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Home My WebLink About185-062 ect Well History File' Cover e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing (done) RESCAN [] Color items: [] "'~ayscale items: Poor Quality Originals: [] Other: NOTES: Well History File Identifier DIGITAL DATA n Diskettes, No. [] Other, No/Type OVERSIZED (Scannable) D Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: ISl Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: IS/ Scanning Preparation BY: BEVERLY BRE~SHERYL MARIA LOWELL ~ -- TOTAL PAGES .~v~ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General Notes or Comments about this file: Quality Checked {done) 10125/02Rev3NOTScanned.wpd RECEn/ED . STATE OF ALASKA . Al,Ai Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS o D D 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 59 KB 8. Property Designation: ADL-047437 - 11. Present Well Condition Summary: Total Depth " measured 10750 true vertical 7248.55 " Effective Depth measured 10336 true vertical 7024.58 Casing Conductor Surface Production Length 80 6172 10382 Size 13-3/8" 48# H-40 9-5/8" 36# K-55 7" 26# L-80 Perforation depth: Measured depth: 10069 - 10097 True Vertical depth: 6878.14 - 6893.61 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x APi? 9. 1 _"n . 4' Stimulate D ia¡¡ & f' WaiverD Time Extension D "~~" Cons. CGmmi Re-enter Suspended Well D 5. Permit to Drill Number: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development M Stratigraphic [J Exploratory Service 185-0620 6. API Number: 50-029-21324-00-00 9. Well Name and Number: MPB-07 10. Field/Pool(s): Milne Point Field/ Kuparuk River Oil Pool " feet feet Plugs (measured) Junk (measured) 10060, 10098 10231 feet feet MD 35 - 115 34 - 6206 34 - 10416 Collapse 750 2020 5410 TVD 35 - 115 34 - 4609.16 34 - 7067.86 Burst 1740 3520 7240 ".~.. "" b. .. i "I ,:;: (\ ~\¿ft~~E.'tGG' r' I £)0' fie ~\,j ~± c... 'uU 10109 - 10145 6900.23 - 6920.1 3-1/2" 9.2# L-80 33 - 10036 3-1/2" Baker HB Packer 9986 RBOMS 8Ft APR 2 8 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development M 16. Well Status after proposed work: Oil ¡;;¡ Gas [J WAG Tubing pressure o o Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatu~ Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 4/19/2006 ~( \ ;iu m.it Original Only ",,4 S'. 2. . 0(. 5PtfJ6 ~ß-07 ~T¡f-lð DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY . &P¿ 5!/cb .. . ACTIVITYDATE I SUMMARY 2/14/2006 ***WELL S/I ON ARRIVAL*** SET 2.5" BAKER IBP IN 7" CASING @ 10060' CORRECTED DEPTH CCL TO MID ELEMENT = 19.51', 7.12' FROM TOP OF IBP TO MID ELEMENT IBP HAS 1 3/8" FN, 5500 LBS TO RELEASE & THERE ARE 2- 6" RUBBER ELEMENTS & 1- 1" STIFFNER RING STICKY SPOTS EXPERIENCED THROUGOUT WELL @ - 4500' - 4650', 8950' (BUTRESS TUBING) ***CONTINUED ON 15-FEB-06 WSR*** 2/14/2006 T/I/O=1650/1920/500 Assist E-line (set IBP) Pumped 10 bbls diesel to assist E-line RIH. Final WHP's=1950/2020/500 2/15/2006 ***CONTINUED FROM 14-FEB-06*** FINISH SETTING 2.5" BAKER IBP @ 10060' CORRECTED DEPTH ***JOB COMPLETE, LEAVE WELL SHUT IN & TURN OVER TO DSO*** 2/15/2006 T/I/O=1800/1950/500 CMIT Tx IA to 2200 psi (PASSED) (test IBP) Pumped 4 bbls diesel to pressure. Lost 20 psi in 15 min. Lost 0 psi 2nd 15 min. For a total of 20 psi in 30 min. Bled pressure down. Final WHP's=1800/1900/500 3/9/2006 *** WELL SI ON ARRIVAL *** (Dump Bail Sand) RIH W/ 2/25" X 10' DUMP BAILER,TAGGED IBP @ 10043' SLM.(DUMPED 4 BAILER LOADS OF SANDS). ***CONTINUE 03-10-06*** 3/10/2006 ***CONTINUE FROM 03-09-06***DUMP BAIL SAND. RIH W/ 2.25" X 10' DUMP BAILER,TAGGED IBP @ 10044' SLM. DUMPED 2 LOADS OF SLUGGITS. TAGGED @ 10038' SLM.RDMO. ***WELL LEFT S/I.*** 3/20/2006 Monthly rental for IBP set 2/15/06 Rental period of 3/20 - 4/20/06. Month 2. 4/14/2006 *** WELL SI ON ARRIVAL *** ATTEMPT TO SET TTP. SD @ 7216' SLM. RUN 2.65" CENT, SAMPLE BAILER. BEAT THRU TIGHT SPOTS @ 7249'-7350', 8067'-8164', 8899'- 8915' SLM. RECOVERED PARAFFIN SAMPLE. TAG D NIPPLE @ 10006' SLM W/ 2.75" GAUGE RING. SET 2.75" CRX TTP @ 10036' MD. *** WELL LEFT SI *** ." FLUIDS PUMPED BBLS 15 I Diesel TOTAL 15 Milne Pt Unit KR B-07 (185-062) Status f1 ,b : 18.5 -O~) ~ Subject: Milne Pt Unit KR B-07 (185-062) Status From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Mon, 23 Feb2004 10:00:56 -0900 1:9;.....§t~Xé.....MÞM().m~.......~stçyé...........ß1Cm~iHs@~c.i.rP.~Î1.~fat~.~..~.'û.~ê . Steve, As we discussed, I have just reviewed the file for the subject well and compared it to the production record and the status print out. Based on my file review, I recommend some changes/corrections to the current status date and production method for certain months in the production record. ...~ 11 recommend that the I-oil status date be changed from 7/22/1986 to . the date of first production 11/2/85. The suspended status ''-t>eginning 4/17/85 is correct. There is a 403 in the well file \ giving, the first production date. That information should have ~been flIed on a 404. . - In the production record, I recommend that the production method .\ ,... '\for Dec 1985, Jan 1986 and Mar 1991 be changed to flowing from gas 'lift. According to the well file, perforations were made in the tubing on April 1, 1991 to allow the well to be gas-lifted. Any production prior to that would have been flowing. ~Let me know if you have any questions. I have the backup information. Tom L(uJ d3+-JJ )OO~ ~SfY\ 1 of 1 SCANNED FES 2 3 2004 2/23/2004 10:01 AM ~ Milne Point 2001 Shut In Wells Date Reason for Future Utility Plans & Sw Name Shut-In Well Shut-tn f Current Mechanical Condition of Well2 Possibilities 3 Comments MPB-07 Jul-97 A No known problems I High GOR well, Facilities can not handle gas. Possible production after gas expansion project. MPB-08 May-94 E No known problems 3 ~uther use as an Injector not required MPB-13 Jan-86 B GL well that was shut in due to high 3 Wellhouse and flowlines removed water cut. Possible channel into water zone. MPB-17 Jan-96 E No mechanical problems. Quick 3 /Vellhouse and flowlines removed communication with producer MPB-19 Jul-91 B GL well. High water cut producer. 3 Wellhouse and flowlines removed Possible frac into water zone ~~ Feb-96 E No known problems 3 Further use as an injector not required while associated producer shut-in MPC-12 / Jan-O0 E Fish in hole, drilling problems 3 Suspended due to drilling problems. 12a MPC-16 Aug-93 A High GOR well, parrs and completion 3 ~Yellhouse and flowlines removed i abandoned MPC-17 May-O0 D Leak in 9 $/8" casing to surface I Evaluating possible plans for solution to problem. MPC-20 Apr-O0 B ~ High water cut well, no mechanical I Evaluating possible plans for solution to =roblems problem. MPC-21 Feb-02 D Problems with Jet Pump Completion I Evaluating possible plans for solution to problem. MPD-01 Dec-90 C Dead ESP completion, no support to I Evaluating possible plans for solution to block problem. Possible alternative uses for wellbore MPD-02./ Aug-99 B Dead ESP completion, very high water I Evaluating possible plans. 02a cut well MPE-02 Jun-OS C No known problems 2 ~Recomplete to upper Kup zone MPE-19 Aug-99 C Failed ESP on tubing string 2 Well brought on line in 2002 MPL-01 Feb-O0 B High water cut well, no mechanical I Evaluating possible plans problems dead ESP in hole MPL-IO Feb-99 E No proof that is supports other wells I Evaluating side track possibilities MPL-17 Apr-O0 B No menchanical problems, dead ESP I Evaluating side track possibilities MPL-21 0ct-98 E HighT~ressure~block ~ 5000 psi, no I Possible 'use for injection when pressure support needed for producers lowers MPL-37a Nov-99 C Dead ESP, noother mechanical I Evaluating possible side track plans or issuses recompletions MPL-39 Jan-99 E Could not inject gas into well, no use I Evaluating possible side track plans or for it. recompletions *Note - Wells were shut in 100% during 2001 Milne Pt Shut In Wells 2001 .)ds STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Posi-Plug Set Pull tubing _ Alter casing _ Repair well _ Perforate _ Other _X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 581' FSL, 760' FWL, Sec 18, T13N, R11E Um At top of productive interval 1359' FNL, 195' FEL, Sec 23, T13N, R10E Um At effective depth 1363' FNL, 222 FEL, Sec 23, T13N, R10E Um At total depth 1416' FNL, 767' FEL, Sec 23, T13N, R10E Um 5. Type of Well: Development __X Exploratow__ Stratigraphic__ Service__ asp 571834, 6023702 asp 56561~ 6021705 asp 565591, 6021700 asp 565046, 6021642 6. Datum elevation (DF or KB feet) RKB 59 feet 7. Unit