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205-016
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 20, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-28 NORTHSTAR UNIT NS-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/20/2025 NS-28 50-029-23248-00-00 205-016-0 G SPT 10558 2050160 3500 4727 4731 4248 4247 70 254 230 183 REQVAR I Sully Sullivan 1/20/2025 Annual MIT-IA to 3500 psi per AIO 23.003. #2 HP turbine Compressor dropped offline during test and destabilized flow rate. Adjusted other injectors and restabilize injection rate and temp then retest (see related inspection). 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:NORTHSTAR UNIT NS-28 Inspection Date: Tubing OA Packer Depth 827 3810 3693 3582IA 4248 151 45 Min 3521 60 Min Rel Insp Num: Insp Num:mitSTS250121120836 BBL Pumped:5.6 BBL Returned:7.3 Thursday, March 20, 2025 Page 1 of 1 9 9 9 9 9 9 9 9999 9999 99 9 9 9 6HH,QVS5SWPLW676IRUUHWHVW Annual MIT-IA to 3500 psi per AIO 23.003. James B. Regg Digitally signed by James B. Regg Date: 2025.03.20 14:27:19 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 20, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-28 NORTHSTAR UNIT NS-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/20/2025 NS-28 50-029-23248-00-00 205-016-0 G SPT 10558 2050160 3500 4599 4604 4607 4614 1 43 39 37 REQVAR P Sully Sullivan 1/20/2025 Annual MIT- IA to 3500 psi per AIO 23.003. This MIT was performed after #2 compressor went down and process was restabilized (see related inspection). 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:NORTHSTAR UNIT NS-28 Inspection Date: Tubing OA Packer Depth 874 3801 3741 3724IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250121122840 BBL Pumped:8.2 BBL Returned:9.2 Thursday, March 20, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 UHIHUWR,QVS5SWPLW676IRULQLWLDOWHVW 9 9 Annual MIT- IA to 3500 psi per AIO 23.003 James B. Regg Digitally signed by James B. Regg Date: 2025.03.20 14:21:28 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, March 4, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-28 NORTHSTAR UNIT NS-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/04/2024 NS-28 50-029-23248-00-00 205-016-0 G SPT 10558 2050160 3500 4686 4686 4682 4684 0 9 9 10 REQVAR P Kam StJohn 1/20/2024 AOGCC 1 Year MIT-IA Per AIO 23.003 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:NORTHSTAR UNIT NS-28 Inspection Date: Tubing OA Packer Depth 1358 3853 3815 3799IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240121111531 BBL Pumped:6 BBL Returned:4.3 Monday, March 4, 2024 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-28 NORTHSTAR UNIT NS-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/17/2023 NS-28 50-029-23248-00-00 205-016-0 G SPT 10558 2050160 3500 4563 4563 4563 4563 34 75 75 74 REQVAR P Brian Bixby 1/29/2023 MITIA as per AIO 23.003 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:NORTHSTAR UNIT NS-28 Inspection Date: Tubing OA Packer Depth 1607 3800 3765 3754IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230129162454 BBL Pumped:6.8 BBL Returned:4.8 Friday, March 17, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, February 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Lou Laubenstein P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-28 NORTHSTAR UNIT NS-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv ________ Comm ________ NS-28 50-029-23248-00-00 205-016-0 G SPT 10558 2050160 3500 4755 4755 4755 4755 23 35 36 36 REQVAR P Lou Laubenstein 1/10/2022 MIT-IA to 3500 psi per AIO 23.003. Test was started @ 2552 psi due to a stop in fluid packing and checking for gas on the pressurizing of the annulus, the pressure was 641 psi when I arrived on location. 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:NORTHSTAR UNIT NS-28 Inspection Date: Tubing OA Packer Depth 2552 3850 3827 3816IA 45 Min 60 Min Rel Insp Num: Insp Num:mitLOL220112122347 BBL Pumped:3.3 BBL Returned:3.3 Wednesday, February 2, 2022 Page 1 of 1 9 99 9 -%5 9 7LPHOLQHRIWKH0,7DWWDFKHGVKRZLQJ,$SUHVVXUHV James B. Regg Digitally signed by James B. Regg Date: 2022.02.02 13:07:16 -09'00' Timeline of NS 28 (Donald Maxon, Hilcorp; 1/11/2022) Pressure before we started pre-loading with diesel was 1005psi. 4am – Had planned to start preloading IA at the beginning of night shift, but due to plant issues we were unable to start pre-loading until 4am. 4am – Triplex pump was engaged to pump diesel into IA. 5:20am – Pressured up to 1955psi and disengaged pump. Actual pressure of IA was ~1451psig. 6am- Shift change (Nights to Days) up to this point we were unsure that the state was going to witness. 7am – Checked email and found out the State Rep was going to witness MIT. 8am- Worked on State Rep travel to Northstar. 9am – State Rep arrived at Northstar. 9:24am – Operations bleed off gas cap down to 647psi. 10:05am – Continued pre-loading IA. At this point we discussed with State Rep to do a spot check during pressure build up to ensure there was no more gas cap that could affect the MIT. 11:04am – Disengaged the pump @ 2922psi to do a spot check. Actual IA psi was at 2552psig and IA was fluid packed. This is where State Rep said to write the pretest pressures (2552psig) and start bbl count. Up to this point we had pre-loaded ~40bbl of diesel. 11:07am – Engage pump and loaded IA to 3850psi ~3.3bbl added (~43bbl total) to start MIT @ 11:28am. 11:28am – 12:01pm – State Rep said the test was a Pass and we were good to de-pressure. 12:01pm – 1:36am – de-pressured IA off and on throughout shifts. (~17bbls have been recovered so far). 9 9 9 9 9 -%5 -%5 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. You don't often get email from donnie.maxon@hilcorp.com. Learn why this is important From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: MIT - NS 28 Date:Monday, January 10, 2022 4:16:02 PM Attachments:Copy of NS28 TIO.xlsx Northstar NS-28 (PTD 2050160) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Donald Maxon <Donnie.Maxon@hilcorp.com> Sent: Monday, January 10, 2022 2:58 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: MIT - NS 28 Here are requested plots for the past 90 days. Donnie Maxon Hilcorp Nstar: Operation Lead Positional: AlaskaNS-Northstar-OperationsLeads@hilcorp.com Individual: donnie.maxon@hilcorp.com Office: (907) 670-3533 Cell: (907) 205-7013 Alt: Bill Bryant From: Regg, James B (OGC) <jim.regg@alaska.gov> Sent: Monday, January 10, 2022 2:22 PM To: Donald Maxon <Donnie.Maxon@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: [EXTERNAL] RE: MIT - NS 28 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. Some people who received this message don't often get email from donnie.maxon@hilcorp.com. Learn why this isimportant Send TIO pressure plot for past 90 days. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Donald Maxon <Donnie.Maxon@hilcorp.com> Sent: Monday, January 10, 2022 1:40 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Alaska NS - Northstar - Operations Leads <AlaskaNS-Northstar-OperationsLeads@hilcorp.com>; Alaska NS - Northstar - Field Foreman <AlaskaNS-Northstar-Field-Foreman@hilcorp.com>; Joleen Oshiro <Joleen.Oshiro@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com> Subject: MIT - NS 28 Attached is the completed MIT on NS -28. Regards, Donnie Maxon Hilcorp Nstar: Operation Lead Positional: AlaskaNS-Northstar-OperationsLeads@hilcorp.com Individual: donnie.maxon@hilcorp.com Office: (907) 670-3533 Cell: (907) 205-7013 Alt: Bill Bryant 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 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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO. Jim ReggDATE: Thursday, January 14, 2021 P.I. Supervisor ' l � Z21 7tii.( SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC NS -28 FROM: Brian Bixby NORTHSTAR UNIT NS -28 Petroleum Inspector Src: inspector Reviewed By: P.I. Sup" Comm Well Name NORTHSTAR UNIT NS -28 API Well Number 50-029-23248-00-00 Inspector Name: Brian Bixby Permit Number: 205-016-0 Inspection Date: 1/1311021 ✓ Insp Num: mireDB210114110506 Rel Insp Num: Packer Deptb Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS -29 Type Inj G TVD 10558 - Tubing 4619 4621 - 4648 - 4651 - 4650 - 4648' PTD 2050160 Type Test SPT Test psi 3500 r IA 543 3851 3658 - 3638 3614 3598 BBL Pumped: 4 1 IBBL Returned: 14 OA 36 128 72 63 56 51 Interval OTHER P/F P Notes: Annual MIT -IA as per ALO 23.003. Test Detail readings are the last 60 minutes of the [es[. I watch the test for 2 hours and IS minutes total due to a compressor being started and changing the wellbore temperature. l have the field copy saved if needed. Total Pressure loss on the IA was only 253 psi in 2 hours 15 minutes. Thursday, January 14, 2021 Page I of I Wallace, Chris D (CED) From: David Gorm <dgorm@hilcorp.com> Sent: Tuesday, March 10, 2020 3:55 PM To: Wallace, Chris D (CED) Subject: NS -28 IA pressure Bleed (PTD: 205-016) Chris, On 3/9/2020 7 PM we increased our gas injection rate from 22 MMCFD to 45 MMCFD on NS -28 gas injection well. With the increase in rate we have had IA pressure increase due to thermal expansion. Today on 3/10/2020 we have blead the IA pressure down from 1,800 psi to 320 psi. Please let me know if you have any questions. Thanks, David Gorm Operations Engineer— Northstar/Endicott Hilcorp Alaska Office: 907-777-8333 Cell: 505-215-2819 The Information contained in this e-mail message is confidential information intended only for the use of the reciplent(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. 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 Permit Number: 205-016-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg {�j -, P.I. Supervisor '\ �, I I Of � u'' DATE: Wednesday, January 15, 2020 SUBJECT: Mechanical Integrity Tests Hikorp Alaska LLC NS -28 FROM: Bob Noble NORTHSTAR UNIT NS -28 Petroleum Inspector Well NS -28 Sre: Inspector jTVD Reviewed B,.y�: P.I. Supry . 7z— NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS -28 API Well Number 50-029-23248-00-00 Inspector Name: Bob Noble Permit Number: 205-016-0 Inspection Date: 1/13/2020 ' Insp Num: mitRCN200I13145603 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS -28 IType Inj c jTVD 1 10558 -ITubingl Ons 1 4916 4915 4980 PTD 2050160 Type Test I sPT Test psi 3500 - IA 1646 3855 - 3850 3849 BBL Pumped: 6.5 'BBL Returned: 6.5 OA 261 483 a9a - 507 Interval REQVAR P/F P Notes: Yearly MIT -]A to 3500 psi as per A10 23.003. ✓ Wednesday, January 15, 2020 Page l of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 24, 2019 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC NS -28 NORTHSTAR UNIT NS -28 Sre: Inspector Reviewed By: P.I. SuprvjGz— Comm Well Name NORTHSTAR UNIT NS -28 API Well Number 50-029-23248-00-00 Inspector Name: Bob Noble Permit Number: 205-016-0 - Inspection Date: 1/22/2019 - Insp Num: mitRCN190122172330 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS -28 '�Typelnj 6 TVD ro55s Tubing sols 5033 F 503s so4o PTD 2050160 • Type Test sill Test psi 3500 IA 2016 3633 3619 i 3613 BBL Pumped 154 BBL Returned 1' 5 OA 217 33s - � 341 344 IntervalREQVAR P/F _l Notes: Yearly MIT -IA to 3500 psi as per A10 23;003 Thursday, January 24, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,January 23,2018 TO: Jim Regg ,z3 SUBJECT:�� SUBJECT: Mechanical Integrity Tests P.I.Supervisor HILCORP ALASKA LLC NS-28 FROM: Jeff Jones NORTHSTAR UNIT NS-28 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry a3r-- NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS-28 API Well Number 50-029-23248-00-00 Inspector Name: Jeff Jones Permit Number: 205-016-0 Inspection Date: 1/16/2018 Insp Num: mitJJl80116202028 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS-28 • Type Inj G 'TVD 10558 - Tubing 4873 4872 4872' 4872 • PTD 2050160 -Type Test SPT Test psi 2640 IA 1710 366Q 3640. 3637 ' BBL Pumped: 5.3 • BBL Returned: 3.3 - OA 70 224 . 223 - 225 , Interval —�.REQVAR jP/F P • , Notes: A1O 23.003:T x IA communication,annual MIT. 1 well inspected,no exceptions noted. SCANNEV t Tuesday,January 23,2018 Page 1 of 1 RECEIVED STATE OF ALASKA ALARAOIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS OCT 0 4 2017 1.Operations Abandon Li Plug Perforations L] Fracture Stimulate U Pull Tubing LI AOGi ti ns shutdown ❑ Performed: Suspend ❑ Perforate ❑ Acid Stimulate 0 Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska LLC Development❑ Exploratory❑ 205-016 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service E 6.API Number: AK 99503 50-029-23248-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312799 NORTHSTAR UNIT NS-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Northstar Field/ Northstar Oil Pool 11.Present Well Condition Summary: Total Depth measured 14,150 feet Plugs measured N/A feet true vertical 11,170 feet Junk measured N/A feet 10,504, 12,142 Effective Depth measured 14,106 feet Packer measured 12,186 feet 9,140, 10,558& true vertical 11,166 feet true vertical 10,597 feet Casing Length Size MD TVD Burst Collapse Conductor 200' 20" 200' 200' N/A N/A Surface 3,590' 13-5/8" 3,590' 3,197' 5,020psi 2,260psi Intermediate 10,671' 9-5/8" 10,671' 9,287' 7,930psi 6,620psi Liner 1,851' 7" 12,365' 10,751' 8,160psi 7,020psi Liner 1,964' 4-1/2" 14,150' 11,170' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED ( E( 0 8 2017, Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13CR VAM-TOP 12,186' 10,597' 9-5/8"x 7"ZXP LTP 7"x 4-1/2"S-3 Packe 1,008' Packers and SSSV(type,measured and true vertical depth) 5"HRD ZXP LTP 4-1/2"TRM-4E SSSV See Above 995' 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 45,988 0 1,025 4,696 Subsequent to operation: 0 47,192 0 833 4,695 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service 2 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 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: 317-413 Authorized Name: Bo York Contact Name: WWWyatttt Rivard Authorized Title: Operations Manager Contact Email: wrivard c(l�hilcorp.cortm Authorized Signature: -� Dab 10/3/2017 Contact Phone: 777-8547 Form 10-404 Revise 4/2017 /0 .2.z-47 Submit Original Only RBDMS ti v OCT - 2017 ,e,0,,, • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-28 Pump 50-029-23248-00-00 205-016 9/10/17 9/10/17 Daily Operations: 9/6/2017 -Wednesday No activity ivi report. Y to e p 9/7/2017-Thursday No activity to report. 9/8/2017 - Friday No activity to report. 9/9/2017-Saturday No activity to report. 9/10/2017 -Sunday Hold safety meeting ATP and permit to work. MIRU SLB pump van and acid tubes. RU iron. PT 250/4,500 psi. Open companion flange 23.5 turns. Initial WHP 4,081psi. IA pressure 916. Online at .75 bbls/min increase rate pump 20 bbls of heated seawater at 90*F. WHP starting to drop as we increase hydrostatic from fluid. Online with DAD acid (12 % HCL) @ 3 bbls/.min. 81.2 bbls pumped. (acid density 8.51ppg). 3,664psi pump pressure. Swap to heated sea water for 210 bbls. WHP dropping. Shut down for 1 hr. Let DAD acid soak into perfs. 415psi WHP. Soak for 1 hr. Online 5 bbls/min with heated seawater for over flush. 240 bbls pumped. Pump 5 bbls of methanol behind seawater for gas/water spacer. Shut down. Shut in companion flange 23.5 turns. Final SITP 411psi. RDMO SLB. 9/11/2017 - Monday No activity to report. 9/12/2017-Tuesday No activity to report. QF T • • e \\V/7', THE STATE Alaska Oil and Gas lrAvi OfA L A S KA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Bo York Operations Manager a Hilcorp Alaska, LLC SCA*4�®' . Z0 !_" 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field,Northstar Oil Pool, NS-28 Permit to Drill Number: 205-016 Sundry Number: 317-413 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Commissioner DATED this 3e/CC-lay of August, 2017. RBDMS W t j 1 2017 RECEIVED STATE OF ALASKA AUG 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION ACPS' 8/3'1, APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Acid Stimulate I] . Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP Change-out ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑ 205-016 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 2. 6.API Number: Anchorage Alaska 99503 50-029-23248-00-00. 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 458A Will planned perforations require a spacing exception? Yes ❑ No 0 NORTHSTAR UNIT NS-28• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312799 ' Northstar Field/Northstar Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,150' . 11,170' • 14,106' . 11,166' . 4,062 N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 200' 20" 200' 200' N/A N/A Surface 3,590' 13-5/8" 3,590' 3,197' 5,020psi 2,260psi Intermediate 10,671' 9-5/8" 10,671' 9,287' 7,930psi 6,620psi Liner 1,851' 7" 12,365' 10,751' 8,160psi 7,020psi Liner 1,964' 4-1/2" 14,150' 11,170' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 4-1/2" 12.6#/13CR VAM-TOP 12,186 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"ZXP LTP,7"x 4-1/2"S-3 Packer&7"x 5"HRD ZXP LTP 10,504(MD)/9,140(TVD),12,142(MD)/10,558'(TVD)&12,186(MD)/10,597(TVD) and and 4-1/2"TRM-4E SSSV 1,008(MD)/995(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic I] 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 2 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/8/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 . Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York Contact Name: Wyatt Rivard 1^/Lr2 Authorized Title: Operations Manager Contact Email: Wrivard(p.hiICorp.COm fir►- -� Contact Phone: 777-8547 Authorized Signature: Date: 8/24/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ( 7- `f/ 3 Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No z' Subsequent Form Required: ID—40k r RBDMS L'� �,_� � 1 1017 die"? APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 8•3Q . / 7 %8 ,_.� � c' a./7 � Submit Form and Form 10-403 Revised 4/2017 Gg4,GliNAaLfor 12 months from the date of approval. Attachments in Duplicate • • Acid Treatment Well: NS-28 PTD: 205-016 Hilcorp Alaska,LL) API: 50-029-23248-00 Well Name: NS-28 API Number: 50-029-23248-00 Current Status: Injecting Rig: LRS Estimated Start Date: Sep 7, 2017 Estimated Duration: 2 days Reg.Approval Req'std? Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 205-016 First Call Engineer: Wyatt Rivard (907) 777-8547 (0) (509) 670-8001 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Current Bottom Hole Pressure: 5172 psi @ 11,100'TVDSS (Based on avg Ivishak BHP on 8/4/17) Maximum Expected BHP: 5172 psi @ 11,100'TVDSS (Based on avg Ivishak BHP on 8/4/17) Max.Anticipated Surface Pressure: 4062psi (Based on 0.1 psi/ft. gas gradient) Current Injection Pressure: 4742 psi (Taken on 8/22/17) Last SI WHP: 3972 psi (Taken on 4/22/17) Wellbore Volume to Perfs: 210 bbls Brief Well Summary: Northstar gas injector NS-28 operates under admin approval AIO 23.003 for slow TxIA gas communication . Since resuming regular gas injection in January 2016,the well has experienced periods of decreasing gas injectivity roughly every 3-4 months. Injectivity gradually drops to—50%of normal capacity. Each instance of decreased injectivity has been successfully addressed by either drifting/bailing through solids or by performing a hot water tubing volume flush to clear up the tubing. Historically gas injectors at Northstar have benefited significantly from periodic acid/xylene treatments of tubing & perfs. NS-28 was converted from a producer in 2015 and has not yet been treated with acid. Objective: 1. Perform an acid/xylene treatment with 12% DAD acid on NS-28 to improve injectivity. Procedure: Hot Oil &Acid Transport 1. SI well. MI rig up hot oil skid to 500 bbl upright tank prefilled with ambient seawater. 2. Roll tank while heating seawater until heated to^'90 degF to reduced tubing contraction. 3. Rig up hardline from hot oil skid to tree and pressure test to 300psi low/4500psi high. 4. Rig up LRS skid to acid transport 5. Monitor IA pressure prior and during pumping to ensure no increase in pressurization. 6. Pump the following treatment at maximum rate or 4000 psi max pressure. Contact OE prior to pumping to confirm pump rates and pressures. a. 20 bbls heated seawater(verify injectivity down tubing) b. 80 bbls 12 % DAD acid (12% HCL) c. 210 bbls heated seawater to displace acid into perfs i. Shut down for 1 hour and let acid soak d. 240 bbls heated seawater(overflush to displace acid away from wellbore) e. 5 bbls methanol (spacer between water and gas). 7. Once pumping is complete, bring well back on injection slowly. Step injection pressure from 4000 psi to full injection pressure over a 4 hour period. 8. RDMO hot oil skid and acid transport • Northstar Unit Well: NS-28 SCHEMATIC Last Completed: 5/9/2005 Mean)Alaska,LLC PTD: 205-016 CASING DETAIL KBE=55.67'/BFE=40'MSL(CB 15.67') Size Type Wt/Grade/Conn ID Top Btm i I20" Conductor 169/X-56/N/A N/A Surface 200' 20' 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,590' 9 5/8" Production 53.5/L-80/Btrc. 8.535 Surface 10,671' 7" Liner 29/L-80/Hydril 511 6.184 10,513' 12,365' �� 1 4-1/2" Liner 12.6/13Cr80/ 3.958 12,186' 14,150' T 13-3/8.- TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/ 3.958 Surface 12,186' 2 JEWELRY DETAIL No Depth Item 1 1,008' 4-1/2"TRM-4E SSSV,ID=3.812":LOCKED OUT 4/22/06,Control Line Ported Open 1, 2 4,551' GLM-MMG Dummy w/RK Latch 3 10,504' 9-5/8"x 7"Baker ZXP LTP,ID=6.30" y '€ 4 10,525' 9-5/8"x 7"Baker Flex Lock Liner Hanger,ID=6.33" 5 12,096' 4-1/2"X Nipple,ID=3.813 6 12,117' 4-1/2"Fiber Optic Transducer,ID=3.958 7 12,142' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 8 12,165' 4-1/2"X Nipple,ID=3.813 9 12,176' 4-1/2"XN Nipple,ID=3.725"(12,146'ELM) 10 12,186' 7"x 5"Baker HRD LTP w/11-3/4"Tieback,ID=4.430" 11 12,190' 4-1/2"Self Aligning Mule Shoe,ID=3.958" 12 12,209' 7"x 5"Baker Flex Lock Liner Hanger,ID=4.39" 13 12,218' 5"x 4-1/2"XO,ID=3.91" .); PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Ivishak 13,282 " 13,657' 11,108' 11,128' 375 5/6/2005 Open Ivishak 13,796' • 13,916' 11,141' 11,150' 120 10/23/2005 Open IL ill 3 WELL INCLINATION DETAIL :pi T. KOP@250' ( n 4 Max Hole Angle=89 deg.@ 13,550' Max Angle at Top Perf:85 Deg.@ 13,282' OPEN HOLE/CEMENT DETAIL 20" Driven 9-5/8"a • 13-3/8" 542 sx PF"L",472 sx Class"G"in 16"Hole 5 9-5/8" 645 sx Extended,458 sx Class"G"in 12-1/4"Hole 6 7" 438 sx Class"G"in 8-1/2"Hole 4-1/2" 210 sx Class"G"in 6"Hole :4 ►.; 7 TREE&WELLHEAD I 8 Tree CIW 5-18"5SK1(uprated to 6.5ksi) Wellhead ABB-VGI 13-5/8"Multibowl 6.Sksi 1 9 GENERAL WELL INFO API:50-029-23073-00-00 10 Completed-4/15/2002 12 Add Perforations-10-23-2005 13 SSSV Lock Out-4/22/2006 7"I 6 SAFETY NOTE Well requires a safety valve,4-1/2"Chrome Tubing Liner 4-1/2" TD=14,150(MD)/TD=11,170(TVD) PBTD=14,106'(MD)/PBTD=11,166'(TVD) Created By:WLR 4/14/2016 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,January 12,2017 TO: Jim Regg '7 l(iZ i P.I.Supervisor Nf 7 ( � SUBJECT: Mechanical Integrity Tests t HILCORP ALASKA LLC NS-28 FROM: Matt Herrera NORTHSTAR UNIT NS-28 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1 �— NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS-28 API Well Number 50-029-23248-00-00 Inspector Name: Matt Herrera Permit Number: 205-016-0 Inspection Date: 1/10/2017 Insp Num: mitMFH170111170401 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS-28 Type Inj G 'TVD 10558 , Tubing, 4693 4695 4693 - 4688 - 4687 PTD 2050160 - Type Test SPT ;Test psi 3500 - IA 1377 3621 ` 3613 • 3614 3614 - BBL Pumped: 5.5 BBL Returned: 7.5 OA 218 380 392 - 398 - 403 - Interval T REQVAR - P/F P Notes: Test pressure for MIT Per AIO 23.003.BBLs Pumped to reach Max Test Pressure 5.5 BBLS 7.5 BBLS Bled back to restore IA to normal operating status MIT performed Annually % 4t4E APR 0 8 ZG17 Thursday,January 12,2017 Page 1 of I • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, December 30, 2016 4:26 PM To: Wallace, Chris D (DOA) Subject: RE: NS-28 (PTD # 2050160) Remain on Injection Attachments: NS-28 TIO.xlsx Chris, Northstar gas injector NS-28 (PTD#2050160) returned to injection on 12/6/16 for TxIA monitoring following a reset of the SSSV. Since returning to injection,there have been no further bleeds and the IA pressure has remained stable. Going forward, Hilcorp plans to leave NS-28 on injection and obtain an AOGCC witnessed MIT-IA to 3500 psi in January as per A10 23.003. A TIO plot is attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer I Hilcorp Alaska,LLC 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCANNED i C4 r) n From:Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Monday, December 05, 2016 10:12 AM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: NS-28 (PTD#2050160) Request to Return to Injection Wyatt, As discussed, your plan forward including the return to injection for monitoring and testing as detailed below is APPROVED. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907) 276-7542(fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. Fro . "V. .rd [mailto:wrivard@hilcorp.com] Sent: Monday, Decem•- ! 2016 8:14 AM To: Wallace, Chris D (DOA)<chris., - lace • alaska.:ov> Subject: RE: NS-28 (PTD#2050160) Requ- o Return to Injection Chris, Waivered Northstar gas injector NS-28 (PTD#2050160) was SI on 11/22/1. : lack of injectivity and increased IA pressurization. Slickline recently drifted the tubing and encountered a sand bridge I se XN nipple at 12176'. 1 • • • 1 , , , , I , , , , i , , -T- , I , . , , 1 , , i 9TOZ/6Z/ZT 9TOZ/LZ/ZT 9TOZ/SZ/ZT 9TOZ/£Z/ZT 9T0Z/TZ/ZT 9T0Z/6T/ZT 9T0Z/LT/ZT _ I4i> 9T0Z/ST/ZT 9TOZ/£T/ZT 9TOZ/TT/ZT 9T0Z/60/u ,: 9TOZ/LO/ZT ,- 9TOZ/SO/ZT 9T0Z/£0/ZT 9TOZ/T0/ZT 9TOZ/6Z/TT 9TOZ/LZ/TT 9TOZ/SZ/TT a0 9TOZ/£Z/TT I 9TOZ/TZ/TT O 9TOZ/6T/TT E: O 9TOZ/LT/TT 9TOZ/ST/TT 00 9TOZ/£T/TT N vi9TOZ/TT/TT Z 9T0Z/60/TT 9T0Z/L0/TT Q 9TOZ/S0/TT I 9T0Z/£0/TT /I) 9TOZ/T0/TT 9TOZ/0£/OT 910Z/8Z/01 910Z/9Z/01 < I 9T0Z/bZ/0T 9TOZ/ZZ/0T 9TOZ/OZ/OT c 9TOZ/81/01 i 9TOZ/9T/OT ~ 9TOZ/bT/0T I 9TOZ/ZT/OT 9T0Z/OT/0T 9TOZ/80/0T 9TOZ/90/0T 9TOZ/ti0/OT 9TOZ/ZO/OT 00 0 0 0 0 0 0 0 0 0 0 0 v m c'.i ,- aanssaad Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, December 05, 2016 10:12 AM To: Wyatt Rivard Subject: RE: NS-28 (PTD # 2050160) Request to Return to Injection Wyatt, As discussed,your plan forward including the return to injection for monitoring and testing as detailed below is APPROVED. