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Home My WebLink About185-310Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned dudng 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. ~.(~ -..~ L{~ Well History File Identifier Organization {done) V~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [3 Color items: [3 Diskettes, No. [3 Ma ps: [] Grayscale items: [3 Other, No/Type rn Other items scannable by large scanner [3 Poor Quality Originals: J Other: ~~ OVERSIZED(Non-Scannable) [3 Logs of vadous kinds TOTAL PAGES: ? / NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL~ LOWELL Project Proofing Other [] Staff Proof By: Date: PROOFED BY: BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: /si PAGES: q I (at the time of scanning) SCANNED BY; BEVERLY BREN VINC~ARIA .LOWELL RESCANNEO BY.' BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI Quality Checked (done) Rev1NOTScanned.v4~l • ConocoPhillips ~~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • =i ~~~i ,. ~'~d ~~,~ I r 'v~ ~~ p_ ~~~ ,/ ~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped April 7th , 2009. The corrosion inhibitor/sealant was pumped April 15th and 16th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,. _ ` Perry Klein ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off .~~ Report of Sundry Operations (10-404) Kuparuk Field Date 4/1712009 Well Name PTD # Initial top of cement Vol, of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 31-01 185-307 58' 10.10 4' 1" 4/7/2009 4.40 4/15/2009 31-03 185-309 69 '8" 10.20 4' 3" 4/7/2009 8.50 4/15/2009 31-04 185-310 26' 4" 4.10 2' 4R/2009 3.40 4/15/2009 31-05 186-036 76' 12.70 3' 6" 4/7/2009 8.50 4/15/2009 31-08 186-040 8' 6" 1.20 1' 9" 4/7/2009 3.40 4/15/2009 31-09 186-055 40' 5.10 1' 9" 4/7/2009 3.40 4/15/2009 31-11 189-035 1' 9" N/A N/A N/A 2.60 4/16/2009 31-12 186-060 44' 6.80 1' 11" 4/7/2009 2.60 4/16/2009 31-13 189-025 SF N/A N/A N/A 2.50 4/16/2009 31-14 186-062 77' 11.30 2' 11" 4/7/2009 8.50 4/16/2009 31-16 189-022 24' 3.54 1' 7" 4/7/2009 2.30 4/16/2009 31-17 189-024 37' 3.64 1' 7" 4/7/2009 2.00 4/16/2009 e Conoc6Phillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 December 5, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 RECEIVED DEC 1 3 2005 Alaska Oil & Gas Cons co '. A h . mmlSSlon nc orage Subject: Report of Sundry Well Operations for 31-04 (APD # 185-310) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 31-04. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 111. L1~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad ~ 1.1"'\1"11: ,,~ n¡; C "î () iN;) ~çANNE'.... lei b·J .< e e RECEIVt::U DEC 1 3 2005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~Ia$ka Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon 0 Repair Well D Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 185-310/ 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21517 -00 7. KB Elevation (ft): 9. Well Name and Number: RKB 71' 31-04 8. Property Designation: 10. Field/Pool(s): ADL 25631, ALK 2564 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8420' feet true vertical 6550' feet Plugs (measured) Effective Depth measured 8183' feet Junk (measured) 7989' true vertical 6377' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 99' 16" 99' 99' SUR CASING 3848' 9-5/8" 3919' 3330' PROD. CASING 8329' 7" 8400' 6536' Perforation depth: Measured depth: 7986', 7978'-7996', 7992', 8006'-8046', 8116'-8122' true vertical depth: 6233',6228'-6241',6238',6248'-6277',6328'-6332' Tubing (size, grade, and measured depth) 2-7/8", J-55, 7902' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 7832' SSSV= Cameo 'TRDP-1A-SSA' 1802' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS BFL DEC 1 3 2005 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation 275 918 662 -- 171 Subsequent to operation 327 623 635 -- 177 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJD WDSPL D 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: Contact Printed Name bl J Title Signature JI! 1f1~ Phone Date / Z/1 />5 , -,,--1"..... , Preoared bv Sharon AI/suo-Drake 263-4612 ~ Form 10-404 Revised 04/2004 ORiGINAL Submit Original Only ConocoPhillips Alala, Inc. e KRU 3-04 3li04 API: 500292151700 . VYE}!'-I¥.~ PROD AnQle @_TS: ·43 deQ.@ Z8~_. .._... ._. .H___.H 27411986 -.--- SSSV Type: TRDP Orig Angle @ TD: 43 deg @ 8420 sssv L II: Completion: (1802-1803, Annular Fluid: Last W/O: Rev Reason: TAG FILL 00:2.875) Reference LOQ: Ref Loo Date: Last Update: 10/28/2005 Last Taa: 8183 TD: 8420 ftKB Last TaQ Date: Max Hole AnGie: 47 deo (â) 5100 ..__m~__ "".-. Gas Lift ,,¡Æ:1i.i1i.i MandrelNalve Descrietion Wt , ... Thread -... 1 Size Toe Bottom TVD ! Grade (2404-2405, CONDUCTOR 16.000 0 99 99 62.50 H-40 SUR. CASING 9.625 0 3919 3330 36.00 J-55 PROD. CASING 7.000 0 8400 6536 26.00 J-55 Gas Lift "'.: }TiinfiiiS .·.i.: ffi;f!fi}i; ;!i';!! III lULling '-" LI' ii MandrelNalve Size I Top I Bottom I TVD I Wt I Grade I Thread 2 (4590-4591, 2.875 I 0 I 7902 I 6172 I 6.50 I J-55 I EUE 8RD AB MOD ;....ii if. ·B. ¡;;f;!I!I: Interval TVD Zone Status Ft SPF Date Type Comment Gas Lift 7986 - 7986 6233 - 6233 A-3 0 1 5/20/1986 IPERF 90 deg. phase; 4" Hyper Jet MandrelNalve " 3 (5753-5754, 7992 - 7992 6238 - 6238 A-3 0 1 5/20/1986 IPERF 90 deg. phase; 4" Hyper Jet " 8006 - 8046 6248 - 6277 A-2 40 4 5/20/1986 IPERF 90 deg. phase; 4" Hyper Jet Gas Lift II MandrelNalve 8116 - 8122 6328 - 6332 A-1 6 4 5/20/1986 IPERF 90 deg. phase; 4" Hyper Jet 4 (6414-6415, " ~s !,.ift_Mandrelsl\(alves_... XI; iif;:ffii!i;;.· iiit : St MD I TVD I Man ; Man Type I V Mfr V Type V 0['- ! Latch Port TRO Date Vlv Gas Lift Mfr Run Cmnt MandrelNalve 1 2404 2262 Camco KBMG GLV 1.0 BK-2 0.156 1309 2/19/2005 5 (6858-£859, 2 4590 3809 Camco KBMG GLV 1.0 BK-2 0.188 1344 2/19/2005 3 5753 4632 Camco KBMG GLV 1.0 BK-2 0.188 1336 2/19/2005 4 6414 5113 Camco KBMG GLV 1.0 BK-2 0.188 1324 2/18/2005 Gas Lift 5 6858 5432 Camco KBMG OV 1.0 BK-2 0.188 0 2/13/2005 mdrel/Oummy 6 7333 5768 Camco KBMG DMY 1.0 BK-2 0.000 0 6/3/2000 Valve 6 7 7775 6080 MMH 2.875 X 1.5 Camco DMY 1.5 RK 0.000 0 6/312000 (7333-7334, 00:4.750) i!$l'LI'" . ..' .; '..Iî$\Ail: RVi: i.li Gas Lift Depth TVD Type Description ID Indrel/Oummy 1802 1769 SSSV Camco'TRDP-1A-SSA' 2.312 Valve 7 (7775-7776. 7814 6109 PBR Camco 'OEJ' 2.313 00:4.750) 7832 6122 PKR Camco 'HRP-1-SP' 2.347 7869 6148 NIP Camco'D' Nioele NO GO 2.250 PBR 7902 6172 SOS Camco 2.441 (7814-7815, 7902 6172 TTL 2.441 00:2.875) l1tisn.. =ISRi'iiff! ;:;::; :IB :} Depth I Description I Comment 7989 11 1/2" GLV I Emetv Pocket; Oriainal GLV Lost to Rathole 8/14/1990 PKR (7832-7833, 00:6.151) NIP (7869-7870, 00:2.875) TUBING (0-7902, -----....&i 002.875. 102:441) ~ Perf ~ ~ (7986-7986) 11/2"GLV ~ (7989-7990, 00:1.500) Perf ~ - (7992-7992) Perf ~ - (8006-£046) ~ - ~ - Perf == == (8116-<:!122) ~ - ~ - e 31-04 Well Events Summary e Date Summary . 11/12/05 ATTEMPED DRIFT TBG WITH 21' X 2-1/8" STEM. SET DOWN @ 6972' WLM. BRUSH TBG WITH 2-7/8" BLB. 11/13/05 BRUSHED & FLUSHED TBG WITH 2-7/8" BLB TO 8181' RKB. DRIFTED WITH 21' X 2-1/8" DUMMY GUN. 11/15/05 PERFORATED 7978' TO 7996', 6 SPF WITH 2-1/8" SPIRAL POWER ENERJET GUN. Schlumberger NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 10/07/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1)'"'f1h ~~D NO\J () 2 LUU;) Field: Well Job# Log Description Date BL 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1 E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1 G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 1 D-122 11015730 INJECTION PROFILE 09/06105 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1 D-114 11015728 INJECTION PROFILE 09104/05 1 2V -08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10/02105 1 1 E-105 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: :IL,; a1!J DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk -~ Color CD '--' /7 G~JvN-r- ; R ç - J itJ F:ft-- STATE OF ALASKA ALA'5'KA OIL AND GAS CONSERVATION COMMIS,'~'rON 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 295' FSL, 122' FWL, Sec. 31, T13N, R9E, UM At top of productive interval 1026' FNL, 1499' FEL, Sec. 5, T12N, R9E, UM At effective depth 1099' FNL, 1192' FEL, Sec. 5, T12N, R9E, UM At total depth 1116' FNL, 1119' FEL, Sec. 5, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 842O 6549 6. Datum elevation (DF or KB) RKB 71 feet 7. unit or Property name Kuparuk River Unit 8. Well number 31-04 9. Permit number/approval number 85-310 10. APl number 50-029-21517-00 11. Field/Pool Kuparuk River Field/Oil Pool feet feet Plugs (measured) None Effective depth: measured 831 0 true vertical 6469 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 88 8' 9 - 5 / 8" Intermediate Production 8376' 7" Liner Perforation depth: measured Cemented Measured depth True vertical depth 255 SX CS II 99' 99' 1500 Sx AS III & 391 9' 3330' 320 Sx Class G 300 Sx Class G & 8400' 6534' 175 Sx AS I 7986'-7986',7992'-7992',8006'-8046',8006'-8046' true vertical 6232'-6232',6236'-6236',6246'-6276',6327'-6335' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 7902' Packers and SSSV (type and measured depth) Packer: Camco HRP-I-SP @ 7832'; SSSV: Camco TRDP-1A-SSA @ 1802' ORIGINAL 13. Stimulation or cement squeeze summary Fracture stimulated 'A' sands 5/29/97. Intervals treated (measured) 7986'-7986',7992'-7992',8006'-8046',8006'-8046' Treatment description including volumes used and final pressure ~'\" ~ '~'*'~' ~'" ' Pumped 161 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp = 6100 psi. 14. Representative Daily Average Production or Injection Data ~, OiI-Bbl Gas-Mc'f Water-Bbl Casing Pressure~ Tubing Pressure,,.. Prior to well operation 715 683 563 1 ::~,~[~,~.;~, U,~ '-:,,~ ..... ,~,~:':".,~. ,.