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Home My WebLink About189-017MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 27, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC E-03 MILNE PT UNIT E-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/27/2025 E-03 50-029-21916-00-00 189-017-0 G SPT 6459 1890170 4116 3362 3370 3372 3360 593 586 591 593 REQVAR P Sully Sullivan 12/27/2024 MIT-IA every 2 years to 1.2 x MAIP per AIO 10B.006 (MAIP 3430 x 1.2) = 4116 psi 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 E-03 Inspection Date: Tubing OA Packer Depth 1181 4258 4193 4170IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241228163200 BBL Pumped:3.3 BBL Returned:3.3 Monday, January 27, 2025 Page 1 of 1 9 9 9 9999 99 9 9 9 9 9 9 AIO 10B.006 James B. Regg Digitally signed by James B. Regg Date: 2025.01.27 00:22:46 -09'00' 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: Under Evaluation: MPE-03 (PTD 1890170) - IA Pressure Increase Date:Tuesday, January 7, 2025 3:54:15 PM From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, December 23, 2024 4:29 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Alaska NS - Milne - Wells Foreman <AlaskaNS- WellsForeman@hilcorp.com>; Derek Weglin <Derek.Weglin@hilcorp.com> Subject: Re: Under Evaluation: MPE-03 (PTD 1890170) - IA Pressure Increase Ryan, Thank you for the email. Your request is approved. Regards, Chris From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, December 24, 2024 12:03:35 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Alaska NS - Milne - Wells Foreman <AlaskaNS- WellsForeman@hilcorp.com>; Derek Weglin <Derek.Weglin@hilcorp.com> Subject: RE: Under Evaluation: MPE-03 (PTD 1890170) - IA Pressure Increase Mr. Wallace, On 12/15/24 Gas Injector MPE-03 (PTD 1890170) passed a PPPOT-T after torquing three loose nuts on the tubing adapter flange. On 12/21/24 a non-witnessed passing MIT-IA to 1556 psi was performed with the well offline. AOGCC approval is now requested to place the well back on gas injection in order to perform an AOGCC witnessed MIT-IA. MPE-03 is due for its 2 year MIT-IA this month, if the well remains shut in through December, we will re-classify the well to Not Operable until AOGCC approval to resume injection is received. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Tuesday, December 10, 2024 5:57 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: Under Evaluation: MPE-03 (PTD 1890170) - IA Pressure Increase Mr. Wallace – Gas Injector MPE-03 (PTD: 1890170) operates under AIO 10B.006 for sustained OA pressure. The well is due for its 2 year MIT-IA this month. On 12/6/24 the IA was bled to 600 psi in preparation for a pre-witnessed MIT-IA (MIT-IA has not yet been performed). On 12/9/24 the IA had risen to 1200 psi and on 12/10/24 further increased to 1280 psi. The well has been shut in and re-classified as Under Evaluation. Plan Forward: 1. PPPOT-T 2. MIT-IA with the well shut in. The well will remain shut in until AOGCC approval is received following the diagnostic work. Please respond with any questions or concerns, Attached is a WBS and 30 day TIO. Thank you, Ryan Thompson Milne / Islands / WNS 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 the individual 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: Under Evaluation: MPE-03 (PTD 1890170) - IA Pressure Increase Date:Wednesday, December 11, 2024 9:03:33 AM Attachments:MPE-03 30 day TIO plot.docx MPE-03 .pdf From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, December 10, 2024 5:57 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: Under Evaluation: MPE-03 (PTD 1890170) - IA Pressure Increase Mr. Wallace – Gas Injector MPE-03 (PTD: 1890170) operates under AIO 10B.006 for sustained OA pressure. The well is due for its 2 year MIT-IA this month. On 12/6/24 the IA was bled to 600 psi in preparation for a pre-witnessed MIT-IA (MIT-IA has not yet been performed). On 12/9/24 the IA had risen to 1200 psi and on 12/10/24 further increased to 1280 psi. The well has been shut in and re-classified as Under Evaluation. Plan Forward: 1. PPPOT-T 2. MIT-IA with the well shut in. The well will remain shut in until AOGCC approval is received following the diagnostic work. Please respond with any questions or concerns, Attached is a WBS and 30 day TIO. Thank you, Ryan Thompson Milne / Islands / WNS 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, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. DATE REV. BY COMMENTS MILNE POINT UNIT WELL E-03 API NO:50-029-21916 BP EXPLORATION (AK) MPU E-03i KB-SL = 54' Parker 141 KB-GL = 30' Parker 141 10,707' CASING RA MARKER 11,241' 7" EZSV 7/1/95 DBR/DMR CONVERT TO MAC DIAGRAM 8/5/89 DBR/DMR INITIAL COMPLETION 6679' 9-5/8“ 47 #/ft L-80 110' 13-3/8“ 46 ppf H-40 11/20/03 MAS Add9-5/8“&SurfaceCasingtoDiagram Well required to have a SSSV installed when on injection. BOT IBP Perforation Summary Ref log:SWS 4/19/94 Size SPF Interval TVD 3 3/8" 4 10740-10756' 6828' - 6837 3-3/8" 6 10,768' - 10,796' 6843' - 6858' 3 3/8" 6 11,096' - 11,130' 7013' - 7030' 3 3/8" 6 11,154' - 11,212' 7042' - 7072' 3 3/8" 4 11,280' - 11,288' 7108' - 7112' C-Sands A-Sands SQUEEZED SQUEEZED KOP @ 1100'' Max. hole angle = 60° @ 6500' 7" 26 & 29 ppf, L-80, BTC & NSCC Csg ( drift ID = 6.059", cap. = 0.0371 bpf ) ( capacity w/ 3.5" Tbg inside = 0.0252 ) 3 1/2" 9.2 ppf, L-80, TC-II Tbg ( drift ID = 2.867", cap. = 0.0087 bpf ) 7" Csg above Pkr was tested to 4200 psi on 10/31/12 3.5" SLB ‘BP-6I’ SSSV Nipple (2.813" ID) 2183' 3.5" HES ‘XD’ Duro Sleeve 2.813" ID (Opens Down) 10,004 3.5" HES ‘X’ Nipple (2.813" ID) 10,105' 10,165' WLEG 10,196' 3.5" HES ‘XN’ Nipple (2.750" No-Go ID) 7" x 3.5" HES ‘TNT’ Packer 10,069' 11/1/12 Hulme Casing Repair and RWO - Doyon 16 1/4" Control line displacement is 0.95 gallons per 1000' 7" BOT Payzone ‘ECP’ Inflatable Pkr w/ cement to surface @ 1831' 7" BOT Float Collar & Csg Patch @ 1850' 7" HES ‘BTC’ ES-Cementer @ 1808' Tree: 3 1/8" 5M Cameron Wellhead: 11" FMC Gen 5 Tbg. Hgr: 3.5" w/ TC-II T&B Thread & 3" CIW ‘H’ BPV Profile WRDP-1WARNING: The needle valve between the panel and the wellhead must be closed when a SCSSV or dummy is not set in the nipple down hole. Failure to do this will allow effluents to back flow into the reservoir of the control panel causing a release into the wellhouse. Cement chunks are covering the top of the IBP that has moved down the hole. 3 1/2"WRP-1 Set 7/18/143 1/2"WRP-1 Set 2/15/13 3.5" WRDP-1 Set 10/28/18 (65" in length). Hilcorp Alaska, LLC 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: MPE-03 (PTD# 189-017) Inconclusive MIT-IA Date:Friday, December 23, 2022 9:08:29 AM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (OGC) Sent: Friday, December 23, 2022 9:07 AM To: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: RE: MPE-03 (PTD# 189-017) Inconclusive MIT-IA 2 tests were witnessed by AOGCC on 12/11/2022 test #1 was suspended after 15 minutes (pressure declined below required test pressure) – FAIL test #2 was deemed Inconclusive (slight pressure increase during the last 15 minute test interval) – I have changed the test result to PASS Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Wednesday, December 21, 2022 3:12 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: MPE-03 (PTD# 189-017) Inconclusive MIT-IA Mr. Regg, On 12/11/22 we conducted a witnessed MIT-IA on MPE-03 Gas Injector. Initially Austin and Derek called it a passed in the field (-45 psi/+2 psi). Austin spoke with Derek a short time later and wanted to call the test inconclusive due to gaining 2 psi in the second 15 minute period. Attached is the data from the MIT. After a review of this data by myself and Oliver, we feel that the MIT is a pass. Below is the time period that we looked at: 13:09:13.186 4612 psi 13:24:13:186 4567 psi 13:39:13.186 4567 psi Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward 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 State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC E-03 MILNE PT UNIT E-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 E-03 50-029-21916-00-00 189-017-0 G SPT 6459 1890170 4450 3539 3533 3547 3558 760 757 756 759 REQVAR P Austin McLeod 12/11/2022 Two year to 1.2x MAIP. AIO 10B.006. This report is the bump up from previous fail. 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 E-03 Inspection Date: Tubing OA Packer Depth 4405 4608 4566 4568IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221212183228 BBL Pumped:0.2 BBL Returned:3 Thursday, January 26, 2023 Page 1 of 1             (refer to Inspect Rpt # mitSAM1212182528) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC E-03 MILNE PT UNIT E-03 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 E-03 50-029-21916-00-00 189-017-0 G SPT 6459 1890170 4450 3549 3541 3539 763 758 760 REQVAR F Austin McLeod 12/11/2022 Two year to 1.2x MAIP. AIO 10B.006. Test fell below test pressure. IA presssure was bumped up and on a separate report. 30 MinPretest Initial 15 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 E-03 Inspection Date: Tubing OA Packer Depth 1572 4511 4405IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221212182528 BBL Pumped:4.2 BBL Returned: Thursday, January 26, 2023 Page 1 of 1 Two year to 1.2x MAIP. AIO 10B.006. Test fell below test pressure. IA presssure was bumped up and on a separate report. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, December 24, 2020 P.I. Supervisor I li 'i1 Z,I L7-1 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC E-03 FROM: Adam Earl MILNE PT UNIT E-03 Petroleum Inspector Sre: Inspector Reviewed By: n P.I. Supry v— NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT E-03 API Well Number 50-029-21916-00-00 Inspector Name: Adam Earl Permit Number: 189-017-0 Inspection Date: 12/19/2020 Insp Num: mitAGE201220122548 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well E-03 'Type Inj G " Typ 6459 Tubing 3259 3261 3256 3259 PTD 1890170 Type Test SPT Test psi 4000 IA 1674 4080 4000 3983 - BBL Pumped: �i 2 BBL Returned: - -- 1.9 I OA 521 - 515 - --- 519 - szo, Interval REQVAR P/F P Notes: Tested as per AIO 1013.006 to 1.2 X's the MAIP Thursday, December 24, 2020 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,December 28,2016 TO: Jim Regg P.I.Supervisor ))gee; (Z.fr SUBJECT: Mechanical Integrity Tests l ` L' HILCORP ALASKA LLC E-03 FROM: Jeff Jones MILNE PT UNIT KR E-03 Petroleum Inspector Src: Inspector Reviewed By:,-- P.I.Supry JT 2 NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT KR E-03 API Well Number 50-029-21916-00-00 Inspector Name: Jeff Jones Permit Number: 189-017-0 Inspection Date: 12/13/2016 Insp Num: mitJJ161213213805 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11 E-03 ' Type Inj G TVD i 6483 Tubing 3358 J 3333 • 3328 - 3327- PTD 1890170 (Type Test SPT'Test psi 4200 IA 1044 4475 4396 4356 P ✓: ..A. j 1352 1328 . 1300 . 1291 - Interval IP/F OA REQVAR 2year MIT-IA to 1.2 X maximum in- _ barrels injection pressure per AID l OB.006(MIP=3450).3,4 barrels diesel pumped.One well inspected,no exceptions noted. -- SCANNED APR 0 5 LO Wednesday,December 28,2016 Page 1 of 1 IRSKA OIL AND G STATE OF ALASKA RECEIVED AS CONSERVATION COMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 2 2 20113 1. Operations Performed: AOGCC ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic \ . 189 - 017 3. Address: ❑ Development ® Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50.029 21916 - 00 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025518 & 047437 MPE - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): USIT Milne Point / Kuparuk River 11. Present well condition summary: Total depth: measured 11520' feet Plugs:(measured) 11241' feet true vertical 7234' feet Junk: (measured) 11152' feet Effective depth: measured 11241' feet Packer: (measured) 10069' feet true vertical 7087' feet Packer: (true vertical) 6461' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 13/3/8" 110' 110' 1670 670 Surface 6679' 9 -5/8" 6679' 4655' 6870 4760 Intermediate Production 11375' 7" 11375' 7158' 7240 / 8160 5410 / 7020 Liner SCANNED MAR 18 2013 Perforation Depth: Measured Depth: 10740' - 11212' feet True Vertical Depth: 6828' - 7072' feet Tubing (size, grade, measured and true vertical depth): 3 - 1/2 ", 9.2# L - 10197' 6532' Packers and SSSV (type, measured and true vertical depth): 7" x 3 - 1/2" HES TNT Packer 10069' 6461' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Pull Tubing, Cut 7" Casing at 1853', Pull and Replace with 7 ", 26#, L - 80. Cement w/ 67 Bbls (322 sx) Class 'G' (yield 1.17). 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 6071 1420 3870 Subsequent to operation: 0 340 620 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: o ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service ® Daily Report of Well Operations 16. Well Status after work: ., ❑ Oil ❑ Gas ❑ WDSPL ® Well Schematic Diagram ❑ GSTOR ❑ WINJ ❑ 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: Contact: Sean McLaughlin, 564-4387 • 312 Email: Sean.McLaugn @p.com Printed : Joe L; ., Title: Drilling Technologist Signatur- i , ' LL_______ RBr �1sho $ `: 4091 Date: (f2.1/15 l '�� Form 10-404 R- • ed 10/201 2,2743 bmit Original Only Tree: 3 1/8" 5M Cameron • Wellhead: 11" FMC Gen 5 MPU E -�31 KB-SL = 54' Parker 141 Tbg. Hgr: 3.5" w/ TC -II T &B Thread KB -GL = 30' Parker 141 & 3" CIW 'H' BPV Profile • ( 2- - `'`) o 7" Csg above Pkr was tested S 7051 '' to 4200 psi, on 10/31/12 110' 13 - 3/8" 46 ppf H - 40 Well required to have a SSSV c, installed when on injection. • 7" HES `BTC' ES- Cementer @ 1808' 4 7" BOT Payzone 'ECP' Inflatable Pkr w/ cement to surface @ 1831' 7" BOT Float Collar & Csg Patch @ 1850' KOP @ 1100" Max. hole angle = 60° @ 6500' ,, 3 1/2" 9.2 ppf, L -80, TC -II Tbg D nt. '' 3.5" SLB 'BP -61' SSSV Nipple I 2183' v ( drift ID = 2.867 ", cap. = 0.0087 bpf) (2.813" ID) ' 7" 26 & 29 ppf, L -80, BTC & NSCC Csg ( drift ID = 6.059 ", cap. = 0.0371 bpf ) ( capacity w/ 3.5" Tbg inside = 0.0252 ) 4 6679' 9 -5 /8" 47 # /ft L -80 1/4" Control line displacement is 0.95 gallons per 1000' Ep ► s; i ■ : 3.5" HES `XD' Duro Sleeve 10,004 The needle valve between I 2.813" ID (Opens Down) the panel and the wellhead II must be closed when a SCSSV or dummy is not set in the nipple down hole. 7" x 3.5" HES TNT' Packer 10,069' Failure to do this will allow Iti effluents to back flow into the 3.5" HES 'X' Nipple 10,105' reservoir of the control panel (2.813" ID) causing a release into the welihouse 3.5" HES `XN' Nipple 1 10,165' (2.750" No -Go ID) El WLEG 1 10,196' 1 Cement chunks are covering the top I � C 6 ts` ` - of the IBP that has moved down the --/-7/ r JN 1 3 hole. BOMB P • G — 10,707 CASING RA MARKER Perforation Summary — Ref Iog:SWS 4/19/94 .• . Size SPF Interval TVD D 11,241' 7" EZSV C -Sands A / 3 3/8" 4 10740 - 10756' 6828' - 6837 — A Sanris 3 -3/8" 6 10,768' - 10,796' 6843' - 6858' 3 3/8" 6 11,096' - 11,130' 7013' - 7030' 3 3/8" 6 11,154' - 11 212 7042 7072' 3 3$ in Ji 4,:r 11,280' - 11,288' S: t7/t(18 If 7112N DATE 2EV BY COMMENTS MILNE POINT UNIT 8/5/89 DBR /DMR INITIAL COMPLETION WELL E -03 7/1/95 DBR /DMR CONVERT TO MAC DIAGRAM API NO: 50- 029 -21916 11/20/03 MAS Add 9 -5/8" & Surface Casing to Diagram 11/1/12 Hulme Casing Repair and RWO - Doyon 16 BP EXPLORATION (AK) , i� a MPU E -03i 11V 13 -3/8" 46 #/ft H -40 I I FMC TUBING HANGER W/ 3" 'H' BPV PROFILE NOTES: ,, 2 7/8" 6.5 # /FT L -80 CS HYDRIL Al (2.441' ID, 2.347" DRIFT) 1. ALL MEASUREMENTS ARE FROM KDB OF PARKER RIG 141 -411 1.125" 2.5 # /FT CS HYDRIL SIDE STRING KDB -SL = 54' KDB-GL = 30' Qssv 526' OTIS FMX 2 7/8" SCSSV 2. MAX. ANGLE = 60' 6500' Note: The TRSV is locked out and a WLRSV is set in the nipple. 3. K.O.P. = 1100' Run oversize o - rings on safety valve. 91QV117 - H HES SAP# 100006558 4. SLANT HOLE: YES - lig 2057' END OF TUBING 5. TREE TYPE: FMC 3 1/8" API 5000# WITH 2 7/8" 8rd TREETOP CONNECTION Well required to have a SSSV >/ installed. 6. MIN. RESTRICTION IS OTIS XN NIPPLE . (2.205" 1D) 7. COMPLETION FLUID: 9.6 PPG NaCL BRINE • 6679' 9-5/8' 47 #/ft L -80 PERFORATIONS: ' 6 SPF AT 0' PHASING, 2 1/8" DYNASTRIP % 11,096'- 11,130'MD v _ i ) i/ 'C 7009' -7027" TVD / \ ` v 11,150'- 11,208' MD / 1 7038' -7067' TVD 4 SPF AT 90' PHASING �— OTIS SBR OVERSHOT /J -SUB ASSEMBLY ~� 11,288' - 11280' MD 7109' -7111' TVD 10,109' OTIS HCM PERMANENT PACKER (2.97" ID ) (SQUEEZED WITH CEMENT) Qv ec� / /l - 1Q/156' 2 7/8" OTIS XN NO- GO NIPPLE (2.205" ID) PERFORATIONS ADDED 10,164' 3 1/2" OTIS RH CATCHER SUB 4 -19 -94 10,165' TUBING TAIL A SANDS 6 SPF 0 DEGREES PHASING I S v .� 10,707' CASING RA MARKER 11100' - 11130' MD 1 v i „ i ' . , i 11154' - 11212' MD t ,,.� C- SANDS 4 SPF CD 0 DEGREES PHASIN 7 „„ c , _ ' l t 10740'- 10756' MD 10 11,241' 7" EZSV — `A PERFORATIONS ADDED 7 -3 -94 — 11,375' 7 ", 29 LB /FT L -80 BTRS (6.184" ID, B -SANDS II k 6.059" DRIFT) 10768 -10796 RKB MD 4 SPF, 0 DEGREES PHASING, 100 SHOTS TOTAL DATE 1EV BY COMMENTS MILNE POINT UNIT 8/5/89 DBR/DMR INITIAL COMPLETION WELL E -03 7/1/95 DBR /DMR CONVERT TO MAC DIAGRAM API NO: 50-029 -21916 11/20/03 MAS Add 9 -5/8' & Surface Casing to Diagram BP EXPLORATION (AK) • • MPE -03, Well History (Pre Rig Workover) Date Summary 09/09/12 T /I /O= SI,790,660 Conducted PJSM Removed well house, verified barriers (SSV/ Wing, Lateral Valves) and removed flowlines from the wing valve back to the lateral valve. Installed, TQ'd and leak tested blinds. Removed foundation, and installed 2nd lateral valve on the backside of well. TQ'd and PT'd connections (300 low / 3500 High). 09/13/12 DRIFT W/ 2.08" DMY PERF GUN, T.E.L, S. BAILER SD @ 10091' SLM.. CONT RIH. LOC TT @ 10141' SLM (10164' MD -24' CORRECTION). TAG SOLID BTM @ 11148' SLM (11162' MD). 50' OF FILL ABOVE BTM PERFS. RECOVERED 2 TBL SPOONS OF FORMATION SAND . 09/14/12 T /I /0= 3050/750/740 Assist E'line, Load and kill Rigged up to remote kill line and pumped 3 bbls 60/40 meth, 155 bbls 1% KCL, 15 bbls 60/40 meth down Tubing. * *Swab, Wing= closed. Master, IA, 0A= open kill line left open to double block ** FWHP's= 1500/1070/880. 09/14/12 INITIAL T /I /O - 3050/748/738 PSI. RIG UP ELINE EQUIPMENT AND PT RIH W/ HEAD /ERS/WB /BAKER IBP OAL = 38.2' OAW = 230LBS MAX OD = 2.125" FN = 1.38 ". ME SET DEPTH = 10820'. CCL TO ME = 24.2'. CCL STOP DEPTH = 10795.8'. TOP OF PLUG = 10812.88' CORRELATED TO HALLIBURTON PERFORATING RECORD DATED 11- AUGUST -1989. FINAL T /I /O = 1650/700/700. 09/15/12 Pumped 100 bbls kcl at about 1.6 bpm at 2700 psi for about the first 50 bbls. Rate increased from 1.6 bpm to 2.7 bpm in the remaining 50 bbls, at 2700 psi. Freeze protect tubing with 15 bbls 60/40. Final W H Ps= 1800/950/800. 09/15/12 T /I /O = 1680/740/720. Barriers; Pri - SSV, Sec - Swab. ** *Scope; set salt plug to cover perfs * ** Max allowable WHP during pump job 2700 psi (1000 psi over SIWHP) Speared in a 30 bbl meOH pill followed with a load of 2% KCI. Pumped 4100 Ibs of fine salt (not sized) NaCI, mixed w/ 16.3 bbls saturated brine / for a salt slurry (pill). Spaced out before (5 bbls) and after (10 bbls) salt pill with high viscosity 10 ppg /AV saturated brine. Shut down pump after displacing w/ 53 bbls 60/40 as the salt pill reached the top perf at 10740'. TBG freeze protected. SLB RDMO. SSV and Swab vlvs S/I an DSO notified @ departure. IA/OA open to gauges. Final T /I /O= 2100/800/830. 09/16/12 RAN 2.0" CENT, T.E.L., SAMPLE BAILER. LOC TT @ 10138' SLM (10165' MD -27' CORRECTION. TAG SALT @ 10715' SLM (10742' MD 2' BELOW TOP OF PERFS). RECOVERED 1/4 CUP OF SALT. 09/18/12 SVS W/ AS. GREASE CAPS VERIFIED. SVC, SV,SSV,SO RIG UP COULD GET LEAK TIGHT BARRIERS. GOOD BARRIERS. 09/19/12 Slickline, E -Line And Ct Tags [TAG] - CTU #9 - 1.75" CT - JOB SCOPE = TAG SALT PLUG /LAYIN ADDITIONAL SALT /CEMENT CAP. RIH W/ NIPPLE LOCATOR. LOCATE NIPPLE AT 10115' CTM, CORRECT DEPTH TO 10156 ELM, TAG SALT TOP AT 10736 ELM. POOH AND PIC. 09/19/12 CTU #9 - 1.75" CT - Job Scope = Tag salt plug /layin additional salt/cement cap. RIH w/ nipple locator. Locate nipple at 10115' ctm, correct depth to 10156 elm, tag salt top at 10736 elm. POOH and pick up 2" BDN. Pumped 2600# of NaCL brine. POOH to pick up 2.1" Pig shear nozzle while salt settled out. Tagged top of salt at 10745, pull up hole and wait for salt to continue settling. Page 1 of 2 • • MPE -03, Well History (Pre Rig Workover) Date Summary 09/20/12 CTU #9 - 1.75" CT - Job Scope = Tag salt plug /layin additional salt/cement cap....Continued from WSR 9/19/12...RIH w/ Pig shear nozzle to tag top of salt in preparation for cement cap. Initial top of salt tag at 10745.4', second tag of 10743.9, continue standing by while salt settles out. After 8 hrs tag at 10737' and POOH to MU latch assembly to confirm tag depth. Tagged top of salt @ 10745' down & 10737' on the up wt. Page 2 of 2 • °� 3a o Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/20/2012 00:00 - 00:30 0.50 MOB P PRE CREW CHANGE. PJSM FOR PULLING OFF WELL. - WSL, TOOL PUSHER AND CREW IN ATTENDANCE. - REVIEW DDI SOP FOR PULLING OFF WELL AND RIG MOVE. - NOTIFY DSO FOR PULLING OFF WELL, HE WAIVED WITNESS. 00:30 - 01:00 0.50 MOB P PRE LAY MATS TO PULL OFF WELL. 01:00 - 02:00 1.00 MOB P PRE WITH WELL SECURE. - JACK UP RIG AND PULL OFF WELL. - POSITION RIG ON SIDE OF PAD. 02:00 - 04:00 2.00 MOB P PRE POSITION MATS IN FRONT OF RIG TO WEST SIDE OF PAD. 04:00 - 05:00 1.00 MOB P PRE MOVE RIG TO OPPOSITE WEST SIDE OF PAD. - TRAVELING ON RIG MATS. - SET RIG DOWN ON RIG MATS. 05:00 - 06:00 1.00 MOB P PRE CLEAR MATS AND HERCULITE FROM AROUND CELLAR. - P/U MATS FROM BEHIND RIG AND STACK ON SIDE OF PAD. 06:00 - 06:30 0.50 MOB P PRE COMPLETE PAD INSPECTION ON MPE -06 WITH DSO. - CLOSE OUT WELL WORK TRANSFER PERMIT. 06:30 - 07:00 0.50 MOB N WSEQ PRE WAIT ON ORDERS FROM TOWN FOR NEXT WELL. 07:00 - 09:00 2.00 MOB P PRE CONDUCT LEVEL 2 RISK ASSESMENT AT MPU. - FOR UPCOMING RIG MOVES FOR DOYON 16 F/ MPE PAD TO MPF PAD. - INCLUDING DOYON 14 RIG MOVE FROM MPS PAD TO MPE PAD. - WITH DOYON 16, DOYON 14, BP SAFETY, MPU TEAM AND RWO FIELD SUPERINTENDANT. 09:00 - 12:00 3.00 MOB N WSEQ PRE RIG ON STANDBY FOR SERVICE COIL TO COMPLETE WORK ON MPE -03. - WHILE WAITING PERFOM RIG MAINTENANCE. - PAINTING PROJECTS AND CLEANING ON RIG. - PJSM FOR DRAG CHAIN REMOVAL AND REPAIRS. - PREP DRAG CHAIN FOR REMOVAL. 12:00 - 12:30 0.50 MOB N WSEQ PRE RIG ON STANDBY FOR SERVICE COIL TO COMPLETE WORK ON MPE -03. - CREW CHANGE. PJSM FOR DRAG CHAIN REMOVAL. 12:30 - 17:00 4.50 MOB N WSEQ PRE RIG ON STANDBY FOR SERVICE COIL TO COMPLETE WORK ON MPE -03. - REMOVE DRAG CHAIN AND TRANSPORT TO • SHOP FOR REPAIRS. - PJSM, REMOVE FRONT BOOSTER AND BOOSTER CRADLE. - REMOVE FONT SPREADER BEAM. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF- E:DRILL (3,860,000.00 Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 00:00 7.00 MOB N WSEQ PRE RIG ON STANDBY FOR SERVICE COIL TO COM WORK ON MPE -03. - PJSM, REMOVE FRONT BOOSTER ROLLUP DOORS AND TRACKS. - PREP AND CLEAN DRAG CHAIN AT SHOP FOR REPAIRS. - CLEAN AND PAINT ON RIG. 9/21/2012 00:00 05:00 5.00 MOB N WSEQ PRE RIG ON STANDBY FOR SERVICE COIL TO COMPLETE WORK ON MPE -03. - CREW CHANGE, PJSM FOR ONGOING MAINTENANCE. - REINSTALL FRONT SPREADER BEAM. - PREP AND CLEAN DRAG CHAIN AT SHOP FOR REPAIRS. - CLEAN AND PAINT ON RIG. - COMPLETE DDI WORK ORDERS. 05:00 - 12:00 7.00 MOB N WSEQ PRE TOOL SERVICE FIELD SUPPORT LAYED RIG MATS FROM BEHIND RIG TO OTHER SIDE OF MPE PAD TO MOVE RIG TOWARDS MPE -03. - LAYED ABOUT HALF THE MATS AND STOPPED DUE TO FREEZE PROTECT JOBS PAD. ON 2 WELLS ON THAT SIDE OF THE - RIG CREWS WORKED AS DIRECTED BY TOOL PUSHER AND WSL. 12:00 - 18:00 6.00 MOB N WSEQ PRE WORK ON THE RIG AS DIRECTED BY TOOL P USHER. - TOOL PUSHER DISCUSSED WITH BOTH RIG CREWS THE LATEST DRIVING INCIDENTS ACROSS THE FIELD. - REVIEWED DDI FATIGUE MANAGEMENT PROGRAM WITH CREWS. - REVIEWED BP POLICY OF 16 HRS WORK MAXIMUM IN A 24 PERIOD. 18:00 - 22:00 4.00 MOB N WSEQ PRE UIT STY CE COIL CONTIN TO COM E WH ANDB WORK ON FOR MPE -03. SERVI - CONTINUE WITH GENERAL RIG MAINTENANCE. - CLEAN AND PAINT ON RIG. - CONTINUE WITH DRAG CHAIN REPAIRS AT SHOP. - LAY MATS TO MOVE RIG TO EAST SIDE OF PAD. 22:00 - 00:00 2.00 MOB N WSEQ PRE PJSM, JACKUP, MOVE RIG TRAVELING ON RIG MATS. - STAGE RIG ON MATS AT EAST SIDE OF P AD. - MOVING RIG ON SAME SIDE OF PAD AS MPE -03. - MATS NOT BEING UTILIZED NEEDED FOR NORDIC 1 RIG MOVE. - REVIEW DDI POLICY WITH BOTH CREWS FOR DECONTAMINATION OF WORK CLOTHES AND PPE. 9/22/2012 00:00 - 00:30 0.50 MOB N WSEQ PRE RIG ONL STANDBY FOR SERVICE COIL TO COMPLETE WORK ON MPE -03. - CREW CHANGE, PJSM FOR ONGOING MAINTENANCE. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No I L Event Type: ( WO e: WORKOVER Start Date: 9/20/2012 End Date: 11/1/2012 X4- 0OVKF -E:DR L (3, 86 0,000.00 ) (WO) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 05:00 4.50 MOB N WSEQ PRE - CONTINUE WITH GENERAL RIG MAINTENANCE. - CLEAN AND PAINT ON RIG. - CONTINUE WITH DRAG CHAIN REPAIRS AT SHOP. - GATHER AND STACK UNUSED RIG MATS. 05:00 - 12:00 7.00 MOB N WSEQ PRE CONTINUE WITH GENERAL RIG MAINTENANCE. - CLEAN AND PAINT ON RIG. - CONTINUE WITH DRAG CHAIN REPAIRS AT SHOP. - SUCCESSFUL FUNCTION TEST ON ESD FOR BOTH BOILERS - RIG CREWS WORK AS DIRECTED BY TOOLPUSHER. 12:00 - 18:00 6.00 MOB N WSEQ PRE PRETOUR SAFETY MEETING AND CREW CHANGE. - DISCUSSED WITH RIG CREW RECENT DEBRIS IN EYE INCIDENTS ON THE RIG. - WSL, TOOLPUSHER, SCS, AND RIG CREW IN ATTENDANCE. - CONTINUE WITH GENERAL RIG MAINTENANCE. CLEAN AND PAINT ON RIG. CONTINUE WITH DRAG CHAIN REPAIRS AT SHOP. - RIG CREW WILL WORK AS DIRECTED BY TOOLPUSHER. - RE- INSTALLED REBUILT DRAG CHAIN ASSEMBLY. - DRILLER WILL REVIEW UPCOMING WELL PLAN WITH CREW WHEN TIME AND TASKS PERMIT. - COIL SERVICE RIG #9 PERFORM CMT JOB AT NOON. 18:00 - 22:00 4.00 MOB N WSEQ PRE RIG ON STANDBY FOR SERVICE COIL. CURRENTLY R/D SERVICE COIL. - SLICKLINE TO R/U ON MPE -03. - CLEAN AND PAINT ON RIG. - COMPLETE DDI WORK ORDERS. - MAT IN FRONT OF RIG DOWN NORTH END OF PAD. - 24 HR NOTIFICATION TO AOGCC AT 19:00 HRS FOR MPE -03 INITIAL BOP TEST. - AOGCC REP LOU GRIMALDI WAIVED WITNESS TO BOP TEST. 22:00 - 00:00 2.00 MOB N WSEQ PRE RIG ON STANDBY FOR SLICKLINE TO COMPLETE WORK ON MPE -03. - PJSM, JACKUP RIG AND MOVE AHEAD TRAVELING ON MATS TO CLEAR MPE -06 TO ALLOW CRANE TO INSTALL FLOWLINE AND WELLHOUSE ON MPE -06. - STAGE RIG ON MATS AT NORTH END OF PAD. - P/U MATS TO MAKE ACCESS FOR MPE -06 CRANE WORK. Printed 1/14/2013 1:45:58PM • Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 9/23/2012 00:00 - 05:00 5.00 MOB N WSEQ PRE RIG ON STANDBY FOR SLICKLINE TO COMPLETE WORK ON MPE -03. - FINISH GATHERING UP RIG MATS FROM SOUTH END OF PAD FOR CRANE ACCESS. - CLEAN AND PAINT ON RIG. - COMPLETE DDI WORK ORDERS. 05:00 - 10:30 5.50 MOB N WSEQ PRE RIG CREWS TO CONTINUE TO WORK AS DIRECTED BY TOOLPUSHER. - CLEAN AND PAINT ON RIG. - CONTINUE TO COMPLETE MAINTENANCE AND WORK ORDERS. 10:30 - 12:00 1.50 MOB N WSEQ PRE HELD WEEKLY SAFETY MEETING WITH RIG CREW. - WSL, TOOLPUSHER, SCS, RIG CREW, AND RIG SUPPORT CREW IN ATTENDANCE. - REVIEWED DDI DRIVING POLICY CONCERNING CELL PHONES, FATIGUE, DRIVER DISTRACTIONS, AND LOW VISIBILITY AT DUSK AND DAWN. REVIEWED EYE INJURIES ON THE RIG DURING MAINTENANCE AND STAND BY. - WATCHED THE GWO -HIGH VALUE LEARNING -DOYON 16- MPL -06 VIDEO. CREW DISCUSSED THE LESSONS LEARNED FROM THE VIDEO FINDINGS. - THE VALUE OF HAVING A THOROUGH PROCEDURE TO FOLLOW. - WHAT THE BARRIERS ARE BETWEEN YOU AND THE PRESSURE. - THE RISKS OF THE OPERATION. 12:00 - 00:00 12.00 MOB N WSEQ PRE RIG ON STANDBY FOR WIRELINE TO COMPLETE WORK ON MPE -03. - RIG CREWS TO CONTINUE TO WORK AS DIRECTED BY TOOLPUSHER. - NOTED SLICKLINE TAGGED TOC @ 10520' MD. - CLEAN AND PAINT ON RIG. - CONTINUE TO COMPLETE MAINTENANCE AND WORK ORDERS. - INVENTORY EQUIPMENT FOR MPE -03 AS IT ARRIVES. - CONDUCT WEEKLY SAFETY MEETING WITH ONCOMING CREW. - REVIEW RECENT EYE INJURIES DUE TO LACK OF PPE DECONTAMINATION. - WATCH AND REVIEW PRESENTATION ON STENA INCIDENT, IMPROPER RIGGING RESULTING IN FATALITIES. - REVIEW AND DISCUSS DRIVING INCIDENTS DUE TO FATIGUE AND DISTRACTIONS. WHAT WE CAN DO TO MITIGATE DRIVING HAZARDS. - WATCH DDI PRESSURE RELIEF VALVE TRAINING POWER POINT. - WATCHED THE GWO -HIGH VALUE LEARNING -DOYON 16- MPL -06 VIDEO. Printed 1/14/2013 1:45:58PM z A Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:OO:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/24/2012 00:00 - 12:00 12.00 MOB N WSEQ PRE RIG ON STANDBY FOR WIRELINE TO COMPLETE WORK ON MPE -03. - RIG CREWS TO CONTINUE TO WORK AS DIRECTED BY TOOLPUSHER. - CLEAN AND PAINT ON RIG. - C TO COMPTE MAINTENANCE AND WORK ORDERS. - INVENTORY ONTINUE EQUIPMENT LE FOR MPE -03 AS IT ARRIVES. 12:00 - 18:00 6.00 MOB N WSEQ PRE RIG SD F PRE WE WORK MPE -03. - INFORMED MPE -03 BY OR FAILED MIT LL AT 2500 PSI ON CEMENT ON TAN PLUG. - WS WORK DIRECTED BY TOOLPUSHER. - CLEAN CRE AND PAINT TO CONTINUE ONL RIG. - CONTINUE TO COMPLETE MAINTENANCE E AND RIG WORK ORDERS. 18:00 - 00:00 6.00 MOB N WSEQ PRE SA W WORK ON - RIG CREWS TO CO MPE -03. RIG - WIR ELINE T R/D NDBY UNIT. FOR NTINUE PRE W OE WORK AS DIRECTED BY TOOL ON RIG . CLEAN AND PAINT ON RIG. CONTINUE TO COMPLETE MAINTENANCE AND WORK ORDERS. 9/25/2012 00:00 - 05:00 5.00 MOB N WSEQ PRE RIG ON STANDBY FOR PRE WELL WORK ON MPE -03. - RIG CREWS TO CONTINUE TO WORK DIRECTED BY TOOLPUSHER. - CLEAN AND PAINT ONL RIG. - CONTINUE TO COMPLETE MAINTENAN E C AND WORK ORDERS. 05:00 - 12:00 7.00 MOB N WSEQ PRE DISCUSSED ACTION ITEM AND CI LIST. STANDBY PROJECTS. - RIG WELDERS WORKING ON RIG ROOF HANDRAIL SYSTEM. - CONTINUE TO CLEAN AND PAINT ON RIG. - WORK AS DIRECTED TANDBY FOR BY TOOLPUSHER. 12:00 - 18:00 6.00 MOB N WSEQ PRE RIG ON S PRE WELL WORK ON MPE -03. - RIG CREWS TO WO AS DIRECTED BY TOOLPUSHER. - CLEAN AND PAINT CONTINUE ON RIG. CONTINUE TO COMPLETE MAINTENANCE AND WORK ORDERS. - WELDERS REMOVING ROOF PANEL OVE DRAWORKS. - WIRELINE R/U ON MPE -03 18:00 00:00 6.00 MOB N WSEQ PRE RIG STANDBY WELL WORK ON MPE -0 3. - RIG CREWS TO CONTINUE TO WORK AS DIRECTED BY TOOLP USH ER. - CLEAN AND PAINT ON RIG. - CONTINUE TO COMPLETE MAINTENANCE AND WORK ORDERS. - W INING P OVER DRAWORKS. - WELDERS ELDERS WORK STALL ON FRONT ROOF BOOSTER DOOR FRAME FOR NEW DOOR INSTAL L. - WIRELINE R/U ON MPE -03 Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/26/2012 00:00 - 02:30 2.50 MOB N WSEQ PRE RIG ON STANDBY FOR PRE WELL WORK ON MPE -03. - WIRELINE R/U ON MPE -03. - SUCCESSFUL WITH SETTING PXN PLUG ANUNITT. - SUCCESSFULL NEGATIVE PRESSURE TEST. - WIRELINE R/D. - RIG CREWS TO CONTINUE TO WORK AS DIRECTED BY TOOLPUSHER. - CLEAN AND PAINT ON RIG. - CONTINUE TO COMPLETE MAINTENANCE AND WORK ORDERS. 02:30 - 05:00 2.50 MOB N WSEQ PRE RIG ON STANDBY FOR PRE WELL WORK ON MPE -03. - E -LINE R/U TO MAKE TBG CUT. 05:00 - 12:00 7.00 MOB N WSEQ PRE E -LINE MADE SUCCESSFUL CUT @ 10,070'. - RIGGED DOWN E -LINE. - RIG CONTINUES TO STAND BY FOR PRE RIG WORK TO BE COMPLETED. 12:00 - 17:00 5.00 MOB N WSEQ PRE RIG CONTINUES TO STAND BY FOR PRE RIG WORK TO BE COMPLETED. - NEXT STEP IS FOR WELLS GROUP TO PUMP KILL WT FLUID. - FLOW BACK TANK SPOTTED. 17:00 - 00:00 7.00 MOB N WSEQ PRE RIG CONTINUES TO STAND BY FOR PRE RIG WORK TO BE COMPLETED. - LRS R/U TO CIRC OUT WELL WITH 11 PPG KWF. - PUMP 96 BBL, START TO SEE INCREASE IN TBG PRESSURE TO 2700 PSI. - APPEARS TUBING PACKING OFF. - CONTINUE PUMPING AT REDUCED RATE .25 BPM AT 2700 PSI ON TBG. - ROOF REPAIRS OVER DRAWORKS COMPLETED. - CONTINUE TO COMPLETE MAINTENANCE AND WORK ORDERS. 9/27/2012 00:00 - 02:00 2.00 MOB N WSEQ PRE RIG CONTINUES TO STAND BY FOR PRE RIG WORK TO BE COMPLETED. - LRS CIRC OUT WELL WITH 11 PPG KWF. - CONTINUE PUMPING .25 BPM 2700 PSI. - 107 BBLS PUMPED LOCKUP ON TBG OCCURRED. CANNOT CIRCULATE. - ATTEMPT TO ROCK PUMP RATES. - NOTIFY ODE. - DECISION MADE TO PUMP UP TO 3000 PSI DOWN VA ATTEMPTING TO FREE UP BLOCKAGE. 02:00 - 04:00 2.00 MOB N WSEQ PRE RIG CONTINUES TO STAND BY FOR PRE RIG WORK TO BE COMPLETED. - LRS R/U TO REVERSE CIRCULATE DOWN I /A. - PUMP 10 BBL @ 1 BPM 800 PSI ESTABLISHING RETURNS AT TBG. - INCREASE PUMP TO 2.5 BPM 1600 PSI. - INCREASE PUMP TO 3 BPM 2000 PSI. TBG 125 PSI. - PUMP TOTAL 60 BBLS TO CLEAR TBG. Printed 1/14/2013 1:45:58PM "" 3 ffi $ a Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4 OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:00 1.00 MOB N WSEQ PRE RIG CONTINUES TO STAND BY FOR PRE RIG WORK TO BE COMPLETED. - LRS R/U TO PUMP DOWN TBG. 05:00 - 12:00 7.00 MOB N WSEQ PRE RIG CONTINUES TO STAND BY FOR PRE RIG WORK TO BE COMPLETED. - LITTLE RED PUMPING DOWN TUBING, 86 BBLS AWAY .2 BPM / 3000 PSI. - CONSULT TOWN, OPT TO REV CIRCULATE 15 BBLS. - REV CIRC 15 BBLS @ 1.2 BPM / 2900 PSI, FULL LIQUID RETURNS. - LINE BACK UP AND PUMP DOWN TUBING. - PUMPING 3 BPM / 5 BBLS TO GET RETURNS. - PUMP ANOTHER (7) BBLS @ 3 BPM, THEN OBSERVE PRESSURE INCREASE. - FCP, 3/4 BPM / 2900 PSI. SHUT DOWN PUMPING. 12:00 - 17:00 5.00 MOB N WSEQ PRE RIG CONTINUES TO STAND BY FOR PRE RIG WORK TO BE COMPLETED. - LITTLE RED PERFORMS COMBINATION MIT I/A X TBG @ 1200 PSI AS PER TOWN ENGINEER. (PASSED). LITTLE RED RIGGING DOWN. RIG MATS BEING LAID, RIG PREPARING TO MOVE OVER THE WELL. - NOTIFY DSM TO INSTALL BPV IN MPE -03. 17:00 - 00:00 7.00 MOB N WSEQ PRE WAIT ON DSM TO INSTALL BPV. - COMPLETE WELL WORK TRANSFER PERMIT FOR MPE -03. - NOTED 310 PSI ON VA. - NOTIFY RWO FIELD SUPERINTENDANT AS STATED IN WELL PLAN, STEP # 8. - CONTINUE LAYING RIG MATS TO PULL OVER WELL. - VAC TRUCK EMPTY FLOWBACK TANK. - LEAVE MESSAGE WITH AOGCC AT 15:30 HRS TO UPDATE ON INITIAL BOP TEST. - WITNESS WAS WAIVED BY LOU GRIMALDI ON 9 -22 -12 19:00 HRS. 9/28/2012 00:00 - 02:15 2.25 MOB N WSEQ PRE WAIT ON DSM, INSTALL AND TEST BPV. - TBG ON VAC. I /A= 100 PSI. O /A= 520 PSI. 1" SIDE STRING= 340 PSI. 02:15 - 02:30 0.25 MOB P PRE PJSM FOR MOVING RIG AND PULLING OVER WELL. - ENSURE ALL TREE VALVES CLOSED. - NOTIFY DSO FOR BACKING OVER WELL. 02:30 - 04:00 1.50 MOB P PRE MOVE RIG AROUND FRONT OF PAD ON RIG MATS. - BACK AND CENTER RIG OVER MPE -03 - SHIM AND LEVEL RIG. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 06:00 2.00 RIGU P PRE P/U RIG MATS. SET EQUIPMENT. - STRING GIATRONICS CABLE TO WSL OFFICE. - R/U KILL MANIFOLD IN CELLAR. - FILL PITS WITH 11 PPG BRINE KWF. - HARD LINE CREW CALLED OUT @ 04:30 HRS. ACCEPT RIG ON MPE -03 AT 06:00 HRS. 06:00 - 10:30 4.50 KILLW P DECOMP PJSM. TAKE ON 100 DEGREE 11 PPG BRINE TO PITS. - PREPARE TO CIRCULATE WELL TO 11 PPG BRINE. - FLOW BACK TANK SPOTTED, WAITING ON HARDLINE CREW. - CONDUCTED RIG EVACUATION DRILL, FIRE IN THE PIPE SHED. - SITE CONTROL SPECIALIST CHANGE OUT DAY. - TOOLPUSHER ACTED AS SCS. ALL HANDS ON LOCATION ALERTED. - HALLIBURTON HANDS MUSTERED WITH RIG HANDS. - GOOD AAR. FORK LIFT SECURED PAD. 10:30 - 13:00 2.50 KILLW P DECOMP PJSM. RIG UP HARD LINE TO FLOW BACK TANK. - PRESSURE TEST HARD LINE @ 250 / 4000 PSI, 5 MIN EACH / CHARTED. - PRESSURE RELIEF VALVE ON MUD PUMP SET @ 4250 PSI. 13:00 - 16:00 3.00 KILLW P DECOMP CREW @ RIG 14, WAIT ON WELL SUPPORT TO PULL BPV. -PJSM. PICK UP LUBRICATOR AND TEST TO 250 / 4000 PSI, 5 MIN EACH / CHARTED. - PULL BPV, 0 PSI ON TUBING. L/D LUBRICATOR. 16:00 - 16:30 0.50 KILLW P DECOMP PRE CIRC OUT SAFETY MEETING. - EMPHASIZE GOOD COMMUNICATION TECHNIQUES. - EMPHASIZE GOOD FLUID MANAGEMENT. - TASK ASSIGNMENTS AND VALVE ALIGNMENT. Printed 1/14/2013 1:45:58PM . b m _ „ " • • • • Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:0O:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 21:30 5.00 KILLW P DECOMP LINE UP TO PUMP DOWN TUBING AND TAKE RETURNS UP VA, THRU CHOKE AND TO FLOW BACK TANK. BRING ON PUMP @ 2 BPM, PRESSURE SLOWLY INCREASING. - SHUT DOWN PUMP W/ 10 BBLS PUMPED, PRESSURE CLIMBED TO 2900 PSI. - ALLOW PRESSURE TO BLEED OFF AND BRING ON PUMP, SHUT DOWN AFTER PRESSURE SLOWLY CLIMBS TO 2900 PSI. FULL RETURNS TO FLOW B ACK TANK. - PUMP 59 BBLS WITH CONTINUED RESTRICTION HAVING TO STOP PUMPING AT 2900 PSI ONLY TO ACHIEVE 1.5 BPM BETWEEN CYCLES. - R/U AND REVERSE CIRCULATE 5.7 BBLS CLIMBING TO 2900 P51. - LET PRESSURE BLEED TO 0 PSI, LINE UP TO PUMP DOWN TBG. - PUMP 2 BPM 200 PSI, PUMP 200 BBLS TOTAL WITH NO RESTRICTIONS. - FCP AT 2 BPM= 300 PSI, WITH 11 PPG KWF AT RETURNS. - R/U TO TAKE RETURNS THROUGH 1" CSH SIDE STRING. - PUMP ANOTHER 5 BBLS AT .5 BPM UNTILL CLEAN 11 PPG KWF ACHEIVED. - FLOW CHECK TBG, VA AND SIDE STRING FOR 10 MIN. - ALL STATIC. WELL IS DEAD. 21:30 - 22:00 0.50 WHSUR P DECOMP BLOW DOWN KILL MANIFOLD AND LINES. - R/D KILL MANIFOLD. 22:00 - 00:00 2.00 WHSUR P DECOMP PJSM WITH DSM FOR SETTING AND PT TWC. - R/U AND TEST LUBRICATOR TO 250/4000 PSI 5 MIN EA. CHARTED. - SET TWC. - R/D LUBRICATOR. 9/29/2012 00:00 - 01:30 1.50 WHSUR P DECOMP CREW CHANGE. PJSM FOR TESTING TWC. - PRESSURE TEST FROM BELOW TWC TO 1000 PSI FOR 10 MIN. - PRESSURE TEST ABOVE TWC TO 250/4000 PSI 5 MIN EA. - CHART RECORD TESTS. 01:30 - 03:00 1.50 WHSUR P DECOMP PJSM FOR N/D TREE AND N/U BOPE. -- BARRIERS IN PLACE, 11 PPG KWF, TESTED TWC AND COMBINATION TBG X 1/A MIT. - FMC BLEED PRESSURE OFF TREE VOID AND FUNCTION LDS. - MONITOR VA WHILE N/D TREE. STATIC. - N/D TREE AND ADAPTOR FLANGE. - VERIFY AND INSTALL 1" CSH SIDE STRING BOX X PIN BLANK AND TIGHTEN. - VERIFY LENGTH WILL NOT COMPROMISE LOWER RAM. - FMC VERIFY AND INSPECT HANGER THREADS. 3 1/2" 8RD THREADS, 8.5 TURNS. - WITH 1" CSH BLANK IN PLACE, USE CONTINUOUS FILL DOWN VA WITH BYPASS LINE AND CHARGE PUMP. - FILL ACCROSS TOP WITH 11 PPG KWF, MONITOR RETURNS IN ISOLATED PIT. Printed 1/14/2013 1:45:58PM 4 47., Z4. 7",",,44--.5,447,f4 ? "-;}9 /4% 41 , 4(17 *;.;' /4V "..407/354r- 04* !! f:V ;R:;g4° 40t40 X44; 0 - 444,"/4441,4 6. 4 70 4 1 40 14444 14 T4 '44 4 14 7 414 / "4 Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:0O:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 07:30 4.50 BOPSUR P DECOMP N/U 11" X 135/8" ADAPTOR SPOOL AND 4 PREVENTER BOP. - INSTALL 3 1/2" X 6" VBR IN UPPER BOP. - FUNCTION ALL RAMS, OK. - USE CONTIUOUS HOLE FILL ACCROSS TOP WITH 11 PPG KWF. - MONITOR RETURNS. O /A= 560 PSI. 07:30 - 15:00 7.50 BOPSUR P DECOMP ' I UP T• TEST BOPE - TEST BOPE AS PER AOGCC AND BP REQUIREMENTS. - AOGCC LOU GRIMALDI WAIVED WITNESSING ON THE 22ND. (L - STATE WAS GIVEN 24 HOUR NOTICE AND A (2) HOUR NOTICE. �� PRESSURE TEST ANNULAR PREVENTOR W/ 1 2 7/8" & 4" TEST JT, 250 / 3500 PSI. PRESSURE TEST UPPER 3 1/2" X 6" PIPE RAMS W/ 2 7/8" & 4" TEST JT, BLEEDING PRESSURE OFF MANIFOLD SO AS TO EFFECTIVELY TEST MPLS, 250 / 4000 PSI, 5 MIN EACH. - LOWER PIPE RAMS AND BLIND SHEARS TESTED 250 / 4000 PSI. 5 MIN EACH. - PRESSURE BLED OFF OF MANIFOLD TO EFFECTIVELY TEST MPLS ON LOWER PIPE RAMS AND BLIND SHEAR RAMS, OK. - ALL OTHER VALVES TESTED @ 250 / 4000 PSI, 5 MIN EACH. - ALL TESTS CHARTED AND WITNESSED BY DOYON TOOL PUSHER & WSL. - DRAWDOWN TEST ON ACCUMULATOR. - (1) FAILURE, ANNULAR PREVENTOR HAD TO BE CYCLED (1) TIME TO GET A TEST. 15:00 - 16:00 1.00 BOPSUR P DECOMP BLOW DOWN AND RIG DOWN TEST EQUIPMENT. - VACUUM FLUID OUT OF STACK, CHANGE RISER. 16:00 - 18:30 2.50 BOPSUR P DECOMP PJSM. PICK UP AND INSTALL DUTCH RISER. - RUN IN LOCK DOWN SCREWS. - M/U LUBRICATOR. - PRESSURE TEST LUBRICATOR TO 250/4000 PSI 5 MIN EA. - CHART RECORD TESTS. - PULL TWC. FLOWCHECK WELL, STATIC. - R/D LUBRICATOR AND DUTCH RISER. - VACUUM FLUID OUT OF STACK 18:30 - 19:00 0.50 BOPSUR P DECOMP PJSM. FOR PULLING 1" CS HYDRIL SIDE STRING - R/U BAKER HANDLING EQUIPMENT. - VERIFY ALL EQUIPMENT IS DRESSED FOR THE APPROPRIATE SIZE TBG 19:00 - 21:00 2.00 BOPSUR P DECOMP P/U 1 1/4" CSH LANDING JOINT WITH 1" CSH X /O. - M/U LANDING JT IN SIDE STRING. - P/U AND UNSEAT 1" CSH SIDE STRING FROM TBG HANGER WITH NO OVER PULL. - P/U 18', 15K OVER PULL AT 18' - ATTEMPT TO WORK BACK DOWN. NO GO. Printed 1/14/2013 1:45:58PM North America - ALASKA BP: % Operation Summary Repo' Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 BOPSUR N DPRB 526.0 DECOMP NOTIFY ODE AND RWO FIELD SUPERINTENDANT. - CLEARANCE AT SSV AT 526' X 7" 29# CSG= 1.384" - O/D 1" CSH AT TOOL JT= 1.552" - W/O ORDERS FROM TOWN BEFORE CONTINUING. LOCATING DUAL STRING HANDLING TOOLS. - BARRIERS IN PLACE 11 PPG KWF, COMBINATION MIT VAX TBG. - MONITOR WELL, STATIC. - O /A= 600 PSI. 9/30/2012 00:00 - 06:30 6.50 BOPSUR N DPRB 526.0 DECOMP - W/O ORDERS FROM TOWN BEFORE CONTINUING. - BARRIERS IN PLACE 11 PPG KWF, COMBINATION MIT VAX TBG. - MONITOR WELL, STATIC. 06:30 - 07:30 1.00 BOPSUR N DPRB 526.0 DECOMP PJSM. DISCUSS OPTIONS W/ SUPERINTENDANT AND ODE. - BLEED O/A TO 420 PSI, (GAS). SHUT IN WHEN LIQUID RETURNS. 