%o.%...2~:%_J. ~,~.~ ~.~ ~.~. ~,.~ -~,.~ ~o~.~ ~.~o ......... ¥:~- ............ ;'::;;~;'-':~-~-~,:~i~E~-';';~-~_-:;~-~:;"7~;-~7~': ............... 1' 125-MAR-97 MWD I 7971.12 58.69 142.65 '"-~-~7 4998.14 5669.38 -4378.69 3601.39 1.75 1.72 -0.42 i'~1'~9~"'~L'~'~-~-1"--'~-~;i-~ ...... ~5-~i~'-I141.97 I 180.05 5093.74 5821.91 -4499.43 3694.67 0.90 -0.84 .................. -0.38 +1 .......................................................................... .............................25-MAR-97 MWD -t .... 8246.00 ~-.-,~9- t 142.30 .................................................... 94.83 5144.30 5902.11 -4562,76 3743.91 1.32 1.29 0.35 l ........................................................ ......................................................................................................................................................................................... 25-MAR-97 MWD 8339.42 56.92 141.17 93.42 5194.28 5981.02 -4624.73 3792.78 1.88 .............................. i'~ ~5'--M--~-I~: ~ ...... ~TV~-'"/ 8430.96 ~i~ ....... -~- ....... ;i~ ...... ~'~:'~ ..... 6056.66 -4683.32 3840.61 2.72 -2.62 ......... ~0~8-~ .......................................................................... ~E'~I-A-R---~)~ ...... GW~ .... -~.;T"--7'--;~4~-.~"-'-~.;~ ...... ~2~;~4' 6128.87 -4739.07 3886.51 2.26 -2.24 0.40 ................................................................................................................................................................ !"~;~-~;~:~ ..... ~-'f'"'-'~-~'~'~';'~ ......... ~3'.-~;'"'; ........... -~-0'i~5-6' .......... ;;;~- ...... ~:~'~-~'""I 6202.57 -4796.06 3933.25 1.73 -1.72 -0.17 25-MAR-97 MWD 8707.23 48.62 ~ 140.12 92.53 5417.22 6273.19 -4850.43 3978,32 2.48 -2,45 -0.48 25-MAR-97 ..... [ MWD 8800.23 46.71 140.89 93.00 5479.85 I 6341.93 -4903.47 4022.04 2.14 -2.05 0.83 25-MAR-97 MWD 8892.59 44.60 1 ~ 140.72 92.36 5544.41 6407.98 -4954.66 4063.78 2.29 -2.28 -0.18 MWD 8986.72 42.69 I 142.59 ~_ 94.13 5612.52 6472.93 -5005.59 4104.10 ~.45 25-MAR-97 ...... i¥~.~4-/--~;,74;,- ......... ~;~:37~';"-i ..... ~;';%'E~ ....... ;~;~;~;i'~;--i ...... ;;;;;-~%~ ......... 27~- -2.o3i 1.99 I .......... .......................................................... .i,, ........................ ~ ................... r ................ '-_ , .......... '_' .... ;;~-~:~ ~'D--1-~,-~~ -'~i~T' ~-'~ '~o--~- ~9-~-~-t ~- 7~-~7E- ~;~:4~ -- :3.41 26-MAR-97 MWDqL ~ 9817.72 23:;~-_{, ~8.38 -1-~.~- 6307.'~4 ~9-~7.95 -5373.4~-- ~3-~-~; -- 1.47 ;1.47 0.10 MWD,-IO001.06_ ' 24.60'~ ~ 183.34- 6475.37 6991.56 -5437.69 4394.74 0.88 0.68 1.35 . -- : 27-MAR-97 MWD 10188.44 25.75 151.49 187.38 6644.95 7069.98 -5507.53 4433.16 0.63 0.61 0.34 27-MAR-97 MWD 10323.65 25.31 152.51 135.21 6766.96 7127.16 -5558.98 4460.52 0.46 -0.33 0.75 TD 6.75 HOLE @ 10400'6836'TVD -- 27-MAR-97 MWD 10400.00 25.31 152.51 76.35 6835.98 7159.13 -5587.93 4475.59 0.00 0.00 0.00 CLO.DIST=7159.41'AZI=141.31 DE i ill i i ii iiii i i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 962' FNL, 1979' FWL, Sec. 22, T13N, RgE, UM At top of productive interval 1085' FNL, 1062' FWL, Sec. 26, T13N, RgE, UM At effective depth 1249' FNL, 1152' FWL, Sec. 26, T13N, RgE, UM At total depth 1278' FNL, 1167' FWL, Sec. 26, T13N, RgE, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical I 0400 feet 6836 feet 1 0324 feet 6703 feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 64 7. unit or Property name Kuparuk River Unit 8. Well number 30-20 9. Permit number/approval number 97-045 10. APl number 50-029-22750-00 feet 11. Field/Pool Kuparuk River Field/Oil Pool None None ORIGINAL 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 6267' 7-5/8" 9992' 5.5" 359' 4.5" measured 10116'-10131' true vertical 6580'-6594' Cemented Measured depth Qty/Type unknown 410 Sx ASLW & 595 Sx Class G & AS I 180 Sx Class G II Tubing (size, grade, and measured depth) Mixed 2.875", 6.5#/ft. & 3.5", 9.3#/ft., L-80 @ 10012' Packers