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue,Anchorage, AK 99501, (907)793-1250(phone), (907) 276-7542(fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Monday, December 05, 2016 8:14 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Subject: RE: NS-28 (PTD#2050160) Request to Return to Injection SCANNED DEC 0 52016 Chris, Waivered Northstar gas injector NS-28 (PTD#2050160) was SI on 11/22/16 for lack of injectivity and increased IA pressurization. Slickline recently drifted the tubing and encountered a sand bridge in the XN nipple at 12176'. Slickline made bailing runs over the weekend and was able to clear out the sand bridge and successfully drift to deviation. One attempt was made to reset the SSSV without success. Going forward, Hilcorp requests to return the well injection to warm up the well for the SSSV set and then leave the well on injection for a 28 day monitoring period to confirm that injectivity and IA pressurization are near historic averages.An AOGCC witnessed MIT-IA is due in January as per the AA which would be obtained following the 28 day monitoring period.A TIO plot is attached for reference. Plan Forward -Operations 1) Return well to injection and reset SSSV. Obtain AOGCC witnessed SVS test 2) Monitor well on injection for 28 days 3) Obtain AOGCC witnessed MIT-IA as per AIO 23.003 Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Hilcorp Alaska 1 • I 9L0Z/S0/ZI -- 90 /EO/ZL -- 9L0Z/L0/ZL -- 90Z/6Z/LL -- 9L0Z/LZ/LL -- 9L0Z/SZ/LL -- 9LOZ/£Z/LL 9LOZ/LZ/LL .E 9LOZ/6L/LL -- 9LOZ/LL/LL 9LOZ/SL/LL - 9LOZ/EL/LL - 9LOZ/LL/LL - 9LOZ/60/LL 9LOZ/LO/LL -- 9L0Z/SO/LL -- 9LOZ/E0/LL _ 9LOZ/LO/LL - 9-10Z/OE/OT 0 - 9L0Z/8Z/OL I 910Z/9Z/OL 9LOZ/bZ/OL p 9L0Z/ZZ/OL oo I- 9L0Z/OZ/OL - 9LOZ/8L/OL cn 910Z/91/01 ` 9LOZ/tiL/OL - 9LOZ/ZL/OL — _ 9LOZ/OL/OL - 910Z/80/01 - 9LOZ/90/0L - 910Z/170/01 - 9LOZ/ZO/OL -- 910Z/0E/60 910Z/8Z/60 - 91OZ/9Z/60 aA 9L0Z/tiZ/60 - 9LOZ/ZZ/60 E - 910Z/OZ/60 t 910Z/81/60 9LOZ/9L/60 - 910Z/bt/60 - 910Z/Z1/60 91OZ/O1/60 \ ` 91OZ/80/60 l ► 910Z/90/60 88 0 0 0 00 0 0 0 0 0 0 fr N aanssaad Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, November 22, 2016 5:44 PM To: Wallace, Chris D (DOA) Subject: NS-28 (PTD#2050160) Shut In for IA Buildup Rate and Lack of Injectivity Attachments: NS-28 TIO.x 1 Chris, Northstar gas injector NS-28(PTD#2050160)operates under admin approval AIO 23.003 for slow TxIA communication. The well was SI today for an increased rate of IA pressurization and a lack of injectivity.The TIO plot is attached for reference. On 10/24/16 the Northstar plant's HPB gas compressor went down causing gas injection rates and pressures to decrease for all Northstar gas injectors.After HPB went down, NS-28's injection rate declined to zero over the next two days, suggesting the other Northstar injectors were taking all of the gas at the decreased injection rate/pressure. On 11/10/16 the HPB compressor repairs were completed and fieldwide gas injection resumed at the normal rates& pressures. NS-28's injection rate, however, remained at zero.Two intermittent days of very low injection rate and a decreasing wellhead temperature trend indicate that only a very small amount of injection is taking place below the meter's reading threshold. Soon after HPB was repaired,the well's annular build up rate also appears to have increased to roughly 80 psi/day.This represents an increase from the 15 psi/day average observed on the well since operation began under the AA. The increased IA pressurization combined with the lack of gas injection indicates a possible obstruction or problem with the downhole injection valve. Initial diagnostics will focus on drifting the tubing and troubleshooting the MCX with slickline. Diagnostic results will be provided and AOGCC approval will be requested prior any return to injection. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Hilcorp Alaska NOV 2knit; W y V9toz/zz/tt 9102/81/tt 9t0z/til/tt L-9-10Z/O1/IT 91OZ/90/tt 91OZ/ZO/tt 910Z/6Z/OZ 910Z/SZ/01 .--, N OZ/tZ/OZ a CD 910Z/LZ/OZ 9IOZ/£t/OZ 9tOZ/60/01 9tOZ/SO/Ot 9102/10/OZ iiiii9tOZ/LZ/60 9IOZ/EZ/60 910Z/6t/60 910Z/SZ/60 < NOV-IT/600 9TOZ/L0/60 I O 910Z/E0/60 E ' 910Z/0£/80 O_ 1 910Z/9Z/80 = 910Z/ZZ/80 oNo 910Z/81/80 z 91oZ/bt/80 9toZ/Ot/80 Q I AL Troz/90/80 — 9toZ/Z0/80 I 910z/6Z/LO 91oZ/SZ/LO 9IOZ/tZ/LO di 91oZ/Lt/LO 9102/EZ/LO al ..../ 9TOZ/60/L0 9102/SO/LO 910Z/t0/L0 .c 910Z/LZ/90 9IOZ/£Z/90 I 910Z/61/90 910Z/S1/90 910Z/11/90 910Z/L0/90 910Z/E0/90 910Z/O£/S0 N OZ/9Z/S0 I 0 0 0 0 0 0 0 0 0 0 0 V) CY M N .-i aanssaad • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, March 23, 2016 9:35 AM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L(DOA) Subject: RE: NS-28 (PTD #2050160) Remain on Injection Attachments: NS-28 TIOwWHT.xlsx Chris, Northstar gas injector NS-28 (PTD#2050160) returned to injection on 1/29/16 for a 28 day monitoring period. On 2/25/16, monitoring was extended an additional 28 days after significant thermal-induced IA pressure fluctuations. Both IA and OA were bled on 2/26/16 following a —20 degF increase in injection temperature over a 5 day period. A TIO plot with wellhead temperature is attached for reference. Since the bleed, IA pressure has increased 400 psi in 25 days. Over a period of relatively stable injection temperature (169 degF on 3/13 to 170 degF on 3/20), IA build up rate (BUR) was roughly^'8 psi/day. Going forward, Hilcorp would like to monitor the well on injection for an additional 28 days to determine if this small IA BUR represents thermal effects or continued TxIA communication. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 SCONEp APR 0 4 2016 Ilil...'p 1,1..•1..4. 11.4 From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sen . ursday, February 25, 2016 11:24 AM To: Wyatt • and Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: NS-28 (PTD # 2050 0) Remain on Injection Wyatt, Thank you for the email. Continued injection and moo storing for an additional month seem warranted. The IA appears to be fluctuating significantly and another month should ge a more definitive view. Please send us a follow up after another month. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907) 793-1250(phone) 1 • • I 9TOZ/So/£0 9TOZ/£0/£0 9TOz/TO/£0 N0Z/8z/z0 9TOZ/9Z/Z0 9TOZ/bZ/Z0 9TOZ/ZZ/Z0 O 9TOZ/0Z/Z0 I 9TOZ/8T/Z0 9-10Z/9I/Z0 9T0Z/t7i/Z0 - 9I0Z/ZI/Z0 O - 9IOZ/0T/Z0 0 - 9TOZ/80/Z0 17- 00 - 9I0Z/90/Z0 N - 9IOZ/b0/Z0 z - 9T0Z/Z0/z0 9IOZ/T£/T0 I 910Z/6Z/10 9IOZ/LZ/T0 9I0Z/SZ/T0 9TOZ/£Z/TO 9TOZ/TZ/I0 9TOZ/6T/TO 9TOZ/LT/T0 9T0Z/ST/I0 taa 9TOZ/£I/TO 9T0Z/TI/TO E 9TOZ/60/T0 9T0Z/L0/TO 9IOz/SO/TO 9T0Z/£0/T0 9T0Z/T0/TO STOZ/0£/ZT SIOZ/8z/z1 STOz/9Z/ZT SIOZ/t7Z/ZT o 0 0 0 0 0 0 0 0 0 o n o L. o �n o Ln o U1 a' M M N N aanssaad Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, February 25, 2016 12:05 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: NS-28 (PTD # 2050160) Remain on Injection Chris, Thanks for the quick response, I will follow up with an updated TIO in 28 days. Thanks, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 sc pfEV MAR 1 5 2016 )Illilrv �Ir \3.�YI.a. t I From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Thursday, February 25, 2016 11:24 AM To: Wyatt Rivard Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: NS-28 (PTD # 2050160) Remain on Injection Wyatt, Thank you for the email. Continued injection and monitoring for an additional month seem warranted. The IA appears to be fluctuating significantly and another month should get us a more definitive view. Please send us a follow up after another month. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. 1 • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, February 25, 2016 10:59 AM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L(DOA) Subject: RE: NS-28 (PTD# 2050160) Remain on Injection Attachments: NS-28 TIO.xlsx Chris, Northstar gas injector NS-28 (PTD#2050160) returned to injection on 1/29/16 following a gas lift valve change out to restore tubing integrity.The well has been on injection with no further indication of IA pressurization. Hilcorp believes there are no further integrity concerns with this well and would like the well to remain on injection. A TIO plot is attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 llitrnrp Mask*. 1.11,4: From: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: Friday, January 29, 2016 9:06 AM To: Wyatt Rivard Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: NS-28 (PTD # 2050160) Request To Return To Injection Wyatt, Pla elow for the return to injection for confirmation of repairs is APPROVED. Notify on first in i ' of leak, or if all looks good send us a confirmation email with TIO at the end of the 28 days monitoring. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday,January 29, 2016 9:06 AM To: 'Wyatt Rivard' Cc: Regg,James B (DOA); Brooks, Phoebe L(DOA) Subject: RE: NS-28 (PTD#2050160) Request To Return To Injection Wyatt, Plan below for the return to injection for confirmation of repairs is APPROVED. Notify on first indication of leak,or if all looks good send us a confirmation email with TIO at the end of the 28 days monitoring. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 ScpPINED JUL 2 2016 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Friday, January 29, 2016 7:16 AM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L(DOA) Subject: RE: NS-28 (PTD # 2050160) Request To Return To Injection Chris, Northstar gas Injector NS-28(PTD#2050160) underwent an acoustic leak detect log on 1/7/16 to determine the location of TBGxIA communication.The log showed a clear indication of a leak in the well's single GLM at 4551'. Slickline subsequently pulled the dummy valve on 1/23/16 and found evidence of packing damage.The valve was replaced and tubing pressurized with gas to-3800 psi against a tubing tail plug. Subsequent monitoring has shown zero IA pressurization. A passing diagnostic MIT-IA was obtained on 1-27-16 to 2977 psi. Hilcorp believes tubing integrity has been restored and would like to return the well to injection for 28 days to confirm.The leak detect log,TIO and MIT-IA are attached for reference. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 1 . • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, November 26, 2015 3:30 PM To: Wallace, Chris D (DOA) Cc: Regg,James B (DOA) Subject: RE: NS-28 (PTD#2050160) Monitoring Results Attachments: NS-28 TIO.xlsx Chris, Gas injector NS-28(PTD#2050160) returned to injection on 10/29/15 for additional diagnostics and monitoring of inner annulus build up rate (BUR).The well was shut-in on 11/25/15 and will remain SI until further diagnostics/remediation are complete. The IA was bled twice over the monitoring period with an average BUR of—110 psi per day, down from the previous injecting BUR of 175 psi/day. Inner annulus fluid level depressed from surface when first put on injection on 10/29/15 to 200' based on fluid levels taken on 11/19/15 and 11/22/15.An additional fluid level will be taken with the well shut-in to assist in leak point diagnostics. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 Nitnrp ttn.t►a. l.l,c: SCANNED AUG 1 7 2016 m: Wallace, Chris D (DOA) [mailto:chris.wallace@alaska.gov] Sent: day, October 29, 2015 1:51 PM To: Wyatt Riva Cc: Regg, James B (b0A)• Brooks, Phoebe L(DOA) Subject: RE: NS-28 (PTD 150160) Request To Return to Injection Wyatt, Approved for the requested plan forward with . .rms and bleeds as stated below- including up to 28 days additional injection for diagnostics and monitoring. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) 1 • • i i i i iv STOZ/SZ/TT STOZ/£Z/TT STOZ/TZ/TT STOZ/6T/TT q1/4.%4N.. 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Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue SCANNED AUG 1 12096 Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.Rov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Thursday, October 29, 2015 1:42 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: NS-28 (PTD # 2050160) Request To Return to Injection Chris, Hilcorp would like to return Northstar gas injector NS-28 (PTD#2050160)to injection for a 28 day monitoring period following recent diagnostics. Background NS-28 was shut in for TBGxIA communication on 9/4/15.At the time of shut-in,the IA build up rate(BUR)was roughly 175 psi/day. Following shut in,the IA continued to pressurize at a steady BUR of"60psi/day. Diagnostics efforts focused on the integrity of the subsurface injection valve and control line.The control line was found to have communication with tubing suggesting a leak by the sub surface injection valve seal(s). Despite successfully resetting the inject valve five times with good draw down tests,the control line continued to communicate with the tubing through either the top or the bottom injection valve seals. GX sealant was pumped into the control line and eventually a positive pressure differential was achieved but slow annulus pressurization continued. • On 9/19/15,while troubleshooting both the MCX injection valve and the controlTme,the shut-in IA BUR appeared to decrease from ''60 psi/day to—20 psi per day where it has remained since.A passing MIT-IA(attached) was achieved on 9/26/15 demonstrating two competent barriers under fluid. Request Going forward,we would like to return NS-28 to injection for a 28 day monitoring period to determine if we have positively affected the IA BUR with the well warm and on gas injection. Plan Forward 1) Return the well to injection for 28 days, monitoring IA BUR 2) Following 28 day injection period, obtain an IA fluid level for comparison with"'685'fluid level pre MIT-IA Mitigations Alarms: In the event that IA pressurization reaches 1750 psi, an automated alarm notifies the board operators. Bleeds: If required,the IA would be bled to maintain it below 2000 psi not to exceed two bleeds per week. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 11i1 ,,p t[oi.1,a. 1.1.4. 2 STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMMSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate U Pull Tubing U Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Convert to Gas Injector ❑✓ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development.0 Exploratory ❑ 205.016 • 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23248-00-00 r 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0312799 • NORTHSTAR UNIT NS-28 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): `" N/A NORTHSTAR FIELD/NORTHSTAR OIL POOL • .Y r t� 11.Present Well Condition Summary: ���� i �� � >> Total Depth measured 14,150 4 feet Plugs measured N/Afeet O - ' `" true vertical 11,170 r feet Junk measured N/A feet 10,540, 12,142& Effective Depth measured 14,106 feet Packer measured 12,186 feet 9,140,10,558& true vertical 11,166 feet true vertical 10,597 feet Casing Length Size MD TVD Burst Collapse Conductor 200' 20" 200' 200' Surface 3,590' 13-5/8" 3,590' 3,197' 5,020psi 2,260psi Intermediate 10,671' 9-5/8" 10,671' 9,287' 7,930psi 6,620psi Production 1,851' 7" 12,365' 10,751' 8,160psi 7,020psi Liner 1,964' 4-1/2" 14,150' 11,170' �g 8,430psi 7,500psi : e Perforation depth Measured depth See Attached Schematic feet i49 True Vertical depth See Attached Schematic feet Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/13CR Vam Top 12,190' 10,600' 9-5/8 x 7 ZXP LTP 7 x 4-1/2 S-3 1,008'MD Packers and SSSV(type,measured and true vertical depth) HRD ZXP LTP TRM-4E See Above 995'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 17 107 Subsequent to operation: 0 0 0 226 2,933 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development ` Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ Q ' SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-219 Contact Taylor Wellman Email twellman c(�.hilcorp.com Printed Name Taylor Wellman Title Operations Engineer ' Signature / Phone p 777-8449 Date 10/14/2015 Form 10-404 Revi -. /2015 ,,JJ 10. 2,7,-i s" OCT)2D / Z 1 1U1y Submit Original Only .. • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reac alaska.gov; doa.aoocc.prudhoe.bav(dtalaska.gov; phoebe.brookst0alaska.00v: chris.wallace(8alaska.aov OPERATOR: Hilcorp Alaska LLC FIELD/UNIT/PAD: Northstar/NSU/NS DATE: 05/29/15 OPERATOR REP: Crowder AOGCC REP: Herrera Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NS-28 Type Inj. G TVD _ 10,558' Tubing 4200 4200 4174 4199 Interval 1 P.T.D. 2050160 Type test P Test psi 2639.5 Casing 822 3084 3027 3003 P/F P • Notes: OA 245 527 513 501 Well Type In]. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In]. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In]. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In]. ND 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 10-426(Revised 06/2010) MIT NSU NS-28 5-29-15.xls ix ID Northstar Unit . 0 Well: NS-28 SCHEMATIC Last Completed: 5/9/2005 Hilcorp Alaska,LLC PTD: 205-016 CASING DETAIL KBE=55.67/BFE=40'MSL(CB 15.67)[ L Size Type Wt/Grade/Conn ID Top Btm 1 20" Conductor 169/X-56/N/A N/A Surface 200' 2pI I 13 3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,590' 9S-25i0: 5/8" Production 53.5/L-80/Btrc. 8.535 Surface 10,671' { 7" Liner 29/L-80/Hydril 511 6.184 10,513' 12,365' CI '; 1 4-1/2" Liner 12.6/13Cr80/ 3.958 12,186' 14,150' 3/8" TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/ 3.958 Surface 12,186' 2 JEWELRY DETAIL No Depth Item 1 1,008' 4-1/2"TRM-4E SSSV,ID=3.812":LOCKED OUT 4/22/06,Control Line Ported Open 2 4,551' GLM-MMG Dummy w/RK Latch 1 3 10,504' 9-5/8"x 7"Baker ZXP LTP,ID=6.30" 4 10,525' 9-5/8"x 7"Baker Flex Lock Liner Hanger,ID=6.33" f 5 12,096' 4-1/2"X Nipple,ID=3.813 , 6 12,117' 4-1/2"Fiber Optic Transducer,ID=3.958 7 12,142' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 1 8 12,165' 4-1/2"X Nipple,ID=3.813 9 12,176' 4-1/2"XN Nipple,ID=3.725"(12,146'ELM) I 10 12,186' 7"x 5"Baker HRD LTP w/11-3/4"Tieback,ID=4.430" I 11 12,190' 4-1/2"Self Aligning Mule Shoe,ID=3.958" 12 12,209' 7"x 5"Baker Flex Lock Liner Hanger,ID=4.39" 13 12,218' 5"x 4-1/2"XO,ID=3.91" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status Ivishak 13,282 13,657' 11,108' 11,128' 375 5/6/2005 Open i Ivishak 13,796' 13,916' 11,141' 11,150' 120 10/23/2005 Open I` f 3 WELL INCLINATION DETAIL ti KOP @ 250' j 1 4 Max Hole Angle=89 deg.@ 13,550' Max Angle at Top Perf:85 Deg.@ 13,282' OPEN HOLE/CEMENT DETAIL 20" Driven 9-5/8" 13-3/8" 542 sx PF"L",472 sx Class"G"in 16"Hole 5 9-5/8" 645 sx Extended,458 sx Class"G"in 12-1/4"Hole 7" 438 sx Class"G"in 8-1/2"Hole 6 4-1/2" 210 sx Class"G"in 6"Hole �� TREE&WELLHEAD 8 Tree CIW 5-18"SSKI(uprated to 6.Sksi) Wellhead ABB-VGI 13-5/8"Multibowl 6.Sksi i 9 GENERAL WELL INFO API:50-029-23073-00-00 1 LI 10 Completed-4/15/2002 12 Add Perforations-10-23-2005 13 SSSV Lock Out-4/22/2006 ri• & SAFETY NOTE Well requires a safety valve,4-1/2"Chrome Tubing Liner 4-1/r4 0 1D=14,150(MD)/TD=11,170(TVD) PBTD=14,106'(MD)/PBTD=11,166'(TVD) Created By:TDF 10/14/2015 Hilcorp Alaska, LLC flavor') ►.«k:,.Li.0 Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date NS-28 50-029-23284 205-016 4/17/2015 5/25/2015 Daily Operations: 4/15/15-Wednesday No operations to report. 4/16/15-Thursday No operations to report. 4/17/15-Friday PRESSURE TEST LUBRICATOR TO 3,00PSI LOW/4,000PSI HIGH. DRIFTED W/3.84 G-RING TO SSSV NIPPLE @ 970'SLM. PULLED 4-1/2"X-LOCK, CARRIER W/K-VALVE (SER#K-20) FROM 970'SLM 1,008' MD. K-VALVE IS MISSING BROKE @ WINDOWS ON XO. DRIFTED W/3.625 CENT&3.25 LIB TO DEVIATION @ 11,896'SLM (80+/-),SLIGHT IMPRESSION OF FISH ON LIB". 4/18/15-Saturday PRESSURE TEST LUBRICATOR TO 300PSI LOW/4,000PSI HIGH. BRUSHED SSSV NIPPLE WITH 4-1/2" BLB&3.70 G-RING. SET PX PLUG BODY W/(4-3/16" ECi PORTS) @ 966'SLM/1008' MD.SET PRONG (OAL=102"W/1-3/4"FN 1.89 OD BODY). 3,750 PSI BELOW PLUG WHEN SET. 4/19/15-Sunday No operations to report. 4/20/15-Monday No operations to report. 4/21/15-Tuesday No operations to report. • Hilcorp Alaska, LLC ililwirpAlaska,LLC Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date NS-28 50.029-22348-00-00 205-016 4/17/2015 5/25/2015 Daily Operations: 4/22/15-Wednesday No operations to report. 4/23/15-Thursday No operations to report. 4/24/15-Friday No operations to report. 4/25/15-Saturday No operations to report. 4/26/15-Sunday No operations to report. 4/27/15-Monday No operations to report. 4/28/15-Tuesday TREE SWAP. ND TREE. NU NEW CAMERON 5-1J8"6,500#TREE. PRESSURE TEST TREE TO 6,500PSI- PASSED. BLEED PRESSURE ON TREE TO 1,500PSI.TEST TUBING HANGER TEST VOID TO 6500PSI- PASSED. BLEED OFF ALL PRESSURE AND PULL TWC. " y • • Hilcorp Alaska, LLC 'Mein")Alau.ka. Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date NS-28 50.029-22348-00-00 205-016 4/17/2015 5/25/2015 Daily Operations: 4/29/15-Wednesday Set tree and weld pipe. 4/30/15-Thursday Welding pipe and getting measurments. 5/1/15-Friday Redress and test wireline valves,check out equipment and spot up units. 5/2/15-Saturday Pressure test lubricator to 300psi low/4,000psi high. Pulled pxn plug at 1,008' md. Drifted and tagged xn-nipple at 12,176' md. ran SBHP gauges. Lay down for night. 5/3/15-Sunday Pressure test lubricator to 300psi low/4,000psi high. Unable to get valve to set.Tried 2x,second time with over size packing on bottom of assembly and different running tool. Never able to gain control line integrity. over sized packing torn up on second run. lay down for night. 5/4/15-Monday No operations to report. 5/5/15-Tuesday No operations to report. • • Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Saturday, September 19, 2015 1:38 PM To: Wallace, Chris D (DOA) Cc: Taylor Wellman;Alaska NS - Northstar - Operations Leads Subject: Gas Injector NS-28 (PTD # 2050160) Warm Up Again For Injection Valve Reset Attachments: image003jpg Chris, Northstar gas injector NS-28 ( PTD#2050160) received a GX sealant treatment on the SSSV control line as part of ongoing TBGxIA troubleshooting. Going forward, we plan to again reset the SSSV and monitor the inner annulus for pressurization. Plan Forward 1) Bring the well on injection for up to six hours to warm up tubing for injection valve reset. 2) SI the well and set the injection valve 3) Bleed tubing and perform a closure test 4) Monitor inner annulus for pressurization for 3 days. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com<mailto:ckanyer@hilcorp.com> 3800 Centerpoint Drive, Suite 1400 I Anchorage,AK 99503 [HAK_Logo] Sent from my iPhone SCANNED JUN 0 1 2016 1 • • pTo 5 - C.- Loepp, Victoria T (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, September 11, 2015 5:47 PM To: Wallace, Chris D (DOA) Cc: Regg, James B (DOA); Loepp, Victoria T(DOA) Subject: RE: Gas Injector NS-28 (PTD#2050160) TBGxIA Communication Follow Up Flag: Follow up Flag Status: Flagged tigo 1\;�ta 1 6 2Q16 Chris, (�� The delay in communication of the 8/30/15 bleed on NS-28 stemmed from a misinterpretation of the pressurization as being thermally induced. NS-28 Bleed Events The inner annulus on NS-28 was bled four times from 8/14/15 to 8/26/15.The bleeds were associated with either increases in injection gas temperature or a return to injection following the resetting/testing of the subsurface injection valve.The outer annulus was also bled on 26-Aug due to thermal effects.An additional bleed on 30-Aug was attributed by operators to recent thermal events but was later determined by review of injection rate and temperature to have no thermal contribution. Communication of NS-28 Bleeds On 9/4/15 the inner annulus pressurization trend was recognized by operators as potential pressure communication. The Well Integrity Engineer was contacted and the IA pressure and injection temperature was reviewed along with the bleeds. It was determined that the 8/30/15 bleed and annular pressurization had no thermal explanation, suggesting TBGxIA communication.The well was SI and AOGCC notified. Please call with any questions. Thank You, Wyatt Rivard 'dell Integrity Engineer 0: (907) 777-83471C: (509)670-8001i wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 1 Anchorage,AK 99503 iii&wri► <t.i•l.r. II 4. From: Wyatt Rivard Sent: Friday, September 04, 2015 6:38 PM To: Wallace, Chris D (DOA) Cc: 'Regg, James B (DOA)'; Loepp, Victoria T(DOA) Subject: Gas Injector NS-28 (PTD # 2050160)TBGxIA Communication Chris, 1 • Northstar gas injector NS-28 ( PTD p050160) was recently converted from a production well to a gas injector under sundry 315-219.The well had a passing AOGCC witnessed MIT-IA to 3003 psi on 5/29/15.The well now appears to be exhibiting possible TBGxIA communication with the IA requiring five bleeds in two weeks.The bleeds were initially attributed to thermal effects due to corresponding swings in injection gas temperature in addition to Off/On cycling of the well that occurred during the 8/19 and 8/24 SVS testing and injection valve reset. However, after a more thorough review of the temperature/pressure/injection trends, it was determined that there was no wellhead temperature change associated with the 8/30 bleed. Once this was determined,the well was immediately SI.The well will remain SI until integrity is restored. As per AIO 23, indications of pressure communication on an injector shall result in SI of the well and communication to AOGCC within 24 hours.A review of the method with which annular bleeds on injectors are communicated at Northstar will be conducted to determine the delay in notification of the 8/30 bleed. Results/follow-up will be provided next week. August Bleeds Date Annulus Pressures Notes 14 Aug IA 1750-750 Increase in WHT w/corresponding bump in OA pressure 19-Aug IA 1750-575 Well SI then RTI for SVS testing 24-Aug IA 1794-850 Well SI then RTI SVS reset 26 Aug IA 1754-683 Increase in WHT w/corresponding bump in OA pressure 26 Aug OA 783-191 Increase in WHT w/corresponding bump in OA pressure 30-Aug IA 1752-1052 NS-28 Diagnostic Steps Going Forward 1) Perform a packoff test of wellhead seals 2) Verify control line integrity 3) Bleed tubing pressure to^'1500 psi to create differential above and below the injection valve 4) Monitor IA pressurization for equalization with tubing above or below the injection valve Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 H Mew, <<i M,i.i.t: 2 j-1 i L.c' — C1/ Loepp, Victoria T (DOA) From: Tom Fouts <tfouts@hilcorp.com> Sent: Monday,June 29, 2015 3:30 PM To: Loepp, Victoria T (DOA) Cc: Taylor Wellman; Wyatt Rivard Subject: NS-28 Sundry#205-016 Status Update: Revised Follow Up Flag: Follow up Flag Status: Flagged Victoria, I needed to correct the"Subsequent: Gas-MCF" entry due to a misplaced comma. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Presse Prior to well operation: 0 0 0 17 106 Subsequent to 0 47,416 0 280 4,300 operation: Thanks, Tom Fouts I Senior Ops/Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907)777-8398 Mobile: (907) 351-5749 SCANNED JUL 2 12015. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1 5 I S DATE: Monday,June 01,2015 P.I.Supervisor �I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC NS-28 FROM: Matt Herrera NORTHSTAR UNIT NS-28 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J- NON-CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS-28 API Well Number 50-029-23248-00-00 Inspector Name: Matt Herrera Permit Number: 205-016-0 Inspection Date: 5/29/2015 Insp Num: mitMFH150531152820 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS-28 • Type Inj G 1TVD 10558 Tubing 420o - 4200 - 1 4174 - 419971 PTD 2050160 - Type Test SPT Test psi 2639 5 IA 822 3084- 3027 - 3003 • Intery INITAL P/F P OA i 245 ' 527 1 513 501 - Notes: Operations determined test pressure p�EC 3 `101 Sa Monday,June 01,2015 Page 1 of 1 Brooks, Phoebe L (DOA) 2oSOI1oo From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Monday, June 01, 2015 4:16 PM To: Brooks, Phoebe L (DOA) Subject: RE: MIT NS-28 (PTD # 2050160) Attachments: image001jpg; image002jpg; MP H-04 SCHEMATIC 5-26-2015.doc; NS-28 SCHEMATIC 4-7-2015.doc Hello Phoebe, Please see the attached schematics for MPH-04 and NS-28. I have updated the NS-28 MIT form with the Matt Herrera's name. Thank You, Wyatt Rivard I Well Integrity Engineer 0 007) 777-8. 