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Home My WebLink About186-005MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 11, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC B-20 MILNE PT UNIT B-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/11/2024 B-20 50-029-21524-00-00 186-005-0 W SPT 6913 1860050 1728 2218 2223 2232 2234 106 105 106 105 4YRTST P Sully Sullivan 4/22/2024 tested to 2850 for 500 psi dp 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT B-20 Inspection Date: Tubing OA Packer Depth 328 2869 2799 2786IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240423155503 BBL Pumped:2.6 BBL Returned:2.6 Tuesday, June 11, 2024 Page 1 of 1           MEMORANDUM TO: Jim Regg P.I. Supervisor 2%, 4/kw FROM: Matt Herrera Petroleum Inspector I Well Name MILNE PT UNIT B-20 InSp Num: mitMFH2O0421142719 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April 23, 2020 SUBJECT: Mechanical Integrity Tests Hdcorp Alaska, LLC B-20 MILNE PT UNIT &20 Src: Inspector Reviewed By: P.I. Supry 'P NON -CONFIDENTIAL Comm API Well Number 50-029-21524-00-00 Inspector Name: Matt Hemem Permit Number: 186.005-0 Inspection Date: 4/16/2020 ' Packer Depth Well s-20 - Type Inj W - TVD 691; Tubing PTD 1860050 Type Test SPT Test psi 1 na IA BBL Pumped: 2 BBL Returned: 2 OA Interval 4YRTST P/F P Notes: IA Pressure tested to 2400 PSI Per Operator based on Tubing pressure. Pretest Initial 15 Min 30 Min 45 Min 60 Min I->66 lz6a' t27o - [271 306 2405 2331 - 2316 - 209 209 209 209 Thumday, April 23, 2020 Page I of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,April 20,2016 Jim Regg P.I.Supervisor �Prec 4(z6C1( SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC B-20 FROM: Bob Noble MILNE PT UNIT KR B-20 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Tee--- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR B-20 API Well Number 50-029-21524-00-00 Inspector Name: Bob Noble Permit Number: 186-005-0 Inspection Date: 4/16/2016 Insp Num: mitRCN160416165931 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min T eIn Well� B-20 yP J w TVD 6913 - Tubing' 2029 2030 2028 2027 2027 PTD Type Test Test psi IA 1860050 SPT 1728787 - 3025 , 3033 . 2997- 2995 Interval 4YRTST P/F I P V OA 252 - 250 250 250 250 . Notes: SCANNED SEP 2 7 2016 Wednesday,April 20,2016 Page 1 of 1 by • `' �! � ' , . mi l's BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519 -6612 Main 907 564 5111 June 5, 2012 Cathy Foerster RECEIVED Chair, Alaska Oil & Gas Conservation Commission JUN 2012 333 W. 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 AOGCC Re: Milne Point Field, Kuparuk River Pool, MPB -20 Sundry Number: 311 -385 lq ()— °CIS- Dear Ms. Foerster: Enclosed is an interpretive report of a water flow log run in water injection well MPB -20i. The water flow log was performed to comply with the AOGCC Sundry Number 311 -385. The report summarizes the findings from the water flow log and temperature log. Sincerely, Jessie Chmielowski Milne Point Petroleum Engineer st,,AidtED JUL 0 9 1012 Encl. • • Water Injection Well MPB -20i WFL Interpretive Report Prepared for the AOGCC 5 June 2012 Purpose: Milne Point water injection well MPB -20i was placed on water injection on April 11, 2012. A water flow log (WFL) was performed on the well on April 30, 2012. The WFL was performed to comply with the AOGCC Sundry Number 311 -385 approving conversion of the well to injection. This report summarizes the findings from the water flow log and temperature log. The logs were run to demonstrate confinement of injection to the approved interval. A witnessed MIT -IA passed on April 22, 2012. Summary: During the WFL, stop counts were taken at 7,787 -ft, 7,837 -ft, 7,887 -ft, 7,937 -ft and 7,991 -ft Measured Depth (MD). Logging was performed with the well injecting at an average rate of 2,750 bwpd and a well head injection pressure of 150 psig. The minitron was set to detect upwards flow in channels behind the casing with a minitron on -time of 10.0 seconds and a minitron off -time of 90.67 seconds. Log :; WFL tr. Stop • "Flow Velocity Velocity WFL "" WFL File Detector Depth. ' : Detected' - (ft/min) Error " l ;= ft . U ftlmin time(s) times) 28 RST - Near 7,787 Yes 4.0 - 10 90.67 27 RST -Near > 7,837 No F - 10 " h . 00, 0 26 RST - Near 7,887 U nknown 2.8 0.3 10 90.67 24 RST -Near 7,937 No 7S, - 0.8 5227 23 RST -Near 7,937 Unknown 2.4 0.5 10 90.37 25 RST - Near:: 7,991 UnKnovm 1 2.6 0 5 =10 90.67 : 21 RST -Near 7,991 Unknown 4.5 0.5 10 90.67 Explanation: When a water flow log is run in a well with low fluid velocity, the computerized data analysis is not a reliable indicator of whether flow has been detected behind pipe. For the MPB -20i water flow log, the individual station summaries were reviewed and verified by myself and a well intervention engineer who is a former Schlumberger E -line engineer. No flow was detected behind pipe at stop depths 7,937 -ft and 7,991 -ft which are below the tubing packer at 7,927 -ft. For the three stop depths above the tubing packer, 7,787 -ft, 7,837 -ft and 7,887 -ft, anomalous upward flow was detected due to localized convection currents in the inner annulus. The temperature log with warm back passes showed no evidence of flow behind pipe outside of the permitted injection zone. The top of the permitted injection zone in the Kuparuk reservoir for well MPB -20i is 7,824 -ft MD. Thus, the mechanical integrity of the casing and down -hole cement for water injection well MPB -20i has been demonstrated. 9 /(jYj'' Jessie L. Chmielowski 5 June 2012 1 . • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION • MAY 2 5 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Convert To Injector Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Development © Exploratory ❑ 186 -005 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: . Anchorage, Alaska 99519 -6612 50- 029 - 21524 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADLO- 047438 MPB -20 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — 1 Milne Point Field / Kuparuk River Pool 11. Present Well Condition Summary: Total Depth measured 8295 feet Plugs measured NONE feet true vertical 7196 feet Junk measured 8047,8064 feet Effective Depth measured 8146 feet Packer measured 7927 feet true vertical 7082 feet true vertical 6913 feet Casing Length Size MD TVD Burst Collapse Structural . Conductor 84' 13 -3/8" 48# H -40 24' -108' 24' -108' 1740 750 Surface 5011' 9 -5/8" 36# K -55 23' -5034' 23 .,, 3520_ , 2020 Production 8248' 7" 26# L -80 22' -8270' 22' -7177' 7240 • 5410 Liner Liner Perforation depth Measured depth SEE ATTACHED feet SOWED JUL 0 3 2012 True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 21' -7957' 21' -6936' Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker HB PKR 7927' 6913' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 2421 18 14. Attachments: 15. Well Class after work: . Copies of Logs and Surveys Run Exploratory Development ❑ Service ® Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: „ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ II WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -385 Contact Nita Summerhays Printed Name Nita S - rhays Title Petrotechnical Data Technician Signatur= ,d �„ i y/ _ Phone 564 -4035 Date 5/25/2012 ■ /- �GMS MAY 2 9 2012 Form 10-404 Revised 11/2011 6/5/74 74,' Submit Original Only MPB -20 186 -005 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPB -20 1/27/86 PER 7,994. 8,013. 6,964.9 6,979.66 MPB -20 1/27/86 PER 8,017. 8,047. 6,982.76 7,005.97 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • MPB -20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/2/2012! * ** WELL S/I ON ARRIVAL * ** (tree replacement prep) RAN 1.72" CENT & SAMPLE BAILER. S/D ON TOP OF PATCH @ 4855' SLM. 'TAGGED BOTTOM @ 8017' SLM. RAN 1.625" GAUGE CARRIER W/ DUAL SPARTEK GAUGES.RAN AS PER PROCEDURE (see log for depths). * ** CONTINUE ON 4 -3 -12 * ** 4/3/2012 * ** CONTINUED FROM 4 -2 -12 * ** (tree replacement prep) SET 3.5" WHIDDON @ 4882' MD. PULLED 1" LGLV FROM ST #6 @ 4239' MD. PULLED 1" LGLV FROM ST #7 @ 3522' MD. PULLED 1" SO FROM ST#8 @ 2882' MD. SET 1" DGLV STA #8 @ 2882' MD SET 1" DGLV STA #7 @ 3522' MD LRS LOADED I/A (see Irs log). SET 1" DGLV IN ST#6 @ 4329' MD. LRS PERFORMED MIT - I.A,PASSED (see Irs IQc). PULLED 3.5" WHIDDON FROM 4882' MD (empty). DRIFT W/ 2.85" NO- GO,LOCATED © 474' SLM. SET 2.813" CSA -2 PLUG @ 499' MD. *** CONTINUE ON 4-4 -12 * ** 4/3/2012 T /I /0= 1150/1120/584. MIT -IA PASSED to 2000 PSI. (Injection Cinversion) Loaded IA w/ 125 bbls inhibited KCL. Freeze protected w. 65 bbls diesel. S -Line set DGLV. Pumped 4.6 bbls diesel down IA to reach test pressure. Loss of 88 psi 1st 15 min. Loss of 32 • si 2nd 15 min. Bled IA to 0. Continued on 04- 04 -12. 4/4/2012 Continued from 04 -03 -12 MIT -T PASSED to 2000 psi Pumped 2.2 bbls down Tbg to reach test pressure. Loss of 168 psi 1st 15 min. Loss of 23 psi 2nd 15 FWHP=0/0/610. 4/4/2012 * ** CONTINUED FROM 4 -3 -12 * ** (tree replacement prep) LRS PERFORMED MIT - T,PASSED (seel Irs loq). ***WELL LEFT S/I ON DEPARTURE * ** 4/4/2012'Well shut in on arrival. Pressured tubing up to 200 psi against downhole CSA -2 plug, verified barriers ( SSV / Swab), rigged up lubricator and set TWC. Verified barriers (CSA -2 plug, TWC), then replaced tree with like for like Cameron FL 3- 1/8" tree. TQ'd to spec and P/T'd 300 low and 5000 high for 5 minutes each. Verified barriers (Swab / SSV) R/U lubricator, PT low 300 high 3500 (charted) for five min. each. Pulled TWC. 4/6/2012 * ** WELL S/I ON ARRIVAL * ** (pull plug) PULLED 2.813" CSA -2 PLUG FROM 499' MD. * ** WELL S/I ON DEPARTURE * ** Pad 0. Notified 4/9/2012 Pressure test injection line to 3600psi. 4/22/2012 T/I/O= 0/680/549 temp =120 ** MIT -IA to 2000 psi (AOGCC witness- Matt Herrera) PASS Rigged up'to IA and pumped 1.2 bbls diesel to reach test pressure. IA lost 90 psi in 15 min's, 20 psi in 2nd 15 min's, for a total loss of 110 psi in 30 min's. Bled back +/- 1.2 bbls. * *Swab valve closed, Well on injection on de • arture ** FWHP's= 0/650/550 • • FLUIDS PUMPED BBLS 3 DIESEL 3 TOTAL ' TREE: 3 1/8" - 5M FMC M P B -2 0 w/ 3 1/2" Otis Quick Union KB Elev. = 59' Nabors 27E GL Elev. = 35' Nabors 27E WELLHEAD: 11" 5M FMC w/ 3 1/2" 'H' BPV profile. A R C ; T Camco TRDP -1A -SSA SCSSV 1 499' I (2.812" ID) 13 3/8 ", 48 #, H -40 108, 4 C , PELP r P a Note: The Camco TRDP -1A -SSA was locked out of service 10/31 /95. C 9 5/8 ", 36 #, K -55 5034 4K M BTRC 1 " x 3 1/2" McMurray FMHO w/ BK lat :h r t, # and tvd dg KOP @ 2500' 9 2185' 2185' 0 MAX Hole Angle: 8 2882` 2881 ` 8 41.5 DEG @ 4600' V G V 7 3522' 3492' 24 Bak :; "/ 6 4239' 4087' 37 1,83" minn ID. a 5 4896' 4588' 40 Differential psi rating —25 ;psi„ X882 *4* 5555' 5095` 39 3 1/2" , 9.3#, BTRS, L-80 TUBING l 0 3 6213' 5598' 39 DRIFT ID: 2.867" = 2 6871 ` 6100` 41 CAPACITY: 0.0087 BBL/FT I 1 7555' 6623' 39 7" , 26#, L-80, BTRC Casing DRIFT ID: x.151 „° Note: Station 4 @ 5555 has broken latch, No -Go is still attached to DMY CAPACITY w/ th':.0264 bpf valve. Casing RA Tag 1 7723' X IP Baker `PBR' Seal Assy (3.00” ID) 1 7914' I . Baker `HB' Packer (3.0" ID) 1 7927' I Tubing Tail Jet Cut (9 -8 -90) 1 7957` I PERFORATION SUMMARY _ Uo .- I _ (DIL Log dated //) _ o Zone Size SPF MD' TVD' 0 1 _- Fish:Est. Top of Tubing Tail 8047' 0 Est. Top of Pert guns 8064' MK -1 5" 12 7994' - 8013' 6965' - 6980' 0 1 MK -2 5" 12 8017' - 8047' 6983' - 7006' 0 _ PBTD (Float Collar) 1 8146` - 7" 26 # Shoe 18270' DATE REV. BY COMMENTS MILNE POINT UNIT 9/25/06 M. Ross Convert drawing to Canvas WELL MPB -20 API NO: 50- 029 -21524 BP EXPLORATION (AK) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg � 5151(2, DATE: Monday, April 30, 2012 P.I. Supervisor �� j SUBJECT: Mechanical Integrity Tests j I BP EXPLORATION (ALASKA) INC B -20 FROM: Matt Herrera MILNE PT UNIT KR B -20 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name MILNE PT UNIT KR B - 20 API Well Number 50 - 029 - 21524 - 00 - 00 Inspector Name: Matt Herrera Permit Number: 186 - 005 - Inspection Date: 4/22/2012 Insp Num: mitMFH120423134227 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B -20 - Type Inj W TVD 6913 " IA 680 2040 - 1950 1930 . I PTD 1860050 - Type Test SPT Test psi 1728 OA 552 556 554 553 . Interval MTAL P/F P -' Tubing, 0 0 0 0 Notes: MITIA retested after well stabilized and prior failure earlier. JUN l 2 2,61 Monday, April 30, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg � � _ DATE: Monday, April 30, 2012 P.I. Supervisor ` c � 3 1� 7/ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B -20 FROM: Matt Herrera MILNE PT UNIT KR B -20 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -0 rC- — NON CONFIDENTIAL Comm Well Name MILNE PT UNIT KR B - 20 API Well Number 50 029 - 21524 - 00 - 00 Inspector Name: Matt Herrera Permit Number: 186 - 005 - Inspection Date: 4/22/2012 Insp Num: mitMFH120423133657 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well? B - 20 Type Inj W ' TVD 6913 IA 680 2035 , 2010 1990 - 1950 1920 PTD 1860050 - Type Test SPT Test psi 1728 OA 549 549 552 552 550 548 J Interval INITAL B PIF 1 F Tubing o 0 0 0 I 0 0 Notes: Initial MITIA on this well. Producer converted to an injector. IA pressure would not stabilize will do a retest. IA tested to 2000 psi. Formation not pressured up reflecting "0" psi on tubing. 1 JVN 12 LU1L Monday, April 30, 2012 Page 1 of 1 DATE: 17- May -12 Stephanie Pacillo TRANS#: 5955 Data Delivery Services Technician " , V, MakanaIs.Bender Schlumberger Oilfield Services N Natural Rescilrces Techntcian II Data & Consulting Services ' - - `- - 1l ' ' ` , �, : " 2525 Gambell St, Ste. 400 Anchorage, AK 99503 1E : Office: (907) 273 -1770 WELL SERVICE OH RESERV CNL MECH LOG DESCRIPTION DATE B/W COLOR ELECTRONIC {� f * a ' a,,, i 71.1-'41 ° , . Pd w ,�7 , .: - i, {'" ift, k- a iff,: ... '1,.,1ti.