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Home My WebLink About207-148MEMORANDUM 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 North Slope, LLC L-219 PRUDHOE BAY UN ORIN L-219 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 L-219 50-029-23376-00-00 207-148-0 W SPT 4322 2071480 1500 915 915 913 912 547 686 691 692 4YRTST P Kam StJohn 11/22/2025 4 year AOGCC MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN L-219 Inspection Date: Tubing OA Packer Depth 621 2253 2183 2167IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS251122144018 BBL Pumped:2 BBL Returned:2 Friday, January 16, 2026 Page 1 of 1             Test due 5/3/2025; notice from Hilcorp 5/6/2025 that thewell was not operable . Well was SI until mid Nov 2025 -- jbr CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector L-219 (PTD #2071480) Requires AOGCC MIT-IA once thermally stable Date:Tuesday, November 18, 2025 1:54:25 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, November 18, 2025 5:08 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Injector L-219 (PTD #2071480) Requires AOGCC MIT-IA once thermally stable Mr. Wallace, Injector L-219 (PTD #2071480) was due for its 4-year AOGCC MIT-IA in May 2025. The well is now ready to be put on injection. It will now be classified as OPERABLE and a AOGCC witnessed MIT-IA will be performed once it is thermally stable. Please respond with any questions. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, May 6, 2025 9:49 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector L-219 (PTD #2071480) will lapse on AOGCC MIT-IA Mr. Wallace, Injector L-219 (PTD #2071480) is due for its 4-year AOGCC MIT-IA in May 2025. The well is currently shut-in with no plans to return it to service before the end of the month. It will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector L-219 (PTD #2071480) will lapse on AOGCC MIT-IA Date:Thursday, May 8, 2025 7:15:32 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, May 6, 2025 9:49 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector L-219 (PTD #2071480) will lapse on AOGCC MIT-IA Mr. Wallace, Injector L-219 (PTD #2071480) is due for its 4-year AOGCC MIT-IA in May 2025. The well is currently shut-in with no plans to return it to service before the end of the month. It will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-219 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-148 50-029-23376-00-00 12240 Conductor Surface Intermediate Production Liner 4840 80 4482 12206 10400 20" 9-5/8" 7" 4764 30 - 110 29 - 4511 26 - 12232 30 - 110 29 - 2586 26 - 4839 10754 3090 5410 10400, 10737 5750 7240 8435 - 12069 3-1/2" 9.2# L80 24 - 10744 4341 - 4836 Structural 3-1/2" HES AHR Dual Feed Packers 8398, 4328 / 8722, 4436 8398, 8722, 9136, 9362, 9905, 10631 4328, 4436, 4547, 4604, 4727, 4773 Torin Roschinger Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, SCHRADER BLUFF OIL, ORION Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028238 24 - 4777 N/A N/A 1016 1289 750 400 1739 494 N/A 13b. Pools active after work:SCHRADER BLUFF OIL, ORION 3-1/2" HES AHR Single Feed Packers 9136, 4547 / 9362, 4604 / 9905, 4727 / 10631, 4773 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:32 pm, May 17, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.17 13:27:45 -08'00' Torin Roschinger (4662) DSR-5/17/23 RBDMS JSB 072723 WCB 1-4-2024 ACTIVITY DATE SUMMARY 5/12/2023 LRS CTU #2- 1.50" Blue Coil Job Objective; Set XX plug MIRU CTU. Make up 2.80" JSN and RIH. Tagged in sta#2 and X nipple at 10615'. Consult with OE and decide to set CIBP. PUH and flag pipe at 10400'. POOH. Make up and RIH with NS CIBP (max OD: 2.5"). ***Job Continued on 5/13/2023*** 5/13/2023 LRS CTU #2- 1.50" Blue Coil Job Objective; Set CIBP Continue RIH with NS CIBP (max OD: 2.5"). Set CIBP at 10400. POOH. Well failed a negative pressure test. OOH with CIBP setting BHA, all looks normal. Relay results to OE, and slickline to diagnose. Pad op notified to not POI until after slickline work. Begin rig down. Well freeze protected with 34 bbl of diesel. ***Job Complete*** Daily Report of Well Operations PBU L-219 The CIBP is correctly shown on the new WBS, below. -WCB jg MIRU CTU. Make up 2.80" JSN and RIH. Tagged in sta#2 and X nipple at 10615'.gg Consult with OE and decide to set CIBP. PUH and flag pipe at 10400'. POOH. Make up and RIH with NS CIBP j Continue RIH with NS CIBP (max OD: 2.5"). Set CIBP at 10400. POOH. Well failed a negative pressure test. C MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 26, 2021 TO:Jim Regg / P.I. Supervisor �etjC2' I t SUBJECT: Mechanical Integrity Tests (C Hilcorp North Slope, LLC L-219 FROM: LOU Laubensteln PRUDHOE BAY UN ORIN L-219 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J94— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN L-219 API Well Number 50-029-23376-00-00 Inspector Name: Lou Laubenstein Permit Number: 207-148-0 Inspection Date: 5/25/2021 Insp Num: mitLOL210526081248 Rel Insp Num: Packer Well L-219 -!Type Inj W TVD PTD - —2071480 Type Test SPT Test psi BBL Pumped: 13 - !BBL Returned: Interval 4YRTST 1P/F Notes: Standard 4 year test Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 4322 Tubing 726 730 - 726 - 724 ' 1500 IA 250 1806 1744 1736 i 1.3 - OA 737 920 908 - 900- P Fe'5— ctty 100(7 WeU Si z(ze/I" Wednesday, May 26, 2021 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] Sent: Wednesday, October 16, 2013 12:14 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Kirchner, Carolyn J; AK, OPS Well Pad LV; Weiss, Troy D; Wallace, Chris D (DOA); Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: Operable: Injector L-219 (PTD#2071480) Passed AOGCC witnessed MIT-IA All, WAG Injector L-219 (PTD # 2071480) passed an AOGCC witnessed MIT-IA on October 15, 2013, verifying two competent barriers. At this time the well is reclassified as Operable and may remain online as needed. Please call with any questions. Thank you, Laurie Climer $CANNED 4 BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, October 11, 2013 1:55 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Kirchner, Carolyn J; AK, OPS Well Pad LV; Weiss, Troy D; Chris Wallace (chris.wallace @alaska.gov); 'jim.regg @alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; 'AK, D&C Projects Well Integrity Engineer'; Climer, Laurie A; 'Grey, Leighton (CH2M Hill)' Subject: UNDER EVALUATION: Injector L-219 (PTD #2071480) Due For 4 Year Compliance MIT-IA All, WAG Injector L-219 (PTD# 2071480) was not operable due to being shut in for reservoir management at its 4 year AOGCC compliance MIT-IA anniversary in August 2012. At this time, the well is able to be brought online and tested. It is currently classified as Under Evaluation. Plan forward: 1. Ops: bring well online 1 2. DHD: Once thermally stable, perform an AOGCC witnessed MIT-IA to 2,000 psi Please call with any questions. Thank you, Laurie Climer BP Alaska - Well Integrity Coordinator << OLE Object: Picture (Device Independent Bitmap) » WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator PBP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, August 13, 2012 9:36 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Welipad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Kirchner, Carolyn J; Chris Wallace (chris.wallace @alaska.gov) Cc: AK, D&C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector L-219 (PTD #2071480) Shut In Injector Due For 4 Year Compliance MIT-IA All, WAG injector L-219 (PTD # 2071480) is currently shut in for reservoir management and is due for a 4 year compliance AOGCC MIT-IA on 08/14/2012. The well is reclassified as Not Operable until such time that a MIT- IA can be performed with the well on injection. The well will be added to the AOGCC Quarterly Not Operable Report while shut-in. Plan forward when ready to resume injection: 1. Fullbore: MIT-IA to 2000 psi prior to injection 2. Operations: Put well on injection while classified as Under Evaluation 3. Fullbore: AOGCC witnessed MIT-IA once well is thermally stable A TIO plot is included for reference: « File: L-219 TIO Plot 08-13-12.docx>> Please call if you have any questions or concerns. Thank you, Mehreen Vazir 4,ltcI I?td( Gel lc Myrphyi 2 BP Alaska - Well Integrity Coordinator << OLE Object: Picture (Device Independent Bitmap) » WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator @BP.com 3 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, October 11, 2013 1:55 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Kirchner, Carolyn J; AK, OPS Well Pad LV; Weiss, Troy D; Wallace, Chris D(DOA); Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Climer, Laurie A; Grey, Leighton (CH2M Hill) Subject: UNDER EVALUATION: Injector L-219 (PTD#2071480) Due For 4 Year Compliance MIT-IA All, WAG Injector L-219 (PTD# 2071480) was not operable due to being shut in for reservoir management at its 4 year AOGCC compliance MIT-IA anniversary in August 2012. At this time, the well is able to be brought online and tested. It is currently classified as Under Evaluation. Plan forward: 1. Ops: bring well online 2. DHD: Once thermally stable, perform an AOGCC witnessed MIT-IA to 2,000 psi Please call with any questions. Thank you, Laurie Climer (.Vter•rhate:Jack L)Ishr ob) BP Alaska - Well Integrity Coordinator r ! 'i SCOW CI: WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, August 13, 2012 9:36 PM To: 'Regg,lames B (DOA)'; 'Schwartz, Guy L(DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Kirchner, Carolyn 3; Chris Wallace(chris.wallace@ alaska.gov) Cc: AK, D&C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector L-219(PTD #2071480) Shut In Injector Due For 4 Year Compliance MIT-IA All, 1 WAG injector 1-219 (PTD#2071480) is currently shut in for reservoir management and is due for a 4 year compliance AOGCC MIT-IA on 08/14/2012. The well is reclassified as Not Operable until such time that a MIT- IA can be performed with the well on injection. The well will be added to the AOGCC Quarterly Not Operable Report while shut-in. Plan forward when ready to resume injection: 1. Fullbore: MIT-IA to 2000 psi prior to injection 2. Operations: Put well on injection while classified as Under Evaluation 3. Fullbore: AOGCC witnessed MIT-IA once well is thermally stable A TIO plot is included for reference: « File: L-219 TIO Plot 08-13-12.docx>> Please call if you have any questions or concerns. Thank you, Mehreen Vazir BP Alaska - Well Integrity Coordinator «OLE Object: Picture (Device Independent Bitmap) >> WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator @BP.com 2 • • Wallace, Chris D (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, August 13, 2012 9:36 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Kirchner, Carolyn J; Wallace, Chris D (DOA) Cc: AK, D &C DHD Well Integrity Engineer; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Injector L -219 (PTD #2071480) Shut In Injector Due For 4 Year Compliance MIT -IA Attachments: L -219 TIO Plot 08- 13- 12.docx All, WAG injector L -219 (PTD # 2071480) is currently shut in for reservoir management and is due for a 4 year compliance AOGCC MIT -IA on 08/14/2012. The well is reclassified as Not Operable until such time that a MIT - IA can be performed with the well on injection. The well will be added to the AOGCC Quarterly Not Operable Report while shut -in. Plan forward when ready to resume injection: SCANNED �� 203 1. Fullbore: MIT -IA to 2000 psi prior to injection 2. Operations: Put well on injection while classified as Under Evaluation 3. Fullbore: AOGCC witnessed MIT -IA once well is thermally stable A TIO plot is included for reference: «L - 219 TIO Plot 08 13 12.docx» Please call if you have any questions or concerns. Thank you, Mehreen Vazir BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com 1 • WAG Injector L-219 (PTD # 2071480) TIO Plot Well' I.-219 1M 1 roX --M- 00A ...... on 0514,2 0512.12 O€02/12 06W2 C616 os2311 csmna 070,1 7711/12 07/27,12 071112 MOM 1871702 us'F t:. A,r ~a. ~a - _ YT. 5 ~~ f~ ¢ ~ T-Y _ ? ~ ~ ~ ~ . ~~ ~$ . ~.riS R~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE... C:\temp\Temporary Internet Files\OLK9\Microfitm_Marker.doc ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~ , r ~ ~~~.. ,ca ~~y,~ a~.~:;~ ~ ~f? ~_ ,t ~;4 ~,~~i:9 t..~ `~„J'd'Lr 4,sS:+~+~ August 14, 2009 • bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 0 5 2009 ~iasVCa ~ii ~a Gas Cons. Gotrnni~~io~ Anchorap~ a~,~~ i~g ~, -~ ~.~ ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Expioration (Alaska ) Inc. . Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundcy Operationa (14-404) nata L pad A/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al L-01 2070720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 1-105 2020580 50029230750000 NA 1.75 NA 24.65 5!6(2009 1-106 20i2230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L•111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 225 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L•121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231970000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 1-202 2041960 5~29232290000 NA 2 NA 17 6126/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 5002923376~00 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 162 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 ,~~ ~ Date: 03-03-2009 Transmittal Number: 93043 ~~~ :, ,. ~~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have anv questions. please contact Joe Lastuflca at (9071564-4091 Delive Contents SW Name Date Contractor Descri tion ANALYSIS OF BOTTOMHOLE RESERVOIR-FLUID SAMPLES L-219 06-30-2008 SCH HEAW OIL PVT STUDY REPORT CD-ROM -ANALYSIS OF BOTTOMHOLE RESERVOIR-FLUID L-219 06-30-2008 SCH SAMPLES HEAVY OIL PVT STUDY REPORT ANALYSIS OF BOTTOMHOLE RESERVOIR-FLUID SAMPLES L-205 07-30-2008 SCH HEAVY OIL PVT STUDY REPORT CD-ROM -ANALYSIS OF BOTTOMHOLE RESERVOIR-FLUID L-205 07-30-2008 SCH SAMPLES HEAVY OIL PVT STUDY REPORT ~' Pl~s'e Sign and Return one copy of this transmittal. Thank You, Joe Lastuflca Petrotechnical Data Center ConocoPhillips Exxon ChevronTexaco DNR AOGCC ~-~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Don Ince Steve Krohn Steve Wright Kristin Dirks Christine Mahnken DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071480 Well Name/No. PRUDHOE BAY UN ORIN L-219 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23376-00-00 MD 12240 TVD 4840 REQUIRED INFORMATION Completion Date 1/18/2008 Completion Status WAGIN Mud Log No DATA INFORMATI ON Types Electric or Other Logs Run: MWD / GR, MDT / GR, USIT /CBL Well Log Information: Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name og See Notes Log Cement Evaluation ,~ED C Las 15949~Density ~ ~ D C Lis 16026 Gamma Ray +~D D Asc Directional Survey Rpt Directional Survey ~D C Asc Directional Survey '.B~>' Directional Survey l~Cog InductionlResistivity C/LOg Induction/Resistivity ~/ED C Lis 16104 Induction/Resistivity ~eog Leak ED C Las 16285 eak ~ED C Las 16284`See Notes ~g Density Samples No Directional Su (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No 5 Col 1 5 Col 1 5 Blu 5 Blu 1 Col 1 5 Blu Current Status WAGIN Interval OH / Start Stop CH Received Comments 9267 12108 Case 1/22/2008 MDT 22-Dec-2007 225 12100 Case 1/22/2008 Iso Scanner CBL, PDC log, IBC, DSLT, GR, GPIT 2-Jan-2008 8325 12140 Open 2/25/2008 LAS DRHB, RPM, GR, NPHI, RAM, RPM w/PDS graphics 233 12095 Open 3/13/2008 LIS Veri, GR, CCL 0 12240 Open 1 /23/2008 0 12240 Open 1 /23/2008 0 1000 Open 1/22/2008 0 1000 Open 1/22/2008 108 12240 Open 4/10/2008 MD Vision Serives 22-Dec- 2007 108 12240 Open 4/10/2008 TVD Vision Serives 22- Dec-2007 179 12264 Open 4/10/2008 LIS Veri, GR, FET, RPM, RAM, DRHO, NPHI, DCAL. 0 10730 Case 5/19/2008 LDL, MPU, Pres, CCL, GR, ILS, Temp, Spin 2-May- 2008 0 10730 Case 5!19/2008 LDL, MPU, Pres, CCL, GR, ILS, Temp, Spin 2-May- 2008 10268 10772 Case 5/19/2008 Coil Flag, GR, CCL 10 9468 Case 7/28/2008 Fluid Den, CCL, GR, Temp, Gradio, Pres 16-Ju1- 2008 DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071480 Well Name/No. PRUDHOE BAY UN ORIN L-219 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23376-00-00 MD 12240 TVD 4840 Completion Date 1/18/2008 Completion Status WAGIN Current Status WAGIN UIC Y ~D C Pds 16692 Density 10 9468 Case 7/28/2008 Fluid Den, CCL, GR, Temp, Gradio, Pres 16-Ju1- 2008 Well Cores/Samples Information: Interval Name Start Stop Sample Set Sent Received Number Comments • ADDITIONAL INFORMATION Well Cored? Y / Chips Received? r'ffid"' Analysis __.-- Y / N Received? Daily History Received? (~ / N Formation Tops ~y/ N Comments: -- Compliance Reviewed By: _ _ _ _. _____ Date: _ ~ t~ ~_ ~~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, August 19, 2008 4:29 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU L-219 / PTD # 207-148 Hi Art, Please reference the following well: Well Name: PBU L-219 Permit #: 207-148 API #: 50-029-23376-00-00 Top Perf MD: 8425' Bottom Perf MD: 12050' This well began Injection on August 10, 2008 Method of Qperations is: Produced Water No further test data is available for injectors. Thanks! Terrie 8/20/2008 MEMORANDUM TO: Jim Regg ~ ~ ( ~13~2c~`3 P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Monday, August 18, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-219 PRUDHOE BAY UN ORIN L-219 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J i?- Comm Well Name: PRUDHOE BAY UN GRIN L-219 Insp Num' mitCS080814145557 Rel Insp Num: API Well Number 50-029-23376-00-00 Permit Number: zo7-148-o Inspector Name: Chuck Scheve Inspection Date• 8ilai2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-219 Type Inj. ~'/ 'r~rD 4328 IA 140 1990 1940 1930 p.T. 2o71aso TypeTest SPT Test psi lsoo pp sso Tao 7~0 770 Interval INITAL p~ P '~ Tubing 960 960 960 960 Notes: Monday, August 18, 2008 Page 1 of 1 o7i2sios Schlumberg~r N0.4799 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Gomm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1Nell .Inh # 1 nn necrrinfinn fl~fn RI f`nli.r r`r1 G-29A 12096905 MEM PROD PROFILE ~ 07/18/08 1 P1-04 12017505 PROD PROFILE 07/17/08 1 1 L-219 11999028 FLUID DENSITY LOG 07/16/08 1 1 L-205 11999021 USIT 06/17/08 1 1 X-16A 11978465 RST I 06/03/08 1 1 K-14A 11628804 MCNL 11/15/07 1 1 r~~r.vr-riv~nv~r~cviacnwcrrr of arVr~n~Vl line nClUn1Y11Ylp VIVC I.VrT CNl.r11V: BP Exploration (Alaska) Inc, Petrotechnical Data Center' LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9 503-28 $ ATTN: Beth j / Received by: V ®'~'~ ~~L~ L~G~ ~~fi/ V~i>I~l~~f-l~ ~:. ProActive Diagnostic Services, Inc. To: AC~GCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTn The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petnotechnical Data Center Attn: Joe Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: 1~ber~ A. ~Chey Ur-r ~° ~~ /~~S 130 West International Airport Road Suite C Anchorage, AK 99518 ~ (off ~ ~-/ Fax: (907) 245.8952 ~~a~5~ 1) Leak Detection Log 02-May-08 L-219 1 Color Log / EDE 50-029-23376-00 2] Coil FLag 02-May-08 L-219 EDE Signed : ~ Date Print Name: ~ ~/l f ~ ~~ j~ f V I ~(~A~' 50-023376-00 '~'. PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. (NTERNATIONAI. AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ~s~sas:c3:mr:~e;esC~~~ra®~~,hs~~.cs~~ WEBSITE:'nrv~JV.~es~ao~~;ls~ C:\Doejunents and Settings\Oamec\Desktop\Tiansmit_BP.doc ~u J Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 4657 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Orion n~*o RI Cnlnr CI'1 04/09/08 03-10 12045070 USIT -~ 03/24/08 1 1 1-21/K-25 11998996 USIT 03/25/08 1 1 V-223 12061688 CEMENT EVALUATION LOG /(p 03/23/08 1 1 V-214 11978449 MI INJECTOR V '~- ~ (p I O 04/01/08 1 1 18-138 12061689 PRODUCTION PROFILE ~ ~_~-( ~ 03/27/08 1 1 E-10A 11998994 USIT (~ '} 03/28/08 1 1 02-12B 11628789 MCNL a l ! U ~ 08/21/07 1 1 15-456 11963079 MCNL Q"~- _ 02/14/08 1 1 V-220 12031459 CH EDIT PDC GR (USIT)~(y~ l(o ,O 03/07/08 1 V-214 40016214 OH MWD /LWD ! 04/01/08 2 1 -~ 1 - PLEASE AGKNOWLtUGt HtGtIYI tlT slamrvu t-rvv rsei urtrvnvu vrvc ~,vrr cr~~.n i v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ,, '~ 1 ~~'pJ Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ATTN: Beth Received b 03/06/08 ~~il(1~~~~1"~ir~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Field: P.Bay,Pt.Mac,Milne Pt,Orion,Lisburne Well Job # Lo Descri tion N0.4621 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD C-41A 12021141 MEM LDL 02/25/08 1 1 MPS-01A 11970714 SCMT ~'} _ C 02/21/08 1 1 P1-06 11975757 PROD PROFILE q- 03/02/08 1 1 P1-05 11998992 PROD PROFILE ~ 02/29/08 1 1 P1-06 11975757 SCMT /aj ''~-'~ 03/02/08 1 1 09-23A 12045070 USIT gj -~ Q~(C ~ 03/02/08 1 1 L5-34 12057596 PROD PROFILE ~ ~ 02/28/08 1 1 W-40 11970816 PRODUCTION LOG _i 03/04/08 1 1 15-046 12005202 MCNL ~~ - * G 1?J28/07 1 1 C-356 12021139 MCNL ~ 01/26/08 1 1 X-20A 11661178 CH EDIT PDC GR (MEM CORRELATION) 10/26/07 0l~- 1 L-219 12017479 CH EDIT PDC GR (IBC) - [ / 01/02/08 1 PLEASE ACKNOWLEDGE RECEIPT BY,SI~NI~IG AND A'ETUR[~ING;ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~. Anchorage, Alaska 99508 ~ ~/~~~~~ ~~ -~(~~~ Date Delivered: „r,i~m •~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 13 Date 02-25-2008 Transmittal Number:92929 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 elivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: ?-09C ~U'~- 139 '~159~~gr L-219 UAL' 20'3-- 1K~ '`t59y°[ 15-046 ~o~-r3~s "~ ~s"~G 15-046P61dp~-[3`b ~ ~59~/'-} 18-136 ~p~_ /b ~ '~ 169~~~ 19 T~5¢ f tvo o,~e r~o+ c~orrec~ • -die f1P•= #f 1~ ~r m ~ fl -(9 S a`w. ~n.a~ dare iR you pu-E l-~e 19L1 `1 f 1M~k1-1qL-I - !1rF'~ '- 1'"lPASL •- CG•~i~Nkte - `~~~ a E 1~:~3 "~ ~~ ~ilC~; P.91~ ~~. 4 VYR uiA:: V. ~}t.iY. ~.'%I ~''°er~:~l~t~Y' Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ~ rcbe~cil q.e.o Please Sign ar~d Ret~rone copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 I~C:~ANICAL INTEGRITY REPORT ~ - -" ~~ ^ \ ~~ U D u '_ . ~ : ~ a-~,'~-°U `~ QPER ~ FIELD ~j ~ ~Cy~~~~ ~ ci oh .G c 5~~~_~C . - i' i~s-Ob i,~ L Nt1MBER 1..._`" "~-~ N t LL D~ T ~_ TD . '~~d-{{~.2~U.. ~"I,~6~~'I'-VD ; .~BTD _ l~-1 +-Ecl 2~D ~~~ TV~D C a s i^ g : '~ Shoe : L~2~t ID ~-l~S~_TVD ; i~ V : ~J I~ _ ?~ '~ ~ -'~'~T7i =.,er . ~ ~ Shoe . ~ 'L'`Jr ; ~i r . ?-~ ';D ;: o i~ C ~P 2cice_ ~1-as- :-~ T'J~i Sec a t ~ ~ ~~-~~ ole S~.~e ~_~ end ; Perks \ co - 'rLC..L~~1=C'c~.. S.NTEGR?TY - ?A1ZT #~ rnr:uy~:s ?ress Test: _? ~5 nin :;0 min Garments : ~- ,~ ~' ~ ~ _ ~ ~ ~ ~,~ _~z '~CHANIC~_T., 1NTEGRI?'~ -PART # 2 .~~-~~.~°~LS Cement Volumes :. Amt. Liner Csg ~ DV ~~ C,nc Jol to cove= pens ~3~~ 1~.5 ~~~ ~~~~ ~c~.xL~-~ ` ` o _ eoretical TOC ~ ~~~rJ~l..~ ~^ ~~.©~ . ~cs'k6~ ~-t.~ 11 1 Cement Bond Log (Yes or No) ~~ t~-V~a In AOGCC t File ~\ ~~~ CBL Lveluation, zone above perks CyU~ c~cc~~~-C~ oc~ ~ 1~~ Production 'Log: Type £.v81L.ati on CON~LJSIONS: ?arm :l: ?ar~ 12: ~j'~a-la-S"cf6 ~~ STATE OF ALASKA - -~~ ` ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ol ~~~ 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL ~ WAG ^ Other No. of Completions One 1 b. ^ Developrl~ll)~QBxplor2t ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. Q 1/18/2008 ~Qo 12. Permit to Drill Number 207-148 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~' 12/12/2007 ~ 13. API Number _ 50-029-23376-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/20/2007 ~ 14. Well Name and Number: L-2191- 2612 FSL, 3530 FEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 1071' FSL, 1849' FWL, SEC. 26, T12N, R11 E, UM 8. KB (ft above MSL): 78.06'- Ground (ft MSL): 49.9' 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 1424' FSL, 314' FWL, SEC. 25, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 12149 4838 Schrader Bluff 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 583383 y- 5978336 Zone- ASP4 10. Total Depth (MD+TVD) 12240 4840 ~ 16. Property Designation: ADL 028238' TPI: x- 588713 y- 5982136 Zone- ASP4 Total Depth: x- 592453 y- 5982534 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): .1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD / GR, MDT, MWD / GR, USIT / CBL 22. CASING, LINER AND CEMENTING RECORD CASING °SETTING DEPTH MD SETTING DEPTHiTVD' FjQLE AMOUNT WT.,PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# A-53 Surface 108' Surface 108' 34" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 4511' 29' 2853' 12-1 /4" 753 sx DeepCrete, 315 sx Class'G', 80 sx DuraStone 7" 26# L-80 26' 12232' 26' 4839' 8-3/4" 95 sx LiteCrete 470 sx FlexStone 23. Open to production or inject ion? ®Yes ^ No 24, TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-112" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 10744' 8722', 9136', MD TVD MD TVD 9362' & 9905' 8425' - 8550' 4337 - 4380' 8900' - 9030' 4488' - 4521' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9170' - 9215' 4556' - 4567' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 9390' - 9440' 4610' - 4622' 9650' - 9740' 4671' - 4691' Freeze Protect w/ 161 Bbls of Diesel 9950' - 10550' 4737' - 4769' 12000' - 12050' 4834' - 4836' 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.0 ;Q71. - ~~v k'Lt~.:i}~ j None s I/~"~ Form 10-407 Revised 02!2007 CONTINUED ON REVERSE SIDE ~~1 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested. ®Yes ^ No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1976' 1765' detailed test information per 20 AAC 25.071. Ugnu 4843' 2984' MDT was ran; summary supplied for detail. Schrader Bluff NA 8386' 4324' Schrader Bluff NB 8432' 4340' Schrader Bluff NC 8533' 4374' Schrader Bluff NE 8572' 4387' Schrader Bluff NF 8750' 4445' Schrader Bluff OA 8882' 4483' Schrader Bluff OBa 9168' 4555' Schrader Bluff OBb 9391' 4611' Schrader Bluff OBc 9654' 4672' Schrader Bluff OBd 9928' 4732' Formation at Total Depth (Name): Schrader Bluff OBd 9928' 4732' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. D~ Signed Terrie Hubble Title Drilling Technologist Date '~/ L-2191 207-148 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: gob Coolidge, 564-5776 Permit No. / A royal No. INSTRUCTIONS GeNer~A~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only chlumberger MDT .rob Report DATE 9/8/2006 ' ~ - ~ - Page 1 of ~ MRMU MRML - I--~.4 ~ ~~ I BP ' Upper Element ~~ ~ ~_ ~ CLIENT ~ ~ Lower Element - 2191 ' ~ ~ ~ ' L ~ -- MRPS 2: - WELL: MRPS 1: SO # Time File Time end Tool Zone De th TVD TVDSS Mud Before Pretest Mud After Formation Pressure Mob Tem Pum Time Flow V Flow ressure Chamber # Comments 20:00 19 sl latch check 23:05 23 s OBd 9976 4742 4664 2324 10+10 2310 1739 4.70 95 good test 23:26 24 s OBd 10003 4747 4669 2338 10+10 2318 1746 84.00 95 good test 25 s OBd 10058 4756 4678 2343 10+10 2314 1965 0.60 95 supercharge 0:34 26 s OBd 10257 4770 4692 2333 10+10 2318 2027 0.30 95 supercharge 1:20 27 s OBd 10430 4764 4686 2333 10+10 2317 95 Lost Seal 1:35 28 s OBd 10431 4764 4686 2318 10+10 2314 1875 69.00 95 ood test 2:02 29 s OBd 10547 4769 4691 2327 10+10 2317 1913 296.70 95 ood test 2:31 30 s OBd 10640 4773 4695 2331 10+10 2319 1943 314.40 95 ood test 3:00 31 s OBd 10752 4777 4699 2331 10+10 2320 1978 75.70 95 ood test 3:28 32 s OBd 10889 4783 4705 2336 10+10 2322 2013 107.50 95 ood test 3:56 33 s OBd 11004 4788 4710 2336 10+10 2325 2028 129.20 95 ood test 4:21 34 s OBd 11100 4791 4712 2347 10+10 2325 2033 5.20 95 ood test 4:47 35 s OBd 11191 4795 4717 2352 10+10 2328 2036 3320 95 ood test 5:09 36 s OBd 11260 4797 4719 2366 10+10 2331 2038 33.00 95 ood test 5:32 37 s OBd 11395 4802 4724 2369 10+10 95 Lost Seal 5:43 38 s Oed 11396 4802 4724 2343 10+10 95 Lost Seal 5:51 39 s OBd 11397 4802 4724 2344 95 Lost Seal 6:22 40 s OBd 11574 4809 4731 2383 10+10 95 Low Perm. 6:36 41 s OBd 11575 4809 4731 2344 10+10 2330 2198 1.40 95 ood test 7:05 42 s OBd 11614 4811 4733 2380 10+10 2332 2150 1.60 95 ood test 7:29 45 s OBd 11716 4817 4739 2378 10+10 2334 2086 95 D Test 7:54 46 s OBd 11776 4820 4742 2384 10+10 2337 2097 28.70 95 ood test 8:15 47 s OBd 11845 4825 4746 2392 10+10 2346 2055 76.20 95 ood test 8:42 48 s OBd 11964 4832 4754 2383 10+10 2342 2059 110.80 95 ood test 9:08 49 s OBd 12039 4835 4757 2385 10+10 2356 2061 442.70 95 ood test 9:24 50 s OBd 12108 4837 4759 2398 10+10 2356 2062 776.10 95 ood test 9:50 53 10:50 s OBd 12108 4837 4759 2398 10+10 2337 2062 618.00 95 40 Min 8.8 al 2048 2868/1400 Sam le Point #1. MRMS #3 bottles 1 and 2. 12:15 56 17:30 a OBd 11776 4820 4742 2333 10 + 10 2323 2052 95 160 12 al 2050 2870/1295 Sam le Point #2. MRMS #3, bottles 3 and 4. 18:30 57 23:50 a OBd 11574 4809 4731 2353 10+10 2315 1610 95 252 5.1 1200 2865/2876 Sam le Point #3. MRMS #3 bottles 5 and 6. 0:30 58 1:15 OBd 11191 No seal usin MRPO 1:30 60 6:25 PA OBd 11191 4795 4717 2316 2309 2035 96 167 min 13 al 2022 1292/1290 Sam le Point #4. MRMS 2 Bottles 1 and 2 7:00 61 7:15 PO OBd 10890 -78 2308 10 + 10 2013 Lost seal after 1.5 hrs um in w/ uard 8:58 62 8:59 PO OBd 10892 No seal usin MRPO 9:10 63 PO Oed 10888 No seal usin MRPO 9:30 65 2:40 PA OBd 10890 4783 4705 150 9.2 1995 1397/1399 Sam le oint # 5 MRMS #2 Bol0es 3 and 4 11:00 68 latch check 1:38 73 s Mb1 7803 4115 4037 2040 10+10 2020 1855 G1.20 83 ood test 1:55 74 s Mb1 7899 4151 4073 2063 10+10 2038 1867 78.80 83 ood test 2:10 75 s Mb1 7940 4167 4089 2070 10+10 2043 1876 44.60 83 ood test S. Thornhill Page 1 L-2191 MDT_State Data_worksheet_12-28-07 (3).xls 2/13/2008 chlumberger ~ MDT Job Report DnTE s/B/2oos ' ~ ~ - ~---- ~ Pagel of .. - ~ - _-. MRMU MRML CLIENT BP - ~ ~ ~ ~ ~ - ~ ~ ' ~' _ Upper Element --~ - Lower Element MRPS 2: WELL: L-2191 ~ - ~ _ MRPS 1: SO # Time File Time end Tool Zone De th TVD TVDSS Mud Before Pretest Mud After Formation Pressure Mob Tem Pum Time Fbw V Fbw sure Chamber # Comments 2:34 76 s Mb2 8080 4219 4141 2091 10+10 2068 1892 480.20 83 ood test 2:47 77 s Mb2 8124 4236 4157 2100 10+10 2070 1899 568.10 84 ood test 3:06 78 s Mb2 8204 4264 4186 2111 10+10 2085 1912 250.00 84 ood test 4:02 79 s Na 8440 4342 4264 2132 10+10 2103 1931 0.80 85 ood test 4:30 80 s Na 8456 4348 4270 2161 10+10 2120 1919 28.80 86 ood test 4:50 81 s Na 8476 4355 4277 2164 10+10 2121 86 D Test 5:11 82 s Nc 8540 4377 4299 2172 10+10 2124 1950 2.90 86 ood test 5:40 83 s Ne 8622 4404 4326 2185 10+10 2131 2058 0.60 87 ood test 6:40 84 s OA 8893 4486 4408 2212 10+10 2187 2005 15.60 87 ood test 7:03 BS s OA 8927 1495 4417 2224 10+10 2200 2008 112.9 88 ood test 7:19 86 s OA 8977 4508 1430 2236 10+10 2201 2014 9.4 8B ood test 7:54 8:12 87 B8 s s OBa OBa 9182 9207 4559 4565 4481 4487 2258 2267 10+10 10+10 2231 2234 1994 1995 124.2 14.3 88 88 ood test ood test 8:37 8:56 89 90 s s OBa OBa 9254 9267 4577 4581 4499 4502 2355 2331 10+10 10+10 2333 2324 2017 2008 1.9 361.4 89 89 ood test ood test 9:09 91 s OBa 9308 4591 4512 2325 10+10 2322 lost seal 9:22 92 s OBa 9309 4591 4513 2321 10+10 2318 89 lost seal 9:37 93 s OBb 9404 4614 4536 2331 10+10 2331 89 lost seal 9:51 94 s OBb 9405 4614 4536 2336 10+10 2334 1965 2.6 90 ood test 10:13 95 s OBb 9420 4618 4539 2337 10+10 2334 1960 3.4 90 ood test 10:31 96 s OBb 9432 4620 4542 2334 10+10 2326 1960 47.0 90 ood test 11:08 97 s OBb 9646 4670 4592 2350 10+10 2343 90 lost seal 11:27 11:46 98 99 s s OBb OBC 9612 9660 4662 4673 4584 4595 2343 2346 10+10 10 2341 2344 91 lost seal lost seal 11:53 100 s OBc 9661 4673 4595 2348 10 2342 lost seal 12:11 101 s OBc 9672 4676 4598 2343 10 2340 lost seal 12:47 102 s OBc 9736 4690 4612 2301 10 2346 lost seal 72:49 103 s OBc 9737 4690 4612 2344 2343 lost seal 106 Down to 12/26/07 14:20 19:50 108 109 18:28 23:05 a a OBd OBd 10547 10003 4769 4747 4691 4669 2347 2320 2302 1746 93 93 127 130 14.7 1860 1675 2866, 2871 2867, 2872 MRMS 2 123 Bottles 1 8 2 MRMS 2 123 Bottles 3 & 4 2867, 2872 12/27/07 1:30 110 6:30 a OBC 9672 4675 4597 2283 2256 1990 90 210 1950 1780 1291, 2875 MRMS 2 123 Bottles 5 & 6 1291 2875 7:00 111 11:49 a OBb 9432 4620 4542 2246 2211 1959 90 220 18.1 1952 1294, 2873 MRMS 1 1322 Bottles 1 8 2 1294 2873 13:05 112 0:00 a Na 8456 4348 4270 2121 2084 1864 85 167 10.8 1766 1401, 2869 MRMS 1 1322 Bottles 3 8 4 1401 2869 S. Thornhill Page 2 L-2191 MDT_State Data_worksheet_12-28-07 (3).xls 2/13/2008 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: L-219 Common Name: L-219 - - _ Test Date Test Type 12/18/2007 LOT Test Depth (TMD) 4,540.0 (ft) - -_ - Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) 2,853.0 (ft) 8.80 (ppg) 1,082 (psi) 2,386 (psi) EMW 16.10 (PPg) v Printed: 1/24/2008 2:45:21 PM ~l BP EXPLORATION Page 1 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 ,Event Name: DRILL+COMPLETE Start: 12/10/2007 End: jContractor Name: NABORS ALASKA DRI LLING I Rig Release: 1/18/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Task Code Hours NPT Phase 'I ~ Description of Operations 12/10/2007 09:00 - 12:00 3.00 RIGD P PRE - Rig down off of well slot V-07. Load the Shop and Rig Camp. 12:00 - 16:30 4.50 MOB P PRE Mobilize the Rig Camp, Shop and Pits Module to L-Pad. Prepare to lower the Derrick. 16:30 - 18:30 2.00 RIGD P PRE PJSM with Crew. Back the Sub off of well slot V-07. PJSM with Crew. Lower the Derrick. 18:30 - 22:30 4.00 RIGD P PRE Mobilize the Sub from V-Pad to L-Pad. 22:30 - 00:00 1.50 RIGU P PRE Arrive on L-Pad. Remove drifted snow and lay matting boards. Spread out Herculite and spot the Sub. 12/11/2007 00:00 - 02:00 2.00 RIGU P PRE Spot Sub over well slot L-2191 and lay out matting boards. 02:00 - 05:00 3.00 RIGU P PRE Dig snow out of Cellar Rig up 21 1/4" Diverter and 90' of 16" Diverter line 05:00 - 12:00 7.00 RIGU PRE PJSM with all hands 12:00 - 22:00 I 10.001 RIGU I P 22:00 - 00:00 2.00 RIGU P 12/12/2007 00:00 - 04:00 4.00 RIGU P 04:00 - 04:30 0.50 RIGU P 04:30 - 07:30 3.00 DRILL P 07:30 - 08:30 1.00 DRILL P 08:30 - 11:00 2.50 DRILL P 11:00 - 12:00 ~ 1.00 ~ DRILL ~ P 12:00 - 00:00 I 12.001 DRILL I P 12/13/2007 100:00 - 13:00 I 13.001 DRILL I P Inspect derrick prior to raising Raise derrick Rig up floor while waiting on trucks PRE Move Pit Module into place, rig up lines Rig accepted 12/11/07 C~ 12:00 Hang bridle line Prep rig floor for spud Hook up service lines from pits to rig Spot cuttings box Bring on Spud mud Load pipe shed with drill pipe PRE Pick up 48 Jnts 4" HT40 Drill Pipe and rack back in Derrick PRE Pick up 84 Jnts 4" HT40 Drill Pipe and rack back in Derrick Pick up 20 Jnts 4" HWDP + Jars and rack back in Derrick Function test diverter witness waived by John Crisp, witnessed by WSL Joey LeBlanc and NTP Biff Perry PRE Pre Spud meeting with Turner's crew Pre Job Safety Meeting for Rigging up Gyro and Picking up BHA SURF Bring all components up to the rig floor for picking up BHA Pick up BHA #1, 12 1/4" MXL-1 X, 1.5 ABH Motor, and MWD SURF Rig up Sperry E-line unit and Gyrodata's tool SURF Drill ahead from 108' to 265', Sliding to build curve, Gyro each connection for sunre 500 GPM C~ 600 psi off, 650 psi on WOB=5K, PUW=40K, SOW=40K, RWT=40K Torque 2K off, 2.3K on @ 40 RPM Wipe 30' on connection without rotation SURF Pull out of hole from 265' to 84' Pick up rest of BHA #1 Run in hole to 265' SURF Drill ahead from 265' to 950', Sliding to build curve, Gyro each connection for survey, swap Gyro tools after 4 survey stations for calibration confirmation 516 GPM ~ 1,100 psi off, 1,275 psi on WOB=15K, PUW=60K, SOW=58K, RWT=58K Torque 0.8K off, 2.3K on ~ 50 RPM Wipe 30' on connection without rotation SURF Drill ahead from 950' to 1,685', Sliding to build curve, Gyro each connection for survey to 1,000' 550 GPM C~ 1,549 psi off, 1,619 psi on Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 2 of 22 Operations Summary Report Legal Well Name: L-219 Common W ell Name: L-219 Spud Date: 12/10/2007 Event Nam e: DRILL+C OMPLE TE Start : 12/10/2007 End: Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 1/18/2008 Rig Name: NABOB S 7ES Rig Number: I~ I Date From - To .Hours ', Task Code NPT j Phase Description of Operations 12/13/2007 00:00 - 13:00 13.00 DRILL P SURF WOB=20-30K, PUW=70K, SOW=65K, RWT=65K Torque 1.6K off, 3.7K on C~ 55 RPM Wipe 30' on connection without rotation Rig down Gyro after reaching 1,000' Gyro Survey depth as per survey program and two good MWD surveys 13:00 - 15:00 2.00 DRILL N RREP SURF Pump #2 Discharge valve washed out Orient high side, reciprocate pipe, 200 GPM C~3 340 psi 15:00 - 15:30 0.50 DRILL P SURF Drill ahead from 1,685'to 1,759', Sliding to build curve 550 GPM ~ 1,660 psi off, 1,740 psi on , W06=20-30K, PUW=75K, SOW=65K, RWT=70K Torque 2.OK off, 4.2K on ~ 60 RPM 15:30 - 16:30 1.00 DRILL P SURF Circulate 1.5 bottoms up prior to wiper trip 545 GPM C~ 1,650 psi, 60 RPM C~3 3Kft/Ibs, reciprocate pipe 16:30 - 19:00 2.50 DRILL P SURF Pull out of hole from 1,759' to 170' Wiped several tight spots but could not wiper through tight spot at 1,046' Back ream from 1,050' to 994', 200 GPM C~ 400 psi, 40 RPM C~? 