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192-047
19 2A 47 • • 29309 WELL LOG TRANSMITTAL #904850427 To: Alaska Oil and Gas Conservation Comm. June 5, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 `` Anchorage, Alaska 99501 "° �` ���YfA JUN 12 2Q1 AOGCC RE: Coil Flag Record: 2M-05 Run Date: 5/11/2018 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 2M-05 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20168-00 Coil Flag Record (Field Print) SCANNEV JUN 2 7 01 8 1 color log 50-103-20168-00 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 FRS ANC@halliburton.com X91?Date: Signed: a • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 5/Z<7f1 . DATE: May 17, 2018 P.I. Supervisor 71 SUBJECT: Well Bore Plug &Abandonment KRU 2M-05 - FROM: Jeff Jones CPAI Petroleum Inspector PTD 1920470; Sundry 318-140 Section: 27 Township: 11N ' Range: 8E ' Meridian: Umiat T Drilling Rig: NA Rig Elevation: NA Total Depth: 8931 ft MD - Lease No.: ADL 2558r r Operator Rep: Suspend: P&A: X Casing/Tubing Data: Casing Removal: Conductor: 16" -0.D. Shoe@ 119 Feet Csg Cut@ Feet Surface: 9 5/8" _ O.D. Shoe@ 3167 - Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" _ O.D. Shoe@ 8916 • Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3.5" - O.D. Tail@ 8457 Feet Tbg Cut@ Feet Plugging Data: Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole , Retainer - 8444 ft MD y 8422 ft MD- Test Data: Initial 15 min 30 min 45 min Result Tubing 1640 . 1530 v 1520 - IA 290 - 300 , 300 P OA 410 - 410 , 410 Remarks: Well plugged; no future utility per Sundry 318-140. Pressure test for AOGCC witness after Bob Noble(AOGCC)witnessed questionable plug tag at 8422 ft on 5/15/2018. 1 well inspected; no exceptions noted. Attachments: none SCANNED JUN 0 1 2018 rev. 05-02-18 2018-0517_Plug_Verification_KRU 2M-05Jj • Loepp, Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent Wednesday, May 16,2018 4:10 PM To: Loepp,Victoria T(DOA) Cc: Noble, Robert C (DOA) Subject: RE: [EXTERNAL]KRU 2M-05 P&A (PTD#: 192-047, Sundry#: 318-140) Follow Up Flag: Follow up Flag Status: Flagged Thanks,Victoria.We will schedule testing with inspector. Jill SCANNED JUN 5 2018 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 16,2018 2:52 PM To:Simek,Jill<Jill.Simek@conocophillips.com> Cc: Noble, Robert C(DOA)<bob.noble@alaska.gov> Subject: [EXTERNAL]KRU 2M-05 P&A(PTD#: 192-047,Sundry#: 318-140) Jill, The initial tag was witnessed and although deeper than planned is adequate. Please have the pressure test state witnessed and proceed. Thanx, Victoria From:Simek,Jill [mailto:Jill.Simek@conocophillips.com] Sent:Wednesday, May 16,2018 2:19 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: 2M-05 P&A(PTD#: 192-047,Sundry#: 318-140) Victoria, The retainer was set at 8,435ft KB and 10 bbls cement was pumped through the retainer. Squeeze pressure of 36000 was observed,at which time coil tubing unstung from the retainer,and an additional 1 bbl cement was pumped. Coil tubing was pulled up to 50ft above planned TOC(8,270ft KB)and excess cement was contaminated and circulated out of the hole. WSR is attached. -Jill From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 16,2018 1:39 PM To:Simek,Jill<Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE:2M-05 P&A(PTD#: 192-047,Sundry#: 318-140) 1 • What depth was the retainer acts set at? How much cement was pumped?Was squeeze pressure seen?Was"'1 b I cement laid in above retainer? How did the cement go? n hilli s.com From:Simek,Jill [mailto:JilLSimek(c�co ocop p ] Sent:Wednesday, May 16,2018 11:46 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: 2M-05 P&A(PTD#: 192-047,Sundry#:318-140) Victoria, Yesterday(5/15/18)we performed the Plug#1 Top of Cement tag on 2M-05,with Bob Noble witnessing for the AOGCC. The tag was at 8,422ft KB, 102ft deeper than expected (expected tag—8,320ft KB). After the first tag,the inspector left the wellsite,assuming that with a deep tag we would not be proceeding to the next steps of the P&A program. After the inspector left,we performed the tag again,tagging at 8,424ft KB and recovering a cement sample in the bailer. A LIB was also run to see if indications of the cement retainer could be seen. The LIB was clean with no marks. With the clean LIB and cement sample/tag obtained at 8,424ft KB,we are confident that approximately 11ft of cement is on the cement retainer. A passing MIT-T was also performed to 1650psi. Next steps planned, per approved Sundry,are to punch tubing"'20ft above Top of Cement,establish injectivity, and then proceed with tubing and IA cement plug placement(Plug#2). Given the operations performed to date, is it ok for us to proceed with next steps? Or would you like additional testing and/or witnessing to be performed? Please advise. Thank you, Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 2 • • • Job: ABANDONMENT WSR Historical - QC Report Date: 5/12/2 18 Rig: SLB COILED TUBING CT 11 2M-05 ConocoPhiiiips h;,rk JOB API/UWI Legal WellName Field Name 5010320168 2M-05 KUPARUK RIVER UNIT Well Type Original KB/RT Elevation(ft) Well Status Development 146.00 INJ Actual Start Date End Date Secondary Job Type Primary Wellbore Affected 5/12/2018 06:00 5/12/2018 19:00 ZX52 Cementing 2M-05 NETWORK Primary Job Type Project Description Common WellName AFE/RFE Network/ID# ABANDONMENT 2M-05 P&A-Wells 2M-05 10409722 10409722 RIG Rig Accept Date Rig Release Date Rig Type Contractor Rig Name/No 5/12/2018 06:00 5/12/2018 19:00 COILED TUBING SLB CTU 11 Rig Supervisor Title Company Phone Work Phone Mobile Pager APPLEHANS,AARON Wells Supervisor CPAI 659-1742 N/A N/A job scope,worksting information,or noted if job is performed during Drilling Operations Comment 2"COIL BHA#1 (CTC 2.125"X.3')(WFT MHA 2.125"X 1.72')(2.40"CARRIER WITH GR AND CCL 2.40"X 9.83'(XO 2.125"X.43')(DJN 2.5"X.58')TOL=12.86' BHA#2(CTC 2.125"X.3')(WFT MHA 2.125"X 1.72'))(WFT FH ONE TRIP CEMENT RETAINER 2.125"X 5.5')(3.5"CEMENT RETAINER 2.75"X 1.42') TOL=8.94' initial and final pressures General Remarks INITIAL T/I/O=1507/298/424 FINAL T/1/0= this data box is reviewed daily by engineers,supervisors,and techs. Last 24hr Summary RIH WITH MEMORY GAMMA RAY AND CCL, LOG FROM 8600'RKB TO 8450'RKB, PAINT WHITE FLAG,CONTINUE LOGGING UP TO 8200'RKB, OOH MAKE UP 3.5"CEMENT RETAINER, RIH TO D NIPPLE,CORRECT COIL DEPTH TO 8443'RKB CENTER OF ELEMENT. PUH TO 8435'RKB CENTER O ELEMENT, DROP.5"BALL,SET RETAINER AT 8435'RKB, PUMP 19.6 BBLS THROUGH RETAINER, UNSTING FROM RETAINER, LAY IN 1 BBL ON TO�' OF RETAINER.ESTIMATED TOC IS+/-8320'RKB. (WAIT 24HRS,READY FOR SLICKLINE) weather related data when and if weather has affect on job Weather Wind T(°F) DAILY OPERATIONS Report Start Date Report End Date Status at Reporting Time Time Log Total Hours(hr) 5/12/2018 06:00 5/12/2018 19:00 Reported 05/16/2018 13.01 CONTRACTOR Supervisor Title Company Phone Work Mobile Pager THORNHILL,BILLY Coil Tubing Operator SLB 982-2676 943-1564 .N/A TIMELOG Time Start Cum Dur Major Activity P-T- Time End Time Dur(hr) (hr) Equip Code X Operation Vendor Wellbore 06:00 06:12 0.20 0.20 CT TRAV P TRAVEL TO LOCATION 2M-05 06:12 06:18 0.10 0.30 CT RURD P CONTACT DSO,INSPECT LOCATION,PJSM 2M-05 06:18 07:18 1.00 1.30 CT RURD P MIRU 2M-05 07:18 08:48 1.50 2.80 CT RURD P MAKE UP CC,PULL TEST 20K,MAKE UP REST OF TOOLS,PT LOW 250, 2M-05 HIGH 3500 08:48 08:54 0.11 2.91 CT RURD P HEAD TO WELL,STABBED ON WELL,FLUID PACK FOR PT,LOW 250,HIGH 2M-05 4000 08:54 09:00 0.10 3.01 CT CTOP P OPEN WELL,SWAB 18,WHP 1507,IA 298,OA 424 2M-05 09:00 09:30 0.50 3.51 CT CTOP P WT CK 3000'=4K 2M-05 09:30 10:00 0.50 4.01 CT CTOP P WT CK 7000'=17K 2M-05 10:00 10:12 0.20 4.21 CT CTOP P TAG AT 8577'CTMD 2M-05 10:12 10:18 0.10 4.31 CT CTOP P WAIT 5 MIN,START LOGGING UP 2M-05 10:18 10:27 0.15 4.46 CT CTOP P STOP PAINT WHITE FLAG M 8457'E 8450' 2M-05 10:27 10:28 0.01 4.47 CT CTOP P CONTINUE LOGGIN UP TO 8200'CTMD AT 50 FPM 2M-05 10:28 10:28 0.01 4.48 CT CTOP P AT 8200'STOP FOR 5 MIN 2M-05 10:28 10:34 0.10 4.58 CT CTOP P POOH 2M-05 10:34 11:19 0.75 5.33 CT RURD P TAGGED UP,BLEED DOWN,BLOW DOWN,POP OFF WELL 2M-05 Page 1/2 Report Printed: 5/16/2018 0 • S Job: ABANDONM NT 0WSR Historical - QC Report Date: 5/12/2 18 Rig: SLB COILED TUBING CTU 11 cif 2M-05 C P�ill pts Mack* TIMELOG Time Start Cum Dur Major Activity P-T- Time End lime Dur(hr) (hr) Equip Code X Operation Vendor Wellbore 11:19 11:49 0.50 5.83 CT RURD P DOWNLOAD DATA,GOT GOOD DATA 2M-05 11:49 12:01 0.20 6.03 CT RURD P MAKE UP CMT RETAINER,HEAD TO WELL,QTS PT,LOW 250,HIGH 3500, 2M-05 12:01 12:13 0.20 6.23 CT CTOP P OPEN WELL,SWAB 18,WHP 1500,IA 2M-05 12:13 13:25 1.20 7.43 CT CTOP P TAG AT NIPPLE 8444'CORRECT TO CENTER ELEMENT 8443'RKB,PICK UP 2M-05 TO 8435'RKB,DROP.5"BALL 13:25 14:10 0.75 8.18 CT CTOP P .5"BALL ON SEAT,MM TOTAL 2M-05 14:10 14:22 0.20 8.38 CT CTOP P PRESSURE UP TO SHEAR SETTING TOOL AND SET RETAINER 2M-05 14:22 14:28 0.10 8.48 CT CTOP P SHEARED AT 4300 PSI,SET DOWN 4K RETAINER SET 2M-05 14:28 14:29 0.01 8.49 CT CTOP P START INJECTION TEST, 1 BPM,CTP 2473, IA 286,OA 444, 1.5 BPM CTP 3100 2M-05 PSI,WHP 0,IA 286,OA 444 14:29 14:59 0.50 8.99 CT CTOP P LINE UP CEMENTERS TO FLUID PACK LINES DOWN THE COIL,PT CMT 2M-05 LINES,LOW 250,HIGH 4500,BATCH UP CEMENT 14:59 15:05 0.10 9.09 CT CTOP P ONLINE WITH CEMENTRS DOWN COIL 2M-05 15:05 16:05 1.00 10.09 CT CTOP P CMT AT RETAINER,WHP 0,CTP 3020, IA 298,OA 470 2M-05 SQUEEZE 10 BBLS BELOW RETAINER,WHP 0,CTP 3600,IA 306,OA 490 16:05 16:35 0.50 10.59 CT CTOP P UNSTING FROM RETAINER,LAY IN 1 BBL ON TOP OF RETAINER,TOC AT+/- 2M-05 8270'RKB 16:35 16:41 0.10 10.69 CT CTOP P CHASE CONTAMINATED CMT OUT OF HOLE 2M-05 16:41 17:30 0.82 11.51 CT RURD P TAGGED UP,WHP 0,IA 300,OA 543 2M-05 17:30 18:30 1.00 12.51 CT RURD P RDMO,.5"BALL RECOVERED 2M-05 18:30 19:00 0.50 13.01 CT TRAV P TRAVEL TO 1B FOR THE NIGHT 2M-05 DAILY COSTS **amount=0 for jobs done while drilling,show cost&customer in note section for jobs done while drilling** AFE/RFE/Maint.# Cost Des Vendor Note 10409722/10409722 Miscellaneous Consultant Fees Fairweather E&P Service Inc 10409722/10409722 Coiled Tubing Service Schlumberger 10409722/10409722 Diesel to Well-recoverable ConocoPhillips Company 10409722/10409722 Trucking&Ground Transport ASRC Energy Services(Natchiq) 10409722/10409722 Data Logng Srvcs.(memory tools) Halliburton Energy Services Inc.(HES) 10409722/10409722 Fishing/Milling Srvcs. Weatherford FLUIDS Fluid To(bbl) Note DIESEL,SLICK 200.0 Page 2/2 Report Printed: 5/16/2018 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ! � 5/ '/1€) DATE: May 15, 2018 P.I. Supervisor SUBJECT: Well Bore Plug &Abandonment KRU 2M-05 FROM: Bob Noble CPAI Petroleum Inspector PTD 1920470; Sundry 318-140 Section: 27 - Township: 11N Range: 8E - Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 8931 ft MD Lease No.: ADL 2558 Operator Rep: Chris Watkins (Halliburton) Suspend: P&A: X Casing/Tubing Data: Casing Removal: Conductor: 16" - O.D. Shoe@ 119 - Feet Csg Cut@ Feet Surface: 9 5/8" - O.D. Shoe@ 3167 - Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7" - O.D. Shoe@ 8916 _ Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 3.5" - O.D. Tail@ 8457 _ Feet Tbg Cut@ Feet Plugging Data: Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Open Hole- Retainer 8444 ft MD - 8422 ft MD- Wireline tag L.-- Test -Test Data: Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I arrived on location and the CPAI company men were changing out(not coming to location). Halliburton operator Chris Watkins was in charge. They ran in hole and tagged up at 8422 ft MD. The procedure called for top of cement(TOC) at 8320 ft MD; coil tubing crew said TOC would be at 8270 ft MD. Bailer came back clean and empty. I called AOGCC Inspection Supervisor Jim Regg; he instructed me to tell operator to contact AOGCC Engineer Victoria Loepp to discuss before proceeding. Hallibuton decided to move forward with a pressure test against the plug which I did not witness. Attachments: none SCOW JUN 0 1 nth rev. 05-02-18 2018-0515_Plug_Verification_KRU 2M-05_bn • tiOFTjt • • A THE STATE Alaska Oil and Gas OfALASK A Conservation Commission 333 West Seventh Avenue ij/irqmPxGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 •, Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jill Simek Staff Wells Engineer ConocoPhillips Alaska, Inc. SCANT { P.O Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 2M-05 Permit to Drill Number: 192-047 Sundry Number: 318-140 Dear Ms. Simek: 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 L DATED this O day of April, 2018. ABDMS (/ APR 1 12018 ult C `'0 7 PI tin.04 40 MAR 302018 STATE OF ALASKA .L//0 7/ f h t'S ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon U\ Plug Perforations U Fracture Stimulate U Repair Well U Operations shutdownll Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska. Inc. Exploratory ❑ Development ❑ 192-047 • 3.Address: Stratigraphic ❑ Service Q. 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-103-20168-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No U KRU 2M-05 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25586,ALK2672 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 ND: MPSP(psi): Plugs(MD): Junk(MD): 8,931' 6,309' 8,444' 5,936' 3,250 psi 8444'MD NONE Casing Length Size MD ND Burst Collapse Conductor 77' 16" 119' 119' • Surface 3,125' 9-5/8" 3,167' 2,750' Intermediate Production 8,878' 7" 8,918' 6,299' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8535'-8562'MD ` 6005'-6026'ND 8574'-8601'MD - 6035'-6056'ND 3.500" J-55 8,457' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-BAKER F-1 PERMANENT PACKER W/XO&SEAL BORE EXT ' MD=8421 ND=5918 SAFETY VLV-CAMCO TRDP-4A SAFETY VALVE • MD=1827 ND=1807 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: �`t Detailed Operations Program CI BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service [� 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/22/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q t 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: Jill Simek Contact Name: Jill Simek Authorized Title: Staff Wells Engineer Contact Email: Jill.Simek©cop.com I ' - Contact Phone: (907)263-4131 Authorized Signature: ! �/ �1I Date: ) I COMMISSIONUSE ONLY Conditions of approval: N, ommission so that a representative may witness Sundry Number: 513 _ Igo .... Plug Integrity rErf BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance i E Other: ci ph0 .o dbc wi e�-� s- i. oil c cul---r- Post Initial Injection MIT Req'd? Yes 0 No Er Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: /0 — 4( APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1i lk ra 11Q) 4Y ,t) 'c- Y/./i ,440-4, v�4 01 G INA .. 