~....~, Subsequent to operation 1 1 3 8 666 501 1247 188 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. Signed ~~)Z,~._~.., ~~J~,'~ For:-~4t ~e~ e~'l~ '~ I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT --' WELL SERVICE REPORT ~ K1(31-04(W4-6)) WELL JOB SCOPE JOB NUMBER 31-04 FRAC, FRAC SUPPORT 0523971713.4 DATE DAILY WORK UNIT NUMBER 05/29/97 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoI (~ Yes (~ No DS-YOKUM CHANEY FIELD AFC# CC,# DAILY COST ACCUM COST Si¢~e_~i ~ //' ESTIMATE KD1038 23ODS361L $1 1 1,694 $122,306 ~ ~ ,/~-'~--~~~.,~ I Out(~r A'nn Final Oute .~,,~p Initial Tbq Press Final Tbq Press Initial Inner Ann Final Inner Ann Initial '~1' 1100 PSI 1200 PSI 200 PSI 500 PSI 25 PSII SI DALLY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 160994 LBS OF PROP IN THE FORMATION W/11.Zl4f PPA OF #12/18 @ THE PERF'S. FREEZE PROTECTED TBG DOWN TO 3400' W/DIESEL.MAXIMUM PRESSURE 8200 PSI & F.G. @ (.71/ TIME 06:00 07:45 08:15 09:15 10:50 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRK, & LRS HOT OIL UNIT. HELD SAFETY MEETING (15 ON LOCATION) PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER. PT'D HIGH PRESSURE LINES AND EQUIP TO 10000 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 20 TO 15 BPM. VOLUME PUMPED 288 BBLS. USED 6004 LBS OF #20/40 PROP FOR SCOURING. MAXIMUM PRESSURE 8200 PSI AND ENDING PRESSURE 3600 PSI. S/D AND OBTAINED ISlP OF 1674 PSI W/F.G. @ (.71). STOOD-BY AND MONTIORED WHTP. PULSED TO DETERMINE CLOSURE. PUMP DATAFRAC W/50# DELAYED XL. GW @ 5 TO 15 BPM. VOLUME PUMPED 170 BBLS. MAXIMUM PRESSURE 6100 PSI AND ENDING PRESSURE 3800 PSI. S/D AND OBTAINED ISIP OF 1844 PSI W/F.G. @ (.74). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5TO 15 BPM. COMPLETED THRU FLUSH. PUMPED 161954 LBS. INJECTED 160994 LBS OF PROP (13400 LBS 04 #20/40 & 148554 LBS OF #12/18) W/11.44f PPA OF #12/18 @ THE PERF'S. LEFT 960 LBS OF PROP IN THE WELLBORE AND ESTIMATE TOP OF FILL @ 7944' RKB. FREEZE PROTECTED TBG DOWN TO 3400' W/DIESEL. S/D AND MONITORED WHTP FOR 10 MINS. 12:10 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRK. 12:30 13:30 REMOVED TREESAVER (LOST 25% OF CUPS). CONTINUED R/D. R/D COMPLETE AND DOWELL MOVING OFF LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DALLY COST ACCUM TOTAL $0.00 $1,071.00 APC $5,500.00 $5,500.00 DIESEL $400.00 $400.00 DOWE LL $104,034.00 $104,034.00 HALLIBURTON $0.00 $4,481.00 LR-FLE RED $1,760.00 $6,820.00 TOTAL FIELD ESTIMATE $111,694.00 $122,306.00 STATE OF ALASKA ALASKA ~rlL AND GAS CONSERVATION COT~MISSION W~(~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OILX[~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-310 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21517 4. Location of well at surface 9. Unit or Lease Name 295' FSL, 122' FWL, Sec.31, T13N, R9E, UM Kuparuk River Unit 10. Well Number At Top Producing Interval 1026~FNL, 1499' FEL, Sec.5, T12N, R9E, UM 31-4 At Total Depth 11. Field and Pool 1116' FNL, 1119' FEL, Sec.5, T12N, R9E, UM Kuparuk River Field Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 571' RKB ADL 25631 ALK 2564 J 12. Date .Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/27/86 02/01/86 06/22/86* N/A feet MSL 1 i7. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8420 'MD ,6549 'TVD 8310 'MD ,6469 'TVD YEsX~cl NO [] 1802 feet MD] 1650' (approx.) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6:: bZ.~¢~ H-~,U 5urt 99' 24" 255 sx CS II 9-5/8" 36.0# J-55 Surf 3919' 12-1/4" 1500 sx AS Ill & 320 sx Class G 7" )_6.0# J-55 Surf 8400' 8-1/2" 300 sx Class G & 175 sx IS 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) 7986 'MD 6232 'TVD 2-7/8" 7902 ' 7832 ' 7992 'MD 6236 'TVD 8006' - 8046'MD 6246' - 6276'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8116' - 8122'MD 6327' - 62,35'TVD DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED See attached Addendum, dated 6/26/86, for fracture data. 27~1./A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~I~ Flow Tubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * NOTE: Drilled RR 2/4/86. Perf'd well & ran tubing 5/22/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WCl/090 Submit in duplic~/' 29. GEOLOGIC MARKE'I~IS 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 7850' 51:~4' N/A Base Kuparuk C 7887' 5160' Top Kuparuk A 7963' 5216' Base Kuparuk A 8124' 5333' 31. LIST OF ATTACHMENTS Addendum (dated 6/26/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ (/~j ~.L~ Title ASSOci ate Engineer Date '-~/~-~I~ _ 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 (G L) 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: 2/13/86 6/22/86 3I-4 Arctic Pak w/175 sx AS I, followed by 59 bbls Arctic Pak. RU & rn CET/GR/CCL & 6.125" gage ring f/8286'-6300'. Rn GCT gyro f/8250'-surf. Frac'd Kuparuk "A" sand perfs 7986', 7992', 8006'-8046' & 8116'-81.22' in 9 stages per 6/20/86 (revised 6/21/86) procedure using Musol, diesel, gel/diesel, 100 mesh & 20/40 sand. Press'd annulus to 2150 psi w/diesel. Tst lns to 8000 psi; OK. Stage #1: Pmp'd 20 bbls 140° diesel w/5% Musol @ 5 BPM w/3480 psi Stage #2: 67 bbls gel/diesel spacer @ 20 BPM w/6980-4330 psi Stage #3: 25 bbls gel/diesel pre-pad @ 20 BPM w/4400 psi Stage #4: 24 bbls gel/diesel w/1 ppg 100 mesh @ 20 BPM w/4400-4360 psi Stage #5: 150 bbls gel/diesel pad @ 20 BPM w/4360-4100 psi Stage #6: 20 bbls gel/diesel w/ 3 ppg 20/40 @ 20 BPM w/4100-4300 psi ("on fly") Stage #7: 43 bbls gel/diesel w/6 ppg 20/40 @ 20 BPM w/4300-6400 psi ("batch") Stage #8: 16 bbls gel/diesel w/10 ppg 20/40 @ 20 BPM w/6400-6780 psi ("batch") Stage #9: 48 bbls gel/diesel flush @ 20 BPM w/6780-5100 psi Pmp'd 1000# 100 mesh & 19,716# 20/40 in formation leaving 360# 20/40 (per procedure) in csg. Load to recover 413 bbls of diesel. Job complete @ 1404 hrs, 6/22/86. Turn well over to Production. Production to rn post frac logs. Drill~SUperint~t gate STATE OF ALASKA ALASKA ulL AND GAS CONSERVATION COMMISSION r _nMPL TION OR RECOMPLETION REPORT AND LOG Classification of Serwce Well 1. Status of Well OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-310 8. APl Number 3. Address P. 0. Box 100360, Anchorage, AK 99510 50- 029-21517 9. Unit or Lease Name 4. Location of well at surface 295' FSL, 122' FWL, Sec.31, T13N, R9E, UN Kuparuk River Unit 10. Well Number At Top Producing Interval 1026~FNL, 1499' FEL, Sec.5, T12N, R9E, UM 31-4 -11. FIeld and Pool At Total Depth 1116' FNL, 1119' FEL, Sec.5, T12N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 71' RKB ADL 25631 ALK 2564 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01/27/86 02/01/86 06/22/86* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I21'Thickness°fPermafr°st 8420'MD,6549'TVD 8310 'MD ,6469 'TVD YEsX~] NO [] 1802 feet MD 1650' (approx.) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ~ 6;; bZ.~Cr H-u~U Surf 99' 24" 255 sx CS I I 9-5/8" 36.0# J-55 Surf 3919' 12-1/4" 1500 sx AS Ill & 320 sx ;lass G 7" 26.0# J-55 Surf 8400' 8-1/2" 300 sx C1 ass G & 175 sx IS 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) 7986 'MD 6232 ' TVD 2-7/8" 7902 ' 7832 ' 7992 'MD 6236 'TVD 8006' - 8046'MD 6246' - 6276'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8116' - 8122'MD 6327' - 6335'TVD DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED See attached Addencum, dated 6/26/86, for fracture data. 2~./A PRODUCTION TEST - Date First Production I Method of Operation (Flowing, gas lift, etc.) Hours Tested PRODUCTIONI FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO Date of Test TEST PERIOD ~I .... - Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co.r) 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. None Form 10-407 * NOTE: Drilled RR 2/4/86. Perf'd well & ran tubing 5/22/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/090 Subr0~t in duplicate 29. ~ - 30. 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 7850' 5134' N/A Base Kuparuk C 7887' 5160' Top Kuparuk A 7963' 5216' Base Kuparuk A 8124' 5333' 31. LIST OF ATTACHMENTS Addendum (dated 6/26/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned [/~ (~.,¢' ~ '~~,A._/ Title A$$oci ate Engineer Date , 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: 2/13/86 6/22/86 31-4 Arctic Pak w/175 sx AS I, followed by 59 bbls Arctic Pak. RU & rn CET/GR/CCL & 6.125" gage ring f/8286'-6300'. Rn GCT gyro f/8250'-surf. Frac'd Kuparuk "A" sand perfs 7986', 7992', 8006'-8046' & 8116'-8122' in 9 stages per 6/20/86 (revised 6/21/86) procedure using Musol, diesel, gel/diesel, 100 mesh & 20/40 sand. Press'd annulus to 2150 psi w/diesel. Tst lns to 8000 psi; OK. Stage #1: Pmp'd 20 bbls 140° diesel w/5% Musol @ 5 BPM w/3480 psi Stage #2: 67 bbls gel/diesel spacer @ 20 BPM w/6980-4330 psi Stage #3: 25 bbls gel/diesel pre-pad @ 20 BPM w/4400 psi Stage #4: 24 bbls gel/diesel w/1 ppg 100 mesh @ 20 BPM w/4400-4360 psi Stage #5: 150 bbls gel/diesel pad @ 20 BPM w/4360-4100 psi Stage #6: 20 bbls gel/diesel w/ 3 ppg 20/40 @ 20 BPM w/4100-4300 psi ("on-fly") Stage #7: 43 bbls gel/diesel w/6 ppg 20/40 @ 20 BPM w/4300-6400 psi ("batch") Stage #8: 16 bbls gel/diesel w/10 ppg 20/40 @ 20 BPM w/6400-6780 psi ("batch") Stage #9: 48 bbls gel/diesel flush @ 20 BPM w/6780-5100 psi Pmp'd 1000# 100 mesh & 19,716# 20/40 in formation leaving 360# 20/40 (per procedure) in csg. Load to recover 413 bbls of diesel. Job complete @ 1404 hrs, 6/22/86. Turn well over to Production. Production to rn post frac logs. Drill~SUperint~t SUB.SURFACE DIRECTIONAL ~URVEY [~UIDANCE ~ONTINUOUS [-~OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED WELL 31-4 (295'FSL, 122'FWL, S31, T13N, R9E) __ i KUPARUK, NORTH SLOPE, ALASKA _ ! Jo13 Reference No~. 