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Home My WebLink About187-038 STATE OF ALASKA • ALL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Qperations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ .erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Gravel Pack w/HCL 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development Q Exploratory❑ 187-038 3.Address: P. O. Box 100360,Anchorage, Stratigraphic❑ Service❑ 6.API Number: Alaska 99510 50-029-21718-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3M-11 ADL 25523 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,959 feet Plugs measured None f E C E I V Ery true vertical 6,434 feet Junk measured 7156, 7677 feet V �„/ SEP 2 9 2017 Effective Depth measured 7,724 feet Packer measured 7,537 feet true vertical 6,255 feet true vertical 6,113 feet /►OG/ti, Casing Length Size MD ND Burst Collapse CONDUCTOR 77 feet 16 " 115' MD 115 TVD SURFACE 3,835 feet 9 5/8" 3,872' MD 3331 TVD PRODUCTION 7,869 feet 7 " 7,899' MD 6388 TVD Tubing(size,grade,measured and true vertical depth) 3.5" L-80 7,563' MD 6,133'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER 3.5"X 7"SAB-3,PERM.PKR 7,537' MD 6,113'TVD SSSV -NONE 514' MD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED DEC 1 4 Z0I 1, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut-In 0 0 0 0 Subsequent to operation: 50 100 700 610 215 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I] Exploratory ❑ Development El Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-605 Contact Name: Marshall Brown Authorized Name: Marshall Brown Contact Email: H.Marshall.Brown@cop.com Authorized Title: Wells Engineer /': A Contact Phone: (907)265-6218 / ,T ,�,ry �� Authorized Signature: (L+; livriv� Date: 9/0S/Z0/ � � .ice 7.-- tin- 10` l7]I. - iof/sl7 Form 10-404 Revised 4/2017 RBDMS 1 - OCT - 3 2017 Submit Original Only 0 • 3M-11 Operations Report 9/14/2017 3M-11 "PUMPED 25 BBLS DSL DWN TBG PUMPED 8 BBLS DSL DWN FL 9/14/2017 3M-11 WITH 2.5" BAILER,TBG TO TOP OF PIIP PACKER @ 7544' RKB. BAILER EMPTY. MEASURE BHP @ SAME (^'2 DAYS AFTER 25 BBLS PUMPED DOWN HOLE) SBHP OF 3,848 PSI MEASURED. JOB COMPLETE. 9/12/2017 3M-11 "PUMP 15 BBLS METH DOWN IA PUMP 25 BBLS METH DOWN TBG JOB COMPLETE" 9/9/2017 3M-11 PULLED DV AND SET GLV @ 4630' RKB. PULLED DV AND SET GLV @ 2961' RKB. SWEPT TBG FOR MISSING LATCH PARTS. PERFORMED DDT ON IA. PULLED TEST TOOL @ 7544' RKB. MISSING WOBBLE RING AND SPRING RECOVERED IN CATCHER. COMPLETE. 9/8/2017 3M-11 MULTIPLE ATTEMPTS w/OVERSHOTS AND SPEARS TO FISH DV w/MISSING LATCH @ 6578' RKB, NO SUCCESS. PERFORMED A PASSING MIT-T TO 2500 PSI CONFIRMING DV @ 6578' RKB WITH BROKEN LATCH HAS INTEGRITY. PULLED DV AND SET OV @ 5757' RKB. IN PROGRESS. 9/7/2017 3M-11 MULTIPLE ATTEMPTS w/SPEARS AND OVERSHOTS TO FISH DV w/MISSING LATCH @ 6578' RKB, NO SUCCESS. IN PROGRESS. 9/3/2017 3M-11 SET 2.72" PII PACKER,SPACER PIPE, 2.70" LATCHING OVERSHOT(13.29'OAL), TOP OF PACKER @ 7544' RKB. SET TEST TOOL IN PII PACKER @ SAME. PULLED RUNNING & PULLING NECK FROM LATCH ON DV @ 6578' RKB. RAN LIB ON KOTTO SAME; IMPRESSION SHOWS TOP OF NO-GO(PIC IN ATTACHMENTS/WOBBLE RING &SPRING IN HOLE). IN PROGRESS. 9/2/2017 3M-11 TAGGED @ 7565' RKB WITH 2.725" LIB(PARTIAL IMPRESSION OF VENT CAP). PULLED UPPER SECTION OF GRAVEL PACK SCREEN ASSY @ SAME (ANCHOR LATCH NOT SHEARED).ADDED 10'SPACER PIPE TO BHA AND SET TOP @ 7555' RKB.ATTEMPTED SET 2.72" PIIP, SPACER PIPE, LATCHING OVERSHOT; BOTTOM FEED THRU PIN LOST CONTINUITY NOT ALLOWING CMDFIRE TO RECEIVE COMMAND. IN PROGRESS. 9/1/2017 3M-11 RIH WITH OVERSHOT,TAG GLM STATION #6 AT 7451' RKB, POOH TO ADD A KNUCKLE JOINT, RIH TO TAG SCREEN VENT TOP AT 7591' RKB,APPEARS THAT THE ENTIRE SCREEN HAS MOVED DOWN HOLE INTO THE 7" CSG,JOB SUSPENDED. 8/31/2017 3M-11 TAGGED SAND SCREENS AT 7552 KB, LAY IN 19 BBLS HEC GEL WITH 1200#OF 20/40 SAND,SECOND RUN CONFIRMED SAND IS ALONG SIDE OF VENT PLUG, RETURN IN AM FOR FCO,JOB IN PROGRESS. 8/29/2017 3M-11 RAN TTS GRAVEL PACK SCREEN ASSEMBLY(90.06'OAL) IN THREE SEPERATE RUNS. HUNG OFF BHA1 IN THE TUBING ON J-ANCHOR LATCH AT 7463' RKB. DEPLOYED BHA2 AND 3, ENGAGING POLISH BORES W/ANCHOR LATCH SEALS ON EACH SECTION. WITH BHA1, 2,AND 3 ASSEMBLED DOWNHOLE, RELEASED BOTTOM J-ANCHOR LATCH AND LANDED TOP OF ASSEMBLY @ 7555' RKB, BOTTOM OF ASSEMBLY ESTIMATED TO BE AT 7645' RKB. READ FOR CTU TO LAY IN SAND. KUP OD11110 3M-11 • ConocaPhillips �.: Well Attrib Max Angle&MD TD AI<9ket.Inc. Qj, Wellbore APUUWI Field Name Wellbore Status Ind(°) MD(RKB) Act Btm(ftKB) ConocoPhillips 1 500292171800 KUPARUK RIVER UNIT PROD 1 46.10 2,400.00 7,959.0 .°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-11,9/26(20173:37:37 PM SSSV:NIPPLE 260 12/7/2005 Last WO: 6/2/1997 42.51 5/9/1987 Vertical schematic(aclan5 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 7,565.0 9/2/2017 Rev Reason:SET GRAVEL PACK SCREEN pproven 9/15/2017 ASSEMBLY,GLV C/O 8 PULL TTS TEST TOOL Casing Strings HANGER,34.0 ',:vr Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread la-WI CONDUCTOR _ 16 15.062 380 115.0 115.0 62.58 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L..Grade Top Thread SURFACE 95/8 8.835 37.0 3,871.7 3,331.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 30.2 7,898.7 6,387.9 26.00 J-55 BTC Tubing Strings uuLTubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt(lb/ft) Grade Top Connection ~qv '4. TUBING 3 1/2 2.992 34.0 7,563.5 6,1333 9.30 L-80 EUE ABM CONDUCTOR,36.0-115.0 i • Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) NIPPLE:513.9 34.0 34.0 0.15 HANGER FMC Gen IV,3 1/2"Tubing hanger,31/2"EUE land the 2.992 ' 513.9 513.9 0.54 NIPPLE CAMCO DS Nipple w/2.813 NO-GO profile,OD 4.54 2.813 is 7,497.3 6,082.9 40.44 NIPPLE 3.5"CAMCO W Nipple w/2.812 selective profile,OD 2.812 GAS LIFT,2,960.9 4'54" 7,536.7 6,112.9 40.46 PACKER Baker 3.5"0 7"SAB-3,perm.Pkr.,w/K22 Anchor seal 3.000 assembly J : .: : .: . : : .: • • . . , . , .• SURFACE;37.0-3,671.7 . .• 7,551.5 6,124.2 40.48 NIPPLE CAMCO 3.5"D Nipple w/2.75"NO-GO profile.OD 4.500" 2.750 .•• iH7,562.6 6,132.6 40.49 SOS Baker 3.5"SOS pinner for 3500 psi.OD 4.500",ID 2.937" 2.937 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) To p(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,156.0 5,824.5 41.20 Fish 3 KOT ARM Springs Lost while Running GLV 6/25/1997 1.000 GAS LIFT,4,630.3 7,544.0 6,118.5 40.47 PACKER 2.72"PII PACKER,SPACER PIPE,2.70" 9/3/2017 1.875 LATCHING OVERSHOT(13.29'OAL) MID ELEM @ 7546.5'RKB GAS LIFT;5,756.8 - 7,544.0 6,118.5 40.47 GRAVEL GRAVEL PACK ASSEMBLEY 9/3/2017 0.000 PACK IASSEMBLEY 7,554.0 6,126.1 40.48 19 BBLS 19 BBLS HEC GEL WITH 1200#OF 20/40 SAND, 8/31/2017 0.000 GAS LIFT,6,577.6 ,. HEC GEL CONFIRMED SAND IS ALONG SIDE OF VENT WITH 1200# PLUG OF 20/40 SAND GAS LIFT,7.1557 7,555.0 6,126.8 40.48 GP SCREEN TTS GRAVEL PACK SCREEN ASSEMBLY(90.06' 8/29/2017 0.000 OAL) I • • • 19 BBLS HEC GEL w/1200#20/40 SAND ON TOP DEPLOYMENT SUB(MID); OF SCREEN BHA 7,3670 7,677.0 6,219.6 40.48 Fish CTU FISH COILED TUBING FISH LEFT IN HOLE 3/2/2006 1.000 DEPLOYMENT SUB(423); Perforations&Slots ,423.0 Shot GAS LIFT,7,451 B } To ND Btm NO Dens ITop(ftKB) Btm(ftKB) p( ) ( ) (shots/ (ftKB) (ftKB) Zone Date ft) Type Corn 7,650.0 7,676.0 6,199.1 6,218.8 C-4,A-1,3M- 9/5/1987 12.0 IPERF 5"HSC;120 deg. 11 phasing Mandrel Inserts at ti ., .,. on Top(ND) Valve Latch Port Size TRO Run NIPPLE,7,497.3 - - N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com tor I. 1 2,960.9 2,652.3 Camco KBUG 1 GAS LIFT GLV BK 0.188' 1,357.0 9/9/2017 2 4,630.3 3,899.8 Camco KBUG 1 GAS LIFT GLV BK 0.188 1,328.0 9/9/2017 ' 11 3 5,756.8 4,764.4 Camco KBUG 1 GAS LIFT OV BK 0.250 0.0 9/8/2017 4 6,577.8 5,389.4 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/6/2016 Broke PACKER 7,53E7 �4��. n Latch has 77 Integr ity- Wobb PACKER 7,544.0 3 , le NIPPLE;7,551.5 ring 8 sprin liti . ecov . 5 7,155.7 5,824.3 Camco KBUG 1 GAS LIFT DMY BK-5 0.000 0.0 7/7/2005 ,Aran 6 7,451.7 6,048.3',,Camco MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/7/2005 Oil Notes:General&Safety SOS,7,562.6 End Date Annotation 11/29/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 IIIA GRAVEL PACK ASSEMBLEY; 7,544.01 GP SCREEN;7,555 0 1,1 i 11 IPERF,7,650.0-7,6760-1 { I I PRODUCTION;30.2-7,898.7 i l V OF T y� • • 11/7,,• THE STATE Alaska Oil and Gas ��tt 0/A LA c KA Conservation Commission art}t 333 West Seventh Avenue '' " c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 TIP* Main: 907.279.1433 oA'ALAsA‘ks. .r,,. ..,_, ,,.,.;,., Fax: 907.276.7542 www.aogcc.alaska.gov Marshall Brown Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360SCAB —ri t Ah , �l LL Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3M-11 Permit to Drill Number: 187-038 Sundry Number: 316-605 Dear Mr. Brown: 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, F-)i Cathy P. Foerster Chair DATED this 2e---,ay of December, 2016. RBDNNS LL DL 2 9 2016 • • STATE OF ALASKA NOV 2 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 24 241/4. APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations E Fracture Stimulate E Repair Well r Operations Shutdown E Suspend E Perforate E Other Stimulate r Pull Tubing E Change Approved Program E Plug for Redrill E Perforate New Pool ��''''``Re-enter Susp Well 1 Alter Casing 1 Other: Gravel Pack w/HCL 3 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory r Development 17 , 187-038 ' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 500292171800 , 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 r No i / KRU 3M-11 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25523 * Kuparuk River Fields/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7,959' • 6,434' " 7724 ` 6255 • NONE 7156,7677 Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 115' 115' Surface 3,835' 10" 3,872' 3,331' Production 7,869' 7" 7,899' 6,388' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7650-7676 , 6199-6219 3.500" L-80 7,563' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER 3.5"X 7"SAB-3,PERM.PKR.,W/K22 ANCHOR SEAL ASSEMBLY " MD=7537 TVD=6113 SSSV ' NIPPLE-DS Nipple w/2.813 NO-GO Profile 12.Attachments: Proposal Summary 0 Wellbore schematic D 13.Well Class after proposed work: 1 Jib Detailed Operations Program ❑ BOP Sketch ❑ Exploratory I— Stratigraphic • Development 17' Service E 14.Estimated Date for 12/12/2016 15.Well Status after proposed work: Commencing Operations: OIL F WINJ WDSPL ESuspended E 16.Verbal Approval: Date: GAS fl WAG E GSTOR E SPLUG E Commission Representative: GINJ E Op Shutdown I— Abandoned E 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Marshall Brown @ 265-6218 Email H.Marshall.Brownaaconocophillios.com Printed Name MarVy Brown Title Wells Engineer i .