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191-095
Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/21/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230421 Well API #PTD #Log Date Log Company Log Type BCU 19RD 50133205790100 219188 5/11/2023 AK E-LINE PPROF MPU I-27 50029236920000 221013 3/23/2023 HALLIBURTON Tubing Punch-Cut MPU J-05 50029221960000 191095 3/25/2023 HALLIBURTON Tubing Punch-Cut MPU L-36 50029227940000 197148 3/14/2023 HALLIBURTON MFC24 Please include current contact information if different from above. T37778 T37779 T37780 T37781 MPU J-05 50029221960000 191095 3/25/2023 HALLIBURTON Tubing Punch-Cut Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.21 13:55:21 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC J-05 MILNE PT UNIT J-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 J-05 50-029-22196-00-00 191-095-0 W SPT 4045 1910950 1500 686 689 688 688 47 143 145 143 4YRTST P Adam Earl 6/16/2023 MIT IA 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 J-05 Inspection Date: Tubing OA Packer Depth 634 1709 1653 1642IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230620115959 BBL Pumped:1.2 BBL Returned:1.2 Thursday, July 27, 2023 Page 1 of 1 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Punch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6,648 feet N/A feet true vertical 4,203 feet N/A feet Effective Depth measured 6,638 feet feet true vertical 4,203 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.3# / L-80 / NSCT 26' MD 26' TVD 2-7/8" 6.5# / L-80 ' EUE 8rd 4,061' MD 3,783' TVD Tubing (size, grade, measured and true vertical depth)2-3/8" 4.5# / L-80 ' EUE 8rd 4,664' MD 4,057' TVD Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Operations Manager Contact Phone: 4,011, 4,079, 4,616 & 4,658 3,748, 3,796, 4,045 & 4,056 9-5/8" Permanent / SC-1L 96A4-60 / SC-1L 96A4-60 N/A See Above N/A 6,390psi 6,350psi 2,730psi 6,870psi 7,740psi 7,780psi 4,891' 4,105' Burst N/A Collapse N/A 1,400psi 4,760psi Liner 546' 2,014' Casing Conductor 4,047' 4,203' 4,624' 6,638' 4,891' 2,458'Surface Production Liner 20" 13-3/8" 9-5/8" 110' 2,458' measured TVD 5-1/2" 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 191-095 50-029-22196-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025906 MILNE POINT / SCHRADER BLUFF OIL MILNE PT UNIT J-05 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 110' 20 Size 110' 2,415' 1066 6400 0 747627 781 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Brian Glasheen Brian.Glasheen@hilcorp.com 907-564-5277 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 1:30 pm, Apr 24, 2023 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.04.24 11:55:31 -08'00' David Haakinson (3533) DSR-4/26/23WCB 11-28-2023 RBDMS JSB 042523 _____________________________________________________________________________________ Revised By: TDF 4/24/2023 SCHEMATIC Milne Point Unit Well: MPU J-05 Last Completed: 6/20/2015 PTD: 191-095 TD =6,648’(MD) / TD = 4,203’(TVD) KB Elev.: 70.2’/ DF Elev.=69.2/ GL Elev.: 35.2’ 9-5/8” 4 12, 13 & 14 1 5 20” 2 3 Tubing Punch 4,491’ to 4,511’ 3/25/2023 TOC Calculated @ 2,619’ “N” Sands PBTD = N/A (MD) / PBTD = N/A(TVD) RA Tag @ 4,273’ 6 7 8 9&10 11 13-3/8” 15 16 17 18 19 20 21 “O” Sands CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94 / K-55 / Butt Weld 19.124 Surface 110' 13-3/8" Surface 61 / K-55 / Btrc. 8.835 Surface 2,458’ 9-5/8" Production 45 / L-80 / Btrc 8.681 Surface 4,891’ 5-1/2” Liner 17 / N-80 / EUE 8rd 4.892 4,078’ 4,624’ 4-1/2” Liner 11.6 / N-80 / LTC 4.000 4,624’ 6,638’ TUBING DETAIL 3-1/2” Tubing 9.3 / L-80 / NSCT 2.992 Surface 26’ 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 26’ 4,061’ 2-3/8” Tubing 4.5 / L-80 / EUE 8rd 1.995 4,061’ 4,664’ JEWELRY DETAIL No Depth ID Item 1 35’ 3-1/2” x 2-7/8” X-Over 2 4,011’ 9-5/8” Permanent Packer 3 4,049’ XN Nipple 4 4,061’ X-Over 2-7/8” to 2-3/8” 5 4,079’ 6.00 Baker SC-1L 96A4-60 Packer 6 4,086’ 6.25 Sliding Sleeve 7 4,112’ 5.20 7” x 5-1/2” 8rd Cross-over 8 4,353’ 5.00 5-1/2” .012 Baker-weld Screen 9 4,615’ 4.00 S-22 Snap Latch Seal Assy. 10 4,616’ 6.00 Baker SC-1L 96A4-60 Packer 11 4,623’ 4.00 7-5/8” x 4-1/2” LTC Cross-over 12 4,657’ Snap Latch 13 4,658’ 5’ Seal Assembly 14 4,658’ 4-1/2” Packer 15 4,709’ 3.813 Otis X-Nipple 16 4,797’ 5.00 Pack-off Overshot (Top) 17 4,890’ 4.00 6-5/8” x 4-1/2” LTC Single Screen Prepack Liner 18 5,675’ 3.813 Otis X-Nipple 19 6,098’ 4.00 6-5/8” x 4-1/2” LTC Single Screen Prepack Liner 20 6,624’ 3.725 Otis XN-Nipple 21 6,634’ 4.00 Spaded Bullnose w/ ports - Bottom @ 6,638’ PERFORATION & OPEN HOLE DETAIL Schrader Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Status “N” Sands 4,378’ 4,392’ 3,958’ 3,964’ 14 Open “N” Sands 4,425’ 4,465’ 3,977’ 3,993’ 40 Open “N” Sands 4,495’ 4,515’ 4,004’ 4,011’ 20 Open “N” Sands 4,560’ 4,605’ 4,027’ 4,042’ 5 Open “O” Sands 4,891’ 6,648’ 4,105’ 4,203’ 1,757 Open WELL INCLINATION DETAIL KOP @ 900’ Max Hole Angle in Tubing = 41 deg. @ 3,900’ Hole angle thru perfs= 66deg. Max Hole Angle = 89 deg. @ 6,518’ TREE & WELLHEAD Tree FMC 3-1/8” 5M Wellhead 13” 5M tbg. Spool 13” x 3-1/2” NSCT (T&B) FMC tbg. Hgr w/ 3.5” ‘H’BPV Profile GENERAL WELL INFO API: 50-029-22196-00-00 Drilled and Cased by Nabors 27E - 10/3/1991 ESP Replacement by Nabors 4ES – 10/24/2000 ESP Replacement – 8/8/2003 OPEN HOLE / CEMENT DETAIL 20” 624 Sacks Permafrost 13-3/8” 1,600 Sacks ‘E’ / 250 Sacks ‘G’ 9-5/8” 634 Sacks ‘G’ Well Name Rig API Number Well Permit Number Start Date End Date MP J-05 SL & Eline 50029221960000 191-095 3/24/2023 3/25/2023 3/24/2022 - Friday WELL INJECTING ON ARRIVAL. DRIFT TO 4,600' SLM (target depth 4,511' md) W/ 1.75" CENT, 10' x 1-1/2" STEM, 10' x 1.75" DRIVE DOWN BAILER (no issues). WELL INJECTONG ON DEPARTURE, PAD OP NOTIFIED. 3/22/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 3/23/2022 - Thursday No operations to report. No operations to report. WELL ONLINE ON ARRIVAL, DSO NOTIFIED (tubing punch). PT 300L/3500H. PUNCH TUBING FROM 4491'-4511' W/ 1.56", 0 DEG PHASED, 4 SPF HSC. CCL TO TOP SHOT OFFSET: 4'. CCL STOP DEPTH: 4491'. CORRELATED TO TUBING TALLY DATED 20-JUN- 2015. PRE-PUNCH T/IA/OA: 350/0/100. POST PUNCH T/IA/OA: 200/0/100. WELL LEFT S/I ON DEPARTURE, WELL SECURE. 3/25/2022 - Saturday No operations to report. 3/28/2023 - Tuesday 3/26/2023 - Sunday No operations to report. 3/27/2023 - Monday PUNCH TUBING FROM 4491'-4511' MEMORANDUM State of Alaska Permit Number: 191-095-0 Alaska Oil and Gas Conservation Commission Insp Num: mitMFH190610160853 DATE: Wednesday, June 12, 2019 TO:JimRegg ��< 6(i3ll SUBJECT: Mechanical Integrity Tests P.I. Supervisor %I 15 Min 30 Min 45 Min 60 Min Well J -0s "TypeInj W -TVD 4045 Tubing 495 -, 496 -� HILCORP ALASKA LLC _ _ ___ PTD 1910950 Type Test SPT Test psi 1500 IA 1620 J-05 FROM: Matt Herrera MILNE PT UNIT J-05 Petroleum Inspector OA 191 263 Ste: Inspector 262 Reviewed By: Interval 4YRTST _1P/F P P.I. Supry 3V - Notes: IA Pressure Tested to 1600 PSI Per Operator' NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT J-05 API Well Number 50-029-22196-00-00 Inspector Name: Matt Herrera Permit Number: 191-095-0 Inspection Date: 6/10/2019 ' Insp Num: mitMFH190610160853 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J -0s "TypeInj W -TVD 4045 Tubing 495 -, 496 -� 494 - 493 -- _ _ ___ PTD 1910950 Type Test SPT Test psi 1500 IA 1620 1583 1 1524 BBL Pumped: I 0.8 . BBL Returned: I OA 191 263 263 262 Interval 4YRTST _1P/F P Notes: IA Pressure Tested to 1600 PSI Per Operator' Wednesday, June 12, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,September 03,2015 TO: Jim ReggI`Z� c9I- 1I' P.I.Supervisor t� SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J-05 FROM: Jeff JonesS � SEV r'`__ 3 L I '`' F' MILNE PT UNIT Ss J-05 Petroleum Inspector W�" Src: Inspector NON-CONFIDENTIAL Well Name MILNE PT UNIT SB J-05 API Well Number 50-029-22196-00-00 Inspector Name: Jeff Jones Permit Number: 191-095-0 Inspection Date: 7/3/2015 Insp Num: mitJJ150706102455 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wells J-o5 - Type Inj 1 W`l'VD 1 4045 - Tubing j 0 25 - 25 25 - PTD 1910950 ' 1Type Test SPT Test psi 1500 • IA 256 1804 — 1766 - 1737 -'] —T Interval i Initial Test p/f' Pass ✓ OA 100 290 - 280 • 280 - L Notes: Producer converted to injector. , Thursday,September 03,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,July 20,2015 TO: Jim Regg P.I.Supervisor h I J is SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC J-05 FROM: Jeff Jones MILNE PT UNIT SB J-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB J-05 API Well Number 50-029-22196-00-00 Inspector Name: Jeff Jones Permit Number: 191-095-0 Inspection Date: 7/6/2015 Insp Num: mitJJ150706102455 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1910950 ' e In' 4045 Tubingf o 25 T 25 25 _ [Type J TVD PTD Type Test Test psi 1500 . IA 256 1804 - ' SPT 1766 - 1737 1 — fi Interval INITAL P/F P / OA 100 290 280 280 - I Notes: Producer converted to injector Monday,July 20,2015 Page 1 of 1 STATE OF ALASKA AL. __,KA OIL AND GAS CONSERVATION COIe.....SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations U Fracture Stimulate ❑ Pull Tubing Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Convert to WINJ ❑., 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 191-095 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22196-00-00 7 Property Designation(Lease Number): 8.Well Name and Number: RECFED ADL0025906 MILNE PT UNIT SB J-05 W 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s). N/A MILNE POINT/SCHRADER BLUFF OIL Ail- 1 5 2015 11.Present Well Condition Summary: AOGCC Total Depth measured 6,648 feet Plugs measured N/A feet true vertical 4,203 feet Junk measured N/A feet 4,011,4,079, Effective Depth measured 6,638 feet Packer measured 4,616&4,658 feet 3,748,3,796, true vertical 4,203 feet true vertical 4,045&4,056 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' 2,110psi 520psi Surface 2,458' 13-3/8" 2,458' 2,415' 2,730psi 1,400psi Production 4,891' 9-5/8" 4,891' 4,105' 6,870psi 4,760psi Liner 546' 5-1/2" 4,624' 4,047' 7,740psi 6,390psi Liner 2,014' 4-1/2" 6,638' 4,203' 7,780psi 6,350psi Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet 3-1/2" 9.3#/L-80/NSCT 26'MD 26'TVD 2-7/8" 6.5#/L-80'EUE 8rd 4,061'MD 3,783'TVD Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.5#/L-80'EUE 8rd 4,664'MD 4,057'TVD 9-5/8"Permanent/ 4,011'&3,748'/ SC-1L 96A4-60/ N/A 4,079'&3,796'/ N/A Packers and SSSV(type,measured and true vertical depth) SC-1L 96A4-60 4,616'&4,045' 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured) N/A A �� ) Treatment descriptions including volumes used and final pressure: N/A ��ANHE� -i i_ s' l_�� N 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 0 0 0 750 -16 Subsequent to operation: 0 0 580 660 105 14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Q 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: 315-341 Contact Chris Kanyer Email ckanyer(c�hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature if,LAp. Phone 777-8377 Date 7/14/2015 Form 10-404 Revised 5/2015 7--7. RBDMSS`' it Jrigjnal1OpIY201t 14Milne Point Unit Well: MPU J-05 SCHEMATIC Last Completed: 6/20/2015 Hilcorp Alaska,LLC PTD: 191-095 CASING DETAIL KB Elev.:70.2/DF Elev.�9.2/GL Elev.:35.2' Size Type Wt/Grade/Conn ID Top Btm 1 ' 20" _ Conductor 94/K-55/Butt Weld 19.124 Surface 110' P 20''r " I, 13-3/8" Surface 61/K-55/Btrc. 8.835 Surface 2,458' 9-5/8" Production 45/L-80/Btrc 8.681 Surface 4,891' i 5-1/2" Liner 17/N-80/EUE 8rd 4.892 4,078' 4,624' s' 4-1/2" Liner 11.6/N-80/LTC 4.000 4,624' 6,638' '1 4 ...^ TUBING TUBING DETAIL ' , 3-1/2" _ Tubing 9.3/L-80/NSCT 2.992 Surface 26' %i 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 26' 4,061' 2-3/8" Tubing 4.5/L-80/EUE 8rd 1.995 4,061' 4,664' r JEWELRY DETAIL 0 No Depth ID Item " 1 35' 3-1/2"x 2-7/8"X-Over ] 2 4,011' 9-5/8"Permanent Packer . 3 4,049' XN Nipple i ) 4 4,061' X-Over 2-7/8"to 2-3/8" 13-3/8". 5 4,079' 6.00 Baker SC-1L 96A4-60 Packer 6 4,086' 6.25 Sliding Sleeve 7 4,112' 5.20 7"x 5-1/2"8rd Cross-over 8 4,353' 5.00 5-1/2".012 Baker-weld Screen TOC Calculated 9 4,615' 4.00 S-22 Snap Latch Seal Assy. @2,619'\` 10 4,616' 6.00 Baker SC-1L 96A4-60 Packer � 11 4,623' 4.00 7-5/8"x 4-1/2"LTC Cross-over 12 4,657' Snap Latch 13 4,658' 5'Seal Assembly .' 14 4,658' _ 4-1/2"Packer e, 15 4,709' 3.813 Otis X-Nipple 1' L. 16 4,797' 5.00 Pack-off Overshot(Top) r 17 4,890' 4.00 6-5/8"x 4-1/2"LTC Single Screen Prepack Liner 18 5,675' 3.813 Otis X-Nipple i.1 19 6,098' 4.00 6-5/8"x 4-1/2"LTC Single Screen Prepack Liner f 20 6,624' 3.725 Otis XN-Nipple o 'o. 9 21 6,634' 4.00 Spaded Bullnose w/ports- Bottom @ 6,638' r Y PERFORATION&OPEN HOLE DETAIL r a 2 Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Status "N"Sands 4,378' 4,392' 3,958' 3,964' 14 Isolated e 4 0; A'II• "N"Sands 4,425' 4,465' 3,977' 3,993' 40 Isolated 1 I . j1 5 RA Tag @ 6 ?11 i ,; t "N"Sands 4,495' 4,515' 4,004' 4,011' 20 Isolated 4273 •,-`.' 1 7 "N"Sands 4,560' 4,605' 4,027' 4,042' 5 Isolated 8 .`'L N }"M Sande "Cr Sands 4,891' 6,648' 4,105' 4,203' 1,757 Open i� `i i -- f, WELL INCLINATION DETAIL OPEN HOLE/CEMENT DETAIL `` , KOP @ 900' 20" 624 Sacks Permafrost • 9&10 I 111 r: Max Hole Angle in Tubing=41 deg. @ 3,900' 13-3/8" 1,600 Sacks'E'/250 Sacks'G' 12,13&14 Hole angle thru perfs=66deg. 9-5/8" 634 Sacks'G' 9-5/8„ as 6 •ii 75 Max Hole Angle=89 deg. @ 6,518' a 16 17 TREE&WELLHEAD GENERAL WELL INFO A Tree FMC 3-1/8"SM API:50-029-22196-00-00 13"5M tbg.Spool 13"x 3-1/2" Drilled and Cased by Nabors 27E -10/3/1991 it 18 .0"Sands Wellhead NSCT(T&B)FMC tbg.Hgr w/3.5" ESP Replacement by Nabors 4ES-10/24/2000 ' 'H'BPV Profile ESP Replacement-8/8/2003 19 ✓ll 20 21 ID=6,64g(MD)/TD=4,203'(1VD) PBTD=N/A(MD)/PBTD=N/A(1VD) Revised By:TDF 7/2/2015 Hilcorp Alaska, LLC 1 ,.,,r,,_,,:,�,;_, ,,� Weekly Operations Summary 7i1 Well Name API Number Well Permit Number Start Date End Date MP J-05 50-029-22196-00-00 191-095 6/15/2015 6/20/2015 Daily Operations: 6/10/15-Wednesday, No operations to report. 6/11/15-Thursday No operations to report. 6/12/15- Friday No operations to report. 6/13/15-Saturday No operations to report. 6/14/15-Sunday No operations to report. 