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211-006
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-223 PRUDHOE BAY UN POL W-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2024 W-223 50-029-23440-00-00 211-006-0 G SPT 5074 2110060 1500 1733 1742 1735 1735 84 93 93 94 OTHER P Guy Cook 5/9/2024 Performing test due to possible damage or obstruction in the tubing. MITIA to verify tubing/casing integrity. Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 POL W-223 Inspection Date: Tubing OA Packer Depth 67 2415 2356 2338IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC240508183346 BBL Pumped:3 BBL Returned:3 Friday, June 14, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 possible damage or obstruction in the tubing James B. Regg Digitally signed by James B. Regg Date: 2024.06.14 14:43:57 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Injector W-223 (PTD #2110060) Tubing restriction / Anomaly in recent caliper survey Date:Tuesday, May 7, 2024 12:28:58 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, May 7, 2024 12:23 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Injector W-223 (PTD #2110060) Tubing restriction / Anomaly in recent caliper survey Mr. Wallace, WAG Injector W-223 (PTD #2110060) caliper survey was run on 05/02/24 while slickline was attempting to remove a tubing plug and unable to pull out with the plug body. Possible buckled or otherwise deformed tubing was identified around ~6100’. At this time, there are no signs of annular pressure communication and the well is not being made under evaluation. However, I wanted to make you aware that I am planning on performing AOGCC MIT-IA later this week during the next tranche of monthly testing to verify tubing / casing integrity. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, January 20, 2020 11:45 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPadDFTN2@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com>; Youngmun, Alex <younak@BP.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector W-223 (PTD #2110060) needs AOGCC MIT-IA All, W-223 (PTD #2110060) is a mechanically sound WAG injector that was made Not Operable on 10/13/19 for lapsing on its 4-year AOGCC MIT-IA. Operations is ready to put the well on injection. After the well is online and thermally stable, an AOGCC witnessed MIT-IA will be performed. The well is now classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, October 13, 2019 8:00 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPadDFTN2@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Youngmun, Alex <younak@BP.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: NOT OPERABLE: Injector W-223 (PTD #2110060) due for a 4-year AOGCC MIT-IA All, Injector W-223 (PTD # 2110060) was due for its AOGCC 4-year MIT-IA in August. Due to the GC2 TAR, the well has not been online and was being tracked with the monthly compliance report. It has now been determined the well will not be put on injection in the near future. The well is now classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, March 4, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-223 PRUDHOE BAY UN POL W-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/04/2024 W-223 50-029-23440-00-00 211-006-0 G SPT 5074 2110060 1500 2933 2929 2931 2940 31 36 37 40 4YRTST P Kam StJohn 1/18/2024 AOGCC 4 Year 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 POL W-223 Inspection Date: Tubing OA Packer Depth 5 2267 2200 2185IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240119130613 BBL Pumped:3.9 BBL Returned:3 Monday, March 4, 2024 Page 1 of 1 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 W-223 211006 500292344000 7 9/23/2023 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, February 6, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. W-223 PRUDHOE BAY UN POL W-223 Ste: Inspector Reviewed By: P.I. SuprvSUe_ Comm Well Name PRUDHOE BAY UN POL W-223 API Well Number 50-029-23440-00-00 Inspector Name: Matt Herrera Permit Number: 211-006-0 Inspection Date: 1/27/2020. IDSA Num: mi[MFH2O0128075241 Rel Insp Num: Thursday, February 6, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-223 ITypelnj I G TVD 5074 -Tubing 2959 2565 - 2864 2870 - PTD 2110060 TYPe Test I SPT Test psi 1500 — IA 42 2000 _I 1965 - 1918 L BBL Pumped: 3.6 BBL Returned: 1.8 ' OA 34 34 35 36 Interval 4YRTST P/F P Notes: L4 Pressure tested to 2000 PSI Per Ops BBL's Returns reflects IA bled back to within 200 PSI of original pretest pressure Thursday, February 6, 2020 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, January 20, 2020 11:45 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad OFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W, AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr, AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Nottingham, Derek; Stechauner, Bernhard; Youngmun, Alex Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector W-223 (PTD #2110060) needs AOGCC MIT -IA All, W-223 (PTD #2110060) is a mechanically sound WAG injector that was made Not Operable on 10/13/19 for lapsing on its 4 -year AOGCC MIT -IA. Operations is ready to put the well on injection. After the well is online and thermally stable, an AOGCC witnessed MIT -IA will be performed. The well is now classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-81 10 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sunday, October 13, 2019 5:00 AM To:'chris. a@alaska.gov' <chris.waIlace @alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facilit <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2FieldPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC2 bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp. >; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPadDFTN2@bp.co AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeliPadLV@bp.com>; AK, OPSad MN <AKOPSWeIIPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWeliPadRJ@bp.com>; AK, OPS WELL PAD S <A WELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWeliPadSW@bp.com>; AK, OPS WELL PAD W <AKOPLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAre @br com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt En KRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Nottingham, Derek <Derek.Not ' ham@bp.com>; Youngmun, Alex <younak@BP.com> Cc:'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completl Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp. >; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe .cam>; Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Sunday, October 13, 2019 8:00 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW, AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Nottingham, Derek, Youngmun, Alex Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector W-223 (PTD #2110060) due for a 4 -year AOGCC MIT -IA All, Injector W-223 (PTD # 2110060) was due for its AOGCC 4 -year MIT -IA in August. Due to the GC2 TAR, the well has not been online and was being tracked with the monthly compliance report. It has now been determined the well will not be put on injection in the near future. The well is now classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Sunday, September 1, 2019 8:08 AM To: Wallace, Chris D (CED) Cc: AK, GWO Projects Well Integrity, AK, GWO Well Integrity Well Information Subject: GC2 Injectors overdue for AOGCC MIT -IA Mr. Wallace,a cD Injectors W-207 (PTD # 2030490), W-221 (PTD #2110290), W-220 (PTD #210260), W-223 (PTD 60 , R-06 (PTD #1981270), and W-219 (PTD #2101050) were due for 4 year AOGCC MIT-IAs at the end of August 2019. Due to the GC2 TAR the wells have been shut in and were not tested before the end of the month. GC2 is expected to be back up to full rate by the end of next week so BP is requesting to leave the above mentioned wells in Operable status and track them on the monthly compliance report until they are brought back online and pressure tested. Please advise if this is not acceptable, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg j� DATE: Wednesday,August 12,2015 P.I.Supervisor Ns e,1 t)(13/1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC W-223 FROM: Bob Noble PRUDHOE BAY UN POL W-223 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JBP— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-223 API Well Number 50-029-23440-00-00 Inspector Name: Bob Noble Permit Number: 211-006-0 Inspection Date: 8/10/2015 Insp Num: mitRCN150811120942 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W 223 Type Inj w TVD 5074 Tubing; 1151 - 1157 . 1155 ua9 PTD 2110060 - Type Test SPT Test psi 1500 ' IA 468 2500 - 2469 - 2461 - - i -- Interval 4YRTST P/F P < OA 87 218 219 , 216 Notes: SCANNED z 2 j Wednesday,August 12,2015 Page 1 of 1 \. a 4 n 'IA 4\ tz o O ai W a '! 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N U 3 N , 0 A w O. y IY co O c E > 0 p_ m O Q N € € E z �, C Z V O . LL N co 'NO p A O N �' NNr 0 ate+ w 01• Q - 4. N Z N d o o w OLL a) 0 Od caIn 0 - o I c j m Z W J U 0 0 V ce a ? o E a a 2 I o 3 .o - >. w Ce w W0 ,77 ? 0 a` 0 v v 777 7 . Op 0 Tran,._ BPXAL D aVP _ DATA 0C.