�. „,, w ,,, `"'! , .. , . _ ..- j MPB -20 C4W7 -00008 X WATERFLOW RST LOG 30- Apr -12 1 1 G -09B BD88 -00204 X MEMORY PPROF W GHOST 20- Mar -12 1 1 G -09B BD88 -00204 X MEMORY CNL BORAX IPROF 22- Mar -12 1 1 16 -22 BX69 -00028 X PPROF W GHOST DEFT 22- Feb -12 1 1 P2 -39 BYS4 -00024 X USIT 26- Mar -12 1 1 OWDW -C C2JC -00013 X USIT W CBL 23- Apr -12 1 1 J -26 C2JC -00015 X LEAK DETECT LOG 7- May -12 1 1 II , X X Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 JUN 1 '1.112. c4. Iv 1 N0 kfl • • c)) 1 A'T' l a' ALA 'EA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Jessie Chmielowski Petroleum Engineer r O BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Kuparuk River Pool, MPB -20 Sundry Number: 311 -385 Dear Mr. Chmielowski: �, ' ? 2, ; < 2. ;1 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair ri DATED this Z day of December, 2011. Encl. ,� • .tio I 1 EC �V D TE OF ALASKA 1 0 1(- ' 16 ?fit ` ALASKA OIL ANI S CONSERVATION COMMISSION I APPLICATION FOR SUNDRY APPROVALS Alaio{a Lit.::.., e;. ornmission 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change 43 r eii 'Pidgram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: CONVERT TO INJECTOR N 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development 0 - Exploratory ❑ 186 -0050 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21524 -00 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No ❑ MPB -20 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 047438 • MILNE POINT Field / KUPARUK RIVER Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8295 . 7196.1 8146 7081.96 NONE 8047, 8064 Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 13 -3/8" 48# H-40 24 108 24 108 1740 750 Surface 5011' 9 -5/8" 36# K -55 23 5034 23 4693 3520 2020 Production 8248' 7" 26# L -80 22 8270 22 7177 7240 5410 Liner Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 0 7994 - 8013 6964.9 - 6979.66 3 -1/2" 9.3# L -80 21 7957 0 8017 - 8047 6982.76 - 7005.97 Packers and SSSV Tvae: 3 -1/2" Baker HB Packer Packers and SSSV MD and TVD (ft): 7927 6913 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service la • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/27/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 ` GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jessie Chmielowski Printed Name Jessie Chmielowski Title PE Signature -Q� n Phone Date ( �. _ 564 -5015 12/13/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test [ Location Clearance ❑ Other: ¥ wFL• (L.. a ilot.) /O ) re- i cc.2J►tY Subsequent Form Required: / 0-4/Coq APPROVED BY a i Approved by: /44 2 Z 1 l COMMISSIONER THE COMMISSION Date: MS E C 22 20 ' /z./ /t ° j 1 Form 10 -403 Revised 1/2010 0 RIG 1 N A L - ® '�/�/ �/ Submit in Duplicate / 1 6 • Milne Point B -20 (PTD 186005) Current Status The Milne Point well B -20 was drilled and completed as a Kuparuk formation �` gas -lifted producer in January 1986. The well has been shut in due to gas handling limits at the facility which caused this well to be uncompetitive. MPB -20 was last online in 2009, and the well tested at —40 bopd, 94% WC and 26 scf /stbo GOR. MPB -20 has no known casing problems. The Base Management team's (with approval from the Reservoir Management) plan forward is to convert well MPB -20 to B and C sand injector in the Kuparuk pool. The conversion will increase injection capacity in the hydraulic unit, establish new streamlines between wells and better support producers MPB -15 and MPB -16. Completion MPB -20 (PTD 186005) enters the Kuparuk formation at 7995' MD. A 9 -5/8" casing was run to 5034' MD and cemented to surface with 456 bbls of 12.3 ppg Permafrost "E" cement and 56 bbls of class "G" cement with 3% NaCI and 1% CFR -2. About 160 bbls of cement returns were seen at surface and the plugs bumped with floats holding. A 7" production casing string was run from surface to 8270' MD. The production casing was cemented with 55 bbls of 15.8 ppg class "G" cement with 1% CD -31. Plugs bumped with floats holding, and the estimated top of cement is 7100' MD. Although no cement bond log was run after the — 7 re c Q 5 cementing operation, we are confident that there is competent cement isolation itr` 1 " on both the production and surface casing to facilitate a conversion from producer to injector. The well is perforated in the Kuparuk B and C sands. .2.t 4.4 Plan Forward: 1) Obtain Sundry for conversion to water injection 2) Complete water injection header tie -in 3) Place well on water injection (confirm AOGCC approval prior to injection) 4) AOGCC witnessed MITIA once injection has stabilized cor,wr vehr 74/090 4 /'ni ,9e - d a ' 4 �PC /A/41 2u/ 112 4c4c1`i6 „d 1 ncieq; LvD,fr ��od�a;o.4 v�,s,4 %� . , ' ( foc/Icxoti wtit COff /en7 6 ,016v v J0r 9 ^- Wo MP Cdr Wtif buts 95 t g .4rtemfrf ib pit f ��'F well did A �lO �rf� Oh s1CC.SfC, /. (0,✓erT%�j 4; wet/ b S CC"`� /o/ W i d / xn, fe CAW, from 143- 'of Tie 100 • of f / /s7i • Area of Review — Milne Point B -20 (Permit# 186005) This Area of Review is required prior to the conversion of well MPB -20 from a producer to a water injector. This AOR discusses wells within 1 /4 mile of the well's entry point into the Kuparuk Formation to the bottom of MPS -20 well bore completion. Two other wellbores, MPB -01 and MPCFP -2, enter the Kuparuk formation in this area of review. The tables below illustrate the wells within the AOR, distance from MPB -20, completion details, and annulus integrity /cement conditions based on in -depth review of each well. Distance -1114me F ; , e PTD (feet) y � ,, � „ nnulus Inte•rity MPB -20 186005 0 TOC estimated at 7100' MD — 0 C MPB - 01 180075 980 TOC estimated at 1500' MD, CBL dated March 1981 MPCFP -2 184242 965 TOC unknown Table 1: Table showing distance & annulus integrity of wells within AOR Hole Vol. of Well Name Casing Size Cement Kuparuk depth (MD) Kuparuk depth (TVDss) MPB -20 7" 8 -1/2" 55 bbls 7995' 6906' MPB - 9 - 5/8" 12 1/4" 183 bbls 7169' 6929' MPCFP -2 7" 8 1/2" 85 bbls 7787' 6908' Table 2: Completion Detail Well MPB -01 (Permit # 180075) was completed in May 1981. While the original wellbore crossed the Sag and Kuparuk formations, it is now a Prince Creek Reservoir water source well. The Sag and Kuparuk formations are isolated and inaccessible below two EZSV retainers and a cement plug. A 13 -3/8" casing was run to 2635' MD and cemented to surface with 4000 SX of 15 ppg Dowell Arctic Mk s Set II. A 9 -5/8" production casing was run to —7617' MD and cemented in place with 897 SX of 14.4 ppg class G cement. A cement bond log run in March 1981 7 1b ,�u ' /� showed good cement up to 1800' MD. 0 S & 6 - � '� >e /L. Lr+d H OP MPCFP -2 (Permit # 184242) was completed in January 1985. The completion crossed the Kuparuk formation at 7787' MD. A 9 -5/8" casing string was run to 4881' MD and cemented to surface with 1000 SX (342 bbls) of 12.3 ppg Arctic Set III and 952 SX (195 bbls) of 15.8 ppg class G cement. A 7" casing was run to 8193' MD and cemented with 85 bbls of 15.8 ppg class G cement. • • ,.,-) \ ' ----------, ' ' ,— , A 0. ....."0" li lir 1 ..... --) #4 -.11 ---._,..._ , ' , - ••� i ,y A / ` O''''..r- .. ' . -'- t 410 WW1 6 \ . A 5 . 12 (if f "-",. \ \\,_ ---' \ ''..- s ) '-‘' "s -'-'. '''%,-... 4 \ \\ 7 (19 L/ - 6 1 ---; '''''s ,' : t } _ 1J r •,,, f - ( 7 -- ----.., I r ,., -_, Figure: Map showing wells within 0.25 mi radius from MPB -20. • • TREE: 31/8" -5M FMC MPB -20 w/ 3 1/2" Otis Quick Union KB Elev. = 59' Nabors 27E GL Elev. = 35' Nabors 27E WELLHEAD. 11" 5M FMC w/ 3 1/2" 'H' BPV profile. A R C T Camco TRDP -1A -SSA SCSSV 1 499' I i (2.812" ID) 13 3/8 ", 48 #, H -40 PELP 108' , C P Note: The Camco TRDP -IA -SSA was A locked out of service 10/31/95. C 9 5/8 ", 36 #, K -55 5034` , K BTRC , 1" X 3 1/2" McMurray FMHO w/ Blt lattl # and tvd dg KOP @ 2500' 9 2185' 2185' 0 MAX Hole Angle- 8 2882' 2881 ` 8 41.5 DEG @ 4600' 8 7 3522' 3492' 24 6 4239' 4087' 37 Baker Patch covering SPM @ 4896' 4882 4907, 5 4896' 4588' 40 1.83" min ID *4* 5555` 5095` 39 3 1/2" , 9.3#, BTRS, L -80 TUBING 3 6213' 5598' 39 DRIFT ID: 2.867" 2 6871' 6100` 41 CAPACITY 0.0087 BBL /FT 1 7555' 6623' 39 7" , 26#, L - 80, BTRC Casing Note: Station 4 @ 5555 has broken DRIFT ID: 6.151" r latch, No-Go is still attached to DMY CAPACITY w/ tbq .0264 bpf valve. Casing RA Tag 7723' X Baker `PBR' Seal Assy (3.00" ID) 7914' Baker'HB' Packer (3.0" ID) 7927' Tubing Tail Jet Cut (9 - - 90) 7957' PERFORATION SUMMARY A — (DIL Log dated //) _ Zone Size SPF MD' TVD' 8 Fish:Est. Top of Tubing Tail 8047' 0 UU VV Est. Top of Perf guns 8064' MK -1 5" 12 7994' - 8013' 6965 - 6980' o MK -2 5" 12 8017' - 8047' 6983' - 7006' 0 •' . r •1 'a � PBTD (Float Collar) 8146' AIIIIMENEK 7" 26 # Shoe 8270' DATE REV. BY COMMENTS MILNE POINT UNIT 9/25/06 M. Ross Convert drawing to Canvas WELL MPB -20 API NO: 50- 029 -21524 BP EXPLORATION (AK) . 01i25 %o6 06:53 , 7 0. 201 .32 1 . MILNE POINT UNIT CASING AND CE`SENTING REPORT CS -...( Well: .+9,1.' ,9 - . Ground Elevation: 5 (ft) Drillers T.D.:129S' (ft) RKB - Grd. Elev.: -4' (ft) Loggers T.D.: $2G?E, (ft) Top of Han 8 er -BR3: 35.7S" (ft) Maximum Recorded Temperature from Logging duns Aro ° F Casing Tally Makeup i Setting No. Pieces' Size - Weight - Grade - Thread - Etc. Length Deoth / 1/5"0.-4-e.4.. ,la �..-/ ,5%4 J. ?5/ . '3 1 49;94 ! - "/ ‘ 2 — e?4 ..etrAec ego ( - 79".74/ 1 53Z ". 11 / 1 . r /.,� -� 1. /cLy / 72 91$T.) / 17 ' 11 ' _2-8a .43'7. G. s j 2g.ao 812;75/5 / } e Kl , " 0/4 . L . a A ' , - , 0 t 7 u t 1,. 3 t f 7.90 1?./ 9$ Vsj / , G` - G,.'' ' 2 e..J 4�, , �`4,�i = / o. 3z $ !7.18~ 5 . 1 13 4. s r II /o 71 / ;Zb;' It/ .2. -'40 .d774'G Cy - x$9.20 I S /l.Z.d, A' A - /°<;,, e �:� /4/ - 1 772 3.3 y Vi Ar., - Centralizers and Spacing ',2. 4g -- 7/c V i4u •.I 4/• . 3 9 96 - s ' o ,�.r:o - C Preflush: 'd BBLS of / PFG . a Gei Cement (Stage I) .5 BBLS of f 1513' ?PG G �a.t C 2kIZ/ i. 1.Z3/ Cement (Stage II) BBLS of PPG Disp. Fluid: 1 3/2.7 BBLS of 9tg PPG /(/a. en/ ,l'�■n.e @ AO ° F Time Started Time Completed Rate (BPM) PSI (max.) Circulation 7; cl4 0 : sz .A5 /c o4 Pre -F1ueh $: ..S 2. - 9 tee R' 9so Stage I 9.//2P — : 3 © 44 r s o Stage II Displacement 9 .......//: 0 3-S 1)00 Recip. Pipe 7; 4/0 1:0,•SC (Why Stopped) C 4 Go v" Bottom Plug: c• No) Top Plug: (gI), No) Bumped Top Plug: es No) 3 ©00 p Total Pumped Diep. 5/# (bbls) Floats Held: tt5Z No) 1 - Full Returns: (Yes, No) Cement Returns to Surface: (Yee, .1y BBLS Initial String Weight: ,'.Zr) (ibs) Final Landing Weight JA9/ (lbs) Service Co.: ,d -- 77, .. Performance: (Good, Fair, Poor) Date: ,// 5 Supervisor: d e e Aleol "'"'"- 1 11/14.4 -- 40 MILNE POINT UNIT " - : CASING AND CEMENTING REPORT C--54:-- g5 / �. d Wells r2D Ground El- =tion: t) f '� Drillers T.D.: Soy/$''(ft) RKB - Grd. Elev.: " (ft) ' --, Loggers T.D.: (ft) Top of Hanger -RKB: 3430 (ft) Maximum Recorded Temperature from Logging Runs °F' 3 Casing Tally "' _ Makeup Setting t No. Pieces Size - Wei ht - Grade - Thread - Etc. Len th Death _ "or.- .glad .,..c+Z .f"„e. . 8_ So 3 ci. o S 3. '°''' - -.fir . r r LIPMEIRMIIMPIN1111111111 t1' 9 . 3D .2. Go -- --- ,c r..._. _ - _ 0 _' ty0 /i %zo i Centralizers and Spacing o � ! 6 / oo boo - 2 Soe 4 SD a - 9 0 -4: Preflush: s'o BBLS of // PPG Z--�o :.. Cement (Stage I) BBLS of /2 3 PPG / e 1,T E Cement (Stage II) SW. 5 BBLS of /$ t PPG ,/e....., SS G' s.,,/3 ."7oAct•C` . / C./C Diep. Fluid: 352.1, BBLS of Q,5) PPG ,'f,. — @ 4r °F Time Started Time Completed Rate (BPM) PSI (max.) -;.,%: M Circulation /.. ; � o I'2.r 3 —6 ra0— 2 co - ' • Pre -Flush /,'1 r J; 3s' — — u :4t Stage I /, <r 5.l 0P d - 2 ; s'o Stage II - S / J3 s': 44 VA- j got; Displacement r - vs- _ 7; VS g — 3 '75 ' 4 . .. Recip. Pipe /1'/0 S" /f ' ��` (Why Stop ed) S p-i c in . _.,,: Bottom Plug: 0) No) Top Plug: es Y No) Bumped Top Plug: No) QQ s ` ' Total Pumped Disp. X$D (bbls) Floats Held: ...-4: r Full Returns: (Yes,C Cement Returns to Surface: No) AO BBLS ``" _- Initial String Weight: Alt 1 k (lbs) Final Landing Weight . ' Service Co.: ,arff'6ttr soh. Performance: (Good, Fair, oor "`} Date: / //9A% Supervisor: lJ, "."1,0. .. ,�a r `. •• lb _ ._ MILNE POINT B -20 (P) OPERATOR: CONOCO INC. NOTES: 1. All measurements from KDB of Nabors Rig 027 -E SURFACE LOCATION: 930' FSL, 673' FWL, 2. KDB - SL = 59' Section 18, T13N, R11E, U.M. — 3. KDB - GL Q 35' BOTTOM HOLE LOCATION: 2521' FNL, 609' FWL, Section 19, T13N, R11E, U.M. 4. Max. angle - 41.5 @ 4600' M.D. 1 _ SPUD DATE: 01/16/86 5. KOP at 2500' 6. Slant Type Hole - YES — 9 5/8" Surface Casing 1. Pumped 50 Bbls of 11 ppg Zeogel preflush. 2. Pumped 456 Bbls (1340 sx) of 12.3 ppg Permafrost "E" cement. 3. Pumped 56.3 Bbls (275 sx) of Class "G" cement with 3% NaCI and I% - CFR -2. 4. Displaced with 383 Bbls 9.4 ppg mud. NOTE: Approximately 160 Bbls cement returns to surface. 13 3/8" :.} 48 H -40 Centralizers: - at 108' 1 per 120' 90' - 2500' 1 per 80' 2500' 4500' I per 40' 4500' - 5020' 7" Production Casing 1. Pumped 40 Bbls of 12 ppg Zeogel preflush. 2. Pumped 55.3 Bbls (270 sx) of 15.8 ppg Class "G" cement with 1% CD -31. �'' 9 5/8" 3. Displaced with 313 Bbls of 9.6 364 K -55 Btrs. ppg NaC1 brine. at 5034' ,ti." Est. TOC Centralizers: at 7100' ±* 1 per 120' 75' - 2500' 1 per 80' 2500' - 3990' 1 per 40' 7104' - 8265' 7" x 9 5/8" Annulus Not Arctic Packed. g i . ECP 8113' - * Based on 100% excess in 81" hole. ECP 8131' Wireline PBTD @ 8146' ;rli:: ;;:.__:;: 7" 269 L -80 Btrs. at 8270' MUM .. /C KJS 02/04/86 bee 6 1_ , I D... / CMId MM. ■ • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907 793-1225 t ~;;:~~~y~~ ~~r~ ~. 