71333 Lo,qaed By;. Date_ 12-MAR-86 Computed 8¥: OGDEN GCT 2I~iCTIO~L SU~¢~Y 'UST]MER L£$TINg KUO~RU( $LOPE,AL~SK4 SURV=Y DATE: ENGINEEq: T. METHODS 0= CDqDUT~TI3~ TOOL LDS~TZDN: TANGENTIAL- AVERAGED DE~!ATIDN ~N3 4Z!~JTH INTE~P]_ATIDN: LinEAR VERTICAL SECTION: qORIZ. DIST. PR]JECTZD 3~TS ~ T~RGET 4ZiqJT~ 3F 5~ CD~PUT~TI3q 3I-4 KJP~RJ~ NDRTH D&T~: 12-M~R-85 INT:~PGLAT=3= V~LJ:S_ =OR :VEN 100 ~EET 0= ~JRSE~. V:RTI'~L. 333' =G~ ]EVI~TI3~ ~ZIMOTfl SECTION SEVZRITY DsS 4ZN DES MIN FE~T DES/IO~ TRU= SJ~-SE~ MEASURED V~RTIZ~L V~RTI'AL 0 0 N 3 3 E 0.00 3.00 0 2 N 55 25 W 0.11 3.OR 0 3 S 37 57_ ~_ 0.10 0.1~ 0 B S 56 25 N 0.11 ~.21 0 7 S 35 39 4 -0.05 3.15 0 i1 S 29 4~ ~ 0 O1 ,) ~D ~ · · ~ 1 6 S 69 23 - 9.97 1.21 1 ~2 S 73 25 ~ 3.37 3.52 1 %4 S 71 3~ 5 5.28 O. 1~ 2 10 S 72 41 ~ 9.59 1.1~ 0,33 0,00 -71,00 1DO,O0 100,00 29,00 220,33 200.00 12~,00 300.09 300.00 229.00 ¢~0,00 4~0,00 32~.00 500,~3 500,00 ~2~.00 SDO.O~ 5~9.99 52~.~9 790.30 $99.~5 52~.96 330.30 799.~2 728.92 900.3~ 899.~5 92~.86 4 !4 S 79 25 5 1~.92 3.09 6 %1 S 70 Z E 2%.53 2.55 9 33 S ?0 27 E 38.59 3.07 12 9 S 71 4! ~ 57.35 3.1~ 14 ~4 S 7i 2~ E ~0.77 1.9~ 18 gl S 59 37 ~ 139,27 5,63 20 ~0 S 7D 5 E 142,8~ !,45 23 56 S 71 52 E 180.41 2.57 26 ~0 S 7~ 5 : 222.71 3. 2~ ~2 S 73 55 ~ 269.97 2.3~ · 31 %7 S 73 27 ~ 320.~3 2.51 34 9 S 71 25 5 375.15 37 ) S 59 50 ~ 433.34 3.53 40 3 S 69 2 E 495.~5 !.67 43 8 S 6~ 2 5 562.15 45 ]8 5 57 29 ~ 632.41 0.72 45 53 S 57 21 = 70~ 10 0 45 55 S 67 22 ~ 775.73 3.82 ~6 9 S 57 45 ~ ~27.82 ~.63 45 57 S 68 ~ E 919.76 1}30.00 ggg.?l ~28.71 1100.09 1099.!5 102~.25 i230,33 ii9~.24 ii27.24 1300.00 12~6.45 1225.45 1~30.30 1393,56 1322.66 1500.00 1~9.%9 1413.49 1500,00 1583,58 1512,68 1TOO.DO 1676.34 1505.34 1800.00 1766.91 1695.91 19~0.00 1~54.~ 1783.99 20~0,00 19~0,99 1969,99 2100.33 202~.59 1953.99 2200,33 2105,Z0 2335.20 2300,00 2184,24 2113.24 2~00,00 2259.37 218~.07 2500,0~ 2330.17 2259,17 2500.00 2399.53 232~.83 2700,30 2~69.54 239~.5~ 2800.23 2538.18 2457.7~ 2900.00 2608.21 2537.21 45 56 S 58 13 5 991,59 0,31 45 ~0 S 58 22 E 1053,29 ~5 25 S 53 35 ~ 113~,.5~ 3,32 45 15 S 5~ 53 : 1205.68 3.3~ ~5 2 S 69 9 5 1275,59 0.3~ 44 %6 S 59 1 : 1347.22 3,2! 44 29 S 56 55 ~ 1417.49 3.39 44 10 S 69 55 E 1487.36 0.61 43 58 S 59 5 ~ 1555.92 3.4~ a3 36 S 59 4 E 1625.16 O.SR 3000.00 2677.77 2505.77 3100.00 2767.~5 2575.~5 3230.0~ 2817.50 27~5.50 3300.00 2887.~6 2~15.36 3¢)0.00 2958.37 2387,37 3500.0) 3029,15 2955,15 3500,00 3100.30 3029.30 3?00,00 3171.33 310~.$3 3800,0~ 3243.57 3172.67 3900.00 3315.31 32~.81 3. O. O. O. O. 1. !. 2. 3. 13. 1~. !5. 35. 48. 60. 73. 87. 101. 117. 137. 159. 183. 210 · 237. 7_65. 292, ~19, 346. 373 · 399. ~+25. %50. &75. 501. 525 · 551. 575. ~TE ]F SJR~fEY: 12-F:B-85 ~.LLY ~JSHING ELEVATIDN: 71,03 F :NGI~=ER: T. UR4~ 3 9E~TH 3UL&R C33RJI~ATES H]RIZ, O;~RTUR: SOJTH EaST/W:ST DIST. ~ZIMUTH T FEZT F::T 3ES MIN 39 N 3,00 E 0,00 30 S O,O1 E 0,30 S 1 54 = 29 S 0,03 5 0,29 S 0 47 ~4 S 0.35 W 0.~+5 S 5 31 55 S 3,25 W 0,52 77 S 0.27 W 0.~2 S 25 S 0,57 E 1.37 S 24 32 ~3 S 2.8B E 3.47 S 55 '3 r- '32 S 5,55 E 5.32 S 53 79 S 8.82 .= ~.50 S 65 45' _ ~5 S 13,89 E 14,93 S 63 33 E 72 S 22,92 E 24,53 S 53 S 35.14 5 38.59 S 59 28 E 55 S 53.93 5 57.37 93 S 75.15 5 80.71 S 70 31 E 37 S 103.05 E 109.28 S 70 33 5 16 S !3~.47 E 142.84 S 70 17 ~4 S 170.00 E 180.42 S 73 25 ~'9 S 210,27 E 222,79 S 70 44 21 S 255,59 E 270,05 S 71 9 38 S 304,57 E 321,00 S 71 35 E 75 S 355,4~ E 375,39 S 71 43 09 S 411.33 = ~33.57 S 71 34 07 S 469.8~ E 996.04 S 71 17 37 S 531.54 E 562.29 S 70 58 11 S 596,57 = 532,~9 S 73 35 53 S 662,52 E 704.13 S 73 16 E 34 S 728.95 E 775.74 S 69 59 55 S 795.6~ E 8~7.82 S 69 47{ 92 S 862,32 E ~19,76 S 58 S 929,.01 E 991,59 S 69 32 E 16 S 995,55 E 1063,29 S 31 S 1062 07 E 1134 65 S ~8 S 1128.2~ E 1~05.70 S 69 21 58 S 119~.45 E 1275,52 S 69 19 85 S 1260,42 ~ 1347.25 S 69 19 06 S 1326,01 E 1~17,53 S 69 17 15 S 1391.23 E 1~87.40 S 08 S 1455.18 E 1556.96 S 69 15 77 S 1520,87 E 1626,21 S b9 15 E 3I -4 KJ~aRJ( N]RTH SL,DPE, AL6Sq& DfiTE: 12-M~R-$5 ZNTE~OLATE] VfiLJES :gR ;VEX 100 TRUE 3JB-SEA ~EASUR:] V~RTICaL V~RTI'AL DEPTq DEPTq 3=oTH 4930.33 33~8.~0 3317.4~ 4100.00 3459.51 339).51 4ZOO.OD 3532.37 3451.37 4300.00 3503.93 3532.93 ~%]0.~ 367~.99 3503,)7 4500.03 3745.~5 367~.45 4500.00 3815.71 37~%.71 47]0,00 3885.73 3815.73 4BOO.O~ 3955.%3 388%.43 4}D0.00 %02~.~5 3953.~6 ~]JRS~ 22Vi6TI]X ~ZIMOTq 3:G fliN 3:3 43 37 43 58 44 11 44 38 ~3 16 45 27 a5 ~0 ~3 35 46 5 S 59 2~ S 6~ 5~ S 70 45 S 71 33 S 72 1~ S 73 1~ S 74 3 S 7~ ¢~ S 75 29 S 75 S 46 46 43 44 44 4~ 43 42 42 43 43 ~3 ~4 43 4~ 45 45 ~5 ~5 44 44 43 39 30 13 I1 34 9 ~2 15 35 0 7 1T 10 57 Z5 26 37 26 57 13 !5 22 S 75 3~ :_ S 77 1Z E S 77 S 75 2:J S 77 31 S 7~ 375255 S 75 25 E S 72 31 E S 71 9 E S 71 3~ S 5~ 12 E S $~ ~l ~_ S 70 ~1 E S 72 1~ E S 73 22 E S 74 ZO S 75 1] E S 73 15 S 7] 35 S T~ ~2 ~ S 75 51 E S 75 55 E S 77 S 7~ ~] E S 7~ 1] E S 75 S 75 50 ~ S 75 5090.00 %094.}4 %023.04 5100.00 4152.59 %091.99 5Z00.00 4231.55 4169.85 58~0.00 %303.10 %232.10 5¢30.03 %374.~7 %303.87 5530.0~ 4446.~4 ~373.44 5500.D~ %518,31 %447.31 5700.00 4591.39 %520.39 53~0.90 %665.}6 ~59~.96 5~]0.00 4740.11 ~569.11 51~0.33 %885.53 ~81%,53 6~00,~0 %958,27 %887,27 6300.00 5030.28 %959.28 6~20.90 5102.12 5031.12 6520.00 5174.10 5103.10 6520.0~ 5245.~5 5175.05 57~0.]0 5317.71 5245.71 6820.]D 5389.50 531~.60 6900.00 5461.38 5390.38 7]]0.]~ 5532,%1 5%61.41 7100,00 5603,12 5532,12 7200.00 5673.58 5502.;3 73D0.00 57~3.?0 5572.70 7%00.00 5813.49 374!.49 7500.00 5883.%8 5512.45 7530.33 5953.B9 5882.8~ 7100.OD 5024.~8 5953.~8 7800.00 5097.22 5025.22 7900.09 5169.~0 509~.90 ~GE 2 D~T: 3~ SUQVEY: 12-;:B-85 <:LLY BUSHIX8 ELEVATION: 71.00 PT :NSIXEER: T. UR&M V:RTI'AL OOS_EG R6'T6N SECTION SEV:RIT¥ ~EET DES/lC] FEE 1594.9~ 9,53 590, 1754.23 9,53 524. 1833.76 3,58 547. 1903.60 3.67 570. I973,90 3.95 592. 20~&.76 9.72 713. 2115,74 9.62 733. 2185.39 3.70 752. 2238.28 3.4~ 770. 2329.83 3.45 7~8. 2401.55 0.50 ~05. 2473.51 9.45 ~21. 2345,28 2.73 337. 2514.94 3.73 353, Z68~.00 0.69 ~59. 2753.13 1.15 38~. 2821.77 1.05 ~97. 2889.32 2.30 911. ~955.57 9.89 923. 3022.45 2.97 ~45. ~093.99 0.1~ ~58. 3159.57 D.51 990. 322~.28 2.2¢ 1912. 3297.65 1.50 I~35. 3357.21 1.37 1362. 3436.59 1.05 1084, 3505.93 ].93 1104. 3575.51 0.75 1124. 36~%,73 1,05 1142. 3714.10 1.87 1161. 3784.36 0.77 1131. 3~5~,86 1.1¢ 1200. 3~25.49 1.OD 1218. 3995.30 3.99 1235. ~057.26 3.91 1251. %137.89 9.75 1265. ~207.99 1.98 1279. ~277.74 1.85 1295. ~345.49 3,55 1312, ~41%.77 0.3& 1328. 3UL&R C33RDI~ATES q]RIZ. DE~&RTURE SSJTq E&ST/,~:ST DIST. &ZI~IOT~ T FEET F_:~T 14 S 1585.20 E 1593.00 S 25 ~ 1550 1~+ ~ 1764 27 S 69 16 : 50 S 1715.65 E 1833.80 S i8 S 1781.73 E 1903.63 S 69 23 E 02 S 1848.63 E 1973.91 S 69 23 E 08 S 1916.40 E 2345.77 S 69 35 09 S 1984.67 E 2i15.74 S 69 43 E 24 S 2053.45 E 2186.90 S 69 52 : 50 S 2122.75 5 2253.32 S 26 S 2192.5% 5 232~.~3 S 70 13 27 S 2262.71 E 2%01.74 S 70 24 E 57 S 2333.37 E 2%73.81 S 70 36 E 58 S 2~04.0i E 2543.7~ S 70 47 E B5 S 2472.25 E 2515.56 S 73 56 E %9 S 2540.11 E 2584.80 S 71 6 E 17 S 2603.3) E 2754.17 S 71 16 E 54 S 2675.63 E 2823.11 S 71 27 E 36 S 2743.35 E 2990.93 S 71 36 E 27 S 2807.~2 E 2~57.38 S 71 42 E ~7 S 2872.50 E 3324.41 S 71 45 E 29 S 2937,50 E 3392,.~8 S 71 45 E 15 S 3002.55 E 3161.60 S 71 44 E 77 S 3057.44 E 3230,31 S 71 43 E 26 S 3131.97 ~ 3!99.58 S 71 39 E 38 S 3197.22 E 3369.10 S 71 37 E 44 S 3263.03 E 3~+38,51 S 71 36 98 S 3329.37 E 3507. ~4 S 71 33 :-._ 37 S 3395.38 E 3577.55 S 71 40 50 S 3463.47 E 3547,05 S 7i 44 14 S 3530,55 E 3716,58 S 71 47 50 S 3597,93 E 3785.95 5 71 49 E 95 S 3665.94 E 3357.61 S 71 51 E ~0 S 373q,.55 E 3~28.~5 S 71 55 54 S 3803.87 E 3~99.53 S 72 0 E 24 S 3873.77 E ¢370.83 S 72 5 E 74 S 3943.71 E 4141.~5 S 72 12 E ~8 S 4013,35 E 4212,35 S 72 19 E 23 S 4081.91 E 4282.47 S 72 23 E 25 S 4148.92 E ~+35!.50 S 72 26 E ~3 S 4215.35 E 4420.06 S 72 30 E ~CO ~L~S~, INC. 3I-¢ KJ~ARJK N3RTH SLOPE~aL~SK~ CgMPUT~TI]~ D~TE: 1Z-M~R-B$ INTE~]L~TE] VaLJES =DR EVEN 100 TRUE SJS-SE~ ME~SURE] V=RTIC~L VERTi'~L ]£PTt DEPTq 3E~FH 8000.33 5242.~8 5171.43 8100.00 5315.18 5244.18 8Z30.~0 5338.35 5317.06 8300.03 5451.Z1 5390.21 8400.03 5534.38 5453.38 8~ZO.OD 5549.01 $47~.01 C]JRSE V:RTiS~L ]EVi~TI]N aZIMJTH SECTION OEG q!N DES MIN ;EET 43 Z9 S 75 1~ E $~83.13 43 9 S 75 5~ E ~551.Z8 43 7 S 75 5~ E ~619.ZO 42 58 S 75 5S E ~685.8~ 42 5~ S 75 53 E ;755.47 42 Si S 75 53 E ~767.9~ m::T_~ D3S_EG S=V:RITY 3E3/109 ].