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Home My WebLink About197-119MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC G-11 MILNE PT UNIT G-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 G-11 50-029-22781-00-00 197-119-0 W SPT 4110 1971190 1500 238 240 238 238 4YRTST P Guy Cook 12/20/2025 Testing completed with a Little Red Services pump truck and calibrated gauges. This is a mono-bore well. 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 G-11 Inspection Date: Tubing OA Packer Depth 846 1764 1719 1707IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC251220160322 BBL Pumped:0.9 BBL Returned:0.9 Friday, January 16, 2026 Page 1 of 1 Test due 7/31/2023; well made not operable by email 7/27/2023; reclassified as Operable 12/9/2025 - jbr           CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: MPG-11 (PTD# 197-119) - Return to injection. Date:Monday, December 15, 2025 11:11:17 AM Attachments:image001.png From: Chris Casey - (C) <chris.casey@hilcorp.com> Sent: Tuesday, December 9, 2025 11:04 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Alaska NS - Wells Integrity <AKNSWellsIntegrity@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: OPERABLE: MPG-11 (PTD# 197-119) - Return to injection. Mr. Wallace, PWI MPG-11 (PTD #1971190) was made Not Operable after being shut in for its 4-year MIT-IA due in July 2023. The well is re-classified as OPERABLE, an AOGCC witnessed MIT-IA will be performed once the well is on stable injection. Please respond with any questions. Chris CaseyHilcorp Alaska LLCField Well IntegrityAKI/MPU/WNS chris.casey@hilcorp.com O: (907) 685-1494 C: (907) 242-1021Alt: Steve Soroka Hilcorp North Slope, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/26/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250626 Well API # PTD # Log Date Log Company Log Type AOGCC E-Set# MPU G-11 50029227810000 197119 06/13/2015 Halliburton Radial Cement Bond Log Please include current contact information if different from above. T40625 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.26 14:18:56 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPG-11 (PTD# 197-119) Missed AOGCC Witnessed MIT-IA Date:Tuesday, August 1, 2023 11:12:46 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Thursday, July 27, 2023 2:17 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPG-11 (PTD# 197-119) Missed AOGCC Witnessed MIT-IA Mr. Wallace – PWI well MPG-11 (PTD# 197-119) is currently shut in and will not be brought online for its scheduled 4 year MIT-IA due this month. The well will now be classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg / I P.I. Supervisor�� 7 666 FROM: Matt Herrera Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 10, 2019 SUBJECT: Mechanical Integrity Tests Hilcom Alaska LLC G-11 MILNE PT UNIT G-1 I Src: Inspector Reviewed By: P.I. Supry J I0)— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT G -I I API Well Number 50-029-22781-00-00 Inspector Name: Matt Herrera Insp Num: mi[MFHI90701170941 Permit Number: 197-119-0 Inspection Date: 7/1/2019 Rel Insp Num: Wednesday, July 10, 2019 Page I of I Parker Deptb Pretest Initial Min 30 Min 45 Min 60 Min Well G -ii TNpelnj `t' TVD aii0 Tubing 9S1 984 - �15 983 981 PTD 1971190 Type Test SP Test psi 1500 IA io> 1706 1637 - 162G - - - BBL Pumped: 1 5 1313L Returned: L5 - OA Interval -_--- 4vRTS1 P/P _ a. Notes: Monobore Completion no GA IA Pressure tested to 1700 PSI Per Operator Wednesday, July 10, 2019 Page I of I Kikt C-1 ( Pm (97 i n0 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, August 11, 2015 3:03 PM Iq 811t(11--; To: 'Wyatt Rivard' II Cc: Wallace, Chris D (DOA) Subject: RE: MPG-11 (PTD #1971190) MIT-IA Frequency With competent mechanical integrity, an MIT every 4 years is the proper interval for MPU G-11 (conversion from producer to injector). As noted in the Area Injection Order 10B (Rule 5), injection rates and/or operating pressures that indicate pressure communication or leakage of the casing, tubing or packer requires the well to be immediately shut and secured, notification and submittal of a sundry for corrective action (application for admin approval may also be required to continue to inject with repaired well; post-repair MIT frequency would be addressed in the admin approval). Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 ��ut Anchorage,AK 99501 SC 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Wednesday, July 29, 2015 4:13 PM To: Regg, James B (DOA) Subject: MPG-11 (PTD #1971190) MIT-IA Frequency Jim, MPG-11 (PTD#1971190) was recently converted from an ESP producer . a water injector.The well had a passing AOGCC witnessed MIT-IA on 7/3/2015 which was submitted on 7/6/ .15. Hilcorp currently has an MIT scheduled by 7/3/2019 based on a four year MIT-IA interval as per AIO 10-B. The well was completed with tubing, packer and a single 7" s face casing with no additional production casing string. Injectors of this type on the North Slope appear to have mi -d testing intervals of 2 or 4 years.The well maintains a monitor-able annulus and two barriers to flow. In the ab -nce of an alternative testing history, Hilcorp believes the four year MIT-IA interval is appropriate for MPG-11.The 7/12019 due date will be used for MIT planning unless a different interval is requested. Thank You, Wyatt Rivard WyllIntcgrity Fingiricer O. (907) 777-8547 I C: (509)670-8001 ! wrivard@hilcorp.com 3800 Cc'nte1 poiii) I)mo,Suitt 14100 1An(hor.igr, 11K 99503 1 til Pct q --(t Qraj (q7((l0 Regg, James B (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, July 29, 2015 4:13 PM , a 31i5 To: Regg, James B (DOA) 1 Subject: MPG-11 (PTD #1971190) MIT-IA Frequency Attachments: MIT MPU G-11 7-3-15.xls; G-11 SCHEMATIC 6-25-2015.doc Jim, MPG-11 (PTD#1971190) was recently converted from an ESP producer to a water injector. The well had a passing AOGCC witnessed MIT-IA on 7/3/2015 which was submitted on 7/6/2015. Hilcorp currently has an MIT scheduled by 7/3/2019 based on a four year MIT-IA interval as per AIO 10-B. The well was completed with tubing, packer and a single 7" surface casing with no additional production casing string. Injectors of this type on the North Slope appear to have mixed testing intervals of 2 or 4 years.The well maintains a monitor-able annulus and two barriers to flow. In the absence of an alternative testing history, Hilcorp believes the four year MIT-IA interval is appropriate for MPG-11.The 7/3/2019 due date will be used for MIT planning unless a different interval is requested. Thank You, Wyatt Rivard Wrll1ntegnly Engiuorr 0: (007) 777-8517 1 C: (509)670-80011 wrivard@hilcorp.com 3800 CL'ntcrpoint Dnvr,Stith 1400 Anchor<.gc',AK 0050.1 liil.,,il, 11.u•ka, LI(. 1 • STATE OF ALASKA L��1 ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to pm regq(CDalaska.gov doa.aoqcc.prudhoe bay(rDalaska qov phoebe brooksaialaska qov OPERATOR: Hilcorp Alaska LLC FIELD/UNIT/PAD: Milne Point/MPU/G DATE: 07/03/15 OPERATOR REP: Matt Linder AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min — Well MPG-11 Type In/ W TVD 4,114' Tubing 450 450 450 450 Interval I P T D 1971190 Type test P Test psi 1500 Casing 1,046 1,807 1,779 1,772 P/F P Notes: Initial AOGCC MIT-IA post conversion OA 6 bbls diesel pumped to reach test pressure.Monobore,no OA Well Type In) TVD ,Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well Type In). TVD TubingInterval P T D. Type test Test psi _Casinq P/F Notes: OA Well Type In) TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: OA Well Type In) TVD Tubing_ Interval P T D Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dnlling Waste M=Annulus Monitonng I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Infecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 02/2012) MIT MPU G-11 7-3-15 xis sti ____ ,P(i_ Milne Point Unit Well: MPU G-11 SCHEMATIC Last Completed: 6/14/2015 Mom)Alaska,r.r,c PTD: 197-119 CASING DETAIL Orig.KB Elev.:58.3'/GL Elev.:29.3' Size Type Wt/Grade/Conn ID Top Btm `, 20" Conductor 91.1/H-40/N/A N/A Surface 112' 20"!' i. ' s' L., 7" Production 26/L-80/Btc 6.276 Surface 7,364' i TUBING DETAIL 'it,' ' 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 6,855' I JEWELRY DETAIL No Depth Item 9 9 1 2,067' HOWCO ES Cementer S 1' 2 6,801' 3-1/2"x 7"Permanent Packer 3 6,842' XN-Profile Nipple I:' 1" 4 6,854' WLEG—Bottom @ 6,855' 5 7,080' Packer:7"x 3.5"Hydraulic Baker FB-1 0 • Q� 1 6 7,084' 3.5"BXP(Broken Glass Disk) S; - 7 7,088' 3.5"WLEG ' PERFORATION DETAIL ., I. Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 'OA'Sands 7,040' 7,065' 4,326' 4,348' 25 12/28/1997 Open L.,, 'OB'Sands 7,113' 7,138' 4,392' 4,414' 25 12/24/1997 Open . i' y Perf Detail:4.5"/4spf/Phasing 0 to 180 Deg.—SWS 43C UP RDX Big Hole Charges for'OA'&'OB'Sands Only OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole `.• 7" 1,185 sx PF'E',130sx Class'G'in 8-1/2"Hole:CBL runon 6/13/2015 i STIMULATION DETAIL 12/26/1997:'OB'56,7501bs of 16-20 Prop-Lok resin coated 16-20Carbolite behind pipe. ' +, 12/30/1997:'OA'76,640Ibsw of 16-20 Prop-Lok resin coated 7'x21' ' 16-20 Carbolite behind pipe.Screened out on lOppg Marker Joint „ 4 4 @6'731' k TREE &WELLHEAD 1. r;� , Tree 2-9/16"-5M FMC f' '' 11"x 5M Monobore w/2-7/8"FMC Tubing Hanger,EUE lift Wellhead • 4 threads,2-7/8"CIW H BPV profile. 1 GENERAL WELL INFO API:50-029-22781-00-00 , '.. Drilled and Cased by Nabors 22E -7/14/1997 • Y-Tool ESP Completion by Nabors 4ES—1/11/1998 i ESP RWO w/5S—4/20/1998 ESP RWO w/4ES—4/5/2001 t 1 ''.!%'.' '.y 2 { "3 4 'S ' 'OA'Sands 7 4. %. 5&6 1. a Y 1 'OB'Sands 7'a :o.t'li_Lr.'`1 TD=7,385'(MD)/TD=4,636'(TVD) PBTD=7,279'(MD)/PBTD=4,541'(TVD) Created By:TDF 6/25/2015 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg !� DATE: Monday,July 20,2015 P.I.Supervisor y ( I i s SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC G-II FROM: Jeff Jones MILNE PT UNIT SB G-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3612-- NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB G-11 API Well Number 50-029-22781-00-00 Inspector Name: JeffJones Permit Number: 197-119-0 Inspection Date: 7/3/2015 Insp Num: mitJJ150706100829 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' G-II Type Inj W"TVD 4110 Tubing 450 450 450 • 450 • PTD! 1971I90 Type Test SPT Test psi 1500 IA 1046 1807 1779 - -1772 Interval INITAL P/F P i OA Notes: Recent conversion to monobore injector WJE(( seta( ,`c ctA . SSE Monday,July 20,2015 Page 1 of 1 Milne Point Unit Well: MPU G-11 SCHEMATIC Last Completed: 6/14/2015 Mein„Alaska,LIC PTD: 197-119 CASING DETAIL Orig.KB Elev.:58.3'/GL Elev.:29.3' Size Type Wt/Grade/Conn ID Top Btm 20.'j 7" L 20" Conductor 91.1/H-40/N/A N/A Surface 112' 20.'j7" Production 26/L-80/Btc 6.276 Surface 7,364' TUBING DETAIL r' 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 6,855' JEWELRY DETAIL s No Depth Item •, ) '1 1 2,067' HOWCO ES Cementer .'• 2 6,801' 3-1/2"x 7"Permanent Packer 3 6,842' XN-Profile Nipple 4 6,854' WLEG–Bottom @ 6,855' 5 7,080' Packer:7"x 3.5"Hydraulic Baker FB-1 .0 0; 1 6 7,084' 3.5"BXP(Broken Glass Disk) t- 7 7,088' 3.5"WLEG 5• PERFORATION DETAIL t s Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 'OA'Sands 7,040' 7,065' 4,326' 4,348' 25 12/28/1997 Open .• 'OB'Sands 7,113' 7,138' 4,392' 4,414' 25 12/24/1997 Open Perf Detail:4.5"/4spf/Phasing 0 to 180 Deg.–SWS 43C UP RDX Big Hole Charges for'OA'&'OB'Sands Only ' OPEN HOLE/CEMENT DETAIL 4 20" 250 sx of Arcticset I in 24"Hole s, t` 7" 1,185 sx PF'E',130sx Class'G'in 8-1/2"Hole:CBL runon 6/13/2015 STIMULATION DETAIL 12/26/1997:'08'56,7501bs of 16-20 Prop-Lok resin coated ' 16-20Carbolite behind pipe. 12/30/1997:'OA'76,640Ibsw of 16-20 Prop-Lok resin coated 7'x21' 16-20 Carbolate behind pipe.Screened out on lOppg Marker Joint , " @6,73r\; TREE&WELLHEAD G Tree 2-9/16"-5M FMC Wellhead 11"x 5M Monobore w/2-7/8"FMC Tubing Hanger,EUE lift threads,2-7/8"CIW H BPV profile. , GENERAL WELL INFO API:50-029-22781-00-00 i; Drilled and Cased by Nabors 22E -7/14/1997 Y-Tool ESP Completion by Nabors 4ES–1/11/1998 ' ? ESP RWO w/55–4/20/1998 ESP RWO w/4ES–4/5/2001 ' 1--t , 3 . 4 '7 " —'OA'Sands -,5&6 .., 7 ='OB.Sands 7". '.:1,:"i TD=7,385(MD)/TD=4,636'(1VD) PBTD=7,279'(MD)/PBTD=4,541'(TVD) Created By:TDF 6/25/2015 Brooks, Phoebe L (DOA) PTDtk 14'17 M O 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: image002jpg; image003jpg; 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 Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-80011 wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 sCANNED JUL 1 0 2015 tlikrnrp AIa*ka, 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 (e...>7 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)670-80011 wrivard@hilcorp.com 3800 Centerpoint Drive, Suite 1400 ( Anchorage,AK 99503 1 Milne Point Unit Well: MPU G-11 SCHEMATIC Last Completed: 6/14/2015 PTD: 197-119 IliIcor!)_ilaska.LLA; CASING DETAIL Orig.KB Elev.:58.3'/GL Elev.:29.3' Size Type Wt/Grade/Conn ID Top Btm a,, k 20" Conductor 91.1/H-40/N/A N/A Surface 112' t 20 f ' 7" Production 26/L-80/Btc 6.276 Surface 7,364' TUBING DETAIL ;." r 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 6,855' 1 JEWELRY DETAIL rp i.„": No Depth Item 0 3 1 2,067' HOWCO ES Cementer 2 6,801' 3-1/2"x 7"Permanent Packer `• 3 6,842' XN-Profile Nipple 4 6,854' WLEG—Bottom j. 6,855' 5 7,080' Packer:7"x 3.5"Hydraulic Baker FB-1 w • ae 1 6 7,084' 3.5"BXP(Broken Glass Disk) t4 7 7,088' 3.5"WLEG I ',« PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status ,w «' 'OA'Sands 7,040' 7,065' 4,326' 4,348' 25 12/28/1997 Open Rkt '4 'OB'Sands 7,113' 7,138' 4,392' 4,414' 25 12/24/1997 Open ii 4 Perf Detail:4.5"/4spf/Phasing 0 to 180 Deg.—SWS 43C UP RDX Big Hole Charges for'OA'&'OB'Sands Only OPEN HOLE/CEMENT DETAIL ; t'l 20" 250 sx of Arcticset I in 24"Hole 7" 1,185 sx PF'E',130sx Class'G'in 8-1/2"Hole:CBL runon 6/13/2015 r STIMULATION DETAIL 12/26/1997:'OB'56,7501bs of 16-20 Prop-Lok resin coated 16-20Carbolite behind pipe. . 