or Property name Milne Point Unit 8. Well number MPB-07 9. Permit number / approval number 185-062 10. APl number 50-029-21324-00 11. Field / Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical 10750 feet 7248 feet Effective depth: measured 10098 feet true vertical 6894 feet Plugs (measured) Casing Length Conductor 80' Surface 6170' Production Liner 10382' Sidetrack Liner Junk (measured) Size Cemented 16" To Surface 9-5/8" 275 SX Class G 2600 SX Arctic Set 7" 370 SX Class G Posi-plug set @ 10107' on 2/15/02 (9' of cement on top) 10231' Perf Guns Measured Depth True VerticalDepth 115' 115' 6206' 4606' 10416' 7068' Perforation depth: measured 10069'-10097', 10109'-10145' true vertical 6878'-6894', 6900'-6920' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 at 10038' Packers & SSSV (type & measured depth) HB Hydraulic packer (ID = 2.89") at 9986' Camco IA-SSA-SCSSV (ID = 2.812") at 1867' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Pdor to well operation shut-in Subsequent to operation 2/21/02 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcr Water-Bbl 1479 5710 0 Casing Pressure Tubing Pressure 2O8 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. _.,~~ ~ Title: Production Technical Assistant Garry Catron Date March 25, 2002 Prepared b~/Garry Calron 564-4657 Form 10-404 Rev 06/15/88 · ORI61NAL SUBMIT IN DUPLICATE MPB-07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/30/02 Drift & Tag 2/15/2002 Cement Plug 2/23/2002 Well Test ! Freeze Protect EVENT SUMMARY 01/30/02 Tagged TD al: 10137' ELMD, 8' of MK-2 perf covered. 2/15/2002 Set Posi-set plug and dump 9' of cement on top to isolate the water influx. Top of cement is 10098' ELMD. 2/23/2002 Conduct well test/Freeze protect tubing and flowline. FLUIDS PUMPED BBLS 30 Methonal down tubing 10 Methonal down flowline 4O TOTAL Page I . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0/7:) DATE: July 12, 2000 Commissioner I tf //eybc.;.) THRU: Blair Wondzell, ~~ P. I. Supervisor .êf1(cij FROM: ~t!1 Jeff Jones ,.--" SUBJECT: Safety Valve Tests Petroleum 'I sp c r Milne Point Unit B & C Pads Julv 9. 2000: I traveled to BP'S Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP'S MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. 'J J'vO... r.z..-hz-7i- 21 well houses were inspected, no failures. .". Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc~ NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: FieldlUnitlPad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 HPS N/A 7/9/00 N W N I~¡~¡+rf I . .Well.I)atii7". ;;::.:', '.;.~;: '!.:.\<':.<~:' :\:: :':::.;'.'J~llots~'.. .: ",,'.~:!'~'h.:,'.~~,::,,>.> ':,S.V':, .:ssy.~ . .. -', . I .' ~ Well!:Typ~ .:. , .. . 'þ ,I; ~ "'" .~. . . ". -. . ,- '.. . Well Permit Separ Set LIP Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE B-02 1811420 B-03 1820560 140 100 115 P P OIL B-04A 1821000 140 100 95 P P OIL B-06 1850130 140 100 90 P P OIL B-07 1850620 B-09 1850340 140 100 95 P P OIL B-10 1850170 140 100 90 P P OIL B-13 1850930 B-15 1851210 140 100 95 P P OIL B-16 1851490 B-19 1852300 B-20 1860050 140 100 95 P P OIL B-21 1860230 140 100 95 P P OIL B-22 1853020 140 100 100 P 4 OIL B-23 1890160 9 Componen.ts: 18 Failures: 1 Failure Rate: 5.5% 090 Day Wells: Remarks: Three well SV's recorded slow closing times; B-04A(3:20), B-03(3:03),B-06(3:30). Some of the wells on this pad do not have well signs on them. Larry Niles, the BP representative, said he would have these items corrected. R/7/00 Page 1 of 1 Vvo43m 1 t.xls December 11, 1992 Conoco Inc. ,.--' 'q '~ ~ · 2 ~ " 3201 C Street, Suite 00-,-.r~-' ";" ";':.~. Anchorage, AK 99503-3999r.'~ ~,!~ (907) 564-7600 ~:~'~ ~ ~/ Ms. Joan Miller Statistical Technician Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 REEEIVED DEC 1 4 1992 RE: OUTSTANDING APPLICATIONS FOR SUNDRY APPROVAL Alaska 0il & Gas Cons. Gomr~-fissiO~' Dear Ms. Miller, Anchorage The following list of wells and the status of their outstanding Application for Sundry Approval forms was prepared in response to your October 6, 1992 letter to Bob Fulkerson: /cE,-,~/¢ ~ Well Approval No. No. Status ,¢'~'-¢ ~. B-7 90-869 Work completed, 10-404 form attached ,,--,~-~-1'7 B-10 90-393 Work canceled ,¢.¢'-- ¢'¢, B- 12 91-363 ,~' ~"-/"/? B-16 91-330 Work pending, please keep 10-403 form open Work ongoing, please keep 10-403 form open ,¢'~"--.~Z ? B-18 91-364 Work completed, 10-404 form attached Work pending, please keep 10-403 form open Work pending, please keep 10-403 form open ¢',~¢../~--C-10 90-878 Work canceled C-12 90-881 Work canceled C-15 91-366 Work pending, please keep 10-403 form open 9-878 Work completed, 10-404 form attached ~..¢---,,.~,~ ~' C-18 91-367 Work pending, please keep 10-403 form open Ms. Joan Miller December 11, 195_ Page 2 v,~'g'--.~ e (. C-19 90-879 Work canceled ~-./'7 E-3 91-368 -~ ~'~ -.~" E-4 91-152 Work pending, please keep 10-403 form open Work canceled ~ ? ~--~/ I-2 92-036 Work canceled ?~ --?.~ I-4 91-263 Work recently completed, 10-404 form will be mailed under separate cover ~,"~/'"~' 7 J-7 92-037 Work canceled '" L-1 ~ 90-803 ~--~ ?~-~ L-2~' 9-153 ~'~-,~? L-5./ 90-797 ?~.../~ / L-9 ' 91-313 ,~"3-/~ L-10 / 91-314 Work completed, 10-404 form attached Work completed, 10-404 form attached Work completed, 10-404 form attached Work completed, 10-404 form attached Work completed, 10-404 form attached Work completed, 10-404 form attached Please direct any concerns or questions regarding this matter to me at 564-7660. Tom Yeager SHEAR Specialist att: cc: BGS, LEN/JMK cc w/o att: CVL, JHA, BGA, WCD/HDS REEE VEE DEC t 4 ~99~ Alaska Oil & Gas Cons. O0r~rf~'~ssior' 'An~h0mge STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMIb~.ION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation shutdown __ Stimulate __ AJter casing __ Repair well __ Pull Tubing __ AJter casing Repair well Other X Perf. for G/L Injection Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 5, Type of Well: Development X__. Exploratory __ Stratigraphic __ Service Location of well at surface 581' FSL, 760' FWL, Sec. 18, T13N, R11E, U.M. At top of productive interval 1358' FNL, 194' FEL, Sec.23, T13N, R10E, U.M. At effective depth 1364' FNL, 251' FEL, Sec.23, T13N, R10E, U.M. At total depth 1415' FNL, 765' FEL, Sec.23, T13N, R10E, U.M. 6. Datum elevation (DF or KB) 59'KDB feet 7. Unit or Property name Milne Point Unit 8. Well number B-7 9. Permit number 85-62 10. APl number 50-029-21324 11. Field/Pool Kuparuk River Field 12. Present well condition summary Total depth: measured true vertical 10,750' feet 7,248' feet Effective depth: measured 10,137' feet true vertical 6,915 Casing Length Size Cemented Structural Conductor 80' 16" To Surface Surface 6,170' 9-5/8" 275 sx Class G Intermediate 2600 SX Arctic Set Production 10,382' 7" 370 SX Class G Uner Perforation Depth: measured 10,069'-10,097'; 10,109'-10,145' Plugs (measured) Junk (measured) 10,231' PERF feet Measured depth True vertical depth 115' 115' 6,206' 4,606' 10,416' 7,068 true vertical 6,879'-6,893'; 6,900'-6,924' Tubing (size, grade, and measured depth) 3-1/2", L-80, 10,038' Packers and SSSV (type and measured depth) CAMCO TRDP-1A SCSSV @ 1,867'; BOT'HB' Pkg. @9,986' 13. Stimulation or cement squeeze summary REE~iV~. 14. Prior to well operation Subsequent to operation Intervals treated (measured) DEC 1 4 1992 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Anchorage Representative Daily Average Production or Injection Data OiI-Bbl ~' Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 375 38 0 174 2Ol 223 0 1240 156 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereb ~fy that t Signed \ Form 10-404 06/15/88 16. Status of well classification as: Oil X Gas Suspended.~ Service true and correct to the best of my knowledge. SUBMIT IN DUPLICATE Lir~_ Conoco, Inc. Daily Well Activity Re~..,rt Alaska Activity: P.~F,~F ~4 ~//v ,,/,42,.),~"~. 7'/~,4') Zone(s) Open: //~,~ --/, ..~ Weather: Wind: ~ M./' @ '~ Kts.; GustsTo: ~ Ets.; Temp:.---,,2.~:) OF/ - ,4](/oFWC; Visibility: / t:5) Mi. From To Daily Operations ~o~~.~. M)~U H~r ~ T~u~4 ~ Pump O~w~ o~ ~. 12~ leto ~1~ C~mco . R/iq ~/ 2,~2"/Zex~ ~,.,~=- o~ / 2~ 2~ ~0 T Total Fluid Produc~: Last 24 Hrs. ¢ BBLS, Cum. BBLS, Type , Weight PPG, Visc. Sec. Total FluiO Lost: Last ,4 Hrs. ~ ,BLS, Cum. ,BLS, Type ,Weight ~:E~~.