1, RBDMS_._: APti- 1 1 ntlemit Form and DC X0 Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 Commissioner, State of Alaska 22 March 2018 Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to Plug and Abandon Kuparuk Injector 2M-05 (PTD#: 192-047). 2M-05 was drilled and completed in June 1992 as an A and C sand injector. In September 2012, an MIT-IA failed during the 4-year 2M pad MIT testing, and the well was subsequently shut-in and freeze protected. Leak-detect logging identified two leaks in the production casing at approximately 6,927ft—6,932ft KB and 6,952ft—6,957ft KB. Slickline secured the well in March 2014 with a 2.75"CA-2 plug set at 8,444ft KB. Since then,repair has been deemed uneconomical and the well remains shut-in. / No future utility exists for 2M-05 as offset producers have not shown significant declines since the well has been shut-in. Furthermore, a grassroots well is planned at 2M, to utilize the 2M-05 location and reuse flowlines, wellhouse and other facilities. With no future utility and a ne d t recover the 2M-05 location,a P&A of the well is recommended.V I c7noir. r 4 The well has 9-5/8" surface casing to 3,166.6ft KB, 7" production casing to 8,917.9ft KB, and 3-1/2" tubing to 8,456.7ft KB,with a packer set at 8,420.6ft KB. A 2.75"CA-2 plug is set in the Camco"D"Nipple at 8,444.0ft KB. Two sets of Kuparuk perforations are at 8,535.0ft—8,562.0ft KB and 8,574.0ft—8,601.0ft KB. Per this procedure,P&A operations will be performed to pump cement across the Kuparuk perforations and into the 3-1/2"tubing to 8,320ft KB (Plug#1). Holes will then be punched in the tubing, above Plug#1 and cement pumped into the tubing and tubing x production casing annulus(IA)to 2,000ft KB (Plug#2). Tubing and production casing will be perforated above Plug#2 and a third cement plug(Plug#3)will be pumped to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level,wellhead and cellar removed,and site backfilled with gravel/fill to ground level. ✓ Please refer to the attached procedure for more details. If you have any questions or require any further information, please contact me at 263-4131. Sincerely, Jillr'Simek Well Integrity Engineer CPAI Drilling and Wells v • • ConocoPhillips 2M-05 P&A Permit to Drill #: 192-047 P&A operations will be performed to pump cement across the Kuparuk perforations and into the 3-1/2" tubing to 8,320ft KB (Plug #1). Holes will then be punched in the tubing, above Plug #1 and cement pumped into the tubing and tubing x production casing annulus (IA) to 2,000ft KB (Plug #2). Tubing and production casing will be perforated above Plug #2 and a third cement plug (Plug #3) will be pumped to bring cement to surface in the tubing, IA, and production casing x surface casing annulus (OA). The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Procedure: Slickline / Little Red: Objective: Pull plug, injectivity test, drift for cement retainer. 1. Inspect pad and work area for hazards. Complete pre-job Safety Meeting. 2. RU Slickline unit and support equipment. PT lubricator and surface lines as required. 3. RIH with 2.75" x 15' dummy mechanical cement retainer tool string, down to plug at 8,444.0' KB. 4. if drift not successful, RDMO. 5. If drift successful, RIH and pull plug at 8,444.0' KB. 6. Rig up LRS, pump 30 bbls diesel to verify injectivity for cementing operations (+/- 2 bpm at 2,000psi). DISCUSS RESULTS WITH WELL INTEGRITY ENGINEER 7. RDMO. Coiled Tubing / Cementing: Objective: Plug #1 - Place a cement plug across the open perforations and squeeze some cement into perforations. NOTE: Maximum pressure, volume and rate for squeeze to be discussed and agreed with client representative at site prior to starting cement job, based on injectivity test results. Cement Volume Calculations (TOC in tubing to be at approximately 8,320' KB): • 7" production casing volume from 100ft below perforations to tubing tail = (8,701' — 8,456') x (0.03826 bbl/ft) = 9.4 bbl • 3-1/2 tubing volume from tubing tail to 8,320' KB = (8,456' — 8,320') x (0.008696 bbl/ft) = 1.2 bbl • Squeeze volume: 10 bbl • Total volume: 9.4 + 1.2 + 10 = 20.6 bbl 1. Ensure an approved sundry has been received from AOGCC. Js • • 2. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Charles Hacker/ Stephen Higgins 907 659-6121). The job is designed for 20.6 bbls of 15.8# Class "G" cement. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU Coil Tubing Unit and PT Surface Equipment as required. 5. Reference 5/25/2014 schematic and tubing details for depth correlation. Perform tie- in/pipe flag run to ensure cement retainer is set at desired depth. 6. RIH with Weatherford 2.75" cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 8,435' KB (middle of tubing joint in tubing tail), or as deep as the retainer will safely drift. 8. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 9. Pump 30 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 10. RU SLB Cement Equipment and PT surface lines as required. 11. Pump 10 bbls fresh water spacer 12. Pump 19.6 bbls of 15.8# Class "G" cement. If squeeze pressure is seen before pumping total cement volume, unsting from retainer and begin next step. 13. Shut down, un-sting from retainer 14. Lay in remaining 1 bbl cement above retainer (equates to - 115' of cement above the retainer, leaving TOC -8,320' KB) 15. POOH above TOC 16. Circulate CTU clean. 17. RDMO Slickline / DHD Objective: State witnessed tagof TOC, MIT-T, DDT-T 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 8,320' KB. Record Results. TAG MUST BE AOGCC WITNESSED 111(- 5. Perform MIT-T to 1,500 psi. Record Results. PRESSURE TEST MUST BE AOGCC WITNESSED 6. Perform DDT-T. Record Results. 7. Report issues and results to Well Integrity Engineer. 8. RDMO Js • • Eline / Little Red: Objective: Punch tubing, injectivity test 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU E-Line and PT Equipment as required. 3. RIH with 2" x 4' tubing punch, 4 spf; reference 5/25/2014 schematic and tubing details for depth correlation. 4. Punch approximately 20' above TOC or as close to mid joint as possible. 5. Rig up LRS and pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32' above the previous holes. 7. Observe IA returns to determine leak rate through production casing. DISCUSS RESULTS WITH WELL INTEGRITY ENGINEER 8. RDMO. Cementing: Objective: Plug #2 - Fill the wellbore with cement from tubing punch (-8,300' KB) to approximately 2,000' KB. We will be circulating cement down the 3 1/2" tubing and up the 3 1/2" x 7" annulus. Cement Volume Calculations (TOC approximately 2,000' in tubing and annulus): • Volume in 3 1/2" x 7" annulus: (8,300' —2,000') x 0.02636 bbl/ft = 166.1 bbl • Volume inside 3 1/2' tubing: (8,300' —2,000') x 0.008696 bbl/ft = 54.8 bbl • Total volume: 166.1 + 54.8 = 220.9 bbl • Displacement volume: (2,000' KB) * (0.008696 bbl/ft) — 3 bbl spacer = 14.4 bbl 1. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Charles Hacker/ Stephen Higgins 907 659-6121). The job is designed for 220.9 bbls of 15.8# Class "G" cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. Ensure a 5" foam ball is loaded into the tree prior to the cement job. 4. RU cementers. Ensure to rig up a cement clean up line using an isolation valve and "T" connection off the tree. 5. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3 1/2" x 7" (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 6. PT surface equipment as required 7. Establish circulation with diesel. 8. Pump 2 bbls fresh water spacer Js • 9. Pump 220.9 bbls of 15.8 ppg Class "G" cement with LCM additive. • LCM type/amount to be determined based on production casing leak rate established in previous operation. • Cement volume assumes tubing punch at 8,300' KB. Recalculate based on actual tubing punch depth. • Pump up to 2 bpm initially and slow pump rate to <1 bpm after first 90 bbl of cement, to avoid pumping through production casing leak into formation. 10. Drop 5" Foam Ball 11. Pump 3 bbls fresh water spacer. 12. Displace with 14.4 bbls diesel to leave Top of Cement in tubing and IA at 2,000' KB. Do not overdisplace 13. Shut down pumps and close in well. Leave IA open for one hour, to balance, 14. Wash up cement pumps and clean up surface lines. 15. RDMO Slickline / DHD Objective: Tag TOC, CMIT-TxIA, DDT-TxIA 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 2,000' KB. Record results and report tag depth to Well Integrity Engineer. / not , iv 4-O Cz CG 5. Perform CMIT-TxIA to 1,500 psi. Record results. o►� to v 6. Perform DDT on Tubing and IA. Record results. ,� r a r f Grp 7. Report issues & results to Well Integrity Engineer. I J PT- 8. RDMO l,,/► f-✓r(5 5 E-line / Little Red Objective: Log CBL, perforate 31/2" tubing and 7" production casing to establish circulation for surface cement plug. 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU e-line and PT Equipment as required. 3. Log CBL to determine TOC in IA. 4. DISCUSS CBL RESULTS WITH WELL INTEGRITY ENGINEER TO CONFIRM REQUIRED PUNCH DEPTH. 5. RIH with dual-string perforating gun (5ft x 2" Powerflow downloaded to 1spf, zero degree phased), referencing 5/25/2014 schematic and tubing details for depth correlation. Js i 6. Punch at depth determined by TOC tag and CBL log, TO BE CONFIRMED BY WELL INTEGRITY ENGINEER. 7. Pump diesel down tubing to confirm circulation to both IA and OA (+/- 2 bpm <= 2,000psi). Ensure fresh diesel is circulated into OA to fully displace unknown annulus fluid. 8. If 2 bpm circ. rate is not achievable, RIH with a second perforating gun and punch holes 32' above the previous holes. 9. RDMO Cementing: Objective: Plug #3 - Fill the wellbore with cement from perforating depth (-2,000' KB) to surface. We will be circulating cement down the 3 '/2" tubing and up the 9- 5/8" x 7" annulus as well as up the 7" x 3 '/2" annulus. Cement Volume Calculations: • Volume in 3 1/2" x 7" annulus: (2,000'-0') x 0.02636 bbl/ft = 52.7 bbl • Volume in 7" x 9 5/8" annulus: (2,000'-0') x 0.02561 bbl/ft = 51.2 bbl • Volume inside 3 1/2' tubing: (2,000'-0') x 0.008696 bbl/ft = 17.4 bbl • Excess: 20 bbl • Total volume: 52.7 + 51.2 + 17.4 + 20 = 141.3 bbl 1. Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Charles Hacker/ Stephen Higgins 907 659-6121). The job is designed for 141.3 bbls of ArcticSet 1 (AS1) cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU cement equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from both the 7" x 9 5/8" (OA) and 3 '/" x 7" (IA) annuli independently. Also ensure that there is a way to pump down the IA or OA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4. Close the OA, open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5. Close the IA, open the OA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the OA to confirm circulation. 6. After circulation to IA and OA is confirmed, batch up AS1. 7. Line up to pump cement down the tubing, taking returns from the OA. 8. Follow Pump Schedule below: i. 5 bbls fresh water spacer ahead ii. 141.3 bbl of Permafrost Cement (cement to surface in T/I/O, including 20 bbls excess) 9. After approximately 68.6 bbls of cement is pumped away, expect to see OA cement returns. Utilize mud balance to confirm good AS1 to surface coming from the OA. Pumpcontingency cement if needed to obtain good cement to surface. 9 Y Js • 10. With good OA cement to surface, open the IA, close the OA, and line up to take IA returns to tanks. This step must be performed efficiently as AS1 is thixotropic and will develop gel strength quickly when static. 11. After approximately 52.7 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud balance to confirm good AS1 to surface coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 12. After good OA and IA cement is seen at surface, shut down pumps and close in the IA and OA valves. 13. Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 14. RDMO DHD: Objective: DDT 1. WOC for 48 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. Wellhead Excavation / Final P&A: 1. Determine top of cement in tubing and annuli; perform cement top up job. 2. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 3. Remove the well house, if still installed. 4. Bleed off T/I/O to ensure all pressure is bled off the system. 5. Remove the production tree, in preparation for the excavation and casing cut. 6. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 7. Cut off the wellhead and all casing strings at 4 feet below original ground level. 8. Verify that cement is at surface in all strings. AOGCC witness and photo document required. 9. Send the casing head w/ stub to materials shop. Photo document. 10. Weld %4" thick cover plate (16" O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 2M-05 PTD #: 192-047 API #: 50-103-20168-00 11. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12. Obtain site clearance approval from AOGCC. RDMO. Js • 13. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. Js • • Schematic: KUP INJ 2M-05 ConocoPhillips well Attributes Max apse 8 MD TO MOP. WI Field Mr Wigton Suer red 1'1 MD(RKS) Ad Pm 8e®) M;nk;i 501032016800 KUPARUK RVER UNR INJ 55.92 7,600.39 8,931.0 Comment MSS 0wasl We Mended. End Date 68-Ord(16 Rig Release Date ... SSS/:TRDP Last WO: 4511 6/6/1992 14,46,2)2000102:1232 PM Last Tag vaMatselnma4fa.altj Ampbfion DepthB) End D4 last Med er LAM Tap:SLM 8,56,56(MB) 3/2/2014 leneM Last Rev Reason Annotation Dae M Mey n'Ifi Rev Renton:TAG IEM 5/25/2014 L 1Omalilon naeeG:J9O___._ � Casing Strings Casing Desuydan DO lin) ID lin) Top MOS) Set Depth MK0) Sas Depth(TVD)_.Witten 11..Ora. Top Tread '�� eW CONDUCTOR 16 15.062 42.0 1190 1190 6258 H-40 WELCED Camp Desa1pom '00(m) ID 0.1) 101,I038) SatDMhMON 'SM Deem(TVD)...WeLen11...Gra. "Teelined SURFACE 9516 8.921 61.0 3,186.0 2,7614 47.00 J-55 ETC 96 1 MOD L Casing0.000/ 00 'OO lin) D lin) Top IMK9) Set Depth(M®) Sm Depth(IV0)...'WAen(I..Ora. Top DewedPRODUCTION 7 6.276 37.0 8,915.0 6,297.1 26.00 J-55 13TC Tubing Strings Tubing Description OMNI Ma_.D 8,1) Tap MR) sa Dept Bl..Set Depth(NMI...Wt(RAM Gra. Top Cont.oUon TUBING 312 2992 399 8,4567 5,9454 9.30 J-55 ABM-EUE Completion Details A/o/CO4ou0TOR.40.011 G.Oddn^o.A, Top(TVD) Top and Nominal Top(M148) (1999) I'1 Awn Des Con D lin) 39.9 39,9 0.10 WINGER FMC GEN IV TUBING HANGER 3.500 1,826.5 1,607.0 2735 SAFETY VLV CAMCO TRDPAA SAFETY VALVE 2.812 5/JEW VIN:t a:a.s 8,419.8 5,917.1 40.24-SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.985 ''� 8,420.6 5,917.7 40.21 PACKER BAKER F-1 PERMANENT PACKER w010&SEAL BORE 4.000 EXTENSION(S 00,4.1X D SEAL BORE) 8,444.0 5,935.7 39.84 NPPLE CAMCO 0 NIPPLE NO GO 2.750 8,455.8 5,947.7 39.81 SOS BAKER SHEAR O(7r SUB,ELME,TTL a 8445'2/4/2007 3.015 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Toy{ND) Top Biel Tep(M9) OMB) P) Das Con Run Date ID)in) 8,444.0 5.935.6 39.84 PLUG SET 2.75'Cbl PLUG 3/18/2014 0.000 Perforations&Slots her _ DensS@6ACCad.m3?e61— telselodt NOVO) 90069!8) TM(TVD) IMt18) 7 Dao 1 TSM Com 8,535.0 8,582.0 6,005.4 6,026.0 C-4,A-4,21405 224)1995 4A PETE ZOO deg.plming,2118' GAS LIFT:32301II EnanJot HI 8,574.0 8,581.0 6,035.2 6,040.6 A-3,29905 12/15/1902 4.0 PERF 180 deg.phasing;O0ented 127 deg.CCW,SWS 4 12' Cep Gun 000LMr:69134a. 8,561.0 8,607.0 6,010.8 6,055.9 A-3,299-05 72/15/1992 4.0 PERF 180 deg.pheeing;SWOr4n1led 124 deg.CCW, 5412' Cog Gun GAS UfT:1.0110 B. Mandrel Inserts — It vi Om Tq(iV01 Valve Laleh Pat Site TRO Run M TM(99{8) IMIB) MAIM 1044 CO(M) Sea Type Type Do) (psi) Run Dale Cam OAS LIET:69294III -{ 3,239.8 2,793.2 MACCO SPM-1A 1 GAS LIFT DMY BK2 0.000 0.0 7)15/1905 2 6,073.8 4,491.5 MACCO SPM-1A 1 GAS LFT 0991' BK2 0.000 0.0 7116/1995 3 7,575.0 5,378.1 MACCO SPM-1A 1 GAS LFT DMY BK3 0.000 0.0 7/16/1995 OAS LIT:6,112 4 8,229.5 5,779.1 MACCO SPM-7A 1'GAS LIFT DMY BK2 0.000 0.0 7/16/1995 5 8.368.2 5,878.3 CAMCO MA/G-2 1 12'GAS LIFT MAY RIC 0.000 0.0 7/16/1995 Notes:General&Safety End Date Annotation 11/102010 NOTE:View SMetnmEw/Alaska Scheman6.D 3/2/2014 NOTE:TAGGED AT RADOLE 8564',EST RATMOLE 3' afM AaaY:44194 0ACKEM:OCAS a •a plug;a/4 0 APPLE;64444 SSC:04881 '.ii NE/IF,5333.0402.0— . PER,.6.31A61,Sei 0— PERF:9.36 t.0.e.6010 Js • • P&A Diagram: 2M-05 Plug &Abandonment PTD#: 192-047 Current Completion 2.1BIL41.6.11PLA Tits Rag tT.IA,8 O 12.0.810'KH-,4grtd02 T.a PetfrDsl CemEiY 16 62.5a H40 Cond c9or 4 119'KB SSD/ 1,826.5 KB X :.= : Secorltl PNKg iT S IA)8,3617 iB-2,007 KB 15.8 ppg Dam-G" d1 ,ScB'36-nn.55 xff :361^g;X3.iE .oKF A 11111. Proauctlfr Casing Least -6.927-6,932'KB .6.952-6,957'KB GUR DMY 3.239.6IB _ DMY 6.073.8'KB OMY ig 7.575.'KB DMY 8,229.6 KB DMY 8.3682'KB RV Plug;Pentratiors.Casing,8 Tubing; 8.701'-632'KB - IIEN orf 15.8 ppg Class Otis Hirt Retrievable Packer 4)8,420.6'KB f/ i 2,75'CA-2 Ruga 8,444.D'KB , r � f Cem ert Retainer Se;g 8,435 KB 344'9.30/J-55 Tttlhg k'¢8.455.8'ISH /. 8.535.0-8,562.0'KB 8.574.0-8,581.0'KB 8.581.0-8,601.'KB.411 7'261.-55 ProtUotlor Casing g8.917.5 KB 12 2-28-2018 Js XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢¢,~¢7 Fi leNu m b er of Well H is to ryFi ie PAGES TO DELETE Complete RESCAN E] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED -[] ' Logs-of vadous kinds [] Other COMMENTS: Scanned by: Beverly Dianna~ Nathan Lowell Date: ,~/E [] TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si • • Wallace, Chris D (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Monday, September 03, 2012 9:28 AM To: Regg, James B (DOA); Wallace, Chris D (DOA) Subject: 2M -05(P 0) report of failed MITIA on 9 -2 -12 Attachments: 2M -05 schematic.pd Chris, Jim, P i b . 0 20 470 Kuparuk injector 2M -05 (PTD 192 -047) failed an MITIA yesterday, 09- 02 -12, as witnessed by Bob Noble, during the 4 yr 2M pad MIT testing. While pumping away 8.5 bbls, IA pressures could not rise above 1270 psi. The well was shut in and freeze protected yesterday evening. Diagnostics will be pursued and it will be added to the monthly injector report and remain on it until the problem can be diagnosed and repaired if possible. Attached are a wellbore schematic and 90 day TIO plot. 2013 SCANNED 1AAx 0 7 2013 1 • • Well Name 2M-05 Notes: Failed MITIA Start Date 6 Days 90 End Date 912012 Annular Communication Surveillance 4000 -- — 150 — 145 3500 — WHP 1AP i }AP — 140 3000 — — 135 2500 — 130 It 44 2000 1254 0 - — 120 1500 —115 1000 — 110 500 - — 105 0 - 100 Jun -12 Jul -12 Aug -12 Sep -12 300 - - __ -__� 250 "•°"■^.DGI j 200 - "MG! ■ m I1 m 150 = 100 - ••■•■•BLPD 50 ei Jun -12 Jul -12 Aug -12 Sep -12 Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 2 KUP • 2M -05 ConocoPhillips Well Well Attributes Max Angle & MD TD Alaska I , Wellbore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 501032016800 KUPARUK RIVER UNIT INJ 55.92 7,600.39 8,931.0 Comment H2S (ppn) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TRDP Last WO: 45.11 6/6/1992 Well Confer - snema 2c1= ec 7/1-ACa9/2012 al 10 27 23 AM Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date I Last Tag: RKB 8,617.0 4/18/2012 Rev Reason: WELL REVIEW osborl 7/19/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String String Top Thrd HANGER,40 1 1 CONDUCTOR 16 15.062 42.0 119.0 119.0 62.58 H WELDED 1 ' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 41.6 3,166.6 2,749.9 47.00 J - 55 BTC AB � i. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 40.0 8,917.9 6,299.4 26.00 J -55 BTC � Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... IString Top Thrd TUBING 31/2 I 2.992 39.9 8,456.7 5,945.4 9.30 J -55 1 ABM -EUE Completion Details Ill Top Depth (TVD) Top Intl Nomi... Top (ftKB) ( (°) Item Description Comment ID (in) CONDUCTOR, 39.9 39.9 0.10 HANGER FMC GEN IV TUBING HANGER 3.500 II 42 - 119 1,826.5 1,807.0 27.36 SAFETY VLV CAMCO TRDP -4A SAFETY VALVE 2.812 8,419.8 5,917.1 40.24 SEAL ASSY BAKER GBH -22 LOCATOR SEAL ASSEMBLY 2.985 I I 8,420.6 5,917.7 40.21 PACKER BAKER F -1 PERMANENT PACKER w/XO 8 SEAL BORE EXTENSION 4.000 (5" OD, 4.0" ID SEAL BORE) SAFETY vw, 1.827 8,444.0 ' 5,935.7 39.84 NIPPLE CAMCO D NIPPLE NO GO 2.750 a 8,455.8 5,944.7 39.77 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 8445' 2/4/2007 3.015 Mr Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh... Type Comment 8,535.0 8,562.0 6,005.4 6,026.0 C-4, A-4, 2M -05 2/24/1995 4.0 IPERF Zero deg. phasing, 2 1/8" EnerJet III 8,574.0 8,581.0 6,035.2 6,040.6 A -3, 2M -05 12/15/1992 4.0 IPERF 180 deg. phasing; Oriented 127 deg. CCW, SWS 4 1/2" Csg Gun SURFACE, v . • 42 - 3,787 8,581.0 8,601.0 6,040.6 6,055.9 A -3, 2M -05 12/15/1992 4.0 IPERF 180 deg. phasing; Oriented 124 deg. CCW, SWS 4 1/2" Csg Gun Notes: General & Safety End Date Annotation GAS LIFT, _ 11/10/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3,240 GAS LIFT, -- 8,074 GAS LIFT, 7,575 GAS LIFT, 8,229 T, 11 7 GAS LIFT, _ 8,368 SEAL A557, 8,420 PACKER, 8,421 NIPPLE, 8,444 SOS, 8,456 - - IPERF, • 8,535 -8,582 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( Make Model (in) Sery Type Type (in) (psl) Run Data Com... IPERF, 1 3,239.8 2,793.2 53.92 MACCO SPM - 1A 1 GAS LIFT DMY BK2 0.000 0.0 7/15/1995 • 8,574 2 6,073.8 4,491.5 52.64 MACCO SPM -1A 1 GAS LIFT DMY BK2 0.000 0.0 7/16/1995 IPERF, __ 3 7,575.0 5,378.1 55.74 MACCO SPM -1A 1 GAS LIFT DMY BK3 0.000 0.0 7/16/1995 8,581 - 801 4 8,229.5 5,779.1 46.69 MACCO SPM -1A 1 GAS LIFT DMY BK2 0.000 0.0 7/16/1995 5 8,368.2 5,878.3 42.32 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/16/1995 PRODUCTION, 40 -8,918 N • TO 8,931 • • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 13, 2011 go2-0 47 Commissioner Dan Seamount _ D� Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 AdkitglEk) APR 1 2.01 Commissioner Dan Seamount: 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 and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped November 11, 2001. The corrosion inhibitor /sealant was pumped February 17 and 18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor , • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 4/13/11 2M & 2N PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 2M-05 50103201680000 1920470 Surface NA 16" NA 2.5 2/17/2011 '' 2M -06 50103201760000 1 192 Surface NA 19" NA 2.5 2/18/2011 2M -30 50103201800000 1920840 Surface NA 16" NA 4.25 2/17/2011 2N -303 50103203520000 2001690 26' 5.00 20" 11/8/2001 4.4 2/17/2011 2N -306 50103204900000 2040620 _ SF NA 24"" NA 2 2/17/2011 2N -310 50103205490000 2070900 SF NA 28" NA 5.1 2/17/2011 2N -342 50103205470000 2070680 24" NA 24" NA 7 2/17/2011 10~E10~®RAI~TDLT10~ To: Jim Regg P.I. Supervisor ~ ~C ~~(~~Ll FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June t 1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-OS KUPARUK RIV UNIT 2M-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ '2 Comm Well Name: KUPARUK RN UNIT 2M-OS API Well Number: so-103-20168-00-0o Inspector Name• Jeff Jones Insp Num• mitJJ080610124051 Permit Number: 192-047-0 / Inspection Date• 6/2/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zM-os iT a In'. ~ w s91s yp J TVD ~ IA 1070 I 2930 ;/ I 2850 2870 i 2860 t---- - -- P.T. ~ 1920470 T}'peTest ~ SPT ~ T@St psi ii 1500 ~ OA 430 ~ 620 ~ 620 I 600 ~ 600 I Interval 4YRTST Pte, P ~ Tubing 176s n6s I --- - i765 I 1755 ~ 1755 ~ -- Notes: 2.8 BBLS diesel pumped; no exceptions noted. - ---- `~,~'~~ JUL ~ 4,~ 2008 Wednesday„tune 1 I, 2008 Page 1 of 1 Schlumbepgep ~\.. . ..ft'\ ......1 ,¡ I," c.--'~' / 03/05/07 NO. 4173 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth SCANNED MAR 3 l) 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 t1N< ï. 70tH Field: Kuparuk Û""I0-- l C18- - cH'~ Well Job# Log Description Date BL Color CD 2G-03 11638824 INJECTION PROFILE 02/15/07 1 1 R-08 11628971 INJECTION PROFILE 02/15107 1 1 F-17 11638827 SBHP SURVEY 02/17/07 1 1F-14 11638826 SBHP SURVEY 02/17/07 1 1 F-19 11638828 SBHP SURVEY 02/19/07 1 1C-13 11628977 SBHP SURVEY 02/19/07 1 1C-02 11628978 SBHP SURVEY 02/19/07 1 2M-02 11628979 INJECTION PROFILE 02/20/07 1 35-26 11638813 INJECTION PROFILE 01/21/07 1 1 C-121 11665391 INJECTION PROFILE 02/05/07 1 1J-180 11665390 USIT 02/06/07 1 3J-14 11638825 PROD PROFILE 02/16/07 1 1 J-118 11665392 U51T 02/22/07 1 10-11 11665393 INJECTION PROFILE 02/24/07 1 2M-OS 11665400 INJECTION PROFILE 03/01/07 1 2M-04 11665399 INJECTION PROFILE 03/01/07 1 1 F-13 11665401 INJECTION PROFILE 03/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. I~J . . 02/16/07 SChlumbel'gel' NO. 4142 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth .9.) ,0. ~.1 'U ?OOl Comm!®6í;ANNED FES 2 1 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 UTe.. 19f)-(Y/?- Field: Kuparuk Well Job# Log Description BL Color CD Date 1D-111, 11638816 INJECTION PROFILE 01/24/01 1 1 H-19 . 11663824 INJECTION PROFILE 01/25/01 1 2T -30 . 11663825 PRODUCTION PROFILE 01/26/01 1 2K-02 11663829 PRODUCTION PROFILE 01/30/01 1 3J-02 11632653 INJECTION PROFILE 01/30/01 1 3J-08 11632657 INJECTION PROFILE 02/03/01 1 2M-OS· 11632658 SBHP SURVEY 02/04/01 1 1A-19· 11632660 PRODUCTION PROFILE 02/05/01 1 3J-04· 11628963 INJECTION PROFILE 02/08/01 1 1C-09· 11638818 INJECTION PROFILE 02/09/01 1 2M-26 11638819 INJECTION PROFILE 02/10/01 1 1 D-03 11628961 PRODUCTION PROFILE 02/11/01 1 1C-20 N/A RSTIWFL 02/12/01 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. f/f . . ') MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '7/1.. q(I)/D'- P.I. Supervisor r-..(....t1 ::> DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-OS KUPARUK RIV UNIT 2M-OS ./ ~~)\)( ~~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. suprv"18f2. Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2M-OS Insp Num: mitCS050812194922 Rei Insp Num: API Well Number: 50-103-20168-00-00 Permit Number: 192-047-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. f¥'yI~;;;J;;:~;;!~~I{;p~~~85J¥-.~· ;oo_-t _2~:~o±~f.L:8~Oo_L~~~+--.· ... ~ Interval 4YRTST P/F p Tubing I 3600 . 3600 I 3600 I 3600 I I _'_'_~'...._.."n'_.'._.... ...__..__.._...____. .__... ___._~____u.. J_...___.. .."___.....-----1___ .._._ ....---L_.._ ._..1____..__ Notes: Pretest pressures observed for 30+ minutes and found stable. .' ,~. "'.', C' - n q "':, ("2 n (ItJ~ C.' f' i~ \I\\~. \1..11 Ii:;: &.' "J!" ',-' (, ,J>. ..IJ.¡ ,. \)~flf·\\l,\'n..~H\..-,L. ~,' l..c Wednesday, August 17,2005 Page I of I THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P ~ M C:LO~M.DOC lJ T H E R IA L I'S- T~ E U N R K E D E W E R R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing ~ Alter casiqg ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address Stimulate Repair well 5. Type of Well: Development Exploratory Stratigraphic P. ©. Box 100360, Anchorage, AK 99510 Service Plugging Perforate Other X 6. Datum elevation (DF or KB) RKB 146 feet 7. Unit or Property name 4. Location of well at surface 114' FSL, 64' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1386' FNL, 1592' FWL, SEC 28, T11N, R8E, UM At effective depth 1250' FNL, 1461' FWL, SEC 28, T11N, R8E UM At total depth 1202' FNL, 1416' FWL, SEC 28, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Kuparuk River Unit 8. Well number 2M-05 9. Permit number/approval number 92-47/95-103 =,10. APl number 5o-1 03-201 68 11. Field/Pool Kuparuk River Field/Oil Pool 8 9 31 feet Plugs (measured) 6309 feet Effective depth: measured 8828 feet true vertical 6230 feet Junk (measured) Casing Length Size Cemented Structural Conductor 121' 1 6" 214 SX ASI · Surface 31 25' 9 5/8" 430 SX PR E Intermediate 540 SX CLASSG Production 8 8 91 ' 7" 200 SX CLASS G Liner Perforation depth: measured 8535' - 8562', 8574' - 8601' true vertical 6005' - 6026', 6035' - 6056' Tubing (size, grade, and measured depth) 3 1/2", 9.3# J-55 @ 8457' Packers and SSSV (type and measured depth) Baker F-1 @8421', Camco TRDP-4A-MOD @ 1826' Measured depth 121' 3167' 8915' True vertical depth 121' 2750' 6297' 13. Stimulation or cement squeeze summary Converted well from oil producer to WAG injector. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 1 83 31 151 0 1345 0 0 2 2 0 0 45O Tubing Pressure 239 2400 15. Attachments Wellbore Schematic Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ 16. Status of well classification as: Oil Gas - Suspended__ Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S'~ned~~ ~/ Title Wells Superintendent Form 10-404 Rev 06/15/88 Date ~/~~"' SUBMIT iN DUPLICATE WELL 2M-05 INJECTOR APl #50-103-20168 SURFACE LOCATION: 114' FSL, 64' FWL, SEC 27, T11N, R8E, UM TOP OFKUPARUK: 1320'FNL, 1590'-FWL, SEC28, T11N, R8E, UM TD LOCATION: 1144' FNL, 1418' FWL, SEC 28, T11N, R8E, UM DEPTHS: REFERENCED TO 146' RKB ALL DEPTHS MD-RKB WELL TYPE: Oil Producer TUBING HEAD FLANGE RKB=39.90' 16": 62.5# H-40 @ 121' 9.625": 47# L-80 @ 3166' Baker LOC Seal Assy: 2.985" ID @ 8420 Baker F-1 PERM PKR: 4.0" ID @ 8421' CAMCO D NIPPLE: 2.75" ID @ 8444' Baker SHEAR OUT: 2.875"1D @ 8456' C4 B A3 7": 26# J-55 @ 8915' VOLUME: 0.0383 BBL/FT PBTD: 8828' L SPUD:5/28/92 COMPLETION: 12/15/92 SSSV: CAMCO TRDP-4A-MOD @ 1826' GLMI: GLM2: GLM3: GLM4: GLM5: 3240'/MACCO SPM-1A/1.0"/DV 6074'/MACCO SPM-1A/1.0"/DV 7575'/MACCO SPM-1A/1.0"/DV 8229'/MACCO SPM-1A/1.0"/DV 8368'/CAMCO MMG2/1.5"x1.5" DV 3.5" 9.3# J-55 EUE, @ 8457' VOLUME: 0.00870 BBL/FT HOLE ANGLE ACROSS KUPARUK = 40.0 DEGREES MAX. HOLE ANGLE = 55 DEGREES @ 7350' VOLUME TO TOP PERF = 78.0 BBLS 8535-8562', 4 SPF O° PHASING 2/24/95 8573'-8600' (27'), 4 SPF, 180° @ 125° CCW LAST TAG DATE: 7/15/95 @ 8560' RKB REVISED: CJF/EZ ARCO Alas , Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Mark E. Eck Wells Superintendent Kuparuk Production NSK-69 Phone: 659-7226 Fax: 659-7314 May 31, 1995 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Application for Sundry Approvals (Form 10- 403) and in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) on the following Kuparuk wells. Well Form Action - 2M-05 I O-4O3 2M-05 10-40.4 · -- 2M-18 10-403 ¢'2T- I 0 10-403 3F-10 10-404 3G- 18 1 O-4O4 (Other) Conversion Perforate (Other) Conversion (Other) Conversion Stimulate Perforate If you have any questions, please call me at 659-7226. Sincerely, M. E. Eck Attachments Well Files (attach only) File: FTR 053196 (w/o attach) RE6EiVED JUN 0 ? 7995 Alaska Oil & Gas Cons. Commission Anchoraj~ ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Type of Request: Abandon 2. Name of Operator 3A. RACd?resAslaS ka, Inc. _ Suspend _ Operation Shutdown_ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program_ Pull tubing _ Variance _ Perforate _ Other X (CONY) P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_%_ Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 114' FSL, 64' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1386' FNL, 1592' FWL, SEC 28, T11N, R8E, UM At effective depth 1250 FNL, 1461' FWL, SEC 28, T11N, R8E, UM At total depth 1202' FNL, 1416' FWL, SEC 28, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8931' feet Plugs (measured) 6309 feet 6. Datum elevation (DF or KB) RKB 146 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-05 9. Permit number 92-47 10. APl number 50-103-20168 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 8828' feet Junk (measured) 6230' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 121' 1 6" 214 SX ASl 3167' 9 5/8" 430SXPRE 540 SX CLASSG 8 91 5' 7" 200 SX CLASS G measured 8535' 8562', 8574" - 8601' true vertical 6005' 6026', 6035' - 6056' Measured depth True vertical depth 121' 121' 3167' 2750' 8915' Tubing (size. grade, and measured depth) 3 1/2", 9.3# J-55 @ 8457' ~ackers and SSSV (type and measured depth) Baker F-1 @8421', Camco TRDP-4A-MOD @ 1826' 6297' RECEIVED JUN 0 1 1995 Atsska 0il & Gas Cons. Commissi Anchora ie 13. Attachments Description summary of proposal X CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR. Detailed operation program _ BOP sketch 14. Estimated date for commencing operation JULY 1, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended To be reclassified as: Service WAG INJECTOR 17. I hereby certify that the fore,,~g,j,s, true Signe~/~~('''' ~ and correct to the best of my knowledge. Title Wells Superintendent FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity __ BOP Test _ Location clearance __ 6~ OO~::)~ I ~,.~' / 0 _~ Mechanical Integrity Test ~ Subsequent form require 10-~0¢-~,oo..-,,.,~,O~_ '-~ 0rJgJna., Signed BYw. Johnston David .~' Approved by order of the Commission ~.U Commissidner Date ~J /~ '~ ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Kuparuk Well 2M-05 ARCO Alaska requests approval to convert Well 2M-05 from an oil producer to a water injector. This well will be operated as a Class !1 UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6005" and 6056~ TVD. This interval correlates with the strata found in ARCO's West Sak River State Well No, 1 between the depths of 6474' and 6880' as authorized in Rule I of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 114' FSL, 64' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1386' FNL, 1592' FWL, SEC 28, T11N, R8E, UM At effective depth 1250' FNL, 1461' FWL, SEC 28, T11N, R8E UM At total depth 1202' FNL, 1416' FWL, SEC 28, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 8931 ' feet 6309 feet Plugs (measured) 6. Datum elevation (DF or KB) 146' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-05 9. Permit number/approval number 92-47 10. APl number 50-103-20168 11. Field/Pool Kuparuk River Oil Pool feet Effective depth' measured 8828' feet true vertical 6230' feet Junk (measured) Casing Length Size Cemented Structural I 21' 1 6" 214 SX ASI Conductor Surface 3167' 9 5/8" 430 SX PR E Intermediate 540 SX CLASSG Production Liner 8 91 5' 7" 200 SX CLASS G Perforation depth: measured 8535' - 8562', 8574' 8601' true vertical 6005' - 6026', 6035' - 6056' Tubing (size, grade, and measured depth) 3 1/2", 9.3# J-55 @ 8457' Packers and SSSV (type and measured depth) Baker F-1 @8421', Camco TRDP~4A-MOD @ 1826' 13. Stimulation or cement squeeze summary Perforate C4 Sand w/4 SPF @ 0° Phasing Intervals treated (measured) 8535' 8562' Treatment description including volumes used and final pressure Measured depth 121' True vertical depth 121' 3167' 2750' 8915' 6297' RECEIVED :llj,~! 0 ? i995 AJaska Oil & Gas Cons. Commission .4nchora 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 0 4 1 4 6 8 I 1 2 4 1340 110 Subsequent to operation 5 2 1 1 2 5 1 1 2 6 8 1,~. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Water Injector __ Dally Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1325 Service 110 Form 10-404 Rev 06/15/88 Title Wells Superintendent SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL DESCRJIPTION OF WORK 2M-05 C4 PERFORATING DATE 2/24/95 DAY 1 TIME 1500 1630 1700 1820 1830 1900 1930 2000 ! ! CONTRACTOR / KEY PERSON SCHLUMBERGER/BAILEY PBTD (RKB) [LAST TAG (RKB) . DATE 8828' ! 8580'- 2/08/95 FIELD COST EST. $13,471 SSSV TYPE / STATUS KUPARUK RIVER UNIT WELL SERVICE REPORT IAFC/CC# . SCA# K84959 ACCUMULATED $13,471 CAMCO TRDP-4A-MOD COST LOG ENTRY MIRU SWS. HELD SAFETY MEETING. FTP - 250 #, IA - 1300 #, OA - 1100~ PRESSURE TEST LUBRICATOR TO 3000 PSIG. TEST OK. R/H W/PERF GUN - 4' WGT., CCL, MPD, 2-1/8" ENERIET I11 @ 4 SPF, 0 DEG PHASING TO PERF 8535' - 8562'. ON BOTTOM AND TIED-IN USING CET DATED 6/10/92. IN POSITION @ 8530.2' TO SHOOT 8535'-8562'. FIRED GUNS. POH. AT SURFACE W/GUN. INSPECT GUN; ALL SHOTS FIRED. COMPLETE RD. TURN WELL OVER TO PROD. MO. FTP- 260#, IA- 1300#, OA- 1100~ SUMMARY: PERFORATE C4 SAND @ 8535'- 8562' · . I ICHECK TttlS BLOCK IF SUMMARY IS CONTINUED ON BACK ~ ...... . _ ~_~,7.~ W~mer ITemp. I~l!! Factor IV~bm, IW~d Vel. IS~ ? ........ ~ ...... ------~ ; .... Z ---~7.~~ ~ ~.~-~- PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 11/10/94 RUN DATE_RECVD 92-047 5311 92-047 SURVEY 92-047 SURVEY 92-047 DAILY WELL OP 92-047 407 T 3041-8929 OH/CDR&CDN R 0.00-8931 GCT 92-047 CET L 5815-8823 92-047 CDR L 3110-8930 92-047 CDN L 2940-8930 92-047 CBT L 5815-8781 1 06/29/92 07/20/92 01/20/92 01/20/92 01/20/92 1 06/18/92 1 06/18/92 1 06/18/92 1 06/18/92 Was the well cored? ~no /~n,aly~s ~ Are well tests require~ no Received? Well is in compliance ~~~aln° COMMENTS And received? description received? yes no yes no yes no ARCO AlasKa, inc. ?os~ C ific3 2o:-. Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 11, 1994 Mr, David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 'Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION *, ?;--- i.~3 2M-01 Stimulate ~,?~ - 5'~'¢ 2M-05 Stimulate ~:.- ;..or 2M-08 Stimulate o/~_-~0 2M-12 Stimulate ¢1 ~.-~ 2M-27 Stimulate ~ 7..-?o 2M-28 Stimulate qz-~off 2M-32 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ....... Ancb0rag~ ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA .... '~ ALNsr~ OIL AND GAS CONSERVATION COMMIS,_. .. !N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed' Operation Shutdown__ Pull tubing Alter casing 2. Name of Operator ARCO Alaska. In0. 3. Address P. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Stimulate X Plugging ... Perforate _ Repair well Other 6. Datum elevation (DF or KB) Location of well at surface 114' FSL, 64' FWL, SEC 27, T11N, R8E, UM At top of productive interval 1386' FNL, 64' FWL, SEC 28, T11N, R8E, UM At effective depth At total depth 1202' FNL, 64' FWL, SEC 28, T11N, R8E, UM Present well condition summary Total Depth' measured true vertical 12. 8931 ' feet 6309 feet 146' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-~)5 9. Permit number/approval number 10. APl number 5a-103-21068 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) Effective depth: measured 8828' true vertical 6230' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 121' 16" 31 67' 9 5/8" 8915' 7" measured 8574'- 8601' true vertical 6035' - 6056' Cemented 214 SX ASI 430 SX PR E 540 SX CLASSG 200 SX CLASS G Tubing (size, grade, and measured depth) 3 1/2", 9.3# J-55 @ 8457' Packers and SSSV (type and measured depth) Baker F-1 @8421', Camco TRDP-4A-MOD @ 1826' Measured depth 121' 3167' 8915' True vertical depth 121' 2750' 6297' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure /.,,,::,.:.;.k~ 0il & 6as Cons. C0mmissi 14. Pressure Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Prior to well operation Subsequent to operation (Stabilized) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 2627 1488 0 1220 psi 16. Status of well classification as' Water Injector __ Oil X Gas Suspended Service 270 psi 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢~~o ~ Tit,e Senior Engineer Form 10-404 Rev 06/15/88 Date / -'"//~("¢f SUBMIT IN DUPLICA'rE March 27, 1993 2M-05 GSW DATAFRAC W/DOWELL. PUMP 3 SLK WTR PI/SI'S & GSW MINIFRAC @ 25 BPM. DATA AS FOLLOWS: STEP VOLUME FWHTP ISIP CLOS P FG PERF/XS FRIC PI/SI#I 150 3900 1200 3425 .64 1009 PI/SI#2 50 3740 1200 3425 .64 849 PI/SI#3 10 3704 1049 3425 .61 964 MINIFRAC 300 3748 1515 3775 .69 415 FE=49% (SMART CLOS TIME), 50% (DOWELL), NO CHANGE TO PAD SIZE. GSW REFRAC W/DOWELL. PUMP 240 BBL PAD @ 25 BPM, LAST WHTP=4468 PSI. PUMPED 22.1 MLBS 16/20 CL IN 1-2 PPA STAGES & 220.6 MLBS 12/18 CL IN 4-14 PPA STAGES @ 25 BPM, LAST WHTP=5635 PSI. FLUSH W/76 BBL GW/SLK WTR/SLK DSL @ 25-3 BPM, LAST WHTP=6345 PSI. TRT PRESS INC F/5700-6700 PSI 31 BBLS INTO FLUSH, CUT RATE F/25-12 BPM. CUT RATE F/12-3 BPM DURING REMAINER OF FLUSH TO MAINTAIN TRT PRESS BELOW 7000 PSI MAX. TOT PROP: DESIGN=199.9 MLBS, IN FORM=241.1 MLBS W/14.0 PPA @ PERFS. TOT FLUIDS: WATER=1584 BBL, DSL(FLA + FLUSH)=70 BBL, ADD'S=ll9 BBL. ALL FLUIDS LOOKED EXCELLENT. SMART COMPUTER WORKED GOOD. (TOTH/BRADLEY) RECEIVED i ..., ..~ ' - { .,.,~ ,",.::.:::.'.i.',~. u:~ & Gas Cons. Commission Anchorag~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~'~ GAS r~ SUSPENDED [] ABANDONED r'"] SERVICE r~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc ~ 92-47 3 Address 8 APl Number P.O. Box 100360, Anchorao~e, AK 99510-0360 50-103-20168 4 Location of well at surface ~- ........... 9 Unit or Lease Name ~ .-.-~,~T KUPARUK RIVER 114'FSL, 64'FWL, SEC27, T11N, R8E, UM ~ ~ At Top Producing Intewal ~ .... /-.~./~___. i~~ ~ i ji,~a~,,~r 10 Wel12M-05Number 1386' FNL, 1581' FWL, SEC28, TllN, R8E, UM ~;~-~:'" At Total Deplh ~ --~.,~. ~_.... ~:? 11 Field and Pool 1202' FNL, 1415' FWL, SEC 28, T11N, RSE, UM KUPARUK RIVER FIELD 5 Elevation in lee{ {indicata KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 146', PAD 105' GLI ADL25686, ALK 2672 12 Date Spudded 13 Dat® T.D. Reached 14 Date Comp., Sump. or Al:~nd. I 15 Water Depth, if offshore 116 No. oi Completions 05129192, 06104/92, 12/15/92,I NA feet MSLI 1 ,, 17 Total Depth (MD+TVD) 18 Plug Back D~pth (MD+'rVD) 19 DireCtional Survey 20 Depth where SSS¥ set 21 Thickness of permafrosl 8931' MD, 630~' TVD 8828' MD, 6230"rVD YES--[~ NO E~ 1827' re. MD 1400' APPROX 22 Type Electric or Othar Logs Run CDR,CDN, GR, CET, CBT, GYRO 23 CASING, UNER AND CEMENTING RECORD I SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SI71~ CEMENTING RECORD AMOUNT PULLED 16' 62.$# H-40I SURF 121' 24' 214SXASI 9-5/8' 47#/36~ L-80/J-55 SURF 3167' 12-1/4' 430 SX PF E, 540 SX CLASS 7" 264~ J-55 SURF 8915' 8-1/2' 200 SX CLASS 24 Periomfions open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET IMD/ PACKER SET {MD) 3-1/2' 9.3~ J-55 8457' 8421' 8574' -8601' W/4-1/2' CSG GUN ~ 4 SPF MD 6035'-6056' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMelhod of Operation (Flowing, gas lift, etc.) I , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-IVlCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ,~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (con') Press. 24-HOUR RATE Bdef description of lithology, porosity, fractures, al3parant dips and preseace of oil, gas or Water. Submit core chips. Form 10407 Submit in duplicate Rev. 7-1-80 CONTII~ED ON REVERSESDE NNv~ Include interval tested, pressure data, all fluids recoverd and gravity, IVF__AS. DEPTH TRUE VERT. DEPTH GOR, and time o~ each phe. se. KUPARUK C TOP 8534' 6005' NA KUPARUK C BO'FI'OM 8552' 6018' KU PARUK A TOP 855Z 6018' KUPARUK A BO3-1'OM 8695' 6128' : : · . ., . 31. LIST OF ATTACHMENTS GYRO, REPORT OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best o~ my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, ROd Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 2M-05 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER 50-103-20168 ACCEPT: 05/29/92 08:05 SPUD: 05/29/92 06:05 RELEASE: 12/15/92 11:30 OPERATION: DRLGRIG: PARKER 245 WO/C RIG: NORDIC I 05/16/92 (1) TD: 141'( 141) 05/17/92 ( 2) TD: 141'( 0) 05/18/92 (3) TD: 141'( 0) PREPARE TO MOVE TO 2M-5 16"@ 121' MW: 0.0 VIS: 0 SECURE EQUIPT IN CELLAR F/PAD MOVE, REMOVE FLOWLINE & BASKET F/BRIDGE CRANE, BLOW DOWN STEAM LINE IN DRLG MOD. PREPARE TO MOVE TO 2M-5 16"@ 121' MW: 0.0 VIS: 0 MOVING DRLGMOD & UTILITY MOD TO 2M PAD; DRLG MOD, PREPARE CELLARBOX TO BE RAISED. LOOSEN STORM CLAMPS, SKID RIG BACK TOWARDS CENTER OF MOD.