12/30/1997:'OA'76,640Ibsw of 16-20 Prop-Lok resin coated 7x21' ' I ,4 16-20 Carbolite behind pipe.Screened out on lOppg Marker Joint , @6,731', ,,,,,,,, „ TREE&WELLHEAD Tree 2-9/16"-5M FMC ''''i '” : i 'h, 11"x 5M Monobore w/2-7/8"FMC Tubing Hanger,EUE lift Wellhead threads,2-7/8"CIW H BPV profile. GENERAL WELL INFO API:50-029-22781-00-00 ) Drilled and Cased by Nabors 22E -7/14/1997 i Y-Tool ESP Completion by Nabors 4ES—1/11/1998 ESP RWO w/5S—4/20/1998 r* ' I ESP RWO w/4ES—4/5/2001 2 t= Ft„ 3 r ', 4 j X'k r -- 'OA'Sands �r •x . 5&6 i 7 .='OB'Sands &it TD=7,385'(MD)/TD=4,636'(TVD) PBTD=7,279'(MD)/PBTD=4,541'(TVD) Created By:TDF 6/25/2015 STATE OF ALASKA SKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS iUN 3 0 2015 1 Operations Abandon ❑ Repair Well U Plug Perforations ❑ Perforate H Other gret Injector Performed: Alter Casing ❑ Pull Tubing Q Stimulate-Frac ❑ Waiver ❑ Time Extensio Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 197-119 3 Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-029-22781-00-00 7 Property Designation(Lease Number): 8.Well Name and Number: ADL0025518 MILNE PT UNIT SB G-11 9 Logs(List logs and submit electronic and printed data per 20AAC25.071) 10.Field/Pool(s) N/A MILNE POINT/ SCHRADER BLUFF OIL 11.Present Well Condition Summary: Total Depth measured 7,385 feet Plugs measured N/A feet true vertical 4,636 feet Junk measured N/A feet Effective Depth measured 7,279 feet Packer measured 7,080 feet true vertical 4,541 feet true vertical 4,362 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20" 112' 112' 1,490psi 470psi Surface Intermediate Production 7,364' 7" 7,364' 4,617' 7,240psi 5,410psi Liner i Perforation depth Measured depth See Attached Schematic SCA" JUL0 LOU True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 26#/L-80/8rd EUE 6,896'(MD) 4,196(TVD) 7,080'(MD) Packers and SSSV(type,measured and true vertical depth) 7"x 3.5"Hyd.Pkr N/A 4,362'(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure N/A 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 1,320 430 Subsequent to operation: 0 0 500 1,350 748 14 Attachments: 15 Well Class after work 1 Copies of Logs and Surveys Run N/A Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ 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: 315-301 Contact Chris Kanyer Email ckanyerhilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature Phone 907-777-8377 Date 6/30/2015 RBDMS4 JUL - 1 2015 Form 10-404 Revised 10/2012Ak 7-615 Submit Original Only Milne Point Unit Well: MPU G-11 11 SCHEMATIC Last Completed: 6/14/2015 Ililcorp Alaska,LLC PTD: 197-119 CASING DETAIL Orig.KBAGL:29.0/GL Elev.:29.3' Size Type Wt/Grade/Conn ID Top Btm eA A 20" Conductor 91.1/H-40/N/A N/A Surface 112' 2O . 7" Production 26/L-80/Btc 6.276 Surface 7,364' • 04 TUBING DETAIL i 0 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 6,855' ti V. JEWELRY DETAIL No Depth Item 1 2,067' HOWCO ES Cementer 2 6,801' 3-1/2"x 7"Permanent Packer .0 3 6,842' XN-Profile Nipple �! 4 6,854' WLEG—Bottom @ 6,855' ,;' 5 7,080' Packer:7"x 3.5"Hydraulic Baker FB-1 • 1 6 7,084' 3.5"BXP(Broken Glass Disk) F 7 7,088' 3.5"WLEG 4, PERFORATION DETAIL 0 Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status >f 'OA'Sands 7,040' 7,065' 4,326' 4,348' 25 12/28/1997 Open V 'OB'Sands 7,113' 7,138' 4,392' 4,414' 25 12/24/1997 Open Perf Detail:4.5"/4spf/Phasing 0 to 180 Deg.—SWS 43C UP RDX Big Hole Charges for'OA'&'OB'Sands Only G OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 7" 1,185 sx PF'E',130sx Class'G'in 8-1/2"Hole:CBL runon 6/13/2015 STIMULATION DETAIL 12/26/1997:'OB'56,750Ibs of 16-20 Prop-Lok resin coated . 16-20Carbolite behind pipe. il i4 12/30/1997:'OA'76,6401bsw of 16-20 Prop-Lok resin coated 7'x 21' 16-20 Carbolite behind pipe.Screened out on 10ppg AtrkerJoint i @6,731' &WELLHEAD Tree 2-9/16"-SMTREE FMC Wellhead ii."x 5M Monobore w/2-7/8"FMC Tubing Hanger,EUE lift threads,2-7/8"CIW H BPV profile. GENERAL WELL INFO API:50-029-22781-00-00 Drilled and Cased by Nabors 22E -7/14/1997 Y-Tool ESP Completion by Nabors 4ES—1/11/1998 • ESP RWO w/5S—4/20/1998 ESP RWO w/4ES—4/5/2001 if X V 4estws lie.4 • f • *'CA's 1'f • 5&6 y i TD=7,385'(MD)/TD=4,636'(TVD) PBTD=7,279'(MD)/PBTD=4,541'(TVD) Created By:TDF 6/25/2015 Hilcorp Alaska, LLC Alaska.LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MP G-11 50-029-22781-00-00 197-119 6/11/2015 6/14/2015 Daily Operations: 6/10/15-Wednesday No operations to report. 6/11/15-Thursday MIRU Accepted Rig.Spot tanks, berm cellar, MU hardline to kill tank, pulled BPV, off loaded 380 bbls of hot sea water. Tested lines to 3,000psi.SITP 1,120psi,SICP 1,140psi, bled both to Opsi.Started pumping, reverse circulating @ 4bpm, broke cir @ 104bbls continued circulating until returns cleaned up. Returns 30%oil, no soilds. Set BPV and ND Production tree/NU BOPE and connected lines, pulled BPV and set a TWC. Filled BOPE and shell test, performed BOPE test as following:Annular 250psi low/2500psi high,Valves 250psi low/3000psi high, Rams 250psi low/3,000psi high, held and charted 5 mpt,gas detection and kommey drawdown.John Hill from AOGCC waived witness of the test. 6/12/15-Friday Finished BOPE testing. Prep rig to pull ESP completion, pulled TWC, PU landing jt MU_to tbg hanger, opened csg and backed out lock down pins, pulled 86k to unseat tbg hanger and pulled to rig floor, esp cable-good,decompleted hanger BO/LD same, pull stand and thread cable/heat trace to spooler.TOOH w/ESP completion,tallied stands out LD GLM's and XN-nipple, BO/LD ESP assembly. Recovered 77 lasalle clamps,347 6'flat gaurds, 224'flat gaurds,73'flat gaurds, 1,130 stainless bands, 3 protectizers, 3 flat bands.Cleaned and prep rig to make cleanout trip. PU/MU csg scraper BHA and tallied,TIH with same to packer set depth @ 6,800' reciprocated csg scraper thru pkr set depth, continued TIH to 7,030'. Lined up manifold and started pumping, reverse circulate @ 4bpm broke circulate after 23bbls, pumped 2 bottoms up with returns clean SD pump. Returned light sand and oil.TOOH w/cleanout BHA. 6/13/15-Saturday Continued TOOH w/cleanout BHA, LD 41 jts(175-216) identified bad from caliper log. LD csg scraper. Prep rig for WL operations, RU Dutch riser, MIRU EL unit,tested to 500psi. RIH w/GR/CBL to 7,080' logged up to 200'. POOH. RDMO EL unit, LD Dutch Riser and preped floor to run injection completion.Tallied completion, MU WLEG and TIH with completion as follows- EOT/WLEG @ 6,855'KB 10' 2-7/8"6.5#EUE 8rd pup jt,XN-Nipple @ 6,843'KB, 1 jt of 2-7/8" 6.5#EUE 8rd, Hydraulic Pkr @ 6,806'KB, 216 jts of 2-7/8" 6.5#EUE 8rd, 10' 2-7/8" 6.5#EUE 8rd pup jt, 2' 2-7/8" 6.5#EUE 8rd pup jt, MU Hanger, PU Landing Jt and land string SW 72K up 58k down. Run in lock down screws. ND BOP/NU tree. Orient tree and test to 5,000psi. 6/14/15-Sunday Reverse circulated in 130bbls of packer fluid with rig pump. MIRU hot oil unit. Pumped 76 bbls of diesel down csg.SI the swab valve and MU 8' riser to drop ball and rod. Pumped 20 bbls of diesel down tbg and dropped ball and rod. Pumped 8bbls behind ball and rod but couldnt seat the ball. MU 2"JDC and roller bar and dropped down the tbg to wieght up the ball and rod. Pumped 8 bbls down tbg and seated ball. Pressured up to 3,800psi and held for 15 mins to set packer. Bled off pressure. Lined up to csg. Pressured up on csg to 2,600psi.Charted and held for 30 mins.Test good. RDMO MPG-11. 6/15/15-Monday No operations to report. 6/16/15-Tuesday No operations to report. M‘ t\ ft7r,t(5 (4)1( . ` q� OF Th k°11 - , l 1 j�,s, THE STATE Alaska Oil and Gas • ti1 of LAsKAL Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 OFALAr-�Y'P Fax 907.276 7542 www aogcc.alaska gov Chris Kanyer Operations Engineer Hilcorp Alaska, LLC SCANNED MAY 2 9 2015 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB G-11 Sundry Number: 315-301 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, P7?/).0_,7 Cathy P. oerster Chair St DATED this 2/ day of May, 2015 Encl. „6 RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 14 2015 APPLICATION FOR SUNDRY APPROVALS AO ;C(` 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing El Operations shutdown ❑ Suspend❑ Perforate E Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well' jI Re-enter Susp Well ❑ Other. Convert to Injector ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑✓ ' 197-119 3.Address: Stratigraphic ❑ Service El6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22781-00-00 • 7. If perforating: 'rid 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.us Will planned perforations require a spacing exception? Yes ❑ No 0 MILNE PT UNIT SB G-11 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0025518 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): 7,385 - 4,636 - 7,279 4,541 7,279' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 112' 20” 112' 112' 1,490psi 470psi Surface - Intermediate Production 7,346' 7" 7,346' 4,617' 7,240psi 5,410psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic' See Attached Schematic 2-7/8" 26#/L-80/EUE 8rd 6,896 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7"x 3.5"Hyraulic Packer and N/A / /vD 7"x 3.5"Hyraulic Packer and N/A 12.Attachments: Description Summary of Proposal ❑� 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ 14.Estimated Date for 15.Well Status after proposed work: 5/20/2015 Commencing Operations: OIL ❑ WINJ Ei 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(a�hilcorp.com Printed Name Chris Kanyer Title Operations Engineer / ,..,./ Signature / d Phone 777-8377 Date 5/14/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i5.- 3CA i. Plug Integrity ❑ BOP Test ig Mechanical Integrity Test LJ Location Clearance ❑ Other: ii30a) f54 (J 0 1 1 C--S. C r� v �..- 71- Z _S-00 P c=ti s i �t s� -fit- C(3 L-, rel °.a.i f r.C2 Spacing Exception Required? Yes ❑ No Ei7 Subsequent Form Required: Jo-• L. �l� I APPROVED BY Approved by: P COMMISSIONER THE COMMISSION Date:S- � —15 247 Submit Form and Form 10-403 Rev' d 8C 5/2015 2_/v 4404nAvid lid for 12 months frgim the date of approval. Attachments in Duplicate �� 1 RBDMSJ MAY 2 9 2015 Well Prognosis • Well: MPG-11 Hilcorp Alaska,LL Date: 5/14/2015 Well Name: MPG-11 API Number: 50-029-22781-00-00 Current Status: SI Producer Pad: G Pad Estimated Start Date: May 20, 2015 Rig: Nordic 3 Reg.Approval Req'd? May 19, 2015 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 197-119 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: Current Bottom Hole Pressure: 1,503 psi @ 4,000' TVD (Last BHP measured 5/14/2015) Maximum Expected BHP: — 1,800 psi @ 4,000' TVD (Assumed virgin Pressure NB Sand) Max. Allowable Surface Pressure: 482 psi ((Based on possible reservoir conditions of 100% oil cut(0.385psi/ft) (currently WC 7%)) Brief Well Summary: The Milne Point G-11 well was drilled as a Schrader Bluff development well that TD'd at 7,385' and ran and cemented 7" casing in July 1997. The well was completed initially as an ESP producer. This completion and subsequent ESPs failed and were replaced in 1998 and 2001. The recent pump failed in July 2001. The most recent casing pressure test performed to 1,000psi on December 1997. A casing pressure test will be completed during this workover with the newly installed packer. r n cvr. LAihcn rite- // 7'7 No subsidence issues are expected in this well. /fro civ c,ed t t.0' < (Oo 10 n ,,roe I Yk Lvet ',S I've f/ (O /L-eY TD P Notes Regarding Wellbore Condition sem?. AQnZoh 1 I ea-1014_ 4,/torr 7-0 794 c 0 €r �j (6 CerrriAfl Current well status is shut in oil producer. No subsidence issues suspected.�ro ' r , 74;S wady ro 4� ")°r /Oat AOR (status of wells within 1/4 mile radius of injection zone): 4-4v/d ,4/rove re 69 16'6- )fir API Well No Permit Well Current Status Zonal isolation (method) Estimated TOC (calculated) at 4,592'MD 50-029-23228-00-00 204-192 MPG-19 Injecting >3,000' above Schrader NB sand 50-029-21942-01-00 204-219 MPG-03A Injecting Estimated TOC (calculated) at 3,468'MD >2,450' above Schrader NB sand Estimated TOC (calculated) at 2,690'MD 50-029-23189-00-00 203-210 MPG-16 Producing >2,600' above Schrader NB sand Estimated TOC (calculated) at 5,125'MD 50-029-23259-00-00 205-055 MPE-28 S/I >2,550' above Schrader NB sand RWO Objective: Pull ESP, run casing scraper, & run 2-7/8" water injection completion with packer set<200ft of planned perfs. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. 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. . 11 Well Prognosis • Well: MPG-11 Ilil(orp:tla.ka.I.I. Date:5/14/2015 a. 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. 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.) A;( f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ oi 4 / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, y 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"tubing, heat trace, and ESP completion from 6,896'to surface and lay down same. 1"c i d^ -roe-- 6. RIH with cleanout BHA to+/-7,000'. POOH with same. 1 1 7. MU and RIH with hydraulic permanent packer on 2-7/8" 8RD EUE L-80 tubing [replace as necessary]. Space out with WLEG at+/-6,865', XN nipple, and injection packer at+/-6,825'. 8. ND BOP, NU and tree. / -� 9. Set plug in profile and pressure up on tubing to set injection packer at+/-6,825'. 10. Perform a charted casing pressure test tosi for 30min. Bleed off pressure. 11. RDMO workover rig and equipment. ,25-e.✓`'Pte. y.,..5.41 i., 12. Turn well over to production. Post Rig Activities: 13. Slickline to pull plug in XN nipple post rig. 14. Eline to perforate the Schrader NB sand from +/-6,889' to +/-6,903'. // ll DD r--. L. —7 t, i -1,, _ /4 4 l c5 T -�- `� Attachments: 1. As-built SchematicS Zi-I 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPU G-11 SCHEMATIC Last Completed: 4/3/2001 Hump Alaska,LLC PTD: 197 119 CASING DETAIL Orig.KB AGL.:29.0'/GL Elev.:29.3' Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 2tT _ 7" Production 26/L-80/Btc 6.276 Surface 7,364' 1 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface 6,896' JEWELRY DETAIL No Depth Item 1 139' GLM: Camco 2-7/8"x 1"Sidepocket KBMM 4 2 2,067' HOWCO ES Cementer �' , 3 6,692' GLM: Camco 2-7/8"x 1"Sidepocket KBMM . i..): 4 6,833' 2-7/8"HES XN Nipple:ID=2.205" 5 6,847' Centrilift 214 Stage FC 925 GPMTAR 1:2 Trace @22 0 O 2 6 6,867' FRSTXBAR Tandem AR Gas Separator 7 6,871' Tandem Seal Section:Centrilift 513 Series GSBSDB UT/LT AFLAS/HSN 8 6,885' Motor:Centrilift 562 Series 76hp/KMH 1,360 V/34 Amp 9 6,893' Centrilift PumpMate and Six Fin Centralizer:Bottom @ 6,896' 10 7,080' Packer:7"x 3.5"Hydraulic Baker FB-1 11 7,084' 3.5"BXP(Broken Glass Disk) 12 7,088' 3.5"WLEG PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 'OA'Sands 7,040' 7,065' 4,326' 4,348' 25 12/28/1997 Open 'OB'Sands 7,113' 7,138' 4,392' 4,414' 25 12/24/1997 Open Perf Detail:4.5"/4spf/Phasing 0 to 180 Deg.