and SSSV (type and measured depth) Packer: Baker SBE @ 10012'; SSSV: None, nipple @ 499' Stimulation or cement squeeze summary Fracture Stimulate 'A' Sands on 4/16/97. Intervals treated (measured) 10116'-10131' Treatment description including volumes used and final pressure True vertical depth 121' 121' 63O8' 4130' 10031' 6502' 10390' 6827' dUi'.J 1 'i 199( Pumped 221.1 Mlbs 20/40,12/18, &10/14 ceramic proppant into formation, fp was 5200 psi Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1275 172 Subsequent to operation 631 3 0 4 10 1337 185 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. ~.by certify Form/O~-40~ ~v ~'~1b-7~ that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~ K1(30-20(W4-6)) WELL JOB SCOPE JOB NUMBER 30-20 FRAC, FRAC SUPPORT 0408971021.3 DATE DAILY WORK UNIT NUMBER 04/16/97 INITIAL "A" SANDS FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes O NoI (~ Yes O No DS-YOAKUM JOHNS , _,r"~ ESTIMATE -A448.-T-1-7~, ~ 230DS36OG $177,350 $192,157 Initial Tb.q Press Final Tb.q Press Initial Inner Ann Final Inner Ann IInitial OutelC"Ann I Final Ot;;~L~Ann 450 PSI 0 PSI 2500 PSI 1000 PSII 400 PSII 400 PSI DALLY SUMMARY I PUMPED INITIAL 'A' SANDS FRAC. 221,112# IN PERFS W/12#PPA 10/14 AT PERFS. TIME 11:00 11:45 13:30 13:35 13:40 14:39 16:35 17:25 17:30 18:17 18:27 18:30 18:32 LOG ENTRY MIRU FRAC EQUIP, LITTLE RED PUMP AND APC VAC. TRUCK. HELD ON SITE SAFETY MEETING. PRESSURE TEST TREATING LINE TO 9000 PSI. PUMPED BREAKDOWN STAGE , 120 BBLS AND 30 BPM 8323 PSI TO 4925 PSI. PUMPED SCOUR AND FLUSH STAGE 15 BPM AND 5167 PSI. SHUT DOWN FOR ISIP 1702 PSI AND PULSE TEST. PUMPED DATA FRAC AND FLUSHED, 5 TO 15 BPM AND SHUT DOWN FOR ISIP 1839. PUMPED 100 BBLS PAD , 5 TO 15 BPM 5432 PSI. PUMPED 200 BBLS 2 PPA STAGE 20/40 PROP. 15 BPM AND 4509 PSI. PUMPED 727 BBLS 6 PPA STAGE 12/18 PROP. 15 BPM AND 4366 PSI. PUMPED 150 BBLS 10 PPS 12/18 4856 PSI. PUMPED 37 BBLS 11 PPA 12/18 PUMPED 40 BBLS 12 PPA 10/14 PROP TO 5200 PSI PUMPED FLUSH TO 8 BBLS SHY OF COMPLETE, 40 BBLS DIESEL IN TUBING. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $40.00 APC $7,500.00 $9,375.00 ARCO $350.00 $350.00 DOWELL $167,000.00 $167,000.00 HALLIBURTON $0.00 $2,401.00 LR-FLE RED $2,500.00 $2,500.00 SCHLUMBERGER $0.00 $10,491.00 ,, TOTAL FIELD ESTIMATE $177,350.00 $192,157.00 June 9, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 30-20 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 30-20 Tie in point 0.00', interpolated depth at 10,400.00' Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company C! I::! i I--I-- I N G S I=: !=! ~/I I-- E S WELL LOG TRANSMITTAL To~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 30-20, AK-MM-70071 May 7, 1997 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ytrn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22750-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska May 7, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 30-20, AK-MM-70071 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 30-20: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22750-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22750-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 995i8 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 25, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 30-20 Dear Mr. Commissioner: Enclosed please find the LOT plot, cementing detail and the casing detail sheets for Kuparuk Well 30720c, These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad RECEIVED Anchora~ cc: Blair Wondzell CASING AND LEAK-OFF FRACTURE TESTS Well N~.me: Supervisor: K R U 30-20-17 Date: 3/24/97 Donald Lutrick 7 5/8", 29.7#, L-80, BTC Casing Size and Description: Casing Setting Depth: Mud Weight: 8.5 6308' TMD 4131' TVD PPg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD LOT = 800 psi/(0.052 x 4131 ft) + 8~5 ppg = 12.22 ppg Fluid Pumped = 1.36 bbls. Hole Depth (md)-- 6338' Pump output -- .085 bps 