07:30 - 08:30 1.00 BOPSUR N DPRB 526.0 DECOMP PJSM. ATTEMPT TO PUSH 1" CS HYDRIL DOWN HOLE. - UNSUCCESSFUL. DISCUSS NEXT OPTION. 08:30 - 12:00 3.50 BOPSUR N DPRB 526.0 DECOMP PJSM. MAKE UP LANDING JT. - SCREW INTO TUBING HANGER. BOLDS. - PULL HANGER FREE, UP WT 107K, (40K TOP DRIVE). - 2 7/8" TUBING IS FREE, GOOD CUT. - 1" HYDRIL TRAVELS UP AND DOWN W/ 2 7/8" TUBING. - WORK UP AND DOWN (4') A FEW TIMES. - 1" HYDRIL CAME FREE WHILE PICKINGS,JP ON 2 7/8" TUBING. - RELAND, RILDS. - WELL BORE STATIC THROUGHOUT, 0 BBLS LOST OR GAINED. 12:00 - 17:00 5.00 BOPSUR N WAIT DECOMP PJSM. UD LANDING JT. LEAVE 1" CS HYDRIL JT MADE UP. - WAIT ON HANDLING EQUIPMENT FOR PULLING DUAL STRING. - UPDATED ODE, SUPERINTENDANT AND WTL ON CURRENT OPS. - CONDUCTED WEEKLY SAFETY MEETING. - HIGH LIGHTED EYE PROTECTION, DRIVING SAFETY AND TOTAL COMPLIANCE WITH REGARD TO SAFE BEHAVIOR AND CONTROL OF WORK. Printed 1/14/2013 1:45:58PM 8; $ t AteVf,:*),NikiVAVEAfiMfit14 ;14446 Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:0O:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 00:00 7.00 BOPSUR N WAIT DECOMP WAIT ON HANDLING EQUIPMENT FOR PULLING DUAL STRING. - CLEAN AND PERFORM RIG MAINTENANCE. - LOAD SOME DUAL STRING EQUIPMENT ONTO RIG FLOOR. - CONTINUE W/O ELEVATORS AND 1" INSERTS. MONITOR WELLBORE, REMAINS STATIC. - O /A= 500 PSI. CONDUCT WEEKLY SAFETY MEETING WITH ONCOMING CREW. - REVIEW RECENT INCIDENTS WITH CREW. - HEIGHTEN AWARNESS OF EYE INJURY PREVENTION. - EMPHASIZE PROPER PPE AND DECONTAMINATION PROCEDURES . - RECENT DRIVING INCIDENTS IN THE FIELD. - FATIGUE AND DRIVING HAZARDS. 10/1/2012 00:00 - 17:00 17.00 BOPSUR N WAIT DECOMP WAIT ON HANDLING EQUIPMENT FOR PULLING DUAL STRING. - CLEAN AND PERFORM RIG MAINTENANCE. - CONTINUE W/O DUAL STRING ELEVATORS AND 1" INSERTS. MONITOR WELLBORE, REMAINS STATIC. - O /A= 540 PSI. - PJSM. BLEED O/A TO 200 PSI, (GAS) - OBSERVE DIESEL RETURNS & SHUT IN O /A. 17:00 - 00:00 7.00 BOPSUR N WAIT DECOMP WAIT ON HANDLING EQUIPMENT FOR PULLING DUAL STRING. - CLEAN AND PERFORM RIG MAINTENANCE. - CONTINUE W/O DUAL STRING ELEVATORS AND 1" INSERTS. - MONITOR WELLBORE, REMAINS STATIC. - O /A= 440 PSI. 10/2/2012 00:00 - 12:00 12.00 BOPSUR N WAIT DECOMP WAIT ON HANDLING EQUIPMENT FOR PULLING DUAL STRING. - CLEAN AND PERFORM RIG MAINTENANCE. - CONTINUE W/O DUAL STRING ELEVATORS AND 1" INSERTS. - MONITOR WELLBORE, REMAINS STATIC. - BLED DOWN O/A FROM 460 PSI TO 310 PSI, (GAS). - BLED UNTIL DIESEL RETURNS & SHUT IN. - LOSSES TO WELL, 0 BBLS, NO GAINS, WELL STABLE. 12:00 - 15:00 3.00 BOPSUR N WAIT DECOMP CONTINUE TO WAIT ON PLAN FORWARD FROM TOWN. - EQUIPMENT TO PULL DUAL STRING COMPI FTION EN ROI ITF - MAINTAIN, CLEAN AND PAINT ON RIG. - PJSM. BACK OUT 1 1/4" CS HYDRIL LANDING JT & CROSS OVER. - BLANKING SUB STILL MADE UP TO TOP OF 1" CS HYDRIL IN HANGER. 15:00 - 16:00 1.00 BOPSUR N WAIT DECOMP PJSM. DRY ROD / SET TWO WAY CHECK IN TUBING HANGER. Printed 1/14/2013 1:45:58PM �/ r / i4 _ f .✓ .ems r Fr r - PdePt 7 ,41:i?i ; ?;t 4 4:SIVIA t ?:r/bIr f r ' Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 19:00 3.00 BOPSUR N WAIT DECOMP RIG UP TO TEST TWO WAY CHECK. - TEST FROM THE BOTTOM @ 250 / 1000 PSI / 5 MIN / CHARTED. - TEST FROM THE TOP, 250 / 4000 PSI / 5 MIN / CHARTED. 19:00 - 22:30 3.50 BOPSUR N WAIT DECOMP PJSM, R/U TO TEST BOP - PERFORM DRAW DOWN TEST ON ACCUMULATOR - ATTEMPT MPL TEST ON 2 7/8 LOWER PIPE RAMS, FAILED - ATTEMPT TO TROUBLESHOOT 22:30 - 00:00 1.50 BOPSUR N WAIT DECOMP PJSM, OPEN BOP DOORS BOP STACK - INSPECT 2 7/8 RAMS AND SEALING ELEMENTS - RAMS ARE IN GOOD CONDITION - CLOSE RAM DOORS AND TIGHTEN SAME 10/3/2012 00:00 - 08:30 8.50 BOPSUR N WAIT DECOMP PJSM, TEST BOP PER AOGCC REGULATIONS AND DOYON TEST PROCEDURE - FOLLOW CURRENT DOYON MPL TEST PROCEDURE % - TEST ALL BOP AND CHOKE MANIFOLD `// VALVES TO 250 PSI LOW, 4000 PSI HIGH, 5 MINUTES, CHARTED - TEST ANNULAR USING 2 7/8" TEST JOINT TO 250 LOW, 3500 PSI HIGH - TEST 31/2" X 6" VBR PIPE RAMS USING 4" TEST JOINT - TEST 2 7/8" SOLID RAMS WITH 2 7/8" TEST JT - TEST BOTH SETS OF 2 7/8" AND 4" FLOOR VALVES - TEST USING FRESH WATER - JEFF JONES OF AOGCC WAIVED STATES RIGHT TO WITNESS THE BOP TEST, 10/02/12 @ 0900 HRS - ANNULAR PREVENTER FAILED, ELEMENT WILL BE REPLACED AND RE- TESTED - OA PRESSURE = 450 PSI AT 01:00 HRS 08:30 - 12:00 3.50 BOPSUR N WAIT DECOMP PJSM. RIG DOWN TEST EQUIPMENT. - DRAIN STACK. - PJSM. FUNCTION T3 ANNULAR PREVENTOR. - INCREASE CLOSING PRESSURE TO 3000 PSI IN STAGES. - ANNULAR CLOSED TO ABOUT A 1 1/2" OPENING. - ELEMENT LOOKS GOOD, WITH VERY LITTLE WEAR. - ORDER OUT REPLACEMENT ELEMENT AND OTHER COMPELTE ANNULAR PREVENTOR. Printed 1/14/2013 1:45:58PM o s Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:0O:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 17:00 5.00 BOPSUR N WAIT DECOMP CONTINUE TO WAIT ON APPROVAL TO PROCEED. - RIG UP GBR EQUIPMENT AND INSPECT FOR DEFICIENCIES. - ALL LOOKS GOOD. - WAITING ON REPLACEMENT ANNULAR PREVENTOR, REPLACEMENT ELEMENT, DOYON TOOLPUSHER, SUPERINTENDANT AND HYDRIL REP TO OVER SEE THE ANNULAR PREVENTOR OPERATION. - OA PRESSURE = 520 PSI AT 12:30 HRS 17:00 - 20:00 3.00 BOPSUR N RREP DECOMP PJSM, PREP FOR WORK ON ANNULAR PREVENTOR. - HOOK UP ACCUMULATOR HOSES TO GK HYDRIL FOR TEST PURPOSES - REMOVE FLOW NIPPLE ON BOP STACK TO PREP FOR REPLACEMENT - WAIT ON DOYON SUPERINTENDENT 20:00 - 22:00 2.00 BOPSUR N RREP DECOMP FUNCTION TEST GK HYDRIL ON MAT BOARD IN CELLAR BEFORE INSTALLATION - CLOSE ANNULAR ELEMENT WITH 750 PSI, OPEN BAG - WORK ELEMENT OPEN AND CLOSE WHILE INCREASING PRESSURE TO 2500 PSI - CLOSE BAG AROUND 3/4" PIPE WITH 2500 PSI, WILL HOLD PIPE AND WATER - DECIDE TO CHANGE OUT ANNULAR ASSY TO "GK" STYLE HYDRIL 22:00 - 00:00 2.00 BOPSUR N RREP DECOMP PJSM ON N/D BOP YOKE AND T3 ANNULAR PREVENTOR - N/D AND REMOVE BOP YOKE 10/4/2012 00:00 - 06:30 6.50 BOPSUR N RREP DECOMP PJSM, CHANGE OUT ANNULAR PREVENTOR - REMOVE AND LOWER "T3" ANNULAR PREVENTOR TO CELLAR FLOOR - CLEAN AND PREP FLANGE AND BOLTS - HOIST GK HYDRIL TO TOP OF BOP STACK AND MAKE UP FLANGE - OA PRESSURE = 580 PSI 06:30 - 10:00 3.50 BOPSUR N RREP DECOMP PJSM. INSTALL YOKE FOR ANNULAR PREVENTOR. - INSTALL FLOW NIPPLE, HOOK UP ACCUMULATOR HOSES. - NIPPLE UP RISER. 10:00 - 12:00 2.00 BOPSUR P DECOMP RIG UP TO TEST ANNULAR PREVENTOR. - CONDUCT INITIAL TEST ON BREAKS, OK. - TEST ANNULAR PREVENTOR W/ 2 7/8" TEST JT. - TEST @ 250 / 3500 PSI / CHARTED/ GOOD TEST. 12:00 - 13:00 1.00 BOPSUR P DECOMP PJSM. RIG DOWN TEST EQUIPMENT. - UD TEST JT, BLOW DOWN LINES. - OA PRESSURE = 610 PSI Printed 1/14/2013 1:45:58PM North America - ALASKA BP r Operation Summary Repo, Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time. 7/14/1989 12:00:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 16:30 3.50 BOPSUR P DECOMP PICK UP AND INSTALL DUTCH RISER. RILDS. - PICK UP LUBRICATOR, TEST @ 250 / 4000 PSI / 5 MIN EACH. - ATTEMPT TO PULL TWO WAY CHECK VALVE. - GALLED THREADS ON RETRIEVING TOOL, ONLY (1) SPARE. -- CONSULT ODE AND GO HAVE A DISCUSSION WITH MILNE PT SUPERVISORS. - DECISION MADE TO USE THE OFF SET LUBRICATOR TO AVOID RUINING THE OTHER PULLING TOOL THREADS. 16:30 - 00:00 7.50 BOPSUR P DECOMP R/D DUTCH RISER. PICK UP OFF SET LUBRICATOR. UNABLE To LOCATE BORED ID CROSSOVER FOR LUBRICATOR - SENT PUP JOINT/ CROSSOVER TO BAKER MACHINE - BORE ID TO ENABLE TWC TO PASS THROUGH PUP AND LUBRICATOR - PERFORM RIG WORK ORDERS AND MAINTENANCE 10/5/2012 00:00 - 02:30 2.50 WHSUR P _ DECOMP PJSM, PULL TWC M/U MACHINED CROSSOVER TO OFF -SET LUBRICATOR AND SCREW INTO HANGER - R/U WELL SUPPORT LUBRICATOR - TEST TO 250 PSI LOW, 4000 PSI HIGH, 5 MIN, CHARTED - PULL TWC - R/D WELL SUPPORT AND OFF -SET LUBRICATOR - CLEAR RIG FLOOR - OA PRESSURE = 640 PSI 02:30 - 06:00 3.50 WHSUR P DECOMP PJSM, PULL HANGER AND RIG UP GBR EQUIPMENT - M/U LANDING JOINT TO HANGER - WSL AND FMC REP VERIFY NO PRESSURE ON IA - BACK OUT LOCK DOWN SCREWS AND PULL HANGER TO RIG FLOOR, PUWT = 95K - R/U GBR DUAL STRING SLIPS, ELEVATORS, POWER TONGS - R/U SCHLUMBERGER TOOLS - L/D HANGER 06:00 - 06:30 0.50 PULL P DECOMP PRE JOB SAFETY MEETING ON PULLING DUAL COMPLETION. - EMPHASIS ON VERBAL COMMUNICATION BEFORE ALL ACTIONS. - STEPS ON WELL CONTROL REVIEWED. TABLE TOP DRILL AND WALK THRU COMPLETED. CONTROL LINE TO BE CUT WHILE PULLING EACH JTAND LAYING DOWN 30' SEGMENTS. INDIVIDUAL TASKS ASSIGNED. EMPHASIS ON GOING SLOW AND NOT MAKING ANY MIS STEPS. - CONFIRM COLLAR CLAMP OD IS LESS THAN 135/8 ". Printed 1/14/2013 1:45:58PM - ;• a ..; i s a. . ; a • 3 yk g33 or Y '-.� • • Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:0O:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 14:30 8.00 PULL P DECOMP MAKE FINAL ADJUSTMENTS ON GBR AND RIG EQUIPMENT. - OPT TO USE RIG TONGS TO BREAK OUT 2 7/8" TUBING. - LAY DOWN 2 7/8" TBG AND 1" TBG, (5 JTS EACH AND PUP JTS). 14:30 - 15:30 1.00 PULL P DECOMP HAVE CREW COMING ON GO DIRECTILY TO RIG FLOOR. - CREW COMING ON WATCHES AND LEARNS FROM CREW ON TOUR. - PRE JOB WITH CREW COMING ON AND REVIEW AND DO TABLE TOP WELL CONTROL DRILL. ENSURE ALL HANDS HAVE FULL UNDERSTANDING OF SHUT IN PROCEDURE WITH DUAL STRINGS IN THE HOLE. WALK THRU SHUT IN STEPS. 15:30 - 17:00 1.50 PULL P DECOMP POOH W/ REMAINING (4) JTS OF 1" AND 2 7/8" AND CONTOL LINE. - UD SSSV, ALL CLAMPS RECOVERED, NO FLUID LOST OR GAINED. 17:00 - 18:00 1.00 PULL P DECOMP RIG DOWN GBR TONGS - R/D GBR POWER UNIT - CLEAR RIG FLOOR OF POWER TONGS AND CASING EQUIPMENT 18:00 - 22:30 4.50 PULL P DECOMP PJSM, RIG UP 1" ELEVATORS ■ - POOH AND UD 1" CSH TUBING AND MULE SHOE 22:30 - 23:00 0.50 PULL P DECOMP R/D GBR DUAL SPIDER / SLIP ASSY - CLEAR RIG FLOOR OF ALL GBR EQUIPMENT - R/U 2 7/8" SLIPS AND YC ELEVATORS - INSTALL SAFETY VALVE IN PIPE 23:00 - 00:00 1.00 PULL N WAIT DECOMP RECEIVED CALL FROM WTL JIM WILLINGHAM - DUE TO STUCK PIPE PROBLEMS ON DOYON 14 - WE ARE INSTRUCTED TO STAND DOWN UNTIL FURTHER NOTICE 10/6/2012 00:00 - 06:00 6.00 PULL N WAIT DECOMP PJSM, CONTINUE TO STAND BY - RECEIVED CALL FROM WTL JIM WILLINGHAM - DUE TO STUCK PIPE PROBLEMS ON DOYON 14 - WE ARE INSTRUCTED TO STAND DOWN UNTIL FURTHER NOTICE - OA PRESSURE = 650 PSI - PERFORM WORK ORDERS AND RIG MAINTENANCE Printed 1/14/2013 1:45:58PM A g o Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Release: 11/1/2012 Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:OO:OOPM Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 18:00 12.00 PULL N WAIT DECOMP SM, CONTINUE TO AY RECEIVED CALL FROM ST WTL ND B JIM M WILLINGHAM PJ :14\N DOYON ON DOWN UNTIL FURTHER NOTICE REVIEW DRIVING GUIDELINES WITH RIG PER - OA PRESSURE = 650 PSI - PERFORM WORK ORDERS AND RIG MAINTENANCE 18:00 - 00:00 6.00 PULL N WAIT DECOMP i CONTINUE TO STAND BY PERFORM WORK ORDERS AND RIG MAINTENANCE PAINTING WIND WALLS - CLEANING AND PAINTING MECHANIC SHOP REMOVE FRONT SPRADER BEAM 10/7/2012 00:00 - 10:30 10.50 PULL N WAIT DECOMP PJSM, CONTINUE TO STAND BY - RECEIVED ORDER FROM WTL JIM WILLINGHAM DUE TO STUCK PIPE PROBLEMS ON DOYON 14 WE ARE RK INSTRUCTED TO ORDERS STAND DOWN UNTIL FURTHER NOTICE - UN PERFORM WO AND G MAINTENANCE PAINTING WIND WALLS - CLEANING AND PAINTING MECHANIC SHOP - OA PRESSURE = 650 PS 10:30 - 11:00 0.50 PULL P DECOMP APPROVAL GIVEN BY WTL JAMES WILLINGHAM TO PROCEED. APPROVAL GIVEN TO PULL 2 7/8" TUBING AND RUN USIT LOG, - FTG DOWN PAINTING PROJECT AND MAKE READY TO PULL TUBING. 11:00 - 12:00 1.00 PULL P DECOMP PJSM. POOH AND L/D 2 7/8" CS HYDRIL TUBING. - H 9544' - '. , 68K DRIVE, DOWN WT. - ALL WEIGHT F/ CHECK INCLUDE 77K UP WT TOP (40K). POO 112 LOST OR GANG LA 12:00 - 18:00 6.00 PULL P DECOMP PJSM W/ CREW COMING INED ON TOUR. DURI ST CONTINUE O 2 7/8" CS HYDRIL TUBING FROM 9034 TO H W/ 600' WELL CONTROL TO DRILL HELD W/ POOH. - FLOOR VALVE STABBED, SIMULATED CLOSING ANNULAR PREVENTOR. - HANDS AT STATION, GOOD AAR. Printed 1/14/2013 1:45:58PM 4 # 3 Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:0O:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 ©52.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ate o o as Co p p p (hr) (ft) 18:00 - 22:00 4.00 PULL N RREP DECOMP AT 21:00, A JOINT OF PIPE SLID OFF OF PIPE SKATE RAMP - JOINT WAS RETRIEVED WITH TUGGER AND PLACED BACK ON SKATE RAMP - THERE WERE NO INJURIES OR DAMAGE TO EQUIPMENT - PROPER NOTIFICATIONS WERE MADE AAR WAS HELD WITH WSL, TOUR PUSHER, DOYON SUPERINTENDANT, AND DOYON HSE FIELD REP - SEE TRACTION REPORT # IR- 4252018 22:00 - 23:30 1.50 PULL P DECOMP POOH FROM 600' TO SURFACE - TOTAL JOINTS LAYED DOWN = 338 - CUT JOINT = 11.58 - 3 1/16" OD FLARE ON CUT 23:30 - 00:00 0.50 PULL P DECOMP RIG DOWN HANDLING EQUIPMENT AND POWER TONGS - CLEAR CLEAN RIG FLOOR - NO FLUID LOST OR GAINED DURING LAST 24 HOURS. 10/8/2012 00:00 - 00:30 0.50 PULL P DECOMP PJSM, INCIDENT REVIEW AND RIG UP OF WIRE LINE - CLEAR RIG FLOOR - INSTALL WEAR BUSHING, 7" ID - OA PRESSURE = 660 PS 00:30 - 03:00 2.50 EVAL P DECOMP PJSM WITH SCHLUMBERGER - SPOT E -LINE UNIT - MOBILIZE SWS TOOLS TO RIG FLOOR - HANG WIRELINE SHEAVES AND R/U LINE WIPER 03:00 - 04:00 1.00 EVAL P -_ DECOMP MAKE UP E -LINE USIT BHA - PERFORM SURFACE TEST 04:00 - 12:00 8.00 EVAL P DECOMP RIH WITH USIT LOGGING TOOLS - LOG FROM 10020' TO SURFACE IN CEMENT / CORROSION MODE - O/A PRESSURE 660 PSI. 0 BBLS LOST OR GAINED TO WELL. 12:00 - 13:00 1.00 EVAL P DECOMP PJSM. RIG DOWN SCHLUMBERGER E LINE. 13:00 - 16:30 3.50 EVAL N WAIT DECOMP STAND BY, WAIT ON ORDERS. - @ 14:30 HRS, PERMISSION GIVEN TO PROCEED AHEAD. - CALLED HALLIBURTON FOR RBP - CALLED SCHLUMBERGER FOR RIVER SAND. - CALLED AOGCC AND GAVE 24 HR NOTICE FOR INTENT TO CONDUCT FULL BOPE TEST, (CHUCK SCHEVE OKAYED IT AND ASKED FORA HEADS UP). 16:30 - 20:00 3.50 CASING P DECOMP PJSM WITH HALLIBURTON REP - M/U HALLIBURTON RBP - RIH WITH 4 "DP1 X1 TO2100'MD - PUWT = 67K, SOWT = 70K Printed 1/14/2013 1:45:58PM „-,” / , ,,,,,,,,r %/1:1 r , „„r„ ,,,,,, .,„,,,.. „,, ;,,,, „,;,,, ,,,,, „, / ,./, „, ,„, ,,,,,,„„ ,,,,„„..,:„.„..„,,, „,..„7„,,,, ,, „,„,,,,,,,„„):,,, ,,,, ,,,,,..„ , r ,04, ,.../0 --,,,,,,,,..„-,„ 7,..., i i • J ., ,,,,,,,,,, 47 ., Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:OO:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 ©52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT (ft) Depth Phase Description of Operations (hr) 20:00 - 22:30 2.50 CASING P DECOMP SET RBP ' MD WH DOW N O WEIGHT ...._��IT" - ATTEMPT AT TO TEST 2100 RBP TO 250 15K PSI LW, AND 4000 PSI HIGH - UNA TO H SE A , ON CALCULATED STROKES �� - CHECK BLE AND TROUBLESHOOT PRES SURFACE URTEST EQUIPMENT, ALL REACH GOOD HIG - UNSEAT RBP, MOVE UP 10 FEET AND SET AT 2090' MD - TEST RBP TO 250 PSI LOW, 4000 PSI HIGH, 5 MINUTES, CHARTED, GOOD HOLE TEST IP F L = ' MD RILL RBP RBP TOP CENTER OF TOOL = 2086EMENT ' MD 22:30 00:00 1.50 CASING P DECOMP OOH FROM2090' TO 1990' R/U AND DUMP O 20 E / 40 SAND DOWN M D D R AND ON TOP OF RBP NO FLUID LOST OR GAINED DURING LAST 24 HOURS. 10/9/2012 00:00 - 02:00 2.00 CASING P DECOMP M, P AND SPCC T AT CHECKS CONTINUE ERFORM TO DUMP SAND EQUIPMENT ON RBP, SE 1990 MD - 0/A PRESSURE 670 PSI. -0 BB1-01 S LOST OR GAINED TO AP TO WEL 02:00 - 06:00 4.00 CASING P DECOMP PJSM, PREWO PPG T 9.8 PPG PARE BRINE S - CLEAR PIPE TO ENSURE SAND FLUID IS CLEAR M 11.0 FROM IPE i T RANSFER 380 BBLS 11.0 PPG BRINE FROM PITS TO UPRIGHT STORAGE FILL PITS WITH 9.8 PPG BRINE SWAP FLUID IN WELL TO 9.8 PPG BRINE - FLOW CHECK 10 MINUTES, NO FLOW -- TAG TOP OF SAND AT 2036' MD 06:00 - 07:00 1.00 CASING P DECOMP POOH FROM 2036' TO SURFACE - L/D RBP RUNNING TOOL 07:00 - 07:30 0.50 CASING P DECOMP PULL WEAR RING, INSTALL TEST PLUG - SUCK OUT BOP 07:30 - 10:30 3.00 CASING P DECOMP PJSM, CHANGE OUT RAMS - REMOVE 3 1/2" X 6" RAMS, INSTALL 7" RAMS U RAM BODY REMOVE PPER 2 719" RAM B ODY I N �O - INSPECT RAMS AND S FROM LOWER RAM DOORS v - INSTALL NEW PACK OFF RUBBER AND SEALS ON 3 1/2" X 6" RAM BLOCKS - INSTALL 3 1/2" X 6" RAMS IN LOWER RAM BODY - U A DOORS -AT 8: 00HS RM -OA M/ =700 SI BLEED OFF OA PRESSURE UNTIL RETURNS SEEN, OA = 470 PSI Printed 1/14/2013 1:45:58PM t Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 ©52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 12:00 1.50 BOPSUR P DECOMP R/U TEST EQUIPMENT FOR WEEKLY BOPE TEST - PERFORM ACCUMULATOR TEST -OA =535 PSI 12:00 - 16:30 4.50 BOPSUR P DECOMP PJSM, BOPE TEST - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 4" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST UPPER 7" RAMS WITH 7" TEST JOINT, 250 PSI, 4000 PSI, 5 MIN, CHARTED - TEST LOWER RAMS WITH 4" TEST JOINT, 250 PSI, 4000 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, CHOKE MANIFOLD TO 250 PSI, 4000 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - CHUCK SCHEVE OF AOGCC WAIVED STATES RIGHT TO WITNESS TEST 16:30 - 17:00 0.50 BOPSUR P DECOMP R/D TEST EQUIPMENT BLOW DOWN ALL LINES, CLEAR RIG FLOOR - PULL TEST PLUG AND INSTALL 7" ID WEAR RING 17:00 - 00:00 7.00 CASING N WAIT DECOMP WAIT ON ORDERS TO PROCEED - PAINT WIND WALLS, RIG MAINTAINENCE - CLEAN AND PAINT TRUCK SHOP - WELL IS STATIC 10/10/2012 00:00 - 12:00 12.00 CASING N WAIT DECOMP PJSM, WAIT ON ORDERS TO PROCEED - PAINT WIND WALLS, RIG MAINTAINENCE - CLEAN AND PAINT TRUCK SHOP - CLEAN AND PAINT CATTLE CHUTE - CALIBRATE GAS DETECTORS - OA = 520 PSI AT 07:00 HRS 12:00 - 00:00 12.00 CASING N WAIT DECOMP PJSM, WAIT ON ORDERS TO PROCEED - CLEAN AND PAINT CATTLE CHUTE - INSTALL FRONT ROLL -UP DOORS IN WHEEL WELL - INSTALL STEERING ARM - OA = 520 PSI AT 12:00 HRS - WELL IS STATIC 10/11/2012 00:00 - 12:00 12.00 CASING N WAIT DECOMP PJSM, WAIT ON ORDERS TO PROCEED - FINISH PAINTING CATTLE CHUTE - OA = 530 PSI AT 00:30 HRS - AT 6:30, BLEED OFF OA UNTIL GETTING RETURNS -OA =340 PSIAT6:30 Printed 1/14/2013 1:45:58PM ' a ' ;.? !mac' - r < >. // Ids° o / p // 7. Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 18:30 6.50 CASING N WAIT DECOMP PJSM, RECIEVE PLAN FORWARD FOR RETURN TO OPERATIONS - PLAN IS TO RDMO MPE PAD AND MOVE TO MPL PAD C PAINTING AND OTHER LEAN RIG OPERATIONS - REMOVE FISHING TOOLS FROM PIPE SHED AND RIG FLOOR REMOVE 7" PATCH BHA P - REMOVE ALL DRILL PIPE FR PIPE E SHED SHED - LOAD 63 JOINTS OF 2 7/8" EUE 8RD TUBING IN PIPE SHED FOR KILL STRING - BEGIN RIH WITH DRILL PIPE FROM DERRICK (TO LAY DOWN 1X1) - OA = 260 PSI AT 12:00 HRS - 17:30, BLEED OFF OA UNTIL GETTING RETURNS - OA= 190 PSI AT18:OOHRS 18:30 - 00:00 5.50 CASING N WAIT DECOMP TALK TO TOWN ENGINEER AND DISCUSS RBP IN HOLE - DECO R OPERATIONS - WAITI DE DOE ORDERS STOP TO DMO PROCEED RESUME RIG REPAIR AND MAINTAINENCE INSTALL FRONT SPREADER BEAM 10/12/2012 00:00 - 06:00 6.00 CASING N WAIT DECOMP PJSM, WAIT ON ORDERS TO PROCEED - PERFORM RIG MAINTAINENCE WORK ORDERS - OA = 250 PSI AT 00:30 HRS 06:00 - 11:00 5.00 CASING N WAIT DECOMP PJSM, WRON - PERFORM AIT RIG ON Om AINTENANCE DERS T WORK ORDERS - MEETING AT MILNE POINT TO REVIEW L2RA FOR RIG TO MOVE FROM MPE -PAD TO MPL -PAD. - 11:00 HRS RECEIVED PERMISSION TO PROCEED WITH MPE -03 RWO, FROM RWO & CTD WTL. 11:00 - 21:00 10.00 CASING P DECOMP PJSM, R" TBG OM PIPE SHED. - PJSM, LOAD EMOVE AND 2 -7/8 STRAP 274 FR JTS, 4" DP INTO PIPE SHED. - MOBILIZE HEATED BRINE AND VAC - TRUCKS FOR ARCTIC PACK CIRC OUT. MOBILIZE BAKER FISHING TOOLS FROM BAKER SHOP. 21:00 - 22:00 1.00 CASING N HMAN DECOMP 8 GED FROM BLEEDING LINE AL DOSPILL WN R IN TO SULTE CUTTING BOX. ALL TN MILNE NOTIFICA POINT ENVIRO IOMADE. TECH SUPERVISED CLEAN UP. AAR HELD: WILL UPDATE SOP TO INCLUDE LINE UP AND STEPS TO BLEED TO TANK. 22:00 - 00:00 2.00 CASING P DECOMP PJSM, R/U MANIFO FROM A TH TH LD CHOKE THE O TO THE ROUGH ARCTIC E PACK KILL TANK. - CLEAR WITH AIR, STEAM, FILL LINES. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 ©52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/13/2012 00:00 - 01:30 1.50 CASING P DECOMP PJSM - TEST LINES TO ARCTIC PACK TANK - 250 PSI / 3000 PSI FOR 5 CHARTED MIN. GOOD 01:30 - 02:00 0.50 CASING P DECOMP PJSM WITH LRS AND VAC TRUCK FOR CoW. 02:00 - 04:30 2.50 CASING P DECOMP PSJM, M/U 7" CSG CUTTER AND RIH FROM DERRICK - P/U WT. = 65K INCLUDING 40K BLOCK / TOP DRIVE WT. - SO WT. = 68K. - LOCATE CSG COLLARS. - UPPER CSG COLLAR @ 1842' MD. - LOWER CSG COLLAR @ 1880' MD. P/U AND MAKE CUT AT 1853' MD - 80 RPM WITH 2K FREE TORQUE. - PUMPING AT 4.5 BPM WITH 850 PSI. - CONFIRM CUT WITH — 20 PSI INCREASE ON OA. - 200 PSI DROP AT THE CUT. 04:30 - 05:00 0.50 CASING P DECOMP MONITOR WELL AFTER 7" CSG CUT. - BLOW DOWN TOP DRIVE AND ASSOCIATED EQUIPMENT. - RIG UP CIRCULATING HEAD. 05:00 - 06:00 1.00 CASING P DECOMP LRS PUMPED 20 BBLS DOWN DP. SHUT DOWN LRS PUMP. - CLOSE ANNULAR AND LINE UP ON REMOTE CHOKE. - LRS PUMPED 50 BBLS DIESEL @ 2 BPM / 500 PSI. 06:00 - 07:30 1.50 CASING P DECOMP SHUT WELL IN AND LET FLUIDS SOAK. 07:30 - 09:30 2.00 CASING P DECOMP PJSM, ON SWITCHING OVER FROM LRS TO RIG PUMP. - WSL VERIFIED ALL VALVE ALIGNMENT. - ALL PUMPING WAS DOWN THE DP OUT THE OA THROUGH THE KILL CHOKE TO ARCTIC PACK TANK. - — 75 PSI ON DOWN STREAM CHOKE GAUGE. - LRS PUMPED 25 BBLS DIESEL @ 2 BPM / 300 PSI. - RIG PUMPED 20 BBLS KWF W/ VISCOUS SPILL 4 -5 BPM / 360 PSI. - RIG PUMPED 20 BBL SWEEP( KWF AND SAFE SURF -O) USING RIG PUMP. 4 -5 BPH / 360 PSI. - RIG PUMPED 290 BBL 'DEEP CLEAN' SWEEP WITH 120 DEGREE 9.8 PPG KWF. - PUMP @ 5 BPM / 410 PSI. - ONLY THIN ARCTIC PACK, NO BALLS NOTED IN RETURNS. - KWF 9.8 PPG BRINE. 09:30 - 10:30 1.00 CASING P DECOMP DRILLER AND WSL VERIFIED NO TRAPPED PRESSURE. - MONITOR WELL FOR 30 MINUTES. - WSL VERIFIED THE WELL IS STATIC. - OPEN ANNULAR AND B/D LINES. - SOME DIESEL STILL MIGRATING IN WELL BORE, NO GAIN / NO LOSSES. Printed 1/14/2013 1:45:58PM o a . Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 11:30 1.00 CASING P DECOMP PJSM, POH WITH 7" CSG CUTTER ASSEMBLY F/ 1853' MD - L/D CUTTER ASSEMBLY. - W/ CONTINUOUS HOLE FILL. - 0.50 BBL LOSS ON TRIP OUT. 11:30 - 12:00 0.50 CASING P DECOMP CLEAN AND CLEAR RIG FLOOR - BLOW DOWN ALL CIRCULATING LINES AGAIN. 12:00 - 14:30 2.50 CASING P DECOMP CREW CHANGE, PJSM. MONITOR WELL WITH PUMPS OFF. - CIRC ACROSS TOP OF HOLE WITH HOLE FILL PUMP. - DECIDE TO MONITOR WELL MORE ACCURATELY WITH LOW PRESSURE GAUGES. - PREP TBG SPOOL FOR REMOVAL. - B/D HARD LINE TO ARCTIC PACK TANK TO ENSURE CLEAR OF FLUIDS. 14:30 - 15:30 1.00 CASING P DECOMP SHUT OFF HOLE FILL. CLOSE BLINDS. INSTALL LOW PSI GAUGE ON VA. - MONITOR PRESSURE EVERY 15 MIN. - PRESSURE ON VA =10 PSI AT SHUT IN. 15 MIN. = 8 PSI GAIN. 30 MIN. =4 PSI GAIN - 45 MIN. = 8 PSI GAIN - 60 MIN. = 6 PSI GAIN. -I /A AT36 PSI -O /A AT 150 PSI AFTER 60 MIN. - WSL DISCUSSED OPTIONS WITH RWO TOWN TEAM. 15:30 - 16:30 1.00 CASING N DPRB DECOMP LINE UP AND PUMP A BTM'S UP WITH 9.8 PPG KWF. - TAKE RETURNS TO ARCTIC PAK TANK. - PUMPED 50 BBLS @ 7 BPM / 550 PSI. - RETURNS FROM BTM'S UP WERE SEVERELY FOAMED UP DUE TO "DEEP CLEEN SOAP" 16:30 - 17:30 1.00 CASING N DPRB DECOMP LINE UP TO TAKE RETURNS BACK TO PIT SYSTEM. - TREATED KWF IN PITS WITH DEFOAMER BEFORE PUMPING DOWN DP. - BEGIN TO PUMP 75 BBLS OF KWF @ 3 BPM / 150 PSI. - REDUCE PUMP RATE TO 1 BPM @ 40 PSI. 17:30 - 23:00 5.50 CASING N DPRB DECOMP CALL TOWN ENGINEER AND DISCUSS PLAN FORWARD -ORDER 290 BBLS OF CLEAN 9.8 PPG BRINE FROM MUD PLANT SHUT IN WELL AND MONITOR OA AND IA PRESSURES EVERY 15 MIN - BEGINING OA PRESSURE = 80 PSI - AFTER 5 HOURS OF MONITORING ENDING OA PRESSURE = 300 PSI - IA = 250 PSI Printed 1/14/2013 1:45:58PM •S 9 Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1 /2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 CASING N DPRB DECOMP PUMP 290 BBLS OF 9.8 PPG CLEAN BRINE TO WELL TAKING RETURNS THROUGH GAS BUSTER - PUMP DOWN THE IA (7" CASING) AT 5 BPM = 530 PSI - HOLD SLIGHT BACK PRESSURE THROUGH CHOKE ON "OA" -OA =340 PSI - NO FLUID LOSS TO HOLE IN LAST 24 HOURS 10/14/2012 00:00 - 00:30 0.50 CASING N DPRB DECOMP PJSM, CIRCULATE WELL - COMPLETE CIRCULATING 9.8 PPG CLEAN BRINE INTO WELL THRU GAS BUSTER - 5 BPM, IA = 530 PSI, OA = 340 PSI, WHILE PUMPING 00:30 - 03:00 2.50 CASING N DPRB DECOMP SHUT WELL IN AND RECORD PRESSURES - BEGINING IA PRESSURE = 0 PSI - BEGINING OA PRESSURE = 20 PSI - AFTER 2 HOURS OF MONITORING - IA PRESSURE = 140 PSI - OA PRESSURE = 140 PSI CALL TOWN ENGINEER AND DISCUSS PLAN FORWARD - MOBILIZE VAC TRUCK TO MPF PAD TO RETRIEVE USED 11.0 PPG BRINE FROM UPRIGHT TANK - WILL CHANGE OUT 9.8 PPG BRINE IN WELL TO 11.0 PPG 03:00 - 06:00 3.00 CASING N DPRB DECOMP CONTINUE TO CONSTANTLY MONITOR IA AND OA PRESSURES - RECORD PRESSURES EVERY 30 MINUTES - WAIT ON 11.0 PPG TO ARRIVE. WHP'S AT 05:00 HRS - IA = 250 PSI - OA = 280 PSI. 06:00 - 09:30 3.50 CASING N DPRB DECOMP 11.0 PPG BRINE ARRIVED ON LOCATION. - CONTINUE MONITORING VA AND 0/A PRESSURES. - 0730 HRS IA = 280 PSI OA = 305 PSI - OFFLOAD 9.8 PPG BRINE FROM PITS TO VAC TRUCK. - ONLOAD 11.0 PPG 60 DEGREE BRINE TO PITS TO PREP FOR DISPLACEMENT. TALKED TO BOB NOBLE ON PLANS TO INCREASE KWF TO 11.0 PPG AND DISCUSSED 24 HRS NOTICE OF WEEKLY BOPE TEST AT 06:50 HRS 10/14/12. Printed 1/14/2013 1:45:58PM North America ALA gwor Operation Summary Repojrt Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 12:00 2.50 CASING N DPRB DECOMP SHUT IN WELL PRESSURES ARE = I/A - 230 PSI. 0/A - 330 PSI. PJSM, BEFORE PUMPING, TOOLPUSHER AND WSL HELD TABLE TOP WELL KILL EXERCISE WITH CREW, ALL CREW MEMBERS RECEIVED INSTRUCTION ON HOW TO FILL OUT A KILL SHEET PROPERLY RECEIVED PLAN FORWARD FROM RWO TOWN TEAM. - LINE UP TO DISPLACE WELL WITH 11.0 PPG BRINE. - R/U LINES TO FLOWBACK TANK AND PIT TO 3000 PSI. - VERIFY FLOWBACK TANK LEVELS BEFORE DISPLACEMENT. - NO LOSSES TO THE WELL LAST 12 HRS. WEEKLY SAFETY MTG WITH DDI HSE REP, RIG SUPPORT CREW, AND RIG CREW. - DISCUSSED RECENT INCIDENTS ON THE - RIG,AND FIELD WIDE SAFETY BULLETINS. 12:00 - 12:30 0.50 CASING N DPRB DECOMP -CREW CHANGE, DISCUSSION ON RIG FLOOR. WSL DISCUSSED DISPLACEMENT WITH CREW COMING ON TOUR. - WSL / TOOLPUSHER VERIFY VALVE ALIGNMENT. - - PUMP 15 BBLS VISCOUS SPACER AT 3 BPM / 400 PSI - DISPLACE WELLFROM 9.8 PPG BRINE TO 11.0 PPG BRINE - . - ICP = 300 PSI - FCP = 50 PSI -- 11.0 PPG IN TILL 11.0 PPG OUT. CLOSELY MONITOR BRINE WT. IN. - PUMPED DOWN THE 7" CSG UP THE 7" X 9 -5/8" OA THROUGH THE CELLAR KILL SKID, - TO THE FLOWBACK TANK. - SHUT -IN PRESSURE = 0 12:30 - 15 :00 2.50 CASING N DPRB DECOMP PJSM, B/D ALL CELLAR LINES AND ASSOCIATED EQUIPMENT. - R/U TO CIRCULATE BACK TO PITS. - RETEST CEMENT LINE. - PUMP DOWN 7" CSG TAKING RETURNS THROUGH RIG CHOKE TO PITS. - CIRCULTED 127 BBLS, 11.0 PPG BRINE. - 3 BPM / 125 PSI - CLOSELY MONITOR BRINE WT. IN AND OUT. - RETURNS WERE VERY CLEAN 11.0 PPG BRINE. 15:00 - 15:30 0.50 CASING N DPRB DECOMP PJSM, BLOW DOWN ALL SURFACE LINES - FLOWBACK TANK LINES AND KILL SKID. Printed 1/14/2013 1:45:58PM i ® , '6"in/ d% Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 21:00 5.50 CASING N DPRB DECOMP MONITOR WELL HEAD PRESSURES - IA (7" CSG) - OA 7" X 9 -58" ANNULUS) - 15:00 HRS. - IA = 0 - OA = 0 - FROM 15:00 HRS TO 18:00 HRS, OA PRESSURE INCREASED FROM 0 PSI TO 240 PSI - FROM 18:00 HRS TO 21:00 HRS, OA PRESSURE STABILIZED AT 240 PSI - FROM 15:00 HRS TO 19:00 HRS, IA PRESSURE INCREASED FROM 0 PSI TO 240 PSI - FROM 19:00 HRS TO 21:00 HRS, OA PRESSURE STABILIZED AT 240 PSI - SEE ATTACHED GRAPH RELEASED BAKER HAND AT 18:00 HRS 21:00 - 23:30 2.50 CASING N DPRB DECOMP CALL TOWN ENGINEER AND DISCUSS PLAN FORWARD - R/U LINES FROM OA THRU KILL MANIFOLD CHOKE IN CELLAR TO ARCTIC PACK BLEED TANK - PRESSURE TEST LINES TO 3000 PSI, 5 MIN, CHARTED - OPEN OA TO BLEED TANK WITH CHOKE AT 1/4 OPEN - BEGINNING OA = 240 PSI - IMMEDIATELY AFTER OPENING OA, PRESSURE DROPPED TO "0" PSI - CONSTANTLY MONITORED BLEED TANK FOR 2 HOURS, STRAP EVERY 15 MINUTES - RETURNS WERE INTERMITTENT, NO STEADY FLOW, COULD HEAR PRESSURE BREAKING OUT OCCASIONALLY FROM DIFFUSER - TOTAL 2 HOUR GAIN IN BLEED TANK = 2 BBL OF BRINE IN 1ST HOUR, "0" BBLS IN 2ND HOUR - SHUT IN OA AND IA AT 23:30 HRS 23:30 - 00:00 0.50 CASING N DPRB DECOMP CALL TOWN ENGINEER AND RWO SUPERVISOR DISCUSS PLAN FORWARD BLOW DOWN AND R/D CELLAR LINES - R/U CELLAR LINES TO TAKE RETURNS THRU RIG CHOKE AND GAS BUSTER TO MONITOR RETURNS MORE ACCURATELY - 24 HOUR FLUID LOSS TO WELL = 0 BBLS Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/15/2012 00:00 - 06:00 6.00 CASING N DPRB DECOMP PJSM, WEEKLY SAFETY MTG WITH TOOLPUSHER AND RIG CREW. - DISCUSSED RECENT INCIDENTS ON THE RIG AND FIELD WIDE SAFETY BULLETINS - AT 00:30, OPEN OA THRU CHOKE AND GAS BUSTER TO PITS - CONSTANTLY MONITOR PIT VOLUME - OA WAS SHUT IN FOR 1 HOUR WHILE R/U LINES TO GAS BUSTER - OA PRESSURE BUILT TO 100 PSI DURING THIS TIME - OPENED OA THRU CHOKE (1/4 OPEN) TO PITS AND PRESSURE FELL TO "0" IMMEDIATELY - AT 03:30, OPEN CHOKE TO 1/2, NO RETURNS TO PITS - OPENED 1/4" INSTRUMENT (WHITEY) VALVE AT TOP OF CHOKE MANIFOLD TO CHECK EXHALE PRESSURE. NO FLUID RETURNS. MINOR CONTINUOUS EXHALING / VENTING DETECTED - AS OF 09:00, NO RETURNS TO PITS - DISCUSSED POSSIBLE TEST TIME WITH AOGCC INSPECTOR BOB NOBLE AT 06:05 HRS 10/15/12. 06:00 - 10:00 4.00 CASING N DPRB DECOMP PJSM, CIRCULATE SURFACE TO SURFACE +, W/ 11.0 PPG BRINE. - CIRCULATED 128 BBLS, 11.0 PPG BRINE, THROUGH THE GAS BUSTER. - 3 BPM / 200 PSI. 52 DEG. - RETURNS AT THE SHAKER AFTER 6.5 BBLS AWAY. - AT 53 BBLS AWAY, RECORDED -10 BBLS OF 9.8 PPG KWF. - MIX 14 SX SALT TO MAINTAIN KWF WT. - RECOVERED 3 GAL ARCTIC PACK BALLS AT THE SHAKER. - ALL RETURNS VERY CLEAR. - WSL VERIFIED NO GAS / DIESEL SMELL AT SHAKER, ONLY SOAP. LOST 3 BBLS TO WELL. Printed 1/14/2013 1:45:58PM i , # , ,/,,,, 0 „,,, ,,,,,, <1 „, . 4.,,,4;,6,77-:; em,,„,,,,,,,,,/;,,t;,,,:/:,,,,,441::!,;, ,/,;:gfo.';',:fo .V6,0111 ';''',4,,,,4,4,-/#'w*;-7,"/R,,/,f0#1707?",„,/,'1,-j:-//;:ifirli-fe,''''''' • • Common Well Name: MP -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 11!1/2012 X4- 0OVKF- E:DRILL (3,860,000.00 ) Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM End Date: Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Project: Milne Point Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs ) Task Code NPT NPT Depth Phase Description of Operations (hr (ft) 10:00 - 22:00 12.00 CASING N DPRB DECOMP MONITOR STA WELL AT THE SHAKERS RT TIME AT 10:00 HRS - KWF RETURN RATE Iso LESS THAN 1 BBL IN 24 HS ALL MOST STOPED AT 0S IA IS R SLIGHTLY Puy ENTING AIR 160 AT HR W . ELL HEAD, NO GAS DETECTED OA IS SLIGHTLY VENTING AIR AND A SMALL AM - OUNT OF LIQID, NO GAS DETECTED - CAN R RWO ENG W USSED ILL PERF PLAN FO WEEKLY WARD WITH BOPS TEST TO NIGHT. 12:20 HRS, AOGCC INSPECTOR BOB NOBLE REQUESTED, 2 HRS NOTICE, PRIOR TO TEST. PR CON: A T P ! EQUIPMENT AINPROJ FOR ROPE TEST, E PT PROJECTS COPLETE NU BOILER INSPECTION WITH COMBUSTABLE BOILER INSPECTOR HELD CONTINOUS IMPROVEMENT MEETING WITH RWO SUPERVISOR, WELLSITE LEADERS, DOYON TOOLPUSHERS, DOYON SUPERINTENDANT, DOYON HSE, AND SITE CONTROL SPECIALISTS 22:00 - 00:00 2.00 BOPSUR N DPRB DECOMP PJSM, R/U TO TEST BOP R/D PAINT PROJECTS - LINE UP IA AND OA VENT LINES ON ARCTIC PACK BLEED TANK STATION MAN AT TANK DURING BOP TEST TO MONITOR AND STRAP - RECORD ANY GAIN IN VOLUME - CA OF 0, 10/16/2012 00:00 01:00 1.00 HE WILL BE WITNESSING AOGCC THE BOP AT TEST BOPSUR N DPRB DECOMP PJSM, TEST BOP 'S - STATION MAN AT BLEED TANK DURING BO TEST TO MONITOR AND STRAP ANY GAIN IN VOLUME LL BOB BOB - IA AND RECORD OA OPEN, CHECK RAMS WELL FOR PRESSURE, OPEN BLIND - FILLED 7" CASING, 2 BBLS TO FILL OBSERVED IA AND OA U- TUBING FLUID AT WELL HEAD BEFORE TEST PLUG WAS INSTALLED SMALL STEADY STREAM RETUNING ARCTIC BLEED TANK FROM COMM UNIC ATED IA AND OA Ti PULL WEAR , INSTALL TEST G AND CHOKE MANIFOLD EST JOINT FILL STACK AND RING WITH FRESH WATER - R/U BOP TEST EQUIPMENT Printed 1/14!2013 1:45:58PM f d ,¢. r / /i L eo � 4 Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 ©52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 06:00 5.00 BOPSUR N DPRB DECOMP PJSM, BOPE TEST - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - FOLLOW CURRENT DOYON MPL TEST PROCEDURE - TEST ANNULAR WITH 4" TEST JOINT TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES EACH, CHARTED - TEST UPPER 7" RAMS WITH 7" TEST JOINT, 250 PSI, 4000 PSI, 5 MIN, CHARTED - TEST LOWER RAMS WITH 4" TEST JOINT, 250 PSI, 4000 PSI, 5 MIN, CHARTED - TEST BLIND RAMS, FLOOR VALVES, CHOKE MANIFOLD TO 250 PSI, 4000 PSI, 5 MIN, CHARTED - TEST WITH FRESH WATER - PERFORM ACCUMULATOR DRAW DOWN TEST - BOB NOBLE OF AOGCC WAS PRESENT TO WITNESS BOP TEST - IA AND OA CONTINUES TO VENT, NO FLUID .RETURNED TO BLEED TANK 06:00 - 12:00 6.00 CASING N DPRB DECOMP WAIT ON APPROVAL FROM RWO TOWN TEAM TO PROCEED. - WITH BLIND RAMS CLOSED, CONT. TO MONITOR WELL. - I/A AND 0/A LINED BACK UP TO ARCTIC PAK TANK VIA KILL MANIFOLD. - HAND STATIONED AT TANK TO MONITOR FOR FLUIDS FROM WELL. - WELL SUPPORT PERFORMED FLUID SHOT. - I/A LEVEL AT SURFACE- 0/A LEVEL CLOSE TO SURFACE. - NO FLUID RETURNS TO VA AND 0/A. - " 0 " LOSSES TO WELL LAST 12 HOURS. 12:00 - 13:00 1.00 CASING N DPRB DECOMP PJSM ON RIG FLOOR. - WSL, TOOL PUSHER, RIG CREW, AND FMC REP IN ATTENDANCE. - DISCUSSED PLAN FORWARD FOR 7" CSG SPOOL SWAP. 13:00 - 14:30 1.50 CASING N DPRB DECOMP WSL, TOOLPUSHER, DRILLER, AND FMC REP. VERIFIED VA AND 0/A PRESSURES. - 0/A 5 MINUTE SHUT IN = 20 PSI ON GAUGE. - I/A 5 MINUTE SHUT IN = 0 PSI ON GAUGE. - HOLD CONFERANCE CALL WITH RWO TOWN TEAM. 14:30 - 16:00 1.50 CASING N DPRB DECOMP PJSM WITH WSL, TOOLPUSHER, RIG CREW. - FILL HOLE WITH 11 PPG BRINE. - RE -RIG CIRCULATING LINES TO PUMP FULL CIRCULATION IN WELL WITH 11 PPG BRINE. - P/T ALL CIRCULATING LINES TO 250 / 3000 PSI. - WSL VERIFIED VALVE ALIGNMENT FOR TESTING LINES AND CIRCULATING WELL. - SHUT -IN IA = 60 PSI - SHUT -IN OA = 110 AT THE RIG FLOOR CHOKE. Printed 1/14/2013 1:45:58PM �� % " t 7 a a ' f,+% �i ; %' � �✓,frr � r / / , _ ,AA, Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:30 1.50 CASING N DPRB DECOMP CIRCULATE 11.0 PPG BRINE SURFACE TO SURFACE. - CIRCULATE 134 BBLS KWF, DOWN THE IA. OUT THE OA, THRU THE CELLAR KILL SKID, - THEN UP THE CEMENT LINE, THRU HALF OPEN CHOKE, THRU THE GAS BUSTER, - THEN TO THE SHAKER. 3 BPM/ 140 PSI PUMP PRESSURE. - 10 -'0' PSI ON CHOKE PANEL. - 11.0 PPG BRINE IN AND OUT. - PUMPS OFF @17:10 HRS. - IA WAS SHUT -IN - OA OPEN FULL CHOKE TO GAS BUSTER AND SHAKER. 17:30 - 00:00 6.50 CASING N DPRB DECOMP MONITOR SHUT -IN VA AND OPEN 0/A. - RECORD PRESSURES AT 30 MIN INTERVALS. - INITIAL PSI ON CLOSED VA AND OPEN 0/A AT 20 PSI. - WITH OPEN 0/A THRU CHOKE AND GAS BUSTER TO PITS. - CONSTANTLY MONITOR PIT VOLUME. - 0/A RETURN RATE REDUCED TO VERY SLIGHT TRICKLE. - AT 24:00 HRS- 2 BBLS BLED BACK TO PITS FROM 0/A. - I/A AT 3 PSI. 0/A AT 15 PSI. 10/17/2012 00:00 - 02:00 2.00 CASING N DPRB DECOMP MONITOR SHUT -IN VA AND OPEN O/A. - RECORD VA PSI AND O/A FLOW RATE AT 30 MIN INTERVALS. - WITH OPEN 0/A THRU CHOKE AND GAS BUSTER TO PITS. - CONSTANTLY MONITOR PIT VOLUME. - AT 02:00 CLOSED VA AT 3 PSI. OPEN 0/A AT 17 PSI. - 0/A RETURN RATE CONTINUES WITH VERY SLIGHT TRICKLE. - 0/A BLEED BACK VOLUME TOTAL AT 2.1 BBLS 11 PPG BRINE. 02:00 - 13:30 11.50 CASING N DPRB DECOMP MONITOR SHUT -IN VA AND OPEN O/A. - RECORD VA PSI AND 0/A FLOW RATE AT 30 MIN INTERVALS. - WITH OPEN 0/A THRU CHOKE AND GAS BUSTER TO PITS. - CONSTANTLY MONITOR PIT VOLUME. - 04:30 HRS: SHUT -IN IA = —4 PSI -OPEN OA= 15 PSI - 5 MINUTE SHUT -IN: OA = 15- 23- 25 -28 -30 PSI -AND THE IA BUILT TO -8 PSI. - 05:00 HRS:SHUT -IA IS ON A VACUUM. - AND THE OPEN OA = 11 PSI. - VERY SMALL DRIP - DRIP -DRIP FOR RETURNS. Printed 1/14/2013 1:45:58PM %�,� Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 13:45 0.25 CASING N DPRB DECOMP REDIRECT RETURNS FROM RIG FLOOR CHOKE TO SHAKER, - TO CELLAR KILL SKID CHOKE TO FLOW BACK TANK. - IA REMAINS SHUT -IN ON A VACUUM. - OA OPEN = —4 PSI - NO FLUID RETURNS. TOTAL RETURNS IN 21 HR PERIOD = 3 BBLS 11 PPG BRINE. 13:45 - 16:00 2.25 CASING N DPRB DECOMP DHD REP ARRIVE ON LOCATION - RECIEVED RIG ORIENTATION FROM SCS. - SCS ESCORTED DHD REP TO CELLAR. - DHD REP CONDUCTED GAS LEAK QUANTIFICATION TEST FROM OA. - CONDUCT 1 HOUR CRYSTAL METER TEST. - RESULTS OF TEST- OA =79 PSI IA =27 PSI. - REACHED 100 PSI ON OA IN 1.25 HRS. - DHD REP COLLECTED PORTABLE GAS SAMPLE FROM OA. - ALL TEST WITH THE IA SHUT -IN. 16:00 - 18:00 2.00 CASING N DPRB DECOMP OPEN O/A TO FLOW BACK TANK. - CONTINUOUSLY MONITOR SHUT -IN VA AND OPEN 0/A. 18:00 - 00:00 6.00 CASING N DPRB DECOMP WITH O/A OPEN TO FLOW BACK TANK. - WAIT ON GAS LEAK QUANTIFICATION TEST RESULTS FROM 0/A SAMPLE. - CONTINUOUSLY MONITOR SHUT -IN VA AND OPEN 0/A. - 18:00 HRS 4 PSI ON 0/A. I/A ON SLIGHT VAC. - NO RETURNS NOTED ON 0/A. - 24:00 HRS 4 PSI ON 0/A. I/A CONTINUES ON SLIGHT VAC. 10/18/2012 00:00 - 10:30 10.50 CASING N DPRB DECOMP WITH 0/A OPEN TO FLOW BACK TANK. - WAIT ON GAS LEAK QUANTIFICATION TEST RESULTS FROM 0/A SAMPLE. - CONTINUOUSLY MONITOR SHUT -IN VA AND OPEN 0/A. - NO RETURNS NOTED ON 0/A. - 05:00 HRS 4 PSI ON 0/A. I/A CONTINUES ON SLIGHT VAC. 10:30 - 17:30 7.00 WHSUR P DECOMP RECEIVE PERMITTING TO RESUME RWO OPERATIONS FROM TOWN. - NOTIFY FMC AND BAKER REP. - ORDER TRUCKS FOR ARCTIC PACK CIRC -OUT. PJSM ON N/D BOPE. - BLOW DOWN ALL LINES AND N/D BOPE. - REMOVE HARD LINE FROM IA VALVE. - LOAD GEN 5 DRILLING SPOOL INTO CELLAR. - BARRIERS IN PLACE, CMT PLUG @ 10520', COMBINATION TBG X VA MIT TEST PERFOMEDAND 11 PPG KWF. - ND TBG SPOOL. Printed 1/14/2013 1:45:58PM ® % ®/ b V • Common Well Name: MP— AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M P E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:OO:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 • : 03 7/14/1989 00:00 @52.Oft (above Mean Sea Level) Date From - To H rs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 19:30 2.00 WHSUR P DECOMP NU 11" GEN 5 DRILLING SPOOL. INSTALL OUTER VA VA • LVE - INSTALL MOUSE HOLE, RISER AND BOP ANCHORS. 19:30 20:00 0.5 WHSUR P UM DECOMP TEST J PJSM, M/U AND INSTALL TEST PLUG AND 4" T. H FRESH FILL STACK WIT WATER. RAJ TEST PP. 6" LOW TES A GAINST 3.5" X ER RAMS TO 250/3500 PSI 5 MIN EA. CHART RECORD TEST. 20:00 21:00 1.00 WHSUR P MBLY. IG OMP D TEST P RAIN STACK - VAC OU TEST FLUID. PULL TELUG, UD 4" TEST JT. 21:00 - 21:30 0.50 WHSUR FLOOR. ER. ONTROL. P DECOM PJSM WITH EMC REP, BOT RE WSL, TOOL DEC PUSHER AND CREW. FOR M/U SPEAR ASSE FOR PULLING 7" UPPER CUT JT TO R F - REMOVING HANG REVIEW PLAN FO WELL C 21:30 22:00 0.50 CASING P DECOMP M/U X /O, FOSV AND HEAD PIN. CLOSE BLIND SHEAR RAM. - M/U SPEAR ASSEMBLY PER BO REP BULL NOSE, PACKOFF ASSY, SPEAR ASSY, S PE AR EX T, STOP SUB, XO, XO= 15.28• OPEN BLIND SHEAR RAM. 22:00 23:00 1.00 FISH P DECOMP RII-126 .5' ENGA(�INC TOP nF 7" ( A gyp( TL H SPEAR. TAG 7" CSG WITH STOP SUB. IIII M/U TOP DRIVE. - FMC BOLDS. 23:00 - 00:00 1.00 FISH P DECOMP PULL 7" CSG, BROKE FREE AT 110K INCLUDING 40K TO DRIVE WT. CLOSE 0/A VALVE. PULL 7 " CSG SLIPS TO RIG FLOOR. 85K PM WT INCLUDING 40K TOP DRIVE WT. - SET SLIPS, M/U DOG COLLAR. - FM REMOVE 7" EMERGENCY CSG SLIPS. - PULL AND up CUT JT 7" CSG AND SPEAR ASSEMBLY. FLOW CHECK WELL- STATIC. # L 80 CSG. 10/19/2012 00:00 01:00 1.00 CASING P DECOMP PJSM FOR CBU AND UD 7" 2 M/U X0, FO AND HEAD PIN. SPOT VAC TRUCKS. 01:00 - 02:00 1.00 CASING P DECOMP CBU FRO 1817' PUMPING 11 PPG BRINE AT 8 BPM 880 PSI. RECIP 7" CSG 60' PUMP 47 BBLS TOTAL WITH RETURNS ACCROSS SHAKERS. - CHECK FLUI RET URNS AT 11 PPG. NO ARCTIC PACK SEEN AT SHAKERS. - R/D CIRC EQUIPMENT. 02:00 04:00 2.00 CASING P DECOMP R/U 7" HANDLING EQUIPMENT. POH AND LID 7" 29# L -80 CSG. - UPPER CUT JT= 37.62' - 46 FULL JTS 7" CSG - LOWER CUT JT 11.32' - 20 CENTRALIZERS RECOVERED ON CSG. AVERAGE BREAKOUT TORQUE= 14K Printed 1/14/2013 1:45:58PM f Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 04:30 0.50 CASING P DECOMP PJSM. P/U AND REMOVE SPEAR FROM UPPER CUT JT. - L/D SAME. - MONITOR WELL. 04:30 - 05:30 1.00 BOPSUR P DECOMP PJSM. M/U 4" TEST JT AND LOWER TEST PLUG. - TEST LOWER TBG SPOOL FLANGE TO 250/4000 PSI 5 MIN EA. - CHART RECORD TESTS. - INSTALL 9" ID. WEAR RING. 05:30 - 12:00 6.50 CASING P DECOMP PJSM, ON P/U DRESS OFF BHA WITH WSL, BOT REP, AND RIG CREW. - M/U BHA TO RIH AND DRESS 7" CSG STUB. - ATTEMPTED TO RIH WITH PORTED FLOAT, FLOWING OUT DRILL COLLARS. - POH, PULL PORTED FLOAT. - RECIEVE APPROVAL FROM RWO FIELD SUPERINTENDANT TO RUN SOLID FLOAT. - INSTALL SOLID FLOAT. - RIH, CBU AFTER DRILL COLLARS IN HOLE. 12:00 - 12:30 0.50 CASING P DECOMP CONTINUE T/ RIH WITH 7" DRESS OFF ASSEMBLY F/ 1165' MD TO 1829' MD. - OBTAIN PARAMETERS WITH PUMPS ON @ 3 BPM AND 100 PSI. - P/U WT. = 70K INCLUDING 40K BLK/TOP DRIVE WT. - ROT. WT. = 72K @ 50 RPM WITH 3K TQ. 12:30 - 13:00 0.50 CASING P DECOMP - DUE TO THE 8.50" O.D. OF DRESS OFF SHOE INSIDE OF 8.681" 9 -5/8" CSG STRING. - TOO MUCH FLOWBACK INSIDE DRILL STRING TO RIH. - RECEIVED APPROVAL FROM RWO TOWN TEAM TO USE SOLID FLOAT. - INSTALLED SOLID FLOAT. RIH WITH DRESS OFF BHA PER BOT REP. - FILL EACH JOINT. - CBU AFTER THE BHA AND FIRST STAND OF DP WAS RIH. - FILL 4" DP EVERY STD WHILE RIH. CBU EVERY 5 STDS. - REPEAT FOR FIRST 18 STDS OF DP. - PUMP RATE = 6.5 BPM / 250 PSI WHILE CIRCULATING. - RIH WITH 7" DRESS OFF ASSEMBLY T/ 1165' MD. - LOSSES TO WELL LAST 12 HRS = 3 BBLS. 11 PPG BRINE. - WITH PUMPS OFF NO CHANGE TO BUBBLE MIGATION AT SURFACE. 