~Y~. BPV: In/~ SSSVO/Closed Downhole Plug: Yes Depth Type Rig: ~ ~ ~ ~* Z]~- E~¢¢ S~ ] Supe~isor: % r~P~W~aska 0il & 6as Cons. Corn~.is¢oi Daily Cost Estimate: $ ]& ¢ ~ ~ J Cum. Well/ActiviWCost:$ J Auth. Amt:$ Anchorage STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMIS,~,,JN APPLTCATTON FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend Alter casing Repair well Change approved program __ Operation shutdown Re-enter suspended well Plugging __ Time extention Stimulate Pull tubing __ Variance __ Pedorate __ Other X Return to production with gas lift 2. Name of Operator Conoco Inc. 3. Address 3201 C Street, Suite 200 Anchorage, AK 99503 4. Location of well at surface 581' FSL, 760' FWL, Sec. 18, T13N, R11E, U.M. At top of productive interval 1358' FNL, 194' FEL, Sec. 23, T13N, R10E, U.M. At effective depth 1364' FNL, 251' FEL, Sec. 23, T13N, R10E, U.M. At total depth 1415' FNL, 765' FEL, Sec. 23, T13N, R10E, U.M. 5. Type of Well: Development X Exploratory __ Stratigraphic ~ Service Datum elevation (DF or KB) 59' KDB 7. Unit or Property name Milne Point Unit 8, Well number B-7 9. Permit number 85 -62 10. APl number 50- 029-21324 11, Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' surface 6,170' Intermediate Production 10,382' Liner Perforation Depth: measured 10,750' feet Plugs (measured) 7,248' feet 10,137' feet Junk (measured) 6,915' feet true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 10,231' PERF GUNS Size Cemented Measured depth True vertical depth 16" To Surface 115' 9-5/8" 275 SX CLASS G 6,206' 2600 SX ARCTIC SET 7" 370 sx CLASS G 10,416' 10,069' - 10,097'; 10,109' - 10,145' 6,879' - 6,893'; 6,900' - 6,924' 3-1/2", L-80, 10,038' 115' 4,606' ! EC 1 2 1990 A!aska Oil & Gas Cons. Cornrnissio~ Anchorage CAMCO TRDP-1A. SCSSV @ 1,867'; BOT 'HB' Pkr. @ 9,986' 13. Attachments De,.,.,~dption summary of proposal __ Wellbore Diagram Detailed operations program __ BOP sketch 14. Estimated date for commencing operation December 20, 1990 16. If proposal was verbally approved Oil X Name of approver ~ Date approved Service 17. I hereby ce~ify that/~,e foregoing is true and correct to the best of my knowledge. Signed ~/~ /~IV~ J.H. Andrew Title Production Engineer FOR COMMISSION USE ONLY 15, Status of well classification as: Gas Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C. Approved by order of the Commission [R _,,~ ,,~ ~) Commissioner Form 10-403 Rev 06/15/88 Suspended__ Date 12/07/90 IApproval No. SUBMIT IN TRIPLICATE _ ILNE POINT UNIT · . . .......... ON 4-22-85 F~ ~[~ ~ V/ 3 ~/2' 'H' Elm/PROFILE I 1<I]8 - Et..59' KDO - ~ . 35' AA)(. AI, I]LE · 57.5 a 4288' K~ · 588' FAC 3 I/8' APl 5000, V/ 3 !/2' 8 TREETCP ~T IN, £CNSTRICTI~ APl NO.: 50-829-21324 £OAPLET [(3,1 FLUID · 9.6 PP~ NoCI V/ 181 ~ D[ESB_ 13JSH]~ FF. RFORAT l~: 12 SF~ V/ 128 PHASING 19,069-10.097' ND 6.879-§,893 ' ]'VD 10,109-10,145' ND 900-6. 924' T~ 3 I/2' 9.2, L-80 BI'RS 1 2.992 ID I 1867' CAJ'~0-IA-SSA SCSSV ilo · 2.8121 9848' CASING RA AN;tXE~ 9948' TUBING RA/MCY, E:R 9971' EOT PE~ SEAL ASSEAELY I lO · 3.0) 9986' BOT '~' PACKER ( 2.89 lO I DEC 1 Alaska 0il & Gas 10,824' CAACD 'D' Ancb NIPPLE ( 2.7'5 ID ) -- 10,RI3§' TUBING TAIL - 10.231' TOP CF FISH 10.336' PELTO IVIREL. II~ 4-16-85) 10.416' 7' 26, L-80 BI'R!:j. 16.276 ID. 6. 151 E~IFT) ons. rage Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (9O7) 564-76O0 April 27, 1987 Ms. Fran Jones Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Ms. Jones: Enclosed please find the drilling "well history" from Conoco's Milne Point Unit well No. B-7. If you require additional information concerning this well history, please contact Don Girdler at 564-7637. Yours very~ E. D. Wilson Sr. Administrative Coordinator DRG/vv B-7 Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.7- CONFIDENTIAL (10,750'-Kuparuk River) AFE 10-61-1091 AP1 No. 50-029-21324. Ak. Permit No. 85-62. Elevation: 59' KB. Location: 581' FSL, 760' FWL, Sec. 18, T13N, RilE, Umiat Meridian 04-02-85: RU. Pick up BHA. Orient ~D. Function test hydril and test to 200 psi. Mix spud mud. Drill & survey 105' to 866'. 04-03: Drill & survey 866' - 917'. Pump pill. TOOH from 917'. Change bit & BHA. TIH to 917'. Drill & survey 917' to 2974'. 04-04: Drlg. from 2974' to 3162'. Wireline survey & POOH. Change BHA & bit. TIH to 3162'. Drlg. from 3162' to 4297'. Pump slug. POOH to change BHA. Change BHA to stop angle build. Orient MWD TIH to 4297'. Drlg from 4297' to 4561'. Remove & replace broken Kelly hose. 04-05: Work pipe while replacing Kelly hose. Drlg to 4805'. POOH from 4805' to L/D L. collar. D/D L. collar to stop angle drop. TIH to 4805'. Break circ. & drlg from 4805' to 6250'. Circ. & make short trip to 4666'. TIH & circ. 04-06: Circ. & cond. mud. POOH, hit tight spot @ 4350'; hole swabbing. TIH. Circ. & cond. POOH slow. L/D BHA. RU to run 9 5/8" csg. Run 158 its of 36#/ft K-55 9 5/8" csg. Float shoe @ 6206'. Float collar @ 6127'. Circ. w/10.1 ppg mud. Test lines & cmt. w/Dowell. Pump 40 bbl Zeogel preflush @ 11 ppg. Pump 888 of 12.2 ppg Arctic Set III w/~ lb/bbl cellophane drop plug. Pump 56 bbls of 15.8 ppg Class G w/l% CaC1 & 0.2% D46 defoamer. Drop top plug. Displace w/5 bbl H20 & 473 bbls of 10.1 ppg mud. Bump plug w/1500 psi. Floats held. Lost circ. w/888 bbls pumped. Csg. stuck 19" off of bottom. ND diverter. Prepare to install Tanko emerg, kit. 04-07: ND diverter. RU & perform top job. Pump 15 bbl of Arctic Set I; 2 bbls of cmt. returns. Make rough cut on 9 5/8" csg.; remove hanger. Make finish cut, install emergency mandrel. Weld mandrel. Repair weld. Preheat to 400°F & maintain through weld, stress relieve area w/800°F; wrap & allow to cool. Allow well to cool to 100°F & test weld to 3000 psi. MU speed head on mandrel. Max torque 8000 ft.lbs; NU BOP stack. 04-08: NU BOP stack. Pressure test choke & kill manifold, upper & lower pipe rams, blind rams, upper & lower Kelly cock, spare TIW & inside BOP. Choke and kill valves to 5000 psi. Annular to 3000. Csg. tested to 2000 psi. Tests witnessed by Ed Sipple. RD; install wear bushing. PU BHA. TIH to tag F.C. @ 6125'. Drill cmt. plugs, float collar & float shoe + 30' of new hole. Perform equivalent MW test. Press. up 1 SPM to 670 psi w/9.3 ppg mud & TVD = 4640' (12.1 ppg EMW). Drlg & orienting from 6280' to 6835'. 04-09: Drlg. to 6915'. L/D 2 jts & ream back to bottom to correct hole direction POOH looking for washout, -500 psi loss Check BHA. for washout; change bit. Reorient MWD. TIH. Drlg from~ 6915! ~to~ 7940' . Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.7- CONFIDENTIAL (10,750'-Kuparuk River) AFE 10-61-1091 API No. 50-029-21324. Ak. Permit No. 85-62. Elevation: 59' KB. Location: 581' FSL, 760' FWL, Sec. 18, T13N, RilE, Umiat Meridian 04-10: Drlg., survey & orient from 7940' to 9365'. 04-11: Drlg., survey & orient from 9365' to 10,091'. 04-12: Drlg. from 10,091' to 10,498'. Pump pill, POOH from 10,498' to 6207' - 1st 15 stds tight. TIH. Break circ.; pipe stuck, hole packed off, work stuck pipe. Establish circ. & free pipe; pump hig visc. sweep & circ. 04-13: Circ. & cond. mud. POOH for open hole logs. LD motor, MWD, centralizer & O. sub. Logging w/G.O.; tools would not go past 7610'. POOH. Install skate & RIH. No change° POOH. RD G.O. & RIH w/bit. Slip & cut drill line. RIH to 7500'. Wash & ream to 7700'. RIH to 10,498'. Circ. & cond. mud. Pump pill. POOH, slow. 04-14: POOH. RU Gearhart. RIH w/G.R., CNL, CDL, DIL, & Caliper. Tools would not go past 10,424'. Logged interval shows MK-1 10,066'-10,094'; MK-2 10,105'-10,140' indicating need for additional 252' of hole. Change BHA, RIH to 10,498'. Drlg. from 10,498' to 10,508'. Hole packing off, pipe stuck; work stuck pipe. Establish circ. & pump high visc. sweep. Drlg. from t0,508' to 10,750'. 04-15: LD 10 jnts & ream back to bottom. Pump high visc. sweep, circ.- & cond. POOH from 10,750'. RIH w/d/p. & hwdp & mule shoe to log through drill pipe. Hang Schlumberger sheave in derrick. RU DIL & GR; install side door sub, MU in string. Logging w/Schlumberger through d.p. Circ. & work pipe while pulling Schlumberger out of pipe. 04-16: Wireline w/Schlumberger & RD. Run GR & DIL through drill pipe from 10,565' to 9820'. TIH to 10,750'. Circ. & cond. mud. POOH. LD drill pipe & BHA. Spit lubrication pill @ shoe. Pull nominal seat protector & change pipe rams. RU & run 7" csg. Broke circ. @ 8657'. Lost returns. Hole tight @ 9636'. 