4 HOC RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe lastufka lR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245,6952 1 J Leak Detection - WLD 24Mar~09 MPB 20 2~ Signed Print Name: I ~ ~o'~S j~5 5 Color Log / EDE 5~ -o2q - a r 5 ate/- vc~ Date ~' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL ~1a~~, ~ ''. WESSITE: ~_~~_ C:\Documents and SeUmgs\OametiDeslC.op\Ti~ansmit_BP.doc~c ~1f~LL L~ifa ~,`ry__; ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration [Alaska, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~~~~ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Eax (907) 245,8952 1) Leak Detection - WLD 03-Mar~09 MPB-20 2) Signed . \~ ' ~ ~~__ Print Name: `~~ y ~-- l~~J ~_ Color Log / EDE 50-0221524 - m _~ _. = .~ ., , ~. ?~ Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (907)245-8951 Fax: (907)245-88952 E-WAIL . ~^-'~15~3"^.C ~-as~~~~~~ °i1tP. WEBSITE ~ ?,~~.~ " ?SC, 1~rya ;~.x"'i. '' C:\Docum~Lc and Settings\OwtierlDesktop\1lansa~it BP.docx MICROFILMED 9/11/O0 DONOT PLACE ANY' NEW MATERIAL UNDER THIS PAGE . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0.77 DATE: July 12, 2000 Commissioner' f //eybc.v THRU: Blair Wondzell, ~~ P. I. Supervisor . 'df '1(Oa FROM: ~t1t¡ Jeff Jones ,.-"" SUBJECT: Safety Valve Tests Petroleum'l 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 8-22 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. 260/0 failure rate. '3 M:J~ r.:L-hz--;;r 21 well houses were inspected, no failures. -y 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 Rcp: Jeff Jones Submitted By: Date: FieldlUnit/Pad: Kuparuk River/MPU/B-Pad Separator psi: LPS 140 I-IPS NI A 7/9/00 N \-...) N ;¡fì;',,",~": weli~fjât~'?; ".r,'> ,. . . -. -' . ., ~- ." .~:." 'f¡;',&Riibt$:f.~¡:;;J!:}:,r~~1f¡!.~y~~~~~~~t~tfi\ 'is:S;J.1?'f;:: :;,':.:;"". :',,' Well ;;Týp'è,<;:.i:,': 'SSV' " ;:f ~ ' .: . -;.::~ ..1, ,', :!.,~, ~ ;',\.',1 .'I~~,... _...,:.<:~ :~:.:'~'.;' y." ", "I,":':'\)?: '.;11. ... ' , . '':'0 . ,,_'or..;. .:.: ~ :;"1 !\~;~ ~.~ -:.;',~ ~'" I '<', ~~...,.. '.' .: :::-'.~'.'.' Well Permit Separ Set LIP Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GINJ, 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 Compollents: 18 Failures: Failure Rate: 5.5% 090 Day We lis: Relnarks: Three well SV's recorded slow closing times; 8-04A(3 :20), B-03(3 :03),8-06(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. ')1.17/00 Page 1 of 1 Vv043m 1 txls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Receipt of the following material which was transmitted via z/z~t~ ,' / //f~-/~x /~c,'e~~- is hereby acknowledged: QUANT I TY DESCRIPTION RECEIVED: DATED: Copy sent YES to sender NO September 17, 1990 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-1433 RE' Milne Point Unit Well B-20 Report of Sundry Well Operations Dear Mr. Smith' Attached is the Report of Sundry Well Operations (Form 404) and the summary of operations for Milne Point Unit Well B-20. If there are any questions pertaining to this well please call me at 564-7637. Very truly Yours, R. S. Rossb~ Sr. Drill ing Engineer RSR/jcd cc- MPS File- 500.21.08 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPEFIATIO R 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging Pull tubing ~ Alter casing ~ Repair well ~' 2. Name of Operator 5. Type of Well: Conoco Inc_.. Development ~ Exploratory __ 3. Address 99503 StratJgraphic ~ 3201 C Street, Suite 200, Anchorage AK Service__ 4. Location of well at sudace 930' FSL, 673' FWL, At top of productive interval 2074' FNL, 595' At effective depth Sec. FWL,' SEc. 18, T13N RllE, U.M. 19, T13N, RilE, U.M. At total depth 2521' FNL. 609' F~. Sec. 12. Present well condition summary Total depth: measured 8-1.46 ' true vertical 7082 ' 19. T13N~ RllE~ U.M. Perforate __ Other 6. Datum elevation (DF or KB) 59' KB feet feet Plugs (measured) 7. Unit or Prope~y name Milne Point Unit feet 8. Well number B-20 9. Permit number/approval number 86-5 / ~~ 10. APl number 50--029-21524 11. Field/Pool Kuparuk River Effective depth: measured true vertical feet feet Junk(measured) Casing Length Size Structural Conductor 80 ' 16" Surface 4998 ' 9 "5 / 8" Intermediate Production 8236 ' 7" Liner Perforation depth: measured 7994'-8013', Cemented Measureddepth Surface 108' Surface 1615. Sacks 5034' 270 Sacks 8270' 8017'-8047' ~ue~rticaldepth 108' 4693' 7177' true vertical 6965 ' -6980 ', 6983 '-7006 ' Tubing (size, grade, and measured depth) - 3-1/2", L-80, 7966' Packers and SSSV (type and measured depth) T.R. SCSSV @ 1892'; PKR 7921 13. Stimulation or cement squeeze sumrflary InterVals treated (measured) Treatment description including volumes used and final pressure Cut and pulled RIH w/3i7' 9-5/8'7 CSG & D.V. Tool~ Cemented with 67 bbls :: ':i't'i:.":f :! 317' 9'5/8" CSG, , Arctic Type IV 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and SurVeys run __ Daily Report of Well Operations X Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 660 191 1600 1500 psig 200 191 2100 1229 psig 16. Status of well classification as: Oil_~.X Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed. [~ ~_~,~,.,~.~,..- TitleSr. Drilling Engineer Form 10-404 Rev 06/15/88 - 44 - Service ~bingPressure 150 psig 190 psig Date9/12/90 SUBMIT IN DUPLICATE 14 '90 15:14 PAGE.00~ TO RNCHORf-AGE KuDaruk Rive~_._....Field - North Slope Borough, Alaska _.M..~.i.]ln_e Point B No. 20 (P} CONFIDENTIAL AFE 10-16- Location: ' FSL, ' FWL, Section , , , tim API No. 50-029- - AK Per, it No. - Elevation: , KB AUGUST INSTALL 2-WAY CHECK, ATTEMPT TO TEST BOP, TOP PIPE RAMSANDANNULAR LEAKING. ND FLOWLINEAND RISER, REMOVE MOUSEHOLE, OPEN AND INSPECT TOP RAMS, CHANGE OUT MANUALKILL LINE VALVE. TEST CHOKE MANIFOLD. CHANGE OUT HYDRIL RUBBER. NUADAPTER FLANGE, FLOWLiNE AND RISER, INSTALL MOUSEHOLE. INSTALL TEST JOINT ATTEMPT TO TEST PIPE RAMS. OPEN TOP RAM DOORS;-REMOVE UPPER SEAL AND SEAT, INSTALL NEW SEAL AND $~AT IN BODY OF BOP. INSTALL TEST JOINT. TEST TOP PIPE RAMS TO 500/5000 PSI, TEST ANNULAR TO 250/2500. TEST BLIND RAMS TO 500/5000 PSI. SCREW INTO HANGER, CLOSE ANNULAR, PULL OUT OF SEAL ASSEMBLY. CIRC OiL OUT OF ANNULUS, REVERSE OIL OUT OF TUBING. POOH WITH 3-12" TUBING AND CONTROL LINE. LD GAS LIFT MAN. 140 DAYS SINCE LAST LOST TiME ACCIDENT. 65 DAYS WITHOUT A RECORDABLE ACCIDENT. 35 DAYS WITHOUT A RECORDABLE ACCIDENT SINCE STARTUP. DAILY COST 33,351 CUMI/I~TI~ COST 146,011 APG_U/iT 22. 1990 POOH WITH 3-1/2" TBG. WAITING ON SPEAR TO PULL GAS LIFT MANDREL WITH'DAMAGEDTHREADS. FINISH POOH WITH3-1/2" TBG. L/D GLM'S SEAL ASSEMBLY--CLEANRIG FLOOR. M/U BRIDGE PLUG', RIHAND SET AT 2016'. DROP 6 SXS OF SAND THROUGH TBG. CHASE SAND WITH $ BBLS 9.6 PPG BRINE AND POOH WITH 3-1/2" TBG. CLEAN RIG FLOOR. P/UMECHANICAL CUTTER, RIH AND CUT 7" CSG AT 45' RKB. P/U PACKOFF RETRIEVING TOOL, RIH AND R~fRIEVE PACKOFF, 7" CSG HANGER, 3.1' PUP AND 8.21 CUTOFF 7" CSG. P/U 7" CSG. SPEAR, R/U HLS WITH FREE POINT, RIHAND VERIFY FREE PIPE AT 500''AND 2000' RKB. POOH R/D FREE POINT. R/U STRING SHOT, RIH, SET SPEAR, APPLY 1/2 TURN LEFT HAND TORQUE AND GRAPPLE BROKE--LEFT 1.5" X 2" PIECE OF METAL GRAPPLE IN HOLE. NOTE: RUN MAGNET BEFORE SAND CLEANOUT. CHANGED GRAPPLE, RIH CORRELATED STRING SHOT IN COLLAR AT 499' WITH CCL, APPLIED LEFT HAND TORQUE, BACKED OFF AND FISH--3 RUNS AND 2 SHOTS TOTAL. REVERSE CIRC DEAD CRUDE WITH 45 BBLS 9.6 PPG CRUDE'AND POOH TO SPEAR--BROKE OUT AND LAID DOWN. DAILY COST 45,280 CUMULATIVE COST 193,501 AUGUS.T~22o 1990 FINISH POOH AND L/D FISH--ll JTS AT 452' AND A 28.27' CUT OFF PIECE OF 7" CSG. NOTE~ L~FT CO~ LOOKING UP AT 499t I~KB. RIH WITH I 0 HP~LiMUKH~.~ CCL AND LOG 9-5/8" CSG CO?~T.ARS F/ 499' RKB TO SURFACE. R/D AND RELEASE W/L UNIT. P/U 9-5/8" BRIDGE PLUG AND RIH--UNABLE TO GET PAST TIGHT SPOT 64* RKB. WAITING ON W/L WITH MULTIFINGER CASING CALIPER. R/U W/L LOGGING UNIT. RUN MULTIFINGER CSG CALIPER F~ 499' RKBTO SURFACE. DETECTED ELIPTICALSHAPED COLLAPSE WITH LONG AXIS=9.8'' AND SHORT AXIS=7.6". DAMAGED SECTION: TOP AT 60' AND BOTTOM AT 66'. THE REMAINING CASING IS FREE FROM COLLAPSE OR DISTORTION F/ 499' RKB. RIH WITH 8.25" SWEDGE AND WORK THROGH COLLAPSED CSG INTERVAL WITH P/UWTSK LBS OVER STRINGWT. POOH AND M/U 8.5" SWEDGE. RIHANDWORKTHROUGH COLLAPSED CSG INTERVAL WITH INITIAL P/UWT 5 TO 15K LBS OVER STRING WT. THE LATCH PIN UNSEATED AND THE LATCH LOCK SPRING BROKE ON THE 350 TON BJ G SERIES 5" ELEVATORS WHILE JARRING DOWN USING THE SURFACE JARS. THE SAFETY LATCH OPENED SNAPPING THE SAFETY ROPE AND ALLOED THE'8.5 SWEDGING ASSEMBLY TO FALL INTOTHEWELLBORE CREATING A FISHING JOB. WAITING ON 8-1/2" OVERSHOT AND 6.25" AND 6.375" GRAPPLES. M/U 6.375" GRAPPLE IN OVERSHOT, RIH AND FAiL TO LATCH FISH. CIRC AND CONDITION THE 9.6 PPG BRINE IN THE HOLE. POOH AND CHANGE GRAPPLE TO 6.25", RIH TO TOP.OF FISH AT 416' AND LATCH FISH. POOH WITH COMPLETE 8.5" SWEDGING ASSEMBLY. PULLED THROUGH COLLAPSED CSG INTERVAL WITH 5K LBS OVER STRING WT. SHUT DOWN OPERATION WHILE COMPANY MAN ANALYZED SITUATION. B/O AND L/D THE 8.5" SWEDGING ASSEMBLY. CLEAR AND CLEAN RIG FLOOR. RIH WiTH 12-6 1/4" DC BELOW A 9-5/8 RTTS WITH STORM VALVE SET AT 37'RKB. DRAINED STACK AND SHUT BLIND RAMS. NIPPLE DON BELL NIPPLE AND FLOWLINE. DAILY COST 39,792 CUMULATIVE COST 233,293 · FINISH N/D 13-5/8" BOP'S. BUILD HEAVY DUT POTATO MASHERWITH JUNK JOINT OF 5" HWDP AFTER ATTEMPTS TO BACK OFF 9-5/8" SPEED HEAD FAILED. M/U HEAVY DUTY POTATO MASHER AND B/O SPEED HEAD 1-1/2 TURNS. NOTED THAT HANGER WAS BACKING O UTWITH SPEED HEAD. UNBOLT POTATO MASHER AND RESET RTTS AND STORM VALVE 8' DEEPER AT 45' RKB. (5' INSIDE FIRST FULL JOINT OF 9-5/8' CHG.) PUMPED FLUID OUT OF CSG TO RTTS WITH CELLAR PUMP. MARKED CONNECTIONS BETWEEN HANGER, PUP AND FIRST FULL JOINT OF 9-5/8" CASING WITH PIPE DOPE. M/U POTATO MASHER, UNSCREW SPEED HEAD 1/4 TURN, REMOVE POTATO MASHER AND DETECT CONNECTION BETWEEN HANGER AND PUP JT IS BREAKING OUT. FINISH UNSCREWINGANDL/D SPEED HEAD ANDHANGER. N/U 20" DIVERTER, BELL NIPPLE AND FLOWLINE. FUNCTION TEST 20" KNIFE VALVE AND DIVERTER--OK. N/U FLOW NIPPLE AND INSTALL MOUSE HOLE. POOH WITH RTTS, STORM VALVEAND L/DTWELVE 6-1/4' DC. P/U TRISTATE SPEAR~ INSTALL g-5/8" GRAPPLE. ATTEMPT BLIND B/O--UNSUCCESSFUL- POOH AND L/D SPEAR. P/U 9-5/8" HYDRAULIC CSG CUTTER (8-1/4" OD) AND RIH. MADE CUT AT 70' RKB, POOH AND L/D HYDRAULIC CSG CUTTER. M/U AND RIH WITH 9-5/8" CSG SPEAR. 'LATCH, POOH AND L/D FISH. DAILY COST 31,144 C~TIVE COST 264,437 ~UGUST 25,...1999 UNSUCCESSFULLY ATTEMPTED TO B/OHANGERFROM SPEED HEAD (CSG SPOOL). WELD 9-5/8" PUP TO BOTTOM OF THE HANGER, HEATED UP CONNECTION, APPLIED B/O TORQUE AND COLLAPSED 9-5/8" PUP. UNBOLT POTATO MASHER AND L/D CSG SPOOL. P/U WASHOVER SUBS, STRA~S AND CALIPER. WASHOVER PIPE ASSEMBLY--WASH F/70'-102' (NO ROTATION--NO CEMENT). P/U ZND WASHOVER PIPE AND WASH F/102'-118'. P/U, STOP PUMPS, RUN BACK DOWN AND TAG AT 113 '--WASHOVER 5' OF FILL. INDICATIONS ARE THAT GRAVEL IS SLOUGHING. POOH AND L/D JARS, JUNK BASKET AND WASH PIPE (NOTE: JUNK BASKET WAS FULL OF PEA GRAVEL. UNSUCCESSFULLY ATTEMPTED TO B/U HANGR FROM SPEED HEAD (CSG SPOOL). WELD 9-5/8" PUP TO BOTTOM OF THE HANGER, HEATED UP CONNECTION, APPLIED B/O TORQUE AND COLLOAPSED 9-5/8" PUP. UNBOLT POTATO MASHER AND L/D CSG SPOOL. P/U WASHOVER SUBS, STRAPS AND CALIPER. P/U WASHOVER PIPE ASSEMBLY--WASH F/70 '-102 ' (NO ROTATION--NO CEMENT). P/U 2ND WASHOVER PIPE AND WASH F/102 '-118'. P/U, STOP PUMPS, RUN BACK DOWN AND TAG AT Ii3'--WASHOVER 5t OF FILL. POOH AND L/D JARS, JUNK BASKET AND WASH PIPE (NOTE: JUNK BASKET WAS FULL OF PEA GRAVEL. CLEAR 'AND CLEAN RIG FLOOR. R/U SCHLUMBERGER, RIH WITH. CET'S AND GAMMA RAY. R/D LOGGING TOOLS AND R/U TO RUN FREE POINT. P/U BUMP~ SUB SPEAR AND FREE POINT TOOL. RIH WITH FREE POINT AND SPEAR--LATCH 9-5/8" AND FREE POINT. POOH, L/D FREE POINT AND SPEAR. (FREE POINT AT 155'). STRAP 8" DRILL COLLAR AND RATCHET. COMPANY MAN HELD MEETING WITH SERVICE COMPANY PERSONNEL. P/U 9- 5/8" RETRIEVABLE BRIGE PLUG, RIH AND SET AT 483 t RKB. DROP 6 SACKS OF SAND DOWN 5" DP AND CHASE WITH 8-1/2 BBLS OF 9.6 PPG BRINE. DAILY COST 60,036 C~TIVE COST 324,473 AUGUST 26, 1990 CONVERT COMPLETION FLUIDS F/ 9/6 NACL BRINE TO AQUA GEL SALT MUD WITH +/- 100 FUNNELS VIS. MIX AND PUMP 25 BBLS PILL WITH 200 BBL FUNNEL VISCOSITY. POOH AND L/D 9-5/8" SETTING TOOL. CLEAR' RIG FLOOR. PREPARE TO RUN 11 3/4" WASH PIPE. M/UJT OF WASH PIPE AND WASH Fl 9-5/8" CSG AT 70' RKB TO 120' RKB. SET BACK KELLY, L/D BUMPER SUB, OIL JAR AND JUNK BASKET. P/U JT OF WASH PIPE, M/U JUNK BASKET, OIL JARAND BUMPER SUB. M/U KELLY. WASH F/120'-155'. WT INDICATOR SHOWS CENTRALIZER ACROSS COLLAR AT 118'--WE SEEM TO SWALLOW IN RIGHT UP THE WASH PIPE. THIS MEANS NEXT CENTRALIZER SHOULD BE ACROSS COLLAR AT 239' (COLLARS AT 78' 118' 158' 198t, 239', 280' , 318' , 356t . POOH WiTH WASH PIPE AND CLEAR FLOOR. P/U 9-5/8" HYDRAULIC CASING CUTTER, RIH AND MAKE CUT AT 242' POOH, L/D CUTTER, P/U SPEAR AND SPEAR PACKOFF. RIH, LATCH FISH AT 70' RKB, ATTEMPT TO CIRCULATE--NO RETURNS. ATTEMPT TO PULL FISH WITH 260K T..~S--DID NOT EVEN BUDGE. RELEAE SPEAR, POOH, L/D SPEAR AND SPEAR PACKOFF. P/U 9-5/8" BRIDGE PLUG RETRIEVING TOOL, RIH, RETRIEVE, POOH AD L/D BRIDGE PLUG AND RETRIEVING TOOL. CLEAR FLOOR, R/U W/L UNIT, FREE POINT AND 7" CSG SPEAR. RIH WITH SPEAR, LATCH 7" CSG AT 499' RKB, RIH WITH STRING SHOT AND B/O 7" CSG AT 1706' I~KB. POOH AND R/D WIRELINE UNIT--R/U AND CSG EQUIPMENT. START POOH WITH FISH. DAILY COST 62,595 CUMULATIVE COST 387,068 Aq,~,os, T, ,.,28._.. ...... .~,9_9..o_. DAILY COST 46,465 CUMULATIVE COST 497,203 AUGUST 29. 19_9_0 CIRC AT 284' (TOF) WITH WASH PIPE. ATTEMPTS TO WASH OVER FISH FAILED, UNABLE TO SWALLOW FISH. POOH WITH WASH PIPE ASSEMBLY. M/U SPF2kRWITH J LATCH, RIH AND SET SPEAR IN TOF AT 284'. RIH WITH WASHPIPE ASSEMBLY AND SET DOWN AT 170' (114' ABOVE TOP). P/U TO 160' AND E4ST CIRC, PACKED OFF AND LOST CIRC, UNABLE TO RE- ESTABLISH CIRC. RIH WITH 12.25" BIT ASSEMBLY AND CIRC AT THE 13- 3/8" CSG SHOE AT 108'. WASH AND REAM F/108'-274' WITH i TO 5K LBS. CIRC SALT MUD SYSTEM, PUMP 30 BBLS FRESH H20 BARAVIS SPACER AND DISPLACE HOLE VOLUME WITHFRESH WATER GELLEDMUD. MADE WIPER TRIP TO SHE, RIH TO 276', CIRC HOLE CLEAN, POOH, L/D BIT AND BIT SUB. P/U 2 JTS WASH PIPE, 3 DC AND RIH--SET DOWN AT 267~. P/U AND ESTABLISH CiRC, WASH OVER 9-5/8" TO 323' AND CIRC HOLE CLEAN. POOH, SET BACK WASH OVER PIPE, P/U J-JOINT RET TOOL AND RIH INTO SPEAR, LATCH SPEAR, POOH AND L/D SAME. CLEAR AND CLEAN RIG FLOOR. M/U BHA FOR BACK OFF TOOL. DAILY COST 41,829 CUMULATIVE COST 539,032 AUGUST 30, 3.