13:00 - 13:30 0.50 CASING P DECOMP TAG 7" CSG STUB @ 1853' MD. ER STUB 2 TURNS. - STOP ROTATION AND SLIDE DN. T/ TAG WITH INNER DRESS OFF MILL @ 1853 MD. - SLOW PUMP RATE T/ 3 PBM @ 100 PSI AND DRESS OFF 7" CSG STUB. - DRESS 7" CSG STUB —4" WITH 5K WOB / 50 RPM WITH 2 -5K TQ. - WITH PUMPS OFF P/U OFF STUMP. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 14:30 1.00 CASING P DECOMP HI-VIS SWEEP. - PUMPED 40 BBL DEEP CLEAN HI-VIS SWEEP AND CBU WITH 11.0 PPG BRINE F/ PITS. - PUMP RATE = 7 BPM @ 430 PSI. - NO GAINS OR LOSSES. - WITH PUMPS OFF NO CHANGE TO BUBBLE MIGRATION AT SURFACE. 14:30 - 19:30 5.00 CASING P DECOMP WAIT ON REDESIGN OF 7" CSG PATCH ASSEMBLY. - CIRCULATE 2 BPM @ 50 PSI. - CLOSELY MONITOR FOR GAIN / LOSSES TO WELL. 19:30 - 21:00 1.50 CASING P DECOMP PJSM, POH WITH 7" DRESSOFF ASSEMBLY FROM 1853'. - CIRCULATE DRILL PIPE VOLUME EVERY 5 STANDS WHILE TOH. - PUMPING 4 BPM AT 140 PSI. 21:00 - 23:00 2.00 CASING P DECOMP L/D 7" DRESS OFF BHA. - RECOVER /2 GALLON FINE METAL FROM BOOT BASKET. - CLEAR AND CLEAN RIG FLOOR. - LOAD OUT DRESS OFF TOOLS. 23:00 - 23:30 0.50. CASING P DECOMP . R/U AND PULL 9" ID WEAR RING. 23:30 - 00:00 0.50 CASING P DECOMP PJSM, R/U 7" CASING EQUIPMENT. - R/U DDI 7" CASING HANDLING EQUIPMENT. 10/20/2012 00:00 - 02:00 2.00 CASING P DECOMP PJSM. R/U TORQUE TURN EQUIPMENT. - R/U 7" CASING EQUIPMENT. 02:00 - 02:30 0.50 CASING P DECOMP PJSM FOR RUNNING 7" CASING. - IN ATTENDANCE, BOT REP, HES REP, DDI CASING, WSL, TOOL PUSHER AND CREW. - REVIEW RUNNING TALLEY AND WELL PLAN STEPS. - DISCUSS TORQUES AND CASING FILL. - REVIEW WELL CONTROL PLAN FOR NON SHEARABLES ACROSS BOP. 02:30 - 07:00 4.50 CASING P DECOMP P/U AND RIH WITH 7" CSG PATCH PER WSL — TALLEY AND PROGRAM. - M/U 7" BAKER CASING PATCH, FLOAT COLLAR ASSY, ECP INFLATABLE PACKER, HES ES CEMENTER W/ 6 PINS, BTC X VAM TOP XO PER HES AND BOT REPS. - BAKER LOCK 1ST JT BETWEEN PATCH AND ES CEMENTER. - P/U AND RIH WITH 43 JTS 7" 26# L -80 VAM TOP CSG. - M/U TO OPT TORQUE SPECS 11950 FPS. - FILL EVERY JT WITH 11 PPG BRINE. - USE JET LUBE SEAL GUARD PIPE DOPE. - AT 0500 HRS 30 JTS IN. - CONT. RIH WITH 7" TIE BACK STRING T/ 1841' MD. AND OBTAIN PARAMETERS. - PU WT. = 80K INCLUDING 40K BLK / TOP DRIVE WT. - SO WT. = 82K - ROT WT = 83K. - POSITION OVERSHOT –2 FT ABOVE THE STUMP AT 1853" MD. - WITH PUMPS OFF. 07:00 - 07:30 0.50 CASING P DECOMP PJSM WITH HES FOR M/U CEMENT HEAD. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4 OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 08:00 0.50 CASING P DECOMP - MU TOP DRIVE AND ROTATE OVER 7" CSG STUB @ 10 RPM. - SLIDE DN T/ 1853' MD. SET DN 25,000# T/ ENGAGE GRAPPLES. - PULL TEST T/ 30,000# AND WORK TO 150,000# OVER STRING / BLK WT. - SO 100,000# OVER STRING / BLK WT. AND SET SLIPS. = 180,000# 08:00 - 09:30 1.50 CASING P DECOMP PJSM, BRING SLB CMT HEAD AND ASSOCIATED EQUIPMENT T/ RIG FLOOR. - R/U XO, CMT HEAD AND HOSES. - WSL VERIFIED CEMENT PLUG LOADING. - P/T HARD LINE TO FLOWBACK TANK T/ 2500 PSI AND CHART RECORD 5 MIN. 09:30 - 10:30 1.00 CASING P DECOMP SCS SPOT CEMENTER AND VAC TRUCKS VEHICLES. - IMPLEMENTED CoW PRACTICES. PJSM, P/T 7" CSG T/ 1000 BY STAGING UP IN INCREMENTS OF 200 PSI. - CHART RECORD TEST 5 MIN. - SET BOT ECP PER BOT REP. - OPEN ECP INFLATION CONTROL VALVE W/ 1730 PSI. - TEST 7" CSG TO 2000 PSI AND CHART RECORD 10 MIN. PASSED - BLEED OFF ALL PRESSURE. - ESTABLISH CIRCULATION. 10:30 - 12:00 1.50 CASING P DECOMP CIRCULATE 3 BPM @ 130 PSI WHILE FINISH R/U SLB CEMENT EQUIPMENT. - WILL BEGIN CEMENT JOB AFTER CREW CHANGE. 12:00 - 13:30 1.50 CASING P DECOMP PJSM ON 7" CSG PATCH CEMENT JOB. - RWO SUPERINTENDENT, WSL, TOOLPUSHER, RIG CREW, SCS, CH2 TRUCK DRIVERS SLB REPS, HES REPS IN ATTENDANCE. TOTAL HEAD COUNT ON LOCATION = 24 - DISCUSSED GOOD COMMUNICATION BETWEEN DRILLER AND SLB LEAD. - STAYING CLEAR OF HIGH PRESSURE LINES AND HOSES. - ASSIGNED INDIVIDUAL TASKS TO AVOID CONFUSION. - COVERED ALL THIRD PARTY ROLES AND RESPONSIBILITIES. - SCS RESTRICTED ACCESS T/ NON - ESSENTIAL PERSONNEL. 13:30 - 14:00 0.50 CASING P DECOMP CONTINUE T/ CIRC @ 3 BPM / 150 PSI. - CEMENTERS AFFECTED BY NEGATIVE TEMPS @— 10 BELOW - CALLED WELL SUPPORT FOR TIOGA HEATER T/ WARM EQUIPMENT. 14:00 - 15:00 1.00 CASING P DECOMP PJSM, PRESSURE TEST 7" INSIDE CSG T/ 3000 PSI T/ SHEAR OPEN "ES" CEMENTER. - PRESSURE TEST ALL CEMENT EQUIPMENT AND HARD LINES. 250 / 4000 PSI. - WSL VERIFIED SLB POP OFF SET @ 5000 PSI. - SLB VERIFIED BLEND WITH UCA FIELD TEST. - START BATCH MIX @ 14:40 HRS. Printed 1/14/2013 1:45:58PM r. Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 18:00 3.00 CASING P DECOMP CEMENT 7" CSG PATCH PER WELL PLAN. - PUMPED 5 BBLS 80 DEG H2O - 69 BBLS 15.8 PPG SURFACE TAIL @ 70 BHCT - 15:25 HRS OBSERVED PLUG RELEASED. - 5 BPM / 530 PSI 4 BPM / 730 PSI -(11 1 1 1 1 7 11 11 3 BPM / 930 PSI / r U - AFTER 25 BBLS DISPLACED OPEN OA T/ V FLOW BACK TANK. CLOSE ANNULAR. PUMP STROKES INDICATED CEMENT RETURNS ARRIVING AT CALCULATED DICPLACEMENT VOLUME TO FLOW BACK TANK. - BUMP PLUG ON STROKES @ 2400 PSI.( 761 STKS) - FLOAT EQUIPMENT HELD. CIP @1549HRS. - MONITOR 7" CSG FOR FLOW 10 MIN. NO FLOW. - FLUSH LINES AND WELL HEAD TO OPEN TOP TANK AT 5 BPM AT 160 PSI. - R/D SLB EQUIPMENT AND CMT HEAD. - SEE ATTACHED REPORTS AND TEST CHARTS. 18:00 - 21:00 3.00 CASING P DECOMP PJSM FOR N/D SPOOL AND INSTALLING EMERGENCY SLIPS AND PACKOFF. - WITH 2 TESTED BARRIERS, CMT PLUG AND RPB. - UNBOLT AND P/U SPACER SPOOL. - PER FMC REP INSTALL 7" EMERGENCY SLIPS AND PACKOFF. - SLACKOFF 100K OVERPULL ON 7" CSG ONTO SLIPS. - RILDS, R/U AND WACHS CUT 7" CSG. - L/D 20' 7" PUP AND 12.20' 7" CUT JT. 21:00 00:00 3.00 CASING P DECOMP N/D DRILLING SPOOL AND INSTALL NEW TBG SPOOL. - FMC REP TEST 7" VOID TO 4300 PSI FOR 30 MIN. 10/21/2012 00:00 - 00:30 0.50 CASING P DECOMP PJSM, CONTINUE TESTING 7" CSG VOID TO 4300 PSI FOR 30 MIN. - TEST VOID PER FMC REP. 00:30 - 01:00 0.50 BOPSUB P DECOMP R/D HOSES AND LO TORQUE VALVES ON 0/A. 01:00 03:30 2.50 BOPSUB P DECOMP PJSM. N/U BOP. - REMOVE 7" RAMS FROM UPPER BOP. - INSTALL 2 7/8" X 5" VBR IN UPPER BOP. - OPEN LOWER RAM DOOR AND INSPECT 3 1/2" X 6" VBR AND RAM CAVITY. - CLEAN OUT TRACES OF CMT. Printed 1/14/2013 1:45:58PM '/ / ". ��la.� l 0',.44)t7''',/ °` / � i % , , ,,, Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of ations (hr) (ft) 03:30 05:00 1.50 BOPSUB P DECOMP PJSM. M/U 3 1/2" TEST J Operations T AND TEST PLUG. WITH VA OPEN. MONITOR VA. - TEST UPPER 2 7/8" X 5 PSI " VBREA. , LOWER 3 1/2" X 6" VBR TO 250/4000 Ti T E ANNULAR 250/3500 PSI 5 MIN EA /U 4" TEST NNUL JT TEST UPPER 2 7/8" X 5" VBR CHART RECORD AL - 250 /4000 PSI MIN TO EA. . L TESTS. - CLOSE VA. - R/D TEST EQUIPMENT. 05:00 05:30 0.50 BOPSUR P DECOMP INSTALL WEAR RING 7" ID. - PREP FLOOR FOR RIH WITH MILL ASSEMBLY. 05:30 - 07:00 1.50 CLEAN P DECOMP PJSM, M/U 6" DRILL OUT BHA AND RIH T/ 1837' MD. - OBTAIN PARAMETERS. - PUWT.= 68K- SOWT. =70K -ROT. WT= 70K - FREE TQ = 3K - PUMP 6BPM@ 580 PSI. 07:00 - 12:00 5.00 CLEAN P DECOMP WASH DOWN WITH 6" MILL ASSEMBLY - ROTATE @ 80 RPM. - PUMPS @ 5 BPM / 480 PSI. 2 -5K WOB AND 2 -3.5 K DRILLING TQ. - CEMENT CONSISTENCY IS MEDIUM TO HARD. -MILL F/ 1807' T/ 1837' MD. = B SPR SPR = 4 3 BPM PM @@N 350 160 PS I. TIE IN CREW OTIFIED @ 08:00 HRS. LOSSES TO WELL LAST 12 HRS = 0 BBLS. 12:00 12:30 0.50 CLEAN P DECOMP PJSM, DISCUSSED POSSIBLE TRAPPED GAS UNDER FLOAT COLLAR. ( ONTINUE TO MILL THRU CEMENT. - ROTATE @ 80 RPM. - PUMPS @ 5 BPM / 480 PSI. 2 5K WOB AND 2 -3.5 K DRILLING TQ. - CEMENT CONSISTENCY IS MEDIUM TO HARD. - MILL HARD CEMENT F/ 1837' T/ 1847' MD. 12:30 - 14:30 2.00 CLEAN P DECOMP CIRCULATE HI-VIS SWEEP SURFACE TO SURFACE. - 6 BPM / 540 PSI - 11.0# BRINE - BITS OF RUBBER AND CEMENT AT SHAKER. CON'T DRILL OUT CEMENT F/ 1847' TO 1849' - DRILL OUT FLOAT COLLAR F/ 1849' TO 1850' - 2 -5 K WOB 14:30 - 15:00 0.50 CLEAN P DECOMP CBU 6 BPM @ 630 PSI. (MON'T WELL) - 10 MINUTE FLOW CHECK WITH PUMPS OFF AFTER DRILLING THE FLOAT COLLAR. - NO GAINS NO LOSSES. 15:00 16:30 1.50 CLEAN P DECOMP CONTINUE TIH W/ 19 STD. - TAG TOP OF SAND 6' IN ON BOTTOM SINGLE OF STD 20 @ 2028' - ROT AND DRY DRILL ON SAND F/ 2028' TO 2030' - 60 RPM, WOB 5 -K, 10 MIN. - P/U CIRC. B/U 5.5 BPM @ 560 PSI. - FLOWCHECK WELL, STATIC Printed 1/14/2013 1:45:58PM � s Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ft 16:30 - 17:30 1.00 CLEAN P DECOMP TOH WITH 20 STANDS 4" D/P 17:30 - 18:30 1.00 CLEAN P DECOMP L/D BHA # 4. CLEAN JUNK BASKET. - CLEAR FLOOR. - RECOVERED 1/2 GAL METAL AND SOME BRASS. - INSPECT 6" BLADED JUNK MILL. - IN GAUGE. 10% WEAR ON TIPS OF MILL TEETH. 18:30 - 19:00 0.50 CLEAN P DECOMP M/U REVERSE BASKET BHA # 5 PER BOT REP. - 6" JET BSKT, DOUBLE PIN SUB, 4- 4 3/4" BOOT BASKETS, - 7" CSG SCRAPER, BIT SUB, 4 3/4" JAR, XO. 19:00 - 20:30 1.50 CLEAN P DECOMP RIH WITH BHA # 5 TO 2020', 21 STDS 4" DP. - P/U WT= 70K. S/O WT= 70K. - P/U SINGLE, TAG TOP OF SAND AT 2036' - M/U TOP DRIVE. 20:30 - 21:30 1.00 CLEAN P DECOMP BREAK CIRCULATION. CIRC 5 BPM AT 450 PSI. - SHUT DOWN PUMP, B/O SINGLE. - DROP 7/8" STEEL BALL. - ESTABLISH CIRC RATE 6.5 BPM 1900 PSI. - RPM= 30, FREE TORQUE 2 -3K. - WASH SAND DOWN TO 2046' - PUH TO 2030', CBU PUMPING 6.5 BPM 1450 PSI. - L/D SINGLE. BLOW DOWN TOP DRIVE. - FLOWCHECK WELL, STATIC. 21:30 - 22:00 0.50 CLEAN P DECOMP POH FROM 2046' WITH REVERSE CIRC JUNK BASKET. 22:00 - 22:30 0.50 CLEAN P DECOMP PJSM. L/D BHA # 5. - CLEAN OUT REV BASKET AND 4 BOOT BASKETS. - INSPECT BHA. - RECOVERED FLOAT VALVE PIECE, 6 PIECES FLOAT MATERIAL, SOME ALUM. 22:30 - 23:30 1.00 CLEAN P DECOMP M/U SAME REV CIRC BASKET ASSY, BHA # 6 PER BOT REP. 23:30 - 00:00 0.50 CLEAN P DECOMP RIH WITH BHA # 6. 10/22/2012 00:00 - 00:30 0.50 CLEAN P DECOMP RIH WITH 6" REV CIRC JUNK BASKET ASSY. TO 2035' - TAG SAND AT 2046' - P /U, CIR 6.5 BPM 1480 PSI. - S/O WT= 70K, P/U WT= 67K. 30 RPM 2K FREE TORQUE. - WASH DOWN IN 2' INCREMENTS TO 2056' - FLOWCHECK WELL. STATIC. 00:30 - 02:00 1.50 CLEAN P DECOMP POH F/ 2056' - CLEAN BOOT BASKETS AND RCJB. - RECOVER SEVERAL PIECES FROM RCJB. - SOME CEMENT, LITTLE PIECES OF METAL FROM BOOT BSKT. 02:00 - 03:00 1.00 CLEAN P DECOMP RIH TO 2032'. - P/U WT= 67K. S/O WT= 70K. - TAG SAND @ 2048' - P /U, CIRC 7.5 BPM 1750 PSI. - 30 RPM AT 2K FREE TORQUE. - WASH DOWN TO 2068'. FLOW CHECK WELL. STATIC. Printed 1/14/2013 1:45:58PM j / iii .i �� oi,. � g, �.,, - - -�. �:- i =f ;f1 s t t • t Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 0OVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 04:00 1.00 CLEAN P DECOMP POH FROM 2068'. - CLEAN BOOT BASKETS AND RCJB. - NO JUNK RECOVERED. 04:00 - 05:00 1.00 CLEAN P DECOMP M/U RCJB AND RIH T/ 2032 MD. ESTABLISH PARAMETERS. - PU WT. = 70K INCLUDING 40K BLK / TOP DRIVE WT. SO WT. = 70K @ 30 RPM W/ 2K TQ. CIRC. AT 7.5 BPM / 1790 PSI. - WASH DOWN T/ 2076 MD. 05:00 05:30 0.50 CLEAN P DECOMP CIRCULATE 20 BBL HIGH VIS SWEEP @ 7.5 BPM/ 1790 PSI. - CIRC. AT 2076 MD. 05:30 - 08:00 2.50 CLEAN P DECOMP POH F/ 2076 MD. - BREAK DOWN ASSEMBLY. CLEAN JUNK BASKETS. - RCJB, CLEAN WITH NO JUNK. - CLEAR RIG FLOOR OF TOOLS. 08:00 - 11:00 3.00 CLEAN P DECOMP PJSM, R/U TO TEST 7" CSG. PER WELL PROGRAM. Y - WSL VERIFY VALVE ALIGNMENT. - MIT -IA AT 4000 PSI. 30 CHARTED MINUTES. - 11.0 PPG BRINE. - OA =0 PSI. - WTL APPROVED MIT -IA, MEETS CRT- AK -10 -45 CRITERIA - WTL GAVE PERMISSION TO PROCEED WITH RWO OPS. - WSL VERIFY NO TRAPPED PRESSURE PRIOR TO OPENING RAMS. - BLOW DN. ALL LINES AND ASSOCIATED EQUIPMENT. - CLOSE IA AND FILL GAS BUSTER. 11:00 - 12:00 1.00 CLEAN P DECOMP PJSM, M/U HES RBP RETRIEVAL TOOL PER HES REP. - RIH T/ 2035 MD. ESTABLISH PARAMETERS. - PU WT.= 68K INCLUDING 40K BLK / TOP DRIVE WT. -SO WT. =70K CIRC = 8 BPM / 340 PSI. - SET 15K DN WT. ON RPB. - CIRC. 20 BBL HI VIS SWEEP@ 8 BPM / 340 PSI. LOSSES TO WELL LAST 12 HRS = 0 BBLS. Printed 1/14/2013 1:45:58PM r Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:OO:OOPM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM, WITH WSL, HES REPS, BAKER REP, TOOL PUSHER, 2,086.0 RIG CREWS. - CONTINUE T/ CIRC OUT 20 BBL HI VIS SWEEP. - CIRC @ 4 BPM / 150 PSI. - SET DN 20K TOTAL ON RBP. - VVSL / HES REP VERIFY BY -PASS OPEN - NO FLOW, STATIC. - LATCH AND UNSEAT RBP. - CLOSE ANNULAR AND LINE UP THROUGH RIG CHOKE AND GAS BUSTER TO PITS. - CBU THROUGH RIG CHOKE AND GAS BUSTER @ 5 BPM / 230 PSI. - MONITOR WELL AFTER BU REACHES SURFACE. STATIC. - WSL / DRILLER VERIFY NO TRAPPED PRESSURE. - OPEN ANNULAR. DRAIN GAS BUSTER, B/D LINES, AND LINE UP ON HOLE FILL 13:30 - 15:00 1.50 DNB P DECOMP PJSM, POH F/2086 D - WITH 7" RBP ON 4 DP. - CONTINUOUS HOLE FILL, 11.0# BRINE. - L/D RBP 15:00 - 16:00 1.00 FISH P DECOMP CLEAR AND CLEAN RIG FLOOR. - LOAD TOOLS ONTO RIG FLOOR FOR NEXT BHA. 16:00 - 17:30 1.50 FISH P DECOMP PJSM, M/U BHA # 9 TO DRESSOFF AND PULL SBR ASSY. - CUT LIP GLIDE, INSERT, GRAPPLE, EXT., TS, BS, OIL JAR, XO, 6- 4 3/4 DC, XO, INTENSIFIER, XO. 17:30 - 18:00 0.50 FISH P DECOMP RIH WITH 22 STDS 4 DP FROM DERRICK TO 2312 18:00 - 23:00 5.00 FISH P DECOMP PJSM, P/U AND DRIFT 4 DRILL PIPE FROM PIPESHED. - RIH FROM 2312 TO 6767 - FLUID STARTED RUNNING OVER DRILL PIPE. - STOP TRIPPING, MONITOR DRILL PIPE AND WELLBORE 10 MIN. 23:00 - 00:00 1.00 FISH P DECOMP PJSM, P/U AND DRIFT 4 DRILL PIPE FROM PIPESHED. - CIRCULATE DRILL PIPE VOLUME. - PUMP 6 BPM 660 PSI. - FLOWCHECK- STATIC. 10/23/2012 00:00 - 04:00 4.00 FISH P DECOMP PJSM, CONTINUE P/U 4" DRILL PIPE FROM PIPESHED. - DRIFT DRILL PIPE. - RIH FROM 6767' TO 10019'. - P/U WT= 185K. S/O WT= 100K. Printed 1/14/2013 1:45:58PM r` % / /� y �i /iin p # ,�f ma el, A 7/, * • 1 t Common Well Name: MPE 03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:00 1.00 FISH P DECOMP PJSM FOR SILP AND CUT DRLG LINE. - REVIEW DDI SOP. - M/U FOSV, MONITOR WELL. - HANG BLOCKS. - SLIP AND CUT DRILLING LINE. 05:00 - 06:00 1.00 FISH P DECOMP PJSM, CONTINUE T/ RIH F/ 10019 MD. TO 10050 MD. - OBTAIN PARAMETERS. - PU WT. = 185K INCLUDING 40K TOP DRIVE! BLK WT. - SO WT. = 100K, ROT WT. =135K WITH 8K TQ. - TAG FISH @ 10066 MD. ROTATE OVER STUB @ 30 RPM W/ PUMPS OFF. - WORK 2 TIMES OVER STUB. SLIDE DN T! 10073 MD. - PU AND PULL SBR FREE WITH 195K INCLUDING 40K TOP DRIVE / BLK WT. - MONITOR WELL 15 MINUTES. WELL IS STATIC. - B/D TOP DRIVE AND ASSOCIATED LINES. 06:00 - 10:30 4.50 FISH P DECOMP POH F/ 10073 MD. WITH SBR ON 4" DP. - RACK 4" DP AND DC IN DERRICK. +_ 10:30 11:30 1.00 FISH P DECOMP PJSM, LAY DOWN BHA # 9 - RECOVERED 2 7/8" TBG STUB. ,/. d - 2 7/8 " PUP JT., SBR AND SLICK STICK ASSEMBLY. - PKR SEAL ASSEMBLY RECOVERED = 5" OD. - BREAK DN FISHING ASSEMBLY AND RELOAD GRAPPLE. - CLEAR AND CLEAN FLOOR OF TOOLS. - P/U TOOL AND WASH BOP STACK OUT. SPR = 35 SPM / 290 PSI. SPR = 45 SPM / 450 PSI. 11:30 - 13:00 1.50 BOPSUR P -_ DECOMP R/U AND PULL WEAR RING. - R/U TO TEST BOPE. 13:00 - 19:00 6.00 BOPSUR P DECOMP AOGCC JOHN CRISP WAIVED WITNESS ON 10/22/12. - TEST BOPE ACCORDING TO AOGCC REGULATIONS AND DOYON PROCEDURES - TEST ANNULAR WITH 3 1/2" TEST JOINT TO 250/3500 PSI 5 MIN EA. - TEST UPPER 2 7/8 x 5 VBR WITH 3 V2 AND 4 TEST JOINTS TO 250/4000 PSI 5 MIN EA. - TEST LOWER 3 1/2 X 6 VBR WITH 3 1/2 AND 4" TEST JOINTS TO 250/4000 PSI 5 MIN EA. - TEST BLIND RAMS, FLOOR VALVES, CHOKE MANIFOLD TO 250/4000 PSI, 5 MIN EA. - TEST WITH FRESH WATER. - CHART RECORD ALL TESTS. - PERFORM ACCUMULATOR DRAW DOWN TEST. - NO FAILURES. 19:00 - 19:30 0.50 BOPSUR P ■- DECOMP - BLOW D EQUIPMENT. . NLI - BLOW DOWN LINES - INSTALL 7 WEAR RING. RI2LDS. Printed 1/14/2013 1:45:58PM 0 ° t Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 21:30 2.00 FISH P DECOMP PJSM, M/U 6 PACKER MILL. BHA # 10. - 6 PACKER MILL, X/O WITH STINGER, 3- 4 3/4 BOOT BASKETS, - BIT SUB, BUMPER SUB, 4 3/4 JAR, X/O, 9- 4 3/4 DC, X/O, - 4 3/4 INTENSIFIER, PUMP OUT SUB, XO= 332.57 21:30 22:30 1.00 FISH P DECOMP P /U, DRIFT AND RIH TO 1469 WITH 36 JTS 4 DRILL PIPE FROM PIPE SHED. 22:30 - 00:00 1.50 FISH P DECOMP CONTINUE RIH WITH 4 DRILL PIPE FROM DERRICK TO 4597 # 1 MUD PUMP PINNED @ 4150 PSI. 10/24/2012 00:00 - 02:00 2.00 FISH P DECOMP PJSM. CONTINUE R114 WITH 4" DRILL PIPE FROM DERRICK. - RIH FROM 4597' TO 10093' 02:00 - 05:00 3.00 FISH P DECOMP OBTAIN PARAMETERS. - P/U WT= 185K-S/0 WT= 100K ( INCLUDES 40K TOP DRIVE WT) - ROT = WT 133K. FREE TQ 8 -10K @ 80RPM / 5 BPM / 1150 PSI. - TAG PKR @ 10104'. - MILL PACKER W/ VARYING PUMP RATES WITH 3 -9K WOB. - ADD SAFE LUBE. - REDUCTION IN TORQUE FROM 11 -12K TO 9 -10K - MILL PACKER PER BOT REP FROM 10104' TO 10106' 05:00 12:00 7.00 FISH P DECOMP CONTINUE MILLING ON PACKER - PACKER / MANDREL SPINNING. - TRY VARIOUS TECHNIQUES DURING MILLING OPS. - MILLING @ 10,106 . 70 - 75 RPM / 10 - 20K WOB, 3 BPM © 350 PSI. - ACQUIRE SLOW PUMP RATES, 3 BPM / 250 PSI & 3 BPM / 470 PSI. - NO LOSSES OR GAINS TO PITS LAST 12 HOURS. 12:00 12:30 0.50 FISH P DECOMP INSPECT AND SERVICE RIG EQUIPMENT. 12:30 - 00:00 11.50 FISH P DECOMP PJSM. CONTINUE TO MILL ON PACKER @ 10,106 - 70 RPM, 4 BPM @ 520 PSI, 10 - 20K WOB. - PACKER / MANDREL SPINNING, APPLYING VARIOUS TECHNIQUES. - FLOW CHECKING EVERY HOUR AND JARRING DOWN A FEW TIMES PRIOR TO RESUMING MILLING OPS AFTER FLOW CHECKING. - CONTINUE MILLING WITHIN ABOVE PARAMETERS @ 10,106 . Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No LL 000.00 Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF -E:DRI (3, 860 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/25/2012 00:00 - 03:30 3.50 FISH P DECOMP PJ CO ON PACKER @ 10,106 '. - 80 RPM, 4 BPM NTINUE @ 520 TO MILL PSI, 10 - 20K WOB. - PACKER Ti MANDREL SPINNING, APPLYING VARIOUS ECHNIQUES. - FLOW CHECKING EVERY HOUR AND DOWN A FEW TIMES PRIOR TO RESUMING MILLING OPS AFTER FLOW CHECKING. JARRING - CONTG F 10,' TO 10107' _p PACKER DROPP MILLIN L. 10107' 03:30 - 05:00 1.50 FISH P DECOMP OSITION INUE TOOL JT. CLOSE ROM ANNULA ic L U TO RENS THROUGH HOKE INE AND P GAS TAKE BUSTER. TUR CBU 3.5 BPM 620 PSI. - NO GAS SEEN AT BOTTOMS UP. - OPEN ANNULAR. - MONITOR WELL FOR 10 MIN. STATIC. 05:00 - 06:00 1.00 FISH P DECOMP PJSM. CHASE PACKER TM - TOP OF PACKER NOW @ TO 10 O . S ET DOWN 20K, SOLID TAG. - ACQUIRE 4 BPM / SLOW 450 PUMP RATES, 3 BPM / 300 PSI PSI. , 06:00 - 07:30 1.50 FISH P DECOMP PJSM. U PUMP 20 - CLATE SWEEP BBLS AROHI VIS UND SWEEP. @ 6 BPM / 1540 CIR PSI. - BACK OVER SHAKER W/ BOTTOMS NOT MUCH UP. - MONITOR WELL, WELL STABLE. 07:30 - 09:00 1.50 FISH P DECOMP . H 4" DP AND MILLING ASSE - POOH TO 5000 W/ . MONITOR WELL, WELL STABLE. - NO LOSSES ORN GAINS POINT. 09:00 - 09:30 0.50 FISH P DECOMP PJSM. CLOSE ANNULAR PREVENTOR. TO THIS - LINE UP AND CIRCULATE THRU CHOKE. - CIRCULATE BOTTOMS UP @ 4.5 BPM / 660 PSI. - TAKING RETURNS THRU MUD GAS SEPARATOR. OPEN ANNULAR PREVENTOR, NO GAS, MONITOR WELL, WELL STABLE. 09:30 10:30 1.00 FISH P DECOMP PJSM. CONTINUE TO W" POOH TO 2500 ,MONITOR POOH WEL 4 , WELL DP. STABLE. NO SS OR GAINS TO THIS POINT. 10:30 - 11:00 0.50 FISH P DECOMP PJSM. LO CLO SE ANNULAR PREVENTOR. - LINE UP AND CIRCULATE THRU CHOKE. - CIRCULATE BOTTOMS UP @ 4.5 BPM / 470 PSI. - TAKING RETURNS THRU MUD GAS SEPARATOR. - OPEN ANN 11:00 - 11:30 0.50 ULAR PR, NO GAS, MONITOR WELL, WELL STABLE. FISH P DECOMP PJSM. CONTINUE TO POOH WREVENTO/ 4" DP. - POOH TO 1500 , MONITOR WELL, WELL STABLE. - NO LOSSES OR GAINS TO THIS POINT. Printed 1/14/2013 1:45:58PM i e Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14 /1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 12:00 0.50 FISH P DECOMP PJSM. CLOSE ANNULAR PREVENTOR. - LINE UP AND CIRCULATE THRU CHOKE. - CIRCULATE BOTTOMS UP @ 4.5 BPM / 430 PSI. - TAKING RETURNS THRU MUD GAS SEPARATOR. - OPEN ANNULAR PREVENTOR, NO GAS, MONITOR WELL, WELL STABLE. - 0 BBLS LOST OR GAINED DURING LAST 12 HOUR PERIOD. 12:00 - 13:00 1.00 FISH P DECOMP INSPECT AND SERVICE RIG EQUIPMENT 13:00 - 13:30 0.50 FISH P DECOMP PJSM. CONTINUE TO POOH. - MONITOR WELL AT COLLARS, WELL STABLE. 13:30 - 15:30 2.00 FISH P DECOMP PJSM. STAND BACK COLLARS, LID BHA. - INSPECT MILL, OD APPROXIMATELY 1/16" UNDER GAUGE. - MILL EXTREMELY WORN, SMOOTH ON BOTTOM AND SIDES. 15:30 - 16:30 1.00 FISH P DECOMP PJSM. PICK UP PACKER SPEAR ASSEMBLY. - 2 13/16 SPEAR, XO, 4 3/4 BUMPER SUB, 4 3/4 JAR, XO, 9- 4 3/4 DC, XO, INTENSIFIER, PUMP OUT SUB, XO= 316.45 16:30 - 20:00 3.50 FISH P DECOMP RIH WITH 107 STANDS 4 DRILL PIPE TO 10456 20:00 - 20:30 0.50 FISH P DECOMP P/U SINGLE, M/U TOP DRIVE. - OBTAIN PARAMETERS. P/U WT= 185K, 5/0 WT= 106K - PUMP 2 BPM 440 PSI. TAG PACKER, NO GO @ 10466 - STACK 20K. NO PUMP PRESSURE INCREASE. P/U 20 , STACK 25K. - P/U 20 WITH NO OVERPULL. L/D SINGLE. PULL AND SET BACK 1 STAND. - POH WITH NO OVERPULL AND NO DRAG. 20:30 - 22:00 1.50 FISH P DECOMP DROP 7/8 BALL, M/U TOP DRIVE. CLOSE ANNULAR. - LINE UP TO TAKE RETURNS VIA CHOKE AND GAS BUSTER. - SHEAR PUMP OUT SUB 2500 PSI. - CBU 5 BPM 580 PSI. NO GAS AT RETURNS. - FLOW CHECK WELL FOR 10 MIN. STATIC. - OPEN ANNULAR. MONITOR WELL. STATIC. 22:00 - 00:00 2.00 FISH P DECOMP POH WITH 4 DRILL PIPE FROM 10370 TO 8087 - MONITOR CLOSELY FOR POTENTIAL SWABBING 10/26/2012 00:00 - 00:30 0.50 FISH P DECOMP PJSM, POH WITH SPEAR BHA FROM 8087' TO 5000' - MONITOR CLOSELY FOR POTENTIAL SWABBING. 00:30 - 01:00 0.50 FISH P DECOMP PJSM. CLOSE ANNULAR. - LINE UP CHOKE AND GAS BUSTER. - CBU @ 5000', PUMP 4.5 BPM 250 PSI. - TAKE RETURNS THROUGH CHOKE AND GAS BUSTER. - NO GAS @ RETURNS. - OPEN ANNULAR. MONITOR WELL. STATIC. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 01:30 0.50 FISH P DECOMP CONTINUE POH WITH SPEAR BHA FROM 5000' TO 2500'. - MONITOR CLOSELY FOR POTENTIAL SWABBING. 01:30 - 02:00 0.50 FISH P DECOMP CLOSE ANNULAR. - LINE UP CHOKE AND GAS BUSTER. - CBU © 2500', PUMP 4.5 BPM 120 PSI. TAKE RETURNS THROUGH CHOKE AND GAS BUSTER. - NO GAS @ RETURNS. - OPEN ANNULAR. MONITOR WELL. STATIC. 02:00 - 02:45 0.75 FISH P DECOMP CONTINUE POH WITH SPEAR BHA FROM 2500' TO 1500'. - MONITOR CLOSELY FOR POTENTIAL SWABBING. 02:45 - 03:00 0.25 FISH P DECOMP CLOSE ANNULAR. - LINE UP CHOKE AND GAS BUSTER. - CBU @ 1500', PUMP 4.5 BPM 80 PSI. - TAKE RETURNS THROUGH CHOKE AND GAS BUSTER. - NO GAS @ RETURNS. - OPEN ANNULAR. MONITOR WELL. STATIC. 03:00 - 03:30 0.50 FISH P DECOMP CONTINUE POH WITH SPEAR BHA FROM 1500' TO BHA. - MONITOR CLOSELY FOR POTENTIAL SWABBING. - FLOWCHECK WELL BEFORE PULLING BHA THROUGH STACK. - WELL IS STATIC. 03:30 - 04:30 1.00 FISH P DECOMP PJSM FOR BHA. - L/D POS AND INTENSIFIER. - STAND BACK DRILL COLLARS. - PULL SPEAR TO RIG FLOOR. NO FISH. ~MARKS ON OUTSIDE EDGE OF BULLNOSE. - BULLNOSE APPEARED TO STACK ON TOP OF PACKER. 04:30 - 05:00 0.50 FISH N DPRB DECOMP DISCUSS OPTIONS WITH BOT REP. - W/O 2 15/16" JUNK MILL TO CLEANUP PROFILE ON PACKER. - MONITOR WELL. 05:00 - 09:30 4.50 FISH N DPRB DECOMP WAIT ON BAKER TOOLS. 09:30 - 10:30 1.00 FISH N DPRB DECOMP CONTINUE TO WAIT ON BAKER TOOLS. - @ 09:30 RECIEVED NOTIFICATION OF WELL CONTROL EVENT @ DOYON 25. - THIS IS A DRILL AND WE WERE ASKED TO STAND DOWN. - CONTACTED BY SUPERINTENDANT. CREW NOTIFIED. - CONTINUE TO WAIT ON TOOLS. 10:30 - 11:30 1.00 FISH N DPRB DECOMP PJSM. M/U BHA TO MILL ID OF PACKER. - 2 15/16" JUNK MILL W/ 6" STABILIZER FOR CENTRALIZATION. 11:30 - 15:30 4.00 FISH N DPRB DECOMP PJSM. RIH W/ JUNK MILLING BHA ON 4" DP. - 107 STANDS, P/U (1) SINGLE, MAKE UP TOP DRIVE. Printed 1/14/2013 1:45:58PM • f i °/ d %r ` " x °if rs • i Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 16:30 1.00 FISH N. DPRB DECOMP - ESTABLISH PARAMETERS, 185K UP WT, 106K DOWN WT, 135K ROTATING WT. - TAG TOP OF PACKER @ 10,464'. PUMP PRESSURE INCREASED. - PUMPING 3 BPM @ 900 PSI ABOVE PACKER. - ROTATING @ 10 RPM, 7500 - 8000 FT /LBS TORQUE OFF BOTTOM. WORK THRU FILL ON TOP OF PACKER AND WORK DOWN TO APPROXIMATELY 2.3' BELOW TOP OF PACKER, OBSERVE INCREASE IN PUMP PRESSURE TO 2500 PSI @ 3 BPM. REPEAT SEVERAL TIMES. 16:30 - 19:00 2.50 FISH N DPRB DECOMP PJSM. PUMP 30 BBLS HI VIS SWEEP. - @ 10,466.3' W/ SWEEP © MILL. PUMP 5 BBLS PAST MILL, P/U 3' AND BRING PUMP UP TO 6 BPM / 1800 PSI. -CLEAN AT SWEEP RETURNS. - BREAK OFF AND BLOWDOWN TOP DRIVE. 19:00 - 20:00 1.00 FISH N DPRB DECOMP PJSM FOR SILP AND CUT DRLG LINE. - REVIEW DDI SOP. - M/U FOSV. HANG BLOCKS. - SLIP AND CUT 81' DRILLING LINE. - MONITOR WELL. STATIC. 20:00 - 21:30 1.50 FISH N DPRB DECOMP POH WITH 2 15/16" MILL BHA FROM 10450' TO 7810'. - START PULLING WET. 21:30 - 22:00 0.50 FISH N DPRB DECOMP DROP 7/8" STEEL BALL. M/U TOP DRIVE. - CIRC 4 BPM 100 PSI. BALL ON SEAT. - PRESSURE UP TO 2500 PSI. SHEAR POS. - BREAK OFF AND BLOW DOWN TOP DRIVE. 22:00 - 00:00 2.00 FISH N DPRB DECOMP POH WITH 2 7/8" MILL BHA FROM 7810' TO 4682'. 10/27/2012 00:00 - 01:00 1.00 FISH N DPRB DECOMP SERVICE RIG FLOOR EQUIPMENT. - PJSM FOR POH. 01:00 - 03:00 2.00 FISH N DPRB DECOMP POH WITH 2 15/16" MILL BHA FROM 4682' TO 354'. - FLOWCHECK WELL 10 MIN. BEFORE PULLING BHA. 03:00 - 04:00 1.00 FISH N DPRB DECOMP PJSM. LID MILL AND BOOT BASKET. - MILL IN GAGE, SLIGHT WEAR ON NOSE AND SIDES. - , FROM BOOT BASKET RECOVERED 1 PACKER SLIP AND SMALLER PIECES OF PACKER. - SEE ATTACHMENT. 04:00 - 04:30 0.50 FISH N DPRB DECOMP CLEAR AND CLEAN RIG FLOOR. 04:30 - 05:30 1.00 FISH N DPRB DECOMP PJSM. PICK UP PACKER SPEAR ASSEMBLY. - 2 13/16" SPEAR, XO, 43/4" BUMPER 3/4" JAR, XO, 9- 4 3/4" DC, XO, INTENSIFIER, PUMP OUT SUB, XO= 316.45' 05:30 - 09:30 4.00 FISH N DPRB DECOMP PJSM. RIH F/ 316' - 10,456'. - ESTABLISH PARAMETERS: 190K UP WT, 105K DOWN WT. - ACQUIRE SLOW PUMP RATES: 2 BPM / 410 PSI, 2 1/2 BPM/ 550 PSI. Printed 1/14/2013 1:45:58PM e ° � �, a , Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:30 1.00 FISH N DPRB DECOMP PJSM. WASH DOWN TO PACKER, PUMPING 3 BPM / 900 PSI. - SEE TOP OF PACKER @ 10,464', ROTATE (1) TURN TO THE RIGHT. - POP INTO PACKER, OBSERVE PRESSURE INCREASE TO 1300 PSI. - PICK UP, OBSERVE 30K OVER PULL. - ALL WEIGHT CHECKS INCLUDE 40K TOP DRIVE. 10:30 - 12:00 1.50 FISH N DPRB DECOMP PJSM. L/D (1) SINGLE, DROP BALL TO OPEN PUMP OUT SUB. - OPEN PUMP OUT SUB, CIRCULATE BOTTOMS UP, 5 BPM / 570 PSI. - NO GAS WITH BOTTOMS UP, WHILE CIRCULATING WORK PACKER UP AND DOWN THROUGH CASING COLLAR. 0 BBLS LOST OR GAINED LAST (12) HOURS. 12:00 - 12:30 0.50 FISH N DPRB DECOMP SERVICE RIG AND MONITOR WELL, WELL STABLE. 12:30 - 16:30 4.00 FISH N DPRB DECOMP PJSM. POOH W/ 4" DP F/ 10,453' - 4770'. - WELL TAKING FLUID NOW, LOSS RATE FLUCTUATING. 16:30 - 17:30 1.00 FISH N DPRB DECOMP - CIRCULATE BOTTOMS UP, 5 BPM / 350 PSI. - LOST (5) BBLS DURING CIRCULATION. - MONITOR WELL, WELL STABLE. 17:30 - 19:00 1.50 FISH N DPRB DECOMP CONTINUE POH WITH 4" DRILL PIPE FROM 4770' - FLOWCHECK WELL FOR 10 MIN BEFORE PULLING BHA. - WELL STATIC. 19:00 - 21:30 2.50 FISH P DECOMP PJSM FOR HANDLING BHA AND UD FISH. - REVIEW DDI SOP FOR TRAPPED PRESSURE IN TBG TAIL. - STAND BACK DRILL COLLARS. - L/D FISHING BHA. PACKER ASSY RECOVERED. 1 - R/U HOLE PUNCH, PUNCH SEVERAL HOLES ' IN TAIL PIPE ASSY. 1f7 - RELEASING TRAPPED PRESSURE AND SAND. 6 - UD FISH, TOTAL LENGHT= 53.77' - MONITOR WELL, STATIC. 21:30 - 22:00 0.50 FISH P - DECOMP CLEAR AND CLEAN RIG FLOOR. - LOAD OUT FISHING TOOLS AND FISH. 22:00 - 23:00 1.00 FISH P DECOMP PJSM, M/U 6" MILL BHA. - 6" MILL, BIT SUB, STAB, DBL PIN SUB, BOOT BSKT,BIT SUB, BUMPER SUB, JAR, XO, 9- 4 3/4" DC, XO, PUMP OUT SUB, XO= 320.71' 23:00 - 00:00 1.00 FISH P DECOMP RIH WITH 4" DRILL PIPE TO 1647'. - LOSSES TO WELL LAST 12 HRS= 17 BBLS 11 PPG BRINE. 10/28/2012 00:00 - 00:30 0.50 CLEAN P DECOMP SERVICE AND INSPECT RIG FLOOR EQUIP. 00:30 - 04:00 3.50 CLEAN P DECOMP PJSM, RIH WITH 6" MILL CLEANOUT BHA. - RIH FROM 1674' TO 10080' WITH 4" DRILL PIPE. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 04:30 0.50 CLEAN P DECOMP M/U TOP DRIVE. PUMP 6 BPM 950 PSI. - S/O WT= 98K. P/U WT= 180K. - 80 RPM= 9 -10K FREE TORQUE. - CLEANUP PACKER SETTING AREA @ 10065' TO 10095' - BLOW DOWN TOP DRIVE. 04:30 05:00 0.50 CLEAN P DECOMP RIH WITH 4" DRILL PIPE FROM 10080' to 10461' 05:00 - 12:00 7.00 CLEAN P DECOMP PJSM. TAG TOP OF CEMENT @ 10,517 DPM. - ESTABLISH PARAMETERS, 190K UP WT, 102K DOWN WT, 135K ROTATING WT. 11,000 FT /LBS OFF BOTTOM TORQUE. - ALL WT CHECKS INCLUDE 40K TOP DRIVE WT. - ACQUIRE SLOW PUMP RATES: 30 SPM / 260 PSI, 40 SPM / 420 PSI. - MILLING CEMENT FROM 10 517 .80 - 100 RPM, 6 BPM/ 1020 PSI. - 1- 3K WOB, MILL TO 10,594 , SWEEPING HOLE REGULARLY. CONDUCT WEEKLY SAFETY MEETING WITH ONCOMING CREW PRIOR TO C/O. - DDI SUPPORT CREW IN ATTENDANCE. - REVIEW NEW SAFETY BULLETINS - DISCUSS DRIVING INCIDENTS, HOW THESE INCIDENTS RELATE TO OUR OPERATIONS AND WHAT PRECAUTIONS WE HAVE PUT IN PLACE TO HELP PREVENT DRIVING INCIDENTS. - IMPORTANCE OF 360 WALK AROUND VEHICLES AND EQUIPMENT. - REVIEW DDI LOADER FUELING POLICY. - 0 BBLS LOST OR GAINED LAST (12) HOURS 12:00 - 18:30 6.50 CLEAN P DECOMP PJSM. CONTINUE TO MILL CEMENT FROM 10,594 . - REGULARLY CHECKING FOR SALT PILL BY STOPPING ROTATING AND SEEING IF IT TAKES WT WITH ONLY PUMP ON. IF YES, MUST BE CEMENT. - MILL DOWN TO 10651 AT END OF CEMENT PLUG. - MILL TO 10656 , VERY SOFT AT SALT PLUG. 18:30 - 19:30 1.00 CLEAN P DECOMP PJSM, P/U 6 TO 10650 , L/D 1 SINGLE. - CLOSE ANNULAR, CIRC BOTTOMS UP 4 BPM 590 PSI WITH RETURNS THROUGH CHOKE AND GAS BUSTER. - NO GAS AT RETURNS. WELL STATIC. - OPEN ANNULAR. 19:30 - 21:30 2.00 CLEAN P DECOMP PUMP 20 BBL HI VIS SWEEP 6 BPM 1450 PSI. - SOME CEMENT RETURNS AT SHAKER. - CIRC OUT SWEEP, CLEAN RETURNS. - MONITOR WELL FOR 10 MIN. STATIC. 21:30 - 22:00 0.50 CLEAN P DECOMP PJSM, BREAK OUT TOP DRIVE. - POH AND LID 4 DRILL PIPE FROM 10650 . - ENCOUNTER 30K OVERPULL AT 10618 Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE N Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- OOVKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Description P th Phase Descri tion of Operations (hr) (ft) 22:00 - 23:00 1.00 CLEAN P DECOMP MAKE UP TOP DRIVE. PUMP 7 BPM 1900 PSI. - ROTATE 60 RPM, WORK PIPE FROM 10618 TO 10555 - WORKING FREE ANY POSSIBLE JUNK. 23:00 - 23:30 0.50 CLEAN P DECOMP BREAK OUT TOP DRIVE. POH L/D 4 DRILL PIPE FROM 10555 TO 10429 ENCOUNTER 20K OVERPULL AT 10429 23:30 - 00:00 0.50 CLEAN P DECOMP MAKE UP TOP DRIVE. PUMP 6 BPM 1540 PSI. - PUMP 20 BBL HI VIS SWEEP. - RECIPROCATE AND ROTATE FROM 10429 TO 10334 . - FREE UP JUNK ALONG SIDE MILL. - CIRC SWEEP AROUND. - VERY LITTLE CEMENT AT SWEEP RETURNS. CONDUCT WEEKLY SAFETY MEETING WITH ONCOMING CREW PRIOR TO C/O. - WATCH HIGH VALUE LEARNING VIDEO FOR MPL -06. - WHAT ARE OUR BARRIERS. "- PROPER VALVE LINEUP. ASK AND VERIFY. - IMPORTANCE OF DETAILED CREW CHANGE. - DISCUSS DRIVING INCIDENTS, HOW THESE INCIDENTS RELATE TO OUR OPERATIONS. - REVIEW DDI LOADER FUELING POLICY. - NO LOSSES OR GAINED FLUID FROM WELL IN LAST 12 HRS. 10/29/2012 00:00 - 08:30 8.50 CLEAN P DECOMP PJSM. BREAK OFF AND BLOW DOWN TOP DRIVE. - FLOWCHECK. WELL REMAINS STATIC. - POH LID 4" DRILL PIPE FROM 10334' TO 5000' 08:30 - 09:00 0.50 CLEAN P DECOMP WELL CONTROL DRILL. - SAFETY VALVE STABBED, SIMULATED CLOSING IN WELL. - WELL OPENED TO A CLOSED CHOKE, ALL HANDS ON STATIONS. - GOOD RESPONSE, (1 MIN 30 SEC), AAR HELD IN DOGHOUSE. 09:00 - 10:00 1.00 CLEAN P DECOMP CONTINUE TO POOH W/ DRILL PIPE. - MONITOR WELL F/ 10 MIN, WELL STABLE. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM. LAY DOWN BHA. - LAY DOWN DRILL COLLARS AND MILLING BHA. - WEAR ON OD OF MILL, (METAL CONTACT). - CLEAN JUNK SUBS, RECOVERED 10 SMALL PIECES OF METAL AND (1) SLIP DIE. CLEAR FLOOR OF BAKER TOOLS. NO FLUID LOST OR GAINED LAST (12) HOURS. 12:00 - 13:00 1.00 RUNCOM P RUNCMP PJSM. SERVICE RIG. CLEAR / CLEAN RIG FLOOR. - PULL WEAR BUSHING. Printed 1/14/2013 1:45:58PM 74, *4 "%eltj''' 144443 1411,4';',11rt --/101:4110011714//:-/>":,41,111;1/111?;',It'i,:iilLi;t;''i!: P $ ! 8 Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4 -OOVKF E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 15:30 2.50 RUNCOM P RUNCMP CHANGE OUT BALES, R/U TO RUN COMPLETION. - RIG UP STABBING BOARD & COMPENSATOR. - RIG UP TORQUE TURN EQUIPMENT 15:30 - 16:30 1.00 RUNCOM P RUNCMP PJSM WITH ALL HANDS, SCHLUMBERGER AND HALLIBURTON. EMPHASIS ON HAND PLACEMENT AND COMMUNICATION. - PICK UP AND MAKE UP TAIL PIPE ASSEMBLY AND PACKER. - ALL CONNECTIONS BELOW PACKER BAKER LOCKED. 16:30 - 21:00 4.50 RUNCOM P RUNCMP ,.E/U AND RIH WITH 3 1/2 9.2# L -80 TC-11 COMPLETION PER WSL TALLY AND WELL PLAN. - DRIFT TUBING AND JEWELRY. - TORQUE TURN 3 1/2 TBG TO OPTIMUM RANGE @ 2300 FT LBS. - USE JET LUBE SEAL GUARD PIPE DOPE. RIH TO 1914 21:00 - 21:30 0.50 RUNCOM P RUNCMP WELL CONTROL DRILL WHILE RUNNING COMPLETION. STAB AND M/U FOSV AND CROSS OVER. CLOSE FOSV. - SIMULATE SHUTTING ANNULAR. - KILL LINE OPENED TO CLOSED CHOKE. - SECURE WELL 2 MIN 11 SEC. CONDUCT AAR WITH CREW. - GOOD RESPONSE TIME. - FLOORHANDS RESPONDED WELL. - ALL REPORTED TO ASSIGNED STATIONS. - SCS NOTIFIED. 21:30 - 00:00 2.50 RUNCOM P RUNCMP CONTINUE P/U AND RIH WITH 3 1/2 9.2# L -80 TC -I I COMPLETION. - RIH FROM 1914 TO 3484 ( 105 JTS ) - NO LOSSES OR GAINED FLUID FROM WELL IN LAST 12 HRS. 10/30/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP INSPECT AND SERVICE RIG FLOOR EQUIPMENT. - PJSM FOR RUNNING COMPLETION WITH RIG CREW, HES AND SLB REPS. - DISCUSS WELL CONTROL PLAN, PIPE SKATE AND RIG FLOOR RED ZONES. - REVIEW RUNNING ORDER. 00:30 - 08:30 8.00 RUNCOM P RUNCMP P/U AND RIH WITH 3 1/2" 9.2# L -80 TC-II COMPLETION PER WSL TALLEY AND WELL PLAN. - DRIFT TUBING AND JEWELRY. - TORQUE TURN 3 1/2" TBG TO OPTIMUM RANGE @ 2300 FT LBS. - USE JET LUBE SEAL GUARD PIPE DOPE. - RIH FROM 3484' 08:30 - 10:00 1.50 RUNCOM P RUNCMP PJSM. M/U LANDING NIPPLE W/ ISOLATION SLEEVE. - RIG UP SLB SHEAVE & CONTROL LINE. - TIE IN CONTROL LINE & TEST @ 5000 PSI / 5 MIN / GOOD TEST. Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4 -OOVKF E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 12:00 2.00 RUNCOM P RUNCMP CONTINUE TO RIH F/ 8002' - 8664'. UP WT 101 K, DOWN WT 76K. - ALL WEIGHT CHECKS INCLUDE TOP DRIVE, (40K). - 0/A © 750 PSI, BLED OFF TO SLOP TANK, PRESSURE BUILT BACK UP TO 750 PSI IN 20 MIN. 12:00 13:00 1.00 RUNCOM P RUNCMP INSPECT EQUIPMENT & SERVICE RIG COMPONENTS. 13:00 - 16:00 3.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 3 1/2" TCII COMPLETION STRING AND 1/4" CONTROL LINE. - INSTALLING STAINLESS STEEL BAND ON EVERY JOINT. - @ 9565', (TUBING TAIL DEPTH), SET DOWN 5K. - PACKER DEPTH IS 9436'. CONSULT WITH ODE. 16:00 - 17:30 1.50 RUNCOM P RUNCMP PJSM. RIG UP TO CIRCULATE THE LONG WAY. - CIRCULATE @ 2 BPM / 190 PSI, SET DOWN 5K IN SAME SPOT. REPEAT WITH SAME RESULTS. - SHUT DOWN PUMP, STOP PIPE 6" ABOVE TROUBLE SPOT. - CLOSE ANNULAR PREVENTOR, LINE UP TO REVERSE CIRCULATE. - REVERSE CIRCULATE @ 4 BPM / 650 PSI FOR (5) MINUTES. - OPEN ANNULAR AND WORK PAST TROUBLE SPOT. 17:30 - 22:30 5.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 3 1/2" TCII COMPLETION STRING AND 1/4" CONTROL LINE - SET DOWN 5K AGAIN AT — 9640', 9821', 9989', 10174', (TUBING TAIL DEPTHS) - UNABLE TO WORK PAST TROUBLE SPOTS WITH REVERSE CIRCULATION AT 4 BPM = 660 PSI - BEGAN WORKING PIPE 40 FEET PER STROKE WITH SUCCESS - ABLE TO WORK PAST TROUBLE SPOTS 22:30 - 23:30 1.00 RUNCOM P RUNCMP MAKE UP HANGER AND LANDING JOINT - ATTACH CONTROL LINE TO HANGER AND TEST LINE TO 5000 PSI - PUWT = 110K, SOWT = 80K - LAND HANGER - 70 SS BANDS USED 23:30 - 00:00 0.50 RUNCOM P RUNCMP RUN IN LOCK DOWN SCREWS - L/D LANDING JOINT - OA= 830PSI - NO FLUID LOSS TO WELL Printed 1/14/2013 1:45:58PM Common Well Name: MPE -03 AFE No Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/31/2012 00:00 - 02:30 2.50 RUNCOM P RUNCMP PJSM, PUMP CORROSION INHIBITOR - PRESSURE TEST SURFACE LINES - REVERSE CIRCULATE 260 BBLS ON 11.0 PPG CORROSION INHIBITED HEATED BRINE DOWN IA - 3.2 BPM = 700 PSI - MONITOR WELL = STATIC 02:30 - 04:30 2.00 RUNCOM P RUNCMP M/U LANDING JOINT TO HANGER - DROP 1 5/16" BALL AND ROD, WIRELINE RETRIEVABLE - SET PACKER, PRESSURE UP TO 4000 PSI, 30 MINUTES CHARTED, GOOD TEST - BLEED TUBING PRESSURE BACK TO 1500 PSI - PRESSURE TEST IA TO 4200 PSI, 30 MINUTES, CHARTED, GOOD TEST 04:30 - 05:30 1.00 RUNCOM P RUNCMP - TEST CHARTED, WC M ABOVE TEST 3500 PSI,10 05:30 - 09:00 3.50 BOPSUR P WHDTRE PJSM. FLUSH OUT STACK AND DRAIN. - FLUSH CHOKE AND ALL ASSOCIATED LINES. DISCONNECT LINES FROM STACK, BLOW DOWN ALL LINES. 09:00 - 12:00 3.00 BOPSUR P WHDTRE PJSM. CHANGE OUT LOWER RAMS TO 2 7/8" FIXED BORE. - OPEN DOORS TO BLIND SHEAR RAMS AND UPPER PIPE RAMS. - CLEAN AND INSPECT UPPER PIPE RAMS AND BLIND SHEAR RAMS. - SECURE DOORS TO UPPER PIPE RAMS AND BLIND SHEAR RAMS. 0/A PRESSURE BLED FROM 940 PSI TO 500 PSI @ 08:00 HRS. - @ 08:45 HRS, 0/A PRESSURE @ 830 PSI. - 0 BBLS GAINED OR LOST TO WELLBORE LAST (12) HRS. 12:00 - 14:30 2.50 BOPSUR P WHDTRE PJSM. BLEED OFF ACCUMULATOR PRESSURE TO LINES. - RIG DOWN ACCUMULATOR LINES TO BOPE. - N/D 13 5/8" X 5M BOP STACK. 14:30 - 19:30 5.00 WHSUR P WHDTRE PJSM. N/U 11" X 3 1/8" 5K ADAPTER FLANGE. - FMC TESTED ADAPTER / HANGER VOID TO 5000 PSI, 30 MIN, GOOD TEST - ATTACH AND PURGE CONTROL LINES - TEST CONTROL LINES TO 5000 PSI, 15 MIN, GOOD TEST 19:30 - 21:00 1.50 WHSUR P WHDTRE PJSM, N/U 3 V' 5K FMC TREE - TEST TRES TO 5000 CHARTED, GOOD TEST - REMOVE SECONDARY VALVE ON ANNULUS 21:00 - 22:30 1.50 WHSUR N WAIT WHDTRE WAIT ON WELL SUPPORT, TIED UP ON ANOTHER JOB - CLEAN PITS, REMOVE HOPPER FROM HOPPER ROOM - CHANGE OUT BLOCK VALVE ON CHOKE MANIFOLD Printed 1/14/2013 1:45:58PM I, AFE N o Common Well Name: MPE -03 Event Type: WORKOVER (WO) Start Date: 9/20/2012 End Date: 11/1/2012 X4- 00VKF- E:DRILL (3,860,000 00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/14/1989 12:00:00PM Rig Release: 11/1/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 2 : 03 7/14/1989 00:00 @52.Oft (above Mean Sea Level) Date (hr) From - To Hrs Task Code NPT NPT (ft) Depth Phase Description of Operations 22:30 - 00:00 1.50 WHSUR P WHDTRE -PJSM, R/U WELL SUPPORT LUBRICATOR - TEST LUBRICATOR, 250 PSI LOW, 4000 PSI HIGH, 5 MIN, CHARTED -OA =810 PSI 11/1/2012 00:00 01:30 1.50 WHSUR P WHDTRE PJSM, - PULL TWC i TEST LUBRICATOR, 250 PSI LOW, 4000 PSI HIGH, 5 MIN, CHARTED INSTALL BPV - R/D WELL SUPPORT 01:30 - 02:00 0.50 WHSUR P WHDTRE R/D CELLAR AND SECURE TREE - RELEASE RIG AT 2:00 Printed 1/14/2013 1:45:57PM • MPE -03, Well History (Post Rig Workover) Date Summary 11/02/12 Pulling CIW H BPV # MP3 -01 > 200 psi. T /I /O = 250/200/860 Conduct PJSM. Barriers = SV & SSV. Verified by bleeding tubing pressure off SV. LTT Passed. R/U lubricator and tested to 300 low and 3500 high. Pulled BPV with no extension and tagged at 108 ". PT'd lateral lines to 5000 psi for 15 min. 11/03/12 RAN 2" DRIVE DOWN BAILER.S /D @ 3' SLM.RECOVERED CUP OF ICE. TARPPED WELL & CASING HANGER.APPLIED HEAT, RAN 2.5" CENT & 1.5" SAMPLE BAILER.DRIFTED DOWN TO 100' SLM. PULLED ISOLATION SLEEVE FROM 2183' MD. RAN 3.5" SHIFTING & OPENED SLIDING SLEEVE @ 10004' MD. STBY FOR LRS TO R/U ON I.A FOR FREEZE PROTECT AND C- MITxI.A. 11/04/12 CLOSED SSD @ 10004' MD.PRESSURED TBG TO 2000 PSI TO CONFIRM SSD CLOSED. PULLED BALL & ROD AND RHC -M PLUG BODY FROM 10165' MD. SET ISOLATION SLEEVE@ 2183' MD. 11/04/12 T/I/O= 0/270/770 Freeze Protect. Pumped 85 bbls diesel down IA taking returns up Tbg. to Surface tank. U -Tube FP into Tbg. 11/12/12 PULLED 2.813" DSSSV FROM 2162' SLM/ 2183' MD. D &T W/ 2.60" CENT, TEL, & S.BAILER, LOC TT @ 10183' SLM/ 10196' MD (13' CORRECTION), TAGGED FILL @ 10629' MD. 11/16/12 Objective- recover IBP post RWO. MIRU from MPJ -17. RU scaffolding on top of wellhouse. Weekly BOPE test completed. Make up Venturi BHA with 2.70" junk basket and RIH. 11/17/12 Job Objective. ecover IBP post R RIH with Venturi BHA and jet to top of salt plug. Tagged at_, 10662 feet and made multiple slow pick ups to collect debris. POH. Recovered one cup of metal fines and 1/2 cup of rig milling debris (2" x 1" x 1/32 "). Open well to 1150 psi. Rerun Venturi to 1250' and set down in slush. POH and assume well fluids have hydrates. LD Venturi assy. Replumb PIS assy to get BOP'S lower. Add return line to MPE -08 tree cap. Make up Hydrate jetting BHA with 2.5" DJN. RIH jetting hydrates with methanol holding 2500 psi WHP. 11/18/12 RIH with 2.5" OD DJN jetting hydrates with methanol. Holding 2500 psi back pressure and broke through at 1370' and 1740 psi. Ran to 10,100' and pumped bottoms up of 60/40 while walking down WHP to maintain 1350 psi (- 200psi overbalance). POOH pumping displacement- maintain 1350 psi. LD nozzle assy. MU Venturi assy w/ extension. RIH taking returns to E -08 FL holding 1400 psi backpressure. Tag at 10665' CTM. Break thru crust and Hoover to 10668' using 60/40. POOH. Recovered 2.5 gal salt, steel, brass and slip debris, plus several small -egg sized chunks of cement. Rerun same assy (BHA #5). Tag at 10665' CTM and made no progress past 10666'. POOH. Check wall thickness of bias weld at 5410'. Wall thickness found to be 0.116" (nom 0.134 "), below minimums and will need to go to shop. Continue POOH. Recovered quarter sized cement chunks as well as more steel debris. Prep to blow down coil with N2. 