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202-141
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-18 NORTHSTAR UNIT NS-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 NS-18 50-029-23102-00-00 202-141-0 G SPT 8709 2021410 3500 4772 4776 4775 4777 19 40 46 51 REQVAR P Kam StJohn 12/14/2025 MIT-IA 1 year to min 3500 psi per AIO 23.005 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-18 Inspection Date: Tubing OA Packer Depth 1666 3900 3878 3875IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS251214120508 BBL Pumped:7.3 BBL Returned:7.1 Friday, January 16, 2026 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Sunday, January 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-18 NORTHSTAR UNIT NS-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2025 NS-18 50-029-23102-00-00 202-141-0 G SPT 8709 2021410 3500 4323 4327 4328 4327 15 125 138 148 REQVAR P Austin McLeod 12/14/2024 Annual to 3500psi. AIO 23.005. 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-18 Inspection Date: Tubing OA Packer Depth 1475 3656 3627 3616IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM241215182254 BBL Pumped:8.9 BBL Returned:5.8 Sunday, January 26, 2025 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.26 23:05:59 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-18 NORTHSTAR UNIT NS-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/22/2024 NS-18 50-029-23102-00-00 202-141-0 G SPT 8709 2021410 3500 4676 4675 4676 4675 35 78 89 96 REQVAR P Brian Bixby 12/12/2023 MITIA as per AIO 23.005 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-18 Inspection Date: Tubing OA Packer Depth 1275 3662 3639 3632IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB231212161930 BBL Pumped:9.2 BBL Returned:8.8 Monday, January 22, 2024 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC NS-18 NORTHSTAR UNIT NS-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 NS-18 50-029-23102-00-00 202-141-0 G SPT 8709 2021410 3500 4761 4759 4766 4762 62 148 151 155 REQVAR P Adam Earl 12/12/2022 MIT-IA tested as per AIO 23.005 to 3500psi. 30 MinPretest Initial 15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name: NORTHSTAR UNIT NS-18 Inspection Date: Tubing OA Packer Depth 1495 3699 3646 3626IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE221214093812 BBL Pumped:10.9 BBL Returned:7 Thursday, January 26, 2023 Page 1 of 1 MIT-IA tested as per AIO 23.005 to 3500psi. MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 29, 2021 SUBJECT: Mechanical Integrity Tests I ilcorp Alaska, LLC NS -18 NORTHSTAR UNIT NS -18 Src: Inspector Reviewed By: P.I. Supry - w— Comm Well Name NORTHSTAR UNIT NS -18 API Well Number 50-029-23102-00-00 Inspector Name: Brian Bixby Permit Number: 202-141-0 Inspection Date: 12/4/2021 Insp Num: mitBDB211205043854 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS -18 •I,'I'ype Inj G ' TVD 8709 Tubing 4760 4760 4760 4760 PTD 202144 Type Test sPT' Test psi 3500 - IA 1855 - 3696 - 3683 3681 g10 BBL PumpedBBL Returned: 7-5 OA 61 130 _ 146 - 161 Interval REQVAR P/F P - Notes' MITIA as per AIO 23.005 ✓ Wednesday, December 29, 2021 Page 1 of 1 From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: Northstar well NS-18 (PTD# 202141) IA repressurization Date:Monday, October 25, 2021 9:16:00 AM Attachments:image001.png image003.png image004.png From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, October 20, 2021 3:44 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: Northstar well NS-18 (PTD# 202141) IA repressurization Mr. Wallace, Gas injector NS-18 (PTD#202141) was found upon review of long- term annulus pressure trends to show signs of slow TxIA communication when on injection. The last AOGCC witnessed MIT-IA was conducted on 2/7/2019 which passed to 2429 psi. We currently plan to leave the well on injection to aid in diagnostics. Annulus pressures will be maintained under MOASP while diagnostics are performed, if the IA pressure cannot be managed with periodic bleeds the well will be shut-in. Plan forward: 1. PPPOT-T 2. Monitor for continued repressurization post tubing hanger diagnostics. 3. Request Administrative Approval for continued gas injection with slow TxIA communication as necessary. Please contact me with any questions or concerns. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above,then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systemsor 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS MAR 4 1 2019 A 1. Operations Abandon LJ Plug Perforations LJ Fracture StimulateLJ Pull Tubing Operations shutdown Ll Performed: Suspend ❑ Perforate ❑ Other Stimulate[--] Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: Convert to Gas Injector ❑� 2. Operator Name: Hilcorp Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ 202_141 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6. API Number: AK 99503 50-029-23102-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0312799 NORTHSTAR UNIT NS -18 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A NORTHSTAR / KUPARUK OIL 11. Present Well Condition Summary: Total Depth measured 16,865 feet Plugs measured 16,856 feet true vertical 11,117 feet Junk measured N/A feet 13,874, 14,471, Effective Depth measured 16,856 feet Packer measured 16,323 & 16,362 feet 8,666, 9,089, true vertical 11,109 feet true vertical 10,615 & 10,650 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 4,033' 13-3/8" 4,033' 3,207' 5,020psi 2,260psi Production 14,668' 9-5/8" 14,668' 9,234' 6,870psi 4,760psi Liner 2,070' 7" 16,541' 10,815' 7,240psi 5,210psi Liner 503' 4-1/2" 16,865' 11,117' 8,430psi 7,500psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6/ 13CR/ VAM-TOP 13,915' 8,710' Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6/ 13CR/ VAM-ACE 16,362' 10,650' 9-5/8" x 4-1/2" S3 9-5/8"x7" Liner Top 7"x4-1/2" Baker S-3 989' MD Packers and SSSV (type, measured and true vertical depth) 7"4" Liner Top TRM-5E SSSV See Above 986' 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 0 978 34 Subsequent to operation: 0 81,020 Injection 0 649 1 4,750 14. Attachments (required per 20 AAC 25.070, 25.011, & 25.283) 15. Well as after work: Daily Report of Well Operations ❑' Exploratory ❑ Development ❑ Service ❑' Stmtigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑� SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-412 W LXContact Authorized Name: Bo York Name: Wyatt Rivard Authorized Title: Operations ManKnag'err/ Contact Email: wrlyard(Whilcorp.cOm Authorized Signature: w�f�— W [V/ Date: 3/11/2019 Contact Phone: 777-8547 onn V X Wq 5 , _ 3 Zo -/1 na1J1V10jL^~ MAR 1 Z 2019 ouunm vngmammy K !cora Almka, LLC IB Elev.: 55.85'/ BF aw..: 39.9(0815.9') TD=16,865' (MD) / TD=11,117'(TVD) FETID=16,856' (MD) / PBTD=11,109'(TVD) Schematic Northstar Unit Well: NS -18 Last Completed: 8/21/2016 PTD: 202-141 TREE & WELLHEAD Tree ABB-VGI 5-1/8" 6.SKSI Wellhead ABB-VGI13-5/8"Multibowl SK51 OPEN HOLE / CEMENT DETAIL 13-3/8" 669 sx PFT, 472 sx Class'G' in 16" Hole 9-5/8" 794 sx Econolite, 564 sx % In a 12-1/4" Hole 7" 325 sx Class "G" In 8-1/2" Hole 4-1/2" 93 sks Class "G" In 6-1/8" Hole CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm 20" Conductor 169/X-56/N/A N/A Surface 201' 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' 7" Production 26/ L-80/ Hydril 521 6.276 14,471' 16,541' 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' TUBING DETAIL 4-1/2" Tubing T2.6/13CR/VAM-TOP 3.958 Surface 13,915' 4-1/2" Tubing 12.6/ 13CR/ VAM-ACE 3.958 16,317' 16,362' WELL INCLINATION DETAIL KOP @ 351' Max Hole Angle - 59 deg. @ 3,590' Angle at Top Perf= 47 Deg. @ 14,195' JEWELRY DETAIL No IDepth I Item 1 989' 41/2" TRMAXX-SE SSSV w/ X Profile ID= 3.813" Date Status GLM Detail - MMG 13cr w/ RK Latch 2 3,913' ST 3: Port= 0, Dev. 55, VLV= DMY, ND= 3,137', 8/8/2016 3 8,544' ST 2: Port=O, Dev: 57, VLV=DMY, TVD- 5,658,8/8/2016 4 1 11,965' 1 ST 1: Port= 0, Dev. 56, VLV= DMV, TVD= 7,557', 8/8/2016 5 1 13,858' 1 4.5"X Nipple - ID= 3.813' 6 13,874' 9-5/8"x41/2" Baker S3 Packer 7 13,895' 4.5"X Nipple - ID= 3.813" 8 13,908' 4.5"XN Nipple - ID= 3.725" 9 13,915' WLEG - Bottom @ 13,916' 10 14,471' 9-5/8" x 7" Baker ZXP Liner Top Packer 11 14,490' 9-5/8" x 7" Baker Uner Hanger 12 16,323' 7" x 4-1/2" Baker 5-3 Packer, ID- 3.875" 13 16,347' 4-1/2" HES X Nipple, ID- 3M3 14 16,358' 4-1/2" HES XN Nipple, ID= 3.725" (16,350' ELM) 15 16,362 7"x5" Baker ZXP Uner Top Packer 16 16,369' 41/2" Bkr Model W Ratcheting Muleshoe, ID= 3.5" 17 16,384' 9-5/8" x 7" Liner Hanger 18 16,750' 1 CIBP PERFORATION DETAIL Sands Top (MD) IBtm (MD) Top (TVD) Btm (TVD) FT Date Status :up CSands 14,202' 14,262' 8,901' 8,941' 60 12/18/16 Oen ip A3 Sands 14,338' 14,358' 8,994' 9,008' 20 10/18/16 Open jp A2 Sands -Sands 14,390' 14,420' 9,031' 9,052' 30 10/18/16 Open sp Al 14,436' 14,456' 9,064' 9,078' 20 10/17/16 Open AS Sands 14,456' 14,476' 9,078' 9,093' 20 10/17/16 Open Ishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed ishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed GENERAL WELL INFO API: 50-029-23102-00-00 Drilled & Cased by w/ Nabors 33E -1/5/2003 Original Completion w/ Nabors 33E -1/15/2003 Perforate w/ Nabors 33E-1/22/2003 Add Perforations -12/8/2005 Add Perf & Complete w/ASR41 - 8/21/2016 Revised By: TDF 3/11/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS -18 Pumper 50-029-23102-00-00 202-141 1/19/2019 3/8/2019 Daily Operations. 1/16/2019- Wednesday No activity to report. 1/17/2019 - Thursday No activity to report. 1/18/2019 - Friday No activity to report. 1/19/2019 -Saturday Set 5" 2 way check. ND Producer tree. NU new 5-1/8" 6,500 tree in Injector orientation. Bleed IA from 1,000 psi to 35 psi. ND 13-3/8 x 5-1/2 adapter and tree and index to injector position. Noted small leak at control line swagelock fitting at the NPT thread. Tightened same and bubbles stopped. Retightened swagelock cap and noted bubbles. Tightened cap and bubbles stopped. MU adapter/tree assy. test Tbg Hgr void to 4,000 psi. Test tree with 4,800 psi gas. -PASS. RU lubricator and pull 2 way check. 1/20/2019 -Sunday No activity to report. 1/21/2019 - Monday Successful AOGCC witnessed pre injection MIT -IA to 2,258 psi following conversion to gas injector. 1/22/2019- Tuesday No activity to report. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS -18 Daily Operations. Pumper 50-029-23102-00-00 202-141 1/19/2019 3/8/2019 2/6/2019 - Wednesday No activity to report. 2/7/2019 - Thursday Successful AOGCC witnessed MIT -IA with well on injection to 2,429 psi following conversion to gas injector. 2/8/2019 - Friday No activity to report. 2/9/2019 -Saturday No activity to report. 2/10/2019 -Sunday No activity to report. 2/11/2019 - Monday No activity to report. 2/12/2019 -Tuesday No activity to report. rp Alaska, LLC perations Summary Well Name jWeek rmit Number Start Date End Date NS -18 3102-00-00 202-141 1/19/2019 3/8/2019 Daily Operations. 3/6/2019 - Wednesday No activity to report. 3/7/2019 - Thursday No activity to report. 3/8/2019 - friday Shut master and bleed off tree. Noted 3,200psi on tubing. 500psi on IA. RU lubricator and install 5" "H" 2 way check. Test tree to 250psi low for 5 mins-PASS. Test to 6,500psi for 5 min. --PASS. Bleed tree down to 2,800psi and test Tbg Hgr void to 250psi low -PASS. Increase pressure incrementally to 6,000psi. Held good for a minute. Increase pressure to 6,500psi Held for a few seconds and then bled back to 3,000. Could not get back to 6500psi.Tried 5,000psi buck kept bleeding back. Tried 4K but kept bleeding back. Slowed down at 3,200psi but slowly bled to 1200psi over 45 minutes. Noted a leaking control fitting earlier this year and tightened but this is likely leak path. 6,500psi tree test shows that tubing neck seals are good and there is no TxIA communication. 3/9/2019 -Saturday No activity to report. 3/10/2019 -Sunday No activity to report. 3/11/2019 - Monday No activity to report. 3/12/2019 -Tuesday No activity to report. Schwartz, Guy L (DOA) From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Friday, March 8, 2019 11:41 AM To: Schwartz, Guy L (DOA) Subject: RE: [EXTERNAL] RE: NS -18 (PTD # 201410) Retest of Newly Converted Injection Tree Guy, Thank you for the approval to retest. We have begun addressing this with our field crews to ensure consistent tree testing and adherence to test pressures listed in the Sundry. Thank You, Wyatt Rivard I Well Integrity Engineer IHilcorp Alaska, LLC 0: (907) 777-8547 I C: (509)670-80011 wrivard0hilcorn.com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, March 08, 2019 11:11 AM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: [EXTERNAL] RE: NS -18 (PTD # 201410) Retest of Newly Converted Injection Tree Wyatt, I see the oversite now ... go ahead and test tree and tbg hanger voids as per Sundry #318-412 to 6500 psi and report in the 10-404. The field crews should have had a copy of the sundry procedure so not sure how it got missed or mis interpreted. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 intormation. 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 Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska,,gov). From: Wyatt Rivard <wrivard(�hilcoro.com> Sent: Friday, March 8, 2019 10:35 AM To: Schwartz, Guy L (DOA) <Ruy.schwartzCalalaska.eov> Subject: NS -18 (PTD # 201410) Retest of Newly Converted Injection Tree Hello Guy, While preparing the 10-404 to close out the NS -18 (PTD # 2021410) conversion to gas injection sundry #318-412 (attached), we discovered an inconsistency in the pressure testing performed on the tree with respect to what we had planned to test to in the sundry. Instead of testing to the uprated working pressure of the tree (6500 psi) we tested to the gas injection pressure (4800 psi). The well had a passing witnessed MIT -IA on 2/7/19 and has maintained a —4000 psi TxIA differential since initial injection (TIO Plot Attached). The tree had previously been tested to 9750 psi (1.5x WP) as part of the manufacturer's uprating and again to 6500 psi during previous use on well NS -13. Within the next week and prior to closing out the Sundry, we plan to rig back up to the well, set a two way check, and retest the tree to 6500 psi. Please let me know if this is acceptable or if you have any questions. For reference, here is the WSR entry from the tree swap 1/20/19: "Set 5" 2 way check. ND Producer tree. NU new 5 1/8" 6500 tree in Injector orientation. Bleed IA from 1000 psi to 35 psi. ND 13 3/8 x 5 1/2 adapter and tree and index to injector position. Noted small leak at control line swagelock fitting at the NPT thread. Tightened same and bubbles stopped. retightened swagelock cap and noted bubbles. Tightened cap and bubbles stopped. MU adapter/tree assy. test Tbg Hgr void to 4000 psi for 10 min --PASS. Test tree with 4800 psi gas. - PASS. RU lubricator and pull 2 way check" And these are the relevant steps from the Sundry. t, Pressure test the uce to 250psi low for 5 minutes (stabilized) and 650Opsi for 5 minutes (stabilized). a. Stab into and monitor the tubing hanger test void to ensure the neck seals are intact while conducting, the pressure test of the tree. 7. Bleed the pressure in the tree to 1500psi. Pressure test the Tubing Hanger Void to 6500psi. a. Do not exceed 15O0psi on the tubing (tree side) and 650Opsi on the hanger void. The combined load can cause damage to the load shoulder on the tubing hanger. b. Do not allow the tubing hanger void pressure to exceed a 50O0psi differential over the tubing pressure. the tubing neck seal is a flex seal and has a rating of 5000psi differential frorn below. c. Bleed all pressure off the tubing hanger void and the tree. Thank You, Wyatt Rivard Well Integrity Engineer IHilcorp Alaska, LLC , � f'W- i ---8547 1 C: (509)670-80011 wriyarclPhilcorp com 3800 Centerpoint Drive, Suite 1400 1 Anchorage, AK 99503 E MEMORANDUM State of Alaska Inspection Date: 2/7/2019 Alaska Oil and Gas Conservation Commission To Jim Regg Il fes' I DATE: Friday, February 15, 2019 P.I. Supervisor q SUBJECT: Mechanical Integrity Tests NS -18 2021410 HILCORP ALASKA LLC 8683 Tubing, zrn _ IA NS -I8 FROM: Bob Noble NORTHSTAR UNIT NS -18 Petroleum Inspector Src: Inspector z Reviewed By: 2 P.I. SuprvZ2 414 NON -CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS -18 API Well Number 50-029-23102-00-00 Inspector Name: Bob Noble Insp Num: mi[RCN190207164813 Permit Number: 202-141-0 Inspection Date: 2/7/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PTD NS -18 2021410 Type Inj G ^TVD Type Test' SPT Test )Sil 8683 Tubing, zrn _ IA 4811 - F las? 4807 7443 - 4805 2430 7476 BBL Pumped: z BBL Returned: 2 OA 414 458 - 468 474 - Interval_ INITAL iP/F Notes: Friday, February 15, 2019 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �I DATE: Thursday, January 24, 2019 P.I. Supervisor y �i I� SUBJECT: Mechanical Integrity Tests (( HILCORP ALASKA LLC NS -18 FROM: Bob Noble NORTHSTAR UNIT NS -I8 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Suprv�_ NON -CONFIDENTIAL Comm Well Name NORTHSTAR UNIT NS -I8 API Well Number 50-129-23102-00-00 Inspector Name: Bob Noble Insp Num: mi[RCN190122172850 Permit Number: 202-141-0 Inspection Date: 1/22/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NS-18Typelnj N TVD 8683 Tubing 2171 2170 2170' 2170 2170 2171 ' PTD 2021410 --' Type Te$ St PT LTest psi 7171 IA 837 2252 • 2255 " r 2253 2257 2258 BBL Pumped: li 5.8 1IBBL Returned: 4.2 OA 8 — 8 8 s 9- 9 Interval INITAL -ip/F P v Notes: Initial MIT -IA following toner-" to gas infector. 175 barrels of cold diesel on 1-21-19 to load the L4. Thursday, January 24, 2019 Page I of I 6R. Hilcorp Alaska, LLC Post Office Box 244027 Anchorage,AK 99524-4027 3800 Centerpoint Drive Suite 100 Anchorage,AK 99503 Phone: 907/777-8300 Fax: 907/777-8301 11/13/17 RECEIVED Ms. Cathy Foerster Chair, Commissioner NOV 15 2017 Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue,Suite 100 Anchorage,AK 99501-3572 ®GCC RE: Well Status Report of NS08,NS18 and NS15 Kuparuk Formation Testing Dear Commissioner: As requested in the AOGCC's letter of March 17, 2010 attached are the 10-409s containing the NS08,NS18, and NS15 Kuparuk Formation well tests acquired for the period of July 1St,2017 to September 30`h,2017. The NS15 came on production August 28th,2017,well testing commenced at that point. Should you have any questions,please contact Wyatt Rivard at (907) 777-8547. Sincerely, SCANNED Leanne Watkins Production Analyst,North Slope I. - D Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z. 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CD A J W 6) N A Cb O 0 J i0 iD O 01 - A J W w A J J cO ib • W 0 N co co O N co OD CT J 01 A CO j CO 01 co co Ut co W 0 CO 0 CO A 0 N V CO A CO N CO V CO N OD co N A co CO CO CO 0- 0 0 co CA co A V V CO A V CO A V A -. (T co CT W W pO aD A V V • C O OD A Cn A CO Zo z - 1 '( 1 8/18/17 Ms. Cathy Foerster . 116 2 Chair, Commissioner 21 Chair, ,7 Alaska Oil and Gas Conservation Commission 333 W. 7`''Avenue, Suite 100 Anchorage,AK 99501-3572 RE: Well Status Report of NS08 and NS18 Kuparuk Formation Testing Dear Commissioner: As requested in the AOGCC's letter of March 17, 2010 attached are the 10-409s containing the NS08 and NS18 Kuparuk Formation well tests acquired for the period of April 1st,2017 to June 30th, 2017. Should you have any questions,please contact Wyatt Rivard at (907) 777-8547. Sincerely, SCANNED AUG 2 3 2017 Leanne Watkins Production Analyst, North Slope )O C — N COM 00 CO V' N O n t` S O O CO• V• CO 00 V' N 76 Lo V' CO M '- O O CA V• `s 1° 0 • M � 4 O u) u) O 0 V N O • L.L. M CO M M CO V' . V' V' V" V' U- (.) U N CO CO V• O) 0 CA CO N O O) r N V' CO M CO V' N CO V' N 10 CO O 10 CO ‘-•L-- _ 0 C- CO N tg me L.'^"., N V' V' d• V' V' d• V' V' V' V' V- V' 0 Yom'-- `4 ' L" ocienta P""• YiCD 6 R N ` (6 z z z•Lt z•CC z z z z z z Q z 6M/3 (;� Z Z Z Z Z Z Z Z Z Z Z Z rn c • . 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N N J • o a) -, r cq C O V) a Z LL 0 V co r-- Ti. as• .. a) 3 o v i o o) 0) a) m ii Z CC < 2 m o < T./50 N- nnnr- nFF- nnr- n 2 C J H N N N N N N N N N N N N .OT E J 0 v v vv. r M C\ V- v CO ,- M LU a) _ _ CD _N st --- LO N_ N O ca ° O a) N .. C L �XX L O U Oo 0 0 0 o o o 0 0 0 0 0 `CC ` CM -°45 1 O O O O O O O O O O O O '00 0 to 0 0 0 0 0 0 0 co 0 0 0 0 01 E 0 0 0 0 0 0 0 0 0 0 0 0 O C N co co co co co CO N N N N N N U O Y Q LL 0 0 CO CO CO 0 0 0 0 0 0 0 Cp 7 ' Q co co co co co co co co co CO C+) CM C > co Qi N N N N N N N N N N N (.1 " > O) 0) 0) CA 0) C7) 0) CY) 0) CA 0) 0) O) '00 N N O N N N N N N N N N N N N N O C 0) C N O O O O O O O O O O O O O E C • N L OOOOOOOOOOOO OO r- ) 0 CCC0 )0 CO C) C) O co > 3 whi Et O >. C 0 c 3 rn J • Z N w. Z C C V' °_ C O0) CO O ' _. i-/-) O CU < O O N C J d -c f Q N O d d O LL c Z d 8 LL O Cr y N — T co 0 2 O 7 0 0 0 0 0 0 CO 0 0 CO 0 0 N 2 0 2- Q M ZZZZZZZZZZZZ — Q • • 2_ \ \ Hilcorp Alaska, LLC RECEIVED Post Office Box 244027 Anchorage,AK 99524-4027 MAY 12 2017 3800 Centerpoint Drive f1 A OGCC Suite 100 Anchorage,AK 99503 Phone:907/777-8300 Fax:907/777-8301 5/11/17 Ms. Cathy Foerster Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7'Avenue, Suite 100 Anchorage,AK 99501-3572 RE: Well Status Report of NS08 and NS18 Kuparuk Formation Testing Dear Commissioner: As requested in the AOGCC's letter of March 17, 2010 attached are the 10-409s containing the NS08 and NS18 Kuparuk Formation well tests acquired for the period of January 1St,2017 to March 31t'', 2017. Should you have any questions,please contact Wyatt Rivard at (907) 777-8547. Sincerely, scANNE® .1 .�! . illt/ /AV- Leanne Watkins Production Analyst,North Slope • • = • - O ) •N N 7 M N- LO N N U) M 0 • N CO O _M 7 CO L- (0 M Cfl tf) 50 -T2 7 N- co M CO M O M O 7 U) CO M CO N (A r N O m D) M a0 U) O N C) M 7 f� CO C)) N W (A M CO Q3 '..= •-;._ . N CT N N CO N M r M 7 N O CO O C6 Ll M co CC M M co CO CO r f� W WO N M M O to W M C'M M C) CM 7 C) M 7 7 M 7 M L.L. () O CO 7 7 N N CO M O N 7 (O CO I- N- Cn CO N • O CO CO 7 N M CO O) 7 Ci M M7 7 N Co CO Cf) 7 M x- rA O O O C) CT N CO 7 7 N- h CO 7 M M C) N N N U) U) U) U) 7 7 7 7 7 7 7 7 7 7 7 7 7 7 O ':• ,,, < < < < < < < < < < < < QQ ¢ a ¢ aa m O z 'Z z z z z z z z z z z z z z z z z z H O CC') N O CO U) CO r Cn O CO M N- CD 7 CA 0 7 0 00 N m CO 7 CM 7 N N CO M O O N ? CO N M O ) CO U) C - 7 7 7 7 7 7 r N N N N r r N- O O O O O O O U 7 O .? 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Should you have any questions,please contact Wyatt Rivard at (907) 777-8547. Sincerely, ` Leanne Watkins Production Analyst,North Slope • — 7 • M to CO U) N- V O C) O M coMO M O f0 co coo a) O N • O O m O M CO o r op co V co co CO 0) N n W r V coMVV N CO C6 •- ,— V O M CO _ N V co co co V n CA n CO a' Ll Com`) M M CO COVCOVr CO CO a) O O co CO ca M M M co co4 cci Mco`oM Co) co coVCc) L.L. 0 n CO 0 CO n n CO N CD CO n CO n CO CO 0 O) CO CO CO CO n M 2 CO n M n v U) CA v CO 0 n N _O C) 0 it) Co O M co CC) at (0 n M0 N N n CO n U) M C) O CO O CO CO CO CO CA CO V CO CC M CO C) N- n CO CD CC) O 0 CO CO CO CO CA O) CO CA CO CO CO CO CO CO CO N CO M CO CO) f') Cc) Cc) M C) C) ') (7 a V. lir Er FO- • (,� Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z co C O N N- O CO CO M r•I▪ L O O O CA M r O CO n N O O N M n O N C CO CO CO M V V V vO•) CA N n (T CO CO CO COCCO CO On) OM) O O O Q U 7 io 2 -' C`') C') M co M C') n n N- n n n n n n n n n n n n n n n n d N (O CO CO CO (VO� CO 0 0 0 co co O co O co co co O O O O co co O O CO coVco co CO C() co co C() co C() CC( CO U) CIO CMO CC) LC) U) CO LC) U) CO CO U) N a) 5 N cosr TO 0 CO0 0 0 CO 0 r N NNN 0Z as O •N In O to E 111 CO E J CC O 0 y 01 O. O CO 6) n O O N 0 0 0 M M 0 0 0 0 V �' V 0 Z O O L a E O) CA r r Q) C) co CO a) o CA O CA CA o CA CA C O c o a) a) o D Z ~ co CD o a) co g .. 1.6c H V r V V V V V V V V v V V v v V V v V V V V v v v v p _• J a) CO CO U _ _ CO C O CO CO CO N n CO CO N CO n N Cc) 0 N V V CO V CO 0 CO N 0 Q LL Z p V CO M V' V V CO CO CO CO N M V V CO V V V V V V V V V V -p C n S Q O I n n n n n n n n n n n n n n n n n n n n n n n n N- C o Cr Y ~ < a)nO o r « Q /• � O o a V I� rn Y 0 N j 5 Q N Q N N N N N N N CO CO 0 CO CO r 0 O CO CO N 0 O) (A Cr) CO N N 0 CO 0 a iiLL Q LLI Ci(n N N y C V' V V V V V O O M V CO CO V V V V V V V Q ... O Q'i LL OO < < D CL ° W 0 Q v in CD CO _ N 2 • O CO CT 0 0 OM) O 0 0 CCl CO CMO CO V COO COO CU) CO C0) COMr V r C)O V O r 0 C HQ N c co eonMMMnnnnnnnnrnMaor� � � n (o (n (U)) CO V O Ca O 2 N 7 2 o d Y a H U Z W m E 00000Ovv V' a s d' vVI' vvvvvvNI' vvv v a Z Q A/ c -6 a) a) O) C) C) C) C) C) CO CO U) CO (O CO CO CO CO CO CO CO CO CO CO CO CO CO CO — Ce •C O n 0 N (CO 0 =• aza � U � o c as c o N L o N L C5 a) Q _ O CA N o N a) N Q (i Z Q a) 3 CO CD CO CO CO CO CO CD CO CO CO CO CO CO CO CO CO CO CO CO CO CO COCO CO 2 C JH a) o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m N N N N N N N N N N N N N N N N N N N N N N N N N d E Jp n N CCY) C`) 0 r Cc) 0 N M N U) r O) O N M V CO CO n CO C) 0 m W N 25 N r N N N 6 r N N N N r N N N N N N N N N M C) a) r O r r r N r 0 o N N N N N N N N N N CV OQ Cl)al a r r rr0. CU a) L O a) 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 C d co L O O O O O O O O O O O O o O O O O O O O O O O O O Ca O o f o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 '2 o (cr)n C o O o 0 0 0 0 0 0 0 o O o 0 0 0 0 0 0 0 0 0 0 0 0 o c c O) Z CO CO CO CO CO CO N N N N N N N N N N N N N N N N N N N CO) Ca w Y - O COO CO CD OO CO 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 m <,I4 m Q < 5 C) c`') co M C., 0•) C) ') C) C) C) CO V') Cl C) C) CM M C+) M Cc) C') Cc) C•) C'�) C 0 (,- N N N N N N N N N N N N N N N N N N N N N N N N N N 'a - C o) Q) O) 6) C)) C) 6) C) (A O) CS) Cn O) CA O) co O) C) C) C) O) O) O) C) C) CO ' co C C Ca O N N N N N N N N N N N N N N N (N N N N N N N N N N CC) C cs T. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 9 O E c mc. L O O O O O O O o O O O O o 0 o O O O O O O O O O O O a) o CO CO M C CO O CO CO CO CO LO CO CO CO CO CO CO CO CO CO CO CO CO CO CO CO 2 O) J C a) d a J O O C a) as O 6 QJ as c C Z N w Z C Ni YN L (3 07 Cf) C as 'O .L.. C (n • E Q ae) E o r c d c 06 O- CU LL d c Z 2 o o X N a) — co 0 v o 000000cocococococococococococ corn ococococo d 0 o- _J 'O M co fn co !n fn (� (n fn f!) (n us CA (A V) (Q fn fn ch ch U) U) Cn co co CA _ a) 0 1 Q co Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Q L RECEIVED STATE OF AL OIL AND GAS CONSERVATION COMARION REPORT OF SUNDRY WELL OPERATIONS DEC 2 8 2.016 1.Operations Abandon Lf Plug Perforations LJ Fracture Stimulate Li Pull Tubing Li AdigiGeoiGown Li Performed: Suspend ❑ Perforate ❑� Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perf.New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Casing Jack ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development ❑✓ Exploratory ❑ 202-141 3.Address: Stratigraphic Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23102-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312799 NORTHSTAR UNIT NS-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A NORTHSTAR/KUPARUK UNDEF OIL 11.Present Well Condition Summary: Total Depth measured 16,865 feet Plugs measured 16,856 feet true vertical 11,117 feet Junk measured N/A feet 13,874,14,471, Effective Depth measured 16,856 feet Packer measured 16,323&16,362 feet 8,666,9,089, true vertical 11,109 feet true vertical 10,615&10,650 feet Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 4,033' 13-3/8" 4,033' 3,207' 5,020psi 2,260psi Production 14,668' 9-5/8" 14,668' 9,234' 6,870psi 4,760psi Liner 2,070' 7" 16,541' 10,815' 7,240psi 5,210psi Liner 503' 4-1/2" 16,865' p X111,117' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic SCANNED tibLik a R 0 j?;, True Vertical depth See Attached Schematic 4-1/2" 12.6/13CR/VAM-TOP 13,915' 8,710' Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/13CR/VAM-ACE 16,362' 10,650' 9-5/8"x 4-1/2"S3 9-5/8"x7"Liner Top 7"x4-1/2"Baker S-3 989'MD Packers and SSSV(type,measured and true vertical depth) 7"x5"Liner Top TRM-5E SSSV See Above 986'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: 235 13,675 750 1,109 761 Subsequent to operation: 1,014 32,145 10 1,149 1,713 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Ej Exploratory El Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-604 Contact Taylor Wellman '7,i. Email twellman@hilcorp.com Printed Name Mike nn Title Operations Manager c Signature Phone 777-8382 Date 12/27/2016 Form 10-404 Revised SRBDMS 1/ ' DEC 2 9 2016 0RIGINAL /4_, h...at I bmit Original Only/ (70/7 Lx II • • Northstar Unit Well: NS-18 SCHEMATIC Last Completed: 8/21/2016 Hilcorp Alagka,LLC PTD: 202-141 TREE&WELLHEAD KB Elev.:55.85'/BF Elev.:39.9'(CB 15.9') Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20 �a� OPEN HOLE/CEMENT DETAIL 13-3/8" 669 sx PF'L',472 sx Class'G'in 16"Hole st 1 9-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole 7" 325 sx Class"G"in 8-1/2"Hole DVTcol 4-1/2" 93 sks Class"G"in 6-1/8"Hole k% @ 1,625' *, CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm :" 2 • 20" Conductor 169/X-56/N/A N/A Surface 201' 13-5/8" 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' P II 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' il 4 TUBING DETAIL 4-1/2" Tubing 12.6/13CR/VAM-TOP 3.958 Surface 13,915' 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 16,317' 16,362' WELL INCLINATION DETAIL I' 1 51 *4 KOP @ 351' =- "v 6 Max Hole Angle=59 deg. @ 3,590' 1 Nin ID@i I i8 L V....01 Angle at Top Perf=47 Deg.@ 14,195' „1 JEWELRY DETAIL 9 (� P No Depth Item 1 989' 4-1/2"TRMAXX-5E SSSV w/X Profile ID=3.813" P"-4 10 A Vi X11 GLM Detail-MMG 13cr w/RK Latch i+ 2 3,913' ST 3:Port=0,Dev.=55,VLV=DMY,TVD= 3,137',8/8/2016 t0 3 8,544' ST 2:Port=0,Dev.=57,VLV=DMY,TVD= 5,658', 8/8/2016 9-5/8"4 1. 4 11,965' ST 1:Port=0,Dev.=56,VLV=DMY,TVD= 7,557',8/8/2016 5 13,858' 4.5"X Nipple-ID=3.813" 6 13,874' 9-5/8"x 4-1/2"Baker S3 Packer 7 13,895' 4.5"X Nipple-ID=3.813" 8 13,908' 4.5"XN Nipple-ID=3.725" _ 9 13,915' WLEG-Bottom @ 13,916' ', 12 10 14,471' 9-5/8"x 7"Baker ZXP Liner Top Packer s In° 13 $ 11 14,490' 9-5/8"x 7"Baker Liner Hanger ; 12 16,323' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 11. 13 16,347' 4-1/2"HES X Nipple,ID=3.813 .3 i - 14 *: 14 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) 15 16,362 7"x 5"Baker ZXP Liner Top Packer 16 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" l `, 17 16,384' 9-5/8"x 7"Liner Hanger e4 18 16,750' CIBP )mow® .� ' 15 PERFORATION DETAIL , ��6 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 7 I jC Kup C Sands 14,202' 14,262' 8,901' 8,942' 60 12/18/16 " Open d Kup A3 Sands 14,338' 14,358' 8,994' 9,008' 20 10/18/16 Open t;, ':4 Kup A2 Sands 14,390' 14,420' 9,031' 9,052' 30 10/18/16 Open TOC@16,725 , Kup Al Sands 14,436' 14,456' 9,064' 9,078' 20 10/17/16 Open Kup Al Sands 14,456' 14,476' 9,078' 9,093' 20 10/17/16 Open Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed s, ,.a 18 Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed GENERAL WELL INFO API:50-029-23102-00-00 Drilled& Cased by w/Nabors 33E -1/5/2003 4-1/2" ep - Original Completion w/Nabors 33E-1/15/2003 TD=16,865'(MD)/TD=11,117'(1VD) Perforate w/Nabors 33E-1/22/2003 PBTD=16,856'(MD)/PBTD=11,109'(TVD) Add Perforations -12/8/2005 Add Perf&Complete w/ASR#1-8/21/2016 Updated By:TTW 12/21/2016 • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-18 Slickline 50-029-23102-00-00 202-141 12/18/2016 12/18/2016 Daily Operations: 12/14/2016-Wednesday No activity to report. 12/15/2016-Thursday No activity to report. 12/16/2016- Friday No activity to report. 12/17/2016-Saturday INITIAL T/I/0=1400/1050/OPSI. PT 1,000 psi Low/2,650psi High. PERFORATED 1,42421-14,262' DEPTH CORRECTED TO SLB PERF RECORD DATED 10-AUG-16, GUN #5 TIE-IN PASS. 20' - 2.88" HSD 6SPF 60 DEG PHASED PJ NOVA GUN. PRESSURE INCREASED FROM 1,500 TO 1,700 AFTER SHOOTING, LOST 250 POUNDS ON LINE TENSION. WELL BUILT UP TO 2250 PSI BY TIME OOH. 12/18/2016-Sunday PRESSURE TESTED LUBE, 500 LOW, 3,200 HIGH. PERFORATED 14,202'-14,242' IN TWO RUNS. 20' - 2.88" HSD 6SPF 60 DEG PHASED PJ NOVA GUN. USED GR/CCL FOR CORRELATION, DEPTH CORRECTED TO SLB PERF LOG DATED 10-AUG-16, GUN #5 TIE-IN PASS. ALL SHOTS FIRED.TUBING PRESSURE INCREASED FROM 1,400 TO 2,600 OVER THREE PERF RUNS.TURN WELL OVER TO PRODUCTION FOR TESTING. FINAL T/I/O = 2,600/1,050/0,JOB COMPLETE. 12/19/2016- Monday No activity to report. 12/20/2016-Tuesday No activity to report. OF . Iv7, THE STATE Alaska Oil and Gas ti ►,� ts, of Li\ SI(i\. Conservation Commission 333 West Seventh Avenue t91 C*h, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 UP Main: 907.279.1433 A ;S� Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn • Operations Manager ��ED rte`' ; • Hilcorp Alaska, LLC SCA 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Northstar Field, Kuparuk Undefined Oil Pool,NU NS-18 Permit to Drill Number: 202-141 Sundry Number: 316-604 Dear Mr. Dunn: 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, 1/ Daniel T. Seamount, Jr. GG ,/ Commissioner DATED this / day of December, 2016. RBDMS DEC - 9 2016 G .fir q'�� RECEWED • STATE OF ALASKA Q ' NOV 2 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate 0 . Other Stimulate 0 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other: ❑ 2.Operator Name: 4.Current Well Class: : 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory 0 Developr>ent' 202-141 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage Alaska 99503 50-029-23102-00-00 " 7.If perforating: ,,? ii19c_e-5,.C3.5'L 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? -6 ILS Will planned perforations require a spacing exception? Yes 0 No 2 NORT STAR UNIT NS-18 • 9.Property Designation(Lease Number): 10.Field/Pool(s): K e-c sdfL gitctcS� ADL0312799• NORTHSTAR/KUPARUK OIL . ,z. 6,1, 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): 16,865' . 11,117' " 16,856' 11,109' 208 16,856' N/A Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 4,033' 13-3/8" 4,033' 3,207' 5,020psi 2,260psi Production 14,668' 9-5/8" 14,668' 9,234' 6,870psi 4,760psi Liner 2,070' 7" 16,541' 10,815' 7,240psi 5,210psi Liner 503' 4-1/2" 16,865' 11,117' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2" 12.6/13CR/VAM-TOP 13,915' See Attached Schematic See Attached Schematic 4-1/2" 12.6/13CR/VAM-ACE 16,362' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x 4-1/2"S3,9-5/8"x7"Liner Top,7"x4-1/2"Baker S-3& 13,874(MD)/8,666(TVD),14,471(MD)/9,089(TVD), 16,323(MDy 10,615(TVD)& 7"x5"Liner Top and TRM-5E SSSV 16,362(MD)/10,650(TVD)and 989(MDY 986(TVD) 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ StratigrapItic ❑ Development Q . Service ❑ 14.Estimated Date for / 15.Well Status after proposed work: Commencing Operations: ,c21/5 r o i 6 OIL Q • WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG 0 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. Contact Taylor Wellman T.,,/ Email twellrlen(. hilcorv,com Printed Name cot' Dunn 1 Title Operations Manager �� #4 dW 1"��t YHYY% Signature�.,�i"�� Phone 777-8382 Date 11/z964, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 , Spacing Exception Required? Yes ❑ No up' Subsequent Form Required: /b__,-iO4-1 RBDI�S Lu DEC - 9 2016 /0 APPROVED BY /) Approved by: COMMISSIONER THE COMMISSION Date: ) 1 ) 1/)/ I ` / Quhmit Fn m and Form 10-403-evised 11/2015 r r a n valid for 12 onths from the date of approval. Attachments in Duplicate 0R'1 I �/Z-7-/ . a/r/rd m ,2--G; • Kuparuk C Perf Well: NS-18 • fir PTD: 202-141 Hilcorp Alaska,LU API: 50-029-23102-00-00 Well Name: NS-18 API Number: 50-029-23102-00-00 Current Status: Online Pad: Northstar Island Estimated Start Date: December 15, 2016 Rig: EL Reg.Approval Req'd? No Date Reg.Approval Rec'vd: N/A Regulatory Contact: Tom Fouts Permit to Drill Number: 202-141 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907)777-8412 (0) (907) 331-8228 (M) AFE Number: Sundry/WellEZ Input Req'd Yes Current Bottom Hole Pressure: 4225 psi @ 9000' TVD (Based on Kuparuk A BHP on 8/17/15) Maximum Expected BHP: 4225 psi @ 9000' TVD (Based on Kuparuk A BHP on 8/17/15) Max.Anticipated Surface Pressure: 3325 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 3020 psi (Taken on 08/19/16) Min ID: 3.725"XN Nipple @ 13,908' and Brief Well Summary: The well was recently recompleted to the Kuparuk formation from the Ivishak. A total of 90'of perfs were shot in the Kuparuk A in stages. After each stage the well was flowed and showed an increased production each time. The lowest sand shot(Kuparuk Al) produced 41 API oil and has lightened as each higher sand was shot until now the combination of all 90' is 55 API. After initial flush production,the well has curtailed off. A • production profile was run that indicates the Al has zero contribution,the A2 perfs are partially contributing at —11%of the flow and the A3 has only half of the shot perforations contributing—89%of the production. On 10/16-10/17 all zones were re-perforated with minimal increase in production rates. Objective: Perforate the following intervals in the table below. Gun Run# Perf Top Perf Bottom Perf Length Formation 1 ±14,244' ±14,264' 20' Kuparuk C 2 ±14,224' ±14,244' 20' Kuparuk C 3 ±14,204' _ ±14,224' 20' Kuparuk C Total 60' Table 1: NS-18 Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" Procedure: E-Line 1. RU EL unit and pressure test to 250psi low/4000psi. 2. MU perforating tool string with 2-7/8"-3-3/8", 6spf, 60 deg phasing guns. 3. RIH and correlate 1st gun run to Tie-In Log: HES CBL dated 10Aug2016.Contact OE Taylor Wellman or RE Chris Kanyer(contact info above) prior to perforating for final approval of tie in. a. Note any tubing pressure change in WSR. 4. MU perf toolstrings and repeat step 3 as needed to perforate Gun Runs#2-3 as per the above table with the Proposed Perf Gun Runs. POOH. • . Kuparuk C Perf Well: NS-18 • PTD: 202-141 Hilcorp Alaska,LL API: 50-029-23102-00-00 a. Note any tubing pressure change in WSR. 5. RD Eline. a. Notify Operations to bring well online and flow well. Northstar Unit • Well: NS-18 II II SCHEMATIC Last Completed: 8/21/2016 IIilcorp Alaska,LLC PTD: 202-141 TREE&WELLHEAD KB Elev.:55.85'/BF Elev.:39.9'(CB 15.9') Tree ABB-VGI 5-1/8"SKS! Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20OPEN HOLE/CEMENT DETAIL va ' 13-3/8" 669 sx PF'L',472 sx Class`G'in 16"Hole 11 1 ri9-5/8" 794 sx Econolite,564 sx`G'in a 12-1/4"Hole ti 7" 325 sx Class"G"in 8-1/2"Hole DVTooi 4-1/2" 93 sks Class"G"in 6-1/8"Hole se' F @1,625' CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 2 ki 20" Conductor 169/X-56/N/A N/A Surface 201' 13-5/8'� 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' , 3 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' 3+ 10 4? 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' 4 TUBING DETAIL es 4-1/2" Tubing 12.6/13CR/VAM-TOP 3.958 Surface 13,915' i i 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 16,317' 16,362' t4 5 WELL INCLINATION DETAIL KOP @ 351' i -- , tamsilie6 Max Hole Angle=59 deg. @ 3,590' rt 1 win ID @`. 4 1 7 ,y Angle at Top Perf=47 Deg.@ 14,195' 13,908 I 1 8 4 JEWELRY DETAIL t 9 No Depth Item f ► . 10 1 989' 4-1/2"TRMAXX-SE SSSV w/X Profile ID=3.813" + X11 GLM Detail-MMG 13cr w/RK Latch ' r. 2 3,913' ST 3:Port=0,Dev.=55,VLV=DMY,TVD= 3,137',8/8/2016 84 3 8,544' ST 2:Port=0,Dev.=57,VLV=DMY,TVD= 5,658', 8/8/2016 9-5/8 4 11,965' ST 1:Port=0,Dev.=56,VLV=DMY,TVD= 7,557',8/8/2016 5 13,858' 4.5"X Nipple-ID=3.813" 6 13,874' 9-5/8"x 4-1/2"Baker S3 Packer 7 13,895' 4.5"X Nipple-ID=3.813" 8 13,908' 4.5"XN Nipple-ID=3.725" C 7 ."4 Pi 12 9 13,915' WLEG-Bottom @ 13,916' 10 14,471' 9-S/8"x 7"Baker ZXP Liner Top Packer 1 i 13 ;111 14,490' 9-5/8"x 7"Baker Liner Hanger 12 16,323' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 13 16,347' 4-1/2"HES X Nipple,ID=3.813 14 14 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) ITI A,1 15 16,362 7"x 5"Baker ZXP Liner Top Packer 16 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" 17 16,384' 9 5/8"x 7"Liner Hanger I 18 16,750' CIBP :' 15 PERFORATION DETAIL 's 16 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status A s '17 7 Kup A3 Sands 14,338' 14,358' 8,994' 9,008' 20 10/18/16 Open Kup A2 Sands 14,390' 14,420' 9,031' 9,052' 30 10/18/16 Open Kup Al Sands 14,436' 14,456' 9,064' 9,078' 20 10/17/16 Open TOC@16,725' Kup Al Sands 14,456' 14,476' 9,078' 9,093' 20 10/17/16 Open Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed fiN Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed ' r 18 GENERAL WELL INFO = API:50-029-23102-00-00 Drilled& Cased by w/Nabors 33E -1/5/2003 Original Completion w/Nabors 33E-1/15/2003 4-1/2 kilyr Perforate w/Nabors 33E-1/22/2003 TD=16,865'(MD)/TD=11,117'(TVD) Add Perforations -12/8/2005 PBTD=16,856'(MD)/PBTD=11,109'(TVD) Add Perf&Complete w/ASR#1-8/21/2016 Updated By:1CM 10/18/2016 • Northstarll: NS-18 Unit We • H 0 PROPOSED Last Completed: 8/21/2016 Hilcorp Alaska,LLC PTD: 202-141 TREE&WELLHEAD KB Elev.:55.85'/BF Elev.:39.9'(CB 15.9') Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI � OPEN HOLE/CEMENT DETAIL 20' . F' -, ;: 13-3/8" 669 sx PF'L',472 sx Class'G'in 16"Hole 1 ' 9-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole 7" 325 sx Class"G"in 8-1/2"Hole * DVTooI 4-1/2" 93 sks Class"G"in 6-1/8"Hole yx @1, 515 CASING DETAIL ,0 liP ASize Type Wt/Grade/Conn Drift ID Top Btm 2 if, 20" Conductor 169/X-56/N/A N/A Surface 201' 13-5/8%1 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' 3 ri 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' to r+„fi4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' 4 TUBING DETAIL 4-1/2" Tubing 12.6/13CR/VAM-TOP 3.958 Surface 13,915' ».M 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 16,317' 16,362' WELL INCLINATION DETAIL *l 5 Ay KOP @ 351' 6 Max Hole Angle=59 deg. @ 3,590' ft Ma ID@ 7 I 1 ii Angle at Top Perf=47 Deg.@ 14,195' 13,908' s;. I j 8 il JEWELRY DETAIL ' 9 1,4 7. No Depth Item :-« 10 1 989' 4-1/2"TRMAXX-5E SSSV w/X Profile ID=3.813" ..::11 GLM Detail-MMG 13cr w/RK Latch ' 2 3,913' ST 3:Port=0,Dev.=55,VLV=DMY,TVD= 3,137',8/8/2016 4 g 3 8,544' ST 2:Port=0,Dev.=57,VLV=DMY,TVD= 5,658', 8/8/2016 9-5/8'• 4 11,965' ST 1:Port=0,Dev.=56,VLV=DMY,TVD= 7,557',8/8/2016 5 13,858' 4.5"X Nipple-ID=3.813" 6 13,874' 9-5/8"x 4-1/2"Baker S3 Packer 7 13,895' 4.5"X Nipple-ID=3.813" 8 13,908' 4.5"XN Nipple-ID=3.725" 9 13,915' WLEG-Bottom @ 13,916' c 0, a 12 k :I 10 14,471' 9-5/8"x 7"Baker ZXP Liner Top Packer 1 i 13 11 14,490' 9-5/8"x 7"Baker Liner Hanger .* 12 16,323' 7"x4-1/2"Baker S-3 Packer,ID=3.875" $, 13 16,347 4-1/2"HES)(BBB Nipple,ID=3.813 14 1111111107543261 4 111111114466666;,:,433343335497862648730912,::: 6,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) 15 16,362 7"x 5"Baker ZXP Liner Top Packer 16 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" P 17 16,384' 9-5/8"x 7"Liner Hanger 18 16,750' CIBP 15 PERFORATION DETAIL x'1s Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status -17 ' 7 ' f Kup CSands ±14,204' ±14,264' ±8,902' ±8,943' ±60 Future Future G, Kup A3 Sands - 14,338' 14,358' 8,994' 9,008' 20 10/18/16 Open Kup A2 Sands 14,390' 14,420' 9,031' 9,052' 30 10/18/16 Open TOC @16,725 ' Kup Al Sands 14,436' 14,456' 9,064' 9,078' 20 10/17/16 Open Kup Al Sands 14,456' 14,476' 9,078' 9,093' 20 10/17/16 Open Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed • 18 Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed a GENERAL WELL INFO API:50-029-23102-00-00 a Drilled& Cased by w/Nabors 33E -1/5/2003 41/2 a Original Completion w/Nabors 33E-1/15/2003 1D=16,865'(MD)/TD=11,117'(TVD) Perforate w/Nabors 33E-1/22/2003 PBTD=16,856'(MD)/PBTD=11,109'(TVD) Add Perforations -12/8/2005 Add Perf&Complete w/ASR#1-8/21/2016 Updated By:TDF 11/28/2016 • • Davies, Stephen F (DOA) From: David Duffy <dduffy@hilcorp.com> Sent: Wednesday, November 30, 2016 3:16 PM To: Davies, Stephen F (DOA); Colombie, Jody J (DOA) Cc: Chris Kanyer; Larry Greenstein; Cody Terrell Subject: Northstar Kuparuk Rules/ NS-18 AOGCC 10-403 SUBMITTAL 11-28-2016 Attachments: NS-18 AOGCC 10-403 SUBMITTAL 11-28-2016.pdf; Geology and Reservoir Descriptions - Questions for Hilcorp 20161117.docx; 20161123143411749.pdf Steve, Hilcorp's technical team has prepared a non-confidential geologic report for AOGCC's consideration of our proposed NS Kuparuk Pool Rules. We have also provided a working document (Word version)to answer specific questions regarding geology and reservoir descriptions. We believe these materials are responsive to specific questions raised by the Commissioners during the hearing, and as such, respectfully request AOGCC now close the record and move this matter towards adjudication. Hilcorp's previously submitted confidential reports are requested to remain confidential, or alternatively, be returned to Hilcorp. Hilcorp has also prepared a sundry for the NS-18 well (currently a Kuparuk A producer) to add perfs in the Kuparuk C sands (attached). Under Hilcorp's proposed pool rules, the entire Kuparuk would treated as a single pool, and would thus eliminate commingling. Production would be accounted for under Hilcorp's proposed vertical expansion of the Kuparuk PA (matching base and top of our proposed Kuparuk pool). Spacing would also be governed by the proposed pool rules. Hilcorp would very much like to proceed with the NS-18 perf add during the month of December and requests your consultation regarding procedure, timing and status. Regards, David Duffy, Landman Hilcorp Alaska, LLC Direct: 907-777-8414 Cell: 907-301-2629 dduffy@hilcorp.com This email may contain confidential and / or privileged information and is intended for the recipient(s)only. In the event you receive this message in error, please notify me and delete the message. 1 • 111) 1 0 0 0 a) I _ N I fg , o I ! N i III I 8 5 o v Ell , Ill H/ CVA 2 s � , 1 I E,_ . W Ni , C C _ 1T fsz. (0 �X um v- ; 8 0 S g 'X g _ SSS t 00 ami it iii -F---,---, 00 z1' 01 M M o N N O 1— L1J LLJ s CO LL M a N 0 Z � CO co 00 O nCO G - N o V) (.1) (fl N Ti O N � � � o o NQ M E— cg a i_ cVZ ' 11111111111111!./b illi illif ill fir- N M Z a• .3 ct P W a q R t r 1 ii 111 ,f11j11 � 1,1lcill, llfl E -g Si N 6 Sim Va a� i N2 1 j 1 1 1 1 M 00,MM --I--- -f-- = •c .... a a as 0 0 0 0) • • 0 N Produced Gas (Thousand Cubic Feet ("MCF") per Day) or Gas-Oil Ratio (MCF per Barrel) 0 O O .c0..0 o 0 0 0 0 0 0 0 = N-+ .O-I oho l00 v N O cc O• ›- E 'F 9r lO EYaYo c >- 0 a0 O 0 cerp - >,20._ >J (^ CZ 71:2 ka � _0 0 L i N Mco N °' _ .zr k0 -a Qr-i-� w lE n1 Y o in r-Z Cl.) s a - [I r° - 4P�47 u l vO Ou aO 0"0 P-I 4.r O L- 1:,_ v N U a 0 T O 13 O C7 o N 0 O E E • °�0_ cts U U H• o s—I fa i a _/ W 1213 Y CSO Z - sr%/) cc a �l° °I 0 a ✓ T hq — m .6 as 0 *• O 0 a 03 P 4,4 0 0 0 0 0 0 0 0 0 0 0 I�l 0 .�-1 .�—I .�—I aNi a0CO ter 0 Aea Jad iale/N Jo slaLiee Jo Aea Jed Ha Jo wing L0 0 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate Lf Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perf.New Pool ❑ Repair Well El Re-enter Susp Well ❑ Other: Casing Jack ❑ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development Q Exploratory ❑ 202-141 3.Address: Stratigraphic El Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23102-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312799 NORTHSTAR UNIT NS-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A NORTHSTAR/KUPARUK UNDEF OIL&NORTHSTAR OIL 11.Present Well Condition Summary: Total Depth measured 16,865 feet Plugs measured 16,856 feet true vertical 11,117 feet Junk measured N/A feet 13,874, 14,471, E t* Effective Depth measured 16,856 feet Packer measured 16,323&16,362 feet 8,666,9,089, NOV 1 2016 true vertical 11,109 feet true vertical 10,615&10,650 feet A C Casing Length Size MD TVD Burst ollapse'� Conductor 201' 20" 201' 201' N/A N/A Surface 4,033' 13-3/8" 4,033' 3,207' 5,020psi 2,260psi Production 14,668' 9-5/8" 14,668' 9,234' 6,870psi 4,760psi Liner 2,070' 7" 16,541' 10,815' 7,240psi 5,210psi Liner 4-1/2" 16,865' 11,117' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 4-1/2" 12.6/13CR/VAM-TOP 13,915' 8,710' Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/13CR/VAM-ACE 16,362' 10,650' 9-5/8"x 4-1/2"S3 9-5/8"x7"Liner Top 7"x4-1/2"Baker S-3 989'MD Packers and SSSV(type,measured and true vertical depth) 7"x5"Liner Top TRM-5E SSSV See Above 986'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A SCANNED KAP, s 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: 296 19,703 2 1,110 849 Subsequent to operation: 257 16,485 0 1,111 757 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil 0 Gas U WDSPL U Printed and Electronic Fracture Stimulation Data ❑ GSTOR El WINJ El WAG ❑ GINJ El SUSP❑ SPLUG El 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: 316-477 Contact Taylor Wellman tri Email twellman(a�hilcorp.com� Printed Name _. Mi Dunn Title Operations Manager c Signature Phone 777-8382 Date 11/15/2016 Form 10-404 Revised 5/201 ,"�� // �3 /� RBDMS / NOV 1 7 2016 Submit Original Only • • Northstar Unit Well: NS-18 • SCHEMATIC Last Completed: 8/21/2016 I lilcorp Alaska,LLC PTD: 202-141 TREE&WELLHEAD KB Elev.:55.85'/BF Elev.:39.9'(CB 15.9') Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI ,',f L 204.4 OPEN HOLE/CEMENT DETAIL i. I; I .,, 0 13-3/8" 669 sx PF`L',472 sx Class'G'in 16"Hole 1 9-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole 7" 325 sx Class"G"in 8-1/2"Hole 4 DV Tod 4-1/2" 93 sks Class"G"in 6-1/8"Hole 1,a @1,625' CASING DETAIL ,01 Size Type Wt/Grade/Conn Drift ID Top Btm it 2 20" Conductor 169/X-56/N/A N/A Surface 201' 13-5/8"1 ii Ii" 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' .& 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' 3 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' le an 3 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' 4 ri TUBING DETAIL 4-1/2" Tubing 12.6/13CR/VAM-TOP 3.958 Surface 13,915' 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 16,317' 16,362' WELL INCLINATION DETAIL 1 i 5 1 KOP@351' of 4.=6 Max Hole Angle=59 deg. @ 3,590' 13�ID @ j 7 Angle at Top Perf=47 Deg.@ 14,195' „, 6 Q SA JEWELRY DETAIL KNo Depth Item 111 01 989' 4-1/2"TRMAXX-5E SSSV w/X Profile ID=3.813" GLM Detail-MMG 13cr w/RK Latch 2 3,913' ST 3:Port=0,Dev.=55,VLV=DMY,TVD= 3,137',8/8/2016 3 8,544' ST 2:Port=0,Dev.=57,VLV=DMY,TVD= 5,658', 8/8/2016 9-5/8" 4 11,965' ST 1:Port=0,Dev.=56,VLV=DMY,TVD= 7,557',8/8/2016 5 13,858' 4.5"X Nipple-ID=3.813" 6 13,874' 9-5/8"x 4-1/2"Baker S3 Packer 7 13,895' 4.5"X Nipple-ID=3.813" 8 13,908' 4.5"XN Nipple-ID=3.725" 9 13,915' WLEG-Bottom @ 13,916' i i 18a 12 10 14,471' 9-5/8"x 7"Baker ZXP Liner Top Packer . 11 14,490' 9-5/8"x 7"Baker Liner Hanger x P 12 16,323' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" r 3 13 16,347' 4-1/2"HES X Nipple,ID=3.813 4 14 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) I:,:I 14 'Al 01 ki xt 15 16,362 7"x 5"Baker ZXP Liner Top Packer 3 16 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" 17 16,384' 9-5/8"x 7"Liner Hanger 18 16,750' CIBP 415 PERFORATION DETAIL 7 ' 17 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup A3 Sands 14,338' 14,358' 8,994' 9,008' 20 10/18/16 Open Kup A2 Sands 14,390' 14,420' 9,031' 9,052' 30 10/18/16 Open r i. Kup Al Sands 14,436' 14,456' 9,064' 9,078' 20 10/17/16 Open TOC@16,725' Kup Al Sands 14,456' 14,476' 9,078' 9,093' 20 10/17/16 Open w Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed L:. ,18 -- GENERAL WELL INFO API:50-029-23102-00-00 Drilled& Cased by w/Nabors 33E -1/5/2003 Original Completion w/Nabors 33E-1/15/2003 4-1/2" "t Perforate w/Nabors 33E-1/22/2003 TD=16,865'(MD)/TD=11,117'(TVD) Add Perforations -12/8/2005 PBTD=16,856'(MD)/PBTD=11,109'(TVD) Add Perf&Complete w/ASR#1-8/21/2016 Updated By:JCM 10/18/2016 f • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-18 Slickline 50-029-23102-00-00 202-141 10/13/16 10/17/16 Daily Operations: 10/12/2016-Wednesday No activity to report. 10/13/2016-Thursday Eline prep for adperf job (waiting on gun, winds to high to fly them over) 10/14/2016- Friday Eline prep for adperf job (waiting on gun, winds to high to fly them over) 10/15/2016-Saturday Eline prep for adperf(flying guns from airport to island) 10/16/2016-Sunday WELL FLOWING UPON ARRIVAL(ELINE REPERF). PT SURFACE EQ. 500/3,750#. RUN#1 - RIH W/201X 3-1/8" GEODYNAMICS PERF GUN -SHOT INTERVAL @ 14,456' - 14,476'. RUN#2 - RIH W/20' X 3-1/8" GEODYNAMICS PERF GUN -SHOT INTERVAL @ 14,436' - 14,456'.TIED INTO SLB PERF RECORD 10-AUG-16 CORRELATION PASS. 10/17/2016- Monday RUN#3 - RIH W/20' X 3-1/8" GEODYNAMICS PERF GUN -SHOT INTERVAL @ 14,400' - 14,420'. RUN#4- RIH W/ 10'X 3-1/8" GEODYNAMICS PERF GUN -SHOT INTERVAL @ 14,390' - 14,400'. RUN#5 - RIH W/20' X 3-1/8" GEODYNAMICS PERF GUN - SHOT INTERVAL @ 14,338' - 14,358'.TIED INTO SLB PERF RECORD 10-AUG-16 CORRELATION PASS. 10/18/2016-Tuesday No activity to report. yw\ �I/7, THE STATE Alaska Oil and Gas J ,, of/� T /\ C[`T /� Conservation Commission 333 West Seventh Avenue r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALA41‘p Fax: 907.276.7542 www.aogcc.alaska.gov Mike Dunn Operations Manager SCANSB FEE 4 °I I Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Northstar Field, Kuparuk C Undefined and Northstar Oil Pools,NU NS-18 Permit to Drill Number: 202-141 Sundry Number: 316-477 Dear Mr. Dunn: 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 P oerster Chair DATED this 2/ day of September,2016. RBDMS wee-7 L 9 2016 • STATE OF ALASKA • SEP 1olb 0/S R ALASKA OIL AND GAS CONSERVATION COMMISSION p/ )2f/4 APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend ❑ Re-Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: / 5.Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Developmen }, ,LTJ{ 202-141 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ,iv❑6 .API Number: Anchorage Alaska 99503 i 17 50-029-23102-00-00 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 El NORTHSTAR UNIT NS-18 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312799• NORTHSTAR/KUPARUK OIL&NORTHSTAR OIL 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): 16,865' ' 11,117' ' 16,856' 11,109' 208 16,856' N/A Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 4,033' 13-3/8" 4,033' 3,207' 5,020psi 2,260psi Production 14,668' 9-5/8" 14,668' 9,234' 6,870psi 4,760psi Liner 2,070' 7" 16,541' 10,815' 7,240psi 5,210psi Liner 503' 4-1/2" 16,865' 11,117' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2" 12.6/13CRt VAM-TOP 13,915' See Attached Schematic See Attached Schematic 4-1/2" 12.6/13CR1 VAM-ACE 16,362' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ftX 9-5/8"x 4-1/2"S3,9-5/8"x7"Liner Top,7"x4-1/2"Baker S-3& 13,874(MD)/8,666(TVD),14,471(MD)/9,089(TVD), 16,323(MD)i 10,615(TVD)& 7"x5"Liner Top and TRM-5E SSSV 16,362(MD)/10,650(TVD)and 989(MDX 986(TVD) 12.Attachments: Proposal Summary ❑ Wellbore schematic M 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/30/2016 Commencing Operations: OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ 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. Contact Taylor Wellman -"rid Email twellman( hilcom.com Printed Name 'ke Dunn Title Operations Manager Signature Phone 777-8382 Date 7127/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3kU2 - 9i7 Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes E1 No Subsequent Form Required: I (} "LI 044 RBDMS Li' - !T'r G 9 2016 APPROVED BY powowIllailiall_by; COMMISSIONER THE COMMISSION Date: ` ,7. t m} n and --_ `Form 10-403 R vised 11/2015RitglitrAti for 12 months from the date of approval. ttachments in Duplicate • • Re-Perf Well: NS-18 PTD: 202-141 Hawn.Alaska,LLQ API: 50-029-23102-00-00 Well Name: NS-18 API Number: 50-029-23102-00-00 Current Status: Online Pad: Northstar Island Estimated Start Date: September 30, 2016 Rig: EL Reg.Approval Req'd? No Date Reg.Approval Rec'vd: N/A Regulatory Contact: Tom Fouts Permit to Drill Number: 202-141 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Wyatt Rivard (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: 1620567 Sundry/WeIIEZ Input Req'd Yes Current Bottom Hole Pressure: 4225 psi @ 9000' TVD (Based on Kuparuk A BHP on 8/17/15) Maximum Expected BHP: 4225 psi @ 9000' TVD (Based on Kuparuk A BHP on 8/17/15) Max. Anticipated Surface Pressure: 3325 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 3020 psi (Taken on 08/19/16) Min ID: 3.725"XN Nipple @ 13,908' and Brief Well Summary: The well was recently recompleted to the Kuparuk formation from the Ivishak. A total of 90' of perfs were shot in the Kuparuk A in stages. After each stage the well was flowed and showed an increased production each time. The lowest sand shot(Kuparuk Al) produced 41 API oil and has lightened as each higher sand was shot until now the combination of all 90' is 55 API. After initial flush production,the well has curtailed off. A production profile was run that indicates the Al has zero contribution, the A2 perfs are partially contributing at —11%of the flow and the A3 has only half of the shot perforations contributing—89%of the production. Objective: Perforate the following intervals in the table below. Gun Run# Perf Top Perf Bottom Perf Length Formation 1 ±14,456' - ±14,476' 20' Kuparuk Al 2 ±14,436' • ±14,456' 20' Kuparuk A2 3 ±14,400' - ±14,420' 20' Kuparuk A2 Upper 4 ±14,390' ±14,400' 10' Kuparuk A2 Upper 5 ±14,338' • ±14,358' 20' Kuparuk A3 Total 90' Table 1: NS-18 Proposed Perf Gun Runs Note: Final depths to be confirmed in "Final Approved Perf Sheet" Procedure: E-Line 1. RU EL unit and pressure test to 250psi low/4000psi. 2. MU perforating tool string with 2-7/8"-3-3/8", 6spf, 60 deg phasing guns with Connex Charges. 3. RIH and correlate 1st gun run to Tie-In Log: HES CBL dated 10Aug2016.Contact OE Taylor Wellman or RE Chris Kanyer(contact info above) prior to perforating for final approval of tie in. a. Note any tubing pressure change in WSR. 4. MU perf toolstrings and repeat step 3 as needed to perforate Gun Runs#2-5 as per • • Re-Perf II Well: NS-18 PTD: 202-141 TIilcorp Alaska,LL API: 50-029-23102-00-00 Gun Perf Top Perf Bottom Perf Length Formation Run 1 ±14,456' ±14,476' 20' Kuparuk Al 2 ±14,436' ±14,456' 20' Kuparuk A2 3 ±14,400' ±14,420' 20' Kuparuk A2 Upper 4 ±14,390' ±14,400' 10' Kuparuk A2 Upper 5 ±14,338' ±14,358' 20' Kuparuk A3 Total 90' 5. Table 1: NS-18 Proposed Perf Gun Runs. POOH. a. Note any tubing pressure change in WSR. 6. RD Eline. a. Notify Operations to bring well online and flow well. • Northstar Unit • Well: NS-18 SCHEMATIC Last Completed: 8/21/2016 Hilcorp Alaska,LLC PTD: 202-141 TREE&WELLHEAD KB Elev.:55.85'/BF Elev.:39.9'(CB 15.9') Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20 4LOPEN HOLE/CEMENT DETAIL i''. OPEN 13-3/8" 669 sx PF'L',472 sx Class'G'in 16"Hole 1 9-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole 7" 325 sx Class"G"in 8-1/2"Hole DV Tooliki4-1/2" 93 sks Class"G"in 6-1/8"Hole , @1,625' CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm ^,* 2 t1/4,,',: 20" Conductor 169/X-56/N/A N/A Surface 201' 13-5/8"Al II re 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033'- 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' 3r 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' 41,10TUBING DETAIL 4-1/2" Tubing 12.6/13CR/VAM-TOP 3.958 Surface 13,915' 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 16,317' 16,362' r WELL INCLINATION DETAIL i i 5 KOP @ 351' s.�. -7---- '6 Max Hole Angle=59 deg. @ 3,590' f Min ID @`i 7 13,908' 1 Angle at Top Perf=47 Deg.@ 14,195' i8 1L . JEWELRY DETAIL s a,� No Depth Item _� f pe10 1 989' 4-1/2"TRMAXX-5E SSSV w/X Profile ID=3.813" 1,«11 GLM Detail-MMG 13Cr w/RK Latch A 2 3,913' ST 3:Port=0,Dev.=55,VLV=DMY,TVD= 3,137',8/8/2016 3 8,544' ST 2:Port=0,Dev.=57,VLV=DMY,TVD= 5,658', 8/8/2016 9-5/8"a4 4 11,965' ST 1:Port=0,Dev.=56,VLV=DMY,TVD= 7,557',8/8/2016 5 13,858' 4.5"X Nipple-ID=3.813" 6 13,874' 9-5/8"x 4-1/2"Baker S3 Packer 7 13,895' 4.5"X Nipple-ID=3.813" 8 13,908' 4.5"XN Nipple-ID=3.725" 13,915' WLEG-Bottom @ 13,916' I, 4 4 t„ 12 14,471' 9 5/8"x 7"Baker ZXP Liner Top Packer t i 13 11901 14,490' 9 5/8"x 7"Baker Liner Hanger r , 12 16,323' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 1Zi 1 13 16,347' 4-1/2"HES X Nipple,10=3.813 c 14 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) i i 14 r L (4 15 16,362 7"x 5"Baker ZXP Liner Top Packer k 16 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" 'r 17 16,384' 9-5/8"x 7"Liner Hanger 18 16,750' CIBP ,,C . 15 PERFORATION DETAIL L� �� T16 Sands Top(MD) 1 Btm(MD) Top(TVD) Btm(TVD) FT Date Status A 17 7 ' w. Kup A3 Sands 14338' i 14358' 8,994' 9,008' 20 8/21/16 Open Kup A2 Sands 14,390' 14,420' 9,031' 9,052' 30 8/20/16 Open ' Kup Al Sands 14,436' 14,456' 9,064' 9,078' 20 8/19/16 Open TOC @ 16,725 Kup Al Sands 14,456' ` 14,476' 9,078' 9,093' 20 8/10/16 Open Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed .18 GENERAL WELL INFO API:50-029-23102-00-00 -' Drilled& Cased by w/Nabors 33E -1/5/2003 ?, 1 Original Completion w/Nabors 33E-1/15/2003 41/2' l'+' a Perforate w/Nabors 33E 1/22/2003 TD=16,865'(MD)/TD=11,117'(TVD) Add Perforations -12/8/2005 PBTD=16,856'(MD)/PBTD=11,109'(TVD) Add Perf&Complete w/ASR#1-8/21/2016 Updated By:TDF 8/25/2016 STATE OF ALASKA ALOKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon u Plug Perforations 0. Fracture Stimulate u Pull Tubing ❑ ❑ Operations shutdown Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perf.New Pool ❑✓ Repair Well ❑ Re-enter Susp Well❑ Other: Casing Jack 0 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 202-141 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 50-029-23102-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0312799 NORTHSTAR UNIT NS-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A NORTHSTAR/KUPARUK UNDEF OIL&NORTHSTAR OIL 11.Present Well Condition Summary: Total Depth measured 16,865 feet Plugs measured 16,856 feet true vertical 11,117 feet Junk measured N/A 13,874, 14,471, Effective Depth measured 16,856 feet Packer measured 16,323&16,362 feet <S P 1 5 2016 8,666,9,089, true vertical 11,109 feet true vertical 10,615&10,650 feet i ("'( Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 4,033' 13-3/8" 4,033' 3,207' . . . 5,Q20psi 2,260psi Production 14,668' 9-5/8" 14,668' 9,234' 6,870psi 4,760psi Liner 2,070' 7" 16,541' 10,815' 7,240psi 5,210psi Liner 4-1/2" 16,865' 11,117' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic SCANNED FEB 2 2 2017 True Vertical depth See Attached Schematic 4-1/2" 12.6/13CR/VAM-TOP 13,915' 8,710' Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6/13CR/VAM-ACE 16,362' 10,650' 9-5/8"x 4-1/2"S3 9-5/8"x7"Liner Top 7"x4-1/2"Baker S-3 989'MD Packers and SSSV(type,measured and true vertical depth) 7"x5"Liner Top TRM-5E SSSV See Above 986'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: 5 501 1 689 3,835 Subsequent to operation: 297 19,647 2 1,109 845 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 ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL 7 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-343 Contact Taylor Wellman Tom/ Email twellman(C7hiIcorp.com Printed Name Mi Dun 1 Title Operations Manager - Signature Phone 777-8382 Date 9/15/2016 Form 10-404 Revised 5/2015 Submit Original Only �`(OA w rt•f4 RBDMS t-t/ SEP 1 6 2016 H . . Northstar Unit Well: NS-18 SCHEMATIC Last Completed: 8/21/2016 Hilt-ora Alaska,LLC PTD: 202-141 TREE&WELLHEAD KB Elev.:55.85'/BF Elev.:39.9'(CB 15.9') Tree ABB-VGI 5-1/8"5KSI Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 20 Jv`.° � OPEN HOLE/CEMENT DETAIL 13-3/8" 669 sx PF 1',472 sx Class'G'in 16"Hole 1 9-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole 7" 325 sx Class"G"in 8-1/2"Hole DV Tool 4-1/2" 93 sks Class"G"in 6-1/8"Hole -@1625' CASING DETAIL Size Type Wt/Grade/Conn Drift ID Top Btm 2 20" Conductor 169/X-56/N/A N/A Surface 201' 13.5/8„, 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' 3 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' 4-1/2" liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' 4 TUBING DETAIL 4-1/2" Tubing 12.6/13CR/VAM-TOP 3.958 Surface 13,915' 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 16,317' 16,362' WELL INCLINATION DETAIL I5 414 KOP@351' ►_' 6 Max Hole Angle=59 deg. @ 3,590 1"Mn ID C i 17 Angle at Top Perf=47 Deg.@ 14,195' 13,908'- I 18 JEWELRY DETAIL 9 g No Depth Item I.",.910 1 989' 4-1/2"TRMAXX-5E SSSV w/X Profile ID=3.813" . ,' % , 11 GLM Detail-MMG 13cr w/RK Latch A A ,- 2 3,913' ST 3:Port=0,Dev.=55,VLV=DMY,TVD= 3,137',8/8/2016 _ 3 8,544' ST 2:Port=0,Dev.=57,VLV=DMY,TVD= 5,658', 8/8/2016 9-5/8" k 4 11,965' ST 1:Port=0,Dev.=56,VLV=DMY,TVD= 7,557,8/8/2016 ^-° 5 13,858' 4.5"X Nipple-ID=3.813" 6 13,874' 9-5/8"x 4-1/2"Baker S3 Packer 7 13,895' 4.5"X Nipple-ID=3.813" 8 13,908' 4.5"XN Nipple-ID=3.725" ►`1 12 9 13,915' W LEG-Bottom @ 13,916' 10 14,471' 9 5/8"x 7"Baker ZXP Liner Top Packer f' :'13 '' 11 14,490' 9 5/8"x 7"Baker Liner Hanger 12 16,323' 7"x 4-1/2"Baker 5-3,Packer,ID=3.875" 111321 3 16,347' 4-1/2"HES X Nipple,ID=3.813 14 14 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) 15 16,362 7"x 5"Baker ZXP Liner Top Packer r 16 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" o 17 16,384' 9-5/8"x 7"Liner Hanger 18 16,750' CIBP 15 PERFORATION DETAIL T. i "`16 Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 7„ , s ♦ k 17 i` 4 Kup A3 Sands 14,338' 14,358' 8,994' 9,008' 20 8/21/16 Open Kup A2 Sands 14,390' 14,420' 9,031' 9,052' 30 8/20/16 Open , Kup Al Sands 14,436' 14,456' 9,064' 9,078' 20 8/19/16 Open TOC @ 18,725 Kup Al Sands 14,456' 14,476' 9,078' 9,093' 20 8/10/16 Open Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed 18 GENERAL WELL INFO API:50-029-23102-00-00 Drilled& Cased by w/Nabors 33E -1/5/2003 Original Completion w/Nabors 33E-1/15/2003 4-1/2' Perforate w/Nabors 33E=1/22/2003 TD=16,865'(MD)/TD=11,117'(TVD) Add Perforations -12/8/2005 PBTD=16,856'(MD)/PBTD=11,109'(TVD) Add Perf&Complete w/ASR#1-8/21/2016 Updated By:TDF 8/25/2016 . 111 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-18 Slickline 50-029-23102-00-00 202-141 7/15/16 8/21/16 Daily Operations: 7/13/2016-Wednesday No activity to report. 7/14/2016-Thursday No activity to report. 7/15/2016- Friday Arrive at North Star, Get unit set up and ready to RIH w/ plug, Low PT to 300, High PT to 4800, RIH w/ Head/ ERS/2.125 7/16/2016-Saturday ,r4s-j Arrive at North Star. Get unit set up and ready to RIH w/ plug, Low PT to 300, High PT to 4,800, RIH w/ Head/ERS/2.125 oo,yi_ weight X3/CCL/2.125 MSST/3.0" CIBP, Plug Set at 16,750', CCL to Mid Element= 8.75', CCL Stop Depth = 16741.25'. Log ��""//a tied into tubing tally dated 01/13/2003. POOH. 7/17/2016-Sunday Rig up, Low PT 300psi/ High PT 4,800psi. Made three Dump bailer runs.Total cement dummied: 25.3' Estimated top of cement= 16,725'. Bleed TBG to F/L. Fluid Pack TBG with 206 bbls of 125° F SW. FWHP= 13/252/0. 7/18/2016- Monday Loaded IA. MIT-IA to 2,500 psi. *PASSED*. Rig up, Low PT 300psi/ High PT 4,600psi. Cut Tubing at 16,317'. 7/19/2016-Tuesday `/C) T/I/O= 0/400/0. Circulate down the TBG with IA returns to NS-19 flowline. Pressure test rig up. LPT= 350psi/ HPT= 3,800psi. Over displace TBG through cut into IA with 300 bbls of 135° F seawater at 4 bpm. FWHP= 300/300/0. Fill and heat both upright tanks to 135° F in preparation of IA displacement. . • II Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-18 Slickline 50-029-23102-00-00 202-141 7/15/16 8/21/16 Daily Operations: II , 7/20/2016-Wednesday T/I/0 = 245/300/0. Pre RWO Well Circulation. Pumped 1,100 bbls of 135°F seawater down the TBG with IA returns to NS-19 flowline.This is in addition to the 300 bbls pumped on 7/19/2016. CMIT-TxIA to 2,000psi. *PASSED* T&IA each lost total of 23 psi during the 30 minute test. Pumped 6.6 bbls of SW to achieve test pressure. Bled back to FWHP= 0/0/0. Filled both UR tanks and heated first one to 80°F. 7/21/2016-Thursday Heat 600 bbl UR tanks to 80°F for upcoming RWO. 7/22/2016- Friday No activity to report. 7/23/2016 -Saturday No activity to report. 7/24/2016-Sunday No activity to report. 7/25/2016- Monday Rig Crew Travel in from Anchorage to Milne Point, Move Rig equipment from A Pad to F-pad in preparation for barge. Transfer Misc. Rig parts to New Tool Skid. 7/26/2016-Tuesday PEC Training with all crew members &Well Site Supervisors. Load out Mud Tank Trailer for barging. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name 'ig i API Number Well Permit Number Start Date End Date NS-18 ASR# 50-029-23102-00-00 202-141 7/15/16 8/21/16 Daily Operations: I ' X111 I � 7/27/2016-Wednesday PJSM, Load out Rig Components on Barge at Milne Point F-Pad, Mud Pit Trailer, Well Site Trailer, Rig floor&Well Cover, Loaded out mud Boat & Pipe Skate & pipe Racks.Transport Rig components to from Milne Point F-pad to North Star Island. Transport Rig Crew to North Star island via Crew boat from MPF- Pad to North Star Island.All personnel attend SEMS& North Star orientation. Off load Rig components from barge. Mud Pits, Well Site Trailer, Rig floor, Sub floor&Conex's. Day crew shut down for the night. Night crew at Milne Pt. awaiting barge to load out remainder of Rig Components. 7/28/2016-Thursday Held ATP Meeting with North Star Island Staff&all ASR Crews&Well Site Supervisors. Held Sundry meeting on NS-18 with ASR Crews&Work Over Engineer. Notified AOGCC of right to witness BOP Test @ 07:45 AM 7-28-16. Inspector Bob Noble replied at 08:30 and requested an update Friday morning. Move equipment on Island, offload second Barge of Rig& Equipment, Offload Mud Tanks from trailer, Move Gravel in and raise grade for Mud boat.Spot Mud Boat. Install BPV. Function LDS(OK). Packed hanger void w/fluid.Terminate control lines. ND Tree & pull same w/crane. Dry run XO sub for lifting hanger. OK(18 1/2 turns). Barge arrived at NS Island @ 19:30 hrs. but high winds/seas prevented docking. Barge returned to shore. NU 13-5/8" BOPE: Install Mud Cross, Double Gate rams. Install Annular. Install 2-7/8"x 5"VBR's in top ram body. Install blind rams in lower ram body. Attempt to set well cover(Sub).Actuator&wing valve on NS-17 protruding into path of well cover. Discuss with pad Operator and obtain permission to remove actuator&wing valve and blind off at tree. PJSM w/crew, crane operator and Pad Operator on task. Operator safe out tree & actuator. ND actuator, support beam &wing valve. Install blind flange on tree. Attempt to set well cover. No solid base to set footings on. Pull Mud Boat. Place 1/2 mat on backside of well w/crane. Place 1/2 mat in front of well. Set Mud boat&shim same.Shim 1/2 mats. Set Well Cover. Shim & level same. 7/29/2016- Friday PJSM,Set Rig Floor on Well Cover, Set Casi g)acks on BOP, Move Rig on Mud Boat, Raise derrick, Install high Line power.Install Stairs, rig up Rig floor, Change dies in slips& Elevators&Tongs, Change out Bails from 8' to 10' Install all circulating t:PC)hoses.Set Cat Walk& Pipe Racks, Install Choke & Kill line hoses to BOP. Connect Koomey hoses. Double check all spill f containment. Check gas alarms. Ground fault on gas alarms. NS Electricians trouble shooting ground fault. Continue to4 /4/ trouble shoot gas alarm ground fault. Milne Pt. Electricians arrived at Island to help NS Electricians. "Shell"testing BOPE while waiting on electricians. Ground fault found and Gas alarms operational. Continue to shell test BOP while waiting on AOGCC Rep.to arrive.Testing BOPE per AOGCC Regulations,Tested with 2-7/8" 4.5" test Joint to 250/3,000psi.Test was witnessed by AOGCC Inspector,Johnnie Hill, Attempt to test Annular to 250/2,500psi. Could not get Annular to Test. Perform Koomey Test.All Gas alarms Tested. 7/30/2016-Saturday Rig Down Casing JacksBreak_Annular connection remove 13:5j. " Hydrij Annular,Install 13-5/8" Shaffer Annular. Rig up & Test Annular to 250/2,500psi. Good Test. Rig Down Test Equipment. Install Casing Jacks.Check Back Side, Pull TWC, Install Landing Joint in Hanger, Back out Lock down screws.Jack Hanger to Rig floor at 182K, Free weight dropped to 168K, Lay down Tubing Hanger& Landing joint. Hang Sheaves for control line.TOOH,jacking 4.5"Tubing out and Lay down same f/ ±16,317'to 15,270' (25 jts.). • Hilcorp Alaska, LLC Weekly Operations Summary c „,P(4317 Well Name Rig API Number Well Permit Number Start Date End Date NS-18 ASR#1 50-029-23102-00-00 202-141 7/15/16 8/21/16 7/31/2016-Sunday Service Rig, Check fluids in equipment. Continue to TOOH with 4.5”Tubing, Laying down, Pulling with Rig. Starting with join a8Lbezan_missing Cannon Clamps. Recovering partials (very corroded).After joint#200, recovering full clamps. Will make a final count when OOH to estimate clamps left in hole. Casing on fiber optic brittle and breaking apart.At joint 195, lost fiber optic cable.At joint 200, recovered cable and began spooling same again. 270 jts out at report time. 8/1/2016- Monday Continue to TOOH laying down 4.5" Tubing to 3,000'. Work on Rig Engine, MPU Mechanic checking Service alarm light on Rig Engine. Continue to TOOH, Laying down 4.5"Tubing. LD Fiber optic jt. &cut jt (4.51'). Recovered 381 full clamps and 12 - 1/2 clamps. Clear rig floor of all equipment not needed. Move pipe rack. Rig down & LD casing jacks. Replace pipe rack. Fish Cannon Clamp (1) out of BOP stack. NU riser on BOP stack. Load 2-7/8" PH-6 on pipe rack. Strap 1st row. PU BHA w/8-1/2" junk mill, 9-5/8" scraper. PU 60 jts. of 2-7/8" f/surface to ±1,800'. 8/2/2016-Tuesday Continue to TIH picking up 2-7/8" PH6 Work String to 14,445'. Obtain parameters. PUW 105k-SOW 38k. PU jt.#465 and tag 7" liner top w/5k down. NOTE: While RIH, RU to take returns through manifold and inject same into NS-10 (approved by NS Production Supervisor). LD jt.#465. RU to circulate pumping down tubing and taking returns out IA to manifold & inject into NS-10. Line up to header and fill pits w/seawater. Hold PJSM with crew and Pad Operator.Test lines to 2,500psi. Pump 450 bbls of clean seawater down tubing taking returns out IA and injecting same into NS-10 w/3 bpm. Initial injection pressure= 750psi. Final injection pressure = 1,100psi. Shut in NS-10. Blow down lines. RU to reverse circulate taking returns to pits. Reverse circulate w/4 bpm while adding 1 drum of corrosion inhibitor every hour(225 bbls)to achieve 0.5%. Initial reverse circ. rate & pressure = 3-1/2 bpm, 2,350psi. • • Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-18 ASR#1 50-029-23102-00-00 202-141 7/15/16 8/21/16 Daily Operations: 8/3/2016-Wednesday Reverse Circulate with 0.5%Corrosion Inhibitor @ 3.5 Bbls. Per Min. @ 2,350psi for a total 680 bbls. Reverse an additional 200 bbls clean seawater(no inhibitor)to cap off well and allow for upcoming tubing displacement. POH LD 2-7/8" PH-6 work string (464 jts). LD Mill &Scraper assembly. Clear/Clean floor. Clear pipe rack. Change over to 4-1/2" handling equipment. MU hanger to landing joint. PU same. "Dummy" run hanger and land in wellhead. OK. LD hanger. Load Packer, XN nipple,X nipples on off side of pipe rack. Load 45 jts on pipe rack and strap same. PU tailpipe assembly w/WLEG,XN- nipple (w/XN plug installed), X-Nipple & Baker"S3" packer. BakerLok all connections below packer. PU X-Nipple assembly above packer. 8/4/2016-Thursday TIH, Picking up 4.5" VAM Top Completion Tubing 169 Joints to 7,000'. Service Rig, Clean EGR Sensor&Clear Codes. Continue to TIH, Picking up 4.5"VAM Top Completion Tubing (308 Jts). Pick& Make up 6.875 OD SSSV, Hang sheave in Derrick, Connect 1/4 Control Line to SSSV, Pressure Test to 5,000 psi Function Test Valve, Holding 4,500psi on Line while RIH. Continue to TIH, Picking up 4.5" VAM Top Completion Tubing(Jts 309 to 331). Pick& Make up Tubing Hanger, Replaced top Seal on Hanger, Cut and Run Cap String Through Hanger, Install Valve Pressure up 4,500psi Close Valve, Land Tubing Hanger RILDS Break out Lay Down Landing Joint P/U/W=82K S/O/W=32K (Total Its Ran 331; Total Flat Bands Ran 26). Close Blind Rams Fill Tubing With 211 bbl. Pressure up on Tubing&Set Baker S3 Packer to 4,000psi Charted. 8/5/2016- Friday Rig up on Backside, Pressure up on backside 4.5"Tubing X 9-5/8"to 3,100psi. Charted for 30 minutes. PJSM, Rig up Halliburton Slick Line, Run# 1 RIH with RD to 13,904' SLM, Pull Prong& POOH. Make up GX,TIH to 13,908' SLM Pulling Very Slow out of Hole, Ports are Clogged on Tool, able to pull out of the hole at 60 ft per minute, to 5,700' SLM.Then slowed down,to 10 ft per minute pulled up to 4,400 SLM,Attempt to Shear GS with no luck, Pulled to 4,056'. Shear GS. POOH , RD Halliburton Slick Line. Well head Rep Tee Bar and Install TWC Valve in Tubing Hanger. Electricians Disconnected Fire and Gas Alarms, Blow down and Disconnect all Lines, Prep Rig Floor and Derrick, Break over and Lower Derrick onto Carrier. Moved Rig off of Mud Boat, Move Well site Trailer& Cat Walk, Nipple down Bop Stack to Four Bolts. Remove Rig Floor, Removed 13-5/8" Spacer Spools, Stairs and Well House, Remove BOPE Load on Rig Mats. Install and Nipple up Production Tree,Torque up Connections. 8/6/2016-Saturday Test Hanger Void to 500/5,000psi.Test Tree to 5,000psi. Pull TWC, Install Tree Cap. Rig Down Equipment& Prep Rig for Barging. 8/7/2016-Sunday Rig up slickline to pull DGLV and set circ valve in GLM #3. PT 250psi/ 1,800psi-good test Slickline completed setting circ 8/8/2016-Monday Slickline pulled Circ valve from GLM #3. Set DGLV in GLM #3. Bled tubing from 1,500psi to 750psi. DGLV holding. IA still 1,500psi. 8/9/2016-Tuesday Slumberger E-line and Halliburton E-line travel to Northstar. Tested WLV's. Check HES equipment with SLB equipment. • • • II Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-18 E-Line 50-029-23102-00-00 202-141 7/15/16 8/21/16 Daily Operations: r 104 8/10/2016-Wednesday Rig up Schlumberger E-line with Halliburton logging tools. Ran cement bond log on 9-5/8" liner. Shot 20' of perforation 14,456' to 14,476' ELMD. 8/11/2016-Thursday PT 250/2,200 PSI (GOOD TESTS) +17' CORRECTION. RAN A 1.85" CENT, 1-3/4" SAMPLE BAILER, DRIFT DOWN TO 11,150' SLM (11,167' MD), NO RESTRICTIONS. RAN A 1.85" CENT, SOFT SET, DUAL TANDEM SPARTEK GAUGES, START TIME 15:26, 150' PER MINUTE. MADE 5 MINUTE STOPS AT DEPTHS LISTED IN JOB LOG. GOOD DATA. RDMO. 8/12/2016 - Friday No activity to report. 8/13/2016-Saturday No activity to report. 8/14/2016-Sunday No activity to report. 8/15/2016- Monday No activity to report. 8/16/2016-Tuesday No activity to report. 0 • 1 II Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date NS-18 Slickline 50-029-23102-00-00 202-141 7/15/16 8/21/16 Daily Operations: 8/17/2016-Wednesday (Well s/I on arrival) P/T TO 250 LOW, 3,500 HIGH (pull gauges). PERFORMED WELL CONTROL DRILL PULLED 3.813" XN-LOCK, FLOW THROUGH SUB, DUAL SPARTEC GAUGES FROM XN NIPPLE @ 13,905' MD 13,883' SLM. RAN BARBELL 3.65" DRIFT, AND TAGGED 9-5/8" X 7" LINER TOP PACKER @ 14,450' SLM, 14,471' MD. UNABLE TO MAKE IT PAST. RDMO - NOTIFIED PAD OP AND CONTROL ROOM OF DEPATURE. 8/18/2016-Thursday Bringing in eline from prudhoe for adperf job 8/19/2016- Friday WELL SHUT IN UPON ARRIVAL(ELINE ADPERF) PT 250 PSI LOW/3,000 HIGH. RAN 20' X 2.88" HSD 6SPF W/ NOVA CHARGE PERF GUN, SHOT INTERVAL @ 14,436' - 14,456'. DEPTH CORRECTED TO HES CBL LOG DATED 10-AUG-16. ALL SHOTS FIRED. LAY DOWN EQUIP FOR NIGHT-TURNED WELL OVER TO DSO TO POP FOR NIGHT, WILL RESUME PERFORATING AFTER WELL TEST SAMPLE IS TAKEN IN THE MORNING. 8/20/2016-Saturday WELL FLOWING UPON ARRIVAL(ELINE ADPERFS) PT 250 PSI LOW/3,000 PSI HIGH. WELL SAMPLES TAKEN BY SLB BEFORE RUNNING NEXT SET OF GUNS. RAN 20' X 2.88" HSD 6SPF PERF GUN W/ NOVA CHARGES- PERFORATED INTERVAL @ 14,390' - 14,400'. RAN 10' X 2.88" HSD 6SPF PERF GUN W/ NOVA CHARGES- PERFORATED INTERVAL @ 14,400' - 14,420'. DEPTH CORRECTED TO HES CBL LOG DATED 10-AUG-16. LAY DOWN EQ. FOR NIGHT-TURN WELL OVER TO DSO TO POP FOR NIGHT. 8/21/2016 -Sunday WELL FLOWING UPON ARRIVAL (ELINE ADPERFS) PT 250 PSI LOW/3,000 PSI HIGH. RAN 20' X 2.88" HSD 6SPF PERF GUN W/ NOVA CHARGES- PERFORATED INTERVAL @ 14,338'-14,358'. DEPTH CORRECTED TO HES CBL LOG DATED 10-AUG-16. RIGGED UNIT DOWN ELINE UNIT FULLY FOR STORAGE. WELL POPPED BY DSO PRIOR- HAND OVER AREA TO DSO AND OPS. 8/22/2016- Monday No activity to report. 8/23/2016-Tuesday No activity to report. pro lir' • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday,August 12, 2016 2:52 PM To: Wyatt Rivard (wrivard@hilcorp.com) Subject: FW: NS-18 (PTD#202-141) Production Tests- Flaring Request Follow Up Flag: Follow up Flag Status: Flagged From: Schwartz, Guy L(DOA) Sent: Friday, August 12, 2016 2:51 PM To: Loepp, Victoria T(DOA) Subject: RE: NS-18 (PTD # 202-141) Production Tests- Flaring Request Wayatt, You have approval to flare well NS-18 as proposed below for a period of 2 weeks or 4 mmscf. If further flaring is needed contact the AOGCC. Regards, Guy Schwartz Sr. Petroleum Engineer scoop FEB 1 5 201i<, AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: Loepp, Victoria T(DOA) Sent: Friday, August 12, 2016 1:54 PM To: Schwartz, Guy L(DOA) Subject: RE: NS-18 (PTD # 202-141) Production Tests- Flaring Request Guy, Approval of this flaring sounds fine- Victoria From: Wyatt Rivard [mailto:wrivard@hilcorp.com] Sent: Friday, August 12, 2016 11:01 AM To: Loepp, Victoria T(DOA) Subject: NS-18(PTD # 202-141) Production Tests- Flaring Request Hello Victoria, 1 • • Hilcorp would like to request permission for intermittent flaring to kick off Northstar producer NS-18(PTD#202-141)as we continue to test the newly completed Kuparuk well. Background NS-18 was recently recompleted to the Kuparuk A sands with the first 20'pert interval successfully shot as per sundry# 316-343.The well was successfully kicked off on 8/11/16 for testing but the gas had to be taken to the low pressure flare system briefly for a four hour period to reduce back pressure and allow the well to continue unloading workover fluids and ultimately surface production fluids. The well flowed for"'12 hrs then was shut-in to allow Slickline to install a downhole pressure/temperature gauge to monitor flow.An attempt was made to bring the well back online,first taking the gas to the high pressure gas compressor for approximately 4 hours then taking the gas to the low pressure flare system for a 3 hr period but the well would not surface fluids though the well continues to flow gas at^'4 mmscfpd. It is believed that well cannot surface production fluids with the current 20'of perfs unless the gas is initially taken straight to the low pressure flare system. Once the well surfaces fluids,it should continue stable production while flowing gas to the high pressure gas compressor. Request Going forward Hilcorp would like to flow the well to as low a back pressure as possible to periodically kick off the well. The well will be intermittently shut-in as we test SVS systems,obtain samples and pull/set downhole gauges. Hilcorp would like to be able to conduct a series of short term flaring events, if needed,to kick the well off following these shut- in periods.The next set of perfs will occur within two weeks and is expect to increase the well's gas rate and improve its ability to unload and flow. o Total Duration:Two Weeks or until next set of perfs is added,whichever comes first.Short term flaring events only to unload the well as needed. o Anticipated Gas Rate:4 mmscfpd based on current gas production rate. During this time, rates would be monitored and all volumes would be submitted at the end of the month. If you would like to discuss this further please feel free to contact me. Thank You, Wyatt Rivard { Well Integrity Engineer 0: (907) 777-8547 C: (509)670-8001 I wrivardPhilcorp.com 3800 Centerpoint Drive,Suite 1400 (Anchorage,AK 99503 11iI ri► tl�•lr. 1.11.4. 2 • • OF T11 As I%y s,, THE STATE Alaska Oil and Gas 0��L1 1 Conservation Commission 333 West Seventh Avenue 07 C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O Q, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Mike Operattiions Manager SCWIE® FEB 0 2201-L Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Northstar Field, Kuparuk C Undefined Oil and Northstar Oil Pools,NU NS-18 Permit to Drill Number: 202-141 Sundry Number: 316-343 Dear Mr. Dunn: 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, "447g. Daniel T. Seamount Commissioner DATED this it' day of July, 2016. RBDMS c.'- JUL 1 4 2016 RECEIVED STATE OF ALASKA JUN 2 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations Q ' Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate Q /,/..,i)ther Stimulate ❑ Pull Tubing Q • Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool [ Re-enter Susp Well ❑ Alter Casing ❑ Other: CAS tpC., ,c El 2.Operator Name: 4.Current Well Class: ,,�� / 5.Permit to Drill Number. Hilcorp Alaska LLC Exploratory ❑ Development/'O 202-141 - 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Serviceiv- ,L.5 ❑ 6.API Number. Anchorage Alaska 99503 50-029-23102-00-00 . 7.If perforating: K, -n Gid Qr l, zOAicic 05-3--- 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool?A/5 el jC: C.O. 458A Will planned perforations require a spacing exception? Yes ❑ No Q •4,-43'14 NORTHSTAR UNIT NS-18 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0312799 • NORTHSTAR/KUPARUK C UNDEF OIL&NORTHSTAR OIL ' 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): 16,865' • 11,117' • 16,856' 11,109' 208 16,856' N/A Casing Length Size MD TVD Burst Collapse Conductor 201' 20" 201' 201' N/A N/A Surface 4,033' 13-3/8" 4,033' 3,207' 5,020psi 2,260psi Production 14,668' 9-5/8" 14,668' 9,234' 6,870psi 4,760psi Liner 2,070' 7" 16,541' 10,815' 7,240psi 5,210psi Liner 503' 4-1/2" 16,865' 11,117' 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-ACE 16,367 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9-5/8"x7"Liner Top,7"x4-1/2"Baker S-3&7"x5"Liner Top 14,471'(MD)/9,089'(TVD), 16,323'(MDy 10,615'(TVD)&16,362'(MDy 10,650(TVD)and and TRM-4E SSSV 1,045'(MDy 1,041'(TVD) 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development[ • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Operations: 7/27/2016 ❑ ❑ ❑ Suspended ❑ Commencing OIL ✓ WINJ WDSPL 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ 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. Contact Taylor Wellman Ti(,/ Email twellmanahilcorp.com Printed Name / Mike If n Title Operations Manager if, 6/22,146 Signature / Phone 777-8382 Date 7127/2 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness ' Sundry Number. Plug Integrity ❑ BOP Test [Yr Mechanical Integrity Test 111 Location Clearance ❑ Other: ..K! 3Orc• /0S LS 3OE' Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS 0- JUL 1 4 2016 Spacing Exception Required? Yes ❑ No Subsequent Form Required: I 0—y09 APPROVED BY j Approved by: 7--/6/19 COMMISSIONER THE COMMISSION Date: 1-1�- ,t..Q JJ� 1` ORrf6sIlPNiAsEidSubs int Form ane kt Revised 11/2015 for 12 months from the date of approval. Attachments in Duplicate 4:4 741-lG401, / b /C, • Recomplete Well: NS-18 PTD: 202-141 llitcoru Alaska,l L API: 50-029-23102-00-00 Well Name: NS-18 API Number: 50-029-23102-00-00 Current Status: SI - Producer • Pad: Northstar Island Estimated Start Date: July 27, 2016 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: 315-230 Regulatory Contact: Tom Fouts Permit to Drill Number: 202-141 First Call Engineer: Taylor Wellman (907)777-8449 (0) (907)947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: 1620567 Sundry/WeIIEZ Input Req'd Yes Current BHP (Ivishak): 5114 psi @ 11,100' TVD (BHP from NS-15 measured 11/12/2015) Equivalent Mud Weight: 8.9 ppg Max Expected BHP (Kuparuk): —4425 psi @ 9,000' TVD (Based on offset RFT data) Equivalent Mud Weight: 9.5 ppg MPSP: 208 psi Based on plug and cement isolating the Ivishak formation, no other perforations in the well, and / column of 8.5ppg seawater. 3525 psi I (Based on a gas gradient of 0.1 psi/ft and if L ��,� ��"' ��� exposed to the Kuparuk—Kuparuk will not be perforated until after the RWO completion) Brief Well Summary: The Northstar 18 well was drilled as an Ivishak development well that TD'd at 16,865' and with a 9-5/8" production casing x 7" intermediate liner x 4-1/2" production liner in January of 2003. During completion activities the casing was tested to 4200psi. The well as perforated in the Ivishak sands. In October 2007, the tree was changed out from a partial clad system to a fully clad tree and pressure tested to 5000psi. No other mechanical issues have been observed to date. The well's downhole location is on the higher portion of the structure and the well produces as a cycle well with marginally competitive GOR's. Notes Regarding Wellbore Condition kciG-S ,.�' Current well status is in operable and good mechanical condition. • At-14 RWO Objective: Isolate the current Ivishak formation and recomplete the well to be able toroduce from the Ku aruk p p L..,,,formation higher in the well. Pre-Workover Prep Procedure: 1. MIT-IA to 2000psi. 2. Spot Slickline unit and RU unit. 3. Pressure test lubricator to 300psi low/4200psi high. 4. Drift with 3.0" dummy plug. a. Target CIBP set depth is 16,750' md. V 5. MU SBHP memory gauges. RIH with gauges at a constant speed. a. While POOH make 5 min stops at the following depths: 16,613' md(10,900'tvd); 16,395' md(10 700' tvd); 16,174' md(10 500'tvd). afr/ A0.0 I ,onGvi . Rese,veS /tw'ew Compete4i f '0/ jU �y ,3U-23D „ex,/ted J T441- /OP wvrK• „/"K" 54,6 Recomplete • Well: NS-18 PTD: 202-141 API: 50-029-23102-00-00 IIileorn Alaska,LU 6. RD Slickline. 7. Spot E-Line unit to well and RU unit. 8. Pressure test lubricator to 300psi low and 4000psi high. 9. Set CIBP at+/- 16,750. Bleed tubing pressure down by 1000psi and monitor for 30 min to check for solid plug set. 10. Load 50bbls of seawater into tubing and allow to fall onto plug. 11. Dump 25' of cement onto plug up to+/- 16,725'. 12. Load tubing with seawater. a. A minimum of 224 bbls of seawater will need to be pumped into the tubing. This would leave the fluid level at approx. 3000' md. After pumping into the tubing and with Opsi on the tubing and IA, the tubing and IA will be hydrostatically equalized at proposed cut depth. The IA is filled with 5455' of diesel and the rest is inhibited seawater. 13. Increase tubing pressure to"500psi. 14. RIH with jet cutter. Cut tubing in the middle of the 15t pup joint above packer @ +/-16.317_' md. Note pressure equalization in report. a. Use tubing tally dated 01/13/2003 as reference log. b. Cut depth must be done below Fiber Optic Transducer to avoid cutting any control line. 15. RU hardline and have LRS pump down the IA of well 18 and take returns from the tubing and down the flowline. 16. Circulate well clean with seawater(approx.^'135 deg F) down IA and up tubing while taking returns to the facility. a. The combination of partially heated seawater and the diesel freeze protect in the IA will help to clean the tubing in preparation to pull to surface. 17. CMIT-TxIA to 2000psi. _ vru� Workover Procedure: 18. Mobilize ASR#1 from Endicott dock and offload onto Northstar Island. 19. Verify 0 psi on the annulus and tubing pressure. 20. Set BPV, ND tree, NU 13-5/8" BOP's. a. Make scribe mark on tree for orientation for re-installation. b. Function test all prior to arrival of AOGCC inspectors. y. � 21. Spot and rig up ASR#1 and all supporting equipment. ( ma22. PU Casing Jacks vja the beaver slide and Tugger winches to rig floor. IK" 23. Set casing jacks on top of the BOP Annular with Tuggers. Connect Hydraulics and function test same. 24. Check for pressure and if Opsi, pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, circulate 8.5ppg seawater and confirm dead prior to pulling BPV. Set TWC. 25. Test BOPE to 250j si Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure dated 11/03/2015. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8" and 4-1/2"test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. • • Recomplete Well: NS-18 PTD: 202-141 API: 50-029-23102-00-00 Hilcora Alaska,LL, 26. Contingency: (If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor y�S the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) 4ti d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves, gas detection,etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 27. Bleed any pressure off casing to 500bbl returns tank. Pull TWC. 28. Casing Jack RU Procedure: a. RU Casing jack Hydraulics to the ASR#1 control Panel. Set pressure relief high point as 2,038 psi ✓' (equates to—230.4k#or 80%of yield strength). b. Yield strength of 4-1/2", 12.6#, 13CR= 288k#, and the VAM connections=288k#. c. String weights during 2003 completion: PUW=230k#,SOW=160k#. The blocks on Nabors 33-E were approximately 60k#. d. Cycle jacks up and down to ensure proper function (dry run without being connected to hanger). 29. MU 4-1/2" landing joint and BOLDS. 30. Set Casing Jack pressure to 1,592 psi (180,000 lbs). Slowly pressure up on jacks. Hold for 5 min. a. 16,303' of 4-1/2"tubing= 206k#dry/179k# buoyed in 8.5ppg. 31. If hanger does not unseat, increase pressure in 100 psi increments holding for 5 min between pressure increases. Note: do not exceed 2,(238 psi (230.400#). If unmoved contact Ops Engineer for further discussion. a. Contingency: If tubing will not pull, RU EL and jet cut tubing in the middle of 2nd pup joint above the packer at+/-16,307' md. 32. Once hanger becomes free check for flow to insure well is dead. LD Tubing hanger. a. Use of the additional bowl assembly will be used to increase stroke length of jacks when unseating hanger. b. Contingency: (If a rolling test was conducted.) i. MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 33. RU Spoolers and continue to jack 4-1/2" tubing from cut at+/-16,303', and lay down the same in singles. a. From 0—1045'there is a%" control line to the TRSSSV and a fiber optic line to the downhole gauge. ,I�. From 1045'—16,276'there is a fiber optic line to a CIDRA Gauge (Weatherford). • Recomplete Well: NS-18 PTD: 202-141 Ilitcoro Alaska,Lb API: 50-029-23102-00-00 c. There are 393 Canon Clamps installed (1 per joint) and 7 half clamps holding the control line and fiber optic line in place. / d. ASR rig can pull —155k#. The initial 3000' of tubing will need to utilize Casin Jg acks to pull the `"�` tubing from the well. (13,600' of 4-1/2", 12.6#tubing=-150k#buoyed weight in 8.5ppg seawater). While using casing jacks, do not attempt to save the 4-1/2"tubing recovered from the well. The use of casing jacks will generate hard spots and will damage the tubing. Mark these joints so they are not inspected for re-use. 34. Once the string weight is comfortably less than 150k#, set tubing in lower slips, retract casing jacks into lowered position and swap to 'Carriage mode'. Resume pulling the completion utilizing upper slips only with rig while laying down the same in singles. a. Install thread protectors on tubing after use. Thread protectors are made for VAM TOP threads but are still acceptable for this purpose. Tubing should be sent to inspection to make ready to re-use. 35. Use inverted test plug to install wear bushing. 36. PU 2-7/8" workstring and MU 9-5/8" mule shoe casing scraper assembly. RIH and wash to 14,000' and circulate x2 bottoms up or until clean returns are observed. a. Packer setting depth is+/- 13,850' md. 37. Line up to reverse circulate and reverse circulate 680bbls of completion fluid into well at 4-5 bpm. a. Completion fluid to be seawater w/0.5%corrosion inhibitor. 38. POOH w/2-7/8" workstring and lay down. a. Monitor fluid level in well and fill as needed (-3.5gaI/joint). 39. MU 4-1/2", 13CR completion and begin to run. a. Ensure XN plug is set in the XN nipple in the tubing tail prior to running. b. Displacement from the well will be"'0.80 bbl/joint. 40. Run 4-1/2", 13CR tubing tail and completion with packer to setting depth. a. Packer setting depth is+/- 13,857' and and the WLEG depth is+/- 13,925' md. b. Note the Baker S-3 packer is a hydraulically set and will only set with a hydrostatic overbalance of pressure from the inside of the tubing string. Risk of setting due to RIH speed is negligible. ft ej- c. A single SSSV control line will be run from +/- 1000'TVD to surface. d. Enclosed table are the projected weights of the completion during running with a plug in tubing 4J string and 8.5ppg seawater in the wellbore. 41 MD (ft) TVD (ft) Dry wt (k#) Projected Hook Load Wt (k#) bcjV 1,000 997 13 4 3,000 2,641 38 14 5,000 3,773 63 28 7,000 4,841 88 43 9,000 5,910 113 57 11,000 7,045 139 71 12,000 7,576 151 78 13,000 8,157 164 85 14,000 8,765 176 92 Table 1—Projected hook loads w/plug in tubing tail while running completion 41. Space out and land the tubing into the hanger. RILDS. Lay down landing joint.Test tubing hanger to 250psi low/5,000psi High. • Recomplete Well: NS-18 PTD: 202-141 LL API: 50-029-23102-00-00 • 'blear!)Alaska. a. Space out to the nearest joint and shift depths accordingly. b. Note PU (Pick Up) and SO (Slack Off)weights on tally. 