� TRANSMITTAL MITTAL Enclosed are th materials ��u �-0 Enclosed listed below. (BPXA FIE LOGD JUL �, 2013 If ou have an , DATA) uesti ons, 'lease contact D u. AOGCC 3 04,,z 7 Delive Dortch at the PDC at 564-4 Contents 9 1 CD-ROM 73 Containing Field Log Data& Electronic Lo W-223 9 Prints for the following wells: s Please Sign d Return one copy o this transmittal. Thank You, Doug Dortch Pe trotechn' is al Data Center Attn: State of Alaska - Attn: Christine S AOGCC hartz 333 W. 7th Aveer , Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E.Benson Blvd.PO Box 196612 Anchorage,AK 99519-6612 McMains, Stephen E (DOA) From: McMains, Stephen E (DOA) Sent: Wednesday,June 12, 2013 11:36 AM To: 'lastufjn@BP.com' Subject: Data 1 \i$5 111 a(� ^ o�p(p r p � W -" 1 In the permit to drill 211-006, PBU W-223 well, BP said the following logs would be run and AOGCC hasn't received them yet. I am requesting these logs from you if they were run. The following logs are missing from our records: MWD GR, RES, NEU, AZI DENS both prints and digital data. Please submit within 15 days the requested data. The AOGCC's reporting requirements are found in statute AS 31.05.030 and regulations 20 AAC 25.070 and 20 AAC 25.071. Steve McMains AOGCC, Ph: 793-1233 email @ steve.mcmains@alaska.gov Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L[Terrie.Hubble@bp.com] Sent: Monday, September 19, 2011 11:23 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU W-223/PTD#211-006 Hi Art, Please reference the following well: Well Name: PBU W-223 Permit #: 211-006 API #: 50-029-23440-00-00 Top Perf MD: 9178' Bottom Perf MD: 9426' This well began Injection on September 7, 2011 Method of Operations is: Produced Water Injection There is no test data for injection wells. 1 MEMORANDUM State of Alaska Ili, Alaska Oil and Gas Conservation Commission DATE:Friday,September 09,2011 TO: Jim Reggt,- c P.I.Supervisor T(t ,I 21// SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC W-223 FROM: Chuck Scheve PRUDHOE BAY UN SCH W-223 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J��'� NON-CONFIDENTIAL Comm _ Well Name: PRUDHOE BAY UN SCH W-223 API Well Number: 50-029-23440-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS110901201041 Permit Number: 211-006-0 Inspection Date: 9/1/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-223' Type Inj. W' TVD 5074 -T IA 480 2080 - 2040 2030 - P.T.D 2110060'TypeTest 1 SPT 1 Test psi 1500 - OA 590 680 680 I 680 Interval INITAL - P/F P - Tubing 1450 I 1450 1450 1450 Notes: Friday,September 09,2011 Page 1 of 1 E• o O c U `m m Nr U O• (66 N N �Q v HCO WOE' 30 > Y C9 CO cQYcoon U) « t Q on't m 63 �_ H rt di c ID cn p R• U ar 0 m co C o co X S .cU Lo cowV �w M C cnaQMQ °o Z irs to O CO tv O. 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Well Class: 20AAC 25.105 2OAAC 25.110 0 Development 0 Exploratory 0 GINJ ®WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One ®Service 0 Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 5/22/2011 211-006 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 4/27/2011 50-029-23440-00-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 5/10/2011 PBU W-223 361'FNL, 1176'FEL, SEC.21,T11 N, R12E, UM 8. KB(ft above MSL): 87 6' 15.Field I Pool(s): Top of Productive Horizon: 440'FNL, 1978'FEL, SEC. 15,T11 N, R12E, UM GL(ft above MSL): 53.3' Prudhoe Bay Field/Polaris Pool Total Depth: 9.Plug Back Depth(MD+TVD): 37'FNL, 1967'FEL, SEC. 15,T11 N, R12E, UM 9646' 5456' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 612049 y- 5959896 Zone- ASP4 9742' 5526' ADL 028263 TPI: x- 616437 y- 5965164 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 616441 y- 5965567 Zone- ASP4 None 18.Directional Survey: ®Yes ❑No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1906'(Approx.) 21.Logs Obtained (dist all logs here andsubmit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD GR, RES/NEU/AZI DENS/PWD, USIT N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE Top BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 129.5# X-65 Surface 110' Surface 110' 42" -260 sx Arctic Set 13-3/8" 68# L-80 34' 2326' 34' 2042' 16" 1318 sx Arctic Set Lite. 1162 sx Class'G' y 9-5/8" 40# L-80 2146' 546T 1930' 3419' 12-1/4" 272 sx LiteCrete.992 sx Class'G' 7" 26# L-80 31' 9729' 31' 5516' 8-3/4" 663 sx LiteCrete.897 sx Class'G' , 24. Open to production or injection? ®Yes 0 No 25. TUBING RECORD If Yes,list each interval open (MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 4-1/2"Gun Diameter,5 spf 3-1/2",9.2#,L-80 9469' ,9099'/5074', 9232'/5165' MD TVD MD TVD &9344'/5243' 9178'-9212' 5128'-5151' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9288'-9332' 5204'-5235' ,,,. 