04-17: Finish running 262 jts of 7" 26#/ft L-80. Csg. shoe @ 10,416'. Float collar @ 10,334'. Bottom of ECP's @ 10,295' & 10,234'; top of marker jnt @ 9965'. RA marker @ 9848'. Begin circ. with partial returns. Pump 30 bbls of 11.3 ppg Dowell spacer 3000; repair cmt. line. Drop bottom plug. Pump 76 bbls of 15.8 ppg Class G w/0.8% D60, 0.25% D13, 0.2% D46, drop top plug. Displace cmt w/9.6 ppg. NaC1 brine - 402 bbls, bumped plug & press, up to 3000 psi to set BOT packers. Hold 10 min. & release. Note - returns lost while circ. & not regained throughout cmt. job. Floats held. CIP @ 1355 hrs. LD Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Pt. B No.7- CONFIDENTIAL (10,750'-Kuparuk River) AFE 10-61-1091 API No. 50-029-21324. Ak. Permit No. 85-62. Elevation: 59' KB. Location: 581' FSL, 760' FWL, Sec. 18, T13N, RilE, Umiat Meridian landing jnt, insert lockdown screws & test 7" packoff to 5000 psi; RU Camco E. Line. Run gyro, G.R. & CCL. RD & run 3 1/2 9.2 lb/ft L-80 buttress tbg. 320 jnts to be run. Perf. interval 10,066'-10,094'; 10,106' to 10,142'. BOT packer @ 9970' 2500 psi setting pressure. RA marker @ 9939'. Circ. vent to close ~ 1000 psi. Production vent to open @ 3600 psi. 04-18: Continue to run 3 1/2" tbg. 9.2 lb/ft, buttress, 320 jts total ran. Make up tbg. hanger. Land tbg. RU Camco, run CCL/GR for correlation. RD Camco. Displace tbg. w/101 bbls. diesel. Close circ. port w/2100 psi. Set packer w/2800 psi. Open circ. port w/ 3600 psi. Test SSSV to 1500 psi. Test annulus to 1500 psi. Shear out of PBR w/145,000. LD landing jt., install two way check. ND BOP stack. NU tree. Test tree and tbg. hanger to 5000 psi. Remove two way check. RIG RELEASED. Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 December 23, 1986 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99503 Dear Mr. Chatterton: Temporary Shut-in of Production and injection Wells Within the Milne Point Unit As you are aware, Conoco et al. has filed an application with the Department of Natural Resources to temporarily discontinue production operations at Milne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Mitne Point Unit. There are !9.active and 5 inactive production wells at Mi!ne Pcint. All active production wells will be freeze protected by displacing the top 3nnn' ' uu~ of the tublng with a 1:3 diesel:oil mixture. The annu±ar fluid levels will be monitored for leaking gas lift valves, if necess=:5 ~..e production casing annulus will be displaced with a diesel:oil mixture to at least 3000'. Once the shut-down operation is completed, pressure surveys will be run in all production wells. After the =u~vevs are run BPVs will be installed and all SCSSVs and wellhead valves will be closed. The inactive production wells have been adequately freeze protected with diesel across the permafrost. There are currently ten active and six inactive water injection wells in the Milne Point Unit. ACTIVE: B-8, B-12, B-14, B-17, B-18 C-8, C-ii, C-12, C-15 CFP-2 STATIC: B-5A, B-7, B-19 C-6, C-10, C-19 Active water injection wells will be freeze protected by displacing the tubing to at least 2000' with a 50:50 water:methanol mix. The SCSSV and wellhead valves will remain open for two to three weeks after the well is shut-in to monitor wellhead pressure. When adequate wellhead data has been obtained the BPVs will be set and the SCSSVs and all wellhead valves will be closed. The static injection wells are currently freeze protected and no additional work will be required. Injection water is supplied by three water source wells. Though only one well is active at any given time, all wells are capable of produc- ingo A-2A; B-I; CFP-1 Water source wells will be freeze protected by displacing the tubing to at least 2000' with a 2:1 propylene glycol:water mixture. After the wellslhave been displaced with the glycol:water the BPVs will be set and all wellhead valves will be closed. The E-2 gas storage well has been shut-in since July 1986 due to a tubing leak. l~ne wei!bore is filled with natural gas so that freezing is not a concern, but to prevent potential corrosion an inhibitor will be displaced into the well. A 50:50 methanol:water mix will be used to carry the inhibitor. if you have any questicns on the shutdc~ procedure please ccntact Don Girdler at 56g-7637. Yours very truly, i nt er Manager STATE OF ALASKA ALASK._OILAND GAS CONSERVATION COMfy, .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~.' Operation Shutdown Re-enter suspended well E} Alter casing E] Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing :~ Amend order ~ Perforate[; Other 2. Name of Operator 5. Datum elevation(DF or KB) Conoco Inc. 59' KB feet 3'Add~e~l C Street, Ste 200, Anchorage, Alaska 99503 6. Uni[,Q~Prop~rty qa~ .. · mm±ne romnc unz[ 4. Location of well at surface 581' FSL, 760' FWL, Sec. At top of productive interval 1358' FNL, 194' FEL, Sec. At effective depth N/A At tcj_t~a~.~PtCNL, 765' FEL, Sec. 18, T13N, RllE, U.M. 23, T13N, R10E, U.M. 23, T13N, R10E, U.M. 7. Well number 8. Permit number 85-62 9. APl number 50-- 029-21324 10..POO~uparuk River 11. Present well condition summary Total depth: measured true vertical 10750 7248 feet feet Plugs (measured) Effective depth: measured N/A true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 80' 16" To Surface 6170' 9 5/8" 944 bbls 10382' 7" 76 bbls measured 10069'-10097'; 10109'-10145' true vertical 6879'-6893'; 6900'-6924' Tubing (size, grade and measured depth) 3~"2 , L-80, 10038' T.R. SCSSV @ 1867'; Packers and SSSV (type and measured depth) Measured depth True Vertical depth 115' 115' 6206' 4606' 10416' 7068' '}lB' Pkr. @ 9986' 12.Attachments Description summary of proposal,~ Detailed operations program !~ BOP sketch 13. Estimated date for commencing operation January 1987 14. If proposal was verbally approved Name of approver Date approved Signedtx" -"h ~k'~,___//¢,,,.,_~! [,'- ~-- -__ Title Sr. Production F_noi___er Commission Use Only Date Conditions of approval Notify commission so representative may witness ..~ Plug integrity ~ BOP Test [] Location clearance >:,~: 7 i-:;: .- '.:~ '":.; · / ./ f.1. /. / Approved by Commissioner Approval NO. ~' 7'¢~ by order of /' ,, / the commission Date..l.. '/..:,-:, :..; ~_.,~ Form 10-403 Rev 12-1-85 Sub(nit inr triplicate "'., --~ STATE OF ALASKA ~ ALASi -L AND GAS CONSERVATION L;. 7;]MISSION WELL COMPLETION OR RECOMPL TION REPORT AND LC G 1. Status of Well Classification of Service Well ~ 2. Name of Operator 7. Permit Number Conoco Inc. 85-62 3. Address 8. APl Number 3201C St. Ste., 200, Anchorage, AK 99503 50-029-21324 4. Location of well at surface 581' FLS, 760' FWL, Sec. 18, T13N, RllE, U.M. At Top Producing Interval 1358' FNL, 194' FEL, Sec. 23, T13N, R10E, U.M. At Total Depth 1415' FNL, 765' FEL, Sec. 23, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 59' KB ADL 47438 12. Date Spudded 13. Date T.D. Reached 4-2-85 4-15-85 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 10750'(7248') 10334' (7023') 22. Type Electric or Other Logs Run GR- CNL-CDL-DIL-Cal-Gyro-CCL 9. Unit or Lease Name Milne Point Unit 10. Well Number :8-7 1 1. Field and Pool Kuparuk River Field Kuparuk River 14. Date Comp.,Susp. orAband. J 15. Water Depth, if offshore'116. No. of Completions 4-17-85 I N/A feet MSLI 1 19. Directional Survey 20, Depth whereSSSV set I 21. Thickness of Permafrost YES ~ NO ~ 1867 feet MD I 1800'TVD 23. CASING SIZE 1.3 3/8" 9 5/8" 7" 24. Perforation CASING, LINER AND CEMENTING RECORD WT. PER FT. GRADE TOP 48# H-40 36# K-55 0 ~ 6206' 26# L-80 0 10416' open to Production (MD+TVD of Top and Bottom and SETTING DEPTH MD BOTTOM 0 115' interval, size and number) 10,069'-10,09.7' (6879'-6893') ~-1 10,109'-10,145' (6900-6924') MK-2 5" Hollow Carrier 22 gram 12 spf HOLE SIZE 15" CEMENTING RECORD AMOUNTPULLED 100 cf of Perm. Cmt. 888 bbls Arctic Set $1I 56 bbls Class G 9~" 76 bbls Class G 25. TUBING RECORD SIZE DEPTH SET (MD) ~" q 2~ T.-gN INN3g' PACKER SET (MD) 9992' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. Date First Production 11-5-85 Date of Test 11-26-85 Flow Tubing Press. 210 IHours Tested 6 Casing Pressure PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD CALCULATED 24-HOUR RATE OIL-BBL OIL-BBL 32 GAS-MCF GAS-MCF 11 WATER-BBL WATER-BBL 0 CHOKE SIZE IGAS'OIL RATIO OIL GRAVITY-AP (cor~' 28. CORE DATA Brief description of ithology, porositY, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in dupl~cate~¢~/,' 29. .MA NA OA OB NAME GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 5036 5400 5746 5959 6058 3905 4125 4236 4461 4520 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR,and time of each phase. Middle Kuparuk 31. LIST OF ATTACHMENTS · 10066 6876 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments.' Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). . · Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no corps taken, indicate "none". - "/ Form 10i407 January 30, 1986 Conoco Inc, 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 Harold Hedlund State-of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hedlund: Attached are the originals and one copy of each of the Sundry Notices required to remove the suspended status from currently active wells. Should you need additional information or have any questions, feel free to call Lynn Alexander at 694-7609. Very truly yours, Everett D. Wilson Division Administrative Manager LA/kss STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Conoco Inc. 3. Address 3201C Street, Suite 200, Anchorage, Alaska 4. Location of Well 581IFSL, 760' FWL, Sec. 18, T13N, RllE, U.M. 99503 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 6. Lease Designation and Serial No. 47438 7. Permit No. 85-62 8. APl Number 50- 029-21324 9, Unit or Lease Name Mi!ne Point Unit 10. Well Number B-7 11. Field and Pool Kuparuk River 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was brought on as an oil producing well on11-2-85, and its suspended status should be removed. 14. I hereby certify that the foregoing is true and corr~e~t to the best of my knowledge. ~ig~ed . _~- ~'-'~-~ Title Th~;;; ~/w for Commission use Date Condition~of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 October 11, 1985 Mr. C. V. Chatterton, Chairman Alaska oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed please find the "Well Completion" forms #10-407 from Conoco's Milne Point Unit wells No.~CFP-1, CFP-2, B-5A, B-6, B-7, B-8, B-9, B-lC, B-Il, B-12, B-13, B-14, B-15, and B-16. If you require additional information concerning these completion forms, please contact Jim Hand at 564-7640. Very truly yours, (~~anager of Alaska Operations lb RECEIVED oc'r lSS§ Alaska 0ii & Gas Cons. Commissl0rl Anchorage STATE OF ALASKA ALASKA._ ' AND GAS CONSERVATION C(- MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED ~ SERVICE ~] 2. Nan;e of Operator 7. Permit Number CONOCO, INC. 85- 62 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, AK 99503 50-029-21324 4. Location of well at surface 581' FSL, 760' FWL, Section 18, T13N, RllE, U.M. At Top Producing Interval 1358' FNL, 194' FEL, Section 23, T13N, RZOE, U.M. At Total Depth 1415' FNL, 765' FEL, Section 23, T13N, R10E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 59' KB 6. Lease Designation and Serial No. ADL 47438 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 4/2/85 4/15/85 4/17/85 17. Total Depth (MD+TVD) 10750' (7248') 9. Unit or Lease Name Milne Point Unit 10. Well Number i3 NO. 7 11. Field and Pool Kuparuk River Field Kuparuk River 18.PlugBackDepth(MD+TVD) 19. Directional Survey 10334 ' (7023 ' ) YES ~ NO i~ 15. Water Depth, if offshore 16. No. of Completions N/A feet MSL I 20. Depth where SSSV set 21. Thickness of Permafrost 1867 feet MD 1800 ' TVD 22. Type Electric or Other Logs Run GR-CNL-CDL-DIL-Cal-Gyro-CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 48# H-40 0 115' 17-1/2" 100 cf of Permafrost Cmt 9-5/8" 36# K-55 0 6206' 15" 888 bbls Arctic Set III 56 bbls Class G 7" 26# L-80 0 10416' 9-1/4" 76 bbls Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.2ff T,-80 10038' 9992' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10,069'-10,097' (6879-6893') MK1 10,109'-10,145' (6900-6924') lyE<2 5" Hollow Carrier 22 gram 12 spf 27. Date First Production Date of Test Flow Tubing Press. Hours Tested Casing Pressure PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) PRODUCTION FOR TEST PERIOD I~ CALCULATED 24-HOUR RATE OI L-BBL OIL-BBL GAS-MCF GAS-MCF WATERoBBL WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-AP (corel 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29 ........ . 30. 'GEOLoGIc MARKERS ' . ': FORMATION ~-ESTs NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. .. KA 5036 3905 -- MA 5400 4125 NA 5746 4236 OA 5959 4461 OB 6058 4520 M. Kuparuk 10066 6876 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed z~/~/~ ~ ~TitleErlg'i flee r' Date10-22-85 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-sku 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- lng 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: tf no cores taken, indicate "none". Form 10407 A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY CONOCO, INC. COMPANY Pad B, Well Number: 7 WELL NAME Milne Point, North Slope, Alaska LOCATI ON JOB NUMBER A0485G0243 SURVEY BY B JAHN TYPE OF SURVEY Gyro Multi-Shot DATE , F f -~'~ ~z',l 6-APR- '" '5'/40 Off (, ' ~, Uas Cb//.s' 85 OFFICE Anchorage, Alaska 2201 C. Street Suite 200 .AnchOrage, Alaska 99503 Well Number: Pad' B, Well -No: 7 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 16-APR-85 Method of COmputation: RadiUs 'of Curvature Surveyor: B JAHN Job Number: A0485G0243' A~ten: Mr. Dan Robertson Dear Mr. Robertson: We are ~enclosing the original and one copy of the Gyro Multi- Shot survey run on the above meatJ_oned well. -_ To date, the following distribution [:as been accomplished: A. 1 copy delivered 'to drilling for in-house distribution. 2 B, 9 copies noted fo:: o.~_.'[ company representatives. C 3 co,~ies for ~/W i~ermanent well W..'? wish to take this opportunity t:,.) ,~_.an~: 7fou ,_or using ?astman Whipstock and look forwa:~d to being of service :[n the future. '~e ly, cc/file cc: L.A. Dinges - Off~hore E:.:.~)icrntio~ Conoc¢~ O.G. Kiel--PoE.S. Reservoir Fection Conoco H.E. Gi].li!,~d - P.I<.O. }~,:::servo:}.~' ':~,.--,':t'i. on Conoco William Van Alert - Al~sk<-~ O]]..and C:es Cor~servati. on Co~issir~n J.L. Weaver - Chev};on U.S.A. ,. ~nc. Dave Engstrom - Chevron U.f~.A., i~'~c. Concord Office Dale Bossert -Champ!J.n PetroLeum Co. C.E. Seery~ Jr. - Readin9 :-:~nd Bates t:'etro]_eum Co. Neil Buttram - Cities Sea-vice Oil and Gas Corp. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide A t:'~'TR("~ ANF {~OMPIWY MEA:::i;URIE:D DR I F:"l- r'l E F:' "1" 1.4 A hi 13 L E FEI!:'T D M :l" IR U D R '[ F T C ID L.I R :-.7:; E V E R'I" ]; F': D i R E r": 'T' I r)N L. E N G T I-.-I D F:.: F."'T' H D M F=EET FEET R E C: T A N G I_l L. 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CI:i: ::i; 6, I c") W :i.: 1 :".:':c:,, J. 5 :::; ,'.':, 1 I 5 W :':',2,{..,(':,,. 00 '.!i!; 6 i:3:.]!', W :'?, 4 cf:, I. ,, ()!5 :::; 6 :L :i.'.'; 1 !,,? PAGE Nf'l. 2 '!::' :_--:6 1 8 70 55 5600. 00 570 cz). C' 0 5800.00 5'P el)0.00 /'-, 000. c) 0 5 5.,-i. i 5,/:, 4. 1 · '",/' .'.1 1 1'5 ::: 4 J. 5'P 41 . ,, 00 .00 ~ 00 ,00 I :E: 17. '-1.6 F; 182:3.00 S 182:3.,37 S 18:35.52 S 1 ','-":4.4-. 2:i: '.E; '445i. 14. W ._,,:,.:,, 61 N 4717. (i)2 W 4'P7:B, 1 ,_, ~'' W '. f".nl'qO~":O., :[ I'.lr".. F:'A D B., W F!' L L N 0: 7 r':; I','i::2; M I LNE I-":-' l'.., I'".I~'"~R'I"I'-'I :.'.:;LnF'IE, M E A S I_1R E D D E P T H FEE't" TRUE VERT I C:AL DEF'TH FEE]" 6, 6,,:")O. ,:..7)0 6'7 0 ("). 0 0 6, ::.'.', 0,::) ,, ()0 6,'P (")O. 0':":, 7C100. O0 '710 (-) ,, 0 C:, 7 :::'i: ,:]:, ,:]) , 'r} '::.) ,J 0 E': N 0: :ii; U B :F..; E A VER]" I CAL. DEP'TH F'EE:'T ,'.':,,."') .4.1.. 0 0 6:1. 4 ;i . 0 6 2 41.0 C) 6:3 4 :L. 0 0 ,'::, 4 4 .1.. (")(::, 7 (":, 4 :l. ,, ,:'7:, '7 i 4 :t.. ,:i:,,:} A 0 48 5 G ,:") 2.:: 4 5:: R E (": T A N G LI L A R r" 0 ri R D I N A T E S FEET ;l 5)'7 I::5 ,, 81 ::.'; ,'} 55'7 :'::i, ,.% 7 W 1'::: ::',':i;' ":'/', 53 ,,'-, "7 ":,, 'r", .':5Pi W ., ,. u ..' .... · .- .. · - . C: L 0 S U R E D I :::; T A N C E D I R F C T I 0 N FEE'T' D M 54.:34, 'i.:.'?-.: :.7 '70. 3 W 5574,71 S 7C) 29 W ':5 =- :57 '1. :':', ...... , S 7,rI)... ,:, W 584 9. 14 :::-: 7 J. 1 ,'--, W r:;':.) ::: '2 ,5,4 :":; '71 ":' :::::/:,,/.., 1. ,r') :.':; .-.;....-, .... . ....... .:, .1. / 7 0 .1. 8 ,, :3'!:.'" S 7 3 3 2 p'Al:3 E N 0, · . . - astman CONOCO. INC. PAD B, WELL NO, Z GMS MILNE PT.. NORTH SLOPE. ALASKA EASTIflAN WHIPSTOCK' INC. HORIZONTAL PROJECTION SCALE ! IN. = 1000 FEET DEPTH INDICATOR~ TVD FINAL STATION ~ DEPTH 10750 ~ID. 7248-:38 TVD ~ 3319 SOUTH 1995.92 t4EST 6805.47 ~ CLOSURE 7092.12 S 73 39 16 ~ 6840 ........ - ........ CONOCO. !~C. PAD B. WELL NO' 7 GiftS 'MILNE PT.. NORTH SLOPE. ALASKA EASTHAN WHIPSTOCK, [NC. 0 0 1000 C 2O0O 2000 4000 60OO 3000 4000 5000 6O00 7000 80CC 9OO0 10000 8OOO I I I 2000 4000 6000 VERTICAL SECTION CLOSURE 7092,12 S 7:3 :39 16 I 8000 i~A'i'A t- t L~* G2658 . VERTICAL PROJECTION SCALE I IN. = 2000 FEET Suggested form to be insert:zd in each "Active" well folder to check for timely compliance with our regulations. ERA~7OR, WELL NAME AND NUKBER Reports and Materials to be received by: Date Required Date Received Remarks Well Histo~ ~' ~:. -. , -,- . Samples .... ' Core Chips Registered Su~ey Pl , i inc!