42. Load tubing and hydraulically set the packer as per Baker's setting procedure. 43. Conduct MIT-T to 3000psi and MIT-IA to 3100psi. (A,,< 44. Terminate the control line. Pressure test control line to 5000psi and the tubing hanger to 5000psi. 45. Test TRSSSV. 46. Set BPV. 47. RU SL and pull XN plug from +/-13,820' md. Drift to 14,600' and w/2-7/8" dummy gun. RD SL. 48. RD Hilcorp ASR#1 WO Rig, ancillary equipment and lines to 500bb1 returns tank. Post Workover Procedure: 49. RD mud boat. RD BOPE house. 50. RU crane. ND BOPE. Pull BPV.Set TWC. 51. NU 4" 5,000#tree and adapter flange and test to 500 psi low/5,000 psi high. 52. Test tubing hanger void to 500psi low/5,000psi high. 53. Pull TWC. RD crane. 54. Move 500bbl returns tank and rig mats. 55. Spot Slickline unit and RU. 56. Pressure test lubricator to 300psi low and 4000psi high. 57. Pull dummy GLV's for kick off design. 58. Set kick off GL design (kick off design to be provided in well folder). 59. RD Slickline. 60. Spot E-Line unit to well and RU unit. 61. Pressure test lubricator to 300psi low and 4000psi high. q• 62. Perforate+/-14,195'—14,470' and (specific intervals to be determined at a later date and confirmed on final perforation sheet). 63. RD E-Line and demobilize from island. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic • Northstar Unit • Well: NS-18 PROPOSED Last Completed: 1/17/2003 Hilcorp Alaska,LLC PTD: 202 141 CASING DETAIL KB Elev.:55.85'/BF Elev.:39.9'(CB 15.9') Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 169/X-56/N/A N/A Surface 201' 20 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' 410 1 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' ( 2 TUBING DETAIL 4-1/2" Tubing 12.6/13CR/VAM-TOP 3.958 Surface ±13,925' 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 ±16,310' 16,362' 3 JEWELRY DETAIL 13-5/8".4 , if No Depth Item 4 .} 1 ±1,000' 4-1/2"TRM-4E SSSV w/4-1/2"w/X Profile,ID=3.812 `' 2 ±1,625' 13-3/8"DV Tool 5 :', 3 ±3,917 GLM 1 4 ±8,559' GLM 5 ±11,974' GLM 6 ±13,817' X Nipple 7 ±13,857 9-5/8"x4-1/2"Packer 1 6 8 ±13,885' X Nipple A�: -7 7 9 ±13,905' XN Nipple 8 10 ±13,925' WLEG I9 �, 11 14,471' 9-5/8"x 7"Baker ZXP Liner Top Packer 10 12 14,490' 9-5/8"x 7"Baker Liner Hanger Ki t f 13 16,276' 4-1/2"Fiber Optic Transducer,ID=3.958"(16,281'ELM) 11 rt-r 14 16,301' 4-1/2"HES X Nipple,ID=3.813 1 12 15 16,323' 7"x 4-1/2"Baker 5-3 Packer,ID=3.875" A 16 16,347' 4-1/2"HES X Nipple,ID=3.813 17 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) 9-5/g'I 1 18 16,362 7"x 5"Baker ZXP Liner Top Packer 19 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" 20 ±16,750' CIBP PERFORATION DETAIL i° , 13 Sands Top(MD) Btm(MD) Top(TVD) Btm(ND) FT Date Status 1, 1 14 1 Kuparuk Sands ±14,195' ±14,470' ±8,896' ±9,088' ±275 FUTURE FUTURE Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed ". 15 `; WELL INCLINATION DETAIL KOP @ 351' ' P= Max Hole Angle=59 deg. @ 3,590' Angle at Top Peri=47 Deg.@ 14,195' _ OPEN HOLE/CEMENT DETAIL 17 1 a"1819 13-3/8" 669 sx PF 1',472 sx Class'G'in 16"Hole 7" a 9-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole 7" 325 sx Class"G"in 8-1/2"Hole 4-1/2" 93 sks Class"G"in 6-1/8"Hole TOC@±16,72(Y TREE&WELLHEAD Tree ABB-VGI 5-1/8"5KSI 20 Wellhead ABB-VGI 13-5/8"Multibowl 5KSI GENERAL WELL INFO API:50-029-23102-00-00 Drilled& Cased by w/Nabors 33E -1/5/2003 4-1/2" Original Completion w/Nabors 33E-1/15/2003 Perforate w/Nabors 33E-1/22/2003 TD=16,865'(MD)/TD=11,117'(1VD) Add Perforations -12/8/2005 PBTD=16,856'(MD)/PBTD=11,109'(ND) Updated By:TTW 6/13/2016 • . Northstar Unit Well: NS-18 • SCHEMATIC Last Completed: 1/17/2003 Hilcarp Alaska,LLC PTD: 202-141 CASING DETAIL KB Elev.:55.85'/BF Elev.:39.9'(CB 15.9') Size Type Wt/Grade/Conn Drift ID Top Btm , 04 20" Conductor 169/X-56/N/A N/A Surface 201' 20 . !, L k* 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' rr +:q ' 9-5/8" Intermediate 47/L-80/Btc-M. 8.681 Surface 14,668' 1 11 k+ 1 , 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' k4 rs 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' 2 TUBING DETAIL ) 0,1 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 0 16,362' I 1 JEWELRY DETAIL 5/8yLI No Depth Item 1 1,045' 4-1/2'TRM-4E SSSV w/4-1/2"w/X Profile,ID=3.812 s 2 1,625' 13-3/8"DV Tool 3 6,355' SMOR GLM w/Dummy Valve and BK Latch 4 7,516' SMOR GLM w/Dummy Valve and BK Latch 5 14,471' 9-5/8"x 7"Baker ZXP Liner Top Packer "` 3 6 14,490' 9-5/8"x 7"Baker Liner Hanger kA i 7 16,276' 4-1/2"Fiber Optic Transducer,ID=3.958"(16,281'ELM) F.- 8 16,301' 4-1/2"HES X Nipple,ID=3.813 4 9 16,323' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 10 16,347' 4-1/2"HES X Nipple,ID=3.813 11 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) i` ' 12 16,362 7"x 5"Baker ZXP Liner Top Packer 13 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" 14 16,384' 9-5/8"x 7"Liner Hanger ' 15 16,393' 5"x 4-1/2"X0,ID=3.958" IN ►_.' 5 PERFORATION DETAIL i w - v'6 !! Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 9-5/8"A Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Open 7 Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Open vaxWELL INCLINATION DETAIL 8 Lh` KOP @ 351' i Max Hole Angle=59 deg. @ 3,590' I, '174 ra 9 Angle at Top Perf=20 Deg.@ 16,775' 61 '10 OPEN HOLE/CEMENT DETAIL lZ 13-3/8" 669 sx PF'L',472 sx Class'G'in 16"Hole ' _ q 9-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole 11 7" 325 sx Class"G"in 8-1/2"Hole k" 4-1/2" 93 sks Class"G"in 6-1/8"Hole ti t I TREE&WELLHEAD Tree ABB-VGI 5-1/8"5KSI 12 Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 13 s' ;1415 GENERAL WELL INFO 7 � � , ,a API:50-029-23102-00-00 "rant Drilled& Cased by w/Nabors 33E -1/5/2003 r Original Completion w/Nabors 33E-1/15/2003 s r Perforate w/Nabors 33E-1/22/2003 Add Perforations -12/8/2005 x aK 4-V2" et TD=16,865'(MD)/TD=11,117'(TVD) PBTD=16,856'(MD)/PBTD=11,109'(TVD) Revised By:TDF 4/15/2015 • •• r , ll Northstar ASR 13-5/8" BOP w/Jacks Ifa.,c" 06/14/2016 slips x .i 200 TON JACKING SYSTEM Slips ASP • • 111 Iii IIt ll 111 lil Il 11t tt$t. 1 III fit I4II In lei`^ ` Shrsffer ,:- r re - 2 7/8'"x 5"'VBR Rams Tire Blinds 21/16"5M Kill Valves '17.1 2 1/1.6' 5M Choke Valves Manual and Manual Manual and HCR III DT III l!I Itl ► 0.14 4% ' fill I I Ilil �% , PTD ZoZ-i it Loepp, Victoria T (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Monday,June 29, 2015 12:49 PM To: Loepp, Victoria T(DOA) Subject: RE: NS-18 (PTD #202-141, Sundry 315-230) Four Preventer BOP Stack Required Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thank you and as discussed,will be added to the BOP configuration. -Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907)777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, June 29, 2015 11:03 AM To: Taylor Wellman Subject: RE: NS-18 (PTD # 202-141, Sundry 315-230) Four Preventer BOP Stack Required Taylor, 20 AAC 25.285(c)(2)(C) requires a BOP stack of at least four preventers when MPSP>3000psi. This four preventer BOP stack is required for the workover operation described in Sundry 315-141. Please include this BOP requirement with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer 2 t State of Alaska SCAMD JUL 12015 Oil&Gas Conservation Commission I�b,!'���`� 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppealaska.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 Victoria Loepp at(907)793-1247 or Victoria.Loeoe@alaska.gov 1 From: Taylor Wellman [mailto:twellman@hilcorp.com] Sent: Monday, June 29, 2015 10:03 AM To: Loepp, Victoria T(DOA) Subject: NS-18 (PTD # 202-141) Recompletion, Sundry 315-230 Victoria, Further review of the expected pressures in the Kuparuk confirm the MASP at 3100psi. A few pieces that are important to note are during the entire workover the well will not be open or exposed to either the Ivishak or the Kuparuk formations. - Ivishak will be isolated with a bridge plug and^'30'of cement placed on top via E-Line operations. This plug will also be pressure tested to 2000psi. - Kuparuk will be isolated by the 9-5/8" liner(MIT-IA during original completion to 4200psi and no signs of communication since). - The Kuparuk will not be perforated until the rig operations are completed. The perforations will be done via E- Line after the well is mechanically recompleted uphole. - The wellbore will be filled with seawater to be able to monitor for any signs of change. Thank you, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907)777-8449 Endicott: (907)777-8449 Cell: (907)947-9533 Email: twellman@hilcorp.com 2 OF 7� .0.-' \��j,, s THE STATE Alaska Oil and Gas F "'t'' � O Conservation Commission -_ ___ fALAS ;A .ti it x`__, 333 West Seventh Avenue if GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 T Main: 907 279.1433 �F4V� ALAS�P QY LO�3 Fax: 907.276 7542 Sa�SE© www aogcc alaska.gov Taylor Wellman Operations Engineer Hilcorp Alaska, LLC Q., (5 g--.- i 1/4 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Northstar Field,Northstar Oil Pool,NS-18 Sundry Number: 315-230 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, of / fij-/--t4Vf—•—_ Cathy '. Foerster Chair DATED this 4 day of May, 2015 Encl. RECEIVED • STATE OF ALASKA APR 1 7 20h ALASKA OIL AND GAS CONSERVATION COMMISSION or °-12-- //s APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 ,-,/ 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool t✓J Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations E5r Perforate❑ Pull Tubing E Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0 • 202-141 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. 6'C., .`/•23 WL,c'r',a, 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029�-,34010-00-0,y 7.If perforating: Zcvs S 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? zebe C.O.458A Will planned perforations require a spacing exception? Yes ❑ No Q -i(--%� NORTHSTAR UNIT NS-18' 9.Property Designation(Lease Number): 10.Field/Pool(s): .�..i_ ADL0312799 • NORTHSTAR/NORTHSTAR OIL 1 K cr-� r.], ( 11. PRESENT WELL CONDITION SUMMARY �1tL ')4� Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Juhk(measured): 16,865. 11,117 16,856 11,109 16,856' N/A Casing Length Size MD ND Burst Collapse Conductor 201' 20" 201' 201' Surface 4,033' 13-3/8" 4,033' 3,207' 5,020psi 2,260psi Production 14,668' 9-5/8" 14,668' 9,234' 6,870psi 4,760psi Liner 2,070' 7" 16,541' 10,815' 7,240psi 5,210psi Liner 503' 4-1/2" 16,865' 11,117' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 4-1/2" 12.6/13CR/VAM-ACE 16,362' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 9-5/8"x7"Liner Top,7"x4-1/2"Baker S-3&7"x5"Liner Top 14,471'(MD)/9,089'(TVD), 16,323'(MD)/10,615'(TVD)&16,362'(MD)/10,650(TVD)and and TRM-4E SSSV 1,045'(MD)/1,041'(TVD) 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: • Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic❑ Development Q Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/23/2015 Oil Q , Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: N/A WINJ 0 GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Taylor Wellman Email twellman@hilcorp.com Printed Name Taylor Wellman Title Operations Engineer Signature � Phone 777-8449 Date 4/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 - 2-50 Plug Integrity ❑ BOP Test Er Mechanical Integrity Test ❑ Location Clearance ❑ Other: OPP tt5 i tb yDoo ps , (/vt nsP / s 3iar ps,, O-vtnvlGtb' prC ✓ h f-Tr tt5/ tb 2,3--z7.0 `�5 Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY _ Approved by: 26//c"1 COMMISSIONER THE COMMISSION Date:.-S-- 4- -t S � L 4/ n D v N pp Suts in Form and / Form 10-403(Revised 10/2012) 10.3pi`d i i A. Or 12 months f the date of approval. Attachments m land BDMS–M. MAY - 6 101 `/.27-ic-- —y/ r" Recomplete Well: NS-18 PTD: 2021410 Hilcory Alaska,LL, API:50-029-23102-00 Well Name: NS-18 API Number: 50-029-23102-00 Current Status: SI Producer Pad: o Northstar Island Estimated Start Date: June 15, 2015 Rig: ASR 1 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 2021410 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(Ivishak): - 5083 psi @ 11,100'TVD (Last BHP measured 03/09/2014) Maximum Expected BHP (Ivishak): -5083 psi @ 11,100'ND (Last BHP measured 03/09/2014) 5-083 — (. i) (ti► oa) 3. 173- ,p5 ; Current Bottom Hole Pressure(Kuparuk): -4050 psi @ 9,000' ND (NS-08 BHP measured July2014) Maximum Expected BHP (Kuparuk): --4000 psi @ 9,000' TVD (Extrapolation from NS-08) Max. Anticipated Surface Pressure: 3100 psi ✓ (Based on a gas gradient of 0.1 psi/ft and exposed to the Kuparuk BHP from July2014) Brief Well Summary: The Northstar 18 well was drilled as an Ivishak development well that TD'd at 16,865' and with a 9-5/8" production casing x 7" intermediate liner x 4-1/2" production liner in January of 2003. During completion activities the casing was tested to 4200psi (with 8.5ppg seawater). The well as perforated in the Ivishak sands. In October 2007,the tree was changed out from a partial clad system to a fully clad tree and pressure tested to 5000psi. No other mechanical issues have been observed to date. The well's downhole location is on the higher portioof the structure and the well produces as a cycle well with marginally competitive GOR's. ,j (cniCvf. t./ i nFQ/yyat/oqmy er/ S,r j g /o We 11�to ff.'l co,/ Ifi) 4 fonif 74 f 714,)- Notes 3-,fNotes Regarding Wellbore Condition j,t / over 1'1,e AN)/ w/fge ' '- ' ' 601Z a 17 01/,s (i t l,,;if VQ ue. fligr4 f tell P4c /Vv�7 4ftgi �� ( /an l Current well status is in operable and good mechanifa�candition. Co ,'t fan `e co (� /`4 /_ RWO Objective: (�(�,/Qi'k j cMaf► �a /kdd q/lOw kr ,'rsfloved /CCDver, b.604 id,Z Isolate the current Ivishak formation and recomplete the well to be able to produce from the Kuparuk formation higher in the well. i/�� �j Pre-Workover Prep Procedure: � y 1. Spot Slickline unit and RU unit. 2. Pressure test lubricator to 300psi low/4200psi high. 3. Drift with 3.70"dummy plug. 4. RD Slickline. 5. Spot E-Line unit to well and RU unit. 6. Pressure test lubricator to 300psi low and 4000psi high. Recomplete Well: NS-18 PTD: 2021410 HiIconu Alaska,LLAPI:50-029-23102-00 7. Set CIBP at+/- 16,750. 8. Dump 30' of cement onto plug up to+/- 16,720'. 9. Punch tubing at+/-16,304' md. Note pressure equalization in report. 10. Cut tubing mid joint in 1st pup joint above packer(+/-16,312' md). 11. RD E-Line and demobilize from island. 12. Circulate well clean with seawater down IA and up tubing while taking returns to the facility. 13. CMIT-TxIA to 2000psi. Workover Procedure: 14. Mobilize workover unit from Westdock and offload onto Northstar Island. 15. Spot and RU workover unit and supporting equipment. 16. Verify 0 psi on the annulus and tubing pressure. 17. ND tree, NU 13-5/8" BOP's,and set TWC. 18. Test BOPE to Sundry Requirements/250psi low/4,000psi high,Annular to 250psi low/2,500psi high. Notify AOGCC 24 hours in advance to witness test. Contingency: (If the tubing hanger won't pressure test due to the BPV profile is eroded and/or corroded and TWC cannot be set with tree on.) a. Notify Operations Engineer(Hilcorp), Mrs.Victoria Loepp(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path,test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. g. Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). h. If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 19. Pull TWC. 20. Pull hanger, pull 4-1/2"tubing from cut at+/-16,312',and lay down the same in singles. 21. MU and RIH with 9-5/8" mule shoe casing scraper assembly. Wash to+/-14,500'and circulate x2 bottoms up or until clean returns are observed. 22. RU Slickline and drift with 8.4" dummy to+/-14,200' md. POOH. 23. RD Slickline. 24. Run 4-1/2", 13CR completion assembly to packer setting depth. Dual SSSV control lines will be run from+/- 1000'ND to surface. 25. Space out and land the tubing into the hanger. Terminate the dual control lines. Pressure test control lines to 5000psi and the tubing hanger to 5000psi. 26. Set packer(drop ball and rod ) at+/-13,800' md, MIT-IA to 2500psi. 27. Shear RP valve and freeze protect to 2000'with diesel (tubing and IA). 28. Test TRSSSV. Recomplete Well: NS-18 PTD: 2021410 Ailcorp Alaska,LL API:50-029-23102-00 29. Set TWC, ND BOP's, NU tree,and test tree to 300psi low and 5000psi high. 30. Demobilize rig and depart Northstar Island. Post Workover Procedure: 31. Spot Slickline unit and RU. 32. Pressure test lubricator to 300psi low and 3500psi high. 33. Pull ball and rod. 34. Pull RHC ball seat. 35. Set dummy GLV in Station#1 (+/-5700' md). Confirm set with MIT-IA to 1000psi. 36. Drift tubing and casing with dummy guns. 37. RD Slickline. 38. Spot E-Line unit to well and RU unit. 39. Pressure test lubricator to 300psi low and 3500psi high. 40. Perforate+/-14,195'—14,470' md. 41. RD E-Line and demobilize from island. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: NS-18 14 SCHEMATIC Last Completed: 1/17/2003 llilcorp Alaska,LLC PTD: 202-141 CASING DETAIL KB Elev.:55.85'/BF Elev.:39.9(CB 15.9') Size Type Wt/Grade/Conn Drift ID Top Btm I' 'o20" Conductor 169/X-56/N/A N/A Surface 201' ,. � 13-3/8" Surface • 9 5/8" Intermediate 47/L68/-80/L-80/Btc-M.Btc 12.415 Surface 4,033' 8.681 Surface _ 14,668' 4 A 1 h 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' TUBING DETAIL !g % 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 0 16,362' 1 a 1 I JEWELRY DETAIL 13-5/8" No Depth Item 1 1,045' 4-1/2"TRM-4E SSSV w/4-1/2"w/X Profile,ID=3.812 2 1,625' 13-3/8"DV Tool ' 3 _ 6,355' SMOR GLM w/Dummy Valve and BK Latch 4 7,516' SMOR GLM w/Dummy Valve and BK Latch 1. 3 i� 5 14,471' 9-5/8"x 7"Baker ZXP Liner Top Packer f; 6 14,490' 9-5/8"x 7"Baker Liner Hanger ' ^4 7 16,276' 4-1/2"Fiber Optic Transducer,10=3.958"(16,281'ELM) V 8 16,301' 4-1/2"HES X Nipple,ID=3.813 4 9 16,323' 7"x 4-1/2"Baker S-3 Packer,10=3.875" e "r 10 16,347' 4-1/2"HES X Nipple,ID=3.813 i P 11 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM) r12 16,362 7"x 5"Baker ZXP Liner Top Packer 0 01 13 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" 4. 14 16,384' 9-5/8"x 7"Liner Hanger ; 15 16,393' 5"x 4-1/2"XO,ID=3.958" M>� 5 8 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status 9-5/8"1 i Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Open „ 7 Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Open rWELL INCLINATION DETAIL I8 KOP@351' _Max Hole Angle=59 deg. @ 3,590' w •1, i Angle at 9 Top Perf=20 Deg.@ 16,775' 1• 10 OPEN HOLE/CEMENT DETAIL ' 13-3/8" 669 sx PF l',472 sx Class'G'in 16"Hole 0 . ,, 119-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole M 1 1 " 7" 325 sx Class"G"in 8-1/Y'Hole >• !' 4-1/2" 93 sks Class"G"in 6-1/8"Hole yX F tA, TREE&WELLHEAD it, Tree ABB-VGI 5-1/8"5KSI S. •12 Wellhead ABB-VGI 13-5/8"Multibowl 5KSI 13 1415 GENERAL WELL INFO 7",A •, r API:50-029-23111-00-00 Drilled& Cased by w/Nabors 33E -1/5/2003 Original Completion w/Nabors 33E-1/15/2003 - Perforate w/Nabors 33E-1/22/2003 Add Perforations -12/8/2005 1 r ' i A % 4-1/2" .e TD=16,865'(MD)/TD=11,117(1VD) PBTD=16,856'(MD)/PBTD=11,109'(1VD) Revised By:TDF 4/15/2015 Milne Point Unit Well: NS-18 14 PROPOSED Last Completed: 1/17/2003 Hilcora Alaska,LLC PTD: 202-141 CASING DETAIL KB Elev.:55.85'/BF Elev.:39.9(CB 15.9') Size Type Wt/Grade/Conn Drift ID Top Btm '•c ` 20" Conductor 169/X-56/N/A N/A Surface 201' 22'� #�' 13-3/8" Surface 68/L-80/Btc 12.415 Surface 4,033' <d 9-5/8" Intermediate _ 47/L-80/Btc-M. 8.681 Surface 14,668' 1 7" Production 26/L-80/Hydril 521 6.276 14,471' 16,541' P 4-1/2" Liner 12.6/13CR/VAM-ACE 3.958 16,362' 16,865' �eil 2 ,; TUBING DETAIL t »M 4-1/2" Tubing 12.6/13CR/VAM-TOP 3.958 ±0 ±13,825' 4-1/2" Tubing 12.6/13CR/VAM-ACE 3.958 ±16,310' 16,362' il '4 JEWELRY DETAIL 13-5/8" i k.1 S" No Depth Item a3 e` 1 ±1,000' 4-1/2"TRM-4E SSSV w/4-1/2"w/X Profile,ID=3.812 2 ±1,625' 13-3/8"DV Tool 3 ±5,700' GLM 4 ±13,788' X Nipple w' 5 ±13,800' Packer 6 ±13,813' X Nipple 7 ±13,825' WLEG 41 8 14,471' 9-5/8"x 7"Baker ZXP Liner Top Packer 1 1 4 r 9 14,490' 9-5/8"x 7"Baker Liner Hanger }moi.► _ . ''5 10 16,276' 4-1/2"Fiber Optic Transducer,ID=3.958"(16,281'ELM) t 6 11 16,301' 4-1/2"HES X Nipple,ID=3.813 11 ,''''i .,1:l 7 12 16,323' 7"x 4-1/2"Baker S-3 Packer,ID=3.875" 4 7 13 16,347' 4-1/2"HES X Nipple,ID=3.813 ®_i ,'8 14 16,358' 4-1/2"HES XN Nipple,ID=3.725"(16,360'ELM)s. r' ,, . i 15 16,362 7"x 5"Baker ZXP Liner TopPacker 4 b. 4 ,"'9 'NI ' ' V, 16 16,369' 4-1/2"Bkr Model'A'Ratcheting Muleshoe,ID=3.5" 17 ±16,750' CIBP 9-5/g'A 1W PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(ND) Btm(TVD) FT Date Status Kuparuk Sands ±14,195' ±14,470' ±8,896' ±9,088' ±275 FUTURE FUTURE Ivishak Sands 16,775' 16,835' 11,033' 11,089' 60 1/22/2003 Closed t 10 Ivishak Sands 16,830' 16,850' 11,084' 11,103' 20 12/08/2005 Closed 1 7 11 WELL INCLINATION DETAIL KOP @ 351' Max Hole Angle=59 deg. @ 3,590' 12 Angle at Top Perf=47 Deg.@ 14,195' OPEN HOLE/CEMENT DETAIL 13-3/8" 669 sx PF'L',472 sx Class'G'in 16"Hole 9-5/8" 794 sx Econolite,564 sx'G'in a 12-1/4"Hole 7" _ 325 sx Class"G"in 8-1/2"Hole ... .z ;__ e 1314 4-1/2" 93 sks Class"G"in 6-1/8"Hole '' +' ..1516 y, ' TREE&WELLHEAD Tree ABB-VGI 5-1/8"5KSI g Wellhead ABB-VGI 13-5/8"Multibowl 5KSI TOC@±16,720 GENERAL WELL INFO API:50-029-23111-00-00 ‘'- . ; 17 Original Completion w/Nabors 33E-1/15/2003 Perforate w/Nabors 33E-1/22/2003 $ Add Perforations -12/8/2005 y, d` 4-1/2" - TD=16,865'(MD)/TD=11,117(1)/D) PBTD=16,856'(MD)/PBTD=11,109'(TVD) Created By:TDF 4/17/2015 HYDRILL 13-5/8"sr,n ANNULAR ....---1- .) .• w►+.rr.rte war. • r ---- I13-5J3"SM I • SWI , 0 ' 1 � 1 I... 0 ke C` VBR 2 7/8-5" ,, ./ ......_ C) ..el'i.P. '-'7" C)T T "4 413. 14, c) �-*-_- �� BLINDS y 1 () C.MERCNTYPE "U' lI Ai . 4„.. . .._. ,.., ...7,, ,.,... lir * MU OSS iI : KILL LINEOKE LINE = I'M ►fii - ■ C1 I LS-5/S"5NA K1 HCR 1 11111 • HCR 2 • • Roby, David S (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Thursday,April 23, 2015 1:15 PM To: Roby, David S (DOA) Subject: RE:Sundry Application for NS-18 (PTD 202-141) Attachments: NS-18 AOGCC Production Volumes.xlsx David, Sorry it took me so long for me to get to data and then sort through the differences in numbers. Enclosed is an explanation as to why NS-18 was selected as the candidate for recompletion to the Kuparuk. GOR vs. Marginal GOR The allocated figures for oil production that are reported are a combination of black oil and NGL's. The NGL allocation to each well is done a little differently between the previous operator and Hilcorp. The shift in methodology explains the shift in GOR in recent months (90-100 MCF/STB in 2014 to 70-75 MCF/STB in 2015). Enclosed is table that shows the true GOR without NGL's included and this puts the GOR's into the 150-170 MCF/STB in the recent months. It is important to note that we are working on ways to improve this NGL allocation to better optimize our total oil production (black oil + NGL)coming from each well with our limited gas handling capacity. We have taken gas samples from each well and using to develop an NGL yield per well. The piece to highlight that you mentioned is in the GOR comparison to the other wells. This well rides right at and above the marginal GOR for the field and makes it uncompetitive: NS-18 GOR 70-75 MCF/STB vs. Marginal GOR 60-65 MCF/STB. Also as you stated below the on time for this well has declined from 299 days in 2013 to 207 days in 2014 and is trending further down with decline. Other factors played into the further selection of this well as the candidate but only after the future utility of the current completion in the Ivishak was compared against the other producers. Some of these factors were location in reservoir in the Ivishak, proximity to gas injection wells, and location of where it intersected the Kuparuk in relation to mapped formation & NS-08. Thank you and feel free to contact me if you would like to discuss further, Taylor Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 Cell: (907)947-9533 Email:twellman@hilcorp.com From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Tuesday, April 21, 2015 1:37 PM To: Taylor Wellman Subject: Sundry Application for NS-18(PTD 202-141) Taylor, 1 I'm reviewing your application to plug the Northstar Oil Pool perfs in the subject well and recomplete the well in the Kuparuk formation for potential impacts on ultimate recovery and have a question. In reviewing the production data the well doesn't appear to be that bad of a well. It generally produces in the 500-700 BOPD range, has a decent amount of up time(202 days during 2014 and 299 days during 2013),the current GOR isn't horrible (70-75 MCF/STB versus 60-65 MCF/STB for the full field, in fact the GOR was much higher 90+ MCF/STB for most of 2013 when the well had more uptime).There are other wells with comparable performance and some with worse performance,so my question is why was this particular well chosen for recompletion in the Kuparuk formation? Regards, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 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). 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Our plans for the proposed perforations will conform to the spacing requirements outlined in 20 AAC 25.055. Subsection (3)applies: Oil has been discovered, so the drilling unit for the Northstar, Kuparuk C Undefined Oil Pool is a governmental quarter section. The enclosed map shows no other wells to that pool exist in the SW1/4 of Section 3,and the nearest well open in that same pool lies in the NW1/4 of Section 11. These two wells are also more than 1000'feet apart. To isolate the existing Ivishak formation from the Kuparuk, a plug will be set and—30' of cement will be dumped on top of it prior to moving the rig onto the well. There are no plans to comingle these formations. If in the future a return to the Ivishak formation is needed, it would require another work-over to isolate the Kuparuk and re-access the Ivishak. The production will be reported against field/pool code 590150 for the Kuparuk Formation. Thank you and please contact me with any other comments/concerns/questions. -Taylor 1 0 N N Q Q O a /\/ --,,,, _ CU 13 `r►• a) c / 11,o 0_ v C /' ta Q CO E L O i j w I La ic(7' ,� \\,..,..... j I N 1 cca Z co VI Z U U C7 0 Q .'uIIIIIIIIIIIIIIII • . ibliw .. 10 .s. 2 • Taylor Wellman Hilcorp Energy Company-Operations Engineer Office: (907)777-8449 Endicott: (907) 777-8449 Cell: (907)947-9533 Email: twellman@hilcorp.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, April 20, 2015 2:40 PM To: Taylor Wellman Cc: Loepp, Victoria T(DOA) Subject: Sundry Application to Recomplete NS-18 (PTD #202-141) Taylor, Hilcorp's Application for Sundry Approvals for NS-18 concerns isolation of the existing Ivishak formation perforations followed by recompletion of the well and the addition of perforations in the Kuparuk formation. Under Conservation Order No.458A,the Northstar Oil Pool is defined as the accumulation of hydrocarbons common to and correlating with the Sag River, Shublik, and Ivishak Formations in the Seal A-01 well.Since the Kuparuk Formation is not included in this pool, Hilcorp's proposed perforations will be governed by statewide spacing regulations. Please provide a map or a written description that provides the following information: • the location of the proposed Kuparuk perforations in NS-18 in terms of quarter-quarter section,section, township, and range; • the distance to nearest well that is also perforated and open to that same pool;and • the location of the existing perforations in that nearest well also in terms of quarter-quarter section, section, township,and range. Will Hilcorp's proposed perforations in the Kuparuk formation conform to all relevant spacing requirements of 20 AAC 25.055? Production from the Kuparuk formation must be reported against field/pool code 590150,which designates the Northstar, Kuparuk C Undefined Oil Pool. Please be aware that all AOGCC personnel needed for review and approval of sundry applications may not be immediately available to meet rush requests. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone:907-793-1224 AOGCC:907-279-1433 Fax:907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 3 Davies, Stephen F (DOA) From: Taylor Wellman <twellman@hilcorp.com> Sent: Monday, April 20, 2015 2:44 PM To: Davies, Stephen F (DOA) Cc: Loepp, Victoria T (DOA) Subject: RE: Sundry Application to Recomplete NS-18 (PTD #202-141) Steve, Thank you very much for the prompt reply to the Sundry Application. I will pull the requested information and return it back to you. Some of it is readily available, such as our plans for production reporting, but I will make sure all questions are addressed. Thank you, Taylor for Wellman Hilcorp Energy Company-Operations Engineer Office: (907) 777-8449 Endicott: (907) 777-8449 Cell: (907) 947-9533 Email: twellman@hilcorp.com From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Monday, April 20, 2015 2:40 PM To: Taylor Wellman Cc: Loepp, Victoria T(DOA) Subject: Sundry Application to Recomplete NS-18 (PTD #202-141) Taylor, Hilcorp's Application for Sundry Approvals for NS-18 concerns isolation of the existing Ivishak formation perforations followed by recompletion of the well and the addition of perforations in the Kuparuk formation. Under Conservation Order No. 458A, the Northstar Oil Pool is defined as the accumulation of hydrocarbons common to and correlating with the Sag River, Shublik, and Ivishak Formations in the Seal A-01 well. Since the Kuparuk Formation is not included in this pool, Hilcorp's proposed perforations will be governed by statewide spacing regulations. Please provide a map or a written description that provides the following information: • the location of the proposed Kuparuk perforations in NS-18 in terms of quarter-quarter section, section, township, and range; • the distance to nearest well that is also perforated and open to that same pool; and • the location of the existing perforations in that nearest well also in terms of quarter-quarter section, section, township, and range. Will Hilcorp's proposed perforations in the Kuparuk formation conform to all relevant spacing requirements of 20 AAC 25.055 ? 1 • Production from the Kuparuk formation must be reported against field/pool code 590150, which designates the Northstar, Kuparuk C Undefined Oil Pool. Please be aware that all AOGCC personnel needed for review and approval of sundry applications may not be immediately available to meet rush requests. Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. 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 be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ od..- ~ ~ ~ Well History File Identifier ~I 0+ ~.C:¡ = TOTAL PAGES ~·~8 (coun~ 10ed no' include cover sheet) .M. f\, Date: Lf- I OS' 151 --y " I· Organizing (done) ~ wo-sided ""111111111"1 III DI9P"AL DATA '\,l1' Diskettes, No.d- o Other, No/Type: RFJCAN '\,Ø' Color Items: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: BY: Helen ~ Project Proofing BY: Hele~. Scanning Preparation BY: Helen ~ 7 x 30 = Production Scanning ~scan Needed OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ~9S of various kinds: o Other:: , Date:lJ: ',/ ()"5 I Isl rv() , ~ ~ Date: if I Ð á 151 I I Stage 1 Page Count from Scanned File::J ,"3 c¡ (Count does include ~er sheet) Page Count Matches Number in Scanning Preparation: V YES BY: Helen G.--Maria J . If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: NO Date: 4- I OS- Is! ~ YES NO Date: 151 111111111111111 111111111111111 Date: 151 Quality Checked 1111111111111111 III BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 April 21, 2010 _ ~ ~ E~ ~ ~~ .. E.~ `~~' " :'~ ~~~ 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, • by ~~~~~~~ ~t>s a, Ns 1y$- 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 a/~n/gym n 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 NSO6 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 NSOS 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. • • ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 c ~' M~~ ~~~i~ May 26, 2009 i~~~ l &1ti ~$`~~~li~sion i~~l~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~ ~„ 333 West 7th Avenue ~~°~ ~-~ Anchorage, Alaska 99501 ~ 1 v 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 n BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ '~~\ 0~ Date Northstar L~ 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 NS14 A 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 o ~ 2009 1-~ ~-: ~~. L~ 1~- c ~,~` ~:~ JV ~~ \` ,~la ~-,~ ~'~ ~~,~ _~,4~~i i ~~?~ [ ; J, \~~+'' .~^ .d`.~~~ . \~ .~/ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv auestions. please contact Joe Lastufka at (907)564-4091 Date: 02-25-2009 Transmittal Number: 93041 Delive Contents SW Name Date Contractor Run To De th Bottom De th Descri tion -NS24 12-05-2008 SCH 12450 12490 PL ADVISOR NS24 12-05-2008 SCH CD-ROM - PL ADVISOR NS09 12-17-2008 SCH 1 13044 13339 MEMORY SBHPS LOG CD-ROM -MEMORY SBHPS NS09 12-17-2008 SCH LOG PRODUCTION PROFILE NS16A 02-12-2009 SCH 1 11150 11390 ITH DEFT AND GHOST ' CD-ROM -PRODUCTION PROFILE WITH DEFT AND NS16A 02-12-2009 SCH GHOST PRODUCTION PROFILE NS05 02-13-2009 SCH 1 13551 13860 WITH DEFT AND GHOST CD-ROM -PRODUCTION PROFILE WITH DEFT AND NS05 02-13-2009 SCH GHOST ULTRASONIC CEMENT/CORROSION NS33 01-29-2009 SCH 1 100 15550 EVALUATION CD-ROM -ULTRASONIC CEMENT/CORROSION NS33 01-29-2009 SCH EVALUATION NS34A 12-16-2008 SCH 1 16088 17108 MEMORY SBHPS LOG CD-ROM -MEMORY SBHPS NS34A 12-16-2008 SCH LOG STATIC TEMPERATURE/ NS18 02-16-2009 PDS PRESSURE SURVEY S18 02-17-2009 PDS 1 16250 16851 CORRELATION LOG CD-ROM STATIC TEMPERATURE/PRESSURE SURVEY/CORRELATION NS18 02-17-2009 PDS LOG,, :.~ . ` ~` l Q~ ~~,~,~~~ ~ CAF .~ y~;a i Please Sign nd turn one copy of this transmittal. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 e.P Exploration ~Alaskaf. 1~~. Static Temperature/ Pressure Survey NS - 78 North Star North Slope Surface -Before R/H Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 60.67 3751.51 0.5 61.58 3751.49 1.0 62.44 3751.51 1.5 62.66 3751.55 2.0 62.07 3751.61 2.5 61.38 3751.67 3.0 60.79 3751.73 3.5 60.15 3751.79 4.0 59.61 3751.86 4.5 59.09 3751.92 5.0 58.67 3751.97 5.5 58.03 3752.03 6.0 57.46 3752.08 6.5 56.83 3752.12 7.0 56.12 3752.16 7.5 55.48 3752.20 8.0 54.93 3752.23 8.5 54.38 3752.26 9.0 53.85 3752.28 9.5 53.38 3752.30 10.0 52.90 3752.31 AVERAGE 58.21 3751.93 Current Wellhead Read in s Wellhead Pressure (psig) : 3750 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : 750 Outer Annulus Pressure (sig) : N/A ~0 2 - Imo/ ~ Date: February 16, 2009 ob~F,M WE[~ SAF a ~: Q v~ ._ ,~ ~ N P~oAcriv[ Di~yr.osric 5[avic[s Start time: 22:32:00 Temperature Data 70 so - - 50 ~ 40 - 30 - 20 - 10 - 0 - --- 0 1 2 3 4 5 6 7 8 9 10 Minutes 3780 3770 3760 N 3750 a 3740 3730 3720 Pressure Data 0 Page 1 1 2 3 4 Minutes 6 7 8 9 10 B.P, Exploration (AlaskaJ. lnc. NS - 98 North Star North S/ope 90,983' TVDss M.D. = 96,782' Static Temperature/ Pressure Survey Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psis) 0.0 250.22 5086.63 1.0 250.19 5086.76 2.0 250.19 5086.93 3.0 250.22 5087.12 4.0 250.22 5087.32 5.0 250.24 5087.52 6.0 250.24 5087.73 7.0 250.25 5087.92 8.0 250.31 5088.11 9.0 250.32 5088.30 10.0 250.33 5088.47 11.0 250.36 5088.65 12.0 250.34 5088.81 13.0 250.37 5088.96 14.0 250.38 5089.11 15.0 250.38 5089.25 16.0 250.42 5089.39 17.0 250.42 5089.52 18.0 250.46 5089.64 19.0 250.42 5089.75 20.0 250.46 5089.86 21.0 250.47 5089.97 22.0 250.51 5090.07 23.0 250.48 5090.16 24.0 250.51 5090.24 25.0 250.49 5090.32 26.0 250.52 5090.40 27.0 250.52 5090.47 28.0 250.56 5090.53 29.0 250.50 5090.59 30,0 250.56 5090.65 AVERAGE 250.38 5089.01 Date: February 17, 2009 Temperature Data 251 Ob~f,M WE(( SAf a n,• 4 ~ N P~oAcriv[ Df~yMOSric SEI1vic[f Start time: 00:02:00 2so LL 249 248 v 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 Minutes 5095 5090 5085 H 5080 a 5075 solo 5065 Pressure Data 0 2 4 6 8 10 12 ~ 16 18 20 22 24 26 28 30 notes Page 2 B.P. Exploration (A/eska). lnc. Static r@/7~~DE/'c~tU/'@~ P/'BSSU/'@ J~'U/'V@~/ NS - 98 North Star North Slope 90,932' M)ss M.D. = 96,728' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 250.48 5085.24 0.5 250.52 5085.27 1.0 250.48 5085.29 1.5 250.47 5085.32 2.0 250.49 5085.35 2.5 250.51 5085.37 3.0 250.51 5085.39 3.5 250.47 5085.41 4.0 250.50 5085.44 4.5 250.45 5085.45 5.0 250.47 5085.48 5.5 250.47 5085.50 6.0 250.47 5085.51 6.5 250.44 5085.53 7.0 250.47 5085.54 7.5 250.47 5085.56 8.0 250.44 5085.57 8.5 250.47 5085.58 9.0 250.47 5085.60 9.5 250.47 5085.61 10.0 250.46 5085.62 10.5 250.47 5085.63 11,0 250.47 5085.64 11.5 250.45 5085.65 12.0 250.47 5085.66 12.5 250.47 5085.67 13.0 250.46 5085.68 13.5 250.46 5085.69 14.0 250.47 5085.70 14.5 250.47 5085.70 15.0 250.46 5085.71 AVERAGE 250.47 5085.53 Date: February 17, 2009 Temperature Data 251 ob`6M WE((sAf a ~~• Q ~~ W !^ N PwoAcrivr Di~y~osric Scwviccs Start time: 00:33:00 250 249 248 ~ 0 5095 5090 5085 ~ 5080 a 5075 5070 5065 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 0 Page 3 1 2 3 4 5 6 ~linute~ 9 10 11 12 13 14 15 a.p Exp~o~stion raleska>.1~~. Static Temperature/ Pressure Survey NS - 98 Narth Star Narth Slope 90,987' TVOss M,D. = 96,786' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psis) 0.0 250.62 5090.95 0.5 250.62 5090.95 1.0 250.62 5090.95 1.5 250.62 5090.95 2.0 250.62 5090.95 2.5 250.62 5090.95 3.0 250.66 5090.95 3.5 250.62 5090.95 4.0 250.63 5090.95 4.5 250.63 5090.95 5.0 250.64 5090.96 5.5 250.66 5090.96 6.0 250.62 5090.96 6.5 250.66 5090.96 7.0 250.66 5090.96 7.5 250.64 5090.97 8.0 250.67 5090.97 8.5 250.66 5090.97 9.0 250.67 5090.97 9.5 250.67 5090.98 10.0 250.67 5090.98 10.5 250.67 5090.98 11.0 250.67 5090.98 11.5 250.67 5090.98 12.0 250.67 5090.99 12.5 250.67 5090.99 13.0 250.65 5090.99 13.5 250.69 5090.99 14.0 250.67 5090.99 14.5 250.71 5090.99 15.0 250.67 5090.99 AVERAGE 250.65 5090.97 Date: February 17, 2009 Temperature Data 251 Ob`EM WE« SAF a ~: Q v~ F~ N P~oAcrivc DiwyMmric ScavkEs Start time: 00:55:00 2so 249 248 + 0 5095 5090 5085 H 5080 a 5075 5070 5065 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 0 Page 4 1 2 3 4 5 6 Minutes 9 10 11 12 13 14 15 e.P Exp~oret/on ~A/eske> 1~~, Static Temperature/ Pressure Survey NS - ?8 North Star North S/ope ?0,882' TI/Uss M.D. _ ?6,674' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 249.94 5080.44 0.5 249.93 5080.47 1.0 249.88 5080.50 1.5 249.90 5080.52 2.0 249.86 5080.54 2.5 249.84 5080.56 3.0 249.83 5080.57 3.5 249.83 5080.58 4.0 249.78 5080.59 4.5 249.81 5080.59 5.0 249.78 5080.60 5.5 249.78 5080.60 6.0 249.78 5080.60 6.5 249.77 5080.60 7.0 249.76 5080.60 7.5 249.73 5080.60 8.0 249.78 5080.60 8.5 249.76 5080.60 9.0 249.73 5080.59 9.5 249.73 5080.59 10.0 249.70 5080.59 10.5 249.69 5080.59 11.0 249.73 5080.58 11.5 249.69 5080.58 12.0 249.70 5080.58 12.5 249.72 5080.57 13.0 249.72 5080.57 13.5 249.72 5080.57 14.0 249.69 5080.56 14.5 249.68 5080.56 15.0 249.71 5080.56 AVERAGE 249.77 5080.57 Date: February 17, 2009 Temperature Data 251 ob`EM WE(( sAE a ~: Q v~ W !^ 2 ~' M P~oAcriv[ Di+yr~osric Sewvic[s Start time: 01:17:00 2so 249 248 + 0 5095 5090 5085 N 5080 a 5075 5070 5065 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 0 Page 5 1 2 3 4 5 6 f~linutes 9 10 11 12 13 14 15 B.P. Exploration (A/askaJ, lnc. St[~tYCi TB~77pB/'c'~1tU/'6~ P!'@SSU!'@ SU!'1/BJ/ NS-24 North Star North S/ope 90,783' TVDss M.O. = 96,576' Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psia) 0.0 248.64 5070.01 0.5 248.69 5070.04 1.0 248.67 5070.07 1.5 248.62 5070.09 2.0 248.60 5070.12 2.5 248.60 5070.13 3.0 248.60 5070.15 3.5 248.59 5070.16 4.0 248.55 5070.16 4.5 248.57 5070.17 5.0 248.54 5070.17 5.5 248.54 5070.17 6.0 248.57 5070.17 6.5 248.52 5070.16 7.0 248.50 5070.16 7.5 248.51 5070.15 8.0 248.49 5070.15 8.5 248.50 5070.14 9.0 248.49 5070.14 9.5 248.45 5070.13 10.0 248.48 5070.12 10.5 248.45 5070.12 11.0 248.47 5070.11 11.5 248.44 5070.11 12.0 248.47 5070.10 12.5 248.44 5070.09 13.0 248.45 5070.09 13.5 248.47 5070.09 14.0 248.47 5070.08 14.5 248.44 5070.07 15.0 248.44 5070.07 AVERAGE 248.52 5070.12 Date: February 15, 2007 ob`EM WE(( SAE a ~~ Q 9~ F~ N PROACTIV[ ~I~fjFOfTI[ Sf RVICFI Start time: 01:39:00 Temperature Data 251 250 --- - - -- ---- d 249 - --------- -- - 248 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes 5095 5090 5085 N 5080 a 5075 5070 5065 Pressure Data 0 Page 6 1 2 3 4 5 6 Minutes 9 10 11 12 13 14 15 ~ ~ ~ ! ~ ~ ~ ~ ~ ~ ~ ~ ~ s ~ ~ ~ ~ ~ BP Exploration ~AlaskaJ lna Static Temperatu/'e/Pressure Survey wEll NS - 7B a~b`EM Sp fc'. North Star ~ ~ ~ N North Slope Surface -After POIO/'/ P~oAcrivr D4y Date: February 17, 2009 Start time: 03:19:00 Elapsed Time (Minutes) Temperature (Deg. F) Pressure (psis) 0.0 13.13 3751.24 0.5 12.34 3751.26 1.0 11.70 3751.31 1.5 11.09 3751.39 2.0 10.45 3751.52 2.5 10.08 3751.67 3.0 9.55 3751.85 3.5 8.98 3752.06 4.0 8.50 3752.27 4.5 8.12 3752.47 5.0 7.61 3752.66 5.5 7.02 3752.83 6.0 6.56 3752.99 6.5 6.08 3753.13 7.0 5.67 3753.26 7.5 5.36 3753.39 8.0 5.07 3753.50 8.5 4.86 3753.58 9.0 4.57 3753.63 9.5 4.32 3753.67 10.0 4.12 3753.68 AVERAGE 7.87 3752.54 Current Wellhead Read in s Wellhead Pressure (psig) : 3720 Wellhead Temperature (deg. F.) : N/A Inner Annulus Pressure (psig) : 750 Outer Annulus Pressure si N/A Temperature Data 70 so 50 - LL 40 -- ~~ --- 20 10 -- -- 0 0 1 2 3 4 5 6 7 8 9 10 Minutes 3780 3770 3760 N 3750 a 3740 3730 3720 Pressure Data 0 Page 7 1 2 3 4 Mins es 6 7 8 9 10 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ B.P. Exp/oration (AleskaJ. lnc. NS - 78 North Star North Slope Downho% Temp/ Press Date: February 17, 2009 Static Temperature /Pressure Survey Start time: 00:02:00 End time: 01:40:00 Ob`F,Wi WE(( sAf Qa c'~ W s ~. P~oAcTiv[ Diwpwofrfc S[RVic[s Temperature Data 251 250 LL ..--- 249 248 -200 0 200 400 600 800 1000 1200 1400 1600 Minutes Pressure Data 5095 - --- 5090 -- -- . --- -- -- --- -- - 5085 -- -----.-_ _ _.- - ------- -------- H 5080 a -- - - --- -- - -- 5075 ---- _------ -- ------------ - ------ - -- --- 5070 -------_- - - - - - --- - - 5065 -200 0 200 400 600 Minutes 800 1000 1200 1400 1600 r1 ~J Page 8 . . bp Date 10-23-2007 Transmittal Number:92913 n J ;:~ /~~ 'JDC? !:;Fl.:;. Cuns, Anr;hDrB~)H BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. ~ -155 Log Top SW Name Date Contractor Run Depth Bottom Depth LOQ Type MEMORY MULTI-FINGER -I:JT CALIPER LOG RESULTS (pi..( NS16 09-11-2007 PDS 1 0 12110 SUMMARY MULTI-FINGER CALIPER 3D NS16 09-11-2007 PDS 1 0 12110 DATA AND VIEWER -d~ "1- NS30 09-16-2007 SCH 1 15900 16170 PERFORATING RECORD - MEMORY STATIC PRESSURE -fol NS06 07 -29-2007 SCH 1 13096 13694 AND TEMERATURE SURVEY MEMORY STATIC PRESSURE _ L.f( NS18 07 -30-2007 SCH 1 16290 16845 AND TEMERATURE SURVEY - h~·lq MEMORY STATIC PRESSURE NS09 07-31-2007 SCH 1 12666 1 3341 AND TEMERATURE SURVEY Jo5 ,!)tf) ;;D'd :¡o é,~ Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petro technical Data Center SCANNED NOY ,01 2007 Attn: Doug Chromanski Ignacio Herrera Howard Okland Kristin Dirks Cheryl Ploegstra MMS Murphy Exploration AOGCC DNR BPXA Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 '- '~\t, ~ 1"1"' % c:-cl· J" fE \..::/ ,,_ if l.Ji. ~"".._.. ,,("I'::;~l:, .,r, -F:;Y i ¡, ¡. 'ì ~ l~::U Lf 'A\f1 ~'\:\ !u\ ll¡. ¡ll\ /1""",\, ¡ ¡rì' ~"..¡ d L_7:::J L ".J IA\\'" 1'--' 1 f~l' ". ...1 / ¡ / / f I / ¡ SARAH PALIN, GOVERNOR AI,ASKA OIL AlO) GAS CONSBRVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Carolyn Kirchner Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 &CANNED JAN 1 7 20D7 Re: Northstar Field, Northstar Oil Pool, Well Name: NS 18 Sundry Number: 307-013 Dear Ms. Kirchner: 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. When providing 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, é DATED this IVaay of January, 2007 Ene!. 86 'd-IL{( · ",µ' \ E/ l STATE OF ALASKA /íJP7 RECEIVED ~r \ \'1\ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ . \ APPLICATION FOR SUNDRY APPROVAL " 1y.. JAN 0 9 2007 20 AAC 25.280 /' Abandon U Suspend U Operational shutdown ~ Perforate L~l A'~Oill& Gas Con~ttt,eó,h,tiss;on Alter casing 0 Repa~~,>..PIU9 Perforations ~ Stimulate 0 Time Extension 0 IfhCfi_,ze Change approved program 0 ~Ubing 0 r I Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ItI Exploratory 0 202-1410 / 3. Address: P.O. Box 196612 0 SelVl'ce 0 6. API Number: Stratigraphic 1. Type of Request: 50-029-23102-00-00 , Anchorage, AK 99519-6612 7. KB Elevation (ft): 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4·1/2" Liner Top Packer 12. Attachments: DescriDtive SummaryofProposal1tl Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Carolyn Kirchner Title Signature ¡1 1 1r--l L c.v ,vVI....Å, ! ,; \,/"'"'-..... 8. Property Designation: 11. Total Depth MD (ft): 16865 Casing Surface Production Liner Liner Perforation Depth MD (ft): 16775 - 16835 J 16830 - 16850 J Packers and SSSV Type: Commencing Operations: 16. Verbal Approval: Commission Representative: 9. Well Name and Number: 55.85 KB J NS18 / ADL-312799 I 10. Field/Pools(s): Northstar Field / Northstar Oil Pool I PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 16861 11113.5 Total Depth TVD (ft): 11117.25 Plugs (measured): Junk (measured): None None Burst Collapse 3207 4930 2270 9234 6870 4760 10815 7240 5410 11117 8430 7500 Length Size MD TVD 3989 13-3/8" 68# L-80 44 4033 44 14625 9-5/8" 47# L-80 43 14668 43 2070 7" 26# L -80 14471 16541 9088.99 503 4-1/2" 12.6# 13Cr80 16362 16865 10650.46 Perforation Depth TVD (ft): 11032.76 - 11089.09 11084.39 - 11103.17 Tubing Size: 4-1/2" 12.6# Tubing Grade: 13Cr80 Tubing MD (ft): 40 - 16369 Packers and SSSV MD (ft): 1045 14471 16323 16362 13. Well Class after proposed work: Exploratory 0 Developm ent ItI Service 0 1/18/2007 Date: 15. Well Status after proposed work: Oil ItI Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Prepared by Gary Preble 564-4944 Contact Carolyn Kirchner Production Engineer 1/4/2007 WDSPL 0 Abandoned 0 Phone 564-4862 COMMISSION USE ONLY Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 r¡ -ð I ð Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 <-6\ \ ':) '- e: L \ \ \ BFL JAN 1 6 2007 Other: ~ 'S ~O ....." ~ ",l":> ~,"'_ \. ~ '-J ~«:> \. ~ \ 'l'.....,~ ~ \"-\....., ~ ~ "'~'>~ Approved by: Form 10-403 Revised 7/2000 RIG I APPROVED BY THE COMMISSION Date: /-I1"ð?" Submit in Duplicate bp Date: .,. ,\If.''', ..'~ ....: ."'\' ". To: December 15, 2006 Jerry Bixby / Clark Olsen - Well Operations Supervisor From: Robert Younger / Carolyn Kirchner - Northstar Production Engineer WK:564-5392 HM:677-2599 Cell: 830-4920 WK:564-4862 HM:N/A Cell: 603-781-4062 Subject NS18 GSO Squeeze Est. Cost Charge Code lOR: $200M NSFLDWL 18 200 Please perform a gas shut-off squeeze on NS18. This procedure includes the following steps. Type lOR DSWL AFE Job Description Priority Comments/Other S 200 NS18 NSFLDWL 18 Driftrrag TD C 200 NS18 NSFLDWL 18 Acidize, Cement squeeze S 200 NS18 NSFLDWL 18 Driftrrag wI Dmy Gun (md 16850') E 200 NS18 NSFLDWL 18 Perforate (16840'-16850') Production: 1,808 BOPD; 21 BWPD; 38.6 MMSCFD Max Deviation: 59.23 deg @ 3,590 MD Max Dog Leg: 5.1 deg/100' @ 2,355' MD Perf Deviation: 1.6 deg Min.ID: 3.725" ID, 4.5" XN Nipple @ 16,358' MD Last TD Tag: 16,800' SLM on 11/12/05 Last Downhole Ops:04/04/06 - Bullhead Acid Treatment. Tie-in Log: Perforating Record w. Jewelry 01/22/03 BHP: 5188 psi @11, 100' md 2/17/04 Background NS18 has shown a steady decline since coming on at -10,000 bopd in January 2003. Since then, periodic acid treatments have provided a boost in production by combating scale buildup, however we have seen a steady rise in GOR. Today, production is at -3000bopd and GOR is at 20,000. The primary purpose of this job is to squeeze off the existing perforations, and then reperforate the bottom 10' of perfs to re-establish NS 18 as a low GOR producer. Northstar Specific Information/Procedures: C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS18 CTU GSO saz Program 12-15-06.doc 1. Contact Northstar prior to mobilizing equipment. · Operations Support Supervisor - Wade Srock / Lowry Brott - 670-3520 · Operations Team leader - Michael Johns/ Ken Wood - 670-3601 · lead Tech - Troy Helmandollar / Bràd Hobson - 670-3533 · Control Room - 670-3515 · Safety - Jim Croak / Jim Short - 670-3509 · Environmental (ACS) - Hunter Ervin / Joe Serra 670-3508 2. Contact Northstar Scheduler to arrange transport to island (days only). Lori Murray / Jeff Carter - 659-1941 · All vehicles coming to and from Northstar Island must be escorted by Northstar logistics. Contact 659-1939 or 659-1941 prior to departure for approval. 3. Conduct Authorization to Proceed (A TP) pre-job meeting prior to commencing work. The PE is responsible for administering the A TP with the help of Operations and Safety. 4. Winter gear is required for all transportation to and from the island during the winter months. 5. Items of note: · All chemicals must be cleared with Environmental. · Spill containment is required under every vehicle. · All engine driven equipment must be logged when arriving on the island and reported to Environmental. ~ BJ Northstar ATP .doc (35 KB) Primary Squeeze Target '~AP The perforated interval 16,775' - 16,850' MD' ¡v,j Program NOTE: NS18 has chrome tubing. Ensure coil has sufficient coil life and wall thickness for proposed procedure. Slickline (Pre-Squeeze) 1. Drift and Tag TD with sample bailer (Previous tag @ 16,800' SLM, 16,840' on 11/12/05). Please note any restrictions and plan to increase acid volumes if scale encountered in tubing or liner. C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS18 CTU GSO SOZ Program 12-15-06.doc Coiled TubinSl (Pre-Squeeze) Please note that Northstar wells have the potential for Shut-in Tubing Pressures up to ....3900 psi. Therefore, downhole checks are required on all coil tubing operations. 1. MIRU 1-3/4" CTU wi at least 17,500' of CT. 2. MU the following BHA: 2.25" CRC, 2 6' stingers, and a 2.5" 00 ball drop nozzle. 3. PT HL, CT, BOP's and lubricator to 4500 psi (final squeeze pressure may reach 4000 psi at surface). 4. Open up well and prepare to pump down the backside. 5. Spear wi 10 bbls of meth water, then bullhead kill the tubing with a minimum of 383 bbls of SW (1.5 times the wellbore volume to the bottom perf). 6. When WHP drops below 1500 psi, begin RIH while continuing to pump down the backside. 7. After 383 bbls away, continue pumping down the b/s at 1 bpm and dry tag TO (reduce rate to a minimum when the nozzle is across the perfs) 8. Tag TO, PUH 10', and flag pipe. PUH above all perfs. If tag is above 16,850' call Anchorage engineer. 9. Switch to pumping down the coil @ 1 bpm to ensure the nozzle is clear and prevent gas from entering the well. Begin batch mixing cement. Coiled Tubing Acid & Squeeze 1. Pump 12 bbls of 120/0 HCI with nozzle making 1 dn and 1 up pass across perfs at max rate. 2. Overdisplace acid with 75 bbls of filtered Seawater Coiled Tubing Squeeze 1. Batch mix 17 bbls (12 pump-able) of LARC cement (15.8 ppg Class G wi GasBlok). Increase IA pressure to 1500 psi with triplex. Place a field mix sample of cement in UCA at 2540 F. Cement ac should include fluid loss, slurry density, slurry temperature, slurry rheology, and filter cake thickness and quality. Compare to design parameters. Place 2 samples in a hot water bath, one with 100% cement and one with 50/50 mix of cement and biozan. 2. Pump the following: · 10 bbl fresh-wtr spacer · 12 bbl LARC 15.8 ppg cement (Attachment A). (May pump all cement in batch mixer) · 40+ bbls of fresh wtr flush The cement should be pumped at a high enough rate to prevent free fall (-1.5 BPM). 3. RIH to the flag as the cement reaches the nozzle. PUH at 1:1 with chokes closed to the top perf. Reciprocate near the top perf with the chokes closed until a 1000 psi pressure bump is achieved. C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS18 CTU GSO SOZ Program 12-15-06.doc 4. As you see the pressure increase, position the nozzle close to the top perf when the chokes are opened. Circulate 2 bbls around the nozzle and lay in the remaining cement while maintaining constant WHP. Do not build squeeze pressure until the nozzle is above the perforations at 16,775'. Keep the coil moving at all times while laying in cement. Don't lay in remaining cement until initial squeeze pressure is obtained. If the squeeze pressure does not build then pump all cement behind pipe and pump another batch of cement. Contaminate and overflush while mixing next batch of cement. 5. After all of the cement is out of the nozzle, race to safety (-16,656', assuming no cement behind pipe). 6. Attempt to build squeeze pressure in 500 psi increments every 10 minutes to a final squeeze pressure of 3500 L\P at the perfs. Last BHP was 5188 psi at 11,100' SS. Hold final squeeze pressure for 1 hour. Bleed pressure back to 1000 psi L\P at the perfs to commence the contamination and cleanout. If unable to achieve final squeeze pressure, pump all cement away and contaminate any cement in the liner and over flush. Mix and pump another 25 Bbls of LARC. Monitor the lAP during the squeeze pressure ramps. 7. Drop the ball for jetting. Maintain 1000 psi L\P for the entire cleanout. Displace ball with 1.5#/bbl biozan at max rate. Pump at least 75 bbls of bio. Begin contaminating cement after the ball lands on seat at max rate. Slow pump rate to 1 bpm when across the perforated interval to not blow away cement nodes. Clean out no deeper than the coil flag. 8. Displace biozan with slick KCI or filtered seawater. Make 3 down and up passes at maximum pump rate but reduce pump rate to 1 bpm when across perfs. 9. On the final up pass, lay in 5 Bbls of 100/0 TEA from flag. This should more than cover the perf interval. 10. POOH at 80% while reducing POOH speed through the jewelry 11. Reciprocate (1 down pass then back up @ 500/0, 10' on either side) across the following: a. Pressure transducer at 16,276' b. Gas lift mandrel at 6355' & 7516'. c. SSSV nipple at 1045'. 12. Lay in meth water freeze protection from 3000'. Trap 1000 psi L\P on the well and SI. 13. RDMO CTU and cementing equipment Slickline/E-line (Post Sqz) 1 . WOC a minimum of 72 hours. Monitor cement compressive strength in UCA. Bleed well pressure to zero for an in-flow test. 2. RU SL. Drift/tag with 2-7/8" dummy gun. Bottom perf to be shot at 16,850'. RD SL. 3. RU EL. RIH with 2-7/8" perf guns. Perf per attached perforating procedure. C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS18 CTU GSO saz Program 12-15-06.doc ATTACHMENT Date: October 6, 2006 Well: NS18 BP CEMENT DESIGN FORM Cement Type: BHST BHCT Pumpable Volume Class G LARC 254°F 235°F 12 bbls Submitted By: Robert Younger Thickening Time Filter cake Target Acceptable Range Fluid Loss Target Acceptable Range 5-7 hours incl. 2 hr suñace plus 3-5 hrs pump time Firm cake Firm cake API, cc/30 min. at BHCT API, cc/30 min at BHCT 0.75 inches 0.6-0.8 inches 60cc 50-70 cc The slurry should have no free water. MINUTES 0-120 120-150 1 50-1 80 180-210 210-End of Test TEMPERATURE/PRESSURE gO°F @ Atmospheric Pressure Increase pressure to 5000 psi. Increase temperature to 235°. Gradually increase pressure to 8500 psi. Hold Temp & Press @ 235°F & 8500 psi. Decrease pressure to 5000 psi and hold 5000 through-out the remainder of the test. Increase temp by 15°/hr to a BHST of 254°F (if reached) until End of Test. Results: Please submit results to Company Man. Date of Test: Lab Filter cake (thickness, in): Lab API Fluid Loss: Service Co. Engineer: Description: Soft, Med., Firm?: Thickening Time (hrs): Slurry Density(lb/gal): C:\Documents and Settings\preblegb\Local Settings\Temporary Internet Files\OLKBC\NS18 CTU GSO SOZ Program 12-15-06.doc P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Class: Development (;71 Stratigraphic fJ ',' Stimulate [] Other 0 " c;, Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 'j .::.' . !'<:. /'. " . STATE OF ALASKA _ ALA OIL AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon D Repair Well D Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: . -. '.' . 3. Address: 202-1410 6. API Number: 50-029-23102-00-00 9. Well Name and Number: Exploratory Service 55.85 KB NS18 ADL-312799 11. Present Well Condition Summary: 10. Field/Pool(s): Northstar Field/ Northstar Oil Pool 8. Property Designation: Total Depth measured 16865 feet Plugs (measured) None true vertical 11117.25 feet Junk (measured) None Effective Depth measured 16856 feet true vertical 11113.5 feet Casing Length Size MD TVD Burst Collapse Surface 3989 13-3/8" 68# L-80 44 - 4033 44 - 3206.55 4930 2270 Production 14625 9-5/8" 47# L-80 43 - 14668 43 - 9234.29 6870 4760 Liner 2070 7" 26# L -80 14471 - 16541 9088.99 - 10815.44 7240 5410 Liner 503 4-1/2" 12.6# 13Cr80 16362 - 16865 10650.46 - 11117.25 8430 7500 Perforation depth: Measured depth: 16775 - 16835 True Vertical depth: 11032.76 - 11089.09 16830 - 16850.. 11084.39 _ 11103';1i~,t\; ~"'Ú'-} '0 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 40 - 16369 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 1045 14471 16323 16362 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl MAY 3 0 2006 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 56974 210 425 59931 204 0 15. Well Class after proposed work: Exploratory Development (;7 16. Well Status after proposed work: Oil (;7¡ Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 4187 4311 Tubing pressure 879 889 13. Service x GINJ 01 WINJ WDSPL Sundry Number or N/A if C.O. Exempt: 306-059 Contact Sharmaine Vestal P",ted N,me Sh"m",e Ve,tel . . _ ~ Signatu~ 7~ Title Data Mgmt Engr Phone 564-4424 Date 5/15/2006 Form 10-404 Revised 04/2004 ORIG\NAL Submit Original Only . . NS18 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE I SUMMARY 4/3/2006 ***Prep fluids for acid treatment*** **Continued to next days WSR** 4/4/2006 ***Continued from Previous Days WSR*** T/I/O=2600/975/425 Assist SLB Pump Crew (Acid Pickle) - Pumped tubing w/82 bbls 120* diesel following acid pickle. Turned well over to operations for pickle flow back. Final WHP's=1150/800/vac *** Job in Progress*** 4/4/2006 ***Continued from Earlier Todays WSR*** Assist SLB Pump Crew (Acid Treatment) - Pumped tubing w/82 bbls 100* diesel following acid treatment. Turned well over to operations for 4 hr soak. Final WHP's=725/740/vac *** Job Complete*** FLUIDS PUMPED BBLS 82 Diesel 172 Seawater 40 12% acid 67 2% KCL 361 TOTAL . . Date: 03-15-2006 Transmittal Number:92763 ,,""'1' "-'A '^f>:.,~h\"ii";-': BPXA WELL DATA TRANSMÌTTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091 ~~^' lyt SW Name Date Contractor Loq Run TaD Depth Bottom Depth Log Type VISION SERVICE LWD MD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE VISION SERVICE LWD TVD NS05PB1 02-25-2005 SCH 1 200 11991 COMPOSITE N814 01-07 -2006 SCH 1 9900 10300 BRIDGE PLUG SET RECORD N824 03-26-2005 SCH 1 12150 12478 MEM PSP PPROF NS10 12-26-2005 SCH 1 4800 8025 CHEMICAL CUTTER RECORD NS14 12-22-2005 SCH 1 11500 11867 CHEMICAL CUTTER RECORD NS08 10-26-2005 SCH 1 111 30 11915 CHEMICAL CUTTER RECORD NS19 09-26-2005 SCH 1 13700 13990 PERFORATION RECORD NS27 06-06-2005 SCH 1 10950 11 300 PERFORATION RECORD NS31 06-05-2005 SCH 1 10950 11320 PERFORATION RECORD NS24 09-22-2005 SCH 1 11800 12470 PERFORATION RECORD NS25 10-03-2005 SCH 1 18750 19200 PERFORATION RECORD NS21 07 -31-2005 SCH 1 22050 22225 PERFORATION RECORD NS08 12-16-2005 SCH 1 9500 11244 PERFORATION RECORD NS05 09-19-2005 SCH 1 13210 14002 PERFORATION RECORD NS06 09-17 -2005 SCH 1 13040 13825 PERFORATION RECORD NS18 12-08-2005 SCH 1 16200 16834 PERFORATION RECORD NS17 07 -29-2005 SCH 1 17850 18200 PERFORATION RECORD Petrotechnical Data Center LR2-1 900 E Benson Blvd, PO Box 196612 Anchorage, AK 99519-6612 ~ D?v" (4 ( ~/· (-<. BPXA WELL DATA TRANSMITTAL I I I I I I ~ (JiLl Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center . Attn: Cheryl Ploegstra Howard Okland Tim Ryherd Doug chromanski Ignacio Herrera Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 . Date: 03-15-2006 Transmittal Number:92763 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marlœr.doc e e FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Younger Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 ~o:}..~ 14-1 Re: Northstar Field, NS 18 Sundry Number: 306-059 ¡.c,., (J Dear Mr. Younger: 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. When providing 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. n . orm Chairman DATED this ~/day of February, 2006 Encl. bp e e BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 15, 2006 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RECEIVE FEB 1 7 {OOb Alaska Oil & Gas Anchorage Re: Sundry Notice for NS18 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS18 well. This well has exhibited a steady decline and historical analysis of formation water indicates the formation of CaC03 scale is likely. This well has responded well to similar treatments annually since 2003. The procedure includes the following major steps: · Pickle the tubing · Bullhead HCI based acid treatment / · Flowback Sincerely, Robert Younger Production Engineer BPXA, ACT, Northstar AL 1. Type of Request: en z~u~o' . STATE OF ALASKA ~ ~ ~"Mä/, AL OIL AND GAS CONSERVATION COMMI_N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development ø / Stratigraphic 0 \1..161'\- 1.../ U I %.-00 ~ RECEIVE FEB 1 7 ZOOb Abandon Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Suspend Repair well 0 Pull Tubing 0 Perforate Ala k Wðlve . . s a /I Stimulate [] Time Extension Re-enter Suspended Well Other as Cons. Cmnmís¡;¡,j" chorage 5. Permit to Drill Number: Exploratory 0 Service 0 202-1410 / 6. API Number: Anchorage, AK 99519-6612 7. KB Elevation (ft): 50-029-23102-00-00 /' 9. Well Name and Number: 55.85 KB NS18 / 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 16865 Casing Surface Production Liner Liner Total Depth TVD (ft): 11117.25 10. Field/Pools(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 16861 11113.5 None Junk (measured): None Collapse 2270 4760 5410 7500 Length Size TVD Burst 3989 13-3/8" 68# L -80 44 4033 44 3207 4930 14625 9-5/8" 47# L-80 43 14668 43 9234 6870 2070 7" 26# L-80 14471 16541 9088.99 10815 7240 503 4-1/2" 12.6# 13Cr80 16362 16865 10650.46 11117 8430 Perforation Depth MD (ft): 16775 - 16835 16830 - 16850 / Perforation Depth TVD (ft): 11032.76 - 11089.09 11084.39 - 11103.17 Tubing Size: 4-1/2" 12.6# ./ Tubing Grade: 13Cr80 Tubing MD (ft): 40 - 16369 Packers and SSSV Type: 4-1/2" TRM-4E SSV 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 12. Attachments: Descriptive Sum mary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Packers and SSSV MD (ft): 1045 14471 16323 "" 16362 Date: 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 Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Robert Younger Title Production Engineer Signature Phone 564-5392 Date COMMISSION USE ONLY 2/24/2006 Abandoned 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Robert Younger 2/10/2006 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3oú> - 0 5 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test D Location Clearance 0 Other: J,RDMS 8Ft 2 2 2006 APPROVED BY Date: ;. - p.. /, 0 {; Approved by: Form 10-403 Revised 7/2005 Submit in Duplicate NS18 / TREE WELLHEA D = A CTUA TOR = KB, NOTES: ***4-1/2" CHROME TBG & LNR*** o 1045' -14-1/2"TRM-4ESSSV,ID=3812" I ~ 1625' H 13-3/8" DV TOOL I 113-3/8" CSG, 68#, L-80 BTC, ID = 12.415" I Minimum ID = 3.5" @ 16369' Baker Model "A" Muleshoe 1 TOP OF 7" LNR 19-5/8" CSG, 47#, L-80 BTM-C, ID = 8.681" 4-1/2" TBG, 12.6#, 13CR VAM-ACE, .0152 bpf, ID = 3958" 17" LNR, 26#, L-80 Hydril 521. 10 = 6.276" PERFORA TION SUMMARY REF LOG: LWD on 12/31/02 (TIE-IN LOG GRlCCL 01/14/03) ANGLE AT TOP PERF: 20 16775' INITIAL PERF - CHARGE: 2906 POWERJET, HMX, PENETRA TION: 27", HOLE: 0.36", PHASE: 60 OEG. Note: Refer to Productíon DB lor hístorical perl data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 2-7/8" 6 16775 - 16835 0 01/23/03 2-7/8" 6 16830 - 16850 0 12/08/05 DATE 07/03/02 11/25/02 01/17/03 01/23103 11/04/05 12/08/05 REV B IPBTO I 4-1/2" LNR, 126#, 13CRVAM-ACE, .0152 bpi, ID = 3.958" 16865' REV BY COMMENTS BM H INITIAL COM PLETION 8M H INITIAL COM PLETION MJF FINAL COMPLETION MJF ADD PERFS BJM NEW FORMA T WRRlTLH REPERF/ADPERF DATE COMMENTS ST MO NO 1 6355 4498 2 7516 5115 GAS LIFT MANDRELS OEV TYPE VLV LATCH PORT 58 58 DATE 16276' -14-1/2" FIBER OPTIC TRANSDUCER, ID 3.958" 116281' ELM I 4-1/2" FIBER OPTIC TRANSDUCER, 10 3.958" 1630 l' 16323 ' 16347' 16358' 16369' 4-1/2" BKR MODEL "A" RA TCHETING MULESHOE, MIN ID = 3.5" NORTHSTAR WELL: NS18 PERMIT No: "'2021410 API No: 50-029-23102-00 BP Exploration (Alas ka) ~ AL.'- n"ot". t"^^ft - 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate D vmer u ~ __v _ Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension D Allt.hor age Change Approved Program D Operat. Shutdown D Perforate 0 Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~I Exploratory 0 202-1410 3. Address: P.O. Box 196612 Stratigraphic 0 Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-23102-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55.85 KB NS18 8. Property Designation: 10. Field/Pool(s): ADL-312799 Northstar Field/ Northstar Oil Pool 11. Present Well Condition Summary: Total Depth measured 16865 feet Plugs (measured) None true vertical 11117.25 feet Junk (measured) None Effective Depth measured 16856 feet true vertical 11113.5 feet Casing Length Size MD TVD Burst Collapse Surface 3989 13-3/8" 68# L-80 44 - 4033 44 - 3206.55 4930 2270 Production 14625 9-5/8" 47# L-80 43 - 14668 43 - 9234.29 6870 4760 Liner 2070 7" 26# L-80 14471 - 16541 9088.99 - 10815.44 7240 5410 Liner 503 4-1/2" 12.6# 13Cr80 16362 - 16865 10650.46 - 11117.25 8430 7500 SrI' ~~~ftr (;)' ~) '~~~J\Jl:< .¿': ",; (:~. Perforation depth: Measured depth: 16775 - 16835 16830 - 16850 True Vertical depth: 11032.76 - 11089.09 11084.39 - 11103.17 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 40 - 16369 Packers and SSSV (type and measured depth) 4-1/2" TRM-4E SSV 1045 7" Liner Top Packer 14471 7" Baker 13Cr80 Packer 16323 4-1/2" Liner Top Packer 16362 12. Stimulation or cement squeeze summary: R8DMS 8Ft .IAN 1 2; 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 5385 68536 338 550 3650 Subsequent to operation: 4231 53131 267 10 525 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development P1 Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil P1 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: 305·158 Contact Sharmaine Vestal Printed Name Sharmaine Vestal / Title Data Mgmt Engr Signatur~cf~ ?/~ Phone 564-4424 Date 1/10/2006 _ STATE OF ALASKA _ ALA~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEIVEù JAN 1 1 2006 siC] Form 10-404 Revised 04/2004 0 R \ G \ N A L Submit Original Only e - NS18 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE '~Ûlc, ''',is' SUMR!III~~' 12/2/2005 RIH w/ electronic release, gr-ccl, 20' gun. Attempt to perforate 16,830- 16,850. weight ck at 15,500 was max pull @ 3000 Ib's. pooh continue on 12-02-05. 12/3/2005 continue pooh and rig down. move unit over for Rig 33E to travel by. start work on BOP's to switch to .39" wire. 12/4/2005 *** JobF'r~p/~pot Equipment & Uprights**** 12/5/2005 *** Job Prep/Spot in Equipment*** 12/6/2005 ***Heat seawater & Load uprights**** 12/7/2005 ***LRS 38 North Star weather hold*** 12/8/2005 rih w/.39" wire, electronic release sub,gr/ccl, 20' x 2.88" 6 spf perf gun. perforate from 16830 to 16850'. return well to tender to pop. 12/9/2005 finish rig down FLUIDS PUMPED BBLS 550 SW 273 Lubetex 45 Diesel 6 Meth 3 Glycol 877 TOTAL .~i) ~ /;-\ "-lIT' '¡;=1 ,l ,',~ -,"," ,,1 ,ii' , ,!'~ "1" " ',', "Ii 1,' ~",\I' I'~ '\ " ;:J " ' , .: ",-~', ; J !! ,I rWJ ,II ;1,1\\', '\ ·I~ '''-' Ww ;;..¡ k) ,...:::::¡ ( '@,j-:=J Pi'· :16 !\ U J iU¡' '-' ( ¡-\ j1 ¡-\ ~ j"""'! 11 r:ï ':~'" :1 j j 1 'l Cw ;\ Jj("' ¡.~ \ i J \ ", J; /J L "'_,\, 1 l, / j:' \. !~\ I~I, ¡Wí, "'\ /.,1.\, ¡¡J'i I ~' 1 I '". ,i';, , ï¡' \U' ': '1-. f ¡.,..-." \ r'U J ¡ j \ \ JJ"-\ \ .:-J . ~;-J W "'--'''' W ~ " "':-1 FRANK H. MURKOWSKI, GOVERNOR AI,.SKA OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael 1. Francis, PE Senior Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 -' l\~\ '}O'ð- \ Re: NS 18 305-158 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 ou unless rehearing has been requested. DATED thi~day of June, 2005 Encl. bp ) ) .,. ,\.tf.'", ~~~ ~~. .-"- _.~ ........~ ~~~ .,.,,\,. ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 27, 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: R' 'E""" (""'\\ ~"""" IlæiJJ~ , :11711 ' ¡m:",'ZI i '\ "... ,"', ~"""'"' JUN 2 S Z005 Œ!& Re: Sundry Notice for NS18 to Peforate (Ivishak) BP Exploration Alaska, Inc. proposes to shoot perforation in the NS18 well. The recent correction of the original directional data in NS 18 revealed that the the oil /~ water contact is 18' lower than originally believed. Perforating 20' (15' of new perfs below the existing perfs and reperfing the bottom 5' of existing perfs) is recommended to increase the rate and lower the GaR from this well. The procedure includes the following major steps: Type Slickline Electric Line Work Description Drift/tag wI dummy gun Perforate 20' of Ivishak 16,830' - 16,850' MDrkb / Sincerely, :~~~~~ Senior petrore~m Engineer BPXA, ACT, Northstar ORIGINAL welt tv /Z,f/zfJoç ) {;(!.;r ro ~zJj - ð 5 ALASKA b'L AND ~~sT~g~S~':~~ON COMMISSlm,C;; r-'. i,',".,·lJ,.'"",: ~,:¡ ~;;\ , ':'f"",', ii,",',',,,,,,,,,},,,:: è C;!.. (J APPLICATION FOR SUNDRY APPRt)\tÞ:L":' \:,' "l:",,: ~ 20 AAC 25.280 JUN 2. Z005 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: Suspend 0 RepairWell 0 Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development [!J BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.85 KB 8. Property Designation: ADL-312799 11. Present Total Depth MD (ft): 16865 Casing Length peJ~~~t~&i]:~J ~~" ::'::'Wai~~1EJ::~:,icf~" Other D StimulateD "Tin,eEXtension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1410/, /' Exploratory D 6. API Number / 50-029-23102-00-00 Plugs (md): None Burst Junk (md): None Collapse StratigraphicD Service D 9. Well Name and Number: NS18 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11061.0 16856 11053.0 Size MD TVD SURFACE INTERMEDIATE LINER PRODUCTION top bottom top bottom 3989 13-3/8" 68# L-80 44 4033 44.0 3206.6 4930 2270 14625 9-5/8" 47# L-80 43 14668 43.0 9234.3 6870 4760 2070 7" 26# L-80 14471 16541 9089.0 10815.4 7240 5410 503 4-1/2" 12.6# 13Cr80 16362 16865 10650.5 11117.3 8430 7500 Perforation Depth MD (ft): 16775 - 16835 dóf<' ~,~o ~<;o \i"t Perforation Depth TVDss (ft): 10977 -11033 Tubing Size: 4-1/2 " Packers and SSSV Type: 7" Liner Top Packer 7" Baker 13Cr80 Packer 4-1/2" Liner Top Packer 4-1/2" TRM-4E SSV Tubing Grade: Tubing MD (ft): 12.6 # 13Cr80 40 Packers and SSSV MD (ft): 12. Attachments: 13. Well Class after proposed work: Description Summary of Proposal Œ1 Detailed Operations ProQram D BOP Sketch D 14. Estimated Date for Commencing Operation: 16369 14471 16323 16362 1045 / Exploratory D DevelopmentOO 15. Well Status after proposed work: Oil ŒJ / GasD PluggedD AbandonedD WAG 0 GINJD July 2, 2005 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: Printed Name Signature Michael Francis ~{~ (J :J/.~J {J¡ g - U Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test D RBDMS BFL JUN 3 0 2005 Location Clearance D \C - 4-04-. J ORIGINAL Form 1 0-403 Revised 11/2004 Contact Title Phone ServiceD WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Michael Francis Petroleum Engineer 564-4240 6/27/05 SundrY Number: .!StJ5 -Ió-g' BY ORDER OF ~~h / THE COMMISSION Date: I ' ~ dS SUBMIT IN DUPLICATE .. , TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI13-5/8" Multibowl 5ksi ') 13 3/8" DV Tool at +1-1625'MD 1 3 3/8", 68#/ft, L-80, BTC @ 4033' MD 4 1/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 14668' MD 4.5" X NIPPLE, @ 16301' MD 3.813" ID 4.5" X NIPPLE, @ 16347' MD 3.813" ID 4.5" XN NIPPLE, @ 16358' MD 3,725" ID Baker Model "A" Ratcheting Muleshoe, @16369' MD Note smalllD!!! 3.5" ID 7", 26#/ft L-80, Hydril 521 @ 16541' MD NS18 )RIGINAL KB. ELEV = 55.8' KB-BF. ELEV = 39.9' BASE FLANGE ELEV = 15,9' 4 1/2" TRM-4E SSSV @ 1045' MD w/4 1/2 "X" PROFILE=3.812" ID ~ .. 4 1/2" GLM @ 6355' MD (4505' TVD) wI 3,833" ID 41/2" GLM @ 7516' MD (5124'TVD) wI 3.833" ID þ. ~n}N 2 8 2005 ¿. ~ - 7" LINER TOP @14471' MD J V I 4.5" Fiber Optic Transducer 3.958 "ID 16281' MD elm, 10595 TVDrkb, 10540 TVDss -;;- _ 7" Baker S-3 PACKER. 13Cr @ 16323' MD, 10634' TVD ~E 1 E- 4.5" LINER TOP @ 16362' MD ~ ~ PERFORATION SUMMARY REF l.OG: LWD (12/31/2002) [Tie,in log:GR/CCl. 1/14/20031 ANGLE AT TOP PERF: 21 deg Note: Refer to Production DB for historical perf data Initial Perf, Charge: 2906 PowerJet, HMX; Penetration: 27"; Hole: ,36"; Phase: 60 deg I SIZE I SPF I INTERVAL MD I INTERVAl. TVD I Opn/Sqz I DATE I 2,875 6 16775',16835' 11051',11107' Opn 1/23/2003 PBTD @ 16856' MD, 1/14/03 E-line tag TD @ 16865' MD 1 ~ 4.5",12.6#, 13CrVam Ace DATE 7/3/02 11/25/02 1/17/03 1/23/03 REV. BY BMH BMH MJF MJF COMMENTS ""NS18 Proposed NS18 Proposed NS18 Post Rig Post Initial perfs BP Exploration (Alaska) URIC:NAL Northstar WFI I : NS18 API NO:50-029-231 02-00 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alaska ÙH & GtJ;; O,~~!"'~'r'~~'~ '~b~l.J1II~ ~,~\\.II WaiverD Time ExtensionD Re-enter Suspended Well 0 ~ rt~r~r, 'ED R t,:: ~~i",f! t,::, 11\ \/ ' ,- . . JUN 0 6 2005 (:ij~~mis Repair Well 0 Pull Tubing D Operation Shutdown D Pluç Perforations 0 Perforate New Pool D Perforate D Stimulate 00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ŒI Exploratory 0 5. Permit to Drill Number: 202-1410 6. API Numbe 50-029-23102-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.85 8. Property Designation: ADl-312799 11. Present Well Condition Summary: Stratigraphic D Service 0 9. Well Name and Number: NS18 10. Field/Pool(s): Northstar Field / Northstar Oil Pool Total Depth measured 16865 feet true vertical 11117.3 feet Effective Depth measured 16856 feet true vertical 11108.8 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse LINER 2054 7" 26# l-80 14487 - 16541 9100.6 - 10815.4 7240 5410 LINER 483 4-1/2" 12.6# 13Cr80 16382 - 16865 10668.8 - 11117.3 8430 7500 PRODUCTION 14625 9-5/8" 47# l-80 43 - 14668 43.0 - 9234.3 6870 4760 SURFACE 3989 13-3/8" 68# l-80 44 - 4033 44.0 - 3206.6 4930 2270 Perforation depth: Measured depth: 16775 - 16835 <C:'l·'ÖJ,~ì~lt.iE·"r,"'j I Ut~ J. il 2,005 \:..,,7 'i¡"'~'3'i'.: ' ,,~",..~, ! True vertical depth: 11032.76 - 11089.09 Tubing ( size, grade, and measured depth): 4-112" 12.6# 13Cr80 @ 40 16373 RBDMS B~L ,JUN 0 7 2005 Packers & SSSV (type & measured depth): 7" Top Packer 4-1/2" Top Packer 4-112" Baker S-3 Perm Packer 4-1/2" TRM-4E SSV @ 14471 @ 16362 @ 16323 @ 1045 12. Stimulation or cement squeeze summary: Intervals treated (measured): 16775' -16835' Treatment descriptions including volumes used and final pressure: 12 Bbls 12% HCl, 29 Bbls 12% HCl with l66 @ 3500 psig Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 48.7 278 950 38.2 460 810 13 Prior to well operation: Subsequent to operation: Oil-Bbl 5357 5590 Tubing Pressure 852 1115 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD DevelopmentŒ] Service 0 Signature Garry Catron Garry Catron .Jj(~,. rtJ::¡-~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 305-036 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name (-'\ U Title ') p~\nt \\:\"-""'/~....." \1h......&,Ii.;¡ Production Technical Assistant 564-4657 Date 6/3/05 Form 10-404 Revised 4/2004 ) ) NS18 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/18/05 ATTEMPT ACID TREATMENT / SCALE INHIBITION: UNABLE TO HEAT AND LOAD SEA WATER OR DIESEL WITH LRS TRUCK. WORK ENTIRE SHIFT ON REPAIRS. CREW TIMED OUT. WILL CONTINUE REPAIRS IN THE AM. 04/19/05 ACID TREATMENT / SCALE INHIBITION: CONTINUE WITH REPAIRS TO LRS PUMP. REPAIRS COMPLETED, FINISH HEATING SW THEN SNAP U-JOINT ON MISSION PUMP. REPAIRS TO MISSION PUMP COMPLETE. PUMP TBG PICKLE: 12 BBLS 12% HCL, 154 BBLS SW, 82 BBLS DIESEL. PRODUCE PICKLE BACK TO WELL CLEAN UP TANK. JOB IN PROGRESS... 04/20/05 ACID TREATMENT / SCALE INHIBITION: CON'T FROM PREVIOUS DAY. PUMP MAIN TREATMENT...29 BBLS 12% HCL W/ L66, 141 BBLS 2% KCL W/ L66, 15 BBLS DIESEL, 224 BBLS SW, 82 BBLS DIESEL (ALL FLUIDS HEATED TO +90 DEG F). SLOWED PUMP RATE TO 1 BPM WITH 15 BBLS ACID BEHIND PIPE (GIVING ACID -15 MINUTE SOAK TIME AT PERFS) & PICKED UP RATE TO +5 BPM FOR REMAINDER OF THE JOB. LET TREATMENT SOAK 4 HOURS AND POP TO WELL CLEANUP TANK. LDFN. FLUIDS PUMPED BBLS 5 Neat Methanal 12 120/0 HCL 282 2% KCL w/L66 378 SeaWater 179 Diesel 29 120/0 HCL w/L66 885 TOTAL Page 1 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi ) NS18 133/8" DV Tool at +1-1625'MD 133/8", 68#/ft, L-80, BTC @ 4033' MD ~ 4 1/2", 12.6#/ft, 13-Cr, Yam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBL/FT ~ 9-5/8" 47# L-80 BTM-C @ 14668' MD ¿. 4.5" X NIPPLE, @ 16301' MD 3.813" ID 4.5" X NIPPLE, @ 16347' MD 3.813" ID 4.5" XN NIPPLE, @ 16358' MD 3.725" ID Baker Model "A" Ratcheting Muleshoe, @16369' MD Note smaIlID!!! 3.5" ID 7", 26#/ft L-80, Hydril 521 @ 16541' MD ~- B J. PERFORATION SUMMARY REF LOG: LWD (12/31/2002) [Tie-in Log:GR/CCL 1/14/20031 ANGLE AT TOP PERF: 21 deg Note: Refer to Production DB for historical perf data Inilial Perf - Charge: 2906 PowerJet, HMX; Penetration: 27'; Hole: ,36": Phase: 60 deg I SIZE I SPF ¡INTERVAL MD I INTERVAL TVD I Opn/Sqz I DATE I 2,875 6 16775'·16835' 11051'-11107' Opn 1/23/2003 PBTD @ 16856' MD, 1/14/03 E-line tag j TD @ 16865' MD DATE 7/3/02 11/25/02 1/17/03 1/23/03 REV. BY BMH BMH MJF MJF COMMENTS ""NS18 proposed NS18 Proposed NS18 Post Rig Post I nitial perfs V I flGINAL KB. ELEV = 55.8' r\.B-BF. ELEV = 39.9' BASE FLANGE ELEV = 15.9' 4 1/2" TRM-4E SSSV @ 1045' MD w/4 1/2 "X" PROFILE=3.812" ID ... 4 1/2" GLM @ 6355' MD (4505' TVD) wi 3.833" ID 41/2" GLM @ 7516' MD (5124'TVD) wi 3.833" ID "I\. - 7" LINER TOP @14471' MD 4.5" Rber Optic Transducer 3.958 "ID 16281' MD elm, 10595 TVDrkb, 10540 TVDss -;¡ _ 7" Baker S-3 PACKER, 13Cr@ 16323' MD, 10634' TVD 'E ... ~ 4.5" LINER TOP @ 16362' MD 4.5",12.6#, 13CrVam Ace Northstar WFJ J : NS18 API NO:50-029-23102-00 BP Exploration (Alaska) J.- 3 FL;~ ; ~ 6 ~ DATA SUBMITTAL COMPLIANCE REPORT 21112005 Permit to Drill 2021410 Well Name/No. NORTHSTAR UNIT NS-18 Operator BP EXPLORATION (ALASKA) INC I J ' 5r tit ~ I ç, v v.l.) À.-tl"'\ ~ API No. 50-029-23102-00-00 MD 16865-' TVD 11135./ Completion Date 1 /23/2003 ~ Completion Status 1-01L Current Status 1-01L UlC N ~-- --- --~---- -------- ------ REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Q - --------~-.--~-- ---~--- DATA INFORMATION Types Electric or Other Logs Run: MWD, GYRO, GR, CCL, DIR, RES, PWD, RFT Well Log Information: Log/ Electr Data Digital Dataset _IJI'2',!JPt ~__nIIe~d/~rmt Number Name c.Rþt Directional Survey (data taken from Logs Portion of Master Well Data Maint) ~. Ck6g IJZÐ' 0 Ll:og ¥óg ~g Mud Log Directional Survey [.Gámma Ray L96rmation Tester ç-6~mma Ray Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 1 0 16865 Open 1/31/2003 2 Blu U' .f.., Ö 201 16550 Open 12/5/2002 1 0 16550 Open 8/14/2002 2 Blu "Cf 15885 Case 1/3/2003 5 Blu '"'1'4884 16774 Case 2/28/2003 5 Blu .< 14150 14478 Case 2/28/2003 Jewelry Log Depth Determination 201 16550 Open 9/5/2002 End of well report ~'~Blu V"1 ìvij 201 16550 Open 12/5/2002 W' ~g ~e Notes Mud Log Mud Log See Notes l.e~ísing collar locator 5 Blu ..2ð1 16550 Open 9/5/2002 ~onitoring .'............ 11530 16774 Case 2/28/2003 Jewelry Log Depth Determination 201 16550 Open 9/5/2002 i.1'íQ monitoring c7F' Mt:> 201 16550 Open 12/5/2002 201 16550 Open 9/5/2002 mud log data ASCII files 11530 16774 Case 2/28/2003 &Jewelry Log Depth Determ ination 0 16550 Open 8/14/2002 0 16865 Open 1/31/2003 0 15885 Case 1/3/2003 14150 14478 Case 2/28/2003 Jewelry Log Depth Determination ~'-- ~. ~ ~ ti--ED/D ~ :c:RPt ~/D ~ p.0g V'lLog See Notes Gamma Ray 2 5 Col Blu See Notes 5 5 Col Blu Directional Survey Directional Survey _ ~!ilsing collar locator ~asing collar locator 2 5 Blu Blu - ----~--- ----- DATA SUBMITTAL COMPLIANCE REPORT 211/2005 Permit to Drill 2021410 Well Name/No. NORTHSTAR UNIT NS-18 MD 16865 TVD 111 35 Completion Date 1/23/2003 - ~- -- - - '-112014L18 Verification s~~ C Asc C Pds 12014 Neutron i/ /'12014 ED C Pds Neutron ED C Pds 12014 Induction/Resistivity ~D C Pds .....12014 I nd uction/Resistivity '~ 12014 Neutron ,~' 12014 Neutron ~()g 12014 I nd uction/Resistivity j:;.09 12014 I nd uction/Resistivity .~ 12014 Nputron 'V ~inal Well R ------- ,----- Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y 'Ð Chips Received? ~ Analysis Y / N Received? -------- ----~ -------..--- ------~--- Comments: ------- , fr-o - ---------- Compliance Reviewed By: Operator.~ BP EXPLORATION (ALASKA) INC Completion Status 1-01L 25 1-5 25 1-5 25 1-5 25 1-5 25 1-5 'l5 Blu 1-5 LA5 Blu 1-5 ßß Blu 1-5 Q6'-- Blu 1-5 25 Rlu 1-5 Sent Received Daily History Received? Formatiçm Tops API No. 50-029-23102-00-00 Current Status 1-01L 221 16867 Open 7/17/2003 16515 16830 Open 7/17/2003 16515 16830 Open 7/17/2003 UIC N Vision Density Neutron - MD Vision Density Neutron - TVD 265 16767 Open 7/17/2003 Vision Resistivity - MD 265 16767 Open 7/17/2003 Vision Resistivity - TVD 16515 16830 Open 7/17/2003 ~!~iOn Density Neutron - <~ MD . 16515 16830 Open 7/17/2003 Vision Density Neutron - ¿:p¡rD 265 16767 Open 7/17/2003 LYision Resistivity - MD 265 16767 Open 7/17/2003 ....\IiSion Resistivity - TVD 16515- 15830 0p¡::m 7/1712003 Vision Den~ity Neutron - -MQ- 0 0 5/28/2003 Located in the Well History File. Sample Set Number Comments -~/"- ,ry ''t'/N '~j DJ/N Date: b2-~ t~ ~S--· ) ) ~ð2 -/¿j¡ ~ ~ß~C:-;:¡¡ Œ i' , I ¡ . i ¡ I ... ItA Ii II ,I , I ,,~¡ I I I . ,II..,; u !Æfi ,A n , li,iì./ '\ ~ ¡~l !Æ:A I,' il Ii íß \\\I!, il \ ,¡ ¡;::, n')! U ' ! G.uu,01!';:'" i .U,A.~fiA OIL AND GAS / CONSERVATION COMMISSION / , FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Michael Francis Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Northstar NS18 Sundry Number: 305-036 Dear 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 0 iday or weekend. A person may not appeal a Commission decision to Superia Cour unless rehearing has been requested. - DATED tlrisJ!Æ day of February, 2005 Encl. , ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV A'lliB 20 AAC 25.280 1. Type of Request: \AiGA- 2i22/2(ìO~ OIS <I 2.¿f..s 1 8 200S Operation Shutdown D Plug Perforations D Perforate New Pool 0 4. Current Well Class: Development Œ] ,{, i:' PerforateD §':fWåi:v:ef¡!~ Stimulate[!] Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 202-1410 "."'" Abandon D Suspend D Alter Casing D Repair Well D Change Approved Program D Pull Tubing D 2. Operator Name: BP Exploration (Alaska), Inc. (/ Exploratory D 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 Stratigraphic D Service D 9. Well Name and Number:, NS18 //' 10. Field/Pool(s): Northstar Field I Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 16856 11071.0 Size MD TVD 7. KB Elevation (ft): 55.85 KB 8. Property Designation: ADL-312799 11. Presen1 Total Depth MD (ft): 16865 Casing Total Depth TVD (ft): 11135.2 Length Other D 6. API Number / 50-029-23102-00-00 Plugs (md): None Burst Junk (md): None Collapse top bottom top bottom LINER 2054 7" 26# L-80 14487 16541 9127.9 10833.7 4930 2270 LINER 483 4-1/2" 12.6# 13Cr80 16382 16865 10687.5 11135.2 6870 4760 PRODUCTION 14625 9-5/8" 47# L-80 43 14668 43.0 9261.9 7240 5410 SURFACE 3989 13-3/8" 68#, L-80 44 4033 44.0 3206.6 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 16775 - 16835 11051 - 111 07.1 4-1/2 " 12.6 # 13Cr80 40 16373 Packers and SSSV Type: 7" Top Packer 4-1/2" Top Packer 4-1/2" Baker S-3 Perm Packer 4·1/2" TRM-4E SSV 12. Attachments: Packers and SSSV MD (ft): 14471 16362 16323 1045 Description Summary of Proposal ŒI Detailed Operations ProQram D BOP Sketch D 14. Estimated Date for Commencing Operation: 13. Well Class after proposed work: Exploratory D Development~ 15. Well Statu~r proposed work: Oil(Y Gasn PluggedD AbandonedD VJ4~ WAG D GINJD March 25, 2005 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: Contact Michael Francis sk '1Y{.NvJ L ¿ f'/A/Ýt/)., J p, F- e Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Printed Name Signature Title Phone Petroleum Engineer 564-4240 2/8/05 BOP TestD Mechanciallntegrity Test D Location Clearance D Other: Subseque - 40 4 . BY ORDER OF THE COMMISSION Date: yf,g/o( RBDMS 8Fl MAR () 1 2005 r¡ r~ ~ q ¡l,.._..- '....., . ...---. , , ~, ..~ iL__, Form 1 0-403 Revisea 11/2004 i4J41\- Service-~ WIN~ WDSPLD Prepared by Garry Catron 564-4657. Michael Francis Sundry Number: 3t)5-0.~G- SUBMIT IN DUPLICATE TREE: ABB-VGI 5 1/8" 5ksi ) WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi NS18 133/8" DV Tool at +/-1625'MD 133/8", 68#/ft, L-80, BTC @ 4033' MD ~ 4 1/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT ~ 9-5/8" 47# L-80 BTM-C @ 14668' MD H Jj- 4.5" X NIPPLE, @ 16301' MD 3.813" ID 4.5" X NIPPLE, @ 16347' MD 3.813" ID 4.5" XN NIPPLE, @ 16358' MD 3.725" ID Baker Model "A" Ratcheting Muleshoe, @16369' MD- Note smalllD!!! 3.5" ID 7", 26#/ft L-80, Hydril 521 @ 16541' MD j ~ PERFORATION SUMMARY REF LOG: LWD (12/31/2002) [Tle·ln Log:GR/CCL 1/14/2003] ANGLE AT TOP PERF: 21 deg Note: Refer to Production DB for historical perl data Initial Perl· Charge: 2906 PowerJet. HMX; Penetration: 27"; Hole: ,36"; Phase: 60 deg I SIZE I SPF I INTERVAL MD I INTERVAL TVD I Opn/Sqz I DATE I 2.875 6 16775'·16835' 11051'·11107' Opn 1/23/2003 PBTD @ 16856' MD, 1/14/03 E-line tag J TD @ 16865' MD DATE 7/3/02 11/25/02 1/17/03 1/23/03 REV. BY BMH BMH MJF MJF COMMENTS "'Ns 18 Proposed NS18 Proposed NS18 Post Rig Post Initial perfs .. )RIGINAL KB. ELEV = 55.8' KB-BF. ELEV = 39.9' BASE FLANGE ELEV = 15.9' 'I 1/2" SSSV @ 1040' TVD TRM-4E 3.812" ID 1045' md 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4030' TVD (5455'MD) .. 4 1/2" GLM @ 4504' TVD (6355' MD) wi 3.833" ID 41/2" GLM @ 5124' TVD (7516' MD) wi 3.833" ID ~ - 7" LINER TOP @14471' MD ~ I 4.5" Fiber Optic Transducer 3.958" ID 16281' MD elm, 10595 TVDrkb, 10540 TVDss -;;- _ 7" Baker S-3 PACKER, 13Cr @ ~- 16323' MD, 10634' TVD E 4.5" LINER TOP @ 16362' MD ... ~ 4.5", 12.6#, 13Cr Vam Ace Northstar WF. . : NS18 API NO:50-0?9-?310?-00 BP Exploration (Alaska) ~., . l'f\~ " bp ) ) ... ,\W'.tffl. ..'~ ~~. .-"~ ~...-. - ,~....... 1"- ,. BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 16, 2005 RlL'" , ~, f£: Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 FEB 1 8 ZOOS A~f~s!'a Oil ¿~l Dear Winton: Re: Sundry Notice for NS 18 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS18 well. This well has exhibited a high rate of decline and analysis of formation water indicates the / formation of CaC03 scale is likely. This well has responded very well to similar treatments in the past. The procedure includes the following major steps: . Bullhead HCI based acid treatment (which includes scale inhibitor) /" . Flowback Sincerely, ~~¡~ Senior Petroleum Engineer BPXA, ACT, Northstar OH\G d L ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D Repair Well 0 Pluç PerforationsD Pull Tubing 0 Perforate New PoolD Operation Shutdown 0 Perforate 0 2. Operator 8P Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development ŒJ Exploratory D Stimulate 00 OtherO WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 202-1410 6. API Number 50-029-23102-00-00 55.85 8. Property Designation: ADL-312799 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: NS18 10. Field/Pool(s): Northstar Field I Northstar Oil Pool Total Depth measured 16865 feet true vertical 11135.2 feet Effective Depth measured 16856 feet true vertical 11126.8 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Liner 2054 7" 26# L-80 14487 - 16541 9127.9 - 10833.7 7240 5410 Liner 483 4-1/2" 12.6# 13Cr80 16382 - 16865 10687.5 - 11135.2 8430 7500 Production 14625 9-5/8" 47# L-80 43 - 14668 43.0 - 9261.9 6870 4760 Surface 3989 13-3/8" 68# L-80 44 - 4033 44.0 - 3206.6 4930 2270 Perforation decth: Measured depth: 16775 - 16835 True vertical depth: 11050.84 -11107.11 RECEIVED 16373 SEP 2 1 2004 Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 40 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 4-1/2" Liner Top Packer @ 4-1/2" TRM-4E SSV @ 7" Liner Top Packer @ 16323 16362 1045 14471 12. Stimulation or cement squeeze summary: Intervals treated (measured): 16775 -16835 Treatment descriptions including volumes used and final pressure: 14 Bbls 12% DAD Acid @ 3026 psig Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 37.3 247 954 30.9 183 954 13 Prior to well operation: Subsequent to operation: Oil-Bbl 7951 6070 Tubing Pressure 963 2046 14. Attachments: ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: Oil [!] Gas D Development ŒJ Service D Copies of Logs and Surveys run _ Daily Report of Well Operations. WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 304-268 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )::Ict (' ~ Title Production Technical Assistant Signature Phone 564-4657 Date 9/16/04 Form 10-404 Revised 4/2004 ORIGiNAL â,~, .. ~. -~ SF? \ ~¡ 1 1,~\L;\ik, ~,~ , ' "', " ) ) J NS18 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/26/04 ACID TREATMENT: PUMP PICKLE AND FLOW BACK. PUMP SCALE INHIBITED 12 % DAD ACID TREATMENT AS PER PLAN. GIVE BACK TO OPS FOR 4 HOURS SOAK TIME AND TO FLOW BACK.. «JOB IS COMPLETE» BBLS 26 120/0 DAD Acid 448 Sea Water 164 Diesel 638 TOTAL FLUIDS PUMPED Page 1 bp ) ) ..,t~~I. ......~ ~~. I U/' .~:; i~" a O~ -. 7 ·"$4\- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 7,2004 / Winton Aubert Alaska Oil & Gas Oònservation Commission 333 West 7th 'Avenue Suite 100 Anchorage, AK 99501 Dear Winton: J\)L 113¡ 7\1ü4 Re: Sundry Notice for NS18 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS18 well. This well has exhibited a steady decline and analysis of formation water indicates the formation of CaC03 scale is likely. Last summer's acidizing campaign at Northstar was very successful. The procedure includes the following major steps: · Pickle the tubing · Bullhead HCI based acid treatment (which includes scale inhibitor) · Flowback Sincerely, ~~J~ Michael J. Fr£:cis, P.E. Senior Petroleum Engineer BPXA, ACT, Northstar O:iIGINAL VJ6t\ 7/14/2.004 ) 8T A TE OF ALASKA ) ~fiJf~-:: M{4!t1--- ALASKA OIL AND GAS CONSERVATION COMMISSION~"G'f1~ ,': 'I),. n4 APPLICATION FOR SUNDRY APPROV~t l'·~\~i ?Ûu 20 AAC 25.280 Liner 2054 Liner 483 Production 14625 Surface 3989 Perforation Depth MD (ft): 16775 - 16835 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 4-1/2" Liner Top Packer 4-1/2" TRM-4E SSV 7" Liner Top Packer 12. Attachments: Description Summary of Proposal Œ) 1. Type of Request: Abandon D D o Alter Casing Change Approved Program 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 55.85 KB 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 16865 Casing Total Depth TVD (ft): 11135.2 Length Suspend D D o o D D PerforateD WaiverD Annular DisposalD StimulateŒ] Time ExtensionD OtherD Re-enter Suspended Well 0 5. Permit to Drill ~ber: 202-1410 / Operation Shutdown Plug Perforations Perforate New Pool Repair Well Pull Tubing 4. Current Well Class: Development Œ] Exploratory 0 6. API Number /' 50-029-23102-00-00 Stratigraphic 0 Service 0 9. Well Name and Numbe7r: NS18 10. Field/Pool(s): Northstar Field / Northstar Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 16856 11071.0 MD TVD Plugs (md): None Burst Junk (md): None Collapse Size top 14487 16382 43 44 bottom top 16541 16865 14668 4033 Tubing Size: 4.5 " 12.6 # Packers and SSSV MD (ft): 16373 bottom 10833.7 11135.2 9261.9 3206.6 Tubing Grade: 13Cr80 7" 26# L-80 4-1/2" 12.6# 13Cr80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 11050.8 11107.1 Detailed Operations Program D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 9127.9 10687.5 43.0 44.0 7240 8430 6870 4930 Tubing MD (ft): 40 5410 7500 4760 2270 16323 16362 1045 14471 BOP Sketch D 13. Well Class after proposed work: ExploratoryD DevelopmentŒ) Service D August 1 , 2004 15. Well Status after proposed work: Oil ŒJ GasO WAG D GINJD PluggedO AbandonedO WINJD WDSPLD Prepared by Garry Catron 564-4657. Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Contact Michael Francis Michael Francis Title ~~....J I ¿jf"~ w. ) ,.J. ~ _ Phone e Commission Use Only 7/8/04 Petroleum Engineer 564-4240 Sundry Number: ....?O V- ¿¥.ð' Conditions of approval: Notify Commission so that a representative may witness Other: BOP TestO Mechanciallntegrity Test D Location Clearance 0 fe, - 404 BY ORDER OF THE COMMISSION Date: 1ffyY ,Jjl .~ 1 /.L::,· Approved by. Form 1 0-403 Revised 06/2004 O· r-) I ~~! í\ IA L __afl i\lUII.\J _ SUBMIT IN DUPLICATE TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI13-5/8" Multibowl 5ksi ) NS18 133/8" DV Tool at +1-1625'MD 133/8", 68#/ft, L-80, BTC @ 4033' MD ... 41/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" CAPACITY: 0.01522 BBLlFT ~ 9-5/8" 47# L-80 BTM-C @ 14668' MD ¿- 4.5" X NIPPLE, @ 16301' MD 3.813" ID 4.5" X NIPPLE, @ 16347' MD 3.813" ID 4.5" XN NIPPLE, @ 16358' MD 3.725" ID Baker Model "A" Ratcheting Muleshoe, @16369' MD - Note small IDI!! 3.5" ID 7", 26#/ft L-80, Hydril 521 @ 16541' MD J , E- ~ PERFORATION SUMMARY REF LOG: LWD (12/31/2002) [Tie-in Log:GR/CCL 1/14/2003) ANGLE AT TOP PERF: 21 deg Note: Refer to Production DB for historical perf data Initial Perf - Charge: 2906 PowerJet, HMX; Penetration: 27"; Hole: ,36"; Phase: 60 deg I SIZE I SPF I INTERVAL MD I INTERVAL TVD I Opn/Sqz I DATE I 2,875 6 16775'-16835' 11051'·11107' Opn 1/23/2003 PBTD @ 16856' MD, 1/14/03 E-line tag j TD @ 16865' MD DATE 7/3/02 11/25/02 1/17/03 1/23/03 REV. BY BMH BMH MJF MJF COMMENTS ""NS18 Proposed NS18 Proposed NS18 Post Rig Post Initial perfs ... )RIGINAL KB. ELEV = 55.8' r<B-BF. ELEV = 39.9' BASE FLANGE ELEV = 15.9' 4 1/2" SSSV @ 1040' TVD TRM-4E 3.812" ID 1045' md 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4030' TVD (5455'MD) ... 4 1/2" GLM @ 4504' TVD (6355' MD) wi 3.833" ID 4 1/2" GLM @ 5124' TVD (7516' MD) wi 3.833" ID ~ - 7" LINER TOP @14471' MD ~ I 4.5" Fiber Optic Transducer 3.958" ID 16281' MD elm, 10595 TVDrkb, 10540 TVDss -;;- _ 7" Baker S-3 PACKER, 13Cr @ ,- 16323' MD, 10634' TVD E 4.5" LINER TOP @ 16362' MD ~ ~ 4.5",12.6#, 13CrVam Ace Northstar WFI I : N~18 API NO:50-029-231 02-00 BP Exploration (Alaska) bp ) ) o BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 22,2004 Howard Okland Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 Mr. Jeffrey Walker Regional Supervisor Field Operations Minerals Management Service 949 East 36th Avenue, Suite 308 Anchorage, Alaska 99508-4363 tt"CICì (,\, ß 2.0012 ~~NED \1" lÇ.,t) ~~ß Dear Mr. Okland and Mr. Walker Northstar Reports Please find the following reports enclosed in response to a recent request for some data from Robert Crandall. ;·1.C') - (J~GìNS13 - Reservoir fluids - Kuparuk Sample (Sample - Downhole RFT) ~6~"1ibf. 'I NS18 - Preliminary Recombination Results (Sample - Separator Oil and Gas) ''19C\- OloONS31 - Reservoir Fluids -Ivishak Sample (Sample - Downhole MDT) For NS27 fluid samples were not taken in the Ivishak. Some RFT samples were taken in the Kuparuk, however they were flashed at the surface and only used for geochem analysis. There is some compositional analysis and PVT work on samples from NS09, NS13, NS08 and NS15 but the report has not yet been finalized. There was a request for the NS20 completion package. A copy of Form 1 Q-407 for NS20 has been enclosed. This was submitted to the agencies on 9/15/03. The final logs for NS20 are not yet available, as we were unhappy with the original primary depth control log. A new primary depth control log will be acquired as soon as it is logistically feasible, but please let us know if you would like us to provide you with field prints in the interim. Sincerely, Mic"1ael J. Fr Senior Petrole Northstar, BP REce'VED f/ ..~ n .I'} r. 0004 I 1 ¡"'It \ tA..;:;II,... .: ,I File: AOGCC (: h",,1~~ f~~! ,~r~ '~". ;. \'1,i,:·,':.A \\,;)i' '1':, \\.:..