-990 RIH W/HyDRAULIC RATCHET TO BACK OFF THE CASING @ 318~. ATTEMPT TO B/O FISH @ 318~. DC BELOW B/O TOOL PULLED OUT OF CSG STUB. P/U 9- 5/8" SPEAR, PACKOFF, & BUMPER SUB -- LATCH ONTO FISH @ 284t. ROTATE 4 TURNS TO LEFT & PULL FREE W/ 5K LBS. OVER. CIRCULATE HOLE CLEAN. POOH W/FISH. L/D FISH & BACKOFF TOOL. RIH W/CUTLIP GUIDE TO 318'. CIRC & CONDHOLE. POOH, L/D BHA & WASHPIPE. R/U CSG RUNNING EQUIP, & 9-5/8", RUN DV'TOOL, 8 JTS + 10' JT. M/U FOR THE BUTTRESS CONN WAS 6500-7000 PSISG. STAB DV TOOL IN COLLAR & M/U W/12 TURNS TO 12000 M/U TORQUE. PRESSURE TESTED CASING TO 1000 PSIG --OK. BACK OUT CIRC SW~DGE, DROP OPENING PLUG, SHEAR DV OPEN W/ 850 PSIG. PERFORM CEMENT JOB: 80 BBL SPACER, 67 BBLS 12.2 PPG'ARCTIC SET IV. CIRCUNITL C~MENTTOSURFACEAND PUMP 17 BBLS. DISPLACEMENT~B~ TOP PLUG & SHEAR DV TOOL CLOSED @850 PSIG. HOLD 1000 PSIG FOR 10 MIN. -- OK R/D CSG & CEMENTING EQUIPMENT. A~GUST'3.1,. 1990 INSTALL SPLIT FLUTED HANGER, CUT 9-5/8", & N/D RISER, HYDRIL, AND DIVERTER. MAKE FINAL CUT &.WELD ON NIPPLE FOR BRAIDENHEAD. TEST WELD TO 1000 PSIG & M/U BRAIDENHEAD. N/U BOP'SAND SET HOUSEHOLE. L/D DRI~J. COLLARS. CHANGE TOP SET OF PIPE RAM F/ 7" TO 5". TEST BOPE TO 5000 PSiG -- 3500 PSIG ON A~D~ULARPR~ER. INSTALL LONG WEAR BUSHING. SEPTEMBER 1. 1R90 P/U USED 8.~" ATJllH (HUGHES) INSERT BIT, 2 STAB, & 8 DC-- RIH & TAG CEMENT @270'. DRLG CMT F/270'-318'. TAG DY @318' & DRILL TO 320'. RIH & TAG FILL @1560e. PRESSURE TEST 1000 PSIG FOR 5 MIN-- OKK. DRILL F/1560'-1575w IN. POOH W/ & L/D 8.5" BIT, 2 STABS, & 8 DC. M/U JET BASKET, BIT SUB, BUMPER JARS, OIL JARS, & 9 6-3/4". COLLAR & RIH. MAKE 3 RUNS FOR PIECES OF DV TOOL BOMB--TWO SUCCESSFUL. POOH W/JET BASKET ASSEMBLY AFTER RUN ~ 3. RIH WITH 8.75" CUT LIP GUIDE, R/U HEAD PIN WITH 2" HIGH PRESSURE HOSE TO SHAKER, & REVERSE CIRC. CIRC 180 BBLS & RECOVERED 3 BRASS FINGERS. 1990 POOH & L.D OVERSHOT. RIH W/BRIDGE PLUG RETRIEVING TOOL, LATCH, UNSERAT, POOH SLOW, RIH W/MULE SHOE TO 1706' & CIRC .AROUND 7" COLLAR. CIRC & COND HOLE. POOH, 5" DP & 6-1/4" DC. PULL WEAR BUSHING, INSTALL TEST PLUG, & TEST BOTTOM RAHDOOR. 5000 PSIG. PULL TEST PLUG. R/U CSG EQUIP. & RUN 43 JTS. + 10' PUP OF 7", 265, J53, BUTT. R/U TO CIRCULATE DEAD CRUDE IN 7" X 9-5/8"ANNULUS. PUMP120 BBLS OIL TO FILL 7" CASING & 7" X 9-5/8" ANNULUS FOR FREEZE PROTECTION. R/U WIRELINE UNIT~ RIH W/6" OD MAGNET --RUN 6" OD IMPRESSION BLOCK REVEALED RiM OF COLLAR DAMAGED. POOH W/43' JTS. + 10! JT. OF 7" CSG. FINISH POOH W/7" CSG. P/U SPEAR & RIH WHILE P/U 5" DP FROM SHED. RU.U W/L, CORRELATE COLLARS, SET SPEAR, APPLY LEFT HAND TORQUE TO PIPE, SHOOT a BACK OFF. POOH SLOWLY W/FISH--L/D FISH, PULL WEAR BUSHING, BRF2tKKELLY. R/U CSG EQUIP & RUN 45 JTS. + 10~ FOOT PUP. BREAK CIRC @JT. ~43 & CIRC SLOWLY TO FILL ANNULUS W/OIL. RUN LAST 3 JTS. OF 7" & M/U 7" BUTTRESS INTO COLLAR @1819' W/11 TURNS & 7000 FT. LBS. N/D BOPE, SET EMERGENCY SLIPS AND PACK OFF. N/U BOPE. S.E~TEHBER _ .4J__1.9_9_0. FINISH N/U BOPE, CHANGE TOP PEPE RAMS TO 3.5". N/U RISER, FLOW NIPPLE, MOUSEHOLE~ TURN BUCKES, & CHOKE & KILL LINES. PRESSURE TEST ALL B~S ON BOP STACK. L/D 17 JTS. 5" DP F/DERRICK USING MOUSEHOLE. R/U HANDLING EQUIP. FOR 3 1/2" DP. M/U REVERSE BASKET W/ESTENSION. RIH USING HEADPIN & TIW VALVE. RIH TO 1750'. RIH P/U SINGLES WHILE REVERSE CIRCULATiNG--REACHED 1946' BHA PACKED OFF. POOH FOR PLUGGED BHA. RIH W/REV CIRC BASKET AGAIN. REV CIRCULATE F/1947'-1965' POOH W/CLEAN OUT BASKET. R/U W/L UNIT. RIH W/HYDROSTATIC BAILER W/FLAPPER VALVE. RAN WIRELINE BAILER, RUN $1 CONTAINED SAND, LEFT BAILER IN HOLE ON RUN ~2. RIH WITH IMPRESSION BLOCK, RIH WITH LATCH AND LATCHED FISH, WORKED'FISH FREE, POOH W/FISH, RD WIRELINE UNIT. RIH W/REVERSE CIRC JUNK BASKET, CIR 1947' TO 2007'. RIH W/OVERSHOT, UNSEAT BP, RESET AT 1942', RIH TO 2037' POOH LEFT BP IN HOLE. RACK 3 1/2" DP ON LEFT SIDE OF DERRICK RU POWER TONGS RIH TO 2449' CIRC BRINE RIH TO 3100t, LATCHED ONTO BP POOH LD BP RiH W/3 1/2" DP, LD DP. SEPTEMBER 6, 1%9.0 FINISHED LD 3 1/2" DP AND DC'S. BREAK DOWN FISHING TOOLS & LD, PU~.L WEAR RING. RIH W/9 G/L MANDELS, SSSV & 242 JTS TBG, STAB INTO PKR, PU SPACE OUT, MU HANGER. CIRC HOLE CLEAN. LAND TBG, TEST TBG AND PKR TO 1500 PSI, SET BPV RD TUBING TONGS AND CAMCO. ND BOP'S, CHANGE RAMS, NU TREE, AND TEST TO 5000 PSI, OK. SEPTEMBER___TJ 7990 PULL 2'-WAY CHECK, RU SLICKLINE UNIT, RIH WITH JDC RETRIEVING TOOL SET DONE AT 7896t, POOH, RIH W/2.2§" IMPRESSION BLOCK. RIH W/2.5" PUMP.BAILER RECOVERED 2 SMALL PIECES OF RUBBER AND SMALL PIECE OF BRASS. RIH W/DRIVEDOWNBAILERR~COVERED LARGE PIECE OF RUBBER AND PIECE OF METAL. RIH W/4 LEGGED GRAB TO 7913' RECOVERED LARGE PIECE OF RUBBER, RIH W/4 LEGGGEDGRABTO 7913t WITH NO RECOVERY. RIH WITH GAUGE RING TO 7523~ NO RECOVERY, RIH W/DRIVE DOWN BAILER7939 W/2.75" BLIND BOX COULDN'T BEAT DOWN PAST 7939' NOW RD SLICKLINE. SEPTEMBER 8~ 199_0 RD SLICKLINE, RU HLS, RIH CORRELATE, JET CUT TBG AT 7957' TBG DIDN'T DROP OFF, JET CUT AGAIN AT 7957'. TBG DROPPED OFF LEAVING 17' OF FISH IN.HOLE. CLOSE SSSCV, INSTALL BPV. STEAM, RELEASED RIG AT 1200 HRS. SCHLUMBERGER WELL SERVICES A DIVISION OF ,~HLUMBERGER TECHNOLOGY CORPORATION HOUSTON, TIrXAS 7725 1-2175 AUG 2 7 1990 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 AHention: Marc Shannon ~$E REPLY TO SCHLUMBERGER WELL Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed ore 2 R1. printsofthe Compony CONOCO, Inc. Well Milne Point Unit B-20 CET, Run 1, 8/25/90 .on: Field Mi lne Poi Additional prints ore being sent tO: 1 BL prints CONOCO, ..... Inc. 600 North Dairy Ashford Houston, TX 77079 Attn:. George Lamb - OF 2018 PER County, Nmrth Slope State Alaska _l_JlL_prints, 1RF Sepia CONOCO~ Tnr~ 1000 South Pine Ponca City, OK 74603 Attn: Log Library 1BL prints, 1RF Sepia OXY U.S.A., Inc. Midland, TX 79710 Attn:. John Carrol .*(915/685-5600) _~rints, I RF Sepia Chevron U.S.A. 6001BollJnger Canyon Road San Ramon, CA 94583-0943 Attn: Priscilla MacLeroy *(415/842-1000) l~nts, 1 KF Sep~ /~las~a Oil & Gas Conservatio~n~ / Co_~si0,~ ~ / 3001 PorCupine Drive / ~AnChorage, AK 99501 , // XA~tn: John Boyle // The film is returned to Conoco, Log Library. We oppreciote the privilege of serving you. prints prints prints Receivedby. AUG ;~1 1990 glas~a Oi! & Gas Cons-,;,;,.mission Da~e: Very truly yours, SCHLUMBERGER WELL SERVICES · David M. Saalwaechter D~TR ICT I~ANAGrR S~-- t 327-,F Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 August 14, 1990 Mr. Lonnie C. Smith Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-1433 RE: Milne Point Unit Well B-20 Casing Repair Dear Mr. Smith' Attached is an Application for Sundry Approval and supporting documentation to perform a surface casing repair job on MPU well B-20. Well B-20 has a confirmed leak in the 9 5/8" surface casing, resulting in communication of arctic pack fluids to the 9 5/8" X 13 3/8" annulus. Attached are wellbore diagrams and a summary workover procedure. The well averaged 650 BOPD prior to shut-in and has a remaining reserve of approximately 300 MBO. It is in the best interests of the Milne Point Unit owners and the state of Alaska to perform the repair and return the well to production. The proposed workover is scheduled to commence on August 17, 1990. If you have questions regarding the proposed work please call me at 564-7637. Very truly yours, Sr. Drilling Engineer lrl cc' MPS, DLM, PMS File #' 500.21.04 .... STATE OF ALASKA ALAS .,,,IL AND GAS CONSERVATION COMMISSIL,.. . APPLICATION FOR SUNDRY APPROVALS l I, l l 1. Type of Request: Abandon w Suspend Operation shutdown __ Re-enter suspended well w Alter casing ~ Repair ~'~ ~ Plugging ~ Time extension ~ Stimulate ~ Change approved program __ Pull tubing ~ Variance ~ Pedorate ~ Other 2. Name of Operator . Conoco Inc 3. Address 3201 C Street, Suite 200, Anch. AK 4. Location pi well at surface 930 ' FSL, U.M. At top of productive interval 2074' FNL, 595' FWL, Sec. At effective depth N/A At total depth 2521'FNL~ 609' .FWL, Sec. 12. Present well condition summary Total depth: 5. Type of Well: Development .._.X Exploratory ~ Stratigraphic ~ Service ~ 673' FWL, Sec. 18, T13N, Rll. E, 19, T13N, RllE, U.M. 19, T13N, .RllE, U,.M, measured 8146 feet . Plugs (measured) true vertical 7082 feet 6. Datum elevation (DF or KB) · 59' KB 7. Unit or Property name Milne Point Unit 8. Well number B-20 9. Permit number 86-5 10. AP! number 50-- 029-21524 11. Field/Pool Kuparuk River ' feet Effective depth: measured N/A feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80 ' 16" To .. Surface . 108' 108' Sudace 4998' 9-5/8" 1615 '5034' 4693' Intermediate Production 8236 ' 7'" 270 8270 ' 7177 ' Liner Perforation depth: measured 1), 7994 - 8013 2) 8017 - 8047 , true vertical l) 6965- 6980 2) 6983' "7006 Tubing (size, grade, and measured depth) 3-1 / 2" L- 80 7966 ' ~/~'~ Packers and SSSV (type and measured depth) T.R. SCSSV ~ 1892'; Pet. PKS ~ 7921' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 8/17/90 16. If proposal was verbally approved Name of approver Date approved 15. Status o! well classification as: Oil ~ Gas ~ Suspended Service 17. I hereby certify that the J~regoing is true and correct to the best of my knowledge. Signed[Y~.~~/ Title SR. Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify,~ommission so representative may witness Plug integrity __ BOP Test ~ Location clearance ~ ,.._ ,.. - "" ,q'C~ Mechanical Integrity Test __ Subsequent form requirea :u-... ," - Approved by order of the Commission Date 8/13/90 J Approval No..~/,~._/_,, 'Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH - 43 - Approved Copy SUBMIT IN TRIPLICATE SUMMARY OF PROCEDURE 1) Rig up wireline pressure control equipment. RIH with wireline and set plug in tubing nipple @ 7959'. 2) Nipple down tree and nipple up BOPs. POOH with tubing. 3) RIH and set bridge plug in 7" casing @ approximately 7200'. 4) Run free point tool on wireline and determine the casing free point. 5) Cut off 7" casing above free point and POOH with 7" casing. 6) RIH with fishing tools. Stab into 7" casing and POOH. 7) RIH with bridge plug and packer and attempt to find leak in 9 5/8" casing by pressure testing. 8) If leak is near the surface, wash over 9 5/8" casing and clean out annulus cement to below leak. Back off casing and POOH. 9) RIH 9 5/8" replacement casing and make up with existing casing. Set bridge plug below replacement casing depth and pressure test to 1000 psig. POOH. 10) If leak is deeper than 1000', mechanically isloate and perform a cement squeeze. 11) Set bridge plug in 9 5/8" casing and pressure test to 1000 psig. POOH with bridge plug. 12) RIH with 7" casing and make up with 7" casing in the hole. Pressure test 7" to 1000 psig. 13) RIH and retrieve 7" bridge plug. 14) RIH with tubing and sting into the packer. 15) RIH with wireline and retrieve the tubing plug. Return well to production. RECEIVED .Armhorag~ MILNE POINT UNIT B-20 ACTUAL COMPLETION SKETCH COMPLETED ON" 1-27-86 NOTES: FMC TUBING HANGER w/ $ i/l. 'H' BPV PROFILE 1. All meaauremente ere from KDB of Robots Riq 27 E 2. KDB - SL 59' 3. KDB - GL 35' 4.' MIx. Ingle 41. 50 ~'~ 4600' MO 6. KOP ;[500' 8. Slant type hole YES 7. Min. ingle 38.5° ~ 7900' 8. FMC 3 118" APl 6000~ tree with 3 1/2° 8 rd treetop connection. D. Min. reetrictlon IG CAMCO 'D' Nipple ~'~ 7959' ( 2.75" ID ) 10. APl No. 50- 029 - 21524 Completion fluid 9.6 ppg NoCI brine tieing and cement Information eUl3plled on tieing lnd cement Iketch. ~ 3 I/~,, 9.2# L-80 EUE ~ Rd tubing (2.992" lO, 2.867" d~iff) 1892' CAMCO TROP - I A SSA SCSSV ( 2.812 " ID ) · . 2100',~ 2 795,'~ $42B,~ ~ 4156'. ~ 54601 / 6064.' / 7718' Casing RA marker 7866' Tubing RA marker 7868' / Brown- Hughes FMHO I" Gas Lift Mandrels w/ BK - 2 latches PERFORATIONS: 12 SPF, 120° phasing, 5" guns ( All depths from OIL of I- 23 - 86 ) MK-I 7994 - 8013' MO 6965 - 6980' TVD MK-2 8017 - 8047' MD 6983- 7006' TVD 7906' BaT PaR Seal Assembly ($.0" ID ) ~ 7921' BaT ' HO' Retrievable Pecker (2.89" lO ) ~7959' CAMCO '0' Nipple (2.75" ID) 7966' Tubing Toil 8064 ' Top of hSh ( calculated ) POll ORIGINAL I[¥1,11 I0#s Or/Ck ._ 9146' PBTO (Wireline measurements.) 8270' 7" 26 # L-80 8TRS (6.276" ID, 6.151" drift) NOT'E.* Al~ dez~f~$ correcfecf fo open /~ole logs. MILNE POINT B-20 (P) ., OPERATOR: CONOCO INC. SURFACE LOCATION: 930' FSL, 673'. FWL, Section 18, TI3N, RILE, U.M. NOTES: 1. All measurements from KDB Of Nabors Rig #27-E 2. KDB - SL = 59' 3. KDB ~ GL = 35' BOTTOM HOLE LOCATION: 2521' FNL, 609' FWL, Section 19, T13N, RilE, U.M. 4. Max. angle = 41.5° @ &600' M.D. SPUD DATE: 01/16/86 5. KOP at 2500' 6. Slant Type Hole - YES I3 3/8" 48# H-40 at 108' 9 5/8" 36# K-55 Btrs. at 5034' Est. TOC at 7100'±* 9 5/8" Surface Casing 1. Pumped 50 Bbls of 11 ppg Zeogel pre flush. 2. Pumped 456 Bbls (1340 sx) of 12.3 ppg Permafrost "E" cement. 3. Pumped 56.3 Bbls (275 sx) of Clas~ "G" cement with 3% NaC1 and 1% CFR-2. ' '~ 4. Displaced with 383 Bbls 9.4 ppg mud. NOTE: Approximately 160 Bbls cement returns to surface. Centralizers: 1 per 120' 90' - 2500' ! per 80' 2500' - 4500' 1 per 40' 4500' - 5020' 7" Production Casing 1. Pumped 40 Bbls of 12 ppg Zeogel preflush. ~ 2. Pumped 55.3 Bbls (270 sx) ~f 15.8 ppg Class"G" cement with 1% CD-31 3. Displaced with 313 Bbls of 9.6 ppg NaC1 brine. Centralizers: 1 per 120' 75' - 2500' 1 per 80' 2500' - 3990' i per 40' 7104' - 8265' 7" x 9 5/8" Annulus Not Arctic Packed. ECP 8113' ECP 8131' Based on 100% excess in 8~" hole. · .. ,I 26# L-80 Btrs. at 8270,' Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 MR. MIKE MINDER STATE OF ALASKA OIL AND GAS COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 DEAR MR. MINDER, ATTACHED IS THE REQUEST FOR SUNDRY APPROVAL TO CONDUCT WORKOVER OPERATIONS ON THE B-20 WELL. THESE OPERATIONS WILL BE NECESSARY TO CONVERT THE PRODUCTION TECHNIQUE ON THE B-20 WELL FROM THE CURRENT GAS LIFT DESIGN TO ELECTRIC SUBMERSIBLE PUMP DESIGN. RESPECTFULLY, · D. POLYA DRILLING FOREMAN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION i~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ 2. Name of Operator CONOCO INC. PullQtuQbiTng~ t5/11 . Type of Well: Development .