~a=io= Survey ,/~ " '~ ,:::~:-'(//%.. Dri~ S:~ %est Reports ¢-. ~'/~ .~.~. ,-~ . Production Test Reports Log R~ ~, .~/. , , l~, ~ · ~. (~/~. ,. IZ-- Digit.ed Data I .~. ~ · ~ -. ,.~ John R, Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 September 27, 1985 Mr. Robert Burd, Director U.S.E.P.A. Water Division, Region X 1200 Sixth Avenue, M/S 409 Seatt!e, Washington 98101 Dear Mr. Burd: Attached please find completion reports for Milne Point Unit injection wells B-7, B-8, B-12 and C-12. Also included are wellbore diagrams and geophysical logs for the subject wells. All four wells were issued emergency permits in accordance with 40 CFR 144.34 (a) (3) on December 21, 1984. Completion reports for other permitted Milne Point wells will soon be submitted. Please call Rod Schulz at (907) 564-7600 if you have any questions. ~Y°urs very tr~ //anager °f AL/cc:-Mr. C..Vlai~i~ti~ii~iii~iirma~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 t~N!I-ED STATES ENVIRONMENTAL PROTECTION AGENCY WASHINGTON, DC 20460 COMPLETION REPORT FOR BRINE DISPOSAL, HYDROCARBON STORAGE, OR ENHANCED RECOVERY WELL Form Approved OM8 No. 2040.0042 Approval exmlres ~-30-R6 NAME AND ADDRESS OF EXISTING PERMI~FEE CODOCO TOd. 3201 "C" Street, Suite 200 Anchorage, AK 99503 LOCATE WELL AND OUTLINE UNIT ON SECTION PLAT -- 640 ACRES ---I-~-----t- ! I I ! I I I --I I .I ~.,~.,I I I I i I I W NAME AND ADDRESS OF SURFACE OWNER State of Alaska STATE COUNTY ] PERMIT NUMBER AK North Slope Borough I AK-2ROO73-E SURFACE LOCATION DESCRIPTION SE ~4OF STAT ¥~OF SW %SECTION 18 TOWNSHIP 13N RANGEllE LOCATE WELL IN TWO DIRECTIONS FROM NEAREST LINES OF QUARTER SECTION AND DRILLING UNIT Surface _ ~ Location ~ .J-it. from(N/S} S I ina of ~Nl~ section a,d760 ft. from {E/V,n .~ , U.e of ~ s~io. WELL ACTIVITY TYPE OF PERMIT D Brine DiSDOSal D Individual [~ Enhatlced Recovery D Area D Hydrocarbon Storage Number of Wells 2 2 , Antic/Dated Daily Iniection Volume (Bbls) Inieclion Interval Estimated Fracture Pressure of In/action Zone · 75 psi/it Average t Maximum 4,000 10,000 Antic/Dated Daily Injection Pressure ~PSI) Average I Maximum 1,900 2,500 , tFee! to Feet 10,069 J. .10, .145 DeDth to Bosom of Lowermost Freshwater Formation (Feet). 3,100' (Sec UIC Permzt) Type ot Injection Fluid (Check the appropria[e block(s// DSal, Water r~ Brackish Water [~ Fresh Water D Liquid Hydrocarbon D Other Date Ordling Began ~ Date Well Comoleted April 2, 1985 IApril 18, 1985 Oate Ordhng Comolet~:l April 14, 1985 13 _ g CASING AND TUBING OD Size VVI'/Ft -- Grade -- New or Used 3/8" !48# - H 40 - New 5/8~' .. !36# - K 55 - New I 7" 126#- ~ ~0 - New 1/2" 19. ~ ~ 2~,- L _80 - New I Deottl 105 ' 6206' 10416' 9.992' Lease Nam. Milne Point Unit Name of Iniect~on Zone Kuparuk Well Number B-7 Permeabdit'y of Iniection Zone 60 - 300 md Porosity of Injection Zone 20~ CEMENT HOLE .PO Sacks Surface 2600 27~, Class krctic Grade krcticSetIII Depth + 125' 6,250' O, 75,0' . INJECTION ZONE STIMULATION WIRE LINE LOGS LIST EACH TYPE Treated Materiels and Amount Used IJmg Types Lo~lged In!erwals 10416' - 6210' Comolete Atlachments A -- E listed on the reverse. .DTL - SF~ -,Gg. CNS - GDL - CAL CNS - GR in csA. 10389' - 9500' CERTIFICATION .:'.i~,I,.,~ :~: i'.- I certify under the penalty of/aw that I have personally examined and am familiar with the information ~ubmitted in this document and ali attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, / believe that the information is true, accurate, and complete. I am a ware that there are si2nificant pena/ties for submitting false information, including the possLhility off/ne and imprisonm~.nt. (Ref. 40 CFR 144.32% NAME AND OFFICIAL TITLE (Please ty~e or p~,nr) John R. Kemp _Manager of Alaskan Operations EPA Form 7520.10 {2-S¢) ~Jit Diameter 8 1/2" B - 7 ATTACH~[ENTS A. See attached diagrams B. Pressure tested 9 5/8" casing to 2000 psi for 30 minutes with no bleed-off. Pressured up on tubing to 2800 psi to set packer, increased pressure to 3600 psi to open production vent. Pressure tested casing - tubing annulus to 1500 psi for 10 minutes with no bleed-off. Pressure tested tree to 5000 psi for 10 minutes with'no bleed-off. C. A report was submitted on May 15, 1985, which was approved on June 21,1985. D. No defective wells. T~IT l~T FTM E. Included are final prints of the ~=L-S~-,.-~R and CNS-CDL-CAL logs N SEC. 19 SI MPSO,~ LAGOON M~I NEFi'. uNiT . ........... ........... SCALE ~U ~l~S CONOCO MILNE POINT UNIT EXISTING OEV[LOPM[NT NOTEg: I. SLATE PLANE CO-ORDINAT£S ARE ZONE 4. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFS£TS TO Sir CTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. 4. LOOATEO WITHIN SECTION 18 & 19, TISN,RIIE,U.M.,AK. LOCATION I~ SECTION FRO~. S. LINE FROM W. UNE STATE PLANE CO'O RDS. NORTHINGS EASTINGS GEODETIC POSITION LATITUDE LONGITUDE 149°24' 41. 176" W. DATE 6 ,022,960,76 CHECKED 'FIELD BOOK 212' ~ 978' 6,0~?. ,911.70 572,058.98 70° ~8'22367" N. 3.6 , 82 L.K. 09'82 2' 910' 6,023,121.62 571,989.81 ?0° 28'24.438" N. 149°24' 43.149" W. 6.2,85 J. 8.S. 21-85 49'~ 1129' 6,023,077,00 572,209.10 ?0° 28'25.978"N. 149°24'36.714" W. 4.22,8Z L.K. 09-82 185'e 1158' 70° 28' 22.832"N. 149°24' 35.865" W. 4.22,82. L.K. 09'82 572,239.11 572, 178.88 6,025,193.25 571,955.~6 I II0' 68' 115' 6, 023,238.24 57 1 , 894.74 877' 581' 760 ' 6, 0:>3,702.33 57 I, 834.16 697' 731' 6, 023 , 818.63 57 I , 804. ZS 348' 819' 6,023, 470.5:> 70° :>8' 25. I P 4" N. 70028. 25.588 "N. 149°:>4' 37.570" W. TO° 28' 26.7~"N. , 848' 14902 4' 44.129' W. 6. 2~85 6,023 J. B.S. 700 28' 30.164" N. 149° 24' 47. 56 I"W .... ?0° 28' 31.311 , N. 149°24' 48.408" W. " " 70° :>8' 27.878"N. ~49°z4'45.a45" w. - " 571 ,925.13 R[GIS1[REO AND LICENSED 10 PRACTICE LAND SURVEYING IN ~H[ 5TAT[ OF ~L~SKA My SUPERws~oN. ~D 1HaT ~LL D*MENS~ONS 21 -85 # # 'B' PAD AS- BUILT WELL LOCATION Surveye0 for CONOCO SCALE : J SHEET ' I' · 400' J I O~ CO~UENTS , D~u£NSION THUS'~r' FRON N. LINE SECT. 19, ALL OTHERS FROM S LINE SECT. GEARHART INDUSTRIES, INC. June 20, 1985 Please disregard previously delivered L.I.S. tapes for Cono Milne Point Unit B-7, run on 4-13-85 as the incorrect job ticket number was used for the data file. The job ticket reference number has been changed from 304963 to 304962. This change should reflect the correct job ticket number for which the field and final logs were generated under. We apologize for any inconvenience. David Douglas Computing Center DD/sjt 139 East 515t St., Suite 102 P.O. Box 102436 Anchorage, AK 99510 Telephone (907) 562-2538 John R, Kemp Manager of Alaskan Operations Hay 29, 1985 conoco) Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (9O7) 564-7600 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Monthly Report of Drilling and Workover Operations on wells No. B?7, B-8, C-9, C-11, and C-13. If you have any questions, please call Lynn Alexander at 564-7609. Very truly yours, ohn R KeJ~ ~laskan Operations LA/vv RECEIVED JUN. 0 "Chorage' CornmiSSlor~ STATE OF ALASKA ALASKA O!L AND GAS CONSERVATION CO~IMISSION MONTHLY REPORT F DRILLING AND WO ..OVIBR OP! RATiIONS? · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 85-62 3. Address 3201 C Street, Suite 200, Anchorage, AK 99503 4. Location of Well at surface 581' FSL, 760' FWL, Section 18, T13N, RllE, U.M. 5. Elevatio, i, fe~ fi,dm, ate KB, DF, etc.) t 6. Lease Designation and Serial No. 59'KBJ ADL 47438 8. APl Number 50_029-21324 9. Unit or Lease Name Milne Point Unit 10. Well No. B No, 7 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of. May , 19 85 12. De~th at er~d o! rnor~zh, foota~ drilled, fishing jobs, directional drilling problems, spud date, remarks None. 13. Ca~ir~j or ~in~, run and quantities of c~n~r~t, results of pressure tests None. 14. Corim:j re~',,m~e arm t~rief de,;c~, iption None. 15. Lr_4~ run and d~pth wh~e run None. 16. DST dala. perforatJncj data, s,hov~s of H2S. m;isceilaneous data None. Well suspended. Completion report to follow. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO.*-"MISSION MONTHLY REPORT _ F DRILLING AND WO ..OVER OPERATIONS · Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. CONOCO INC, 85-62 3. Address 3201 C Street, Suite 200, Anchorage, AK 99503 4. Location of Well at surface 581' FSL, 760' FWL, Section 18, T13N, RilE, U.M. 5. Elevation in feet (indicate KB, DF, etc.) 59 'KB 6. Lease Designation and Serial No. ADL 47438 8. APl Number 50-029-21324 9. Unit or Lease Name Mi lne Point Unit 10. Well No. B No. 7 11. Field and Pool Kuparuk River Field Kuparuk River For the Month of. April , 19 85 12. De~th at ~ of monzh, foota~ drill,rt, fishing jobs, directional drilling problems, spud date, remarks 10,750' TD Spud 5-1-85 13. Ca¢~ ~ ~im~r ~n aM q~ntiti~ of carnet, ~ults of pressure tests Size Wt. Grade From To Cement 9 5/8" 36 # K-55 O' 6206' 888 bbls. 12.2 ppg. Arctic Set III, 56 bbls. Class G top job 15 bbls. Arctic Set I 7" 26# L-80 O' 10416' 76 bbls. 15.8 ppg. Class G 15.8 ppg. 14. Corir~j ~e~,~te ar,~o Ibrief de~c~,iCzion None 15. Lcgs_ run and cinCh wJ3ere run D!L-6,210' - 10,416' CD-CN -9,5OO' - 10,420' GR-CN '- in csg. 4,600' - 6,31'O' DIL-SN-9,972' - 10,737' 16. DST data. perforad~ da~, Cows of H2S, misceiJaneous da~ 10,066' - 10,O94' 12 JSPF 10,106' - 10,142' 17. I hereby cert,fy that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 ADDITIONAL TAPES TO: = * ! ~ CITIES SERVICE:BAKERSFIELD CA ~'-' ~ '~ ~-~-~ READING & BATES :TULSA,OK CHAMPLIN: ENGLEWOOD, CO CHEVRON USA: ANCHORAGE ALASKA OIL&GAS :ANCHORAG~CHLUMBERGER OFFSHORE SERVICES CONOCO :ANCHORAGE 5oo w. INTERNATIONAL AIRPORT ROAD CONOCO: PONCA CITY, OK ANCHORAGE, ALASKA 99502 N_o 000553' COMPUTING CENTER PRINT CENTER WELL NAME ' ~~~:~:~..~: ~;: WELL NAME · s~v~c~s · .? - OO/-/~?_q services · No. OF BOXES-~~ XO. OF BOXgS- ~OB NO. ·~~/~ ~OB NO. · ADD'L TAPES '~ ADD'L TAPES ' WELL NAME · WELL NAME · SERVICES ' SERVICES · NO. OF BOXES' NO. OF BOXES' JOB NO. · JOB NO. · ADD'L TAPES · ADD'L TAPES · WELL NAME · WELL NAME · SERVICES · SERVICES · NO. OF BOXES' NO. OF BOXES' JOB -NO. · JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER DATE DELIVERED RECE.IW~p ~B,Y , e ~a~ Cons~ Com~issior~ Anchorage GEARHART INDUSTRIES, INC. CUSTOMER ~-_,~.~0...(~ FIELD ~_~~ ~ Well Name~~~~ ~~~.: 'County~~ ~-~ State ~~ ~~ Type of Logs Distributed 0~~~ ~0~ Date ~ 25~~ Date Job Ran ~X~~ Blue Line ~ Sepia Pre-Fold [ Rolled~ Logs mai 1 ed to: PRINTS MAILED FROM 2"/100' TOp DEPTH TYPE BOTTOM DEPTH Lo'bio 5"/100' TYPE Please date and sign and return in the enclosed self-addressed and return to Conoco. ~rr - Alaska Ull & (:i;~.s Co~)s. t';orrimissJor¢ Anchorage 139 East 518t St., Suite 102 RO. Box 102436 Anchorage, AK 99510 Telephone (907) 562-2538 MEMORANDUM State of Alaska ALASYJ~ OIL A~D GAS CONSERVATION COI~'~ISSION TO: THRU: FROM: C. V/z~/~'~t ter ton Chai ~i"~a'.rb- Lonnie C. Smith ~/~.~-;<-?'~' '~ ;' Commissioner Petrole~ Inspector~ DATE: April 9, 1985 FILE NO: D.EWS. 26 TELEPHONE NO: SUBJECT: Witness BOPE Test on Conoco Milne Pt. B-7, Sec. 18, T13N,RllE,b/'~, Permit No. 84-62, Nabors Rig 27E. Saturday, Ap~-il 6, 1985: I traveled this date from Texaco's ~-6iVili~DeI~--~f~-_-_-_~ject of another report), to Conoco's t~'~ilne Point B-7, Nabors Rig 27E to witness a BOPE test. The drilling contractor was in the process of welding the casing head. Sunda , A r~i~, ~985: The BOPE test commenced at 9:00 am and was c-~ u ee at I1:0 a~ There was one failure. A valve on the choke manifold leaked; it was greased and tested to 5,000 pounds satisfac '~ ' torz~v. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on Conoco's 1.1ilne Point B-7, Nabors Rig 27E. Attachment 02-001AfRev, !0/79'~ . O&G' #4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COb~ISSION B.O.P.E. Inspection Report Inspector Operator Weii Location: Sec__/~ T/pfJR i/6 ~ ~AS~ Rig #jT~ ~ ~ Well Sign ~k . ~ Rig Visual Aud io Drillin~ Contractor Location, General General Housekeeping Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack An~ ~ numar ~reventer Pipe Rams Blind Rams ~ fi Ch6ie ~ne Valves H.C~- Valve ~ Kill L{ne Valves Check Valve ff Test Pressure 5o~o z, i .,'/t ~.~.~. !l ' Test Results:. Failures Date Weli 4~'- 7 Representative Permit # ~- ~ ~ ~ Casing Set Representative ACC~LATOR SYSTEM Full Charge Pressure Pressure After Closure / Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: ft. ~2c __ _ .:, j) psig z~ G;<~ ) psig /'/~>.~O ~ min~/~ sec. / min~f sec. Controls': Master '~1~: ::~,-~:.~ ,-.: ~;"~' , Remote~+~' Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Ok' ~'Test Pressure Lower Kelly. ~/( ~Test Pressure Ball Type ~) /~, '~est Pressure Inside BOP ~}'~i.. ~st Pressure Choke Manifold ~9,.',~ Test Pressure No. Valves /~ (~) No. flanges ~/~' Adjustable Chokes ~ m J -' Hydrauically'operated choke Test Time ~-- hrs. Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: I VA 1 ~/~ o ~j C_~ o !~-~ > ,',,~,,,~, ~, ! ~ days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor ? ./ ,: + . Inspector · ,- // ~{arch 29, 1985 James B. Fox Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point B-7 Conoco inc. Permit No. 85-62 Sur. Loc. 581' FSL, 760' FWL, Sec. 18, T13N, RllE, UM. Btmhole Loc. 1482' FNL, 914' FEL, Sec.23, T13N, R10E, IR{. Dear Mr. Fox: Enclosed is the approved application for permit to drill 'the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the .spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmen%al Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention ~i~. j±~ Fox 'r, --f 4 1 ~:.~ne Point Unit B-7 -2- i,.iarch 29, 1985 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~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. ~ 4 in the event of suspension or abandonment, please give ~h~s office adequate advance notification so that we may have a witness present. Very truly y~9urs, / //-'I,? C. V. Chatterton Chairman o f Alaska Oil and Gas Conse_~vation Commission BY ORDER OF THE COMMISSION lc Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery John R. Kemp Manager of Alaskan Operations Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 March 27, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed are the original and two copies of the Permit to Drill application for Milne Point B-7. A $100 check is being submitted with the permit application to fulfill the permitting fee requJ~rement. If you have any questions, please call Dan Robertson at 564-7635. ~/Manager of Alaskan Operations JBF/vv cc: MP B-7 Correpondence File RECEIVED '~,: ~ ~--~ ¢9 .... Alasl~,~ Oil & Cas Con~. Co,,,rm .... ALASK~ STATE OF ALASKA )IL AND GAS CONSERVATION C PERMIT TO DRILL 2O AAC 25.005 ¢IMISSION la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator - Conoco Inc. 3. Address 3201 "C" Street, Suite 200, Anchorage, BK. 99503~,/. 4. Location of well at surface 'o~....~ 581' FSL, 760' B~L, Sec 18, T13N, RilE, U.M. ej2 At top of proposed producing interval r~' 1300' FNL, 300'FEL, Sec 23, T13N,RiOE, U.M. d;, ~' At total depth ;9~ -~3' '-- . T13N. RIO~. U.M ~' '~ 1482' FNL. 914' FEL; Sec 23; ~ ' 6. Lea~e designation and serial no. 5. Elevation in feet (indicate KB, DF etc.) KB 59' Pad 24' AD~ 47437 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number 8086-15-54 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 rn~ NW of P~dhnr.qm 16. Proposed depth (MD & TVD) 1~.7~0' Wn i 19. If deviated (see 20 AAC 25.050) i KICK OFF POINT 500 feet. 121 mil es 3800_ ~ feet 17. Number of acres in lease feet ?; 560 120. Anticipated pressures MAXIMUM HOLE ANGLE 52Ol(see2OAAC25.035(c) (2) Proposed Casing, Liner and Cementing Program SIZE Hole 9. Unit or lease name Milne Point lt~it ,~4~] Well number B No. 7 11. Field and pool Kuparuk River Amount $200..000.00 15. Distance to nearest drilling or completed B-11well 120 ,feet 18. Approximate spud date ~,~ psig@ ~,~, Surface psig@o,700! ft. TD (TVD) Casing CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Weight I Grade Length MD TOP TVD MD BOTTOMTVD (include stage data) I 22. Describe proposed program: ±60 B~, Arctic Pac Conoco Inc. proposes drilling the subject we].], a.s a delineation we]]. in the Kupar~ River field. Mud system will: be non-dispersed, ].ow solids with a minimum mud weight in surface hole of 9.0 ppg to a maxJnum of 9.8 ppg. Mud weight at T.D. w~]] be 10.2 ppg. A 20" 2000 psig diverter will be instal]ed on the ]3 3/8" conductor for dril]~n the surface hole.' A 13 3/8" 5000 psig RSRRA BOPE stack wJ ] ] be used on surface casing. Pressure tests w~ ] ] be performed as per State Regulations. ~~n anticipated surface pressure ~¢as based on a fluid column at T.D. of 80% gas and 20% oil. Casing will be pressure tested to 1500 psig. B No. 7 J s no closer than 120' from another wel]bore. The closest we]lbore will be B No. 11 which w~]] parallel tbJs we]]bore at a distance of 120' to the B-7 kickoff point at 500'. B-il w~]] kickoff at 2000¢. The B-7 well will cross over the B-Il we].], as it Js drilled in a southwest direction. Arctic pack will be placed in the 7" x 9 5/8" annulus after disposing o~ test oil and excess drill~ fluid. The perforating and completion assemblies wi]]. be run in the we] ]. before releasi~. t~ H~l~e ~e Thru ~rat!no m_~_= ,;fi_!! be det~ated _~-J the ,.,¢~ f!