2.5KWIbs Pull from 994' to 170' on elevators 19:00 - 19:30 0.50 DRILL P SURF Service Topdrive 19:30 - 20:30 1.00 DRILL P SURF Run in the hole from 170' to 1,570' without any problems Tag up at 1,570', try to work through tight spot without success Kelly up and wash last two stands to bottom 200 GPM Cpl 530 psi, 30 RPM C~? 4Kft/Ibs 20:30 - 00:00 3.50 DRILL P SURF Drill ahead from 1,759'to 2,143', Sliding to build curve 550 GPM ~ 1,900 psi off, 1,990 psi on W06=20-25K, PUW=75K, SOW=60K, RWT=65K Torque 4.5K off, 6.OK on C~3 60 RPM Wipe 30' on connection with rotation Base Permafrost @ 1,976' 12/14/2007 00:00 - 06:00 6.00 DRILL P SURF Drill ahead from 2,143' to 2,800', Sliding to build curve 600 GPM @ 2,200 psi off, 2,350 psi on W06=20-25K, PUW=75K, SOW=60K, RWT=65K Torque 4.9K off, 6.OK on ~ 60 RPM Wipe 30' on connection with rotation Hydrates from 2,334' to 2,394' Losses started at 2 500' 80 bbls/hr initiall slowed to 40 bbls/hr after LCM swee Drilled to 2,750,,losses back up to 80-100 bbls/hr Top of SV3 ~ 2,572' 06:00 - 12:00 6.00 DRILL P SURF Drill ahead from 2,800' to 3,623', Sliding as needed to maintain tangent 580 GPM @ 2,520 psi off, 2,640 psi on W06=25-30K, PUW=80K, SOW=60K, RWT=70K Torque 4.OK off, 7.OK on C~ 60 RPM Wipe 30' on connection with rotation Losses 80 bbls/hr pumps on, adding 3 sacks per hour Medium Nut Plug to active system Adding water at 100 bbls/hr to keep up with losses Top of SV2 ~ 2,986' 12:00 - 20:00 8.00 DRILL P SURF Drill ahead from 3,623' to 4,520', Sliding as needed to maintain tangent Printed: 1/24/2008 2:45:27 PM ~ ~ BP EXPLORATION Page 3 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Hours I Task Code ! NPT Phase Description of Operations - --_ 12/14/2007 12:00 - 20:00 8.00 DRILL P SURF 563 GPM ~ 3,369 psi off, 3,215 psi on, back off flow rate due to pressure limitation WOB=25-30K, PUW=95K, SOW=60K, RWT=70K Torque S.OK off, 7.OK on C 60 RPM Wipe 30' on connection with rotation Hydrates breaking out in the bell nipple for this whole section, flow line temp increasing to egrees Losses 80-100 bbls r um son, adding 3 sacks per hour Medium Nut Plug to active system Adding water at 100 bbls/hr to keep up with losses Add 290 bbls of new mud to active system -4,000' Top of SVi C~ 3,906' Stop drilling and wipe to 1,000' while waiting on remainder of 9 5/8" casing to arrive on location 20:00 - 22:00 2.00 DRILL P SURF Circulate to clean the well bore, rack back stand every 30 minutes from 4,520' to 4,140' 578 GPM C~ 3,220 psi, 120 RPM @ 6 Kft/Ibs No noticeable change in cuttings after 1 bottoms up 50% decrease in cuttings after 1.5 bottoms up 70% decrease in cuttings after 2.0 bottoms up Wiper trip while waiting on last 12 joints of 9 5/8" 40# surface casing to arrive on location 22:00 - 23:00 1.00 DRILL P SURF Pull out of hole on elevators from 4,140' to 4,520' Hole in good shape, no overpulls greater than 20K Static losses -20 bbls/hr while pulling out of hole 23:00 - 00:00 1.00 DRILL P SURF Pull 40KIbs over at 3,163', attempt multiple wipes without success Screw in the topdrive and allow pipe to orient itself while pulling, no success Orient in 90 degree increments with topdrive, still tight Back ream from 3,163'to 3,110', run back in dry, pull out with no problems 60 RPM Q 5-12 Kft/Ibs, torque erratic, 435 GPM C~? 1,700 psi Attempt next stand dry, work through tight spots as required to 3,000' Last 12 joints of 9 5/8" 40# casing arrive on location 12/15/2007 00:00 - 03:30 3.50 DRILL P SURF Pull 40KIbs over at 2,965', attempt multiple wipes without success, losing down weight with each wipe Screw in the topdrive and backream to 2,400', slow pulling speed to get bottoms up before entering Permafrost 100 RPM ~ 6 KWlbs, 600 GPM ~ 2,500 psi Attempt to pull on elevators through Permafrost, Hole swabbing, pump out to 1,900' 200 GPM ~ 350 psi pull out on elevators to 980' wipe as needed Strap on last 12 joints of 9 5/8" 40# casing confirms 4,520' as TD 03:30 - 06:00 2.50 DRILL P SURF Run in hole from 980'to 1,750' without any problems Work through tight spot from 1,750' to 1,860' Run in hole from 1,860' to 4,520', taking weight, looks like bit is pushing something to bottom (Work through tight spots from 3,700' to 4,220') 600 GPM, 2,170 PSI, 100 RPM Printed: 1/24/2008 2:45:27 PM • BP EXPLORATION Page 4 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/15/2007 03:30 - 06:00 2.50 DRILL P SURF PUW= 75K, SOW= 60K, ROT WT= 60K 06:00 - 07:30 1.50 DRILL P SURF Circulate 1.5 bottoms up to clean the well bore 600 GPM, 3141 PSI, 100 RPM ~ 5.5 Kft/Ibs 07:30 - 10:00 2.50 DRILL P SURF POH from 4,520' to 803' Wipe through tight spot from 2,000'to 1,800' Static losses slowed to 2 bbls/hr 10:30 - 13:45 3.25 DRILL P SURF Rack back 6 stands of HWDP and jar stand Pick up additional 6 3/4 collar to rack stand back Lay down all 8" collars, MWD, 12 1/4" Stabilizers, Motor and bit 13:45 - 15:45 2.00 CASE P SURF PJSM on running 9 5/8" casing Rig up casing running equipment Dummy run with fluted mandrel hanger 15:45 - 00:00 8.25 CASE P SURF Run ints 9 5/8" 40# L-80 BTC casin to 3,550' Run bow spring centralizers on first 26 joints Fill on the fly with Franks tool, top off every 10 joints 1,900' started losing down weight, 2,200' down to block weight Circulate from 2,270' to 2,350', bottoms up over two joints, 5 BPM l~ 320 psi, loss 12 bbls while circulating down weight back for 2 joints then started losing down weight again, up weight still tracking model, no increase in up weight, continue running in hole It a ears we are ushin somethin ahead of the shoe picked up around 1,900' similar to wiper trip Installed Tam Port Collar on top of Joint 86 (1,010'), bow spring centralizer on each side of Tam Port Collar Getting back 1/2 of pipe displacement every 10 joints 12/16/2007 00:00 - 01:30 1.50 CASE P SURF Run 23 joints 9 5/8" 40# L-80 BTC casing, total run 110 joints 4 480' . _to- Fill on the fly with Franks tool, top off every 10 joints Getting back half metal displacement every 10 joints 01:30 - 02:00 0.50 CASE P SURF Make up FMC 9 5/8" fluted mandrel hanger and landing joint Confirm pipe count on location Run in hole and land mandrel hanger on landing ring with shoe at 4,510' 02:00 - 03:00 1.00 CEMT P SURF Circulate bottoms up with Franks tool, lower yield point 5 BPM ~ 550 psi Reci rocate Pi a 15' stroke U Wt 170K Dn Wt 70K Avg losses 6 bbls/hr while circulating 03:00 - 03:30 0.50 CEMT P SURF Rig up Schlumberger cement head 03:30 - 08:00 4.50 CEMT P SURF Circulate and condition mud, drop yield point to 15-20 range 5 BPM ~ 430 psi Reci rocate Pi a 15' stroke 3 minutes er stroke U Wt 160K Dn Wt 80K Recieved UCA from Schlumberger, Tail will take 20.5 hrs to reach 260 psi comperssive strength, Lead will take 11 hrs to reach 190 psi compressive strength Consult with town before pumping, decision made to pump cement PJSM with Schlumberger cementers and rig crew Start hatching up 15.8 ppg class G tail cement slurry Avg losses 6 bbls/hr while circulating 08:00 - 11:30 3.50 CEMT P SURF Pump 5 bbls of water to cement head Test lines to 4,000 psi Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 5 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date !~ From - To Hours Task Code NPT Phase Description of Operations 12/16/2007 08:00 - 11:30 3.50 CEMT P - -- SURF - - Pump 100 bbls of 10.0 ppg Mud Push, avg 5 BPM, reciprocate pipe - 8' stroke 3 min/stroke Drop top plug, positive indication plug left head Pump 516 bbls of 10.7 ppg DeepCrete Lead cement slurry, avg 5 BPM, reciprocate pipe - 8' stroke 3 min/stroke 100 bbls of lead out the shoe and i e became stick , ark fluted mandrel han er on landin rin for rest of cement ~ob Pump 65 bbls of 15.8 ppg Class G tail cement slurry, avg 3.2 BPM Pump 17 bbls of 16.5 ppg DuraStone tail cement slurry, avg 3.2 BPM Drop top plug, pump down 5 bbls water from Schlumberger, positive indication plug left cement head Switch over to rig and displace with old spud mud, as per cade pumping schedule Bum lu with 327 bbls final circulatin res pressure up to 1,800 si hold for 3 min t bleed off pressure, check floats, floats held Cement in place C~ 11:27am, full returns throughout cement job 120 bbls cement back to surface 11:30 - 12:00 0.50 CASE P SURF Pressure up to 3,500 psi for casing test, cement head adapter leaking Rig down cement head, rig up pump in sub 12:00 - 13:00 1.00 CASE P SURF Pressure u to 3 500 si for casin test chart and record for 30 minutes Rig down casing testing equipment and blow down lines 13:00 - 15:00 2.00 CEMT N CEMT SURF Wait on 50 psi compressive strength to nipple down diverter 15:00 - 18:00 3.00 DIVRTR P SURF Back out landing joint Rig down 350 ton elevators Run in hole with circulating tool and jet cement out of annular and riser 18:00 - 21:00 3.00 DIVRTR P SURF Nipple down diverter line Nipple down riser and diverter Wash annular 21:00 - 23:30 2.50 WHSUR P SURF Clean and Prepare hanger neck and ID of Gen 5 casing speed head Set and orient casing speed head Run in alien set screws, torque to 350 Wlbs Nipple up tubing head Pressure test casing head to hanger neck for 30 minutes 12/17/2007 00:00 - 03:30 3.50 BOPSU P SURF Nipple up 13 5/8" BOP Nipple up 16" riser 03:30 - 04:00 0.50 BOPSU P SURF Rig up to test BOP 04:00 - 08:00 4.00 BOPSU P SURF Test BOP, low 250 psi, high 4,000 psi Test Annular low 250 psi, high 2,500 psi AOGCC witness waived by John Crisp, test witnessed by WSLs Joey LeBlanc and Duncan Ferguson, NTPs Lenward Toussant and Larry Wurdeman 08:00 - 08:30 0.50 WHSUR P SURF Rig down BOP test equipment Blow down all lines and choke manifold Install wear bushing 08:30 - 09:30 1.00 CASE P SURF Make up BOP jetting tool Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 6 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To ', Hours Task Code NPT Phase Description of Operations 12/17/2007 08:30 - 09:30 1.00 CASE P SURF Run in hole to 30' and tag cement Wash down with jetting tool to clean out casing 09:30 - 14:00 4.50 DRILL P PROD1 Run in the hole picking up 120 joints of 4" 15.7# HT40 Drill Pipe to 4,393' 14:00 - 15:00 1.00 DRILL P PRODi Circulate 225 bbls, 236 GPM @ 530 psi 15:00 - 17:30 2.50 DRILL P PRODi 17:30 - 20:00 2.50 DRILL P PROD1 20:00 - 00:00 4.00 DRILL P PROD1 12/18/2007 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 05:30 4.50 DRILL P PROD1 05:30 - 07:30 2.00 DRILL P PROD1 07:30 - 09:00 1.50 DRILL P PROD1 09:00 - 09:30 0.50 DRILL P PROD1 09:30 - 10:30 1.00 DRILL P PROD1 10:30 - 00:00 13.50 DRILL P PROD1 12/19/2007 00:00 - 06:00 6.00 DRILL P PROD1 06:00 - 00:00 18.00 DRILL P PROD1 12/20/2007 00:00 - 06:00 6.00 DRILL P PROD1 06:00 - 18:30 12.50 DRILL P PROD1 PJSM for cut and slip drilling line Cut and slip 136' of drilling line Stripping drill Blow down lines Pull out of hole racking back stands of 4" 15.7# HT40 Drill Pipe 84 stands in the derrick Pick up BHA #2, Scott & James Xpress DTX619M-D2, 1.5 ABH motor, Res/Gr, MWD, Den/Neu Continue picking up BHA #2 RIH with 4" HWDP out of derrick Run in hole picking up 108 joints of 4" 15.7# HT40 drill pipe out of pipe shed Rotate bit and all stabilizers past Tam Port Collar at 1,010' Drill plugs and float collar at 4,426' Drill cement down to shoe at 4,510' Circulate at 4510' and displace well to 8.8 ppg LSND mud system w/335 bbls. 450 gpm, 1300 psi. Drill 4510' to 4540'. PU 110K, SO 65K, ROT 75K, 470 gpm, 1420 psi, 45 rpm, WOB 5K. Circulate and condition 8.9 ppg LSND mud for LOT. Perform LOT to 16.1 ppg EMW w/8.8 ppg mud, 2853' TVD, 1082 psi. Drill/slide f/4540' to 6808'. 548 gpm, 2533 psi on, 8K tq off, 9K tq on, 130K PU, 60K SO 85K ROT, 100 rpm. Calc ECD = 9.63 ppg. Actual ECD = 10.37 ppg. ADT f/24 hrs = 7.69 hrs. AST f/24 hrs = 1.17 hrs. ARTf/24 hrs = 6.52 hrs. Drill, slide and rotate to maintain angle and direction from 6808' to 7800. 548 gpm, 2874 psi on, 9K tq off, 11 K tq on, 137K PU, 65K SO 87K ROT, 100 rpm. Calc ECD = 9.78 ppg. Actual ECD = 10.25 ppg. Drill directionally f/7800' to 9884'. 550 gpm, 3678 psi on, 3450 psi off, 7K tq off, 9K tq on, 125K PU, 75K SO, 94K ROT, 80 rpm. 9.86 ppg ECD calculated, 10.54 ppg ECD actual. ADT f/24 hrs = 15.62, AST = 6.70 hrs, ART = 8.92 hrs. Progress f/24 hrs = 3076'. Drill directionally (/7800' to 10450'. 550 gpm, 3180 psi on, 3075 psi off, 6.5K tq off, 7.5K tq on, 130K PU, 80K SO, 96K ROT, 80 rpm. 9.87 ppg ECD calculated, 10.3 ppg ECD actual. Swap 580 bbls new mud in and old mud out of LSND system. Drill directionally f/10450' to 12240' MD/4840 TVD (OWC at 11945' MD/4831' TVD). TD well per geo. WOB 10K, 551 gpm, 3693 psi on, 3509 psi off, 10K tq on, 8K tq off, PU 135K, SO 70K, ROT 95K, 80 rpm. 9.94 ppg ECD calculated, 10.17 ppg ECD actual. Printed: 1/24/2008 2:45:27 PM ~ • BP EXPLORATION Page 7 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABORS 7ES Rig Number: Date From - To ~', Hours ', Task Code ~', NPT ' Phase Description of Operations 12/20/2007 106:00 - 18:30 ~ 12.50 ~ DRILL P PROD1 ADT f/day = 8.98 hrs, ART = 5.6 hrs, AST = 3.38 hrs. Progress f/day = 2356'. 18:30 - 00:00 5.50 DRILL P PROD1 MADPass (/12240' to 10451'. 530 gpm, 82 rpm, 3000 psi. ~ 12/21/2007 00:00 - 06:30 6.50 DRILL P PROD1 MADPass (/12240' to 8413' at 600 fph. 530 gpm, 82 rpm, 3000 psi. 06:30 - 10:00 3.50 DRILL P PROD1 POH/Short trip to 9-5/8" shoe at 4510'. 10:00 - 11:00 1.00 DRILL P PROD1 PJSM. Slip and cut 91' drilling line. 11:00 - 15:30 4.50 DRILL P PROD1 RIH from 4510' to TD at 12240'. Wash last stand to bottom. No problems with hole. 15:30 - 16:30 1.00 DRILL P PROD1 Circulate and condition hole. Calculated ECD 10.0 ppg. Actual ECD 9.91 ppg. 16:30 - 17:30 1.00 DRILL P PROD1 Backream f/12240' to 11763'. 553 gpm, 3580 psi, 9K tq, 80 rpm, 135K PU, 60K SO, 90K ROT. 17:30 - 18:30 1.00 DRILL P PROD1 Monitor well. MW = 9.1 ppg. Pump dry job. Blow down top drive. Drop 2-3/8" drift. 18:30 - 00:00 5.50 DRILL P PROD1 POH to 8400'. No problems w/hole. 12/22/2007 00:00 - 03:30 3.50 DRILL P PROD1 PJSM for nuke handling w/Schlumberger, all hands, TP, WSL. Stand back Heviwate. LD BHA #2. 03:30 - 04:00 0.50 DRILL P PROD1 Clean and clear floor. 04:00 - 10:30 6.50 EVAL P OTHCMP PU and RIH w/Schlumberger MDT logging tool. PJSM w/all hands before PU/RIH to 4488'. 10:30 - 11:30 1.00 EVAL P OTHCMP Circulate and condition hole. Pump one drill pipe capacity. Stage pump rate up to 5 bpm, 235 psi. RU wireline sheave in derrick while circulating. 11:30 - 17:30 6.00 EVAL P OTHCMP RIH f/ 4488' to 9810'. 125K PU, 70K SO, filling pipe every 5 stands. 17:30 - 21:00 3.50 EVAL P OTHCMP RU side entry sub and pump wireline down. Latch up and test Down Hole Wet Connect. Install wireline clamp at side entry sub. 21:00 - 23:00 2.00 EVAL P OTHCMP Log and correlate depth MDT GR log to MWD GR logs. 23:00 - 00:00 1.00 EVAL P OTHCMP Record formation pressures w/MDT sidewall penetration probe at 10011', 10038', and 10093'. 12/23/2007 00:00 - 09:30 9.50 EVAL P OTHCMP Record formation pressures w/MDT sidewall penetration probe at 10292', 10465', 10582', 10675', 10787', 10925, 11039', 11135', 11226', 11285', 11439', 11609', 11.649', 11751', 11811', 11880', 11999', 12074', 12143'. 09:30 - 00:00 14.50 EVAL P OTHCMP Set MDT packers and collect formation fluid samples at: 12143', 11776',11574'. 12/24/2007 00:00 - 06:00 6.00 EVAL P OTHCMP Set MDT packers and collect formation fluid samples at:11220'. 5.4 bbls fluid lost to formation from 18:00 12-23-07 to 06:00 today. Handmixed and filled 20" x 9-5/8" annulus w/cement to flutes on han er. 06:00 - 15:30 9.50 EVAL P OTHCMP Set MDT packers and collect fluid samples at 11191', 10941', 10891'. 15:30 - 18:00 2.50 EVAL P OTHCMP Release packers. Monitor well. MW = 9.1 ppg. Pump dry job. POH to 9817'. 18:00 - 19:30 1.50 EVAL P OTHCMP Release E-Line from Down Hole Wet Connect. POH w/Eline. RD side door entry sub. Monitor well. MW = 9.1 ppg. 19:30 - 21:45 2.25 EVAL P OTHCMP POH f/ 9817' to 7712'. 21:45 - 22:30 0.75 EVAL P OTHCMP Circulate 2 drill pipe volumes. 189 gpm, 432 psi, pump 157 bbls. PJSM on E-line rigup while circulating w/crew, Printed: 1/24/2008 2:45:27 PM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date From - To Hours Task Code NPT ____ --- 12/24/2007 21:45 - 22:30 ~ 10.50 EVAL P 22:30 - 00:00 12/25/2007 100:00 - 06:00 I 6.00 (EVAL I P Start: 12/10/2007 Rig Release: 1/18/2008 Rig Number: Page 8 of 22 Spud Date: 12/10/2007 End: Phase Description of Operations OTHCMP Schlumberger, TP, WSL. OTHCMP RU side door entry sub and install E-line clamp on sub w/bottom of tools at 7712'. RIH w/e-line, pump down and latch up Down Hole Wet Connect. OTHCMP Function test E-Line tools. Log pressure samples w/MDT probe at: 7838', 7934', 7975', 8115', 8159', 8239', 8475, 8491', 8511', 8575', 8657'. Adding biocide to LSND mud system. 06:00 - 13:00 7.00 EVAL P OTHCMP Circulate surface to surface f/top of tools at 7717'. 126 gpm, 510 psi. Continue to log pressure samples w/MDT probe at: 8928', 8962', 9012', 9217', 9242', 9289', 9302', 9343', 9439', 9455', 9467', 9646', 9695', 9707'. 13:00 - 16:00 3.00 EVAL N DFAL OTHCMP Blow down top drive, pump dry job. Monitor well. Static. MW= 9.1 ppg. POH f/9772' to 7710' to trip for pump repair on MDT sample catcher. 16:00 - 17:45 1.75 EVAL N DFAL OTHCMP Pull free of Down Hole Wet Connect. POH w/E-line and RD Side Door Entry Sub. 17:45 - 23:00 5.25 EVAL N DFAL OTHCMP POH f/7710' to top of MDT logging tools at 190'. 23:00 - 00:00 1.00 EVAL N DFAL OTHCMP LD MDT logging tools f/190' to surface. 12/26/2007 00:00 - 01:00 1.00 EVAL N DFAL OTHCMP LD MDT tool. 01:00 - 02:30 1.50 EVAL N DFAL OTHCMP Repair pump on MDT logging tools. 02:30 - 03:30 1.00 EVAL N DFAL OTHCMP PU MDT tool and RIH to 190'. Function test MDT tool. 03:30 - 05:30 2.00 EVAL N DFAL OTHCMP RIH w/MDT tool f/190' to 4484'. 05:30 - 06:00 0.50 EVAL N DFAL OTHCMP Circulate and condition mud. Pump drill pipe volume. 168 gpm, 255 psi. 06:00 - 08:00 2.00 EVAL N DFAL OTHCMP Continue to RIH (/4484' to 7671'. 08:00 - 09:30 1.50 EVAL N DFAL OTHCMP MU Side Entry Sub, pump Down Hole Wet Connect and latch up. Function test tools. OK. 09:30 - 14:30 5.00 EVAL N DFAL OTHCMP RIH w/MDT f/7671' to 10547'. 14:30 - 00:00 9.50 EVAL P OTHCMP Log formation fluid samples w/MDT tool at: OBd sand/10547' and OBd sand/10004'. 12/27/2007 00:00 - 12:00 12.00 EVAL P OTHCMP Log formation fluid samples w/MDT tool at: OBc sand/9672', OBb sand/9432'. 12:00 - 17:30 5.50 EVAL P OTHCMP Log formation fluid samples w/MDT tool at: Nb sand/8456'. (Planned sample acquisition f/OBa at 9182' deleted per asset geos). 17:30 - 18:30 1.00 EVAL P OTHCMP Monitor well. PJSM. MW = 9.1 ppg. POH f/8456' to the Side Entry Sub at 7660'. Remove a-line retainers on side entry sub. 18:30 - 20:30 2.00 EVAL P OTHCMP Pull free of Down Hole Wet Connect. POH w/E-line. RD Side Entry Sub and lay down E-line sheaves. Clear floor of E-line equipment. 20:30 - 21:00 0.50 EVAL P OTHCMP Monitor well. MW = 9.1 ppg. Pump dry job. Blow down top drive. 21:00 - 23:30 2.50 EVAL P OTHCMP POH f/'7660' to 3875'. Saw 8K overpull at 7220', 6040', 4632'. 23:30 - 00:00 0.50 EVAL P OTHCMP Move 7 stds HWDP to opposite side of derrick. POH f/3875' to 3687'. 12/28/2007 00:00 - 01:30 1.50 EVAL P OTHCMP POH to MDT BHA. 01:30 - 03:00 1.50 EVAL P OTHCMP LD MDT tools. Clear floor. 03:00 - 04:00 1.00 CLEAN P CLEAN PU BHA #3 including 8-3/4" Hughes MX-C1 bit ser. # 5042383, near bit stabilizer w/float, two 6-1/2" NM spiral drill collars, NM stabilizer, NM spiral drill collar, saver sub, hydraulic jars, XO to Printed: 1/24/2008 2:45:27 PM R BP EXPLORATION Page 9 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: ~~ i i i ~~~ Date 12/28/2007 From - To 03:00 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 10:30 10:30 - 11:30 11:30 - 14:30 14:30 - 21:00 Hours I .Task. Code I NPT 1.00 CLEAN P 1.50 CLEAN P 0.50 CLEAN P 4.50 CLEAN P 1.00 CLEAN P 3.00 CLEAN P 6.501 CLEAN I P 21:00 - 23:00 23:00 - 00:00 12/29/2007 00:00 - 01:00 01:00 - 03:00 03:00 - 04:00 04:00 - 06:00 06:00 - 07:00 07:00 - 10:30 10:30 - 11:45 2.00 CLEAN P 1.00 BOPSU P 1.00 BOPSU P 2.00 CASE P 1.00 CASE P 2.00 CASE P 1.00 CASE N SFAL 3.50 CASE P 1.25 CASE P 11:45 - 00:00 12.25 CASE ~ P 12/30/2007 100:00 - 03:00 I 3.001 CASE I P Phase ~ Description of Operations CLEAN 4" HT40, 20 jts 4" HWDP. CLEAN RIH w/4" HT 40 drill pipe to 4160'. CLEAN CBU and condition hole. 400 gpm, 860 psi. CLEAN RIH f/f/4160' to 12170'. No problems w/hole. CLEAN Wash down f/12170' to 12240'. No fill noted. CLEAN Circulate to condition mud prior to 7" casing running. Stage pumps up to 550 gpm, 3250 psi, 100 rpm, 10K tq. Circulate a total volume of of 2712 bbls per mud engineer. CLEAN Monitor well. Static losses = 1/2 bbls/hr. PJSM. MW = 9.2 ppg. PU 145K, SO 60K, ROT 95K. POH f/12240' to 11789'. Well not swabbing. Pump dry job. POH w/out pumps or hole problems to 800'. CLEAN LD HWDP, Jars, Drill Collars, Stabilizers. Clear and clean floor. Bit 1 / 1 and in gage. Pull wear bushing. RUNPRD CO top rams f/3.5" x 6" variables to 7" f/casing running. PJSM. MU 7" test jt. and test plug. RUNPRD T st 7" rams and doors to 250/4000 i I w _' _ Record on chart. RUNPRD Make dummy run w/casing hanger and mark landing jt. RU 7" casing running equipment. RU torque turn equipment. PU Franks fill up tool. RUNPRD PU and RIH w/shoe track. Check floats. OK. Pump through floats w/Franks tool. OK. RUNPRD RIH w/7" L-80, 26# BTC/TCII casing filling on the fly w/Franks tool. Record PU/SO every 15 jts in casing, every 10 jts in open hole. Average torque f/BTC = 8K fUlbs. Optimum torque for TCII = 10100 ft/Ibs. RUNPRD Repair torn cup on Franks tool. RUNPRD RIH w/7" casing f/1850' to 9-5/8" shoe at 4510'. RUNPRD Circulate and condition hole per mud engineer, staging pumps up to 3.5 bpm 345 psi, 4 bpm 355 psi, 5 bpm 405 psi. No losses. RUNPRD RIH w/7" 26# casing to 10696'. Washed casing down at the following depths when SO weights were less than .35 OH torque/drag broomstick chart friction parameters: Wash down f/8942' to 9061', 4 bpm, 620 psi, 90 bbls. Wash down f/9602' to 9640' 4 bpm, 650 psi, 30 bbls. Wash down f/10112' to 10230', 4 bpm, 600 psi, 90 bbls. PU 230K, SO 65K. RUNPRD RIH w/7" 26# L-80, BTC/TCII casing f/10696' to 12232'. Wash down when SO weights less than torque/drag broomstick chart parameters: Wash down f/11364' to 11483', 3.5 bpm, 630 psi. PU/SO parameters recorded as follows: 8710' PU 175K, SO 78K. 9140' PU 187K, SO 82K. 9488' PU 193K, SO 80K. 10269' PU 235K, SO 70K. 10658' PU 230K, SO 65K. 11053' PU 235K, SO 65K. 11521' PU 240K, SO 68K. 11834' PU 250K, SO 60K. Wash down last jt and landing jt. Tag up on landing joint mark as expected. Weight indicator showing 57K at tagup vs. 67K on Epoch screen. Made 3 Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 10 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABORS 7ES Rig Number: Date From - To .Hours Task Code NPT Phase Description of Operations 12/30/2007 00:00 - 03:00 3.00 CASE P RUNPRD attem is to reci ro te. PU wts 245K. Had to work pipe to hanger landed. Parked pipe to allow circulating time to free 03:00 - 04:15 1.25 CEMT P RUNPRD Bring pumps up to 5 bpm. No losses. CBU w/Franks tool. SD pumps. 04:15 - 04:45 0.50 CEMT P RUNPRD LD Franks tool. RU DS cement head and lines. Plugs loaded and checked by WSL. 04:45 - 06:30 1.75 CEMT P RUNPRD Stage pumps up 2 bpm 312 psi, 3 bpm 500 psi, 4 bpm 583 psi, 5 bpm 700 psi. Reciprocate pipe PU 250K, at 5 bpm can , not get back on bottom, at 2 bpm SO 35K. Park pipe. Circulate and condition mud per mud engineer. PJSM w/Schlumberger, all hands, mud engineer, WSL while circulating. Reciprocate pipe. 06:30 - 10:00 3.50 CEMT P RUNPRD Pump 5 bbls H2O to floor out Tee to flow line. Shut in. Test lines to 4000 psi. Pump 40 bbls 10 ppg Mud Push II to floor w/no H2O down hole, all out Tee to flow line. Shut in at Tee. Drop bottom plug and pump 57 bbls lead Lite Crete cement at 11.0 ppg followed by 180 bbls. of tail 13.0 ppg Flexstone cement. SD. Pump 10 bbls H2O to TEE on floor down flow line to clear Schlumberger pumps and lines---No H2O /cement down hole. Drop top plug. Follow using rig pumps w/465.2 bbls of 9.0 ppg brine. Park pipe 1460 strokes into displacement. No fluid losses throughout job. Average displacement rate 5 bpm. Slow pumps to 3 bpm at 7800 strokes. FCP = 2067 psi. Bump plug on schedule w/8067 strokes displacement away. CIP at 10:00. Bring pressure up to 2575 si and hold f/5 mins. Bleed pressure to ec °~ floats. Holding, no flowback. 10:00 - 11:00 1.00 CEMT P RUNPRD Pressure up and test casing to 4000 psi w 6.2 bbls and hold 11:00 - 11:30 0.50 CEMT P RUNPRD LD cementing head. RD casing equipment. Flush stack. 11:30 - 13:00 1.50 WHSUR P RUNPRD Install 7" FMC casing packoff. Run in lock down screws Test to 5K psi. f/10 mins. 13:00 - 14:00 1.00 PERFO P OTHCMP RU second kill on OA, RU secondary annulus valve on IA. PT lines to 3500 psi. No leaks. Inject 6 bbls. 9.2 ppg drilling mud down 7" x 9-5/8" annulus. Pump at 1.5 bpm. Break down at 1850 psi. Continue to inject 1 bbl ea. hr until 1000 psi compressive strength of tail cement reached and freeze protection pumped. 14:00 - 16:00 2.00 PERFO P OTHCMP RU-and changout 7" pipe rams to 3-1/2" x 6" variables. Change out door seal on upper pipe ram door. 16:00 - 21:30 5.50 BOPSU P OTHCMP PJSM and RU test equipment to test BOP. Test witnessed by WSLs Mike Dinger/Lowell Anderson and NAD TPs Chris Weaver/Bill Perry. AOGCC representative Bob Noble waived AOGCC witnessing of test. Test all rams and valves 250/4000 psi low/high w/3.5" and 4" test jts. Test annular to 250/3500 psi low/high. Record test on chart. 21:30 - 22:00 0.50 PERFO P OTHCMP Cut and slip 132' drilling line. Service rig and topdrive. 22:00 - 00:00 2.00 PERFO P OTHCMP Changeout to long bails. RU to TCP running equipment. 12/31/2007 00:00 - 01:30 1.50 PERFO P OTHCMP Load pipeshed w/guns, check tallies, position/count guns and accessory equipment. Program firing heads. 01:30 - 11:30 10.00 PERFO P OTHCMP PJSM w/all rig hands, Schlumberger, WSL, TP and cover TCP Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 11 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABORS 7ES Rig Number: Date From - To Hours ~, Task i Code ~ NPT Phase Description of Operations - --- -- 12/31/2007 01:30 - 11:30 10.00 PERFO P OTHCMP - hazards and running procedures. U TCP guns and RIH per Schlumberger running order. Run drill pipe f/derrick and tag up on float collar at 12145.5'. 11:30 - 14:30 3.00 PERFO P OTHCMP Log GR w/LWD Impulse tool f/comparison log strip tie in to Measured Depth Log dated 12-12-07 thru 12-22-07. Log 12144'/11857'. 250 gpm, 880 psi. 300'/hr Log w/GR to find RA Pip in casing at 4242'. RIH to 12143', log 2nd confirming pass up to 12048'. 250 gpm, 890 psi. Use 5' stick and measure up. Set guns on depth at 12050' w/bottom shot, 8425' w/top shot. 14:30 - 15:00 0.50 PERFO P OTHCMP PJSM w/ all hands, Schlumberger, WSL, TP. Run practice firing sequence w/pumps. Fire guns w/following pressure sequence: 400 psi/2 mins, increase to 600 psi/2 mins, bleed to 50 psil2 mins, bleed to 0 psi. Wait 5 mins feel three shots at floor. 15:00 - 16:30 1.50 PERFO P OTHCMP POH f/12050' to 8416'. 16:30 - 17:00 0.50 PERFO P OTHCMP Monitor well. Taking fluid 67 bbl/hr. 17:00 - 19:30 2.50 PERFO P OTHCMP POH f/8416' to 3625'. MW = 9.0 ppg. LD pup, LWD Impulse Tool, bumper sub. 19:30 - 00:00 4.50 PERFO P OTHCMP PJSM w/Schlumberger on gun handling. Check PPE, face shields, Kevlar gloves. LD perf guns. Taking 9.0 ppg brine at 60 bbls/hr at 23:59. Total fluid lost to well bore f/15:00 to 00:00 = 461 bbls. 1/1/2008 00:00 - 05:00 5.00 PERFO P OTHCMP POH laying down 4.5" TCP pert guns. All shots fired. Losing brine to perfs at 60 bbls/hr. Perfs as follows (see pert report in DIMS dated 12/31/2007 f/details): Nb 8425' to 8550' OA 8900' to 9030' OBa (upper) 9170' to 9215' OBb 9390' to 9440' OBc 9650' to 9740' OBd 9950' to 10550' OBd 12000' to 12050' 05:00 - 05:30 0.50 PERFO P OTHCMP Clear rig floor of TCP perforating equipment. Losing fluid to perfs at 48 bbls/hr as of 05:30. 05:30 - 06:00 0.50 CLEAN P CLEAN PU cleanout BHA #4 w/6" used bit, scraper, 2 boot baskets, drilling jars, 3 drill collars. 06:00 - 12:00 6.00 CLEAN P CLEAN Trip in hole to 12081' MD. Circulate and condition the well. Wash down from 12081' to 12146' Circ 350 gpm - 1885 psi 30 RPM - 8K Tq Pickup wt 143K slackoff wt 60K. 12:00 - 13:00 1.00 CLEAN P CLEAN Circulate and condition wellbore. 350 gpm, 1950 psi, circ 452 bbls. PU 143K, SO 60K, ROT 120K. Monitor well for 10 min, 22 bph static losses. 13:00 - 22:00 9.00 CLEAN P CLEAN Trip out of hole laying down drillpipe from 12,146'. pull 5 stands, blow down top drive. Cont to pull out of hole to 8355' top of perfs). Monitor well for 15 minutes, static losses at 20 bph. POOH to 138'. Monitor well for 10 min, static loss rate 20 22:00 - 23:00 1.00 CLEAN P CLEAN Trip out of hole laying down BHA from 138'. LD jars, 3 DC's, 2 boot baskets, bit sub. Recovered 1/2 gallon of paraffin from boot baskets. Clean and clear rig floor. 23:00 - 00:00 1.00 BOPSU P OTHCMP RU to pump down kill line through choke manifold. ND riser 1/2/2008 00:00 - 02:00 2.00 BOPSU P OTHCMP Remove the airboot flange from the annular. Printed: 1/24/2008 2:45:27 PM f M BP EXPLORATION Page 12 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 .Rig Name: NABOBS 7ES Rig Number: Date 'From - To Hours Task ~~ Code NPT Phase Description of Operations 1/2/2008 02:00 - 03:00 1.00 EVAL P OTHCMP NU the shooting nipple and Schlumberger's wireline BOP equipment. Test BOP with no visible leaks. Spot Schlumberger's wireline truck. 03:00 - 05:00 2.00 EVAL P OTHCMP RU E-line equipment with with Islolation Scanner/CBL log and 1 /3/2008 1 /4/2008 05:00 - 11:30 11:30 - 19:00 6.50 7.50 EVAL EVAL P P OTHCMP OTHCMP well tech tractor; function test tools. RIH with E-line to 12,120' Using Welltec Tractor due to inclination. 12 1 0' feet to surface with Isolation Scanner/CBL. Confirmed perforation depths with town. 19:00 - 20:00 1.00 EVAL P OTHCMP PJSM with hands. Lay down Schlumberger's logging tools and Welltec's tractor. 20:00 - 21:30 1.50 EVAL P OTHCMP ND Schlumberger's wireline BOP equipment and shooting nipple. NU the airboot flange and riser. 21:30 - 00:00 2.50 RIGU P RUNCMP Begin Rigging up to run completion: change bails, pull wear ring, make up tubing hanger and perform dummy run, PJSM with Nabors Casing Service, and Schlumberger and Halliburton's completion specialists. RU torque turn equipment and control line spools. Total Losses over 24 hrs = 219 bbls; loss rate = 9.1 bph 00:00 - 01:30 1.50 RIGU P RUNCMP Continue to RU to run completion. Hang sheeves for control lines. 01:30 - 12:00 10.50 BUNCO RUNCMP RIH with 3.5", 9.2#, L-80, TC-II premium thread, 6 packer completion. Bakerloked all connections below packer. Torque turned TC-II connections to 2300 ft-Ibs (optimal torque). Used Jet-Cube sealguard on all connections. Ran one clamp per joint in horizontal section. Performed continuity check on first Phoenix Gauge. Test the AHRfeed-through ports in each packer to 5000 psi. RIH to 2030' MD. 93 bbls lost during 12 hour period. 12:00 - 00:00 12.00 BUNCO RUNCMP RIH with 3.5", 9.2#, L-80, TC-II premium thread, completion with control line and I-wire. Continue to run one clamp per joint. RIH to 4640' MD. 93 bbls lost over 12 hr period. 00:00 - 13:00 13.00 BUNCO RUNCMP Continue to RIH with Completion to 9,128' MD with 3.5" TCII connections. Continue to run I-Wire with clamps on each connection Torque connections to 2300 ft Ibs PUW=85K, SOW=45K While RIH at 9,128' MD, took 10K on SOW Continued to work string down to 9,186' MD Total losses for 13 hrs-120bb1s 13:00 - 13:30 0.50 BUNCO RUNCMP RU circulation lines Pump down tubing at 1 bpm, 86 psi, total of 13 bbls RD circulation lines Printed: 1/24/2008 2:45:27 PM i BP EXPLORATION Page 13 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: i Date From - To Hours Task I Code NPT Phase ', Description of Operations Continue to RIH from 9,186' MD to 9,362' MD l 1/4/2008 13:30 - 15:00 1.50 BUNCO RUNCMP ', Continued with sticking problems, taking 10-15K SOW 'i 15:00 - 16:30 1.50 BUNCO RUNCMP RU circulation lines Circulate down tubing to spot 80 bbl lubrication pill with 5% Safe Lube Pump rate-1 bpm, 76 psi Pumped 50 bbls through tubing and into annulus RD circulation lines 16:30 - 19:00 2.50 BUNCO RUNCMP RIH from 9,302'MD to 9,530' MD Unable to get past 9,530' while working string Took 15K on SOW while working back and forth slowly Pulled back to 9,510' 19:00 - 20:00 1.00 BUNCO RUNCMP RU circulation lines Circulate and condition remainder of lubric tion ill bl Pump rate-1 bpm, 56 psi RD circulation lines Unable to work string pass 9530' MD 20:00 - 00:00 4.00 BUNCO 1/5/2008 100:00 - 02:30 I 2.501 RU 02:30 - 03:30 I 1.00 03:30 - 04:30 1.00 BUNCO 04:30 - 12:00 7.50 BUNCO 12:00 - 16:30 4.50 BUNCO 16:30 - 20:00 I 3.50 20:00 - 21:00 1.001 BUNCO 21:00 - 23:00 I 2.00 23:00 - 23:30 ~ 0.50 ~ RU 23:30 - 00:00 0.50 RUNCMP Attempt to continue to RIH- Consult with Anchorage Team MU top drive and circulate at 1 bpm while working pipe down slowly Took 15K SOW Work pipe down down to 9537' MD Total losses for 11 hrs-70 bbls RUNCMP Work pipe between 9537' MD and 9500' MD taking 10-15K SOW and pumping at 1 bpm RUNCMP RIH with tubing from 9537' MD to 9790' MD RIH slowly having to pick up and work pipe often SOW 45K RUNCMP Work pipe between 9790' MD and 9775' MD RUNCMP RIH with tubing to 9816' MD working pipe through tight spots. RUNCMP PUW 85K, SOW 50K Consult with Anchorage on plan forward Decision made to POOH DPRB RUNCMP POOH to 9752' MD RU circulating lines and pump dry job at 1 bpm, 60 psi POOH to 9390' MD .PUW 85K, SOW 50K OVER PULL 20K DPRB RUNCMP Pick up and Slack off attempting to free pipe. Min SOW = 38K, MAX PUW = 188K (80% of rating) No movement DPRB RUNCMP RU to circulating lines pump at 1 bpm for 5 minutes. 110 psi Pick up and Slack off DPRB RUNCMP RU top drive to circulate Circulate at 3 bpm 486 psi Work pipe DPRB ~ RUNCMP ~ Pull one joint of tubing Printed: 1/24/2008 2:45:27 PM ~ ~ BP EXPLORATION Page 14 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours ; Task Code I NPT Phase Description of Operations 1/5/2008 23:30 - 00:00 0.50 BUNCO DPRB RUNCMP PUW 85K, SOW 50K, no overpull 1/6/2008 00:00 - 01:30 1.50 BUNCO DPRB RUNCMP POOH with tubing from 9197' MD began taking weight Work pipe free with 76K overpull PUW 85K, SOW 50K Same on next joint 01:30 - 03:30 2.00 BUNCO DPRB RUNCMP 100K overpull at 9164' MD worked pipe for 30 minutes RU circulating lines Circulate 3 bpm, 770 psi for 45 minutes while working pipe Came free with 170K PUW, 85K overpull Lost 50 bbls while pumping for 45 minutes 03:30 - 04:30 1.00 BUNCO DPRB RUNCMP POOH with tubing working through tight spots with up to 100K overpulls and pumping 3 bpm 85K PUW 04:30 - 08:30 4.00 BUNCO DPRB RUNCMP Unable to POOH at 9093' MD. Work pipe, PUW 190K circulate up to 3.5 bpm, 350 psi. 