9370'-9426' 5262'-5301' "��PLEfltwl DEPTH INTERVAL(MD)I AMOUNT AND KIND OF MATERIAL USED . t f_____ _2550' Freeze Protect w/87 Bbls of Diesel 4=y pt el 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): Not on Injection Yet N/A Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL-BEL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 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 250.071. None RECENED RBDMS JUN 21 201 JUN 2 0 2011 Form 10-407 Revised 12/2009 CONTI ED ON REVERSE Alaska MI&Gm Cone. Commission Submit Original Only Yom` 6-2 t Ii AOChnrage447/3/ 6 29. GEOLOGIC MARKERS(List all formations and mark countered): 30. RATION TESTS NAME MD TVD Well Tested? 0 Yes ®No Permafrost Top 33' 33' If yes,list intervals and formations tested,briefly summarizing test Permafrost Base 2160' 1939' 1 results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 4 5532' 3446' None Ugnu 3 5655' 3499' Ugnu 1 7600' 4328' Ugnu Ma 8374' 4651' Schrader Bluff Na 8832' 4903' Schrader Bluff Nb 8882' 4935' Schrader Bluff Nc 8936' 4969' Schrader Bluff Ne 8951' 4978' Schrader Bluff Nf 9037' 5033' Schrader Bluff OA 9092' 5069' Schrader Bluff OBa 9173' 5124' Schrader Bluff OBb 9215' 5154' Schrader Bluff OBc 9288' 5204' Schrader Bluff OBd 9373' 5264' Schrader Bluff OBe 9470' 5332' Schrader Bluff OBf 9530' 5374' Base Schrader Bluff OBf 9596' 5421' Formation at Total Depth(Name): Colville 9596' 5421' 31.List of Attachments: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Terrie Hubble � � ����L�� Title: Drilling Technologist Date: • b /z°// ( PBU W-223 211-006 Prepared By Name/Number. Terrie Hubble,564-4628 Well Number Permit No./Approval No. Drilling Engineer: Wilson Quinta,564-4458 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing 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. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: 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 MC 25.071. Item 30: 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 MC 25.071. IForm 10-407 Revised 12/2009 Submit Original Only TREE= CIW WELLHEAD= FMC 1N-22 3 SAFETY I S: ACTUATOR= HYD PJC DRAT KB.ELEV= 86.67' BF.ELEV= 53.3' L 29' —14-1/2"X 3-1/2"XO, ID=2.992" _KOP= 250' 20"CONDUCTOR, —I 80'? Max Angle= 67'@ 3847' 129.5#,X-65, 2146' — 13-3/8"X 9-7/8"ZXPN LTP Datum MD= 9752' w/FLIX LOCK LNR HGR, ID=9.50" ID=18.770" Datum TVO= 5446'SS 2179' — 10-3(4"X 9-5/8"XO SUB, ID=8.82" 2274' -1 3-1/2"HES X NIP, ID=2.813" 13-3/8"CSG,68#,L-80 BTC, ID=12.415" —I 2326' 9-5/8"CSG,40#,L-80 BTC, ID=8.835" —I 5467' v . , GAS LIFT MANDRELS Li 4 ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 9044 5037 49 MMG DCR RKP — 05/20/11 3-1/2"RA TAG H 9075' 9099' H 7"X 3-1/2"BKR PREM FFM THRU PKR, ID=2.965" • 9111' —13-1/2"HES X NIP,ID=2.813" ■ 9117' —3-1/2"NDPG MULTI SUB, ID=2.992" 7'MARKER JOINT — 9133' WATER INJECTION MANDRELS Opd- ST MD TVD DEV TYPE VLV LATCH PORT DATE D r 5 9142 5103 47 MMG DMY RK 0 05/20/11 L 4 9213 5152 46 MIM DMY RK 0 05/20/11 3 9265 5188 46 MMG DMY RK 0 05/20/11 2 9326 5231 46 MMG DMY RK 0 05/20/11 1 9387 5274 45 MMG DMY RK 0 05/20/11 9232' H 7"X 3-1/2"BKR PREM FEED THRU PKR,ID=2.965" I 9244' —13-1/2"HES X NIP, ID=2.813" ()kr_ ■ 9250' —3-1/2"NDPG MULTI SUB, ID=2.992" PERFORATION SUMMARY I 9344' ,—7°X 3-1/2"BKR PREM FEED THRU PKR,ID=2.965" REF LOG:LWD LOG ON 05/16/11 ANGLE AT TOP PERF: 46 '@ 9178' 9356' -1 3-1/2"HES X NIP, ID=2.813" Note:Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 OBa 9178-9212 0 05/16/11 I 9362' —3-1/2"NDPG SINGLE SUB, ID=2.992" 4-1/2" 5 OBc 9288-9332 0 05/16/11 4-1/2" 5 OBd 9370-9426 0 05/16/11 ' I-1 9426' —3-1/2"HES X NIP. ID=2.813" 0S•1 r--- I 9447' —I3-1/2"HES XN NIP. ID=2.750" 3-1/2"TBG,9.24,L-80 TCII, .0087 bpf, ID=2.992" H 9469' I k i 9469' —3-1/2"WLEG, ID=2.992" PBTD -$ 9646' —1ELMD NOT LOGGED 7"CSG,26#,L-80 VAM TOP HC, — 9729' .0383 bpf, ID=6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 05/22/11 D-14 ORIGINAL COMPLETION WELL: W-223 05/27/11 PJC DRLG DRAFT CORRECTIONS PERMIT No: 2110060 API No: 50-029-23440-00 SEC 21,T11 N, R12E,361'FNL&1176'FEL BP Exploration(Alaska) •eNNP.-m Q OA.-O AO . m m W 004. N. mm N O O N g!8882? • _yayQN 81832 8 AA(22' fAVAnn NOm. NN pNmMm p NNNNN WMN DO,r.O Wp ANMA mWmQ 828 I C NNN NNNNN N, ^ 0O OM0. OD0pY03. s J 00888 80888 88888 80 000000 00 v v66666 v v v v66666 v v v v66666 66666 66666 v vvvv vQQ • • �IVVpp . • • oma • i p• i i i ®p W� • • • m• • p� . f S v W W O W O ,-...MVO Q °,28:2§2 {Op{Wp W m YI t•)t�'1 Wm<A �O+l t•I P t+l�O Q A{Wp a0 N A m m t7 m s^ .'s' W MMM M g OI N m A�—.W. 