~ 3.75 O.O0 0.03 RECT6 NORTH FE 1345 1351 1375 1392 1507 1~19 ~TE 3F SURVEY: 1Z-:ES-SS ELLY BUSqZNS ELEV~T[3N: 71.00 F ENGInEeR: T. URAM ] OEPTH SUL~R CO3RDI~ATES HDRIZ. 3ED~RTURE SOUTq E&ST/WEST DIST. AZIMUTH T FEET FE:T D:S MIN aZ S 428Z.34 E 4488.72 S 7Z 33 E Z5 S 4349.14 E 4557.20 S 72 37 E SO S 4415.~ E 4525.~8 S 7Z 41 E 35 S 4482.29 E 4593.48 S 7Z 44 E 51 S 4548.57 E ~761.45 S 72 48 E 51 S 4551.g5 E 4775.06 S ?Z ~g E CDMPJT~TI]'~ D~ITE: 12-M~R-85 m~,SE ~ ~'0 AL&S(A, IqC. 3I-4 KJP~RJ~, N]qTH INT:qPDLAT:g VALJES TqU: SJ~-S:& ~E~SURE2 ~:RTI-&L V=qTi'~L DEPTH 2=PTq DEPTH 0.00 0.00 -71.00 1300.32 999.71 925.71 2000.03 1~40.99 1~69.99 3030.3~ 2677.77 2505.77 49]0.~3 33~8.%0 3317.40 5000.03 ~09~.04 ~323.04 6330.30 ~812.~9 ~741.89 7000.93 5532.~1 5451.41 8300.~ 5242.~8 5171.48 8~ZO.D3 5549.01 $~/~.01 C]JRS; ]EVI%TIg~ AZIMJTt ]~G qlN DES ~Iq :VF-N V=RTIC S=CTI ~,.. -- _ O. 320. 991. !401. ~090. 378~. ~4~3. ~757. 100) ~L T O0 83 59 95 55 3~ 13 FeET 3: SEV:~ITY 3:3/103 3.09 2.51 0.31 P .53 3.53 O.l~ 2.77 0.69 DATE OF SURVEY: 12-F:B-B5 KELLY BUSHIN$ ELE~TIDN: ~1.0~ £NGIN=_$2: T. URA~ MEiSUR R6'T&N NO~TW/ 5. 101. 346. 500. BO5. 1131. 1345. 1410. 3ULAr< CODRDINAT~S HDq!Z. SOUTH EAST/W--ST 9IST. AZIMUT~ T F:ET FE_:T D:~ MI~ 33 N 0.00 E 0.00 N 0 0 ~6 S 13.89 E 14.93 S 6~ 33 3B S 304.57 E 321.00 S 71 35 5~ S 92~.01 E g91.5~ S 69 32 14 S 15q5.23 E 1595.00 $ 69 15 17 S 2262.71 : 2~01.74 S 70 24 29 S 2937.50 E 3~Z.9~ 5 71 ~5 50 S 35~7.~3 5 3786.96 S 71 ~9 ~2 S 4282.34 $! S a561.95 E ~775.06 S 72 ~9 A:~20 ~,L~.S<,~, I~C. 3I-4 KJ~ARJK N]RTH SL3~E,AL~SK~ C3MPUT&TI]~ D~TE: 12-MAR-85 D~TE 3~ SJRVE?: 12-F53-35 q~LLY BUStlING ELEVATION: 71.00 ENSI~EER: T. UR4M INT:RPgL~T:D V~k.J:S :IR :?EN 100 F_~ET O: SUB-SEek DEPTH ME~SgR:] VERTICAL VERTI'AL S]J~SE V:~TI'AL D9~' EG ]EVIATi]~ .,AZiHJTt 5:CTION SzV:~IT¥ lEG ~I~ DES 0 0 N 2 J 5 0.00 O.O9 0 4 S B$ 55 ,~ 0.14 0.5! 0 1 S 73 53 E 0.09 ~.21 0 7 S 3~+ 45 W 3.13 9.15 0 7 S 57 ~5 4 -0.03 3.17 0 7 S 13 1 = -3.05 J.3l 0 %6 S 6~ 41 E 9.49 1.23 1 ~5 S T~ 13 ~ 2 63 '} 17 1 ~3 S 72 1~ ' 5.40 3.11 I 59 S 73 43 ~ ~.56 3 11 14 17 20 23 25 29 30 S 71 27 E 12.9a 2.95 5~ S 70 17 E 21.40 2.45 %2 S 70 9 ~ 34.1) 3.51 02 S 71 35 : 52 05 ~ 9~ 15 S 71 33 ~ 7~.90 !.55 3~ S 70 3 ~ 103.26 3.9~ ~1 S 5~ 52 : 138.07 26 S 71 45 E 179.11 2.75 : 224.7~ ~.9P 50 S 72 ~ = ~ _ 59 S 73 5~ ~ 279.09 2.35 32 35 ~5 34 S 7~ 53 ~_ 339.73 2.35 %7 S 70 31 E 407.35 3.25 36 S 69 13 = 48~.$4 2.53 %2 S 67 32 ~ 573.34 3.6~ ~3 S 57 25 E 67~.36 ~.3~ 56 S 57 Z2 E 777.24 9.85 1 ~ 57 53 : 891 21 0 42 56 S 68 11 ,: 98~.60 0.39 35 S 5~ 27 E 1037.37 ~.51 12 S 63 ~7 ~ 11~.69 3.23 44 43 43 43 44 44 45 45 1 S 59 Z E 123~.22 0.31 36 S 58 5~ = 13~8.65 3.22 10 S 58 55 ~ 1~85.55 2.59 53 S 5~ ~ E 1593.25 29 S 59 21 E 157~.41 3.63 5~ S 70 $ ; 177¢.35 3.51 19 S 71 ~ E 1871.36 0.69 55 S 72 15 ~ 1959.91 1.01 1) S 73 33 E Z070.52 D.62 37 S 74 39 ~ ~171.39 ~.6{ 0.09 0.30 -71.00 71.33 71.00 3.00 171.00 171.00 100.00 !71.00 271.00 203.00 371.~D 371.00 303.00 ~71.39 ~71.00 ~03.00 571.31 571.00 503.00 571.03 671.30 500.00 771.07 771.30 733.00 ~71.11 871.90 ~O0.O0 971.22 971.00 909.00 1971.5~ 1071.90 1033.00 I172.~3 1171.00 ii00.00 1214.00 1271.00 1ZO0.O0 1376.5~ 1371.00 1300.00 1~80.55 1~71.00 1400.00 1586.~5 1571.30 1500,00 1594.19 1671.30 1500.00 1~34.5~ 1771.00 1918.~5 1871.00 1803.00 2335.¢B 1971.00 1903.00 2156.2% 1071.20 2033.00 2232.78 2171.00 2100.00 2~16.37 2271.00 ZgOO.O0 255~.57 2371.00 1302.09 2732.10 2471.00 2~00.00 2~6.~1 2571.30 2503.00 2~90.27 2671.00 2603.00 3133.69 2771.00 2700.00 3276.06 2871.00 2800.00 3~17.35 2971.00 Z~O0.O0 3558.89 3071.00 3009.00 3598.$~ 3171.00 3100.00 3337.95 3271.00 3200.00 3~76.33 3371.D0 3300.00 4114.53 3471.30 3400.00 4253.91 3571.00 3503.00 4394.35 3671.00 3500.00 4536.32 3771.30 3700.00 4578.~3 3871.00 3800.00 5(JLAR CD3RDI~TES H3RIZ. SOUTq :~ST/WEST DIST. T FEET F~:T 3EP~RTUR AZIMUTH . O. O. O. 9. 3. 1. !. 2. 3. 90 N 0 90 : O 31 S 3.03 ~ 0.31 ~8 S 3 01 W 0.~ ~0 S 3.01 W 0.~0 52 S 0.22 W 0.55 70 S 0.31 W 0.76 05 S 0.13 '~ 1.05 73 S 2.15 E 2.77 55 S ~.~2 E 5.45 ¢'~ S 7.3~ ~ 3.5~ S 5 18 E S 1 47 ~ S O 53 ~ 22 55 ~ S 23 46 N S 7 8 : S 62 t - 7. 12. 17. 25. 34. 45. 59. 74. 89. ql S 12 32 : 12 94 57 S lg.'~ ~ 21.~+0 04 S 32.00 E 34.19 ~'g S 4~3.8~ E 5!.05 37 5 70.5~ E 7~.~1 30 S 97.~1 5 103.28 53 5 130.00 E 138.07 71 S 157.52 ~ 178.13 13 S 212.22 ~ 224.52 74 S 26~.39 ~ 27~.19 S 6~ S 6~ S 70 S 70 S 70 S 70 S 71 12 0 22 54 26 36 24 44 15 106 · 128. 155. I~7. 225 · 255. 305. 344. 382. 96 S 322.7:) E 339. -)3 26 S 395.B3 E ~07.59 15 S 459.55 E ~85.04 56 S 541."~3 E $73.~7 21 S 635.3~ E 574.41 ~2 S 730.55 E 777.25 ~6 S 825.57 E ~81.21 08 S 922.53 E ~84.'$0 03 S 1018.05 ~_ 1~87.38 93 S 1112.4& E 1188.71 S 71 40 E S 71 39 E S 71 20 E S 70 5~ E S 72) 24 E 5 6~ 59 E S 69 32 E S 59 2f ' s692t ~55 · ~90 · 525. 550. 594. 527. 559. 590. 729. 748. 10 S 1205.25 E 1289.25 70 S 1299.09 E 1383.58 86 S 1390.~.7 E 1485.59 ~5 $ 1480.78 E 1583.29 32 S 1569.72 E 1575.z+5 72 S 1659.55 E 177~,.~0 37 S 1751.10 E 1371.~0 81 S 1844.~2 E i~69.92 ~5 S 1941.13 E 2070.52 28 S 2038.93 E 2171.90 S 69 S 69 S 6) S 59 S 6) S 6~ S 69 19 18 17 16 15 16 21 28 38 50 4~C0 ~L4$<A, i~C. 3I -4 KJ~ARJ{ N3~TH SLJ~E,4L~S<~ CO~IPdT~TI3~ D~I'E: 12-MAR-85 DATE O,= SJ'~lVEY: 12-~:3-~35 KELLY BUSqI~3 :LEV4TI3N: ENGINEER: T. UR~M INTZ~PDL4TED VALJES FDR :VE~ 100 nE=T O: SU{-SE& DEPTH C]J~S= V=RTIS4L 3EVI~TIDX 4ZIMUTH 5:CT!3N }EG qiN OEG MI~ mEET 45 SS S 75 35 E 227~..2~ 46 17 S 75 25 f 2377.56 45 %0 S 77 1% E 2482.0'~ 44 22 S 75 23 E 25~13.90 44 12 S 77 28 E !530.27 44 3 S 7~ ~,9 ~ 2775.63 ~2 35 S 77 15 E 2~70.:37 41 ~A S 75 21 E 2950.03 43 15 S 71 27 E ~051.35 ~3 15 S 71 35 ~ 3145.~2 43 %3 S 53 ~5 E 32~+0.42 44 6 S 69 51 = 3337.01 ~3 %~3 S 72 7 c 3433.62 44 15 S 73 43 E 3530.26 43 35 S 73 7 E 3626.'34 4~ 32 S 73 S ~ 3723.S5 ~5 1 S 74 g E 3~22.95 45 25 S 75 49 ~ 3922.87 45 f3 S 77 17 E ~029.06 45 31 S 7~ 3~ E ~125.39 TRUE SJE-SZA MEASURED VERTI'AL VERTI'AL ]EPT't DEPTH 3E~TH SzV=RITY NDRTH/S 9.51 774.5 3.63 799.5 3.3~ 323.5 1.10 546.5 3.59 ~65.6 3.93 ~.85 907.5 1.13 ~29.3 1.35 955.5 9.5! ~5.~ 1.91 1317.1 1.3~ 1352.1 i.ii i3~3.5 ~.95 1111.~ 1.34 1137.9 1.23 1163.9 1.09 1192.1 1.01 121.9.2 0,79 1141.5 1.18 1263.2 ?1.00 4822.39 5971.00 3903.00 4955.51 ~071.00 gOOO.OO 5111.93 ~171.00 ~103.00 5255.23 4271.00 ~ZO0.O0 53~4.50 %371.00 ~300.00 5534.1~ 4471.09 ~403.00 5572.%1 %571.00 ~500.03 5~05.7% %671.~0 %503.00 5~2.32 ~771.00 4700.00 6079.91 ~871.00 %503.00 6217.5g ~971.30 %93~.00 6356.53 5071.00 5000.00 64~5.73 5171.00 510D.O0 653¢.B8 5271.20 5200.00 5774.21 5371.20 5300.00 6~13.~ 5471.00 5400.00 7054.55 5571.D0 5500.00 7196.31 5671.00 5603.00 7339.11 5771.00 5700.00 7%32.13 5871.30 5800.00 7524.13 5971.00 5903.03 7763.~5 5071.00 5000.00 7931.52 5171.00 5100.00 8339.2~ 5271.]0 5200.00 8176.5~ 5371.~0 5303.00 8313.38 5471.00 5~03.00 B$ZO.O0 55~9.31 5~7~.01 dL&q CDDROI~TES HD~IZ. OE~&RTU: 3UT4 E4STtWEST DISt. ~Zi~UTH FEET FE:T 3=3 MIN 2135.35 E 2274.34 2239.22 E 2377.72 2341.71 6 2482.37 2441.89 E 2584.45 2536.¢~ E 2691.06 2531.71 E 2777.77 2725.25 E 2~72.~2 2~12.25 E 2961.35 2893.98 E 3353.33 2989.43 E 3147.33 5 S 3073.76 E 3242.~3 9 S 3158.79 E 3338.91 3 S 3250.20 E 3%35.54 8 S 3352.75 E 3332.31 5 S 3445,19 E 3529.21 0 S 3539.60 E 3726.05 5 S 3535.10 E 3~25.52 5 S 3732.01 E 3925.~2 8 S 3831.17 E 4027.42 6 S 3931.30 E 4129.25 2.05 1283.,31 S 4030.02 E 4229.32 3.92 1306.13 S 4124.;30 E 4326.55 3.37 1329.18 S 4215.55 E 4~21.10 3.57 1351.7~ S 4308.50 E 4515:57 1.OD 1372.99 S 4400.25 E 4609.~+8 3.00 11394.12 S 4491.17 ~. 4702.57 3.00 1%10.61 S 4551.95 E 4775.06 ST0 S 70 20 S 73 37 S T~ 52 ! S 71 5 S 71 20 1 S 71 34 1 S 71 s71 S 71 ~.-, i S 71 43 ~ S 71 37 ~ S 71 36 ~ S 71 39 S 71 43 ~ S 71 47 i S 71 50 i S 71 55 ~ S 72 2 i S 72 11 i S 72 25 ~ S 72 30 1 S 72 34 i S 72 40 S 72 49 i 31-4 KJD~RJq NDRTH TOP B6SE TOP B6SE ~BTD TD M,a, RK ER KdP~RUK C KJPARJK A CD~oUT6TZ]~ INTER?OL~TED V6LJES =OR ~;ASJR:D Dz~TH~ 3ELSW KS 7350.00 7387.00 ?g53.30 ~310.00 ~20.90 O~TE: 1Z-M~R-]$ ]RI3IN: TV] :ROM K5 5133.55 5160.45 5215.~4 5332.72 5~63.53 55~9.01 195' ;SL, SJ5-S:& 5362.55 5399.g5 51a4.54 5261.72 5397.53 5978.31 3~TE 3F SURVEY: 12-VES-B5 KELLY BUSqIN3 ELEV~TI3N: ?I.00 F =NGIqEER: T. U~ SJ 122' ~WL, SES 31, r13X, RgE, UM R:CT~NSUL~R 'O]R]IN~TES ~SRTH/S]UTq E~ST/~EST 1320.59 S ~182.25 1326.75 S 4206.$9 1339.35 S ~257.51 1354.95 S 4355.12 1393.39 S 44~.~3 1~I0.51 S ~551.g5 31-4 KJP~RJ~ N3~TH SLOPE,4~4$K4 C3MPUT~TI]~ Onto: D&TE 3F SJR¢:Y: 12-$:B-B5 <2LLY ~USHING ELE~ATIDN: :NGINEER: T. 71 M4qKER ]'DP B~SE ]'DP 5D~SE PBTD TO <UP~RJK ' KU~4RJq C KUD~RJK A =IN4L WEL~ LD~TI]N ~T q~SJ2E] 35~TH ~5L3,~ K5 7850.30 7~87.00 7~53.J0 5124.00 ~310.33 ~20.OO TD: ]~I31N: TVD K~_ $133.55 5160.45 5215.64 5332.72 546B.53 5549.01 SJR~a'E LOC~TZJN IT 295' =SL, 1ZZ' :WL, SEC 11, T13N, 295, ~SCT~NGULaR 200RD!N~TES SJB-S;~ NOqTH/SDUTq E~ST/~:ST 5362.55 1320.5~ S 41B2.25 5JR9.~5 1326.75 S 4225.$9 51~,54 13~9.35 S ~257.51 5251.72 13~4.95 $ 4355.12 5397.53 1393.59 S 4488.93 5&Tg. D1 1~10.61 S 4551.95 ~iE~SjRE] 84ZO.O0 TRJE ~ERTiSAL $54~.J1 SJ3-S:& V~RTi'4L 5~7g.31 qDql['JNr~L DEPARTURE 9IST4NC~ 4ZI~UTq FE~T J~$ MIN 47T5.05 S 72 49 ~ SCHLUMBEROER 0 1 RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3I-4 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE 00007139B WELL 3I-4 (295'FWL, 122'FWL, S31, T13N, R9E) HORIZONTAL PROJECTION NORTH 4000 3OOO 2000 ! 