'de to run free B E-line. 08:30 - 18:30 10.00 BUNCO DPRB RUNCMP Continue to work pipe every 15 minutes while E-line unit finishes work on different well. RD top drive and crossovers. RU long bails to pick up and slack off tubing during SLB free point test. 18:30 - 21:00 2.50 BUNCO DPRB RUNCMP RU E-line, RU "Y" block system with pump in sub, grease tubes and packoff. 21:00 - 22:30 1.50 BUNCO SFAL RUNCMP SLB heater in unit broke down, grease line frozen. RD frozen line, RU warm line, set up Tioga heater to keep line warm. 22:30 - 00:00 1.50 BUNCO DPRB RUNCMP PJSM with Nabors and SLB hands. Finish RU SLB grease line and packoff. RIH with SLB free point tool. Feed wire in by hand for first 300' due to weight of tool. Total losses for 12hrs = 65bbls, 6.5 bph rate 1/7/2008 00:00 - 02:00 2.00 BUNCO DPRB RUNCMP RIH with SLB free point tool to 2500' MD. Use rig pumps to help tool down. 02:00 - 08:30 6.50 BUNCO DPRB RUNCMP Calibrate free point tool with 85K and 150K PUW at 2500' MD. Continue to RIH taking periodic readings from free point tool at 85K and 150K PUW. Free point tool indicated pipe is stuck at the bottom packer, 78' MD. _ _ __ 08:30 - 09:30 1.00 BUNCO DPRB RUNCMP POOH with SLB free point tool and RD. 09:30 - 14:00 4.50 BUNCO DPRB RUNCMP RU SLB jet cutter. Unable to run jet cutter though "Y" block; tool OD=2.5", "Y" block ID=2.25" RD "Y" blocks, pass wireline through, RU jet cutter. RU "Y" block and circulating line. RIH with jet cutter pumping tool down at 1 bpm 50 psi. 14:00 - 15:30 1.50 BUNCO DFAL RUNCMP PU 105K, 20K overpull. Printed: 1/24/2008 2:45:27 PM ~ ~ BP EXPLORATION Page 15 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date I From - To j Hours I Task Code ~ NPT Phase Description of Operations 1/7/2008 14:00 - 15:30 1.50 BUNCO DFAL RUNCMP Attem t to fire jet cutter at 8942' MD (first full joint above bottom packer). No indication of cut on weight indicator. SLB surface equipment indicated successful cut. Work pipe to 190K PUW, 105K overpull. Pipe failed to cut. 15:30 - 23:30 8.00 BUNCO DFAL RUNCMP POOH with jet cutter. RD "Y" block and pull SLB tools. Confirm that cutter did not fire. Trouble shoot; look for short in connections starting from bottom of tool working up. No short in tools. Problem located in wireline. Cut 100' of line, test still failed. RD "Y" block and circulating line. RD E-line. Change drum on E-line unit to different line. 22:30 - 00:00 1.50 BUNCO DFAL RUNCMP RU E-line and pass line through "Y" block. RU Jet cutter and test. RU "Y" block, circulating line, and packoff. Loss rate = 6.7 bph 1/8/2008 00:00 - 03:00 3.00 BUNCO DFAL RUNCMP RIH with SLB jet cutter to 8942' MD (middle of first joint above bottom packer), pump at 1 bpm, 60 psi. PU 105K, 20K overpull. Fie 'et cutter Hook load decreased to 60K. Pick up 6 feet to confirm tree pipe. PUW 75K. 03:00 - 07:00 4.00 BUNCO DPRB RUNCMP POOH with SLB E-line. RD "Y" block (pump in sub), circ line, grease lines, and packoff, RD SLB. Change to short bails 07:00 - 20:30 13.50 BUNCO DPRB RUNCMP POOH with 3.5", 9.2#, L-80, TC-II completion from cut at 8942' MD. LD tubing in pipe shed in running order. Spool up i-wire. A pin from the i-wire clamps fell to the rig floor and down the wellbore. The pin is 5" long x 1 " wide x 1/8" thick. Pull rotary table master bushing and drain stack to look for pin. Pin was not found. 20:30 - 21:00 0.50 BUNCO DPRB RUNCMP POOH with packer #6 to 2341' MD. No visible signs of damage on packer #6. Shear pins had endured some down weight, but not enough to shear. Cut i-wire and made a rough splice to continue spooling line. 21:00 - 00:00 3.00 BUNCO DPRB RUNCMP POOH with packer #5 No visible signs of damage. Shear pins had endured some down weight. Continued to pull tubing and completion equipment out of hole seeing no signs of excessive wear, or indication of damage on packers #4 and #3. Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To ~I Hours Task Code NPT I Start: 12/10/2007 Rig Release: 1/18/2008 Rig Number: Page 16 of 22 Spud Date: 12/10/2007 End: Phase Description of Operations 1/8/2008 21:00 - 00:00 3.00 BUNCO DPRB RUNCMP Total losses for 24 hrs = 174 bbls 1/9/2008 00:00 - 01:00 1.00 BUNCO DPRB RUNCMP Pull Packer #2 Showed minor wear, a hard material rubbed against the side of packer. No damage to rubber elements. Two metal pieces half the size of a dime came out of the well with packer #2 (possibly pert debri). 01:00 - 02:30 1.50 BUNCO DPRB RUNCMP Finish pulling tubing down to jet cut. Tubing flared out to 4" Top offish at 8948' MD, Top of packer at 8979' MD based on 02:30 - 05:30 3.00 BUNCO DPRB RUNCMP Pull rotary table master bushing and drain stack looking for lost pin from i-wire clamp Prepare to MU Baker fishing BHA with spear, jars, CCV and drill collars. 05:30 - 22:30 17.00 BUNCO DPRB RUNCMP MU and RIH with Baker fishing BHA with 2.93" grapple on fishing spear. Picking up drillpipe singles and loading pipe shed every 120 jts. RIH to 8907' MD. PU = 120K, SO = 75K (A pin was found on the rig floor, likely the pin believed to be down the wellbore). 22:30 - 23:30 1.00 BUNCO DPRB RUNCMP Establish circulating rates. 2 bpm, 735 psi 2.5 bpm, 1150 psi 3 bpm, 1560 psi 3.5 bpm, 2000 psi Circulate 32 bbls. Bring pumps down to 70 gpm and 500 psi. Attempt to engage fish twice, rotate 1/2 turn, attempt to engage fish 3 times. Set down 15K to engage. of fish = 8944' MD. Pick up, jars fired at 150K, pick up to 175K to confirm fish is on. No increase in pressure with fish engaged, 70 gpm, 500 psi. 23:30 - 00:00 0.50 BUNCO DPRB RUNCMP Pump a 50 bbl high vis sweep through the fish at 500 psi, 70 gpm. 8 bph loss rate. 1/10/2008 00:00 - 02:00 2.00 BUNCO DPRB RUNCMP Continue to pump 50 bbl high vis sweep. Drop ball to CCV at 2500 strokes. Seat ball at 1 bpm. Open CCV 1800 psi and bring pumps up to 7 bpm, 1060 psi. Pump sweep to surface. A small amount of very fine grained sand came back with sweep. 02:00 - 02:30 0.50 BUNCO DPRB RUNCMP Drop ball to close CCV. Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 17 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date .From - To 'Hours Task Code NPT Phase Description of Operations 1/10/2008 02:00 - 02:30 0.50 BUNCO DPRB RUNCMP 1850 psi to close. 02:30 - 03:30 1.00 BUNCO DPRB RUNCMP Working pipe without firing jars at 9093'. When pipe is free PU = 120K, SO = 75K Circulate through fish 70 gpm, 440 psi. Work pipe; PU = 150K, SO = 120K Pressure while working pipe: 450 psi slackoff, 385 psi pickup Continue to work pipe increasing pickup in +5K increments to 200K PU. 03:30 - 05:30 2.00 BUNCO DPRB RUNCMP Work pipe. SO 71 K, PU 175K and fire jars, repeat 2 times. Fi h f Pulled up to 8908' MD and stuck again. SO 71 K, PU 170K and fire jars, repeate 3 times. PU to 225K and Fish came free. Pulled up to 8894' MD and stuck again. SO 65K, PU 200K and fire jars, continue to PU to 250K. Fish came free. Max PU to fire jars is 200K and max PU without jars 250K. Work pipe when stuck to Max pickup to fire jars and max pickup without firing jars. Stuck at 8870' Stuck at 8854' Stuck at 8821' Stuck at 8808' Stuck at 8770' Never set down more 15K to avoid setting packer. 05:30 - 14:30 9.00 BUNCO DPRB RUNCMP Continue to Work pipe up to 8714'. Mix 118 bbls of 2% tube and spot in annulus. Work pipe to 7440' MD. Began pulling pipe without overpull. 15 bph loss rate 14:30 - 16:00 1.50 BUNCO DPRB RUNCMP POOH to BHA. Rack back 3 stands of drill collars, LD intensifiers, CCV, Jars and oil sub. Break spear from fish and LD. 16:00 - 18:30 2.50 BUNCO DPRB RUNCMP LD cut off joint, 15.33'. LD acker #1 Packer #1 damaged. Large dent in housing around dogs. Deep gouges along sides of packer and gauge ring. Damaged teeth on one dog. One rubber element missing two torn in half. Some debri recoved in profiles of packer: A metal wire/spring, and a few metal fragments the biggest is 1" long x 1/4" wide x 1/8" thick. LD GLM and tail pipe assembly, heating joints to break Bakerlok. No damage to threads on GLM pups. Clean and clear the rig floor. 18:30 - 19:30 1.00 BUNCO DPRB RUNCMP PJSM. MU Baker clean out BHA with full gauge, 6.151 flat bottom, mill, scrapper, boot baskets, string magnets, and jars. MU 3 stands of 4-3/4" drill collars to 318' Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 18 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To ' Description of Operations Hours Task Code NPT Phase I - 1/10/2008 19:30 - 23:30 4.00 BUNCO DPRB RUNCMP RIH picking up 102 joints of drillpipe singles to 3568' MD. 23:30 - 00:00 0.50 BUNCO DPRB RUNCMP RIH with 4" drillpipe stands to 5381' MD filling pipe every 30 stands. 1/11/2008 00:00 - 03:30 3.50 BUNCO DPRB RUNCMP Continue to RIH to 12,148' MD with no rotation, no circulation. Fill pipe every 30 stands. PU = 135K, SO = 60K 03:30 - 04:30 1.00 BUNCO DPRB RUNCMP POOH to 12,100' and circulate bottoms up 5 bpm, 830 psi. Fine, dark sand on bottoms up. 04:30 - 06:30 2.00 BUNCO DPRB RUNCMP Continue to circulate and pump 100 bbl high vis sweep. 7 bpm. 12 bph loss rate while pumping sweep. 06:30 - 11:00 4.50 BUNCO DPRB RUNCMP POOH to 8300' MD rotating. Circulate 5 bpm, 750 psi. PU = 130K, SO = 60K, ROT =110K 11:00 - 15:30 4.50 BUNCO DPRB RUNCMP Circulate 5 bpm, 760 psi. Rotate 30 RPM 15:30 - 16:00 0.50 BUNCO DPRB RUNCMP RIH to 12,148' MD. POOH to 12074' MD Obtain slow pump rates. 16:00 - 21:30 5.50 BUNCO DPRB RUNCMP POOH to 8250' MD rotating. Circulate 5 bpm, 670 psi. Rotate 18 RPM. 21:30 - 23:30 2.00 BUNCO DPRB RUNCMP PJSM. Slip and cut 136' of drilling line. Service top drive and inspect draw works. 23:30 - 00:00 0.50 BUNCO DPRB RUNCMP POOH to 7484' MD rotating. Circulate 5 bpm, 560 psi. Rotate 20 RPM. Total losses for the day = 70 bbls 1/12/2008 00:00 - 05:30 5.50 BUNCO DPRB RUNCMP Continue to POH from 7,484' MD to 2,300' MD ROT=25 rpm, GPM=210, psi=580 05:30 - 06:00 0.50 BUNCO DPRB RUNCMP Circulate bottoms up at 5 bpm, 580 psi. 06:00 - 06:30 0.50 BUNCO DPRB RUNCMP POH from 2,300' MD to surface 06:30 - 08:00 1.50 BUNCO DPRB RUNCMP LD BHA Recover and inspect debris from magnets and boot basket. Approximately 5 Ibs small metal particles (flake/chip) debris retrieved 08:00 - 09:30 1.50 BUNCO DPRB RUNCMP Conduct I-Wire Resilience test as follows: Install test plug and joint with I-Wire attached and run through the BOP. Set Accumulator pressure on Annulus at 250 psi, 500 psi and 750 psi with no damage to I-Wire housing at each pressure setting. At the same time apply pressure from below the annular preventor, held 160 psi from below with 750 psi on accumulator. Increase accumulator pressure to 1000 psi and 1500 psi with no noticeable damage to I-Wire at each pressure setting. Rig down equipment. 09:30 - 10:30 1.00 BOPSU P RUNCMP RU BOP test equipment 10:30 - 16:45 6.25 BOPSU P RUNCMP Test BOP Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 19 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To ' Hours i Task Code NPT Phase Description of Operations 1/12/2008 10:30 - 16:45 6.25 BOPSU P RUNCMP BOP test witnessed by Duncan Ferguson WSL, Larry Wurdeman TP Low test pressure 250 psi high test pressure 4000 for Rams, Annular and Valves, choke manifold, 3500 psi for Annular Rams and Hydril tested with both 4" and 3 1/2" test joints Accumulator test 1,450 psi after functioning all valves, 15 sec for 200 psi, 1 min ~~ 41 sec for full recovery to 3,000 psi Average charge for 8 bottles of Nitrogen is 1800 psi 16:45 - 17:30 0.75 BOPSU P RUNCMP RD BOP test tools Set wear bushing Blow down choke manifold, choke and kill lines 17:30 - 19:00 1.50 BUNCO DPRB RUNCMP MU cleanout BHA with mill and scraper assembly 19:00 - 00:00 5.00 BUNCO DPRB RUNCMP RIH with mill and scraper assembly on 4" drill pipe to 12074' MD. Total losses for the day = 38 bbls. 1/13/2008 00:00 - 02:00 2.00 BUNCO DPRB RUNCMP Continue in hole to 12,148' MD. POOH to 12,074' MD. Circulate a 100 bbl high vis sweep discarding brine returns. 8 bpm, 2050 psi, rotating 20 RPM. Sweep returned with minimal debri/sand. Displaced hole with clean 9.0 ppg brine. 02:00 - 09:30 7.50 BUNCO DPRB RUNCMP POOH laying down 4" drill pipe to 2800' MD 09:30 - 10:30 1.00 BUNCO RREP RUNCMP A'kickers' malfunctioned on the laydown machine. Set 'kicker' to neutral position and utilized remaining kickers to continue laying down drill pipe. 10:30 - 13:00 2.50 BUNCO DPRB RUNCMP Continue to POOH laying down drill pipe to BHA. 13:00 - 14:00 1.00 BUNCO DPRB RUNCMP LD BHA: 9 drill collars, jars, bumper sub, magnet, bootbaskets, scraper, and mill. Boot baskets contained 75% less debri than previous run. 14:00 - 18:00 4.00 BUNCO DPRB RUNCMP RU two I-Wire spooling units and one control line spooling unit on rig floor Hang sheaves in derrick RU to run 3.5", 9.2#, L-80, TC-il 6 packer completion 18:00 - 00:00 6.00 BUNCO DPRB RUNCMP PJSM with SLB, Halliburton, and Nabors rig crew. RIH with completion to 1206' MD, past packer #2. Bakerlok each joint below the bottom packer. Total losses for day = 16 bbls OA pressure = 300 psi 1/14/2008 00:00 - 09:30 9.50 BUNCO DPRB RUNCMP Continue to RIH with 3.5", 9.2#, L-80, TC-II 6 packer i completion to 2345' MD Torque turn each connection to 2300 ft-Ibs. RIH with packer #6 and terminate control line, 09:30 - 00:00 14.50 RUNCOI~V DPRB RUNCMP RIH with 3.5" tubing to 7791' MD. Run two I-wire control lines and one clamp per joint. Printed: 1/24/2008 2:45:27 PM BP EXPLORATfON Page 20 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date I From - To Hours 1/14/2008 09:30 - 00:00 14.50 1/15/2008 00:00 - 03:00 3.00 03:00 - 06:30 I 3.50 06:30 - 07:00 0.50 07:00 - 19:00 12.00 19:00 - 19:30 19:30 - 20:30 20:30 - 21:30 21:30 - 23:00 23:00 - 23:45 Task I Code I NPT ' Phase 0.50 RUN 1.00 RUN 1.00 RUN 1.50 RUN 0.75 RUN 23:45 - 00:00 0.25 RUN 1/16/2008 00:00 - 01:30 1.50 RUN 01:30 - 02:30 1.00 RUN 02:30 - 03:00 0.50 RUN 03:00 - 06:30 3.50 RUN 06:30 - 08:30 2.00 RUN 08:30 - 09:30 1.00 RUN 09:30 - 10:00 0.50 RUN 10:00 - 11:30 1.50 RUN 11:30 - 12:00 12:00 - 13:45 13:45 - 15:00 15:00 - 17:00 0.50 RUN 1.75 RUN 1.25 RUN 2.00 RUN Description of Operations DPRB RUNCMP Test I-wire evey two hours for functionality. DPRB RUNCMP RIH with 3.5" TC-II tubing to 9093' MD. Run two I-wire control lines and one clamp per joint. Test I-wire evey two hours for functionality. RUNCMP RIH with 3.5" TC-II tubing to 10,744' MD. Run two I-wire control lines and one clamp per joint. Ran a total of 329 full clamps, 26 half clamps. Test I-wire evey two hours for functionality. RUNCMP Clean and clear rig floor of tubing running equipment. WAIT RUNCMP Wait on weather. Temperature -45 deg. F. Unable to rig up Schlumberger E-line due to low temperature. Maintenance on rig. Replace ram on laydown machine. RUNCMP Temperature at -35 deg F. Hold PJSM w/Schlumberger, all hands, WSL, tourpusher on a-line rig up. RUNCMP Brakes frozen on E-line unit. Acquire Tioga heater and thaw brakes. Reposition unit. RUNCMP RU E-line with pump in sub and line packing on tubing for GR/CCL. RUNCMP RIH with E-line GR/CCL to packer #5 in completion. RUNCMP Run GR/CCL log. Locate RA tags in 3-1/2" tubing and 7" casing. Correlate with original GR and USIT logs. Completion equipment on depth. RUNCMP POH w/E-line logging tools. RUNCMP RD E-line logging equipment and clear floor. RUNCMP Lay down top jt of 3-1/2" tubing. PU landing jt. and 3-1/2" FMC tubing hanger. Install I-Wire clamp on last joint, terminate two I-Wire through tubing hanger and test. Land tubing hanger with WLEG at 10,744'. Run in lock down screws. Test hanger to 5000 psi f/10 minutes. RUNCMP Rig up Hot Oil Service to pump diesel freeze protection fluid. Test lines to 3500 psi. RUNCMP Reverse circulate 154 bbls of corrosion inhibited 9.8 ppg brine to inner annulus w/rig pumps at 1 bpm max rate per Halliburton to avoid damaging packer elements. 180 psi. Hold back pressure on tubing as required to prevent 'U' tubing. RUNCMP Reverse circulate 68 bbls of 50 deg. diesel w/Hot Oil Svcs pumps to inner annulus for freeze protection. i bbl/min, 180 psi. RUNCMP Pump (bullhead) 71 bbls of 9.8 ppg brine down tubing w/annulus shut in. 1 bpm, 565 psi. RUNCMP Pump (bullhead) 22 bbls diesel down tubing w/Hot Oil Svcs pumps for freeze protection. 1 bpm, 565 psi. RUNCMP Drop 2.5" OD bronze ball down tubing to pressure up against to set packers. Wait 10 minutes for ball to fall. Pump (bullhead) 60 bbls of 9.8 ppg brine down tubing at 1 bpm with 575 psi to attempt to seat ball. Ball did not seat. RUNCMP Shut down and allow diesel to migrate to top of fluid column in tubing. RUNCMP Pump (bullhead) additional 60 bbls of 9.8 ppg brine down tubing, 1 bpm, 570 psi and attempt to seat ball. Did not seat. RUNCMP RU Schlumberger E-line. Test Schlumberger BOP to 500 psi f/5 mins, RUNCMP Re-head E-line. RU Well Tec tractor with Slick Line 2.65" blind Printed: 1/24/2008 2:45:27 PM BP EXPLORATION Page 21 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours Task i Code NPT Phase i Description of Operations -- 1/16/2008 15:00 - 17:00 2.00 BUNCO RUNCMP box tool on bottom of tractor . 17:00 - 23:00 6.00 BUNCO RUNCMP RIH w/tractor and attempt to push ball on seat. Tractor stopped at GLM #2 at 10565'. Work tractor up and back attempting to push ball through GLM. Failed to get tractor through GLM. Stopped solid at same point each time. Pull tractor slightly off ball and circulate at various rates f/1 bpm 500 psi to 2 bpm at 725 ps. Attempt many times to work tractor/ball through GLM #2. Would not pass. Pulled tractor back up through GLM # 3 at 9933' and passed back through to verify that tractor had not sustained damage and could still pass through GLM geometry. No difficulty passing through GLM # 3. RIH back down to ball/GLM #2 and attempt many times to work ball through GLM. Failed to pass through GLM. 23:00 - 00:00 1.00 BUNCO RUNCMP POH w/tractor assembly. While POH, consult w/slope wells group slickline PEs on possible configurations to push ball out of GLM. Mobilize 2.625" OD gauge tool w/flex knuckle w/5/8" sucker rod thread as suggested. 1/17/2008 00:00 - 02:00 2.00 BUNCO RUNCMP POH w/tractor. 02:00 - 02:30 0.50 BUNCO RUNCMP RU new tractor w/2.625" WL paraffin cutter and knuckle joint on bottom of tractor. 02:30 - 05:00 2.50 BUNCO RUNCMP RIH w/tractor assembly to GLM at 10565'. 05:00 - 08:30 3.50 BUNCO RUNCMP Attempt to work ball throujgh GLM # 2 to seat ball and set packers. Work gage/single knuckle assembly back and forth w/tractor. No movement through GLM #2. Slack off and land gage/single knuckle against ball and shut in Schlumberger packoff assy. Stage pumps up in 1/2 bpm increments up to 2 bpm and 750 psi. Rock pump rate up and back f/0 to 2 bpm. SD pumps and prepare to move tractor. Airlines frozen upon Schlumberger E-line unit. RU Tioga heater to thaw truck. Work tractor up and back to attempt to dislodge ball. 08:30 - 09:30 1.00 BUNCO RUNCMP Consult w/town team and slope slick line team on action plan. 09:30 - 12:00 2.50 BUNCO RUNCMP POH w/E-line tractor. 12:00 - 16:00 4.00 BUNCO RUNCMP LD E-line tractor. MU new tractor w/2.5" OD WL paraffin cutter (face of paraffin cutter conformed to 2.5" ball size w/water courses to allow fluid passage if necessary) two knuckle joints, solid bar and knuckle joint to bottom of tractor. Assembly acquired from North Slope slick line shop (this assembly was performance tested w/2.5 "bronze ball in GLM on surface by field drilling superintendent and drilling manager prior to RIH at Camcoshnp----------guaranteed to succeed). 16:00 - 19:00 3.00 BUNCO RUNCMP RIH w/tractor and triple knuckle assembly. 19:00 - 20:00 1.00 BUNCO RUNCMP Ball hung up in GLM 2 and 1 and XN nipple. Work through w/tractor and knuckle/2.5" OD paraffin cutter assembly by bumping up with tractor at stop point, pick up ten feet and run at and bump ball w/knuckle assembly several times until ball bumped past stop point. 20:00 - 21:00 1.00 BUNCO RUNCMP RU Schlumberger E-line BOP and attempt to fill BOP w/grease between rams for packer setting and pressure testing sequence per Schlumberger. Pressure up slowly. Could not get rams to seal completely. Tubing holding solid, no leaks, at 600 psi. Increase tubing pressure above 600 psi and constant leak alongside wire and out of line wiper on top of E-line BOP. Leaking off 5 psVmin. Decision made to go ahead and set Printed: 1/24/2008 2:45:27 PM ~ ~ BP EXPLORATION Page 22 of 22 Operations Summary Report Legal Well Name: L-219 Common Well Name: L-219 Spud Date: 12/10/2007 Event Name: DRILL+COMPLETE Start: 12/10/2007 End: Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 1/18/2008 Rig Name: NABOBS 7ES Rig Number: Date From - To '~ Hours Task Code I NPT ' Phase I Description of Operations 1/17/2008 20:00 - 21:00 1.00 BUNCO RUNCMP packers. Pressure up on tubing to 3500 psi, set packers and leeding off slowly through E-line BOPS through line wiper. 21:00 - 22:30 1.50 BUNCO RUNCMP Attemppted to pressure test tubing and annulus. E-line BOPs and line wiper bleeding down and not able to hold pressure. Decision made to POH w/E-line tractor assembly, RD E-line BOP and then RU hard line for tubing and annulus test. 22:30 - 00:00 1.50 BUNCO RUNCMP POH w/E-line tractor assembly. 1/18/2008 00:00 - 01:00 1.00 BUNCO RUNCMP POH w/tractor assembly. 01:00 - 02:00 1.00 BUNCO RUNCMP RD tractor assembly, E-line equipment and E-line BOP. Clear floor. 02:00 - 04:00 2.00 BUNCO RUNCMP RU for pressure testing tubing and annulus. Phone message left on night North Slope pager of AOGCC notifying time of test. No AOGCC representative attended. Roll pumps on tubing and find ball immediately on seat. Test tubing to 3500 si for 30 min. and record on chart. Good test. Bleed tubing , 30 min. and record on chart. Good test. Bleed pressure to 0 both annulus and tubing. Rig down test equipment. 04:00 - 06:00 2.00 BUNCO RUNCMP LD landing joint and have FMC hand install Two Way Check valve in tubing hanger and test to 1000 psi. 06:00 - 08:00 2.00 BUNCO RUNCMP ND BOP stack. 08:00 - 10:00 2.00 BUNCO RUNCMP Pass dual I-Wires through adaptor spool and terminate. Test I-Wire. NU adaptor flange and double master valve "Dry hole tree". Test double master valve/flange assy against TWC w/diesel to 5000 psi for 30 mins. OK. 10:00 - 12:00 2.00 BUNCO RUNCMP RU Drill Site Maintenance and test lubricator to 500 psi. Pull TWC. RD lubricator and set BPV. Set VR plugs in two IA valves and one OA valve. 12:00 - 15:00 3.00 BUNCO RUNCMP Secure well. Release rig at 15:00 hrs. Rig Down f/L-2191. Printed: 1/24/2008 2:45:27 PM by ... _ ~ .. ~ Schlumberger Repvrt Report Date: December 27, 2001 Survey 1 DLS Computation Method: Mlntmum CuNahlre / L Client: BP Exploration Alaski Vertical Section Azimuth: 60.000° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 fl Structure 1 Slot: L-PAD I L-219 TVD Reference Datum: Rotary Table Well: L-219 TVD Reference Elevation: 78.06 ft relative t0 MSl Borehole: L-219 Sea Bed 1 Ground Level Elevation: 49.90 ft relative to MSL UWIIAPI#: 50029233760( Magnetic Declination: 23.168° Survey Name I Date: L-219 /December 20, 2001 Total Field Strength: 57639.734 nT Tort 1 AHD 1 DDI 1 ERD ratio: 225.180° / 10342.42 ft 16.770 / 2.13; Magnetic Dip: 80.880° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Fee Declination Date: December 20, 2001 Location LatlLong: N 70 212.798, W 14919 22.81' Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5978336.100 ftl1S, E 583383.330 ftU: North Reference: True North Grid Convergence Angle: +0.63757795` Total Corr Mag North -> True North: +23.168° `~, u Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longkude Depth Section Departure ft d d k k k k k k ft d 100ft kUS ftUS tilt U.W V.UU U.W -/o.VO U.UV U.VV U.UU U.UV V.UU V.UU V.W 07/OJJO.IV :IOJJOJ.JJ IY /V LI L./AO YY 19.7 ID LL.O11 GYD CT DMS 108.00 0.00 0.00 29.94 108.00 0.00 0.00 0.00 0.00 0.00 0.00 5978336.10 583383.33 N 70 21 2.798 W 14919 22.811 175.00 1.10 38.53 96.94 175.00 0.60 0.64 0.64 0.50 0.40 1.64 5978336.61 583383.72 N 70 21 2.802 W 14919 22.800 264.00 2.24 43.00 185.90 263.96 3.06 3.24 3.23 2.44 2.12 1.29 5978338.57 583385.42 N 70 21 2.822 W 14919 22.749 355.00 2.64 49.74 276.81 354.87 6.82 7.11 7.09 5.10 4.93 0.54 5978341.25 583388.20 N 70 21 2.848 W 14919 22.667 445.00 3.67 44.61 366.68 444.74 11.64 12.06 12.04 8.49 8.54 1.19 5978344.68 583391.77 N 70 21 2.881 W 14919 22.562 534.14 5.31 48.21 455.54 533.60 18.43 19.03 19.01 13.27 13.62 1.87 5978349.52 583396.80 N 70 21 2.928 W 14919 22.413 625.38 7.53 50.29 546.20 624.26 28.45 29.23 29.20 19.90 21.36 2.45 5978356.24 583404.47 N 70 21 2.993 W 14919 22.187 715.74 9.93 52.63 635.51 713.57 42.02 42.94 42.88 28.42 32.11 2.68 5978364.87 583415.12 N 70 21 3.077 W 14919 21.873 815.59 12.82 55.39 733.39 811.45 61.60 62.63 62.50 39.94 48.07 2.94 5978376.56 583430.95 N 70 21 3.190 W 14919 21.406 MWD+IFR+MS 928.78 16.57 57.31 842.86 920.92 90.25 91.34 91.09 55.79 72.00 3.34 5978392.68 583454.70 N 70 21 3.346 W 14919 20.707 1025.33 20.85 57.14 934.28 1012.34 121.18 122.30 121.96 72.56 98.03 4.43 5978409.74 583480.54 N 70 21 3.511 W 1491919 1120.79 24.16 53.03 1022.47 1100.53 157.55 158.82 158.47 93.53 127.92 3.84 5978431.04 583510.19 . N 70 21 3.717 W 1491919. 1216.42 28.21 52.11 1108.27 1186.33 199.38 201.01 200.65 119.19 161.41 4.26 5978457.07 583543.39 N 70 21 3.970 W 1491918.094 1311.50 31.12 52.99 1190.88 1268.94 246.04 248.06 247.69 147.79 198.77 3.09 5978486.08 583580.43 N 70 21 4.251 W 1491917.002 1406.81 34.88 53.71 1270.80 1348.86 297.59 299.96 299.59 178.76 240.42 3.97 5978517.50 583621.72 N 70 21 4.556 W 1491915.785 1502.92 37.60 52.78 1348.31 1426.37 354.00 356.77 356.40 212.76 285.93 2.89 5978552.01 583666.85 N 70 21 4.890 W 1491914.455 1596.80 40.21 53.82 1421.36 1499.42 412.55 415.73 415.36 247.98 333.20 2.87 5978587.75 583713.72 N 70 21 5.236 W 1491913.073 1691.42 41.57 54.82 1492.89 1570.95 474.19 477.66 477.28 284.10 383.52 1.60 5978624.42 583763.63 N 70 21 5.592 W 1491911.603 1789.20 44.94 54.89 1564.09 1642.15 540.91 544.66 544.26 322.67 438.30 3.45 5978663.59 583817.97 N 70 21 5.971 W 1491910.001 1884.30 49.96 53.91 1628.38 1706.44 610.61 614.69 614.29 363.45 495.23 5.33 5978705.01 583874.44 N 70 21 6.372 W 14919 8.337 19$0.04 50.20 53.79 1689.82 1767.88 683.61 688.12 687.72 406.77 554.52 0.27 5978748.98 583933.24 N 70 21 6.798 W 14919 6.604 2076.07 52.10 53.79 1750.05 1828.11 757.96 762.90 762.50 450.95 614.86 1.98 5978793.82 583993.08 N 70 21 7.232 W 14919 4.841 2171.73 54.84 53.33 1806.99 1885.05 834.33 839.76 839.36 496.60 676.69 2.89 5978840.16 584054.39 N 70 21 7.681 W 14919 3.034 SurveyEditor Ver SP 2.1 Bld( doc40x_100) L-219\L-219\L-219\L-219 Generated 2/13/2008 2:41 PM Page 1 of 5 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft d d n n n n n n n de 1100 n ftUS nUS ZZW.`JV D/. I I ~J.W 16OU.L4 R7J8.JV 71L.O4 716.03 Y IO.LJ a9J.oY /J7.o 1 L.9V Jai vooo. ly aow ~ w.av t~ i v c ~ o. ~+~ vv ~Ya ~a ~. wa 2362.56 59.34 53.16 1910.61 1988.67 993.37 999.95 999.54 592.74 804.83 2.34 5978937.70 584181.44 N 70 2 1 8.627 W 14918 59.288 2457.71 62.00 53.72 1957.21 2035.27 1075.77 1082.90 1082.49 642.14 871.45 2.84 5978987.84 584247.50 N 70 2 1 9.112 W 14918 57.341 2553.75 64.24 54.20 2000.63 2078.69 1160.95 1168.56 1168.14 692.53 940.72 2.37 5979038.99 584316.20 N 70 2 1 9.608 W 14918 55.316 2647.80 65.05 54.49 2040.91 2118.97 1245.53 1253.54 1253.13 742.07 1009.78 0.91 5979089.29 584384.69 N 70 21 10.095 W 14918 53.297 2744.85 64.33 54.25 2082.40 2160.46 1332.84 1341.28 1340.85 793.18 1081.09 0.77 5979141.19 584455.42 N 70 21 10.598 W 14918 51.213 2840.32 65.37 54.08 2122.97 2201.03 1418.81 1427.70 1427.27 843.78 1151.15 1.10 5979192.55 584524.91 N 70 21 11.095 W 14918 49.165 2935.89 67.37 54.10 2161.27 2239.33 1505.90 1515.25 1514.82 895.13 1222.06 2.09 5979244.69 584595.24 N 70 21 11.600 W 14918 47.092 3031.74 66.62 54.00 2198.73 2276.79 1593.65 1603.47 1603.04 946.92 1293.48 0.79 5979297.27 584666.07 N 70 21 12.109 W 14918 45.004 3127.01 67.01 54.01 2236.24 2314.30 1680.74 1691.05 1690.62 998.39 1364.33 0.41 5979349.52 584736.34 N 70 21 12.615 W 14918 42.933 3222.41 66.71 54.16 2273.73 2351.79 1768.00 1778.78 1778.34 1049.85 1435.38 0.35 5979401.76 584806.81 N 70 21 13.121 W 14918 40.856 3317.57 66.40 53.92 2311.59 2389.65 1854.83 1866.08 1865.65 1101.12 1506.05 0.40 5979453.80 584876.89 N 70 21 13.625 W 14918 38. 3413.61 66.99 54.48 2349.59 2427.65 1942.59 1954.28 1953.85 1152.71 1577.59 0.81 5979506.18 584947.84 N 70 21 14.133 W 14918 36.6 3508.54 66.74 54.89 2386.89 2464.95 2029.51 2041.58 2041.14 1203.17 1648.82 0.48 5979557.43 585018.50 N 70 21 14.629 W 1491834.617 3604.20 67.31 54.64 2424.23 2502.29 2117.21 2129.65 2129.20 1253.99 1720.75 0.64 5979609.04 585089.86 N 70 21 15.128 W 14918 32.514 3699.53 66.96 54.73 2461.27 2539.33 2204.67 2217.49 2217.03 1304.76 1792.43 0.38 5979660.60 585160.96 N 70 21 15.628 W 14918 30.418 3795.75 66.68 54.33 2499.14 2577.20 2292.72 2305.94 2305.48 1356.09 1864.47 0.48 5979712.72 585232.42 N 70 21 16.132 W 14918 28.312 3891.17 66.49 54.98 2537.06 2615.12 2379.90 2393.50 2393.03 1406.74 1935.89 0.66 5979764.16 585303.27 N 70 21 16.630 W 14918 26.224 3987.02 67.74 55.11 2574.33 2652.39 2467.88 2481.81 2481.32 1457.34 2008.26 1.31 5979815.55 585375.07 N 70 21 17.128 W 14918 24.108 4081.68 68.78 54.80 2609.40 2687.46 2555.46 2569.73 2569.24 1507.83 2080.25 1.14 5979866.84 585446.48 N 70 21 17.624 W 14918 22.003 4177.70 67.17 54.88 2645.40 2723.46 2644.11 2658.74 2658.24 1559.08 2153.02 1.68 5979918.90 585518.66 N 70 21 18.128 W 149 1819.876 4273.36 66.56 54.86 2682.99 2761.05 2731.72 2746.71 2746.20 1609.70 2224.96 0.64 5979970.31 585590.03 N 70 21 18.625 W 149 1817.772 4368.13 67.35 54.81 2720.08 2798.14 2818.58 2833.92 2833.40 1659.83 2296.25 0.84 5980021.32 585660.75 N 70 21 19.119 W 1491815.688 4454.19 67.33 54.64 2753.24 2831.30 2897.66 2913.33 2912.81 1705.79 2361.09 0.18 5980067.90 585725.07 N 70 21 19.570 W 1491813.792 4531.10 66.63 54.10 2783.32 2861.38 2968.10 2984.12 2983.59 1747.03 2418.62 1.12 5980109.76 585782.14 N 70 21 19.975 W 14918 12.110 4625.71 67.21 54.30 2820.40 2898.46 3054.69 3071.15 3070.63 1797.94 2489.21 0.64 5980161.45 585852.15 N 70 21 20.476 W 1491810.046 4721.49 67.01 53.86 2857.66 2935.72 3142.46 3159.39 3158.87 1849.70 2560.67 0.47 5980214.01 585923.02 N 70 21 20.985 W 14918 7.957 4816.77 66.33 53.83 2895.39 2973.45 3229.44 3246.88 3246.35 1901.32 2631.31 0.71 5980266.40 585993.08 N 70 21 21.492 W 14918 5.891 4912.75 66.26 54.91 2933.98 3012.04 3316.90 3334.76 3334.23 1952.51 2702.74 1.03 5980318.38 586063.92 N 70 21 21.995 W 14918 3.803 5008.43 67.01 56.02 2971.93 3049.99 3404.46 3422.60 3422.04 2002.30 2775.10 1.32 5980368.97 586135.71 N 70 21 22.485 W 14918 1 5103.76 67.37 56.02 3008.88 3086.94 3492.12 3510.47 3509.87 2051.42 2847.96 0.38 5980418.89 586208.02 N 70 21 22.968 W 14917 59. 5199.30 67.20 56.40 3045.78 3123.84 3580.05 3598.60 3597.95 2100.43 2921.21 0.41 5980468.71 586280.71 N 70 21 23.449 W 14917 57.415 5294.97 66.84 56.35 3083.13 3161.19 3667.96 3686.68 3685.97 2149.20 2994.55 0.38 5980518.29 586353.50 N 70 21 23.929 W 14917 55.270 5389.93 66.50 57.11 3120.73 3198.79 3755.01 3773.87 3773.09 2197.04 3067.45 0.82 5980566.93 586425.86 N 70 21 24.399 W 14917 53.138 5485.42 67.75 57.65 3157.85 3235.91 3842.90 3861.85 3860.95 2244,46 3141.55 1.41 5980615.17 586499.42 N 70 21 24.865 W 14917 50.971 5580.16 67.84 57.10 3193.66 3271.72 3930.52 3949.57 3948.56 2291,75 3215.43 0.55 5980663.27 586572.76 N 70 21 25.330 W 1491748.811 5676.50 67.35 57.06 3230.38 3308.44 4019.47 4038.63 4037.54 2340.16 3290.19 0.51 5980712.50 586646.97 N 70 21 25.806 W 1491746.625 5771.87 66.46 56.69 3267.79 3345.85 4107.06 4126.36 4125.19 2388.10 3363.66 1.00 5980761.25 586719.89 N 70 21 26.277 W 1491744.476 5867.58 67.83 56.39 3304.96 3383.02 4195.10 4214.55 4213.34 2436.72 3437.24 1.46 5980810.69 586792.92 N 70 21 26.755 W 14917 42.325 5963.03 69.13 57.36 3339.97 3418.03 4283.76 4303.35 4302.07 2485.24 3511.60 1.66 5980860.03 586866.73 N 70 21 27.231 W 1491740.150 6058.64 68.94 57.23 3374.18 3452.24 4372.94 4392.63 4391.26 2533.48 3586.73 0.24 5980909.10 586941.31 N 70 21 27.706 W 14917 37.953 SurveyEditor Ver SP 2.1 Bld( doc4Ox_1OO) L-219\L-219\L-219\L-219 Generated 2/13/2008 2:41 PM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND VeRlcal Along Hole Closure NS EW DLS Northing Easting Latitude Longkude Depth Section Departure k de de k k k k ft ft k d 1100 k kUS kUS 6154.05 69.30 57.94 3408.19 3486.25 4462.00 4481.77 4480.30 2581.27 3661.98 0.79 5980957.71 587016.02 N 70 21 28.175 W 149 17 35.752 6249.79 68.86 57.00 3442.37 3520.43 4551.34 4571.20 4569.63 2629.35 3737.38 1.03 5981006.63 587090.87 N 70 21 28.648 W 14917 33.547 6345.32 67.63 57.04 3477.78 3555.84 4639.95 4659.92 4658.29 2677.65 3811.81 1.29 5981055.75 587164.75 N 70 21 29.122 W 14917 31.371 6441.09 66.58 57.50 3515.04 3593.10 4728.07 4748.15 4746.44 2725.35 3886.02 1.18 5981104.27 587238.42 N 70 21 29.591 W 14917 29.200 6536.64 68.52 57.03 3551.53 3629.59 4816.27 4836.45 4834.68 2773.11 3960.30 2.08 5981152.84 587312.16 N 70 21 30.060 W 14917 27.028 6631.98 68.54 57.12 3586.42 3664.48 4904.88 4925.18 4923.34 2821.33 4034.77 0.09 5981201.88 587386.08 N 70 21 30.534 W 14917 24.850 6727.25 69.01 57.37 3620.91 3698.97 4993.59 5013.98 5012.09 2869.38 4109.46 0.55 5981250.76 587460.22 N 70 21 31.006 W 14917 22.665 6824.36 68.84 56.24 3655.83 3733.89 5084.06 5104.60 5102.66 2918.99 4185.29 1.10 5981301.20 587535.49 N 70 21 31.494 W 14917 20.448 6919.65 67.91 55.98 3690.95 3769.01 5172.44 5193.18 5191.23 2968.38 4258.82 1.01 5981351.41 587608.46 N 70 21 31.979 W 14917 18.297 7015.23 66.51 54.24 3727.97 3806,03 5260.23 5281.29 5279.34 3018.78 4331.10 2.23 5981402.60 587680.16 N 70 21 32.474 W 14917 16.183 7110.16 66.16 54.71 3766.08 3844.14 5346.77 5368.24 5366.28 3069.30 4401.86 0.58 5981453.90 587750.35 N 70 21 32.971 W 14917 14. 7206.58 65.73 54.22 3805.38 3883.44 5434.41 5456.29 5454.32 3120.47 4473.51 0.64 5981505.86 587821.42 N 70 21 ~ 33.474 W 149 17 12. 