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 9O0 800 700 600 400 $00 200 100 0 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 STROKES CASING / TUBING / LINER DETAIL ARCO ALASKA / Subsidiary of Atlantic Richfield WELL: 30-20 DATE: 3/21/97 PAGE: 1 of 1 # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH 75/8" SURFACE CASING TOPS Above RKB -3.94 Landing Joint 45.53 -3.94 9 5/8", 40#, L-80 Fluted mandrel hanger 1.53 41.59 39 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 1678.52 43.12 C' Jt 7 5/8", 29.7#, L-80, BTc, R-3, Class A-BakerLocked 41.97 1721.64 Halliburton ES Cementer 2.47 1763.61 B' Jt 7 5/8", 29.7#, L-80, BTC, R-3, Class A-BakerLocked 42.65 1766.08 101 Jts 7 5/8% 29.7#, L-80, BTC, R-3, Class A 4324.74 1808.73 A' Jt 7 5/8", 29.7#, L-80, BTC, R-3, Class A-BakerLocked 43.55 6133.47 Halliburton Landing Collar 1.39 6177.02 1 Jts 7 5/8", 29.7#, L-80, BTC, R-3, Class A 43.31 6178.41 Gemoco 7 5/8" Float Collar 1.33 6221.72 2 Jts 7 5/8", 29.7#, L~80, BTC, R-3, Class ^ 83.45 6223.05 Gemoco 7 5/8" Float Shoe 1.50 6306.50 Shoe set @ 6308.00 ES Cementer and lock Jts (B & C)between jt #104 - #105 TD = 6318.00 PBTD = 6177.02 RATHOLE = 10.00 Parker 245 RKB to Wellhead =~ 41.27 FLUTED HANGER GOES IN TOP OF JT. #143 *'12 Jts (#144 -#155) stay in the shed **. BAKER-LOCK TO TOP OF BAFFLE COLLAR JT. National lead free mod. (BOL 2000) TORQUED TO BASE OF TRIANGLE (avg 9000 Ft-Lbs) RAN: 30 bow spring centralizers on jt #1 thru #30 2 bowspring centralizers on jt #B and #C RIG SUPER VISOR: Donald Lutrick ARCO Alaska, Inc. Cementing Details Well#: 30-20 Field: KUPARUK Date: 3/23/97 CasingSize7 5/8" HoleDiameter9.875. HoleAngle I ShoeDepth58° 6,318' Float Depth16,222' % wash°ut Centralizers State type used, intervals covered and spacing 32 Gemco centralizers. Jts # 1 - 31 and on either side of ES cementer Mud Weight YP(prior cond) YP(after cond) I PV(prior cond) PV(after cond) 9.8/9.5 19 lbs/100 ft2 11 lbs/100 ft21 24 cP 12cP Gels before Gels after Total Volume Circulated 5/7 4/5 762 bbls Spacer Type Volume Weight Water 40/20 8.3 PPG Lead Type IMix wtr temp No. of sacks Weight Yield Cement ASLW I 70 200/21 0 1 0.5/1 0.5 4.41 STAGE 1/2 Additives G + 3.5% DO44, .6% DO46, 30% D53, 1.5% DO79, 50% D124, 1.5% SOO1 Tail Cement STAG E 1/2 G/AS 1 70 530/65 15.8/15.8 1.15/0.93 STAGE 1' G, 2.66% DO29, .2% DO46, .3% DO65, 1.5% SOO1 STAGE 2: ASl Displacement Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 8 8 25O Reciprocation length 10 Reciprocation speed 10 fpm Actual Displacement 277/82 STAG E 1/2 Theoretical Displacement 276/81 Str. Wt. Dn. 140 Str. Wt. Mud Calculated top of cement I CIP 3/23/97 Bumped plug Floats held 1762'/surface12° :08/22'1 0 yes/yes yes/yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Stage 1- Reciprocated csg until cement rounded shoe. Had full returns through out job Stage 2: Opened ES cementer w/3100 psi. Circ out cement contaminated mud. :Had cement to surface w/ 164 bbls cement pumped. Switched to tail. Displaced w/ rig pumps. Closed cementer w/2000 psi. Floats OK Cement Company I Rig Contractor I Signature Dowell IParker I Donald Lutrick ALASKA OIL AND CiAS CONSERVATION COMMISSION March 14, 1997 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 30-20 ARCO Alaska, Inc. Permit No: 97-045 Sur. Loc.: 962'FNL, 1979'FWL, Sec. 22, T13N, R9E, UM Btmhole Loc: 1366'FNL, 1316'FWL, Sec. 26, T13N, R9E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This approval includes annular disposal of drilling wastes and is contingenent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records, FIT data, and any CQLs are to be submitted to the Commission prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Commissioner BY ORDER OF THE COMMISSION dlffenclosures Department of Fish & Game, Habitat Section w/o encl. Department of Envinornment Conservation w/o encl. .... ' STATE OF ALASKA AL/.,...,A OIL AND GAS CONSERVATION