–SWS 43C UP RDX Big Hole Charges OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 7 x21' 7" 1,185 sx PF'E',130sx Class'G'in 8-1/2"Hole Marker Joint 13 STIMULATION DETAIL @6,731' ? 12/26/1997:'OB'56,7501bs of 16-20 Prop-Lok resin coated II?C' 16-2OCarbolite behind pipe. IN 12/30/1997:'OA'76,640lbsw of 16-20 Prop-Lok resin coated E'El 4 16-20 Carbolite behind pipe.Screened out on l0ppg 1E TREE&WELLHEAD Tree 2-9/16"-5M FMC 5 Wellhead 11"x 5M Monobore w/2-7/8"FMC Tubing Hanger,EUE lift threads,2-7/8"CIW H BPV profile. • 11 '6 GENERAL WELL INFO 17 API:50 029 22746 00 00 Drilled and Cased by Nabors 22E -7/14/1997 •8 ' ' Y-Tool ESP Completion by Nabors 4ES–1/11/1998 3,..1t.4- 4 ESP RWO w/5S–4/20/1998 ESP RWO w/4E5–4/5/2001 0 9 'OA'Sands 471111 10&11 • 12 -'OB'Sands TD=7,385'(MD)/TD=4,636'(TVD) PBTD=7,279'(MD)/PBTD=4,541'(TVD) Created By:TDF 4/23/2015 Milne Point Unit Well: MPU G-11 PROPOSED Last Completed: 4/3/2001 Hilcorp Alaska,LLC PTD: 197-119 CASING DETAIL Orig.KBAGL:29.0/GLEIev.:29.3 Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/H-40/N/A N/A Surface 112' 20" 7" Production 26/L-80/Btc 6.276 Surface 7,364' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/8rd EUE 2.441 Surface ±6,865' 67,1 JEWELRY DETAIL No Depth Item 1 2,067' HOWCO ES Cementer 2 ±6,825' 3-1/2"x 7"Packer A 3 ±6,845' XN-Profile Nipple ° 4 ±6,865' WLEG • 5 7,080' Packer:7"x 3.5"Hydraulic Baker FB-1 0 1 6 7,084' 3.5"BXP(Broken Glass Disk) 7 7,088' 3.5"WLEG PERFORATION DETAIL Schrader Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status 'NB'Sands ±6,889' ±6,903' ±4,190' ±4,202' ±14 Future Proposed 'OA'Sands 7,040' 7,065' 4,326' 4,348' 25 12/28/1997 Open 'OB'Sands 7,113' 7,138' 4,392' 4,414' 25 12/24/1997 Open Perf Detail:4.5"/4spf/Phasing 0 to 180 Deg.—SWS 43C UP RDX Big Hole Charges for'OA'&'OB'Sands Only OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I in 24"Hole 7" 1,185 sx PF'E',130sx Class'G'in 8-1/2"Hole STIMULATION DETAIL 12/26/1997:'OB'56,7501bs of 16-20 Prop-Lok resin coated 16-20Carbolite behind pipe. 7"x 21' 12/30/1997:'OA'76,640Ibsw of 16-20 Prop-Lok resin coated Marker pant 16-20 Carbolite behind pipe.Screened out on lOppg TREE&WELLHEAD Tree 2-9/16"-5M FMC Wellhead 11"x 5M Monobore w/2-7/8"FMC Tubing Hanger,EUE lift threads,2-7/8"CIW H BPV profile. b9 GENERAL WELL INFO API:50-029-22746-00-00 Drilled and Cased by Nabors 22E -7/14/1997 Y-Tool ESP Completion by Nabors 4ES—1/11/1998 ESP RWO w/5S—4/20/1998 ESP RWO w/4ES—4/5/2001 2 1•82 s' /AI) f� d 3 Q4'Sands , t 5&6 i I 7 ' 'OB'sands r'' a 7"3;;,x, TD=7,385'(MD)/TD=4,636'(TVD) PBTD=7,279'(MD)/PBTD=4,541'(7VD) Created By:TDF 5/13/2015 11" BOP Stack r 1 1111111111 0 iiiii Hydril 11" 5M , , ,iiiii / '( Shaffer0 7F- CO — 2 3/8" Rams 11" 5M _ _ 2 7/8-5.5 0_-4 _ variables Hydril ao11" 5M OD Blinds . 0, _ , , Optional valve port -) iri:ert4-3 t 2' 64 , c a = 01S4 .1 i 0 J A. 0'! :/._1_,4 t 1 J 4;10 . J_ ■ v . A- _ _-01 E-33 \\\ ' 410--'-- -- ---4,11 Q B-09 .„ 1\-' et- A A 1 E-18 ' E-13B N N E-19 E-20AL1 A...1 .. .... IC V \ Q E-20A -44411.1.11441114411""ftim.u............._ : \ 1L1 i I i I I I � - 3A �� I G-03 -19 I - - - - _ 4,, - 1 - I..., 1141-1-t ,- E-15 G-16L1'. v' / I I I i I I E I i T I � I , HILCORP ALASKA LLC r.wru< MILNE POINT FIELD AOR MAP G-02 H-13A • I MPG-11 --------- .. 1...--- — 0 1 05 FEET POSTED WELL DATA S Well Number • N Eio ` e, WELL SYMBOLS • Active Oil D&A 0INJ Well(Water Flood) 0 r S P&A Oil i REMARKS 03 ' / RED DOT=Top Schrader Bluff OA Sand Well Symbol at BHL / i Black Long Dash Oirde=1320 radius from mi i Perfs along wellpath in green / i / April 16,2015 Pages NOT Scanned in this Well History File XHVZE 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. /~'7- l//~' File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Odginal- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type -OVERSIZED [] Logs of vadous kinds n Other COMMENTS: Scanned by: ~y Mitdred-Daretha I~Lowe, TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Damtha Nathan Lowell Date: /si • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder ( Alaska Oil and Gas Conservation Commission pe-11 333 West 7 Avenue M Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -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 • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPG -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPG -01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG -02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG-04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG -05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 MPG -07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 MPG-08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 MPG-09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 MPG-10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 -9 MPG-11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 MPG-12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 MPG-13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 MPG -15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 MPG -16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG-17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 MPG-18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG-19 2041920 50029232280000 _ 1.6 NA 1.6 NA 13.6 8/15/2011 RE: [Fwd: MPG-03A et al] ') ') Subject: RE: [Fwd: MPG-03A et al] From: "Green, Matt D" <GreenMD@BP.com> Date: Wed, 27 Oct 2004 13:21:59 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Walter Quay (Natchiq) (Quay, Walter (Natchiq»" <QuayWD@BP.com>, "Stewman, Sondra D" <StewmaSD@BP .com> Hi Tom, In answer to your question on MPG-11, that well is no longer planned to be converted to injection. In fact, please cancel that sundry #304275 on 15Jul04. The wells G-19 and G-03 will now provide injection to that hydraulic unit when they are drilled next month. We would like to keep MPG-11 shut-in as a surveillance well since it still has a working pressure gauge at the ESP. \,\'\- \\~ Hope this helps! Cheers, Matt -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, October 27, 2004 1:14 PM To: Green, Matt D Subject: [Fwd: MPG-03A et al] -------- Original Message -------- Subject: MPG-03A et al Date: Wed, 27 Oct 2004 08:39:52 -0800 From: Thomas Maunder <tom maunder@admin.state.ak.us> Org ani z at ion: S tat e 0 f Al a ska-.-..........-.....-......."-.....-.--.-" ... To: Wal ter Quay <QuayWD@BP. com> Hi Walter, Some questions on MPG. 1. Has the conversion/workover work on MPG-11 been done yet?? When might it be scheduled?? 2. Has MPG-19 been drilled yet?? Thanks, ~ L {")~~Q:'d . h-. \ Tom ,",C, 'S." '('.c~ SCANNEL; NO'J \) 3 ¿OOL} OCl 2 t1 - (Jl ~ \)t\~ C(þ 1 of 1 10/28/20047:25 AM \<\'ì-\\~ MECR.A.NICAL INTEGRITY REPORT' ...... ~ I ~ -s ~ ~\' ~'\\'4?~ M?C,-\\ :: ? U D D .~- :::: : OPER & FIELD ? ]: G a E ~ =: ;. ::: ;:: . w=:LL NUMBER TD: ~S~HD, 4 b<'~TVD i :?BTD: '\dì'; H1? 4Sl-il TVD Cë.si~g: ~.\ Shoe: '\~~~HD t-tb\l TVD¡ DV: -3-ùb~MD .TVì) _:':1e-z:- : ~ ~ Shoe: HD I'ffi; :OF: I-m :':l!J p\r. """1~ -- . , °D .,-' ~-' 0 _£ .' ~c.. \ . <0<; ~ç '\ t) S \ ~,~.... - 8 oz,/ç;:. P aCKe:::- '1C~ ~. HI) TVTI; Set ê. t. "\ \\ a O~ ~('),-\~-~\)(oç ~Ç) ::ole S:..ze ççl{;:,''''~ 2.na ~~ Perfs t.o Oß \\\~ ~\\~<t; ~ :~ ~LL DAT}.a .', ~Cr~.A.NIC;'~ INTEGRITY - PART /1 't . - ._.~*- ~ ~ t ~ ',~ ~ I (J .~ / h . {, ~ '(í CJ,- ,ee ~(J .~~ ~ e ¡ ..J A' IS ~ - v CONCLUSIONS: ~ i ? art: n: ~ 0 : 2. '). ?ar:: :2: Annulus Press Test: ; 15 min i 30 min :;:'1' COW!Ilents: "\:>\;- --~ S - ~"<~ \. ,-' ~~~" ~t~ \~Â a CO~f)~ ~CHÞ_1\IIC;~ INTEGRITY PART 42 s%(JE 1S0Ç~ C emen t. Volumes :', Amt. Liner W ~ ; Cs g \ ~Ù c..., j DV v ~ (;J CUlt -"01 to cover perf s " l~. '->'-1- 'c-~ ~\\ ~~~.\-'\<..:.\tt.~\- ~ Ct)~<e. ç-- ~'> Q ~O"'2c" S Theoret:ical Toe \<cy\-s\-c..~::'...)~'öe.,,~-\~ c...a..::ß",,>~ ~ \ +0. \~ C:.- Cement Bond Log (Yes or No) "-)'~ ; In AOGCC File' CBL ~valuation, =one aDove perfs Proàu~tion Log: Typ~ Evaluation ~bCJ \~ 07S I (l<i /4- Æ,\< ~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 11104 1, Type of Request: 0 Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Alter Casing II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Change Approved Program 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well Convert to Dual Inj~.£t~ II Other 0 Time ExtenSion 2. Operator Name: BP Exploration (Alaska) Inc, '3. Address: P,O, Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4, Current Well Class: a Development D Exploratory D Stratigraphic D Service 5. Permit To Drill Number 197-119 6. API Number: 50- 029-22781-00-00 99519-6612 KBE = 58.30' 9. Well Name and Number: MPG-11 8, Property Designation: 10, Field 1 Pool(s): ADL 025518 Milne Point Unit 1 Schrader Bluff 11. Total Depth MD (ft): 7385 Casing Structural Conductor Surface Intermediate Production Liner PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD (ft): Plugs (measured): 4636 7279 4541 NI A Length Size MD TVD Burst Junk (measured): N/A Collapse 80' 20" 112' 112' 1490 470 7334' 7" 7364' 4617' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): 7040' a 7138' 4326' - 4414' Packers and SSSV Type: 7" x 3-1/2" Hyd. Baker FB-1 Tubing Size: 2-7/8",6.5#: 3-1/2" BXP Glass Insert Tubing Grade: Tubing MD (ft): L-80 6896';7084' - 7088' Packers and SSSV MD (ft): 7080' 12, Attachments: 1m Description Summary of Proposal D Detailed Operations Program 14, Estimated Date for Commencing Operations: 16, Verbal Approval: Commission Representative: 17, I hereby certif that the foregoing is true and correct to the best of my knowledge, Printed Nam )avid Reem Title Drilling Engineer r:~ D BOP Sketch 13. Well Class after proposed work: D Exploratory D Development 1m Service August20,2004 Date: 15. Well Status after proposed work: DOil DGas D WAG 0 GINJ 0 Plugged aWINJ D Abandoned D WDSPL Contact David Reem, 564-5743 Signature Phone 564-5743 Commission Use Only Prepared By NameINumb&r' Date ~JI$J01- Sondra Stewman, 564-4750 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: 3o<f-~ 7S D Plug Integrity ~OP Test ~echanicallntegrity Test 0 Location Clearance ''''-J þ\. \1:.'Q.. tJ ~\.- \{ Other: b.Wro..)ü \ -\<Ù "f-<:- -\- <"Û\)\~-\ -\U. ,>.~b t'<\\ \-\ \,,~ c. ~\S -\c.,~\'ì \:p ~ \os.. r,,~~~ Vtc."-~ ~ ocr:.cJ) v.J { ~\O \0 \3, ,--SfL JUl 2 1 lOU~ COMMISSIONER APPROVED BY THE COMMISSION Date ~ ItJI V {£m~¡ ~Plicale '-- nD/(:;/NAL Project: l'vlPG-ll Conversion from ESP Producer to Dual Injector ~1PG-II Status: SI (Last production 7/l9/01) -83 bopd. -4 bwpd. -268 GOR (Last test 6/4/2001 ) Scope of \Vork: Assume work will be performed by Doyon 14 I) l'vlIRU Doyon 14 2) Kill \Vell 3) Pull existing ESP (FC925) and Raychem heat trace completion 4) l'v'lill & retrieve Baker F B-1 Packer/tubing tail @' 7080' 1\110 5) Bit 8.: scraper run. and FCO to PBTD 6) Run cement bond log (USIT) to veri fy cement integrity If necessary: a) Cement squeeze b) FCO to PBTD c) Run cement bond log (USIT) d ') Perforate 7) Change out wellhead and tubing hanger 8) Run dual string injection completion 8.: set Baker packers 9,) Install new tree 10) RDIVIO Doyon 14 Pressure: 6/7/2004 1577 psi @ 4197' TVDss = 0.376 psi/ft () .23 ppg) Tree: 2-9/16"- 5M FMC Wellhead: 11"x 5M Mo\ Jre w/ 2-7/8" FMC Tbg. Hng , EUE lift threads, 2-7/8" CIW H BPV profile MPU G-11 Ong. KR elev.= 58.30 (N22E) Orig. ~' :V. = 29.30 (N22E) 27/8" 6,5 ppF, L-80, 8 rd EUE tbg.. ( driFt 10 = 2.347", cap. = 0.00592 bpf) 7" 26 ppf. L-80, Btre, production casing ( dnFt 10 = 6,151 ", cap, = 0,0383 bpF ) Stimulation Summary: 12/26/97 - 'OB' 56,750 Ibs of 16-20 PropLok resm coated 16-20 Carbolite behmd pipe. Screened out on 10 ppg. 12/30/97 - 'OA' - 76,640 Ibs of 16-20 Prop-Lok resin coated 16-20 Carbolite behind pipe. Screened out on 10 ppg, 7" x 21' Marker joint I 6731' I Intake @ 4203' TO Perforation Summary: Ref. Log: GR/CCL 12/14/97 Size SPF (TVO) Interval 'OA' Sand 4,5" 4 7040'-7065' 4326'-4349' 'OB' Sand 4,5" 4 7113'-7138' 4392'-4414' SWS 43C UP ROX big hole charges, 0 to 180 deg. phasing ~ x 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' 1'.- I' I' I' I' 1'- I' I' I' I' I' I' I' ~ ] [ I' ~~ 1'-- I' I' ~~'-"-" 1'- I' I' A ~ .. Camco 2 7/8" x 1" sidepocket KBMM GUvl 139' ~ j Raychem heat trace. 2250' 0 1", HOWCO ES cementer I 2067' I ) Camco 2 7/8" x 1" sidepocket KBMM GLM 6692' I Centrilift 214 Stage FC 925 I GPMTAR 1:2 FRSTXBAR Tandem AR Gas I Separator 2-7/8" HES "XN" Nipple 2.205" 10 6833' 6847' 6867' Intake TVO 4173' CentriliFt 513 series GSBSOB I UT/LT IL AFLAS/HSN Tan- 68ì1' dem Seal Section Centrilift 562 Series 76 HP KMH 1360 V / 34 Amp Motor Centrilift PumpMate and Six Fin Centralizer 6896' PumpMate TVO 4197' 6885' : 1 7,080' Tx 3.5" Hyd. Baker F B-1 3.5" BXP (Broken glass disk) I 7,084' 3.5" wleg 7,088' 5-S tagged TO @7279' DPM 4/98 IT, Landing collar .. T, 26 PPr. L-80 Buttress 7279' md 7364' md DATE REV. BY COMMENTS MILNE POINT UNIT 07/14/97 M, Linder Drilled by Nabors 22-E WELL: MPU Ga11 01 /11 /98 MOO V-Tool ESP Completion 4 ES API NO: 50-029-22781-00 04/20/98 M, Linder RWO Nabors 5-S 04/05/01 B, Hasebe RWO Nabors 4ES BP EXPLORATION (AK) Tree: CIW 2 1/16" 5M ,?llal String MPG-118 Wellhead: 11" x 23/8¡ I 5M FMCDual String Tbg, Hng: 2 3/8" 1ST top and bottom 2" CIW-H SPV profile: ..4 7" 26 ppf. L-80, Strc. (drift ID = 6.151", cap, = 0.0383 bpf) 2-3/8" 4,7#/ft., L-80, TCII tbg. (Dnft ID = 1.901", cap, = 0,00387 bpf) D Stimulation Summary: 12/26/97 - 'OB' 56,750 Ibs, of 16-20 PropLok resin coated 16-20 Carbolile behmd pipe. Screened out on 10 ppg. 12/30/97 - 'OA' - 76,640 Ibs of 16-20 Prop-Lok resin coaled 16-20 Carbollle behind pipe. Screened out on 10 ppg. 7" x 21' Marker Joint X I 6731'1 I~ ~ Perforation Summary: Ref. Log: GR/CCL 12/14/97 ~ Size SPF Interval (TVD) 'GA' Sand 4,5" 4 7040'-7065' 4326'-4349' ~ 'OB'Sand 4,5" 4 7113'-7138' 4392'-4414' SWS 43C UP RDX big hole charges, 0 to 180 deg, phasing ~ ~ 1", Landing collar 7279' md ~ .. 