47 C: (509)070-8001 I wrivard@hilcorp.com .3R(10 Cent Suite 1 400 I Anchorage,AK 99503 Ilil .artr 110.1ka. IAA SCANNED ,I,.lIN 0 9 2015 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, June 01, 2015 3:57 PM To: Wyatt Rivard Subject: RE: MIT NS-28 (PTD # 2050160) Wyatt, Can I also add MPH-04 to the list? Thanks, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you,contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. 1 Northstar Unit Well: NS-28 II SCHEMATIC Last Completed: 5/9/2005 ua�1)11):ti.«k a.t.l.c PTD: 205-016 CASING DETAIL KBE=55.67'/BFE=40'MSL(CB 15.67') Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 169/X-56/N/A N/A Surface 200' 217'J { 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,590' e 9-5/8" Production 53.5/L-80/Btrc. 8.535 Surface 10,671' \.?f "' [ I 7" Liner 29/L-80/Hydril 511 6.184 10,513' 12,365' 1 4-1/2" Liner 12.6/13Cr80/ 3.958 12,186' 14,150' 13_3/8„ 1 TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/ 3.958 Surface 12,186' 2 JEWELRY DETAIL No Depth Item 1 1,008' 4-1/2"TRM-4E SSSV,ID=3.812":LOCKED OUT 4/22/06,Control Line Ported Open 2 4,551' GLM-MMG Dummy w/RK Latch 3 10,504' 9-5/8"x 7"Baker ZXP LTP,ID=6.30" 1 4 10,525' 9-5/8"x 7"Baker Flex Lock Liner Hanger,ID=6.33" 5 12,096' 4-1/2"X Nipple,ID=3.813 f I 6 12,117' 4-1/2"Fiber Optic Transducer,ID=3.958 1 7 12,142' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 8 12,165' 4-1/2"X Nipple,ID=3.813 9 12,176' 4-1/2"XN Nipple,ID=3.725"(12,146'ELM) 10 12,186' 7"x 5"Baker HRD LTP w/11-3/4"{Tieback,ID=4.430" 11 12,190' 4-1/2"Self Aligning Mule Shoe,ID=3.958" I 12 12,209' 7"x 5"Baker Flex Lock Liner Hanger,ID=4.39" { 13 12,218' 5"x 4-1/2"XO,ID=3.91" PERFORATION DETAIL ISands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Ivishak 13,282 13,657' 11,108' 11,128' 375 5/6/2005 Open Ivishak 13,796' 13,916' 11,141' 11,150' 120 10/23/2005 Open 3 WELL INCLINATION DETAIL F ') KOP @ 250' 4 Max Hole Angle=89 deg.@ 13,550' Max Angle at Top Perf:85 Deg.@ 13,282' OPEN HOLE/CEMENT DETAIL 20" Driven 9-5/8" 13-3/8" 542 sx PF"L",472 sx Class"G"in 16"Hole I 5 9-5/8" 645 sx Extended,458 sx Class"G"in 12-1/4"Hole 7" 438 sx Class"G"in 8-1/2"Hole 6 4-1/2" 210 sx Class"G"in 6"Hole ; R /;;,/,'J'.:. 7 TREE &WELLHEAD 8 Tree CIW 5-18"SSKI(uprated to 6.5SKI) Wellhead ABB-VGI 13-5/8"Multibowl SKSI 9 GENERAL WELL INFO API:50-029-23073-00-00 10 Completed-4/15/2002 JIIIIL 12 Add Perforations-10-23-2005 13 SSSV Lock Out-4/22/2006 7"/ I SAFETY NOTE Well requires a safety valve,4-1/2"Chrome Tubing Liner 4-1/2"1 I TD=14,150(MD)/TD=11,170(TVD) PBTD=14,106'(MD)/PBTD=11,166'(TVD) Created By:TDF 4/7/2015 Wallace, Chris D (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, May 19, 2015 8:50 AM To: Wallace, Chris D (DOA); Regg,James B (DOA) Cc: Alaska NS - Northstar- Operations Leads;Alaska NS - Northstar- Field Foreman;Taylor Wellman Subject: Injector NS-28 (PTD#2050160) Ready For Injection Attachments: image002 jpg All, NS-28(PTD#2050160)was recently converted from a natural flow producer to a Gas Injector.A passing pre MIT-IA was completed on 5-16-15.Well is ready to put on injection for stabilization and compliance testing. Plan Forward—Operations 1) Place well on injection. Use caution,annuli are fluid packed. 2) AOGCC MIT-IA when well is on injection and thermally stable. Thank You, Wyatt Rivard I Well Integrity Engineer 0: (907) 777-8547 I C: (509)670-8001 I wrivard@hilcorp.com 3800 Centerpoint Drive,Suite 1400 I Anchorage,AK 99503 I l ik urp 11i.hw. 1.1.4. SCANNED MAY 2 8 2 015 1 • • OF T� Alaska Oil and Gas -w\��\��j,�s� THE STATE m�' -- em—'� of Conservation Commission_ ALAS :A tI -- 333 West Seventh Avenue " 1WALKERAnchorage, Alaska 99501-3572 Op. P � GOVERNOR BILL g Main: 907 279 1433 ALAS Fax 907 276 7542 www.aogcc.alaska.gov Taylor Wellmanc Operations Engineer -0/ C7Hilcorp Alaska, LLCap5 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field, Northstar Oil Pool,Northstar Unit NS-28 Sundry Number: 315-219 Dear Mr. Wellman: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, al-6 Cathy V Foerster Chair DATED this i lay of April, 2015 Encl. C E VE D APR 10 2015 STATE OF ALASKA r---S. q-11'7 f is • ALASKA OIL AND GAS CONSERVATION COMMISSION AoG rc APPLICATION FOR SUNDRY APPROVALS 2QAAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate D• Pull Tubing❑ Time Extension El Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Convert tWtlnlecfor D • !/� 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska,LLC Exploratory ❑ Development D 205-016 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23248-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 458A Will planned perforations require a spacing exception? Yes ❑ No D NORTHSTAR UNIT NS-28 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312799 • Northstar Field/Northstar Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): 'Junk(measured): 14,150 • 11,170 . 14,106 11,166 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 200' 20" 200' 200' Surface 3,590' 13-5/8" 3,590' 3,197' 5,020psi 2,260psi Intermediate 10,671' 9-5/8" 10,671' 9,287' 7,930psi 6,620psi Liner 1,851' 7" 12,365' 10,751' 8,160psi 7,020psi Liner 1,964' 4-1/2" 14,150' 11,170' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft). See Attached Schematic See Attached Schematic 4-1/2" 12.6#/13CR VAM-TOP 12,190 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 7"ZSXP LTP,7"x 4-1/2"S-3 Packer&7"x 5"HRD ZXP LTP . 10,504(MD)/9,140(TVD), 12,142(MD)/10,558'(TVD)&12,186(MD)/10,597(TVD) and and 4-1/2"TRM-4E SSSV 1,008(MD)/995(TVD) 12.Attachments: Description Summary of Proposal D 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service D 14.Estimated Date for / 15.Well Status after proposed work. 4/17/2015 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ D • WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman 1 Email twellmanta'�hilcorD.com Printed Name Ta for Wellman Title Title Operations Engineer Signature / `i,4' " Phone 777-8449 Date 4/10/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test CJ Location Clearance ❑ Other: dtwfc wi'f-). zsszCI /171cT- !.4 t—<V--/ ✓< c/ ctFtt",- 1.--1--6, , lt�ccl ip,J- f, _ Spacing Exception Required? Yes El No 4 Subsequent Form Required: / — 4o 4. APPROVED BY Approved by: COMMISSIONER THE COMMISSION Dat,. L[/7 /) V #//7//5" '�i��/� ' g-17.'15 t Submit p and Form 10-403(Revised 10/2012) Approvnnc1ti aI f 2 onths fr m he date of approval. Atta mems in Duplicate MS ( APR 10 1015f4/�n 'it' as •'s Tree Swap Well: NS-28 PTD: 2050160 Hilcorp Alaska,LL API: 50-029-23248-00 Well Name: NS-28 API Number: 50-029-23248-00 Current Status: SI—Convert to GI Rig: SL&Tree/WH Crew Estimated Start Date: April 17, 2015 Estimated Duration: 4 days Reg.Approval Req'std? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts 777-8398 Permit to Drill Number: 2050160 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Mike Dunn (907) 777-8382 (0) (907) 351-4191 (M) Current Bottom Hole Pressure: 4972psi @ 11,100' TVD (Based on SBHPS on NS-28 09/22/14) Maximum Expected BHP: 4972psi @ 11,100' TVD (Based on SBHPS on NS-28 09/22/14) Max. Anticipated Surface Pressure: 3,900psi (Based on 0.1 psi/ft. gas gradient) Last WHP: 3700psi Recorded on 04/22/14 Brief Well Summary: The well NS-28 was completed with a 9-5/8"x7" casing string in May 2005. The well has 4-1/2", 12.6#, 13CR tubing and received an MIT-IA upon installation in May 2005. In March 2006 the TRSSSV began to have troubls functioning. At this time a K-Valve was placed into the well and the TRSSSV was locked out. In June 2009, the SSV was replaced for corrosion due to the incorrect trim. The well has shown no indications of mechanical issues since this point. NS-28 is a production well that is located high the structure and produces at above marginal GOR's. The well has little on-time and has been shut in since October 2013. Objective: To establish barriers (downhole plug and BPV) and then replace the existing dry hole tree to an injection tree. JJ - Procedure: CmNGt>/, I �G`/ WG' �r'© kci -1y- Gtr ef Tree &Wellhead Work lvdi- Cori i ec/-ij ,r4 's /tie!/ tO a�! 1. RU BPV lubricator and pressure test to 300psi low/4000psi high. l‘T J PGtor 5 h 4l` ® '^/ 2. Pull BPV. RD from well. v for 'M/reyed r9 C0ve7 r I/ Slickline ficaM T�`�' / 1. RU and pressure test PCE to 300psi low/4000psi high. 2. RIH and pull the K-Valve set in the SSSV profile at 1008' md. 3. MU 4-1/2"PX plug and set in the SSSV profile at 1008' md. 4. RD slickline unit. Operations 1. Bleed the tubing down to 0 psi and monitor for 30 minutes for pressure build up. Tree &Wellhead Work Tree Swap Well: NS-28 PTD: 2050160 flacon)AI,,,ka.LI. API: 50-029-23248-00 5. Set TWC in hanger profile and pressure test to 4000psi. 6. ND dry hole tree and NU new Cameron 5-1/8" 5000# (Uprated 6500#) injection tree as per attached diagram. 7. Pressure test tree to 250psi low for 5 minutes (stabilized) and 6500psi high for 5 minutes (stabilized). 8. Pull TWC. RD from well. Slickline 9. Connect jumper hose from gas source to increase tubing pressure to approximately 3700psi. 10. RU and pressure test PCE to 300psi low/4000psi high. 11. RIH and pull PX plug from SSSV profile at 1008' md. 12. Drift tubing with 3-3/8" dummy gun to deviation. 13. RIH and set 4-1/2" MCX valve into the SSSV profile at 1008' md. 14. RD slickline unit. Pumping—Once well is on injection 15. MIT-IA to 2700psi. a. Note: 9-5/8" casing is set on emergency slips. These are protected by the IC hanger secondary seal. Test pressures will be 0.25 x TVD of packer (0.25 x 10578'=2645psi). Contingency—Dependent upon gas injectivity Expected BHP remains the same as all proposed perforation intervals are in the same Ivishak formation sands. E-Line 16. RU and pressure test PCE to 300psi low/4000psi high. 17. RIH and perforate +1- 12,730' — 13,000' md. Attachments:Wellbore Schematic(Current& Proposed),Tree Diagram (Current& Proposed), Area of Review for conversion Northstar Unit • Well: NS-28 SCHEMATIC Last Completed: 5/9/2005 Hilcorp Alaska,LLC PTD: 205-016 CASING DETAIL KBE=55.67/BFE=40 MSL(CB 15.67') Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 169/X-56/N/A N/A Surface 200' 20"I 1 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,590 9-5/8" Production 53.5/L-80/Btrc. 8.535 Surface 10,671' [ I 7" Liner 29/L-80/Hydril 511 6.184 10,513' 12,365' 4-1/2" Liner 12.6/13Cr80/ 3.958 12,186' 14,150' 133/8„ TUBING DETAIL C4-1/2" Tubing 12.6/13Cr80/ 3.958 Surface 12,186' 2 JEWELRY DETAIL No Depth Item 1 1,008' 4-1/2"TRM-4E SSSV,ID=3.812":LOCKED OUT 4/22/06,Control Line Ported Open 2 4,551' GLM-MMG Dummy w/RK Latch 3 _ 10,504' 9-5/8"x 7"Baker ZXP LTP,ID=6.30" 4 10,525' _ 9-5/8"x 7"Baker Flex Lock Liner Hanger,ID=6.33" 5 12,096' 4-1/2"X Nipple,ID=3.813 6 12,117' 4-1/2"Fiber Optic Transducer,ID=3.958 7 _ 12,142' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 8 12,165' 4-1/2"X Nipple,ID=3.813 9 _ 12,176' 4-1/2"XN Nipple,ID=3.725"(12,146'ELM) 10 12,186' 7"x 5"Baker HRD LTP w/11-3/4"{Tieback,ID=4.430" 11 12,190' 4-1/2"Self Aligning Mule Shoe,ID=3.958" 12 12,209' 7"x 5"Baker Flex Lock Liner Hanger,ID=4.39" 13 12,218' 5"x 4-1/2"XO,ID=3.91" PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status Ivishak 13,282 13,657' 11,108' 11,128' 375 5/6/2005 Open Ivishak 13,796' j 13,916' 11,141' 11,150' 120 10/23/2005 Open j 3 WELL INCLINATION DETAIL KOP @ 250' 4 Max Hole Angle=89 deg.@ 13,550' Max Angle at Top Perf:85 Deg.@ 13,282' OPEN HOLE/CEMENT DETAIL 20" Driven 9-5/g' 13-3/8" 542 sx PF"L",472 sx Class"G"in 16"Hole 5 9-5/8" 645 sx Extended,458 sx Class"G"in 12-1/4"Hole 7" 438 sx Class"G"in 8-1/2"Hole 6 4-1/2" 210 sx Class"G"in 6"Hole 2 7 TREE&WELLHEAD 8 Tree ABB-VGI 5-1/8"5KSI t Wellhead ABB-VGI 13-5/8"Multibowl 5KSI i 9 GENERAL WELL INFO API:50-029-23073-00-00 iitti10 Completed-4/15/2002 12 Add Perforations-10-23-2005 13 SSSV Lock Out-4/22/2006 7"i 6 SAFETY NOTE Well requires a safety valve,4-1/2"Chrome Tubing Liner 4-1/2 4 IL TD=14,150(MD)/TD=11,170(TVD) PBTD=14,106'(MD)/PBTD=11,166'(TVD) Created By:TDF 4/7/2015 Northstar Unit Well: NS-28 11 PROPOSED Last Completed: 5/9/2005 tlitcorp Alaska,LLC PTD: 205-016 CASING DETAIL KBE=55.67/BFE=40'MSL(CB 15.67) Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 169/X-56/N/A N/A Surface 200' 20"41 I [ L 13-3/8" Surface 68/L-80/Btrc. 12.415 Surface 3,590 9-5/8" Production 53.5/L 80/Btrc. 8.535 Surface 10,671' . 7" Liner 29/L-80/Hydril 511 6.184 10,513' 12,365' i 1 '.1, 4-1/2" Liner 12.6/13Cr80/ 3.958 12,186' 14,150' 3/g, TUBING DETAIL 4-1/2" Tubing 12.6/13Cr80/ 3.958 Surface 12,186' 2 JEWELRY DETAIL No Depth Item 1 1,008' 4-1/2"TRM-4E SSSV,ID=3.812":LOCKED OUT 4/22/06,Control Line Ported Open 2 4,551' GLM-MMG Dummy w/RK Latch 3 10,504' 9-5/8"x 7"Baker ZXP LTP,ID=6.30" 4 10,525' 9-5/8"x 7"Baker Flex Lock Liner Hanger,ID=6.33" 5 12,096' 4-1/2"X Nipple,ID=3.813 6 12,117' 4-1/2"Fiber Optic Transducer,ID=3.958 7 12,142' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 8 12,165' 4-1/2"X Nipple,ID=3.813 9 12,176' 4-1/2"XN Nipple,ID=3.725"(12,146'ELM) 10 12,186' 7"x 5"Baker HRD LTP w/11-3/4"{Tieback,ID=4.430" 11 12,190' 4-1/2"Self Aligning Mule Shoe,ID=3.958" 12 12,209' 7"x 5"Baker Flex Lock Liner Hanger,ID=4.39" 13 12,218' 5"x 4-1/2"XO,ID=3.91" i PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Date Status • ± ±13,000' ±11,005' ±11,084' Future/ 12 Ivishak ,730' ±270 * Contingency 3 Ivishak 13,282 13,657' 11,108' 11,128' 375 5/6/2005 _ Open Ivishak 13,796' 13,916' 11,141' 11,150' 120 10/23/2005 Open 4 WELL INCLINATION DETAIL KOP @ 250' Max Hole Angle=89 deg.@ 13,550' 9-5/g'a 6 Max Angle at Top Perf:85 Deg.@ 13,282' 6 7 OPEN HOLE/CEMENT DETAIL 20" Driven 13 3/8" 542 sx PF"L",472 sx Class"G"in 16"Hole 8 9-5/8" 645 sx Extended,458 sx Class"G"in 12-1/4"Hole 7" 438 sx Class"G"in 8-1/2"Hole 4-1/2" 210 sx Class"G"in 6"Hole 9 TREE&WELLHEAD 10 Tree ABB-VGI 5-1/8"5KSI 12 Wellhead ABB-VGI 13-5/8"Multibowl SKSI 13 r"• 6 GENERAL WELL INFO API:50-029-23073-00-00 Completed-4/15/2002 Add Perforations-10-23-2005 SSSV Lock Out-4/22/2006 Our• SAFETY NOTE Well requires a safety valve,4-1/2"Chrome Tubing Liner TD=14,150(MD)/TD=11,170(TVD) - -----_-----------__.-_-- PBTD=14,106'(MD)/PBTD=11,166'(TVD) Created By:JLL 4/10/2015 NS-28 Injector Conversion April, 2015 NS-28 Well Integrity History • 04/18/05: Land 9-5/8" casing.Test casing hanger seals to 5000psi. • 05/08/05: Land completion. Test tubing hanger seals to 5000psi. • 05/09/05: MIT-T to 4200psi—Passed, MIT-IA to 4200psi—Passed. • 05/03/09: Pumped 8.07 gal RG-2401 into conductor • 06/22/09: Unable to pull TWC; retiever tool and pin stuck in tree • 07/02/09: Recovered two pulling nubbins from above TWC • 07/11/09: Pulled TWC • 03/02/15: Set TWC • 03/04/15: Pull TWC, set BPV. • 03/05/15: Change tree to dry hole tree, test upper tree to 5000psi. Steps to Conversion: 1) Pull BPV 2) Pull K-Valve from 1008' md. 3) Set PX plug in SSSV nipple at 1008' md. 4) Set TWC 5) Change-out tree to 5-1/8" 6500# Injection Tree 6) Pull TWC 7) Pull PX plug 8) Set 4-1/2" MCX injection SSSV 9) Start injection 10) State witnessed MIT-IA to 2700 psi after injection stabilizes Contingency 11) Add Perforations+/-12,700'—13,000' and Area of Review — Northstar Island Unit NS-28 (2050160) Prior to the conversion of well NS-28 from producer to gas injector, an Area of Review (AOR) must be conducted. This AOR found one other well within 1/4 mile of NS-28's entry point into the Ivishak Formation: NS-14 parent wellbore that has been abandoned. Table 1: Wells within AOR Well Name PTD Annulus Integrity NS-28 2050160 MIT-IA on 05/08/2005 passed to 4200 psi NS-14 2010180 P&A parent wellbore, sidetracked to new location. Table 2: Completion Detail Well Name Liner Size Hole Size Vol Cement Ivishak Depth NS-28 4-1/2" 6-1/8" 52.3 bbls Class G, Good 12,583' and (10,860 tvdss) cement across Ivishak zone up to 12,186' Basis: Rig cementing records and full returns during job NS-14 4-1/2" 6-1/8" 28 bbls Class G, 12,678' and (10,856 tvdss) Good cement across Ivishak zone up to 12,490' Basis: 17Feb2002 SCMT NS-28 (PTD #2050160) In well NS-28, a 4-1/2" production liner was run to 14,150' and and hung at 12,209'. The completion enters the Ivishak formation at 12,583' and (10,860 tvdss). The 4-1/2" liner was cemented with 52.3 bbls of class G cement. During the cement job, full returns were observed, the wiper plug was bumped and held 4200psi. The liner top packer was then set. The packer setting tools were unstung and the excess cement was circulated from the well. A volume of 20 bbls of excess cement was observed in the returns. No cement bond log was run on the 4-1/2" liner section. The high inclination across this section increases the difficulty in logging (reaches 70 degrees at 12,840') this section. NS-14 (PTD#2010180) In well NS-14, a 4-1/2" production liner was run to 13018' and and hung at 12,319' md. The completion enters the Ivishak formation at 12,678' and (10,856' tvdss). The liner was cemented with 28 bbls of class G cement. During the job full returns were observed with 5 bbls excess cement circulated to surface after the liner top packer was set. A cement bond log (Schlumberger SCMT 17-Feb-2002)was run to assess the cement job. N', • (�10,90 ` . a.o flit.ibill' 11 , e N. -0 .., 1 176 ft 24 c MVO **Ilk --- litt *SillikeP.-1741*:. N 5-�14� __oy.f,. C:441440.45. 0,55 4, Figure 3: Ivishak Map Illustrating AOR • NS-28 13 5/8 X4'A tubing hanger/W 4"BPV • profile 111 1.‘uiu•r rod¢ `� e16 a G�aH off¢ 1Tark ,16 I.,G `a�66CA ,c ii 1.APP1, \<t po S "1.111 �,'1•r' , sm Wm. ,3516SPaae �' ,-� 11i1� 13 5/8 5M X 13 5/8 SM -IIlli „„,,q f"'. -a1 21/16 gray HWO valve Tubing spool � 4. l 1 I. 1 ,r` 11- 4 p II r7:- .11 lop . 2 1/16 gray HWO valve 13 5/8 9 5/8 41/2 NS-28 PROPOSED + 13 5/8"x 51/8 Hanger 5"'H'profile 5-1/8"Cameron 5000#(Uprated 6500psi)Otis,Tree Cap iforl 11111.111 5-1/8"Cameron 5000#(Uprated 6500psi)Swab Valve � -art f0 111 5-1/8"Cameron 5000#(Uprated '~/ J1/�r 3-1/8"Cameron 5000#(Uprated 6500psi)Wng Valve {~ H} N 6500psi)Companion Valve 41 sr 5-1/8"Cameron 5000#(Uprated 6500psi) Valve,SSV w/Baker Hydraulic"C"Actuator lyy u.17-L.)? 5-1/8"Cameron 5000#(Uprated 6500psi)Master Valve 413 4,546 Itle keS ,,3222 E .- 135/85Mx135/85M Tubing spool "0#1 'i If Ill_ll.I1 ,I 5$le•. 21/16 gray HWO valve El ry vt "Ili 0-8.• ra lio 21/16 gray HWO valve 13 5/e 9 5/8 4 1/2 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may bescanned during a special rescan activity or are viewable by direct inspection of the file. ao 5 - OJ ~ Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed ""111111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Diskettes, No. D Other, No/Type: D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: ~ Date to /#1/ tJ 7 , I Date {g I~ jêJ7 ~ X 30 =-(PO D Other:: BY: ME 1111111111111111111 l11P + S = TOTAL PAGES hs (Count does not include cover sheet) Isl Isl Project Proofing BY: ~ Isl Scanning Preparation Date: p Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES ~ Date &/'J-Cfjo7 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO Isl vvvf NO BY: Stage 1 BY: Maria Date: Isl 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 1111I BY: Maria Date: Isl Comments about this file: Quality Checked 111111111I111111111 10/6/2005 Well History File Cover Page.doc BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 ~r~~,~t a.:r 4~'i 4 `' t r Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, • I~AY (~ ~ '~[~1ii ~' aos-l~ 1(0 ~~,a~ Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Northstar ai~ni~nln Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 50029232440000 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 50029230880000 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 50029230810000 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 50029230680000 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 50029230520000 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 50029229850000 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 50029233030000 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 50029230910000 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 50029230170000 1.7 na 1.7 na 6.8 5/1/2009 NS14A 2052020 50029230260100 0.9 na 0.9 na 2.8 5/1/2009 NS16A 2061410 50029230960100 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 50029231130000 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 50029231020000 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 50029231220000 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 50029231180000 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 50029231260000 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 50029231280000 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 50029231460000 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 50029231110000 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 50029231810000 na na 2.6 5/2/2009 NS-26 2002110 50029229960000 at surface na na na na na NS27 2010270 50029230030000 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 50029232480000 1.5 na 1.5 na 8.1 5/3!2009 NS30 2052070 50029232930000 0 na 0 na 4.3 5/3/2009 NS32 2031580 50029231790000 na na 1.7 5/3/2009 NS33A 2081890 50029233250100 Sealed conductor na na na na NS34A 2080170 50029233010100 0 na 0 na 2.2 5/3/2009 'Not measured due to rig proximity. • • bpi BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 ;: Anchorage, Alaska 99519-6612 ~~~ ~~~Y z~r~ May 26, 2009 i~~~ ail ~ et~~ ~~~i~i~sion ~~~12~A~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t~ Avenue ~~~"~ ~ ~~ Anchorage, Alaska 99501 ~ ~ _ ~,.~ Subject: Corrosion Inhibitor Treatments of Northstar Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from Northstar that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~ Andrea Hughes BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ ~,~~ Date Northstar 5/26/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al NS05 2050090 1.7 na 1.7 na 10 4/30/2009 NS06 2021010 0.5 na 0.5 na 1.7 4/30/2009 NS07 2020770 1.1 na 1.1 na 5.3 4/30/2009 NS08 2020210 0.75 na 0.75 na 3.6 4/30/2009 NS09 2012190 1.2 na 1.2 na 3.4 4/30/2009 NS10 2001820 0.25 na 0.25 na 3 4/30/2009 NS11 2060360 0.75 na 0.75 na 5.1 5/1/2009 NS12 2021100 1.2 na 1.2 na 3.2 5/1/2009 NS13 2010860 1.7 na 1.7 na 6.8 5/1/2009 NS141\ 2052020 0.9 na 0.9 na 2.8 5/1/2009 NS16 2061410 1.3 na 1.3 na 5.8 5/1/2009 NS17 2021690 1.2 na 1.2 na 2.6 5/1/2009 NS18 2021410 1.5 na 1.5 na 7.3 5/1/2009 NS19 2022070 1.5 na 1.5 na 10.2 5/2/2009 NS20 2021880 1.4 na 1.4 na 8.5 5/2/2009 NS21 2022180 1.7 na 1.7 na 4.3 5/2/2009 NS22 2022230 1.6 na 1.6 na 10.2 5/2/2009 NS23 2030500 0.75 na 0.75 na 3 5/2/2009 NS24 2021640 0.75 na 0.75 na 2.6 5/2/2009 NS25 2031660 * na * na 2.6 5/2/2009 NS27 2010270 0.6 na 0.6 na 1 5/3/2009 NS28 2050160 1.5 na 1.5 na 8.1 5/3/2009 NS30 2052070 0 na 0 na 4.3 5/3/2009 NS32 2031580 na na 1.7 5/3/2009 NS34 2080170 0 na 0 na 2.2 5/3/2009 *Not measured due to rig proximity. ~, L JUN 0 1 1009 • • _~~:, . . . ~ ~~ o3io~~2oos DC~ NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\I,aserFiche\C;vrPgs_InsertslA~ticrofilm Marker.doc J 0 J "'.....4.- DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 Permit to Drill 2050160 Well Name/No. NORTHSTAR UNIT NS-28 MD 14150 TVD 11170 Completion Date 5/10/2005 --~-~---"".---._._""-~ ~..~.__.~-~-------~----- -~------'----'---'-----~'----'-----'----~- REQUIRED INFORMATION Mud Log No -~-----_.- Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L ____~_w__·_______._·__ ~------_._"_.._._-- J ~ ~.s- API No. 50-029-23248-00-00 UIC N Directional su~ .. DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, GYRO, PWD, RES, DEN, NEU Well Log Information: Log/ Electr Data Digital Dataset Ty~Med/Frmt Number Name -----_._-~- ~ Sonic og Production 14 Perforation I ~g Perforation I I~c Pds 13416 I ì ~ 13416 I nd uction/Resistivity ~ 13416 Ind uction/Resistivity i ~g 13416 I ì ~ 13416 I Well Cores/Samples Information: Name Interval Start Stop Samples No (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH/ Scale Media No Start Stop CH Received 5 Col 1 0 12250 Open 1/17/2006 5 Blu 13150 13750 Case 1/17/2006 5 Blu 12000 14015 Case 1/17/2006 12000 14030 Case 1/17/2006 134 12379 Open 1/25/2006 134 12379 Open 1/25/2006 134 12379 Open 1/25/2006 134 12379 Open 1/25/2006 134 12379 Open 1/25/2006 5 Blu 5 Blu 5 Blu 5 Blu 5 Blu e Comments Ultra Sonic Imaging Log w/PDC GR 22-April 2005 Memory PSP GR/CCLlSTP/DEFT/GHOS T 20 Aug 2005 Perf Record GR/CCL 2 7/8 Power Jet 16-0ct-2005 Perf Record GR/CCL 2 7/8 PowerJet 21-0ct-2005 Resistivity/Service both MD & TVD PDS True Vertical Depth Log Composite Print Resistivity Measured Depth Log Composite Print Resistivity Measured Depth Log Composite Final Print Service True Vertical Depth Log Composite Final Print Service . Sent Sample Set Number Comments Received Permit to Drill 2050160 MD 14150 TVD 11170 ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Analysis Received? ~ DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 Well Name/No. NORTHSTAR UNIT NS-28 Operator BP EXPLORATION (ALASKA) INC Completion Date 5/10/2005 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? C!J/N ®/N Formation Tops Comments: Fm Compliance Reviewed By: API No. 50-029-23248-00-00 Date: ~- ~rg Ju ~~ ~ i--= e - bp . . Date: 01-24-2006 Transmittal Number:92749 BPXA WELL DATA TRANSMITTAL ~D5-0/0 Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 SW Name Date Contractor Loa Run Top Depth Bottom Depth Loa Type NS28 05-02-2005 SCH 1-8 330 14150 VISION SERVICE TVD NS28 05-02-2005 SCH 1-8 12240 14150 VISION RESISTIVITY MD NS28 05-02-2005 SCH 1-8 12240 14150 VISION RESISTIVITY TVD NS28 05-02-2005 SCH 1-8 330 14150 VISION SERVICE MD NS28 05-02-2005 SCH 1-8 198 14153 CD ROM Attn: Jason Smith Howard Okland Tim Ryherd Doug Choromanski Jim Seccombe Cheryl Ploegstra Murphy Exploration AOGCC DNR MMS BPXA BPXA RECEIVE 2 52006 ~J-"""c"'W R, '" . . , ~i;,.;1 .'JI .~ Anchr~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . . Date: 01-17-2005 Transmittal Number:92745 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. NS29 survey supersedes all previously delivered data. If h 1 h PDC 5644091 you aye any questIOns, p¡ ease contact me In t e at - SW Name Date Contractor LoCI Run Top Depth Bottom Depth LoCI Type ~ f\JS28 1 0/21/2005 SCH 1 12000 14030 PERF RECORD ./ NS28 10/16/2005 SCH 1 12000 14015 PERF RECORD /' NS28 08/20/2005 SCH 1 13150 13750 PRODUCTION PROFILE NS06 06/30/2005 SCH 1 13500 13864 PRODUCTION PROFILE /' NS28 04/22/2005 SCH 1 0 12250 ULTRA SONIC IMAGING LOG NS29 06/03/2005 SCH DIRECTIONAL SURVEY Plea~~~0:~t transmittal. Thank You, Andy Farmer Petrotechnical Data Center J7J~ .~ ~ Attn: Cheryl Ploegstra ACT Data Manager Jim Seccombe BPXA Howard Okland AOGCC Jason Smith Murphy Exploration Kristin Dirks DNR Doug Chromanski MMS REceiVED JAN 1 7 2006 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Alaska Oil & Gas COnS. Ctmmissitn An<;ttørage AO)-- 01~ r=; { -\.. 