000 - 1000 -2000 -:9000 -4000 -2000 PIE:ST REF 0000'71333 SCRLE = 1/1000 IN/FT - 1000 0 1000 2000 5000 4000 SO00 6000 £1:~T WELL 3I-4 (295'FSL, 122'FWL, S31, T13N, R9E) VERTICAL PROJECTION 2gO. -2000 - 1000 0 0 1000 2Onn 3000 :; ;';:::' ~ :~:x~:::: i~:::': :zx~:::: ~ ~;*~:_~ ~-,~++ ~.----7~-': :'--:z::]i': cz.c:',::':": ..... ~ ; ;-F T' 7'! .... ;:::.TTT% TTTTI'T'T .:?'~:':--L:.:.-:--;-:.-: :*:-; t :~-~- · ' ~ * ' * .... "~ .......... ~ .................... t ..... ~-~,--~ .... ;-~,;. . .'. ~ , . . i . , - ;: ~';2~'''~Z Z~';' 7 ~': ....... }--~ - f- ;. :.-;--{- ~:; :-::;..:_'L';. ~";..L~T: :: .......... ~ ...... t'*~ ........... ~ ............... T'"~ ..... · .... T ' ~" ~ .... ~ .................. ~'~ ' : ....[ ~1 ' '~ ....., ~ ~ ' : ; : : ' I ~ , ~ , , , , , ~ , , ~ , ,. Z..;. ;'.. ;.T']. 7; ~;; :7;' ":'~ ........ ~'~ .... t .......... ~: ........... : ...... ~.: .......... ~': ;";"r 7~': ;':: ~':'~ f ~":-;': ': ~'~ ~ t':"; ;-;-':; ;'; ~" ~-~--~- ;-- ;-; :-::-f :-:';-: :-~-: :-: 7'~ 7'~ ,"~'7~'~--';'TT'T r ~'~ :'~ .... ~'~n~T~'7: T 7T 7'~' '~ :' '' ';' ~: ....... ~ :' ~': ''~' ~'': ~''~ '.:: h:'.:.: .~':' :-.::: ::.. :~:_: ' [":' .: -: ._: -- :.--;- ::.: T ~"*-*'" * ~ * ~ .... ~ ?-'*' *' ~*' ~ * '*-q-~-4-*-. .... .-~-...~ -'*-~-*~-'-*~*-~*---~ 4 ~.. ~. 4 · . ~ . ' ~ ' : ' ' · ~ ~ ' ~~ ~ ~ ~ i , , / '' ' ' ~ ' ' ' ' ..... t [ ~ ~ ....... ~"''t ~ ..... * ....... ~" * ...... t"~'~': ~ ~ ~ ~"~- ~ .... ~ ..... : · ~ ~ ~ 7~ ',' 7~ ~'~ '~ ~'~ ~'~ ~'r ~"' ':: :-;:'h :-:--:: :::-: :"::~':'::.-: ;: ~ ' ' / ............... ~"-' ........ ............ :' ~ ........ ~'~ ~ ~'~'7' ~ PROdECTION ON VERTICAL PLANE ! 10. - 2gO. SCALEO IN VERTICAl. DEPTHS HORIZ SCALE = 1/1000 IN/FT EXACT RAO!US OF CURVATURE METHOD TIE-IN LOCATION MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE NORTH DISTANCE EAST BOTTOM HOLE COURSE LENOTH COURSE AZIMUTH LOCATION MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE SOUTH DISTANCE ERST 0.0 FT 0.0 FT 0.0 FT 0.0 FT 477S.3 FT 307.2 OEO 8420.0 FT 6S49.! FT 3430.8 FT 4S62.0 FT REF 000073333 Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WE~L NAME AND Reports and Materials to be received by: ,~--~-- Date Required Date Received Remarks Completion Report S~ples _ Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Drill Stem Test Reports , ro uction epor s Digitized Data STATE OF ALASKA A~'~SKA OIL AND GAS CONSERVATION COMMIS~ON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4, Location of well at surface 295' FSL, 122' FWL, Sec. 31, T13N, R9E, UM At top of productive interval 1026' FNL, 1499' FEL, Sec. 5, T12N, R9E, UM At effective depth 1099' FNL, 1192' FEL, Sec. 5, T12N, R9E, UM At total depth 1116' FNL~ 1119' FEL~Sec. 5, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8420' feet 6549' feet Plugs (measured) 6. Datum elevation (DF or KB) 71' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number ~ _ 31-04 /"/~ 9. Permit number/approval number 85-310 / ~'-~~ / I 10, APl number 5o-029-2151 7 I11, Field/Pool Kuparuk River Oil Pool Effective depth' measured 8 31 0' true vertical 6469' feet Junk (measured) feet Casing Length Size Structural Conductor 9 9' I 6" Surface 3888' 9 5/8" Intermediate Production 8376' 7" Liner Perforation depth: measured 7986', 7992', true vertical Cemented Measured depth True vertical depth 255 Sx CS II 99' 99' 1500 Sx AS III & 391 9' 3326' 320 Sx Class "G" 300 Sx Class "G" 8 4 0 0' 6 5 2 6' 175 Sx AS I 8006'-8046', 8116'-8122' MD 6232', 6236', 6246'-6276', 6327'-6335' TVD Tubing (size, grade, and measured depth) 2 7/8", 6.5# J-55 EUE Tubing with tail @ 7902' Packers and SSSV (type and measured depth) '"'~¢'-;',~ {i~] ~ d;~$ O0~ C,O~i~.~L~;!~,~ Camco HRP-1-SP pkr ~ 7832', Camco TRDP-1A-SSA SSSV ~ 1802' ~, 13. Stimulation or cement squeeze summary , Refracture stimulated the 'A' Sands interval with 20/40 mesh proppant. Intervals treated (measured) Kuparuk 'A' Sands Treatment description including volumes used and final pressure Pumped 111,169# of 20/40 mesh proppant and 1341 bbls of gelled diesel @ 3600 psig 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 961 355 0 1080 159 1337 535 0 600 164 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. Form 1'0-404 Rev 1~/15/88 SUBMIT IN DUPLICATE A'RCO Alaska, Inc.~-~{) Subsidiary of Atlantic Richfield Company WELL 'qTRACTOR REMARKS WELL SERVICE REPORT FIELD - DISTRICT- STATE OPERATION AT REPORT TIME [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather}TemP.Report oF Chill Fact°r 1 VisibilitYoF miles ]Wind Vel. .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION i.' Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 2. Name of Operator FOR SUNDRY APPROVALS Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing_ Variance _ Perforate _ Other 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 295' FSL, 122' FWL, Sec. 31, T13N, R9E, UM At top of productive interval 1026' FNL, 1499' FEL, Sec. 5, T12N, R9E, UM At effective depth 1099' FNL, 1192' FEL, Sec. 5, T12N,R9E, UM At total depth 1116' FNL, 1119' FEL, Sec. 5, T12N, R9E, UM 8420' feet Plugs (measured) 6549' feet 831 O' feet Junk (measured) 6469' feet 6. Datum elevation (DF or KB) RKB 71 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 31-04 9. Permit number 85-310 10. APl number 5o-02~)- 2151 7 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Length Size Cemented Measured depth 80' 1 6" 255 Sx CS I 99' 3888' 9 5/8" 1500Sx AS III & 391 9' 320 Sx Class G 8376' 7" 300 Sx Class G 8400' 175 Sx AS I measured True vertical depth 99' 3326' 6526' 7986' MD, 7992' MD, 8006'- 8046' MD, 8116' - 8122' MD true vertical 6232' TVD, 6236' TVD, 6246' - 6276' TVD, 6327' - 6335' TVD 12. BOP sketch Suspended Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Tubing (size, grade, and measured depth 2 7/8" J-55 set at 7902' Packers and SSSV (type and measured depth) HRP-1 @ 7832', Camco TRDP-1A-SSA @ 1802' 13. Attachments Description summary of proposal _ Detailed operation program X.~ Refracture stimulate the 'A' Sand interval (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: July, 1989 Oil X Gas m 16. If proposal was verbally approved Name of approver Date approved Service Producer 17. I hereby certify that the foregoing is true and correct to t,b~ best of my knowledge. Signed .,-/¢5~)O..-~-"~ /d /~tcc~..~'0-~c&,',' Title ¢.~.~.4..,/~.-~ ~___.~,~.~ ~/ FOR COMMISSION USE ONLY ~/ Conditions of approval' Notify Commission so representative may witness Plug integrity m BOP Test_ Location clearance__ Mechanical Integrity Test m Subsequent form require ~,nproved C~opY "' Returne~. ~er IApproval No. , Approved by the order of the Commission ORIOle's!. ~'"'~ED BY LONNI[': C SMITH Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Kuparuk Well 31-04 Application for Sundry Approval May 22, 1989 . . . The static bottomhole reservoir pressure is estimated to be 2600 psig based on data taken 2/19/89. No workover fluids will be used during the stimulation. No BOPE is required. The treatment will be pumped through a surface manifold. 'A' Sand Refracture Stimulation Procedure Kuparuk Well 31-4 . . , , , , Pressure up 2-7/8" by 7" annulus such that the final pressure during the fracture treatment will be 3500 psig. RU fracturing equipment and tree saver. All fluids should be maintained at 70° to 90° F on the surface. Pump 100 bbl PREPAD containing 40 lb/1000 gallons silica flour at 20 BPM. Shutdown for ISIP and to check perf friction. Leave well shut-in for five minutes to allow pressure to stabilize. * Check tank straps against flow meter. Correct for flush volume after frac. Pump fracture treatment per the attached schedule. * Pump rate should be 20 BPM. Use silica flour in the PREPAD AND PAD ONLY at 40 lb/1000 gallons. Slurry and flush stages should contain NO silica flour. The gelled diesel prepad, pad and slurry stages should contain an 8 hour breaker. The flush volume should contain Iow temperature breaker. The frac schedule may be approximated by smooth ramp-ups using the vendor's computer. * Expected WHTP = 4021 psig (during pad stage) based on: Frac gradient A Sand TVD (mid perf) Tubing Tail (MD) Tubing friction 0.66 psi/ft TVD 6209' TVD (Tbg Hgr) 7855' MD (Tbg Hgr) 270 psi/1000 ft 7. Bleed down annulus pressure to 500 psig after the job. WELL 31-04 FRAC PUMP SCHEDULE CLEAN VOLUME PROPPANT DIRTY VOLUME CUMULATIVE STAGE HITS STAGE (B B L) (POUNDS) ( B B L) DIRTY VOL (BBb) PERFS @ (BBL) BREAKDOWN 1 00 0 1 00 1 00 4 9 SD FOR ISIP (30 MINUTES TO ALLOW LEAKOFF OF PREPAD AND PROVE FLOWMETERS) PAD 800 0 800 900 149 SLURRY STAGES 2 PPG 36.8 3088 40 940 949 4PPG 34.0 5713 40 980 989 6 PPG 94.9 23915 120 I 1 00 1029 8 PPG 177.4 59606 240 1340 1149 10 PPG 27.8 11676 40 1380 1389 FLUSH 46 0 4 6 1426 1429 TOTAL 1 31 7 1 03998 1426 VOLUME TO PERFS (BBL) = 49 BBLS PROPPANT = 20/40M CARBOLITE PUMP RATE = 20 BPM I ,BREAKDOWN = GD + 40 LB/1000 GAL SILICA FLOUR + 8 HR BREAKER ~PAD = GD + 40 LB/1000 GAL SILICA FLOUR + 8 HR BREAKER SLURRY = GD, + BREAKER (NO SILICA ,FLOUR) LO TEMP BREAKER DURING I'AST HALF OF FLUSH ESTIMATED T,REATING PRESSURE (DURING PAD) = 402! psi 5/22/89 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal # 5943 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. 