~,~IJ Ct1,nS CCfj{U~}~~~ "l~J:;;~I¡W~~;·A..!. ·,.;.n ) ) Preliminary Recombination Results for BP Exploration (Alaska), Inc. NS-18 Well Northstar Field, Alaska A product of PENCOR Special Fluid Studies wire Lab; PETH OLEUM SERVICES RFL 2003-036 4-Sep-2002 RECEIVED t·i :'} P 2 ~ ?i\04 ~: u \ V L....JJ ÞJaska Oil & Gas Cons. Comrnistlon Anchorage The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgement of Core Laboratories. Core Laboratories assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations or profitableness, however, of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. ). ~ ~- it/I! F;'l-t I' i.;"\ CorE! lab PEnlDLEUM ST:R.'mES September 4,2003 BP Exploration (Alaska), Inc. PO Box 196612 900 E. Benson Blvd Anchorage, AK 99519-6612 ATTENTION: Mr. Terry C. Wilcox Subject: File: Abreviated Study Northstar 18 Well Northstar Field, Alaska RFL 2003-036 Dear Mr. Wilcox, A sample of separator gas and two samples of separator liquid were collected from the subject well and sent to the PENCOR Advanced Fluid Studies laboratory located at Core Laboratories' Advanced Technology Center in Houston, Texas USA. The samples were evaluated for use in a well stream recombination and subsequent l11iscibility study. It has been a pleasure to perfon11 this study for BP Exploration (Alaska), Inc. Should any questions arise or if we may be of any fmiher service, please don't hesitate to contact me. Sincerely, Lee Williams Lab Manager Advanced Fluid Studies Houston, Texas LW:lw ) ) BP Exploration (Alaska), Inc. Northstar 18 Well RFL 2003-036 IJore LaI:1 i tf:11IQUU:HSUN»U:S Executive summary A sample of separator gas was received in a 2.5 gallon Schlumberger cylinder and two samples of separator liquid were received in 1-liter Welker cylinders at our PEN COR Advanced Fluid Studies laboratory in Houston, Texas for use in a miscibility study. Each sample was subjected to preliminary quality assurance tests. The separator gas cylinder was pre-heated to 141°F and the opening pressure was determined to be 761 psig. After heating the cylinder, a small amount of liquid was drained from the cylinder which subsequently solidified into an amber wax at ambient lab temperature. Each of the Welker cylinders containing separator liquid sample was pressurized to 1200 psig at ambient temperature. After pressurizing to 1200 psig at ambient temperature, one of the Welker cylinder rupture discs failed causing the cylinder to de-pressurize and resulting in the loss of the separator liquid sample. The remaining cylinder was inverted (sample side down) to drain the free water content; however, there was no free water in the cylinder. A portion of the same sample was charged to a PVT cell and heated to the sampling temperature of 129°F. The bubblepoint pressure of the sample was determined to be 700 psig at 129°F. Upon completion of the preliminary sample quality assurance tests, the compositions of the samples were measured by flash-chromatographic technique using Gas Producers Association (GPA) standard methods. Using the compositions and reported gas/oil ratio, the samples were physically recombined. A portion of the recombined sample was charged to a PVT cell and the bubblepoint pressure was determined to be 5273 psig at 254°F. After reviewing the historical data on the NS-18 well, it was determined that this bubblepoint was high in comparison to the known reservoir pressure. As a quality check on the recombination, the sample was re-pressurized in the PVT cell to single phase conditions and thoroughly homogenized. A separator test was then conducted in the cell at the reported separator conditions of 701 psig and 129°F. The recombined sample gas/oil ratio was determined to be 1591 scf of gas at 14.65 psia and 60°F per barrel of separator liquid at 701 psig and 129°F. This compared favorably to the target recombination gas/oil ratio of 1614.9 scf/bbl indicating that the physical recombination of the separator products was calculated and performed correctly. After review of the preliminary quality assurance tests and the bubblepoint of the recombined fluid, it was decided to recommend that any further analytical work using these samples be terminated as the testing might lead to nonrepresentative results. Observations After recombination of the separator products, the bubblepoint pressure of the recombined sample that was observed in the laboratory was not consistent with the known reservoir pressure suggesting that the sample might not be representative. In reviewing the quality assurance data, two potential sources for this were identified. Separator liquid samples for this well were collected in light duty Welker cylinders. These cylinders are not designed for sampling complex hydrocarbons since they cannot be heated to restore the samples in the laboratory. Heating of these cylinders compromises the strength of the safety rupture disc attached to the sample side of the cylinder and usually results in the loss of the sample. For waxy crudes such as these samples, this is a limitation that may result in paraffin deposits being left in the cylinder during subsampling or transfer of the cylinder contents. The second potential source of low quality sample was indicated by a condensable liquid volume in the separator gas cylinder with high wax content suggesting liquid carryover from the separator unit into the gas line at the time the sample was collected. This suspicion was further supported in comparing the compositions of the separator products using measured equilibrium ratios relative to GPA- published component equilibrium ratios. The samples appeared to be non-equilibrium products in the range of pentanes and heavier components (page one of this report). Since the separator liquid was compromised by the sampling vessel, the separator gas contained liquid carryover, the equilibrium ratios appeared skewed for PENCOR Advanced Fluid Studies Page i - RFL 2003-036 Core Laboratories BP Exploration (Alaska), Inc. Northstar 18 Well RFL 2003-036 íi.i~~~~':: ¡';:::: .... /, '1'11-.....,.......... ,:~.~~~'~.' ·'I<;:,::::.~~~, ' ' " ': ).~; '\e~~-;>,:I the heavier gas components and the bubblepoint of the recombined fluid was higher than the reported reservoir pressure, a recommendation was made and the decision was taken to terminate further testing. Laboratory Procedures Sample Quality Assurance Tests Two 1-liter capacity, DOT-approved, Welker piston cylinders were received in the laboratory marked as separator liquid samples along with a separator gas sample in a 12 liter Schlumberger cylinder. A complete list of samples received is presented on page one of the report. The separator liquid cylinders were connected to a water pump and pressurized to 1200 psig at ambient lab temperature. During the pressurization of cylinder TC 1130, the rupture disc failed and the sample was lost. Cylinder TC 1099 was inverted and the free water content drained into a graduated flask. After draining and measuring the free water content, the sample was placed in an upright position and agitated for a short period of time. Once homogenization of the sample was complete, a small portion of the sample was charged to a high-pressure, windowed PVT cell pre-heated to 129°F and the bubblepoint was measured. Comparison of the bubblepoint pressure to the reported sampling pressure indicated a good quality sample. Using the volume recorded on the sampling tag, the sample was deemed of sufficient quality and quantity for further use. The separator gas cylinder was placed in a temperature-regulated oven at 141°F and allowed to reach thermal equilibrium overnight. After heating and agitating the gas cylinder, the opening pressure of the cylinder was measured at the top valve. The free liquid content was drained from the bottom valve of the cylinder into a graduated flask. Finally, a small subsample of gas was charged directly to a micro-GC to determine air content in the separator gas. The preliminary quality assurance tests indicated that the gas sample was not of superior quality but might be sufficient for use in a physical recombination. Compositions of Separator Samples The subsample of separator liquid charged to the high-pressure, windowed PVT cell was repressurized and thoroughly homogenized at sampling temperature. The sample was subsequently charged to a temperature- controlled, atmospheric flash apparatus and the flashed gas and liquid were collected for compositional analysis. The volumetric and gravimetric data were recorded during the flash and used, with the measured compositions, to calculate the live liquid composition. The compositions of the flash products were measured using the methods described below. The separator liquid composition is reported on page three of this report. After completing the quality assurance tests on the separator gas sample, the cylinder was connected to a tri- column gas chromatograph for compositional analysis. The composition of the gas sample was measured using the method described below. The separator gas composition is reported on page two of this report. Gas Analysis - Gases produced in the laboratory testing program are analyzed by GPA method 2286 for extended natural gases on a Varian 3800 tri-column gas chromatograph. The gas is charged under partial pressure to the chromatograph using helium as the carrier. The chromatograph is equipped with an automated valving system that splits the sample onto three different columns including a mole sieve, silica and 'extended' column. The responses of the components eluting from the mole sieve column are directly proportional to their molar concentration in the sample and are recorded using a Thermal Conductivity Detector (TCD). The responses of the components eluting from the silica columns are directly proportional to their weight fraction in PENCOR Advanced Fluid Studies Page ii - RFL 2003-036 Core Laboratories ) ) BP Exploration (Alaska), Inc. Northstar 18 Well RFL 2003 -036 the sample and are recorded using a Flame Ionization Detector (FID). The responses from the detectors are integrated and combined to calculate the total gas sample composition by GPA 2286 method. Liquid Analysis - Liquid samples collected during the laboratory program are diluted in carbon disulfide (CS2) and analyzed using the ASTM 0-5134 method on a temperature-programmed Varian 3600 chromatograph equipped with a single silica-gel column using cold, on-column injection and helium as the carrier gas. The responses of the liquid components are detected by FID and are directly proportional to the weight fraction of the component in the total sample. Duplicate samples are charged to the chromatograph - one containing an internal calibration standard and another without the standard. The standard is used in subsequent calculations to correct for small upstream 'losses' of heavy components that coke in the column and never elute to the detector. The total sample molecular weight is measured by freezing point depression using an automated cryoscope calibrated with benzene. The total sample density is measured using an automated, frequency-based densitometer calibrated with triple-distilled water. After integrating the chromatogram, the integrated results are combined with the total sample molecular weight and density to calculate and balance the composition. Recombination Procedure A field-measured gas/oil ratio was recorded for the NS-18 well at, or around, the time of sampling. No corrections were applied to the field-measured gas/oil ratio. The separator products were physically recombined in a high-pressure laboratory cylinder to the prescribed ratio of 1614.9 scf/S1bbl. The recombined sample was thoroughly agitated and mixed at 7000 psig and 254°F. This sample was used for the remainder of the laboratory testing program. The recombination parameters and calculated recombined wellstream composition are presented on pages four and five of this report. Constant Mass Expansion A small subsample of the recombined fluid was charged to a high-pressure, windowed PVT cell at 7000 psig and 254°F for a constant mass expansion test. During the test, a bubblepoint pressure was observed at 5273 psig. Results of the expansion test are presented on page seven and eight of this report. Separator Test As a quality check on the recombination and after the bubblepoint measurement, the sample was re- pressurized and thoroughly agitated at 7000 psig and 254°F. A portion of the sample was charged through a temperature-controlled flash apparatus to ambient pressure for compositional analysis as described above. The remaining sample in the PVT cell was subjected to a separator test to determine the true gasíoil ratio of the reservoir fluid as a further quality check of the recombination. The composition of the reservoir fluid and the gas/oil ratio measured during the separator test indicated that the physical recombination was performed correctly. Results of the separator test are presented on page six of thise report. PENCOR Advanced Fluid Studies Page iìì - RFL 2003-D36 Core Laboratories TABLE OF CONTENTS Description Page Laboratory Procedures i-hi Preliminal-y Quality Checks and Sample Preparation Summary of Samples Received and Preliminary Checks of Sample Quality........... .. Separator Gas Composition. ... . . . ... .. . . . . . . . ... . .. . .. . .. . .. . . .. .. . .. .... . . . .. . . . . .. . . . . ... . . .. . 2 Separator Liquid Composition............................................... ..... ............... 3 Recombination Parameters and Calculated Well stream Composition..................... 4,5 Recombination Gas/Oil Ratio Check. ....... .......... ........... ...... . .... . . ..... ... ......... 6 Partial Pressure-Volume Relations at Reservoir Temperature....... . .......... ..... ....... 7,8 PEN COR Special Fluid Studies CORE LABORATORIES ) ') BP (Alaska) Exploration, Inc. Northstar NS-18 Well RFL 2003-036 SUMMARY OF SAMPLES RECEIVED and Preliminary Checks of Sample Quality ......., ........................ .......u.........................,................."..................."" Separator Gas Samples .~;·I!.~~·~·.~·Ú.~.;..~~:r..··· ............ ... ........ ...:........:.,... ·..·.·.::··1···.· 97 AO 08 ;;~......'.'..J.........................................'.....:..::...:..r......'.........'..... .. Cylinder Size, liters Sampling Conditions Pressure, psig Temperature, of Opening Conditions Pressure, psig Temperature, of Liquid Content, cc Air Content, mol% ¡ .. :.··.f, ...."............,.,. ............. 12 701 128.6 761 141 2 0.673 Separator Liquid Samples ··········::·::::::r::·.·::·:.·· TC 1 ~·~·~·~·····..··:·:.'r··::·········~~···~·~·~'~;···::.·::"'r:..::.":':":':::'. .:..J.:,::::..:...:::::.::.:~.:::.::...:. ::.:........::::[....'.. .~Y.lì.~9~.r...t.'I~.r.!1~.~.r. Cylinder Size, cc Sampling Conditions Pressure, psig Temperature, of Bubblepoint Check Pressure, psig Temperature, of Water Content, cc Sample Volume, cc 1000 1000 701 701 128.6 128.6 700 na 129 na 0 na 800 na . These samples selected for recombination and further analysis. + Sample lost through rupture disc at room temperature and 1200 psig. 10 -~ ro > ~ .Q ro a::: E .2 :9 :; 0- w 0.1 PENCOR Special Fluid Studies 100 .... ........ ............... ' :i~··.~...... '. nC5 "':. <;6 Theoretical Equilibrium Ratios'calculated at 701 psig and 128.6 'F(dashed line) I 0.01 -400 -100 -200 100 200 -300 Boiling Point, of 'Source: GPSA Engineering Data Book. Page 1 CORE LABORATORIES BP (Alaska) Exploration, Inc. Northstar NS-18 Well RFL 2003-036 COMPOSITION OF PRIMARY STAGE SEPARATOR GAS (by Programmed-Temperature, Capillary Chromatography) Plant Liquid Component Mol% Products Density MW (GPM) (gm/cc) SAMPLING CONDITIONS Hydrogen Sulfide 0.00 Carbon Dioxide 6.72 0.8172 44.010 701 psig Nitrogen 0.94 0.8086 28.013 128.6 of Methane 78.20 0.2997 16.043 Ethane 7.65 2.033 0.3562 30.070 Propane 3.73 1.021 0.5070 44.097 iso-Butane 0.47 0.153 0.5629 58.123 n-Butane 0.86 0.269 0.5840 58.123 Gas Cylinder iso-Pentane 0.15 0.055 0.6244 72.150 97A00873 n-Pentane 0.15 0.054 0.6311 72.150 Hexanes 0.21 0.081 0.6850 84.0 Average Sample Properties Heptanes 0.21 0.088 0.7220 96.0 Octanes 0.36 0.163 0.7450 107 Critical Pressure, psia ..................................... 687.9 Nonanes 0.35 0.174 0.7640 121 Critical Temperature, oR .................................. 397.7 Average Molecular Weight ............................... 21.89 Calculated Gas Gravity (air = 1.000) ............. 0.756 Totals ........... 100.00 I 4.091 at 14.65 psia and 60 of Properties of Plus Fractions Heating Value, Btu/scf dry gas' Gross ............... ................................,.....,....... 1139 Component Liquid Liquid Mol% Density API (gm/cc) Gravity 0.92 0,7480 57.5 MW Heptanes plus 109.8 Note: Component properties assigned from literature. . ref: Gas Producers & Suppliers Association (GPSA) Engineering Data Book PENCOR Special Fluid Studies Page 2 CORE LABORATORIES ) ') BP (Alaska) Exploration, Inc. Northstar NS-18 Well RFL 2003-036 COMPOSITION OF PRIMARY STAGE SEPARATOR LIQUID (by Flash I Programmed-Temperature, Capillary Chromatography) Liquid Component Mol % Wt% Density MW (gm/cc) Hydrogen Sulfide 0.00 0.00 SAMPLING CONDITIONS Carbon Dioxide 2.35 0.83 0.8172 44.010 Nitrogen 0.06 0.01 0.8086 28.013 701 psig Methane 13.82 1.77 0.2997 16.043 228.6 of Ethane 5.43 1.30 0.3562 30.070 Propane 6.60 2.32 0.5070 44.097 iso-Butane 1.74 0.81 0.5629 58.123 n-Butane 4.65 2.16 0.5840 58.123 iso-Pentane 2.21 1.27 0.6244 72.150 Liquid Cylinder n-Pentane 3.14 1.81 0.6311 72.150 TC 1099 Hexanes 4.56 3.06 0.6850 84.0 Heptanes 7.59 5.82 0.7220 96,0 Octanes 9.01 7.70 0.7450 107 Average Sample Properties Nonanes 5.82 5.62 0.7640 121 Decanes 4.31 4.61 0.7780 134 Average Molecular Weight ............................... 125.27 Undecanes 3.46 4.06 0.7890 147 Calculated Density at 0 psig and 60 of ........... 0.7649 Dodecanes 2.92 3.75 0.8000 161 Tridecanes 2.81 3.93 0.8110 175 Tetradecanes 2.54 3.85 0.8220 190 Pentadecanes 1.96 3.22 0.8320 206 Hexadecanes 1.70 3.01 0.8390 222 Heptadecanes 1.44 2.72 0.8470 237 Properties of Plus Fractions Octadecanes 1.36 2.72 0.8520 251 Nonadecanes 1.24 2.60 0.8570 263 Liquid Liquid Eicosanes 0.95 2.09 0.8620 275 Plus Fraction Mol% Wt% Density API MW Heneicosanes 0.87 2.02 0.8670 291 (gm/cc) Gravity Docosanes 0.76 1.85 0.8720 305 Tricosanes 0.66 1.68 0.8770 318 Heptanes plus 55.44 84.66 0.8377 37.3 191 Tetracosanes 0.60 1.59 0.8810 331 Undecanes plus 28.71 60.91 0.8778 29.5 266 Pentacosanes 0.53 1.46 0.8850 345 Pentadecanes plus 16.98 45.32 0.9059 24,5 334 Hexacosanes 0.46 1.32 0.8890 359 Eicosanes plus 9.28 31.05 0.9373 19.3 419 Heptacosanes 0.41 1.22 0.8930 374 Pentacosanes plus 5.44 21.82 0.9684 14.5 502 Octacosanes 0.38 1.18 0.8960 388 Triacontanes plus 3.29 15.45 1.0038 9.3 588 Nonacosanes 0.37 1.19 0.8990 402 Triacontanes plus 3.29 15.45 1.0038 588 Totals ........... 100.00 I 100.00 I PENCOR Special Fluid Studies Page 3 CORE LABORATORIES BP (Alaska) Exploration, Inc. Northstar NS-18 Well RFL 2003-036 WELLSTREAM RECOMBINATION CALCULATION (based on field production data) Conditions for Recombination Calculations Primary Stage at 701 psig and 129 OF Field Gas Rate Correction Factors - Gas Gravity (air=1,OOO) ..................,............................... Gas Gravity Factor, Fg ........................................................ Field Measured Rates and Ratios - Primary Stage Gas Flow Rate, Mscf/D ............................. Primary Stage Liquid Flow Rate, bbl/D ............................ Primary Stage Gas I Oil Ratio, scf/S'bbl .......................... Gas Deviation Factor, Z ..........,............................................ Super Compressibility Factor, Fpv ...................................... Pressure Base, psia ........................................................... 14.650 Recombination Rates and Ratios- Laboratory Gas Rate Correction Factors - Gas Gravity (air=1.000) ....................................................... 0.756 Gas Gravity Factor, Fg (not applied).................................... 1.1503 Gas Deviation Factor', Z ..................................................... 0.904 Supercompressibility Factor, Fpv (not applied)................... 1.0516 Pressure Base, psia ........................................................... 14,650 Laboratory Liquid Rate Correction Factors - Liquid Volume Factor, S'bbl/bbl @ 60 of ........................... na Bitumen, Sediment & Water (BS&W) Factor ...................... 1.000 . From: Standing, M.B" "Volumetric and Phase Behavior of Oil Field Hydrocarbon Systems", SPE (Dallas), 1977, 8th Edition, Appendix II. .. Data not supplied to Core Laboratories PENCOR Special Fluid Studies Page 4 Primary Stage Gas Flow Rate, Mscf/D ............................. Primary Stage Liquid Flow Rate, bbl/D ............................ Primary Stage Gas I Oil Ratio, scf/bbl .............................. We/lstream Recombination Ratio mol/mol.......................... 9670.0 5988 1614.9 9670.0 5988 1614.9 2.0553 CORE LABORATORIES ) ') BP (Alaska) Exploration, Inc. Northstar NS-18 Well RFL 2003-036 COMPOSITION OF RECOMBINED WELLSTREAM (from calculated recombination of separator products) Liquid Component Mol % Wt% Density MW (gm/cc) Hydrogen Sulfide 0.00 0.00 RECOMBINATION CONDITIONS Carbon Dioxide 5.29 4.18 0.8172 44.010 Nitrogen 0.65 0.33 0.8086 28.013 701 psig Methane 57.13 16.43 0.2997 16.043 129 of Ethane 6.92 3.73 0.3562 30.070 Propane 4.67 3.70 0.5070 44.097 iso-Butane 0.89 0.93 0.5629 58.123 n-Butane 2.10 2.19 0.5840 58.123 Recombination Parameters iso-Pentane 0.82 1.06 0.6244 72.150 n-Pentane 1,13 1.46 0.6311 72.150 Primary Stage Gas I Oil Ratio, scf/bbl Hexanes 1.63 2.46 0.6850 84.0 at recombination conditions ........................... 1614.9 Heptanes 2.63 4,53 0.7220 96.0 Wellstream Recombination Ratio Octanes 3.19 6.12 0.7450 107 moles gas I mole liquid ................................... 2.0553 Nonanes 2.14 4.65 0.7640 121 Decanes 1.41 3.39 0.7780 134 Undecanes 1.13 2.98 0.7890 147 Average Wellstream Properties Dodecanes 0.96 2.77 0.8000 161 Tridecanes 0.92 2.89 0.8110 175 Average Molecular Weight ............................... 55.7 Tetradecanes 0.83 2.83 0.8220 190 Calculated Density at 0 psig and 60 of ........... 0.5982 Pentadecanes 0.64 2.37 0.8320 206 Hexadecanes 0.56 2.23 0.8390 222 Heptadecanes 0.47 2.00 0.8470 237 Properties of Plus Fractions Octadecanes 0.45 2.03 0.8520 251 Nonadecanes 0.41 1.93 0.8570 263 Liquid Liquid Eicosanes 0.31 1.53 0.8620 275 Plus Fraction Mol% Wt% Density API MW Heneicosanes 0.28 1.46 0.8670 291 (gm/cc) Gravity Docosanes 0.25 1,37 0.8720 305 Tricosanes 0.22 1.26 0.8770 318 Heptanes plus 18.77 63.53 0.8358 37.6 189 Tetracosanes 0.20 1.19 0.8810 331 Undecanes plus 9.40 44.84 0.8778 29.5 266 Pentacosanes 0.17 1.05 0.8850 345 Pentadecanes plus 5.56 33.37 0.9059 24.5 334 Hexacosanes 0.15 0.97 0.8890 359 Eicosanes plus 3.03 22.81 0.9373 19.3 419 Heptacosanes 0.13 0.87 0.8930 374 Pentacosanes plus 1.77 16.00 0.9684 14.5 502 Octacosanes 0.12 0.84 0.8960 388 Triacontanes plus 1.08 11.40 1.0038 9.3 588 Nonacosanes 0.12 0.87 0.8990 402 Triacontanes plus 1.08 11.40 1.0038 588 Totals ........... 100.00 I 100.00 I PENCOR Special Fluid Studies Page 5 CORE LABORATORIES BP (Alaska) Exploration, Inc. Northstar NS-18 Well RFL 2003-036 RECOMBINATION GAS/OIL RATIO QUALITY CHECK (performed in PVT cell) Flash Conditions Gas/Oil Gas/Oil Stock Tank Formation Separator Specific Oil Phase Ratio Ratio Oil Gravity Volume Volume Gravity of Density ( scf/bbl ) ( scf/STbbl ) at 60 of Factor Factor Flashed Gas ( gm/cc ) (A) (B) ( ° API) Bofb (C) (0) ( Air=1.000 ) psig I of 129 1,591 40.4 0.738 0.5501 + 0.7965++ 5273 701 254 + Single point measurement (no redundant data for quality check). ++ Calculated density at indicated pressure and temperature from measured gravity at 60°F, (A) Cubic Feet of gas at 14.65 psia and 60 OF per Barrel of oil at indicated pressure and temperature. (B) Cubic Feet of gas at 14.65 psia and 60 of per Barrel of Stock Tank Oil at 60 of, (C) Barrels of saturated oil at 5273 psig and 254 of per Barrel of Stock Tank Oil at 60 of, (0) Barrels of oil at indicated pressure and temperature per Barrel of Stock Tank Oil at 60 of, PEN COR Special Fluid Studies Page 6 CORE LABORATORIES PENCOR Special Fluid Studies ) ') BP (Alaska) Exploration, Inc. Northstar NS-18 Well RFL 2003-036 VOLUMETRIC DATA (at 254 OF) Saturation Pressure (Psat) ................................... Density at Psat .............. .............. ......................... 5273 psig 0.5501 gm/cc AVERAGE SINGLE-PHASE COMPRESSIBILlTIES Pressure Range psig Single-Phase Compressibility v/v/psi 7000 6500 6000 5500 6500 6000 5500 5273 25.48 E -6 29.48 E -6 35.30 E -6 43,72 E -6 to to to to Page 7 CORE LABORATORIES CORE LABORATORIES Page 8 (A) Relative Volume: VNsat or volume at indicated pressure per volume at satur 0.5810 0.5737 0.5654 0.5635 0.5617 0.5597 0.5577 0.5556 0.5533 0.5521 0.5509 0.5501 0.9468 0.9589 0.9730 0.9761 0.9794 0.9828 0.9864 0.9902 0.9942 0.9963 0.9986 1.0000 Density gmlcc Relative Volume (A) 7000 6500 6000 5900 5800 5700 5600 5500 5400 5350 5300 b»5273 Pressure psig PRESSURE-VOLUME RELATIONS (at 254 OF) BP (Alaska) Exploration, Inc. Northstar NS-18 Well RFL 2003-036 PEN COR Special Fluid Studies ) ) Date: 05-27-2003 Transmittal #92651 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS23 05-09-2003 SCH 1 0 13981 MWD SURVEY R~QRT/HARD.cOPY/ DISKETTE r\.c~.; '\,,"~ ~ A. ~ ~ f:)r;Y-d67 NS19 05-03-2003 SCH 14012 12550 JEWELRY LOG; -- . ~~' NS10 03-25-2003 SCH 4850 8015 RST WFL-UP FLOW MODE; ~O·-\ NS19 05-05-2003 SCH 13140 14000 PERFORATING RECORD; - NS06 04-09-2003 SCH 13000 13788 PERFORATING RECORD; - ~S23 05-01-2003 SCH 11040 13333 PERFORATING RECORD; ~.. . NS23 04-29-2003 SCH 13340 13212 DEPTH DETERMINATION SAMPLE BAILER;....,··'· ?J{j/!) .. \ C\ \ NS06 04-11-2003 SCH 13025 13746 BAKER IBP SET RECORD; ~~I L\ \ .~S18 07 -17 -2002 SPERRY 1 END OF WELL REPORT/MUDLOG: --¡;2:13 NS22 01-22-2003 SPERRY 1 END OF WELL REPORT/MUDLOG: @..~ -jlPt-f NS24 12-27 -2002 SPERRY 1 END OF WELL REPORT/MUDLOG: ~\.~tJV'.. ~ dJ A~'_ V\. Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center ~.~ r': C c: 'VI:': 0 f-{ r:.. ~ Q~- ~ !...... MIX y 2. e Z000 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ."" ", I..'....~ """.\.{''''~'t.¿i¡'V:'\ r.I!"I)ÍI<\C.· .: l .,", \,,; '1(;. \..~..¡.th~"i:""'~ ~!:wT\t.,.¡ ,,, "". ....1.....'" ... ., ,~:i,:;1 t~:~ 'l .'" " I; ) BPXA WELL DATA TRANSMITTAL BP - Ken Lemley BP - Ester Fueg AOGCC Attn: Lisa Weepie Murphy Exploration (Alaska), Inc. Attn: Jason Smith DNR - Division of Oil & Gas Attn: Tim Ryherd MMS Attn: Doug Choromanski Attn: Kristin Dirks (DNR) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ) Date: 05-27-2003 Transmittal #92651 ) STATE OF ALASKA )- ALASr,A OIL AND GAS CONSERVATION COMh..JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD Alter CasingD Change Approved Program 0 Suspend c:J Repair WellC] Pull TubingL:] Operation Shutdown 0 Plug perforationsD Perforate New Pool D PerforateD VarianceD Stimulate~ Time ExtensionD Re-enter Suspended WellD Annular DisposalD OtherD 2. Operator BP Exploration (Alaska), Inc. Name: 4. Current Well Class: Development Œ ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 StratigraphicD ServiceD 9. Well Name and Number: NS-18 10. Field/Pool(s): Northstar 5. Permit to Drill Number: 202-1410 6. API Number 50-029-23102-00-00 7. KB Elevation (ft): 55.85 8. Property Designation: ADL-2799 11. Present Well Condition Summary: I Northstar Total Depth measured 16865 feet true vertical 11135 feet Plugs (measured) Effective Depth measured 16856 feet true vertical 11 015 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 3989 14625 483 2054 13-3/8" 68# L-80 9-518" 47# L-80 4-112" 12.6# 13Cr80 7" 26# L-80 44 43 16382 - 14487 - 4033 14668 16865 16541 44 43 10687.46 - 9127.88 - 3206.56 9261.85 11135.2 10833.7 4930 6870 8430 7240 2270 4760 7500 5410 Perforation depth: Measured depth: 16775' - 16815', 16815' - 16835' True vertical depth: : 11050.84' -11088.35' ,11088.35' -11107.11' Tubing: ( size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 @ 40' - 16373' MD Packers & SSSV (type & measured depth) 7" Liner Top Packer @ 14471' MD / Baker S-3 Packer @ 16323' MD-, 4-1/2" Liner Top Packer @ 16362' MD /4-1/2" TRM-4E SSV @ 1045'MD~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: (See Attachment) Prior to well operation: Subsequent to operation: 14. Attachments: Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 6,700 16,500 93 9,844 20,570 237 Tubing Pres¿J'rè" 741 1472 13 15. Well Class after proposed work: ExploratoryD DevelopmentŒ] Service D Signature Michael J. Francis, P.E. Michael J. Francis ~eAa ,1 r.:f--~ 16. Well Status after proposed work: Operational Shutdown D OilŒ GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 303-243 Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Senior Petroleum Engineer Phone 564-4240 Date 9/26/03 ORIGINAL ~~ ~lrê- :k~ .~ ~ Ll~'\Ùj Form 10-404 Revised 4/2003 ) ) NS-18 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/23/03 Acid Treatment, well flowing on arrival, Pump pickle per procedure, 12 bbls 12% DAD Acid, 154 bbls SW, 82 bbls Diesel, flowback pickle to production. 08/24/03 Pickle pumped and flown back, continue with main DAD Acid treatment per procedure, 14 bbls 12% DAD Acid, 254 bbls SW, shut down for 30 minute soak, 40 bbls SW, 82 bbls Diesel, leave well shut in for 4 hours, turn over to production. FLUIDS PUMPED BBLS 26 120/0 DAD Acid 448 Sea Water 164 Diesel 638 TOTAL Page 1 bp ') ) .,. ,\If.'ll. ..~~ ~~..- ~- --:....~ ..~ ~... ·"~1\" BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 15, 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for NS18 to Acidize (Ivishak) BP Exploration Alaska, Inc. proposes to acidize the NS18 well. This well has exhibited a high rate of decline and analysis of formation water indicates the formation of CaC03 scale is likely. Additionally, CaC03 scale was recovered from the offset NS 13 wellbore using slickline. The procedure includes the following major steps: · Pickle the tubing · Bullhead HCI based acid treatment (which includes scale inhibitor) · Flowback Sincerely, o/Jt' /J~ ~ ..- C 11 ~J( ,---:F¿VY'-t¿,,,,;, MicH el J. Fr is, P.E. Senior Petrol m Engineer BPXA, ACT, Northstar O~IGINAL ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 VJC1A- .1i(i i{2-0o'3 ¿;--;1f ~l2 1. Type of Request: D D D PerforateD VarianceD Annuar Disposal D Abandon Suspend Operation Shutdown Alter Casinq 0 Repair Well 0 Pluq Perforations 0 Stimulate IX! Time Extension 0 OtherD Chanqe Approved Proqram 0 Pull Tubinq 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): RKB 55.85 8. Property Designation: ADL-312799 11. Total Depth MD (ft): 16865 Casing Conductor Surface Intermediate Liner Production Liner 5. Permit to Drill Number: 202-1410 /' 6. API Number /' 50-029-23102-00-00 4. Current Well Class: Development IX! ExploratoryD Stratigraphic D Service D 9. Well Name and Number: NS18 ../ 10. Field/Pool(s): Northstar / Northstar PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 11135.24 16856 11015.1 Length Size M D TVD 3989 13.37511 68# L-80 14625 9.62511 47# L-80 2070 711 26# L-80 503 4.511 12.6# 13CR80 Perforation Depth TVD (ft): 11050.8' -11107.1' Plugs (measured): Junk (measured): Burst top bottom top bottom 44 - 4033 44 - 3206.5 5020 43 - 14668 43 - 9261.9 6870 14471 - 16541 9116.2 - 10833.7 7240 16362 - 16865 10669.2 -11135.2 8440 Collapse 2270 4760 5410 7500 Tubing MD (ft): 49.3' - 16369' Perforation Depth MD (ft): 16775' -16835' // I-"ackers and SSSV 'I ype: 711 HYD 521 Liner Top Pkr, 711 Baker S-3 Pkr, 7" VAM ACE Liner Top Pkr 4.5" TRM-4E SSSV 12. Attachments: Description Summary of Proposal IX! Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Tubing Grade: 12.6# 13CR80 Packers and SSSV MD (ft): 14471',16323',16362' 1045' 13. Well Class after proposed work: ExploratoryD DevelopmentOO ServiceD 15. Well Status after proposed work: Oil I!] GasD PluggedD AbandonedD WAGD GINJD WINJD WDSPLD Prepared by S. Copeland 564-4424 8/20/2003 Date: Tubing Size: 4.511 Printed Name 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Francis Signature Production Engineer 564-4240 Date 8/15/03 Michael Francis Title ~?'I1",,j {) ~/A.:")') Phone ¡ (1'-- Commission Use Only Plug Integrity D Conditions of approval: Notify Commission so that a representative may witness Location ClearanceD Other: BOP TestD Mechanciallntegrity TestD Subsequent Form Required: ì (!) - 40L{ Approved by: Form 10-403 Revised 2/2003 BY ORDER OF COMMISIONER THE COMMISSION OR\G\NAL Sundry Number: .3o"3-¡'t../3 /: t ~ "_:,1 _~ ~ --:., Date: SUBMIT IN DUPLICATE .' bp ... ,,\If.''', -......~ ~..,.~ ~..- ~..-- ..~ F..... ·'.'·'1'" ". ) ) To: Gary McBride/John Smart - Well Operations Supervisor August 8, 2003 From: Mike Francis and Patty Hill - Northstar Subject: NS18 DAD Acid/51 Treatments AFE NSZ832018 Est. Cost: $60 M lOR: Est 250 BOPD Please perform an acid stimulation/SIT with 120/0 DAD acid on the NS18: Type lOR PR N DSWL AFE Job Description Priority Com ments/Other o 250 NS18 NSZ832018 Pump Acid and SIT NS 18 has suffered significant decline since start-up. The water chemistry indicates CaC03 scale formation is likely and the presence of scale has been confirmed in the offset NS13 well. This treatment will dissolve the scale and place scale inhibitor in the formation. The treatments are being combined to simplify logistics. Procedure 1. Mobilize pumps, tanks and acid transport to Northstar. 2. Order out volume of seawater and diesel to flush both the pickle and the acid job. See attached Volumes table. 3. RU pumping equipment. 4. Hold PJSM. Possible hazards on this job include bringing partially spent acid back to surface when the pickle is produced back. 5. Preheat seawater and diesel to 80°F. The heating of these displacement fluids will eliminate the need to hold backside pressure on the wells during treatment. 6. PT Dowell surface lines to 5000 psi 7. Pump the following fluids to pickle the production tubing at 3 bpm, 3500 psi max pressure. ~ a) 12 Bbls 120/0 DAD acid b) 154 Bbls seawater c) 82 Bbls diesel 8. Produce pickle back to test separator and well clean up tank. The pickle volume to flowback is 248 Bbls. ) ') '. 9. Pump the following treatment at maximum rate or 3500 psi max pressure. a) 14 bbls 120/0 DAD Acid b) 254 bbls Seawater (To displace acid to perfs) c) Shut down for 30 minutes and allow acid to soak d) 40 bbls Seawater (for over flush and displacement) e) 82 bbls Diesel (for displacement and under-balance) 10. Shut well in for 4 hours to allow scale inhibitor to precipitate. 11. RD Schlumberger. 12. Flow back Procedure: For flow back, line up into the test separator and well cleanup tank. Produce clean-up volume of 391 bbls. After clean-up, divert back to the plant and get 2 6-hour tests. Fluid descriptions: 120/0 DAD Acid to contain: 100/0 Nalco Scale Inhibitor + 0.60/0 A261 + 4 ppt A179 + 8 ppt A 153 + 0.20/0 F103 + 20 ppt L58 + 1.50/0 U74 + 100/0 Xylene Note: Acid strength to be verified and documented via titration before leaving Schlumberger. Results will be available on location. Procedure Contacts: Mike Francis WK: 564-4240 H M: 644-0534 Cell: 529-8678 Patty Hill WK: 564-4346 H M: 248-6262 Cell: 350-0742 TREE: ABB-VGI 5 1/8" 5ksi ) WELLHEAD: ABB-VGI13-5/8" . Multibowl 5ksi NS18 ,¡. 133/8" DV Tool at +/-1625'MD 13 3/8", 68#/ft, L-80, BTC @ 4033' MD ~ 4 1/2", 12.6#/ft, 13-Cr, Yam-Ace TUBING ID: 3.958" .. CAPACITY: 0.01522 BBL/FT 9-5/8" 47# L-80 BTM-C @ 14668' MD H ~- 4.5" X NIPPLE, @ 16301' MD 3.813" ID 4.5" X NIPPLE, @ 16347' MD 3.813" ID 4.5" XN NIPPLE, @ 16358' MD 3.725" ID Baker Model "A" Ratcheting Muleshoe, @16369' MD - Note small 10!!! 3.5" 10 7", 26#/ft L-80, Hydril 521 @ 16541' MD J , E- J. PERFORATION SUMMARY REF LOG: LWD (12/31/2002) [Tie-in Log:GR/CCL 1/14/2003] ANGLE AT TOP PERF: 21 deg Note: Refer to Production DB for historical perf data Initial Perf· Charge: 2906 PowerJet. HMX; Penetration: 27"; Hole: ,36"; Phase: 60 deg I SIZE I SPF I INTERVAL MD I INTERVAL TVD I Opn/Sqz I DATE I 2.8756 16775'·16835' 11051'-11107' Opn 1/23/2003 PBTD @ 16856' MD, 1/14/03 E-line tag J TD @ 16865' MD DATE 7/3/02 11/25/02 1/17/03 1/23/03 COMMENTS ~S18 ~roposed NS18 Proposed NS18 Post Rig Post Initial perfs REV. BY BMH BMH MJF MJF ~ )RlGINAL KB. ELEV = 55.8' KB-BF. ELEV = 39.9' BASE FLANGE ELEV = 15.9' '1 1/2" SSSV @ 1040' TVD TRM-4E 3.812" ID 1045' md 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4030' TVD (5455'MD) ~ 4 1/2" GLM @ 4504' TVD (6355' MD) wi 3.833" ID 4 1/2" GLM @ 5124' TVD (7516' MD) w/ 3.833" ID ~ - 7" LINER TOP@14471'MD V I 4.5" Fiber Optic Transducer 3.958" ID 16281' MD elm, 10595 TVDrkb, 10540 TVDss -;:;- _ 7" Baker S-3 PACKER, 13Cr @ ~- 16323' MD, 10634' TVD E 4.5" LINER TOP @ 16362' MD ~ ~ 4.5",12.6#, 13Cr Yam Ace Northstar WFI I : N~18 API NO:50-029-231 02-00 BP Exploration (Alaska) ) )8oa- - ) LI ( Date: 06-24-2003 Transmittal N umber:92654 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the Petrotechnical Data Center at (907) 564-4091 or by e-mailingtojohnsojh@bp.com Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS18 07 -16-2002 SCH 1-5 265 16767 VISION RESISTIVITY BOREHOLE CORRECTED LOG; MEASURED DEPTH; COMPOSITE FINAL PRINT; NS18 07 -16-2002 SCH 1-5 265 16767 VISION RESISTIVITY BOREHOLE CORRECTED LOG; TRUE VERTICAL DEPTH LOG; COMPOSITE FINAL PRINT; NS18 07 -16-2002 SCH 1-5 265 16767 VISION DENSITY NEUTRON; TRUE VERTICAL DEPTH LOG; COMPOSITE FINAL PRINT; NS18 07 -16-2002 SCH 1-5 265 16767 VISION DENSITY NEUTRON; MEASURED DEPTH LOG; COMPOSITE 0 FINAL PRINT; 0\ NS18 07 -16-2002 SCH 1-5 265 16767 NS18 OPENHOLE DATA ON CD RO~ ,~ RECEIVED p~ /1 . l~A" ð // ~~~~:~ Pleas~~-~~rn~~f this transmittal. ~ Thank You, V James H. Johnson Petrotechnical Data Center Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Howard Okland (AOGCC) Attn: Jason Smith (Murphy Exploration Alaska), Inc Attn: Kristin (ON R) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~\s~\\ \ ~ \. ) ) Date: 02-28:-2003 Transmittal Number:92583 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type NS-22 01-24-2003 SCH 1 0 12860 JEWELRY LOG GR/CCL;CD v aD~-aa.3 ROM; NS-17 12-15-2002 SCH 50 17170 CEMENT BOND LOG/PRIMARY v dÖd.-lln'1 DEPTH CONTROL; NS06 06-03-2002 SCH MWD SURVEY REPORT; ./ dDJ.--IOJ HARDCOPY/DISKETTE; NS-18 01-05-2003 SCH 15530 16774 JEWELRY LOG GR/CCL DEPTH v dDa.- JY I DETERMINATION NS-24 01-06-2003 SCH 11750 12464 JEWELRY LOG; PERFORATING vaDd.-lIo4 RECORD NS-18 01-12-2003 SCH 14150 14478 GAMMA RAY COLLAR LOG; / .a~..JL 1 DEPTH DETERMINATION NS-27 / 01-09-2003 SCH 10700 11255 PERFORATING RECORD; ADD ~Ol-0~ ï PERF - 2.875" PJ HSD NS-18 V :Jë?!~RJT SCH 14884 16774 REPEAT FORMATION TESTER ~af: £~~ copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley Bp - Ester Fueg AOGCC Attn: Howard Okland Murphy Exploration (Alaska), Inc. Attn: Buford Bates RECEIVED DNR - Division of Oil & Gas Attn: Tim Ryherd FEB 28 2003 AJaaka Oil & Gas Cons. Cornnieeion Andøige MMS Attn: Doug Chorolnanski Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) \ ) 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1219' NSL, 645' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 3179' NSL, 4595' WEL, SEC. 03, T13N, R13E, UM At total depth 3205' NSL, 4648' WEL, SEC. 03, T13N, R13E, UM X = 650386, Y = 6038062 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Northstar Unit RKB = 55.85' ADL 312799 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/16/2002 ' 12/30/2002 1/23/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 16865 11135 FT 16861' 11131' FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GYRO, GR , CCL , DIR , RES, PWD , RFT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 2011 169# X-56 Surface 201' 2011 13-3/811 68# L-80 44' 4033' 1611 9-5/811 47# L-80 43' 14668' 12-1/411 711 26# L-80 14471' 16541' 8-1/211 4-1/211 12.6# 13Cr80 16362' 16865' 6-1/811 Classification of Service Well I : I ':'~'~ 7\~ ~ 1__~,~2_-;-~ L~~~~~~j ;U>J'~ 'b~!}~'.-"'t~"'I!,Iit\'\""~,', ' ~11.x~'T1OiÇ1 ;.; y~~ ~~ ~~Dì~b~~, , ~.::Li ij !I~': I II' ft, ",~,,-:r;!J" ,~~,,,,'i::I"~~' L<l41·~' ,..'~,.~;:i X = 659829, Y = 6030991 7. Permit Number 202-141 8. API Number 50- 029-231 02-00 9. Unit or Lease Name Northstar Unit X = 650440, Y = 6038036 10. Well Number NS18 15. Water depth, if offshore 16. No. of Completions 39' MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 1045' MD 1545' (Approx.) CEMENTING RECORD Driven 699 sx PF 'L', 472 sx Class 'G' 794 sx Econolite, 564 sx Class 'G' 325 sx Class 'G' 93 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/811 Gun Diameter, 6 SPF MD TVD MD TVD 25. SIZE 4-1/211, 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 16373' PACKER SET (MD) 16323' 16775'-16835' 11051'· 11107' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 375 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 24, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF 1/31/2003 4 TEST PERIOD 11941 19.51 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF Press. 24-HoUR RATE WATER-BBL 23.22 WATER-BBL CHOKE SIZE GAS-Oil RATIO 192 1 .638 Oil GRAVITY-API (CORR) o 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submii:ãb'¡dîipå: ~ ')", .'. \. i No core samples were taken. )\\as¡{(i UL2~" !,,:. Form 10-407 Rev. 07-01-80 ""''¡ ~ ~ HUM S 1:1 ~ l ~ ~ [,:" Co ~ \"):1 '\ ('Î. 1 ~\! ",'1¡ 1 . ..-. .: ,,' ': '\~ 1 . I ",I t-r I;.,. I II 1 \"\ I, ' I' ~"o-,,'~:¡ U h \".I J 11:-..... !\14R 4 20rn Submit In Duplicate ') 29. Geologic Markers Marker Name Measured Depth Top of Ugnu 6848' Top of Schrader Bluff 9711' Top of Kuparuk 13885' Kuparuk C 14191' Top of Miluveach 14628' Top of Kingak 15290' Top of Sag River 16503' Top of Shublik 16610' Top of Ivishak 16710' ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 4766' RFT was ran, log will be supplied with details. 6325' 8716' 8920' 9232' 9757' 10799' 10897' 10990' ,A!asl(i.1 ',\, ."j 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary, Leak-oft Test Summary 32. I hereby certify that the.f?!egoing is true andçorrect to the best of my knowledge Signed SO"f.~:?~~~~ ne Technical Assistant Date Od .¿;:¡L ,œ NS 18 202-141 Prepared By Name/Number: Sandra Stewman, 564-4750 Well Number Permit No. I Approval No. Drilling Engineer: Barbara Holt, 564-5791 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) BP EXPLORATION Paget .of 25 Op~rations Sum.maryReport Legal Well Name: NS18 Common Well Name: NS18 Spud Date: 7/15/2002 Event Name: DRILL +COMPLETE Start: 7/11/2002 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/16/2003 Rig Name: NABORS 33E Rig Number: 33E Date . From- To Höurs Task Code NPT Phase Description of Operations 7/15/2002 17:00 - 17:30 0.50 RIGU P PRE PJSM on skidding rig. 17:30 - 19:00 1.50 RIGU P PRE Skid rig 20' to the north to NS-18. 19:00 - 21 :00 2.00 RIGU P PRE General RIU after skid. Notes: 1) Berm around rig 2) Connect purz 3) Let down stairwells. 4) Hook up injection line. 21 :00 - 00:00 3.00 RIGU P PRE NIU riser & mouse hole. Note: Accepted rig on NS18 @ 21 :00 on 7/15/2002. 7/16/2002 00:00 - 02:00 2.00 RIGU P PRE Finish general R/U. 02:00 - 05:30 3.50 DRILL P SURF PI U BHA # 1. Note: Change out stab. sleeves on motor & 1 stab. 05:30 - 05:45 0.25 DRILL P SURF Fill riser wi sea water & check for leaks. Riser leaking at o-ring. 05:45 - 11 :30 5.75 DRILL N RREP SURF Repair leak in O-Ring on scoping riser connection. Notes: 1) Pulled riser. 2) Changed O-Ring 3) Skidded rig for better alignment of riser. 4) Replace riser. Riser still leaking. 5) Unclamp Junk ring, install rope packing and silicone at leaking area. 6) Leak repaired Note: Investigating better ways to seal in future. 11 :30 - 12:00 0.50 DRILL P SURF Clean out conductor to 200' md. 12:00 - 12:30 0.50 DRILL P SURF Spud Well-- Drill to 230' md. 12:30-13:00 0.50 DRILL P SURF Held Pre-Spud Meeting & PJSM for RIU gyro Notes: 1) Discussed objectives of well. (No Accidents, No Spills or risk to the environment, no policy or law violations, & drilling a quality cost effective well. 2) Hazards associated wi hole section. 3) Drilling parameters of this particular section. 4) Reviewed D-7 drill. 13:00-14:00 1.00 DRILL P SURF RIU gyro & conduct electronic test. 14:00 - 14:30 0.50 DRILL P SURF Gyro survey - Base of conductor Incl. .43 deg, Az. 348.45 deg 14:30 - 16:00 1.50 DRILL P SURF Drill from 230' to 330' md. 16:00 - 16:30 0.50 DRILL P SURF POH wI BHA # 1. 16:30 - 18:30 2.00 DRILL P SURF M/U BHA # 2. 18:30 - 00:00 5.50 DRILL P SURF Drill & run gyro from 330' to 732' md. 7/17/2002 00:00 - 08:15 8.25 DRILL P SURF Drill & slide from 732' to 1382'. Note: 1) Per stand - Sliding 25', rotating 20', sliding 25', & rotating remainder of stand. 08: 15 - 09:30 1.25 DRILL P SURF Pump sweep & run final gyro. 09:30 - 10:30 1.00 DRILL P SURF PJSM - RID Schlumberger. 10:30 - 00:00 13.50 DRILL P SURF Drill & slide from 1382' to 2620' pumping hi-vis sweeps as needed. 7/18/2002 00:00 - 03: 15 3.25 DRILL P SURF Drill & slide from 2620' to 2821'. 03: 15 - 03:30 0.25 DRILL N SFAL SURF Clean mud pump suction screens on both mud pumps. Noise interfering with signal from MWD. 03:30 - 04: 15 0.75 DRILL P SURF Drill & slide from 2821' to 2905'. Packing off while backreaming Printed: 1/20/2003 9:23:03 AM ) ') , BP EXPLORATION Operations Sum 111 a ry Repo.rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From - To Hours Task Code NPT Phase 7/18/2002 03:30 - 04:15 0.75 DRILL P SURF 04:15 - 05:00 0.75 DRILL P SURF 05:00 - 07:45 2.75 DRILL P SURF 07:45 - 08: 15 0.50 DRILL N RREP SURF 08:15 - 18:30 10.25 DRILL P SURF 18:30 - 20:30 2.00 DRILL P SURF 20:30 - 21 :30 1.00 DRILL P SURF 21 :30 - 23:30 2.00 DRILL P SURF 23:30 - 00:00 0.50 DRILL P SURF 7/19/2002 00:00 - 03:00 3.00 DRILL P SURF 03:00 - 04: 15 1.25 DRILL P SURF 04:15 - 04:30 0.25 DRILL P SURF 04:30 - 05:30 1.00 DRILL P SURF 05:30 - 08:00 2.50 CASE P SURF 08:00 - 08:30 0.50 CASE P SURF 08:30 - 16:30 8.00 CASE P SURF 16:30 - 17:00 0.50 CASE P SURF 17:00 - 18:00 1.00 CASE P SURF 18:00 - 21 :00 3.00 CASE P SURF 21 :00 - 21 :30 0.50 CEMT P SURF 21 :30 - 00:00 2.50 CASE P SURF 7/20/2002 1.00 CASE P SURF 00:00 - 01 :00 Page20f 25 Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Description of Operations before a connection. Pump fresh water hi vis sweep & circulate hole clean. Drill & slide from 2905' to 3191'. Saver sub backed out of top drive while making a connection. M/U to top drive & retorque. Drill & slide from 3191' to surface hole TD @ 4050'. Note: Pumped 75 bbl. fresh water mud sweep while drilling last stand down. Pump 75 bbl. weighted hi-vis nut plug I barafibre swep. Pumped 1 surface to surface & 1 additional B/U. Hole cleaned up on 2nd B/U. Monitor well - POH w/2 stands while checking for swabbing - okay. Pump dry job & blow down lines. POH to HWDP. Note: 1) TOH was good with minimum drag of 10 - 20K. 2) Dry wiped stand 21 & 23 once wI 45K drag. After going back down, pulled through with 20K drag. Tight spots -130' apart which might indicate only 1 tight spot as different stabs. passed by. UD BHA#2. Note: Tops of stabs, motor stab. sleeve & bit wI significant amounts of clay. UD BHA#2. Clean rig floor & clear floor of stabs. & bit. Prepare for casing tool RIU. PJSM - Cut & slip drilling line. Cut & slip drilling line. PJSM - UD bails, P/U Frank's fill up tool, & RIU casing tools. PJSM for running casing. Run 98 jts. of 13 3/8" 68 lb. L-80 Buttress Casing. Note: P/U landing jt, hangar & land. UD Frank's tool & RIU cement head & x-over. Break circulation by staging pump up slowly from .5 BPM to 10 BPM. Final circulating pressure @ 10 BPM - 390 psi. Note: 1) Service top drive while circulating. 2) Held PJSM for cement job. 3) Pumped 70 bbl. bi-carb spacer before turning over to HOWCO pump. Pump 5 bbls. of sea water & test cement lines to 3000 psi. Check for leaks & retest. Pump 75 bbls. 10.2 weighted spacer - dropped bottom plug - pumped 517 bbls. 10.7 ppg lead cement followed by 96bbls. of 15.9 ppg tail cement. Dropped top plug & chased wI 25 bbls. sea water. Displace cement wI rig pump @ 10 BPM. Notes: 1) Bumped plug wI 566 bbls. of mud @ 95.6% pump efficiency. 2) Tested casing to 1950 psi & held for 3 min. (OK) Printed: 112012003 9:23:03 AM ') ) BP EXPLORATION Operation~ Summary Report Page 3 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From- To Hours Task Code NPT Phase Description of Oþerations 7/20/2002 01 :00 - 01 :30 0.50 CASE P SURF Check floats (OK) & LID cement head. 01 :30 - 03:00 1.50 CASE P SURF RID landing jt. - flush riser - LID casing tools & clean floor. 03:00 - 03:30 0.50 CASE P SURF NID surface riser. 03:30 - 04:00 0.50 CASE P SURF Remove rig mat from cellar. 04:00 - 05:00 1.00 CASE P SURF N/U Vet co multi bowl assy & test to 2500 psi. 05:00 - 09:30 4.50 CASE P SURF N/U BOP's. 09:30 - 11 :00 1.50 CASE P SURF cia bails, install iron roughneck floor track, RIU test equip't & fill stack. 11 :00 - 15:00 4.00 CASE P SURF Test BOP's 250/4800 & hold for 5/5 min. 15:00 - 16:15 1.25 CASE P SURF Pull test plug & install bowl protector. 16:15 - 18:00 1.75 CASE P SURF RIH w/8 stands of HWDP & POH LID singles via pipeshed. 18:00 - 19:00 1.00 CASE P SURF Clear floor & bring BHA to floor. 19:00 - 22:00 3.00 CASE P SURF M/U BHA #3 & shallow test MWD & rotary steerable assy. 22:00 - 00:00 2.00 CASE P SURF P/U 63 jts. of 5" DP from pipeshed & RIH. 7/21/2002 00:00 - 01 :30 1.50 CASE P SURF P/U Porcupine reamer, dart sub & RIH. 01 :30 - 02:00 0.50 CASE P SURF Break circulation & wash from 3877' to top of float equip't plugs. 02:00 - 03:00 1.00 CASE P SURF RIU & pressure test 13 3/8" casing to 3500 psi wi 9.2 ppg mud & hold for 30 mins. Note: 1) Discussed well control wi crew mwmbers. (D1, D2, & D5 drills) 2) Discussed drilling hazards associated wI hole section. 03:00 - 06:00 3.00 CASE P SURF Drill float equip't plugs, shoe track, & rathole to 4050'. 06:00 - 07:00 1.00 CASE P SURF Displace wel to new 8.6 ppg mud. 07:00 - 07:30 0.50 DRILL P INT1 Dill from 4050' to 4070'. Circulate MW in to equal MW out. 07:30 - 08:00 0.50 DRILL P INT1 Perform FIT to 12.5 EMW wI 8.6 ppg mud. (650 psi) 08:00 - 12:00 4.00 DRILL P INT1 Establish ECD baseline (8.89 - 8.93) & drill from 4070' to 4710'. 12:00 - 17:30 5.50 DRILL P INT1 Drill 12.1/4" from 4710' to 5687'. 17:30 - 17:45 0.25 DRILL P INT1 Service top drive. 17:45 - 00:00 6.25 DRILL P INT1 Continue drilling 12.1/4" from 5687' to 6500'. 1) Pumping sweeps every 400 -500' or as needed. 2) ECD is staying close to .7 ppg above mud weight. 3) Inconsequential amounts of metal from porcupine reamer while inside casing. 4) No Drag, No losses. Wiping bottom 30 ft. 7/22/2002 00:00 - 12:00 12.00 DRILL P INT1 Drill from 6500' to 8066'. 1) Sweeping hole every 500'. 2) Maintaining MW @ 9.0 ppg wi ECD's in 9.7 to 9.8 range. 12:00 - 14:00 2.00 DRILL P INT1 Drill from 8066' to 8159'. 14:00 - 14:30 0.50 DRILL P INT1 Service top drive, crown, & blocks. 14:30 - 00:00 9.50 DRILL P INT1 Drill 12.1/4 " hole from 8159' to 8756'. Note: Drilling some hard spots - notably from 8751' to 8757' - 3 hrs. to drill 6'. Reduced RPM to 105 while drilling hard streaks. No drag, No losses. Pretreating Sandstones with LCM. 7/23/2002 00:00 - 16:30 16.50 DRILL P INT1 Drill ahead 12-1/4" hole with RSS from 8756' md to 10160' md in the Schrader Bluff and Ugnu. - Rap from 9-200 fph - WOB 10K-lbs, 150 rpm, Torque on 15-16 K ft-Ibs. - 54.83 deg Inclination and 309.34 deg Azim. Printed: 1/20/2003 9:23:03 AM ') !- ') 11 BP EXPLORATION QpérationsSummary Report Page.4of25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From - To Hou rs Task Code NPT Phase Descriptionof Operations· 7/23/2002 00:00 - 16:30 16.50 DRILL P INT1 - Pumping high vis sweeps every 500'. 16:30 - 17:30 1.00 DRILL P INT1 Build and pump 70 bbls high visc BAROFIBREI Walnut sweep. No excess cuttings noted on sweep return. 17:30 - 20:30 3.00 DRILL P INT1 Drill ahead 12-1/4" hole from 10160' md to 10445' md. - Rap from 75- 137 fph. - 285 units gas @ 10281' (max gas) 20:30 - 21 :30 1.00 DRILL P INT1 Service top drive. 21 :30 - 00:00 2.50 DRILL P INT1 Drill ahead 12-1/4" hole from 10445' md to 10620' md into Colville (Field pick Top @ 10613' mdl 6849' tvd). - Slow drilling @ -10495' mdl 6781 tvd. Rap < 10 fph -- Hard streak. - Rap from 68- 137 fph. 7/24/2002 00:00 - 18:30 18.50 DRILL P INT1 Drill ahead 12-1/4" Interm. hole from 10620' mdto 12346' md wi RSS Assy. -Rap averaging 132.3 fph overall. -ECD stable and running from 9.8 to 10.1 wI MW in= 9.4 ppg. -Inclination 53.8 deg and azimth of 305 deg. - WOB= 15-20 K-Ibs, 900 gpm wI 3100 psig. - ROT wI 150 rpm and torque increasing to 22 K ft-Ibs. 18:30 - 19:00 0.50 DRILL P INT1 Service Top-drive. 19:00 - 23:00 4.00 DRILL P INT1 Drill ahead 12-1/4" hole from 12346' md to 12682' md. - Rap, ECD, and Torque good. - Running sea-water at 100+ bbl/hr and dumping mud to G & I to control mud wt and LGS. 23:00 - 23:30 0.50 DRILL N RREP INT1 Mud Pump #1 developed end gasket leak. Continue pumping wI Pump #2. Safeout Pump #1 and repair. 23:30 - 00:00 0.50 DRILL P INT1 Pump repaired come on line and drill ahead from 12682' md to 12726' md. 7/25/2002 00:00 - 18:00 18.00 DRILL P INT1 Drill ahead 12-114" hole from 12726' to 14191' md. - Rap from 120-162 fph. - WOB= 20K Ibs - Pump rate 870-900 gpm wi 3250 psig. - 150 rpm wI Torque running 22-23 K ft-Ibs - MW 10.5 ppg wI ECD 10.9 HRZ interval did not show, eroded away. Found Kalubik @ 13830'1 8679' tvd Drill into Kuparuk @ 13885' mdl 8715' tvd 18:00 - 19:00 1.00 DRILL P INT1 Drilling ahead 12-1/4" hole in Kuparuk "C". - Top Kuparuk "C" @ 14191' mdl 8919' tvd (Max gas 1935 units) 19:00 - 20:00 1.00 DRILL N RREP INT1 Change out swab on #2 mud pump. 20:00 - 00:00 4.00 DRILL P INT1 Drill ahead 12-1/4" hole from 14237'md to 14439' md. - Top Kuparuk "B" @ 14255' md/8963' tvd. - Top Kuparuk "A" @ 14330' mdl 9015' tvd (Max gas 1257 units). Becoming power limited wI plant running 2 turbines wI power to Printed: 1/20/2003 9:23:03 AM , 1 ') ) BP EXPLORATION Operations Summary · Rep.ort Page 5 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/25/2002 20:00 - 00:00 4.00 DRILL P INT1 spare. - Drawing 3000 amps. - Slow to 120 rpm w/25K ft-Ibs torque. - Slow rig pumps to 880 gpm @ 3350 psig. - ROP averaging 45-75 fph wI total average ROP= 122.5 fph. 7/26/2002 00:00 - 05:00 5.00 DRILL P INT1 Drill ahead 12-1/4" Int hole from 14439' md to TD @ 14693' md. - Final Total ROP average 120.1 fph. 05:00 - 08:30 3.50 DRILL P INT1 Circulate Low-vis sweep. Follow with weighted sweep. - Sweeps didn't carry much excess. - Rotate and recip. while circulating. Rack 3 stands back - Circulate a total of 32000 strokes (Hole clean). 08:30 - 09:00 0.50 DRILL P INT1 Monitor well. Good. 09:00 - 11 :30 2.50 DRILL P INT1 POOH to 11780' md. (PU wt off-btm= 325 K Ibs/ SOW = 220 K Ibs). -30 k 'Tugs" at top of Kuparuk. - Decide to keep POOH- hole slick. 11 :30 - 12:00 0.50 DRILL P INT1 Monitor well. Pump dry job. Drop ESS @ 11780' md. 12:00 - 18:00 6.00 DRILL P INT1 POOH into 13-3/8" shoe 4030' md. - Slightly tight spots (30K Ibs overpull) @ 10900', 7240', and 4930' md. - Pump out from 4850' md to 4030' md. Slight amount of swabbing through SV sands. Had to work BHA up into 13.3/8" shoe. 18:00 - 19:30 1.50 DRILL P INT1 Circulate 2 bottoms up. - Quite a bit of excess material on intial bottoms up (smaller to medium size clay clumps and a small amount of Miluveach shale came back on initial bottoms up). - Continued circulating until clean @ 9000 strokes. - Monitor and pump dry job. 19:30 - 22:00 2.50 DRILL P INT1 POOH. - Lay down Porcupine reamer. Worn on leading edge. Missing 1 st row of leading edge cutter buttons. Rest of reamer in good condition. 22:00 - 00:00 2.00 DRILL P INT1 Lay Down BHA #3. . - Recover ESS. Good surveys @ 11517.32', 11424.40', & 10947.36' md. - Bit in good condition (Graded: 2-0-CT-C-X-I-WT-TD) 7/27/2002 00:00 - 01 :30 1.50 DRILL P INT1 LID BHA #3. 01 :30 - 02:00 0.50 DRILL P INT1 Clear and clean rig floor. 02:00 - 03:00 1.00 DRILL P INT1 PU STD and Johnny Wacker. Flush stack. Drain stack. Pull wear bushing. - Wear bushing was damage- no problem pulling. 03:00 - 04:00 1.00 CASE P INT1 PJSM. Change out top set rams to 9-5/8" for running casing. 04:00 - 06:00 2.00 CASE P INT1 PJSM. Slip and cut 102' drilling line. 06:00 - 07:00 1.00 CASE P INT1 PJSM. Test ram door seals to 3000 psig. 07:00 - 08:00 1.00 CASE P INT1 PJSM for RU for running casing. Review Franks tool, installing rails, Rigging up stabbing board, man-riding, and casing running procedures. 08:00 - 09:30 1.50 CASE P INT1 Rig up to run 9-5/8" casing. Printed: 1/20/2003 923:03 AM '. , ) ) BP EXPLORATION O,perationsSummary.Report Page 6 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From~ To Hours Task Code NPT Phase .. Description of Operations 7/27/2002 09:30 - 15:00 5.50 CASE P INT1 MU Float Equipment. Check floats. Run 97 jts of 9-5/8" 47# casing to 3980' md averaging 20 jts/hr. 15:00 - 16:00 1.00 CASE P INT1 Circulate casing volume @ shoe. 16:00 - 19:45 3.75 CASE P INT1 Run jts 97-#165 start On jt 160 (6627' 9-5/8" shoe depth) begin to get some seepage. Slow down rate from 22 jts/hr to 17 jts/h r. 19:45 - 22:30 2.75 CASE P INT1 Run jts #165-180 @ 17 jts/hr. Still seeping. No static losses. However not getting any returns. Run jts #180-187 @ 12 jts/hr. Same losses. Run jts #187-194 @ 7 jts/hr. Losses are less. Run jts #194-203 @ 10 jts/hr. Stop check backside FL- static. 22:30 - 00:00 1.50 CASE P INT1 Run jts #204-210 @ 5 jtsl hr. No change. Run jts #210-216 @ 10 jtsl hr. Start mixing more mud. Note: Total bbls lost from JT #160- 216 is 240 bbls. 7/28/2002 00:00 - 09:30 9.50 CASE P INT1 Run 9-5/8" 47# casing from JT# 216 - 355 wI losses averaging 4.2 bbls/Jt. Hole good. Had some problems getting though top of Kuparuk (slack off 100 klbs)- Typical of previous wells. 09:30 - 10:00 0.50 CASE P INT1 MU Hanger & Land 9-5/8" casing. Hole slick, land Hanger with 225 klbs downweight. 10:00 - 10:30 0.50 CASE P INT1 RD Frank's Fill up tool. RU crossover and Cement Head. RU cement line. 10:30 - 14:00 3.50 CASE N DPRB INT1 Try to Establish circulation - packed off. Attempt to reciprocate Pipe. Not able to move pipe up with 550 klbs and Hanger Catching in Ram Cavities. Surge pipe up to 1400 psi- no go. Make arrangements for Schlumberger to come out to shoot circ holes. 14:00 -18:00 4.00 CASE P INT1 With patience, able to establish circ @ 2 spm wI a finger of returns. - Slowly increased rate to 9 bpm on schedule to a final rate of 9 BPMI 900 psi. Circulate 1.3 bottoms up. No excessive cuttings at surface. PJSM for Cement Job. 18:00 - 23:00 5.00 CASE P INT1 Pumped Cement Job As Per Plan: - Pump 5 bbls and PT lines to 4000 psig. - Pump 50 bbls 11.3 ppg Alpha Spacer. - Drop bottom plug. - Mix and pump 458 bbls (794 sacks) of 11.2 ppg lead cement. - Follow w/116 bbls (564 sacks) of 15.9 ppg tail cement. - Drop top plug and flush wi 25 bbls of water. - Switch to rig pump #2 and begin displacement @ 9 bpm. Pump #2 not running smooth, switch to Pump #1 and continue displacement. - Have 2 bpm losses before cement around shoe. - At 5190 strokes (515 bbls) have good lift, 9 bpm 305 psig and losses quit. - Slow to 5 bpm and 1500 psgi @ 9900 strokes (Slight losses- 3 bbls) - At 10263 strokes slow pump to 3.4 bpm wi 1700 psig. Printed: 1/20/2003 9:23:03 AM 'I ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From - To Hours Task Code NPT 7/28/2002 18:00 - 23:00 5.00 CASE P INT1 23:00 - 23:30 0.50 CASE P INT1 23:30 - 00:00 0.50 CASE P INT1 7/29/2002 00:00 - 00:30 0.50 CEMT P INT1 00:30 - 01 :30 1.00 CEMT P INT1 01 :30 - 03:00 1.50 CEMT P INT1 03:00 - 07:30 4.50 CEMT P INT1 07:30 - 08:00 0.50 BOPSURP INT1 08:00 - 08:30 0.50 BOPSURP INT1 08:30 - 14:30 6.00 BOPSURP INT1 14:30 -15:00 0.50 BOPSUR P INT1 15:00 - 17:30 2.50 CEMT P INT1 17:30 - 18:30 1.00 CEMT P INT1 18:30 - 19:00 0.50 CEMT P INT1 19:00 - 00:00 5.00 CEMT P INT1 7/30/2002 00:00 - 03:30 03:30 - 04:30 3.50 CEMT P 1.00 CEMT P INT1 INT1 04:30 - 05:30 1.00 CEMT P INT1 05:30 - 07:00 1.50 CEMT P INT1 07:00 - 08:30 1.50 CEMT P INT1 08:30 - 11 :00 2.50 CEMT P INT1 11 :00 - 14:30 3.50 CEMT P INT1 14:30 -15:00 0.50 CEMT P INT1 15:00 - 23:30 8.50 DRILL P LNR1 Page 7 of 25 Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Description of Operations - Bump plug @ 10530 strokes, 94.3 % eff (1046 bbls HALCO meter) w/ 3.4 bpm @ 2100 psig. - Pressure to 2600 psig and monitor for 3 mins. Straight line @ 2500 psig. - Estimated total bbls lost on cement job 53 bbls mud. - Estimated 5 bbls Alpha spacer returned just before bumping plug. Bleed off and check floats. Rig down Cement head & landing joint. PJSM. Back Out and pull landing jt. Flush and drain BOPE stack. Install short bails and 5" DP elevators. Install 9-5/8" pack-off. Test to 5000 psig- good. PJSM's. Displace 9-5/8"x13-3/8" annulus wI 240 bbls of 10.2 mud at 1 bpm (Started injecting at 1700 psig. Other simultaneous operations being performe concurrently: - Swap 9-5/8" rams to variables - Clean L-Pit - Change Liners and swabs on mud pumps to 5-1/2". PJSM for setting Test Plug and BOPE test. Set Test plug. Rig up testing equipment and fill BOPE stack. Pressure Test BOP's for 5min (250 psig/4800 psig). PT annular 3500 psig. Pull test plug and install wear ring. MU BHA #4 (RSS, MWD, and 8.5" bit). Shallow test- good. PU 30 Jts of DP from pipeshed. RU to freeze protect 9-5/8" x 13-3/8" annulus. PJSM. Pump 1500 strokes of diesel @ 1.3 bpm. Pumped a total of 127 diesel FP. Continue RIH w/ BHA #4. Replace 1 Jt of DP- Scored. RIH wI BHA #4 w/ 5" DP. Wash down last stand to 14580' md. Circulate MW in = MW out = 10.1 ppg. Pressure test 9-5/8" casing to 4200 psig for 30 minutes on chart. 13 bbls pump/return. Review D5 Drill. Perform D-5 Drill. Drill out Float Collar and cement to 14662' md. Start bleed in for MW increase simultaneously. Condition Mud system to MW= 12.9 ppg. Drill Out shoe and 20' of new hole to 14713' md . Perform FIT to 850 psig wI 3.1 bbls. EMW= 14.6 ppg. Drlg ahead 8.5" hole from 14713' to 15172' md w/8.5" RSS. -Bit balling occured when started drilling ahead. -Assembly dropping @ 1.7 deg/ 100'. - Send command to build 40% of the time wI no response. Printed: 112012003 9:23:03 AM ) BP EXPLORATION Operations Summary Report Page 80f 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From - To Hours Task Code NPT Phase Description of Operations 7/30/2002 15:00 - 23:30 8.50 DRILL P LNR1 Command RSS to build 100% of the time w/ no response. - At present inclination will miss Drillers target by 100'. Confer with Anchorage Engineering and decide to POOH for new RSS assembly or possibly a motor, depending on RSS functioning at surface. Drilling Parameters: - Rap average 64 fph (78-95 fph range). - WOB 15 K - Pump Pressure 3550 w/ 550 gpm flow. -Inclination 34.75 deg / Azimuth 308.89 deg @ 15114' md. - Torque 24 K ft-Ibs w/150 rpm. - ECD running 14.0 ppg to 14.4 ppg EMW. 23:30 - 00:00 0.50 DRILL N DPRB LNR1 CBU w/ reciprocating and rotating 100 rpm. 7/31/2002 00:00 - 01 :00 1.00 DRILL N DPRB LNR1 Continue CBU. Returns cleaning up - lots of excess for the footage drilled. Pump total of 10000 strokes. Monitor well. 01 :00 - 01 :30 0.50 DRILL N DPRB LNR1 Trip out of hole to 9-5/8" shoe. - PUW 295 K Ibs / SOW 225 K Ibs. 01 :30 - 02:00 0.50 DRILL N DPRB LNR1 Monitor well. Pump dry job. Blow down Top Drive. 02:00 - 07:30 5.50 DRILL N DPRB LNR1 POOH to BHA #4. 07:30 - 08:00 0.50 DRILL N DPRB LNR1 Stand back Jars and Drill collars. 08:00 - 09:00 1.00 DRILL N DPRB LNR1 PJSM. Inspect Bit & Test Power Drive. Find PD Bias unit failure. 09:00 - 11 :00 2.00 DRILL N DPRB LNR1 PU BHA #5 (Same string wI different MWD and PD unit). 11 :00 - 12:00 1.00 DRILL N DPRB LNR1 Test Power Drive Unit. Download CDR. 12:00 - 12:30 0.50 DRILL N DPRB LNR1 PU BHA #5. 12:30 - 18:30 6.00 DRILL N DPRB LNR1 RIH wI BHA#5 on 5" DP to 14600' md. 18:30 - 20:00 1.50 DRILL N DPRB LNR1 PJSM. Slip and cut 102' drilling line. Service Top Drive and drawworks. 20:00 - 21 :00 1.00 DRILL N DPRB LNR1 RIH wI BHA #5 into open hole. Wash down last stand. Hole in good condition. - PUW is 310 K, SOW is 210 K, and ROW is 236 K Ibs. - Rotary torque 12 K ft-Ibs. Much improvement from yesterday. 21 :00 - 22:00 1.00 DRILL N RREP LNR1 Not getting good MWD signal frames. On further investigation Pump #2 pulsation dampner has lost integrity- prepare to change out. 22:00 - 22:30 0.50 DRILL N RREP LNR1 POH to 9-5/8" shoe. 22:30 - 00:00 1.50 DRILL N RREP LNR1 Replace Pump #2 pulsation dampner. - Continue circulating wI pump #1 for mud conditioning. 8/1/2002 00:00 - 09:30 9.50 DRILL N RREP LNR1 Continue circulation @ shoe -- Replace #2 MP Dampner. 09:30 - 10:00 0.50 DRILL P LNR1 RIH wI BHA #5. Wash from 15076' md to 15172'. 10:00 - 00:00 14.00 DRILL P LNR1 Drill ahead 8.5" from 15283'-16407' md into Kingak. TOP Kingak field pick 15276' mdl 9745 tvd. - Pump nut-plug sweep and unball bit. - Vary WOB for optimum ROP to get a handle on ECD. - Highest ECD spike to 14.9 ppg. Mud Engineer adding water Printed: 1/20/2003 9:23:03 AM ) ) BP EXPLORATION Operations Summary Report Page 9 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E From;;, To Hours Task Code NPT Phase 8/1/2002 10:00 - 00:00 14.00 DRILL P LNR1 8/2/2002 00:00 - 02:00 2.00 DRILL P LNR1 02:00 - 03:00 1.00 DRILL P LNR1 03:00 - 07:00 4.00 DRILL N DPRB LNR1 07:00 - 10:00 3.00 DRILL P LNR1 10:00 - 10:30 0.50 DRILL N WAIT LNR1 10:30 - 11 :00 11 :00 - 14:00 0.50 DRILL P 3.00 DRILL C LNR1 LNR1 14:00 - 14:30 14:30 - 16:00 0.50 DRILL P 1.50 DRILL P LNR1 LNR1 Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Description of Operations lower MW to target 12.8 ppg. -Varied ROP from 100 to 170 fph wi increase in WOB to 25K Ibs max. ROP= 100 fph I ECD= 14.34 ppg ROP= 120 fph I ECD= 14.34 ppg ROP= 150 fph I ECD= 14.40 ppg ROP= 170 fphl ECD= 14.40 ppg wi spike to 14.7 ppg. Attempt to keep ROP < 150 fph for ECD hardline. Drilling parameters: Total Flow= 552 gpm wi Pump P= 3450 psig. WOB= 17K Ibsl 150 rpm wi 23K ft-Ibs torque. Drill ahead 8.5" hole wi RSS from 16407' md to 16550' md into Top Sag. - Top Sag River @ 16503' md I 10795' TVD. - ROP running 140 fph to 45 fph, still targeting 14.4 ppg ECD wI 12.8 MW Drilling parameters @ TO in Sag River: - 540 gpm wi 3400 psig - 25 K ft-Ibs Torque @ 150 rpm (Higher torque) and 21 K-Ibs Torq off. - 15-20 K Ibs WOB wi ROP 50 fph - PUW= 315, SOW= 220, ROW= 252 K Ibs. - Final Inclination 22.7 degrees. Circulate Hi Vis Sweep. (Lost Circulation @ 7600 strokes - ECD no higher than 14.0 ppg). Continue circulation @ 3 bpm while filling and monitoring (4 bpm losses) stringing in barafibre while getting LCM pill ready to go. No returns with static losses at 75 bph while mixing LCM pill. Mix and pump 80 bbls LCM pill containing at 4 bpm. 25 ppb BARA-Seal M 25 ppb Walnut - M 25 ppb BARO fiber. Note: Anadrill recommed 50 ppb LCM material max through TS. While chasing pill, got partial returns @ 950 strokes. Spot pill and clear bit by 200 strokes over for safety margin. Finished circulation with 75% returns (75 bph losses). Shut down and monitor, well FL is static. Total Mud loss to well: 640 bbls. Monitor well. Trip from 16550' md to 15076' md slowly to prevent swabbing. -PUW= 325 K, SOW= 230 K Ibs. - Max drag was 50k wi average drag of 15K Ibs over. Hole in good condition. No losses on trip. Secure well and muster crew. OPS fire alarm. Wood fire put out. Resume rig operations. Continue trip to 9-5/8" shoe. No losses. Establish circulation @ 9-5/8" shoe. Recover LCM material in annulus. Work circulation rate up to 10.5 bpm. No losses. Monitor well- no static losses. Drop 2.5" rabbit. Pump slug. POH fl running 7" casing. Printed: 1/20/2003 9:23:03 AM ') ) BP EXPLORATION Operations Summary Report Page·10 of25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From - To Hours· . Task Code NPT Phase Descri ptionof Operations 8/2/2002 16:00 - 17:00 1.00 DRILL N WAIT LNR1 Operations lost hi-line power. Switch to rig power 17:00 - 21 :00 4.00 DRILL P LNR1 Continue trip out of hole. 21 :00 - 23:00 2.00 DRILL P LNR1 Flush BHA#5 w/ water. Lay down BHA#5. 8.5" bit graded: 3-0-CT-C-X-I-BF-TD 23:00 - 00:00 1.00 CASE P LNR1 Clear and clean rig floor. RU to run 7" 26 ppf CS-Hydrilliner. 8/3/2002 00:00 - 01 :00 1.00 CASE P LNR1 Continue RU for running 7" 26# L-80 Hydril-521 liner. 01 :00 - 05:00 4.00 CASE P LNR1 PJSM for running liner. MU Float equipment and Bakerlock connections. Fill and check floats- good. Run 51 JTs 7" 26# L-80 Hysril-521 liner. MU torque average of 12 K ft-Ibs. 05:00 - 06:30 1.50 CASE P LNR1 MU Baker 'ZXP' liner top packer and Flex Lock II hanger assembly. Circulate liner volume. PUW= 117 K Ibs & SOW= 115 K Ibs. 06:30 - 17:00 10.50 CASE P LNR1 RIH wI 7" liner on 5" DP to 9-5/8" shoe filling DP every row. 17:00 - 18:00 1.00 CASE P LNR1 Circulate pipe and liner volume. PUW @ shoe= 280K Ibs / SOW 207K ROW 240K @ 15 rpm w/ 11 K ft-Ibs torque 18:00 - 20:30 2.50 CASE P LNR1 Run into 8.5" open hole. - At 15895' have a little drag starting 15-20K. - At 16348' Tight spot 80 K Ibs. Still running in good however. - At 16509' md taking wt. No displacement. Decide to wash down. 20:30 - 21 :30 1.00 CASE P LNR1 Establish circulation and wash down from 16509' md to 16545' md (5' off bottom). - Work rate up slowly to 35 spm @ 757 psig. 21 :30 - 22:00 0.50 CASE P LNR1 Make up cement head. 22:00 - 22:30 0.50 CASE P LNR1 Establish circulation w/ cement head.. -Work rate up to 5 bpm @ 730 psig. PUW= 270K/ SOW= 215 K-Ibs. - Returns full during entire circulation PJSM for cement job. 22:30 - 00:00 1.50 CEMT P LNR1 Pump cement job as per plan: - Pump 5 bbls of 13 ppg Alpha Spacer - Pressure test lines to 4500 psig. - Pump 30 bbls more Spacer 4 bpm- some trouble with electrical. - Pump 86 bbls (325 sacks) of 15.9 ppg tail slurry @ 5 bpm - Drop wiper plug and chase wI 5 bbls sea water - Switch to rig pump for mud displacement @ 5 bpm after catching cement. 8/4/2002 00:00 - 01 :00 1.00 CEMT P LNR1 Continue cement displacement wI mud. Slow rate to 3 bpm (37 stokes @ 480 psig) before latch. Latch @ 2854 strokes (99 % efficiency). Increase rate to 56 spm. Good lift- 4.75 bpm w/ 1100 psig. Bump plug to 3450 psig. Slack off 100 K on hanger. Increase Pressure up to 4500 psig. Bleed off - check floats- good. Pick up to check wt loss (94000 Ibs) @ 226 K. PU 7' to release packer setting dogs. Slack off DP wt to 120 K- Ibs and see liner top packer shear @ 140 K-Ibs. PU to 7' mark and repeat. Printed: 1/20/2003 9:23:03 AM ) ) BP EXPLORATION Operations Summary RepQI1 Page 110f 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From -To Hours Task Code NPT Phase Descriþtiön of Operations 8/4/2002 00:00 - 01 :00 1.00 CEMT P LNR1 PU to 7' and rotate wi 70k Ibs down on pkr (10 rpm wi 9-11 k ft-Ibs torque). Pressure up to 500 psig and pull 17' to release pressure and CBU @ 115 spm to circ out excess cmt. 01 :00 - 03:00 2.00 CEMT P LNR1 Circulate out Alpha space and approximately 30 bbls cement (50% cut on 60 bbls) 03:00 - 04:45 1.75 CEMT P LNR1 Lay down cement head and 2-singles of 5" DP. G & I injecting to make room for Sea water displacement. 04:45 - 06:00 1.25 CEMT P LNR1 RU and test liner top to 1500 psig for 30 min. G & I still injecting to make room for displacement. 06:00 - 09:45 3.75 TA P SURE PJSM for Sea Water Displacement. - Pump 25 bbls high vis spacer - Pump 100 bbls sea water - Pump 50 bbls high vis spacer - Pump 1230 bbls total @ 10 bpm Final NTU= 350. 09:45 -10:15 0.50 TA P SURE Monitor well for 30 mins. PJSM for Slip and Cut drilling line. 10:15 -11 :30 1.25 TA P SURE Slip and cut drilling line. 11 :30 - 12:00 0.50 TA P SURE RU floor for laying down DP. 12:00 - 16:00 4.00 TA P SURE Lay down 105 jts of 5" DP 16:00 -16:30 0.50 TA P SURE Service Top Drive and Drawworks. 16:30 - 22:00 5.50 TA P SURE Lay down 202 jts of 5" DP. Total LD was 307 jts. 22:00 - 23:30 1.50 T A P SURE POOH. 23:30 - 00:00 0.50 TA P SURE Make service breaks on Baker HRD running tool. Tool clean. 8/5/2002 00:00 - 00:45 0.75 TA P SURE Lay down Baker Running Tool. Manifest and stage for barge to WestDock. 00:45 - 02:15 1.50 T A P SURE Test casing to 4800 psig wi Halliburton pump and chart for 15 mins. Good Test. 18.5 bbls of SW to PU. Blow down mud lines 02:15 - 02:45 0.50 TA P SURE Break and LD the cement head. G & I Flushing well for Caliper log in a.m. Cleaning pits. 02:45 - 03: 15 0.50 TA P SURE Clear and clean floor. Prep floor for PU HWDP. 03:15 - 08:00 4.75 TA P SURE PU 24 Jts HWDP and 114 JTs of 5" DP. 08:00 - 09:00 1.00 TA C SURE Morning barge is blocking access for more DP and SWS needing to respot for NS10 Caliper log. 09:00 - 10:30 1.50 TA N RREP SURE Iron roughneck repair. 10:30 - 14:00 3.50 TA P SURE PU singles of 5" DP for total of 212 jts. 14:00 - 15:00 1.00 TA P SURE Service top drive, drawworks, and crown. 15:00 - 17:00 2.00 TA P SURE POOH and rack back rental pipe to 3000' md. 17:00 - 17:30 0.50 TA P SURE PJSM for Diesel FP. 17:30 - 21 :30 4.00 TA P SURE Reverse circulate 125 bbls of diesel from Tank Farm. Strap SW returns to G & I. 21 :30 - 23:30 2.00 TA P SURE U-tube diesel. Replace swivel packing on Top Drive. 23:30 - 00:00 0.50 TA P SURE POOH wI DP. 8/6/2002 00:00 - 01 :30 1.50 TA P SURE Continue to POOH with drill pipe. 01 :30 - 02:30 1.00 TA P SURE Clear lines and mud pump of diesel and fill hole with seawater. 02:30 - 04:45 2.25 T A P SURE Pull wear ring and land tubing hanger with TWC in place on stand of HWDP. Pressure test seals to 5000 psi. Hold ok. 04:45 - 06:00 1.25 T A P SURE Pressure test casing, tubing hanger and TWC to 4200 PSI. Hold ok. Bleed off annulus to bleed trailer. 06:00 - 07:15 1.25 TA P SURE Clean up in cellar and around wellhead. Printed: 1/20/2003 9:23:03 AM ), ) BP EXPLORATION Operati:ons·Summa.ryReport Page 12 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From- To· Hours Task Code NPT Phase Description of Operations 8/6/2002 07:15 - 12:30 5.25 TA P SURE PJSM. Pull riser and nipple down BOP's. Stand back in craddle. 12:30 - 16:00 3.50 TA P SURE PJSM. Install tree, fill with diesel and test to 5000 psi. Held ok. 16:00 - 17:00 1.00 TA P SURE Cean up rig and prepare to move to NS24. Release rig at 1700 hrs. 08/06/2002. 12/27/2002 07:00 - 07:30 0.50 MOB P PRE 0-8 muster drill on rig while remaining personnel on Island muster drill & load up on ARKTOS. 07:30 - 09:00 1.50 MOB P PRE Prepare rig for move. 09:00 - 12:00 3.00 MOB P PRE PJSM - Skid rig. 12:00 - 14:30 2.50 MOB P PRE Safety stand down wI both crews. and Crew Change- Late flights because of fog. Rig Move suspended after 30 ft to ensure no miscommunication during the crew change and standdown. 14:30 - 16:30 2.00 MOB P PRE Continue skidding rig from NS-24 to NS-18. 16:30 -17:00 0.50 MOB N HMAN PRE Shut down & disconnect sea water & fresh water hoses from pipe rack. Hoses -5' too short to reach NS-18 from current drops. 17:00 - 17:30 0.50 MOB P PRE Continue skidding rig to NS-18. 17:30 - 18:00 0.50 MOB P PRE Level rig & center over hole. 18:00 - 18:45 0.75 MOB P PRE Send all personnel to dinner. 18:45 - 21 :00 2.25 RIGU P PRE PJSM - Install drilling sweep on upper annulus. 21 :00 - 22:00 1.00 RIGU P PRE PJSM - Remove tree & put into tree stand. 22:00 - 00:00 2.00 RIGU P PRE PJSM - N/U BOP's & hook up Koomey lines. Accepted rig on NS-18 @ 1800 hrs. 12/28/2002 00:00 - 03:30 3.50 BOPSUR P PRE N/U BOP's & risers. Install mouse hole. 03:30 - 04:30 1.00 RIGU P PRE Install iron roughneck tracks, mats, cIa to 5" on iron roughneck, check for pressure on annulus & BIO lock down screws. Pull tubing hangar & LID. 04:30 - 05:30 1.00 BOPSURP LNR1 R/U to test BOP's - Install test plug & fill stack. 05:30 - 06:00 0.50 BOPSUR N RREP LNR1 Repair leak on riser & choke line. 06:00 - 10:30 4.50 BOPSUR P LNR1 Test BOP's to 250 14800 psi for 5 I 5. Test annular preventer to 3500 psi. 10:30 - 11 :00 0.50 CASE P LNR1 Pull test plug, install bowl protector, BID lines & line up manifolds. 11 :00 - 12:00 1.00 CASE P LNR1 cIa saver sub. 12:00 - 12:30 0.50 CASE P LNR1 Clear floor of tools. 12:30 - 14:00 1.50 CASE P LNR1 PJSM for circulating out F/P. RIH open ended to 2075'. 14:00 - 14:30 0.50 CASE P LNR1 PJSM - M/U head pin 14:30 - 15:30 1.00 CASE P LNR1 Line up to sea water & G & I & test line to 110 psi. 15:30 - 17:15 1.75 CASE P LNR1 Close annular & displace diesel @ 2 BPM through choke. 17:15 - 18:00 0.75 CASE P LNR1 RID & BID - monitor well. 18:00 - 18:45 0.75 CASE P LNR1 POH 18:45 -19:15 0.50 CASE P LNR1 PJSM for casing test. 19:15 - 20:30 1.25 CASE P LNR1 Fill hole & cement line. Test 7" X 9 5/8" casing to 4450 psi wI Halliburton pump & hold for 30 min. 18 bbls Pumped/returned 20:30 - 20:45 0.25 CASE P LNR1 BID lines. 20:45 - 22:30 1.75 CASE N RREP LNR1 PJSM - cIa nuts on stand pipe clamps. 22:30 - 23:30 1.00 CASE P LNR1 PJSM - M/U BHA # 6. 23:30 - 00:00 0.50 CASE N RREP LNR1 Replace fittings on hydraulic lines for EZ-torque & rotary table Printed: 1/20/2003 9:23:03 AM ~) ') BPEXPLORATION Operations Summary Report Page 13 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From -'To Hours Task Code ·NPT Phase Description of Operations 12/28/2002 23:30 - 00:00 0.50 CASE N RREP LNR1 at Driller's console. 12/29/2002 00:00 - 03:00 3.00 CASE P LNR1 P/U BHA, Change bend in motor, orient, & load ADN tools wI source. ( PJSM ) 03:00 - 04:00 1.00 CASE P LNR1 P/U 6 jts 4" HWDP & 12 jts. 4" HT-40 DP from pipeshed & RIH. 04:00 - 04:30 0.50 CASE P LNR1 Shallow test MWD - BID TD & lines. 04:30 - 11 :00 6.50 CASE P LNR1 Strap 5" & RIH to 14457' filling pipe every 30 stds. 11 :00 - 12:30 1.50 CASE P LNR1 PJSM - Fill drill pipe wI 100 bbls. hi-vis sea water spacer @ top of liner to ensure good displacement of 12.8 ppg left inside liner. 12:30 - 13:30 1.00 CASE P LNR1 Continue RIH from 14457' to 16135'. 13:30 -14:30 1.00 CASE P LNR1 Wash down from 16135' to top of landing collar @ 16455'. Taking some weight from 16,135'. 14:30 - 16:00 1.50 CEMT P LNR1 Drill on landing collar from 16455' to 16462'. Unable to rotate due to high tq. 16:00 - 16:30 0.50 CEMT P LNR1 Complete displacement of sea water & old mud wI stored BARADRIL-N mud. 16:30 - 16:45 0.25 CEMT P LNR1 BID lines & monitor well. 16:45 - 17:30 0.75 CASE P LNR1 POH wI 10 stds. to 15600' for MAD pass. 17:30 - 20:00 2.50 EVAL P LNR1 MAD pass from 15605' to 15700' while lubing up the mud. 20:00 - 20:30 0.50 CEMT P LNR1 RIH from 15700' to 16462'. 20:30 - 00:00 3.50 CEMT P LNR1 Drill shoe track from 16462' to 16490'. Could not rotate for first hr due to high torque. (17.5K) Added another 4 drums EP mud lube. 3% lubricants in mud - 2% EP mud lube - 1 % Torque Trim. Ditch magnets look good wI no casing metal. 12/30/2002 00:00 - 04:00 4.00 CEMT P LNR1 Drill shoe track & FIS. Difficulty rotating drill string until additional lubricants were added. 04:00 - 04:30 0.50 DRILL P LNR1 Drill 20' of new hole from 16550' to 16570'. 04:30 - 05:00 0.50 DRILL N RREP LNR1 Thaw out frozen kill line. 05:00 - 06:00 1.00 DRILL P LNR1 Perform FIT to 11.5 EMW wI 9.2 ppg mud. Pressured up to 1300 psi wI 5.1 bbls. Final pressure after holding 10 min. was 1260 psi. 06:00 - 21 :00 15.00 DRILL P PROD1 Drill from 16570' to TO @ 16865' md in 6 1/8" hole wI 4 3/4" motor wI 1.15 deg bent housing. No drag, no losses P/U 300K S/O 240 K ROT 270K Final survey @ TO Incl 20.30, Az 306.29 21 :00 - 23:30 2.50 DRILL P PROD1 Pump 75 bbl Baracarb I Barofibre hi-vis sweep & circulate B/U X 1.5. Sweep did not bring back any additional cuttings. Hole appears to be clean. 23:30 - 00:00 0.50 DRILL P PROD1 Monitor well - UD single & POH inside 7" shoe. Hole in good shape wI no drag, no swab, no losses. 12/31/2002 00:00 - 00:30 0.50 DRILL P PROD1 POH inside shoe & monitor well. OK 00:30 - 01 :30 1.00 DRILL N DPRB PROD1 Drop ball to open PBL & pump down wI 8 BPM. Slowed pumps down to 3 BPM before latching. PBL did not open. Printed: 1/20/2003 9:23:03 AM :) ) BP EXPLORATION Operations Summa.ryRéport Page 14of25 Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From - To Hours Task Code NPT Phase Description of Operätions 12/31/2002 00:30 - 01 :30 1.00 DRill N DPRB PROD1 PJSM - Service top drive. 01 :30 - 02:00 0.50 DRill N DPRB PROD1 Drop ball to close PBl to ensure PBl closed. Pump @ 5 BPM wI 650 psi. Realized PBl was open once pump was started. Lesson learned: Shut down pump & restart pump after opening ball has seated. 02:00 - 02:30 0.50 DRill P PROD1 Monitor well - well static wI no losses. 02:30 - 03:00 0.50 DRill P PROD1 Pump dry job - BID. PJSM - drop rabbit. 03:00 - 10:30 7.50 DRilL P PROD1 POH to 4" & C/O to 4" handling equip't - monitor well. 10:30 - 11 :00 0.50 DRill P PROD1 R/U to & flush BHA wI sea water. BID. 11 :00 - 14:30 3.50 DRill P PROD1 LID 4" HWDP & handle BHA. 14:30 - 15:00 0.50 DRill P PROD1 Clear floor of tools. 15:00 - 16:00 1.00 EVAl P PROD1 PJSM - R/U Schlumberger to run RFT's. 16:00 - 00:00 8.00 EVAl P PROD1 Run RFT's. Was able to get samples at the first 7 out of 20 points, but unable to get below 16786'. Atempted several times- no go. Abort 1/1/2003 00:00 - 03:00 3.00 EVAl P PROD1 POOH with RFT on wireline. Note: Collected -10 gallons of saponified calcium carbonate off wireline cable and RFT tool. 03:00 - 03:30 0.50 EVAl P PROD1 PJSM -- RD Wireliners. 03:30 - 05:30 2.00 CASE P PROD1 PJSM -- RU and Run 4-1/2" Chrome Liner. 05:30 - 07:30 2.00 CASE P PROD1 MU Joint 1 to FS, FC and LC -- Bakerlock. 07:30 - 09:30 2.00 CASE N SFAl PROD1 Dropped bushing locking pin into the hole -- found in drip pan. Notes: 1) Blind rams were still closed from RU to run liner. 2) Pumped out stack to blind rams and checked for pin. 3) Found locking pin on ledge of drip pan. 09:30 - 10:00 0.50 CASE P PROD1 RU and pump thru FE -- Blowdonw mud line. 10:00 - 12:00 2.00 CASE P PROD1 Ran 11 joints of 4-1/2" 12.6# 13CR80 Vam Ace liner. 12:00 - 12:30 0.50 CASE P PROD1 Change out bales. 12:30 - 14:15 1.75 CASE P PROD1 PJSM -- Rig Up and Run 14 joints + 10' pup 2-7/8" 7.9# l80 Fox inner string. 14:15 - 14:45 0.50 CASE P PROD1 Fill 2 7/8" X 4 1/2" annulus wI 10.0 ppg viscosified brine. 14:45 - 15:30 0.75 CASE P PROD1 M/U 7" X 4 1/2" Liner hangar I ZXP packer. 15:30 - 16:00 0.50 CASE P PROD1 Mix & pour pall fluid inside tie back sleeve. 16:00 - 16:30 0.50 CASE P PROD1 C/O to 4" handling equip't & RIH wI 1 std. Notes: Circulate 1 pipe volume. P/U & S/O wts. 160K 16:30 - 18:00 1.50 CASE P PROD1 RIH wI liner wI 4" DP. 18:00 - 00:00 6.00 CASE P PROD1 C/O to 5" handling equip't & RIH to 11,247' filling every 10 stds. No losses. 1/2/2003 00:00 - 05:30 5.50 CASE P PROD1 RIH w/4 1/2" liner from 11247' to 7" shoe @ 14471' P/U & M/U cement head - torque up & stand back in derrick. 05:30 - 07:30 2.00 CASE P PROD1 Stage up pumps & circulate string volume @ shoe. Rate ICP FCP CUM. STKS. 114 - 1 BPM 1360 360 229 2 BPM 550 430 534 3 BPM 570 490 995 Printed: 1/20/2003 9:23:03 AM ') ') BP EXPLORATION Operations Sultnnary Report Page 15 of25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date . From -To Hours Task Code NPT Phase Description of Operations 1/2/2003 05:30 - 07:30 2.00 CASE P PROD1 4BPM 660 660 1893 5 BPM 760 730 2390 6BPM 1080 1040 3700 P/U wt 335K - S/O 230K after circulating. 07:30 - 09:00 1.50 CASE P PROD1 WID liner through OH wI 2.5 - 3 BPM. 580 - 710 psi. S/O wt consistently 230K - 235K. Install cement head & hose No problems getting to bottom. 09:00 - 11 :00 2.00 CASE P PROD1 Stage up pumps from 3 BPM - 6 BPM & circulate B/U. PJSM for cement job. 11 :00 - 12:45 1.75 CEMT P PROD1 Pump 5 bbls. 10.3 ppg Alpha Spacer & test HOWCO cement lines to 4500 psi. Pump remaining 20 bbls. of Alpha Spacer followed by 25 bbls. 15.9 premium class G cement. Clear cement line. Drop dart & displace cement wI 5 bbls. viscosified brine followed by old mud @ 6 BPM. Bump plug wI 96.8 PE & 3200 psi. Bleed off pressure & check floats - OK 12:45 - 13:15 0.50 CEMT P PROD1 Set liner hangar & ZXP. 13:15 -15:00 1.75 CEMT P PROD1 Circulate cement out @ 12 BPM. 15:00 - 15:30 0.50 CEMT P PROD1 PJSM - LID cement head & 1 single. 15:30 - 16:30 1.00 CEMT P PROD1 PJSM - Test 4 1/2" liner to 1575 psi & hold for 30 min. 16:30 - 18:00 1.50 CEMT N HMAN PROD1 Condition mud & circulate. 18:00 - 00:00 6.00 CEMT N HMAN PROD1 Plugged off G & I conical & vibrating ball miils wI saponified calcium carbonate. Disaasembled vibating mill & emptied contents. Replace discharge grate & reassemble. Conical mill being emptied of product & will require reloading of steel balls. Cleaning process pit # 2. Rig activity: Service top drive. Thaw cement stand pipe. Install washers on mud line stand pipe clamps. 1/3/2003 00:00 - 22:30 22.50 CEMT N HMAN PROD1 Clean saponified CaC03 out of both G&I ball mill trains: - Includes vibrating mill, conical mill, both process pits, injection pit 1. - Treated saponified CaC03 with surfactants to allow for diposal into NS10. - Injected CaC03 weighted production drilling fluid in surface pits down NS10. Refilled pits with visosified sea water. Notes - Rig Activitoies performed in parallel with G&I clean-up. 1. PJSM - Cut & slip drilling line 2. PJSM - Perform top drive inspection. 3. PJSM - Remove VLE winch & replace. 4. C/O bolts on kelly hose safety clamp @ stand pipe. Printed: 1/20/2003 9:23:03 AM ') ) BP EXPLORATION OperationsS~mmary Report Page 16 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date FrOm ~ To . Hours Task Code NPT Phase Description of Operations 1/3/2003 00:00 - 22:30 22.50 CEMT N HMAN PROD1 Help out @ G & I. No losses I no gains while circulating across top of hole. 22:30 - 00:00 1.50 CEMT N HMAN PROD1 Displace drilling mud wI 9.0 ppg viscosified brine @ 15 BPM. 1/4/2003 00:00 - 00:30 0.50 CASE N HMAN PROD1 Continue displacing 9.0 ppg viscosified brine @ max rate 15.5 BPM. All returns going to G & I via drag chain. 15.5 BPM is max rate drag chain will handle. 1 3/4" BU 00:30 - 03:00 2.50 CEMT P PROD1 Allow G & I time to inject fluids for next displacement. All pits full @ G & I. Injecting @ max. rate 7 BPM & receiving @ 15.5 BPM. No abnormal injection pressures while pumping calcium carbonate down NS-10 injection well or during subsequent sea water chases. 03:00 - 05:00 2.00 CEMT P PROD1 Pump 70 bbl hi-vis 11.5 ppg sweep @ 14 - 14.5 BPM. Surface to surface. Hole cleaning up well. 05:00 - 10:00 5.00 CEMT P PROD1 30 min negative test on liner - No losses, no gains. Test 4 1/2" x 7" liner to 4200 psi & hold for 30 min. G & I injecting fluids, cleaning 600 bbl pit & re-filling for next displacement. 10:00 - 11 :00 1.00 CEMT P PROD1 PJSM - Mix 50 bbl Barascrub, 50 bbl Dirt Magnet, & 50 bbl hi - vis casing wash spacers in rig pits & G & I. 11:00 -13:45 2.75 CEMT P PROD1 Pump spacers followed by clean sea water. Pump 1 114 X surface to surface. Hole cleaned up to 36 NTU's. 13:45 - 14:00 0.25 CEMT P PROD1 Monitor well - BID lines. 14:00 - 20:30 6.50 CEMT P PROD1 PJSM - POH wI 5" DP. Notes: 1. Some calcium carbonate sludge residue on DP tool jts. 20:30 - 21:15 0.75 CEMT P PROD1 PJSM - C/O to 4" tools & POH wI 4" DP. 21:15 - 22:30 1.25 CEMT P PROD1 PJSM - Make service breaks & LID liner running tool. 22:30 - 23:30 1.00 CEMT P PROD1 PJSM - R/U for handling 2 7/8". 23:30 - 00:00 0.50 CEMT P PROD1 POH wI 2 7/8" & LID. 1/5/2003 00:00 - 01 :00 1.00 CEMT P PROD1 LD 2-7/8" inner string. 01 :00 - 01 :30 0.50 CEMT P PROD1 RD 2-7/8" equipment and make service breaks on Baker TO cement head. 01 :30 - 02:00 0.50 CASE N RREP PROD1 Clear Floor and pull rotary table and remove locking devices. Note: Action item from dropped object on 1/1/03 when rotary pin fell downhole and was recovered in drip pan. 02:00 - 03:00 1.00 CASE N HMAN PROD1 PJSM -- RU E-line Unit to make tag for fill. Note: Slick line runs to check for fill and clean out runs had successfully been eliminated on past wells; however, this well experienced hole cleaning problems when the EP Mud Lube wetted the CaC03 causing a adverse reaction in which the precipitate formed a sludge to coat wellbore and caused CaC03 clumps to fall out on low side of hole which may have resulted in fill. This fill could prevent the perforation guns from reaching TO resulting in either lost production or numerous hydrostatic bailer run with slickline. 03:00 - 06:30 3.50 CASE N HMAN PROD1 Tag up at 16793' md driller depth with Gauge Ring/GRlCCL. Repeat tag. 26 feet of fill above bottom perf planned @ 16819' md driller depth. POOH with Eline. Notes: Printed: 1/20/2003 9:23:03 AM ') ") BP EXPLORATION pperations .Summary Report Page 17 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From - To Hours Task Code NPT Phase Descti ptionofOperations 1/5/2003 03:00 - 06:30 3.50 CASE N HMAN PROD1 1. PBTD to top of Wiper Plug is @ 16858' md. 2. Bottom perf depth is 16822' md ELM: This correlates to 16819' md driller depth. 3. Total fill above bottom perf: 16819' md minus 16793' md equals 26 feet. 4. Total fill above PBTD of wiper plug on landing collar: 16858' md minus 16793' md equals 65 feet. 5. 65 feet of fill equates to 1 bbl of material in 4-1/2" liner. 06:30 - 07:30 1.00 CASE N HMAN PROD1 RD E-Line Unit. Note: No evidence of CaC03 sludge on cable or tools as witnessed on the RFT run on 1/1/03. 07:30 - 09:00 1.50 CASE N HMAN PROD1 Finish Loading 2-3/8" dp and gathering bha components to rig floor. 09:00 - 10:30 1.50 CASE N HMAN PROD1 Decision to reverse fill out of hole with mule shoe versus cleaning out fill while circulating conventionally with motor and mill -- based on challenge by Tour Pusher Jim Wood. Fabricate 2-3/8" mule shoe. 10:30 - 12:00 1.50 CASE N HMAN PROD1 PJSM -- MU BHA#7 (16 jts 2-3/8" HT SLH90) and xo to 7" scraper. 12:00 - 14:00 2.00 CASE N HMAN PROD1 PJSM -- Switch over to 4" handling equip and RIH with 20 stands of 4" dp and xo to 9-5/8" casing scraper. 14:00 - 17:45 3.75 CASE N HMAN PROD1 PJSM -- Switch over to 5" handling equip and RIH to just top of 7" liner @ 14389'. 17:45 - 18:45 1.00 CASE N HMAN PROD1 Rev Circ 1.25 x DP volume and blow down lines. Note: 6 bpm @ 890 psi and increase rate to 9 bpm @ 1660 psi. Very Slight trace of CaC03 on shakers at bottoms up. B 18:45 - 20:00 1.25 CASE N HMAN PROD1 RIH to 16284' md to just above top of 4-1/2" liner @ 16284' md. 20:00 - 20:45 0.75 CASE N HMAN PROD1 Rev Circ 1.25 x DP volume and blow down lines. Note: 9 bpm @ 2250 psi. Very slight trace of CaC03 on shakers at bottoms up. 20:45 - 21 :15 0.50 CASE N HMAN PROD1 RIH to 16772' md. 21:15 - 22:00 0.75 CASE N HMAN PROD1 Rev Circ while washing down f/ 16772' to PBTD @ 16857' md. 22:00 - 00:00 2.00 CASE N HMAN PROD1 Rev Circ while pumping two 65 bbl Hi-Vis Sweeps weighted to 10 ppg with NaCI. Notes: - Established circ with 6.5 bpm and 1712 psi. Slacked off and washed down to estimated top of fill at 16792'. - Circuated while pressure dropped to 1670 psi. Washed down thru fill to PBTD on top of wiper plug at 16857' md with constant pressure of 1670 psi. - PU 4' and increased rate to 9 bpm with 3300 psi. - Pressure increased to 3800 psi when sweeps entered drill pipe. Shut down pumps, closed upper pipe rams, open bag and resumed reverse circulating sweeps to surface. 1/6/2003 00:00 - 01 :00 1.00 CASE N HMAN PROD1 Continue reverse circulating 10.0 ppg hi-vis sweeps. Notes: Sweeps did not bring back any additional material. - 1 cup. Hole clean of fill. Printed: 1/20/2003 9:23:03 AM ') ) BP EXPLORATION Operations. Summary. Rep()rt Page 18of25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From -To Hours Task Code NPT · Phase Description of Operations 1/6/2003 01 :00 - 01 :45 0.75 CASE N HMAN PROD1 Mix 50 bbl soda ash pill @ 10 ppb, 50 bbl Barascrub I Con-det pill wi 7 drums Barascrub & 4 drums Con-det, & 50 bbl viscous Barazan pill @ 3 ppb. 01 :45 - 05:00 3.25 CASE N HMAN PROD1 Reverse circuate sweeps & displace well to clean sea water. 1.5 circulations wi fianal NTU @ 38. 05:00 - 06:00 1.00 CASE N HMAN PROD1 BID lines & monitor well. 06:00 - 11 :30 5.50 CASE N HMAN PROD1 POH wi 5" DP. 11 :30 - 12:00 0.50 CASE N HMAN PROD1 Break 9 5/8" casing scraper & x-overs & C/O to 4" handling equip't. 12:00 - 13:30 1.50 CASE N HMAN PROD1 POH wi 4" DP. Break 7" casing scraper & x-over. 13:30 - 14:00 0.50 CASE N HMAN PROD1 R/U 2 3/8" handling tools. 14:00 - 15:00 1.00 CASE N HMAN PROD1 POH wI 23/8" DP. Still some oil wet CaC03 residue on 2 3/8" & 4" DP. Mostly near tool jts & on one side. Spotty. 15:00 - 15:30 0.50 CASE N HMAN PROD1 Clear floor. 15:30 - 15:45 0.25 CASE P PROD1 PJSM for R/U & pull wear ring. 15:45 - 16:00 0.25 CASE P PROD1 Pull wear ring & install junk catcher. 16:00 - 17:00 1.00 CASE P PROD1 M/U flushing tool & flush stack. BID & pull junk catcher. 17:00 - 17:30 0.50 CASE N HMAN PROD1 Clear floor & install wear ring. 17:30 - 18:15 0.75 CASE N HMAN PROD1 Clear floor & pull wear ring. 18:15 - 19:00 0.75 CASE P PROD1 Clear floor - PJSM on R/U to run 41/2" 13CR80 tubing. 19:00 - 23:15 4.25 CASE P PROD1 R/U to run 4 1/2" 13CR80 tubing & Weatherford to run fiber optics cable. 23:15 - 23:30 0.25 CASE P PROD1 PJSM - Running 41/2" 13CR80 Vam Ace tubing. 23:30 - 00:00 0.50 CASE P PROD1 Run 1 st 3 pre-bucked up ass'ys including WEG, centralizer, XN & X nipples, & permanent packer. 1/7/2003 00:00 - 00:30 0.50 RUNCOI\tP COMP MU Weatherford "Cidra" Fiber optic mandrel. 00:30 - 02:00 1.50 RUNCOI\tP COMP Connect Fiber Optic sensor and fiber optic cable to Mandrel. - Pressure test 7500 psig for 15 mins. - Install protective clamps. 02:00 - 12:00 10.00 RUNCOI\tP COMP Make up and RIH wi 4.5" 12.6 ppf, 13CR80, Vam-Ace completion. - Run Jts #1-130. - Make up torque 3620 ft-Ibs. - Average shoulder torque 1041 ft-Ibs through jts 1-25. 12:00 - 00:00 12.00 RUNCOI\tP COMP Continue RIH wi 4.5" 13CR80 Vam-Ace completion. - Run GLM wi RP shear valve after joint #208. - Run jts #209- 234. - Run 2nd GLM wI DGLV installed after JT #234. - Averaging 12 to 13 jtsl hr. - At Jt #282 by midnight. 1/8/2003 00:00 - 04:00 4.00 RUNCOI\tP COMP Run 4.5" 12.6 ppf, 13CR80, Vam-Ace tubing from Jt# 286-341. 04:00 - 07:00 3.00 RUNCOfv'N DPRB COMP Completion string taking wt @ 144489' md (PU wt= 200 KI SOW= 150 K). - Attempt to work past. - Kinked Cidra Fiber Optic cable (pulled tight on loop in cable on the sheave) when attempting to skip past 7" liner top. 07:00 - 14: 15 7.25 RUNCOfv'N HMAN COMP Splice Cidra Fiber Optic cable. 