6/15/15- Monday MIRU Nordic 3 and associated equipment.Spotted kill tank and RU hardline, loaded pits and tested hardline.SITP 700psi, IA 740psi. Bled both to Opsi. Reversed circulated 8.5ppg kill fluid @ 5bpm, broke circulation @ 47bbls.Continued to pump well volume returns clean.Set BPV and ND Tree/NU 13-5/8" BOP Stack, installed 2-7/8" Pipe Rams and connected lines. Pulled BPV and set TWC performed shell test. Door seal leak. Had to remove choke line to repair. Performed shell test, good test on low and high.Jeff Jones with AOGCC waived witness of the BOPE Test, Annular 250psi low/2,500psi high, valves 250psi low/3,000psi high, rams 250psi low/3,000psi high, held and charted 5 mpt,gas detection and kommey drawdown- no failures recorded. Pulled TWC and MU Landing jt and report time 6/16/15-Tuesday Pulled TWC and MU Landing Jt. Back out lockdown pins pulled 70k to unseat hanger, pulled to rig floor, decompleted hanger BO/LD same, pull stand and thread cable to spooler.TOOH standing back tbg, LD ESP completion.Tallied pipe for cleanout trip. Loaded pipe shed with 19 jt. 2-3/8" PH6 work and Tallied. MU BHA 2-3/8" mule shoe 19 jts of 2-3/8" PH6 TIH w/same. PU/MU XO 2-3/8" PH6 x 3-1/2" IF,9-5/8" csg scraper, 87 jts of 2-7/8"TIH w/same. Continued TIH, 2-3/8" mule shoe @ 4,660' and csg scraper @ 4,060'. Reciprocated csg scaper thru packer set depth @ 4,010' &4,650'. Reversed circulated bottoms up and continued circulating until returns cleaned up.TOOH LD 2-7/8"Tbg and cleanout BHA. Perp rig to WL operations. MU Dutch Riser. Hilcorp Alaska, LLC llileorp AIa ka,IAA: Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP J-05 50-029-22196-00-00 191-095 6/15/2015 6/20/2015 Daily Operations: 6/17/15-Wednesday MIRU E-Line, PU/MU GR/CCL,firing head,#10 setting tool and 4-1/2" permanent packer w/2-3/8" mule shoe on bottom. RIH w/same and set down at 4,260' hard tag. PU and made several attempts to get thru 4,260'with no luck. POOH LD tools no scale or solids in tool string, RDMO E-Line. MIRU slick-line, PU/MU 3.80" centralizer,4.60"csg scratcher/brush and 3.95 GR. RIH w/same and tagged 4,265'.Tried working tools thru tag depth with no luck. POH RDMO slick-line.Tallied new 2-7/8" 6.5#EUE 8rd L-80 completion TBG.TIH w/same.TOH standing back.Waiting on 5-1/2"csg scraper to arrive. PU/MU 1 jt of 2-7/8"w/mule shoe on bottom,5-1/2" 17#casing scraper.TIH w/same and tagged bridge at 4,269'washed down to 4,280' reverse circulating 3bpm and fell thru. Circulated bottoms up, Returns clean.Continue in hole and tagged with casing scraper @ 4,617' mule shoe @ 6,648' Reverse circulating out heavy sand at report time. 6/18/15-Thursday Circulating well.Continue reverse circulating 3bpm @ 4,685' until return cleaned up SD pumping. Returns were heavy sand,seawater and 5%Oil.TOH w/cleanout BHA,tripped slow not to swab. LD/same. PU/MU 9-5/8"test packer and TIH w/same to set depth @ 4,055'.Set packer, closed BOP's and filled casing. Pressured up on casing to 1,500psi charted for 30mins-Tested good. Bled off pressure released packer and TOH. L/D 9-5/8"test packer. MU/PU tbg hanger w/TWC installed to landing jt. Landed hanger and RILDS. NU 13-5/8"single gate BOP w/2-3/8" pipe. 6/19/15-Friday AOGCC notified and Waived by Lou Grimaldi, Completed Shell Test 2-3/8" Pipe Rams 250-3,000psi,Annular 250-2,500psi, charted for 5mins, Kommey drawdown-no failures recorded.Tallied 2-7/8" PH6 work string, PU/MU 2-3/8" mule shoe and TIH w/67 jts of 2-3/8" PH6, PU/MU 2-3/8" PH6 x 2-7/8"8rd XO and TIH tagged hard 5k down @ 5,230'.Start to circulate @ 3bpm and could not wash thru.Tried making PU and rotated mule shoe still could not work thru. Reversed circulated 2 bottoms @ 3bpm, returns clean with 50% losses.SD Pump.TOH Standing back 2-7/8"and L/D 2-3/8"work string and mule shoe. PU/MU #10 Hyd setting tool,4-1/2" DNL permanent packer TIH w/same to 4,650'. Displaced tubing volume and dropped ball. Pumped ball down @ 2bpm and pressured up to 2,500psi.Set packer @ 4,650'.TOH w/work string L/D setting tool.Tallied completion jewelry. PU/MU 5'snap latch seal assembly and TIH w/same at report time. 6/20/15-Saturday Continued TIH w/completion string,tagged 4-1/2" packer with seal ext and marked, L/D 1 jt, PU/MU 2' pup 6' pup and tubing hanger.Slack off and stung in seal ext(neutral weight) landed hanger 64k up 60k down. RILDS. Completion as follows: EOT @ 4,664,4-1/2" packer @ 4,657',Snap Latch 4,656', 19 jts of 2-3/8", xo @ 4,061',xn nipple @ 4,049',9-5/8" packer @ 4,010', 2-7/8" 6.53 EUE 8rd L-80 to hanger.Set BPV ND BOP's/NU tree,tested void to 5,000psi-test ok, pulled BPV. RU hose to IA and bullheaded 120bbls of packer fluid. MIRU pumped down 175 bbls of diesel casing for freeze (A protection.Swapped hose to tubing and pumped 15bbls of diesel down tubing for freeze protection. Dropped ball &rod down tubing pressured up on tubing to 3,500psi and set 9-5/8" permanent packer.Swapped back to casing and pressured up to 1,500psi charted and held for 30 mins-test ok. Rig released at RDMO Nordic 3 and associated equipment. 6/21/15 Sunday No operations to report. 6/22/15 Monday No operations to report. 6/23/15-Tuesday No operations to report. Brooks, Phoebe L (DOA) b 19104150 From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, July 06, 2015 4:55 PM To: Brooks, Phoebe L (DOA) Subject: RE: Milne Point MITs on 7-3-15 Attachments: image002 jpg; image003 jpg; MPJ-05 SCHEMATIC 7-2-2015.doc; G-11 SCHEMATIC 6-25-2015.doc Phoebe, Please see attached schematics for packer MD on the new injector conversions MPG-11 and MPJ-05. Thanks, Wyatt Rivard I Well Integrity Engineer- 0: ngineer0: (907) 777-8547 I C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED JUL z 0 2015 If 11..1. lt.,.l:..1,1A. From: Wyatt Rivard Sent: Monday, July 06, 2015 4:44 PM To: 'chris.wallace@alaska.gov'; 'phoebe.brooks@alaska.gov'; 'jim.regg@alaska.gov'; 'doa.aogcc.prudhoe.bay@alaska.gov' Cc: Alaska NS - Milne - Wellsite Supervisors Subject: Milne Point MITs on 7-3-15 All, Five Milne Point water injectors had passing AOGCC witnessed MIT-lAs on 7-3-15.The MIT forms are attached for reference for the following wells: Well Field PTD MPG-11 Milne Point 1971190 MPJ-05 Milne Point 1910950 MPS-16 Milne Point 2030650 MPS-18 Milne Point 2022420 MPS-26 Milne Point 2030610 Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive, Suite 1400 I Anchorage,AK 99503 1 Milne Point Unit • Well: MPU J-05 ._ SCHEMATIC Last Completed: 6/20/2015 tlileni i,;klu,ka,1.1A, PTD: 191-095 CASING DETAIL KB Elev.:70.2'/DF Elev.=69.2/GL Elev.:35.2' Size Type Wt/Grade/Conn ID Top Btm 120" Conductor 94/K-55/Butt Weld 19.124 Surface 110' 20"J 13 3/8" Surface 61/K-55/Btrc. 8.835 Surface 2,458' 9-5/8" Production 45/L-80/Btrc 8.681 Surface 4,891' 5-1/2" Liner 17/N-80/EUE 8rd 4.892 4,078' 4,624' 4-1/2" Liner 11.6/N-80/LTC 4.000 4,624' 6,638' TUBING DETAIL 4' 3-1/2" Tubing 9.3/L-80/NSCT 2.992 Surface 26' A 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 26' 4,061' i, 2-3/8" Tubing 4.5/L-80/EUE 8rd 1.995 4,061' 4,664' 8 JEWELRY DETAIL No Depth ID Item 'i 1 35 3-1/2"x 2-7/8"X-Over 2 4,011' 9-5/8"Permanent Packer 3 4,049' XN Nipple 4 4,061' X-Over 2-7/8"to 2-3/8" 13-3/8" 4 11, . 5 4,079' 6.00 Baker SC-1L 96A4-60 Packer 6 4,086' 6.25 Sliding Sleeve 7 4,112' 5.20 7"x 5-1/2"8rd Cross-over 8 4,353' 5.00 5-1/2".012 Baker-weld Screen TOC Calculated 9 4,615' 4.00 S-22 Snap Latch Seal Assy. @ 2,619''---...,4_ 10 , 4,616' 6.00 Baker SC-1L 96A4-60 Packer 11 4,623' 4.00 7-5/8"x 4-1/2"LTC Cross-over 12 , 4,657' Snap Latch 13 4,658' 5'Seal Assembly >1' - 14 4,658' 4-1/2"Packer m 15 4,709' 3.813 Otis X-Nipple 4, 16 4,797' 5.00 Pack-off Overshot(Top) 17 4,890' 4.00 6-5/8"x 4-1/2"LTC Single Screen Prepack Liner 18 5,675' 3.813 Otis X-Nipple 19 6,098' 4.00 6-5/8"x 4-1/2"LTC Single Screen Prepack Liner - 20 6,624' 3.725 . Otis XN-Nipple NA 21 6,634' 4.00 Spaded Bullnose w/ports- Bottom @ 6,638' PERFORATION &OPEN HOLE DETAIL . Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Status "N"Sands 4,378' 4,392' 3,958' 3,964' 14 Isolated mc 4 "N"Sands 4,425' 4,465' 3,977' 3,993' 40 Isolated RATag@ 6 '''� 5 "N"Sands 4,495' 4,515' 4,004' 4,011' 20 Isolated 4,273' A 6, 7 "N"Sands 4,560' 4,605' 4,027' 4,042' 5 Isolated 8 , F ^}"N'Sads "0"Sands 4,891' 6,648' 4,105' 4,203' 1,757 Open WELL INCLINATION DETAIL OPEN HOLE/CEMENT DETAIL 9&10 KOP @ 900' 20" 624 Sacks Permafrost '11 Max Hole Angle in Tubing=41 deg. @ 3,900' 13-3/8" 1,600 Sacks'E'/250 Sacks'G' 12,13&14 Hole angle thru perfs=66deg. 9-5/8" 634 Sacks'G' � 15/8" , I, 15 16 Max Hole Angle=89 deg. @ 6,518' IL 17 TREE &WELLHEAD GENERAL WELL INFO Tree FMC 3-1/8"5M API:50-029-22196-00-00 13"5M tbg.Spool 13"x 3-1/2" Drilled and Cased by Nabors 27E -10/3/1991 18 "Cr SandsWellhead NSCT(T&B)FMC tbg.Hgr w/3.5" ESP Replacement by Nabors 4ES-10/24/2000 zir 'H'BPV Profile ESP Replacement-8/8/2003 20 21 ••• TD=6,648'(MD)/TD=4,203'(1VD) PBTD=N/A(MD)/PBTD=N/A(TVD) Created By:TDF 7/2/2015 • Schwartz, Guy L (DOA) From: Chris Kanyer <ckanyer@hilcorp.com> Sent: Monday,June 15, 2015 9:01 AM To: Schwartz, Guy L (DOA) Cc: Tom Fouts Subject: MPJ-05 BOP schematic update (PTD# 191-095, API# 50-029-22196-00-00, Sundry# 315-341) Attachments: MPU 13.625 BOP (w 2.875 Ram).pdf Guy, Due to the 13"wellhead on MPJ-05 (PTD#191-095, API#50-029-22196-00-00),the attached 13-5/8" BOP (schematic) will be installed and tested during the Nordic#3 rig workover in accordance with the approved sundry#315-341. Please let me know if you have any questions. Chris Kanyer Operations Engineer HiIcorp:%Lasko.IAA: ckanyer@hilcorp.com SCANNED JUL 0 22015 Direct: (907) 777-8377 Mobile: (907) 250-0374 1 MPU BOP Stack / 1 -t Y , \,,, e1 HydrII 13 5/8 5M filkarilltaill igi4W, • thaffer0 7,;8 a f'l 5 13518SSM Bands ,I....lcz I :0 i iii," , : : pi!,..e 4,:i i., 7 ...„. `) . �Y:tIi' _. i . iiiilidibillial i lir 135/85MFE x 35 Th r4, THE STATE Alaska Oil and Gas o Conservation Commission � � fAI ,ASl<�A. ' - ;_ _ = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 ALASY'P Fax: 907 276.7542 www.aogcc alaska.gov Chris Kanyer S Operations Engineer - 0 1 Hilcorp Alaska, LLC 1 I 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB J-05 Sundry Number: 315-341 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1C) Daniel T. Seamount, Jr. Commissioner gTh DATED this/ day of June, 2015 Encl. RECEIVED • STATE OF ALASKA JUN 0 2 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION GA`1��7 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request. Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Convert to WINJ D 2.Operator Name. 4 Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q • 191-095 • 3.Address. Stratigraphic ❑ Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22196-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 / Will planned perforations require a spacing exception? Yes ❑ No 0 / MILNE PT UNIT SB J-05 ' 9.Property Designation(Lease Number): 10 Field/Pool(s): ADL0025906• MILNE POINT/SCHRADER BLUFF OIL . 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): 6,648. 4,203 . 6,638- 4,203 - N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 110' 110' 2,110psi 520psi Surface 2,458' 13-3/8" 2,458' 2,415' 2,730psi 1,400psi Production 4,891' 9-5/8" 4,891' 4,105' 6,870psi 4,760psi Liner 546' 5-1/2" 4,624' 4,047' 7,740psi 6,390psi Liner 2,014' 4-1/2" 6,638' 4,203' 7,780psi 6,350psi Perforation Depth MD(ft): Perforation Depth TVD(ft). Tubing Size. Tubing Grade: Tubing MD(ft): 3-1/2" 9 3#/L-80/NSTC 26' See Attached Schematic See Attached Schematic 2-7/8" 6 5#/L-80/EUE 8rd 4,033' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft). SC-1L x(2)and N/A 4,078(MD)/3,795(TVD)&4,616(MD)/4,054(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic❑ Development❑ Service Q 14.Estimated Date for 15.Well Status after proposed work: 6/18/2015 Commencing Operations: OIL ❑ WINJ Q WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative. N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature .? ' Phone 777-8377 Date 6/2/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i5-3`-( I Plug Integrity ❑ BOP Test /' Mechanical Integrity Test [ Location C earance ❑ �/ / j Other: 4 4`tr ck ctc�K-�y- kc.Gt,by ci//- e 0-1.. az, 44' Z_5 ' !L(b) ) , Spacing Exception Required? Yes ❑ No I Subsequent Form Required: /Q•—4/01-/ / APPROVED BY / `S Approved by: ( C COMMISSIONER THE COMMISSION Date. ` 67- ; • S A � Submit Form and Form 10-403 R ised 5/2015/ 0 Ri6144i �is�valid for 12 month from the date of approval. hments i uplicate ///!'�'ll�\ ` 3 ��`il� ,/.�i6���,� RBDMS JUN 1 0 201! • Well Prognosis Well: MPJ-05 Hilcon,Alaska,LL Date:6/1/2015 Well Name: MPJ-05 API Number: 50-029-22196-00-00 Current Status: SI Producer Pad: J Pad Estimated Start Date: June 18, 2015 Rig: Nordic 3 Reg.Approval Req'd? June 16, 2015 Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 191-095 First Call Engineer: Chris Kanyer (907) 777-8377 (0) (907)250-0374 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: 1521485 Current Bottom Hole Pressure: — 1,512 psi @ 4,000' TVD (Last BHP measured 7/2/2014) Maximum Expected BHP: — 1,512 psi @ 4,000' TVD (No new perfs being added) Max. Allowable Surface Pressure: 1,112 psi (Assumed 0.1 psi/ft, based on actual reservoir conditions with observed of high GOR &49% water cut) Brief Well Summary: The Milne Point J-05 well was drilled as a Schrader Bluff development well that TD'd at 6,648' and ran 4-1/2" pre- packed screens into open hole, with a gravel pack across the N sands in December 1991. The well was completed initially as an ESP producer. This completion and subsequent ESPs failed and were replaced in 2000 and 2003. The recent pump failed with a broken shaft in October 2013. The most recent casing pressure test was performed to 3,500psi on 8/7/03. A casing pressure test will be conducted to 1,500psi during this workover with the newly installed packer. A 20ft subsidence drift was run 11/5/2013 and encountered no issues. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issues suspected. Variance from 20AAC25.412(h) Packer will be set greater than 200ft measured depth from open perfs. '' AOR(status of wells within 1/4 mile radius of injection zone): API Well No Permit Well Current Status Zonal isolation (method) Estimated TOC (calculated) at 3,375'MD 50-029-22196-00-00 191-095 l MPJ-05 � S/I Producer >1,500' above Schrader OA sand Schrader Note: Temperature log ran 11/20/1991 to determine TOC was inconclusive Monobore well cemented to surface, full 50-029-23031-00-00 201-133 MPG 14 Active Producer returns with 300bbl cement to surface - Schrader noted in reports. >6,500' above Schrader OA sand 50-029-22071-00-00 190-096 MPJ 02 S/I Injector- Estimated TOC (calculated) at 4,492'MD Schrader >1,250' above Schrader OA sand 50-029-22500-00-00 194-110 MPJ-10 Active Producer Estimated TOC (calculated) at 4,098'MD — Kuparuk >550' above Schrader OA sand Active Injector- Segmented Bond Log run on 10/15/1994 50-029-22508-00-00 194-126 MPJ-13 Kuparuk indicates TOC at 4,764'MD —410' above Schrader OA sand • II Well Prognosis Well: MPJ-05 llileorp Alaska,LL Date:6/1/2015 RWO Objective: Pull ESP, run casing scraper, straddle (isolate)the N-sand gravel pack, and run 2-7/8" x 2-3/8" water injection completion in the Schrader OA&OB sands,with packer set+200ft from perfs. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Attempt to circulate well with 8.5ppg seawater and monitor well. 3. ND tree, NU 11" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/2,500psi high. • Notify AOGCC 24hrs in advance to witness test. 4. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. i b. With stack out of the test path,test choke manifold per standard procedure. c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 5. Unseat hanger and pull 2-7/8" ESP completion from 4,033'to surface and lay down same. 6. RIH with cleanout BHA to+/-4,050'. POOH with same. 7. RU Eline. RIH with lower straddle 4-1/2" permanent packer and set same at+/-4,650'. RD Eline. 8. MU and RIH with upper straddle assembly on 2-7/8" 8RD EUE L-80 tubing [replace as necessary]. • 5ft seal assembly/snap latch • -600' of 2-3/8"4.6# L-80 8RD EUE tubing • 2-3/8"x 2-7/8" crossover • 2-7/8"XN nipple • 9-5/8" hydraulic set permanent packer See attached Proposed Schematic for set depths of jewelry. 9. Locate/space out/latch into lower straddle 4-1/2" packer at+/-4,650' (set in step#7), land tubing hanger, and 9-5/8" packer at+/-4,010'. 10. Set plug in 2-7/8" XN nipple (at+/-4,040') and pressure up on tubing to set 9-5/8" packer at+/-4,010'. 11. Perform a charted casing pressure test to 1,500psi for 3omin. Bleed off pressure. L p r- 12. ND BOP, NU and tree. , �.e// '!'7 / ��� �� ���„ � ro 13. RDMO workover rig and equipment. T COnGU/. f�r� s by q/PG�4� I� 14. Turn well over to production. 4Act P Z p�Dn u p 14e C' 4 15. Slickline to pull plug in XN nipple at+/-4,040' post rig. jqi-;t O(j,,�p �'•�- 76 , i//Y a 1 ,�r p rs ���(�►' raoGu��on . A. erh/6 ro /tog(&a./ Attachments: t— kf�•�"A"" f / 1. As-built Schematic ,tk lrPP" e � f�;►Cc rho, �j4�c- 5 Dws �� 2. Proposed Schematic ' 5-4-4,64...t� ���e+ ��vqrTi�J. 70l ro 4M ;A a ,tw 3. BOP Schematic Lp,' r4,.. "or 1710•1 & foi- 5.46,001 1,1/01,4_ recd d rite loot. if 4 2 Milne Point Unit Well: MPU J-05 SCHEMATIC Last Completed: 10/24/2000 llileorp Alaska,LLC PTD: 191-095 CASING DETAIL KBEIev.:70.2'/DFEIev.69.2/GL Elev.:35.2' Size Type Wt/Grade/Conn ID Top Btm 20"9'A ^1 1 `,d * 20" Conductor 94/K-55/Butt Weld 19.124 Surface 110' ti::: " 13-3/8" Surface 61/K-55/Btrc. 8.835 Surface 2,458' 2 9-5/8" Production 45/L-80/Btrc 8.681 Surface 4,891' " 5-1/2" Liner 17/N-80/EUE 8rd 4.892 4,078' 4,624' r 4-1/2" Liner 11.6/N-80/LTC 4.000 4,624' 6,638' r. ;: Milne Point Unit . 13 Well: MPU J-05 • PROPOSED Last Completed: 10/24/2000 Hlilcorp Alaska,LLC PTD: 191-095 CASING DETAIL KB Elev.:70.2'/DF Elev.