--- {\ /Z1 / ZO(0. Signature ./ Phone 265-6218 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ';k1•2^1.e05 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: _/ cc--- vz_h_t,1 1 k Post Initial Injection MIT Req'd? Yes 1:1 No Ltd Spacing Exception Required? Yes No Subsequent Form Required: S DEC❑ ��' �n� RC®�� L v 2 9 2D16 p APPROVED BY Approved by: / ,1 COMMISSIONER THE COMMISSION Date:/2__ 2)3.-/ . (-1? 'o 1"3 � A� Submit Form and Form 10-40z:// iced 11 ois r ��pp is valid for 12 months from the date of approval. Attachments in Duplicate '?I(4 II/OP r 1C3vab • • 1. The following steps will be taken prior to procedure. The well will be cleaned out with CT. Injection rates will be taken to verify a competent conduit for the GP. GLM dummies will be installed. 4.5 bbl. of 75# Cross linked K-Max pill spotted across perfs to prevent sloughing. 2. MIRU Slickline and run a 2.725" Gauge run to±7,666'. POOH.Note any tight spots encountered during run. POOH. 3. RIH with the following Slickline bottom hole assembly: LENGT DEPTH DESCRIPTION O.D. I.D. H (Feet) (Feet) PBTD 7,666.00 PX Plug(3rd Party Supplied) 2.72 /////// 0.60 7,665.40 xx 5 A PX Pulling Tool (3rd Party Supplied) 2.70 /////// 1.00 7,664.40 0 B Combination Bull Plug, 1-1/2"NU 10Rd x 5/8" 2.20 /////// 0.33 7,664.17 SR 0 1-1/2" NU LORD Premium Screen(2 Jts.) L-80 2.30 1.610 20.00 7,644.17 C 2.300" O.D. x 1.610" I.D. 4.83 lbs/ft 10.00ft 0 Long D 1-1/2"NU 10Rd Bow Spring Centralizer w/ 2.26 1.610 2.46 7,641.71 2.200" OD Collar 0 E 1-1/2" NU 10Rd Sand Height Control Valve 2.20 1.400 0.57 7,641.14 (2,200 psi Shear Value) 0 F 1-1/2"NU 1ORD N-80 Blank Pipe w/2.200" 1.90 1.610 94.51 7,550.13 OD Collars 0 3 1/2" 9.3# Removable Vent Plug Assembly 2.12 1.150 3.50 7,546.63 G Latching; includes Polished nipple w/2.700" 5 Weld-on centralizers, 18" 8 gauge Vent screen and 1.750" Removable Vent plug BHA Left In Wellbore 119.37 4. Go in hole with vent screen BHA at a maximum in-hole rate of 60' per minute. Record pick-up, neutral and slack-off weights every 1,000'. Run correlation log and tie-in tool string. Gently tag PBTD at 7,668'. Confirm Wire-line depth. Release the vent screen assembly. POOH. 5. Hook up pumping equipment to tubing and establish injection rates at 1,2, 3 bbl/min.Note and record the corresponding pressures at each rate. 6. Pump the following thru coiled tubing: a. 1000 gal 15%HC1 spearhead to clean up K-max pill; circulate to bottom b. Displace 1 bbl of Gel Pad c. 107 bbl of gel containing 2 ppg of 20/40 Econo-Prop. 10,000 lb total • • 7. Pump the slurry at highest rate allowed until sand out is achieved (Sand Height Control valve set to shear at 2,200 psi). 8. RIH on DSL to determine the height of sand above the vent. 9. P/U a wash nozzle on CT and washout excess proppant above the vent. POOH. 10. RIH with the washing overshot w/indicator pins on DSL to verify the polished nipple is clear of debris. POOH and inspect indicator pins. If pins are not sheared, go to Step 11. If pins are sheared, go to step 12. 11. RIH w/the following on Coiled Tubing and wash out excess slurry and proppant located above and around the vent assembly using the washing overshot. 12. RIH on DSL w/ 2-1/2" JDC Pulling Tool. Latch Fishing Neck on removable vent plug located at the top of the vent screen assembly @ 17,546',jar up and release the vent plug from the vent screen BHA and POOH w/the same. 13. On DSL P/U and RIH w/the following vent screen isolation packer assembly: Note: Can be run on CT if desired OD ID Length Depth Bottom (Polished nipple) 7,548.63 A Latching Overshot w/Seals w/ 1 %2"NU 10 Rd Box 2.700 2.130 3.50 7,545.13 B 3-1/2" 9.3# Hang-off Crossover for Paragon II 2.725 1.625 0.33 7,544.80 Packers 1-1/2"NU LORD Pin C 3-1/2" 9.3#Paragon II Packer 2.725" O.D. x 1.625" 2.725 1.625 3.80 7,541.00 I.D. Seal Bore Above To Be Left in Well 7.63 D 3 %2" 9.3# E-Line Adapter Kit for TTS Paragon II 2.700 /////// 2.00 Packer E Wire-Line Setting Tool 1.690 /////// 6.00 Total BHA 15.63 14. Check PU, slack-off and neutral weight every 1,000'. Stab Latching Overshot over Polished Nipple. Pull 500— 1,000 lbs to check latch is set, then Set Packer at 7,541'. 15. POOH w/DSL. 16. Return well to production. Starting at low flow rate with gradual increases over time while monitoring. s KUP illfD 3M-11 CopocoPhiffips Well Attribu Max Angle .D TD Alaska,Inc :- '%. orWellbe API/UWI Field Name Wellbore Status ncl(1 MD(ftKB) Act Btm(ftKB) CxlocoDhillips 500292171800 KUPARUK RIVER UNIT PROD 46.10 2,400.00 7,959.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3M-11,11/29/2016 11:12:04 AM SSSV:NIPPLE 260 12/7/2005 Last WO: 6/2/1997 42.51 5/9/1987 Verbal actnmax(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,392.0 11/15/2011 Rev Reason:GLV C/O pproven 9/8/2016 ........ ................................ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len fl...Grade Top Thread HANGER,34.0 VACONDUCTOR 16 15.062 38.0 115.0 115.0 62.58 H-40 Illi'ii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)... VW/Len(I...Grade Top Thread SURFACE 95/8 8.835 37.0 3,871.7 3,331.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 30.2 7,898.7 6,387.9 26.00 J-55 BTC Tubing Strings Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(WD)(...Wt OM) Grade Top Connection • TUBING 'String 3 1/21 2.9921 34.01 7,563.5 6,133.31 9.301L-80 !Top ABM ..............................................., . Ma Completion Details �w ' Nominal ID Top(ftKB) Top(WD)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;38.0-115.0 " 34.0 34.0 0.15 HANGER FMC Gen IV,31/2"Tubing hanger,31/2"EUE land the 2.992 513.9 513.9 0.54 NIPPLE -CAMCO DS Nipple w/2.813 NO-GO profile,OD 4.54 2.813 7,497.3 6,082.9 40.44 NIPPLE 3.5"CAMCO W Nipple w/2.812 selective profile,OD 2.812 NIPPLE;513.9 4.54" 7,536.7 . 6,112.9' 40.46 PACKER 'Baker 3.5"x 7"SAB-3,perm.Pkr.,w/K22 Anchor seal 3.000 assembly GAS LIFT,2,0600 7,551.5 6,124.2 40.48 NIPPLE CAMCO 3.5"D Nipple w/2.75"NO-GO profile.OD 4.500" ' 2.750 7,562.6 6,132.6 40.49 SOS Baker 3.5"SOS Pinner for 3500 psi.OD 4.500",ID 2.937" ' 2.937 • 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) J Top(WD) Top Incl Top(ftKB) (ftKB) C.) Des Corn Run Date ID(in) 7,156.0 5,824.5 41.20 Fish 3 KOT ARM Springs Lost while Running GLV 6/25/1997 1.000 l 7,677.0 6,219.6 40.48 Fish CTU FISH COILED TUBING FISH LEFT IN HOLE 3/2/2006 1.000 SURFACE;37.0-3,871.7I Perforations&Slots Shot Dens GAS LIFT,4,630.3 Top(ftKB) B[m(ftKB) Top((ftKB)WD) (ftKB) Zone Date ft) Type Com 7,650.0 7,676.0 6,199.1 Btm(WD) (shots/ 6,218.8 C-4,A-1,3M- 9/5/1987 12.0 (PERF 5"HSC;120 deg. 11 phasing Mandrel Inserts GAS LIFT,5,756.8 St ati on Top(TVD) VaNe Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,960.9 2,652.3 Camco --KBUG - 1 GAS LIFT DMY BK 0.000 0.0 9/6/2016 GAS LIFT,0.5770 2 4,630.3 3,899.8 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/6/2016 3 5,756.8 4,764.4 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/6/2016 111 4 6,577.8 5,389.4 Camco KBUG 1 GAS LIFT DMY BK 0.000 0.0 9/6/2016 5 7,155.7' 5,824.3 Camco KBUG 1 GAS LIFT,7,155.7 6 7,451.7 6,048.3 Camco MMM i 1/2 GASGAS LIFTLIFT DMYDMY RKBK-5 0.000 0.0 7/7/2005 0.000 0.0 7/7/2005 Notes:General&Safety End Date Annotation 11/29/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT,7,451.8 I NIPPLE,7,497.3 1NS E .4_-E PACKER.7,536.7 II NIPPLE;7,551.5 tr 505;7,5626 ' IPERF;7,650.0-7,676.0 ] l PRODUCTION;30.2-7,898.7 1 l Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ' RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes No. Other, No/Type TOTAL PAGES: ~ ~ NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other IS~ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si SCANNED BY: BEVERLY BREN ~HERYL MARIA LOWELL RESCANNED BY: BEVERLY BREN VINCEN~-C::;HFRYfL'' [I~ARIA LOWELL DATE: General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 October 26, 2011 RECEIVED Commissioner Dan Seamount Alaska Oil and Gas Commission NO '0'2 2011 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 & Gas Cons. Commission p Commissioner Dan Seamount: 3 A I 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 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 corrosion inhibitor /sealant was pumped 10/18, 10/19 and, 10/21, 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 Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, � j r bt)(,)&41- Martin Walters 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 10/26/11 2L, 3K, 3M & 3Q 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 2L -301 50103205880000 2081920 10" N/A 10" N/A 1.7 10/18/2011 3K -20 50029230190000 2010880 SF N/A 14" N/A 1.7 10/19/2011 3K -24 50029229350000 1982490 SF N/A 24" N/A 3.5 10/19/2011 