1", 26 ppf, L-80 BuUress 7364' md DATE REV. BY COMMENTS 07/14/97 M, Linder Drilled by Nabors 22-E 01 111 198 MDO Y-Tool ESP Completion 4 ES 04/20/98 M, Linder RWO Nabors 5-S 04/05/01 B. Hasebe RWO Nabors 4ES OW' KB elev.= 58.30 (N22E) Proposed (1 GL lev. = 29.30 (N22E) ~ 0 T, HOWCO ES cementer I 2067' I ~ Short String 2-3/8"HEsx-r'll,pple(1.8iS pkg.bore) I -300û' I Long String 2-3'8"' HES x-~Jlpple (1 875" pk'J bore) I -3000 I Short Strina 2-3/8" HES X-Nipple (1.875" pkg. bore ¡ I 69-13 Long Strina 2-3/8"' HES X-N,pple 1,8 7S" pkg. bore I I 6963' I 7" x 2-3'8' Baker "G l' ReI. dual pkr, I 698S' 1.9..\S"ID, 2-3/8" HES X~J-N'pple (1.8'7S' pkg, bore I I 7029' No-Go 1.791" Tubing tall I WLEG I 7û31 ~ I 7" x 2-3/8" Baker pkr. 1,94S" IDI 7079' 2-3/8" HES XN-Nlpple 11 87S" pkg. bore) I 7108 No.Go 1.791' Tubing laill WLEG I 7110' ~ MILNE POINT UNIT WELL: MPU Ga11 API NO: 50-029a22781-00 BP EXPLORATION (AK) ",......, ~. Subject: RE: Milne Point, G-ll From: "Coyner, Skip (NATCHIQ)" <coynsO@BP.com> Date: Thu, 10 lun 200407:08:50 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> tc\~ -n~ Thanks. s!üp Coyrœr 907-5644395 BPXA 907-748-3689 cell -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, June 09, 2004 3:40 PM To: Coyner, Skip (NATCHIQ) Subject: Re: Milne Point, G-l1 Skip, What you propose should be workable. Logging as you propose, you will be able to verify isolation between the zones and above the upper. If the cement is good on what you log, it is not unreasonable that it will be good below. Tom Maunder Coyner, Skip (NA TCHIQ) wrote: , We're thinking of converting this well into a dual-string OA / OB injector. , The well is currently shut in with the ESP all sanded up. We already have an FB-1 PKR in place between the OA and OB sands. We plan to run a US IT log to evaluate the cement coverage as required. Question: would it suffice to run the US IT log above the FB-1 PKR only (across the OA only), or must we drill out the FB-1 PKR and log the whole interval? : Again, we do plan on injecting into both sands. The sands are +/- 50' TVD apart and they were frac'd separately. s!üp Coyrœr . ~ ~~~; Energy ServIce. 907-564-4395 BPXA 907-748-3689 cell I of I 6/1 0/2004 II :29 AM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2 001. M p l A T E E IA L U N D W T H IS M ARK ER C:LORIkMFILM.DOC STATE OF ALASKA ALASKA _AND GAS CONSERVATION COMM, REPORT OF SUNDRY WELL OPERATIONS .,ION 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP !2. Name of Operator 15. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 58.3' [] Exploratory 7. Unit or Property Name i3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1724' NSL, 3357' WEL, SEC. 27, T13N, R10E, UM MPG-11 At top of productive interval 9. Permit Number / Approval No. 197-119 3184' NSL, 1118' EWL, SEC. 26, T13N, R10E, UM 10. APl Number At effective depth 50-029-22781-00 3218' NSL, 1220' EWL, SEC. 26, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 3233' NSL, 1264' EWL, SEC. 26, T13N, R10E, UM 12. Present well condition summary Total depth: measured 7385 feet Plugs (measured) true vertical 4636 feet Effective depth: measured 7279 feet Junk (measured) true vertical 4541 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arctic Set I (Approx) 112' 112' Surface Intermediate Production 7334' 7" 1185 sx PF 'E', 130 sx Class 'G' 7364' 4617' Liner Perforation depth: measured open: 7040' - 7065', 7113' - 7138' true vertical open: 4326'- 4348', 4392' - 4414' R E C E IVE D Tubing(size, grade, andmeasureddepth) 2-7/8",6.5#,b-80to6896' M,~ Y 0 .~ 2001 Alaska Oil & Gas Cons. Commission Packers and SSSV (type and measured depth) None A~horage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection 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 fore_g.oing is true and correct to the best of my knowledge Signed Sondr Title Technical Assistant Date ~ ~'-' (~) l --(~) j Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate ~ ~~:~BP ~PLoRATION Page 1 of 1 SUmmary Report Legal Well Name: MPG-11 Common Well Name: MPG-11 Spud Date: 71611997 Event Name: WORKOVER Start: 4/1/2001 End: 41212001 Contractor Name: NABORS Rig Release: 4/3/2001 Group: RIG Rig Name: NABORS 4ES Rig Number: ' From- To ~ours Tas~i (~&be PhaS~ '~ii i~il Description of Operations 4/1/2001 04:00 - 13:00 9.00 RIGU PRE MI/RU & RAISE & SCOPE DERRICK & LEVER & BERM SAME. 13:00 - 16:30 3.50 KILL DECOMP RIG TIGER TANK & LINES TO TREE & TEST TO 3500 PSI. & TAKE ON FLUID. & RIG LUBRICATOR & PULL BPV. TBG= 1080# & ANNULUS= 1010 PSI. 16:30 - 20:30 4.00 KILL DECOMP CIRC. INFLUX FROM WELL BORE WITH 8.5 PPG. SEAWATER 20:30 - 21:00 0.50 WHSUR DECOMP SET TWC & ND TREE. 21:00 - 23:00 2.00 BOPSUF DECOMP ~NIPPLE UP BOP 23:00 - 00:00 1.00 BOPSUF DECOMP TEST BOP TO 250-& 3500 (TEST WAIVED BY CHUCK SHEVE WITH AOGC. 4/2/2001 00:00 - 02:00 2.00 BOPSUF DECOMP TEST BOP'S TO 3500 PSI. TEST WAIVED BY CHUCK SHEVE WITH AOGC 02:00 - 03:30 1.50 BOPSURr DECOMP PULL TWC & PULL HANGER TO FLOOR & LAY DN SAME. 03:30 - 12:30 9.00 PULL ! DECOMP PULL ESP COMPLETION & LAY DN SAME. 12:30 - 00:00 11.50 RUNCOI¥1 COMP PREPARE EQUIPMENT & MAKE UP ESP ASSY & RIH WITH SAME STARTING HEAT TRACE AT 2250' FROM SERVICE. '4/3/2001 00:00 - 11:00 11.00 RUNCOr~I COMP CONTINUE TO SPLICE ESP & HET TRACE & TEST SAME & LAND HANGER & RILDS. & SET TWC & TEST SAME. 11:00- 13:00 2.00 BOPSUF; COMP NIPPLE DOWN BOP 13:00-15:00 2.00 WHSUR COMP NIPPLLE UP TREE & TEST TO 5000 PSI. & PULL TWC & SET BPV & SECURE TREE & RELEASE RIG @ 1500 HRS. 4/3/2001 I Printed: 4/12/2001 10:04:44 AM Well Report t,~omp. 01 /03 /1998 MILNE POINT UNIT SB G-11 Completion Status: 1-OIL Current Status: 029-22781-00 197-119-0 BP EXPLORATION MD 07385 TVD 04636 Name Interval Sent Received BOX 8095 C,,d~ SPERRY MPT/GR/EWR4 9/10/97 9/10/97 DGR/EWR4-MD cL-"~INAL 4534-7385 9/17/97 9/17/97 DGR/EWR4-TVD C.L,'/'FINAL 2940-4636 9/17/97 9/17/97 MWD SRVY ~ SPERRY 00-7385.00 3/2/98 3/2/98 PERF ¢.~"FINAL 5500-7250 ] ,/"-//7. ~/~,~ ~ 1/21/98 1/29/98 PERF ~'"'~INAL 5500-7240 12/29/97 1/21/98 1/29/98 STAT PRES SRVY t~F~ TEM 550-7250 1/21/98 1/29/98 .a.y W l. Was the well cored? yes Are Dry Ditch Samples Required? yes ~ And Received.°-3't~,-m~-~ Analysis Description Receiv ~edZ--y~---no .... Sample Set # ' Comments: Monday, January 10, 2000 Page 1 of 1 STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [~.Pull Tubing E~]Alter Casing [] RepairWell []Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1724' NSL, 3357' WEL, SEC. 27, T13N, R10E, UM At top of productive interval 3185' NSL, 1116' EWL, SEC. 26, T13N, R10E, UM At effective depth 3220' NSL, 1217' EWL, SEC. 26, T13N, R10E, UM At total depth 3235' NSL, 1261' EWL, SEC. 26, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RTE = 58.3' 7. Unit or Property Name Milne Point Unit 8. Well Number MPG-I 1 9. Permit Number / Approval No. 97-119 10. APl Number 50- 029-22781 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 7385 feet true vertical 4578 feet Effective depth: measured 7279 feet true vertical 4483' feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 80' 20" 7334' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (Approx) 1185 sx PF 'E', 130 sx Class 'G' MD TVD 112' 112' 7364 4559' Perforation depth: measured true vertical 7040' - 7065', 7113'- 7138' (Subsea) 4268' - 4290', 4333' - 4356' Tubing (size, grade, and measured depth) 2 7/8" 6.5 ppf L-80 tubing to 6841' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~~..~%.,,'~ .~,,¢~.~,.~.,42~j Title Staff Technical Assistant Prepared By Name/Number: Date Jeanne Haas, 564-/5225 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11734 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anch0.rage, AK 99501 Milne Point (Cased Hole) 1/21/98 Well Job # Log Description Date BL RF Sepia LIS Tape MPB-25 PERFORATION RECORD 9 8 0101 1 1 MPU C-15 INJECTION PROFILE 971 124 I 1 MPG-11 STATIC PRESSURE SURVEY 9 71 2 2 3 I 1 MPG-11 PERFORATION RECORD 9 71 2 2 3 I 1 MPG-11 PERFORATION RECORD 9 71 2 2 9 I 1 MPG-12 PERFORATING RECORD 9801 10 1 1 MPG-12 PERFORATING RECORD 9 8 01 13 I 1 MPG-12 PERFORATING RECORD 9 8 01 1 6 I 1 MPJ-17 RFT 971 1 1 6 I 1 MPJ-17 PERF RECORD 971 1 1 9 I 1 MPJ-17 CHEMICAL CUT RECORD 971 1 1 9 I 1 M PK-34 PERFORATION RECORD 9 71 1 17 I 1 M P K-34 SUMP PACKER SET RECORD 9 71 1 17 I 1 MPL-35 TCP GR TIE IN W/PRESS-TEMP 971 207 I I . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG · . I Status of Well Classification of Service Well,. [~Oil ~]Gas []Suspended [~Abandoned ~Service .... :' i· 2. Name of Operator 7. Permit Number BP Exploration (Alaska)inc. 97-119 3. Address 8. APl Number · ". ,',.. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22781 "~ 4. Location ofwell at surface '~ ~ ~ .... :' 'J;f,I;;;~~J 9. Unit or Lease Name 1724' NSL, 3357' WEL, SEC. 27, T13N, R10E, UM .... ..i.' .... ~.; I '"¢''~rlI Milne Point Unit At top of productive interval At total depth ~ ~ ~ M 7~'~¢~'~'~': ~~ 1'i. Field and Pooll0' Well Number 3185' NSL, 1116' EWL, SEC. 26, T13N, R10E, U ~ - MPG-11 , 3235' NSL, 1261 EWL, SEC. 26, T13N, R10E, ,. :. '¢ Milne Point Unit / Schrader Bluff 15. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. KBE = 58.3' .I ADL 025518 12. Date Spudded7/6/97 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre I 16' NO' Of COmpletiOns7/10/97 1/3/98 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+-i-VD)J19. Directional Survey J20. Depth where sSsv set J21. Thickness of Permafrost 7385 4636 FTI 7279 4541 FT1 [~Yes E~ NoI N/A MD I 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, GR/CCL . . 23. CASING¢ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.4# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 30' 7364' 8-1/2" 1185 sx PF 'E', 130 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 6905' MD TVD MD TVD 3-1/2" BXP glass insert sub 7084'-7088' 7080' 7040'-7065' 4326 '-4434' 7113'-7138' 4478'-4414' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 65 bbls diesel Prop Lok Frac, 7113'-7138' 56,750# 1 6/20 Carbolite behind pipe Prop Lok Frac, 7040'-7065' 76,640#, 16/20 Carbolite behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) January 27, 1998 J Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure OALCULATED OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORI¢INAL ................ %~Jhmit In Duolicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TSBD 7032' 4319' TSBC 7071' 4354' TSBB 7110' 4389' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord .~,/¢//dr,~¢~ ~-' . Title Engineering Supervisor Date MPG-11 97-119 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: if this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. r-,-,.,~ in 4F~7 I~/ nT_nl_nn Facility M Pt G Pad Progress Report Well MPG-11 Rig Nabors ~'"' Page Date 1 18 February 98 Date/Time 05 Jul 97 06 Jul 97 07 Jul 97 08 Jul 97 09 Jul 97 10 Jul 97 11 Jul 97 17:00-00:00 00:00-05:00 05:00-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-09:30 09:30-10:00 10:00-11:00 11:00-18:00 18:00-06:00 06:00-09:30 09:30-10:00 10:00-11:00 11:00-11:30 11:30-12:30 12:30-22:00 22:00-23:00 23:00-01:00 01:00-01:30 01:30-03:30 03:30-04:30 04:30-06:00 06:00-12:30 12:30-14:30 14:30-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-23:00 23:00-23:30 23:30-06:00 06:00-07:00 07:00-08:30 08:30-09:00 09:00-11:00 11:00-14:00 14:00-15:30 15:30-20:00 20:00-21:30 21:30-04:00 04:00-05:30 05:30-06:00 06:00-08:00 08:00-08:30 08:30-09:00 09:00-10:00 10:00-18:30 18:30-20:30 20:30-00:00 00:00-00:30 00:30-03:30 03:30-05:30 05:30-06:00 Duration 7 hr 5 hr 1 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 1/2 hr lhr 7 hr 12 hr 3-1/2 hr 1/2 hr 1 hr 1/2 hr 1 hr 9-1/2 hr 1 hr 2 hr 1/2 hr 2 hr 1 hr 1-1/2 hr 6-1/2 hr 2 hr 3-1/2 hr 1/2 hr 2 hr 1/2 hr 2 hr 1/2 hr 6-1/2 hr 1 hr 1-1/2 hr 1/2 hr 2 hr 3 hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 6-1/2 hr 1-1/2 hr 1/2 hr 2 hr 1/2 hr 1/2 hr 1 hr 8-1/2 hr 2 hr 3-1/2 hr 1/2 hr 3 hr 2 hr 1/2 hr Activity Rig moved 100.00 % Installed Divertor Made up BHA no. 1 Held safety meeting Made up BHA no. 1 Made up BHA no. 1 Tested Divertor Functioned downhole tools at 112.0 ft Made up BHA no. 1 Rig waited: Production facilities Drilled to 1654.0 ft Drilled to 2125.0 ft Circulated at 2115.0 ft Pulled out of hole to 91.0 ft Serviced Top drive R.I.H. to 2115.0 ft Drilled to 3500.0 ft Circulated at 3500.0 ft Pulled out of hole to 1654.0 ft Serviced Top drive motor R.I.H. to 3500.0 ft Circulated at 3500.0 ft Drilled to 3680.0 ft Drilled to 4536.0 ft Circulated at 4536.0 ft Pulled out of hole to 90.0 ft Pulled BHA Made up BHA no. 2 Serviced Crown block R.I.H. to 4250.0 ft Washed to 4536.0 ft Drilled to 5507.0 ft Circulated at 5507.0 ft Pulled out of hole to 4300.0 ft R.I.H. to 4682.0 ft Reamed to 5507.0 ft Drilled to 5698.0 ft Held safety meeting Drilled to 6078.0 ft Held safety meeting Drilled to 6747.0 ft Circulated at 6747.0 ft Pulled out of hole to 5817.0 ft Pulled out of hole to 4743.0 ft (cont...) Serviced Top drive R.I.H. to 5570.0 ft Reamed to 6747.0 ft Drilled to 7385.0 ft Circulated at 7385.0 ft Pulled out of hole to 0.0 ft Serviced Top drive R.I.H. to 7385.0 ft Circulated at 7385.0 ft Pulled out of hole to 5900.0 ft Facility M Pt G Pad Progress Report Well MPG- Rig Nabors Page Date 2 18 Fcbruary 98 Date/Time 12 Jul 97 06:00-07:30 07:30-11:30 11:30-12:30 12:30-14:00 14:00-17:00 17:00-19:00 19:00-20:00 20:00-20:30 20:30-06:00 06:00-06:15 06:15-08:30 08:30-09:30 09:30-10:00 10:00-12:30 12:30-14:30 14:30-18:00 18:00-19:30 19:30-23:30 23:30-01:00 Duration 1-1/2 hr 4 hr 1 hr 1-1/2 hr 3 hr 2 hr 1 hr 1/2 hr %1/2 hr 1/4 hr 2~1/4 hr 1 hr 1/2 hr 2-1/2 hr 2 hr 3-1/2 hr 1-1/2 hr 4hr 1-1/2 hr Activity Pulled out of hole to 3052.0 ft Repaired Draw works R.I.H. to 7385.0 ft Circulated at 7385.0 ft Pulled out of hole to 745.0 fl Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 7in (7332.0 ft OD) Ran Casing to 7363.8 ft (7in OD) (cont...) Circulated at 7363.8 ft Mixed and pumped slurry - 175.000 bbl Displaced slurry - 278.000 bbl