7303.30 66.02 54.55 3844.91 3922.97 5522.25 5544.56 5542.58 3171.87 4545.27 0.43 5981558.05 587892.60 N 70 21 33.979 W 14917 9.9 7397.61 66.46 54.71 3882.91 3960.97 5608.19 5630.87 5628.90 3221.84 4615.65 0.49 5981608.79 587962.42 N 70 21 34.470 W 14917 7.860 7493.98 67.93 54.93 3920.26 3998.32 5696.66 5719.71 5717.73 3273.02 4688.26 1.54 5981660.77 588034.44 N 70 21 34.973 W 14917 5.736 7589.86 67.61 55.05 3956.54 4034.60 5785.08 5808.46 5806.48 3323.94 4760.96 0.35 5981712.49 588106.56 N 70 21 35.473 W 14917 3.610 7685.55 67.91 54.92 3992.75 4070.81 5873.31 5897.03 5895.06 3374.76 4833.50 0.34 5981764.11 588178.52 N 70 21 35.972 W 149171.488 7779.82 68.29 54.81 4027.91 4105.97 5960.43 5984.50 5982.52 3425.10 4905.03 0.42 5981815.24 588249.48 N 70 21 36.467 W 14916 59.395 7877.26 67.25 54.84 4064.78 4142.84 6050.25 6074.70 6072.72 3477.06 4978.75 1.07 5981868.01 588322.62 N 70 21 36.978 W 14916 57.239 7971.89 68.04 55.61 4100.77 4178.83 6137.47 6162.21 6160.23 3526.97 5050.64 1.12 5981918.72 588393.94 N 70 21 37.468 W 14916 55.136 8067.86 67.94 56.34 4136.74 4214.80 6226.22 6251.19 6249.20 3576.76 5124.38 0.71 5981969.32 588467.11 N 70 21 37.957 W 14916 52.979 8164.30 69.26 56.59 4171.93 4249.99 6315.84 6340.98 6338.96 3626.36 5199.22 1.39 5982019.74 588541.39 N 70 21 38.445 W 14916 50.789 8259.10 70.27 56.57 4204.71 4282.77 6404.63 6429.93 6427.88 3675.35 5273.47 1.07 5982069.55 588615.08 N 70 21 38.926 W 14916 48.618 8354.25 71.52 59.01 4235.86 4313.92 6494.46 6519.83 6517.68 3723.26 5349.53 2.76 5982118.30 588690.60 N 70 21 39.397 W 149 1646.392 8448.82 69.54 61.91 4267.39 4345.45 6583.61 6608.99 6606.46 3767.23 5427.08 3.57 5982163.12 588767.65 N 70 21 39.828 W 1491644.124 8545.62 70.38 64.63 4300.56 4378.62 6674.39 6699.92 6696.50 3808.12 5508.30 2.78 5982204.91 588848.40 N 70 21 40.230 W 14916 41.748 8640.73 70.94 66.80 4332.06 4410.12 6763.68 6789.67 6784.79 3845.02 5590.09 2.23 5982242.72 588929.77 N 70 21 40.592 W 14916 39.356 8734.98 72.17 70.31 4361.89 4439.95 6852.07 6879.07 6871.89 3877.70 5673.30 3.77 5982276.32 589012.60 N 70 21 40.913 W 14916 36.922 8830.59 73.10 74.26 4390.44 4468.50 6941.21 6970.32 6959.35 3905.45 5760.21 4.06 5982305.03 589099.18 N 70 21 41.185 W 14916 34.380 8926.58 74.93 78.13 4416.88 4494.94 7029.80 7062.59 7045.92 3927.45 5849.80 4.32 5982328.02 589188.52 N 70 21 41.401 W 14916 31 9022.47 76.32 82.10 4440.69 4518.75 7116.99 7155.47 7130.86 3943.38 5941.29 4.26 5982344.97 589279.81 N 70 21 41.557 W 14916 29.085 9118.10 75.25 86.33 4464.19 4542.25 7201.52 7248.17 7212.98 3952.73 6033.49 4.43 5982355.34 589371.90 N 70 21 41.648 W 14916 26.388 9214.19 74.87 90.67 4488.97 4567.03 7283.09 7341.01 7292.09 3955.16 6126.28 4.38 5982358.81 589464.64 N 70 21 41.671 W 14916 23.675 9308.94 76.12 90.45 4512.70 4590.76 7362.08 7432.74 7368.84 3954.27 6218.00 1.34 5982358.93 589556.36 N 70 21 41.662 W 14916 20.993 9405.48 76.02 90.28 4535.94 4614.00 7442.93 7526.44 7447.75 3953.67 6311.70 0.20 5982359.38 589650.05 N 70 21 41.655 W 14916 18.253 9500.48 76.02 89.47 4558.89 4636.95 7522.86 7618.62 7526.14 3953.87 6403.88 0.83 5982360.61 589742.22 N 70 21 41.656 W 14916 15.558 9596.43 77.43 90.52 4580.93 4658.99 7603.73 7712.01 7605.76 3953.88 6497.26 1.81 5982361.65 589835.59 N 70 21 41.656 W 1491612.827 9691.50 76.98 90.15 4601.98 4680.04 7683.75 7804.72 7684.83 3953.33 6589.97 0.61 5982362.14 589928.29 N 70 21 41.649 W 14916 10.116 9786.76 77.53 88.16 4623.00 4701.06 7764.89 7897.63 7765.34 3954.71 6682.87 2.12 5982364.55 590021.15 N 70 21 41.662 W 14916 7.400 9882.67 76.79 89.58 4644.31 4722.37 7846.78 7991.14 7846.87 3956.55 6776.36 1.64 5982367.43 590114.61 N 70 21 41.679 W 14916 4.666 SurveyEditor Ver SP 2.1 Bld( doc40x_100) L-2191L-219\L-219\L-219 Generated 2/13/2008 2:41 PM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k de d k k k k k k k d 1100 k kUS kUS ~/tS.yV /y.15 tSy.tS.f 41iti4.3/ 4/4[.43 /~JLiS.OL tSU00.L, /`JLO.JL .S`JO/.U4 00/V.4/ L.4/ ,YOL300.Y0 .7yVLV0./V IY lU L141.003 YY 14y 10 I.:f 14 10074.69 81.12 90.71 4680.78 4758.84 8010.02 8179.62 8010.21 3956.59 6964.84 2.25 5982369.57 590303.06 N 70 21 41.678 W 14915 59.155 10170.14 86.75 89.55 4690.86 4768.92 8092.08 8274.50 8092.74 3956.38 7059.71 6.02 5982370.41 590397.92 N 70 21 41.675 W 1491556.381 10265.47 91.93 88.49 4691.96 4770.02 8175.40 8369.79 8176.78 3958.01 7154.99 5.55 5982373.10 590493.16 N 70 21 41.690 W 149 15 53.595 10360.97 92.99 88.14 4687.86 4765.92 8259.40 8465.20 8261.70 3960.81 7250.36 1.17 5982376.97 590588.48 N 70 21 41.717 W 14915 50.806 10457.20 89.06 87.41 4686.14 4764.20 8344.51 8561.39 8347.96 3964.55 7346.48 4.15 5982381.77 590684.55 N 70 21 41.753 W 14915 47.995 10488.59 86.49 87.53 4687.36 4765.42 8372.34 8592.76 8376.20 3965.93 7377.81 8.20 5982383.50 590715.86 N 70 21 41.766 W 14915 47.079 10520.99 86.03 87.79 4689.47 4767.53 8400.98 8625.09 8405.29 3967.25 7410.12 1.63 5982385.18 590748.15 N 70 21 41.779 W 1491546.135 10553.30 86.51 88.89 4691.57 4769.63 8429.35 8657.33 8434.16 3968.19 7442.34 3.71 5982386.48 590780.36 N 70 21 41.788 W 14915 45.192 10583.67 87.67 88.12 4693.11 4771.17 8456.01 8687.66 8461.29 3968.98 7472.66 4.58 5982387.60 590810.67 N 70 21 41.795 W 149 1544.306 10616.83 87.58 88.42 4694.49 4772.55 8485.19 8720.79 8491.02 3969.98 7505.78 0.94 5982388.97 590843.77 N 70 21 41.805 W 14915 43.337 10647.34 87.79 88.13 4695.72 4773.78 8512.03 8751.28 8518.40 3970.90 7536.25 1.17 5982390.23 590874.22 N 70 21 41.813 W 14915 42. 10678.34 88.00 88.36 4696.86 4774.92 8539.32 8782.26 8546.24 3971.85 7567.22 1.00 5982391.52 590905.17 N 70 21 ~ 41.822 W 14915 41. 10710.86 88.21 88.69 4697.93 4775.99 8567.88 8814.76 8575.42 3972.68 7599.71 1.20 5982392.72 590937.65 N 70 21 41.830 W 14915 40. 10743.14 88.64 88.00 4698.82 4776.88 8596.28 8847.03 8604.44 3973.61 7631.96 2.52 5982394.01 590969.89 N 70 21 41.839 W 14915 39.647 10774.04 88.70 88.25 4699.54 4777.60 8623.52 8877.92 8632.31 3974.62 7662.84 0.83 5982395.37 591000.75 N 70 21 41.849 W 14915 38.745 10807.09 88.21 87.63 4700.43 4778.49 8652.71 8910.96 8662.17 3975.81 7695.85 2.39 5982396.92 591033.74 N 70 21 41.860 W 14915 37.779 10838.79 86.78 87.49 4701.81 4779.87 8680.78 8942.62 8690.91 3977.16 7727.49 4.53 5982398.62 591065.36 N 70 21 41.873 W 1491536.854 10870.35 86.95 88.26 4703.54 4781.60 8708.64 8974.14 8719.46 3978.33 7758.98 2.50 5982400.14 591096.84 N 70 21 41.884 W 14915.35.933 10903.25 87.11 88.47 4705.25 4783.31 8737.55 9006.99 8749.12 3979.27 7791.83 0.80 5982401.44 591129.66 N 70 21 41.893 W 149 1534.973 10933.76 87.63 87.64 4706.65 4784.71 8764.45 9037.47 8776.73 3980.30 7822.29 3.21 5982402.81 591160.11 N 70 21 41.903 W 14915 34.082 10965.59 87.51 88.52 4707.99 4786.05 8792.51 9069.27 8805.55 3981.37 7854.07 2.79 5982404.23 591191.87 N 70 21 41.913 W 149 15 33.153 10998.48 87.91 89.18 4709.31 4787.37 8821.29 9102.14 8835.16 3982.03 7886.93 2.35 5982405.26 591224.72 N 70 21 41.919 W 14915 32.192 11029.84 88.14 88.58 4710.39 4788.45 8848.73 9133.48 8863.42 3982.64 7918.26 2.05 5982406.22 591256.04 N 70 21 41.925 W 14915 31.276 11061.78 88.51 88.94 4711.32 4789.38 8876.72 9165.40 8892.26 3983.33 7950.18 1.62 5982407.27 591287.95 N 70 21 41.931 W 14915 30.342 11093.67 88.23 87.21 4712.23 4790.29 8904.85 9197.28 8921.23 3984.40 7982.04 5.49 5982408.69 591319.79 N 70 21 41.942 W 14915 29.411 11126.07 86.81 87.06 4713.63 4791.69 8933.65 9229.65 8950.89 3986.02 8014.37 4.41 5982410.67 591352.10 N 70 21 41.957 W 14915 28.465 11158.01 87.08 85.38 4715.33 4793.39 8962.26 9261.54 8980.33 3988.12 8046.19 5.32 5982413.12 591383.89 N 70 21 41.978 W 14915 27.535 11189.43 87.34 85.93 4716.86 4794.92 8990.55 9292.93 9009.43 3990.50 8077.48 1.93 5982415.85 591415.15 N 70 21 42.001 W 14915 26.620 11220.85 88.00 85.81 4718.14 4796.20 9018.80 9324.32 9038.51 3992.76 8108.79 2.13 5982418.46 591446.43 N 70 21 42.023 W 14915 25.704 ~ 11252.74 88.35 85.15 4719.16 4797.22 9047.58 9356.19 9068.13 3995.27 8140.57 2.34 5962421.32 591478.18 N 70 21 42.047 W 14915 24 11284.76 88.43 84.69 4720.06 4798.12 9076.60 9388.20 9098.01 3998.10 8172.45 1.46 5982424.51 591510.02 N 70 21 42.074 W 14915 23.842 11316.64 88.34 84.32 4720.96 4799.02 9105.60 9420.07 9127.85 4001.16 8204.17 1.19 5982427.92 591541.70 N 70 21 42.104 W 14915 22.915 11348.66 87.78 85.41 4722.04 4800.10 9134.63 9452.07 9157.76 4004.02 8236.04 3.83 5982431.13 591573.54 N 70 21 42.132 W 14915 21.983 11380.25 88.13 86.03 4723.17 4801.23 9163.08 9483.64 9187.11 4006.38 8267.53 2.25 5982433.84 591604.99 N 70 21 42.155 W 14915 21.062 11411.81 88.32 85.83 4724.14 4802.20 9191.44 9515.18 9216.41 4008.62 8298.99 0.87 5982436.43 591636.42 N 70 21 42.176 W 14915 20.142 11443.63 87.96 84.70 4725.18 4803.24 9220.21 9546.99 9246.10 4011.24 8330.68 3.73 5982439.41 591668.08 N 70 21 42.202 W 1491519.215 11476.01 86.99 84.73 4726.60 4804.66 9249.59 9579.34 9276.42 4014.22 8362.90 3.00 5982442.74 591700.26 N 70 21 42.231 W 1491518.273 11507.44 87.30 84.85 4728.17 4$06.23 9278.09 9610.73 9305.84 4017.07 8394.16 1.06 5982445.94 591731.48 N 70 21 42.259 W 1491517.359 11538.20 87.54 85.08 4729.55 4807.61 9305.95 9641.46 9334.63 4019.77 8424.77 1.08 5982448.98 591762.06 N 70 21 42.285 W 1491516.464 11570.57 87.61 84.86 4730.92 4808.98 9335.26 9673.80 9364.93 4022.60 8456.98 0.71 5982452.17 591794.24 N 70 21 42.312 W 149 1515.522 SurveyEditor Ver SP 2.1 BId( doc40x_100) L-219\L-219\L-219\L-219 Generated 2/13/2008 2:41 PM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND VeRical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k d d k ft ft k k k k d 1100 ft kUS kUS I IWL.34 8/.31 8.11 4/3L.3J 4o IU.3`J `JJOY.UJ 7/U~.~4 yJ7'iA0 4VL.7.J0 O400AV I.GJ JaVLYJJ.JV 11633.59 86.85 84.30 4733.92 4811.98 9392.39 9736.75 9424.00 4028.26 8519.68 2.98 5982458.52 11666.80 86.85 84.01 4735.75 4813.81 9422.64 9769.90 9455.27 4031.63 8552.66 0.87 5982462.27 11698.71 86.41 85.73 4737.62 4815.68 9451.54 9801.76 9485.19 4034.48 8584.39 5.55 5982465.47 11729.14 86.77 83.06 4739.43 4817.49 9479.20 9832.14 9513.81 4037.45 8614.62 8.84 5982468.77 11762.09 86.52 82.91 4741.36 4819.42 9509.48 9865.03 9545.09 4041.47 8647.27 0.88 5982473.15 11793.99 86.28 83.58 4743.37 4821.43 9538.74 9896.87 9575.32 4045.21 8678.88 2.23 5982477.25 11825.81 86.60 83.79 4745.34 4823.40 9567.82 9928.62 9605.41 4048.71 8710.45 1.20 5982481.09 11856.50 86.65 83.77 4747.15 4825.21 9595.86 9959.26 9634.43 4052.02 8740.90 0.18 5982484.75 11889.00 85.89 87.65 4749.26 4827.32 9625.07 9991.69 9664.80 4054.45 8773.24 12.14 5982487.53 11920.27 86.57 84.07 4751.32 4829.38 9653.14 10022.89 9693.99 4056.70 8804.35 11.63 5982490.13 11953.23 86.82 84.29 4753.22 4831.28 9683.16 10055.80 9725.13 4060.04 8837.09 1.01 5982493.83 11984.06 87.27 84.36 4754.81 4832.87 9711.22 10086.59 9754.24 4063.08 8867.73 1.48 5982497.22 12016.27 87.68 84.33 4756.23 4834.29 9740.54 10118.77 9784.68 4066.26 8899.75 1.28 5982500.74 12047.59 87.84 83.58 4757.45 4835.51 9769.14 10150.06 9814.36 4069.55 8930.87 2.45 5982504.39 12079.62 88.12 83.50 4758.58 4836.64 9798.48 10182.07 9844.80 4073.15 8962.68 0.91 5982508.34 12112.13 88.56 83.55 4759.52 4837.58 9828.28 10214.57 9875.72 4076.82 8994.97 1.36 5982512.36 12143.90 88.86 83.44 4760.24 4838.30 9857.41 10246.33 9905.95 4080.42 9026.52 1.01 5982516.31 Last Survey 12175.91 89.35 83.56 4760.74 4838.80 9886.76 10278.34 9936.43 4084.04 9058.32 1.58 5982520.29 TD (Projected) 12240.00 89.35 83.56 4761.47 4839.53 9945.50 10342.42 9997.46 4091.23 9122.01 0.00 5982528.18 Survey Type: Definitive Survey NOTES: GYD CT DMS - (Gyrodata -cont. drillpipe m/s - Gyrodata pump-down multishot surveys with continuous tool (RGS-Cn in drill-pipe.) MV1ID + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (lt7 [ftUS] Easting (X) [ftUS] Surface : 2612 FSL 3530 FEL S34 T12N R11E UM 5978336.10 583383.33 BHL : 1418 FSL 4961 FEL S25 T12N R11E UM 5982528.18 592458.39 J~IYGJ.VG - 591856.86 N 70 21 42.367 W 14915 13.688 591889.80 N 70 21 42.400 W 14915 12.724 591921.49 N 70 21 42.428 W 149 1511.796 591951.68 N 70 21 42.457 W 149 1510.912 591984.28 N 70 21 42.496 W 14915 9.957 592015.85 N 70 21 42.532 W 14915 9.032 592047.37 N 70 21 42.566 W 14915 8.109 592077.78 N 70 21 42.598 W 14915 7.219 592110.09 N 70 21 42.622 W 14915 6.273 592141.17 N 70 21 42.644 W 14915 5.363 592173.87 N 70 21 42.676 W 14915 4. 592204.46 N 70 21 42.706 W 14915 3. 592236.45 N 70 21 42.737 W 14915 2. 592267.53 N 70 21 42.769 W 14915 1.663 592299.29 N 70 21 42.804 W 14915 0.733 592331.53 N 70 21 42.839 W 14914 59.789 592363.04 N 70 21 42.874 W 14914 58.866 592394.80 N 70 21 42.910 W 14914 57.936 592458.39 N 70 21 42.979 W 1491456.073 SurveyEditor Ver SP 2.1 Bld( doc40x_100) L-219\L-219\L-219\L-219 Generated 2/13/2008 2:41 PM Page 5 of 5 TREE~ 4-1/16" CMI WELLHEAD= 11" FMC ACTUATOR= NA KB. ELEV = 28.13' BF. ELEV = 26.35' KOP = 175' Max Angle = 93° @ 10361' Datum MD = 8864 Datum TV D = 4400' SS J L-219 SA OTES: WELL ANGLE> 70° @ 8259' 20" X 34" INSULATED CONDUCTOR, - 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" - 7" CSG, 26#, L-80 TC11 XO TO L-80 BTC 3-1/2" RA PIP TAG'S (2 7" X 3-1/2" HES AHR DUAL ~ 83 FEEDTHRU PKR, tD = 2.965" Minimum ID = 2.750" @ 10722' 3-112" HES XN NIPPLE 7" X 3-1 /2" HES A HR DUAL 87; FEEDTHRU PKR, ID = 2.965" 7" X 3-1/2" HES AHR SINGLE FEEDTHRU PKR, ID = 2.965" 7" X 3-1/2" HES AHR SINGLE FEEDTHRU PKR, ID = 2.965" PERFORATION SUMMARY REF LOG: SLB REALTIME LWD ON 12/31/07 ANGLE AT TOP PERF: 70° @8425' SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 Nb 8425 - 8550 O 12/31/07 4-1/2" 5 OA 8900 - 9030 O 12/31/07 4-1 /2" 5 OBa 9170 - 9215 O 12/31 /07 4-1/2" 5 OBb 9390 - 9440 O 12/31/07 4-1 /2" 2.5 OBc 9650 - 9740 O 12/31 /07 4-1/2" 5 OBd 9950 - 10550 O 12/31/07 4-1/2" 5 OBd 12000 - 1205 O 12131107 2__ J-j 4-1 /2" X 3-1 /2" XO, ID = 2.992" 1010' 9-5/8" TAM PORT COLLAR 359 3-1/2" HES X NIP, ID = 2.813" ' 8242• -{7" MARKER JOINT I 8486 3-1/2" HES X NIP, ID = 2.813" WATER INJECTION MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 8 8598 4396 71 MMG-HW-H DMY RK 0 01/16/08 7 9056 4527 76 MMG-HW-G DMY RK 0 01/16/08 6 9164 4554 75 MMG-HW-F DMY RK 0 01/16/08 5 9265 4580 76 MMG-HW-E DMY RK 0 01/16/08 4 9744 4692 77 MMG-HW-D DMY RK 0 01/16/08 3 9933 4733 78 MMG-HW-C DMY RK 0 01/16/08 2 10566 4770 87 MMG-HW-B DMY RK 0 01/16/08 1 10659 4774 88 MMG-FiVV-A DMY RK 0 01/16/08 SLt3 StLtC:l IV t LHNUINCi C:UUF'LIN(i titLUW tHC:Fi IiLM. J I HK I INIi w/ "A" PROFILE BELOW #8 THROUGH PROFILE "H" BELOW #1 8616' 3-1/2" HES X NIP, ID = 2.813" 8736 ~ PHOENUCPRESSlTEMP SENSOR SUB, ID - 2.992" 9093' 3-1/2" HES X NIP, ID = 2.813" 3-1/2" HES X NIP, ID = 2.813" 9831' ~-~3-1/2" HES X NIP, ID = 2.813" 7" X 3-1/2"AHR SINGLE" FEEDTHRU PKR, ID = 2.965 PHOENIX PRESS/ TEMP SENSOR SUB, ID - 2.992" 3-1/2" HES X NIP, ID = 2.813" 7" X 3-1/2" ARH PKR, ID = 2.965" 10701 ~ ~-~ 3-1 /2" HES X NIP, ID = 2.813" 3-1/2" HES XN NIP, ID = 2.750" 3-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" I PBTD 7" CSG, 26#, L-80 BTC, .0383 bpf, ID = 6.276" 10{ 7aa' I~ 3-112" WLEG, ID = 2.813" ELMD NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 01/18/08 N7ES ORIGINAL COMPLETION 01/21/08 ?/ PJC DRLG DRAFT CORRECTIONS ORION UNIT WELL: L-219 PERMff No: 2071480 API No: 50-029-23376-00 SEC 34, T12N, R11 E, 2612' FSL & 3530' FEL BP Exploration (Alaska} CJ gyr data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP L-Pad #L-219 P8 Prudhoe Bay, AK AK1207G_565 13 Dec 2007 ~~ ~t~~ ~ ~ Lkl~~7 f~l~t;~l~s~ ~W & ~~~ fl yy ~Q~~a !t~d11'~/Y~IAlpjp~ ~IW~E1~~~p~! Serving the Worldwide Energy Industry with Precision Survey Instrumentation ~ o ~-1~8 gyr data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 January 15, 2008 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: L-Pad, Well #L-219 P8 Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, ~F Rob Shoup North American Regional Manager RS:kI Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) Lease: L-Pad Well: L-219 P8, 4-1/2" Drillpipe Location: Nabors #7ES, Prudhoe Bay, Alaska Job Number: AK1207G 565 Run Date: 13 Dec 2007 Surveyor: James Butler Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350777 deg. N Longitude: 149.323003 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location LJ Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey BP Exploration (Alaska) Lease: L-Pad Well: L-219 P8, 4-1/2" Drillpipe Location: Nabors #7ES, Prudhoe Bay, Alaska Job Number: AK1207G 565 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. • 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 - 0.00 N 0.00E ----------------------------------------------------------------------------------------------------- 0 - 1000 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 4-1/2" ----------------- DRILLPIPE ------- --- ------------------ --------------- ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #7ES R.K.B. ---------------------------------------------------------------------------------------------------------------------- ----------- ------------------ --------------- 85.00 0.13 292.72 N 67 17 W 0.15 85.00 0.1 292.7 0.04 N 0.09W 175.00 1.10 38.63 N 38 38 E 1.27 174.99 0.8 25.6 0.75 N 0.36 E 264.00 2.24 43.00 N 43 0 E 1.29 263.96 3.4 37.7 2.69 N 2.08 E 355.00 2.75 47.33 N 47 20 E 0.60 354.87 7.3 41.8 5.47 N 4.90 E 445.00 3.67 44.61 N 44 37 E 1.03 444.73 12.4 43.4 8.98 N 8.50 E 540.00 5.31 48.21 N 48 13 E 1.76 539.43 19.8 44.7 14.07 N 13.92 E 628.00 7.53 50.29 N 50 18 E 2.54 626.88 29.6 46.3 20.47 N 21.39E 719.00 9.93 52.63 N 52 38 E 2.67 716.81 43.4 48.0 29.04 N 32.22 E 815.00 12.82 55.39 N 55 23 E 3.06 810.92 62.2 49.9 40.12 N 47.57 E 900.00 15.79 55.80 N 55 48 E 3.49 893.27 83.2 51.3 51.98 N 64.90 E 1000.00 19.78 58.60 N 58 36 E 4.08 988.48 113.6 52.9 68.46 N 90.61 E Final Station Closure: Distance: 113.56 ft Az: 52.93 deg. BP Exploration (Alaska) Well: L-Pad L-219 P8 4-1/2" Drillpipe Location: Nabors #7ES, Prudhoe Bay, Alaska 70 60 50 X40 z O z 30 20- 10- 0- Inrun Gyrodata AK1207G 565 DEFINITIVE i, j ~ - ~ 1- ~ BOTTOM HA 'LOCATED MD: 1000.0 LE -- ~ i I - -- -- j i ---- ---- - I - --- -- r I __ --- - i i ~ I j I ~ ~ I I I i ~ i ~ ~ I ~ ~ ~ ~ i i i ~ ~ i i I ~ -1 i -- i • i i 0 10 20 30 40 50 60 70 80 90 FASTING (ff:) BP Exploration (Alaska) Well: L-Pad L-219 P8 4-1/2" Drill pipe Location: Nabors #7ES, Prudhoe Bay, Alaska 12 11 10 9 w o g- 0 ~ 7- ~ 6- w ~ 5- O 4 3- 2- 1- o- Inrun Gyrodata _ AK1207G_565 DEFINITIVE - -- - - ! ~ I ~ ~ ~ ~ ~ - ~ i ~ I i ------ ~ I -- -- - I -1 ~ - ~ ---- i ~- -- I -- --- - ~------ ----------- --------- ------- ~ ------ ---- r ~~ - _ ___ -~ i ---- - ~ I L -j --- ----~ ~ ---- __-~ ~ ------- j __--- _ ----- fi-----------~ --------- i ---- ~ I i~ ----..__ -_- ------ - ~ --- -- ------ ~ I ------ -- + ._---- ~ --- - - --- ~ ~ - - I - ----- E -------- --- _ I _------ i ~ OTTOM HO E --+ -- L CATED '-X008 i --- ~~ I i i I 100 200 300 400 500 600 700 800 900 1000 1100 MEASURED DEPTH (ft) • • BP Exploration (Alaska) _ Well: L-Pad L-219 P8 4-1/2" Drillpipe Location: Nabors #7ES, Prudhoe Bay, Alaska 62 60 58 .-. a~ ~ 56- w W H 54- 52- 50- Inrun Gyrodata AK1207G 565 DEFINITIVE I I i ~ ~ ~~ -- --- -- .._ _ i --~ __. ___- - --.._ ----- ~ i -- -- B ~ L - --- TOM HO CATED --- E --- _ 1- ----- -- - I -- -- i -------. _. _- ~ +---- ------- - __ }-- - i - - I ~------- - ------- D: 1000.0 ------- , ! -- _ I ~ --~ - --._ ~ ~ ; - --- -- - _ ___- ------ - --- I ~ ~ i -- ~ 1 ~ - ~ ~ I ~ - i ~ ------ _ ~ _ i ~ ~ ~ ~ I ~ ~ I i i --- ~ ~ ~ ~ 'I ~ ~ i ~ ~~ i ~ I i i ~ i i I ~ ~ ~ j ~ i • ~ ~ , ~ i i i i 100 200 300 400 500 600 700 800 900 1000 1100 MEASURED DEPTH (ft) BP Exploration (Alaska) _ Well: L-Pad L-219 P8 4-1/2" Drillpipe Location: Nabors #7ES, Prudhoe Bay, Alaska 20 18 16 14 z12 O Q X10 U Z 8 6 4 2 0- Inrun Gyrodata _ AK1207G 565 DEFINITIVE - I---- - j ~ ~ -- -- - -- - ---- OTTOM H E ~ID: 1000. - - -- LE 00 _._------ ----- --- ' _ _ __ ____-______ ~ .________ j T_.___- ~ i __-_ _-_ j I i I I ~ --~ - --- I I - _ ------ -- - ~ i I ~ - I ~ -- - - - ~ ~ -- ------ -- ~ - -- -i - - -- I ---- - - i i • 100 200 300 400 500 600 700 800 900 1000 1100 MEASURED DEPTH (ft) BP Exploration (Alaska) _ Well: L-Pad L-219 P8 4-1/2" Drillpipe Location: Nabors #7ES, Prudhoe Bay, Alaska 300 250 200 N Q 150 100 50 Inrun - Gyrodata _ AK1207G 565 DEFINITIVE ~ ' ----- ~ - T--- - -- - - T-- - - ---- {- -- ~ i I ~ I i ~ I I -- ~ ~ --- - - ~ ~ ~ ~' - ,I i - i Ii I ---- r-- --- I -- _ i ~ I i i l ~ i ~ i i i , ~ i BOTTOM LOCATE MD: 100 - -r i i HOLE .00 --- ~ C~ 100 200 300 400 500 600 700 800 900 1000 1100 MEASURED DEPTH (ft) ~~ V ~~ 1 ^~ t SCHLUMBERGER Survey report Client ...................: BP Field ....................: Orion Well .....................: L-2191 API number ...............: 50-029-23376-00 Engineer .................: Edward Galotta Rig :.....................: 7ES STATE :...................: AK ----- Survey calculation methods- ------ Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: ---------------- Mean Sea Level Drill Pipe Tally 49.00 ft N/A 78.1 ft ----- Vertical section origin----------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft Azimuth from Vsect Origin to target [(c)2007 IDEAL ID12_OC_13] 64.95 degrees 21-Dec-2007 15:37:06 Page 1 of 7 Spud date ................: 11-Dec-07 Last survey date.........: 21-Dec-07 Total accepted surveys...: 166 MD of first survey.......: 0.00 ft MD of last survey........: 12240.00 ft ----- Geomagnetic data ---------------- Magnetic model...........: BGGM version 2007 Magnetic date ............: 11-Dec-2007 Magnetic field strength..: 57639.31 LAMA Magnetic dec (+E/W-).....: 23.18 degrees Magnetic dip .............: 80.88 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............: Tolerance of G............ Tolerance of H...........: Tolerance of Dip.........: Criteria - --- 1002.68 meal 57639.50 GAMA 80.88 degrees (+/-) 2.50 meal (+/-)300.00 LAMA (+/-) 0.45 degrees ----- Corrections ------ ----------- Magnetic dec (+E/W-).....: 23.18 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.18 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 2 108.00 0.00 0.00 108.00 3 175.00 1.10 38.53 67.00 4 264.00 2.24 43.00 89.00 5 355.00 2.64 49.74 91.00 6 445.00 3.67 44.61 90.00 7 534.14 5.31 48.21 89.14 8 625.38 7.53 50.29 91.24 9 715.74 9.93 52.63 90.36 10 815.59 12.82 55.39 99.85 11 928.78 16.57 57.31 113.19 12 1025.33 20.85 57.14 96.55 13 1120.79 24.16 53.03 95.46 14 1216.42 28.21 52.11 95.63 15 1311.50 31.12 52.99 95.08 16 1406.81 34.88 53.71 95.31 17 1502.92 37.60 52.78 96.11 18 1596.80 40.21 53.82 93.88 19 1691.42 41.57 54.82 94.62 20 1789.20 44.94 54.89 97.78 21 1884.30 49.96 53.91 95.10 22 1980.04 50.20 53.79 95.74 23 2076.07 52.10 53.79 96.03 24 2171.73 54.84 53.33 95.66 25 2266.90 57.11 53.00 95.17 26 2362.56 59.34 53.16 95.66 27 2457.71 62.00 53.72 95.15 28 2553.75 64.24 54.20 96.04 29 2647.80 65.05 54.49 94.05 30 2744.85 64.33 54.25 97.05 21-Dec-2007 15:37:06 Page 2 of 7 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 108.00 0.00 0.00 0.00 0.00 0.00 0.00 BP _CB GYRO SS 175.00 0.58 0.50 0.40 0.64 38.53 1.64 BP _CB GYRO SS 263.96 2.95 2.44 2.12 3.23 40.93 1.29 BP _CB GYRO SS 354.87 6.63 5.10 4.93 7.09 44.04 0.54 BP _CB GYRO SS 444.74 11.33 8.49 8.54 12.04 45.16 1.19 BP _CB GYRO SS 533.60 17.95 13.27 13.62 19.01 45.74 1.87 BP _CB GYRO SS 624.26 27.78 19.90 21.36 29.20 47.03 2.45 BP _CB GYRO SS 713.57 41.12 28.42 32.11 42.88 48.49 2.68 BP _CB GYRO SS 811.45 60.46 39.94 48.07 62.50 50.28 2.94 BP _CB GYRO SS 920.92 88.85 55.79 72.00 91.09 52.23 3.34 BP _MWD+IFR+MS 1012.34 119.53 72.56 98.03 121.96 53.49 4.43 BP _MWD+IFR+MS 1100.53 155.49 93.53 127.92 158.47 53.83 3.84 BP _MWD+IFR+MS 1186.33 196.69 119.19 161.41 200.65 53.56 4.26 BP _MWD+IFR+MS 1268.94 242.65 147.79 198.77 247.69 53.37 3.09 BP _MWD+IFR+MS 1348.86 293.49 178.76 240.42 299.59 53.37 3.97 BP _MWD+IFR+MS 1426.37 349.12 212.76 285.93 356.40 53.35 2.89 BP _MWD+IFR+MS 1499.42 406.86 247.98 333.20 415.36 53.34 2.87 BP _MWD+IFR+MS 1570.95 467.74 284.10 383.52 477.28 53.47 1.60 BP _MWD+IFR+MS 1642.15 533.69 322.67 438.30 544.26 53.64 3.45 BP _MWD+IFR+MS 1706.44 602.54 363.45 495.23 614.29 53.72 5.33 BP _MWD+IFR+MS 1767.88 674.59 406.77 554.52 687.72 53.74 0.27 BP _MWD+IFR+MS 1828.11 747.96 450.95 614.86 762.50 53.74 1.98 BP _MWD+IFR+MS 1885.05 823.31 496.60 676.69 839.36 53.73 2.89 BP _MWD+IFR+MS 1938.30 900.51 543.89 739.81 918.23 53.68 2.40 BP _MWD+IFR+MS 1988.67 980.09 592.74 804.83 999.54 53.63 2.34 BP _MWD+IFR+MS 2035.27 1061.37 642.14 871.45 1082.49 53.61 2.84 BP _MWD+IFR+MS 2078.69 1145.46 692.53 940.72 1168.14 53.64 2.37 BP _MWD+IFR+MS 2118.97 1229.00 742.07 1009.78 1253.13 53.69 0.91 BP _MWD+IFR+MS 2160.46 1315.24 793.18 1081.09 1340.85 53.73 0.77 BP MWD+IFR+MS • [(c)2007 IDEAL ID12_OC_13] SCHLUMBERGER Survey Report 21-Dec-2007 15:37:06 Page 3 of 7 --- 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 Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2840.32 65.37 54.08 95.47 2201.03 1400.13 843.78 1151.15 1427.27 53.76 1.10 BP _MWD+IFR+MS 32 2935.89 67.37 54.10 95.57 2239.33 1486.11 895.13 1222.06 1514.82 53.78 2.09 BP _MWD+IFR+MS 33 3031.74 66.62 54.00 95.85 2276.79 1572.75 946.92 1293.48 1603.04 53.79 0.79 BP _MWD+IFR+MS 34 3127.01 67.01 54.01 95.27 2314.30 1658.73 998.39 1364.33 1690.62 53.80 0.41 BP _MWD+IFR+MS 35 3222.41 66.71 54.16 95.40 2351.79 1744.88 1049.85 1435.38 1778.34 53.82 0.35 BP MWD+IFR+MS 36 3317.57 66.40 53.92 95.16 2389.65 1830.61 1101.12 1506.05 1865.65 53.83 0.40 BP _MWD+IFR+MS 37 3413.61 66.99 54.48 96.04 2427.65 1917.27 1152.71 1577.59 1953.85 53.85 0.81 BP _MWD+IFR+MS • 38 3508.54 66.74 54.89 94.93 2464.95 2003.16 1203.17 1648.82 2041.14 53.88 0.48 BP _MWD+IFR+MS 39 3604.20 67.31 54.64 95.66 2502.29 2089.85 1253.99 1720.75 2129.20 53.92 0.64 BP _MWD+IFR+MS 40 3699.53 66.96 54.73 95.33 2539.33 2176.28 1304.76 1792.43 2217.03 53.95 0.38 BP MWD+IFR+MS 41 3795.75 66.68 54.33 96.22 2577.20 2263.27 1356.09 1864.47 2305.48 53.97 0.48 BP _MWD+IFR+MS 42 3891.17 66.49 54.98 95.42 2615.12 2349.43 1406.74 1935.89 2393.03 54.00 0.66 BP _MWD+IFR+MS 43 3987.02 67.74 55.11 95.85 2652.39 2436.41 1457.34 2008.26 2481.32 54.03 1.31 BP _MWD+IFR+MS 44 4081.68 68.78 54.80 94.66 2687.46 2523.00 1507.83 2080.25 2569.24 54.06 1.14 BP _MWD+IFR+MS 45 4177.70 67.17 54.88 96.02 2723.46 2610.63 1559.08 2153.02 2658.24 54.09 1.68 BP MWD+IFR+MS 46 4273.36 66.56 54.86 95.66 2761.05 2697.24 1609.70 2224.96 2746.20 54.12 0.64 BP _MWD+IFR+MS 47 4368.13 67.35 54.81 94.77 2798.15 2783.09 1659.93 2296.25 2833.40 54.14 0.84 BP _MWD+IFR+MS 48 4454.19 67.33 54.64 86.06 2831.30 2861.25 1705.79 2361.09 2912.81 54.15 0.18 BP _MWD+IFR+MS 49 4531.10 66.63 54.10 76.91 2861.38 2930.83 1747.03 2418.62 2983.59 54.16 1.12 BP _MWD+IFR+MS 50 4625.71 67.21 54.30 94.61 2898.47 3016.34 1797.94 2489.21 3070.63 54.16 0.64 BP MWD+IFR+MS 51 4721.49 67.01 53.86 95.78 2935.72 3102.99 1849.70 2560.67 3158.87 54.16 0.47 BP _MWD+IFR+MS 52 4816.77 66.33 53.83 95.28 2973.45 3188.84 1901.32 2631.31 3246.35 54.15 0.71 BP _MWD+IFR+MS 53 4912.75 66.26 54.91 95.98 3012.04 3275.23 1952.51 2702.74 3334.23 54.15 1.03 BP _MWD+IFR+MS 54 5008.43 67.01 56.02 95.68 3049.99 3361.86 2002.30 2775.10 3422.04 54.19 1.32 BP _MWD+IFR+MS 55 5103.76 67.37 56.02 95.33 3086.95 3448.67 2051.42 2847.96 3509.87 54.23 0.38 BP MWD+IFR+MS 56 5199.30 67.20 56.40 95.54 3123.84 3535.78 2100.43 2921.21 3597.95 54.28 0.41 BP _MWD+IFR+MS 57 5294.97 66.84 56.35 95.67 3161.19 3622.87 2149.20 2994.55 3685.97 54.33 0.38 BP _MWD+IFR+MS 58 5389.93 66.50 57.11 94.96 3198.80 3709.17 2197.04 3067.45 3773.09 54.39 0.82 BP _MWD+IFR+MS 59 5485.42 67.75 57.65 95.49 3235.91 3796.38 2244.46 3141.55 3860.95 54.46 1.41 BP _MWD+IFR+MS 60 5580.16 67.84 57.10 94.74 3271.72 3883.33 2291.75 3215.43 3948.56 54.52 0.55 BP MWD+IFR+MS [(c)2007 IDEAL ID12_OC_13] SCHLUMBERGER Survey Report 21-Dec-2007 15:37:06 Page 4 of 7 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 Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5676.50 67.35 57.06 96.34 3308.44 3971.56 2340.16 3290.19 4037.54 54.58 0.51 BP _MWD+IFR+MS 62 5771.87 66.46 56.69 95.37 3345.85 4058.41 2388.10 3363.66 4125.19 54.63 1.00 BP _MWD+IFR+MS 63 5867.58 67.83 56.39 95.71 3383.02 4145.66 2436.72 3437.24 4213.34 54.67 1.46 BP _MWD+IFR+MS 64 5963.03 69.13 57.36 95.45 3418.03 4233.57 2485.24 3511.60 4302.07 54.71 1.66 BP _MWD+IFR+MS 65 6058.64 68.94 57.23 95.61 3452.24 4322.05 2533.48 3586.73 4391.26 54.76 0.24 BP _MWD+IFR+MS 66 6154.05 69.30 57.94 95.41 3486.25 4410.46 2581.27 3661.98 4480.30 54.82 0.79 BP _MWD+IFR+MS 67 6249.79 68.86 57.00 95.74 3520.43 4499.13 2629.35 3737.38 4569.63 54.87 1.03 BP _MWD+IFR+MS • 68 6345.32 67.63 57.04 95.53 3555.84 4587.01 2677.65 3811.81 4658.29 54.91 1.29 BP _MWD+IFR+MS 69 6441.09 66.58 57.50 95.77 3593.10 4674.44 2725.35 3886.02 4746.44 54.96 1.18 BP _MWD+IFR+MS 70 6536.64 68.52 57.03 95.55 3629.59 4761.95 2773.11 3960.30 4834.68 55.00 2.08 BP _MWD+IFR+MS 71 6631.98 68.54 57.12 95.34 3664.48 4849.84 2821.33 4034.77 4923.34 55.04 0.09 BP _MWD+IFR+MS 72 6727.25 69.01 57.37 95.27 3698.97 4937.84 2869.38 4109.46 5012.09 55.08 0.55 BP _MWD 73 6824.36 68.84 56.24 97.11 3733.89 5027.54 2918.99 4185.29 5102.66 55.11 1.10 BP _MWD+IFR+MS 74 6919.65 67.91 55.98 95.29 3769.01 5115.07 2968.38 4258.82 5191.23 55.12 1.01 BP _MWD+IFR+MS 75 7015,23 66.51 54.24 95.58 3806.04 5201.89 3018.78 4331.10 5279.34 55.12 2.23 BP _MWD+IFR+MS 76 7110.16 66.16 54.71 94.93 3844.14 5287.38 3069.30 4401.86 5366.28 55.11 0.58 BP _MWD+IFR+MS 77 7206,58 65.73 54.22 96.42 3883.44 5373.96 3120.47 4473.51 5454.32 55.10 0.64 BP _MWD+IFR+MS 78 7303.30 66.02 54.55 96.72 3922.97 5460.73 3171.87 4545.27 5542.58 55.09 0.43 BP _MWD+IFR+MS 79 7397.61 66.46 54.71 94.31 3960.97 5545.65 3221.84 4615.65 5628.90 55.08 0.49 BP _MWD+IFR+MS 80 7493.98 67.93 54.93 96.37 3998.32 5633.10 3273.02 4688.26 5717.73 55.08 1.54 BP _MWD+IFR+MS 81 7589.86 67.61 55.05 95.88 4034.60 5720.52 3323.94 4760.96 5806.48 55.08 0.35 BP _MWD+IFR+MS 82 7685.55 67.91 54.92 95.69 4070.81 5807.75 3374.76 4833.50 5895.06 55.08 0.34 BP _MWD+IFR+MS 83 7779.82 68.29 54.81 94.27 4105.98 5893.87 3425.10 4905.03 5982.52 55.07 0.42 BP _MWD+IFR+MS 84 7877.26 67.25 54.84 97.44 4142.84 5982.66 3477.06 4978.75 6072.72 55.07 1.07 BP _MWD+IFR+MS 85 7971.89 68.04 55.61 94.63 4178.83 6068.92 3526.97 5050.64 6160.23 55.07 1.12 BP MWD+IFR+MS 86 8067.86 67.94 56.34 95.97 4214.80 6156.81 3576.76 5124.38 6249.20 55.09 0.71 BP _MWD+IFR+MS 87 8164.30 69.26 56.59 96.44 4249.99 6245.61 3626.36 5199.22 6338.96 55.10 1.39 BP _MWD+IFR+MS 88 8259.10 70.27 56.57 94.80 4282.77 6333.61 3675.35 5273.47 6427.88 55.13 1.07 BP _MWD+IFR+MS 89 8354.25 71.52 59.01 95.15 4313.92 6422.81 3723.26 5349.53 6517.68 55.16 2.76 BP _MWD+IFR+MS 90 8448.82 69.54 61.91 94.57 4345.45 6511.68 3767.23 5427.08 6606.45 55.23 3.57 BP _MWD+IFR+MS [(c)2007 IDEAL ID12_OC_13] SCHLUMBERGER Survey Report 21-Dec-2007 15:37:06 Page 5 of 7 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 Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) ------- (ft) - -------- (ft) -------- (ft) -------- (ft) -------- (deg) ------- 100f) ----- - type (deg) ---- ------ --- 91 -------- 8545.62 ------ 70.38 ------- 64.63 ------ 96.80 ------- 4378.62 - -------- 6602.57 -------- 3808.12 -------- 5508.30 -------- 6696.50 ------- 55.34 ----- 2.78 - BP ---- ------ _MWD+IFR+MS 92 8640.73 70.94 66.80 95.11 4410.12 6692.30 3845.02 5590.10 6784.79 55.48 2.23 BP _MWD+IFR+MS 93 8734.98 72.17 70.31 94.25 4439.95 6781.51 3877.70 5673.30 6871.89 55.65 3.77 BP _MWD+IFR+MS 94 8830.59 73.10 74.26 95.61 4468.50 6871.99 3905.45 5760.21 6959.35 55.86 4.06 BP _MWD+IFR+MS 95 8926.58 74.93 78.13 95.99 4494.94 6962.48 3927.45 5849.80 7045.92 56.12 4.32 BP _MWD+IFR+MS 96 9022.47 76.32 82.10 95.89 4518.75 7052.10 3943.38 5941.29 7130.86 56.43 4.26 BP _MWD+IFR+MS 97 9118.10 75.25 86.33 95.63 4542.25 7139.59 3952.73 6033.49 7212.98 56.77 4.43 BP _MWD+IFR+MS 98 9214.19 74.87 90.67 96.09 4567.03 7224.68 3955.16 6126.28 7292.09 57.15 4.38 BP _MWD+IFR+MS 99 9308.94 76.12 90.45 94.75 4590.76 7307.40 3954.27 6218.00 7368.83 57.55 1.34 BP _MWD+IFR+MS 100 9405.48 76.02 90.28 96.54 4614.00 7392.03 3953.67 6311.70 7447.75 57.94 0.20 BP MWD+IFR+MS 101 9500.48 76.02 89.47 95.00 4636.95 7475.63 3953.87 6403.88 7526.14 58.31 0.83 BP _MWD+IFR+MS 102 9596.43 77.43 90.52 95.95 4658.99 7560.23 3953.88 6497.26 7605.76 58.68 1.81 BP _MWD+IFR+MS 103 9691.50 76.98 90.15 95.07 4680.04 7643.99 3953.33 6589.97 7684.83 59.04 0.61 BP _MWD+IFR+MS 104 9786.76 77.53 88.16 95.26 4701.06 7728.73 3954.71 6682.87 7765.33 59.38 2.12 BP _MWD+IFR+MS 105 9882.67 76.79 89.58 95.91 4722.37 7814.20 3956.55 6776.36 7846.87 59.72 1.64 BP _MWD+IFR+MS 106 9978.90 79.15 89.83 96.23 4742.43 7899.67 3957.03 6870.47 7928.52 60.06 2.47 BP _MWD+IFR+MS 107 10074.69 81.12 90.71 95.79 4758.84 7984.97 3956.59 6964.84 8010.21 60.40 2.25 BP _MWD+IFR+MS 108 10170.14 86.75 89.55 95.45 4768.92 8070.83 3956.38 7059.71 8092.74 60.73 6.02 BP _MWD+IFR+MS 109 10265.47 91.93 88.49 95.33 4770.02 8157.83 3958.01 7154.99 8176.78 61.05 5.55 BP _MWD+IFR+MS 110 10360.97 92.99 88.14 95.50 4765.92 8245.42 3960.81 7250.36 8261.70 61.35 1.17 BP _MWD+IFR+MS 111 10457.20 89.06 87.41 96.23 4764.20 8334.08 3964.55 7346.48 8347.96 61.65 4.15 BP _MWD+IFR+MS • 112 10488.59 86.49 87.53 31.39 4765.42 8363.06 3965.93 7377.81 8376.20 61.74 8.20 BP _MWD+IFR+MS 113 10520.99 86.03 87.79 32.40 4767.53 8392.88 3967.25 7410.12 8405.29 61.84 1.63 BP _MWD+IFR+MS 114 10553.30 86.51 88.89 32.31 4769.63 8422.47 3968.19 7442.34 8434.16 61.93 3.71 BP _MWD+IFR+MS 115 10583.67 87.67 88.12 30.37 4771.17 8450.28 3968.98 7472.66 8461.29 62.03 4.58 BP _MWD+IFR+MS 116 10616.83 87.58 88.42 33.16 4772.55 8480.70 3969.98 7505.78 8491.02 62.12 0.94 BP _MWD+IFR+MS 117 10647.34 87.79 88.13 30.51 4773.78 8508.69 3970.90 7536.25 8518.40 62.21 1.17 BP _MWD+IFR+MS 118 10678.34 88.00 88.36 31.00 4774.92 8537.15 3971.84 7567.21 8546.24 62.31 1.00 BP _MWD+IFR+MS 119 10710.86 88.21 88.69 32.52 4775.99 8566.94 3972.68 7599.71 8575.42 62.40 1.20 BP _MWD+IFR+MS 120 10743.14 88.64 88.00 32.28 4776.88 8596.55 3973.61 7631.96 8604.44 62.50 2.52 BP _MWD+IFR+MS [(c)2007 IDEAL ID12_OC_13] SCHLUMBERGER Survey Report 21-Dec-2007 15:37:06 Page 6 of 7 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 Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 10774.04 88.70 88.25 30.90 4777.60 8624.95 3974.62 7662.84 8632.30 62.58 0.83 BP _MWD+IFR+MS 122 10807.09 88.21 87.63 33.05 4778.49 8655.36 3975.81 7695.85 8662.17 62.68 2.39 BP _MWD+IFR+MS 123 10838.79 86.78 87.49 31.70 4779.88 8684.60 3977.16 7727.49 8690.91 62.77 4.53 BP _MWD+IFR+MS 124 10870.35 86.95 88.26 31.56 4781.60 8713.62 3978.33 7758.98 8719.46 62.85 2.50 BP _MWD+IFR+MS 125 10903.25 87.11 88.47 32.90 4783.31 8743.77 3979.27 7791.82 8749.12 62.95 0.80 BP MWD+IFR+MS 126 10933.76 87.63 87.64 30.51 4784.71 8771.80 3980.30 7822.28 8776.73 63.03 3.21 BP _MWD+IFR+MS 127 10965.59 87.51 88.52 31.83 4786.06 8801.05 3981.37 7854.07 8805.55 63.12 2.79 BP _MWD+IFR+MS • 128 10998.48 87.91 89.18 32.89 4787.37 8831.10 3982.03 7886.92 8835.16 63.21 2.35 BP _MWD+IFR+MS 129 11029.84 88.14 88.58 31.36 4788.45 8859.74 3982.64 7918.26 8863.42 63.30 2.05 BP _MWD+IFR+MS 130 11061.78 88.51 88.94 31.94 4789.38 8888.95 3983.33 7950.18 8892.26 63.39 1.62 BP _MWD+IFR+MS 131 11093.67 88.23 87.21 31.89 4790.29 8918.27 3984.40 7982.04 8921.23 63.47 5.49 BP _MWD+IFR+MS 132 11126.07 86.81 87.06 32.40 4791.69 8948.24 3986.02 8014.36 8950.89 63.56 4.41 BP _MWD+IFR+MS 133 11158.01 87.08 85.38 31.94 4793.40 8977.96 3988.12 8046.19 8980.33 63.63 5.32 BP _MWD+IFR+MS 134 11189.43 87.34 85.93 31.42 4794.92 9007.31 3990.50 8077.48 9009.43 63.71 1.93 BP _MWD+IFR+MS 135 11220.85 88.00 85.81 31.42 4796.20 9036.64 3992.76 8108.79 9038.51 63.78 2.13 BP MWD+IFR+MS 136 11252.74 88.35 85.15 31.89 4797.22 9066.49 3995.27 8140.57 9068.13 63.86 2.34 BP _MWD+IFR+MS 137 11284.76 88.43 84.69 32.02 4798.12 9096.57 3998.10 8172.45 9098.01 63.93 1.46 BP _MWD+IFR+MS 138 11316.64 88.34 84.32 31.88 4799.02 9126.60 4001.16 8204.17 9127.85 64.00 1.19 BP _MWD+IFR+MS 139 11348.66 87.78 85.41 32.02 4800.10 9156.69 4004.02 8236.04 9157.76 64.07 3.83 BP _MWD+IFR+MS 140 11380.25 88.13 86.03 31.59 4801.23 9186.21 4006.38 8267.52 9187.11 64.15 2.25 BP MWD+IFR+MS 141 11411.81 88.32 85.83 31.56 4802.20 9215.66 4008.62 8298.99 9216.41 64.22 0.87 BP _MWD+IFR+MS • 142 11443.63 87.96 84.70 31.82 4803.24 9245.48 4011.24 8330.68 9246.10 64.29 3.73 BP _MWD+IFR+MS 143 11476.01 86.99 84.73 32.38 4804.66 9275.93 4014.22 8362.89 9276.42 64.36 3.00 BP _MWD+IFR+MS 144 11507.44 87.30 84.85 31.43 4806.23 9305.45 4017.07 8394.16 9305.84 64.43 1.06 BP _MWD+IFR+MS 145 11538.20 87.54 85.08 30.76 4807.61 9334.33 4019.77 8424.77 9334.63 64.49 1.08 BP MWD+IFR+MS 146 11570.57 87.61 84.86 32.37 4808.98 9364.71 4022.60 8456.98 9364.93 64.56 0.71 BP _MWD+IFR+MS 147 11602.34 87.31 85.11 31.77 4810.39 9394.53 4025.38 8488.60 9394.68 64.63 1.23 BP _MWD+IFR+MS 148 11633.59 86.85 84.30 31.25 4811.98 9423.91 4028.26 8519.68 9424.00 64.69 2.98 BP _MWD+IFR+MS 149 11666.80 86.85 84.01 33.21 4813.81 9455.22 4031.63 8552.66 9455.27 64.76 0.87 BP _MWD+IFR+MS 150 11698.71 86.41 85.73 31.91 4815.68 9485.17 4034.48 8584.39 9485.19 64.83 5.55 BP MWD+IFR+MS [(c)2007 IDEAL ID12_OC_13] SCHLUMBERGER Survey Report 21-Dec-2007 15:37:06 Page 7 of 7 --- 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 Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) -------- (deg) ------- 100f) ----- - type (deg) ---- ------ 151 11729.14 86.77 83.06 30.43 4817.49 9513.81 4037.45 8614.62 9513.81 64.89 8.84 BP _MWD+IFR+MS 152 11762.09 86.52 82.91 32.95 4819.42 9545.09 4041.47 8647.27 9545.09 64.95 0.88 BP _MWD+IFR+MS 153 11793.99 86.28 83.58 31.90 4821.42 9575.31 4045.21 8678.88 9575.32 65.01 2.23 BP _MWD+IFR+MS 154 11825.81 86.60 83.79 31.82 4823.40 9605.39 4048.70 8710.45 9605.41 65.07 1.20 BP _MWD+IFR+MS 155 11856.50 86.65 83.77 30.69 4825.21 9634.39 4052.02 8740.90 9634.43 65.13 0.18 BP MWD+IFR+MS 156 11889.00 85.89 87.65 32.50 4827.32 9664.71 4054.45 8773.24 9664.80 65.20 12.14 BP _MWD+IFR+MS 157 11920.27 86.57 84.07 31.27 4829.38 9693.85 4056.70 8804.35 9693.99 65.26 11.63 BP • _MWD+IFR+MS 158 11953.23 86.82 84.29 32.96 4831.28 9724.92 4060.04 8837.09 9725.13 65.32 1.01 BP _MWD+IFR+MS 159 11984.06 87.27 84.36 30.83 4832.87 9753.96 4063.08 8867.73 9754.24 65.38 1.48 BP _MWD+IFR+MS 160 12016.27 87.68 84.33 32.21 4834.29 9784.32 4066.25 8899.75 9784.68 65.44 1.28 BP _MWD+IFR+MS 161 12047.59 87.84 83.58 31.32 4835.51 9813.91 4069.55 8930.87 9814.36 65.50 2.45 BP _MWD+IFR+MS 162 12079.62 88.12 83.50 32.03 4836.64 9844.25 4073.15 8962.68 9844.80 65.56 0.91 BP _MWD+IFR+MS 163 12112.13 88.56 83.55 32.51 4837.58 9875.05 4076.82 8994.97 9875.72 65.62 1.36 BP _MWD+IFR+MS 164 12143.90 88.86 83.44 31.77 4838.30 9905.16 4080.42 9026.52 9905.95 65.67 1.01 BP _MWD+IFR+MS 165 12175.91 89.35 83.56 32.01 4838.80 9935.50 4084.04 9058.32 9936.43 65.73 1.58 BP MWD+IFR+MS 166 12240.00 89.35 83.56 64.09 4839.52 9996.24 4091.23 9122.01 9997.46 65.84 0.00 Pr ojected_TD [(c)2007 IDEAL ID12_OC_13] a~.t1~-(`'~8 01 /18/08 i u N0. 