~ Exploratory __ 3. Address Stratigraphic_ p f~ Rn¥ '4/tC~l'l/tR DDIIrtl-lt'tl:' RItV Al¢ Service__ 4. l'o~.ti'on-o~'~v'ell-a~ s-u-rf~,~ ............. ' ......... 930' FSL, 673' FWL, Sec 18, T13N, R11E, UH At top of productive interval 2190' FNL, 4510' FEL, Sec 19, T13N, Rl13, UN At effective depth At total depth 2521' FNL, 609' FWL, Sec 19, T13N, R11E, UN 12. Present well condition summary Total depth: measured feet true vertical 8270 ' feet N/A Effective depth: measured N/A feet true vertical feet N/A Casing Length Size Structural Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension ~ Stimulate __ Variance __ Perforate ~ Other "X'- 6. Datum elevation (DF or KB) KB 59 7. Unit or Property name M!LNE PO!NT UN!T 8. Well number B-2o 9. Permit number 86-5 10. APl number 50-- 029-21524 11. Field/Pool Kuparuk River Plugs(measured) 8146' Junk (measured) N/A Cemented Measured depth True vertical depth Conductor Surface Intermediate Production Liner Perforation depth: 108' 13-3/8" 108' 9-5/8" 5034' 7" 8270' measured NK-1 7994'-8013' , MK-2 8017'-8047' truevertica~K-1 6965'-6980' , MK-2 6983'-7006' Tubing (size, grade, and measured depth) 3-1/2", 9.2#/FT, L-80 EUE e 7966' ,,, feet ,, Packers and SSSV (type and measured depth~oT 'HB' RETRIEVABLE PACKER e 7921' RSSV CAMCO TRDP-IA SSA ~CS£V 8 1892' 13, Attachments Description summary of propose__ Detailed operations programX._ BOP sketch __ 14. Estimated date for commencing operation Date approved 16. If proposal was verbally approved Name of approver 15. Status of well classification as: O~Ix__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Gas __ Suspended __ JUNE 14, Title ~MT~ PDN~IICTT~N FNDFMAN FORCOMMfSSfONUSEONL¥ Date 1990 Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ ~ ¢ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH I Approval No.¢ ~ Approve.'.~ .',': .~:' a~. Returned ~omm¢sSioner - Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NOTE~: MILNE POINT UN. ,.. 20 ACTUAL COMPLETION SKETCH COMPLETED ON" 1-27-86 . FMC; TUBING HANGER w/ 3 I/t 'H' BPV PROFILE 1. All maeaurementa ere from KDB of No~3ors R~ 27 E 2. KDB - eL 59' 8. KDB - GL 35 4. Max. eflOla41 5o ~ 4600' MD ~. Slant typohole YES 7. Min. oriole ~B5° ~ 7900' FMC ~ 11~' APl ~O00* tree with 3 112' 8 rd treoto~ connection. e. Min. rootrlction i~ CAMCO 'D' Nipple 7959' (~.~5" ID ) 10. APl No. 50 - 0~9 - 11. Completion fluid ~.6 apg NGCI ~rine C88lng and cement ~formetJon ~ 3 s/2" 9.2~1' L-80 EUE B Rd ~ub,ng (2 992" ID, 2.867" "ID) ~ I892' CAMCO TRDP ' I A SSA SCSSV ( 2,812 drift ) ~ 2 IO0'~ , ~ ~. 795 ~ 3428' 4824 ' , 5460 ~ 6064' -- 7240' -- 7718' Casing RA marker !--'---%-- 7866' Tubing RA morker 7868' / Brown- Hughes FMHO I" Gas Lift Monntels w/ BK - 2 latches PERFORATIONS: 12 SPF, 120° phasing, ,~" guns ( All depths from DIL of I - 23 - 86 } MK-I 7994- 8015' MD 6965 - 6980' TVD MK-2 BOlT - 8047' kD 6983 * 7006' TVD 7906' BeT PBR Seal Assemtfly (3.0" ID) 7921' BOT' HB' Retrievable Packer (2.69" ID ) 7959' CAMCO 'D' h,ppie (2 7966' TuDing -- --8064' Topof f;sh (colculoted) 8146' PBTD (Wtreline meosu,ements~ 8270' 7" 26~f' L-80 8TRS (6.276"1D, 6.lSl"¢trift) MILNE POINT B-20 (P) OPERATOR: CONOCO INC. -. SURFACE LOCATION: 930' FSL, 673' FWL, Section 18, Ti3N, RllE, U.M. BOTTOM HOLE LOCATION: 2521' FNL, 609' FWL, NOTES: 1. Ail measurements from KDB of Nabors Rig #27-E 2. KDB - SL = 59' 3. KDB - GL = 35' Section 19, T13N, RllE, U.M. 4. Max. angle z 41.5° @ 4600' M.D. SPUD DATE: 01/16/86 5. KOP at 2500' 6. Slant Type Hole - YES 13 3/8" 48# H-40 at 108' 9 5/8" 36# K-55 Btrs. at 5034' Est. TOC at 7100'±* 9 5/8" Surface Casin~ 1. Pumped 50 Bbls of 11 ppg Zeogel pre flush. 2. Pumped 456 Bbls (1340 sx) of 12.3 ppg Permafrost "E" cement. 3. Pumped 56.3 Bbls (275 sx) of Clas~ "G" cement with 3% NaC1 and 1% CFR-2. 4. Displaced with 383 Bbls 9.4 ppg mud. NOTE: Approximately 160 Bb]s cement returns to surface. Centralizers: ! per 120' 90' - 2500' 1 per 80' 2500' - 4500' 1 per 40' 4500' - 5020' 7" Production Casing 1. Pumped 40 Bbls of 12 ppg Zeogel preflush. 2. Pumped 55.3 Bb].s (270 sx) of 15.8 ppg Class"G" cement with 1% CD-31 3. Displaced with 313 Bb].s of 9.6 ppg NaC1 brine. Centralizers: 1 per 120' 75' - 2500' 1 per 80' 2500' - 3990' 1 per 40' 7104' - 8265' 7" x 9 5/8" Annulus Not Arctic Packed. PBTD @ 8146' ECP 8113' ECP 8131' 7,! 26# L-SO Btrs. * Based on 100% excess in 8½" hole. HPU KUPARUK RESERVOIR PROCEDURE FOR CONVERSION OF GAS LIFT WELLS TO ELECTRIC SUBNERSIBLE PUNP I. STABILIZED WELL TESTS WERE OBTAINED FOR EACH WELL. 2. PRESSURE GAUGES WERE RUN ON WIRELINE AND FLOWING BOTTOM HOLE PRESSURES WERE MEASURED FOR EACH WELL. WELLS WERE THEN SHUT IN AT SURFACE AND 12 HOUR PRESSURE BUILDUP SURVEYS WERE PERFORMED TO DETERMINE RESERVOIR PRESSURES. 3. KILL FLUID DENSITIES WERE THEN DESIGNED BASED ON THIS PRESSURE DATA FOR EACH WELL TO PROVIDE FOR BALANCED CONDITIONS DURING THE WORKOVER OPERATIONS. FOLLOWING ARE THE RESULTING KILL FLUID DENSITIES: WELL DEPTH SBHP FBHP KILL FLUID (TVD-FT) (PSIG) (PSIG) (PPG) B-lO 7026 4370 1629 12.5 B-20 6985 3265 2349 9.5 B-23 6900 3500 2200 10.3 NOTE: KILL FLUIDS ARE A HALF POUND OVER-BALANCED TO THE SBHP. THE BRINES FOR THE B PAD WELLS SHOULD BE ABLE TO BE DELIVERED FROM TOWN SINCE THE KUPARUK RIVER BRIDGE SHOULD BE BACK IN BY THEN. IF THE RIG MOVES ON B PAD BEFORE THE BRIDGE IS BACK IN PLACE, B-lO SHOULD BE DRILLED FIRST SINCE IT WILL BE THE EASIEST AND MOST INEXPENSIVE BRINE TO BUILD ON LOCATION. ANY REMAINING BRINE CAN BE USED AS A BASE FOR THE B-23 WELL WHICH SHOULD PRECEED THE B-23 WELL FOR THE SAME REASON. 4. ALL KILL FLUIDS WILL BE FILTERED TO 2 MICRON AND STORED IN CLEAN TANKS. 5. SHUT IN OFFSET INJECTORS PRIOR TO RIGGING UP WORKOVER RIG ON WELL. BULLHEAD KILL FLUID DOWN TUBING TO KILL THE WELL. (SEE ATTACHED WELL BORE DIAGRAMS.) NIPPLE DOWN WELLHEAD AND NIPPLE UP BOPs. PRESSURE TEST BOPs TO 3000 PSIG. 6. P/U TUBING AND SHEAR THE PBR ASSEMBLY (SEE ATTACHED WELL BORE DIAGRAMS). CIRCULATE KILL FLUID AROUND AND MAINTAIN HOLE FULL OF KILL FLUID. POOH WITH TUBING AND LAY DOWN SBR. 7. M/U THE ELECTRIC SUBMERSIBLE PUMP ASSEMBLY AS ILLUSTRATED IN THE ATTACHED OTIS COMPLETION GUIDE. STRAP AND RECORD THE LENGTH OF EACH COMPONENT. RUN A STANDARD CENTRALIFT MOTOR CENTRALIZER FOR THE 562 SERIES MOTORS AND 7" 26# CASING ON THE BOTTOM OF THE MOTOR. 8. RIH WITH THE ELECTRIC SUBMERSIBLE PUMP NO FASTER THAN 30' PER MINUTE. MAINTAIN SUFFICIENT HYDRAULIC PRESSURE WHILE RIH TO MAINTAIN VALVES IN THE OPEN POSITION. ATTACH 2 CABLE BANDS PER JOINT. ATTACH ADDITIONAL BANDS ABOVE AND BELOW EACH CABLE SPLICE. SET THE BOTTOM OF THE MOTOR AT DEPTHS SPECIFIED IN THE ATTACHED E.S.P. DATA TABLE. 9. LOCATE PACKER AND CONTROL VALVES NOT LESS THAN 500 FT MD. PIN PACKERS TO BEGIN SETTING AT APPROXIMATELY 1100 PSIG. (IMPORTANT NOTE: THE COMBINED MEASUREMENT OF THE DIAMETERS OF THE #2 ROUND CABLE DIAMETER AND THE SCSSV IS 6.07 INCHES -- THE DRIFT OF THE 7" CASING IS 6.059" (TO0 LARGE TO FIT). IT WILL THEREFORE BE NECESSARY TO SPLICE APPROX. 20 FT OF #2 FLAT CABLE TO EXTEND ACROSS THE SCSSV.) 10. RIH WITH "X" PLUG ON WIRELINE AND SET IN THE "X" NIPPLE LOCATED BELOW THE PACKER AND PRESSURE UP TO 1000 PSIG. SET PACKER BY GRADUALLY PRESSURING UP THE TUBING FROM 1000 PSIG TO 2500 PSIG. 11. BLEED OFF THE CONTROL LINE PRESSURE TO CLOSE THE ANNULAR VENT VALVE AND TRSCSSV. PRESSURE THE ANNULUS TO 500 PSIG FOR 10 MINUTES TO TEST THE PACKER AND ANNULAR VENT VALVE. RETRIEVE THE X PLUG ON W/L. IF PRESSURE HOLDS, PROCEED TO STEP 12. IF PRESSURE DOES NOT HOLD, RETRIEVE THE PACKER/TRSCSSV SYSTEM, REPAIR OR REPLACE IT, RIH, RESET, AND RETEST IT. 12. NIPPLE DOWN BOPs, N/U AND TEST WELLHEAD TREE, RIG DOWN WORKOVER RIG, MOVE TO NEXT WELL. THIS PROCEDURE IS IN ACCORDANCE WITH AN EARLIER PROCEDURE WHICH WAS: PREPARED BY STEVE ROSSBERG, SENIOR PRODUCTION ENGINEER (3/23/90) REVIEWED BY MARC SHANNON, SUPV. PRODUCTION ENGINEER (3/27/90) APPROVED BY GARY FLOWERS FOR JACK COPELAND, PRODUCTION SUPT. (4/3/90) J.D. POLYA DRILLING FOREMAN Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-76OO December 23, 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 histories" from Conoco's Milne Point Unit Wells No. C-17, C-19, B-20, B-21 and B-22. If you .require additional information concerning this well history, please contact Mike Zotzky at 564-7623. Yours very truly, E. D. Wilson Sr. Administrative Coordinator vv C-17, C19, B-20, B-21, B-22 DEC £ Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Point B No. 20 - CONFIDENTIAL (8295'-Kuparuk River) AFE 10-61-1153 API No. 50-029-21524. Ak. Permit No. 86-5. Elevation: 59' KB. Location: 930' FSL, 673' FWL, Sec. 18, T13N, RILE, U.M. 01-16-86: Set pipe shed #2, level sub, NU Tankco equip. NU 20" Hydril & diverter. Install mousehole. Load BHA in pipe shed, repair skate, strap BHA. PU BHA, service MWD. MU BHA & test diverter system. Spud well, drlg from 108' to 443'. 01-17: Drlg. Work on MWD system. Drlg to 2516'. Circ, pump pill, POOH. Thaw hole fill line. POOH, LD, stab, PU Navidrl & BS. Orient BHA, test Navidrl, RIH to 2516'. Navidrl from 2516' to 2780'. 01-18: Navidrl from 2780' to 3521'. Pump pill & POOH for bit & BHA change, change Navidrl & bit. Service MWD. Test Navidrl, RIH to 1667'. Cut drlg line. Finish RIH. Navidrl from 3521' to 3557'. 01-19: Orient, Navidrl and drl from 3557' to 4749'. MWD failed, RU and run single shot. Drld from 4749' to 4930'. 01-20: Drld from 4930' to 5045'. Short trip to 2500'. Circ and cond mud, drop single shot. POOH & LD BHA. RU & run 126 jnts 9 5/8", 36#, K-55 btrc csg, (FS @ 5034' FC ~ 4952') w/full returns. MU hgr & cmtng head, circ and recip pipe. Pump 50 bbls of Zeogel spacer. Mixed & pumped 1300 sks of Permafrost E and 275 sks of Class G w/3% NaCI and 1% CFR-2 w/full returns. 01-21: Displaced cmt w/382 bbls of 9.4 ppg mud, circ out 160 bbls cmt, lost returns w/20 bbls left to displace. Cmt didn't fall back at surface. RD cmtng head & LD lndg int. ND flowline & 20" diverter, clean cmt out of same. Make up speed head. NU BOP. Test BOP's and choke manifold to 5000 psi, annular to 3500 psi; witnessed by Harold Hawkins - AOGCC. PU BHA, orient MWD, test Navidrl. RIH to 4936', test csg to 2500 psi for 30 min, O.K. Drld FC cmt & FS, clean out to 5045'. 01-22: Drld from 5045' to 5073', ran 12 ppg shoe test, O.K. Drld from 5045' to 7130'. 01-23: Drld from 7130' to 8295'. Mix and pump pill. POOH to 5034' for short trip, RIH to 7350', work tight spot. RIH to 8081', work tight spot, RIH to 8295'. Circ & cond mud, MWD survey. 01-24: POOH, SLM 8297', service MWD & LD, LD Navidrl. RU Gearhart, RIH w/GR-SP-CNL-FDC- DIL to 8296'. Log to 7750' w/all tools, run GR-CNL to 3600', RD Gearhart. MU BHA, RIH to 8264'. Circ & cond hole. POOH, LD DP to BHA. Cut & slip drlg line. POOH, LD HWDP & BHA. Change rams & RU csg crew. 01-25: RU to run csg. Run 211 jnts 7", 26#, L-80 btrc csg, shoe ~ 8270', FC ~ 8187' w/full returns. Circ & cond hole, pumped 40 bbls 12 ppg Zeogel preflush ~ 8 bpm. Cmtd w/275 sks Class G w/l% CD-31, displaced w/314 bbls 7.6 ppg NaC1 brine, bumped plug to 3000#, tested csg to 3000# for 30 min, O.K. Tested floats, O.K. LD lndg jnt, wash out BOP, insiall packoff & test. RU Camco, RIH w/Gyro, GR-CCL. Kuparuk River Field North Slope Borough, Alaska W.I. - 50.58467% Milne Point B No. 20 - CONFIDENTIAL (8295'-Kuparuk River) AFE 10-61-1153 API No. 50-029-21524. Ak. Permit No. 86-5. Elevation: 59' KB. Location: 930' FSL, 673' FWL, Sec. 18, T13N, RllE, U.M. (cont'd.) 01-26: Finish running Gyro, CCL-GR, PU & RIH w/gauge ring and junk basket. RD Camco. R to run tbg. Make up Vann guns & packer. RIH w/149 jnts 3 1/2", 9.2#, L-80 EUE tbg. RU Camco, run correlation log, RD Camco. Space out tbg & make up hgr. Land tbg, close CV after pumping 10 bbls diesel. Set pkr, shear out of PBR & open PV. Finish displacing tbg w/diesel, test SSSV to 1000 psi. Land tbg, test backside to 1500 psi, install BPU. ND BOP. 'rom 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 Mitne Point. The attached sundry notices are intended to serve as notice of the pending temporary shut-in of all wells located within the Miine Point Unit. There are 19 active and 5 inactive production wells at Miine Point. ~TiVE: B-3, ~-~,~ '~ B-6, B-9, B-10, ~-i!,_ B-!3, B-15, B-16, £-~., C-2, C-3, C-4, C-5A, C-7, C-9, C-~3,~ C-14, C-16 ~ C-17, B-?0, ~-?], ...... C-!g Ail active production wells will be freeze protected by displacing the top 3000' of the cubing with a 1:3 diesel:oil mixture. The annular fluid levels will be monitored for leaking gas lift valves. If necessary the 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 surveys 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 ?oint Unit. [~ .