14:15-15:15 1.00 RUNCOfv'N DPRB COMP PJSM for rigging up a circulation hose to head pin. 15:15-17:15 2.00 RUNCOfv'N DPRB COMP Attempt to enter 7" liner while circulating @ 6 bpm wi 440 psig. - No progress. Not seeing any pressure changes on surface. Printed: 1/20/2003 9:23:03 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION Operations Summary Report NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From - To Hours Task Code NPT Phase 1/8/2003 17:15 -17:30 0.25 RUNCOIVN COMP 17:30 - 18:00 0.50 RUNCOIVN COMP 18:00 - 18:30 0.50 RUNCOIVN COMP 18:30 - 19:00 0.50 RUNCOIVN COMP 19:00 - 21 :00 2.00 RUNCOIVN COMP 21 :00 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 1.50 RUNCOIVN COMP 0.50 RUNCOIVN COMP 0.50 RUNCOrvT-J COMP 0.50 RUNCOI\rf\J COMP Page 190f 25 Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Description of Operations PJSM for rigging down circulation hose from head pin. Work pipe in attempt to skip past. PJSM for rigging down head pin and single joint compensator. Rig down head pin and single joint compensator. MU Top Drive to TIW valve. Rotate and attempt to get past. - Work torque down with 4, 6, 9 revolutions keeping torque at < 3000 ft-Ibs. - With 9 revs set down 8' higher (Suspect Centrailizer not getting past originally and now mule shoe on 7" liner top). Attempt to get past. - With 12 revs set down at 14489' (inside tie-back with mule shoe). Stack up to 75K down in attempt to slide by. Discuss options (Elected to rotate pipe to reorient the mule shoe to lowside low side of pointing down): Condition are these: - Dimensions: * 5.0 00 mule shoe with 5.875" intergral blader centralizer 8.4' back and a second 5.875" intergral blade centralizer 26'. * Liner tie back 7.4" id with tie back of 8.4' long. * hole angle is 43.5 degrees and dropping with 1.5 degree dogleg. * General opinion is mule shoe is oriented high side with stiff tail pipe and is tagging top of liner on high side of hole given hole is dropping. Options: 1. Stack up with max wieght -- Called Baker engineer in Anchorage and tube move says that the 4-1/2" tubing can withstand 112K compression before buckling failure -- with safety factors and all he recommended we not exceed 75K. Other than buckling, risk is that mule shoe could wedge between tie back and casing as opposed to fall into liner tie· back -- damage to tie back and mule shoe. 2. Bump and Jump while slacking off. While slacking off driller could repeatedly acutate the brake handle to transfer oscilating harmonics in attempt to jump the mule shoe into the top of liner. Same risk as above risk is that mule shoe could wedge between tie back and casing as opposed to fall into liner tie back -- damage to tie back and mule shoe. 3. Rotate string while limiting surface torque to 3000 ft Ibs with top drive. MU torque is 3620 and max allowable is 3900 ft Ibs. Risk is over torque connection of connection and damage to feber optic line. Back out of Top drive and pull 50' to check for increase in drag- Smooth pull 200 K. Screw back in with top drive and get inside liner tie-back with mule shoe WLEG with 3 turns. - Attempt to stay inside tie-back adding 3 more turns. Slack off- no progress. Back out top drive and lay-down TIW Valve. - Prepare to POOH with completion string. Conclusion: - Looks like centralizer is hanging up on top of 7" tieback assy -- 00 of centralizer is 5.875" and 10 of tie back is 7.5" at top Printed: 1/20/2003 9:23:03 AM ) ) BP EXPLORATION Ope ratio ns8 urnrnaryRepQ rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Date From ..To Hours Task Code NPT Phase 1/8/2003 23:30 - 00:00 0.50 RUNCOIVN CaMP 1/9/2003 00:00 - 02:00 2.00 RUNCOIVN DPRB CaMP 02:00 - 00:00 22.00 RUNCOIVN CaMP 1/10/2003 4.00 RUNCOIVN DPRB CaMP 00:00 - 04:00 04:00 - 05:00 1.00 RUNCOIVN CaMP 05:00 - 06:30 1.50 RUNCOIVN CaMP 06:30 - 07:30 1.00 RUNCOIVN CaMP 07:30 - 08:00 0.50 RUNCOIVN CaMP 08:00 - 09:00 1.00 RUNCOIVN CaMP 09:00 - 13:00 4.00 RUNCOIVN CaMP 13:00 - 15:30 2.50 RUNCOIVN CaMP 15:30 - 16:30 1.00 RUNCOIVN CaMP 16:30 - 18:30 2.00 RUNCOIVN CaMP 18:30 - 00:00 5.50 RUNCOIVN CaMP 1/11/2003 00:00 - 01 :30 1.50 RUNCOIVN CaMP 01 :30 - 02:00 0.50 RUNCONN CaMP 02:00 - 04:00 2.00 RUN CONN CaMP 04:00 - 05:00 1.00 RUNCONN CaMP Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Description of Operations and tapers down to a 6." 1 inside which then goes to 6.276" id of 7" 26# casing. Prepare floor for POOH wI 4.5" 12.6 ppf, 13CR80, completion string. -Back out crossover. LD Jt #342. -Rig up single joint compensator. Pull 4.5" completion from Jt#341- Jt #41. - Vam-PDS Rep inspecting threads after recleaning. Approximately 80 jts were damaged in the nose seal. Continue OOH wI 4.5" 12.6 ppf, 13CR80, tubing joints. - Pull Jrs #41- Jt #1. ***Est 20% of sealing surfaces damaged on Vam-Ace connections. *** Clean off Cidra mandrel (Sponified CaC03). Disconnect Fa cable and PIT sensor. Clean off jewelry wI power sprayer and inspect string for damage. - Mule shoe WLEG has been damaged- suspect 7" tie-back ext damaged. Contact BOT fishing shop to dispatch polish mill. No evidence of any damage to centrailizers. - Apply heat to Baker lock connection between Packer Assembly and Centrailizerl tailpipe assy. No problem with breakout. LD packer and tailpipe assembly. Note: RHC plug body still needs to be retrieved by Halco completion hand when he returns to island. Note: Extra SWS crew sent back to Prudhoe for day. Will need them back after polish mill - clean out run. RD Cidral Weatherford sheaves for Fiber optic cable. Island wide muster drill to Arktos. PJSM- RD tubing running equipment. PJSM for replacing brushes in TD motor. - Clean rig floor. Steam clean cannon clamps for Fa cable. - Replace brushes Top Drive motor. PJSM for slipping and cutting drilling line. - Slip and cut drilling line. Install wear ring. PJSM for PU Baker polish mill assembly. - PU polish mill BHA. RIH wI Polish mill assembly on 5" DP. - Strap pipe into hole. - At stand #103 by midnight. Note: Stopped and checked Torque readings against load cell. Gauge in good calibration. Continue RIH wI Baker tapered polish mill on 5" DP. - Run stands 104-120. Move 24 stands of 4" DP from Driller's side to Off-Driller's side. RI H wI stands 120- 153 of 5" DP. Dress liner top as per Baker Fishing Hand. - PU Wt=295 K, SOW= 225 K, Rot Wt= 255 K Ibs. - Torque 9K wI 40 rpm. Printed: 1/20/2003 9:23:03 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ') ') BP EXPLORATION Operations. Summary· Report NS18 NS18 DRILL +ÇOMPLETE NABORS ALASKA DRILLING I NABORS 33E Page 21 of 25 Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: 1/11/2003 04:00 - 05:00 From - To Hours . Task Code Description of Operations 05:00 - 12:30 1.00 RUNCOIVN COMP 7.50 RUNCOIVN COMP 12:30 - 13:00 0.50 RUNCOIVN COMP 13:00 - 17:00 4.00 RUNCOIVN COMP 17:00 - 17:30 0.50 RUNCOIVN COMP 17:30 - 20:30 3.00 RUNCOIVN COMP 20:30 - 21 :30 1.00 RUNCOIVN COMP 21 :30 - 22:00 0.50 RUNCOIVN COMP 22:00 - 23:30 1.50 RUNCOIVN COMP 23:30 - 00:00 0.50 RUNCOIVN COMP 1/12/2003 00:00 - 01 :00 1.00 RUNCOIVN OPRB COMP 01 :00 - 03:00 03:00 - 04:00 04:00 - 05:00 05:00 - 07:00 07:00 - 07:45 2.00 RUNCOIVN OPRB COMP 1.00 RUNCOIVN OPRB COMP 1.00 RUNCOIVN OPRB COMP 2.00 RUNCOWN OPRB COMP 0.75 RUNCOWN OPRB COMP - No increase in torque as pilot mill and polish mill entered tie-back extension. - Mill for 35 mins total wI WOB= 2K Ibs and torque increase to 10-11 K Ibs. PU 3 times and run back down without any resistance or torque increase speak of. PJSM for casing wash. PU 10' and begin casing wash as per plan: 1. Pump 100 bbls warm diesel 2. Follow with 25 bbls of BARASCRUB 3. Follow with 50 bbls of Condet 4. Follow with 50 bbls of 10 ppg -hi- vis NACL brine pill. 5. Chase with Sea Water at 6.5 bpm rate while rotating and reciprocating pipe. - Torque increased as solution coming out the mill. Good evidence of wall clean up wI thick viscous returns with diesel and BARASCRUB. - Final torque 16 K ft-Ibs without reciprocation. Monitor well. Tag liner top. -PU wt 305K, SOW= 210 K, 17K torque. Pull out hole with mill. Check out top drive torque against load cell. POOH to run e-line. Lay down Baker milling assembly. - Tattle tail indicates on liner top. Pilot mill very little evidence of wear. Service TO. Grease crown. PJSM for rigging up SWS e-line. - Rig up. RIH wI run #1: 6" Gauge ring and Junk Basket. Continue RIH wI Run #1 (6.00" GR/JB and GR/CCL)on SWS wireline. -Tie in above 7" liner top. - RIH and set down at 14484' elmd, inside 7" tie-back. Tap down 5 or 6 times with no progress. Attempt to pick up- stuck. Work wireline while stuck inside 7" Tie-back extension. - Line up fishing tools from Prudhoe. - Pull free wI 4800 Ibs (1300 Ibs over). POOH with 6.00 GR/JB. - One gash on side of gauge ring. - Either gauge ring was cocked inside tie-back or there is obstruction. Change out e-line tools to 1-11/16" GR/CCL. MU 6.02" tapered, gauge ring, centrailizer. RIH wI Run #2 wI SWS wireline (6.02" tapered centralizer). - Tie in above 7" liner top. - Tools stop inside 7" tie-back extension at 14489' elmd. Attempt to work past several times. No further progress. POOH wI 6.02" centrailizer. - Centrailizer has shining markings around the center (6.02" GR surface- middle of cent.), however no markings to speak of Printed: 1/20/2003 9:23:03 AM "\ J ') BP EXPLORATION Operations SUI11JnaryReport Page 22 of 25 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date Frofl1- To HoUrs Task Code NPT . · Phase Descri ptionof Operations 1/12/2003 07:00 - 07:45 0.75 RUNCOWN DPRB COMP on the lower taper surface. 07:45 - 08:00 0.25 RUNCOWN DPRB COMP Change out 6.02" tapered centrailizer wI 3.625" tapered centrailizer wI a sample bailer on bottom. Gather rig team for meeting on foward plan and what might be the problem in the tie-back extension. Check Baker machine print on tie-back extension. 08:00 - 09:00 1.00 RUNCOWN DPRB COMP RIH wI 3.625" cent and sample bailer. 09:00 - 09:30 0.50 RUNCOWN DPRB COMP After further discussion, rig team elects to not run 3.625" centrailizerlsample bailer past problem area in tie-back ext (possibility of creating fishing operation). -POOH wI run #3. 09:30 - 10:00 0.50 RUNCOWN DPRB COMP LD wireline tools and RD e-line temporarily. 10:00 - 10:30 0.50 RUNCOWN DPRB COMP Continue meeting with rig team slope and town on plan foward. - Load pipe shed wI 4-3/4" DC for probable string mill run. 1 0:30 - 11 :00 0.50 RUNCOWN DPRB COMP RD SWS e-line. 11 :00 - 12:00 1.00 RUNCOWN DPRB COMP Continue loading new 4.5" Vam-Ace in pipe shed. - Continue discussion on plan foward. 12:00 - 13:00 1.00 RUNCOWN DPRB COMP PT wellbore to 4200 psig. 13:00 - 14:30 1.50 RUNCOWN DPRB COMP Repair worn iron ruffneck rails. 14:30 - 16:00 1.50 RUNCOWN DPRB COMP PU and RU to MU Tapered string mill assembly. 16:00 - 18:00 2.00 RUNCOWN DPRB COMP MU BHA. - 4.75" tapered mill, XO, 6.15" String mill, Boot Basket, Bumper Sub, Jars, 6 each DC's, and 18 stands 4" DP. 18:00 - 20:30 2.50 RUNCOWN DPRB COMP RIH wI string mill assembly. 20:30 - 21 :00 0.50 RUNCOWN RREP COMP Replace broken air line on high drum clutch. 21 :00 - 21 :30 0.50 RUNCOWN WAIT COMP Operations has Fire alarm in HP-A. Muster. False Alarm. 21 :30 - 22:30 1.00 RUNCOWN RREP COMP Continue replacing broken air line on high drum clutch. 22:30 - 00:00 1.50 RUNCOWN DPRB COMP RIH wI string mill assembly on 5" DP. 1/13/2003 00:00 - 02:00 2.00 RUNCOWN DPRB COMP RIH wI string mill assembly to 14000' md. 02:00 - 03:30 1.50 RUNCOWN DPRB COMP PJSM. Slip and cut drilling line. - Install spacer in pipe handler. 03:30 - 04:00 0.50 RUNCOWN DPRB COMP RIH fl 14000' to 14487' (7" Liner Top- tie back ext). 04:00 - 04:45 0.75 RUNCOWN DPRB COMP Mill @ 14487'. - PU wt = 290 K, SOW= 215 K, ROT wt= 250 K Ibs - 11 K torque wI 40 rpm. - 57 spm wI 400 psig. -Milled for a total of 15 mins wI < 2000 Ibs WOB. Worked mill through 7" liner top area-- smooth. 04:45 - 06:00 1.25 RUNCOrvt-J DPRB COMP RIH to 16369' (4.5" liner top) - PU Wt= 325 K Ibsl SOW= 235 K - PU 10' and mark no-go line. - Install TIW valve. 06:00 - 06:30 0.50 RUNCOrvt-J DPRB COMP PJSM for pumping casing wash. 06:30 - 12:30 6.00 RUNCOrvt-J DPRB COMP Pump casing wash as per plan: - Pump 50 bbls of diesel - Followed wI 25 bbls Barascrub - Followed wI 50 bbls CONDENT - Chase with sea water. - Pump 65 bbls of 10 ppg hi vis sweep. Printed: 1/20/2003 9:23:03 AM ) ) BPEXPLORATION Page 23 of 25 OpérationsSummary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From.;. To Hours Task Code NPT Phase Description. of Operations 1/13/2003 06:30 - 12:30 6.00 RUNCOIVN DPRB CaMP - Chase with 1200 bbls sea water to surface at 6.5 bpm. Note: Good drag response from treatment: PU Wt 360 K Ibs- vs- 325 K Ibs before wash. 12:30 - 13:00 0.50 RUNCOIVN DPRB CaMP Monitor well. - Lay down TIW valve. Tag 4.5" liner top. BID. 13:00 - 20:30 7.50 RUNCOIVN DPRB CaMP POOH wi 5" & 4" DP. 20:30 - 21 :30 1.00 RUNCOIVN DPRB CaMP Lay down milling assembly. Very little evidence of any damage. Pillow baskets contained 1/2 coffee cup of longer metal cuttings (some aluminum and steel) wi a little bit of hard CaC03. 21 :30 - 22:00 0.50 RUNCOIVN DPRB CaMP Clear and clean rig floor. 22:00 - 23:00 1.00 RUNCOIVN DPRB CaMP PJSM. Pressure test wellbore to 4200 psig for 30 mins on chart. - PJSM for rigging up wireline. 23:00 - 00:00 1.00 RUNCOIVN DPRB CaMP RU SWS e-line. 1 114/2003 00:00 - 01 :45 1.75 RUNCOIVN DPRB CaMP Continue RIH wi 3.625" GR-CCL wi sample bailer. - Tag bottom at 16856' md. - Sample bailer returned wI black pipe dope mixed with EP mud lube. POOH fl running completion. 01 :45 - 03:00 1.25 RUNCOIVN DPRB CaMP POOH after logging through from TO to 15370'. 03:00 - 03:30 0.50 RUNCOIVN DPRB CaMP PJSM. RD SWS wireline. 03:30 - 04:30 1.00 RUNCOIVN DPRB CaMP Pull wear ring - run wear ring junk basket. - Flush stack. - Pull junk basket (Thick mud returns - no metal) 04:30 - 05:00 0.50 RUNCOIVN DPRB CaMP LD Baker tools from rig floor. 05:00 - 06:30 1.50 RUNCOIVN DPRB CaMP PJSM for rigging up to run completion. - Decide to bring up 200 T elevators and back up tongs to floor. Rig welder and personnel will be working on VLE modification simultaneously while the running completion. 06:30 - 07:30 1.00 RUNCOIVN DPRB CaMP RU Weatherford Fiber Optic Cable and sheaves. 07:30 - 08:00 0.50 RUNCOIVN DPRB CaMP PJSM for running completion. 08:00 - 08:30 0.50 RUNCOIVN DPRB CaMP MU jewelry: 1) Tailpipe assembly (Racheting Mule Shoe- 3.5" 10) wI 'XN' Nipple (RHC Plug body installed) and 'X' Nipple. 2) Packer Assembly --Bakerlock connection. 3) 'X' nipple assembly. 4) Weatherford Fiber Optic Mandrel. 08:30 - 09:00 0.50 RUNCOIVN DPRB CaMP Install Fiber Optic PT sensor. -Test to 7500 psig for 15 mins. 09:00 - 12:00 3.00 RUNCOIVN DPRB CaMP Run 4.5" 12.6 ppf, 13CR80, Vam-Ace tubing. - Run Jts #1- 41 (14jts I hr) - MU torque is 3620 ft-Ibs wi shoulder coming in at 900 to 1100 ft-Ibs. 12:00 - 00:00 12.00 RUNCOIVN DPRB CaMP Continue running 4.5", 13CR80, Vam-Ace tubing. - Run Jts #42- 221. Install GLM wi RP shear valve after JT -#209. 1/15/2003 00:00 - 08:00 8.00 RUNCOIVN DPRB CaMP Run Jts 222 - 340 of 4.5" 12.6 ppf, 13CR80, Vam-ace tubing. - PU Wt= 203 K Ibs & SOW= 147 K Ibs. Printed: 1/20/2003 9:23:03 AM ) ) BP EXPLORATION Operations .Summary.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Date From ..;To· Hours Task Code··· NPT Phase Description of Operations 1/15/2003 00:00 - 08:00 8.00 RUNCOIVN DPRB COMP PU Jts 341-344. Run carefully through 7" liner top with WLEG. No indication. Production packer went through without any seeing anything on wt indicator. 08:00 - 09:15 1.25 RUNCOIVP COMP Run Jts #345- 362 09:15 - 09:45 0.50 RUNCOIVP COMP MU CAMCO TRSSV. - MU single control line. - Test control line to 6000 psig f/15 mins. 09:45 - 11 :30 1.75 RUNCOIVP COMP Run Jts #363- 387. Tag at 16377' for space out. 11 :30 - 12:00 0.50 RUNCOIVP COMP Rig up to circulate. Tag liner and confirm with pump at 3 bpm = 150 psig. No increase in pressure seen when WLEG entered 4.5" tie-back extension. 12:00 - 14:00 2.00 RUNCOIVP COMP Reconfirm tag. - Racheting WLEG working. Tag 4.5" line top. Set down wI 8K Ibs 2 more times and Tag bottom of tie-back. LD jts 387, 386, and 385. MU 28' of space out pup jts (7.92'/9.98'/10.18'). MU Jt #385. 14:00 - 15:00 1.00 RUNCOIVP COMP MU tubing hanger and landing joint. - PUW= 230 K Ibs - SOW=160 K Ibs 15:00 - 17:00 2.00 RUNCOIVP COMP Run control line & Cidra Fiber Optic line through tubing hanger. 17:00 -18:30 1.50 RUNCOIVP COMP Land tubing wI 6000 psig on control line. - RILDS. - Test tubing hanger seals to 5000 psig. 18:30 - 19:30 1.00 RUNCOIVP COMP RU TIW and manifold for dropping Ball & Rod. 19:30 - 20:30 1.00 RUNCOIVP COMP Drop 1.7/8" ball and rod (42") wI 1.375" FN and fins. - After 15 mins pressure up on tubing side to 4200 psig to set PKR and for tubing test. 20:30 - 21 :00 0.50 RUNCOIVP COMP Hold Pressure Test at 4200 psig for 30 min on tubing- record on chart. 21 :00 - 22:00 1.00 RUNCOIVP COMP Pressure Test Inner Annulus: - Bleed tubing pressure to 3000 psig. - Pressure up on annulus to 4200 psig (Held tubing constant at 3000 psig by bleeding while pumping) - Record 4200 psig for 30 mins. 22:00 - 23:00 1.00 RUNCOIVP COMP Shear out "RP-shear valve in lower GLM: -Bleed down both sides to 0 psig. - Pressure up on annulus to 2600 psig and shear out Valve. - Pump 2 bpm for 5 min to ensure valve shear out. 23:00 - 23:30 0.50 RUNCOIVP COMP Pressure Test Camco TRSV: - Bleed off control line to 0 psig (close flapper valve). - Pressure up on annulus side to 1000 psig. - Hold test for 30 mins - Pressure up on control line to 6000 psig and open valve. 23:30 - 00:00 0.50 RUNCOIVP COMP Reverse circulate 25 bbls of sea water containing 2 bbls of corrosion inhibitor (EC1142A). - Follow corrosion inhibitior pill wI 30 bbls Sea Water. 1/16/2003 00:00 - 00:30 0.50 RUNCOIVP COMP Reverse circulate 30 bbls of sea water. Printed: 1/20/2003 9:23:03 AM ') ) BP EXPLORATION O,perations Summ:é\ry.Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/16/2003 NS18 NS18 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 33E From - To Hours Task Code NPT Phase 00:00 - 00:30 0.50 RUNCOrvP COMP 00:30 - 07:00 6.50 RUNCOrvP COMP 07:00 - 09:00 2.00 RUNCOrvP COMP 09:00 - 10:00 1.00 RUNCOrvP COMP 10:00 - 10:30 0.50 BOPSURP COMP 10:30 - 12:00 1.50 BOPSUR P COMP 12:00 - 17:30 5.50 WHSUR P COMP 17:30 - 20:30 3.00 WHSUR P COMP Page 25 of 25 Start: 7/11/2002 Rig Release: 1/16/2003 Rig Number: 33E Spud Date: 7/15/2002 End: Description of Operations PJSM for pumping diesel from warm up tank. Reverse circulate 375 bbls of warm diesel. Allow diesel to U-tube after bleeding off 2 bbls of sea water flush. LO landing jt. Close TRSV and terminate Fiber Optics. Install TWC. PJSM for NO BOP's. - Clean up riser NO BOP's and secure on rack. Wrap and terminate TRSV control line and Cidra Fiber Optic lines through the WH. NU tree and test to 5000 psig. «RELEASE RIG AT 20:30 HRS» Printed: 1/20/2003 9:23:03 AM ) ) Well: Field: API: Permit: NS18 Northstar Unit 50-029-23102-00 202-141 Accept: Spud: Release: Rig: 07/15/02 07/16/02 01/16/03 Nabors 33E POST-RIG WORK 11/30/02 ARRIVE ON ISLAND. SPOT CRANE. MOVE SWS EQUIPMENT INTO LOCATION. RIG UP EQUIPMENT. ATTEMPT TO RIH. COULD NOT GET PAST THE SSV AREA. POH ICE ON TOOLS. PUT HEATER ON SSV. AFTER SSV IS THAWED, TRIED TO PULL BPV BUT AREA BELOW SSV TO BPV IS ALL ICE. TENT UP AREA BELOW SSV AND PUT HEATER ON. WILL LEAVE HEATER ON OVER NIGHT. 12/01/02 LOG GR/CCL FROM 158851 TO SURFACE FOR PRIMARY E-LlNE DEPTH LOG- TD TAG IS HIGH COMPARED WITH DRILLING PBTD. 01/21/03 PULLED BALL & ROD FROM THE RHC PLUG @ 163321 SLM. PULLED RP SHEAR VALVE FROM #1 GLM @ 74891 SLM, SET DUMMY GLV IN PLACE. PULLED THE RHC PLUG FROM 163341 SLM. DRIFTED W/2 7/811 DUMMY GUN TO 168291 SLM 01/22/03 PERFORATE 16815' - 16835', 6 SPF POWERJET, HAD 2 MISS-RUNS DUE TO TOOL FAILURE FRIST MISS-RUN WE FOUND TOOL SAVER (SHOCK ADAPTER) HAD AN ELECTRICAL LEAK SECOND MISS-RUN WE FOUND A DEFECTED EFI CHARGE. 01/23/03 RAN 2 7/811 HSD PJ 6SPF, TOTAL INTERVAL SHOT = 60'.167751-168351 UNABLE TO SHOOT THE TOP 131 (16775'-16762') DUE TO TOOL PROBLEMS FOUND FAILED O-RING. IN AH-38 ADAPTOR APPEARS TO BE THE CAUSE OF THE FAILURE 01/30/03 SPOT EQUIP, STAND BY FOR USE OF POWER CORD FROM CIDRA UNIT, CHANGE OUT DGLV @ STA# 1 (DUMMY INDICATING ONLY HALF WAY IN POCKET) BLEED IA DOWN, GOOD TEST. Legal Name: Common Name: Test Date 7/21/2002 7/31/2002 12/30/2002 FIT FIT FIT NS18 NS18 Test Type Test Depth (TMD) 4,070.0 (ft) 14,713.0 (ft) 16,541.0 (ft) Test Depth (TVD) 3,239.0 (ft) 9,262.0 (ft) 10,842.0 (ft) AMW 8.60 (ppg) 12.90 (ppg) 9.20 (ppg) SurfacePressLlre 650 (psi) 850 (psi) 1,300 (psi) L¢akOffp.r~$l,lrè(BHP) 2,097 (psi) 7,057 (psi) 6,482 (psi) EMW 12.46 (ppg) 14.67 (ppg) 11.51 (ppg) -~ '--' Printed: 1/20/2003 9:22:55 AM ¡ op NS18 Schlumbergep Survey Report - Geodetic Report Date: 31-Dec-03 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 308.060° Field: Northstar Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Northstar PF / NS18 TVD Reference Datum: KB Well: NS18 TVD Reference Elevation: 55.850 ft relative to MSL Borehole: NS18 Sea Bed I Ground Level Elevation: 15.670 ft relative to MSL UWVAPI#: 500292310200 Magnetic Declination: +26.262° Survey Name / Date: NS 18 / December 31 , 2002 Total Field Strength: 57543.057 nT Tort / AHD / DDI/ ERD ratio: 168.287° / 11806.51 ft / 6.478 / 1.060 Magnetic Dip: 80.945° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: July 31,2002 - Location Lat/Long: N 70.49121354, W 148.6933044E Magnetic Declination Model: BGGM 2002 Location Grid NIE YIX: N 6030991.320 ftUS, E 659828.760 ftUS North Reference: True North Grid Convergence Angle: +1.23170237° Total Corr Mag North -> True North: +26.262° Grid Scale Factor: 0.99992902 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ-S El-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 o Oft} (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6030991.32 659828.76 N 70.49121354 W 148.69330448 50.00 0.31 38.86 50.00 0.00 0.11 0.08 0.62 6030991.43 659828.84 N 70.49121383 W 148.69330379 100.00 0.33 342.08 100.00 0.12 0.35 0.13 0.61 6030991.67 659828.88 N 70.49121449 W 148.69330346 150.00 0.37 344.64 150.00 0.36 0.64 0.04 0.09 6030991.96 659828.78 N 70.49121529 W 148.69330417 162.00 0.43 348.38 162.00 0.43 0.72 0.02 0.55 6030992.04 659828.76 N 70.49121551 W 148.69330433 281.00 0.99 296.50 280.99 1.78 1.62 -0.99 0.67 6030992.92 659827.73 N 70.49121796 W 148.69331259 351.00 1.11 282.55 350.98 2.98 2.04 -2.19 0.40 6030993.31 659826.52 N 70.49121910 W 148.69332242 441.00 1.27 284.77 440.96 4.68 2.48 -4.01 0.18 6030993.71 659824.70 N 70.49122031 W 148.69333726 533.00 1.76 281.26 532.93 6.88 3.01 -6.38 0.54 6030994.20 659822.32 N 70.49122178 W 148.69335664 ~' 624.00 2.49 295.11 623.86 10.06 4.13 -9.54 0.98 6030995.24 659819.13 N 70.49122482 W 148.69338248 660.00 3.16 291.02 659.82 11.77 4.81 -11.18 1.94 6030995.89 659817.48 N 70.49122669 W 148.69339584 750.00 5.63 296.77 749.55 18.47 7.69 -17.43 2.78 6030998.64 659811.17 N 70.49123456 W 148.69344699 840.00 7.51 301.00 838.95 28.64 12.71 -26.42 2.16 6031003.46 659802.08 N 70.49124827 W 148.69352043 930.00 9.39 304.20 927.97 41.80 19.87 -37.53 2.15 6031010.37 659790.81 N 70.49126782 W 148.69361128 1030.00 11.78 306.19 1026.26 60.14 30.48 -52.52 2.42 6031020.66 659775.60 N 70.49129681 W 148.69373379 1121.00 14.02 306.92 1114.96 80.45 42.59 -68.83 2.47 6031032.42 659759.03 N 70.49132989 W 148.69386713 1218.00 17.12 308.11 1208.39 106.48 58.46 -89.46 3.21 6031047.84 659738.07 N 70.49137325 W 148.69403578 1280.00 18.42 307.73 1267.43 125.40 70.09 -104.39 2.11 6031059.14 659722.89 N 70.49140502 W 148.69415781 NS18 ASP Final Surveys2.xls Page 1 of 6 1/16/2003-5:15 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1310.68 19.07 309.52 1296.48 135.26 76.25 -112.09 2.83 6031065.13 659715.06 N 70.49142183 W 148.69422076 1408.82 21.53 312.58 1388.52 169.25 98.64 -137.72 2.73 6031086.97 659688.96 N 70.49148300 W 148.69443028 1501.89 21 .44 313.01 1475.13 203.22 121.79 -162.74 0.19 6031109.58 659663.45 N 70.49154626 W 148.69463475 1596.67 22.10 313.43 1563.15 238.23 145.87 -188.35 0.72 6031133.09 659637.33 N 70.49161203 W 148.69484414 1691.84 23.74 312.27 1650.80 275.16 171.06 -215.53 1.79 6031157.70 659609.62 N 70.49168085 W 148.69506632 1785.67 25.30 311.90 1736.17 314.00 197.16 -244.43 1.67 6031183.16 659580.16 N 70.49175214 W 148.69530258 1880.95 25.80 313.39 1822.13 354.96 225.00 -274.65 0.85 6031210.35 659549.35 N 70.49182819 W 148.69554963 1975.10 28.72 310.93 1905.82 397.96 253.90 -306.64 3.32 6031238.55 659516.76 N 70.49190715 W 148.69581112 2068.71 30.78 309.26 1987.09 444.38 283.80 -342.18 2.37 6031267.68 659480.58 N 70.49198882 W 148.69610167 2164.39 34.43 312.22 2067.68 495.85 317.48 -381.19 4.16 6031300.51 659440.87 N 70.49208083 W 148.69642052 2260.36 36.14 313.36 2146.02 551.10 355.14 -421.86 1.91 6031337.29 659399.40 N 70.49218372 W 148.69675300 -- 2355.46 40.72 310.89 2220.50 610.04 394.73 -465.72 5.08 6031375.92 659354.70 N 70.49229184 W 148.69711160 2451.43 42.96 309.43 2292.00 674.00 435.99 -514.65 2.55 6031416.12 659304.89 N 70.49240457 W 148.69751161 2546.90 44.60 307.95 2360.92 740.05 477.27 -566.21 2.03 6031456.28 659252.46 N 70.49251733 W 148.69793314 2642.55 47.69 306.65 2427.19 809.00 519.05 -621.08 3.38 6031496.86 659196.71 N 70.49263144 W 148.69838171 2738.43 51.03 306.94 2489.63 881.73 562.62 -679.33 3.49 . 6031539.17 659137.54 N 70.49275046 W 148.69885792 2834.14 55.04 306.59 2547.17 958.17 608.38 -740.59 4.20 6031583.59 659075.32 N 70.49287545 W 148.69935869 2927.54 55.90 307.26 2600.11 1035.10 654.61 -802.10 1.09 6031628.49 659012.84 N 70.49300172 W 148.69986157 3025.36 56.14 306.26 2654.78 1116.19 703.15 -867.08 0.88 6031675.62 658946.83 N 70.49313431 W 148.70039286 3120.67 56.80 306.57 2707.43 1195.61 750.31 -931.02 0.74 6031721.39 658881.90 N 70.49326314 W 148.70091558 3214.04 56.00 307.00 2759.10 1273.36 796.88 -993.30 0.94 6031766.61 658818.63 N 70.49339033 W 148.70142482 3309.10 56.61 307.00 2811.84 1352.43 844.48 -1056.47 0.64 6031812.83 658754.46 N 70.49352034 W 148.70194124 3404.87 56.86 307.64 2864.37 1432.50 893.03 -1120.15 0.62 6031860.00 658689.76 N 70.49365294 W 148.70246191 3499.43 58.00 308.33 2915.27 1512.19 942.07 -1182.95 1.35 6031907.68 658625.92 N 70.49378690 W 148.70297541 3590.25 59.23 308.98 2962.57 1589.72 990.50 -1243.50 1.49 6031954.79 658564.35 N 70.49391918 W 148.70347043 3685.92 58.01 308.92 3012.38 1671.38 1041.85 -1307.01 1.28 6032004.76 658499.75 N 70.49405941 W 148.70398979 .~ 3781.29 57.77 308.41 3063.08 1752.16 1092.32 -1370.09 0.52 6032053.85 658435.61 N 70.49419726 W 148.70450552 3876.15 55.29 308.63 3115.39 1831.28 1141.59 -1431.99 2.62 6032101.78 658372.66 N 70.49433184 W 148.70501171 3975.52 54.12 308.24 3172.80 1912.38 1192.01 -1495.52 1.22 6032150.82 658308.07 N 70.49446954 W 148.70553116 4191.86 53.45 305.27 3300.64 2086.84 1296.45 -1635.33 1.15 6032252.23 658166.06 N 70.49475478 W 148.70667434 4287.67 53.34 306.42 3357.77 2163.70 1341 .49 -1697.67 0.97 6032295.91 658102.77 N 70.49487778 W 148.70718413 4382.39 53.81 305.11 3414.01 2239.85 1386.03 -1759.51 1.22 6032339.11 658039.99 N 70.49499942 W 148.70768981 4477.03 53.93 305.49 3469.81 2316.20 1430.20 -1821.90 0.35 6032381.92 657976.67 N 70.49512005 W 148.70819994 4571.59 54.12 303.99 3525.36 2392.59 1473.80 -1884.78 1.30 6032424.16 657912.87 N 70.49523913 W 148.70871414 4667.63 54.30 304.83 3581.53 2470.34 1517.83 -1949.05 0.73 6032466.79 657847.68 N 70.49535935 W 148.70923970 NS18 ASP Final Surveys2.xls Page 2 of 6 1/16/2003-5:15 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) C/100ft) (ftUS) (ftUS) 4761.62 53.95 303.90 3636.61 2546.34 1560.82 -2011.92 0.88 6032508.42 657783.91 N 70.49547675 W 148.70975377 4856.65 54.31 305.15 3692.30 2623.20 1604.46 -2075.36 1.13 6032550.69 657719.55 N 70.49559593 W 148.71027256 4951.25 54.69 306.46 3747.23 2700.15 1649.52 -2137.81 1.20 6032594.39 657656.14 N 70.49571897 W 148.71078331 5046.76 55.23 307.19 3802.07 2778.33 1696.39 -2200.41 0.84 6032639.90 657592.56 N 70.49584697 W 148.71129520 5142.43 55.56 307.82 3856.40 2857.07 1744.33 -2262.88 0.64 6032686.48 657529.08 N 70.49597789 W 148.71180605 5237.81 56.11 308.11 3909.96 2935.99 1792.88 -2325.09 0.63 6032733.68 657465.84 N 70.49611047 W 148.71231488 5333.96 56.48 307.86 3963.32 3015.97 1842.11 -2388.14 0.44 6032781.54 657401.75 N 70.49624490 W 148.71283047 5429.05 56.89 308.37 4015.55 3095.44 1891.16 -2450.66 0.62 6032829.23 657338.20 N 70.49637884 W 148.71334177 5524.61 57.60 309.01 4067.25 3175.80 1941 .40 -2513.38 0.93 6032878.10 657274.41 N 70.49651602 W 148.71385478 5620.82 58.07 309.31 4118.47 3257.22 1992.83 -2576.53 0.56 6032928.16 657210.18 N 70.49665646 W 148.71437126 5716.52 58.46 309.68 4168.81 3338.59 2044.59 -2639.34 0.52 6032978.56 657146.28 N 70.49679782 W 148.71488495 -- 5812.50 58.59 309.86 4218.92 3420.41 2096.96 -2702.26 0.21 6033029.56 657082.25 N 70.49694082 W 148.71539955 5906.45 58.55 309.30 4267.91 3500.55 2148.04 -2764.04 0.51 6033079.29 657019.39 N 70.49708029 W 148.71590490 6001.37 58.48 309.10 4317.48 3581.48 2199.20 -2826.77 0.19 6033129.09 656955.58 N 70.49721999 W 148.71641796 6096.84 58.31 309.68 4367.52 3662.77 2250.80 -2889.61 0.55 6033179.32 656891.65 N 70.49736088 W 148.71693194 6191.43 58.09 309.60 4417.36 3743.13 2302.08 -2951 ,,52 0.24 6033229.26 656828.66 N 70.49750092 W 148.71743830 6287.48 57.99 310.00 4468.20 3824.58 2354.25 -3014; 13 0.37 6033280.06 656764.95 N 70.49764336 W 148.71795040 6382.41 57.78 310.82 4518.67 3904.91 2406.37 -3075.35 0.76 6033330.85 656702.62 N 70.49778568 W 148.71845117 6477.00 58.05 311.01 4568.92 3984.96 2458.85 -3135.91 0.~3 6033382.02 656640.95 N 70.49792900 W 148.71894656 6573.11 58.09 310.95 4619.75 4066.42 2512.35 -3197.49 0.07 6033434.18 656578.24 N 70.49807506 W 148.71945027 6667.77 57.85 310.77 4669.95 4146.57 2564.85 -3258.18 0.30 6033485.36 656516.44 N 70.49821841 W 148.71994675 6761.25 57.65 310.29 4719.83 4225.56 2616.22 -3318.27 0.48 6033535.42 656455.26 N 70.49835869 W 148.72043829 6858.23 57.31 311.05 4771.97 4307.25 2669.51 -3380.29 0.75 6033587.37 656392.11 N 70.49850420 W 148.72094566 6953.34 57.27 310.68 4823.37 4387.18 2721.87 -3440.82 0.33 6033638.41 656330.49 N 70.49864716 W 148.72144074 7048.34 57.34 310.67 4874.68 4467.04 2773.98 -3501 .45 0.07 6033689.20 656268.75 N 70.49878944 W 148.72193676 7142.04 57.44 309.93 4925.18 4545.91 2825.03 -3561.65 0.67 6033738.94 656207.48 N 70.49892882 W 148.72242920 __. 7237.08 57.61 309.90 4976.21 4626.05 2876.48 -3623.14 0.18 6033789.05 656144.89 N 70.49906928 W 148.72293228 7332.53 57.83 309.98 5027.18 4706.70 2928.28 -3685.01 0.24 6033839.51 656081.93 N 70.49921073 W 148.72343845 7428.76 57.93 308.53 5078.35 4788.18 2979.85 -3748.12 1.28 6033889.70 656017.73 N 70.49935152 W 148.72395471 7523.75 58.20 306.79 5128.60 4868. 79 3029.10 -3811.94 1.58 6033937.57 655952.88 N 70.49948597 W 148.72447676 7619.07 58.33 305.21 5178.74 4949.80 3076.75 -3877.52 1.42 6033983.79 655886.29 N 70.49961605 W 148.72501327 7714.10 58.57 304.62 5228.46 5030.66 3123.10 -3943.93 0.59 6034028.70 655818.91 N 70.49974258 W 148.72555652 7810.36 58.21 302.62 5278.92 5112.39 3168.49 -4012.18 1.81 6034072.61 655749.69 N 70.49986647 W 148.72611491 7906.00 58.17 302.96 5329.33 5193.32 3212.50 -4080.51 0.30 6034115.14 655680.44 N 70.49998662 W 148.72667385 7998.39 57.94 303.32 5378.22 5271.43 3255.36 -4146.15 0.41 6034156.58 655613.90 N 70.50010360 W 148.72721088 NS18 ASP Final Surveys2.xls Page 3 of 6 1/16/2003-5: 15 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 8095.73 57.85 303.53 5429.95 5353.61 3300.78 -4214.97 0.20 6034200.50 655544.12 N 70.50022758 W 148.72777386 8190.23 57.62 303.76 5480.40 5433.28 3345.05 -4281 .49 0.32 6034243.33 655476.67 N 70.50034842 W 148.72831808 8286.77 57.80 304.13 5531.97 5514.68 3390.63 -4349.19 0.37 6034287.43 655408.01 N 70.50047281 W 148.72887195 8381.33 57.59 304.79 5582.51 5594.45 3435.85 -4415.09 0.63 6034331.23 655341.16 N 70.50059624 W 148.72941109 8478.95 57.15 305.33 5635.14 5676.55 3483.07 -4482.39 0.65 6034376.99 655272.87 N 70.50072514 W 148.72996166 8576.15 56.81 306.29 5688.11 5757.98 3530.76 -4548.48 0.90 6034423.24 655205.77 N 70.50085530 W 148.73050241 8666.77 56.38 305.95 5738.00 5833.59 3575.35 -4609.59 0.57 6034466.50 655143.72 N 70.50097702 W 148.73100238 8763.65 56.19 308.20 5791.78 5914.15 3623.93 -4673.88 1.94 6034513.68 655078.41 N 70.50110961 W 148.73152840 8858.57 56.19 308.94 5844.60 5993.02 3673.10 -4735.54 0.65 6034561.51 655015.71 N 70.50124384 W 148.73203294 8953.74 56.12 309.34 5897.60 6072.05 3722.99 -4796.85 0.36 6034610.07 654953.35 N 70.50138003 W 148.73253458 -" 9049.24 56.39 310.13 5950.66 6151.42 3773.75 -4857.91 0.74 6034659.51 654891.21 N 70.50151860 W 148.73303427 9144.86 56.22 309.26 6003.70 6230.94 3824.56 -4919.13 0.78 6034708.99 654828.92 N 70.50165730 W 148.73353517 9240.02 56.08 309.1 8 6056.71 6309.96 3874.53 -4980.35 0.16 6034757.63 654766.64 N 70.50179370 W 148.73403618 9335.64 55.74 309.17 6110.30 6389.13 3924.56 -5041.74 0.36 6034806.32 654704.20 N 70.50193024 W 148.73453852 9431.05 55.39 309.14 6164.25 6467.81 3974.24 -5102.76 0.37 6034854.68 654642.13 N 70.50206587 W 148.73503785 9526.50 55.12 309.10 6218.65 6546.22 4023.73 -5163.61 0;28 6034902.84 654580.23 N 70.50220094 W148.73553579 9620.55 54.87 309.37 6272.61 6623.24 4072.46 -5223.28 0.35 6034950.27 654519.54 N 70.50233394 W 148.73602408 9715.38 54.60 308.88 6327.36 6700.66 4121.31 -5283.34 0.51 6034997.82 654458.44 N 70.50246730 W 148.73651563 9810.97 54.53 309.09 . 6382.78 6778.53 4170.31 -5343.88 0.19 6035045.50 654396.86 N 70.50260104 W 148.73701106 9905.17 54.49 309.28 6437.47 6855.22 4218:77 -5403.34 0:17 6035092.67 654336.39 N 70.50273331 W148.73749758 10000.59 54.25 309.16 6493.05 6932.76 4267.81 -5463.42 0.27 6035140.40 654275.27 N 70.50286716 W 148.73798930 10096.79 53.92 309.29 6549.48 7010.65 4317.08 -5523.78 0.36 6035188.36 654213.87 N 70.50300163 W 148.73848324 10191.53 53.78 309.47 6605.37 7087.13 4365.62 -5582.91 0.21 6035235.61 654153.72 N 70.50313410 W 148.73896717 10286.70 54.07 309.11 6661.41 7164.04 4414.33 -5642.44 0.43 6035283.03 654093.15 N 70.50326705 W 148.73945440 10380.99 54.45 309.1 0 6716.49 7240.56 4462.60 -5701.83 0.40 6035330.01 654032.75 N 70.50339880 W 148.73994045 10476.35 54.83 309.34 6771.67 7318.31 4511.77 -5762.08 0.45 6035377.87 653971.46 N 70.50353301 W 148.7 4043354 .~ 10571.41 55.36 309.71 6826.07 7396.24 4561.39 -5822.21 0.64 6035426.18 653910.28 N 70.50366842 W 148.74092569 10666.19 55.75 310.59 6879.68 7474.35 4611.79 -5881.95 0.87 6035475.28 653849.47 N 70.50380597 W 148.74141467 10760.77 56.13 310.71 6932.65 7552.62 4662.83 -5941 .40 0.42 6035525.03 653788.94 N 70.50394529 W 148.74190124 10854.57 56.71 310.84 6984.53 7630.68 4713.86 -6000.58 0.63 6035574.78 653728.69 N 70.50408458 W 148.74238561 10947.38 56.97 310.59 7035.29 7708.29 4764.54 -6059.47 0.36 6035624.17 653668.72 N 70.50422290 W 148.74286764 11042.46 57.32 310.97 7086.88 7788.08 4816.71 -6119.95 0.50 6035675.03 653607.14 N 70.50436529 W 148.74336268 11139.49 57.59 309.91 7139.07 7869.80 4869.77 -6182.20 0.96 6035726.73 653543.77 N 70.50451008 W 148.74387223 11234.43 57.86 310.12 7189.77 7950.02 4921.38 -6243.68 0.34 6035777.00 653481.20 N 70.50465094 W 148.74437544 11327.46 58.10 309.49 7239.10 8028.86 4971.87 -6304.27 0.63 6035826.18 653419.54 N 70.50478875 W 148.74487144 NS18 ASP Final Surveys2.xls Page 4 of 6 1/16/2003-5:15 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 11425.05 58.30 309.53 7290.52 8111.77 5024.64 -6368.26 0.21 6035877.56 653354.43 N 70.50493275 W 148.74539523 11517.60 58.50 309.79 7339.02 8190.57 5074.95 -6428.95 0.32 6035926.55 653292.69 N 70.50507005 W 148.74589197 11614.52 58.61 309.92 7389.58 8273.22 5127.94 -6492.42 0.16 6035978.15 653228.09 N 70.50521466 W 148.74641156 11711.03 57.93 309.16 7440.34 8355.27 5180.20 -6555.72 0.97 6036029.04 653163.69 N 70.50535727 W 148.74692973 11803.31 57.33 308.53 7489.74 8433.21 5229.09 -6616.42 0.87 6036076.60 653101.95 N 70.50549067 W 148.74742662 11899.19 56.78 307.19 7541.89 8513.66 5278.47 -6679.95 1.31 6036124.60 653037.39 N 70.50562542 W 148.74794659 11994.42 56.20 306.27 7594.46 8593.04 5325.95 -6743.58 1.01 6036170.71 652972.75 N 70.50575499 W 148.74846747 12089.41 55.61 305.45 7647.71 8671.65 5372.04 -6807.33 0.95 6036215.41 652908.03 N 70.50588072 W 148.74898929 12183.86 55.03 305.67 7701.45 8749.24 5417.21 -6870.52 0.64 6036259.20 652843.89 N 70.50600396 W 148.74950650 12278.16 54.24 304.93 7756.03 8826.05 5461.64 -6933.27 1.05 6036302.28 652780.20 N 70.50612520 W 148.75002021 12374.44 53.72 305.01 7812.65 8903.81 5506.28 -6997.09 0.54 6036345.53 652715.45 N 70.50624697 W 148.75054256 .-" 12470.34 53.82 304.80 7869.33 8981.05 5550.54 -7060.53 0.21 6036388.41 652651.07 N 70.50636773 W 148.75106187 12566.37 53.80 305.01 7926.03 9058.43 5594.89 -7124.09 0.18 6036431.38 652586.58 N 70.50648872 W 148.75158216 12660.29 53.75 305.38 7981.53 9134.11 5638.56 -7186.00 0.32 6036473.71 652523.75 N 70.50660785 W 148.75208899 12754.37 53.99 307.03 8037.01 9210.05 5683.44 -'7247.31 1.44 6036517.26 652461 .49 N 70.50673030 W 148.75259089 12848.36 54.21 308.43 8092.12 9286.18 5730.03 -7307.53 1.23 6036562.54 652400.29 N 70.50685742 W 148;75308383 12941.73 54.17' 308.66 8146.75 9361.90 5777.21 -7366.75 0.20 6036608.43 652340.08 N 70.50698615 Wt48.75356868 13038.40 54.31 309.03 8203.25 9440.33 5826.41 -7427.84 0.34 6036656.31 652277.94 N 70.50712040 W 148.75406888 13135.16 54.64 309.13 8259.47 9519.07 5876.06 -7488.97 0.35 6036704.62 652215.76 N 70.50725585 W 148.75456937 13225.71 54.68 308.99 8311.85 9592.92 5922.60 -7546.33 0.13 6036749.92 652157.43 N 70.50738285 W 148.75503896 13324.37 54.13 309.58 8369.27 9673.13 5973.40 -7608.42 0.74 6036799.37 652094.26 N 70.50752144 W 148.75554737 13419.60 53.23 309.14 8425.67 9749.84 6022.06 -7667.75 1.02 6036846.74 652033.91 N 70.50765421 W 148.75603309 13515.51 52.37 308.69 8483.66 9826.22 6070.05 -7727.19 0.97 6036893.43 651973.45 N 70.50778515 W 148.75651976 13610.21 51.78 308.95 8541.87 9900.92 6116.88 -7785.39 0.66 6036939.00 651914.26 N 70.50791291 W 148.75699630 13706.03 50.93 308.16 8601.71 9975.75 6163.52 -7843.91 1.10 6036984.37 651854.76 N 70.50804017 W 148.75747546 13800.84 50.27 308.44 8661.88 10049.01 6208.93 -7901.40 0.73 6037028.53 651796.30 N 70.50816404 W 148.75794622 ..~ 13896.70 49.46 308.12 8723.67 10122.30 6254.33 -7958.93 0.88 6037072.68 651737.82 N 70.50828791 W 148.75841727 13992.58 48.60 308.00 8786.54 10194.69 6298.96 -8015.93 0.90 6037116.07 651679.87 N 70.50840967 W 148.75888398 14087.22 47.82 309.00 8849.61 10265.25 6342.88 -8071.16 1.14 6037158.79 651623.72 N 70.50852949 W 148.75933617 14181.94 47.15 308.15 8913.62 10335.06 6386.42 -8125.74 0.97 6037201.14 651568.22 N 70.50864826 W 148.75978309 14277.49 46.31 308.37 8979.11 10404.64 6429.50 -8180.37 0.89 6037243.03 651512.69 N 70.50876579 W 148.76023041 14373.53 44.90 308.28 9046.30 10473.26 6472.05 -8234.20 1.47 6037284.42 651457.95 N 70.50888188 W 148.76067123 14467.82 43.44 308.51 9113.93 10538.96 6512.86 -8285.69 1.56 6037324.10 651405.60 N 70.50899319 W 148.76109288 14562.69 42.31 307.76 9183.45 10603.50 6552.72 -8336.46 1.31 6037362.86 651353.99 N 70.50910194 W 148.76150859 14626.58 41.83 307.49 9230.88 10646.31 6578.85 -8370.36 0.80 6037388.26 651319.53 N 70.50917323 W 148.76178622 NS18 ASP Final Surveys2.xls Page 5 of 6 1/16/2003-5:15 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec Nt-S EI-W DLS Northing Easting Latitude Longitude (ft) n (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 14732.87 40.74 306.48 9310.75 10716.43 6621.05 -8426.38 1.20 6037429.24 651262.63 N 70.50928833 W 148.76224489 14828.91 39.20 307.49 9384.35 10778.11 6658.15 -8475.66 1.74 6037465.27 651212.56 N 70.50938955 W 148.76264845 14924.34 37.57 307.00 9459.15 10837.35 6694.02 -8522.83 1.74 6037500.11 651164.64 N 70.50948738 W 148.76303468 15019.68 36.26 308.01 9535.38 10894.61 6728.88 -8568.26 1.51 6037533.98 651118.48 N 70.50958246 W 148.76340670 15114.53 34.76 308.44 9612.59 10949.70 6762.96 -8611.54 1.60 6037567.13 651074.47 N 70.50967544 W 148.76376113 15204.17 34.04 308.82 9686.55 11000.34 6794.58 -8651 .1 0 0.84 6037597.88 651034.24 N 70.50976168 W 148.76408513 15299.96 34.52 308.16 9765.70 11054.29 6828.15 -8693.33 0.63 6037630.54 650991.31 N 70.50985327 W 148.76443096 15394.77 34.92 308.02 9843.63 11108.29 6861.46 -8735.83 0.43 6037662.93 650948.10 N 70.50994414 W 148.76477901 15488.84 35.04 308.01 9920.70 11162.22 6894.68 -8778.32 0.13 6037695.22 650904.91 N 70.51003474 W 148.76512696 15585.09 35.03 307.35 9999.51 11217.48 6928.45 -8822.05 0.39 6037728.04 650860.47 N 70.51012687 W 148.76548508 ~ 15680.74 34.19 306.93 10078.24 11271.80 6961 .26 -8865.36 0.91 6037759.91 650816.47 N 70.51021634 W 148.76583973 15774.89 33.66 307.01 10156.36 11324.33 6992.86 -8907.34 0.56 6037790.59 650773.82 N 70.51030253 W 148.76618352 15870.90 32.78 307.30 10236.68 11376.93 7024.62 -8949.26 0.93 6037821.45 650731.23 N 70.51038917 W 148.76652684 15965.96 30.92 307.04 10317.42 11427.08 7054.93 -8989.23 1.96 6037850.89 650690.62 N 70.51047184 W 148.76685416 16059.32 29.05 306.86 10398.28 11473.73 7082.98 -9026.52 2.01 6037878.13 650652.75 N 70.51054834 W 148.76715951 16155.28 27.61 306.49 10482.75 11519.25 7110.18 -9063.04 1.51 6037904.54 650615.65 N 70.51062253 W148.76745858 16249.90 25.67 305.46 10567.32 11561.65 7135.11 -9097.36 2.11 6037928.72 650580.80 N 70.51069052 W 148.76773967 16344.38 23.99 305.13 10653.06 11601.27 7158.04 -9129.74 1.78 6037950.94 650547.94 N 70.51075304 W148.76800483 16439.46 23.43 305.81 . 10740.12 11639.47 7180.22 -9160.88 0.66 6037972.45 650516.34 N 70.51081354 W 148.76825983· 16488.39 22.70 306.38 10785.14 11658.62 7191.51 -9176.37 t.56 6037983.41 650500.61 N 70.51084433 W 148:76838668 16566.53 22.77 304.65 10857.20 11688.79 7209.05 -9200.95 0.86 6038000.41 650475.66 N 70.51089217 W 148.76858796 16663.54 22.01 305.21 10946.90 11725.69 7230.21 -9231.24 0.81 6038020.91 650444.92 N 70.51094986 W 148.76883607 16757.11 20.59 306.29 11034.08 11759.64 7250.06 -9258.83 1.57 6038040.16 650416.91 N 70.51100399 W 148.76906201 16785.70 20.30 306.29 11060.87 11769.63 7255.97 -9266.88 1.01 6038045.90 650408.74 N 70.51102011 W 148.76912793 16865.00 20.30 306.29 11135.24 11797.13 7272.25 -9289.06 0.00 6038061.70 650386.22 N 70.51106452 W 148.76930954 -- NS18 ASP Final SUNeys2.xls Page 6 of 6 1/16/2003-5:15 PM ANADRILL SCHLUMBERGER Survey report Client. . . . . . . . . . . . . . . . . . .: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Northstar Well.....................: NS18 API number...............: 50-029-23102-00 Engineer.................: M. Leafstedt RIG:.....................: Nabors 33E STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS. . . . . . . . . . .: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference....... ...: Driller's Pipe Tally GL above permanent.......: 15.90 ft KB above permanent. . . . . . .: NA DF above permanent.......: 55.85 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0 . 00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 308.16 degrees [(c)2002 Anadrill IDEAL ID6_1C_I0J 31-Dec-2002 08:12:01 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.. .....: MD of last survey........: Page 1 of 8 Jul-17-2002 31-Dec-02 183 0.00 ft 16865.00 ft .--- ----- Geomagnetic data ---------------------- Magnetic model..... ......: BGGM version 2002 Magnetic date..... .......: 27-Dec-2002 Magnetic field strength..: 1150.98 HCNT Magnetic dec (+E/W-) .....: 26.11 degrees Magnetic dip.............: 80.95 degrees ----- MWD survey Reference Reference G..... .........: Reference H... ....... ....: Reference Dip......... ...: Tolerance of G...........: Tolerance of H....... ....: Tolerance of Dip...... ...: Criteria --------- 1002.69 mGal 1150.98 HCNT 80.95 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.11 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.11 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)... .....: No degree: 0.00 --, ANADRILL SCHLUMBERGER Survey Report 31-Dec-2002 08:12:01 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 0.00 50.00 100.00 150.00 162.00 0.00 0.31 0.33 0.37 0.43 0.99 1.11 1.27 1.76 2.49 3.16 5.63 7.51 9.39 11.78 14.02 17.12 18.42 19.07 21.53 21.44 22.10 23.74 25.30 25.80 28.72 30.78 34.43 36.14 40.72 0.00 38.86 342.08 344.64 348.38 296.50 282.55 284.77 281.26 295.11 291.02 296.77 301.00 304.20 306.19 306.92 308.11 307.73 309.52 312.58 313.01 313.43 312.27 311.90 313.39 310.93 309.26 312.22 313.36 310.89 0.00 50.00 50.00 50.00 12.00 119.00 70.00 90.00 92.00 91.00 36.00 90.00 90.00 90.00 100.00 91.00 97.00 62.00 30.68 98.14 93.07 94.78 95.17 93.83 95.28 94.15 93.61 95.68 95.97 95.10 [(c)2002 Anadrill IDEAL ID6_1C_I0] 281.00 351.00 441.00 533.00 624.00 660.00 750.00 840.00 930.00 1030.00 1121.00 1218.00 1280.00 1310.68 1408.82 1501.89 1596.67 1691.84 1785.67 1880.95 1975.10 2068.71 2164.39 2260.36 2355.46 0.00 50.00 100.00 150.00 162.00 280.99 350.98 440.96 532.93 623.86 659.82 749.55 838.95 927.97 1026.26 1114.96 1208.39 1267.43 1296.48 1388.52 1475.13 1563.15 1650.80 1736.17 1822.13 1905.82 1987.09 2067.68 2146.02 2220.50 0.00 -0.00 0.12 0.37 0.43 1.78 2.98 4.68 6.88 10.05 11.76 18.46 28.63 41.79 60.13 80.44 106.47 125.39 135.25 169.23 203.21 238.22 275.16 314.01 354.97 397.98 444.40 495.88 551.13 610.08 0.00 0.11 0.35 0.64 0.72 1.62 2.04 2.48 3.01 4.13 4.81 7.69 12.71 19.87 30.48 42.59 58.46 70.09 76.25 98.64 121.79 145.87 171.06 197.16 225.00 253.90 283.80 317.48 355.14 394.73 0.00 0.08 0.13 0.04 0.02 -0.99 -2.19 -4.01 -6.38 -9.54 -11.18 -17.43 -26.42 -37.53 -52.52 -68.83 -89.46 -104.39 -112.09 -137.72 -162.74 -188.35 -215.53 -244.43 -274.65 -306.64 -342.18 -381.19 -421.86 -465.72 0.00 0.14 0.37 0.64 0.72 1.90 2.99 4.71 7.06 10.40 12.17 19.06 29.32 42.47 60.72 80.94 106.87 125.74 135.56 169.40 203.27 238.23 275.16 314.04 355.05 398.11 444.56 496.08 551.44 610.50 0.00 38.86 19.84 3.43 1.51 328.51 312.85 301.73 295.29 293.39 293.30 293.81 295.69 297.89 300.13 301.75 303.16 303.88 304.22 305.61 306.81 307.76 308.44 308.89 309.32 309.62 309.67 309.79 310.09 310.28 2 of 8 DLS (deg/ 100f) 0.00 0.62 0.61 0.09 0.55 0.67 0.40 0.18 0.54 0.98 1.94 2.78 2.16 2.15 2.42 2.47 3.21 2.11 2.83 2.73 0.19 0.72 1.79 1.67 0.85 3.32 2.37 4.16 1.91 5.08 ------ ------ Srvy tool type Tool qual type ------ ------ TIP GYR GYR GYR GYR GYR GYR GYR GYR GYR -/ GYR GYR GYR GYR GYR GYR GYR GYR D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG - D-MAG D-MAG D-MAG D-MAG D-MAG ANADRILL SCHLUMBERGER Survey Report 31-Dec-2002 08:12:01 -------- ------ ------- ------ -------- -------- Page ---------------- --------------- ---------------- --------------- -------- ------ ------- ------ -------- -------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 2451.43 2546.90 2642.55 2738.43 2834.14 2927.54 3025.36 3120.67 3214.04 3309.10 3404.87 3499.43 3590.25 3685.92 3781.29 3876.15 3975.52 4191.86 4287.67 4382.39 4477.03 4571.59 4667.63 4761.62 4856.65 4951.25 5046.76 5142.43 5237.81 5333.96 42.96 44.60 47.69 51.03 55.04 55.90 56.14 56.80 56.00 56.61 56.86 58.00 59.23 58.01 57.77 55.29 54.12 53.45 53.34 53.81 53.93 54.12 54.30 53.95 54.31 54.69 55.23 55.56 56.11 56.48 309.43 307.95 306.65 306.94 306.59 307.26 306.26 306.57 307.00 307.00 307.64 308.33 308.98 308.92 308.41 308.63 308.24 305.27 306.42 305.11 305.49 303.99 304.83 303.90 305.15 306.46 307.19 307.82 308.11 307.86 95.97 95.47 95.65 95.88 95.71 93.40 97.82 95.31 93.37 95.06 95.77 94.56 90.82 95.67 95.37 94.86 99.37 216.34 95.81 94.72 94.64 94.56 96.04 93.99 95.03 94.60 95.51 95.67 95.38 96.15 [(c)2002 Anadrill IDEAL ID6_1C_10J 2292.00 2360.92 2427.19 2489.63 2547.17 2600.11 2654.78 2707.43 2759.10 2811.83 2864.37 2915.27 2962.57 3012.38 3063.08 3115.39 3172.80 3300.64 3357.77 3414.01 3469.81 3525.36 3581.53 3636.61 3692.30 3747.23 3802.07 3856.40 3909.96 3963.32 674.05 740.09 809.05 881.77 958.21 1035.13 1116.22 1195.64 1273.38 1352.46 1432.52 1512.21 1589.74 1671.40 1752.18 1831.30 1912.41 2086.86 2163.71 2239.86 2316.20 2392.59 2470.32 2546.31 2623.16 2700.11 2778.29 2857.03 2935.94 3015.93 435.99 477.27 519.05 562.62 608.38 654.61 703.15 750.31 796.88 844.48 893.03 942.07 990.50 1041.85 1092.32 1141.59 1192.01 1296.45 1341.49 1386.03 -514.65 -566.21 -621.08 -679.33 -740.59 -802.10 -867.08 -931.02 -993.30 -1056.47 -1120.15 -1182.95 -1243.50 -1307.01 -1370.09 -1431.99 -1495.52 -1635.33 -1697.67 -1759.51 1430.20 -1821.90 1473.80 -1884.78 1517.83 -1949.05 1560.82 -2011.92 1604.46 -2075.36 1649.52 -2137.81 1696.39 -2200.41 1744.33 -2262.88 1792.88 -2325.09 1842.11 -2388.14 674.51 740.53 809.42 882.06 958.43 1035.31 1116.35 1195.73 1273.45 1352.50 1432.56 1512.24 1589.77 1671.44 1752.23 1831.35 1912.45 2086.88 2163.72 2239.86 2316.20 2392.59 2470.35 2546.36 2623.24 2700.22 2778.41 2857.15 2936.07 3016.05 310.27 310.13 309.89 309.63 309.40 309.22 309.04 308.87 308.74 308.64 308.56 308.53 308.54 308.56 308.56 308.56 308.56 308.41 308.32 308.23 308.13 308.02 307.91 307.80 307.71 307.65 307.63 307.63 307.64 307.65 3 of 8 DLS (deg/ 100f) 2.55 2.03 3.38 3.49 4.20 1.09 0.88 0.74 0.94 0.64 0.62 1.35 1.49 1.28 0.52 2.62 1.22 1.15 0.97 1.22 0.35 1.30 0.73 0.88 1.13 1.20 0.84 0.64 0.63 0.44 ------ ------ Srvy tool type Tool qual type ------ ------ D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG .~ D-MAG D-MAG D-MAG D-MAG D-MAG ANADRILL SCHLUMBERGER Survey Report 31-Dec-2002 08:12:01 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 5429.05 5524.61 5620.82 5716.52 5812.50 5906.45 6001.37 6096.84 6191.43 6287.48 6382.41 6477.00 6573.11 6667.77 6761.25 6858.23 6953.34 7048.34 7142.04 7237.08 7332.53 7428.76 7523.75 7619.07 7714.10 7810.36 7906.00 7998.39 8095.73 8190.23 56.89 57.60 58.07 58.46 58.59 58.55 58.48 58.31 58.09 57.99 57.78 58.05 58.09 57.85 57.65 57.31 57.27 57.34 57.44 57.61 57.83 57.93 58.20 58.33 58.57 58.21 58.17 57.94 57.85 57.62 308.37 309.01 309.31 309.68 309.86 309.30 309.10 309.68 309.60 310.00 310.82 311.01 310.95 310.77 310.29 311.05 310.68 310.67 309.93 309.90 309.98 308.53 306.79 305.21 304.62 302.62 302.96 303.32 303.53 303.76 95.09 95.56 96.21 95.70 95.98 93.95 94.92 95.47 94.59 96.05 94.93 94.59 96.11 94.66 93.48 96.98 95.11 95.00 93.70 95.04 95.45 96.23 94.99 95.32 95.03 96.26 95.64 92.39 97.34 94.50 [(c)2002 Anadrill IDEAL ID6_1C_10J 4015.55 4067.25 4118.47 4168.81 4218.92 4267.91 4317.48 4367.52 4417.36 4468.20 4518.67 4568.92 4619.75 4669.95 4719.83 4771.97 4823.37 4874.68 4925.18 4976.21 5027.18 5078.35 5128.60 5178.74 5228.46 5278.92 5329.33 5378.22 5429.95 5480.40 3095.39 3175.76 3257.19 3338.56 3420.38 3500.52 3581.45 3662.74 3743.11 3824.57 3904.91 3984.96 4066.43 4146.59 4225.58 4307.27 4387.21 4467.08 4545.95 4626.09 4706.75 4788.23 4868.84 4949.85 5030.70 5112.41 5193.33 5271.43 5353.60 5433.26 1891.16 -2450.66 1941.40 -2513.38 1992.83 -2576.53 2044.59 -2639.34 2096.96 -2702.26 2148.04 -2764.04 2199.20 -2826.77 2250.80 -2889.61 2302.08 -2951.52 2354.24 -3014.13 2406.37 -3075.35 2458.85 -3135.91 2512.35 -3197.49 2564.85 -3258.18 2616.22 -3318.27 2669.51 -3380.29 2721.87 -3440.82 2773.98 -3501.45 2825.03 -3561.65 2876.48 -3623.14 2928.28 -3685.01 2979.85 -3748.12 3029.10 -3811.94 3076.75 -3877.52 3123.1Q -3943.93 3168.49 -4012.18 3212.50 -4080.51 3255.36 -4146.15 3300.78 -4214.97 3345.05 -4281.49 3095.51 3175.86 3257.28 3338.64 3420.44 3500.57 3581.50 3662.78 3743.13 3824.58 3904.92 3984.96 4066.43 4146.59 4225.58 4307.28 4387.23 4467.12 4546.00 4626.15 4706.82 4788.31 4868.91 4949.90 5030.73 5112.43 5193.33 5271.43 5353.61 5433.28 307.66 307.68 307.72 307.76 307.81 307.85 307.88 307.92 307.95 307.99 308.04 308.10 308.16 308.21 308.25 308.30 308.35 308.39 308.42 308.45 308.47 308.49 308.47 308.43 308.37 308.30 308.21 308.14 308.06 308.00 4 of 8 DLS (deg/ 100f) 0.62 0.93 0.56 0.52 0.21 0.51 0.19 0.55 0.24 0.37 0.76 0.33 0.07 0.30 0.48 0.75 0.33 0.07 0.67 0.18 0.24 1.28 1.58 1.42 0.59 1.81 0.30 0.41 0.20 0.32 Srvy tool type D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ------ ------ Tool qual type ------ ------ -~- ---- ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 ------ ------- ------ ------- Incl angle (deg) Azimuth angle (deg) 31-Dec-2002 08:12:01 Page ------ -------- -------- ------ -------- -------- ---------------- --------------- ---------------- --------------- Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 8286.77 8381.33 8478.95 8576.15 8666.77 57.80 57.59 57.15 56.81 56.38 56.19 56.19 56.12 56.39 56.22 56.08 55.74 55.39 55.12 54.87 54.60 54.53 54.49 54.25 53.92 53.78 54.07 54.45 54.83 55.36 55.75 56.13 56.71 56.97 57.32 304.13 304.79 305.33 306.29 305.95 308.20 308.94 309.34 310.13 309.26 309.18 309.17 309.14 309.10 309.37 308.88 309.09 309.28 309.16 309.29 309.47 309.11 309.10 309.34 309.71 310.59 310.71 310.84 310.59 310.97 96.54 94.56 97.62 97.20 90.62 96.88 94.92 95.17 95.50 95.62 95.16 95.62 95.41 95.45 94.05 94.83 95.59 94.20 95.42 96.20 94.74 95.17 94.29 95.36 95.06 94.78 94.58 93.80 92.81 95.08 [(c)2002 Anadrill IDEAL ID6_1C_I0J 8763.65 8858.57 8953.74 9049.24 9144.86 9240.02 9335.64 9431.05 9526.50 9620.55 9715.38 9810.97 9905.17 10000.59 10096.79 10191.53 10286.70 10380.99 10476.35 10571.41 10666.19 10760.77 10854.57 10947.38 11042.46 5531.97 5582.50 5635.14 5688.11 5738.00 5791.78 5844.60 5897.60 5950.66 6003.70 6056.71 6110.30 6164.25 6218.65 6272.61 6327.36 6382.78 6437.47 6493.05 6549.48 6605.37 6661.41 6716.49 6771.67 6826.07 6879.68 6932.65 6984.53 7035.29 7086.87 5514.65 5594.41 5676.50 5757.93 5833.53 5914.09 5992.96 6071.99 6151.37 6230.90 6309.91 6389.09 6467.77 6546.19 6623.21 6700.63 6778.50 6855.19 6932.73 7010.63 7087.11 7164.02 7240.54 7318.30 7396.23 7474.35 7552.63 7630.69 7708.31 7788.10 3390.63 -4349.19 3435.85 -4415.09 3483.07 -4482.39 3530.76 -4548.48 3575.35 -4609.59 3623.93 -4673.88 3673.10 -4735.54 3722.99 -4796.85 3773.75 -4857.91 3824.56 -4919.13 3874.53 -4980.35 3924.56 -5041.74 3974.24 -5102.76 4023.73 -5163.61 4072.46 -5223.28 4121.31 -5283.34 4170.31 -5343.88 4218.77 -5403.33 4267.81 -5463.42 4317.08 -5523.78 4365.62 -5582.91 4414.33 -5642.44 4462.60 -5701.83 4511.77 -5762.08 4561.39 -5822.21 4611.78 -5881.95 4662.83 -5941.40 4713.86 -6000.58 4764.54 -6059.47 4816.71 -6119.95 5514.69 5594.47 5676.58 5758.03 5833.65 5914.22 5993.08 6072.10 6151.46 6230.98 6309.99 6389.15 6467.83 6546.24 6623.26 6700.67 6778.54 6855.22 6932.76 7010.65 7087.13 7164.03 7240.55 7318.31 7396.24 7474.35 7552.63 7630.69 7708.31 7788.10 307.94 307.89 307.85 307.82 307.80 307.79 307.80 307.82 307.84 307.86 307.88 307.90 307.91 307.93 307.94 307.96 307.97 307.98 308.00 308.01 308.02 308.04 308.05 308.06 308.08 308.10 308.12 308.15 308.18 308.20 5 of 8 DLS (deg/ 100f) 0.37 0.63 0.65 0.90 0.57 1.94 0.65 0.36 0.74 0.78 0.16 0.36 0.37 0.28 0.35 0.51 0.19 0.17 0.27 0.36 0.21 0.43 0.40 0.45 0.64 0.87 0.42 0.63 0.36 0.50 ------ ----- ------ Srvy tool type Tool qual type ------ ------ D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG .- D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ANADRILL SCHLUMBERGER Survey Report -------- -------- Seq Measured # depth (ft) 121 122 123 124 125 126 127 128 129 130 131 132 133 134 135 136 137 138 139 140 141 142 143 144 145 146 147 148 149 150 ------ ------- ------ ------- Incl angle (deg) Azimuth angle (deg) 31-Dec-2002 08:12:01 ---------------- ------ -------- -------- ------ -------- -------- ---------------- Course length (ft) TVD depth (ft) vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Page --------------- --------------- Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 11139.49 11234.43 11327.46 11425.05 11517.60 11614.52 11711.03 11803.31 11899.19 11994.42 12089.41 12183.86 12278.16 12374.44 12470.34 12566.37 12660.29 12754.37 12848.36 12941.73 13038.40 13135.16 13225.71 13324.37 13419.60 13515.51 13610.21 13706.03 13800.84 13896.70 57.59 57.86 58.10 58.30 58.50 58.61 57.93 57.33 56.78 56.20 55.61 55.03 54.24 53.72 53.82 53.80 53.75 53.99 54.21 54.17 54.31 54.64 54.68 54.13 53.23 52.37 51.78 50.93 50.27 49.46 309.91 310.12 309.49 309.53 309.79 309.92 309.16 308.53 307.19 306.27 305.45 305.67 304.93 305.01 304.80 305.01 305.38 307.03 308.43 308.66 309.03 309.13 308.99 309.58 309.14 308.69 308.95 308.16 308.44 308.12 97.03 94.94 93.03 97.59 92.55 96.92 96.51 92.28 95.88 95.23 94.99 94.45 94.30 96.28 95.90 96.03 93.92 94.08 93.99 93.37 96.67 96.76 90.55 98.66 95.23 95.91 94.70 95.82 94.81 95.86 [(c)2002 Anadrill IDEAL ID6_1C_10J 7139.07 7189.77 7239.10 7290.52 7339.02 7389.58 7440.33 7489.74 7541.88 7594.46 7647.71 7701.45 7756.03 7812.65 7869.33 7926.03 7981.53 8037.01 8092.12 8146.75 8203.25 8259.47 8311.84 8369.27 8425.67 8483.66 8541.87 8601.71 8661.88 8723.67 7869.82 7950.05 8028.90 8111.81 8190.61 8273.26 8355.33 8433.26 8513.72 8593.09 8671.69 8749.28 8826.08 8903.83 8981.07 9058.44 9134.11 9210.05 9286.18 9361.89 9440.33 9519.07 9592.93 9673.14 9749.85 9826.23 9900.93 9975.77 10049.03 10122.31 4869.77 -6182.20 4921.38 -6243.68 4971.87 -6304.27 5024.64 -6368.26 5074.95 -6428.95 5127.94 -6492.42 5180.20 -6555.72 5229.08 -6616.42 5278.47 -6679.95 5325.95 -6743.58 5372.04 -6807.33 5417.20 -6870.52 5461.64 -6933.27 5506.27 -6997.09 5550.54 -7060.53 5594.89 -7124.09 5638.56 -7186.00 5683.44 -7247.31 5730.03 -7307.53 5777.21 -7366.75 5826.41 -7427.84 5876.06 -7488.97 5922.60 -7546.33 5973.40 -7608.42 6022.06 -7667.75 6070.05 6116.88 6163.52 6208.93 6254.33 -7727.19 -7785.39 -7843.91 -7901.40 -7958.93 7869.83 7950.06 8028.91 8111.83 8190.63 8273.29 8355.36 8433.29 8513.75 8593.12 8671.71 8749.29 8826.09 8903.84 8981.07 9058.44 9134.11 9210.05 9286.18 9361.90 9440.34 9519.07 9592.93 9673.14 9749.85 9826.23 9900.93 9975.77 10049.03 10122.31 308.23 308.25 308.26 308.27 308.29 308.30 308.32 308.32 308.32 308.30 308.28 308.25 308.23 308.20 308.17 308.14 308.12 308.10 308.10 308.10 308.11 308.12 308.13 308.14 308.15 308.15 308.16 308.16 308.16 308.16 6 of 8 DLS (deg/ 100f) 0.96 0.34 0.63 0.21 0.32 0.16 0.97 0.87 1.31 1.01 0.95 0.64 1.05 0.54 0.21 0.18 0.32 1.44 1.23 0.20 0.34 0.35 0.13 0.74 1.02 0.97 0.66 1.10 0.73 0.88 ----- Srvy tool type D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ------ ------ Tool qual type ------ ------ .~ .- ANADRILL SCHLUMBERGER Survey Report 31-Dec-2002 08:12:01 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) 151 152 153 154 155 156 157 158 159 160 161 162 163 164 165 166 167 168 169 170 171 172 173 174 175 176 177 178 179 180 Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 13992.58 14087.22 14181.94 14277.49 14373.53 14467.82 14562.69 14626.58 14732.87 14828.91 14924.34 15019.68 15114.53 15204.17 15299.96 15394.77 15488.84 15585.09 15680.74 15774.89 15870.90 15965.96 16059.32 16155.28 16249.90 16344.38 16439.46 16488.39 16566.53 16663.54 48.60 47.82 47.15 46.31 44.90 43.44 42.31 41.83 40.74 39.20 37.57 36.26 34.76 34.04 34.52 34.92 35.04 35.03 34.19 33.66 32.78 30.92 29.05 27.61 25.67 23.99 23.43 22.70 22.77 22.01 308.00 309.00 308.15 308.37 308.28 308.51 307.76 307.49 306.48 307.49 307.00 308.01 308.44 308.82 308.16 308.02 308.01 307.35 306.93 307.01 307.30 307.04 306.86 306.49 305.46 305.13 305.81 306.38 304.65 305.21 95.88 94.64 94.72 95.55 96.04 94.29 94.87 63.89 106.29 96.04 95.43 95.34 94.85 89.64 95.79 94.81 94.07 96.25 95.65 94.15 96.01 95.06 93.36 95.96 94.62 94.48 95.08 48.93 78.14 97.01 ((c)2002 Anadrill IDEAL ID6_1C_l0J 8786.54 8849.61 8913.62 8979.11 9046.30 9113.93 9183.45 9230.88 9310.75 9384.35 9459.15 9535.38 9612.59 9686.55 9765.70 9843.63 9920.71 9999.51 10078.24 10156.36 10236.68 10317.42 10398.28 10482.75 10567.32 10653.06 10740.12 10785.14 10857.21 10946.90 10194.71 10265.27 10335.08 10404.65 10473.28 10538.97 10603.52 10646.33 10716.44 10778.12 10837.37 10894.63 10949.72 11000.36 11054.31 11108.31 11162.24 11217.49 11271.81 11324.34 11376.93 11427.09 11473.73 11519.25 11561.65 11601.27 11639.46 11658.62 11688.78 11725.67 6298.96 -8015.93 10194.71 6342.88 -8071.16 10265.27 6386.42 -8125.74 10335.08 6429.50 -8180.37 10404.65 6472.05 -8234.20 10473.28 6512.86 -8285.69 10538.97 6552.72 -8336.46 10603.52 6578.85 -8370.37 10646.33 6621.05 -8426.38 10716.44 6658.15 -8475.66 10778.12 6694.02 -8522.83 10837.37 6728.88 -8568.26 10894.63 6762.96 -8611.54 10949.72 6794.58 -8651.10 11000.36 6828.15 -8693.34 11054.31 6861.46 -8735.84 11108.31 6894.67 -8778.33 11162.24 6928.45 -8822.06 11217.49 6961.25 -8865.37 11271.81 6992.85 -8907.35 11324.34 7024.62 -8949.27 11376.94 7054.92 -8989.24 11427.09 7082.97 -9026.52 11473.74 7110.17 -9063.04 11519.26 7135.10 -9097.37 11561.65 7158.03 -9129.75 11601.28 7180.21 -9160.89 11639.47 7191.50 -9176.38 11658.63 7209.04 -9200.95 11688.79 7230.20 -9231.25 11725.69 308.16 308.16 308.17 308.17 308.17 308.17 308.17 308.17 308.16 308.15 308.15 308.14 308.14 308.15 308.15 308.15 308.15 308.14 308.14 308.13 308.13 308.13 308.12 308.12 308.11 308.10 308.09 308.09 308.08 308.07 7 of 8 DLS (deg/ 100f) 0.90 1.14 0.97 0.89 1.47 1.56 1.31 0.80 1.20 1.74 1.74 1.51 1.60 0.84 0.64 0.43 0.13 0.39 0.91 0.56 0.93 1.96 2.01 1.51 2.11 1.78 0.66 1.56 0.86 0.81 Srvy tool type D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG D-MAG ------ ------ Tool qual type ------ ------ '- --'" ANADRILL SCHLUMBERGER Survey Report 31-Dec-2002 08:12:01 Page -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Az im (deg) 181 182 16757.11 16785.70 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 308.06 308.06 20.59 20.30 306.29 306.29 Projected to TD 183 16865.00 20.30 306.29 93.57 28.59 11034.08 11060.87 11759.63 11769.61 7250.05 -9258.84 11759.65 7255.96 -9266.89 11769.63 79.30 11135.25 11797.08 7272.23 -9289.04 11797.10 308.06 [(c)2002 Anadrill IDEAL ID6_1C_I0] 8 of 8 DLS (deg/ 100f) ----- Srvy tool type 1.57 D-MAG 1.01 D-MAG 0.06 PROJ ------ ------ Tool qual type ------ ------ -, ---- b.p \ , ) Date: 01-27-2003 Transmittal Number:92613 BPXA WELL DATA TRANSMITTAL Enclosed are the Inaterials listed below. If you have any questions, please contact Ine in the PDC at 564-4091. \..í NS24 12-23-2002 .~~..tlð(P NS24' 12-20-2002 V V NS18 12-31-2002 ANA 0 16865 MWD SURVEY REPORT; éX('}rl,- It/I v HARDCOPY/DISKETTE; NS22 12-12-2002 ANA 1 0 '12486 MWD SURVEY REPORT; ~~~~ \I" HARDCOPY/DISKETTE; NS24 12-20-2002 ANA 1 0 '12607 MWD SURVEY REPORT; ~~JI.o1 v HARDCOPY/DISKETTE; NS~·~ Â~.~~,-v~-c/AW~JVfK}N~FõR-PmMI-~ /' i/ 1/ // MODIFY; N3J-1/}/~ï:JOt.~/L-'l----;~-'·-L.::----l_~---v~~0NlQR-f£RM.IT-T~ Top SW Name Date Contractor Log Run Depth NS07 05-06-200~ SCH 1 11418 dC8--077 NS01 05-06-2002 SCH 11418 ( NS07· 05-06-2002 SCH 11418 V NS07 05-06-2002 SCH 11418 ./ NS07 05-06-2002 SCH 11418 /' NS07 05-06-2002 SCH 11418 /' SCH 1 '1795 ../ SCH 11 350 ~d ~!~~py of this transmittal. Thank You, James H. Johnson Petro technical Data Center Bottom Depth Log Type 11750 GAMMA RAY LOG; MERGED COPY; 11750 PLATFORM EXPRESS; TRIPLE COMBO SSTVD; MERGED COPY; 11750 PLATFORM EXPRESS; NEUTRON/DENSITY; MERGED COPY; 11750 PLATFORM EXPRESS; TRIPLE COMBO; MERGED COPY; 11750 DIPOLE SONIC; MERGED COPY; PLATFORM EXPRESS; HIGH RESOLUTION LA TEROLOG TOOL; '12494 DEPTH DETERMINATION LOG; --- 11750 '12590 REPEAT FORMATION TESTEr..; RECEIVED JAN 31 2003 Alaaka Oil & Gø8 Cons. Comrniaeion And1cnge Pctrotcchnical Data Ccnter LR2-1 900 E. Bcnson Blvd, PO Box 196612 Anchoragc, AK 99519-6612 Perforation intervals for Northstar wells ) ) Subject: Perforation intervals for Northstar wells Date: Fri, 17 Jan 2003 11 :44:09 -0600 From: "Sherritt, Allen" <SherriJA@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Francis, Michael J" <Michael.Francis@BP.com>, "Hernandez, Floyd" <HernanFl@BP.com> Winton, As per our conversation, the following Northstar wells do not have a reference to perforation intervals included in the drilling permits. NS18 ~I..?Z,.... tc.¡./ NS22 NS06 NS20 NS16 NS21 NS19 They all will be perforated within the Ivishak interval: "Perforate -140' Ivishak formation between the Top Ivishak and Owc." "Perforation interval will be based on PE recommendation after completion of well. II The actual perforation depths will be provided in the final well completion reports. If you need any further information, give me a shout. Thanks, Allen Sherritt BP Northstar Operations Drilling Engineer * (907) 564-5204 (Direct) * (907) 240-8070 (Mobile) * sherrija@bp.com * (907) 564-5200 (Fax) * MB 3-6 / 383B ) ) Date: 01-02-2003 Transmittal Number:92451 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS-15 10-11-2002 SCH 2 14420 15100 PERFORATING RECORD; .. ÖìQê) -()5 c¡ NS-15 10-04-2002 SCH 1 15006 15093 PERFORATING RECORD; aoa-05t.J J NS-20 10-22-2002 SCH ~- ,/d~ ... NS-I b I !l-fJ/)-2¿¡jf). 5 ( 1-/ /}..l5-,B /~-t)I-;J.oofJ. S C¡"'J ... fA( ~-I 7 I:J - t:J/.- ?wf), 5 C I'f /' ~... . ~ kOo· ~ lease Sign and Return O~Opy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center 100 15770 ULTRASONIC IMAGER; ~/a, pR'MA~y D¡¡:P'TI-I L~)' d.o~-I \ff /12'»AI!. Y /)E¡.Prfl L,~; a Od-.-/Lf I jJrïJll41412V ¡)t?l'ìN L l'fQ,..; ~D~ -ó? 0 Î I J i-IO I:) /¡f!I&.5- I ç;-B8.s- ¥t:' / "3 '-I t" C' Ken Lemley MB3-6 Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Tim Ryherd (DNR) Attn: Doug Choromanski RECEIVED JAN 0 3 2003 AIasIca Qi¡' & Ga$ W,-,¿. ~mmiaeion Anchorage . ~-'!'Ii Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ') J Date: 12-5-2002 ,'¡Transmittal Number:92602 0,,1 I BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. . Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type NS06 06-07 -2002 SPERRY 100,101, 201 13396.9 MUD LOG - 5" - MD LOG -- SUN 200,300, () .,/ v 400 -; N S06 06-07 -2002 SPERRY 100,101, 201 13396.9 MUD LOG - 2" - TVD LOG C\) SUN 200,300, ~NS06 ,¡' /' 400,401 06-03-2002 SPERRY 1 00,1 01 , 201 13396.9 MUD LOG - 2" - MD LOG SUN 200,300, I 400,401 NS07 05-15-2002 SPERRY 100,200, 201 13529 MUD LOG - 5" - MD LOG SUN 300,400, r;: NS07 v' 500 05-15-2002 SPERRY 100,200, 201 13529 MUD LOG - 2" - TVD LOG 0 SUN 300,400, ( ¡- 500 ßNS07 05-15-2002 SPERRY 100,200, 0 13529 MUD LOG - 2" - MD LOG SUN 300,400, t\) .¡ 500 NS08 03-10-2002 SPERRY 1 ,2,3,4 201 12030 MUD LOG - 5" - MD LOG ~ NS08 SUN 03-10-2002 SPERRY 1 ,2,3,4 201 12030 MUD LOG - 2" - TVD LOG ~NS08 SUN 03-10-2002 SPERRY 1 ,2,3,4 201 12030 MUD LOG - 2" - MD LOG SUN NS12 06-27 -2002 SPERRY 100,200, 201 13135 MUD LOG - 5" - MD LOG C V' SUN 300 -NS12 06-27 -2002 SPERRY 100,200, 201 13135 MUD LOG - 2" - TVD LOG - ,/ SUN 300 , 2J NS12 ./ 06-27-2002 SPERRY 100,200, 201 13135 MUD LOG - 2" - MD LOG lQ SUN 300 NS14 .} q~~béi2õbk) ;Þ,ËßRY 1 ,2,3,4 201 13020 MUD LOG - 5" - MD LOG v' SUN ÒO NS14 02'-09-2002 ,:Sp:ERRY 1 ,2,3,4 201 13020 MUD LOG - 2" - TVD LOG - .¡ SUN - \ Õ NS 141q-~i"t:;( 02.;.09~200~:-US'PERFty; 1 ,2,3,4 201 13020 MUD LOG - 2" - MD LOG ~ ,/ ~~. ~:,~-..,t'";"'.',. '/ SUN NS15 04-13-2002 SPERRY 100,200, 201 15370 MUD LOG - 5" - MD LOG ~ SUN 300,400, ~ NS15 V'" 500 04-13-2002 SPERRY 100,200, 201 15370 MUD LOG - 2" - TVD LOG ~ / SUN 300,400, 0 'â Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ') ') Date: 12-5-2002 Transmittal Number:92602 BPXA WELL DATA TRANSMITTAL 500 NS15 04-13-2002 SPERRY 100,200, 201 15370 MUD LOG - 2" - Mb LOG ./ SUN . 300,400, 500 NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 5" - MD LOG r- ,/' SUN ~ NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 2" - TVD LOG ( ,/ SUN 'ð NS16 07 -15-2002 SPERRY 1,2,3 201 12105 MUD LOG - 2" - MD LOG 0) I SUN NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 5" - MD LOG SUN 200,201 , ./ 300,301 , 400,401 ~NS18 08-06-2002 SPERRY 100,101, 201 16550.4 MUD LOG - 2" - TVD LOG ...... SUN 200,201 , . 300,301, i\5 ~ 400,401 ~NS18 08-06-2002 SPERRY 100,101 , 201 16550.4 MUD LOG - 2" - MD LOG SUN 200,201, \., / ,\ 300,301, 400,401 NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 5" - MD LOG ~ ¡/ SUN 300 ~ NS24 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 2" - TVD LOG ~ NS24 v SUN 300 08-24-2002 SPERRY 100,200, 201 12127 MUD LOG - 2" - MD LOG ~ ( SUN 300 Q~g~m one copy of this transmittal. Thank You, RECEIVED James H. Johnson Petrotechnical Data Center DEC 0 5 2002 Ken Lemley MB3-6 AIIIka Oil , Gal ConI. ConniIIiøn Esther Fueg MB3-6 AniIcøþ Attn: Howard Okland (AOGCC) Attn: Buford Bates (Murphy Exploration Alaska), Inc Attn: Tim Ryherd (DNR) Attn: Doug Choromanski (MMS) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Northstar - SSSV Setting Depths ) ) Subject: Northstar - SSSV Setting Depths Date: Fri, 22 Nov 2002 13:35:25 -0600 From: "Francis, Michael J" <Michae1.Francis@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Holt, Barbara M" <HoltBM@BP.com>, "Sherritt, Allen" <SherriJA@BP.com>, "Hernandez, Floyd" <HernanF1@BP.com>, "Schultz, Mikel" <Mike1.Schultz@BP.com>, "Garing, John D" <GaringJD@BP.com> Winton, Pursuant to our conversation, this note is to inform you that BP will be changing the SSSV setting depths in the following already permitted producer wells: NS24 NS18 z.,oz.... ''1-1 NS16 NS20 NS19 As allowed by Conservation Order No. 458A, these setting depths will be changed to 1000' TVD. Please call if you have any questions or comments, Mike Michael J. Francis, P.E. BP Exploration Alaska, Inc. Senior Petroleum Engineer Phone: (907) 564 -4240 Cell: (907) 529-8678 Fax: ( 90 7 ) 564 - 52 0 0 e-mail: Michael.Francis@bp.com P.O. Box 196612 Anchorage, AK 99519-6612 ), bp I ,1 ) Date: 09-05-2002 Transmittal #92565 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name NS18 !~..~1~1 IDJ.-} 0 J ;b~- J~, NS16 NS06 NS12 ~æ.; ]) 0 Date Contractor Log Run 07~17-2002 SPERRY Bottom Top Depth Depth 05-18-2002 SPERRY 06-07 -2002 SPERRY 06-28-2002 SPERRY ~ú..Ç)Qop_ ) Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Ken Lemley MB3-6 Attn: Esther Fueg MB3-6 Attn: Lisa Weepie (AOGCC) Attn: Doug Choromanski (MMS) Attn: Tim Ryherd (DNR) Attn: Buford Bates (Murphy Exploration) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Log Type END OF WELL REPORT; MUDLOG DATA ASCII FILES; END OF WELL REPORT; MUDLOG DATA ASCII FILES; END OF WELL REPORT; MUDLOG DATA ASCII FILES; END OF WELL REPORT; MUDLOG DATA ASCII FILES; RECEIVED SEP 05 2002 Alaska VI{ & Gas Cons. Ccmmizskm AnchroJge b.Jp ) ) Date: 08-12-2002 Transmittal Number:92561 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top Bottom SW Name Date Contractor Log Run Depth Depth Log Type Ja-Oì7 NS-07 07 -29-2002 SCH 1 13186 13320 PERFORATION RECORD ,¿ NS-07 08-01-2002 SCH 13186 13210 PERFORATION RECORD ~Oó-JO I NS-06 08-03-2002 SCH 1 70 11470 GAMMA RAY/COLLAR LOCATOR LOG œ.- JY l NS18 08-02-2002 SCH SURVEY REPORT - PAPER NS18 08-03-2002 SCH FINAL SURVEY - DISC ~-' ll~ ~~ and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center BP - Ken Lemley Bp - Ester Fueg AOGCC Attn: Howard Oklanà Murphy Exploration (Alaska), Inc. Attn: Buford Bates DNR - Division of Oil & Gas Attn: Tim Ryherd ~·iE.CE:i\fE'-) I,UG 1 t ~Ino~'t MMS Attn: Doug Choromanski ,~:..,,~. ',\ ~ \1.\ i ~~I.:~ C,f,~:.. i ;(;\, \P:~~:h;\. \;-¡r:':¡r.1'ilt'" , BP - SSD - Terrie Hubble to Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 19-6612 NS18 9.5/8" Cement ) , Subject: NS18 9.5/8" Cement Date: Mon, 29 Jul 2002 16:23 :08 -0500 From: "Holt, Barbara M" <HoltBM@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> 2Dl.-/c.// Winton, As discussed over the phone this weekend, the cement volume pumped for the 95/8" casing on NS18 was planned at 555 bbls of lead and 127 bbls of tail. The actual volume pumped was 458 bbls lead and 116 bbls tail. This volume is sufficient to reach 6800' MD, more than adequate to cover the Kuparuk at 14191'MD. Thanks Winton! Barbara M. Holt Northstar Drilling Engineer Office: (907) 564-5791 Cell: (907) 240-8044 ~----._-~."-_.."'..''''''---' . , Name: Blank Bkgrd.gi f; ~Blank Bkgrd.gifi Type: GIF Image (image/gif)\ .."o..o,......,..."^..,.."..,..,,,i~,~~,?~.~~~~..,~..~~~?~,.o,..o.o.."....o'oJ @~®1.1 re @)u~jlJlb ~. ,'""'" r,. -[::J i / i! I 11. iÜ'. ,:.:1: ¡ I ¡ \ ~j . ) ®n@~:y¡® Lrû ~ UL\ Q)J L!~ /A1 ) AI A~KA ORAND GAS CONSERVATION COMMISSION / í I i / / TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Floyd Hernandez Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Northstar Unit NS 18 BP Exploration (Alaska), Inc. Permit No: 202-141 Surface Location: 1219' NSL, 645' WEL, Sec. 11, TI3N, RI3E, UM Bottomhole Location: 3254' NSL, 4676' WEL, Sec. 03, TI3N, RI3E, UM Dear Mr. Hernandez: Enclosed is the approved application for permit to drill the above development well. The 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, c~~;o~ Chair BY ORDER OF THE COMMISSION DATED this ~L day of July, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. , . \kJ 61\ 7/, (!J 0 ~l-. --::JF t{ æf6µ 1<'1 :.< ) STATE OF ALASKA '\ ALASKA\.Ju:' AND GAS CONSERVATION COMMI~JION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 56' Northstar Unit 6. Property Designation ADL 312799 7. Unit or Property Name Northstar Unit 8. Well Number ,./ NS18 9. Approximate spud date 07/17102 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 16930' MD /11136' TVD o 17. Anticipated pressure {s7ð 20 AAC 25.035 (e) (2)} 56.50 Maximum surface 4172 psig, At total depth (TVD) 11080' I 5280 psig Setting Depth T OD Bottom MD TVD MD TVD Surface Surface 201' 201' Driven Surface Surface 4046' 32061 696 sx PF IL', 466 sx Class 'GI Surface Surface 14829' 9331' 962 sx Econolite, 618 sx Class IG' 146791 9218' 16615' 10846' 301 sx Class 'G' 16465' 10709' 16930' 11136' 82 sx Class 'G' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill . 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1219' NSL, 645' WEL, SEC. 11, T13N, R13E, UM At top of productive interval 3169' NSL, 4569' WEL, SEC. 03, T13N, R13E, UM At total depth 3254' NSL, 4676' WEL, SEC. 03, T13N, R13E, UM Number 2S 100302630-277 12. Distance to nearest property line 13. Distance to nearest well /' ADL 312798, 4123' MD (Approx.) No Close Approach 16. To be completed for deviated wells Kick Off Depth 600' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade CouDlina 20" 169# X-56 WELD 13-3/8" 68# L-80 BTC 9-518" 47# L-80 BTC-Mod 7" 26# L-80 Hydril521 4-1/2" 12.6# 13Cr Vam Ace Hole 20" 16" 12-1/4" 8-112" 6-1/8" LenQth 201' 4046' 14829' 1936' 465' Quantitv of Cement (include staae data) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD ~) U,·'" .t"" ~.~ W , ' ~- [) , ~""'~ ~.- ~ t ',. ~ \. ~- 1\,«, L, ~ :j t"" , Perforation depth: measured ¡¡II ',~ I.... :.. 1:-; tJ002 ,J L. '." true vertical Alaska Oi! & Gas Gons. l:ormmssaof' Anchorage 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Barbara Holt, 564-5791 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that th~, f o~>~ a~e best of my ~nowl~~ge . Signed FIoydHemand~. W~.,."". Title SenlorDnlllngEnglneer Date, ~f.o~ ,\":,:),,;,,'j¡''}./:i,~;/:!,:J;':<~ ,:'::,:',' ",':', '::, '" '<; ,:':""I,I\,~"'.('º,,'i~.,,:';':~~:,:::~::, c' ", I Permit Number API Number 3//'\ ~p~roval Date See cover letter -<.a z -/7" / 50- cr ¿ 7' - 2- v 2-- '1/4 to ;)- for other reQuirements Conditions of Approval: Samples Required 0 Yes .21 No Mud Log Required 181 Yes Id No Hydrogen Sulfide Measures 0 Yes g.No Directional Survey Required BI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: per 'Z..o Me. 2.'5. O~~ (k.)l2.) I tU" ~~ "('~¿J ~ M »-Ut-vV't wtc..(' \I~d . r L..~ .t- t~Ç> E l-o 41\90 r?.>¿, bt order of I f Approved By \JnwM..r.ï '~/~' Commissioner the commission Date 1- C1 0 d- Form 10-401 Rev. 12-~-85 , Submit In Triplicate ) ) bp .,. .\1,.,,,. -...~..,~. ~......- ~...- ~...~ ..~ ~.. ·'i'.~\~" ".~ BP Exploration Alaska Inc. To: Winton Aubert - AOGCC Date: July 3,2002 From: Barbara M. Holt Northstar Operations Drilling Engineer Subject: NS18 Application for Drilling Permit Mr. Aubert, NS18 is currently scheduled for Nabors 33E on July 1ih, 2002. / A Diverter waiver is also requested on NS18. To date, BP has drilled thirteen development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. Twelve 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 one well extending into the SV5 -3280' TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. NS18 will perform an "Operation Shutdown'/during the 2002 Seasonal Drilling Restriction period. A Sundry for the Operation Shutdown will not be submitted, as the operations are covered in the ADP procedure. Please find attached the NS18 Well Plan Summary, directional plan and proposed completion diagram. If you should have any questions or concerns, please contact me @ 564-5791. lbi cerely, ,~ .. . '4'--,:,/ . ,¿tu)///Þ-& Barbara M. Holt BP Northstar Operations Drilling Engineer 564-5791 " ) ) NS18 SUMMARY DRilliNG OPERATIONS Pre-Ria Work: 1. Set 20" conductor and weld an ABB Vetco landing ring for the ABB Vetco Multibowl Wellhead on the conductor. (Already performed.) 2. Install 7' x 7' cellar and polyshield same. (Already performed.) Ria Operations: 1. MIRU Nabors 33E. 2. Nipple up and function test 21-1/4" diverter syste~, if required. NOTE: A diverter dispensation has been requésted. 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 +1-150' TVD below the top of the SV6 marker at approximately 3777' MD. Surface casing point has been picked at 4046' /' MD. POOH. 4. Run 13-3/8", 68# surface casing. Cement the casing to surface in 1 stage. A TAM port collar will be run at +/- 1600' MD. In the event the cement does not circulate to surface, this port collar will be ~ízed to ensure a successful cement job is performed. / 5. i D d1verter I riser system and NU casing I multi-bowl wellhead. NU BOPE and test to 3,50/4800 psi. 6. ul12-1/4" directional assembly. RIH to float collar. Test the 13-318" 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. (FITILOT procedure on file with AOGCC). 8. Drill 12-1/4" intermediate hole to casing point (approximately 14829' MD) at the top of the Miluveach. Minimum mud weight of 9.6 ppg at the top of HRZ and 10.3 ppg at the top of Kuparuk. POOH. (No logs will be run, unless the Kuparuk is oil bearing.) 9. Run 9-5/8", 47# intermediate casing. Cement the casing to the top of the SV2 sand in 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" directional assembly and RIH to float collar. Pressure-test the 9-5/8" casing to 4100 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 9-518" shoe and perform a FIT to a 14.0 ppg EMW, (FIT/LOT)*ocedure on file with AOGCC). 12. Weight up to 12.9 ppg prior to drilling ahead. Drill the drilling liner hole to the top of the Sag at approximately 16581' MD. Intermediate casing point has been picked at 16616' MD. POOH. 13. Run and cement a 7" 26# drilling liner. Displace cement with 12.9-ppg mud. Set the liner hanger and liner top packer. Circulate excess cement from well bore. 14. Pressure-test the liner top packer and casing to 1500 psi (11.8 ppg equivalent) 15. Circulate to clean 8.65 ppg seawater, using spacers as per Baroid recommendation. 16. Shut down and monitor the well for a minimum of 30 minutes (negativyest on liner top). 17. POOH and lay down liner running tools. Test 9 518" x 7" liner to 4800 psi for 30 minutes (MMS - 70% of burst), will need to wait 8 hrs for cement to build SOO-psi compressive strength. RIH to 100' below the base of permafrost and circulate 6.8 ppg diesel to freeze protect the well to surface. POOH. 18. Prepare for l'Operations Shutdown. (June 1st Seasonal Drilling Restriction)" 19. Install 4 %" tubing hanger and test to 5000 psi. 20. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. 21. Install (dry rod in) BPV and test. Ensure all valves are closed. RD and move off well. 22. Prepare to re-enter well post "Seasonal Drilling Restriction." / " NS18 Permit to Drill ) ) 23. MIRU Nabors 33E. / 24. Pull BPV. Install TWC. ND tree. NU BOPE and test to 250/4800 psi. 25. RIH wI 6-1/8" directional assembly to approximately 2000' MD..v1)isplace diesel with seawater, (see diesel handling procedure). Test 9 5/8" x 7" liner to 4800 psi for 30 mins. RIH to 7" liner top. Displace seawater to 9.3 ppg mud. Clean out 7' liner to the landing collar, 26. Drill out remaining cement. Drill 20' of new formation below 7" shoe with 9.1 ~.. mud. Perform a Formation Integrity test to 11.5 ppg. (FIT/LOT procedure on file with AOGCC). /' 27. Drill 6-1/8" production interval to the proposed TD at 16930' MD. Increase mud weight to 9.3 ppg prior to POOH. 28. Make a clean out run, if required, and condition the hole for a liner. POOH. // 29. Run and cement the 4-112" 12.6# 13Cr liner with an inner string. Set the liner hanger and liner top packer. Circulate a minimum of 1 bottoms up to remove excess cement 9.3 ppg viscosified brine. 30. Pressure-test the It· /~r, packer and casing to 1500 psi (11.8 ppg equivalentV' 31. Circulate to clean eaw er using spacers as per Baroid recommendation. 32. Shut down and mo ·t r the well for a minimum of 30 minutes (negative test on liner top). 33. POOH. Close the blind rams and pressure-test the liner lap to 3400 psi with 9.3-ppg fluid in the well for 30 minutes. Prepare to run the 4 %" completion. No slick line work will be done. 34. Run the 4 %", 13Cr Vam Ace completion assembly with CIDRA fiber optics. The fiber optic cable will be run from packer setting depth to surface. 35. RIH to packer setting depth. Dual SSSV control lines will be run from the SVLN at +/- 2000' TVD (2084' MD) to surface. 36. Run space out pups and terminate the 2 - 0.25" control lines 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. 37. Pump corrosion inhibitor and heated diesel down the 4 %" x 9 5/a" annulus equivalent to the annulus capacity plus tubing capacity to a depth of 4000' TVD (5484' MD). RU the U-tubing manifold and allow the Freeze Protection fluid to u-tube through the GLM lower, -7500 MD. 38. Drop ball and rod to set packer. Increase the tubing pressure to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg completion fluid and hold for 30 minutes. Monitor tubing pressure for leaks. Record on chart. 39. Bleed tubing to 3000 psi and maintain during MIT. Pressure test annulus to 4200 psi (maximum anticipated surface pressure) with 8.65-ppg-completion fluid for mechanical integrity test (MIT). Monitor tubing pressure for leaks. Maintain pressure for 30 minutes and record as annulus test on chart. Email or fax chart to Drilling Engineer. 40. Bleed down the annulus to 3500 psi. Bleed down the tubing to 0 psi. This will shear the RP valve in the lower most GLM. 41. Bleed off annulus to 0 psi. Allow fluids to U-tube from the annulus into the tubing. /' 42. Set the TWC. ND BOP's. NU Tree. Test the tubing head adapter and tree to 5000 psi. 43. Install and test (dry rod in) BPV. Ensure all valves are closed. RD and move off well. Estimated Spud Date: July 17th, 2002 Barbara M. Holt Operations Drilling Engineer 564-5791 2 NS18 Permit to Drill ) ) NS 18 WELL PLAN SUMMARY 1 Type of Well (producer or injector): Northstar Slot: Surface Location: I Producer NS18 121" FSL, 645' FEL, Sec. 11, T13N, R13E, UM X = 659829 Y = 6030991 3169' FSL, 4569' FEL, Sec. 3, T13N, R13E, UM X = 650466 Y = 6038028 10,815' TVDrkb 3254' FSL, 4676' FEL, Sec. 3, T13N, R13E, UM X = 650357 Y = 6038110 11,136' TVDrkb 1 AFE Number: 1 NSD831319 1 Rig: 1 Nabors 33E 1 1 Estimated Start Date: 17/17102 / 1 Operating days to complete: 139.7~· I 1 MD: 116,930 I 1 TVDrkb: 111,136 1 1 RKB/Surface Elevation: (a.m.s.I.) 156.0' /15.9' 1 1 Well Design (conventional, slimhole, etc.): I Modified Big Bore 1 I Objective: I Ivishak Producer with fiber optic surveillance control line I Target (top of SAG): 400' Radius Bottom Hole Location: Well Name: API Number: Well Type (proposed): BHP: EMW: BHT: MECHANICAL CONDITION: Cellar box: RKB to Cellar box: Rig Elevation: Conductor: NS18 Producer 5175 psi @ 11,100' TVDss 8.96 ppg 254 OF @ 11,100' TVDss Elevation above MSL = 15.9' 40.1' (Estimated) RKB + MSL = 56.0' 201' MDrkb of 20", 169#, X-56 (pre-driven) 3 NS18 Permit to Drill '} ) MUD PROGRAM: Suñace Hole Mud Properties: Seawater Spud Mud 16" Hole Section From Surface to -4046' MD /3206' TVD (-150' TVD below top SV6). Interval Density Viscosity YP Tauo Gel APIFL pH (ppg) (seconds) 10 sec Initial 8.8-9.0 100 - 200 50 - 70 >8 25 - 40 15 - 20 8.5 - 9.5 from -1555' *9.0 - 9.5/ 100 - 200 30 - 45 >6 15 - 25 4-10 8.5 - 9.5 SV6 @ Interval TD *9.5 75 -100 20 - 35 >6 10 - 25 4-10 8.5 - 9.5 * Should gas hydrates be encountered, mud densities up to 10.2 ppg may prove necessary. Intermediate Hole Mud Properties: Seawater Polymer 12-1/4" Hole Section From Surface Casing Shoe to 14,829' MD /9331' TVD (-65 below top Miluveach). Interval Density (ppg) PV YP Tauo Initial 8.7 - 9.3 10 -16 20 - 30 4-7 Top HRZ 9.6 ' 10 - 16 20 - 25 4 - 7 Top Kuparuk to Miluveach 10.3 / 10 - 18 20 - 28 4 - 7 API I HTTP FL 6 -10 4-6/ <12 4-6/ <12 pH 8.5 - 9.5 8.5- 9.5 8.5- 9.5 Drilling Liner Hole Mud Properties: Inhibited KCL 8-112" Hole Section From Intermediate Casing Shoe to 16,615' MD /10,846' TVD (top of Sag) Interval Density (ppg), PV YP Miluveach & Kingak to top of Sag 12.9 7 10 - 25 20 - 25 Tauo 4-7 APIFL 4-6/ <10 pH 8.5 - 9.5 Production Hole Mud Properties: SeawaterlCaC03 Drill-In Fluid From Intermediate Casing Shoe to 16,930' MD /11,136' TVD Interval Density (ppg) PV YP Initial/Final 9.1 - 9.3 /' 8 - 12 20 - 25 6-1/8" Hole Section Tauo API FL 4-7 3-5 pH 8.5 - 9.5 DIRECTIONAL:(P6) KOP: Maximum Hole Angle: Close Approach Wells: Survey Program: ±600' MD Cantenary curve 1.0°/100' to 2.50°/100' build ±56.50° No surface collision issues. NS17 - planned well, not yet drilled. NS19 - planned well, not yet drilled. Gyro will be used for initial surveys and kickoff Gyros as required from surface to +/-1600'. Standard MWD surveys from +/-1600' to TD. ../ SURFACE AND ANTI-COLLISION ISSUES: Well NS18 has passed major risk on all existing wells. All wells pass the major risk rule. Gyros will be run from surface to -1600' MD or until reliable MWD surveys can be taken. See Anti-collision Report in directional (P6) attachment for summary of allowable deviations. Suñace Shut-in Wells: See Northstar Anti-Collision and Well Shut-In checklist. 4 NS18 Permit to Drill ) ') LOGGING PROGRAM: 16" Section: Drilling: GRlDirectional - Gyro as needed to -1600' MD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology description Open Hole: None Cased Hole: None 12-1/4" Section: Drilling: GRlDirectional, Resistivity (real-time) from top Colville to TD, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology description Open Hole: PEX and RFT's - Contingent on oil being present in the Kuparuk. Cased Hole: None 8-1/2" Section: Drilling: GRlDirectional, PWD Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology description Open Hole: None Cased Hole: None 6-1/8" Section: Drilling: GRlDirectional; Resistivity, Density, Neutron (recorded) Mud Logging - Gas analysis/detection, show kit with indexed sample bottles, lithology description Open Hole: None Cased Hole: None Intearitv Testina: Test Point Depth Shoe Test Type FIT FIT FIT EMW Estimated Casing/Liner Test 3500 psi w/ 9.3 ppg 4100 psi w/10.1 ppg 4800 psi w/12.9/8.65 3400 psi w/9.3 ppg 12 X" Surface 95/8" Intermediate 7" Drilling Liner 4 %" Production Liner 20' min from 12 1/4" shoe 20' min from 9 518" shoe 20' min from 7" shoe 12.5 ppg EMW Target 14.0 ppg EMW Target 11.5 ppg EMW Target CASINGITUBING PROGRAM: / Hole Size Casing/ WtlFt Grade Conn. Casing Casing Top Hole Btm Tbg O.D. Length MDITVDrkb MDITVDrkb 20" 20" 169# X-56 WELD 201' Surface 201'/201' 16" 13 318" 68# L-80 BTC 4046' Surface 4046'/3206' 12 %" 9 5/8" 47# L-80 BTC-Mod 14829' Surface 14829'19331 ' 8%" 7" 26# L-80 Hydril 521 1936' 14679'/9218' 16615'/10846' 6-1/8" 4-1/2" 12.6# 13Cr Vam Ace 465' 16465'110709' 16930'/11136' Tubing 4-1/2" 12.6# 13Cr Vam Ace 16465' Surface 16465'110709' 5 NS18 Permit to Drill ) ) FORMATION MARKERS: TVDss MDrkb Pore Press. Comment Formation Top estimated (Psi) I (ppg EMW) Top Permafrost 1,149 1,209 542 8.65 Base Permafrost 1,519 1,598 708 8.65 SV6 - top confining zone 3,002 3,777 1375 8.65 Set surface casing -150' tvd Surface casing point 3,150 4,046 0 0.00 below top SV6 SV5 - base confining zone 3,250 4,227 1487 8.65 SV4 3,554 4,777 1623 8.65 SV2 - top upper injection zone 3,955 5,504 1804 8.65 SV1 - top major shale barrier 4,425 6,355 2015 8.65 TMBK - top lower injection zor 4,697 6,848 2137 8.65 WS1 - top Schrader Bluff - Ba~ 6,232 9,629 2828 8.65 CM3 - Base lower injection zor 6,813 10,682 3089 8.65 Fault "26" - throw = 75' 8,050 12,923 THRZ - Top HRZ 8,599 13,866 3893 8.65 BHRZ - Base HRZ 8,695 14,013 3936 8.65 Top Kuparuk 8,795 14,163 4265 9.33 Kuparuk C 8,966 14,409 4428 9.50/ Top Miluveach 9,230 14,769 4333 9.03 Set intermedate casing into the Intermediate casing point 9,275 14,829 0 0.00 top of the Miluveach Intermediate logging point 9,275 14,829 0 0.00 / Top Kingak 9,678 15,340 4690 9.32 Top Sag River 10,759 16,581 5033 8.95 Geol target #1 10,759 16,581 4992 8.92 400' radius Set drilling liner into top Sag River to cover Kingak. Intermediate casing point 10,790 16,615 0 0.00 Hydrocarbon bearing. Top Shublik - 90 10,825 16,653 5064 8.95 Top Ivishak 10,915 16,750 5105 8.95 TD - - 20' above OWC. Total Depth 11 ,080 16,930 5182 8.95 Oil- Water contact 11,100 5192 8.95 Top Kavik 11 ,255 5264 8.95 Total Depth 11,080 16,930 5180 8.95 Top Lisburne 11 ,424 5484 9.19 / 6 NS18 Permit to Drill REQUIRED MATERIALS: L-80 Surface: L-80 Intermediate: L-80 Drlg Liner: 13Cr Liner: 13Cr Completion: ') 4046' 1 - 13 3/8" 1 - 13 3/8" 1 - 13 318" 17 -133/8" x 15314" 1 - 20" x 13 3/8" 1 - 13 5/8" 14829' 1 - 9 5/8" 1 - 9 5/8" 1 - set 1 - 13 5/8" x 9 5/8" 227 - 9 5/8" x 12" 1936' 1-8%" 1-7" 1-7" 6 - 7" x 8 1/4" 1 - 7" x 9 5/8" 1 - 7" x 9 5/8" 1 -7" 1 - 7" 465' 1 - 4-1/2" 1 - 4-112" 22 - 4-1/2" x 5-3/4" 22- 4-1/2" x 5-3/4" 1 - 4-112" x 7" 1 - 4-1/2" x 7" 1 - 4-1/2" 16465' 1 1 1 1 1 1 1 1 1 2 1 ') 13318",68# L-80 BTC HES Super Seal II Float Shoe (4.25" valve) HES Super Seal II Float Collar (4.25" valve) TAM Port Collar SV Rigid Centralizers ABB-VGI Fluted hanger - BTC down, 11 %" external ACME landing thread ABB-VGI Casing HeadlTbg head 95/8",47# 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 7", 26# L-80 Hydril 521 BBL reamer shoe HES Super Seal II Float Shoe HES Super Seal II Float Collar SV Rigid Centralizers Baker Flex Lock Hydraulic Set Liner Hanger Baker ZXP Liner Top Packer Baker HRD running tool Baker Landing Collar and plug set 4-1/2", 12.6# 13Cr-80 Vam Ace HES Super Seal II Float Shoe H ES 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 Vam Ace 4 %" ABB-VGI tubing hanger 4 %" ABB-VGI adapter flange 4 %" ABB-VGI5-1/8" 5K Swab Valve wI tree cap CIDRA mandrel and 0.25" fiber optic cable (wI 4 %" cable clamps). 4 %" SVLN and 2 - 0.25" control lines 4 %" x 1 %" GLM with dummy valve installed 4 %" x 1 %" GLM with RP Shear valve installed 7" x 4 %" Baker 13 Cr packer S-3. 4 %" WLEG (w/o holes) 4 %" 13 Cr X nipples 4 %" 13 Cr XN nipple 7 NS18 Permit to Drill ) ') PERMAFROST: The 13-3/8" surface casing will be run approximately 16001 TVD below the permafrost to -4046' MD I 3206' TVD. The casing will be cemented to surface with a Premium 'G' with 2% calcium chloride tail slurry and a 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: The following cement calculations are based upon a single stage job. Casing 113-3/8" Surface I Basis: Stage 1: lead: Based on 200' cased hole capacity from surface to 200' MD, 1399' of Open Hole + 175% excess from the permafrost to surface + 50% excess to 750'MD above the shoe. lead TOC: Surface Tail: Based on 750' of 16" open hole x 13 3/8" casing with 50% excess + 80' shoe joint. Tail TOC: -3292' MD I Total Cement I Spacer Preflush Spacer Lead 20 bbl sea water 75 bbl Alpha ~cer weighted to 1.0 ppg over mud weight 515 bbl/696 sk 12888 ft of 10.7 ppg Permafrost 'l' Cement. 4.15 cf/sk, BJ;!ST 50° I. BHCT 50°, TT = 6.0 hrs 96 bbll 466 sk I 541 ffS of 15.8 ppg Premium 'G' wI 2% CaCI2. 1.16 cf/sk, BHST 50° I BHCT 50°, TT = 4.0 hrs Tail Casing 19-518" Intermediate Basis: Stage 1: lead: Based on 7659' of 12 1/4" open hole x 9 5/8" csg with 30% excess lead TOC: At -5504' MD (4010' TVD) Tail: Based on 1666' of 12 X" open hole x 9 5/8" csg with 30% excess + 80' shoe joint. Tail TOC: At -13162' MD (8238' TVD) IStage 1: Total Cement I Spacer Preflush 20 bbls sea water Spacer 50 bbl Alpha Spac,er weighted to 1.0 ppg over mud MW lead 555 bbl I 962 ski'3117 ft of 11.2 ppg Econolite. 3.24 cf/sk, BHST 210° I BHCT 130°, TT = 4.0 hrs Tail 127 bbl/618 s0711 ffS of 15.9 ppg Premium 'G'. 1.15 cf/sk, BHST 210° I BHCT 130°, TT = 4.0 hrs Casing 17" Drilling Liner Basis: Stage 1: Slurry: Based on 1786' of 8 112" open hole x 7" csg with 50% excess + 150' 95/8" csg x 7" csg liner lap + 200' 9-5/8" csg x 5" drillpipe above TOl + 801 shoe joint. Slurry TOC: At -146791 MD (9218' TVD) Stage 1: Total Cement I Spacer Spacer 50 bbl Alpha SP5lcer ~eighted to 1.0 ppg over mud MW Slurry 82 bbl/301 sk1452 ft;j of 15.9 ppg Premium 'G'. 1.50 cf/sk, BHST 250° I BHCT 150°, TT = 4.0 hrs Casing 14-112" Prod Liner Basis: Stage 1: Slurry: Based on 315' of 6 118" open hole x 4 1/2" csg with 50% excess + 150' 7" csg x 4 1/2" csg liner lap + 200' 7" csg x 4" drillpipe above TOl + 80' shoe joint. Slurry TOC: At -16465' MD (10709' TVD) Stage 1: Total Cement I Spacer Spacer 35 bbl Alpha ~acer weighted to 1.0 ppg over mud MW Slurry 22 bbl/82 sk 1123 ft,j of 15.9 ppg Premium 'G'. 1.50 cf/sk, BHST 250° I BHCT 150°, TT = 4.0 hrs 8 NS18 Permit to Drill ) ) WELL CONTROL: ~ A diverter waiver is also requested on NS18. To date, BP has drilled thirteen development wells through the Northstar upper strata-graphic intervals and has not experienced any difficulty with shallow gas. Twelve 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 one well extending into the SV5 -3280' TVDss. Well mud logs and seismic data do not indicate the presence of a shallow gas hazard. ~ Equipment to be Installed and 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. Surface Section: · Maximum anticipated BHP: 1375 psi @ 3002' TVDss - SV6 · Maximum surface pressure: 1075 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Intermediate Section: · Maximum anticipated BHP: 4428 psi @ 8966' TVDss - Kuparuk 'c' · Maximum surface pressure: 3532 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Drilling Liner Section: · Maximum anticipated BHP: 5033 psi @ 10759' TVDss - Sag River · Maximum surface pressure: 3957 psi @ surface (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) Production Section: · Maximum anticipated BHP: 5280 psi @ 11080' TVDss - Total Depth · Maximum surface pressure: 4172 psi @ surface / (Based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 4800 psi (annular to 3500 psi) /' · Planned completion fluid: 8.5 ppg Seawater /6.8 ppg Diesel DRILLING HAZARDSICONTINGENCIES: HYDROGEN SULFIDE - H2S: ./ Northstar is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should 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-01 I 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 II fluids will be processed by the Grind and Inject Facility on Nabors 33E and will be disposed of in the Northstar NS10 Class I Waste Disposal Well. 9 NS18 Permit to Drill ) ') SURFACE HOLE SECTION: · Mudloggers will be rigged up throughout the entire section. · No significant drilling problems have been identified in the surface hole interval based on offset data. Good hole cleaning and management of required mud properties are key to a successful interval. · Minor tight hole conditions have been noted in the shale intervals immediately below the permafrost during short trips. · Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud. · Lost circulation has only been noted while drilling during hole opening runs and was most likely induced by poor hole cleaning. Losses have occurred while running and cementing surface casing. The NS27 experienced losses on the surface cement job at a rate of 12 BPM. The displacement rate was lowered to 10 BPM and full returns were re-established. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. Minor losses were seen on NS29 while running the 13 3/8" surface casing. Reduced running speed eliminated losses and the casing was cemented at 10 BPM displacement rate. · Gas hydrates may be present near the base of the permafrost. Wells drilled in the 2000-2002 drilling season have not experienced hydrates. Mudloggers will be used continuously on NS18 to help identify and trend any increase in background gas readings. 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. INTERMEDIATE SECTION: · Mudloggers will be rigged up throughout the entire section. · Minor gas shows have been reported in the four (4) Seal Island wells and have been identified as coal associated methane. No indications of shallow gas were seen while drilling during the 2000-2002 drilling season. Mudloggers will be used continuously on this well to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. A minimum of 9.0 ppg is recommended. · The shallow intervals beneath Northstar are, by interpretation, not faulted. To 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. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the well bore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. · Differential sticking can be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable SV Sands. · Gas in the Kuparuk is likely (5000 unit mud log show in NS13). Circulate as required. High mud weight should minimize the gas entry from the Kuparuk. · Oil is not expected in the Kuparuk, however, if oil is found be prepared to run wireline logs to evaluate. · A small possibility exists that fault #26 will be penetrated at approximately 12092' MD; however, the intent is to miss the fault. 