=69.2/GL Elev.:35.2' Size Type Wt/Grade/Conn ID Top Btm 1 20" Conductor 94/K-55/Butt Weld 19.124 Surface 110' 20"j 13-3/8" Surface 61/K-55/Btrc. 8.835 Surface 2,458' 9-5/8" Production 45/L-80/Btrc 8.681 Surface _ 4,891' • , 5-1/2" Liner 17/N-80/EUE 8rd 4.892 4,078' 4,624' 4-1/2" Liner 11.6/N-80/LTC 4.000 4,624' 6,638' TUBING DETAIL 3-1/2" Tubing 9.3/L-80/NSCT 2.992 Surface 26' 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 26' ±4,050' 2-3/8" Tubing 4.5/L-80/EUE 8rd 1.995 ±4,050' ±4,650' JEWELRY DETAIL No Depth ID Item 1 ±26 3-1/2"x 2-7/8"X-Over 2 ±4,010' 9-5/8"Permanent Packer ((,,j. 3 ±4,040' XN Nipple 44 4 ±4,050' X-Over 2-7/8"to 2-3/8" 13-3/8", IL 5 4,079' 6.00 Baker SC-1L 96A4-60 Packer 6 4,086' 6.25 Sliding Sleeve 7 4,112' 5.20 7"x 5-1/2"8rd Cross-over 8 4,353' 5.00 5-1/2".012 Baker-weld Screen TOC Calculated 9 4,615' _ 4.00 S-22 Snap Latch Seal Assy. @2,619'\� 10 4,616' 6.00 Baker SC-1L 96A4-60 Packer , 11 4,623' 4.00 7-5/8"x 4-1/2"LTC Cross-over i IP le 12 ±4,649' Snap Latch 13 ±4,650' 5'Seal Assembly "1." r 14 ±4,650' 4-1/2"Packer 15 4,709' 3.813 Otis X-Nipple *"ae 16 4,797' 5.00 Pack-off Overshot(Top) k& 17 4,890' 4.00 6-5/8"x 4-1/2"LTC Single Screen Prepack Liner t k* 18 5,675' 3.813 Otis X-Nipple 19 6,098' 4.00 6-5/8"x 4-1/2"LTC Single Screen Prepack Liner 20 6,624' 3.725 Otis XN-Nipple 21 6,634' 4.00 Spaded Bullnose w/ports- Bottom @ 6,638' A. s. ,,•; PERFORATION &OPEN HOLE DETAIL t � 2 40N, Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Status w •-_-7-• "N"Sands 4,378' 4,392' 3,958' 3,964' 14 Isolated ra N• 4 O 1 "N"Sands 4,425' 4,465' 3,977' 3,993' 40 Isolated 6 1,' SRt9I " 5 3� "N"Sands 4,495' 4,515' 4,004' 4,011' 20 Isolated 4RA2 @ ``73 �' j `� 7 H 37g "N"Sands 4,560' 4,605' 4,027' 4,042' 5 Isolated 8 s ; 1"11.Sands "O"Sands 4,891' 6,648' 4,105' 4,203' 1,757 Open -- C) WELL INCLINATION DETAIL OPEN HOLE/CEMENT DETAIL 6 ?,:f4i +' yg10 t N KOP @ 900' 20" 624 Sacks Permafrost "f 1 11 Max Hole Angle in Tubing=41 deg. @ 3,900' 13-3/8" 1,600 Sacks'E'/250 Sacks'G' "i 19-5/8"1, . • 2'13' 14 Hole angle thru perfs=66deg. 9-5/8" 634 Sacks'G' • 51 Max Hole Angle=89 deg. @ 6,518' a 16 17 TREE&WELLHEAD GENERAL WELL INFO al Tree FMC 3-1/8"5M API:50-029-22196-00-00 13"SM tbg.Spool 13"x 3-1/2" Drilled and Cased by Nabors 27E -10/3/1991 • 1811, a Sands Wellhead NSCT(T&B)FMC tbg.Hgr w/3.5" ESP Replacement by Nabors 4ES-10/24/2000 'H'BPV Profile ESP Replacement-8/8/2003 iti 21 ••• TD=6,648'(MD)/TD=4,203'(1VD) PBTD=N/A(MD)/PBTD=N/A(TVD) Created By:TDF 6/2/2015 11" BOP Stack r 1 O O iiia ii Hydril 11" 5M [alt"L°H (1°0 L Shaffer * _1 On 2 3/8" Rams 1410 [-\ 11" 5M1 COD 2 5.5 variable7/8s — Hydril MO— L 11" 5M1._—__)=DBlinds 0 . Optional valve port -16 J-11 • J-08 J-13 J-01 A Q-I 4 J-15 G- 11 G-14 v G 10 ;II Ili J-0.-01AL lA \ \ J-12 \ \0 / v G-08 \ \ V N .25.- P 1 —y 1\ 1,191 , X05 '�_ tlrilliIllk - - M \ _1 ' i 1 , / , \` O1- -• -F _i_o__-- -_ 0! 'J-0 2 \\=�'\ G-04 ill 1 \l INk ' ) II G-12 a26 '-`\-4) „ 17#, _ - G-11 - / ��Q7 /-1 HILCORP ALASKA LLC I \ 3L1 H-1 8L 1 MILNE POINT FIELD . -f I AOR MAP i \I\ MPJ-05 +i II x. 1 \ 0 1052 \ I 1/-04 FEET \ i 1-04A 1 \ I , • POSTED WELL DATA Well Number \ • J rll0Ir--- L1 \• \ WELL SYMBOLS \ • Active Oil \ \ ,k INJ Well(Water Flood) \ I-02 P&A Oil \ REMARKS \ RED DOT=Top Schrader Bluff OA Sand Wel■ \ —11.4\ Back DashoCaGe=1329'radius from midperf ' \ / — Perfs along wellpath in green / \ / —. — April 18,2015 PETRA 4/16/2015 3'.19'.45 PM XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~/--~ ~-File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts - Pages: [3 Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type OVERSIZED .~' Logs *of vadous kinds [] Other Complete COMMENTS: Scanned by: Dianna Vincent Nathan Lowell TO RE-SCAN Notes: · Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: isl bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 ) FEB 2 1 21 Mr. Tom Maunder t ° ( °R5- Alaska Oil and Gas Conservation Commission 333 West 7 Avenue— S 9� Anchora a Alaska 99501 " V Subject: Corrosion Inhibitor Treatments of MPJ -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPJ -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPJ -Pad 9/5/2011 Corrosion Vol. of cement Cement top off Corrosion inhibitor/ I Well Name PTD # API # Initial top of cement pumped Final top of cement date inhibitor sealant date I ft bbls ft gal MPJ -01A 1991110 50029220700100 Sealed Conductor NA NA NA NA NA MPJ -02 1900960 50029220710000 Sealed Conductor NA NA NA NA NA MPJ -03 1900970 50029220720000 Sealed Conductor NA NA NA NA NA MPJ-04 1900980 50029220730000 Sealed Conductor NA NA NA NA NA ---� MPJ-05 1910950 50029221960000 Dust Cover NA NA NA 3.4 9/5/2011 MPJ-06 1940950 50029224930000 4 NA 4 NA 8.5 8/21/2011 MPJ -07 1910970 50029221980000 3.8 NA 3.8 NA 3.4 8/21/2011 MPJ -08A 1991170 50029224970100 18 NA Need top job MPJ -09A 1990114 50029224950100 Sealed Conductor NA NA NA NA NA MPJ -10 1941100 50029225000000 Sealed Conductor NA NA NA NA NA MPJ -11 1941140 50029225020000 Sealed Conductor NA NA NA NA NA MPJ -12 1941180 50029225060000 Sealed Conductor NA NA NA NA NA MPJ -13 1941260 50029225080000 1 NA 1 NA 3.4 8/21/2011 MPJ -15 1991070 50029229520000 Dust Cover NA NA NA 5.1 9/5/2011 MPJ -16 1951690 50029226150000 1.8 NA 1.8 NA 11.1 8/20/2011 MPJ -17 1972080 50029228280000 0.8 NA 0.8 NA 8.5 9/5/2011 MPJ -18 1972200 50029228340000 1.3 NA 1.3 NA 17.0 9/5/2011 MPJ -19A 1951700 50029226070100 2.2 NA 2.2 NA 15.3 8/20/2011 MPJ -20A 2001850 50029228320100 5.8 NA 5.8 NA 65.5 9/5/2011 MPJ -21 1972000 50029228250000 3.5 NA 3.5 NA 28.1 8/20/2011 MPJ -23 2001200 50029229700000 0.8 NA 0.8 NA 10.2 11/1/2009 MPJ -24 2001490 50029229760000 Open Flutes - Treated MPJ -25 2040730 50029232070000 1 NA 1 NA 8.5 8/21/2011 MPJ -26 2040640 50029232050000 1.2 NA 1.2 NA 11.9 8/20/2011 KA( STATE OF ALASKA 'd~' ALAS ,~IL AND GAS CONSERVATION C ~v,,vllSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: [] Abandon [] Suspend [] Operation Shutdown [] Perforate [] Variance I~ Othe, [] Alter Casing I~ Repair Well [] Plug Perforations r"l Stimulate [] Time Extension Change Out ESP [] Change Approved Program I~1 Pull Tubing [] Perforate New Pool [] Re-Enter Suspended Well I-] Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number- BP Exploration (Alaska) Inc. [] Development [] Exploratory 191-095 ,., 3. Address: [] Stratigraphic [] Service 6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22196-00-00 7. KB Elevation (ft): KBE = 70.20' 9. Well Name and Number: MPJ-05 . 8. Property Designation: 10. Field / Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 6648 feet true vertical 4203 feet Plugs (measured) Effective depth: measured 6638 feet Junk (measured) true vertical 4203 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 2320 1500 Surface 2458' 13-3/8" 2458' 2415' 2730 1130 Intermediate Production 4891' 9-5/8" 4891' 4105' 6870 4760 Liner 1791' 6-5/8" 4078' - 6638' 3795' - 4203' Perforation Depth MD (ft): 4378'- 6648' Perforation Depth TVD (ft): 3958'- 4203' Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# N-80 4031' Packers and SSSV (type and measured depth): Gravel Pack Assembly Baker SC-IL at 4078' and 4616' 12'""Stimulation or cement squeeze summary: . Intervals treated (measured): Treatment description including volumes used and final pressure: , 13. Representative Daily Avera~le Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casinq Pressure Tub[,,n,q Pressure Prior to well operation: Subsequent to operation: " :14. Attachments:' " 15. Well Class after proposed wo~:i(: ..... [] Copies of Logs and Surveys run [] Exploratory [] Development [] Service [] Daily Report of Well Operations 16. Well status after proposed work: [] Oil [] Gas [] WAG [] GINJ [] WINJ [] WDSPL ~"71 I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: I Contact Robert Odenthal, 564-4387 Printed Name Sondra Stewman Title Technical Assistant ~ ~ ~~~,,~~' '~-~' Prepared By Name/Number: Si ~' ~ Phone .~-~', ..... g[,.,u,~ /~:vo~,~%~ t~',.%~fl~--.-.---- ~..')L~: ": ~7c::;'~.~ Date -/~:'~Y~ Sondra Stewman, 564-4750 Form 10-4( U BP EXPLORATION Page 1 of 3 Operations Sumrna Report . !Legal Well Name: MPJ-05 Common Well Name: MPJ-05 Spud Date: 11/14/1991 Event Name: WORKOVER Start: 8/6/2003 End: 8/8/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/8/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 8/6/2003 06:00 - 07:30 1.50 MOB P PRE Held PJSM. Rigged Down. Scoped Down and L / D Derrick. 07:30 - 08:30 1.00 MOB I p PRE Broke Apart Rig Modules. Prepared to Move Rig. 08:30 - 11:00 2.50 MOB P PRE Held PJSM w/Truck Drivers and Drilling Crew. Moved Rig from MPC-41 to MPJ-05. 11:00 - 11:30 0.50 MOB P PRE Moved and Spotted Sub Over MPJ-05. 11:30 - 12:30 1.00 MOB P PRE Held PJSM. Raised and Scoped Derrick. R / U Derrick and Rig Floor. 12:30 - 13:00 0.50 MOB P PRE Spotted Pit Module, Pipe Shed and Camp. Bermed Rig. 13:00-14:30 1.50 WHSUR P DECOMP R/U Lines to Tree and Wellhead. R/UTigerTankand Hardlines. Took on Seawater. Accepted Rig at 1300 hrs 8 / 6 / 2003. 14:30 - 15:00 0.50 KILL = DECOMP Held PJSM. Pressure Tested Hardlines to 3,500 psi, OK. 15:00 - 16:00 1.00 WHSUR P DECOMP Held PJSM. R / U DSM Lubricator, Pulled BPV, R / D DSM. Tubing Pressure 100 psi, Annulus Pressure 490 psi. 16:00 - 18:00 2.00 KILL = DECOMP Held Pre Spud Meeting, Monitored Well, Tubing 100 psi, Annulus 400 psi. Bled Down Tubing and Annulus. Pumped Down Tubing to Displace Well to 140 deg 8.6 ppg Seawater. Pump Rate 4 bpm, 150 psi. Pumped 3 Tubing Volumes, 75 bbls w/No Returns. R / U to Pump Down Annulus, Shut in Choke and Bullheaded 335 bbls 140 deg 8.6 ppg Seawater Down Annulus. Shut Down Pump and Shut In Well. 18:00 - 18:30 0.50 KILL P DECOMP Opened Well and Monitored. Tubing and Annulus on Vacuum. 18:30 - 19:00 0.50 WHSUR P DECOMP Set TWC and Tested to 1,000 psi, OK. 19:00-20:00 1.00 WHSUR.P DECOMP HeldPJSM. BIDandRIDLines, DrainedandNID Production Tree. 20:00-21:30 1.50 BOPSUF P DF:COMP Held PJSM. N/U 13-5/8"x5,000 psi BOP Stack. Hydril Annular Preventer, Blind Rams, Mud Cross, Lower Pipe Rams w/2-7/8" x 5" Variable Rams. 21:30 - 00:00 2.50 BOPSUR P DF:COMP Held PJSM. R / U Test Equipment. Tested BOPE. Tested Lower Rams, Blind Rams, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves, IBOP and Kelly to 2,500 psi High / 250 psi Low. Tested Annular Preventer to 2,500 psi High / 250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held w/No Leaks or Pressure Loss. Test Waived by AOGCC Rep Chuck Scheve. 8/7/2003 00:00 - 01:00 1.00 BOPSUI~ P DECOMP Completed BOPE Test. Performed Accumulator Test. Witness of BOP Test Waived by AOGCC Rep Chuck Scheve. R / D BOPE Test Equipment. 01:00 - 01:30 0.50 WHSUR P DECOMP Held PJSM. R / U DSM Lubricator, Pulled TWC, R / D DSM. Tubing and Annulus on Vacuum. 101:30-02:00 0.50 PULL P DECOMP HeldPJSM. M/U3-1/2"DPandXO. M/UtoTubingHanger, BOLDS. 02:00 - 02:30 0.50 PULL P DECOMP Pulled Hanger Offseat, String Weight Up 37,000#. Pulled Tubing Hanger to Floor. Tested ESP Cable, OK. Terminated ESP Cable. Broke Out and L / D Landing Joint and Tubing Hanger. Ran ESP Cable Through Sheave and Connected to Spooler in Spooling Unit. 02:30 - 06:30 4.00 PULL P DECOMP POOH w/2-7/8" Tubing. Racked Tubing in Derrick. Spooled Up ESP Cable. 06:30 - 08:00 1.50 PULL P DECOMP Inspected, Broke Out and L / D ESP Pump Assembly. 08:00 - 09:00 1.00 PULL P DECOMP 'R / D Spooling Equipment and 2 7/8" Handling Equipr~ent. !Cleared and Cleaned Rig Floor. R/U 3 1/2" Drill Pipe Handling Equipment. Printed: 8/11/2003 10:55:44 AM BP EXPLORATION Page 2 of 3 Operations Surnrna Report , , Legal Well Name: MPJ-05 Common Well Name: MPJ-05 Spud Date: 11/14/1991 Event Name: WORKOVER Start: 8/6/2003 End: 8/8/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/8/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 8/7/2003 09:00 - 09:30 0.50 CLEAN ~ DECOMP Held PJSM. M / U BHA #1:8 1/2" Bit - 9-5/8" Casing Scraper- 2 x Boot Baskets - Bit Sub - Oil Jar - XO. BHA Total Length 27.43'. 09:30 - 13:00 3.50 CLEAN = DECOMP RIH w/BHA #1 on 3-1/2" DP to 4,061'. Tagged Top of Packer at 4,061'. No Fill. 113:00 - 15:00 2.00 CLEAN = DECOMP M / U Circulating Head and Line. Filled the Hole, Took 42 bbls, Fluid Level at 685'. Circulated Bottoms Up, Pump Rate 6 bpm, 750 psi, Average Loss 60 bph. Total Volume Pumped 311 bbls. Circulated back 70 bbls of Crude Oil w/Slight Show of Gas at Bottoms Up. Reciprocated Drill String While Circulating. 15:00 - 16:00 1.00 CLEAN P DECOMP Held PJSM. Slipped and Cut Drilling Line. 16:00 - 17:30 1.50 CLEAN P DECOMP POOH w/3-1/2" DP. 17:30 - 18:30 1.00 CLEAN P DECOMP Broke Out and L / D BHA. 18:30 - 19:00 0.50 EVAL I p DECOMP Held PJSM. M / U 9-5/8" RTTS Packer. 19:00 - 20:30 1.50 EVAL P ~DECOMP 'RIH w/RTTS Packer on 3-1/2" DP to 4,035'. 20:30 - 22:00 1.50 EVAL P I DECOMP ~M / U Circulating Head and Line. Circulated 5 bbls Around Packer to Ensure Packer Rubbers were Clear of Debris. Set I RTTS Packer at 4,032'. Filled Hole, Took 31 bbls, Fluid Level 505'. Closed Pipe Rams, Pressure Tested 9-5/8" Casing, to 3,500 psi. Calculated Strokes to Pressure Up to 3,500 psi -- 50 stks, (2.88 bbls), Actual Strokes to Pressure Up to 3,500 psi = 57 stks, (3.30 bbls). OA Pressure During Test 150 psi. Held Test f/30 Minutes w/No Pressure Loss or Leaks. Bled Down Pressure, Opened Pipe Rams. Blew Down Lines, Released RTTS Packer. 22:00 - 00:00 2.00 EVAL P DECOMP POOH, L / D 3-1/2" DP. Pumped 2 x Displacement. 8/8/2003 00:00 - 01:30 1.50 EVAL P DECOMP POOH, L / D 3-1/2" DP. Pumped 2 x Displacement. 01:30 - 02:00 0.50 EVAL P DECOMP Broke Out and L / D RTTS Packer. 02:00 - 03:00 1.00 RUNCOI~P COMP R / D 3-1/2" DP Handling Equipment. Cleared and Cleaned Rig Floor. R / U 2-7/8" Tubing Handling Equipment. 03:00 - 06:00 3.00 RUNCOI~P COMP M / U ESP Assembly. Connected MLE to ESP Pump and Secured. Tested Cable and Pump, OK. 06:00 - 08:00 2.00 RUNCOI~P COMP RIH w/ESP Assembly on 2-7/8" 6.5# 8rd EUE Tubing, Average M / U Torque, 2,350 ft / lbs. Pumped 10 bbls of Seawater Down Tubing at 2,000' to Ensure Tubing was Clear of Debris. 108:00 - 08:30 0.50 RUNCOI~P COMP M / U Tubing Hanger and Installed Penetrator. 08:30 - 10:30 2.00 RUNCOI~P COMP M / U EFT Connector Splice, Attached Cable and Tested, OK. 10:30 - 11:00 0.50 RUNCOr~' COMP Landed Tubing Hanger and RILDS. String Weight Up 41,000#, String Weight Down 38,000#. Completion Equipment Set At The Following Depths: Item Length Depth ESP Pump Assembly 63.12' 4,032.31' 2-7/8" 6.5# 8rd EUE Pup Jt 10.02' 3,967.08' 2-7/8" 6.5# 8rd EUE Pup Jt 2.11' 3,957.06' XN Nipple 0.96' 3,956.10' 4 Jts 2-7/8" 6.5# 8rd EUE Tbg 126.11' 3,829.99' #1 GLM Assembly 22.41' 3,807.58' 119 Jts 2-7/8" 6.5# 8rd EUE Tbg 3,649.02' 158.56' #2 GLM Assembly 26.28' 13,2.28' 3 Jts 2-7/8" 6.5# 8rd Tbg 94.50' 3,7.78' 2-7/8" 6.5# 8rd EUE Pup Jt 10.31' 27.47' 2-7/8" x 3-1/2" 8rd XO 1.84' 25.63' 3-1/2" 8rd x 3-1/2" NSCT XO 1.67' 23.96' Printed: 8/11/2003 10:5.5:44 AM BP EXPLORATION Page 3 of 3 Operations Surnma Report Legal Well Name: MPJ-05 Common Well Name: MPJ-05 Spud Date: 11/lz1/1991 Event Name: WORKOVER Start: 8/6/2003 End: 8/8/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/8/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 8/8/2003 10::30 - 11:00 0.50 RUNCOrt~ COMP 3-1/2" NSCT Pup Jt 1.89' 22.07' Tubing Hanger 0.78' 21.29' 11:00 - 11:30 0.50 WHSUR ~ COMP Broke Out and L / D Landing Joint. Set TWC and Tested to 1,000 psi, OK. B / D Lines, Drained BOP Stack. 11:30 - 13:00 1.50 BOPSUF ~ COMP Held PJSM. N / D BOPE. 13:00 - 14:00 1.00 WHSUR ~ COMP Held PJSM. N / U Production Tree. 14:00 - 14:30 0.50 WHSUR ~ COMP Held PJSM. Tested Hanger, Neck Seal and Void to 5,000 psi, OK. Tested Tree to 5,000 psi, OK. 14:30 - 15:30 1.00 WHSUR ~ COMP Held PJSM. R / U DSM Lubricator, Pulled TWC, Set BPV, R / D DSM. Tubing Pressure 0 psi, Casing 0 psi. 15:30 - 16:00 0.50 WHSUR P COMP Secured Well, Released Rig 1600 hrs 8 / 08 / 2003. Printed: 8/11/2003 10:55:44 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' Julie Heusser, Commissioner DATE: April 22, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Milne Point Unit J &,l Pads Sunday April 22, 200t.' I traveled to BPXs MPU J & I Pads and witnessed the semi annual safety valve system testing. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 17 wells and 34 components with no failures. Lee Hulme performed the testing today; he demonstrated good test procedures and was a pleasure to work with. I also inspected the well houses on these pads during the SVS testing. All the wellhouses were very clean and the equipment appeared to be in excellent condition. Summary: i witnessed SVS testing at BPXs MPU J & I Pads. MPU J Pad, 1'lWells 22 components 0 failUres MPU I Pad ~6-wellS '12 components 0 failures 23 wellhouse inspections Attachment: SVS MPU J Pad 4-22-01 CS SVS MPU I Pad 4-22-01 CS ~X UnClassified Confidential (Unclassified if doc. removed ) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee H~lme ' AOGCC Rep: Chuck Scheve Submitted By: 'Chuck ~hex)e ' Date: Field/Unit/Pad: ~ Point / R/iPu / I Pad Separator psi: LPS 140 HPS 4/22/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI, PSI ..... Trip Code , Code Cod,e Passed GAS, or CYCLE 1-01 1900900 1-02 1900910 140 100 .... 