Circulated at 2067.0 ft Mixed and pumped slurry - 410.000 bbl Rigged down Cement head Removed Divertor Installed Xmas tree Cleared Header box Facility M Pt G Pad Progress Report Well MPG-11 Rig Nabors 4ES Page Date 1 18 February 98 Date/Time 21 Dec 97 22 Dec 97 23 Dec 97 24 Dec 97 25 Dec 97 26 Dec 97 27 Dec 97 28 Dec 97 06:00-14:30 14:30-15:30 15:30-16:30 16:30-18:00 18:00-22:00 22:00-03:30 03:30-06:00 06:00-08:00 08:00-09:00 00:30-01:00 15:30-17:00 03:30-06:00 06:00-12:00 12:00-20:00 20:00-21:00 21:00-23:00 23:00-06:00 06:00-08:00 08:00-08:30 08:30-11:30 11:30-18:30 18:30-22:00 22:00-01:00 01:00-03:00 03:00-06:00 06:00-06:30 06:30-15:00 15:00-16:30 16:30-17:00 17:00-22:00 22:00-02:30 02:30-06:00 06:00-09:00 09:00-10:30 10:30-11:00 11:00-11:30 11:30-12:00 12:00-14:30 14:30-t6:30 16:30-17:30 17:30-18:00 18:00-19:00 19:00-23:30 23:30-00:30 00:30-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-11:00 11:00-14:30 14:30-15:30 15:30-16:30 16:30-19:30 19:30-23:30 Duration 8-1/2 hr 1 hr 1 hr 1-1/2 hr 4 hr 5-1/2 hr 2-1/2 hr 2 hr 1 hr 1/2 hr 1-1/2 hr 2-1/2 hr 6 hr 8 hr 1 hr 2 hr 7 hr 2 hr 1/2 hr 3 hr 7 hr 3-1/2 hr 3hr 2 hr 3 hr 1/2 hr 8-1/2 hr 1-1/2 hr 1/2 hr 5 hr 4-1/2 hr 3-1/2 hr 3hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2 hr 1 hr 1/2 hr 1 hr 4-1/2 hr 1 hr 3-1/2 hr 2 hr 1/2 hr 1-1/2 hr 3 hr 3-1/2 hr 1 hr 1 hr 3 hr 4 hr Activity Rig moved 100.00 % Rigged up Drillfloor / Derrick Removed Xmas tree Rigged up All rams Rigged up All rams Tested All rams Rigged up All rams Installed Drillstring handling equipment Made up BHA no. 1 Made up BHA no. 2 Perforated Ran Tubing to 2350.0 ft (3-1/2in OD) Ran Tubing to 6613.0 ft (3-1/2in OD) Rigged up High pressure lines Held safety meeting Serviced Additional services Mixed and pumped 60.000 bbl of treatment Monitor pressures Mixed and pumped 103.000 bbl of treatment Reverse circulated at 6613.0 ft Reverse circulated at 7238.0 ft Circulated at 7238.0 ft Rigged up High pressure lines Mixed and pumped 582.000 bbl of treatment Reverse circulated at 6613.0 ft Held safety meeting Monitor wellbore pressures Circulated at 6613.0 ft Held safety meeting Pulled Tubing in stands to 0.0 ft R.I.H. to 6903.0 ft Reverse circulated at 7033.0 ft Reverse circulated at 7241.0 ft Reverse circulated at 7241.0 ft Held safety meeting ,.... Pulled out of hole to 6241.0 ft ~ .' ~.: ' : Serviced Block line "'~- Pulled out of hole to 0.0 ft Ran Drillpipe to 340.0 ft (3-1/2in OD) Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 340.0 ft Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe in stands to 7090.0 ft Set Bridge plug at 7090.0 ft with 3500.0 psi Pulled Drillpipe in stands to 0.0 ft Ran Drillpipe in stands to 1860.0 ft Held safety meeting Ran Drillpipe in stands to 7113.0 ft Pulled Drillpipe in stands to 0.0 ft R.I.H. to 7128.0 ft Reverse circulated at 7128.0 ft Serviced Block line Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 7080.0 ft Facility M Pt G Pad Progress Report Well MPG- 11 Rig Nabors 4ES Page Date 2 18 February 98 Date/Time 29 Dec 97 30 Dec 97 31 Dec 97 01 Jan 98 02 Jan 98 03 Jan 98 23:30-02:30 02:30-06:00 06:00-10:30 10:30-13:30 13:30-16:30 16:30-17:00 17:00-03:00 03:00-03:30 03:30-06:00 06:00-06:30 06:30-09:30 09:30-12:00 12:00-12:30 12:30-19:00 19:00-23:30 23:30-02:30 02:30-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-14:00 14:00-18:30 18:30-22:30 22:30-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-09:30 09:30-10:00 10:00-12:00 12:00-15:00 15:00-19:00 19:00-01:00 01:00-03:30 03:30-06:00 06:00-06:30 06:30-11:30 11:30-14:30 14:30-20:00 20:00-21:00 21:00-06:00 06:00-08:00 08:00-10:30 10:30-11:30 11:30-14:30 14:30-16:30 16:30-19:00 19:00-21:00 Duration 3 hr 3-1/2 hr 4-1/2 hr 3 hr 3 hr 1/2 hr 10 hr 1/2 hr 2-1/2 hr 1/2 hr 3 hr 2-1/2 hr 1/2 hr 6-1/2 hr 4-1/2 hr 3 hr 3-1/2 hr 1/2 hr 3-1/2 hr 1 hr 3 hr 4-1/2 hr 4 hr 5 hr 1-1/2 hr 1 hr 1/2 hr 3 hr 1/2 hr 2 hr 3 hr 4 hr 6 hr 2-1/2 hr 2-1/2 hr 1/2 hr 5 hr 3 hr 5-1/2 hr 1 hr 9 hr 2 hr 2-1/2 hr 1 hr 3 hr 2 hr 2-1/2 hr 2 hr Activity Pulled Drillpipe in stands to 0.0 fl Perforated Perforated from 7040.0 fl to 7065.0 ft Ran Tubing in stands to 6613.0 ft Tested Testing equipment Held safety meeting Mixed and pumped 1040.000 bbl of treatment Reverse circulated at 6613.0 ft Monitor pressures Held safety meeting Monitor pressures Reverse circulated at 6613.0 ft Held safety meeting Laid down 6613.0 ft of Tubing Tested BOP stack R.I.H. to 6755.0 ft Reverse circulated at 6850.0 fi Held safety meeting Reverse circulated at 7080.0 ft Reverse circulated at 7080.0 ft Pulled out of hole to 0.0 ft R.I.H. to 7080.0 ft Pulled out of hole to 0.0 ft Set packer at 7090.0 ft with 2000.0 psi Reverse circulated at 7080.0 ft Laid down 500.0 ft of Drillpipe Held safety meeting Laid down 4000.0 ft of Drillpipe Serviced Block line Laid down 7080.0 ft of Drillpipe Worked on BOP - Pipe ram Installed ESP Serviced ESP Installed ESP Ran Tubing to 600.0 ft (2-7/8in OD) Held safety meeting Ran Tubing to 4603.0 ft (2-7/8in OD) Conducted electric cable operations Ran Tubing to 5517.0 ft (2-7/8in OD) Conducted electric cable operations Ran Tubing to 6850.0 ft (2-7/8in OD) Ran Tubing to 6905.0 ft (2-7/8in OD) Installed Tubing hanger Rigged up Tubing hanger Rigged down BOP stack Installed Tubing head spool Circulated at 6905.0 ft Removed High pressure lines Facility Date/Time 13 Apr 98 14 Apr 98 15 Apr 98 16 Apr 98 17 Apr 98 M Pt G Pad Progress Report Well MPG-11 Page 1 Rig Nabors 5S Date 21 April 98 Duration Activity 06:00-12:00 12:00-18:00 18:00-21:30 21:30-03:00 03:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-12:30 12:30-15:30 15:30-17:00 17:00-18:00 18:00-19:00 19:00-20:00 20:00-23:00 23:00-02:30 02:30-05:30 05:30-06:00 06:00-06:15 06:15-11:30 11:30-17:30 17:30-18:00 18:00-18:15 18:15-21:30 21:30-01:30 01:30-02:30 02:30-04:00 04:00-05:30 05:30-06:00 06:00-06:15 06:15-10:30 10:30-14:30 14:30-15:00 15:00-15:30 15:30-06:00 06:00-06:00 06:00-06:15 06:15-08:00 08:00-12:00 12:00-13:00 13:00-15:00 15:00-18:30 6hr 6hr 3-1/2 hr 5-1/2 hr 3hr 2hr lhr lhr 2-1/2 hr 3hr 1-1/2 hr lhr lhr lhr 3hr 3-1/2 hr 3hr 1/2 hr 1/4 hr 5-1/4 hr 6hr 1/2 hr 1/4 hr 3-1/4 hr 4hr lhr 1-1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 4-1/4 hr 4hr 1/2 hr 1/2 hr 14-1/2 hr 24 hr 1/4 hr 1-3/4 hr 4hr lhr 2hr 3-1/2 hr Rig moved 100.00 % Rig moved 100.00 % Removed Hanger plug Repaired High pressure lines Circulated at 6900.0 ft Circulated at 6900.0 ft Rigged up Hanger plug Removed Xmas tree Rigged up All rams Tested BOP stack Removed Hanger plug Removed Tubing hanger Removed Tubing hanger Rigged up Completion string handling equipment Pulled Tubing in stands to 2250.0 ft Pulled Tubing in stands to 6900.0 ft Laid down 0.0 ft of Tubing Laid down 0.0 ft of Tubing Held safety meeting Ran Tubing in stands to 7025.0 ft Washed to 7094.0 ft Flow check Held safety meeting Pulled Tubing in stands to 0.0 ft Ran Tubing to 7094.0 ft (2-1/16in OD) Washed to 7098.0 ft Installed Swivel Removed Swivel Ran Tubing to 7150.0 ft (2-1/16in OD) Held safety meeting Reverse circulated at 7247.0 ft Pulled Tubing in stands to 200.0 ft Laid down 200.0 ft of Tubing Serviced Tubing handling equipment Ran Tubing in stands to 6900.0 ft Ran Tubing in stands to 6900.0 ft (cont...) Held safety meeting Ran Tubing in stands to 6900.0 ft Space out tubulars Installed Hanger plug Removed BOP stack Installed Xmas tree Milne Point Unit, Alaska TO: Bill Hill FROM: Herb Thackeray Well Name: IMp G-11 Main Category:tE-LINE Sub Category: PERF Operation Date: I12/23-24/97 Date: 112/24/97 Objective: Run GR/CCL for primary depth control, pedorate "OB" sand, record static BHP. Sequence of Events: MIRU SWS. PJSM. Request radio silence. PT to 1000 psi. RIH w/15' of 4-1/2" guns & logging tools on rollers. No problems getting through 73 degree hole. Ran GR/CCL from log TD 7273' to 5500'. Correlate lithology to Sperry LWD log (1' difference). Perforate 7123-7138' with 4 spf 180 degree phasing. POOH, all shots fired. RIH w/10' of 4-1/2" guns & logging tools on rollers. Correlate and perforate 7113-7123' with 4 spf 180 degree phasing. POOH, all shots fired. Lift radio silence. RIH with pressure/temp tools to 7130' for 1-1/2 hours. Pressure stable @ 2009 psi. POOH. RD SWS. Results: Ran G R/CCL from 7273-5500', perforated "OB" sand from 7113-7138' with 4 spf 43C UP RDX charges at 0-180 degree phasing in 2 runs, measured SBHP @ 7130' = 2009 psi. NOTE: Petredat rep programmed gauge to monitor frac job and HES S/L crew installed in GLM in pipe shed to run with 3-1/2" tubing. Tie in log/date_Sperry LWD .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 17113 7138 4-1/2 4 spf 0-180 I Milne Point Unit, Alaska TO: Bill Hill FROM: Herb Thackeray Well Name: tEM_PLI~-E11 Main Category: Sub Category: PERF Operation Date: Date: [12/30/97 Objective: Perforate "OA' sand,. Sequence of Events: MIRU SWS. PJSM. Request radio silence. PT to 1000 psi. RIH w/25' of 4-1/2" guns & logging tools on rollers. Correlate to SWS GR/CCL 12/23/97. Tag sand on RBP @ 7074'. Perforate "OA" sand 7040-7065' with 4 spf 180 degree phasing. POOH, all shots fired. Lift radio silence. RD SWS. Results: Perforated "OA" sand from 7113-7138' with 4 spf 43C UP RDX charges at 0-180 degree phasing in 2 runs, measured SBHP @ 7130' = 2009 psi. Tie in log/date SWS GR/CCL 12/23/97 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation Phasing 7040 7065 4-1/2 4 spf 0-180 , , , BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: J. Spearman / B. Hill FROM: J. Fox DATE: 12/29-30/97 RE: G-11 'OA' DATA FRAC AND PROP-LOK FRAC .~'.i ,. SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak JOB SUMMARY The frac resulted in getting 76,640 lbs of PropLok resin coated 16-20 Carbolite proppant behind pipe out of a designed vol. of 80 M#. The treatment screened out (with little warning) with approx. 130 bbls. of the 10 ppg stage into the formation. There was an approx. 300 psi of net pressure build between the time proppant hit the perfs, until just before completely screening off. A Nolte Smith plot was not available to indicate exactly when TSO initiated. Prior to the refrac a 100 bbl. (40 bbl. HEC gel and 60 bbl. water) flush was made in an attempt to break down and clean up the perfs. Near wellbore friction pressures were significantly reduced relative to the data frac as indicated by the NWFP being reduced by 120 psi to 110 psi. There were three pre-frac tests performed; a 30 bbl. impulse test, a 20 bbl. (Iow rate) matrix pressure falloff, and a 125 bbl. data frac. All three were performed with water only. Notes: · Blue dye was added to the PropLok resin. The blue color on the sand will be utilized in the future to distinguish where produced proppant originated from. The "OB" was not dyed and will be distinguished by it's natural color. · Prior to the pre-frac testing the 8.7 ppg brine was circulated out of the wellbore with 2% KCI water to give a constant hydrostatic on the tubing. This in hopes of preventing inconsistencies previously experienced in the pressure falloff data which were attributed to fluid swapping out. Cold weather ( - 30 deg. ) created the usual complications but were effectively managed by the Dowell / Halliburton crews. During the perforation flush / gel breakdown, the initial attempts to come up to max. rate resulted in pump cavitation. Loss of suction pressure to the pumps was experienced at rates greater than 15 bpm until tanks were switched to KCI. This is suspected to be due to a partial plugging of the gel tank suction line. When the wellbore screened out during frac the pop off valve appeared to relieve but pressures greater than the pop off pressure setting remained on the annulus. It is suspected that the discharge line between the pop off and the tank may have been restricted by ice accumulation. The Petredat gauge was set up for continuous 15 sec. readings starting at 2000 on 12/28 and running for 60 hours. All of the data frac / frac should have been recorded. There was some pulsation of the treating lines that were effectively mitigated by the Dowell crew. The size of the data frac and frac design was increased due to the higher leakoff than expected on the impulse test. Add'l gel had to be built for this same reason. This caused only a slight delay as MI was utilized to build the gel. O3/O2/98 4:09 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL II TIMEI RATE ANNP WHP STAGE BPM PSIG PSIG BBL PUMPING SUMMARY COMMENTS CUM BBL · 30 bbl. of fluid was pumped during the impulse test rather than 20 bbl. design inadvertantly. · Dowell Iow rate pump was not available. Opted to attempt minimum rate with frac pump. With little to no surface pressure minimum rate was approx. 1.7 bpm. The formation did not appear to part at this rate / pressure so this posed no problem. _- After the impulse test the formation would not support a fresh water gradient fluid column and went on a vacuum. The pressure falloffs fell below 0 psi at surface but were not terminated at that point in order to capture the pressures on the downhole pressure gauge. IMPULSE TEST Design Rate, Bbls Max Rate, Final lAP, ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 10 to 15 20 15.8 1190 820 370 0.71 DATA FRAC Bbls Bbls KCI wtr. Time KCI wtr. Final STP, ISlP, psi NWB Treat grad, Pumped on Perfs on perfs psi friction, psi psi/ft 125 20 1:40 1170 850 250 0.70 PERF. FLUSH / GEL BREAKDOWN Design Rate, Bbls Max Rate, Final lAP, ISlP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft max. 40 HEC/ 24.6 1013 @ 12 900 113 0.67 60 KCl bpm FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind behind pipe, Liner Sand, rubber left Job was (lbs.) (lbs. pipe, M# (lbs.) (lbs.) in hole? /size) /size screened out 79,180 56,750/16-20 n/a 80,000 22,430 n/a w/PropLok Page 3 l' DATE/TIME OPERATIONS SUMMARY 12/28/97 2000 Petredat gauge start on 15 sec. recording interval for 60 hr. period. 12/29/97 1400 3.5", 9.2 ppf tbg. in place w/tubing tail at 6613' MD and Petredat gauge at 6561'. Finish rigging up Dowell treating lines. 1515 Hold pre-job safety meeting. 1630 Pumps primed. Start pressure test to 6200 psig. - ok. 1640 Start circulating in KCI water at 8 bpm with 840 psig treating pressure and 111 psi lAP. Taking 8.9 ppg brine returns through choke. 