11/19/12 Blow down CT w/ N2. RDMO to SWS yard to cut out bad section of CT. 11/20/12 MIRU from SWS yard after cutting out bad spot in CT @ — 5400'. Drift w/ 1.25" ball and fill reel w/ 60/40. MU Venturi BHA. Open well to 900 psi. RIH holding 1400 psi bp while take displacement returns to E -08 FL. Lost wt at 10663' and stack 2k by 10665' using 20 bbls McOH. POH. Recovered thick hydrocarbons, some salt and a few dime sized cement chunks and small metal pieces. MU nozzle assy and RIH. Jet top of salt plug to 10700 and swap wellbore over to warm water. Page 1 of 3 • • MPE -03, Well History (Post Rig Workover) Date Summary 11/21/12 RIH with 2.5" DJN and jet top of salt plug for fill to ensure successful venturi run. Make up venturi basket and RIH. Tag w/ min rate at 10685'. Hoover at this depth and made no progress. POH. Recovered one quart of small cement chunks and steel debris along with a 2" x 1" x 1 -1/4" chunk of cement jammed in the bottom of the Venturi and likely preventing additional recovery. MU same BHA( #9). RIH to 10685' and made no progress -solid bottom. POH. Recovered 3 quarts of pea gravel sized cement w/ little metal, six dime to quarter sized chunks of cement and one 1" +square cement chunk. Discuss w/ APE. Bottom is solid so assume there are larger pieces which won't fit in barrel. LD Venturi. RIH w/ BTT DB UR assy w/ 6.023" blades. UR from first stall at 10688' to last (5th) stall at 10692'. Clean to 10700'. POH. 11/22/12 Attempt BOP test and determine end of pipe and downcomer frozen. Apply heat and RIH to thaw, POOH. Complete weekly BOP Test. RIH with venturi and jet down to 10700' with very little resistance. When at surface only 1/4 cup of pea sized cement chunks and metal shavings returned. Make /RIH w/ Jetting BHA with a 2.5" DJN. RIH in progress. 11/23/12 RIH w/ 2.5" DJ nozzle. Dry tag @ 10715' (up ctm). Jet 41 10' bites w/ 50',_ up short trips to 1086', past set depth of IBP Circulate bottoms up/ chase into 3.5 'tubing. RIH for dry tag to 11002'. Flag CT @ 10098', 20' above tag. Jet pert interval from 10600'- 10800' @ 1200,1400 and 1600 psi WHP. No injectivity_- established. Continue cleaning out with freshwater unitl non jettable tag found at 11077, 11071 PU. Believe to be fishing neck. Still no Injectivity. POOH. MU /RIH w/ jars, hyd centralizer and hyd JD overshot. 11/24/12 RIH w/ jars, hyd centralizer and hyd JDC. Dry tag fish @ 11075'. PU was heavy. Pull to tail. No indication at tail. continue out of hole to inspect BHA. No fish. Inspect BHA, Run back in hole w/ same fishing BHA (jars, hyd centralizer and 2.71" skirt hyd JDC). Ran in to latch fish while pumping to centralize. Came to surface and no fish and some of the centralizer bows were broken. Removed centralizer so that the tool would stay on the low side and ran in. Tried to latch fish while pumping and pushed fish from 11077 to 11087 and then had a chunky pickup with pump of. Ran back in to retag and only made it to 11085. POOH. No fish. RDMO. * * * ** Note: IBP has fallen /been pushed down hole to 11085'- 11087'. Hole has i t. been rolled to meth /wtr top to bottom. 1400 psi on WHP. Do not underbalance to avoid hydrate formation. 11/29/12 RAN 2.5" LIB.S /D @ 11076' SLM.RECOVERED NO IMPRESSION. RAN 2 1/8" EQZ SUB.S /D @ 11073' SLM.UNABLE TO LATCH, SUB PACKED FULL OF CHUNKY /ROCKY CEMENT W/ METAL SLIVERS. RAN 2.25" X 5' DRIVE DOWN BAILER.S /D @ 11073' SLM.RECOVERED CHUNKY/ ROCKY CEMENT. 11/30/12 MADE SEVERAL BAILER RUNS W/ 2.25" DRIVE DOWN.S /D @ 11073' SLM, RECOVER CHUNKY /ROCKY CEMENT. ATTEMPTED PULLING IBP.S /D @ 11073' SLM.UNABLE TO LATCH.PULLING TOOL PLUGGED OFF W/ CEMENT. 12/22/12 Finish rig up CTU. Make up Venturi basket BHA and RIH. Made 2 runs with venturi basket with fines and cement chunks recovered. Continue running venturi until clean. 12/23/12 Complete 3rd venturi with heavy schmoo and small cement chunks. Make up jetting BHA with 2.5" JSN and perform hot diesel wash of tubing to 11035'. Perform weekly BOP test. Standby for weather. 12/24/12 End of weather standby. RIH with venturi and attempt to suck up debris. Returned with small chunks of cement but no schmoo. Re- running venturi. Page 2 of 3 • • MPE -03, Well History (Post Rig Workover) Date Summary 12/25/12 Complete Venturi run, returned small 2 -4 golf ball sized chunks of cement though finger cages were packed off by marble sized chunks. Re -run venturi though same returns as before with some large chunks and packed off finger cages. Swapped out to sprung flutter style cages and re -run. 3rd run recovered 1 golf ball size cement chunk along with a cup of fines. Make up venturi basket w/o extra barrel and re -run. 12/26/12 Completed venturi run and had 3 -4 cups of small pea to quarter size cement chunks though a large egg size chunk got stuck between the flutter cages and packed off with fines. Re -run venturi with only one flutter cage, got back the same fines and chunks no apparent signs of IBP fish neck contact on bottom of shoe. spoke with pad engineer and will run venturi with burn shoe on bottom, milled 15' 11071'- 11086' ctm. Returned full of pea and quarter sized cement chunks. Re -ran and had initial tag at 11091' and made it down to 11100' when pumping without any stalls or hard set downs. 12/27/12 Job Objective: Pull IBP. Pull to surface with Venturi. Returned 10 -12 silver dollar sized and 2 -3 cups pea sized. Re running venturi. Initial dry tag at 11110', made hole to 11120' before increase motor work and weight set down. Reciprocate across interval and POOH. Recovered 6 -8 silver dollar size chunks and 2 -3 cups of fines, Re running venturi. 4 big chunks and a bunch of fines with metal shavings and one piece of metal 1.5" x 2.5" x 1/8 ". 12/28/12 CTU #9 1.75" w/ CT. Job Scope: Venturi to top of IBP, Fish IBP. RIH w/ Venturi w/ 2.63" barrel. Lightly tagged at 11,131'CTM. Sucked down to 11,141'CTM. POOH. Recovered 1.5 gal of salt/cement mixture. RIH w/ same Venturi. Circulate 80 bbls of 150*FW on top of IBP /Fill /Salt to dissolve salt. Venturi above IBP while reciprocating for 37 bbls w/ 1% Slick KCI. POOH. Recovered —2 cups of fine cement. RIH w/ 2.63" Venturi and 2.375" PDS GR /CCL in carrier. Tag at 11,143'CTM. Venturi on top of IBP, surging pump and reciprocating. Perform inj test at 1325 psi, lost 50 psi in 15 min. Took 0.1 bbls to pressure back up to 1325 psi. Paint yellow flag and log up from 11,143' to 9,950'CTM at 40 fpm. -4' correctionat surface. MU BOT fishing assembly with JDC and RIH. Freeze protect well. 12/29/12 Corrected depth shows a tag of 11152' MD. Attempted to latch IBP several times and ways with no indication of latching. POOH. No fish. RDMO. 01/02/13 S/D W/ 2.25" LIB @ 11139' SLM, IMPRESSION OF TRASH & FILL. BAILING FILL FROM TOP OF IBP (MILLINGS & CEMENT CHUNKS). RAN 3.68" CENT, T.E.L., 2.5" LIB. LOC TT @ 10190' SLM/10196' MD. SD @ 11154' MD. NO IMPRESSION OF IBP. WILL LEAVE IBP IN WELL. Page 3 of 3 • • �, r r .� ), E SEAN PARNELL, GOVERNOR Li Ifi ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1rIISSIOIIT ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader 0 1 BP Exploration (Alaska), Inc. ' 9 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Kuparuk River Pool, MPE -03 Sundry Number: 312 -049 Dear Mr. Reem: ` , ) LL) `tX °L 1 . Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, rr Daniel T. Seamount, Jr. 71‹, Chair DATED this ) day of February, 2012. Encl. STATE OF ALASKA ' ON c4,-3-1A A /ALASKA IL AND GAS CONSERVATION COMMIS RECEIVED a, � APPLICATION FOR SUNDRY APPR9VAL 20 AAC 25.280 FEB 0 2 2012 1. Type of Request: 1 ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool • ® Repair Well ❑ Oh -, g o R�� gs. Commission ❑ Suspend ❑ Plug Perforations ❑ Perforate •® Pull Tubing ❑ Timet x(ension Anchorage ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ (other _ _ _ L 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 189 - 017 3. Address: • ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 21916 - 00 - 00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPE -03 - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 025518 & 047437 Milne Point / Kuparuk River' 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): 11520' - 7234' - 11241' 7087' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 13/3/8" 110' 110' 1670 670 Surface 6679' 9 -5/8" 6679' 4655' 6870 4760 Intermediate Production 11375' 7" 11375' 7158' 8160 7020 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10740' - 11212' 6828' - 7072' 2 -7/8 ", 6.5# L -80 10164' Packers and SSSV Type: OTIS HCM Permanent Packer Packers and SSSV 10109' / 6483' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development - 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 15, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas _ _1 GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564 -4387 Printed Name avid Re Title Engineering Team Leader Signature C Phone 564 -5743 Date 2_ Prepared By Name /Number: 2_2_0)2 Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval: Notify Commission that a representative may witness 2 �"C G �/ Sundry Number: ❑ Plug Integrity L� BOP Test E Mechanical Integrity Test ❑ Location Clearance *- cf0010 /QS is /p/ Ic.s Other: 4 / _ _ C-•�. if ZSoo �° S' n w - � * Art-.,-......A_ p - `. L. Agfa prav- 1 /2e-c.. 2 -4 9 /44c- ZS": t in - CO Subsequent Form Required: it Approved By: , p 1 12 APPROVED BY Z /2 J qf COMMISSIONER THE COMMISSION Date �/ / Form 10-403 - ev -d 11/2010 vD�� rCp 2 1 1L Submit In Duplicate w"ve4tel Og1G1NAL upli , • • , ,' by pik MPE -03i Expense Rig Workover Well Objective: 1) Decomplete existing 2 -7/8" main string and 1 -1/4" side string 2) Cement OA to prevent external gas entry 3) Tubing leak repair 4) Run 3 -1/2" gas injection string. Well History: MPE -03i is a gas injector that was drilled and completed in August 1989. Gas injection into the Kuparuk A sands began in September 1989. In January 1993, the well injectivity began to decline, so the C and B sands were perforated in early 1994. An outer annulus pressure of 1580 psi was recorded in March 1998. In order to investigate the high OA pressure, a sampling and monitoring program was performed. The results of the program indicated that there was not communication between the IA and OA, and the source of the high OA pressure was from another source. With the OA pressure maintained below the limit of 1000 psig, the well was allowed to operate under an Administrative Approval. In May 2011, MPE -03i began exhibiting signs of TxIA communication. A leak detection log run in June was unable to locate the leak. MITs on the tubing and IA passed indicating that the tubing will hold fluid but Teaks to gas. A tubing tail plug was set to secure the well in late June 2011. The intent of the RWO is to restore well integrity by fixing the OA and TxIA leak and resuming gas injection in the current well location. MASP: 3,400 psi Well Type: Gas Injector Estimated Start Date: May 15 2012 Pad Engineer: Jessie Chmielowski 564 -5015 Intervention Engineer: Sean McLaughlin 564 -4387 Pre -Riq Work Request: S 1 SBHPS W 2 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. S 4 Pull PXN plug; SBHPS within -20 days of rig arrival F 2 Place sized salt pill with -50' c cap in the 7" liner across existing perforations. ✓ Swap the tubing to KWF with diesel cap. MIT -T to 1,000 psi to test salt/cement plug. MIT -IA to 4000 psi. MIT -OA to 2,000 psi. LLR if any fail. Well Tx IA to gas, not liquid. S 3 Drift for 2 -7/8" jet cutter, reset PXN plug. E 6 Jet cut the 2 -7/8" tubing at -10,070' which is 10' from the top of the first full joint above the packer (based on tubing tally dated 8/5/89). We want a 20' stub looking up. F 7 Circulate the well with KWF and place a diesel freeze protect cap on top to protect surface equipment. CMIT TxIA to 1000 psi to ensure post jet cut integrity. O 9 Remove the wellhouse & flow line. Level the pad as needed for the rig. • Proposed Procedure 1. MIRU. Install TWC in main string. Nipple down tree and adapter flange. Install 1" CSH plug for side string. 2. NU 4 preventer BOP consisting of annular, 2 -7/8" x 5" VBR, blind shear rams, flow cross and 2 -7/8" x 5" VBR. Pressure test BOPE to 4,000 psi high / 250psi low with 2 -7/8" and 4" test joints. Test the annular to 3,500 psi with a 2 -7/8" test joint. 3. Pull and lay down 1 -1/4" CSH side string. There are no BOP rams for the side string. The barriers will include cement cap, PXN plug, tested IA, and KWF. 4. Pull and lay down 2 -7/8" main string to the cut. 5. Recover existing 7" Otis permanent packer. 6. RU a -line and run USIT to the top of the cement plug to determine cement quality at packer depth and TOC in the 7" annulus. / 7. Set 7" retrievable bridge plug -100' below top of cement. Test RBP to 4500 psi. 8. Swap top set of 2 -7/8" x 5" VBR's to 7" casing rams. Test to 4000 psi. 9. Cut and pull the 7" production casing. 10. Dress casing stub. Run and fully cement 7 ", 26 #, L -80, VamTop HC casing with ECP, ES cementer and casing patch to surface. 11. Install new tubing spool. 12. Swap 7" casing rams to 2 -7/8" x 5" VRB's. Test to 4000 psi. 13. Drill out shoe track, MIT -IA to 4500 psi, and retrieve 7" RBP. 14. Drill out cement cap. 15. Run 3 -1/2 ", 9.2# L -80, TC -II injection completion wit packer at 10,100'. o Request varience from 20 AAC 25.412 (b) - th d2 i will be more than 200' above - top perforation o Planned packer depth of 10,100' is 640' above top perforation o 352' above approved injection interval top o 9' above existing packer depth. o The WLEG will be 232' above the approved injection interval top and will facilitate future well operations (logging and perforating). o The casing above 10,100' has been tested and is known to be good. The formation between the Kuparuk and injection paker is the Kalubik Shale. 16. Displace the IA to packer fluid and freeze protect. 17. Set and test the packer to 4,500 psi. AOGCC slope rep will be notified 24 hrs prior to test. 18. Set TWC. ND BOPE. NU and test tree. RDMO. L _ + �, 1141 4416,c Post -rise work: S 1 Pull Ball -n -Rod, pull RHC seat. C 2 Cleanout salt plug S 3 Run WR -SSSV • • b MPE -O3i Expense Rig Workover Well Objective: 1) Decomplete existing 2 -7/8" main string and 1 -1/4" side string 2) Cement OA to prevent external gas entry 3) Tubing leak repair 4) Run 3 -1/2" gas injection string. MASP: 3,400 psi • Well Type: Gas Injector Estimated Start Date: April 15 2012 Pad Engineer: Jessie Chmielowski r -* Intervention Engineer: Sean McLaughlin SU Pre -Riq Work Request: S 1 SBHPS - as soon as possible W 2 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. S 3 Drift for 2 -7/8" jet cutter. S 4 SBHPS within -20 days of rig arrival, reset PXN plug, dump sluggits, install junk catcher. F 5 MIT -T to 4,000 psi to test PXN plug. MIT -IA to 4,000psi. Well leaks gas T x IA, not liquid. ✓ E 6 Jet cut the 2 -7/8" tubing at - 10,070' which is 10' from the top of the first full joint above the packer (based on tubing tally dated 8/5/89). We want a 20' stub looking up. F 7 Circulate the well with KWF and place a diesel freeze protect cap on top to protect surface equipment. CMIT TxIA to 1000 psi. O 9 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. Install TWC in main string. Nipple down tree and adapter flange. Install 1" CSH plug for side string. 2. NU 4 preventer BOP consisting of annular, 2 -7/8" x 5" VBR, blind shear rams, flow cross and 2 -7/8" x 5" VBR. Pressure test BOPE to 4,000 psi high / 250psi low. Test the annular to 3,500 psi. 3. Pull and lay down 1 -1/4" CSH side string. Nd R4K S 4. Pull and lay down 2 -7/8" main string to the cut. 5. RU a -line and run USIT in the 7" casing to determine TOC in the 7" annulus.. 6. Set 7" retrievable bridge plug -100' below top of cement. Test RBP to 4500 psi. . I) 1') 7. Cut and pull the 7" production casing. Noe: - ipe-ramswviit -not -be- shanged-to - 7 - as - the wen nas two tested b i,:-- r/o RitM.s 7`' 4 1 Z) 4/3 P 8. Dress casing stub. Run and fully cement 7 ", 26#, L- 0, VamTop HC casing with ECP, ES cementer and casing 3) ku, patch to surface. MIT -IA to 4500 psi. 9. Install new tubing spool 10. Drill out shoe track and retrieve 7" RBP. 11. Run a 7" casing scraper to proposed packer setting depth and dress tubing stub. 12. Run 3 -1/2 ", 9.2# L -80, TC -II injection completion with packer and overshot. 13. Displace the IA to packer fluid and freeze protect. 14. Set and test the packer to 4,500 psi. AOGCC slope rep will be notified 24 hrs prior to test. 15. Set TWC. ND BOPE. NU and test tree. RDMO. �.� i cy Sr �4sT Post -rip work: S 1 Pull Ball -n -Rod, pull RHC seat. C 2 Retrieve Junk catcher and PXN plug S 3 Run WR -SSSV FLOOR ELEVATION 25' -6" AGL Drilling Mode VALVE LEGEND BYPASS � C IZOZ� 02 KILL Three Rams : �� T, �� l 30 CHOKE 13 5/8 ", 5000 PSI, HYDRIL ANNULAR BOP, �Q� ©�Q�� ©��Q�O�� STUDDED TOP /FLANGED BOTTOM 40 LOW PIPE RAMS ii L i i i 50 SHEAR RAMS ` �� ■ ©TOP PIPE RAMS a i A 07 ANNULAR 11111111111TH 1111 1 1 1 ■ _ - -- FLANGED TOP B% 160 ACCUMULATOR: KOOMEY TYPE 80, 180 GAL 7 / � y x S TRIPI FX PUMP: 575 VAC, 30 HP n Q 13 5/8", 5000 PSI, 10" MPL OPERATORS, AIR PUMP: 3 e0. KOOMEY y63^ HYDRIL PIPE RAM • 3 1/8" 5000 P51 SIDE OUTLET 3" CHOKE UNE •41 O lim• 13 5/8 ", 500 PSI, 14" MPL RAM OPERATORS, STUDDED BOTTOM BX 160 O 0 O • - 3 1/8" 5000 PSI HCR VALVE ■�► ■II,/,III, /III�II"II' /II 2" KILL UNE 1 1 111111 ' V 3 1 / 8" 5000 PSI HCR VALVE / 3 1 / 8" 5000 PSI GATE VALVE 3 1/8" 5000 PSI GATE VALVE 1 � Fl.ANGED TOP BX 160 Do- SINGLE 13 5/8 ", 5000 PSI, 10" MPL OPERATORS, « _ VIA STUDDED BOTTOM 0 • LL itki ADAPTER SPOOL cHOlBOP STACK • WELLHEAD ("I 1 >11 ACCUMULATOR MANIFOLD 20 BOTTLES, 10 GALLONS EACH ; Li BOP STACK ELEVATION REMOTE PANEL IN DOGHOUSE AND UTILITY MODULE • .101. hod NITROGEN BACKUP BOTTLES 21 1/4". 2000 P51, 5 EACH TT• , • m1w 1r 16' 150 P51 MR. MSP HRDRIL BOP /OPIORIER P1sa1T s tERIIS.IE par r X11101® ■ OPERATED KNIFE GATE VALVE STUDDED TOP /FINKED BOTTOM May � FIAHGE/FIAHGE R% 7J 16' FLC'0 VENT UNE, SCH 80 O PROEM RIG 16 7/1/10 0 LEA AM SHEARS ' DRILLING MODE BOP SYSTEM • • 12_20 -00 2 On LEA UPDATE BCP 51 AND CONTROLS SURFACE DIVERTER CONFIGURATION 11 -25-9E q CH LEA pPN1110 WOW 01 /1/10 amp • TwnorFO BY 2 °NE Ap,' ear I5Vrt YESDAPIION A NTS 019131 0113. R1 6BOPSYS&CONTROL 1 C,�tlLj • • MPU E -03i 110' 13 -3/8" 46 # /ft H -40 I I FMC TUBING HANGER W/ 3" 'H' BPV PROFILE NOTES: .04 2 718" 6.5 # /FT L -80 CS HYDRIL (2.441' ID, 2.347" DRIFT) 1. ALL MEASUREMENTS ARE FROM KDB OF PARKER RIG 141 1.125" 2.5 # /FT CS HYDRIL SIDE STRING KDB -SL = 54' KDB -GL = 30' s -411111— 526' OTIS FMX 2 7/8" SCSSV 2. MAX. ANGLE = 60' 6500' Note: The TRSV is locked out and a WLRSV is set in the nipple. 3. K.O.P. = 1100' Run oversize o - rings on safety valve. 91QV117 - H HES SAP# 100006558 4. SLANT HOLE: YES 4 1 2057' END OF TUBING 5. TREE TYPE: FMC 3 1 /8" API 5000# WITH 2 7/8" 8rd TREETOP CONNECTION Well required to have a SSSV installed. 6. MIN. RESTRICTION IS OTIS XN NIPPLE (2.205" ID) 7. COMPLETION FLUID: 9.6 PPG NaCL BRINE , , 6679' 9 -5/8" 47 # /ft L -80 PERFORATIONS: 6 SPF AT 0' PHASING, 2 1 /8" DYNASTRIP 11,096'- 11,130' MD 7009'- 7027" TVD / \ 11,150'- 11,208' MD 7038' -7067' TVD 1 — OTIS SBR OVERSHOT /J -SUB ASSEMBLY 4 SPF AT 90' PHASING 11,288' - 11280' MD 10,109' OTIS (2 HO PERMANENT 7109' -7111' TVD PACKER "I D) (SQUEEZED WITH CEMENT) 10, 156' 2 7/8" OTIS XN NO- GO NIPPLE (2.205" ID) PERFORATIONS ADDED_ 10,164' 3 1/2" OTIS RH CATCHER SUB 4 -19 -94 10,165' TUBING TAIL A SANDS 6 SPF @ 0 DEGREES PHASING 11100'- 11130' MD 10,707' CASING RA MARKER 1 — 11154'- 11212' MD C- SANDS 4 SPF @ 0 DEGREES PHASING — p ` 10740'- 10756' MD 11,241' 7" EZSV T - ` PERFORATIONS ADDED 7 -3 -94 11,375' 7 ", 29 LB /FT L -80 BTRS (6.184" ID, B -SANDS 6.059" DRIFT) 10768 -10796 RKB MD 4 SPF, 0 DEGREES PHASING, 100 SHOTS TOTAL DATE REV.. BY COMMENTS MILNE POINT UNIT 8/5/89 DBR /DMR INITIAL COMPLETION WELL E -03 7/1/95 DBR /DMR CONVERT TO MAC DIAGRAM API NO: 50-029-21916 11/20/03 MAS Add 9 -5/8" & Surface Casing to Diagram BP EXPLORATION (AK) • MPU E -03i Casin;epair 110' 13 -3/8" 46 #/ft H -40 ( FMC TUBING HANGER W/ 3 " 'H' BPV PROFILE NOTES: 1_ ALL MEASUREMENTS ARE FROM KDB OF PARKER RIG 141 KDB -SL = 54' Cement OA to surface KDB -GL = 30' 2. MAX. ANGLE = 60' @ 6500' 7 ", 26 #, L -80 VamTop HC 3. K.O.P. = 1100' 4. SLANT HOLE: YES HES ES- Cementer 5. TREE TYPE: FMC 3 1/8" API 5000# Z --- Baker External Casing Packer WITH 2 7/8" 8rd TREETOP CONNECTION 'b Bowen 7" Casing Patch 6. MIN. RESTRICTION IS OTIS XN NIPPLE (2.205" ID) 7. COMPLETION FLUID 9.6 PPG NaCL BRINE Cement expected 1950' to 3000', confirm with USIT log; cut casing Well required to have a sssv -100' above top of cement installed. ■— 6679' 9 -5/8" 47 #/ft L -80 Set 7" RBP -100' below top of logged cement PERFORATIONS: 6 SPF AT 0' PHASING, 2 1/8" DYNASTRIP 11,096'- 11,130' MD 7009'- 7027" TVD 11,150'- 11,208' MD 7038' -7067' TVD 4 SPF AT 90' PHASING 11,288' - 11280' MD 7109' -7111' TVD —50' cement cap @- 10650' (SQUEEZED WITH CEMENT) -- Top Perforation - 10740' PERFORATIONS ADDED 4 -19 -94 – Sized salt plug A SANDS 6 SPF @ 0 DEGREES PHASING 11100'- 11130' MD 11,241' 7" EZSV 11154'- 11212' MD C- SANDS 4 SPF @ 0 DEGREES PHASING 10740' - 10756' MD 11,375' 7 ", 29 LB /FT L -80 BTRS (6.184" ID, 6.059" DRIFT) PERFORATIONS ADDED 7 -3 -94 4 B -SANDS 10768 -10796 RKB MD 4 SPF, 0 DEGREES PHASING, 100 SHOTS TOTAL DATE REV. BY COMMENTS MILNE POINT UNIT 8/5/89 DBR /DMR INITIAL COMPLETION WELL E-03 7/1/95 DBR /DMR CONVERT TO MAC DIAGRAM API NO: 50-029 -21916 11/20/03 MAS Add 9 -5/8" & Surface Casing to Diagram BP EXPLORATION (AK) • MPU E -03i Propo 110' 13 -3/8" 46 #/ft H -40 1 MC TUBING HANGER W/ 3" 'H' BPV PROFILE NOTES: 1. ALL MEASUREMENTS ARE FROM KDB OF PARKER RIG 141 [ KDB -SL = 54 ' control line KDB -GL = 30' 0 V` surface controlled, wireline 2. MAX. ANGLE = 60' @ 6500' retrievable safety valve —600' 3. K.O.P. = 1100' Cement OA to surface 4. SLANT HOLE: YES 7 ", 26 #, L -80 VamTop HC 5. TREE TYPE: FMC 3 1/8" API 5000# = HES ES- Cementer WITH 2 7/8" 8rd TREETOP CONNECTION X X Baker External Casing Packer 6. MIN. RESTRICTION IS OTIS XN NIPPLE 1 .--- Bowen 7" Casing Patch (2.205" ID) 7. COMPLETION FLUID: 9.6 PPG NaCL BRINE Well required to have a SSSV installed. -- 3 -1/2" 9.2 #, L -80 TC -II 4 ■ 6679' 9 -5/8" 47 # /ft L -80 ID - 8.681" Drift - 8.525" . Annular cement will be logged with USIT prior to setting packer. Casing will need to be tested prior to setting packer as set depth is lower than present depth. 3 -1/2" X Nipple ID= 2.813" 3 -1/2" x 7" HES TNT L -80 Packer —10100' 3 -1/2" X Nipple ID= 2.813" PERFORATIONS: 3 -1/2" XN Nipple ID= 2.75" 6 SPF AT 0' PHASING, 2 1/8" DYNASTRIP WLEG ✓10,220' 11,096'- 11,130' MD - 7009'- 7027" TVD 11,150'- 11,208' MD 7038' -7067' TVD - Approved injection interval top @10,452' 4 SPF AT 90' PHASING 11,288'- 11280' MD 7109' -7111' TVD (SQUEEZED WITH CEMENT) — — — Top Perforation - 10740' PERFORATIONS ADDED 4 -19 -94 — - Sized salt plug A SANDS 6 SPF @ 0 DEGREES PHASING 11100' - 11130' MD , 1 11,241' 7" EZSV 11154'- 11212' MD C- SANDS 4 SPF @ 0 DEGREES PHASING 10740'- 10756' MD 11,375' 7 ", 29 LB /FT L -80 BTRS (6.184" ID, 6.059" DRIFT) PERFORATIONS ADDED 7 -3 -94 B -SANDS 10768 -10796 RKB MD 4 SPF, 0 DEGREES PHASING, 100 SHOTS TOTAL DATE EV. BY COMMENTS MILNE POINT UNIT 8/5/89 DBR /DMR INITIAL COMPLETION WELL E -03 7/1/95 DBR /DMR CONVERT TO MAC DIAGRAM API NO: 50- 029 -21916 11/20/03 MAS Add 9 -5/8" & Surface Casing to Diagram BP EXPLORATION (AK) Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, February 14, 2012 9:32 AM To: 'McLaughlin, Sean M' Subject: RE: revised MPE -03i documents (PTD 289 -017) Sean, New procedure looks fine. If USIT shows anything questionable call me right away. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Tuesday, February 14, 2012 8:51 AM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L Subject: revised MPE -03i documents Guy, As discussed we will plan to remove the existing packer and add 7" casing rams prior to pulling casing. I have requested a variance to set the new packer -10' above the existing packer because that casing has already been tested. We'II confirm what the cement picture looks like behind casing when we run the USIT. Regards, sean Sean McLaughlin RWO Engineer 564 -4387 Office 223 -6784 CeII 2/14/2012 Page 1 of 2 • • Schwartz, Guy L (DOA) From: McLaughlin, Sean M [Sean.McLaughlin ©bp.com] Sent: Wednesday, February 08, 2012 8:07 AM To: Schwartz, Guy L (DOA) Subject: RE: MPE -03i ( PTD 189 -017) Okay, I see where the disconnect is, I agree with have hydraulic isolation from the open hole. If there is not isolation from the open hole then the drilling regulations would apply. I see now that that my pre -rig work I sent you doesn't have a MIT -OA on it. It should have. If there is a passing OA test showing hydraulic isolation would that allow the commission waive the need for rams. The second barrier would be the KWF circulated to the OA once the casing is cut. This hole section was TD'd with 8.7 ppg mud and we will have -11.7 ppg mud. The 4 preventer stack does make it easier to add 7" rams but we would still need to open the stack to add them then swap back to VBR's when finished with the casing repair. sean From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, February 07, 2012 1:47 PM To: McLaughlin, Sean M Subject: RE: MPE -03i ( PTD 189 -017) Sean, 1) I was thinking the same thing with the 1 %4" CSH... there really aren't BOP rams out there for that size. CTD has the same issue when they are running TCP guns or memory tools and need drill pipe for ID restrictions. 2) As far as the 7" casing rams I looked closer at the regulations. Drilling regulations state full Ram coverage if you are exposed to the OH as per 20 AAC 25.035(e) In this case you have zonal isolation from the reservoir but not hydraulic isolation from OH. In any case since you have two sets of rams one could be set up for 7" rams .. the other VBR's. I know in the past we have approved some RWO's where we didn't require Ram coverage .. I will be try to be consistent and reasonable when the regulations are not crystal clear. 20 AAC 25.285 doesn't address this specifically so I have fallen back to 20 AAC 25.035. 3) As far as the annular cement distance above the packer... that is strictly an internal guideline. By regulation there should be 500' of cement above any hydrocarbon zone so if the packer is 200' above a zone that leaves 300' of cement above the packer. It is always very much preferred to have the annulus behind a packer cemented to insure that the casing below the packer is fully supported (sees 100% injection pressure) and is less likely to leak uncontrolled out of zone... such as a casing thread leak just below the packer and above the injection zone. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: McLaughlin, Sean M [mailto:Sean.McLaughlin @bp.com] Sent: Tuesday, February 07, 2012 11:17 AM To: Schwartz, Guy L (DOA) Subject: RE: MPE -03i ( PTD 189 -017) Guy, 2/8/2012 Page 2 of 2 • • 1) Yes, the 1 -1/4" CSH will be pulled before the tubing. There will not be ram coverage while pulling the 2000' x 1 -1/4" side string as they do not exist. Our barriers will be a tested plug in the tubing tail and KWF in which the fluid level is monitored. We will get a 2nd BHP reading —20 days prior to the RWO to see if the BHP is building. The last resort will be the blind /shears. As near as I can tell (drilling records are slim) we are pulling the completion the same way it went in. 2) I am a bit confused by the requirement to install 7" rams. Historically, two internal barriers to the reservoir were sufficient along with the logged annular cement. I took look at wells X -22, NGI -14, 12 -04, 12 -29, and P1 -07 to make sure the plan for MPE -03 was consistent. The cement in the annulus was not thought of as a barrier but as zonal isolation. The plan is to cut the 7" casing above the logged cement in the surface casing. Records show 26 bbls of cement was down squeezed in the OA in 9/89. The OA also passed a MIT in 12/04 indicating cement is present in the 7" x 9 -5/8" annulus. However, if there is no cement found in the surface casing (shoe at 6679') we will plan to cut —50' above the shoe. I believe in this case it would be prudent to install a set of casing rams. Can we discuss some more? 3) Good point about the 200' rule and needing the variance. I'll pull some more reservoir information together. We will use the planned USIT log data to verify annular cement. Can you tell me where the requirement for 300' of cement above the packer comes from? I don't see it in the Regulations. Regards, sean From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, February 06, 2012 12:36 PM To: McLaughlin, Sean M Subject: MPE -03i ( PTD 189 -017) Sean, I am reviewing the sundry to the RWO on MPE -03i. I have a few questions /comments: 1) The 1 %4 CSH string will be pulled before the tubing. Is there Ram coverage for this string or are you relying on Shears to cut if needed? 2) When pulling and running the 7" casing the Commission will require 7" rams to be installed. Once casing is cut you are down to one barrier.. the cement in the annulus. 3) Although the original packer was more than 200' above the injection perfs... you are moving up hole even more with the stacker packer. Please request a variance from 20 AAC 25.412 (b) and also verify that cement is at least 300' above the new packer set depth. You can either use an old CBL or use the USIT log you are running to verify the cement. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 2/8/2012 June 2011 AOGCC MIT Forms • Page 1 of 2 Re James B DOA � sy 01 9J, (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @ bp.com] Sent: Wednesday, July 13, 2011 6:07 PM ?D 7 / 4 / it To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: RE: June 2011 AOGCC MIT Forms Hi Jim, The MIT -IA conducted 06/10/2011 on MPU E -03 (PTD #1890170) was for diagnostic purposes due to suspected TxIA communication. Although this well passed the MIT -IA, it continued to exhibit IA repressurization. At this time, this well is shut in and secured and we are actively progressing a Rig Workover to restore integrity to the well. Please let me know if you have any further questions. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 :,;,‘ J 4- Ai JUL 1 t? 2O1 Email: AKDCWeIIlntegrityCoordinator @BP.com From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, July 12, 2011 3:30 PM To: AK, D &C Well Integrity Coordinator Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: RE: June 2011 AOGCC MIT Forms MPU E -03 (PTD 1890170) - does not appear this was tested per AIO 10B.006 (1.2 times max well (injection) pressure); required test pressure is at least 4560psi (3800psi x1.2) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIlntegrityCoordinator @bp.com] Sent: Sunday, July 03, 2011 3:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: June 2011 AOGCC MIT Forms 7/14/2011 June 2011 AOGCC MIT Forms Page 2 of 2 • Tom, Jim, and Phoebe, Please find attached AOGCC MIT forms for the following wells: NK -23 (PTD # 1940350) LGI -10 (PTD # 1860690) W -11 (PTD # 1891070) P2 -09 (PTD #1980660) M -18B (PTD #1930540) W -210 (PTD # 2061850) P2 -15A (PTD # 2070320) M -28 (PTD #1860740) Z -12 (PTD #1891020) MPE -03 (PTD #1890170) R -13 (PTD #1830440) MPS -04 (PTD # 2030520) x 2 R -32A (PTD #1980090) 13 -09 (PTD # 1811580) S -06 (PTD #1821650) E -103 (PTD #2012000) V -121 (PTD # 2070360) LGI -02 (PTD # 1861400) x 2 V -215 (PTD #2070410) «June 2011 MIT Forms.zip» Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/14/2011 June 2011 AOGCC MIT Forms • Page 1 of 1 • Regg, James B (DOA) From: Regg, James B (DOA) PT b/ S 1 --c)t Sent: Tuesday, July 12, 2011 3:30 PM 7 //e1// To: 'AK, D &C Well Integrity Coordinator' Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: RE: June 2011 AOGCC MIT Forms MPU E -03 (PTD 1890170) - does not appear this was tested per AIO 10B.006 (1.2 times max well (injection) pressure); required test pressure is at least 4560psi (3800psi x1.2) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 =1 , 'tt JUL 1 4. L U From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Sunday, July 03, 2011 3:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: June 2011 AOGCC MIT Forms Tom, Jim, and Phoebe, Please find attached AOGCC MIT forms for the following wells: NK -23 (PTD # 1940350) LGI -10 (PTD # 1860690) W -11 (PTD # 1891070) P2 -09 (PTD #1980660 M -186 (PTD #1930540 (PTD TD # 20 18 6 5 0 4 P2 -15A (PTD # 2070320) M -28 (PTD #1860740) Z -12 ( PTD #1891020) MPE -03 (PTD #1890170) R -13 (PTD #1830440) MPS -04 (PTD # 2030520) x 2 R -32A (PTD #1980090) 13 -09 (PTD # 1811580) S -06 (PTD #1821650) E -103 (PTD #2012000) V -121 (PTD # 2070360) LGI -02 (PTD # 1861400) x 2 V -215 (PTD #2070410) «June 2011 MIT Forms.zip» Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/12/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rega ialaska.gov; doa .aoocc.prudhoe.bayAalaska.gov; phoebe.brooks(oaalaska.00v; tom.maunderaalaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Milne Point / MPU / E Pad f et T'1 ZJI DATE: 06/10/11 OPERATOR REP: Jeff Rea AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPE -03 Type Inj. G TVD 6,483' Tubing 3800 3800 3800 3800 Interval 0 P.T.D. 1890170 Type test P Test psi '1620.75 Casing 1177 4303 4169 4135 P/F P Notes: MIT -IA for suspected TxIA communication OA 1050 1050 1060 1060 _ 7.3 bbls to pressurize to test pressure Well MPE -03 Type Inj. G TVD 6,483' Tubing 3,800 3,800 3,800 3,800 Interval 0 P.T.D. 1890170 Type test P Test psi 1620.75 Casing 4,135 4,313 4,294 4,288 P/F P Notes: Retest MIT -IA for suspected TxIA communication OA 1060 1060 1060 1060 0.2 bbls to pressurize to test pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test_ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) !1/4)(}Tf .r k--Te t tG -OQ 6 ret.tif r Z Ay_ press At4- p"ofes_ freSSta Form 10 -426 (Revised 06/2010) MIT MPU E - 03 06 10 11.xls NOT OPERABLE: Injector MPE -03 (PTD #1890170) Slow IA Repressurization Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, June 24, 2011 8:34 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Daniel, Ryan Cc: King, Whitney; Russell, James; McEntyre, Scott R Subject: NOT OPERABLE: Injector MPE -03 (PTD #1890170) Slow IA Repressurization Attachments: MPE -03 6- 24- 11.doc All, Injector MPE -03 (PTD #1890170) passed an MIT -IA to 4300 psi on 6/10/2011. However, the well continues to exhibit slow repressurization of the IA. A Tecwel LDL was run on 6/23/2011 in an attempt to locate the leak point, however no data has been recovered due to tool malfunction. At this time, the well is shut in and is being secured with a TTP until a plan forward is determined. The well has been reclassified as Not Operable and should remain shut in. Attached is an updated TIO plot for reference. «MPE -03 6- 24- 11.doc» Thank you, JUN 2 8 2.011 Mehreen Vazir t Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.6593102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent:. Friday, May 27, 2011 7:57 PM To: 'Mann. - , i omas E (DOA)'; 'Regg, James B (DOA); 'Schwartz, Guy L (DOA) ; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D: ireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Yeager, Kevin E Cc: King, Whitney; Russell, James Subject: UNDER EVALUATION: Injector MPE -03 (PTD #18' • IA Repressurization Post Bleed All, Injector MPE -03 (PTD #1890170) operates under Administrative Approval AIO 10:.:' • dated 03/12/2008 for OA repressurization from an external source. The IA and OA pressures were bled on 05/01/21 • . The initial bleed pressures were tubing /IA/OA = 3550/1450/760 and final bleed pressures were 3550/800/300. Fo • • • • this bleed there was a period of stablized IA pressure followed by IA repressurization which correlates to an increase 6/28/2011 • Injector MPE -03 (PTD #1890170) TIO Plot 06 -24 -2011 Wet. MPE-U 3 000 I 00 ±N OI DOU\ 0325n1 W /02Th O4, '11 0416/11 /CR3/11 34/ /11 09,0)/9 94 IE21 /Il f5/zall 04201/11 06/11/11 06 /16/it FW: UNDER EVALUATION: Injector MPE -03 (PTD #1890170) IA Repressurization P... Page 1 of 3 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, June 14, 2011 2:33 PM To: Maunder, Thomas E (DOA); AK, D &C Well Integrity Coordinator Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: UNDER EVALUATION: Injector MPE -03 (PTD #1890170) IA Repressurization Post Bleed Follow UP Tom, 1. When the IA was bled on 5/1/2011 and 5/26/2011, all gas was returned. 2. The short term plan forward will be to divert the gas to WAG injectors. Please let me know if you have further questions. Thanks, Mehreen From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, June 14, 2011 8:51 AM To: AK, D &C Well Integrity Coordinator Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: UNDER EVALUATION: Injector MPE -03 (PTD #1890170) IA Repressurization Post Bleed Follow UP Jerry, Thanks for the information. A couple of questions, 1. When the IA has been bled, what fluid is bled off? Based on the note on the MIT sheet, there appears to be some voidage given the volume of diesel necessary to pump up. 2. Where does the gas "go" when this well is not available? Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, June 14, 2011 7:36 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: FW: UNDER EVALUATION: Injector MPE -03 (PTD #1890170) IA Repressurization Post Bleed Follow UP All, This note is to update you on the current status of MPE -03 which is Under Evaluation. Injector MPE -03 (PTD #1890170) has continued to exhibited slow IA repressurization. The well passed a packoff test on both the tubing and inner casing hangar (PPPOT -T and PPPOT -IC) on 06/04/2011. The well passed a MIT -IA to 4300 psi on 06/10/2011. Plan forward: 1. Slickline: Secure well with downhole plug. 6/17/2011 FW: UNDER EVALUATION: Injector MPE -03 (PTD #1890170) IA Repressurization P... Page 2 of 3 2. E -line: Perform Leak Detect Log A copy of the TIO and Injection plot, and a copy of the MIT -IA performed are included for reference. «MPE -03 (PTD #1890170) TIO and Injection Plot.doc» «MIT MPU E -03 06- 10- 11.xls» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, May 27, 2011 7:57 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA) ; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, OPS MPU Control Room; Yeager, Kevin E Cc: King, Whitney; Russell, James Subject: UNDER EVALUATION: Injector MPE -03 (PTD #1890170) IA Repressurization Post Bleed All, Injector MPE -03 (PTD #1890170) operates under Administrative Approval AIO 108.006 dated 03/12/2008 for OA repressurization from an external source. The IA and OA pressures were bled on 05/01/2011. The initial bleed pressures were tubing /IA/OA = 3550/1450/760 and final bleed pressures were 3550/800/300. Following this bleed there was a period of stablized IA pressure followed by IA repressurization which correlates to an increase in injection pressure and temperature. On 05/26/2011 the IA and OA were bled again. The beginning bleed pressures were tubing / IA/OA = 3750/1340/1100 and final bleed pressures were 3750/300/480. A post -bleed monitor was done on 05/27/2011 and the pressures were tubing /IA/OA = 3790/520/740. Although significant increase in injection pressure or temperature is not apparent during the monitor period, influx on the OA from the external source would result in applied forces on the production casing which could be cause for increased pressure observed on the IA during the monitor. The well has been classified as Under Evaluation and will remain on injection while the IA pressure is monitored for post -bleed response during the next 10 -14 days. If the well exhibits IA repressurization a plan forward for diagnostics and mitigation will be submitted. A T /I /O Plot, Injection Plot, Wellbore Schematic, and AA are attached for reference. «MPE -03 TIO 05- 27- 11.doc» «MPE- 03.pdf» «MPE -03 AA Approval 03- 12- 08.pdf» Please let me know if you have any questions or concerns. Thank you, 6/17/2011 • • MPE -03 (PTD #1890170) TIO Plot WeH: MPE -03 4,000 3,000 - -t -- Tbg 2,000 - -- - OA ODA 1,000 - ''.'uMi~ 000A fit'*' On 03/19/11 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 05/14/11 05)21/11 05/28/11 06/04/11 06./11 ' MPE -03 (PTD #1890170) Injection Plot Wet NPE-03 '50G �- - -- - - - T - 4.000 - 3,500 V 3.000 - 3,000 £ - WHIP EL 2,500 0 - 2,500 0 - SW 2.00 2,000 -MI 1,500 - 1.500 q -- GI 1 000 - 1000 Other Suo - 500 - On 03/26/11 04/09/11 04/23/11 05/0711 05/21/11 06 /04 /11 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim gska.gov: doa .aogcc.prudhoe.bav(Dalaska.gov; phoebe.brooks(dwalaska.gov; tom.maunder(Dalaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Milne Point / MPU / E Pad DATE: 06/10/11 OPERATOR REP: Jeff Rea AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPE -03 Type Inj. G TVD 6,483' Tubing 3800 3800 3800 3800 Interval 0 P.T.D. 1890170 Type test P Test psi 162075 Casing 1177 4303 4169 4135 P/F P Notes: MIT -IA for suspected TxIA communication OA 1050 1050 1060 1060 _ 7.3 bbls to pressurize to test pressure Well MPE -03 Type Inj. G WD 6,483' Tubing 3,800 3,800 3,800 3,800 Interval O P.T.D. 1890170 Type test P Test psi 1620.75 Casing 4,135 4,313 4,294 4,288 P/F P Notes: Retest MIT -IA for suspected TxIA communication I OA 1060 1060 1060 1060 0.2 bbls to ressurize to test pressure - Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F _ Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA - TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 (Revised 06/2010) MIT MPU E-03 06 -10-11 (2).xls WELL LOG TRANSMITTAL PROACTIVE DIACINOSTic SERVICES, INC. i To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE: Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection {Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 -1 900 Benson Blvd. U a O C4 - G c9 3c, 9 Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. (} _ l 9 Qi _ �c�3C3d Attn: Robert A. Richey 130 West International Airport Ro Suite C Anchorage, AK 995180'(( Fax: (907) 245 -8952 JIM 1) Injection Profile 10Sep 10 MPU E-03 BL /EDE 50 -029- 21916 -00 2j Injection Profile 12 Aug-10 MPU C -42 BL/ EDE 2J� n i(1 Signed: Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W . INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)2454951 FAx: (907)245 -88952 E- MAIL : gdsanchorage@_memoryIoa.com WESSITE : www.memoryiog.com CADocuments and SeftbW\Diane Williams \Desktop \Ttansmit_SP.docx Regg, James B (DOA) From: Regg, James B (DOA) ~~~ ~ I ro Ii 0 Sent: Thursday, May 06, 2010 10:44 AM To: Jones, Jeffery B (DOA) Subject: RE: MPE-03 IPROF Review Request yes Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jones, Jeffery B (DOA) Sent: Tuesday, May 04, 2010 10:38 AM To: Regg, James B (DOA) Subject: FW: MPE-03 IPROF Review Request Jim, ~ FYI, is this OK with you? Jeff From: Jones, Jeffery B (DOA) Sent: Tuesday, May 04, 2010 7:20 AM To: 'AK, OPS MPU Well Ops Coord' Subject: RE: MPE-03 IPROF Review Request ~.~ ~~Ci Lee, The two successful witnessed tests you cite below will suffice to demonstrate a competent SSV & pilot for the proposed well work on MPF E-03. If you have any doubts about the SVS system competency please perform an SVS test. Thanks, Jeff Jones 659-2714 ~ From: AK, OPS MPU Well Ops Coord [mailto:AKOPSMPUWeIIOpsCoord@bp.com] Sent: Monday, May 03, 2010 7:52 PM To: AK, OPS MPU Well Ops Coord; Russell, James; Jones, Jeffery B (DOA) Cc: AK, OPS MPU Wells Ops Coord 2; AK, OPS MPU Field Ops TL Subject: RE: MPE-03 IPROF Review Request All, / I just got a message from Jeff Jones and he said he spoke with Jim Regg. Jim stated that with a competent and tested SSV (last tested 3/4/10) we do not need a man watch, if we are doing active well work for 15 days. This qualifies as active well work. If the SSSV is not back in place by the end of the 15 days we will need the variance to continue. Therefore, hold off on the variance request. Jeff, Is the last test date sufficient? The SSV passed on two testing dates (2/25 & 3/4, both witnessed) since the SSSV needed to be retested post putting the well on injection. Please advise. Lee Hulme MPU Wells Operations Coordinator • Page 1 of 3 5/6/2010 • Page 2 of 3 (907) 670-3387 Office (907) 670-3390 Fax • (Alternate: Rob Handy) From: AK, OPS MPU Well Ops Coord Sent: Monday, May 03, 2010 3:17 PM To: Russell, James Cc: AK, OPS MPU Wells Ops Coord 2 Subject: RE: MPE-03 IPROF Review Request See comments below. Also, I spoke with Jeff Jones of AOGCC fame and he advised us to submit a request for a variance with Jim Regg at AOGCC. He said that BP just did the same sort of job over in Lisburn Field which required the well to be put on injection for analysis with out the SSSV installed. Jeff said to describe the job, location of the pad (always visible -across the street from the camp) and to ask if it requires a man watch to perform the requested task. I will leave the request to you and your people since that is where they are usually initiated. Lee Hulme MPU Wells Operations Coordinator (907) 670-3387 Office (907) 670-3390 Fax (Alternate: Rob Handy) From: Russell, James Sent: Monday, May 03, 2010 11:05 AM To: AK, OPS MPU Well Ops Coord Subject: RE: MPE-03 IPROF Review Request Lee, Here is the procedure revised to heed your requests. A couple of changes: . I omitted any Shut-in periods, and assigned a manwatch. This omits the warmback passes shown at the bottom of the IPROF. This is unfortunate, but there is not much else we can do. . I combined the FB/SL steps, so it's kind of one big procedure with a "pause" in the middle to allow for the redress. I am happy as long as we have enough time to push the diesel away and get original conformance. Is the way it's written what you would prefer?[Hulme, Lee] Doing it during the first SL rig up would give the best time allotment to displace the diesel used. . WBS lists SSSV as a FMX...not sure if that is the same as an FXE. [Hulme, Lee] FMX is the tubing retrievable safety valve. The FXE is the SL retrievable set inside the FMX. . I have written "SLB Preferred" for my log presentation, as Ryan had a lot of issues with PDS in his time at this position. The color on the SLB logs is a huge bonus, and the instant InterAct availability is also a plus. [Hulme, Lee] Maybe Ryan liked the pretty colors. I do know that there was one thing that PDS didn't have that he specifically requested in his programs to get SLB on location; but, I can't remember what the name was. Will this be an issue? It seems like everyone has had mixed experiences with who they prefer. From what I understand, cost differences are neglible. [Hulme, Lee] There is a cost difference if it is a short notice type of job or one that keeps getting pushed back (only one SL unit) since PDS is more willing to work with us on call outs that are deferred or delayed. Do we have the freedom to choose who we want?[Hulme, Lee] We meaning you or 5/6/2010 Page 3 of 3 .. me? We (meaning you) always ha~he freedom to choose. Whether it is right, a most cost efficient, fills up the PE's candy drawer or gives us the best data is the question. Thanks for your help, James 5/6/2010 MEMORANDUM TO: Jim Regg ~ ~ ~~~~ ~ ~~z~ ~1 P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 16, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-03 MILNE PT UNIT KR L'-03 Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: MILNE PT UNIT KR E-03 API. Well Number: 50-029-21916-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS091212140755 Permit Number: 189-017-0 Inspection Date: 12/11/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - ~ , I E o3 1Type In~.T ~ , TVD 6a83 ~A ~~_ ~ -170 ~~ 80 } 4220 ~ 4170-- ----- -i_ ------ -__ ~ _ .I. eTest I --YTest si ~ _ ~ ~ ~I-- -_ ~ -- p T1DI is9o17o~YP P ~ ~--- -~- ~_ _._ - ~-- SPT ~I 1620 ~ 840 i 860 860 ~ 860 OA i ---- ---REQVAR L- `- P - ~ ~-- g, -- - - ---- rt----~- Interval P~F ~ Tubin ~ 3450 J 3450 3450 '~ 3450 ------- - -------- ------ --_ _ _-_ ----1- ---~-----1---~--- Notes: ~~ ~ ~ 13, C1D(r ~~ ~~ ~~~~ Wednesday, December 16, 2009 Page 1 of 1 MEMORANDUM To~ Jim Re °'' P.I. Supervisor t FROM: John Cnsp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 02, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC E-03 MILNE PT UNIT KR E-03 Src: Inspector NON-CONFIDENTIAL Reviewed By:, r: P.I. Suprv ,~~~." Comm Well Name: MILNE PT UNIT KR E-03 Insp Num: mitJCr071213193940 Rel Insp Num: API Well Number: ~0-029-21916-00-00 Permit Number: 189-017-0 Inspector Name: John Crisp Inspection Date: 12/12!2007 Packer Depth Pretest Initial 151VIin. 30 Min. 45 Min. 60 Min. Well E-03 T),p0 III. ~ G 'I'`7D ~-,--~ ~ 6483 jA 1375 4000 ,if 3820 3800 j ~ P.T. ~ 1890170 ~Tf'peTCSt ~ SPT ~ TeSt pSl _ 1620.75 ~ OA 920 ~ 920 i 920 ~ 900 ~ Interval 4YRTST P~F P ~~ TUbing I 3750 , 3750 _ 3750 3750 Notes: 6.1 bbl's pumped for test. Operator decided test pressure for this gas storage well. C,31~::JG6Ciil~'.4~ JQi~ 6r `~= ~~UL} Wednesday, January 02, 2008 Page 1 of I RE: MPU (PTD #1890170) Internal Waiver Cancellation - Normal Well • • *Object: RE: MPU (PTi ##0 *, 70) Int• aal Waiver Cancellation - Normal Well k From, " ghes, Andrea" <1 li P :c rn> \ . Date, Mon, 30 Oct 200645:43:16 =0900 T �Tl r a scat \ a� \ CC♦ 451.20519,;::4 m 4 � 7 N PN! tal Tom, tSCS - ®` That is correct that cancellation is not desired for sundry 304 -007 for MPE -03. t _ Thank you for clarification on the members of both the East and West Teams. Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659 -5102 Pager: (907) 659 -5100 x1154 E) APR 15201 Original Message From: Thomas Maunder [mailto:tom maunder @admin.state.ak.us] Sent: Monday, October 30, 2006 3:19 PM To: NSU, ADW Well Integrity Engineer Cc: jim regg Subject: Re: MPU (PTD #1890170) Internal Waiver Cancellation - Normal Well Joe, With regard to MPE -03, we have received a 10 -404 dated October 10 "canceling" sundry 304 -007. As indicated in your last message, cancellation is not desired. If this is so, would you please advise by return message? Also, the cover letter was incorrectly addressed. On the North Slope, the East Team (Winton Aubert /Bob Crandall /Jane Williamson) has responsibility for Prudhoe Bay Field and fields further east. The West Team (Tom Maunder /Steve Davies /Dave Roby) has the responsibility of Milne Point and fields to the west. Call or message with any questions. Tom Maunder, PE AOGCC NS , ADW Well Integrity Engineer wrote, On 10/24/2006 10:45 AM: Hi Ji . We would 11 - to keep sundry 304 -007 in effect for well MPE -03 . When the OA is depre ed, it repressures to approximately 900 psi. We are reviewing the internal wait; and evaluating re- issuing it. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska nc. Work: 1- 907 - 659 -5102 Mobile: 943 -1154 Pager: 659 -5100, x1154 Email: NSUADWWeiiIntegrityEngineer @bp.com < mailto: NSUADWWellIntegrityEngineer @bp.ccm> 1 of 2 10/31/2006 8:13 AM RE: MPU (PTD #1890170) Internal Waiver .ellation - Normal Well . /7 _.. . D-j 2---4 \D0 r-t?dd I \ Hi Jim. We would like to keep sundry 304-007 in effect for well MPE-03 . When the OA is depressured, it repressures to approximately 900 psi. We are reviewing the internal waiver and evaluating re-issuing it. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllnteqrityEnqineer@bp.eom From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Wednesday, October 11, 2006 12:47 PM To: NSU, ADW Well Integrity Engineer Cc: Tom Maunder; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; MPU, Well Operations Supervisor; MPU, Operations Manager; MPU, Wells Ops Coord; NSU, ADW WI Tech; McLeod, Jennifer D Subject: Re: MPU (PTD #1890170) Internal Waiver Cancellation - Normal Well Well MPU E-03 (PTD 1890170) is a gas injector. Where do the annulus pressure limits you reference come from? Are you intending to withdraw the sundry (304-007)? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: All, An internal waiver was issued for high OA pressure on Milne Point well MPU (PTD #1890170) on 06/12/04. The waiver was to allow an OA operating pressure to 1500 psi. The OA is now stable at less than 1000 psi and therefore the waiver and related sundry are cancelled. The operating pressure limits are 2000 psi on the IA and 1000 psi on the OA. lof2 10/24/2006 10:50 AM RE: MPU (PTD #1890170) Internal Waiver Wllation - Normal Well . The well is reclassified as a Normal well. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, flnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 20f2 10/24/2006 10:50 AM • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB -24 Post Office Box 196612 Anchorage, Alaska 99519 -6612 cc ENE® October 10, 2006 0 CI 1 3 2006 a }& Gas Cons. Commission Mr. Winton Aubert, P.E. , nchotaga Alaska Oil & Gas Conservation Commission 333 W. 7 Ave. ia Anchorage, Alaska 99501 l 'O t q . y ( Subject: MPE -03 (PTD Application for Cancellation of Sundry #304 -007 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 304 -007 for Milne Point well MPE -03. Purpose of this request is to cancel sundry requirements for continued injection with increased maximum operating on the outer annulus of 1500 psi. When the sundry was applied for, the outer annulus pressure had increased to above the operating limit but has since stabilized below the normal outer annulus MAASP of 1000 psi. By canceling the sundry, the well will continue normal operation with an operating limit of 1000 psi on the outer annulus. If you require any additional information, please contact myself or Joe Anders at 659- 5102. Sincerel , #,AA,c,cc(D4A Anna Dube Well Integrity Coordinator Attachments: (1) TIO Plot beginning date 1/1/2001 to 10/10/2006 (2) TIO Plot beginning date 10/10/2005 to 9/12/2006 Wellbore Schematic Application for Sundry Cancellation form 10-404 0 STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION T 1 3 ZOO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Ala,ka Oil & Gas Co .ftTImlSStOf1 Abandon Repair Well❑ Plug PerforationsO Stimulate El Arc % r © 10 -403 Canc Alter Casing❑ Pull Tubing❑ Perforate New Pool❑ Waiver❑ Ti - Extension': Change Approved Program': Operation Shutdown Perforate ❑ Re -enter ' spended Well❑ 2. Operator Bp Exploration (Alaska), Inc. 4. Current Well Class: 5. • - rmit to Drill Number: Name: Development ❑ Exploratory❑ 189 -0170 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519 -6612 StratigraphicO Service © 50- 029 - 21916 -00 -00 7. KB Elevation (ft): 9. Well Name and Number: 52.00 MPE -03 8. Property Designation: 10. Field /Pool(s): ADL -047437 Milne Point Field / Kuparuk Ri - r Sand Pool 11. Present Well Condition Summary: Total Depth measured 11520 feet true vertical 7233.6 feet Plugs (measured) EZSV set © 11,241' Effective Depth measured 11240 feet Junk (measured) None true vertical 7034.7 feet Casing Length Size Ma TVD Burst Collapse CONDUCTOR 79 13 -3/8" 46# H -40 31 - 110 31.0 - 110.0 1670 670 M . SURFACE 6649 9 -5/8" 47# L -80 30 - 6679 30.0 - 4655.1 6870 4760 PRODUCTION 11346 7" 29# L -80 - - 11375 29.0 - 7157.5 8160 7020 :`Perforation depth: Measured depth: 10740 - 10756, 10768 - 10796, 11096 -111 r, 11100 - 11130, 11150 - 11154, 11154-11208, 11208 -11212 True vertical depth: 6828 -6836, 6843 -6858, 7013 -7015, 015 -7030, 7040 -7042, 7042 -7070, 7070 -7072 Tubing ( size, grade, and measured depth): 2 -7/8" 6. L -80 © 27 - 10165 Packers & SSSV (type & measured depth): 7" 1 tis HCM Perma -Drill PKR © 10109 /8" Otis FMX SCSSV 0 526 12. Stimulation or cement squeeze summ. : 4 ` Intervals treated (measured): Treatment descriptions including v,lumes used and final pressure: 13 Representative Daily Average Production or Iniection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operati : — 783 -- -- 3490 Subsequent to oper. ion: — 772 - -- - -- 3487 14. Attachments: 15. Well Class after proposed work: Exploratory❑ Development❑ Service ig Copies of Logs and S , rveys run _ 16. Well Status after proposed work: Daily Report of Wel Operations _ X Oil❑ Gas❑ WAG 0 GINJ © WINJ❑ WDSPL❑ Prepared by DeWayne R. Schnorr (907) 564 -5174. 17. I hereby certi that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Anna Dube 7 L 304 -007 �� F� OCT � 2006 Printed Na - Anna D, ee A Title Well Integrity Coordinator Signature ♦�, _ � Phone 659 -5102 Date 10/10/06 • Form 10 -404 Revised 4/2004 1 A • . 4,000 - -- -- — . '464 . 0 VS 4 4% i 1,471 CY II' • Tbg I i 3,000 II! ( I ! " ! -•- IA • I II i Y 1 1 I 2,000 IA MAASP L & I - ' d ■ ■ I E i - OA II ■ 1ro OA MAASP � �_ i . , . A I I .— . � .,- 1,000 I 1 ( Z .L' y 1 I II ii 1 ,1 1 I ! r r� 1 II I i !i i '; , { i I ii I s 000A 0 • Iii • I • 1/1/2001 12/18/2001 12/4/2002 11/21/2003 11/6/2004 10/23/2005 10/10/2006 • 0 4,000 4 1 % 11, Tbg • ii it ' ; 1 y I • 1 • 3,000 - ( i 1 I • 1 1 -n- IA 1 11 I IA MAASP 2,000 1 t f OA 1 .. , :.i. '1� - -11, - - -- ii 1 1 OOA ,000 i rr 1 -a- 000A 10/10/2005 12/9/2005 2/8/2006 4/10/2006 6/10/2006 8/10/2006 10/10/2006 MPU E -03i 110'13-3/8" 46 #/ft H -40 I I FMC TUBING HANGER W/ 3" '1-1' BPV PROFILE NOTES: / 2 7/8" 6.5 # /FT L -80 CS HYDRIL (2.441' ID, 2.347" DRIFT) 1. ALL MEASUREMENTS ARE FROM KDB OF PARKER RIG 141 -1111 1.125" 2.5 # /FT CS HYDRIL SIDE STRING KDB -SL = 54' KDB -GL = 30' sssv 526' OTIS FMX 2 7/8" SCSSV 2. MAX. ANGLE = 60' @ 6500' Note: The sssv is locked out and a WLRSV is set in the nipple. 3. K.O.P. = 1100' Run oversize o -rings on safety valve. 91QV117 -H 4. SLANT HOLE: YES 5. TREE TYPE: FMC 3 1/8" API 5000# 2057' END OF TUBING WITH 2 7/8" 8rd TREETOP CONNECTION 6. MIN. RESTRICTION IS OTIS XN NIPPLE (2.205" ID) 7. COMPLETION FLUID: 9.6 PPG NaCL BRINE , , �— 6679' 9 -5/8" 47 #/ft L -80 PERFORATIONS: 6 SPF AT 0' PHASING, 2 1/8" DYNASTRIP 11,096'- 11,130' MD 7009'- 7027" TVD / \ 11,150'- 11,208' MD 7038' -7067' TVD OTIS SBR OVERSHOT /J - SUB ASSEMBLY 4 SPF AT 90' PHASING 11,288'- 11280' MD 10,109' OTIS HCM PERMANENT 11111 7109' -7111' TVD PACKER (2.97" ID ) (SQUEEZED WITH CEMENT) 10, 156' 2 7/8" OTIS XN NO- GO NIPPLE (2.205" ID) PERFORATIONS ADDED 10,164' 3 1/2" OTIS RH CATCHER SUB 4 -19 -94 10,165' TUBING TAIL A SANDS 6 SPF @ 0 DEGREES PHASING -4411i1—_ 11100'- 11130' MD 10,707' CASING RA MARKER 11154'- 11212' MD C- SANDS 4 SPF @ 0 DEGREES PHASING _ 10740'- 10756' MD 11,241' 7" EZSV — PERFORATIONS ADDED 7 -3 -94 — 11,375' 7 ", 29 LB /FT L -80 BTRS (6.184" ID, B -SANDS 6.059" DRIFT) 10768 -10796 RKB MD 4 SPF, 0 DEGREES PHASING, 100 SHOTS TOTAL DATE REV. BY COMMENTS MILNE POINT UNIT 8/5/89 DBR /DMR INITIAL COMPLETION WELL E -03 7/1/95 DBR /DMR CONVERT TO MAC DIAGRAM API NO: 50- 029 -21916 11/20/03 MAS Add 9 -5/8" & Surface Casing to Diagram BP EXPLORATION (AK) '!( ( VIC File Review Date: November 24,2003 and January 12,2004 Subject: BPXA MPU Well E-03 PTD #: 189-017 Sundry: 304-007 Orders: CO 432 B (consolidated orders) AIO lOB and prior versions Reviewers: Tom Maunder, P.E. ~ ~~ 1f2.-0 ~ Initiating Action: Reported IA and OA Communication Review Summary 1. This well was drilled in late July 1989. 2. Gas cut mud was experienced twice while drilling the surface hole. At 5300' md the mud was cut from 9.6 to 9.4. A drilling break was experienced at 5470' md and the mud was cut from 9.8 to 8.7. Some tight hole was experienced as well. 3. Surface casing was successfully run, however returns were lost while pumping the tail slurry. According to the records, some 501 bbls of fluid were lost. The TOC was estimated at 4200' in the reports. Using the cement calculation sheet and 30% washout, TOC calculates to 4251'. This is likely the shallowest it could be. 4. The casing successfully pressure tested and the formations under the shoe were tested to 11.8 EMW. It is not clear if there was an actual leak off performed or if it was a FIT. 5. The report does not indicate that there were any problems drilling the 8-1/2" hole to TD at 11520', 6. 7" casing was run, but became stuck and packed off with the shoe at 11369'. The casing was perforated above the float collar at 11288' and the casing was cemented via the perfs with 86 bbls of Class G cement. "Full returns" is noted in the report. 7. A cement bond log was run. Blair performed the original MIT II analysis in March 1991. He notes that MI is indicated and there are some bonded intervals above the perforations. I have examined the log. Initial cement indications are at about 9400' md. This is about 1000' below the calculated top with 30% enlargement. Overall, the cement quality is not great, however I agree that there are bonded intervals that should provide isolation. 8. The well successfully passed its original MIT on 8/6/89 with Bobby Foster witnessing. 9. The approved drilling program notes that a down squeeze of the OA was planned with 180 sx of Class C cement and 60 bbl of Arctic Pak. This would be the freeze protection strategy for the OA. There is no report in the file that this operation was performed, although it likely was. 10. IA pressure problems were noted as early as April 1993 when a sundry was submitted. It was noted that the pressure would stabilize at 1360 psi and could not be bled below 500 psi. Nothing is noted regarding the OA. 11. An application was made to add perforations and operate the well in IMW AG service to improve recovery in the area and help reduce the injection pressures due to the formation compartmentalization. 12. There is a June 1998 letter in the file reporting OA pressure problems. The OA was reported to be at 1580 psi and was bled to 250 psi and returned to 1470 psi in 7 days. BP proposed to re-torque :~ 1 the wellhead and load the IA with heavy brine to prevent any communication from the IA to the OA. 13. In May 1999, BP reported the results of a sampling program where they had determined by gas analysis that the gases in the IA and the OA were different composition and that their diagnostics had not indicated that the IA and OA were in hydraulic communication. It was also noted that both the IA and OA had passed MITs in January 1998. BP proposed to continue to monitor the well pressures and performance since the IA and OA pressures were below the newly established pressure limits. 14. Last MIT performed, December 10,2001. Witnessed by Chuck Scheve, passed. 15. On November 17, an email was received from BP reporting "high" OA pressure. BP has shut in the well and is performing "diagnostic tests". 16. On January 8,2004 BP submitted a sundry application (304-007) regarding MPE-03. BP proposes to keep the well in service, place the well on the monthly monitoring list, increase the allowable OA pressure to 1500 psi and perform a MITT in conjunction with the required 4 year normal MIT. Review Conclusions: 1. Schrader Bluff intervals containing hydrocarbon were encountered while drilling the surface hole. 2. The surface casing was not cemented to surface. "Best case" calculations on cement height show that the shallowest cement top would be about 4200' md. This is more than 1000' above the first reported "gas" interval. It is probable that cement was placed across that zone. 3. 7" casing became stuck about 160' from TD. It was necessary to perforate the casing to cement. That job is not reported to have encountered problems. 4. A bond log was run in the 7" casing. TOC is indicated at about 9400' md (shallowest perforation is 10740' md). Isolation is indicated, although the bond is variable. 5. Original plans were to freeze protect the OA by down-squeezing cement followed by Arctic Pak. The well file does not have sufficient information to determine if that was done, although the MP contact indicates the operation was performed. 6. It appears from the file information that the well has had some sort of pressure communication for some time. The earliest report in the file is from April 1993. Given the similar pressure values reported, it is possible that the pressure originally reported was for the OA rather than the IA. According to the MP contact, there are other wells on MPE pad with pressure on the OA, however none build as high as MPE-03 or have to be actively managed. 7. The well has passed all MITs that are in the file. The initial and most recent were witnessed. In the most recent tests, MITs of the lA, OA and tubing were performed. 8. The OA pressures source does not appear to be related to the "internal operations" of the well. According to information received from BP, the analysis of the gas is different from both Kuparuk and Schrader gas. No comparison has been made with the recent U gnu sample from S pad. 9. Since this well is an injection well, the recent Sustained Casing Pressure Order (CO 496) does not apply although the AIO requires notification for any suspected leakage in an injection well. BP has complied with that notice requirement. The reported OA pressure does exceed the trigger limit as specified in CO 496. BP's proposed OA pressure limit of 1500 psi is only 22% of the listed burst of the surface casing. Recommendation 1. I recommend approval of BPs proposal as outlined in the sundry application. 2. Evaluation of the monitoring information should be conducted to identify any new problems. RE: MPE-03 ~ ~ Subject: RE: MPE-03 From: "Sauve, Mark Aft <mark.sauve@bp.com> Date:Fri, 16 Jan 200412:59:16 -0900 J?~;...'.'.ÃbQII).a& .Mé.tlffid~r.;..$t()m;'.Il1~1mdef@.é.tclmiJ).sta.t~..aK..t1S~' . Tom, I have good tabular records for the IA and OA bleeds that took place in Mid-November which do not indicate any annular or tubing communication. These bleeds occurred while the well was on injection and warm. After E-03i was shut in on November 15th it had 30+ days to cool off before we pumped the tubing, IA and OA MITIs on December 18th. No communication was observed between any of the casing or tubing strings at this point either. Mark -----Original Message----- From: Thomas Maunder [!nail to ~_om ma~_nd~-F~~.9,!ll~E_,:-.§tat~....:..9~_' us] Sent: Wednesday, January 14, 2004 10:18 AM To: Sauve, Mark A Subject: Re: MPE-03 Mark, Was there any response on the IA or tubing? Was the well in operation or had it been SI? Tom Sauve, Mark A wrote: Tom, When the OA pressure first came to our attention we bled off the pressure and monitored it. This occurred several times during the course of our troubleshooting as a routine diagnostic for an annular pressure build-up that we do not believe is thermally related. On average it took 5-7 days for the OA pressure to build from 500 psi to 1000 psi. 10f2 1/16/2004 1:15 PM RE: MPE-03 it, '\ If by pressure test you are referring to a traditional pressure transient analysis (Horner plot, build-up curve, estimation of kh & skin) then the answer is no we have not done that type of analysis on the OA. Mark -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, January 14, 2004 9:27 AM To: Sauve, Mark A Subject: MPE-03 Mark, Has there been any bleed down or off/build up testing/analysis performed on the OA? Would that be a routine diagnostic that you (BP) would perform?? Tom 20f2 1/16/2004 1 :15 PM RE: MPU December increased monitoring information ~ ( Subject:RE: MPU December increased monitoring infonnation From: "Sauve, Mark An <mark.sauve@bp.com> Date: Mon, 12 Jan 200413:10:22-0900 ~~,:;'Qi,9n?-~§,;~~9tî~ç~'$~~H1<iffi~~Î1q~~@~~Þ.;~tél~@.a~.1.1s~~' ~'. Tom, Our best evidence indicates the Schrader is not the source of the OA gas in E-03i. The OA gas in E-03i carries a methane molar fraction of 97%. The injection gas typically carries a methane molar fraction of 87-92% and the Schrader gas typically carries a methane molar fraction of 89-92%. Mark -----Original Message----- From: Thoma s Ma unde r [m~,1_~<2-~.~.S?~~a ~~~ge !:~êJ)~9:!!!..~~§-~~~~~~~...:~.§,] Sent: Monday, January 12, 2004 11:55 AM To: Sauve, Mark A Subject: Re: MPU December increased monitoring information Mark, One further question on E-03. You have indicated that sample analysis has determined that the injected gas is not the source of the gas seen in the OA. How does that OA gas compare with any SB gas samples?? Tom Maunder Sauve, Mark A wrote: Tom, 1 - Yes, the E-03i OA was downsqueezed with Arctic Pack cement during the original drilling period. The volume of cement and displacement should have placed the OA cement from 1950' to 30001 MD. 2 - We hold some pressure on the OA of about half of the E-pad wells but E-03i is the only E-pad well that builds up pressure over 1000 psi and requires frequent bleeds. 1 of 5 1/12/20042:39 PM RE: MPU December increased monitoring information \~ ( Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, January 12, 2004 9:25 AM To: Sauve, Mark A Subject: Re: MPU December increased monitoring information Mark, I was looking at the sundry and preparing my review of the E-03 well file. I have a couple of questions. 1--Was the OA downsqueezed with cement and Arctic Pak when the well was originally drilled?? Our file indicates that such was the plan, but I cannot determine from the information available if that was done. Given that you can perform a MIT OA, the likely answer is yes. 2--Are there any other wells on E pad that also have pressures in the OA?? In particular this would be wells that follow the E-03 trajectory to the surface casing point. Thanks in advance for this information. Tom Maunder, PE AOGCC Thomas Maunder wrote: Mark, If the paperwork is in the pipeline, lets wait to put in service. As I indicated a while back, we look at any integrity issue with gas injectors very carefully. It would appear that you are not in a bind without the well since the subject of putting it back into service has 2 of 5 1/12/20042:39 PM RE: MPU December increased monitoring information ( it not come up. I look forward to the 403 and I will get it through our process quickly. Tom Sauve, Mark A wrote: Tom, E-03i is still shut-in. I have just submitted the cover letter and proposed plan of action to accompany the 10-403 you should be seeing soon. I have asked our Slope operations group to not place E-03i into injection service until we get the approved 10-403 back from you. If you are comfortable with giving us consent to initiate injection in E-03i prior to formal approval of the 10-403 please just let me know with a reply to this message. All the best, Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, January 05, 2004 4:12 PM To: Sauve, Mark A Subject: Re: MPU December increased monitoring information 30f5 1/12/20042:39 PM RE: MPU December increased monitoring information \{ ,r Mark, Thanks for the information. I concur that there does not appear to be IA x OA communication for F-83i. How is E-03 doing?? Has it been put back into service?? Tom Maunder, PE AOGCC Sauve, Mark A wrote: Gentlemen, Enclosed below is the December 2003 enhanced monitoring spreadsheet for MPU injector F-83i currently approved for water injection with a known tubing to IA leak as per AOGCC variance number 302-204 dated 7/9/02. The last combined tubing/IA MIT was performed 6/14/02 and the last tubing to IA leak rate test was performed 6/1/03. «031203 F-83i Annulus Monitoring.xls» We continue to have no evidence of any IA x OA communication. Please feel free to contact me if you have any questions. Mark Sauve *Milne Point Artificial Lift Coordinator* *BP Exploration - Alaska * *900 E. Benson Blvd * *Anchorage, AK 99519* 40f5 1/12/20042:39 PM Re: Milne Point E-03i MIT results ~ ~ Subject: Re: Mì1ne Point E-03i MITresults From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon,22 Dee 2003 14:21:30 -0900 'fQ:,:..'."..~)all¥.e,......~ß.tk.'...'A-'.'.....-<rn.~t~...~.~ity~@bp.c'()l11? Yes Mark, That is one of those little semantic things. My opinion is development wells are made of two sub-sets (producers and injectors). But, I wasnlt asked to provide a recommendation on the definition. Tom Sauve, Mark A wrote: Tom, Thanks for the clarification concerning the definition of a "Development Well" as referred to in the Sustained Casing Pressure Rules. I incorrectly thought both injectors and producers were covered. You should be seeing the 10-403 sometime soon. Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: .~?-u:~~ma~_!?_E.:..s:_orr~ -----Original Message----- From: Thomas Maunder [mail to: ~o~aunder@admi:Q~t_~te. ak. us] Sent: Monday, December 22, 2003 10:00 AM To: Sauve, Mark A Subject: Re: Milne Point E-03i MIT results Thanks Mark, When Jim Regg and I were talking regarding E-03, he pointed out to me that the Sustained Casing Pressure Rules apply to production wells. Injection wells were already covered by the regulations and the applicable Injection Order. Might be a little confusing, however the plans you have for E-03 appropriate and we do look forward to the sundry when you submit it. Best wishes for the holidays. Tom Maunder, PE AOGCC Sauve, Mark A wrote: 1 of 4 1/12/2004 11 :47 AM Re: Milne Point E-03i MIT results {' 1 Tom, Yes, the OA does develop a small "gas head" which can be quickly bled off. In the summer of 1998 we did a compositional analysis of E-03's OA gas and found it was dissimilar to the injection gas composition. Our best guess is that a shallow formation (such as the Prince Creek) is in slow communication with the OA of E-03. It is well known that the Prince Creek formation water carries a small amount of gas in solution. In addition, the OA pressure on E-03 does not build over 1350 psi which also suggests a shallow source (-3000' TVD). The casing in well E-03 is fairly robust with 9-5/8" 47#/ft L-80 BTRS (6870 psi burst) from surface to 6679' MD and 7" 29#/ft L-80 BTRS (8160 psi burst) from surface to 11,375 MD. We certainly agree with you concerning the extra rigor employed for integrity verification & monitoring on gas injection wells. Temperature effects will be foremost in our minds when E-03 is brought back into active injection service. Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, December 19, 2003 10:10 AM To: Sauve, Mark A Cc: Jim Regg Subject: Re: Milne Point E-03i MIT results Hi Mark, The revised pressure plot did not come through. I did get Mark OlS message and I have Lou Grimaldils report regarding his witnessing the test. It appears that as so far as it can be determined that the well has integrity to liquid. I agree with the plan to institute increased monitoring as a method to determine the well IS behavior when returned to gas service as well the recharging of the OA. Based on the 30 minute observation of the OA, there does appear to be integrity. Does a "gas head" develop through time?? One thing you should note though, allowing a gas injection well (includes MI as well) with an integrity loss is something that we take very seriously. The analysis and verification is much more rigorous than for a comparable water injection well like F-83. Temperature effects need to be of prime consideration in the operation of this well. I have not checked the file, but the 2 of 4 1/12/2004 11:47 AM Re: Milne Point E-03i MIT results ~ ~: surface casing weight and grade are likely much less than the surface casings used at Prudhoe. Please call with any questions. Tom Maunder, PE AOGCC Sauve, Mark A wrote: Tom, I believe you have been in correspondence with Mark O'Malley at Milne Point concerning the latest round of mechanical integrity tests performed on Milne Point gas injection well E-03i. As you are aware these MITIs established that E-03i has good tubing and annular integrity. During previous troubleshooting we have also established that the OA appears to be in slow communication with a source of pressure (probably a shallow formation) that tends to push OA pressures above the 1000 psi maximum established in Conservation Order No. 496 for the Milne Point Field. As per paragraph 4 of Order No. 496 Rules Section we at BP intended to submit a Form 10-403 concerning a proposal for increased surveillance to allow E-03i to operate with a sustained OA pressure greater than 1000 psi. A new OA pressure maximum of 1500 psi will be requested. I propose that BP initiate a monthly increased monitoring report for E-03i, similar to the F-83i report, which will include daily tracking & trending of tubing pressure, IA pressure, OA pressure and injection rate. Formally witnessed MIT's will continue to be performed once every four years unless pressure observations indicate a change in the integrity status. Please let me know if this proposal appears reasonable and I will begin work on the formal sundry application. Please also note that the E-03i MIT tracking spreadsheet mailed to you on 12/18/03 by Mark OlMalley had two corrections in it. Cell M20 should have been 1000 psi (instead of 100 psi) and Cell L24 should have been 1760 psi (instead of 1825 psi). I have included the corrected spreadsheet. «031218 MPE-03 MIT.xls» Thanks, Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 3 of 4 1/12/2004 11 :47 AM RE: Milne Point gas injection well E-03-189-017 ~\ t Subject: RE: Milne Point gas injection well E-03-189-0 17 From: "Sauve, Mark Aft <mark.sauve@bp.com> Date: Tue, 02 Dee 2003 15:05:41-0900 . '. ... Tg.:,~øma.~J5.4jij.AA~~~^.5;~QIIl.,.,mftW14~r@~~l'l~§tåt~~.ak:.J.1.s::? : " , . . ~ç:>I!m~~:gg.:(jjW.2rçgg@~grpip..$tåt~~,~~tll$~H . '" . , Tom, Thank you for such a fast reply! We are committed to progressing the diagnostic work on E-03 and will keep you informed of our progress. Mark -----Original Message----- From: Thomas Maunder [!TIai1. to :_t:.s?E1 mau~~er@aÈmiI~~.~t~.!:~~ ak_:..~_§.] Sent: Tuesday, December 02, 2003 2:53 PM To: Sauve, Mark A Cc: Jim Regg Subject: Re: Milne Point gas injection well E-03-189-017 Mark, In the unlikely event E-03 were needed as an emergency fuel source, we have no objection to using it for that purpose. The TIO plot you sent previously showed that there was still a substantial differential between the tubing and the IA/OA. That would indicate tubing integrity is still there. We do encourage you to continue with the diagnostics to determine the integrity failure and potential work to resolve it. Tom Maunder, PE AOGCC Sauve, Mark A wrote: Tom, Yes, E-03 is the "dark start" well for Milne Point. I was hoping to gain your approval for the continued use of E-03 in that capacity even though we have officially declared to the AOGCC that E-03 has been shut-in for integrity troubleshooting. Sorry for the confusion. Mark -----Original Message----- 1 of 3 1/12/2004 11 :49 AM RE: Milne Point gas injection well E-Q3-189-0 17 ( ,{ From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, December 02, 2003 2:03 PM To: Sauve, Mark A Cc: Jim Regg Subject: Re: Milne Point gas injection well E-03-189-017 Mark, I thought E-03 already was the "dark start" well. Is this not correct?? Tom Sauve, Mark A wrote: Tom, I have a question for you concerning the possible utility of Milne Point gas injector E-03. As you know, E-03 is currently shut-in awaiting a series of tubing and annular pressure tests to confirm it IS mechanical integrity status. However, E-03 is the only gas injection well that we have configured to provide source gas for the Milne Point Central Processing Facility during start-up. If in the unlikely event that we suffer a plant shutdown before E-03 is returned to normal service it would greatly facilitate our ability our ability to bring the plant back up if E-03 were temporarily used as a source of fuel gas. We believe that the use of E-03 as a temporary source of fuel gas in the event of a plant shutdown would be reasonable and prudent. We seek your concurrence prior to implementing this strategy. Thanks, Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com 2 of 3 1/12/2004 11 :49 AM RE: Milne Point gas injection well E-03-189-017 ( t Subject: RE: Milne Point gas injection well E-03-189-017 From: "Sauve, Mark A" <mark.sauve@bp.com> Date:Fri, 21 Nov 2003 14:19:33 -0900 . .. . Tq;J'.()m.Ma,.ull,Cief<tofuLm(1ûrid~r:@âqm.i#:$t~t,Þ.