95 P " P' ~ ' OIL 1-03 1900920 140 100 95 P P ' ' 1-04 1900930 140 100 " 95 P P 0IL 1-06 1971950 140 100 95 P P OIL! 1-07 1951510 140 1 O0 95 P P OIL 1-08 1971920 ' ' '~40! 100 95 .... P P ' ' 'OIL' Wells: 6 Components: 12 Failures: 0 Failure Rate: 0.00% E] 90 oar Remarks: RJF 1/16/01 Page 1 ofl SVS MPU I Pad 4-22-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Milne Point / MPU / J Pad Separator psi: LPS 140 HPS 4/22/01 ! Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE J-01A 199111'0 ' 140 100: 95 p p OIL , J-03 1900970 140 100 95 p p OIL j204 1900980 140 100 95 p ~ 'OIL ~05 1910950 140 100 95 p P OIL J-06 1940950 '140 " 100 125 P p ........ OIL J-07 'i910670 140 100 95 ~ e' " OIL J-08A 1991170 '140 100 95 P p ' ' OIL J-09A " 19911~0: ''140 100 110 p P OIL J-10 1941100 140 100 95 p p OIL J-11 1941140 ~12' '194i180 ' ' ' , , J~lS' 1972200 ' , , , J-19A 1951700 320 1972i50 " ' J-21 1972000 140 100 ' 95 p "p ' ' '0IL , , J-22 1981240 140 100 95 p p OIL ~23 2001200 ~ , . ,, ,, , Wells: 11 Components: 22 Failures: 0 Failure Rate: 0.00% F! oo var Remarks: RJF 1/16/01 Page 1 ofl 'SVS MPU JPad 4-22-01 CS · *'-'--, STATE OF ALASKA ,~-~ ALASKA ,..AND GAS CONSERVATION COMN. .JlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 70.2 [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2292' NSL, 2113' EWL, SEC. 28, T13N, R10E, UM MPJ-05 At top of productive interval 9. Permit Number / Approval No. 191-095 3153' NSL, 3163' EWL, SEC. 28, T13N, R10E, UM 10. APl Number At effective depth 50- 029-22196-00 4603' NSL, 4906' EWL, SEC. 28, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 4609' NSL, 4914' EWL, SEC. 28, T13N, R10E, UM 12. Present well condition summary Total depth: measured 6648 feet Plugs (measured) true vertical 4203 feet Effective depth: measured 6638 feet Junk (measured) true vertical 4203 feet Casing Length Size Cemented MD TVD Structural Conductor 115' 20" 480 sx Permafrost 'C' 110' 110' Surface 2957' 13-3/8" 1600 sx PF 'E', 250 sx Class 'G' 2458' 2415' Intermediate Production 4891' 9-5/8" 634 sx Class 'G' 4891' 4105' Liner 1791' 6-5/8" Pre-Packed Screen Assembly 4078' - 6638' 3795' - 4203' (Open Hole from 4891' to 6648') Perforation depth: measured 4378' - 4392', 4425' - 4465', 4495' - 4515', 4560' - 4605' true vertical 3957' - 3964', 3977' - 393', 4005' - 4012', 4028' - 4042', 4105' - 4203' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 4030' Packers and SSSV (type and measured depth) Gravel Pack Assembly Baker SC-IL packers at 4078' and 4616' 13. Stimulation or cement squeeze summary Intervals treated (measured) DEC 2 2 2000 Treatment description including volumes used and final pressure Alaska 0¢1 & Gas Cons. Commission Anchor~e 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerdeHubble,~~ ~-~ Title TechnicalAssistant Date Prepared By Name/Number: Terde Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplica~ Legal Well Name: MPJ-05 Common Well Name: MPJ-05 Spud Date: 11/14/1991 I Event Name: REPAIR Start: 10/18/2000 End: Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES 10/21/2000 21:00 - 22:30 1.50 MOB PRE SCOPE AND LOWER DERRICK 22:30 - 00:00 1.50 MOB PRE MOBILIZE RIG MOVE FROM MPC-01 TO MPJ-05 10/22/2000 00:00 - 01:30 1.50 MOB PRE 00:00-01:30 MOBILIZE RIG MOVE FROM MPC-01 TO MPJ-05 01:30 - 03:30 2.00 RIGU PRE BERM AND SPOT SUB, PITS AND PIPE SHED 03:30 - 07:00 3.50 RIGU PRE SPOT AND BERM TIGER TANK, RIG UP LINES TO KILL TO KILL WELL. RIG ACCEPTED AT 05:00 HRS 10-22-00 07:00 - 07:30 0.50 WHSUR DECOMP PICKED UP LUBRICATOR AND PULLED BPV. 320 PSI SlTP 07:30 - 09:00 1.50 WHSUR DECOMP RIG UP LINES TO TREE AND HANG ELEPHANT TRUNK. TAKE ON WATER TO PITS 09:00 - 09:30 0.50 KILL DECOMP TESTED LINES TO 2500 PSI 09:30 - 16:30 7.00 KILL DECOMP OPEN WELL TO CHOKE WITH 250 PSI ON THE TUBING AND 1300 PSI SLOP. CIRCULATED WELL AROUND WITH 8.4 PPG FLUID. WELL NOT DEAD. RECOVERING OILY FLUID. WEIGHT UP TO 8.8 PPG AND CONTINUED TO CIRCULATE WELL CLEAN. TAKE ON ADITIONAL SOURCE WATER. CIRCULATED 225 BBLS OF OILY FLUID TO TIGER TANK. LOST 203 BBLS TO THE WELL. WELL DEAD 16:30 - 18:30 2.00 WHSUR DECOMP INSTALLED TWCV AND TESTED SAME TO 2500 PSI 18:30 - 19:30 1.00 WHSUR DECOMP BLEED HANGER PRESSURE AND NIPPLE DOWN TREE 19:30 - 22:30 3.00 BOPSUE DECOMP INSTALL MUD CROSS AND NIPPLE UP BOP EQUIPMENT 22:30 - 00:00 1.50 BOPSUF DECOMP TESTED CHOKE MANIFOLD, AND BEGAN BOP TEST 250 PSI/3500 PSI. 10/23/2000 00:00 - 00:30 0.50 BOPSUF DECOMP COMPLETED BOP TEST AT 250 PSI/3500 PSI. ANNULAR 250~2500 PSI 00:30 - 02:00 1.50 BOPSUF DECOMP R D TEST EQUIP/PU LUBRICATOR AND PULL TWCV/LD LUB 02:00 - 03:30 1.50 PULL DECOMP MAKE UP LANDING JOINT, BACK OUT LOCK DOWN SCREWS, PULL HANGER TO THE FLOOR. TEST ESP CABLE AND LAY DOWN HANGER. PICK UP WEIGHT 35 K. SHOT FLUID LEVEL AND ~ FOUND FLUID AT 270' FROM SURFACE '~ 03:30 ~ 06:00 2.50 PULL DECOMP PULL OUT OF THE HOLE WITH 2 7~8" RICE COATED TUBING TO ._~ ~ ~ 2794' PUMPED DOUBLE DISPLACEMENT WHILE PULLING ~ o TUBING. ~ ~ 06:00 - 08:00 2.00 PULL DECOMP WEIGHTED UP VOLUME IN PITS TO 8.8 PPG FROM 8.3 PPG. -~ PUMPED TUBING VOLUME WITH 8.8 PPG FLUID. _3 ~ ,~ 08:00 - 12:00 4.00 PULL DECOMP PULLED OUT OF THE HOLE WITH AND LAID DOWN 2 7/8" RICE ~1 ,~ WRAPPED TUBING. PULLED TO TOP OF ESP ~ ~ 12:00 - 13:30 1.50 PULL DECOMP LAID DOWN ESP ~ 13:30 ~ 15:00 1.50 PULL DECOMP CLEAR RIG FLOOR AND RIG UP TO RUN 2 7/8" ESP COMPLETION .~ 15:00 - 17:00 2.00 RUNCOI~ COMP PICKED UP AND SERVICED NEW ESP. MAKE UP PUPS AND XN ~ NIPPLE. 17:00 - 22:30 5.50 RUNCOI~ COMP RIH WITH ESP WHILE PICKING UP 2 7/8" TUBING 22:30 - 00:00 1.50 RUNCOI~ COMP MAKE UP LANDING JOINT AND MAKE UP TUBING HANGER WITH XO. ATTACH FIELD CONNECTION. 10/24/2000 00:00 - 01:00 1.00 RUNCOr COMP ATTACH FIELD CONNECTION. 00:00-01:00 CONNECT TO PENETRATOR AND TEST. 01:00 ~ 01:30 0.501 RUNCO~ COMP LAND HANGER AND RUN IN LOCK DOWN SCREWS 01:30 - 02:00 0.50 RUNCO~ COMP LAY DOWN LANDING JOINT. SET TWCV AND TEST TO 2500 PSI 02:00 ~ 04:00 2.00 WHSUR COMP N D BOP AND MUD CROSS 04:00 - 06:30 2.50 WHSUR COMP PICK UP TREE, CHANGE OUTADAPTER FLANGE NIPPLE UP :TREE 06:30 ~ 07:30 1.00 WHSUR COMP TEST TREE AND HANGER TO 5000 PSI 07:30 ~ 08:30 1.00 WHSUR COMP PICKED UP LUBRICATOR AND PULL TWCV. SET BPV Printed: 11/28/2000 8:53:10 AM BP EXPLORATION Page 2 of 2 Operations Summary Report Legal Well Name: MPJ-05 Common Well Name: MPJ-05 Spud Date: 11/14/1991 Event Name: REPAIR Start: 10/18/2000 End: Contractor Name: NABORS Rig Release: 10/24/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES Sub Date From - To Hours Task COde Phase DesCription of Operations 10/24/2000 08:30 - 09:000.50 WHSUR COMP SECURE WELL HEAD- PICK UP CELLER AREA RIG RELEASED Al' 09:00 HRS 10-24-2000 RECEIVED DEC %~ ZOO0 Alaska 0it & Gas Co~s. commiss'~on Anchorage Printed: 11/28/2000 8:53:10 AM INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 91-095 DDL/GR/CCL 91-095 GCT/TEMP/GR 91-095 MWD-DGR/EWR/FXE 91-095 MWD-DGR/EWR/FXE 91-095 TEMP/GR 91-095 407 91-095 DAILY WELL OP 91-095 SURVEY 91-095 SURVEY 91-095 5132 91-095 5160 R1-3,5"~4000-4410 0-4510 2&5"MD~2447-6648 2&5"TVD,2404-4200 R1,5",20-4332 COMP DATE:12/03/91 11/14/91-12/03/91 MWD SS DIRECTIONAL OH-MWD,2447-6648 GCT,1.35-6648 SUMMARY Are well tests Was well cored? If yes, was the core Are dry ditch samples required? Yes WELL IS IN COMPLIANCE. Yes No analysis & description received? INerTIAL 11/15/1993 PAGE: COMMENTS: Slaer r -sun 0 Fi I I--I--I N CS SE Fi~JI i-- E S OI{IGINA£ February 18, 1992 Mr. Steve Rossberg Conoco, Inc. 3201 C Street, Suite 200 Anchorage, AK 99503 Re: MWD Survey Report J-5 Dear Mr. Rossberg, Enclosed is the survey report you requested. This is the final version. Regards, Ken Broussard Alaska Manager RECEIVED Gas Cons, ~'"" ~"~"~ 5631 SilveradoWay, SuiteG · Anchorage, Alaska99518 ° (907) 563-3256 ° Fax (907)563-7252 A Baroid Company STATE OF ALASKA 0 RIG I N.A L ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] sUSPENDED [] ABANDONED [] SERVICE 2. Name of Operator Conoco, Inc. 3. Address 3201 "C" Street, Anchorage, AK 99503 14. Locat on of weH at surface 2988' FNL, 3167' FEL, Sec. U. M. At mop Producing lnterva12104 ' FNL, 2100' FEL, Sec. At TotaI Depth 648~ F~L, 380' FEL, Sec 28, T13N, 6. Lease Designation and Serial No. ADL25906 7. Permit Number 91-95 8. APl Number 50-029-22196 9. Unit or Lease Name Milne Point 10. Well Number J-5 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 70' ASL Schrader Bluff 12. Date Spudded 113. Date T.D. Reached ' I 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 11/14/91 111/23/91 112/03/91 feet MSL I 17. TotalDepth (MD+TVD)/18.PIugBackDepth(MD+TVD)I 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 6648' MD(4200'TVD~ 6638' FfD(41a0'TV~TESE~ NO[] feetMD 1700' 'KB 22. Type Electric or Other Logs FRom MWD - OR/RES 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 20" 13 3/8" WT. PER FT. 94 GRADE K-55 K-55 SETTING DEPTH MD TOP BOTTOM Surf. 115' Surf. 2957' HOLE SIZE 36" 17 1/2" CEMENTING RECORD 624 SACKS PERMAFROST 54.5 9 5/8" 47 L-80 Surf. 4891' 12 1/4" 634 SACKS "G" Pre-Pack 6 5/8" 4849' 6640' Screen 8 1/2" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) .4378' - 4605' MD Perforations 3962' - 4032' TVD 4891' - 6648' MD Open-hole 4103' - 4200' TVD 1600 SACKS "E"/250 S~ AMOUNT PULLED ~CKS "G" 25. SIZE 2 7/8" 26. TUBING RECORD DEPTH SET (MD) I PACKER SET (MD) 3410' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 4891' - 6648' 50 bbl. HCL 27. Date First Production Date of Test Flow Tubing Press. ~8. Hours Tested Casing Pressure PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) PRODUCTION FOR I OI L-BB L TESTPERIOD Jl~ ] CALCULATED i~ I OIL-BBL 24-HOUR RATE -~' I GAS-MCF GAS-MCF WATER-BBL WATER-BBL ICHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (cor¢i CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or w ate r. Submit core c hipsR. E NO CORES TAKEN Alaska 0il & Gas Cons. Anchorage Form 10-407 Submit in duplicate// Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME KA MA NA NE OA OB GEOLOGICMARKE i: 3637 4343 4557 4924 6106 TRUE VERT. DEPTH ?~3457 il 3689 "3942 4O24 4107 4183 30, -~MATION TESTS Include interval tested, pressure data, ail fluids recovered and gravity, GOR, and time of each phase, 3!. LiST OF ATTACHMENTS DIRECTIONAL DATA, SUMMARY OF OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ~ _'//~~j Title Sr. Drillins Eng. Date 2/24/92 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 supo y 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 inte,vai (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 2!' Indicate whether from ground level (Gl_) or other elevation (DF, KB, etc.). Item 53: Attached supplemental records for this welt should show the details of any multiple stage cement- ing and the location of the cementing toot. Item 27' Method of Operation Flowing, Gas lift, nod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' tf no cores taken, indicate "none" Form I0-407 Milne Point J No. 5 - COMPLETION APl No.: 50-029-22196 11/14/91' Finish moving Nabors 27-E from J-7 to J-5. Spud J-5 at 2300 Hrs on 11/13/91. Drill 17-1/2" hole to 166'. 11/15/91' Drill and Survey from 166' to 1506'. 11/16/91' Drill and survey from 1506' to 2471'. CBU, wiper trip, and circ. & cond. hole. POOH. 11/17/91: R/U and run 59 joints of 13-3/8", 61 Cf/fi, K-55, BTRC casing to 2457' (FS), FC at 2374'. Circ. 500 bbls of mud while reciprocating casing. R/U DP stinger running tools and RIH with DP and stab-in tool and stab-in FC. Pump 130 bbls water spacer and test lines to 3000 psi - OK. Mix and pump 575.6 bbls (1600 sx) Permafrost 'E' cement with 5 Cf/sk Gilsonite at 12.3 PPG, mix and pump 51.2 bbls (250 sx) with additives at 15.8 PPG, and displace with 38 bbls of mud. Bump plug with 1500 psi. POOH with DP stinger. N/D diverter system and make rough cut on 13- 3/8" casing. 11/18/91: Make final cut on 13-3/8". Preheat casing and spool. Weld on 13-3/8" head, post heat and test to 500 psi - OK. Test weld to 1000 psi for 15 min. after cooling - OK. N/U BOP's and test to 500/3000 psig - OK. L/D 19 stands of G DP. P/U 12-1/4" BHA and · 11/19/91: TIH to FC at 2373'. Test casing to 1200 psi for 30 min. - OK. Drill FC, FS, and 10 formation to 2481'. Circ. and Cond. mud. Perform LOT to 11.8 PPG with 9.1 PPG mud. Drill and survey from 2481' to 3741'. Short trip to shoe - no hole problems. Drill and survey from 3741' to 4149' (49 o). 11/20/91' Drill and survey from 4149' to 4900' MD (85.9°)/4100' TVD - TD of 12-1/4" hole section. CBU. Make wiper trip to shoe - no hole problems. Circ. and Cond. mud. POOH. 11/21/91: Run 56 joints of 9-5/8", 47 Cf/fi, N-80 BTRC casing to 13-3/8" casing shoe. Circulate at shoe to condition mud for cementing. Finish running same casing to 4891' MD (FS), FC at 4884' MD. Land casing and circ. 1.5 casing volumes. R/U Halliburton and test lines to 3000 psi- OK. Pump 50 bbls Halliburton Dual Spacer at 11.0 PPG, 50 bbls water, mix & pump 121 bbls (586 sx) "Latex 2000" cement with additives at 15.8 PPG, 10 bbls (48 sx) "Latex 2000" cement with additives at 16.5 PPG, and displaced with 355 bbls of 10.6 PPG mud with full returns. Bumped plug RECEIVED Alaska 0il & Gas Cons. Anch0rag¢ with 1500 psi. Set pack-off and test to 5000 psi - OK. R/U Schlumberger and run AMS-CCL-GR (temperature) Icg. 11/22/91: Run GR-GCT (Gyro) Icg for run #2. P/U 8-1/2" motor BHA and TIH to FC. Test 9-5/8" casing to 1500 psi for 30 min. - OK. Drill float equipment and 10' of new formation. Circ. and Cond. mud. Perform LOT to 13.3 PPGe. Displace mud with 10.6 PPG size salt system. Drill and survey from 4910' to 5607'. Short trip - no hole problems. Drill and survey from 5607' to 5667'. 11/23/91: Drill and survey from 5667' to 5920'. Short trip to 9-5/8" casing shoe - no hole problems. Drill and survey from 5920' to 6300'. Mud weight decreased from 10.6 PPG to __ 10.3 PPG (aeration). Pull into 9-5/8" casing shoe and condition mud. TIH and drill and survey from 6300' to 6648' - TD. Circ. and Cond. mud. 11/24/91: Short trip to 9-5/8" shoe - no hole problems. Circ. and Cond. mud at T.D. POOH with BHA. Released rig from Drilling AFE No. 1406 to Completion AFE No. 1407 at 0600 hrs on 11/23/91. Above cost reflects AFE 1406 total. ************************************ 11/24/91: Accepted rig to AFE 1407 at 0600 Hrs on 11/23/91. P/U 9-5/8" scrapers and TIH to 4720'. Displace casing with a 10.6 PPG brine system. POOH and L/D scrapers. R/U Weatherford and M/U & RIH with 26 joints of 6-5/8" X 4-1/2" pre-packed screen and 11 joints of 4-1/2" blank pipe with X-nipple. 11/25/91: Finish RIH with pre-packed screen. P/U 2-3/8" washpipe and run inside screen. RIH with screen on 5" DP to 4700' (9-5/8" shoe). Break circ. at shoe. RIH to 6404' - stuck pipe. Spot XC pill and attempt to work pipe - unsuccessful. Cannot move pipe but can circulate. 11/26/91: R/U hot oil truck and test lines to 2000 psi. Pump 100 bbls 8.5 PPG brine at 190°, 50 bbls Lithium Hypochlorite (bleach), and 75 bbls of 8.5 PPG brine at 190°. Pump a 50 bbl 10% HCI acid solution and displace with brine to the screen while working pipe. Pipe pulled free as acid was circulated. RIH with pre- packed screen and set at 6638'. Treat open hole with brine/bleach solutions. Spot 75 bbls of bleach across open · hole. R/U Schlumberger and run GR-CCL to confirm screen top at 4799'. Treat open hole with 10% HCI acid solution. 11/27/91: Finished acid treatment of open hole. Drop ball and shear release from GP liner from R/T. POOH and L/D washpipe. Test BOP's. M/U Baker sump packer assembly and RIH with same. R/U Schlumberger and run correlation Icg for depth verification. Set sump packer with 2500 psi at 4616' MD. Test backside to 500 psi for 10 min. - OK. Pull R/T out of packer and reverse circulate to retrieve ball- no ball. 11/28/91: Mix & filter brine. P/U 6-5/8" perf guns and RIH to 4605'. R/U Schlumberger and run correlation Icg. Set packer at 4310' and test same - OK. Displace DP with diesel and fire guns. Perforate at 12 SPF with 45 ° phasing from 4378' - 4605'. Flow back 27 bbls of fluid/gas to surface. Reverse oil out and monitor well. POOH and L/D perf string. 