COMMIS,s~(,)N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [~] lb Type of Well Exploratory [-'] Stratigraphic Test [] Development Oil X Re-Entry r~ Deepen r-~ Service D Development Gas [-~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. Ri~l RKB 41', Pad 23' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 25519, ALK 2555 4. Location of well at surlace 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 962' FNL, 1979' FWL, Sec. 22, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1195' FNL, 1184' FWL, Sec. 26, T13N, R9E, UM 30-20 #U-630610 , At total depth 9. Approximate spud date Amount I1, 1366' FNL, 1316' FWL, Sec. 26, T13N, R9E, UM 3/,1,~/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) property line 30-10 10444' MD 1184 @ TD feet 13.1' @ 450' feet 2560 6892' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 54.5° Maximurnsurface 2441 psig At total depth (TVD) 3600 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity/of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875' 7.625' 29.7# L-80 LTC 5737' 41' 41' 5903' 4123' 900 Sx Arcticset III & HF-ERW 460 Sx Class G 6.75' 5.5' 15.5# L-80 LTCMOD 9968' 41' 41' 10009' 6560' HF-ERW 130 Sx Class G 6.75' 4.5' 12.8# L-80 EUE8rdlV 439' 10009' 6560' 10444' 6892' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true verlical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~] i,~ '~ ' Conductor Sudace Intermediate Production Liner Perforation depth: measured Alaska 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat D BOPSketch X Diverter Sketch X Drilling program X Ddlling fluid program X Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21 .~regoing is true and correct to the best of my knowledge Sig~~~~~~_ ~"e,~ ~..~'.~,~, Title Drill Site Develop. Supv. Date ~,/''~/~'~-'- ! Commission Use Only Permit Number I APl number I Approval d~ / .~....~ I See cover letter for ~ 7 - O~'l~-- 50- O~.¢~ -- ~ ~- '75~ t...~ - , other requirements Conditions of approval Samples required D Yes ~ No Uud log required [] Yes [~ No Hydrogen sulfide measures [~ Yes r-~ No Directional survey required .~ Yes [~] No Required working pressure for BOPE 2M [~] 3M D 5M D 1OM E] 15M Other: ong na ary C, Marshbum by order of Commissioner the commission Date i~ ~'/'~"'~ ~ Approved by Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3O-2O I , , . . , . . . . 10. 11. 12. 13. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (5,903')according to directional plan. Run and cement 7-5/8" casing, using stage collar placed at the base of permafrost, and light weight lead cement. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to total depth (10,444') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) Pressure test 5-1/2" x 4-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 30-20 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 ___10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System' Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes- Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2397 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 30-20 is 30-10 As designed, the minimum distance between the two wells would be 13.1' @ 450'. Drilling Area Risks: Risks in the 30-20 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 30-20 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 30-20 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is re~.uested that _.30'20 be permitted for annular ..... pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.0~7~A71~~ntaining significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 30 surface casing shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4027 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)iGrade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 LTC 4790 4072 6890 58 57 5.