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 kick tolerance for the 12 114" open hole section would be 95.9 bbls assuming an influx from the Kuparuk interval at -8851 TVD. This is the worst-case scenario based on a 10.0 ppg (0.5 ppg over the known pore pressure) pore pressure gradient, a fracture gradient (FIT) of 12.5 ppg at the 13-318" shoe, and 10.3 ppg mud in the hole. 10 NS18 Permit to Drill ) '). DRilliNG liNER SECTION: · Mudloggers will be rigged up throughout the entire section. · Pressure While Drilling (PWD) will be used to monitor the annular pressure. The pressure data will be used to minimize the equivalent circulating density (ECD), minimize lost circulation due to packing off due to loading up the wellbore with solids and provide for an additional well control tool to make sure the well does not become under-balanced. · Gas in the Sag is possible. Circulate as required. According to Geology, the top of the Sag is poor, not porous/permeable rock. This, along with the higher mud weight should minimize the gas in the top of the SAG. · The kick tolerance for the 8-1/2" open hole section is infinite (due to limited amount of open hole) assuming an influx from the Sag River interval. This is the worst-case scenario based on a 9.8 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 14.0 ppg at the 9-5/8" shoe, and 12.9 ppg mud in the hole. PRODUCTION SECTION: · Mudloggers will be rigged up throughout the entire section. Gas in the Sag River or Ivishak will be circulated out as required. · The drilling liner shoe will be drilled out with the 12.9 ppg mud. The mud will then be displaced with a 9.1 ppg drill-in fluid. The mud weight will be increased to 9.3 ppg prior to tripping out of the hole. · Differential sticking is not anticipated but the drill string should not be left stationary for any length of time. · Losses are not expected but calcium carbonate (CaC03) will be maintained in the system. Severe lost circulation was encountered on the NS29. · The Ivishak is a conglomerate section. Directional control will be maintained with MWD surveys to minimize doglegs. · The well is planned to stop short of the OWC. The Kavik will not be penetrated. The project Geologist will be in charge of picking TD above the OWC and sufficient rathole will be drilled. · The kick tolerance for the 6 1/8" open hole section is infinite (due to limited amount of open hole) assuming an influx from the proposed TD. This scenario is based on a 9.62 ppg (0.5 ppg over the anticipated pore pressure) pore pressure gradient, a fracture gradient of 11.5 ppg (based on FIT) at the 7" shoe, and 9.1 ppg mud in the hole. 11 NS18 Permit to Drill ) ) NS18 Ria-site Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE ~ Gas hydrates may be present near the base of the permafrost. Mudloggers will be used continuously on NS18 to help identify and trend any increase in background gas readings. 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. ~ 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. ~ 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 previously drilled Northstar wells. Mudloggers will be used continuously on NS18 to help identify and trend any increase in background gas readings. Surface casing will be set prior to any intervals with previously noted gas shows to facilitate nippling up the BOP's. ~ 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 %" assembly to the Top Sag to allow an appropriate cushion for mud weight increases in the Jurassic shale interval. To be prepared for any potential lost circulation I 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. ~ 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. ~ Northstar is not a designated H2S pad. ~ CONSULT THE NORTHSTAR PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 12 TREE: ABB-VGI 5 1/8" 5ksi WELLHEAD: ABB-VGI 13-5/8" Multibowl 5ksi )NS18 - Proposed 13 3/8" TAM Port Collar at +1-1600'MD 13 3/8", 68#/ft, L-80, BTC @ 4046' MD ~ 41/2", 12.6#/ft, 13-Cr, Vam-Ace TUBING ID: 3.958" .. CAPACITY: 0.01522 BBLlFT 9-5/8" 47# L-80 BTM-C @ 14829' MD ~ ~- 4.5" X NIPPLE, @ 16415' MD 3.813" ID 4.5" X NIPPLE, @ 16435' MD 3.813" ID 4.5" XN NIPPLE, @ 16445' MD 3.725" ID 4.5" WLEG, @16455' MD 3.958" ID - J B 7", 26#/ft L-80, Hydril 521 @ 16615' MD ~ PBTD @ 16890' MD TD @ 16930' MD j DATE 7/3/02 REV. BY BMH COMMENTS ~~ 18 proposed .. O"'-~NAL KB. ELEV = 56' Kl 1=. ELEV = 40;1' CB. ELEV = 15.9' '1 1/2" SSSV @ 2000' TVD wI HXO SVLN nipple - 4.562" ID 6.8PPG DIESEL FREEZE PROTECTION AT +1- 4000' TVD (5484'MD) .. 41/2" GLM @ 4500' TVD (6389' MD) wI 4.62" ID 4 1/2" GLM @ 5113' TVD (7500' MD) wI 4.62" ID .l\. - 7" LINER TOP @14679' MD ~ I ~ 4.5" Fiber Optic Transducer 3.958" ID 4.5" LINER TOP @ 16465' MD 4.5",12.6#, 13Cr Vam Ace Northstar WF. . : NS18 API NO: BP Exploration (Alaska) õ I KBE Bid 1/100 Bid 1.75/100 Bid 2.5/100 Top Permafrost Base Permafrost Report Date: Client: Field: Structure I Slot: Well: Borehole: UWIIAPI#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location LaULong: Location Grid N/E Y/x: Grid Convergence Angle: Grid Scale Factor: NS18 Schlumberger Proposed Well Profile - Geodetic Report July 3, 2002 Survey I DlS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Northstar t dy Vertical Section Origin: Northstar PF / NS18 b-I-It)f 5 U TVD Reference Datum: NS18 F 51- I TVD Reference Elevation: NS 18 e8 Sea Bed I Ground level Elevation: 50-029- Magnetic Declination: NS18 (P6) S15 / July 3,2002 Total Field Strength: 89.998° / 11849.33 ft / 6.210/1.064 Magnetic Dip: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: N 70.49121354, W 148.69330448 Magnetic Declination Model: N 6030991.320 ftUS, E 659828.760 ftUS North Reference: +1.23170237° Total Corr Mag North -> True North: 0.99992902 Local Coordinates Referenced To: Minimum Curvature / Lubinski 308.160° S 50.290 ft, E 1.410 ft KB 55.8 ft relative to MSL 15.670 ft relative to MSL 26.269° 57542.807 nT 80.944° July 25, 2002 BGGM 2002 True North +26.269° Well Head - Grid Coordinates Geographic Coordinates MD I Incl I Azim I TVD I vSec NJ-8 I EI·W I DlS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS) 0.00 0.00 308.16 0.00 32.18 0.00 0.00 0.00 6030991.32 659828.76 N 70.49121354 W 148.69330448 600.00 0.00 308.16 600.00 32.18 0.00 0.00 0.00 6030991.32 659828.76 N 70.49121354 W 148.69330448 700.00 1.00 308.16 699.99 33.05 0.54 -0.69 1.00 6030991.85 659828.06 N 70.49121502 W 148.69331013 800.00 2.75 308.16 799.94 36.33 2.56 -3.26 1.75 6030993.81 659825.45 N 70.49122054 W 148.69333113 900.00 5.25 308.16 899.69 43.30 6.87 -8.74 2.50 6030998.00 659819.87 N 70.49123231 W 148.69337593 1000.00 7.75 308.16 999.04 54.62 13.86 -17.64 ~50 6031004.80 659810.83 N 70.49125141 W 148.69344868 1100.00 10.25 308.16 1097.80 70.26 23.53 -29.94 2.50 6031014.20 659798.32 N 70.49127782 W 148.69354922 1200.00 12.75 308.16 1195.78 90.20 35.85 -45.62 2.50 6031026.18 659782.38 N 70.49131148 W 148.69367739 1209.22 12.98 308.16 1204.77 92.25 37.11 -47.23 2.50 6031027.40 659780.75 N 70.49131492 W 148.69369055 1300.00 15.25 308.16 1292.80 114.39 50.79 -64.64 2.50 6031040.71 659763.05 N 70.49135229 W 148.69383287 ~ 1400.00 17.75 308.16 1388.68 142.79 68.34 -86.97 2.50 6031057.77 659740.35 N 70.49140024 W 148.69401540 1500.00 20.25 308.16 1483.22 175.34 88.45 -112.57 2.50 6031077.32 659714.32 N 70.49145517 W 148.69422467 1598.39 22.71 308.16 1574.77 211.37 110.71 -140.89 2.50 6031098.97 659685.53 N 70.49151598 W 148.69445617 1600.00 22.75 308.16 1576.26 211.99 111.09 -141.38 2.50 6031099.34 659685.04 N 70.49151702 W 148.69446017 1700.00 25.25 308.16 1667.60 252.66 136.22 -173.36 2.50 6031123.77 659652.52 N 70.49158567 W 148.69472159 1800.00 27.75 308.16 1757.09 297.27 163.79 -208.44 2.50 6031150.58 659616.86 N 70.49166099 W 148.69500836 1900.00 30.25 308.16 1844.54 345.75 193.74 -246.56 2.50 6031179.70 659578.11 N 70.49174280 W 148.69531997 2000.00 32.75 308.16 1929.80 398.00 226.02 -287.64 2.50 6031211.09 659536.35 N 70.49183098 W 148.69565579 Station ID NS18 (P6) report.xls Page 1 of 3 7/3/2002-12:34 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec I NI-S EI-W I DLS Northing Easting _ Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (o/10Oft) (ftUS) (ftUS)- 2100.00 35.25 308.16 2012.70 453.91 260.56 -331.61 2.50 6031244.67 659491.65 N 70.49192534 W 148.69601523 2200.00 37.75 308.16 2093.08 513.39 297.31 -378.38 2.50 6031280.41 659444.;11> N 70.49202573 W 148.69639757 2300.00 40.25 308.16 2170.79 576.32 336.19 -427.85 2.50 6031318.21 659393.81 N 70.49213193 W 148.69680198 2400.00 42.75 308.16 2245.68 642.57 377.13 -479.95 2.50 6031358.02 659340.85 N 70.49224377 W 148.69722790 2500.00 45.25 308.16 2317.60 712.03 420.04 -534.57 2.50 6031399.74 659285.32 N 70.49236098 W 148.69767442 2600.00 47.75 308.16 2386.43 784.57 464.86 -591.60 2.50 6031443.32 659227.35 N 70.49248341 W 148.69814065 2700.00 50.25 308.16 2452.04 860.03 511.48 -650.94 2.50 6031488.65 659167.02 N 70.49261076 W 148.69862577 2800.00 52.75 308.16 2514.28 938.29 559.83 -712.47 2.50 6031535.67 659104.47 N 70.49274283 W 148.69912880 2900.00 55.25 308.16 2573.06 1019.18 609.81 -776.08 2.50 6031584.26 659039.81 N 70.49287935 W 148.69964885 End Bid 2949.95 56.50 308.16 2601.08 1060.53 635.36 -808.59 2.50 6031609.11 659006.76 N 70.49294914 W 148.69991464 SV6 3777.36 56.50 308.16 3057.77 1750.48 1061.64 -1351.11 0.00 6032023.60 658455.24 N 70.49411346 W 148.70435032 - 13-3/8" Csg pt 4045.50 56.50 308.16 3205.77 1974.08 1199.79 -1526.92 0.00 6032157.93 658276.52 N 70.49449078 W 148.70578787 SV5 4226.67 56.50 308.16 3305.77 2125.15 1293.13 -1645.71 0.00 6032248.68 658155.76 N 70.49474570 W 148.70675921 SV4 4777.44 56.50 308.16 3609.77 2584.43 1576.88 -2006.84 0.00 6032524.59 657788.64 N 70.49552063 W 148.70971230 SV2 5503.95 56.50 308.16 4010.77 3190.24 1951.18 -2483.19 0.00 6032888.53 657304.39 N 70.49654277 W 148.71360794 SV1 6355.47 56.50 308.16 4480.77 3900.30 2389.89 -3041.51 0.00 6033315.11 656736.81 N 70.49774070 W 148.71817443 TMBK 6848.26 56.50 308.16 4752.77 4311.23 2643.78 -3364.63 0.00 6033561.98 656408.33 N 70.49843392 W 148.72081747 WS1 9629.29 56.50 308.16 6287.77 6630.25 4076.57 -5188.08 0.00 6034955.14 654554.64 N 70.50234525 W 148.73573622 CM3 10681.91 56.50 308.16 6868.77 7508.01 4618.88 -5878.26 0.00 6035482.45 653853.01 N 70.50382536 W 148.74138451 Fault 26 Crossing 12923.03 56.50 308.16 8105.77 9376.82 5773.51 -7347.72 0.00 6036605.14 652359.18 N 70.50697609 W 148.75341299 Drp 1/100 13230.99 56.50 308.16 8275.75 9633.62 5932.17 -7549.64 0.00 6036759.41 652153.91 N 70.50740898 W 148.75506613 13300.00 55.81 308.16 8314.18 9690.94 5967.58 -7594.70 1.00 6036793.84 652108.10 N 70.50750559 W 148.75543505 13400.00 54.81 308.16 8371.10 9773.16 6018.38 -7659.35 1.00 6036843.24 652042.38 N 70.50764419 W 148.75596437 13500.00 53.81 308.16 8429.44 9854.37 6068.56 -7723.21 1.00 6036892.03 651977.46 N 70.50778109 W 148.75648722 13600.00 52.81 308.16 8489.19 9934.56 6118.10 -7786.26 1.00 6036940.20 651913.36 N 70.50791625 W 148.75700345 13700.00 51.81 308.16 8550.33 10013.69 6166.99 -7848.48 1.00 6036987.74 651850.11 N 70.50804963 W 148.75751289 13800.00 50.81 308.16 8612.84 10091.74 6215.22 -7909.86 1.00 6037034.64 651787.71 N 70.50818121 W 148.75801546 c~ Top HRZ 13865.89 50.15 308.16 8654.77 10142.57 6246.62 -7949.82 1.00 6037065.17 651747.09 N 70.50826687 W 148.75834265 13900.00 49.81 308.16 8676.71 10168.69 6262.76 -7970.36 1.00 6037080.86 651726.21 N 70.50831091 W 148.75851083 14000.00 48.81 308.16 8741.90 10244.51 6309.61 -8029.98 1.00 6037126.42 651665.60 N 70.50843872 W 148.75899900 Base HRZ 14013.45 48.67 308.16 8750.77 10254.62 6315.85 -8037.93 1.00 6037132.48 651657.52 N 70.50845574 W 148.75906410 14100.00 47.81 308.16 8808.41 10319.19 6355.74 -8088.70 1.00 6037171.27 651605.91 N 70.50856457 W 148.75947981 Top Kuparuk 14162.69 47.18 308.16 8850.77 10365.40 6384.30 -8125.04 1.00 6037199.04 651568.97 N 70.50864248 W 148.75977737 14200.00 46.81 308.16 8876.22 10392.69 6401.15 -8146.49 1.00 6037215.42 651547.16 N 70.50868845 W 148.75995301 14300.00 45.81 308.16 8945.29 10464.99 6445.83 -8203.34 1.00 6037258.87 651489.37 N 70.50881034 W 148.76041852 NS18 (P6) report.xls Page2of3 7/3/2002-12:34 PM Grid Coordinates Geographic Coordinates Station ID MD I Incl I Azim TVD I VSec I N/-S I EI·W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 14400.00 44.81 308.16 9015.62 10536.08 6489.75 -8259.24 1.00 6037301.57 651432.54 N 70.50893015 W 148.76087625 Kuparuk C 14408.66 44.72 308.16 9021.77 10542.18 6493.52 -8264.04 1.00 6037305.24 651427.66 N 70.50894044 W 148.76091556 14500.00 43.81 308.16 9087.18 10605.93 6532.91 -8314.17 1.00 6037343.54 651376.70 N 70.50904789 W 148.76132605 14600.00 42.81 308.16 9159.95 10674.53 6575.29 -8368.10 1.00 6037384.75 651321.87 N 70.50916350 W 148.76176766 14700.00 41.81 308.16 9233.90 10741.84 6616.88 -8421.03 1.00 6037425.19 651268.07 N 70.50927696 W 148.76220109 TMLV 14769.22 41.12 308.16 9285.77 10787.67 6645.19 -8457.06 1.00 6037452.71 651231.44 N 70.50935419 W 148.76249614 14800.00 40.81 308.16 9309.01 10807.85 6657.66 -8472.93 1.00 6037464.84 651215.31 N 70.50938820 W 148.76262609 9-5/8" Csg pt 14828.68 40.52 308.16 9330.77 10826.54 6669.21 -8487.63 1.00 6037476.07 651200.36 N 70.50941971 W 148.76274647 14900.00 39.81 308.16 9385.27 10872.54 6697.63 -8523.80 1.00 6037503.70 651163.59 N 70.50949724 W 148.76304266 15000.00 38.81 308.16 9462.64 10935.89 6736.77 -8573.61 1.00 6037541.76 651112.96 N 70.50960401 W 148.76345056 15100.00 37.81 308.16 9541.11 10997.88 6775.07 -8622.35 1.00 6037579.00 651063.41 N 70.50970848 W 148.76384969 - 15200.00 36.81 308.16 9620.65 11058.49 6812.52 -8670.01 1.00 6037615.42 651014.96 N 70.50981064 W 148.76423999 15300.00 35.81 308.16 9701.23 11117.70 6849.10 -8716.57 1.00 6037650.98 650967.63 N 70.50991042 W 148.76462128 Top Kingak 15340.02 35.41 308.16 9733.77 11141.00 6863.50 -8734.89 1.00 6037664.99 650949.00 N 70.50994970 W 148.76477131 15400.00 34.81 308.16 9782.83 11175.50 6884.81 -8762.01 1.00 6037685.71 650921.43 N 70.51000783 W 148.76499341 15500.00 33.81 308.16 9865.43 11231.86 6919.64 -8806.33 1.00 6037719.57 650876.38 N 70.51010284 W 148.76535636 15600.00 32.81 308.16 9949.01 11286.77 6953.56 -8849.51 1.00 6037752.55 650832.48 N 70.51019537 W 148.76570998 15700.00 31.81 308.16 10033.52 11340.22 6986.59 -8891.53 1.00 6037784.67 650789.76 N 70.51028546 W 148.76605411 15800.00 30.81 308.16 10118.96 11392.19 7018.69 -8932.39 1.00 6037815.88 650748.23 N 70.51037302 W 148.76638873 15900.00 29.81 308.16 10205.29 11442.65 7049.87 -8972.07 1.00 6037846.20 650707.89 N 70.51045807 W 148.76671370 16000.00 28.81 308.16 10292.49 11491.60 7080.12 -9010.56 1.00 6037875.61 650668.76 N 70.51054058 W 148.76702893 16100.00 27.81 308.16 10380.53 11539.02 7109.42 -9047.85 1.00 6037904.10 650630.85 N 70.51062050 W 148.76733433 16200.00 26.81 308.16 10469.38 11584.90 7137.76 -9083.92 1.00 6037931.66 650594.18 N 70.51069780 W 148.76762973 16300.00 25.81 308.16 10559.02 11629.22 7165.15 -9118.77 1.00 6037958.29 650558.75 N 70.51077251 W 148.76791515 16400.00 24.81 308.16 10649.42 11671.97 7191.56 -9152.39 1.00 6037983.97 650524.58 N 70.51084455 W 148.76819050 16500.00 23.81 308.16 10740.56 11713.14 7216.99 -9184.75 1.00 6038008.70 650491.68 N 70.51091391 W 148.76845553 Top Sag River 16580.86 23.00 308.16 10814.76 11745.25 7236.84 -9210.01 1.00 6038028.00 650466.00 N 70.51096805 W 148.76866242 ~' Target 815 16580.87 23.00 308.16 10814.77 11745.26 7236.84 -9210.01 1.00 6038028.00 650466.00 N 70.51096805 W 148.76866242 7" Csg pt 16614.54 23.00 308.16 10845.77 11758.42 7244.97 -9220.36 0.00 6038035.90 650455.48 N 70.51099023 W 148.76874718 Top Shublik 16652.57 23.00 308.16 10880.77 11773.27 7254.15 -9232.04 0.00 6038044.83 650443.61 N 70.51101527 W 148.76884285 Top Ivishak 16750.34 23.00 308.16 10970.77 11811.48 7277.75 -9262.08 0.00 6038067.78 650413.07 N 70.51107964 W 148.76908888 TO /4-1/2" Csg pt 16929.59 23.00 308.16 11135.77 11881.51 7321.03 -9317.15 0.00 6038109.86 650357.08 N 70.51119769 W 148.76953992 Leaal Description: Northina (Y) rftUSl EastinQ IX) rftUSl Surface : 1218 F8L 645 FEL S11 T13N R13E UM 6030991.32 659828.76 Target 815 : 3169 F8L 4569 FEL 83 T13N R13E UM 6038028.00 650466.00 BHL: 3254 F8L 4676 FEL 83 T13N R13E UM 6038109.86 650357.09 N818 (P6) report.xls Page 3 of3 7/3/2002-12:34 PM ò 0- 2500 --- ~- ~æ 8~ 1.0 Q) C'\I > II ~ .E CO 5000 T"""~ -....... .c:f': õ.1.O Q)!£. om -~ co .2 t ia:: > > Q) Q) :JW ~ t- 7500 L - 10000 == - , -2500 0 Fault 26 Crossing - fi - =~~ãžTVD-+ - - - - i 9377 departure I , , - -V~....' -- - --~."..:.1::~~;~ , ~ D6a4 departure i ~: =~~~331TVD ¡ , . 40~52° 308.16" az ¡ fi;~ = d ~ '~~~ 7" Csg Pt 16615MD 10846TVD 23.00" 308~ 16" az ¡ 11758 departure :m /k1~sG:Ì't = ï693O'M1J111"36 TVD - 23.000 308,16"iaz 11882 departure; I 15000 VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: NS18 (P6) Field: Northstar Structure: Northstar PF Section At: 308.16 deg Date: July 03, 2002 BId 1/100600 MP 600 TVD / O.cK)" 308,16" aiz 32 departure / __ Bid 1.75/100700 MD 700 TVO ::::=---- UK)" 308.1E!- az 33 departure Bid 2. 5/1 OQ 800 MO 800 TVD _ _ 2250 _308f.6" ~ 36_~r=- ----- -¡TopperÍiÏafrost 1209 MD 12õ5 TVO ~ , ï L ~ . TBaSePeÏiñafrõšt 1598MO 15751Vo- - ~V/r3777 MlJ3058 TV!) - - TSV54227MD3306TVD - - lSv44717 MD 361õ rVõ - SV2 - ssõ4 MD 4011 TVD ~V1-6355MD44š1TŸÕ !1MBK 684a MD 4753 NO- i.. Hold Angle 56.~O° - w.31 š629MO 62aaTvO- -'- - cM3 100a2-;Mo 6a69TVD - - - ~ - - - ::ròp:aRZ438$ MD: a6S5 TJ;lD - ~~1~3 ~ ~1 ~::ïop:B:upa::r¡,k :B161:MiL~~ Kuparuk C 1«09 MO 9022 TVD ' TMLV1476'9,jr¡ fQã6 NO - - Top RíngaK 1~Om:> 9734ì'VD- ~~ ~eIf!6~ M!!: 1~5:!:YD:::r~~k ~¡Äom,w, == Top Ivishak 16750 MO 10971 TVD ¡ ------ ------ ------ Hold Angle 23~OO° I 10000 ì 2500 , 5000 I 7500 -i -;. I 12500 Vertical Section Departure at 308.16 deg from (-50.3, 1.4). (1 in = 2500 feet) Schlumberger - - - - "-' ò -12000 8000 -, I I TD 14-112"' C~ PI 16930MD '1136TVD 23.00' 308.36" az "'" "r ! T' Csg PI I 16615MD .10846t 23,00· 30816· az 7245 N 9220 W ! ^ ^ 6000- ^ I ..... 0:::: o Z 4000 - I 2000 - ..... => 0 en V V V 0- I î ! ì I ! i I ! I ~ I I -12000 -10000 PLAN VIEW Client: Well: Field: Structure: Scale: Date: BP Exploration Alaska NS18 (P6) Northstar Northstar PF 1 in = 2000 ft 03-Jul-2002 Schlumbørgør -10000 -8000 -6000 , -4000 , -2000 2000 I ---L- -- True North Mag Dee ( E 26.270 ___ _________h_ i ~---- Drp 1/100 3231 MD f276 TVD 56,50' 308.116" az 5932 N 7siJW i Fault 26 Crossing , !12923MD-61ÓfftvD-- ---¡---.~--.- I 56.50' 308,16" az . 5774N 7348W -------------- --. --H----r- .L'Óh, ~--·----I------------~--- I "4. ' j ~ . ~,,~ Ö>Oc9 ·'6'0 13~'CsgPl 4045 MD 3206 TVD ---/~~~;;~:~- ...- l\ ' 56.50" 308,16" az .'-. 635 N 809 W L::>...;,. BId 2.5/100 800 MD 800 TVD 275' 308.16" az 3N 3W Bid 1.75/100 700 MD 700 TVD 1.00' 308.16" az 1 N 1 W / Bid '/100 600 MD 600 TVD 0.00' 308,16" az ON OE I -8000 -6000 «< WEST o I 2000 I -4000 -2000 EAST »> .-- - 8000 '- u._ 6000 --..--- - 4000 .-- --- 2000 --- --- - 0 ) Schlumberger Anticollision Report ';J:)~~,;,:,,'~'3i2Q,Ø~ ',:\', ";i'i~e:,' '1#:'þÖ:4;t:' ':", 'P.g~::" : I"~;"~ :,I,;C "il i" i." ,";',,,,, ,"~I; "':1 I,: ',,1',' ""'," >" <",:, ", ',i" ,: I, ':.' ' ,I"~ 'Ç~4Ørdbt~~,(~):'ª~f~~ee;' ...')Nell:',NS1~,T:ruEl, North '::' ':~~~.e~:(1'YDle."fere~ee:,::."i,:N~~E~~,a:,·,·":~'I:"·· .,,', , I,' ',' '" , "~I : ',";:',,.,,, "',"".'i':."'i,,:i'.'.' ,,,r'",I,:il'·,: " "Db:," ISýbåse: ' Reference: Principal Plan & PLANNED PROGRAM Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing C()n1pany:, , ,f3P ~()C::Ò' . Field: . , , " ." ~Qr1ti~ta~," ReferenctfSite: 'INorthstarPF' Ref~r~nceWeµ:,"iN~t~ ",.'. I'."".:': . : ReferençeW~llpat~:'pl~n'~S1.~ :::,;.'...:,:",11 '. ",.: 1,1,:::,,:',lt, ¡ I ~ 'I' I I I I . " , 'I ' ';:"','1,';'. NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 40.20 to 16951.72 ft Maximum Radius: 2000.00 ft Survey Program for Definitive Well path Date: 11/1/2000 Validated: No Planned From To Survey ft ft 40.20 1100.00 Planned: Plan #6 V1 1100.00 16929.59 Planned: Plan #6 V1 Casing Points MI> rVo. :Ði:~~et~~ ' ,ft , ,,',ft ,'I I ' ,in, 4045.50 3205.77 13.375 16.000 13 3/8" 14828.68 9330.77 9.625 12.250 95/8" 16614.54 10845.77 7.000 8.500 7" 16929.59 11135.77 4.500 6.125 41/2" Summary ,,"< Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Northstar PF Seal Island Seal Island Seal Island Seal Island Seal Island Version: 7 Toolcode CB-GYRO-SS MWD Tool Name 0) Camera based gyro single shots MWD - Standard 'O"SetW~llp~tlal"'1 ",,""1'> ,. , " ,:'g~f~~~"~:II(:)f(liet' "C~G,," No~ 'weir' ..../.':.' "'::~~~!ii':'i::¡;, 'If!':ii,~'.gi;i~f~;"i~'~"::' 750.00 131.03 17.10 650.00 122.48 13.07 200.00 112.28 4.94 700.00 104.24 13.76 750.00 92.53 13.67 750.00 67.08 12.99 600.00 71.54 13.90 800.00 60.88 16.29 700.00 53.07 13.09 650.00 37.12 12.99 750.00 32.38 14.81 400.00 22.12 9.67 650.00 9.93 7.09 750.00 9.75 6.42 350.00 30.64 9.13 700.00 41.35 16.14 950.00 57.79 20.25 1150.00 53.91 35.75 1200.00 62.68 20.53 950.00 87.40 18.95 1250.00 77.04 26.78 400.00 110.95 8.52 1100.00 120.47 21.62 1600.00 273.85 32.59 1650.00 254.54 33.27 1649.98 256.39 31.27 1600.00 260.13 28.17 1600.00 313.05 31.76 NS05 NS06 NS07 NS08 NS09 NS10 NS11 NS12 NS13 NS14 NS15 NS16 NS17 NS19 NS21 NS22 NS24 NS25 NS26 NS27 NS28 NS29 NS31 SEAL-A-01 SEAL-A-02 SEAL-A-02 SEAL-A-03 SEAL-A-04 Plan NS05 V1 0 Plan: PI NS06 V32 NS07 V33 NS08 V18 NS09 V14 NS10 V17 Plan NS11 V7 Plan: Pia NS12 V21 NS13 V12 NS14 V11 NS15 V19 NS16 V31 Plan NS17 V6 Plan: Pia Plan NS 19 V1 Plan: Pia Plan NS21 V39 Plan: PI Plan NS22 V2 Plan: Pia Plan NS24 V6 Plan: Pia Plan NS25 V3 Plan: Pia NS26 V22 NS27 V29 Plan NS28 V1 Plan: Pia NS29 V22 NS31 V14 SEAL-A-01 V4 SEAL-A-02 VO SEAL-A-02A V4 SEAL-A-03 V4 SEAL-A-04 V4 747.30 648.92 199.59 698.43 747.56 748.38 599.68 796.36 698.93 649.74 749.32 399.73 649.94 750.52 349.99 700.45 951.08 1152.54 1203.76 951.41 1254.10 399.59 1104.64 1623.66 1674.19 1673.95 1624.70 1630.61 :AU9w¡aÞI~ '", .:',"/i,I, '1,1' D~viati9~ I i"~ar,iM,':)\::;'" ' ,:1 ftll I ~,.,:.:,:.,:I,'::',."II"."",,":<\..!I\, ,.'.",'. ",;' I' ;'"1",1 .. 1111", 113.93 109.41 107.35 90.48 78.86 54.14 57.64 44.59 39.97 24.13 17.57 12.47 2.84 3.33 21.51 25.20 37.54 18.18 42.20 68.46 50.32 102.43 98.86 241.58 221.61 225.46 232.28 281.62 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Minor 1/200 Pass: Minor 1/200 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Site: Northstar PF ) Drilling Target Conf: 90%' Description: Map Northing: 6038028.00 ft Map Easting : 650466.00 ft Latitude: 70030'39.485N Shape: Circle Target: S 15 r '\ NS18,NS20 . .,Æt on: Planned Program Vertical Depth: 10759.00 ft below Mean Sea Level Local +N/-S: 7236.83 ft Local +E/-W: -9209.99 ft Longitude: 148°46'07.185W Radius: 400 ft __ .... ..._., ._.... '__n__....__.._.",,__,_.__ ,__ .".._ __.._..____._.."_"._._._...__._._..__~___,,_____.__..._"'_".~.__,_..__..____ . _______._.,,_,__....~ _____.__"~,___._..__._..__R___.~.__..·__."..____.._.__._..___.....,..__..,._"__~._____..'__.__ . .~--,--~..._._......_-'._._-,-_.._--_._-._-----_._----- .--- 000 l800 l500 l4-00 l200 lOOO 5800 5500 0 CJ CJ CJ CJ CJ CJ CJ o 0 CJ CJ CJ CJ CJ CJ CJ o ~ LO -=I- N CJ m LO -=I- 0 o ~ u u u u m m m 0 ~ I I I I I I I / ~ / / 0 I -I 206931 DATE INVOICE / CREDIT MEMO :;/23/02 CK052302N v1~ l B : ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY ) DESCRIPTION Permit To Drill Fee DATE CHECK NO. ) OS/28/02 H206931 GROSS VENDOR DISCOUNT NET $100.00 Pis call Terrie Hubble X4628 TOTAL ~ RECEIVED JUL 5 2002 Alaska on & Gas Cons. Commission Anchonge $100.00 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 2 ass 31 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 --¡:j'2 'P.'..... tJ,<.:.'.:....·..· . <.....:,...' .,-(.,... i'''', ,I,m" ¡f""" .r~ .·1;,.'·'.'.' LJ r -.u j . I f I lI,r ...~ ·1·' './ .... ...... 'U" 'W' 'onlll ........ "~;;;. TO THE ORDER OF A;laskë3.0il& Ga~ fonse.rva tioI)..Comínissi~n '333 W 7th Aye , . Ste 100 Ancho~ag~1 AK 99501 :". .:.',: AMOUNT :·DATE> ,2002** ··,~~***$foo.oo**,***** NorVALlD AFTER 120 DAYS :,'::::: :". "":':;,;. ".:: < .n..".......,'.··........:.····. ...............,.........,.............".......,.......:....,.....'..,............:........:. "..,...,....,..................,.,..,........:..,. '''''.'''.':-.' \4.~(!;¡fK~ ',1,' ",. " " , : , . . '._~ .. _....... í~"." \J> ~ . III 2 0 b t¡ 3 ~ III I: 0 l. ~ 2 0 3 a c¡ 5 I: 0 0 a ... l. ~ c¡ III '~.' '. -, ~." "..~ c CHECK 1 ST ANDARD LETTER DEVELOPMENT x DEVELOPMENT REDRILL EXPLORA TION INJECTION WELL INJECTION WELL REDRILL Rev: 6/18/02 C\jody\templates ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /I~S' - /<{ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CL UE" The permit is for a new well bore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-> SPACING EXCEPTION DRY DITCH SAMPLE Enclosed is the approved application for permit to driH the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. pt -/1 WELL PERMIT CHECKLIST COMPANY.8fI X WELL NAME¡fI~~ Ú PROGRAM: Exp _ Dev X Redrll _ Se~ _ Wellbore seg _ Ann. disposal para req --:- FIELD & POOL ..t;90/C!Jö INITCLASS c~J/ I-"y,/I GEOLAREA ?tt1 UNIT# IJ.r~^ ON/OFFSHORE øff ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Iv)N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . ( Y \ N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y \¡ 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~.f.R J?~9 12. Permit can be issued without administrative approval.. . . . . Y N If/Y- :ff/¿?7..,. 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided . . . . . . . . . . . . . . . . . .. 1 N 'l...O L( G2 Wt I 15. Surface casing protects all known USDWs. . . . . . . N nI i '- . 16. CMT vol adequate to circulate on conductor & surf csg. . N. ~dÆ'/"'" ~U 0i CRS ç 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ U 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N Ai&[ £0 r~ , "56 . 21. If a re-drill, has a 10-403 for abandonment been approved. . . '~^,/ft 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . @ N 23. If diverter required, does it meet regulations . . . . . . . . .. '+~ Wt:Ú.\J it"" VV1UPc;.~d 24, Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . N P II 7 2. ;. ,11 -/lA. . ~ 1-: t I I JJ þ'-P~.R. D^TE 26. BOPE press rating appropriate; test to 4- ~()c? psig. ,N It( Ç...,,-I f~ I /lv~. Cß;c. ¥> (' -ó {)O f Ç..(', \4út\ 1[3{ 02. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ( 28. Work will occur without operation shutdown. . . . . . . . . . . 11 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . . @ N 31. Data presented on potential overpressure zones. . . . ... )YN /7) /7. 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y ,/ \.....', r-¡ . A~?B ~~~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ;rÆ' 7~¿ ~ 34. Contact namelphone for weekly progress reports [exploratory onr Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPc/f? JDH ::fÞF ¡(jJ¿ WGA vJG/r GEOLOGY APPR DATE //~ ~7~ ( /LI, /i Commentsllnstructions: COT , DTS 07/0 lÒ? G:\geology\permits\checklist. doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly gemìane to the Well Pennitling Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding infomìation, information of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically '. organize this category of information. , &09 '-JLf ( HALLIBURTON Sperry-Sun BP EXPLORATION ALASKA END OF Wr::LL f{EfJORl" NORTI~ISTAR NS18 c; ,', t~ECE\VED ,~t, Y Z ß (oo~ All}ftk! (ttll~ {~a5 coos. (À)mm¡~~;~t) Àf'1r:hOf0~~C' I I I I I I I I I I I NORTHSTAR NS18 I I I I I END OF WELL REPORT BP EXPLORATION ALASKA spe.....r-\I-5un [J RILL I N G 5 E R V I c: E 5 I I I ( T ABLE OF CONTENTS ( I 1. General Information I 2. Daily Summary 3. Daily Operations [ 4. Show Reports [ 5. Morning Reports 6. BHA's [ 7. Bit Record ( 8. Mud Reports 9. Survey Record I 10. Formation Tops I 11. Formation Evaluation Logs I I I I I I I I I I I I I I I I I I I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well : Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDl Engineers: Company Representatives: Company Geologist: lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS 18 Northstar North Slope Alaska United States 50-029-23091-00 AK-AM-22120 July 17, 2002 December 30,2002 True 26.269 deg 80.944 deg 57542.807 nT Jun 03, 2002 North 70 deg 29 min 28.37 sec East 148 deg 41 min 35.90 sec 308.16 deg Doug Wilson Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Jeff Smith Joe Polya Mike Dinger Ken Lemley I Rick Matson Northstar 107 Alaska North Slope spe....r..v-sun I:J R........ N G 511: R\J. c: e 5 I I I I I I I I I I I I I I I I I I I BP Exploration - Northstar NS18 Daily Summary 07/15/02 Move rig from NS 16 to NS 18 slot. Preparing to spud. Nipple up riser. 07/16/02 Build spud mud. Mud weight = 8.85 ppg. Nipple up riser and flowline, Pickup 16" drilling assembly and BHA #1 (Bit # 1 HTC MX-Cl, TFA 1.031). Drill to 230' MD and run wireline gyro's. 22 units of gas was seen from diesel contamination in this interval. Drill to 330' MD and trip out of the hole to chane to BHA #2 ( Rerun Bit # 1 ). Run in hole and drill ahead to 722' MD running Gyro directional surveys on wireline. Maximum ROP in this interval was 407 ftIhr at 701' MD. 07/17/02 Drill 16" hole from 722' to 2618' MD. Top of the permafrost was 1210' MD, 1200' TVD. Base of the Permafrost was 1597' MD, 1562' TVD. Maximum ROP in this interval was 655 ft/hr at 1770' MD. Maximum gas was 35 units at 2268' MD. First trace of methane gas seen at 1195' MD. 07/18/02 Drill 16" hole from 2268' to 4050' MD, 3216' TVD Total Depth for the 13 3/8" casing. Circulate sweeps and clean hole. Trip out of hole to run casing. Top of the SV6 marker was 3771' MD, 3055' TVD. Maximum ROP in this interval was 839 ftIhr at 2893' MD. Maximum gas for this drilling interval was 13 units at 3445' MD. Bit #1 and Rerun Bit #1 combined statistics= 3849 feet, 20.1 hours and 123.1 K revolutions. 07/19/02 Run 13 3/8" casing to 4033' MD. Circulated casing volume with maximum bottoms up gas of 13 units. Pump cement spacer and cement per well plan. 07/20/02 Clean pits. Nipple down riser and nipple up BOP's. Test BOP's. Laydown heavyweight drill pipe and pickup new drilling assembly BHA #3 (12 Y4" Bit #2, RSX238HF+GS, TFA= .9410). A Porcupine Reamer was run at 2262' up in the drill pipe to effect cleaning ofther SV sands. Build new mud volume 9.0 ppg and prepare to trip in hole. 07/21/02 Trip in hole and pressure test casing to 3500 psi for 30 minutes with 8.7 ppg mud. Displace hole to new 9.0 ppg mud while drilling shoe track. Drill 20' of new formation to 4070' MD and perform Formation Integrity Test to 12.5 ppg EMW. Drill 12 Y4" hole from 4070' to 6504' MD, without problems. Top of the SV5 marker at 4214' MD, 3313' TVD. Top of the SV4 marker at 4730' MD, 3617' TVD. Top of the SV2 marker at 5424' MD, 4012' TVD. Top of the SVl marker at 6164' MD, 4402' TVD. A moderate amount of large casing metal shavings was seen at 4200' MD, which decreased to negligible by 5800' MD. Maximum ROP in this interval was 608' ft/hr at 4858' MD. Maximum gas was 148 units at 6189' MD. 07/22/02 Drill 12 Y4" hole from 6504' to 8756' MD. Top of the Ugnu formation was 6852' MD, 4768' TVD. Maximum ROP was 550 ft/hr at 7888' MD. Maximum gas was 1087' units at 6934' MD from a coal stringer. 07/23/02 Drill 12 Y4" hole from 8756' to 10609' MD. Top of the Schrader Bluff formation at 9711' MD, 6324' TVD. Top of the Colville formation at 10713' MD, 6905' TVD. Maximum ROP in this interval was 471' ft/hr at 8883' MD. Maximum gas was 285 units at 10281' MD. Mud weight increased to 9.2 ppg. 07/24/02 Drill 12 Y4" hole from 10609' to 12724' MD. Top of Colville formation at 10713' MD, 6905' TVD. Maximum gas 381 units at 11869' MD. Maximum ROP 252 ft/hr at 12441' MD. I I I I I I I I [ I I I I I I I I I BP Exploration - Northstar NS18 Daily Summary 07/25/02 Drill 12 14" hole from 12724' to 14423' MD. Mud weight at 10.5 ppg. No HRZ was encountered, although there was up to 10% HRZ fragments in the drill cuttings. Consultation with the Geophysicist in Anchorage ( Rick Matson) produced the conclusion that based upon seismic data there was a possible turbidite that eroded off the basal section of the Colville and all of the HRZ. A small section ofKalubik formation was encountered 55 feet MD thick, (Top 13830' MD, 8679' TVD) and correlated from small sandstone and tuffaceous sandstone stringers in the Northstar NS15 well. Top of the Kuparuk formation was 13885' MD, 8715' TVD. Top of the Kuparuk "c" sand was 14191' MD, 8919' TVD. Top pfthe Kuparuk" B" shale interval / LCU was 14255' MD, 8963' TVD. Top of the Kuparuk "A" sand package was 14330' MD, 9015' TVD. Correlation of interval thickness of the 3 different Kuparuk zones (C, B, and A) was similar with the Northstar NS15 well. Maximum ROP in this interval was 268 ft/hr at 12725' MD. Maximum gas in this interval was 1953 units at 14215' MD. 07/26/02 Drilled from 14423' to the 12 14" Total Depth of 14693' MD, 9280' TVD. Circulate hole clean. Minimal amount of cuttings / cavings after bottoms up. Trip out of hole. Top of the Miluveach formation 14620' MD, 9225' TVD. Maximum ROP was 113 ft/hr at 14454' MD. Maximum gas was 957 units at 14451' MD. Bit #2 statistics= 10643 feet, 89.5 hours and 748K revolutions. Final mud weight was 10.5 ppg atT.D. 07/27/02 Laydown BHA #3 and rig up to run 9 5/8",47 #/ft casing. Ran casing to 3980' and circulated one casing volume. Continued to run casing at 12 joints/ hour and began to see mud losses at 6626' MD, top of the Schrader Bluff formation. Lost 20 bbls from joint 160 to 170. No returns after joint 170 and losing 1 bbl per joint. Total losses from joint 160 to 210 are 235 bbls. 07/28/02 Continued losing mud until casing was landed at 1045 AM. Total loss was 710 bbls. Attempted circulation, packed off. Worked pipe and pumped up to 1200 psi, then bled off 200 psi at a time-no circulation. Established circulation at 1400 hrs by very slowly staging up pumps a few strokes at a time to hold standpipe pressure at 1200 psi until a small flow was noted at the shakers. Staged up slowly to 9 bpm. Pump cement job-lost 53 bbls while displacing cement. Average gas while circulating was 146 units. Maximum bottoms up trip gas 1173 units. 07/29/02 Test BOP's. Pickup BHA #4,8 Y2" Bit #3 ( DS164F+JNW, TFA=.610 ), rotary steerable drilling assembly and trip in hole. 07/30/02 Bleed in spike fluid to bring mud weight up to 12.9 ppg while drilling shoe track. Drill 20' of new 8 Y2" hole to 14713' MD- severe bit balling. Perform Formation Integrity Test to 14.5 ppg EMW. Drill from 14713 to 15172' MD in Miluveach formation. Rotary steerable assembly failed. Trip out of hole. Average ROP was 65 ft/hr. Maximum gas was 131 units at 14908' MD. 07/31/02 Trip in hole. Bad MWD signal. Investigation found pump #2 pulsation dampner bad. Pull out to shoe. Replaced pulsation dampner. 08/01/02 Run in hole and wash to bottom. Drill ahead from 15172' MD to 16407' MD. Top of Kingak at 15276' MD, 9745' TVD. 08/02/02 Drill Ahead from 16407' MD to 16550' MD. Top of Sag River formation at 16503' MD, 10795' TVD. TD hole in Sag River. Lost circulation before bottoms up sample. Pumped LCM pills. Pulled out to shoe and checked flow. Circulated at shoe to 10.5 bpm . no losses. Monitor well- no static losses. Dropped rabbit pulled out of hole. I I I I ( I I I I I I I I I I I I UP Exploration - Northstar NS18 Daily Summary 08/03/02 Rig up and run liner. Establish circulation. Pump cement as per plan. 08/04/02 Pressure test as per plan. 08/05/02 Pull out of hole. 12/28/02 Move rig to NS 18 slot. Nipple down tree. Nipple up and test BOP's. Trip in hole openended to 2000' to circulate out diesel with seawater. Trip out. Test casing to 4800 psi. Pick up BRA #6 ( 6 1/8" HC408 Bit #4, TF A= .518 , Mud motor and MWD ). 12/29/02 trip in hole. Wash through tight spots in liner. Rotate on cement plugs. Pipe shows high torque. Displace seawater and old mud with 9.3 ppg Baradril-N mud. Pull 10 stands and begin MAD Pass. Continue drilling cement with high torque. 12/30/02 Drill float equipment, shoe track and 20' of new formation. Perform Formation Integrity Test to 11.5 ppg. Drill ahead to Total Depth in the 6 1/8" hole at 16685' MD, 11135' TVD. Circulate sweep bottoms up. Top of the Shublik formation at 16610' MD, 10896' TVD. Top of the Ivishak formation at 16710' MD, 10989' TVD. Maximum gas inthis interval was 497 units at 16724' MD. Maximum Rap was 180 ft/ hr at 16559 ' MD. Bit # 6 statistics= 315 feet, 11.8 hours and 111 K revolutions. 12/31/02 Trip out of hole to 7" casing shoe. Circulate hole clean. Pump slug. Trip out to surface. Rig up and run RFT wireline. Drill & slide from 732' to 1382'. Finish general R/U. P/UBHA# 1. Note: Change out stab. sleeves on motor & 1 stab. Fill riser wi sea water & check for leaks. Riser leaking at o-ring. Repair leak in O-Ring on scoping riser connection. Notes: 1) Pulled riser. 2) Changed O-Ring 3) Skidded rig for better alignment of riser. 4) Replace riser. Riser still leaking. 5) Unc1amp Junk ring, install rope packing and silicone at leaking area. 6) Leak repaired Note: Investigating better ways to seal in future. Clean out conductor to 200' md. Spud Well-- Drill to 230' md. Held Pre-Spud Meeting & P JSM for RlU gyro Notes: 1) Discussed objectives of well. (No Accidents, No Spills or risk to the environment, no policy or law violations, & drilling a quality cost effective well. 2) Hazards associated wi hole section. 3) Drilling parameters of this particular section. 4) Reviewed D- 7 drill. R/U gyro & conduct electronic test. Gyro survey - Base of conductor Incl. .43 deg, Az. 348.45 deg Drill from 230' to 330' md. POHwlBHA# 1. M/U BHA # 2. Drill & run gyro from 330' to 732' md. P JSM on skidding rig. Skid rig 20' to the north to NS-18. General R/U after skid. Notes: Berm around rig 2) Connect PUTZ 3) Let down stairwells. 4) Hook up injection line. N/U riser & mousehole. Note: Accepted rig on NS18 @ 21 :00 on 7/15/2002. Operations Breakdown BP Exploration - Northstar NS18 Daily Operations (I.A.D.C) 13:00-14:00 1.00 14:00-14:30 0.50 14:30-16:00 1.50 16:00-16:30 0.50 16:30-18:30 2.00 18:30-00:00 5.50 07/17/02 00:00-08: 15 8.25 ( I I I I I I I I 'I I I I 11 :30-12:00 0.50 12:00-12:30 0.50 12:30-13 :00 0.50 05:30-05:45 0.25 05:45-11 :30 5.75 07/16/02 00:00-02:00 2.00 02:00-05:30 3.50 21 :00-00:00 3.00 07/15/02 17:00-17:30 0.50 17:30-19:00 1.50 19:00-21 :00 2.00 I 'I I I 1 Time Elapsed (hrs) Time I Note: 1) Per stand - Sliding 25', rotating 20', sliding 25', & rotating remainder of I stand. 08:15-09:30 1.25 Pump sweep & run final gyro. 09:30-10:30 1.00 P JSM - RiD Schlumberger. I 10:30-00:00 13.50 Drill & slide fron1 1382' to 2620' pumping hi-vis sweeps as needed. 07/18/02 'I 00:00-03: 15 3.25 Drill & slide from 2620' to 2821'. 03: 15-03 :30 0.25 Clean mud pun1p suction screens on both mud pumps. Noise interfering 1 with signal from MWD. 03 :30-04: 15 0.75 Drill & slide from 2821' to 2905'. Packing off while backreaming before a connection. I 04: 15-05:00 0.75 Pump fresh water hi vis sweep & circulate hole clean. 05:00-07:45 2.75 Drill & slide from 2905' to 3191'. 07:45-08: 15 0.50 Saver sub backed out of top drive while making a connection. M/U to top ~ drive & retorque. 08:15-18:30 10.25 Drill & slide from 3191' to surface hole TD @ 4050'. Note: Pumped 75 bbl. fresh water mud sweep while drilling last stand down. 18:30-20:30 2.00 Pump 75 bbl. weighted hi-vis nut plug I barafibre swep. Pumped 1 surface to surface & 1 additional B/U. Hole cleaned up on 2nd BIU. I 20:30-21 :30 1.00 Monitor well - POR wi 2 stands while checking for swabbing - okay. Pump dry job & blow down lines. 21 :30-23 :30 2.00 POR to HWDP. I Note: 1) TOR was good with minimum drag of 10 - 20K. 2) Dry wiped stand 21 & 23 once wi 45K drag. After going back down, I pulled through with 20K drag. Tight spots --130' apart which might indicate only 1 tight spot as different stabs. passed by. 23 :30-00:00 0.50 LID BRA # 2. I Note: Tops of stabs, motor stab. sleeve & bit wi significant amounts of clay. I 07/19/02 00:00-03:00 3.00 LID BRA # 2. 03:00-04: 15 1.25 Clean rig floor & clear floor of stabs. & bit. I Prepare for casing tool RID. 04: 15-04:30 0.25 P JSM - Cut & slip drilling line. 04:30-05 :30 1.00 Cut & slip drilling line. I 05 :30-08 :00 2.50 PJSM - LID bails, PfU Frank's fill up tool, & RIU casing tools. 08:00-08:30 0.50 P JSM for running casing. 08:30-16:30 8.00 Run 98 jts. of 13 3/8" 68 lb. L-80 Buttress Casing. 16:30-17:00 0.50 P /U landing j t, hangar & land. 17:00-18:00 1.00 LID Frank's tool & R;U celnent head & x-over. 18:00-21 :00 3.00 Break circulation by staging pump up slowly from .5 BPM to 1 0 BP~1. Final circulating pressure @ 10 BPM - 390 psi. Note: 1) Service top drive \vhile circulating. 2) Held PJSNI for cenlent job. 3) Pumped 70 bbl. bi-carb spacer before turning over to HOWCO pump. 21 :00-21 :30 0.50 Pump 5 bbls. of sea water & test cement lines to 3000 psi. Check for Drill from 6500' to 8066'. 1) Sweeping hole every 500'. 2) J\llaintaining MW @ 9.0 ppg wi ECD's in 9.7 to 9.8 range. Drill from 8066' to 8159'. 12:00-14:00 2.00 07/22/02 00:00-12 :00 12.00 PIU Porcupine reamer, dart sub & Rill. Break circulation & wash from 3877' to top of float equip't plugs. R/U & pressure test 13 3/8" casing to 3500 psi wi 9.2 ppg mud & hold for 30 mins. Note: 1) Discussed well control wi crew members. (Dl, D2, & D5 drills) 2) Discussed drilling hazards associated wi hole section. Drill float equip't plugs, shoe track, & rathole to 4050'. Displace wel to new 8.6 ppg mud. Drill from 4050' to 4070'. Circulate MW in to equal MW out. Perfonn FIT to 12.5 EMW wi 8.6 ppg mud. (650 psi) Establish ECD baseline (8.89 - 8.93) & drill from 4070' to 4710'. Drill 12.114" from 4710' to 5687'. Service top drive. Continue drilling 12.1/4" from 5687' to 6500'. 1) Pumping sweeps every 400 -500' or as needed. 2) ECD is staying close to .7 ppg above mud weight. 3) Inconsequential amounts of metal from porcupine reamer while inside casIng. 4) No Drag, No losses. vViping bottom 30 ft. leaks & retest. Pump 75 bbls. 10.2 weighted spacer - dropped botton1 plug - puo1ped 517 bbls. 10.7 ppg lead cen1ent followed by 96bbls. of 15.9 ppg tail cement. Dropped top plug & chased wi 25 bbls. sea water. I 21 :30-00:00 2.50 I ( 07/20/02 00:00-01 :00 1.00 ( 1 01:00-01:30 0.50 01 :30-03:00 1.50 I 03 :00-03 :30 0.50 03 :30-04:00 0.50 04:00-05 :00 1.00 05:00-09:30 4.50 09:30-11 :00 1.50 11 :00-15 :00 4.00 ,I 15:00-16: 15 1.25 16: 15-18:00 1.75 18:00-19:00 1.00 ,( 19:00-22:00 3.00 22:00-00:00 2.00 I 07/21/02 00:00-01 :30 1.50 01 :30-02:00 0.50 I 02:00-03:00 1.00 I 03 :00-06:00 3.00 J 06:00-07:00 1.00 07:00-07:30 0.50 07:30-08:00 0.50 08:00-12:00 4.00 12:00-17:30 5.50 17:30-17:45 0.25 17:45-00:00 6.25 Displace cement wi rig pump @ 10 BPM. Notes: 1) Bumped plug wi 566 bbls. of mud @ 95.6% pump efficiency. 2) Tested casing to 1950 psi & held for 3 min. (OK) Check floats (OK) & LID cement head. RID landing jt. - flush riser - LID casing tools & clean floor. N/D surface riser. Remove rig mat from cellar. N/U Vetco multi bowl assy & test to 2500 psi. N/U BOP's. CIO bails, install iron roughneck floor track, RJU test equip't & fill stack. Test BOP's 250/4800 & hold for 5/5 min. Pull test plug & install bowl protector. Rlli wi 8 stands ofRWDP & POR LID singles via pipeshed. Clear floor & bring BRA to floor. MIU BRA #3 & shallow test MWD & rotary steerable assy. PIU 63 jts. of 5" DP from pipeshed & Rill. I I I I I I I I I I I I I I I I 14:00-14:30 0.50 1-+:30-00:00 9.50 Service top drive, crown, & blocks. Drill 12.1/4 "hole from 8159' to 8756'. Note: Drilling some hard spots - notably from 8751' to 8757' - 3 hrs. to drill 6'. Reduced RPM to 105 while drilling hard streaks. No drag, No losses. Pretreating Sandstones \vith LCM. 07/23/02 00:00-16:30 16.50 Drill ahead 12-1/4" hole with RSS from 8756' md to 10160' md in the Schrader Bluff and Ugnu.- ROP from 9-200 fph - WOB 10K-Ibs, 150 rpm, Torque on 15-16 K ft-Ibs. - 54.83 deg Inclination and 309.34 deg Azim. - Pumping high vis sweeps every 500'. Build and pump 70 bbls high visc BAROFIBREI Walnut sweep. No excess cuttings noted on sweep return. Drill ahead 12-1/4" hole from 10160' md to 10445' md. - ROP from 75- 137 fph. - 285 units gas @ 10281' (max gas) Service top drive. Drill ahead 12-1/4" hole from 10445' md to 10620' rod into Colville (Field pick Top @ 10613' md/6849' tvd). - Slow drilling @ -10495' md/6781 tvd. ROP < 10 fph -- Hard streak. - ROP from 68- 137 fph. 16:30-17:30 1.00 17:30-20:30 3.00 20:30-21 :30 1.00 21 :30-00:00 2.50 07/24/02 00:00-18:30 18.50 Drill ahead 12-1/4" Interm. hole from 10620' md to 12346' md wi RSS Assy. -ROP averaging 132.3 fph overall. -ECD stable and running from 9.8 to 10.1 wi MW in= 9.4 ppg. -Inclination 53.8 deg and azimth of305 deg. - WOB= 15-20 K-Ibs, 900 gpm wi 3100 psig. - ROT wi 150 rpm and torque increasing to 22 K ft-Ibs. Service Top-drive. Drill ahead 12-1/4" hole from 12346' md to 12682' md. - ROP, ECD, and Torque good. - Running sea-water at 100+ bbl/hr and dumping mud to G & I to control mud wt and LGS. Mud Pump #1 developed end gasket leak. Continue pumping wi Pump #2. Safeout Pump #1 and repair. Pun1p repaired come on line and drill ahead from 12682' md to 12726' md. 18:30-19:00 0.50 19:00-23 :00 4.00 23:00-23:30 0.50 23 :30-00:00 0.50 07/25/02 00:00-18:00 18.00 Drill ahead 12-1/4" hole from 12726' to 14191' md. - ROP from 120-162 fph. - \VOB= 20K lbs - Pump rate 870-900 gpn1 wi 3250 psig. - 150 rpm wi Torque running 22-23 K ft-Ibs - rvIW 10.5 ppg wi ECD 10.9 HRZ interval did not show, eroded away. I 00:00-18:00 18.00 I 18:00- ì 9:00 1.00 19:00-20:00 1.00 ,I 20:00-00:00 4.00 I I I 07/26/02 00:00-05 :00 5.00 I 05:00-08:30 3.50 I 08:30-09:00 0.50 I 09:00-11 :30 2.50. I 11 :30-12:00 0.50 12:00-18:00 6.00 I I 18:00-19:30 1.50 I 19:30-22:00 2.50 Found Kalubik @ 13830'1 8679' tvd Drill into Kuparuk @ 13885' md/ 8715' tvd Drilling ahead 12-1/4" hole in Kuparuk "C". - Top Kuparuk "C" @ 14191' md/ 8919' tvd (Max gas 1935 units) Change out swab on #2 mud pump. Drill ahead 12-1/4" hole from 14237'md to 14439' md. - Top Kuparuk "B" @ 14255' md/ 8963' tvd. - Top Kuparuk "A" @ 14330' md/ 9015' tvd (Max gas 1257 units). Becoming power limited wi plant running 2 turbines wi po\ver to spare. - Drawing 3000 amps. - Slow to 120 rpm wi 25K ft-Ibs torque. - Slow rig pumps to 880 gpm @ 3350 psig. - Rap averaging 45-75 fph wi total average ROP= 122.5 fph. 22:00-00:00 2.00 Drill ahead 12-1/4" Int hole from 14439' md to TD @ 14693' md. - Final Total Rap average 120.1 fph. Circulate Low-vis sweep. Follow with weighted sweep. - Sweeps didn't carry much excess. - Rotate and recip. while circulating. Rack 3 stands back - Circulate a total of 32000 strokes (Hole clean). Monitor well. Good. POOH to 11780' md. (PU wt off-btm= 325 K lbsl SOW = 220 K lbs). -30 k'Tugs" at top ofKuparuk. - Decide to keep POOH-hole slick. Monitor well. Pump dry job. Drop ESS @ 11780' md. POOH into 13-3/8" shoe 4030' md. - Slightly tight spots (30K lbs overpull) @ 10900', 7240', and 4930' md. - Pump out ttom 4850' md to 4030' md. Slight amount of swabbing through SV sands. Had to work BHA up into 13.3/8" shoe. Circulate 2 bottoms up. - Quite a bit of excess material on intial bottoms up (smaller to medium size clay clumps and a small amount of Miluveach shale came back on initial bottoms up). - Continued circulating until clean @ 9000 strokes. - Monitor and pump dry job. POOH. - Lay down Porcupine reamer. Wom on leading edge. Missing 1 st row of leading edge cutter buttons. Rest of reamer in good condition. Lay Down BHA #3. . - Recover ESS. Good surveys @ 11517.32', 11424.40', & 10947.36' md. - Bit in good condition (Graded: 2-0-CT-C-X-I-WT-TD) 07/27/02 00:00-01 :30 1.50 01 :30-02:00 0.50 02:00-03 :00 1.00 03 :00-04:00 1.00 04:00-06:00 2.00 LID BHA #3. Clear and clean rig floor. PU SID and Johnny \Vacker. Flush stack. Drain stack. Pull wear bushing. - \Vear bushing \vas damage- no problem pulling. PJSM. Change out top set rams to 9-5/8" for running casing. PJSM. Slip and cut 102' drilling line. I 06:00-07:00 1.00 07:00-08:00 1.00 I 08:00-09:30 1.50 09:30-15:00 5.50 I 15: 00-16: 00 1.00 I 16:00-19:45 3.75 19:45-22:30 2.75 I I 22:30-00:00 1.50 I 07/28/02 I 00: 00-09: 3 0 9.50 [ 09:30-10:00 0.50 I 10:00-10:30 0.50 10:30-14:00 3.50 [ I 14:00-18:00 4.00 I 18:00-23:00 5.00 I I I I I I P JSlV1. Test ram door seals to 3000 psig. PJSlVl for RU for running casing. Review Franks tool, installing rails. Rigging up stabbing board, man-riding. and casing running procedures. Rig up to nm 9-5/8" casing. MU Float Equipment. Check floats. Run 97 jts of 9-5/8" 47# casing to 3980' md averaging 20 jts/hr. Circulate casing volume @ shoe. Runjts 97-#165 start Onjt 160 (6627' 9-5/8" shoe depth) begin to get some seepage. Slow down rate from 22 jts/hr to 17 jts/hr. Runjts #165-180 @ 17 jts/hr. Still seeping. No static losses. However not getting any returns. Runjts #180-187 @ 12jts/hr. Same losses. Runjts #187-194 @ 7 jts/hr. Losses are less. Run jts # 194-203 @ 10 jts/hr. Stop check backside FL- static. Run jts #204-210 @ 5 jtsl hr. No change. Runjts #210-216 @ 10 jtsl hr. Start mixing more mud. Note: Total bbls lost from JT #160- 216 is 240 bbls. Run 9-5/8" 47# casing from JT# 216 - 355 wi losses averaging 4.2 bbls/Jt. Hole good. Had some problems getting though top of Kuparuk ( slack off 100 klbs)- Typical of previous wells. Hanger & Land 9-5/8" casing. Hole slick, land Hanger with 225 klbs downweight. RD Frank's Fill up tool. RU crossover and Cement Head. RU cement line. Try to Establish circulation - packed off. Attempt to reciprocate Pipe. Not able to move pipe up with 550 klbs and Hanger Catching in Ram Cavities. Surge pipe up to 1400 psi- no go. Make arrangements for Schlumberger to come out to shoot cire holes. With patience, able to establish circ @ 2 spm wi a finger of returns. - Slowly increased rate to 9 bpm on schedule to a final rate of 9 BPM/ 900 psi. Circulate 1.3 bottoms up. No excessive cuttings at surface. PJSM for Cement Job. Pumped Cement Job As Per Plan: - Pump 5 bbls and PT lines to 4000 psig. - Pump 50 bbls 11.3 ppg Alpha Spacer. - Drop bottom plug. - Mix and pump 458 bbls (794 sacks) of 11.2 ppg lead cement. - Follow wi 116 bbls (564 sacks) of 15.9 ppg tail cement. - Drop top plug and flush wi 25 bbls of water. - Switch to rig pun1p #2 and begin displacement @ 9 bpm. PUll1p #2 not running smooth, switch to Pump #1 and continue displacen1ent. - Have 2 bpm losses before cement around shoe. - At 5190 strokes (515 bbls) have good lift, 9 bplll 305 psig and losses quit. - Slow to 5 bpm and 1500 psgi @ 9900 strokes (Slight losses- 3 bbls) - At 10263 strokes slow pump to 3.4 bpm \vl 1 700 psig. - Bun1p plug @ 10530 strokes, 94.3 % eff (1046 bbls HALCO n1eter) w 3.4 bpn1 @ 2100 psig. - Pressure to 2600 psig and monitor for 3 n1ins. Straight line @ 2500 Rlli w/ BRA #4 w/ 5" DP. Wash down last stand to 14580' md. Circulate MW in = MW out = 10.1 ppg. Pressure test 9-5/8" casing to 4200 psig for 30 minutes on chart. 13 bbls pump/return. Review D5 Drill. Perform D-5 Drill. Drill out Float Collar and cement to 14662' md. Start bleed in for MW increase simultaneously. Condition Mud system to MW= 12.9 ppg. Drill Out shoe and 20' of new hole to 14713' md . Perform FIT to 850 psig wi 3.1 bbls. E~IW= 14.6 ppg. Drlg ahead 8.5" hole from 14713' to 15172' md wi 8.5" RSS. -Bit balling occured \vhen started drilling ahead. -Assembly dropping @ 1.7 degJ 100'. - Send command to build 400/0 of the time wi no response. Command RSS to build 1000/0 of the time wi no response. At present inclination will miss Drillers target by 100'. Confer with Anchorage Engineering and decide to POOH for ne\V RSS assembly or possibly a motor, depending on RSS functioning at suríàce. pSlg. - Estimated total bbls lost on cement job 53 bbls mud. - Estimated 5 bbls Alpha spacer returned just before bun1ping plug. Bleed off and check floats. Rig down Cement head & landing joint. I I 23 :00-23 :30 0.50 23 :30-00:00 0.50 I 07/29/02 00:00-00:30 0.50 I' 00:30-01 :30 1.00 1 01 :30-03 :00 1.50 03 :00-07 :30 4.50 I 1 I 07:30-08:00 0.50 08:00-08:30 0.50 08:30-14:30 6.00 I 14:30-15:00 0.50 15:00-17:30 2.50 I 17:30-18:30 1.00 18:30-19:00 0.50 19:00-00:00 5.00 I I 7/30/02 00:00-03:30 3.50 03 :30-04:30 1.00 I 04:30-05 :30 1.00 I 05 :30-07 :00 1.50 07:00-08:30 1.50 I 08:30-11 :00 2.50 11 :00-14:30 3.50 14:30-15 :00 0.50 15 :00-23 :30 8.50 P JS~f. Back Out and pulllandingjt. Flush and drain BOPE stack. Install short bails and 5" DP elevators. Install 9-5/8" pack-off. Test to 5000 psig- good. PJSM's. Displace 9-5/8"x13-3/8" annulus wi 240 bbls of 10.2 mud at 1 bpm (Started injecting at 1700 psig. Other simultaneous operations being perfom1e concurrently: - Swap 9-5/8" rams to variables - Clean L-Pit - Change Liners and swabs on mud pumps to 5-1/2". PJSM for setting Test Plug and BOPE test. Set Test plug. Rig up testing equipment and fill BOPE stack. Pressure Test BOP's for 5min (250 psig/4800 psig). PT annular 3500 pSlg. Pull test plug and install wear ring. MU BRA #4 (RSS, MWD, and 8.5" bit). Shallow test- good. PU 30 Jts ofDP from pipeshed. RU to freeze protect 9-5/8" x 13-3/8" annulus. PJSM. Pump 1500 strokes of diesel @ 1.3 bpm. Pumped a total of 127 diesel FP. Continue Rlli wi BRA #4. Replace 1 Jt ofDP - Scored. Drilling Paran1eters: - ROP average 64 fph (78-95 tþh range). - WOB 15 K - Pump Pressure 3550 \v/ 550 gpm flow. - Inclination 34.75 deg / Azimuth 308.89 deg @ 15114' n1d. - Torque 24 K ft-lbs w/ 150 rpm. - ECD running 14.0 ppg to 14.4 ppg E~lW. CBU wi reciprocating and rotating 100 rpm. I I I 23 :30-00:00 0.50 I 07/31/02 I 00:00-01 :00 1.00 01 :00-01 :30 0.50 I 01:30-02:00 0.50 02:00-07:30 5.50 I 07:30-08:00 0.50 08:00-09:00 1.00 09:00-11 :00 2.00 ( 11 :00-12:00 1.00 12:00-12:30 0.50 . 12:30-18:30 6.00 I 18:30-20:00 1.50 20:00-21 :00 1.00 I 21 :00-22:00 1.00 ( 22:00-22:30 0.50 22:30-00:00 1.50 I 08/01/02 I 00:00-09:30 9.50 09:30-10:00 0.50 10:00-00:00 4.00 I I I I I I Continue circulation @ shoe -- Replace #2 MP Dampner. Rlli w/ BHA #5. Wash from 15076' md to 15172'. Drill ahead 8.5" from 15283'-16407' md into Kingak. TOP Kingak field pick 15276' md/ 9745 tvd.- Pump nut-plug sweep and unball bit. - Vary WOB for optimum ROP to get a handle on ECD. - Highest.ECD spike to 14.9 ppg. Mud Engineer adding water lo\ver MW to target 12.8ppg. -Varied ROP from 100 to 170 fph wi increase in WOB to 25K Ibs max. ROP= 100 fph I ECD= 14.34 ppg ROP= 120 fph I ECD= 14.34 ppg ROP= 150 [ph I ECD= 14.40 ppg ROP= 170 fphl ECD= 14.40 ppg wi spike to 14.7 ppg. Attempt to keep ROP < 150 fph for ECD hardline. Drilling parameters: Total Flow= 552 gpm wi Pump P= 3450 psig. WOB= 17K lbsl 150 rpm wi 23K ft-Ibs torque. Continue CBU. Returns cleaning up - lots of excess for the footage drilled. Pump total of 10000 strokes. Monitor well. Trip out of hole to 9-5/8" shoe.- PUW 295 K lbs I SOW 225 K lbs. Monitor well. Pump dry job. Blow down Top Drive. POH N POOH to BHA #4. Stand back Jars and Drill collars. PJSM. Inspect Bit & Test Power Drive. Find PD Bias unit failure. PU BHA #5 (Same string wi different MWD and PD unit). Test Power Drive Unit. Download CDR. PU BHA #5. Rill wi BHA#5 on 5" DP to 14600' md. PJSM. Slip and cut 102' drilling line. Service Top Drive and drawworks. Rlli w/ BHA #5 into open hole. Wash down last stand. Hole in good condition.- PUW is 310 K, SOW is 210 K, and ROW is 236 K lbs. - Rotary torque 12 K ft-Ibs. Much improvement from yesterday. Not getting good MWD signal frames. On further investigation Pump #2 pulsation dampner has lost integrity- prepare to change out. POH to 9-5/8" shoe. Replace Pump #2 pulsation dampner.- Continue circulating wi pump #1 for mud conditioning. I 08/02/02 I 00: 00-02: 00 2.00 I I I 02:00-03:00 1.00 I 03:00-07:00 4.00 I I I I 07:00-10:00 3.00 I I 10:00-10:30 0.50 I 10:30-11:00 0.50 11 :00-14:00 3.00 I 14:00-14:30 0.50 14:30-16:00 1.50 I 16:00-17:00 1.00 17:00-21 :00 4.00 21 :00-23:00 2.00 I 23 :00-00:00 1.00 I 08/03/02 00:00-01:00 1.00 I 01 :00-05 :00 4.00 01 :00-05 :00 4.00 I Drill ahead 8.5" hole wi RSS from 16407' md to 16550' md into Top Sag. Top Sag River @ 16503' md I 10795' TVD. - ROP nlnning 1-W fþh to 45 fph, still targeting 14.4 ppg ECD wi 12.8 M\V Drilling paran1eters @~ TD in Sag River: .. 540 gpm w/ 3400 psig - 25 K ft-Ibs Torque @ 150 rpm (Higher torque) and 21 K-Ibs Torq off. - 15-20 K lbs WOB wi ROP 50 fph .. PUW= 315, SOW= 220, ROW= 252 K lbs. - Final Inclination 22.7 degrees. Circulate Hi Vis Sweep. (Lost Circulation @ 7600 strokes - ECD no higher than 14.0 ppg). Continue circulation @ 3 bpm while filling and monitoring (4 bpm losses) stringing in barafibre while getting LCM pill ready to go. No returns with static losses at 75 bph while mixing LCM pill. Mix and pump 85 and pump 80 bbls LCM pill containing at 4 bpm. 25 ppb BARA-Seal M 25 ppb Walnut-M 25 ppb BARO fiber. Note: Anadrill recommed 50 ppb LCM material max through IS. While chasing pill, got partial returns @ 950 strokes. Spot pill and clear bit by 200 strokes over for safety margin. Finished circulation with 75% returns (75 bph losses). Shut down and monitor, well FL is static. Total Mud loss well: 640 bbls. Monitor well. Trip from 16550' md to 15076' md slowly to prevent swabbing. -PUW= 325 K, SOW= 230 K Ibs. - Max drag was 50k wI average drag of 15K Ibs over. Hole in good condition. No losses on trip. Secure well and muster crew. OPS fire alann. Wood fire put out. Resume rig operations. Continue trip to 9-5/8" shoe. No losses. Establish circulation @ 9-5/8" shoe. Recover LCM material in annulus. Work circulation rate up to 10.5 bpm. No losses. Monitor well- no static losses. Drop 2.5" rabbit. Pump slug. POH fl running 7" casing. Operations lost hi-line power. Switch to rig power Continue trip out of hole. Flush BHA#5 wi water. Lay down BHA#5. 8.5" bit graded: 3-0-CI-C-X-I- BF - TD Clear and clean rig floor. RU to run 7" 26 ppf CS-Hydrilliner. Continue RU for running 7" 26# L-80 Hydril-521 liner. PlSNl for running liner. MU Float equipment and Bakerlock connections. Fill and check floats- good. Run 51 lIs 7" 26# L-80 Hysril-521 liner. MU torque average of 12 K ft I Ibs. 05 :00-06:30 1.50 MU Baker 'ZXP' liner top packer and Flex Lock II hanger assen1bly. I Circulate liner volun1e. PUW= 117 K lbs & SOW= 115 K Ibs. 06:30-17:00 10.50 Rill wi 7" liner on 5" DP to 9-5/8" shoe filling DP every ro\v. 17:00-18:00 1.00 Circulate pipe and liner volume. PUW @ shoe= 180K lbs I SO\V 207K I ROW 240K @ 15 rpm wi IlK ft-Ibs torque 18:00-20:30 2.50 Run into 8.5" open hole. - At 15895' have a little drag starting 15-20K. I - At 16348' Tight spot 80 K Ibs. Still nlnning in good however. - At 16492' md taking wt. No displacement. Decide to wash down. 20:30-21 :30 1.00 Establish circulation and wash down fro In 16492' md to 16545' md (5' off I bottom).- Work rate up slowly to 35 spm @. 757 psig. 21 :30-22:00 0.50 Make up cement head. 22:00-22:30 0.50 Establish circulation wi cement head..- \V ork rate up to 5 bpm @ 730 I psig. PUW= 270KJ SOW= 215 K-Ibs.- Returns full during entire circulation I PJSM for cement job. 22:30-00:00 1.50 Pump cement job as per plan: - Pump 5 bbls of 13 ppg Alpha Spacer - Pressure test lines to 4500 psig. I - Pump 30 bbls more Spacer 4 bpm- some trouble with electrical. - Pump 86 bbls (325 sacks) of 15.9 ppg tail slurry @ 5 bpm - Drop wiper plug and chase wi 5 bbls sea water I - Switch to rig pump for mud displacement @ 5 bpm after catching cement. I 08/04/02 I 00:00-01:00 1.00 Slack off 100 K on hanger. Increase Pressure up to 4500 psig. Bleed off - check floats- good. Pick up to check wt loss (94000 lbs) @ 226 K. PU 7' to release packer setting dogs. Slack offDP wt to 120 K-lbs and see liner I top packer shear @ 140 K-lbs. PU to 7' mark and repeat. PU to 7' and rotate w/70k lbs down on pkr (10 rpm w/9-11k ft-lbs torque). Pressure up to 500 psig I and pull 1 7' to release pressure and CBU @ 115 spm to circ out excess cmt. 01 :00-03:00 2.00 Circulate out Alpha space and approximately 30 bbls cement (500/0 cut on 60 bbls) 03 :00-04:45 1.75 Lay down cement head and 2-singles of 5" DP. G & I injecting to n1ake room for Sea water displacement. 04:45-06:00 1.25 RU and test liner top to 1500 psig for 30 min. G & I still injecting to make room for displacement. 06:00-09:45 3.75 P JSM for Sea Water Displacement. - Pump 25 bbls high vis spacer - Pump 100 bbls sea water - Pump 50 bbls high vis spacer - Pump 1230 bbls total @ 10 bpm Final NTU= 350. 09:45-10:15 0.50 j\'1onitor well tàr 30 mins. PJSM for Slip and Cut drilling line. 10:15-11:30 1.25 Slip and cut drilling line. 11:30-12:00 0.50 RU floor for laying down DP. 12:00-16:00 4.00 Lay do\vn 105 jts of 5" DP I 16:00-16:30 0.50 Service Top Drive and Drawworks. 16:30-22:00 5.50 Lay down 202 jts of 5" DP. Total LD was 307 jts. I 22 :00-23 :30 1.50 POOH. I, 23 :30-00:00 0.50 Make service breaks on Baker HRD running tool. Tool clean. I 08/05/02 I 00:00-00:45 0.75 Lay down Baker Running Tool. Manifest and stage for barge to \VestDock. 00:45-02: 15 1.50 Test casing to 4800 psig wi Halliburton pump and chart for 15 mins. I Good Test. 18.5 bbls of SW to PU. 00:45-02:15 1.50 Blow do\Vll mud lines 02: 15-02:45 0.50 Break and LD the cement head. G & I Flushing well for Caliper log in a.nl. I Cleaning pits. 02:45-03: 15 0.50 Clear and clean floor. Prep floor for PU HWDP. 03:15-08:00 4.75 PU 24 Jts HWDP and 114 JTs of 5" DP. I 08:00-09:00 1.00 Morning barge is blocking access for more DP and SWS needing to respot for NS 1 0 Caliper log. I 09:00-10:30 1.50 Iron roughneck repair. 10:30-14:00 3.50 PU singles of 5" DP for total of212 jts. 14:00-15:00 1.00 Service top drive, drawworks, and croWD. I 15:00-17:00 2.00 POOH and rack back rental pipe to 3000' md. 17:00-17:30 0.50 PJSM for Diesel FP. I 17:30-21 :30 4.00 Reverse circulate 125 bbls of diesel from Tank Farm. Strap SW returns to G&I. 21 :30-23:30 2.00 U-tube diesel. Replace swivel packing on Top Drive. I 23 :30-00:00 0.50 POOH wi DP. 12/27/02 I 22:00-00:00 2.00 PJSM - NIU BOP's & hook up Koorney lines. Accepted rig on NS-18 @ 1800 hrs. I 12/28/02 00:00-03 :30 3.50 NfU BOP's & risers. Install mouse hole. 03 :30-04:30 1.00 Install iron roughneck tracks, mats, C/O to 5" on iron roughneck, check I for pressure on annulus & BIO lock down screws. Pull tubing hangar & LID. 04:30-05 :30 1.00 RID to test BOP's - Install test plug & fill stack. I 05 :30-06:00 0.50 Repair leak on riser & choke line. 06:00-10:30 4.50 Test BOP's to 250/ 4800 psi for 5 I 5. Test annular preventer to 3500 psi. I 10:30-11 :00 0.50 Pull test plug, install bowl protector, BID lines & line up manifolds. 11 :00-12:00 1.00 CIO saver sub. 12:00-12:30 0.50 Clear floor of tools. I 12:30-14:00 1.50 PJSM for circulating out FIP. Rlli open ended to 2075'. 14:00-14:30 0.50 P JSM - ~VU head pin 14:30-15 :30 1.00 Line up to sea water & G & I & test line to 110 psi. I 15: 3 0-1 7: 15 1.75 Close annular & displace diesel @. 2 BPM through choke. 17: 15-18 :00 0.75 RiD & BiD - monitor well. 18:00-18:45 0.75 POH I Drill shoe track & F IS. Difficulty rotating drill string until additional lubricants were added. Drill 20' of new hole from 16550' to 16570'. Thaw out frozen kill line. Perfonn FIT to 11.5 EMW wi 9.2 ppg mud. Pressured up to 1300 psi wi 5.1 bbls. Final pressure after holding 10 min. was 1260 psi. Drill from 16570' to TD @ 16865' md in 6 1/8" hole wi 4 3/4" motor \v/ 1.15 deg bent housing. No drag, no losses PIU 300K SIO 240 K ROT 270K Final survey @ TD Incl 20.30, Az 306.29 Pump 75 bbl Baracarb I Barofibre hi-vis sweep & circulate BID X 1.5. Sweep did not bring back any additional cuttings. Hole appears to be clean. Monitor well - LID single & POH inside 7" shoe. Hole in good shape wi no drag, no swab, no losses. I 18:45-19:15 0.50 19: 15-20:30 1.25 I 20:30-20:45 0.25 20:45-22:30 1.75 I 23:30-00:00 0.50 I 12/29/02 00:00-03 :00 3.00 I 03 :00-04:00 1.00 04: 00-04: 3 0 0.50 04:30-11 :00 6.50 I 11 :00-12:30 1.50 12:30-13 :30 1.00 I 13:30-14:30 1.00 14:30-16:00 1.50 I 16:00-16:30 0.50 16:30-16:45 0.25 16:45-17:30 0.75 I 17:30-20:00 2.50 20:00-20:30 0.50 20:30-00:00 3.50 I I 12/30/02 I 00:00-04:00 4.00 04:00-04:30 0.50 I 04:30-05:00 0.50 05 :00-06:00 1.00 I 06:00-21 :00 15.00 I I 21 :00-23 :30 2.50 I 23 :30-00:00 0.50 I PIU BHA, Change bend in motor, orient, & load ADN tools wi source. ( PJSM ) PIU 6 jts 4" HWDP & 12 jts. 4" HT-40 DP from pipeshed & RIH. Shallow test MWD - BID TD & lines. Strap 5" & RIH to 14457' filling pipe every 30 stds. PJSM - Fill drill pipe wi 100 bbls. hi-vis sea water spacer @ top of liner to ensure good displacement of 12.8 ppg left inside liner. Continue Rill from 14457' to 16135'. Wash down from 16135' to top of landing collar @ 16455'. Taking some weight from 16,135'. Drill on landing collar from 16455' to 16462'. Unable to rotate due to high tq. Complete displacement of sea water & old mud wi stored BARADRIL- N mud. BID lines & monitor well. paR wi 10 stds. to 15600' for MAD pass. MAD pass from 15605' to 15700' while lubing up the mud. Rill from 15700' to 16462'. Drill shoe track from 16462' to 16490'. Could not rotate for first hr due to high torque. (17.5K) Added another 4 drums EP mud lube. 3% lubricants in mud - 2% EP mud lube - 1 % Torque Trim. Ditch magnets look good wi no casing metal. P JSM for casing test. Fill hole & cement line. Test 7" X 9 5/8" casing to 4450 psi \vl Halliburton pump & hold for 30 min. 18 bbls Pumpedlreturned BID lines. PJSM - MID BHA # 6. Replace fittings on hydraulic lines for EZ-torque & rotary table at Driller's console. 12/31/02 00:00-00:30 0.50 00:30-01 :30 1.00 I I I I I I I I I I I I I I I I I I POH inside shoe & monitor well. OK Drop ball to open PBL & pump down wi 8 BPM. Slowed pun1ps down to 3 BPM before latching. PBL did not open. PJSM - Service top drive. Drop ball to close PBL to ensure PBL closed. Pump @ 5 BPM wI 650 psi. Realized PBL was open once pump was started. Lesson learned: Shut down pump & restart pump after opening ball has seated. Monitor well - well static wI no losses. Pump dry job - BID. PJSM - drop rabbit. paR to 4" & cia to 4" handling equip't - monitor well. RID to & flush BRA wI sea water. BID. LID 4" HWDP & handle BRA. Clear floor of tools. PJSM - RJU Schlumberger to run RFT's. Run RFT's. Was able to get samples at the first 7 out of 20 points, but unable to get below 16786'. Atempted several times- no go. Abort 02:00-02:30 0.50 02:30-03:00 0.50 03:00-10:30 7.50 10:30-11 :00 0.50 11 :00-14:30 3.50 14:30-15:00 0.50 15:00-16:00 1.00 16:00-00:00 8.00 01 :30-02:00 0.50 I sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS18 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: RICK MATSON Depth (MD) (TVD) 13800 to 13870 ft 8660 to 8705 ft Show Report No. 1 DatefTime: 7/26/2002 Interpretation: The high gas corresponds to a 15 foot thick (13815-13830' MD. 8670-8679'1VD) Tuffaceous Sandstone at the base of the Colville formation /Kalubik formation erosional surface that eroded off the HRZ. Steam still analysis indicates that this interval would produce gas. No sample fluorescence or cut fluorescence was observed. The sand contained carbonaceous material. Note: 2 steam still runs were performed on this sample. I % Depth 13821 ft Gas x Units 1221 Mud Chlorides (ppm) = 18.5K ---FfÕWliñë-------šüëtiõñ------š-tiõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 99.0 15.18 = 83.8 - - C2 10.32 3.03 7.30 - - C3 8.11 3.56 = 4.55 C4 5.62 3.37 = 2.26 - - C5 3.08 2.16 = 0.93 --Prõauctiõ-ñ------=------=---------------------------------------------- Analysis (X1Gas nail nWater nNon-Producible Hydrocarbons 2 % I Hydrocarbon Ratios C1/C2 11.5 C1/C3 18.4 C1JC4 37.1 C1JC5 90.5 I I Depth 13821R2 ft Gas x Units 1221 Mud Chlorides (ppm) = 18.5K ---¡:fõwlrñë-------šüëtiõñ-----=-stiõy¡.::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 72.4 15.18 = 57.2 - -- C2 7.74 3.03 = 4.71 - -- C3 6.10 3.56 = 2.54 - - C4 4.51 3.37 1.14 - -- C5 2.54 2.16 = 0.38 --Prõauctiõ-ñ------=------=----------------------------------------------- Analysis )qGas nOil nwater nNon-Producible Hydrocarbons 3 % I Hydrocarbon Ratios C1JC2 12.1 C1/C3 22.6 C1/C4 50.1 C1JC5 149.1 [ I Depth ft Gas x Units Mud Chlorides (ppm) = ---¡:rõwlrñë-------š-üëtiõñ-----=-Š-tiõÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 1.0 - - C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 --Prõëiuctiõñ------=------=---------------------------------------------- Analysis nGas nail nWater nNon-Producible Hydrocarbons 4 % I Hydrocarbon Ratios C1/C2 1.0 C1/C3 1.0 C1/C4 1.0 C1JC5 1.0 I [ Depth ft Gas x Units Mud Chlorides (ppm) = ---Fiõ\Ñlrñë-------šüëtiõñ-----=-šl1õw----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 1.00 --Prõauctiõ-ñ------=----- Analysis Gas Oil Hydrocarbon Ratios C1/C2 1.0 C1JC3 1.0 C1/C4 1.0 C1/C5 1.0 ---------------------------------------------- 1000.0 .~ NPH 100.0 Gas 10.0 NPH 1.0 1000.0 NPH 100.0 Gas 10.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ----..- ,-----~..-..--_. ---~.._.._. ,.~ "" ...._-----.. ,--~--'-- --- .-.-.--.----------" . ~----------_._-- --_.--- --.-.---.--.-------.-,.-.,--- -.----..-..------....--- -------.--.,-.--- -,-- --.-....-,,-.------..-- ~---'---'-'~- -_._".,_..._-_._.._...~--."-~ - ~----,--_.__._-,----_._..- ~'-'-'---'-"--'''- Oil _ .___ _ . " __,__" _n__ _ _........._..._.,,_.....___......_. .--....-.,..---..-....-.--- --.-.""-"..-"'.-..."-,.,...-...,,.-. - -",._..-----_._._--~- · "" _'''',_ .._..."...._.. ·______n__._ .....-. __,_......"._.". _____ C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ,--_._._--~---,..._----_.._.~..~...._-_.---_._--_..__." -'-'--'- _____..__._____ . '_"_'" ____,_._,__"..._.__~..____._.._..,,'__ ___._..n___ .,._ · _.....,_ .., "'n.__~__.,.._._.,.,'__...___.._. ,_.._..."...,_____.____..._.._____ __.__.....__._n_ ._. ,_____...._, __.. ._...~__ · ._.·_.__._..._.,..".__..R..__......__. .~___,. ..,,_."'...._.._.__~__.._._,..___..___.__~. _ ._.__._ ___.__.._~__.___..._.._.__.__'". ."...._.__..__~....___.. .b...'..~_·,,···_._ ..___~_~..R._______ -------- --,.....,....-.....----.-...---...---..--- .._.-....,.,-".,..._...---_..._~._--,,---_. ........-."..---. ~._._-_..__._._---- .----.-----.-.-.--....--..--. ._-~.._._--_.__..__....._-_.-.- ~..".._,-._,~_.._.._-_.-~.__. -' -- _.. _...~..._ _...",___._.",~ ........,.. __. _._.____.... "....._._,.. _. ..,__...._._ ..__.__._"._~M'~..._..._...__ _.___. .RW_ _.___.__~__~___._._... _n____ .----..--., --"..-"._.-'~"'-'---- --'..-. .._.._____,.,_. _....._..m____..__.~,_,_..._"__.....'_.__,._ .........--- --- ...-" ...--_... --._~ . . ... n. __...._n~._.". ....,,_. ,,...,___._. . ._. _" _...".._.____._.~__~__. ..~..___..__n______..__ _.~. ._ _.. "..._.........,_......,._.._ Oil ".-.......,-....-.--- ""--,,-,--,.._...-.....---._, --._--_.--.....- .... ....- - ~ .-..-_..-- ..-..-..,-.-..-.-- _.... _._.._.__"'... ...,..,__on._" _'..'_._'_~_n__'_'___".__ __~_._ _......_.,,__.. ,___. u.___. . __. _ ~'___"'''.__''_'_'~,__. ........-...-,---..-._--, _.......--,---"----.._. Ii ... .. NPH 1.0. f sperry-sun DRilLING SERVICES Show Report Well Name: NORTHST AR NS 18 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: RICK MATSON 14191 to 14255 ft 8919 to 8963 ft Show Report No. 2A DatefTime: 7/26/2002 Depth (MD) (TVD) f Interpretation: Steam still analysis indicates the Kuparuk "c" would produce gas. Drilling Mud contained 2.5 % lubricants. No oil odorlsheen visually present in steam still samples. Sandstone in samples ( 14150-14250' MD) had no fluorescence, but a dull yellowlgreen very slow dry sample cut fluorescence was noted that corresponded to drilling mud lubricants. Steam still for 14195' MD rerun for repeatability of results. KUP ARUK "c" % I Depth 14195 ft Gas x Units 1418 Mud Chlorides (ppm) = 19K ---Fiõwlrñë-------~uëiiõñ------~-hõW'----------------------------------------------- ppm ppm ppm (Steam Stili PPM's in 1000's) C1 134.1 1.40 132.7 - -- C2 12.09 0.47 = 11.62 - -- C3 6.42 0.92 5.50 - - C4 3.90 1.40 = 2.50 - -- C5 2.47 1.33 = 1.14 --Prõaüëiioñ------=------==----------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 2 I Hydrocarbon Ratios C1/C2 11.4 C1/C3 24.1 ClIC4 53.1 ClIC5 116.2 I Depth 14195R2 ft Gas x Units # 1418 Mud Chlorides (ppm) = 19K --1=rõwliñë-------~üëtiõñ-----=-~l1õW'.:::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 125.6 1.40 = 124.2 - -- C2 11.75 0.47 = 11.28 - -- C3 6.07 0.92 = 5.15 - -- C4 3.92 1.40 = 2.52 - -- C5 2.44 1.33 = 1.11 --Prõaüëiío-ñ------=------=---------------------------------------------- Analysis x Gas Oil Water Non-Producible Hydrocarbons 3 I Hydrocarbon Ratios C1/C2 11.0 C1/C3 24.1 ClIC4 49.3 C1/C5 111.9 [ Depth 14220 ft Gas x Units 1477 Mud Chlorides (ppm) = 19K ---FrõWirñë-------~üëfiõñ-----=-~l1õW'----------------------------------------------- ppm ppm ppm (Steam Stili PPM's in 1000's) C1 101.3 1.40 = 99.9 - -- C2 9.90 0.47 = 9.43 - -- C3 5.11 0.92 4.19 - -- C4 3.20 1.40 = 1.80 - -- C5 2.07 1.33 = 0.74 - -- --Prõaüëiiõ-ñ------------------------------------------------------------------------- Analysis Non-Producible Hydrocarbons 4 I Hydrocarbon Ratios C1/C2 10.6 C1/C3 23.8 C1/C4 55.5 C1/C5 135.0 I f I Depth 14250 ft Gas x Units 1671 Mud Chlorides (ppm) 19K --1=iõ\Ñlrñë-------§üëtiõñ-----=-àl1õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 154.2 1.40 = 152.8 - -- C2 15.48 0.47 = 15.01 - -- C3 8.35 0.92 7.43 - -- C4 4.75 1.40 = 3.35 - -- C5 2.56 1.33 = 1.23 -15rådüët¡õ-ñ------=----- Analysis x Gas Oil Hydrocarbon Ratios C1/C2 10.2 C1/C3 20.6 C1/C4 45.6 C1/C5 124.7 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 -- -_.-- - C1 C5 1000.0 ------"---.- ---..-...-.--.----...--.- -. ------ _._------.,,--_._~.. -- - -..-.- ---...-.-"'-'-. ~ -.--- .__.~...._-,,--_.._-~.-_.._.-- --.. .-.--.-.-...--,----- __._n_._.__. __,,____~__.. _._...____..__.__.~ ._....... ,_____.._._.....__. NPH ._..__ _......__._..___.._....._.__,_.._..._ __ - . n. _ _....__.._.._..... Gas 100.0 - -- -- .".. .... . ;.~-:. --~¿...~ ~~~~: ------ ....--- 10.0 .._._.~._.__, .._m_·.·__n.____._.. ...._ _____..... ......_.__,__~._.,,_...""_...___ .__ ..-.- .-..-.-.---".. "--.,-....- ... __. ~... ,__.._"'__,,_. ..n __...____,,_._________. _.._.___._. _...__.__.______,_ _.._.... .._ ..,,_ .___. ,......__....__ ,____._. ".___....._n .--~-,----_.._._~.__. -----.-.--.---....-.--- -------.---...-. --.--.-,--.---- _..,_..--~---,-_. .--.- .--...---..., "'''--''-.....--.--' --- '.- _.- -.-.--..-- ._~....._-----_.- Oil .---.---,,---.-.-...- ---.----.-...--,..--...,... NPH 1.0 ..---.....-...----....,---...-,..,..., -.---.-.--- ...----...-......, - --,-_._.._.__..._-_.-~_._..._-----_..__.__._-,,--,_._."'--.------.-----.----.-...-.-.-.------.- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ._---_......._._._-------------._-~_._....._-_._.._-- --- -.-..-. "-'-_._--".~'''--- -". 1 000.0 -."........-"....--...--.".,.....-.....----.....- _..._..~..-------_._--_._..__.._--_.._- --. NPH 100.0 --' --- ~~~~:~~~~=~:~f~~=~~~:~~ ~"~:=~~:::"_~:~_~__...,__,_.._ Gas 10.0 --..----,--...---..---......-...-.- ....-,..-.-..-...---.---.-.....--. --'-'.--'--.-'--.'--..-.---'--"-'- ~---_._--_._---_.,-_._----_._.__.--- ---~--------~'-'--'---_._"-'-'----- _...._.__..__._.......,._______...."_ __."".._~_""_~._.____._." _____~__o_,_...,..._..______ Oil -----..-------------......---,--- ---.--.-------. ,-..----.-.---.-.-.--- --..----.-.------ . ----~--_._-"'-_.-._._---_. .--.---..---...-...-.- ---_....__.__.__..-...~._-_.. ----_._.--_.~.."......-- .........-----------.-...-...- --'..- -._,-,..._-_..._~,-,-_.,,-_."_.. NPH 1.0 "_~".___._.._.__.________ __.._______._..__.______. _'0"_- ...~..____._......._.__......."._ _._. I sperry-sun DRilliNG SERVICES Show Report Well Name: NORTHSTAR NS18 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: RICK MATSON Depth (MD) 14330 to 14465 ft (TVD) 9015 to 9111 ft Show Report No. 2B Datemme: 7/26/2002 I Interpretation: Steam still analysis indicates the Kuparuk "An would produce gas. Drilling Mud contained 2.5 % lubricants. No oil odor/sheen visually present in steam still samples. Sandstone in sample ( 14350-14400' MD) had a trace dull orange fluorescence with no cut fluorescence. Sandstone in sample 14400-14500' MD 10% moderately bright yellow fluorescence with a very very slow dull yellow green cut fluorescence. I % Depth 14300 ft Gas x Units 808 Mud Chlorides (ppm) = 19K ---FiõWlrñë-------šuciiõñ------s-Ji'õy¡----------------------------------------------- ppm ppm ppm (Steam Stili PPM's in 1000's) C1 94.1 1.40 92.7 - -- C2 9.29 0.47 = 8.82 - -- C3 4.97 0.92 = 4.05 - - C4 3.27 1.40 = 1.87 - -- C5 2.16 1.33 = 0.83 - -- --PrÕ<1üëiiõ-ñ------------------------------------------------------------------------- Analysis (X1Gas nOil nWater nNon-producible Hydrocarbons 2 % Depth 14350 ft Gas x Units # 935 Mud Chlorides (ppm) = 19K --Fiõw1fñë-------Šuciiõñ-----=-S-Ji'õy¡.:::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 91.2 1.40 = 89.8 - -- C2 12.18 0.47 = 11.71 - -- C3 7.82 0.92 = 6.90 - -- C4 5.50 1.40 = 4.10 - -- C5 3.51 1.33 = 2.18 --Prõaüëiío-ñ------==-------=---------------------------------------------- Analysis (X1Gas nOil nwater nNon-Producible Hydrocarbons 3 % I Hydrocarbon Ratios C1/C2 10.5 C1/C3 22.9 C1/C4 49.5 C1/C5 111.4 I [ I Hydrocarbon Ratios C1/C2 7.7 ClIC3 13.0 C1/C4 21.9 ClIC5 41.3 I I Depth 14450 ft Gas x Units 1058 Mud Chlorides (ppm) = 19K --1=iõwirñë-------šuciiõ-ñ-----=-sl1õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 134.8 1.40 = 133.4 - - C2 14.06 0.47 = 13.59 - - C3 8.21 0.92 = 7.29 - -- C4 5.17 1.40 = 3.77 - -- C5 3.34 1.33 = 2.01 --PrÕaüëiiÕ-ñ------==-------=---------------------------------------------- Analysis (X1Gas JlOil Jlwater nNon-Producible Hydrocarbons 4 % Depth ft Gas x Units Mud Chlorides (ppm) ---Fiõwirñë-------šuciiõñ-----=-S-Ji'õy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - - C3 1.00 0.00 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 --Prõaüëiiõñ------------------ Analysis I Hydrocarbon Ratios C1/C2 9.8 ClIC3 18.3 ClIC4 35.3 ClIC5 66.4 I Hydrocarbon Ratios C1/C2 1.0 C1/C3 1.0 C1/C4 1.0 ClIC5 1.0 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 - .--.--- ----- -~------_._. --.---------------..-..- -.---.- -- 1000.0 .-.------.-.---.-- - .--..- .---... ..------ -------.-------- .._---_._-----------,-~- ..'-'-'. ..--.-'.-- -.._-._~_. --. .- _.-_,-_..._._.---~.--..--._..-._-- ...-- -~---_.._---. '-'---'"--'''''---'- ----..-.--..-.- -.-...-------- .--.--------.-----.--- --.----- . -_.~-_.._-~--_...- .--- .__._~-----_._-------_._- ------.-----,--.- -- - ---".-..- --'..- _ _..______.___ n NPH -- .........- ----.-...-.- - -. 100.0 Gas 10.0 ~ -_.----,-,,_.__.- ._-------_._~_._--_. -'--'-"--"-'- ._-~----_._-_....~._._--------_.~._._-_._---_.,,_. -..... -..-".---.--.-..-.-..--.--- -.-.-,--..--,,----.-...-.-- ,,--....--... Oil -_.,,_.'"-,,_._.._.__._..._._-~------_.-.... ..._.--~.._-~- ..........,-.....--...-.-.-- NPH 1.0 ---,-,---......-----,.-..- .--.....-...,..----...- .....--,-....,-,.....---,..-. ~._.__._--_._.._.~.._._.~..-._._._------.__."._-~------.-.-.-----.--.".---..,-..-.---.,--..,..--..--.-.-..- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ".,.-..--...--..- --_.",,-..... -.-----.-.-,--".-...- ..._"'-'--.--~--.-'-"--.--"'-" ,. 1000.0 - ------_._-~---_...,._.._- ------_.._,._.....~...._-_.._---- -_.-~.__..__....~.~"._--,,-- -.---.---.---- --,...._.._.._.~_._".. ._-_..._--_._,._....._._,._,_..._.._,,~ ._.._.._"._~-----,-~_.._-----,....._.- ---_._-_."_.,_.~_._-,.._..._.- -_...._._-_.._-~-~--_._-~-_.- ._- -.. .. ... ---.-.-----.-.-.--. -~.._..~_..__....,...- ...... _...,._,_._...._._._.._....._~.._-- --.-.-- -.----,.._--,.._-,._...,,------, -----...---.---. NPH _.___~_,,_.___..__,__..~__,_.~..,_...._....,.__,.._.,__.._._______.__. _..___"___.._m..'___,~._~____..__,,..__.__ 100.0 c;,,,_,,- ~'-'d- - -' ~~~~.~~==~:?~~~~= .~=~~-=~~~:.~.:=:~-~=~::~_..- ,,,- ...... ..:_.:~~~....~-.~~~..~:..=...=' .._~.._-_.,_.._.._,.- Gas ---.-.-,---.,---.--...-..-.----- ...---- 10.0 -----"......_-~~_._.._..".., ....-..---..-.-.---.--......-........--.-.--" ..."....-...-..-...-..--.-.-...-.-..-..-...-.....- -.---....-....-.--..--.----.---" .-----..-..........,-...-..--,----- ..--.-.....,..---.,-.-..-..--..-.-- _____. ..._.......__.n.. .__....,_. _",_ _ .n_'.__ .__..___._.._~__ .,_"., _ .'"__".._ __,.. ___. .___. __ ----_.,- .~._._._--.---_._--._.._..,,---,- Oil ----..--.---....-...-- -..-.---,-------..------.---... -...---------.----.---- ---'---'._-_._'--~- ____.._ _._..__._~__,_" "_..__,,_._.._,,. __. ____.__n'_.______._. _ __ n'_' .. __.__._......... _____.. .___._.__..._ ----------.--.,..---. ---.-----.---...."'.-....-- ----.-.-...--.----..-"..-....-.,-. ~. NPH 1.0 . sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS18 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY I Depth (MD) (TVD) 16710 to 16865 ft 10989 to 111 34 ft Show Report No. 3A DatelTime: 12/31/2002 Interpretation: Steam still analysis indicates the Ivishak would produce oil. Drilling Mud contained 3 % lubricants. No oil odorlsheen visually present in steam still samples. Conglomerate in samples ( 16710-16830' MD) had abundant yellow fluorescence with moderate to abundant milky white cut fluorescence. A faint to moderate oil odor was noted in samples 16710-16810' MD 1 % I Depth 16716 ft Gas x Units 236 Mud Chlorides (ppm) = 18K ---Frõwirñë-------~üèiìõ-ñ------~hõy¡----------------------------------------------- ppm ppm ppm (Steam Stili PPM's In 1000's) C1 46.8 0.52 = 46.2 - -- C2 7.38 0.27 7.12 - -- C3 7.38 0.54 6.84 - - C4 5.34 0.77 = 4.57 - -- C5 2.95 0.76 = 2.19 - -- --Product¡õ-ñ------------------------------------------------------------------------- Analysis nGas [X10il nWater nNon-producible Hydrocarbons 2 % Depth 16724 ft Gas x Units # 497 Mud Chlorides (ppm) = 18K ---Fiõwiiñ¡-------suèiìõñ"-----=-Šhõy¡.:::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 78.8 0.52 = 78a3 - -- C2 13.96 0.27 = 13.69 - -- C3 11.74 0.54 = 11.20 - -- C4 8.02 0.77 = 7.25 - -- C5 4.18 0.76 = 3.42 -Prõauctiõñ------=------=---------------------------------------------- Analysis nGas [X10il nWater nNon-Producible Hydrocarbons 3 % Depth 16754 ft Gas x Units 144 Mud Chlorides (ppm) = 18K ---Frõwlrñ¡-------~üèiìõñ"-----=-Šhõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's In 1000's) C1 20.1 0.52 = 19.5 - -- C2 4.54 0.27 = 4.27 - -- C3 4.51 0.54 = 3.97 - -- C4 3.88 0.77 = 3.11 - -- C5 2.41 0.76 = 1.65 - -- --Prõd¡jëtiõñ----------------------------------------------------------~-------------- Analysis nGas [X10il nwater nNon-Producible Hydrocarbons 4 % Depth 16800 ft Gas x Units 135 Mud Chlorides (ppm) 18K --"Fiõwirõ¡-------Š-ucilõñ"-----=-Šhõy¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 16.9 0.52 = 16.4 - -- C2 3.75 0.27 = 3.48 - -- C3 3.66 0.54 = 3.12 - -- C4 3.22 0.77 = 2.45 - -- C5 2.12 0.76 = 1.36 - - -Prõd¡jëiiõ-ñ------------------ Analysis Hydrocarbon Ratios C1/C2 6.5 C1/C3 6.8 C1JC4 10.1 C1IC5 21.1 I I Hydrocarbon Ratios C1/C2 5.7 C1JC3 7.0 C1/C4 10.8 C1/C5 22.9 I I Hydrocarbon Ratios C1/C2 4.6 C1/C3 4.9 C1/C4 6.3 C1JC5 11.8 I Hydrocarbon Ratios C1JC2 4.7 C1JC3 5.3 C1JC4 6.7 ClIC5 12.1 -------------------------------------------..-- C1 C2 Hydrocarbon Ratios C1 C1 C1 - - C3 C4 C5 --.- _._--,-. --~~ .---.------.--- --~_._-_._-_.._---_.- 1000.0 ""'-'"--'-- -,,-------.----.-.-.-.---.- ---------------- ..---.-.----.----..-.---....-- --.-.- -------..,-..----..--.".--,----.-.,---...---.-.--.-.--- _.~ -.~--"...._._-- - '-.-.'- --. ---------.- _.__._.___.___,~___~"_ ______..___,_._ ____.._. ___·',_._'__n__.__ -_.._----~.__..---- '--,----------..---.-.---...-." --- -- .--'-".--'--"...--.-.---. -,-_. NPH ____~___h.._'_..,__.._,_ __._._______._"_....__ .n__.___.,.._,,_ - -. 100.0 i.:::.ø~::~~:~~ -.-------.---- --,-_._---..-.., ----.,.----.--.,.."'--,. Gas 10.0 __:___==_<=-===~ £~~~.~~~~-~==~~~===~~--~~.~-~ ~-~~-~--~-;=.~~;.~~ Oil ___'"___..~____".._ _m_.__.._.___._..,""__"._'_"_'__""__"_"'_"'__''''__ NPH 1.0 .. ,_~__'._,_,._~___.._".____.____ _____..._._...___,,_"_""_.___ _'_' __~.~,....._. ''''_._..__._.."._._._n_... ~._..__._.__..__.__..~-_..,-"._. ...__.__.'_._-~-,_.._-,._----_..._.__.._--~. C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 __.,.,.,_.__.~_____.____.._._____._,._.~,._,___...._.._.·______.n____.._____·_ 1000.0 ------------~-- ----...-..---.-..-..,." --~-,,----~,_._-,--..._-"...-.-.". ,--.._,-_..-,._-_.~.,._,--_._-,.,,- ..--.--,.----..---.....--...----- ________.__.__n___ .__________..._.._____.,__._.__ .·_'"._____~,__,_·__·__~_.'___..h.... _".___.__._,__,,__.,~.,~.___ -_..,_.-,-~_._..----_._._-" '._-'-""-"~-'---"-..",--.-,,_..- ...,...~..".._._.,-..~.~-_.,._~.._-_._.....".- _._-"'_._~_.. _.._-..,--..._,~..._-,._-,. -_."_.._-,,,.~._.__.~~.....,,-_._,._~--,~- "..---., -_.--_.~"--_.,,.".""_._-_.- ---.- .._---~._...~,--~---" _.~--- NPH ., ._..".,,--,_._"'--.---_..._._,~-~._,_. -,.._-_..-,-"._,-_._.",_...__._--~._.~, ...-.."'-..-.,- --- --.._-"-.~-----..'---"--~- ._..._...._.__.~._-,~_._...,_._--_._--- 100.0 --' -- ... ..--.. .... ~~~~~.::~::~~=~~::~::-::-.':':'-,::: :::=....:=::.:.:.,---..- _, _ .""__...__. ..._'_'_..' '.'"___'_.._n~__ n. ...,__" ...._. _....._._..____.. _,_. _.._ ....._.._...."..__.___.._....._____._.. ---,-_._,-~'""---_._-_._---".~-- -~.~---_...~...__.__._-.._._. ......, ..-. ......- "...."". . ...-..,,-....,.--- .-. Gas __...__.____..__,____._.___.... '-'-'-'-'-"'--'-'-""0"_.. .._._._._,,__ ___.__~_, _."..~ ._=..:-.:._=-=-..::--;.;.-_..._.._------~-~,..~'-~._._~.." :;; ¿=-EJ~:ïf!!!J!!!! ~__,_·.."~··..._._·___n~__·_____.__..___ ___"__.._~_....._.....______._.__~ ,,__. .,.__.__~."__...._._..__..."._ --..,,----._------ --- _._._-~-,--_.-._.,_.~..~-_._- NPH 1.0 -.._.__.._---,_.._-,..._._-_....~..._~, _._----_.__.._~ .._.~......_-- -~-_...._._._._.~._.~._.__._. I ~ ( sperry-sun DRILLING SERVICES Show Report Well Name: NORTHSTAR NS18 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: KEN LEMLEY Interpretation: SEE SHOW REPORT 3A I I % Depth 16835 ft Gas x Units 68 Mud Chlorides (ppm) = 18K ---¡:rõwlfñ¡-------§üëüõñ------sh'õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 7.8 0.52 7.3 - -- C2 1.66 0.27 1.39 - -- C3 2.01 0.54 1.4 7 - - C4 2.24 0.77 = 1.47 - -- C5 1.63 0.76 = 0.87 - -- --Prõaüë'f¡õñ------------------------------------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 2 I Hydrocarbon Ratios C1IC2 5.2 C1/C3 4.9 C1/C4 4.9 C1/C5 8.3 I I Depth ft Gas x Units # 935 Mud Chlorides (ppm) = --Frõwlfñë-------süëüõñ-----=-ShõW'.::---------------------------------------------- ppm ppm ppm (Steam Stili PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 -Prõaüë'fiõñ------====-------=---------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 3 Depth ft Gas x Units 1058 Mud Chlorides (ppm) = ---Frõwlrñë-------§""uëüõñ-----=-~hõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 1.00 -Prõaüë'fiõñ------=-----=---------------------------------------------- Analysis Gas Oil Water Non-Producible Hydrocarbons 4 Depth ft Gas x Units Mud Chlorides (ppm) ---Frõw1fñë-------§""uëflõñ-----=-~hõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 --Prõaüë'fiõñ------====------ Analysis [ Hydrocarbon Ratios C1/C2 1.0 C1/C3 1.0 C1/C4 1.0 C1/C5 1.0 I I I Hydrocarbon Ratios C1IC2 1.0 C1IC3 1.0 C1/C4 1.0 C1/C5 1.0 I I Hydrocarbon Ratios C1/C2 1.0 C1/C3 1.0 C1/C4 1.0 C1/C5 1.0 I ---------------------------------------------- Depth (MD) (1VD) 16710 to 16865 ft 1 0989 to 11134 ft Show Report No. 3B DatefTime: 12/31/2002 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ._---~-"_.._"----_._-_._._--_._-~_.~- 1000.0 .-.---...-,.---,.-.------- --,,_._.._--,-~---,.-. -_._,-----~,._-_.._._- -.-.'.....-.--...-------------------.-----..---- -- _'"_" - ____~ nO. .__.__,___.__ ___no ___,,__. ____._.______. _,._..._,_.,_~ _ .~_ .__. .__.'~ _____. ---~------------- '-'- ---.--------- ____.__.____~._____,_..___ _._0_.__-·--·----- ---,". ----.---- .----....-. -.-....-.-.--..---- -.. .,..-...-.... ,--,.._--_.._.._---~ NPH 100.0 - -. --- --------.---'"..-.--"'.---.--" ;~:..---:-~~~~~~ ::=====~:~~=-~:=~===~.===-.. Gas ------ ...-....... -- ... - -- ~-- 10.0 ..~~~~~:~~~~~~~~~:~.~:=::~~~~~ --_._._--_._-~."_._~--_._- ---_._-.-"-_._-~~-.-.,,,._,, --_._~,,--~._-- Oil ."..--....-..--...-,---.-.... . ~ - -_.._,--,_.....---~._._.._..- ---. .- .-. ."....--..-.....,..------..-.. ---_....__.._..__.~._._----_...~..,.- -.--..." .-- --_..~--_...._.. ...--...-...-,.,..- .- NPH 1.0 . . . . .,-....-..-..,.-.-..-------.--.-- ----_._-_.__.~.._-------_._----~~-_._.._....._.".._...--......--.--...----.-.---".-..-.---,---.---- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 _._..._-,..~....,-_._--_.._~--_._.__._--_._...._-_.__._--_._-_......._-,---....__._--_.~- 1000.0 ~ '--'" .._.._---~_......,- ---..,--.-...-.- ... _. ~-,,_.~_.-- .---.....-.-" ._.....-~"- .. __ . _U_._". _._. __. .~.__....-.~-----"._-_.- _._.._-_.~ - - -. ..-..-..-.-....." ~-_.__. - -.....-...-..--.-,...-. ._._.__._....___.___..._.._~.___ ._,._..._.._..._._....__..._....___~_._ .,..._.,._.__·_._..._._.__~.u.·. NPH 100.0 --' -- _::~,:~~:.::'_--- -..----...---.-.-----.- '~:::~,~::~:::~~:~ ~~~:=::=~='::,=::==~::_.__._,_..._.._._-- ...-., ____'.... _._. _____.__.._ ..___ ,....._...._ ".. n__·._"_, _.._._,_._.._.._~___,.._._ .____..._______._....._ ..._,__.____ ._,..._----_...__.__._._-~...,'-_._-_._-_..._-.. -......----.----- Gas ----.-..----.-------...-..------------ .._--,._._-'~..__.._---:::.~.-:: -~-;.;;_.__._..-----.~~~..'"~..._._-_.- ...--- 10.0 - .. "-......-.. ...----.--..-.-.-...----..-...--..."-.-'" ........"..--.-..--.-----..--,,-- .------.-.--.-........-...-..-...-..-- ._~,......_._......_._------,..__.._~".,. .-....-".-.....---. -"---"'''''--'''-'-- -..--.--.... . ."_.... '''-'..-. .._~......_-_.._- Oil . ..--.-..-..,.--.,.- ...---.-.----- .....~------------~_.__._--- ----------.-----....--. ----...----......-- ....---,- .._....__._--_._-~_._._....,~_._... ,---_...._.-._--,,-_.._..__._.~.-.~_.. -.---,-.......---. -.--..----.-.---- _..__._---_..~--_.~,_...._..._- --_._--~._,--_._._._.._-~.... ------.-----.--..... --.......-..._.,...-.._-~.._~_..- .--.--- NPH 1.0 . . . . ;~' \ ,.' .~~\ . '~..:' .~ . : ~. ~\:'., ~ ~~. ".;. " 1 0000 units = 1 00% Gas In Air t,:" ~,~". \ '..;' , ! ~! "\ ~.. Logging Engineer: Tom Mansfield / Doug Wilson 1 .~··~~;~~J.:'7.·':/.:~·~', :'~ 24 hr Rec; Moved rig over NS 18 at 21 :00 hrs. Currently rigging up and building spud mud. I ; :.~'/. ~..' ;1.: '.'...._~ 'i:~ :'\,r""}~';:" . :'''~ jF,··~ ~\ ~~., ..~: ··;~:':·'.~f.~'{-'::>~~,·,"·;'P:~· '~".:' ,', ' '~''><:'.~ "~";i' .,. '.~~" Ä ~\""~ ~.~':.',":!t::~·· ~t ~~1)~W1~~:i!~1~' ~,;s~,¡~_~~,;,";·ti::. ~'-.~'¡: - :.,< ':,' ".:, ';');. J',' "~"::;<" ~ ,,': ,.:.-. -":",/~,~~~~~~~ ~,' tl~>. " . oz. ,-','.'.. . .' ,. ,. :.. ... % Lithology Sst Sltst Sh Gas during after % I . I . . "'>:'I~·rr.::'.' ......~~~.. ';- ,"', ~~~: ppm ppm ft ppg Trip cl: ppg Short Trip cl: Feet of Fill on Bottom: 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ,- ':;~ l' ': . "::~' .~". ,~~,~,~~. .~. .~:'~~. '.~'~ ~ '),', I r'. ,~..tl' ~.. ? ~:.....f., .~I~~:~'~,\:I;S::.:'~,r~:~,.~~/j.~~ .., .~' ~~ ,~:,~" ~ ,t ,I , ;.,.~~.. 'Î qoLCM _ ~ :.." :"'·."\IH,'¡;~¡~~~>':''i,.:".·,:;¡e:·',~,'!\~,fI~;::;'''i''': ·'1,~~.¡:·'-i(1,;·i¡,:~!,··\ .¡;~!.t;iI~;...::;~ ,;, . '. , " ,...,. ,,"::'-:. ',', ..,' ".' '-:'m!°1.., Connection Gas and Mud Cut f ft units _ ppg ft units ppg 1 ft units _ ppg ft units ppg: ft units ppg ft units ppg "..D:.-...·:¡;"S;··[]lm:~. ·:IID:OO'~~lmj:x:·:œl___~_if8) .. before after to to to to I Drilling Breaks O' .0 , < ",' ,. before I Drill Rate during Depth I ppg ppg ppg units units units ft ft ft ; ¡,; ..', ':'~...(..:~¡':"/> :~."",:~~~"~~~"..~~~~;.,.,,.;:~~~,;.\\~)'.;.¡'" . ':'" I % % Current Lithology: ~.' ,~I . r:" " , ,", . ...t~.;',.'· :,.......'..~~~~.,r;.,,~~..:', ";;'i,,; I_;'r.":~JI"·"· to to Trip Depth: Short Trip Depth Tight Spots: I Jets: \ \ \ \ \ TFA: ------ Total Revs on Bit Footage for Bit Run Mud Cut Mud Cut to % Mud Wt at Max Gas Ibs/100ft2 pH --- ml HTHP Gel~ / API filt Ibs/100ft2 ",.' .'~ '.- I~',' :'~"'\:.; ¡" "J \'_ij",j.~"~ ",,~.' Trip Gas: Short Trip Gas: ft ft '~ ',.' ( ·t.;~;'~~1.f.~~ : ",:"",t;., ~i~~""''':'~'~¡''' .~': ::,: à"::r;'~:~: ~t:,r" ,~,I.: ,!"!:.r;:f<¡. ~..:: ~~:1!~:f~~~~-~>'" ,,:..~ ":., ~...~, ".'. .' ,~ ',Jr. .':: ~. ".:. ' .~: ~ . .:.' :,. I", "", ';. .....! ' ~ '. , :",...{~~'.~,/.~:~_.\;;: .-:':> ';;",'.7".';:~'..~, ~-\\.~~':~'1',:' ( Sd ppg g¡::rì g¡::m f ¡:: í'7ì f¡::m .' Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC Pump 1 Pump 2 Pump 3 Pump Pres 1 7/15/2002 o o Rig Up Polya / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Bit Size: Hrs. On Bit Type: RPM: secs cP YI Visc PV ppg ppg Mud Wt In Mud Wt Out I 24 hr Max ft/hr @ units @ deg F @ BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 24 hr Avg ftJhr ( unit~ ( ( ft/hr units Deg F r R.O.P. Gas" Temp Out Current Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sper'r'v-sul' DRILLING SERVICES Î I " ," * 10000 units = 100% Gas In Air ,C,..' ."" .'. Logging Engineer: Tom Mansfield / Doug Wilson 24 hr ReCê Build spud mud. N/U riser and flowline. P/U drilling assembly. Drill to 230' and wireline gyro. 22 units gas from deisel contamination. Drill to 330' and POOH to change BHA. RIH. Drill ahead wi wireline gyros. . ~ " ...,. ': r' % Lithology Sltst Sh .~ ,~.~ 'f ppm I~ i ppm ,.¡;, ft ï, ~ . . "·1 "~-I .'Io,\,,'~ ~ ppg ;!" ppg ¡ Ppg ··r ,,"1.' %LCM , '¡ " ~. : "".''1: , . '.::: < :~ . '.:' ~r~'3 \ ;.: ~;r~. '~;' .....":' ~",: ,"" oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: "Ii' .r\:·.~·.....L" .. '~~/"}/':~~:I:::';':'r"'t':, 'i¡, '~~.::( ..~.>..,' 'r~.,(t :- I' ~i :'~~.., ~ ..~.:. ~"', ).~'~::'~ ~'. ~::c:~ '~~;I' ?~I '~!.~' :111<t:., .~ ~.: ~~, Sst Gas during before after after Drilling Breaks " 'I ~._ to to to to r""" '''''...·D...·''....,··,., ....~i H'.'."""""· i'·.'.·..,· .." ,,1 ~\' .~.. J;, '." Drill Rate during before Depth .... .l,lJ'r¡Ij.\",·f1,::r.·~:f.Iit/.:-" ~~,~~,~~j~I·.I'I·'·(i~.!-I·~~ft"·!' L ',' '. .~ iIi't', '.;.' I" ,.:'" units units Units 1!~".''¡'',·;, ".,', I I j il' I I I· ~.. .". ...,...:-'¡.~::~-::., ,,"" .....".::;:::::;~::;~:~p~:..,. "'--.~" "..ø~: " - - ft units ppg ft units ppg ft ::? tt - units PPg ft Units - Ppg f1 % % % % Current Lithology: I I Trip Depth: 330 ft Trip Gas: 8 Mud Cut: Short Trip Depth ft Short Trip Gas: Mud Cut: 'jl Tight Spots: to to to 1"~," J' ;".' ,- ~C;'''' "-T: "-.,,,;, ''':'''.''': ,.,.¡ ¡'':':''!'/T~~~t'':'}Í;I':<. ....,.. ,;;", :.: :-.'¡~"- "." ·.i-'.:';.'~~; .J. 'i/1' ~~:.\-¡ :!" ~-'I ;\~;I'/hc'... .... . '. "J:i.~.,,, ~~¡;"'(" "'~' .'. ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ..- .'..;; " ".,,,:;' :..~..~.,,~ ~.."t!:.ti,;:.¡'!-:" :.i: ?:,' "·"..;I:~.;. .~t'. ~,: ~~~,~~è Z~.~~;~,:':~.,~,,·L~~.::·~~~!:.\' ~~. .t:·.~ ~~~,~ ~~..;.~¡;;", ~:·<.;:~':..'Æ.;.~)~~_,.~~~,l:~~ifJ::;.;; .:'."r: {~~.~ "~'j. ~:- .~", ,....1...:' . .t"~"",~ .r ,~~~: ',~ \. J,~: :.',~. ~ :' , ' 1 .031 0 722 Jets: 20 \ 20 \ 20 \ 12 \ \ TF A: ------ Total Revs on Bit: 17.6k Footage for Bit Run 16 3.8 Bit Size: Hrs. On Bit: HTC MX-C1 50 Bit No.: Wt On Bit: Type: RPM: 1 5-10 --- 8.85 ppg 8.85 ppg Visc ~ sees API filt 10.0 ml HTHP _ Mud Wt at Max Gas _ ppg PV 19 cP YI 46 Ibs/100ft2 Gel!: 17 / 26 / 28 Ibs/100ft2 pH 8.5 Sd 0.75 % Mud Wt In Mud Wt Out I I I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 179 ft/hr 190 ft/hr ( 407 ft/hr @ 701 ) Pump 1 75 spm DH flow gpr.ì - Gas* 8 units 8 unit~ ( 22 units @ 300 ) Pump 2 74 spm Total flow 630 gpm - Temp Out 65 Deg F ( deg F @ ) Pump 3 spmAV@DP 45 fpm Pump Pres 930 psi A V @ DC 81 fpm 2 7/16/2002 722 722 Drilling Polya I Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spef"""'f"""'Y- sun o A I LL IN G 5 E A V I c:: E 5 I . ~. ..,.' .., ',,': ~.~ ~ '. . . "':..... ~. '.. . * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield / Doug Wilson TOP OF PERMAFROST @ 1210' MO, 1200' TVO BASE OF PERMAFROST @ 1597' MO, 1562' TVO Drilled ahead. ~" '~::. )~;': ~.: " :', .:~.~. ...:'~:~> '" ~~: .:. '~I~~,._:.~),.::; I,~ <~"....,~ , .".., .. ~. .'! ::-';"-" oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: J 1'1 't , ',:., . . J" ..~ .~. ~ . ,.":..' , ~;:~,."., "..:.~ ~: ~ ,j.' {- ~ 1 .~ '~f~~t;.~ r,~ 4 '~~";l} ~'r~',,~ :, :,,~'.~:.":.' :~ ' ,'~:i :~' .:'~~."/~!~./",;~, :.- ;: .:' {':~';~E~:';I . .~:~..~.~ ~;¡\~~..,~, :~'::" ..~ I' . ", .~I" , ..·.f ....,1. "'': j to to ~ to to .-~ ' '" i .>, ~~ ill}i; ~~' Current Lithology: % % % % %LCM '~~ - I~},.-.~"~ .,'. .":;>.i,·'' .\'$~~~,·;.g·i~~ß'(!i,~~''1('1,~'ì..4.''lt,:..,·lt~;tÞ#Xi!1r~"'~~~~~~~~;«l.'~v ~r#ß'w.t, \¡:1: ,-I.,it::'¡'~~':;"'<1·l.;r'iì'J"i.~~~w."'i"''¡'''.J'\'''lilÌ!~-:¡~ t""~, ;~~:t itcf''':-<t,·, -"J,¡, .~:, ::",~. 'f"<~.' ; , Connection Gas and Mud Cut , ft units ppg ft_units _ppg ft_units _ppg ft units ppg ft units ppg ft units ppg :~ h Units =ppg ft=Llnlts =ppg H_ullilS =ppg ~I" I·"'~·¡"I ;"""",.",,, ,..,:'/" ~""""''¡;'\'·~.I'~1."._....... . ""''''',,' ~.,~.. -1 ò. ",, ""''''~~ .... ',' ''''1,~·,·1''._ ..-~.;)u,,",...... ,"' ;·r. ",. ", ", ,·.,,,.~,~,'·'.."41".'- ..,..I·,...':/j......,..¡·~...· ,'.1.; ,,, ,'....,'.". ,,~;, "'. . ."'iI',..... '.;" 'a"".... I. ¡;¡; _.,ro-;... .,.... s..qj,",I IIf-~._ ·P-A~"'r...,..i"J"riffti..I; '_I .. ~ .. ~.....c. ....~.Y' :~,Ij,Ii'I~~;"",,~III!ii"~~VI 'õJ'oi¡~IJ' l t' '.. "I ,~. 'II ._~t..::.I.iIir. ~-, ~~..'