11/29/91: M/U seal assembly with washpipe below for clean-out. TIH to 4616'. Reverse circ. 16' above packer. Test disc to 500# - OK. POOH and L/D assembly. P/U 261' of 5-1/2" GP screen and 240' blank pipe and TIH to 4230'. Monitor well. 11/30/91: R/U Dowell. Finish RIH to 4615' - tag fill. Attempt to circ. and work through fill- not successful. POOH with GP screen assembly. M/U seal assembly and 15' stinger for clean-out. TIH to 4601' - tag fill. Circ. and rotate through sand bridge and stab into sump packer at 4616'. Test disc - OK. POOH and L/D assembly. P/U GP screen assembly. 12/01/91: RIH with GP assembly and stab into sump packer. Set GP packer at 4078'. R/U Dowell and GP as per procedure. Pumped away 9800# of sand. Reverse circ. and test pack - OK. POOH and L/D GP tool. M/U GP isolation assembly and TIH. Isolate GP assembly, J-out of washpipe and POOH. P/U 2-3/8" flush joint tubing. 12/02/91: TIH with tubing and tag fill at 4620'. Reverse circ. from 4620' to 4752' (disc), break disc. POOH and L/D 2-3/8" tubing. P/U isolation assembly retrieving tool and TIH. Attempt to J-into string - not successful. POOH with tool and P/U spear. TIH and spear isolation assembly and POOH and L/D same. Prepare to run 2-7/8" tubing and pump. 12/02/91: P/U ESP pump and heat wrap 2-7/8" tubing and RIH. Land tubing hanger and R/U ESP and heat wrap tubing outer surface connections. Displace 8.5 PPG brine with brine/methanol mixture. 12/03/91: Finish displacing well with brine/methanol mixture. Install BPV and N/D BOP's. N/U tree and test same - OK. Freeze protect tubing. Release rig from AFE Cf 10-61-1407 at 10:00 hrs on 12/03/91. Moving to well MPU J-7. SUB - S URFA CE DIRECTIONAL SURVEY ~-~ UIDANCE r'fl OOL 9ate ~.~1~C10_.~_ RECEIVED JAN 1"; 1992 Alaska Oil & Gas Cons. Commission Anchorage Company Well Name CONOCO INC. MPU J-5 (2988'FNL~3167'FEL~SEC 28tT13N,R10E/ Field/Location SCHRADER BLUFF, NORTH SLOPE, ALASKA Job Reference No. 75337 Locjcjed BV: T. WEST Date 21-NOV-1991 Computed By; R. KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMEg ' ISTING FOR CONOCO INC. MILNE POINT UNIT d-5 SCHRADER BLUFF NORTH SLOPE, ALASKA SURVEY DATE: 21-NOV-1991 METHODS OF COMPUTATION TOOL LOCAT[ON: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- LINEAR HORIZ. DIST. ENGINEER: T. WEST Averaged deviation PROJECTED ONTO A ~nd azimuth TARGET AZIMUTH OF NORTH 49 DEG 59 MIN EAST COMPUTATION DATE: 12-JAN-92 PAGE 1 CONOCO INC. MILNE POINT UNIT J-5 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 21-NOV-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 100.00 100 200.00 200 300.00 299 400.00 399 500.00 499 600.00 599 700.00 699 800.00 799 900.00 899 0 O0 -70 20 0 0 N 0 0 E O0 29 O0 129 99 229 99 329 99 429 98 529 97 629 97 729 96 829 80 0 19 N 69 46 E 8O 0 16 N 85 36 E 79 0 28 S 86 22 E 79 0 33 N 85 9 E 79 0 29 N 68 4 E 78 0 37 S 90 0 E 77 0 43 N 79 2 E 77 0 40 N 76 42 E 76 0 50 N 89 50 5 0 O0 0 64 1 04 1 53 2 19 2 99 3 75 5 76 6 8C~ 0 O0 0 08 0 48 0 04 0 06 0 2,4 0 08 0 36 0 O0 0 08 0.00 0.17 0.3O 0.29 0.28 0.50 0.63 0.68 0.96 ~,.04 0 O0 E 0 69 E 1 10 E 1 75 E 2 63 E 3 49 E 4 37 E 5 57 E 6 71 E 8 O0 E 0 O0 N 0 0 E 71 N 75 49 E 14 N 74 38 E 78 N 80 45 E 64 N 83 56 E 52 N 81 47 E 41 N 81 44 E 62 N 83 1E 78 N 81 50 E 07 N 82 36 E 1000.00 999.95 929.75 1 9 N 85 40 E 1100.00 1099.91 1029.71 1 41 N 80 49 E 1200.00 1199.84 1129.64 2 53 N 61 19 E 1300.00 1299.48 1229.28 6 58 N 42 57 E 1400.00 1398.46 1328.26 8 52 N 44 43 E 1500.00 1497.20 1427.00 9 17 N 47 15 E 1600.00 1595.89 1525.69 9 25 N 48 37 E 1700.00 1694.40 1624.20 10 25 N 48 29 E 1800.00 1792.69 1722.49 10 38 N 48 46 E 103 1900.00 1890.83 1820.63 12 10 N 46 49 E 122 8 08 10 15 13 64 21 78 35 93 51 71 67 81 85 01 41 60 061 0 49 2 72 3 79 081 0 37 0 89 0 55 0 07 4 17 1 08 N 1 39 N 12 2 56 N 15 8 05 N 21 18 34 N 31 29 28 N 42 4O O3 N 54 51 43 N 67 63 60 N 81 76 45 N 95 9 65 E 9.7t N 83 38 E 08 E 12.16 N 83 26 E 66 E 15.86 N 80 43 E 68 E 23.13 N 69 37 E 51 E 36.46 N 59 48 E 94 E 51.97 N 55 43 E 94 E 67.97 N 53 55 E 82 E 85.11 N 52 50 E 63 E 103.48 N 52 5 E 90 E 122.64 N 51 26 E 2000.00 1987.55 1917 35 16 48 N 44 1 E 147,79 2100.00 2082.61 2012 41 19 8 N 43 58 E 178.64 2200.00 2176.68 2106 48 20 21 N 44 47 E 212.37 2300.00 2270 05 2199 85 21 47 N 46 20 E 248.07 2400.00 2362 13 2291 93 24 11 N 47 43 E 286.99 2500.00 2452 94 2382 74 24 57 N 48 38 E 328.84 2600.00 2543 49 2473 29 25 22 N 50 49 E 37;.29 2700.00 2633 44 2563 24 26 51 N 51 34 E 414.96 2800.00 2722 03 2651.83 28 16 N 53 1 E 461.29 2900.00 2810 31 2740.11 27 31 N 49 46 E 508.21 3 O6 1 98 1 18 2 O6 2 29 0 18 1 80 0 78 2 08 94 25 N 113 84 E 147 79 N 50 23 E 116 140 166 192 22O 247 275 3O3 332 62 N 135 85 N 159 O0 N 184 45 N 213 36 N 244 94 N 276 29 N 310 59 N 347 37 N 384 33 E 178 O3 E 212 55 E 248 16 E 287 37 E 329 64 E 371 70 E 415 42 E 461 53 E 508 65 N 49 15 E 44 N 48 28 E 22 N 48 2 E 18 N 47 55 E 05 N 47 57 E 48 N 48 8 E 11 N 48 27 E 38 N 48 51 E 27 N 49 10 E 3000.00 2898.98 2828.78 27 42 N 47 2 E 554 43 3100.00 2987.53 2917.33 27 46 N 48 43 E 600 85 3200.00 3076.74 3006.54 26 12 N 47 50 E 646 3300.00 3166.34 3096.14 26 31 N 47 53 E 690 3400.00 3255.51 3185.31 27 24 N 49 6 E 735 3500.00 3343.25 3273.05 30 17 N 47 59 E 783 3600.00 3428.23 3358.03 32 53 N 49 48 E 836 3700.00 3511.23 3441.03 35 20 N 51 21 E 892 3800.00 3591.03 3520.83 38 32 N 51 57 E 952 3900.00 3667.49 3597.29 41 26 N 53 16 E 1016.59 02 38 63 56 25 01 22 0 50 0 50 0 47 0 93 1 67 4 13 2 O0 3 64 3 10 2 46 363.23 N 418.97 E 554.50 N 49 5 E 394.40 N 453.41 E 600.94 N 48 59 E 424.35 N 487.25 E 646.13 N 48 57 E 454.25 N 520.06 E 690.51 N 48 52 E 484 22 N 553 99 E 735.78 N 48 51 E 516 13 N 589 78 E 783.73 N 48 49 E 550 72 N 629 53 E 836.42 N 48 49 E 586 O1 N 672 71 E 892.16 N 48 56 E 623 52 N 719 84 E 952.34 N 49 6 E 662 67 N 771 01 E 1016.66 N 49 19 E CONOCO INC. MILNE POINT UNIT J-5 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 12-JAN-92 PAGE 2 DATE OF SURVEY: 21-NOV-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG 'RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WES7 DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4000.00 3740 51 3670.31 44 44 4100.00 3810 4200.00 3874 4300.00 3924 4400.00 3967 4500.00 4006 4600.00 4040 4700.00 4067 4800.00 4088 4900.00 4105 24 3740.04 46 50 04 3803.84 55 15 36 3854.16 63 12 65 3897,45 66 2 35 3936.15 67 44 34 3970.14 72 40 O~ 3996.88 76 15 27 4018.07 78 51 83 4035.63 81 0 5000.00 4117.30 4047.10 86 57 5100.00 4120.93 4050.73 88 26 5200.00 4123.34 4053.14 87 40 5300.00 4130.14 4059.94 85 18 5400.00 4138.01 4067.81 86 51 5500.00 4140.69 4070.49 88 48 5600.00 4143.77 4073.57 86 35 5700.00 4151.60 4081.40 84 55 5800.00 4161.23 4091.03 84 7 5900.00 4171.15 4100.95 85 11 6000 O0 4177.85 4107.65 86 9 6100 O0 4184.52 4114.32 86 8 6200 O0 4191.45 4121.25 87 4 6300 O0 4195.52 4125.32 87 54 6400 O0 4197.85 4127.65 89 1 6500 O0 4199.59 4129.39 89 0 6600 O0 4201.34 4131.14 89 0 6648 O0 4202.18 4131.98 89 0 N 54 10 E 1084 74 N 55 14 E 1156 N 55 31 E 1232 N 53 20 E 1318 N 49 41 E 1408 N 50 56 E 1500 N 48 28 E 1594 N 48 57 E 169~ N 49 3 E 1788 N 49 20 E 1887 15 7O 68 78 98 92 23 9,~ 37 N 52 30 E t986 62 N 52 24 E 2086 N 50 29 E 2186 N 49 50 E 2286 N 49 28 E 2385 N 49 13 E 2485 N 49 47 E 2585 N 49 1 E 2685 N 48 56 E 2784 N 49 53 E 2884 i45 38 13 81 75 69 37 90 37 N 50 45 E 2984 13 N 48 38 E 3083 89 N 50 24 E 3183 64 N 51 7 E 3283 55 N 51 41 E 3383 49 N 51 42 E 3483 43 N 51 42 E 3583 37 N 51 42 E 3631 34 2 57 2 62 11 54 5 26 4 74 3 39 5 98 4 41 1 79 2 64 9 83 1 78 4 54 1 93 5 62 1 21 5 6O 2 7O 1 .78 4.26 5.96 1 .61 4.01 2.24 1.19 0.00 0.00 0.00 703 14 N 826 03 E 1084 77 N 49 36 E 744 788 837 894 953 1014 1078 114! 1206 41 N 884 17 N 947 75 N 1018 40 N 1088 39 N 1159 41N 1230 14 N 1303 74 N 1377 10 N !451 62 E 1156 82 E 1232 46 E 1318 54 E 1408 40 E 150~ 84 E 1594 08 E ~691 27 E 1788 75 E t887 16 N 49 55 E 71 N 50 15 E 74 N 50 34 E 85 N 50 36 E 06 N 50 34 E 99 N 50 3O E 28 N 50 24 E 98 N 50 21 E 39 N 50 17 E 1268.93 N 1528 60 E 1986 65 N 50 18 E 1329.66 N 1607 1391.89 N 1686 1455.43 N 1763 1520.31 N 1838 1585.83 N 1914 1650.70 N 1990 1714.91 N 2066 1780'.06 N 2141 1845.85 N 2216 95 E 2086 18 E 2186 08 E 2286 76 E 2385 25 E 2485 28 E 2585 53 E 2685 78 E 2784 42 E 2884 5O N 5O 25 E 45 N 50 28 E 21 N 50 28 E 87 N 50 25 E 80 N 50 22 E 73 N 50 20 E 42 N 50 19 E 93 N 50 16 E 39 N 50 13 E 1910.35 N 2292 54 E 2984 15 N 50 12 E 1975.45 N 2368 14 E 3083 91 N 50 10 E 2040.05 N 2444 14 E 3183 65 N 50 9 E 2103.71 N 2521 15 E 3283 57 N 50 9 E 2166,01 N 2599 34 E 3383 51 N 50 12 E 2227.98 N 2677 80 E 3483 46 N 50 14 E 2289.95 N 2756 27 E 3583 41 N 50 17 E 2319.69 N 2793 93 E 3631 39 N 50 18 E CONOCO INC. MILNE POINT UNIT J-5 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 12-JAN-92 PAGE 3 DATE OF SURVEY: 21-NOV-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUI~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -70.20 0 0 N 0 0 E 0.00 1000.00 999 95 929.75 1 9 N 85 40 E 8.08 2000.00 1987 55 1917.35 16 48 N 44 1 E 147.79 3000.00 2898 98 2828.78 27 42 N 47 2 E 554.43 4000.00 3740 51 3670.31 44 44 N 54 10 E 1084.74 5000.00 4117 30 4047.10 86 57 N 52 30 E 1986.62 6000.00 4177 85 4107.65 86 9 N 50 45 E 2984.13 6648.00 4202 18 413~.98 89 0 N 51 42 E 3631.34 0 O0 0.00 N 0.00 E 0.00 N 0 0 E 0 61 ' 1 08 N 9.65 E 9.71 N 83 38 E 3 06 94 25 N 113.84 E 147,79 N 50 23 E 0 50 363 23 N 418.97 E 554.50 N 49 5 E 2 57 703 14 N 826.03 E 1084.77 N 49 36 E 9 83 1268 93 N 1528.60 E 1986,65 N 50 18 E 5 96 1910 35 N 2292.54 E 2984.15 N 50 12 E 0 O0 2319 69 N 2793.93 E 3631.39 N 50 t8 E CONOCO INC. MILNE POINT UNIT J-5 SCHRADER BLUFF NORTH SLOPE, ALASKA COMPUTATION DATE: 12-JAN-92 PAGE 4 DATE OF SURVEY: 21-NOV-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 70 20 70 170 20 170 270 21 270 370 21 370 470 21 470 570.22 570 670.22 67O 770.23 770 870.24 870 0 O0 -70 20 0 0 N 0 0 E 20 0 20 100 20 200 20 300 20 400 20 500 20 600 20 700 20 800 O0 0 19 N 68 2 E O0 0 12 N 73 3 E O0 0 23 S 84 3 E O0 0 32 N 88 57 E O0 0 28 N 70 37 E O0 0 34 N 85 6 E O0 0 44 N 87 43 E O0 0 40 N 75 19 E O0 0 47 S 88 11 E 0 O0 0 47 0 94 1 37 1 97 2 76 351 4 39 5 46 6 48 0 O0 011 0 07 0 22 031 0 09 0 30 0 44 0 35 0 O6 0 O0 N 0 11 N 0 28 N 0 30 N 0 26 N 041 N 0 62 N 0 64 N 0 88 N 1 05 h, 0 O0 E 0 53 E 0 99 E 1 53 E 2 35 E 3 26 E 4 06 E 5.19 E 6.38 E 7.59 E 0.00 N 0 0 E 0.54 N 77 56 E 1 .03 N 73 59 E 1 .56 N 78 48 E 2.36 N 83 34 E 3.28 N 82 45 E 4.11 N 81 17 E 5.22'~ N 83 1 E 6.4,4 N 82 7 E 7.66 N 82 8 E 970.25 970 20 900.00 0 59 N 88 0 E 1070.27 1070 1170.33 1170 1270.54 1270 1371.41 1370 1472.65 1470 1573.96 1570 1675.40 1670 1777.11 1770 1878.93 1870 7.64 20 1000.00 1 32 N 82 7 E 9.44 20 1100.00 2 22 N 69 28 E 12.34 20 1200.00 5 34 N 43 41 E 18.59 20 1300.00 8 37 N 43 54 E 31.60 20 1400.00 9 12 N 46 49 E 47.32 20 1500.00 9 16 N 48 32 E 63.59 20 1600.00 10 13 N 48 23 E 80.60 20 1700.00 10 41 N 48 39 E 99.18 20 1800.00 11 27 N 47 20,E 118.30 0 45 0 64 1 69 491 1 25 0 32 0 22 1 15 0 40 2 85 1.05 N 1.27 N 11 26 E 11 1 .99 N 14 44 E 14 5.70 N 19 48 E 20 15.23 N 28 47 E 32 26.29 N 39 72 E 47 37.24 N 51 77 E ,63 48.50 N 64.52 E 80 60.81 N 78.45 E 99 73.51 N 92.75 E 1 18 9.09 E 9 15 N 83 26 E 33 N 83 34 E 57 N 82 9 E 30 N 73 41 E 29 N 61 51 E 63 N 56 30 E 77 N 54 16 E 72 N 53 4 E 26 N 52 13 E 35 N 51 36 E 1981.91 1970 20 1900.00 16 12 N 44 20 E 142 69 2086.87 2070 20 2000.00 18 53 N 43 57 E 174 37 2193.09 2170 20 2100.00 20 16 N 44 44 E 209 99 2300.17 2270 20 2200.00 21 47 N 46 20 E 248 13 2408.84 2370 20 2300.00 24 23 N 47 46 E 290 61 2519.04 2470 20 2400.00 24'59 N 48 44 E 336 88 2629.58 2570 20 2500.00 25 30 N 51 12 E 383 99 2741.33 2670 20 2600.00 27 30 N 52 17 E 433 84 2854.67 2770 20 2700.00 28 2 N 52 37 E 487 11 2967.51 2870.20 2800.00 27 34 N 47 30 E 539.38 3 61 2 02 1 16 2 06 2 O8 0 46 0 89 1 84 2 38 1 64 90.58 N 110.27 E 142 70 N 50 36 E 113.54 N 132.36 E 174 139.15 N 157.35 E 210 166.04 N 184.59 E 248 194.88 N 215.83 E 290 225.67 N 250.40 E 337 255.93 N 286.51 E 384 286.93 N 325.57 E 433 319.15 N 368.08 E 487 352.99 N 407.91 E 539 38 N 49 23 E 06 N 48 31E 28 N 48 2 E 80 N 47 55 E 09 N 47 58 E 17 N 48 14 E 96 N 48 37 E 17 N 49 4 E 44 N 49 8 E 3080.42 2970.20 2900.00 27 42 N 48 30 E 591.74 3192.72 3070.20 3000.00 26 10 N 47 54 E 642.81 3304.31 3170.20 3100.00 26 34 N 47 54 E 692.31 3416.57 3270.20 3200 O0 27 43 N 48 48 E 743 30 3531.40 3370.20 3300 O0 31 25 N 48 37 E 799 67 3650.22 3470.20 3400 O0 33 47 N 50 53 E 863 82 3773.51 3570.20 3500 O0 37 48 N 51 38 E 935 86 3903.63 3670.20 3600 O0 41 32 N 53 18 E 1019 O0 4042.13 3770.20 3700 O0 45 39 N 54 48 E 1114 54 4193.35 3870.20 3800 O0 54 29 N 55 29 E 1227 29 1.04 0.38 0.94 2.37 3.19 2.73 2.72 2.56 2.39 11.46 388.38 N 446.57 E 591 83 N 48 59 E 422.19 N 484.86 E 642 91 N 48 57 E 455.54 N 521.50 E 692 44 N 48 52 E 489.26 N 559.77 E 743 45 N 48 51 E 526.85 N 601.81 E 799 84 N 48 48 E 568.34 N 650.74 E 863 98 N 48 52 E 613.40 N 706.97 E 935.99 N 49 3 E 664.12 N 772.95 E 1019.07 N 49 20 E 720.50 N 850.36 E 1114.55 N 49 44 E 785.10 N 943.34 E 1227.30 N 50 14 E COMPUTATION DATE: 12-JAN-92 PAGE 5 CONOCO INC. MZLNE POINT UNIT J-5 SCHRADER BLUFF NORTH SLOPE, ALASKA DATE OF SURVEY: 21-NOV-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4406.31 3970.20 3900.00 66 20 N 49 43 E 1414.55 4713.12 4070.20 4000.00 76 45 N 48 52 E 1703.98 5890.08 4170.20 4100.00 84 58 N 49 31 E 2874.49 6648.00 4202.18 4131.98 89 0 N 51 42 E 3631.34 4.73 B98.13 N 1092.95 E 1414.63 N 50 35 E 4.21 1086.49 N 1312.71 E 1704.02 N 50 23 E 4.22 1839.34 N 2209.00 E 2874.52 N 50 13 E 0.00 2319.69 N 2793.93 E 3631.39 N 50 18 E CONOCO INC. MILNE POINT UNIT J-5 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER 13 3/8" CASING (FS) LAST READING GCT MWD TIE IN POINT 9 5/8" PBTD (FC) 9 5/8" CASING (FS) TD COMPUTATION DATE: 12-JAN-92 PAGE 6 DATE OF SURVEY: 21-NOV-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2988' FNL & 3167' FEL, SEC28 T13N RIOE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 2458 O0 4509 74 4524 99 4884 O0 4891 O0 6648 O0 2414.86 2344.66 4010.03 3939.83 4015.66 3945.46 4103.24 4033.04 4104.44 4034.24 4202.18 4131.98 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 208 62 N 959 06 N 968 O9 N 1195 81N 1200 32 N 2319 69 N 231 11 E 1166 42 E 1177 28 E 1439 78 E 1444 99 E 2793 93 E CONOCO INC. MILNE POINT UNIT J-5 SCHRADER BLUFF NORTH SLOPE, ALASKA MARKER 13 3/8" CASING (FS) LAST READING GCT MWD TIE IN POINT 9 5/8" PBTD (FC) 9 5/8" CASING (FS) TD COMPUTATION DATE: 12-JAN-92 PAGE 7 DATE OF SURVEY: 21-NOV-1991 KELLY BUSHING ELEVATION: 70.20 FT ENGINEER: T. WEST ************ STRATIGRAPHIC SUMMARY **********~* SURFACE LOCATION = 2988' FNL & 3167' FEL, SEC28 Tt3N RIOE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 2458 O0 4509 74 4524 99 4884 O0 4B91 O0 6648 O0 2414 86 4010 03 4015 66 4103 24 4104 44 4202 18 2344.66 3939.83 3945.46 4033.04 4034.24 4131.98 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 2O8 62 N 959 06 N 968 09 N 1195 81N 1200 32 N 23t9 69 Ix 231.11 E 1166.42 E 1177.28 E 1439.78 E 1444,99 E 2793.93 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 6648.00 4202.18 4131.98 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 3631.39 N 50 18 E DIRECTIONAL SURVEY COMPANY FIELD COUN'rRY RUN DATE LOQ~ED CONOCO INC. SCHRADER BLUFF MILNE POINT UNIT J-5 USA ONE 21 - NOV - 91 DEPTH UNIT FEET WELL' r~PU J-5 (2988' FNL,3167' FEL,SEC 28,T13N,R10E) HORIZONTAL PROJECTION .................................................................. i..-~.--h--~ ..... i--.~---:---~ ...... :-.-~,--h.-~--- ...:...:...:...: ..... :...~...:...: ...... :...:...:...: ...... :._:..,:...: ...... :...:...:...: ...... :...:...:...: ..... :_.:...:...: ...... :...:,..:...:... :::: :::: :::: ::.: :::: ::;: :::. 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Azimuth i~e Vet. Depth Depth 2401.00 24.40 47.90 2362.35 2438.00 25.09 48.50 2395.95 2502.58 25.30 48.76 2454.39 2597.90 25.50 50.43 2540.49 2691.59 27.00 51.25 2624.52 COORDINt?E 194.66 N 217.91 204.98 N 229.46 223.15 N 250.09 249.64 lq 281.22 275.80 N 313.35 3.02 292.05 1.98 307.53 0.37 335.02 0.78 375.90 ]..65 417.33 2786.18 28.46 52.26 2708.24 2881.54 27.80 49.60 2792.34 2976.42 27.60 46.70 2876.35 3071.60 27.90 47.90 2960.59 3164.9! 26.40 47.10 3043.61 3260.20 26.60 47.70 3128.89 3355.15 27.10 48.20 3213.60 3386.45 27.30 49.30 3241.44 3418.57 27.80 49.10 3269.92 3450.55 28.70 48.10 3298.09 303.04 N 347.92 331.36 N 382.83 360.78 N 415.67 390.83 N 448.24 419.59 N 479.64 448.37 N 510.94 477.09 N 542.78 486.52 N 553.54 496.23 N 564.78 506.24 N 576.14 1.62. 