~ ~., ! ACTIVE: B-8, B-!2, B-14, B-17, B-18 C-8, C-il, 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. %hough only one well is active at any given time, all wells are capable of produc- ing. A-2A; B-l; 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 wells have 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. The wellbore 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 questions on the shutdo~ procedure please contact Don Girdler at 564-7637. Yours very truly, Painter ~~jv~sion Manager STATE OF ALASKA ALAS, OIL AND GAS CONSERVATION COMi, ,,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate IL3 Other 2. Name of Operator 5. Datum_elevation (DF or KB) Conoco Inc. 59' KB feet 3. Add~ez~l C Street, Ste. 200 Anchorage, Alaska 99503 6. UniLo~Prol~ert.v ease .. , mi±ne 'roln~: unz~: 4. Location of well at surface 930' FSL, 673' FWL, Sec. At toP_of productive interval 2074 ' FNL, 595' FWL, Sec. At effective depth N/A 610' FWL, Sec. 18, T13N, RilE, U.M. 19, T13N, RilE, U.M. 19, T13N, RllE, U.M. 7. Well number B-20 8. Permit number 86-5 9. APl numt~.r9_21524 50-- 10..PO~uparuk River 11. Present well condition summary Total depth: measured true vertical 8295 feet 7 196 feet Plugs (measured) Effective depth: measured N/A feet true vertical feet Junk(measured) Casing Length Size Cemented Structural Conductor 80 ' 16" To Surface Surface 4998' 9 5/8" 1615 Sxs Intermediate Production 8236 ' 7" 270 Sxs Liner Perforation depth: measured 7994'-8013'; 8017'-8047' true vertical 6965'-6980'; 6983'-7006' 3~" L-80, 7966' Tubing (size, grade and measured depth) 2 , T.R. SCSSV @ 1892' Packers and SSSV (type and measured depth) Measured depth 115' 5034' ~ue Verticaldepth 115' 4693' 7177' ; Ret. Pkr. @ 7921' 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 15. I hereby_ certify that the fpregoing is true and correct to the best of my knowledge Signed ~~;~,,~...._ _ Title gr. p,rnd,,~.r.inn l~.n~.in~,~, Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by Commissioner IApproval No. by order of ~.' the commission Date/ subr~ii ir{ triplicate Form 10-403 Rev 12-1-85 STATE OF ALASKA ALASK, ..... ~ AND GAS CONSERVATION ~._ ,MISSION WELL COMPLETION OR RECOMPLETION HEPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 86-5 3. Address 8. APl Number 3201 C Street, Ste., 200, Anchorage, Alaska 99503 50-029-21524 4. Location of well at surface 9. Unit or Lease Name 930' FSL, 673' FWL, Sec. 18, T13N, RllE, U.M. Milne Point Unit At Top Producing Interval 10. Well Number 2074' FNL, 595' FWL, Sec. 19, T13N, RllE, U.M. B-20 At Total Depth 11. Field and Pool 2267' FNL, 610' FWL, Sec. 19. T13N. RllE. U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Field 59' KBI ADL 474.38 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 1-16-86 1-23-86 1-27-86I N/A feet MSL 17. Total Depth (MD+TVD) 1B. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8295' (7196') 8146' (7082') YES[~ NO[]I 1892 feetMD 1800+ 22. Type Electric or Other Logs Run GR-SP-CNL-FDC-DIL, Gyro-CCL-GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 9 5/8" 36# K-55 0 5034' 12¼" 1340 sks Perm E 275 sks Class G 7" 26# L-80 0 8270' 82"~ 270 sks Class G 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) 3~" 9.2# L-8t 7966' 7921' MK_I: - 7994'-8013' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6965'-6980' TVD All Shots 12 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 120° phasing, 5" guns MK-2: 8017'-8047' MD 6983'-7006' TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED,a~ 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. ,, Submit in duplicate~/ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKER. S NAME NA OA T/Kup Interval M. Kuparuk Lam. Kuparuk L. Kuparuk MEAS. DEPTH 4052' 4354' 4603' 4777' 7833' 7994' 8156' 8270' TRUE VERT. DEPTH 3938' 4178' 4367' 4497' 6839' 6965' 7090' 7177' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Sign e d~:~ ~~~ Title ~-.~/~/~/~/'~ ~'~' 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". I:nrm 1N-4 N7 Conoco Inc. 3201 C Street Suite 200 Anchorage, AK: 99503 (907) 564-7600 February 24, 1986 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Well Completion or Recompletion Report and Log Attached for your information and file are the original and one copy of 'each of the required reports referenced above. If you should have any questions please call Lynn Alexander at 564-7609. Very truly yours, Everett D. Wilson Division Administrative Manager LA/vv Att. .~-~'. STATE OF ALASKA ' -' · -~ ALASK/ .... AND GAS CONSERVATION C .. .MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED E~ ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Conoco Inc. 86-5 3. Address 8. APl Number 3201 C Street, Suite 200 Anchorage, Al. aska 99503 5o-029-21524 4. Location of well at surface 9. Unit or Lease Name 930' FSL, 673' FWL, Sec. 18, T13N, RIlE.~ U.M. Milne Point Unit At Top Producing Interval 10. Well Number 2074' FNL.~ 595' F'~L~ Sec. 19, T13N, Rile, U.M. B-20 At Total Depth 11. Field and Pool 2267' FNL, 610' FWL, Sec. 19, T13N, R11E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri ver 5_9,' KBI ADL 47438 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. J 15. Water Depth, if offshore 116' No. of Completions 1~,,16-86 1-23-86 1-27-86I N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8295'MD(7196'TVD) 8146'MD(7082'TVD) YES~ NO[]I 1892 feetMD 1800'-+ 22. Type Electric or Other Logs Run GR-SP-CNL-FDC-DIL, Gyro-CCL-GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9-5/8" 36# K-55 0 5034' 12¼" 1340 sks. Permafros E 275 sks Class G 7" 26# L-80 0 8270 8'-"2 270 sx. Class G 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) MK-I" ~-~"92 .2 L-80 7966' 7921' 7994' - 8013' MD 6965' - 6980' TVD A11 Shots 12 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED MK-2' 120~...phasing, 5" guns 8017' - 8047' MD 6983' - 7006' TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED 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. . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. KA MA NA 0A NAME GEOLOGi'C MARKERS MEAS. DEPTH 4052' 4354' 4603' 4777' T/Ku-P/Interval Middle Kuparuk Laminated Kuparu Lower Kuparuk 7833' 7994' 8156 8270' TRUE VERT. DEPTH 3938' 4178' 4367' 4497' 6839' 6965' 7090' 7177' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is tCue and correct tQ'the best of my knowledge Signed /~k./~ ~ ~, Title Pr°duction Engr- Date 2/14/86 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- 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: If no cores taken, indicate "none". Eastman/ l Whipstock l .A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY Pad B, ~~?Number: 5~ilne Po~' North Slope, 2O Alaska LOCATION JOB NUMBER 450.-025 TYPE OF SURVEY Gyro F~u ltl-Shot DATE 2 tl --.,.lAN--- SURVEY BY B JAHN OFFICE Anchorage, Alas]ca Eastman' Whipstock A PETROL/WE COMPANY Date: January 30, 1986 (907) 563-3650 P. O. Box 4-1970~Anchorage, Alaska 99509-1970 Conoco, Inc. 3201 C. Street Suite 200 Anchorage, Alaska 99503 Well Number: Pad B, Well No: 20 Location: Milne Pt., North Slope, Alaska Type of Survey: Gyro Multi-Shot Date: 26-JAN-86 Method of Computation: Radius of Curvature Surveyor: B JAHN Job Number: 450-025 Attn: Mr. Dan Robertson Dear Mr. Robertson: We are enclosing the original and one copy of the Gyro Multishot survey run on the above mentioned well. To date, the following distributions have been accomp- lished: A. 1 Copy delivered to drilling in-house distribution. B. 9 Copies noted for oil company representatives. C. 3 Copies for E/W permanent well files. We wish to take this opportunity to thank you for using Eastman Whipstock and look forward to being of service in the furture. S_in~ere ly, Dis%~Liz~ Technical coordinator TJ/pdh cc/file cc: Kathy McGill O.G. Kiel - P.E.S. Reservoir Section Conoco H.E. Gilliland - P.R.D. Reservoir Section Conoco William Van Allen - Alaska Oil & Gas Conservation Commission J.L. Weaver - Chevron U.S.A., Inc. Dave Engstrom - Chevron U.S.A., Inc. San Ramone Jim Laws - Champlin Petroleum Co. C.E. Seery, Jr. - Reading & Bates Petroleum Co. Neil Buttram - Cities Service Oil & Gas Corp. Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide EASTMAN WHIPSTOCK, INC. REE:ORD OF SURVEY F' ri R OPERATOR STRUCTURE : F'AD B WELL LOC:AT I ON dOB NUMBER : RIG : DECLINATION : 30.50 E RKB TO SEA : 59.0 : CONOCO, INC:. : 20 '-'.:,LL]T .' 20 : MILNE F'OINT, NORTH 'SLOF'E, ALASKA PLANE OF VERTIC:AL SECTION DIRECTION : S 0 42 E EW DISTRICT : ANCHORAGE, ALASKA Eastman Whipstock CONOCO, INC:. PAD B MILNE F'OINT, NORTH SLOPE, ALASKA · SLOT : 20 WELL : 20 F'BHL : S 0 42 E DATE PRINTED : 30-.JAN-:S:6 OUR REF. NO. : :E;05484.8C:0 dOB NUMBER : PAGE NO. : MEAF;URED DRIFT DRIFT F:OURSE TRUE VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGL[ ~' F' D I '.E;VRT' DEF'TH ANGLE DIRECTION LENGTH VERTICAL .=.E_.TION TVD C: 0 0 R D I N A T E '..2; DISTANC:E IRECT ON D M D M DEPTH D M 0.00 0 0 N 0 0 E 0.00 100.00 0 0 N 0 0 E 100.00 20£).0£) 0 0 N 0 0 E 100.00 :2:00.0o 0 0 N 0 0 E 100.o0 400.00 0 0 N 0 0 E 100.00 500.00 0 0 N 0 0 E 100.00 600.00 0 0 N 0 0 E 100.00 700.00 0 15 C-; 78 :=:0 E 100.00 :300.00 0 15 S :3:3 0 E 100.00 ':-.~00.00 0 15 .'_=; 54 30 E 100.00 0.00 0.00 -59.00 0.00 N 0.00 E 100.00 0.0C) 41.00 0.00 N 0.00 E 200.00 0.00 141.00 0.00 N 0.00 E 300.00 0.00 241.00 0.00 N 0.00 E 400.00 0.00 341.00 0.00 N 0.00 E 500.00 0.00 441.C)C) 0.00 N 0.00 E 600.00 0.00 541.00 0.00 N 0.00 E 700.00 0.05 641.00 0.04 S 0.21 E 800.00 0.12 741.00 0.11 S 0.64 E 700.00 0.28 841,00 0.27 'S 1.05 E 0.00 S ':';'0 0 E 0.0~ 0. O0 S '.::.'0 0 E O. (':,. ·...,:..':"=' S 78 :=:_ c). E 0 . ..-.'-" 0.65 S :30 0 E 0.0: 1.08 S 75 :_=:2 E 0.1'. 000.00 0 0 N 0 0 E 100.00 1000.00 100.00 0 0 N C) 0 E 100.00 1100.00 200.00 0 15 N :38 0 E 100.00 ' 1200.00 300.00 0 15 N 8'F./ :3C) E 100.£)0 1:300,00 400.00 0 0. N 0 0 E 10C).00 1400.00 0.41 941.00 0.41 1041.00 0.24 1141.00 0.06 1241.00 C). 06 1:341.00 ('). 4,[:~ ::; 1.22 E 0.40 S 1 .... ' ...,::..,:= '..2; 1. :2:6 E 0.04 S !.7:3 E 0.0,4 :---; 1. ':.--'5 E 2'-.":'.:E; '7. 2 :3 E ,:')_.z..'-" 2'F.-' S 72 ::: E 0.0, :2:7 S 80 35 E ,F:,,.2~ 74 '.=; 8F:: 44 E 0.2: 95 S :i.:.:8 56 E 0,2! 500,00 0 15 N 44 30 E 100.00 1. 500,00 600.00 c) 0 N 0 0 E 100.00 1600.00 700.00 0 0 N 0 0 E 100.00 1700.00 '~0.00 0 0 N 0 0 E 100.00 1800.00 · )0.00 0 0 N 0 0 E 100.00 1?200.00 -0.09 1441,00 . .,::.._, 1541. C) 0 -0.25 1641.. 00 -F~. ';25 1741.0 (:) -0.25 1841.00 (').. 12 N ,-.":". 1 ¢)- E 0.27 N '-'2.26 E 0.27 N 2.2:6 E: 0.27 N 2.26 E ().,27 N ...,'-' 26 E 2. 11 N :::/-, 47 E ,r') . ...... 2.2'7. N :3:3 .=;_ E c)...,::.'-" 2,27 N :.2::3 5 E 0, 2.27 N :'2::3 5 E 0.0~ 2.27 N :.2::2: 5 E 0.0" 2000.00 0 0 N 0 0 E 100.00 2000.00 2100·00 0 0 N 0 0 E 100.00 2100.00 2200.00 0 0 N 0 0 E 100.00 2200.00 2300.00 0 0 N 0 0 E 100.00 2300.00 2400.00 0 0 N 0 0 E 100.00 2400.00 -0.25 1941, O0 -0.25 2041.00 -0.25 2141.00 -0.25 2241.00 --0 '-"=' o.-, · ..' ._, -.- o 41 · 00 0.27 Iq 2.26 E o..27 N ~.'-' 26 E 0 27 N '-' 26 E 0.27 N 2.26 E 0,27 N '2.26 E .-' 2'7 N ':":' . ,-,._, .-, E (") (') 2.27 N 8:=: 5 E 0, '=:. 27 N ::33 5 E 0. '::' 27 N ':":' .=;E ,F) ¢)~ 2,27 N :.2:3 5 E 0 2500.00 0 15 N 60 0 E 100.00 2499.99 2600.00 1 0 S 24 0 E 100.00 2599.99 2700.00 3 15 S 4 0 W 100.00 269'='.~.91 2800.00 5 30 S 7 0 W I00.00 2797.62 2900.00 8 45 S 6 C) W 100. O0 28'F.~:E:. 83 CONTINUED ON NEXT PAGE ... -0.35 2440.99 -0.04 2540.99 3.58 2640.91 11.16 2740.62 23.47 2839.83 0.38 N 0.08 N 3.53: S 11.12 S 2:3.45 2.44 E 2.47 N :.2:1 7 E 0.21 3.36 E 3.37 N 88:35 E 1.0~ 4.00 E 5.34 S 48 34 E 2.4 3.27 E 11.60 S 1/-. 2:.2: E 2.2~ 1 6:7 E '-"':'-="- ' . .,. ...... ',-' S 4:2::':. E :'-:. 21 = East n CONOCCt, INC:. F'Alr~ B MILNE F'OINT, NORTH SLOF'E, ALASKA '.:;LOT : 20 WELL : 2(:) PBHL : c.._, 0 49_ E DATE PRINTED : .:,O-,.IAN-o OUR REF. NO. : S05484.:=:C0 ,_lOB NI_IMBER : F'AGE NO, " MEASURED DRIFT DRIFT COURSE TRUE VERTICAL RUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE DEPTH ANGLE DIRECTION LENGTH VERTICAL '.=~EC:TION TVD C: 0 0 R l]I N A T E S DISTANCE DIREC:TION SVRT' D M D M DEPTH D M 3000.00 11 30 S 8 0 W 100.00 2'FJ'P7.26 3100.00 14 0 S 10 0 W 100.00 30'74.7 3200· 00 16 30 S 8 0 W 100.00 318~1.26 3300· 00 I?J 15 S 7 0 W 100· 00 3286.42 '-'400.00 21 30 S 7 0 W 100.00 3380.16 :-4500.00 24 0 S 6 0 W 100.0C) 3472.37 3600.00 26 45 8 4 0 W 100.0¢) 3562.72 3700.00 31 0 S i 0 E 100.00 3650.27 3800· 00 33 30 S 2 0 E 100· 00 :3734.8:-.: 38~00.00 35 45 S 2 0 W 100.00 3817.11 · -- . al.. o- --J I~J l 62.64 3035.7'F/ 88.56 3132,26 118. '.--.J4 3227.42 153.44 3321.16 191.80 3413.37 234.44 :_-:503.72 282./..:,7 :35'~ 1.27 :-.:36.02 3675.8:} 38y2.82 375:-.:. I 1 40.8'-7 S 0.27 W 62.67~ S 3.73 W 8:-.:.66 S 7.84 W 11'F/.07~ S 11.85 W 15:}·65 S 16.08~ W 1o°;-.(])7 S 2(')..47 W 234.75 ._, ¢' 24. _'.-~o. W 28 :}. ¢) 0 ¢'._, .--._~-' .~;. 46 W ':'":: "- :5:4._,':' :24 .07 W :5:? :'-':. ! 4 S 2 4.0 7 W 40.83~ S 0 2:3 W '2.7: 62.80 S :--: 24 W 2.5, 8'F~. 01 S 5 3 W 2.5~ i 1 'F/./-_, o,_, '.B 5 41 W 2 .7' 154.4 ?~ S 5 5'P W ':-.'..--, 17:3. 15 S 6 5 W 2.5: .' ._1 ._ . .... -_ ~ a-- · 284. 14 '.-; 5 9' W 4.8: :2::2:7.20 8 4 6 W 2.5~ · --,o---, ,=, o S :--: :=: 0 W :3.2' 4000.0 ('). 37 4.5 ._, '=' :3 0 W 100 .0 () :38'F.' 7 .24 4100.00 37 30 S 3 0 W 100.00 37,'76,44 4200.00 37 0 S 4 30 W 100.00 ' 4056.04 . lO.=,. 4:}00.0¢) :37 15 'S 4 C) W 100'0¢) 4 ..... 77 4400.00 40 45 S 4 0 W 100.00 4213.47 452.55 3838·24 51:3.48 3917.44 573.82 3797.04 633.95 4076.77 6?6.66 4154.47 4._..'.71 S 26 /~,P W 513 GO ,.=; '-'- :-.:7 W 574· 28.:,'-' 33.8:3 W 6:34· 47 'S ._,':'°,_,, :";:o.. W 6?7 ':.24 S 42.6? W 453.70 S :} 22 W 2.o' 14 75 S :--: 2¢) W (";' '-" 575 27 ':' 3 '-"-' · ~ W 1 '-~.~1 · '-! . m 6.:,._ 62 S 0.:-, 2'7 W 0 ,':-,'.~ 8.54 S :--: 3 (] W :}. 5: 450¢). C)¢) 41 ¢) S 2 30 W 100, 00 4289' . o'='..,,.. 761 . c..,~..._ 4230 . (}'.:.,' 762 .57_ ':'._, · 4.:, :.:, 4 27 827 70 4...:(..-,. 27 828. :2:8 .=, 46(')0.00 41 30 '.E; 4:30 W 100 ¢)0 '-'/ · · '-')':- '-' 4700 C) 0 41 15 ¢' 4 0 W 100. C) 0 443'F¢ · :31 ,:, c¢.-., = ~ 8 ? 4. ::: 0 '.E; ........... ,.._, =, 4:2:80. :2:1 ~ 44._,._, 64 S ')0.00 41 0 c. 4 °(' F, 64 '~R9 08 = = 3-~59 :=:9 · _,.) W 100 00 4._14. · _l · .- '-- . . . · - - -- · 4-_,.:, 1 .... -,. 00.00 4C) 15 c.~, 6 0 W 10C), 0C) 4.~9(')_. .. 5:-.:_ 1¢')22. .. 