1710 W/250 bbls pumped (20 bbl. overdisplacement) S/D pumps, close choke and pipe rams. 25 psi surface pressure both sides . . 1713 Start Impulse test w/2% KCI water. Bring pumps us as quickly as possible to a rate of 15.5 bpm and hold. 30 bbls. pumped. At rate w/5 bbls. away. 1715 S/D pumps - monitor pressure falloff. ISIP = 820 psig. With well shut it at rig floor freeze protect treating lines w/diesel. Continue monitoring falloff pressures for 1.5 hours. 1820 Well on vacuum. Continue PFO as data will still be recorded on the downhole gauge. 1850 Start 20 bbl KCI matrix injection. Pump at minimum rate with frac pump. With well on vacuum rate was up to 3 + bpm. 1900 S/D matrix injection and monitor falloff pressures for two hours. 2104 Start pumping 125 bbl. KCl data frac. Up to design rate of 12 bpm w/5 bbls. away. 2114+ S/D pumps to monitor pressure falloff for two hours. Extend survey while add'l gel is being mixed and transported. 12/30/97 0131 Start bullhead displacement vol. of KCI water, 40 bbl. HEC gel, 60 bbl. KCI water and displace into the formation. Unable to reach max. rate initially due to suspected restriction (ice plug) in the gel tank suction line. Once on KCI water full rate (4500 psig STP was targeted) was established. 0142 S/D pumps and monitor pressure falloff for 15 min. ISIP = 900. NWFP = 113 psi. 0208 Start pumping gel pad for revised frac design. 0247 S/D pump #2. 0252 Wellbore screened out. S/D pumps. Rig up to reverse out tubing. PUMPING SUMMARY TIME I RATE ANNP WHP STAGE CUMI COMMENTS BPM PSIG PSIG BBL BBL 12/27/97 IMPULSE TEST DISPLACEMENT = 74.2 BBLS I 1713 [ 0 / 15 24 25 0 250.9 Prepare to start impulse test. r 1713 15.0 1288 3023 4 255 At rate. 1714 15.6 1196 3042 20 , 270.2 1715 15.8 1183 3051 30 280.3 S/D pumps and monitor pressure falloff. ISIP - 820 psig 1716 0 720 744 1717 0 670 679 ~1720 0 514 519 1725 0 317 322 1730 0 212 217 1740 0 125 135 1800 0 47 52 1820 0 I 7 Well on vacuum. MATRIX PRESSURE FALL¢ ~FF 1848 0 vac vac 0 280.5 Prepare to start pumping. 1849 1.9 734 812 1.5 282 1851 1.7 830 831 5 285 1855 1.5 926 908 11 292 1900 1.5 972 1046 19 299 1901 1.7 / 0 956 918 20 299.8 S/D pumps and monitor pressure falloff. 1902 0 619 657 1905 0 455 I 483 1910 0 290 322 1920 0 I 157 [ 185 1940 0 f 56 I 89 2000 0 15 43 2030 0 -12 2 Well on vacuum , DATA FRAC 2103 0 vac vac 0 299.8 Prepare to stad data frac. ~2104 3.6 789 936 1.4 301 2105 12.2 1118 2309 12 312 2106 12.2 1077 2218 24 324 2107 11.9 1096 2208 35 335 2108 12.2 1118 2240 48 348 2109 11.9 1105 2204 60 360 2110 12.2 1109 2204 73 373 2112 12.1 1105 2144 95 395 2113 12.1 1082 2135 107 407 2114 12.1 1082 2149 119 419 2114.5 12.1 I 1082 2167 125.7 425.5 S/D pumps and monitor pressure falloff. ISIP = 850, NWFP = 232 psi 2116 I 0 , 821 808 I o 2130 0 706 712 2146 0 523 524 22OO 0 381 373 223O 0 217 2O8 2300 0 139 135 2330 0 88 94 2358 0 7O 57 FRAC 0131 0 11 11 0 0 Prepare to start pumping 40 bbl. gel breakdown / perf, flush. 0132 5 958 1087 7 Having problem getting suction at high rates. 0134 15 1105 3547 26 Increasing rate but still having problems reaching high rates w/o pump cavitation. 0135 11 1082 2483 40 Switch to water. 0137 24.6 1192 3724 74 Gel on perfs. 0139 18.9 1210 3454 114 Water on perfs 0140 21.1 1205 4196 133 0141 12 1027 2076 156 Slow rate down to 12 bpm to compare NWFP with data frac. 0142 12 1013 2025 174 s/d pumps. ISIP = 900 psi. Monitorfalloff pressures 0207 0 688 689 0 173.6 Prepare to pump frac. 0208 0/12 844 885 175 Coming up to rate 0209 12 1118 2181 184 At rate. 0211 12.1 1105 2126 206 0213 11.9 1045 1819 229 0214 12.1 1059 1842 248 Pad on perfs 0216 12.1 1036 1915 272 0217 11.9 1068 1920 283 1 ppg on perfs 0220 12.1 1137 1888 315 0222 12.1 1167 1897 339 0224 12.1 1187 1764 368 2 ppg on the perfs 0226 12.1 1192 1810 390 3 ppg on the perfs 0228 12.1 1155 1970 412 5 ppg on the perfs 0230 11.9 1160 1850 436 6 ppg on the perfs 0232 11.4 1178 1851 461 7 ppg on the perfs 0234 11.7 1237 2007 483 0236 11.9 1242 2135 505 0238 12.1 1256 2300 534 9 ppg on the perfs. 0240 12.2 1242 2360 554 0242 12.1 1260 2158 579 , 10 ppg on the perfs. 0244 12.1 1283 2340 601 0247 12.6 1279 2172 643 0249 11.9 1338 2230 665 0251 11.9 1416 2500 689 0252 0 698.1 Wellbore screened out. Pumps shutdown. FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 425 Bbls FRAC: 698 Bbls 1123 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME ., GEL QUALITY CONTROL CHECK KCI H20 SEA H20 60# GEL 60# GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH DF/FRAC 7.0 98 deg. 7.0 70 cp n/a n/a n/a FLUID ADDITIVES 60 ppt HEC gel wi 2% KCI SF BP EXPLORATION MILNE POINT / MPG-ii 500292278100 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -58.30 112.00 112.00 53.70 205.61 205.61 147.31 296.00 296.00 237.70 386.59 386.57 328.27 476.76 476.69 418.39 570.44 570.26 511.96 660.03 659.63 601.33 751.28 750.36 692.06 845.12 843.21 784.91 936.83 933.21 874.91 1032.15 1025.43 967.13 1123.14 1111.83 1053.53 1214.75 1196.90 1138.60 1307.41 1280.79 1222.49 1399.94 1362.18 1303.88 1491.94 1440.98 1382.68 1583.98 1519.36 1461.06 1679.04 1599.80 1541.50 1770.39 1676.61 1618.31 1862.98 1753.60 1695.30 1954.16 1827.15 1768.85 2046.21 1899.09 1840.79 2137.83 1968.50 1910.20 2229.75 2036.57 1978.27 2321.15 2101.99 2043.69 2412.84 2163.89 2105.59 2506.77 2222.45 2164.15 2597.41 2274.24 2215.94 2689.35 2321.32 2263.02 2781.35 2362.49 2304.19 2870.60 2397.73 2339.43 2963.21 2431.92 2373.62 3057.30 2464.35 2406.05 3149.42 2493.39 2435.09 Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE DATE OF SURVEY: 071097 MWD SURVEY JOB NUMBER: AK-MM-70196 KELLY BUSHING ELEV. = 58.30 FT. OPERATOR: BP EXPLORATION COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 0 N .00 E .00 .00N .00E 0 0 N .00 E .00 .00N .00E 0 22 N 12.06 W .41 .30N .06W 0 31 N 66.23 E .64 .76N .25E 1 27 S 88.98 E 1.12 .91N 1.78E .00 .00 .04 .49 1.98 2 17 N 86.52 E .95 1.00N 4.73E 3 5 N 88.68 E .85 1.17N 9.13E 4 50 N 88.66 E 1.95 1.31N 15.33E 7 10 N 87.57 E 2.57 1.64N 24.87E 9 21 N 83.18 E 2.41 2.80N 38.30E 4.79 8.99 14.86 23.95 36.97 12 43 N 86.47 E 3.75 4.31N 55.79E 16 28 N 83.89 E 3.99 6.39N 79.72E 20 2 N 81.80 E 3.98 9.99N 107.99E 23 27 N 80.32 E 3.78 15.30N 141.52E 26 46 N 79.52 E 3.59 22.20N 180.23E 53.93 77.15 104.96 138.29 177.04 30 1 N 79.04 E 3.52 30.39N 223.45E 32 4 N 78.84 E 2.24 39.49N 270.02E 31 9 N 79.76 E 1.13 48.46N 317.43E 33 12 N 80.18 E 2.17 57.27N 367.28E 32 18 N 80.27 E .99 65.66N 415.99E 220.48 267.37 315.00 364.88 413.55 35 10 N 80.68 E 3.10 74.16N 466.71E 37 16 N 80.37 E 2.31 83.04N 519.84E 39 54 N 78.74 E 3.07 93.47N 576.29E 41 34 N 78.22 E 1.85 105.41N 634.87E 42 52 N 76.48 E 1.90 118.95N 695.13E 464.13 517.12 573.75 632.90 694.17 45 42 N 75.73 E 3.16 134.28N 757.07E 49 21 N 73.93 E 4.24 152.01N 822.33E 53 28 N 74.16 E 4.39 172.18N 892.92E 56 49 N 72.99 E 3.83 193.23N 964.25E 61 33 N 71.86 E 5.26 217.08N 1039.50E 757.64 825.04 898.28 972.52 1051.40 65 15 N 69.90 E 4.45 244.04N 1117.20E 68 13 N 70.45 E 3.38 271.85N 1194.34E 68 26 N 70.43 E .23 300.66N 1275.44E 71 13 N 70.36 E 2.97 330.29N 1358.63E 72 1 N 70.66 E .91 359.46N 1441.04E 1133.64 1215.63 1301 . 70 1390.01 1477.43 SP f-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPG-ii 500292278100 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 071097 MWD SURVEY JOB NUMBER: AK-MM-70196 KELLY BUSHING ELEV. = 58.30 OPERATOR: BP EXPLORJkTION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3242.34 2521.63 2463.33 3335.08 2549.27 2490.97 3427.81 2576.67 2518.37 3518.87 2604.69 2546.39 3610.73 2634.02 2575.72 72 72 72 71 71 35 43 54 15 3O N 70.55 E .62 388.86N 1524.54E N 70.59 E .16 418.31N 1608.03E N 70.27 E .38 447.98N 1691.50E N 70.46 E 1.82 477.09N 1773.09E N 71.08 E .70 505.76N 1855.28E 1565.95 1654.47 1743.06 1829.69 1916.73 3705.07 2664.48 2606.18 3798.24 2694.90 2636.60 3890.15 2726.15 2667.85 3985.43 2757.87 2699.57 4081.27 2787.63 2729.33 7O 71 69 71 71 49 3 11 54 54 N 71.13 E .73 534.68N 1939.76E N 70.71 E .50 563.46N 2022.98E N 71.07 E 2.07 591.76N 2104.64E N 69.75 E 3.14 621.88N 2189.27E N 70.06 E .31 653.19N 2274.83E 2006.01 2094.06 2180.48 2270.31 2361.41 4176.52 2816.80 2758.50 4271.82 2845.92 2787.62 4367.68 2877.89 2819.59 4463.44 2912.45 2854.15 4560.15 2946.41 2888.11 72 72 69 68 70 25 0 1 39 13 N 70.41 E .64 683.85N 2360.16E N 70.89 E .65 713.91N 2445.77E N 71.32 E 3.13 743.18N 2531.26E N 72.32 E 1.05 771.04N 2616.11E N 74.00 E 2.29 797.26N 2702.76E 2452.08 2542.82 2633.16 2722.43 2812.83 4654.46 2977.28 2918.98 4750.32 3006.23 2947.93 4845.92 3033.25 2974.95 4940.47 3060.14 3001.84 5035.71 3087.67 3029.37 71 73 73 73 73 33 17 52 4 19 N 72.66 E 1.95 822.83N 2788.11E N 71.69 E 2.05 850.80N 2875.10E N 70.49 E 1.35 880.52N 2961.84E N 68.59 E 2.10 912.19N 3046.76E N 68.41 E .31 945.61N 3131.59E 2901.79 2993.11 3084.79 3175.42 3266.55 5131.11 3114.28 3055.98 5227.66 3140.01 3081.71 5323.35 3165.96 3107.66 5418.44 3194.46 3136.16 5514.08 3226.74 3168.44 74 74 73 71 69 17 47 44 22 10 N 68.56 E 1.03 979.21N 3216.82E N 68.29 E .58 1013.43N 3303.35E N 68.19 E 1.10 1047.57N 3388.89E N 67.61 E 2.56 1081.69N 3472.92E N 67.39 E 2.30 1116.13N 3556.08E 3358.13 3451.14 3543.19 3633.82 3723.73 5608.75 3262.65 3204.35 5704.11 3303.62 3245.32 5798.84 3349.41 3291.11 5894.06 3400.62 3342.32 5989.86 3457.79 3399.49 66 62 59 55 51 13 52 19 35 6 N 69.54 E 3.76 1148.30N 3637.54E N 70.59 E 3.66 1177.66N 3718.47E N 71.53 E 3.85 1204.58N 3796.89E N 71.77 E 3.92 1229.85N 3873.06E N 72.03 E 4.68 1253.73N 3946.10E 3811.27 3897.37 3980.27 4060.49 4137.30 6085.45 3520.27 3461.97 6181.40 3587.69 3529.39 6276.93 3658.92 3600.62 6372.47 3734.06 3675.76 6468.13 3813.02 3754.72 47 43 4O 36 32 15 27 6 8 35 N 69.48 E 4.51 1277.52N 4014.39E N 67.59 E 4.20 1302.46N 4077.91E N 67.11 E 3.51 1326.96N 4136.64E N 67.13 E 4.16 1349.89N 4190.98E N 65.84 E 3.79 1371.40N 4240.49E 4209.61 4277.82 4341.39 4400.28 4454.16 SP~ f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPG-ii 500292278100 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 071097 MWD SURVEY JOB NUMBER: AK-MM-70196 KELLY BUSHING ELEV. = 58.30 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 6563.88 3895.71 3837.41 27 53 N 68.69 E 5.12 1390.11N 4284.91E 6658.92 3980.79 3922.49 25 1 N 68.52 E 3.03 1405.55N 4324.34E 6755.47 4068.43 4010.13 24 34 N 68.23 E .47 1420.47N 4361.99E 6850.91 4154.98 4096.68 25 16 N 69.47 E .92 1434.98N 4399.51E 6946.54 4241.42 4183.12 25 22 N 70.36 E .41 1449.03N 4437.92E 4502.30 4544.62 4585.10 4625.32 4666.22 7042.37 4327.96 4269.66 25 30 N 71.02 E .33 1462.64N 4476.76E 7137.46 4413.66 4355.36 25 51 N 71.35 E .40 1475.93N 4515.76E 7233.21 4499.79 4441.49 25 58 N 71.39 E .13 1489.29N 4555.41E 7300.22 4560.02 4501.72 26 1 N 71.23 E .14 1498.70N 4583.23E 7385.00 4636.17 4577.87 26 6 N 71.02 E .14 1510.76N 4618.48E 4707.38 4748.57 4790.40 4819.77 4857.01 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4859.30 FEET AT NORTH 71 DEG. 53 MIN. EAST AT MD = 7385 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 70.13 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 7,385.00' MD SP~' f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPG-Ii 500292278100 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 071097 JOB NUMBER: AK-MM-70196 KELLY BUSHING ELEV. = 58.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58.30 .00 N .00 E 1000.00 994.50 936.20 5.51 N 70.99 E 2000.00 1863.31 1805.01 87.95 N 547.58 E 3000.00 2445.11 2386.81 312.17 N 1307.79 E 4000.00 2762.40 2704.09 626.68 N 2202.27 E .00 5.50 5.50 136.69 131.20 554.89 418.20 1237.60 682.72 5000.00 3077.42 3019.12 933.02 N 3099.78 E 6000.00 3464.19 3405.89 1256.17 N 3953.58 E 7000.00 4289.72 4231.42 1456.71 N 4459.52 E 7385.00 4636.17 4577.87 1510.76 N 4618.48 E 1922.58 684.98 2535.81 613.23 2710.28 174.47 2748.83 38.55 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPI f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPG-ii 500292278100 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 071097 JOB NUMBER: AK-MM-70196 KELLY BUSHING ELEV. = 58.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58 58.30 58.30 158.30 158.30 100 258.30 258.30 200 358.31 358.30 300 .30 .00 .00 .00 .00 .00 N .00 E .00 .00 N .00 E .00 .00 .01 N .00 W .00 .00 .62 N .06 W .00 .00 .92 N 1.06 E .01 .01 458.36 458.30 400 558.46 558.30 500 658.70 658.30 600 759.29 758.30 700 860.43 858.30 800 .00 .00 .00 .00 .00 .95 N 4.00 E 1.15 N 8.49 E 1.31 N 15.21 E 1.69 N 25.87 E 3.09 N 40.85 E .06 .05 . 16 .10 .40 .24 .99 .59 2.13 1.14 962.61 958.30 1066.56 1058.30 1172.92 1158.30 1282.32 1258.30 1395.48 1358.30 9OO 1000 1100 1200 1300 .00 .00 .00 .00 .00 4.72 N 61.69 E 7.56 N 89.83 E 12.68 N 125.63 E 20.19 N 169.30 E 29.97 N 221.29 E 4.31 2.18 8.26 3.95 14.62 6.36 24.02 9.40 37.18 13.15 1512.38 1458.30 1629.58 1558.30 1748.72 1658.30 1868.73 1758.30 1993.62 1858.30 1400 1500 1600 1700 1800 .00 .00 .00 .00 .00 41.59 N 280.67 E 52.66 N 340.77 E 63.70 N 404.58 E 74.70 N 469.98 E 87.25 N 543.69 E 54.08 16.90 71.28 17.20 90.42 19.14 110.43 20.01 135.32 24.89 2124.19 1958.30 2259.62 2058.30 2404.32 2158.30 2568.74 2258.30 2771.48 2358.30 1900 2000 2100 2200 2300 .00 .00 .00 .00 .00 103.56 N 626.01 E 123.78 N 715.05 E 150.24 N 816.14 E 186.33 N 941.43 E 241.00 N 1108.80 E 165.89 30.57 201.32 35.43 246.02 44.69 310.44 64.42 413.18 102.74 3038.78 2458.30 3365.49 2558.30 3686.27 2658.30 3986.83 2758.30 4310.56 2858.30 2400 2500 2600 2700 2800 .00 .00 .00 .00 .00 324.41 N 1342.14 E 427.96 N 1635.42 E 528.93 N 1922.95 E 622.35 N 2190.52 E 725.87 N 2480.47 E 580.48 167.30 807.19 226.72 1027.97 220.77 1228.53 200.56 1452.26 223.73 4595.28 2958.30 4934.14 3058.30 5295.99 3158.30 5597.86 3258.30 5816.06 3358.30 2900.00 3000.00 3100.00 3200.00 3300.00 806.37 N 2734.54 909.98 N 3041.12 1037.81 N 3364.50 1144.78 N 3628.20 1209.25 N 3810.88 E 1636.98 184.73 E 1875.84 238.86 E 2137.69 261.85 E 2339.56 201.87 E 2457.76 118.21 SP. f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPG-ii 500292278100 NORTH SLOPE BOROUGH COMPUTATION DATE: 7/17/97 DATE OF SURVEY: 071097 JOB NUMBER: AK-MM-70196 KELLY BUSHING ELEV. = 58.