3M -01 50029216600000 1870120 SF N/A _ 12" N/A 5.95 10/21/2011 3M -03A 50029216960100 2081790 SF N/A 18" N/A 5.1 10/21/2011 3M -08 50029217090000 1870280 SF N/A 17" N/A 2.85 10/21/2011 3M -11 50029217180000 1870380 SF N/A 26" N/A 4.25 10/21/2011 3M -21 50029217390000 1870660 SF N/A 15" N/A 3.4 10/21/2011 3Q -03 50029222210000 1911260 SF N/A 18" _ N/A 3.45 10/19/2011 3Q -07 50029216820000 1861940 SF N/A 17" N/A 4.68 10/21/2011 3Q -08A 50029216810100 1971930 SF N/A 15" N/A 3.55 10/21/2011 3Q -09 50029216740000 1861860 SF N/A 13" N/A 4.4 10/21/2011 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pull tubing _ Alter casing _ Repair well _ Perforate _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1019' FNL, 1626' FEL, Sec.25, T13N, R8E, UM 5. Type of Well: Development __X Explorato~__ St ratig raph lc__ Service__ (asp's 506242, 6016482) 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3M-11 At top of productive interval 1423' FNL, 294' FEL, Sec.26, T13N, R8E, UM At effective depth At total depth 1461' FNL, 500' FEL, Sec.26, T13N, RSE, UM (asp's 502294, 6016074) (asp's 502088, 6016037) 9. Permit number / approval number 187-038 10. APl number 50-029-21718 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 3808' PROD CASING 7834' 7959 feet Plugs (measured) 6434 feet 7724 feet Junk (measured) 6255 feet Size Cemented 16" 206 SxCS II 9-5/8" 1200 Sx AS III & 350 G 7" 300 Sx G & 175 Sx AS I Tagged Fill (6/20/00) @ 7724' MD. Measured Depth 115' 3872' 7898' True verticalDepth 115' 3331' 6387' Perforation depth: measured 7650- 7676' true vertical 6199 - 6219' tubing (size, grade, and measured depth) 3.5", 9.3#, L-80, Tubing @ 7563' MD. RECEIVED MAR ? 2001 Oil & Gas Cons. Commission ~ackers & SSSV (type & measured depth) Baker 'SAB-3' Perm Packer w/K22 Anchor Seal Assembly @ 7537' MD. Camco 'DS' Nipple No-Go @ 514' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 439 Subsequent to operation 390 Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 300 239 345 330 Casing Pressure Tubing Pressure 183 185 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~ Title: Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3M-11 CEMENT OUTER ANNULUS DESCRIPTION OF WORK COMPLETED 6/7/00: MIRU. Ran 3/4" PVC pipe 70' down the 9-5/8 x 16" annulus, then pumped 12.4 bbls of 12 ppg Litecrete cement down the pipe into the annulus. RD. 6/20/00: RIH & tagged fill at 7724' MD. Returned the well to production w/gas lift & obtained a valid well test. MICROFILMED 9/28/00 DO NOT PLACE 'ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1019' FNL, 1626' FEL, Sec. 25, T13N, RSE, UM At top of productive interval 1423' FNL, 294' FEL, Sec. 26, T13N, RSE, UM At effective depth 1445' FNL, 405' FEL, Sec. 26, T13N, RSE, UM At total depth 1461' FNL, 500' FEL, Sec. 26, T13N, RSE, UM 12. 6. Datum elevation (DF or KB) RKB 64 7. Unit or Property name Kuparuk River Unit 8. Well number 3M-11 9. Permit number/approval number 87-38 10. APl number 5o-029-21718-00 11. Field/Pool Present well condition summary Total Depth: measured 7959 feet true vertical 6433 feet Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 7 81 2 fe et true vertical 6322 feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 8 31 ' 9 - 5 / 8" Intermediate Production 7891' 7" Liner Perforation depth: measured 7650'-7676' true vertical 6198'-6218' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 7563' Cemented Measured depth True vertical depth 206 Sx CS II 1 15' 1 1 5' 1200 Sx CS III & 3872' 333 1' 350 Sx Class G 300 Sx Class G & 7 8 9 9' 6 3 8 8' 175 Sx AS I Packers and SSSV (type and measured depth) Packer: Baker SAB-3 @ 7538'; SSSV: None, nipple @ 514' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sand on 6/22/97 ORIGINAL Intervals treated (measured) 7650'-7676' Treatment description including volumes used and final pressure Pumped 189.2 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 7777 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 185 219 168 1060 191 Subsequent to operation 931 765 300 1065 182 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /t/~~ '~-~£ ~'k"~cN. Title Wells Superintendent Form ~0-404 Rev Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. ' KUPARUK RIVER UNIT WELL SERVICE REPORT ~ K1 (3M-1 1 (W4-6)) WELL JOB SCOPE JOB NUMBER 3M-11 FRAC, FRAC SUPPORT 0620971809.4 DATE DALLY WORK UNIT NUMBER 06/22/97~ REFRAC "A" SANDS DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes' O No (~ Yes (~ No DS-GALLEGOS i~~ FIELD AFC.~ CC~ DAILY COST ACCUM COST ESTIMATE KDl126 230DS36ML $143,566 $143,566 Initial Tb.cl Press Final Tb.(:l Press Initial Inner Ann Final Inner Ann , Initial Outer An~ , Final Outer Ann 1335 PSI 7700 PSI 500 PSI 500 PSII 10 PSI 100 PSI DAILY SUMMARY "A" SAND RE FRAC COMPLETE. SCREENED OUT IN 10 PPA FLAT STAGE W/TOTAL OF 209,914 LBS OF PROP PUMPED (189,248 LBS IN FORMATION & 20,666 LBS IN WELLBORE): MAXIMUM PRESSURE 7777 PSI (FG=.81). TIME 08:30 13:45 15:15 17:00 19:30 LOG ENTRY MIRU DOWELL SCHLUMBERGER, APC & LRS. HOLD SAFETY MEETING & SAFETY ASSESSMENT TABLE TOP EXERCISE (16 ON LOCATION). PT BACKSIDE LINES TO 3500 PSI & RAISE ACCORDINGLY, SET TREESAVER & PT HIGH PRESSURE LINES TO 10,000 PSI. PUMP BREAKDOWN W/50# XL F/15 TO 25 BP,,; ?U.; 4nE~ TOT.'~.L OF 302 BBLS. MAXIMUM PRESSURE 6800 PSI W/ ENDING PRESSURE 3360 PSI. ISIP=2303 PSi it:" ~;~,.~; !). ~:,i..~ & MONITOR PRESSURES. PUMP DATAFRAC W/50# XL F/5 TO 15 BPM. PUMPED TOTAL OF 131 BBLS. MAXIMUM' PRESSURE 4350 PSI W/ ENDING PRESSURE 2280 PSI. ISIP=2280 PSI. SD & MONITOR PRESSURE FOR CLOSURE. ADJUSTED PAD TO 220 BBLS VERSUS DESIGN OF 75 (CLOSURE TIME ESTIMATED +/- 12 MINUTES). PUMP FRAC W/50# XL F/5 TO 15 BPM. SCREENED OUT IN 10 PPA FLAT STAGE (PUMPED 335 BBLS OF 436 BBLS IN THIS STAGE W/MAX PRESSURE OF 7777 PSI). DURING FRAC PUMPED TOTAL OF 1189 BBLS. PUMPED 209,914 LBS OF PROP (9402 LBS OF 20/40 & 200,512 LBS OF 12/18). INJECTED 189,248 LBS OF PROP IN FORMATION W/ 10 PPA OF 12/18 @ PERFS. LEFT 20,666 LBS OF PROP IN WELLBORE (TOP TO BOTTOM). BEGIN RD. DEPRESSURED IA TO 500 PSI & RD/RELEASE LRS. CONTINUE RD. REMOVED TREESAVER ',RETRIEVED +/- 85% OF CUPS). CONTINUE RD. COMPLETE W/DOWELL LEAVING LOCATION. NOTIFY NORDIC & DSO. RETURN TO OPERATIONS AWAITING CTU CLEAN OUT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $7,800.00 $7,800.00 DOWELL $133,016.00 $133,016.00 LITTLE RED $2,750.00 $2,750.00 .... TOTAL FIELD ESTIMATE $143,566.00 $143,566.00 , ARCO Alaska, Inc. Post Office Box 10036o Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3M-11 (Permit No. 87-38) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3M-11. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSUskad ORIGINAL ,"-" STATE OF ALASKA ~ ALAS~.,,. OIL AND GAS CONSERVATION L,,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service , 2. Name of Operator 7. ~er~it NUmber ARCO Alaska Inc. 87-38 3. Address 8. APl Number P. O. Bo.x. 100360,....A...n..chor.a. ge, .A.!aska 9.9.5!0 ......... ~ 50-029-21718 4. "t~ocati'on of well at surface "'"'"~'"'"-- 9. Unit or Lease Name 1019' FNL, 1626' FEL, Sec. 25, T13N, R8E, UM ~ Kuparuk River Unit At top of productive interval 10. - · · _...~L-~?-,I~ 1423' FNL, 294' FEL, Sec. 26, T13N, R8E, UM ~. ~ 3M-11 At total depth ~ i i. Field' a'r~'d Pool 1461' FNL, 500' FEL, Sec. 26, T13N, R8E, UM .......................................................................................................................................... Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 64'I ADL 25523, ALK 2559 12. Date Spudded i13. Date T.D. Reached ! 14. Date Comp., Susp., or Ab~nd.115. Water 5/3/87 I 5/7/87 I 6/3/97 I N/A MSLI Two I ........ I ...................... i .... 17. Total Depth (MD+TVD)! 18. Plug Back Depth (MD+TVD)I19. Directional SurveyOr20. Depth where SSSV set~21. Thickness of Permafrost · _ _7_959 _ __6~33 F'h1 7812 6322 FT~ I-lYes [~No I N/A MDl _ 1650'_(_Ap_p~0~)_- _ 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD CASING SE'FFiNS DEPTH HOLE .................... ...... _S_ ! _Z_ _E_ _ ..... _V~'___.__PER____FT._ .... GRAD~ _, T_OP __ B0'I-[_O__M __ SIZ__E _ ____OEMENTIN_G_ RE__C_ORD_ ............ AMOUNT__ PU.L:_LED 16" 62.5# H-40 Surf. 115' 24" 206 s× CS II 9.625" 36.0# J-55 Surf. 3872' 12.25" 1200 sx AS III 8, 350 sx Class G 24; PerforatiOns open to ProdUCtion (MD+TVD of Top and Bottom 25. TURING RECORD and interval, size and number) ........... -S-izE DEPTH SET (MO) PACKER SET (MD) 3.5" 7563' 7537' MD TVD MD TVD 7650'-7676' 6198'-6218' - ................................................. 12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Dat~ FirSt prOductiOn ~Meth°d"~Jf (~'erati0n' (Flowing, gas lift, etcl) i Date of Test iHours Tested PRODUCTION FOR 1OIL-BBL GAS-MCF WATER-BEE CHOKE SIZE t GAS-OIL RATIO .~! TEST PERIOD ° / FiE-~--Tubin-~iCasing Pressure OALCULATED· (~i~.:~-L .......... ~:M~ ............ ~WATER-B~L .... Oi~GR~-~IT~;2-AP¢(CORR) P.r. ess.: .i .... _~4-HouR R.A..T.E ..... 28. COBE DATA ...................... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Mar?~"''~''- ~'-', Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Annulus left open - Freeze protected with diesel. :3iJ l..iSt Of Attachments .................... Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 1.