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C O • a E,roog3 a o :"Som n m C LL 0 N n O aQ ('0 3 • 0 0`! e s s E g1 a w`a` A- E 0 U In CO MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 12,2013 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC W-223 FROM: Chuck Scheve PRUDHOE BAY UN POL W-223 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name PRUDHOE BAY UN POL W-223 API Well Number 50-029-23440-00-00 Inspector Name: Chuck Scheve Permit Number: 211-006-0 Inspection Date: 9/1/2011 Insp Num: mitCS110901201041 Rel Insp Num: MITOP000003719 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-223 Type Inj W TVD 5074 IA 480 2080 2040 2030 PTD 2110060 Type Test SPT Test psi 1500 OA 590 680 680 680 Interval Initial Test P/F Pass Tubing 1450 1450 1450 1450 Notes: Wednesday,June 12,2013 Page 1 of 1 /- 006 MECHANICAL INTEGRITY REPORT • • SPUD DAT: ' 40 7//; OPER & FIELD P rift-rS F.',0 l . G- - - - - ER — 22-3t � r ',TELL DATA TD : et yug. .. 5S2 _TVD ; _BTD : of Gzg, 54156TvD ,./ Casi^.g : ctS/S Shoe: S`/(,? MD 34I/T TVD ; liV : •TVD 6,_ner : 7 „ Shoe: 17Z1 ?-+.D SS/!oTVD ; :OP : TVD Tubing 31/14 Packer clpiS07VTVD ; Sec at u :ole Size 34 and ; Per-Fs "117 to 720 Z-1- • iug8 ' _ qs3 Z CciAN.CAL INTEGRITY - PART ft /370- gKZG' • r�rc S'i Annulus Press Test: _? '1O ; 15 min 34:17-C--; 30 min 31GS . Comments : ed' bur- m a r ( ?& CHAN I CA1, INTEGRITY - PART #2 v Cement Volumes :• Amt. Liner ii/fr ; Cs ; DV -- Cmc vol to cover perls I�� fF32 ' At . 6‘ts . Aitc.00 Theoretical TOC -FOC_ L/ 364- e ch • .Zoo tiro GUS s -Fa ,VK (7— Lo Cement Bond Lo No) tS( R. In AOGCC File • CBL Evaluation, zone above perfs Production Log: Type N/A ; Evaluation CONCLUSIONS : Part 11 : M I T 4-y4 • ' grit Part 12: //a t a`/Lf/ .442 • 7.24, // North America -ALASKA- BP Page 1 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project:Prudhoe Bay Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 4/26/2011 00:00 - 02:00 2.00 MOB P PRE MAKE UP 20"ANNULAR TO THE SURFACE SPOOL AND HOOK UP AT THE LINES. • INSTALL THE MOUSE HOLE, LOAD DRILL PIPE IN TO THE SHED ALONG WITH THE BHA. -RIG ACCEPTED AT MIDNIGHT ON THE CONDITION REPAIRS ARE COMPLETE PRIOR TO SPUD OF WELL 02:00 - 06:00 4.00 MOB P PRE INSTALL THE DIVERTER TO THE 20" ANNULAR, LOAD THE MUD PRODUCT HOT SHACK,TAKE ON DRILLPLEX, SPOT THE ENVIROVAC. FINISH HOOKING UP ALL OF THE LINES AND DOUBLE CHECKING RIG EQUIPMENT IS OPERATIONAL FOR THE UPCOMING SPUD. TIGHTEN UP 4"VALVES ON THE CONDUCTOR,LOAD THE PIPESHED WITH DRILL PIPE AND BHA. 06:00 - 08:30 2.50 RIGU P PRE ATTACH THE DIVERTER LINES AND MOBILIZE ELEVATORS TO THE RIG FLOOR. 08:30 - 12:00 3.50 RIGU P PRE PICK UP 5" HWDP AND JARS AND RACK j L THEM BACK IN THE DERRICK. CHANGE OUT ELEVATORS AND CONTINUE TO PICK UP 4" DRILL PIPE OUT OF THE SHED RACKING IT BACK IN THE DERRICK. -LUSCHE'S CREW HELD SPILL DRILL,CRT 74 SEC. 12:00 - 13:00 1.00 BOPSUR. P PRE TEST THE DIVERTER. KNIFE VALVE TOOK 2 ` I SEC TO OPEN AND BAG SHUT IN 29 SECONDS. ACCUMULATOR TEST STARTED WITH 3000 PSI. BLED DOWN TO 1900 PSI,200 PSI GAIN IN 39 SEC, RETURN TO FULL PRESSURE IN 171 SEC. 4 BOTTLES AT 2200 PSI EACH. TEST WITNESSED BY BP WSL BLAIR NEUFELD AND DOYON TOOL PUSHER NICK MARMON. AOGCC REP.JEFF JONES - WAIVED WITNESS OF TEST. 13:0014:00 1.00 RIGU P I PRE CONTINUE TO PICK UP 4"DRILL PIPE AND RACK BACK IN THE DERRICK. 14:00 - 14:30 0.50 RIGU P • PRE PICK UP REMAINING BHA TOOLS TO THE FLOOR. 14:30 - 17:30 3.00 RIGU P ! PRE CHANGE OUT THE ELEVATORS AND MAKE UP BHA#1 AS FOLLOWS: -16"MX-1 HUGHES BIT,SERIAL#5191535 • -MOTOR WITH 2.12 BEND -NON MAG UBHO SUB -NON MAG PONY COLLAR -NON MAG IBS -NON MAG BOTTLENECK CROSS OVER -5"HWDP 17:30 - 19:00 1.50 RIGU P PRE SPOT AND RIG UP GYRO. 19:00 - 19:30 0.50 RIGU P PRE LUBRICATE THE RIG AND DOUBLE CHECK EQUIPMENT ON THE RIG FLOOR. 19:30 - 21:30 2.00 RIGU P PRE TEST POP-OFF ON MUD PUMPS. MUD PUMP #1 SET AT 4230 PSI, MUD PUMP#2 SET AT 4460 PSI. CHANGE OUT 4"VALVE ON THE CONDUCTOR. PERFORM PRE-SPUD DERRICK INSPECTION. 21:30 - 00:00 i 2.50 RIGU N RREP PRE CHANGE OUT 4"VALVE ON MUD PUMP#2. Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 2 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date:5/11/2011 X3-00W92-C(4,355,681.00) Project:Prudhoe Bay Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release:5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 4/27/2011 00:00 - 00:30 I 0.50 DRILL P SURF REVIEW PRE-SPUD CHECKLIST WITH ALL j HANDS. -PRE-SPUD MEETING HELD WITH LUSCHE'S CREW AT PRE-TOUR. 00:30 - 01:00 0.50 • DRILL • P SURF FLOOD DIVERTER WITH SPUD MUD AND CHECK FOR LEAKS. 01:00 - 02:30 1.50 DRILL P I SURF PICK UP 1 STAND OF 5"HWDP AND RUN IN THE HOLE. TAGGED CEMENT AT 100'. TURN ON THE PUMPS TO 400 GPM AND BEGIN CONTROL DRILLING TO 110'AT 220 PSI. UP WT.65K/DOWN WT.65K 02:30 - 03:00 0.50 DRILL P I SURF I RECONFIRM SURFACE EQUIPMENT DUE TO EXTENDED RIG MAINTENANCE. 