~I<:~s>; . "..' .' .; CC:' "ToWnsénd,MontC A"<TownseMA@bþ.com>,"MPU, Well OþeiätìoIlsSupëivisöf" ' <welloperationssupervisor@bp.com>, Jim Regg <jim_regg@admin.state.ak.us>, AOGCC North Slope Office <aogcc -prudhoe - bay@admin.statc.ak.us> Tom, Sorry to keep you waiting for this. I have enclosed a T/I/O pressure monitoring sheet for MPE-03 similar to what we provide for MPF-83. I have also checked the drilling records and the volume of cement pumped to set the 7" production casing was not sufficient to cover the lap up to the shoe of the 9-5/8" casing @ 6680' MD. However, 26 bbls of arctic pack cement was pumped into the IA and displaced with 50 bbls diesel. This would place the arctic pack cement coverage from 2000' to 3000' MD in the OA. To update you on the history of MPE-03, BP submitted a 10-403 dated 6/18/98 concerning the build-up of IA & OA pressure on MPE-03's which was approved on 7/22/98. The 10-403 indicated BP would re-check the wellhead & tree for leaks and load the OA with heavy brine. A follow-up 10-404 submitted on 5/4/99 indicated that the wellhead & tree were checked but the loading of heavy weight brine into the OA was not done because a study into the composition of IA & OA gas had indicated that the two were not in communication. I propose that after we have completed our diagnostic's tests on MPE-03 we come to a common path forward concerning the nature, timing and frequency of future monitoring and integrity verification. I look forward to working with you on this matter. Thanks, Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.com -----Original Message----- From: Tom Maunder [mailto:tom -maunder@admin.state.ak.us] Sent: Monday, November 17, 2003 3:36 PM To: Sauve, Mark A Cc: Jim Regg¡ AOGCC North Slope Office Subject: Re: Milne Point gas injection well E-03-189-017 Mark, Thanks for the information. Your actions to SI the well and begin diagnostics seems appropriate. Do you have any T/I/O pressure monitoring 1 of3 1/12/2004 11 :49 AM RE: Milne Point gas injection well E-Q3-189-0 17 ~. ( information similar to what you submit on MPF-83?? I will have a look at our files, but do you know if the OA "has a cement shoe"? Look forward to your reply. Tom Maunder, PE AOGCC "Sauve, Mark A" wrote: Tom, Here is some additional data on E-03: During routine monitoring operations on 11/11/03 it was found that the OA pressure on gas injection well E-03 had risen to 1080 psi (IA pressure was 1580 psi and tubing injection pressure was 3790 psi). OA pressure was then bled off to 600 psi and closely monitored. Over the next three days OA pressure rose back up to 980 psi, while IA and tubing pressure remained stable. On 11/14/03 the IA pressure was bled from 1580 psi to 640 psi. The following day IA pressure had risen to 740 psi while OA and tubing pressure remained unchanged. At this point we decided to shut-in E-03 and continue with additional diagnostics. The wellhead seals have been checked out and they appear to be holding. It is our intent to set a tailpipe plug in the tubing of well E-03 and confirm tubing integrity. Afterwards, we plan to begin a systematic process of determining casing integrity and if necessary leak path magnitude & direction. I hope you find this additional information helpful. We will keep you informed of our progress. Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.~o~ -----Original Message----- From: Tom Ma un de r [E~.§..~..1..t..?m:.m~.g.~~.~.~~.~9:,~,E,~~.9.:,9:,!.~.~.~'~m~_..§.,~.,9.:..t.,~....:.,-~,~..=..,~_!:?_] Sent: Monday, November 17, 2003 1:37 PM To: Sauve, Mark A Subject: Re: Correction - Milne Point gas injection well E-03 Thanks Mark, please see my other note. Tom -----Original Message----- From: Tom Maunder [mail to : t_om maunder@admin. state. ak. us] Sent: Monday, November 17, 2003 1:35 PM To: Sauve, Mark A Cc: Jim Regg¡ AOGCC North Slope Office Subject: Re: Milne Point gas injection well E-03-189-017 Mark, Could you provide us with some further information with regard to this integrity loss. Some statement or report regarding the well history would be appropriate as would what diagnostics were performed. Also, would you please confirm that the well is E-03. 2 of 3 1/12/2004 11 :49 AM RE: Milne Point gas injection well E-93-189-0 17 !i' :¡ \ ~ That is what the text of your message says, however the message title says E-06. Thanks in advance for your reply. Tom Maunder, PE AOGCC "Sauve, Mark A" wrote: Gentlemen, As per Rule 5 of Area Injection Order 10-B for the Milne Point Field we wish to inform you that Milne Point gas injection well E-06 has been shut in after diagnostic work over the weekend indicated the possibility of a loss of casing integrity. We will keep you appraised of our efforts and wish to assure you that E-03 will not be returned to service until it's mechanical integrity has been demonstrated to the satisfaction of all parties. If you have questions please feel free to give me a call. Sincerely, Mark Sauve Milne Point Artificial Lift Coordinator BP Exploration - Alaska 900 E. Benson Blvd Anchorage, AK 99519 Work Ph #: 907-564-4660 Work Fax #: 907-564-4440 E-mail: sauvema@bp.co~ C t t D . t. . 031120 E-03i Increased on en - escrlp Ion. M .t' 1 onl onng.x s 031120 E-03i Increased . . Content-Type: apphcatlon/vnd.ms-excel Content-Encoding: base64 30f3 1/12/2004 11:49 AM ( ( bp January 7,2004 Mr. Tom Maunder AOGCC 333 W 7th Ave # 100 Anchorage, AK 99501 Dear Mr. Maunder Attached you will find a form 10-403 and supporting information concerning Milne Point Gas Injection Well E-03i. The attachments detail MPE-03i's latest tubing & annular mechanical integrity information and our planned path forward. We seek your concurrence for this plan of action. Please feel free to contact me with any questions you might have. Mark Sauve Milne Point Artificial Lift Coordinator c.c. MPE-03i Well Files Monte Townsend Mike Hefley Clint Spence ~ RECEIVED JAN 0 8 2004 Alaska Oil & Gas Cons. Commission Anchorage 5(ÇAWi\JE[J) ,JA~~ 2 @ 2004 0 RIG I N A L ¡Á-¡ ,~' ;( II ""'\ \ STATE OF ALASKA~, .e/v-y \ d- ALASKA OIL AND GAS CONSERVATION COMMISSION, V /4-/ APPLICATION FORSUNDRY APPROVAL 9fY 1(/6 : 20 AAC 25.280 ;' 1. Type of Request: Abandon 0 Suspend 0 Operation Shutdown D PerforateD VarianceŒ) Annular DisposalD Alter CasinQ 0 Repair Well 0 PluQ Perforations 0 StimulateD Time Extension 0 OtherD Change Approved Program 0 Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name' BP Exploration (Alaska), Inc. 189-0170 . Development D Exploratory D 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD Service [!] 50-029-21916-00-00 7. KB Elevation (ft): 9. Well Name and Number: 52.00 KB M PE-03 8. Property Designation: 10. Field/Pool(s): ADL-047437 Kuparuk River Field / Kuparuk River Oil Pool, Milne Point Unit 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): rTotal Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 11520 7233.6 I 11240 I 7034.7 11240 None Casing Length Size ~ TVD Burst COllapse top bottom top bottom Conductor 79 13~3/8" 46# H-40 31 - 110 31.0 - 110.0 1670 670 Production 11345 7" 29# L-80 30 - 11375 30.0 - 7157.5 8160 7020 Surface 6650 9-5/8" 47# L-80 29 - 6679 29.0 - 4655.1 6870 4760 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10740 - 10756 6828 - 6836.5 2.875 " 6.5 # L-80 27 - 10165 10768 10796 6843 - 6857.6 11096 11100 7013 - 7014.8 11100 11130 7015 - 7030.2 11150 11154 7040 - 7042.5 11154 11208 7042 - 7070.1 11208 11212 7070 - 7072.1 Packers and SSSV Type: Packers and SSSV MD (ft): 2-7/8" Otis FMX SCSSV 526 2-7/8" Otis HCM Perm a-Drill Packer 10109 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 DevelopmentD ServiceŒ 14. Estimated Date for J 5 2004 15. Well Status after proposed work: Commencina Operatio anuary, Oil D GasO PluggedD AbandonedD 16. Verbal Approval: Date: WAG D GINJŒ] WINJD WDSPLD Commission Representative: Perpared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Sauve Printed Name ~k~e 4. Title Artificial Lift Coordinater Signature ,¿. -- ~.. .., - Phone 564-4660 1/5/04 Commission Use Onlv ~undry Number: Conditions of approval: Notify Commission so that a representative may witness - - .-. _....'?¿>¥- 00 7' Plug Integrity 0 BOP TestO Mechanciallntegrity Test D Location Clearance D t( t: l,; t: I V I:: D Other: ¡;'<:.t'Cët.~ ~.:.~ ~ "":::. ?tt~~'\~t>.!.~~~~ 'H\ ~'N. ...,,~ \\ (.c..-\-'\C> " JAN 0 8 2004 Subsequent Form Required: NJ~(,¿; Alaska Oil & Gas Cons. Commission BY ORDER OF Anchorag~. / I I. "J Approved by: THE COMMISSION Date: I II ~I tJ'1 IIJ)MS BFl JAN 2 0 200' 0 R G I N ' ( Form 10-403 Revised 2/2003 a A L SUBMIT IN DUPLICATE ... ( l' MPE-03i Mechanicallntearitv Monitorina Plan During normal annular pressure surveillance monitoring activities in November of 2003 operations personnel reported that the outer annulus (OA) of gas injection well E-03i was experiencing a slow increase in pressure, causing it to exceeding the 1 000 psi th reshold. During December 2003, a series of AOGCC witnessed MITis established that MPE-03i has good tubing, inner and outer annular mechanical integrity. In addition, a previous OA gas compositional analysis had indicated that the source of the gas in the OA was different from that of the injection gas. It is our belief that the source of the OA pressure in well MPE-03i is not due to communication with either the IA or tubing but rather to a shallow aquifer with a small amount of dissolved gas in solution. The following path forward is therefore recommended for MPE-03i: 1) An increased monitoring report be generated and submitted to the AOGCC each month. This report will include daily injection volumes, lA, OA and tubing pressures (in both tabular & graphical format). 2) The maximum allowable operating OA pressure be raised to 1500 psi. 3) The addition of a four-year tubing mechanical integrity test requirement to be performed in conjunction with the normal four-year inner annular MIT. If any of this surveillance information indicates a change in the mechanical integrity status of well MPE-03i then well will be immediately shut-in and the. AOGCC notified. ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: BP Exploration - Alaska FIELD 1 UNIT 1 PAD: Milne Point Unit / E-pad DATE: 12/18/03 OPERATOR REP: Mark O'Malley AOGCC REP: Lou Grimaldi Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes F = Fresh Water In] M = Annulus Monitoring J = Initial Test G = Gas In] P = Standard Pressure Test 4 = Four Year Cycle S = Salt Water In] R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT MPU E-03 12-18-03.xls MPU E-03i ( 110' 13-3/8" 46 #/ft H-40 FMC TUBING HANGER WI 3" 'H' BPV PROFILE NOTES: ~ - 27/8" 6.5#/FT L-80 CS HYDRIL ~ (2.441'ID, 2.347" DRIFT) 1. ALL MEASUREMENTS ARE FROM KDB OF PARKER RIG 141 1.125" 2.5#/FT CS HYDRIL SIDE STRING KDB-SL = 54' KDB-GL = 30' 526' OTIS FMX 27/8" SCSSV 2. MAX. ANGLE = 60' @ 6500' Note: The sssv is locked out and a WLRSV is set in the nipple. 3. K.O.P. = 1100' . Run oversize o-rings on safety valve. 91 QV117-H 4. SLANT HOLE: YES 2057' END OF TUBING 5. TREE TYPE: FMC 3 1/8" API 5000# WITH 2 7/8" 8rd TREETOP CONNECTION 6. MIN. RESTRICTION IS OTIS XN NIPPLE (2.205" ID) 7. COMPLETION FLUID: 9.6 PPG NaCL BRINE ~ 6679' 9-5/8" 47 #/ft L-80 PERFORATIONS: 6 SPF AT 0' PHASING, 2 1/8" DYNASTRIP 11,096'-11,130' MD 7009'-7027" TVD 11,150'-11,208' MD 7038'-7067' TVD OTIS SBR OVERSHOT/J-SUB ASSEMBLY 4 SPF AT 90' PHASING 11,288'-11280' MD 10,109' OTIS HÇM PERMANENT 7109'-7111'TVD PACKER (2.97"'D) (SQUEEZED WITH CEMENT) 10, 156' 2 7/8" OTIS XN NO- GO NIPPLE (2.205" ID) PERFORATIONS ADDED 10,164' 31/2" OTIS RH CATCHER SUB 4-19-94 - 10,165' TUBING TAIL A SANDS 6 SPF @ 0 DEGREES PHASING 11100'-11130' MD .... 10,707' CASING RA MARKER 11154'-11212' MD C- SANDS 4 SPF @ 0 DEGREES PHASING 10740'-10756' MD ~ 11,241' 7" EZSV PERFORATIONS ADDED 7-3-94 11,375' 7", 29 LB/FT L-80 BTRS (6.184" ID, B-SANDS 6.059" DRIFT) 10768-10796 RKB MD 4 SPF, 0 DEGREES PHASING, 100 SHOTS TOTAL DATE EV. BY COMMENTS MILNE POINT UNIT 8/5/89 DBR/DMR INITIAL COMPLETION WELL E-03 7/1/95 DBRIDMR CONVERT TO MAC DIAGRAM API NO: 50-029-21916 11/20/03 MAS Add 9-5/8" & Surface Casing to Diagram BP EXPLORATION (AK) ( ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission /j '( TO: Jim Regg \<fÆÎlé 17;{ 7:7,/ D) DATE: December 18,2003 P.I. Supervisor l SUBJECT: Mechanical Integrity Tests THRU: BPX MPU E pad MPU E-03i FROM: Lou Grimaldi Milne Point Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Weill MPU E-03i I Type Inj.1 G I TV.D. I 6423 Tubing 350 2700 2550 2550 Interval! 0 P.T.D.I 1890170 ITypetestl P ITestps¡ 1606 IA 1300 1375 1375 1375 P/F I P 0 A 1000 1000 1000 1000 Notes: Diagnostic test 1 of 3 W/L plug set in TT Weill MPU E-03i I Type Inj.1 G I TV.D. I 6423 Tubing 500 600 600 600 Interval! 0 P.T.D.I 1890170 ITypetestl P I Test psi I 1606 IA 1375 2250 2200 2200 P/F I P 0 A 1000 1000 1000 1000 Notes: Diagnostic test 2 of 3 W/L plug set in TT Weill MPU E-03i I Type Inj.1 G I TV.D. I 6423 Tubing 500 500 500 500 Interval I 0 P.T.D.I 1890170 ITypetestl P ITestps¡ 1606 IA 1050 1050 1075 1075 P/F I P 0 A 1000 1825 1760 1720 Notes: Diagnostic test 3 of 3 W/L plug set in TT Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details Well had experienced unexplained OA pressure increase during normal Gas Injection. Wireline (WIL) plug set in Tubing Tail (TT) @ 10,156 (RKB) prior to these tests. All tests seem to indicate integrity at fluid packed conditions. M.I.T.'s performed: Three Number of Failures: None Total Time during tests: 4 hours Attachments: None cc: Mark O'Mallev (BPX MPU) ~t¿p~NNE[: IDEC 3 1 2003 MIT report form 5/12/00 L.G. MIT MPU E-03 12-18-03 LG.xls 12/22/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor THRU: TCohr~r~aa~nder P.I. S uperv iso%~_c_~,~;) FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL DATE: December 10, 2001 SUBJECT: Mechanical Integrity Tests BPX MPU-E Pad E-03 & E-07 MPU Milne Point Packer Depth Pretest Initial 15 Min. 30 Min. WelllMPUE-031Typelnj.I G i'T.V.D. I' 6481 I Tubingl 3600 13600 13800 I ~3~0o I lntervall 4 P,T.D.I' 189-017 ITypetestl P I~estpsi'l 1620 Icasingl 960 I 20201 20201 2020 I' P/F I _~ Notes: 4-year we,,IaPu E-07 I Type,ni.I ~ i ~.v.o. I ~"~ i +~,n, I ~oo I ~oo '1 ~oo I ~,oo l,nte~va, I4 P.T.D.I 191-049 ITYpet.estl P. 'lTestpsil 1734'.lCasingl "l 2.000 I 19.30 I 1920 I'P/F J P Notes: 4-ye. ar Well[ I Type Inj.I' ' IT.V.D.I ' ' ITubingI I I ' I I lntervalJ ' P.T.D.I . ITypetestl' ITestpsil '] Casing l '1 ' I I . IP/F,I Notes: Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs E Pad in the MPU and witnessed the 4 year MIT on wells E-03 and E-07. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with both wells demonstrating good mechanical integrity. M.I.T.'s performed: 2 Attachments: Number of Failures: Total Time during tests: 3 hours CC: MIT report form 5/12/00 L.G. MIT MPU E-03 & E-07 12-10-01 CS.xls 12/13/01 STATE OF ALASKA ALASK/~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Pull Tubing 2. Name of Operator BP Exploration (Alaska) Inc. ,,,,, ,,,,, ,,, ,,, , ,,, 3. Address P.O. Box 196612, Anchorage, Alaska ~-~ Operation Shutdown [-~Stimulate []Alter Casing [~] Repair Well [~ Other J 5. Type of well: Development ...... Exploratory ervice 99519-6612 4. Location of well at surface 1262' FNL, 2169' FEL, Sec, 25, T13N, R10E, UM At top of productive interval 5043' FSL, 1444' FEL, Sec. 23, T13N, R10E, UM At effective depth 5143' FSL, 1517' FEL, Sec. 23, T13N, R10E, UM At total depth 56' FSL, 1656' FEL, Sec. 14, T13N, R10E, UM Plugging E] Perforate 6. Datum Elevation (DF or KB) KBE: 54' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-03 9. Permit Number / Approval No. 89-17 398-176 10. APl Number 50-029-21916 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11520' feet Plugs (measured) 7229' feet 11241' feet Junk(measured) 7085' feet Length Size Cemented M D TVD 78' 13 3/8" Cold set to surface 110' 110' 6646' 9 5/8" 540 bbls Permf 'E', 56 bbls Class 'G' 6678' 4652' 7122' 7" 71.7 bbls Class 'G' 11375' 7154' Perforation depth: measured 10740'-10756'; 10768'-10796'; 11096'-11130'; 11150'-11212'(11280'-11288')SQZD true vertical 6776'-6785'; 6791 '-6806'; 6961 '-6978'; 6988'-7020'; (7056'-7060') SQZD Tubing (size, grade, and measured depth) 2 7/8" 1.5# L-80 with 3 1/2" tailpipe to 10165' Packers and SSSV (type and measured depth) 7" Otis HCM Permanent packer @ 10109' 2 7/8" SSSV @ 526' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) JL~ ['~ Treatment description including volumes used and final pressure , '""~ ... 4faska Oil & ....... Ankh 14. Representative Daily Average Production or Injection Data .......... Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: E~ Copies of Logs and Surveys run l--I Oil [--I Gas j-q Suspended l--I Daily Report of Well Opera~ions 17'. I hereby o ,~.~e ~correct to the best of my knowledgeSigned Angela M.~orrentino Service Gas Injection Title Surveillance Engineer Prepared By Name/Number: Date ~/~/,~'' Michael Wil)iam~, 56'4-4~5 7 Form 10-404 Rev. 06/15/88 Submit In Duplicate E-03i Outer Annulus Pressure Problem Actions A 10-403 was filed for E-03i on 6/18/98 with two recommendations for a path forward. ommendation, to test and re-torque the well head and tree, was completed new pressure gauges were installed on the IA and OA. The second .... reeo~endation was to use a side string in the inner annulus to load the IA with heavy brine to discourage pressure migration from tubing to annulus. Instead, a sampling and monitoring program was performed to evaluate the source of the outer annulus pressure. IA and OA pressures were monitored daily from 7/28/98 to 8/15/98 and gas samples from the IA, OA and tubing were collected and analyzed. Further sampling and analysis took place 3/11/99. Daily pressure readings on the IA/OA showed that the OA pressure remained constant while the IA pressure increased. This indicates that there is not communication from the IA to the OA. The percent composition methane in the IA sample remained constant over time which suggests that a constant source is feeding the IA. The percent composition methane in the OA sample differed from that of the IA and also remained relatively constant over time. This suggests that a separate constant source is feeding the OA. The conclusion of the monitoring and sampling is that while there may be a leak allow!ng communication between the tubing and the IA, it is not believed that there is communication from the IA to the OA. The source of the high pressure in the OA is believed to be from the Prince Creek formation and not due to communication with the IA. Both the IA and OA passed MIT tests 1/12/98. In addition, both are below the newly established IA and OA pressure thresholds. It is recommended to continue the practice of obtaining weekly pressure readings and reporting these in the Monthly Well Mechanical Integrity Surveillance Report as well as performing MIT tests. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate OA pressure problem 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [~ Development r--I Exploratory [] Stratigraphic l--] Service 4. Location of well at surface 1262' FNL, 2169' FEL, Sec. 25, T13N, R10E, UM At top of productive interval 5043' FSL, 1444' FEL, Sec. 23, T13N, R10E, UM At effective depth 5143' FSL, 1517' FEL, Sec. 23, T13N, R10E, UM At total depth 56' FSL, 1656' FEL, Sec. 14, T13N, R10E, UM 12. Present well condition summary Total depth: measured 11520 feet true vertical 7229 feet Effective depth: measured 11241 feet true vertical 7085 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) 6. Datum Elevation (DF or KB) KBE: 54' 7. Unit or Property Name Milne Point Unit 8. Well Number MPE-03 9. Permit Number 89-17 10. APl Number 50- 029-21916 11. Field and Pool Milne Point Unit / Kuparuk River Sands Cemented MD TVD 78' 13 3/8" Cold set to surface 110' 110' 6646' 9 5/8" 540 Bbls Permf 'E', 56 Bbls Class 'G' 6678' 4652' 7122' 7" 71.7 Bbls Class 'G' 11375' 7154' ~.~5 ~' Perforation depth: measured true vertical 10740'-10756',10768'-10796',11096'-11130',11150'-11212',11280'-11288'(Squeezed) (Subsea) 6776'-6785',6791'-6806',6961'-6978',6988'-7020',7056'-7060"(Squeezed) Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 with 3 1/2" tailpipe to 10165' Packers and SSSV (type and measured depth) 7" Otis HCM Permanent packer at 10109'; 2 7/8" SSSV at 526' 13. Attachments [~ Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation July, 1998 'J 6. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Trina Cooper/ 564-4212 15. Status of well classifications as: [-] Oil [] Gas J--1 Suspended Service Gas Injection & gas producer at field shut down Prepared By Name/Number: Jeanne L. Haas, 564-5225 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Staff Technical Assistant Date Commission Use Only (~onditions of Approve'l: Notify Commission so representative may witness I Approval .l~,-- Plug integrity BOP Test Location clearance -" Mechanical Integrity Test ./~. Subsequent form required 10- 0riginal Signe(~ By W. Johnston Approved by order of the Commission David Commissioner Date MPE-03 Outer Annulus Pressure Problem E-03i outer annulus was at 1580 psi in February, 1998. No volume was recovered indicating that gas was bled from the outer annulus to a pressure of 250 psi. The pressure continued to climb daily and was at 1470 psi after seven days. This well failed the CPRP and we are now reporting it to the State. The following path forward is recommended: o Test and re-torque the well head and tree. Using the sidestring in the inner annulus, load the inner annulus with heavy brine to discourage pressure migration from tubing to annulus and then from annulus to annulus. June 24, 1998 Mr. Blair Wondzell AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Attached you will find a form and supporting information concerning Milne Point Well E-03i. The attachments detail E-03i's current annulus pressure condition and our planned path forward. Please contact me if you require any different or addtional action on this well. Sincerely, Bill Hill WNS Kuparuk Production Team Leader Attachments ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVEI~NOFt 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 3, 1995 John Hendrix BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519,6612 Re: MP E-3 Dear Mr. Hendrix: The Commission has no objections to your request to flow back gas from MP E-3 as proposed in your September 27, 1995 letter. Should the test prove positive, the Commission grants approval to use E-3 gas for lease use purposes. The Commission will appreciate information about how the use of this gas will affect pressure maintenance in that portion of the Milne Point reservoir and your plans to accommodate any corresponding decline in pressure or reservoir performance. David ~/. Johnstm Chairm~ C:\ BPX-~IILI~ PO I NT-~ 907 276 7542;# 1/ 2 Pest-It" brand fax transmittal memo 7b"71 BPX-~IL1NE POINT~ ~07 276 7542;# 2/ 2 Via E,~csimile September 27, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attention: Mr. '.Blair Wondzell Dear Sirs: Per your telephone conversation between BP Milne Point's John Ketchum and yourself earlier today, this letter documents our verbal discussion. BPX Milne Point requests permission to back flow gas from the MP-E-3 gas injection well into a temporary test separator and then back into the CFP production facility. This will be a short term 2 to 4 day test flowing back a peak rate of $ MMSCFD from the E-3 well. After metering and sampling from the temporary test separator; gas will be reinjected into the MP-E-7 IWAG well. The purpose of this test is to determine the feasibility of using E-3 gas to supply Milne Point with gas for turbine fuel and during startup of the Milne Point field after our major shutdown planned for late November and December. The gas composition and flowing volumes are both important data points in evaluating this decision. Should results from the E-3 flow back test be successful, BP-Milne Point also requests permission to use the E-3 well to supply gas during the year end shutdown for fuel and as a warm up circulating fluid for the plant during restart after our major shutdown. BPX will advise you of thc rcsul~ of E-3 testing and our future gas requirements during the upcoming November / December shutdown once test results are known. At this time, we ask for your signature below, indicating AOGCC agreement with the concepts presented in thin letter. If you have any further questions, please contact John Kctchum or Chuck Stewart at 659-6333 or 659- 634:5 respectively. Sincerely, n Hendrix wnme Point Well Facilities Supervisor Blair Wondzell - AOGCC BP EXPLORATION January 18, 1994 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 q David W. Johnston AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501-3192 Dear Mr Johnson: BP Exploration requests approval to add perforations to Milne Point well E-03 in the Middle Kuparuk sands and begin immiscible WAG injection after appropriate surface tie-ins can be connected. The purpose of the work is to increase recovery in the B Pad area and to increase short term gas injection capacity while the other WAG injector E-07 is on a water cycle. Approval of this work should potentially increase oil rates in several B Pad wells, give 2% additional recovery to the local area, and prevent shut in of several producers should we reach our gas injection limit, which we anticipate reaching shortly. E-03 is currently a gas injector perforated and injecting into the Lower Kuparuk (A-sands) interval (figure 1). This well is responsible for re-injecting the entire field's produced gas and is currently operating at approximately 5 MMSCFD. The well is currently injecting near the maximum header pressure attainable by the facility (4800 psi). Therefore, it is anticipated that within the next month we will need to begin shutting in production from higher GOR producers in order to reduce gas injection requirements. The proposed following changes to E-03 should increase the injection potential as well as add additional rate and recovery benefits to the field. The Middle Kuparuk (C and B sands) are not yet perforated in E-03. Gas injection is currently directed into the Lower Kuparuk (A sand) interval. Since there is minimal production from the A sand in this region (figure 2), the well has pressured up and injection capacity is becoming limited. Gas injection capacity in the C and B sands is potentially much greater since there is currently production from both intervals, and the sand quality is much higher than in the A sands. Production impacts for the WAG injection would likely be positive. Three wells in the affected fault blocks currently produce only 500 bopd combined at 83% water cut. Current oil recovery is approximately 30% which is near the maximum recovery expected for this fault block. WAG injection is anticipated to add 2% recovery to the OOIP of 11 MMSTBO, or 220 MSTBO. Given the current weak production capacity in the area, potential negative impacts to production are minimal. R E CF..IV F-.D FEB 2_ 8 199~ Oil & Gas O0ns. O0rn~nission Anchorage The WAG injection cycle would be the same as recently proposed for injector E-07. The start of immiscible WAG process would begin with a conservative 2: 1 WAG ratio, again building upon Arco's experience base in the Kuparuk. Due to the potential for a high perm streak in the B sand, we would begin by only perforating the C sand, and injecting 5% of the total sand movable pore volume during the gas half cycle. Eventually we will open the B sand for injection and begin at 2.5% pore volumes to limit the effect of the high perm streak. We are also investigating use of diversion treatments to limit the thief zone effect. After the initial cycle we would inject at a 1: 1 ratio and eventually set our target at a 0.5 WAG ratio. Results from the other WAG at E-07 are preliminary but very encouraging. After 1 completed water and gas cycle the well is currently on water injection. Not only has decline been reversed in the affected fault block, but production has increased by 750 BPD with no f measurable increase in GOR. Therefore, initial results from the pilot WAG look good. ! In summary, we feel that adding perforations, and putting E-03 on WAG injection will likely increase production rates, add to ultimate recovery, and mitigate negative effects of limited gas injection capacity at Milne Point. In addition, the production in the affected part of the field is minimal with worst case production losses of 500 bopd. Estimated production gains are 200-400 bopd, with ultimate recovery increases of 200 MSTBO. As you may recall, the other gas injection well, E-07, is operating as a WAG injector and is currently on a water cycle. The water cycle is planned to continue for several more months, therefore, E-03 remains the only outlet to re-inject produced gas. If you have any questions regarding this matter, please call Dave Uldrich, our lead reservoir engineer, at 564-7623. Sincerely, .., /) / Manager Mine Point Exploitation BP/abc RECEIVED i.i~t & ~as Cons. CoIt~missior, Anchorage O. O0 lo.00 O. O0 ~AMMA RAY APl 1~0.oo DEEP RESISTIVITY OHM-M 2.00 200.00 VPS POROSITY 0.50 0.00 VP8 WATER SATURATION 0.00 1.00 HEADER 10700.00F 10787.00F RECEIVED u~i ~ 6as Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 13 July 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~PFC/GR/CCL RF SEPIA 1 PFC/GR/CCL FINAL BL ~MPL-15 1/~SBT/GR/CCL FINAL BL SBT/eR/CCh ~F SEPIA PFC/PERF RF SEPIA 1 PFC/PERF FINAL BL Run # 1 Run # 1 ECC No. 6188.01 Run # 1 6223.00 Run # 1 Run ~ 1 6223.01 Run ~ 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Please s~s-n and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by VEO JUL 2.5 Alaska Oil & Gas Cons. Commission Anchorage Date BP EXPLORATION DATE: 04/28/94 T~ 85649 BP/MILNE POINT CASED HOLE LOGS BP/MILNE POINT OPEN HOLE LOGS Enclosed'~s the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4424. · OPEN.~OLE LOGS: NOPoINT-I~/MWD:DPR/GR 3/18-04/03/94 1-5 104-14465 BAKER 2/5"MD ~ NOPOINT-lJMWD:DEN-NEU PORO/GR 3/18-04/03/94 1-5 104-14465 BAKER 2/5"MD ~-NOPOINT~I/MWD:DEN-NEU PORO/DPR/GR 3/18-04/03/94 / '~'NOPO'INT-YJMWD:BULK DENSITY/GR 3/18-04/03/94 1-5 104-14465 BAKER 2/5"MD 1-5 104-14465 BAKER 5 "MD 'N~OIN~-i~MWD:DPR/GR 3/18-04/03/94 1-5 120- 7150 BAKER 2/5"TVD NOPOINT-i~MWD:DEN-NEU PORO/GR 3/18-04/03/94 1-5 120- 7150 BAKER 2/5"TVD NOPOINT-I~MWD:DEN-NEU PORO/DPR/GR 3/18-04/03/94 1-5 120- 7150 BAKER 2/5"TVD CASED HOLE LOGS' -~'~'~ ~ MPL~'~E-03 v/PFC 04/19/94 #1 10600-11206 ATLAS 5" ?0O0MPL_ 03 ~GR 04/14/94 #1 8250- 8683 ATLAS 5 " 03 ~PFC 04/14/94 #1 8270- 8477 ATLAS 5 " MPL-03 ~/PFC 04/15/94 #1 8258- 8492 ATLAS 5 " NOPOINT-1 ~/SBL 04/07/94 ~1 12553-14354 ATLAS 5 " NOPOINT-1 ~. 04/07/94 #1 . . 0- 358 ATLAS Please sign and return one c~py~f this transmittal. Thank-you, Sonya Wallace ~ ~ . Petrotechnical Data Center ~ ~.~.~ Milne Point Milne Point Milne Point Milne Point '~ OXY OXY OXY OXY AOGCC AOGCC Greatland STATE OF ALASKA APPLICATION FOR SUNDRY APPROVALS Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing__ Vadance ~ Perforate x. Other x 1. Type of Request: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 4. Location of well at surface 1251'SNL, 2178 FEL, Sec. 25 T13N, RIOE, UM At top of productive interval 5154 FSL, 1525 FEL, Sec. 25 T13N, RIOE, UM At effective depth 5154 FSL, 1525 FEL, Sec. 25 T13N, RIOE, UM At total depth 67' FSL, 1666'FEL, Sec. 14 T13N, RIOE, UM RECEIVED FEI3 28 1994 fi~ska, 0il & Gas Cons. Commission Anchorage 6. Datum elevation (DF or KB) KBE = 28.0 feet 7. Unit or Property name 8. Well number E-03 MPU 9. Permit number 89-17 10. APl number 50- 029-221916 11. Field/Pool Milne Point/Kuparuk 12. Present well condition summary Total depth: measured true vertical 11,520 MD feet Plugs (measured) 7229 BKB feet Effective depth: measured true vertical 11241 MD feet Junk (measured) 7085 BKB feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 110' 6679' 13 3/8" Cold set to surface 9 5/8" 622bbls typee, 56 classG Measured cl~,~ 110' 6679' 11375' 7" 86 bbls class G 11375' 7" 331 c.f. Class G 13216'- 14085' measured current: 11096'- 11130' 6spf ; 11150'- 11208' 4spf; 11288-11280' (squeezed) Proposed: 10740-10756 md; 10764'-10797' md; CBL 6 spf, O.37dia, 15.6'penetration true vertical current: 7009-7027'; 7038'-7067'; 7109'-7111' (squeezed) Proposed: 6786'-6800'; 6810'-6840' Tubing (size, grade, and measured depth) 2-7/8" 6.5 Ib/ft L-80 with 3-1/2" tailpipe to 10165'md. 1"2.5 Ib/ft hydril side string Packers and SSSV (type and measured depth) 7" Otis HCM Permanent packer at 10109'; 2 7/8 SSSV at 1534 True vertical depth BKB 131' 2509' 9809' 9605'-10293' 13. Attachments Description summary of proposal × . Detailed operations program × .. BOP sketch × 14. Estimated date for commencing operation February20, 1994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil__ Gas x Suspended__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed A, ~,'~ ~~ Title ,~~ ~F~ ~ (J FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so r.ep,)'esentative may witness Plug integrity BOP Test v- Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10- ~ ~) 7 Approved by order of the Commission Form 10-403 Rev 06/15/88 jnginal Signed By gavld W. Johnston Commissioner ,Approved Copy Returned Date ,~, -,'-z /,~ SUBMIT IN TRIPLICATE Milne Point Unit Well E-3 A & C Sand Proposed Procedure- Perforating Note: A safety meeting shall be held with all personnel prior to RU electric line equipment. The meeting shall include a review of this procedure and discussion of the Milne Point W.L. Perforating Checklist. Radio silence shall be maintained and posted on location when guns are on, or within 500' of the surface, when RIH and POOH. . , . . . . . Reroute gas injection to well E-7. S.I. well E-3. Estimated SITP = 4800+ psi. RU FMC 3-1/8"x 2-7/8" 8rd x-over flange. Lock open SCSSV. Install fusible cap on SSV. Monitor SCSSV control line pressure throughout job. RU Camco slickline. Make 2" gauge run to 11240'. POOH & RD slickline. RU Western Atlas electric line unit and crane. RU high pressure grease injector head. RU Tioga heater and heat sock on lubricator. Note: Complete and sign Milne Point W.L. Perforating Checklist prior to arming perf guns. RU Western Atlas 1-11/16" Silver Jet - D.P. perforating guns loaded at 6 spf (HMX charge), 0o phasing with CCL/GR sub. RIH and tie-in with Halliburton CBL dated August 3, 1989. Minimum restriction is Otis XN nipple (2.205" i.d.) at 10156' MD. Other i.d. restrictions at SCSSV (526'), packer (10100') and tubing tail (10165'). RECEIVED -,~,~-, Oil & C;as 6ons. 6ommission Anchorage . 1 10. 11. Perforate intervals listed below. Record SITP before & after firing guns. A Sand (formerly Lower Kuparuk) est. SBHP = 5300 psi- Reperforations 11194' - 11212' (18' gross) 11174' - 11194' (20' gross) 11154' - 11174' (20' gross) 11115' - 11130' (15' gross) 11100'- 11115' (15' gross) C Sand (formerly Middle Kuparuk) est. SBHP -- 3500 psi- New Perforations 10740' - 10756' (16' gross) Perf depths have corrected to CBL measurements. The CBL reads 4' Iow of open-hole logs (i.e. 10700' on OHL is 10704' on CBL). POOH and RD electric line. Remove fusible cap from SSV. Return SCSSV to service. Reroute gas injection from E-7. Commence E-3 gas injection. RECEIVED · - I ,J .j ~. "~"'~".~ Oli&" ," " ' ' Anchorage FE~ 18 '~4 · 03:SZPM BPX ENDICOTT DEVP ~3ASIC SYSTEM MAKEUP ' 8OWIEN PACKOFF _" i ' -HANO PUMP --- ~m~s~ SeAL 'F~O,.WTUe~. P. 1/1 FLOWLINE GREASE LINE ,, ~"," FLOWLINE . .. I 'vAILV E ';~ = II ~, I I . I "'', ' , ~,~ . ,, ' . , . GREASE , : " : MANIFOED,, · , . . :~ ~,~. .-,, . ~ ~,. ~ ... PUMP: . ~ o'.' R ECEIV[ D . . , & Oas Cons. Commissior: Anchorage December 17, 1993 Conoco Inc. 3201 C Street, Suite 200 Anchorage, AK 99503-3999 (907) 564-7600 Mr. Russell A. Douglass Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Douglass, Pursuant to our December 15, 1993 meeting, please regard this letter as Conoco's request to cancel the following Applications for Sundry Approvals, Form 10-403: Well Approval Date Approval No. E-3 4-28-93 93-101 C-8 5-18-93 93-117 B-19 7-01-93 93-170 Please direct any questions regarding this matter to me at 564-7660. Sincerely, Tom Yeager SHEAR Specialist CC: Mr. Jack Hartz, AOGCC JHA, WCD/HDS Chevron Occidental E-3 Well File C-8 Well File B-19 Well File RECEIVED DEC 23 19~5 Alaska OJj& Gas Cons. Commission Anchorage e Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 November 8, 1993 Mr. Blair E. Wondzell Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Wondzell, · Mechanical Integrity Tests were performed on two Milne Point injection wells (C-8 and E-3) during the third quarter of 1993. Following is the information you requested on these two wells' C-8 C-8, which is on a six month cycle for testing, passed a MIT on August 27. This test was preceded by a series of downhole procedures intended to locate and repair a suspected tubing leak· These procedures, which included running a DND Hole Finder, cost $82,000. E-3 ... E-3 passed a standard four year.. MIT on July 19. $900. The cost of this test was Please direct your questions and comments regarding this matter to me at 564-7660. Sincerely, -- Tom Yeager SHEAR Specialist RECEIVED N0V - 9 199 Alaska Oil & Gas Cons. Commission Anchorage April 21, 1993 Conoco Inc. 3201 C Street, Suite 305 Anchorage, AK 99503-3999 (907) 564-7600 ORIG INAL Mr. David Johnston Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: APPLICATION FOR SUNDRY APPROVAL Dear Mr. Johnston, Attached is an Application for Sundry Approval, Form 10-403, for perforating Milne Point Unit gas injection well E-3. This work is being performed as part of our efforts to increase Milne Point's gas handling capabilities. Please direct any questions regarding this application to me at 564-7660. Sincerely, Tom Yeager SHIEAR Speaialist Attachments CC: CVL, JHA, TJY Chevron Occidental E-3 Well File RECEIVED APR ~ 6 199,~ Alaska Oil .& Gas Cons. Commission /~nchOra.qo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLTCAT;[ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend Operation shutdown __ Re-enter suspended well Alter casing __ Repair well __ Plugging_ Time extention __ Stimulate__ Change approved program Pull tubing __ Variance Perforate x Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development__ 54' KDB feet 3. Address Exploratory__ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic__ Milne Point Unit Service X i 4. Location of well at surface 8. Well number 1262' FNL, 2169' FEL, Sec. 25, T13N, R10E, U.M. E-3 At top of productive interval 9. Permit number 5043' FSL, 1444' FEL, Sec. 23, T13N, R10E, U.M. 89-17 At effective depth 10. APl number 5143' FSL, 1517' FEL, Sec. 23, T13N, R10E, U.M. 50-029-21916 At total depth 11. Field/Pool 56' FSL, 1656' FEL, Sec. 14, T13N, R10E, U.M. Kuparuk River Field ,, 12. Present well condition summary Total depth: measured 11520' feet Plugs (measured) true vertical 7229' feet Effective depth: measured 11241' feet Junk (measured) true vertical 7085' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 78' 13-3/8" To Surface 110' 110' Surface 6646' 9-5/8" 56 bbl Class G 6678' 4652' Intermediate 540 bbl Permf E Production 7122' 7" 71.7 bbl Class G 11375' 7154' Liner Perforation Depth: measured 11096'-11130'; 11150'-11208' true vertical 7008'-7025'; 7035'-7065' APR 2 6 1993 Tubing (size, grade, and measured depth) 2-7/8" 6.5#/FT, L-80, 10165' Alaska Oil & Gas Cons. C0mmissi0~ Packers and SSSV (type and measured depth) Otis FMX SCSSV @52~;Otis HCM Pkr @10109' Anchorage 13. Attachments Description summaryof proposal X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: N/A 16. If proposal was verbally approved Oil__ Gas __ Suspended Name of al: prover ~ Date approved Service Gas Injector , 17.1 hereby ca ~ify thatj ~le foregoing is true and correct to the best of my knowledge. / / / Signed ~4'~ /" ~0~ J.H. Andrew Title Sr. Production Engineer , Date April 20, 1993 co ,ss,o. Conditions of approval: Notify Commission so representative may witness I Approval No._,.. Plug integrity , BOP Test __ Location clearance __ ,,~ Mechanical ,ntegrlty Test__ Subsequent form required 10- ~ ~ ': .~"' '~ :~ ~_~._~_.