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA . AlASr Oil AND GAS CONSERVATION COMM. ON REPORT OF SUNDRY WELL OPERATIONS o o o t(ECE/VED NaV 2 3 2005 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development R1 Stratigraphic [J Exploratory Service Stimulate 0 Other Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 205-0160 6. API Number: 50-029-23248-00-00 Ion P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 9. Well Name and Number: 55.67 KB NS28 8. Property Designation: ADL-312799 11. Present Well Condition Summary: 10. Field/Pool(s): NORTHSTAR Field/ NORTHSTAR OIL Pool Total Depth measured 14150 feet Plugs (measured) None true vertical 11170.23 feet Junk (measured) None Effective Depth measured 14106 feet true vertical 11165.98 feet Casing Length Size MD rvD Burst Collapse Surface 3546 13-3/8" 68# L-80 44 - 3590 44 - 3196.61 4930 2270 Production 10628 9-5/8" 53.5# L-80 43 - 10671 43 - 9286.86 7930 6620 Li ner 1862 7" 29# L-80 10513 - 12375 9148.14 - 10760.41 8160 7020 Liner 1964 4-1/2" 12.6# 13Cr80 12186 - 14150 10596.88 - 11170.23 8430 7500 Perforation depth: Measured depth: 13282 - 13657 13796-13916 True Vertical depth: 11108.01 - 11127.97 11140.64 - 11150.32 Tubing: (size, grade, and measured depth) 4-1/2" 12/6# 13CR80 40-12190 Packers and SSSV (type and measured depth) 7" Liner Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer 10513 12142 12186 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 1284 2047 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 14280 92 100 18288 591 100 15. Well Class after oroposed work: Exploratory Development R'i 16. Well Status after proposed work: Oil R'i Gas [J WAG Tubing pressure 3064 2911 Service x Contact Sharmaine Vestal WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Data Mgmt Engr Sign Phone 564-4424 Date 11/23/2005 .~ cDMs ~,5 rn Submit Original Only Form 10-404 Revised 04/2004 , '- c.. . . NS28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY lÄ~~!IYITY~~TE:<I'iii;':¡ ...,;._',; ¡i;;¡~~I('IIJI~~X ..~.=~i ;¡¡£:~1Ji~. ;;$;,,; "tiliú>i~~~;1 1 0/16/2005 ***Continued From Previous Days WSR*** ! TII/0=750/vac/vac Assist E-line (Add Perfs) - Pumped 5 bbls methanol spear, 135 bbls 160* filtered seawater, 3 bbls methanol. Final WH P's=400/vac/vac *** Job Postponed*** 10/17/2005 TI0=3010/vac/5, temp=104. OA FL near surface (Injectivity Test). 10/19/2005 ***Prepare equipment @ shop*** 10/20/2005 Travel to Northstar Island, Prep to perforate using Welltec tractor. Little Red repairing pump truck. 10/21/2005 *****Continue from WSR 10-20-05***** Little Red pump repair completed 0100 hrs. Continue prep work while waiting on morning chopper for Welltec crew and SWS e-line tech. RIH for perf run #4 w/20' x 2.875" 2906 PJ HMX 6 SPF 60deg. phasing gun. Make jewelery log pass & make correction (-15 ft). ***Continued on WSR 10-21-05*** 10/21/2005 T/IIO = 3500/vac/vac Assist E-line w/ perforating operations. Pumped 5bbls 60/40, 300bbls hot seawater, 10bbls meth down tubing. FWHP's = O/vac/vac 10/22/2005 E-Line Tractor Add Perf:***Continued from WSR 10-21-05*** Tie into MWD dated 5/1/05. Perf interval gun #4 w/20' x 2.875" 2906 PJ HMX 6 SPF 60deg. phasing gun. (13836' -13856') POOH. ***Continued on WSR 10-23- 05.*** Stand by on weather. 10/22/2005 Heated up 350bbls seawater (180*F) for NS-28. 10/23/2005 E-Line Tractor Add Perf: ***Continued from WSR 10-22-05.*** Stand by on weather. Winds subsided. RU to run gun #5, perforate 13816' - 13836' elmd, gun #613796' elmd - 13816' elmd. Tie into MWD dated 5/1/05. Same guns used on both runs = 20' x 2.875" 2906 PJ HMX 6 SPF 60 deg phasing. RD & package up unit. Informed pad op well ready to POP. *** Job Complete*** 10/23/2005 T/I/O= 1000/vac/vac Assist E-Line w/ perforating operations. Pumped 220bbls hot seawater, 10bbls meth. Later, 175bbls seawater, 10bbls meth. FWHP's = 400/vac/vac 10/24/2005 ***Continue to package up E-Line unit & re-dress tools.*** FLUIDS PUMPED BBLS 780 30 810 I ~~~AL '.... ø I ;J , 'i / ¡ if ¡ l' !Í ¡ AI1ASIiA. OIL AND GAS / CONSERVATION COMMISSION / -- ~ ' !j~ ì # ~ 1 'W FRANK H. MURKOWSK/, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Sr. Petroleum Engineer P.O. Box 196612 Anchorage, AK 99519-6612 .~~~, Re: Northstar NS28 Sundry Number: 305-276 Dear Mr. Francis: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, tY4f~þ John K. Norman Chairman µ.. DATED thisjî day of September, 2005 Enc!. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development ø /~ Exploratory 0 e Suspend D Repair well D Pull Tubing D 1. Type of Request: Abandon U Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 14150 Casing Surface Production Liner Liner Perforation Depth MD (ft): 13282 -13657 / Packers and SSSV Type: 12. Attachments: \t..l6t\-.,..~ J ''l~c Cç e Perforate ~ Waiver U Stimulate D Time Extension D Re-enter Suspended Well D OtherTI Service 0 5. Permit to Drill Number: 205-0160 / 6. API Number: Stratigraphic 0 55.67 KB 50-029-23248-00-00 / 9. Well Name and Number: NS28 ./ 10. Field/Pools(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): Effective Depth TVD (ft): rPIUgS (measured): I 14106 11165.98 None Size MD TVD Burst rTotal Depth TVD (ft): 11170.23 Length 3546 10628 1862 1964 13-3/8" 68# L-80 9-5/8" 53.5# L-80 7" 29# L-80 44 43 10513 12186 4-1/2" 12.6# 13Cr80 3590 44 10671 43 12375 9148.14 14150 10596.88 4930 7930 8160 8430 IJunk (measured): I None Collapse 2270 6620 7020 7500 3197 9287 10760 11170 - - Tubing Size: 4-1/2" 12.6# Tubing Grade: 13CR80 Tubing MD (ft): 40 - 12190 Perforation Depth TVD (ft): 11108.01 -11127.97 - - 7" Liner Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer DescriDtive Summary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for /) Commencing Operations: ( 9/2j/2005 16. Verbal Approval: '-d~ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Michael Francis .# Title Sr. Petroleum Engineer Signature &yv1,- / ~ 1.1. I) P ..AJ'""'ne 564-4240 Date \ fl,"/ COMMISSION USE ONLY V- Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D Other: Date: BOP Test 0 Packers and SSSV MD (ft): 10513 12142 12186 o 0 13. Well Class after proposed work: / Exploratory 0 Development ø 15. Well Status after proposed work: Oil ø / Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Service 0 Abandoned 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Michael Francis 9/15/2005 Isund~ Number:3iJ5.-~7 ((; Mechanical Integrity Test 0 Location Clearance 0 Subsequent Form Required: l 0 .~ 40 4 . Approved by: /1/ ~ ¡J~. 1 L :{ W'" r ·/~v/ " / RBDMS BFL SEP 2 0 2005 APPROVED BY THE COMMISSION Date: ç; v 17 --0 5' COMMISSIONER Form 10-403 Revised 11/2004 OR G f\Jp,L Submit in Duplicate e . bp ...,. ,~'.'~. .....~... ,.~..- .,..- ~...~ .,.~ .¡;.... .'~~.'~\~ BP Exploration (Alaska) Inc. "~ 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 16, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS28 to Perforate BP Exploration Alaska, Inc. proposes to add perforations in the NS28 well. This well is producing at a high GOR and adding perforations lower in the oil column is recommended to lower the GOR to make this well more competitive in this .,/ gas handling constrained field. The procedure includes the following major steps: T e Electric Line Work Descri tion Add 125' of Ivishak perforations 13,796' -13,921' MDrkb / Sincerely, ~~~~ ~~ Senior pet~E~g~~eer BPXA, ACT, Northstar . ST ATE OF ALASKA _ ALASKA I AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: a Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: : 20AAC 25.105 20AAC 25.110 a Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5-10-2005 205-016 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4/2/2005 50- 029-23248-00-00 4a. location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 5/1/2005 NS28 1319' FSL, 648' FEl, SEC.11, T13N, R13E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 3706' FSl, 742' FEL, SEC. 10, T13N, R13E, UM 55.67 Northstar Unit Total Depth: 9. Plug Back Depth (MD+ TVD) 4720' FSl, 2068' FEL. SEC. 10, T13N, R13E, UM 14106 + 11166 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 659824 y- 6031091 Zone- ASP4 14150 + 11170 Ft ADl 312799 TPI: x- 654398 y- 6033364 Zone- ASP4 11. Depth where SSSV set 17. land Use Permit: Total Depth: x- 653050 y- 6034351 Zone- ASP4 (Nipple) 1008' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost aYes ONo 39' MSL 1545' (Approx.) 21. Logs Run: DIR , GR , GYRO, PWD , RES, DEN, NEU 22. CASING, LINER AND CEMENTING RECORD CA.SING SETTING ..QEf>'1'H MD ::SETTING OEP1}j .1VD HOLE .......... : SIZE WT,···PËRFT; GRADE .' TOP I BoTTOM TOP BOTTOM SIZE :/. :: POL;L;ED 20" 169# X-56 Surface 200' Surface 200' 20" Driven 13-3/8" 68# L-80 Surface 3590' Surface 3197' 16" 542 sx PF 'L', 472 sx Class 'G' 9-5/8" 53.5# L-80 Surface 10670' Surface 9286' 12-1/4" 645 sx Extended, 458 sx Class 'G' 7" 29# L-80 10513' 12375' 9148' 10760' 8-1/2" 438 sx Class 'G' 4-1/2" 12.6# 13Cr-80 12186' 14150' 10590' 11170' 6" 210 sx Class 'G' 23. Perforations open to Production (MD + TVD of TOE and 24. TUSING :' . Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diametr, 6 SPF 4-1/2", 12.6# 13CR80 12190' 12142' MD TVD MD TVD 25. 4,919 è:rr. .........:.. 13282' - 13657' 11108' - 11128' :: ÞEMENT : .. DEPTH INTERVAL; (MD) AMOUNT & KIND OF MATERIAL; USED Freeze Protected with 225 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): May 16,2005 Flowing Date of Test Hours Tested PRODUCTION FOR OIL;-BsL; GAs-McF WATER-BSL; CHOKE SIZE I GAS-OIL; RATIO 5/18/2005 4 TEST PERIOD ... 929 4.76 4.33 5132 Flow Tubing Casing Pressure CALCULATED ... Oll-BSl GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 5574 28.6 26 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None "'êtM~TiõÑ1 RBDMs BFL .ìUl 1 .3 2DD5 ~j¿~ ~~ J váí GF Form 10-4 . , ,,/2003 ONTIN ED N REVERSE SIDE C U 0 28. ~ GEOLOGIC MARKERS 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Kuparuk Kuparuk C 10115' 8805' None 10285' 8951' Top of Miluveach 10612' 9235' Top of Kingak 11132' 9686' Top of Sag River 12335' 10727' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Post Rig Summary and a Leak-Off Test Summary Report. 31. I hereby certify that the fore oing is true an correct to the best of my knowledge. Signed Title Technical Assistant DateO, -bl- 0 ~ NS28 Well Number Prepared By Name/Number: Drilling Engineer .' Sondra Stewman, 564-4750 Dan Kara, 564-5667 205-016 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE: ABB-VGI51/8" 5ksi . NS28 _ Actual WELLHEAD: ABB-VGI13-5/8" Multibowl 5ksi 9-5/8" 53.5# L-80 BTM-C @ 1 41 .... 6.8 - AT .... a.. O'MO Vam-Top - LIFT ... 0666' MD -~ ~~- 96' MO I .813" 10 4 3 164' MO 8 ~ _7" .813" 10 1'-' 176' MO 1 .813" 10 - 190' MO --......-; h ~ .958"10 - ril 511 -... ... 14065' MO .4 ~ 133/8", 68#/ft, L-80, BTC @ 359 41/2", 12.6#/ft, 13Cr-80, TUBING 10: 3.958" CAPACITY: 0.01522 BB 4.5" X NIPPLE. @ 120 3 4.5" X NIPPLE, @ 12 3 4.5" XN NIPPLE, @ 12 3 4.5" WLEG, @ 12 3 7", 29#/ft L-80, Hyd @ 12278' MO PBTO @ TO @ 14150 MO DATE 1/18/05 COMMENTS ~IGINAL KB. ELEV = 56' -BF. ELEV = 40.1' B. ELEV = 15.7' /2" TRSV @ 1008' TMOITVO PPG DIESEL FREEZE PROTECTION +/- 3000' TVO (3350'MO) 4 1/2" GLM @ 4000' TVO (4551' MO) T' LINER TOP @ 10522' MD .5" Fiber Optic Transducer .958"10 @ 12117'MO PACKER, 13 Cr @ 12141' MO 4.5" LINER TOP @ 12186' MO 4.5", 12.6#, 13Cr-80 Vam Top Northstar WELL: NS28 API NO: 50-029-23248 BP Exploration (Alaska) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: Rig Release: Rig Number: 4/1/2005 5/10/2005 Spud Date: 4/2/2005 End: 5/10/2005 3/31/2005 18:00 - 00:00 6.00 MOB P PRE -Prep tJ Move Rig -Move Rig f/ NS05 tJ NS28 4/1/2005 00:00 - 19:30 19.50 MOB P PRE -Move Rig f/ NS05 tJ NS28 19:30 - 21:00 1.50 MOB P PRE -Center Rig Over Hole-Level Rig -Install Berms 21 :00 - 00:00 3.00 MOB P PRE -N/U Riser -Berm Rig & Install Stairs -Accepted Rig @ 2100 4/2/2005 00:00 - 04:00 4.00 MOB P PRE -Install Turnbuckles on Riser-Build Walkway Over Cellar -Remove Excess Tubing f/ Pipe Shed-Load BHA #1 & HWDP in Pipeshed -Change Bails & Elevators 04:00 - 06:00 2.00 MOB P PRE -Clean & Secure Rig f/ Spud 06:00 - 08:00 2.00 DRILL N SFAL SURF -Attempt to PIU HWDP-Iron Roughneck Not Torquing Correctly-Rig Mechanic Troubleshooting -Bring Gyrodata Tools tJ Floor 08:00 - 10:30 2.50 DRILL P SURF -P/U HWDP -Torqued w/ Rig Tongs & Stand Back In Derrick 10:30 - 12:00 1.50 DRILL P SURF -M/U BHA #1 12:00 - 12:30 0.50 DRILL P SURF -Water Test Riser 12:30 - 14:00 1.50 DRILL P SURF -Rig Up Schlumberger tJ Gyro Surveying 14:00 - 15:00 1.00 DRILL P SURF -Service Top Drive 15:00 - 16:00 1.00 DRILL P SURF -Pre-spud Meeting w/ WSL -Discussed D7 Drill (Kick wlo Diverter) 16:00 - 16:30 0.50 DRILL P SURF -Clean Out Conductor f/ 156' tJ 201' 16:30 - 18:00 1.50 DRILL P SURF -Drill f/ 201' tJ 330' 18:00 - 19:30 1.50 DRILL P SURF -POH w/ BHA #1 19:30 - 21 :00 1.50 DRILL P SURF -M/U BHA #2 21 :00 - 21 :30 0.50 DRILL P SURF -Gyro Survey 21 :30 - 00:00 2.50 DRILL P SURF -Drill f/ 330' tJ 459' -ART =.6 Hrs. / AST =.42 Hrs. I Total=1.02 Hrs. -Up Wt=1 05K / Down Wt=1 05K I Rot Wt=1 05K 4/3/2005 00:00 - 12:00 12.00 DRILL P SURF -Directional Drill 16" Hole f/459' tJ 1218' -Surveying w/ Gyrodata On Schlumberger Wireline tJ 1000' -PU Wt=142K / SO Wt=140K I Rot Wt=140K -Pump @ 800 GPM I Pressure On Bottom=1450 psi / Off Bottom=1150 psi 12:00 - 00:00 12.00 DRILL P SURF -Directional Drill 16" Hole f/ 1218' t/ 2702' -PU Wt=150K / SO Wt=140K I Rot Wt=140K -Pump @ 847 GPM / Pressure=1900 psi 4/4/2005 00:00 - 07:00 7.00 DRILL P SURF -Directional Drill 16" Hole fl 2702' t/361 0' -PU Wt=175K / SO Wt=145K / Rot Wt=161K -Pump Pressure @ 900 gpm-On Bottom=2320 psi I Off Bottom=2000 psi -Rot Torque @ 40 rpm-On Bottom=10K / Off Bottom=8K 07:00 - 09:30 2.50 DRILL P SURF -Circulate Sweep SIS @ 920 gpm / 2300 psi-Reciprocate & Rotate @ 40 rpm 09:30 - 14:00 4.50 DRILL P SURF -POH fl 3610' t/187' -Pulled Wet -Monitor Well Prior tJ Trip -Pulled 15K tJ 20K Over String Wt f/1930' tJ 1820'-Wiped Clean 14:00 - 15:00 1.00 DRILL P SURF -Clean Clay f/ Stabilizers Printed: 5/16/2005 11:56:59AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 4/4/2005 14:00 - 15:00 1.00 DRILL P SURF -Clear & Clean Rig Floor 15:00 - 16:00 1.00 DRILL P SURF -Cut & Slip Drill Line (102') 16:00 - 18:00 2.00 DRILL P SURF -RIH V 3610' 18:00 - 20:30 2.50 DRILL P SURF -Circulate Weighted Sweep S/S @ 890 gpm /2300 psi-Reciprocate & Rotate @ 40 rpm 20:30 - 23:00 2.50 DRILL P SURF -POH f/3610' V BHA-Pulled Wet -Monitor Well Prior V Trip 23:00 - 00:00 1.00 DRILL P SURF -UD BHA #2 4/5/2005 00:00 - 02:30 2.50 DRILL P SURF UD BHA #2 02:30 - 03:30 1.00 DRILL P SURF -Clear & Clean Rig Floor -Send Stabilzers Down VLE 03:30 - 05:30 2.00 CASE P SURF -R/U V Run 133/8" Casing 05:30 - 14:00 8.50 CASE P SURF -Run 133/8" 68# L-80 Casing V 3590' -Ran 3 Joints & Checked Floats (OK) 14:00 - 15:00 1.00 CASE P SURF -M/U Landing Joint & Hanger -Land Casing-RID Franks Tool & R/U Cement Head 15:00 - 18:30 3.50 CEMT P SURF -Circulate & Condition Mud -Stage Pumps Up f/1 bpm V 10 bpm-1 bpm=208 psi /10 bpm=360 psi -No Losses While Circulating 18:30 - 19:00 0.50 CEMT P SURF -Pressure Test Lines V 3500 psi wI Seawater -Mix CW-101 19:00 - 21 :00 2.00 CEMT P SURF -Pump 25 bbls CW-101/ 75 bbls Weighted Mud Push II @ 10.3 ppg -Pump 414 bbls Lead Cement @ 10.7 ppg /98 bbls Tail Cement @ 15.8 ppg -Displace w/ 25 bbls of Seawater I Tum Over To Rig fl Displacement 21 :00 - 22:00 1.00 CEMT P SURF -Displace Cement w/ 500 bbls 9.3 Drilling Mud I Bumped Plugs @ 5089 Strokes (93% Eff.) -Confirmed Cement V Surface w/ Dye @ 3250 Strokes I PH & Weight Consistent w/ Cement V Surface (200 bbls V Surface) -Pressured to 500 psi Over Circulating Pressure (1300 psi)-Held Three Minutes & Checked Floats (OK) 22:00 - 00:00 2.00 CEMT P SURF -RID Cement Head & Casing Equipment -Clear Rig Floor 4/6/2005 00:00 - 01 :00 1.00 CEMT P SURF -Change Out Bails I Install 5" Elevators -UD Mousehole -Clean & Clear Rig Floor of Casing Tools 01 :00 - 05:30 4.50 BOPSU SURF -N/D Riser & Remove fl Cellar 05:30 - 10:30 5.00 BOPSU SURF -N/U BOPE /Install Choke & Kill Lines -Install Mousehole & Flow Riser 10:30 - 11 :00 0.50 BOPSU SURF -Pressure Up Accumulator -Function Test Annular I Rams & HCR Valves 11 :00 - 12:00 1.00 BOPSU SURF -RlU V Test BOPE -Install Test Plug & Test Joint 12:00 - 18:30 6.50 BOPSU SURF -Test BOPE-Test Annular V 3500 psi-Test Upper & Lower Pipe Rams-Choke Manifold-HCR I Manual Kill & Choke Line Valves- Floor Valves & Top Drive IBOP Valves V 4800 (No Failures) -Pulled Test Plug & Tested Bline Rams V 4800 psi -AOGCC Witness Waived By Jeff Jones-Witnessed by WSL 18:30 - 19:30 1.00 BOPSU P SURF -Blow Down All Lines -Reinstall Turnbuckles On BOPE Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 -Pull Test Plug & Install Wear Sushing -Prepare tJ P/U BHA #3 21 :00 - 00:00 3.00 CASE P SURF -M/U BHA #3 -Obstruction In Casing @ 220' -WSL & DD Evaluate Problem 4/7/2005 00:00 - 03:00 3.00 CASE P SURF -Rotate & Circulate Throuh Obstruction @ 220' / Wiped f/ 250' tJ 200' (OK) -RIH w/ BHA #3 tJ 3475' / Wash tJ 2466' 03:00 - 04:00 1.00 CASE P SURF -Pressure Test Casing tJ 3500 psi f/30 Minutes/ Pumped 6.5 bbl (Test Good) -WSL Reviewed D1, D2 & D5 Drill wI Rig Crew During Test 04:00 - 04:30 0.50 CASE P SURF -Service Top Drive & Slocks 04:30 - 06:30 2.00 DRILL P SURF -Wash tJ Cement @ 3480' -Drill Shoe Track & Float Shoe / Clean Out Rathole tJ 3610' -Pump Pressure=1270 psi @ 715 gpm I Rotate @ 80 rpm 06:30 - 07:30 1.00 DRILL P SURF -Displace tJ New LSND 8.5 ppg Mud System -Circulate & Condition tJ MW in = MW out f/ FIT 07:30 - 08:00 0.50 DRILL P SURF -Drill 20' New Hole tJ 3630' -Pump Pressure=1300 psi @ 800 gpm 08:00 - 08:30 0.50 DRILL P SURF -Perform FIT tJ 12.5 ppg EMW / 665 psi w/ 8.5 ppg MW 08:30 - 00:00 15.50 DRILL P INT1 -Directional Drill 12 1/4" Hole f/ 3630' tJ 6022' w/ RSS -Establish Baseline ECD Data -PU Wt=220K / SO Wt=170K / Rot Wt=190K -Pump Pressure=1900 psi @ 900 gpm -Torque On Bottom=14K I Off Bottom=10K @ 140 rpm 4/8/2005 00:00 - 08:00 8.00 DRILL P INT1 -Directional Drill 12 1/4" Hole f/ 6022' tJ 6776' -PU Wt=248K I SO Wt=183K / Rot Wt=211 K / Bit Wt=1 OK -Pump Pressure=2190 psi 2 895 gpm -Rotary Torque On Sottom=15K I Off Bottom=13K @ 140 rpm 08:00 - 09:00 1.00 DRILL P INT1 -Replace Swab, Liner & Wear Plate #1 Pump / #3 Cylinder 09:00 - 12:30 3.50 DRILL P INT1 -Directional Drill 12 1/4" Hole f/6776' tJ 6965' 12:30 - 13:00 0.50 DRILL P INT1 -Service Top Drive 13:00 - 00:00 11.00 DRILL P INT1 -Directional Drill 12 1/4" Hole f/6965' tJ 7955' -P/U Wt=275K / SO Wt=190K / Rot Wt=220K -Pump Pressure=2450 @ 895 gpm -Rotary Torque= 14K @ 140 rpm 4/9/2005 00:00 - 04:30 4.50 DRILL P INT1 -Directional Drill 12 1/4" Hole f/ 7955' tJ 8481' -PU Wt=275K / SO Wt=190K Rot Wt=220K -Pump Pressure 2450 psi @ 895 gpm -Torque=18K @ 140 rpm -Pump Sweeps @ 500' Intervals 04:30 - 05:00 0.50 DRILL P INT1 -Service Top Drive & Slocks 05:00 - 08:00 3.00 DRILL P INT1 -Directional Drill 12 1/4" Hole f/8481' tJ 8860' 08:00 - 11 :00 3.00 DRILL N DFAL INT1 -POH f/ 8860' tJ 8100' fl Wash Out In Drill Pipe -Pumped Out f/ 8330' tJ 8100' Due tJ Tight Hole -Drill Pipe Washed Out 8100'-Wash Out In Tube l' Above Tool Jt. 11 :00 - 11 :30 0.50 DRILL N DFAL INT1 -RIH f/8100' tJ 8860' 11 :30 - 13:00 1.50 DRILL P INT1 -Circulate & Clean Up Well After Trip 13:00 - 13:30 0.50 DRILL P INT1 -Service Top Drive 13:30 - 21:30 8.00 DRILL P INT1 -Directional Drill 12 1/4 Hole f/8860' tJ 9573' -PU Wt=280K / SO Wt=220K / Rot Wt=245K Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 4/9/2005 13:30 - 21:30 8.00 DRILL P INT1 -Pump Pressure=3400 psi @ 850 gpm -Weight Up tJ 10.5 ppg @ 9000' I Pump Sweeps @ 500' Intervals 21 :30 - 22:30 1.00 DRILL P INT1 -Circulate & Condition Mud Due tJ Lost Circulation -100 % Losses While Pumping I Fluid Level In Annulus Static -ECD Spike tJ 11.8 ppg EMW Preceding Losses 22:30 - 00:00 1.50 DRILL P INT1 -POH f/9573' tJ 9051' -Tight Hole wI Overpulls tJ 380K fl Bottom tJ 9051' 4/1 0/2005 00:00 - 03:00 3.00 DRILL P INT1 -POH f/9051 tJ 8655' (Depth Ghost Reamer Reached) -Tight Hole wI Swabbing I Overpulls tJ 420K -Attempted tJ Pump wi No Succes 03:00 - 21 :30 18.50 DRILL P INT1 -POH fl 8655' tJ BHA #3 -Tight Hole Continuous tJ 133/8 Shoe -Attempted tJ Rotate & Circulate w/ No Success -11" Diameter Clay Ring f/15' Above Ghost Reamer 21 :30 - 00:00 2.50 DRILL P INT1 -POH wI BHA #3 -BHA Packed Off wi 11" Diameter Clay Ring / 75% Covered 4/11/2005 00:00 - 02:00 2.00 DRILL P INT1 -POH w/ BHA #3 I -Remove Nuclear Source I Download MWD -Remove 11" Diameter Clay Ring f/ BHA 02:00 - 03:30 1.50 DRILL P INT1 -Clean & Clear Rig Floor -Remove Rotary Master Bushings & Clean Clay Out of Drip Pan & Flow Line 03:30 - 07:30 4.00 DRILL P INT1 -RIH w/ BHA #4-Shallow Hole Test & Blow Down -Load Nuclear Source I Upload MWD 07:30 - 09:30 2.00 DRILL P INT1 -RIH tJ 3561' 09:30 - 11 :30 2.00 DRILL P INT1 -Circulate & Condition Mud -Losing Mud @ 10-20 bph While Circulating 11 :30 - 13:00 1.50 DRILL P INT1 -Cut & Slip Drill Line -Adusted Brakes 13:00 - 15:30 2.50 DRILL P INT1 -Level Rig & Center Over Hole -Shim Over Flowlines 15:30 - 16:00 0.50 DRILL P INT1 -Change Out Saver Sub On Top Drive 16:00 - 21 :30 5.50 DRILL P INT1 -RIH fl 3550' tJ 3730' -Wash & Ream fl 3730' tJ 5456' 21 :30 - 22:00 0.50 DRILL P INT1 -CBU tJ Lower ECD @ 800 gpm /2200 psi -ECD Lowered f/11.2 ppg EMW tJ 10.9 ppg EMW 22:00 - 00:00 2.00 DRILL P INT1 -Wash & Ream fl 5456' tJ 6493' -Pump Pressure 2000 psi @ 700 gpm -PU Wt=240K I SO Wt=200K I Rot Wt=220K 4/12/2005 00:00 - 08:30 8.50 DRILL P INT1 - Wash & ream to bottom from 6493' tJ 9573'. 08:30 - 09:00 0.50 DRILL P INT1 - Circulate & condition mud. 09:00 - 00:00 15.00 DRILL P INT1 - Drill directional in 12 1/4" hole from 9573' to 10,530' pumping sweeps every 500'. - Drilling parameters: WOB 20K, 850 GPM, 3700 psi, 140 RPM, Tq on bottom 23K, Tq off bottom 14K, P/U wt 300K, SIO wt 240K, Rot wt 265K. ADT 9.3 hrs. - ECD's ranging from 11.0 - 11.1 ppg. ECD spike of 11.8 ppg @ 10,255' & 11.65 ppg @ 10,270'. No losses. Circulate for ECD management. 4/13/2005 00:00 - 02:00 2.00 DRILL P INT1 - Drill directional in 12 1/4" hole from 10,530' to 10,671' MD. - Top of Miluveach @ 10,612' MD. Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 4/13/2005 02:00 - 05:30 3.50 DRILL P INT1 - Pump hi-vis sweep & pump surface to surface. 850 GPM, 3675 psi, 140 RPM & reciprocating. - UD single & rack back one stand. Resume circulating B/U x 1.5 05:30 - 07:00 1.50 DRILL P INT1 - Short trip to 9149'. Wipe tight spots @ 10,300', 10,150', & 10,040'. (30K drag) 07:00 - 08:00 1.00 DRILL P INT1 - RIH to TD @ 10,671' w/ no problems. 08:00 - 11 :00 3.00 DRILL P INT1 - Pump hi-vis sweep & circulate surface to surface & additional B/U x 1.5. - Monitor well & B/D lines. 11 :00 - 19:00 8.00 DRILL P INT1 - POH to HWDP. Spotted G Seal pill across Shrader on way out. - Hole in good condition for running casing. 19:00 - 22:30 3.50 DRILL P INT1 - UD BHA #4. 22:30 - 23:00 0.50 DRILL P INT1 - Clear BHA from rig floor. 23:00 - 23:30 0.50 BOPSU P INT1 - Pull bowl protector & install test plug. 23:30 - 00:00 0.50 CASE P INT1 - C/O upper pipe rams to 9 5/8". 4/14/2005 00:00 - 02:00 2.00 CASE P INT1 Fin change top rams to 9 5/8" 02:00 - 02:30 0.50 CASE P INT1 Body test BOP 250 low - 3500 high as per BP & AOGCC regs. Test witnessed by WSL. 02:30 - 05:30 3.00 CASE P INT1 RU to run 9 5/8" csg. - Chg bails - PU / MU Franks tool dressed wI cup for 53.5# - PU elevators / slips - RU tongs 05:00 - 10:30 5.50 CASE P INT1 PJSM wI all personel. PU & RIH w/9 5/8", 53.5#, BTC, L 80 csg to 13 3/8" shoe @ 3,590 ft. Circ csg volume @ 9 BPM, 675 psi, PUW 230 k, SOW 200k. No losses. - Displacement showing well static 10:30 - 22:00 11.50 CASE P INT1 Con't PU & RIH w/9 5/8",53.5#, BTC, L 80 csg to 10,671 ft. Hole in good shape. - Displacement showing well static. 22:00 - 20:30 22.50 CASE P INT1 LD landing jt, RD Franks tool, PU Cmt head. 20:30 - 00:00 3.50 CASE P INT1 Break circ staging pumps up from 1 BPM to 9 BPM. 845 psi. PUW 540k, SOW 375k. No losses. 4/15/2005 00:00 - 01 :30 1.50 CASE P INT1 - Circ staging pumps up from 9 BPM to 11 BPM. 845 psi. PUW 540k, SOW 375k. No losses. 01 :30 - 05:00 3.50 CEMT P INT1 - Pump 10 bbls SIW & test lines to 4000 psi. pump 35 bbls CW -100 followed by 70 bbls 11.0 ppg Mud Push. Drop bottom plug & pump 370 bbls 11.3 ppg (645 sx) lead cement followed by 96 bbls 15.8 ppg (458 sx) Class G cement. Drop top plug & wash up on top of plug w/15 bbls SIW. Turn over to rig pump & displace cement wI 735 bbls mud @ 10-11 BPM. Bump plug wI 500 psi over @ 1300 psi & hold for 5 min. Bleed pressure & check floats. Floats holding. Good indication of lifting cement while displacing wI full returns. CIP @ 05:00 05:00 - 07:00 2.00 CASE P INT1 - R/U to pump down 133/8" x 95/8" annulus. Test kill line to 3000 psi. 07:00 - 09:00 2.00 WHSUR P INT1 - Pump 220 bbls 10.5 ppg mud down 133/8" x 9 5/8" annulus. Max pressure 575 psi. 09:00 - 12:00 3.00 WHSUR P INT1 - P/U stack & install casing slips w/ 385K. Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 4/15/2005 12:00 - 16:00 4.00 WHSUR P INT1 - Cut hole in casing & drain. Make rough cut on casing. - N/D riser & clean out under table. - P/U stack & rack back. - Make final cut on casing. 16:00 - 17:00 1.00 WHSUR P INT1 - Install packoff. 17:00 - 19:30 2.50 WHSUR P INT1 - P/U stack & N/U. Test packoff to 5000 psi for 10 min. 19:30 - 21:30 2.00 WHSUR P INT1 - C/O top pipe rams to 41/2" x 7". - Clean & install riser. 21 :30 - 22:30 1.00 WHSUR P INT1 - Change bails & elevators. - Install iron roughneck track. - Set mouse hole. 22:30 - 23:30 1.00 WHSUR P INT1 - MIU test jt & set test plug. 23:30 - 00:00 0.50 WHSUR P INT1 - Test annular preventer to 250 psi /3500 psi for 5/5 min. · Test witnessed by AOGCC Rep John Crisp & WSL. 4/16/2005 00:00 - 04:30 4.50 WHSUR P INT1 - Test BOPE per AOGCC & BP regs. 4800 psi /250 psi. Test witnessed by AOGCC Rep John Crisp & WSL. No failures on BOP components but had two flange leaks 04:30 - 05:30 i during test. 1.00 WHSUR P INT1 - Pull test plug & install bowl protector. - R/D test equip't 05:30 - 07:30 2.00 CASE P INT1 - PJSM - P/U & M/U BHA #5. 07:30 - 09:00 1.50 CASE P INT1 · Shallow hole test rotary steerable & MWD. B/D lines. C/O bit used to shallow hole test. 09:00 . 10:00 1.00 CASE P INT1 - Continue M/U BHA # 5. 10:00 - 14:00 4.00 CASE P INT1 - RIH w/5" DP to 10,461' filling pipe every 30 stands. - Freeze protect OA w/130 bbls diesel. 14:00 - 15:00 1.00 CASE P INT1 - Circulate MW in = MW out @ 10.7 ppg. - R/U to test casing. 15:00 - 16:30 1.50 CASE P INT1 - Pressure test 9 5/8" casing to 4560 psi w/10.7 ppg mud. Chart & hold for 30 min. 16:30 - 17:30 1.00 CASE P INT1 - B/D TD, kill line, & pumps. - Remove air slips. 17:30 - 19:00 1.50 CASE P INT1 - Slip & cut drilling line. 19:00 - 20:00 1.00 CASE P INT1 - Lubricate & service TD, drawworks, & crown. 