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ARCO ALASKA, Inc. Pad 30 20 slot #20 Kuparuk River Unit North Slope, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E by Baker I~ughes INTEQ REPORT Your ref : 20 Version #3 Our ref : prop1781 License : Date printed : 12-Mar-97 Date created : 21-Aug-96 Last revised : 12oMar-97 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 28 24.450,w149 48 25.1 Slot location is nTO 28 14.986,w149 47 26.922 Slot Grid coordinates are N 6021856.594, E 525614.275 Slot local coordinates are 962.00 S 1979.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. PGMS <0-8137'>,,14,Pad 30 27-Aug-91 90.9 1000.0 1000.0 PGMS <0-9195'>,,18~Pad 30 27-Aug-91 214.9 180.0 180.0 PGMS <0-9263'>,,17,Pad 30 27-Aug-91 187.6 550.0 550.0 PGMS <0-8351'>,,16A,Pad 30 27-Aug-91 127.5 1100.0 1100.0 PMSS <5107-8184'>,,16,Pad 30 27-Aug-91 127.5 1100.0 1100.0 PGMS <0-9450'>,,15,Pad 30 27-Aug-91 133.5 550.0 550.0 PGMS <0-7950'>~13,Pad 30 27-Aug-91 90.9 20.0 600.0 PGMS <0-7005'>~12,Pad 30 27-Aug-91 62.4 550.0 550.0 PGMS <0-7803'>,,11,Pad 30 27-Aug-91 38.1 500.4 500.4 PGMS <0-8830'>,,lO,Pad 30 27-Aug-91 13.1 450.0 450.0 PGMS <0-7916'>,,9,Pad 30 27-Aug-91 75.2 180.0 180.0 PGMS <0-7770'>,~8,Pad 30 27-Aug-91 95.6 400.0 400.0 PGMS <0-8148'>,,7,Pad 30 27-Aug-91 121.2 350.0 350.0 PGMS <O-8172'>,,6,Pad 30 27-Aug-91 150.1 20.0 20.0 PGMS <0-8840'>,,5,Pad 30 27-Aug-91 172.5 350.0 350.0 PGMS <O-8984'>,,4,Pad 30 27-Aug-91 198.9 325.0 325.0 PGMS <O-9140'>,~3~Pad 30 27-Aug-91 224.9 20.0 20.0 PGMS <0-10420'>,~2A~Pad 30 27-Aug-91 249.4 220.0 220.0 PMSS <203-5718'>,,2,Pad 30 27-Aug-91 248.7 350.0 350.0 PGMS <O-9173'>,,1,Pad 30 2Z-Aug-91 274.6 20.0 10324.1 19 Version #2~19,Pad 30 1Z-Mar-97 60.0 280.0 280.0 ICr~ted by~on~s For: D Petrash[ Dote plotted; 12-Mar-97 Plot Reference is 20 Version tf3. C~ordinates are in feet reference slot ~20. [ Tree V~al mpths~ ARCO ALASKA, Inc. Structure: Pad 50 Well: 20 Field : Kuporuk River Unit Location : North Slope, Alaska East (feet) -> 500 0 500 1000 1500 2000 2500 `3000 .3500 I I I I II I I I I II II II I IEstimated I SURFACE LOCATION: 962' FNL, 1979' FWL SEC. 22, T13N, RgE ~egin Turn to Target Base Permafrost EOC 140.87 AZIMUTH 7107' (TO TARGET) ***Plane of Proposal*** Top Ugnu Sands 500 500 1000 1500 2000 2500 3000 0 3500 4-- > 4000 F.~ 4500 I 5000 5500 600O 650O 7000 75OO 5OO Top West Sok Sands RKB ELEVATION: 64' KOP TVD=300 TMD=300 DEP=O 3.00 g.o0 BEGIN TURN TO TRGT TVD=632 TMD=633 DEP=14 12.66 17.26 DLS: 3.00 deg per I00 ft 22.52 28.06 33.75 39.52 B/ PERMAFROST TVD--1664 TMD--1768 DEP--427 45.34 51.20 EOC TVD=2038 TMD=2312 DEP=821 T/ UGNU SNDS TVD=2725 TMD=3496 DEP=1784 T/ W SAK SNDS TVD=3451 TMD=4746 DEP=2802 B/ W SAK SNDS TVD=5925 TMD=5559 DER=3463 7 5/8" CSG PT TVD=4123 TMD=5903 DEP=3744 Base West Sak Sands 7 5/8 Casing Pt Companion T S( Begin Angle K-1 TARGET LOCATION: 1195' FNL, 1184' FWLI SEC. 26, T13N, R9E TARGET TVD=6635 TMD=10109 DEP=7107 SOUTH 5513 EAST 4485 MAXIMUM ANGLE 54.5 DEG TARGET ANGLE 40 DEG 0 500 1000 4000 4500 Base HRZ 4000 45OO 50OO 55OO 6O00 TD LOCATION: 1366' FNL, 1316' FWLI SEC. 26, T13N, R9E CAMPANIAN T SNDS TVD=6064 TMD=9246 DEP=6464 BEGIN ANGLE DROP TVD=6144 TMD=9584 OEP=6576 B/ HRZ TVD=6198 TMD=9474 DEP=6649 K-1 MARKER -[VD=6309 TMD=9650 DEP=6786 54.17 T/ UNIT D TVD=6440 TMD=9843 0EP=6927 50.17 ~ I I, BLS: 2.00 deg per 100 ft ,~ 46.17 ~ Z 1~ 4 /Z, C,~, T/ UNIT C TVD=6531 TMD=9970 OEP=7015 k~,,~'~.~ 42.17 · ,x.~ ~'1" ~T/ UNIT B TVD=6560 TMD=IO009 DEP=7042 ~ - '~ --~" T/ UNIT A TVD=6625 TMD=10096 0EP=7099 "xx TARGET - A3 Interval TVD=6635 TMD=10109 DEP=7107 x~Nt~aq B/ KUP SNDS TVD=6739 TMD=10244 DEP=7194 ~ i i i i i i i i i ii i ii i ii i i 500 2000 2500 3000 3500 4000 4500 5000 5500 6000 VerTical SecTion (feeT) -> AzimuTh 140.87 with reference 0.00 N, 0.00 E from slot //20 I i i i i I 6500 7000 7500 5000 500 0 500 1000 1500 2000 2500 3000 3500 Created by jones For: D Petrash] Dote plotted: 12-Mar-97 Plot Reference is 20 Version tf3. Coordinates are fn feet reference slot ~20. True Vertical Depths~ RKB CParker ~245).I I~ J ARC0 ALASKA, Inc. Structure: Pad 30 Well: 20 Field : Kuparuk River Unit Location : North Slope, Alaska 120 80 2500 40 2900 /' oo/ / ,%,,~.