(OFF CANTILIVER), RAISE CELLARBOX, INSTALL SAFETY LINES, TIGHTEN STORM CLAMPS, RAISE DRLG MOD & SET ON CRIB BLOCKS, ROTATE MOD TO ROAD POSITION. MOVE DRLG MOD OFF 3R PAD, @ 21:30 DRIVE CHAIN ON %2 LAMPSON BROKE WHILE TURNING MOD ONTO OLIKTOK ROAD. BACK CHAIN #2 CRAWLER LEFT TRACK, REPAIRED CHAIN @ 02:30, CONT MOVING DRLG MOD, ARRIVE @ STAGING PAD @ 05:00, ARCO CREW CHANGE. UTILITY MOD, RAISE & SET ON BIG CRIB BLOCKS, MOVE MOD OFF MATTING BOARDS, ROTATE MOD TO ROAD POSITION & MOVE TO 2M PAD, @ E PIT CUT-OFF @ 06:00. MOVING RIG TO 2M-5 16"@ 121' MW: 0.0 VIS: 0 MOVE DRLG MOD I MILE, 07:00-09:30, L.H. ENGINE LAMPSON #1 DIED, WORK ON SAME, REFILL CHAIN OILERS, CHECK BRAKES 09:30-10:15, MOVE .4 MILES, BROKE SECONDARY DRIVE CHAIN #2 @ 10:15-11:30, REPAIR CHAIN 11:30-12:00, SERVICE BOTH LAMPSON'S, TIGHTEN BOTH BOLSTERS, CONT MOVE DRLG MOD AROUND CORNER, BROKE SECONDARY DRIVE CHAIN TWICE %2 L.H. TRACK, REPAIR SAME 24:00-03:30, CONT MOVE, @ E-PIT CUT-OFF @ 06:00. UTILITY MOD AT E PAD CUT-OFF @ 06:00 5/17, MOVE TO 1K PAD, 50 YDS PAST CPF-3 BROKE SECONDARY DRIVE CHAIN ~4, REPAIR CHAIN 12:00-15:00, BACK MOD TO CPF-3 & PARK FOR GRAVEL TRUCKS TO PASS FOR ROAD REPAIR FOR DRLGMOD 15:00-15:30, UTILITY MOD PARKED F/15:30-24:00, CONT MOVE @ 00:45, @ lQ TURN OUT @ 05:00, CREW CHANGE. WELL : 2M-05 OPERATION: RIG : PARKER 245 PAGE: 2 05/19/92 (4) TD: 141'( 0) 05/20/92 (5) TD: 141'( 0) 05/21/92 (6) TD: 141'( 0) 05/22/92 (7) TD: 141'( 0) MOVING RIG TO 2M-5 16"@ 121' MW: 0.0 VIS: 0 CONT MOVE TO 2M PAD DRLG MOD-@ E-PIT CUTOFF, WAIT ON RIG TRUCK W/MATS TO PASS, CONT MOVE F/07:50-09:30 .7 MI, GREASE LINES FOR TRACK CARRIAGE ROLLERS BROKEN, REPAIR SAME F/09:30-16:00, CONT MOVE TO CPF-3 (1.9 MI), @ CPF-3 @ 21:00, PER ARCO WAIT FOR AMBULANCE TRANS 21:00-06:00, SERVICE LAMPSONS WHILE WAITING, TIGHTEN SECONDARY DRIVE CHAIN 92 L.H. TRACK, CHECK STORM CLAMPS, DERRICK SHOE BOLTS, TURNBUCKLES, GREASE TRACK ROLLERS. UTILITY MOD-@ lQ PAD, CONT MOVE, @ TOOLHOUSE @ 12:00, MOVE TO OLIKTOK-SPLINE ROAD INTER 12:00-14:00, STOP @ INTER PER ARCO F/14:00-19:00, CONT MOVE 19:00-06:00, @ CPF-3 @ 03:15. WITHIN AN HOUR OF 2B PAD @ 06:00. WAITING ON CPF CREW CHANGE 16"@ 121' MW: 0.0 VIS: 0 CONT MOVE TO 2M PAD DRLG MOD- STOPPED @ CPF-3 PER ARCO, CONT MOVE @ 13:00-18:00 TO lQ PAD, REPAIR DRIVE CHAIN # 2 & GREASE LINES FOR TRACK ROLLERS 18:00-23:00, CONT MOVE, @ OLIKTOK Y STOP FOR CPF-2 & 3 CREW CHANGE @ 06:00. UTILITY MOD- WAIT FOR ORDERS @ 2B PAD @ 07:10-08:45, CONT MOVE TO 11:15, STOP TO REPAIR FITTING ON TORQUE CONVERTER %4 & REPAIR KEEPER PINS 11:15-11:45, CONT MOVE TO INTER, APPROX 2M F/2M PAD, SEAL LEAKING ON TORQUE CONVERTER PUMP, WAIT ON PARTS 14:00-24:00 MOVING RIG TO 2M-5 16"@ 121' MW: 0.0 VIS: 0 CONT MOVE TO 2M PAD DRLG MOD- CONT MOVE, CPF-2 &3 CREW CHANGE @ 4:30-7:00, STOPPED @ INTER FOR ROAD REPAIR (SIDE SLOPE CORR.) F/4:30-6:00 UTILITY MOD- STOPPED 3 MILES FROM 2M PAD, WAIT ON PARTS TILL 14:00, REPAIR RADIATOR FAN PUMP 14:00-14:30, MOVE MOD TO 2M PAD, MOD ON PAD & PARKED @ 21:30, SERVICE UNITS MOVING RIG TO 2M-5 16"@ 121' MW: 0.0 VIS: 0 CONT MOVE TO 2M PAD DRLG MOD- BROKE DRIVE CHAIN, REPAIR F/6:00-7:30, CONT TO MOVE RIG TO 2Z ACCESS ROAD, STOP FOR TRAFFIC F/ 9:30-10:30, CONT TO MOVE, HAVE TO PLYWOOD CURVES, DRLG MOD CANNOT COUNTER ROTATE IN GRAVEL ROADBED. BROKE & REPAIR SECONDARY DRIVE CHAIN ON #2 UNIT, GREASE LINES AND GUARD, CONT TO MOVE RIG TO 2X ACCESS ROAD, STOP FOR TRAFFIC F/ 24:00-1:30, CONT TO MOVE, COVERED 3.8 MILES IN LAST 24 HOURS @ 6:00 WELL : 2M-05 OPERATION: RIG : PARKER 245 PAGE: 3 05/23/92 (8) TD: 141'( 0) 05/24/92 (9) TD: 141'( 0) 05/25/92 (10) TD: 141' ( 0) 05/26/92 (11) TD: 141' ( 0) PREP TO LAY DERRICK DOWN 16"@ 121' MW: 0.0 VIS: 0 CONT MOVING TO 2M PAD DRLG MOD- @ 6:00 ON CPF-2 BALL CAME OUT OF UNIVERSAL BOLSTER DAMAGING BOLSTER AND ONE 375 TON JACK, PARK RIG @ CPF-2, SET RIG DOWN, UNHITCH LAMPSON UNITAND, PREP DERRICK TO LAY DOWN, ORDER CRANES, LOAD OUT MATTING BOARDS TO DOUBLE MAT KUPARUK RIVER BRIDGE PREP TO LAY DOWN DERRICK 16"@ 121' MW: 0.0 VIS: 0 CONT MOVE TO 2M PAD DRLG MOD- FIN WALKING UTILITY LAMPSON UNIT F/2M TO CPF-2, MAKE REPAIRS ON UTILITY LAMPSON BOLSTER, PREP DERRICK TO LAID DOWN, MOVE DRILLING TOOLS FROM RIG FLOOR TO PIPE SHED, INSTALL MATTING BOARDS UNDER RIG END OF DRLG MOD, SKID RIG TO DRILLING POSITION, LAY DOWN PIPE HANDLING EQUIP AND TORQUE TUBE FOR TOP DRIVE, LAY DOWN STABBING BOARD, PLACE TOP DRIVE ON TRANSPORT SKID, INSTALL STOP PLATES, PREP TOP DRIVE TO BE LAID DOWN. UTILITY MOD- LOAD OUT CAMP, SDS PLANT, AND SHOP TO 2M PAD, SPOT & RU CAMP, SDS PLANT AND SPOT SHOP, CAMP RIGGED UP @ 20:00 PREP TO LOAD OUT DERRICK 16"@ 121' MW: 0.0 VIS: 0 CONT MOVE TO 2M PAD DRLG MOD- RIG DOWN TOP DRIVE, SERVICE LOOP AND HANG IN DERRICK, REMOVE UPPER ROLLERS AND HILLMAN ROLLERS FROM TOP DRIVE CARRIER, RIG DOWN FRONT WINDWALLS, SPLIT TRANSPORT CARRIERAND LAY DOWN TOP DRIVE, LAY DOWN 500 TON BALES AND COUNTER BALANCE REINSTALL WORKING RAIL, SKID 6" TO CENTER MARK, TIGHTEN STORM CLAMPS, BRIDLE DERRICK FOR LAYING DOWN, LAY DERRICK DOWN & PREP TO MOVE FROM RIG FLOOR, LAY PLYWOOD ON SOFT SOPTS IN ROAD F/CPF-2 TO 2M PAD, REMOVE DERRICK F/RIG FLOOR AND PREP TO LOAD OUT. PREP TO LOAD OUT DERRICK 16"@ 121' MW: 0.0 VIS: 0 CONT MOVE TO 2M PAD DRLG MOD- SET DERRICK ON TRUCKS FOR MOVE TO 2M PAD, REPLACE FUEL TANK ON RIG, JACK RIG TO CENTER OF MOD FOR RIG MOVE, JACK UP RIG AND REMOVE RIG MATS, CLEAN PANS ON LAMPSONS UNITS, LAY PLYWOOD FOR RIG MOVE, MOVE RIG 200 YDS AROUND CORNER OF CPF-2, REPAIR GREASE LINES FOR TRACK CARRIAGE ROLLERS, MOVE F/CPF-2 TO 2B PAD, ARRIVE @ 2B @ 22:40, REPAIR GREASE LINES AND KEEPERS FOR TRACK CARRIAGE ROLLERS, SERVICE LAMPSON UNITS, MOVE F/2B TO 2M ACCESS ROAD. WELL : 2M-05 OPERATION: RIG : PARKER 245 PAGE: 4 05/27/92 (12) TD: 141'( 0) 05/28/92 (13) TD: 141'( 0) 05/29/92 (14) TD: 141' ( 0) 05/30/92 (15) TD: 1380' (1239) 05/31/92 (16) TD:. 2685' (1305) PREP TO PICK UP DERRICK 16"@ 121' MW: 0.0 VIS: 0 CONT MOVE TO 2M PAD DRLG MOD- CONT MOVE F/2B PAD TO 4-WAY INTER, WORK ON LAMPSON AIR LINE, REPAIR GREASE LINES, ALLOW TRAFFIC TO PASS, CONT MOVE, F/11:30-14:30 REPAIR GREASE LINES ON CRAWLER, SERVICE LAMPSON, CONT MOVE, F/15:00-19:00 REPAIR LAMPSON GREASE LINES AND AIR COMPRESSOR GASKET, CONT MOVE, ARRIVE @ 2M PAD @ 21:36, SPOT DRILLING MOD ON MATTING BOARD, RIG UP TO PICK UP DERRICK. PREP TO MOVE DRLG MOD TO 2M-05 16"@ 121' MW: 0.0 VIS: 0 INSTALL MONKEY BOARD, PIN DERRICK AND RAISE SAME. PICK UP AND INSTALL TOP DRIVE COUNTER BALANCE. PICK UP AND INSTALL TOP DRIVE AND HILLMAN ROLLERS. INSTALL WIND WALLS AND PIPE SHED COVER. SLIDE DRILLING RAILS INTO POSITION AND PIN SAME. MAKE UP STAND PIPE AND CMT LINE. HANG BRIDLE LINES. SET MATTING VOARDS AND PREPARE TO MOVE DRLG MOD TO 2M-05. ASSEMBLING TOP DRIVE 16"@ 121' MW: 9.0 VIS: 41 MOVE DRLG MOD TO 20' OF WELL. REMOVE LARGE CRIB BLOCKS, INSTALL AND SET MOD ON SMALL CRIB BLOCKS, SPOT DRLG MOD OVER 2M-05 & REMOVE CRIB BLOCKS, LOWER CELLAR. REMOVE LAMPSON UNIT F/DRLG MOD & INSTALL IN UTILITY MOD, MATE UTILITY MOD TO DRLG MOD, NU DIVERTER STACK & LINES, FLOOR IN CELLAR, MUD LINE, CMT LINE, CHOKE & KILL LINES. CHANGE HANDLING RING AIR SWIVEL IN TOP DRIVE, HOOK UP ELECTRIC & GLYCOL LINES TO TOP DRIVE, MU UPPER & LOWER KELLY VALVES AND SAVER SUB. INSTALL EQUIP FOR INSIDE BOP, INSTALL CLAMPS, REMOVE MATTING BOARDS, SPOT & RU CPM, MIX SPUD MUD, BEGIN REMOVING DP F/UTILITY MOD & CONT ASSEMB TOP DRIVE. DRILLING @ 1380' 16"@ 121' MW: 9.1 VIS: 58 REPAIR TOP DRIVE. ACCEPT RIG AT 0830 ON 5/29/92. NU DIVERTER. MU BHA W/ 1 DEGREE AKO. FUNCTION TEST DIVERTER. SPUD @ 1830 HRS 5/29/92. DRILL 12-1/4" HOLE TO 1380'. DRILLING 16"@ 121' MW: 9.6 VIS: 60 DRILL FROM 1380 TO 1700. CHANGED SHAKER SCREENS IN CPM. DRILL 1700 TO 1957, HOLE PACKED OFF AND LOST RETURNS. PU TO 1777 AND PULLED FREE. CIRC AND WASH TO BOTTOM. DRILL 1957 TO 2647, HOLE PACKED OFF AND LOST RETURNS. PU AND PULLED FREE. CIRC AND WASH TO BOTTOM AT 2647. DRILL 2647 TO 2685, PUMP PRESSURE INCREASED FROM 2500 PSI TO 3200 PSI. POOH. CO NAVI DRILL MOTOR, RR BIT. SLIP AND CUT DRILL LINE. RIH TO 2647. WELL : 2M-05 OPERATION: RIG : pARKER 245 PAGE: 5 06/01/92 (17) TD: 3186' ( 501) 06/02/92 (18) TD: 3958'( 772) 06/03/92 (19) TD: 8053' (4095) 06/04/92 (20) TD: 8931' ( 878) 06/05/92 (21) TD: 8931'( 0) 06/06/92 (22) TD: 8931'( 0) CEMENTING 9 5/8 CASING 9-5/8"@ 3166' MW: 9.7 VIS: 49 DRILL FROM 2685 TO 3186. WIPER TRIP FOR CASING. RUN 75 JOINTS 9 5/8" CASING. CIRC THRU BRIDGE AT 2230. PUMPED 165 BBLS LEAD CMT AND 111 BBLS TAIL CMT. BUMP PLUG AT 0600. NO CMT TO SURFACE, FULL RETURNS EXCEPT ROUNDING SHOE LOST 23 BBLS, RECIP PIPE THROUGHOUT UNTIL 133 BBLS INTO DISPLACEMENT. DRILLING 9-5/8"@ 3166' MW: 8.8 VIS: 31 ND DIVERTER. DO TOP CMT JOB. MU CSG HEAD. NU BOP AND TEST. RIH TO 3084. DRILL CMT, FC AND TEST CASING. DRILL CMT AND FS AND 10' NEW FORM. TEST OH TO 12.5 EMW. DRILL 3196 TO 3958. DRILLING 9-5/8"@ 3166' MW:10.4 VIS: 44 DRILLED 8.5" F/ 3958 TO 8019. LR AT 6 BPM, PUMP WALNUTS AND MICA, STILL LR AT I BPM. LET STAND 20 MIN. DRILLED F/ 8019 TO 8058 W/ FULL RETURNS. SHORT TRIP FOR CASING 7"@ 8914' MW:10.3 VIS: 47 DRILLED 8.5" HOLE FROM 8019 TO 8931, TD. CIRC AND COND MUD, TRIP 15 STANDS. SWABBED 5 BBLS. RIH TO CIRC BOTTOMS. RUN 7 CASING 7"@ 8914' MW:10.3 VIS: 44 CIRC AND COND MUD, DRY JOB. POOH TO SURF CASING SHOE. WORK TIGHT AREA F/ 3960-3700. REPAIR GLYCOL HOSE ON DRUM FLANGE. CUT AND SLIP DRIL LINE. RIH AND WASH TO 8931, CIRC BOTTOMS. DRY JOB. POOH, L/D 30 JTS 5" DP, LWD TOOLS, AND BHA. RETRIEVE WEAR BUSHING. R/U 7" CASING. P/U 7" CASING, TRICO SHORT CENTRALS TOO TIGHT SUGGEST LARGER BOW SPRING CENTRALS. RIH W/ 7" CASING. RIG RELEASE 7"@ 8914' MW:10.3 VIS: 57 RIH W/ 7" CSG. LR AT 4600. RECIPROCATED LOST 29 BBLS, HOLE FULL. RIH W/ CSG TO 5250, CIRC NO GOOD. RIH W/ CSG TO 8915, NO RETURNS. ADDED LCMAND FILLED PIPE. CIRC WHILE RECIP PIPE, LR 325 BBLS. R/U HALLIBURTON AND MIX CMT. RAN CLASS G CMT, BUMPED PLUG. R/D HALLIBURTON. FLUSH, N/D,AND P/U STACK. SET SLIPS. L/D LANDING JOINT, CSG TOOLS. N/D BOPE STACK. WELL : 2M-05 OPERATION: RIG : NORDIC PAGE: 6 12/15/92 (23) TD: 8931 PB: 8828 12/16/92 (24) TD: 8931 PB: 8828 PREP TO MVE RIG F/ 2B TO 2M 7"@ 8914' MW: 0.0 SERV GENERATORS & SPLITTER BOX. HELD SAFETY MEETING. MVE RIG F/2B TO 2M. MOVE RIG OVER WELL. LEVEL RIG. ND DRY HOLE TREE. SET TEST PLUG. MU BOP. TAKE ON FLUID. BREAK STACK ABOVE MUD CROSS. ROTATE 180 DEGREE. NU. BLIND RAMS LEAKED AT LOW PRESS. OPEN DORRS AND INSPECT RAMS. NO APPARENT DAMAGE. CLOSE DOORS. RETEST. OK. TEST MUD PMP TO 4500 PSI. TEST BOPE TO 3000 PSI. PULL TEST PLUG. PRESS 7" CSG TO 3500 PSI F/30 MIN. RU SWS. MU 4.5" PERF GUNS & RIH. LUB TESTED TO 1000 PSI. TIE IN W/CDR LOG DATED 6/1-6/4/92, ORIENT & FIRE GUNS IN A3 ZONE. POOH. GUN 91, 20' LONG, PERF F/8581'-8601', 127 DEGREE CCW, ASF. GUN #2, 7' LONG, PERF F/8574'-8581', 124 DEGREE CCW, ASF. LOAD TBG INTO PIPE SHED. DRIFT, STRAP, & INSTALL SEAL RINGS. MU JB & 6.0" GUAGE RING & RIH TO 8630'. NO TIGHT SPOTS OR DRAG. POOH. MU BAKER 3-1/2" X 7" F-1 PERM PKR ON WL SETTING TOOL. RIH TO SET @ + 8424', PUTTING TT @ + 8460'. RIG RELEASED 7"@ 8914' MW: 0.0 FIN RIH W/F1 PKR ON WL. SET PKR @ 8410' W/TT @ 8446'. POH. RD SWS. RU TO RUN COMP ASSY. RIH W/3-1/2" COMP ASSY AS PER WELL PLAN. MU SSSV. ATTACH CONTROL LINE & TEST TO 5000 PSI. CONT RIH W/3-1/2" TBG BANDING CONTROL LINE EVERY OTHER JT. TAG PKR. SPACE OUT AND LAND, LOCK DOWN. MU HGR & CONTROL LINE. TEST SAME. TEST SSSV TO 1000 PSI, TEST TBG TO 2500 PSI, TEST ANN TO 2500 PSI FOR 15 MIN. SHEAR BALL @ 3700 PSI, PULL LANDING JT, SET BPV. STRING WT: UP 54K DN 34K. RD FLOW RISER, ND BOP'S & CHOKE LINE. BRING IN FMC TREE, NU SAME. STEAM HEAT TREE, TEST TBG HEAD ADPT, PULL BPV, SET TEST PLUG, TEST TREE TO 5000 PSI, PULL TEST PLUG, RU LANDING JT & HOSE, PMP 12 BBLS DIESEL DOWN ANN, INJECT 4 BBLS DIESEL DOWN TBG. RD LINES, DRESS FMC TREE, SICP-0 PSI & SITP-0 PSI. SET FMC BPV. RELEASED RIG 12/15/92. 06/12/92 (25) TD: 8931 PB: 8828 RUN GCT/CBT/CET 7"@ 8914' MW: 0.0 SCHLUMBERRAN CBT/CET/ FL8829'-5820' WLM. RAN GCT F/8765' TO SURF. EST COST- $31,468 SIGNATURE: ( dril li n~u~e r£nt en~ht ) DATE: MICROFILMED SUB - S URFA CE DIRECTIONAL SURVEY ['~ UIDANCE I'~'] ONTINUOUS J-fi OOL Company ARCO ALASKA, INC. Well Name 2M-05 (114'FSL,64'FWL,SEC 27,T11N,R8E,UM) Field/Location KUPARUK RIVER, NORTH SLOPE, ALASKA Job Reference No. 92367 Locjqed By: SIMMONS Date 11-JUNE-1992 Computed By: R. KRUWELL * SCHLUIVlBERGER · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. 