20:00 - 21 :30 1.50 DRILL P INT1 · Wash down & tag plugs on depth @ 10,580'. - Drill cement from 10,580' to 10,650' @ 80 RPM, 350 GPM, 1300 psi. (lower flow rates to refrain from opening up Rhino Reamer) 21 :30 - 00:00 2.50 DRILL P INT1 - Displace to 12.5 ppg drilling fluid @ 350 GPM. - Troubleshoot & attempt to repair RPM sensor on TD. 4/17/2005 00:00 - 01 :00 1.00 DRILL P INT1 - Empty L pits & trip tanks. 01 :00 - 02:00 1.00 DRILL P INT1 - Drill remaining 15' of shoe track. 02:00 - 07:30 5.50 DRILL P LNR1 - Clean out rat hole & drill new hole to 10695'. - Pumped three nut plug sweeps for potential bit balling. 07:30 - 08:00 0.50 DRILL P LNR1 - Circulate in preparation for FIT. 08:00 - 08:30 0.50 DRILL P LNR1 - Perform FIT to 14.5 ppg EMW wI 12.5 ppg to 965 psi. Held pressure for 10 min - FP 950 psi. 08:30 - 12:30 4.00 DRILL P LNR1 - Drill 8 1/2" hole 10,714'. · Increase pump rate & open up Rhino Reamer. Check same. - Drill 9 1/2" to 10,751'. 12:30 - 14:00 1.50 DRILL N RREP LNR1 - Change out pop off valve on mud pump. 14:00 - 23:00 9.00 DRILL P LNR1 - Drill ahead in 91/2" hole from 10,751' to 11,014'. - Drilling parameters: WOB 20-30K, 600 GPM, 3700 psi, 140 Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 4/17/2005 14:00 - 23:00 9.00 DRILL P LNR1 RPM, Tq on bottom 21K, Tq off bottom 17K, P/U wt 285K, S/O wt 220K, Rot wt 250K. ADT 10.33 hrs. 23:00 - 23:30 0.50 DRILL N DFAL LNR1 - Lost 300 psi pump pressure. Check pumps & test surface equip't for leaks. 23:30 - 00:00 0.50 DRILL N DFAL LNR1 - POH checking for wash out. 4/18/2005 00:00 - 01 :00 1.00 DRILL N DFAL LNR1 - Continue POH looking for wash out. Locate wash out on stand 10 - 1 1/2' above tool jt on pin end. 01 :00 - 01 :30 0.50 DRILL N DFAL LNR1 - RIH to 11,014' 01 :30 - 02:30 1.00 DRILL P LNR1 - Drill 9 1/2" hole to 11033'. 02:30 - 03:00 0.50 DRILL N SFAL LNR1 - Switch out pop off valves on #1 & #2 mud pumps. 03:00 - 05:30 2.50 DRILL P LNR1 - Drill 9 1/2" hole from 11033' to 11077'. - Experiencing intermittent problems blowing pop off pins on #1 mud pump. Suspect bad batch of pins. 05:30 - 18:00 12.50 DRILL P LNR1 - DriIl91/2" hole from 11077' to 11537'. - Drilling parameters: WOB 25K, 565 - 600 GPM, 3800 psi, 140 GPM, Tq on bottom 21K, Tq off bottom 17K, PIU wt 280K, SIO wt 225K, Rot wt 250K. 18:00 - 19:00 1.00 DRILL P LNR1 - Clean suction screens on both mud pumps. 19:00 - 00:00 5.00 DRILL P LNR1 - Drill 9 1/2" hole to 11701 '. - Drilling parameters: WOB 25 -30K, 580 GPM, 3675 psi, 140 RPM, Tq on bottom 21.5K, Tq off bottom 17K, P/U wt 285K, S/O wt 230K, Rot wt 250K. - ART last 24 hrs = 18.4 hrs 4/19/2005 00:00 - 12:00 12.00 DRILL P LNR1 - Drill directional in 9 1/2" hole from 11701' to 12,103'. 12:00 - 20:00 8.00 DRILL P LNR1 - Drill directional in 91/2" hole from 12,103' to 12,327'. Pumped sweep prior to entering Sag formation. Sweep out of hole prior to swivel packing failure. Cuttings at shakers appear MW is correct. - Drilling parameters: WOB 25K, 580 GPM, 3650 psi, 150 RPM, Tq on bottom 23K, Tq off bottom 18K, PIU wt 295K, SIO wt 235K, Rot wt 255K. 20:00 - 22:30 2.50 DRILL N RREP LNR1 - Replace swivel packing. - Circulated through headpin @ 6.5 BPM 1285 psi while replacing packing, moving pipe 30' periodically. 22:30 - 00:00 1.50 DRILL P LNR1 - Drill 9 1/2" hole from 12,327' to 12,360'. - ADT last 24 hrs = 17.5 hrs. 4/20/2005 00:00 - 01 :00 1.00 DRILL P LNR1 - Drill directional in 91/2" hole to TD @ 12,381'. 01 :00 - 02:30 1.50 DRILL P LNR1 - CBU x 1.5 @ 580 GPM, 3600 psi, 140 RPM & reciprocating. 02:30 - 04:00 1.50 DRILL P LNR1 - POH to 9 5/8" shoe. Wipe tight spots once @ 12201' (45K drag) & 12109' (50K drag) Remaining trip to shoe indicates hole in good shape for running liner. 04:00 - 05:00 1.00 DRILL P LNR1 - RIH to TD - hole slick. 05:00 - 08:00 3.00 DRILL P LNR1 - Pump hi-vis sweep & circulate surface to surface + B/U x 2. 580 GPM, 3600 psi, 140 RPM & reciprocating. - Monitor well. 08:00 - 13:30 5.50 DRILL P LNR1 - POH to 9 5/8" shoe - hole in good shape. - Monitor well - pump dry job - drop rabbit - BID lines. - POH to HWDP. 13:30 - 14:30 1.00 DRILL P LNR1 - UD 23 jts HWDP 1 x 1. 14:30 - 16:00 1.50 I DRILL P LNR1 - UD BHA & clear floor. 16:00 - 17:00 1.00' DRILL N RREP LNR1 - Replace leaking blind ram accumulator hose on stack. Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/1 0/2005 4/20/2005 17:00 - 20:00 3.00 DRILL N RREP LNR1 - Clean cellar area of hydraulic fluid. 20:00 - 20:30 0.50 CASE P LNR1 - RJU to run 7" liner 20:30 - 00:00 3.50 CASE P LNR1 - Ran 35 out of 45 jts 7" 29# L-BO Hydril 511 liner. Used Jet Lube Seal Guard thread compound w/ M/U Tq 15K. - Bakerlok pin ends through jt #3. Filled shoe track & checked floats. 4/21/2005 00:00 - 01 :00 1.00 CASE P LNR1 - Run 10 jts 7" 29# L-BO Hydril 511 liner. M/U Tq 15K. Ran a total of 45 jts. 01 :00 - 02:00 1.00 CASE P LNR1 - C/O to 5" handling equip't. - MIU 9 5/B" x 7" HRD liner hanger I ZXP packer 02:00 - 02:30 0.50 CASE P LNR1 - M/U stand 5" DP & circulate string volume @ 6.5 BPM, 400 psi. - P/U wt 115K, SIO wt 11 OK. 02:30 - 09:00 6.50 CASE P LNR1 - Run 7" liner on 5" DP filling every row. 09:00 - 10:00 1.00 CASE P LNR1 - Circulate string & liner volume @ 6.5 BPM, 900 psi. P/U wt 270K, S/O wt 220K, Rot wt 245K @ 15 RPM, Tq BK 10:00 - 11 :30 1.50 CASE P LNR1 - Continue running 7" liner into OH to 12,349'. 11 :30 - 12:00 0.50 CASE P LNR1 - P/U & M/U cement head & RIH to 12,365'. 12:00 - 17:00 5.00 CASE P LNR1 - Stage up pump from 1 BPM to 6 BPM in preparation for cement job. - No losses - ICP @ 1 BPM 170 psi, FCP @ 6 BPM BBO psi. 17:00 - 19:30 2.50 CEMT P LNR1 - PJSM for cement job. - Pump 5 bbls S/W & test lines to 4500 psi. Pump 55 bbls 13.5 ppg Mud Push followed by 119 bbls 15.B ppg Class G cement (439 sx). Wash up on top of plug wi 10 bbls S/W & drop wiper dart. Displace w/ rig pump @ 6.5 BPM. Slow down to 3 BPM prior to latch & resume displacement @ 6.5 BPM after seeing latch. Bump plug w/242.6 bbls mud @ 97% pump efficiency & increase pressure to 4200 psi to set hanger. - Good indication of cement lift throughout displacement w/ no losses. CIP @ 19:20 19:30 - 20:00 0.50 CASE P LNR1 - S/O 90K to ensure hanger set & bleed off pressure. Check floats - floats holding. - PIU 10' to release packer setting dogs. S/O BOK to set packer - good indication packer set. SIO BOK wi rotation to ensure packer set. Apply 1000 psi pressure & pick up on string & unsting packoff. Increase pump rate after setting tool clear. 20:00 - 21 :00 1.00 CASE P LNR1 - CBU @ 14.5 BPM 3375 psi. Approximately 40 bbls cement back to surface. 21 :00 - 22:00 1.00 CASE P LNR1 - UD 2 singles & RID cementing head. - POH w/5 stands DP. 22:00 - 22:30 0.50 CASE P LNR1 - Service TD & C/O hydraulic compensating cylinder. 22:30 - 23:00 0.50 CASE P LNR1 - Pump dry job - BID TD - B/O 10' DP pup jt off of cement head. 23:00 - 00:00 1.00 CASE P LNR1 - POH wI 5" DP. 4/22/2005 00:00 - 03:00 3.00 CASE P LNR1 - POH w/5" DP. 03:00 - 03:30 0.50 CASE P LNR1 - B/O Baker setting tool. - Dog sub sheared. 03:30 - 04:00 0.50 BOPSU P LNR1 - Pull bowl protector. 04:00 - 05:30 1.50 BOPSU P LNR1 - RU 4" test equipment. 05:30 - 07:00 1.50 BOPSU P LNR1 - Test annular preventer to 250 psi /3500 psi & hold 5 min each test w/ 4" test jt. - Test lower pipe rams, dart sub, & TIW valve to 250 psi /4BOO Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 psi & hold for 5 min each test wI 4" test jt. Test witnessed by WSL & waived by AOGCC Rep Jim Spaulding. No failures. 07:00 - 07:30 LNR1 - Pull test plug & install bowl protector. 07:30 - 08:30 LNR1 - C/O 4" equip't to 5" equip't. 08:30 - 11 :00 LNR1 - Bring tools to rig floor & R/U Schlumberger E-line. 11 :00 - 16:00 LNR1 - Run US IT I PDC logs. - USIT log confirmed sufficient length of bond in place to meet state requirements. 16:00 - 17:00 1.00 EVAL P LNR1 - RID Schlumberger. 17:00 - 18:00 1.00 CASE P LNR1 - Test 7" x 9 5/8" casing to 3600 psi wI 12.5 ppg mud. Chart & hold test for 30 min. 18:00 - 18:30 0.50 CASE P LNR1 - BID kill line & mud line. - Service TD. 18:30 - 21 :00 2.50 CASE P LNR1 - PIU 6" drilling assy - 6" MX-18HDX, 1.5 deg bend motor wI AIM, NM stab, MWD, NMXO, 3 NM flex collars, pump out sub, XO, jars, & 1 jt 4" DP. - Shallow hole test MWD. 21 :00 - 23:30 2.50 CASE P LNR1 - P/U 119 jts 4" DP from pipeshed & RIH 1 x 1. 23:30 - 00:00 0.50 CASE P LNR1 - CIO to 5" handling equip't. - M/U XO & dart sub. 4/23/2005 00:00 - 03:30 3.50 CASE P LNR1 - RIH wI 6" drilling assy on 5" DP to 10,106' filling every 30 stands. 03:30 - 05:30 2.00 CASE P LNR1 - Slip & cut drilling line. 05:30 - 06:00 0.50 CASE P LNR1 - RIH wI 5" DP. 06:00 - 09:00 3.00 EVAL P LNR1 - Madd pass @ 150 FPH from 11290' to 11,560' 09:00 - 09:30 0.50 CASE P LNR1 - Continue RIH & wash down last stand & tag UC @ 12,285'. 09:30 - 14:30 5.00 DRILL P LNR1 - Drill landing collar, firm cement in shoe track, & float collar. 14:30 - 17:00 2.50 DRILL P LNR1 - Displace 12.5 ppg old mud wI new 9.1 ppg flo-pro mud system. - Pumped 100 bbls S/W followed by 100 bbl hi-vis sweep spacer prior to pumping new mud. 17:00 - 19:00 2.00 DRILL P LNR1 - Drill remaining cement in shoe track, tag reamer shoe @ 12385' & drill out. 19:00 - 20:30 1.50 DRILL P LNR1 - Drill 20' new hole from 12,381' to 12401 '. Rotate from 12,381' to 12,390' & slide from 12,390' to 12,401'. 20:30 - 21 :00 0.50 DRILL P LNR1 - Perform FIT to 11.5 ppg EMW wI 9.1 ppg mud. 1340 psi. - Held pre-reservoir meeting & reviewed D1, D2, & D5 roles & responsibilities. 21 :00 - 00:00 3.00 DRILL P PROD1 - Drill directional in 6" hole from 12,401' to 12,460'. (100 % slide) - Drilling parameters: WOB 20K, 270 GPM, 1550 psi on bottom, 1450 psi off bottom, P/U wt 275K, S/O wt 235K, ART .24 hrs, AST 2.26 hrs, ADT 2.50 hrs. 4/24/2005 00:00 - 12:00 12.00 DRILL P PROD1 - Drill directional in 6" hole from 12,460' to 12,635'. (100 % slide) - Drilling parameters: WOB 20K, 280 GPM, 1650 psi on bottom, 1550 psi off bottom, P/U wt 280K, SIO wt 235K. - AST 9.58 hrs, ADT 9.58 hrs. 12:00 - 12:30 0.50 DRILL P PROD1 - Circulate in 9.3 ppg MW for trip margin. 12:30 - 13:00 0.50 DRILL P PROD1 - Monitor well - pump out 3 stands to 7" shoe. 13:00 - 14:00 1.00 DRILL P PROD1 - Drop dart & open circ sub - circ until 9.3 ppg around 500 GPM, 1450 psi. Printed: 5/16/2005 11:56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 4/24/2005 14:00 - 15:30 1.50 DRILL P PROD1 - PJSM - Raise & shim substructure for more clearance over flow lines. 15:30 - 16:00 0.50 DRILL P PROD1 - Pump dry job - BID lines. 16:00 - 17:30 1.50 DRILL P PROD1 - POH to 7885'. 17:30 - 18:30 1.00 DRILL P PROD1 - Flow check - monitor well - OK. 18:30 - 21 :00 2.50 DRILL P PROD1 - POH to BHA. 21 :00 - 23:00 2.00 DRILL P PROD1 - Rack back collars, C/O circ sub, B/O bit. - M/U new bit, dial in motor to 1.83 deg bend & orient. 23:00 - 23:30 0.50 DRILL P PROD1 - Down load MWD. 23:30 - 00:00 0.50 DRILL P PROD1 - UD collar & C/O MWD. Wear band on MWD protecting electronics loose. 4/25/2005 00:00 - 01 :30 1.50 DRILL P PROD1 - M/U BHA # 7 & RIH. 6" Hughes STX30CDX, 1.83 deg bend mud motor wI AIM, NM stab, MWD, NMXO, 3 NM flex collars, circ sub, XO & jars. - Shallow hole test MWD & BID. 01 :30 - 02:30 1.00 DRILL P PROD1 - Service TO, drawworks, & crown. 02:30 - 04:30 2.00 DRILL P PROD1 - RIH wI 4" DP. - C/O to 5" handling equip't & fill pipe. 04:30 - 08:30 4.00 DRILL P PROD1 - RIH w/5" DP filling every 30 stands. 08:30 - 09:30 1.00 DRILL P PROD1 - Circulate to condition mud. 09:30 - 12:30 3.00 DRILL P PROD1 - Drill directional in 6" hole from 12,635' to 12,715'. (100% slide) - Drilling parameters: WOB 20K, 275 GPM, 1650 psi on bottom, 1550 psi off bottom, PIU wt 280K, S/O wt 240K. AST 2.36 hrs, ADT 2.36 hrs. 12:30 - 13:30 1.00 DRILL P PROD1 - Circulate OH volume x 4 & pump out to 7" shoe. 13:30 - 15:30 2.00 DRILL P PROD1 - Drop dart & open circ sub - circulate around until consistent 9.3 ppg in & out. 15:30 - 16:00 0.50 DRILL P PROD1 - Monitor well - mix dry job. 16:00 - 16:30 0.50 DRILL P PROD1 - Pump dry job & BID TO. 16:30 - 19:30 3.00 DRILL P PROD1 - POH w/5" DP to 6,000'. 19:30 - 20:30 1.00 DRILL N RREP PROD1 - Replace "0" ring in iron roughneck. 20:30 - 22:00 1.50 DRILL P PROD1 - POH to BHA. 22:00 - 23:00 1.00 DRILL P PROD1 - Rack back collars & jars, C/O circ sub, B/O bit, & UD mud motor. - 6" STX30CDX grade - 3-1-WT-A-E-I-BT-BHA. 23:00 - 23:30 0.50 DRILL P PROD1 - P/U new motor & set to 2.12 deg bend, M/U new 6" Hughes MX18HDX bit & orient. 23:30 - 00:00 0.50 DRILL P PROD1 - Down load MWD. 4/26/2005 00:00 - 01 :00 1.00 DRILL P PROD1 - M/U BHA #8- 6" Hughes MX18HDX, 2.12 deg bend mud motor w/ AIM -Shallow Hole Test, C/O Elevators tl4", BID Mud Lines 01 :00 - 03:00 2.00 DRILL P PROD1 - RIH w/4" DP & Fill Pipe. 03:00 - 07:00 4.00 DRILL P PROD1 -C/O Elevators tiS" & RIH wI 5" DP tl12,375' -Fill Pipe @ 30 Stand Intervals 07:00 - 07:30 0.50 DRILL P PROD1 -Break Circulation & Check Survey 07:30 - 08:00 0.50 DRILL P PROD1 -RIH tl12,575' -Wash f/12,575' tl12,715' 08:00 - 08:30 0.50 DRILL P PROD1 -Directional Drill f/ 12,715' tl12,721' (100% Sliding) -Lost Returns @ 12,721' 08:30 - 11 :30 3.00 DRILL N DPRB PROD1 -Fill Backside w/ Hole Fill Pump (Loss Rate 320 bph) -Mix & Pump LCM Pill, POH tl12,575', Monitor Loss Rate (24 Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 4/26/2005 08:30 - 11 :30 3.00 DRILL N DPRB PROD1 bph) 11 :30 - 12:00 0.50 DRILL N DPRB PROD1 -POH t/ 7" Shoe @ 12,365' 12:00 - 14:00 2.00 DRILL N DPRB PROD1 -Monitor Well & Fill Backside wI Hole Fill Pump (Loss Rate 24 bph) 14:00 - 18:30 4.50 DRILL N DPRB PROD1 -Circulate 9.0 ppg Mud Down String @ 3/4 bpm, 340 psi wI 50% Returns -Stage Pumps Up t/ 5.5 bpm, 950 psi wI 50% Returns 18:30 - 19:00 0.50 DRILL N DPRB PROD1 -RIHt/Bottom @ 12,721' -Fluid Level in Well Static wI RIH 19:00 - 00:00 5.00 DRILL P PROD1 -Directional Drill 6" Hole fl 12,721' t/ 12,860' wI 90%-95% Returns -Total Losses fl Event 715 BBL 4/27/2005 00:00 - 22:00 22.00 DRILL P PROD1 -Directional Drill 6" Hole f/12,860 t/ 13,409' -AST=12.13 Hrs. I ART=5.27 Hrs. -Bit Pulled Due t/ Symptoms of Being Undergauge 22:00 - 00:00 2.00 DRILL P PROD1 -Pump Out t/ 7" Shoe -24 Hour Total Losses=700 bbl 4/28/2005 00:00 - 01 :30 I 1.50 DRILL P PROD1 -Drop Circ Sub Opening Dart & Open Circ Sub -Spot LCM Pill. 01 :30 - 03:00 1.50 DRILL P PROD1 -POH to 10,395'. 03:00 - 03:30 0.50 DRILL P PROD1 -Circulate & Condition Mud t/ 9.1 ppg fl Trip Margin -At 1653 stks Pumped, Flow Increased & Gas Alarm Went Off 03:30 - 04:30 1.00 DRILL N DPRB PROD1 -Shut In Well & Monitor Pressure -Initial SICP: 180 psi--increased to 350 psi. Initial SIDPP: 0 psi--increased to 40 psi. -Made Notifications t/ Island Control Rm; Anchorage Team; AOGCC ( Chuck Scheve ); & Island Manager ( Gary Herring) 04:30 - 08:30 4.00 DRILL N DPRB PROD1 -Circulate Out Influx Using Driller's Method -Pumped -45 bbls Before Returns Were Established, Appeared t/ Be Gas Very Close t/ Surface, -Continue Circulating 9.1 ppg SIS @ 40 spm wI 400 psi fl 9570 stks (810 bbl) 08:30 - 09:00 0.50 DRILL N DPRB PROD1 -Shut Down Pumps & Open BOPE -Monitor Well fl Flow 09:00 - 10:00 1.00 DRILL N DPRB PROD1 -Pump BU @ 10,238' (Circulating Sub Depth) -Pump @ 10.5 bpm-Max Gas=2135 Units 10:00 - 11 :00 1.00 DRILL N DPRB PROD1 -RIH fl 10,395 t/ 12,375' 11 :00 - 13:00 2.00 DRILL N DPRB PROD1 -Pump BU @ 12,218' (Circulating Sub Depth) @ 7 bpm 13:00 - 13:30 0.50 DRILL N DPRB PROD1 -Load DP wI LCM Pill 13:30 - 16:00 2.50 DRILL N DPRB PROD1 -POH t/ 10,400'-7" Liner Top @ 10696' -Displacing DP wI LCM Pill @ 30 stkslstand wI POH 16:00 - 18:00 2.00 DRILL N DPRB PROD1 -Circulate Well t/ 9.2 ppg Mud SIS wI No Losses -Monitor Well Static 18:00 - 19:30 1.50 DRILL P PROD1 -MU Storm Packer & Set @ 62', Test t/ 1000 psi -Bit Depth 10,464' 19:30 - 20:00 0.50 BOPSU PROD1 -Blow Down Top Drive & Mud Lines -Drain Stack & Pull Wear Bushing 20:00 - 20:30 0.50 BOPSU PROD1 -MU Test Joint & Set Test Plug -Fill Stack wI H2O 20:30 - 00:00 3.50 BOPSU PROD1 -Test BOPE As Per BP Policy & AOGCC Regulations -AOGCC Witness Waived by Chuck Scheve -Test Witnessed by WSL Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 -Test Performed wI 5, 4.5 & 4 Inch Test Joints tJ Cover All Upcoming Operations 4/29/2005 00:00 - 06:00 PROD1 -Test BOPE As Per BP Policy & AOGCC Regulations (No Failures) -AOGCC Witness Waived by Chuck Scheve -Test Witnessed by WSL -Test Performed wI 5, 4.5 & 4 Inch Test Joints tJ Cover All Upcoming Operations 06:00 - 08:00 2.00 BOPSU PROD1 -Change Out Top Drive Gripper Dies 08:00 - 09:00 1.00 BOPSU PROD1 -RD 4" & 5" Test Joints & Install Wear Bushing 09:00 - 09:30 0.50 BOPSU PROD1 -RD 4" Floor Valves, Break XO on 4" Test Joint 09:30 - 11 :30 2.00 BOPSU PROD1 -MU Storm Packer Running Tool, RIH tJ Storm Packer @ 62' & Screw In Running Tool -Close Annular Preventer & Unseat Packer, Well Took - 10 bbl Mud -Pull Packer tJ Surface, LD Packer, Valve & Running Tool 11 :30 - 12:00 0.50 BOPSU PROD1 -Blow Down Choke & Kill Lines 12:00 - 14:30 2.50 DRILL PROD1 -Circulate & Condition Mud i 14:30 - 15:00 -Minor Gas Show @ BU 0.50 DRILL P PROD1 -Monitor Well & Pump Slug 15:00 - 20:00 5.00 DRILL P PROD1 -POH wI DP tJ BHA #8 20:00 - 21 :30 1.50 DRILL P PROD1 -LD BHA #8 21 :30 - 00:00 2.50 DRILL P PROD1 -PU BHA # 8 -CO Motor & PU ADN-PWD 4/30/2005 00:00 - 01 :30 1.50 DRILL P PROD1 -Mu & RIH wI BHA #9 -Load Source fl ADN 01 :30 - 02:00 0.50 DRILL P PROD1 -Surface Test MWD -Blow Down Mud Lines 02:00 - 07:00 5.00 DRILL P PROD1 -RIH wI BHA #9 on DP tJ TOL @ 10,514' 07:00 - 08:30 1.50 DRILL P PROD1 -Cut & Slip Drill Line (114') 08:30 - 09:00 0.50 DRILL P PROD1 -Service Drawworks, Top Drive & Blocks -Inspect Brakes 09:00 - 10:00 1.00 DRILL P PROD1 -RIH wI DP tJ 12,385' 10:00 - 12:30 2.50 DRILL P PROD1 -CBU @ Shoe -Staged Pumps Up Slow tJ 250 gpm 12:30 - 13:00 0.50 DRILL P PROD1 -RIH wI DP tJ 12,950' 13:00 - 14:30 1.50 PROD1 -Wash f/12,950' tJ 13,250' 14:30 - 16:00 1.50 DRILL P PROD1 -Ream f/ 13,250' tJ 13,409' -1600 psi @ 250 9pm, 40 RPM -1950 Units I Gas @ BU 16:00 - 00:00 8.00 DRILL P PROD1 -Drill fl 13,409' tJ 13,633', AST =1.87 Hrs. I ART =3.35 -PU Wt=295K I SO Wt=230K I 260K -Pump @ 250 gpm=1650 psi I Torque 10K @ 50 rpm -ECD As Calculated 5/1/2005 00:00 - 01 :00 1.00 DRILL P PROD1 -Directional Drill 6" Hole fl 13,633' tJ 13,658' 01 :00 - 02:00 1.00 DRILL N RREP PROD1 -Work On Top Drive -Yoke fl Lifting Pipe Handler Unscrewed fl Hydraulic Cylinder Shaft 02:00 - 16:00 14.00 DRILL P PROD1 -Directional Drill 6" Hole fl 13,658' tJ 14,150 -PU Wt=290K I SO Wt=230K I Rot Wt=260K I WOB=20K -Pump Pressure=1650 psi @ 250 gpm I ECD as Calculated -Rotary Torque=10K-12K @ 50 rpm lAST =1.27 hrs. I ART =8.75 Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 5/1/2005 16:00 - 17:00 1.00 DRILL P PROD1 -Circulate & Condition Mud -Pumped 4 OH Volumes 17:00 - 00:00 7.00 DRILL P PROD1 -Open Hole MAD Pass @ 330 ftIhr -Losses 5 bbl/hr 5/2/2005 00:00 - 01 :30 1.50 DRILL P PROD1 -Open Hole MAD Pass @ 330 ftIhr 01 :30 - 03:00 1.50 DRILL P PROD1 -CBU @ 7" Shoe @ 10 bpm (6500 stks) -Dressed Mud t/ 9.2 I Minimal Losses 03:00 - 05:00 2.00 DRILL N RREP PROD1 -Change Out Saver Sub -Replace Flow Divider Valve f/ Backup Wrench 05:00 - 07:30 2.50 DRILL P PROD1 -Pump Out of 7" Liner t/ Eliminate Possible Swabbing 07:30 - 09:00 1.50 DRILL P PROD1 -Flow Check Well fl TOH -Pump Slug, Dropped 2 1/2" Drift, Blow Down Lines 09:00 - 12:00 3.00 DRILL P PROD1 -POH w/ 5" DP 12:00 - 13:30 1.50 DRILL P PROD1 -POH w/4" DP 13:30 - 15:30 2.00 DRILL P PROD1 -UD B:HA #9 -Nuclear Source Removed f/ BHA 15:30 - 16:00 0.50 DRILL P PROD1 -Clean & Clear Rig Floor 16:00 - 18:00 2.00 CASE P PROD1 -Rig Up t/ Run 4.5 Vam Top Liner wlTorque Turn 18:00 - 21 :30 3.50 CASE P PROD1 -RIH w/4.5" 12.6# Vam Top Liner 21 :30 - 22:30 1.00 CASE P PROD1 -MU 7' X 4.5" Liner Hanger / Packer Assembly 22:30 - 23:00 0.50 CASE P PROD1 -Circulate Liner Volume @ 6 bpm wI 230 psi 23:00 - 00:00 1.00 CASE P PROD1 -RIH wI Liner on 4" DP -Up Wt I Down Wt @ 2000'=90K 5/3/2005 00:00 - 06:30 6.50 CASE P PROD1 -RIH wI 4.5" 12.6# Vam Top Liner on 5" DP -Controlled Running Speed as per Perform Engineer Guidelines -30 sec/stand in 9 5/8, 60 sec/stand in 7" 06:30 - 07:00 0.50 CASE P PROD1 -Circulate String Volume @ 7" Shoe 07:00 - 08:30 1.50 CASE P PROD1 -RIH w/ Liner t/14, 135' (Hole in Excellent Condition) -Running Speed in OH=2 min/stand 08:30 - 10:00 1.50 CASE P PROD1 -Make Up Cement Head & Wash Up Line 10:00 - 11 :30 1.50 CASE P PROD1 -Wash t/ Bottom @ 14,150' -Staged Pumps Up @ 1/2 bbllntervals t/6 bbl/min 11 :30 - 12:00 0.50 CEMT P PROD1 -Pressure Test Lines w/ H20 t/4500 psi & Pump Cement Job as Follows -15 bbl of CW100, 30 bbl of 10.3 ppg Mud Push, 50 bbl of Class G Tail Cement @ 15.8 ppg -Opened Up Tee in Wash Up Line & Washed Up w/5 bbl H2O 12:00 - 13:00 1.00 CEMT P PROD1 -Displace Cement wI Rig Pump @ 6 bpm -Displaced wI 30 bbl High LSRV Perf Pill & 200 bbl 9.2 ppg 13:00 - 13:30 0.50 CASE P PROD1 - Set Liner Hanger & Release HRD Liner Running Tool -Mud Pump Popped Off @ 4000 psi-Switched t/ Cement Unit t/ Finish Hanger Setting Sequence -P/U t/ Activate Packer Setting Dogs & Set Packer wI 50K Slack Off 13:30 - 14:30 1.00 CASE P PROD1 -Unstung fl Running Tool Packoff & Circulated Excess Cement t/ Surface -While Unstinging fl Packoff Mud Line Was Shut In @ Standpipe, Standpipe wI Lined Up & Excess Cement Circulated fI Well +1-20 bbl 14:30 - 15:30 1.00 CASE P PROD1 -UD Cement Head & Cement Hoses 15:30 - 21 :30 6.00 CASE P PROD1 -POOH w/ HRD Running Tool on DP -Inspect Liner Running Tool (OK) Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 5/3/2005 21 :30 - 22:00 0.50 CASE P PROD1 -UD Liner Running Tool & Break Cement Head 22:00 - 23:00 1.00 CASE N HMAN PROD1 -Bring 3 7/8" Mill & XO,s fl BHA #1 O-Liner Cleanout V Rig Floor -Rig Up V Run 2 7/8 Fox Tubing 23:00 - 00:00 1.00 CASE N HMAN PROD1 -Make Up BHA # 10 5/4/2005 00:00 - 00:30 0.50 CASE N HMAN PROD1 -M/U BHA #10-3 7/8" Cleanout Assembly 00:30 - 05:00 4.50 CASE N HMAN PROD1 -P/U & RIH wi 60 Jts. of 2 7/8 Fox Tubing -Drifting Pipe Off Skate, Break Circulation Every 20 Joints 05:00 - 11 :00 6.00 CASE N HMAN PROD1 -RIH wi BHA # 10 on 4" & 5" DP V Landing Collar @ 14,065' -Filled DP Every 3,000' -No Signs of Cement @ TOL 11 :00 - 12:30 1.50 CASE N HMAN PROD1 -Break Circulation & Fill DP wI High LSRV Perf Pill -160 gpm Maximum Pump Rate 12:30 - 15:00 2.50 CASE N HMAN PROD1 -POH While Displacing Perf Pill fl Drill Pipe V TOL 15:00 - 16:00 1.00 CASE N HMAN PROD1 -Open Circ Sub & Clean Pits 16:00 - 19:30 3.50 CASE P PROD1 -Flush Well wI Sweeps (Caustic-Safe Surf W-Hi Vis) -Displace Sweeps wI 800 bbl Sea Water 19:30 - 20:00 0.50 CASE P PROD1 -Nègative Pressure Test on Liner Top wI Seawater 'Commenced Loading G&I Pits wi 800 bbl 9.3 Brine in Mud Pits 20:00 - 22:30 2.50 CASE P PROD1 -Load G&I Pits wI 800 bbl 9.3 Brine -Start Cleaning Rig Mud Tanks 22:30 - 00:00 1.50 CASE P PROD1 -Displace Well V 800 bbl Clean 9.3 Brine 5/5/2005 00:00 - 00:30 0.50 CASE P PROD1 -Displace Well wI 800 bbl 9.3 Brine -36 NTU @ Completion of Displacement 00:30 - 01 :00 0.50 CASE P PROD1 -Blow Down Mud Lines & Adjust Brakes 01 :00 - 06:00 5.00 CASE N HMAN PROD1 -POH wi BHA #10 on DP 06:00 - 06:30 0.50 CASE N HMAN PROD1 -R/U V Pull 2 7/8 Tubing 06:30 - 07:30 1.00 CASE N HMAN PROD1 -UD 24 Jts. 2718 Tubing 07:30 - 08:30 1.00 CASE N HMAN PROD1 -POH & Rack 12 Stds. 2718 Tubing in Derrick 08:30 - 10:00 1.50 CASE N HMAN PROD1 -UD BHA #10 10:00 - 10:30 0.50 CASE N HMAN PROD1 -Clean & Clear Rig Floor 10:30 - 11 :30 1.00 BOPSU P PROD1 -Pull Wear Bushing -Set Junk Catcher in Wellhead 11 :30 - 12:00 0.50 BOPSU P PROD1 -Function & Flush BOPE 12:00 - 13:00 1.00 BOPSU P PROD1 -RID Flushing Tool -Pull Junk Catcher & Install Wear Bushing 13:00 - 14:30 1.50 CASE P PROD1 -Pressure Test 9 5/8 X 7 X 4.5 Casing V 3700 psi/30 Minutes -Blow Down All Mud Lines 16:00 - 17:00 1.00 CASE P PROD1 -Cut & Slip Drill Line (110') 17:00 - 20:00 3.00 PERFO P OTHCMP -P/U 375' 2.88" 6SPF Sclumberger TCP Guns & Baker Disconnect -P/U Schlumberger Slim Pulse MWD & Baker Bumper Sub 20:00 - 22:00 2.00 PERFO P OTHCMP -RIH wI Perf Guns on 2 7/8 Tubing -Shallow Test MWD & Blow Down Lines 22:00 - 00:00 2.00 PERFO P OTHCMP -RIH wI Perf Guns on 4" & 5" DP -DP Filling Through Ported Sub 5/6/2005 00:00 - 04:30 4.50 PERFO P OTHCMP -RIH wI Sib TCP 2.88" 6 spf Perf Guns on DP V 13,065' -Filled Pipe @ 4112 Liner Top Due V Ported Sub Plugging (Notified SLB TCP Prior V Pumping) 04:30 - 06:00 1.50 PERFO P OTHCMP -Log wI Slim Pulse GR MWD -Tie In Depth wI Gamma Spike @ 12,580' 06:00 - 06:30 0.50 PERFO P OTHCMP -RIH V wi SLB TCP 2.88" 6 spf Per Guns on DP II 13,657' Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 -Spot Guns on Depth f/13,282' t/13,657' -Break Circulation & Initiate Shot Sequence -Perforate fl 13,282' t/13657' (375') 6 spf 08:00 - 09:00 1.00 OTHCMP -POH t/ -13,280' -Flow Check Well (6 bph Losses) & Blow Down Mud Lines 09:00 - 16:30 7.50 OTHCMP -Lay Down 5" Drill Pipe -Hole Fill Correct (6 bph losses) 16:30 - 19:30 OTHCMP -Lay Down 4" Drill Pipe -Flow Check Well (Well Static) 19:30 - 00:00 OTHCMP -Lay Down 2 7/8 Fox Tubing, MWD, Bumper Sub, Disconnect & Fired Guns -PJSM Held wI SLB TCP Prior t/ Handling Fired Guns (All Guns Fired) 5/7/2005 00:00 - 01 :00 1.00 OTHCMP -UD Perf Guns -Clean & Clear Rig Floor 01 :00 - 02:00 1.00 OTHCMP -RID Perf Gun Handling Tools (Power Tongs & Small Rig Tongs) -Clean & Clear Rig Floor -Island Power Outage Resulted in -1 Hr. Lost Time 02:00 - 04:00 2.00 OTHCMP -RIH wI 5" Drill Pipe fl Derrick (50 Stands) 04:00 - 08:00 OTHCMP -UD 5" Drill Pipe 08:00 - 08:30 OTHCMP -Pull Wear Bushing 08:30 - 10:00 RUNCMP -Bring Tubing Tongs & Tubing Handling Equipent t/ Rig Floor -Remove Short Bails & Install Long Bails 10:00 - 14:00 RUNCMP -R/U t/ Run 4 112" Tubing wI NAD Casing Torque Turn -R/U Weatherford Cidra Fiber Optic Cable Running Equipment 14:00 - 00:00 RUNCMP -RIH w/4 1/2" 12.6# Vam Top Completion String as per Drillers Running Tally t/ 4,453' -Well Taking 2-4 bph While Running Completion String in Hole 5/8/2005 00:00 - 12:30 RUNCMP -RIH w/4 1/2 12.6# Vam Top Completion as per Drillers Running Tally fl 4,500' t/11, 177' 12:30 - 13:30 RUNCMP -R/U Control Line fl SSSV -Test t/6,OOO psi/15 minutes 13:30 - 15:00 RUNCMP -RIH wI Completion f/11,177' t/12, 197' (Lost 55 bbl Brine During Tubing Run) -Spaced Out 6' Off Liner Top in Tie Back Sleeve (12,191' WLEG Depth) 15:00 - 15:30 RUNCMP -M/U Tuing Hanger & Landing Jt. -No Space Out Pups Required 15:30 - 17:00 1.50 RUNCMP -Terminate Fiber Optic Line & SSSV Control Line @ Hanger 17:00 - 17:30 0.50 RUNCMP -Land Hanger & Run In LDS - POW 195k, SOW 170k -Test Hanger Seals t/5000k & R/U t/ Reverse Circulate 17:30 - 22:00 RUNCMP -Reverse Circulate Corrosion Inhibited 9.3 Brine @ 3 bpm - Displace t/ GLM @ 3 bpm (Corrosion Inhibited Brine f/4,551' t/12,142') 22:00 - 00:00 2.00 WAIT RUNCMP -Mobilize XO Subs t/ RIU Shlumberger Slickline on Tubing t/ Run RHC Plug & Prong 5/9/2005 00:00 - 00:30 0.50 RUNCMP -Unload NC50 X 7" Otis XO & Schlumberger Packoff-Pump In Sub fl AIC Truck -Stage Tools t/ Rig Floor wI Pipe Shed Elevator (Rig VLE Blocked wI Fiber Optic Cable) Printed: 5/16/2005 11 :56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS28 NS28 DRILL+COMPLETE 01 :30 - 10:30 RUNCMP 10:30 - 11 :00 11 :00 - 12:00 12:00 - 13:30 RUNCMP RUNCMP