3I-3 3I-4 3J-J0 3J-11 3I-8 3I-7 3I-5 3N-2A CET 2-12-86 6100-7610 CET 2-12-86 6300-8280 CET 2-11-86 5686-7181 CET 2-11-86 6084-7520 CET 3-8-86 7400-9176 CET 3-8-86 4950-7238 CET 3-7-86 6100-9948 CET 2-15-86 7315-8761 Receipt Acknowledged: DISTRIBUTION: Drilling Mobil NSK SAPC Unocal Vault (film) ARCO Alaska, Inc. Is a Subsidiary of AllanllcRIchfieldCompany STATE OF ALASKA ALASK~r.~OIL AND GAS CONSERVATION COMMi'~%ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other 2. Name of Operator ARCO Alaska, Inc. Stimulate [] Plugging [] Perforate o m p 3. Address P.0. Box 100360 Anchorage~ AK 99510 4. Location of well at surface 295'FSL, 122'FWL, Sec. 2,1, T13N, R9E, UM At top of productive interval 1026'FNL, 1499'FEL, $ec.5, T12N, RgE, UN At effective depth 1099'FNL, 1192'FEL, Sec.5, T12N~ RgE, UN At total depth 1116'FNL~ 1119'FEL~ Sec.5~ T12N~ R9E~ UN 11. Present well condition summary Total depth: measured 8420 feet true vertical 6549 feet Effective depth: measured 831 0 feet true vertical 6469 feet Pull tubing [] 5. Datum elevation (DF or KB) RKB 71 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Approval number 75 9. APl number 50-- P?q-? 1 51 7 10. Pool Kuparuk River Oil Pool Plugs (measured) None Junk (measured) None Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" Surface 3888' 9-5/8" Production 8376' 7" 255 sx CS I I 99 'MD 1500 sx AS II I & 3919'MD 320 sx Class G 300 sx Class G & 8400'MD 1 75 sx AS i 99'TVD 3326'TVD 6526'TVD Perforation depth: measured 7986 ' MD 7992 ' MD true vertical 6232 ' T V D 6236' TVD 8006'-8046' MD 8116'-8122' MD 6246'-6276' TVD 6327'-6335' TVD ~bing(size, grade and measured depth) 2-7/8" J-55 tbg w/tail ~ 7902' Pal~l~¢r_sla_~dpSSSV (tvpe and measured .dle~ths)$ Pkr (~ 7832' & TRDP- - A SSSV ~ 1802' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History) Daily Report of Well Operations '~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge 0(/ ~ /_~ Associate Eng~ neet Signed ~ , I / jI, I A_.J Title Form 10-404 Rev. 12-1-85 Date Submit in Duplicato ARCO Oil and Gas Company Daily Well History-Final Report Instructions Prepare and submit the 'Final Report' on 'he hrst Wednesday after allowable has been assigned or well ~s Plugged Abandoned or Sold "Final Report" should be submitted also when operations are s.spended for an mdehmte or appreciable length of time On workovers when an Of~lClaJ test is not requ*red upon completion, report completion and representative test data (n blocks prowded The "Final Report" form may be used for reporhng the entire operation ~f space is available Dlst.ct County or Parish JLease or Unit IT~tle Accounting cost center code State Alaska Well no 3I-4 F~eld Alaska Kuparuk River North Slope Borough ADL 25631 Auth or W O no AFE AK0936 Completion Nordic 1 Operator ARCO Alaska, Inc. Spudded or W O begun Complete Date and depth Complete record for each day reported as of 8 00 a m API 50-029-21517 5/21/86 5/22/86 5/23/86 ARCo WI 56.24% Date 5/20/86 I otal number of wells (achve or ~nacbve) on th~s DSt center prior to plugging and bandonment of th~s well I our I Prior status If a W O, I 1915 hrs. 7" @ 8400' 8310' PBTD, Rn'g 2-7/8" compl 9.8 ppg NaCl/NaBr Accept rig @ 1915 hrs, 5/20/86. NU & tst BOPE. RU Schl, perf w/4" gun, 4 SPF, 90° phasing f/8116'-8122' & 8006-8046', RD Schl. RIH w/250 jts, 2-7/8", 8RD EUE AB Mod w/TT to 7902'. 7" @ 8400' 8310' PBTD, Displ'g w/diesel 9.9 ppg NaCl/NaBr Rn 250 its, 2-7/8", J-55, 6.5# EUE 8RD AB Mod tbg w/SSSV @ 1802', HRP-1-SP Pkr @ 7832', TT @ 7902'. Set pkr, tst SSSV & pkr. ND BOPE, NU & tst tree. Displ well w/diesel. 7" @ 8400' 8310' PBTD, RR Diesel Displ well w/diesel. RR @ 0815 hrs, 5/22/86. Old TD Released mg 0815 hrs. New TO Date 5/22/86 PB Depth K~nd of rig 8310' PBTD Rotary Classdicahons (od, gas, etc ) Oil Type completion (single. dual, etc ) Single Producing method Ofhclal reservoir name(s) Flowing Kuparuk Sands PotenI~al test data Well no Date Reservoir Producing Interval Od or gas Test bme Production Od on test Gas per day Pump size, SPM X length Choke size T P C P Water % GOR Grawty Allowable Effective date corrected The above is correct s~:~~~_ tDate 6/04/86 JT,t,e For form preparation and distribution, see Procedures Manual, Section t0, Ordhng, Pages 86 and 87 Drillin~ Supervisor STATE Of ALASKA ALASK..~-,.~lL AND GAS CONSERVATION COMM',.._.,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request,,: Abandon [] Suspend ~ Operation Shutdown '~ Re-enter suspended well .~ Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate Pull tubing ~ Amend order [] Perforate , Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 71 ' RKB 3. Address P. 0 . Box I 00~¢,(1 Annhnrng~ . AK qq51 0 4. Location of well at surface 295'FSL, 122'FWL, Sec.31, T13N, RgE, UM At top of productive interval 1026'FNL, 1499'FEL, Sec.5, T12N, RgE, UM At effective depth 1099'FNL, 1192'FEL, Sec.5, T12N, RgE, UM At total depth 1116'FNL, 1119'FEL, Sec.5, T12N, RgE, UM 6. Unit or Property name K'_'p_~ru!-. River Unit 7. Well number 31-4 8. Permit number 85-310 9. APl number 50-- 029-21 517 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured 8420 true vertical 6549 feet Plugs (measured) None feet Effective depth: measured feet Junk (measured) true vertical 831 0 feet None 6469 Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 255 sx CS I I 99'MD 99'TVD Surface 3888' 9-5/8" 1500 sx AS III & 3919'MD 3326'TVD 320 sx Class G Production 8376' 7" 300 sx Class G & 8400'MD 6526'TVD 175 sx AS I Perforation depth: measured None true vertical No ne Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Well History, Addendum (dated 2/27/86),-Gyroscopic Survey (2 copies) 13. Estimated date for commencing operation June, 1986 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 0 ~ Title Associate Engineer Signed j Commission Use Only (DAM) SA/021 of approval Notify commission so representative may witness I Approval No. Conditions [] Plug integrity [] BOP Test [] Location clearance I Date ,~--8'~(~ . Approved by Commissioner Form 10-403 Rev 12-1-85 the commission Date Submit in triplicab; ARCO Oil and Gas Company Well ~Story- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well ~s spudded or workover operations are started Daily wor~( prior to spudding shouJd be summarized on the form giwn9 mclumve dates only District Alaska F~eld Kuparuk River County, parish or borough North Slope Borough Lease or Un,t ADL 25631 IT,t e Drill IState Alaska JWell no 3I-4 Auth, or W,O no AFE AK0936 Parker 141 API 50-029-21517 Operator JARCO w I ARCO Alaska, Inc. J 56.24% Spudded or W O begun JDate JHour JP .... status if a W O Spudded J 1/27/86 J 1915 hrs. Date and depth Complete record for each day reported as of 8.00 a m 1/28/86 1/29/86 1/30/86 1/31/86 The above is correct For form preparation and dlstrlbutior~ see Procedurss Manual, Section 10,' D.Iling, Pages 86 and 87 16" @ 99' 763', (664'), Turbo drlg Wt. 9.5, PV 7, YP 14, PH 10.0, WL 15.4, Sol 6 Accept rig @ 1500 hrs, 1/27/86. NU diverter sus. 1915 hrs, 1/27/86. Turbo drl to 763'. Spud well @ 16" @ 99' 2440', (1677'), Drlg Wt. 9.7+, PV 11, YP 13, PH 10.0, WL 15.8, Sol 7 Turbo drl 12¼" hole to 795', DD to 1837', rotary drl to 2440'. 920', Assumed vertical 1086', 6.7°, S72E, 1085 TVD, 10 VS, 3 S, 9E 1584', 20.3°, S67E, 1569 TVD, 124 VS, 42S, l16E 9-5/8" @ 391~' 3940', (1500'), Cmt 9-5/8" csg Wt. 10, PV 8, YP 7, PH 9.5, WL 16.2, Sol 10 Drl & surv 12¼" hole to 3940', 28 std short trip, C&C, POOH. RU & rn 96 jts, 9-5/8", 36#, J-55 ERW BTC csg w/FC @ 3837', FS @ 3919'. Begin cmt'g 9-5/8" csg. 2435', 44.7°, S66.1E, 2282.34 TVD, 578.55 VS, 203.16S, 541.71E 3196', 45.6°, S67.6E, 2812.87 TVD, 1123.4 VS, 418.34S, 1043.04E 3905', 43.8°, S67.7E, 3315.12 TVD, 1623.03 VS, 603.35S, 1507.32E 9-5/8" @ 391~' 4494', (554'), Turbine drl Wt. 8.5, PV 3, YP 2, PH 10.5, WL NC, Sol 2 Cmt 9-5/8" w/1500 sx AS III & 320 sx Cl "G". Bump plug. ND diverter. NU & tst BOPE. TIH w/BHA, tst csg to 2000 psi, DO flt equip & cmt. Co~duct formation tst to 12.5 ppg EMW. Drl 8½" hole to 4494'. Orilling Superintendent Atla nticRichfieldCom paii Daily We l History-Final Report Instruct,one: Prepare and submit the "Final Report" on the hrst Wednesday after allowable has been asmgned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an mdehmte or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representahve test data in blocks provided The "Final Report" form may be used for reporting the entire operation if space IS avadable Accounting cost center code Spudded or W.O. begun Spudded State Distract ICounty or Parish Alaska I North Slope Borough Alaska Field ILease or Unit IWell no Kuparuk River ADL 25631 Auth, or W.O, no. ~Title AFE AK0936 I Drill Parker 141 API 50-029-21517 Operator A R,Co, W I rTotal number of wells (achve or inachve) on this, ARCO Alaska Inc. 56. 