03:00 - 11:00 8.00 DRILL P SURF .CONTINUE TO DRILL AHEAD FROM 110' TO 516'AT 400 GPM WITH 500 PSI ON/350 PSI OFF. UP WT.75K/DOWN 75K. MUD WT IN AND OUT 8.8 PPG 11:00 - 11:30 0.50 DRILL P SURF PULL OUT OF THE HOLE FROM 516'TO 58'. RACK BACK 1 STAND OF 4"DRILLPIPE AND 4 STANDS OF 5"HWDP. 11:30 - 12:00 J 0.50 DRILL P ` SURF TORQUE LIFT SUB INTO THE MOTOR,PICK UP MOTOR,AND ALLOW IT TO DRAIN. -PRE-SPUD MEETING HELD WITH JENNINGS CREW AT PRE-TOUR. 12:00 - 15:30 3.50 DRILL P SURF ADJUST THE MOTOR TO A 1.83 DEGREE I BEND. LAYDOWN THE UBHO SUB. PICK UP THE BHA AS FOLLOWS: , -16"MX-1 HUGHES BIT,SERIAL#5191535 -MOTOR WITH 1.83 BEND -NON MAG PONY COLLAR -NON MAG IBS 16" -MWD -NON MAG UBHO SUB -NON MAG IBS 16" -NON MAG BOTTLE NECK CROSS OVER -NON MAG DRILL COLLAR -NON MAG DRILL COLLAR -NON MAG IBS 8.75" -NON MAG DRILL COLLAR -5"HWDP(1 JT.) -JARS i-5"HWDP(13 JTS.) -CROSS OVER 15:30 - 16:00 0.50 DRILL P SURF RUN BACK IN THE HOLE TO 471'AND WASH DOWN TO 516'AT 550 GPM WITH 930 PSI. 16:00 - 00:00 8.00 1 DRILL P SURF DIRECTIONALLY DRILL FROM 516'T0905'; TAKING GYRO-SURVEYS EVERY 100'. DRILL AT 525 GPM WITH 1010 PSI ON/850 PSI OFF. j1 TQ 5K ON/2K OFF AT 40 RPM WITH WOB OF 20-25K. UP WT 91K/DOWN WT 91K/ROT WT 191K -JENNINGS CREW HELD SPILL DRILL,CRT 93 SEC. Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 3 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 4/28/2011 00:00 - 04:30 4.50 DRILL P -� SURF DIRECTIONALLY DRILL FROM 905'TO 1120'. TAKING GYRO-SURVEYS EVERY 100'. DRILL AT 550 GPM WITH 1010 PSI ON/850 PSI OFF. TQ 5-7K ON/2K OFF AT 40 RPM WITH WOB OF20-25K. UPWT91K/DOWNWT91K/ROT WT 91K -MUD WT IN AND OUT 9.1 PPG -LUSCHE'S CREW HELD TABLE TOP DIVERTER DRILL 04:30 - 05:00 0.50 DRILL P SURF MWD DETECTION CLEANED UP AND RECEIVED 3 GOOD SURVEYS THAT WERE CLOSE TO THE GYRO SURVEY. RIG DOWN GYRO. 05:00 - 11:30 6.50 DRILL P SURF TDRILL AHEAD FROM 1120' TO 1492'AT 550 GPM WITH 1460 PSI ON/1260 PSI OFF. ROTATING AT 40 RPM WITH TQ ON 6-7K/OFF I 3K. UP WT. 110K/DOWN WT.85K/ROT WT. 102K -MUD WT IN AND OUT 9.3 PPG 11:30 - 14:30 3.00 DRILL P SURF WASH AND REAM FROM 1398'TO 1492'TO SMOOTH OUT THE DOGLEG. ROTATING 40 RPM AT 520 GPM WITH 1260 PSI. - -MUD WT IN AND OUT 9.2 PPG. 14:30 - 00:00 9.50 DRILL P SURF DRILL AHEAD FROM 1492' TO 1940'AT 525 GPM WITH 1250 PSI ON/1050 PSI OFF. ROTATING AT 40 RPM WITH TQ ON 6-7K/OFF 3K AND WOB 25-35K. UP WT. 107K/DOWN WT. 90K/ROT WT. 100K -MUD WT IN AND OUT 9.1 PPG -JENNINGS CREW HELD A FIRE DRILL, CRT 110 SEC. 4/29/2011 00:00 - 07:30 7.50 DRILL P SURF DRILL AHEAD FROM 1940'TO 2266'AT 525 GPM WITH 1300 PSI ON/1200 PSI OFF. ROTATING AT 40 RPM WITH TQ ON 6-8K/OFF 4K AND WOB 25-35K. UP WT. 115K/DOWN WT. 85K/ROT WT. 100K -MUD WTINAND OUT 9.1 PPG 07:30 - 10:30 3.00 DRILL P ( ' SURF BACK REAM OUT OF THE HOLE FROM 2266' TO 1771'AT 800 GPM WITH 2480 PSI ROTATING AT 60 RPM,CIRCULATE BOTTOMS UP. CUT THE PUMPS TO 600 GPM AT 1771' AND CONTINUE BACK REAMING OUT TO 655'. LARGE QUANTITIES OF SAND AND GRAVEL OVER THE SHAKERS. -MUD WT IN AND OUT 9.1 PPG 10:30 - 12:00 1.50 DRILL P SURF REAM IN THE HOLE FROM 655'TO 1585'. WORK THROUGH TIGHT SPOTS AT 1287'AND 1345'. 12:00 13:30 1.50 DRILL P SURF CONTINUE TO REAM IN THE HOLE TO 1800'. WASHING DOWN THE LAST 100'TO 2259'. 13:30 - 14:30 1.00 DRILL P SURF CIRCULATE AND CONDITION RECIPROCATING 20'STROKES PUMPING AT 600 GPM WITH 1400 PSI. 1D 14:30 - 15:30 li 1.00 DRILL P SURF DRILL AHEAD FROM 2256'TO 2338'AT 630 GPM WITH 1930 PSI ON/1720 PSI OFF. ROTATING AT 40 RPM WITH TQ ON 6-8K/OFF • 4K AND WOB 25-35K. UP WT. 112K/DOWN WT. 90K/ROT WT. 100K -MUD WT IN AND OUT 9.1 PPG Printed 6/6/2011 1:32:37PM "orth America -ALASKA- BP Page 4 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project:Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 15:30 - 17:00 1.50 DRILL P SURF CIRCULATE BOTTOMS UP 20'OFF BOTTOM RECIPROCATING PIPE PUMPING AT 650 GPM WITH 1720 PSI ROTATING AT 40 RPM WITH 5K TQ. STAGE UP THE PUMPS TO 800 GPM WITH 2570 PSI. 17:00 - 21:00 4.00 I DRILL P SURF BACK REAM OUT OF THE HOLE FROM 2338' TO 655'AT 700 GPM WITH 1740 PSI ROTATING AT 40 RPM WITH 5K TQ. LARGE QUANTITIES OF SAND AND GRAVEL OVER THE SHAKERS. -MUD WT IN AND OUT 9.1 PPG 21:00 - 21:30 0.50 DRILL P SURF MONITOR THE WELL,STATIC.CHANGE OUT THE ELEVATORS TO 5"AND BLOW DOWN THE TOP DRIVE. -CARLOS CREW HELD KICK WHILE TRIPPING DRILL,CRT 120 SEC. 21:30 - 00:00 2.50 DRILL P SURF STAND BACK 5"HWDP,JARS,AND NON MAG 8.75"DRILL COLLARS. LAY DOWN THE 16" STABILIZER,BREAK OFF THE BIT AND LAY DOWN THE STABILIZER AND MWD TOOLS. 4/30/2011 00:00 - 00:30 0.50 DRILL P SURF LAYDOWN STABILIZER,LEAD COLLAR, ,4 MOTOR,AND BIT. -BIT GRADE:3-3-WT-A-E-I-SS-TD 00:30 - 02:00 ' 1.50--- CASING P SURF CLEAR FLOOR OF ALL TOOLS NOT NEEDED I FOR UPCOMING OPERATIONS. MOBILIZE ELEVATORS LINKS. SAVER SUB,AND 5" JOINT OF DRILL PIPE. -LUSCHES CREW HELD SPILL DRILL,CRT 84 • SEC. 02:00 - 04:00 2.00 CASING P SURF CHANGE OUT THE SAVER SUB,REMOVE ELEVATOR LINKS. BELL GUIDE, POSITION TONGS, CHANGE OUT SUB, INSTALL TORQUE RING,TORQUE EVERYTHING TO SPECS,WIRE TIE,CHANGE OUT GRABBER DIES,WIRE TIE GRABBER SECTION. 