461.32 1.48 506.26 1.44 550.33 0.67 594.60 1.65 637.13 0.35 679.61 0.58 722.47 1.73 736.77 1.58 751.62 3.18 766.76 3482.45 29.80 48.00 3325.92 3512.95 30.90 47.70 3352.24 3544.85 32.00 48.20 3379.46 3576.18 32.50 48.50 3405.95 3608.18 33.10 49.40 3432.85 3639.88 33.60 49.9{) 3459.33 3670.98 34.40 50.60 3485.12 3702.93 35.40 51.40 3511.32 3734.98 36.70 51.00 3537.23 3764.90 37.60 51.30 3561.08 516.66 N 587.73 527.00 N 599.16 538.15 N 611.51 549.26 N 624.01 560.64 R 637.08 571.92N 650.36 583.04 N 663.73 594.55 N 677.94 606.36 N 692.64 617.70 N 706.71 3.45 782.33 3.64 797.73 3.54 814.37 1.68 831.08 2.42 848.41 1.80 865.84 2.86 883.23 3.44 901.50 4.12 920.36 3.07 938.42 3796.86 38.30 52.20 3586.28 3828.88 39.60 51.00 3611.18 3860.28 40.50 52.50 3635.22 3892.51 41.30 53.30 3659.58 3924.03 42.10 53.20 3683.11 3955.91 43.40 53.70 3706.52 3987.58 44.60 54.30 3729.30 4018.43 45.20 54.30 3751.16 4050.48 45.70 55.20 3773.64 4082.55 46.50 54.10 3795.88 629.86 N 722.14 642.37 N 737.92 654.88 N 753.78 667.6ON 770.62. 680.15 N 787.42 2.79 958.07 4.69 978.19 4.20 998.38 2.97 1019.46 2.55 1040.39 693.04 N 804.80 g 4.21 1061.99 705.96 N 822.60 g 4.01 1083.94 718.67 N 840.28 E 1.94 1105.65 731.85 N 858.94 g 2.54 1128.41 745.22H 877.78 E 3.51 1151.44 4114.45 47.10 54.70 3817.72 4146.18 49.40 55.10 3838.84 4178.09 52.40 55.60 3858.96 4210.09 56.40 55.40 3877.59 4242.02 59.30 55.00 3894.58 4272.O0 61.70 53.90 4303.95 63.30 52.40 4334.75 63.80 SO.OO 4366.[~_~0 ~.10 ~398V07 758.76 H 896.69 g 2.33 1174.63 772.37 N 916.06 E 7.31 1198.21 786.44 N 936.43 E 9.48 1222.86 801.18 N 957.86 g 12.51 1248.76 816.61 N 980.06 g 9.14 1275.68 3909.34 831.78 N 1001.29 E 8.62 1301.69 3924.09 848.78 }I 1023.96 E 6.51 1329.98 3937.81 866.06 N 1045.45 E 7.16 1357.55 ~ ~~066.96 g L21~1385.82 3964~903.64 N 1088~56~ .... ~.32 1414.73 4429.85 67.00 47.40 4461.63 67.40 48.20 4493.05 67.70 48.90 4524.99 68.80 49.80 4556.39 70.30 49.50 4587.34 72.10 48.30 4618.31 73.50 48.70 4649.43 74.50 48.00 3977.69 923.34 N 1110.01 g 3.79 1443.82 3990.01 943.01 N 1131.71 g 2.64 1473.10 4002.01 962.24 N 1153.48 E 2.27 1502.13 4013.84 981.56 N 1175.99 g 4.32 1531.79 4024.81 1000.61 N 1198.41 g 4.86 1561.21 4034.79 1019.87 M 1221).48 E 6.88 1590.50 4043.94 1039.47 N 12.42.64 E 4.68 1620.08 4052.52 1059.35 N I264.99 E 3.87 1649.98 ~easm:~ Depth 4681.28 4711.54 4743.46 4774.25 4805.55 ~CO ~. ~ ~ Page3 ~ PODiT,J5 Yom: :e~: 8.5' !~ b"OR~'gS lllUIE POII~,~I~ SI~P~.,~ Last z'evLsed: 23-tlov-~1 IIIcLLI1. L~imRh ~'~,Ver~. RECTAIIGULAR l)oole~ Vet COORDrS ES Sect 75.50 49.20 4060.77 1079.70 N 1288.07 E 4.81 1680.73 76.70 48.80 4068.04 1098.97 N 1310.24 g 4.17 1710.10 77.70 50.10 4075.11 1119.20 N 1333.89 !: 5.06 1741.23 78.60 49.30 4081.43 1138.69 N 1356.87 E 3.87 1771.36 78.90 49.00 4087.54 1/58.77 If 1380.09 g 1.34 1802.06 4830.00 79.40 49.20 4092.14 1174.49 N 1398.24 E 2.20 1826.06 4891.42 80.80 49.10 4102.70 1214.07 N 1444.01 g 2.28 1886.56 4921.32 81.50 49.90 4107.30 1233.26 R 1466.47 E 3.53 1916.10 4953.28 83.00 50.20 4LLI..61 1253.59 N 1490.75 E 4.78 1947.77 4985.28 85.80 52.60 4114.73 1273.45 N .1.5.1.5.64 g 11.50 1979.60 5017.10 5048.90 5080.41 5112.28 5143.95 5174.77 5206.82 5240.00 5269.95 5301.85 5333.74 5365.20 5397.50 5429.00 5461.40 5491.38 5523.34 5554.16 5585.59 5617.48 5649.38 5681.16 5712.58 5744.50 5775.92 88.30 52.40 4116.37 1292.80 Ii 1540.84 g 7.88 2011.35 87.90 52.70 4117.42 1312.12 R 1566.08 g 1.57 2043.10 88.00 52.70 4118.55 1331.20 N 1591.12 g 0.32 2074.55 88.70 52.20 4119.47 1350.62 Ii 1616.38 E 2.70 2106.38 89.43 51.30 4119.98 1370.22 ii 1641.25 g 3.66 2138.03 88.30 51.50 4120.60 1389.45 N 1665.33 E 3.72 2168.84 87.50 50.20 41_~1.77 1409.67 N 1690.17 g 1.76 2200.86 86.10 50.80 4123.62 1430.74 N 1715.73 g 4.59 2233.98 85.30 50.40 4125.87 1149.70 Ii 1738.81 g 2.98 2263.85 85.30 49.80 4128.48 1470.09 H 1763.20 E 1.87 2295.64 85.40 49.00 4131.t:)7 1490.77 Ii 1787.33 i: 2.52 2327.42 84.90 49.50 4133.73 1511.24 11 1811.08 g 2.24 2358.77 86.70 49.50 4136.09 1532.16 Ii 1835.57 g 5.57 2390.98 88.60 49.00 4137.38 1552.70 N 1859.42 g 6.24 2422.45 88.90 48.80 4L38.09 L~73.9~ N 1883.82 g 1.11 2154.84 88.80 49.00 4138.69 1593.70 Ii 1906.41 g 0.74 2484.80 88.~0 49.80 4139.36 1614.49 Ii 1930.67 g 2.50 2516.76 88.80 49.50 4140.01 1634.44 N 1954.16 E 0.97 2547.57 87.30 49.20 4141.08 1654.90 Ii 1977.99 E 4.87 2578.98 85.70 50.50 4143.02 1675.43 N 2002.32 E 6.46 2610.81 85.40 50.30 4145.50 1695.70 N 2026.82 E- 1.13 2642.61 85.10 49.50 4148.13 1716.10 N 2051.05 g 2.68 2674.28 84.80 48.70 4150.90 1736.59 ii 2074.70 E 2.71 2705.57 84.50 49.20 4153.87 1757.46 N 2098.67 g 1.82 2737.35 84.20 49.40 4156.97 1777.85 Ii 2122.37 g 1.14 2768.61 5806.87 84.10 48.80 4160.12 1798.01 Ii 2145.65 g 1.96 2799.40 5837.48 83.80 47.60 4163.35 1818.30 Ii 2168.34 g 4.02 2829.82 5900.44 85.20 49.90 4169.38 1859.62 N 2215.45 g 4.26 2892.47 5930.70 86.40 49.60 4171.60 1879.11ii 2238.48 E 4.09 2922.65 5962.62 86.40 49.00 4173.60 1899.89 Ii 2262.64 E 1.88 2954.50 5993.40 6024.70 6O56.6O 6120.45 6151.73 86.20 51.00 4175.59 1919.63 Ii 2286.16 g 6.52 2985.22 86.00 49.80 4177.72 1939.54 Ii 2310.23 g 3.88 3016.45 86.40 48.70 '4179.83 1960.31 Ii 2334.34 g 3.66 3048.27 86.00 48.60 4184.06 2002.40 N 2382.16 g 0.64 3111.96 85.20 50.10 4186.46 2022.72 Ii 2105.83 g 5.42 3143.15 6340.84 88.60 51.60 4195.01 2142.68 i 2551.73 g 2.43 3332.03 6369.82 89.20 51.40 4195.57 2160.72 N 2574.41 g 2.18 3360.99 6401.53 89.00 51.70 4196.06 2180.43 Ii 2599.24 g 1.14 3392.69 6183.72 86.40 50.20 4188.81 2043.16 R 2430.32 g 3.76 3175.05 6215.67 87.70 50.60 4190.45 2063.50N 2454.90 g 4.26 3206.96 6247.54 87.70 49.80 4191.73 2083.88 N 2479.37 g 2.51 3238.80 6278.04 87.90 50.70 4192.90 2103.37 R 2502.80 E 3.02 3269.28 6309.53 87.90 51.30 4194.05 2123.18 S 2527.26 E 1.90 3300.74 ~.asur~d Xaclia. Afimutb true reft. pth 6t33.15 ~. 70 1~.70 11~6.70 6465.~ 88.50 49.~ 4197.48 6496.~ 89.30 ~.50 4198.08 6559.80 89.30 49.~ 4~98.85 6595.~ 89.~ 49.~ 1~.38 6648.~ 88.50 49.~ 42~.53 ¥o~ z~f: 8.5 !~ ~$ last z~vis~l: 23-11ov-91 RECTANGULARDeg~~ Vert COORDIHATES Ft Sect 2200.45 N 2623.70 E 6.39 3424.30 2221.01 N 2648.02 E 0.89 3456.14 2240.92 N 2671.92 E 3.21 3487.24 2281.85 N 2720.70 g 1.57 3550.92 2304.83 N 2747.36 E 1.66 3586.12 2339.59 N 2787.36 E 0.94 3639.I0 Extrapolated bottom hole co-ordinate Ail data is in feet unless o~erwise stat~i Coordinates are from slot ~1 and TI~Ds are from rkb. Vertical section is from wellhead on azJ~-th 49.99 dectrees. Calculation uses ~e mini~u~ curva~e ~ethod. L/ SCHLUMBERGER. WELL SERVICES 500 W. INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 :: 626i COMPANY · LOCATION ' ATTENTION · WELL NAME · SERVICES · NO. OF BOXES: JOB NO. ' ADD'L TAPES ' ,,,,, ,,,~ .... ~,c Cf~NqFRVAT~uH COHNISSi 300! PORCUPINE DRIVE s. rtC]' Bi .... '"'-[0NAL ¢"'m/Ev 75337 *SEE A~30VE COM PUTI NG CENTER PRINT CENTER WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · WELL NAME ' SERVICES · NO. OF BOXES: JOB NO. · ADD'L TAPES · NO. OF BOXES' JOB NO. · ADD'L TAPES · WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · SCHLUMBERGER COURIER: DATE DELIVERED: WELL NAME · SERVICES · NO. OF BOXES' JOB NO. · ADD'L TAPES · Aiasl(a 0il & Gas Cons. Commissiof, Anchorage / RECEIVED. BY: P ( ..... ::"~-.'":~ '";?;&&";" ..... ' GEORGE ~, COURIER SERVICE 344-3323 FROM ADDRESS : :: : CITY STATE ZIP SHIPPER : ~ : DATE I:' I TIME TO ADDRESS CITY STATE ZIP ATTENTION PHONE INSTRUCTIONS _ ',~ 24 HOUR CASE NO. COURT DOCUMENTS ~ P/U ]~1' ~B~"] .... ._~ w.!~m~i~E HOUR ONE HOUR $ SAME DAY $ 24 HOUR $ OTHER $ TOTAL $ t DATE t TIME TO: Alaska Oil & Gas Conservation Commission DATE: Attn: ~- T~I..--1-~___,~ 3001 Porcupine Drive Anchorage, AK 99501 Conoco Point J - 5 // TRANS #: December 4, 1991 AK-MF-911127 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to the address printed below, attention Doug McGregor. If you have any problems or questions with this data please call me at 563-3256. We have enjoyed working with you and look forward to future projects. sC,' DougJ~ FEWD Manager ENCLOSED INFORMATION SUMMARY Well J- 5 MD: 1 Blueline Print 1 Folded Sepia TVD: 1 Blueline Print 1 Folded Sepia RECEIYED DEC 0 6 199'1 0ii & Gas Cons. Commission Anchorage 1 LIS Tape Received B &"Alaska Gfi~:Gas,~.xSnservation Commission-Date 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Baroid Company SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725 1-2175 DEC 0 1 1~I Conoco, Inc 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: LJ. nda St arr PLEASE RElY TO SCHLUMBERGER WELLSERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 ATTN: Bernie/Shelley Gentlemen: Enclosed are 3 BLprints of the Depth Determination Log, Run_l.=3, 11/25/91 Company Conoco, Inc Well Milne Point Unit J-5 Field MJlne Point/Schrader Bluff Additional prints ore being sent to: 1 BL prints Conoco~ Inc 600 North Dairy Ashford Houston, TX 77079 Attn: Georg~ Lamb, OF 2018 PER County North Slope State Alaska 1 BL prints, 1 RF Sepia Chevron U.S.A. on: 11111 South Wi]crest Houston, TX 77099 ATTN: Michael Quinn ~(713/561-3673) 1 BL prints Conoco, Inc 1000 Soutk Pine Ponco City, OK 74603 Attn: Glenn Welch, 7360 RDW A/la~ka 0il & Gas Conservation f Commission 3001 Porcupine Drive \Anchorage.: AK 99501// prints 1 BL prints, 1 RF Sepia OXY U.S.A. Inc 6 Damta DrJv~_~ guJt~_ 6002 Mid]and, TX 797G5 Attn: .]ohn Carra] *(gl ~/~5-5898) __prints prints The film is returned to Conoco, Linda Starr We appreciate the privilege of serving you. - /?/= Very truly yours, SCHLUMBERGER WELL SERVICES SwS-- 1327-F OH/CH (ltBL/3RF) Raymond N. DJckes DISTRICT MANAGER SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOK~Y CORPORATION HOUSTON, TEXAS 77251-2175 Conoco, Inc 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: LJ. nda Starr Gentlemen: [~- .~e~ ~ z Enclosed ore ~ BLprints of the GOT/Temperature-GR, Run 1, 11/21/91 Company C/onoco, Inc %/'Milne Point Unit J-5 Well ~F.J~E RElY TO ~HLUMSERGER WELLS~RWCES Pouch 340069 Prudhoe Bay, AK 99734-0069 ATTN: Bernie/Shelley on: Field Milne Point /Schrader Bluff Additional prints ore being sent to: I BL prints Conoco, Inc 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb, OF 2018 PER 1 BL prints Conoco, Inc 1000 South Pine POtiCO City, ~ '~'-~° Attn: Glenn Welch, 7360 RDW /~ask~Is~i~sC°nservati°~ 3OO1 Porcupine Drive Anchorage.- AK 99501 Attn' 5o~n Bo_v~ ~ t · _ _ prints County, North Slope State A] a.~ka 1 BL prints, 1 RF Sepia Chevron U.S.A. 11111 South Wilcrest Houston, TX 77099 ATTN: Michael Quinn ~(713/561-3673) 1 BL prints, 1 RF Sepia OXY U.S.A. Inc 6 Desta Drive; gu~te 6(]02 MJ diand: TX 7°va= Attn: John Cmrrm] *(~1 5/685-5898) prints Alaska Oil & Gas Cons. Commission prints Anchorage The film is returned to Conoco, Linda Start Received by: Date: We appreciate the privilege of serving you. Very truly yours, SCHLUMBERGER WELL SERVICES Sw~-- 1327-F OH/CU (ll~./3RF) Ra_~fmond N. DJ ckes DISTRICT MANAGER TO: THRU: MEMORANOUM State of Alaska ALASY~A .OIL AND GAS CONSERVATION COMMISSION -L0~ntl[e C.' Sm DATE: Nov. 29, 1991 Com]~lsa%oner/ FILE NO: LG1129- 7 DOC Blair Wondzeli sr Petr Eng TELEPHONE NO: SUBJECT: BOP Test Conoco J-5 Permit 91-95 Milne Point Unit FROM: Louis R Grimaidi~g Petr Inspector Tuesd__ay, November 26 1991 I traveled to Milne Point to witness a BOP test on Nabor's Rig 27-E~ Drilling Well ~J-5~ for Conoco. The test was conducted quite thoroughly with Joe Polya(Conoco Rep) in attendance. The only discrepancy noted being there was not a crossover to fit the floor safety valve to the tubing that was going to be run on the rig's next operation. The tool pusher had one coming and we stood by for 45 minutes until it arrived~ it should be noted that the crew seemed conscientious and willing to perform a good BOP test. Also~ the surrounding location was very clean and orderly. in summary, I witnessed a good BOP test on Nabor's Rig 27-E, We~l · Drilling ~ ~ ~J-5~ in the Milne Point Unit Attachment 02-00lA (Rev. 6/89) 20/11/MEMO1.PM3 ALAS KA OIL AND GAS CONSERVATION COMMI S S ION TO:' Lonnie C. Smith Commissioner FROM: Louis R.Grimaldi Petroleum Inspector DATE: FILE NO: ,~a '~j C ox3 o c o o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Drlg Wkvr Operator Locati on: Drlg contrctr Location (general Housekeeping Reserve pit Sec ~ ~' T /3 /k~ R/~)-~ M 0)~ Well sign Rig MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors Visual Audio BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve TEST: Initial Weekly ~ Other Representative ~_~)~' Casing set ~ ft Rig# ~7-~- Rep ~/~ ACCUMULATOR SYSTEM: Full charge pressure ~/ ~]) ~[3 psig Press after closure / /-2/~Z~) psig Pump incr clos press 200 psig -- min ~ sec Full charge press attained Controls: Master Remote ~ Blind switch cover KELLY AND FLOOR SAFETY VALVES: Upper Kelly Test pressure Test Pressure Lower Kelly ~-- Test pressure ~,~)0~:~ Ball type Z/ Test pressure ~)~ Inside BOP ~ Test pressure ~ ~) ~ ~]) Choke manifold // Test pressure ~ ~)~)~) Number valves ~ 0 ~ Number flanges ~ ~ O~ ~) '"-- Adjustable chokes ~//~' Hydraulically operated choke TEST RESULTS: Failures (~) Test time ~ ~ hfs Repair or replacement of failed equipment to be made within days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/08/91) ALASKA OIL AND GAS CONSERVATION COMMISSION October 30, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Steve Rossberg Senior Drilling Engineer Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Re: Milne Point Unit J-5 Conoco, Inc. Permit No. 91-95 Rev. Sur. Loc. 2988'FNL, 3167'FEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 673'FNL, 409'FEL, Sec. 28, T13N, R10E, UM \ Dear Mr. Rossberg: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated July 19, 1991 are in effect for this revision. irman Alaska Oil~m%d-/Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~) printed on recycled pape, b y O'oD. ,: llSSION ~._...STATE OF ALASKA ALASKA C' 'AND GAS CONSERVATION CO PERMIT TO DRILL la. Type of work Drill ~ Redritl Re-Entry -- Deepen 20 AAC 25.005 lb. Type of well. Exploratory ,~ Stratigraphic Test ~ Service _-- Developement Gas ~ Single Zone .~. Development Oil ~ Multiple Zone El 2. Name of Operator Conoco Inc. 3. Address 3201C Street, #200, Anchorage, AK 99501 4. Location of well at surface 2988' FNL, 3167' FEL,Sec. 28, T13N, RIOE, U.M.,NSB,AK At top of productive interval 1670' FNL, 1597' FEL,Sec. 28, T13N, RIOE 5. Datum Elevation (DF or KB) 70 ' RKB feet 6. Property Designation ADL 25906 7. Unit or property Name Milne Point Unit 8. Well number J-5 10. Field and Pool KRF Schrader Bluff Pool 11. Type Bond (S'%20 ^AC 25.025) Blanket Number 8086-15-54 At total depth 673' FNL, 409' FEL, Sec. 28, T13N, RIOE 12. Distance to nearest property line 4871 feet 13. Distance to nearest well 90' at 1530' M.D. feet 16. To be completed for deviated wells Kickoff depth 1100 feet Maximum hole angle 88 0 9. Approximate spud date November, 1991 14. Number of acres in property 2560 Amount $ 200,000.00 15. Proposed depth (MD and TVD) 6649 feet 17. Anticipated pressure (see 20 AAC 25.035 (eX2)) Maximum surface 1 850 psig At total depth fTVD) 1950 psi§ 18. Casing program size Hole Casing 36" 20" 13-3/8" 17½" 12~." 9-5/8" 8½" 6-3/4" Specifications Weightl Grade I Coup, lng ILength 80' 2379' 4896' 1800' 19. To be completed for Redrill, Re-entry, and Deepen O Present well condition summary Total depth: MD 35' 35' 35' 48~9' ~erations. Setting Depth Top Bottom TVD 1 MD ! TVD 35' I 115' I 35' ! 2414'I 2400' 35' I 4931'I 4130' 4121' ] 6649'I 4230, measured true vertical feet feet Plugs (measured) Quantity of cement (include stage data) +600 sks Type "C" +650 sks "E" 300 sks "G" , _ +500 sks "G" -- , ,. Downsqueeze + 400 -- sks Type "C" 60 barrels, of diesel Effective depth: measured true vertical feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured dep.th True Vertical depth 0C'f 5 Alaska Oil & Gas Cons. Commiss~O 'Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch ~ Diverter Sketch -- Drilling program ~ Drilling fluid program El Time vs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements 21. I hereby certify that the f. oregoing is true and correct to the best of my knowledge ,/,~,~~ R.S. Rossberg Title Sr. Drilling Engineer Date 10/18/91 Signed Commission Use Only Permit Number I APl number _ 1 Approval date 1 See cover letter .