84 ~'~' . F,~-' 1024.72 S 5000.00 39 45 S 7 0 W 100.00 4667.14 1087.61 4608·14 1088.57 8 5100·00 39 0 S 7 30 W 100.00 4744·44 1150.44 4685.44 1151.52 S 5200.00 37 30 S 8 0 W 100.00 4821.88 1213.02 4762.88 1214.21S 5300.00 39 45 S 6 30 W 100.00 4898.90 1276.18 4839.90 1277.47 S 5400.00 40 0 S 3 0 W 100.00 4975.65 1340.00 4716.65 1341.36 S 5500.00 39 45 S 3 0 W 100.00 5052.39 1403.98 4993.39 14C)5.38 S 5600.00 37 45 S 2 0 W 100.00 5127.27 1467.82 5070.27 1467.26 S 5700.00 39 45 S 3 30 W 100·00 5206.16 1531.65 5147·16 1533.13 S 5800.00 40 15 S 3 0 W 100.00 5282.76 1575.78 5223.76 1597.31S ~5900.00 40 30 S 1 0 W 100.00 5358.95 1660.48 5279.95 1662.04 S CONTINUED ON NEXT PAGE ... 106.68 W 1407~.42 S 4 20 W 0.2~ 10'F~.47 W 1473.34 S 4 16 W 0.6, 112.54 W 1537.26 S 4 12 W 0.'.~ 116.18 W 1601.53 S 4 10 W 0.5'i 118.44 W 1666.26 S 4 5 W 1.3] n CONOCO-, INC:. PAD B MILNE POINT, NORTH SLOPE, ALASKA SLOT : 20 WELL : 20 F'BHL.' ._,c. (]. 42 E DATE F'RINTED : 30-,JAN-86 OUR REF. NO. : S054:34.:::C0 dOB NUMBER : Z/SO-oZ~ PAGE NO. 4 MEA:E;URED DRIFT DRIFT COURSE TRUE VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOGLE oE_.TION TVD C 0 0 R D I N A T E :--' DISTANCE I RECTI '.E;VRTY DEPTH ANGLE DIRECTION LENGTH VERTICAL ~' c' , £1CIN D M D M DEPTH b M .~ --, ,.~9 .=,--,-'= 9,-} 1726 '.~,q ¢' /-,000 00 40 30 o 0 0 W 100 O0 ._4.z, 4 1725 41 ._._./._,. ..~ -- m ._m . . . · · · · /-,_ 100. C)0. 40 :%)_ ._,c. C). 0 W 100 .00 5511 .03 1790.35 54~':'_ _ _. 03 17.91 . .9~:_ c.._, '-'5 77¢ ~=o,-, 49 1856:37 S 6200 00 29 4.5 c. 0 0 W 100.00 5587 4'2 1,:,._4 .... ,~,:, 6300.00 40 0 c- i 0 W 100 00 5664.23 191:3.:::.9 ~"'~ -- ' .... . _ ._ =,,~._,. Z :z: 1 '.720.48 S /-~00.00 40 15 S 0 0 W ~00.00 5740.70 1'F~:3:3.:32 56:31.70 1984.9:3 S 6500.00 3.9 45 S 1 0 W 100.00 5817.30 2047.5:3 5758.:30 204.9.20 S 6600.00 40 0..,'z' 0 0 W 100 .00 ._,,=, ~ 4 . C). ~_ ~'z~ 111 . 68 ._~.z, ~'._,°._,~ . 05 ~'-' 11.z.'-'. 31.z.'-' /-,700_ .00 40 45 c..., O. 0 W 100.00 5970_. .23 2176.45 ~91_. I . z.:,'-'" 2178.09 S '-' ' R 2243 52 S /_-800.00 41 0 .=, 2 0 E 100.00 6O4._ ""= ....... . ,=,._, 2241 :~ 9 ~ 9:=:/-,. '='~ . m_l ._ m 6.900.00 41 0 c. 0 E 100 00 6121 .... ~ ........... ._, .;: , ':"-' 2:307,46 &OA2 ._,= 9'::o,;¢ 06 .., 119.01 W 17:31 ·'¢' '-' (.) 117.01 W 17.95. ,=,o S .3 48 W 0.0C 11 ~. 01 W 1 :=:60. 1 '.7 :=; :_--: 40 W 0.7.=_ 11.9.57 W 1'-724.2o 8 3 34 W 0.6'F, 120. 1'-~,._ W 1 '.788 . .=,/-,_ _ .z,'-'._ 120./-,_ c~.. W ~..'.-.' o F,_ 2 .75 S 3 2 .. '~' W 0 . o._. 1 121...' ._,'-' = W ..':' 1 16, . 7'z~.. ,z-._,._'-] 17 W 0 ,6, S 1 'sd 1.5.'5 W 21 :=: 1.46 '.E; :':: 1 1 W 0.7~ 120. 11 W ..' ..' 4 s,. 72-:._-, L--: 4 W I 3 L~ 117.25 W 2312.04 S 2 54 W 0. 7000.00 40 15 S 3 0 E 100.00 61.97.21 2372.52 6138.21 2374.0? S 7100.00 40 30 c-._, 3: 0 E 100.00 6273.40 2437.~._~'~ 6214.4(]) 2438.77 S 7200.00 40 0 S 2 0 E 100.00 ' 6~47.72 256)1.83 62~0.72 2503.32 S 7300.00 37 45 S 3 0 E 100.00 6426.46 2565..91 6367.46 2567.37 S 7400.00 3.9 45 S 2 30 E 100.00 6503.35 2627.81 6444.35 2631.24 S 113. :34 W 2 :--:_ '7. z-,_. :q_ l .z,'-'2 4.5 W c).. 7 F_ 110.45 W 2441.27 :z; 2 3/_', W C).2F- ~C) =' /-,:2: .z. '-' 2:.'-:: W C) :32 107.6:3 W 2._,.._,. _ ._, ~: _. 104.84 W 256.9 · 51 '.::; 2 2:0 t.4 0.6'.:. 101.77 W 26:3:3.21 '.3 2 1:3 W 0. :--: 2- 7500.00 3.9 30 S ~'o 0 E lO0.0C). 6580. :37 .s'-'z- cr-,:,; .=.._~4 6._z1~'-' .37 26'.74 . .94 S 7600 00 ':"~ 45 ':' 4 0 E 100 00 6 a._, 7.9 ~ ':' 7~ a ._ 7 ,~ ~ 9 ::: 7700.00 ?:9_. 15 S 3 0 E 100.00 67o._ ./-,6_ 2819.42 6676./-,6_ 2~:20_ .. 74 c-._, ~'0 00 3:3 45 S 4 0 E 100.00 6813 '-'?' 2:~:~2 .s,o ~ . . o o 67._ 4. '-~ P '" '~ q o 55 '-' .,0.00 :~:~ 30 c 5 0 E 100.00 68~1 ~(') 2.944 ~z-. ~ ~"-'~' 50 c.c~. ~ - - ... ...... $, o.s, ~. ~ .... 78 S '.--..' 8.71 W 26'.--.~ 6.7.5 S 2 6, W 0.4 ] 94.86 W 275.9.5/_-, ,.z; 1 5:_--: W 0. '.7:: '-7/. 1 . C). 2 W 2:322 · 21 '.E; 1 51 W 0 . o,_, (. 87. 18 W 2:s::=:4.87 S 1 44 W O.:E:C '-'o .-"-'...":":',-, W 2'.74- 6..9:3 c.._. 1 :":. 6 W 0.6; 8000.00 37 0 S 4 0 E 100.00 696.9.49 3007.01 6710.4.9 3008.17 S 8100.00 40 0 S 4 0 E 100.00 7046.65 3070.51 6.987.65 3071.63 S 8200.00 40 0 S 5 0 E 100.00 7123.26 3134.65 7064.26 3135.71S 82.95.00 40 0 S 5 0 E 95.00 7176.0~ 31.95.54 7137.03 3196.54 S 77 ...... :37 W :z:o09 17 .z,'-'1 ,.--.=:'-"- W o.. :=:c_. 72,.9:3 W :3072.4.9 S 1 22 W 1.o( 67.:_=:.9 W :31:36.44 S 1 14 W 0. /-':' 57 W :3197.15 :S 1 7 W 0 0( CLOSURE - D I ST;%NCE : ~ ! 97.15 DIRECTION :._,¢' 1 7 W REPORT UNITSFeet SURVEY C:ALC:ULATION METHOD : Rmdius of c,Jr.v~t,Jr.e SURVEY RUN INFORMATION 0-,:, ..' 0 J M D GYRO MULTI SHOT SURVEY, ' '"'-' c . R JN 26-dAN-86 :SURVEYOR: B OAHN DATE ,t : SURVEY RUN INFORMATION - (CONTINUED) GYRO NO: 39~, 90 DEG A/U NO: 1536, CAMERA NO: 1572 dOB NO: 450-025 NOTE: 8295 MD IS PROdECTED ONLY Eastn~n ~--~~ ~ Whi.pst~oc~_k~l /~ CONOCO, INC. PAD B WELL: 20 SLOT:20 MILNE PT., NORTH SLOPE, ALASKA GMS, 0-8200 MD, SURVEYOR: B dAHN, DATE RUN: 26-dAN-86 FILE: 3052 REVOX FROM SPUDD RECORD OF INTERPOLATED SURVEY [-/ Eastn~n ~ ]ONOCO, :'AD IB dELL: 20 KA KB KC KD LA MA MB NA NB NC ND NE NF OA OB Un c c,n~:. Mkr- 19 T/KI T(" '::- 1 B/MK-1 T/MK-2 B/MK-2 L-8 L-9 PBTD T / /K- 1 TD ' INE:. :SLOT: 20 MARKER ....... CODE NAME MEASURED DEPTH FEET 4052.00 4109.00 4153.00 4226. O0 4245.00 4283.00 4354.00 4430.00 4603.00 4627.00 4659.00 4672.00 4700.00 4750.00 4777.00 48:3:E:. 00 7565. C)0 7674. O0 7833. 00 7994. O0 8013.00 8018.00 8047.00 8156.00 8176.00 8189.00 .~' .,.,. 00 E,.-~ o~. (')C) TRUE VERTICAL DEPTH FEET :3 ~ 38.42 3'.;~83.60 4018.63 4076.77 40~ 1.92 4122.21 4177.73 42:36.16 4366.52 4:384.53 4408.54 4418.30 4439.31 4476.97 4497.31 4543.48 6630.80 6715.46 6839.16 6964.81 697~.52 6983.38 7005.76 7089.55 7104.87 7114.8:3 7176 7196.03 SUBSEA VERTICAL DEPTH FEET 3879.42 :3'~24.60 ~,o=~, 63 4017.77 4032.92 4063.21 4118.7:3 4177. 16 4307.52 4:325.5:3 4349.54 4359.30 4380.31 4417.97 4438.31' 4484.48 6571.80 6656.46 6780.16 6905.81 6920.52 6924.38 6946.76 7030.55 7045.87 7055. :5:3 7117. ~.o 71:37.0:3 COMF'UTAT I ON TIME DATE I5: ~ '-'/. :30-dAN-:~/. 2.-: ,:, -', . -- F'AGE NO. RECTANGULAR C: 0 0 R D I N A T E S FEET 484.61S 28.34 W 519.31S 30.23 W 545.89 S 31.97 W 589.93 S 34.99 W 601.36 S 35.84 W 624.23 S 37.54 W 668.36 S 40.67 W 716.84 S 4:3.81W 830.36 S 50.57 W 846.18 S 51.75 W 867.27 S 53.:32 W 875.84 S 53.95 W 894. F:O_ :-'; ==._,._,. :3:3 W 927.09 S 57.76 W 944.80 S 59.08 W 984.52 :=; 62.46 W o7o.=, ,:,,:, S 96 21 W ~ ..._1._ i I_II!1 2:E:04.41 S 92.(:)2 W 2904 09 :~ ~' ~ .~,6 W , -- ~"~._l, -- 3004.43 S 77.66 W 3016.42 S 76.79 W 3¢)19.60 S 76.57 W 3038.00 S 75.28 W 3107.51S 70.11W 3120.33 S 69.10 W :31 '-"'- . _. · -~,~.66 S A~ 44 W :31:::0_....~'~'._, S 63 · 97 W F:1S/6.54 S 62.57 W C L 0 $ U R E DISTANC:E DIRECTION FEET D M 485.44 c'._, :3 21W 520.19 S 3 20 W 546.82 S 3 21W 590.~6 S :3 24 W 602.43 S 3 25 W 71~_.17 ._,¢' 3:30 W o~-'1 90 S :':: 29 W i_~._1. . . . . , :, S :2: W o'-'/-.,,.,°. 9. 1 S :--: .31 W 877.5o S :3:2:2 W .:, ;~6.01 ._.':':2: :2:2 W ';'. 2 :R_. :'~. ':'-~, .:,'-':5: :2:4 W 946.65 S :2: ._,":'.=i._ W : PAD B · i/ELL ~, 20 ,.~ SLOT ~ 20 EASTI"IAN 'dHIPSTOCK, INC. -VERT [CAL.-' PRq-3ECT i~ ON-'i SCALE 1 'IN. -!2000 FEET , ...................... [ 5500 6000 6500 7500 800.0 ~ ,_. 500 1500 2000 ........ ~ 2500 I'q ..... · -,. 4000 ...... o 4500 2000 ~ooo . V£RTI¢^L~-.SE-CTtOH .... CLOS:URE..i3.19.~.,.~.].5....i.S ...... 1. 7 ....... 1...7 SLOT~20 ! DEPTH 8295 HD. 71'96.03; TVD .... ~ ..... SOUTH 3196.54 WEST 62.57 ....................... ~._..SCLOSURE 3197,15 S 1 7 17' W _ . . . 1 ~3897 4289 5052 5435 97' 6580 6969 i insetted eck~ Suggested form to be in each "Active" wel! fo~der to for timely compliance ~tth our ~esulattons, ~ ! STATE OF ALASKA ALASK~ ' . AND GAS CONSERVATION C(' ,dlSSION SUNDRY OTIC $ REPORT:5 CN 1. DRILLING WELL[] COMPLETED WELLC~ OTHER 2. Name of Operator 7. Permit No. Conoco Inc. 86-5 3. Address 3201 C Street, Suite 200, Anchorage, Alaska 99503 4. Location of Well 930' FSL, 637'FWL, Sec. 18, T13N, R11E, U. M. 5. Elevation in feet (indicate KB, DF, etc.) 58' KB Lease Designation and Serial No. APL 47438 8. APt Number 5o- 029-21524 9. Unit or Lease Name Milne Point Unit 10. Well Number B-20 1 1. Field and Pool Kuparuk River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ]~] PulLing Tubing [] (Note' Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of startmg any i proposed work, for Abandonment see 20 AAC 25.105-170). Approval is requested to allow Milne Point Unit B-20 Well to utilize the high-low pressure pilots and safety system linesin conjunction with the MPU B-7 Well. This is necessary to operate surface and subsurface safety valves while temporarily producing B-20. RECFiVFP. 14. I hereby certify that the foregoing is true and ~ct to the best of my knowledge. The ;~'"~ce/,.~ ~or Commission use Title Cond,t,on~of Approvat--'--~;~ an~ Approved by Form 10-403 Date Rev. 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate PERMANENT WELLHEAD SAFETY PANEL to SSV Hi - Lo Sensor Return Oil Pilot Return Gas Pilot Hi -Lo Sensor Sub-surface Safety Valve SAFETY SYSTEM INSTALLATION TEMPORARY INSTALL,~, Hi- Lo Pilot O[ , [ ~1 /VO T£ : __ S'ur face · · ' Safety Regulator ~o.oo 500 psi psi · i:' nd I.p°rt ZI'~ BI eed ValvesI Surface Safety Valve' Bleed Valves i Drain to Cellar i1 Injection Line Hi-Lo Pilot There are no additional valves in the flow or injection h'nes. i[~~-~~~ C hake Valve 4500 psi Flow Line lnjectio Line Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 February 12, 1986 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: ~onth. ly. Report of Drilling. and Workover Operations Attached for your information and file are the original and one copy of each of the required Monthly Reports of Drilling and Workover Operations conducted during January 1986. If you should have any questions, please call Lynn Alexander at 564-7609. Very truly yours, Everett D. Wilson Division Administrative Manager LA/kss Att RECEIVr ) FEB 1 2 1986 Alaska Oil & Gas Cu~l~. u ..... .lsslorl Anchorage STATE OF ALASKA ~-" ALASKA C.,_ AND GAS CONSERVATION COt,.,¢IlSSION ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Conoco Inc. 86-5 3. Address 8. APl Number 3201 C Street, Suite 200, Anchorage, Alaska 99503 5o- 029-21524 9. Unit or Lease Name Milne Point Unit 4. Location of Well at surface 930' FSL, 673' FWL, Sec. 18, T13N, R11E, U.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 59' KRI ADL 47438 For the Month of January ,19 86 10. Well No. B-20 11. Field and Pool Kuparuk River Field 12· Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date' 1-15-86 D'ep('h.at end of Month- 8295' MD Footage Drilled. 8295' 13. Casing or liner ru.n and quantities of cement, results of pressure tests Ran 126 jts. of 36#/ft., K-55, 9-5/8' casing w/BTRC. Float shoe at 5034'. Pumped 1300 sks. Permafrost E and 275 sks. of class G w/3% NeC1 and 1% CFR2, Ran 26#/ft. L-80, 7"-' Casi~ w/BTRC to 8270'. Pumped 275 sks. of Class G cement. 14. Coring resume and brief description None 15. Logs run and depth where run GR-SP-CNL-FDC-DIL from 8296' to 7750' GR-CNL from 7750' to 3600' also 6. DST7994,,data PC'~°r,~n'~ '~ta'~v ~,,~,,, shows12 SPS°f H2S, miscellaneous data 8017' to 8047' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--~epor~oF~jthis ~rm is required for each calendar month regardless of the~tatus of operations and must be' f,led' ,n' dupl,cate' ' with the Alaska Oil an~-Gas ¢~servation Commission by the 15th of the succeeding month, unless otherwise directed. ' Form 10-404 Submit in duplicate MEMORAN' UM Stat of Alaska ALASKA OIL A~O GAS CONSERVATION CO~4ISS~vN TO:Chai~~an~C. V 'i' ~'ton D^T[: January 29, 1986 TH RU: FROM: Lonnie C. Smith / ~ Commissioner Harold R. Hawkins .:~/~,.~ Petroleum Inspector .~?~'~ . FI LE NO.: D. HRH. 6 TELEPHONE NO.: SUBJECT: BOPE Test Conoco B-20, ~iPU Permit No. 85-5 Kuparuk River Field Monday, January 20, 1986: I left Conoco' s Operation Base Camp, '~Ubjec't of anOther"report, to Rig 27-E, Conoco's B-20 well MPU to witness the BOPE Test. I witnessed the BOPE test on B-20, there were no failures. I filled out an A.O.G.C.C. Report which is attached. In summary: [Pnen the BOPE tests were completed by Nabors 27E Crew for Conoco, the tests were satisfactorily performed. Attachment 02-001A(Rev 10-84) O&G ~4. sl 4 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report · Date Well '--" Location: Sec Drillin~ Contractor Location, General Ri Well Sign,~f~ General Housekeeping (f~Rig df/~ Reserve Pit ~ Mud Systems Visual Audio Trip Tank / Pit.Gauge L// Flow Monitor / Ga~ Detectors y~" BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves · H.C.R. Valve Kill Line Valves Check Valve Test Pressure Full Charge Pressure .~~.~ pstg Pressure After Closure./~90 psig Pump incr. clos. pres. 200 psig -~ min/~ sec. _-..~ Full Charge Pressure'Attained:,., / min,~j sec. Controls: Master ~/~ Remote O~ Blinds switch cover~/~ Kelly and Floor Safety Valves Upper Kellx Lower Kelly Ball Type Inside BOP Choke Manifold No. Valves /~ No. flanges Test Pressure Test Pressure Test Pressure __~.d~ Test Pressure, Test Pressure Adjustable Chokes zdrauicall~ Test Time Test Results: Failures ~ dA'~'~ Repair or Replacement of failed equipment to be made within Commission office notified. I :ed choke hrs. days and Inspector/ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector. January 6, 1986 Mr. Kent J. Stolz Production Engineer Conoco Inc. 2525 C Street, Suite 100 Anchorage, Alaska 99503 Re: Milne Point Unit No. B-20 Conoco Inc. Permit No. 86-5 Sur. Loc. 930!FSL, 673'FILL, Sec. 18, T13N, RILE, L!M. Btmhole Loc. 2343'FML, 4509'FEL, Sec. 19, T13N, RllE, UM. Dear Mr. Stolz: Enclosed is the approved application for permit to drill the · above referenced well. The permit to drill does not indemnify you from 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 installati~n 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, l~here 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. Ve~r~--~ trul~ygur s, Chai~an of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE CO}'~ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery PLANE CO ORDINATES ALL GEODETIC POSITIONS ARC BASED OH N.A.D. 1921. OFF SETS 10 S[CIIOH LINES An[ COMPUT£D BASED O, PnOtn&CTgD YALU£S Of THC SE CTIOH CO~I ~/[ R POSITIONS. 