(~)(~ .31 "e" '~. ....... ~-'-. 5oo ........ 40 2300 3300 2500 East (feet) -> 120 80 40 0 40 80 120 160 200 240 280 320 360 400 440 I I I I I I I I I I I I I I I I I I I I I I I I I I I I 80 500 -I 1300 120 16o 200 240 280 520 560 1500 5700 5900 610~ 7OO 400 45OO 3700 1700 4100 1300 120 80 120 16O 1900 20O 240 ('- .--I- 28o 320 v 360 330O 400 440 480 520 56O 600 1700. 3500 1500 1300 2100 2300 440 480 52O 56O 600 640 64O 680 I I I 120 80 4-0 0 40 80 120 160 200 240 280 320 360 400 440 East (feet) -> 680 Creoted by jones For: D Petrash] Do'~e plotted: 12-Uor-97 Plot Reference is 20 Version C~ordinotes are in feet reference slot ~120. True Vertical Depths~ RKB (Porker ARCO ALASKA, Inc. Structure: Pad 50 Well: 20 Field : Kuparuk River Unit Location : North Slope, Alaska East (feet) -> 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 1700 I I II II II II II II II II II II II II II ,, 300 400 5OO 600 I 7OO 8OO 03 900 -4.- 1000 0 1100 I v 1200 1300 1400 1500 1600 1700 1800 1900 2000 700 %.% "% 1900 \%,..,, 2300 2500 1700 2700 "...\ '~ 2100 \'%% '%"\,,\ '~ 2300 · '"'....,. 2900 1900 3100 2100 3300 2300 2500 2700 ',. 2500 -. '~ 2700 ,.\ 3500 '"",,,, 3700 3900 4100 '~ 2900 ''~'~,~,,~ '-. 3100 4300 ", · 4500 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 16oo 1700 800 900 , ~ 2000 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 1700 East (feet) -> UPARUK RIVER UNIT 20" DIVERTER SCHEMATIC I 3 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP~3N WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"-2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 7 , 6 5 4 I3 I1 1. 16' -2000 PSI STARTING HEAD 2. 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13..5/8" - 5000 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR 13 5/8" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID, 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4, RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD, ALL OTHERS OPEN, 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE, 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BO'I-I'OM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES, 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY, NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE THE BOP STACK TEST WILL BE CONDUCTED AS DESCRIBED ABOVE, BUT WILL BE TESTED TO 5000 PSI HIGH. ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL ALSO BE TESTED TO 250 PSI LOW. Memorandum of Agreement Regarding KRU Well 30-20(A) and MPU Wells Drilled Near KRU/MPU Boundary ARCO Alaska, Inc. ("ARCO"), as Operator and on behalf of the Working Interest Owners of the Kuparuk Participating Area of the Kuparuk River Unit ("KRU"), proposed to drill Well 30-20(A) near the boundary of the KRU and the Milne Point Unit ("MPU") to develop the Kuparuk Reservoir in the KRU. The preliminary target location of the well was to be within the KRU and 500 feet south of the KRU/MPU boundary line ("Boundary Line" as defined below), which is permitted by state statues and regulations. After consultation, BP Exploration (Alaska), Inc. ("BPXA"), as Operator and on behalf of the MPU Working Interest Owners, and ARCO determined that the best development practice for the Kuparuk Reservoir, which also exists in the Kuparuk Participating Area of the MPU, would be to drill wells near the Boundary Line as follows. ARCO will drill well 30-20(A) to a target location within the KRU and approximately 1200 feet south of the Boundary Line. BPXA will not drill a well to a target in the Kuparuk Reservoir closer than 1200 feet north of the Boundary Line. ARCO wil not drill a well to a target in the Kuparuk Reservoir closer than 1200 feet south of the Boundary Line. (Attachment 1). For purposes of this agreement, the Kuparuk Reservoir is defined as that interval between 7586 MD (-6373 'I'VD ss) and 7915 MD (-6646 TVD ss) as