~ R .. <I. l' I.f,"', ... : ' Drilling Breaks %; Depth Drill Rate Gas % Lithology \:~ before during after before during after Sst Sltst Sh ..,:t, :'.(!.r,,',··t;:a'·,,' '." . , 1 ;-~';~"', ';'''::¡:¡1'~''. . 'r " '. ;\.t· :.... -;'--:..' :.; . . ..... ~, :...r;... ;', 1 'f": . 1\" ppm ppm ft Trip Depth: Short Trip Depth Tight Spots: ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to ft Trip Gas: ft Short Trip Gas: to to .:,.:" . :'/. ...~;. :'~-·<~i.'. :~rt:~'; ..-..',:...... ~ ,~.,~'~ .r<~.<~..; ....~,-; If . .~:~": f~~~~~t.,~.'.';.&., ,I. . :~, ~. ~J ~~': ;':'::';". ~~~1\i"~. :.': .::~.:", ~..':..'::.:' .,>\I('~.;..:~..~).".\ \:~!.:'~,;\~:::.;;,~~< ,'.::'"[:: ;~~~~:'( ~~~'0:?::·:¡t"~j,~:~.,~·:r.:i0~~t.~~r',~:.:,~· ·'.-r,~~~...~~.~b.~·..~ . Jets: 20 \ 20 \ 20 \ 12 \ \ TF A: ------ Total Revs on Bit: 47.6K Footage for Bit Run 1.0310 2,618 Bit Size: . Hrs. On Bit: 16 8.6 HTC MX-C1 50 Type: 25-30 RPM: --- Mud Wt In I Mud Wt Out ppg 1.5 % 9.6 ml HTHP Mud Wt at Max Gas - - Gel~ 23 / 29 / 31 Ibs/100ft2 pH 9.0 Sd Visc 72 secs API filt PV 18 cP YI 46 Ibs/100ft2 9.20 ppg 9.20 ppg gpm gpm fpm fpm Pump and Flow Data 105 spm DH flow 105 spm Total flow spm AV @ DP 2050 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 888 64 113 24 hr Max ft/hr @ units @ deg F @ 24 hr Avg 304 ft/hr ( 15 unit~( ( ft/hr units Deg F R.O.P. Gas* Temp Out Current 340 12 65 1770 2268 655 35 3 7/17/2002 2,618 1,896 Drilling Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: sper'r'y-sun -DR!LLIN-G SEAVIC:ES Mudlogger's Morning Report BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: I I I I I I ( I I I I I ',." ',,'. , ~ . ~ :' . 't'~ ", ' 1 0000 units = 1 00% Gas In Air Logging Engineer: Tom Mansfield / Doug Wilson SV6 @ 3771' MD, 3055' TVD Surf. CSG pt. @ 4050' MD, 3214' TVD Drilled ahead to 4050', TO for 13 3/8" CSG. Circulate sweeps and clean hole. POOH to run casing. 24 hr Recê ;".. ,',J'~'~$;I,~'" ::'.\.:' .' ~,:,"~: !I'~' \'; ~.~" ~'¡£..~"~ ~~, f' ~·,'I·'. '~''''''.' 1:";' ~~. / ';:',,'; ~'~ _..,:...~, .::; '.'!). :~. '. :",. ,:,:1)';.:; ¡·1::~, : ~':','.. ~ ~~~~~-,f; ~ ,j ~/. t' '.~~:' .:....' ":.; r_:;~~~,-i~·:~,· ~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. , ' ',..,:. '. '.: ~,.'\:,~ to to to to I~~.· t',;;' '.," '.ot'",'. '""-:::':~~;\'IIiI\.d~';:;\~'1'!I~\\<r~"Jm\'*.f".~" 1;, ,...,.P':'!I.-...",..:-O' ··~l~~~"¡(,~;fl~tf.:.t~.I'" 'J:;'~ 'i:';"iiIoi'<:<.-!-Í".' ,It'",'-:-" ..... -t >.'" ,~~~,..:,,~.TI~ ' "; ;"~ ;""~~''''''''~'''1;'''~':- ,";~r"; I , Connection Gas and Mud Cut , ft units ppg ft _ units _ ppg ft _ units ft units ppg ft units ppg ft units ~: ft units ppg ft_units _ppg ft_umts t ," :,,:.~ .- J',:. ~'~~;""'~""~"'. 't",.....~, ;¿.'-.b.>.....~i-:. :...w...." ; .,..,.';\'..><1oÞ....~~trf.,¡;¡,¡",¡:-..~.......>.,"'.......~1 .!',.....,.¡¡¡,¡æ;,¡:..;..'" fir:', ,; ., I~M,_,~, ;.'._.....~iüI.>..;,.¡¡;\,'fH :.11' '\' .~~ ;.,~'¡',~ ,~: . '... )\,0,,' ''';',:,'';. . " I" -~.--, ,~.~,.,.~, "'~-"-::::::a~--" ~. -,- ., ..... .' ,. I Depth Drill Rate Gas % Lithology +i. before during after before during after Sst Sltst Sh r·",:",,· %LCM % % % % Current Lithology: - ,,",~~'l'¡'. 1.:·.'1 .', . ", " ·,d_',~_'·:':""·~"~'~~-.' ",..~·,~·~~,~fi.." ~.~-·r,:.:,~:~?:~. ~::r~·r_~.'r. "'.:":' :,~'. ·f..::!·' I..i' '~;ll,{,<;~I-! " '~~I···~t\lÌ·"'.'~~~·"'l~'·<L:' '., .:J.l'......:! '-'.' ':~.~'r"" I, ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to Bit No.: 1 Type: HTC MX-C1 Bit Size: 16 Wt On Bit: 40 RPM: 50 Hrs. On Bit: 20.1 Trip Depth: 4050 ft Trip Gas: na Short Trip Depth ft Short Trip Gas: Tight Spots: to to Jets: 20\ 20\ 20\ 12\ \ TFA: ------ Total Revs on Bit: 123.1 K Footage for Bit Run 1 .031 0 4,050 --- 9.10 ppg 9.10 ppg Mud Wt In Mud Wt Out ppg 1 % 8.8 ml HTHP Mud Wt at Max Gas - - Gel~ 15 / 20 / 24 Ibs/100ft2 pH 8.5 Sd Visc 61 secs API filt PV 14 cP YI 37 Ibs/100ft2 gpm gpm, fpm fpm Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 96 spm DH flow 96 spm Total flow spm AV @ DP 2100 psi AV @ DC 888 64 113 ft/hr units Deg F 24 hr Max ft/hr @ units @ deg F @ Current R.O.P. na Gas * na Temp Out 95 839 13 24 hr Avg 187 ft/hr ( 7 unit~ ( ( 2893 3445 4 7/18/2002 4,050 1,432 POOH fl surf csg Kidd 1 Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: sper'r')J-sun Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 DRILLIN-G SERVICES {¡; I ,,' ( I I I I I .' r'~ 'I . , ' ::! .. ~ ; . ' ':. .~ "',,:' . . J. : :..' ~ .. , , ,. 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield I Doug Wilson Run 13 3/8" casing to 4033'. Circ. casing volume. Max gas 13 units. Pump cement spacer and 24 hr Recí cement. . I,.. ~. ,;--;'.... .·~:I,·>.\_~, ' :-:.,:\''-:',:.~: :~~(.:'I~.~ ..::,. "'::~'''~'.~·,:~..\.t'';.:I~'.,'I;';,;·" :'.',,~,'.:"" - .;,,~ . ......." ',..-.' " ' .. , oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ";~~' ':":"', .,,;;':: .. ,';':<" ,,'~'<:::'':''.,:i ,'è",;,~..'J¡;\":"j~,.~ :~,..·"h..:;>',,:~::/,--:,:'.;,:,::,,!,'~:>'~":>.,:,':',' ',,:"''"'',;;'..,;. ' ,",' , ,;_"1'.;-,.:" ",.,,'.", ,,',',:'; ," , ':J~i 1:~: Trip Depth: 4050 ft Trip Gas: 13 Mud Cut: ppg Trip CI: ppm 'I'~ ,~¡~ Short Trip Depth ft Short Trip Gas: Mud Cut: = ppg Short Trip CI: ppm ':,;',: ~ Tight Spots: to to to Feet of Filion Bottom: ft ¡~.J .~.í' ,~,~" "~"~~~' ,,,,,ç .....";.¡',;,',;.: ~.~.~y,.k!i,. :.",\ ~J<t~' ·':';;'t1~~'.Y~1:'·".. ,>r.::W",<.(.';f ,,~,¡!{f,;t~i.\;,,~~~w.~¡, ,rv..'il\i".';;': "·'ÍO:~·,e·1.' .~..;,:'~. :. .," . . ,.J:kV·!~v;";.":" -C~~~"',. '"J-.".>' ' :"" .,',':" ,; ~':", , ',:. ~~ I ~ ~~ Current Lithology: _ % _ % % % %LCM _ I r>"'·~'~~;;-;_%~:::;~;'-'·'~-~~·;~'·~~;; "~';"~';'~M~1 ,} ft _ Units ppg ft Units _ ppg ft units _ ppg \ ,~ ." ,',. '" -'>:::~h~'·¡~'~\~'~·"~'^ '~~O;:~':~:~'~-::==~~~~~:s"~";'-_W~' .~~:; L::OIO~~ .~, ~-' 'I~",'.."."'.'.'.:........ before during after before during after Sst Sltst Sh ;~. ': to ,it to I to ;~,' to ~,~" , "!Ñ' t,~ ~ . ~.," ,','. "... 1.0310 4,050 20 \ 20 \ 20 \ 12 \ \ ------ Total Revs on Bit: 123.1 K Footage for Bit Run Bit No.: Wt On Bit: 16 20.1 Bit Size: Hrs. On Bit: HTC MX-C1 50 1 40 Type: RPM: TFA: Jets: --- 9.00 ppg 9.00 ppg Mud Wt In Mud Wt Out ppg 0.5 % Visc 52 sees API filt 11.0 ml HTHP Mud Wt at Max Gas - - PV 12 eP YI 28 Ibs/100ft2 Gel~ 10 / 13 I 15 Ibs,'100ft2 pH 8.0 Sd Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. na ft/hr ftIhr ( ftIh r @ ) Pump 1 48 spm DH flow Gas* na units unit~ ( 13 units @ Cire CSG ) Pump 2 47 spm Total flow 400 Temp Out 95 Deg F ( deg F @ ) Pump 3 spm AV @ DP Pump Pres 900 psi A V @ DC 5 7/19/2002 4.050 o CMT 13 3/8 CSG Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: sper'......v-sun o RILL I N G 5 E A V I c:: E 5 Mudlogger's Morning Report BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: '- ( ( ,( I I .... . ,..~.. . .."I.". .'1; . .... ,. ..'., :';". .~ .", .. ....... '''' .. ,. 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Doug Wilson 24 hr Reci Cement 13 3/8" C8G @ 4033'. Clean pits. Nipple down riser & nipple up BOPE. LID HWDP. P/U BHA. Build new mud volume. Prep. to run DP in hole. ,,:,; ' ,;.: <'"." :",~l~":: ~~,""" . ,.'.~.~ ~ .~\~~~ '11' " '1L"'~:'~'::' ~ ~.~~.::/ ' ~. ~, .;/.-'.,'.:, !~:'. :.:-~. ,. .. '" :~. . .~'. '.,; .:~} ..' ~,~~.~;).;..:,- ~>: c :~~·"'·";¿~F:. '. i~':~~ ,~~·"~t~~ ',-: ~ '·f'!',· ....~ .,,~~':;~;.....; ~,. :~:. ,-'.-- ,:t.~ '::tr ~;'~... ..:~;::.. ,~J1. .,:/~';";,,.,.....1:·' ' oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: to to to to % Lithology Sst 81tst Sh after Gas during before after D rill Rate during before Depth Drilling Breaks Connection Gas and Mud Cut ~~i,~. ft_units _ppg ft units _ppg , ft units ppg ft units ppg ft - units - ppg ft units - ppg ~ ~~~..z,",_.. !,.L' .r)l.II11IJ11l¡~¡ r~'1\~~ ,__11im~1PÐJlj;.~~'W ft units ppg ft units ppg ft units ppg ~F1[ 't~ IIf[lì¡m~~!l!JJf¡mn¡¡¡4OC.m,iaI I %LCM % % % % Current Lithology: I '.. .:::. ~~' ,';. V~I. \:,', ,':. .".. ~:~'.'=' ,:--~~"I.. .. . ppm ppm ft ppg Trip CI: ppg Short Trip CI: Feet of Filion Bottom: Mud Cut: Mud Cut: to ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: I ~... . ,_ ~) ~" : J,' '~.'.. . ;"0'. c, "I ....... .,.~. "'. ,'\:"'..' ~.,": ~~."'" ~~'.;. .,..··-.\r..'··-:'"'\····~I\ ~.' .. ., ," '~ . ~ .,; : ~ I: ...; ,.- .,;,. ... .1 ...;¡ '."., ;::.'. . " .... .'~, ( 6 \ x \ 12 TFA: 0.9410 --- Footage for Bit Run 121/4 Jets: 3 \ x \ 11 \ -- Total Revs on Bit: RSX238HF+GS Bit Size: . Hrs. On Bit: 2 Type: RPM: --- ppg o % HTHP Mud Wt at Max Gas 6 1 8 1 10 Ibs/100ft2 pH 9.2 Sd 9.2 ml Gel~ Vise 49 sees API filt PV 17 cP YI 23 Ibs/100ft2 ppg ppg 8.70 8.70 Mud Wt In Mud Wt Out Customer: BP Alaska Report No.: 6 Well: NorthStar NS 18 Date: 7/20/2002 sper"'''')j-sun Area: North Slope Depth 4,050 I DRILLING SERVIc::es Lease: NorthStar NS 18 Footage Last 24 hrs: 0 _. --.. Rig: Nabors 33E Rig Activity: P/U BHA Job No.: AK AM 22120 Report For: Kidd 1 Dinger Mudlogger's Morning Report Shows: Current 24 hr Avg 24 hr Max Pump and Flow Data I R.O.P. na ft/hr ft/hr ( ft/hr @ ) Pump 1 spm DH flow _ gpm Gas* na units unit~ ( units @ ) Pump 2 spm Total flow gpm - Temp Out 95 Deg F ( deg F @ ) Pump 3 spm AV @ DP fpm - Pump Pres psi A V @ DC fpm j ,(.. * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Doug Wilson 24 hr Reci RIH & pressure test casing to 3500 psi for 30 min. wI 9.0 ppg mud. Displace hole to new mud while drilling shoe track. Drill 20' new hole to 4070' and perform FIT to 12.5 ppg EMW. Drill ahead with no problems. SV6 @ 3768' MD, 3055' TVD, SV5 @ 4214' MD, 3313' TVD, SV4 @ 4730' MD, 3617' TVD, SV2 @ 5424' MD, 4012' TVD, SV1 @ 6164' MD, 4402' TVD :',".' <·5~, ~: ,';;": ~. ~ ~ "~:'~".:..,:.~;"..-:,~::.,: '.'~~ ..,.,;:",,, . .= . ,~ -";' '1~' :.~ 'r' '1.0::', .~, ~ '.. .,:.1: :::·~~·::I~.:~i ,,:',.: I :¡ }"~..~·.c ,¡:.. '.~. ,>'I' ,~ ,',.. '. ,'.' oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Approx. 2-3 Description of fillings: moderate amount of large casing shaving decreased to negligible by 5800'. i ""~~ ppm I ppm 'I ft ,) ....... ¡i;Io, . ~' ,~., ,'. ., :""".',·:"'W@iF~,,\;::;r'-~~~', ",~.',~,'jII,~~¡I'<;':': ¡;7.,'~~ '0( I,' ,. ;;<,W:o-:·:r:';~~ '!'4i'IJjIi!'~""'~''1..,( ,",,\.,,';.,,;"rfo¡~~.~..-il.'.' 'J..J'':_"!:!;'''~I i.',' '; .'-:¡¡,,1.'II"~~'" f"·"C",. ,: :: , . ': -:' ",1' . .", - .¡e:~.: Connection Gas and Mud Cut I ft units ppg ft _ units _ ppg ft units _ ppg ft units ppg ft units ppg ft units ppg ',I h_unllS ppg ft_unltS _ppg h_unils _ppg " ·'i .. I,,: '.. ',.(: t·...~"JV-,'¡'!~~:'t>I\~!:' ~~..~:.r¡..' ¡f;,:".;",r":.;"~':';;'~" '.,,:.,~.,,: .'",: -C'''Ift'~f'f~~;~'~1'f.¡~''~. ~':";"( '.;:I!.fl'Í""M.Ö\~'¡:!¡¡f'"hí~',~",·,,,·,,:,~t'i~"ð¡ ,""" . ·....._it:. ':f'"·\'v",;··,,,, ...1 :¡O" :",I"";';':";'J"'~:,~ '",,~~ "~~I\~~~ ¥, % Lithology Sst Sltst Sh Gas during after %LCM % % SLTST .' I:l/S' no . ~ "V~~¡:L ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: " .\ ~,-.: '.. .:'.:. ,,,,,:: ¡..,'" '). ,', ,'. ';. '-,~,"',\I\",";' '" I.' before after Drilling Breaks 20 % CLYST , :'. ' ,',', ,~.éI'>-." ..;-..~. '., ;.....¡;'.' to ':', ,~,' . Mud Cut: Mud Cut: to .:: ~... ·~fr·;d--· ~;'~':";'.. to to to to I Drill Rate during before Depth 60 SST 20 % Current Lithology: ( :"'~' ,;44"'\',..,........:,..:,... 'I' \.,. ::'~;\';'....;'" ): "',·t~ . . to Trip Depth: Short Trip Depth Tight Spots: ( Trip Gas: Short Trip Gas: ft ft ... ,¡.. .:~ r..··:;~~\·~'..~~,·'.;'~'.;.~: ;':"~'~' ".."~''-'f . l'.t:·'}' .':~~' (.... - . .""I~''''' '~·;It'·'·· .:":i,·~~ :~;:',~'\r..~·.....ç·I,...: ~, ( Jets: 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ------ Total Revs on Bit: 86.9K Footage for Bit Run 2,454 12 1/4 10.8 HTHP Mud Wt at Max Gas ~ ppg 8 1 12 1 14 Ibs/100ft2 pH 9.0 Sd 0.25 % gpm gpm fpm fpm Pump and Flow Data 105 spm DH flow 105 spm Total flow spm AV @ DP 1850 psi AV @ DC -n-- Pump 1 Pump 2 Pump 3 Pump Pres 890 170 320 7 7/21/2002 6,504 2,454 Drilling Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: RSX238HF+GS Bit Size: 150 .. Hrs. On Bit: Bit No.: Wt On Bit: I 2 Type: 10 - 15 RPM: .^ .,,¡, . I ppg ppg 6.6 ml Gel~ Visc 59 secs API filt PV 14 cP YI 28 Ibs/100ft2 4858' 6189 6504 24 hr Max ftIhr @ units @ deg F @ BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 9.00 9.00 Mud Wt In Mud Wt Out 608 148 80 24 hr Avg 227 ftIhr ( 92 unit~ ( ( ft/hr units Deg F R.O.P. Gas* Temp Out Current 175 55 80 I Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report spe~~v-sun DR I LL I N G 5 E R V I c:: E 5 I I.'.,: . I':.' ., * 10000 units = 100% Gas In Air '- ',;, ,"'f', '\, . Logging Engineer: Tom Mansfield 1 Doug Wilson UGNU @ 6852' MD, 4768' TVD I Drilled ahead. 24 hr Recé ~ .,:" 'n ~ ~ I..""~;'-~:~,~?-\t:,: ?~.~?;,; ~fo.",~¡:i' 'I .,~~ :~~.. '\~\fjl" ~,;; :. ;-, '~ ~> ¿, ~ "/( ~ , ~ ~' '. ,~. ,< before after " . . '¡¡~'. . '.-' " oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Approx. 2-3 Description of fillings: moderate amount of large casing shaving decreased to negligible by 5800'. "..".." % Lithology Sst Sltst Sh Gas during after Drilling Breaks to to to to I Drill Rate during before Depth I ,"rl,.', ", ~(;':'.a!'$',:,."!;,,¡,,.);,,~,'i1":,:J.:"'~:. N,~~"I ;~',',l', \~,,~:·.:·"·-i"·"~~:~''''''··''';¡~lt'r~',:,;.;\i~1':\:.~'y~:ï.~~t.l;,·"';.~,~'¡~:·;:;';"''.;',..+-,\<¡::,,:\'I''":'':'~~·''''':: . ; ~,>;';;$~¡i;"iII!tt:)i'l ,', .'>~"'~""" . ,,' \ ^,', . ,:,"it·" ' .,.¡ ..". ;'fj.':"'I'j Connection Gas and Mud Cut ft _ units ppg ft units _ ppg ft units _ ppg ft _ units ppg ft units _ ppg ft units _ ppg ft units ppg ft units ppg ft units ppg - - - II, .}-,: t;~~~·;).,,~~'; :..'¡¡í~~t::.·':é~,:~Þ.ì~:;"/.¡.~·~ìi1.;~.·~'.·h:-i:ï;¡"";:'·;.~:'t~~,~~~;,n};·IjI\,:;<v".~:r::~,:!''è¥~'~,~.'''J~~~.~~~},,·~,.,,/,u.:-,,~~,r''''i'i{'4:!r;''f¡' :.'wí;'f;¡.':.I..'.. ..~ ~loLCM 0/ .oJ ":,~' ~~.,:.;..- '~.~\~~-::'~ :·:f~:.~').t,~ ",~,t-'\~~~';\~:~~~;m~"'"1:'\Y, ';'·':'~i~',ii,t'~,. ';~,ûi..·,~,:~~·,~{:~t,,'5·~~}~".:/~~~:h"t1'~~¡Ji~"~~~;~; ,·ti.,1¡~~~i~4<~". ·~~~:'1~,",,~,:..~... ~ ~..I..~~~ :;: ~.;;:,!,~·;.:,~~,:r"_~~;;'·>~:,~~":::)i~,;¡ _1·~"···1,:-;'·':>.<;'" :..~:.,",: ,'~(lf',,':~.~··_~: ,,~~,:~ ~,,' ppm ppm ft ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ~ r:' " % SLTST Mud Cut: Mud Cut: to '. ' I·..~ \1-,'j, .:" ;' ·r)'.~¡'1 ~ .;'. '.", " :',\- .~, 121/4 Jets: 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ------ 29.2 Total Revs on Bit: 246K Footage for Bit Run 4,706 HTHP _ Mud Wtat Max Gas ~ppg 8 / 12 1 14 Ibs/100ft2 pH 9.0 Sd 0.25 % gpm gpm fpm fpm Pump and Flow Data 104 spm DH flow 106 spm Total flow spm AV @ DP 2300 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 888 169 315 8 7/22/2002 8,756 2,252 Drilling Kidd 1 Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: % SST % Current Lithology: I 70 30 ft Trip Gas: ft Short Trip Gas: to to I Trip Depth: Short Trip Depth Tight Spots: .~'..' , " ..'::' .,', 't"·,,,:~,·. \~,:'. '.¡¡,...),:~.¡(:-~. RSX238HF+GS Bit Size: 150 _ Hrs. On Bit: 2 Type: 10 - 15 RPM: ppg ppg 6.6 ml Gels Vise 59 sees API filt PV 14 cP YI 28 Ibs/100ft2 7888 6934 8756 24 hr Max ftihr @ units @ deg F @ BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 9.00 9.00 Mud Wt In Mud Wt Out 550 1087 90 24 hr Avg 122 ft/hr ( 140 unit~ ( ( R.O.P. Current 1 (on bone) ftihr 65 units 90 Deg F Gas· Temp Out I Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I sperr'y-sul' DRILLING SERVICES ~. ~, .... . ...."' * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield / Doug Wilson Drilled ahead. 24 hr Rec; [ SCHRADER BLUFF @ 9711' MD, 6324' TVD COLVILLE @ 10713' MD, 6905' TVD ~". ~: " ~1\'lf,7i~,'t~,i:;:'. ~i>'.I:,~; ~;c:,'~ '~" .,,:.~ ~r~ ..:d"·',r"_~·''":;' .:'. ~~:." ~'? !..):~...,: '.~,~",' . ~ ".~:',~',~~~:.}~~:.,~,,::(':t,-:~~:~: <': ·~,>'..'·~T·:.t,~).~, ".r!;" ~,:" ~'~~' 7' ;:',"',', ~.. ~:; ;~.~..~.;:" : :-¡,:>t:: '.:. ";\ï;:'.,¡. ."'<': ':, '." -.~ , .~ 1 24 hour accumulation of Steel Filings from Possum Belly Magnets: Approx. 2-3 oz. Description of fillings: moderate amount of large casing shaving decreased to negligible by 5800'. I ',~' I. ~'~''''''I~·'~.:'':~~ '.':.'0/ '_':~', ~."'",~,."".~ ~:~~:¡!,~'.~~'~~f:"t:.:~. "¡·:,ìt,·..~~.,'.~':;~'.~,"\',~ :.,....~.:_~.,'.,.",.~~..r';:~.:~·~';ër/,~\~'~~~;,~ ~ ""1'.", ~.:~': I~'·~ ,,~~~;,I:,,~ "'~~ ~·.~·I~. to to to to I % Lithology Sst Sltst Sh after Gas during before after Drill Rate during before Depth Drilling Breaks ft ft ft Connection Gas and Mud Cut ft _ units _ ppg ft_units _ppg ft units ppg ppg ppg ppg ( units _ ppg units ppg ~! units~_.,n:,'::~ J &'œ;;,w:w, "f_; 1"i units units units ft ft ft %LCM % % 75 % SLTST SST 25 % Current Lithology: ~'" ..'\.::.,...:,~/;?~; ,"/ '';.\.\--:, ~,~ ":', ,~~~ ~ .':-_~~,..!'_. :'~, :~_~;'r~~,:-;~' ; .'. . ";''''''¡'':; :·;':'~',~*,·;ì·':.~~:~kÚj;¡if~~':;' ppm ppm ft ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: [ Bit No.: Wt On Bit: >~.,,'~':' ...~. . :". . i""~' ;',l9I~ ,;.~~...'- ~..' ~'.'" ",',;,.:",,~.-;. ..·.:~::-.t~.'-7-r.; ;1·W':"i:;·}·:~i~~:~~.~~,~.:.-.·_~~~~t:'~'·'~~¡~:>f'~ ~ :":~:~ ~:; .. ~~~·"1"'~~\~':' "·~': : ')j,' :~'\~'. ,"if':.~~' ,,~~~~,,~. <'t~:'... ,; "c'. ,', ~,': :..1:, .:: ".:"'.~ ,;: ~~. .... ,. . '. ,"." i ;' (',:' '~a",."· Jets: 12 1/4 47.4 RSX238HF+GS Bit Size: 145 _ Hrs. On Bit: Type: RPM: 2 10 I 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ------ Total Revs on Bit: 398K Footage for Bit Run 6,559 --- 5.2_ml HTHP _ Mud Wtat Max Gas ~ppg Gel~ 12 / 17 / 20 Ibs/100ft2 pH 8.6 Sd 0.25 % Visc 60 secs API filt PV 14 cP YI 31 Ibs/100ft2 9.20 ppg 9.20 ppg Mud Wt In Mud Wt Out Current 24 hr Avg 24 hr Max Pump and Flow Data RO.P. 200 ftJhr 102 ft/hr ( 471 ftJh r @ 8883 ) Pump 1 104 spm DH flow gpm - Gas* 180 units 146 unit~ ( 285 units @ 10281 ) Pump 2 106 spm Total flow 888 gpm Temp Out 110 Deg F ( 110 deg F @ 10600 ) Pump 3 spm AV @ DP 169 fpm Pump Pres 2300 psi A V @ DC 315 fpm .. f 9 7/23/2002 10,609 1,853 Drilling Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I spsr'ry-sun DRILLING SERVlc:es r II * 10000 units = 100% Gas In Air Logging Engineer: Tom Mansfield 1 Doug Wilson '"'.."':. ." ,t, ." ~. ~ ' . . . I . .l ~~' ~."", ,"..' Colville @ 10713' MD, 6905' TVD Drilled ahead. I have waffied on Colville top and revised it: .t' oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: % Lithology Sst Sltst Sh ppg ppg ppg units units units to to to to after Gas during Depth Drill Rate during after before before Drilling Breaks ft ft ft Connection Gas and Mud Cut ft _ units _ ppg ft_units _ppg ft units ppg I ppg ppg ppg units units units ft ft ft I %LCM ~:>;i~~'¡;~~~?~*~;~··~~~i>:>"t~~.N·¡iþtd!ì~~~_"'À<~~~~:I'::.~,,~"·:¡,~M~:-:.~t-~;'~~~!~'!¡':t;~I~\'I~;$:,~:}f ;·tJf¡:':·.:·-(;'-:¿;f,~, % 90 % SLTST 10 % % SST Current Lithology: I ~. ~~:.'<~~,;~í.",~~~tf~ r:,~~';..' ::, ~.i,~~ ~;"::~~~':f~e~ ;c:' ',' ,<::f-!.f;!'·':1 ~~~"':"'~("¿:r.~.~'...~..~.~1)¡..;;. ':"',,', '.,,'J:~' ::~~:¡';:'~1 ~~;. }':~\~!;":~;~~~~;¥Jè,~~·~t~~'~;;;Jr:'t..,~, ;1;-~.' ./:~."~f.~,V)·..~~·~. ~r\.·;'·. ,:J."':.~~,' :"~Irt",~~}j;"~;;~~,:,-, J~,::~-~~{f~' '!~'i:";',~~~....'~: ,,:' ~ '..~"",(.:+;: '''', .' ;:. ?' i. I'''· ppm ppm ft ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Trip Depth: Short Trip Depth Tight Spots: Mud Cut: Mud Cut: to ft Trip Gas: ft Short Trip Gas: to to Jets: 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ------ Total Revs on Bit: 559k Footage for Bit Run 8,674 12 1/4 66.2 RSX238HF+GS Bit Size: 147 _ Hrs. On Bit: Type: RPM: 2 20 Bit No.: Wt On Bit: --- 9.40 ppg 9.40 ppg Mud Wt In Mud Wt Out 7.8_ml HTHP _ Mud Wtat Max Gas ~ppg Gels 12 1 16 / 20 Ibs/100ft2 pH 8.3 Sd 0.25 % Visc 56 secs API filt PV 18 cP YI 25 Ibs/100ft2 I Current 24 hr Avg 24 hr Max Pump and Flow Data R.OP. 72 ft/hr 113 ft/hr ( 252 ft/hr @ 12441 ) Pump 1 107 spm DH flow gpm - Gas* 265 units 185 u n it~ ( 381 units @ 11869 ) Pump 2 106 spm Total flow 901 gpm Temp Out 112 Deg F ( 112 deg F @ 12724 ) Pump 3 spm A V @ DP 171 fpm Pump Pres 3100 psi A V @ DC 320 fpm .. 10 7/24/2002 1 2.724 2.115 Drilling Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: I Mudlogger's Morning Report BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: sperr'y-swn DR I LL IN G 5 E A V I c:: E 5 ,~. . . " ì..t..L, . .~"'::".\ . "'" * 1 0000 units = 1 00% Gas In Air No HRZ, Kalubik 13830' MO, 8679' TVD Kuparuk 13885' MD, 8715' TVD Kuparuk C 14191' MD, 8919' TVD Logging Engineer: Doug Wilson / Mark Lindloff Drilling Ahead 24 hr Recê :,,).:~':',~~~.i:· J.;r\.,~'~·.':'!'.r~ .~! .;' '~·"'··~"'.I """1 ;''':~'~:,''.;.,'Ib'~~~~;~':r¡' ".\"~J"'.,~),.,,,,~, ',' oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: I to to to to % Lithology Sst Sltst Sh after Gas during before after Drill Rate during before Depth Drilling Breaks ft units _ ppg ft units ppg ft units ppg :~~1l~ Connection Gas and Mud Cut ft_units _ppg ft _ units _ ppg ft units ppg ppg ppg ppg units units units ft ft ft I I %LCM % % 60 % SLTST SST 40 % Current Lithology: [ .,' ~ ;':~:~ :'':''~~'#$f''~~~''i ';;;'!..~~·.;;~"·,:~.'\~~'f~fJM:~\,~:{'.~·,,~~,¿r;:'.'~rJ't~;;::~~'!;':~1':~~.f~t,~~:~:!:~~ ;. ::{·~~)';~~:::·~~;-'_~'~'~·~~"f'ir~~~~;r.¡:(\.~~~t.·<.i~.~:v· ~~?.!'~'''::~:'',' . ,', ~,,"1..~~..; . :':~\:'./'; '~~~~1"~;1 ~¡;f'¡:~1..:r~~·~;:.'rf,~:.~" ~ ,,' Ù' . ~,' ,.::¡. : <. "-:::~ ..':~,' Bit No.: Wt On Bit: I ppm ppm ft ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: ::'.11I ...... . ~'" -.' ~, .' ·."'-..'<,.:..¡;:'~~:-'i.:':\G ,"',;'.. ~~;\,::':..~. . ,~r~:~-·,'i.~~'~..... ... ::....·..·.~'~·~.P:~,~::.....);.:<·:'~~",tlij·~;;J.,('-~\·~::~~',,;~"":~.:' '...... .....-!....:.~.:~..;. ."'~. Jets: 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ------ Total Revs on Bit: 718k Footage for Bit Run 10,373 12 1/4 85.6 RSX238HF+GS Bit Size: 105 _ Hrs. On Bit: Type: RPM: 2 13 I 4.8_ ml HTHP 10.0 f\1ud Wt at Max Gas ~ ppg Gel~ 15 1 27 1 32 Ibs¡ 100ft2 pH 8.0 Sd 0.2 % -- Vise 55 sees API filt PV 18 cP YI 33 Ibs/100ft2 10.50 ppg 10.50 ppg Mud Wt In Mud Wt Out I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 16 ft/hr 119 ftlhr ( 268 ftlhr @ 12725 ) Pump 1 96 spm DH flow gpí7l - Gas* 918 units 412 unit~ ( 1953 units @ 14215 ) Pump 2 96 spm Total flow 876 gpm Temp Out 118 Deg F ( 118 deg F @ 14025 ) Pump 3 spm A V @ DP 166 fpm " Pump Pres 3510 psi A V @ DC 311 fp r.ì ~ 11 7/25/2002 14,423 1,699 Drilling Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report DR I L.L.I N G 5 E A V I c:: E 5 I sperry-sun " 10000 units = 100% Gas In Air MILUVEACH 14620' MD, 9225' TVD Logging Engineer: Doug Wilson 1 Mark Lindloff Drilled to 14693, TO 12 1/4" hole, Circulate hole clean, POOH, currently laying down BHA. 24 hr Rec; , ".t· '.,;, ~~j~:I\f..r", . ¡ I . . .~.' ,... . .~ ¡J,' "":1 (,I ~ Y<: .'.... Or' :'µ':·;.I"~,,,,~:~:. ~:,~s..~-, :~~'~:I'~'" ~."~ ';. . '\0 ¡) :: ~ i ,..:'~",..~, .~' .....~.~i~,!~\f "';:~', ~I '/',,' t" oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ,:," [ ;f¡,iW Connection Gas and Mud Cut I ft _ units ppg ft units _ ppg ft units _ ppg < ft _ units ppg ft units _ ppg ft _ units _ ppg ft units ppg ft units ppg ft units ppg I L - -- 1·,·,<:··Hií!g¡~h"i~__.-.mml:TI!~~J:ti.~..~~11'.l!m_IJ~·!%:~._\. Drilling Breaks Depth Drill Rate Gas % Lithology [ before during after before during after Sst Sltst Sh to to to to ,',: ":·~;;·"'~IiJ~~;.'<iirì:;âbì;¡'~ft¡'¡~_~~1i;;.Fi.~6!~~:\\t~'t,''i:!!i:iif.'\~~~~;;r~~i$Y~,!;~;l':i:if,':4;¡{.;¡fo:¡~~oJ.~;~;1'1.~:;:'~~":Ii-~~j<~~'~ìfd:¡;,:: '. ··".:,¡·":;>~0f:¡.,<,~<',, " %LCM % SH 30 % 50 % SLTST SST 20 % Current Lithology: ~.: :*:~?"\;:\~~~~:::',~:' ~~ .>'~::4::¡;~~~'Þ¥~~~"tt~~,~:~~~~;_~,..,~;"\~.i.'~:,~ \E~~' ~'~'.~~~~:~~~~~\r:t',~'''f'}';(rW~I~V~~i?J,~~,~~~~~~ß'- ~,~'::?f,~~.~,;'. ),~.' }'. ~ntr·,,:~ , ;-.:~~;~...;.~'~~~' ':';J:. ,..~¡,·',~;~~~:t3~~·":,~~,~;"':~ ~~,,:'~:,~~~"f ,,:¡.< ,:~." :'.. ;' ~ ',~.~. ,'~'.',~J ¡, . ":' :~;~~. ppm ppm ft ppg Trip CI: 19000 ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to ft Trip Gas: ft Short Trip Gas: 4030 to Trip Depth: Short Trip Depth Tight Spots: 4600 to I Jets: 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ------ Total Revs on Bit: 748 Footage for Bit Run 10,643 12 1/4 89.5 RSX238HF+GS Bit Size: o Hrs. On Bit: Type: RPM: 2 o Bit No.: Wt On Bit: I , . ~ _.',~ ""H:, . ~ ..,..:.,' .' ," _..;¿\ n ~.:....... ~ ";"~,-; : , f~"-',~::"\ ~""~\~",, "'~", .' ..<'_~;.,:(:~;.' .~~'" ....,." '. 'j: I. :""', Visc 61 secs API fìlt PV 19 cP YI 35 Ibs/100ft2 10.50 ppg 10.50 ppg Mud Wt In Mud Wt Out 4.7_ml HTHP ~ Mud Wt at Max Gas ~ppg Gel~ 19 1 29 1 35 Ibsi100ft2 pH 7.5 Sd 0.1 % --- I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/h r 70 ft/hr ( 113 ft/hr @ 14454 ) Pump 1 0 spm DH flow gpm - Gas* 0 units 305 u n it~ ( 957 units @ 14451 ) Pump 2 0 spm Total flow 0 gpm Temp Out 102 Deg F ( 118 deg F @ 14693 ) Pump 3 spm AV @ DP 0 fpm Pump Pres 0 psi A V @ DC 0 fpm I 12 7/26/2002 14,693 270 POOH Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sperry-sun DRILLING SE~VIC:ES I r" .1"" .' ~, " ',~', .:.: ~ .~. ; ,:'1. '.:;. : . " .I',q * 10000 units = 100% Gas In Air Logging Engineer: Doug Wilson / Mark Lindloff 24 hr Recê Finish laying down BHA #3, Pull wear ring, change top rams to 9.625, test door seals to 3000 psi rig up to run 9.625" Csg. Run casing to 3980" and circulated one casing volume- continue to run casing. Began seeing losses at 6626', lost 20 bbls from Stand 160-170. No returns after joint 170 and losing 1 bbl per joint. Total losses from 160 - 210 are 235 bbls. ;"..( ... .'-., <:.;:'H "~'I'.' ....)~.;,.\\.: .~ /.~ :::.I\"::'··':..i'~,~:.':~. '.~4·· oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: :. ,'.:::'/ ~I'. . I..·.. ,...; : :"'j~~., \, '.,. .: -.:':: .: , ~¡~:¡" ~., . . ;,~:.t:. 1"~j:··~~'~;',>· to to to to .~ -, Depth I % Lithology Sst Sltst Sh after Gas during before after Drill Rate during before Drilling Breaks ppg ppg ppg f t units units unlls ,.',.:-',0£:: ';.... ;':;",' ",::..'If£',1' ~:"'''''~'J",t·t'';~:':t'',ii'';¡O'i'V.~¡'''.J;,2\'':'''';::'''''''''·'· ."-~',;'. j ',,.,' ~~:'IðriÌ~.,.w~~"''''·d't1'''':~i~~II;¡Ir;,~;,',,' ,,"-'" ,(" -',' "I",,:~ ",<"\",':':'¡.;I'~',·,, ,-., :,,",, /,',' "" . -,,"",..1,', ~'" 1,1.,',.....· . ,.. , " , Connection Gas 'and Mud Cut " . : ft _ units ppg ft units _ ppg ft , . ft _ units ppg ft units _ ppg ft ,r· f1 uMs ppg f1 unllS ppg h I . I ",... ,I ',¡,,,. .:... ".1,. '. I;. '=L~~, .~; , .'f·';· .~~~;¡"' ..¡~ .~(?':.... .¡:~;, ',""_. .. ". ~ :n. r. ·i.·f,j';~.t,l':':¡ ~;J{!'~~"':'::~~~~!.;.I!i.:"f~{~¡":"~ ~...~~~~t:~':(.~,'" 'O. ,I. "''> !;._~ .' ~i ",. :~,!W~-I,,"'fl~· 1.1:¡:1:: t,: .(; ,,~~' , ',~j~~ I"i ." i ... ~ ." ,! '.\ 1 '. },~. ; \"p¡ r \ .~~ ,.. ',¡It\". I .~\~ - - , ;"~o),¡<;' O/oLCM % ft Trip Gas: Mud Cut: ft Short Trip Gas: Mud Cut: to to to '" _' h .. .~. . ..', ," ,of, '" ,,,.;~,'f,, ,. ~j ,~J.'- ....., .:.. ....,...'·....;..1, . 20 % SST 50 0' SLTST 30 ~,'Ó SH /0 Current Lithology: I ~ . 'I ... "''1.. ~~"''': . - ~ -':....:_:. . ..:. '10: ...., .. ,~..~ ,. , ~'. :,' . ppg Trip CI: 19000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft Trip Depth: Short Trip Depth Tight Spots: I ;';":::",::;"'", '~"!' f.1..,~.~<"~' '<~.. ',-;;'~..:_.,..J",'.~..'~ :. :...~~. ~ .....:~ ...:}.... :',..::.. ~;-r:;~:~'." '.; "«'!' (;':;~"""", :.i':,~~,:..~~3~:.,~'~¡$~~.c'-:::": ~>.~'::. ,'..:. .,'\'.: ;"::: :' :~. ...;,_.'t~·:; j~'h"'.:·,:.:j:~ ~,>; _1< :~_ ,....:,. Jets: \ \ \ \ \ TFA: ------ Total Revs on Bit: Footage for Bit Run Bit Size: Hrs. On Bit: Type: RPM: I 5.0 ml HTHP ~ Mud Wtat Max Gas ~ppg Gel~ 16 / 24 / 27 Ibs/100ft2 pH 7.5 Sd 0 % --- Vise 53 secs API filt PV 19 cP YI 28 Ibs/100ft2 10.40 ppg 10AO ppg Mud Wt In Mud Wt Out Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftlhr ftIhr ( ftIhr @ ) Pump 1 0 spm DH flow gpm Gas" 0 units unit~ ( units @ ) Pump 2 0 spm Total flow 0 gpm Temp Out 80 Deg F ( 84 deg F @ 14693 ) Pump 3 spm AV @ DP 0 fpm Pump Pres 0 psi A V @ DC 0 fpm 13 7/27/2002 14,693 o RIH wI 9.625 Csg Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I D R ~ !-!-I N G 5 e R v I c: e 5 5per~Y-5un I ~r . "1\1...' "',I '" . . ,1;" . . '~~ .' . " Y' ,'~ . . ~:: "~"::~,'. :.... ',~"'''-'; .::,"},:'.... ,,~.~ f~'·,',!,;(:~~~··. ~ ~ ':,,:\' ,": ;:, _ '. :, ,'~ . I .; ": ~:~. .' * 10000 units = 100% Gas In Air Logging Engineer: Doug Wilson / Mark Lindloff 24 hr Recê Started losing fluid at the top of the Schrader and continued losses till casing was landed around 1045 AM Total Losses 710 bbls. Attempted to .circulate, packed off, worked pipe and pumped to 1200 psi then bled off 200 psi at a time. Established Circulation at 1400. Staged up to 9 bpm- Pump cmt job, lost 53 bbls while displacing CMT. Currently laying down Cmt Head. Avg Gas while circulating 146 units. Max TG 1173 oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: . ' ";0 ~ " l. .' .. " . ,/ 'I " ,~.. . I~' ..,.. ,~..~..,.... I~'.~::;~>:.. ¡.j:', . ~ .... of . ,- i, ¡ Drilling Breaks ~~ Depth Drill Rate Gas % Lithology 11 .~. before during after before during after Sst Sltst Sh t to · ~ ====~ ~ ~ f ----~ ~ .~ {' I ',\" .JO \ ',",.. ". .., .' I :r~ %LCM 01 ,0 SH % 30 % SLTST 50 SST 20 % Current Lithology: :,>~.~;~_~~:~:~~~,;~,...', ~t~:;': . :~~.: :~, >:" .;.r¡~~, ':':o,i~,,~·~~v(,:,:~~,~t-:;.';;ftÁ~~ii~~~·,"'~'~~-"'.}¡~'~~; ;.:./~'~:~~~:W,~;· ,\..j'"i~,,¡.t s'~~~ );:·'~J~~¡~~~.~~'~':.~·~i}:~';f...;¿i.¡ ~1W:'::, ·:'.':~i .' ~\'; -, ~ '.:: \,,'....- .:~...:1~-~~:.'t, ,.>.:' ~""1~".,\L,~f'(',\" 'i~·;'~.:~I"~~' ,.h'.j.f~I\:i~::~~ "...<::. :' ~~¡ :'~. r~ ppm ppm ft ppg Trip CI: 19000 ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to to to Trip Depth: Short Trip Depth Tight Spots: 1173 Trip Gas: Short Trip Gas: 14666 ft ft ". "..,,\~i;.;.. ;.~ ,,¡'?:;,.' ",:' ,:.;.; '. ' "'" _~ : ,. '.~ .~;, ~ I \ \ TF A: --- Footage for Bit Run Jets: \ --- Total Revs on Bit: Bit Size: Hrs. On Bit: Type: RPM: HTHP ~ Mud Wt at Max Gas .J..92.. ppg 7 / 11 / 13 Ibs/100ft2 pH 7.0 Sd 0 % 6.2 ml Gels Visc 42 secs API filt PV 14 cP YI 21 Ibs/100ft2 10.20 ppg 10.20 ppg Mud Wt In Mud Wt Out Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 fUhr ftlhr ( ftJhr @ ) Pump 1 0 spm DH flow gpm Gas* 0 units 146 unit~ ( units @ ) Pump 2 0 spm Total flow 0 gpm - Temp Out 78 Deg F ( 78 deg F @ 14693 ) Pump 3 spmAV@DP 0 fpm;, - Pump Pres 0 psi A V @ DC 0 fpm I 14 7/28/2002 14.693 o LD Cmt Hd Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: I BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sperry-sun DRILLING SERVices I 1 ' ~:.. :". _ . ~" ,-;' . ~' - . . , ," .,1':0 . * 10000 units = 100% Gas In Air 1'..l!l¡.. I ': " : '" '.'" ~. Logging Engineer: Doug Wilson 1 Mark Lindloff } C~: :'":'~I\:~r:' .,: . ''-. I, Test BOP's, Pick up Bit #3, RIH, Freeze protect 9.625" X 13.375" annulus, cont to RIH ....'. ~ . l.· ' % Lithology Sst Sltst Sh . ~;, I~." ..¡,~. ,'I.~" ~ ..... . ~ , \:,' , .:.." ¡ " , oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: after Gas during before after . .. Drilling Breaks to to to to I Drill Rate during before Depth , ·f·:.'1' .c, "~~;,~"¡....."j,i'*'¡~.~~:~J!, /;¿i~M'.Mi:~')<;;' :¡-~j;.v\"\:r'!f~.t·~~,,~~.¡':<"·,:~~:!f\~~~*\.':;.~~ti\l'.i.\r.,~-:-::&\~·..·,'·'2·'~:~~~~~.~'!<'·,;"W(.:; ':"~"'. ~e''''<'~\"h··.,'.::.'·''~''·''''''.l~· ".'.,., ".:~~...¡~ ppg ppg ppg ~;"'" units units units "': .; ~"\:.J,' ~oLCM ft ft ft Connection Gas and Mud Cut ft _ units _ ppg ft_units _ppg ft units ppg ppg ppg ppg I .':I.~··"~!'iJ.ot;~t,:~··:\·~.Jtf,~>·J~·~J~~~'·~¡"·IP.¡,L'r~~·~·<~~' :"it.';';.\Io,t. ...·.'··1. ' units units units ft ft ft I ~/:J 30 .~. ,\ \ ). {~:tc~ ~ ,'" .,.:T ~.'\"o !.' 1#.1';'.. ..;"5~~~~oL::~":"~t- ~.;i'!·".'~4~ R; ;.~,~'.~ ..~...;\r:".., .':- '.' ':.'¿;",:" ~~~. ~~~~. ~.~~J:bt},~~", "~: ~Io-:~~.; :¡ C SST 20 % Current Lithology: 50 % SLTST ppg Trip CI: 19000 ppm ppg Short Trip CI: ppm Feet of Filion Bottom: ft % SH Mud Cut: Mud Cut: to ;:,;.::~~. ." ¡..'.. I ~:~'i .~..':.. :~'..'"~'';,'.~~::'' Jets: 12 \ 12 \ 12 \ 12 \ 12 \ 12 TFA: 0.6100 ------ Total Revs on Bit: 0 Footage for Bit Run 0 HTHP ~ Mud Wtat Max Gas ~ppg ~ 1 ....:!2... 1 ~ Ibs/1 00ft2 pH 7.1 Sd 0 % 6.2 ml Gels Vise 42 sees API filt PV 14 eP YI 21 Ibs/100ft2 ft Trip Gas: ft Short Trip Gas: to to I -. ".:fo:·S"· ç; :or>~::';~~:1:": t,,,-:.~,t-~~.'r\ ~~'~.~.~:"~:~~.~.,~: ~'f:.,~~"'! ,~~.~.~'~ ~~,1"'~~~ ·,:.;.~Çf\1 ~ ~.'~'i'~~~~:'·~M~~i·~"I.~·l=r.'~~i}~~~4~t,\ti~lj~~¡~:~~'~.\~~~r~.l,\::.,:·;\~r ~'\',:~~~;.~~:'f~~·:'~'~~J.:..·~~~? ~~')i~~.:~ ~~:.r ~<:;',~.'~'?'~~f~i~;:.~~.<· .~~.::. l' :.,.: ~ ~: .-11, :.:' .' ,~~\... ',:; ~:,' . 'J ·'t::ft.: .~:~. Trip Depth: Short Trip Depth Tight Spots: I . .~'.:,.~~ ~'~\" .' . .,. .', .. . :~.. I...' o " . . ',.' ...~. ¡' :. ~ I , . . ~~ ~,.~' ,.: ~f~:~:~~;·}:'l ·old:. -,. :~,~~~>~~:. ;':' ~.~':..\ ~ ¡;a-... '..,:', ~ .:~ 8 1/2 0.0 DS164F+JNW Bit Size: _ Hrs. On Bit: 3 Type: RPM: 10.20 ppg 10.20 ppg Mud Wt In Mud W1 Out Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr ftIhr ( ft/hr @ ) Pump 1 0 spm DH flow gpm Gas* 0 units 146 unit~ ( units @ ) Pump 2 0 spm Total flow 0 gpm Temp Out 78 Deg F ( 78 deg F @ 14693 ) Pump 3 spm AV @ DP 0 fpm Pump Pres 0 psi A V @ DC 0 fpm 15 7/29/2002 14.693 o RIH Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sper'r"'y-sun o A I LL IN G 5 E A V I c:: E 5 * 10000 units = 100% Gas In Air Logging Engineer: Doug Wilson 1 Mark Lindloff Still in the Miluveach Changeout day:Doug Wilson goes in and Reg Wilson comes out. hr Recê Continue RIH, Drill out cement, weight up to 12.9 PPG, drill out shoe and 20ft of rat hole. Perform FIT to 14.5 EMW, drill from 14713 to 15172' MD, Rotary steerable not holding angle, POOH wlo CBU. . ',,,~ ,; :,' '. '~:, ., ;' "~~.I;~,:.f'~;'~~~V':~~' ,.t.. },¡~.. . ~ .~. ~. :.It . '" ......1'... ':. ~:,:,,;~y.<.. ):~:. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: "..").. % Lithology Sst Sltst Sh oz. after Gas during before after I to to to to I Drilling Breaks Drill Rate during before Depth ppg ppg ppg I units units units ppg ppg ppg , :<..: . '¥t:t'^~.\.....I, ;¡¡.~~?:'~ ""i~;~·',¡,;"J,.:.,~' . ',.,. :·1~'s;:'.,;'; ·'.N,:' ;.'..' :;;'."~; .'~g~':'''';'"_:~~'I'': rti:-';'·;~~' ~; '':':1', >".,<,'/!"." .,:' '''-'\:'~!~, t:.i ,:';t "~~;,:,~~~~.\,,,, ¡.'Ii"¡f,"!.~ '.;,0. ;:·r,;'·""",;,·~~;,:, ·'_¡¡;'i·~:ft·t~~~. ft ft ft " . -, ~ "', - .~. -"/"', ft ft ft ppg ppg ppg ':~'" :·1 . T9.,,~:..:!{·i,·.~\ ,~. '¡,:r~,~·,~,~ ;'~~f":~i I.<·~·I·"·'··:.' I;" ~'o "0.,. "~,,, ppg Trip CI: 58000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft ~''' ,.', ... Connection Gas and Mud Cut ft units ft units ft units units units units I 01 10 sh -"....~.t1¡~W~,~.~A"*~,~..;,¡:·,tÎ'/¡'(~ ~':'..- ·',;r·(þ-:' "'~;,-:.,.~: ~~'!"I"~_~':1:~~,i;'.":"~;'.~~h;. ,.:y,~ 20 % sltst 80 % Current Lithology: '~. j.4~.. ", ~:·::~~l~'··.·"·~~ . ~~~~ft 1, ~~:-;....~:"t,·: ~:'~ .. .',:..~. Mud Cut: Mud Cut: to " ¡", :~.,'\o ,:..~..¡-~ ,:", .~' ~ ("..' '-t'.":>",i. ~~·.~I'$:.,:..t·i..'·.: 0.6100 479 Jets: 12 \ 12 \ 12 \ 12 \ 12 \ 12 TF A: ------ Total Revs on Bit: 54 Footage for Bit Run ... ..... ¡......-.,:t'" "'-", .", ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: ( " ,. '. ",,>.~;,:i' "*:.>:.'.~~-::~:, ·,r~:....'I;:';'."~':\,:~I:';<\\: ' ( ;._:~' ...:'. :.;::. :," " '.. ~. y'....,., I 8 1/2 7.1 DS164F+JNW Bit Size: 85 _ Hrs. On Bit: 3 Type: 23 RPM: Bit No.: Wt On Bit: Visc ~ secs API filt ~ ml HTHP ~ Mud Wt at Max Gas ~ ppg PV 26 cP YI 29 Ibs/1 00ft2 Gels~ / ~ / ~ Ibsí1 00ft2 pH 8.1 Sd 0 % 12.90 ppg 12.90 ppg Mud Wt In Mud Wt Out I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 88 ft/hr 85.16 ftJhr ( 343 ft/hr @ 14700 ) Pump 1 70 spm DH flow gpm - Gas* 47 units 89 unit~ ( 131 units @ 14908 ) Pump 2 90 spm Total flow 569 gpm Temp Out 92 Deg F ( 92 deg F @ 15120 ) Pump 3 spm AV @ DP 270 fpm Pump Pres 3380 psi AV @ DC 522 fpm 16 7/30/2002 15,172 479 Drilling Kidd I Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report sperr-'y-sun DRILLI N-G seRVIc:es * 10000 units=100%GaslnAir Logging Engineer: Reg Wilson / Mark Lindloff 24 hr Reci Continue POOH, Pick up BHA #5, RIH, Cut and Slip Drill Line, Rih to 15165", Pump #2 failure, FIT to 14.5 EMW, drill from 14713 to 15172' MO, Rotary steerable not holding angle, POOH wlo CBU. Currently Repairing bladder and circulating at the shoe. No problems POOH or RIH. Still in the Miluveach 1':'1' .":: I: I,: "\ ! <::\ ....': ":~~':'~-'.',·I,,. ,':' "''''(.., '>;::f~~' ::";','~'?~.':'~" ';, :~.. ~?~·h~':':~;:~~';''';'.{:::;~~;:-')'''~':.·~.,< ':,. -., . ' oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: % Lithology Sst Sltst Sh after Gas during before after '., .' ~r~\¡,~~,~·;r.. y:·:·j.,~t.~r.ltt.,tf.,~·,~ "W~ .' 'r..~ '* .~.} !I'" :.,' , . ..... ~J.1.·. a;~~" __i Drilling Breaks . !:'.:-:.~~'~.: "~~ir:y:t~'~\~~·· :~...,,:~~_..,~~,:..~!;.i~~:~~~'~J''':,,;;¡\:......- ';;; ::.....,.~, ~~~\-·~;~·.;.;~)'l~~!~~..·~:"'.I~j;~i!.:.¡.:';'f'.:~·I~;..\;·:,~, ...., ...,i;'~"- o;-'·1 ~ ppg ppg ppg units units units '. %LCM ft ft ft Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units ppg to to to to Drill Rate during before Depth ppg ppg ppg I units units units ft ft ft I n' ",0) sh ,. "b..... :.(~·i~1)-!-t:,:':'l1~:.'~:t ·..~~It;(:~·l-··~~,~j,;:~;~.;~~r.r . .... ~; .,....~.. 'I, 20 % sltst Current Lithology: ," ~ '1 ;,~J.j't~.~:''', ~J1..r.: I ' ~ o .. 7~..·~, ..'. "'.f!'" - ',....... 1~·~ '~{.1·~:,......!.f._~W~~ -,.{.; g''ll~~.'. 'r¡~; :;~·-I.·'."\t~,~;j,~..1~~I~':..' ~.;.~~ ";:~ I.··... ',t I 80 % " r '," .: .";":.' ~;~Õl...; .~....¡ ~lrV.,".·!....: 1·...~~i';;.~A, ppg Trip CI: 58000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft Mud Cut: Mud Cut: to . :'., tI. . - . ~. ,.. :: .' ~. J;. " ':.. .!.i 'a . '.' ~" '. . I' .,I! ft Trip Gas: ft Short Trip Gas: to to Trip Depth: Short Trip Depth Tight Spots: I I ., ~. . " ~ '. . .\...: :'r·,:·,~, ~f"~':~: ::' ...J ::\'" ; '. :' .' ¡>~ . ".:::..: :"";'~~' ~:>{.::, ~,4. ~~. ~!:.: .' ?",:, '~." (. I.,':).":':;:: :·i"':"-~·)~·'¡'·'~';';i..., .~:-~: ;.'. ~ i~" I:;. ~". ~'.,' t. ," '." y "0'" : .~,). Jets: 12 \ 12 \ 12 \ 12 \ 12 \ 12 TFA: 0.6100 ------ Total Revs on Bit: 0 Footage for Bit Run 0 8 1/2 0.0 DS164F+JNW Bit Size: 85 Hrs. On Bit: Type: RPM: 4 20 Bit No.: Wt On Bit: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 0 ftlhr ( 0 ft/hr @ 0 ) Pump 1 80 spm DH flow gpm. Gas· 23 units 21 unit~ ( 42 units @ 15172 ) Pump 2 0 spm Total flow 280 gpm Temp Out 92 Deg F ( 92 deg F @ 15120 ) Pump 3 spm AV @ DP 135 fpm f Pump Pres 1151 psi A V @ DC 224 fpm Mud Wt In 12.90 ppg Visc 55 secs API filt 3.6 ml HTHP 9.6 Mud Wt at Max Gas ~ppg Mud Wt Out 12.90 ppg PV 29 cP YI 32 Ibs/100ft2 Gels 12 / 30 / 33 Ibs/100ft2 pH 8.0 Sd 0 % - 17 7/31/2002 15,172 o Fixing Pumps Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report I DRILLING SEAVtCES sper'ry-sun * 10000 units = 100% Gas In Air ··r··... , , .... '~ :~ . 'V!"'r:;.,. Logging Engineer: Reg Wilson I Mark Lindloff " / .' ~ .' *Note an unmapped 30ft fault just above the Sag River Formation was found 24 hr Reci Drilled from 16403 to 16550, Td for 8" hole section. Pumped sweep and when sweep came around lost circulation. Around 75 bbls/hr. Pumped fibre and walnut pill, started rcieving 65% returns. Hole stayed full when static. Pulled to shoe, Pulled hard first 4 stands, Circulated to 450 GPM in shoe, no losses. , . , , ~..,. . , .,;',:::" ,'':'M'.~ .", ,~,<, 1--'11"'\.:1 . .r·.' . ~,., ~';:~~.;:''',:/,,,:' '~~'~ ,~..;. :~:'~ "<t,:,!:·;\':-::':l~.~ i t~¡· :"':;~~'? :, '.:;'~.;';, . " ~. % Lithology Sst Sltst Sh 20 80 oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: after 367 before 94 after 160 Drill Rate during 60 before 142 16405 16324 to to to to Gas during 75 Drilling Breaks ft ft ft Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units ppg Depth . .. '. ~';~." .~' ::.,.:,¡J.,~ i"*i,:','~'::~~~~ ,!\;, :~~.~ :'~:~: .~\. ~;;.,;. '",," " ...~: (I . ,.i,:;ri..:i. :~t.:,':·:Gi~_"'¡¡}¡i;~~~~i~:;"· ;. :-,"'ii,':; ;l, ,,¡.., ,:. ~·.I':' .. ~ ...?',' ;:'" ':',' ", f,.-~ ,¡\Ii;/,....:' .'Ii,'~ ¿ t,~f¡:;¡:·< :.,J.<. ',' '-"" ;.' :,," ppg ppg ppg units units units ppg ppg ppg units units units ft ft ft ;..... _ ~.i.:': 10.:" t:r';~. .. "'-"~'\ f,¡f' 'i ,..=; I (" ',~,Iolllo'~$,'k~¡'' '~~ 4;'" ...; \ ·"...F ....;" .."" ".. ~": ~"'/.;;,lr", :~"""~:~~ t~J..,.~,~,:".,,;:~ ~:~'~.~:"..t':'~1 '.' ., ~l~" "I ',:": '.' ~~. .... ': .;:,~:..:"~',,~ ;:1, ,I, - Io.,"t~"::-~·\ "if~~'.' ~ '.:I":'I:~""" ".......'.. Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 55000 - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: - Tight Spots: to to to Feet of Fill on Bottom: 1 ,~. '. '.. .' "," ~ l~ ,~... '"" .... ~ . " I"" ...:,". ",,', "<I· .'_Ott··}: ",'r:';./, ", :", .¡-". \,,', ' ,,''¡'',~....~ ,', ,.".~ ~ Current Lithology: 10 % sltst 90 % sh % % ~·~LCI\I ppm ppm ft , ' ;':~'~~::~'¡",,,.,'. - ;.:/'C·;· ,~~ . ,'.. .~I : _:"':. ~.~.::,:. ~ /¿L'á.,.-· ~,:.:.ç ,~'. :"'¡" '¡;,¡,; 'i;L,~'o;,~ 'r'~;í .,i~ ,J¿:~~ .~~;::~'. ~I' :~"~':"i ,. ~~"':l ¿~? ~,:~~' ".};,;,,' -"-.~~ ·i..\~~¿ ~: ~ :~....; ~~:~.. ".~\;~~'",.'~';.~"" ~~~~":"',,;¡ ; t~: ~~ ',; ~,,:~' ~ ..... , .- Jets: 12 \ 12 \ 12 \ 12 \ 12 \ 12 TFA: 0.6100 ------ Total Revs on Bit: 107.8 Footage for Bit Run 1,378 8 1/2 12.7 --- HTHP ~ Mud Wt at Max Gas ~ ppg 9 I 35 I 37 Ibs/100ft2 pH 8.4 Sd 0.25 % DS164F+JNW Bit Size: Hrs. On Bit: Type: RPM: 4 Bit No.: Wt On Bit: 12.70 ppg 12.70 ppg Mud Wt In Mud Wi Out 4.0 ml Gel~ Visc 51 secs API filt PV 24 cP YI 22 Ibs/100ft2 I I I I I I I Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/h r 109 ft/hr ( 191 ft/hr @ 16407 ) Pump 1 0 spm DH flow g¡::m Gas* 0 units 114 unit~ ( 367 units @ 16404 ) Pump 2 0 spm Total flow 0 gpm - , Temp Out 92 Deg F ( 92 deg F @ 15120 ) Pump 3 spm A V @ DP 0 f¡::m Pump Pres 0 psi A V @ DC 0 fpm 19 8/2/2002 16,550 147 RIH WIT' LINER Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report DR! !-!...I N G 5 = A V I c: e 5 sper'r'v-sun I I I I I I I I I spe....,....,y- sun o A I LL IN G SEA V I c:: e S Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 20 8/3/2002 16,550 o Cementing Smith 1 Clump Bit No.: Wt On Bit: Bit Size: Hrs. On Bit: Jets: \ -- Total Revs on Bit: \ \ TF A: --- Footage for Bit Run Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 fUhr 0 fUhr ( 0 ftihr @ 0 Pump 1 0 spm DH flow gpm Gas* 0 units 0 unit~ ( 0 units @ 0 Pump 2 0 spm Total flow 0 gpm Temp Out 92 Deg F ( 92 deg F @ 16550 Pump 3 spm A V @ DP O· fpm Pump Pres 0 psi AV @ DC 0 fpm ft ft ft Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg Mudlogger's Morning Report BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 ~oLCM Mud Wt In Mud Wt Out 12.70 ppg 12.70 ppg Visc 51 secs API filt 4.0 ml HTHP 9.2 Mud Wt at Max Gas ~ ppg PV 19 cP YI 19 Ibs/1 00ft2 Gel~ 8 / 29 / 33 Ibs/100ft2 pH 8.0 Sd 0.2 % units units units ppg ppg ppg Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: 50000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft ,~¿'L ",. : ·--'í~.~~,·~." f',~Ç~ .:i..·:I, .~J~· I~l'''''~:;''''';~' ::!i~:.;'~"~ ~- 1,}:,,~.~II..:';..~,...r,' ~~'~'-'''I'';!'' ~;:',~! "i." Ii ~I',"-'" I .~Tr.~:~~~Ð~l,~-~.~·~·',~t~""~\i¡;1~j.·"j:',~,r(~,~~,::~!~,,;,;~, "t,,;,, "r'~'~,-";'~.~~"':." ~,~ ".1," ~-,~:~,..:n'"I·l,'¡ :'\:-~ I,:':.:".::;~' ~.i'. . .,"' ,',\:. . Type: RPM: .. ' '", ;. ~':?: :".~;,,' 1','. ~: ;,: ",." . ", .:: " , . .."/ . ~:,I I .·."f·~· ..' ',."...:......'" .~;.:..,. . .~l-·· ".~ ···...~jÙtlj.·...,::,...,tÄ~(.· ..~f,/..!..,.>~.....":.,.: .,","'; .'..~a, " . . . . .' ~.~I j;' Current Lithology: 10 % 90 % % % sltst sh Drilling Breaks Depth Drill Rate during Gas during after after before before to to to to , ' . ·1' ,.\., ""0. " 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ,.'.. . , ~..'~\¡·f<,' ~," , i . : ,.' ~ ~~. ':' .. :.:...~ ~.,...: .,"'- ~;'.':,:::'~ :'/j¡. ~~.... . ~ ,~{.<, :";'" '....:'.!... units ppg units ppg units ppg ," '.'"....',...', '.....,"" ¡ 'ti ~ ì ~, :~ I .' ,(?i* :. ' . . ~'IIr','~ . '~\:' ft ft ft Sst % Lithology Sltst Sh oz. ...'. ),.... 24 hr Recé Finish laying down BHA, P/U 7" liner, RIH to shoe, circulate bottoms up, Ran Liner without problems, Established circulation without losses or pack offs, Rig up to cement 7" liner, Currently Pumping cement. , ..... . ", * 10000 units = 100% Gas In Air Logging Engineer: Reg Wilson / Mark Lindloff , ' , ;t·. . I Customer: Well: Area: Lease: Rig: Job No.: sperry-sun o A I LL! N G 5 E A V I c:: E 5 f Mudlogger's Morning Report Current 24 hr Avg ft/hr ( unit~ ( ( R.O.P. Gas* Temp Out ft/hr units Deg F BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 21 12/28/2002 16,550 o P/U BHA Kidd I Dinger 24 hr Max ftIhr @ units @ deg F @ Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres g¡::m g¡::m fpm fpm 5.2 ml HTHP Mud Wt at Max Gas Gel~ 11 1 13 1 14 Ibs/100ft2 pH 9.0 Sd Mud Wt In Mud Wt Out 9.40 ppg 9.40 ppg Visc 84 secs API filt PV 10 cP YI 24 Ibs/100ft2 -- I 6 Type: na RPM: HC408 Bit Size: na Hrs. On Bit: Bit No.: Wt On Bit: ~7'\ ;" '",: ~'" . . . '. '. '. ~.~ '.' ", [ .. '". '.'; .<,~;¿.~.~~~I~?·I~ ·~":':~~>'~4'~,:\,~~~-:1..a.+'~~d·''',~V=,;,,~.'_~''r..:.,,;;..tt':~~ ...~: :~.. ......... . :: Trip Depth: Short Trip Depth Tight Spots: ft ft Trip Gas: Short Trip Gas: to ppg o % .' ' . 61/8" 0.0 Jets: 13 \ 13 \ 13 \ 13 \ \ TF A: -- --- Total Revs on Bit: 0 Footage for Bit Run 'i' )':. 0.5180 o ""... . ~. ,,' to Mud Cut: ppg Trip CI: 50000 ppm ~;'; Mud Cut: ppg Short Trip CI: ppm ¡ to Feet of Filion Bottom: ftl ",\ ~;.:',,':;..;..,:':;. :': ,:@II:r,;1t"!;;,~.,\~,,,:. ", ' ":', ,.," .. J':":; ':":,;~,, ','::!, '.,: ~ ",' ", ,¡""".',,. :"~i' % % %LCM ~: , ¡,~:,~:'!l''''>'::'''~~'(':'' n··,...·,~~.(;~,c:"., ,,;,;t',·!· ~.!.." ; ..'," " ' ""!"~'.,"" -' ";~:., ,..,'~"'~~.....,! ~ Current Lithology: % . ':', ~."..I'!:'1.':4. i".:t '~"'l;l;~; ..~.~.: ~~. .:t';'-;~- .t·\:~,f'~'l':'f.;:\ ,~),~~,~,,~~,~..·:,.,J."J~).~;~.'\,'r~2~~"c~~'!..{.~ti}~.~·.'~'~.,. ~~~>:~ ~~;:.~*~~~~~\:"'\~ì~'~'¡~~~ ::~""~fr'!.\~ '~ ,~,~.,,·::~~',\\~¡6~~r.,j; "....~~ .,.; ~·i~:~~'~~:¡",'~· % " '.~', ~.,~'.'.' ..~.. ·~'~-':~k . ,'" ".t.1..' ~~,.:.. . ~'.. , , Connection Gas and Mud Cut .,'. ft units ppg ft units ppg ft units ppg ;1; ft _ units ppg ft _ units ppg ft units ppg ".,' .I\~ ft_units ppg ft_units ppg ft_units _ppg ¡ ·¡;"'~'·~,$'('it{¡:.~__~w':r~~~·;t;.'1$~~_;.»:''''~;¡\¡4M~tii<'Wt~~~_m~;y~~~'$~'~~'Ii'~~~!¡"-¡;N·iik-iI$&\I:'!i!t.""'_~;?!ií¥t~'~~· ;~ "" '.'C""',. ..", '"". '., .....~'..,.. " ~, .' ,«., ' "\' ",' .. . .. <.".... , "'~' ,.. ..'^" l. f.. .....~ '. ~~, ~~~. , , f I I Depth Drill Rate during before to to to to Drilling Breaks after Gas during Sst % Lithology Sltst Sh before after .. I oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ;-:- '~ '< i;', ,~.:" ,..; . .': ~ ..' ",~' <. ? . I :.'....':,),.I,).'~..:..~." ....~."">'..~., '. ..:-:' .,...: " :'1 ~!;, .' .' ~' ,.. .'., \ /'0..'.'..": ". 24 hr Rec; Move rig to NS18. N/D tree. N/U stack and test BOPs. RIH wi open ended D.P. to 2000'. Circ, Out diesel wi sea water. POOH. Test casing to 4800 psi. Begin picking up BHA, Logging Engineer: Tom Mansfield 1 Doug Wilson . :.;, . * 10000 units = 100% Gas In Air . '. . . > , "'I" * 10000 units = 100% Gas In Air , ~".,,~ '.. ",' Logging Engineer: Tom Mansfield 1 Doug Wilson 24 hr Rec; RIH. Wash through tight spots in liner. Rotate on cement plugs. Pipe torque high. Displace sea water and old mud with Baradril-N mud. Pull 1 0 stands and begin mad pass. Continue drilling cement with high torque. . ;;;.~ oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: after Gas during before after Drill Rate during before to to to to Depth 'to ,:"~~":!'¥.h~~~t:'\'~~~~4'~~~1f:¥~~"~;¡J~~i<:':~..~;*~,?~,~~~,ff~~;¿~i:ï~~~~~:;t'~[,~}'$-'iÌ\~~1f,~~'iI"t~"~'.;>¡<1;,~~ !!";.";~:~;¡:~¡:.,¡;~¡,.r,':;'~ -f;~~- I ~~,o ...~f~1 % Lithology Sst Sltst Sh ppg ppg ppg units units units Drilling Breaks ft ft ft Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units ppg ppg ppg ppg % % units units units ft ft ft I %LCM % % ",~:... i"';'~:·"'.:I.·'·~."'."'?,,¡.c..~, ':"'~~ ..~ !.~"!:t',,,,:,~ '''I~J~''.'~'.,r..'''' ,.:~ '\.... ": ": .:1'. ,,~...·L~''\'·f:"i'~. ·~_'"1,..·',~~lf...~.;:t".,:·) -:·r'l '.~~: ? .:. ~.:. :~"".~..~: ," . .." i ' , , ' Current Lithology: ..;~*,,' i:"'· I.j' 01, ,\A,¡'~.:".,.. .,'::.' '.t' , I,.Þ .~. I ppg Trip CI: 18000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft Mud Cut: Mud Cut: to ft Trip Gas: ft Short Trip Gas: to to ':"', '.:, .'.:...1'~ '," '_\' ," ~.7 .:" ", :t' ",- ....'.'.. i;, ,01, ,.1"'1': ,:~~.. :",I"~~_..;"~:I~ :':;~,!;,- ,"":';::-~:'~> .' ':'.: ,", "f"' ,'. ' ;.,.~ " 7;r,,'~'·-:''\:. :,;1, Jets: 13 \ 13 \ 13 \ 13 \ \ TFA: 0.5180 ------ Total Revs on Bit: 0 Footage for Bit Run 0 61/8" 0.0 --- Visc 43 secs API filt PV 10 cP YI 24 Ibs/100ft2 9.25 ppg 9.25 ppg ppg 0.1 % 4.2 ml HTHP 9.0 Mud Wt at Max Gas - - Gels 10 1 12 1 13 Ibs/100ft2 pH 8.0 Sd I gpm gpm fpm fpm Pump and Flow Data spm DH flow spm Total flow spmAV@DP psiAV@DC 22 12/29/2002 16,550 o Drill Shoe Track Kidd / Dinger Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ft/hr @ units @ deg F @ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 "i'~" I:«'_~~-" Bit Size: Hrs. On Bit: HC408 na 6 Type: na RPM: Trip Depth: Short Trip Depth Tight Spots: I , ~..; I Bit No.: Wt On Bit: Mud Wt In Mud Wt Out I 10 24 hr Avg ft/hr ( 8 unit~ ( ( ftJhr units Deg F R.O.P. Gas" 8 Temp Out Current Mudlogger's Morning Report I Customer: Well: Area: Lease: Rig: Job No.: DR! LL IN G 5 E A V I c:: E 5 sper...,v-sun * 10000 units = 100% Gas In Air SHUBLIK @ 16610' MO, 10896' TVO IVISHAK @ 16710' MO, 10989' TVO , Logging Engineer: Tom Mansfield 1 Doug Wilson 24 hr Rec: Drill float equipment, shoe track, and 20' of new hole. Perform FIT to 11.5 ppg. Drill ahead to T.D. at 11685' MD. 11135' TVO. Circulate sweep. " , . ,~,~.~ ~,¡¡;'::::"'" I'~r:, ? ~~~.: \..~. " :.~.: !:..'¡';',' :~'~ ~~:~~;',;' ~ V(''¡;'':; ,I ,:~~.~I~ ,:'" ,;".'. '. ,<'\; /,~:~.~ ~':\ '\.~/I ,..,~:. ,'"A' ~~ ~ . " ;r' þ' ~:". . ;~. :;.; '.'~,~. r, . , " oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Mostly small splinters, occasionally larger peelings 0.45 Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Cgl 16550 to 16610 55 175 50 65 240 45 90 10 --- 16710 to 16810 50 110 25 60 497 65 1 0 1 0 80 -- to to ',' . '.......,.;'::;~', .' Im.~.,'.. \ ppg ppg ppg units units units . "!'\I~'''''~'¡.,~ ~r. ~',~LCM , "':. I :'!".. \; ~~"!I'·, ,-' .;. !."...~,1:,.. ~':·~·',~~.\.:·':"t7.i;~~ "¡t.:;(~ è-.....; p ,.~.,L., '"1:, ~.~";1~·-f-·1~'; . I,'" II .1J~~-1,~:.{¡~fi\.@~·:.!~:.~f:~'-f·:~~ r 1'.9" ii!:~'~;,"'·,t.f..It',.~.<,:~·::.~, ,·..~'.~t:,..~-t';r,'I·:0,~I~I:7i~~~."j"/~J,¡'.',i~.~·'~,·~ ~ 1'~ ",' . ft ft ft Connection Gas and Mud Cut ft units _ ppg ft _ units _ ppg ft units ppg ft ft ft ppg ppg ppg units units units " .... .:. i'~ '~~'. ' "':: ,". "'I .~'" ~ 'i';~~r~~" ~~~ ¿......: oI;:'l.ff,; ."'~ ,~'.':' I~" ." ',\"\ 1 '" ~."' ""'::~"~'~~'" I . :..d/.{~~";'¡.\ " , " ~ .-", , .¡I, 'þ. ..~., ".. ,...~ ". .~ '·~t to.""': ,:!"'¡';'!I. ~lirl".~:~·"r:}.:.",:.J, .. % 75 % CGL Current Lithology: 10 % SLTST 15 % SST Mud Cut: Mud Cut: to "~>~,~"'~,' <'¡,.:":,:;:" :~':;;\;", ',:: ~~; ~~'.;..~},'~: '~1"1~': ·~~,·,,·::t,·.~~'\;i~:,~·~ "J~~,~}¡"~~·I!,~it.,k~$¡/:·\''';'0·;{~~:,:,,-~-:,,\·~,:~!-;,,~.:: ~~~b:~.:{:-'·,'::r~~~~:~~~~t~.\.If.;;(t~~,~:-.t~;: :~i.,.~,/:~;;~":~), ~.; ~'~:~\~í~~, :..~; ,!.,>:I :,,:.~~;~~~,,~.:" I; ·r..t~"~~;....' ~ ::~~:7-'\::~ I", v.;f.~~''''~'''' .:.' . . ", ".......?-.. : to Trip Depth: Short Trip Depth Tight Spots: ppm ppm ft ppg Trip CI: 18000 ppg Short Trip CI: Feet of Filion Bottom: 16865 ft ft .' '. ' to Trip Gas: Short Trip Gas: ,.:. :'~":: =, ~ "J ·~y,:,:n." . .rt"'.~:,~~,,;,.,:,::,~':"'1:~:>/".¡'I.~<~.~r:.,',:~. .: ~....;~~ . ..-.' '. .~...~.., . '.' " j." " ':' ;..:},~>r. ·.~7. .,~~. .:{;; :)"'. ~..(,;" \~; "~~:'~~'!.f;"": ~';":": . 0.5180 315 6 1/8" Jets: 13 \ 13 \ 13 \ 13 \ \ TFA: ------ 11.8 Total Revs on Bit: 111 KREVS Footage for Bit Run 6 10 HC408 Bit Size: 95 Hrs. On Bit: Type: RPM: --- 4.0_ml HTHP ~ Mud Wtat Max Gas ~ppg Gel~ 10 1 13 1 15 Ibs/100ft2 pH 9.1 Sd 0.1 % 9.30 ppg 9.30 ppg Vise 43 secs API filt PV 10 cP YI 23 Ibs/100ft2 Mud Wt In Mud Wt Out Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. na ft/hr 27 ft/hr ( 180 ft/hr @ 16559 ) Pump 1 spm DH flow gpm - Gas· na units 100 u n it~ ( 497 units @ 16724 ) Pump 2 94 spm Total flow 334 gpm Temp Out 90 Deg F ( 90 deg F @ 16851 ) Pump 3 spm AV @ DP 135 fpm Pump Pres 2290 psi A V @ DC 823 fpm 23 12/30/2002 16,865 315 TO Hole Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: sper'r'v-sun o A I LL I N G 5 E A V I r:::: E 5 I I I I [ I I I I ,:",1 J.' .' . .1" ~ * 10000 units = 100% Gas In Air ~ ;. '. ::.·.t,( \ . . ~,'~.' ;,,~ .~ .,I~. '. . Logging Engineer: Tom Mansfield 1 Doug Wilson \: POOH to shoe. Circulate hole clean. Pump slug. POOH. Rig up and run wireline RFT logs. ., , 24 hr Rec: "'...~~~:'~~ oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: 4ii, 'fij¡ i.% ppg Trip CI: 18000 ppm :~~ ppg Short Trip CI: ppm.~1 Feet of Fill on Bottom: ft .~ (1(., ",,, . ".rj~ ~:~~~ Current lithology: - % - % % % %LCM -1~lt,: '.,:' ','" . "" ,,.,,..;,¡):\ '1;1<., "'''''''~ ·t'l¡~1!<··!'"'>''' '('~'~'1'J',¡¡::!i,>'i"';~~""'. ~"'"I,~""I "'~~-mr,~' '1'.'X·?o""'i¡m¡.>þ'¡..".·^ ~ " ,~. '.U" '··\"""~""""~$t':¡ '''''''''~}.',i''A' '¡~4'" "",'J ":.,,,,,:.«,',.' "'!.';. ",-."',,,,",,' .. .....,. If "', "".., ".' '-,' .'. ,.,. ¡. . '" ", . ",0 '. ....;t"?~ ". '. ,..",- "'" " .,'. , .. ",.' , .", -,' "..,' ..,~,.,...,,', , I:..*~ Connection Gas and Mud Cut . " :, , ft un~ts ppg ft _ un~ts _ ppg ft un~ts ppg~, ft Units ppg ft Units ppg ft Units ppg ill ~ "If - -- - ~~ ft _ units ppg ft _ units ppg ft units ppg ~& " 'I."..·.',$.'.,rf:.,.. :;·~··~"(":>:J.¡;·..t&':N~~):,;~~~~t:qi~_~~~~~~~~¡~~;.m;Ø:<;~wJwt,¥,!j'S,',~I~~.":¡·.1\'\th~},,,;~"i'<':~'tI~~\·'L'IZ'I:.,~f· ':" ~ ::t1 Drilling Breaks ; )~' :i~: I ;1 I % lithology Sltst Cgl Gas during Sst before after after :: :;" ~.,.... ::; I~~~~~;=r~ f<f.,¡-~),ji:.f:n'.--' ;{;: ..."1 . .., : :.:",~.\.'. ;. . ~ ':~ ,..( 'â"~"·1{.t~;.. I,t.: :~: .:'. ,'~;\fìP:.~,i:-'..... ';';,',"~J..S'''~'::''''''' ~ '1~~~' ~ 7.::~·..· ,.......';::~, ·".i;"':'-,;~:"'~)'Yt:~.~~:-I.~::.c}~·~'t:;~~'::4:~;~~ .~' '-i':,i~ :t~I'¡~ \\:~I.t.~1':t~:~,:·~~ ~~:ì.1,.~,~{,.~ :';;~'j.... to Mud Cut: Mud Cut: to J. .~. ~.""':.\,~" ,....:. "'. ...;;1'.'..:'" ~¡ - ". :". ..~, ~,;'tl"-,:~~!~·.'.t \~.~-,o\ 1-: ¡~' :.....~.~.. :'~~~- :...., \ to to to to Drill Rate during before Depth " , r r I I to Trip Depth: Short Trip Depth Tight Spots: ( Mud Wt In 9.30 ppg Visc 44 secs API filt 4.0 ml HTHP 9.0 Mud Wt at Max Gas ppg - - - Mud Wt Out 9.30 ppg PV 10 cP YI 23 Ibs/100ft2 Gel!: 10 / 12 1 13 Ibs/100ft2 pH 9.0 Sd 0 % - Bit No.: 6 Type: HC408 Bit Size: 6 1/8" Jets: 13 \ 13 \ 13 \ 13 \ \ TFA: 0,5180 -- - -- Wt On Bit: 10 RPM: 95 Hrs. On Bit: 11.8 Total Revs on Bit: 111 KR EVS Footage for Bit Run 315 r gpr.l gpr:l fpr.l . fpr.l . Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC 24 hr Max ftlhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres 24 12/31/2002 16.865 o Run RFTs Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Trip Gas: Short Trip Gas: ft ft 16865 ... ~. .:<:~, ;.;,I,:r~~¡ ~i,~;-;,v~·,,·:~:,,~,\"~~ -;',~; '~:~~~~r:· I'. '~~-."j.'. ~.I . :' ~"':.~ ì:: ·,.'FI. :~~:k'~·'.:· '~'f ,:. ,". 24 hr Avg ftlhr ( unit~ ( ( ftlhr units Deg F RO.P. Gas" Temp Out Current Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report 5pe~t'""'Y-5UI' DRILLING SERVices I ".' \.:;:-'.:;:C' Logging Engineer: Tom Mansfield / Doug Wilson ., * 10000 units = 100% Gas In Air , . ..··1 ;. ..., '.~., '·w " ." 24 hr Recí Run RFTs. Could not get all the way to bottom due to sticky hole conditions. Rig down wireline. Rig up and run 4 1/2" production liner on drillpipe. " ~~ ~' . I .l¡i''''~; I ..'~.' ~?"~. ."~.~: ,.':~ '~'~'~~:.\~::"\~ :·::rl~"~:.: ..:;.~ 'v: :;':'.'- ~x ~ :', " ,:,.:: ....~:.~. i' :". "L ::. ~ ':". ~ ~ ',~. , :: ;'~/;': "" ':~~;" .:~ <::t, ~ ~:,...', ,:',t¡";~~' 01 ~~'J ,,'~ ~.:;~'~ "~~. ~~'''~if' "i,".I>::' ~ :' :t~" oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: t~~ '-1''1( Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 18000 ppm I Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm 0 Tight Spots: to to to Feet of Filion Bottom: ft :. , .' ¡:" ~~'~,1k~~,~'.:t~:~·~'«~~::.t~',~~f:~W:,~,~~·~:·'t-:~·~~~':i~¡·I ~~4;'~,~~::~l":''\. ·':'~''~~~:~~'/~i~: ...:.;'~·~~~;':~_.i\~~~·~~.~,~~~~,~..;~\ti-"1~.1:~~-.~~"}'~~~~~;.h·~~~,,{·~~·~·),:,: ;'·'¡~.'\·~·r-·~~JI~K('t~'~ ~':, :-, .... ", :".' . t: ;.," :;r.~.,;( -::~~'~'" .,~~,;:.....~~.~? .;,' : "\,.~~, ,'." \. ~~,~ r i Current Lithology: - % - % % % q·~LCM -1~ :1."'..':":":'.'''''' ~" ..;,-~"·~;I:· .". :..IJ'¡::"'~f I...·~,',r·~v)r¡..;·~,~t.:.,...: I:~.J I"t'1i ~..:..i".I~to' ,.' If' '. ..\·.4~ -i";~--\~~···'· ~.:t.J..'''-,' . .~~l~~·')~·Ñ':::~fto;:r :JI·~~:'~.I~.~;~'~.( ~'~". '~Ir;¡.~'-f:.,~\,~._v,:,,~ ~~-.~..,~, ..... ..,~:.t;l1. ·,i,'.: .," \ ';" '-~. ... ;1:(0 ,.1,,·. .1, '!. 1 . ", t . ~I '~ , Connection Gas and Mud Cut . ; :,..',:" ft units ppg ft_units _ppg ft_units ppg ~1. ~~. :: ft units ppg ft units ppg ft units ppg!Ji ;~~: ft units ppg ft = units = ppg ft = units ppg ~ ~~'~"~"MI:w.."'},'~"~~'.;'-'.(A.~~¥$~~iß~~~~~,fI..1f~_~~;:t~~~~~~':\'ë~1i'¡~i#~~~·h,i~{i":·,"<'!';;'PØ'4iN".t.¡/ t I""'" ,.;¡,,~,. ...,' ....', """,,,:.~",.- j¡¡, ..'. ...,.." '"", '". ,."',''''' . ,,,". ;, <..,.'", .,...,.1:),'.. " , '.- Drilling Breaks liil; :·'1'·"·' ::~ :~.¡ - I~ t~1 % Lithology Sltst Cgl Gas during before after Sst after to to to to I Drill Rate during before Depth I I I I '/." .':'.:~ ,:' , - . . "~" ..' .~,' , ":' ~ ':'~'-,:;..r"~' 'i;;;K,~..,......'-~~'\~,f~<~~)'''~,7,¡~~~;'::'~~4t:-#.11.:~::-,~~,1~:~:<, .~~. ; '~'f;:~,r;:.-,.., ~~ï\: ~':~~. ,,< '~; ~.:r.::-: .~\~' ~:. ,," ': ,~:' :.~~ ";.. . ..~,. '~,'~ . ~<,~.".' '.~";'~~'.oI ~::'::~~~'...>~;~.~;~.~'.f,.",~.~:\: ~ ~l,·.:...~'f..::':"?:i I Jets: \ \ \ \ \ TFA: ------ Total Revs on Bit: Footage for Bit Run --- ppg o % HTHP 5.0 Mud Wt at Max Gas 8 / 10 / 12 Ibs/100ft2 pH 9.0 Sd Bit Size: Hrs. On Bit: Type: RPM: Bit No.: Wt On Bit: I ppg ppg Visc 44 secs API filt 3.8 ml - - PV 9 cP YI 20 Ibs/1 00ft2 Gel~ '" gpm gpm fpm . fpm Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ftJhr @ units @ deg F @ 9.30 9.30 Mud Wt In Mud Wt Out 24 hr Avg ftJhr ( unit~ ( ( ftlhr units Deg F R.O.P. Gas· 17 Temp Out Current I 25 1/1/2003 16,865 o Run Liner Poly a I Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: spe.....,.....,v- sun DR I LLI N G 5 E:RV I c= e 5 I I Schlumberger BHA# 1 Job # 40007796 Date In 16-Jul-02 Date Out 16-Jul-02 Hole Size 16 Customer BP AOW Time In 5:30 Time Out 16:30 Hole Sect Surface Well NS-18 Depth In 201 Depth Out 330 Bha Type Steerable Field Northstar TVD In 201 TVD Out 330 Hrs BRT 11.0 Rig Nabors 33E Drlg Hrs 1.1 Drlg Ft 129 Avg ROP 117 AFE # 831319 Slide Hrs 0.2 Slide Ft 31 Slide ROP 155 DD's Tunnell/Robertson Rot Hrs 0.9 Rot Ft 98 Rot ROP 109 Co. Men Polya/Oinger Pump Hrs 2.0 Rotate % 76 Slide % 24 PDM Run # 1 R/S 5/6 PDM Jet Blk Incl In Az In Bit>Srvy 43.0 PDM Ser# 962-1126 Stages 3.0 Bearing Mud InclOut 0.99 Az Out 296.84 T/F Corr PDM Size 9 9/16 Rev/Gal 0.100 Rubber RM1000 Avg Dls 0.3 Max Ds 0.6 Plan DIs Mud Type Sea H20 Spud Mud Wt 9 Sand % 1 RPM 40 GPM 500 SPP On 320 BHT F Mud Vis 100 Solids % 8 Dig TQ 3.0 WOB 10 SPP Off 300 Item Description Vendor SIN OD ID Stab OD F.N. Connections Length Cum Length Bit #1 MX-C1 TFA=1.031 Hughes 6004904 16 1x12,3x20 7 5/8 Reg P 1.35 1.35 2 9 5/8 Std POM 1.83° 7 5/8 Reg B *float* Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6 5/8 H-90 B 26.00 27.35 3 Orienting Sub 6 5/8 H-90 P Ana GLDD-105 8 2 3/4 6 5/8 H-90 B 1.46 28.81 4 MONEL 5T AB 6 5/8 H-90 P Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 B 5.49 34.30 5 MONELLC 6 5/8 H-90 P Ana 1 O-HA-O 11 8 2 13/16 6 5/8 H-90 B 9.69 43.99 6 MONEL LC 6 5/8 H-90 P Ana 10-HA-013 8 1/16 2 13/16 6 5/8 H-90 B 9.96 53.95 7 MONEL 5T AB 6 5/8 H-90 P Ana HA-O 16 8 2 7/8 15 7/8 2.35 6 5/8 H-90 B 5.60 59.55 8 X-OVER 6 5/8 H-90 P Ana ANA614 7x8 2 7/8 1.20 4 1/2 IF B 3.09 62.64 I , I I I I I I' I I ' [ \ BHA and Run Objective Clean out Conductor, ---.------. survey Bottom Hole Location, Rat hole to pick BHA , BHA and Run Results \ Why POOH I Comments I~~_~~ge BHA / pick up M~~~_~.~~~}~!~_.._... BHA Weight Dry Wt 10,694 Buoyed Wt 9,228 Incl Angle 2 Buoy+lncl Wt 9,222 Bit Data IADC # Footage 129 Hrs 1.1 k Revs 5 k Grade not graded Comment rerun in next BHA on this well Tool Motor Jars Bit #1 Hrs. In 87.4 0.0 Hrs. Out 89.4 1.1 1.1 2.0 Bit To AIM=X', Res=X', GR=X', 0&1=43', PWO=X', Oens=X', Nuet=X' I Schlumbel'gel' BHA# 2 Job # 40007796 Date In 16-Jul-02 Date Out 19-J ul-02 Hole Size 16 I Customer SF ADW Time In 17:00 Time Out 3:00 Hole Sect Surface Well NS-18 Depth In 330 Depth Out 4050 Bha Type Steerable Field Northstar TVD In 330 TVD Out 3217 Hrs BRT 58.C J Rig Nabors 33E Drlg Hrs 25.6 Drlg Ft 3720 Avg ROP 145 AFE # 831319 Slide Hrs 9.5 Slide Ft 1311 Slide ROP 138 DO's Tunnell! Robertson Rot Hrs 16.1 Rot Ft 2409 Rot ROP 150 Co. Men Polya! Dinger Pump Hrs 43.4 Rotate % 65 Slide % 35 1 POM Run # 2 R/S 5/6 PDM Jet Blk Inclln 0.99 Az In 296.84 Bit>Srvy 67.~ PDM Ser# 962-1126 Stages 3.0 Bearing Mud InclOut 54.00 Az Out 308.00 T/F Corr 13.C PDM Size 9 9/16 Rev/Gal 0.100 Rubber RM100D Avg Dls 2.5 Max Ds 5.1 Plan Dls 2.5 I Mud Type Sea H20 Spud Mud Wt 9.1 Sand % 1 RPM 40 GPM 900 SPP On 1900 BHT F 95 Mud Vis 61 Solids % 4.4 DIg TQ 8.0 WOB 20-30 SPP Off 2000 Item Description Vendor SIN OD ID Stab OD F.N. Connections Length Cum Length Bit #1 MX-C1 I TFA=1.031 Hughes 6004904 16 1x12,3x20 7 5/8 Reg P 1.35 1.35 2 9 5/8 Std PDM 1.830 7 5/8 Reg B *float* Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6 5/8 H-90 B 26.00 27.35 3 MONEL LC 6 5/8 H-90 P - 2 13/16 6 5/8 H-90 B 9.69 37.04 Ana 10-HA-011 8 4 MONEL LC 6 5/8 H-90 P Ana 10-HA-013 8 1/16 2 1 3/16 6 5/8 H-90 B 9.96 47.00 I 5 MONEL STA8 6 5/8 H-90 P Ana HA-012 8 2 7/8 15 7/8 2.12 6 5/8 H-90 B 5.25 52.25 6 MWD 6 5/8 H90 P I( Ana 173 8 1/4 3 1/4 1.52 6 5/8 H90 B 29.18 81 .43 7 MONEL X-OVER 6 5/8 H90 P Ana LWD S8102 8 1/2 2 13/16 6 5/8 FH 8 1.41 82.84 I 8 Down hole filter sub 6 5/8 FH P Ana DFS 838 AK 8 3 3/8 6 5/8 H90 8 2.20 85.04 Orienting Sub 6 5/8 H-90 P 9 Ana GLDD-105 8 2 3/4 6 5/8 H-90 8 1.46 86.50 ,I 10 MONEL STA8 6 5/8 H-90 P Ana HA-O 16 8 2 7/8 15 7/8 2.35 6 5/8 H-90 8 5.60 92.10 11 MONEL DC 6 5/8 H-90 P I Ana 831-021DC 7 15/16 2 13/16 6 5/8 H-90 8 30.94 123.04 12 MONEL DC 6 5/8 H-90 P Ana 831-020DC 8 2 13/16 6 5/8 H-90 8 31.01 154.05 13 MONEL STA8 6 5/8 H-90 P 1 Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 8 5.49 159.54 \ 14 MONEL DC 6 5/8 H-90 P corrosion ring Ana 831-012DC 7 7/8 2 7/8 6 5/8 H-90 8 30.58 190.12 15 HYDJARS 6 5/8 H90 P DAILEY 1417-1119 7 13/16 3 1.69 4 1/2 IF B 31.00 221 .12 16 26 Jts. HWDP 5" 4 1/2 IF P NAD 26 HWDP 5 3 4 1/2 IF B 786.17 1007.29 ! 17 DP 5" to Surface 4 1/2 IF P NAD DP 5 4 8/29 4 1/2 IF B 1007.29 -"'.---.-.-..,., ,...--......-." ...--"- ...._,_._~--,....-~~_._.,--,-- - ....~.,---_...,. -.". '._._...'...'-~ BHA Weight Dry Wt 71,431 Buoyed Wt 61,530 Incl Angle 56 Buoy+lncl Wt 34.407 Bit Data IADC # 117 Footage 3720 Hrs 25.6 k Revs 177 k Grade 2-3-WT -A-E-I-NO- TD ':;omment Do not rerun. Tool Motor Jars Bit #1 Hrs. In 89.4 1.1 1.1 Hrs. Out 132.8 26.7 26.7 43.4 BHA and Run Objective Drill surface with 2.50/100 curve .·.__n._ _..,,,"_.__. __.____....._._....__._., ~....___.. .", ._..._ ._.. .~.___..".. ....... ..... ._. BHA and Run Results Why POOH / Comments 113..~,~':__~!-=-i~~_,~.0~~~....._... ......-..........-.--.......-..".....-,.. Bit To jAIM=X', Res=X', GR=65.41', D&I=67.40', PWD=X', Dens=X', Nuet=X' Schlumberger BHA# 3 Job # 40007796 Date In 20-Jul-02 Date Out 26-Jul-02 Hole Size 12 1/4 Customer BP ADW Time In 21 :00 Time Out 23:59 Hole Sect Intermediate Well NS-18 Depth In 4050 Depth Out 14693 Bha Type RSS Field Northstar TVD In 3217 TVD Out 9280 Hrs BRT 147.0 Rig Nabors 33E Drlg Hrs 88.6 Drlg Ft 10643 Avg ROP 120 AFE # 831319 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0 DD's Tunnelll Robertson Rot Hrs 88.6 Rot Ft 10643 Rot ROP 120 Co. Men Kidd/Clump Pump Hrs 118.3 Rotate % 100 Slide % 0 I PDM Run # R/S PDM Jet Incl In 54.12 Az In 308.24 Bit>Srvy 59.5 PDM Ser# Stages Bearing Incl Out 41.83 Az Out 307.49 T/F Corr PDM Size Rev/Gal Rubber Avg Dls 0.6 Max Ds 1.9 Plan Dls 1.0 I Mud Type Polymer Mud Wt 10.5 Sand % .2 RPM 150 GPM 900 SPP On 3600 BHT F 154 Mud Vis 55 Solids % 11 Dig TQ 25.0 WOB 15 SPP Off 3600 Item Description Vendor SIN OD ID Stab OD F.N. Connections Length Cum Length I #2 RSX238HF+GS TFA=.941 Hycalog 203060 12 1/4 3x11,6x12 6 5/8 Reg P 1.00 1.00 PO Bias Unit 6 5/8 Reg B 2 Ana 90073 9 5/16 Tool 1.35 NC 70 B 3.20 4.20 ,- 3 PO Extention Sub NC 70 P Ana 90051 9 1/4 Tool 7 5/8 Reg P 1.26 5.46 4 PO Control Collar 7 5/8 Reg B I Control Unit 056 Ana CC-90051 9 3/16 Tool 2.36 6 5/8 Reg B 10.14 15.60 5 XO FLOAT SUB 6 5/8 Reg P *float* Ana STFLS-HH-11 ï 8 2 13/16 6 5/8 H90 B 1.97 17.57 6 MONEL STAB 6 5/8 H-90 P I Ana HA-019 8 2 7/8 12 3/16 2.36 6 5/8 H-90 B 5.57 23.14 7 COR 6 5/8 H90 P Ana 8039 8 5/16 3 1/4 15.15 6 5/8 FH B 22.82 45.96 I 8 MWD 6 5/8 FH P Ana 074 8 1/4 3 1/4 1.38 6 5/8 H90 B 27.51 73.47 MONEL X-OVER 65/8 H90 P 9 Ana LWD SB102 8 1/2 2 13/16 6 5/8 FH B 1.41 74.88 [ 10 Down hole filter sub 6 5/8 FH P Filter Ana DFS 838 AK 8 3 3/8 6 5/8 H90 B 2.20 77.08 11 MONEL STAB 6 5/8 H-90 P I * Totco ring * Ana HA-008 8 2 7/8 12 1/4 2.30 6 5/8 H-90 B 5.48 82.56 12 MONEL DC 6 5/8 H-90 P Ana 831-021 DC 7 15/16 2 13/16 6 5/8 H-90 B 30.94 113.50 13 MONEL DC 6 5/8 H-90 P I Ana 831-020DC 8 2 13/16 6 5/8 H-90 B 31.01 144.51 14 MONEL STAB 6 5/8 H-90 P Ana HA-006 8 2 7/8 12 1/4 2.45 6 5/8 H-90 B 5.60 1 50. 11 15 MONEL DC 6 5/8 H-90 P *corrosion ring* Ana 831-012DC 7 7/8 2 7/8 6 5/8 H-90 B 30.58 180.69 16 HYDJARS 6 5/8 H90 P DAILEY 1417-1119 7 13/16 3 1.69 4 1/2 IF B 31.00 211.69 17 2 Jts HWDP 5" 4 1/2 IF P NAD 2 HWDP 5 3 4 1/2 IF B 60.58 272.27 18 21 STO 5" DP 4 1/2 IF P 21 STOOP 5 4 8/63 4 1/2 IF B 1983.94 2256.21 19 STEL 4 1/2 IF P STC ES1496 7 1/2 2 7/8 1.73 4 1 /2 I F B 6.41 2262.62 20 Dart Valve Sub 4 1/2 IF P BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF B 2.37 2264.99 aHA and Run Objective Drill toTO with RSS without BHA Weight Bit Data Tool Hrs. In Hrs. Out .. .--.-.-.. ,-_.~-" -." ."-.. ....- ~ "..--- . -.-.." ._-- ----..., ...--.,... ....-.,-.------...-..--. .......,- - 118.3 a short trip or bit trip. Make 1/100 drop fro 56 tp 40 degrees Dry Wt 33,151 IADC # Motor BHA and Run Results I §:~~~~:_~~ill~~_!_~_T~~~~~~t_~_~~_____ Buoyed Wt 27,849 Footage 10643 Jars 26.7 115.3 trouble. Tripped to surface without a short trip. Inel Angle 56 Hrs 88.6 Bit#2 0.0 88.6 Why POOH I Comments Buoy+lnel Wt 15,573 k Revs 797 k RSS 0.0 118.3 Grade 2-0-CT -C-X-I-WT -TO Bit To Res=29.22', GR=40.22', PWO=30.97', O&I=59.52',MWD GR=57.53' ':;omment Schlumberger BHA# 4 Job # 40007796 Date In 29-Jul-02 Date Out 31-Jul-02 Hole Size 8 1 2 Customer BP ADW Time In 15:30 Time Out 8:30 Hole Sect Intermediate Well NS-18 Depth In 14693 Depth Out 15172 Bha Type Steerable Field Northstar TVD In 9280 TVD Out 9660 Hrs BRT 41.0 I Rig Nabors 33E Drlg Hrs 7.5 Drlg Ft 479 Avg Rap 64 AFE # 831319 Slide Hrs 0.0 Slide Ft 0 Slide Rap 0 DD's Rinke Rot Hrs 7.5 Rot Ft 479 Rot Rap 64 Co. Men Kidd/ Clump Pump Hrs 20.7 Rotate % 100 Slide % 0 I PDM Run # R/S PDM Jet Inclln 41.83 Az In 308.24 Bit>Srvy 56.7 PDM Ser# Stages Bearing InclOut 34.75 Az Out 308.89 T/F Corr PDM Size Rev/Gal Rubber Avg Dls 1.5 Max Ds 1.7 Plan Dls 1.0 I Mud Type Polymer Mud Wt 12.9 Sand % 0 RPM 150 GPM 540 SPP On 3450 BHT F Mud Vis 21 Solids % 18.6 DIg TQ 23.0 WOB 15 SPP Off 3450 Item Description Vendor SIN aD ID Stab aD F.N. Connections Length Cum Length Bit #3 OS 164F+JNv\¡ I TFA=.663 Hycalog 200044 8 1/2 6x12 4 1/2 Reg P 0.85 0.85 2 PO Bias Unit 4 1/2 Reg B Ana 60285 6 3/4 Tool 4 1/2 IF B 2.33 3.18 I 3 PO Extention Sub 4 1/2 IF P - 6 3/4 Tool 4 1/2 IF P 1.05 4.23 Ana 631-ES-60 162 4 PO Control Collar 4 1/2 IF B Ana 60101 6 7/8 Tool 4 1/2 IF B 9.90 14.13 I 5 X-OVER 4 1/2 IF P Float Ana AFS301 6 1/2 2 3/4 4 1/2 XH B 1.35 15.48 6 NM STABILIZER 4 1/2 XH P I Ana NMS2SS-FA 011 6 3/4 2 13/16 8 1/2 2.45 4 1/2 XH B 5.62 21.10 7 COR (PWD) 4 1/2 XH P Ana 7125 6 3/4 Tool 11.91 5 1/2 FH B 21.87 42.97 8 MWD 5 1/2 FH P I Ana 344 6 3/4 Tool 1.64 4 1/2 XH B 27.81 70.78 9 NM XO 4 1/2 XH P Ana L WD-BA-259 6 15/16 3 5 1/2 FH B 1.58 72.36 'I 10 Downhole filter Sub 5 1/2 FH P Ana CB-028-JS 6 13/16 2 3/8 4 1/2 XH B 2.76 75.12 11 NM STABILIZER 4 1/2 XH P I Totco Ring Ana MSZSS-F A-OC 6 3/4 2 13/16 8 1/2 2.42 4 1/2 XH B 5.70 80.82 12 NM FLEX 4 1/2 XH P Ana MMFL-FA 027) 11/16x5 1/1 2 13/16 2.55 4 1/2 XH B 31.02 111 .84 13 NM FLEX 4 1/2 XH P I Ana MMFL-FA 025 6 5/8x5 1/16 2 13/16 2.50 4 1/2 XH B 31.01 142.85 14 NM FLEX 4 1/2 XH P Ana MMFL-FA 024) 11/16x5 1/1 2 13/16 2.53 4 1/2 XH B 29.50 172.35 15 X-OVER 41/2XH P Corrosion Ring Ana 3TXOS-FE 104: 6 3/4 2 3/4 4 1/2 IF B 1.98 174.33 16 2 Jts HWDP 5" 4 1/2 IF P NAD 2 HWDP 5 3 4 1/2 IF B 60.58 234.91 17 HYDJARS 4 1 /2 I F P DAILEY 1416-1562 6 1/2 2 3/4 1.70 4 1/2 IF B 32.62 267.53 18 Dart Valve Sub 4 1/2 IF P BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF B 2.37 269.90 19 OP 5" to Surface 4 1/2 IF P NAD DP 5 4 8/29 4 1/2 IF B 269.90 aHA and Run Objective Drill to 8 1/2 hole TD, stay in target BHA Weight Bit Data Tool Hrs. In Hrs. Out _._...._.._.. ,..________.,_"'._.."....___._h.,,_ ."__...__. ."'__._.____ ,...________..__.. 20.7 Dry Wt 21,916 IADC # Motor aHA and Run Results Buoyed Wt 17.609 Footage 479 Jars 7.5 _~______"'_~'_ "._·n_.'"_. _.",_,_._'.._, ,.. . .._._____._____ h_'_'_'_ '..'_n~____.____..__ Ine! Angle 23 Hrs 7.5 Bit #3 7,5 Why POOH I Comments I ~.~.?-' ~.~_,~~~.~~~__ fa ~,I~r..~ __,_, __._______.h___"'___._ Buoy+lne! wt 16,210 k Revs 68 k RSS 20.7 Grade Not graded. one chipped cutter, will rerun Bit To AIM=X', Res=26.46', GR=37.46', D&I=56.70', MWD GR=54.71' PWD=28.21', Dens=X', Nue~omment , Schlumberger BHA# 5 Job # 40007796 Dateln 31-Jul-02 Date Out 02-Aug-02 Hole Size 8 1 :; Customer BP ADW Time In 11 :30 Time Out 22:30 Hole Sect Interrlediate Well NS-18 Depth In 15172 Depth Out 16550 Bha Type Steerable Field Northstar TVD In 9660 TVD Out 10842 Hrs BRT 59.0 Rig Nabors 33E Drlg Hrs 12.3 Drlg Ft 1378 Avg Rap 112 AFE # 831319 Slide Hrs 0.0 Slide Ft 0 Slide Rap 0 DD's Rinke / Robertson Rot Hrs 12.3 Rot Ft 1378 Rot Rap 112 Co. Men Smith / Clump Pump Hrs 35.0 Rotate % 100 Slide % 0 1 PDM Run # R/S PDM Jet Inclln 34.75 Az In 308.89 Bit>Srvy 56.7 PDM Ser# Stages Bearing InclOut 22.70 Az Out 306.38 T/F Corr PDM Size Rev/Gal Rubber Avg Dls 1.3 Max Ds 2.1 Plan Dls 1.3 Mud Type Polymer Mud Wt 12.9 Sand % .25 RPM 150 GPM 550 SPP On 3650 BHT F 180 Mud Vis 58 Solids % 5.6 Dig TQ 24.0 WOB 20 SPP Off 3650 Item Description Vendor SIN OD JD Stab OD F.N. Connections Length Cum Length Bit #3 OS164F+JNW I TFA=.663 Hycalog 200044 8 1/2 6x12 4 1/2 Reg P 0.85 0.85 2 PO Bias Unit 4 1/2 Reg B Ana 60298 6 3/4 Tool 4 1/2 IF B 2.32 3.17 I 3 PO Extention Sub 4 1/2 IF P Ana 631-ES-60217 6 3/4 Tool 4 1/2 IF P 1.05 4.22 4 PO Control Collar 4 1/2 IF B Control Unit 234 Ana 60057 6 7/8 Tool 4 1/2 IF B 9.91 14.13 ( 5 X-OVER 4 1/2 IF P Float Ana AFS301 6 1/2 2 3/4 4 1/2 XH B 1.35 15.48 6 NM STABILIZER 4 1/2 XH P I Ana NMSlSS-FA 011 6 3/4 2 13/16 8 1/2 2.45 4 1/2 XH B 5.62 21.10 7 CDR (PWO) 4 1/2 XH P Ana 7125 6 3/4 Tool 11.91 51/2 FH B 21.87 42.97 8 MWO 5 1/2 FH P I Ana MOC-234 6 13/16 Tool 2.39 4 1/2 XH B 28.51 71 .48 NM STABILIZER 4 1/2 XH P 9 Ana MSZSS-FA-OC 6 3/4 2 13/16 8 1/2 2.42 4 1/2 XH B 5.70 77.18 10 NM FLEX 4 1/2 XH P Ana MMFL-FA 027) 11 /16x5 1/1 2 13/16 2.55 4 1/2 XH B 31.02 108.20 11 NM FLEX 4 1/2 XH P :1 Ana MMFL-FA 025 6 5/8x5 1/16 2 13/16 2.50 4 1/2 XH B 31.01 139.21 12 NM FLEX 4 1/2 XH P Ana MMFL-FA 024) 11/16x5 1/1 2 13/16 2.53 4 1/2 XH B 29.50 168.71 13 X-OVER 4 1/2 XH P I Ana 3TXOS-FE 104: 6 3/4 2 3/4 41/21FB 1.98 170.69 14 2 Jts HWOP 5" 4 1/2 IF P NAD 2 HWOP 5 3 4 1/2 IF B 60.58 231.27 I 15 HYOJARS 4 1/2 IF P Corrosion Ring DAI LEY 1416-1562 6 1/2 2 3/4 1.70 4 1/2 IF B 32.62 263.89 Dart Valve Sub 4 1/2 IF P 16 BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF B 2.37 266.26 17 DP 5" to Surface 4 1/2 IF P NAD OP 5 4 8/29 4 1/2 IF B 266.26 BHA and Run Results I E.~~.:.~~~.~ ._.__.__.._.._.._,...__ 7.5 7.5 Hrs. Out 35.0 19.8 19.8 35.0 Why POOH I Comments Bit Data Tool IADC # Motor Footage 1378 Jars Hrs 12.3 Bit #3 k Revs 111 k RSS Grade 3-0-CT-C-X-I-BF-TD AIM=X', Res=26.46', GR=37.46', 0&1=56,67', MWO GR=54.68' PWD=28.21', Dens=X', Nue--Comment Drill to 8 1/2 hole TO, stay in target "p--- --.... .~."._-"' ..... -,.-.--.-...-...-..-,-... . ".---.".....--.- .. ,,-,~...__._------ ,,_. - ...~._._-----_..._..- BHA Weight Dry Wt 21,856 Buoyed Wt 17,561 Inel Angle 23 Buoy+lnel Wt 16,165 Hrs. In BHA and Run Objective I T~.____.....__......., _.... ,.......,........._ ..., "-.-.-...- ---...........-. Bit To I BHA #: 1 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Slide Sheet Well: NS18 Borehole: NS 18 UWI/API#: Directional Driller: James Tunnell Directional Driller: Job #: I Depth In: 201.00 Inclination In: 0.99 Azimuth In: 296.50 Depth Out: 330.00 Inclination Out: 0.99 Azimuth Out: 296.50 Tot Distance: 129.00 Dist Steering: 31.00 % Steer: 24.0 Dist Rotating: 98.00 % Rot: 76.0 Total Time: 1.1 Time Steering: 0.2 Time Rotating: 0.9 % Steer: 15.4 % Rot: 84.6 { Total ROP: 119.1 Steering ROP: 186.0 Rotating ROP: 106.9 Comments: I I Duration) Md From) Md To I RoUSlid I Course I Avg ROPI TF I Flow ISPP On ,SPP Off , WOB I RPM forq on, Svy Md I Incl I Azmth I (hr:min) (ft) (ft) (RIS) (ft) (ftIh) n (gallmin) (psi) (psi) (10001b0 (A) (ft) (0) (0) 0:15 201.00 230.00 R 29.00 116.0 500 310 300 5.0 40 3 281.00 0.99 296.50 0:08 230.00 239.00 R 9.00 67.5 515 320 300 10.0 40 3 0:10 239.00 270.00 S 31.00 186.0 M250 515 320 300 10.0 0 0 0:32 270.00 330.00 R 60.00 - 112.5 515 320 300 10.0 40 3 I I I I I I NS18_Bha's.xls Page 1 of 1 3/27/2003-4:22 PM BHA #: 2 Slide Sheet ( Client: BP Exploration Alaska Well: NS18 Directional Driller: James Tunnell Field: Northstar Borehole: NS18 Directional Driller: Structure: Northstar PF UWI/API#: Job#: I Depth In: 330.00 Depth Out: 4050.00 Tot Distance: 3720.00 Total Time: 25,6 Inclination In: 1.11 Inclination Out: 54.12 Dist Steering: 1311.00 % Steer: 35,2 Time Steering: 9.5 % Steer: 37.1 Azimuth In: 282.55 Azimuth Out: 308.24 Dist Rotating: 2409.00 % Rot: 64.8 Time Rotating: 16.1 % Rot: 62.9 I Total ROP: 145.5 Steering ROP: 138.2 Rotating ROP: 149.8 Comments: I Durationl Md Froml Md To I Rot/Slid I Course I Avg ROPI TF I Flow ISPP On 1SPP Off 1 WOB I RPM forq On 1 Svy Md I Incl I Azmth I (hr:min) (ft) (ft) (RJS) (ft) (fUh) (0) (gallmin) (psi) (psi) (1000 IbD (A) (ft) n (0) 0:17 330.00 369.00 R 39.00 137.6 635 660 620 10.0 40 3 351.00 1.11 282.55 0:33 369.00 459.00 R 90.00 163.6 480 450 400 10.0 40 3 441.00 1.27 284.77 ( 0:15 459,00 489.00 S 30.00 120.0 M290 490 680 610 10.0 0 0 533.00 1.76 281.26 0:26 489.00 550.00 R 61.00 140.8 635 830 780 15.0 40 5 624.00 2.49 295.11 0:35 550.00 640.00 R 90.00 154.3 640 620 550 15.0 40 4 660.00 3.16 291.02 0:08 640.00 665.00 S 25.00 187.5 M 310 630 880 830 15.0 0 0 750.00 5.63 296.77 0:09 665.00 685.00 R 20.00 133.3 625 890 820 20.0 40 5 840.00 7.51 301.00 0:06 685.00 710.00 S 25.00 250.0 M305 650 910 860 10.0 0 0 930.00 9.39 304.20 0:13 710.00 732.00 R 22.00 101.5 650 950 860 15.0 40 4 1030.00 11.78 306.19 0:09 732.00 757.00 S 25.00 166.7 M300 650 990 900 20.0 0 0 1121.00 14.02 306.92 . 0:06 757.00 777.00 R 20.00 200.0 650 1000 900 20.0 40 5 1218.00 17.12 308.11 0:08 777.00 802.00 S 25.00 187.5 M 310 650 1000 900 20.0 0 0 1280.00 18.42 307.73 0:07 802.00 823.00 R 21.00 180.0 650 1000 900 20.0 40 5 1310.68 19.07 309.52 I 0:07 823.00 848.00 S 25.00 214.3 G 20 650 1000 900 20.0 0 0 1408.82 21.53 312.58 0:07 848.00 873.00 R 25.00 214.3 640 950 870 15.0 40 4 1501.89 21.44 313.01 0:07 873.00 893.00 S 20.00 171.4 G20 650 1000 900 15.0 0 0 1596.67 22.10 313.43 I 0:05 893.00 913.00 R 20.00 240.0 650 1000 900 20.0 40 5 1691.84 23.74 312.27 0:08 913.00 938.00 S 25.00 187.5 GO 650 1000 900 20.0 0 0 1785.67 25.30 311.90 0:06 938.00 958.00 R 20.00 200.0 650 1000 900 20.0 40 5 1880.95 25.80 313.39 0:06 958.00 983.00 S 25.00 250.0 G 10 650 1000 900 20.0 0 0 1975.10 28.72 310.93 I 0:06 983.00 1004.00 R 21.00 210.0 650 1000 920 20.0 40 5 2068.71 30.78 309.26 0:08 1004.00 1029.00 S 25.00 187.5 GO 650 1000 930 15.0 0 0 2164.39 34.43 312.22 0:06 1029.00 1049.00 R 20.00 200.0 650 1000 930 20.0 40 3 2260.36 36.14 313.36 0:08 1049.00 1074.00 S 25.00 187.5 GO 650 1000 940 10.0 0 0 2355.46 40.72 310.89 I 0:06 1074.00 1098.00 R 24.00 240.0 645 1000 940 20.0 40 4 2451.43 42.96 309.43 0:12 1098.00 1123.00 S 25.00 125.0 GO 650 1100 990 25.0 0 0 2546.90 44.60 307.95 0:13 1123.00 1143.00 R 20.00 92.3 650 1100 990 25,0 40 5 2642.55 47.69 306.65 0:28 1143.00 1168.00 S 25.00 53.6 G 10 660 1090 975 30.0 0 0 2738.43 51.03 306.94 0:12 1168.00 1192.00 R 24.00 120.0 660 1110 975 30.0 40 7 2834.14 55.04 306.59 0:20 1192.00 1218.00 S 26.00 78.0 GO 660 1110 975 30.0 0 0 2927.54 55.90 307.26 0:04 1218.00 1226.00 R 8.00 720 1300 1200 35.0 40 5 3025.36 56,14 306.26 0:12 1226.00 1253,00 R 27.00 135,0 720 1300 1200 35.0 40 5 3120.67 56.80 306.57 0: 13 1253.00 1278.00 S 25.00 115.4 GO 750 1450 1300 35.0 0 0 3214.04 56.00 307,00 0:03 1278.00 1287.00 R 9.00 760 1500 1350 35.0 40 5 3309,10 56.61 307.00 0:14 1287.00 1312.00 S 25.00 107,1 GO 760 1500 1350 35.0 0 0 3404.87 56.86 307.64 0:10 1312,00 1337,00 R 25.00 150.0 760 1500 1350 30.0 40 5 3499.43 58,00 308,33 0:10 1337,00 1362.00 S 25.00 150.0 GO 760 1550 1350 38.0 0 0 3590,25 59,23 308.98 0: 10 1362.00 1382.00 R 20.00 120,0 760 1500 1350 35.0 40 Ô 3685,92 58.01 308.92 0:18 1382.00 1412.00 S 30.00 100.0 G -20 760 1450 1350 35.0 0 0 3781.29 57,77 308.41 0:26 1412.00 1477.00 R 65.00 150.0 765 1500 1350 30.0 40 5 3876.15 55,29 308.63 0:40 14ì7.00 1572.00 R 95,00 142.5 800 1700 1550 30.0 40 3975,52 54.12 308.24 005 1572.00 1592,00 S 20.00 240,0 G -20 810 1600 1500 25.0 0 4050.00 54,12 308.24 NS 18_Bha's.xls Page 1 of 3 3/27/2003-4:22 Pr-,\ 0:07 1592,00 1622.00 R 30.00 257.1 850 1700 1600 20.0 40 5 0:04 1622,00 1642.00 S 20.00 G -20 850 1700 1600 25.0 0 0 0:15 1642.00 1668.00 R 26.00 104.0 850 1700 1600 15.0 40 5 0:26 1668.00 1763.00 R 95.00 219.2 850 1750 1650 25.0 40 0:04 1763,00 1788.00 S 25.00 G -30 850 1750 1700 20.0 0 0 0:06 1788.00 1813.00 R 25.00 250.0 850 1750 1700 15.0 40 5 J 0:04 1813.00 1838.00 S 25.00 G -20 850 1750 1700 20.0 0 0 0:05 1838.00 1857,00 R 19.00 228.0 850 1750 1700 20.0 40 5 0:04 1857,00 1882.00 S 25.00 G -30 880 1900 1850 20.0 0 0 0:05 1882.00 1907.00 R 25.00 300.0 880 1900 1850 30.0 40 6 0:13 1907.00 1932.00 S 25,00 115.4 G -30 880 1900 1800 20.0 0 0 0:04 1932.00 1952.00 R 20.00 880 1900 1850 25.0 40 6 0:08 1952.00 1982.00 S 30.00 225,0 G -20 790 1650 1600 25.0 0 0 0:07 1982.00 2012.00 R 30.00 257.1 880 1950 1850 25.0 40 7 0:07 2012.00 2042.00 S 30.00 257.1 G -30 880 2000 1850 15.0 0 0 0:02 2042.00 2046.00 R 4.00 880 2000 1850 20.0 40 7 0:08 2046.00 2071.00 S 25.00 187.5 G -10 900 2000 1900 25.0 0 0 ,. 0:07 2071.00 2096.00 R 25.00 214.3 900 2000 1900 15.0 40 7 0:18 2096.00 2126.00 S 30.00 100.0 G -10 800 1650 1600 25.0 0 0 0:03 2126.00 2140.00 R 14.00 900 2000 1950 20.0 40 7 0:06 2140.00 2170.00 S 30.00 300.0 GO 900 2050 1950 25.0 0 0 0:05 2170.00 2200.00 R 30.00 360.0 900 2000 1950 15.0 40 7 0:06 2200.00 2230.00 S 30.00 300.0 GO 900 2050 1950 20.0 0 0 0:01 2230.00 2235.00 R 5.00 900 2000 1950 30.0 40 7 I 0:07 2235.00 2265.00 S 30.00 257.t GO 890 1900 1820 20.0 0 0 0:03 2265.00 2285.00 R 20.00 890 1870 1820 10.0 40 6 0:14 2285.00 2315.00 S 30.00 128.6 G -20 900 1950 1870 25.0 0 0 0:03 2315.00 2331. 00 R 16.00 900 1830 1760 10.0 40 6 0:08 2331.00 2361.00 S 30.00 225.0 G-30 905 1910 1850 20.0 0 0 0:06 2361.00 2381. 00 R 20.00 200.0 900 1740 1640 25.0 40 7 0:07 2381.00 2406.00 S 25.00 214.3 G -30 900 1950 1880 15.0 0 0 I 0:04 2406.00 2426.00 R 20.00 900 1920 1880 10.0 40 5 0:09 2426.00 2446.00 S 20.00 133.3 G-30 900 1960 1880 15.0 0 0 0:09 2446.00 2470.00 R 24.00 160.0 900 2000 1920 30.0 40 9 0:28 2470.00 2495.00 S 25.00 53.6 G -30 900 2000 1920 30.0 0 0 0:07 2495.00 2522.00 R 27.00 231.4 900 2000 1920 30.0 40 9 0:21 2522.00 2547.00 S 25.00 71.4 G -30 900 2050 1910 30.0 0 0 0:04 2547.00 2567.00 R 20.00 900 2010 1910 25.0 40 6 I 0:22 2567.00 2597.00 S 30.00 81.8 G -30 900 1980 1910 30.0 0 0 0:03 2597.00 2618.00 R 21.00 900 1950 1910 5.0 40 6 0:05 2618.00 2648.00 S 30.00 360.0 G -20 900 2020 1940 15.0 0 0 0:08 2648.00 2668.00 R 20.00 150.0 900 2040 1940 25.0 40 9 0:14 2668.00 2695.00 S 27.00 115.7 G -20 900 2080 1940 30.0 0 0 0:03 2695.00 2713.00 R 18.00 900 1970 1950 10.0 40 8 0:09 2713.00 2743.00 S 30.00 200.0 G -20 900 2110 2000 30.0 0 0 0:36 2743.00 2763.00 R 20.00 33.3 900 2000 1930 30.0 40 8 0:31 2763.00 2793.00 S 30.00 58.1 G -20 900 2040 1960 35.0 0 0 0:08 2793.00 2808.00 R 15,00 112.5 900 2020 1960 30.0 40 8 0:11 2808.00 2841.00 S 33.00 180.0 G -20 890 2000 1930 30.0 ° 0 0: 13 2841,00 2860.00 R 19.00 87.7 900 2000 1930 30.0 40 8 0:08 2860.00 2890.00 S 30.00 225.0 G -20 900 1980 1930 20.0 0 0 0:02 2890.00 2903.00 R 13.00 900 1960 1930 10.0 40 8 0:39 2903,00 2998.00 R 95.00 146.2 900 2000 1900 35.0 40 8 0:08 2998.00 3018.00 S 20.00 150,0 G -35 890 2020 1890 30.0 0 ° 0:25 3018,00 3093.00 R 75,00 180.0 890 2000 1890 30,0 40 10 0: 17 3093.00 3117.00 S 24.00 84.7 G -30 880 2000 1950 35.0 ° 0 0:25 3117,00 3188.00 R 71.00 170.4 880 2150 1950 40.0 40 10 NS 18_Bha's.xls Page 2 of 3 3/27/2003-4:22 PM 0:20 3188.00 3283.00 R 95,00 285.0 880 2150 1950 40.0 40 ~O 0:03 3283.00 3303.00 S 20.00 G -25 900 2000 1900 40.0 0 0 0:28 3303.00 3378.00 R 75.00 160.7 940 2250 2150 20.0 40 1 1 0:54 3378.00 3473.00 R 95.00 105.6 900 2150 1950 30.0 40 12 0: 15 3473.00 3567.00 R 94,00 376.0 860 1850 1750 30.0 40 11 0:46 3567.00 3663.00 R 96.00 125.2 860 1850 1750 40.0 40 12 0:09 3663.00 3693.00 S 30.00 200.0 G -160 860 1800 1700 45.0 0 12 0:13 3693.00 3757.00 R 64.00 295.4 860 1800 1700 40.0 40 12 0:22 3757.00 3778.00 S 21,00 57.3 G 180 860 1850 1700 45.0 0 0 1:00 3778.00 3852.00 R 74.00 74.0 860 1850 1700 40.0 40 11 0:24 3852.00 3882.00 S 30.00 75.0 G 180 860 1800 1700 50.0 0 0 0:51 3882.00 3948.00 R 66.00 77.6 860 1850 1700 40.0 40 12 1:08 3948.00 4043.00 R 95.00 83.8 860 1900 1800 40.0 40 12 0:07 4043.00 4050.00 R 7.00 60.0 860 1900 1800 40.0 40 12 I ( NS 18_Bha's.xls Page 3 of 3 3/27/2003-4:22 PM I BHA #: 3 Slide Sheet Client: BP Exploration Alaska Well: NS18 Directional Driller: James Tunnell Field: Northstar Borehole: NS 18 Directional Driller: Alan robertson Structure: Northstar PF UWI/API#: Job #: I Depth In: 4050.00 Depth Out: 14693.00 Tot Distance: 10643.00 Total Time: 88.6 Inclination In: 53.45 Inclination Out: 41.83 Dist Steering: 0.00 % Steer: 0.0 Time Steering: 0.0 % Steer: 0.0 Azimuth In: 305.27 Azimuth Out: 307.49 Dist Rotating: 10643.00 % Rot: 100.0 Time Rotating: 88,6 % Rot: 100,0 Total Rap: 120.1 Steering Rap: 0.0 Rotating Rap: 120.1 Comments: I Durationl Md Froml Md To I RoUSlid I Course I Avg ROPI TF I Flow ISPP On ,SPP Off' WOB I RPM forq on, Svy Md I Incl I Azmth I (hr:min) (ft) (ft) (RJS) (ft) (ftlh) (0) (gal/min) (psi) (psi) (10001bD (A) (ft) n (0) 0:05 4050.00 4065.00 R 15.00 180.0 0/0% 850 1550 1550 10.0 80 9 0:03 4065.00 4070.00 R 5.00 700 950 950 10.0 80 9 I 0:08 4070.00 4097.00 R 27.00 202.5 900 1450 1450 10.0 120 9 0:14 4097.00 4160.00 R 63.00 - 270.0 900 1450 1450 10.0 120 9 0:19 4160.00 4255.00 R 95.00 300.0 900 1450 1450 10.0 120 9 4191.86 53.45 305.27 0:17 4255.00 4351.00 R 96.00 338.8 900 1450 1450 10.0 140 9 4287.67 53.34 306.42 0:15 4351.00 4445.00 R 94.00 376.0 900 1450 1450 10.0 150 10 4382.39 53.81 305.11 0:17 4445.00 4540.00 R 95.00 335.3 900 1500 1500 10.0 130 10 4477.03 53.93 305.49 0:38 4540.00 4635.00 R 95.00 150.0 900 1500 1500 10.0 130 10 4571.59 54.12 303.99 0:19 4635.00 4730.00 R 95.00 300.0 900 1500 1500 10.0 130 10 4667.63 54.30 304.83 I 0:18 4730.00 4825.00 R 95.00 316.7 0/20% 900 1500 1500 10.0 130 10 4761.62 53.95 303.90 0:16 4825.00 4920.00 R 95.00 356.3 900 1500 1500 10.0 130 11 4856.65 54.31 305.15 0:24 4920.00 5015.00 R 95.00 237.5 900 1550 1550 10.0 130 11 4951.25 54.69 306.46 I 0:23 5015.00 5110.00 R 95.00 247.8 900 1550 1550 10.0 130 11 5046.76 55.23 307.19 0:18 5110.00 5205.00 R 95.00 316.7 900 1600 1600 10.0 130 11 5142.43 55.56 307.82 0:22 5205.00 5301.00 R 96.00 261.8 900 1650 1650 10.0 130 12 5237.81 56.11 308.11 I 0:16 5301.00 5396.00 R 95.00 356.3 900 1650 1650 10.0 130 12 5333.96 56.48 307.86 0:18 5396.00 5493.00 R 97.00 323.3 900 1700 1700 10.0 130 12 5429.05 56.89 308.37 0:20 5493.00 5588.00 R 95.00 285.0 900 1700 1700 10.0 130 13 5524.61 57.60 309.01 0:16 5588.00 5684.00 R 96.00 360.0 900 1700 1700 10.0 150 13 5620.82 58.07 309.31 0:39 5684.00 5779.00 R 95.00 146.2 010% 900 1750 1750 10.0 140 13 5716.52 58.46 309.68 0:17 5779.00 5875.00 R 96.00 338.8 890 1720 1720 10.0 140 13 5812.50 58.59 309.86 0:16 5875.00 5971.00 R 96.00 360.0 900 1750 1750 10.0 160 13 5906.45 58.55 309.30 0:27 5971.00 6065.00 R 94.00 208.9 900 1750 1750 10.0 160 13 6001.37 58.48 309.10 0:38 6065.00 6160.00 R 95.00 150.0 900 1750 1750 10.0 160 13 6096.84 58.31 309.68 0:24 6160.00 6256.00 R 96.00 240.0 900 1750 1750 10.0 160 12 6191.43 58.09 309.60 0:32 6256.00 6351.00 R 95.00 178.1 900 1750 1750 10.0 120 12 6287.48 57.99 310.00 0:47 6351.00 6447.00 R 96.00 122.6 900 1800 1800 10.0 140 13 6382.41 57.78 310.82 0:42 6447.00 6495.00 R 48.00 68.6 900 1800 1800 10.0 150 12 6477.00 58.05 311,01 0:18 6495.00 6542.00 R 47.00 156.7 900 1850 1850 10,0 150 13 0:31 6542.00 6637.00 R 95.00 183.9 900 1850 1850 10.0 150 13 6573.11 58.09 310,95 0:36 6637,00 6732.00 R 95.00 158.3 900 1850 1850 10.0 150 13 6667.77 57.85 310,77 0:48 6732.00 6827.00 R 95,00 118.7 900 1900 1900 10.0 150 13 6761.25 57,65 310.29 0:26 6827.00 6922.00 R 95.00 219.2 900 1900 1900 10.0 150 13 6858.23 57.31 311.05 0:16 6922,00 7017.00 R 95.00 356.3 900 1900 1900 5.0 150 14 6953.34 57,27 310.68 0:22 7017.00 7112.00 R 95.00 259,1 254/20% 900 1900 1900 5.0 150 14 7048.34 57.34 310.67 0:20 7112.00 7207.00 R 95.00 285.0 900 1900 1900 8.0 150 15 7142,04 57.44 309.93 0:23 7207,00 7302.00 R 95.00 247.8 900 1900 1900 10.0 150 15 7237,08 57,61 309,90 0:18 7302,00 7396.00 R 94,00 313.3 248/40% 900 1900 1900 10.0 150 15 7332.53 57.83 309.98 0:30 7396,00 7492,00 R 96.00 192.0 900 1950 1950 10.0 140 15 7428.76 57,93 308,53 0:23 7492.00 7586.00 R 94.00 245.2 900 1950 1950 10.0 140 15 7523.75 58.20 306.79 0:24 7586,00 7682.00 R 96.00 240.0 900 2000 2000 10,0 150 15 7619.07 58.33 305.21 NS18_Bha's.xls Page 1 of 3 3/27/2003-4:22 PM 3/27/2003-4:22 PM Page 2 of 3 NS18_Bha's.xls 0:50 7682.00 7777.00 R 95.00 114.0 900 2050 2050 10.0 150 15 7714.10 58.57 304.62 0:44 7777.00 7874.00 R 97.00 132.3 0/0% 900 2100 2100 10.0 140 16 7810.36 58.21 302.62 0:24 7874,00 7969.00 R 95.00 237.5 900 2100 2100 10.0 140 16 7906.00 58.17 302.96 0:37 7969,00 8063.00 R 94.00 152.4 900 2200 2200 10.0 150 16 7998.39 57,94 303.32 1:40 8063.00 8159.00 R 96.00 57.6 900 2200 2200 10.0 150 17 8095,73 57,85 303.53 0:37 8159,00 8254.00 R 95.00 154.1 900 2200 2200 10.0 150 16 8190.23 57.62 303.76 I 1:03 8254.00 8350.00 R 96.00 91.4 900 2300 2300 10.0 150 16 8286.77 57.80 304.13 0:58 8350.00 8445,00 R 95.00 98.3 71/20% 900 2200 2200 10.0 150 16 8381,33 57.59 304.79 0:53 8445.00 8542.00 R 97.00 109.8 900 2300 2300 10.0 150 16 8478.95 57.15 305.33 0:43 8542.00 8637.00 R 95.00 132.6 900 2380 2380 10.0 150 14 8576.15 56.81 306.29 1 :16 8637.00 8731.00 R 94.00 74.2 36/20% 900 2350 2350 10.0 150 15 8666.77 56.38 305.95 2:39 8731.00 8756.00 R 25.00 9.4 900 2300 2300 10.0 150 15 1:45 8756.00 8827.00 R 71.00 40.6 900 2350 2350 10.0 150 15 8763.65 56.19 308.20 0:28 8827.00 8922.00 R 95.00 203.6 900 2350 2350 10.0 150 15 8858,57 56.19 308.94 1:36 8922.00 9017.00 R 95.00 59.4 900 2300 2300 10.0 150 15 8953.74 56.12 309.34 1:20 9017.00 9112.00 R 95.00 71.2 0/0% 900 2400 2400 10.0 150 16 9049.24 56.39 310.13 0:38 9112.00 9208.00 R 96.00 151.6 900 2400 2400 10.0 150 15 9144.86 56.22 309.26 0:38 9208.00 9303.00 R 95.00 150.0 " 900 2400 2400 10.0 150 16 9240.02 56.08 309.18 I 0:44 9303.00 9396.00 R 93.00 126.8 900 2350 2350 10.0 150 16 9335.64 55.74 309.17 0:43 9396.00 9494.00 R 98.00 136.7 900 2400 2400 10.0 150 16 9431.05 55.39 309.14 1:47 9494.00 9589.00 R 95.00 53.3 900 2450 2450 10.0 150 16 9526.50 55.12 309.10 0:32 9589.00 9684.00 R 95.00 178.1 " 900 2400 2400 15.0 150 17 9620.55 54.87 309.37 0:37 9684.00 9779.00 R 95.00 154.1 900 2450 2450 15.0 150 17 9715.38 54.60 308.88 0:36 9779.00 9874.00 R 95.00 158.3 " 900 2450 2450 15.0 150 17 9810.97 54.53 309.09 f 0:31 9874.00 9969.00 R 95.00 183.9 900 2500 2500 15.0 150 17 9905.17 54.49 309.28 1:02 9969.00 10065.00 R 96.00 92.9 " 900 2500 2500 15.0 150 17 10000.59 54.25 309.16 0:47 10065.00 10160.00 R 95.00 121.3 " 900 2550 2550 15.0 150 17 10096.79 53.92 309.29 1:16 10160.00 10256.00 R 96.00 75.8 326/20% 880 2600 2600 15.0 150 17 10191.53 53.78 309.47 I 0:41 10256.00 10350.00 R 94.00 137.6 " 900 2650 2650 15.0 150 17 10286.70 54.07 309.11 0:47 10350.00 10446.00 R 96.00 122.6 " 900 2650 2650 15.0 150 17 10380.99 54.45 309.10 1:14 10446.00 10539.00 R 93.00 75.4 " 900 2700 2700 15.0 150 17 10476.35 54.83 309.34 1:02 10539.00 10610.00 R 71.00 68.7 " 900 2770 2770 15.0 150 17 10571.41 55.36 309.71 I 0:32 10610.00 10635.00 R 25.00 46.9 " 900 2800 2800 15.0 150 17 0:43 10635.00 10729.00 R 94.00 131.2 " 900 2800 2800 15.0 150 18 10666.19 55.75 310.59 0:32 10729.00 10824.00 R 95.00 178.1 " 900 2800 2800 15.0 150 18 10760.77 56.13 310.71 1:36 10824.00 10918.00 R 94.00 58.8 900 2800 2800 15.0 150 20 10854.57 56.71 310.84 0:49 10918.00 11013.00 R 95.00 116.3 " 900 2750 2750 15.0 150 20 10947.38 56.97 310.59 0:41 11013.00 11108.00 R 95.00 139.0 " 900 2950 2950 15.0 150 20 11042.46 57.32 310.97 0:44 11108.00 11203.00 R 95.00 129.5 " 900 2800 2800 15.0 150 20 11139.49 57.59 309.91 0:51 11203.00 11297.00 R 94.00 110.6 " 900 2900 2900 15.0 150 20 11234.43 57.86 310.12 1:00 11297.00 11393.00 R 96.00 96.0 900 2950 2950 15.0 150 20 11327.46 58.10 309.49 0:47 11393.00 11488.00 R 95.00 121.3 900 3000 3000 15.0 150 20 11425.05 58.30 309.53 0:59 11488.00 11583.00 R 95.00 96.6 900 3000 3000 15.0 150 20 11517.60 58.50 309.79 0:47 11583.00 11678.00 R 95.00 121.3 217/20% 860 2950 2950 18.0 150 21 11614.52 58.61 309.92 0:41 11678.00 11773.00 R 95.00 139.0 " 900 3000 3000 18.0 150 21 11711.03 57.93 309.16 0:39 11773.00 11868.00 R 95.00 146.2 900 3000 3000 20.0 150 21 11803.31 57.33 308.53 1:01 11868.00 11963.00 R 95.00 93.4 900 3000 3000 20.0 150 21 11899.19 56.78 307.19 0:43 11963.00 12058.00 R 95.00 132.6 900 3000 3000 20.0 150 21 11994.42 56.20 306.27 0:39 12058.00 12153.00 R 95.00 146.2 900 3050 3050 20.0 150 21 12089.41 55.61 305.45 0:41 12153.00 12247.00 R 94.00 137.6 . 900 3050 3050 20.0 150 21 12183.86 55.03 305.67 0:53 12247.00 12342.00 R 95.00 107.5 900 3050 3050 20.0 150 21 12278.16 54.24 304.93 0:43 12342.00 12438.00 R 96.00 134.0 0/20% 900 2950 2950 20.0 150 22 12374.44 53. 72 305.01 0:40 12438.00 12534.00 R 96.00 144.0 900 3050 3050 20.0 150 21 12470.34 53.82 304.80 0:48 12534,00 12629.00 R 95,00 118.7 900 3050 3050 20.0 150 21 12566,37 53,80 305.01 0:32 12629.00 12682.00 R 53.00 99.4 22140% 900 3050 3050 20.0 150 21 12660,29 53.75 305.38 0:23 12682.00 12725.00 R 43.00 112,2 900 3050 3050 20.0 150 21 0:38 12725,00 12818.00 R 93.00 146.8 900 3000 3000 20.0 150 21 12754,37 53.99 307.03 3/27/2003-4:22 PM Page 3 of 3 NS18_Bha's.xls I I 0:42 12818.00 12912.00 R 94.00 134,3 900 3150 3150 20.0 150 22 12848.36 54.21 308.43 0:44 12912.00 13007,00 R 95.00 129.5 326/20% 900 3250 3250 20.0 150 22 12941.73 54.17 308.66 0:39 13007.00 13103.00 R 96.00 147.7 900 3200 3200 20.0 150 22 13038.40 54.31 309.03 0:35 13103.00 13198.00 R 95.00 162.9 900 3150 3150 20.0 150 22 13135.16 54.64 309,13 0:47 13198.00 13292.00 R 94.00 120.0 0/0% 870 3150 3150 20.0 150 23 13225.71 54,68 308,99 0:38 13292.00 13389.00 R 97.00 153,2 900 3250 3250 20.0 150 23 13324,37 54.13 309.58 r 0:40 13389.00 13482.00 R 93.00 139.5 900 3250 3250 20.0 150 23 13419.60 53.23 309.14 0:43 13482.00 13578.00 R 96.00 134.0 900 3200 3200 20.0 150 23 13515.51 52.37 308.69 0:38 13578.00 13673.00 R 95.00 150.0 900 3250 3250 20.0 150 23 13610,21 51.78 308,95 0:42 13673.00 13768.00 R 95.00 135.7 900 3250 3250 20.0 150 23 13706.03 50.93 308. 16 I 0:45 13768.00 13864.00 R 96.00 128.0 870 3050 3050 20.0 150 23 13800.84 50.27 308.44 1:47 13864.00 13960.00 R 96.00 53.8 865 3500 3500 20.0 150 23 13896.70 49.46 308.12 1:26 13960.00 14055.00 R 95.00 66.3 880 3650 3650 15.0 150 25 13992.58 48.60 308.00 I 2:15 14055.00 14150.00 R 95.00 42.2 880 3550 3550 15.0 150 23 14087.22 47.82 309,00 1:58 14150.00 14245.00 R 95.00 48.3 880 3550 3550 15.0 150 23 14181.94 47.15 308.15 2:04 14245.00 14341.00 R 96.00 46.5 880 3450 3450 20.0 130 25 14277.49 46.31 308.37 I 1:32 14341.00 14436.00 R 95.00 62.0 " 840 3320 3320 18.0 115 25 14373.53 44.90 308.28 1 :35 14436.00 14531.00 R 95.00 60.0 326/20% 820 3200 3200 18.0 120 26 14467.82 43.44 308.51 1:19 14531.00 14625.00 R 94.00 71.4 " 840 3450 3450 16.0 120 25 14562.69 42.31 307.76 0:55 14625.00 14693.00 R 68.00 74.2 840 3400 3400 13.0 120 26 [ I BHA #: 4 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Depth In: 14693.00 Inclination In: 40.74 Azimuth In: 306.48 Depth Out: 15172.00 Inclination Out: 34.76 Azimuth Out: 308.44 Total ROP: 64.0 Comments: I I Duration I Md Froml Md To I Rot/Slid I Course I Avg ROPI (hr:min) (ft) (ft) (RIS) (ft) (ftIh) 0:03 14693.00 14695.00 R 2.00 1:44 14695.00 14713.00 R 18.00 10.4 ( 1 :02 14713.00 14791.00 R 78.00 75.5 1 :08 14791.00 14886.00 R 95.00 - 83.8 1: 11 14886.00 14982.00 R 96.00 81.1 0:24 14982.00 15017.00 R 0:48 15017.00 15077.00 R 1:09 15077.00 15172.00 R 35.00 60.00 95.00 I I I I NS18_Bha's.xls Slide Sheet Well: NS18 Borehole: NS 18 UWIIAPI#: Directional Driller: James Tunnell Directional Driller: Alan Robertson Job#: Tot Distance: 479.00 Dist Steering: 0.00 % Steer: 0.0 Dist Rotating: 479.00 % Rot: 100.0 Total Time: 7.5 Time Steering: 0.0 Time Rotating: 7.5 % Steer: 0.0 % Rot: 100.0 Steering ROP: 0.0 Rotating ROP: 64.0 87.5 75.0 82.6 TF I Flow ISPP On ,SPP Off' WOB I RPM forq on, Svy Md I Incl I Azmth I (0) (gal/min) (psi) (psi) (1000 Ib~ (A) (ft) (0) (0) 480 2950 2950 5.0 100 22 14732.87 40.74 306.48 480 2750 2750 20.0 120 21 14828.91 39.20 307.49 550 3500 3500 15.0 150 23 14924.34 37.57 307.00 540 3450 3450 15.0 150 24 15019.68 36.26 308.01 540 3450 3450 15.0 150 23 15114.53 34.76 308.44 540 3450 3450 15.0 150 23 540 3450 3450 15.0 150 23 550 3550 3550 20.0 150 24 Page 1 of 1 3/27/2003-4:23 PM 3/27/2003-4:23 PM Page 1 of 1 NS18_Bha's.xls I Rot/Slid I Duration I Md From I Md To I Avg ROPI TF I Flow ISPP On ~ WOB I RPM forq On 1 Svy Md I Incl I Azmth I Comment I (R/S) (hr:min) (ft) (ft) (ft/h) (0) (gal/min) (psi) (1000 Ibf) (c/min) K ft/lbs (0) (0) R 1 :13 15172.00 15263.00 74.8 -- 550 3650 20.0 150 24 15204.17 34.04 308.82 RSS @ 337/60% R 0:49 15263.00 15359.00 117.6 - 550 3650 20.0 150 24 15299,96 34.52 308.15 RSS @ 337/60% R 0:45 15359.00 15454.00 126.7 -- 550 3650 20.0 150 24 15394.77 34.92 308.02 RSS @ 337/40% I R 0:44 15454.00 15548.00 128.2 -- 550 3650 20.0 150 24 15488.84 35.04 308.01 RSS @ 337/40% R 0:42 15548.00 15644.00 137.1 -- 550 3650 25.0 150 24 15585.09 35.03 307.35 RSS @ 337/40% R 0:48 15644.00 15740.00 120.0 - 500 3200 15.0 150 24 15680.74 34.19 306.92 RSS @ 337/40% I R 0:57 15740.00 15835.00 100.0 --- 525 3350 15.0 150 24 15774.89 33.66 307.01 RSS @ 337/40% R 0:47 15835.00 15930.00 121.3 - 512 3220 20.0 150 22 15870.90 32.78 307.30 RSS @ 337/40% R 0:38 15930.00 16025.00 150.0 --- 510 3260 20.0 150 24 15965.00 30.92 307.04 RSS@ 337/40% R 0:36 16025.00 16120.00 158.3 -- 522 3370 25.0 150 22 16059.32 29.05 306.86 RSS @ 337/40% I R 0:44 16120.00 16215.00 129.5 - 522 3400 22.0 150 24 16155.28 27.61 306.49 RSS @ 337/40% R 0:37 16215.00 16309.00 152.4 -- 522 3400 22.0 150 23 16249.90 25.67 305.46 RSS @ 337/40% R 1:31 16309.00 16403.00 62.0 -- 523 3340 25.0 150 23 16344.38 23.99 305.13 RSS @ 337/40% R 0:51 16403.00 16499.00 112.9 - 545 3500 25.0 150 23 16439.46 23.43 305.81 RSS@337/40% ( R 0:38 16499.00 16550.00 80.5 - 540 3475 25.0 150 24 16488.39 22.70 306.38 RSS @ 337/40% I Comments: Rotating Rap: 111.7 Steering Rap: 0.0 Total Rap: 111.7 % Steer: 0,0 % Rot: 100.0 Total Time: 12,3 Time Steering: 0.0 Time Rotating: 12.3 Tot Distance: 1378.00 Dist Steering: 0.00 % Steer: 0.0 Dist Rotating: 1378.00 % Rot: 100.0 Depth Out: 16550,00 Inclination Out: 22.70 Azimuth Out: 306.38 Depth In: 15172.00 Inclination In: 34.04 Azimuth In: 308.82 I Directional Driller: Directional Driller: Job#: Slide Sheet Well: NS18 Borehole: NS18 UWI/API#: Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Schlumberger BHA #: 5 I \~, !\r .