247o Icost center prior to plugging and I ) labandonment of this well Date IHour I Pnor status if a W,O, 1/27/86 1915 hrs. Complete record for each day reported Date and depth as of 8'00 a.m 2/01/86 thru 2/03/86 2/04/86 2/12/86 0200 hrs. Old TD 9-5/8" @ 39 ' 8420', (3926'), RU to rn 7" csg Wt. 10.1+, PV 12, YP 7, PH 9.0, WL 8.6, Sol 13.3 Turbo drl & surv 8½" hole to 8420', 48 std short trip, circ hi-vis sweep & spot Lub 106 pill, TOH to log. RU Schl, rn DIL/GR/SP/SFL f/3917'-8412', cont w/GR to 1000'. Rn FDC/CNL f/7550'-8412' & CAL f/3917'-8412', RD Schl. RIH, wsh & rm 90' to btm, make 20 std short trip, C&C, pmp Lub 106 pill, TOH, LD DP. RU to rn 7" csg. 4329', 44.7°, S70.2E, 3619.43 TVD, 1918.87 VS, 709.62S, 1783.44E 5299', 44.2°, S75.7E, 4301.98 TVD, 2606.06 VS, 900.93S, 2445.37E 6450', 44.0°, S71.2E, 5133.33 TVD, 3401.07 VS, 1141.92S, 3203.88E 6951', 44.9°, S74.5E, 5490.97 TVD, 3751.38 VS, 1245.37S, 3539.12E 7266', 45.6°, S78.3E, 5712.73 TVD, 3973.56 VS, 1297.97S, 3756.56E 8074', 43.4°, S77.8E, 6288.04 TVD, 4535.78 VS, 1421.96S, 4310.15E 8345', 42.6°, S76.9E, 6486.25 TVD, 4718.96 VS, 1462.43S, 4490.49E 7" @ 8400' 8420' TD, 8310' PBTD, RR 10.0 ppg brine RU & rn 190 jts + 2 mkr its, 7", 26#, J-55 BTC csg w/FS @ 8400', FC @ 8310'. Cmt w/lO0 sx 50/50 Poz, followed by 200 sx C1 "G" w/3% KCl, .9% D-127, .3% D-13 & .2% D-46. Displ w/10.0 ppg brine, bump plug. CIP @ 1800 hrs, 2/3/86. ND BOPE. NU & tst tree to 3000 psi. RR @ 0200 hrs, 2/4/86. Arctic packed well w/175 sx AS I. New TD Date 8420' TD PB Depth 8310' PBTD K,nd of rg Rotary 2/4/86 Released rig 3I-4 Classifications (o11, gas, etc,) Oil Producing method Flowing Type completion (single, dual, etc ) Single Ofhclal reservoir name(s) Kuparuk Sands Potenhal test data Well no Date Reservoir Producing Interval Od or gas Test time Production Od on test Gas per day Pump s~ze, SPM X length Choke raze T.P C P Water % CDR Gravity Allowable Effechve date corrected The above ~s correct For form preparahon and d~strlbu~on, see Procedures Manual, Section 10, Drilling, Pages 86 and 87 Drilling Superintendent ADDENDUM WELL: 2/13/86 3I-4 Arctic Pak w/175 sx AS I, followed by 59 bbls Arctic Pak. RU & rn CET/GR/CCL & 6.125" gage ring f/8286'-6300'. Rn GCT gyro f/8250'-surf. Drilling~ Superintendent ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 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. return one signed copy of this transmittal. Final Prints: Schl: Open Hole: One * of each 2A-!~5" bIL/SFL-GR ~2" DIL/SFL-GR ~5" Den/Neu-GR 2" Den/Neu-GR ~5" Den/Neu-GR 2" Den/Neu-GR ~ Cyberlook '~ RFT Log 5" DIL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu 2" Den/Neu ~5" Den/Neu ~2" Den/Neu yberlook 3I-3 ~ DIL/SFL-GR ~2" DIL/SFL-GR ~ 5" Den/Neu -~,~ '~ 2" Den/Neu "~ 5" Den/Neu ~~ Den/Neu _______ ~ ~(Cyber!ook ~ ~%rberiook 01-28-86 01-28-86 (poro) 01-28-86 (poro) 01-28-86 (raw) 01-28-86 (raw) 01-28-86 01-28-86 01-28-86 02-02-86 02-02-86 (poro) 02-02-86 (poro) 02-02-86 (raw) 02-02-86 (raw) 02-02-86 02-02-86 01-26-86 01-26-86 (poro) 01-26-86 (poro) 01-26-86 (raw) 01-26-86 (raw) 01-26-86 01-26-86 0!-!_~-86 01-18-86 (poro) 01-18-86 (poro) 01-18-86 (raw) 01-18-66 (raw') 01-iS-86 01-18-86 DATE 04-01- 86 TRANSMITTAL # 5612 Please acknowledge receipt and Run #1 6113-6664 Run #1 6113-6664 Run #1 6113-6639 Run #1 6113-6639 Run #1 6113-6639 Run #1 6113-6639 Run #1 6113-6639 Run ,%1 6249-6378 Run #1 1000-8406 Run #1 1000-8406 Run #1 7550-8380 Run #1 7550-8380 Run #1 7550-8380 Run #1 7550-8380 Run #1 7550-8350 Run #1 2096-8076 Run #1 2096-8076 Run #1 5600-8050 Run #1 5600-8050 Run= =1 5600-8050 Run #1 5600-8050 Run #1 7400-7832 R~n #! 1800-8546 Run #1 1800-8546 Run #1 8000-~-=2! R'~ #! 8000-8521 R~ #1 8000-8521 R'~n #1 8000-8521 Ru.n #1 8200-8500 Rat?~na!!*bi Dri!!ing'bi D & M'b! ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage ~-K 99510-0360 DATE 03-04-86 · "5UkNSMITTAL # 5588 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Lis Tapes Plus ~'~3N-4 02-14-86 '~3N-~ - 02,-07-86 '~ 3N-2 01-27-86 '~3J-16 02-15-86 ~3I-5 02-09-86 '~I-4 02-02-86 3I-3 01-26-86 ~2A- 11 01-28-86 ~2A-10 02-06-86 2A-9 02-17-86 listings/ SCHL/ One of each Receipt Acknowledged: STATE OF_AK Date: A~ska Oil & G~ Cons. A.q~3rage ARCO AJltki. Inc. mi · Sul)l,Cl,·ry O! AtlafltlcRmctlheldCompi~ly ARCO Alaska, Inc. Post Office B, 00360 Anchorage, Ala=Ka 99510-0360 Telephone 907 276 1215 February 12, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton: Enclosed are the January Monthly Reports for the following wells' 1A-8 3F-16 3J-13 3N-2A 4-27 L2-25 2A-11 3I-1 3J-14 4-7 4-28 L2-29 2A-12 3I-2 3J-15 4-17 16-21 L3-5 2H-5 3I-3 3N-1 4-18 16-24 L3-23 2X-8 (2) 3I-4 3N-2 4-24 L1-9 ,Ugnu State #1 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L111 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED F E B 1 1986 Alaska 0il & bus Gm'ts. Cuu,missi0n Anchorage STATE OF ALASKA --- ALASKA C._ AND GAS CONSERVATION COt,_.JISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling weliX~~X-} Workover operation [] 2. Name of operator 7. Permit No ARCO Alaska, Inc. 85-310 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21517 9. Unit or Lease Name Kuparuk River Unit 4. Location of Well atsurface 295' FSL, 122' FWL, Sec.31, T13N, R9E, UM 5 Elevation in feet (indicate KB, DF, etc.) 71 ' RKB I 6. Lease Designation and Serial No. ADL 25631 ALK 2564 10. Well No. 31 -4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of January , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1915 hrs, 1/27/86. Drld 12-1/4" hole to 3940'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8420'TD (2/1/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 8310'. Secured well & RR ~ 0200 hfs, 2/4/86. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set ~ 99'. Cmtd w/255 sx CS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe 3919'. Cmtd w/1500 sx AS Ill & 320 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8400'. Cmtd w/300 sx Class G.. 14. Coring resume and brief description None 15 Logs run and depth where run DIL/GR/SP/SFL f/3917' - 8412'; GR to 1000' FDC/CNL f/7550' - 8412' Cal f/3917' - 8412' 6. DST data, perforating data, shows of H2S, m~scellaneous data None 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. /~j,e ~ ~~., ^ssociate Engineer' ~'JZ-~ SIGNED TITLE DATE NOZE--Repor(~,/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska O~1 and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise d~rected. Fnrm 1N-4N4 r~ANI/NtI~N~ Submit ~n duplicate MEMORANDUM TO ~:~ THRU: FROM: State,-of Alaska ALASKA OIL .~.~D GAS CONSERVATION COM}JIISb~ON g~a .V'~~~On Lonnie C. Smith~// Commissioner Doug Amos~ Petroleum Inspector DATE: FI LE NO.: TELEPHONE NO.: SUBJECT: February 7, 1986 D.ADA. 8 BOPE Test ARCO KRU 3I-4 Well Permit No. 85-310 Kuparuk River Field Wednesday, January 29, 1986: After witnessing the test at Sohio PBU k-~6-~-we-l~-,~ i-t~a~e'Iedtb-~AR~Co KRU 3I-4 well to witness the BOPE test. Thursda ,~nuary 30, 1986: The test commenced at 12:30 PM and was C0nClUde~-I:00~PM~ 'th~e were no failures and I filled out an A.O.G. Co C. BOPE Inspection Report which is attached. In summary, I witnessed the successful BOPE test at ARCO KRU 3I-4 well. Attachment 32-(Jt~1 A ( Rev 10-84) O&G #4 ~ ~ ~80 ® STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Representative_ Permit # " ~. g/~'~asing Set Rig $ ~ Representativ- Inspector Operator . . Well Location: Drilling Contracto . Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams ~ ~ Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves~'~ Check Valve Test Pressure t~ ACCUMULATOR SYSTEM Full Charge Pressure ~.O96) psig Pressure After Closure ~ ~O psig 200 psig Above Precharge Attained: min~7 sec Full Charge Pressure Attained: ~ min ~-~ sec N2 ~6k¢ ~.~OO, ~~ Controls: Master Remote ~ Blinds switch cover Kelly and Floor Safety Valves U~per Kelly. Lower Kelly Bal 1 Type Ins ide BOP I/Test Pressure. 51900 I ~ Test Pressure '~ .. , I ~%/Test Pressure ~ ] ~Test Pressure ,~ Choke Manifold ~ Test Pressure No. Valves No. flanges Adjustable Chokes Hydrauically operated choke Test Results: Failures .~1~O.~%~= Test Time I Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: hrs. days and Distribut ion orig. - AO&GCC' cc - Operator cc - Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 17, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 3I Pad (Wells 1- 16) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L06 Enclosure RFCFIVFD Alaska O~l & bas tuns. ~;umm~ssi0n Anchorage If ARCO Alaska, Inc is a Subsidiary of AtlantlcRichf~eldCompany NOTES ~ 2. SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL POSITIONS BASED ON ON-PAD CONTROL PER L.H.D. 6 ASSOC. 4. VERTICAL POSITIONS BASED ON TBM 3~ - 4 PER LHD ~ ASSOC. 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. CED- RlXX-- ~O50 rev. ~ LOCATED IN PROTRACTED SEC. SI,TISN~ RgE, U. MER. LOCATED IN PROTR~TEDSEC.~,TI3 N, RSE, U. MER. . [- Y= 6,007,295.50 LAT. 70°25'52.0592'' 9- Y= 6,007,[2[.00 ~T. 70°~5'50.443Z" X= 508,056.44 LONG. [49°56'03.596'' X= 507,867.9[ L0~G. [49°56'09. [34" [79' FWL, 345' FSL 0G. 33.6', PAD 39.9' ~80' FSL, [0' FEL 0G. 35.0', PAD 39.9' 2- Y= 6,007,269.06 LAT. 70°25'5[.8978'' Z0- Y= 6,007,[04.59 LAT. 70°25'50.282[" X= 508,037.66 LONG. 149°56'04. 148'' X= 507,849.11 LONG. 149056'09.686'' 160' FNL, 328' FSL 0G. 33.7', PAD 39.9' 164' FSL, 29' FEL 06. 35.0, PAD 40.0 ,, 11- Y= 6,007,088.16 LAT. 70°25'50 1206" 3- Y= 6,007,252.70 LAT. 70°25'51.7370 · X= 508,018.80 LONG. 149o56'04.702" X= 507,830.23 LOH6. 