~:, .. ,,' Origin¢! ~'~-,n~d By Approved by order of the Commission David ~J? .o¢tRstoPt Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE Milne Point Unit E-3 MK Perforating Proposed Procedure NOTES: . . . . . . . . A safety/planning meeting shall be held with all personnel prior to RU electric line equipment. Radio silence shall be maintained at all times when guns are on, or within 500' of, the surface. This includes both GIH and POOH. Check wellhead connection and crossover requirements and confirm crossover is available and on location for electric line company lubricator BEFORE calling to location. Notify Schlumberger to expect + 4600 psig surface gas pressure. Lock open Otis FMX SCSSV at 526'. Place fusible cap on SSV. NOTE: 1. SCSSV shall be functioned by Conoco operations personnel only. RU Schlumberger electric line unit and crane. RU high pressure grease injector head. RU Tioga heater and heat sock on lubricator. RU Schlumberger 1-11/16" Enerjet I!1 perf guns loaded 6 SPF, 0o phasing with COL sub. TIH and tie in with Halliburton CBL dated August 3, 1989. Tag PBTD to confirm lower perf interval is open. CAUTION: Conoco Milne Point Perforating Checklist must be completed and signed by Conoco and Schlumberger representatives prior to arming perforating guns. NOTES: 1. 2. . . . Exercise caution when working around live perf guns. Confirm radio silence signs are posted and everyone on the pad is notified prior to PU guns. Exercise caution when passing through SCSSV @526', packer/seal assembly @10100', and tubing tail @10165'. SCSSV control line pressure shall be monitored continuously throughout the job. CBL is not correctly tied into open hole logs. CBL reads 4' Iow (ie. features at 10700' on OHL are 10704' on CBL Perf depths have been corrected tying in with CBL Perforate the following intervals: 1. 10768'-10788' (20' gross) 2. 10740'-10755' (15' gross) APR 2 6 199;~ Alaska 0il & Gas Cons. 6ommissiof~ Anchorage NOTE: 1. Record well pressure prior to firing and after firing each o gun. POOH and RD electric line. o o Remove fusible cap from SSV and place SCSSV back in service. Begin gas injection. Report results and notice of completion for this work to AOGCC on Form 10- 404. R'E .EIVED Alasl~a Oil & Gas Cmos. Cornmissio~ Anchorage ~ NOTES: . .3. 4. 5. . ALL MEASUREMENTS ARE FROM KDB OF PARKER RIG 141 KDB-SL = 54' KDB-GL = ..30' MAX. ANGLE = 60'@ 6500' K.O.P. = 11OO' SLANT HOLE: YES TREE TYPE: FMC $ 1/8" AP! 5000# WiTH 2 7/8' 8rd TREETOP CONNECTION MIN. RESTRICTION IS.OTIS XN NIPPLE (2.205" ID) 7. COMPLETION FLUID: 9.6 PPG NoCI BRINE WELL No. E-3 COMPLETION SKETCH MILNE POINT UNIT (GIW) APl No.: 50-029-21916 PERMIT No.: 89-17 COMPLETED: 8/5/89 LAST WORKOVER: N/A FMC TUBING HANGER W/ 2 1/2" 'H' BPV PROFILE ~ 2 7/8", 6.5#/FT L-80 C5 HYDRIL (2.441' ID, 2.347" DRIFT) 1.125" 2.5#/FT CS HYDRIL SIDE STRING 526' OTIS FMX 2 7/8" SCSSV 2057' END OF TUBING OTIS SBR OVERSHOT/J-SUB ASSEMBLY 10,109' OTIS HCM PERMANENT PACKER (2.87" ID) 10,156' 2 7/8" OTIS XN NO-GO NIPPLE (2.205" ID) 10,164' 5 1/2" OTIS RH CATCHER SUB 10,165' TUBING TAIL PERFORATIONS: 6 SPF AT O' PHASING, 2 1/8" DYNASTRIP 11,096'-11,150' MD 7009'-7027' TVD 11,150'-11,208' MD 7058'-7067' TVD 4 SPF AT 90' PHASING 11,288'-11,280' MD 7109'-7111' TVD (SQUEEZED WITH CEMENT) CONOCO INC. ANCHORAGE DIVISION _2 RECEIVED -"---'-10,707' CASING RA MARKER APR 26 1993 Alaska 0il & Gas Cons. 6ommiSSiO ~: Anchorage -r--' ~-- 11,241' 7' EZSV 11,575' 7", 29 LB/FT L-80 BTRS (6.184" ID, 6.059" DRIFT) IAPPRC~VED BY: JHA/HDS 'bATE:' 6/2.~/92 DRAFTED BY: SdN CAD FILE: WCC~3 Milne Point Unit E-3 Well The MPU E-3 well is an active gas injection well. Pressure on the 3-1/2" x 7" production tubing-casing annulus is currently 1360 psig, well below the 3050 psig surface injection pressure. This is in excess of the 500 psig maximum annular pressure guideline established by the Commission for continuous operation of injection wells. Conoco requests a variance to allow injection to continue until the MPU E-8 replacement well can be commissioned. Pressure builds up in the 2-7/8" x 7" production casing annulus of the E-3 well over a period of several weeks. Multiple attempts have been made to control the annulus pressure by bleeding it off. The pressure can be bled to less than 500 psig, but then builds very slowly up to the current level. A small leak in the wellhead seals is suspected of allowing communication between the casing and tubing. The MPU E-8 well was drilled and completed earlier this year specifically to replace the E-3. Surface piping and facilities are currently being fabricated and installed. The E-8 should be commissioned into service as a gas injector by the first quarter of 1992. The E-3 will be shut in and the casing pressure bled off at that time. The annular pressure will continue to be monitored on a routine basis. Due to the very slow nature of the leak, recurrences of pressure will be controlled and maintained under the 500 psig limit by periodic bleed cycles. No further action is planned at this time. STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLTCAT1'ON FOR SUNDRY APPROVALS 0 fl I G IN A 1. Type of Request: Abandon Suspend __ Operation shutdown __ Re-enter suspended well ~ Alter casing m Repair well m Plugging_ Time extention ~ Stimulate Change approved program Pull tubing ~ Variance x Perforate __ Other ~ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development__ 54' KDB feet 3. Address Exploratory__ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 StratigraphicN Milne Point Unit Sentice X 4. Location of well at surface 8. Well number 1262' FNL, 2169' FEL, Sec. 25, T13N, R10E, U.M. E-3 At top of productive interval 9. Permit number 5043' FSL, 1444' FEL, Sec. 23, T13N, R10E, U.M. 89-17 At effective depth 10. APl number 5143' FSL, 1517' FEL, Sec. 23, T13N, R10E, U.M. 50-029-21916 At total depth 11. Field/Pool 56' FSL, 1656' FEL, Sec. 14, T13N, R10E, U.M. Kuparuk River Field 1'2. Present well condition summary Total depth: measured 11520' feet Plugs (measured) true vertical 7229' feet Effective depth: measured 11241' feet Junk (measured) true vertical 7085' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 78' 13-3/8" To Surface 110' 110' Surface 6645 9-5/8" 56 bbl Class G 6678' 4652' Intermediate 540 bbl Permf E Production 7122' 7" 71.7 bbl Class G 11375' 7154' Liner Perforation Depth: measured 11096'-11130'; 11150'-11208' RECEIVED true vertical 7008'-7025'; 7035'-7065' NOV 2 6 1991 Tubing (size, grade, and measured depth) 2-7/8" 6.5#/FT, L-80, 10165' Alaska 0JJ & Gas Cons. Packers and SSSV (type and measured depth) Otis FMX SCSSV @526';Otis HCM Pkr @10109' .grlch0rag~ 13. Attachments Description summary of proposal .X Detailed operations program BOP sketch ~ 14. Estimated date for commencing operation 15. Status of well classification as: N/A 161 If proposal was verbally approved Oil ~ Gas Suspended Name of approverj J Date approved Service Gas Injector 17.1 hereby c~rllfy that ff ~ foregoing is true and correct to the best of my knowledge. / ..S. igned (~_,,j'l~ /' ~'V~ J.H. Andrew Title Production Engineer Date Nov 19, 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Appr°val No: ~/ Plug integrity BOP Test__ Location clearance__ Mechanical Integrity Test Subsequent form required 10--3~iff"~ ~ ~. ..... , ORIGINAL SIGNED BY __/.. ...... : Approved by order of the Commission LO,~IE C. $1~!TH Commissioner DAte''~l__/,-.~4, ---'~_~ _. '~' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Milne Point Unit E-3 Well The Milne Point Unit E-3 well is currently an active gas injection well. During the course of a recent well study it was discovered that the SCSSV in this well was not placed 500' or more below ground level, as required by the Milne Point Kuparuk Pool Rules. The SCSSV is located at 526' KB. KB elevation is 28' to the hanger at ground level, thus placing the SCSSV at 498' below ground level. Conoco requests a variance of the rules to allow this particular well to be used until such time as the tubing is pulled or the well is abandoned. The SCSSV will be reset at a depth satisfying the Pool Rules the first time the tubing is pulled. A new gas injection well, MPU E-8, has been drilled and completed to take the place of this well. The E-3 will be shut-in once the E-8 is commissioned. Piping and facilities modifications are in progress and the E-8 is expected to be on line in the first quarter of 1992. -' ' -' ' STATEOF ALASKA' OR I G 1 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION RE OR'r AND LOG 1. Status of Well Classification of Service Well X GAS IN~IECTION OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE ...... 2. Name of Operator '-;' ...... 7. Permit Number ~ONOI'.O TNt'._ L, ,,_.~,.-,~,-, fig_ 1 ~.-~o~ati~;-;f ~il~a~ ;uCf;c~ ........... ~'}. 9. Unit or Lease Name 1251' FNL, 2178 FEL, SEC 25, T13N, R10E, UM ' '.:~;:":"':".~',~; MXLNE P0XNT UNiT 5154' FSL, 1525' FEL, SEC 23, T13N, RIOE, UR ~S__--~-,~ c ~ At Total Depth ~Field and Pool u. clevation in teet ~indlcate ~D, u~, etcj / 6. Lease D~slgnatlon and Serial No. / ~..~.~dOeO ll~3'~t~T~'~eacheO "-~~om~.,Sus¢.orABanO._ _ [-t~Water'~[~f~r~" ~.~o. ofComoletionSfeet MSk ~lS.Plug Back Depth (M~WD) ~ ~ ' 17. Total Depth '(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11.520'HD/7229' :11.241 ~D 7085 YES ~ NO ~ ~32' feet MD 22. Type Electric or Other Logs Run . 23. ' CASING, LINER ~NDCEMENTING RECORD , , sETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ,. , ,.. IA-~/R" ~ Q ~-AQ ~llfl~A~ 11A~D~R ~. ~1~ ~T TQ ~IID~AP~ MIA , . , ~ ........ ,, , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD .... interval, size and number) SIZE DEPTH sET (MD) PACKER SET (MD) 2-7/8",6.5LB/FT . .]0 09 ]",a. 5L /FT 2056 11096-11130 ND =7008' - 7025'TVD 2~.ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11150-11208 NB =7035' - 7065'TVD DEPTH INTERVAL (MD) AMOUNT & KINDOF'M~TERIAE USED 6 SHOTS PE~ FOOT 0.47 IN DIA. · 12.57 ~N PENETRAT]0N .... ..... ............ 27. PRODUCTION TEST .... Date First Production ~ Method of Operation (Flowing, gas lift, etc.) TN,1FCTT~N R- 1 1 -RQ~ ,, 6~t~G~fost Ho.r~Tost~d P~ODUCT,b~ FOR OtL-~8~' OAS-MCF wATER-~eL cHoKE S~ZE OAS-O~L ~T~O TEST PERIOD ~ , . , Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF wATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ '2~. CORE DATA . , , ...... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 4,000 HCF/~AY GAS ]NOECTXON P4~O0 PSI TUBING PRESSURE . Form 10-407 Submit in duplicate CONTINUED ON REVERSE SIDE NAME GEOLOGIC MARKERS MEAS. DEPTH 1oo6o TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~--~, ~~_ --'~--~"~" Title~, INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 CHRONOLOGICAL WELL HISTORY July 14, 1989 Accept rig. Function test Diverter System. Ok. bottom hole assembly, tag bottom at 100'. Drill to 620'. Pick up July 15 Drill to 692' using Navidrill. Pooh, Change out MWD. RIH, MWD not working, POOH. RIH, Drill 692~ to 783°. Unable to build angle, POOH. PU Navidrill and bent sub. RIH. Attempt circulate, DP screen parted, POOH. RIH and drill to 1106~. July 16 Continue drilling from 1106°-1252°. POOH, change BHA. Lay down straight motor and Bent Sub. PU Bent Housing Navidrill. Slip and cut drill line. RIH. Drill 1252-2165~. Continue to build hole angle. July iT Take directional survey. POOH and lay down 4 jts. Ream 6 degree dog leg back to 3 1/2. Drill from 2165~ to 2257'. Pump pill, short trip, drill to 2377'. Pump pill POOH. PU Navidrill, RIH. Side track Well bore, Drill 1350 to 1415'. Drill 1415' to 1816'. July 18 Drill to 2125', pump pill. POOH. Pick up stabilizer. PU new Bit and Navidrill (1/2 degree). Rih to 1992. Take directional survey. Ream 1992° to 2125 twice. Drill 2125' to 3166°. July 19 Drill to 3225~. Short trip, clean. Drill to 4043'. Short trip to 1300~, pulled 60k over at 3200'. Slip and Cut 90' drill line. RIH to 4039~, tagged 4~ fill. Drill to 4380'. July 20 Drill to 4453. Circulate and condition mud. (9.5 ppg). POOH for MWD failure. RIH w/ new BHA to 4453, clean trip. Drill to 5179°. Short trip, clean. Drill to 5211'. July 21 Drill to 5300~. Mud wt. cut from 9.6 to 9.4 by gas. Drill to 5590'. Drill break at 5470~, Mud wt. cut from 9.8 to 8.7, by gas, no flow w/pumps off. Circulate and condition mud. Drill to 5773'. Short trip to 5100, clean trip. Drill to 6152, short trip to 5475', clean trip. Drill to 6183. July 22 Drill to 6700~. Short trip to 4754, clean triP~ Cir~u,l~e~ and condition. POOH to 1427~. Pipe will not pull pas%~1427'~,~f~e~ going down, work pipe to 1387~. July 23 Work pipe to 1327'. POOH, tight spot at 1075'. Retrieve single shot survey. Survey disagrees w/ MWD by 5 degrees to north. L/D BHA. P/U new BHA.. RIH to 1100'. Work pipe through 1100 to 1600'. No tight spots seen. RIH to 6175, Wipe out tight spot at 6175', TIH to 6612~, Wash and ream to 6675', ream to 6700' although no tight spots found. Circulate and condition. POOH f/ 6700~, clean trip. R/U to run casing, held safety meeting w/ all. RIH w/ 170 jts of 47 ~/ft. Ran 88 centrilizers. Full returns while running pipe. July 24 Finish running 170 jts of 47 ~/ft, 9 5/8 casing with buttress threads. RU cement head and cement line. Pump 40 bbls of 10 ppg Sepiolite preflush followed by 5 bbls H20. Test lines to 4000 psi. Mix and Pump 622 bbls of 12.2 ppg Permafrost type E with 5 lb./sk Gilsonite and additional .05% Sodium Citrate. Full returns while pumping. Mix and pump 56.5 bbls of 15.8 ppg Class G with 1% Gel, .2% CFR-3 and 3% salt. Lost retuns with 38 bbls of tail cement away. Displace top plug with 483 bbls of Water at 4/6 BPM. Estimate cement top at 4200' md. Bump plug and press up to 2500 psig. Floats held. N/D diverter. Perform top job at 110' RKB w/ 20 bbls of 15.6% ppg Permafrost type C.. Good cement returns to surface. M/U split speed head. NU BOP, Run Schlumberger GCT Gyro directional survey while NU, from RKB to 6550° MD. July 25 RIH w/ BHA to 6592', tag cement. Test casing to 1500 psi for 30 minutes, ok. Drill to 6710°, Circulate. Run EMW test=il.8 ppg. Drill to 7652. July 26 Short trip to shoe. Drill to 8368'. Wiper trip to shoe. Repair rotary clutch. Break circulation, ream 40° fill to bottom. Drill to 8585'. July 27 Drill to 9023'. Short trip 10 stds, ream 40' to bottom, no fill. Drill to 9525°, repair rotary chain. Drill to 9860'. 9.6 ppg mud. Drill to 9900~. circulate bottoms up, pump slug. POOH, P/U RLL, RIH to shoe. Cut and slip drill line. RIH, ream 30' to bottom, no fill. Drill to 9990°. Repair rotary chain and guard. Drill to 10221'. July 29 Drill to 10278'. Tighten rotary chain. Short trip 10 stds, no fill. Drill to 10661'. fill. Drill to 10,860~. Drill to 10304. Short trip, no July 30 Drill to 10936', change shaker screens, Drill to 10982'. drill to 11168'. Circulate bottoms up, take survey. POOH, LD turbine and Dir MWD, RIH to 8900', fill DP. July 31 RIH to 10900'. Ream and log 10900 to 11168'. Drill to 11520. Circulate, short trip to shoe, RIH. Au~ 1 RIH wash and ream 28~ to bottom 10~ fill. Circulate and condition mud. POOH, LD DP. Cut drill line. LD BHA. Pull wear bushing, set test plug, test rams and Annular, RU Casing crew, RIH w/ 60 jts 7" 29~, L-80 Buttress casing. Au~ 2 Continue to run casing to 9 5/8 shoe. Drop ball and shift sleeves of float collar and float shoe. Wait on ball and circulate. Run Casing to 11369' (wlm) and pipe stuck. Pipe stuck and packed off, attempt to circulate and work pipe while waiting on HLS. P/U 120,000 lbs over string wt.. Little or no movement, pressure up to 2000 psi, pumping away mud at 3.5 bbls/minute. Rig up HLS and run GR and CCL from 10700' to 11292'. complete fab of XO from 7' buttress to lubricator. R/U lubricator and test to 1000 psi. RIH w/ perf guns, tie in and shoot 8 shots from 11288 to 11290. POOH w/ guns. RU circulating head and circulate through perfs. 30 spm at 750 psi, 50 spm at 950 psi. Became packed off while circulatin, reestablish circulation at 20 spm, slowly increase to 45 spm, full returns. RU cementers and pump 40 bbl of 10 ppg sepiolite, 86 1/2 bbls of 15.8 ppg class g w/ .2% cfr-3. Drop plug and displace with 9.6 ppg NaC1 brine at 3 to 5 bpm, full returns. Bump plug 200 psi over circ. pressure, and hold pressure. ND and set 7" slips with 150,000 ~'s. Continue to hold press on casing. Au~ 4 Hold Press on casing. Press gradually bled off from an initial pressure of 800 psig. Bleed press off of csg. slight flow from casing, continuous. Cut casing and set 7' packoff, NU stack and test broken flanges. Tested pack off to 3500 psig for 15 minutes. Run gauge ring (6"), Junk Basket to 11288', no obstructions, POOH. Press. test casing to 500 psi, ok, 1000 psi, slow leak, 1500 psi, slow leak, 2000 psi slow leak. Rig up and run gyro survey to 11,250' pooh making check shots, good survey. PU Halliburton EZ drill w/ bridge plug on Baker Model 20 setting tool, RIH to 11,241~, cannot get below this depth. Work tools from 11,215 to 11,241, would not fall past this depth. Detonate setting tool and place EZSV at 11,241'. POOH. RU lubricator, pressure test to 500 psi. RU and CBL w/ GR w/ 3 centrilizers. Estimated cement top at 9404°. Generally poor bonding. POOH. RD HLS, Pressure test 7° casing to 3200 psig, good test. RU to run tbg. Run 2 7/8", 6.5 ~/ft CS Hydril tubing, 324 joints. Set 2 7/8 in slips, RU to run dual string. RIH with 1 1/8, 2.5 ~/ft hydril side string. Aug 6 Continue running 1 1/8 side string. PU scssv, run 2 strings in together. PU tbg hanger and control line, test control line to 5000 psig, land tbg., drop ball and engage tubing hanger lockdown screws. RU to high pressure pump to set packer. Set packer and pressure test to 4000 psig, hold for 15 minutes, good. Backout lockdown screws, PU and displace tubing w/ 74 bbls of diesel. Pumped 60 bbls of diesel into 7" annulus. Land tubing, install 2 way check, ND BOP, NU xmas tree, test tubing hanger, 2 7/8 slickneck and 1 1/8 slickneck, and sssv line to 5000 psi. Test tree to 5000 psi. Pull 2 way check , test tubing to 2000 psi for 30 minutes per Bobby Foster. Release pressure, Pump down 1 1/8 side string w/ 3 bbls diesel to press, annulus to 2000 psi and hold for 30 minutes per AOGCC. Rig released at 1900 hrs. CI FI I I--I--I N (~ SEFI~JICE S April 8, 1991 Mr. Harold Oakland Alaska Oil & Gas Conservation Commission .3001 Porcupine Drive Anchorage, AK 99501 RE: Boss Gyroscopic Survey Conoco, Well E-3 ~q"-!-'7 Dear Mr. Oakland: Please find enclosed Sperry-Sun's Boss Gyroscopic Survey for Conoco's Well E-3 as requested. Please call 563-3256 if you have any questions. Sincerely, Ken Broussard Alaska Region Manager Enclosure. RECEIVED 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Baroid Company August 9, 1989 Mr. Steve Brady Conoco, Inc. Milne Point Pouch 340045 Prudhoe Bay, Alaska 99503 Re: Our Boss Gyroscopic Survey Job No. AK-BO-90074 Well: E-3 Milne Pt., Alaska Survey Date: August 4, 1989 Operator: D. Harger Mr. Brady: Please find enclosed original and one copy of our Boss Gyroscopic Survey on the above well. Sperry-Sun tied in with Schlumberger at 6471'. Schlumberger information from 100' through 6471'. Sperry's survey starts at 6500'. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services 8537 Corbin Drive (99507) · P.O. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid C, ompar, y SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 0 .00 -52.00 0 0 N .00 E .00 .00 .00 .00 100 100.00 48.00 0 13 N 70.10 E .23 .07N .19E -.06 200 200.00 148.00 0 21 S 88.18 E .16 .13N .68E -.30 300 300.00 248.00 0 24 N 81.49 E .09 .1TN 1.34E -.65 400 399.99 347.99 0 24 N 74.81 E .05 .31N 2.03E -.94 500 499.99 447.99 600 599.99 547.99 700 699.99 647.99 800 799.98 747.98 900 899.92 847.92 0 24 N 80.19 E .04 0 18 S 77.03 E .17 0 12 S 75.11 E .10 0 58 N 10.06 W 1.08 2 34 N 23.84 W 1.65 .47N 2.71E -1.21 .46N 3.32E -1.57 .36N 3.76E -1.91 1.14N 3.79E -1.29 4.03N 2.73E 1.67 1000 999.75 947.75 3 58 N 26.61 W 1.40 1100 1099.33 1047.33 6 19 N 28.18 W 2.36 1200 1198.29 1146.29 10 4 N 33.94 W 3.82 1300 1296.70 1244.70 10 22 N 34.91 W .35 1400 1395.16 1343.16 9 43 N 38.09 W .85 9.19N .27E 7.29 17.14N 3.88W 16.17 29.26N 11.37W 30.37 43.90N 21.40W 48.12 57.94N 31.77W 65.57 1500 1493.14 1441.14 13 15 N 42.17 W 3.62 73.09N 1600 1589.34 1537.34 18 19 N 40.65 W 5.08 93.53N 1700 1683.25 1631.25 21 50 N 40.20 W 3.52 119.67N 1800 1775.99 1723.99 22 5 N 41.50 W .55 147.96N 1900 1867.26 1815.26 26 5 N 42.94 W 4.04 178.15N 44.69W 85.42 62.64W 112.50 84.89W 146.72 109.36W 183.98 136.81W 224.53 2000 1954.97 1902.97 31 14 N 41.68 W 5.19 213.64N 2100 2038.33 1986.33 35 46 N 40.87 W 4.56 255.14N 2200 2119.66 2067.66 35 23 N 40.65 W .41 299.21N 2300 2200.18 2148.18 37 19 N 40.61 W 1.93 344.20N 2400 2279.31 2227.31 38 3 N 40.19 W .78 390.76N 169.05W 272.18 205.44W 327.12 243.44W 385.10 282.03W 444.16 321.65W 505.11 2500 2357.24 2305.24 39 32 N 39.97 W 1.49 438.70N 361.99W 567.59 2600 2432.96 2380.96 41 59 N 39.13 W 2.51 489.04N 403.55W 632.74 2700 2504.89 2452.89 45 59 N 38.87 W 4.00 543.01N 447.24W 702.07 2800 2571.89 2519.89 49 52 N 39.28 W 3.89 600.62N 494.03W 776.17 2900 2634.61 2582.61 52 24 N 39.35 W 2.54 660.85N 543.36W 853.88 3000 2694.31 2642.31 54 16 N 39.67 W 1.88 722.73N 594.39W 933.92 3100 2751.92 2699.92 55 22 N 39.40 W 1.12 785.76N 646.41W 1015.48 3200 2808.96 2756.96 55 4 N 38.86 W .53 849.48N 698.25W 1097.49 3300 2863.98 2811.98 58 9 N 39.68 W 3.15 914.11N 751.11W 1180.82 3400 2916.98 2864.98 57 50 N 39.18 W .53 979.61N 804.96W 1265.46 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. - 52.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DGMN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3500 2970.49 2918.49 57 27 .N 38.92 W .44 1045.21N 858.19W 1349.80 3600 3024.25 2972.25 57 29 N 38.68 W .21 1110.92N 911.02W 1434.01 3700 3078.74 3026.74 56 28 N 38.26 W 1.07 1176.57N 963.18W 1517.77 3800 3133.42 3081.42 57 13 N 38.36 W .74 1242.26N 1015.08W 1601.41 3900 3187.98 3135.98 56 38 N 38.22 W .59 1308~04N 1067.01W 1685.14 4000 3243.22 3191.22 56 17 N 37.62 W .60 1373.79N 1118.24W 1768.44 4100 3297.98 3245.98 57 17 N 38.20 W 1.10 1439.80N 1169.65W 1852.05 4200 3351.59 3299.59 57 52 N 38.49 W .63 1506.01N 1222.02W 1936.39 4300 340.4.73 3352.73 57 55 N 38.01 W .41 1572.53N 1274.46W 2021.02 4400 3457.67 3405.67 58 9 N 38.08 W .23 1639.35N 1326.75W 2105.80 4500 3510.22 3458.22 58 26 N 38.01 W .30 1706.35N 1379.18W 2190.82 4600 3561.93 3509.93 59 16 N 37.76 W .87 1773.90N 1431.74W 2276.35 4700 3613.10 3561.10 59 10 N 37.40 W .33 1841.99N 1484.14W 2362.23 4800 3665.31 3613.31 57 52 N 36.81 W 1.38 1910.00N 1535.59W 2441.49 4900 3718.41 3666.41 57 58 N 36.10 W .61 1978.15N 1585.93W 2532.22 5000 3771.01 3719.01 58 33 N 35.56 W .75 2047.11N 1635.72W 2617.26 5100 3824.01 3772.01 57 25 N 34.95 W 1.25 2116.34N 1684.66W 2702.05 5200 3879.09 3827.09 55 43 N 34.55 W 1.72 2184.91N 1732.23W 2785.49 5300 3935.19 3883.19 56 1 N 34.50 W .29 2253.11N 1779.15W 2868.25 5400 3990.72 3938.72 56 31 N 34.79 W .55 2321.53N 1826.43W 2951.39 5500 4045.09 3993.09 57 36 N 34.93 W 1.10 2390.39N 1874.40W 3035.30 5600 4098.62 4046.62 57 39 N 34.54 W .33 2459.81N 1922.52W 3119.75 5700 4151.93 4099.93 57 54 N 33.84 W .64 2529.79N 1970.07W 3204.32 5800 4204.56 4152.56 58 34 N 35.02 W 1.20 2599.91N 2018.14W 3289.32 5900 4256.89 4204.89 58 19 N 34.84 W .29 2669.78N 2066.93W 3374.52 6000 4309.47 4257.47 58 14 N 34.52 W 6100 4361.85 4309.85 58 34 N 34.21 W 6200 4413.84 4361.84 58 46 N 33.34 W 6300 4465.22 4413.22 59 22 N 32.65 W 6400 4515.72 4463.72 59 57 N 32.20 W .28 2739.73N 2115.33W 3459.56 .43 2810.04N 2163.41W 3544.72 .77 2881.05N 2210.90W 3630.09 .84 2953.00N 2257.62W 3715.77 · 70 3025.85N 2303.89W 3801.92 6471 4551.39 4499.39 60 24 N 31.89 W 6500 4565.36 4513.36 60 19 N 31.80 W 6600 4614.29 4562.29 61 4 N 31.20 W 6700 4663.22 4611.22 60 20 N 30.60 W 6800 4712.22 4660.22 60 58 N 30.90 W .73 3078.62N 2336.92W 3864.04 .40 3099.48N 2349.88W 3888.53 .91 3173.84N 2395.44W 3975.49 .90 3248.67N 2440.23W 4062.37 .69 3323.58N 2484.80W 4149.20 (; SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6900 4761.10 4709.10 60 30 N 31.60 W .78 3398.16N 2530.06W 4236.15 7000 4812.41 4760.41 57 45 N 34.20 W 3.53 3470.23N 2576.65W 4321.85 7100 4865.90 4813.90 57 33. N 34.60 W .39 3539.94N 2624.38W 4406.31 7200 4919.44 4867.44 57 42 N 35.10 W .44 3609.25N 2672.64W 4490.76 7300 4972.63 4920.63 58 2 N 36.00 W .83 3678.15N 2721.88W 4575.44 7400 5025.49 4973.49 58 8 N 36.30 W .27 3746.70N 2771.95W 4660.33 7500 5078.40 5026.40 57 57 N 35.50 W .70 3815.43N 2821.71W 4745.18 7600 5131.80 5079.80 57 29 N 34.70 W .82 3884.60N 2870.32W 4829.72 7700 5185.60 5133.60 57 25 N 35.40 W .59 3953.61N 2918.73W 4914.00 7800 523~.28 5187.28 57 39 N 36.20 W .71 4022.03N 2968.08W 4998.37 7900 5292.72 5240.72 57 44 N 36.50 W .27 4090.11N 3018.18W 5082.89 8000 5345.76 5293.76 58 11 N 36.60 W .46 4158.21N 3068.67W 5167.66 8100 5398.32 5346.32 58 24 N 36.90 W .33 4226.38N 3119.57W 5252.72 8200 5451.59 5399.59 57 14 N 33.10 W 3.42 4295.68N . 3168.12W 5337.33 8300 5505.74 5453.74 57 10 N 33.80 W .59 4365.82N 3214.45W 5421.32 8400 5560.04 5508.04 57 2 N 34.10 W .28 4435.48N 3261.35W 5505.25 8500 5614.60 5562.60 56 49 N 34.30 W .28 4504.79N 3308.46W 5589.02 8600 5669.00 5617.00 57 15 N 34.50 W .47 4574.02N 3355.86W 5672.89 8700 5722.88 5670.88 57 32 N 32.90 W 1.38 4644.10N 3402.60W 5757.07 8800 5776.43 5724.43 57 42 N 33.10 W .23 4714.93N 3448.59W 5841.42 8900 5829.78 5777.78 57 49 N 33.30 W .21 4785.70N 3494.91W 5925.91 9000 5882.78 5830.78 58 10 N 33.90 W .62 4856.33N 3541.83W 6010.64 9100 5935.45 5883.45 58 15 N 34.20 W .27 4926.76N 3589.43W 6095.60 9200 5987.73 5935.73 58 42 N 34.20 W .44 4997.27N 3637.34W 6180.81 9300 6039.68 5987.68 58 42 N 34.50 W .26 5067.82N 3685.56W 6266.24 9400 6092.99 6040.99 56 50 N 35.30 W 1.99 5137.19N 3733.95W 6350.81 9500 6147.70 6095.70 56 49 N 35.20 W .08 5205.55N 3782.26W 6434.51 9600 6201.88 6149.88 57 33 N 35.10 W .73 5274.27N 3830.65W 6518.56 9700 6255.35 6203.35 57 47 N 35.10 W .23 5343.41N 3879.24W 6603.05 9800 6309.83 6257.83 56 10 N 34.20 W 1.78 5412.38N 3926.91W 6686.87 9900 6365.21 6313.21 56 33 N 34.90 W .70 5480.95N 3974.13W 6770.11 10000 6420.40 6368.40 56 26 N 35.10 W .20 5549.26N 4021.96W 6853.49 10100 6475.76 6423.76 56 20 N 35.30 W .19 5617.31N 4069.97W 6936.77 10200 6531.08 6479.08 56 29 N 34.90 W .37 5685.47N 4117.87W 7020.07 10300 6586.26 6534.26 56 31 N 35.10 W .17 5753.78N 4165.70W 7103.45 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. ~- 52.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION, RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT, 10400 6641.21 6589.21 56 49 N 34.80 W ,39 5822,27N 4213.57W 7186.99 10500 6695.88 6643.88 56 53 N 34.80 W .07 5891.02N 4261.35W 7270.71 10600 6750.41 6698.41 57 i N 35.00 W .21 5959,77N 4309.31W 7354.52 10700 6804.16 6752.16 57 57 N 35.00 W .94 6028,85N 4357.68W 7438.84 10800 6856.94 6804.94 58 19 N 35.30 W .44 6098.29N 4406.58W 7523.77 10900 6908.95 6856.95 59 0 N 35.60 W ,73 6167,87N 4456.11W 7609.17 11000 6960.48 6908.48 58 57 N 35.80 W .18 6237.46N 4506.12W 7694.87 11100 7011.97 6959.97 59 3 N 35.80 W .10 6306,99N 4556.27W 7780.60 11200 7063.20 7011.20 59 18 N 36.10 W .36 6376,51N 4606.69W 7866.48 11250 708~.08 7037.08 58 20 N 36.00 W 1.93 6411.10N 4631.86W 7909,26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 79,09.26 FEET AT NORTH 35 DEG. 50 MIN. WEST AT MD = 11250 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 324.15 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -52.00 100 100.00 48.00 200 200.00 148.00 300 300.00 248.00 400 399.99 347.99 0 0 N .00 E .00 .00 .00 .00 0 13 N 70.10 E .23 .07N .19E -.06 0 21 S 88.18 E .16 .13N .68E -.30 0 24 N 81.49 E .09 .17N 1.34E -.65 0 24 N 74.81 E .05 .31N 2.03E -.94 500 499.99 447.99 600 599.99 547.99 700 699.99 647.99 800 799.98 747.98 900 899.92 847.92 0 24 N 80.19 E .04 .47N 2.71E -1.21 0 18 S 77.03 E .17 .46N 3.32E -1.57 0 12 S 75.11 E .10 .36N 3.76E -1.91 0 58 N 10.06 W 1.08 1.14N 3.79E -1.29 2 34 N 23.84 W 1.65 4.03N 2.73E 1.67 1000 999.75 947.75 1100 1099.33 1047.33 1200 1198.29 1146.29 1300 1296.70 1244.70 1400 1395.16 1343.16 3 58 N 26.61 W 1.40 9.19N .27E 7.29 6 19 N 28.18 W 2.36 17.14N 3.88W 16.17 10 4 N 33.94 W 3.82 29.26N 11.37W 30.37 10 22 N 34.91 W .35 43.90N 21.40W 48.12 9 43 N 38.09 W .85 57.94N 31.77W 65.57 1500 1493.14 1441.14 1600 1589.34 1537.34 1700 1683.25 1631.25 1800 1775.99 1723.99 1900 1867.26 1815.26 13 15 N 42.17 W 3.62 73.09N 44.69W 85.42 18 19 N 40.65 W 5.08 93.53N 62.64W 112.50 21 50 N 40.20 W 3.52 119.67N 84.89W 146.72 22 5 N 41.50 W .55 147.96N 109.36W 183.98 26 5 N 42.94 W 4.04 178.15N 136.81W 224.53 2000 1954.97 1902.97 2100 2038.33 1986.33 2200 2119.66 2067.66 2300 2200.18 2148.18 2400 2279.31 2227.31 31 14 N 41.68 W 5.19 213.64N 169.05W 272.18 35 46 N 40.87 W 4.56 255.14N 205.44W 327.12 35 23 N 40.65 W .41 299.21N 243.44W 385.10 37 19 N 40.61 W 1.93 344.20N 282.03W 444.16 38 3' N 40.19 W .78 390.76N 321.65W 505.11 2500 2357.24 2305.24 2600 2432.96 2380.96 2700 2504.89 2452.89 2800 2571.89 2519.89 2900 2634.61 2582.61 39 32 N 39.97 W 1.49 438.70N 361.99W 567.59 41 59 N 39.13 W 2.51 489.04N 403.55W 632.74 45 59 N 38.87 W 4.00 543.01N 447.24W 702.07 49 52 N 39.28 W 3.89 600.62N 494.03W 776.17 52 24 N 39.35 W 2.54 660.85N 543.36W 853.88 3000 2694.31 2642.31 3100 2751.92 2699.92 3200 2808.96 2756.96 3300 2863.98 2811.98 3400 2916.98 2864.98 54 16 N 39.67 W 1.88 722.73N 594.39W 933.92 55 22 N 39.40 W 1.12 785.76N 646.41W 1015.48 55 4 N 38.86 W .53 849.48N 698.25W 1097.49 58 9 N 39.68 W 3.15 914.11N 751.11W 1180.82 57 50 N 39.18 W .53 979.61N 804.96W 1265.46 RECEIVED ~o,,~. ~ommissb~, ~'%~aska 0ii .& ~as ~ ~ ~ Anchorag, a SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3500 2970.49 2918.49 3600 3024.25 2972.25 3700 3078.74 3026.74 3800 3133.42 3081.42 3900 3187.98 3135.98 DATE OF SURVEY: 08-04-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 57 27 N 38.92 W .44 57 29 N 38.68 W .21 56 28 N 38.26 W 1.07 57 13 N 38.36 W .74 56 38 N 38.22 W .59 1045.21N 858.19W 1349.80 1110.92N 911.02W 1434.01 1176.57N 963.18W 1517.77 1242.26N 1015.08W 1601.41 1308.04N 1067.01W 1685.14 4000 3243.22 3191.22 4100 3297.98 3245.98 4200 3351.59 3299.59 4300 3404.73 3352.73 4400 3457.67 3405.67 56 17 N 37.62 W .60 57 17 N 38.20 W 1.10 57 52 N 38.49 W .63 57 55 N 38.01 W .41 58 9 N 38.08 W .23 1373.79N 1118.24W 1768.44 1439.80N 1169.65W 1852.05 1506.01N 1222.02W 1936.39 1572.53N 1274.46W 2021.02 1639.35N 1326.75W 2105.80 4500 3510.22 3458.22 4600 3561.93 3509.93 4700 3613.10 3561.10 4800 3665.31 3613.31 4900 3718.41 3666.41 58 26 N 38.01 W .30 59 16 N 37.76 W .87 59 10 N 37.40 W .33 57 52 N 36.81 W 1.38 57 58 N 36.10 W .61 1706.35N 1379.18W 2190.82 1773.90N 1431.74W 2276.35 1841.99N 1484.14W 2362.23 1910.00N 1535.59W 2447.49 1978.15N 1585.93W 2532.22 5000 3771.01 3719.01 5100 3824.01 3772.01 5200 3879.09 3827.09 5300 3935.19 3883.19 5400 3990.72 3938.72 58 33 N 35.56 W .75 57 25 N 34.95 W 1.25 55 43 N 34.55 W 1.72 56 1 N 34.50 W .29 56 31 N 34.79 W .55 2047.11N 1635.72W 2617.26 2116.34N 1684.66W 2702.05 2184.91N 1732.23W 2785.49 2253.11N 1779.15W 2868.25 2321.53N 1826.43W 2951.39 5500 4045.09 3993.09 5600 4098.62 4046.62 5700 4151.93 4099.93 5800 4204.56 4152.56 5900 4256.89 4204.89 57 36 N 34.93 W 1.10 57 39 N 34.54 W .33 57 54 N 33.84 W .64 58 34 N 35.02 W 1.20 58 19 N 34.84 W .29 2390.39N 1874.40W 3035.30 2459.81N 1922.52W 3119.75 2529.79N 1970.07W 3204.32 2599.91N 2018.14W 3289.32 2669.78N 2066.93W 3374.52 6000 4309.47 4257.47 6100 4361.85 4309.85 6200 4413.84 4361.84 6300 4465.22 4413.22 6400 4515.72 4463.72 58 14 N 34.52 W .28 58 34 N 34.21 W .43 58 46 N 33.34 W .77 59 22 N 32.65 W .84 59 57 N 32.20 W .70 2739.73N 2115.33W 3459.56 2810.04N 2163.41W 3544.72 2881.05N 2210.90W 3630.09 2953.00N 2257.62W 3715.77 3025.85N 2303.89W 3801.92 6471 4551.39 4499.39 6500 4565.36 4513.36 6600 4614.29 4562.29 6700 4663.22 4611.22 6800 4712.22 4660.22 60 24 N 31.89 W .73 60 19 N 31.80 W .40 61 4 N 31.20 W .91 60 20 N 30.60 W .90 60 58 N 30.90 W .69 3078.62N 2336.92W 3864.04 3099.48N 2349.88W 3888.53 3173.84N 2395.44W 3975.49 3248.67N 2440.23W 4062.37 3323.58N 2484.80W 4149.20 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 6900 4761.10 4709.10 7000 4812.41 4760.41 7100 4865.90 4813.90 7200 4919.44 4867.44 7300 4972.63 4920.63 60 30 N 31.60 W .78 57 45 N 34.20 W 3.53 57 33 N 34.60 W .39 57 42 N 35.10 W .44 58 2 N 36.00 W .83 3398.16N 2530.06W 3470.23N 2576.65W 3539.94N 2624.38W 3609.25N 2672.64W 3678.15N 2721.88W 4236.15 4321.85 4406.31 4490.76 4575.44 7400 5025.49 4973.49 7500 5078.40 5026.40 7600 5131.80 5079.80 7700 5185.60 5133.60 7800 5239.28 5187.28 58 8 N 36.30 W .27 57 57 N 35.50 W .70 57 29 N 34.70 W .82 57 25 N 35.40 W .59 57 39 N 36.20 W .71 3746.70N 2771.95W 3815.43N 2821.71W 3884.60N 2870.32W 3953.61N 2918.73W 4022.03N 2968.08W 4660.33 4745.18 4829.72 4914.00 4998.37 7900 5292.72 5240.72 8000 5345.76 5293.76 8100 5398.32 5346.32 8200 5451.59 5399.59 8300 5505.74 5453.74 57 44 N 36.50 W .27 58 11 N 36.60 W .46 58 24 N 36.90 W .33 57 14 N 33.10 W 3.42 57 10 N 33.80 W .59 4090.11N 3018.18W 4158.21N 3068.67W 4226.38N 3119.57W 4295.68N 3168.12W 4365.82N 3214.45W 5082.89 5167.66 5252.72 5337.33 5421.32 8400 5560.04 5508.04 8500 5614.60 5562.60 8600 5669.00 5617.00 8700 5722.88 5670.88 8800 5776.43 5724.43 57 2 N 34.10 W .28 56 49 N 34.30 W .28 57 15 N 34.50 W .47 57 32 N 32.90 W 1.38 57 42 N 33.10 W .23 4435.48N 3261.35W 4504.79N 3308.46W 4574.02N 3355.86W 4644.10N 3402.60W 4714.93N 3448.59W 5505.25 5589.02 5672.89 5757.07 5841.42 8900 5829.78 5777.78 9000 5882.78 5830.78 9100 5935.45 5883.45 9200 5987.73 5935.73 9300 6039.68 5987.68 57 49 N 33.30 W .21 58 10 N 33.90 W .62 58 15 N 34.20 W .27 58 42 N 34.20 W .44 58 42 N 34.50 W .26 4785.70N 3494.91W 4856.33N 3541.83W 4926.76N 3589.43W 4997.27N 3637.34W 5067.82N 3685.56W 5925.91 6010.64 6095.60 6180.81 6266.24 9400 6092.99 6040.99 9500 6147.70 6095.70 9600 6201.88 6149.88 9700 6255.35 6203.35 9800 6309.83 6257.83 56 50 N 35.30 W 1.99 56 49 N 35.20 W .08 57 33 N 35.10 W .73 57 47 N 35.10 W .23 56 10 N 34.20 W 1.78 5137.19N 3733.95W 5205.55N 3782.26W 5274.27N 3830.65W 5343.41N 3879.24W 5412.38N 3926.91W 6350.81 6434.51 6518.56 6603.05 6686.87 9900 6365.21 6313.21 10000 6420.40 6368.40 10100 6475.76 6423.76 10200 6531.08 6479.08 10300 6586.26 6534.26 56 33 N 34.90 W .70 56 26 N 35.10 W .20 56 20 N 35.30 W .19 56 29 N 34.90 W .37 56 31 N 35.10 W .17 5480.95N 3974.13W 5549.26N 4021.96W 5617.31N 4069.97W 5685.47N 4117.87W 5753.78N 4165.70W 6770.11 6853.49 6936.77 7020.07 7103.45 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 10400 6641.21 6589.21 56 49 N 34.80 W 10500 6695.88 6643.88 56 53 N 34.80 W 10600 6750.41 6698.41 57 1 N 35.00 W 10700 6804.16 6752.16 57 57 N 35.00 W 10800 6856.94 6804.94 58 19 N 35.30 W .39 5822.27N 4213.57W 7186.99 .07 5891.02N 4261.35W 7270.71 .21 5959.77N 4309.31W 7354.52 .94 6028.85N 4357.68W 7438.84 .44 6098.29N 4406.58W 7523.77 10900 6908.95 6856.95 59 0 N 35.60 W .73 6167.87N 4456.11W 7609.17 11000 6960.48 6908.48 58 57 N 35.80 W .18 6237.46N 4506.12W 7694.87 11100 7011.97 6959.97 59 3 N 35.80 W .10 6306.99N 4556.27W 7780.60 11200 7063.20 7011.20 59 18 N 36.10 W .36 6376.51N 4606.69W 7866.48 11250 7089.08 7037.08 58 20 N 36.00 W 1.93 6411.10N 4631.86W 7909.26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7909.26 FEET AT NORTH 35 DEG. 50 MIN. WEST AT MD = 11250 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 324.15 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -52.00 1000 999.75 947.75 2000 1954.97 1902.97 3000 2694.31 2642.31 4000 3243.22 3191.22 .00 .00 .00 9.19 N .27 E .25 .25 213.64 N 169.05 W 45.03 44.78 722.73 N 594.39 W 305.69 260.66 1373.79 N 1118.24 W 756.78 451.09 5000 3771.01 3719.01 6000 4309.47 4257.47 7000 4812.41 4760.41 8000 5345.76 5293.76 9000 5882.78 5830.78 2047.11 N 1635.72 W 1228.99 472.21 2739.73 N 2115.33 W 1690.53 461.54 3470.23 N 2576.65 W 2187.59 497.06 4158.21 N 3068.67 W 2654.24 466.65 4856.33 N 3541.83 W 3117.22 462.98 10000 6420.40 6368.40 11000 6960.48 6908.48 11250 7089.08 7037.08 5549.26 N 4021.96 W 3579.60 462.37 6237.46 N 4506.12 W 4039.52 459.92 6411.10 N 4631.86 W 4160.92 121.41 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = OPERATOR: D. HARGER 52.00 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 0 .00 52 52.00 152 152.00 252 252.00 352 352.00 -52.00 .00 .00 .00 .00 .01 N .02 E .00 100.00 .13 N .40 E .00 200.00 .12 N 1.01 E .00 300.00 .23 N 1.71 E .01 .00 .00 .00 .00 452 452.00 552 552.00 652 652.00 752 752.00 852 852,00 400.00 .41 N 2.38 E .01 500.00 .51 N 3.06 E .01 600.00 .40 N 3.58 E .01 700.00 .41 N 3.91 E .01 800.00 2.16 N 3.55 E .03 .00 .00 .00 .00 .02 952 952.00 1052 1052.00 1153 1152.00 1254 1252.00 1356 1352.00 900.00 6.31 N 1.71 E .14 1000.00 12.65 N 1.48 W .40 1100.00 23.00 N 7.31 W 1.11 1200.00 37.19 N 16.73 W 2.56 1300.00 52.09 N 27.21 W 4.20 .11 .26 .71 1.45 1.64 1457 1452.00 1560 1552.00 1666 1652.00 1774 1752.00 1883 1852.00 1400.00 66.26 N 38.65 W 5.86 1500.00 84.73 N 55.02 W 8.89 1600.00 110.42 N 77.05 W 14.48 1700.00 140.67 N 102.90 W 22.11 1800.00 172.77 N 131.82 W 31.07 1.65 3.03 5.60 7.63 8.95 1996 1952.00 2116 2052.00 2239 2152.00 2365 2252.00 2493 2352.00 1900.00 212.32 N 167.87 W 44.54 2000.00 262.59 N 211.89 W 64.85 2100.00 316.65 N 258.40 W 87.67 2200.00 374.42 N 307.85 W 113.31 2300.00 435.38 N 359.21 W 141.21 13.47 20.31 22.83 25.64 27.89 2625 2452.00 2769 2552.00 2928 2652.00 3100 2752.00 3277 2852.00 2400.00 502.61 N 414.58 W 173.85 2500.00 582.76 N 479.46 W 217.56 2600.00 678.32 N 557.68 W 276.50 2700.00 785.85 N 646.49 W 348.14 2800.00 899.46 N 739.00 W 425.54 32.65 43.71 58.95 71.63 77.40 3465 2952.00 3651 3052.00 3834 3152.00 4015 3252.00 4200 3352.00 2900.00 1022.67 N 839.99 W 513.63 3000.00 1144.78 N 938.08 W 599.47 3100.00 1264.89 N 1032.99 W 682.32 3200.00 1384.22 N 1126.27 W 763.82 3300.00 1506.51 N 1222.42 W 848.76 88.10 85.84 82.85 81.50 84.94 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER 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 4389 3452.00 4580 3552.00 4774 3652.00 4963 3752.00 5151 3852.00 3400 3500 3600 3700 3800 .00 .00 .00 .00 .00 1632.17 N 1321.12 W 1760.68 N 1421.50 W 1893.03 N 1522.88 W 2021.81 N 1617.63 W 2152.00 N 1709.54 W 937.26 88.50 1028.56 91.29 1122.97 94.41 1211.55 88.59 1299.70 88.15 5330 3952.00 5512 4052.00 5700 4152.00 5890 4252.00 6081 4352.00 3900 4000 4100 4200 4300 .00 .00 .00 .00 .00 2273.66 N 1793.27 W 2399.33 N 1880.64 W 2529.89 N 1970.13 W 2663.27 N 2062.40 W 2796.70 N 2154.34 W 1378.07 78.37 1460.91 82.83 1548.14 87.23 1638.68 90.54 1729.10 90.42 6274 4452.00 6472 4552.00 6677 4652.00 6881 4752.00 7074 4852.00 4400 4500 4600 4700 4800 .00 .00 .00 .00 .00 2934.19 N 2245.57 W 3079.53 N 2337.49 W 3231.70 N 2430.20 W 3384.47 N 2521.63 W 3521.93 N 2611.96 W 1822.05 92.95 1920.99 98.94 2025.32 104.33 2129.52 104.21 2222.08 92.56 7261 4952.00 7450 5052.00 7637 5152.00 7823 5252.00 8011 5352.00 4900 5000 5100 5200 5300 .00 .00 .00 .00 .00 3651.40 N 2702.44 W 3781.09 N 2797.14 W 3910.65 N 2888.36 W 4038.24 N 2979.95 W 4166.28 N 3074.66 W 2309.03 86.95 2398.21 89.17 2485.58 87.38 2571.78 86.20 2659.83 88.06 8200 5452.00 8385 5552.00 8568 5652.00 8754 5752.00 8941 5852.00 5400 5500 5600 5700 5800 .00 .00 .00 .00 .00 4296.21 N 3168.47 W 4425.21 N 3254.40 W 4552.23 N 3340.88 W 4682.56 N 3427.50 W 4815.22 N 3514.30 W 2748.76 88.93 2833.22 84.46 2916.56 83.34 3002.29 85.73 3089.73 87.44 9131 5952.00 9323 6052.00 9507 6152.00 9693 6252.00 9876 6352.00 5900 6000 6100 6200 6300 .00 .00 .00 .00 .00 4948.89 N 3604.46 W 5084.53 N 3697.04 W 5210.93 N 3786.05 W 5339.06 N 3876.18 W 5464.55 N 3962.69 W 3179.46 89.72 3271.73 92.27 3355.86 84.13 3441.72 85.86 3524.03 82.31 10057 6452.00 10237 6552.00 10419 6652.00 10602 6752.00 10790 6852.00 6400.00 6500.00 6600.00 6700.00 6800.00 5588.19 N 4049.35 W 5711.39 N 4135.95 W 5835.82 N 4222.99 W 5961.77 N 4310.71 W 6091.76 N 4401.95 W 3605.13 81.11 3685.90 80.77 3767.72 81.82 3850.92 83.19 3938.59 87.68 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 8 CONOCO INC. E-3 MILNE POINT ALASKA COMPUTATION DATE: 8/ 7/89 DATE OF SURVEY: 08-04-89 JOB NUMBER: AK-BO-90074 KELLY BUSHING ELEV. = 52.00 FT. OPERATOR: D. HARGER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10983 6952.00 6900.00 11178 7052.00 7000.00 11200 7063.20 7011.20 6226.03 N 4497.88 W 4031.55 92.95 6361.27 N 4595.57 W 4126.06 94.51 6376.51 N 4606.69 W 4136.80 10.74 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS Telecopy No. (907) 276-7542 September 17, 1990 D J Raint-~ee Foreman, Milne Pt Prod Conoco Inc 3201 C St Ste 200 Anchorage, AK 99503-2689 Dear Mr Raintree: On September 13, 1990, we received a form 10-407 (Well Co~te~..