}...I)::: Schlumberger BHA# 6 Job # 40007796 Date In 28-Dec-02 Date Ou t 31-Dec-02 Hole Size 6 1, S ( Customer BP ADW Time In 23:00 Time Out 14:30 Hole Sect ProdL;ction Well NS-18 Depth In 16,550 Depth Out 16,865 Bha Type Steerable Field Northstar TVD In 10,842 TVD Out 11,1 35 Hrs BRT 63.50 Rig Nabors 33E Drlg Hrs 11.7 Drlg Ft 315 Avg ROP 26.92 I AF£ # 831319 Slide Hrs 0.3 Slide Ft 3 Slide ROP 10.00 DD's Rinke Rot Hrs 11.4 Rot Ft 312 Rot ROP 27.37 Co. Men Polya / Clump Pump Hrs 32.8 Rotate % 99 Slide % 1 PDM Run # R/S 7/8 PDM Jet 8 Inclln 22.70 Az In 306.38 Bit>Srvy 74.10 PDM Ser# 475-3717 Stages 2.0 Bearing OSB Incl Out 20.39 Az Out 306.29 T/F Corr 108.9 PDM Size 4 3/4 Rev/Gal 0.300 Rubber RM100D Avg Dls Max Ds Plan Dls Mud Type Dril-N Mud Wt 9.2 Sand % RPM 100 GPM 340 SPP On 2250 I BHT F Mud Vis 43 Solids % 5.5 DIg TQ 16 K WOB 10 SPP Off 2150 Item Description Vendor SIN OD ID Stab OD F.N. Bottom Conn Length Cum Length In lOut Top Conn I Bit#6 HC408 HTC 7101710 6 1/8 4 X 13 0.50 0.50 TFA=.518 Jets 3 1/2 REG 2 ~ 3/4 PDM SSS 1.15' Ana 475-3717 4 3/4 Tool 5 7/8 3 1/2 Reg B 22.84 23.34 3 1/2 IF B ( 3 FLOAT SUB Ana GLOO 276 4 5/8 2 1/4 3 1/2 IF P 1.60 24.94 Float 3 1/2 IF B 4 AON4 Ana 125 4 3/4 Tool 5 7/8 2.14 3 1/2 IF P 27.00 51.94 ( 3 1/2 IF B 5 NM IB Stab Ana 002 4 3/4 2 1/4 6 1/8 2.56 3 1/2 IF P 5.99 57.93 3 1/2 IF B 6 NM SlimPulse DC Ana 4741 4 13/16 2 1/4 3 1/2 IF P 33.49 91.42 I 3 1/2 1 F B 7 ARC5 Ana 62 4 3/4 Tool 1.44 3 1/2 IF P 23.73 115.15 3 1/2 IF B I 8 NM IB Stab Ana 810 4 3/4 2 1/4 6 2.15 3 1/2 IF P 4.87 120.02 31/211=B 9 NMOC Ana NMDC-EA-001 4 3/4 2 1/4 3 1/2 IF P 30.98 151.00 ( 3 1/2 IF B 10 NMDC Ana NMDC-EA-004 4 3/4 2 1/4 3 1/2 IF P 31.01 182.01 Corrosion ring 3 1/2 IF B 11 PBL Sub NOR475BP64 4 3/4 2 1/2 3 1/2 IF P 8.12 190.13 I 3 1/2 IF B 12 HYOJAR DAILEY 1400-1407 5 1/4 2 1/4 1.85 3 1/2 1 F P 30.12 220.25 HT40 13 6 Jts HWOP NAD 4" HWOP 4 2 11/16 HT 40 P 184.30 404.55 HT 40 B 14 72 Jts. OP 4" NAD 720P 4 4 3 5/16 HT 40 P 2262.48 2667.03 HT 40 B I 15 XO NAD 400008C 6 1/4 2 5/8 HT 40 P 1.88 2668.91 4 1/2 IF B 16 Dart Valve Sub BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF P 2.37 2671.28 I 4 1/2 IF B 17 DP 5" to Surface NAD OP 5 4 1/4 4 1/2 IF P 2671 .28 4 1/2 IF B -..-.---- ..-. ."...-.-- -....- ,- ------- .-,."..-.. ~-_. .._.~-,.,.. .._.. - ... ". --.--. ----- BHA Weight Dry Wt 15,479 Buoyed Wt 13,310 Inc! Angle 23 Buoy+lnc! Wt 12,252 Bit Data IADC "# Footage 315 Hrs 11 .7 k Revs 140 k Grade 7-7-BT-A-X-IN-RO-TD Tool Motor Jars Bit #6 Hrs. In 27.2 12.7 Hrs. Out 60.0 24.4 BHA and Run Objective Drill to TO ( BHA and Run Results Ha~__~ ig~~~_r.q~:, ..____.._.__n_..__'_. 11,7 Why POOH / Comments I~.~..__._-----,_.__._-_._,- 32.8 _,...".__~,___h.,_'_.___.__..__._..___ Bit To JRes:97.95, Arc Ga=102.87, Slimpulse Ga, 77.10, 0&1,74.10, Neu=34.50, Oen=32.25 ~omment 3/27/2003-4:23 PM Incl I Azmth I DLS I n {OJ (0 /1 CO ft) 22.77 304.65 0.86 22.01 305.21 0.81 20.59 306.29 1.57 20.30 306.29 1.01 % Steer: 2.2 % Rot: 97.8 Schlumberger Page 1 of 1 NS18 Bha06_12-31-02.xls I I I I 16757.11 16 16785.70 16 9.0 0.0 2250 2250 24.3 15.6 I 95.00 28.00 3:55 16742.00 16837.00 1 :48 16837.00 16865.00 340 340 R R 100 100 2100 2100 I Duration I Md From I Md To , course, Avg ROP' ROt/Slid' TF , Flow 'SPP On ,SPP Off' WOB , RPM rorq on, Svy Md , I (hr:min) (ft) (ft) (ft) (ftIh) (RIS) (0) (gaVmin) (psi) (psi) (1000Ibf) K ftIlbs (ft) 0:30 16550.00 16570.00 20.00 40.0 R --- 340 2150 1950 7.0 35 17 16566.53 0:36 16570.00 16607.00 37.00 61.7 R -- 340 2150 1950 7.0 35 17 0:15 16607.00 16610.00 3.00 12.0 S GO 340 2150 1950 30.0 0 0 1:18 16610.00 16647.00 37.00 28.5 R --- 340 2150 1950 7.0 40 17 3:05 16647.00 16742.00 95.00 30.8 R --- 340 2150 1950 5.0 100 16 16663.54 Comments: Rotating ROP: 27.9 Steering ROP: 12,0 Total ROP: 27.5 Total Time: 11.5 Time Steering: 0.3 Time Rotating: 11,2 Tot Distance: 315.00 Dist Steering: 3.00 % Steer: 1.0 Dist Rotating: 312.00 % Rot: 99.0 I Depth Out: 16865.00 Inclination Out: 20.39 Azimuth Out: 306.29 Depth In: 16550.00 Inclination In: 22.77 Azimuth In: 304.65 Directional Driller: Rinke Directional Driller: Job#: Slide Sheet Well: NS18 Borehole: NS18 UWI/API#: 50-029-23102-00 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF BHA #: 6 I I - ,...-- - - - -.. ~ ~ ~ ~ -..... -... --.¡ - ~ ~ Customer: BP EXPLORATION ALASKA inch at sperry-sun Well: NS18 inch at Area: BEAUFORT SEA,ALASKA inch at Lease: NORTHST AR 7" inch at DRilliNG SERVICES Rig: NABORS DRLG RIG 33E inch at Mud Company: BAROID inch at Bit Record Job No.: AK-AM 22120 BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours Rap RPM KREV Slide No. Type Number In Out ftlhr % GRADE 1 1 MX-C1 600494904 16 1.031 201 330 129 1.1 222 35 5K 24 2 RR1 MX-C 1 600494904 16 1.031 330 4050 3921 19.5 169 35 177K 35 2-3Wf -A-E-I-NO- TO 3 2 RSX238HF+GS 203060 12.25 0.941 4050 14693 10643 88.6 120 150 797K 2-0-CT -C-X-I-WT - TD 4 3 OS70FNPV 200044 8.5 0.663 14693 15172 479 7.5 64 150 68K 5 RR3 OS70FNPV 200044 8.5 .907 15172 16550 1378 12.3 112 150 111K 3-0-CT -C-X-BF- TO 6 4 HC408 710710 6.125 .518 16550 16865 315 11.7 26.9 100 140K 7 -7BT -A-X-IN-RO- TD - - ---. - - - - - - Customer: BP ALASKA Casing Program 20" inch at 201 ft sperry-sun Well: NORTHSTAR NS18 13.375" inch at 4033' ft Area: BEAUFORT SEA, ALASKA 9.625" inch at 14668 ft Lease: NORTHST AR 7" inch at 16546 ft DRilliNG SERVICES Rig: NABORS DRILLING RIG 33E 4.5" inch at ft Mud Company: BAROID DRILLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 22120 Depth MW Vis PV YP Gels Fltr HTHP Cake Sol Oil Water Sd CEC pH Pm I Pf / Mf Chlorides Calcium Comments Date ft Ib/gal see LB/100 10S/10M mll30 ml@deg F 32's % % % % mge/hg ppm ppm UII1ti/UZ 637 1$.9 91 19 46 17/Z6/Zts 1U.U Z 3.ti U.U 96.4 U./~ U.U 1S.5 U.UU U.UU/U.Z5 19UUU tiUU ~pua UII1//UZ Z61U 8.Z IZ 16 4ti Z3/Z9/31 9.6 Z 6.Z 1.U 9Z.8 1.5U 6.U 9.U U.3U U.U~/U.6U 195UU ISUU rurlllIng U1I11S/UZ 4U5U 8.1 61 14 37 15/ZU/Z4 6.6 Z 5.5 1.U 93.5 1.UU IS.U 1S.5 U.5U U.1U/U.8U 195UU I:S6U 1 U 1;$ ;S/1S l;sg UII19/UZ 4U5U 8.U 75 16 4Z 1U/13/15 11.U Z 4.Z U.5 95.3 U.5U 4.U ts.U U.1U U.UU/U.;S5 19UUU tsUU rt;ement l;~(:j U7/ZU/UZ 4U5U 8.7 49 1/ Z3 ti/6/1 U 9.Z 1 Z.5 U.U 9/.5 U.UU U.U 9.Z U.5U U.3U/U.1U 19UUU 9UU ~IH, test l;sg UIIZ1/UZ 645U 8.U 59 14 Z6 1S/1:U14 6.ti 1 4.1S 1.U 94.2 U.Z5 4.U 9.U U.35 U.ZU/U.ti5 195UU 9tsU rurlllmg UlIZ:UUZ ts75U 8.1 tiU 15 U 9/13/15 5.6 1 5.5 1.5 93.U U.Z5 7.U 9.U U.1U U.U5/U.1S5 195UU 1UUU rurll II ng UlIZ;S/UZ 1UtiUU 8.Z 6U 14 31 1:U111ZU 5.Z 1 6.U Z.U 9Z.U U.25 6.5 ts.6 U.U5 U.UUlU.6U ZU5UU 11UU rurllllng U7/Z4/UZ 1Z675 8.4 56 16 25 1:U1ti/ZU I.ts 2 7.9 2.5 1S9.6 U.2~ 14.U 6.3 U.UU U.UU/U.6U 195UU tsUU rurll II ng . U7/Z5/UZ 144Z3 1U.6 55 16 33 15/Z7/32 4.6 1U.U 2 12.U Z.5 1S~.5 U.2U 6.5 IS.U U.UU U.U/U.8U 19UUU tslSU rurlllmg UlIZ6/UZ 14ti93 1U.5 61 19 3f) 19/25/35 4.7 1 12.2 4.U 1S3.6 U.1U 12.~ 7.~ U.UU U.U/U.tsU 19UUU 92U ¡l--UUH Uts/U IUZ 14ti93 1U.4 53 19 Z6 1ti/Z4IZ7 5.U 1 12.U 4.U ts4.0 U.UU 12.U 7.5 U.UU U.U/U.8U 19UUU 61SU 'kun 9 5/1S l;sg U7/Zts/U2 14ö93 1U.2 42 14 21 1/11113 6.Z 1 1U.ti 2.U 1S7.4 U.UU 1.5 7.U U.UIJ U.UU/1.3U 19UUU ISISU 'klg uown l;tnt H U7/Z9/UZ 14ti93 1U.Z 4Z 14 Z1 ts/11/13 ti.Z 1 1U.ti 2.U 1S7.4 U.UU 1.5 7.1 U.UU U.UU/1.3U 19UIJU ISISU 'kIH tslt #3 U 1I3U/UZ 15172 12.9 51 26 29 11/Z6/32 4.4 1U.U 1 22.5 2.5 75.0 U.UU 6.5 1S.1 U.UU U.UU/Z.ISU 5tsUUU 92U ¡l--UUH U7/31/UZ 1517Z 12.9 55 Z9 3Z 1:U3U/33 3.ti 9.ti 1 22.5 Z.tI 75.U U.UU 6.5 ts.U U.UU U.UU/2.tsU 5tiUUU 92U 'kIH Uts/U1/UZ 16396 1Z.1S 5U U 24 12131141 ;S.5 9.U 1 ZZ.U 3.U 75.0 U.ZU ti.U ts.5 0.1U .U5/Z.6U 56UUU 9UU 'Urllllng UIS/U:UU2 1655U 12.7 51 Z4 ZZ 9/35/37 4.U 9.ti 1 2U.5 3.5 7ti.0 U.25 5.5 8.4 U.UU .U4/Z.6U 5t1UUU ISISU 'LJu tsHAA5 Uts/U3/UZ 1ti55U 12.7 51 19 19 6/Z11/33 4.U 9.2 1 ZU.5 ;S.U 76.5 U.UU 5.5 IS.U U.UU U.UU/UZ.ISU ~UUUU 8tsU \;M 1 (" Liner . 1 2IZ8/UZ 1655U 8.4 64 1U 24 11/13/14 5.Z 1 7.U 2.U 91.U U.UU U.I 9.U U.3U U.15/U./U 16UUU 92U ..../U tsHA 121Z9/UZ 1ti55U 8.3 43 1U 24 1U/12113 4.2 9.U 1 6.9 2.5 9U.6 U.1U U.I ts.U U.1U U.UU/U.7U 11SUUU 91SU rurlll ~noe 1 rk 1213U/UZ 1tits51 8.3 43 1U 23 1U/13/15 4.U 9.U 1 1.1 Z.I 9U.2 U.1U U.5 9.1 U.3U U.15/U.65 11SUUU 9tiU 'Unll to I.U. 12131/UZ 1titsti5 9.3 44 1U 23 1U/1:U13 4.U 9.U 1 7.U 3.0 9U.0 U.UU U.5 9.U U.2U U.1U/U.tiU 1tsUUU 9tiU 'kun KI- IS U1/U1/U2 16tsti5 8.3 44 9 2U 6/1U/1Z 3.6 9.U 1 I.U 3.0 9U.0 U.UU U.5 9.U U.25 U.1U/U./U 11SUIJU 9tsU 'kun 4 1/2" lIner Page 1 of 4 uProjections and Interpolations in Italicsu 3/27/2003-4:20 PM NS18 Final Surveys_12-31-02.xls I Final Survey I Client: BP Exploration Alaska Survey Computation Method: Minimum Curvature Field: Northstar DLS Computation Method: Lubinski Structure: Northstar PF Vertical Section Azimuth: 308.150· Well: NS18 Vertical Section Origin: N 0.000 ft, E 0.000 ft Borehole: NS18 TVD Reference: Borehole: KB UWIJAPI#: 50-029-23102-00 55.8 ft above MSL Date: October 18,2002 Magnetic Declination: 26.282· Grid Convergence: 1.23170237· Total Field Strength: 57542.264 nT Scale Factor: 0.99992902 Dip: 80.944· Declination Date: July 12, 2002 Location: N 70 29 28.369, W 148 41 35.896 Magnetic Declination Model: BGGM 2002 N 6030991.320 ftUS, E 659828.760 ftUS North Reference: True North Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Coordinate Reference To: Wellhead (True) Comment MD Incl Azim TVD VSec NS EW Closure CIAzim DLS I (ft) (~) (.) (ft) (ft) (ft) (ft) (ft) (.) (·/100tt) Tie-In 0.00 0.00 308.16 0.00 0.00 0.00 0.00 0.00 0.00 GYRO 50.00 0.31 38.86 50.00 -0.00 0.11 0.08 0.14 38.86 0.62 GYRO 100.00 0.33 342.08 100.00 0.12 0.35 0.13 0.37 19.84 0.61 I GYRO 150.00 0.37 344.64 150.00 0.37 0.64 0.04 0.64 3.43 0.09 GYRO 162.00 0.43 348.38 162.00 0.43 0.72 0.02 0.72 1.51 0.55 GYRO 281.00 0.99 296.50 280.99 1.78 1.62 -0.99 1.90 328.51 0.67 I GYRO 351.00 1.11 282.55 350.98 2.98 2.04 -2.19 2.99 312.85 0.40 GYRO 441.00 1.27 284.77 440.96 4.68 2.48 -4.01 4.71 301.73 0.18 GYRO 533.00 1.76 281.26 532.93 6.88 3.01 -6.38 7.06 295.29 0.54 GYRO 624.00 2.49 295.11 623.86 10.05 4.13 -9.54 10.40 293.39 0.98 ( GYRO 660.00 3.16 291.02 659.82 11.76 4.81 -11.18 12.17 293.30 1.94 GYRO 750.00 5.63 296.77 749.55 18.46 7.69 -17.43 19.06 293.81 2.78 GYRO 840.00 7.51 301.00 838.95 28.63 12.71 -26.42 29.32 295.69 2.16 GYRO 930.00 9.39 304.20 927.97 41.79 19.87 -37.53 42.47 297.89 2.15 I GYRO 1030.00 11.78 306.19 1026.26 60.13 30.48 -52.52 60.72 300.13 2.42 GYRO 1121.00 14.02 306.92 1114.96 80.44 42.59 -68.83 80.94 301.75 2.47 GYRO 1218.00 17.12 308.11 1208.39 1 06.4 7 58.46 -89.46 106.87 303.16 3.21 I GYRO 1280.00 18.42 307.73 1267.43 125.39 70.09 -104.39 125.74 303.88 2.11 MWD DMAG 1310.68 19.07 309.52 1296.48 135.25 76.25 -112.09 135.56 304.22 2.83 MWD DMAG 1408.82 21.53 312.58 1388.52 169.23 98.64 -137.72 169.40 305.61 2.73 I MWD DMAG 1501.89 21 .44 313.01 1475.13 203.21 121.79 -162.74 203.27 306.81 0.19 MWD DMAG 1596.67 22.10 313.43 1563.15 238.22 145.87 -188.35 238.23 307.76 0.72 MWD DMAG 1691.84 23.74 312.27 1650.80 275.16 171.06 -215.53 275.16 308.44 1.79 MWD DMAG 1785.67 25.30 311.90 1736.17 314.01 197.16 -244.43 314.04 308.89 1.67 MWD DMAG 1880.95 25.80 313.39 1822.13 354.97 225.00 -274.65 355.05 309.32 0.85 I MWD DMAG 1975.10 28.72 310.93 1905.82 397.98 253.90 -306.64 398.11 309.62 3.32 MWD DMAG 2068.71 30.78 309.26 1987.09 444.40 283.80 -342.18 444.56 309.67 2.37 MWD DMAG 2164.39 34.43 312.22 2067.68 495.88 317.48 -381 .19 496.08 309.79 4.16 I MWD DMAG 2260.36 36.14 313.36 2146.02 551 . 13 355.14 -421.86 551.44 310.09 1.91 MWD DMAG 2355.46 40.72 310.89 2220.50 610.08 394.73 -465.72 610.50 310.28 5.08 MWD DMAG 2451.43 42.96 309.43 2292.00 674.05 435.99 -514.65 674.51 310.27 2.54 MWD DMAG 2546.90 44.60 307.95 2360.92 740.09 477:27 -566.21 740,53 310.13 2.03 MWD DMAG 2642.55 47.69 306.65 2427.19 809.05 519.05 -621.08 809.42 309.89 3.38 MWD DMAG 2738.43 51.03 306.94 2489.63 881.77 562.62 -679.33 882.06 309.63 3,49 MWD DMAG 2834.14 55.04 306.59 2547.17 958.21 608.38 -740.59 958.43 309.40 4.20 MWD DMAG 2927.54 55.90 307.26 2600.11 1035.13 654,61 -802.10 1035,31 309.22 1.09 rv1WD DMAG 3025.36 56.14 306.26 2654.78 1116.22 703.15 -867,08 1116.35 309,04 0.88 MWD DMAG 3120.67 56.80 306.57 2707.43 1195,64 750.31 -931.02 1195.73 308.87 0.74 MWD DMAG 3214.04 56.00 307.00 2759.10 1273.38 796,88 -993,30 1273.45 308.74 0.94 MWD DMAG 3309.10 56.61 307.00 2811.84 1352.46 844.48 -1056.47 1352.50 308.64 0.64 I MWD DMAG 1432.52 893.03 -1120,15 1432.56 3404,87 56.86 307.64 2864.37 308.56 0.62 MWD DMAG 3499.43 58.00 308.33 2915.27 1512.21 942.07 -1182.95 1512.24 308.53 1.35 MWD DMAG 3590,25 59.23 308.98 2962.57 1589.74 990.50 -1243,50 1589.77 308.54 1.49 MWD DMAG 3685.92 58.01 308.92 3012.38 1671.40 1 041 ,85 -1307.01 1671.44 308.56 1,28 MWD DMAG 3781,29 57.77 308.41 3063.08 1752.18 1092.32 -1370,09 1752.23 308.56 0.52 I MWD DMAG 3876.15 55.29 308.63 3115.39 1831.30 1141.59 -1431.99 1 831 .35 308.56 2.62 MWD DMAG 3975.52 54.12 308.24 3172.80 1912.41 1192.01 -1495.52 1912.45 308.56 1.22 MWD DMAG 4191.86 53.45 305.27 3300.64 2086.86 1296.45 -1635.32 2086.88 308.41 1.15 MWD DMAG 4287,67 53.34 306.42 3357.78 2163.70 1341.48 -1697.67 2163.71 308.32 0.97 MWD DMAG 4382.39 53.81 305.11 3414.03 2239.84 1386.02 -1759.51 2239.85 308.23 1.22 ( MWD DMAG 4477.03 53.93 305.49 3469.83 2316.19 1430.19 -1821.89 2316.19 308.13 0,36 MWD DMAG 4571.59 54.12 303.99 3525.37 2392.58 1473.80 -1884.78 2392.59 308.02 1.30 MWD DMAG 4667.63 54.30 304.83 3581.54 2470.32 1517.82 -1949.05 2470.34 307.91 0.73 ( MWD DMAG 4761,62 53.95 303.90 3636.63 2546.30 1560.81 -2011.91 2546.35 307.80 0.88 MWD DMAG 4856.65 54.31 305.15 3692.31 2623.15 1604.45 -2075.35 2623.23 307.71 1.13 MWD DMAG 4951.25 54.69 306.46 3747.25 2700.09 1649.50 -2137.81 2700.20 307.65 1.20 MWD DMAG 5046.76 55.23 307.19 3802.09 2778.27 1696.37 -2200.41 2778.39 307.63 0.85 I MWD DMAG 5142.43 55.56 307.82 3856.42 2857.01 1744.31 -2262.88 2857.14 307.63 0.64 MWD DMAG 5237.81 56.11 308.11 3909.98 2935.93 1792.86 -2325.10 2936.06 307.64 0.63 MWD DMAG 5333.96 56.48 307.86 3963.33 3015.92 1842.10 -2388.14 3016.05 307.64 0.44 I MWD DMAG 5429.05 56.89 308.37 4015.56 3095.39 1891.15 -2450.66 3095.51 307.66 0.61 MWD DMAG 5524.61 57.60 309.01 4067.26 3175.75 1941.38 -2513.39 3175.86 307.68 0.94 MWD DMAG 5620.82 58.07 309.31 4118.47 3257.18 1992.81 -2576.54 3257.28 307.72 0.56 MWD DMAG 5716.52 58.46 309.68 4168.81 3338.55 2044.57 -2639.35 3338.63 307.76 0.52 I MWD DMAG 5812.50 58.59 309.86 4218.93 3420.37 2096.94 -2702.27 3420.44 307.81 0.21 MWD DMAG 5906.45 58.55 309.30 4267.92 3500.52 2148.02 -2764.05 3500.57 307.85 0.51 MWD DMAG 6001.37 58.48 309.10 4317.49 3581.45 2199.18 -2826.78 3581.49 307.88 0.19 MWD DMAG 6096.84 58.31 309.68 4367.52 3662.74 2250.77 -2889.62 3662.77 307.92 0.55 ( MWD DMAG 6191.43 58.09 309.60 4417.37 3743.10 2302.06 -2951.53 3743.13 307.95 0.24 MWD DMAG 6287.48 57.99 310.00 4468.21 3824.56 2354.22 -3014.14 3824.58 307.99 0.37 MWD DMAG 6382.41 57.78 310.82 4518.68 3904.90 2406.34 -3075.36 3904.91 308.04 0.76 I MWD DMAG 6477.00 58.05 311.01 4568.92 3984.95 2458.83 -3135.92 3984.95 308.10 0.33 MWD DMAG 6573.11 58.09 310.95 4619.75 4066.42 2512.32 -3197.50 4066.42 308.16 0.07 MWD DMAG 6667.77 57.85 310.77 4669.96 4146.58 2564.82 -3258.19 4146.58 308.21 0.30 MWD DMAG 6761.25 57.65 310.29 4719.84 4225.57 2616.20 -3318.28 4225.58 308.25 0.48 I MWD DMAG 6858.23 57.31 311.05 4771.98 4307.26 2669.49 -3380.30 4307.28 308.30 0.75 MWD DMAG 6953.34 57.27 310.68 4823.37 4387.20 2721.85 -3440.82 4387.23 308.35 0.33 MWD DMAG 7048.34 57.34 310.67 4874.69 4467.07 2773.96 -3501.46 4467.11 308.39 0.07 MWD DMAG 7142.04 57.44 309.93 4925.18 4545.95 2825.01 -3561.66 4545.99 308.42 0.67 MWD DMAG 7237.08 57.61 309.90 4976.21 4626.09 2876.46 -3623.15 4626.15 308.45 0.18 MWD DMAG 7332.53 57.83 309.98 5027.19 4706.75 2928.26 -3685.02 4706.82 308.47 0.24 MWD DMAG 7428.76 57.93 308.53 5078.36 4788.23 2979.83 -3748.13 4788.31 308.49 1.28 MWD DMAG 7523.75 58.20 306.79 5128.61 4868.83 3029.08 -3811.95 4868.91 308.4 7 1.58 MWD DMAG 7619.07 58.33 305.21 5178.75 4949.84 3076.73 -3877.53 4949.90 308.43 1.42 MWD DMAG 7714.10 58.57 304.62 5228.47 5030.69 3123.08 -3943.93 5030.73 308.37 0.59 I MWD DMAG 7810.36 58.21 302.62 5278.93 5112.41 3168.47 -4012.19 5112.42 308.30 1.81 MWD DMAG 7906.00 58.17 302.96 5329.34 5193.33 3212.48 -4080.52 5193.33 308.21 0.30 MWD DMAG 7998.39 57.94 303.32 5378.22 5271 .42 3255.34 -4146.16 5271.42 308.14 0.41 MWD DMAG 8095.73 57.85 303.53 5429.96 5353.60 3300.76 -4214.98 5353.60 308.06 0.20 MWD DMAG 8190.23 57.62 303.76 5480.40 5433.26 3345.03 -4281.50 5433.28 308.00 0,32 MWD DMAG 8286.77 57.80 304.13 5531.98 5514.65 3390.60 -4349.20 5514.69 307.94 0.37 MWD DMAG 8381.33 57.59 304.79 5582.51 5594.40 3435.83 -4415.10 5594.46 307.89 0.63 MWD DMAG 8478.95 57.15 305.33 5635.15 5676.49 3483.05 -4482.40 5676.58 307,85 0.65 MWD DMAG 8576.15 56.81 306.29 5688.12 5757.92 3530.73 -4548.49 5758.03 307.82 0,90 MWD DMAG 8666.77 56.38 305.95 5738.01 5833.53 3575.33 -4609.60 5833.64 307.80 0.57 MWD DMAG 8763.65 56.19 308.20 5791.79 5914.09 3623.90 -4673.89 5914.21 307,79 1.94 MWD DMAG 8858.57 56.19 308.94 5844.61 5992.95 3673.07 -4735.55 5993.07 307,80 0.ô5 MWD DMAG 8953.74 56.12 309.34 5897.61 6071.98 3722.97 -4796.86 6072.09 307.82 0,36 NS18 Final Surveys_12-31-02.xls Page 2 of 4 "Projections and Interpolations in ItalicsU 3/27/2003-4:20 PM I I MWD DMAG 9049.24 56.39 310,13 5950.66 6151.36 3773.73 -4857,92 6151.46 307.84 0.74 MWD DMAG 9144.86 56.22 309.26 6003.71 6230.89 3824.54 -4919.14 6230.97 307,86 0.78 I MWD DMAG 9240.02 56.08 309.18 6056.72 6309.91 3874.51 -4980.36 6309.98 307.88 0.16 MWD DMAG 9335.64 55.74 309.17 6110.31 6389.08 3924.54 -5041,75 6389.15 307.90 0.36 MWD DMAG 9431.05 55.39 309.14 6164.26 6467.76 3974.22 -5102.77 6467.82 307.91 0,37 MWD DMAG 9526.50 55.12 309.10 6218.66 6546.18 4023.71 -5163,62 6546.24 307.93 0,28 I MWD DMAG 9620.55 54.87 309.37 6272.61 6623.20 4072.43 -5223.29 6623.25 307.94 0.35 MWD DMAG 9715.38 54.60 308.88 6327.36 6700.62 4121.29 -5283.35 6700.66 307.96 0.51 MWD DMAG 9810.97 54.53 309.09 6382.78 6778.50 4170.29 -5343.89 6778.53 307.97 0.19 MWD DMAG 9905.17 54.49 309.28 6437.47 6855.18 4218.75 -5403.34 6855.22 307.98 0.17 I MWD DMAG 10000.59 54.25 309.16 6493.06 6932.73 4267.79 -5463.43 6932.76 308.00 0.27 MWD DMAG 10096.79 53.92 309.29 6549.49 7010.62 4317.06 -5523.79 7010.65 308.01 0.36 MWD DMAG 10191.53 53.78 309.47 6605.38 7087.11 4365.59 -5582.92 7087.13 308.02 0.21 I MWD DMAG 10286.70 54.07 309.11 6661.42 7164.01 4414.30 -5642.45 7164.03 308.04 0.43 MWD DMAG 10380.99 54.45 309.10 6716.49 7240.54 4462.58 -5701.84 7240.55 308.05 0.40 MWD DMAG 10476.35 54.83 309.34 6771.68 7318.29 4511.75 -5762.09 7318.30 308.06 0.45 MWD DMAG 10571.41 55.36 309.71 6826.07 7396.23 4561.36 -5822.22 7396.23 308.08 0.64 I MWD DMAG 10666.19 55.75 310.59 6879.68 7474.34 4611.76 -5881.96 7474.35 308.10 0.87 MWD DMAG 10760.77 56.13 310.71 6932.65 7552.62 4662.81 -5941.41 7552.62 308.12 0.42 MWD DMAG 10854.57 56.71 310.84 6984.53 7630.69 4713.84 -6000.59 7630.69 308.15 0.63 MWD DMAG 10947.38 56.97 310.59 7035.30 7708.30 4764.52 -6059.48 7708.30 308.18 0:36 I MWD DMAG 11042.46 57.32 310.97 7086.88 7788.09 4816.69 -6119.96 7788.09 308.20 0.50 MWD DMAG 11139.49 57.59 309.91 7139.08 7869.82 4869.75 -6182.21 7869.82 308.23 0.96 MWD DMAG 11234.43 57.86 310.12 7189.78 7950.05 4921.36 -6243.69 7950.06 308.25 0.34 MWD DMAG 11327.46 58.10 309.49 7239.10 8028.89 4971.85 -6304.28 8028.90 308.26 0.63 ~ ~~~g-:~---_.~- 11425.05 58.30 309.53 7290.53 8111.81 5024.62 -6368.27 8111.82 308.27 0.21 1+5H-;60----~-5a.5Q--3Q9_;_79-7~39002---81_90.6-1~ --50~4.93----~6428.._96-8_1.90-.63-----301L29...__ ___---G.32 MWD DMAG 11614.52 58.61 309.92 7389.59 8273.26 5127.92 -6492.43 8273.28 308.30 0.16 I MWD DMAG 11711.03 57.93 309.16 7440.34 8355.32 5180.18 -6555.73 8355.35 308.31 0.97 MWD DMAG 11803.31 57.33 308.53 7489.75 8433.25 5229.06 -6616.43 8433.29 308.32 0.87 MWD DMAG 11899.19 56.78 307.19 7541.89 8513.71 5278.45 -6679.96 8513.74 308.32 1.31 MWD DMAG 11994.42 56.20 306.27 7594.47 8593.09 5325.93 -6743.59 8593.11 308.30 1.01 I MWD DMAG 12089.41 55.61 305.45 7647.72 8671.68 5372.01 -6807.34 8671.70 308.28 0.95 MWD DMAG 12183.86 55.03 305.67 7701.46 8749.27 5417.18 -6870.53 8749.29 308.25 0.64 MWD DMAG 12278.16 54.24 304.93 7756.04 8826.08 5461.62 -6933.28 8826.08 308.23 1.05 I MWD DMAG 12374.44 53.72 305.01 7812.65 8903.83 5506.25 -6997.10 8903.83 308.20 0.54 MWD DMAG 12470.34 53.82 304.80 7869.33 8981.06 5550.52 -7060.54 8981.06 308.17 0.21 MWD DMAG 12566.37 53.80 305.01 7926.04 9058.44 5594.87 -7124.10 9058.44 308.14 0.18 MWD DMAG 12660.29 53.75 305.38 7981.54 9134.10 5638.54 -7186.01 9134.10 308.12 0.32 MWD DMAG 12754.37 53.99 307.03 8037.01 9210.04 5683.42 -7247.32 9210.04 308.10 1.44 MWD DMAG 12848.36 54.21 308.43 8092.13 9286.17 5730.01 -7307.53 9286.17 308.10 1.23 MWD DMAG 12941.73 54.17 308.66 8146.76 9361.89 5777.19 -7366.76 9361.89 308.10 0.20 MWD DMAG 13038.40 54.31 309.03 8203.25 9440.33 5826.39 -7427.85 9440.33 308.11 0.34 MWD DMAG 13135.16 54.64 309.13 8259.48 9519.07 5876.04 -7488.98 9519.07 308.12 0.35 MWD DMAG 13225.71 54.68 308.99 8311.85 9592.92 5922.58 -7546.34 9592.92 308.13 0.13 MWD DMAG 13324.37 54.13 309.58 8369.28 9673.13 5973.38 -7608.43 9673.13 308.14 0.74 I MWD DMAG 13419.60 53.23 309.14 8425.68 9749.84 6022.04 -7667.76 9749,84 308.15 1.02 MWD DMAG 13515.51 52.37 308.69 8483.67 9826.23 6070.03 -7727.20 9826.23 308.15 0.97 MWD DMAG 13610.21 51.78 308.95 8541.87 9900.92 6116.85 -7785.40 9900.92 308.16 0.66 MWD DMAG 13706.03 50.93 308.16 8601.71 9975.76 6163.50 -7843.92 9975.76 308.16 1.10 MWD DMAG 13800.84 50.27 308.44 8661.89 10049.02 6208.91 -7901.41 10049.02 308.16 0.73 MWD DMAG 13896.70 49.46 308.12 8723.68 10122.31 6254.31 -7958.94 10122.31 308.16 0.88 MWD DMAG 13992.58 48.60 308,00 8786,55 10194.70 6298.94 -8015.94 10194.70 308.16 0.90 I MWD DMAG 14087.22 47.82 309.00 8849.61 10265.26 6342.86 -8071.17 10265.26 308.16 1.14 MWD DMAG 14181.94 47.15 308.15 8913.62 10335.08 6386.40 -8125.75 10335.08 308.17 0.97 MWD DMAG 14277 .49 46.31 308.37 8979.12 10404,65 6429.48 -8180.37 10404.65 308.17 0.89 MWD DMAG 14373,53 44.90 308.28 9046.31 10473,27 6472.03 -8234.21 10473,27 308.17 1.47 ~'WD DMAG 14467,82 43.44 308.51 9113.94 10538.97 6512.83 -8285.70 10538.97 308.17 1.56 NS18 Final SUNeys_12-31-02.xls Page 3 of 4 UProjections and Interpolations in Italics'· 3/27/2003-4:20 PM Page 4 of 4 uProjections and Interpolations in Italics" 3/27/2003-4:20 PM NS18 Final Surveys_12-31-02.xls I I I I I MWD DMAG 14562.69 42.31 307.76 9183.46 10603.52 6552.70 -8336.47 10603.52 308.17 1.31 MWD DMAG 14626.58 41.83 307.49 9230.89 10646.32 6578.83 -8370.37 10646.32 308.17 0.80 MWD DMAG 14732.87 40.74 306.48 9310.76 10716.43 6621.02 -8426.39 10716.43 308.16 1.20 MWD DMAG 14828.91 39.20 307.49 9384.36 10778.11 6658.13 -8475.67 10778.11 308.15 1.74 MWD DMAG 14924.34 37.57 307.00 9459.16 10837.36 6694.00 -8522,84 10837.36 308.15 1.74 MWD DMAG 15019.68 36.26 308.01 9535.39 10894.62 6728.85 -8568.27 10894.62 308.14 1.51 I MWD DMAG 15114.53 34.76 308.44 9612.59 10949.71 6762.94 -8611,55 10949.71 308.14 1.60 MWD DMAG 15204.17 34.04 308.82 9686.56 11000.35 6794.55 -8651.11 11000.35 308.15 0,84 MWD DMAG 15299.96 34.52 308.16 9765.71 11054.30 6828.13 -8693.34 11054.30 308.15 0.63 MWD DMAG 15394.77 34.92 308.02 9843.63 11108.30 6861.44 -8735.84 11108.30 308.15 0.43 I MWD DMAG 15488.84 35.04 308.01 9920.71 11162.23 6894.66 -8778.33 11162.23 308.15 0.13 MWD DMAG 15585.09 35.03 307.35 9999.52 11217.48 6928.43 -8822.06 11217,48 308.14 0.39 MWD DMAG 15680.74 34.19 306.93 10078.24 11271.80 6961.23 -8865.37 11271.80 308.14 0.91 MWD DMAG 15774.89 33.66 307.01 10156.37 11324.34 6992.83 -8907.35 11324.34 308.13 0.56 I MWD DMAG 15870.90 32.78 307.30 10236.68 11376.93 7024.60 -8949.27 11376.93 308.13 0.93 MWD DMAG 15965.96 30.92 307.04 10317.4311427.08 7054.91 -8989.24 11427.08 308.13 1.96 MWD DMAG 16059.32 29.05 306.86 10398.29 11473.73 7082.96 -9026.53 11473.73 308.12 2.01 MWD DMAG 16155.28 27.61 306.49 10482.75 11519.25 7110.16 -9063.05 11519.25 308.11 1.51 I MWD DMAG 16249.90 25.67 305.46 10567.33 11561.64 7135.09 -9097.37 11561.64 308.11 2.11 MWD DMAG 16344.38 23.99 305.13 10653.07 11601.26 7158.01 -9129.75 11601.27 308.10 1.78 MWD DMAG 16439.46 23.43 305.81 10740.12 11639.45 7180.20 -9160.89 11639.46 308.09 0.66 I MWD DMAG 16488.39 22.70 306.38 10785.14 11658.61 7191.49 -9176.38 11658.62 308.09 1.56 MWD 16566.53 22.77 304.65 10857.21 11688.77 7209.03 -9200.95 11688.78 308.08 0.86 MWD 16663.54 22.01 305.21 10946.91 11725.66 7230.18 -9231.25 11725.68 308.07 0.81 I MWD 16757.11 20.59 306.29 11034.08 11759.62 7250.03 -9258.84 11759.64 308.06 1.57 MWD 16785.70 20.30 306.29 11060.87 11769.60 7255.94 -9266.89 11769.62 308.06 1.01 Projection to TD 16865.00 20.39 306.2911135.2311797.16 7272.26 -9289.11 11797.18 308.06 0.11 I - - -- ~ - -- - ~ ~ NS18 Prognosed Tops Actual Depths Formation TVDss I TVDrkb I MDrkb TVDss I TVDrkb I MDrkb Top Permafrost í.149 1206 l')no 1143 1200 1210 .L~..j j' Base Permafrost 1.519 1576 1598 1505 1562 1597 SV6 - top confming zone 3.002 3059 3777 2998 3055 3771 Surface casing point 3,150 3207 4046 3160 3217 4050 SV5 - base confining zone 3.250 3320 4227 3259 3316 4227 SV4 3.554 36] ¡ 4777 3561 3618 4777 SV2 - top upper injection zone 3~955 4012 5504 3956 4013 5504 SVl - top major shale barrier 4.425 4482 6355 4347 4404 6355 TMBK - top lower injection zone - Top Ugnu 4.697 4754 6848 4695 4752 6848 WS1- top Schrader Bluff - Base Ugnu 6.232 6289 9629 6267 6324 9711 CM3 - Base lower injection zone (top Colville) 6.813 6870 10682 6792 6849 10682 Fault "26" - throw = 75' 8.050 8107 12923 Unidentifiable THRZ - Top HRZ 8.599 8656 ]3866 Missing - likely eroded BHRZ - Base HRZ 8.695 8752 14013 Missing - likely eroded Top Kuparuk 8.795 8852 14163 8658 8715 13885 Kuparuk C 8.966 9023 14409 8862 8919 14191 Top Miluveach 9,230 9287 14769 9175 9232 14628 Intermediate casing point 9,275 9332 14829 9224 9281 14693 Intermediate logging point 9.275 9~"'\J ]4829 Exercised option not to run J-'~ Top Kingak 9.678 9735 ]5340 9698 9755 15290 Unmapped fault - throw = 30' Not observed 10623 10680 16378 Top Sag River 10,759 10816 16581 10738 10795 16503 Geol target #1 10759 10816 16580.9 10759 10816 16524 Intermediate casing point 10,790 10847 16615 10785 10842 16550 Top Shublik - 90 10,825 10882 16653 10839 10896 16610 Top Ivishak 10.915 109T2 ]6750 10932 10989 16710 Total Depth 11,080 11137 16930 11077 11134 16865 Oil- Water contact 11,100 11157 11100 11157 0 Top Kavik 11,255 11312 11255 11312 0 BP EXPLORATION ALASKA aocÁ ',~~~~ 441 END OF WELL REPORT REPORT FROM SPUD TO TOP SAG RIVER NORTHSTAR NS18 I I I I I I I I I I I I I I I I I I 5pe""~V-5un [J R I L-L I N G 5 E R V I c: E S I I I T ABLE OF CONTENTS I I 1. General Information I 2. Daily Summary 3. Daily Operations I 4. Show Reports I 5. Morning Reports 6. BHA's [ 7. Bit Record I 8. Mud Reports 9. Survey Record I 10. Formation Tops I 11. Formation Evaluation Logs I I I sperr'V-5Un I 1:1 RI L.L.I N e se R\J I c: e Sii I I I I I I I I I I I I I I I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date: North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: Vertical Section Azimuth: SDL Engineers: Company Representatives: Company Geologist: Lease Name: SSDS Unit Number: State: Borough: BP Exploration Alaska Nabors Alaska Drilling No. 33-E Northstar NS 18 Northstar North Slope Alaska United States 50-029-23091-00 AK-AM-22120 July 17, 2002 Aug 11, 2002 True 26.269 deg 80.944 deg 57542.807 nT Jun 03, 2002 North 70 deg 29 min 28.37 see East 148 deg 41 min 35.90 sec 308.16 deg Doug Wilson Mark Lindloff Reg Wilson Tom Mansfield Gavin Kidd Bob Clump Jeff Smith Joe Polya Mike Dinger Ken Lemley I Rick Matson Northstar 107 Alaska North Slope spe.....r...v- sun J:JRU_Lot N a !5eR\JIc:es I I' "I BP Exploration Daily Summary NS18 (7/15/02 Move rig nom NS16 to NS18 slot. Preparing to spud. Nipple up riser. 107/16/02 Build spud mud. Mud weight = 8.85 ppg. Nipple up riser and flowline, Pickup 16" drilling assembly and ,-qHA #1 (Bit # 1 HTC MX-Cl, TFA 1.031). Drill to 230' MD and run wireline gyro's. 22 units of gas was seen '. rom diesel contamination in this interval. Drill to 330' MD and trip out of the hole to change to BHA #2 ( Rerun Bit #1 ). Run in hole and drill ahead to 722' MD running Gyro directional surveys on wireline. Maximum ROP in this I 'nterval was 407 ft!hr at 701' MD. 07/17/02 Drill 16" hole from 722' to 2618' MD. Top of the permafrost was 1210' MD, 1200' TVD. Base of the I· T)ermafrost was 1597' MD, 1562' TVD. Maximum ROP in this interval was 655 ftIhr at 1770' MD. Maximum gas vas 35 units at 2268' MD. First trace of methane gas seen at 1195' MD. 117/18/02 Drill 16" hole from 2268' to 4050' MD, 3216' TVD Total De,pth for the 13 3/8" casing. Circulate sweeps md clean hole. Trip out of hole to run casing. Top of the SV6 marker was 3771' MD, 3055' TVD. Maximum ROP in this interval was 839 ft/hr at 2893' MD. Maximum gas for this drilling interval was 13 units at 3445' MD. Bit #1 1 md Rerun Bit #1 combined statistics= 3849 feet, 20.1 hours and 123.1 K revolutions. 07/19/02 Run 13 3/8" casing to 4033' MD. Circulated casing volume with maximum bottoms up gas of 13 units. I-'wop cement spacer and cement per well plan. 07/20/02 Clean pits. Nipple down riser and nipple up BOP's. Test BOP's. Laydown heavyweight drill pipe and ('iCkUP new drilling assembly BHA #3 (12 Y4" Bit #2, RSX238HF+GS, TFA= .9410). A Porcupine Reamer was un at 2262' up in the drill pipe to effect cleaning ofther SV sands. Build new mud volume 9.0 ppg and prepare to trip in hole. 117/21/02 Trip in hole and pressure test casing to 3500 psi for 30 minutes with 8.7 ppg mud. Displace hole to new 9.0 ppg mud while drilling shoe track. Drill 20' of new formation to 4070' MD and perform Formation Integrity Test I ~ 12.5 ppg EMW. Drill 12 Y4" hole from 4070' to 6504' MD, without problems. Top of the SV5 marker at 4214' jID, 3313' TVD. Top of the SV4 marker at 4730' MD, 3617' TVD. Top of the SV2 marker at 5424' MD, 4012' TVD. Top of the SVl marker at 6164' MD, 4402' TVD. A moderate amount of large casing metal shavings was 1 een at 4200' MD, which decreased to negligible by 5800' MD. Maximum ROP in this interval was 608' ft/hr at ,·858' MD. Maximum gas was 148 units at 6189' MD. 117/22/02 Drill 12 Y4" hole from 6504' to 8756' MD. Top of the Ugnu formation was 6852' MD, 4768' TVD. J.Æaximum ROP was 550 ft/hr at 7888' MD. Maximum gas was 1087' units at 6934' MD from a coal stringer. 117/23/02 Drill 12 Y4" hole from 8756' to 10609' MD. Top of the Schrader Bluff formation at 9711' MD, 6324' ~'VD. Top of the Colville formation at 10713' MD, 6905' TVD. Maximum ROP in this interval was 471' ft/hr at 8883' MD. Maximum gas was 285 units at 10281' MD. Mud weight increased to 9.2 ppg. lu7/24/02 Drill 12 Yo" hole from 10609' to 12724' MD. Top of Colville fonnation at 10713' MD, 6905' TVD. Maximum gas 381 units at 11869' MD. Maximum ROP 252 ft/hr at 12441' MD. IV7/25/02 Drill 12 Yo" hole from 12724' to 14423' MD. Mud weight at 10.5 ppg. No HRZ was encountered, although there was up to 10% HRZ fragments in the drill cuttings. Consultation with the Geophysicist in Anchorage ( Rick I tfatson) produced the conclusion that based upon seismic data there was a possible turbidite that eroded off the basal section of the Colville and all of the HRZ. A small section of Kalubik formation was encountered 55 feet MD thick, (TOP 13830' MD, 8679' TVD) and correlated nom small sandstone and tuffaceous sandstone stringers in the BP Exploration rn Daily Summary NS18 I,"¡orthstar NS 15 well. Top of the Kuparuk formation was 13 885' MD, 8715' TVD . Top of the Kuparuk "c" sand was 14191' MD, 8919' TVD. Top pfthe Kuparuk "B" shale interval / LCU was 14255' MD, 8963' TVD. Top of the r ~uparuk "A" sand package was 14330' MD, 9015' TVD. Correlation of interval thickness of the 3 different Kuparuk zones (C, B, and A) was similar with the Northstar NS15 well. Maximum ROP in this interval was 268 ftIhr at 112725' MD. Maximum gas in this interval was 1953 units at 14215' MD. u7/26/02 Drilled from 14423' to the 12 1;4" Total Depth of 14693' MD, 9280' TVD. Circulate hole clean. Minimal I.~mount of cuttings / cavings after bottoms up. Trip out of hole. Top of the Miluveach formation 14620' MD, 9225' I 'YD. Maximum ROP was 113 ft/hr at 14454' MD. Maximum gas was 957 units at 14451' MD. Bit #2 statistics= 10643 feet, 89.5 hours and 748K revolutions. Final mud weight was 10.5 ppg at T.D. 1'7/27/02 Laydown BHA #3 and rig up to run 95/8",47 #/ft casing. Ran casing to 3980' and circulated one casing volume. Continued to run casing at 12 joints/ hour and began to see mud losses at 6626' MD, top of the Schrader IqlUff formation. Lost 20 bbls from joint 160 to 170. No returns after joint 170 and losing 1 bbl per joint. Total losses rom joint 160 to 210 are 235 bbls. 1"7/28/02 Continued losing mud until casing was landed at 1045 AM. Total loss was 710 bbls. Attempted . irculation, packed off. Worked pipe and pumped up to 1200 psi, then bled off 200 psi at a time-no circulation. Established circulation at 1400 hrs by very slowly staging up pumps a few strokes at a time to hold standpipe pressure ,-t 1200 psi until a small flow was noted at the shakers. Staged up slowly to 9 bpm. Pump cement job-lost 53 bbls , vhile displacing cement. Average gas while circulating was 146 units. Maximum bottoms up trip gas 1173 units. 1"'7/29/02 Test BOP's. Pickup BHA #4, 8 ~"Bit #3 ( DSI64F+JNW, TFA=.610 ), rotary steerable drilling , ssembly and trip in hole. 1,7/30/02 Bleed in spike fluid to bring mud weight up to 12.9 ppg while drilling shoe track. Drill 20' of new 8 Y2" lole to 14713' MD- severe bit balling. Perform Formation Integrity Test to 14.5 ppg EMW. Drill from 14713 to 15172' MD in Miluveach formation. Rotary steerable assembly failed. Trip out of hole. Average ROP was 65 ft/hr. . - Ilaximum gas was 131 units at 14908' MD. 07/31/02 Trip in hole. Bad MWD signal. Investigation found pump #2 pulsation dampner bad. Pull out to shoe. 1 teplaced pulsation dampner. 08/01/02 Run in hole and wash to bottom. Drill ahead from 15172' MD to 16407' MD. Top of Kingak at 15276' 1 JD, 9745' TVD. 08/02/02 Drill Ahead from 16407' MD to 16550' MD. Top of Sag River formation at 16503' MD, 10795' TVD. 1 ~D hole in Sag River. Lost circulation before bottoms up sample. Pumped LCM pills. Pulled out to shoe and ..:hecked flow. Circulated at shoe to 10.5 bpm . no losses. Monitor well- no static losses. Dropped rabbit pulled out of hole. I J8/03/02 Rig up and run liner. Establish circulation. Pump cement as per plan. I )8/04/02 Pressure test as per plan. 08/05/02 Pull out of hole. I I BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) lme I :) Elapsed Time Operations Breakdown U15/02 i )0-17:30 0.50 11':30-19:00 1.50 1)'00-21 :00 2.00 1 l :00-00:00 I 7/16/02 1'000-02:00 00-05 :30 3.00 P JSM on skidding rig. Skid rig 20' to the north to NS-18. General R/U after skid. Notes: Berm around rig 2) Connect PUTZ 3) Let down stairwells. 4) Hook up injection line. NIU riser & mousehole. Note: Accepted rig on NS18 @ 21:00 on 7/15/2002. 2.00 3.50 Finish general R/U. P/UBHA# 1. Note: Change out stab. sleeves on motor & 1 stab. Fill riser wi sea water & check for leaks. Riser leaking at o-ring. Repair leak in O-Ring on scoping riser connection. Notes: 1) Pulled riser. 2) Changed O-Ring 3) Skidded rig for better alignment of riser. 4) Replace riser. Riser still leaking. 5) Unclamp Junk ring, install rope packing and silicone at leaking area. 6) Leak repaired Note: Investigating better ways to seal in future. Clean out conductor to 200' md. Spud Well -- Drill to 230' md. Held Pre-Spud Meeting & PJSM for R/U gyro Notes: 1) Discussed objectives of well. (No Accidents, No Spills or risk to the environment, no policy or law violations, & drilling a quality cost effective well. 2) Hazards associated wi hole section. 3) Drilling parameters of this particular section. 4) Reviewed D-7 drill. RJU gyro & conduct electronic test. Gyro survey - Base of conductor Inc!. .43 deg, Az. 348.45 deg Drill from 230' to 330' md. POH wi BHA # 1. M/U BHA # 2. Drill & run gyro from 330' to 732' md. r 30-05:45 0.25 45-11 :30 5.75 I r 1 30-12:00 0.50 ~:00-12:30 0.50 130-13:00 0.50 kOO-14:00 1.00 I 00-14:30 0.50 r.30-16:00 1.50 >:00-16:30 0.50 I 30-18?0 2.00 ,.30-00.00 5.50 117/02 8.25 J:00-08: 15 Drill & slide from 732' to 1382'. ( 15-09:30 1.25 i: .30-10:30 1.00 ):30-00:00 13.50 .. I I ì ,18/02 ):00-03: 15 3.25 ( 15-03 :30 0.25 ~ : 30-04: 15 0.75 Ls-os:oO 0.75 ) :00-07 :45 2.75 ( 45-08:15 0.50 ~:15-18:30 10.25 1 f30-20:30 2.00 1.00 J:30-21 :30 I 30-23:30 2.00 BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) Note: 1) Per stand - Sliding 25', rotating 20', sliding 25', & rotating remainder of stand. Pump sweep & run final gyro. PJSM - RID Schlumberger. Drill & slide from 1382' to 2620' pumping hi-vis sweeps as needed. 130-00:00 0.50 1 '/19/02 ['00-03:00 3.00 00-04: 15 1.25 flS-04:30 0.25 30-05:30 1.00 ):30-08:00 2.50 r 00-08:30 0.50 30-16:30 8.00 >:30-17:00 0.50 r 00-18:00 1.00 . 00-21.00 3.00 Drill & slide from 2620' to 2821'. Clean mud pump suction screens on both mud pumps. Noise interfering with signal from MWD. Drill & slide from 2821' to 2905'. Packing off while backreaming before a connection. Pump fresh water hi vis sweep & circulate hole clean. Drill & slide from 2905' to 3191 '. Saver sub backed out of top drive while making a connection. M/U to top drive & retorque. Drill & slide from 3191' to surface hole TD @ 4050'. Note: Pumped 75 bbl. fresh water mud sweep while drilling last stand down. Pump 75 bbl. weighted hi-vis nut plug I barafibre swep. Pumped 1 surface to surface & 1 additional BID. Hole cleaned up on 2nd B/U. Monitor well- POH wi 2 stands while checking for swabbing - okay. Pump dry job & blow down lines. POH to HWDP. Note: 1) TOR was good with minimum drag of 10 - 20K. 2) Dry wiped stand 21 & 23 once wi 45K drag. After going back down, pulled through with 20K drag. Tight spots"'" 130' apart which might indicate only 1 tight spot as different stabs. passed by. LID BRA # 2. Note: Tops of stabs, motor stab. sleeve & bit wi significant amounts of clay. LID BRA # 2. Clean rig floor & clear floor of stabs. & bit. Prepare for casing tool RiD. P 1SM - Cut & slip drilling line. Cut & slip drilling line. PJSM - LID bails, P/U Frank's fill up tool, & RIU casing tools. P JSM for running casing. Run 98 jts. of 13 3/8" 68 lb. L-80 Buttress Casing. P/U landingjt, hangar & land. LID Frank's tool & RIU cement head & x-over. Break circulation by staging pump up slowly from.5 BPM to 10 BPM. Final circulating pressure @ 10 BPM - 390 psi. Note: 1) Service top drive while circulating. 2) Held PJSM for cement job. PIU Porcupine reamer, dart sub & RIH. Break circulation & wash from 3877' to top of float equip't plugs. RJU & pressure test 13 3/8" casing to 3500 psi wi 9.2 ppg mud & hold for 30 mins. Note: 1) Discussed well control wi crew members. (D 1, D2, & D5 drills) 2) Discussed drilling hazards associated wi hole section. Drill float equip't plugs, shoe track, & rathole to 4050'. Displace wel to new 8.6 ppg mud. Drill from 4050' to 4070'. Circulate MW in to equal MW out. Perform FIT to 12.5 EMW wi 8.6 ppg mud. (650 psi) Establish ECD baseline (8.89 - 8.93) & drill from 4070' to 4710'. Drill 12.1/4" from 4710' to 5687'. Service top drive. Continue drilling 12.1/4" from 5687' to 6500'. 1) Pumping sweeps every 400 -500' or as needed. 2) ECD is staying close to .7 ppg above mud weight. 3) Inconsequential amounts of metal from porcupine reamer while inside casIng. 4) No Drag, No losses. Wiping bottom 30 ft. 3.00 1.00 0.50 0.50 4.00 5.50 0.25 6.25 'I I 7/22/02 I ( ·00-06:00 00-07:00 7:00-07:30 I' "30-08:00 00-12:00 ~:00-17:30 I· 30-17:45 45-00:00 ': .JO-O 1 :30 0.50 l :30-03 :00 1.50 ~ )0-03 :30 0.50 -, .30-04:00 0.50 ~:00-05:00 1.00 I )0-09:30 4.50 ,:30-11 :00 1.50 :00-15 :00 4.00 )0-16:15 1.25 '):15-18:00 1.75 tOO-19:00 1.00 )0-22:00 3.00 ~~:OO-OO:OO 2.00 ll/02 ):00-01:30 1.50 '30-02:00 0.50 DO-03 :00 1.00 Displace cement wI rig pump @ 10 BPM. Notes: 1) Bumped plug wi 566 bbls. of mud @ 95.6% pump efficiency. 2) Tested casing to 1950 psi & held for 3 min. (OK) Check floats (OK) & LID cement head. RID landingjt. - flush riser - LID casing tools & clean floor. NID surface riser. Remove rig mat from cellar. NIU Vetco multi bowl assy & test to 2500 psi. NIU BOP's. CIO bails, install iron roughneck floor track, RJU test equip't & fill stack. Test BOP's 250/4800 & hold for 5/5 min. Pull test plug & install bowl protector. RIH wI 8 stands of HWDP & POR LID singles via pipeshed. Clear floor & bring BRA to floor. MIU BRA #3 & shallow test MWD & rotary steerable assy. PIU 63 jts. of 5" DP from pipeshed & RIR. BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) 3) Pumped 70 bbl. bi-carb spacer before turning over to HOWCO pump. Pump 5 bbls. of sea water & test cement lines to 3000 psi. Check for leaks & retest. Pump 75 bbls. 10.2 weighted spacer - dropped bottom plug - pumped 517 bbls. 10.7 ppg lead cement followed by 96bbls. of 15.9 ppg tail cement. Dropped top plug & chased wi 25 bbls. sea water. I. JO-21 :30 0.50 I )0-00: 00 2.50 I 7/20/02 )0-01:00 1.00 110-12:00 12.00 f )0-14:00 2.00 ·,.JO-14:30 0.50 k30-00:00 9.50 I I !3/02 ".JO-16:30 16.50 I 130-17:30 1.00 rO-20:30 3.00 (30-21 :30 1.00 30-00:00 2.50 I ( '24/02 00-18:30 18.50 I I ~:30-19:00 0.50 r 00-23:00 4.00 I 00-23 :30 0.50 I 30-00:00 0.50 1.'25/02 ):00-18:00 18.00 t BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) Drill from 6500' to 8066'. 1) Sweeping hole every 500'. 2) Maintaining MW @ 9.0 ppg wi ECD's in 9.7 to 9.8 range. Drill from 8066' to 8159'. Service top drive, crown, & blocks. Drill 12.1/4 " hole from 8159' to 8756'. Note: Drilling some hard spots - notably from 8751' to 8757' - 3 hrs. to drill 6'. Reduced RPM to 105 while drilling hard streaks. No drag, No losses. Pretreating Sandstones with LCM. Drill ahead 12-1/4" hole with RSS from 8756' md to 10160' md in the Schrader Bluff and Ugnu.- ROP from 9-200 fph - WOB 10K-Ibs, 150 rpm, Torque on 15-16 K ft-Ibs. - 54.83 deg Inclination and 309.34 deg Azim. - Pumping high vis sweeps every 500'. Build and pump 70 bbls high visc BAROFIBREI Walnut sweep. No excess cuttings noted on sweep return. Drill ahead 12-1/4" hole from 10160' md to 10445' md. - ROP from 75- 137 fph. - 285 units gas @ 10281' (max gas) Service top drive. Drill ahead 12-1/4" hole from 10445' md to 10620' md into Colville (Field pick Top @ 10613' md!6849' tvd). - Slow drilling @ -10495' rod! 6781 tvd. ROP < 10 fph -- Hard streak. - ROP from 68- 137 fph. Drill ahead 12-1/4" Interm. hole from 10620' md to 12346' md wi RSS Assy. -ROP averaging 132.3 fph overall. -ECD stable and running from 9.8 to 10.1 wi MW in= 9.4 ppg. -Inclination 53.8 deg and azimth of305 deg. - WOB= 15-20K-Ibs, 900 gpm wi 3100 psig. - ROT wi 150 rpm and torque increasing to 22 K ft-Ibs. Service Top-drive. Drill ahead 12-1/4" hole from 12346' md to 12682' md. - ROP, ECD, and Torque good. - Running sea-water at 100+ bbl/hr and dumping mud to G & I to control mud wt and LGS. Mud Pump # 1 developed end gasket leak. Continue pumping wi Pump #2. Safeout Pump #1 and repair. Pump repaired come on line and drill ahead from 12682' md to 12726' rod. Drill ahead 12-1/4" hole from 12726' to 14191' rod. I )0-18:00 18.00 ~:00-19:00 1.00 I ~.JO-20:00 1.00 ):00-00:00 4.00 I I I 7/26/02 I 30-05:00 5.00 1'00-08:30 3.50 130-09:00 0.50 ):00-11 :30 2.50. LO-12:00 0.50 I 00-18:00 6.00 I ~:00-19:30 1.50 1 I ):30-22:00 2.50 I ~:OO-OO:OO 2.00 I I BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) - ROP from 120-162 fph. - WOB= 20K lbs - Pump rate 870-900 gpm wi 3250 psig. - 150 rpm wi Torque running 22-23 K ft-Ibs - MW 10.5 ppg wi ECD 10.9 HRZ interval did not show, eroded away. Found Kalubik @ 13830'/8679' tvd Drill into Kuparuk @ 13885' md! 8715' tvd Drilling ahead 12-1/4" hole in Kuparuk "C". - Top Kuparuk "C" @ 14191' md! 8919' tvd (Max gas 1935 units) Change out swab on #2 mud pump. Drill ahead 12-1/4" hole from 14237'md to 14439' md. - Top Kuparuk "B" @ 14255' md! 8963' tvd. - Top Kuparuk "A" @ 14330' md! 9015' tvd (Max gas 1257 units). Becoming power limited wi plant running 2 turbines wi power to spare. - Drawing 3000 amps. - Slow to 120 rpm wi 25K ft-Ibs torque. - Slow rig pumps to 880 gpm @ 3350 psig. - ROP averaging 45-75 fph wi total average ROP= 122.5 fph. Drill ahead 12-1/4" Int hole from 14439' md to TD @ 14693' md. - Final Total ROP average 120.1 fph. Circulate Low-vis sweep. Follow with weighted sweep. - Sweeps didn't carry much excess. - Rotate and recip. while circulating. Rack 3 stands back - Circulate a total of 32000 strokes (Hole clean). Monitor well. Good. POOH to 11780' md. (PU wt off-btm= 325 K lbsl SOW = 220 K lbs). -30 k 'Tugs" at top of Kuparuk. - Decide to keep POOH- hole slick. Monitor well. Pump dry job. Drop ESS @ 11780' md. POOH into 13-3/8" shoe 4030' md. - Slightly tight spots (30K lbs overpull) @ 10900', 7240', and 4930' md. - Pump out from 4850' md to 4030' md. Slight amount of swabbing through SV sands. Had to work BHA up into 13.3/8" shoe. Circulate 2 bottoms up. - Quite a bit of excess material on intial bottoms up (smaller to medium size clay clumps and a small amount of Miluveach shale came back on initial bottoms up). - Continued circulating until clean @ 9000 strokes. - Monitor and pump dry job. POOH. - Lay down Porcupine reamer. VI om on leading edge. Missing 1 st row of leading edge cutter buttons. Rest of reamer in good condition. Lay Down BHA #3. . - Recover ESS. Good surveys @ 11517.32', 11424.40', & 10947.36' rod. - Bit in good condition (Graded: 2-0-CT-C-X-I-WT-TD) BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) I !7/02 i .JO-01 :30 1.50 l :30-02:00 0.50 I )0-03 :00 1.00 ( )0-04: 00 1.00 ',.JO-06:00 2.00 >:00-07:00 1.00 ( )0-08:00 1.00 ~:00-09:30 1.50 130-15:00 5.50 ;:00-16:00 1.00 1 )0-19:45 3.75 ):45-22:30 2.75 I LID BRA #3. Clear and clean rig floor. PU STD and Johnny Wacker. Flush stack. Drain stack. Pull wear bushing. - Wear bushing was damage- no problem pulling. PJSM. Change out top set rams to 9-5/8" for running casing. P JSM. Slip and cut 102' drilling line. PJSM. Test ram door seals to 3000 psig. PJSM for RU for running casing. Review Franks tool, installing rails, Rigging up stabbing board, man-riding, and casing running procedures. Rig up to run 9-5/8" casing. MU Float Equipment. Check floats. Run 97 jts of 9-5/8" 47# casing to 3980' md averaging 20 jts/hr. Circulate casing volume @ shoe. Runjts 97-#165 start Onjt 160 (6627' 9-5/8" shoe depth) begin to get some seepage. Slow down rate from 22 jts/hr to 17 jts/hr. Run jts #165-180 @ 17 jts/hr. Still seeping. No static losses. However not getting any returns. Runjts #180-187 @ 12 jts/hr. Same losses. Runjts #187-194 @ 7 jts/hr. Losses are less. Runjts #194-203 @ 10 jts/hr. Stop check backside FL- static. Runjts #204-210 @ 5 jtsl hr. No change. Runjts #210-216 @ 10 jtsl hr. Start mixing more mud. Note: Total bbls lost from JT #160- 216 is 240 bbls. ~:30-00:00 1.50 I '! /18/02 ! aO-09:30 9.50 I 0.50 ):30-10:00 I 00-10:30 0.50 1'"30-14:00 3.50 I 00-18:00 4.00 I ~:00-23:00 5.00 f I I Run 9-5/8" 47# casing from JT# 216 - 355 wi losses averaging 4.2 bbls/Jt. Hole good. Had some problems getting though top of Kuparuk ( slack off 100 klbs)- Typical of previous wells. Hanger & Land 9-5/8" casing. Hole slick, land Hanger with 225 klbs downweight. RD Frank's Fill up tool. RU crossover and Cement Head. RU cement line. Try to Establish circulation - packed off. Attempt to reciprocate Pipe. Not able to move pipe up with 550 klbs and Hanger Catching in Ram Cavities. Surge pipe up to 1400 psi- no go. Make arrangements for Schlumberger to come out to shoot circ holes. With patience, able to establish circ @ 2 spm wi a finger of returns. - Slowly increased rate to 9 bpm on schedule to a final rate of 9 BPMI 900 psi. Circulate 1.3 bottoms up. No excessive cuttings at surface. PJSM for Cement Job. Pumped Cement Job As Per Plan: - Pump 5 bbls and PT lines to 4000 psig. - Pump 50 bbls 11.3 ppg Alpha Spacer. - Drop bottom plug. - Mix and pump 458 bbls (794 sacks) of 11.2 ppg lead cement. - Follow wi 116 bbls (564 sacks) of 15.9 ppg tail cement. - Drop top plug and flush wi 25 bbls of water. I I I BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) - Switch to rig pump #2 and begin displacement @ 9 bpm. Pump #2 not running smooth, switch to Pump # 1 and continue displacement. - Have 2 bpm losses before cement around shoe. - At 5190 strokes (515 bbls) have good lift, 9 bpm 305 psig and losses quit. - Slow to 5 bpm and 1500 psgi @ 9900 strokes (Slight losses- 3 bbls) - At 10263 strokes slow pump to 3.4 bpm wi 1700 psig. - Bump plug @ 10530 strokes, 94.3 % eff (1046 bbls HALCD meter) wi 3.4 bpm @ 2100 psig. - Pressure to 2600 psig and monitor for 3 mins. Straight line @ 2500 psig. - Estimated total bbls lost on cement job 53 bbls mud. - Estimated 5 bbls Alpha spacer returned just before bumping plug. Bleed off and check floats. Rig down Cement head & landing joint. LO-23:30 0,50 ~ :30-00:00 0.50 ".29/02 ):00-00:30 0.50 30-01:30 1.00 P JSM. Back Out and pull landing jt. Flush and drain BOPE stack. Install short bails and 5" DP elevators. Install 9-5/8" pack-off. Test to 5000 psig- good. PJSM's. Displace 9-5/8"xI3-3/8" annulus wi 240 bbls of 10.2 mud at 1 bpm (Started injecting at 1700 psig. Other simultaneous operations being performe concurrently: - Swap 9-5/8" rams to variables - Clean L-Pit - Change Liners and swabs on mud pumps to 5-1/2". PJSM for setting Test Plug and BOPE test. Set Test plug. Rig up testing equipment and fill BOPE stack. Pressure Test BOP's for 5min (250 psig/4800 psig). PT annular 3500 psig. Pull test plug and install wear ring. MU BHA #4 (RSS, MWD, and 8.5" bit). Shallow test- good. PU 30 Jts of DP from pipeshed. RU to freeze protect 9-5/8" x 13-3/8" annulus. PJSM. Pump 1500 strokes of diesel @ 1.3 bpm. Pumped a total of 127 diesel FP. Continue RIH wi BRA #4. Replace 1 Jt ofDP - Scored. 30-03:00 1.50 ;,:00-07:30 4.50 I I ,7·30-08:00 0.50 00-08:30 0.50 ~:30-14:30 6.00 I 30-15:00 0.50 ;:00-17:30 2.50 f30-18:30 1.00 30-19:00 0.50 ):00-00:00 5.00 rO/O2 00-03 :30 3.50 ~:30-04:30 1.00 I 30-05 :30 1.00 i 30-07:00 1.50 7:00-08:30 1.50 I RIH wi BRA #4 wi 5" DP. Wash down last stand to 14580' md. Circulate MW in = MW out = 10.1 ppg. Pressure test 9-5/8" casing to 4200 psig for 30 minutes on chart. 13 bbls pump/return. Review D5 Drill. Perform D-5 Drill. Drill out Float Collar and cement to 14662' md. í 'I ~ . 2.50 L30-11.00 l :00-14:30 3.50 r 30-15:00 0.50 ~. JO-23 :30 8.50 I I I I Lo-oo:oO 0.50 I 31/02 )~OO-O 1 :00 1.00 ::00-01:30 0.50 '30-02:00 0.50 ~0-07:30 5.50 ~:30-08:00 0.50 ~'OO-09:00 1.00 I 00-11: 00 2.00 l :00-12:00 1.00 rOO-12:30 0.50 30-18:30 6.00 ~:30-20:00 1.50 rOO-21 :00 1.00 (00-22:00 1.00 ~:00-22:30 0.50 f 30-00:00 1.50 r ·01/02 ):00-09:30 9.50 30-10:00 0.50 00-00:00 4.00 BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) Start bleed in for MW increase simultaneously. Condition Mud system to MW= 12.9 ppg. Drill Out shoe and 20' of new hole to 14713' md . Perfonn FIT to 850 psig wi 3.1 bbls. EMW= 14.6 ppg. Drlg ahead 8.5" hole from 14713' to 15172' md wi 8.5" RSS. -Bit balling occured when started drilling ahead. -Assembly dropping @ 1.7 degl 100'. - Send command to build 40% of the time wi no response. Command RSS to build 100% of the time wi no response. - At present inclination will miss Drillers target by 100'. Confer with Anchorage Engineering and decide to POOH for new RSS assembly or possibly a motor, depending on RSS functioning at surface. Drilling Parameters: - Rap average 64 fph (78-95 fph range). - WOB 15 K - Pump Pressure 3550 wi 550 gpm flow. - Inclination 34.75 deg I Azimuth 308.89 deg @ 15114' md. - Torque 24 K ft-lbs wi 150 rpm. - ECD running 14.0 ppg to 14.4 ppg EMW. CBU wi reciprocating and rotating 100 rpm. Continue CBU. Returns cleaning up - lots of excess for the footage drilled. Pump total of 10000 strokes. Monitor well. Trip out of hole to 9-5/8" shoe.- PUW 295 K Ibs I SOW 225 K Ibs. Monitor well. Pump dry job. Blow down Top Drive. POH N POOH to BRA #4. Stand back Jars and Drill collars. PJSM. Inspect Bit & Test Power Drive. Find PD Bias unit failure. PU BHA #5 (Same string wi different MWD and PD unit). Test Power Drive Unit. Download CDR. PU BHA #5. RIH wi BHA#5 on 5" DP to 14600' md. PJSM. Slip and cut 102' drilling line. Service Top Drive and drawworks. RIH wi BHA #5 into open hole. Wash down last stand. Hole in good condition.- PUW is 310 K, SOW is 210 K, and ROW is 236 K Ibs. - Rotary torque 12 K ft-lbs. Much improvement from yesterday. Not getting good MWD signal frames. On further investigation Pump #2 pulsation dampner has lost integrity- prepare to change out. POH to 9-5/8" shoe. Replace Pump #2 pulsation dampner.- Continue circulating wi pump #1 for mud conditioning. Continue circulation @ shoe -- Replace #2 MP Dampner. RIH wi BHA #5. Wash from 15076' md to 15172'. Drill ahead 8.5" from 15283'-16407' md into Kingak. TOP Kingak field pick 15276' md/ 9745 tvd.- Pump nut-plug sweep and unball bit. .~ I I ( I I ~/02/02 I '...JO-02:00 2.00 I I I 30-03:00 1.00 rOO-07:00 4.00 I I I 00-10:00 3.00 BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) - Vary WOB for optimum ROP to get a handle on ECD. - Highest ECD spike to 14.9 ppg. Mud Engineer adding water lower MW to target 12.8ppg. -Varied ROP from 100 to 170 fph wi increase in WOB to 25K lbs max. ROP= 100 fph I ECD= 14.34 ppg ROP= 120 fph I ECD= 14.34 ppg ROP= 150 fph I ECD= 14.40 ppg ROP= 170 fphl ECD= 14.40 ppg wi spike to 14.7 ppg. Attempt to keep ROP < 150 fph for ECD hardline. Drilling parameters: Total Flow= 552 gpm wi Pump P= 3450 psig. WOB= 17K lbsl 150 rpm wi 23K ft-Ibs torque. r 00-10:30 0.50 ):30-11 :00 0.50 ' 00-14:00 3.00 kOO-14:30 0.50 r 30-16:00 1.50 00-17:00 1.00 7 :00-21 :00 4.00 I Drill ahead 8.5" hole wi RSS from 16407' md to 16550' md into Top Sag. Top Sag River @ 16503' md I 10795' TVD. - ROP running 140 fph to 45 fph, still targeting 14.4 ppg ECD wi 12.8 MW Drilling parameters @ TD in Sag River: - 540 gpm wi 3400 psig - 25 K ft-Ibs Torque @ 150 rpm (Higher torque) and 21 K-Ibs Torq off. - 15-20 K lbs WOB wi ROP 50 fph - PUW= 315, SOW= 220, ROW= 252 K lbs. - Final Inclination 22.7 degrees. Circulate Hi Vis Sweep. (Lost Circulation @ 7600 strokes - ECD no higher than 14.0 ppg). Continue circulation @ 3 bpm while filling and monitoring (4 bpm losses) stringing in barafibre while getting LCM pill ready to go. No returns with static losses at 75 bph while mixing LCM pill. Mix and pump 85 and pump 80 bbls LCM pill containing at 4 bpm. 25 ppb BARA-Seal M 25 ppb Walnut - M 25 ppb BARO fiber. Note: Anadrill recommed 50 ppb LCM material max through TS. While chasing pill, got partial returns @ 950 strokes. Spot pill and clear bit by 200 strokes over for safety margin. Finished circulation with 75% returns (75 bph losses). Shut down and monitor, well FL is static. Total Mud loss to well: 640 bbls. Monitor well. Trip from 16550' md to 15076' md slowly to prevent swabbing. -PUW= 325 K, SOW= 230 K Ibs.' - Max drag was 50k wi average drag of 15K Ibs over. Hole in good condition. No losses on trip. Secure well and muster crew. OPS fire alarm. Wood fire put out. Resume rig operations. Continue trip to 9-5/8" shoe. No losses. Establish circulation @ 9-5/8" shoe. Recover LCM material in annulus. Work circulation rate up to 10.5 bpm. No losses. Monitor well- no static losses. Drop 2.5" rabbit. Pump slug. POH fl running 7" casing. Operations lost hi-line power. Switch to rig power Continue trip out of hole. ~i 10-23 :00 2.00 ~. .10-00.00 1.00 ~/03/02 - : .JO-Ol :00 1.00 l :00-05:00 4.00 LO-05:00 4.00 ;:00-06:30 1.50 r ,.30-17:00 10.50 7:00-18:00 1.00 T i.JO-20:30 2.50 ,'r:30-21 :30 1.00 : :30-22:00 0.50 ~:00-22:30 0.50 1"0-00:00 1.50 I I r04/02 ):00-01 :00 1.00 I I l :00-03:00 2.00 r 00-04:45 1.75 k45-06:00 1.25 I 00-09:45 3.75 I BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) Flush BHA#5 wi water. Lay down BHA#5. 8.5" bit graded: 3-0-CT-C-X-I-BF-TD Clear and clean rig floor. RU to run 7" 26 ppfCS-Hydrilliner. Continue RU for running 7" 26# L-80 Hydril-521 liner. PJSM for running liner. MU Float equipment and Bakerlock connections. Fill and check floats- good. Run 51JTs 7" 26# L-80 Hysril-521 liner. MU torque average of 12 K ft-Ibs. MU Baker 'ZXP' liner top packer and Flex Lock II hanger assembly. Circulate liner volume. PUW= 117 K Ibs & SOW= 115 K Ibs. RIH wi 7" liner on 5" DP to 9-5/8" shoe filling DP every row. Circulate pipe and liner volume. PUW @ shoe= 280K Ibs I SOW 207K ROW 240K @ 15 rpm wi IlK ft-Ibs torque Run into 8.5" open hole. - At 15895' have a little drag starting 15-20K. - At 16348' Tight spot 80 K Ibs. Still running in good however. - At 16492' md taking wt. No displacement. Decide to wash down. Establish circulation and wash down from 16492' md to 16545' md (5' off bottom).- Work rate up slowly to 35 spm @ 757 psig. Make up cement head. Establish circulation wi cement head..-Work rate up to 5 bpm @ 730 psig. PUW= 270KJ SOW= 215 K-Ibs.- Returns full during entire circulation P JSM for cement job. Pump cement job as per plan: - Pump 5 bbls of 13 ppg Alpha Spacer - Pressure test lines to 4500 psig. - Pump 30 bbls more Spacer 4 bpm- some trouble with electrical. - Pump 86 bbls (325 sacks) of 15.9 ppg tail slurry @ 5 bpm - Drop wiper plug and chase wi 5 bbls sea water - Switch to rig pump for mud displacement @ 5 bpm after catching cement. Slack off 100 K on hanger. Increase Pressure up to 4500 psig. Bleed off - check floats- good. Pick up to check wt loss (94000 lbs) @ 226 K. PU 7' to release packer setting dogs. Slack offDP wt to 120 K-Ibs and see liner top packer shear @ 140 K-lbs. PU to 7' mark and repeat. PU to 7' and rotate wi 70k lbs down on pkr (10 rpm wi 9-11k ft-lbs torque). Pressure up to 500 psig and pull 17' to release pressure and CBU @ 115 spm to circ out excess cmt. Circulate out Alpha space and approximately 30 bbls cement (50% cut on 60 bbls) Lay down cement head and 2-singles of 5" DP. G & I injecting to make room for Sea water displacement. RU and test liner top to 1500 psig for 30 min. G & I still injecting to make room for displacement. P JSM for Sea Water Displacement. - Pump 25 bbls high vis spacer '.11)5/02 ,:00-00:45 0.75 '·45-02: 15 1.50 J:45-02: 15 1.50 , ·15-02:45 0.50 t5-03:15 0.50 ~:15-08:00 4.75 ~ ·00-09:00 1.00 ):00-10:30 1.50 f 30-14:00 3.50 00-15:00 1.00 ;:00-17:00 2.00 r 00-17:30 0.50 30-21 :30 4.00 l :30-23 :30 2.00 r 30-00:00 0.50 I' I I I I Lay down Baker Running Tool. Manifest and stage for barge to WestDock. Test casing to 4800 psig wi Halliburton pump and chart for 15 mins. Good Test. 18.5 bbls ofSW to PU. Blow down mud lines Break and LD the cement head. G & I Flushing well for Caliper log in a.m. Cleaning pits. Clear and clean floor. Prep floor for PU HWDP. PU 24 Jts HWDP and 114 JTs of 5" DP. Morning barge is blocking access for more DP and SWS needing to respot for NS 1 0 Caliper log. Iron roughneck repair. PU singles of 5" DP for total of212 jts. Service top drive, drawworks, and crown. POOH and rack back rental pipe to 3000' md. P JSM for Diesel FP. Reverse circulate 125 bbls of diesel from Tank Farm. Strap SW returns to G & 1. U-tube diesel. Replace swivel packing on Top Drive. POOH wi DP. BP Exploration - Northstar NS18 Daily Operations (I.A.D.C.) - Pump 100 bbls sea water - Pump 50 bbls high vis spacer - Pump 1230 bbls total @ 10 bpm Final NTU= 350. Monitor well for 30 mins. PJSM for Slip and Cut drilling line. Slip and cut drilling line. RU floor for laying down DP. Lay down 105 jts of 5" DP Service Top Drive and Drawworks. Lay down 202 jts of 5" DP. Total LD was 307 jts. POOH. Make service breaks on Baker HRD running tool. Tool clean. 0.50 1.25 0.50 4.00 0.50 5.50 1.50 0.50 ~A5-10:15 ):15-11:30 r ~ iO-12:00 ~:vO-16:00 ~;:OO-16:30 ;0-22:00 ~:ÙO-23 :30 ~:10-00:00 I sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS18 Location: NORTHST AR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: RICK MATSON 13800 to 13870 it 8660 to 8705 it Show Report No. 1 DatefTime: 7/26/02 Depth (MD) (TVD) Interpretation: The high gas corresponds to a 15 foot thick (13815-13830' MD, 8670-8679'1VD) Tuffaceous Sandstone at the base of the Colville fonnation IKalubik fonnation erosional surface that eroded off the HRZ. Steam still analysis indicates that this interval would produce gas. No sample fluorescence or cut fluorescence was observed. The sand contained carbonaceous material. Note: 2 steam still runs were perfonned on this sample. % I Depth 13821 it Gas x Units 1221 Mud Chlorides (ppm) = 18.5K ---Frõwiiñ¡-------süëiiõñ------!fi"õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 99.0 15.18 = 83.8 - -- C2 10.32 3.03 7.30 - -- C3 8.11 3.56 = 4.55 - - C4 5.62 3.37 = 2.26 - -- C5 3.08 2.16 = 0.93 --Prõaüëiiõ-ñ------=------=---------------------------------------------- Analysis fXtGas nail nwater nNon-ProduCible Hydrocarbons 2 % Depth 13821R2 it Gas x Units 1221 Mud Chlorides (ppm) = 18.5K --i!rõwirñ¡-------SüëÐõñ-----=-~hÕW'.::---------------------------------------------- ppm ppm ppm (Steam Still PPM's In 1000's) C1 72.4 15.18 = 57.2 - -- C2 7.74 3.03 = 4.71 - - C3 6.10 3.56 = 2.54 - -- C4 4.51 3.37 = 1.14 - -- C5 2.54 2.16 = 0.38 -15¡:'õaüëiîõ'ñ------------------------------------------------------------------------- Analysis pqGas nail nWater nNon-Producible Hydrocarbons 3 % Depth ft Gas x Units Mud Chlorides (ppm) = ---Fiõwiiñë------§üëtiõñ-----=-~-li"õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 --Prõaüëiiõ-ñ------=------=---------------------------------------------- Analysis nGas nail nWater nNon-producible Hydrocarbons 4 % Depth it Gas x Units Mud Chlorides (ppm) = --Fiõwirñ¡-------§üëiiõñ-----=-~hõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1,00 0.00 = 1.00 - - --proaüë'£¡õ-ñ------------------ Analysis Hydrocarbon Ratios C1/C2 11.5 C1/C3 18.4 C1IC4 37.1 C1/C5 90.5 Hydrocarbon Ratios I C1/C2 C1/C3 C1/C4 C1/C5 12.1 22.6 50.1 149.1 I Hydrocarbon Ratios C1/C2 1.0 C1/C3 1.0 C1/C4 1.0 C1/C5 1.0 Hydrocarbon Ratios C1IC2 1.0 C1/C3 1.0 C1IC4 1.0 C1/C5 1.0 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 __ _____ ______._.".._.____._ __ ___.____ .__._n_..____.____ --.-----.-.....-.-.- NPH 100.0 -- ]g:~~~:~~~~;~~~~~~.~.._::::::...,.:.-~.~~ Gas --- 10.0 __ ._ __. _. .._.._..._.__ _ .____ ._,._~._______._._ __ .._.__.m__._._......__.,,_.._.._._..'_ _ u _ ___u_.._.___._ ..._.._ ~~_.__u"_____.,,.·_.__.,,__._,·_·__·_· __._____.._______..___.. ,_______,_______._,_ 011 ..-,..-".."'..-..--..---....-. ---.--".. .---.--.-.. --_._.~._._-_.._....__._---_._'. NPH 1 .0 .. ---..----..--,.-....-,.-..,---",- .---..--...-.-...,---..-,..., .-,...-----..--.-.-,----,-- C1 C2 -- --.-..- ,,--,.._.....-- Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 -.-.-,..----,---.----,.--".,-.-".------ 1 000.0 ..._ _...._n. ____._,_ ____. .._, ___._..... _._,_._._.__,_, .__" _____..__ . , -,,_..~"'._.-..- --..-.--- _._..__.__._---~----- -- ~ _ __, _ ...,_. '.."_'''''''''''''.'~''''..'.'''_ '-"_'_.0-. ".~._,.,.,_".,.~,_.__.,"_.~",.._ .... ,.~_.. ...----..--.....,,-..,-.-.----- --...--,,--- ..-----..----,..---.-----....... .-.. -'-.-.-- -.-----.......--..-..--. . "... _._. ....__......~._-...---....._..,,_._--_.. -- _.,--_..._._...~....-,,-".__._.....__._.._._~..- ..-,.,.----.,,----'"-,..----..-. ."......-.-,....,.-. ,--.....-.-" ...._-,-" .-...-.----.-.--..,..-, -..-.....-.-.. ''''-'''---'-''-'.-'-'-'- NPH ---------- ---.----...-...-----.-- -.-..-.----------.--.. --- 100.0 ï--""':'=-____ ~----_:- -----_.-~_.._._._~.-.__.- ,-- --.....,.~~_.::.._.._._._- ..--.....--..---- ....~_.._._-----_.-_.-.------ .'."--'''.._'---.-''. -......-.-...-.--- Gas -..-..----..- .,..-.._,,-,--.'_'.'-'-'"' .__...~---- .._~ ~ ~_._"._n.n ... ... -- :.. .:: - ;;.-;,;;,;: -- ------ 10.0 ---------.--..-------- .._---~--~---- Oil .....----..-.....--,..--..","...-,... "".-.."......,.."...,.. "'....,.,-.. ,. -"", . .._......_._.-~ -_..._---_."--~._,----- _. _.__. _,,,__,.._..___..._,,._.._._,___..._ .._.._____..__._____.,,_.__.__,_... _ . _.__ _.__~_._ ..___._d_..__ ____.__..__._..__.,_...__.n_.'__..._ . NPH 1.0. . . . sperry-sun DRilLING SERVICES Show Report Well Name: NORTHSTAR NS18 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: RICK MATSON Depth (MD) (ND) 14191 to 14255 ft 8919 to 8963 ft Show Report No. 2A DatelTime: 7/26/02 Interpretation: Steam still analysis indicates the Kuparuk "C" would produce gas. Drilling Mud contained 2.5 % lubricants. No oil odorlsheen visually present in steam still samples. Sandstone in samples ( 14150-14250' MD) had no fluorescence, but a dull yellow/green very slow dry sample cut fluorescence was noted that corresponded to drilling mud lubricants. Steam still for 14195' MD rerun for repeatability of results. KUPARUK "C" I 1 % r L Depth 14195 ft Gas x Units 1418 Mud Chlorides (ppm) = 19K ---FiõWirñë-------Š-üéiiõn------š-hõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 134.1 1.40 = 132.7 - - C2 12.09 0.47 = 11.62 - -- C3 6.42 0.92 = 5.50 - - C4 3.90 1.40 2.50 - -- C5 2.47 1.33 = 1.14 - -- --Prõaüctiõñ------------------------------------------------------------------------- Analysis fX1Gas 'l0il nwater JlNon-producible Hydrocarbons 2 % Depth 14195R2 ft Gas x Units # 1418 Mud Chlorides (ppm) = 19K ---Fiõwliñë-------§üëÜõñ-----=-ŠhõW'..:::---------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 125.6 1.40 = 124.2 - -- C2 11.75 0.47 = 11.28 - -- C3 6~07 0.92 = 5.15 - -- C4 3.92 1.40 = 2.52 - -- C5 2.44 1.33 = 1.11 --Prõaüctiõ-ñ-------==------=---------------------------------------------- Analysis fX1Gas nOil nWater nNon-Producible Hydrocarbons 3 % Depth 14220 ft Gas x Units 1477 Mud Chlorides (ppm) = 19K ---FiõWifñë-------Süéiiõn-----Tti"õW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 101.3 1.40 = 99.9 - -- C2 9.90 0.47 = 9.43 - -- C3 5.11 0.92 = 4.19 - -- C4 3.20 1.40 = 1.80 - -- C5 2.07 1.33 = 0.74 -proaüctiõñ-------==------=---------------------------------------------- Analysis fX1Gas nOil nwater nNon-Producible Hydrocarbons 4 % Depth 14250 ft Gas x Units 1671 Mud Chlorides (ppm) 19K --FiõWirñë-------Süéflõn-----~ñõW'----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 154.2 1.40 = 152.8 - -- C2 15.48 0.47 = 15.01 - -- C3 8.35 0.92 = 7.43 - -- C4 4.75 1.40 = 3.35 - -- C5 2.56 1.33 1.23 -Prõaüctiõñ-------==----- Analysis x Gas Oil I Hydrocarbon Ratios ClIC2 11.4 ClIC3 24.1 ClIC4 53.1 ClIC5 116.2 Hydrocarbon Ratios C1/C2 11.0 ClIC3 24.1 C1/C4 49.3 C1/C5 111.9 I Hydrocarbon Ratios C1/C2 10.6 C1/C3 23.8 C1/C4 55.5 ClIC5 135.0 Hydrocarbon Ratios C1/C2 10.2 ClIC3 20.6 ClIC4 45.6 ClIC5 124.7 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 -- .----.--- --.-----..---...-".-- 1 000.0 ---"...._._~ -~_.- --..- --~ ,- ~-----~-_._~--~.._-_..-._- -~-- ----""--._------ --- -..-.-.----- -.--...-.-.--.---'-' ~.-..--~- ------...-.-,,-.-.---......- NPH ,,- ..-. ..--."--"--~_.' -- ..---. .-. -..__..__.~ ..".... -..-.-..-. ,,-_.._._._.__._.-_.,,~._~..._---_._- 100.0 ,~?::'~ ~~~~::=:~~::~~~.mn._._n_ _, Gas _____..". _.__'h.__~. ,_ _...--- 10.0 _._ ._..... ~_., _ ,_....____..__.._ .__.._ _".~..___..__.,~,,",m__u . .".~_._.._, ._.. ._..,.~..... _____..__'.h____._,,~~____ __,__._,~_. ~ ~.- ._..~- .-----..'''-,,-----..--...----- -_._._..__..._.~--".._-_.._--_..._.,. .-.--..- . ------..,-....-..-..-.---- -_._---~- Oil _..u' . _'"_'__""''''U__''~_".....__ _.-_-._-__-......__-,_.._.-._...._--._- _ __ .. >..__,_,..n NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 . ".~,_.._.---_..,_....._.__... ~-.-.__._... - -.- --.- --,,_....._.__.,--~_.~.~-_._-,_.-.._._---~- 1000.0 -. ,,- --',-'''--''''--''--''--''- -. ._-""."._._,--_.._--~,-- ..- ...._--~-_.__._-~, .---.. .--".-.....-,----.-----..-.- .---.- .._--,_.~...__...~,,-_. ...._.~._._. _ ~ _ __,,__.~..__ _.._.._._ . h_"__·.·_.···.._..~~"..~.h_...'_"'.· .__._.._.____._..__....,_....~...._,__ -'.-.,...-- ."._-~_._'"._..---- . .._. .._.'"....~._._..h'_".._..... ",._..,...__.___. ___,_,___,_"..._._._~___...__ ._......__._._ NPH --_....._-,,--,-.-._-~,---~- ._------_._---_...._.~--- _.._--,-_.,,"--..._._~,-_.._-_._- 100.0 --- ::;.......- .~.."..~.. ... ~:~~~:::~--=- -~.:::::--=-~=:~~=~=,=:=._.=--- _..~_..~:~:~~ Gas -- ..._~... ~ .. 10.0 "_ ~..._._.____.._ _.____~.._____.m___ _. ..____.._____. ...__... .__,_ _._._. _ - .-,.- ._...--_._.,.--.~. ......,. . Oil ,----.--,.. .. ~...__._..,_..._--_.,_.. _ __,,,,,,.~_,,.,"_m_...._. u. n._.._._~.____._._._.._____. ___._. ._,--" -"..-...--...... -.-- .-...-.- - -- ,-- ._"..-. .--. _..- NPH 1.0 ~ sperry-sun DRilLING SERVICES Show Report Well Name: NORTHST AR NS 18 Location: NORTHSTAR AREA Operator: BP EXPLORATION ALASKA Report Prepared By: DOUG WILSON Report Delivered To: RICK MATSON 14330 to 14465 ft 9015 to 9111 ft Show Report No. ~ DatelTime: 7/26/02 Depth (MD) (TVD) I Interpretation: Steam still analysis indicates the Kuparuk "A" would produce gas. Drilling Mud contained 2.5 % lubricants. No oil odorlsheen visually present in steam still samples. Sandstone in sample ( 14350-14400' MD) had a trace dull orange fluorescence with no cut fluorescence. Sandstone in sample 14400-14500' MD 10% moderately bright yellow fluorescence with a very very slow dull yellow green cut fluorescence. I % Depth 14300 ft Gas x Units 808 Mud Chlorides (ppm) = 19K ---Fiõwliñë-------Sucfiõñ------s-h'õÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 94.1 1.40 = 92.7 - -- C2 9.29 0.47 = 8.82 - -- C3 4.97 0.92 = 4.05 - - C4 3.27 1.40 = 1.87 - -- C5 2.16 1.33 = 0.83 --Prõaüciiõ-ñ------==------=---------------------------------------------- AnalySis [XJGas nOil nwater nNon-Producible Hydrocarbo~s 2 % 1 Hydrocarbon Ratios ClIC2 10.5 ClIC3 22.9 ClIC4 49.5 ClIC5 111 .4 I Depth 14350 ft Gas x Units # 935 Mud Chlorides (ppm) = 19K ---¡:iõwlrñë-------sucfiõñ-----=-Shõÿ¡.=---------------------------------------------- ppm ppm ppm (Steam Still PPM's In 1000's) C1 91.2 1.40 = 89.8 - -- C2 12.18 0.47 = 11.71 - -- C3 7.82 0.92 = 6.90 - -- C4 5.50 1.40 4.10 - -- C5 3.51 1.33 = 2.18 --prõaüCiiõ-ñ------==------=---------------------------------------------- Analysis [XJGas nOil nWater nNon-Producible Hydrocarbons 3 % Depth 14450 ft Gas x Units 1058 Mud Chlorides (ppm) = 19K ---Frõwliñ¡-------siJëfiõñ-----=-Shõÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's In 1000's) C1 134.8 1.40 = 133.4 - -- C2 14.06 0.47 = 13.59 - -- C3 8.21 0.92 = 7.29 - -- C4 5.17 1.40 = 3.77 - -- C5 3.34 1.33 = 2.01 -Prõaüë:iiõ-ñ------==------=---------------------------------------------- Analysis [XJGas nOil nwater nNon-producible Hydrocarbons 4 % Depth ft Gas x Units Mud Chlorides (ppm) ---Frõwlfñ¡-------Š-ucfiõñ-----=-Shõÿ¡----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 1.0 0.00 = 1.0 - -- C2 1.00 0.00 = 1.00 - -- C3 1.00 0.00 = 1.00 - -- C4 1.00 0.00 = 1.00 - -- C5 1.00 0.00 = 1.00 - - --PrõaüCi¡õ-ñ------------------ Analysis I Hydrocarbon Ratios C1/C2 7.7 C1/C3 13.0 C1/C4 21.9 C1/C5 41.3 I Hydrocarbon Ratios C1/C2 9.8 C1/C3 18.3 C1/C4 35.3 ClIC5 66.4 Hydrocarbon Ratios C1/C2 1.0 ClIC3 1.0 ClIC4 1.0 ClIC5 1.0 ---------------------------------------------- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 1000.0 --- --~_..---~---- - - ,..-." ~-,--,-----..._-_.._- ......_..0_.','-"--- ._...._... ,,,__ ___._' '.. ".--.- .-..-'.'~...- " -,.,-~-_.-_.__._.,---".-._..- .---.-- - ..-.-.-.,- ,----,_. .--- NPH ."_ _._ - ___.,,_..".,,_...___..,___."_____. __....,._..__._..._~_..______ ,_~ __., .,.._...___.._.,..__._O__m_____'. 100.0 --- -- =~:-:=-'=-=-:~~=-:~~',~~~~-'::; ~~'~==-;~::,:::~=='~ ::.~..'-':~-.-:~~~-=.~..,~~~'" - ._---=~:: ...."-~..~.. --..-.-. Gas ~~ 1 0.0 ~:::_~:;~ ~:_:~:_~:_ -.-.--.-..----.,-..- ,-,,--- -_....,--- ----.,.'"' ".._,---_..,_..--_.. ,-~,,---_., - ,. -"--.- ---" - ---,.-,._-,.,...__. .....---........-,...-...-..".--.--...-. ---_..__._~.._..----_....".__.- Oil .._..._..~---_..__..--_._"._---_._."._-" ,._-,. .-.--..-.--.-" NPH 1.0 - . -. ...-.---..."...--.----.-.--- C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ._.._.__.-._.-_.~ -.-.-. 1000.0 -.---- -'"~,-..,--_.__._~--_.._.. .-"..------.-"".- 'P- ~._....__ ---.-.---------.----- --....................-------,-.--...-...-"..-.- -..---.-.-..---.--..--.--.,.-..--..,. .-. - --....--..-....---.-,,-...,..----,-...- ...--. -~.,--,,_.__._~--~.-._---- .._.,.~-_...-....,._-_.."'_."'_..,.-._-,-- ----."---------,,.......,...-. .... .-. .... ."_.._._..._.__...~""_..._..,,_.~......h...'_......_,,....._._.._._..... ---......."....,.-.--.--.----.-. NPH _..._,....."~.._,_.___._, ..~ .,,__...._.._.. ....,.._....__..._""_.__~_~._._._·h"."_..___ ---.......-----.----..-".--- --....--.-,-----..----.- ----..--..------- --- ~::~~ . ....-.--........--.-.------.-.-.."'.......-"-,,-..- --_._----_._._"....._--~_.. .....--...-..-."...---..--...- .......- -....---.-...-,. Oil ._._,_....."_._.,._,,..,_._ _._.._._n___h_.. .__ "....._"......,,....._......__ _n. ._n._.__"_"·_·__'_ ~___.__._ __._._ __...___._____ ----,_.._._.___._____ .-...----...-----".- ...--.-" ---.- NPH 1.0 . spe....,....,v- sun Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 ----.....-,-...-..-.---..----.---- DRILLI NG SERVICES .--.-...--..-.-.....---.--..-......,.-...---....-......-..--,.-"-.,.-..--.-,----..-- Mudlogger's Morning Report Current 24 hr Avg ft/hr ( unit~ ( ( 24 hr Max ft/h r @ units @ deg F @ I R.O.P. Gas' Temp Out ft/hr units Deg F I Mud Wt In Mud Wt Out API filt Ibs/100ft2 ml HTHP Gel~ I --- Visc PV ppg ppg secs cP YI I Connection Gas and Mud Cut tt units tt units tt units Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 1 7/15/02 o o Rig Up Polya / Dinger , , Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi AV @ DC Mud Wt at Max Gas Ibs/100ft2 pH ppg Sd 0/0 Type: RPM: Bit Size: Hrs. On Bit: Jets: \ \ \ TFA: ------ Total Revs on Bit: Footage for Bit Run "" ~, " ~~ ,.,', I Trip Depth: tt Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth tt Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: tt ct:]m^~:,'ßm.,r_.. JIf. .1 ~ ~ m [~JJt,,:.I!!.'Í'Im.lKl -:I.if! III mJ I~ ,.[1Jr";'i:~m~l: rn !Iii ! ,I! I ]1ì1SUìfEi~.";:L·~ ~~~n:rU;:lT... . I Current Lithology: % % .;:;;£;:'CJl::-"::=~[",.11~1..". .!I~a:~jI~::.¡n1.1l::R.L:::J,::Jí.l. . I, tt ft ft units units units ppg ppg ppg I _.:;"J::l",r,~Jf,: - Drilling Breaks Depth Drill Rate during before before after to , to to to % 010 %LCM "MJJ:;1~~~~",,!I!'R,...~,,!.\\\.f.~1¡11I.,..."',,""'.....,.,:::~:::"':""~tJ.I ppg ppg ppg "[";I'[:=:~r-;t;. 1"111.11 tt units ppg tt units ppg ft units ppg 1m!: ¡¡Ii.! I I !. n ~r::1rr:t:: Gas during after % Lithology Sst Sltst Sh .:~. ~_~~W~~~~~~'~~F'~~'&;~~~.~~{;'f(~~~~~~,(.· oz. ::,~,:·~~~~'¥.,'t:;~,~~4~f.~!~~~!'!:r·~::¡};!··1:~~~\,;i/¡,¡,¡:;1I::i¡~'¡!ß.f~~~;;;:;-f¿!.;i:!'~W'}1~::~~k$1~15:m~~~j:;~mlj.\'f'¡;.'..¡;;,2fø_iE~~~i~'~;::.:~' 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: .,~ .:'.;,_'I.~..:?~";'''~. ~. ~'~:,>,,~,,:_: ;, ~ 1 Î " 10000 units = 100% Gas In Air~i '.~' : ~:" 1',.;. Moved rig over NS 18 at 21 :00 hrs. Currently rigging up and building spud mud. Logging Engineer: Tom Mansfield I Doug Wilson : ; "',~_. '~~; ¿~~L'~~~:';:~ r '~.f:.~~~ ~~~~ ~ =', .';:.': V "':~ ~ ,..' 1?~~'~~ · ~; <' :~',:~ ;~.~~;:~~:;;~~_~.~'":!.: ~ ","'~ ~ ~ ',,; :ë-" .. . ~ '" . ~ . .....' . . Pump and Flow Data Pump 1 75 spm DH flow gpm ",~\ Pump 2 74 spm Total flow 630 gpm<~. Pump 3 spm A V @ DP 45 fpm"; Pump Pres 930 psi AV @ DC 81 fpmt~! ~~~:: ~ut :::~ ~~~ ~~c 199:pse~~ 46 ~:;1f~~ft2 10.0Ge~1 17HT~P26 I ~Ibs~~~~t at ~':; Ga:.s Sd oPis9 % 1 "~:;~:@:;i~~:'·~+>~~:¥.1~~M#W~~~t~,IV%~M*,·:i(,;:~~~.:.·'i'\~~,\~'1i_.:· ',' \~h~:·;~~i,~~1~·S~~~ ,::;*~,~': ,":',' '~"'. .i~.:~.~,:': :,:f¢].~,;.'~Ú.'@&i~,:;"",:,,)~~,tÄ;\~~'~~jit-~,·~~4~+~j::;-;;;'~4)W{~ti~~:á:~é..~~::~>}<~{': ~~jV:~~~*.)i.#~~41.lá:~~~..~~~?j~~~,~'~.'~i~i8M~,·~}1~~j:~¡:,~~/~*ti;L/::,';~':: :::>~~#~9?:~~~;~~~~,tt.r~\~)'.:> ,;-::;. ~'~';':~:~«&~~#K::~'#~N+'~~>,;.; , , .~{;i\'i~ ',"i " " , ,)~¡ :,i¡ Bit No.: 1 Type: HTC MX-C1 Bit Size: 16 Jets: 20 \ 20 \ 20 \ 12 \ \ TFA: 1.0310 I ~~~~~~~:~~~:~~~:~:~~··i ~~ Trip Depth: 330 ft Trip Gas: 8 Mud Cut: ppg Trip CI: ppm fj. I. Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm I , Tight Spots: to to to Feet of Fill on Bottom: ft ~ ~.t:Bm~=lIl Lijm I L Ifd JI n ~m _._"La.IIL n ~ ~ ~ L _ n'~~:;\';n;::~~~~~W!I;..JU_J¡II,¡r,I~~~'": ~ Current Lithology: % % % % %LCM '~ f . .~~~rmlr m~L::l\.L,,,.,,..;,,~::n:_ _ -::~::U:U;:J,:UI.J.. lili ij I~l. (,111m ,~~HU~nlill!!!.__~)U[mm,j !lIllm1~ûn~.M~_. ~ I sper''''''V- sun ---..- --.--- Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 º,_~_~,~..'=,L~'m~__'_ 5 e R \¿,_~~..§_§ Mudlogger's Morning Report Current 179 8 65 24 hr Avg 190 ftJhr ( 8 unit~ ( ( 24 hr Max ftJhr @ units @ deg F @ R.O.P. Gas' Temp Out ftJhr 407 22 701 300 units Deg F Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 2 7/16/02 722 722 Drilling Polya / Dinger I I I I Connection Gas and Mud Cut ft units ft units ft units ft units ft units ft units ppg ppg ppg .......1,[']3_,1 nUrnlH mm I~m lr I I , ,\"..._t. Drilling Breaks Depth Drill Rate during before before after to to to to ," -" , ,~"" ",,:,,~,,~~~i%t.:~t?~f:'~~~~~_~~~:~i!,;q:¡:~A~~~'~_~~~-¡~~1i~IT~h oz. I .,.~~~.'_~j~~~;~~~~~~~)~'~~~~~~;~¥%~(G.~ . :~ 24 hr Recé Build spud mud. N/U riser and flowli.ne. P/U drilling assembly. Drill to 230' and wireline gyro. 22 units ,;'fJ gas from deisel contamination. Drill to 330' and POOH to change BHA. RIH. Drill ahead wi wireline gyros. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ~ .¡~~ :'. Logging Engineer: Tom Mansfield / Doug Wilson ..... . . .,\,. ".;'" .: ,; ~~.' ; ,),:.....:.,::'. '~'. .:'; , ~ .. - -, - . ._ ,.... .. L' - _,: '.:.:' ,", i ' ~. ~!!':-.' ;" . . ,~. .. I ì : ppg ft units _ ppg _ ppg ft units ppg _ppg ft units ppg ,n:~~::'-':;~,D~)'Nr'~;;,~; Gas during , ¡ ~ ri ~ " , after % Lithology Sst Sltst Sh : ~ f 10000 units = 100% Gas In Air .Î ... ... ., , ' * 10000 units = 100% Gas In Air " :@~ '., Logging Engineer: Tom Mansfield 1 Doug Wilson TOP OF PERMAFROST @ 1210' MD, 1200' TVD BASE OF PERMAFROST @ 1597' MD, 1562' TVD Drilled ahead. 24 hr Rec¡ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Ni ---- ''', .~. ,... ~. , '. ;~' ~,: : "'" i'" ,~ ~" ~'~\'~'~;i~ì?~I~~t' '~, I I~~,,': :1.~l~~·:~~~~~~Wit ~¡¿j~~.~ "'··~i~:~i?' ,";4. ~.'~"~ , .i~~~~~~.~..,. "~F.I:J.,,. ~;i~"".:~, '~'.'1 ,~.~j<~~Jj ~.~ ~ .\" ~ .;:--¡-,..>" .' ... .~~.. .'.. .', ".,~". 7*t~',. ,I ". . .~'¥f~,-< oz. ~ I; % Lithology Sst Sltst Sh Gas during before after after Drilling Breaks ft_units _ppg ft ..:.-- units _ ppg ft _ units _ ppg _Wf'''I,:h'''''^:lœ;~I;(^](:::-.--r" '''---;l;;;¡::- Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft un~s ppg ...ø··m_~~I,G¡J}I:W:::" %LCM % % ,~,,,,.,,~, '::t ' ;'~'¡;!1~i;~ ',,~~i':b~~~, to to to to ~~~ t I Drill Rate during before Depth I ppg ppg ppg units units units ft ft ft I _K''"~''.~)j!;]I[J-I·Iü··:::-' Current Lithology: ::::J:ti']jli(m~'W:,\f~-===n~ I % % ppm ppm ft ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: . Tight Spots: to to ~:;:::;"lI::œ.."JY.~~~¡¡lrx~>"",,,,,,w....,,~,,,,,_.,,,,,,.....I;~ïlfI!KØ ~ ' I ~...,.!'~,-" , , ;,;....'.~'¡'~~¡.;..~..¡;:,~~~"'~:r~~~~~,;~I!Ø r.~¡'~~4f'·¡:~ :r~~~~~~'¡'·\~~~:~;'~!:"; .1'.....,:~ ',,:,:·:';t~!~~d::i;<t~·;"·· ':,; .',". ", :;:,';:, ',;, 1.0310 2.618 Jets: 20 \ 20 \ 20 \ 12 \ \ TFA: ------ Total Revs on Bit: 47.6K Footage for Bit Run --- 9.6_ml HTHP _ MudWtatMaxGas _ppg Gel~ 23 1 29 1 31 Ibs/100ft2 pH 9.0 Sd 1.5 % 16 8.6 Bit Size: Hrs. On Bit: I HTC MX-C1 50 Type: 25-30 RPM: 9.20 ppg 9.20 ppg Mud Wt In Mud Wt Out Vise 72 secs API filt PV 18 cP YI 46 Ibs/100ft2 \....:.!~'~....:'~~ "'~'. 888 64 113 Pump and Flow Data 1 05 spm DH flow 105 spm Total flow spm AV @ DP ,~050 psi A V @ DC 1770 2268 24 hr Max ftIhr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres 3 7/17/02 2,618 1,896 Drilling Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 ',. . ¡ ~"::,,.,~~. . ,~"..... 655 35 24 hr Avg 304 ft/hr ( 15 unit~( ( Current 340 12 65 ftIhr units Deg F R.O.P. Gas* Temp Out '" " Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report -.~.._-_.._--_._.- sper"r"v-sun i5"A'TL:.. L-ï"ï,fG"-"'s EA v -.-ë::e-·s , . ~,¡ r spe.....,.....v- sun Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 q__~~,~~_~.!'I G.___~,_s I§=~~~~~~,§ Mudlogger's Morning Report I Current 24 hr Avg 187 ftJhr ( 7 unit~ ( ( 24 hr Max ftJhr @ units @ deg F @ 2893 3445 R.O.P. Gas- Temp Out ft/hr units Deg F 839 13 na na 95 I ~. ',' . ... .. , , . '., :' ~ 'I. '. ...- : ' f ., <,··r Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 4 7/18/02 4.050 1 ,432 POOH fl surf csg Kidd 1 Dinger ~ ~,Î ~11 Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 96 spm DH flow 96 spm Total flow spm A V @ DP 2100 psi AV @ DC 888 64 113 gpm gpm fpm fpm --- . , ... ... . . .', ,. ,... '. ' Visc 61 secs API tilt PV 14 cP VI 37 Ibs/100ft2 8.8 ml HTHP Mud Wt at Max Gas Gel~ 15 / 20 / 24 Ibs/100ft2 pH 8.5 Sd ppg 1 % Mud Wt In Mud Wt Out 9.10 ppg 9.10 ppg I ;'~, Bit No.: 1 Type: HTC MX-C1 Bit Size: 16 Jets: ~ \ ~ \ ~ \ ..23.... \ _ _ TFA: 1.0310 ';Î Wt On Bit: 40 RPM: 50 Hrs. On Bit: 20.1 Total Revs on Bit: 123.1 K Footage for Bit Run 4,050 ,V1~ ::~ - ,·~",~'~~~~¡QlM':'·'\U.~t:'U'j'~,,:,"~~~~~¡;¡.~·~:..t~.'~,¡i~:l~;,,:::;'ì' "·4¡";·':';"i·~i:W';;10¡~~'.,.~~«~:t:r,~~¡,.:·~>':·:;'lJl~~.~',,:.i'. ~;~'.' '. ~!~ Trip Depth: 4050 ft Trip Gas: na Mud Cut: ppg Trip CI: ppm ~~:y:~W~~:~ I Æ:' '.UA.¡\:''::~, 11~I.:l::"'h,,~I....~l~ TIR_~_.n1.:.U~Jf..~t~_~:~..,."Itm:::Ð:l:.nt"i,'~:." I ppg ppg ppg 1, Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg lli 1m I -"-:"'''t.,JYL ~ . [I I "x:..tt::=::::-::'] n." I ft units ft units ft units I , . . .l~ 111111 .. .It~ Î I Depth ~ to "=t ~ to I to to Drilling Breaks Drill Rate during after before before Gas during after ft ft ft units ppg units ppg units _ ppg % Lithology Sst Sltst Sh ;·.5\~~~Ji___~~'~_~~f~:~~j~~, l Hl' 24 hour accumulation of Steel Filings from Possum Belly Magnets: '~~j' Description of fillings: ~~~. ,,·':;"¡I.~~,Pi!:&1~~...9w.~2;~:!'Mi~!:rt+..tÏ'~~~;~~~.~;i!*7~f.~~~;¡'~~f:,è~~~¿~t';'¡~~~*t?~~~*M-,::,¡~~;';¿¡/ì'W.f;:G~::¡:I,;;):.,!:~.;~\1'i,:s~'¡;.¡:"~h1'~;;',::"c ~l:¡ 24 hr Reci Drilled ahead to 4050', TO for 133/8" CSG. Circulate sweeps and clean hole. POOH to run casing. i~,:' ~~\': SV6 @ 3771' MD, 3055' TVD Surf. CSG pt. @ 4050' MD, 3214' TVD ':~ ,: Logging Engineer: Tom Mansfield / Doug Wilson .. '.:~,.':~ :::-"'¡',\~~~,~:~~J:~~·(Y~':~'·:'~~:'_~~;i,"'···'~'_ :.:~.: . , . . . . " t' ..' oz. : . ! r~ i, . " 10000 units = 100% Gas In Air .' I -I lJ J ....-,. .,,~, ., 'f¡~ ·~f ~~ ~;I'.'·'·~·~··-.~··· ~~.'': ~ ) .' ?: ~,,> .," ,Y',". " 1 0000 units = 1 00% Gas In Air :~ ,.. . ~ . . . . \.... ~ . ...... Logging Engineer: Tom Mansfield 1 Doug Wilson Run 13 3/8" casing to 4033'. Circ. casing volume. Max gas 13 units. Pump cement spacer and 24 hr Rec¡ cement. . ':)~ìi :::r~k~~~#~jf:.!l~.I::;, :Í\:r\'~:~'~\(~::;'.r.4~~..i~i'M:'+':;: /¡t....~ :·:,~'~'I;.t.~."-~!!;":-:'~·r:::,]:!·".!,:L~' !~\B:'>I':'"':)~;~"'''·.:, '':: ;'(B.';~'I;~::::::&:~~{i';;:n .~,~~~': ~,: 'F~i_':·: ,;. :. to i~ to . . to ',_~ to _ _ _ ~":';:i,'fl'~~~~- - :~~. -~., ~ . . . . .~' 1>'1';~~.;::':_r:t.<.:l&¡~j~~.;¡~'·~li~r-:I";:~::-, ·r" :""':~;::--l'JL~¡:'" ;,;r:·":.¡~,.;r¡;:~:ii·¡:;'~:q": __;;6" .:¡I~..~j,;·....... ,;........~ ,J, .~ ~ .., ,,:1 . ,!...,." rdt·· tfl~h".,. ,..~~h~~:~1~:f¡'!=-;~';·'~"'~~!Jf ........mr~~~!...~ 'I'.. I....~. p..~.~:t;.r.,J~1 ,)i '~.. ...... -eo . y..'/. " ...:...., . ~ I ¡ I'" I I '.. ~ ,. c,' t . J. . ....." .. . ,~' 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. Description of fillings. % Lithology Sltst Sh ." ;~ I I I ,'~,~~ ",'1',' f~'i units units units Sst Gas during Depth Drill Rate during after before after before Drilling Breaks I ft ft ft Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ppg ppg ppg I units units units ft ft ft 1'1 11 I.. ..11 :~['~iI~_",.lJI.~ ml IIIJI',:~··:IlŒ,1E~:~,·:;~., __..X'-'La:lf&Iill11J III I ~:~,~ gpm ':~i ;v 400 gpm:~ fpm ,à~, fpm ;~ ,~{{ ~'¥. 'f~ Mud Wt In 9.00 ppg Visc 52 secs API filt 11.0 ml HTHP Mud Wt at Max Gas ppg 'I Mud Wt Out 9.00 ppg PV 12 cP YI~ Ibs/1 OOft2Gel~~ 1 13 1 15 Ibs/100ft2 pH ~ Sd 0.5 % I: , ",;: :.: - .c;,,~·:;,~.¡~<;:·;'~~f,I,JI~;~,;:(::.;i,!1'!=:i~:::r;:,¡:,¡::~:~~,,:. .~,'~'.;~,:':'-:$.~:~~~~~,¡.t;,¡:,¡';rl\.:\.:¡.':;;,;, '-'''''¡;!';,:< "~''''1;,lr+;.;.;':;d·h,,··~~;i'·::::!~";·:;,;'' ~'-" -;~;':,' '-'.' ..'... ....:,~,"'.~{,..,'~:,.;,"," :',::':::'.: ';ii Bit No.: 1 Type: HTC MX·C1 Bit Size: 16 Jets: ~ \ ~ \ ~ \ ~ \ _ \ _ TFA: 1.0310 I: Wt On Bit: 40 RPM: 50 Hrs. On Bit: 20.1 Total Revs on Bit: 123.1 K Footage for Bit Run 4.050 i~1 '. . ..t. ._.''¡'~"".-.¡..;,,, " "'''',~''...".,;,,'''_C, ";'-":.~~="¡'¡'''~''''''''' ·.',....";.¡t;L..""~<J.~~.~',~·. ,.::..1..;...;.'\..... :..- .. _ ¡.'. ;1.;.1,'11I:. .... .~,.,,~::"~:'. _. ,. .'" .... ... -', I Tri·p'~:::~·'·--·--:~~~··~~~:-~=·'"-1~-'~'·:;CU;:·~'~~:' ~r::I:"'''-'' ". '~pm ~, Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm... ~.l" 1U~~L:.w.u... 11I1-.1 ~II::¡_.... _~~:~. ~ I~ f"', "M""+ I :+....^I^...,,· % % % % %LCM . ".~".=".~L",,~: I I . . :'~,: ........... '. .. ~ ',,__.~.'.".: :,', ,'; -. "~~¡'~~:":~'.:·~~"i"" .~.v. ,......, ",~':~,~- .~ ';~~"'~~.:'·I~. ," ~ .~~. -". , .~;.~':.".. .':~:,:-,,~ :::.-:'!.:j,,:,,~,,:,~ ":," ~"." . ' ." ._-..... ., I .. Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 48 spm DH flow 47 spm Total flow spm A V @ DP 900 psi AV @ DC 5 7/19/02 4.050 o CMT 13318 CSG Kidd / Dinger Deg F 95 R.O.P. Gas' Temp Out 24 hr Max ft/hr @ units @ deg F @ 24 hr Avg ft/hr ( u n it~ ( ( Circ CSG units na 13 ft/hr na Current I Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 -.-.--.......-......-..--.......----..-....-..-.-..--.....-....--.-,. .........--.---.--- spe.....,...,v- sun DAIL.LI-NG'·-'--sE'A\TfEes ·.. , . I 10000 units = 100~:' Gas In Air ~1 Logging Engineer: Tom Mansfield / Doug Wilson .:: " ~ ~~:¡¡'~$N~f::t:H~~~tì':4~~~j;~s;¡$";f(~¡E¡#!&t::*.?tØ~¿A;~~~~'>~1_;0jI!\1mi~~1~!.\:ì.~~;~~j¡>::~{;~':?t~P..f~;~~~~:t~'~~~~.~~~~i:"¡~.~; ~r'i'. ,i;,,~~f: ":b(~ì~'i:'!f¡~'¡;~.· :, : ::':':,~: , 24 hr Reci Cement 133/8" CSG @ 4033'. Clean pits. Nipple down riser & nipple up BOPE. UD HWDP. P/U BHA. Build new mud volume. Prep. to run DP in hole. ~"~~~~~~~~~;~~Jl~t¥:*;\~~*~·\r:i~ ,,-,..~. to to I to ¡ to ',. ':!~:~our ~~cumulatio~ ~f'~teel Filin~s'fr~'~ possUm~~~IY 'Ma~n:ts~ :i~ Description of fillings: oz. I I Connection Gas and Mud Cut ft units ppg ft units -ppg ft units -ppg - ft units ppg ft units -ppg ft units -ppg - ft units ppg ft units -ppg ft units -ppg - - :;;~;:;;~~,,~ H , I!~ - I I I ~- W lUll . .., "',_....,- - ~.'·æ-:::-U""'·Á.l1~~~' Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh .":~::'J"·-'.:"~.~·:rI!$fì~.W~_I~'~it_ ~n,:;';~l"~' Current Lithology: % _ % ~:::;;:1d~Wf{ij.J! tIll. .lh,:::...~<:].."...""..1l:::.-:J:,~:JI~ %LCM 0/0 % . , ~. ~:';. ;.:.~:::.;.,.'~:j~jrS'~~.~i<i~;n;...\i4?~ f;"~~.l~:·;i~~·~";.~i';~h!;:\':j":/hi,zt'~¡'!Ii1'.ri~::~~""~_~*'~~<;':::,.: 'Yj:~ ,:" :j:;'k~ ::,;~!?:;:,·~:':'!:,Milii,f:~.~~~~·",: . ~-~;:'..': ".1. 'I Trip Depth: ft Trip Gas: ~I! Short Trip Depth ft Short Trip Gas: ~~' Tight Spots: to to I , , . ~''"'IJ.{Jt:mD'1''-''i---'~'.r---~r:¡¡¡i'''I!r'~'''II!1I'-'õ!'T-~ t . .'" ~. 0, ,J,_ ~,~,.I:,.~'~,_~'--~~Ui... .......,_.''''"t Mud Cut: _ ppg Trip CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: ~~~1~~f~:~~~~..~~,~ ~=, -1:'.DB"~f I ppm ppm ft I Jets: 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ------ Total Revs on Bit: Footage for Bit Run 12 1/4 RSX238HF+GS Bit Size: Hrs. On Bit: Type: RPM: 2 Bit No.: -i.' Wt On Bit: I ,. ' 9.2 ml HTHP _ Mud Wt at Max Gas _ppg Gel~~ / ~I ~ Ibs/1 00ft2 pH ~ Sd ~ % Vise 49 sees API filt PV 17 cP YI 23 Ibs/100ft2 ppg ppg 8.70 8.70 Mud Wt In Mud Wt Out ," .,.....~....'t',,~:.. ""0' ~'~"f.:t"'!:''':~''' .. . '.":",.,." :'...,..', .", '" -.,... .:: ~~. ~,' ."..., .,', 'L }""'~'<';'.~~ ...: . Pump and Flow Data spm DH flow spm Total flow spm AV @ DP psi A V @ DC Pump 1 Pump 2 Pump 3 Pump Pres Current 24 hr Avg 24 hr Max " R.O.P. na fVhr fVhr ( fVhr @ Gas' na units unit~ ( units @ Temp Out 95 Deg F ( deg F @ 6 7/20/02 4,050 o P/U BHA Kidd 1 Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report .-.-.-.---.----.------.--.--.-..-.-..--..__.__0._0_.- sper'r'V-5un ëi,=ff-CL"¡-"i\TG-u" 5 -e A v I c:::e-s 'I, I spe.....,rv-sun Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 ...-~.-..-...-.-.---_._---...-.-.---..'.....-.-_._._.-.-.------,,-.-..--.. º..~.LI:::::_!:::J....~..,§..,_.,.._§..,~..~_\¿..~..¡:;.._~..? Mudlogger's Morning Report I Current R.O,P. 175 ft/hr Gas" 55 units Temp Out 80 Deg F 24 hr Avg 227 ft/hr ( 92 unit~ ( ( 608 148 80 24 hr Max ft/hr @ units @ deg F @ I Mud Wt In Mud Wt Out 9.00 ppg 9.00 ppg Vise 59 sees API filt PV 14 cP YI 28 Ibs/100ft2 I I 4858' 6189 6504 6.6 ml Gel~ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 7 7/21/02 6,504 2,454 Drilling Kidd / Dinger Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 105 spm DH flow 105 spm Total flow spm AV @ DP ,,1850 psi AV @ DC 890 170 320 gpm gpm fpm --- HTHP Mud Wt at Max Gas ~ppg 8 / 12 / 14 Ibs/100ft2 pH 9.0 Sd 0.25 % Mud Cut: ppg Trip CI: Mud Cut: _ ppg Short Trip CI: to Feet of Fill on Bottom: ~:n¡ ~,:¡;T);ltl~~., . J [jj, Ir~~JI.11 ppm ppm ft 20 % SLTST o~ _. .~~1'm1J[::.ml1:::.::t::;n;;~.,';J,l"'U;;;~:::.· '-~':: %LCM before ft units ft units ft units , ~.___!f.,;wm'. ppg ppg ppg , II' ~,,;~.'~pf'- Connection Gas and Mud Cut ft units ft units ft units '....'[ - rnllwu _ -ppg -ppg -ppg ",..IT:-I];¡Cn~'r-::S;:'"J¡ . ft units ppg ft units ppg ft units ppg m¡ ::.iJ 1 ff , ,:r:.:J='-~ % Lithology Sst Sltst Sh Gas during after ;liBitNo.: 2 Type: RSX238HF+GS Bit Size: 121/4 Jets: 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ~I Wt On Bit: 10 - 15 RPM: 150 Hrs. On Bit: 10.8 Total R~n Bit: 86.9K - Footage for Bit Run 2,454 ;tt;:'¡''';';;?1.iti~~¥-:~~~'Ìiiltí:~~i.'¡\'ífM~t;~'i¡¡f~i~:?~~.$@~~,(~~~~~{6¿;::,*!,~~j'!\'~~J$i~'Pî!,<;'~~~I$~ÿ:¡¡:~I;r!Ù~'ï¥~~,t:ï<1íi'"~Ú¡'"B." ';T\" ;f~' Trip Depth: ft Trip Gas: 1=:.,n--:J.l~nE'~;:::~~Jl': J , Current Lithology: ~ % SST 60 % CL YST ~~"~,__"_,,._,~};:U'~":1i '!JI::u:~œ:::~::':::L.ltJL~~ I I Drilling Breaks Depth Drill Rate during after before ~¡~ ! r ~ I' :;, ¡ . .~, r,~: to to to to J,I~",,· ~~~.~ ~; ,,;:~~I], i'~~,t~';)!~t.f.( \ ~,:r:;.,~' . i '.1; ¿.~',\'~v~~:,,~......ì.t, 1 ,fJ1 ,·'....dV'J,..' ·l~~~' ~~;.~r~i' ';'" 'r"'''~'~I:'r' ii·:"~~io!.'IF,T.;!i\ir.lì~-AÍj":"-,, "',' ',"',' (¡~, .', '1,," " "'~L I~ ."r40-~ T"1r.J~,1 ¿,';~'I.4ìfH,~" ~:i";t"';·YC;1~""'I'" '" ~I~'~~'h~ I"", 1.,.··.'....I,~.r..~,..~"·;1o,f ~ " , I oz , '. 2J hour accumulation i)t Sreel Filings frûm Possum Belly Magnets' ~ppro:.< 2-3 /d', '~~, Description of fillings: moderate amount of large casing shavin9 decreased to negligible by 5800'. :~,.~~ h';"~:;;'i~ "':"~;'~3~~;'r~::~~~:~:¿~:~~ '~';:¡i~'~;~;'*;:~;~~i·;:;';;;~·:~~~:~:;~~:~ :~~g '~Ud', . Dis~,:~~:'t~~~t::~:~~::~'~'d '~vhil~ ~,~ n:: drilling shoe track. Drill 20' new hole to 4070' and perform FIT to 12.5 ppg EMW. Drill ahead with no problems. ~k\ ',i:, SV6 @ 3768' MD, 3055' TVO, SV5 @ 4214' MO, 3313' TVO, SV4 @ 4730' MD. 3617' TVO, ;,:1 SV2 @ 5424' MD, 4012' TVO, SV1 @ 6164' MO, 4402' TVD ;~~~ ;;:;~: ^:~1:~ j ~ 'I....iì~,.,'"...· 'f~ · 10000 units = 100% Gas In Air I :; Logging Engineer: Tom Mansfield / Doug Wilson .' ." ,'þ:" .¡":' , , "".,' -" ',', . '. ... r "0"" .. . ~ '.' .-.....:~- .~,.,-~.; .~.~...~...., ':...:.. -,.... -,'. ':. ',~ , :;"~~/'~'!:; .~....: ;I~ ~': ~~ .. ' . ... - . . . I. ~ d I ~, 1 ... ':: ~. . ~' '~~' ." :.: ~: : ..'.t. . ~~~ '1~' , I ì i' x~, 10000 units = 100% Gas In Air 'fJ. ,- ~'" ,.:..~:,~ ;:~~~\~'-"';'~~7 .;·':"~··~E~~_'~··,r:.: < I. Logging Engineer: Tom Mansfield / Doug Wilson before after Drill Rate during Drilled ahead. UGNU @ 6852' MD, 4768' TVD Connection Gas and Mud Cut ft units ppg ft units _ ppg ft _ units ppg ft units _ ppg ft _ units ppg ft units _ ppg 1111 _ _ ~ [mr.\~ll..1:r:-'::;{X;'(:,~:,~,V~;' Drilling Breaks "",-.1. 7888 6934 8756 24 hr Max ft/hr @ units @ deg F @ 550 1087 90 .. ~;. L . . .,', ....~~':,~:.~:. ~.'~' ",.;, " ,:·::;:~'~'¡H~r.:EM:'»~;:;':; ,~f~;;;·.r..::,,¡ ~rii"1<?\:·i+..~":i-'{.i.J,*:~~".'Ím,,!~;;;:r- .,: .~:::, ',"';" \!r."":~~ t,,:" , <: ,.~j":(':;!,~,,:,:,.~ :::. 24 hr ReCí .. ~ ,I': "':::.. . to to ____~!¡ to ---- ~ ---- ~:¡;1,"l' ,,, T, r ',,,..,.. ." ..' .': ~ ' ....' ï' .... . -- fi:~ '. t' ~. ~ 1£11'. Ft~~i~~;7'J~ "=;iI;n9~ from Possum Belly~agnets: ,..... , AP:~'~~"["'"'' "~ ,,,,," Description of fillings: moderate amount of large casing shaving decreased to negligible by 5800'. 1.: % Lithology Sst Sltst Sh Gas during after before Depth ppg ppg ppg - I units units units C.........., -1~fllU-~··- I II W-'JJJ·"¡¡¡'h"I~"--'iTiIl"nr;~--''''i)1I\t·jJit1:.u,,;¡ r iC;C;-'~·~..~~~~W~I~ ¡ IO~_ ~ ~ .,~R,~~,~~~ t:..~~iI':'~ . 't 8! ........:<>.'.~.,....,-~:A:~:!-~ ..... ......~~~l{~~.. .... ."".... 7f ..... . '..... .,,,.,.. ... .". ,...... ·.·..'1...,,, .".... ... ,,", . ........""...... .....'.. ,... " ...""..'., ,'... "", ..' ".."...' ,..:', i 1 . r I ....: . .:. ::;~,..~rþ:~;.t. :;::":f·~¡.' ;~,;.t':~...: "', .~ , ": ,; . : ~', 1,:,,-<' :'~ ,~,..:,,~':~:....i".i ~... ~,~.:'~::;;... o~_...'~.,:;I' ':" ~. :,' ' ,~ -..::' ".' ',',.:". ~, . '",;. . .: \'. ..".; .,__ ;...! ::. ,,~!:, ~.".. ":' '. '" ,-, . . ',. " '. . ~ ~ :1 Bit No.: 2 Type: RSX238HF+GS Bit Size: 121/4 Jets: ~ \ ~ \ ~ \ ~ \ ~ \ ~ TFA: 0.9410 ¡I ..of.: Wt On Bit: 10 - 15 RPM: 150 Hrs. On Bit: 29.2 Total Revs on Bit: 246K Footage for Bit Run 4.706 I'~ ;J.,~~,;¡..;:~.,;:.."r¡''''';¡;''''~'ij~=.~''¡'!b;j.Ïli;fj¡)..'t'\tl~»t~~H'~MiI':;~j¡"h.~;'~~~~.I:I!Ii",;,;'';~¡''·''x..,¡.;~t~:,!~!';'~ioj,~,,;'~:~'''''i,''':.i;,:\"i"}:::':':;,.,.;;,.- .,lõ.......",. .... ~...'... I Trip Depth: ft Trip Gas: Mud Cut: _ ppg Trip CI: ppm ; , ~ ~ I Visc ~ secs API filt ~ ml HTHP _ Mud Wt at Max Gas ~ ppg PV 14 cP VI 28 Ibs/1 00ft2 Gel~ 8 / ~ 1 ~ Ibs/1 00ft2 pH 9.0 Sd 0.25 % :. ;' .' ',' ',-, . .r·.·.. ..' gpm gpm· fpm fpm Pump and Flow Data 104 spm DH flow 106 spm Total flow spm A V @ DP 2300 psi AV @ DC ~ Pump 1 Pump 2 Pump 3 Pump Pres 888 169 315 8 7/22/02 8,756 2,252 Drilling Kidd / Dinger Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: . ~1:,;iff,~"~':~¡"~ ;.::,:' \' .~';', ;':'~:', x~~~~_~·~iJ;· 9.00 ppg 9.00 ppg Mud Wt In Mud Wt Out '", .....-..- I..". 24 hr Avg 1 22 ftJhr ( 140 unit~ ( ( Current 1 (on bone) ft/hr 65 units 90 Deg F : R.O.P. Gas· Temp Out Mudlogger's Morning Report -...-.---..--.-.---.--.,...----.....-..-....--....---.- ... ...-.....--.-.-.-- sper'r'v-sun DATL-. L I N G --....-s-ei"'FfvTE'e-s .. ,h :'it:t~~ì~~\'~ .' spe.....,....,v- sun ~"._-_.,.._.._---_._---_._----.~------..__..- Customer: Well: Area: Lease: Rig: Job No.: I ÇJ_~..~_~'=J..~_~,_.._~_I?_,!:!..~J,_'::;_§_..? Mudlogger's Morning Report I Current 200 180 110 471 285 110 24 hr Avg 102 ftJhr ( 146 unitq ( R.O.P. Gas· Temp Out ftJhr units Deg F ,. ..", < ~:.'.:./ .'!".~~ ~;",..~,....~:....I'" ".." ," -:- ~:~ ;..~, Mud Wt In Mud Wt Out 9.20 ppg 9.20 ppg Visc 60 sees API filt PV 14 cP YI 31 Ibs/100ft2 5.2 ml HTH P Mud Wt at Max Gas ~ ppg Gel!: 12 1 17 1 20 Ibs/100ft2 pH 8.6 Sd 0.25 % .~ - :.'.,- ·'-.·.:t.t""~· .r:.....,J.:"t:...;...-:-. .... '. .:"" ",' LOr"~ ."!I....-~.. .~'"':~.. ~'i I Bit No.: Wt On Bit: RSX238HF+GS Bit Size: 145 H rs. On Bit: 0.9410 6,559 :, Type: RPM: 2 10 . ..~'L" I BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 24 hr Max ftJhr @ units @ deg F @ 8883 10281 10600 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 9 7/23/02 10,609 1,853 Drilling Kidd / Clump Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data 104 spm DH flow 106 spm Total flow spm AV @ DP 2300 psi AV @ DC ~ , !'...... ' --- 12 1/4 47.4 Jets: 3 \ x \ -- Total Revs on Bit: 11 \ 6 x 12 TF A: ---- 398K Footage for Bit Run Drilling Breaks after before :-".' ": .,' ...~: ; ~L ~', .' '~''''. I Trip Depth: ft Trip Gas: Mud Cut: _ ppg Trip CI: Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: Tight Spots: to to to Feet of Fill on Bottom: ~:II~:iìðf.~;JI::'::ft~r.5.J~,}~:~ïIL'···~\ea'tl"!!1f~i!{:~.~'4i\t1..lrú~,,*,...I':~~~-;r;('-wM" 888 169 315 gpm gpm fpm fpm ppm ppm ft 25 % SST 75 % SLTST % ..,JU:::e"""lJ~,J,,«::.L::UI;:::Al~::vJD11ntL,~lI:JUt.ID.lIIi~ ij:, 1~~]J:ì"jíD':::':u.;;¡:~~::::;:;r;:;.~:: Current Lithology: ~ ¡ (~II';;ç~" ~ % ...".., . ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft ft ft ft units units units Depth Drill Rate during before Gas during after %LCM units _ ppg units ppg units _ ppg --"'^.~ % Lithology Sst Sltst Sh ~ i "~'~ ~.~:~~~~:~ , , 24 hour accumulation of Steel Filings from Possum Belly Magnets: Approx. 2-3 OZ.f; Description of fillings: moderate amount of large casing shaving decreased to negligible by 5800'. I , ,', ·1.~:':;·.~9,~'::',-i'!~~~Jt.M'di~¡,;zr'.~~~::é:-k ;,:~,~:t.?:',~:¡:;,~~,t~~:I¡:":'~;':'~'¡'~""~"<·~:·" '.;.;~', :';"",,,:,,;:k': ,':i~¡3~"",r'" ", .,'.,.":::.,,,:....,~,;~~..;:,:,:. '.'...~[,¡"',','¡..':. '!i:;'.'!\-;Ii~·'" .. ',1,: 2..1. hr Reci Drilled ahead. SCHRADER BLUFF @ 9711' MD, 6324' TVD COLVILLE @ 10713' MD, 6905' TVD Logging Engineer: Tom Mansfield 1 Doug Wilson . '....':.1.',,:.:, 01" I It · 10000 units = 100% Gas In Air I ·:.j~.:~·~~~:t, ': :".:> ~~~;:;'-:'~ ,.'.-'~ ~~~:~ ::1;' . .. ,.. ,'. :~, ï: ," I · 10000 units = 1 00% Gas In Air ~ . ,_. Logging Engineer: Tom Mansfield / Doug Wilson Colville @ 10713' MD, 6905' TVD !i':' ~z::~¡~~·,~~¡~~~'¡~~~~_~\~~1',J¡.3;~~~~~¡.ï~~~~~¡:.:::.~~:;~;:;·,'~;~F~:t;P'i:~~\i¡~,:¡tt:',;:.¡..,"·:·'·~;' :I~<:\'~::: :'~;' ,,!'1i,ï;~~1':;'·,i'·~:¿·;·~:·(f.i,-'~'~:'c::';:;':.:.:;(';;.\IJ~."·' 24 hr Reci Drilled ahead. I have waffled on Colville top and revised it: " oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: ;~ f ~ gpm gpm fpm fpm % Lithology Sst Sltst Sh Gas during after to to to to ~ before I before after Drill Rate during Depth ft _ units _ ppg ft units _ppg ft _ units _ ppg ~:.:~"":mnlW¡"..., Connection Gas and Mud Cut ppg ft units _ ppg ppg ft units _ ppg ppg ft units _ ppg A::ll.,.JJ_ - ml! ø::"'", Drilling Breaks 901 171 320 Pump and Flow Data 1 07 spm DH flow 106 spm Total flow spm AV @ DP .~1 00 psi AV @ DC Pump 1 Pump 2 Pump 3 Pump Pres ;~ Mud Wt In 9.40 ppg Visc 56 secs API filt 7.8 ml HTHP Mud Wt at Max Gas 9.3 ppg :i - - - 'lor;-' Mud Wt .out ,9.40" ppg PV. ~ cP YI~ Ibs/1 00ft2 Gel~~ 1 ~ / ~ Ibs/1 00ft2 pH ~ Sd ~ % _, ',' ~ ".' :,.'.':'-~ " :~:~,--~,,1~~ '~~ ....~J'1.i~.~f~j I<~,:;,~:~=:~,,;.'.: . ;L.t,~ ),',~.~::...:-: . .·,.};:t;,:r.:ç'~~:~,;y:?%~~;,:;: .::--~,~:.~~'.'~~~ ..'-:~~·.~,~'~~:.:i ~.....{.it·D~ ".,:-"~ ~ ~ ::. J~.I;':V ~,':.: . ~ "~'t , ~ :' . ::~ (',1', " ::' : ';~'~~'::' .: ,.':'__;, ~ , "," . .I·.~ ~ ~: '. ~~ " ,~:::~'.~! ' . ' . . ,~~ . ; . " ' , ~.~ . ' '. ~.,' . ~~~~ .' ¡,¡ ~{:~ ~. ,':~ ;i~\r Bit No.: 2 Type: RSX238HF+GS Bit Size: 12 114 Jets: 3 \ x \ 11 \ 6 \ x \ 12 TF A: 0.9410 ; ;;. Wt On Bit: 20 RPM: 147 Hrs. On Bit: 66.2 Total Revs on s;¡:- 559k - Footage for Bit Run 8.674 I I ~ " ,···~r:::::-~'~-:-=----;&~t:::::.,=::,.,:::,...,.....".,. ......,.. :':~pm :;~ ~ Short Trip Depth tt Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm ¡ Tight Spots: to to to - Feet of Fill on Bottom: tt :;:::VUI--'B'l4:::1U:n' 1 m~1 ~rli!~:;:'1J.-::¡¡:YLJI'J' I ill n III :'1...~m¡'1fill~~1Ili~~\J.1J'Jf~~~m.~ ..~ .; 'I Current Lithology: 10 % SST ~ % SL TST % % %LCM _ II ~L-m:~ ~ ~[.I ffrffirUQ;:X:.::'I'-LG m.l_~ ll:;l~:lrjQl':, _,:~~ 10 7/24/02 12,724 2,115 Drilling Kidd / Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: I units units units ft tt ft I I I ,...... ': I . . ." 12441 11869 12724 24 hr Max ft'hr @ units @ deg F @ I 24 hr Avg 1 13 ft'hr ( 185 uniÜ ( ( ft'hr units Deg F R.O.P. Gas· Temp Out Current 72 265 112 252 381 112 BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: _.,--.-.-_.. ..---.---..-.-.----------...--..-.--..--.-.------.----....... --.. 5pe.........,v- sun ëi'ATLL.. I N G "-5 ËR v I I:: 'e 5 ~. ¡:,C ..;:;;~~":'_T¡~~J#£.;,,: , :':<¡:j'~~t.~f~n+.<,:~:,·, ,,; , I spe....,...,v- sun ---_._...._."~---_._.-.__.~-_..._..__...._....__._..--'-'-"-- Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: ÇJ,_~I,.L:. '=_~_~_~_......_?__~__~ v.!_~~_~ Mudlogger's Morning Report 11 7/25/02 14,423 1,699 Drilling Kidd / Clump ''.,it- " ~~ ~ ,:;' :~~ . ,~~ ~~ '. ~: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 16 ft/hr 119 ft/hr ( 268 ft/hr @ 12725 Pump 1 96 spm DH flow gpm Gas~ 918 units 412 unit~ ( 1953 units @ 14215 Pump 2 96 spm Total flow 876 gpm Temp Out 118 Deg F ( 118 deg F @ 14025 Pump 3 spm AV @ DP 166 fpm Pump Pres 3510 psi A V @ DC 311 fpm " -, ,.." " ,,,>,. ':! . " I Mud Wt In Mud Wt Out 10.50 ppg 10.50 ppg Vise 55 sees API filt PV 18 eP YI 33 Ibs/100ft2 4.8 ml HTHP 10.0 Mud Wt at Max Gas ~ ppg Gels~ / ~ / ~ Ibs/1 00ft2 pH 8.0 Sd 0.2 % . " . . ,'.' T..~ ':;':''"'.:~ '.'j,:'. .' ~.f~:.~C"~; ':':"':¡~~ :;:=:~lc. ~ ~.'. "~' " ~~'" ~· ~':~~"'~"'~~·~''''f~.~ :.\ : <.: \~~ 1(::~ ~:' t.¿',' :':~t·::·".:::. 'J' ,'1. '~'~ ..~:";'~i~'''. :'1-(. ?t~.'·:~.. ,': ~'~ 'Y. \ ~'.;.' .. :L:,', :.,~:.(~~ . '. . :~~.:: .,,, Bit No.: Wt On Bit: 2 Type: RSX238HF+GS Bit Size: 12 1/4 13 RPM: 105 Hrs. On Bit: 85.6 :if5::=m:II~am.ua:XJM,l\__,_,,:t:,~ :'.." .~ ".: " Jets: 3 \ x -- Total Revs on Bit: 11 \ 6 \ x \ 12 TFA: 0.9410 ---- 718k Footage for Bit Run 10,373 I Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to ~~.:rJa\m'i1~~~~wl.:iUQ~1 Mud Cut: ppg Trip CI: ppm Mud Cut: _ ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft ~,..if.U'!:1II.~~~I~~:,rmr~~" .:, %LCM 1 Current Lithology: 40 % SST 60 % SL TST % % ,1'\~¡.UJ J illl~ 1----·'11:11.-..· ~""'YW,,--...-.,_.'"rr~nTi.""'..--..........,¡ ""·'_""'iII'Ii''''I1'~'li'''i·\I__I¡iI~VI'''i'' ".. I ¡r~:.:. ,....., " " ..,'~.... '" .", . ,~~'!.,w"'r,......:.<.Å,~,.. ~11¡ ~. ~¡.;«:'-:~~.::::Jt.lb.mJ:"ilJ~'?:"";,.J.il.--..J.,._.I\1I,,.,,-,:~r.:.~,.,_w.N.i+k~~.¡.:~~_ OY\ ___J.L,....w""~.lìt.~J.~,-.¡o;i.h'W;~~~~~~M:.1A~W~,.,, ~~.~(: , .,.. ..- I ; I i~~J'" .i2~'~:.~1¡;~~~~~,~~;\\~¡.:¡Hr,¡';J¡lt#"~':W~~Aœj~w'jt' ,J'~"l;J'::\f~;",; \\;7'." .' ";',~~i~·;L,.,:,:~!!¡;",i\. ïp":f.:~r~'\o:r·'\··',¡ '~~~~... ,;'h : .,;,~:,\tr-~ I~' " '." '....1,r!'\.7.';.~I..,~9·,.."¡J~"~~ip~''"'1~~· ,,,,,"""~~~\~:~,,'~'V~~~~'\'II!r~,',, 'ol'" './_" ,,':'f., ':" ffl-J3Ji-. .',1.", ,.,.... 11 .~: 2..1 hOur accumulation of STeel Filings from Possum Belly Magnets. 'JZ. :f, t DeS;.~':t~,~:O:: .~::;;;'~:~""""""J,~.,:<:O<;:"''''i''''':'!i!''''''' ,.,,' " CŒ'I:.'I<FI'.Ù".',,, '.' 'f" .," ". ',: . " .; ., ':;,,! """ .. '. · .".'.. ;" . ...,,, J ~1 I Connection Gas and Mud Cut ft units ppg ft units -ppg ft ft units ppg ft units ppg ft ft units ppg ft units ppg ft -- Drilling Breaks Depth Drill Rate Gas before during after before during after I I , 'i i"- to to to to 2..1. hr Reci Drilling Ahead No HRZ, Kalubik 13830' MD, 8679' TVD Kuparuk 13885' MD, 8715' TVD Kuparuk C 14191' MD, 8919' TVD Logging Engineer: Doug Wilson;' Mark Lindloff units _ ppg units ppg units _ ppg .....'ru'''ft~. % Lithology Sst Sltst Sh " * 10000 units = 100% Gas In Air .~ _ .. ,'- .. . . :t~t :. ~~ ;;~.:".,:: ~!.:.~.::~~.~: I ~f"': ::' ~< ~ . ~¡ ~..: ~ ::, ( : ~ :~ t~: ~~~ . . , , .. . , , Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 5pe...........,v- 5Un -------- ~~,L~.!_ I,_,~...§_,_.§_§._~..~,L~Ë,.§ Mudlogger's Morning Report ..." ;'~ '~7b,'::'"4F~ ~·:\~~~~~~.;:*;:~.;{.;y:i~~~Þ14·: ?'::, :~;c,' .- Current o o 102 24 hr Max ft/hr @ units @ deg F @ 14454 14451 14693 24 hr Avg 70 ft/hr ( 305 unit~ ( ( R.O.P. Gas" Temp Out ft/hr units Deg F 113 957 118 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 12 7/26/02 14.693 270 POOH Kidd / Clump Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data o spm DH flow o spm Total flow spm AV @ DP o psi AV @ DC :-: ~~:.~<~' J":r~,~,~~~~1~~~\~~:~¡:.;J~\f~~~_t%~.~~~~':\~;;t.~i:·~%~:~»t,t~~~::~t ;,.; o o o gpm gpm fpm fpm I Mud Wt In Mud Wt Out Vise 61 sees API filt PV 19 eP YI 35 Ibs/100ft2 4.7 ml HTHP 0.0 Mud Wt at Max Gas ~ppg Gel~~ / ~/ ~lbs/100ft2 pH 7.5 Sd 0.1 % 10.50 ppg 10.50 ppg .. ;',; "~, ~Ø".':I" ::~:-~~::."'.~.r'-:-:"..'}~i~'~'~~~~~;~' ~,¿~.~_ .~~: ~¡,:,·~~-v:.,:::;'¿,:,·..,~"_·,I::~;';:'?:.~,:,:·,,.:~~)ç·.' :~;'~~.~.~ YI~'~:f"';~f,',:-': :".. . ~ ,,-,,: ,I:;': Þ. ...... ~~,,~:,~:t:;,,'i~~ ~:.~ .~~;.;:'_.}~:':~~"~~,~~';.~ ~t~_·· ~ ~:~ .~:'.., ."..~,,~:.. ,,~:.... . .' ~ . . -, .. ~ " .. ,- I Bit No.: Wt On Bit: Type: RPM: RSX238HF+GS o Bit Size: 121/4 Jets: 3 \ x \ 11 \ 6 \ x \ 12 TFA: 0.9410 ------ Hrs. On Bit: 89.5 Total Revs on Bit: 748 Footage for Bit Run 10,643 "~~~ 2 o Mud Cut: ppg Trip CI: 19000 Mud Cut: ppg Short Trip CI: to to Feet of Fill on Bottom: ~~"',I"UNWw..,·¡] ~u~t~~U-~"" Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: " Tight Spots: 4600 to 4030 ~tM.m:'.;;;;.1Jt'.'~~::::':~:C.'I.IØ.Dl::1I~ 111 ¡ , Current Lithology: 20 % SST 50 """-;¡J!.r.;.,w",_ m , ,.L...J!!L_.N.I_. % SLTST 30 % SH % ,~,,::f:ï-:::~,}'!':::m::K. '''I:: j %LCM T ffJUmm.1~.rn:::J. Connection Gas and Mud Cut ft units -ppg ft units -ppg ft units -ppg ft units -ppg ft units -ppg ft units ppg ft units -ppg ft units -ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Sst Sltst Sh ( ( I . ¡ii-¡}Bt . ~ ¡ 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: . ':¿,?~¡<·~;~~~f;~~i~~f~~~f..~. ::.y:';: ,:i:;';~~~::~J :~~;; ;;;':o;i .,,¡:i?tf~'t';Ç,"';·:i;·:,; ~ '~.'; ~':. .~.~~ ~: ppm ppm ft ., oz. ',.': ''''~,''¡¡;:"'' ·,~.:~,,:?_~~~.~w.i~@ . . . , ." . \;", ~I I · 10000 units = 100% Gas In Air I '~:' Ù~: i"'" . " ..~".. ", ....~. ,....,-,,~~. .. '.¡." . "_-""~ :1:~':,' ::;::,:",,~,.?~? ~'>'~;~".¥~~,~':.~'-':. .~~ %~ ?~:. o. "":.¡?M!i0~~~.~,;:,~!~'itWm~'~~~~~~~~!~}!tI¡~~~¿~~i':·H~0,~,::\E~:,;~~;~~w.~flE:'*¡:~;~~:';*â~é2:';~¿~~~~~?~~~:~~1f.:'~'i'~~~t;'t?!~;.;.~· (& 24 hr Rec¡ Drilled to 14693. TO 12 1/4" hole, Circulate hole clean, POOH, currently laying down BHA. .~ :~~ ~ ~:; MILUVEACH 14620' MD. 9225' TVD ':~ Logging Engineer: Doug Wilson / Mark Lindloff :<> ":,.."'(:.';:'f;:;~~~~m:':<y.;" Customer: BP Alaska Well: NorthStar NS 18 Area: North Slope Lease: NorthStar NS 18 Rig: Nabors 33E Job No.: AK AM 22120 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 13 7/27./02 14.693 o RIH wi 9.625 Csg Kidd I Clump I spe.....rtv-sun ºFÙ-çCT-i\ï-cii--'--' s ë-RvTï::-e-s Mudlogger's Morning Report "...'.::.,;:, ,,:~;:;, """"',.' I Current o o 80 14693 24 hr Avg ft/hr ( unit~ ( 24 hr Max ft/hr @ units @ deg F @ Pump 1 Pump 2 Pump 3 Pump Pres Pump and Flow Data o spm DH flow o spm Total flow spm AV @ DP o psi AV @ DC ..".-- R.O.P. Gas· Temp Out ft/hr units Deg F 84 . a.. ~:r. ~~';:'::' ,,~]:~~ :""1-~.-r.~ ~'''-~. :.~.~~~:"; ,,~'. ,"...,,: . '.'':'~''~~'~~'r:''''''"., , ._a" . .' .", '-.. ...~..' . - .. -'"', .. " " .. , . Mud Wt In Mud Wt Out 10.40 ppg 10.40 ppg Visc 53 secs API filt PV 19 cP YI 28 Ibs/100ft2 5.0 ml HTHP 0.0 Mud Wt at Max Gas 10.4 ppg Gel~~ I ~ I .:E....lbs/100ft2 pH ~ Sd ~ % r ·~~.C'~..\~' ~;~~¡,*:;;-:,J.~:~~i-'1'tt-~'''t~~~,-;; ~"~I~: ~':.,:.¿ ~ ~~:;,;~ :-:_':I":~t'.1:~'t:x>f"~.\.,,,·~~~~~::.~:<:~(fbf~;;:'~~~~~.;~~j.; ~~, "~r.: ~,. ",' :".. ~', ':. ~I,;.': ~~,,,:~,..,::.... . I :~~,'i~' :,,¡,~'\'!~ ~t; ~~~:; -.~: ~ ..~::-..: ,'\':'.; ;"¡ ~t':. -~. - "< . I:·... ,...."" .':"'::',; '~. -,"'.: ~~ h"¡~"':~," :,. ;~:~:," :,-; Bit No.: Wt On Bit: Type: RPM: Bit Size: Hrs. On Bit: Jets: \ -- Total Revs on Bit: \ \ TFA: --- Footage for Bit Run o o o Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 19000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm > Tight Spots: to to to Feet of Fill on Bottom: ft ~ :m:JUI~nr'J,~__.lj."~¡"U::o.J_:lJm:M: Jj ~r~n mn ~ ",,",:r==_~~~_Ic_1r'(-:"":r:~.':XJ~'"El~,1 .ULt.}!:~ ::;n;n~ ~ . ¡ Current Lithology: 20 % SST ~ % SL TST 30 % SH % %LCM _ ~l.::::¡JDu.ll _ UliIl ~rll: ~ II ~,-..""""'.___o"',~__,_~~.~__~_~.n._~.. II œ!HIiflll-"~-,^""~:Jr:::r=:~::m:t:\tr:rtU1L,~' ~ II~U!]lilJHi 111I[1 uBt' n:~';t t · 10000 units = 100% Gas In Air I I~,~~~ ,~~r r r Connection Gas and Mud Cut ft units ppg ft units -ppg ft units -ppg ft units ppg ft units -ppg ft units -ppg ft units ppg ft units -ppg ft units -ppg ,Æ J111I! n W1ß . t. - - fIIr iil ,rllll~lInl~ '.'-0'"'__'_""""_' ( Drilling Breaks Depth Drill Rate during after % Lithology Sst Sltst Sh Gas during before after before to to to -. ..~ -- "'~'::~~~1Í" .~ "".,',. "~" ",',_~~~·,f:f~~~;'?~~H~~·~~~~fl~~~~~fl~~,~~~~·,~~;'~'~·::\. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. . '. ", :;!~':¡-ii'inr:?~>!¥;~~_~:,µ:~~~;'¡:::,~~';':'!i~~~~~~*:.ii':'i!\¡ fl.'F~!:t:~~:~.~~¡;~¡,~¡;~'F:;·~:- :":""·:,,:,,c,¡·_?;':li;"" ~.'" ';¡.' :.:;::,,;,:·~~:..:,;:,;·:,:.:~..,,'ì~"ì~IiI'1'~¡: :~::'¡!;';T~~", ' 24 hr Rec¿ Finish laying down BHA #3, Pull wear ring. change top rams to 9.625. test door seals to 3000 psi rig up to run 9.625" Csg. Run casing to 3980" and circulated one casing volume- continue to run casing. Began seeing losses at 6626' lost 20 bbls from Stand 160-170. No returns after joint 170 and losing 1 bbl per joint. Total losses from 160 - 210 are 235 bbls. Logging Engineer: Doug Wilson / Mark LindloH .~: ~ ~~:,~::'~ i,,~,~~~~k{\":',~~,i~~~'~'ftf^f~;,:~:~;: i'~'.;~'·~~~ ~~. ":":,:' :':,: ,;~ . ~.~ :~~' :"' :'3. .. ··.r,.".~:~·;:::;.-) ..,':;. ";~'~~"~':.:'." >. .:..-:" ." ", . - .:. Bit No.: Type: Bit Size: Jets: '. \ I TFA: .,' ~~; Wt On BIt: RPM: Hrs. On Bit: Total Revs on ~ - - Footage for Bit Run ~ I": . :r~;;ii :'¡,'~:'(I;;~~~¿~:';V'i~~t~>.tii~"ihi:Îiiæ'f;'¡~:¡ ;¡f~r1%l~~·;::Mi:i~:ii'J'~f~~"~t~1tí!)f¡o1M)~!tt;¡i.r;":"£+'¿·:i':':~~1~'~'~ :.~"¡ "!!~~,,I¥:-ï·d,..,·:'i: ',<""'!:' ." I ~ Trip Depth: 14666 ft Trip Gas: 1173 Mud Cut: ppg Trip CI: 19000 ppm I .. Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm , Tight Spots: to to to Feet of Fill on Bottom: It " :, ¡ ~ ~ft'fttJMI:J...RUI J 1 Lilli nlr']J':'B[ílf~JmUlilU 1/100_ ! r~ Inlll,LC:=1C:TJ~'.n~ ::H~J!~ ~~·m~'t!mJlu~.~t;¡¡,~ -t ~ Current Lithology: 20 % SST ~ % SL TST 30 % SH % %LCM , "JJ~~=+=r~ I 1I,2:.:_rn~:J^""I..J!!J] I~II UI~II!I! Jlma. ~Iiilll _ III! 11I1 I~ i !in ;Jt:I'lULL::::::::':C1IIIJ::!!L'f.f:::]:~ :. '- ~:'·',:..:;±i:)iff~h~~~:~::; sper"r'v-sun Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 14 7/28/02 14,693 o LD Cmt Hd Kidd 1 Clump BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 .-....-.-.....-----.--..--.-------.-.------------.--.. r;1_~_I....~~}~..§.._..,..~_I§...A ~",!...,~_~...§ Mudlogger's Morning Report ..';,", .. , , 24 hr Max Pump and Flow Data ft/hr @ Pump 1 0 spm DH flow gpm units @ Pump 2 0 spm Total flow 0 gpm 78 deg F @ 14693 Pump 3 spm AV @ DP 0 fpm Pump Pres 0 psi AV @ DC 0 fpm Current o o 78 ftJhr units Deg F 24 hr Avg ft/hr ( 146 unit~ ( ( '. R.O.P. Gas" Temp Out I Mud Wt In Mud Wt Out 10.20 ppg 10.20 ppg Vise 42 sees API filt PV 14 eP YI 21 Ibs/100ft2 ô.2 ml Gels HTHP 0.0 Mud Wt at Max Gas ~ppg 7 1 11 1 13 Ibs/100ft2 pH 7.0 3d 0 % -- . ~. . ;.~.... "':; :'.. I ,~ ;.. . ;!.-' .1".' . __ I"... ....1. ',-' ..,,'.:..... I I I Connection Gas and Mud Cut ft units ft units ft units units _ppg units _ ppg units _ ppg 'H!IIII~ [Im:n:~.". . ft ft ft units units units ft ft ft '"' ppg ppg ppg ppg -ppg -ppg __...::JIIU.. ¡: [ Drilling Breaks I Depth Drill Rate during after % Lithology Sst Sltst Sh Gas during before after before to to to to ~>k' ,'," ,·.:·'.:..~,'-'"%,I"~",të~~"I.r.\~IÌ/..;ot/jl--[t,,~:'¡j'I,...:~I.~' ·~w·...'.IiI'm,."~i!:~TIIIitI!1!Lrl...:':·~';-;'cr ~;,~.i:f..'",..'(r.J~:"¡~~'.'J¡;:;'iH.¡,l':r. I'~",,':~ -I'.',,', ~~~ I: ~ I \\. ,1'-:'''1 ' ,,:-~....... ~', .~,·~':'i~ ~~1.~~'~)jfl'~ :~.~'. I .~f·-~~:t·r,~f~1,f.\..'f¡lt~. . ~~~~~~~,,~f~t";}'i,"'li'Mt'1,~~t~ '~'~'I ". t'.". ~ I~'I ; :·(~ft. '~~~'~ ~iI.'~(~lir.: Il'\'I.":'''' ~ ~. :" ._ j:1." 2J I'"lliur accumulation of STeel Filings trom Possum Belly Magnels: oz. ;·~t Description of fillings: ;~}' ',~' - .": :·::::;':'~':;i.!:,' ~.' :-f~:i3~.;.~rr:~1ntl"J:h7:.¡~~J<~¡:O';;¡;'·i·,:k&·~;,~?:1!:)1.~i'·:~"'!,~'¡;!.:~H~'J~¡2t:;1~:~.~.;,;':·::.1: :'. :':t,i:;!:'E!':;·?'~(,·:: ".:" ;·~tf!!¥.:.tt~:'~:.;:"i'~:~:::i: /:,~~:::>::: .,'.~;~ - .::. 24 hr Reci Started losing fluid at the top of the Schrader and continued losses till casing was landed around 1045 AM Total Losses 710 bbls. Attempted to .circulate, packed off, worked pipe and pumped to 1200 psi then bled off 200 psi at a time. Established Circulation at 1400. Staged up to 9 bpm- Pump cmt job, lost 53 bbls while displacing CMT. Currently laying down Cmt Head. Avg Gas while circulating 146 units. Max TG 1173 Logging Engineer: Doug Wilson / Mark Lindloff * 10000 units = 100% Gas In Air ". ' .." " '." -.. . . ';: .t7~·· :~ ~'.~~~;~:;~ ,~?'~:;:r ',<~.' ,::. (:~f,~,~~'~~'~':~~~~~.~,;,,~,:,::::· ,;~,~;f}:·~~·:~~~}:"~·:F~~;f~·1~~t ""~; . . - , . , ' ~. . . ~~I. . ';;-". ~. , . - ~J f! =1 - 1 ,f , ,:',t¡ .~ It ~' S¡! .., " ,-r~:~~ ~:' ~,~~;':'~~';~~~:.~. .:~:~:, .~> ';". . :~ ~ ~~:;. <:::'" ,.~: :i ~ ( ~':'~ :.~'~~'~ 5;~:~~ .;.~~.~;~.~ :.:~~.."~'!~:t A~'~~ì·~;.~~;~~~ :~',~.~:~ ~:'~~~~':~·f~~~~'~~I?~~~;:'i: ~~_: ..':~.; <_~,(~~~; :'~~~' ~ .' * 10000 units = 100% Gas In Air ~fì· ~,i~~ -:~~ ~~ ': 'f~..... . Logging Engineer: Doug Wilson / Mark Lindloff oz. 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: "., ·,-~~:·"':-k~~~·'Ï'Í¡1":'~~!':'\·;'¡~<f:'iti,t~;:~~t-;:~".;;':~~~~~_¡:~r::'*~r::t~:~I;;0, \""';it:;'~!fl?:;:';"~;"";;' ,1·;"~;::;¥.~'f~ ~~~~~'':TI-!~~3'' ".>;,~: "'J.: :-: " . ;.~.. 24 hr Rec¡ Test BOP's, Pick up Bit #3, RIH, Freeze protect 9.625" X 13.375" annulus, cont to RIH Mud Cut: _ ppg Trip CI: 19000 ppm Mud Cut: _ ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft -·Ø1l.1~:_.:I~__~:ciJIj IT ¡1J!1~~m:c;..::1t~ Bit No.: 3 Type: DS164F+JNW Bit Size: 81/2 Jets: ~ \ ~ \ ~ \ ~ \ ~ \ ~ TFA: 0.6100 Wt On Bit: RPM: Hrs. On Bit: 0.0 Total Revs on Bit: 0 Footage for Bit Run 0 fli",.,,, "I'¡'¡;"~~""'~;I.......!>.\~r..;,~~'¡I.:'-!i\f"'W_"-' "~'.lßfn~·'riII""w.",,' "r_~'''' ,''¡ '.J,'~..~'" ,~C""' ..' '.' .'.', ,".' ,'; ~~ ...."'JÞI~"]'..J,.: -~.c~-~~,"",·~~~"·.~.í'"~~(W...·~\~'1r'~'~fIÞft.;.:'.R\I':.,;.I":!.)i"l ,...'W"..1~Q!:I.: ,. ;.' , ... :tst~,~~,:t!o'fõ~:.",.~·':'L"=.:"å.~'t;W:'t."'~\j~~l:-·.:.:~·"L.~.;,¡r;,~f":-..~_.~-..~ ~._ .....·:Ii~'I"~.~::.....:., .:..... .,~ ,>·"?1'1!I t l. ¡j ~~W; :œ~~· ~, ,~ '0;:: c ,f~, I I ¡ ...~ ~;~~ gpm!~~' 5;~~ gpm .~~ fpmc'\\¡ .,~~\. fpm '~I I Connection Gas and Mud Cut I ft units ppg tt units -ppg tt units -ppg - ft units ppg tt units -ppg tt units -ppg - ft units ppg tt units -ppg tt units -ppg - - I - Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during atter Sst Sltst Sh ¡J to to to to ~!2~:~~J;,~;EU;l!;, SST 50 ~JC:r~ Current Lithology: J..~:~.w,JlijL llIl~ ~L 20 % I %LCM % SH % 30 - % SLTST Trip Depth: ft Trip Gas: Short Trip Depth tt Short Trip Gas: Tight Spots: to to . !;:~;-:.~.'J....!..\.~..,~_l.,_.\.......,].._.."lll1J..}¡L::,:~:~:::::rr.l:__ '''~.. . :-:~,~~:.;'1.:~:·~..:~~t...(,d·;,~~;,,~~~r~\ç ~':~'C :"0: :~"~: ;r~';j :~ ,;""·;'.\t~~~ ~/ ',~,!;.,;~~~,~'.i:=~ :'1~~~'~~'':'\~,~~~~~'~'>;~~~.~ ~ . ~::.. . :"'i.: ·..t>;;y :>' ~,~,;'~..'. ~ ;.;:.:~~ ~,~9 .::-'>~\:.~'.., .'~. ~~ '. ·4',~;.' -~ :':~'~.,~:Ji:.~'~:'~ : . . ~: ~ ,'" :~";'," --- 0/0 HTHP ~ Mud Wt at Max Gas ~ppg 8 1 11 1 13 Ibs/100ft2 pH 7.1 Sd 0 I 10.20 ppg 10.20 ppg 6.2 ml Gel~ 42 secs API filt 14 cP YI 21 Ibs/100ft2 Visc PV Mud Wt In Mud Wt Out ..... ~, . .. ~ . :r".. - ~. . . o o o Pump and Flow Data o spm DH flow o spm Total flow spm AV @ DP ~ psiAV@DC I Pump 1 Pump 2 Pump 3 Pump Pres 24 hr Max ft/hr @ units @ deg F @ 24 hr Avg ft/hr ( 146 unit~ ( ( ft/hr units Deg F R.O.P. Gas· Temp Out 14693 Current o o 78 78 . . .. ~ '. . ~ 15 7/29/02 14,693 o RIH Kidd 1 Clump Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: sper'r'v-sun o-Ffï-CCrÑ-Gi-'- s e: A v I r::: E 5 Mudlogger's Morning Report BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Customer: Well: Area: Lease: Rig: Job No.: ~._..._.....-...__.._.._._----_..__.._----~------ " I "". ~. ":'. ..... ..... .' 7t'·~r:::r.. :. ,1', J" .',. "::n;"'1i):;::;'*iiÄ~\~~"C;>, ' .. . ,;,,:;,"~¡¿'~~.2~ii::::' sperr'V-5un Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33 E AK AM 22120 ----------------....-..- ~..'F.:!h!.._~_~!...~,_..§...___? E§..~~I_~,§_§ MUdlogger's Morning Report 16 7/30/02 1 5 I 1 72 479 Drilling Kidd 1 Clump Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 88 ft'hr 85.16 ft'hr ( 343 ft'hr @ 14700 Pump 1 70 spm DH flow gpm - Gas· 47 units 89 u n it~ ( 131 units @ 14908 Pump 2 90 spm Total flow 569 gpm Temp Out 92 Deg F ( 92 deg F @ 15120 Pump 3 spm AV @ DP 270 fpm Pump Pres 3380 psi A V @ DC 522 fpm -.r---- . , I --- Vise 51 sees API tilt 4.4 ml HTHP 10.0 Mud Wt at Max Gas ~ppg PV 26 eP YI 29 Ibs/1 00ft2 Gel~ 11 1 28 1 32 Ibs/100ft2 pH 8.1 Sd 0 % Mud Wt In Mud Wt Out 12.90 ppg 12.90 ppg . ., :, '~i.':;:::;.,%',~;~:,.I:.~::y~~:\..J,:;~~,:,~-.:t,;<-.~.,~.. ,~::.1" ·.:...,.,...;,.i~.".'~~:·.;~,~,vJ:::~~~,..·, ~~j.;:.:...."':.;.,¡.,,;.;.....? ,..:~ .' ·..·;:,'.:.;-·~~·.,~',·,.;.·t,;.('~..:. ":,. '~'. . '" - -" ~ . , ' I Bit No.: Wt On Bit: 8 1/2 7.1 Jets: 12 \ 12 \ 12 \ 12 \ 12 \ 12 TFA: 0.6100 ------ Total Revs on Bit: 54 Footage tor Bit Run 479 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 58000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: ppm Tight-Spots: to to to Feet of Fill on Bottom: ft ~l:.:::D':I::~';:::I:U;,:;:;;;:l1.:I:~" ' "1 ,-. ;:~r"..,,,,,,,,,..m.1I, IJJ jll11mirWr~L ;¡~:L" slt8t 20 % sh % % %LCM ß~ ,I ~~:~:.L~.:2::"\:::~If(:l1~JI 11m mt 1IIIIITSt~;':;;;Mi.!.~·' Type: RPM: 3 23 DS164F+JNW Bit Size: 85 Hrs. On Bit: , ~".'m: [ . Current Lithology: 80 % ~ .~. øII .IlIm lrœ~.]I,,:·..-~1:.t~:lit! I Connection Gas and Mud Cut ft un~s ppg ft units ppg ft units ppg ft ft ft ft ft ft units units units ppg ppg ppg I Drilling Breaks Depth Drill Rate during after Gas during before after before to to to to units _ ppg units _ ppg units ppg % Lithology Sst Sltst Sh ..~, ~'¡: ~~~!~~~i':j~~~~~~.:,·!'~~: .:':'~ 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. :,~~ l~t Description ot fil!ings: . . " .... . . " . .... .. ..1 See ~ ~ Still in the Miluveach I ;:Iî Changeout day:Doug Wilson goes in and Reg Wilson comes out. ,ì t,~1: :':,~,:~ ·,,:'t~l¡l,t·~r~~;:·f:'i.<; ~~'~7~~ "~~~: ,; :: :::. :':: , . t)" · 1 0000 units = 1 00% Gas In Air ," 1.:,,,';- Logging Engineer: Doug Wilson 1 Mark Lindloft '.~:', '·~fY~··~r~;·~,s~..~·: '~:, :.~~':.:: ::~:: :'~;: :' , , '"' " 5pe..........,v- sun .___ø....____..._._____.._____.__..___..______....__...__.._.__..... Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 t;J_~"~.~_~..!.._~_~_....,_s ~~_\!..!,~_§_,~ , Mudlogger's Morning Report .' 17 7/31/02 1 5. 1 72 o Fixing Pumps Kidd 1 Clump Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 0 ft/hr ( 0 ft/hr @ 0 Pump 1 80 spm DH flow gpm Gas· 23 units 21 unit~ ( 42 units @ 15172 Pump 2 0 spm Total flow 280 gpm Temp Out 92 Deg F ( 92 deg F @ 15120 Pump 3 spm AV @ DP 135 fpm Pump Pres 1151 psi A V @ DC 224 fpm ".-- f1! ~t~: % Î ~i\ 4~\~~.:.:}..'~i:/¡~)t~%1$~~,,:t.}:~·~:t~~:$~#M$;"è~. '.,',.'?àtt~W~~~~.",~~.'·;:¡:<;~~'##,:~.'.:~~Mf¡.t.;:~~~~*tÛé\~~:\r·: "·~~'Ü~~X;;}~;:·:~'! .,.:j.#g~',~i·>~t%~).,i#4;<~·~~jl~iN.#k{Ni.~~t+'_'-::i<:~'{¡ . .; "~ '. " . .;~..:¡ f i I i ì -I Mud Wt In Mud Wt Out 12.90 ppg 12.90 ppg Visc 55 secs API filt PV 29 cP YI 32 Ibs/100ft2 --- 3.6 ml HTHP 9.6 Mud Wt at Max Gas ~ppg Gel~ 12 1 30 1 33 Ibs/100ft2 pH 8.0 Sd 0 ;; Bit No.: 4 Type: DS164F+JNW Bit Size: 8112 Jets: 12 \ 12 \ 12 \ 12 \ 12 \ 12 TFA: 0,6100 !;~ Wt On Bit: 20 RPM: 85 Hrs. On Bit: 0.0 Total Revs on Bit: 0 - Footage for Bit Run 0 't·,···-:id.; ,<:Tj,~~~,f,,~~~....~~~;;o\:-(~~.:..,I>.,:.:..,rn¡.;)i;}~'!-ri:...fJi!ffJ;,:',i;~~.",:~;~., ,':;.;", :hF;'~;r':'::; ·;niI~~i".~,;¡"',,~i:...~;·,,'¡;.::::'..;,· ",' .,!19 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 58000 ppm ~"''''.'¿:.'~~~...CI:', ~.~~~.Sh:::~:~. ~:t: ~~;tOf~~~:nT~~tt~~: pp~ n.} Current Lithology: ~ % sltst ~ % sh % % %LCM !..: ~'-(q ß ~III~ U~.:.1-"....·..JdBII7~µD.t_~.JlI~_..,;.~~~,.....>~_"1I I 11.1 r i It:r"':n~~'r~:;m_:·:r~Jll\IJmn1J1I1JIWi~-'}I;¡'~~m~ lil-lImll~ Depth to to ~ to 11 to ~i' ,,¡..:.di:.1¡;¡.,i~:~ï;Aij_·· . , .". .-........'...+;1,"'... .;",,,¡_-,<,,,,,,,.., '~"'''''''''''. '..,' ".,. .'..., ,...""l,_-".......",...": .~ 0" H 'h-~~~~. ".' ""., ~~~'w,;:w.~~..": .1.·Ii'r¡·~~·..,¡¡::;:;r:","?'{ìf'l~mJl):';":";'''~l!;j::il1~~· '-.. .,'..-. .'" :.n,': .·'~~:p.o:Q;i.}';.r'.~e;\'I:.~~'II~~,!!:;'IJ ,'"." .".-:.(l . i ,~:: 24 hour accumulation of Steel Filings from Possum Belly Magnets: oz. ~~ ¡I De~~,,~:::,:~~~;., ...~.~~'" ...;¡,.I.."'.\,~IIo!.n<l.!"\.-,'..... "....,.." "." ,.,1, > .' .. ".,,, ... =,..,", ','¡,':,';,.":',",:.,,',"'u",:".,;~"..,.,.,I,C,:.:""';!I"~."",."."ò,...\o.~"..., ,',I't" '..:,.... ~I,'I.,;.:.' jrf 1".. ·:."".f'I~·'¡ kftfij~':"œ.'~~~~·~'i.-i;·:f'Jr'i~~~~~~~2; ·,¡:t;·!~1..·i;~~'\~.'I~~~I·"'Ut~';:&1.-..::".::;1 ~~·i':·'~..'!~':";·~ I~io-1:!~,... ...;......_>J:........!;,..~:..~,;~:' .:~., ~ or _"...~.... ........n;r;. 'o'"Q-,-, Q.:.'.tr =..., "i¡~ :-:' 2-1. hr Reci Continue POOH, Pick up BHA #5, RIH, Cut and Slip Drill Line, Rih to 15165", Pump #2 failure, FIT to 14.5 EMW, drill from 14713 to 15172' MO, Rotary steerable not holding angle, POOH wlo CBU. I Currently Repairing bladder and circulating at the shoe. No problems POOH or RIH. .~ Still in the MillJveach tf ,~ 1.~ ¡,i¡ ~ " 10000 units = 100% Gas In Air;r.'~ I?; !jJ~ ,":,' . ;;:";i¡~i;'!,,>:'44t,'~:i\\~ít,'-'4Þ'f;~_k.,~#%tlii<RiJA~~;;~~~#~~_"i!fii\i\\.~~èwrJiì;¡\'li1Ht(¡;.'·i I I I Connection Gas and Mud Cut ft units ft units ft units ft ft ft ft ft ft IP" il I 11I1 units units units III.. ~r 1m ppg ppg ppg -ppg -ppg -ppg . ~m~ IliJI.11.111J.!IM"lLIID",. n.. illl!!lrnlLllL.JJ"JJ Drilling Breaks I Drill Rate during after Gas during before after before Logging Engineer: Reg Wilson / Mark Lindloff ":':';'"-.;";;" ", .... ",1:. :. . .' units ppg units ppg units _ppg I~ju J [~IIJI ¡ I "-::::.::::- Sst % Lithology Sltst Sh .. ' , .. ,,", ,."' . I . '.~. .~'" : '.' ,rI:ßtt.r. . Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Bit No.: 4 Type: DS164F+JNW Bit Size: 81/2 Jets: 12 12'" 12 \ 12 12 \ 12 TFA: 0.6100 ·":,,,.i·~, _ _ _ _ _ _ J:~~,~, ~~:;",!£--=:'oo¥~-ro..::.~=-:::==~~:",,,,~: ~~.:",,:::~g: f~:"Bit RU~" ,"..1,378 ;):i' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 58000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft ... '., ·i~~ï."..",...r.. I )1 mr;¡t:.:r:::::J:::',~;(]!~. I:i! I 1!I1~::-.f~Ð~i1~D:nCI.III~ejl\\\.tl_:j!jT:TJi.11I\1r.¡:_ I I I Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 19 8/2/02 1 6 I 550 147 RIH WIT' LINER Kidd / Clump 5pe..........,v- sun ·_..._......__...H._..________._._...__.___.____.___ ~,~"I..'=,!::-_L.,~_~.,_._. 5 e A v I c:: e 5 Mudlogger's Morning Report Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 109 ft/hr ( 191 ft/hr @ 0 Pump 1 0 spm DH flow c Gas" 0 units 114 unit~ ( 367 units @ 15172 Pump 2 0 spm Total flow 0 Temp Out 92 Deg F ( 92 deg F @ 15120 Pump 3 spm AV @ DP 0 Pump Pres 0 psi A V @ DC 0 Mud Wt In Mud Wt Out 12.90 ppg 12.90 ppg Visc 55 secs API filt PV 29 cP YI 32 Ibs/100ft2 3.6 ml HTHP 9.6 Mud Wt at Max Gas ~ppg Gel~ 12 / 30 / 33 Ibs/100ft2 pH 8.0 Sd 0 -- . H ,,~,'II':'~ .. , . . .. . I . .. ~Io ...... 'I Current Lithology: 80 % sltst 20 % sh , ,,:;:::=,:.:~::=,~tr_J..l'tJnh~1 n~l!-LrJn.-¡i~~~;~_L,.. ~L: % % %LCM j 1BRD.:::":::t.;DJ~:,~·[:~~iID~¡lim}I]_.I~rrJ__¡j*.~ ft ft ft Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units _ ppg ft units ppg ft units ppg ft units _ ppg , ""-" "·1ü::.JJ""LIULC units units units ppg ppg ppg Drilling Breaks Drill Rate during Gas during Depth % Lithology Sst Sltst Sh before after before after to to to to . :, ~ , ,I_,~ "þ;\:.r. J,'J:hd:~,~"~I~. ~~,,~:;;~(~~,~';f:~. ~~;~~~,~'¡¡~!!1~¡./~'~~~-)Ji~~~~"J;r4.'it6:1';~~.':!':~~;·!'<~: i,¡~b:..~· ~",,; .' ¡"" ,: ",. -·S~~ ,.1,., ~I~~, I. '. , ." ,;t'1'I;:, 2J hour 3Ccumulatlon ot Steel FIlings from Possum Belly Magnets oz Description of fillings: ;=:' ':.;~!;.r.:I~~;~~t..¡¡,~~~~!!-.*:.:ï~~~,:i7;'".:'F.:.r~,!Ï'$~~!J~~,~.~·-:-:~d'¡~~</'\r;'·!,~:'·'> ,:;;',:',:,~:" ;"',""~',::'. :.';.'::'!' ...~~: " 2~ hr Rec, Fix Pumps, Orill ahead to 16403 . ~ I,~¡ ~ t.~~ Kingak 15276' MD, 9745' TVO Sag River 16500 MD, 10794 TVO Logging Engineer: Reg Wilson;' Mark Lindloff * 10000 units = 100% Gas In Air I'" ¡ : '.;. .. " , .;Ii .. ~ .cr )1' 'il: d~ , ,. .~~ -, . , . .~':~. . Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: 19 8/2/02 16,550 147 RIH WIT' LINER Kidd I Clump spef'"""r""V- sun __"_"'~_'~_h"_"_____""'_'______ _.__....".___.._........ ~__~..I...~,~..~,_,~_§,___,_~_~..f!~..,~,~_,~,§ Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr 109 ft/hr ( 191 ft/hr @ 16407 Pump 1 0 spm DH flow gpm Gas- 0 units 114 u n it~ ( 367 units @ 16404 Pump 2 0 spm Total flow 0 gpm Temp Out 92 Deg F ( 92 deg F @ 15120 Pump 3 spm AV @ DP 0 fpm Pump Pres 0 psi AV @ DC 0 fpm Mud Wt In Mud Wt Out 12.70 ppg 12.70 ppg Visc 51 secs API filt PV 24 cP VI 22 Ibs/100ft2 4.0 ml Gel~ I --- HTHP 9.6 Mud Wt at Max Gas ~ppg 9 / 35 / 37 Ibs/100ft2 pH 8.4 Sd 0.25 % . . .,' ~,:,~,:.~..;..-:,<.:~,:. ~ .:~~:r;-,,~,~~;";:~~~~~~: ~',: ~~ ~L.:·: . ..~:.~t:.~~);.¡:;,:..~: '~~t. t1!-L1·.t':;t.~~(~~'~<':,r~,j:~·)'.'~r~H·~\.~~t··:~~~::.~: :;I,':¡ ,~~I.~i:~':-~:~}~'..·.. ',.' ~'~'.~~ "~'~::~"""~.' :. :\f.../{,~'_T~'../' - ." :~: :.'~':.: ':i;,;""~ ~ .:': ,",:~ / " : "'.. ." . . r ...... ,,- I ';., :?;t Bit No.: 4 Type: DS164FtJNW Bit Size: 8 1/2 Jets: 12 \ 12 \ 12 \ 12 \ 12 \ 12 TFA: 0.6100 ;~~tOn,s.it:,,,..,. . ~... RP.~: ... '.. ,~Hr,s:..OnwB,~t: ,......~.2.7 Total..~.~~S.~~Bit~,. 107..8~~~.~~.agefo,r.Bit~un 1,378 .J..,..;, .',::-t·:~t,.",~ ';~~~~:~~d~;¡~.q·.Y,'~~~:~"V:~~~,·.:¡·.~::'>-",~.-,I, ::.:'.~!.~"'" '.:~::''1I4m¡~::',·:,i!:=.;r-··:',:· ",-:. '.: I"~.~;,,. , ;", I ,~~:: ,+,1"'1 Trip Depth: Short Trip Depth Tight Spots: ," .. ·::"'JI:JU.uJn g ft Tnp Gas: ft Short Trip Gas: to to ~ ~ ,~n nø..um::~::J,:,:u::;;~·r·'~rY::.tl~:¡·III~ 10 % sltst 90 % sh ~II '"':m:.:rnU:::ftL Mud Cut: ppg Tnp CI: 55000 ppm Mud Cut: ppg Short Trip CI: ppm to Feet of Fill on Bottom: ft III: nUjl, iq!M;;~":I!I~tRlllïJl.1111ll ¡ i.li IJ '!lI~ C, ·llU~ì'~1L';.\ji~~~~_~11~~ % % %~M I ft ft ft units units units Connection Gas and Mud Cut ppg ft units _ ppg ppg ft units _ ppg ppg ft units _ ppg .. .. 'D~:JT m Y IF" _,~:.;,:~~'~=r~] Drilling Breaks ft units _ ppg ft units ppg ft units ppg _ ....:::::~~~::~l1~t;,~J\";;;·" , [ 16324 to to to to 16405 before 142 Drill Rate during 60 after 160 before 94 Gas during 75 after 367 % Lithology Sst Sltst Sh 20 80 , ( ~ I Depth I 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. ~ :;:';';';t*~~~~~¡r_~~jti,:tm~~}~~.~r.~~~~.¥:;':Ù,;~~~h~~r~~~~;~~\~t~;tf¡;~~;;.:;i< : .'.'.. '. :';.;:-::~:Nr.i'll'<t~$¡,~~';1$¡¡;;ë'Ü::~?:'~.J~,:,::::;··~~_"¡Jt¡/S:;::¡w~;~f.;;,~~f~~};;v;';:~-:::'·~ ,:'."~;::": .",~ ,';.~::J.,\'.;;,~~;,,,'.'~:" ': ' .. . ,'; ~ ,';,::; ,~!..: ' 24 hr Rec, Drilled from 16403 to 16550, Td for 8" hole section. Pumped sweep and when sweep came around lost circulation. Around 75 bbls/hr. Pumped fibre and walnut pill, started rcieving 65% returns.Hole stayed full when static. Pulled to shoe, Pulled hard first 4 stands, Circulated to 450 GPM in shoe, no losses. ~~-',' :.~, .....~::' ·:'~~I'·::~~ ;' :.~~; ~~':F'd'?~~'~. ': :·E:,·¡: : :':~ f:: 1<.: :~,~ ': ;\': .'. . ~. ~,~ l' . I I * 10000 units = 100% Gas I n Air .¡ :'~;; ~1 ~:.';~':~,> >·:::.,..~~:,~r·· "Note an unmapped 30ft fault just above the Sag River Formation was found Logging Engineer: Reg Wilson / Mark Lindloff Î .~ ~I~'" . .:;,~ ~~w . "~:'.·,~.,·.',.~.;i... . .. ~. 'X,," ,11: J~ .!~, 'I J~ ~~~. 10000 units == 100% Gas I n Air ;~~ .,,,. Logging Engineer: Reg Wilson / Mark Lindloff 24 hr Reci Finish laying down BHA, P/U 7" liner, RIH to shoe, circulate bottoms up, Ran Liner without problems, Established circulation without losses or pack ofts, Rig up to cement 7" liner, Currently Pumping cement. . . :'~ ;~'~~;:¿~~-ij~~'aP:'Ji'i.f.~!~~~;(·~~i;t~i"~i::'~~~~_~~~~,r~;f¡j~'i~:~.~ifrtH~:~~1.i~~I;¡!}if:~~~~1;1~'~t~l¡~i~~~~'~~~r ~\, ~,:~:~:,~;,~.,,;,~ t~~;'~·~ t·t~J~t~;::,~~j't~;:~~?~~~!"~·:,~.~i~,~:.~;rq~~~:\: iV',{~mr~~':G~Y~:, :'.- . ~ ¡. ! i~' :~ ," to , to ·~::';':"~~__~~~~~fi,~~c~~·~;¡¿W,i':~~I'/-hi*~t.~:,:,~J :.~;,:~·~¡,.j:¡::;!·,::,~!~.~~~i~,i~.:·A;f¿';~~~~~'t~.~' ..;~,: ':,', ~,' 2~ hour ~c~~m'~'I~tiO~ '~f Ste'e; ~iling~ from p-~~s~m"'~~II~' M~9~~t~:' .., .. ., .. , ' . ~z. . .'i:\ Description of fillings: % Lithology Sltst Sh units _ ppg units _ ppg units _ ppg ~OOmm![ "O! ~~ %LCM Sst Gas during Depth Drill Rate during after before before after 1 Drilling Breaks ft ft ft 'I:~~ ppg ppg ppg Current Lithology: ~ % sltst ~ % sh % % 1.~~RuW:::Ua~~I.I··nu::::r,J[¡ ~¡m 11m -1lI.:C:~, ¡w.;I.1 I.~..III. R .lB_,m_ml1~;;;;~:::'!!;I~CL" Connection Gas and Mud Cut ft _ units ppg ft _ units ppg ft units ppg ft ft ft units units units I, I ppm ppm ft i" ,;"-,'\ '~~~':'ä'~.f.~m-i~í;~>¥,.¡i~;¡.V'~;,:'!S~';¡¡";J ;;~~_;¡t~~r1.'~:-¡~:ii¡*~~::.-QI':a~;.¡;·:'~ì~~· ':,:rll~':">": ~;':'::';" ,'., !.>;;~~J'¡:~~,¡\; ',':'. ;'. t '." '';;~i¡¡¡'' :", ' *.1 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 50000 ",,,.,, - .~. Short Trip Depth ft Short Trip Gas: Mud Cut: _ ppg Short Trip CI: Tight Spots: to to to Feet of Fill on Bottom: .J!;.j;~-:-:'JEI\fl{lt~I'ìœ_I~I]r···fI':'~I~::;KYn'l~ DIll' rll-'·.IW~;_:lr·;¡t'w;;·_~~1 . ~ ... , .!íi 'I' ei [ Bit Size: Hrs. On Bit: I Jets: \ \ \ \ \ TF A: ------ Total Revs on Bit: Footage for Bit Run Bit No.: , Wt On Bit: HTHP ~ Mud Wt at Max Gas ~ppg 8 / 29 / 33 Ibs/100ft2 pH 8.0 Sd 0.2 % Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftIhr 0 ftIhr ( 0 ftlh r @ 0 ) Pump 1 0 spm DH flow Gas~ 0 units 0 unit~ ( 0 units @ 0 ) Pump 2 0 spm Total flow 0 Temp Out 92 Deg F ( 92 deg F @ 16550 ) Pump 3 spm AV @ DP 0 Pump Pres 0 psi A V @ DC 0 I ~ 20 8/3/02 16.550 o Cementing Smith / Clump Type: RPM: "'~'. ",J . ..... ,+/: ,; . .,~~:J:':¡:,"";J~...';,'\;':~L~"'~::;~_~" ~~¡.~~ " ~,;~"'J.J-J".. :".".-~.I,"',t!""~·:)~·"·~~:·'·~"~':'~·'\' ': --- 12.70 ppg 12.70 ppg Mud Wt In Mud Wt Out Visc 51 secs API filt 4.0 ml - - PV 19 cP YI 19 Ibs/1 00ft2 Gel~ Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Shows: Mudlogger's Morning Report BP Alaska NorthStar NS 18 North Slope NorthStar NS 18 Nabors 33E AK AM 22120 .'íi?,¡t;~f;.~f~S'",'·· Customer: Well: Area: Lease: Rig: Job No.: ~-'-'~-" ....-.-.-.---...-..-.-.--.----..--......-..----.........-.....----..-..-. oï=r¡-C L ï--fu..G......'se-A-\Ti-E-es spe...,.....,y- sun Schlumberger BHA# 1 Job # 40007796 Date In 16-Jul-02 Date Out 16-Jul-02 Hole Size 16 I Customer BP ADW Time In 5:30 Time Out 16:30 Hole Sect Surface Well NS-18 Depth In 201 Depth Out 330 Bha Type Steerable Field Northstar TVD In 201 TVD Out 330 Hrs BRT 11.0 I Rig Nabors 33E Drlg Hrs 1.1 Drlg Ft 129 Avg ROP 117 AFE # 831319 Slide Hrs 0.2 Slide Ft 31 Slide ROP 155 DD's Tunnell/Robertson Rot Hrs 0.9 Rot Ft 98 Rot ROP 109 Co. Men PolyaJOinger Pump Hrs 2.0 Rotate % 76 Slide % 24 PDM Run # 1 R/S 5/6 PDM Jet Blk Incl In Azln Bit>Srvy 43.0 PDM Ser# 962-1126 Stages 3.0 Bearing Mud InclOut 0.99 Az Out 296.84 T/F Corr PDM Size 9 9/16 Rev/Gal 0.100 Rubber RM 1000 Avg Dls 0.3 Max Ds 0.6 Plan Dls ( Mud Type Sea H20 Spud Mud Wt 9 Sand % 1 RPM 40 GPM 500 SPP On 320 BHT F Mud Vis 100 Solids % 8 DIg TQ 3.0 WOB 10 SPP Off 300 Item Descriptloll Vendor SIN 00 JD StabOD F.N. Connections Length . Cum Length Bit #1 MX-C1 I TFA=1.031 Hughes 6004904 16 1x12,3x20 75/8 Reg P 1.35 1.35 2 95/8 Std POM 1.83° 7 5/8 Reg B *float* Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6 5/8 H-90 B 26.00 27.35 ( 3 Orienting Sub 6 5/8 H-90 P Ana GLOO-105 8 2 3/4 6 5/8 H-90 B 1.46 28.81 MONEL STAB 6 5/8 H-90 P 4 Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 B 5.49 34.30 'I 5 MONELLC 6 5/8 H-90 P Ana 10-HA-011 8 2 13/16 65/8 H-90 B 9.69 43.99 6 MONEL LC 6 5/8 H-90 P II Ana 10-HA-013 8 1/16 2 13/1 6 6 5/8 H-90 B 9.96 53.95 7 MONEL STAB 65/8 H-90 P Ana HA-016 8 2 7/8 15 7/8 2.35 6 5/8 H-90 B 5.60 59.55 8 X-OVER 65/8 H-90 P [I Ana ANA614 7x8 2 7/8 1.20 41/2 IF B 3.09 62.64 II II I II I \ I II I, I BHA and Run Objective Clean out Con?uctor, I:;;~:;~.: ~:~:..cationí Rát holetopiôk-SHA I, Why POOH / COIlJIl!f'I!'" I :h~~9~~HAIPiC~-"~~~è D~.",~rs._ I 8it To AIM=X', Res=X', GR=X', 0&1=43', PWO=X', Oens=X', Nuet=X' BHA Weight Dry Wt 10,694 Buoyed Wt 9,228 Inel Angle 2 Buoy+lncl Wt 9,222 Bit Data lADe # Footage 129 Hrs 1 .1 k Revs 5 k Grade not graded Comment rerun in next BHA on this well Tool Motor Jars Bit #1 Hrs. In 87.4 0.0 Hrs. Out 89.4 1 ,1 1 .1 2.0 Schlumberger BHA# 2 Job # 40007796 Date In 16-Jul-02 Date Out 19-Jul-02 Hole Size 16 Customer BP ADW Time In 17:00 Time Out 3:00 Hole Sect Surface Well NS-18 Depth In 330 Depth Out 4050 Bha Type Steerable Field Northstar TVD In 330 TVD Out 3217 Hrs BRT 58.0 Rig Nabors 33E Drlg Hrs 25.6 Drlg Ft 3720 Avg ROP 145 AFE # 831319 Slide Hrs 9.5 Slide Ft 1311 Slide ROP 138 DD's Tunnell / Robertson Rot Hrs 16. i Rot Ft 2409 Rot ROP 150 Co. Men Polya / Dinger Pump Hrs 43.4- Rotate % 65 Slide % 35 PDM Run # 2 RlS 5/6 PDM Jet Blk Inclln 0.99 Az In 296.84 Bif>Srvy 67.4 PDM Ser# 962-1126 Stages 3.0 Bearing Mud Incl Out 54.00 Az Out 308.00 T/F Carr 13,0 PDM Size 9 9/16 Rev/Gal 0.100 Rubber RM 1 OOD Avg Dls 2.5 Max Ds 5.1 Plan Dls 2.5 Mud Type Sea H20 Spud Mud Wt 9.1 Sand % 1 RPM 40 GPM 900 SPP On 1900 BHT F 95 Mud Vis 61 Solids % 4.4 DIg TQ 8.0 WOB 20-30 SPP Off 2000 Item De$cl'iption Vendor SIN .00 10 Stab 00 F.N. Connections Length Cum Length Bit #1 MX-C1 TFA=1.031 HUÇJhes 6004904 16 1x12,3x20 7 5/8 Reg P 1.35 1.35 2 9 5/8 Std PDM 1.83° 7 5/8 Reg 8 "float" Ana 962-1126 9 9/16 Tool 15 7/8 1.10 6 5/8 H-90 B 26.00 27.35 r 3 MONEL LC 6 5/8 H-90 P Ana 10-HA-011 8 2 13/16 6 5/8 H-90 8 9.69 37.04 4 MON EL LC 6 5/8 H-90 P Ana 10-HA-013 8 1/16 2 13/16 6 5/8 H-90 8 9.96 47.00 5 MONEL STAB 6 5/8 H-90 P Ana HA-012 8 2 7/8 15 7/8 2.12 65/8 H-90 8 5.25 52.25 6 MWD 6 5/8 H90 P I Ana 173 8 1/4 3 1/4 1.52 6 5/8 H90 B 29.18 81 .43 7 MONEL X-OVER 6 5/8 H90 P Ana LWD S8102 8 1/2 2 13/1 6 6 5/8 FH B 1.41 82.84 8 Down hole filter sub 6 5/8 FH P Ana DFS 838 AK 8 3 3/8 6 5/8 H90 B 2.20 85.04 9 Orienting Sub 6 5/8 H-90 P Ana GLDD-105 8 2 3/4 6 5/8 H-90 B 1.46 86.50 I 10 MONEL STAB 6 5/8 H-90 P Ana HA-016 8 2 7/8 15 7/8 2.35 6 5/8 H-90 B 5.60 92.10 11 MONEL DC 6 5/8 H-90 P Ana 831-021 DC 7 15/16 2 13/16 6 5/8 H-90 B 30.94 123.04 I 12 MONEL DC 6 5/8 H-90 P Ana 831-020DC 8 2 1 3/1 6 6 5/8 H-90 B 31.01 154.05 13 MONEL STAB 6 5/8 H-90 P f Ana HA-009 8 2 7/8 15 7/8 2.38 6 5/8 H-90 B 5.49 159.54 14 MONEL DC 6 5/8 H-90 P corrosion ring Ana 831-012DC 7 7/8 2 7/8 6 5/8 H-90 B 30.58 190.12 15 HYDJARS 6 5/8 H90 P DAILEY 1417-1119 7 1 3/1 6 3 1.69 4 1/2 IF B 31.00 221 . 1 2 16 26 Jts. HWDP 5" 4 1/2 IF P NAD 26 HWDP 5 3 4 1/2 IF 8 786.17 1007.29 17 DP 5" to Surface 4 1/2 IF P NAD OP 5 4 8/29 4 1/2 IF 8 1 007.29 BHA and Run Objective Drill surface with 2.5~/1 00 curve _""''''''_.''0_.__.__'__..''_'_'',_ .'_~M""_".... __ 0.___. .,_"._._ .." __"_'_"__"'_ _.. BHA Weight Dry Wt 71,431 Buoyed Wt 61,530 Incl Angle 56 Buoy+lncl Wt 34,407 Bit Data IADC # 117 Footage 3720 Hrs 25.ô k Revs 177 k Grade 2-3-WT-A-E-I-NO-TD Comment Do not rerun. Tool Motor Jars Bit # 1 HI's. In 89.4 1 .1 1 .1 HI's. Out 132.8 26.7 26.7 43.4 I BHA and Run Results Why POOH / Comments 13.~.~~,~a~~~~.~Oi~~ IBitTo AIM=X', Res=X', GR=65.41', 0&1=67.40', PWO=X', Oens=X', Nuet=X' Schlumberger BHA# 3 Job H 40007796 Date In 20-Jul-02 Date Out 26-Jul-02 Hole Size 1 2 1/4 Customer BP ADW Time In 21 :00 Time Out 23:59 Hole Sect Intermediate Well NS-18 Depth In 4050 Depth Out 14693 Bha Type RSS Field Northstar TVD In 3217 TVD Out 9280 Hrs BRT 147.0 Rig Nabors 33E Drlg Hrs 88.6 Drlg Ft 10643 Avg ROP 120 AFE # 831319 Slide Hrs 0.0 Slide Ft 0 Slide ROP 0 DO's Tunnelll Robertson Rot Hrs 88.6 Rot Ft 10643 Rot ROP 120 Co. Men Kidd/Clump Pump Hrs 118.3 Rotate % 100 Slide % 0 PDM Run H R/S PDM Jet Inclln 54.12 Az In 308.24 Bit>Srvy 59.5 PDM SerH Stages Bearing Incl Out 41.83 Az Out 307.49 T/F Corr PDM Size Rev/Gal Rubber Avg Dls 0.6 Max Ds 1.9 Plan Dls 1.0 ( Mud Type Polymer Mud Wt 10.5 Sand % .2 RPM 150 GPM 900 SPP On 3600 BHT F 154 Mud Vis 55 Solids % 11 Dig TQ 25.0 WOB 15 SPP Off 3600 Item DescrIption Vendor SIN 00 ID Stab. 00 F.N. Connections Length Cum Length #2 RSX238HF+GS I I TFA=.941 Hycaloq 203060 12 1/4 3x11,6x12 6 5/8 Reg P 1.00 1.00 2 PO Bias Unit 6 5/8 Reg B Ana 90073 9 5/16 Tool 1.35 NC 70 B 3.20 4.20 I 3 PO Extention Sub NC 70 P Ana 90051 9 1/4 Tool 7 5/8 Reg P 1.26 5.46 PO Control Collar 7518 Reg B 4 Control Unit 056 Ana CC-90051 9 3/16 Tool 2.36 6518 Reg B 10.14 15.60 5 XO FLOAT SUB 6518 Reg P *float* Ana STFLS-HH-11 í 8 2 13/16 6 5/8 H90 B 1.97 17.57 6 MONEL STAB 6 5/8 H-90 P I Ana HA-019 8 2 7/8 12 3/16 2.36 6 5/8 H-90 B 5.57 23.14 7 COR 6 5/8 H90 P Ana 8039 8 5/16 3 1/4 15.15 6 5/8 FH B 22.82 45.96 8 MWD 6 5/8 FH P Ana 074 8 1/4 3 1/4 1.38 6 5/8 H90 B 27.51 73.47 9 MONEL X-OVER 6 5/8 H90 P Ana LWD SB102 8 1/2 2 13/16 6 518 FH B 1.41 74.88 I 10 Down hole filter sub 6 5/8 FH P Filter Ana DFS 838 AK 8 3 3/8 6 5/8 H90 B 2.20 77.08 11 MONEL STAB 6 5/8 H-90 P * Totco ring * Ana HA-008 8 2 7/8 12 1/4 2.30 6 5/8 H-90 B 5.48 82.56 I I 12 MONEL DC 65/8 H-90 P Ana 831-021 DC 7 15/16 2 13/16 65/8 H-90 B 30.94 113.50 I ~ 13 MONEL DC 6 5/8 H-90 P Ana 831-020DC 8 2 13/1 6 6 5/8 H-90 B 31.01 144.51 14 MONEL STAB 6 5/8 H-90 P I Ana HA-006 8 2 7/8 12 1/4 2.45 6 5/8 H-90 B 5.60 150.11 15 MONEL OC 6 5/8 H·90 P *corrosion ring* Ana 831-012DC 7 7/8 2 7/8 65/8 H·90 B 30.58 180.69 HYOJARS 6 5/8 H90 P I 16 DAILEY 1417-1119 7 13/1 6 3 1.69 4 1/2 IF B 31.00 211.69 II 17 2 Jts HWOP 5" 4 112 IF P NAD 2 HWOP 5 3 4 112 IF B 60.58 272.27 18 21 STO 5" OP 4 112 IF P 21 STOOP 5 4 8/63 4 112 IF B 1983.94 2256.21 II 19 STEL 4 112 IF P STC ES1496 7 1/2 2 7/8 1.73 4 112 IF B 6.41 2262.62 20 Oart Valve Sub 4 112 IF P I BPX CM7996 6 3/4 3 1/8x4 1/2 4 1/2 IF 8 2.37 2264.99 BHA and Run Objective Drill toTO with RSS without BHA Weight Bit Data Tool Hrs. In Hrs. Out la short trip or bit trip. Make 1/10Ü'¡irô'p"tro 5'6-tp'4-Õ"deg~e-es-' Dry Wt 33,151 IADC # Motor 118.3 j BHA and Run Results llõxe~nt: Drilled I<>T[) wi.lt10ut ~ny Buoyed Wt 27,849 Footage 10643 Jars 26.7 115.3 trouble. Tripped to surface without a short trip. Inel Angle 56 Hrs 88.ô Bit#2 0.0 88.ô /WhY POOH/Comments I ...._. Buoy+lnel Wt 15,573 k Revs 797 k RSS 0.0 118.3 Grade 2-0-CT-C-X-I-WT-TO I Bit To I Res=29.22', GR=40.22', PWD=30.97', D&I=59.52',MWD GR=57.53' Comment Job # 40007796 Customer BP ADW Well NS-18 Field Northstar Rig Nabors 33E AFE # 831319 DD's Rinke Co. Men Kidd/ Clump PDM Run # PDM Ser# PDM Size Mud Type Polymer BHT F Item DescrlptlOlJ Bit #3 DS164F+JNW TFA=.663 HycaloÇJ PO Bias Unit Schlumberger I I 2 I PO Extention Sub 3 4 PO Control Collar I 5 X-OVER Float NM STABILIZER 6 I 7 COR (PWD) I I 8 MWD 9 NM XO 'II 10 11 Downhole filter Sub NM STABILIZER Totco Ring NM FLEX NM FLEX NM FLEX X-OVER Corrosion Ring 2 Jts HWDP 5" HYDJARS Dart Valve Sub DP 5" to Surface R/S Stages Rev/Gal Mud Wt 12.9 Mud Vis 21 Vendor SIN 200044 8 1/2 Ana 60285 6 3/4 Ana 631-ES-60162 6 3/4 Ana 60101 6 7/8 Ana AFS301 6 1/2 Ana NMSZSS·FA 011 6 3/4 Ana 7125 6 3/4 Ana 344 6 3/4 Ana LWD-BA-259 6 15/16 Ana CB-028-JS 6 1 3/1 6 Ana IMSZSS-FA-OC 6 3/4 Ana MMFL-FA 027) 11/16x5 1/1 Ana MMFL-FA 025 65/8x5 1/16 Ana MMFL-FA 024) 11 /16x5 1/1 Ana 3TXOS-FE 104: 6 3/4 NAD 2 HWDP 5 DAILEY 1416-1562 6 1/2 BPX CM7996 6 3/4 NAD DP 5 ID 6x12 Tool Tool Tool 2 3/4 2 1 3/1 6 Tool Tool 3 2 3/8 2 13/1 6 2 13/1 6 2 13/16 2 13/16 2 3/4 3 2 3/4 3 1/8x4 1/2 4 8/29 BHA# Date Out 31·Jul·02 Time Out 8:30 Depth Out 15172 TVD Out 9660 Drlg Ft 479 Slide Ft 0 Rot Ft 479 Rotate % 100 Incl In 41.83 Az In 308.24 InclOut 34.75 Az Out 308.89 Avg Dls 1.5 Max Ds 1.7 RPM 150 GPM 540 Dig TQ 23.0 WOB 15 StabOD F.N. Connections 8 1/2 2.45 II 12 13 I, 14 I, :: II 17 18 I 19 I I BHA and Run Objective ~ri~,t~_~ ~~?_hole ~.~'.,~,!~!.'~~_t~riJ~_!__.. BHA Weight Bit Data Tool Hrs.ln Hrs. Out I Dry Wt 21,916 IADC # Motor 20.7 BHA and Run Results Buoyed Wt 17,609 Footage 479 Jars 7.5 I .-.,...._,....,....., Incl Angle 23 Hrs 7.5 Bit #3 7.5 l~hY POOH/Comments IP'O'9,:~f?..~~~~_!~i!.~~~,....___.._ _..._.,____.__ Buoy+lncl Wt 16,210 k Revs 68 k RSS 20.7 Grade Not graded. one chipped cutter, will rerun I Sit To AIM=X', Res=26.46', GR=37.46', 0&1=56.70', MWD GR=54.71' PWD=28.21 I, Dens=X', NU~ommenl Date In 29-Jul-02 Time In 15:30 Depth In 14693 TVD In 9280 Drlg Hrs 7.5 Slide Hrs 0.0 Rot Hrs 7.5 Pump Hrs 20.7 PDM Jet Bearing Rubber Sand % 0 Solids % 18.6 OD' 11.91 1.64 8 1/2 2.42 2.55 2.50 2.53 1.70 4 1/2 Reg P 4 1 /2 Reg B 4 1/2 IF B 4 1/2 IF P 4 1/2 IF P 4 1/2 IF B 4 1/2 IF B 4 1/2 IF P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 5 1/2 FH B 5 1/2 FH P 4 1/2 XH B 4 1/2 XH P 5 1/2 FH B 5 1/2 FH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 41/2XHB 41/2XHP 4 1/2 IF B 4 1/2 IF P 4 1/2 F B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 Hole Size 8 1/2 Hole Sect Intermediate Bha Type Steerable Hrs BRT 41.0 Avg ROP 64 Slide ROP 0 Rot ROP 64 Slide % 0 BibSrvy 56.7 T/F Corr Plan Dls 1.0 SPP On 3450 SPP Off 3450 Length Cum Length 0.85 0.85 2.33 3.18 1.05 4.23 9.90 14.13 1.35 15.48 5.62 21.10 21.87 42.97 27.81 70.78 1.58 72.36 2.76 75.12 5.70 80.82 31.02 111. 84 31.01 142.85 29.50 172.35 1.98 174.33 60.58 234.91 32.62 267.53 2.37 269.90 269.90 I ! 15 I 16 II 17 I t I I BHA and Run Objective D~!~~9.~. ~!3,_~~I,~..!.~' _~.~~!,~~,t~r.~_~~__..__ BHA Weight Bit Data Tool I Dry Wt 21,856 IADC # Motor BHA and Run Results I Excellent. Buoyed Wt 17,561 Footage 1378 Jars I \ ,.,-.--,.....-......-. Incl Angle 23 Hrs 12.3 Bit #3 I Why POOH / Comments I T~_._..... ...______.._.._.___.___...___"_,' Buoy+lncl Wt 16,165 k Revs 111 k RSS Grade 3-0-CT-C-X-I-BF-TD I Bit To AIM=X', Res=26.46', GR=37.46', 0.&1=56.67', MWD GR=54.68' PWD=28.21', Dens=X', NU8IComment ",I~ il 'I Schlumberger I Job # 40007796 Customer BP ADW Well NS-18 Field Northstar Rig Nabors 33E AFE # 831319 OD's Rinke / Robertson Co. Men Smith / Clump PDM Run # PDM Ser# PDM Size Mud Type Polymer BHT F 180 Item Deser/pt/em Bit #3 DS164F+JNW TFA=.663 Hycalog Po. Bias Unit 200044 Date In 31-Jul-02 Time In 11 :30 Depth In 15172 TVD In 9660 Drlg Hrs 12.3 Slide Hrs 0.0 Rot Hrs 12.3 Pump Hrs 35.0 PDM Jet Bearing Rubber Sand % .25 Solids % 5.6 00 R/S Stages Rev/Gal Mud Wt 12.9 Mud Vis 58 Vendor SIN 10 8 1/2 6x12 2 Ana 6 3/4 Tool 60298 I 3 PO Extention Sub Ana 631-ES-60217 6 3/4 4 PO Control Collar Control Unit 234 Ana 60057 6 7/8 5 X-OVER Float Ana AFS301 6 1/2 6 NM STABILIZER Ana NMSZSS·FA 011 6 3/4 7 COR (PWD) Ana 7125 6 3/4 8 MWD Ana MDC-234 6 13/1 6 9 NM STABILIZER Ana IMSZSS-FA-OC 6 3/4 10 NM FLEX Ana MMFL-FA 027) 11/16x5 1/1 11 NM FLEX Ana MMFL-FA 025 6 5/8x5 1/16 12 NM FLEX Ana MMFL-FA 024) 11 /16x5 1/1 13 X-OVER Ana 3TXOS-FE 104: 6 3/4 14 2 Jts HWDP 5" NAD 2 HWDP 5 3 Tool Tool 2 3/4 2 13/16 Tool I Tool 2 13/16 ( 2 13/1 6 2 13/16 I 2 13/1 6 2 3/4 HYDJARS Corrosion Ring Dart Valve Sub DAILEY 6 1/2 2 3/4 1416-1562 BPX 6 3/4 3 1/8x4 1/2 CM7996 DP 5" to Surface NAD DP 5 4 8/29 BHA# Date Out 02-Aug-02 Time Out 22:30 Depth Out 16550 TVD Out 10842 Drlg Ft 1378 Slide Ft 0 Rot Ft 1378 Rotate % 100 Inclln 34.75 Az In 308.89 InclOut 22.70 Az Out 306.38 Avg Dls 1.3 Max Ds 2.1 RPM 150 GPM 550 DIg TQ 24.0 WOB 20 StabOD ,"'.'.. F.N.~ Connections 8 1/2 2.45 4 1/2 Reg P 4 1/2 Reg B 4 1/2 IF B 4 1/2 IF P 4 1/2 IF P 4 1/2 IF B 4 1/2 IF B 4 1/2 IF P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 5 1/2 FH B 51/2 FH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 4 1/2 XH B 4 1/2 XH P 41/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 4 1/2 IF P 4 1/2 IF B 11.91 2.39 8 1/2 2.42 2.55 2.50 2.53 1.70 5 Hole Size 8 1/2 Hole Sect Intermediate Bha Type Steerable Hrs BRT 59.0 Avg ROP 112 Slide ROP 0 Rot ROP 112 Slide % 0 Bit>Srvy 56.7 T/F Corr Plan Dls 1.3 SPP On 3650 SPP Off 3650 Length Cum Length 0.85 0.85 2.32 3.17 1.05 4.22 9.91 14.13 1.35 15.48 5.62 21.10 21.87 42.97 28.51 71 .48 5.70 77.18 31.02 108.20 31.01 139.21 29.50 168.71 1.98 170.69 60.58 231.27 32.62 263.89 2.37 266.26 266.26 Hrs. In Hrs. Out 35.0 19.8 19.8 35.0 7.5 7.5 BHA #: 1 Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF Depth In: 201.00 Inclination In: 0.99 Azimuth In: 296.50 Comments: I Duration Md From I (hr:min) (ftl 0:15 201.00 0:08 230.00 0:10 239.00 0:32 270.00 I ( I NS 18_Bha's.xls Depth Out: 330.00 Inclination Out: 0.99 Azimuth Out: 296.50 Total ROP: 119.1 Md To I RotJSlid I Course I Avg ROPI (ft) (A/S) (ft) (ft/h) 230.00 A 29.00 116.0 239.00 A 9.00 67.5 270.00 S 31.00 186.0 330.00 A 60.00 112.5 Slide Sheet Well: NS18 Borehole: NS18 UWIIAPI#: Tot Distance: 129.;XJ Dist Steering: 31.00 Dist Rotating: 98.00 % Steer: 24.0 % Rot: 76.0 Steering ROP: 186.0 TF (0) I Flow SPP On B SPP Off at WOB I (gaVmin) (~j) (psi) 1(1000 Ibf) 500 310 300 5.0 515 320 300 10.0 515 320 300 10.0 515 320 300 10.0 M250 Page 1 of 1 Directional Driller: James Tunnell Directional Driller: Job #: Total Time: 1.1 Time Steering: 0.2 Time Rotating: 0.9 Rotating ROP: 106.9 RPM trorq On ~ Svy Md I (A) I (ft) 40 3 281.00 40 3 o 0 40 3 % Steer: 15.4 % Rot: 84.6 Incl Azmth I (0) (0) 0.99 296.50 8/28/02-1:35 PM 8/28/02-1 :35 PM Page 1 of 3 NS 1 8_Bha·s.xls BHA #: 2 Slide Sheet r Client: BP Exploration Alaska Well: NS18 Directional Driller: James Tunnell Field: Northstar Borehole: NS18 Directional Driller: Structure: Northstar PF UWVAPI#: Job #: Depth In: 330.00 Depth Out: 4050.00 Tot Distance: 3720.00 Total Time: 25.6 Inclination In: 1.11 Inclination Out: 54.12 Dist Steering: 131 :.ao % Steer: 35.2 Time Steering: 9.5 % Steer: 37.1 Azimuth In: 282.55 Azimuth Out: 308.24 Dist Rotating: 2409,00 % Rot: 64.8 Time Rotating: 16.1 % Rot: 62.9 ( I Total ROP: 145.5 Steering ROP: 138.2 Rotating ROP: 149.8 Comments: I I Duration I Md From I Md To I Rot/Slid I Course I Avg ROP I TF I Flow ISPP On BISPP Off' WOB I RPM forq on, Svy Md I Incl I Azmth I (hr:min) (ft) (ft) (RIS) (ft) (ft/h) (0) (gal/min) icsi) (psi) (1000Ibf) (A) (ft) (0) (0) 0:17 330.00 369.00 R 39.00 137,6 u_ 635 660 620 10.0 40 3 351.00 1.11 282.55 0:33 369.00 459.00 R 90.00 163.6 --- 480 450 400 10.0 40 3 441.00 1.27 284.77 0:15 459.00 489.00 S 30.00 120.0 M 290 490 680 610 10.0 0 0 533.00 1.76 281.26 0:26 489.00 550.00 R 61.00 140.8 --- 635 830 780 15.0 40 5 624.00 2.49 295.11 0:35 550.00 640.00 R 90.00 154.3 n_ 640 620 550 15.0 40 4 660.00 3.16 291.02 0:08 640.00 665.00 5 25.00 187.5 M 310 630 880 830 15.0 0 0 750.00 5.63 296.77 0:09 665.00 685.00 R 20.00 133.3 -.. 625 890 820 20.0 40 5 840.00 7.51 301.00 0:06 685.00 710.00 5 25.00 250.0 M305 650 910 860 10.0 0 0 930.00 9.39 304.20 0:13 710.00 732.00 R 22.00 101.5 -.- 650 950 860 15.0 40 4 1030.00 11. 78 306.19 0:09 732.00 757.00 5 25.00 166.7 M300 ' 650 990 900 20.0 0 0 1121.00 14.02 306.92 0:06 757.00 777.00 R 20.00 200.0 .-- 650 1000 900 20.0 40 5 1218.00 17.12 308.11 0:08 777.00 802.00 ,5 25.00 187.5 M 310 650 1000 900 20.0 0 0 1280.00 18.42 307.73 0:07 802.00 823.00 R 21.00 18"0.0 -., 650 1000 900 20.0 40 5 1310.68 19.07 309.52 0:07 823.00 848.00 5 25.00 214.3 G20 650 1000 900 20.0 0 0 1408.82 21.53 312.58 I 0:07 848.00 873.00 R 25.00 214.3 .-- 640 950 870 15.0 40 4 1501.89 21.44 313.01 0:07 873.00 893.00 5 20.00 171.4 G20 650 1000 900 15.0 0 0 1596.67 22.10 313.43 0:05 893.00 913.00 R 20.00 240.0 -.. 650 1000 900 20.0 40 5 1691.84 23.74 312.27 ( 0:08 913.00 938.00 5 25.00 187.5 GO 650 1000 900 20.0 0 0 1785.67 25.30 311.90 0:06 938.00 958.00 R 20.00 200.0 -.. 650 1000 900 20.0 40 5 1880.95 25.80 313.39 0:06 958.00 983.00 5 25.00 250.0 G 10 650 1000 900 20.0 0 0 1975.10 28.72 310.93 I 0:06 983.00 1004.00 R 21.00 210.0 -.- 650 1000 920 20.0 40 5 2068.71 30.78 309.26 0:08 1004.00 1029.00 S 25.00 187.5 GO 650 1000 930 15.0 0 0 2164.39 34.43 312.22 0:06 1029.00 1049.00 R 20.00 200.0 ... 650 1000 930 20.0 40 3 2260.36 36.14 313.36 0:08 1049.00 1074.00 S 25.00 187.5 GO 650 1000 940 10.0 0 0 2355.46 40.72 310.89 0:06 1074.00 1098.00 R 24.00 240.0 -.- 645 1000 940 20.0 40 4 2451.43 42.96 309.43 0:12 1098.00 1123.00 5 25.00 125.0 GO 650 1100 990 25.0 0 0 2546.90 44.60 307.95 0:13 1123.00 1143.00 R 20.00 92.3 ... 650 1100 990 25.0 40 5 2642.55 47.69 306.65 0:28 1143.00 1168.00 5 25.00 53.6 G 10 660 1090 975 30.0 0 0 2738.43 51.03 306.94 0:12 1168.00 1192.00 R 24.00 120.0 _n 660 1110 975 30.0 40 7 2834.14 55.04 306.59 0:20 1192.00 1218.00 5 26.00 78.0 GO 660 1110 975 30.0 0 0 2927.54 55.90 307.26 0:04 1218.00 1226.00 R 8.00 ..- 720 1300 1200 35.0 40 5 3025.36 56.14 306.26 0:12 1226.00 1253.00 R 27.00 135.0 _n 720 1300 1200 35.0 40 5 3120.67 56.80 306.57 0:13 1253.00 1278.00 5 25.00 115.4 GO 750 1450 1300 35.0 0 ,] 3214.04 56,00 307.00 0:03 1278.00 1287.00 R 9.00 --- 760 1500 1350 35.0 40 5 3309.10 56.61 307.00 0:14 1287,00 1312.00 S 25.00 107,1 GO 760 1500 1350 35.0 0 0 3404.87 56.86 307.64 0:10 1312.00 1337.00 R 25.00 150.0 .n 760 1500 1350 30.0 40 5 3499.43 58.00 308.33 0:10 1337.00 1362.00 5 25.00 150.0 GO 760 1550 1350 38.0 0 ] 3590.25 59,23 308.98 0:10 1362.00 1382.00 A 20,00 120.0 --- 760 1500 1350 35.0 40 S 3685.92 58,01 308.92 0:18 1382.00 1412.00 S 30.00 100.0 G ·20 760 1450 1350 35.0 0 J 3781.29 57,77 308.41 G:26 1412.00 1477.00 A 65.00 150.0 --- 765 1500 1350 30.0 40 5 3876.15 55,29 308.63 0:40 147ì.00 1572.00 A 95.00 142.5 --- 800 1700 1550 30,0 40 5 3975.52 5412 308.24 0:05 1572.00 1592.00 S 20.00 240.0 G ·20 810 1600 1500 25.0 ° J 4050,00 54,12 308.24 8/28/02-1 :35 PM Page 2 of 3 NS 18_Bha's.xls 0:07 1592.00 1622.00 R 30.00 257.1 --- 850 1700 1600 20.0 40 5 0:04 1622.00 1642.00 S 20.00 G ·20 850 1700 1600 25.0 0 0 0:15 1642.00 1668.00 R 26,00 104.0 .-. 850 1700 1600 15.0 40 0:26 1668.00 1763.00 R 95.00 219,2 --- 850 1750 1650 25.0 40 6 0:04 1763.00 1788.00 S 25.00 G ·30 850 1750 1700 20.0 0 0 0:06 1788.00 1813.00 R 25.00 250.0 -.- 850 1750 1700 15.0 40 5 0:04 1813.00 1838.00 S 25.00 G -20 850 1750 1700 20.0 0 0 0:05 1838.00 1857.00 R 19.00 228.0 ... 850 1750 1700 20.0 40 5 0:04 1857.00 1882.00 S 25.00 G ·30 880 1900 1850 20.0 0 0 0:05 1882.00 1907.00 R 25.00 300.0 --- 880 1900 1850 30.0 40 6 0:13 1907,00 1932.00 S 25.00 115.4 G ·30 880 1900 1800 20.0 0 0 0:04 1932.00 1952.00 R 20.00 .-- 880 1900 1850 25.0 40 6 0:08 1952.00 1982.00 S 30.00 225.0 G -20 790 1650 1600 25.0 0 0 0:07 1982.00 2012.00 R 30.00 257.1 ... 880 1950 1850 25.0 40 7 0:07 2012.00 2042.00 S 30.00 257.1 G ·30 880 2000 1850 15.0 0 0 0:02 2042.00 2046.00 R 4.00 _n 880 2000 1850 20.0 40 7 0:08 2046.00 2071.00 S 25.00 187.5 G -10 900 2000 1900 25.0 0 0 0:07 2071.00 2096.00 R 25.00 214.3 _n 900 2000 1900 15.0 40 7 I 0:18 2096.00 2126.00 S 30.00 100.0 G ·10 800 1650 1600 25.0 0 0 0:03 2126.00 2140.00 R 14.00 .n 900 2000 1950 20.0 40 7 0:06 2140.00 2170.00 S 30.00 300.0 GO 900 2050 1950 25.0 0 0 0:05 2170.00 2200.00 R 30.00 360.0 --- 900 2000 1950 15.0 40 7 0:06 2200.00 2230.00 S 30.00 300.0 GO 900 2050 1950 20.0 0 0 0:01 2230.00 2235.00 R 5.00 ... 900 2000 1950 30.0 40 7 I 0:07 2235.00 2265.00 S 30.00 257.1 GO 890 1900 1820 20.0 0 0 0:03 2265.00 2285.00 R 20.00 ... 890 1870 1820 10.0 40 6 0:14 2285.00 2315.00 S 30.00 128.6 G ·20 900 1950 1870 25.0 0 0 0:03 2315.00 2331.00 R 16.00 ... 900 1830 1760 10.0 40 6 I 0:08 2331.00 2361.00 S 30.00 225.0 G ·30 905 1910 1850 20.0 0 0 0:06 2361.00 2381.00 R 20.00 200.0 ... 900 1740 1640 25.0 40 7 0:07 2381.00 2406.00 S 25.00 214.3 G ·30 900 1950 1880 15.0 0 0 0:04 2406.00 2426.00 R 20.00 .n 900 1920 1880 10.0 40 5 I 0:09 2426.00 2446.00 S 20.00 133.3 G·30 900 1960 1880 15.0 0 0 0:09 2446.00 2470.00 R 24.00 160.0 .,. 900 2000 1920 30.0 40 9 0:28 2470.00 2495.00 S 25.00 53.6 G ·30 900 2000 1920 30.0 0 0 0:07 2495.00 2522.00 R 27.00 231.4 ... 900 2000 1920 30.0 40 9 0:21 2522.00 2547.00 S 25.00 71.4 G ·30 900 2050 1910 30.0 0 0 0:04 2547.00 2567.00 R 20.00 -.- 900 2010 1910 25.0 40 6 0:22 2567.00 2597.00 S 30.00 81.8 G ·30 900 1980 1910 30.0 0 0 0:03 2597.00 2618.00 R 21.00 ... 900 1950 1910 5.0 40 6 0:05 2618.00 2648.00 S 30.00 360.0 G ·20 900 2020 1940 15.0 0 0 0:08 2648.00 2668.00 R 20.00 150.0 ." 900 2040 1940 25.0 40 9 0:14 2668.00 2695.00 S 27.00 115.7 G -20 900 2080 1940 30.0 0 0 0:03 2695.00 2713.00 A 18.00 .n 900 1970 1950 10.0 40 8 0:09 2713.00 2743.00 S 30.00 200.0 G ·20 900 2110 2000 30.0 0 0 0:36 2743.00 2763.00 R 20.00 33.3 -.. 900 2000 1930 30.0 40 8 0:31 2763.00 2793.00 S 30.00 58.1 G ·20 900 2040 1960 35.0 0 0 0:08 2793.00 2808.00 R 15.00 112.5 .,. 900 2020 1960 30.0 40 8 0:11 2808.00 2841.00 S 33.00 180.0 G ·20 890 2000 1930 30.0 0 0 0:13 2841.00 2860.00 R 19,00 87.7 --- 900 2000 1930 30.0 40 8 0:08 28ôO.OO 2890.00 S 30.00 225.0 G -20 900 1980 1930 20.0 0 0 0:02 2890.00 2903.00 R 13.00 .,. 900 1960 1930 10.0 40 8 0:39 2903.00 2998.00 A 95.00 146,2 ... 900 2000 1900 35.0 40 8 0:08 2998.00 3018.00 S 20,00 150.0 G -35 890 2020 1890 30.0 0 0 0:25 3018.00 3093.00 A 75,00 180.0 -.- 890 2000 1890 30.0 40 10 0:17 3093.00 3117,00 S 24.00 84.7 G -30 880 2000 1950 35.0 0 0 0:25 3117,00 3188.00 R 71.00 170.4 ... 880 2150 1950 40.0 40 10 8/28/02-1 :35 PM Page 3 of 3 NS 18_Bha's,xls I I I 0:20 3188.00 3283.00 R 95.00 285.0 --- 880 2150 1950 40.0 40 10 0:03 3283.00 3303.00 S 20.00 G -25 900 2000 1900 40.0 0 0 0:28 3303.00 3378.00 R 75.00 160.7 n_ 940 2250 2150 20.0 40 11 0:54 3378.00 3473.00 R 95.00 105.6 -.- 900 2150 1950 30.0 40 12 0:15 3473.00 3567.00 R 94.00 376.0 n. 860 1850 1750 30.0 40 11 0:46 3567.00 3663.00 R 96.00 125.2 .-- 860 1850 1750 40.0 40 12 0:09 3663.00 3693.00 S 30.00 200.0 G -160 860 1800 1700 45.0 0 12 0:13 3693.00 3757.00 R 64.00 295.4 --. 860 1800 1700 40.0 40 12 0:22 3757.00 3778.00 S 21.00 57.3 G 180 860 1850 1700 45.0 0 0 1:00 3778.00 3852.00 R 74.00 74.0 --. 860 1850 1700 40.0 40 11 0:24 3852.00 3882.00 S 30.00 75.0 G 180 860 1800 1700 50.0 0 0 0:51 3882.00 3948.00 R 66.00 77.6 .-- 860 1850 1700 40.0 40 12 1:08 3948.00 4043.00 R 95.00 83.8 --- 860 1900 1800 40.0 40 12 0:07 4043.00 4050.00 R 7.00 60.0 .-- 860 1900 1800 40.0 40 12 8/28/02-1 :35 PM Page 1 of 3 NS 18_Bha·s.xls BHA #: 3 Slide Sheet I Client: BP Exploration Alaska Well: NS18 Directional Driller: James Tunnell Field: Northstar Borehole: NS 18 Directional Driller: Alan robertson Structure: Northstar PF UWVAPI#: Job #: I Depth In: 4050.00 Depth Out: 14693.00 Tot Distance: 106.\.3.00 Total Time: 88.6 Inclination In: 53.45 Inclination Out: 41.83 Dist Steering: 0.00 % Steer: 0.0 Time Steering: 0.0 % Steer: 0.0 Azimuth In: 305.27 Azimuth Out: 307.49 Dist Rotating: 106.\.3.00 % Rot: 100.0 Time Rotating: 88.6 % Rot: 100.0 Total ROP: 120.1 Steering ROP: 0.0 Rotating ROP: 120.1 Comments: Duration Md From Md To Rot/Slid I Course I Avg ROP TF I Flow SPP On B SPP Off , WOB RPM forq on, Svy Md I Incl I Azmth (hr:min) (ft) (ft) (R/S) (ft) (ft/h) (0) (gaVmin) (psi) (psi) (1000Ibf) (A) (ft) (0) (0) 0:05 4050.00 4065.00 A 15.00 180.0 0/0% 850 1550 1550 10.0 80 9 0:03 4065.00 4070.00 A 5.00 700 950 950 10.0 80 9 0:08 4070.00 4097.00 A 27.00 202.5 900 1450 1450 10.0 120 9 I 0:14 4097.00 4160.00 R 63.00 270.0 900 1450 1450 10.0 120 9 0:19 4160.00 4255.00 A 95.00 300.0 900 1450 1450 10.0 120 9 4191.86 53.45 305.27 0:17 4255.00 4351.00 R 96.00 338.8 " 900 1450 1450 10.0 140 9 4287.67 53.34 306.42 0:15 4351.00 4445.00 R 94.00 376.0 · 900 1450 1450 10.0 150 10 4382.39 53.81 305.11 0:17 4445.00 4540.00 A 95.00 335.3 · 900 1500 1500 10.0 130 10 4477.03 53.93 305.49 0:38 4540.00 4635.00 A 95.00 150.0 900 1500 1500 10.0 130 10 4571.59 54.12 303.99 0:19 4635.00 4730.00 R 95.00 300.0 · 900 1500 1500 10.0 130 10 4667.63 54.30 304.83 I 0:18 4730.00 4825.00 A 95.00 316.7 0/20% 900 1500 1500 10.0 130 10 4761.62 53.95 303.90 0:16 4825.00 4920.00 R 95.00 356.3 · 900 1500 1500 10.0 130 11 4856.65 54.31 305.15 0:24 4920.00 5015.00 A 95.00 237.5 · 900 1550 1550 10.0 130 11 4951.25 54.69 306.46 0:23 5015.00 5110.00 R 95.00 247.8 · 900 1550 1550 10.0 130 11 5046.76 55.23 307.19 0:18 5110.00 5205.00 A 95.00 316.7 · 900 1600 1600 10.0 130 11 5142.43 55.56 307.82 0:22 5205.00 5301.00 A 96.00 261.8 · 900 1650 1650 10.0 130 12 5237.81 56.11 308.11 0:16 5301.00 5396.00 A 95.00 356.3 · 900 1650 1650 10.0 130 12 5333.96 56.48 307.86 0:18 5396.00 5493.00 A 97.00 323.3 · 900 1700 1700 10.0 130 12 5429.05 56.89 308.37 0:20 5493.00 5588.00 A 95.00 285.0 · 900 1700 1700 10.0 130 13 5524.61 57.60 309.01 0:16 5588.00 5684.00 A 96.00 360.0 · 900 1700 1700 10.0 150 13 5620.82 58.07 309.31 0:39 5684.00 5779.00 R 95.00 146.2 0/0% 900 1750 1750 10.0 140 13 5716.52 58.46 309.68 0:17 5779.00 5875.00 A 96.00 338.8 · 890 1720 1720 10.0 140 13 5812.50 58.59 309.86 0:16 5875.00 5971.00 A 96.00 360.0 · 900 1750 1750 10.0 160 13 5906.45 58.55 309.30 0:27 5971.00 6065.00 R 94.00 208.9 · 900 1750 1750 10.0 160 13 6001.37 58.48 309.10 0:38 6065.00 6160.00 R 95.00 150.0 · 900 1750 1750 10.0 160 13 6096.84 58.31 309.68 0:24 6160.00 6256.00 R 96.00 240.0 · 900 1750 1750 10.0 160 12 6191.43 58.09 309.60 0:32 6256.00 6351.00 R 95.00 178.1 900 1750 1750 10.0 120 12 6287.48 57.99 310.00 0:47 6351. 00 6447.00 R 96.00 122.6 · 900 1800 1800 10.0 140 13 6382.41 57.78 310.82 0:42 6447.00 6495.00 R 48.00 68.6 900 1800 1800 10.0 150 12 6477.00 58.05 311.01 0:18 6495.00 6542.00 A 47.00 156.7 900 1850 1850 10.0 150 13 0:31 6542.00 6637.00 A 95.00 183.9 900 1850 1850 10.0 150 13 6573.11 58.09 310.95 0:36 6637.00 6732.00 R 95.00 158.3 900 1850 1850 10.0 150 13 6667.77 57,85 310.77 0:48 6732.00 6827,00 A 95.00 118.7 " 900 1900 1900 10.0 150 13 6761.25 57,65 310.29 0:26 6827,00 6922.00 A 95.00 219.2 900 1900 1900 10.0 150 13 6858.23 57.31 311.05 0:16 6922.00 7017.00 A 95.00 356.3 900 1900 1900 5.0 150 14 6953.34 57,27 310.68 0:22 7017.00 7112.00 A 95.00 259.1 254/20% 900 1900 1900 5.0 150 14 7048.34 57,34 310.67 0:20 7112.00 7207.00 A 95.00 285.0 900 1900 1900 8.0 150 15 7142.04 57,44 309.93 0:23 7207,00 7302.00 A 95.00 247.8 900 1900 1900 10.0 150 15 7237.08 57.61 309.9() 0:18 7302,00 7396.00 A 94,00 313.3 248/40o,~ 900 1900 1900 10.0 150 15 7332.53 57,83 309.98 0:30 7396,00 7492,00 R 96.00 192,0 900 1950 1950 10,0 140 15 7428.76 57,93 308,53 0:23 7492,00 7586.00 R 94,00 245.2 900 1950 1950 10.0 140 15 7523.75 58,20 306.79 0:24 7586.00 7682.00 R 96.00 240.0 900 2000 2000 10.0 150 15 7619,07 58,33 305.21 8/28/02-1 :35 PM Page 2 of 3 NS 18_Bha's.xls 0:50 7682.00 7777.00 R 95,00 114,0 900 2050 2050 10.0 150 15 7714,10 58.57 304.62 0:44 7777.00 7874.00 R 97,00 132.3 0/0% 900 2100 2100 10.0 140 16 7810.36 58.21 302.62 0:24 7874,00 7969.00 R 95.00 237.5 900 2100 2100 10.0 140 16 7906.00 58.17 302.96 I 0:37 7969,00 8063.00 R 94,00 152.4 900 2200 2200 10.0 150 16 7998.39 57.94 303.32 1:40 8063.00 8159.00 R 96.00 57.6 900 2200 2200 10.0 150 17 8095,73 57.85 303.53 0:37 8159.00 8254.00 R 95,00 154.1 900 2200 2200 10.0 150 16 8190,23 57.62 303.76 1:03 8254.00 8350.00 R 96.00 91.4 900 2300 2300 10.0 150 16 8286.77 57.80 304.13 0:58 8350.00 8445.00 R 95,00 98.3 71/20% 900 2200 2200 10.0 150 16 8381.33 57.59 304.79 0:53 8445.00 8542.00 R 97.00 109.8 900 2300 2300 10.0 150 16 8478.95 57.15 305.33 0:43 8542.00 8637.00 R 95.00 132.6 900 2380 2380 10.0 150 14 8576.15 56.81 306.29 1 :16 8637.00 8731.00 R 94.00 74.2 36/20% 900 2350 2350 10.0 150 15 8666.77 56.38 305.95 2:39 8731.00 8756.00 R 25.00 9.4 900 2300 2300 10.0 150 15 1:45 8756.00 8827.00 R 71.00 40.6 900 2350 2350 10.0 150 15 8763.65 56.19 308.20 0:28 8827.00 8922.00 R 95.00 203,6 900 2350 2350 10.0 150 15 8858.57 56.19 308.94 1 :36 8922.00 9017.00 R 95.00 59.4 900 2300 2300 10.0 150 15 8953.74 56.12 309.34 1:20 9017.00 9112.00 R 95.00 71.2 0/0% 900 2400 2400 10.0 150 16 9049.24 56.39 310.13 0:38 9112.00 9208.00 R 96.00 151.6 " 900 2400 2400 10.0 150 15 9144.86 56.22 309.26 0:38 9208.00 9303.00 R 95.00 150.0 900 2400 2400 10.0 150 16 9240.02 56.08 309.18 I 0:44 9303.00 9396.00 R 93.00 126.8 II 900 2350 2350 10.0 150 16 9335.64 55.74 309.17 0:43 9396.00 9494.00 R 98.00 136.7 900 2400 2400 10.0 150 16 9431.05 55.39 309.14 1:47 9494.00 9589.00 A 95.00 53.3 " 900 2450 2450 10.0 150 16 9526.50 55.12 309.10 0:32 9589.00 9684.00 A 95.00 178.1 " 900 2400 2400 15.0 150 17 9620.55 54.87 309.37 0:37 9684.00 9779.00 A 95.00 154.1 900 2450 2450 15.0 150 17 9715.38 54.60 308.88 0:36 9779.00 9874.00 A 95.00 158.3 " 900 2450 2450 15.0 150 17 9810.97 54.53 309.09 0:31 9874.00 9969.00 A 95.00 183.9 900 2500 2500 15.0 150 17 9905.17 54.49 309.28 1:02 9969.00 10065.00 A 96.00 92.9 " 900 2500 2500 15.0 150 17 10000.59 54.25 309.16 0:47 10065.00 10160.00 A 95.00 121.3 " 900 2550 2550 15.0 150 17 10096.79 53.92 309.29 1 :16 10160.00 10256.00 A 96.00 75.8 326/20% 880 2600 2600 15.0 150 17 10191.53 53.78 309.47 I 0:41 10256.00 10350.00 A 94.00 137.6 · 900 2650 2650 15.0 150 17 10286.70 54.07 309.11 0:47 10350.00 10446.00 A 96.00 122.6 900 2650 2650 15.0 150 17 10380.99 54.45 309.10 1 :14 10446.00 10539.00 A 93.00 75.4 · 900 2700 2700 15.0 150 17 10476.35 54.83 309.34 1 :02 10539.00 10610.00 A 71.00 68.7 · 900 2770 2770 15.0 150 17 10571.41 55.36 309.71 0:32 10610.00 10635.00 A 25.00 46.9 · 900 2800 2800 15.0 150 17 0:43 10635.00 10729.00 A 94.00 131.2 · 900 2800 2800 15.0 150 18 10666.19 55.75 310.59 0:32 10729.00 10824.00 A 95.00 178.1 · 900 2800 2800 15.0 150 18 10760.77 56.13 310.71 1:36 10824.00 10918.00 A 94.00 58.8 · 900 2800 2800 15.0 150 20 10854.57 56.71 310.84 0:49 10918.00 11013.00 A 95.00 116.3 · 900 2750 2750 15.0 150 20 10947.38 56.97 310.59 0:41 11013.00 11108.00 A 95.00 139.0 900 2950 2950 15.0 150 20 11042.46 57.32 310.97 0:44 11108.00 11203.00 A 95.00 129.5 900 2800 2800 15.0 150 2011139.49 57.59 309.91 0:51 11203.00 11297.00 A 94.00 110.6 · 900 2900 2900 15.0 150 20 11234.43 57.86 310.12 1:00 11297.00 11393.00 A 96.00 96.0 · 900 2950 2950 15.0 150 20 11327.46 58.10 309.49 0:47 11393.00 11488.00 A 95.00 121.3 · 900 3000 3000 15.0 150 20 11425.05 58.30 309.53 0:59 11488.00 11583.00 A 95.00 96.6 900 3000 3000 15.0 150 20 11517.60 58.50 309.79 0:4711583.0011678.00 A 95.00 121.3 217/20% 860 2950 2950 18.0 150 21 11614.52 58.61 309.92 0:41 11678.00 11773.00 A 95.00 139.0 900 3000 3000 18.0 150 21 11711.03 57.93 309.16 0:39 11773.00 11868.00 A 95.00 146.2 · 900 3000 3000 20.0 150 21 11803.31 57.33 308.53 1 :01 11868.00 11963.00 A 95.00 93.4 900 3000 3000 20.0 150 21 11899.19 56.78 307.19 0:43 11963.00 12058.00 A 95.00 132,6 900 3000 3000 20.0 150 21 11994.42 56.20 306.27 0:39 12058.00 12153.00 R 95.00 146.2 900 3050 3050 20,0 150 21 12089.41 55,61 305,45 0:41 12153.00 12247,00 R 94.00 137.6 900 3050 3050 20.0 150 21 12183.86 55.03 305,67 0:53 12247.00 12342.00 R 95.00 107.5 900 3050 3050 20.0 150 21 12278.16 54,24 304,93 0:43 12342.00 12438.00 A 96.00 134.0 0/20% 900 2950 2950 20.0 150 22 12374.44 53.72 305.01 0:40 12438.00 12534.00 A 96.00 144.0 900 3050 3050 20.0 150 21 12470.34 53.82 304,80 0:48 12534,00 12629,00 A 95,00 118,7 900 3050 3050 20,0 150 21 12566.37 53,80 305,01 0:32 12629,00 12682.00 A 53,00 99.4 22/40o~ 900 3050 3050 20.0 150 21 12660.29 53.75 305,38 0:23 12682,00 12725.00 A 43.00 112.2 900 3050 3050 20.0 150 21 0:38 12725,00 12818.00 A 93.00 146.8 900 3000 3000 20.0 150 21 12754.37 53.99 307.03 8/28/02-1 :35 PM Page 3 of 3 NS 18_Bha's.xls I I 0:42 12818.00 12912.00 R 94.00 134.3 900 3150 3150 20.0 150 22 12848.36 54.21 308.43 0:44 12912.00 13007.00 R 95.00 129.5 326/20% 900 3250 3250 20.0 150 22 12941.73 54.17 308.66 0:39 13007.00 13103.00 R 96.00 147.7 900 3200 3200 20.0 150 22 13038.40 54.31 309.03 0:35 13103.00 13198.00 R 95.00 162.9 900 3150 3150 20.0 150 22 13135.16 54.64 309.13 0:47 13198.00 13292.00 R 94.00 120.0 0/0% 870 3150 3150 20.0 150 23 13225.71 54.68 308.99 0:38 13292.00 13389.00 R 97.00 153.2 900 3250 3250 20.0 150 23 13324.37 54,13 309.58 0:40 13389.00 13482.00 R 93.00 139.5 900 3250 3250 20.0 150 23 13419.60 53.23 309,14 0:43 13482.00 13578.00 R 96.00 134.0 900 3200 3200 20.0 150 23 13515.51 52.37 308.69 0:38 13578.00 13673.00 R 95.00 150.0 900 3250 3250 20.0 150 23 13610.21 51.78 308.95 0:42 13673.00 13768.00 R 95.00 135.7 900 3250 3250 20.0 150 23 13706.03 50.93 308.16 0:45 13768.00 13864.00 R 96.00 128.0 870 3050 3050 20.0 150 23 13800.84 50.27 308.44 1:47 13864.00 13960.00 R 96.00 53.8 865 3500 3500 20.0 150 23 13896.70 49.46 308.12 1 :26 13960.00 14055.00 R 95.00 66.3 880 3650 3650 15.0 150 25 13992.58 48.60 308.00 2: 15 14055.00 14150.00 R 95.00 42.2 880 3550 3550 15.0 150 23 14087.22 47.82 309.00 1 :58 14150.00 14245.00 R 95.00 48.3 880 3550 3550 15.0 150 23 14181.94 47.15 308.15 2:04 14245.00 14341.00 R 96.00 46.5 880 3450 3450 20.0 130 25 14277.49 46.31 308.37 1 :32 14341.00 14436.00 R 95.00 62.0 840 3320 3320 18.0 115 25 14373.53 44.90 308.28 1:35 14436.00 14531.00 R 95.00 60.0 326/20% 820 3200 3200 18.0 120 26 14467.82 43.44 308.51 1:19 14531.00 14625.00 R 94.00 71.4 . 840 3450 3450 16.0 120 25 14562.69 42.31 307.76 0:55 14625.00 14693.00 R 68.00 74.2 840 3400 3400 13.0 120 26 8/28/02-1:35 PM Azmth I (0) 306.48 307.49 307.00 308.01 308.44 Incl I (0) 40.74 39.20 37.57 36.26 34.76 % Steer: 0.0 % Rot: 100.0 Page 1 of 1 NS 18_Bha's.xls I I ( ( 23 23 24 150 150 150 15.0 15.0 20.0 3450 3450 3550 3450 3450 3550 540 540 550 87.5 75.0 82.6 35.00 60.00 95.00 R R R 0:24 14982.00 15017.00 0:48 15017.00 15077.00 1 :09 15077.00 15172.00 I Duration I Md From I Md To I Rot/Slid I Course I Avg ROPI TF I Flow ISPP On ,SPP Off' WOB I RPM forq on, Svy Md I (hr:min) (It) (It) (RIS) (It) (It/h) (0) (gal/min) (psi) (psi) (1000 Ibf) (A) (It) 0:03 14693.00 14695.00 R 2.00 --- 480 2950 2950 5.0 100 22 14732.87 1 :44 14695.00 14713.00 R 18.00 10.4 _n 480 2750 2750 20.0 120 21 14828.91 1:02 14713.00 14791.00 R 78.00 75.5 _n 550 3500 3500 15.0 150 23 14924.34 I 1:08 14791.00 14886.00 R 95.00 83.8 _n 540 3450 3450 15.0 150 24 15019.68 1:11 14886.00 14982.00 R 96.00 81.1 _n 540 3450 3450 15.0 150 23 15114.53 Comments: Rotating ROP: 64.0 Steering ROP: 0.0 Total ROP: 64.0 Total Time: 7.5 Time Steering: 0.0 Time Rotating: 7.5 Tot Distance: 479.00 Dist Steering: 0.00 Dist Rotating: 479.00 % Steer: 0.0 % Rot: 100.0 Depth Out: 15172.00 Inclination Out: 34.76 Azimuth Out: 308.44 Depth In: 14693.00 Inclination In: 40.74 Azimuth In: 306.48 Directional Driller: James Tunnell Directional Driller: Alan Robertson Job #: Slide Sheet Well: NS18 Borehole: NS 18 UWVAPI#: Client: BP Exploration Alaska Field: Northstar Structure: Northstar PF I BHA #: 4 " :~ ~ 8/28/02-1 :35 PM Page 1 of 1 NS18_Bha's.xls I BHA #: 5 Slide Sheet Schlumberger I Client: BP Exploration Alaska Well: NS18 Directional Driller: Field: Northstar Borehole: NS 18 Directional Driller: Structure: Northstar PF UWIIAPI#: Job #: I Depth In: 15172.00 Depth Out: 16550.00 Tot Distance: 1378.00 Total Time: 12.3 Inclination In: 34.04 Inclination Out: 22.70 Dist Steering: 0.00 % Steer: 0.0 Time Steering: 0.0 % Steer: 0.0 Azimuth In: 308.82 Azimuth Out: 306.38 Dist Rotating: 1378.00 % Rot: 100.0 Time Rotating: 12.3 % Rot: 100.0 I I Total Rap: 111.7 Steering Rap: 0.0 Rotating Rap: 111.7 Comments: 1 Rot/Slid 1 Duration 1 Md From 1 Md To I Avg ROPI TF 1 Flow ISPP On BI WOB 1 RPM forq on, Svy Md 1 Incl 1 Azmth 1 Comment (RlS) (hr:min) (ft) (ft) (ft/h) (0) (gal/min) (psi) (1000 Ibf) (c/min) K ft/lbs (0) (0) A 1:13 15172.00 15263.00 74.8 --- 550 3650 20.0 150 24 15204,17 34.04 308.82 RSS @ 337/60% A 0:49 15263.00 15359.00 117.6 --- 550 3650 20.0 150 24 15299.96 34.52 308.15 ASS @ 337/60% A 0:45 15359.00 15454.00 126.7 --- 550 3650 20.0 150 24 15394.77 34.92 308.02 ASS @ 337/40% I R 0:44 15454.00 15548.00 128.2 --- 550 3650 20.0 150 24 15488.84 35.04 308.01 ASS @ 337/40% R 0:42 15548.00 15644.00 137.1 --- 550 3650 25.0 150 24 15585.09 35.03 307.35 RSS @ 337/40% R 0:48 15644.00 15740.00 120.0 --- 500 3200 15.0 150 24 15680.74 34.19 306.92 ASS @ 337/40% R 0:57 15740.00 15835.00 100.0 --- 525 3350 15.0 150 24 15774.89 33.66 307.01 ASS @ 337/40% A 0:47 15835.00 15930.00 121.3 --- 512 3220 20.0 150 22 15870.90 32.78 307.30 RSS @ 337/40% R 0:38 15930.00 16025.00 150.0 --- 510 3260 20.0 150 24 15965.00 30.92 307.04 RSS @ 337/40% A 0:36 16025.00 16120.00 158.3 --- 522 3370 25.0 150 22 16059.32 29.05 306.86 RSS @ 337/40% I R 0:44 16120.00 16215.00 129.5 --- 522 3400 22.0 150 24 16155.28 27.61 306.49 ASS @ 337/40% A 0:37 16215.00 16309.00 152.4 --- 522 3400 22.0 150 23 16249.90 25.67 305.46 ASS @ 337/40% R 1:31 16309.00 16403.00 62.0 --- 523 3340 25.0 150 23 16344.38 23.99 305.13 ASS @ 337/40% A 0:51 16403.00 16499.00 112.9 --- 545 3500 25.0 150 23 16439.46 23.43 305.81 ASS @ 337/40% I A 0:38 16499.00 16550.00 80.5 --- 540 3475 25.0 150 24 16488.39 22.70 306.38 ASS @ 337/40% - ,-.-- - --- - ---.: ~ - ,...,...... ,--. ---- ---. ~ ~ - - - ~ Customer: BP EXPLORATION ALASKA Casing Program 20 inch at 201 ft sperry-sun Well: NS18 13 3/8" inch at 4033 ft Area: BEAUFORT SEA,ALASKA 9 5/8" inch at 14668 ft Lease: NORTHST AR 7" inch at 16541 ft DRilliNG SERVICES Rig: NABORS DRLG RIG 33E inch at ft Mud Company: BAROID inch at ft Bit Record Job No.: AK-AM 22120 BHA# Bit Bit Serial Size TFA Depth Depth Feet Hours ROP RPM KREV Slide No. Type Number I" Out ftlhr % GRADE 1 1 MX-C1 600494904 16 1.031 201 330 129 1.1 222 35 5K 24 2 RR1 MX-C1 600494904 16 1.031 330 4050 3921 19.5 169 35 177K 35 2-3WT -A-E-I-NO- TO 3 2 RSX238HF+GS 203060 12.25 0.941 4050 14693 10643 88.6 120 150 797K 2-0-CT -C-X-I-WT - TO 4 3 OS70FNPV 200044 8.5 0.663 14693 15172 479 7.5 64 150 68K 5 RR3 DS70FNPV 200044 8.5 .907 15172 16550 1378 12.3 112 150 111K 3-0-CT-C-X-BF-TD ~ - - - - --- - - -. - - - ~...., ~. Customer: BP ALASKA Casing Program 20" inch at 201 ft sperry-sun Well: NORTHSTAR NS18 13.375" inch at 4033 ft Area: BEAUFORT SEA, ALASKA 9.625" inch at 14668 ft Lease: NORTHSTAR 7" inch at 16541 ft DRilliNG SERVICES Rig: NABORS DRILLING RIG 33E 4.5" inch at ft Mud Company: BAROID DRILLING FLUIDS inch at ft Waterbase Mud Record Job No.: AK-AM 22120 Depth MW Vis PV YP Gels Fltr HTHP Cake Sol Oil Water 5d CEC pH Pm I Pf / Mf Chlorides Calcium Comments Date ft Iblgal sec LB/100 105/10M mU30 ml@deg F 32's % % % % mgelhg ppm ppm Ufl1ö/U~ ö37 6.9 97 19 4ö 1 fl26/26 10.U 2 3.6 U.U 96.4 .75 U.U 6.5 U.UU U.UUlU.25 19UUU 6UU :spua Ufl1 flU2 ~Ö1U 9.~ (2 16 4ö 23/~9/31 9.6 ~ ö.~ 1.U 92.6 1.5 6.U 9.U U.3U U.U5/U.öU 195UU 6UU LJrlIII n 9 U7I16/U2 4U5U 9.1 61 14 3( 1 5/2U/~4 6.6 2 5.5 1.U 93.5 1.U 6.U 6.5 U.5U U.1U/U.6U 19:JUU 66U I U 13316 \,;8g U7I19/U2 4U5U 9.U (5 16 4~ 1U/13/15 11.U ~ 4.~ U.:J 95.3 U.5 4.U 6.U U.1U U.UUIU.3:J 19UUU 6UU '\iement \,;:)l:j . U fI~U/U~ 4U5U 6.( 49 17 23 ö/6/1U 9.2 1 ~.5 U.U 91.5 U.UU U.U 9.2 U.5U U.3U/U.IU 19UUU 9UO "kIH, test \,;8g U fl211U~ ö45U 9.U 59 14 ~6 6/12114 6.ö 1 4.6 1.U 94.~ U.25 4.U 9.U U.35 U.2U/U.65 195UU 96U ùnlllng U7I221U2 675U 9.1 ÖU 15 U 9/13/15 5.6 1 5.5 1.5 93.U U.~5 7.U 9.U U.1U U.U5/U.65 195UU 1UUU ùnlllng U fI~3/U~ 1U6UU 9.~ ÖU 14 31 1211 fI~U 5.2 1 Ö.U 2.U 92.U U.25 6.5 6.ö U.U5 U.UUIU.6U 2U5UU 11UU ûrlllmg U fl24/U~ 12ö75 9.4 56 16 ~5 12116/~U (.6 ~ 7.9 2.5 69.6 U.~5 14.U 6.3 U.UU U.UUIU.öU 195UU 6UU ùrllllng U7/~5IU2 14423 1U.6 55 16 33 15/~7I32 4.6 1U.U ~ 12.U 2.5 65.5 .2U 6.5 8.U U.UU U.U/U.6U 19UUU 660 Ùt<ILLINl:j · o fl26/U~ 14ö93 1U.5 61 19 35 19/~5/35 4.( 1 1~.2 4.U 83.6 .1U 1~.5 (.5 U.UU U.U/U.6U 19UUU 92U poon U6/27/U~ 14ö93 1U.4 53 19 26 16/241U 5.U 1 12.U 4.U 64.U U u.u (.5 U.UU U.U/U.6U 19UUU 66U "kIH, 9 5/6 \,;8g U1I26/U~ 14ö93 1U.2 42 14 21 7111/13 6.2 1 1U.Ö 2.U 61.4 U (.5 (.U U.UU U.UU/1.3U 19UUU 66U "'ug uown \,;mt H U7I~9/U2 14ö93 1U.~ 4~ 14 21 6/11/13 6.~ 1 1U.6 2.U 61.4 U 7.5 7.1 U.UU U.UU/1.3U 19UUU 66U tclH tflt "3 U7I3U/U2 1517~ 12.9 51 ~6 29 11/26/32 4.4 1U.U 1 22.5 2.5 (5.U U 6.5 6.1 U.UU U.UU/2.6U 56UUU 92U ....UUH U7I31 102 15112 12.9 55 ~9 32 1213U/33 3.6 9.6 1 22.5 2.5 75.U U 6.5 6.U U.UU U.UU/2.6U 56UUU 92U "kIH · U6/U1/U~ 1ö39ö 12.6 :JU U 24 12137141 3.5 9.U 1 22.U 3.U (5.U .2U 6.U 6.5 U.1U .U5/2.6U 56UUU 9UU ùrllllng U6/U21U2 1655U 12.7 51 24 ~2 9/35/37 4.U 9.6 1 ~U.5 3.5 (6.U .~5 5.5 6.4 U.UU .U4I2.6U 55UUU 66U "Liu tfHAf#:J U6/U3/U~ 1655U 1~.7 51 19 19 6/~9/33 4.U 9.~ 1 ;ro.5 3.U (6.5 .~U :J.5 6.U U.UU U.UO/U~.6U 5UUUU 66U '\;M I 1" Liner · . - -- - Final Survey NS18.TXT ANADRILL SCHLUMBERGER Survey report 2-Aug-2002 03: 19:24 Page 1 of 7 Client...................: BP Exploration (Alaska) Inc. Field....................: Northstar Wel!.....................: NS18 Spud date................: 16-Jul-2002 API number...............: 50-029-23102-00 Last survey date.........: 02-Aug-02 Engineer.................: Leafstedt / Rathert Total accepted surveys...: 179 MD of first survey.......: 0.00 ft Rig:.....................: Nabors 33E MD of last survey........: 16550.00 ft State:.. ......... ........: Alaska ----- Survey calculatiön methods------------- ----- Geomagnetic data ---------------------- Method for positions.....: Minimum curvature Magnetic modeL.........: BGGM version 2001 Method for DLS...........: Mason & Taylor Magnetic date............: 25-Jul-2002 Magnetic field strength..: 1150.39 HCNT ----- Depth reference ----------------------- Magnetic dec (+EIW- ).....: 26.39 degrees Permanent datum..........: Mean Sea Level Magnetic dip.............: 80.94 degrees Depth reference..........: Drill Floor GL above permanent.......: 15.90 ft KB above permanent....... : Top Drive OF above permanent.......: 55.85 ft ----- D-MAG survey Reference Criteria --------- Reference G..............: 1002.69 mGal Reference H..............: 1150.86 HCNT Reference Dip............: 80.94 degrees ----- Vertical section origin---------------- Tolerance of G...........: (+/-) 2.50 mGal Latitude (+N/S-).........: 0.00 ft Tolerance of H...........: (+/-) 6.00 HCNT Departure (+E/W-)........: 0.00 ft Tolerance of Dip.........: (+/-) 0.45 degrees ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.27 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+EIW-)....: 26.27 degrees 308.16 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 Page 1 Azimuth from rotary table to target: 16 1121.00 14.02 306.92 91.00 1114.96 80.44 42.59 -68.83 80.94 301.75 2.47 GYR 17 1 21 8.00 1 7. 1 2 308.11 97.00 1208.39 106.47 58.46 -89.46 106.87 303.16 3.21 GYR 18 1280.00 18.42 307.73 62.00 1267.43 125.39 70.09 -104.39 125.74 303.88 2.11 GYR 19 1310.68 19.07 309.52 30.68 1296.48 135.25 76.25 -112.09 135.56 304.22 2.83 D-MAG 20 1408.82 21.53 312.58 98.14 1388.52 169.23 98.64 -137.72 169.40 305.61 2.73 D-MAG Page 2 6 281 .00 0.99 296.50 119.00 280.99 1.78 1.62 -0.99 1.90 328.51 0.67 GYR 7 351.00 1 .11 282.55 70.00 350.98 2.98 2.04 -2.19 2.99 312.85 0.40 GYR 8 441.00 1.27 284.77 90.00 440.96 4.68 2.48 -4.01 4.71 301.73 0.18 GYR 9 533.00 1.76 281.26 92.00 532.93 6.88 3.01 -6.38 7.06 295.29 0.54 GYR 10 624.00 2.49 295.11 91.00 623.86 10.05 4.13 -9.54 10.40 293.39 0.98 GYR 11 660.00 3.16 291.02 36.00 659.82 11.76 4.81 -11.18 12.17 293.30 1.94 GYR 12 750.00 5.63 296.77 90.00 749.55 18.46 7.69 -17.43 19.06 293.81 2.78 GYR 13 840.00 7.51 301.00 90.00 838.95 28.63 12.71 -26.42 29.32 295.69 2.16 GYR 14 930.00 9.39 304.20 90.00 927.97 41.79 19.87 -37.53 42.47 297.89 2.15 GYR 15 1030.00 11.78 306.19 100.00 1026.26 60.13 30.48 -52.52 60.72 300.13 2.42 GYR 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 50.00 0.31 38.86 50.00 50.00 -0.00 0.11 0.08 0.14 38.86 0.62 GYR 3 100.00 0.33 342.08 50.00 100.00 0.12 0.35 0.13 0.37 19.84 0.61 GYR 4 150.00 0.37 344.64 50.00 150.00 0.37 0.64 0.04 0.64 3.43 0.09 GYR 5 162.00 0.43 348.38 12.00 162.00 0.43 0.72 0.02 0.72 1.51 0.55 GYR --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Page 2 of 7 2-Aug-2002 03:19:24 [(c)2002 AnadrilllDEAL 106_1 C_10] ANADRILL SCHLUMBERGER Survey Report ** All surveys with tool type liD-MAGI! are corrected for Drillstring Magnetism ** Final Survey NS18.TXT - - - 31 2451.43 42.96·309.43 95.97 2292.00 674.05 435.99 -514.65 674.51 310.27 2.55 D-MAG 32 2546.90 44.60 307.95 95.47 2360.92 740.09 477.27 -566.21 740.53 310.13 2.03 D-MAG 33 2642.55 47.69 306.65 95.65 2427.19 809.05 519.05 -621.08 809.42 309.89 3.38 D-MAG 34 2738.43 51 .03 306.94 95.88 2489.63 881.77 562.62 -679.33 882.06 309.63 3.49 D-MAG 35 2834.14 55.04 306.59 95.71 2547.17 958.21 608.38 -740.59 958.43 309.40 4.20 D-MAG 36 2927.54 55.90 307.26 93.40 2600.11 1035.13 654.61 -802.10 1035.31 309.22 1.09 D-MAG 37 3025.36 56.14 306.26 97.82 2654.78 1116.22 703.15 -867.08 1116.35 309.04 0.88 D-MAG 38 3120.67 56.80 306.57 95.31 2707.43 1195.64 750.31 -931.02 1195.73 308.87 0.74 D-MAG 39 3214.04 56.00 307.00 93.37 2759.10 1273.38 796.88 -993.30 1273.45 308.74 0.94 D-MAG 40 3309.10 56.61 307.00 95.06 2811.83 1352.46 844.48-1056.47 1352.50 308.64 0.64D-MAG 41 3404.87 56.86 307.64 95.77 2864.37 1432.52 893.03 -1120.15 1432.56 308.56 0.62 D-MAG Page 3 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (tt) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100t) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Page 3 of 7 2-Aug-2002 03: 1 9:24 [(c)2002 AnadrilllDEAL ID6_1 C_1 0] ANADRILL SCHLUMBÈRGER Survey Report Final Survey NS18.TXT 21 1501.89 21.44 313.01 93.07 1475.13 203.21 121.79 -162.74 203.27 306.81 0.19 D-MAG 22 1596.67 22.10 313.43 94.78 1563.15 238.22 145.87 -188.35 238.23 307.76 0.72 D-MAG 23 1691.84 23.74 312.27 95.17 1650.80 275.16 171.06 -215.53 275.16 308.44 1.79 D-MAG 24 1785.67 25.30 311.90 93.83 1736.17 314.01 197.16 -244.43 314.04 308.89 1 .67 D-MAG 25 1880.95 25.80 313.39 95.28 1822.13 354.97 225.00 -274.65 355.05 309.32 0.85 D-MAG 26 1975.10 28.72 310.93 94.15 1905.82 397.98 253.90 -306.64 398.11 309.62 3.32 D-MAG 27 2068.71 30.78 309.26 93.61 1987.09 444.40 283.80 -342.18 444.56 309.67 2.37 D-MAG 28 2164.39 34.43 312.22 95.68 2067.68 495.88 317.48 -381.19 496.08 309.79 4.16 D-MAG 29 2260.36 36.14 313.36 95.97 2146.02 551.13 355.14 -421.86 551.44 310.09 1.91 D-MAG 30 2355.46 40.72 310.89 95.10 2220.50 610.08 394.73 -465.72 610.50 310.28 5.08 D-MAG - - - - 61 5429.05 56.89 308.37 95.09 4015.55 3095.39 1891.16 -2450.66 3095.51 307.66 0.62 D-MAG 62 5524.61 57.60 309.01 95.56 4067.25 3175.76 1941.40 -2513.38 3175.86 307.68 0.93 D-MAG Page 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +EJW- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 1 DOt) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Page 4 of 7 2-Aug-2002 03:19:24 [(c)2002 AnadrilllDEAL ID6_1 C_10] ANADRILL SCHLUMBERGER Survey Report Final Survey NS18.TXT 42 3499.43 58.00 308.33 94.56 2915.27 1512.21 942.07 -1182.95 1512.24 308.53 1.35 D-MAG 43 3590.25 59.23 308.98 90.82 2962.57 1589.74 990.50 -1243.50 1589.77 308.54 1.49 D-MAG 44 3685.92 58.01 308.92 95.67 3012.38 1671.40 1041.85-1307.01 1671.44 308.56 1.28 D-MAG 45 3781.29 57.77 308.41 95.37 3063.08 1752.18 1092.32 -1370.09 1752.23 308.56 0.52 D-MAG 46 3876.15 55.29 308.63 94.86 3115.39 1831.30 1141.59 -1431.99 1831.35 308.56 2.62 D-MAG 47 3975.52 54.12 308.24 99.37 3172.80 1912.41 1192.01-1495.52 1912.45 308.56 1.22 D-MAG 48 4191.86 53.45 305.27 216.34 3300.64 2086.86 1296.45 -1635.33 2086.88 308.41 1.15 D-MAG 49 4287.67 53.34 306.42 95.81 3357.77 2163.71 1341.49 -1697.67 2163.72 308.32 0.97 D-MAG 50 4382.39 53.81 305.11 94.72 3414.01 2239.86 1386.03 -1759.51 2239.86 308.23 1.22 D-MAG 51 4477.03 53.93 305.49 94.64 3469.81 2316.20 1430.20 -1821.90 2316.20 308.13 0.35 D-MAG 52 4571.59 54.12 303.99 94.56 3525.36 2392.59 1473.80-1884.78 2392.59 308.02 1.30 D-MAG 53 4667.63 54.30 304.83 96.04 3581.53 2470.32 1517.83 -1949.05 2470.35 307.91 0.73 D-MAG 54 4761.62 53.95 303.90 93.99 3636.61 2546.31 1560.82 -2011.92 2546.36 307.80 0.88 D-MAG 55 4856.65 54.31 305.15 95.03 3692.30 2623.16 1604.46 -2075.36 2623.24 307.71 1.13 D-MAG 56 4951.25 54.69 306.46 94.60 3747.23 2700.11 1649.52-2137.81 2700.22 307.65 1.20 D-MAG 57 5046.76 55.23 307.19 95.51 3802.07 2778.29 1696.39 -2200.41 2778.41 307.63 0.84 D-MAG 58 5142.43 55.56 307.82 95.67 3856.40 2857.03 1744.33 -2262.88 2857.15 307.63 0.64 D-MAG 59 5237.81 56.11 308.11 95.38 3909.96 2935.94 1792.88 -2325.09 2936.07 307.64 0.63 D-MAG 60 5333.96 56.48 307.86 96.15 3963.32 3015.93 1842.11 -2388.14 3016.05 307.65 0.44 D-MAG - - ~ -- Page 5 [(c)2002 AnadrilllOEAL 106_1 C_1 0] Final Survey NS18.TXT 63 5620.82 58.07 309.31 96.21 4118.47 3257.19 1992.83 -2576.53 3257.28 307.72 0.56 D-MAG 64 5716.52 58.46 309.68 95.70 4168.81 3338.56 2044.59 -2639.34 3338.64 307.76 0.52 D-MAG 65 5812.50 58.59 309.86 95.98 4218.92 3420.38 2096.96 -2702.26 3420.44 307.81 0.21 D-MAG 66 5906.45 58.55 309.30 93.95 4267.91 3500.52 2148.04 -2764.04 3500.57 307.85 0.51 D-MAG 67 6001.37 58.48 309.10 94.92 4317.48 3581.45 2199.20 -2826.77 3581.50 307.88 0.19 D-MAG 68 6096.84 58.31 309.68 95.47 4367.52 3662.74 2250.80 -2889.61 3662.78 307.92 0.55 D-MAG 69 6191.43 58.09 309.60 94.59 4417.36 3743.11 2302.08-2951.52 3743.13 307.95 0.24 D-MAG 70 6287.48 57.99 310.00 96.05 4468.20 3824.57 2354.24 -3014.13 3824.58 307.99 0.37 D-MAG 71 6382.41 57.78 310.82 94.93 4518.67 3904.91 2406.37 -3075.35 3904.92 308.04 0.76 D-MAG 72 6477.00 58.05 311.01 94.59 4568.92 3984.96 2458.85 -3135.91 3984.96 308.10 0.33 D-MAG 73 6573.11 58.09 310.95 96.11 4619.75 4066.43 2512.35 -3197.49 4066.43 308.16 0.07 D-MAG 74 6667.77 57.85 310.77 94.66 4669.95 4146.59 2564.85 -3258.18 4146.59 308.21 0.30 D-MAG 75 6761.25 57.65 310.29 93.48 4719.83 4225.58 2616.22 -3318.27 4225.58 308.25 0.48 D-MAG 76 6858.23 57.31 311.05 96.98 4771.97 4307.27 2669.51 -3380.29 4307.28 308.30 0.75 D-MAG 77 6953.34 57.27 310.68 95.11 4823.37 4387.21 2721.87 -3440.82 4387.23 308.35 0.33 D-MAG 78 7048.34 57.34 310.67 95.00 4874.68 4467.08 2773.98 -3501.45 4467.12 308.39 0.07 D-MAG 79 7142.04 57.44 309.93 93.70 4925.18 4545.95 2825.03 -3561.65 4546.00 308.42 0.67 D-MAG 80 7237.08 57.61 309.90 95.04 4976.21 4626.09 2876.48 -3623.14 4626.15 308.45 0.18 D-MAG 81 7332.53 57.83 309.98 95.45 5027.18 4706.75 2928.28 -3685.01 4706.82 308.47 0.24 D-MAG 82 7428.76 57.93 308.53 96.23 5078.35 4788.23 2979.85 -3748.12 4788.31 308.49 1.28 D-MAG 83 7523.75 58.20 306.79 94.99 5128.60 4868.84 3029.10-3811.94 4868.91 308.47 1.58 D-MAG 84 7619.07 58.33 305.21 95.32 5178.74 4949.85 3076.75 -3877.52 4949.90 308.43 1.42 D-MAG 85 7714.10 58.57 304.62 95.03 5228.46 5030.70 3123.10 -3943.93 5030.73 308.37 0.59 D-MAG 86 7810.36 58.21 302.62 96.26 5278.92 5112.41 3168.49-4012.18 5112.43 308.30 1.81 D-MAG 87 7906.00 58.17 302.96 95.64 5329.33 5193.33 3212.50 -4080.51 5193.33 308.21 0.30 D-MAG 88 7998.39 57.94 303.32 92.39 5378.22 5271.43 3255.36 -4146.15 5271.43 308.14 0.41 D-MAG 89 8095.73 57.85 303.53 97.34 5429.95 5353.60 3300.78 -4214.97 5353.61 308.06 0.20 D-MAG 90 8190.23 57.62 303.76 94.50 5480.40 5433.26 3345.05 -4281.49 5433.28 308.00 0.32 D-MAG -- - -- 101 9240.02 56.08 309.18 95.16 6056.71 6309.91 3874.53 -4980.35 6309.99 307.88 0.16 D-MAG 102 9335.64 55.74 309.17 95.62 6110.30 6389.09 3924.56 -5041.74 6389.15 307.90 0.36 D-MAG 103 9431.05 55.39 309.14 95.41 6164.25 6467.77 3974.24 -5102.76 6467.83 307.91 0.37 D-MAG 104 9526.50 55.12 309.10 95.45 6218.65 6546.19 4023.73 -5163.61 6546.24 307.93 0.28 D-MAG 105 9620.55 54.87 309.37 94.05 6272.61 6623.21 4072.46 -5223.28 6623.26 307.94 0.35 D-MAG 106 9715.38 54.60 308.88 94.83 6327.36 6700.63 4121.31 -5283.34 6700.67 307.96 0.51 D-MAG 107 9810.97 54.53 309.09 95.59 6382.78 6778.50 4170.31 -5343.88 6778.54 307.97 0.19 D-MAG 108 9905.17 54.49 309.28 94.20 6437.47 6855.19 4218.77 -5403.33 6855.22 307.98 0.17 D-MAG 109 10000.59 54.25 309.16 95.42 6493.05 6932.73 4267.81 -5463.42 6932.76 308.00 0.27 D-MAG 110 10096.79 53.92 309.29 96.20 6549.48 7010.63 4317.08 -5523.78 7010.65 308.01 0.36 D-MAG 111 10191.53 53.78 309.47 94.74 6605.37 7087.11 4365.62 -5582.91 7087.13 308.02 0.21 D-MAG 112 10286.70 54.07 309.11 95.17 6661.41 7164.02 4414.33 -5642.44 7164.03 308.04 0.43 D-MAG 113 10380.99 54.45 309.10 94.29 6716.49 7240.54 4462.60 -5701.83 7240.55 308.05 0.40 D-MAG 114 10476.35 54.83 309.34 95.36 6771.67 7318.30 4511.77 -5762.08 7318.31 308.06 0.45 D-MAG 115 10571.41 55.36 309.71 95.06 6826.07 7396.23 4561.39 -5822.21 7396.24 308.08 0.64 D-MAG Page 6 96 8763.65 56.19 308.20 96.88 5791.78 5914.09 3623.93 -4673.88 5914.22 307.79 1.94 D-MAG 97 8858.57 56.19 308.94 94.92 5844.60 5992.96 3673.10-4735.54 5993.08 307.80 0.65 D-MAG 98 8953.74 56.12 309.34 95.17 5897.60 6071.99 3722.99 -4796.85 6072.10 307.82 0.36 D-MAG 99 9049.24 56.39 310.13 95.50 5950.66 6151.37 3773.75 -4857.91 6151.46 307.84 0.74 D-MAG 100 9144.86 56.22 309.26 95.62 6003.70 6230.90 3824.56 -4919.13 6230.98 307.86 0.78 D-MAG 91 8286.77 57.80 304.13 96.54 5531.97 5514.65 3390.63 -4349.19 5514.69 307.94 0.37 D-MAG 92 8381.33 57.59 304.79 94.56 5582.50 5594.41 3435.85 -4415.09 5594.47 307.89 0.63 D-MAG 93 8478.95 57.15 305.33 97.62 5635.14 5676.50 3483.07 -4482.39 5676.58 307.85 0.65 D-MAG 94 8576.15 56.81 306.29 97.20 5688.11 5757.93 3530.76 -4548.48 5758.03 307.82 0.90 D-MAG 95 8666.77 56.38 305.95 90.62 5738.00 5833.53 3575.35 -4609.59 5833.65 307.80 0.57 D-MAG --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Page 5 of 7 Final Survey NS18.TXT 2-Aug-2002 03: 1 9:24 ANADRILL SCHLUMBERGER Survey Report - - - ,.-- 121 11139.49 57.59 309.91 97.03 7139.07 7869.82 4869.77 -6182.20 7869.83 308.23 0.96 D-MAG 122 11234.43 57.86 310.12 94.94 7189.77 7950.05 4921.38-6243.68 7950.06 308.25 0.34 D-MAG 123 11327.46 58.10 309.49 93.03 7239.10 8028.90 4971.87 -6304.27 8028.91 308.26 0.63 D-MAG 124 11425.05 58.30 309.53 97.59 7290.52 8111.81 5024.64 -6368.26 8111.83 308.27 0.21 D-MAG 125 11517.60 58.50 309.79 92.55 7339.02 8190.61 5074.95 -6428.95 8190.63 308.29 0.32 D-MAG 126 11614.52 58.61 309.92 96.92 7389.58 8273.26 5127.94 -6492.42 8273.29 308.30 0.16 D-MAG 127 11711.03 57.93 309.16 96.51 7440.33 8355.33 5180.20 -6555.72 8355.36 308.32 0.97 D-MAG 128 11803.31 57.33 308.53 92.28 7489.74 8433.26 5229.08 -6616.42 8433.29 308.32 0.87 D-MAG 129 11899.19 56.78 307.19 95.88 7541.88 8513.72 5278.47-6679.95 8513.75 308.32 1.31 D-MAG 130 11994.42 56.20 306.27 95.23 7594.46 8593.09 5325.95 -6743.58 8593.12 308.30 1.01 D-MAG 131 12089.41 55.61 305.45 94.99 7647.71 8671.69 5372.04 -6807.33 8671.71 308.28 0.95 D-MAG 132 12183.86 55.03 305.67 94.45 7701.45 8749.28 5417.20 -6870.52 8749.29 308.25 0.64 D-MAG 133 12278.16 54.24 304.93 94.30 7756.03 8826.08 5461.64 -6933.27 8826.09 308.23 1.05 D-MAG 134 12374.44 53.72 305.01 96.28 7812.65 8903.83 5506.27 -6997.09 8903.84 308.20 0.54 D-MAG 135 12470.34 53.82 304.80 95.90 7869.33 8981.07 5550.54 -7060.53 8981.07 308.17 0.21 D-MAG Page 7 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVO Vertical Oispl Oispl Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (tt) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Page 6 of 7 2-Aug-2002 03: 19:24 [(c)2002 AnadrilllDEAL 106_1 C_1 0] ANADRILL SCHLUMBERGER Survey Report 116 10666.19 55.75 310.59 94.78 6879.68 7474.35 4611.78-5881.95 7474.35 308.10 0.87 D-MAG 117 10760.77 56.13 310.71 94.58 6932.65 7552.63 4662.83 -5941.40 7552.63 308.12 0.42 D-MAG 118 10854.57 56.71 310.84 93.80 6984.53 7630.69 4713.86 -6000.58 7630.69 308.15 0.63 D-MAG 119 10947.38 56.97 310.59 92.81 7035.29 7708.31 4764.54 -6059.47 7708.31 308.18 0.36 O-MAG 120 11042.46 57.32 310.97 95.08 7086.87 7788.10 4816.71 -6119.95 7788.10 308.20 0.50 O-MAG Final Survey NS18.TXT .- -~--'---" - - 'I - - - - 151 13992.58 48.60 308.00 95.88 8786.54 10194.71 6298.96 -8015.9310194.71 308.16 0.90 D-MAG 152 14087.22 47.82 309.00 94.64 8849.61 10265.27 6342.88 -8071.16 10265.27 308.16 1.14 D-MAG 153 14181.94 47.15 308.15 94.72 8913.62 10335.08 6386.42 -8125.7410335.08 308.17 0.97 D-MAG 154 14277.49 46.31 308.37 95.55 8979.11 10404.65 6429.50 -8180.37 10404.65 308.17 0.89 D-MAG 155 14373.53 44.90 308.28 96.04 9046.30 10473.28 6472.05 -8234.20 10473.28 308.17 1.47 D-MAG 156 14467.82 43.44 308.51 94.29 9113.93 10538.97 6512.86 -8285.69 10538.97 308.17 1.56 D-MAG Page 8 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Seq Measured Incl Azimuth Course TVD Vertical Oispl Oispl Total At OLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ---- Page 7 of 7 2-Aug-2002 03:19:24 [(c)2002 AnadrilllDEAL 106_1 C_1 0] ANADRILL SCHLUMBERGER Survey Report Final Survey NS18.TXT 136 12566.37 53.80 305.01 96.03 7926.03 9058.44 5594.89 -7124.09 9058.44 308.14 0.18 D-MAG 137 12660.29 53.75 305.38 93.92 7981.53 9134.11 5638.56 -7186.00 9134.11 308.12 0.32 D-MAG 138 12754.37 53.99 307.03 94.08 8037.01 9210.05 5683.44 -7247.31 9210.05 308.10 1.44 D-MAG 139 12848.36 54.21 308.43 93.99 8092.12 9286.18 5730.03 -7307.53 9286.18 308.10 1.23 D-MAG 140 12941.73 54.17 308.66 93.37 8146.75 9361.89 5777.21 -7366.75 9361.90 308.10 0.20 D-MAG 141 13038.40 54.31 309.03 96.67 8203.25 9440.33 5826.41 -7427.84 9440.34 308.11 0.34 D-MAG 142 13135.16 54.64 309.13 96.76 8259.47 9519.07 5876.06-7488.97 9519.07 308.12 0.35D-MAG 143 13225.71 54.68 308.99 90.55 8311.84 9592.93 5922.60 -7546.33 9592.93 308.13 0.13 D-MAG 144 13324.37 54.13 309.58 98.66 8369.27 9673.14 5973.40 -7608.42 9673.14 308.14 0.74 D-MAG 145 13419.60 53.23 309.14 95.23 8425.67 9749.85 6022.06-7667.75 9749.85 308.15 1.02 D-MAG 146 13515.51 52.37 308.69 95.91 8483.66 9826.23 6070.05 -7727.19 9826.23 308.15 0.97 D-MAG 147 13610.21 51.78 308.95 94.70 8541.87 9900.93 6116.88-7785.39 9900.93 308.16 0.66 D-MAG 148 13706.03 50.93 308.16 95.82 8601.71 9975.77 6163.52 -7843.91 9975.77 308.16 1.10 D-MAG 149 13800.84 50.27308.44 94.81 8661.88 10049.03 6208.93 -7901.40 10049.03 308.16 0.73 D-MAG 150 13896.70 49.46 308.12 95.86 8723.67 10122.31 6254.33 -7958.9310122.31 308.16 0.88 D-MAG ~ - - - Page 9 [(c)2002 AnadrilllOEAL 106_1 C_1 0] Survey Projected to TO 179 16550.00 22.70 306.38 61.61 10841.97 11682.38 7205.61 -9195.52 11682.39 308.08 0.00 PROJ 176 16344.38 23.99 305.13 94.48 10653.06 11601.27 7158.03 -9129.75 11601 .28 308.10 1.78 O-MAG 177 16439.46 23.43 305.81 95.08 10740.12 11639.46 7180.21 -9160.89 11639.47 308.09 0.66 O-MAG 178 16488.39 22.70 306.38 48.93 10785.14 11658.62 7191.50 -9176.38 11658.63 308.09 1.56 O-MAG 171 15870.90 32.78 307.30 96.01 10236.68 11376.93 7024.62 -8949.2711376.94 308.13 0.93 O-MAG 172 15965.96 30.92 307.04 95.06 10317.42 11427.09 7054.92 -8989.2411427.09 308.13 1.96 O-MAG 173 16059.32 29.05 306.86 93.36 10398.28 11473.73 7082.97 -9026.5211473.74 308.12 2.01 O-MAG 174 16155.28 27.61 306.49 95.96 10482.75 11519.25 7110.17 -9063.0411519.26 308.12 1.51 O-MAG 175 16249.90 25.67 305.46 94.62 10567.32 11561.65 7135.10-9097.3711561.65 308.11 2.11 O-MAG 166 15394.77 34.92 308.02 94.81 9843.63 11108.316861.46-8735.8411108.31308.15 0.430-MAG 167 15488.84 35.04 308.01 94.07 9920.71 11162.24 6894.67 -8778.33 11162.24 308.15 0.13 O-MAG 168 15585.09 35.03 307.35 96.25 9999.51 11217.49 6928.45 -8822.0611217.49 308.14 0.39 O-MAG 169 15680.74 34.19 306.93 95.65 10078.24 11271.81 6961.25 -8865.37 11271.81 308.14 0.91 O-MAG 170 15774.89 33.66 307.01 94.15 10156.36 11324.34 6992.85 -8907.3511324.34 308.13 0.56 O-MAG 161 14924.34 37.57 307.00 95.43 9459.15 10837.37 6694.02 -8522.8310837.37 308.15 1.74 O-MAG 162 15019.68 36.26 308.01 95.34 9535.38 10894.63 6728.88 -8568.26 10894.63 308.14 1.51 O-MAG 163 15114.53 34.76 308.44 94.85 9612.59 10949.72 6762.96-8611.5410949.72 308.14 1.600-MAG 164 15204.17 34.04 308.82 89.64 9686.55 11000.36 6794.58 -8651.10 11000.36 308.15 0.84 O-MAG 165 15299.96 34.52 308.16 95.79 9765.70 11054.31 6828.15 -8693.3411054.31 308.15 0.64 D-MAG Final Survey NS18.TXT 157 14562.69 42.31 307.76 94.87 9183.45 10603.52 6552.72 -8336.4610603.52 308.17 1.31 O-MAG 158 14626.58 41.83 307.49 63.89 9230.88 10646.33 6578.85 -8370.3710646.33 308.17 0.80 D-MAG 159 14732.87 40.74 306.48 106.29 9310.75 10716.44 6621.05 -8426.3810716.44 308.16 1.20 O-MAG 160 14828.91 39.20 307.49 96.04 9384.35 10778.12 6658.15 -8475.6610778.12 308.15 1.74 O-MAG ~ - - - NS18 Formation Top Permafrost Base Permafrost SV6 - top confining zone Surface casing point SV5 - base confming zone SV4 SV2 - top upper injection zone SVl - top major shale barrier TMBK - top lower injection zone - Top Ugnu WSl - top Schrader Bluff - Base Ugnu CM3 - Base lower injection zone (top Colville) Fault "26" - throw = 75' THRZ - Top HRZ BHRZ - Base HRZ Top Kuparuk Kuparuk C Top Miluveach Intermediate casing point Intermediate logging point Top Kingak Unmapped fault - throw = 30' Top Sag River Geol target #1 Intermediate casing point Current Depth Top Shublik - 90 Top Ivishak Total Depth Oil - Water contact Top Kavik - --~-----!- ~j Prognosed Tops TVDss I TVDrkb I MDrkb 1,149 1206 1209 1,519 1576 1598 3,002 3059 3777 3,150 3207 4046 3,250 3320 4227 3,554 3611 4777 3,955 4012 5504 4,425 4482 6355 4,697 4754 6848 6,232 6289 9629 6,813 6870 10682 8,050 8107 12923 8,599 8656 13866 8,695 8752 14013 8,795 8852 14163 8,966 9023 14409 9,230 9287 14769 9,275 9332 14829 9,275 9332 14829 9,678 9735 15340 Not observed 10,759 10816 16581 10759 10816 16580.9 10,790 10847 16615 10,825 10,915 11,080 11,100 11,255 10882 10972 11137 11157 11312 16653 16750 16930 Actual Depths TVDss I TVDrkb I MDrkb 1143 1200 1210 1505 1562 1597 2998 3055 3771 3160 3217 4050 3259 3316 4227 3561 3618 4777 3956 4013 5504 4347 4404 6355 4695 4752 6848 6267 6324 9711 6792 6849 10682 Unidentifiable Missing - likely eroded Missing - likely eroded 8658 8715 13885 8862 8919 14191 9175 9232 14628 9224 9281 14693 Exercised option not to run 9698 9755 15290 10623 10680 16378 10738 10795 16503 10759 10816 16524 10785 10842 16550 10785 10842 16550 10825 10882 10915 10972 11080 11137 11100 11157 0 11255 11312 0