~-L-/~. ~l,~,., . Title ~'~,T~.u,.'c,,~ [::,,,~,.'r..,.,~t~ Date Prepared By Name/Number: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 7/8/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3M-11 RIG:NORDIC WELL ID: 998786 TYPE: AFC:--998786 AFC EST/UL:$ 365M/ 456M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD: START COMP:05/29/97 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21718-00 05/29/97 (C1) TD: 7969' PB: 7813' SUPV:RLM DAILY:$ RIG UP HARD LINE Move rig from 2F pad to 3M pad. 45,452 CUM:$ 45,452 ETD:$ MW: 0.0 0 EFC:$ 410,452 05/30/97 (C2) TD: 7969' PB: 7813' SUPV: RLM DAILY: $ CIRCULATE AND INCREASE WT MW:10.9 BRINE Accept rig at 0430 hrs. 5/30/97. Prepare to kill well. Circ. well with sea water. Test BOPE to 300/3000 psi. 34,415 CUM:$ 79,867 ETD:$ 0 EFC:$ 444,867 05/31/97 (C3) TD: 7969' PB: 7813' SUPV:RLM DAILY:$ RIH WITH FISHING TOOLS MW: 0.0 CBU mud cut 10.9/10.3 prior to bottoms up. Weight up to 11.0 ppg. Monitor well, dead and static. POOH laying down tubing. Well started taking 4 bbls fluid/hr. Reduce brine weight 10.9 ppg. Loss slowed. POOH laying down tubing. 39,077 CUM:$ 118,944 ETD:$ 0 EFC:$ 483,944 06/01/97 (C4) TD: 7969' PB: 7813' S UP V: RLM DAILY: $ CHANGE OUT 7" PACKOFF MW:10.9 RIH with fishing tools. Held safety meeting. Engaged fish at 7524' original RKB. Pulled packer free. Attempt to circ down drill pipe, fluid flow kept energizing packer rubbers. Work packer and wear down rubbers. Circulate hole clean. POOH with fish. Wash and ream from 7658' to PBTD at 7813' 35,515 CUM:$ 154,459 ETD:$ 0 EFC:$ 519,459 06/02/97 (C5) TD: 7969' PB: 7813' S UP V: RLM DAILY:$ RUN 3.5" COMPLETION MW:10.9 Circulate hole clean above perfs at 7650' Set storm packer. Test packoff and seals, slow leak. Test packoff and seals to 3000 psi. Set test plug. Release, pull storm packer. CBU. No gas or oil cut mud. POOH laying down 3.5" drill pipe. 156,917 CUM:$ 311,376 ETD:$ 0 EFC:$ 676,376 06/03/97 (C6) TD: 7969' PB: 7813' SUPV: RLM DAILY:$ End of WellSummary for We11:998786 RUN 3.5" COMPLETION MW: 0.0 Run 3.5" completion, tubing tail at 7563' . Land hanger. Set packer. ND BOPE and NU tree. Test tree to 250/5000, OK. Freeze protect tubing and annulus. Secure well. Rig released at 0000 hrs. 6/3/97. 32,715 CUM:$ 344,091 ETD'$ 0 1. Status of Well Classification of Service Well OILily] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .... 2. Name of OPerator 7. Permit Number ARCO Alaska, Inc. 87-38 ,,, 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21718 4. Location of well at surface 9. Unit or Lease Name 1019' FNL, 1626' FEL, Sec.25, T13N, R8E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1423' FNL, 294' FEL, Sec.26, T13N, RSE, UM 3M-11 At Total Depth 11. Field and Pool 1461' FNL, 500' FEL, Sec.26, T13N, R8E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool RKB 64'I ADL 25523 ALK 2559 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 05/03/87 05/07/87 11/16/87'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7959'MD, 6433'TVD 7812'MD, 6322'TVD YES ~. NO [] 1825' feet MDI 1600' (approx) 22. Type Electric or Other LOgs Run DIL/SP/GR/SFL, FDC/CNL, Cal, CBL/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" 206 sx CS II 9-5/8" 36.0# J-55 Surf 3872' 12-1/4" 1200 sx AS III & 350 s~ Class G 7" 26.0# J-55 Surf 7899' 8-1/2" 300 sx Class G & 175 sx AS I ,, 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf, 120° phasing 2-7/8" 7587' 7556' 7650'-7676'MD 6198"6218'TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addendum~ dated 11/18/87~ for fracture data. 27. N/A PRODUCTION TEST , Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~.I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA ,, , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .on Alasl~ Oil & Gas Cons. Commi~lott Anchorage *Note: Drilled RE 5/9/87. Perforated well & ran tubing 9/6/87. Fractured well 11/16/87. t~-''' STATE OF ALASKA '"-"~ ~ ALASK,o, OIL AND GAS CONSERVATION C;OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Form 10-407 WC~-/11 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS . FORMATION TESTS ,. ,, NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7639' 6190' N/A Base Kuparuk C 7654' 6201' Top Kuparuk A 7654' 6201 ' Base Kuparuk A 7712' 6246' .. 31. LIST OF ATTACHMENTS Addendum (dated 11/18/87) , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ~/,N~)~ ~, Title Associate Engineer Date /2~-~7 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 ADDENDUM WELL: 6123/87 8/02/87 11/16/87 3M-11 Arctic Pak w/175 sx AS I and 54 bbls Arctic Pak. Rn gyro to 7800'. Rn CBL/CCL f/7810'-5200'. Frac Kuparuk A & C sand perfs 7650'-7676' in nine stages per procedure dated 10/21/87 as follows: Stage 1: Pad "A:, 100 bbls gelled diesel @ 10-20 BPM, 5100-4430 psi Stage 2: Pad "B", 400 bbls gelled diesel @ 20 BPM, 4450-4320 psi Stage 3: 40 bbls 2 ppg gelled diesel @ 20 BPM, 4330- 4350 psi Stage 4: 40 bbls 4 ppg gelled diesel @ 20 BPM, 4400- 4450 psi Stage 5: 50 bbls 6 ppg gelled diesel @ 20 BPM, 4500- 4520 psi Stage 6: 50 bbls 7 ppg gelled diesel @ 20 BPM, 4680- 4700 psi Stage 7: 50 bbls 8 ppg gelled diesel @ 20 BPM, 4800- 4930 psi Stage 8: 40 bbls 9 ppg gelled diesel @ 20 BPM, 4950- 5000 psi Stage 9: 30 bbls 10 ppg gelled diesel @ 20 BPM, 5193- 4550 psi Fluid to Recover: Sand in Zone: Sand in Csg: Ave Press: 765 bbls 60,200(/ (computer) 325(! 4694 ps i Dri~g 'Superv~ ' Dat~ ' August 10, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70055 Well: 3M-11 Field: Kuparuk Survey Date: August 2, 19871 Operator: T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss GyroScopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosure NI. Sperry-Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 .......................... ~.]:~-.2_0 ............................ 3 ::2.':2.~.?.'? ...................... 2~i-~.~S.?':~ :':: ::: '-:' --':' · _ (.) (.) 4 '=/.. '=,'.., '-. '-'_ 4.=,"" ....~ =:' , c:,.. 8 .... ,=, ._,, ._-, ::/ E --,.'=:, ,:,':' · '::;':~) -.~. '? :.".-3 .~-q 9 ,=; ,? 8 27 · ,500 .... 'i" . ......... 0 N '7,{:,. ,50 E E --4 ................. :::: ............. (") ~') "7'!?'?., ? 7 '7:2','.::; · o'..:. ,Z ................................... ,") 15 ........... 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DATE O~:~~~Y. :':AUGU~S~..2,'::. 1987 '..... ~"*~: ~~" ~ --~', ~'~.~E:.~ ~". ~:.: ........ ~ ":":'":::??.~' ':'~ "· .... " 12:121N P I_1T A T I EIN JlA T E ;:-:~':":' .... "'~': : · .'~. ' '. ' .... ~LIGLIS;T & 1987 ,JOB__ N ' ' ................................................................... KELL~ ._RI I~H ~NG_~ .... ~.~. ......... ~.A-~._E_~ ................................................................................................................ .................................................................................... SPE'RFIy -SUN SCALE :- I INCH TO 500.00 / 500.0 KUPflRUK FIELD ARCO ALASKA, INC, 3M-11 lSEC25 '[13N RO8E) AUGUST 2, 1987 AK-BO-70055 HOB '[ Z ONT aL PBOJF' C T '[ ON ~~0.00 TRUE NORTH '0.00 -500.00 0.00 1500.00 3000.00 ~500.00 7500.00 SPERRT -SUN 5CRLE :- 1 INCH TO 15'00.00 / 1500.0 KUPARUK FIELD 3H-II(SEC25 Ti3N- ROSE) AK-BO-70055 6433.00 flBCO RLRSKR, INC. AUGUST 2. i987 -7959 I i500. GO 3000.00 4500.00 VER T i CF:IL PROJE C T '[ ON ARCO Alaska, Inc. Post Oflice B,..... 1.00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: October 28, 1987 Transmittal #: 6098 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~' 2X-16 ~3M-lO - 3M-11 -- lQ-12 --- 3C-1 ~ 3F-5 -'-3F-5 ~. 3C-15 ~ 3C-16 - 3C-14 ~- 3C-14 Kuparuk Well Pressure Report(Otis) 10-3-87 PBU 'A' Sand Kuparuk Well Pressure Report(Otis) 10-2-87 Static 'A' Sand Kuparuk Well Pressure Report(Otis) 10-3-87 Static 'A' Sand Kuparuk Operations Engineering Pressure Falloff Analysisl 3-15-87''A' Kuparuk Well Pressure Report(Otis) 8-15/18-87 PBU 'A' Sand Bottom-Hole Pressure Survey 'C' Dual-Zone PBU 10-13-87 50-029-21460 Bottom-Hole Pressure Survey 'A' Dual-Zone PBU 10-13-87 50-029-21460 Kuparuk Well Pressure Report(Otis) 8-28-87 Static 'C' Sand Kupaurk Well Pressure Report(Otis) 8-30-87 Static 'C' Sand Kuparuk Well Pressure Report(Otis) 8-19-87 Static 'C' Sand Kuparuk Well Pressure Report(Otis) 8-16/19-87 PBU 'A' Sand /'~ / Naska 0, ~, uss (;ohs. Commissi01i Anchorage Receipt Acknowledged: · DISTRIBUTION: Date: D&M BPAE Unocal Chevron Mobil SAPC ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany : ARCO Alaska, In Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 10, 1987 Transmittal #6051 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-15 Cement Bond Log 8-3-87 5381-7397 3M-17 Cement Bond Log 8-5-87 6200-8564 3M-19 Cement Bond Log 8-10-87 6500-8794 3M-22 Cement Bond Log 8-12-87 7890-9598 3M-18 Cement.Bond Log 8-21-87 7689-8410 3M-14 Cement Bond Log 8-2-87 4903-7108 3M-13 Cement Bond Log 8-3-87 7495-9559 3M-20 Cement Bond Log 9-1-87 8700-10687 3M-11 Cement Bond Log 8-1-87 5252-7802 3M-16 Cement Bond Log 8-4-87 -7834 3M-lO Cement Bond Log 8-9-87 4700-7039 3M-12 Cement Bond Log(Coiled Tubing Conveyed) 8-12, 13-87 7403-10380 Receipt Acknowledged: DISTRIBUTION: NSK State of Alaska(+sepia) . Vault(film) ARCO Alaska. Inc, Is a Subsidiary of AllanllcRIchfieldCompany STATE OF ALASKA ~-'~' AL~'. (A OIL AND GAS CONSERVATION CO~' ',ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate~ Pull tubing E~ Alter Casing [] Other ~ COHPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 64' Feet 3. Address 6. Unit or Property_ name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk i~iver Unit 4. Location of well at surface 1019' FNL, 1626' FEL, Sec.25, T13N, R8E, UM At top of productive interval 142:3' FNL, 294' FEL, Sec.26, T13N, R8E, UM At effective depth 1445' FNL, 405' FEL, Sec.26, T13N, RSE, UM At total depth 1461' FNL~, 500' FEL~ Sec.26~ T13N~ R8E~ UM 11. Present well condition summary Total depth: measured 7959 'MD true vertical 6433'TVD Effective depth: measured 7812 'MD true vertical 6322 'TVD 7. Well number 3M-11 8. Approval number 7-362 9. APl number 50-- 029-21718 10. Pool Kuparuk River Oil Pool feet Plugs (measured) None feet feet Junk (measured) None feet Casing Length Size Conductor 80' 16" Surface 3835' 9-5/8" Production 7868' 7" Cemented Measured depth 206 sx CS II 115'MD 1200 sx AS III & 3872'MD 350 sx Class G 300 sx Class G & 7899'MD 175 sx AS I ~ue Vertical depth 115'TVD 3331'TVD 6387'TVD Perforation depth: measured true vertical 7650'-7676'MD 6198 ' -6218 ' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tubing w/tail @ 7587' Packers and SSSV (type and measured depth) HRP-1-SP pkr ~ 7556' & TRDP-1A-SSA SSSV @ 1825' RECEIVED 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure SEp 2 2 1 87 &las~ Oil & Gas Cons. Commisslor~ Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations X~ Copies of Logs and Surveys Run)(3 Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~t/~)~'lj~L/~.b~ ~. Title Associate Engineer Form 10-404 Rev. 12-1-85~ (Dani) SW02/84 Date ~/-1~-~7 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. IAccounting coat center cede Stale Alaska District County or Parish Alaska North Slope Borough me~d Kuparuk River tease or U.