~% or Re~omple~ion Report and Log) for Milne Point Unit wel~-? This form is lacking important information, and was filed wi-lb us approximately one year after the date stipulated by the State of Alaska Administrative Code. We find Conoco to be negligent in its responsibility to comply with State of Alaska regulations in this matter. Be advised that further such lapses of responsibility cannot be tolerated. Specifically, the form 10-407 lacks the following information: i) the location of the well at the top o! the target formation and at total depth; 2) the well elevation; 3) the true vertical depth oi the well~ and, 4) a copy of the well's directional survey. Please call me at 279-1433 as soon as possible to inform me as to when a revised form 10-407 for Milne Point well E-3 will be submitted. Should you or your staff feel the need to have Conoco's reporting requirements to this agency verbally presented, we can discuss this at that time. jo/B2. PCPC. 42 · ' ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Status of Well Clztss~f:cat,on of Se~wce Well 'OIL .~ GAS"-; SUSPENDED ~n ABANDONED ~ SERVICE 2. Name of Operator CONOCO ]NC. 3. Address P.O. Box 340045, Prudhoe Bay, Ak 99734 4. Location of well at surface 1251' FNL, 2178 FEL, SEC 25, T13N, RIOE, UM~ At Top Producing Interval At Total Depth 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. AD. 47.437 12. Date Spudded ~7-!4-89 17. Total Depth (MD+TVD) ll,520'MD 13. Date T.D. Reached 1~. Pl~g-Ba~t~ Depth (M~+-TVD) 11,241 ND 7085 7. Permit Number 8g-17 8 APl Number so- 02g-21g16 9. Unit or Lease Name HILNE POINT UNIT ~0, ,,~/e I I Number I 1. Field and Pool KUPARUK RIVER FIELD 14. Date Comp.,Susp. or Aband. 'l 15. Wa[er Depth, if offshore 116' No. of Completions 8-6-_R9 I N/A feet MSL/ ] 19. DirectionalSurvey ) 20. DePtr~hereSSSVset I 21. Thickness of Permafrost YES F~ NO ~( 5321 feet MD +1900'RKB 22. Type Electric or Other Logs Run 23. SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM 13-3/8" 45.9 H-40 SURFACE _ I 9-3/8" 47 L-80 SURFACE , f7" 39 L-80 SURFACE 24. Perforations open to Production (MD+TVD of Top and )ottom and t0n~al~.~r~d number) 11096-11130 HD =7008' - 7025'TVD 11150-11208 MD =7035' - 7065'TVD 6 SHOTS PER FOOT 0.47 IN DXA. 12.57 IN PENETRATION CASING, LINER AND CEMENTING RECORD 1 HOLE SIZE CEMENTING RECORD ]AMOUNT PULLED COLD SET TO SURFACE N/A 110'RKB 6679 11,375 30" ' :1.2-1/4" 8-1/2 622BBLSTYPEE, 56CLAS~;G N/A 86BBLS CLASS G 25. TUBING RECORD SIZE [ DEPTH SET (MD) Z-I/8".6.5L[J/FI 10164 1", 2.5LB/FT) 2056 N/A PACKER SET (MD) 10i09 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. Date First Production PRODUCTION TEST INJECTION 8-11-89 Date of Test F Iow Tubing Press. Hours Tested Casing Pressure iMethod of Operation (Flowing, gas lift, etc.) IPRODUCTION FOR TEST PERIOD ~ 2C. 41 LHCoUuLRARTAE TDE ~ OIL-BBL GAS-MCF OIL-BBL GAS-MCr CORE DATA WATER-BBL I CHOKE SIZE GAS-OIL RATIO I WATER-BBL IOIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED 4,000 HCF/DAY GAS INJECTION l)4200 PSI TUBING PRESSURE . RECEIVED Form 10-407 Rev. 7.1-80 1 i; ~,.,,~,., ,':~iaska Qjl & Gas Cons. C0mm~s~ic~,,'~. ~, CONTINUEDON REVERS~SIDE Alaska 0il & Gas Cons. Anchorage Submit in duplicate GEOLOGIC MARKERS NAME LK1 LK I MEAS. DEPTH 7O0 8 702.5 TRUE VERT. DEPTH 7oZ5 'TVD 7o~5' TV O 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that t,~regoing is true and correct to the best of my knowledge Signed ~' Title 0~',' 04/ Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt~., water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10407 R[C£1V£D CHRONOLOGICAL WELL HISTORY O]l~as- ~o~s. ¢~°mrnis~ion July 14, 1989 Accept rig. Function test DiVerter System. Ok. Pick up bottom hole assembly, tag bottom at 100'. Drill to 620'. July 15 Drill to 692' using Navidrill. Pooh, Change out MWD. RIH, MWD not working, POOH. RIH, Drill 692~ to 783'. Unable to build angle, POOH. PU Navidrill and bent sub. RIH. Attempt circulate, DP screen parted, POOH. RIH and drill to 1106'. July 16 Continue drilling from 1106'-1252°. POOH, change BHA. Lay down straight motor and Bent Sub. PU Bent Housing Navidrill. Slip and cut drill line. RIH. Drill 1252-2165'. Continue to build hole angle. J~lv 17 Take directional survey. POOH and lay down 4 jts. Ream 6 degree dog leg back to 3 1/2. Drill from 2165' to 2257'. Pump pill, short trip, drill to 2377'. Pump pill POOH. PU Navidrill, RIH. Side track Well bore, Drill 1350 to 1415'. Drill 1415' to 1816'. July 18 Drill to 2125', pump pill. POOH. Pick up stabilizer. PU new Bit and Navidrill (1/2 degree). Rih to 1992. Take directional survey. Ream 1992' to 2125 twice. Drill 2125' to 3166'. July 19 Drill to 3225~. Short trip, clean. Drill to 4043'. Short trip to 1300', pulled 60k over at 3200'. Slip and Cut 90' drill line. RIH to 4039', tagged 4' fill. Drill to 4380'. July 20 Drill to 4453. Circulate and condition mud. (9.5 ppg). POOH for MWD failure. RIH w/ new BHA to 4453, clean trip. Drill to 5179°. Short trip, clean. Drill to 5211'. July 21 Drill to 5300°. Mud wt. cut from 9.6 to 9.4 by gas. Drill to 5590'. Drill break at 5470', Mud wt. cut from 9.8 to 8.7, by gas, no flow w/pumps off. Circulate and condition mud. Drill to 5773'. Short trip to 5100, clean trip. Drill to 6152, short trip to 5475', clean trip. Drill to 6183. July 22 Drill to 6700'. Short trip to 4754, clean trip. Circulate and condition. POOH to 1427'. Pipe will not pull past 1427', free going down, work pipe to 1387'. July 23 Work pipe to 1327'. POOH, tight spot at 1075'. Retrieve single shot survey. Survey disagrees w/ MWD by 5 degrees to north. L/D BHA. P/U new BHA.. RIH to 1100'. Work pipe through 1100 to 1600'. No tight spots seen. RIH to 6175, Wipe out tight spot at 6175', TIH to 6612', Wash and ream to 6675', ream to 6700' although no tight spots found. Circulate and condition. POOH f/ 6700', clean trip. R/U to run casing, held safety meeting w/ all. RIH w/ 170 jts of 47 ~/ft. Ran 88 centrilizers. Full returns while running pipe. July 24 Finish running 170 jts of 47 ~/ft, 9 5/8 casing with buttress threads. RU cement head and cement line. Pump 40 bbls of 10 ppg Sepiolite preflush followed by 5 bbls H20. Test lines to 4000 psi. Mix and Pump 622 bbls of 12.2 ppg Permafrost type E with 5 lb./sk Gilsonite and additional .05% Sodium Citrate. Full returns while pumping. Mix and pump 56.5 bbls of 15.8 ppg Class G with 1% Gel, .2% CFR-3 and 3% salt. Lost retuns with 38 bbls of tail cement away. Displace top plug with 483 bbls of Water at 4/6 BPM. Estimate cement top at 4200' md. Bump-plug and press up to 2500 psig. Floats held. N/D diverter. Perform top job at 110' RKB w/ 20 bbls of 15.6% ppg Permafrost type C.. Good cement returns to surface. M/U split speed head. NU BOP, Run Schlumberger GCT Gyro directional survey while NU, from RKB to 6550' MD. July 25 RIH w/ BHA to 6592', tag cement. Test casing to 1500 psi for 30 minutes, ok. Drill to 6710°, Circulate. Run EMW test=il.8 ppg. Drill to 7652. July 26 Short trip to shoe. Drill to 8368'. Wiper trip to shoe. Repair rotary clutch. Break circulation, ream 40' fill to bottom. Drill to 8585'. July 2.7. Drill to 9023'. Short trip 10 stds, ream 40' to bottom, no fill. Drill to 9525°, repair rotary chain. Drill to 9860'. 9.6 ppg mud. Drill to 9900'. circulate bottoms up, pump slug. POOH, P/U RLL, RIH to shoe. Cut and slip drill line. RIH, ream 30' to bottom, no fill. Drill to 9990'. Repair rotary chain and guard. Drill to 10221'. July 29 Drill to 10278'. Tighten rotary chain. Short trip 10 stds, no fill. Drill to 10661'. fill. Drill to 10,860'. Drill to 10304. E]¥,E B Alaska.Oil & Gas Cons. uommissio. ;Anchorage July 30 Drill to 10936', change shaker screens, Drill to 10982'. drill to 11168'. Circulate bottoms up, take survey. POOH, LD turbine and Dir MWD, RIH to 8900', fill DP. July 31 RIH to 10900'. Ream and log 10900 to 11168°. Drill to 11520. Circulate, short trip to shoe, RIH. Au~ 1 RIH wash and ream 28~ to bottom 10' fill. Circulate and condition mud. POOH, LD DP. Cut drill line. LD BHA. Pull wear bushing, set test plug, test rams and Annular, RU Casing crew, RIH w/ 60 jts 7" 29~, L-80 Buttress casing. Au~ 2 Continue to run casing to 9 5/8 shoe. Drop ball and shift sleeves of float collar and float shoe. Wait on ball and circulate. Run Casing to 11369' (wlm) and pipe stuck. Pipe stuck and packed off, attempt to circulate and work pipe while waiting on HLS. P/U 120,000 lbs over string wt.. Little or no movement, pressure up to 2000 psi, pumping away mud at 3.5 bbls/minute. Aug 3 Rig up HLS and run GR and CCL from 10700' to 11292'. complete fab of XO from 7° buttress to lubricator. RfO lubricator and test to 1000 psi. RIH w/ perf guns, tie in and shoot 8 shots from 11288 to 11290. POOH w/ guns. RU circulating head and circulate through perfs. 30 spm at 750 psi, 50 spm at 950 psi. Became packed off while circulatin, reestablish circulation at 20 spm, slowly increase to 45 spm, full returns. RU cementers and pump 40 bbl of 10 ppg sepiolite, 86 1/2 bbls of 15.8 ppg class g w/ .2% cfr-3. Drop plug and displace with 9.6 ppg NaC1 brine at 3 to 5 bpm, full returns. Bump plug 200 psi over circ. pressure, and hold pressure. ND and set 7" slips with 150,000 ~'s. Continue to hold press on casing. A.u~ 4 Hold Press on casing. Press gradually bled off from an initial pressure of 800 psig. Bleed press off of csg. slight flow from casing, continuous. Cut casing and set 7' packoff, NU stack and test broken flanges. Tested pack off to 3500 psig for 15 minutes. Run gauge ring (6"), Junk Basket to 11288', no obstructions, POOH. Press. test casing to 500 psi, ok, 1000 psi, slow leak, 1500 psi, slow leak, 2000 psi slow leak. Rig up and run gyro survey to 11,250' pooh making check shots, good survey. Atasl~a Oil & Bas Co~s. Commissioit Anchorage PU Halliburton EZ drill w/ bridge plug on Baker Model 20 setting tool, RIH to 11,241~, cannot get below this depth. Work tools from 11,215 to 11,241, would not fall past this depth. Detonate setting tool and place EZSV at 11,241'. POOH. RU lubricator, pressure test to 500 psi. RU and CBL w/ GR w/ 3 centrilizers. Estimated cement top at 9404~. Generally poor bonding. POOH. RD HLS, Pressure test 7~ casing to 3200 psig, good test. RU to run tbg. Run 2 7/8", 6.5 ~/ft CS Hydril tubing, 324 joints. Set 2 7/8 in slips, RU to run dual string. RIH with 1 1/8, 2.5 ~/ft hydril side string. Aug 6 Continue running 1 1/8 side string. PU scssv, run 2 strings in together. PU tbg hanger and control line, test control line to 5000 psig, land tbg., drop ball and engage tubing hanger lockdown screws. RU to high pressure pump to set packer. Set packer and pressure test to 4000 psig, hold for 15 minutes, good. Backout lockdown screws, PU and displace tubing w/ 74 bbls of diesel. Pumped 60 bbls of diesel into 7" annulus. Land tubing, install 2 way check, ND BOP, NU xmas tree, test tubing hanger, 2 7/8 slickneck and 1 1/8 slickneck, and sssv line to 5000 psi. Test tree to 5000 psi. Pull 2 way check , test tubing to 2000 psi for 30 minutes per Bobby Foster. Release pressure, Pump down 1 1/8 side string w/ 3 bbls diesel to press, annulus to 2000 psi and hold for 30 minutes per AOGCC. Rig released at 1900 hrs. RECEIVED Oil & Gas Co,is. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCRIPTION Copy sent YES to sender NO RETURN ADDRESS FROM: HALLIBURI'ON L_OGGING SERVICES F'. 0. BOX ..'.:,~.. , AI',ICHORAGE, ALASKA 9~523 TO: CLAIM CHECK NO, / ':-. '.:~ ~. _ ~. /.,~ U. o. !' ::. ; ' LOGGING SERVICE~ INC ~,~' ' ' ~ ' ' ' ~;~.,?~ ,,: .'. ALASI<A OIL. AND {BAS C[]NSEIRVAT I ON [][]MM I SS I ON 30 (') 1 F:'[]R C UF' I N E DR I VE AI'~.ICHORAGE, AI_ASKA 99501 /~'l-'Tl'q .". .] I'll--IN RFiYt F DATE )STMASTER: CONTENTS FIRST CLASS MAIL Alaska 0il & Form HLS-7(~[il ~,$T I~K)TICE · eo!AJeS ;dleoel:l uJnteu .6ulsn JOj noX Hueql CI I:! I I-I- I I~1 Ill TO: Mr. John Boyle Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 DATE: TRANS.#: August 15, 1989 89-713AK REFERENCE: CONOCO Milne Point E-3 The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad. ENCLOSED INFORMATION SUMMARY Well E-3 MD: TVD: Digital: 1 Each Blueline; Total 3 1 Each Sepia; Total 3 1 Each Blueline; Total 1 1 Each Sepia; Total 1 1 LIS Tape 1 LIS Tape Verification Listing Received By: A.O.G.C.C. / Date 8537 Corbin Drive (99507) · P.O. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 August 8, 1989 Mr. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Ak 99501 Dear Mr. Chatterton Re: Application to Begin Gas Injection, MPU E-3 Please be advised that Conoco Inc. will begin gas injection into the newly completed MPU E-3 gas injection well on or about August 12, 1989. We have already notified your office and have been given verbal permission to begin injection. Initial injection rates will be 4-5 mmcf per day. If you have any questions, please contact Hal Stevens or Bob Soptei at 659-6327. Yours very truly, E. L. Robinson/D. F. Rainwater Senior Foreman CC Production Superintendent Safety & Compliance Coordinator MEMORAND' M State Alaska ALASKA OIL AND GAS CONSERVATION COM~IISSION TO: Lonn i e C. Sm i t ~'-/~' DATE: Commi ss i oner FILE NO: July 19, 1989 D. BDF. 075 THRU: FROM: TELEPHONE NO: Michae 1 T. Minder ~ ~,,~, SUBJECT: Sr. Petroleum Engineer Bobby D Fosteri :.-~- Petroleum Inspector Diverter ~nspection Conoco - ~PU~3 Permit No. 8[-17 Milne Pt. Field Friday, July 14, 1989, I was contacted by Jim Fox, Conoco Rep who ~:~L::~:'-fhh~'-~h~-~iverter on Parker rig 141 on well D-3 between 11:00 mn and 4:00 pm. I arrived at the rig at 10:30 am and inspected the petition of the system that was rigged up. The only problem was neither vent line was tied down. I requested this be correct and departed the location. I returned to the location at 6:30 pm and both lines had been secured. I inspected the remainder of the system and found it in compliance with ACf.~CC and API RP 53 regulation. In sun~ary, I inspected the diverter on Conoco's D-3. 02-001A (Rev. 8/85) Conoco Inc. ,..~ Milne Point Operations Ce~nter Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 July 10, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gent 1 emen .' Attached is an Application For Sundry Approval for Well E-3 at Conoco's Milne Point Unit, submitted in triplicate. Please contact Hal Stevens or Bob Soptei if you should have any questions. Yours very truly, D. F. Rainwater Senior Production Foreman STATE OF ALASKA ALASKA el L AND GAS CONSERVATION COM M IUSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program ~ 2. Name of Operator CONOCO INC. Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 3. Address q~nl c_ ~T ~TI:' ~nn A.rHnD~m: aa,::nq 4. L~'a~i~)n ~)f v~e~l ~t'suT-fC.~'e -- -' .................. 1250'FNL, 2178'FEL, SEC25,T13N,R10E,UH,NSB* At top of productive interval NO CHANGE At effective depth 'NA At {~tal depth NO CHANGE *REVISED 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) DF 28 7. Unit or Property name MTI MI:' DflTMT IIMTT 8. Well nb~g~ ............ F-~ 9. Permit number 8g-17 10. APl number 50-- n~a_?lalA 11. Field/Pool KUPARUK RIVER feet 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor 80 Surface No Intermediate Production Liner Perforation depth: measured feet Plugs (measured) true vertical NO Change feet No Change measured N/A feet Junk (measured) true vertical feet N/A Length Size Cemented true vertical 13 3/8" GL to 80' Changes To be determined after logging Tubing (size, grade, and measured depth) 2 7/8", L80, 6.5 ] b/ft Packers and SSSV (type and measured depth) 7" 29 N/A N/A N/A N/A Measured depth 80' Depths to True vertical depth 80' Non-eq 1 zng lb X 2 7/8, Otis HCM Perm. Pkr, SSSV Otis FMX 2.313 13. Attachments Description summary of proposal -X.- Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation n~,.~ll.~nn +n han"~n 711qlRq 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service TA k-- 17. I hereby certif~the foregoing istrue and correct to the best of my knowledge. Signed ~ ~,, /~¢,'~~ T itle-~cm'inv' Pr'nd-O~eman - FOR COMMISSION USE Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner I Approva, No. Approved Co~y Returned Date V- I~/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE SUPPLEMENTAL DATA SHEET APPLICATION FOR SUNDRY APPROVAL CONOCO MILNE POINT UNIT WELL E-3 CONOCO INC. P.O. Box 340045 Prudhoe Bay, Al( gg734 1) Reason for change: Allow easier placement of drilling rig. Moved surface location 15' to the NW of originally proposed location. Target depth and target location remain unchanged. The distance to the nearest well, E- 2, is at the surface and is 125'. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIUSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program ---X Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Per/orate __ Other __ 2. Name of Operator CONOCO INC. 3. Address ANCHORAGE 99503 4. Location of well at surface 1262' FNL, 2169' FEL, SEC 25, T13N, At top of productive interval 200' FNL, 1300' FEL, SEC 23, T13N, At effective depth N/A At total depth 218' FSL, 1590' FEL, SEC 14, T13N, 5. Type of Well: Development __ Exploratory __ Stratigraphic Service '-~ RIOE, U.N. RIOE, U.M. RIOE 6. Datum elev~iCn ~D8F or KB) 7. Unit or Property name MILNE POINT UNIT 8. Well number E-3 9. Permit number 89-17 10. APl number 5o- 029-21916 1t. Field/Pool Kuparuk feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: determined Length 11508' 7370' N/A measured To be after loggi ng true vertical Tubing (size, grade, and measured depth) 2 Packers and SSSV (type and measured depth) feet feet feet feet Size 13 3/8" 9 5/8" 7" 7/8", 65. Otis HCM Plugs (measured) N/A Junk (measured) N/A Cemented Measured depth True vertical depth No Change No Change No Change No Change Substitute No Change Dead 0il for Arctic Pak (60 bbls)'t' lb/ft. L-80, 11400' Perm, depth to be dtrmnd, SSSV Series 10 @ 500' 13. Attachments Description summary of proposal __ Detailed operations program __ *Only change is Dead Oil in place of Arctic Pak BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved 05/09/89 Oil __ C. V. Chatterton Name of approver Date approved Service 17. I hereby certify ~the foregoing is true and correct to the best of my knowledge. Signed ~. /~--,~~-/ Title Senior Prod. Foreman FOR COMMISSION USE ONLY 15. Status of well classification as: Gas ~ Pressure Suspended __ Maintenance Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10-. Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGIN.al_ Sff.',~.~F.,9 BY LONNIE C, ~M~TH ApProved COpY Returnc.d Commissioner I Approval N o. ~'"~ Date ,_~---~--- ~ ~ SUBMIT IN TRIPLICATE Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 May 17, 1989 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive, Anchorage, Alaska 99501 RE: Sundry Notices for Milne Point Unit Wells Dear Mr. Chatterton: Please find attached Sundry Notices for the following Milne Point Unit Wells: B-23, C-20, E-3, and CFP-1. These notices have all been verbally reviewed by members of your staff. Should you have any questions, please contact either Roy Robinson or Doug Rainwater at 659-6323. Thank you for your time and consideration. D. F. Rainwater/E. L. Robinson Senior Production Foreman March 6, 1989 Telecopy: (907)276-7542 D. F. Rainwater Senior Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alaska 99503 Re: Milne Point Unit No. E-3 Conoco Inc, Permit No. 89-17 Sur. Loc. 1262'FNL,2169'FEL, Sec. 25, T13N, R10E, UM. Btmhole Loc. 218'FSL, 1590'FEL, Sec. 14, T13N, R10E, UM. Dear Mr. Rainwater Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment~installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. / - ? o, ;. // / i /k'?// / . ....... C. ~. Cha~ton' ' Chai~n of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco Inc. Milne Point Operations Center Pouch 340045 Prudhoe Bay, AK 99734 (907) 659-6300 February 13, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, kK 99501 Attn. Mr. Mike Minder CCMM 'COMM RES ENG SR ENG SR ENG ENG AS,ST -~NG ASST SR GEOL GEOt. ASST GEOl. ASST _ STAT TECH STAT TECH T-- FILE - RE: Revisions to Permit to Drill Applications Dear Mr. Minder: Please find attached three (3) copies each of revisions for Conoco's Milne Point Unit B-23, C-20, and E-3 Permit to Drill. We have addressed your three concerns and have made the appropriate changes as discussed with you on the telephone on February 10, 1989. Should you have any more questions, please contact Roy Robinson or Doug Rainwater at 659-6323. Thank you very much, D. F. Rainwater/E. L. Robinson Senior Foreman RECEIVED FEB 1 6 1989 A!aska 0ti & Gas Cons. Commission Ar, chorage "'-""-. STATE OF ALASKA ALASK,.. ~. AND GAS CONSERVATION ~. -,,,'1MISSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work Drill [] Redrill ~1 lb. Type of well. ExplOratory [] Stratigraphic Test [] Development Oil Re-Entry D Deepen~1 Service [] Developement Gas [] Single Zone ~ Multiple Zone 2. Name 'of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool CONOCO, TNC. KB 28 feet 3. Address 6. Property Designation 3201 C St. Suite 200, Anchorage, AK 99503 ADL 47437 Kuparuk River Field -'~,. 'Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1262'FNL,2169'FEL,Sec'25,T13N,R10E,U'M',NSB,iAK Milne Point Unit Blanket At top of productive interval 8. Well nurpber Number 8086-15-54 200' FNL, 1300' FEL, Sec. 23, T13N, R10E g-3 At total depth 9. Approximate spud date Amount $200,000 218'FSL,1590'FEL,Sec.14,T13N,R10E June 10, 1989 .... 12.'Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line , 3980 feet 115' to g-2 @ Surffeet 2560 111508'l~)/7370'TVDfeet , , ,, '161 To be completed for deviated wells 17. Anticipated pressure <see ~0 AAC 25.035 Kickoff depth 500 feet Maximum hole angle 55 0 Maximum surface 3200psig At total depth (TVD) 3700 ps~g ...... 1'8'. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight- Grade Coupling Length MD TVD MD TVD (include stage data) 30" 13-3/8' 48~. H-40 WELD 80' 28' 28' 108' 108' _~485 sks Permafrost C 12-1/4" 9-5/8' 47~ L-80 BTRS 6681' 28' 28' 6709' 4650' ~-1969 sks Permafrost E _~272 sks Class G 8-1/2" 7" 29# L-80 BTRS 11480' 28' 28' L1508' 7370' _~412 sks Class G _~180 sks Permafrost C 19. To be completed for Redrill, Re-entry, and Deepen Operations. + 60 Bbls Arctic Pac 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 Measured depth True Vertical depth Structural Conductor RE<i iV'ED Surface Intermediate ]:::'EB ~, 6 ].~J Production Liner Alask; 0il & ,;:is C0il::, ' ' ' ' Perforation depth: measured A,'!~:h: true vertical 20. Attachments Filing fee F~ Property plat ~ BOP Sketch ~ Diverter Sketch [] Drilling program ~ Drilling fluid program '~ Time vs depth plot ~ Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~. 2 ~:'F¢;..A..,¢;~ Title ..~--,,w~,,-,,~. ,,~-';'-.-z,;.~,~..,,,,.,, Commission Use Only Permit N'umber J AP, number J Approval date J See cover ,etter ~'" / 7 50--O ~- ~' - -~- / ~'/~' 0 3 / q 6 / 8 9 for other requirements ConditiOns of approval Samples requ,ir.ed [] Yes .~' No Mud log requ'i,reg · LFYes ~ No Hydrogen sulfide measures [] Yes ,~ No Directional survey required .,~Yes [] No ' Required working p~e for .E~)PE~~ [] 3/M; ,'~ 5M; [] 10M; [] 15M Other. / / <~'~//~~ by order of Approved by k -, ,.~. ( )~'~~~ Commissioner the commission Date Form 10-401 Rev. 1'2--':"F8~ ~ Subm/ ;ate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT NO. E-3 Conoco, Inc. 3201C Street, Suite 200 Anchorage, AK 99502 I. Casing and Cementing Program Ae The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks Permafrost type "C" cement. Be The 9-5/8" surface casing will be cemented with ±1969 sacks of Permafrost cement followed by ±272 sacks of Class "S" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±412 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of ±180 sacks of Permafrost type "C" cement followed by +60 barrels of Arctic Pack pumped down the 7" x 9-5/8" annulus. II. Drilling Fluid Program Ae 0-500 9.0 ppg freshwater spud mud. Be Ce De III. 500'-5000' 9.0 ppg-9.8 ppg freshwater spud mud. REC ?ED 5000'-8000' 9.0 ppg-9.5 ppg dispersed. 8000'-11500' 9.5 ppg-lO. 4 ppg dispersed. FEB 1 6 1989 Drilling Program Conoco, Inc. proposes drilling the E No. 3 as a gas injection well in the Kuparuk River Field. Mud system will be non- dispersed, low solids with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.4 ppg. A 20" 2000 psig diverter will be installed on the 13-3/8" conductor for drilling the surface hole. A 13- 3/8" 5000 RSRRA BOPE stack will be used on surface casing. Maximum anticipated surface pressure was based on an unexpanded gas bubble, temperature taken into account. BOP's choke manifold, Upper and Lower Kelly will be tested to 500 psig and 5000 psig. The Hydril to 350 psig and 3500 psig. Casing will be pressure tested to 1500 psig. The closest wellbore to E-3 is E-2 with 115 feet of closure at the surface. Arctic Pack will be placed in the 7" x 9-5/8" annulus following the primary cement job. A. B. C. Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Drill a 12-1/4" surface hole to +4650' TVD (±6709' MD) and set 9-5/8" casing. Drill a 8-1/2" production hole to 11508' MD and set 7" TVD MD FORMATION 'BIT MUD WEIGHT YP PV YIS FL O' 0' Gravel 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay' 1-1-4 9.0 25 20 65 15 3800' 5172' "K" Sands 1-1-4 9.2 25 15 65 14 4093' 5996' "M" Sands 1-1-4 9.4 25 15 65 13 4289' 6046' "N" Sands 1-1-4 9.4 25 15 65 12 4367' 6586' "O" Sands 1-1-4 9.4 25 15 65 12 6508' 10015' Sea Bee 1-1-4 10.2 8 12 40 10 6651' 10276' Kup Top 1-1-6 10.2 8 12 35 5 6802' 10540' MK (1) 1-1-6 10.2 8 12 35 5 6820' 10573' MK (2) 1-1-6 10.2 8 12 35 5 6908' 10729' 5. Z. 1-1-6 10.2 8 12 35 5 7020' 10930' L K (1) 1-1-6 10.2 8 12 35 5 7040' 10965' L K(2) 1-1-6 10.2 8 12 35 5 7220' 11289' B L K 1-1-6 10.4 6 12 35 5 7370' 11556' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. R . 'iv'ED FEB 1 6 1 8ca Oil & CONOCO, [ne. Ped E, Well No~ ~ Proposed HIIne Poln~ Unl~, North Slope, Aleske 0 RKB ELEYAT~ON~ 2~' I'll 1000 2000 3000 4000 _ 5000 6000 7000 _ 8000 0 KOP lo 20 BUILD 2.~ DEI~ PER ~00 FT SOSS EOB TVD=500 TI'ID=500 DEP=O TVD=2388 TI'ID=2?19 DEP=993 AVERAGE ANGLE 55 DEG 28 HI N 9 5/8' CSO PT TVD=4650 TMD-6709 DEP-4280 TARGET TVD=7020 TMD=10891 DEP=7725 (TOP LOI,/ER KUPARUK) BASE LO14ER KUPARUK TVD-7220 THD-11244 DEP-8016 TD / 7"' LINEER TVD-7370 TPID-11508 DEP-8234 ! 1000 2000 3000 4000 5000 6000 ?000 VERTICAL SECT[ON I 1 8000 9000 HOR I ?~gN T AL S~,~LE I IN. PROJECTION - 1000 FEET CONOCO. ! ne. Pad E. Well No' Ml lne Point Unit, ... :~ Pr, opO.ed No~'th SI ope. Ale=ka 8000 7'000 6000 5000 4000 ~000 2O00 1000 6000 5000 40O0 - I i TARGET TVD=7020 T t'lD- 10891 DEP-ZZ25 NORTH 6342 WEST 4411 N 34 7725' WEST-EAST :3000 2000 I I 1000 0 1 000 I I I DEG 49 MI N W (TO TARGET) TD LOCAT [ ON ' 218' FSL. 1590' FEL SEC. 14. T13N. RIOE TARGET LOCAT ! ON ' 200' FNL. 1 :~4:)0' FEL SEC. :>;3. TI3N. RIOE SURFACE LOCATION, 1262' FNL. 2169' FEL bEC. 25. T I3N. R IOE 1000 . 4OO , , :300 200 1 O0 0 1 O0 I ..... I I .... I ...... Im, i 200 ,, ~ 600 500 _ 400 _ 300 _ 200 100 100 _ 200 _ ~'~.100 I I I I I I I I I I I I I I I I I I \ \ \ 900 \ \ \ %17'00 \ \ \ "U soo '~1300 %1100 \ ~ 900 %... I I I 1 lO0 I 17JO I I 1 500[ I 1 300 I 1100 I 500 I I I I ! m ' ' ' I' .... I ' ' I I " 400 3;00 200 1 O0 0 rl O0 200 _ 60C 50C _ 40C _ 30C _ 20C _ 10C _0 _ 10C _ 20C 9000 8000 7000 6O00 5000 4OO0 3000 2000 1000 6000 5000 4000 I I I 3000 2000 1000 0 1000 I I I I %\?000 \ \ \ \ \ \ '6000 .~~ooo ooo \ 500~ ~000 3000 ! 1000 6000 5000 4000 3000 2000 .. ~* ~200 ! I 0 1000 _ 9000 _ 8000 _ 7000 _ 6000 _ 5000 _ 4O0O _ 3000 2000 _ 1000 _0 N \ \ SIMP' LAGOON MILNE: Pr. UNIT BOUNDARY ........ !1 >i i i i ..!.J..j.'. .. t.::-.,t SCALE IN MIL.ES CONOCO MILNE POINT UNIT EXISTING DEVELOPMENT NOTES: I. STATE PLANE CO-ORDINATES ARE ZONE 4. 2. ALL GEODETIC POSITIONS ARE BASED ON N.A.D. 1927. OFFSETS TO SECTION LINES ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSITIONS. 4. LOCATED WITH IN SECT. 25 ,T 1:5 N, R I0 E, U.M., AK. I 3 59' E- 3 12. G"~/ LOCATION IN SECTION FROM N. LINE~ FROM E. UNE 1983' STATE PLANE CO'O RDS. NORTHINGS CASTINGS 569, 159.84 GEODETIC LATITUDE POSITION LONGITUDE DATE CHECKED FIELD BOOK 6,016,457.87 ?0° 27' 19.162" N. 149° Z6' 08.178" W. II- 1-84 R.M 4-84 Z054' 6,016 ,554.:50 569, 088.27 70° 27' ZO.IIT'N. 149O ZG' 10.2:55" W. II-15 -85 L.O. Z6-85 AND THAT THIS PLAT REPRESENTS A ,~Y suPERV,S,O.. ~[~ T.AT ALL D, MENSIO.S('~: AND OTHER DETAIL~ ARE CORRECT. CERTIFICATE OF SURVEYOR : I HEREBY CERTIFY THAT I AU PROPERLY R[GISTER[O AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AS- BUILT WELL LOCATION Surveyea for CONOCO ) SCALE : I SHEET I= · 400' I I OF 2 COMMENTS: tBSSD§, ENGINEERS AND LAND SURVEYORS TIME ESTIMATE Hours Days Cum. Days A. Rig Up 8 0.33 0.33 B. Drill Surface Hole 107 4.46 4.79 C. Run Surface Casing and Cement 36 1.50 6.29 D. Drill Out and Test 8 0.33 6.62 E. Drill production Hole 138 5.75 12.37 F. Log Open Hole 36 1.50 13.87 G. Condition, POOH, L.D. 20 0.83 14.70 H. Run Production Casing 16 0.67 15.37 I. Cement Production Casing 10 0.42 15.79 J. Run Cased Hole Logs & Perf 36 1.50 17.29 K. Run Completion EQ 12 0.50 17.79 L. Move Rig --8 0.33 18.12 TOTALS 435 18.12 18.12 LAJ :2 0 -1 -2 -3 -4. -5 -6 -7 -8 -9 -10 -11 -12 MILNE POINT UNIT WELL E-5 Rate vs.depth 0.00 2.00 4.00 6.00 8,00 10.00 12.00 14..00 16.00 18.00 RIG DAYS CONOCO, INC. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING I~ILL-UP LiNE FLOw LINE APt SO00~__.~~ TSG OUTLETS U/ ~,~ sPooL · ANNULAR PREVENTER (1) 13%' APl soOoe RAId SOP 13 ~/8" APl SO00 II, RAM BOP (2) 13~!' APl 5000~ . --3' - APl $000 SIDE OUTLETS (3) APl 5000 *It RAM BOP APl 3ooo't' · 'it' APt 5ooo II ' APl ~0004' (~,) 3' APt SO00m , CSG SlOE OUTLETS SPOOL Threaded Connection R.O.P. stack size rating meets APl RP 53 & spec 6A for class 5H vith clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary enerEy source for system activation. Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe ra~s. Choke and kill manifolds shown separately to meet APl RP 53 class 5M requirements. U'I'IL Fr'¥ /# PowE.~.. PIT~ 6ALL VALVe' PiT '10 ~W'O ~ALL VALV~ ~LANK P~PE HOUSF._ ~000 SOOO PSI MANUAL CHOK~ 50CXD F~I RP IO~O00 PSI HYD C I-I01,~ ~. .... _ · _ _ i , , , ii LEVEL · . I. CONOCO, INC. MILNE POINT UNIT BOP STACK FOR 9-5/8" SURFACE CASING FILL*UP LIRE ~ ' FLOw LINE RAM BOP - SPOOL · ~ ~, RAM BOP ~lO[ OUTL[TS~1 SPO0~ · / II' APl 5000e "--,--.-.. ':Il ~, _ : ....';'.- ?, -...-. ANNULAR PREVENTER APl sooo'~ I& S/I u, APl SO00 Il, APl SO00M APl SO00 SlOE OUTLETS 13S/Bu APl SO00E 13~/i' APl SOO0d · '11" APl 5000 (2) (3) (~) (5) R.O.P. stack size rating meets AP1 RP'53 & spec 6A for class 5M with clamp & hub connectors all hydraulically operated. BOPE to be operated on each trip & pressure tested weekly. Hydraulic control system for BOPE to include (5) station control manifold located remote with 160 gallon accumulator and reservoir unit and auxiliary energy source for system activation. Ram type BOP to include a minimum of one set of blind rams and two sets of appropriate pipe rams. Choke and kill manifolds sho~rn separately to meet APl RP 53 class 5M requirements. Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 January 27, 1989 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 RE' REQUEST FOR PERMIT TO DRILL MILNE POINT UNIT WELLS B-23, C-20 AND E-3 Dear Mr. Chatterton' In accordance with AAC 25.005, Conoco Inc. hereby submits applications for permit to drill wells B-23, C-20 and E-3 in the Milne Point Unit, North Slope Borough, Alaska. Attached is a check for $300 payable to the State of Alaska, Department of Revenue to cover the required permitting fees. Well B-23 is tentatively scheduled to spud in early May and will be followed by wells C-20 and E-3. Conoco Inc. is covered under a $200,000 blanket bond for drilling (Number 8086- 15-54), filed with the AOGCC and approved December 22, 1980. Wells B-23 and C-20 are development wells in the Kuparuk reservoir. Well E-3 is a gas injection/storage well. Drilling the subject wells will increase re- covery from the Kuparuk reservoir and provide a necessary gas injection point; therefore, Conoco Inc. contends that drilling these wells is in the best interest of the Milne Point Unit Owners and the State of Alaska. Questions of a technical nature can be directed to Mr. Paul Grimmer in Conoco's Anchorage office at 564- 7635. Yours ve~ Division Manager RSR/cl Att File' 500.21 RECEIVED JAN 2 7 ]9~.~ . J)il & .Gas Cons. Commission STATE OF ALASKA -' 0 R 16 IN A IL ALASKA .JIL AND GAS CONSERVATION C~,vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry ~ Deepen~1 Service [] Developement Gas [] Single Zone [] Multiple Zone ~ I' 2.""Name of Operator " 5. Datum Elevation (DI~ (~r KB) 10. Fieid and Pool CONOCO, INC. KB 28 feet 3."Address ' ' 6. Pr(~p~rty Designation 3201 C St. Suite 200, Anchorage, AK 99503 ADL 47437 Kuparuk River Field 4. Location 'of well at surface 7. Unit Or property Name 11. Type Bond ('see 20 AAC 25.025) 1262'FNL,2169'FEL,Sec.25,T13N,R10E,U.M. ,NSB,.~K Milne Point Unit Blanket · At top of productive interval 8. ~ell ;qurpber Number 8086-15-54 200' FNL, 1300 ' FEL, Sec. 23, T13N, RiOE E-3 At total depth 9. Approximate"spud date Amount $200,000 218'FSL,1590'FEL,Sec.14,T13N,RlOE June 10, 1989 12. Distance t~' nearest 13. Distance/'t~ nearest well' 14. Number of acres in p'r0pert~ 15. Proposed depth (MO and TVD) property line 3980 feet 115' to g.-2 @ Surffeet 2560 l1508'MD/7370'TVDfeet 16. T~ be 'completed for deviated wells i 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum ~ole angle 55 0 Maximum surface 3100 pstg At total depth ('rYE) 3700 18'. Ca~ing progra~ ........"' S~'ti'n~'~Depth ..... size Specifications! " Top Bottom Quantity of cement Hole Casin~' Weight Grade Couplir~'~'~', Length ' ' 'MD TVD' MI~' TV'D' (include stage data) ..... 30" ~3-3/8' 48# H-40 WELD ~ 80' 28' 28' 108' 108' t485 sks Permafrost C 12-1/4'I 9-5/8' 36# J'...55 BTRS ~681' 28' 28' 6709' 4650' _~1969 sks Permafrost E " '~ ..... ~272 sks Class G 8-1/2't 7" 29# L-80 BTRS 11480' 28' 28' 1508' 7370' .~412 sks Class G' .~180 sks Permafrost C 19. TO be completed for Redrill, Re-entry, and'Deepen Opp~ations. + 60 Bbls Arctic Pac Present well condition summary Total depth: measured !~eet Plugs (measured) true vertical ?feet, .:' Effective depth: measured / feet Junk (measured) true vertical_,? feet Casing Length Sj~e Cemented Measured depth True Vertical depth Structural . :- . Conductor Surface ~ - .~-. ~. I nte rmed i ate . Production .- '.. ,,~ ' · '-,. Liner Perforation depth: measured ' .,~ia;;;~.;~, ~jJ ~ .~'.. ~:~,. true vertical : ..~ .... 20. Attachments Filing fee ~ Property plat ~ ~' i~oP Sketch ;~ Diverter'Sket(~h [~ Drilling'program ~ Drilling fluid program ~ Time~"-~E~ plot ~ Refraction analysis [] Seabed report ~ 20 AAC 25.050 requirements 21. i hereby certif~.~h?'~reg°inTq/is t~'e and correct to the best pi my knowledge" S ,g n ed~.~./,~ ~ ~,~'~ ~ Title ~ ~, /~...~ ..... Date " ~ Commission Use Only z~" / 7 50-- O,~._~:~ -., ~ / ~,,/'~' for other requirements Conditions of approval Samples required i~ Yes ~' No Mud log required ~ Yes ~J"N0 Hydrogen sulfide measures [] Yes ,,~ No Directional survey required ,,~ Yes [] No Required working pressure for BOPE E~2M; [] 3M; ~ 5M; [] 10M; ~] 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT NO. E-3 Conoco, Inc. 3201 C Street, Suite 200 Anchorage, AK 99502 I, Casing and Cementing ProGram a. B, C, The 13-3/8" conductor will be set at 80' below the surface, then cemented to the surface with ±485 sacks Permafrost type "C" cement. The 9-5/8" surface casing will be cemented with ±1969 sacks of Permafrost cement followed by ±272 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. The 7" production casing will be cemented in two stages. The first stage will consist of ±412 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of ±180 sacks of Permafrost type "C" cement followed by 60± barrels of Arctic Pack pumped down the 7" x 9-5/8" annulus. II. Drilling Fluid Program a~ B~ C. 0-500 9.0 ppg freshwater spud mud. 500'-5000' 9.0 ppg-9.8 ppg freshwater spud mud. 5000'-8000' 9.0 ppg-9.5 ppg dispersed. 8000'-11500' 9°5 ppg-!0.4 ppg dispersed. III. Drilling Program Conocof Inc. proposes drillino the E No. 3 as a pas injection well in the Kuparuk River Field. Mud system will be non-dispersed, low solids with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.8 ppg. Mud weight at T.D. will be 10.4 ppg. A 20" 2000 psi~ diverter will be installed on the 13-3/8" conductor for drilling the surface hole. A 13- 3/8" 5000 RSRRA BOPE stack will be used on surface casing. Maximum anticipated surface pressure was based on a fluid column at T.D. of 80% gas and 20% oil. BOP's choke manifold, Upper and Lower Kelly will be tested to 500 psig and 5000 psis. The Hydril to 350 psi~ and 3500 psis. Casing will be pressure tested to 1500 psig. E-3 comes within 115' of E- 2 at the surface. Arctic Pack will be placed in the 7" x 9-5/8" annulus following the primary cement job. a~ Be C. Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Drill a 12-1/4" surface hole to ±6692' MD and set 9-5/8" casing. Drill a 8-1/2" production hole to 11556' MD and set 7" casing. TVD Ot 500 3800 4093 4289 4367 6508 6651 6802 6820 6908 7020 7040 7220 7370 MD FORMATION BIT MUD WEIGHT YP PV YIS FL 0' Gravel. 1-1-4 9.0 32 20 90 15 500' Sand/Clay 1-1-4 9.0 25 20 65 15 5172' "K" Sands 1-1-4 9.2 25 15 65 14 5996' "M" Sands 1-1-4 9.4 25 15 65 !3 6046' "N" Sands 1-1-4 9.4 25 15 65 12 6586' "O" Sands 1-1-4 9.4 25 15 65 12 10015' Sea Bee 1-1-4 10.2 8 12 40 I0 10276' Kup Top 1-1-6 10.2 8 12 35 5 10540' MK (1) 1-!-6 10.2 8 12 35 5 10573' MK (2) 1-1-6 10.2 8 12 35 5 10729' L.Z. 1-!-6 10.2 8 12 35 5 10930' L K (1) 1-1-6 10.2 8 12 35 5 10965' L K(2) 1-1-6 10.2 8 12 35 5 11289' B L K 1-1-6 10.4 6 12 35 5 !1556' TD 1-1-6 10.4 6 1.2 .35 5 E-3/WP4A 3/88 CONOCO, INC. MILNE POINT UNIT DIVERTER STACK FOR 13 318' .CONDUCTOR FILL UP LINE VALVE '[~ , ~) FLOW LINE 20" BELL NIPPLE 20" APl tO00 ~Si ANNULAR PREVENTER VALVE L'-~~IO'' RELIEF VALVE "' DIVERTER QUICK CONNECT ASSEMBLY , SAVER *SUB ASSEMBLY STARTING HEAD le e Relief lines from the drilling spool will be rot, ted for downwind diversion. Hydraulic control system will be in accordance with AP1 specifications and AOGCC regulations. Both HCR valves rill open when the preventer closes, then either one may be closed. ~OTE: Depending on rig contracted, the two 6" relief lines may be replaced by a single 10" line with a downstream tee. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) LOc ~?~ /./~)/~ (2 thru 8) ' (8) (3) Admin ~Pp~ ///f//~ 9. (9 thru 13) ' 10. (10 and 13) 12. 13. (4) Casg ~~ ,~-,~B/-~P'~ (14 thru 22) (23 thru 28) Company ~__~D/u3o~.G Lease & Well No. /zf,?~,'z ~o/: YES NO Is the permit fee attached .......................................... ~ -- REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22. 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~.. 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ _~_ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... · 23. 24. 25. 26. 27. 28. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... _~_ Does the well have a unique name and number ......................... Is conductor string provided ........................................ /~ Will surface casing protect all zones reasonably expected to serve as an underground, source of drinking water ..................... ~' Is enough cement used to circulate on conductor and surface ......... ,~ Will cement tie in surface and intermediate or production strings ... ~ Will cement cover all known productive horizons ..................... /~ Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate z~ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~Oo~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER (29 thru 31)~ (6) Add: Geology: DWJ ~ EngSneering: LCS ~-?~,,~ BEW /-' rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. Additional Remarks: INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE // o 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 89/08/14 ORIGIN OF DATA: RLL REEL NAME: CONOCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT +/ ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 89/08/14 ORIGIN OF DATA: E3 TAPE NAME: MILNE PT CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: SSDS REV SERVICE NAME: SSDS VERSION #: REV 1.01 DATE: 89/08/14 MAX. RECORD LENGTH: 1024 FILE TYPE: E3 PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT FET MWD EWR MWD GRC MWD CAL MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD TVD GYRO NDIS GYRO EDIS GYRO ROP GYRO DEVI GYRO NPS MWD RHOB MWD ORDER# L0G TYP CLS MOD NO. 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