2M-05 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA SURVEY DATE: Il-JUN-1992 ENGINEER- SIMMONS METHODS OF COMPUTATION TOOL LOCATION' TANGENTIAL- Averaged deviation and azimuth INTERPOLATION- LINEAR VERTICAL SECTION. HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 44 DEG 19 MIN WEST COMPUTATION DATE' 8-JUL-92 PAGE ARCO ALASKA INC. 2M-055 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 11-JUN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER' SIMMONS INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 O0 -146 O0 100 05 200 05 300 04 400 04 5500 04 600 03 700 02 800 02 900.01 -45 955 54 055 1554 04 2554 04 3554 04 4554 03 5554 02 6554 02 7554.01 0 0 N 0 0 E 0 15 N 35 21E 0 26 N 555 53 E 0 28 N 71 38 E 0 31 N 82 43 E 0 34 N 84 7 E 0 38 N 89 41E 0 40 S 77 10 E 0 42 S 66 46 E 0 37 S 56 559 E 0 O0 0 03 0 O0 -0 255 -0 73 -1 31 -1 98 -2 82 -3 85 -55 03 0 O0 0 52 0 O0 0 19 0 O0 0 O0 0 15 0 16 0 37 0 553 000N 0 12 N 0 557N 0 93N I 11N 123N I 30 N 119 N 0 84 N 0 255N 0.00 E 0.08 E 0 0.59 E 0 1.31 E 1 2.19 E 2 3.13 E 3 4.15 E 4 5.25 E 5 6,38 E 6 7.46 E 7 0 O0 N 0 0 E 14 N 32 52 E 82 N 45 47 E 60 N 54 39 E 46 N 63 4 E 36 N 68 37 E 36 N 72 39 E 39 N 77 15 E 43 N 82 29 E 47 N 88 3 E 1000 O0 1000.01 1100 O0 1099 97 1200 O0 1199 1300 O0 1299 1400 O0 1399 15500 O0 1498 1600 O0 15596 1700.00 1691 1800.00 1783 1900.00 1871 8554.01 0 550 9553.97 2 6 85 10553.855 3 32 557 11553.557 5 1 05 1253 055 6 47 11 1352 11 9 11 03 14550 03 14 12 550 155455 550 20 16 37 1637 37 26 3 27 1725 27 30 43 N 78 28 W -5.23 N 62 58 W -2.62 N 557 44 W 1.95 N 51 28 W 9.24 N 47 13 W 19.38 N 45 20 W 33.02 N 43 552 W 553.10 N 42 29 W 82.68 N 40 11W 122.02 N 39 552 W 169.47 3.10 O. 88 1.13 I. 86 I. 66 4 22 /5 62 /5 67 /5 29 3 81 O01N 1 13N 3550N 783N 14 49 N 23 98 N 38 21 N 559 83 N 89 40 N 126 7 51E 4 0 12 22 36 557 83 03 N 113 7 51 N 89 53 E 92 E 55 79 E 3 22 W 9 90 W 19 71W 33 87 W 53 07 W 82 09 W 122 51W 169 04 N 77 I E 59 N 12 41E 41 N 33 41W 40 N 41 42 W 03 N 43 27 W 10 N 43 59 W 68 N 43 39 W 055 N 42 54 W 61 N 42 I W 2000 O0 1955555 555 1809 5555 34 32 2100 2200 2300 2400 2500 2600 2700 2800 2900 O0 2036 O0 2114 O0 2191 O0 2264 O0 2333 O0 2400 O0 2467 O0 2530 O0 2590 23 1890 92 1968 91 2045 64 2118 84 2187 87 2254 69 2321 53 2384 91 2444 N 41 559 W 223.15 23 37 39 N 42 47 W 282.18 92 38 24 N 42 355 W 343,86 91 41 27 N 43 48 W 407.64 64 455 5 N 44 556 W 476.25 84 47 8 N 44 554 W 548.42 87 48 15 N 44 22 W 622.63 69 48 44 N 44 11 W 697.02 53 552 40 N 44 14 W 774.77 91 553 I N 44 15 W 8554.49 4.42 I 76 0 9O 4 10 2 559 I 81 I 25 4 12 I 04 0 29 166.66 N 148 73 W 223 38 N 41 45 W 210.20 N 188 2555.556 N 230 302.12 N 274 3551.14 N 322 402.22 N 373 45555.04 N 4255 5508.35 N 477 564.09 N 5531 621.20 N 5586 64 W 282 47 W 344 07 W 407 08 W 476 07 W 5548 19 W 622 O8 W 697 29 W 774 91W 8554 43 N 41 54 W 13 N 42 3 W 91 N 42 13 W 48 N 42 32 W 60 N 42 51W' 78 N 43 3 W 155 N 43 11W go N 43 17 W 61 N 43 22 W 3000 O0 26550 85 2504 85 553 21 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2710 O0 2769 O0 2828 O0 2887 O0 2946 O0 3004 O0 3062 O0 3121 O0 3179 37 2564 80 2623 79 2682 81 2741 38 2800 79 2858 97 2916 17 2975 34 3033 37 553 33 80 553 37 79 553 48 81 53 59 38 554 13 79 554 22 97 54 29 17 54 26 34 54 27 N 44 12 W N 44 14 W 1014 N 44 36 W 10955 N 45 14 W 1176 N 45 40 W 1256 N 45 46 W 1337 N 45 53 W 1418 N 46 3 W 1500 N 46 14 W 1581 N 46 19 W 1662 934 53 89 32 06 77 80 94 24 51 81 0 27 0 32 I 09 0 72 0 551 0 38 0 29 0 50 0 16 0 30 678.557 N 642 72 W 934 64 N 43 27 W 736 17 N 698 793 8550 9O7 964 1020 1077 1133 1189 68 N 7554 95 N 811 554 N 869 17 N 927 72 N 985 27 N 1044 59 N 1102 82 N 1161 755 W 1014 98 W 10955 90 W 1176 46 W 1256 46 W 1337 68 W 1418 13 W 1500 79 W 1581 58 W 1662 gg N 43 30 W 41 N 43 34 W 14 N 43 39 W 82 N 43 46 W 84 N 43 53 W 96 N 44 0 W 25 N 44 6 W 51 N 44 13 W 81 N 44 19 W COMPUTATION DATE: 8-JUL-92 PAQE 2 ARCO ALASKA INC. 2M-05 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: Il-JUN-1992 KElly BUSHING ELEVATION: 146.00 FT ENGINEER: SIMMONS INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3238.34 3092 34 52 49 N 44 35 W 1743.51 4100.00 3298.80 3152 4200.00 3358.82 3212 4300.00 3418.52 3272 4400.00 3478.07 3332 4500.00 3537.55 3391 4600.00 3596.89 3450 4700.00 3656.12 3510 4800.00 3715.10 3569 4900.00 3773.90 3627 80 52 57 N 44 30 W 1823 16 82 53 15 N 44 38 W 1903 52 53 30 N 44 37 W 1983 07 53 24 N 43 20 W 2063 55 53 32 N 43 30 W 2144 89 53 41 N 43 41W 2224 12 53 43 N 44 7 W 2305 10 53 59 N 44 29 W 2385 90 53 53 N 44 50 W 2466 15 37 70 O8 56 13 89 77 1.63 1246 12 N 1219.43 W 1743 51 N 44 23 W 0.61 1303 0.37 1359 0.48 1417 0 31 1474 0 43 1533 0 30 1591 0 49 1649 0 51 1707 0 84 1765 02 N 1275.18 W 1823 97 N 1331.34 W 1903 04 N 1387.72 W 1983 86 N 1443.49 W 2063 28 N 1498.70 W 2144 60 N 1554.19 W 2224 62 N 1610.10 W 2305 42 N 1666.48 W 2385 01N 1723.28 W 2466 17 N 44 23 W 15 N 44 23 W 37 N 44 24 W 71 N 44 23 W 08 N 44 21W 56 N 44 19 W 13 N 44 18 W 89 N 44 18 W 77 N 44 19 W 5000.00 3833 13 3687.13 53 29 N 45 37 W 2547 33 5100.00 3893 5200.00 3955 5300 O0 4017 5400 O0 4079 5500 O0 4141 5600 O0 4203 5700 O0 4264 5800 O0 4325 5900 O0 4386 34 3747.34 51 51 N 45 38 W 2627 69 3809.69 51 24 N 45 11 W 2705 84 3871.84 51 43 N 45 9 W 2783 71 3933.71 51 51 N 45 13 W 2862 49 3995.49 51 48 N 45 26 W 2940 O0 4057.00 S2 4 N 45 27 W 3019 43 4118.43 52 10 N 45 25 W 3098 69 4179.69 52 17 N 45 21 W 3177 14 31 65 20 82 65 54 57 44 4240.44 52 41 N 44 28 W 3257.00 I 08 1821.75 N 1780 49 W 2547.33 N 44 21W 24 1877.34 N 1837 86 1932.47 N 1893 28 1987.74 N 1948 77 2043.07 N 2004 76 2098.32 N 2060 63 2153,69 N 2116 23 2209.05 N 2172 97 2264.55 N 2229 35 2320.88 N 2285 79 W 2627.14 N 44 23 W 22 W 2705.32 N 44 25 W 75 W 2783,66 N 44 26 W 52 W 2862.21 N 44 27 W 47 W 2940.83 N 44 29 W 61 W 3019.67 N 44 30 W 83 W 3098.57 N 44 32 W 11 W 3177.59 N 44 33 W 11 W 3257.03 N 44 33 W 6000.00 4446.95 4300.95 52 55 N 44 21W 3336.61 6100.00 4507.48 4361.48 52 40 N 44 30 W 3416.21 6200.00 4567.98 4421 98 52 55 N 44 31W 3495.83 6300.00 4628.28 4482 28 52 54 N 44 50 W 3575.60 6400.00 4688.43 4542 43 53 8 N 44 50 W 3655.49 6500.00 4748.12 4602 12 53 37 N 44 55 W 3735.71 6600.00 4807.30 4661 30 53 32 N 45 4 W 3816.32 6700.00 4867.03 4721 03 53 13 N 45 13 W 3896.51 6800.00 4926.75 4780 75 53 21: N 45 29 W 3976.71 6900.00 4986.78 4840 78 53 4 N 46 9 W 4056.66 0.54 2377.77 N 2340.80 W 3336 64 N 44 33 W 0.36 2434.61 N 2396.53 W 3416 0.05 2491.42 N 2452.31W 3495 0,33 2548 14 N 2508.42 W 3575 0 67 2604 80 N 2564.73 W 3655 0 68 2661 64 N 2621.36 W 3735 0 82 2718 70 N 2678.30 W 3816 0 29 2775 28 N 2735.13 W 3896 0 07 2831 70 N 2792.14 W 3976 0 96 2887 49 N 2849.45 W 4056 24 N 44 33 W 86 N 44 33 W 63 N 44 33 W 52 N 44 33 W 75 N 44 34 W 36 N 44 34 W 55 N 44 35 W 76 N 44 36 W 72 N 44 37 W 7000 O0 5046 71 4900.71 53 25 N 46 46 W 4136 66 7100 7200 7300 7400 7500 7600 7700 7800 O0 5105 86 4959.86 54 11 N 47 5 W 4217 O0 5163 82 5017.82 54 52 N 47 26 W 4298 O0 5221 44 5075.44 54 53 N 45 3 W 4380 O0 5278 86 5132.86 55 19 N 45 19 W 4462 O0 5335 69 5189.69 55 21 N 45 28 W 4544 O0 5392 16 5246.16 55 55 N 45 36 W 4626 O0 5449 29 5303.29 54 0 N 44 23 W 4708 O0 5507.87 5361.87 54 29 N 44 18 W 4789 7900.00 5566.22 5420.22 53 48 N 44 13 W 4871 19 58 26 12 38 9O 95 99 21 1 38 2942.62 N 2907 50 W 4136 73 N 44 39 W 02 2997.67 N 2966 71 3053.00 N 3026 17 3109.54 N 3085 35 3167.26 N 3143 75 3225.06 N 3201 51 3282.91N 3260 67 3340.63 N 3319 61 3398.72 N 3375 40 W 4217 22 W 4298 24 W 4380 30 W 4462 86 W 4544 72 W 4627 06 W 4709 57 W 4790 1.49 3456.85 N 3432.29 W 4871 29 N 44 42 W 70 N 44 45 W 40 N 44 47 W 27 N 44 47 W 55 N 44 48 W 07 N 44 48 W 14 N 44 49 W 17 N 44 48 W 38 N 44 48 W COMPUTATION DATE: 8-JUL-92 PAGE 3 ARCO ALASKA INC. 2M-05 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA DATE OF SURVEY: Il-JUN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SIMMONS INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTIDN SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 5627.38 5481 38 51 14 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 5692.00 5546 O0 5759..14 5613 O0 5828 57 5682 O0 5902 14 5756 O0 5978 67 5832 O0 6055 19 5909 O0 6132 02 5986 O0 6208 78 6062 O0 6285 59 6139 O0 48 13 14 47 30 57 44 14 14 40 59 67 40 1 19 39 46 02 39 47 78 39 49 59 39 49 N 44 12 W 4950.31 N 45 14 W 5026.60 N 45 31W 5100.70 N 45 11W 5172.63 N 44 48 W 5240 34 N 43 47 W 5304 70 N 43 42 W 5369 07 N 43 45 W 5433 08 N 43 34 W 5497 14 N 43 34 W 5561 16 1 43 I 96 1 74 4 97 4 39 0 64 0 52 0 48 0 O0 0 O0 3513.62 N 3487.37 W 4950.48 N 44 47 W 3567.98 N 3540.89 W 5026 77 N 44 47 W 3619.98 N 3593.71W 5100 3670.31N 3645.12 W 5172 3718.29 N 3692.90 W 5240 3764.42 N 3737.78 W 5304 3810.93 N 3782.29 W 5369 3857.22 N 3826.50 W 5433 3903.55 N 3870.75 W 5497 3949.95 N 3914.87 W 5561 88 N 44 47 W 82 N 44 48 W 54 N 44 48 W 89 N 44 48 W 26 N 44 47 W 25 N 44 46 W 31 N 44 45 W 32 N 44 45 W 8931.00 6309.41 6163.41 39 49 N 43 34 W 5581.01 0.00 3964.33 N 3928.55 W 5581.17 N 44 44 W ARCO ALASKA INC. 2M-05 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA COMPUTATION DATE: 8-JUL-92 PaGE 4 DATE OF SURVEY: Il-JUN-1992 KELLY BUSHINQ ELEVATION: 146.00 FT ENGINEER: SIMMONS INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 8931.00 6309 0 O0 -146.00 0 0 N 0 0 E O0 1000 O0 1955 O0 2650 O0 3238 O0 3833 O0 4446 O0 5046 O0 5627 0.00 O1 854.01 0 50 N 78 28 W -5.23 SS 1809.55 34 32 N 41 59 W 223.15 85 2504.85 53 21 N 44 12 W 934.53 34 3092.34 52 49 N 44 35 W 1743.51 13 3687.33 53 29 N 45 37 W 2547.33 95 4300.95 52 55 N 44 21 W 3336.61 71 4900.71 53 25 N 46 46 W 4136.66 38 5481.38 51 14 N 44 12 W 4950.31 41 6163,41 39 49 N 43 34 W 5581.01 0 O0 3 4 0 1 1 0 1 1 0.00 3964.33 N 3928 0.00 N 10 0.01N 7 42 166.66 N 148 27 678.57 N 642 63 1246.12 N 1219 08 1821.75 N 1780 54 2377.77 N 2340 38 2942.62 N 2907 43 3513.62 N 3487 0 O0 E 51E 7 73 W 223 72 W 934 43 W 1743 49 W 2547 80 W 3336 50 W 4136 37 W 4950 55 W 5581 0 O0 N 0 0 E 51 N 89 53 E 38 N 41 45 W 64 N 43 27 W 51 N 44 23 W 33 N 44 21W 64 N 44 33 W 73 N 44 39 W 48 N 44 47 W 17 N 44 44 W COMPUTATION DATE' 8-JUL-g2 PAGE 5 ARCO ALASKA INC. 2M-05 KUPARUK RIVEE UNIT NORTH SLOPE, ALASKA DATE OF SURVEY' 11-JUN-1992 KELLY BUSHING ELEVATION' 146.00 FT ENGINEER- SIMMONS INTERPOLATED V,~J_UES FOR EVEN iOO FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 145 95 245 95 345 96 445 96 545 97 645 97 745 98 845 99 945.99 0 O0 -146 O0 i46 246 346 446 546 646 746 846 946 O0 0 O0 O0 100 O0 O0 200 O0 O0 300 O0 O0 400 O0 O0 500 O0 O0 600 O0 O0 700 O0 O0 800 O0 0 0 N 0 0 E 0 25 N 47 50 E 0 29 N 63 11E 0 32 N 77 46 E 0 32 N 83 4 E 0 35 N 85 7 E 0 37 S 85 35 E 0 41 S 73 10 E 0 44 S 62 31E 0 12 S 37 46 E 0 O0 0 05 -0 09 -0 45 -0 99 -1 60 -2 34 -3 28 -4 40 -5 35 0 O0 0 2O 0 01 0 15 0 O0 0 O0 0 O4 0 08 0 O0 0 75 O00N 032N 0 76N I 03 N 1 16N 1 27 N 1 28N 1 05N 059N O06N 0.00 E 0.26 E 0 0.90 E 1 1.70 E 1 2.61E 2 3.60 E 3 4.66 E 4 5.78 E 5 6.90 E 6 7.73 E 7 000 N 0 0 E 42 N 38 56 E 18 N 49 57 E 99 N 58 41 E 86 N 65 59 E 81 N 70 33 E 84 N 74 41 E 87 N 79 40 E 93 N 85 9 E 73 N 89 31 E 1046 O1 1046.00 1146 1246 1346 1447 1548 1651 1758 1870 1988.43 1946 900.00 07 1146 O0 1000.00 26 1246 63 1346 33 1446 68 1546 93 1646 79 1746 80 1846 1 39 2 36 O0 1100.00 4 10 O0 1200 O0 S 42 O0 1300 O0 7 44 O0 1400 O0 11 27 O0 1500 O0 17 22 O0 1600 O0 23 44 O0 1700 O0 29 26 O0 1800 O0 34 I N 67 8 W -4.29 N 60 57 W -0.83 N 54 30 W 4.99 N 49 20 W 13.57 N 45 54 W 25.36 N 45 12 W 41.70 N 43 2 W 67.20 N 41 13 W 104.68 N 39 35 W 154.90 N 41 47 W 216.64 1 14 0 90 1 76 2 04 1 94 S 52 6 16 6 51 4 86 4 66 037N 201 N 5 23 N 10 60 N 18 61 N 30 07 N 48 46 N 76 22 N 114 161 6 51E 3 1 8 17 28 46 71 78 N 104 81N 144 6 52 N 86 48 E 26 E 3 78 W 5 56 W 13 24 W 25 89 W 41 56 W 67 78 W 104 17 W 155 38 W 216 83 N 58 16 E 53 N 18 49 W 63 N 38 54 W 37 N 42 49 W 70 N 43 51W 20 N 43 51W 70 N 43 17 W O0 N 42 14 W 86 N 41 44 W 2112 34 2046 O0 1900 O0 37 52 2239 2373 2517 2667 2825 2991 3159 3329 3499 83 2146 79 2246 93 2346 41 2446 55 2546 88 2646 98 2746 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 N 42 48 W O0 39 8 N 42 55 W O0 44 16 N 44 44 W 457 O0 47 28 N 44 48 W 561 O0 47 53 N 44 11 W 672 O0 52 49 N 44 14 W 795 O0 53 lg N 44 13 W 928 O0 53 30 N 44 22 W 1063 O0 53 45-'N 45 25 W 1199 O0 54 13 N 45 46 W 1337 11 2846 36 2946 O0 2700 O0 2800 289.72 368 76 82 59 70 11 02 14 54 28 I 11 3 25 3 67 2 11 I 05 0 20 0.48 1.01 0.48 0.39 215.73 N 193 76 W 289 97 N 41 56 W 273.86 N 247 338.07 N 309 411.56 N 382 490.91N 460 578.66 N 545 673.90 N 638 770.72 N 732 867.46 N 828 963.81N 927 36 W 369 O8 W 458 36 W 561 12 W 672 48 W 795 18 W 928 43 W 1063 59 W 1199 08 W 1337 03 N 42 5 W 06 N 42 25 W 76 N 42 54 W 83 N 43 9 W 23 N 43 19 W 12 N 43 26 W 23 N 43 32 W 61 N 43 41 W 32 N 43 53 W 3670 80 3046 O0 2900 O0 54 27 3842 4012 4178 4346 4514 4682 4852 5021 5184 68 3146 O0 3000 66 3246 O0 3100 59 3346 O0 3200 22 3446 O0 3300 22 3546 O0 3400 91 3646 O0 3500 58 3746 O0 3600 59 3846.00 3700 O0 54 26 O0 52 46 O0 53 12 O0 53 29 O0 53 33 O0 53 41 O0 54 0 O0 53 21 46 3946.00 3800.00 51 23 N 45 58 W 1476 48 N 46 17 W 1616 N 44 27 W 1753 N 44 39 W 1886 N 44 3 W 2020 N 43 33 W 2155 N 44 3 W 2291 N 44 36 W 2428 N 45 51W 2564 N 45 8 W 2693 21 58 O0 54 51 36 43 66 17 0.2i 0 i8 0 80 0 27 1 48 0 O5 0 22 0 54 0 99 0 78 1060.76 N 1027 04 W 1476 49 N 44 4 W 1157 60 N 1127 1253 1347 1443 1541 1639 1737 1833 1923 31N 1226 77 N 1319 60 N 1413 58 N 1506 72 N 1600 76 N 1696 85 N 1792 91N 1884 87 W 1616 49 W 1753 29 W 1886 72 W 2020 57 W 2155 52 W 2291 31W 2428 90 W 2564 61W 2693 21 N 44 15 W 59 N 44 23 W O0 N 44 23 W 54 N 44 24 W 51 N 44 21W 36 N 44 18 W 43 N 44 19 W 66 N 44 21W 18 N 44 25 W COMPUTATION DATE: 8-JUL-g2 PAGE ARCO ALASKA INC. 2M-05 KUPARUK RIVER ~IT NORTH SLOPE, ALASKA DATE OF SURVEY: I1-JUN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SIMMONS INTERPOLATED VALUES FOR EVEN 1OO FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 5345 47 4046.00 3900.00 51 46 5507 5669 5833 5998 6163 6329 6496 6664 6832 30 4146 O0 4000.00 51 52 95 4246 28 4346 42 4446 58 4546 41 4646 43 4746 90 4846 17 4946 O0 4100.O0 52 9 O0 4200.00 52 32 O0 4300.00 52 55 O0 4400.00 52 49 O0 4500.00 52 59 O0 4600,00 53 36 O0 4700,00 53 13 O0 4800,00 53 6 N 45 17 W 2819.34 N 45 26 W 2946.56 N 45 25 W 3074.82 N 45 1 W 3203.93 N 44 21 W 3335,34 N 44 29 W 3466,79 N 44 51 W 3599,07 N 44 56 W 3732,84 N 45 8 W 3868,41 N 45 41 W 4002,48 0,38 0,90 0,44 2192 1,88 2283 0,52 2376 0,31 2470 0,09 2564 0.71 2659 0.81 2755 2.00 2849 2012.89 N 1974 09 W 2819 35 N 44 27 W 2102 35 N 2064 39 N 2155 13 N 2247 86 N 2339 70 N 2431 78 N 2524 60 N 2619 47 N 2715 56 W 2946 93 W 3O74 81W 3203 92 W 3335 96 W 3466 97 W 3599 32 W 3732 20 W 3868 76 N 2810.54 W 4002 57 N 44 29 W 84 N 44 31W 96 N 44 33 W 37 N 44 33 W 82 N 44 33 W 11 N 44 33 W 87 N 44 34 W 45 N 44 35 W 53 N 44 36 W 6998,81 5046 O0 4900 O0 53 25 7169.10 5146 7342.65 5246 7518.15 5346 7694.41 5446 7865.59 5546 8029.53 5646 8180.51 5746 8324.12 5846 8457.41 5946 O0 5000 O0 5100 O0 5200 O0 5300 O0 5400 O0 5500 O0 5600 O0 5700 O0 5800 O0 54 40 O0 54 51 O0 55 27 O0 54 1 O0 54 16 O0 50 30 O0 47 44 O0 43 19 O0 39 49 N 46 45 W 4135.70 N 47 18 W 4273.37 N 45 9 W 4415.12 N 45 27 W 4559.32 N 44 28 W 4704.43 N 44 16 W 4843.36 N 44 15 W 4973.22 N 45 31 W 5086,31 N 44 54 W 5189.30 N 44 4 W 5277.38 1.40 0 5O ! 