4560 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis WP_II .Inh $ Inn rlaccrin4inn Ih4n RI Cnlnr Cr1 L-219 11986240 MDT ~- l~- 12/22/07 1 L-114A 11970807 LDL = 12/30/07 1 L-116 11962777 LDL (" ( 12/31/07 1 V-211 12021135 MEM INJECTION PROFILE QC{~- a~ 12/29107 1 V-216 12021136 MEM INJECTION PROFILE U 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL L, 01102/08 1 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F-32 11970707 LDL ~} - 01/04/08 1 15-046 12005202 MEM CEMENT BOND LOG - 12/28/07 1 G-31A 11962778 SCMT j - C 01/01108 1 S-26 11978425 USIT 12/29/07 1 02-16C 11628793 MCNL ~- ~ 08/28/07 1 1 G-04B 11628765 MCNL - ~ *t 04/06/07 1 1 K-02D 11209613 MCNL d~ c, 07/21/06 1 1 17-076 11649940 MCNL - ~- / 02/17/07 1 1 L2-28 11975742 RST = 12/05107 1 1 Z-06 11968821 RST ~ - 12/13!07 1 1 YLtASt AGIINUWLtUGt KtGtlf' I tiY SIGNING ANU KETUKNING UNt GUPY EACH TU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 _, ~ 900 E. Benson Blvd. _' `' Anchorage, Alaska 99508 Date Delivered: ~1~?~~g` 'j, ~'. ~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: ~~ L-2191 (207-14$) Permit changesrequest • Page 1 of 2 Maunder, Thomas E (DOA) From: Coolidge, Robert B [Robert.Coolidge@bp.comJ Sent: Friday, December 21, 2007 10:24 AM To: Maunder, Thomas E (DOA) Cc: Saltmarsh, Arthur C (DOA); NSU, ADW Drtg Rig 7 ES; Bemaski, Greg E; West, Taylor; Hobbs, Greg S (ANC}; Tirpack, Robert B; Schultz, Mike{ Subject: L-219i (207-148) Permit change NOT REQUIRED Tom, We have called TD at 12,241, this is 424 feet further than originally permitted (11,817'MD), hence a new permit revision will not be needed, and new documentation will not be submitted. I nice little present for everyone this holiday season. Thank you for your quick repsonse when needed earlier today. 1 did not want the rig waiting on me, to drill past the 499' max allowable extension without permit approval. bob Bob Coolidge BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling Robert.Coolidge@bp.com Office: 907-564-5776 Cell: 907-980-7183 Fax: 907-564-4040 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.govJ Sent: Thursday, December 20, 2007 3:11 PM To: Coolidge, Robert 6 Cc: Arthur C Saltmarsh Subject: RE: L-2191 (207-148) Permit change request Bob, I have spoken with the Commissioners and you have oral approval to continue drilling as planned. You are correct that a new permit packet will be needed. The permit and API number will remain unchanged. The packet should be submitted tomorrow if possible. Call or message with any questions. Tom Maunder, PE AOGCC From: Coolidge, Robert B [mailto:Robert.Coolidge@bp.com] Sent: Thursday, December 20, 2007 2:56 PM To: Maunder, Thomas E (DOA) Subject: L-219i (207-148} Permit change request Tom, 12/21/2007 L-219i (20?-148) Permit changg request • Page 2 of 2 We are currently drilling at 11,600'MD. The well was permitted to 11,817'MD. The Schrader OB sands have came in differently than projected. Our objective fs to find the OWC (but ail we are finding it Dill) so we can inject into water into the OBd. We request AOGCC approval by email to drib to a new TD of 12,800`MDt4868'TVD, continuing the same basic azimuth and inGfnation. A directional plan &~ AC scan has been run and will be attached for convenience. We are drilling in a direction away the nearest wefts. There wit! be na conflict with wells within 1/4 mile requirements. A complete permit documentation package Witt then be submitted to meet the AOGCC requirements. Thank you Tom far your consideration, and I wish you a great holiday season with family and friends, bob Bob Coolidge BP Exploration (Alaska}, Inc. Operations Drilling Engineer GPB Rotary Drifting Robert. Coolidge@bp. com Offrce: 907-564-5776 Cell: 907-980-7183 Fax: 907-564-4040 «L-219 (P9} report.pdf» 12/21/2007 L-2191(207-148) Permit chap, a request Page 1 of ~~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Thursday, December 20, 2007 3:11 PM To: 'Coolidge, Robert B' Cc: 'Arthur C Saltmarsh' Subject: RE: L-219i (207-148) Permit change request Bob, 1 have spoken with the Commissioners and you have oral approval to continue drilling as planned. You are correct that a new permit packet will be needed. The permit and API number will remain unchanged. The packet should be submitted tomorrow if possible. Call or message with any questions. Tom Maunder, PE AOGCC From: Coot'rdge, Robert B [mailto:Robert.Goolidge@bp.com] Sent: Thursday, December 20, 2007 2:56 PM To: Maunder, Thomas E (DOA) Subject: L-2191(207-148} Permit change request Tam, We are currently drifting at 11,600'MD. The weft was permitted to 11,817'MD. The Schrader OB sands have come in differently than projected. Our objective is to find the OWC (but all we are finding it oil!) so we can inject into water into the OBd. We request AOGCC approval by email to drill to a new TD of 12,800'MD/4868'TVD, continuing the same basic azimuth and inclination. A directional plan & AC scan has been run and wilt be attached for convenience. We are drilling in a direction away the nearest wefts. There wilt be no conflict with wells within 1/4 mile requirements. A complete permit documentation package wil! then be submitted to meet the AOGCC requirements. Thank you Tom for your consideration, and f wish you a great holiday season w~h family and friends, bob Bob Coolidge BP Exploration (Alaska}, inc. Operations Drilling Engineer GPB Rotary Drilling Robert. Coolidge@bp. com Office: 907-564-5776 Cell: 907-980-7183 Fax: 907-564-4040 12i2oiaoo7 L-2191 Permit change request Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, December 06, 2007 3:31 PM To: 'Coolidge, Robert B' Subject: RE: L-219i (207-148) Permit change request Nothing more in the process Bob. One request though, please include the permit # following the well name in message titles. It helps with the filing. Tom From: Coolidge, Robert B [mailto:Robert.Coolidge@bp.com] Sent: Thursday, December 06, 2007 3:28 PM To: Maunder, Thomas E (DOA) Subject: RE: L-219i Permit change request thank you Tom. Just to be clear, since this is my first well, ever, :) I want to be sure I'm all OK does this mean is is approved, or is there more to the process? From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, December 06, 2007 3:24 PM To: Coolidge, Robert B Subject: RE: L-219i Permit change request Thanks. From: Coolidge, Robert B [mailto:Robert.Coolidge@bp.com] Sent: Thursday, December 06, 2007 3:21 PM To: Maunder, Thomas E (DOA) Subject: RE: L-2191 Permit change request Tom, We will NOT reduce the 3 1/2 x 7" IA test pressure. It still will be 4000psi test. bob From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, December 06, 2007 3:17 PM To: Coolidge, Robert B Subject: RE: L-219i Permit change request Page 1 of 2 Hi Bob, You are correct with regard to the pressure testing requirements. We require that tubing and annuli be pressure tested, but do not specify the value. The test pressure is determined by the operator. Reducing the test pressure to 3500 psi should be appropriateo Was the annulus also going to be tested to 4000 psi? Will it be reduced as well? Tom Maunder, PE AOGCC From: Coolidge, Robert B [mailto:Robert.Coolidge@bp.com] 12/6/2007 L-219i Permit change request ~ • Page 2 of 2 Sent: Thursday, December 06, 2007 3:12 PM To: Maunder, Thomas E (DOA) Subject: L-219i Permit change request Tom, Ref: Permit number 2071480 Any future MI injection is exected to be at ~ 2500psi into the Schrader sands. This new test pressure is sufficient for BP's anticipated future needs. I seek your approval to test our 3 1/2" tubing to only 3500psi, instead of 4000psi. I have reviewed the regulations, and i believe this meet all requirements of the AOGCC, however this is a change from the information supplied to the AOGCC in my original permit to drill request. Thank you, and best regards, Bob Coolidge BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling Robert.Coolidge@bp.com Office: 907-564-5776 Cell: 907-980-7183 Fax: 907-564-4040 12/6/2007 ~~ ~- ~` L~ ~ ~ -~~ SARAH PAL/N, GOVERNOR Lais[a-7~ OIL t~1«1 GAS 333 W 7th AVENUE SUITE 100 COI~TSER'PATIOIIT COM1~iISSIOrIT , ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Orion Oil Pool, L-219i BP Exploration Alaska Inc. Permit No: 207-148 Surface Location: 2612' FSL, 3530' FEL, SEC. 34, T12N, R11E, UM Bottomhole Location: 1376' FSL, 5140' FWL, SEC. 26, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9059-3607 (pager). J DATED this ~ day of November, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~ ~'? ALAS~OIL AND GAS CONSERVATION COMMI ON PERMIT TO DRILL ~-~~~~ 20 AAC 25.005 NOV 1 ~ Z007 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. cCflJ17RlISS1011 ^ Coalbed McO~~as Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: L-2191 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11818 TVD 4828 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 3530' FEL 2612' FSL SEC T12N R11 E UM 34 7. Property Designation: ADL 028238 Schrader Bluff , , , , , , Top of Productive Horizon: 1241' FSL, 2201' FWL, SEC. 26, T12N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 10, 2007 Total Depth: 1376' FSL, 5140' FWL, SEC. 26, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 3910' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583383 y-5978336 Zone-ASP4 10. KB Elevation Plan (Height above GL): 79 feet 15. Distance to Nearest Well Within Pool: 1043' 16. Deviated Wells: Kickoff Depth: 250 feet Maximum Hole An le: 88 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2160 Surface: 1677 18. Ca in Pr ram: S ifi To - S in h -Bo ttom uanti of Cem nt c.f. or dcs Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 34" 20" 91.5# A-53 Weld 80' Surface Surface 108' 108' 260 sx Arctic Set A rox. 12-1 /4" 9-5/8" 40# L-80 BTC 4546' Surface Surface 4546' 2869' 734 sx DeepCrete, 305 sx Class'G', 71 sx DuraStone 8-3/4" 7" 26# L-80 T -II 7678' Surface Surfa 7 78' 4 54' Se Below 8-3/4" 7" 26# L-80 BTCM 4139' 7678' 4054' 11817' 4829' 96 sx LiteCrete 34 sx FlexStone 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length > Size ement Volume D D Conductor /Structural Surface Intermediate Pr i n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Bob Coolidge, 564-5776 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4166 Date 1/ /~ ` Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Numb r: /'~ O API Number: 50-va~®?..~.3s?6 oaoo Permit Approval Date: See cover letter for other re uir ment Conditions of Approval: ~~'~-' G~.c~'-+~Y~-~cy~}(y,~~~~`,p~ E ~1~Z~,:~~;~4-f;`~~et-c;:`r~GC~C;c~ "'s/.~~~ ~~ If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ^ ~''~ ~ ~5~ ~~ -~~ 5'~v:'y ~?tC.-.~~u,,, Samples Req'd: ^ Yes ^ No Mad Log Req'd: ^ Yes ^ No ~~`1~` ~ ~ ~~~i ~~~~~ ~~~~ ~ ~C~iGV ,, HZS Measures: g Y~ No ~ rectional Survey Req'd: ^ Yes ^ No Other: ~~C' ~C, ARL } 5.C53S L~,1~,i~ Date `~ ZQ~' a APPROVED BY THE COMMISSION COMMISSIONER. Form 10-401 Revised 12/2005 (1 ~' ~/~~~~ ~ ~~ Submit In Duplicate ~ r Well Name: L-219i Drill and Complete Plan Summary Well Design: USH Grassroots Schrader Bluff Injector 3 '/z",9.2#, L-80, TC-II, multi acker, zonal in'ection, and zonal monitorin com letion AFE Number: API Number: TBD b AOGCC Estimated Start Date: December 10, 2007 Operating days: 28~ Rig: Nabors 7ES TMD 11,817' TVD RICB: 4829.00', RKB/GL 28.5'/49.90' RTE 79.00' Tar et X Y Z TVDss Townslu Ran a Section FSL FEL Surface 583,383 5,978,336 50.5 12N 11E 34 2612 3530 To of O Sands 589,063 5,982,310 -4395 12N 11E 26 1241 3079 BHL 592,000 5,982,480 -4750 12N 11E 26 1376 140 Formation Markers: Formation Est. Formation To s Uncertaint Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. TVDss feet Yes/No Psi EM Gl -255 +/- 50' no 115 8.7 Fault #1- L Pad Fault -815 +/-100' M.D. SV6 -875 +/- 50' no 394 8.7 EOCU -1340 +/- 50' no 603 8.7 SVS -1485 +/- 50' no 668 8.7 SV4 -1625 +/- 50' Gash drates 731 8.7 BPRF -1695 +/- 50' - 763 8.7 SV3 -1995 +/- 50' Gash drates 898 8.7 SV2 -2175 +/- 50' Gash drates 979 8.7 5V1 -2540 +/- 50' Gash drates 1143 8.7 UG4 -28$0 +/- 50' 1296 8.7 Fault #2 -2885 +/_100' M.D. UG4A (faulted to -2885 +/- 50' Heavy Oil - 2885' - 3020' SS 1298 8.7 G3 3165 /- 50' Minor Heavy Oil in thin sands - 3175'-3220' SS; thin coals 424 .7 Fault #3 Possible -3470 +/-150' M.D. UGl -3700 +/- 50' Heavy Oil - 3820'-3970' SS 1665 8.7 UG Ma -3975 +/- 50' Heavy Oil - 4000'-4040' SS 1789 8.7 UG Mbl -4020 +/- 50' Heavy Oil - 4050-4090' SS 1809 8.7 UG Mb2 -4095 +/- 50' Heavy oil - 4115' - 4155' SS 1843 8.7 ~ r UG Mc -4200 +/- 50' no 1890 8.7 SB Na -4230 +/- 25' no 1904 8.7 SB Nb -4255 +/- 25' es 1915 8.7 SB Nc -4290 +/- 25' no 1931 8.7 SB Ne -4300 +/- 25' no 1935 8.7 SB OA -4395 +/- 25' no 1970 8.4-8.6 SB OBa -4465 +/- 25' es 1960-2000 8.4-8.6 SB OBb -4510 +/- 25' es 2020 8.6 SB OBc -4575 +/- 25' es 2040 8.6 SB OBd -4640 +/- 25' es 2020-2060 8.4-8.6 SB OBe not reached SB OBf not reached Base_SB_OBf below T.D.) not reached TD -4750 Casio Tubin Pro ram: Hole Size Csg/ Tbg O.D. Wt/Ft Grade Connection Length (ft) Top MD/TVD RTE ft Btm MD/TVD RTE ft 34" Insulated 20" 91.5 A-53 WLD 80 GL 108/108 12-'/" 9-5/8" 40 L-80 BTC 4546 GL 4546/2869 8-3/" 7" 26 L-80 TC-II 7678 GL 7678/4054 8-'/" 7" 26 L-80 BTC-M 4139 7678/4054 11817/4829 Tubin 3-''/z" 9.2 L-80 TC-II 10759 GL 10759/4783 Note: To roduction acker within 200' MD of to erforation X Ni le at 2500 TVD +/- for future SSSV if desired Mud Program & Disposal: Fluid S stem E ui ment dia ram on file with AOGCC for this ri ,Nabors 7ES. 12-'/." Surface Hole Mud Pro erties S ud -Freshwater Mud Interval Densi PV YP PH Funn Vis FL 0-1950'MD (BPRF) 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 1950' - 4546' MD SV 1 9.2-9.5 30-55 45 - 60 9.0 - 9.5 250-300 < 8.0 8-'/" Intermediate Hole Mud Pro erties Freshwater Mud LSND Interval Densi PV YP PH API Filtrate MBT 4546'-11,817' MD (OBd TD 8.8-9.3 12-18 18-24 9.0-10.0 <6 < 15 Completion Fluid+ +/- 9.Oppg Brine & 6.8 Diesel Disposal of Drilling Mud & Cuttings No annular disposal in this well. Haul all drilling and completion fluids, and other Class II wastes, to DS-04 for disposal. Haul any and all Class I wastes to Pad 3 for disposal. Directional & Survey Program: Refer to attached Directional Plan revision 8 Surface C Casin Size Surface Casin - 9 S/g" 401b/ft L-80 BTC Sin le Sta e Basis Lead: Open hole volume + 250% excess in permafrost and 30% excess below permafrost. TOC at surface. Tail: en hole volume + 30% excess + 80' shoe track. TOC 546' MD above shoe (4000' MD). Fluid Sequence and A Tam Port collar may be located at 1,000' as a contingency for cement to surface Volume: Wash None i acer 100 bbls of MudPush II wei ted to 10.0 Lead 503 bbls of 10.71b/gal DeepCRETE cement (734 SACKS; Yield = 3.85 ft3/sM Tail 63 bbls of 15.8 lb/gal Class G (305 sacks; Yield = 1.16 ft3/sk) followed by 15 bbls of 16.3 DuraSTONE (71 SACKS; Yield: = 1.19 ft3/sk Temp BHST ~ 40° F Surface Shoe Integrity Test: Perform Formation Integrity Test within 20' - 50' from 9 3/8" shoe Production Cementin Casin Size Production Casin - 7" 261b/ft L-80 BTC-M x TC-II -Sin le Sta e Basis Lead: Open hole volume + 30% excess. TOC to 5546' MD. Tail: O en hole volume + 30% excess + 80' shoe track. TOC at 7178' MD, which is 500' above to of Ma. Fluid Sequence and NOTE: This cement job is planned for one stage. If two stages are required, 11 ppg Lite Volume: Crete will be used. Intended TOC will be as on inall Tanned durin the sin le sta a 'ob. Wash None S acer 40 bbl of MUDPUSH II Spacer wei ted to 10.0 Lead 57bbls of 1 lppg LiteCRETE (96 sacks; Yield = 3.32 ft3/sk) based on open hole volume + 30% excess. Tail 164 bbl (349 sacks; Yield = 2.64 ft3/sk) 13.23 g F1exSTONE cement + Latex. Dis lace Seawater Temo BHST ~ 95° F 3-%" Hole Section Cement Inte ri A USIT log should be run on wireline using rollers and a-line tractor in order to reach TD. The log should cover the interval from ~20' above PBTD to at least 200 feet above surface Casin shoe or TOC whichever is hi her. The distance to the nearest property line boundary: 3910 Feet to PBU Boundary Wells within a '/a mile of this infection well: Well Name Dist Ft. Annulus Inte ri Comments L-215PB2 1043' 1043' @Top Na, 1072' @Top Nb inj. Interval. Pilot hole was cemented as er ro am, to of cement in the U u UG1 interval. L-215i 1266' 1266' @Top Na, 1278' @Top Nb inj. Interval. Bond log shows good cement uali alon and above Schrader Bluff . To of cement UG4A. L-202L2 1253' 1253' in OBa HAW. Slotted liner com letion su orted b L-2191. L-202L1 1,273 1273' in OA HAW. Slotted liner com letion su orted b L-2191. L-250L2 1273' 1273' in Nb HAW. Screen com letion su orted b L-219i. ~ ~ Well Control Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. BOP equipment will be tested to 4,000 psi. A function pressure test of the casing rams is required after changing the casing rams. Anticipated surface pressures will not exceed 3,000psi, therefore it will not be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics for Nabors Rig 7ES are on file with the AOGCC. Surface Section InteEri • Diverter: Hydril GK, 21-1/4", 2000 psi • Maximum anticipated BHP: 1298 psi - SV 1 (8.7 ppg EMW @ 2869' TVD) • Planned BOP test pressure: Function Test • 9-5/8" Casing Test: 3,500 psi surface pressure test • Kick Tolerance: NA Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface ~' hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line.b To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. Production Section InteQri • BOPE: • Maximum anticipated BHP: • Maximum Anticipated surfa • Planned BOP test pressure: • 7" Casing Test: Estimated BHT: Hydril, 13-5/8", 5000 psi 2160 psi - OBd (8.6 ppg EMW @ 4829' TVD) ce pressure: 1677 psi -Based on a full column of gas @ 0.10 psi/ft 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular 4,000 psi surface pressure test 95°F @ 4750' TVDss (estimated) • ~ Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control /Reservoir Pressures: a. The Schrader Bluff sands are expected to be pressured at 8.4-8.6 ppg EMW. b. Kick Tai+ttrance ! Irtt r Te~tin " mtna Table Casing /Interval Casing Test Pressure Maximum Influx Volume Mud Wei. ht Exp Pore Press LOT I FIT 9 5/8" Surface Casing / 12 1 /4" hole 3500 psi 191 BBLS (assuming 12.2 LOT) 9.2ppg 8.7ppg LOT Interm. / Prdtn Casin 4000 si NA NA NA NA 2. Hydrates and Shallow gas: a. Gas hydrates and/or free gas may be present in the SVS thru SV1 surface hole interval below base Permafrost. Use standard operating procedures for hydrates. Set surface casing below deepest SV1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. 3. Faults /Lost Circulation /Breathing: a. Fault #1 is the typical "L-Pad Fault" at 900' MD was similarly cut on L-102, L-120, L- 201, L-210PB1 and L-214. b. Fault #2 intersect is expected at 4795'MD in intermediate hole. It divides Orion Polygon S from Polygon 2. It has been penetrated by at least 12 wells including L-2191 include L- 215, L-216, and L-210PB1. Fault #3 separates Orion Polygon 2A from Polygon lA. It dies out upward and L219i appears to cross the fault near it's upward extent. Any LC must get sufficiently healed prior to running MDT tools at TD. Also, any LC material not compatible with the MDT tools must be eliminated prior to running MDT tools. 4. Stuck Pipe & Casing a. 9 S/8" & 7" Casing: low probability of differential sticking. Assure clean hole prior to running casing, follow the centralizer program, keep casing moving while RIH, and reciprocate and rotate while cementing it. b. MDT formation evaluation: Assure clean and stable production hole, and that the mud is within proper fluid parameters prior to and while running MDT tools. 5. Hydrogen Sulfide a. L Pad is not designated as an HZS site, however Standard Operating Procedures for HZS precautions should be followed at all times. H2S levels across the pad are typically in the 10 ppm range based on the latest samples taken. Watch for possible H2S when drilling near wells on MI injection. Well Name H2S Level Date of Readin #1 Closest SHL Well H2S Level L-120 90 m 6/26/2007 #2 Closest SHL Well H2S Level L-201 3S m S/13/2007 #1 Closest BHL Well H2S Level L-2S0 2S m 6/1S/2006 #2 Closest BHL Well H2S Level L-201 35 m 5/13/2007 CONTINUED NEXT PAGE 6. Wells within a'/ mile of this injection well Well Name Dist Ft. Annulus Inte ri Comments L-215PB2 1043' 1043' @Top Na, 1072' @Top Nb inj. Interval. Pilot hole was cemented as er ro am, to of cement in the U u UG 1 interval. L-215i 1266' 1266' @Top Na, 1278' @Top Nb inj. Interval. Bond log shows good cement uali alon and above Schrader Bluff . To of cement UG4A. L-202L2 1253' 1253' in OBa HAW. Slotted liner com letion su orted b L-2191. L-202L1 1,273 1273' in OA HAW. Slotted liner com letion su orted b L-2191. L-250L2 1273' 1273' in Nb HAW. Screen com letion su orted by L-2191. CONSULT THE L PAD DATA SHEET & THE WELL PLAN FOR ADDITIONAL INFORMATION r ~- L-219i -Drill and Comulete Procedure Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 20" conductor. 2. Prepare pad and neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU. Nipple up diverter spool and function test diverter. PU DP. 2. MU 12-'/" drilling assembly with MWD/GR. Directionally drill the surface hole, making short Mp to surface at the BPRF. Continue drilling to 4546'MD TD, assure clean hole, POOH and lay down BHA. 3. PU & Run and cement the 9-s/8", 40.0 lb/ft. surface casing. Test the 9-S/8" casing to 3500 psi at plug bump for 30 minutes. A TAM Port Collar may be run at 1000' MD to provide a contingency. 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test to 4,000 psi / 2500 psi annular. PU 4" DP as needed. 5. MU 8-'/<" drilling assembly and RIH to float collar. Confirm 1,000 psi cement compressive strength prior to testing casing. 6. Drill shoe track and displace to new 8.8 ppg LSND mud. Drill 20 - 50' of new formation & perform LOT. 7. Drill Production hole to 11,817'MD TD. Assure log information meets Geology requirements. Circ & back-ream open hole as needed. POOH. 8. RIH with MDT tools on DP. Take approximately 30 pressures and 12 samples per program via two separate MDT tool runs. Refer to Asset team detailed procedures and requirements. Circ & condition hole. POOH. 9. PU BHA for cleanout trip. POOH. 10. Run and cement the 7" production casing, displacing cement with Seawater. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9-5/g" annulus. 11. PU SLB 4.5" Power Jet 4505 5 spf, DPC perf guns w/MWD/GR for gun correlation and RIH on DP. Displace to completion brine. 12. Space out perf guns and correlate depth by tagging PBTD and utilizing MWD GR to tie-in. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate per plan. POOH and LD guns, RACKING BACK DP. 13. RIH to TD with clean out BHA on DP to recover any perf debris. Repeat until clean to at least 50' below the bottom perforations. / 14. PU USIT & CBL tools on a-line, rollers and tractor tool. DPC is a contingency. 15. Run the 3-''/2" completion with Pump-Out sub on tubing tail so that the top packer is within 200' above top perfs. 16. Perform depth "tie-in" pass a-line and GR/CCL. 17. Run in the lockdown screws in WH. 18. FP IA and tubing to 2500' TVD minimum. 19. Set packers with pressure. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,OOOpsi each 20. Blow Pump-Out-Sub with SOOOpsi and hot oiler truck. 21. Install PX plug in X-Nipple at 2500' TVD. 22. Insta112-way check. 23. ND BOPMU Tree. Nipple up and test the double master to 5,000 psi. 24. Install BPV in tubing hanger, and secure the well. 25. Rig down and move off. Post-Rig Work: 1. Install Tree with electric SSV actuator. 2. RU CTU. Pull plug from X-Nipple at ~2500'TVD @ 68 degree angle. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Wash pump out sub debris to bottom at 11, 800. 5. Install well house and flow lines. r • I ~PLANT'.~ - N ~~s•oo'oo° ~~ - - - - - L-PAD I I ^ N-L (NWE-1) I I L-1111 ^ ^ N-A (NWE-2) L-51 ^ ^ 1-218i L-114 ^ ^ L-124 L-50 ^ ^ L-112i ^ L-02 L-121 ^ ^ L-1231 I ^ 1-122 L-110 ^ ^L-217i L-SI ^ ^ L-1151 1-716 ^ ^ L-117 1-109 ^ ^ L-118 I L-Oai ^ I ^ L-250 L-ot ^ ^ L-zoo L-107 ^ ^ L-202 L-03 ^ ^ L-2121 I ^ L-217i L-2t3i^ ^ L-203 1-1081 ^ ^ L-2761 L-105i ^ ^ L-7031 L-106 ^ ^ L-215i L-204 ^ ^ 1-201 L-104 ^ ^ L-119i 1-214i ^ ^ L-210i L-102 ^ L-120 I L- 2191 J I~ I I I I I II I ~I ~~- IT I 34 I 35 L-PAD -t T12N r--------- -~- T11N 3 2 VICINITY MAP N.T.S. ~P~~ °OF ° AC~s~ °°, Leonad J. O'Hadey 's~°° 11386 'sslowa. ° °` °1~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION ANO THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF OCTOBER 12, 2007. LEGEND ~~ AS-BUILT CONDUCTOR 1. DATE OF SURVEY: OCTOBER 12, 2007. ^ EXISTING CONDUCTOR 2• REFERENCE FIELD BOOK: W007-22 PAGES 50-52. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. HORIZONTAL AND VERTICAL CONTROL IS BASED ON L PAD OPERATOR MONUMENTATION. 5. ELEVATIONS ARE BPX M.S.L. DATUM 6. MEAN PAD SCALE FACTOR IS 0.999907827. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN. ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 2191 L Y= 5,978,336.10 N. 9999.82 70'21'02.798" 70.3507771' 49 9 2,612' FSL - X= 583,383.33 E. 5400.12 149'19'22.811" 149.3230031' ' 3,530' FEL CHECKED:CLARKE by O DATE~10/14/07 ORAN7NG WOA L-PAD SNEEi: y~(~(~(~ fR607 WOL 02-00 ® lU 1~UUlbo ~ Ho- CONDUCTOR AS-BUILT 0 7o is o7 isw fDR wccar~noN 1FD do $CAEE: 1 a 1 7•= tso' WELL L-2191 N0. DA SKIN r piK f TREE _, A53 ERW, Insulated Conductor @ 80' 4-1/2" TBG, 12.6#, L-80, 1' ~TG11, .0152 bpf, ID= 3.958" 9-5/8" CSG, 40#, L-80, TG 11, tD = 8.835" 4546' 7" Csg. MARKER JOINTw/ 8273' RA TAG 7" CSG, 26#, L-80, TGII, .0383 bpf, ID = 6.276" 5500' X/O T' TGII to 7" BTGM 5500' WATER INJECTION MANDRELS MD TV D DEV TYPE V LV LATCH PORT DATE 8724 68 MMG-HW #8 DMY RK 9012 73 MMG-HW #7 DMY RK 9116 78 MMG-HW #6 DMY RK 9276 78 MMG-HW #5 DMY RK 9474 78 MMG-HW #4 DMY RK 9707 85 MMG-HW #3 DMY RK 10585 85 MMG-HW #2 DMY RK 10677 85 MMG-HW #1 DMY RK 2' 1~4-112" XO 3-1/2", ID = 2.992" 3900' ~--j3-1/2" HES X NIP, ID = 2.813" TUBING MARKER JOINTw/ RA TAG 8352' 8405' T' HES AHR PKR w/ 1/4" FEED THRU, ID = 2.920" NOTE: DO NOT EXCEED 4300 PS( 8505' 3-1/2" HES X NIP, ID = 2.813" 8720' 3-1/2" HES X NIP, ID = 2.813" 8823' 7" HES A HR PKR w ! 114" FEED THRU, ID = 2.920" 8833' PHOENDC PRESITEMP SENSOR SUB, ID = 2.992" 9028' 3-1/2" HES X NIP, ID = 2.813" 9071' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 9290' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 9381' 3-1/2" HES X NIP, ID = 2.813" REF LOG: SLB Realtime LWD ANGLE AT TOP PERF: 68 degrees PROPOSED PERF INTERVALS SQE SPF INTERVAL Opn/Sqz DATE 4-112" 5 Nb 8420-8460 O 4-1/2" 5 OA 8840-8950 O 4-1/2" 5 OBa 9177-9317 O 4-1/2" 5 OBb 9338-9478 O 4-1/2" 2.5 OBd (oil) 11,120-10,620 O 4-1/2" 5 OBd (water) 11,650-11,700 O PBTD = 11727' 7" CSG, 26#, L-80, BTGM, .0383 bpf, ID = 6.276 1181T TD 9565' -i 3-1 /2" HES X NIP, ID = 2.813" 9668' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 9678' PHOENDC PRES/TEMP SENSOR SUB, ID = 2.992" 10621' -~3-1/2" HES X NIP, ID = 2.813" 10639' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 10738' 3-1/2" HES XN NIP, ID = 2.75" 10759' 3-1/2" POS, ID = 2.875" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/15/07 RBC Based on approved tally 4-1/S" CM/ L~19i PROPOSED WELLHEAD = ~ FMC ACTUATOR = _ T Electric KB. ELEV = BF. ELEV = pm KOP = 300' Max Angle = 87.8 deg Datum MD = ~ Datum ND = ~~~ ~~ L-219 (P81 Proposal Schlumberger Report Date: October 23, 2007 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 64.950° field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Well: L-PAD I L-219 Plan L-219 (NX+1) ed ~ 012 O TVD Reference Datum: ND Reference Elevation: Rotary Table 78.40 ft relative to MSL Borehole: Plan L-219 ro~ A p Sea Bed 1 Ground Level Elevation: 49.90 ft relative to MSL UWIIAPM: p 50029 Magnetic Declination: 23.168° Survey Name I Date: L-219 (PS) I October 23, 2007 Total Field Strength: 57639.731 nT tort 1 AHD 1 DDI 1 ERD ratio: 112.068° / 9887.20 ft 16.433 / 2.048 Magnetic Dip: 80.880° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: December 20, 2007 Location LaUlong: N 70.35077710, W 149.32300315 Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5978336.100 ftUS, E 583383.330 ftUS North Reference: True North Grid Convergence Angle: +0.63757795° Total Corr Mag North -> True North: +23.168° Grid Scale Faefor: 0.99990790 Local Coordinates Referenced To: Well Head • Measured Vertical Gravity Directional Comments Inclination Azimuth Subsea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft k ft ft de de 100 H Index ftUS ftUS me u .uu V.VU ay.Gb -ib .4U u .uu U.UU U.uu u.uV --- V.VU U.UU J`J/i3JJb.lU OCSSiSS. SS N /U. 3bU///1U W 14y. 3Z3UU31b KOP Bld 1.51100 250 .00 0.00 54.26 171 .60 250 .00 0.00 0.00 0.00 HS 0.00 0.00 5978336.10 583383. 33 N 70. 35077710 W 149. 32300315 300 .00 0.75 54.26 221 .60 300 .00 0.32 0.19 0.27 HS 1.50 0.00 5978336.29 583383. 59 N 70. 35077762 W 149. 32300100 G1 333. 41 1.25 54.26 255. 00 333. 40 0.89 0.53 0.74 HS 1.50 0.06 5978336.64 583384. 06 N 70. 35077855 W 149. 32299715 Bld 2.25/100 350 .00 1.50 54.26 271 .59 349 .99 1.29 0.76 1.06 HS 1.50 0.29 5978336.88 583384. 38 N 70. 35077919 W 149. 32299453 400 .00 2.63 54.26 321 .56 399 .96 3.05 1.82 2.52 HS 2.25 0.91 5978337.94 583385. 83 N 70. 35078206 W 149. 32298267 500 .00 4.88 54.26 421 .33 499 .73 9.48 5.64 7.83 HS 2.25 1.67 5978341.82 583391. 10 N 70. 35079249 W 149. 32293958 600 .00 7.13 54.26 520 .78 599 .18 19.75 11.74 16.32 HS 2.25 2.16 5978348.02 583399. 51 N 70. 35080917 W 149. 32287070 700 .00 9.38 54.26 619 .74 698 .14 33.85 20.12 27.96 HS 2.25 2.51 5978356.53 583411. 06 N 70. 35083207 W 149. 32277616 800 .00 11.63 54.26 718 .06 796 .46 51.76 30.77 42.75 HS 2.25 2.79 5978367.34 583425. 73 N 70. 35086115 W 149. 32265609 Fault Crossing 899. 40 13.86 54.26 815. 00 893. 40 73.30 43.57 60.55 HS 2.25 3.02 5978380.34 583443. 38 N 70. 35089613 W 149. 322 900 .00 13.88 54.26 815 .59 893 .99 73.44 43.66 60.66 HS 2.25 3.02 5978380.42 583443. 50 N 70. 35089636 W 149. 5 3225 Bld 3.51100 956 .21 15.14 54.26 870 .00 948 .40 87.28 51.88 72.09 HS 2.25 3.13 5978388.77 583454. 83 N 70. 35091883 W 149. 32241 SV6 961. 39 15.32 54.26 875. 00 953. 40 88.62 52.68 73.20 HS 3.50 3.14 5978389.58 583455. 93 N 70. 35092100 W 149. 32240892 1000 .00 16.67 54.26 912 .12 990 .52 99.07 58.89 81.83 HS 3.50 3.23 5978395.89 583464. 50 N 70. 35093798 W 149. 32233881 1100 .00 20.17 54.26 1006 .98 1085 .38 130.12 77.35 107.48 HS 3.50 3.43 5978414.63 583489. 93 N 70. 35098840 W 149. 32213060 1200 .00 23.67 54.26 1099 .73 1178 .13 166.80 99.15 137.78 HS 3.50 3.61 5978436.77 583519. 99 N 70. 35104796 W 149. 32188463 1300 .00 27.17 54.26 1190 .03 1268 .43 208.98 124.22 172.62 HS 3.50 3.77 5978462.22 583554. 54 N 70. 35111645 W 149. 32160179 1400 .00 30.67 54.26 1277 .55 1355 .95 256.49 152.47 211.87 HS 3.50 3.92 5978490.90 583593. 47 N 70. 35119361 W 149. 32128315 EOCU 1473. 62 33.25 54.26 1340. 00 1418. 40 294.78 175.23 243.49 HS 3.50 4.02 5978514.01 583624. 84 N 70. 35125579 W 149. 32102639 1500 .00 34.17 54.26 1361 .95 1440 .35 309.17 183.78 255.38 HS 3.50 4.05 5978522.69 583636. 62 N 70. 35127915 W 149. 32092990 1600 .00 37.67 54.26 1442 .91 1521 .31 366.81 218.04 302.99 HS 3.50 4.17 5978557.48 583683. 85 N 70. 35137275 W 149. 32054336 WeIlDesign Ver SP 2.1 Bld( doc40x_100) L-219\Plan L-219 (NX+1)\Plan L-219\L-219 (P8) Generated 10/23/2007 9:57 AM Page 1 of 3 Comments Measured Inclination Azimuth Sul~Sea TVD ND Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty k de de k k k k k de de 100 k Index kUS kUS Jvp 70DJ.tl0 3`J.JD J4.L0 740~.VU 700J.4U 3`J`J.tl4 L3 /.Otl J3V.Lrf I'YJ J.JV 4.L3 O`~/CO//.47 5t3:S/1U.J7 IV /U.:SA74Lb.S`J W 74`J.;iLU:1L7ttb 1700.00 41.17 54.26 1520.15 1598.55 429.20 255.13 354.53 HS 3.50 4.28 5978595.13 583734.96 N 70.35147406 W 149.32012496 1800.00 44.67 54.26 1593.37 1671.77 496.11 294.90 409.79 HS 3.50 4.39 5978635.52 583789.78 N 70.35158271 W 149.31967626 SV4 1845.10 46.25 54.26 1625.00 1703.40 527.70 313.68 435.89 HS 3.50 4.43 5978654.58 583815.66 N 70.35163400 W 149.31946442 1900.00 48.17 54.26 1662.29 1740.69 567.29 337.21 468.59 HS 3.50 4.48 5978678.47 583848.09 N 70.35169828 W 149.31919894 End Bld 1911.61 48.58 54.26 1670.00 1748.40 575.81 342.28 475.63 --- 3.50 4.49 5978683.62 583855.08 N 70.35171213 W 149.31914176 Base Perm 1949.39 48.58 54.26 1695.00 1773.40 603.66 358.83 498.63 --- 0.00 4.52 5978700.42 583877.89 N 70.35175734 W 149.31895503 Bld 3.5/100 2002.30 48.58 54.26 1730.00 1808.40 642.64 382.00 530.83 HS 0.00 4.55 5978723.95 583909.82 N 70.35182064 W 149.31869361 2100.00 52.00 54.26 1792.42 1870.82 716.48 425.90 591.82 HS 3.50 4.63 5978768.51 583970.32 N 70.35194054 W 149.31819838 2200.00 55.50 54.26 1851.54 1929.94 795.72 472.99 657.27 HS 3.50 4.71 5978816.33 584035.23 N 70.35206919 W 149.31766702 2300.00 59.00 54.26 1905.63 1984.03 878.35 522.11 725.52 HS 3.50 4.79 5978866.20 584102.93 N 70.35220336 W 149.3171 2400.00 62.50 54.26 1954.49 2032.89 964.07 573.06 796.33 HS 3.50 4.86 5978917.94 584173.16 N 70.35234254 W 149.3165 SV3 2492.84 65.75 54.26 1995.00 2073.40 1046.13 621.85 864.12 HS 3.50 4.93 5978967.46 584240.39 N70.35247579 W149.315987 2500.00 66.00 54.26 1997.93 2076.33 1052.56 625.67 869.42 HS 3.50 4.93 5978971.34 584245.66 N 70.35248622 W 149.31594448 End Bid 2535.32 67.23 54.26 2011.94 2090.34 1084.41 644.60 895.73 --- 3.50 4.95 5978990.57 584271.75 N 70.35253794 W 149.31573086 SV2 2956.69 67.23 54.26 2175.00 2253.40 1466.21 871.55 1211.10 --- 0.00 5.12 5979220.99 584584.55 N 70.35315783 W 149.31317012 SVl 3899.93 67.23 54.26 2540.00 2618.40 2320.87 1379.59 1917.06 -- 0.00 5.37 5979736.80 585284.74 N 70.35454533 W 149.30743735 L-219 Csg Tgt 4545.98 67.23 54.26 2790.00 2868.40 2906.26 1727.56 2400.60 --- 0.00 5.50 5980090.10 585764.33 N 70.35549557 W 149.30351034 9-5/8" Csg Pt 4546.01 67.23 54.26 2790.01 2868.41 2906.28 1727.57 2400.62 --- 0.00 5.50. 