RUNCMP 13:30 - 14:00 0.50 RUNCMP 14:00 - 16:00 2.00 RUNCMP 16:00 - 20:30 4.50 RUNCMP 20:30 - 21 :30 RUNCMP 21 :30 - 00:00 2.50 WHSUR P RUNCMP 5/10/2005 00:00 - 01 :30 1.50 WHSUR P RUNCMP 01 :30 - 03:30 2.00 WHSUR P RUNCMP 03:30 - 08:30 5.00 WHSUR P RUNCMP 08:30 - 12:00 3.50 RIGD P POST Start: 4/1/2005 Rig Release: 5/10/2005 Rig Number: Spud Date: 4/2/2005 End: 5/10/2005 -RU Schlumberger Packoff-Pump In Sub on 4 1/2" Landing Jt. wI NC50 X 7" Otis XO -Thread Slickline Through Packoff & MIU Rope Socket I Prep to Run PXN Plug Body -RIH wI PXN Plug Body on Slickline (100 fpm Running Speed) tI 'XN' Nipple @ 12,176' -Plug Set in Lower 'X' Nipple. -Shear Off plug, POH to PU Retrieving Tool -Retrieve Plug, Redress & RIH, Set in 'XN' Nipple, POH -RIH wI Prong & Set in Plug, POH -RD Slickline -RU tI Set Packer & Perform MIT -Pressure Up Tubing tI 4200 psi, Set Packer, Held Pressure fl 30 Minutes (OK) -Bleed Tubing tI 2700 psi, Pressure Annulus tI 4200 psi I 30 Minutes (OK) -RD Fiber Optic Line Cable & SSSV Control Line Sheaves fl Derrick -Install BPV -Clear Tubing Running Tools fl Rig Floor -ND BOPE -Pull All Rams & Plug All Hydraulic Fittings Prior tI Placing in Rack -Set BOPE in Rack -ND XO Spool -Terminate SSSV Control Line -Terminate Fiber Optic Cable -Terminate Fiber Optic Cable -N/U Tubing Head Adapter I Dry Hole Tree -RU tI Freeze Protect wI Little Red Hot Oil Service -Little Red test lines. Shear DCK valve @ 2700 psi. -Freeze Protect wI Little Red Hot Oil Service - 225 bbls inhibited diesel -U Tube well to balance point. -Set TWC. -Hot Oil unit test from below - 1000 psi OK. -Suck out all lines. -RD Hoil Oil unit -Close SSSV -Secure well. -Police cellar -Prep rig for move. -Release rig from NS 28 at 1200 hrs May 10, 2005 Printed: 5/16/2005 11 :56:59 AM . . NS28 Northstar Unit 50-029-23248-00-00 205-016 Accept: Spud: Release: Ri: 04/01/05 04/02/05 05/10/05 Nabors 33E POST-RIG WORK 05/15/05 PULLED DCR AND SET 1.5" DGLV @ 4524, PULLED EMPTY CATCHER AND PULLED PXN TTP. TURNED WELL OVER TO TENDER OS/24/05 SCALE INHIBITOR TREATMENT - PUMPED DOWN TUBING, 84.3 BBLS 60*F DIESEL/WAW-5206 PRE-FLUSH MIXED 7.5% BY VOLUME, 250 BBLS 125*F DIESEL SPACER, 119.1 BBLS 80*F SEAWATER/SCW-4004 SCALE INHIBITOR MIXED 11% BY VOLUME, 1224 BBLS TOTAL 100*F FILTERED SEAWATER OVERFLUSH/DISPLACEMENT & 61 BBLS 125*F DIESEL DISPLACEMENT. TURN WELL OVER TO PRODUCTION CONTROL FOR 12 HR SOAK. NS28 Survey Report Schlu berger ! Report Date: 2-May-05 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 295.590' Field: Northstar V~rtical Section Origin: N 0.000 fI, E 0.000 It Structure I Slot: Northstar PF / NS28 tvD Reference Datum: Rotary Table Well: NS28 TVD Reference Elevation: 55.67 fI relative to MSL Borehole: NS28 Sea Bed I Grpund Level Elevation: 15.67 fI relative to MSL UWVAPI#: 500292324800 Magnetic Declination: 24.908' Survey Name I Date: NS28/ May 2, 2005 ¡ T otª' Field Strength: 57647.470 nT Tort I AHD I DDII ERD ratio: 214.362' /7569.11 fI / 6.313 / 0.678 Magnetic Dip: 80.978' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 02, 2005 . Location Lat/Long: N 70.49148680, W 148.69332934 Magnetic Declination Model: BGGM 2004 Location Grid NIE Y/X: N 6031091.250 flUS, E 659823.570 flUS North Reference: True North Grid Convergence Angle: +1.23168102' Total Corr Mag North -> True North: +24.908' Grid Scale Factor: 0.99992902 Local Coord[nates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD NS EW DLS Northing Easting Latitude Longitude Depth It RTE 0.00 N 70.49148680 W 148.69332934 First GYD-CT-DMS 50.00 N 70.49148704 W 148.69332939 100.00 N 70.49148755 W 148.69332918 150.00 N 70.49148788 W 148.69332822 194.00 N 70.49148719 W 148.69332582 250.00 0.64 253.24 194.32 249.99 -0.50 1.40 0.51 -0.29 0.41 2.31 6031090.97 659823.99 N 70.49148600 W 148.69332598 300.00 0.86 286.51 244.32 299.99 0.08 2.04 0.34 -0.27 -0.22 0.96 6031090.98 659823.36 N 70.49148607 W 148.69333110 359.00 1.33 320.87 303.31 358.98 1.14 3.14 1.14 0.39 -1.07 1.33 6031091.62 659822.49 N 70.49148787 W 148.69333811 449.00 2.74 331.25 393.25 448.92 3.83 6.32 4.14 3.09 -2.77 1.61 6031094.28 659820.74 N 70.49149523 W 148.69335195 537.00 5.48 315.47 481.02 536.69 9.49 12.59 10.40 7.93 -6.73 3.34 6031099.03 659816.68 N 70.49150846 W 148.69338432 628.00 9.21 308.17 571.26 626.93 20.69 24.21 21.94 15.53 -15.50 4.22 6031106.44 659807.74 N 70.49152922 W 148.6.5 715.00 12.13 306.30 656.74 712.41 36.47 40.32 37.96 25.24 -28.34 3.38 6031115.88 659794.69 N 70.49155576 W 148.6 4 808.00 13.74 300.20 747.39 803.06 57.08 61.11 58.59 36.59 -45.77 2.27 6031126.84 659777.03 N 70.49158675 W 148.69370345 875.00 15.65 294.66 812.19 867.86 74.05 78.10 75.~1 44.36 -60.86 3.54 6031134.29 659761.78 N 70.49160798 W 148.69382682 950.00 16.65 292.77 884.23 939.90 94.90 98.96 95.79 52.74 -79.96 1.51 6031142.26 659742.50 N 70.49163088 W 148.69398296 Last GYD-CT-DMS 1028.00 18.69 295.16 958.55 1014.22 118.56 122.63 119.20 62.38 -101.58 2.78 6031151.43 659720.68 N 70.49165721 W 148.69415968 First MWD+IFR+MS 1122.56 18.98 299.73 1048.05 1103.72 149.05 153.14 ·'·1:49.65 76.45 -128.65 1.59 6031164.91 659693.32 N 70.49169564 W 148.69438094 1214.24 22.43 297.82 1133.80 1189.47 181.40 185.55 .'H~~.03 92.01 -157.07 3.83 6031179.85 659664.57 N 70.49173815 W 148.69461330 1308.60 23.40 296.63 1220.71 1276.38 218.13 222.29 41.8.73 108.81 -189.74 1.14 6031195.95 659631.55 N 70.49178404 W 148.69488038 1401.67 24.46 297.66 1305.78 1361.45 255.86 260.04 ~56.44 126.04 -223.33 1.22 6031212.45 659597.60 N 70.49183111 W 148.69515494 1495.45 28.35 298.13 1389.76 1445.43 297.52 301.73 298.12 145.56 -260.18 4.15 6031231.17 659560.34 N 70.49188443 W 148.69545615 1588.15 31.40 298.48 1470.13 1525.80 343.64 347.90 3:44.29 167.45 -300.82 3.30 6031252.19 659519.24 N 70.49194424 W 148.69578842 1681.54 32.00 296.53 1549.59 1605.26 392.68 396.97 393.34 190.11 -344.35 1.27 6031273.90 659475.24 N 70.49200613 W 148.69614422 SurveyEditor Ver Sld( doc40x_37 ) NS28\NS28\NS28\NS28 Generated 6/17/2005 1 :47 PM Page 1 of 6 Comments Latitude Longitude N 70.49206618 W 148.69652403 N 70.49212504 W 148.69691009 1966.81 33.47 295.36 1789.10 1844.77 547.63 551.94 548.04 255.58 -484.79 1.08 6031336.34 659333.43 N 70.49218497 W 148.6972923~ 2061.38 34.02 296.20 1867.73 1923.40 600.16 604.47 (¡00.54 278.43 -532.09 0.76 6031358.16 659285.65 N 70.49224739 W 148.69767901 2156.67 35.38 295.36 1946.07 2001.74 654.41 658.71 654.76 302.02 -580.94 1.51 6031380.69 659236.31 N 70.49231181 W 148.69807834 2251.51 35.61 295.26 2023.29 2078.96 709.47 713.78 709.79 325.56 -630.72 0.25 6031403.15 659186.04 N 70.49237611 W 148.69848530 2344.47 33.99 294.71 2099.62 2155.29 762.52 766.83 762.80 347.97 -678.81 1.78 6031424.53 659137.49 N 70.49243733 W 148.69887840 2438.98 35.04 294.56 2177.49 2233.16 816.06 820.38 816.30 370.29 -727.48 1.11 6031445.79 659088.35 N 70.49249829 W 148.69927633 2533.88 34.92 295.36 2255.25 2310.92 870.47 874.79 870.68 393.25 -776.81 0.50 6031467.68 659038.55 N 70.49256100 W 148.69967956 2628.31 34.04 295.19 2333.09 2388.76 923.92 928.25 924.12 416.08 -825.15 0.94 6031489.46 658989.73 N 70.49262334 W 148.70007475 2724.81 34.05 295.19 2413.05 2468.72 977.95 982.27 978.12 439.07 -874.04 0.01 6031511.40 658940.36 N 70.49268614 W 148.70_ 2818.04 34.14 294.79 2490.26 2545.93 1030.20 1034.53 1030.36 461.15 -921.40 0.26 6031532.45 658892.53 N 70.49274644 W 148.70 2912.62 33.96 295.11 2568.62 2624.29 1083.16 1087.49 1083.30 483.49 -969.42 0.27 6031553.75 658844.05 N 70.49280745 W 148.70125420 3007.31 32.05 294.57 2648.03 2703.70 1134.73 1139.07 1134.85 505.16 -1016.22 2.04 6031574.41 658796.80 N 70.49286664 W 148.70163682 3101.19 31.77 294.61 2727.72 2783.39 1184.35 1188.69 1184.45 525.81 -1061.34 0.30 6031594.09 658751.25 N 70.49292303 W 148.70200572 3195.01 33.13 295.29 2806.89 2862.56 1234.68 1239.03 1234.78 547.05 -1106.98 1.50 6031614.34 658705.17 N 70.49298103 W 148.70237884 3289.87 33.46 295.87 2886.18 2941.85 1286.75 1291.10 1286.84 569.53 -1153.95 0.48 6031635.81 658657.73 N 70.49304244 W 148.70276283 3382.71 31.94 296.06 2964.30 3019.97 1336.91 1341.26 1337.00 591.49 -1199.04 1.64 6031656.79 658612.18 N 70.49310240 W 148.70313149 3476.52 31.61 296.05 3044.05 3099.72 1386.30 1390.65 1386.40 613.19 -1243.42 0.35 6031677.52 658567.35 N 70.49316166 W 148.70349431 3541 .84 31.33 296.10 3099.76 3155.43 1420.40 1424.75 1420.50 628.18 -1274.05 0.43 6031691.85 658536.40 N 70.49320259 W 148.70374473 3691.73 30.81 296.70 3228.15 3283.82 1497.75 1502.11 1497.85 662.57 -1343.34 0.40 6031724.74 658466.40 N 70.49329651 W 148.70431122 3787.38 31.31 295.51 3310.09 3365.76 1547.10 1551.46 1547.20 684.28 -1387.65 0.83 6031745.49 658421.63 N 70.49335580 W 148.70467353 3882.87 32.22 294.95 3391.27 3446.94 1597.36 1601.73 1597.46 705.70 -1433.13 1.00 6031765.93 658375.71 N 70.49341430 W 148.70504532 3977.50 32.15 294.70 3471.36 3527.03 1647.76 1652.13 1647.85 726.86 -1478.88 0.16 6031786.11 658329.52 N 70.49347209 W 148.70541934 4071.42 31.93 295.32 3550.98 3606.65 1697.59 1701.96 1697.66 747.93 -1524.03 0.42 6031806.19 658283.93 N 70.49352961 W 148.70578851 4166.89 31.65 294.63 3632.12 3687.79 1747.88 1752.25 1747.95 769.16 -1569.62 0.48 6031826.44 658237.89 N 70.49358760 W 148.70616125 4262.11 31.40 294.52 3713.29 3768.96 1797.66 1802.04 1797.72 789.87 -1614.90 0.27 6031846.17 658192.19 N 70.49364414 W 148.70653144 4357.79 30.91 294.57 3795.17 3850.84 1847.15 1851.54 1847.20 810.43 -1659.93 0.51 6031865.76 658146.73 N 70.49370029 W 148.7.9 4452.02 31.04 294.05 3875.96 3931.63 1895.63 1900.04 1895.68 830.40 -1704.12 0.32 6031884.77 658102.12 N 70.49375480 W 148.7 4 4546.89 30.72 293.48 3957.38 4013.05 1944.30 1948.73 f944.33 850.02 -1748.68 0.46 6031903.43 658057.15 N 70.49380838 W 148.7 28 4641 .50 30.82 292.95 4038.68 4094.35 1992.66 1997.13 1992.68 869.10 -1793.17 0.31 6031921.54 658012.27 N 70.49386047 W 148.70798897 4736.55 31.09 291.88 4120.19 4175.86 2041.47 2046.02 2041 .48 887.74 -1838.36 0.64 6031939.21 657966.69 N 70.49391136 W 148.70835850 4831.27 31.15 291.78 4201.28 4256.95 2090.32 2094.97 2090.32 905.94 -1883.81 0.08 6031956.43 657920.87 N 70.49396106 W 148.70873005 4924.71 31.00 292.15 4281.31 4336.98 2138.45 2143.20 2138.45 923.98 -1928.53 0.26 6031973.50 657875.76 N 70.49401031 W 148.70909576 5019.09 30.69 292.78 4362.34 4418.01 2186.77 2191.59 2186.77 942.47 -1973.25 0.47 6031991.02 657830.66 N 70.49406079 W 148.70946139 5114.32 30.58 293.35 4444.28 4499.95 2235.25 2240.12 2235.25 961 .48 -2017.90 0.33 6032009.07 657785.62 N 70.49411269 W 148.70982643 5208.77 30.15 294.25 4525.77 4581 .44 2282.97 2287.86 2282.98 980.75 -2061.58 0.66 6032027.39 657741.53 N 70.49416529 W 148.71018362 5302.20 29.63 295.08 4606.77 4662.44 2329.52 2334.42 2329.53 1000.17 -2103.89 0.71 6032045.90 657698.82 N 70.49421833 W 148.71052958 5397.16 29.43 295.51 4689.40 4745.07 2376.33 2381.22 2376.34 1020.17 -2146.21 0.31 6032064.98 657656.08 N 70.49427293 W 148.71087558 5491.93 29.74 295.30 4771.81 4827.48 2423.11 2428.01 2423.13 1040.24 -2188.48 0.34 6032084.14 657613.40 N 70.49432773 W 148.71122116 5585.50 29.98 295.78 4852.96 4908.63 2469.70 2474.60 2469.71 1060.33 -2230.51 0.36 6032103.32 657570.95 N 70.49438257 W 148.71156485 SurveyEditor Ver Sld( doc40x_37 ) NS28\NS28\NS28\NS28 Generated 6/17/2005 1 :47 PM Page 2 of 6 Comments Latitude Longitude N 70.49443839 W 148.71191055 5773.28 30.66 295.58 5015.09 5070.76 2564.44 2569.34 2564.45 1101.50 -2315.84 0.43 6032142.64 657484.76 N 70.49449498 W 148.71226255 5869.39 30.98 296.33 5097.62 5153.29 2613.68 2618.58 2613.69 1123.06 -2360.11 0.52 6032163.24 657440.04 N 70.49455382 W 148.71262456 5963.81 31.28 296.21 5178.45 5234.12 2662.49 2667.39 2662.50 1144.66 -2403.88 0.32 6032183.90 657395.82 N 70.49461280 W 148.71298248 6057.98 31.31 294.87 5258.92 5314.59 2711.40 2716.31 2711.41 1165.75 -2448.02 0.74 6032204.03 657351.24 N 70.49467037 W 148.71334335 6151.10 31.66 294.62 5338.33 5394.00 2760.03 2764.94 2760.04 1186.11 -2492.18 0.40 6032223.43 657306.65 N 70.49472594 W 148.71370452 6245.56 32.13 293.41 5418.53 5474.20 2809.92 2814.85 2809.93 1206.41 -2537.77 0.84 6032242.75 657260.64 N 70.49478138 W 148.71407728 6340.10 32.24 293.08 5498.54 5554.21 2860.24 2865.21 2860.25 1226.29 -2584.04 0.22 6032261.62 657213.96 N 70.49483563 W 148.71445562 6434.43 32.18 292.94 5578.35 5634.02 2910.47 2915.49 2910.49 1245.94 -2630.32 0.10 6032280.28 657167.27 N 70.49488928 W 148.71483405 6529.21 31.78 293.04 5658.75 5714.42 2960.61 2965.69 2960.65 1265.55 -2676.53 0.43 6032298.88 657120.65 N 70.49494279 W 148.71521191 6622.91 31.51 292.69 5738.51 5794.18 3009.72 3014.85 3009.76 1284.65 -2721.83 0.35 6032317.01 657074.96 N 70.49499493 W 148.71.0 6716.73 31.36 292.91 5818.57 5874.24 3058.59 3063.78 3058.65 1303.61 -2766.94 0.20 6032334.99 657029.46 N 70.49504668 W 148.715 14 6811.68 31.07 292.84 5899.77 5955.44 3107.74 3112.98 3107.82 1322.74 -2812.27 0.31 6032353.14 656983.72 N 70.49509889 W 148.71632187 6905.50 30.60 292.54 5980.33 6036.00 3155.77 3161.07 3155.86 1341.29 -2856.64 0.53 6032370.73 656938.97 N 70.49514953 W 148.71668466 7000.13 30.48 293.03 6061.83 6117.50 3203.79 3209.16 3203.90 1359.91 -2900.97 0.29 6032388.40 656894.25 N 70.49520035 W 148.71704718 7094.35 30.23 293.93 6143.13 6198.80 3251.38 3256.77 3251.50 1378.88 -2944.64 0.55 6032406.42 656850.18 N 70.49525212 W 148.71740429 7189.04 30.35 293.90 6224.90 6280.57 3299.11 3304.53 3299.25 1398.24 -2988.30 0.13 6032424.84 656806.12 N 70.49530497 W 148.71776130 7284.26 30.86 293.74 6306.85 6362.52 3347.57 3353.01 3347.71 1417.82 -3032.65 0.54 6032443.46 656761.37 N 70.49535840 W 148.71812396 7379.00 31.48 293.71 6387.91 6443.58 3396.58 3402.04 3396.74 1437.55 -3077.54 0.65 6032462.21 656716.06 N 70.49541225 W 148.71849105 7474.69 31.68 293.98 6469.43 6525.10 3446.67 3452.16 3446.84 1457.81 -3123.38 0.26 6032481.48 656669.81 N 70.49546754 W 148.71886585 7568.91 31.27 293.92 6549.79 6605.46 3495.84 3501.35 3496.02 1477.78 -3168.34 0.44 6032500.48 656624.43 N 70.49552205 W 148.71923350 7663.08 30.96 293.88 6630.41 6686.08 3544.48 3550.01 3544.68 1497.49 -3212.83 0.33 6032519.23 656579.53 N 70.49557585 W 148.71959732 7756.91 30.70 293.94 6710.98 6766.65 3592.55 3598.10 3592.76 1516.98 -3256.79 0.28 6032537.77 656535.17 N 70.49562905 W 148.71995681 7851.03 30.30 294.51 6792.08 6847.75 3640.31 3645.87 3640.52 1536.58 -3300.35 0.52 6032556.43 656491.20 N 70.49568254 W 148.72031306 7946.03 30.12 293.82 6874.18 6929.85 3688.09 3693.67 3688.32 1556.15 -3343.96 0.41 6032575.05 656447.18 N 70.49573594 W 148.72066970 8040.44 29.78 293.02 6955.98 7011.65 3735.19 3740.80 3735.43 1574.89 -3387.21 0.56 6032592.85 656403.54 N 70.49578707 W 148.72102337 8135.80 29.44 292.80 7038.89 7094.56 3782.26 3787.92 3782.52 1593.23 -3430.61 0.37 6032610.26 656359.76 N 70.49583712 W 148.72137828 8231.55 29.11 292.12 7122.41 7178.08 3829.01 3834.74 3829.30 1611.12 -3473.88 0.49 6032627.21 656316.12 N 70.49588594 W 148.7.r 8327.37 28.80 292.04 7206.25 7261.92 3875.31 3881.13 3875.63 1628.55 -3516.87 0.33 6032643.72 656272.77 N 70.49593352 W 148.7 5 8422.39 28.82 292.45 7289.51 7345.18 3921.02 3926.92 3921:38 1645.89 -3559.25 0.21 6032660.14 656230.03 N 70.49598082 W 148.7 24 8517.40 28.76 293.02 7372.78 7428.45 3966.72 3972.68 3967.10 1663.57 -3601 .45 0.30 6032676.91 656187.46 N 70.49602908 W 148.72277535 8611.75 28.57 293.60 7455.56 7511.23 4011.94 4017.94 4012.35 1681.48 -3643.01 0.36 6032693.92 656145.52 N 70.49607794 W 148.72311526 8707.34 28.70 294.01 7539.46 7595.13 4057.73 4063.74 4058.15 1699.97 -3684.93 0.25 6032711.50 656103.23 N 70.49612840 W 148.72345801 8801.15 28.87 294.37 7621.68 7677.35 4102.89 4108.92 4103.32 1718.48 -3726.13 0.26 6032729.12 656061.64 N 70.49617891 W 148.72379499 8896.71 29.38 294.47 7705.16 7760.83 4149.39 4155.43 4149.83 1737.71 -3768.48 0.54 6032747.43 656018.89 N 70.49623138 W 148.72414133 8991.79 29.95 294.94 7787.77 7843.44 4196.44 4202.48 4196.89 1757.38 -3811.23 0.65 6032766.18 655975.73 N 70.49628506 W 148.72449094 9085.59 30.59 294.40 7868.79 7924.46 4243.72 4249.77 4244.17 1777.11 -3854.20 0.74 6032784.98 655932.35 N 70.49633890 W 148.72484233 9180.38 30.17 294.22 7950.56 8006.23 4291.64 4297.70 4292.10 1796.85 -3897.88 0.45 6032803.77 655888.25 N 70.49639276 W 148.72519962 9276.34 29.37 293.28 8033.86 8089.53 4339.26 4345.35 4339.74 1816.04 -3941.49 0.97 6032822.02 655844.24 N 70.49644513 W 148.72555625 9370.60 29.52 291.89 8115.94 8171.61 4385.53 4391.68 4386.04 1833.83 -3984.27 0.74 6032838.89 655801.09 N 70.49649367 W 148.72590612 9465.95 31.14 291.31 8198.24 8253.91 4433.56 4439.83 4434.12 1851.55 -4029.04 1.73 6032855.64 655755.96 N 70.49654201 W 148.72627225 SurveyEditor Ver Sld( doc40x_37 ) NS28\NS28\NS28\NS28 Generated 6/17/2005 1 :47 PM Page 3 of 6 Comments Latitude Longitude 9559.18 32.22 291.30 8277.57 8333.24 4482.39 4488.79 4483.00 1869.34 -4074.66 1.16 6032872.44 655709.97 N 70.49659054 W 148.72664529 9653.73 32.26 291.87 8357.55 8413.22 4532.70 4539.23 4533.37 1887.90 -4121.56 0.32 6032889.99 655662.69 N 70.49664116 W 148.72702886 9746.93 32.65 291.89 8436.19 8491.86 4582.61 4589.25 4583.32 1906.54 -4167.97 0.42 6032907.62 655615.89 N 70.49669201 W 148.72740843 9840.99 32.79 292.28 8515.33 8571.00 4633.36 4640.09 4634.12 1925.65 -4215.08 0.27 6032925.72 655568.38 N 70.49674416 W 148.72779372 9935.92 31.46 292.19 8595.72 8651.39 4683.75 4690.57 4684.56 1944.75 -4261.81 1.40 6032943.81 655521.26 N 70.49679627 W 148.72817586 10030.07 30.68 292.04 8676.36 8732.03 4732.25 4739.16 4733.10 1963.05 -4306.82 0.83 6032961.13 655475.86 N 70.49684618 W 148.72854401 10125.15 30.69 292.32 8758.13 8813.80 4780.69 4787.68 4781.58 1981.36 -4351.75 0.15 6032978.48 655430.55 N 70.49689615 W 148.72891147 10219.76 30.67 292.32 8839.50 8895.17 4828.88 4835.95 4829.82 1999.70 -4396.41 0.02 6032995.85 655385.52 N 70.49694616 W 148.72927670 10313.29 30.96 291.88 8919.82 8975.49 4876.71 4883.87 4877.70 2017.72 -4440.80 0.39 6033012.91 655340.75 N 70.49699533 W 148.72963976 10409.27 30.23 292.18 9002.44 9058.11 4925.46 4932.72 4926.50 2036.05 -4486.09 0.78 6033030.25 655295.09 N 70.49704531 W 148.73001011 10506.12 29.39 291.66 9086.47 9142.14 4973.51 4980.86 4974.60 2054.02 -4530.75 0.91 6033047.26 655250.05 N 70.49709434 W 148.73_ 10600.93 28.52 292.05 9169.43 9225.10 5019.31 5026.76 5020.46 2071.11 -4573.35 0.94 6033063.43 655207.09 N 70.49714094 W 148.730 2 10614.33 28.36 291.48 9181.21 9236.88 5025.68 5033.14 5026.83 2073.47 -4579.28 2.35 6033065.67 655201.12 N 70.49714740 W 148.73077229 10758.94 27.19 292.11 9309.16 9364.83 5092.92 5100.53 5094.15 2098.48 -4641.85 0.83 6033089.33 655138.03 N 70.49721562 W 148.73128405 10852.68 27.40 291.92 9392.46 9448.13 5135.82 5143.51 5137.11 2114.60 -4681.70 0.24 6033104.58 655097.84 N 70.49725957 W 148.73160999 10948.63 31.51 291.74 9475.99 9531.66 5182.89 5190.69 5184.23 2132.13 -4725.49 4.28 6033121.17 655053.69 N 70.49730741 W 148.73196814 11043.64 33.28 290.40 9556.22 9611.89 5233.63 5241.59 5235.05 2150.42 -4772.99 2.01 6033138.43 655005.81 N 70.49735727 W 148.73235663 11139.22 32.43 290.39 9636.51 9692.18 5285.27 5293.44 5286.79 2168.49 -4821.59 0.89 6033155.45 654956.83 N 70.49740655 W 148.73275413 11233.17 32.23 289.52 9715.89 9771.56 5335.27 5343.68 5336.89 2185.64 -4868.82 0.54 6033171.57 654909.25 N 70.49745332 W 148.73314038 11327.89 31.76 290.61 9796.23 9851.90 5385.22 5393.87 5386.95 2202.85 -4915.96 0.79 6033187.77 654861.76 N 70.49750026 W 148.73352592 11423.22 30.85 290.59 9877.68 9933.35 5434.56 5443.40 5436.39 2220.28 -4962.33 0.95 6033204.20 654815.03 N 70.49754779 W 148.73390513 11518.17 29.91 290.03 9959.59 10015.26 5482.38 5491.42 5484.30 2236.95 -5007.36 1.03 6033219.89 654769.65 N 70.49759325 W 148.73427344 11611.77 30.14 289.58 10040.63 10096.30 5528.97 5538.25 5531.01 2252.82 -5051.42 0.34 6033234.81 654725.26 N 70.49763651 W 148.73463384 11709.45 30.28 290.00 10125.04 10180.71 5577 .87 5587.40 5580.02 2269.46 -5097.67 0.26 6033250.45 654678.67 N 70.49768189 W 148.73501208 11804.41 30.23 290.31 10207.07 10262.74 5625.50 5635.25 5627.76 2285.94 -5142.58 0.17 6033265.97 654633.42 N 70.49772684 W 148.73537944 11900.11 29.38 290.26 10290.11 10345.78 5672.87 5682.82 5675.23 2302.44 -5187.20 0.89 6033281.49 654588.46 N 70.49777181 W 148.73574436 11995.38 28.79 290.86 10373.36 10429.03 5719.00 5729.13 5721.46 2318.70 -5230.56 0.69 6033296.82 654544.76 N 70.49781615 W 148.73609902 12088.64 28.22 291.74 10455.32 10510.99 5763.38 5773.63 5765.92 2334.86 -5272.03 0.76 6033312.09 654502.96 N 70.49786023 W 148.7.8 12185.05 27.95 293.76 10540.38 10596.05 5808.70 5819.02 5811.30 2352.41 -5313.88 1.03 6033328.73 654460.74 N 70.49790808 W 148.7 0 12281.20 29.65 299.57 10624.65 10680.32 5854.96 5865.31 5857.51 2373.23 -5355.20 3.40 6033348.65 654418.99 N 70.49796488 W 148.7 49 12402.78 34.22 308.96 10727.86 10783.53 5918.30 5929.50 5920.53 2409.61 -5408.00 5.54 6033383.89 654365.42 N 70.49806415 W 148.73755045 12433.29 37.49 309.85 10752.59 10808.26 5935.65 5947.36 5937.76 2420.95 -5421.80 10.85 6033394.93 654351.38 N 70.49809513 W 148.73766338 12465.77 40.44 309.93 10777.84 10833.51 5955.44 5967.79 5957.41 2434.05 -5437.47 9.08 6033407.69 654335.43 N 70.49813088 W 148.73779159 12497.51 42.91 310.90 10801 .55 10857.22 5975.83 5988.89 5977.67 2447.74 -5453.54 8.04 6033421.02 654319.08 N 70.49816823 W 148.73792302 12527.69 44.72 311.75 10823.32 10878.99 5995.94 6009.78 5997.63 2461.53 -5469.23 6.31 6033434.48 654303.10 N 70.49820589 W 148.73805139 12562.87 46.61 311.67 10847.91 10903.58 6020.12 6034.94 6021.64 2478.28 -5488.01 5.37 6033450.81 654283.96 N 70.49825159 W 148.73820509 12592.55 48.73 311.86 10867.89 10923.56 6041.19 6056.88 6042.57 2492.89 -5504.37 7.16 6033465.07 654267.29 N 70.49829148 W 148.73833900 12621.22 50.68 314.20 10886.43 10942.10 6062.05 6078.75 6063.28 2507.81 -5520.35 9.22 6033479.65 654250.99 N 70.49833222 W 148.73846974 12655.10 52.53 313.49 10907.48 10963.15 6087.26 6105.30 6088.33 2526.21 -5539.50 5.70 6033497.62 654231 .45 N 70.49838242 W 148.73862645 12685.06 54.68 312.55 10925.25 10980.92 6110.27 6129.42 6111.21 2542.66 -5557.14 7.61 6033513.69 654213.47 N 70.49842732 W 148.73877073 SurveyEditor Ver Sld( doc40x_37 ) NS28\NS28\NS28\NS28 Generated 6/17/2005 1 :47 PM Page 4 of 6 Comments Latitude Longitude N 70.49847044 W 148.73891310 N 70.49852610 W 148.73909732 N 70.49857847 W 148.73926538 N 70.49862933 W 148.73942015 N 70.49868852 W 148.73959141 12874.07 73.76 316.89 11007.10 11062.77 6270.66 6298.76 6270.89 2660.68 -5678.45 9.61 6033629.07 654089.66 N 70.49874950 W 148.73976349 12903.96 76.57 318.51 11014.76 11070.43 6297.43 6327.65 6297.57 2682.05 -5697.89 10.76 6033650.01 654069.76 N 70.49880783 W 148.73992260 12937.29 80.80 318.83 11021.30 11076.97 6327.49 6360.32 6327.56 2706.58 -5719.47 12.73 6033674.08 654047.66 N 70.49887482 W 148.74009920 12969.34 84.39 317.31 11025.43 11081.10 6356.85 6392.10 6356.87 2730.22 -5740.71 12.15 6033697.25 654025.93 N 70.49893935 W 148.74027300 12998.66 85.63 315.60 11027.98 11083.65 6384.14 6421.31 6384.15 2751.39 -5760.83 7.19 6033717.99 654005.35 N 70.49899715 W 148.74043768 13029.88 85.91 312.07 11030.28 11085.95 6413.71 6452.44 6413.71 2772.95 -5783.28 11.31 6033739.06 653982.44 N 70.49905600 W 148.74. 13062.52 86.01 310.33 11032.58 11088.25 6445.06 6485.00 6445.07 2794.40 -5807.78 5.33 6033759.97 653957.49 N 70.49911453 W 148.74 13093.01 84.84 307.97 11035.01 11090.68 6474.61 6515.39 6474.63 2813.59 -5831.35 8.62 6033778.64 653933.52 N 70.49916690 W 148.7410 4 13125.92 84.64 306.69 11038.03 11093.70 6506.69 6548.17 6506.74 2833.46 -5857.41 3.92 6033797.95 653907.04 N 70.49922113 W 148.74122795 13158.02 85.60 303.45 11040.76 11096.43 6538.23 6580.15 6538.31 2851.83 -5883.58 10.49 6033815.76 653880.48 N 70.49927127 W 148.74144210 13187.18 85.67 302.35 11042.98 11098.65 6567.07 6609.22 6567.16 2867.62 -5907.99 3.77 6033831.02 653855.74 N 70.49931436 W 148.74164183 13220.34 84.02 299.55 11045.96 11101.63 6599.95 6642.25 6600.06 2884.61 -5936.31 9.77 6033847.39 653827.06 N 70.49936069 W 148.74187352 13254.09 83.60 300.10 11049.60 11105.27 6633.41 6675.80 6633.53 2901.30 -5965.42 2.04 6033863.44 653797.60 N 70.49940622 W 148.74211167 13281.93 85.12 299.42 11052.33 11108.00 6661.04 6703.51 6661.17 2915.05 -5989.47 5.98 6033876.68 653773.27 N 70.49944373 W 148.74230843 13316.03 85.01 299.74 11055.27 11110.94 6694.93 6737.48 6695.08 2931.82 -6019.02 0.99 6033892.81 653743.37 N 70.49948948 W 148.74255016 13348.02 86.22 299.73 11057.71 11113.38 6726.75 6769.38 6726.91 2947.64 -6046.71 3.78 6033908.03 653715.34 N 70.49953264 W 148.74277675 13363.68 86.15 300.23 11058.76 11114.43 6742.32 6785.00 6742.50 2955.45 -6060.25 3.22 6033915.54 653701.64 N 70.49955394 W 148.74288748 13389.69 85.80 301 .45 11060.58 11116.25 6768.16 6810.95 6768.35 2968.75 -6082.52 4.87 6033928.36 653679.09 N 70.49959023 W 148.74306974 13420.10 86.62 300.69 11062.59 11118.26 6798.37 6841 .29 6798.57 2984.41 -6108.51 3.67 6033943.45 653652.77 N 70.49963295 W 148.74328238 13454.34 87.72 301 .58 11064.28 11119.95 6832.40 6875.49 6832.64 3002.09 -6137.78 4.13 6033960.50 653623.13 N 70.49968119 W 148.74352187 13485.99 87.76 302.05 11065.53 11121.20 6863.84 6907.11 6864.10 3018.76 -6164.66 1.49 6033976.59 653595.90 N 70.49972667 W 148.74374174 13516.03 88.51 302.62 11066.51 11122.18 6893.66 6937.14 6893.95 3034.82 -6190.03 3.14 6033992.10 653570.20 N 70.49977049 W 148.74394930 13550.14 88.68 304.40 11067.34 11123.01 6927.43 6971.24 6927.77 3053.64 -6218.46 5.24 6034010.31 653541.37 N 70.49982185 W 148.74418193 13582.36 88.51 305.10 11068.13 11123.80 6959.23 7003.45 6959.62 3072.00 -6244.92 2.24 6034028.09 653514.52 N 70.49987194 W 148.7.8 13611.27 87.83 305.27 11069.06 11124.73 6987.72 7032.34 6988.16 3088.65 -6268.54 2.42 6034044.23 653490.55 N 70.49991737 W 148.7 2 13645.31 84.81 304.71 11071.24 11126.91 7021.23 7066.31 7021.73 3108.13 -6296.36 9.02 6034063.10 653462.31 N 70.49997052 W 148.74481941 13677.37 84.70 305.25 11074.17 11129.84 7052.73 7098.23 7053.29 3126.43 -6322.52 1.71 6034080.84 653435.77 N 70.50002046 W 148.74503345 13706.75 84.47 305.74 11076.95 11132.62 7081.54 7127.48 7Q82.16 3143.42 -6346.34 1.84 6034097.30 653411.60 N 70.50006680 W 148.74522831 13740.57 84.32 305.74 11080.25 11135.92 7114.67 7161.14 7115.37 3163.08 -6373.66 0.44 6034116.37 653383.87 N 70.50012044 W 148.74545187 13772.68 85.49 305.40 11083.10 11138.77 7146.17 7193.12 7146.95 3181.68 -6399.67 3.79 6034134.41 653357.46 N 70.50017121 W 148.74566474 13802.04 85.25 305.46 11085.47 11141.14 7175.01 7222.39 7175.85 3198.64 -6423.52 0.84 6034150.86 653333.26 N 70.50021750 W 148.74585986 13836.49 84.59 305.00 11088.52 11144.19 7208.83 7256.70 7209.77 3218.44 -6451.55 2.33 6034170.04 653304.81 N 70.50027151 W 148.74608922 13868.64 85.14 303.99 11091.40 11147.07 7240.47 7288.72 7241 .48 3236.57 -6477.94 3.57 6034187.61 653278.04 N 70.50032098 W 148.74630517 13897.79 86.52 306.04 11093.52 11149.19 7269.15 7317.80 7270.24 3253.25 -6501.74 8.46 6034203.77 653253.88 N 70.50036650 W 148.74649999 13931.94 86.14 305.67 11095.70 11151.37 7302.68 7351.88 7303.87 3273.22 -6529.37 1.55 6034223.13 653225.84 N 70.50042096 W 148.74672602 13961.81 85.63 306.15 11097.85 11153.52 7331.99 7381.67 7333.28 3290.69 -6553.50 2.34 6034240.08 653201.34 N 70.50046864 W 148.74692349 SurveyEditor Ver Sld( doc40x_37 ) NS28\NS28\NS28\NS28 Generated 6/17/2005 1 :47 PM Page 5 of 6 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft) (dea) {deal (ft) (ft) ( It) (ft) (ft) (ft) ( It) (deg/100 ft) (ftUS) (ftUS) . 