02 0 68 2 12 1 73 2 81 0 71 3 O1 0 61 2941.97 N 2906 80 W 4135 78 N 44 39 W 3035.90 N 3007 3134.17 N 3109 3235 54 N 3212 3337 40 N 3315 3436 89 N 3412 3530 05 N 3503 3609 89 N 3583 3682 10 N 3656 3744 74 N 3718 66 W 4273 92 W 4415 50 W 4559 go W 4704 86 W 4843 34 W 4973 44 W 5086 91W 5189 83 W 5277 49 N 44 44 W 27 N 44 47 W 48 N 44 48 W 61 N 44 49 W 54 N 44 48 W 39 N 44 47 W 49 N 44 47 W 49 N 44 48 W 57 N 44 48 W 8588.03 6046.00 5900.00 39 53 8718.19 6146.00 6000.00 39 48 8848.45 6246.00 6100.00 39 49 8931.00 6309.41 6163.41 39 49 N 43 43 W 5361,40 N.43 53 W 5444,72 N 43 34 W 5528,16 N 43 34 W 5581,01 I .40 0.41 0. O0 O. O0 3805,39 N 3776,99 W 5361,59 N 44 47 W 3865,62 N 3834,56 W 5444,89 N 44 46 W 3926,03 N 3892,13 W 5528,32 N 44 45 W 3964,33 N 3928,55 W 5581.17 N 44 44 W ARCO ALASKA INC. 2M-05 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING COMPUTATION DATE: 8-JUL-92 PAGE 7 DATE OF SURVEY: 11-JUN-1992 KELLY BUSHING ELEVATION: 146.00 ET ENGINEER: SIMMONS INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION : 114' FSL & 64' FWL, SEC27 TllN R8E UM MEASURED DEPTH BELOW KB 3167 O0 8534 O0 8552 O0 8552 O0 8695 O0 8765 94 8828 O0 8915 O0 8931 O0 TVD FROM KB SUB-SEA 2750 18 6004 68 6018 43 6018 43 6128 18 6182 67 6230 29 6297 12 6309 41 2604'.18 5858 68 5872 43 5872 43 5982 18 6036 67 6084 29 6151 12 6163 41 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 774.75 N 3780.24 N 3788.63 N 3788.63 N 3854.90 N 3887.71N 3916.54 N 3956.91N 3964.33 N 736 38 W 3752 92 W 3760 96 W 3760 96 W 3824 29 W 3855 71W 3883 11W 3921 49 W 3928 55 W COMPUTATION DATE: 8-JUL-92 PaGE 8 ARCO ALASKA INC. 2M-05 KUPARUK RIVER UNIT NORTH SLOPE, ALASKA MARKER 9 5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A LAST READING GCT PBTD 7" CASING DATE OF SURVEY: ll-JUN-1992 KELLY BUSHING ELEVATION: 146.00 FT ENGINEER: SIMMONS ************ STRATIGRAPHIC SUMMARY ************ SURFACE LOCATION : 114' FSL · 64' FWL, SEC27 TllN R8E tN MEASURED DEPTH BELOW KB 'I'VD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3167.00 8534 O0 8552 O0 8552 O0 8695 O0 8765 94 8828 O0 8915 O0 8931 O0 2750 18 6004 68 6018 43 6018 43 6128 18 6182 67 6230 29 6297 12 6309 41 2604.18 5858.68 5872.43 5872.43 5982.18 6036.67 6084.29 6151.12 6163.41 774.75 N 3780.24 N 3788.53 N 3788 63 N 3854 90 N 3887 71N 3916 54 N 3956 91N 3964 33 N 736 38 W 3752 92 W 3760 96 W 3760 96 W 3824 29 W 3855 71W 3883 11W 3921 49 W 3928 55 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8931.00 6309.41 6163.41 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 5581.17 N 44 44 W DIRECTIONAL SURVEY COMPANY FIELD WELL COUNTRY RUN DATE LOGIGIED DEpTH UNIT ARCo ALASKA INC. 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COm'ACT chect< off or list data as it is received.*list received date for 407. if not rcouired list as NR ' I drillina history' survey well tests core descrintim cored inter~als core analysis dM ditch intervals dioital data LOG -r~=, ,r-L RUN '"' INTERVALS -" ...... ' ..... .... '.:,;' SCALE HO. [to t, he nearest foot ii ii ARCO Alaska, Inc. Date: July 17, 1992 Transmittal #: 8484 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. 2 M - 05 Sub-Surface Directional Survey Receipt Acknowledged: D&M Please acknowledge receipt and return 6-11-92 ..... ~Date: state/of Alaska (2 copies) 92367 R CEIV£D JUL 2 0 1992 ~,lask~ Oit & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: June 26, 1992 Transmittal #: 8472 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. one signed copy of this transmittal. ,5-.~ LIS Tape and Listing 6 - 1 2 - 9 2 2 M- 0.5, 5,~//.~'~ LIS Tape and Listing 6-4- 9 2 Receipt Acknowledged' - .... DISTRIBUTION: Please acknowledge receipt and return 92365 Date' -j-U-~- ~-~J 1992- Alaska 0it & Gas Cons. Commission Anchorage Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: June 17, 1992 Transmittal #: 8461 RETtJRN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-111 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2 M - 0 5 Cement Evaluation Log 6 - 1 0 - 9 2 5 81 5 - 8 8 2 3 2 M - 0 5 Cement Bond Log 6 - 1 0 - 9 2 5 81 5 - 8 7 81 RECEIVED Receipt Drilling Acknowledge: ~-~ Date' State of Alaska(+sepia) .... JUE_.l.8..1992 ~.ka 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: June 17, 1992 Transmittal #: 8460 RETURN TO: ARCO Alaska, Inc. Attn: Maria Trevithick Kuparuk Operations File .Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following Open hole items. and return one signed copy of this transmittal. .~? 1 2M-05 CCN "~ ~ 2M-05 CE~ ~ 2M-22 CCN "'" ~?..~ 2M-22 CDR-/ Please acknowledge receipt Receipt Acknowledged: DISTRIBUTION: D&M Drilling 6/1 -4/92 6/1 -4/92 6/9-12/92 6/9-12/92 3166-7338 3166-7338 3375-8598 3375-8598 RECEIVED Date: .......... JIJl~t 1 8 199~ Alaska 0il & Gas Cons. Commission Anchorage Vendor Package(Johnston) NSK State of Alaska(+Sepia) ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 May 14, 1992 A W McBride Area Drilling Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2M-05 ARCO Alaska, Inc. Permit No: 92-47 Sur. Loc. ll4'FSL, 64'FWL, Sec. 27, TllN, R8E, UM Btmhole Loc. l144'FNL, 1418'FWL, Sec. 28, TllN, R8E, UM Dear Mr. McBride: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 1 a. Type of Work Drill X Redrill r"] I b Type of Well Exploratory D Stratigraphic Test r'l Development Oil X Re-Entry r"l Deepen r'l Service BI Development Gas r~ Single Zone X Multiple Zone ,, 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 146'~ Pad 105' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, AnchoracjeI AK 99510-0360 ADL 25586~ ALK 2672 4. Location ~ well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 114' FSL, 64' FWL, Sec. 27, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) '8. Well number Number 1320' FNL, 1590' FWL, Sec. 28, T11N, R8E, UM 2M-05 #UG630610 At total depth 9. Approximate spud date Amount 1144' FNL~ 1418' FWL~ Sec. 281 T11N~ R8E~ UM 5/1 4/92 $200~000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed deplh (MD and TVD) property line 2 M- 1 0 8,930' MD 1144' @ TD feet 75' @ 0' feet 2560 6,297' TVD feet , 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1 000' feet Maximum hole an~lle 53.62° Maximum surface 1 635 osio At total deoth f'rVDI 3140 osio MD 18. Casing program Settinc~ Depth size Specifications Top Bottom Quantity of cement , Hole Casin~ Weight Grade Coupling Length MD TVD MD TVD tinclude stage datat 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' +200 CF 12.25" 9.625' 36.0# J-55 BTC 3123' 41' 41' 3,164' 2,761' 434 Sx permafrost E & HF-ERW 537 Sx Class G 8.5' 7' 26.0# J-55 BTC 8889' 41' 41' 8,930' 6,297' 201 SxClassG HF-ERW 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 vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor c .iV D Surtace L. E ii,':, Intermediate Production Liner j;; ~ ~ ~¢ ~ ~ Perforation depth: measured ~'"~ ..... " .... ~"i~ ::~ ~"3,':' r"x,,-u,, ,"~'~', 20. Attachments Filing fee X Property plat r'l BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot ri Refraction analysis ri Seabed report F'~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing .is true and correct to the best of my knowledge Si~n~d ~ ,~'~0L~ ~.~1~).~.~:)~¢~ Ti, le Area Drillin~ Encjinoor Da, e ~'~' ' /~' Commission Use Only Permit Number('~- I APl number ! Approval .d~te .. I See cover letter for ~'.~.-'~-".~' 5 o-,.~'~- -~ ~J//~'-~' ...,~.. - ,/~- ~'~;~ I other recluirements Conditions of approval Samples required D Yes ~ No Mud iog required r~ Yes~ No Hydrogen sulfide measures r'l Y es.,~,~ No Directional survey required ~ Yes r'l No Required workir~:l pressure for BOPE ~ 2M ~ 3M r'~ 5M r-! 10a ~ 15M by order of Approved by ~~"~-.~/~ _.~ '~,,._~.~ Commissioner the commission , Date DRILLING FLUID PROGRAM Well 2M-05 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-9.6 15-25 15-35 50-120' 5-15 15-40 10-12 9-10 10_+ Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 8.5-9 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 Notes: Weight up to TD 10.5 10-18 8-12 35-50 2-4 4-8 4-6 9.0-9.5 <10 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 1635 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2M-05 is 2M-10. As designed, the minimum distance between the two wells would be 75' @ 0'. The wells would diverge from that point. 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 the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds. Adjust FV to 50-80 sec/qt below gravel beds. RECEIVED MAY - ,5 ~99~ Alaska 0il & 6as 6ohs. Oor~m~ssioO '~nchorar~e ARCO ALASKA, Inc. Structure : Pod 2M Well Field : Kuparuk River Unit Location : North Slope, Alaska PLOT REFERENCE IS ,~ VERSION COORDINATES ARE IN FEET REFERENCE SLOT #~. ITRUE VERTICAL DEPTHS ARE REFERENCE WELLHEAD. A Baker Hugh,* company , <-- West CREATED By : JONES For: B MATHEWS, ! 4-200 3go0 3600 3300 3000 2700 24-00 2100 1800 1500 1200 go0 600 300 0 300 IDATE PLOTTEB 25-APR-g2 I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I _4200 1144' FNL, 1418' FWL - SEC. 28, T11N, RBE _3~00 _ .3600 I I - TARGET LOCATION: I 320' FNL, 1590' FWL _3300 SEC,28,TI1N, RBE - 300 _3000 © 0 TARGET N 44.31 DEC O TVD=60'~ 5374' (TO TARGET) _~,oo A Lf3 0 RKB ELEVATION: 146' ~ TMD=8553 DEP=5374 - I " NORTH 384-6 300 WEST 3754 _2400 ~ 600 < ~oo - _1800 KOP TVD=IO00 TMD=IO00 DEP=O - 3.00 - --4- 1200_ J 500 9.00 B/ PERMAFROST TVD=1396 TMD=1399 DEP=42 _ ~oo \ 15.00 T/ UGNU SNDS TVD=1436 TMD=14-40 DEP=50 _,200 -I--- - ~ 21.00 BUILD 3 DEG / 100' 0 ,ODD_ ~ 27.00 ooo ~ - '~ 33 O0 T/ W SAK SNDS TVD=2006 TMD=2060 DEP=2B6 ~ _ '~ 3g.o0 m~ -- 2.oo_ ~ 4-5.00 _300 ~ . ~'~ 51.00 EOC TVD--2538 TMD:2787 DEP--777 " ¢~ ~ 8/ W SAK SNDS TVD=2561 TMD=2827 DEP:809 - 2700. .i ~ 9 5/8"CSG PT TVD=2761 TMD=3164 DEP=1080 _ o "+-- . ~ ~ K-lO TVD=2821 TMD=3265 DEP=1162 o ]> ~oo_ - ~ I 114, FSL, 64' FWL I (I.) - ~ I SEC. 27, TllN, R8E I 3600_ k. _ I"-- 3900_ - ~ MAXIMUM ANGLE I ,.~oo_ . ....... ~ 53.62 DEG v ..... CEiVEi 480( 5 1992 , .... MAY - .... Alaska Oil & Gas OOnSi BEGIN ANGLE DROP TVD:55:4 TMD:7822 DEP=4-831 ~ ~:~o Anchorage 57oc 49.50 ¢6.50 ~oo~ TD ANGLE ¢3.50 40 DEG T/ ZONE A TVD=6025 TMD=8572 DEP=5387 ~ ~ ~0 50 B/ KUP SNDS TVD=6144 TMD=8730 DEP=5491 ~oo TD / LOGGING PT TVD=6297 TMD=8930 DEP=5620 '_ ' ' &o ' ,,'oo ' ,:oo ' ,,'oo ' I I I , I , , I , I I I I I , , ' 36'n0_ ' 39100 +2Ino .............. lDO ,,' .... % ~,'oo ~,' .... 'oo ~i .... 'oo SCALE ~ : J SO.O0 VeMical Section on 315.69 azimuth with reference 0.00 N, 0.00 E from slot #7 . , . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2M-05 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, test SSSV, set and test packer. ND B OPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED Afaska Oil & Gas CODS, Anchorage 7 ,6 , 5 4 3 13 5/8" 5000 I-'SI BOP STACK AOCUMUI,,ATOR 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 ARCTIC DIESEL. 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 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 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 BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 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. 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 SPOOLW/ 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 RE CEIV[ D ~UPARUK RIVER UNI! 20" DIVERTER SCHEMATIC 5 6 4 I HCR 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. 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-ON 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" 2OOO PSI ANNULAR PREVENTER ~ ~'~'~''~ ~{~"~ ~ ~1''''~ A~aska Oil & Gas Cons, Comra~ssion Anchorage E DF 3/10/92 ITEM (1) Fee (2) Loc ,, CHECK LIST FOR NEW WELL PERMITS APPROVE DATE '[-2 tl~ru .... (4) Casg ~.~..~ [14 thru 22] (5) BOPE ,,'/'~-~ ,~-2! - ~- [23 thru 28] (6) Other _~ [29 thr~ ~1] Company Lease & Well (7) Contact (8) Addl e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. YES NO 1. Is permit fee attached ............................................... ~._ _ 2. Is well to be located in a defined pool .............................. ~ ,,, 3. Is well located proper distance from property 1 ine ................... 4.. Is well located proper distance from other wells ..................... . .. 5. Is sufficient undedicated acreage available in this pool ............. ~ ... 6. Is well to be deviated & is we!lbore plat included .................. . ,,, 7. Is operator the only affected party .................................. 'L 8. can pemit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... ~ Is administrative approval needed .................................... Is 1 ease nt~nber appropriate .......................................... / Does well have a unique n~ne & n~nber ................................ ~. Is conductor string provided ......................................... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ .... Is enough cement used to circulate on conductor & surface ............ ~ Will cement tie in surface & intermediate or production strings ...... ~ Will cement cover all known productive horizons ..................... ~ ....... Will all casing give adequate safety in collapse, tension, and burst. .~ Is well to be kicked off from an existing wellbore ................... ~ ,,, Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. ~ Is a diverter system required ........................................ ~ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams & descriptions of diverter & BOPE attached .... ..~ Does BOPE have sufficient pressure rating -- test to ~~ psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... ,_ Is presence of H2S gas probable ......................... ' ............ ... ~ 29. 30. 31. 32. FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone n~rnber of contact to supply weekly progress data ...... 33. Additional requirements ............................................. REMARKS -rz u~-~ --I m geology: DWJ rev 04/92 jo/6.011 eng i neer i ng M LCS ' BEW'-~~ d- INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE ,, Add i t i cna 1 remarks' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIx. No special 'effort has been made to chronologically organize this category of information. .o COMPANY NAME : ARCO ~I.,ASKA, I~C. WEbb NAME : 2M-05 FIEbD NAME : KUPARUK~ RIVER BOROUGH ~ MORTH SLOPE STATE : ALASKA AP1 MUMBER : 50-103-20768 REF~RENCE NO : 92352 RECEIVED dUN 2 9 1992 Alaska Oi~ & Gas Cons. Commission Anchorage chlumberger Alaska ComDuting Center 24-JVN-lgg2 06:38 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 92/06/24 O~IGIN : FLIC REEL NAME : 92352 CONTINUATION # : PREVIOUS REEL : CO~ENT : ARCO ALASKA INC., 2M-05, ~UPARUK RIVER, 50-103-20768-O0 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 92/06124 ORIGIN : FbIC TAP~ NAME : 92352 CONTINUATION # ~ ! P~EVIOUS TAPE : CO~ENT : ARC~ ALASKA iNC., 2~-05, K[!PARUK ~IVER, 50-103-20765-00 PAGE: **** FILE HEADER **** FIbS NAME : EDIT ,00t SERVICE : FLIC VERSION : 001A06 DATE : 92/06/24 MAX REC SIZE FILE TYPE : LAST FILE : ******************************************************************************* ******************************************************************************** ** ** SCHLUMBERGER WELL SERVICES ** ******************************************************************************* ******************************************************************************* COMPANY NAME: ARCO ALASKA. !NC. WELL: 2m-05 FIELD: KUPARUK RIVER BOROUGH: NORTH SLOPE STATE: ALASKA API NUMBE~: 50-103-20768 LOCATION: 114' FN[,, & 64' FWL SECTION: 27 TOWNSHIP: PMRMANEMT DAT!