4. LOCAI~O witHIN SECTIO, f6 8 19, Tt~ N, FIIIE,UM ,AK. I LOCATION Itt SECT 464' 790' O - IZ 769' 920' O- ~ 5~2' 979' O 14 649' 9 I~ 300' Q '1~ 416' IOOO' O'IS ~14' TO2' STATE PLANE COOI~OS. Dr. TC CH[CNCO 6.2,85 J. 9. 9. 9.2, 85 J.B.S. 6.2, 85 J.B.9. lO. 25,85 9. T. lO. 23,05 NORTHINGS ,023,686.20 ,023 ,SOO.SO ,023 0656.0T 023 , TT2.36 6 , 023,424.25 6 0 023,540.44 6 ,023,013.86 G ,023,935.OI G , O24,004.84 G. o24..o_~1.o3 [ASIINGS 571,8G4.4T 571,992.42 .~ ~ ,052.7T 572 ~022.58 5?2,113.60 5T2,063.38 572,013.68 5TI,7~J.46 5rl,~GI.T4 ~71.745.4~ GgOOETIC LATITUDE TOO28' 29.019" H. ?O° 20' 3f .901",. ?0028. 29.688'N. 70°28' Z8. 548"N. 70~28' 32.45a'*N. 70°29' 33. 127"H. POSITION LO,Gl ! UDC 1490~4' 4~!. ?0~" W. 14 90:~4' 42.854"W. 149° 2~' 41. 146" W. 14 ~0:~4' 4~. O01' W. 149°24' 39. 42 3"W. 149024 ' 40. 279" Vi'. 149°24' 42.472"W. 149 24 49.280"W. 14ge 24'45. T23 "W. 7-4-50.13o ~ m . i ...... · i i i ii i m _ _~_ i i ii i C[flIIFICAIE O/r SUflV[YOR : ~''" ~'4'~ g~a e~oveeee~'eeem~,a=sleelee~;u~e .'~ ~ ~ ,.,~ ~:,,...,. .... .~. ,,:~ ~d .. o 10.23 O.T. rtlCLO BCX~K J' 21 - 89 21 21-89 39 -89 39- 85 39 -89 59 - a5 10.23,1~ g,t. 10.12,85 L.O. 39 -85 L.O. Il. I§ ,85 II.?Z~. &Si CONOCO SC& I' · 4OO* 2 O~ 3 COHUENIS * ! I B PAD -- BUILT wELL lOCATION ' STATE OF ALASKA ~-' ALASKA O,- AN DpERMiTGAS CONSERVATIONToDRILL ss' ° 0NFI DENT! AL 20 AAC 25.005 ' la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I-Ix DEVELOPMENT GAS [] 2. Name of operator Conoco Inc. SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] 3. Address J A N 0 2 1986 3201 "C" Street, Suite 200, Anchorage, AK. 99503 4. Location of well at surface 930' ;FSL, 673' :FWL, Sec 18, T13N, RllE, U.~M. At top of proposed producing interval 2190' FNL, 4510' FEL, Sec 19, TZ3N, RllE, U.M. At total depth 2343' FNL, 4509' FEL, Sec 19, T13N, RllE, U.M. 5. Elevation in feet (indicate KB, DF etc.) KB 59' to MSL 6. Lease designation and serial no. APL 47438 '"""-.~.~ ~C~I~I~ ?¢;;~i¢~ Unit 10. Well number B No. 20 11. Field and pool Kuparuk River 12. Bond information (see 20 AAC 25.025) Type ;Blanket Surety and/or number 8086-15-54 Amount $200,000.00 15. Distance to nearest drilling or completed well B- 8 90 feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 33 mi NW of Deadhorse miles 2936' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8263' MD* 7111 TVD feet 2544 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2500 feet. MAXIMUM HOLE ANGLE 41.%1 (see 20 AAC 25.035 (c) (2) 21 Proposed Casing Liner and Cementing Program 18. Approximate spud date 01114186 ~,?'&f)psig@__80 °F Surface 3800Psig@ 7!11 ft. TD (TVD) SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT 'Hole 17~" Casing Weight Grade 13 3/;" 48 H-40 9 5/.~" 36 K-55 7" 26 L-80 Couplinfl PEL~ BTR1 BTR1 Length MD TOP TVD 80 35' I 35' 4987 35 ' 35 ' 8230 I I 33' I 33' M D BOTTOM TV D 115 ' 115 5022 ' I 4668 8263'l 7111 (include stage data) ±100 cf Cmt ±1300 sks Prmfrst "E" ±275 Class G ±270 sks Class G ±180 sks Perma C Cmt 22. Describeproposed program: I Conoco Inc. proposes drilling the subject well as a producing well in the Kuparuk River field. The mud syste will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg~ Mud weight at T.D. will be 10.4 ppg. A 20", 2000 PSI diverter will be installed on the ].3 3/8" conductor fo~ drilling surface hole. A 13 3/8", 5000 PSI RSRRA BOPE stack will be used on the surface casing. Pressure test: will be performed as per State Regulations. BOP's, choke manifold, Upper and Lower Kelly will be tested to 501 psig and 5000 psig, the Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. Maxim~ downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded ga~ bubble, temperature taken into account. The closest wellbore is B-8, which is 90' southwest of B-20 at 1760 TVD. The well will be flow tested after the rig is released. Arctic Pack will be placed in the 7" X 9 5/8' annulus after disposing of test oil and excess drilling fluids. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~d!.~ TIT LE Production Engineer The space below for ,~omm~ssion use CONDITIONS OF APPROVAL DA~cember 31, 1985 Samples required []YES Permit number Form 10-401 Mud log required I--JYES Approval date ~_ 0.1./¢6/86 Directional Survey required ] APl number [Z~-YES []NO I 50-o'b?- L/ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE .T~m~ry 6~ 11_986 by order of the Commission Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL RECEIVED Conoco et al - Milne Point No. B-20 JAN 0 2 lgSG Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, Alaska 99503 jJ~J_~J(~JJ ,(Ji| .~ U~ Oult~. vutllllll$$10~ I. CEMENTING PROGRAM mi The 13 3/8" conductor will be set at 80' below the surface (115' K.B.), then cemented to the surface with permafrost cement. Be The 9 5/8" surface casing will be cemented with ±1300 sacks of permafrost cement followed by ±275 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±270 sacks of Class "G" cement pumped around the casing shoe (estimated ±1250' 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. Estimated base of permafrost at 1700'. 4500' - TD Predominantly shale until the Kuparuk Sands - expected at ±6700 subsea TVD. III. FORMATION EVALUATION Ae Wireline logs for the 8½" hole (from TD to ±1000' above the Kuparuk interval) will include: Dual Induction log; Spheri- cally Focused log; Litho Density log; Compensated Neutron log - Gamma Ray. IV. DRILLING FLUIDS A high viscosity fresh water gel (non-dispersed) mud system will be used from 0'-1000'. A low solids non-dispersed gel/water mud system will be used from 1000'-Surf. Csg. Pt. RECEIVED Low solids lightly dispersed mud system 4800'-T.D. J A N 0 2 1986 V. DIRECTION PROGRAM The B-20 well will be drilled to a proposed KO~ of build angle in a south 0° 42' east direCt'ion at a rate of 2.5°/100'. The closest that the proposed B-20 well will come to another wellbore is at a 1760' TVD, where the proposed B-20 path will be 90' northeast of the existing B-8 well. Other wells which paths are crossed are B-18, B-7, B-Il, B-9, B-10, B-3, B-6, B-4, B-17, and B-22 (currently drilling). Of the paths that are crossed, the closest distances are all in excess of 200' with the exception of B-18 and B-19. Closest distances on these two wells are 105' for B-18 (at 1400' TVD), and 106' for B-19 (at 1800' TVD). Extreme caution will be taken and an MWD tool will be run while drilling for surveying purposes. Final hole angle is estimated at 41.1°. The proposed depth is an estimate only. If actual depth exceeds the permit depth by over 300', a Sundry Notice will be submitted. ,D El, w~LI- NO: 20 PROPOSED ~ILNE PT., NORTH SLOPE,~- ALASKA EASTHAN WHIPSTOCK. INC. 0 . SURFACE 1000_ 2000 _ ;3000 _ 4000 _ 5000 _ 6000 _ 7000 _ KOP 5 lO 8000 _ 0 TVD=2500 TMD=2500 DEP=O I- ECEiVED JAN 0 2 lg~J$ Naska 0il & Gas Cons. C0mmissio~ Anchorage BUILD 2.5 DEO PER 100 FT 25 30 4.0 EOB TVD=4007 TMD=4144 DEP=565 9 5/8' CSG PT TVD=4668 TMD=5022 DEP=l142 AVERAGE ANGLE 41 DEG 7 MI N TARGET TVD:6935 TMD:8031 'TENTATIVE' TD TVD=7111 TMD=8264 DEP=3273 DEP=3120 I I I 1000 2000 3000 VERTICAL SECTION I 4000 HOR I ZON=-'%L PROJECT I ON SCALE , IN. = 1000 FEET CONOCO, INC. PAD B, WELL NO; 20 PROPOSED MI LNE PT., NORTH SLOPE, ALASKA EASTMAN WHIPSTOCK. INC. RECEIVED J AN 0 2 198G Alaska 011 & Gas Cons. Commissim~ Anchorage 1000 1000 2000 ~000 4000 WEST-EAST 2000 1000 0 I I /\ ., ( ~ SURFACE 'TENTATIVE' TD S O0 DE G ;$120' (TO 1000 2000 I I SURFACE LOCATION, 930' FSL. 673' FWL SEC. 18. TI3N. RlIE TARGET TVD=6935 TMD=8031 DEP=3120 SOUTH 3120 EAST 38 TARGET LOCATION ~ 2190' FNL. 4510' FEL SEC. 19. T13N. RIlE 42 MINE TARGET) 7OO 8OO 900 1000 1100 ouu I I 1825 100 174 1 46~I I I I I I I I I I I 1 ! I I I I 100 I, 200 300 ,, RECEIVED I 4275 JAN 0 2 .~c,v 1008 1484 / / / / 1892 / / 700 8OO 900 lOOC 1100 1200 1 300 1 400 1500_ 1600_ I ! I 300 2962 2449 200 I 100 2164 I I i , / I / ! / i / I / 2121 I / I / I / / I / I / I / I / I / I/ I/ 0 100 / / / / / / :'4 r'l ri 1200 1300 1400 1500 1600 100 100 2OO 500 4OO 300 5OO 600 700 800 2OO 221 '300 lO0 854 200 86~ 100 200 IV£D 500 Nas~ Oit & Gas Cons. Anchorage 3093 ~ ~ 300 1 I O98 5469 ~' 300 69 95 300 482 } 381 I I % % I 1 ,91 99 300 092 300 500 3877 oo '3495 300 300 100 0 100 2OO 500 400 5OO 600 ?00 800 ' im i ! FROM MUD PUMP ' KILL MANIFOLD Z ' JAN 0 2 1988 FROM REMOTE HIGH _ ~ m.-~,.-m_/,~x REMOTE PRESSURE GA E~' PRESSURE PUMP ~ ~1 orage NOTE: ' ~ HYDRAULIC CONTROLLED i. H~RAULIC CONTEL SYSTEM FOR B~ ~ACK 6 CHO~ ~ REMOTE OPERATED ~ANIFOLD TO INCLUDE (5) STATI~ CONTROL MANIF~ L~ATED RE~OT~Y WITH 3~0 PSI ACCUMULATOR 8 )~0 G~. RESE~m a Aux. ENERGY SOURCE. ()) STA. ~NTROL MANIF~ PLUS V~IAB~ CHOKE / % ~NT~L TO BE ~CATED ON RIG FLOOR. ~ DRILLING ~D ). KILL MANIF~D SIZE-RATING 2"- 5~0 4. CHOKE MANIFO~ SIZE- RATING )'- 5~ '~ HYDRAULIC ~NTROLLED ' ~R~TE OPIATED ~ ~-~RE~TE PRESSURE GAGE SENSOR CHOKE ADJu~AB~ ~ ~~ ~~ ADJU~AB~ MANIFOLD h C~KE ~ I I I SHAKER BL~D LINE TO ATMOSPHERIC TO PIT MUD/GAS SEPARATOR CHOKE 8 KILL MANIFOLDS FOR q~/8" 8 7" OD CASING BOP STACK BOP JAN FOLD LAYOUT - CONO , INC. mm I I CONOCO, INC., MILNE POINT UNIT FILL-UP LINE BOP STACK FOR 'FLOW LINE 13 3/8' CONDUCTOR (i) B.O.P. stack size rating meets API RP. 53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. ANNULAR PREVENTER (2) BOPE to be operated on each trip & pressure tested weekly. SPOOL APl 5000~' -- RAM BOP 13 5/8" AP! 5000 -- RAM BOP 13 5/e " APl 5000~ APl 5000 SIDE OUTLETS 135/8" APl 5000~ (3) (4) 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. Ram type BOP to include a minimum 'of one set of blind rams and two sets of appropriate pipe rams. L Z" APl 5000~ r~./~ SIDE O U T L E TS-~~"~ ? TBG SPOOL RAM BOP 135/8" APl 5000~ x II' APl 5000 II" APl 5000d~ (5) Choke and kill manifolds shown separately to meet API RP 53 class 5M requirements. 3' APl 5OOO~ SIDE OUTLETS WELD - ON IS 3/e# CAS I NG CS$ ( SPOOL I'(ECEIVED J A N 0 2 1988 Alaska Lm a ~as Cons, Commission Anchorags CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 3/8' CONDUCTOR FLOW LINE FILL UP LINE ~' ) _ HCR VALVE L~ 20" BELL NIPPLE 6" RELIEF VALVE JAN 0 2 1986 Alaska 0ii & (~as Cons. Cornrnissio~ Anchorage 20" APl 2000 psi ANNULAR PREVENTER DIVERTER QUICK CONNECT ASSEMBLY SAVER SUB ASSEMBLY STARTING HEAD 13 3/8" CASING Relief lines from the drilling spool will be routed for downwind diversion. me Hydraulic control system will be in accordance with API specifications and AOGCC regulations. Be Both HCR valves will open when the preventer closes, then either one may be closed. NOTE: Depending on rig contracted, the two 6" relief lines may be replaced by a single 10" line with a downstream tee. Eastman (907) 349-4617 P. O. Box 4-1970/Anchorage, Alaska 99509-1970 Jan. 3g 1985 William Van Alen Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Mr. Van Alen Please find attached two cop~~f the Gyro Multi-Shot survey run for Conoco Inc. o~~'B, Well No:20 . This is to be considered.(~%,~mal-letter of transmittal. The data herein, is to co~~ed strictly confidential. A copy of this letter~~ing sent to Conooo's represen- tatives, Mr M. Bradsha~.~ Mr S. Davies. Should you have any qu~stions regarding this survey data, please refer all questions to CONOCO INC. Distri~ ~chnical Coordinator cc: M. BRAD S HAW S. DAVIES RECEIVED FEB O 5 ]986 Alaska Oil & Gas Cons. Commlulon Anchorage Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 (907) 564-7600 December 31, 1985 Mr. Co 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-20. A $100 check is being submitted with the permit application to fulfill the permitting fee requirement. If you have any questions, please call Kent Stolz at 564-7641. Verily yours, Rogers J. Francis Division Manager - Engineering KJS/vv cc: MP B-20 Correspondence File JAN 0 2 1986 Alaska 0U & ~as (,;otis, Uommission Anchorage thru 1~~)2~// ' · and (4) Casg /~r~ thru (22 thr~ ~6) ~ermit fee att' . 2: 2:'.:..~I ~ [ to be located in a defined pool ,,,,,,,,-,~,,,,,, '~.3: ~fs re1~' ~ocated:proPer~ diStanCe, from property' line ..... 4; Is well loCated prOper, distante from other wells ....... ~ 5' .IS '.sufficient undedica'ted~acreage available in this. pool 6,~ Is Well to be 'deviated and...iS' wellb°re plat included .,. 7', Is Operator ~he only .affected party , ........ . .... ,, ..... 8. Can pe~it be aPproved before` ten-day ~ait ...... ~ ~ ..... 9 Does operator have bond in' force ' 10 Is a conse~ation order' needed '11 Is administrative approval needed 12. Is the lease number appropriate ................................. 13. 14. 15. 16. 17. 18. 19. 20. 21. No_ REMARKS eeee~ eeel Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate or production stringsli~i Will cement cover all known prOductive horizons .... ' ............. - 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 ...... . ...................... 22. 23. 24. 25. 26. 2¸7. Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~/~ Does BOPE have sufficient pressure rating - Test to ._gz~-~-D psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. ~zT~ Is the presence of H2S gas probable ................................. Additional requirements ............................................. , ,, Additional Remarks: Geology: Engi. neering.'_.. LcS v~. BEW~ :tv: 03/13/85 i.Oll ' ' INITIAL. OEO. UNIT ON/OFF .... POOL CLASS STATUS AREA NO. SHORE ......... Well Histo.ry 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 natum is accumulated at the end of the file under APPENDIX~ .. No special'effort has been made to chronologically organize this category of information. .o GEARHART GEAR/,/ART · , . · - :.?' ,~:, ,:~; '.i i"? :}:.': !::: {:i; E: .}; :-: ~' f :': "i' '!' !'.'ii.{ '::' :.: :.~-:.}' .;-: '-': :.~ ::.. '{.: :~.: :,{-: '-'.-: .h ':, :+ ::- :.;,: .,;. ':, ,: :,:..-. ri.:-.'.-