~//....'" ~;:;~,,'~"' I 50--~::::~,~' ~-... ,~. 2_. / ~'~" I 7'~ / '~ - ~;;~/ i for other requirements CSn~litions of approval Samples required ~ Yes ~No Mud tog requi,red ~ Yes ,,~No Hydrogen sulfide measures ~ Yes /~No Directional survey required /~ Yes ~ No Required working~_s,,%u_~e for BOP~.~.,~2M; ~ 3M; D 5M; ~ 10M; 'El 15M Other: - by order of Approve' Form 10-401 Rev. 12-1-8~ Submit in triplicate July 1, 1991 Conoco Inc. Suite 200 3201 C Street Anchorage, AK 99503 (907) 564-7600 David W. Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-1433 RE: Milne Point Unit Wells J-5, J-6, J-7 and J-8 Applications for Permit to Drill Dear Mr. Johnston: Attached are the Applications for Permit to Drill (Forms 401 and attachments) requesting approval to drill Milne Point Unit wells J-5, J-6, J-7 and J-8, located in tract 14 of the Milne Point Unit. Well J-5 will be drilled as a horizontal well to continue development of the Schrader Bluff Pool in Tract 14 of the Milne Point Unit. The rig to be utilized to drill these wells is the Nabors Alaska 27-E. Drilling of these wells is scheduled to commence in early August 1991 and continue through mid September 1991. If there are any questions pertaining to these wells please call me at 564-7662 or Steve Bolt at 564-7609. Very truly Yours, J.~L~. Allison Engineer JLA cc: SGB, RSR file Cf 500.21.08 RE'CE:IVED d U L - 8 199_t Alaska Oil & Gas Cons. (;omm~tssiot't ;Anchorage KOP '[V0-1100 T~0-1100 OF_P-O 8UtLO 20EG / tO0' FAOU 0 -- 26.53 OEG _ _ ..... 0 ~NC -C-O_i' ~'"' 0 C -~ '~!'. '- Strucfure : PAD J,5 AJ Field : MILNE POINT UNIT Locotion ' NORTH SLOPE, ALASK ~=,~,- ,~o.® East T'D LOCATION J SEC:. 28. T15N. R10EI TARC~-TLOCA~ON I 1670' F'N~ 1597' FELl SEC. 28. TI3N. RIOE ~ N 49 O£O 59 ~lN E 2050' (TO SURFACE LOCATION 2988' FNL 3167' Fn_.J SEC. 28. T1.ZN. RlCE EOB TVD-2380 TM0--2426 OEP--302 1.3 3/~4:$G PT TVO=2400 'P, aO=244g D~=312 Y, A SNOS ~/D=3487 T~O~$G65 DEP-856 ~A SNOS TVD=3727 ~M0=3963 OEP=lO32 HA SNOSTVO-~975TM0--4369 OEP--1351 --12a3 :tl~-~ '' A Il g AV~P.A~ ANGLf 26.55 DEG KOP ~2 ]','9=3428 ,'I~D=~598 DEP=825 TA,~.GET -- T/OA 5NO"S l~q3=41a-O P./0-5095 DEP~2050 OCT t 5 !~ Alaska 0il .& Gas Cons. 88.2 DEG ~c=!¢ ! ' 16. D_00 Ver'{icci ~eciian on 4g.S9 czimulh with reference 0.00 N, 0.00 E from siruc~,ure cenire CONOCO $1rucluro : ;eld : MILNE POINT UNIT, NORTH SLOPE, ALASKA Well : JSGR Localion : ALASKA -1DO0 -75O -500 --250 0 2~ 50~ 75O tO00 1240 1500 1750 2OO0 2250 250O 275O 30O0 5~5~ ~ 5750 I I I I I I I I I I ! I ! I I I I I I I I i I I I I I I I I I I I I I I I I 4~BOg J I I I I I I I I I I I I I i t I I I I I I I I I I ! I -2800 --2400 -2000 --1600 -1200 --800 --4O0 0 400 ~O0 1200 1600 2000 2400 28~0 .T~.OO 3r~O0 ,,;cole t ' 400.00 v.~a s~,~, ~, ~.sa o,J,~ .~ .~ o.~ ~. o.~ c ~ ~ OOT ~la~ka Oil & Gas Cons, Commission ~,nchorag~ 225O 20OO 1750 1500 1250 1000 750 =~o II o -250 Z o -750 -I00(1 -12~ -1500 -22~ .. '-~ o _ - -27~ PROPOSED MON J--1 NORTH Y 6,015,313-25 X SS1,531.65 N 1700.00 ' E 850.00 PROPOSED PROPOSED O MON J--2 SOUTH EXPANSION Y 6,014,507.26 ' ,,..,,~ .~ X 551,884.66 N 820.00 E 850.00 PI #16 Y= 6,01 4,842.62 X= 552,201.70 POL #15 Y= 6,014,641,12 - X= 552,289.96 MIl_NE POINT UNIT ACCESS ~ ~ ~ . .~ X PRUOHOE MILNE PT. VICINITY MAP O 2, 6 MILES NOTES: 1. STATE PLANE COORDINATES ARE ZONE 4. 2. ALL GEOOETIC POSITIONS ARE BAS'ED ON N.A.D. 1927. 3. OFFSETS TO SECTION UNES ARE COYPU'TED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. Gas Cram. C0rnmissi0n ~,nchorage LEGEND ® EXIS~NG WELL O PROPOSED WELL &~NF~ PROPOSED Loc AT~,g (~,~,,~) WELL DATA LOCATED WITHIN SECTION 28 T. 15 N., R. 10 E., UM1AT MERIDIAN, ALASKA i- N i000.00 i Y 6,0i4,800.50 70' 27' 04.226" 2878' FNL iqq 4-9' 34' J-5 E ii70.00 X 552,i0,~.~4 I 29.550" 5214' FEL d-6 E 1170.00 X 552,i29.61 14-9' 34' 28.835" 3191' FEL E 1170.00 X 552,155.68 14-9' 54' 28.159" 5167' FEL i , N 820.00 I Y 6,0~4,655.64 70' 27' 02.600" 30'43' FNL ¥ J-8 E 1~0.00t x ss:.177.~s 14~' z4' ~7.44~" ~4~' i - - PROPOSED PROPOSED PROPOSED PROPOSED PROPOc:m WEI L SU~VC'VFn ALASKA OIL AND GAS CONSERVATION COMMISSION July 19, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 27g~1433 TELECOPY: (907) 276-7542 Steve Rossberg Senior Drilling Engineer Conoco Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Re: Milne Point Unit J-5 Conoco, Inc. Permit No. 91-95 Sur. Loc. 2878'FNL, 3214'FEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 169'FSL, l134'FEL, Sec. 21, T13N, R10E, UM Dear Mr. Rossberg: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. David W. J~hnst~n, Chairman Alaska Oil ~h~as Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, 'Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS,I~%OIL AND GAS CO,' S~ERVATIOh'-~OMMISSION PERMIT 'lO DRIL 20 AAC 25.005 la. Type of work Drill X-_ Redrill --I lb. Type of well. Exploratory ~' Stratigraphic Test ~ Development Oil Re-Entry -- Deepenf--I Service -- Developement Gas ~ Single Zone X; Multiple Zone 2. Name of Operator Conoco Inc. 5. Datum Elevation (DF or KB) KB 35'AGL feet 3. Address 3201 "C" Street Suite 200 Anchorage, AK 99503 4. Location of well at surface 2,878'FNL, 3214'FEL, Sec.28, T13N, R10E, U.H., NSB AK At top of productive interval 1,659'FNL, 2,382'FEL, Sec. 28, T13N, R10E At total depth 169'FSL, 1,134'FEL, Sec. 21, T13N, R10E 12. Distance to nearest property line 4,146 feet 16. To be completed for deviated wells Kickoff depth 1,100 feet Maximum hole angle 18. Casing program size Hole Casing 30" 20" 17-1/2" 13,3/8" 12-1/4" 9-5/8" . 8-1/2" 4-3/4" 19. TO be completed Present well condition summary Total depth: measured true vertical 13. Distance to nearest well 48 feet 6. Property Designation ADL 25906 7. Unit or property Name Milnc point Unit 8. Well number 9. Approximate spud date November 1991 14. Number of acres in property 2,560 10. Field and Pool Kuparuk Field Schrader Bluff Poo~ 11. Type Bond(see20AAC25.025) Blanket Number 8086-15-54 Amount ~200,000.00 15. Proposed depth (MD and TVD) ;,676'MD 4, 213TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1,850 psig At total depth frVD) 1 ,950 psig Setting Depth Specifications Top Weight !GradelCoupling [Length MD ! ] I i : Pre-Pacl: I I 4,750' Screen ! t I?¢- /¢ for Redrill, Re-entry, and Deepen Operatid'ns. ,/4 Bottom VD I I TVO , I , 00, feet Plugs (measured) feet Quantity of cement (include stage data) ..... i-+600 Sacks Permafrost "C" -+650 Sacks "E":300 Sac_.k_s "G'_! -+?Df~ gar~l~.~ "¢." ~ Horizontal Open-Hole w~th Pre-Pack Screen. Down squeeze ~400 Sacks Permafrost "6" 60 barrels diesel Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True Vertica! depth RECEIVED measured true vertical P I TSKETCH 20. Attachments Filing fee I~ Property plat,~ BOP Sketch I% Diverter Sketch .~. Drilling program X~ Drilling fluid program I~ Time vs depth plot lit Refraction analysis [] Seabed report i~ 20 AAC 25.050 requirements 21. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~/~'~ R.S. RossbergTitle Senior Drillin~ Engineer Commission Use Only Permit Number ! APlnumber IApprovaldate I See cover letter ¢/~ .~ 50-- O.~-- ~'--,' ~ p__,/7 ~'~" 0 '~ -" 1 ~; --'¢ / for other requirements Conditions of approval Samples requir~ed ~ Yes ~No Mud log required. E'] Yes ~ No Hydrogen sulfide measures ~ Yes ,];~No Directional survey required "~ryes ,~ No Required working' pressure for BOPE~ 1~,2M; [] 3M; [] 5M; [] 10M; []'~ 15M Ct h er: '---"~~ ~-'~~¢'~, by order of Approve~~ ~__~[~_[_~,~~ Commissioner' ' the commission Form 10-401 Rev. Date6/28/91 ~ubr~t 'ihQ;iDlicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT J-5 Horizontal Conoco Inc. 3201 C Street, Suite 200 Anchorage, Ak 99503-3992 I. Casing and Cementing Program CASING PROGRAM Hole Size Casing Size Depth Weight Grade (Inches) (Inches) (ft) (pDf) Conn 30" 20" 115' 94 ppf K-55 WELD 17-1/2" 13-3/8" 2,479' 54.5 ppf K-55 BTTS 12-1/4" 9-5/8" 4,800' 36 ppf L-80 BTTS 8-1/2" lateral 4-3/4" 6,676' Pre-packed liner. Al The 20" conductor will be set at 80' below ground level then cemented to the surface with +600 sacks Permafrost type "C". Be The 13-3/8" surface casing will be set approximately 500' below the base of the permafrost at 2,479' MD/2,400' TVD and cemented to surface. The cement slurry will consist of a lead slurry of approximately 650 sacks Permafrost Type "E" followed by a class "G" tail of approximately 300 sacks. A top job utilizing Permfrost Type "C" cement will be performed if cement is not circulated to surface. Ce The 9-5/8" intermediate casing will be set at 4,800' MD/4,121' TVD or approximately 50' past the base of the Schrader Bluff "N" series sands. Class "G" cement (approximately 200 sacks) will be circulated from the 9-5/8" shoe to 500' above the top of the Schrader Bluff "K" series sand. A 8-1/2" horizontal hole will be drilled from 4,800' through the Schrader Bluff "OA" and "OB" series sands to approximately 6,676'MD/4,213' TVD. The well will be completed by running a 4-3/4"wire wrapped screen from the 9-5/8" casing point to T.D. II. A. B. C. D. Drilling Fluid Program 0 - 500' 9.0 ppg freshwater spud mud. 500' - 2,479' 9.0 ppg - 9.2 ppg freshwater spud mud. 2,479' - 4,800' 9.0 ppg - 9.6 ppg dispersed. 4,800' - T D 10.4 ppg - 11.5 ppg Salt Saturated Polymer Brine RE E VED J U L - 8 1 9I ~Ala$~a Oil .& Gas Cons. Commission Anchorage Conoco Inc. Supplemental Data Sheet Well J-5 February 1991 Page 2 III. Drilling Program Conoco Inc. proposes to drill MPU well J-5 as a horizontal well to continue development of the Schrader Bluff Pool in Tract 14 at Milne Point. The mud system will consist of a fresh water spud mud (9.0 - 9.2 ppg) from the surface to the 13-3/8" casing point at approximately 2,479'. A low solids, non-dispersed system (9.2 - 9.6 ppg) will be used from 2,479' to the 9-5/8" casing point at approximately 4,800'. A salt saturated polymer brine will be used to complete the horizontal section of the well. The horizontal section will consist of a 500' lateral in the "OA" sand followed by a drop/build section and a second 500' lateral in the "OB" sand. Plans are to drill a pilot hole to confirm structural interpretation and to ascertain the presence of oil bearing pay in the "CA" and "OB" sands. The bottom portion of the pilot hole will be abandoned according to AOGCC regulations. A kickoff plug will be set at approximately 3,500' and the well side tracked to the horizontal location, which will utilize most of the existing~hole. A complete set of open hole wireline logs will be run from T. D. through the top of the Schrader Bluff interval in the pilot hole. Real time MWD directional, gamma ray and resistivity will be recorded in the sidetrack. Single shot surveys will be taken at the 13-3/8" and 9-5/8" casing points. MWD surveys will be taken every 30' in the horizontal and build sections and every 100' in vertical and tangent sections. A gyro survey will be taken from the 9-5/8" casing point to surface and tied into MWD data in the horizontal section. All surveys will be referenced to the section grid system and corrected for magnetic declination. A 20", 2,000 psig diverter will be installed on the 20" conductor for drilling surface hole. A 13-3/8", 5,000 psi RSRRA BOPE stack will be nippled up to the 13-3/8" surface casing for drilling the intermediate hole. Pressure tests and function tests will be performed on the pressure control equipment as per State Regulations. Maximum downhole pressure is estimated at approximately 1,950 psig and based on initial reservoir pressure. Maximum surface pressure is estimated at 1,850 psig, based on an unexpanded gas bubble with temperature effects not taken into account. The well will be completed with the dri~!jJ~_r, ig. A pre- packed wire wrapped liner with a liner ha~C~w ~~~r will be run from approximately 4,750' to TD. Conoco Inc. Supplemental Data Sheet Well J-5 February 1991 Page 3 An extended production test of the horizontal completion in the "OA" and "OB" sands will be conducted. After testing is complete, the "N" series sands will be completed inside 9-5/8" casing using a wire wrapped screen and gravel packed. The closest wellbore is MPU well J-4 with 48' of closure at 1,200' TVD. Well J-4 will be shut-in and the annulus pressure monitored while drilling this interval. Approximately 400 sacks of Permafrost Type "C" cement displaced with dead crude and/or diesel will be pumped down the 9-5/8" x 13-3/8" annulus for final arctic pack and freeze protection after disposing of excess drilling fluids. WELL PROGNOSIS AND DRILLING PROGRAM TVD MD FORM 500 500 GRAVEL 898 900 SAND/SHALE 2400 2479 CASING PT 3475 3672 K TOP 3710 3969 M TOP 3960 4370 NA TOP~ 4121 4800 CASING PT 4125 4819 OA TOP 4195 5956 OB TOP 4213 6676 T.D. BIT TYPE WT YP PV VISC FL 5-1-5 SPUD 9.0 100 20 100 15 5-1-5 SPUD 9.0 100 20 100 15 5-1-5 SPUD 9.0 25 15 60 15 4-3-7 LSND 9.2 25 15 ~ 60 15 4-3-7 LSND 9.2 15 12 45 8 4-3-7 LSND 9.6 12 8 35 6 4-3-7 LSND 9.6 12 8 35 6 4-3-7 BRN 10.2 12 8 35 6 4-3-7 BRN 10.2 12 8 35 6 4-3-7 BRN 10.2 12 8 35 6 The horizontal section runs from approximately 4,800' to 6,676' T.D. True vertical depths are based on a sub-surface datum. The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. Gas Cons, 6'on~r~isslot~ ~ 3 0 0 0 4 .c: 5 7 Move ~n and Rig Up Conoco Inc. Milne Point Unit Depth VS. Time J-5 Drill 12-1/4' Pilot Hole to 15-3/8' CSG PT. Open tO 17-1/2' and Set 13-3/8' CSG. Plug back and sidetrack Drill Pilot HOle Log Drill tangent and bullcl angle Set 9-5/8' CSG. Drill 'OA' Lateral Drill 'OB' Lateral Days Run and lsat 4-3/4' 13re~packecl screen 20 25 30 o o · ' 200 400 600 800 1000 1600- - 1800- _ 2000- - 2409- _ 2600- 2800- _ - - ~_ _ ~6~ - _ _ 4o~ - 42~- . 44~- 46~- C ONOCO Structure ' Pod J Well · 5 Field ' Milne Point Unit Locofion · North Slope, Alosko IrureOted by : jones For: S ROSSBERO Gte plotted : 1g--Jun--g1 lot Reference is .5 Loterol Version ~,:3. oordinotes ore in feet reference slot ~5. e Verticol Deoths ore refere ..... Ilheod gZ~CHRISTENSEN EASTMAN A ~a~er Hughes compare, . oo.oo Easf 200 400 600 800 1000 1200 1400 16{)0 RKB ELEVATION: 70' N 54 DEG 19 MINE 1476' (TO TARGET) MID OA SNDS LOCATION: I 1100' FNL, 2000' FEL I SEC. 28, TISN, RIOE KOP TVD=llO0 TMD=llO0 DEP=O 3.00 TARGET / NB SNDS LOCATION: I 1659' FNL, 2382' FEL SEC. 28, T13N, RIOE TO LOCATION: 169' FSL, 1134' FEL SEC. 21, T13N, RIOE )~000 2600 ~2200 _ - 2000 A I 9.00 1 5.00 21.00 BUILD 3 OEO/lC, O' EOB TVD=1918 TMD=194-5 OEP=lB4 - g iS 5/8"CSG PT TVD=2400 TM0=2479 OEP=413 AVERAGE ANGLE 25 DEG 22 MIN TD ~/D=4530 TMD=4736 DEP=1043 i i i i t I i i i i i 0 20'0 400 ~ 800 1 Scole 1 ' i00.00 SURFACE LOCATION; I 2878' FNL, 3214' FEL SEC. 28, T15N, RIOE KA SNDS TVD=3475TM0=3672DEP=931 MA SNDS '1A/D=3710 TMD=3969DEP=llll NA SNDS TV0=5960TMD=4-370 DEP=1425 TARGET/ NB SNDS TVD=5990 TMD=4431 DEP=14-76 9 5/8"CSG PT 1~D=4121 TMD=4800 OEP=lB20 OA SNDS TV0=4125 TM0=4819 DEP=1838 MID OA SND$ / FINAl_ EOB TVD=4160 TMD=5136 DEP=2153 0[3 SNDS TVD=4-195 TMD=b956 DEP=2970 'I-D TVD=4215 TMD=6676 DEP=36~,9 OROP/BUILO 4.25 DEG/IO0' TARGET ANGLE 90 DEG i i I i i i i i i i i i t i i i i i i i i i i i 1200 1,~001600 1800 2000 2200 2400 2600 2800 5000 3200 3400 3600 Vertical Section on 34..52 azimuth with reference 0.00 N, 0.00 E from slot #5 A~.ska Oil & Gas Cons, .Com~i~aior Anchorago 3800 400 _ 350 _ 300 _ 250 _ 200 _ 150 _ 100 _ 50 50 100 100 50 0 50 100 150 200 250 300 I I I I I I I I I ~ //J2300 ////'~00 //i// , ' 90-//~'~-u 1 1 O0 // / / / ! / / ! / / / / / ., / / 1900 ~~'"'""9~0 / '/ ~ 7 00 /,~'~ L - ~ ~ I I - I i __ ~~ II - - - n~ .... ~ -~' 500 ~ ~ I I I I I I [ I I I ] O0 50 0 50 1 O0 ~ 50 200 250 300 400 35O 300 _ 250 _ 200 _ 150 _ 100 _ 5O _0 _ 50 _ 100 PROPOSED MON d--1 NORTH Y 5,01 $,313.25 X 551,531.63 N 1700.00 E 850.00 PROPOSED MON J--2 SOUTH Y 6,014,507.26 X 551,884.66 N 820.00 E 850_00 0 J--6 ,13 J--7 PROPOSED e J-8 EXPANSION ¥= 6.014.842_62 X= 552,201.70 % % POL #15 Y= 6,014,641.12 - X= 552,289.96 MILNE PT. VICINITY MAP o 3 6 MILES NOTES: 1. STATE PLANE COORDINATES At;~ ZONE 4. 2. AIL GEOD~C POSITIONS ARE BASEO ON N.A.D. 1927. 3. OFFSETS TO SECTION UNE$ ARE (~MPU'rLmo BASED ON PROTRACTED VALUES OF TItlE SECTION CORNER POSITIONS. LEGEND * ~ L'~® EXIST1NG WEll Gas Cons..Commiss[o~ PROPOSED WELL DATA LOCATED WITHIN SECTION 28 T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA J N 1000.00 J Y 6,014,800.50 70' 27' 04.226" 2878' FNL J-5 E 1170.00J X 552,105.54 i4-9' 54' 29.530". 