~, ADL 25523 Auth. or W.O. no. I T t e AFE AK2114 I Completion Nordic #1 API 50-029-21718 Operator A.R.Co. ARCO Alaska, Inc. w~6.24% Spudded or W.O. begun Date Complete 9/5/87 Date and depth Complete record for each day reported as of 8:00 a.m. 9/08~87 Old TD New TD Released rig Date 0700 hrs. Classifications (ail, gas, etc.) 011 otal number of wells (active or inactive) on this cst center prior to plugging and ~ bandonment of this well J0830 hrs.,HOur IPri°r s'"tus'' a w'°' 7" @ 7899' 7812' PBTD, RR 7.0 ppg diesel Accept ri~ @ 0830 hrs, 9/5/87. ND tree, NU &tst BOPE. Perf well 7650'-7676' @ 12 SPF. Make GR/JB rn to 7700'. RU & rn 229 its, 2-7/8", 6.5#, J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1825', HRP-1-SP pkr @ 7556', TT @ 7587'. Set pkr. ND BOPE. NU &tst tree to 250/5000 psi. Displ well to diesel. RR @ 0700 hrs, 9/6/87. RECEIVED SiP Alaska 0il & Gas Cons. Commissl0~ Anchorage J PB Depth 7812' PBTD Kind of rig 9/6/87 Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected lhe/~i , ....... I~ate ITM Sig~_~ ~ ~'~ (~--~ (~O yJ) Drilling Superintendent Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Page no 1 Dlvlllon of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 29, 1987 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 3M Pad (Wells 1-22) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/pk GRU1/31 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfie!dCompany 24 ,..,... L VICIN:TY S~.-ALE I · Z NOTES: I. ALL COORDINATES ARE A.S.P. , ZONE 4. Z.ALL DISTANCES SHOWN ARE TRUE. ALL WELLS LOCATED IN SEC. 2§, TI:SN, R8E, UMIAT MERIDIAN. ASPs 'X' LATITUDE $.ELEVATIONS ARE B.P.M.$.L. 4.REF. FIELD BOOK LS7-$, PgL 7. I~.; LST-I, P. 7; L87-$,P$1 - SS; $.0.G.ELEVATION$ FROM F... BILL · ~CIATES. ~U~NTS ~R LHD B A~IATES. 6,202.17 506,t26.t! 6~)16,225.10 506,156.45 $~)16,248.;I 506,145.~J8 6,016,271 . ~4 6,016 ,294. 28 506,'65.07 6,016,$17.42 506,174.65 6,016,$40.48 6,016,$65-49 506,195.52 6 ,016 ,$ 86 -92 506,20:5-14 6,016,456-13 506,252-02 6,016,479.22 506,241.52 6,016,502.26 506,251.07 70°21 6,016,525.51 506,260.73 70°2./ 016,~48.$Z 506,270.:50 70°27',{~'1~ 016,571.43 5~,E-79.77 70027 23.410 .016,594.7~ 5~289.40 7~7'Z~.639 ,016,61T~9 ~06,~99.05 70°~7'2~.868 6,016~1.02 5~S08.76 7~Z~'24.094 4~56'54.647 5~ 317.~Z ~PaZ7 ~, ~1~", /~'~ 70'27' 2~.~7 1019 996 ,~,72 ~,.4: m6.4: ~5o ,598' m, ,' m6 4' ~04 1578', ~0.9, 881 1569 EO.9 858' 1559' ~0.8' ~/b ,~b~.B~ A/Z' I~. ~.~' ~Dlb, 1~.77 ~o~,/~7.~ 7~7' 1~'~3' =/~e;;7'DP.~t I HE~Y CERTIFY T~TI ~M PROPERLY TICE L~D ~RVEYING IN ~E ~. - ~ ....... ~, s~;,v,s~. *"u ;,~ ~ ~/49th ...~ ~,.~s,o.s ..~ o~, ~,.,~s ~. ~"'~~ ~ CRAIG L. :~ ARCO Alaska, Inc. Post Office-,'~x 100360 Anchorag~ aska 99510-0360 Telephone 907 276 1215 Date: May 29, 1987 Transmittal #: 5985 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-11 OH LIS Tape 5-8-87 72309 Receip't Acknowledged: DISTRIBUTION: Date: State M. Stanford ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, inc. Post Office,~x 100360 Anchorage .ska 99510-0360 Telephone 907 276 1215 Date: May 26, 1987 Transmittal # 5980 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted'herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-11 Cyberlook 5-8-87 7400-7925 3M-11 ~2" Raw FDC 5-8-87 3872-7925 3M-11 ~2" DIL 5-8-87 3872-7950 3M-11 ~'°5" DIL 5-8-87 3872-7950 3M-11 ~5" FDC 5-8-87 3872-7925 3M-11 ~2" FDC 5-8-87 3872-7925 3M-11 x"~5" Raw FDC 5-8-87 3872-7925 Conll~,ission Anchorage Receipt Acknowledged: DISTRIBUTION: Date: NSK Drilling .- State(+ sepia) Vault (film) Rathmell D&M L. Johnston(vendor pkg) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS...-~ OIL AND GAS CONSERVATION COM~,,,$SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [~ Re-enter suspended well ~ Alter casing Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order ~ Perforate ~ Other 2. N~3~,,e,,of. Oper.ator 5. Datum elevation (DF or KB) ~u ^/asKa, Inc RKB 64' 3. A~[d. re~s. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1019' FNL, 1626' FEL, Sec.25, T13N, R8E, UM At top of productive interval 1312' FNL, 193' FEL, Sec.26, T13N, RSE, UM (approx.) At effective depth 1346' FNL, 372' FEL, Sec.26, T13N, RSE, UH (approx.) At total depth 1361' FNL, 486' FEL, Sec.26, T13N, R8E, UM (approx.) 11. Present well condition summary Total depth: measured 7959 ' MD feet true vertical 6454 ' TVD feet 6. Unit or P,rqperty name Kuparuk ~ver Unit 7. Well number 3M-11 8. Permit number 87-38 9. APl number 50029-21 71 8 10. Pool Ku~aruk River Oil Pool Plugs (measured) None Effective depth: measured 781 2 'MD feet true vertical 6341 ' TVD feet Junk (measured) None Casing Length Size Conductor 80 ' 1 6" Surface 3835 ' 9-5/8" Producti on 7868 ' 7" Cemented 206 sx CS II 1200 sx AS II I 350 sx Class G 300 sx Class 6 Measured depth 115'MD 3872'MD ~ue Verticaldepth 115'TVD 3343'TVD 7899'MD 6408'TVD Perforation depth: measured None true vertical N o n e Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation July, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~..~. ,~,. ~L/j~Ot_., TitleASsoci ate Engineer Commission Use Only (Dani) SA2/58 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by Date by order of Commissioner the commission Date .~""-,~~ I ~i>-~i'~/ Submit in triplicate feet ~" Form 10-403 Rev 124-85 ARCO, Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, parish or b gh .... IState Alaska Alaska North Slope Borough Field , ILease or Unit IWell no. Kuparuk River ADL 25523 3M-11 Auth. or W,O. no. ~Title AFE AK2114 I Drill Doyon #9 API 50-029-21718 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDate IHour Pr or status if a W.O. Spudded ] 5/3/87 ] 1030 hrs. ProJ Complete record for each day reported 16" @ 115' 2225', (2110'), Drlg Wt. 9.0, PV 12, YP 15, PH 8.5, WL 11.2, Sol 5 Accept rig @ 0600 hrs, 5/3/87. NU diverter sys. Spud well @ 1030 hfs, 5/3/87. Drl to 2225'. 1221', 5.4°, S87.5W, 1220.80 TVD, 8.66 VS, .38S, 8.66W 1791', 26.4°, N83.9W, 1766.98 TVD, 159.55 VS, 17.75W, 161.37W 5/04/87 16" @ 115' 3890', (1665'), Rn'g 9-5/8" csg Wt. 9.2, PV 14, YP 13, PH 8.5, WL 8.4, Sol 6 Drl to 3890', short trip, CBU. RU & begin rn'g 9-5/8" csg. 2395', 46.0°, S89.2W, 2246.94 TVD, 519.27 VS, 16.99N, -522.33W 3199', 42.8°, S89.3W, 2838.28 TVD, 1062.57 VS, 6.25N, 1066.54W 3805', 41.5°, S87.5W, 3293.48 TVD, 1462.53 VS, 6.92S, 1466.27W 9-5/8" @ 3872' 4850', (960'), Drlg Wt. 8.8, PV 2, YP 2, PH 9.5, WL 12.8, Sol 4 Ran and cmt'd 9-5/8" csg FC @ 3790', FS @ 3872' wellhead. NU & test BOP's. Drld float equip. ppg EMW. Drld to 4850. Date and depth as of 8:00 a.m. 5/05/87 5/06/87 5/07/87 5/08/87 acted · Install Run LOT 12.5 9-5/8" @ 3872' 7237', (2387'), Drlg Wt. 9.4, PV 5, YP 3, PH 9.5, WL 8.4, Sol 8 Drl & surv to 7237'. 5029', 39.4°, SSO.0W, 4222.64 TVD, 2258.29 VS, 83.99S, 2258.45W 5878', 39.9°, S83.4W, 4874.50 TVD, 2801.28 VS, 155.15S, 2797.59W 6753', 40.9°, S82.1W, 5538.98 TVD, 3369.65 VS, 230.20S, 3361.89W 9-5/8" @ 3872' 7959', (722'), RU Schl Wt. 10.1, PV 18, YP 12, PH 9.5, WL 4.6, Sol 11 Drl & surv to 7959', short trip, C&C, spot diesel pill, POOH. RU Schl to , S81.3W, 5896.23 TVD, 3678.93VS, 274.95S, 3668.64W , S81.0W, 6373.49 TVD, 4086.28VS, 331.31S, 4072.87W , 581.0W, 6453.80 TVD, 4153.69VS, 341.89S, 4139.69W log. 7226', 41° 7854', 40.1° 7959', 40.1° The above is correct Signatur For P p~ . v .s~t ibution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska ]~ Field Lease or Unit Kuparuk River Auth. or W.O. no. ITitle I AFE AK2114 Operator ARCO Alaska, Inc. Doyon 9 A.R.Co. W.I. Spudded or W.O. begun Date Spudded Date and depth Complete record for each day reported as of 8:00 a.m. 5/09/87 thru 5/10/87 North Slope Borough Accounting cost center code State Alaska ADL 25523 Well no. 3M-T1 Drill API 50-029-21718 rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56.24% labandonment of this well I IHour IPrior status If a W,O, 5/3/87 ! 1030 hrs. I 7" @ 789~' 7959' TD, (7812'), RR 10.0 ppg NaCl/NaBr Log DIL/GR/SP/SFL f/7959' to 3872'; cont w/GR to 1000'. Rn FDC/CNL f/7959'-7400', CAL f/7959'-6400', RD Schl. TIH, rm 6 jts to btm, C&C, spot 50 bbl diesel pill, POH, LD DP. RU & rn 184 its, 7", 26#, J-55 BTC csg FC @ 7813', FS @ 7899'. Cmt w/100 sx 50/50 Pozz w/4% D-20, .5% D-65 & .2% D-46, followed by 200 sx C1 "G" w/3% KC1, .3% D-13, .9% D-127 & .2% D-46. Displ w/299 bbls brine, bump plug to 3500 psi; flt did not hold. Reseat plug. WOC. ND BOPE, tnstl pack-off. NU tbg spool, att to tst packoff; failed. ND tbg spool, replace packoff. NU tbg spool & tst packoff to 3000 psi. RR @ 2400 hfs, 5/9/87. 7959' TD 7812' PBTD Released rig I Date IKind of rig 2400 hrs. 5/9/87 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Flowing Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct S " r' .,.X_ _/..____.