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 5990.62 3458.30 3400.00 1253.91 N 3946.64 E 2532.32 6140.35 3558.30 3500.00 1291.73 N 4051.34 E 2582.05 6276.10 3658.30 3600.00 1326.74 N 4136.14 E 2617.80 6402.26 3758.30 3700.00 1356.67 N 4206.92 E 2643.96 6521.12 3858.30 3800.00 1382.34 N 4265.73 E 2662.82 74 .56 49.73 35.75 26.16 18 .86 6634.01 3958.30 3900.00 1401.64 N 4314.38 E 2675.71 6744.33 4058.30 4000.00 1418.76 N 4357.68 E 2686.03 6854.58 4158.30 4100.00 1435.53 N 4400.97 E 2696.28 6965.22 4258.30 4200.00 1451.72 N 4445.46 E 2706.92 7075.98 4358.30 4300.00 1467.35 N 4490.45 E 2717.68 12 .90 10.31 10.25 10.64 10.76 7187.07 4458.30 4400.00 1482.84 N 4536.27 E 2728.77 7298.31 4558.30 4500.00 1498.43 N 4582.44 E 2740.01 7385.00 4636.17 4577.87 1510.76 N 4618.48 E 2748.83 11.08 11.24 8.82 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 0 !:t I I--I--I IM G SEI:t~JI CE S WEI,I, LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.- Loft Taylor 3001 PorCUpine Dr. Anchorage, Alaska 99501 ~fl RE: MWD Formation Evaluation Logs - MPG-Il, AK-MM-70196 September 17, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPG-Il: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22781-00 1 Blueline 1 Rev. Folded Sepia 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22781-00 1 Blueline 1 Rev. Folded Sepia S EP 7 7 1~ ? Alaska Oil & Gas Cons. Commis~on .,Anchorage 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company [::Il:IICI--lNG WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cormn. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - September 10, 1997 MPG-11 AK-MM-70169 The technical data listed below is being submitted herewittz Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Tan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG fommtted Disc with verification listing. API#: 50-029-22781-00 SEP 10 1997 Naska Oil & Gas-% ,,~ns, ~eh0m0e 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASI~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 19, 1997 Tim Schofield Senior Drilling Enginccr BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Milne Point MPG-11 BP Exploration (Alaska). Inc. Permit No. 97-119 Sur. Loc: 1724'NSL.3357'WEL. SEC 27.T13N.RI 0E. UM Btmhole Loc: 3221'NSL.4059'WEL. SEC 26.TI3N.RIOE.UM Dear Mr. Schoficld: Encloscd is thc approvcd application for permit to drill thc abovc rcfcrcnccd well. Thc pcnnit to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd bx' law from other govcrnmcntal agcncics, and docs not authorize conducting drilling opcrations until all other rcquircd pcrmitting dctcrminations arc madc. Blowout prcvcntion cquipmcnt (BOPE) must bo tcstcd in accordancc with 20 AAC 25.035. Sufficicnt noticc (approximatcly 24 hours) of thc BOPE test pcrformcd before drilling bcloxv thc surfacc casing shoc must bc givcn so that a rcprcscntativc of thc Commission max.' xvitncss thc tcst. Notice max.' bc givcn bv contacting thc Commission pctrolcum ficld inspcctor on thc North Slope pagcr at 659-3607. Chairman BY ORDER OF THE COMMISSION dlffcnclosures l)cpatlmcnt of Fish & (,}amc. I Iabitat Section w o cncl. I)cpartlllenl DJ' [',llVillOFlllllClll C(mscrvalion W o ¢llCl. --- :-. STATE OF ALASKA ALASKA ,~_ AND GAS CONSERVATION CON,,¢,,__SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [~ Drill I'-IRedrill Ilb. Typeofwell I--IExploratory I--lStratigraphicTest [~ Development Oil [] Re-Entry [] DeepenI []Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 58.8' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1724' NSL, 3357' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3151' NSL, 4254' WEL, SEC. 26, T13N, R10E, UM MPG-11 At total depth 9. Approximate spud date Amount $200,000.00 3221' NSL, 4059' WEL, SEC. 26, T13N, R10E, UM 07/01/97 12. Distance to nearest property linet 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025906, 1221'I No Close Approach 2560 7374' MD / 4635' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 70.13° Maximum surface 1380 psig, At total depth (TVD) 4200' / 1800 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD 'FVD MD TVD (include stage data) 24" 20" 91.4# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 Btc-Mod 7343' 31' 31' 7374' 4635' 721 sx PF 'E', 110 sx Class 'G' ,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Liner ~. ~,~ ,~,, ,~ ~, ,9 Intermediate Production Perforation depth: truemeasuredvertical ~%\k'%~\\~ 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Narne/Number: Mark Brofka, 564-4809 Prepared By Name/Number: Kathy Campoamor, 564-5122 21' I hereby certify that t~°ing-~-'tru~ and °°~rrlct t° the best °f mY kn°wledgeSigned ¢/~¢tct~~; ~/~! Tim Schofie,d ~ r/~r~ .Z_-.-.-.-.-.-.-.-~ Title Senior Drilling Engineer Date 5?3 /,' Oommission Use Only Permit Number I APl Number . I ApDrova~ Date I See cover letter ¢'?-//¢ t Ifor other requirements Conditions of Approval.' Samples R~ []Yes [] No Mud Log Reqd~red ~/ []Yes [] No 'de Me~s []Yes []No Directional Survey Required []Yes []No ~ ~,~ssu~~M; 1--13M; I-]5M; I--I10M; [-115M '~_ . ~'% ~1 \\ ~ ,,-7~/8/S~_ by order of / , Approved By . ,~,/78Q' 8[/Commissioner the commission Date f../I Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: Mark J. Brofka I MPG-11 Well Plan Summary IType of Well (producer or injector): ISCHRADER BLUFF PRODUCER 564-4809 Surface Location: 1724 FSL, 3357 FEL, S27 T13N R10E UM Target Location: 3151 FSL, 4254 FEL, S26 T13N R10E UM Bottom Hole Location: 3221 FSL, 4059 FEL, S26 T13N R10E UM I AFE Number: 1 337082 I Estimated Start Date: I Rig: I Nabors 22E July 1997 I I Operating daysto complete: 19.5 IMD: 17374, I ITvD: 14635, I I KBE: 15S.S I Well Design: Schrader Bluff Producer Formation Markers: Formation Tops MD TVD (bkb) KOP 300 300 Base of Permafrost 1840 1759 Top of Ugnu 6311 3694 Top M Sand 6607 3941 Top NA (Target) 6883 4190 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 6917 4221 NCND 6950 4251 NE 6981 4279 NF 7035 4328 OA 7075 4364 OA4 7115 4401 OB 7143 4426 Top of Seabee 7174 4454 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 7374 4635 TD at 200' MD past base of Schrader Casing/Tub lng Program: Hole ,~ize ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.4# H-40 Weld 80' 32'/32' 112' / 112' 8-1/2" 7" 2.6# L80 BTC-MOD 7,343' 31'/31' 7,374' / 4,635' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/fi) to the reservoir at +4200' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1380 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Cased Hole Logs: Mudloggers are NOT re( MWD from surface to TD LWD (GR/Resistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr from 7374 - 6311' MD. Drop ESS survey tool at TD to correlate with MWD surveys. RFT log, drillpipe-conveyed (specific RFT program will be submitted to the rig prior to logging operations) NONE ',GR/CCL with completion riD) uired for this well. Mud Program: Spud Mud ISpecial design considerations ISee "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10/final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 (as 20 10 20 9.5 6 required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. Completion Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I 300', Phased Build and Drop, S-shaped Maximum Hole Angle: Close Approach Well: t72.02 NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. In the event that the bridges are not usable due to breakup, all cuttings will be placed in the Milne Point A-Pad reserve pit. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. If the bridges over the rivers are not usable because of breakup, class 2 waste fluids will be hauled to the Kuparuk injection well and class 1 fluids will be transferred to storage tanks for future disposal after breakup. Annular Injection: No wells on G-Pad have been permitted for annular injection. . 2. 3. 4. 5. . . . 10. 11. 12. 13. 14. 15. 16. 17. MP G-11 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. N/U and function test 21-1/4' Hydril MSP 2M diverter system. Build Spud Mud. Drill an 8-1/2" surface hole as per directional plan to 7374' MD / 4635' TVD. Run Directional MWD and LWD GR/Res from surface to TD. Change MWD when tripping for the second bit and drill at a controlled rate of no more than 200 ft/hr through the Schrader Bluff sands. At TD, make a wiper trip to the last bit trip depth and condition hole, making sure to record any tight spots. Run and cement 7", 26#, L80, BTC-MOD casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) MIRU completion rig. N/U & Test BOPE. Drill out ES cementer and clean out the well. Run GR/CCL tool. Perform completion job. MPG-11 will be a sand production candidate. Complete well with 2-7/8" L-80, EUE tubing and ESP for sand production (~ompletion. Set BPV. N/D BOP stack and N/U X-mas tree. RDMO with completion rig. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: The well is planned as a Schrader Bluff single casing string producer. The well will be drilled, cased, and cemented with Nabors 22E which will then suspend the well and move on. The well will be completed at a later date by a completion rig. See the latest Milne Point G-Fad Data Sheet prepared by Pete Van Dusen for information on G pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. .1. Hydrates: Hydrates have occurred on nearby E and H pads and there is a possibility that hydrates may be encountered in the drilling of MPG-11. In the eight wells previously drilled on G-pad, only G-8 encountered gas-cut mud, but only a minor amount. Hydrates on MPG~11 are not expected, but if hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to prevent the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPG-11. The well trajectory does require a 20° azimuthal turn to prevent any near-surface close approaches, but this should not pose any difficulties. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. To date, losses seen on past wells in the area have been minor. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on G Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concerns Also, due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. Also, the producer wells will have a high sail angle and then drop into the reservoir section to allow for the completion. 7. Other There have been only a handful of wells ddlled on the North Slope with an 8-1/2' surface hole and it is important that bit and directional performance is closely monitored and reported so that lessons learned can be included in the next well program. None of the drilling hazards and risks identified above are expected to be magnified by the change in hole size. MPG-11 7" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP SPACER: 50 bbls fresh water spacer (1307' in 7" casing). STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder + CELLO-FLAKES (0.25 Ib/sk) 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk 312 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6107' MD) TO THE ES CEMENTER STAGE TOOL (2050' MD > 200' MD BELOW BASE OF PERMAFROST) + 30% EXCESS. STAGE1 TAIL CEMENT TYPE: PREMIUM ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 110 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30min TAIL CEMENT FROM TD (7374' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (6107' MD) + 30% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 4O9 SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. PUMP UNTIL RETURNS ARE OBSERVED AT SURFACE BEFORE DROPPING CLOSING PLUG. +/- 250% EXCESS IS EXPECTED FROM THE ES CEMENTER TO SURFACE. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY IF THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - two (2) per joint on the bottom twenty-two (22) joints of 7" casing (44 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 6 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is not, necessary. Be sure to keep detailed records of the cement job, and to report the amount of returns seen from both stages so that volumes can be modified on future wells if necessary. CEMENT VOLUME: 1 ~ Stage: 1. The lead slurry volume is calculated to cover from the ES cementer tool (200' MD below base of permafrost) to the top of the tail slurry, at the greater of either 500' MD or 100' TVD above the top of the Ugnu "M' Sands, with 30% excess. 2. The tail slurry volume is calculated to cover the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands to TD with 30% excess. 3. 80' of 7", 26# capacity for the float joints (baffle collar, float collar, and float shoe). 2nd Stage: 1. The slurry volume is calculated to cover from the ES cementer to surface with an excess of 250% expected to be required. Ensure that additional sacks of cement are onsite and available for use The slurry will be pumped until cement returns are seen at surface. Note that in the event that hydrates are encountered, the Operations Drilling Engineer should be notified and a modified cement program will be submitted to ensure isolation of the hydrate zone. DISPLACEMENT OF'CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an impodant consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. 2. After bumping the plug, quickly check to ensure that the floats are holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition the contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for rouse on another well. AnadriLl Schlumberger Alaska DLetrict 1111 East BOth Avenue Anchora~e, AK 995L8 (907) 349-45111 ~aX 344-2160 DIRECTIONAL WELL PLuq/q for SRARHD SERVICES DRILLING Field ........ : Milne Point, G-Pad Co~utation..: MinimumCurvature Un£ts ........ : PEET · Surface I~at..: ?0,449321170 N Surface b0n~_: ~49.532951155 H Legal Description Surface ...... : 372~ F$L 3357 F~L S27 T13N R110E UM TAR~HT ....... : 3151 PSL 4254 FHL S26 T~3N R110~ UM BHL .......... : 3221 F~L 4059 FHL S26 T~3N R10~ UM LOCATIONS - ALASKA ~one: 4 X-Cootacl Y-Coord 557248.29 E014160.28 561617.00 6015622.00 56181~.71 60~5694,05 STATION MEASUP,~D INCLN DIRECTION IDHNTIFICATION DHPTH ANGLH AZIMUTH KB 0.00 0.00 0.00 KOP/BUrLgD 1.25/100 300-00 0-00 0.00 400.00 L.25 90.00 BUILD L-75/100 500.00 2,50 90.00 600.00 4.25 90.00 PROPOSED WELL PROPILH VERTICAL = DE ETB$ mmmmmmm~ SEC~ION DEPART Prepared ..... ; 05 Jun 1997 Vert sect az.: 70.13 KB elevation_: 58.80 ft Na~nettc l)cLn: 428.045 (R) Scale Factor.: 0.99990372 ConvezHence..: +0.44012228 ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN COORD£~AT~S-PROI4 ALASKA Zone 4 TOOL 0.00 -58.80 300.00 24i.20 399.99 341.19 499,94 441.14 $99.76 540.96 0.00 0.00 L 4.10 9.64 0.00 N 0.00 E 557248.29 6014160.28 0.00 N 0.00 B 557148.29 6014160.25 0-00 N 1.09 E 557249.