5980090.11 585764.35 N 70.35549561 W 149.30351018 Crv 1/100 4565.98 67.23 54.26 2797.74 2876.14 2924.38 1738.33 2415.57 66.46R 0.00 5.50 5980101.04 585779.18 N 70.35552499 W 149.30338876 4600.00 67.37 54.60 2810.87 2889.27 2955.23 1756.59 2441.09 66.33R 1.00 5.51 5980119.57 585804.50 N 70.35557484 W 149.30318144 4700.00 67.78 55.59 2849.02 2927.42 3046.30 1809.48 2516.90 65.95R 1.00 5.53 5980173.30 585879.70 N 70.35571928 W 149.30256577 End Crv 4702.39 67.78 55.61 2849.92 2928.32 3048.49 1810.73 2518.72 --- 1.00 5.53 5980174.57 585881.51 N 70.35572269 W 149.30255094 UG4 4781.95 67.78 55.61 2880.00 2958.40 3121.16 1852.33 2579.50 --- 0.00 5.55 5980216.84 585941.82 N 70.35583628 W 149.30205731 Fault Crossing 4795.17 67.78 55.61 2885.00 2963.40 3133.24 1859.25 2589.60 --- D.00 5.55 5980223.87 585951.84 N 70.35585516 W 149.30197525 UG4A 4795.20 67.78 55.61 2885.01 2963.41 3133.27 1859.26 2589.62 -- 0.00 5.55 5980223.88 585951.86 N 70.35585520 W 149.30197508 UG3 5535.74 67.78 55.61 3165.00 3243.40 3809.75 2246.48 3155.37 --- 0.00 5.66 5980617.34 586513.21 N 70.35691246 W 149.29737982 Fault Crossing 6342.43 67.78 55.61 3470.00 3548.40 4546.66 2668.29 3771.65 --- 0.00 5.75 5981045.94 587124.70 N 70.35806402 W 149.29237356 UG1 6950.76 67.78 55.61 3700.00 3778.40 5102.37 2986.38 4236.39 --- 0.00 5.82 5981369.15 587585.83 N 70.35893233 W 149.2885 Ma 7678.10 67.78 55.61 3975.00 4053.40 5766.80 3366.70 4792.05 --- 0.00 5.88 5981755.59 588137.17 N 70.35997041 W 149.2840 Mb1 7797.12 67.78 55.61 4020.00 4098.40 5875.52 3428.93 4882.98 --- 0.00 5.89 5981818.83 588227.39 N 70.36014027 W 149.28334443 Mb2 7995.49 67.78 55.61 4095.00 4173.40 6056.73 3532.66 5034.52 --- 0.00 5.91 5981924.22 588377.76 N 70.36042336 W 149.28211305 Mc 8273.20 67.78 55.61 4200.00 4278.40 6310.42 3677.87 5246.69 --- 0.00 5.93 5982071.78 588588.27 N 70.36081967 W 149.28038905 Na 8352.55 67.78 55.61 4230.00 4308.40 6382.90 3719.36 5307.30 -- 0.00 5.94 5982113.93 588648.42 N 70.36093289 W 149.27989647 Crv 4/100 8362.65 67.78 55.61 4233.82 4312.22 6392.13 3724.64 5315.02 76.77R 0.00 5.94 5982119.30 588656.08 N 70.36094731 W 149.27983375 8400.00 68.13 57.18 4247.84 4326.24 6426.36 3743.80 5343.85 76.18R 4.00 5.95 5982138.78 588684.69 N 70.36099959 W 149.27959947 Nb 8419.32 68.32 57.98 4255.00 4333.40 6444.15 3753.42 5358.99 75.88R 4.00 5.95 5982148.56 588699.73 N 70.36102584 W 149.27947643 8500.00 69.14 61.33 4284.27 4362.67 6519.01 3791.39 5423.88 74.66R 4.00 5.98 5982187.24 588764.17 N 70.36112943 W 149.27894923 Nc 8516.14 69.31 62.00 4290.00 4368.40 6534.08 3798.55 5437.16 74.43R 4.00 5.99 5982194.55 588777.38 N 70.36114898 W 149.27884127 Ne 8544.66 69.62 63.17 4300.00 4378.40 6560.75 3810.84 5460.86 74.02R 4.00 5.99 5982207.11 588800.94 N 70.36118251 W 149.27864869 WeIlDesign Ver SP 2.1 61d( doc40x_100) L-219\Plan L-219 (NX+1)\Plan L-219\L-219 (P8) Generated 10/23/2007 9:57 AM Page 2 of 3 Comments Measured Inclination Azimuth Subsea TVD TVp Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de d ft ft ft ft ft de d 100 ft Index ftUS t1US bbuu.uu 8700.00 8800.00 OA OBa Tgt1 End Crv OBb OBc Crv 4/100 Tgt 2 OBd End Crv Crv 4/100 Tgt 3 End Crv 8842.52 8900.00 9000.00 9100.00 9117.49 9164.20 9200.00 9211.78 9338.24 9663.20 9894.30 9900.00 10000.00 10010.88 10010.97 10065.81 10797.57 10800.00 10829.95 10863.66 TD / 7" Csg 11805.22 11817.68 / U.LD 71.45 72.73 73.30 74.09 75.52 77.01 77.28 78.00 78.35 78.46 78.46 78.46 78.46 78.68 82.58 83.00 83.00 85.14 85.14 85.24 86.40 87.70 87.70 87.70 b0.43 431b.`J`J 69.47 4351.81 73.46 4382.58 75.13 77.38 81.25 85.07 85.74 87.50 88.92 89.39 89.39 89.39 89.39 89.33 88.40 88.30 88.30 4395.00 4411.14 4437.36 4461.11 4465.00 4475.00 4482.34 4484.71 4510.00 4575.00 4621.23 4622.36 4638.63 4640.00 4640.01 43`J / .3y 4430.21 4460.98 4473.40 4489.54 4515.76 4539.51 4543.40 4553.40 4560.74 4563.11 4588.40 4653.40 4699.63 4700.76 4717.03 4718.40 4718.41 87.82 4645.67 4724.07 87.82 4707.61 4786.01 87.79 4707.82 4786.22 87.50 4710.00 4788.40 87.15 4711.73 4790.13 87.15 4749.50 4827.90 87.15 4750.00 4828.40 Leslal Descriation: Surface : 2612 FSL 3530 FEL S34 T12N R11 E UM Casing Target : 4339 FSL 1126 FEL S34 T12N R11 E UM Target 1 : 1287 FSL 2771 FEL 826 T12N R11 E UM Target 2 : 1297 FSL 1941 FEL S26 T12N R11 E UM Target 3 : 1327 FSL 1125 FEL S26 T12N R11 E UM TD / BHL : 1375 FSL 140 FEL S26 T12N R11 E UM WeIlDesign Ver SP 2.1 Bld(doc40x_100 ) OOIL./3 6707.08 6801.59 6841.72 6895.81 6989.27 7081.52 7097.50 7139.90 7172.09 7182.62 7295.42 7585.29 7791.44 7796.52 7886.70 7896.61 7896.69 3[333.3if 3869.58 3899.81 3910.82 3923.92 3941.80 3953.35 3954.72 3957.41 3958.50 3958.67 3960.00 3963.41 3965.84 3965.90 3967.86 3968.17 3968.17 7946.86 3970.02 8618.69 3997.78 8620.91 3997.87 8648.47 3999.10 8679.60 4000.67 9550.69 4047.52 9562.22 4048.14 Northing (Y) [ftUS) 5978336.10 5980090.10 5982360.00 5982380.00 5982420.00 5982480.00 bbU/./U 5594.93 5685.13 5724.28 5777.86 5872.67 5969.09 5986.09 6031.64 6066.66 6078.20 6202.09 6520.47 6746.89 6752.47 6851.10 6861.89 6861.97 / 3.Z4K 71.91 R 70.69R 70.20R 69.57R 68.55R 67.64R 67.50R 76.16R 75.87R 13.38E 13.37E 13.22E 12.63E 12.63E 6916.49 --- 7645.10 14.19E 7647.51 14.19E 7677.36 15.22E 7710.99 --- 8650.62 --- 8663.06 --- Easting (X) [ftUS] 583383.33 585764.33 589370.00 590200.00 591015.00 592000.00 L-2191PIan L-219 (NX+1)1PIan L-219\L-219 (P8) 4.VU b.Ul by8LL3U.l / b8884/.bL N /U.3(i114399 W 14y.17826810 4.00 6.04 5982267.33 588934.33 N 70.36134271 W 149.27755941 4.00 6.07 5982298.56 589024.18 N 70.36142511 W 149.27682662 4.00 6.08 5982310.00 589063.20 N 70.36145510 W 149.27650858 4.00 6.10 5982323.70 589116.63 N 70.36149079 W 149.27607329 4.00 6.12 5982342.63 589211.22 N 70.36153942 W 149.27530309 4.00 6.15 5982355.25 589307.51 N 70.36157077 W 149.27451979 4.00 6.16 5982356.81 589324.49 N 70.36157447 W 149.27438172 4.00 6.17 5982360.00 589370.00 N 70.36158172 W 149.27401175 4.00 6.18 5982361.49 589405.00 N 70.36158463 W 149.27372 4.00 6.18 5982361.79 589416.54 N 70.36158507 W 149.2736 0.00 6.19 5982364.49 589540.39 N 70.36158842 W 149.2726 0.00 6.22 5982371.45 589858.68 N 70.36159700 W 149.2700412 0.00 6.24 5982376.39 590085.04 N 70.36160308 W 149.26820217 4.00 6.24 5982376.52 590090.62 N 70.36160324 W 149.26815680 4.00 6.26 5982379.57 590189.21 N 70.36160834 W 149.26735571 4.00 6.26 5982380.00 590200.00 N 70.36160916 W 149.26726805 4.00 6.26 5982380.00 590200.08 N 70.36160917 W 149.26726738 4.00 6.28 5982382.46 590254.57 N 70.36161408 W 149.26682453 0.00 6.34 5982418.32 590982.75 N 70.36168798 W 149.26090628 4.00 6.34 5982418.44 590985.17 N 70.36168823 W 149.26088665 4.00 6.35 5982420.00 591015.00 N 70.36169150 W 149.26064423 4.00 6.36 5982421.95 591048.60 N 70.36169570 W 149.26037105 0.00 6.43 5982479.24 591987.56 N 70.36182087 W 149.25273854 0.00 6.43 5982480.00 592000.00 N 70.36182253 W 149.25263749 • Generated 10/23/2007 9:57 AM Page 3 of 3 by Schlumherger wE« L-219 (P8) ~~E~u Prudhoe Bay Unit - WOA SrHU"~Ht L-PAD 0 1200 0 0 N ~ 2400 II N N 3600 asoo 0 1200 2400 3600 4800 6000 7200 8400 9600 • Crvd/100 ~' Crv4/100 ~ \ Tgt 2 End Crv End Crv Tgt 3 TD 17" 0 1200 2400 3600 4800 6000 7200 8400 9600 Vertical Section (ft) Azim = 64.95°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E/-V 1200 ?400 3600 • 1800 by Schlumherger WELL L-219 (P8) F~t~p Prudhoe Bay Unit - WOA fiTRNCTpRE L-PAD Magner er Surface NaUZIn s YI an Mooei1 RpGGM ZW% pp 80889" pale paremOe~Zb, Zfp] lal LucN /f1212l9P 69]PJJ6I10 M1119 aye an Grd fnnv x66]]51]95" Siole 9eL-219 TVp ReI RoUry Tale SIB a9X afiwe MSL~ Mag pec x23.tfi8" FS ]619.]nl Wta9 1922 bii [as nngb 6b3JeJ JJ llpB Srale Facl O. ]P9P2 %an. L~219 ~PP~ Srvy Dale. Ocbber 23.2WI 0 1000 2000 3000 4000 5000 6000 7000 8000 n n n Z 0 0 0 c u m m U V V V KOP 4000 • 3000 2000 • 1000 0 0 1000 2000 3000 4000 5000 6000 7000 8000 «< ~l~/ Scale = 1(in):1000(ft) E »> 111011 aoou C ~~ K IINIU ~ ~aN) i IxNI 0 Field: Prudhoe Bav • Site: PB L Pad Well: Plan L-219 (NX+1) Wellpath: Plan L-219 I INN) -IUW U 1600 ?6W 30W 301N) j06p M1fN) 7000 N6(N) N'cat(-fliasll •-1(I WOIVm~ Plan L-219 (NX+1)/Plan L-219 ~, '~, ~ooo Iii l i 2~~~ ~~ 30~~ II I ~~DO ~ I 50~~ 60~~ 0 b ~0~ / S~~O _-_ -__ ~~ ~ ~ ~ ~~~ • • Plan L-219 BP Alaska • Anticollision Report ----, .Company: BP Amoco Date: 11/1/2007 Time: 16:31:57 Page: 5: ,j .Field: Prudhoe Bay RefErenceSite: PB L Pad Co-ordinate(1VE)Reference: Well: Plan L-219 (NX+?),True North ' Reference !'ell: Plan L-219 (NX+1) Vertical (TVD) Reference: L-219 Plan NX+1 78.4 Reference.Wellpathi Plan L-219 Db: Oracle ' r- -------- -- - - ----- ------ GLOBAL SCAN APPLIED: All h~ellpaths within 200'+ ]00/1000 of reference -There are 1<Il2FlsSaeells in thisRtiiidipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse ~, Depth Range: 28.50 to 11817.68 ft Scan Method: Trav Cylinder North Maximum Radius: 1378.92 ft Error Surface: Ellipse + Casing -- --- ------ ----- Survey Program for Definitive Wellpath Date: 1/31/2007 Validated: No Version: 9 ', Planned From To Survey Toolcode Tool Name ft ft ~- - 28.50 1000.00 Planned: Plan #8 V1 GYD-GC-SS ; Gyrodata gyro single shots 1000.00 2400.00 Planned: Plan #8 V1 MWD MWD -Standard 1000.00 4480.00 Planned: Plan #8 V1 MWD+IFR+MS MWD +IFR + Multi Station 4480.00 11817.68 Planned: Plan #8 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points ~ " MD TVD Diameter Hole Size Name ft ft in in ~, 4545.98 2868.40 9.625 12.250 9 5/8" ', 11817.68 4828.40 7.000 8.750 7" Summary --- - ------------ - -- Offset Wel ath - lp ---.-> Reference Offset --- Ctr-Gtr -- No-Go ---- - - Allowable -- j Site Well Wellpath. MD MD bistance Area Deviation ~?Varning ff ft ft ft ft - ~ PB L Pad L-03 L-03 V5 515.82 535.00 230.89 9.77 221.12 Pass: Major Risk I PB L Pad L-102 L-102 V2 327.78 330.00 181.54 5.23 176.31 Pass: Major Risk PB L Pad L-102 L-102PB1 V10 327.78 330.00 181.54 5.33 176.22 Pass: Major Risk ~ PB L Pad L-102 L-102PB2 V2 327.78 330.00 181.54 5.33 176.22 Pass: Major Risk PB L Pad L-103 L-103 V23 323.38 325.00 90.26 5.47 84.79 Pass: Major Risk PB L Pad L-104 L-104 V7 327.09 330.00 185.38 5.68 179.70 Pass: Major Risk PB L Pad L-105 L-105 V4 331.41 335.00 202.75 6.03 196.71 Pass: Major Risk ', PB L Pad L-106 L-106 V14 591.38 610.00 192.82 10.00 182.83 Pass: Major Risk i PB L Pad L-107 L-107 V14 364.15 370.00 241.72 7.74 233.97 Pass: Major Risk PB L Pad ~ L-108 L-108 V18 439.60 450.00 208.35 8.18 200.17 Pass: Major Risk ' PB L Pad L-118 L-118 V9 419.22 430.00 247.51 7.87 239.65 Pass: Major Risk PB L Pad L-119 L-119 V9 348.44 350.00 44.65 5.88 38.77 Pass: Major Risk i PB L Pad PB L P d L-120 L-120 V8 508.22 510.00 13.87 8.80 5.07 Pass: Major Risk a L-200 L-200 V7 293.84 295.00 180.66 5.21 175.44 Pass: Major Risk PB L Pad L-200 L-200L1 V3 293.84 295.00 180.66 5.21 175.44 Pass: Major Risk PB L Pad L-200 L-200L2 V6 293.84 295.00 180.66 5.21 175.44 Pass: Major Risk PB L Pad L-201 L-201 V6 450.99 455.00 60.57 7.84 52.73 Pass: Major Risk PB L Pad L-201 L-201 L1 V9 450.99 455.00 60.57 7.84 52.73 Pass: Major Risk PB L Pad L-201 L-201 L1 PB1 V10 450.99 455.00 60.57 7.84 52.73 Pass: Major Risk PB L Pad L-201 L-201 L2 V5 450.99 455.00 60.57 7.84 52.73 Pass: Major Risk j PB L Pad L-201 L-201 L3 V2 450.99 455.00 60.57 7.84 52.73 Pass: Major Risk i PB L Pad L-201 L-201 L3P61 V6 450.99 455.00 60.57 7.84 52.73 Pass: Major Risk PB L Pad L-201 L-201 PB1 V12 450.99 455.00 60.57 7.84 52.73 Pass: Major Risk i PB L Pad ' L-201 L-201 PB2 V3 450.99 455.00 60.57 7.84 52.73 Pass: Major Risk PB L Pad L-202 L-202 V6 327.96 330.00 165.35 5.62 159.74 Pass: Major Risk PB L Pad L-202 L-202L1 V8 327.96 330.00 165.35 5.62 159.74 Pass: Major Risk PB L Pad L-202 L-202L2 V7 327.96 330.00 165.35 5.62 159.74 Pass: Major Risk PB L Pad L-202 L-202L3 V8 327.96 330.00 165.35 5.62 159.74 Pass: Major Risk PB L Pad PB L P d L-204 L-204 V8 317.66 320.00 186.27 5.68 180.59 Pass: Major Risk a L-204 L-204L1 V5 317.66 320.00 186.27 5.68 180.59 Pass: Major Risk PB L Pad L-204 L-204L2 V7 317.66 320.00 186.27 5.68 180.59 Pass: Major Risk PB L Pad L-204 L-204L3 V5 317.66 320.00 186.27 5.68 180.59 Pass: Major Risk PB L Pad L-204 L-204L4 V5 317.66 320.00 186.27 5.68 180.59 Pass: Major Risk PB L Pad L-210 L-210 V6 481.36 485.00 25.97 8.30 17.67 Pass: Major Risk PB L Pad L-210 L-210P61 V8 481.36 485.00 25.97 8.30 17.67 Pass: Major Risk PB L Pad L-212 L-212 V11 739.78 765.00 153.38 12.41 140.97 Pass: Major Risk PB L Pad L-212 L-212P61 V9 795.65 824.00 153.13 13.40 139.73 Pass: Major Risk PB L Pad L-212 L-212P62 V2 739.78 765.00 154.74 12.49 142.25 Pass: Major Risk j PB L Pad L-213 L-213 V8 278.95 280.00 216.23 4.83 211.41 Pass: Major Risk PB L Pad L-214 L-214 V9 684.27 700.00 167.51 12.45 155.06 Pass: Major Risk PB L Pad L-214 L-214A V4 684.27 700.00 167.51 12.45 155.06 Pass: Major Risk BP Alaska Anticollision Report Company:. BP AmOCO Date; 11/112007 Time. 16:31:57. Rage: 2 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NR) Reference:• Well: Plan L-219 (NX+1), True North Reference Well: Plan L-219 (NX+1) Vertical (T'VI)) Reference: L-219 Plan NX+1.78..4 Reference Wellpath: Plan L-219 __- _ Db: Oracle• ~--~- Summary <.-- - - offset Wellgath - ~ Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath M;D MD Distance Area. Deviation Warning ft ft ft it ft j PB L Pad L-215 L-215 V7 1283.44 1320.00 92.87 23.90 68.97 Pass: Major Risk PB L Pad L-215 L-215PB1 V4 1283.44 1320.00 92.87 23.90 68.97 Pass: Major Risk PB L Pad L-215 L-215P62 V2 1283.44 1320.00 92.87 23.90 68.97 Pass: Major Risk PB L Pad L-216 L-216 V6 458.12 465.00 103.87 7.69 96.18 Pass: Major Risk PB L Pad L-217 L-217 V4 385.33 390.00 132.94 7.11 125.83 Pass: Major Risk i PB L Pad L-250 L-250 V4 351.21 355.00 197.18 6.53 190.65 Pass: Major Risk ~, PB L Pad L-250 L-250L1 V14 351.21 355.00 197.18 6.53 190.65 Pass: Major Risk PB L Pad L-250 L-250L2 V10 351.21 355.00 197.18 6.53 190.65 Pass: Major Risk ', PB L Pad L-250 L-250PB1 V3 351.21 355.00 197.18. 6.60 190.59 Pass: Major Risk PB L Pad - -- _ Plan L-203 (N-Q) . __---- Plan L-203 V6 Plan: PI -- -_ __ -- -_ --- 347.04 - - -- _-__ 350.00 -- -- . 121.10 __--- 6.73 _..__. 114.37 __--_ - Pass: Major Risk -__ ---- -----.._1 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 S Alaska Department of Natural Resources Land Administration System Page 1 of,A-3 s ~ ~:... _ r_~- ~",~ks ~'~c:a~~e~'s ~earcn Stats Cabins E'~~~~ 3~~ ~ ~... Alaska DNR base Summary File Type: ADL File Number: 28238 ~ Printable Case Fiie_Summary See Township, Range, Section and Acreage? C' Yes ~' NO _ New Search LAS Menu I Case Abstract 1 Case Detail I Land Abstract 1'i1e: ADL 24238 ''F Search for Status Plat Updates of I l'I~)%20(17 Customer: 000107377 BP EXPLORATION (ALASKA)1NC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 7~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS C'use Status: 35 ISSUED Status Date: 09!]4/1965 Totul Acres: 2560.000 Date If7itiated.~ 05/28/1965 Office of'Priniary Responsibility: DOG DIV OIL AND GAS Last Tra~tsuction Date: 12/04/2006 Case Szrhtype : ~4~ NORTH SLOPL; Lcrst Transactiojz: AA-NRB ASS[GNMENT APPROVED lrrh~iufi: > ! loivnship: 012N Range. 011E Sc°c~ti~~n: ' ~ Sectir»t , {crc~s ~ ~>-l0 S~ arch 3-~, V~°rr~lr~ut.~ l_~ Zutivnship: O]2N Range: O1IE S~~cli~~n.~ ~6 ,ti"c~c~liun .I~~re.~~: (i~0 V~~ri~lru~i.~ l_! 7un~rz~~hr~>: (1 12 \ li~ailge: 011E Section: 35 .~"~ ~~rrun 4cf°es: f~ 10 1 J~°f~iclrur~: i' 7 ~nti,z~htj~: O I ~ V" R~rnge: Ol I E Sectiofa: 36 ,5~rc~rron Acres: 6~0 Legal Description 0~-2b'-I)6~ *:`*S':~:ILG~~'OTICL~LEGALDES~'RIPTION*** CI ~-16 012N-Dll E-UM 25,26, 3~, 36 ? ~<0.00 0-~-01-19 ~ % * ~U~ITIZED, LEA S'E AND PARTICIP_ATIIVC AR1 ~1 LF(:~1L DI'SC'RIPIION* LEASE COA~IILIITTED IN ENTIRETY TO PRUDHOF. B.4 Y UNIT AND OIL RI~l~I GAS CAP pA PRUDHOL f3.%lY U1VIT http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2823 8... 11 /19/2007 ' Alaska Department of Natural Resources Land Administration System Page 2 of 4~~ TRACT 19 OIL RIMAND GAS CAP PARTICIPATING AREAS T. IZ N, R. l1 E., UMIAT MERIDIAN, ALASKA .SECTION 25: ALL, 60.00 ACRES, SECTION 2f.~ ALL, 6=0.00 ACRES, SECTION 3~: ALL, 6=0.00 ACRES, SECTION 36: ALL, 60.00 ACRES; CONT AINING APPROXIMATELY 2, ~ 60.00 ACRES, MORE OR LESS. ~~:*:k~k*~******~****~~k**=k****~~=*~~~ k~:~~k*~k*:k*x**~**~:k**~~**~***~a:*~~~~*** 11-01- 2001 * *FORMATION OF BORE4LLS PARTICIPATING AREA LEGAL DESCRIPTION LEASE INCORPORATED IN PART TO THE BOREALIS P.~I * * * * * * * * ~ PRUDHOE 13AY UNIT 13ORE4LhS PA TRACT 19 (PARTIAL) T.12N., R.IIE., U1tiIl4TMERIDIAN, ALASKA .SECTION 26: S2NYV-~, SW4, 210.00 ACRES; SECTION 3~: AIL, 60.00 ACRES, SECTION 36: W_7SE~, SW-1, S2NW~, 320.00 ACRES: THIS TRffCT CONTAINS 1.200.00 ACRES, ~IOREOR LESS. k~T:k~;e>,<x*~~*#~k#**~kx-k*t~k;;cx~k;k*T~k***:k#*~=k~=x>;<;k ;;cx~kx~x*~k ~c*;kt ~:x;<;k ~k :k >;:~x~k ~k~~;kx~: 02-01-200-! *'`FOR~ltATION OF ORION P~IRTICIPATING ARE=t LEGAL DE.SCRIPTION~k LEASE CO?l1~lIITTED LN PART TO ORION P.-1RT IC'IP.4 TL~'G .=~RE.~ PR UDHOE BA Y UN11' TRACT 19 ORIONP4RTICIPATI~VGAREA T. 1? N.. R. 1l E., UMI_AT MERIDIAN, ~'1LASKt1 http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2823 8... 11 /19/2007 ' Alaska Department of Natural Resources Land Administration System Page 3 ofd ,~ SECTION 25: SW4. 160.00 ACRES; SECTION 26.~ ALL, 640.00 ACRES; SECTION 35: ALL, 610.00 ACRES; SECTION 36.' ALL, 6=10.00 ACRES; CONT 4INING APPRO,~'IMATELY 2, Of~0.00 ACRES, MORE OR LESS. ~~k*T:k~:kx~~*#**x~~~**~k~=~k****~*x***~k ~k*~~**~k~x#~~*~##***x**:k~~~~*:k*~k~~e*~ 12-01-2004 * * * * BOREALIS PA EXPANDED, LEASE INCORPORATED LV PART* * *'~ LEGAL DESCRIPTIONISASFOLLOWS PRUDHOE BAY UNIT BOREALIS PA TRACT 19 (PARTIAL) [:12N., R.IIE., UILIIAT MERIDIAN, ALASKA SECTION 26: SE4, 160.00 ACRES, THIS E_YPANSION CONTAINS 160.00 ACRES, MORE OR LESS. "* * * * * ~7HE ACREAGF. NOW' INCORPORATED INTO THE BOREALIS PA * * * ~ * * * * * * * ~" PRUDHOE 13AY CHIT BOREALIS PA 1 RACT 19 (PARTIAL) T.12N, R. I1 E., UMIAT MERIDIAN, ALASKA SECTION 26: SE4, 160.00 ACRES: SECTION 3~: ALL. 6-10.00 ACRES; SECTION 36: S2N"T~'~t, SYV-t, WZSE4, 320.00 ACRES: THIS TR-1 CT CONTAINS 1, 360.00 ACRES. ~LIORL' OR LESS. ?k;k**;<«<:k;k~~:%k~~~%,:i:*t<~k;,<;t.~~~k•1'=~=~k=k~x;k%k~k*..%k`-k#*~k~~~k**~k**~x;k ~=~k ~:k ti::;<<:x>k :KYT=k-< http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2823 8... 11 /19/2007 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ` ~f9 P1'D# o~o~l~~' Development '/ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are production should continue to be reported as a function of the between 60-69) original API number stated above. PII,OT HOLE In accordance with 20 AAC 25.005(fj, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (SO- -_) from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occw. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for dame Qf well) until after (Compan~Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompan~Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 7/13/2007 • • ^^ ~ ~ n ~ ~ ~ ~ ~ , ~ py H ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ LLB, C ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ W ~ ~ ~ ~ [6, ~ ~~ m ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ T ~ ~~ ~ ~ ~ ~ ~~ ~ ~ ~ O' fin, O' dA C' ~ ~ ~ ~ tlY ~ C. 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Z~ /6, G o o :~ ¢~ !6 E; is ca E' ~ `3' Q m _~ ~' a gy ~ a. >, s~ Q ~ o' m Ta ;~ ~' a c d ¢ °3 ~~ 4 c, c, ,a m ,m t s• (a c, 'o w ~° iv o~ n ® m' ' ' ~ W ~ ~~ a W, a, ~ a ~ ~, m ~, ' ' ~ ~~ 4 m m ~ m m ~' ' w, La rn /6 . m, ~, m ~ m ~ m. ° ay ~ n 3' o, .,..~ ~' o' 3 o, 3. ~ >r m' °a m o' ~ W o o z 3; y, ~, ~~ 3 c a, a c~ 1'6 m a Q c, :c, a, ~~ >, , m m ' ' ' ' m, ~ _m, > ~ ~ ' `°' ' ° ~, o ~ •' ~, r 3 m ... o o, o ~ ~ o q m `~' m ~ q. a •~ n a -a m~ m ' 0 ~, c6 o~ w c, ; a~ t, ~ .~-~ ~ ~ ~ a d _ ' o ~ ~ ~ W ~ ~ ~ ' ~ ~ c ~ a a e i ' ' g Y m O ' ' ~ O •-' ' m E o p, O, m 3 ~.- 1A, C o' c' o' ots m ~' ~ m; ~ ~ ~ m ~. ~ v,. of ®' ~ W 4 ~ ~ a °, L' ~ °' a ~ of a - a ® m Ts W vi ~ 1c o v ~, c c i, m' al ~ 3. v' a s c o w' ~, •° o, o, ~ m m, ` ~ ~ x16 ~ 6 : ~ ~ 3 W ~ ~ ~ m ' ` ~ ~ ~ a m ~ ai m ~ ~ ~ ~ i6 n n m, m a r c ' .o ~ a -a a •-~ c W, ~ .o, ~ . m ~~ ~ m ~ - ~ •~ m. or 6 > ~ m >, .~ m ° m s, ~ c ~+ a ., m w ~ ~ ~ d m, m m ~, ~ c, ca c E. 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O ~ O !- N N M s1 Ip 10 h OD O r •- ~ M ~ M 10 I~ ~ ~ ~ ~ ~- aD M O ~ ~ N r N M t1' N N N N ~ t0 N N !~ GO M O ~ N N N M M -_-___.__ N M M M~ _ in M t0 I~ GO Oa M M M M U U _ - __-_-_-_ __ _ __-_. __. -___ 0 0 .. yCy~ ' C o ~ ~ N W N V O G. p m ~ ~° ~ c \ ~ ~ m E N ~ mm (-~ m ~ O +I C ~ V y U 3 ~ a a ¢ ~ a ~ ~ a¢ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~~`~.~~% MAC E~ ~ ZJ~ C Schlumberger Analysis of Bottomhole Reservoir-Fluid Samples BP Alaska Orion Pool L-219i Modular Formation Dynamics Testing (MDT) Samples • Heavy-Oil PVT Study Report Prepared for Greg E. Bernaski BP Alaska Standard Conditions Used: Pressure: 14.696 Asia Temperature: 60°F Prepared by Stefan Smuk Schlumberger Oilphase-DBR 16115 Park Row, Suite 150 Houston, Texas, 77084 + 1 281 285 6370 F' 4 ft e ~~ a1~i~~. ~, 1 Date 30 June 2008 Report # 200700328-D C3 ~ 20~ - z ~r~ i ~-C~3~ Client BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-2191 Table of Contents List of Figures .......................................................................... . List of Tables :......................................................................... . EXECUTIVE SllMMARY .......................................................... Objectives ...................................................................... lntroduction .......................................................................... Scope of Work ........................................................................... Results ......................................................................... DETAILED EXPERIMENTAL.RESULTS. -.CO.MI?OSI.TION....... Compositional Data. -.1089A.'.MD ................................................... Compositional Data.-.10547.'.MD ................................................... Compositional Data.-.1.0~3'.MD ................................................... Compositional Data. -.9673: MD .................................................... . Compositional Data. -.8456: MD .................................................... . DETAILED EXP.ERIMENTAL.RESULTS.-.PVT ......................... PVT Analysis - 1D890'MD ............................................................ • PVTAnalysis-1D547.'.Mll ............................................................ PVTAnalysis-11N103'.MD ............................................................. PVT Analysis -9673.'. MD ............................................................. . PVT Analysis -8456.'.MD .............................................................. DETAILED EXP.ERIMENTAL.RESULTS.-.WATER ................... Appendix A: NAme.nclature.and.D.efinitians ........................ Appendix B: Molecular.Weights.and.Densities.Used......... Appendix C: EO.U.IPMENT ...................................................... Fluid Preparation.and.V.alidation .................................................. Fluid Volumetric .(P.VT). and..Viscosiry. Equipment ........................... . Appendix D: PROCEDURE ...................................................... Fluids Preparation and .Validatiaa ................................................ . Constant Composition Expansion. P.rncedure ................................. . Differential Vapoiizatian. P. rncedure ............................................. . Multi-Stage Separation.Test ........................................................ Liquid Phase Viscosityand.Density. Measurements.During DV..Step. Stock-Tank Oil JS.tOJ. Viscosity. and Density. Measurements........... . Asphaltene, Waxand.Sulfnr. Conteoi Measnrements ...................... SAR(PJA Analysis ...................................................................... . High-Temperature. High.P.ressure Filtration .Test ........................... . 3 4 5 5 5 5 s 11 12 15 21 27 33 39 40 45 49 55 59 65 ss s7 ss sa 68 71 71 71 71 71 72 72 72 73 73 Ollphase-DBR 2 file 200700328-D • • Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger List of Figures Figure 1: StockTank.Oil.Chromatogram.(Sample.1.1.) ............................................. Figure 2: k-Plot far. Equilibrium.Check (Sample.l_.1) ............................................... Figure 3: Stock Tank.Oil. Chromatogram. (Sample.1.].1) ........................................... Figure 4: k-Plot fnr.Equilibrium.Check jSample.1..11.- .............................................. Figure 5: Stock Tank.Qil.Chromatogram.(Sample.1.]2) ........................................... Figure 6: k-Plot far.Equilibrium.Check(Sample.]_.12- .............................................. Figure 7: Stock Tank.Oil.Chromatogram.(Sample.1.1.3) ........................................... Figure 8: k-Plot fnr.Equilibrium.Check(Sample.l_.13.) .............................................. Figure 9: Stock Tank.Oil.Chromatogram.(Sample.1.1.4) ........................................... Figure 10: k-Plot for.Equilihrium.Che,~k.(Sample.1.1.4) ............................................ Figure 11: StockTank.Oil.Chromatogram.(Sample.1..15) ......................................... Figure 12: k-Plotfor.Equillhrium.Check.(Sample.1.1.5) ............................................ Figure 13: Stock Tank.Oil.Chromatogram.(.Sample.l.-16- ......................................... Figure 14: k-Plotfor.Equilibrium.Check.(Sample.1.1.6) ............................................ Figure 15: StockTank.Oil.Chromatogram.(Sample.l.-19) ......................................... Figure 16: k-Plot for.Equilihrium.Check.(Sample.1.1.9- ............................................ Figure 17: Stock Tank.Oil.Chromatogram.(Sample..1.2) ........................................... Figure 18: k-Plotfor.Equilihrium.Check(Sample.1.2- .............................................. Figure 19: Constant.Composition.Expansion.at-.Re.lative.Volumes.(.10890'.MD~.......... Figure 20: Reservoir. Fluid Viscosity.9.7. °.F.(.10890.'. MD) ........................................... Figure 21: Constant.Composition.Expansion.at94..5°F.:Relative.Volume.(].054.7.'.MD).. Figure 22: Reservoir. Fluid.Viscosity.94.5°F.(1.0547.'. MD) ......................................... Figure 23: Constant.Composition.Expansion.-.Rslatiue.~[o.lumes..(10003'.MD- ............. Figure 24: Reservoir. FluidViscosity.93°F.(10.003'.MD.- ........................................... Figure 25: Constant.Composition.Expansion.at91..0°F.:Relative.V.olume(96.7.3'.MD-.... Figure 26: Reservoir.FLuidViscosity.9.1°.E.(9673'.MD) ............................................. Figure 27: Constant.Composition.Expansion.-.R.elatiue.Valumes.(8456'.MD.) ................ Figure 28: Reservoir. F.luid:Viscosities.(8456.'.MD) ................................................. Ollphase-DBR 3 14 14 17 17 20 20 23 23 2s 26 29 29 32 32 35 35 38 38 43 44 as 48 52 54 56 58 61 63 File 200700328-D Client BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-2191 • List of Tables Summary Data ............................................... Table 1: Well and.Sample.Identification ................. Table 2: Measured.Reservoir-Fluid.Properties.......... Table 3: Measured.Stock-Tank.OilPrnperties.......... Compositional Data ........................................................................ Table 4: C30+Composition.GDR, °API,.by.Singl.e-Stage.Elash.(Sample.1.1.-.... Table 5: Calculated.Fluid.Pr,operties ...................................................... Table 6: C30+Compositi.on,GDR, °API,.by.Singl.e-Stage.Flash.(Sample.1.1.1).. Table 7: Calculated.Fluid.Prnperties ...................................................... Table 8: C30+ Compositi.on,GDR, °API,.hy.Singl.e-Stage.F.lash.(Sample.1.12).. Table 9: Calculated.Eluid.Properties ...................................................... Table 10: C30+Compositian,.GOR,.°API,.by..Single-Stage. Flash.(.Sample.]._13) Table 11: CalculatedFl.uidPraperties .........:.......................................... Table 12: C30+Compositian,.GOR,.°API,.by..Single-Stage.Flash.GSample.l._14) Table 13: Calculated FluidPraperties .................................................... Table 14: C30+Campositinn,.GOR,..°.AP1,.by..Single-Stage. Flash.(.Sample.l._151 Table 15: CalculatedFl.uidProperties .................................................... Table 16: C30+Composition,.GOR,.°APl,.by.Single-Stage.Flash.GSample.l._16) Table 17: CalculatedFl.uidPraperties .................................................... Table 18: C30+Compnsitian,.GOR,.°API,.by..Single-Stage. Flash.(.Sample.l._19) Table 19: CalculatedFl.uidPraperties .................................................... Table 20: C30+Compositinn..GDR,.°API,.by..Single-Stage.Flash.GSample.l.2).. Table 21: CalcularedFl.uidPraperties .................................................... PVT & Water Data ............................................................ Table 22: Constant.Compositinn.Expansinn.at.97._0°.F.(10890'.MD-. Table 23: Constant.Compositian.Expansinn.at.150°F.(1D890'.MD-.. Table 24: Constant.Compositian.Expansion.at.180°F.(1D890'.MD).. Table 25: Reservoir.Fluid.Viscosity.97°F.(108.90'.MD- .................. Table 26: Constant.Compositian.Expansinn.at.94.5.°.F..(.10547.'.MD) Table 27: Reservoir.Fluid.Viscasity.94.5°F (1.054.7'.MD.- ................ Table 28: Constant.Comp.ositinn.Expansion. at.93.0.°.F.(100.03'. MD-. Table 29: Constant.Compositinn.Expansion.at.150°F.(1D003'.MD).. Table 30: Constant.Compositian.Expansinn.at.180°F.(1D003'.MD).. Table 31: Reservoir.Fluid.Viscosity.97°F..(.10003'.MD) ................. Table 32: Constant.Compositian.Expansinn.at.91._0°.E.(9673'.MD)... Table 33: Reservoir.Fluid.Viscosity.91°F.(9673'.MD) .................... Table 34: Constant.Composition.Expansion.at.150.0°F(8456'.MD-. 0 ................................................................ Table 35: Constant.Compositinn.Expansion.at.85°F (845fi'. MD-..... Table 36: Reservoir.Fluid.Viscasities~8456'.MD- ........................ Table 37: WaterAnalysis.Data .............................................. Ollphase-DBR n 8 8 9 10 12 12 13 15 16 18 1s 21 22 24 25 27 2s 30 31 33 34 36 37 ao 40 41 42 43 45 47 49 50 51 53 55 57 59 59 60 62 65 File 200700328-D Client BP Alaska Well: L-219i Ob'ectives I To evaluate the composition and phase behavior of bottomhole fluid samples collected during openhole formation- dynamics testing. Introduction At the request of BP Alaska, Oilphase-DBR conducted a fluid analysis study of multiple bottomhole reservoir-fluid samples collected during Modular Formation-Dynamics Testing (MDT) operations in the Orion Pool well L-219i, Prudhoe Bay, Alaska. Field/sampling information appears in separate Schlumberger Oilphase-DBR reports, under job number AK055. Two MDT runs were executed, resulting in a total of 22 samples being captured from ten intervals spanning the Schrader Bluff OBb, OBc, OBd and NBb sands. Scope of Work Field: Prudhoe Bay Unit - WOA Schlumberger EXECUTIVE SUMMARY • Homogenize the bottomhole hydrocarbon-fluid samples at the reservoir conditions with rocking for 48 hours. • • Settle the samples vertically for a period of 48 hours. subsample fluids in order to evaluate free-water and emulsified-water content. • Treat water-contaminated samples with chemical tlemulsifier, in a dosage not to exceed 1000 ppmw. Homogenize and settle after treatments, then subsample again to verify that de-watering has occurred to an acceptable extent. • Subject to adequate demulsification, conduct preliminary evaluation of the demulsified hydrocarbon- fluid samples, including single-stage flash Gas-Oil Ratio (GOR-, reservoir fluid composition, stock-tank oil (STO) properties, and calculated monophasic-fluid properties. • Conduct a Constant Composition Expansion (CCE) testing of the test-sample, at reservoir temperature and up to two additional temperatures. • Conducting viscosity testing at reservoir temperature, over a range of pressure conditions. Analysis was to be conducted using Electromagnetic Viscometry (EMV~, after demulsification, with pre-filtration of each subsample acrosss a 0.2-µm filter. • Conduct a water analysis (ions and properties) of four received selected samples, plus one Water-Base Mud (WBM) filtrate sample. • Ollphase-DBR 3 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Results The following points summarize the results of analyses conducted on the received bottomhole-fluid samples: • The 21 samples received included two blown-down water samples (# 1.01 and # 1.02, 12108' MD-, and one mud filtrate (# 1.21-. Of the remaining 18 samples, nine were found to contain analytically useful quanitities of hydrocarbon fluid. The remainder contained only sampled water. • Demulsification of the hydrocarbon-containing samples was carried out successfully, yielding residual water contents in the range of 1 wt% STO or less. • The significant viscosities and limited volumes of available hydrocarbon samples ~ have affected data quality in specific, limited instances, which are noted within the text of this document. Selected analyses underwent secondary verification where possible. • Pressurized density data were verified using gravimetric and densitometric methods. • • Ollphase-DBR 6 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Quality Assurance Process Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottom hole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality. Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry. This objective requires persistent innovation and ongoing development of state-of-the-art technologies and equipment. A rigorous quality assurance program, continuous employee training and enforcement of strict safety standards maintain our compliance with Quality, Health, Safety and Environment (QHSE) requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE policies and standards. Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data. Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures. Details of these programs are available upon request. The lab-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results. a) Establish quality of measurement during data generation. b) Establish quality of processed data as per checklist during data processing by Data Quality Engineer. cl Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency dl The responsible Project Engineer confirms consistency of reported data e) Engineering Project Manager review the results/report for overall consistency Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established Quality checklists designed for each operation and based on the level of complexity. All property measurements and calculation procedures are maintained in company archives for a period of 1 year. This information is available for review by clients upon request. The file and laboratory records information are listed below to provide access reference to all records related to this project. For any questions, please do not • hesitate to contact the undersigned Project Engineer. Project No. 200800328 Data Quality Data Reporting Doris Gonzalez Stefan Smuk Data Quality Engineer Fluids Analysis Support Engineer Overall Report Quality Clay Young Oilphase-DBR Operation Manager, NGC • Ollphase-DBR 7 file 200700328-D • • Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger Table 1: Well and Sample Identification Client: BP Alaska Project No.: 200700328 Field: Orion Well: L-219i Sample ID Sampling Storage Sand Reservoir Conditions Chamber Cylinder Pressure Temperature Depth Depth Ipsia) (°F) Ift MD) Ift ND) MDT Run # 1 1.01 MPSR 2868 Glass SB OBd 2060.23 97.0 12108 -4838 1.02 MPSR 1400 Glass SB OBd 2060.23 97.0 12108 -4838 1.03 MPSR 2870 8626-QA SB OBd 2052 96.0 11776 -4820 1.04 MPSR 1295 8629-QA SB OBd 2052 96.0 11776 -4820 1.05 MPSR 2865 14179-QA SB OBd 2198 95.0 11574 -4809 1.06 MPSR 2876 14185-OA SB OBd 2198 95.0 11574 -4809 1.07 MPSR 1292 14244-QA SB_ OBd 2030 95.0 11191 -4795 1.08 MPSR 1290 14310-QA SB OBd 2030 95.0 11191 -4795 1.09 MPSR 1397 14308-QA SB OBd 1995 94.8 10890 -4783 1.10 MPSR 1399 14332-QA SB OBd 1995 94.8 10890 -4783 MDT Run # 2 1.11 MPSR 2866 14307-QA SB OBd 1913 94.5 10547 -4769 1.12 MPSR 2871 14319-QA SB OBd 1913 94.5 10547 -4769 1.13 MPSR 2867 14333-QA SB OBd 1746 93.0 10003 -4747 1.14 MPSR 2872 14301-OA SB OBd 1746 93.0 10003 -4747 1.15 MPSR 1291 14187-QA SB OBc 1983 91.0 9673 -4675 1.16 MPSR 2875 14320-QA SB OBc 1983 91.0 9673 -4675 1.17 MPSR 1294 14311-QA SB OBb 1959 90.0 9432 -4620 1.18 MPSR 2873 14330-QA SB OBb 1959 90.0 9432 -4620 1.19 MPSR 1401 14314-QA SB_ NBb 1864 85.0 8456 -4362 1.20 MPSR 2869 14313-QA SB NBb 1864 85.0 8456 -4362 1.21 WBM Filtrate N/A - - - - - Ollphase-DBR Pile 200700328-D Client: BP Alaska Well: L-219i • Field: Prudhoe Bay Unit - WOA Schlumberger • t t tt Ollphase-DBR Table 2: Measured Reservoir-Fluid Properties Single-Stage Flash Saturation Sample ID Depth GDR* API** Sol'n. Gas Pressure Gravity*** at Tres (ft. MD) (scf/stb) (°API) (psia) (psia) MDT Run # 1 1.01 12108 - - - - 1.02 12108 - - - - 1.03 11776 - - - - 1.04 11776 - - - - 1.05 11574 - - - - 1.06 11574 - - - - 1.07 11191 - - - - 1.08 11191 - - - - 1.09 10890 - - - - 1.10 10890 161 15.9 0.608 1585197°F~ tt MDT Run # 2 1.11 10547 164 17.4 0.599 - 1.12 10547 195 17.1 0.606 1628 1.13 10003 183 17.4 0.621 1475 1.14 10003 175 17.8 0.617 - 1.15 9673 212 20.2 0.641 1636 1.16 9673 225 20.2 0.677 - 1.17 9432 - - - - 1.18 9432 - - - - 1.19 8456 137 16.1 0.584 1370 1.20 8456 122 16.3 0.580 - Flashed gas scf per barrel of stock tank liquid ~ 60°F. API =141.5/Density -131.5. Specific gravity of flashed gas, relative to air. Volume of live ail at saturation pressure and reservoir temperature, per unit equivalent volume of flashed stock-tank liquid at fi0°F. The separation basis is a single-stage flash to standard conditions. The saturation pressure was measured at a misreported reservoir-temperature of 97°F. The saturation point at Tres= 94.8°F is predicted to be approximately 10 psi lower. 9 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i Table 3: Measured Stock-Tank Oil Pro erties • P r ~J I• Flashed Stock-Tank Oil Properties at Atmopsheric Pressure Sample ID Depth Molar Mass Density Gravity Asphaltene Viscosity Content @ Tres eft. MD) (g/gmol) (g/cc) I°API) (nC5, wt%) (cp) MDT Run # 1 1.01 12108 - 1.015 - - - 1.02 12108 - 1.015 - - - 1.03 11776 - - - - - 1.04 11776 - 1.017 - - - 1.05 11574 - - - - - 1.06 11574 - - - - - 1.07 11191 - - - - - 1.08 11191 - 1.016 - - - 1.09 10890 - - - - - 1.10 10890 392.2 0.960 15.9 4.86 415 MDT Run # 2 1.11 10547 356.8 0.950 17.4 4.65 - 1.12 10547 328.7 0.952 17.1 4.21 197 1.13 10003 344.4 0.950 17.4 4.32 160 1.14 10003 338.8 0.948 17.8 4.26 - 1.15 9673 306.9 0.933 20.2 3.34 80 1.16 9673 300.6 0.933 20.2 3.38 - 1.17 9432 - - - - - 1.18 9432 - - - - - 1.19 8456 363.6 0.959 16.1 5.40 547 1.20 8456 378.2 0.957 16.3 5.58 - 1.21 WBM Filtrate - 1.000 - - - Ollphase-DBR 10 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Well: L-219i Schlumberger • DETAILED EXPERIMENTAL RESULTS -COMPOSITION L Ollphase-DBR File 200700328-D • Client: BP Alaska Well: L-219i Table 4: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.1) Sample 1.10; Cylinder CSB 14332-QA; Depth 10890 ft. MD (-4783' NDSS-, SB_OBd Santl Field: Prudhoe Bay Unit - WOA Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 5.75 2.30 0.00 0.00 0.13 0.73 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.14 0.09 0.00 0.00 0.00 0.03 Methane 16.04 86.06 94.40 0.00 0.00 1.87 30.11 Ethane 30.07 2.91 1.70 0.00 0.00 0.06 0.54 Propane 44.10 1.45 0.58 0.00 0.03 0.04 0.21 I -Butane 58.12 0.50 0.15 0.00 0.01 0.01 0.05 N -Butane 58.12 0.56 0.17 0.00 0.01 0.01 0.06 I -Pentane 72.15 0.21 0.05 0.00 0.00 0.00 0.02 N -Pentane 72.15 1.85 0.45 0.07 0.38 0.11 0.40 C6 84.00 0.19 0.04 0.07 0.30 0.07 0.22 M-C-Pentane 84.16 0.05 0.01 0.00 0.01 0.00 0.01 Benzene 78.11 0.00 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.00 0.00 0.00 0.02 0.00 0.01 C7 96.00 0.16 0.03 0.15 0.57 0.15 0.40 M-C-Hexane 98.19 0.06 0.01 0.01 0.02 0.01 0.02 Toluene 92.14 0.05 0.01 0.18 0.73 0.18 0.50 C8 107.00 0.06 0.01 0.02 0.06 0.02 0.04 E-Benzene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 M/P-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 0-Xylene 106.17 0.00 0.00 0.01 0.03 0.01 0.02 C9 121.00 0.00 0.00 0.11 0.33 0.11 0.22 C10 134.00 0.00 0.00 0.45 1.23 0.44 0.84 C11 147.00 0.00 0.00 0.87 2.20 0.85 1.50 C12 161.00 0.00 0.00 1.40 3.21 1.36 2.19 C13 175.00 0.00 0.00 1.94 4.11 1.90 2.80 C14 190.00 0.00 0.00 2.48 4.83 2.42. 3.29 C15 206.00 0.00 0.00 2.89 5.19 2.82 3.53 C16 222.00 2.91 4.85 2.84 3.30 C17 237.00 3.19 4.99 3.12 3.40 C18 251.00 3.43 5.06 3.35 3.45 C19 263.00 3.61 5.09 3.54 3.47 C20 275.00 3.21 4.32 3.14 2.94 C21 291.00 3.38 4.30 3.30 2.93 C22 300.00 3.22 3.98 3.15 2.71 C23 312.00 2.71 3.22 2.65 2.19 C24 324.00 2.57 2.94 2.52 2.00 C25 337.00 2.56 2.81 2.50 1.91 C26 349.00 2.20 2.33 2.15 1.59 C27 360.00 2.22 2.28 2.17 1.55 C28 372.00 2.38 2.37 2.33 1.61 C29 382.00 1.94 1.88 1.90 1.28 C30 394.00 2.14 2.01 2.09 1.37 C31 404.00 2.07 1.90 2.03 1.29 C32 415.00 1.59 1.42 1.56 0.97 C33 426.00 1.76 1.53 1.72 1.04 C34 437.00 1.13 0.96 1.11 0.65 C35 445.00 1.38 1.15 1.35 0.78 C36+ 850.00 39.75 17.32 38.88 11.79 Total 100.00 100.00 100.00 100.00 100.00 100.00 M W 17.60 370.35 257.83 MOLE RATIO 0.3190 0.6810 Ollphase-DBR 12 File200700328-D • • Client: BP Alaska Well: L-219i Table 5: Calculated Fluid Properties Sample 1.10; Cylinder CSB 14332-OA; Depth 10890 ft. MD ~-4783' NDSS-, SB_OBtl Sand Field: Prudhoe Bay Unit - WOA Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.38 0.07 99.85 99.27 97.69 67.63 C12+ - - 98.05 94.04 95.92 64.04 C20+ - - 76.21 56.71 74.55 38.62 C30+ - - 49.82 26.29 48.74 17.90 C36+ - - 39.75 17.32 38.88 11.79 Molar Mass C7+ 95.64 372.51 372.42 C 12+ - 386.14 386.14 CZO+ - 497.62 497.62 C30+ - 701.94 701.94 C36+ - 850.00 850.00 Density C7+ - 0.921 - C 12+ - 0.923 0.923 CZO+ - 0.950 0.950 C30+ - 0.990 0.990 C36+ - 1.010 1.010 Fluid at 60°F 0.960 Gas Gravity (Air =1) 0.608 Dry Gross Heat Content (BTU/scf) 1,036 Wet Gross Heat Content (BTU/scf 1,018 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 392.17 370.35 850.00 Density (g/cm3) 0.960 0.898 1.010 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 161 - STO Density (g/cm3- 0.960 - STO API Gravity 16.0 - OBM Density (g/cm3) X60°F - Ollphase-DBR 13 File200700328-D • Client: BP Alaska Well: L-219i Figure 1: Stock Tank Oil Chromatogram (Sample 1.1) Sample 1.10; Cylinder CSB 14332-QA; Depth 10890 ft. MD ~-4783' NDSS-, SB_OBd Sand field: Prudhoe Bay Unit - WOA Schlumberger FID1 A, (60?~3 LLNDy14iCHE4M1•1t01L1JATA~0i0C~231CE1@33'E.Dj pA 900 800 7~ 200700328 BP ALASKA 1.10 SSB 14332-QA ~ RF FLASH CELL ao9 sm m ~ m m UID U m 100 N pU p m C m N !fl n Q) ~ Cl ~ N1~1 Qh~nm 610 ~Nm ~N m V ' N NN NNN NNfV61 p7p 1p7p~ uo u? O ~ ry m U CU C CC[CC U ~ C C C CCCW TUB F- U N XU U U U U U ~ ~ U C~ C U O C C C < < < ~~~ III JJJ III ___.1.J_~ 6 0 5 10 15 20 25 30 ~ mi • Figure 2: k-Plot for Equilibrium Check (Sample 1.1) Sample 1.10; Cylinder CSB 14332-QA; Depth 10890 ft. MD (-4783' NDSS-, SB_OBd Sand 3 2 .5 • ~9C4 2 a 1.5 Y m • nC5 ~ 1 0.5 • C6 0 • C7 0 5 - . -4 -3 -2 -1 0 1 2 3 F • Ollphase-DBR 14 File 200700328-D • • • Client: BP Alaska Well: L-219i Table 6: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.11) Sample 1.11; Cylinder CSB 14307-QA; Depth 10547 ft. MD (-4769' NDSS), SB_OBd Santl Field: Prudhoe Bay Unit - WOA Schiumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 4.95 1.95 0.00 0.00 0.11 0.57 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.10 0.06 0.00 0.00 0.00 0.02 Methane 16.04 88.23 95.40 0.00 0.00 1.95 28.08 Ethane 30.07 2.34 1.35 0.00 0.00 0.05 0.40 Propane 44.10 0.94 0.37 0.00 0.03 0.02 0.13 I -Butane 58.12 0.47 0.14 0.00 0.02 0.01 0.06 N -Butane 58.12 1.00 0.30 0.02 0.09 0.04 0.15 I -Pentane 72.15 0.37 0.09 0.02 0.08 0.03 0.08 N -Pentane 72:15 0.58 0.14 0.10 0.46 0.11 0.37 C6 84.00 0.48 0.10 0.17 0.63 0.17 0.47 M-C-Pentane 84.16 0.10 0.02 0.05 0.20 0.05 0.15 Benzene 78.11 0.05 0.01 0.03 0.11 0.03 0.08 Cyclohexane 84.16 0.05 0.01 0.07 0.27 0.07 0.19 C7 96.00 0.17 0.03 0.22 0.75 0.22 0.54 M-C-Hexane 98.19 0.06 0.01 0.10 0.33 0.10 0.24 Toluene 92.14 0.05 0.01 0.21 0.72 0.20 0.51 C8 107.00 0.06 0.01 0.42 1.26 0.41 0.89 E-Benzene 106.17 0.00 0.00 0.05 0.15 0.05 0.11 M/P-Xylene 106.17 0.00 0.00 0.11 0.33 0.11 0.23 0-Xylene 106.17 0.00 0.00 0.11 0.33 0.11 0.23 C9 121.00 0.00 0.00 0.59 1.57 0.58 1.11 C10 134.00 0.00 0.00 1.35 3.24 1.32 2.29 C11 147.00 0.00 0.00 1.84 4.02 1.80 2.84 C12 161.00 0.00 0.00 2.64 5.26 2.58 3.71 C13 175.00 0.00 0.00 2.90 5.31 2.84 3.75 C14 190.00 0.00 0.00 3.44 5.81 3.37 4.10 C15 206.00 0.00 0.00 3.27 5.08 3.19 3.58 C16 222.00 3.47 5.01 3.39 3.54 C17 237.00 3.47 4.69 3.39 3.31 C18 251.00 3.46 4.42 3.39 3.12 C19 263.00 3.44 4.19 3.36 2.96 C20 275.00 3.20 3.73 3.13 2.63 C21 291.00 3.11 3.42 3.04 2.41 C22 300.00 3.09 3.30 3.02 2.33 C23 31 Z.00 2.53 2.60 2.48 1.83 C24 324.00 2.31 2.28 2.25 1.61 C25 337.00 Z.6Z 2.49 Z.56 1.76 C26 349.00 2.15 1.97 2.10 1.39 C27 360.00 2.34 2.08 2.28 1.47 C28 372.00 2.08 1.79 2.03 1.26 C29 382.00 2.19 1.84 2.14 1.30 C30 394.00 2.09 1.70 2.04 1.20 C31 404.00 1.94 1.54 1.90 1.09 C32 415.00 1.67 1.29 1.63 0.91 C33 426.00 1.57 1.18 1.53 0.83 C34 437.00 1.21 0.89 1.19 0.63 C35 445.00 1.75 1.26 1.71 0.89 C36+ 850.00 32.60 12.29 31.88 8.67 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.35 320.44 231.23 MOLE RATIO 0.2943 0.7057 Ollphase-DBR i~ File200700328-D • Client: BP Alaska Well: L-219i Table 7: Calculated Fluid Properties Sample 1.11; Cylinder CSB 14307-QA; Depth 10547 ft. MD (-4769' NDSS-, SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.53 0.10 99.69 98.69 97.50 69.67 C12+ - - 94.53 85.41 92.44 60.27 C20+ - - 68.43 45.65 66.92 32.21 C30+ - - 42.83 20.15 41.89 14.22 C36+ - - 32.60 12.29 31.88 8.67 MDlar Mass C7+ 91.59 323.68 323.59 C12+ - 354.63 354.63 C20+ - 480.42 480.42 C30+ - 681.20 681.20 C36+ - 850.00 850.00 Density C7+ - 0.905 - C12+ - 0.913 0.913 C20+ - 0.945 0.945 C30+ - 0.986 0.986 C36+ - 1.010 1.010 Fluid at 60°F 0.950 Gas Gravity (Air =1) 0.599 Dry Gross Heat Content (BTU/scf) 1,032 Wet Gross Heat Content (BTU/scf 1,014 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 356.84 320.44 850.00 Density (g/cm3) 0.950 0.887 1.010 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 164 - STO Density (g/cm3) 0.950 - STO API Gravity 17.4 - OBM Density (g/cm3)0360°F - Ollphase-DBR iTd File200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Figure 3: Stock Tank Oil Chromatogram (Sample 1.11) Sample 1.11; Cylinder CSB 14307-QA; Depth 10547 ft. MD (-4769' NDSS-, SB_OBd Sand • Fl6^ q (8135 CUi0-tt27CHEM-'-IOILW4TA0 0 7 00 3 2 8111'1~';OIF.OI P0. 000 000 700 200700328 BP ~ 1.11 CSB 14307-QA RF FLASH CYLINDER 300 X00 U U N ~, m ~ U U m ~ m o ~ rvmv ~~onmmo~rx.~vN u m ~ m v ,~ m n m m o ~ ry tv rv rv rv cv rvmmmmm u ' t ~ "' , o m ,yax r im~ U~ ~ U J ,~ c c U UUUUU UU etc ~~~UW~ 5 , ' ~ ~1~''- 4 ~ 7T~fI11~T 1' i-F ' ` ~ c ` i ~ c LF - ~~ ' -~ ~~ I ^' ~Y c c t . ~ , ..._~~~ .:.,,.~,e; t fr I w-.. .~ I ,~+ 1 llf fl 1, 1 1iR °~9 ~ ----r,.-c pJll ~ - 0 0 5 f0 13 20 25 30 35 mi 2.5 2 1.5 a Y 1 O 0.5 0 -0.5 • Ollphase-DBR Figure 4: k-Plot for Equilibrium Check (Sample 1.11) Sample 1.11; Cylinder CSB 14307-QA; Depth 10547 ft. MD (-4769' NDSSI, SB_OBd Sand ~ C3 • nC4 • iC5 • nC5 • C6 • C7 -4 -3 2 1 0 1 2 F 17 File 200700328-D • Client: BP Alaska Well: L-219i Table 8: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.12) Sample 1.12; Cylinder CSB 14319-QA; Depth 10547 ft. MD (-4769 NDSS~, SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 5.19 2.07 0.00 0.00 0.14 0.68 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.02 0.01 0.00 0.00 0.00 0.00 Methane 16.04 86.71 94.84 0.00 0.00 2.28 31.30 Ethane 30.07 2.79 1.63 0.00 0.00 0.07 0.54 Propane 44.10 1.06 0.42 0.02 0.11 0.04 0.21 I -Butane 58.12 0.50 0.15 0.01 0.03 0.02 0.07 N -Butane 58.1 Z 1.09 0.33 0.02 0.11 0.05 0.18 I -Pentane 72.15 0.41 0.10 0.02 0.09 0.03 0.09 N -Pentane 72.15 0.53 0.13 0.04 0.17 0.05 0.16 C6 84.00 0.53 0.11 0.15 0.56 0.16 0.41 M-C-Pentane 84.16 0.10 0.02 0.05 0.18 0.05 0.13 Benzene 78.11 0.04 0.01 0.02 0.10 0.02 0.07 Cyclohexane 84.16 0.14 0.03 0.07 0.25 0.07 0.18 C7 96.00 0.27 0.05 0.20 0.68 0.21 0.47 M-C-Hexane 98.19 0.11 0.02 0.10 0.32 0.10 0.22 Toluene 92.14 0.11 0.02 0.23 0.79 0.22 0.54 C8 107.00 0.18 0.03 0.40 1.20 0.40 0.81 E-Benzene 106.17 0.00 0.00 0.05 0.15 0.05 0.10 M/P-Xylene 106.17 0.00 0.00 0.11 0.32 0.10 0.21 0-Xylene 106.17 0.00 0.00 0.11 0.32 0.10 O.Z1 C9 121.00 0.14 0.02 0.58 1.53 0.57 1.03 C10 134.00 0.08 0.01 1.33 3.18 1.30 2.13 C11 147.00 0.00 0.00 1.83 3.98 1.78 2.67 C12 161.00 0.00 0.00 2.62 5.21 2.55 3.49 C13 175.00 0.00 0.00 2.87 5.26 2.80 3.52 C14 190.00 0.00 0.00 3.43 5.78 3.34 3.87 C15 206.00 0.00 0.00 3.25 5.06 3.17 3.39 C16 222.00 3.47 5.01 3.38 3.36 C17 237.00 3.48 4.70 3.39 3.15 C18 251.00 3.49 4.45 3.40 2.98 C19 263.00 3.47 4.23 3.38 2.83 C20 275.00 3.25 3.78 3.16 2.53 C21 291.00 3.15 3.47 3.07 2.33 C22 300.00 3.16 3.37 3.07 2.26 C23 312.00 2.58 2.65 2.51 1.78 C24 324.00 2.37 2.34 2.30 1.57 C25 337.00 2.44 2.32 2.38 1.55 C26 349.00 2.44 2.24 2.38 1.50 C27 360.00 2.32 2.06 2.25 1.38 C28 372.00 2.15 1.85 2.09 1.24 C29 382.00 2.22 1.86 2.16 1.25 C30 394.00 2.18 1.77 2.12 1.19 C31 404.00 2.06 1.63 2.00 1.09 C32 415.00 1.59 1.23 1.55 0.82 C33 426.00 1.57 1.18 1.53 0.79 C34 437.00 1.43 1.05 1.39 0.70 C35 445.00 2.06 1.48 2.00 0.99 C36+ 850.00 31.66 11.93 30.83 7.99 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 17.55 320.39 220.43 MOLE RATIO 0.3301 0.6699 Ollphase-DBR fi File200700328-D • • Client: BP Alaska Well: L-219i Table 9: Calculated Fluid Properties Sample 1.12; Cylinder CSB 14319-QA; Depth 10547 ft. MD (-4769 NDSS~, SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 1.17 0.21 99.75 98.93 97.16 66.35 C12+ - - 94.69 85.93 92.20 57.57 C20+ - - 68.61 46.22 66.80 30.96 C30+ - - 42.54 20.27 41.42 13.58 C36+ - - 31.66 11.93 30.83 7.99 Molar Mass C7+ 97.93 323.06 322.82 C12+ - 353.06 353.06 C20+ - 475.57 475.57 C30+ - 672.27 672.27 C36+ - 850.00 850.00 Density C7+ - 0.905 - C 12+ - 0.912 0.912 C20+ - 0.944 0.944 C30+ - 0.985 0.985 C36+ - 1.010 1.010 Fluid at 60°F 0.952 Gas Gravity (Air =1 ~ 0.606 Dry Gross Heat Content (BTU/scf) 1,041 Wet Gross Heat Content (BTU/scf 1,022 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 328.70 320.39 850.00 Density (g/cm3) 0.952 0.887 1.010 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 195 - STO Density (g/cm3) 0.952 - STO API Gravity 17.1 - OBM Density (g/cm3) C~60°F - Ollphase-DBR 19 File200700328-D Client: BP Alaska Well: L-219i • i• Field: Prudhoe Bay Unit - WOA Schlumberger Figure 5: Stock Tank Oil Chromatogram (Sample 1.12) Sample 1.12: Cvlinder CSB 14319-QA; Depth 10547 ft. MD (-4769 NDSS1, SB_OBd Sand FID^ n. (GL'~i OL~B-P270HEM-"101lNATAVA1003221CE!Zi? D' DA A00 700 200700328 BP 1.12 CSB 14319-QA ~ RF FLASH CELL 500 200 N N m U U m v 100 U o o o c u u j rpp~, c 0. m O ~ V i[1 m^ m Q~ O N m N W N (r10 ~fl m ^m mOm~N (rXr N N N N N N NN N(~ ('yr y, ^u ° c~ ~ ~y T m ~Xm ~ o~ ~ p p ~ U U U U U ~ U c c c c c c c i im UUUUUUUU UU WUUU cccccc ccc cc ccccc µ ~~ 0 0 5 f0 15 20 25 30 35 mi z 1.8 1.6 1.4 1.2 n 1 rt- o i 0.8 0.6 0.4 0.2 0 -4 i• Ollphase-DBR Figure 6: k-Plot for Equilibrium Check (Sample 1.12) Sample 1.12; Cylinder CSB 14319-QA; Depth 10547 ft. MD I-4769 NDSS-, SB_OBd Sand • iC4 • 3 • nC4 • nC5 • C6 -3 -2 -1 0 1 2 3 F 20 File 200700328-D • • Client: BP Alaska Well: L-2191 Table 10: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.13) Sample 1.13; Cylinder CSB 14333-QA; Depth 10003 ft. MD (-4747 NDSS-, SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 3.72 1.52 0.00 0.00 0.09 0.49 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.11 0.07 0.00 0.00 0.00 0.02 Methane 16.04 82.85 92.92 0.00 0.00 2.10 29.64 Ethane 30.07 4.60 2.75 0.00 0.00 0.12 0.88 Propane 44.10 2.92 1.19 0.00 0.00 0.07 0.38 I -Butane 58.12 0.90 0.28 0.00 0.01 0.02 0.10 N -Butane 58.12 2.07 0.64 0.01 0.03 0.06 0.22 I -Pentane 72.15 0.64 0.16 0.01 0.05 0.03 0.09 N -Pentane 72.15 0.72 0.18 0.02 0.09 0.04 0.1 Z C6 84.00 0.61 0.13 0.14 0.54 0.15 0.41 M-C-Pentane 84.16 0.09 0.02 0.01 0.03 0.01 0.03 Benzene 78.11 0.04 0.01 0.02 0.08 0.02 0.06 Cyclohexane 84.16 0.09 0.02 0.08 0.30 0.08 0.21 C7 96.00 0.21 0.04 0.24 0.80 0.24 0.56 M-C-Hexane 98.19 0.05 0.01 0.13 0.42 0.13 0.29 Toluene 92.14 0.10 0.02 0.11 0.40 0.11 0.28 C8 107.00 0.1 Z 0.02 0.46 1.40 0.45 0.96 E-Benzene 106.17 0.00 0.00 0.10 0.29 0.09 0.20 M/P-Xylene 106.17 0.00 0.00 0.17 0.51 0.16 0.35 0-Xylene 106.17 0.00 0.00 0.13 0.40 0.13 0.27 C9 121.00 0.07 0.01 0.62 1.66 0.61 1.13 C10 134.00 0.07 0.01 1.63 3.93 1.59 2.68 C11 147.00 0.00 0.00 2.06 4.53 2.01 3.09 C12 161.00 0.00 0.00 2.56 5.15 2.50 3.51 C13 175.00 0.00 0.00 3.16 5.84 3.08 3.98 C14 190.00 0.00 0.00 3.39 5.77 3.30 3.93 C15 206.00 0.00 0.00 3.27 5.13 3.18 3.49 C16 222.00 3.60 5.25 3.51 3.58 C17 237.00 3.21 4.38 3.13 2.98 C18 251.00 3.34 4.30 3.25 2.93 C19 263.00 3.36 4.13 3.27 2.81 C20 275.00 2.97 3.49 2.89 2.38 C21 291.00 2.96 3.29 2.89 2.24 C22 300.00 2.75 2.97 2.68 2.02 C23 312.00 2.60 2.69 2.53 1.83 C24 324.00 2.49 2.49 2.43 1.70 C25 337.00 2.14 2.05 2.08 1.40 C26 349.00 2.06 1.91 2.01 1.30 C27 360.00 2.16 1.94 2.10 1.32 C28 372.00 1.99 1.73 1.94 1.18 C29 382.00 2.07 1.75 2.01 1.19 C30 394.00 1.75 1.44- 1.71 0.98 C31 404.00 1.84 1.47 1.79 1.00 C32 415.00 1.63 1.27 1.59 0.86 C33 426.00 1.28 0.97 1.25 0.66 C34 437.00 1.15 0.85 1.12 0.58 C35 445.00 1.24 0.90 1.21 0.61 C36+ 850.00 35.11 13.36 34.22 9.10 Total 100.00 100.00 100.00 100.00 100.00 100.00 M W 17.99 323.45 226.01 MOLE RATIO 0.3190 0.6810 Ollphase-DBR 21 File200700328-D • C • Client: BP Alaska Well: L-219i Table 11: Calculated Fluid Properties Sample 1.13; Cylinder CSB 14333-OA; Depth 10003 ft. MD ~-4747 NDSS-, SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.86 0.16 99.82 99.28 97.31 67.66 C12+ - - 94.07 84.53 91.68 57.56 C20+ - - 68.18 44.57 66.45 30.36 C30+ - - 44.00 20.26 42.88 13.80 C36+ - - 35.11 13.36 34.22 9.10 Molar Mass C7+ 96.89 325.22 325.05 C 12+ - 359.97 359.97 C20+ - 494.76 494.76 C30+ - 702.34 702.34 C36+ - 850.00 850.00 Density C7+ - 0.907 - C 12+ - 0.916 0.916 C20+ - 0.949 0.949 C30+ - 0.990 0.990 C36+ - 1.010 1.010 Fluid at 60°F 0.951 Gas Gravity (Air =1- 0.621 Dry Gross Heat Content (BTU/scf) 1,077 Wet Gross Heat Content (BTU/scf 1,059 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 344.41 323.45 850.00 Density (g/cm3) 0.951 0.888 1.010 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 183 - STO Density (g/cm3) 0.951 - STO API Gravity 17.4 - OBM Density (g/cm3)0360°F - Ollphase-DBR 22 File 200700328-D • i• i• Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger Figure 7: Stock Tank Oil Chromatogram (Sample 1.13) Sample 1.13; Cylinder CSB 14333-QA; Depth 10003 ft. MD (-4747 NDSS-, SB_OBd Sand FID1 A, fG13~, CU+B-Ip7CHEM•1t01L1DATA~U07~A328'rCY1S+33.Gj M 960 400 750 200700328 BP 1.13 CSB 14333-MA 300 RF FLASH CYLINDER zw mo 15a +oo ~ m U~ U ~ m ~ o m a ~ ~ c r~ ~ T ~ rv m' ~' ~~ m m rv rv rvrv rvNrvnmrv°mmmm"n UU UUU ~ o ~'1Xm ~ V U U U U V UUUU ~ ~ m UUU UU( U d (1~ ~ (1 (~0 ~ i) ~,. C ~ C C C C ~ C CC CCCCC CC CCC[[ C C (CjT I _ 0 0 5 10 15 20 75 30 35 mi Figure 8: k-Plot for Equilibrium Check Sample 1.13) Sample 1.13; Cylinder CSB 14333-QA; Depth 10003 ft. MD (-4747 NDSSI, SB_OBd Sand 3 2.5 2 a 1.5 Y J 1 0.5 0 -0.5 -4 Ollphase-DBR • iC5 • C7 - - -3 -2 1 0 1 2 F ~ File200700328-D 3 C • Client: BP Alaska Well: L-219i Table 12: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.14) Sample 1.14; Cylinder CSB 14301-OA; Depth 10003 ft. MD (-4747' NDSS-, SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % W1' % MOLE Carbon Dioxide 44.01 3.87 1.57 0.00 0.00 0.09 0.47 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.05 0.03 0.00 0.00 0.00 0.01 Methane 16.04 83.92 93.50 0.00 0.00 2.04 28.07 Ethane 30.07 4.17 2.48 0.00 0.00 0.10 0.74 Propane 44.10 2.22 0.90 0.01 0.05 0.06 0.31 I -Butane 58.12 0.85 0.26 0.01 0.04 0.03 0.11 N -Butane 58.12 1.89 0.58 0.03 0.17 0.08 0.29 I -Pentane 72.15 0.65 0.16 0.03 0.14 0.05 0.15 N -Pentane 72.15 0.73 0.18 0.05 0.22 0.07 0.21 C6 84.00 0.66 0.14 0.22 0.82 0.23 0.62 M-C-Pentane 84.16 0.14 0.03 0.08 0.30 .0.08 0.22 Benzene 78.11 0.04 0.01 0.04 0.14 0.04 0.10 Cyclohexane 84.16 0.14 0.03 0.12 0.43 0.12 0.31 C7 96.00 0.21 0.04 0.31 0.99 0.31 0.70 M-C-Hexane 98.19 0.05 0.01 0.17 0.52 0.16 0.37 Toluene 92.14 0.36 0.07 0.26 0.88 0.27 0.64 C8 107.00 0.06 0.01 0.60 1.72 0.59 1.21 E-Benzene 106.17 0.00 0.00 0.08 0.22 0.07 0.15 M/P-Xylene 106.17 0.00 0.00 0.17 0.49 0.17 0.34 0-Xylene 106.17 0.00 0.00 0.13 0.39 0.13 0.27 C9 121.00 0.00 0.00 0.85 2.15 0.83 1.50 C10 134.00 0.00 0.00 1.70 3.91 1.66 2.74 C11 147.00 0.00 0.00 2.14 4.47 2.09 3.13 C 12 161.00 0.00 0.00 2.94 5.62 2.87 3.93 C13 175.00 0.00 0.00 3.17 5.57 3.09 3.90 C14 190.00 0.00 0.00 3.69 5.97 3.60 4.18 C15 206.00 0.00 0.00 3.37 5.02 3.28 3.51 C16 222.00 3.55 4.92 3.47 3.44 C17 237.00 3.46 4.48 3.37 3.13 C18 251.00 3.41 4.18 3.33 2.92 C19 263.00 3.37 3.94 3.29 2.76 C20 275.00 2.96 3.31 2.89 2.32 C21 291.00 3.16 3.34 3.09 2.34 C22 300.00 3.01 3.08 2.93 2.15 C23 312.00 2.43 2.39 2.37 1.67 C24 324.00 2.24 2.12 2.18 1.48 C25 337.00 2.29 2.09 2.24 1.46 C26 349.00 2.31 2.03 2.25 1.42 C27 360.00 2.26 1.93 2.21 1.35 C28 372.00 1.89 1.56 1.84 1.09 C29 382.00 2.08 1.67 2.03 1.17 C30 394.00 Z.00 1.56 1.95 1.09 C31 404.00 1.83 1.39 1.78 0.97 C32 415.00 1.77 1.31 1.73 0.92 C33 426.00 1.54 1.11 1.50 0.78 C34 437.00 1.38 0.97 1.35 0.68 C35 445.00 1.59 1.10 1.55 0.77 C36+ 850.00 31.31 11.32 30.55 7.92 Total 100.00 100.00 100.00 100.00 100.00 100.00 M W 17.88 307.22 220.36 MOLE RATIO 0.3002 0.6998 Ollphase-DBR F31 File20(1700328-D • • • Client: BP Alaska Well: L-219i Table 13: Calculated Fluid Properties Sample 1.14; Cylinder CSB 14301-QA; Depth 10003 ft. MD ~-4747' NDSS-, SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 1.02 0.20 99.64 98.56 97.24 69.03 C12+ - - 93.00 81.96 90.74 57.35 C20+ - - 66.03 42.27 64.43 29.58 C30+ - - 41.42 18.75 40.41 13.12 C36+ - - 31.31 11.32 30.55 7.92 Molar Mass C7+ 90.86 310.60 310.40 C 12+ - 348.62 348.62 C20+ - 479.96 479.96 C30+ - 678.47 678.47 C36+ - 850.00 850.00 Density C7+ - 0.901 - C 12+ - 0.911 0.911 C20+ - 0.945 0.945 C30+ - 0.986 0.986 C36+ - 1.010 1.010 Fluid at 60°F 0.948 Gas Gravity (Air =1) 0.617 Dry Gross Heat Content (BTU/scf) 1,070 Wet Gross Heat Content (BTU/scf 1,051 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 338.84 307.22 850.00 Density (g/cm3- 0.948 0.884 1.010 Single Stage Flash Data Original STO De-Contaminated GOR scf/stb) 176 - STO Density (g/cm3) 0.948 - STO API Gravity 17.8 - OBM Density (g/cm3)0360°F - Ollphase-DBR File200700328-D • Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger Figure 9: Stock Tank Oil Chromatogram (Sample 1.14) Sample 1.14; Cylinder CSB 14301-QA; Depth 10003 ft. MD (-4747' NDSS-, SB_OBd Sand FID1 a, f!:~~, Dfp9.1V,'CNEL-1101UL~tA~L07fI1;29}CY1a.301 R.D) PA B00 800 700 200700328 BP 1.14 CSB 14301-QA eaD RF FLASH CYLINDER 500 mD too m U m U N ~ ~~ 0 0 ~ 100 U ((pp ~® i. ~ ~ ~. O ~ N f'7 < N U) n O] m R ry N N N N fV Nm f~Y ~l'7 Rry1R~A*Im Xa1 ~ U p UUUUU UU U ° ° r~UUU O7 ~ U U UUUUU U n ' ~ ' ~ ~ ~ < < I rt t ~ ~..i.~...~d.,~.i, ~,~o-rtt~!>r~fm®nr~~mnt~ ~rlrrlrT~r:~ rrrr~r^---Y-~-,- .~ r~,~V D 0 5 10 15 20 t5 30 35 mi • Figure 10: k-Plot for Equilibrium Check (Sample 1.14) Sample 1.14; Cylinder CSB 14301-OA; Depth 10003 ft. MD (-4747' NDSS-, SB_OBd Sand 3 2.5 2 a 1.5 Y J 1 0.5 0 -0.5 • nC4 • iC5 • nC5 • C6 • C7 -4 3 -2 -1 0 1 2 3 F • Ollphase-DBR 26 File200700328-D • Client: BP Alaska Well: L-219i Table 14: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.15) Sample 1.15; Cylinder CSB 14187-QA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Sand Field: Prudhoe Bay Unit - WOA Schlumherger Component MW Flashed Gas Flashed Liquid Monophasic Fluid ~g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 4.27 1.80 0.00 0.00 0.13 0.58 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.05 0.03 0.00 0.00 0.00 0.01 Methane 16.04 80.20 92.74 0.00 0.00 2.46 30.12 Ethane 30.07 2.58 1.59 0.00 0.00 0.08 0.52 Propane 44.10 1.90 0.80 0.00 0.02 0.06 0.27 I -Butane 58.12 1.97 0.63 0.01 0.07 0.07 0.25 N -Butane 58.12 3.10 0.99 0.05 0.24 0.14 0.48 I -Pentane 72.15 1.71 0.44 0.10 0.38 0.15 0.40 N -Pentane 72.15 1.91 0.49 0.15 0.57 0.20 0.54 C6 84.00 1.22 0.27 0.50 1.66 0.52 1.21 M-C-Pentane 84.16 0.27 0.06 0.20 0.68 0.21. 0.48 Benzene 78.11 0.00 0.00 0.02 0.07 0.02 0.05 Cyclohexane 84.16 0.18 0.04 0.25 0.83 0.25 0.57 C7 96.00 0.36 0.07 0.71 2.07 0.70 1.42 M-C-Hexane 98.19 0.11 0.02 0.55 1.58 0.54 1.07 Toluene 92.14 0.05 0.01 0.27 0.81 0.26 0.55 C8 107.00 0.12 0.02 1.16 3.05 1.13 2.07 E-Benzene 106.17 0.00 0.00 0.06 0.16 0.06 0.11 M/P-Xylene 106.17 0.00 0.00 0.23 0.62 O.Z3 0.42 0-Xylene 106.17 0.00 0.00 0.14 0.38 0.14 0.26 C9 121.00 0.00 0.00 1.40 3.25 1.35 2.19 C10 134.00 0.00 0.00 2.34 4.92 2.27 3.32 C11 147.00 0.00 0.00 2.54 4.86 2.46 3.28 C12 161.00 0.00 0.00 3.17 5.54 3.07 3.74 C13 175.00 0.00 0.00 3.59 5.78 3.48 3.90 C14 190.00 0.00 0.00 3.85 5.71 3.73 3.86 C15 206.00 0.00 0.00 3.55 4.86 3.45 3.28 C16 222.00 3.77 4.78 3.65 3.23 C17 237.00 3.32 3.95 3.22 2.67 C18 251.00 3.33 3.74 3.23 2.53 C19 263.00 3.20 3.43 3.10 2.32 C20 275.00 2.92 2.99 2.83 2.02 C21 291.00 2.84 2.75 2.75 1.86 C22 300.00 2.76 2.59 2.67 1.75 C23 312.00 2.29 2.07 2.22 1.40 C24 324.00 2.40 2.09 2.33 1.41 C25 337.00 1.93 1.61 1.87 1.09 C26 349.00 1.78 1.44 1.73 0.97 C27 360.00 2.1 Z 1.66 2.06 1.12 C28 372.00 1.89 1.43 1.83 0.97 C29 382.00 1.97 1.45 1.91 0.98 C30 394.00 1.57 1.12 1.52 0.76 C31 404.00 1.88 1.31 1.82 0.88 C32 415.00 1.34 0.91 1.30 0.61 C33 426.00 1.36 0.90 1.32 0.61 C34 437.00 1.46 0.94 1.41 0.63 C35 445.00 1.42 0.90 1.38 0.61 C36+ 850.00 29.61 9.81 28.70 6.63 Total 100.00 100.00 100.00 100.00 100.00 100.00 MW 18.55 281.70 196.24 MOLE RATIO 0.3248 0.6752 Ollphase-DBR 27 File200700328-D • • • Client: BP Alaska Well: L-219i Table 15: Calculated Fluid Properties Sample 1.15; Cylinder CSB 14187-QA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Sand Field: Prudhoe Bay Unit - WOA Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 1.09 0.22 99.19 97.06 96.18 65.61 C12+ - - 89.33 73.77 86.59 49.82 C20+ - - 61.54 35.98 59.65 24.29 C30+ - - 38.64 15.89 37.45 10.73 C36+ - - 29.61 9.81 28.70 6.63 Molar Mass C7+ 91.64 287.90 287.68 C12+ - 341.11 341.11 C20+ - 481.86 481.86 C30+ - 684.79 684.79 C36+ - 850.00 850.00 Density C7+ - 0.893 - C 12+ - 0.909 0.909 C20+ - 0.946 0.946 C30+ - 0.987 0.987 C36+ - 1.010 1.010 Fluid at 60°F 0.933 Gas Gravity (Air =1) 0.641 Dry Gross Heat Content (BTU/scf) 1,101 Wet Gross Heat Content (BTU/scf 1,081 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 306.91 281.70 850.00 Density (g/cm31 0.933 0.876 1.010 Single Stage Flash Data Original STO De-Contaminated GOA (scf/stb) 212 - STO Density (g/cm3) 0.933 - STO API Gravity 20.2 - OBM Density (g/cm3)0360°F - Ollphase-DBR 28 File 200700328-D • • • Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger Figure 11: Stock Tank Oil Chromatogram (Sample 1.15) Sample 1.15; Cylinder CSB 14187-QA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Sand RD1 a, (5!O~i i.L1B- 01i THEW-AO'L'~.DATAbD ;S328'~CE13187.D) M Y00 800 7110 200700328 BP ~ 1.15 SSB 14187-QA RF FLASH CELL 2DO Nl ~ U ° m 0 ~ oU U u m T [ m C 100 i ~ U ~ J 00 U ~T ~xU ~ ~ n m ~ N~ n m m ~rvrvv~N nalp1p tv~m ~n c U U c U U~ cUUUUU UUVUUU~ mIU 6 mi ~ c ~ %~mc U U ~ U c c cccccccc ccccccWc _ 0 0 5 10 13 ZO 25 30 35 mi Figure 12: k-Plot for Equilibrium Check (Sample 1.15) Sample 1.15; Cylinder CSB 14187-OA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Sand 2.5 2 a 1.5 Y o ~ 0.5 0 -0.5 Ollphase-DBR • C3 • iC4 • nC4 • nC5 5 • C6 • C7 -4 -3 -2 -1 0 1 2 F 29 File 200700328-D • • Client: BP Alaska Well: L-219i Table 16: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.16) Sample 1.16; Cylinder CSB 14320-OA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Sand Field: Prudhoe Bay Unit - WOA Schlumberger Component MW Flashed Gas Flashed Li uid Monophasic Fluid (g/mole) WT % MOLE % WT ~° MOLE % WT % MOLE Carbon Dioxide 44.01 4.02 1.79 0.00 0.00 0.14 0.62 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.29 0.20 0.00 0.00 0.01 0.07 Methane 16.04 74.53 91.04 0.00 0.00 2.55 31.42 Ethane 30.07 2.32 1.51 0.00 0.00 0.08 0.52 Propane 44.10 1.76 0.78 0.02 0.15 0.08 0.37 I -Butane 58.12 2.05 0.69 0.02 0.11 0.09 0.31 N -Butane 58.12 3.56 1.20 0.06 0.29 0.18 0.60 I -Pentane 72.15 2.47 0.67 0.09 0.37 0.17 0.47 N -Pentane 72.15 2.61 0.71 0.13 0.53 0.22 0.59 C6 84.00 2.74 0.64 0.52 1.81 0.60 1.41 M-C-Pentane 84.16 0.69 0.16 0.19 0.67 0.21 0.49 Benzene 78.11 0.04 0.01 0.02 0.07 0.02 0.05 Cyclohexane 84.16 0.56 0.13 0.23 0.81 0.25 0.58 C7 96.00 1.18 0.24 0.71 2.16 0.73 1.50 M-C-Hexane 98.19 0.45 0.09 0.52 1.54 0.52 1.04 Toluene 92.14 0.19 0.04 0.42 1.34 0.42 0.89 C8 107.00 0.44 0.08 1.12 3.06 1.10 2.03 E-Benzene 106.17 0.00 0.00 0.11 O.Z9 0.10 0.19 M/P-Xylene 106.17 0.00 0.00 0.23 0.62 0.22 0.41 0-Xylene 106.17 0.00 0.00 0.14 0.38 0.13 0.25 C9 121.00 0.12 O.OZ 1.30 3.14 1.26 2.06 C10 134.00 0.00 0.00 2.25 4.88 2.17 3.20 C11 147.00 0.00 0.00 2.42 4.79 2.34 3.14 C12 161.00 0.00 0.00 3.00 5.42 2.89 3.55 C13 175.00 0.00 0.00 3.23 5.38 3.12 3.52 C14 190.00 0.00 0.00 3.76 5.77 3.64 3.78 C15 206.00 0.00 0.00 3.33 4.71 3.22 3.08 C16 222.00 3.39 4.45 3.28 2.91 C17 237.00 3.24 3.98 3.13 2.61 C18 251.00 3.10 3.60 3.00 2.36 C19 263.00 3.07 3.40 2.97 2.23 CZO 275.00 2.62 2.77 2.53 1.81 C21 291.00 2.62 2.62 2.53 1.72 C22 300.00 2.57 2.49 2.48 1.63 C23 312.00 2.10 1.96 2.03 1.28 C24 324.00 1.85 1.66 1.78 1.09 C25 337.00 1.92 1.66 1.86 1.09 C26 349.00 1.77 1.48 1.71 0.97 C27 360.00 1.89 1.53 1.83 1.00 C28 372.00 1.71 1.34 1.65 0.88 C29 382.00 1.63 1.24 1.57. 0.81 C30 394.00 1.79 1.32 1.72 0.86 C31 404.00 1.57 1.13 1.51 0.74 C32 415.00 1.31 0.92 1.27 0.60 C33 426.00 1.27 0.87 1.23 0.57 C34 437.00 1.14 0.76 1.10 0.50 C35 445.00 1.07 0.70 1.03 0.46 C36+ 850.00 34.53 11.83 33.35 7.75 Total 100.00 100.00 100.00 100.00 100.00 100.00 M W 19.60 291.18 197.47 MOLE RATIO 0.3451 0.6549 Ollphase-DBR 30 File 200700328-D • • • Client: BP Alaska Well: L-219i Table 17: Calculated Fluid Properties Sample 1.16; Cylinder CSB 14320-QA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Sand field: Prudhoe Bay Unit - WOA Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 3.66 0.77 99.15 96.74 95.88 63.62 C12+ - - 89.49 72.99 86.42 47.80 C20+ - - 63.35 36.28 61.18 23.76 C30+ - - 42.68 17.53 41.22 11.48 C36+ - - 34.53 11.83 33.35 7.75 Molar Mass C7+ 93.16 298.45 297.59 C 12+ - 357.00 357.00 C20+ - 508.48 508.48 C30+ - 708.96 708.96 C36+ - 850.00 850.00 Density C7+ - 0.900 - C 12+ - 0.916 0.916 C20+ - 0.953 0.953 C30+ - 0.991 0.991 C36+ - 1.010 1.010 Fluid at 60°F 0.933 Gas Gravity (Air =1) 0.677 Dry Gross Heat Content (BTU/scf) 1,153 Wet Gross Heat Content (BTU/scf 1,133 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 300.63 291.18 850.00 Density ~g/cm3) 0.933 0.879 1.010 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 225 - STO Density (g/cm3) 0.933 - STO API Gravity 20.2 - OBM Density (g/cm3) 0160°F - Ollphase-DBR 31 file200700326-D • Client: BP Alaska Well: L-219i FID1 d, (4-t36 CLA6~11:7CNE!A-1161L16 AiA'L97C03:81LY143;U.Dj W 900 800 700 200700328 BP 1.16 CSB 14320-QA 800 RF FLASH CYLINDER 500 300 zoo m h U m UfD o m 100 ~ ~ p o ~ ~ r U ~ ~ ^ ry m ~ i[7 ~D n m T O ~ N 01 7 i0 ID n m T~ ~nR'rty7 ~ UUUUUU W m ~X V r c U-o c U V V U U U UUUUUU UUU U c c c c c c c ccccccc cc ccccc -_ 0 0 5 10 15 20 ?5 30 35 mi i• Figure 13: Stock Tank Oil Chromatogram (Sample 1.16) Sample 1.16; Cylinder CSB 14320-QA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Santl Figure 14: k-Plot for Equilibrium Check (Sample 1.16) Sample 1.16; Cylinder CSB 14320-QA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Sand 2.5 2 1.5 6 Y O J 1 0.5 0 _ ,,, , ~ C3 • nC4 • i~ ~ nC5 • C6 Field: Prudhoe Bay Unit - WOA Schlumberger • C7 -4 -3 2 -1 0 1 2 3 F i• Ollphase-DBR 32 File200700328-D • • • Client: BP Alaska Well: L-219i Table 18: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.19) Sample 1.19; Cylinder CSB 14314-QA; Depth 8456 ft. MD ~-4362 NDSS-, SB_NBb Sand Field: Prudhoe Bay Unit - WOA Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 0.99 0.38 0.00 0.00 0.02 0.11 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.56 0.34 0.00 0.00 0.01 0.09 Methane 16.04 92.78 97.87 0.00 0.00 1.66 27.12 Ethane 30.07 0.21 0.12 0.00 0.00 0.00 0.03 Propane 44.10 0.26 0.10 0.00 0.00 0.00 0.03 I -Butane 58.12 0.24 0.07 0.00 0.01 0.01 0.03 N -Butane 58.12 0.79 0.23 0.01 0.08 0.03 0.12 I -Pentane 72.15 0.51 0.12 0.03 0.13 0.03 0.13 N -Pentane 72.15 1.83 0.43 0.06 0.28 0.09 0.32 C6 84.00 0.74 0.15 0.23 0.97 0.24 0.74 M-C-Pentane 84.16 0.10 0.02 0.06 0.25 0.06 0.19 Benzene 78.11 0.00 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.10 0.02 0.06 0.26 0.06 0.19 C7 96.00 0.34 0.06 0.37 1.38 0.37 1.01 M-C-Hexane 98.19 0.06 0.01 0.14 0.52 0.14 0.38 Toluene 92.14 0.22 0.04 0.24 0.94 0.24 0.69 C8 107.00 0.19 0.03 0.58 1.92 0.57 1.40 E-Benzene 106.17 0.00 0.00 0.04 0.13 0.04 0.09 M/P-Xylene 106.17 0.00 0.00 0.06 0.21 0.06 0.15 0-Xylene 106.17 0.00 0.00 0.05 0.18 0.05 0.13 C9 121.00 0.07 0.01 0.69 2.03 0.68 1.47 C10 134.00 0.00 0.00 1.13 3.00 1.11 2.17 C11 147.00 0.00 0.00 1.38 3.35 1.36 2.42 C12 161.00 0.00 0.00 1.88 4.16 1.84 3.01 C13 175.00 0.00 0.00 2.28 4.64 2.24 3.35 C14 190.00 0.00 0.00 2.64 4.96 2.59 3.59 C15 206.00 0.00 0.00 2.62 4.53 2.57 3.27 C16 222.00 2.81 4.52 2.76 3.27 C17 237.00 2.64 3.98 2.60 2.88 C18 251.00 2.74 3.89 2.69 2.81 C19 263.00 2.73 3.70 2.68 2.67 C20 275.00 2.56 3.32 2.51 2.40 C21 291.00 2.60 3.19 2.56 2.31 C22 300.00 2.55 3.03 2.50 2.19 C23 31 2.00 2.13 2.44 2.10 1.76 C24 324.00 2.22 2.44 2.18 1.76 C25 337.00 1.91 2.02 1.87 1.46 C26 349.00 1.96 2.00 1.92 1.45 C27 360.00 1.83 1.81 1.79 1.31 C28 372.00 1.89 1.81 1.85 1.31 C29 382.00 1.96 1.83 1.92 1.32 C30 394.00 1.61 1.46 1.58 1.06 C31 404.00 1.95 1.72 1.91 1.24 C32 415.00 1.34 1.15 1.31 0.83 C33 426.00 1.39 1.16 1.36 0.84 C34 437.00 1.38 1.13 1.36 0.82 C35 445.00 1.25 1.00 1.23 0.72 C36+ 850.00 44.01 18.47 43.23 13.35 Total 100.00 100.00 100.00 100.00 100.00 100.00 M W 16.92 356.66 262.53 MOLE RATIO 0.2771 0.7229 Ollphase-DBR 33 File200700328-D • Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i Table i9: Calculated Fluid Properties Sample 1.1 y; t;ylmder U5U "1 43 1 4-11/a; Uepth tf45ti tt. MU ~-43tiL I VUSJ~, Jtf_IVtit) Cana Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 1.08 0.19 99.67 98.53 97.91 71.28 C12+ - - 94.87 84.35 93.17 60.98 C20+ - - 74.53 49.98 73.20 36.13 C30+ - - 52.93 26.09 51.99 18.86 C36+ - - 44.01 18.47 43.23 13.35 Molar Mass C7+ 95.86 360.80 360.60 C 12+ - 401.12 401.12 C20+ - 531.91 531.91 C30+ - 723.64 723.64 C36+ - 850.00 850.00 Density C7+ - 0.921 - C 12+ - 0.930 0.930 C20+ - 0.959 0.959 C30+ - 0.993 0.993 C36+ - 1.010 1.010 Fluid at 60°F 0.959 • • Gas Gravity (Air =1 ~ 0.584 Dry Gross Heat Content (BTU/scf) 1,044 Wet Gross Heat Content (BTU/scf 1,026 OBM Contamination Level cwt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+Properties MW 363.56 356.66 850.00 Density (g/cm3 0.959 0.896 1.010 Single Stage Flash Data Original STO De-Contaminated GOA (scf/stb) 137 - STO Density (g/cm3) 0.959 - STO API Gravity 16.1 - OBM Density (g/cm3- Cc360°F - Ollphase-DBR 34 file200700328-D • Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger Figure 15: Stock Tank Oil