found in KRU Well 30-14. Also for purposes of this agreement, the Boundary Line is defined as that common border between the following adjoining sections: From MPU the Boundary Line is the South Line of the SW quarter of section 23, Township 13N and Range 9E UM. From KRU'the Boundary Line is the North Line of the NW quarter section of section 26, Township 13N and Range 9E UM. (Attachment 2). This agreement is limited to only these named quarter sections. ARCO Alaska, inc. Operator of the Kuparuk River Unit BP Exploration (Alaska), Inc. Operator of the Milne Point Unit By: Its: Date: Date: 2-/t5 JcF7 04 .24 -18 -16 6 .59 -66 -66 -6698 -tS -23 -36 30-1 ~ -19 .18 .~'7 I -6715 1 -6723 -38 -47 30-13 6646 -124 30- · -6652 I ~ ~-' I I I ~J~ Future MPU Producer ___ ~ o (ApProximate BHL) SIMPSON L~~ ti3 )6 -$9 ~! LO / 3K-08 · ~G756 KRU /MPU Development Plan Well DS 30-20 (A) Attachment #1 (note: BHL's are shown as conventional wells but could be drilled as horizontal wells) Future MPU Well (min. 1200' North of Unit Boundar~ · MPU H-O -672; MPU ~ -" ~ KRU -68 .59 -55 -51 3 ~ OE 3K 0 · 3K-E · ~o Nils ,j% .22 "., -25 _ 3K-12 30-20(A) Producer 3K (min. 1200' South of Unit Boundary) -6722 · -1- 3K-I · 3K · -6659 3K-L [] 3K-l~: · -6736 ti 3K-K · X 697 · -6533 /Proposed 80-20(A) Well Path ~ ' '~oundary ~ne" ~BL 25528 ~ ~OL 25'519 30-18 30-17 · -6~13 + 2+7 3K-92 · 3K-01 · -645~ .~e.% 3 O-2-El ( I:::t ) 2-6 FEET 0 2000 ~:'~'"E:~' '' · : I",-t'" I :"- ,', ,.,.,,'-:,raT,,:,_ M[L~S L'~ .5 ~TAI'LII'F. _ -649tl I I MPU KRU ARCO Alaska, Inc. KUPFiRUK OEVELOPMENT PLRNNINO ORILLSITES 30 RNO 3K PROPOSED 30-20 LOOBTION F~NO TRFtJEgTORY RTTF]gHMENT 2 I°~ 17- JI::IN-97 WELL PERMIT oo,. PROGRAM: e×pO dev~redrlO se_--'~'O wellbore segO ahn' disp para req~ ADMINISTRATION APPR DATE 1. Permit fee attached ................... ~ N 2. Lease number appropriate ............... .~ N 3. Unique well name and number .............. ~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary.. ~ N 6. Well located proper distance from other wells ...... (~ N 7. Sufficient acreage available in drilling unit ...... '~ N 8. If deviated, is wellbore plat included ........ ~N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order .... ~, N 12. Permit can be issued without administrative approval.. ~N 13. Can permit be approved before 15-day wait.' ....... ~] N ENGINEERING g- D~TE! 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & pe~afrost .... .~ N 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..~~,~-- 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... .~ ~ ~'~ ~ 24. Drilling fluid program schematic & equip list adequate N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to~ ~ psig.~ N 27. Choke manifold complies w/~I ~-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ N REMARKS GEOLOGY ) 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/_ 31. Data presented on potential overpressure zones ..... Y/~ 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... /. Y N ' - - 34. Contact name/phone for weekly progress reports . .~ . . Y N [explorator~onl~] GEOLOGY: ENGINEERING: COMMISSION: ' JDH. -~_~"' mcm Comments/Instructions: HOWldlf - A:\FORMS~cheklist rev 01197 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.. , Speryy-Su_ Dri~ ng Services LiS Scan Utility Thu May 01 14:48:36 1997 Reel Header Service name ............. LISTPE Date ..................... 97/05/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 97/05/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Reccrd TAPE HEADER KUPA/~UK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: CPERATOR: LOGGING COMPANY: TAPE CREATIO~ DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING MWD RUN 3 AK-MM-70071 P. SMITH D. LUTRICK OPEN HOLE BIT SIZE (IN) Date_ 30-20 500292275000 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 01-MAY-97 22 13N 9E 962 1979 64.40 64.40 23.10 CASING DRILLERS SIZE (IN) DEPTH (FT) 2ND STRING. 