13991.28 85.25 306.20 11100.19 11155.86 7360.87 7411.04 7362.25 3308.03 -6577.21 1.30 6034256.91 653177.26 N 70.50051595 W 148.74711754 14024.56 85.08 307.46 11103.00 11158.67 7393.39 7444.21 7394.90 3327.91 -6603.75 3.81 6034276.21 653150.30 N 70.50057019 W 148.74733475 14056.53 84.84 307.60 11105.80 11161.47 7424.55 7476.05 7426.18 3347.31 -6629.01 0.87 6034295.06 653124.63 N 70.50062313 W 148.74754143 14086.36 84.88 307.85 11108.48 11164.15 7453.60 7505.76 7455.36 3365.49 -6652.51 0.85 6034312.73 653100.75 N 70.50067274 W 148.74773374 Last MWD+UFR+MS 14104.36 84.45 308.18 11110.15 11165.82 7471.10 7523.68 7472.94 3376.52 -6666.63 3.01 6034323.46 653086.40 N 70.50070285 W 148.74784929 TD ( Projected) 14150.00 84.45 308.18 11114.56 11170.23 7515.43 7569.11 7517.49 3404.60 -6702.34 0.00 6034350.76 653050.10 N 70.50077948 W 148.74814152 Leqal Description: Surface: 1319 FSL 648 FEL S11 T13N R13E UM SHL: 2056 FSL 560 FEL S23 T13N R13E UM Survey Type: Definitive Survey NOTES: GYD-CT-DMS - (Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination.) MWD + IFR + MS . ( In-field referenced MWD with mult-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Northinq ey) ¡ftUS] Eastinq eX) ¡ftUS] 6031091.25 659823.57 6024459.44 658856.05 . . SurveyEditor Ver Sld( doc40x_37 ) NS28\NS28\NS28\NS28 Generated 6/17/20051 :47 PM Page 6 of 6 Legal Name NS28 Common Name: NS28 4/7/2005 FIT 4/17/2005 FIT 4/22/2005 FIT 2,068 (psi) 2.44 (ppg) 6,996 (psi) 14.50 (ppg) 6,424 (psi) 11.50 (ppg) - Printed: 5/16/2005 11 :56:50 AM 655 (psi 965 (psi ,340 (psi 8.50 (ppg) 2.50 (ppg) 9.10 (ppg) (ft) 9,288.0 (ft) 0,755.0 If 10,671.0 (ft) 12,365.0 If (fù '-' . '\ (11) ~. ri'\ ¡jj\ 1 ,-, ~ UU . AI(ASK& OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar NS28 BP Exploration (Alaska) Inc. Permit No: 205-016 Surface Location: 1319' NSL, 648' WEL, SEC. 11, T13N, R13E, UM Bottomhole Location: 4659' NSL, 2124' WEL. SEC. 10, T13N, R13E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to . ess any required test. Contact the Commission's petroleum field inspector at (907 659-3 7 ~ ger). DATED this~y of February, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. \lJGA- ~/I/ UJ()~ 1 a. Type of work BDrill o Redrill 11 b. Current Well Class o Exploratory B Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name and Num'¡V" BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 NS28 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 14150 TVD 11176 Northstar Unit 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 312799 1319' NSL. 648' WEL, SEC.11, T13N, R13E, UM 8. Land Use Permit: 13. Approximate s~~e: Top of Productive Horizon: 4156' NSL, 1430' WEL, SEC. 10, T13N, R13E, UM 021 51 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4659' NSL, 2124' WEL. SEC. 10, T13N, R13E, UM 2560 6500' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: X-659824 y- 6031091 Zone- ASP4 (Height above GL): 56' feet 2150' away from NS14 16. Deviated Wells: Kickoff Depth: 400 feet 17. Maximum Anticipated Pressures in psig (see 2~~:¡O35) Maximum Hole Angle: 86 decrees Downhole: 5318 Surface: 39 18.C8slng program; Speclfication~ Settlng[)epth .(0.1. ~,9J , Size Top . . . Bottom ...... Hole Casinc Weicht Grade CouplinQ Length MD TVD MD TVD (includinc staQe data) 20" 20" 169# X-56 Welded 200' Surface Surface 200' 200' Driven 16" 13-3/8" 68# L-80 BTC 3599' Surface Surface 3599' 3206' 39 sx PF 'L', 448 sx Class 'G' / 12-1/4" 9-5/8" 53.5# L-80 BTC-M 10700' Surface Surface 10700' 9314' 22 sx Extended, 437 sx Class 'G' / 8-1/2" 7" 29# L-80 Hvdril 511 1856' 1 0550' 9184' 12406:. 10781' 34 sx Class 'G' / 6" 4-1/2" 12.6# 13Cr-80 Vam Ace 1894' 12256' 10652' 14150' 11176' 26 sx Class 'G' ,. 19. PRESENT WEL.LCON.DITION SUMMARY (To be completed forRedrill>ANDRe-entryOpe"~tiOl"ls) Total Depth MD (ft): Total Depth TVD (ft): \ Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft):\ Junk (measured): Casing Length Size Cement Volume MD TVD I Conductor Proch Ir.tion Liner Perforation Depth MD (ft): IPerfOration Depth TVD (ft): 20. Attachments a Filing Fee, $100 o BOP Sketch a Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report a Drilling Fluid Program a 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Kara. 564-5667 Printed Name Pat Archey Title Senior Drilling Engineer Is ~~-? Date ~¡Z/ t>,s-" Prepared By Name/Number: SiQnature Phone 564-5803 Sondra Stewman, 564-4750 r Commission Use Only Permit To Drill API Number: I Permit Approval I ~ee cover letter for Number:.2a S - ð~ 50- CJZ9..... .z. 32. S/~ Date: other requirements Conditions of Approval: Samples Required DYes MNo Mud Log Required DYes ~No Hy ogen Sulfide Measures BJ Yes No Directional Survey Required gYes DNo Other: D~ t- 130 E~~f&. 4 600 f~f'. ~£ U.l~Wl~+ Wtí,./ I/~ J . r~r , ~~ (h){Z), tf<:lIut..... I S e...} .... ,-- .- ... 11 /t1 ð? Anmov . . /jft( r APPROVED BY , THE GÔMMISSION Date Form 10-40\..a6ised O~4 " --- CRIGIf~AL gubmit~n Duplicate - leI STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 / bp " . BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: January 31, 2005 From: Dan Kara Northstar Drilling Engineer Subject: NorthStar NS28 Application for Drilling Permit Mr. Aubert, NS28 is currently scheduled to be drilled by Nabors 33E on February 25, 2005. A Diverter waiver is also requested on NS28. To date, no development well drilled through the Northstar *' upper strata-graphic intervals has experienced any difficulty with shallow gas. All surface holes have been drilled and cemented to a common depth of approximately 3,170' TVDss depth, (-150' TVD below the top of the SV6), with the exception of one well, which extends into the SV5 -3280' TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. Please find attached the NS28 Well Plan Summary, directional plan, and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5667. Si~~IY'\7 ~, Dan Kara BP Northstar Operations Drilling Engineer 564-5667 CRIGlr~AL NS28 Permit to III . Northstar NS28 SUMMARY DRILLING OPERATIONS Pre-Riq Work: 1. Set 20" conductor and weld an ASS Vetco landing ring for the ASS Vetco Multibowl Wellhead on the conductor. (Completed) 2. Install 7' x 7' cellar and polyshield same. (Completed) RiQ Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter system, if required. NOTE: A diverter dispensation has been requested. Confirm dispensation decision with the / Drilling Engineer. A D7 Diverter Drill will be conducted prior to spud. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to +/-150' TVD below the /' top of the SV6 marker at approximately 3435' MD. Surface casing point has been picked at 3600' MD " (3206' TVD). POOH. 4. Run 13-3/8", 68# L-80 surface casing. Cement the casing to surface in 1 stage. A top job will be performed in the event the cement does not circulate to surface. . 5. ND diverter / riser system and NU casing / multi-bowl wellhead. NU SOPE and test to 250/4800 psi. / 6. MU 12-1/4" directional assembly. RIH to float collar. Test the 13-3/8" casing to 3500 psi with 9.3-ppg mud for 30 min. This test pressure may change based on actual mud weight in the hole. 7. Drill out remaining cement. Drill 20' of new formation below 13-3/8" shoe and perform FIT to a 12.5 ppg EMW. (FIT/LOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to 9-5/8" casing point (approximately 10700' MD, 9314' TVD) at the top /' of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 10.0 ppg at the top of Kuparuk. POOH. No logs are currently planned to be run. 9. Run 9-5/8'\ 53.5# L-80 intermediate'casing. Cement the casing to the top of the SV2sandin a single /' stage. Set the 9 5/8" pack off. Perform a down-squeeze on the 9-5/8" x 13-3/8" annulus with 1 annular volume of mud upon installing and testing the packoff. Down-squeeze diesel to 2000' TVD for freeze protection after WOC. 10. MU 8-1/2" (9-1/2" reamer) directional assembly and RIH to float collar. Pressure test the 9-5/8" casing to 4800 psi with 10.3 ppg mud for 30 min. This test pressure may change based on the actual mud weight in the hole. / 11. Drill out remaining cement. Drill 20' of new formation below 9-5/8" shoe and perform a FIT to a 14.5 ppg EMW, (FIT/LOT procedure on file with AOGCC). 12. Weight up to minimum 12.5 ppg prior to drilling ahead. Drill the drilling liner hole into the top of the Sag at approximately 12360' MD (10741' TVD). Intermediate casing point has been picked at 12406' MD (10781' TVD). POOH. // 13. Run and cement a 7" 29# L-80 drilling liner. Set the liner hanger and liner top packer. Circulate off any excess cement. POOH with liner setting string. 14. RIH w/ 6" directional assembly. Test 9 5/8" x 7" liner to 3600 psi for 30 mins with 12.5 ppg mud (this exceeds the minimum requirement of 500 psi over the leak off pressure for liner lap testing.) RIH to /. 7" landing collar. Drill out remaining cement and 20' of new formation below 7" shoe. 15. Displace well 9.1 ppg mud. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). 16. Drill 6" production interval to the proposed TD at 14151' MD (11176' TVD). Acquire MWD/LWD GR/Resistivity/Density/Neutron. Increase mud weight to 9.3 ppg prior to POOH. 17. Run and cement the 4-1/2" 12.6# 13Cr-80 liner with an inner string. Set the liner hanger and liner top ./ packer. Circulate minimum 1 bottoms up to remove excess cement using 9.3 ppg viscosified brine. 18. Pressure-test the liner top packer and casing to 1000 psi w/ 9.3 ppg. 19. Circulate to clean 9.3 ppg brine (less than 80 NTU's) using spacers as per MI recommendation. Leave a 9.3 ppg perf pill (150,000 LSRV SF FloPro) in 4 W' liner. 20. Pressure test liner lap to 3700 psi w/ 9.3 brine in well. This equates to 500 psi above a 15 ppg LOT at the 7" shoe. 2/1/2005 CRIGINAL Page 1 of 11 NS28 Permit to III . 21. Run tubing conveyed guns on drill pipe. Perforate horizontal section (-300' anticipated). 22. Monitor well for stability. POOH w/ guns and prepare to run the 4 W' completion. 23. Run the 4 W', 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will /"" be run from just above packer setting depth to surface. 24. RIH to packer setting depth. Single SSSV control line will be run from the TRSV at +/- 1000' TVD (-1050' MD) to surface. 25. Run space out pups and terminate the 0.25" control line and 0.25" fiber optic line. All lines will be secured using collar cable clamps. Pressure test the control lines and tubing hanger seals. Function test the fiber optic line. 26. Ptlmp heated corrosion inhibited seawater down the IA to inhibit down to the packer. 27. Land tubing hanger, run in lock down screws. Test hanger to 5000 psi. 28. Drop ball and rod to set packer. Increase the tubing pressure to 4200 psi (maximum anticipated / surface pressure) with 9.3-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. 29. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 9.3-ppg-completion fluid for mechanical integrity test (MIT-IA). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Email or fax chart to Drilling Engineer. 30. Simultaneously bleed down the annulus and tubing to 0 psi. 31. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. Pull TWC. 32. RU Slickline. Pull ball/rod/seat. Install tubing tail plug in XN profile. RD slickline. 33. Increase IA pressure to shear circulation valve in GLM. Pump heated diesel down the 4 W' x 9 %" /~ annulus equivalent to the annulus capacity plus tubing capacity to a depth of 3000' TVD (3350'MD). RU the U-tubing manifold and allow the Freeze Protection fluid to u-tube through the GLM. 34. Dry-rod in BPV. RDMOL Estimated Spud Date: February 25, 2005 Dan Kara NorthStar Drilling Engineer 564-5667 2/2/2005 (ìf)\CI L-1t\ \.:I¡ L Page 2 of 11 ) NS28 Permit to I" . General Information I Type of Well (producer or injector): I Producer Northstar Slot: NS28 Surface Location: 1319' FSL, 648' FEL, Sec. 11, T13N, R13E, UM / X = 659,823.57 Y = 6,031,091.25 Target (Ivishak): 4156 FSL, 1430 FEL, Sec. 10, T13N, R13E, UM 400' Radius X= 653700.00 Y= 6,033,800.00 11116.00 TVDrkb Bottom Hole Location: 4659 FSL, 2124 FEL, Sec. 10, T13N, R13E, UM / X = 652,995.20 Y = 6,034,289.27 11176 TVDrkb I AFE Number: I Rig: I Nabors 33E /' I Estimated Start Date: I 3/25/2005 I Operating days to complete: 130 Œ![] 14150 I I TVDrkb: 111176 I I RKB/Surface Elevation: (a.m.sJ.) 156.00'/ 15.67' I 1 Well Design (conventional, slimhole, etc.): I Modified Big Bore I I Objective: I Ivishak Producer / ~ I Well Name: NS28 API Number: BHP: 5192psi @ 11,100' TVDss EMW: , 8.95 PPQ .. BHT: 254 of @ 11,100' TVDss Land Use Permit: LO-N96-006 Distance to Nearest Property: 6500 ft Distance to Nearest Well within Pool: 2150' to NS 14. Cellar box: Elevation above MSL = 15.67' RKB to Cellar box: 40.33' (Estimated) Rig Elevation: RKB + MSL = 56.00' Conductor: 200' MDrkb of 20", 169#, X-56 (pre-driven) 2/1/2005 Page 3 of 11 , NS28 Permit to ", Ie Formation Tops(TVDss) and Estimated Pore Pressures Estimated Depths Estimated Top (TVDss) TVDrkb MDrkb Pore Press. Formation (Psi) (PPfI) Top Permafrost 1,149 1,205 1235 542 8.65 Base Permafrost 1,519 1,575 1666 708 8.65 SV6 - top confining zone 3,012 3,068 3436 1380 8.65 Surface casing point 3,150 3,206 3599 1442 8.65 SV5 - base confining zone 3,273 3,329 3743 SV4 3,580 3,636 4100 1635 8.65 SV2 - top upper injection zone 3,972 4,028 4556 1812 8.65 SV1 - top maior shale barrier 4,363 4,419 5010 1988 8.65 q.~ TMBK - top lower iniection zone - Top Ugnu 4,716 4,772 5421 2146 8.65 WS1 - top Schrader Bluff - Base Ugnu 6,278 6,334 7236 2849 8.65 CM3 - Base lower injection zone (top Colville) 6,952 7,008 8020 3152 8.65 THRZ - Top HRZ 8,528 8,584 9852 3861 8.65 BHRZ - Base HRZ 8,608 8,664 9945 3897 8.65 Top Kuparuk 8,753 8,809 10114 4265 9.37 Kuparuk C 8,890 8,946 10273 4428 9.58 Top Miluveach 9,208 9,264 10643 10. Intermediate casing point 9,258 9,314 10701 Intermediate logging point 9,258 9,314 10701 Fault 18 9,675 9,731 11185 Top Kingak 9,736 9,792 11256 , Top Sag River 10,685 10,741 12360 ¡c· Intermediate casing point 10,725 10,781 12406 5017 8.95 Top Shublik - 90 10,775 10,831 12464 5080 9.07 Top Ivishak 10,880 10,936 12601 cr· ') Geol target #1 11,060 11,116 13291 Oil- Water contact 11,100 11,156 13864 5192 8.95 Geol target #2 11,120 11,176 14151 Total Depth 11 ,120 11 ,176 14151 5201 8.95 Total Depth 11 ,120 11 ,176 14151 5318 8.95 "'S " Notes: 1. Anomalous high gas readings reported in Seal A-01 mud log at the following interval: 3690-3775; 3925 - 4050; 4140 - 4425,4510 - 4700 MD - No significant Gas shows in NS10 through NS17 through this interval- max gas = 70 units 2. Depth predictions based on NS13, NS14, NS27, Seal A-1, NS29, Seal A-3 wells and comparison to 3D seismic volume. 3. Pore pressures estimated using data from offset wells. 2/1/2005 Page 4 of 11 , NS28 Permit to III . General Information CASINGlTUBING PROGRAM: Casing String Hole Casing Description Measured Depth Vertical Depth Length Size Top Bottom Top Bottom Feet Conductor Pipe 20" 20" 169# X-56 Welded Su rface 200 Surface 200 200 Surface Casing 16" 13-3/8" 68.0# L-80 BTC Surface 3599 Surface 3206 3599 Intermediate Csg 12 %" 9-5/8" 53.5# L-80 BTC-M Su rface 10700 Surface 9314 10700 Intermediate Liner 8 Y2" 7" 29.0# L-80 Hydril 511 10550 12406 9184 10781 1856 Production Liner 6" 4-1/2" 12.6# 13Cr-80 Yam Ace 12256 14150 10652 11176 1894 Tubing - 4-1/2" 12.6# 13Cr-80 Yam Ace Surface 12256 Surface 10652 12256 Formation Intecuitv/Casina Testina: 133/8" Surface Casin 9 5/8" Intermediate Casin 7" Intermediate Liner 4 W' Production Liner 20' min below shoe 20' min below shoe 20' min from 7" shoe n/a EMW EMW EMW Test Point Depth Shoe Test T e FIT FIT FIT n/a EMW MUD PROGRAM SUMMARY: Srf HI MdP rf S S d M d 16" HIS u ace oe u rope les: eawater pu u oe ectlon From Surface to ,...3599' MD /3206' TVD -150' TVD below top SV6). . Interval Density Viscosity YP Gel API FL pH (ppg) (seconds) 10 sec Initial to base PF *8.8 - 9.3 100 - 200 50 - 70 25 - 40 15 - 20 8.5 - 9.5 Base PF to the top of SV *9.0 - 9.3 100 - 150 30 - 45 15 - 25 6-10 8.5 - 9.5 sands SV6 @ Interval TO *9.3 max 75 - 125 20 - 35 10 - 25 6-10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. I t d· t HIM d P rf S t P I M d 12 1/4" HIS f n erme la e oe u rope les: eawa er olvmer u - oe eClon From Surface Casing Shoe into the Top of the Miluveach (-10700' MD /9314' TVD). Interval Density (ppg) PV YP API I HTTP FL pH Initial 8.7 - 9.3 10-16 20 - 30 6-10 8.5 - 9.5 Top HRZ 10.1-10.3 10 - 16 20 - 25 4-6/ <12 8.5-9.5 Top Kuparuk to Miluveach 10.1-10.3 10 -18 20 - 28 4-6/ <12 8.5- 9.5 2/1/2005 r' " t 1 U i ¡r"t ! 1-\ ¡ ~/ J ì_.". Page 5 of 11 , NS28 Permit to III . Drillin Liner Hole Mud Pro erties: Inhibited KCL Mud 8-1/2" Hole Section From Intermediate Casing Shoe to 12406' MD /10781' TVD (top of Sag) Interval Densit PV YP Miluveach & Kingak to top of Sag 12.3 25 - 30 20 - 30 API FL 4-6/<12 H 8.5 - 9.5 Production Hole Mud Properties: Seawater a 3 Drill-In Fluid 6" Hole ectlon From Intermediate Casing Shoe to 14150' MD /11,176' TVD Interval Density (ppg) PV YP API/ HTTP FL pH Initial/Final 9.1 -9.3 8-12 20-25 3-5 8.5 - 9.5 Ie co S DIRECTIONAL: KOP: 400 TMDrrVD Build Rates 1°/100' to 3°/100' Maximum Hole Angle: ±86° Close Approach Wells: Surface- 10' well spacing causes close approach at 450/550' to wells NS27/29 respectiv All wells passed the major risk rule, but are within 0.75/2.21' of the allowable tolerance. NS27 &NS29 has been classified under the minor risk rule of 1 :200 which allows a clearance of 5.22'n.28', respectively. Gyro will be used for the initial surveys and kickoff. NS10 Area of Review NS28 does not enter the Area of Review for NS 10 disposal well. Survey Program: Gyros as required from surface to +/-1500'. MWD surveys will be run from 1500' to 2500'. IFR+MS corrected MWD survevs from +/- 2500' to TD. , SURFACE AND ANTI-COLLISION ISSUES: Surface Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. WELL CONTROL: Equipment will be installed that is capable of handling maximum potential surface pressures. (Schematics are on file with the AOGCC and MMS.) ~ 5000 psi working pressure pipe rams (2) ~ Blind/shear rams ~ Annular preventer Based upon the calculations below, BOP equipment will be tested to 4800 psi. Maximum Surface Pressure - Full Column of Gas from TD - 0.12 psilft gradient Gradients - psi/ft Pressures 12 W' Intermediate Hole Section: TVD - ss Formation Gas BHP Surface 1.2 * Surface Kuparuk C 8890 9.58 0.12 4429 3362 4034 8 W' Intermediate Hole Section: SaQ River 10685 8.95 0.12 4973 3691 4429 6" Production Hole Section: /' Ii Total Depth 11120 8.95 0.12 5318 ( 3Q8Jf 4781 / Planned BOP test pressure: 4800 psi (annular to 3500 psi) :../ Planned completion fluid: 9.3 PPQ Brine /6.8 ppg Diesel 2/1/2005 Page 6 of 11 NS28 Permit to I" . LOGGING PROGRAM: Well Evaluation Program 116" Surface Hole I 12-1/4" Interm. Hole I 8-1/2" Interm. Hole 6" Production Hole Interval - MDrkb depths I From I TO I From I TO I From I TO I From I TO I MWD/L WD Directional Surface 3,599 Surface shoe I 10,701 10,701 1 12,406 12,406 I 14151 Gamma Rail Surface 3,599 Surface shoe I 10 701 10,701 I 12 406 12,406 I 14151 Gyro Surface 3,599 None None None PWD None Surface shoe I 10,701 10701 I 12,406 None Resistivity - recorded mode None None None None Resistivitv - real time mode None 6,800 10,701 None 12406 14151 Densitv None 6800 10,701 None 12,406 14151 Neutron None 6,800 10,701 None 12,406 14151 Formation Dressure while drillino None None Sonic ( ISONIC) None None None None Wireline based Open Hole loas GR None None None Continaent Resistivitv ( HALS None None Continoent Neutron (HGNS None None None Continoent Densitv (HRMS) .. None None None Continoent Sonic None None None None FMI (4 arm caliDer) .. None None None None CMR None None None None RFT None None None None MDT None None None None Cased Hole logging SCMT / CBL I USIT None None None 10 701 I 14151 SONIC - DSI ( P wave only needed) None None None None PDC - GR loa needed Surface I 12,406 None Mudloaaina Gas Detection None None None None MAD PASS None None 10200' TVD 11 0500' TVD None None None None None None None None None None None None None Comments Importance Wireline Loas MWD/LWD Logs 12-1/4" Hole: PWD resistivity and LWD in real time Low Do not re-run if unsuccessful If tool fails, drill ahead. m rvi.. 12-1/4" Hole: MDT Re-run if unsuccessful except if Med TBD Continaency conditioning trip required to run casing 8-1/2" Hole: PDC Re-run if unsuccessful, even if If unsuccessful, POOH and repair if GR log needed for depth control. High conditioning trip is required. DP possible. Willing to RIH without tool MAD pass needed after drlg shoe conveyed not required. repaired if necessary. for deDth correlation. Production Hole: Very High Re-run if unsuccessful, even if DP conveyed is required. Cement bond log across OWC. OH Re-run if unsuccessful, even if If unsuccessful, POOH and idle rig wireline logs if MWD log fails. Critical sidetrack or DP conveyed is required. until tool is fixed. 2/1/2005 Page 7 of 11 NS28 Permit to I, L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: L-80 Liner: 13Cr Completion: 2/1/2005 . Ikguired Materials: 3599' 1-133/8" 1 - 13 3/8" 1 - set 17 - 133/8" x 153/4" 17 -133/8" x 153/4" 1 - 20" x 13 3/8" 1-135/8" 10700' 1 - 9 5/8" 1 - 9 5/8" 1 - set 1 - 13 5/8" x 9 5/8" 183 - 9 5/8" x 12" 183 - 9 5/8" x12" 1856' 1-8W' 1 - 7" 7 - 7" x 8 1/4" 7-7"x81/4" 1 - 7" x 9 5/8" t - 7" x 95/8" 1 -7" 1-7" 1894' 1 - 4-1/2" 1 -4-1/2" 30 - 4-1/2" x 5-3/4" 30 - 4-1/2" x 5-3/4" 1 - 4-1/2" x 7" 1 - 4-1/2" x 7" 1 - 4-1/2" 12256' 1 1 1 1 1 1 1 1 2 1 133/8", 68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) HES Cement Plug Set SV Rigid Centralizers Stop Bands ABB-VGI Fluted hanger - BTC down, 11 %" external ACME landing thread ABB-VGI Casing HeadfTbg head 9 5/8", 53.5# L-80 BTC-MOD HES Super Seal II Float Shoe HES Super Seal II Float Collar HES Cement Plug Set ABB-VGI Casing Hanger SV Rigid Centralizers Stop Bands 7",29# L-80 Hydril511 BBL reamer shoe HES Super Seal II Float Collar SV Rigid Centralizers Stop Bands Baker Double-Grip Flex Lock Hydraulic Set Liner Hanger - Rotating hanger. Baker ZXP Liner Top Packer Baker HRD running tool Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Yam Ace HES Super Seal II Float Shoe HES Super Seal II Float Collar RH Turbulators Stop Bands Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Yam Ace 4 W' ABB-VGI tubing hanger 4 W' ABB-VGJ adapter flange 4 W' ABB-VGI5-1/8" 5K Swab Valve w/tree cap CIDRA mandrel and 0.25" fiber optic cable (wi 4 W' cable clamps). 4 W' SVLN and 1 - 0.25" control lines 4 W' x 1" GLM with RP Shear valve installed 7" x 4 W' Baker 13 Cr packer S-3. 4 W' WLEG (Self-Aligning Mule Shoe) 4 W' 13 Cr X nipples 4 W' 13 Cr XN nipple Page 8 of 11 NS28 Permit to ~I . PERMAFROST: The 13-3/8" surface casing will be run approximately 1575' TVD below the permafrost to -3599' MOl 3206' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and "Permafrost" 'L' lead slurry. The tail slurry allows sufficient compressive strength to prevent the shoe from breaking down as well as an accelerator to decrease thickening time. The lead slurry is light slurry that contains a freezing point depressant which enables the cement to set up rather than freeze. CEMENT CALCULATIONS: ole capacity from surface to 200' MD, 125% excess to 1666' MD, 50% to Spacer Slurry Casing -1/2" 12.6# 13Cr-80 Prod Liner Basis: tage 1: Slurry: Based on 1745' of 6" open hole x 4 Y2liner + 50% excess + 150' of 7" csg x 41/2" csg liner lap + 00' of 7" csg x 4" . . e above TaL + 40' shoe joint. lur TOC: At - 05 MD tage 1: Total-e>. Spacer Cement / S acer Slurry k of 15.8 ppg Premium 'G'. 2/1/2005 Page 9 of 11 . . Big Bore Pre-Produced Injectors Casing Specifications Summary Suñace Casing Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Weight Grade Connection ID (in) Drift (in) MinIMax Coupling: OD Strength 0000 Ibs) Stren~ 0000 Ibs) Strength (psi) Strenlrth (psi) 13-3/8" 68 ~80 BTC 12.415 12.295 Position 14.375 1556 1545 5024 2264 Intennediate Casing Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Weight Grade Connection ID (in) Drift (in) MinIMax Coupling OD Strength 0000 Ibs) Strength 0000 Ibs) Strenl!th (psi) Strength (pSi) 9-5/8" 53.5 ~80 BTC-M 8.535 8.5 Position 10.625 1244 1268 7927 6617 Production liner Torque Tensile (Body) Tensile (Thread) Burst Col1apse Size Weight Grade Connection ID (in) Drift (in) MinIMax Coupling OD Strength 0000 Ibs) Strength Strength Strength 7" 29 13CR-80 NSCC 6.184 6.059 6900/8900 7.656 676 691 8160 7020 Production Thbing Torque Tensile (Body) Tensile (Thread) Burst Collapse Size Weight Grade Connection ID (in) Drift (in) MinIMax Coupling OD Strength 0000 Ibs) Strength 0000 Ibs) Strength (psi) Strength (psi) 4.5" 12.6 13CR-80 VAMACE 3.958 3.833 3600 4.964 288 288 8430 7500 DRILLING HAZARDS/CONTINGENCIES: HYDROGEN SULFIDE - H2S: ./ Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautionsšhõuld be followed at all times. ./ No H2S was detected at Northstar while drilling or testing the Seal Island A-01, A-02, or A-03 exploration/appraisal wells. ./ No H2S was detected while drilling the NS10 waste disposal well, or any subsequent Northstar wells. Reference information below on file with AOGCC: ~ Northstar/Nabors 33E H2S contingency plan. ~ Well test hydrocarbon analyses for Seal Island A-Ot, A-02, and A-03. DISPOSAL: Annular Injection: There will be no annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be processed in the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. Fluid Handling: All Class I and Class" fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the NS10 Class I Waste Disposal Well. NS28 Permit to Drill . . NS28 Ria-site Summary of Drillina Hazards POST IN DOGHOUSE / " Gas hydrates may be present near the base of the permafrost. If gas hydrates are encountered, mud weight may be increased to 10.2 ppg and treated with 2 ppb Driltreat (Lecithin). Additional measures include reducing flow rates to -450 to 500 gpm and keeping the mud temperature cool. " Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indication of shallow gas was seen in any other previously drilled Northstar wells. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. " Differential sticking could be problematic in both the surface and intermediate hole sections adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods; tighten fluid loss properties of mud. " Severe losses have been seen in the intermediate section with a higher mud weight (11.6 ppg). The well design has been changed to alleviate this problem. The new casing design sets the 9 5/8" casing in the Miluveach and drills out with an 8 W' assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. However, lost circulation has been seen in both the 12 " 4" and 8 W' hole sections. Be prepared for any potential lost circulation situation. The 'Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. " Packing off due to improper hole cleaning can lead to stuck pipe. The PWD data, pick-up/slack-off weights and other drilling parameters must be monitored at all times. If in doubt, stop and condition the hole prior to drilling ahead or tripping. " Bit balling has been experienced in the Miluveach. The mud properties and PDC bit selection will be closely monitored to minimize potential balling. " No faults are expected to be crossed while drilling NS28, however, be prepared for any potential lost circulation. A copy of the 'Non-Payzone Lost Circulation Decision Tree' can be found in the last section of the Master Well Plan, which can be found on the Rig. " The Kingak shale, in the offset Seal Island wells drilled by Shell, experienced severe hole instability. The casing shoe at the base of the Kuparuk, higher mud weight and lower angles will help with hole conditions. " Conglomerate drilling in the Ivishak can lead to lost circulation, packing off due to unconsolidated formation and directional problems due to deflection of the drill string off of large rocks. Key drilling parameters must be monitored at all times. Do not drill ahead if a potential problem is detected. Severe lost returns were experienced on the NS29 in the Shublik and Ivishak. The LCM decision tree will be maintained on the rig as well as in the Master Well Plan. " There are no mapped faults in the horizontal section of this well. However, sub-seismic faults may exists, leading to potential lost circulation. Be prepared using the pay-zone LCM decision tree. " Northstar is not a designated H2S pad. . CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 11 NS28 (P10) Proposal hlumberuer Report Date: Client: Field: Structure / Slot: Well: Borehole: UWIIAPI#: Survey Name / Date: Tort / AHD I DDII ERD ratio: Grid Coordinate System: Location LaULong: Location Grid NIE Y/X: Grid Convergence Angle: Grid Scale Factor: December 6, 2004 BP Exploration Alaska Northstar Northstar PF / NS28 NS28 Plan NS28 APpro 50029 NS28 (P10) HA I December 6, 2004 91.691' / 7567.68 ft /5.944/ 0.677 NAD27 Alaska State Planes, Zone 04, US Feet N 70.49148680, W 148.69332934 N 6031091.250 ftUS, E 659823.570 ftUS +1.23168102' 0.99992902 Survey / DLS Computation Method: Vertical Section Azimuth: 104 Vertical Section Origin: lVD Reference Datum: 12/1 lVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: Minimum Curvature / Lubinski 295.590' N 0.000 ft, E 0.000 ft Rotary Table 56.00 ft relative to MSL 15.67 ft relative to MSL 24.933' 57645.880 nT 80.978' March 15, 2005 BGGM 2004 True North +24.933' Well Head . Comments RTE KOP Bid 1/100 Bid 3/100 700.00 10.00 297.45 642.31 698.31 29.58 29.60 13.64 -26.27 3.00 O.OOG 3.00 0.00 6031104.32 659797.02 N 70.49152407 W 148.69354404 800.00 13.00 297.45 740.29 796.29 49.51 49.53 22.83 -43.96 3.00 O.OOG 3.00 0.00 6031113.13 659779.14 N 70.49154917 W 148.69368865 900.00 16.00 297.45 837.09 893.09 74.53 74.57 34.37 -66.17 3.00 O.OOG 3.00 0.00 6031124.19 659756.68 N 70.49158069 W 148.69387027 1000.00 19.00 297.45 932.45 988.45 104.58 104.63 48.23 -92.86 3.00 O.OOG 3.00 0.00 6031137.47 659729.71 N 70.49161855 W 148.69408838 1100.00 22.00 297.45 1026.11 1082.11 139.58 139.65 64.37 -123.93 3.00 O.OOG 3.00 0.00 6031152.93 659698.29 N 70.49166264 W 148.69434241 1200.00 25.00 297.45 1117.80 1173.80 179.43 179.52 82.75 -159.31 3.00 O.OOG 3.00 0.00 6031170.55 659662.53 N 70.49171284 W 148.69463164 Top Perm 1234.57 26.04 297.45 1149.00 1205.00 194.31 194.41 89.61 -172.53 3.00 O.OOG 3.00 0.00 6031177.12 659649.17 N 70.49173159 WI48.694. 1300.00 28.00 297.45 1207.29 1263.29 224.02 224.14 103.31 -198.91 3.00 O.OOG 3.00 0.00 6031190.25 659622.50 N 70.49176902 W 148.694 1400.00 31.00 297.45 1294.31 1350.31 273.23 273.37 126.00 -242.60 3.00 O.OOG 3.00 0.00 6031212.00 659578.33 N 70.49183101 W 148.695 End Cry 1449.11 32.47 297.45 1336.08 1392.08 299.05 299.21 137.91 -265.53 3.00 O.OOG 3.00 0.00 6031223.41 659555.16 N 70.49186354 W 148.69549989 Base Perm 1665.93 32.47 297.45 1519.00 1575.00 415.40 415.62 191.57 -368.84 0.00 O.OOG 0.00 0.00 6031274.83 659450.73 N 70.49201011 W 148.69634441 SV6 3435.64 32.47 297.45 3012.00 3068.00 1365.07 1365.79 629.52 -1212.06 0.00 O.OOG 0.00 0.00 6031694.53 658598.35 N 70.49320629 W 148.70323795 Cry 3/100 3599.22 32.47 297.45 3150.00 3206.00 1452.85 1453.62 670.00 -1290.00 0.00 O.OOG 0.00 0.00 6031733.32 658519.56 N 70.49331684 W 148.70387517 13-3/8" Csg PI 3599.23 32.47 297.45 3150.01 3206.01 1452.86 1453.62 670.00 -1290.01 3.00 -129.59G -1.91 -4.31 6031733.32 658519.56 N 70.49331685 W 148.70387522 3600.00 32.46 297.41 3150.66 3206.66 1453.27 1454.03 670.19 -1290.37 3.00 -129.57G -1.91 -4.31 6031733.50 658519.19 N 70.49331737 W 148.70387821 End Cry 3698.12 30.66 292.96 3234.28 3290.28 1504.59 1505.37 692.08 -1336.79 3.00 O.OOG -1.83 -4.54 6031754.39 658472.31 N 70.49337714 W 148.70425772 SV5 3743.14 30.66 292.96 3273.00 3329.00 1527.52 1528.32 701.03 -1357.93 0.00 O.OOG 0.00 0.00 6031762.88 658450.99 N 70.49340159 W 148.70443052 SV4 4100.02 30.66 292.96 3580.00 3636.00 1709.31 1710.30 772.02 -1525.49 0.00 O.OOG 0.00 0.00 6031830.25 658281.95 N 70.49359544 W 148. 70580050 SV2 4555.72 30.66 292.96 3972.00 4028.00 1941.43 1942.67 862.67 -1739.45 0.00 O.OOG 0.00 0.00 6031916.27 658066.11 N 70.49384294 W 148.70754982 SVI 5010.25 30.66 292.96 4363.00 4419.00 2172.97 2174.45 953.08 -1952.86 0.00 O.OOG 0.00 0.00 6032002.07 657850.82 N 70.49408979 W 148.70929473 WellDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) NS28\NS28\Plan NS28\NS28 (P10) HA Generated 12/13/2004 2: 15 PM Page 1 of 2 Comments TMBK WSI CM3 Top HRZ Base HRZ Top Kuparuk 10113.58 30.66 292.96 8753.00 8809.00 4772.51 4776.73 1968.21 -4348.98 0.00 O.OOG 0.00 0.00 6032965.39 655433.60 N 70.49686021 W 148.72888878 TKUP C 10272.84 30.66 292.96 8890.00 8946.00 4853.63 4857.94 1999.89 -4423.76 0.00 O.OOG 0.00 0.00 6032995.45 655358.17 N 70.49694663 W 148.72950034 TMLV 10642.52 30.66 292.96 9208.00 9264.00 5041.94 5046.44 2073.42 -4597.33 0.00 O.OOG 0.00 0.00 6033065.23 655183.07 N 70.49714723 W 148. 73091990 9-5/8" Csg PI 10700.64 30.66 292.96 9258.00 9314.00 5071.55 5076.08 2084.98 -4624.62 0.00 O.OOG 0.00 0.00 6033076.20 655155.54 N 70.49717877 W148.73114311 Fault Crossing 11185.40 30.66 292.96 9675.00 9731.00 5318.47 5323.27 2181.41 -4852.22 0.00 O.OOG 0.00 0.00 6033167.70 654925.93 N 70.49744180 W 148. 73300465 Top Kingak 11256.31 30.66 292.96 9736.00 9792.00 5354.59 5359.43 2195.51 -4885.52 0.00 O.OOG 0.00 0.00 6033181.09 654892.35 N 70.49748027 W 148. 733. Top Sag 12359.51 30.66 292.96 10685.00 10741.00 5916.55 5921.97 2414.96 -5403.50 0.00 O.OOG 0.00 0.00 6033389.33 654369.81 N 70.49807878 W 148.737 7" Csg PI 12406.01 30.66 292.96 10725.00 10781.00 5940.23 5945.68 2424.21 -5425.33 0.00 O.OOG 0.00 0.00 6033398.11 654347.79 N 70.49810401 W 148.73769222 Cry 10/100 12441.08 30.66 292.96 10755.17 10811.17 5958.10 5963.57 2431.18 -5441.80 0.00 15.71G 0.00 0.00 6033404.73 654331.17 N 70.49812303 W 148.73782691 Top Shublik 12464.41 32.91 294. 12 10775.00 108:}1.00 5970.38 5975.86 2436.09 -5453.06 / 10.00 14.72G 9.65 4.98 6033409.40 654319.81 N 70.49813643 W 148.73791904 12500.00 36.36 295.65 10804.28 10860.28 5990.59 5996.08 2444.61 -5471.40 10.00 13.46G 9.70 4.28 6033417.52 654301.29 N 70.49815966 W 148.73806904 12600.00 46.14 298.86 10879.38 10935.38 6056.40 6061.92 2474.92 -5529.84 10.00 11.04G 9.78 3.21 6033446.56 654242.21 N 70.49824234 W 148.73854713 Top Ivishak 12600.90 46.23 298.88 10880.00 10936.00 6057.04 6062.57 2475.24 -5530.41 10.00 11.02G 9.82 2.65 6033446.86 654241.64 N 70.49824320 W 148.73855178 12700.00 55.98 301.16 10942.16 10998.16 6133.83 6139.60 2513.86 -5597.05 10.00 9.59G 9.84 2.30 6033484.05 654174.19 N 70.49834859 W 148.73909691 12800.00 65.85 302.98 10990.71 11046.71 6220.54 6226.88 2560.26 -5670.97 10.00 8.70G 9.87 1.82 6033528.84 654099.29 N 70.49847518 W 148.73970168 12900.00 75.74 304.53 11023.57 11079.57 6313.90 6321.20 2612.69 -5749.37 10.00 8.19G 9.89 1.55 6033579.57 654019.79 N 70.49861826 W 148.74034307 13000.00 85.64 305.95 11039.72 11095.72 6411.06 6419.76 2669.57 -5829.85 10.00 7.96G 9.90 1.42 6033634.71 653938.11 N 70.49877348 W 148.74100160 End Cry 13003.59 86.00 306.00 11039.98 11095.98 6414.58 6423.34 2671.68 -5832.75 10.00 O.OOG 9.90 1.39 6033636.75 653935.17 N 70.49877922 W 148.74102529 NS Target 3-1 HA 13290.59 86.00 306.00 11060.00 11116.00 6696.16 6709.64 2839.96 -6064.37 0.00 O.OOG 0.00 0.00 6033800.00 653700.00 N 70.49923844 W 148.74292045 OWC 13864.01 86.00 306.00 11100.00 11156.00 7258.78 7281.66 3176.19 -6527.15 0.00 O.OOG 0.00 0.00 6034126.18 653230.13 N 70.50015590 W 148.74670722 TO 14150.72 86.00 306.00 11120.00 11176.00 7540.08 7567.68 3344.30 ·6758.54 0.00 O.OOG 0.00 0.00 6034289.27 652995.20 N 70.50061460 W 148.74860073 Leqal Description: Northinq IV) fftUS! Eastinq IX) fftUS! Surface: 1318 FSL 648 FEL S11 T13N R13E UM 6031091.25 659823.57 Target: 4156 FSL 1430 FEL S10 T13N R13E UM 6033800.00 653700.00 . BHL: 4659 FSL 2124 FEL S10 T13N R13E UM 6034289.27 652995.20 WellDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) NS28\NS28\Plan NS28\NS28 (P10) HA Generated 12/13/2004 2: 15 PM Page 2 of 2 WELL NS28 (P10) MagneticParametefS Model: BGGM W04 4500 ;£ 0 0 l!) ~ ~ ~ II \3) (ij 6000 t> C/) 0 > ~ 10500 . Schlumberger . Northstar STRUCTURE Northstar PF Dip' 80.978" MagDe;: +24.933' SurlaœLocatiOl'l Lal N702929.352 Lon: W1484135.986 TVDRef: Rotary Table (56.00fl above MSL) Srvy Dale: December 06, 2004 NAD27 Alaska $tate Plafles. Zone 04. US Feet Northing' 6031091.25ftUS GridConv; "'1.23168102" Eastil1g 659623.57 flUS Scale Fact: 0.9999290163 MisceØanecus Slot: NS28 Plan: NS28 (P10) HA Dale' M8rd1 15,2005 FS; 57645.9nT o 1500 6000 7500 3000 4500 o , RTE ..,,,..,,,,,, ~~OP Bid 11100 ~ld3l100 \ /End Cry ~rrn '\ ,,~ ~ Cry 3/100 13·3/8'· Csg p( " '\ End Cry \ '\ \ \ 1\ \ \ '\ \ \ I\ase HRZ \;00 KUDaruk \\. Þv' ... ,\aK k~~J~~ \\ _7" Csg PI "- owe E ,d cr! .~ ..~ . ..,g...- HA TQ ./ o 1500 1500 3000 3000 4500 6000 7500 7500 9000 9000 10500 o 1500 3000 4500 6000 Vertical Section (ft) Azim = 295.59°, Scale = 1 (in):1500(ft) Origin = 0 Nt-S, 0 Et-W 7500 . . 4000 3000 2000 1000 o eroer L NS28 (P10) FIELD Northstar STRUCTURE Northstar PF - - Sllrfaceloc.a.tioo Miscellaneous ~""p~~"" Modal: BGG,::", Olp: ßQ.9n" Date: March 15,2005 Lat" N702929.352 Northir¡g: 6031091.25ftUS GridCOO\{: +1.23168102" I :::~: ~:~: (P10\HA TVD Ref: Rotary Table (56.00 !tabOVB MSl) MagDa<:" +24.933" FS 57645.9 liT Lon: W1484135.986 Easting 659823.57ftUS Scale Fact: 0.9999290163 S~œmber06,2004 - - - -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 - - T 4000 <'''''^^'' q"~' '''no'',,'''' "'" -f- 3000 ~ """ ' ."".",,,, ..... ".. !}t:""::" ^ ^ /" ^ _~,Þ0"> Z }Crv 10, 2" : 1" Cs, '> 0 0 2000 :;ng~<"" ~ 0 ~ ; , ~ 'cS¡'P! ~ II CD <ii ü (f) (f) V 1000 "", "''''''~'H , 1/8"FSg V V ~ 0 ""»·co,, ,.,>~"". «",,',,",.... - - ~ -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 «< W Scale = 1 (in):1000(ft) E »> . . Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumbørgør 2525 Gambell Street, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8357 Monday, December 13, 2004 Pat Archey Northstar NS28 (P10) BP Exploration Alaska Nabors 33E Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for eyery one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Proqram: Instrument Type GYD-GC-SS MWD MWD + IFR + MS Start Depth 40.43' md 1,000.00' md 1,000.00' md End Depth 1,000.00' md 2,400.00' md 14,150.72' md Close Approach Analysis results: Under method (2), all wells pass major risk rules: / Note: NS27 and NS29 passes the major risk rulesel. However, it is suggested the risk based 1 :200 ruleset be used for more room from tolerance lines during surface drilling. The closest point of tolerance for NS27, is at 450'md, with a 0.8' clearance. With risk based assessment 1 :200, it becomes 5.2' of clearance at a depth of 350'md. A tolerable collision risk worksheet will need to be filled out. The closest point of tolerance for NS29, is at 550'md, with a 2.2' clearance. With risk based assessment 1 :200, it becomes 7.3' of clearance at a depth of 300'md. A tolerable collision risk worksheet will need to be filled out. All data documenting these procedures is available for inspection at the Drilling and Measurements Directional Planning Center. Close Approach Drillinq Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 12/13/04 . BP Alaska Anticollision Report . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 40.43 to 14150.72 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/25/2004 Validated: No Planned From To Survey ft ft 40.43 1000.00 1000.00 2400.00 1000.00 14150.72 Versiou: 5 Toolcode Tool Name Planned: Plan #10 V1 Planned: Plan #10 V1 Planned: Plan #10 V1 GYD-GC-SS MWD MWD+IFR+MS Gyrodata gyro single shots MWD - Standard MWD + IFR + Multi Station Casing Points 3599.22 3206.00 13.375 16.000 133/8" 10700.64 9314.00 9.625 12.250 9 5/8" 12406.01 1 0781.00 7.000 8.500 7" 14150.72 11176.00 4.500 6.125 4 1/2" Summary Northstar PF NS05 Plan NS05 V2 Plan: Pia 445.32 450.00 230.89 8.55 222.33 Pass: Major Risk Northstar PF NS06 NS06 V34 397.99 400.00 221.23 7.39 213.83 Pass: Major Risk Northstar PF NS07 NS07 V33 149.87 150.00 211.16 3.11 208.05 Pass: Major Risk Northstar PF NS08 NS08 V18 349.13 350.00 200.57 6.35 194.21 Pass: Major Risk Northstar PF NS09 NS09 V14 445.84 450.00 194.98 7.71 187.27 Pass: Major Risk Northstar PF NS10 NS10 V17 494.23 500.00 173.55 8.12 165.43 Pass: Major Risk Northstar PF NS12 NS12 V28 398.33 400.00 155.08 7.72 147.36 Pass: Major Risk Northstar PF NS13 NS13 V13 446.51 450.00 153.93 7.95 145.98 Pass: Major Risk Northstar PF NS14 NS14 V11 10053.98 10400.00 260.95 239.10 21.85 Pass: Major Risk Northstar PF NS15 NS15 V19 447.41 450.00 132.11 8.10 124.02 Pass: Major Risk Northstar PF NS16 NS16 V39 496.12 500.00 120.07 9.40 110.67 Pass: Major Risk Northstar PF NS17 NS17 V12 3585.90 3850.00 139.98 95.20 44.78 Pass: Major Risk Northstar PF NS18 NS18 V14 2982.63 3100.00 147.82 108.83 38.99 Pass: Major Risk Northstar PF NS19 NS19 V17 398.59 400.00 88.70 7.35 81.35 Pass: Major Risk Northstar PF NS20 NS20 V8 497.91 500.00 80.89 8.49 72.40 Pass: Major Risk Northstar PF NS20 NS20PB1 V10 448.97 450.00 80.58 7.45 73.13 Pass: Major Risk Northstar PF NS21 NS21 V57 693.90 700.00 66.70 12.65 54.05 Pass: Major Risk Northstar PF NS22 NS22 V13 49.49 50.00 59.84 1.36 58.48 Pass: Major Risk Northstar PF NS23 NS23 V33 498.00 500.00 49.21 9.13 40.08 Pass: Major Risk Northstar PF NS24 NS24 V15 449.08 450.00 39.00 8.19 30.81 Pass: Major Risk Northstar PF NS25 NS25 V3 399.26 400.00 33.04 7.00 26.04 Pass: Major Risk Northstar PF NS25 NS25PB1 V9 399.26 400.00 33.04 7.00 26.04 Pass: Major Risk Northstar PF NS25 NS25PB2 V3 399.26 400.00 33.04 7.00 26.04 Pass: Major Risk Northstar PF NS26 NS26 V23 400.39 400.00 21.99 7.38 14.60 Pass: Major Risk Northstar PF NS27 NS27 V29 450.02 450.00 9.48 8.72 0.75 Pass: Major Risk Northstar PF NS29 NS29 V23 550.29 550.00 12.08 9.87 2.21 Pass: Major Risk Northstar PF NS31 NS31 V14 600.18 600.00 28.82 10.87 17.95 Pass: Major Risk Northstar PF NS32 NS32 V11 350.21 350.00 44.24 7.19 37.05 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 956.46 950.00 220.23 19.17 201.06 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02 VO 1009.09 1000.00 199.82 20.85 178.97 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 1008.42 1000.00 200.80 18.99 181.81 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 957.92 950.00 202.08 16.38 185.70 Pass: Major Risk Seal Island SEAL-A-04 SEAL-A-04 V4 912.83 900.00 248.89 17.05 231.84 Pass: Major Risk 147 100 50 50 100 147 Field: Northstar Site: Northstar PF Well: NS28 Wellpath: Plan NS28 27 e . NS23 (NS23) Travelling Cylinder Azimuth (TFO+AZI) (dcgJ vs Centre to Centre Separation [50ft/in] . BP Alaska Anticollision Report . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 40.43 to 14150.72 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 10/25/2004 Validated: No Planned From To Survey ft ft 40.43 1000.00 1000.00 2400.00 1000.00 14150.72 Version: 5 TooJcode Tool Name Planned: Plan #10 V1 Planned: Plan #10 V1 Planned: Plan #10 V1 GYD-GC-SS MWD MWD+IFR+MS Gyrodata gyro single shots MWD - Standard MWD + IFR + Multi Station Casing Points 3599.22 3206.00 13.375 16.000 13 3/8" 10700.64 9314.00 9.625 12.250 9 5/8" 12406.01 10781.00 7.000 8.500 7" 14150.72 11176.00 4.500 6.125 4 1/2" Summary Northstar PF NS05 Plan NS05 V2 Plan: Pia 445.32 450.00 230.89 8.55 222.33 Pass: Major Risk Northstar PF NS06 NS06 V34 397.99 400.00 221.23 7.39 213.83 Pass: Major Risk Northstar PF NS07 NS07 V33 149.87 150.00 211.16 3.11 208.05 Pass: Major Risk Northstar PF NS08 NS08 V18 349.13 350.00 200.57 6.35 194.21 Pass: Major Risk Northstar PF NS09 NS09 V14 445.84 450.00 194.98 7.71 187.27 Pass: Major Risk Northstar PF NS10 NS10 V17 494.23 500.00 173.55 8.12 165.43 Pass: Major Risk Northstar PF NS12 NS12 V28 398.33 400.00 155.08 7.72 147.36 Pass: Major Risk Northstar PF NS13 NS13 V13 446.51 450.00 153.93 7.95 145.98 Pass: Major Risk Northstar PF NS14 NS14 V11 10053.98 10400.00 260.95 239.10 21.85 Pass: Major Risk Northstar PF NS15 NS15 V19 447.41 450.00 132.11 8.10 124.02 Pass: Major Risk Northstar PF NS16 NS16 V39 496.12 500.00 120.07 9.40 110.67 Pass: Major Risk Northstar PF NS17 NS17 V12 3585.90 3850.00 139.98 95.20 44.78 Pass: Major Risk Northstar PF NS18 NS18 V14 2982.63 3100.00 147.82 108.83 38.99 Pass: Major Risk Northstar PF NS19 NS19 V17 398.59 400.00 88.70 7.35 81.35 Pass: Major Risk Northstar PF NS20 NS20 V8 497.91 500.00 80.89 8.49 72.40 Pass: Major Risk Northstar PF NS20 NS20PB1 V10 448.97 450.00 80.58 7.45 73.13 Pass: Major Risk Northstar PF NS21 NS21 V57 693.90 700.00 66.70 12.65 54.05 Pass: Major Risk Northstar PF NS22 NS22 V13 49.49 50.00 59.84 1.36 58.48 Pass: Major Risk Northstar PF NS23 NS23 V33 498.00 500.00 49.21 9.13 40.08 Pass: Major Risk Northstar PF NS24 NS24 V15 449.08 450.00 39.00 8.19 30.81 Pass: Major Risk Northstar PF NS25 NS25 V3 399.26 400.00 33.04 7.00 26.04 Pass: Major Risk Northstar PF NS25 NS25PB1 V9 399.26 400.00 33.04 7.00 26.04 Pass: Major Risk Northstar PF NS25 NS25PB2 V3 399.26 400.00 33.04 7.00 26.04 Pass: Major Risk Northstar PF NS26 NS26 V23 400.39 400.00 21.99 7.38 14.60 Pass: Major Risk Northstar PF NS27 NS27 V29 350.17 350.00 8.39 3.16 5.22 Pass: Minor 1/200 Northstar PF NS29 NS29 V23 299.83 300.00 9.89 2.61 7.28 Pass: Minor 1/200 Northstar PF NS31 NS31 V14 600.18 600.00 28.82 10.87 17.95 Pass: Major Risk Northstar PF NS32 NS32 V11 350.21 350.00 44.24 7.19 37.05 Pass: Major Risk Seal Island SEAL-A-01 SEAL-A-01 V4 956.46 950.00 220.23 19.17 201.06 Pass: Major Risk Seal Is/and SEAL-A-02 SEAL-A-02 VO 1009.09 1000.00 199.82 20.85 178.97 Pass: Major Risk Seal Island SEAL-A-02 SEAL-A-02A V4 1008.42 1000.00 200.80 18.99 181.81 Pass: Major Risk Seal Island SEAL-A-03 SEAL-A-03 V4 957.92 950.00 202.08 16.38 185.70 Pass: Major Risk Seal Is/and SEAL-A-04 SEAL-A-04 V4 912.83 900.00 248.89 17.05 231.84 Pass: Major Risk !- - --_._-_.__._-_._-_.~_.._.._-..._--_._...__.__._----_._---'----'------ ------.---..----.--..---.----------...-----------.------ Field: Northstar Site: Northstar PF Well: NS28 Wellpath: Plan NS28 147 100 50 27 NS23 (NS23) 50 100 147 Travelling Cylinder Azimuth (TFO+AZI) [dcgJ vs Centre to Centre Separation (50ftlinJ -------- ---._-- . . Site: Northstar PF I Drilling Target Conf.: 9 Yo Description: Map Northing: 6033800.00 ft Map Easting : 653700.00 ft Latitude: 70029'57.258N Shape: Circle Target: NS Target 3-1 HA .ell: NS28 Based on: Planned Program Vertical Depth: 11060.00 ft below Mean Sea Level Local +N/-S: 2839.96 ft Local +E/-W: -6064.36 ft Longitude: 148°44'34.514W Radius: 400 ft / /3500 34-00 3200 N 3000 2800 2500 24-00 2200 S 0 0 0 0 0 0 0 0 0 CJ 0 CJ 0 CJ 0 CJ § } LD J N 0 m LD J N / LD LD LD LD Lf) Lf) Lf) Ln ~ (J / I I I I I I I I / CJ / / / Target: NS Target 3-2 HA Site: Northstar PF I Drilling Target Con£: Yo Description: Map Northing: 6034289.27 ft Map Easting : 652995.20 ft Latitude: 70°30'02.2 I 3N Shape: Circle .ell: NS28 Based on: Planned Program Vertical Depth: 11120.00 ft below Mean Sea Level Local +N/-S: 3344.30 ft Local +E/-W: -6758.53 ft Longitude: 148°44'54.963W Radius: 400 ft 200 4-000 3800 3500 N 34-00 3200 3000 2800 2500 § 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ ! N 0 CO LD J N 0 m I I LD LD LD LD LD Ln / I I I I I I , I ~ (J / ~ / / TREE: ABB-VGI 5 1/S" 5ksi WELLHEAD: ABB-VGI13-5/S' Multibowl 5ksi 133/S", 68#/ft, L-80, BTC @ 3600' MD 41/2", 12.6#/ft, 13Cr-SO, Vam-T TUBING ID: 3.95S" CAPACITY: 0.01522 BBL/FT 9-5/8" 53.5# L-BO BTM-C @ 10700' M 4.5" X NIPPLE, @ 12170' MD 3.813" ID 4.5" X NIPPLE, @ 12215' MD 3.813" ID 4.5" XN NIPPLE, @ 12235' MD 3.725" ID 4.5" WLEG, @ 12255' M 3.958"1 7", 29#/ft L-SO, Hydril 521 @ 12406' MD PBTD @ 14070' TD @ 14150' MD DATE 1/18/05 REV. BY OTK NS28 - Proposed / A 1 ..- 6.8 ..... AT ... .. op - -- - D .... 4 3 I B ~ _7" . I~ I D -...-. ~ ~ D ~ -~ .. MD J ~ COMMENTS RIGINAL KB. ELEV = 56' KB-BF. ELEV = 40.1' CB. ELEV = 15.7' /2" TRSV @ 1000' TMD/TVD PPG DIESEL FREEZE PROTECTION +1- 3000' TVD (3350'MD) 4 1/2" GLM @ 4500' TVD (5100' MD) 7" LINER TOP @ 10550' MD .5" Fiber Optic Transducer .958" ID @ 12120' MD PACKER, 13 Cr @ 12190' MD 4.5" LINER TOP @ 12256' MD 4.5", 12.6#, 13Cr-80 Yam Top Northstar WELL: NS28 API NO: BP Exploration (Alaska) . . SONORA 0 STEWMAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 121 "Mastercard Check" PAY TO THE L/ÄJ-ì( C. (l ORDER OF -./ ~ .... ~ DYVJ~2:\ÀX\Ch·"eð.- ÒJ\...6 _ ~~- - DOLLARS First Nationa nk Alaska Aoohm'g,. AK, 99501 á _ ~ MEMm~ 0 --Ct Sk.- DA TE 01 ~ 0 ~ -C)l:) I $lCO·OD I: ~ 25 2000bOI:~~ ~~lIlb 2 27111 ~5b~lI· 0 ~ 2 ~ . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME .£,~ .2. g PTD# ZcJS"-o/?:" X Development Service Exploration Stratigraphic CHECKWßAT ADD-ONS ~'CLUE n. APPLŒS (OPTIONS) MULTJ The permit is for a Dew weUboresegment of LATERAL existing weD -" Permit No, API No. . (If APJ number Production.sbould continue 10 be reponed as last two (2) digits a fUDction ·of tbe original API number. stated are between 60-69) above. PD...OT HOLE In accordance with 20 AAC 25.005(1), an (PH) records, data and logs acquired for the piJot bole must be dearly differentiated In both name (name OD permit plus PH) .. aDd API number (50 - 70/80) from records, data and logs acquired for wen (Dame on permit). SPACING Tbe permit is approved subject ·to fun EXCEPTION compliance witb 20 AAC 25..055~ Approva) to perforate and produce is contingent upon issuance of ~ conservatioD order approving a spa dng ex reptioD. (Company Name) assumes tbe Jiability of any protest to tbe spacing .exceptioD tbat may occur. : DRY DITCH AlJ dry ditcb sample sets submitted to tbe SAMPLE Commission must be iD no greater ·tbaD 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample ilÍter:va)s tbrough target zopes. .. PTD#: 2050160 Administration Unit Program DEV On/Off Shore On Well bore seg Annular Disposal Appr Date RPC 2/7/2005 Engineering Appr Date WGA 2/8/2005 Geology Appr RPC Date 2/7/2005 Geologic Commissioner: 'PTS Field & Pool NORTH STAR, NORTH STAR OIL - 590100 Well Name: NORTH STAR 28 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV 11-01L GeoArea 1 PermiUee attaçhed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _Lease_number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _Unique welln_ame_a!1d lJu.mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - 4 Well located in a d_efinedpool _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WelUocated pr_opeLdistance_ from driJling unitb9und~lI:Y _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WelUocated proper _distanceJrom otber welJs _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ 7Suffiçientaçreag.e_aYailable indrillilJg unJt _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 8 Ifdeviated, Js_ weJ I bore platincJu_ded _ _ _ _ _ Yes _ 9 Operator onl}' affeçted party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 10 _Oper_ator bas_appropriate_b.ond inJorce. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Permit c:a!1 be issued witbout conservation order _ _ _ Yes _ _ _ _ _ 12 Permitc_a!1 be issuedwitbout ad_ministratÎlleapproval _ _ _ _ _ _ _ _ _ _ No_ 13 Can permit be approved before 15-day wait Yes 14 WeJUocated within area and_strata _authorized by IlJjectiolJ Order # (putlOil in_comments) (For NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 AJI weIJs_withiJUl4JlJile_are.a_of reyieW idelJtified (Forservjcewell onlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre.-produçec! injector; duration of pre-production less than 3 months_ (For_se "\lice well onJy) _ _ NA _ _ _ _ _ _ 17 ACMPFïndingof Con_sistencyhas been issued fortbis pr9ject _ _ NA _ _ _ 18 _C9nductor string provided _ _ _ _ _ Yes _ 19 _S_urface casing pJotects altknown USQWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ 20 CMTv_oladequ_atetocirculate on_cond_uctor_&suJfcsg _ _Yes _ _ _ _ _J\c!e~uateexcess,- 21 _CMT v_ol adequateto tie-in long _string to_surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ No_ 22 _CMTwilJ coyer_aJll<nownpro_ductiye borizons_ _ Yes 23 _C_asing de.signs adeClua_te for CoT, B&permaf[ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 24 Adequate tankage_oJ re_se "\le pit _ _ Yes _ Nab_o/"S_3_3L 25 Ifare-drilt has_a_ tOc403 for abandonme_nt beelJ approved _ NA _ _ _ _ _ _ New welL _ 26 _AdequateweJlbore. separatJo_n_proposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdivecter req_uire.d, does itmeet reguJations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ Wajyerrequested. _ 28 DriUingf]uidprogramschematic&equiplistadequate_ _ _ _ _ _ _ _ _ _ Yes_ _MaxMW12.6ppg. 29 _BOPEs,_d_othey meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 30 _BOPEpress rating appropriate;testto(put psig in_comments)_ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Test toA500_psLMSf> 398<1 psk 31 _CMke_manifold conJRlies w/APt Rf>-53 (May 54) _ _ _ _ _ _ _ _ _ _ _ _ Yes 32 Work will occ_ur withoutoperation _shutdown_ _ _ _ _ _ _ _ _ _ Yes_ 33 Is presence_ of H2S gas prob.able _ _ _ _ . _ _ _ _ _ _ _ _ No _ _ 34 Mecha_nicatCOlJdjlion of wells within J\OR verified (For_s_eNice weU onJ}') _ _ _ _ _ _ _ NA - ~ - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - 2Q" @ 2QO'. _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . NoLan H2S pad. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Permit can be issued wlo_ hydrogen_ sulfide meaSJJres _ . _ _ _ _ _ _ _ _ 36 _D_atapreseoted on pote_ntial oveJpressure _zones _ _ _ _ _ _ _ _ _ _ _ . 37 _SeLsm[c_analysjs of sballow gas_zolJes_ _ _ 38 _Seabed wnditioo survey (if off-sh_ore} . . 39 _ Contact namelphoneJor_weelsly progress reports [exploratory _onlYl _ _ _ . _ _ _ _ _ _ No_ .NA _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _NA .NA _ _ _ _ _N_A _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: :7'ly~ Date Date 2-/ f/ S D . .