__/ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Supervisor April 29, 1987 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, 'AlaSka 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3M-11 ARCO Alaska, Inc. Permit No. 87-38 Rev. Sur. Loc. 1019'FNL, 1626'FEL, Sec. 25, T13N, RSE, b~. Btmhole Loc. 1332'FNL, 449'FEL, Sec. 26, T13N, R8E, UM. Dear Mr. Kewin: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated April 13, 1987, accompanying the original approved permit are in effect for this revision. Ve ~r~y~ trB1y~y~u~, Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery K['-'O STATE OF ALASKA '~' ALAS IL AND GAS CONSERVATION ,_ ~,MMISSION ' PERMIT TO DRILL 2O AAC 25.005 la. Type of workRe. EntryDrill*~ DeepenRedrill ~I lb. Type of welI. Exploratory []Developement StratigraphicTest E3 DevelopmentOil/~ Service [] Gas [] Single Zone /~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64', PAD 27' feet Kuparuk River Field Kuparuk River Oil Pool 3 Address 6. Prop. ertv Desionation P.'O.-Box 100360 Anchorage, AK 99510-0360 ADL 255'23 /~LK 2559 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 1019'FNL, 1626'FEL, Sec.25, T13N, R8E, UN Kuparuk River Unit Statewide 131~t~ ,o f Plr~jd3u,cFt iEv~,i n tbeer~a 8. Well number, Number 126, T13N, RSE, UM 3M-11 #8088-26-27 · At total depth 9. Approximate spud date Amount 1332'FNL, 449'FEL, Sec.26, T13N, RSE, UM 05/03/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3M- 1 0 7953 ' MD 1019'@ Surface feet 23' ~ 1320'TVD feet 2560 (6452'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth1 1 00 feet Maximum hole angle 42 0 Maximum surface 1 988 psig At total depth (TVD) 3 086 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4" 9-5/8" 36.0# J-55 BTC 3777' 35' 35' 3812' 3358' 1200 sx AS Ill & HF-ERW 300 sx Class G blend 8-1/2" 7" 26.0# J-55 BTC 7919' 34' 34' 7953' 6452' 200 sx Class G(minimum HF-ERW TOC 5(~0' abov; top of Ku..p.a,.~ru~k 19. To be completed for Redrill, Re-entry, and DeePen Operations. i~:~ ~':~; ~ .... ii ':',~; ~ Present well condition summary Total depth: measured feet Plugs (measured) true vertical feetAPR 2:4 Effective depth: measured feet Junk (measured) true vertical feet j~,t3S~(~ Oil & GaS C0~S." ..... Casing Length Size Cemented Measured depth True Vertical depth Conductor Intermediate -rb ~LCr~b/..,]~ ~-~--"z_ ~T o~/=~- Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch)~ Diverter Sketch'"~ Drilling program program~' Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements Drilling fluid b(y.. that the foregoing is true and correct to the best of my knowledge 21. I here certify Signed --~'~~ Title Regional Dri 11 ing Engineer Date Commission Use Only (HRE) PD2/19 I API number I Appr(~a) ¢_~t~ I See cover letter Permit Number ,-'~7-~i'~ 50-- o~...c~ .... ~-( -~: ~ 87 for other requirements Conditions of approval Samples required [] Yes I~ No Mud log required L-] Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required .)ii( Yes [] No R equiredwor~~us~f B~~ E~ 5M; [] 10M;[]'15M ~/~ Other: by order of Approved by ~ ~ .,./ .,~._ ../~~~2~ Commissioner the commission Date -. · · i, Form 10-401 Rev. 12-1-85 ~ Subn :ate ! ALASKA,. ~NC.' ................. ~:: ............................................ :' .................... ~' ..................... ' ' I'IEL L ' I 1 R.EV_- I SED p ', ' ' _SJ.~_ OPE, i AL :^ t .[ .... 58: T DEP- t L f- - . ± . " : TYD"48! 13': TYD. 618I. TV-D-6246- "HD-?6T? THD*-??53 TVD"645: TPID+T953 · DEP--3982 DEP=4115 . , . · ' r ''~,J i ' ' ; F : i ~ i i ', ~ ,i, i i i ; i i ' . , - , · , r I , ; .....'.~ __ t ', t t ' ~ ' ' ' ~ ; ~ ' I i sooo ~o0o'. ', ,' ~, ', ~o~0;~ ~o0o:' ' : ~0~:~, ' ~ ~ .... 3: ~:: ~ ~ ~ ' ~ ~00~, ......... . ......... ; ~ ~ . . , , , ,' '., , ~ ~ ~ , : . , . ........ r . j ............. ~ .......... ., : .... J J , ...... : .... , . ' i ~ ' ' * T ' ' .......... ' 1 ..... ; ; ..... t ' ~ ~ ' ~ ' , , t . ~ ~ , ~ , , , , ' , '. ' ' : · · , : , ~ · · j i J ~ ~ ~- t ~ , r~ ' ~ ~ j ~ ' ! ' ' ~ ', ~ ' ~ ' ' ' ' a ' ~ : '' ~ ~ I ' ' ' ' · ~r~3~] ...... ' ', i ; , ~ ~ , , , · ............ I ~ ~ , , , i , ; . ...... ~ - · : t , ' ~ r ' ~' ~ ' ' ~ [ ~ ....... ~ ' ~ ' ~ i ' ' ' ~ ........ ~ ' ' ' ' Ti~T L~I~ ~r~r ~,~ ' ' ~ ' r : ' , ~ , , . : ..... - ....... I . . ~. .... : · ~. ~ , ~ J ~ ?~ -~ .................. ~.-~ ~ ?-~-~ ................ · , ~ . , . - , · ~ , , · , t . ~ .... . ~ , . , t ~ · ' .... , · , .... ; , ..... .............. ~ .... t: .... ~.~ ::;: ..:,~: :i:,. .., . ............ ..... ''''~ ' . ..... L,_~ .......... .... ~ ......... , , . , , ,...... j ~ , ..... , ~ ~ .......... · , · . · · ......... ~ ' ' ' t ........ ' ' ' t FION' OH r, :'L 11150 ~oo .......... .,~ ~ .: -- ........ ~.:.'-------'~; .. :~sSo , ~soo ~ r . 1550. ,i ' KUPARUK RIVER UNIT 20" D IVERTER SCHEMATIC I DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH l'~O 2-1/16" 2000 PS! BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/lO" OUTLETS 5, 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER, VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTI~NANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY, 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 11-3-86 ii ! L_ DIAGRAM #1 13-5/8" 5000 PSI RSRRA BOP STACK I. 16" - 2000 PSI TAN<CO STARTING FEAD 2. !1" - ~X)0 PSI CASING lEAD 3. Ii" - ~ PSI X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE ~ 5. 13-5/8' - 5000 PS! DR!LLING SPO0_ W/CHO<E At~D K!LL LIhF_S 6. 13-5/8" - 5000 PSI DOUIN_E RAM W/PIPE ~ ON TOP, 7. 15-5/8' - 5000 PSI ~ A¢CUMULAT~ CAPACITY TEST I. CH~CI< AbD FILL ACCt~TDR R~OIR TO PR~ LEVEl. WI~ ~IC ~UID. 2. ~ ~T A~T~ ~ IS ~ ~I WI~ 3. ~ TI~, ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T, ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ F I 2 13-5/8" BOP STAQ< TEST FILL BOP STACK AbD C~ MAI~F~ WITH ARCTIC DIESEL. CH~O( THAT ALL LOCK D(]NN SCR~ IN V~9_LI-EAD ARE F1JLLY RETRAC~. SF. AT TEST PLUG IN V~ WITH RUNNING JT ~ RUN IN L~ SC~E]~. LI~E VALVES ADJA(]SNT TO BOP STACK. ALL OTFER VALVES AN) ~ SHClJLD BE OPEN. 4. PRESSURE UP TO 250 PSI ~ HOLD FC~ I0 MIN. IN- CREASE PRESSURE TO 5000 PSI ~ H~LD FDR I0 MIN. BL~-n PRESSURE TO 0 PSI. LI~E VALVES. CLO~ TOP PIPE RAMS AN) H(~ VALVES ON KILL AI~ Q-tCKE LI~ES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. ?. cc~rII~JE TESTING ALL VALVES, LIKES, ~ Q-E3<ES WITH A 250 PSI LOW A~ 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PI~~ TEST ANY ~ NOT A FULL CLOSING POSITIVE SEAL Q-E3<E. 'C~Y~S THAT FUD~ION TEST CHOKES THAT DO NOT FULLY CLC~. 8. OPEN TOP PIPE RAMS ~ CLC~ BOTTCI~ PIPE RAMS. TEST BOTTCIti PIPE RAMS TO 2,~ PSI AI~ 3000 PSI. 9. OPEN BOTT(3a PIPE RAMS, BACK OUT Rt.~IqING JT ~ I0. CLOSE BLIFI) RAMS ~ TEST TO 2.50 PSI AhD 3000 PSI. Ii. OPEN BLII~D RAMS AhD RETRIEVE TEST PLUG. MAKE SURE MANIFCE.D ~ LIhES ARE FULL OF NC~I-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAI~PIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AhD INSIDE BOP TO 250 PSI AhD 13. RECORD TEST IhFOR~TICN ON BL(]N(~ PREVENTER TEST FC~o SIGNo AhD SEN) TO DRILLING SUPERVISOR. 14. PERFC~ COv~ETE BOPE TEST AFTER NIPPLING UP AhI) WEEKLY THEREAFTER ~IC~ALLY OPERATE BCPE DAILY. /:',PR 2 4 510084001 REV. 2 MAY 15°1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight UP 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 p~ 9-10 % Solids 10± 9.5-10.5 4-7 9.5-10.5 9-12 prilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor ~ - Fluid Agitators Notes: 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 (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5/ih GENERAL DRILLING PROCKDURE KUPARUI~ RIVL~ FIELD DEVELOPMENT WELLS 1. Mov&'-.in riB. 2. Ins. tall Tankco diverter sys:em. 3. DrilI 12~" hole Co 9-5/8" surface casing point according co directional plan. 4. Run and cement 9-5/8" casin$. 5. Install and test blow out preventer. Test casin~ to 2000 psiS. 6. D~ill ou~ cement and I0' new hole. Perfom leakoff ~est. 7. Drill 8~" hole co logsinS point accordin~ co directional plan. 8. Rum open hol~ lop. 9. Continu, drilli~ 8~" hol~ ~o provid, 100' b~s~n plu~ back total depth and boc~om of Kupa~k sands. 10. Run ~d ce~nt 7" casin~. Pressur~ cast Co 3500 psis. 11. D~squ~z~ ~ctic Pack and ca~nt in 7" x 9-5/8" a~ulus. 12. Nippl~ d~ bl~ out preventer and install ce~ora~ ~a ~ree. 13. Secure well and release ri~. Il. ~ ~s~d hole loss. 15. ~v~ ~ ~r~ver ril. Nipple up bl~ ~ preventer. 16. Pick up 7" casinj scraper ~d cubi~, trip ~ hole ~o pluf back depth. Ci~cull~t hole ~h clean brine and ~rip ouC of hole c~S back. 17. Perforac~ ~d ~n co~ltciou asse~ly, o~c ~d c~sc pecbr. 18. Nippls d~ bl~ ouc preventer and ~s~lll ~ 1~. ~nje ovtr co diesel. 20. il~ well Co Ca~s. Shut 21. Sscurs v~ll and releas~ 22. Fraccur~ 'MUD '" i CLEANER * ....... TYPICAL MUD SYSTEM SCHEMATIC LWK4/ih APril 13, 1987 Mr. J. B. Kewin Regional Drilling Engineer A~RCO Alaska, Inc. P. O. Box t00360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3M- 1 I ARCO Alaska, Inc. Telecopy: (907) 276-7542 Permit No. 87-38 Sur. Loc. 1019'F~, 1626'FEL, S~c. 25, T13N, R8E, UM. Btmhole Loc. 1331'FNL, 953'FEL, ~Sec. 26, T13N, RSE, · Dear Mr. Kewin: · // Enclosed is the approved applicati'~n for permit to drill the above referenced well The permit to drill does not y you from the probable need to obtain additional permits ~equired by law from other governmental agencies site. To aid us in scheduling hours prior to equipment so that a present to witness casing shoe is please notify befo: drill commencing_ o~er~tion~s at the well work, ~s~'hotify'~~this office 24 llatio~\~fLthe blowout prevention of C~e Commission may be ting of tRe equipment before the surface d. ~fhere ~Piverter system is required, s offic~ 2~ hours prior to con~aencing so ~t~ the Commission may witness testing t~h~f~J~Se of the conductor Pipe. V. Cha ~n of ~ Oil and Gas Conservation Commission BY ORDER OF ~E CO~MISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowe~¢ STATE OF ALASKA ~'-~ ALASKA ~ .