3214-' FEL N 940.00 Y 6,014,74-5_54 70' 27' 03.684-" 2933' FNL J-6 E 1170.00 X 552,129.61 149' 34' 28.835" 3191' FEL N 880.00 Y 6,014,690.59 70' 27' 03.142" 2988' FNL J-7 E 1170.00 X 552,153.68 149' 54' 28.139" 3167' F'EL N 820.00 Y 6,014,6.55.64 70' 27' 02.600" 304-3' FNL J-8 E 1170.00 X 552,177.75 149' 34' 27.443"' 3143' FEL PROPOSED PROPOSED PROPOSED PROPOSED PROPOSED WELL LOCATIONS J-5, J-6, J-7 & J-8 SURVEYED FOR- (conoco} DR AV,.'N: STOLL CHECKED: HERR1H'G JOB NO.: 900.59 SCALE: 1" = 300' D'¢,'G goo59-~ 2-A--i--75 T 13 N R g E I .... T 13 N R 10 E T 13 N R 11 E MILNE POIN'I UNIT ~O-~ ' '-~'~''~ ........................!'"" - - '~.~ ' ..... Q Denolel tract ~VRON ~ Unit Bound.r~ ' ~~~ 7 . O "' ADL-47434 2560 AC ADL-47433' AC ~0L,3,9~,.. __~_CoNocO'7 ~'ET''12~' AAL 8 ~ACC'- ~~L ~--~ . 23 24 lg lO 11 22 23 24 21 22 ADL-4743g ADL-3 158~ ADL-~5516 1280 kC .1280 AC ~'_:55!a ~.5~.O.A~ A~LT~51~_2~_4 AC _ 1?ao AC ~280 AC aOL-41437 2580 AC ''~ ~ . iiii i iii i ~flON ~ .~0'~0C~7'~'' ~ CHEVRON '~ 0'~', , : . .: - .... 30 29 28 27 26 . 25 30 2g ~ , ~ ~ ~':~ 31 3 33 34 ' ~ 8aiad on Umla ~ ~ 35 30 31 32 0 1 2 ;~ ~ ADL-28231 2555 AC KILL L~AI':~FOLD FRO.V: REI,'.OI'E HIGH PRESSURE PUMP I HCc.,~:JLIC CCNI'ROL STST£i,I FOR 8OW' S'i'ACK 8, CHOJQ[ wAN:FOLD 10 f~,CLU~£ (2) SIA/IC~ CCN'IROL I,/ANIFOLD LgC-:!..CD ,R(v31[LT Y~TH ]000 PSI ACCL'~UL.tTOR 8 160 6~ £EE£~',~D:R 8 AUX. £~[RGT SOURCE. (.~! SIA F..~N?ROL UAkJFOCD PLUS ~Rf~BLE CNOKE 6-~NIROL 10 ~)E UDCAI£D ON RIG FLOOR. ~U STDS. 3. KILLD~NIFOLO SIZE - RATING~' - ~000 4. CMCJ:EI~LKIFOU)SIZE - RATING .3'- ~000 RF-',(OT E ppcc~,:~r ........ GZSE SEUSCR HYDRAULIC CONTROLLED REMOTE OPERATED DRILLING SPO(X. ADJUSTABLE CHOKE HYDR.qULIC CONTROLLED R E:I,'IOTE OPERATED REUOTE PRESSURE GAGE SE.~SOR CHOKE ADJU~ABLE UANJFOLD - CHOKE i:: -- VARIABLE CHOKE CONTROL t TO ATUOSPHERIC .. '~.UD/GAS SEPARATOR -.---- TO SHALE SHAKER · ,JUL - .. ~la.s..ga_,oi~ ,& Gas'GoDs. Go ~Dchorag~, .. CHOKE $ KILL iU, AN~IFOLDS FOR ctS/8'~ 8 7" OD CASING BOP STACK ~OP I,IAtIIFOLID LAYOUT - CONOCO, lh'C. · CONOCO, INC. MILN[ POINT ~J'NIT DIVERTER STACK FOR 13 318" CONDUCTOR FILl,. Ut LII~£ {_ tELl -( START ~t~O ~EAD The t-..-j'dr'aulic c©n~ct-ol 5¥~L-~ ~ill be in aecordar,ce with Fd}I specificat ions and D*_~C~2~ requirements. ~. The }4CR valve ~ill open eg~en the p~-eventer clos(:_~. ~q 5inula 10" relief line will run off of the d~illing s~ol }iON valv~ and .ill have a ta~-~eted downst~-eam tee fo~ do~r,~iad divers/on. Valves on bth ~ide5 of the te~ ~tll bo full and the ,:,th(-~ to t~e (-Iosod. CONOCO INC,--NABORS27E 13-5/8" 59888 BOP SYSTEM Flll Line AFl 13-~ ~H AFl 1:3--~ EH 13-5/8' Flow Lln~ Annu kr Pre~antor Ram RBm RBm ~1 x u' Tubing Spool w/ 2"-5800q Side Outlets API 11' 5H Casing Spool w/ 3"-5g~0~t Side Outlets Correction 9-5/8" Sur'Face :Casing t3-~3/8'' Conductor' Casing Choke Line: 3" 58'88~ & 3" HOR Kit[ Line~ Two 3" VaLves Manual. Gate Val.,/e VALVE 588138 Manual Gale 1, BOP STACK SIZE RATINO MEETS APl RP53 & SPEC 6A FOR 2, BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY, 3, BOP HYDRAULIC CONTROL S¥STEH TO INCLUDE (5) STATZON HANZFOLD LOCATED REkIOTE WITH t68 OALLON ACCUHULAT'OR, UNIT, & AUXILIARY ENER0t' SOURCE FOR S¥STEH ACTIVATION, · 5, M]N~HUH ONE SET BLIND RAHS & TWO SETS APPR.OPR]ATE PIPE 5, CHOKE & KILL HAN]F:OLDS SHOWN SEPARATELY TO HEET AP] CLASS 5H REQU]REHENTS, CLASS SM CONTROL RESERVOIR RAMS, RP 53 I~0 TQOUGWl NABOBS D~L L ~'x] ~,~g ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE ~-thru 8] ' '' / [ 9--~h ru [10 & 13] [14 thru 22] [23 thru 28] (6) Other ~ : [29 thFu 31-] . o 3. 4. 5. 6 7 8 e .10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Is pemit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Lease $ Well YES NO Is sufficient undedicated acreage avai,,l'able in this pool Is well to be deviated & is wellbore.plat included ................... Is operator the only'affected party .................................. Can permit be approved before 15-day wait ............................ Does Operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nL~nber appropriate .......................................... Does well have a unique name & n~nber ................................ Is conductor string provided ......................................... Wi to Is Wi Wi Wi Is Is Is 1 surface casing protect all zones reasonably expected serve as an underground source of drinking water .................. ~. enough cement used to circulate on conductor & surface ............ ~ 1 cement tie in surface & intermediate or production strings ...... 1 cement cover all known productive horizons ..................... 1 all casing give adequate safety in collapse, tension, and burst. well to be kicked off from an existing wellbore ................ ~.. old wellbore abandonment procedure included on 10-403 ............. adequate wellbore separation proposed ........... ~ ................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~OOo psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. REMARKS ..... ~p~'ll~,o' 0 .--t -r'z ~0 cn--I geo 1 ogy' DWJ ~ eng i neer i NTH ~-/" LCS~/ .... rev 03/29/91 jo/6.011 INITIAL GE01 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE De_A/ 1'o// ,¢'?'o I/zzy Additional remarks' ** CHECK LIST FOR NEW WELL PERMITS ** ITEM APPROVE DATE (2) Loc .,~'/9.,." ~/~,~..~./ ' '[~ thru ~ Admi /[9 thru 1_/3]~/ ~' [lo ~ 13] .., ., [lg thru 22] (5) BOPE /~'.,~,,'Z"~. 7-?-'~/' [23 thru 28] Other ,~ [29 th~u 31 Addl en9ineering: MTM~ LCS BEW RAD dH geology' DW~ le Company ~.~p=Jf.~ ~_z~ YES Is permit fee attached ............................................... /~ Lease g We 11 ~ /~D/~ 2 5" 9~' ' //~/o/// NO REMARKS conductor string provided ......................................... ..~ 2. Is well to be located in a defined pool ............................... 3. Is well located proper distance from property line ................... 4. Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ 9. Does operator have a bond in force ................................... 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease nL~nber appropriate .......................................... 13. Does well have a unique name & n~nber ................................ 14. Is 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. 16. Is enough cement used to circulate on conductor & surface ............ 17. Will cement tie in surface & intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... 19. Will all casing give adequate safety in collapse, tension, and burst. 20. Is well to be kicked off from an existing wellbore ................... 21. Is old wellbore abandonment procedure included on 10-403 ............. 22. Is adequate wellbore separation proposed ............................. 23. Is a diverter system required ........................................ 24. Is drilling fluid program schematic & list of equipment adequate ..... 25. Are necessary diagrams & descriptions of diverter & BOPE attached .... 26. Does BOPE have sufficient pressure rating -- test to ~~ psig ..... 27. Does choke manifold comply w/API RP-53 (May 84) ...................... 28. Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STP~4TIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Additional requirements ............................................. INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE rev 03/29/91 jo/6.011 O .-I 'TZ ~O t~--! Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX, No special 'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER , ******************************* *----~-' SCHLUMBERGER COmPAnY NA~ : CONOCO INC. FIELD NAME : SCHRADER BLUFF BOROUGH : NORTH SLOPE STATE : ALASKA API NU~BER : 50-0~9-2~196 REFERENCE NO : 75337 RECEIVED JAN 1 7 199P. Alaska 011 & Gas Cons. Comm~lon Anchorage ~IS Tame Verlf!catioD [.,],sting ;cblumberger AlasKa Computinn Center 15-JAN-1992 lg:46 **** RE~L HEADER SERVICE NA~iE : GCT DATE : 92101/15 ORIGIN : FbIC REEL NA~E : 75337 CONTINUATION ~ : PREVIOUS REEL CO,gENT : CCT, <ONOCO !~C, ~DU J-5, SCHRADE~ BLUFF, API #50-029-22196 **** TAPE HEADER **** SERVICE NAME : GCT DATF : 92/01/1.5 O~IGIN : FbIC T~PE NA~E : 75~37 CONTINU~TI[~M # : I PREVIOUS TAPE : COMMENT : GCT, CONOCO INC, ~PU j-5, SCMRADE~ BLUFF, API #50-029-22~96 PAGE~ **** FILE MEADER **** FILE NA~E : GCT .001 SERVICE : FLIC VERSION : 00lA06 DATE : 92/0!/~5 MAX R~C SIZE : ~024 FIL~ TYPE : LO L~S? FII~g ******************************************************************************* ******************************************************************************* ** ** SCHLUMBERGER ~EbL SERVICES ** ** ************************************************* ***************************** ******************************************************************************* COMPANY FIELQ~ BOROUGH: STATE: API NU~BE~: C(}N[CO INC SCHRADER BLUFF NO~TM SLOPE ALASKA 50-029-~2196 LOCATION: 2988' FNL & 3167' FEb SFCTION: 28 TOW>~S}~IP: 13N ~ANGE: iOE P~R~ANENT DATUM: ESL ~ELEYATION: 0' LOG MEASURED FROM RKB 70.2' ABOVE PER~ANENT DATUM itc~ va~e Ver:tf. lc~tion lumber~er Alaska Co,~putino Center 15-JAN-1992 t9:46 PAGE~ ELEVATIO~qS KB: 70.2' DF: 69.2' GL: 35' DATE LOGGED: RUN NUMBE~: TD DRILLER: 21-NOV-1991 0 i',i E 664!~' CASING 2: CASING 2: 13 3/8" 77 bE $ DRILLER OEPT~I OF 0' TO 2458' 9 5/8" 47 LB M DRILLER DEPTH OF 0' TO 4891' TYPE FLUID IN HOLE: i)RILbIMG MUD DENSITYI 1.0.3 LB/GAL ~AXIaUa TEMP RECORDED: 83 DEGF bOGGING DISTRICT: LOGGING ENGINEER: WITNESS: PRUDMOE BAY WEST POLYA TOOL NUMBERS: GCAD 701 GCPC 727 GCID 7 TCC B 439 GCEC 726 COMPUTING CENTER ~E~ARKS: LaST READING GET IS AT 4509 74' MD SPERRY SUN ~WD DIRECTIONAL 6ATA TIE-IH POINT AT 4524.~9' MD DATE JOB STARTED: i2-JAN-92 JOB ~EFERENCE MO: 75337 bDP/ANA: R. KRUWELL TABLE TYPE : CONS TUNI VALU DEFI CONOCO INC. Company Name Field Name CN FN SCHRADER BL[tFF WN ~;ILNE POINT UNIT J-5 Well Name NATI [.ISA Nation STAT ALASKA State or Province COU~ NORTH SLOP~ County SECT 28 Sectto~ TOwN 13N TOW~Sh~D RANG IOE Range FI, 2988' FNL & 3167' FEb Field Location SOM 425544 Service Order Number APIW 50-029-22196 API Serial Number !IS WaDe Verification l, istin~ ;chlumberqer AlasKa ComDt~tfn~ Center 15-JA~I-,19g~ lg:46 TABLE TYPE : CURV DEFI DEPT DePth Cnnna e] ~ame GDEP GYRO Depth VDEP True Vertical DePth as chamoel <TVTCP!> DEVI Deviation HLAZ Deviation Azimuth NSDR North South Drift EwD~ East west Drift Component CWEL CURVATURE OF TgE WELL PAGE~ ** DATA FOR'gAT SPECIFICATION RECORD ** ** SET TYPE - 64EL ** TYPE REPR COD VALUE "; .... '"'",,'""'"'"'"'o 2 66 0 3 73 32 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ** SET TYPE - CHAM ** NIaE $~V UNIT SERVICE AP1 AP1 API AP1 FIbE NUmB NUMB SIZE REPR PROCESS ID ORDER # bO,~ TYPE CLASS ~0[) NUmB EAMP ELEM CODE (HEX) ---------------------------------------------------------------------------------------~FP FT 425544 O0 000 O0 0 1 I i 4 68 0000000000 GDEP GCT VDEP GCT DEVI GCT HLAZ GCT NSD~ GCT EWDR GCT C~EL GCT FT 425544 O0 000 O0 0 FT 425544 O0 000 O0 0 DEG 425544 O0 000 O0 0 PEG 425544 O0 000 O0 0 FT 425544 O0 000 O0 O FT 425544 O0 000 O0 0 D/HF 425544 00 000 00 0 1 I I 4 68 0000000000 I i 1 4 68 0000000000 I I 1 4 68 0000000000 I I I 4 68 0000000000 1 I 1 4 68 0000000000 I 1 I 4 68 0000000000 I I I 4 6~ 0000000000 ,~,IS Ta~)e Verificat~on [,istinc~ ;chltl~berqer Alaska Co~,gutfnq Center 1.9:4'6 PAGE:I 1: * D A T A * * DEPT. 'T 65535.500 GDEP.GCT 1.350 VDFP.GCT HLAZ.GC ' t48.118 NSDR.GCT -0.029 EWPR,GCT DEPT. 65500.000 GDEP.GCT 989.700 VDEP.GCT HLAZ.GCT 86,710 MSDR.GCT 1.0a3 EWD~.GCT DEPT. 65400.000 GDEP.GCT 4649,4~ VDEP,GCT . ~ ~ ' GCT 1045.877 EWDR,GCT HLA~ GCT 48.0~0 ,JSDR. DEPT. b5373.000 GDEP.GCT 6648.000 VDEP.GCT HLAM.GCT 51.7(i)0 NSDR,GCT 2319.690 EWDR.GCT 1 350 DEVI.GCT 0:077 CWEL.GCT 9B9.647 DEVI.GCT 9.444 CWEL.GCT 4054.336 DEVI.GCT 1266.291 CWEL.GCT 4202.~78 DEVI.GCT 2793.930 CWEL.GCT 0.736 16.245 ,087 ~.451 74,500 3,870 89.000 0,000 **** FILE TRAILER FILE NAME : GCT ,00i SERVICE : FLIC VERSION : 00~A06 DATE : 92/01/15 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE **** TAPE TRAIbE~ **** SERVICE NAM~ : GCT DATE : 92/01/~5 ORIGIN : FLIC TAPE NA~E : 75337 CONTINUATION ~ : 1 pREVIOUS TAPE : COMMENT : GCT, CONOCO INC, MPU J-5, SCHRADER BLUFF, API #50-0~9-22196 **** REEL TRAILER **** SERVICE NAMM : GCT D~TE : 92/01/15 ORIGIN : FLIC REEL N~ME ~ : 75~37 CONTIMUATIO[~ # : PREVIOUS REEL : COMMENT : GCT, CONOCO INC, ~PU J-5, SCHRAgER ~LiJFF, API #50-029-22196 LIS READ (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS ~ DATE: 91/12/02 ~1f ORIGIN OF DATA: MPT REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: MPT DATE: 91/12/02 ORIGIN OF DATA: J-5 TAPE NAME: MILNE PT CONTINUATION #: 01 , PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT END OF FILE (EOF # 1) ********** RECEIVED DEC 0 6 1997 ** FILE HEADER FILE SEQUENCE # 1 FILE NAME: J5.DAT SERVICE NAME: MPT VERSION #: V 3.26 DATE: 91/12/02 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS COMPANY: CONOCO I FIELD: MILNE POINT I WELL: J-5 I API#: 50-029-22196 LOCATION: 2,988' FNL & 3,167' FEL SEC. 28, TWP. 13N, RANGE 10E, NORTH SLOPE, ALASKA, USA. I DATE: 23-NOV-91 I RIG: NABORS 27E i CO. REP.: J. POLYA I SSDS ENG.: TILLEY & HANIK I K.B.=70.2' D.F.=69.0' G.L.=36.2' I LOGS MEASURED FROM KELLY BUSHING I VARIABLES: GRC = GAMMA RAY CORRECTED (API), ROP = RATE OF PENETRATION (FT/HR), FXE = FORMATION EXPOSURE TIME (HOURS), AGC = AMPLITUDE RESISTIVITY (OHMMS), EWR = PHASE RESISTIVITY (OHMMS), TVD = CALCULATED I ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 AGC MPT OPLMM 0 0 0 0 1 4 0 1 68 ROP MPT FT/H 0 0 0 0 1 4 0 1 68 DATE MPT 0 0 0 0 1 4 0 1 68 TIME MPT 0 0 0 0 1 4 0 1 68 FXE MPT HOUR 0 0 0 0 1 4 0 1 68 DDE MPT PPF 0 0 0 0 1 4 0 1 68 TEMP MPT DEG 0 0 0 0 1 4 0 1 68 GRC MPT API 0 0 0 0 1 4 0 1 68 EWR MPT OHMM 0 0 0 0 1 4 0 1 68 AGC MPT OHMM 0 0 0 0 1 4 0 1 68 TVD CA.LC FT 0 0 0 0 1 4 0 1 68 NDIS MPT FT 0 0 0 0 1 4 0 1 68 EDIS MPT FT 0 0 0 0 1 4 0 1 68 DEVI DEC 0 0 0 0 1 4 0 1 68 DATA FORMAT SPECIFICATION ENTRY BLOCKS TYPE SIZE REP CODE ENTRY DESCRIPTION NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 AGC MPT OHMM 0 0 0 0 1 ROP MPT FT / H 0 0 0 0 1 DATE MPT 0 0 0 0 1 TIME MPT 0 0 0 0 1 FXE MPT HOUR 0 0 0 0 1 DDE MPT PPF 0 0 0 0 1 TEMP MPT DEC 0 0 0 0 1 GRC MPT AP I 0 0 0 0 1 EWR MPT OHMM 0 0 0 0 1 AGC MPT OHMM 0 0 0 0 1 TVD CALC FT 0 0 0 0 1 NDIS MPT FT 0 0 0 0 1 EDIS MPT FT 0 0 0 0 1 DEVI DEG 0 0 0 0 1 4 4 4 4 4 4 4 4 4 4 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1 68 ** DATA VERIFICATION (every 500 FT) ** DEPT AGC ROP DATE TIME FXE DDE TEMP GRC EWR AGC TVD NDIS EDIS DEVI 2300 -999 22 .000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .250 -999.250 -999.250 -999.250 2269.812 167.445 186.724 .081 2500 72 25 .000 .943 .291 8.774 301.899 911118.000 72.513 7.180 8.866 16413.230 .595 .231 2452. 403 221. 727 247 . 549 3000 81 27 .00O .732 .673 13.315 389.099 911118.000 55.359 13.720 11.863 34151.000 .482 1.611 2897.583 367.603 421.937 35OO 85 3O .000 .248 .467 14.027 229.090 911118.000 47.355 13.572 13.789 50019.570 .396 .307 3341.342 522.027 592.697 4000 87 44 .000 .006 .587 9.003 48.443 84.011 911118.000 8.979 8.810 78659.550 .874 .321 3738.610 711.569 826.925 4500 92 67 .0 .2 .9 00 79 31 8.972 45.772 357.792 911119.000 16.423 8.829 25231.000 .987 1.639 4005.971 967.978 1154.461 500O 85 86 .000 .248 .937 11.999 207.536 911121.000 67.993 12.557 11.596 49049.000 .450 .581 4117.000 1283.906 1523.423 550O 9O 88 .000 .521 .800 15.976 266.410 911121.000 54.580 24.539 16.358 71435.660 .300 .353 4139.807 1601.257 1908.749 60OO 99 86 .000 .310 .161 3.800 135.351 911122.000 87.636 3.692 3.795 27869.000 .429 1.076 4176.960 1926.160 2286.713 6500 101 89 .000 .068 .016 8.575 145.848 911122.000 54.881 7.215 8.799 79519.000 .776 .605 4200.846 2245.988 2670.087 ** 551 DATA RECORDS FROM 2300.00 TO 6700.00 FT ** FILE TRAILER** FILE NAME: J5.DAT SERVICE NAME: MPT VERSION #: V 3.26 DATE: 91/12/02 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 END OF FILE (EOF # 2) ** TAPE TRAILER** SERVICE NAME: MPT DATE: 91/12/02 ORIGIN OF DATA: J-5 TAPE NAME: MILNE PT CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 91/12/02 ORIGIN OF DATA: MPT REEL NAME: CONOCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********