Chromatogram (Sample 1.19) Sample 1.19; Cylinder CSB 14314-QA; Depth 8456 ft. MD (-4362 NDSS1, SB_NBb Sand FID1 A, fF.Bb CLA6~tV7CHEM•116iL1GATAb07C0328lCY1~'s14_D; GA 450 400 Yi0 200700328 BP ~ 1.19 SSB 14314-QA RF FLASH CYLINDER 250 200 X50 Sao Y1 m iD U~p '~ m 50 U obi -° m w. ~ G T o IX m ry m ~ ~ ~ h m T O" N(~7`! f~`INNNNfV to l~iT~Mr1('~P7 ~ ~ U U U U U U U UU UUUUU UUUW(,)U uQ, r° F m ~~'~ ~ C C C C C C C C C C C C S C C C C U U ~ x U ~ C ~ ~ U ~ ~ U ~ C VVVV 0 C C - .L - - - a 0 5 f0 15 X1 25 30 35 mi • • Figure 16: k-Plot for Equilibrium Check (Sample 1.19) Sample 1.19; Cylinder CSB 14314-QA; Depth 8456 ft. MD (-4362 NDSS1, SB_NBb Sand 2.5 2 1.5 n Y 1 0.5 0 -0 5 • nC4 • nC5 • iC5 • C6 • C7 -4 Ollphase-DBR -3 -2 1 0 1 F 35 2 3 File200700328-D • • Client: BP Alaska Well: L-2191 Table 20: C30+ Composition, GOR, °API, by Single-Stage Flash (Sample 1.2) Sample 1.20; Cylinder CSB 14313-QA; Depth 8456 ft. MD (-4362 NDSS-, SB_NBb Sand Field: Prudhoe Bay Unit - WOA Schlumberger Component MW Flashed Gas Flashed Liquid Monophasic Fluid ~g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 1.15 0.44 0.00 0.00 0.02 0.11 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 0.33 0.20 0.00 0.00 0.01 0.05 Methane 16.04 93.71 98.09 0.00 0.00 1.49 24.39 Ethane 30.07 0.29 0.16 0.00 0.00 0.00 0.04 Propane 44.10 0.39 0.15 0.00 0.01 0.01 0.04 I -Butane 58.12 0.31 0.09 0.00 0.01 0.01 0.03 N -Butane 58.12 0.90 0.26 0.01 0.07 0.03 0.12 I -Pentane 72.15 0.56 0.13 0.03 0.12 0.03 0.12 N -Pentane 72.15 0.77 0.18 0.04 0.21 0.06 0.20 C6 84.00 0.80 0.16 0.28 1.16 0.29 0.91 M-C-Pentane 84.16 0.10 0.02 0.07 0.27 0.07 0.21 Benzene 78.11 0.00 0.00 0.00 0.01 0.00 0.01 Cyclohexane 84.16 0.10 0.02 0.07 0.28 0.07 0.22 C7 96.00 0.29 0.05 0.39 1.39 0.39 1.06 M-C-Hexane 98.19 0.06 0.01 0.15 0.51 0.14 0.39 Toluene 92.14 0.16 0.03 0.04 0.14 0.04 0.11 C8 107.00 0.06 0.01 0.63 2.03 0.62 1.53 E-Benzene 106.17 0.00 0.00 0.03 0.10 0.03 0.08 M/P-Xylene 106.17 0.00 0.00 0.07 0.23 0.07 0.17 0-Xylene 106.17 0.00 0.00 0.06 0.19 0.06 0.14 C9 121.00 0.00 0.00 0.78 2.21 0.76 1.66 C10 134.00 0.00 0.00 1.24 3.19 1.22 2.40 C11 147.00 0.00 0.00 1.52 3.56 1.50 2.68 C12 161.00 0.00 0.00 2.07 4.42 2.04 3.32 C13 175.00 0.00 0.00 2.38 4.68 2.34 3.52 C14 190.00 0.00 0.00 3.00 5.43 2.95 4.08 C15 206.00 0.00 0.00 2.86 4.78 2.82 3.59 C16 222.00 2.95 4.57 2.90 3.44 C17 237.00 3.01 4.37 2.96 3.28 C18 251.00 2.98 4.09 2.94 3.07 C19 263.00 2.77 3.63 2.73 2.73 C20 275.00 2.79 3.49 2.75 2.62 C21 291.00 2.90 3.43 2.85 2.58 C22 300.00 2.71 3.11 2.67 2.34 C23 312.00 2.23 2.46 2.20 1.85 C24 324.00 2.03 2.16 2.00 1.62 C25 337.00 2.09 2.13 2.05 1.60 C26 349.00 Z.1 Z 2.09 2.09 1.57 C27 360.00 1.97 1.88 1.94 1.41 C28 372.00 1.96 1.81 1.93 1.36 C29 382.00 1.84 1.66 1.81 1.25 C30 394.00 2.07 1.81 2.04 1.36 C31 404.00 1.61 1.37 1.58 1.03 C32 415.00 1.66 1.38 1.64 1.04 C33 426.00 1.41 1.14 1.39 0.86 C34 437.00 1.37 1.08 1.35 0.81 C35 445.00 1.03 0.80 1.02 0.60 C36+ 850.00 40.76 16.51 40.11 12.40 Total 100.00 100.00 100.00 100.00 100.00 100.00 M W 16.79 344.20 262.80 MOLE RATIO 0.2486 0.7514 Ollphase-DBR 36 File200700328-D • • Client: BP Alaska Well: L-219i Table 21: Calculated Fluid Properties Sample 1.20; Cylinder CSB 14313-QA; Depth 8456 ft. MD (-4362 NDSS), SB_NBb Sand Field: Prudhoe Bay Unit - WOA Schlumberger Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.77 0.14 99.63 98.42 98.06 73.98 C12+ - - 94.59 84.30 93.09 63.34 C20+ - - 72.57 48.32 71.41 36.31 C30+ - - 49.93 24.09 49.13 18.10 C36+ - - 40.76 16.51 40.11 12.40 Molar Mass C7+ 92.73 348.45 348.33 C 12+ - 386.21 386.21 C20+ - 516.93 516.93 C30+ - 713.37 713.37 C36+ - 850.00 850.00 Density C7+ - 0.916 - C 12+ - 0.925 0.925 C20+ - 0.955 0.955 C30+ - 0.991 0.991 C36+ - 1.010 1.010 Fluid at 60°F 0.957 Gas Gravity (Air =1) 0.580 Dry Gross Heat Content (BTU/scf 1,038 Wet Gross Heat Content BTU/scf 1,020 OBM Contamination Level (wt%) - STO Basis - Live Oil Basis Stock Tank Oil Properties at Standard Conditions: Measured Calculated C36+ Properties MW 378.16 344.20 850.00 Density (g/cm3) 0.957 0.892 1.010 Single Stage Flash Data Original STO De-Contaminated GOR (scf/stb) 122 - STO Density Ig/cm3) 0.957 - STO API Gravity 16.4 - OBM Density (g/cm3 0360°F - Ollphase-DBR File 200700328-D • ~• i• Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i Figure 17: Stock Tank Oil Chromatogram (Sample 1.2) Sample 1.20; Cylinder CSB 14313-QA; Depth 8456 ft. MD (-4362 TVDSS~, SB_NBb Sand FIG1 ~ (6:'~?G CtAB+1'dIr,NBA-1101UDAiR!W70032R1LY11317P. D~ PA A00 B00 700 2007000328 BP 1.20 CSB 14313-QA RF FLASH CYLINDER eoo 500 ~ U m 100 U ~~pp ~~ i. m ~ ~. O ~ N 1*1 V U) n O7 m ry N N N N N N (^Y~ Nf"~N'1 m(mr11~T1 u ~ rn UUU ~ n m ~x U U U U U ~U UUU UU WUUW U~ c U U U U U U c c c c c c c c c c c c c c c c c cc c c c o c c - c r c tr - 0 0 5 10 15 t0 25 30 35 mi Figure 18: k-Plot for Equilibrium Check (Sample 1.2) Sample 1.20; Cylinder CSB 14313-QA; Depth 8456 ft. MD (-4362 TVDSS-, SB_NBb Sand 2.5 2 1.5 6 Y 1 O J 0.5 0 -0.5 • C3 • iC4 • nC4 • ~C~S -4 Ollphase-DBR • C6 - • C7 ~ -3 T -2 1 0 1 F 38 File200700326-D • • Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger DETAILED EXPERIMENTAL RESULTS -PVT Ollphase-DBR 39 File 200700328-D Client: BP Alaska Well: L-219i PVT Analysis -10890' MD Field: Prudhoe Bay Unit - WOA Schlumberger Table 22: Constant Composition Expansion at 97.0°F (10890' MD) Sample 1.10; Cylinder CSB 14332-QA; Depth 10890 ft. MD (-4783' NDSS-, SB_OBd Sand • • Pressure (psis) Relative Vol (Vr=VNsat) % liquid (VlNsat) % Liquid IVINtotal) Liquid Density Y Function Ig/cm3) Compressibility 110-6/psia) 1 5016 0.9860 98.6 100.0 4.5 2 4015 0.9900 99.0 100.0 4.3 3 3516 0.9920 99.2 100.0 4.2 4 2515 0.9960 99.6 100.0 4.1 5 2018 0.9980 99.8 100.0 4.0 Pi 1995 0.9980 99.9 100.0 4.0 7 1958 0.9990 99.9 100.0 4.0 8 1724 0.9990 99.9 100.0 4.0 9 1630 1.0000 100.0 100.0 3.9 Pb 1585 1.0000 100.0 100.0 3.9 11 1534 1.0060 5.9 12 1438 1.0180 5.8 13 1356 1.0290 5.8 14 1301 1.0380 5.7 15 1192 1.0590 5.6 16 1109 1.0770 5.6 17 1001 1.1060 5.5 18 881 1.1480 5.4 19 775 1.1960 5.3 20 673 1.2570 5.3 21 567 1.3440 5.2 22 462 1.4710 5.2 23 374 1.6340 5.1 24 234 2.1470 5.0 Ollphase-DBR 40 File 200700328-D • Client: BP Alaska Well: L-219i Constant Composition Expansion 150.0°F Field: Prudhoe Bay Unit - WOA Schlumberger Table 23: Constant Composition Expansion at 150°F (10890' MD- Sample 1.10; Cylinder CSB 14332-QA; Depth 10890 ft. MD ~-4783'. NDSS), SB_OBd Sand • • Pressure (psia- Relative Vol (Vr=V/Vsat) % Liquid (VlNsat) % Liquid (VlNtotal) Liquid Density Y Function (g/cm3) Compressibility (10-6/psia) 1 5015 0.9830 98.3 100.0 5.2 2 4016 0.9880 98.8 100.0 5.2 3 3515 0.9900 99.0 100.0 5.2 4 3016 0.9930 99.4 100.1 5.1 5 2536 0.9960 99.6 100.0 5.1 6 2223 0.9970 99.7 100.0 5.1 7 2018 0.9980 99.8 100.0 5.1 Pi 1995 0.9980 99.8 100.0 5.1 9 1909 0.9990 99.9 100.0 5.1 10 1805 0.9990 99.9 100.0 5.1 11 1713 1.0000 100.0 100.0 5.1 Pb 1683 1.0000 100.0 100.0 5.1 13 1625 1.0060 6.2 14 1529 1.0160 6.2 15 1297 1.0500 6.0 16 1025 1.1120 5.8 17 816 1.1900 5.6 18 621 1.3150 5.4 19 415 1.5790 5.3 20 266 2.0290 5.2 Ollphase-DBR 41 File 200700328-D Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger Constant Composition Expansion 180.0°F Table 24: Constant Composition Expansion at 180°F (10890' MD) Sample 1.10; Cylinder CSB 14332-QA; Depth 10890 ft. MD (-4783' NDSS~, SB_OBd Sand Pressure (psia) Relative Vol IVr=VNsat) °k Liquid IVINsat) % Liquid (VlNtotal) Liquid Density Y Function (g/cm3) Compressibility (10-6/psia) 1 5015 0.9830 98.3 100.0 4.3 2 4534 0.9850 98.5 100.0 4.6 3 4016 0.9880 98.8 99.9 4.9 4 3565 0.9900 99.0 100.0 5.2 5 3079 0.9930 99.3 100.0 5.6 6 2815 0.9940 99.4 100.0 5.8 7 2612 0.9950 99.5 100.0 6.0 8 2500 0.9960 99.6 100.0 6.1 9 2409 0.9970 99.7 100.0 6.1 10 2310 0.9970 99.7 100.0 6.2 11 2206 0.9980 99.8 100.0 6.3 12 2008 0.9990 99.9 100.0 6.5 Pi 1995 0.9990 99.9 100.0 6.5 14 1913 0.9990 99.9 100.0 6.6 Pb 1855 1.0000 100.0 100.0 6.6 16 1815 1.0030 8.2 17 1722 1.0100 8.0 18 1642 1.0170 7.8 19 1531 1.0280 7.6 20 1373 1.0480 7.3 21 1033 1.1200 6.6 22 800 1.2140 6.2 23 517 1.4570 5.7 24 310 1.9460 5.3 Ollphase-DBR 42 File 200700328-D Client BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Figure 19: Constant Composition Expansion at -Relative Volumes (10890' MD) Sample 1.10; Cylinder CSB 14332-OA; Depth 10890 ft. MD (-4783' NDSS~, SB_OBd Sand • 2.4 '~ 2.2 ', i '~~ ', ', 2.0 ~ '~ ~ 1.8 a U ', I > '~ E 1.6 o o I as a .a L ' I ~ 1.4 I i it 1.2 ', ! ~I i ~~ ', 1.0 _ I 0.8 0 1000 2000 3000 4000 5000 6000 Pressure (psia) Ollphase-DBR 43 File 200700328-D • Client: BP Alaska Well: L-219i Reservoir Oil Viscosity at Tres Pressure Viscosity C~ Tres (Psis) IcP- 1 5041 137.1 2 4036 119.0 3 3015 102.8 4 2013 88.6 5 1817 85.2 6 1618 82.3 7 1475 83.4 8 1210 100.4 9 1065 108.4 10 812 126.9 11 484 151.0 STO 14.696 414.7 • 1000 a •~ 100 V _N 10 Field: Prudhoe Bay Unit - WOA Schlumberger Table 25: Reservoir Fluid Viscosity 97°F (10890' MD) Sample 1.10; Cylinder CSB 14332-OA; Depth 10890 ft. MD (-4783' NDSS), SB_OBd Sand Figure 20: Reservoir Fluid Viscosity 97°F (10890' MD) Sample 1.10; Cylinder CSB 14332-QA; Depth 10890 ft. MD (-4783' NDSS-, SB_OBtl Sand 7------- ,---------- --------------~------r------- ----- ------1-------- ------- ----- ------- -------- . _ - _ . - - _ _ Y - . - _ _ ... - - - - _ - _ T . - - _ . - - - . 7 - - . . - _ _ - _., - _ - _ - - 1 _ _ - - -I- _ _ - - ~- _ - - - _ _ - - _ ~ _ - - _ - - - - _ _ ~ _ - - - - - _ _ - 0 1000 2000 3000 4000 5000 Pressure (psis) Ollphase-DBR 44 6000 File 2007328-D • Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger PVT Analysis -10547' MD Table 26: Constant Composition Expansion at 94.5°F (10547' MD) Sample 1.12; Cylinder CSB 14319-QA; Depth 10547 ft. MD (-4769 NDSS~, SB_OBtl Sand Pressure (psis) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % Liquid (VlNtotal- Liquid Density (g/cm3) Y Function Compressibility 110-6/psia) 1 5023 0.9840 98.4 100.0 0.926 4.7 2 4515 0.9860 98.6 100.0 0.923 4.7 3 4014 0.9900 99.0 100.0 0.920 4.7 4 3515 0.9910 99.1 100.0 0.919 4.7 5 3016 0.9940 99.4 100.0 0.917 4.7 6 2814 0.9940 99.4 100.0 0.916 4.7 7 2612 0.9960 99.6 100.0 0.915 4.7 8 2413 0.9960 99.6 100.0 0.914 4.7 9 2215 0.9970 99.7 100.0 0.913 4.7 10 2013 0.9980 99.8 100.0 0.913 4.7 11 1915 0.9990 99.9 100.0 0.912 4.7 12 1913 0.9990 99.9 100.0 0.912 4.7 13 1815 0.9990 99.9 100.0 0.912 4.7 14 1715 1.0000 100.0 100.0 0.911 4.7 Pb 1628 1.0000 100.0 100.0 0.911 4.6 16 1616 1.0010 5.8 17 1516 1.0130 5.7 18 1424 1.0260 5.5 19 1334 1.0410 5.4 20 1256 1.0560 5.3 21 1137 1.0850 5.1 22 1040 1.1140 5.0 23 937 1.1530 4.8 24 739 1.2670 4.5 25 534 1.4840 4.2 26 333 1.9840 4.0 Ollphase-DBR L1; File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Figure 21: Constant Composition Expansion at 94.5°F -Relative Volume (10547' MD) - - 8 OBd San Sample 1.12, Cylinder CSB 14319 QA, Depth 10547 ft. MD (4769 NDSS-, S _ d 2.Z I 2.0 '~ i ~, i I ~~ 1.8 ~ II I~ .. 1.6 '~ ~ ', '~, _ 1.4 • ~ i I'i, II, ~' ~~ 1.2 1.0 ~~ 08 • 0 1000 2000 3000 4000 5000 6000 Pressure (psia) Ollphase-DBR 46 File 200700328-D Client~ BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i Table 27: Reservoir Fluid Viscosity 94.5°F (10547' MD) Sample 1.12; Cylinder CSB 14319-OA; Depth 10547 ft. MD (-4769 NDSS-, SB_OBd Sand Pressure Viscosity @ Tres (Psia) IcPI 1 5019 77.0 2 4017 66.1 3 3022 57.8 4 2021 49.7 5 1725 47.7 6 1620 46.8 7 1435 45.5 8 1377 48.1 9 1326 49.0 10 1297 49.7 11 1216 51.9 12 1172 52.6 13 1089 54.0 14 969 55.9 15 860 59.5 16 683 75.5 STO 14.7 196.9 • • Ollphase-DBR 47 File 200700326-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • 1000 d •y 100 0 a 10 Figure 22: Reservoir Fluid Viscosity 94.5°F (10547' MD) Sample 1.12; Cylinder CSB 14319-QA; Depth 10547 ft. MD (-4769 NDSS-, SB_OBd Sand --------------- --------- ---------~-------------------Y---------~- ------ -------- ------------r-------- -- - --~--------- -- ---- I~ ---------',----------,---------I---------r-------- ~I 1000 2000 3000 4000 5000 Pressure (psis) C Ollphase-DBR 48 6000 File 200700328-D • Client: BP Alaska Well: L-219i PVT Analysis -10003' MD Table 28: Constant Composition Expansion at 93.0°F (10003' MD) Sample 1.13; Cylinder CSB 14333-QA; Depth 10003 ft. MD (-4747 NDSS-, SB_OBd Sand • • Pressure (psia) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % Liquid (VlNtotal) Liquid Density (g/cm3) Y Function Compressibility (106/psia) 1 5015 0.9840 98.4 100.0 0.936 4.2 2 4026 0.9870 98.7 100.0 0.933 4.4 3 3514 0.9900 99.0 100.0 0.930 4.7 4 3014 0.9930 99.3 100.0 0.927 4.9 5 2540 0.9950 99.5 100.0 0.925 5.1 6 2319 0.9960 99.6 100.0 0.924 5.2 7 2127 0.9970 99.7 100.0 0.923 5.3 8 2015 0.9970 99.7 100.0 0.923 5.4 9 1913 0.9980 99.8 100.0 0.923 5.4 10 1813 0.9980 99.8 100.0 0.923 5.4 Pi 1746 0.9990 99.9 100.0 0.922 5.5 12 1699 0.9990 99.9 100.0 0.922 5.5 13 1592 0.9990 99.9 100.0 0.922 5.5 14 1498 0.9990 100.0 100.1 0.922 5.6 Pb 1475 1.0000 100.0 100.0 0.921 5.6 16 1419 1.0020 16.8 17 1317 1.0070 16.1 18 1220 1.0140 15.4 19 1069 1.0270 14.2 20 1015 1.0330 13.7 21 885 1.0530 12.6 22 769 1.0780 11.7 23 619 1.1310 10.5 24 432 1.2650 9.1 25 240 1.6860 7.5 Field: Prudhoe Bay Unit - WOA Schlumberger * Poor stabilization experienced due to severe viscosity. Qllphase-DBR 49 File 200700328-D • Client BP Alaska Well: L-219i Table 29: Constant Composition Expansion at 150°F (10003' MD- Sample 1.13; Cylinder CSB 14333-OA; Depth 10003 ft. MD (-4747 TVDSS), SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Pressure (psis) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % liquid (VlNtotal) Liquid Density Y Function (g/cm3) Compressibility (10~/psia) 1 5015 0.9810 98.1 100.0 5.6 2 4015 0.9860 98.6 100.0 5.8 3 3012 0.9920 99.3 100.1 5.9 4 2520 0.9950 99.5 100.0 6.0 5 2046 0.9980 99.8 100.0 6.1 6 1835 0.9990 99.9 100.0 6.1 7 1735 1.0000 100.0 100.0 6.2 Pb 1685 1.0060 100.7 100.1 5.0 9 1635 1.0120 4.9 10 1490 1.0350 4.8 11 1388 1.0540 4.7 12 1191 1.1020 4.5 13 991 1.1760 4.3 14 774 1.3060 4.1 15 581 1.5160 3.8 16 383 1.9680 3.6 Ollphase-DBR 50 File 2700328-D • • Client: BP Alaska Well: L-2191 Table 30: Constant Composition Expansion at 180°F (10003' MD) Sample 1.13; Cylinder CSB 14333-OA; Depth 10003 ft. MD (-4747 NDSS-, SB_OBd Sand Field: Prudhoe Bay Unit - WOA Schlumberger Pressure (psia) Relative Vol (Vr=VNsat) % Liquid (VI/Vsat) % Liquid (VlNtotal) Liquid Density Y Function Ig/cm3) Compressibility (10-6/psia) 1 5015 0.9820 98.2 100.0 5.8 2 4015 0.9880 98.8 100.0 5.8 3 3514 0.9910 99.1 100.0 5.9 4 3018 0.9940 99.4 100.0 5.9 5 2526 0.9960 99.6 100.0 5.9 6 2311 0.9980 99.8 100.0 5.9 7 2220 0.9980 99.9 100.1 5.9 8 2112 0.9990 99.9 100.0 5.9 9 2005 1.0000 100.0 100.0 5.9 Pb 1945 1.0000 100.0 100.0 5.9 11 1910 1.0030 6.1 12 1814 1.0120 5.9 13 1722 1.0220 5.8 14 1616 1.0360 5.6 15 1528 1.0500 5.5 16 1332 1.0880 5.2 17 1030 1.1820 4.9 18 827 1.2920 4.6 19 630 1.4770 4.4 20 430 1.8550 4.1 Ollphase-DBR 51 File 200700328-D Client: BP Alaska Well: L-219i Figure 23: Constant Composition Expansion -Relative Volumes X10003' MD) Sample 1.13; Cylinder CSB 14333-OA; Depth 10003 ft. MD (-4747 NDSS-, SB_OBd Sand ~~ ~J Field: Prudhoe Bay Unit - WOA Schlumberger z.z z.o 1.8 a 1.6 d E 0 0 .~ 1.4 d 1.2 1.0 ~~ ~~ ~~~ I I 'I ', !, ~~ ~ I! II '' i i I it it ~ 08 • 0 1000 2000 3000 4000 5000 6000 Pressure~psia) Ollphase-DBR 52 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i i Table 31: Reservoir Fluid Viscosity 97°F (;10003' MD) Sample 1.13; Cylinder CSB 14333-QA; Depth 10003 ft. MD (-4747 NDSS-, SB_OBtl Sand Pressure Viscosity @ Tres (psia) IcP) 1 5015 63.0 2 4013 55.9 3 3025 48.3 4 2022 41.2 5 1717 39.2 6 1616 38.7 7 1515 38.3 8 1420 37.7 9 1332 38.3 10 1016 42.5 11 792 47.6 12 598 54.5 STO 15 160.3 • Ollphase-DBR 53 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Figure 24: Reservoir Fluid Viscosity 93°F (10003' MD) Sample 1.13; Cylinder CSB 14333-QA; Depth 10003 ft. MD (-4747 NDSS-, SB_OBtl Sand 1000 O. V •y 100 O y_ • • 10 0 4000 5000 6000 -------------------- it _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ ' _ _ _ _ _ J _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - i i i --- - r-- I i i 1000 2000 3000 Pressure~psia) Ollphase-DBR 54 File 200700328-D .7 Client BP Alaska Well: L-219i PVT Analysis - 9673' MD Field: Prudhoe Bay Unit - WOA Schlumberger Table 32: Constant Composition Expansion at 91.0°F X9673' MD) Sample 1.15; Cylinder CSB 14187-QA; Depth 9673 ft. MD (-4675 NDSS~, SB_OBc Sand J Pressure (Psia) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % Liquid (VlNtotal) Liquid Density (g/cm31 Y Function Compressibility (10"6/psia) 1 8017 0.9690 96.9 100.0 0.933 3.6 2 6022 0.9770 97.7 100.0 0.926 4.3 3 4049 0.9860 98.6 100.0 0.918 5.2 4 3019 0.9920 99.2 100.0 0.912 5.7 5 2516 0.9950 99.5 100.0 0.910 6.0 6 2308 0.9960 99.6 100.0 0.908 6.1 7 2010 0.9980 99.8 100.0 0.907 6.3 Pi 1983 0.9980 99.8 100.0 0.907 6.3 9 1863 0.9980 99.8 100.0 0.906 6.3 10 1741 0.9990 99.9 100.0 0.905 6.4 Pb 1636 1.0000 100.0 100.0 0.905 6.5 12 1633 1.0000 4.4 13 1595 1.0060 4.3 14 1502 1.0210 4.3 15 1406 1.0380 4.3 16 1215 1.0830 4.2 17 1025 1.1470 4.1 18 815 1.2550 4.0 19 620 1.4260 3.9 20 491 1.6160 3.8 Ollphase-DBR File200700326-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i Figure 25: Constant Composition Expansion at 91.0°F -Relative Volume (9673' MD) Sample 1.15; Cylinder CSB 14187-QA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Sand • • 1.7 1.6 1.5 1.4 a d ~, 1.3 as E 0 0 d 1.2 a 1.0 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Pressure (psis) 0.9 08 Ollphase-DBR 56 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Reservoir Oil Viscosity at Tres Table 33: Reservoir Fluid Viscosity 91°F (9673' MD) Sample 1.15; Cylinder CSB 14187-QA; Depth 9673 ft. MD (-4675 NDSS~, SB_OBc Sand Pressure Viscosity @ Tres IPSIa) IcP1 1 8028 29.8 2 6040 24.5 3 4001 20.1 4 3034 18.2 5 2035 16.4 6 1826 16.0 7 1719 16.7 8 1458 20.0 9 1351 20.5 10 1124 22.5 11 1024 22.9 12 901 25.6 13 772 28.1 14 585 30.9 STO 15 80.2 • • Ollphase-DBR bfl File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Figure 26: Reservoir Fluid Viscosity 91°F (9673' MD) Sample 1.15; Cylinder CSB 14187-QA; Depth 9673 ft. MD (-4675 NDSS-, SB_OBc Santl 100 a .y O V N • 10 • 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Pressurelpsia) Ollphase-DBR 58 File 200700328-D • Client: BP Alaska Well: L-219i PVT Analysis - 8456' MD Table 34: Constant Composition Expansion at 150.0°F (8456' MD) Sample 1.19; Cylinder CSB 14314-QA; Depth 8456 ft. MD (-4362 NDSS-, SB_NBb Sand J • Pressure (psia) Relative Vol (Vr=VNsat) ~° Liquid (VlNsat) % Liquid (VI/Vtotal) Liquid Density Y Function (13/cm3) Compressibility (106/psia) 1 8015 0.9640 96.4 100.0 5.2 2 6015 0.9740 97.4 100.0 5.8 3 4015 0.9870 98.7 100.0 6.5 4 3015 0.9930 99.3 100.0 6.9 5 2022 1.0000 100.0 100.0 7.3 Pb 1998 1.0000 100.0 100.0 7.3 7 1916 1.0090 4.8 8 1879 1.0130 4.8 9 1808 1.0220 4.7 10 1494 1.0730 4.6 11 1014 1.2180 4.4 12 518 1.6700 4.3 13 356 2.0990 4.2 Field: Prudhoe Bay Unit - WOA Schlumberger * Poor PV stabilization experienced due to severe viscosity. Reported data are approximated based on visual separation. Ollphase-DBR 59 File 200700328-D • • • Client BP Alaska Well: L-219i Table 35: Constant Composition Expansion at 85°F (8456' MD) Sample 1.19; Cylinder CSB 14314-QA; Depth 8456 ft. MD (-4362 NDSS-, SB_NBb Sand Pressure (psis) Relative Vol (Vr=VNsat) % Liquid (VlNsat) % Liquid (VlNtotal) Liquid Density Ig/cm3) Y Function Compressibility (10-6/psia) 1 10043 0.9620 96.2 100.0 - 2.3 2 8016 0.9680 96.8 100.0 - 3.0 3 6024 0.9750 97.5 100.0 0.938 4.0 4 4050 0.9830 98.3 100.0 0.932 5.2 5 3069 0.9880 98.8 100.0 - 5.9 6 2022 0.9950 99.5 100.0 0.926 6.8 7 1912 0.9960 99.6 100.0 - 6.9 Pi 1864 0.9960 99.7 100.0 - 7.0 9 1812 0.9970 99.7 100.0 - 7.0 10 1711 0.9980 99.8 100.0 - 7.1 11 1610 0.9980 99.9 100.0 - 7.2 12 1508 0.9990 99.9 100.0 - 7.3 Pb 1370 1.0000 100.0 100.0 - 7.4 14 1359 1.0020 100.0 99.8 4.7 15 1309 1.0100 99.9 98.9 4.7 16 1208 1.0290 99.7 96.9 4.6 17 1107 1.0520 99.5 94.5 4.6 18 1005 1.0800 99.2 91.9 4.6 19 905 1.1140 99.0 88.9 4.5 20 804 1.1580 98.9 85.4 4.5 21 704 1.2140 98.7 81.3 4.4 22 604 1.2890 98.5 76.4 4.4 23 502 1.3980 98.3 70.3 4.3 24 401 1.5610 98.1 62.8 4.3 25 301 1.8300 97.9 53.5 4.3 26 200 2.3780 97.7 41.1 4.3 Field: Prudhoe Bay Unit - WOA Schlumberger ** Density data based on independent HPHT Paar densitometer analyses. Ollphase-DBR File 200700328-D Clients BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Figure 27. Constant Composition Expansion -Relative Volumes (8456 MD) Sample 1.19; Cylinder CSB 14314-QA; Depth 8456 ft. MD (-4362 NDSS~, SB_NBb Sand • 2.6 I 2.4 I 2.2 ' I i 2.0 a d U ~ 1.8 ~ ', 0 ~ ~ I ~ 1.6 ~, 1.4 ', 1.Z i ', I 1.0 0.8 0 2000 4000 6000 8000 10000 Pressure (psis) • Ollphase-DBR 61 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Viscosities (8456' MDJ • • Table 36: Reservoir Fluid Viscosities (8456' MD- Sample 1.19; Cylinder CSB 14314-QA; Depth 8456 ft. MD (-4362 NDSS-, SB_NBb Santl Pressure Viscosity Pressure Viscosity Pressure Viscosity (psia) Ti 185°F, cP) (psial @ 100°F IcP) (psis) @ 750°F IcP) 5025 200.3 8024.7 198.0 8016.7 47.9 4025 169.1 7034.7 169.5 7015.7 42.0 3028 141.5 6031.7 146.2 6022.7 36.9 2525 130.4 5019.7 125.1 5017.7 32.4 2019 117.7 4032.7 103.9 4024.7 27.8 1725 110.7 1615 108.2 1517 106.6 1422 105.8 1347 108.3 1288 118.5 1114 131.9 1077 144.6 884 155.6 684 164.0 14.7 546.8 Ollphase-DBR 62 File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • Figure 28: Reservoir Fluid Viscosities (8456' MD) Sample 1.19; Cylinder CSB 14314-QA; Depth 8456 ft. MD (-4362 NDSS-, SB_NBb Sand -o--85°F -o- 100°F --~ 150°F 1000 d •y 100 0 VJ 10 • -- ---- ------------~---- ----J--------- ---- -- -- --- -- -- -- -- i', ~. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 Pressure~psia) Ollphase-DBR 63 File 200700328-D C~ • Client BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger DETAILED EXPERIMENTAL RESULTS -WATER Ollphase-DBR 64 file 200700328-D • • • Client: BP Alaska Well: L-219i Table 37: Water Analysis Data Field: Prudhoe Bay Unit - WOA Schlumberger Sample 1.01 1.02 1.04 1.08 1.21 Chamber MPSR 2868 MPSR 1400 MPSR 1295 MPSR 1290 WBM Depth (ft. MD) 12108 12108 11776 11191 - Sand SB_OBd SB_OBd SB_OBd SB_OBd - Anions Fluoride mg/Kg ntl nd nd nd ntl Chloride mg/Kg 9860.04 9917.31 11019.21 9473.81 586.94 Nitrite mg/Kg nd nd nd nd nd Bromide mg/Kg 41.70 42.32 45.67 39.01 2.82 Nitrate mg/Kg nd nd nd 10.97 nd Phosphate mg/Kg nd nd nd 13.04 nd Sulfate mg/Kg 30.39 28.49 22.23 28.95 199.27 Carbonate mg/Kg 45.87 28.36 52.40 39.20 8.75 Bicarbonate mg/Kg 5866.57 6159.18 6254.84 5496.95 1900.96 Cations Lithium mg/Kg ntl nd nd nd nd Sodium mg/Kg 9081.10 9317.92 10925.74 9408.80 1380.10 Ammonium mg/Kg nd nd nd nd nd Potassium mg/Kg 62.69 63.56 84.32 91.84 548.54 Magnesium mg/Kg 93.85 93.31 129.21 102.53 27.10 Calcium mg/Kg 78.70 100.24 132.24 120.54 155.19 AI mg/Kg 0.11 0.12 0.03 0.02 44.49 Properties pH 7.92 7.69 7.95 7.88 7.69 Sa I i n ity 17813 17916 19907 17115 1060 Resistivity Ohm-cm 33.45 33.33 29.41 33.56 205.76 Spec. Grav. g/g 1.015 1.015 1.017 1.016 1.000 TDS mg/L 21979 22559 25151 23649 12301 Elements B mg/Kg 4.48 4.58 4.94 6.17 0.73 Ba mg/Kg 27.45 28.89 28.45 19.99 3.65 Cu mg/Kg 0.02 0.16 0.05 0.04 0.03 Fe mg/Kg 0.21 0.19 0.08 0.03 20.16 Mn mg/Kg 0.14 0.07 0.27 0.13 0.35 P mg/Kg 0.14 0.21 0.22 4.84 1.14 Pb mg/Kg nd 0.01 nd 0.01 0.01 S mg/Kg 16.47 15.85 9.93 13.46 136.16 Si mg/Kg 9.06 12.77 12.14 11.63 108.64 Sr mg/Kg 13.26 13.39 14.66 13.02 2.22 Zn mg/Kg 4.36 4.04 0.73 0.93 1.21 Organic Acids Glycolic mg/Kg 14.30 18.30 8.01 11.66 58.81 Formic mg/Kg 7.00 6.96 4.82 5.47 21.92 Acetic mg/Kg 11.39 11.27 10.74 12.43 210.29 Propionic mg/Kg 1.30 1.28 3.97 4.70 245.24 Butyric mg/Kg nd ntl ntl ntl nd Ollphase-DBR File 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • • • Appendix A: Nomenclature and Definitions API Gravity American Petroleum Institute gravity Bg Gas formation volume factor Bo Oil formation volume factor CCE Constant composition Expansion DV Differential Vaporization GLR Gas Liquid Ratio GOR Gas Oil Ratio LO Live Oil n Number of moles OBM Oil Based Mud P Absolute pressure Pb Bubble point pressure PV Pressure-Volume Method Pi Initial Reservoir Pressure R Universal gas constant Rs Solution gas oil ratio T Temperature V Volume Vr Relative volume STL Stock Tank Liquid STO Stock Tank Oil %, w/w Weight Percent Z Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid. Wet Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction of water saturated gas at a standard temperature and pressure in which all water formed appears as liquid. Molar masses, densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems" by M.B. Standing Compressibility inconstant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation fGas deviation factor, Z=1) The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. • A positive index indicates scaling tendencies. • A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. Ollphase-DBR 66 File 200700328-D Client: BP Alaska Well: L-219i Field: Prudhoe Bay Unit - WOA Schlumberger • Appendix 6: Molecular Weights and Densities Used Components MW Density 19/cc) C02 44.01 0.827 H2S 34.08 0.993 N2 28.013 0.808 C1 16.043 0.300 C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 N-C4 58.124 0.586 I-C5 72.151 0.625 N-C5 72.151 0.631 C6 84 0.660 MCYC-C5 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0.781 C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 C8 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 • 0-XYLENE C9 106.17 121 0.884 0.768 C 10 134 0.782 C 11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 C15 206 0.836 C 16 222 0.843 C 17 237 0.851 C 18 251 0.856 C19 263 0.861 C20 275 0.866 C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0.885 C25 337 0.888 C26 349 0.892 C27 360 0.896 C28 372 0.899 C29 382 0.902 • Ollphase-DBR 67 File 200700328-D Client BP Alaska Field: Prudhoe Bay Unit - WOA Schlamberger Well: L-219i • Appendix C: EQUIPMENT Fluid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomside of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies. A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer. This unit in conjunction with GC analysis (see below) provides the full fluid compositional analysis, GOR, density at sampling P&T corrected to standard conditions. The JEFRI gasometer consists of a motor- driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L. The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 psia) and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography (GC-. • Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FID-. In this system, separation of individual components is carried out in a 30m long, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range, the components eluted are from C, to C36 along with naphthenes and aromatics components. Based on the physical properties, these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas (helium) through the column. With prior knowledge of the amount of "retention" for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching "retention" times. The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns. The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas. The molecular sieve is used to achieve separation of the light gaseous components (nitrogen, oxygen, and methane) while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis. This column is capable of achieving separation of components up to C,Z„ along with the associated naphthenes and aromatics that are lumped into the Cs+ fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector (TCD) while the C5+ components are analyzed for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns, and hence, allowing for the correct separation and analysis of the injected gas. Fluid Volumetric (PVT) and Viscosity Equipment • Ollphase-DBR 68 File200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-2191 • The preliminary saturation pressure, constant composition expansion (CCE-, differential vaporization (DV-, multi-stage separation tests (MSST) are measured using apressure-volume-temperature (PVT) apparatus. The PVT apparatus consists of a variable volume, visual JEFRI PVT cell. The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm. An especially designed floating piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury-free operation. The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc. The magnetically coupled impeller mixer, mounted on the bottom end cap of the PVT cell, allow quick equilibration of the hydrocarbon fluid. The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. A variable volume JEFRI displacement pump controls the volume, and hence, the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell is mounted on a special bracket, which can be rotated 360°. The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum resistance thermal detector (RTD) and displayed on a digital indicator with an accuracy of 0.2°F. The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to ± 0.1 % of full scale. The temperature and pressure ratings of this PVT system are 15,000 psi (103 MPa) and 360°F (182°C-. The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with ahigh-resolution video camera that minimizes parallax in readings and uses ahigh-resolution encoder producing both linear and volumetric readings. The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test. The floating piston is designed in the shape of a truncated cone with gradually tapered sides, which allows • measurement of extremely small volumes of liquid (0.005 cc) corresponding to roughly 0.01 % of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer, which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston. Viscosity is measured by the motion of the piston, which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe. The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig. The accuracy is ±1.5% of full scale for each individual piston range. The total volume of fluid sample required for viscosity measurement is 5 cc. A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature uniformly throughout the system. • Ollphase-DBR 89 File200700328-D Client BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i • The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation (OHSP) due to changes in the temperature, pressure and/or composition. These fiber optic probes are mounted across the windows of the visual cell. The principle behind the measurement is based on the transmittance of a laser light in the near infra red (NIR) wavelength through the test fluid undergoing temperature, pressure or the fluid composition changes. In this system, a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation, isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies. The process variables (i.e., temperature, pressure, solvent volume, time and transmitted light power level) are recorded and displayed from the detector. The fiber optic light transmittance system referred to here that detects the conditions of OHSP is termed as the light scattering system (LSS-. High pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions. The filter manifold used is rated for 10,000 psia. The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. Ollphase-DBR 70 File 200700328-D Client BP Alaska Field: Prudhoe Bay Unit - WOA schlumberger Well: L-219i • Appendix D: PROCEDURE Fluids Preparation and Validation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio (GORE. The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid. The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids (gas and liquid) are then subjected to compositional analysis using gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOA values. In addition, asub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently, a quick P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The CCE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps. At each pressure step, the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium. Total fluid volume (with visual observation of a single or two phase condition in the cell) is measured at each pressure stage, and subsequently, apressure-volume (P-V) plot is created identifying the phase state at each P-V condition. The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to compute live oil compressibility above the bubblepoint pressure and relative oil volumes over the entire pressure range. • Differential Vaporization Procedure Subsequent to the completion of the CCE experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A differential vaporization (DV) experiment is then conducted by incrementally reducing the pressure in the PVT cell indiscrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a DV test is described below: The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the DV test. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the DV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure see Fluid Analysis Equipment Section) The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. Multi-Stage Separation Test Ollphase-DBR 71 File 200700328-D Client BP Alaska Field: Prudhoe Bay Unit - WOA Schlumberger Well: L-219i Subsequent to the completion of the DV experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A multi-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a separation test is described below: The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the separation test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section- The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity, a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. • A portion of the live reservoir fluid used in the DV test is then transferred into ahigh-pressure high-temperature electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer, flashing of oil takes place, and hence, the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps. At each pressure point, the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration. The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock-Tank Oil (STO) Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. Asphaltene, Wax and Sulfur Content Measurements • Ollphase-DBR 12 file 200700328-D Client: BP Alaska Field: Prudhoe Bay Unit - WOA schlumberger Well: L-219i Asphaltene content of stock-tank oil samples is conducted using the IP-143 jFrench Institute of Petroleum) procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil. Wax content of the STO is measured using UOP (Universal Oil Product- 46-64 procedure. The sulfur content of the STO is measured using ASTM D 2494 procedure.. All other STO analysis were measured according to industrial standards. SAR(P~A Analysis A spinning band distillation was carried out on the original sample to establish two fractions. The initial boiling paint to 300°C fraction was then analysed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes-. This method dissolves the fraction in an equal weight of toluene, then 40 volumes of pentane were added to precipitate the insoluble portion of the sample. The precipitate was filtered, dried and weighed. The solvent was removed from the soluble portion of the sample, which was referred to as the maltenes. The maltenes were then redissolved in pentane and were chromatographically separated into saturates, aromatics and resins (polars) fraction by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents were then removed from each fraction and the amount of material weighed. The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High-Temperature High Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. • Ollphase-DBR 73 File 200700328-D