~ AND GAS CONSERVATION CC .,MISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drilltl~L_ Redrill ~l lb. Type of well. Exploratory [] Stratigraphic Test[] Development Oil~ Re-Entry'[] Deepen_, Service [] Developement Gas [] Single Zone.¢~ Multiple Zone 2. Name of Operator 5. Da. td'm Elevation (DF or KB) 10. Field and Pool ~B-K*B 64', PAD 27' Kuparuk River Field ARCO A1 aska, I nc. t"' feet Kuparuk River 0il Pool 3. Address .... · P.O. Box 100360 Anchorage, AK 99510 0369// 6A-Pr°p~e-rt"v-D~esignati°n - DL Z.bbZ5 /~LK 2559 // 4. Location of well at surface - 7. Unit or property Name 11. Type Bond Isee 2o AAC 25.0251 1019'FNL, 1626'FEL, Sec.25, T13N, R/CeE, UM Kuparuk River Unit Statewide // 8. Well nu ,mber Number At to.p of productive interval 1314'FNL, 705'FEL, Sec.26, TI~, R8E, UM 3M-11 #8088-26-27 At total depth / 9. Approximate spud date Amount 1331'FNL, 953'FEL, Sec.2~/T13N, R8E, UM 04/18/87 $500,000 12. D~stance to nearest i ~Y3~i D~stance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line J/ 3M-lO 8185'MD 1019'@ Surface feect~ 25' (¢ Surface feet 2560 (6450'TVD) feet 16. To be completed for ~viated/~ wells _ 7. ,AntiCipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 700 cee/et Maximum hole angle z~ axi~um rf~/ / 1988 psig At total depth(TVD) 3086 psig 18. Casing program,/ I ~ ~ ~ Settrng Depth size // Specifications V D~ -r'ol~ Bottom Quantity of cement Hole Casin~ Weight Grade Couplimg Length I~1 TVD MD TVD (include stage data) 24" 16"// 62.5# H-40 Weld~ 'P'8'O' 35' 35' 115' 115' +200 cf 12-1/4' 9¢/8"36.0#/ J-55 BTC~ 3943' 35' 35' 3978' 3358' 1020 sx AS III & .5' W 300 sx Class G blend 8-1/2" /7" 26 O#t BTC 8151' 34' 34' 8185' 6450' 200 sx Class G(minimum / ~ ~ ~ HF-Ef W TOC 5)0' abov ; top of Kuparuk 19. To be corrj~)lete)~ ~,-,Ftedrill, Re-entry, and Deepen Operations. Present v~ell 9/6n1: ition summary Total dep~ 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 FCI:'VED Surface i~. ~ , Intermediate Production .,:~.!-::'!'? 0 '; ~ :~ Liner Perforation depth: measured Ai~SK3. 0il &.ua:'~ ........ true vertical 20. Attachments Fil!n~ fee ~--- Property plat [] BOP Sketch ~Diverter Sketch. Drilling program~ Dr ng fluid program~me vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements~;L_ 21. I hereby ~ ~/~,~ certi at the foregoi is:t~r/,, and correct to the best of my knowledge Signed / /,'~.~),-~¢ (;2/.~,~.¢,-'~ /, Title Regional Drilling Engineer Date ( //"' ~ ' / / ' ~ - CcTmmission Use Only (JFB) PD2/19 '~ ' r Permit Numb/el ¢.*-7 .--,,-> I APl number . I Appr..oyaJ..d~t¢~_ I See cover lette ~* ~ /~'~ I 50--¢~. c[% ~-i? '-7i.'~; ,- I ULI./J. Lt/~/ / for other requirements Conditions of approval Samples required [] Yes )~(;L No Mud Icg required ~ Yes ~ No Hydrogen sulfide mea~.u, res [] Yes ~ No _Direction' al survey required ]~'Yes [] No Required working,,,l~sCr~~.¢~~~5M; [] 10M; F~ 15M Other: / .I.,," II / /'1 / / ~ ,~'~.~"~ " " / /~//~ /// ///~ by or ear of /~// ~-2_ Approved by ~ ..- ~'. L ',,~'//¢~-~~'~ Commissioner the commission Date Form 10-401 Rev. 12-1-85 Subl;f .sate ' fVD=2: 181 ~ =627 ., TVD=645, t r 42~E.G ' ' ,( KUPARUK RI VER UNIT :20' DIVERTER SCHEIIATIC DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD 5. FMC DIVERTER ASSEMBLY WITH TWO 2- ! / 16" 2000 PSI BALL VALVES 4. 20' 2000 PSi DRILLING SPOOL W/10" OUTLETS 5. 1 O" HCR BALL VALVES W/1 O' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER 4 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.03S(b) MAINTENANCE & OPERATION i. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLONd AIR THROUGH DIVERTER LINES EVERY 12 HOURS, ~3, CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. · DO NOT SHUT IN~:WELL UNDER ANY CIRCUMSTANCES JG 11-3-86 6 · DIAGRAM #1 13-~/8' 5000 PSI RSRRA BCP STAQ< I. 16" - 2CZ:X) PSI TAI~I(CO 53'~171'INI3 ~ 2- Ii" - ~ ~I ~I~ ~ 4. 1~8" - ~ ~I PI~ ~ 5. 1~8" - ~ ~I ~I~I~ ~ ~~ ~ KI~ LI~ 6. 1~8" - ~ ~l ~ ~~I~ ~ ~ 7. 1~8" - ~ ~l ~ _ACCLM. L~TOR CAPA, CITY TEST I. Q-E(:X ~ FILL ~TCR I;~.,SiRVOIR TO ~ ~ WITH HYI:RN~IC FLUID. 2,. ASSt.t~ THAT ~TOR ~ I$ 3(330 PSI WIT1- 3. ~ TII~.. 13-EN CLOSE ALL UNITS $I~I.TN~Ua.'. N.L LIMITS .~ CL(::I~D WITH Q-IN~ING ~ CFF. I$ 45 Si![~ CL0~INI3 TII~ N~) laid ~I ~I~ 5 4 13-5/8" ~0P STACK_ TEST I. FILL BCP STA(3( ~ ~ M~IIFCLD WITH 2- Q-[CK THAT ALL LOQ( D(]~I ~ IN NEI.LI-r~.~D ARE FLLLY EETRACNED. SEAT TEST PLU~3 IN ~ WITH ELI~IN~ JT At~D ~ IN L~ LII~ VALVES ADJA~ TO B(3P STACK. ALL 4. ~ UP TO 250 PSI ~ HCLD FOR I OMIN. IN- ~ ~ TO 30130 PSI AI~ I.ICLD FOR !0 MIN. BLEED ~ TO O PSI. LII~ VALVES. CL0~I-' TCP PIF~ ~ AI~ H(~ VALVES ~ KILL ~D ~ LIIT. S. 6. TEST TO 250 PSI ~ 3000 PSI AS IN STEP 4. '7. Ca~TI~J~ TESTIN~ ALL VALVES. LI~.So ~ WITH A 250 PSI L(:~ ~ 30130 PSI HI6N. TEST AS I1~ STEP 4. DO M3T ~ ~ CI.fl(E TI-~T IS ~ A FULL CLOSlN~ POSITIVE SEAL CHa<E. CI~I.Y F-UNCIICN TF.,~T Q-E3~$ TI~T DO ~ FULLY (:L__~'_. 8. ~ T(~ PIP[ PJ~I5 ~ CL__0_~h"_ BOTT~ PIP~ RAMS. TEST BOWr(:l~l PIP~ RNa5 TO ~ PSI ~ 3000 PSI. !0. CLOSE BLII~D PJ~4S AI~ TEST TO 250 PSI N~D 3050 PSI. MANIFCLD ~ LI~S ~ FULL CF FLUID. SLr'r ALL VALVES IN DRILLING POSITION. 12. TEST STAi~PlP[ VALVES,, KFI~LYo KELLY C(X3~o DRILL PIF~ SAFETY VALVE° A~D INSIDE B(~ TO 250 PSI A~ 3000 PSI. 13. RECCI~ TEST ItT~TICN 'CN BL~ ~ TE$' F(3~. SI(3~ A~D SE~D TO DRILLIN~ SUP~ISCR. 14. PERFCI~ CQM~LETE BOP~ TEST AFTER NIPPLING UP A~D WF_EELY TFEREJ~rTER FLf, EWI(]qALLY CI:~TE ~ DAIL ..... ~iLO0840Oi I RE:~/i; MAY 15. I~ ' Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weisht Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 % Solids 10± 4-7 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5/ih DRILLING PROCKDUI~ KUPA~UK RIVL~ FIKLD DEVELOP~KNT WELLS 2. In~.t&II Tankco dlvercer system. 3. Drill 12~" hole co 9-5/8" surface casing point accordin$ co direcciona~ plan. 4. Run and ceaenc 9-5/8" 5. Install and ces~ blow ouc preventer. Tes~ casin~ Co 2000 psis. 6. Drill ouc cement and 10' n~w hol~. Perfom leakoff ~esc. Drill 8¥' hol~ Co lo,linI point accordin~ Co di~scCional plan. 8. Run open hol~ lop. Con~inu~ drilli~ 8~" hol~ co p~ovid~ 100' b~ssn plu~ bac~ ~ocal depth and boc~o~ o~ Kupa~k sands. 10. Run ~d cedric 7" casins. Pressure cesc Co 3500 psis. 11. D~sque,ze ~cCic Pack and ce~nc in 7" x 9-3/8" a~ulus. 12. Nipple do~ bl~ ouc preventer and install ~e~ora~ ~8 tree. 13. S~curs w~11 and releas~ ri~. ~ ~s~d hol~ ~vt ~ ~r~vsr rij. Nippls up bl~ ~c preventer. 16. Pick up 7" casin$ scraper ~d tubi~ trip dsp~h. Cl~cula~t hole ~ch clean brine ~nd ~~ b~ck. 17. Ps~fora~n ~d ~n co~le~ion asse~ly~ sst ~d cast pacer. 18. ~ipple d~ bl~ ouc p~evencnr and ~s~all 19. ~n~e ove~ ~o diesel. 20. FI~ well to ta~a. Shut in. 21. Secure well and release 22. Fracture SHALE SHjmd(ER~ CLEANER ,,, .~ STIR _~, STIR MUD .... I TYPICAL MUD SYSTEM SCHEMATIC LWK4 / ih CHECK LIST FOR NEW Wcr.~. PERMIlX3 ITEM APPROVE ~ (1) re_~ ~ ~-~-~ ~ 1. (2) Loc (8) (3) Admin ,~ ~-27-&? 9. (g thru 13) 10. 13) , 12. 13. (4) Casg ~.~ '22) ' (23 thru 28) (6) OTHE~ (2~'~ 31) Geology: Engineering: WVA MIM ~ RAD ~D rev: 01/28/87 6.011 i Is well tO be located in a defined pool .................... i ' ] Is well located proper distance from property line ......... Is well located proper distance from other wells .......... 5~ Is sufficient undedicated acreage available in this pool .. 6. Is well to be deviated and is wellbore plat included ...... 7. Is operator the only affected party ....................... 8. Can permit be approved before fifteen-day wait ............ Is the permit fee attached .......................................... ~ · Does operator have a bond in force .................................. ~ Is a conser~at:i.on order needed ...................................... Is aclm-~nistrative approval-needed ................................... Is the lease number approprSat:e ......................... ~ Is conductor stm-ing provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all~ casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is a diverter system required .......................... * ............. IS the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to $ o oo psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: For 29. 30. 31. Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STAIUS AREA~ NO. SHORE CHECK LIST FOR NEW W~.T. PERMITS ITEM APP~ROVE DATE (1) Fee (2) Loc (2thru 8) (3) Admin~ ~-~",,6 ~7 (9 r~ 13) (10 ~d 13) (4) Cas~ '/-6f.~ do~V (14 thru 22) (23 thru 28) (6) OTHER (29 thru 31) (6) Add: Geology: Engir~eering: LCS ~"~'~:.i BEW /' rev: 01/28/87 6.011 Lease & Well NO. K t~d NO Company '1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. .3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... ~ ] Is sufficient undedicated acreag~-aua~lable in this pool Is wel~0 be deviated and is w~lbor~ plat included ......... 7. Is operatb~.,the only affected p~t~.. ................. .. . 8' Can pe~t ~"'~pr°ved bef°re fifteen-~it ......... 9. Does operator hav~'"~'a, bond in force . . . .: ................ ' i~' 10. Is a conservation or~er,.needed .......... ~ ................. 12. Is the lease number approp~te ... q ..... ..~.... 14. Is conductor str~ provSded ... ~'">, .... .~... ~,~....~. ................... 15. Will surface casing protect fresh mt~ ........ 16. Is enough cement used to circulate on',,c~h~ and surface ...... 17. Will cement tie in surface and interme~t~ or production strings ..o 18. Will cement cover all known productive ho~ ................. 