3RD STRING PRODUCTION STRING REMARKS: 9. 875 7. 625 6308.0 6.750 10400.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. !~[D RUNS 1 X~qD 2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAN~ RAY (DGR/SGRC) UTILIZING GEIGER MUELLER TUBE DETECTORS ~D ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DENISE PETRASH OF ARCO ALASKA, INC. ON 04/14/97. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10400'MD, 6836'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (RESISTIVITY SENSORS). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUN/W3%RY PBU TOOL CODE START DEPTH STOP DEPTH GR 6256.0 10337.0 PEF 6305 5 10344.0 RPD 6305 5 10344.0 RPM 6305 5 10344.0 RPS 6305 5 10344.0 RPX 6305 5 10344.0 ROP 6318 0 10399.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH EQUIVALENT UNSHIFTED DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ RE?lARKS: BIT RUN NO MERGE TOP MERGE BASE 3 6318.0 10400.0 MERGED ~AIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP ~ MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHM~ 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Min 6256 10 9445 37 8583 0 4426 0 3852 0 4719 0 3707 0.1288 Max Mean Nsam 10399.5 8327.75 8288 5159.49 202.923 8164 530.512 110.107 8163 2000 3.64436 8078 2000 3.92847 8078 2000 4.10247 8078 2000 4.17699 8078 50.9791 0.933011 8078 First Reading 6256 6318 6256 6305.5 6305.5 6305.5 6305.5 6305.5 Last Reading 10399.5 10399.5 10337 10344 10344 10344 10344 10344 First Reading For Entire File .......... 6256 Last Reading For Entire File ........... 10399.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. $_~mIB.002 Service Sub Level Name... Version.Number ........... 1.0.0 Date of Generation ....... 97/05/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLiB.00i Comment Record FILE HEADER FILE NUMBER: 2 ~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMY~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6256.0 10337 0 FET 6305.5 10344 0 RPD 6305.5 10344 0 RPM 6305.5 10344 0 RPS 6305.5 10344 0 RPX 6305.5 10344 0 ROP 6318.0 10399 5 $ LOG HEADER DATA DATE LOGGED: 27-MAR-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23.3 MAXIMUM ANGLE: 63.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0675SP4 EWR4 ELECTROMAG. RESIS. 4 P0675SP4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 6.8 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.60 MUD VISCOSITY (S) : 54.0 MUD PH: 10.0 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) : 5.2 RESISTIVITY (OHM}4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.000 MUD AT MAX CIRCULATING TERMPERATURE: 2.025 56.1 MUD FILTRATE AT MT: 2.800 MUD CAKE AT MT: 4.400 ISC 4.88/4.96 CIM 5.46/SP4 5.03/DE?II 2.17f MEMORY 10400.0 6318.0 10400.0 NEUTRON TOOL I~ATRiX: MzATR!X DENSITY: HOLE CORRECTION (IN): TOOL STf~qDOFF (IN) : EWR FREQUENCY (HZ) : RE!~ARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 R©P MWD 3 FT/H 4 1 68 GR MWD 3 AAPI 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHM}4 4 1 68 RPM MWD 3 OHMM 4 1 68 RPD MWD 3 OHM}4 4 1 68 FET MWD 3 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name DE.?T ROP RPX RPS RPM RPD FET Min 6256 10 9445 37 8583 0 4426 0 3852 0 4719 0 3707 0 1288 Max Mean Nsam 10399.5 8327.75 8288 5139.49 202.923 8164 530.512 110.107 8163 2000 3.64436 8078 2000 3.92847 8078 2000 4.10247 8078 2000 4.17699 8078 50.9791 0.933011 8078 First Reading 6256 6318 6256 6305.5 6305.5 6305.5 6305.5 6305.5 Last Reading 103.99.5 10399.5 10337 10344 10344 10344 1034,4 10344 First Reading For Entire File .......... 6256 Last Reading For Entire File ........... 10399.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trai!er ~ ~ Service name ............. LISTPE Date ..................... 97/05/01 Origin ................... STS Tape Name ................ UN.gOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LiS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/05/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