149°56'10.240'' 141' FWL, 312' FSL OG. 33.7', PAD 40.0' 147' FSL, 48' FEL 0G. 35.0, PAD 40.1 4- Y= 6,007,236.23 LAT. 70°25'51.5752" 12- Y= 6,007,071.76 LAT. 70025'49.9595" X= 507,999.99 LONG. 149°56'05.255 X= 507,811.32 LONG. 149°56'10.796" 122' FWL, 295' FSL 0G. 33.8', PAD 40.0' ' 131' FSL, 66' FEL 0G. 35.0, PAD 40.1 5- Y= 6,007,219.81 LAT. 70°25'51.4139" 13- Y= 6,007,055.32 LAT. 70°25'49.7981" X= 507,792 36 LONG. 149°56'11 353" X= 507,981.16 LONG. 149°56'05.808'' · · 104' FWL, 279' FSL OG. 33.9', PAD 40.0' 115' FSL, 85' FEL 0G. 35.0', PAD 40.1' 6- Y= 6,007,203.20 LAT. 70~25'51.2507'' 14- Y= 6,007,038.82 LAT. 70°25'~9.6359'' X= 507,962.12 LONG. 149°56'06.367'' X: 507,773.63 LONG. 149°56'11.903'' 85' FWL 262' FSL 0G. 34.0' PAD 39.9' 98' FSL 104' F 7- Y= 6,007,186.78 k~l. 70~25'51,0895" 15- Y= 6,007,022.42 k~l. 70~25'49.4749" X= 507,943.27 LONG. 149°56'06.920'' X: 507,754.83 LONG. 149°56'12.455" 66 FWL 246 FSL OG. 34.2 , PAD 39.8 · 82, FSL 123' FEL 0G. 35.0' PAD 40.2' 8- y: 6,007,170.37 LAT. 70¢25'50.9282'' 16- y: 6,007,006.02 LAT. 70°25'49.3!37'' X= 507,924.40 LONG. 149o56'07.475" X= 507,736.04 LONG. !49°56'13.007'' 47' FWL, 230' FSL 0G. 34.5', PAD 39.8' 65' FSL, 142' FEL 0G. 35.0', PAD 40.2' I[i CERTIFICATE O¢ SURVEYOR: . ,E~EBw CE~y ~,~% ~ AM ~RO~E~LW SURVEYING IN t~E STATE OF ALASKA MADE BY ME OR UN~_R M 5U ERV S ON, D __. T~;? ALL DIMENSIONS AND OTHER DETAILS --~ ~'~' SURVEYED F0e a~ ARCO Alaska, inc. "~ /Mil ~w~ WU UAILL ~l/b O& UU~UUU/U~ ~ ~~ ~ ;e~". '~' '~ AS-BUiLT LOCAtION o ....................... llow~. NC. ~SK eS- ~e Anch0ra- ~SArct/c Boulevard, Su/fe 201, Anchoraoe, Alaska 99503 /ls~LE AS SHOWN i December 31, 1985 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 31-4 ARCO Alaska, Inc. Permit No. 85-310. Sur. Loc. 295'FSL, 122'F~, Sec.31, T13N, R9E, UM. Btmhole Loc. 1390'FNL, ll30'FEL, Sec.5, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you £rom the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. W~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly v?~urs, Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office ,..~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 18, 1985 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive ^nchorage, AK 99501 SUBJECT: Kuparuk 3I-4 Permit to Drill Dear Mr. Chatterton: Enclosed are: ° An application for Permit to Drill Kuparuk 3I-4, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plot ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on January 17, 1986. If you have any questions, please call me 263-4970. Sincerely, Regional Drilling Engineer JBK/tw PD2/L14 Enclosures ARCO Alaska, Inc ~s a Subsidiary of AtlantlcRichfleldCompany la Type of work. STATE OF ALASKA ALASKA unL AND GAS CONSERVATION CO--MMISSlON PERMIT TO DRILL DRILL REDRILL DEEPEN 20 AAC 25.005 SERVICE[] lb Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] 2 Name of operator ARCO Alaska~ inc. 3. Address P. 0. Box 100360~ Anchorage~ Alaska 99510 4 Location of well at surface 295' FSL, 122' FWL, Sec.31, T13N, R9E, UM At top of proposed producing interval 1299' FNL, 1376' FEL, Sec.5, T12N, R9E, UM At total depth 1390' FNL, 1130' FEL, Sec.5, T12N, R9E, UM 5 Elevat,on ,n -~e~-t (i~dicate KB, DF etc.) T 6 Lease designation and serial no. RKB 71', PAD ~0' / ADL 25631 ALK 256~ 9. Unit or lease name Kuparuk River Unit 10. Well number 31 -4 11.Fieldandpool Kuparuk River Field Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13 D~stance and direction from nearest town 14. D~stance to nearest property or lease line 30 mi. NW of Deadhorse miles 1130' @ TD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8499'HD, 6536' TVD feet 2560 19 If dewated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 46 Ol(see2OAAC25.035(c) (2) Amount $500,000 15. D~stance to nearest drilling or completed 31-3 well25' @ surface feet 18. Approximate spud date 01/17/86 2733 psig@__80°F Surface 3141 ..psig@ 61F,~ ft. TD (TVD) 21 SIZE Hole Casing Weight 24" 16" 62.5# 12-1/4"] 9-5/8" 36.0# 8-1/2" / 7" 26.0# 22. Describe proposed program' Proposed Casing, Liner and Cementing Program CASING AND LINER Grade I Coupling H-40 J Weld J-55/HF-IRW BTC SETTING DEPTH Length MD 80' 32' I 32' I 3830' 32' i 32' TOP TVD 8468' 31' 131' MD BOTTOM TVD 112' 112' 3862'I 3301' 8499'I 6536' 1 QUANTITY OF CEMENT (include stage data) ±200 cf 1300 sx CS III & 320 sx Class "G" 400 sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8499'MD (6536'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2733 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 31-4 will be 25' away from 31-3 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on following sheet) 23. I hereby cer/dt~that the foregoing ~s true and correct to the best of my knowledge SIGNED /~~ TITLE Regional Drilling Engineer ~ee s~ ~/~w' f o~/CfZmp I ss I o n-~ CONDITIONS OF APPROVAL Samples required Mud Icg required D~rectlonal Survey required APt number []YES [~NO [-]YES ~-It40 J~YES []NO 50--0 'L~/- Permit number Approval date ¢ ~O . ~ ~ Z2~3~85 SEECOVER LETTER FOR OTHER REOUIREMENTS APPROVED BY ,COMMISSIONER DATE December 31, 1985 ~- - ' ~' ~~r~ byorder of the Commission Form 10~01 (JFB) PD2/PD14 Submit in triplicate PERMIT TO DRILL 31-4 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After thw workover rig has moved off location, this well will be fracture stimulated. KUPARUK RI VER UNIT 20" DIVEF TER SCHEMATIC DE SCR I PT I ON I. 16' C~CTOR. 2. TAI'~O STARTER t-~AD. 3. TANKO SAVER SUB. 4. TAhI,(O LOY~R QUICK-C~CT ASSY. 5. TAI',,I<OUi:::~ER QUICK-CON'~CT ASSY. 6, 20' 2000 PSI DRILLING SPOOL W/I O' OUTLETS. 7. I0" HCR BALL VALVES W/lO" ~ DIVERTER LINES. VALVES OPEN AUTOMATICALLY UPON CLOSURE OF Al',l',a.~ AR PREVENTER. 8, 20" 2000 PSI Ah~I, JLAR PI~VENTER. k/P,l NTENANCE & OPERAT I ON 4 I. UPON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AhlNULAR PREVENTER AhD BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CL(2SE Ah/NULAR PREVENTER I N THE EVENT THAT AN tAFLUX OF WELL~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, I~kh~ALLY OVERRIDE AhD CLOSE APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ~,k~C~j~VED Do NOT SHUT IN ~.~.~,~ ~ ~'~:~ UNOER ANY ClRCU~TA~ES. Gas Cons. &l~ R4 I 5 4 ,> ,> DIAGRAM #1 ~/ 1~-5/$" 5000 PSI RSRRA BOP STACK I. 16" - 2000 PSI TA/~<~ STARTING HEAD 2. II" - 3000 PSI CASING iF, AD 3. II" - 3000 PSI X 13.5/8' - 5000 PSI SPACE~ SPOS1 4. 13.5/8" - 5000 PSI PIPE RAMS S. 13-5/8' - 5000 PSI DRILLING SPOaL W/O-O<E At~D KILL LIhF_S 6, 13.5/8' - 50~0 PSI DOUBLE ~ W/PIPE RAh~ aN TOP° 7. 13--5/8' - 5000 PSI ~ ACEIJVtJt, ATOR CAPACTTY TEST 1. C~CK AhD FILL ACC~TCI~ RESERVOIR TO F~ LEVEL WITH HYDRALLIC FLUID.' 2. ~ THAT ACCl~TCR Pf~ IS 3~ PSI WITH 3. 08~S~RV~ TIIv~. ThF_.N CLOS~ ALL UNITS SIMJLTA~E~OUSLY ALL UNITS ARE CLOSED W/TH 04ARGING PLM~ OFF. 4. REC~ aN ~ E~PC~T, ~ ACCEPTABLE L(~ LIMIT IS 45 SE~ CLOSING TIIVE A~D ~200 PSI RE]~tAINING 13-5/8" BOP STACK TEST FILL BCP STAO< AN:) CH~ ~IF~LD WITH ARCTIC DIESEL. (~(:X THAT ALL LO(:X D(~ SC~ IN Y~ ARE FLl~Y RETRACTED. SE. AT TEST PLUG IN WITH RL~ING JT ~ RUN IN LO(~ S~. LIh[ VALVES ADJA(~ TO BCP STAC~ ALL OT~ 4. PRES,~ UP TO 250~~ FOR I0 MIN. IN- ~ PRE~ TO~ Aha) H(:I.D FOR I0 MIN. BI ~'~1'~ PRE~ TO 0 PSI, 5. (::PE~ ~ PF~Eh~ A~ MAMJAL KILL AhD Q.-ICKE LIh~ VALVES. CLOSE TOP PIPE RA~ Ah~ H(~ VALVES aN KILL AhD Q'IOKE LIh~S.~----~ 6. TEST TO 250 PSI AhD~30~P$~AS IN STEP ?. CC~Ih~JE TESTING ALL'-VAEVES, LIh~S, AhD CHCKES WITH A 250 PSI LOW AhD 3000 PSI HIGH. TEST AS IN STEP 4, DQ NOT PP~~ TEST ANY CHO<E THAT IS N~T A FULL CLOSING POSITIVE SEAL CHOKE. C~Y F~ICI~ TFST 0-~$ THAT DO h[2T FULLY CLOSE, 8. CPEN TOP PIPE RA~ AhD CLOSE BOq-rOM PIPE RA~. TEST BOTTOM PIPE RA~ TO 250 PSI AhD 3000 PSI. 9. CPEN BOTTOM PIPE RA~, 8AC~ OUT RL~I~ING JT AhD I0. CLOSE BLIhD RAMS AhD TEST TO 250 PSI AhD 3000 PSI. II. OPEN BLIhD RAMS AM2 RETRI~ TEST PLUG. MAKE SURE 'MANIFOLD AhD LI~ES ARE FULL CF NCN-FE%'~-ZING FLUID. SET ALL VALVES IN DRILLING POSITIaN. TEST STAM2PIPE VALVES, KELLY, KELLY COCXS, [;RILL PIPE SAFETY VALVE, AhD INSICE BOP TO 250 PSI AhD 3000 PSI. ~3. RECCRD TEST IhFO;~v~ATIaN aN BL(~ PREV~NTE~ TEST FORM, SIGN, A~ SEhD TO DRILLING SUPERVISOR. 14. PERFCI~ CO~ETE BCPE TEST AFTER NIPPLING UP AhD WEEKLY THEREAFTER FUNCTICNALLY CPERATE BCI~ DAILY. LIST FOR' NEW WELL PERMITS ITEM APPROVE DATE ~'~:i) Fee d~--~ /%-%0 '~1 (~ ~ 8) 5. '(10 and 19)/ 12. (13 thru 21) (22 thru 26) 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26° 27. 2ompany Lease & Well No. /~ YES NO REMARKS Is the permit fee attached .................... Is well located proper distance from property line ° . Is well located proper distance from'other wells ........ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate 4 Is conductor string provided Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons .................. :::~ "' Will surface casing protect fresh water zones ....... Will all casing give adequate safety in collapse[ ;~i~; ;~ ~;~;.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed Is a diverter system required ~ eeeeeeeee®eeeelleeeee®eeeeeeeeeeeeleeee Are necessary diagrams of diverter and BOP equipment attached ... ~ Does BOPE have sufficient pressure rating - Test to ~OOO ~ig :: Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: ,/',//',4v'.~ :zoo' - O i.--] HO Geology: Engineerin8: rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. · T3 ?J :j 0 PROS~$S (~CTAL) O 0"~ 00009 O0 O go" 0330330,30 ]O000 303,303300 O0000 O' O000 on" ~ ,. ~ .... 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