~.; tested op..ce ~h~ d_~]]~_n.~ rJ~ ~21 ~-6~*~tif'-ym[~%t t6~'~ror~(~i"~s tru~'~n~ correct to the best of my knowledge ......... SIGNED Ll~t~/i~ '~. ~ TITLE ~',~,,4 .... ,,~, m,,~1~,~4,,,-- DATE (~¢7~e.~loW for Commission use ~'8 ...... ~5 CONDITIONS OF APPROVAL Samples required i-lYES ~NO Permit number Mud log required. []YES ~lxlO Directional Survey required I APl number t XYE$ [-]NO 50- ~)~.q~ ~2/3 ~./-~ SEE COVER LETTER FOR OTHER REQUIREMENTS I Approval date March 1985 ,COMMISSl ONER DATE /~, by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 SUPPLEMENTAL DATA SHEE~i APPLICATION FOR PERMIT TO DR]iLL Conoco et al - Milne Point No. B-7 Conoco Inc. 3201 "C" Street, Ste 200 Anchorage, Alaska 99503 I. CEMENTING PROGP~M A~ The 13-3/8" conductor wS]l be set at 80' be] ow the surface (115' K.B.), then cemented to the surface with permafrost cement. Be The 9-5/8" surface casing will be cemented with ±1710 sacks of Permafrost "E" cement followed by ±275 sacks of Class "G" cement. A top job will be done if cement 5s pot circulated to the surface. Ce The 7" production casing wi].], be cememted in two stages. The first stage will consist of ±370 sacks of Class "G" cement pumped around the casing shoe (estimated ±1600' of annular cement, based on 100% excess over gauge hole). The secondary cement job will consist of ±180 sacks of permafrost type 'C' cement followed by 60± barrels of Arctic Pack pumped down the 7" x 9 5/8" annulus. II. ANTICIPATED GEOLOGY 0' - 4500' Surface conglomerates, clay, silt and sand sequences. EstSmated base of permafrost at ±].700'. 4500' - TD Predominately shale until the Kuparuk Sands - expected at ±6600' subsea TVD. III. FORM~ATION EVALUATION Ae Wireline logs for the 8~" _ 2 hole (from T.D. to +1000'above tt~e Kuparuk interval) will include: Dual Induction log; Spherically Focused log; Litho DensS. ty log; Compensated Neutron log - Gam~a Ray. IV. DRILLING FLUIDS A b. igh viscosity fresh water ge]_ (.non-dispersed) mud system will. be used from 0'-1000'. i-:: :' i'-: i Vo A low solids non-dispersed gel/water mud system w~,]l be used from 1000'-T.D. DIRECTIONAL PROGRAM The well will be drill.ed to a proposed KOP of 500', then angle will be built in a south 73.5° west direction. The closest that the B-7 wellbore will come to another we]lbore is from surface to KOP where the proposed B-7 well will be 120' northwest of the B-il well. A b~ tool is to be run while drilling for surveying purposes. Final hole angle will be 51.7°. The existing B-9 well is 240' from the proposed B-7 well. 13~-I~'W~['~_-NO'. 7' PROPOSED MILNE PT.. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. SURFACE KOP $ 10 15 1 000 2000 TVD=500 TMD=500 DEP=O BUILD 2 1/2 DEG PER 100 FT 25 3O 4,$ 5o EOB TVD=2298 TMD=2568 DEP=871 ~000 4000 5000 6OO0 7000 _ 8000 _ I 0 1000 AVERAGE 51 DEG ANGLE - 41 MIN . TARGET TVD=6835 "TENTATIVE' 9 5/8' CSG PT TVD=4619 TMD=6311 DEP=3808 TD I 2000 I I I :3000 4000 5000 VERI' T.. C^L SECT I ON 6000 I 7000 HORIZONTAL PROJECTION SCALE 1 IN. = 1000 FEET CONOCO. ! NC, PAD B. WELL NOs 7 PROPOSED' MILNE PT.. NORTH SLOPE. ALASKA EASTHAN WHIPSTOCK. INC. 1000 z 1 000 I · ','- 2000 3000 4000 8000 7000 6000 5000 I I I '1'ENTAT[VE' TD WEST-EAST 4000 3000 L I 2O00 I 1ARGET TVD=6835 TMD=9886 DEP=6613 SOUTH 1881 UEST 63~0 TARGET LOCATION~ 1300' FNL, 300' FEL SEC. 23. T13N, RIOE S 73 DEG 29 MI N W 6613' (TO TARGET) 1000 0 I SURFACE LOCAT!ON ~ 581' FSL, 760' FWL SEC. 18, TI3N, RItE 1 lOOo I lOCATION IN SECTION FROM S. LINd FROM W. UNE H L yes" · 552' .97-9 ' -9so' I 0 37-'-0 - IOO8 STATE NORTHINGS ~ o~3,77E-;41 - - SEC. 19 SIMPSON LAGOON T 12l4 SCALE IN MII.F.S · o CONOCO MILNE POINT ' UNIT EXISTING .DEVELOPAIENT -. -. I. STATE PLANE CO-ORDINATES ARE.20NE 4. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. ~.' 'OFFSETs TO sECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. PLANE CO~RD$. EASTINGS GEODETIC LATITUDE POSITION . LONGITUDE - - . i -149'- z4'- 47:6[0 to DATE CHECKED CERTIFICATE OF SURVEYOR : I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS .PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION, AND THAT Ai.t.'DIM/NSIONS AND OTHER DETAIL~ ARE CORRECT. - .- · 572~0z2,.65 STZ~ tl:j:-4...q 572, o $'~. 2_o 540.2.5 . . 149'-24'-41.99~ ,~ Iz39:24'-40.~,5uu AS- BUILT ~ELL LOCATION CONOCO COMr/NT$ I ' S[CT, t9 ~ ALL ~HERS FROM S. LINE SECT. . . FIEL[~ BOOK . NOTE: I. li11)RAUllC CONTI~*JL S¥STEU FOR BOP STACK 8, CHOKE' MAhlFOLO TO INCLUDE (5~ STATION CONTROL MANIFOLO LOCATED REMOTELY WITH 3000 PSI ACCUMULATOR 8 160 GAL. RESER','OIR a AUX. ENERGY SOURCE. STA CONTROL MANIFOLD PLUS VARIABLE CHOKE CONTROL TO BE LOCATED ON RIG FLOOR. .. 2. KILL R CHGKE UANIFOLDS TO MEET APl RP53 CL. 5u STD$. 3. klLL UANJFOILO SIZE- RATING Z'- 5000 4. CHORE MANIFOLD SIZE- RATING .~'- 5000 'i FROU MUF IMP KILL 'MANIFOLD J~ FROM REMOTE HIGH ~~yDRAU REMOTE PRESSURE GAGE SENSOR PRESSURE PUMP ~ LIe CONTROLLED REMOTE OPERATED . ~ DRILLING SPOOL .. ~k;~~HYDRAULIC CONTROLLED REMOTE OPERATED . REMOTE PRESSURE GAGE SERSOR ! ADJUSTABLE CHOKE ADJUSTABLE CHOKE CHOKE MANI FOLD __ VARIABLE CHOKE REMOTE __ CONTROL TO SHALE SHAKER BLEED LiNE TO PiT TO ATMOSPHERIC MUD/GAS SEPARATOR CHOKE & KILL MANIFOLDS FOR ClS/8'~ & 7" OD CASING BOP STACK E OP ,)ANIFOLD LAYOUT - CONOCO, INC. : CONOCO IN~. MILNE POINT UNIT 20" DIVERTER STACK Fill-~p Line 120'' 2000 psi ! ! Annular I [~Preventer HCR · HCR ValveL Valve Flow Line 6" * - m ,~__] Drilling i. * Relief Line ~ ~) ,S, pool ( ~ 6" Relief Valve ~2o x 2o" FI 2000 psi ~ Diverter Quick ~Connect Assembly ' "i Saver Sub ~'~ . ~~ Assembly - · 'J ~ Starting ] [ ." ::~ ~_ Head -: ' - 13 " 1. Relief lines from the drilling spool will be routed for downwind diversion. 2. Hydraulic control system will be in accordance with AP1 specifications and AOGCC regulations. 3. Both HCR valves will open when the preventer closes then either one may be closed. ' * Depending on rig contracted, the two 6" lines may be replaced by a single 10" line with a downstream tee. DRG 7-17-84 CONOCO INC. MILNE POINT UNIT BOP STACK Fill-up Linel ) Preventer Flow Line (1) B.O.P stack size rating meets API RP 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated (2) BOPE to be operated on each trip --:' & pressure tested weekly. (3) Hydraulic control system for BOPE to include (5) station control . manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. (4) Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. (5) Choke and kill manifolds shown seperately to meet AP1 RP 53 class 514 requirements. RAM 13 5/8"- 5000 RA>I-- 13 5/8" - 5000 3" - 5000 Side Outlets ~ ~~3 5/8"- 5000 · 2"- 5000_ q~ ~ Side Outlets~ .... 2~0<~ '- ,, ~ ~rooLk--' 11" - 5000 S±de Outlets ~SPOO~_~liMI ~. '- .il., . _ ' 33/8 7.-°; CSG o- . . . ;~. ~-.o: .. a'o -. 2256 0 0 0 0 97'1. 2121 2332 2176 CONOCO, INC. PAD B, WELL NS7, MILNE PT., ALASKA 0 o 0 0 1815 2009 1646 1835 1965 o ~,e9 crFp) 31e4 ("rye) 2990 ",.. AFF[-~oY.. [:,~C~": 1 657 1 474. 1619 179~ 0 200 N I00 SURFACE WELL N~- 7 200 300 I0 4OO S CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~>~ '''~''~ ~ ITEM APPROVE DATE YES NO REMARKS (1) Fee _ _~x)~ ~'Z~'f~( (2 thru 8) (8) (9 thru 12) 10. ;,/' _,~ ' . f ' I':,..: > 7: ': :' 1 1 (10 and 12)' 12. (13 thru 21) · (5) BOPE :,,'.,,,,.,.' (22 thru 26) 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 .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. 8. 13. 14. ].5. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is operator the only affected party ................................. ~ Can permit be approved before ten-day wait .......................... ~ Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ 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 ..................... .:i.,,",.:: Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst..' ':." Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ '."~':.- Is a diverter system required ....................................... ', Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to '::,(::~,'.? psig .. .'";~ Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ..... % ........................................ 4:.77/ Additional Remarks: ~)::!",~,( :i::'.''''~ :,..,",..' .,::'..:' ./:.:-~ :'/.: .... ..' o r.~ ~-] Geology: HWK WVA JAL ,,, 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. RECEIV6D Alaska Oil'& Gas Cons. 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