19. Will all casing give adequate safety in colt~~, tension and bur~ [ 20. Is this well to be kicked off from an existin~:~re ........... 21. Is old wellbore abandommnt procedure included 0n~%10-403 .......... . 22 Is adequate wellbore separation proposed ..~' ...... ~'~: ................. 23. Is a diverter system required ...................... ................ 24. Is the drilling fluid program schematic and list of equi'pumnt adequate 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to ~O~o psig .. ,~ 27. Does the choke manifold comply w/API RP-53 (May 84) .................. 28. Is the presence of H2S gas probable ................................. For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requir~ts ............................................. ,, ~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Ctqo(oO l-Oft II tt.o 0/4 Additional Remarks: .,.~/M -// ,~,~ A~- la 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 /P 010,H02 VERIFICATIOIi LIS?lNG PAGE 1 ~ REEb HEADER ~?~ICE NAME :EDI! 187/05/25 NAME ?/05/25 ~N~TNUATZON # 10! ~¢V~OU~ TAPE DMHEN?$ Ibis ?APE, ARCO KUPARUK 3N-11, APl 50-029-21718 I~EIYPE ! R VIOUS'rlbE : ,: ~NrOR~ATION RECORDS CONTENTS N II OWN'I OUN l UNIT 'I'¥PE CATE $I~E CODE ARCO AbASKA INC. 000 000 3~11 000 000 ~PAR. UK ~00 000 O0 000 ~N 000 000 000 000 oooooo AASK UbA8 A 000 000 000 000 CONTENTS 0¸6 O08 002 004 00~ O! 00~ OO3 065 065 065 065 065 065 UNIT' YYPE CA~E SI~E :ODE Z 000 000 00! 065 ~P OIO,H02 VERIFICATION LIS~IN~ PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER 3#PANY = ARCO ALASKA INC [ELD = KUPARUK 9UNTY a NORTH SLOPE ~OROUGH kBING = 9 625" P 3872' - BIT SIZE = 8,5" TO 7959' YPE FbUID = P~LYMER 8CO$ITY · 45 RMF = 3,3 $ DF ~UZP bO~$ = C3 RM AT BHT = l.,~ 2 9 14 DF ~TR~X SANDSTONE ' e~ THIS DATA HAS NOT BEEN DEPTH SHIFTED OVERI, A¥$ FIEbD PRINTS ~P 010,H02 VERIFICATION LISTING PAGE 3 SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC DUAL INDUCTION SPHERICALLY FOCUSED bOG (DIL) DATA AVAXbABLEI 7950 TO 3872' FORMATION DENSITY CONPENSA?ED LOG (tON) OATA AVAiLABbEt 7925' TO 6590e COMPENSATED NEUTRON LOG (FDa) DATA AVAIbABbEI 7908* TO 6590" ~ DATA FORMAt RECORD *a NTRYBLOCKS TYPE SIZE REPRCODE ENTRY t ~ ~ ~ ~° 8 4 73 60 16 I 66 '0 I 66 0 SERVICE SERVICE UN~ APl APl API AP1 :FILE SIZE SPb REPR PROCESS ORDER ~ LOG ~¥ E CLA8$ ~OO: NO, CODE, (OCTAL) , OD ooODo o , Is, oooooooooooooo o... OD ~:o o~o o , ~ ~, oooooooooooooo OH~ O0 ~ 0 4~ 0 0 4 I $8 00000000000000 ~v OD o:o o~ o o , ~:~ oooooooooooooo GAP1 O0 03 0 O~ 0 0 4 I 68 00000000000000 ~ OD~~,o o , ~., oooooooooooooo ~P OIO,H02 VERIFICATION LISTING PAGE 4 RAT liRA FDN PON FDN FDN FDN FDN DN DN FDN FDN PON GAP.I O0 ,. co G/C3 O0 350 G/C3 O0 356 O0 420 O0 000 PU O0 890 PU O0 890 P$ O0 3 0 PS O0 3;0 bB O0 635 Ol O1 02 O1 Ol O0 O0 O0 31 30 21 l:Pl' 7982 :5000 &FLU ~5000 GR -265_ · 5000 RHOB ;3809 NPH! 541.0000 TEN8 2 98 3014 8127 7500 5850 6437 0000 ¸PT 47 7800,0000 SFbU ~:48 li~,9 GR 81 RHOB 3'.~ 7 NPH! 4?4,2500 ?EaS 2,3 08 4764"0000 PT RA ??00,0000 SFbU ~L: 7600.0000 SFbU ',24,7969 GR $ ,9tt44 RHOB 3;9043 NPH! 435.0000 TENS ,1875 4472,0000 EPT CNb 7500,0000 08FRbU -;3 o° , e.43 ? 424 TENS 3.7718 102'J, 875 2' 3848 4 2., 33,40 4332;,0000 EPT 0 srbu 0~0 GR 12! '0229 ,5000 · ':3965 0 0 4 1 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 0 0 4 1 0 0 4 0 0 4 0 0 4 ILD TENS DRHO DPHI DRHD DPHI IbD E:NS DPH.I ILD . NS DPH! DRH:O: DPH! .ILO DRHC) DPH! 1 LD ~ENS DRHD 30124 8268 0000 '0 0107 64:551 4 o)8o 47603:'4 3 ..9g~7 47642. 4597 ,0000 0,,0942 ! 5,6098 3,3532 4444,0000 0.:0889 i 4,6 629 16,:08 2 :l 6:, 8 2,7 '0,03 6: 68 68 68 68 68 68 68 6 68 IbM GR NRA? NCNb NR.AT NCNb GR NRAT: NCNb NRAT NCNB !bM GR. NRAT NCNb ibm GR. NRAT NCNL GR NRAT 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 O00000000000i~O00000 co 0000 00000000000000 00000000000000 1830.0v~ 0 4564 0625 0000 178 '0000 · 181{.,0000 8125 10 ,{875 2,617 7 102, ~ 875 ;oooo 12 ~' ,8 62 ? ~P 010,H02 V~RIFICATION LI$~ING PAG£ 5 ~,5879 NPHI 44 .0000 TENS 7300 -33 8 £PT gPT :Nb NRA ::Nb 0000 srbu GR RHOB NPHI TENS 0 &FLU RHOB 9,3418 NPH! 575,5000 TENS RHOB · 000 TENS 7000,OgO0 '-42e6 75 6900,0000 EFbU ,,,44*8750 g,47~6 ROHRoB 3~,096 NPH! 745,0000 TENS 6800 S449 NPH~ 9000 TENS 6700,0000 srbu -48,6875 Ge 906719 RHOB 3,5156 NPIt! 6600,0000 SrbU -.59e2813 GR 19,.0938 RHOB 576~5000 TE:NS 6500,0000 SFbU '60,6250 OR -999,2500 RH08 43 9453 4288:0000 2 )132 395 iO00 492 1965 4 66 12! 75 47 9883 41 0000 767 000 000 4,28~2 3~,.2539 395 ,0000 38,916 3864,0000 2;509g 34,6 0 ° ~,4996 $ ,7500 "999 * 2500 DPHI TENS DRHO DPH! TENS DRHO DPHI TENS DRHO DPH! bD ~ENS DRHO DPH! bD ~E:NS DRHO DPHI ,s DRHO DPHI I b D TENS DRHO DPHI lbD DRHO DPH! NS HO 15,3730 NCNb 462!,6085 :ibm ,0000 GR ,0850 N:RAT 15,3730 NCNb 0 O0 OR 7859 NCNb 4024 1 g 0498 8754 )000 6xs F859 6 3950 0070 06~4 ~ 5'734 NRAT NCNb lb~q GR.- NRAT NCNb NRA~ NCNb 3 . 4,0000 0*0508 NRAT: 1!;9406 NCNb 382 ,0000 OR ,0498 NRAT 9,6918 aCNb 4,t451. ibm ,0000 a 382~'0786 NRAT 8,5082 NCNb ,0000 -999,2500 NRAT 1604o0000 ! ,243(~ 39 ,50 5 :'o,!o 1924 0000 14 ~8 0 :1,884,00004 980 0 1800,:0000 04,0099 ooo 4,.1048 -~99';~5500 ,,999~,2 O0 VP 010,H02 VERIFICATION bIS?ING PAGE NRA *999,~500 NPHX CNb -999, 500 TENS EPT ~400,0000 S,~bu I -57'3438 -999, 50 ~ NRA '999,~$0O0 NPH~HDB CNL -999*2500 TgN5 ~PT 6200 '53 b.t "999 NRA -999 CNL ,,999 oo0o SFbU 9375 GR 2500 RHOB -?99,2500 ~HOB .999,25.00 NPHI 999,2'500 TENS KPT TENS -9 ~:50u -999~2:500 TENS NRA CNb' ~Srbu RHO:B NPH! TENS NRA 5700,0000 SFbU -52~4063 GR -999,. NPH]: -999** 21500 TEN6 5600 ..0000 SFLU ~'58~1562 GR" '~999,2500 RHOB '99902500 '999,2500 4,1204 89,6250 '999,2500 '999~2500 '999~2500 ..°il 99.3 "9* 0 oo '999,2500 3,2742 .~o8,~75o ;999,~500 .999.2500 999~2500 -¢99.,~00 -999;2500 0625 -999,~0 "999~ 7~4956 86.7500 '999~2500 ~999~2500 ~g99.2500 DPH! ILD TENS DRHO DPHI bO DRHO DPHI DRHO DPH! D HO DPH!. HO DPH! ILO: RHO DPHI bD ~S DRHO DPH.T ,bD ENS DRHO DPH! bO DRHO -999.2500 NCNb 378~,6493 IbM ,0000 OR -999,2500 NRAT -999,2500 NCNb 4,3869 IbM 3.77 ,0000 GR 999,2500 NRAT '999,.2500 ~CNL 4,0tj56 36.44,0 O0 OR -999,2500 NRAT ...999,2500 NCNb .oooo e :2500 NRAT '"999,2500 NCNb 999~2500 NCNb 880 NRA? NCN b' · ,999,2500 NRAT 999'2500 NCNb: ;000o ' , "999.2500 NRA. T -999.2500 -999; 500 -999,. 500 -99~ ~ ' 0 -999 2500 .-99~ 03,59 · O0 ,'~99 ~ O0 · -99~ ~ 0 9~ O0 -9 ,~00 ;2500 -999,2'00 - ...999,2~00 -999,2500 -999,". ,Ob YP 010,M02 VERIFICATION bISTING PAGE 7 NRA 999 2500 NPHI 999,~500 TENS P? 5400,0000 S~bU bi -82,5000 '999,2500 ~OB CNb '999, TENS EPT 5300,0000 .SFbU 0 '999, RHOB -, -,,,.tloOoO 5200 ,,,68 -999 "9 9 9 0 i GR RHOB O0 TENS 5 i O0 '.70 '999 gooo .2500 RHOB TENS 49~80,0000 SrbU ,5938 GR -999,2500 RHOB -99~,2500 NPHI ,2500 TENS NRA 'CNL, 800,0000 SrbU '54:i. 3438 GR -999,2500 RHOB - 9,:$00 TENS 700,0000 SrbU "62,4~063 GR -999~2500 RHOB '999,2500 "999,2500 '999 2500 '50 '999 :999,2500 999,2500 '999,2500 99.: ~0 '999 O0 '999,2 '999'2 3,2825 -999,2500 -999.2500 307960 .94;0000 .999.2500 .999,2500 999;2500 '999d2500 DPH! TENS DRHO DPHI IbP lENS DRHO DPHZ IbD TENS DRHO DPHI RHO DPH! RHO DPH]: bD DR HO DPHI DRHO DPHI DRHO -999,2500 NCNb tS16 I~M 000 GR 2500 NRAT -999.2500 NCNb ,2396 IbM I .oooo .999,2500 NRRT ,2500 NCNb ,0000 GR ,~500 NRAT '999,2500 N:Nb -999~', 500 NRAI '999. 500 NCNb : goo , 500 NCNb "'999 O0 NCNb 0 0 O0 GR ;999,2500 NRAI 999.~500 NCNb 4,:0193 IbM ~890,0000 OR .999,2500 NRA~ -999,2500 :,,l:ili°o 999, 500 '999, 500 . 'i,1095 999'~ O0 -999.t~00 -999. 2500 ,,99~'90~[ -999,2500 .,,, "999,2500 '5593: 0 · .. -999,.2500 -999,2500 :-999,2500 · -999 ' -999, 0 VP OlO.H02 VERIFICATION LISTING PAGE 8 NRA '999,2500 NPH! CNb -999.2500 T£NS EPT 4600,0000 3FLU P .'66,1875 OR lb! 999,2500 RHOB M A -999,2500 TENS C~b -999.2500 NPH! '999,2500 '999,2500 86 93 -999 -~ ~00 -999 O0 -999 : 500 DPHI TEN,5 DRHO DPHI EPT 4500,0 O0 SFbU 3,2 ~ ~b! -999; 50 RHOB 099 · 5 0 DRHO NRA 500 NPH! -999 O0 DPH! ,oo -,,,. oo ZPT 4400,0000 SFbU 4,0 6 ~oo ~o~ -~99 ~ ~o ~00 PHI '9 ~, TENS 9 -999, ' 0 ~PT 4300,00~0 S~bU : "40,95 Ab:! -999,2~0 Gm RHOB O0 PHI NRA -999.{~§0 N CNb -999'. TEN, ~PT' 4200,0000 -999; CNL -999, TENS -999,2500 ~HO8 · 'R.R ,,,999,2500 NPHI ~Nb -999,2500 TENS 400~,0000 SFLU ,2500 RHOB ;2500 TEN 3,4684 '999 0 "999 ~ oo 1,8{~3 .113',3 .-'999,.250 999,2500 ,,999'2500 3,3888 97,8125 ,999,2500 999,2500 -999,2500 ~999,.2500 :999,2500 999,2500 2000,0000 57,3125 '999,2500 PT. 3900,0000 SFLU !~ -984'3125 GR ! 99,2:500 RHOB N A -999,2500 NPHI CNb -999 '2500 TENS 2500 RH. OB bD DRHO DPH! I bD TENS DRHO DPH X DRHO Df'H! IbD TO E N S DPH! XLD TENS DRHD DPHX D ENS DPHZ lbo DRHO -999,2500 NCNb 276!,8794 IbM ,0000 GR -999,2500 NRAT -999,2500 NCNb 27443,6174 ~M ,0000 '999,2500 NRAT -999,2500 NCNb . 4791 IbM 265 ,0000 GR -999,2500 NRAT -999.2500 NCNb 2671 6946 0000 -999 2500 -999 250O '999 '999 T9{ 2078 20 0000 -9 2500 '999 :2500 ,:1554 999,2500 2]04'0000 ' 999, :2500 '999,2500 59,9 5 0 7 .0000 NRAT NCNb IbM OR NRAT NCNb NRAT NCNb NRAT NCNb I L M OR NRAT NCNb GR NRAT -999,2500 -99 '!TM 99' 500 , 500 99, 500 {5500 '999,2 O0 '999,2500 .995:4402 ~ O0 '999,~I00 -999..2500 '999 ..99t~ 3429 2500 2500 '999 2500 99,2500 -999,2500 -999,2500 '999,2500 -999,.2500 -999, 3,7771 -999,2500 '999,2500 -999 ;2500 2000,0000 "999, ~P 010,H02 VERIFICATION LISTING PAGE 9 ~RA o999,2500 NPHI ~999,2500 ~Nb -999,2500 TENS 999,2500 DPHI ILE NAME IEDIT ,001 ERV~CE NAME I ~TE_ ~XIMUM b~NGTH I 1024 ILE TYPE ~ EXT FXbE NAME I -999,2500 NCN6 0999,2500 $ TAPE TRAILER ** ERVXCE NAME IEDXT ATE !87/05/25 RXGXN, l?230 APE NAME l EXT±TAPE NAME ~ OMMENT$ !bis TAPE, ARCO KUPARUK 3M-11, API 50-029-21718 *.: R~EL TRAXbER ,1 ERVXCE NAME: IEDIT E~L NAME 17230, ONTINUATXON # I0~ EXT REE6 NAM£A Ip£ OMMENT$ Ibis ~ , ARCO KUPARUK 3M~,lt, API 50-029~2~7tB EOF EOF