~: ~SL ELEVATIO[~: 0 LOG MEASURED FRO~ RKB 146 ABOVE PER~ANEMT D~TU~ IS Tape Veri~icat~,on Listing chlumberger AlasKa Computin~ Center 24-JUN-I992 06:38 ELEVATIONS KB: 146 DF: 146 GL: DATE 50GGED: 04-JUN-92 RU~ NURSER: ONE TD DRILLER: 7338 TD LOGGER: 7338 CASING 1: 9,625 36 LB 0 DRILLER DEPTM OF -- TO 3166 BIT SIZE !: 8 1/2" DENSITY: 10.3 P~: !0,5 VISCOSITY: 47 FLUID ~UD RESISTIVITY: FILTRATE RESISTIVITY: 2,14 ~ ~0 2,26 0 71 TI~E CIRC!!LATION ENDED: 1800 ~!lXI~Ua TE~P RECORDED: 155 bOGGInG DISTRICT: LOGGING ENGINEER: PRUDHOE BAY PERRY/ST ANOUR TOOL NUMBERS: RG$022 NDS055 CDR. RP TO BIT =.68.3 CDN RP TO BIT = 130' ~P BiT RES. ~P TO BIT - 65, ;, ~R TO : 75,6 DRILLED INTERVAl.,: 3i 0 TO' 8930 MOLE CORRECTION : BIT SIZE, MATRIX DENSITY : 2,65 (G/CC) SAND. ROTATIONAL BULK DENSITY PR{JCES$ING USED, FLUID iJENgITY = 1,0 (G/CC) SLIDING INDICATOR SNOWN IN DEP~H TRACK, DATE JOB STARTED: 08-JUN-92 JOB REFERENCE NO: 92352 LDP/ANA: DEES * F!bE - EDIT,~O1 * ARCO ALASKA INC, * KUPARUK RIVER 2~-05 50-~03-~0768 IS Tape verlficatlon Listing chlUmberger Alaska Computing Center 24-JUM-1992 06138 PAGE~ . D LCG [)A.]A N' ~ 0'~ ':AP~ iS FROM 'RH00 ~AX' THE DENSITY DATA PRESE_ 7EL ~ THIS LIBRARY T ~ , ~ATA SAMPLED EVERY -,5000 FEET ..~A INCLUDED TOOL .~XTENS!O..E N' TOOL TYPE USED NAME RGS ,L~D NDS ,LWD LOGGING W~I'hg DRILLING RESIST!VITY/GR 3166' TO 8865' LOGGING WHILE DRILLING NEUTRON/DENSITY 316:6' TO 8798' ******************************************************************************** TABLE TYPE ~ CONS TUNI VALU DEFI TYPE ,, CN FN WN APIN $~CT TOWN RANG COUN STAT NATI WITN SON PDAT EDF TDD TDL BLI TLI DFT DFD DFPW DFV DFL ~ST RMFS MFST FT FT FT ~r MT FT FT FT FT G/C3 CP F3 OMMM DEGF OHMM OEGF ARCO AbA. SKA, INC, 2M-05 50 3- 0768 ', FNL & 64' NORTH SLOPE ALASKA USA 548953 MSL 146. 146, 146, 105. 7338, 7338, 7338, 3166, GEL/LI~, 1.0,3 10.5 7 2' !4 Cpmpany Name Field Name Well Name API Serial, Number Field LOcation Section Township Ran State or Crovlnce Nation Latitude Longitude Witness' Name Service Order Mummer Permanent datum Elevation of Perm, Da bog Measured From ABOVE PERMANENT DATU~ Elevation of Kelly BU Elevation of Derr!c~ Elevation of Grognd b TOtal DePth - Driller Total Depth -Logger Bottom bog Interval Top Log Interval Drilling Fluid Type Drilling Fluid Dehsit Drlllin~ Fluid Ph Drilling Fluid Vlscos Drillin~ Fluid boss Reslstivity of ~ud Sa ~{ud SamPle TemPeratur ReSistigitY of"mud fi ~ud Filtrate Sample T IS TaLe Verif~¢ation Listing 24-JUN-I. 992 06~38 PAGE: 4 chlumberger Alaska Co~puting Center TUNI VALU DEF! 'TYPE RMCS OH~ Resistivity of ~ud Ca ZONE MCST DEGF ~ud Cake Sample Tempe ZOnE TCS ~800 Tim~e Circulation StOp STE~ DEaF 3~ Surface Temperature BHT DEGF l~, Bottom ~ole Temperatu TABLE TYPE : ZONE TUN! BOEP TDEP RMCS MCST ~. 1 PT O, O, O, O, TABLE TYPE : CURV DEPT DRHO PEF DCA5 DPH! ATR DEFI Depth Channel Name Bulk Density Delta RHO Photoelectric Factor Differe~tial'Caliper Density Porosity T~ermal ~eutron Porosity Gamma Ray ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** .... ...... ..... TYPE PR CODE ALUE 1 66 2 66 0 3 73 44 4 66 5 66 6 73 7 65 8 68 0 5 IS Tape ~ Yerlflcation chlumberger AlasKa Computing Center 24-JUN-lgg2 06;38 11 66 23 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 mmmmm.m.lmmm.mmmmm.mmm.mmmmm.m ** SET TYPE - ..ME SERV IT API AP1 ID ORDER FT 548953 O0 00 DFPT RHO~ LWD G/C3 548953. O0 O0 D~HO LWD G/C3 548953 O0 O0 PMF LWD 548953 O0 O0 DC~[.~ LWD IN 548953 O0 OO DPHI LWD PU 548953 O0 O0 TNP~ LWD DU 548953 O0 O0 ATR LWD OHMM 548953 O0 O0 PSR LWD OHM, 548953 O0 O0 ROP~ LWD F/HR 548953 O0 O0 G~ LWD FISE NU~i~ NUMB . ZE REP~ PROCE$'"' OD NUMB SAgP E. LEM CODE (HEX) 0 O0 0 I 1 I 4 68 0000000000 0 O0 0 1 I I 4 68 0000000000 0 O0 0 1 I 1 4 68 0000000000 0 O0 0 1 I 1 4 68 0000000000 0 O0 0 I I I 4 68 0000000000 0 OO 0 I 1 I 4 68 0000000000 0 O0 0 I 1 I 4 68 0000000000 0 O0 0 I ~ ~ 4 68 0000000000 0 O0 0 I 1 1 4 68 0000000000 0 O0 0 1 I I 4 68 0000000000 0 O0 0 I i I 4 68 0000000000 mmmmm--m)mMmmmm.#mmmmmmmmmm~m..#m.m..mmm.mmm.~mm~Mmmm!.· DATA DFPT. 8929,500 RHOB.bWD DCAL,LWD '999,250 DPHI.bWD PSR,LWD -999,250 ROPE,LWD DEPT. 8900.000 RgOB LWD DCAL,LWD -999,250 DPHI~LWD PSR,LWD -999,250 ROPE.LWD D~PT. 8~00.000 RHOB.bWD DCAL,LWD -999.250 DPHI,bWD PS~.LWD 2,903 ROPE.LWD DEPT 8700.000 RHOB.LWD DCAL:LWD 0..495 DpHI.LWD PS~'LWD 2,677 ROPE.LW~ D~PT 8600.000 RHOB,LWD DCAL:LWD 0,412 DPHI.LWD P$~,LWD 9.589 ROPE.LWD '999' SO TNP. 5WD -999 0 ATR 33'914 GR,LWD -999~i 50 '999 250 DRHO,LWD -999.250 PEF.LWD '999:250 TNPH.LWD -999.250 ATR,LwD 46.631 GR.5WD -999.250 -999 250 DRHO.LWD -999.250 -999!~5~ TNPH, ' LWD -999.250 ATR LWD 39 8 GR,[,WD 80.381 2.535 DRHO,b~D 0 024 PEF.LWD 0'070 TNPH.bWD 36:600 ATR.L~D 88,188 GR.GWD 89.924 ' 2,342 DRHO,LWD 0,015 PEF.LWD 0,187 TNPH.LWD 282400 ATR.LWD 86.143 GR,LWD 59,546 -999. 50 -999'~50 -999250 -999:2so -999.~50 3, 31 3 662 2:5o 2.914 ~0,380 c.hlumberger Alaska Com st. ino utinO Center DEPT. 8500.000 DCAL'LWD 0 ~4! DPHI'5~D PSR,[~WD i]i 38 ROPE'LWD DEPT,, 8400.000 DCAL.bWD 0'594 DPHI,LWD PSg'LWD 1,822 R(~PE.LWD DEPT,L~D $300,000 RHOB.SWD DCA[' O, 26 DPHI.LWD PSR.L~D 3, 68 DEPT. 8200,000 DCAL.LWD 0,352 DEPT 8100.000 DCAL:LWD 0'069 DPHI,~,WO PSR.LWD 32142 ROPE,LWD DEPT, 8000.000 ~,LWD 3, DEPT' 7900.000 RHOB.LWD DCAL'LWD 0.101 DPHI PSR'LWD 3,491 ROPE:bWD DEPT, 7800.000 RHOO.LWD DCAL,LWD 0.000 DPHI,LND PSR.LWD 4,833 ROPE*LWD DEPT, 7700,000 RHOB.LWD DCAL.LWD 0,~07 DPHI.LWD P$~,[,WD 3,888 ROPE.LWD D~PT, 7600,000 DCAL.LWD 0,288 DPHI.LWD ~$~.LWD 3,805 ROPE.LWD DKPT. 7500.000 RMOB,LWD DCAL.LWD 0,261 DPHI.LWD PSR.LWD ].512 ROPE'LWD DEPT. 7400.000 RHOB.LWD DCAL.LWD 0,116 DPHI.LWD PSR,LWD 3,425 ROPE.LWD DEPT. 7300.000 RHOB.LWD DCAL.LWD 0,!67 DPHI.LWD PS~.LWD 3'849 ROPE.LWD 24-dUN-1992 06:38 0 00 21. ~94 2.594 o.o 4 2,407 DRHO,~D 106'513 GR'L~D 2.576 DRHO.LWD 0,045 TNPH,LWD 44,227 GR,LWD 2,385 0,16! TNPf{.bWD 165,162 GR,LWD 2,425 0 ~36 TNPH.LWD I36~i 44 GR.LWD 2.462 DRHO.LWD 0,.114 TNP~,LWD 250,010 GR.LWD 2,463 DRHO.LWD 27~,!13 TNPH,hWD ,49!. GR,.bW'O 2,508 0.086 TNPH,LWD 298.847 GR.LWD 2.457 0 1i7 300::968 GR,LWD 2,463 DRHO.L~D 0.!13 T~P~,LWD 222,206 2.481 DRHO.LWD 0 !03 TNPH,LWD 318:85o GR.LWD ~.455 DRHO.LWD 0 8 TNPM,LWD 0,~29 4i,+00 106.121 0.030 41~00 ,o21 -0,:003 ! ~ 676 o 02o ~0i600 ~7~798 0o0~7 35,800 106~.068 4! 0o !18.725 -0,~006 341'900 97'.248 0.olo 29'900 98'03O 0 0O7 30i!00 92 830 96.252 0.,OO2 33.300 102.376 100.502 -0.004 34 30O 11i:429 PAGEi 3,6'32 1,640 4.~30 !.i5 3,455 3; 375 4, 79 3. 31 ,84,4 · 644 :! 0 i :468 640 3.178 4,108 :2' 777 3.89~ 3.489 3.445 3,369 3.352 3.197 3.557 tis Ta.ve Verification Listino. ichlumherger .AlasKa Computlnq Center DEPT, 0 029 DPHI DCAL LWD 7200.000 DEPT 7100.000 RHOB.LWD DCAL'!~WO 0'026 DPHI.LWD PS~:LWD 4'079 ROPE.LWD DEPT 700~:,000 RI!OB.LWD PSR LWD 5'6" .., ' , 75 ROPE,LWD DEPT. 690~,.000 RHO~.LWD DCAL.LWD ,271 DPHI.LWD Sr,LWD .020 DEPT 6800 000 R..~O~, . DeAL L~D 0,.447 DPHI PSR:LWD 3'319 OPE DEPT,:. 6700,000 i ,. W DeAL LWD 0 187 DPHI,L..D PS~.LWD 2:739 ROPE.LWD DE, PT. 6600.O00 RHO8 :LWD DCAL.SWD 0.307 PSR'LWD 2,586 ROPE.LWD DEPT. 6500,000 DCAL.LWD O.'145 DPHI.LWD PSR,LWD 2.239 ROPE.LWD DEPT'. 6400.000 RHOB.LWD DCAL,LWD 0.242 DP~I.LW[) PSR.LWD 3,763 ROPE.LWD DEPT, 6300.000 DCAL,LWD 0 300 DPHI.LWD PSR.LWD 3:819 ROPE.LWD D~P~ 6~00.000 RHOB D~AL' I, WD 0 1~3 DPHI:LWD ' SR~LND 3~54! ROPE.LWD DrPY. 6 o0.ooo RHO .hWD DCA ' WD DPHt.r D DSR.LWD 1.862 ROPE.LWD DEPT. 6000,000 RHOB.LWD DCAL.LWD 0 080 DPHY.LWD PSR.LWD 2:347 ROPE.bWD 24-dUN-1992 06:38 2,421 DRHO.hWD 0.139 305'989 'GR'DWD 2.353 DRHO.LWD 0,!b0 TNPH,LWD 246,322 GR,bWO 45 226 !7 GR,bWD 2,3~2 DRH0,hWD 0,~ 1 TNPH,LWD 247. 90 ~R.LWD 2,394 D~B0,SWD 0.155 TNPH'LWD 398.033 GR,LWD W 0,197 TNPH.L ~D 359. 967 GR. LWD , 252 DRHO.SWD .24! TNPH,LWD 325'151 2.349 DRH0,bWD .1 83 TNPH,hWD 32 ,254 265 79 2.473 D~HO~LWD 0,108 TNPH,LWD 476,275 'GR,LWD 2.394 DRHO,LWD 0 155 TNPH,SWD 414:576 GR,LWD 2,422 DRHO.LWD o 118 381:162 'GR.GWD 2.]37 DRHO.GWD 0 190 579~444 GR,G~D 2~.600 8 '.098 0.013 !10.373 0'04~ 67.383 0.0~9 3~,900 67.265 -0.012 62.998 -0,023 .236 -0 015 3:4oo 70"466 -0.002 35.000 85.100 -0'00! 35.:~ 6 ~02. 0 39i700 106 459 :oos 80O 124.347 0.028 39.700 ~22.535 -0.009 40.400 139.717 PEF.LWD ATR.LWD PEF.LWD ATR.b~D A?R.5~D PEF.b~D ATR.5WD PEF,L~D ATR.L~D PEF,LWD ATR,LWD PEF.LWD ATR,LWD ATR'LWD PE~.L~D ATR,L~D PEF.LWD ATR,L~D PEFoL~D AT~.L~D PEF.LWD ATR.L~D PEF,LWD AT~.LWD PAGE: 3"212 2.227 , 2.601 4,522 ~,5!7 2,634 3,255 2.689 2:,876 2.481 2,~92 3,057 2.327 31.208 3,837 462 3,297 2.0~6 3.323 2,087 ,'IS Tape Yerlflcatlon Listfn~ :chlu~erger ~laska Co~uti~ Center DFPT, 5800,000 RHOB,LWD DCALiSWD 0.000 DPNI.LWD PSP,LWD 2.071 ROPE.LWD D~PT'. 5700.000 RHOS,LWD DCAL,LWD 0,000 DPHI.LWD PS~,LWD 3,001 ROPE.LWD D~PT, 5600.000 RHOB.LWD DCAL,LWD 0.00o DPMI'LWD Ps~,:Swo 2'71i nOP~:'nWD EP? 5500,000 RMOB LWD C~5' ~ · ..... pS~.L~D 0,000 DPBI.hWD ,LWD 2'547 ROPE,L~D DEPT, 5.400,000. RHDB,LWD DCAL.LWD 0,075 DPHI,SWD PSR,LWD 3.t~0 R[]PE.LWD DEPT. 5300,000 RHOS,SWD DCAL'LWD 0.1~2 DPHI,SWD P$~,LWD 2.894 ROPE*LWD DEPT 5200.000 RHOB.LWD ocA['t~w~ o'ooo D?.!..X~WD P$~.'BWD 2.885 ROPE'.LND D~P~ 5100,000 ~H:OB.LWD PSR,LWD 3,2~0 ROPE,SWD D~PT, 5000,000 RHOB 5WD DCAL,SWD 0.154 DPHI:L~D PSR,LWD ],343 RODE,L.D D~PT, 4900,000 RHOB,LWD DCAL,LWD 0,12~ DPHI,LWD PSR.LWD 3.518 ROPE.LWD DFPT. 4800,000 RNOB.5ND DCAL LN~ 0.022 DPHI.SWD PSR:LW 3'274 ROPE"LWD DEPT, 4700.000 RHOB.LWD DCAL.LWD 0.149 DPMI.LWD PSR.LWD 2.9!9 ROPE.GWD 24-JUN-1992 06:38 0,212 TNPH,SWD 53g,967 .315 D~HO,bWD ~,20] TNPH;hWD 45~.549 GR,LWD 2,3!0 DRHO,~WD 0.206 TNPH,5WD ]40.059 ~,~56 DRHO,LWD 0,~39 TNPH,LWD 431'908 GR.'LWD 2.264 DRHO,LWD 0.~22 TNPN,LWD 235.862 GR.LWD 2,336 DRHO,[~WD 0.190 TNPH.LWD 500.420 GR,~WD 2,326 0.196 TNPH,LWD 567,709 GR,DWD 2.290 DRHO,SWD 0 218 TNPH.LWD 448:910 GR,SWD 2 361 DRHO.LWD 0i175 TNPH.L~D 102 272 GR.LWD 2.243 DRHO,LND o 2~6 290:325 GR.LWD 0.262 T~PH.SWD 267.201 GR,5WD 2,~55 DRHO,G~D 29].304 GR.GWD ~,]2~ DRHO.LWD 0 199 ?RPH.5WD 313~808 001 ~oooo~ 9S;5~2 -0,009 36. 0 -0.006 36:,700 95.463 -0010 7i500 0.002 ~2'5o0 77.!12! ~0.002 38~3B 98~ O0 0 006 36 800 82 247 0,~002: 33.~00 -00 7 88 222 -0 020 78 80 -0.018 35.700 84.636 0.013 37 200 PEF.SWD ATR'b~D PEF, ~WD ATR'[WD PgF*bWD AT:R.bwD PEF.bWD ATR,LWD PEF,LWD ATR,LWD PEF*bWD PEF'LWD ATR,LWD PEF.I~WD PEF*bWD PEF'bWD ATR*bWD PEF, LWD ATR*LWD PEF.SWD ATR,LWD PEF.LWD ATR.LWD PAGE.: 2,906 t,871 2'903 2'085 2,964 2,710 f.764 · 7 8 0 2'755 2,520 2,767 3,165 3,029 '3,010 950 ,830 ,464 ,474 ~.47g 2 555 3': 841 2.755 3,375 2.946 3,002 .IS Tape Verification !,isting ;chlumberger AlasKa CompUting Center R.AOB.L~D DEPT':,WDI 46.00,000 DCab. 0,225 DPHI.LWD PSR,LWD 3~236 ROPE.LWD DEPT, 4500,000 RHOB.LWD DCAL,LWD 0,.114 DPHI,LWD .. i ROPE.LWD PSR,LWD 3,474 DEPT' 4400.000 DCAL'LwD 0,309 ' PSR'bWD 3,551 ROPE,LWD DEPT, 4300,000 DCAL'[,WD 0,:137 DPHI,LWD PSR,'LWD 3,177 ROPE,LWD DEPT. 4200.000 DCAL.~WD 0.:193 DPHI.LWD PSR~LWD 3'476 ROPE.LWD DEPT, 4100.000 RNOB.LWD DCA!.~.L~D 0, 46 DPHI.GW[ PSR L~D 3-8 , . 3 ROPELWD DEPT, 4000,000 RHOB,LWD DCAL,LWD ~ !52 DPH!,~WD PSR,LWD :66! ROPE,LWD DEPT, 3900,000 RHOB.SWD DCAL LWD 0,042 DPHI.bWD PS~:SWD 3,507 ROPE.GNP DFP? 3800.000 RHOB.~WD DCA[;'SWD ' 0 208 DPHI.nWD PSR:~D 3:5~5 ROP~.GWD DEPT, 3700,000 .DCAL.LWD 0.284 DPHI,LWD PSD.LWD 8.375 ROPE.LWD DEPT. 3600.000 RHOB.LWD .. LWD DCAL.LWD 0,000 DPHI, PSR.LWD 6,010 ROPE.LWD D~PT. 3500.000 RHOB.SWD DCAL.LWD 0.1~5 DPHI,LWD PSR.LWD 3,872 RGPE,LWD DEPT 3400,000 RHO~.LWD DCAS:LWD 0,144 DPHI.LWD PSR.LWD 4.543 ROPE,L~ 24,-JUN-1992 06:38 2.340 0.188 388.~28 2,393 0,156 2S~.429 2,306 0,~08 111. 81 2,296 360, 0 0,2~ 236,839 2.224 241;25~ ,608 2 ~78 0 ~6 251 518 2,120 0'321 367.066 2,207 0,269 328,27! 2,279 0,225 299,060 2,!49 0 303 2,057 0,359 311.978 2,184 0.2~2 287,590 006 $6'295 0.031 35.800 79.470 -0.023 37,~00 84.240 0.~07 3S:~O0 95'826 0.002 39,800 78.052 0.004 40'~00 77,730 0~003 42 lO0 65 553 0.010 45,400 68'893 -0,005 39! O0 91 ~86 -0.022 3~.600 11,.674 0.010 44.300 80.355 0 014 49'600 -0.003 39.300 95.777 PEF.LWD A. TR'LWD PEF.LWD ATR'LWD PEF.,~WD ATR,tWD PEF'LWD ATR,LWD PEF LWD PEF*LWD ATR,L~D PEF,LWD ATR,LWD PEF.bWD ATR.LWD PEF,LWD ATR,LWD PEF.LWD ATR.LWD' PEF.LWD ATR,LWD PEF.LWD ATR.LWD PEF,LWD ATR.LWD PAGE: 2,831 3.328 3.349 3,758 2'6t6 3'673 2.692 3,322 · ,774 ~,670 2'680 4,994 ,771 2,634 7,~22 2.658 6,583 2.5tl 4"043 2,654 4,89~ ~!S Tape Verification 5istJlnq ~chlumberger AlasKa Computing Center DEPT,L~D 3300,000 RHOB.L~D DCAL. ' 0,!73 DPHI.hWD PSR.LWD 5,1!6 ROPE.LWD DEPT. 3200.000 RHOB,LWD DCAL,LwD 0.376 DpHI'LWD PSR'LWD 6,8~6 DEPT. 3!00.000 RHOB,bWD DCAL'LWV 0.4~.4 PS~.LWD -999.250 ROPE.LWD ~Ep~. 3041.500 RHOB.DWD [CAL'LWD -999.250 DPHI,DWD PSR,LWD '999.250 ROPE,LWD ** END OF DATA ** 24-jOg-1992 06:38 0[2 0 TNPH,DWr) 650 804 GR bu 2.308 DRHG,bWD . 0'208 TNPH.hWD 999'250 -999.250 DRNO,LWD -999.250 TNPH.~LWD -999'250 GR~L~wD 67.803 36 oo -999.250 999 50 PEF,LWD ATR.LWD PEF.LWD ATR.LWD PEF.LWD ATR.LWD PEF.bMD ATR.LwD 2.567 5,291 2.840 7'225 100,000 -999~250 -999.250 -999,250 0 **** FILE TRAILER **** FILE NAME : EDIT ,001 S~RvICE : FDIC VERSION : 00!A06 DATE : 9~/06/24 ~AX REC SIZE : ! 24 FI'DE TYPE : LO LAST F'IbE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 92/06/24 ORIGIN :FLIC TAPE NA~E ; 92352 CONTINUATION # : 1 P~EViOUS TAPE : COMMENT : ARCO ALASKA INC., 2M-05, KUPARUK RIVER, 50-103-20768-00 **** REEL TRAIbE~ **** SERVICE NAME : EDIT DATE : 92/06/24 ORIGIN : FDIC REEL NAME : q235~ CONTINUATION # : P~EVIOUS REEL : COM"ENT : ~RCO ALASKA !NC,, 2M-05, KUPARI.IK RIVER, 50-103-20768-00