~8 6014160.29 0.00 ~ 4.36 E 557252.65 6014160.3~ 0.00 N L0.25 E 557258.54 6014360.36 CURW~ 2. S/lO0 700.00 6.00 90.00 800.00 8-46 86.61 900.00 L0.94 84.74 1000.00 Z3.43 83,55 1100.00 15,92 82.73 699.36 6§0,56 798.55 739,75 897.11 838.31 994.85 936.05 1091.58 1032.78 18.04 30.02 46.26 66.75 91.44 0.00 N 0.44 N ~.74 N 3,92 N 6.96 N FAC~ L 00 mmm= HS 0. OD 90R 0.0O 90R 1.25 90R 11.25 90R 1.75 19.18 E 557267.47 601~160.43 L2L 1.95 311.76 E 557280.04 6014160.96 8L 2_50 48.56 E 557296.83 6014162-40 61 2.50 69.56 E 557317,81 6014164.73 51 2.50 94.71 E S5~342.93 601416~.96 41 2.50 1200.00 18.42 82 .13 1300.00 20.91 0], .67 1187 . 12 1L28.32 1281.28 1222.48 120.28 153.23 10.86 15-6~ 123.97 ~ 557372,16 6014172.O9 41 2.50 157,28 B 557405.43 6014177.09 3L 2.50 (Anadrill (c) 97 MPGLIP04 3.0C L:3~ PM P) ~ H~D 2.5/100 CURVE C0RV~ 3.5/100 ~ 3.S/£00 CLmV~ DROP 3 .75/1.00 F~ASURED DHFTH 1400.00 1500.00 1700.00 1800.00 23.41 25.91 28.40 30.90 33.40 LSL1.00 33.67 1840.25 33.67 1871.O0 33.67 L9'00,O0 34.65 2000.00 38.04 2300.00 41.45 2200.00 44.86 2300.00 49.29 2400.00 51.72 2500.00 55.16 2600.00 58,61 2700.00 62.06 2800.00 65.51 2900.00 68.96 2988.~8 72.02 5428.71 72.02 5500.00 69.35 5600.00 65.60 5700.00 61.85 S800.00 58.10 05 Jun 199~ Page 2 PR~)POSHD ~HI/~ PROFILE DIRBCT£O~ AZIMUTH 81-30 81,00 80.75 80.53 80.35 80.33 80.33 80.33 79.85 78-38 ~]IRTI CAL-DEPTHS TVD SUB -BaA 1373.88 13 15.08 1464,76 1405.96 1~53.73 [494.93 1640.63 158~.83 1725 . 29 ~666 , 49 1734,46 1758.80 1984.39 1808.38 1888.92 1675.66 1700.00 1725,59 1749.58 1830.12 SECTION CX3ORDINATHS-FROM ALASKA Zone 4 TOOL Dh/ DHPART WELhHHAD X Y EACH 100 190,21 ' 21.20 ~ 194.58 E 557442.69 6034182~97 31 2.50 231.15 27,62 N 235,80 E 557483,85 6014189,71 31 2,50 275.99 34,86 N 280,86 H 557528,85 6014197.29 3L 2.50 324.63 42.91 N 329.67 H 557577.59 6014905.72 2L 2.50 376,98 51.75 N 382.14 H 557629.98 6014214,96 2~ 2,50 382.96 52.77 N 388.13 E 557635.97 6014216.02 HS 2.50 398,93 55.49 N 404.12 E 557651,93 6014218.87 HS 0.00 415.71 58.35 N 4~0.92 B 557668,71 6014221.86 151 0.00 431.74 61,1-6 N 436.97 H 557684,73 60~4224.79 151 3.50 490.28 7~.38 N 495.15 H 557~42.82 60[4236.45 141 3.50 77 76.00 75. O2 74 . 13 73.33 1965.80 t907.00 2038,74 1979.94 2103,47 2048.67 2171.73 2112.93' 2231.28 2172.48 553.64 85.97 N 557.6t ~ 557805.17 6014250,52 L3L 3,50 62k.60 101,89 N 624.12 E 557871.54 6014266.96 12b 3.50 693,90 120.08 N 694,42 E 557941.70 6014285.6~ IlL 3.50 770.27 140.47 N 768,25E 558015.37 6014306.64 11L 3.~0 850.43 162.99 N 845-35 B 558092,28 6014329.74 10L 3.50 72,59 71,90 71,26 70.65 70.13 2285.90 2227,L0 2336,39 2276,59 2379,56 2320.76 2418,25 2359.45 2447,79 ~388,99 93~.07 L020.89 L110.56 1202.75 3286.13 187,54 N 925.41 H 558172,15 601435~.90 t0b 3.50 214.04 N 1008.15 ~ 558254,67 6014382.03 LOb 3.50 242.38 N 1093.25 B 558339.$4 6014411.03 9b 3.60 272,47 N LLB0.40 E 550426,45 6014441,79 9~ 3.50 500,46 N 1258.95 E 558504,77 6014470.37 NS 3.~0 70.13 70.13 90. ti 70.13 70.13 3200.96 3142.16 3224.54 3165.74 3262.84 3204.04 3307.10 3248.30 3357.13 3298.33 3607,23 3674-50 3766.85 3856.51 39~3.07 1089.22 U 3441.92 H 56068L.41 6015275.80 LS O.00 1312.08 N 3505,19 H 560744,49 60£5299.14 bS 3.75 1143.46 ~ 3592,04 H 5608~1.10 60L5331,L9 LS 3.75 1173.93 N 3676,36 R 560915,17 6015362,30 LS 3.75 1203.35 ~ 3757.77 H 560996.35 6015392.34 LS 3.75 5900.00 54.35 6000.00 50.60 6100.00 46.85 (AnadriL1 (c) 97 MPGLLP04 3,0C L:35 PM P} 70,13 70,Lt 70.13 3412.72 3353.92 3473.62 3414.B2 3539.57 3450,77 4026,18 4105,47 4180.6I 1231.59 N 3835.93 E 561074.28 6015421.18 ~S 3.75 1258,53 N 3910.51 E 563148,64 6015448.69 LS 3,75 [284.07 N 3981,~8 E 561219.[0 6015474.$9 LS 3,75 NPG-KI(P04} 05 Jun 3997 Page 3 STATION MHASURHD [DNNTIFICATION DEPTH 6200.00 43.10 6300.00 39.35 TOP UGNU 6310.70 38,95 6400.00 35.60 6500.00 31.85 ~ 3,75/t00 DROP PROPOSED ~B~b PROFELE INCI.,N DIRBCTZON VERTICAL-DEPTHS ANGLE AZIMUTH ~ SUB-SEA 70,13 36L0.30 355].50 70.13 3685,51 1626,71 70.~3 3693,80 $635,00 70.~3 3764.85 3706.05 70.13 3848.03 3789.21 TOP SCHRADH~ 6600.00 28.10 6607.00 27.84 6682.64 25.00 6882.64 25.00 6882.64 25,00 0A OA4 OB RASa .q CH RADER 7" CASING POINT 6882.64 25.00 6916.85 25.00 6949.95 25.00 6980.84 25.00 7034.9l 25.00 7074.63 25.00 7115.45 25.00 7143.04 25.00 7173.93 25.00 7373.93 25.00 SBCTIOM 4251,28 431~.17 4323.92 4370.00 4433,50 70.13 3934.62 3875.82 4483.46 70,13 3940.80 3882.00 4486.94 70.13 4008.94 3949.74 4520.39 70.13 4189.80 4131,00 4604.91 70.13 4109.80 4131.00 4604.91 70.13 ~109.80 4131.00 70.13 4220.80 4162.00 70.13 4250.00 4192.00 ~0,13 4278,80 4220.00 70,13 4327.80 4269.00 4604.91 4619.37 4633.36 4646.42 4669.26 70.13 4363.80 4305.00 4686.05 70.13 4400-80 4342.00 4703.30 70.13 4425.80 4367.00 47]4.96 70.13 4453.80 4395.00 4728.02 70.13 4635.06 4576,26 4812.54 TD 7373,93 25.00 90,13 4635.06 4576,26 48L2.54 C00RDINATHS-FRO~ TOOL Dh/ WRLLHHAD FACE ~00 ]308.08 N 4047.64 H 3.75 1330.47 N 4109.61 H 3.~ 1332.77 ~ &L15.96 H 3.75 135[.~4 ~ 4L66.82 · 561404,20 6~15543.26 3.75 1370.01 N 4219.02 ~ 561456.26 6015562,52 3.75 Zone 4 561285.37 6015499.29 561347.16 6015522.15 561353.49 6015524.49 1386.98 N 4266.00 H 561503.10 6015579.85 LS 3.75 1388,L0 N 4269.09 ~ 561506.18 6015580.99 ~ 3.75 1399.53 N 4300.74 ~ 56L537.74 6015592.67 }{S 3.75 1428.26 N 4380.23 E 56~637,00 6015622.00 ~$ 0.00 ~428.26 N 4~80.23 E 563617.00 60£5622.00 ~S 0.00 3428.26 N 4380.23 B 561617.00 6015622.00 ~ 0.00 1433.t7 N 4393.83 B 561630.56 6015627.02 ~ O.O0 1437.92 N 4406.98 B 561643,67 6015631.87 HS 0.00 1442.~6 N 4~L9.26 E ~61655,92 60156~6.40 KS 0.00 1450.12 N 4440.75 E 563677.35 6015644,33 HS 0.00 1455.83 N 4456.54 H 561693.09 6015650.16 HS 0,00 146~.69 N 4472,77 B 561709.27 6015656.~4 HS O.O0 ]465,65 N 4483.73 H 561720.20 6015660.19 H9 0.00 1470,09 N 4496.01 B 56[732.44 6015664,72 H~ O.GO 1498.81 N 4575.50 K 561011.71 6015694.05 0.00 L498.81 N 4575.50 B 561811.71 6015694.05 O.O0 -U (AnadriLL (c)97 MPGllP04 3.0C 1:35 PM P) ANADRILL AKA-DPC APPROVED FOR PERMITTING 'SHARED 'SERVlCI S ,DRTLLI, NG ..... 0 4oo eoo moo ~600 ~000 ~400 Sect ion Dep,a~,ture 3600 4000 4400 4800 mi /nadrJ ]] Sch]umberger · iii MPG- 1 (PO4) VERIICAL SECIION VIEW Section at: 70, ]3 TVD Scale · 1 'inch = BO0 feet Dep Scale,' I inch = 800 leer Dra~n ..... · 05 dun 1~7 m Marker ]dent i ficat ion A) KB B) KOP/BUILO t.25/t00 C] Bt)ILO 1.75/100 O) CURVE 2.5/i00 E} END 2.5/tO0 CURVE F) CURVE 3.5/]00 G) END 3.5/t00 CURVE H) 8ROP 3.75/t00 I) END 3.75/t00 DROP J) l~GEl K) 7' CASING POI~IT t] TO MD BKB SECTN 0 0 0 300 300 0 500 500 4 700 699 18ii t734 383 187i ~784 ~88 2448 1286 .5429 32Q~ 3607 6683 .4009 452O 6863 4190 4605 7374 4635 46t3 7374 4635 48i3 5200 5600 6000 6400 ii m i INCLN 0.00 0.00 2.50 6.00 33.67 33.67 72.02 72.02 ~5.00 25.00 25.00 25. O0 6800 .I z I - ...SHARED SERV ICES DRILL T NG . i- II I 1-- Il i i . , i i ~ ~ ,.,,r,,,,. ,,,.,-,,~,,,.,:,o. ,o ,,,,,, ,,,','. :c,,,,,,,,',r"u .,.."""'"'-"" (PO4) fi) ENO 3,75/t00 OROP 6683 4009 4520 25.00 B) T,AFIGE'F 6"133 ~o ,~o~ ~.oo VERTICAL SECTION VIEW · D) TO 7374 4635 48!3 ~5.00 Section a~: 70, TVD Scale ' ~ ~nch -- 100 feet 4oo0~- .__ Dap Sca]e,' ~ inch = 100 fee~ A -~' Drawn .... · 05 Jun ~997 4050---X ' ' ' llnc~dr j ] ] ,Cch]u/~berger i i 4:~00 ........ ~]50 .... 4~0C_"1~~ r '43~ ............ :_ .. _ · . T~6.T. V '~ -3bfb - ~'~ ...... D 430O ...... -N~ - ~ ............................. ~ 4350 .I -0i4- -4~- ........... · ................... .. ................... 4500 , i ~ i i i i ~ I I 4550 ' AN~LDR~LL AKA-[)PC ,~,PPR¢)VEE~ 4500- - .. .. FUll, ?ER~411'TING ONLY ,, --~.. .... - ~ _ _ ~7oo ~75o ........ I 4eoo- . , . ......... 4300 4350 4400 4450 4500 4550 4600 4~§0 4700 475D 4800 4850 4900 4950 SO00 Section DepaPture .... ~a~ril! (c)97 ~OGllP04 3.0(:; 1:37 PM P) 7T ~WJ ."') J ['T -I'-I T NL'I'L':-','NW 09 I~-~'b'E-./06 E:g "~'[ /___66 ~,/'§0/90 · i J ,4nadr ~ ]] Sch ] umberger ! ii i ii NP$-J J. (PO4) PLAN VTEW i i · CLOSURE · 48~5 feet at Azimuth 71.86 DECLIPlAT[ON.' +28,045 (E) SCALE...,...' ~ JnC~ = 600 feet DRAWN. 05 Jun 1997 SHARED SERVICES DRILLING i i ii i iii i ~arker [dentif jcalian A) KB B) KOP/BUILD 2.25/100 C) BUILD II.75/100 O} CURVE 2.5/100 E} END 2.5/i00 CURVE F) CURVE 3.5/100 Gl Em 3.5/t00 CURVE H) DROP 3.75/100 I) END 3.75/i00 DROP J) TARGEl K) 7" CAS]HG POINT L} ~o m ~ N/S E/W 0 0 N 0 E 300 0 N 0 E 50O 0 N 4 E 700 0 N t9 E 1815 53 N 3OB E t87~ 58 N 42~ E 2988 300 N ~259 E 5429 1089N 3442 E 6683 1400 N 430~ E 6883 1428 N 4380 E 7374 1499 N 4576 E 7374 ~499 N 4576 E ANADRILL AKA-DP( APPROVED FOR PERMITTING : ...... _pLAN lARGEr ~adius 100 feet i .. .. 300 0 300 600 900 1200 1500 tOO0 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 <- NEST' EISI -> (Anadr)]l (cl97 I~GIIPQ4 3.OC t: 49 Mt P) i i WELL PERMIT CHECKLISToo ,N ¢,2_ / ££ WELL N~E ~p~ GEOL AREA PROGRAM: expD dev~redrln serv~ wellbore segn ann dtsp para req~ ?<~ UNIT# //~.<~? ON/OFF SHORE ("D ~ ADMI N I STRAT I ON 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. . 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ........ '/ 11. Permit can be issued without conservation order .... 1 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING N Y N . N · N REMkRKS D E 14. Conductor string provided ............... .~ N 15. Surface casing protects all known USDWs ........ i; ~-- ~'~"'/~ 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . N 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... N Adequate tankage or reserve pit ............. ~ N 20. 21. If a re-drill, has a 10-403 for abndnmnt been approved.--~k"---~ 22. Adequate wellbore separation proposed ......... .~ N 23. If diverter required, is it adequate .......... N 24. Drilling fluid program schematic & equip list adequate~ N 25. BOPEs adequate .................... N 26. BOPE press rating adequate; test to ~ psig. N 27. Choke manifold complies w/A_PI RP-53 (May 84) ...... N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. GEOLOGY ,TE ~ z/e? 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis of shallow gas zones .......... / N 33. Seabed condition survey (if off-shore) ........ / Y N 34. Contact name/phone for weekly progress reports . . ./. . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/rill- A:\FORMS\cheklist rev 01/97 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. Sperry-Sun Drilling Services LIS Scan Utility Mon Sep 08 16:56:58 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/08 Origin ................... STS Reel Name ................ UNK/~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/09/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MPG- 11 500292278100 RECEIVED SEP 1 0 1997' Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 08-SEP-97 MWD RUN 2 AK-MM-70196 PIEPER NEW 27 13N 10E 1724 3357 .00 58.30 29.30 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 8.500 7385.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWE,ENALI TURKER OF SPERRY-SUN DRILLING SERVICES AND MARK VANDERGON OF BP EXPLORATION (ALASKA), INC. ON 08 SEPTEMBER, 1997. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7385'MD, 4636'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. 'SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH RPM 4465.5 RPS 4465.5 RPX 4465.5 RPD 4466.0 GR 4474.0 STOP DEPTH 7318.0 7318.0 7318.0 7317.5 7325.5 FET 4532.5 7318.0 ROP 4534.0 7385.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 4534.0 7385 . 0 $ REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD AAPI 4 1 RPM MWD OHMM 4 1 ROP MWD FT/H 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPD MWD OHFiM 4 1 FET MWD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 4465.5 7385.5 5925.5 GR 10.2897 132.829 63.2433 RPM 1.4 73.8206 7.32155 ROP 2.8952 1928.15 201.497 RPX 1.404 2000 7.66514 RPS 1.4255 74.8147 7.5762 RPD 1.3993 64.547 7.53369 FET 0.1971 7.0886 1.02964 First Last Nsam Reading Reading 5841 4465.5 7385.5 5704 4474 7325.5 5706 4465.5 7318 5704 4534 7385.5 5706 4465.5 7318 5706 4465.5 7318 5704 4466 7317.5 5572 4532.5 7318 First Reading For Entire File .......... 4465.5 Last Reading For Entire File ........... 7385.5 File Trailer S~rvic~ name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 4465 . 5 7318.0 RPS 4465 . 5 7318 . 0 RPX 4465 . 5 7318 . 0 RPD 4466 . 0 7317.5 GR 4474 . 0 7325 . 5 FET 4532 . 5 7318.0 ROP 4534 . 0 7385 . 5 $ LOG HEADER DATA DATE LOGGED: 10-JUL- 97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7385.0 TOP LOG INTERVAL (FT) : 4534.0 BOTTOM LOG INTERVAL (FT): 7385.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.6 MAXIMUM ANGLE: 74.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA TOOL NUMBER P0771CRG6 P0771CRG6 OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHI~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OH14M 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Rep Code Offset 8.500 8.5 SPUD 8.90 70.0 9.5 8O0 .0 0 4 8 12 16 20 24 28 3 .000 2.230 2.900 4.300 Channel 1 -- 2 3 4 5 6 7 8 28.4 Name Min Max Mean DEPT 4465.5 7385.5 5925.5 GR 10.2897 132.829 63.2433 RPX 1.404 2000 7.66514 RPS 1.4255 74.8147 7.5762 RPM 1.4 73.8206 7.32155 RPD 1.3993 64.547 7.53369 ROP 2.8952 1928.15 201.497 Nsam 5841 5704 5706 5706 5706 5704 5704 First Reading 4465.5 4474 4465.5 4465.5 4465.5 4466 4534 Last Reading 7385.5 7325.5 7318 7318 7318 7317.5 7385.5 FET 0.1971 7.0886 1.02964 5572 4532.5 7318 First Reading For Entire File .......... 4465.5 Last Reading For Entire File ........... 7385.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/08 Origin ................... STS Tape Name ................ I/NIKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/09/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKI~OWN Comments ................. STS LIS Writing Library. Technical Services Physical EOF Scientific Scientific Physical EOF End Of LIS File