04:00 - 07:00 3.00 CASING P SURF PJSM,PICK UP AND MAKE UP TESCO EQUIPMENT,MOBILIZE THE TESCO CONTROL MODULE, HANG THE HOSES, PICK UP THE RUNNING TOOL AND CONNECT. PICK UP PUP JTS.AND MAKE DUMMY RUN WITH LANDING JT. MAKE UP LONG BALES FOR UPCOMING CEMENT JOB. Printed 6/6/2011 1:32:37PM "orth America -ALASKA- BP Page 5 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date:5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 07:00 - 14:30 7.50 CASING P SURF -?PJSM FOR RUNNING 13-3/8"BTC L-80 68/t SURFACE CASING. PICK UP SHOE TRACK, 'CHECK FLOATS, HELD. PICK UP AND MAKE UP 13-3/8"SUFACE CASING AS FOLLOWS: -TESCO WARTHOG 13-3/8"FLOAT SHOE -2 JTS 13 3/8"68#L-80 BTC CASING(#1-#2) -HALLIBURTON 13 3/8"FLOAT COLLAR -1 JTS 13 3/8"68#L-80 BTC CASING(#3) -2 PUP 133/8"68#L-80 BTC CASING(#1,2) -40 JTS 13 3/8"68#L-80 BTC CASING(#4- #43) -1 PUP 13 3/8"68#L-80 BTC CASING -13 3/8"68#L-80 BTC TAM COLLAR -1 PUP 13 3/8"68#L-80 BTC CASING -12 JTS 13 3/8"68#L-80 BTC CASING(#43- #54) -13 3/8"68#L-80 BTC HANGER P X P PUP JT. -13 3/8"FLUTED CASING HANGER -1 SPIRAGLIDERS W/ RING 5'ABOVE SHOE ON JT#1 -1 SPIRAGLIDER ON JOINT#3 FREE FLOATING -1 ON JOINT THE PUP JT. FREE FLOATING -1 SPIRAGLIDER FREE-FLOATING ON JT #27,#28,#29 !-1 SPIRAGLIDER LOCKED DOWN 10'ON 'EACH SIDE OF TAM COLLAR WITH STOP i L. RINGS I-TOTAL 8 SPIRAGLIDERS CENTRALIZERS 'RUN AND 4 STOP RINGS 14:30 15:30 1.00 CASING P SURF PICK UP 13-3/8"CASING HANGER AND LAND ON LANDING RING. BOTTOM OF 13-3/8" CASING AT 2326'. 15:30 - 16:00 0.50 CEMT P SURF CIRCULATE AND CONDITION MUD AT 12 BPM WITH 840 PSI. SIMOPS:CLEAR RIG FLOOR OF SLIPS, THREAD PROTECTORS,AND OPERATING UNIT FOR THE TESCO UNIT. 16:00 - 17:00 1.00 CEMT P SURF LAY DOWN THE TESCO UNIT AND MAKE UP THE CEMENT HEAD CROSS OVER AND HEAD. CIRCULATE AT 6 BPM WITH 140 PSI. 17:00 - 20:15 3.25 CEMT P SURF PUMP 5 BBLS OF 10 PPG MUD PUSH AND PRESSURE TEST THE LINES TO 3500 PSI. 54 PUMP 95 BBLS ADDITIONAL 10 PPG MUD ` � PUSH, DROP THE BOTTOM PLUG, FOLLOWED BY 575 BBLS(1352 SX)ASL LEAD 10.7 PPG • (2.45 CU/FT YIELD)CEMENT AT 8 BPM WITH 450 PSI FOLLOWED BY 240 BBLS(1215 SX) OF CLASS G 15.8 PPG(1.16 CU/FT YIELD)TAIL CEMENT AT 6 BPM WITH 900 PSI. DROP TOP PLUG AND KICK OUT WITH 10 BBLS OF WATER. SWITCH OVER TO THE RIG FOR DISPLACEMENT. Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 6 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date:5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth Phase Description of Operations ' (hr) � 1 (ft) 20:15 - 21:30 1.25 ' CEMT P SURF DISPLACE WITH THE RIG PUMPS STARTING AT 8 BPM WITH 160 PSI. CATCH THE I CEMENT AT 30 BBLS DISPLACED WITH 240 PSI. SLOW TO 6 BPM WITH 140 PSI AT 140 ' 1 1 BBLS DISPLACED TO MAKE RETURNS MORE 1 MANAGEABLE AT SURFACE. INCREASE PUMP RATE TO 5.5 BPM WITH 190 PSI WITH j 154 BBLS DISPLACED. SLOW PUMPS TO 2 BPM WITH 210 PSI AT 226 BBLS DISPLACED I DUE TO RETURNS BECOMING VERY THICK. i I INCREASE RATE TO 4 BPM WITH 460 PSI AT • 300 BBLS DISPLACED. SLOW TO 2 BPM WITH 420 PSI AT 320 BBLS DISPLACED IN PREPARATION FOR BUMPING THE PLUG. BUMP THE PLUG AT 322 BBLS DISPLACED 1 I AND PRESSURE UP TO 1200 PSI AND HOLD. CHECK THE FLOATS, HELD. INCREASE I PRESSURE TO 3500 PSI FOR 5 MINUTES TO , TEST THE CASING. GOOD TEST, NO BLEED l OFF. CIP @ 21:18. 170 BBLS OF CEMENT_ BACK TO SURFACE. ICP-160 PSI/FCP 540 I PSI 21:30 - 23:30 I 2.00 CEMT P SURF LAY DOWN THE CEMENT HEAD AND CROSS OVER. FLUSH THE STACK, BAG, HOLE FILL UP LINE,FLOW LINE AND BLEED OFF LINE. 23:30 - 00:00 0.50 CEMT • P ' SURF CLEAN THE DRIP PAN. — i - - 5/1/2011 00:00 - 04:00 ' 4.00 WHSUR I P SURF i NIPPLE DOWN THE DIVERTER SYSTEM, 1 I REMOVE THE FLOW LINE, BLEED OFF/HOLE FILL LINE, REMOVE THE MOUSE HOLE, TURNBUCKLES, RISER, DIVERTER LINES, !REMOVE ACCUMULATOR LINES,4"VALVES I ON THE CONDUCTOR,AND CLEAR THE ' 1 FLOOR OF THE CEMENT HEAD, CROSS j 'OVERS. LAY DOWN THE RISER AND REMOVE THE LONG BALES. 04:00 - 06:00 2.00 WHSUR P SURF NIPPLING UP THE FMC GEN 5 WELLHEAD ' 'SYSTEM. PRESSURE TEST TO 1000 PSI FOR 5 MINUTES. GOOD TEST. 06:00 - 10:00 4.00 BOPSUR P SURF NIPPLE UP BOP STACK AND REMOVE THE ADAPTOR FLANGE. INSTALL THE CHOKE LINE, RISER,TURNBUCKLES, FLOW LINE, BLEED OFF/HOLE FILL LINES, CENTER THE STACK, FLOW LINE COVERS, INSTALL THE MOUSE HOLE/RISER. MEASURE RKB'S AND MOBILIZE TEST EQUIPMENT TO THE RIG FLOOR. 10:00 - 12:00 2.00 BOPSUR P SURF BODY TEST BOP'S WITH BAG 2500 PSI WITH THE 4"TEST JOINT FOR 5 MINUTES. GOOD TEST. 12:00 - 15:00 3.00 DRILL P SURF LAYDOWN TEST JOINT AND PICK UP 4.5"IF PUP JOINT. CHANGE OUT THE 4.5"IF SAVER - SUB TO XT-39 SAVER SUB. 15:00 - 16:00 1.00 BOPSUR P SURF RIG UP TO TEST BOPE. Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 7 of 22 ( peration Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) i Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase j Description of Operations (hr) ft 16:00 - 22:30 6.50 BOPSUR P O SURF TEST THE ANNULAR TO 250 PSILOW AND 12500 PSI HIGH FOR 5 MINUTES EACH TEST. GOOD TEST. TEST VALVES 1,2,3,4,5,6,7, 8,9, 10, 11, 12, 13, 14 AND TEST THE TOP i 3-1/2"X 6"RAMS WITH 4"TEST JOINT TO 250 PSI LOW/4000 PSI HIGH FOR 5 MINUTES EACH TEST. GOOD TESTS. TEST THE BOTTOM 2-7/8"X 5"RAMS, MANUAL IBOP AND HYDRAULIC IBOP WITH 4"TEST JOINT TO 250 1- PSI LOW/4000 PSI HIGH FOR 5 MINUTES Y EACH TEST. GOOD TESTS. TEST THE XT-39 76 FOSV AND DART VAVLES ALONG WITH THE I BLIND RAMS TO 250 PSI LOW/4000 PSI HIGH FOR 5 MINUTES EACH TEST. GOOD TESTS. TEST THE 4"KILL LINE IN THE PITS TO 250 � PSI LOW/4000 PSI HIGH FOR 5 MINUTES ii EACH TEST. GOOD TESTS. TEST THE MANUAL CHOKE AND HYDRAULIC CHOKES TO 1500 PSI FOR 5 MINUTES. GOOD TESTS. ALL TESTED CHARTED. WITNESSED BY I AOGCC REP CHUCK SCHEVE, BP WSL'S JOEY LEBLANC AND CHRIS KOBUCK,AND DOYON TOOLPUSHERS NICK MARMON AND HARRY GOCHENAER. 22:30 - 23:30 1.00 BOPSUR P SURF RIG DOWN BOP TEST EQUIPMENT. 23:30 - 00:00 0.50 DRILL P SURF 1RIG UP BALES, ELEVATORS,AND PREPARE ATO PICK UP DRILL PIPE. 5/2/2011 00:00 - 00:30 0.50 1 CEMT P SURF ,SERVICE AND INSPECT THE TOP DRIVE, Y I + BLOCKS,AND DRAW WORKS. 00:30 - 04:30 4.00 P CEMTP SURF PICK UP 60 JOINTS OF 4"DRILL PIPE AND SINGLE IN THE HOLE. PULLING OUT OF THE j HOLE RACKING BACK THE DRILL PIPE. 04:30 - 07:00 2.50 CEMT P SURF RIG UP AND PERFORM CASING PRESSURE TEST TO 250 PSI LOW/3500 PSI HIGH FOR 30 j MINUTES. PUMPED 6.1 BBLS AND BLED BACK 6.1 BBLS. 0 PSI LOST IN FIRST 15 MINUTES AND 0 PSI LOST IN SECOND 15 MINUTES. GOOD TEST. 107:00 - 08:00 1 1.00 CEMT P SURF BLOW DOWN THE CHOKE AND KILL LINES. MOBILIZE BHA#3 TO THE RIG FLOOR. 08:00 - 08:30 0.50 CEMT P SURF HOLD PJSM FOR ALL HANDS INVOLVED IN PICKING UP THE BHA. 08:30 - 11:00 2.50 CEMT P SURF PICK UP BHA#3 AS FOLLOWS: -12.25"HUGHES VM-3 JETTED WITH 3/18, 1X16c SERIAL#5191159 I -9.625"MOTOR WITH 1.5 DEG BEND NON-MAG PONY COLLAR I i-NON-MAG IBS 12.25" !-MWD -NON-MAG IBS 12.25" -NON-MAG BOTTLE NECK CROSS OVER I -NON-MAG DRILL COLLARS(2) -NON-MAG IBS 8.75" -NON-MAG DRILL COLLAR , -5"HWDP -6.5"HYDRAULIC JARS I -5"HWDP(13) -CROSS OVER Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 8 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type:DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project:Prudhoe Bay i Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT 1 NPT Depth Phase Description of Operations (hr) 1 (ft) 11:00 - 13:00 2.00 CEMT P SURF PICK UP 1 JT.OF 4"DRILL PIPE AND PULSE TEST THE MWD. GOOD TEST. CONTINUE SINGLING IN THE HOLE WITH 36 ADDITONAL JTS OF 4"DRILL PIPE. 13:00 - 14:00 1.00 CEMT P I SURF CONTINUE TO RUN IN THE HOLE FROM 1768' TO 2000'WITH 4"DRILL PIPE OUT OF THE DERRICK. ESTABLISH PARAMETERS OF UP WT. 113K/DOWN WT.93K/ROT WT. 100K WHILE PUMPING AT 500 GPM WITH 1250 PSI. 14:00 - 16:00 2.00 CEMT P SURF WASH DOWN FROM 2000'TO 2226'AT 500 GPM WITH 1550 PSI. DRILL UP THE SHOE I TRACK FROM 2240'TO 2326'AT 40 RPM WITH 8-10K WOB. 16:00 - 17:00 1.00 CEMT P SURF DRILL UP THE WARTHOG SHOE AT 2326'AND MILL TO 2330'AT 500 GPM WITH 1550 PSI iRUNNING 8-10 WOB AT 40 RPM. 17:00 - 18:00 1.00 CEMT P SURF DRILL UP NEW FORMATION FROM 2330'TO , 2358'AT 500 GPM WITH 1050 PSI. ROTATING AT 70 RPM WITH 7-10K TQ. UP WT. 113K/ DOWN WT.95K/ROT WT. 100K. STAND BACK ONE STAND TO PUT BIT DEPTH AT 2329'. 18:00 - 19:00 1.00 CEMT 1 ` P I SURF CIRCULATE BOTTOMS UP AT 2329'WITH 300 GPM AND 600 PSI ROTATING AT 40RPM WITH 3-7K TQ. RECIPROCATING FULL STAND. 19:00 - 20:00 1.00 CEMT P , SURF •EMPTY PITS 1 AND 2 FRO FLUID DISPLACEMENT OF 9.0 PPG LSND MUD. 20:00 - 21:30 1.50 CEMT P SURF DISPLACE 9.3 PPG DRILPLEX SPUD MUD TO 19.0 PPG LSND. TOTAL OF 404 BBLS DISPLACED TO GET GOOD FLUID BACK TO SURFACE. STARTED DISPLACEMENT AT 4.5 BPM WITH 260 PSI STAGING UP TO 5 BPM WITH 380 PSI. ROTATE AT 40 RPM AND ` 'I RECIPROCATE FULL STAND THROUGHOUT ENTIRE DISPLACEMENT. __ -MUD WT IN AND OUT 9.0 PPG 21:30 - 22:00 0.50 CEMT P SURF BLOW DOWN THE TOP DRIVE AND HOOK UP THE KILL LINE. RIG UP TO PERFORM LOT. 22:00 - 22:30 0.50 DRILL P INTI SHUT THE TOP RAMS AND PERFORM LOT. BREAK OVER AT 400 PSI SURFACE PRESSURE WITH 9.0 PPG MUD AT 2050'TVD. EMW OF 12.75 PPG PUMPED 2 BELS AND BLED BACK.75 BBLS. DETERMINED BY WSL 1 CHRIS KOBUCK,BP ENGINEER WILSON _ _ _ _ QUINTA,AND BP WTL MIKE SCHULTZ. 122:30 - 23:00 0.50 DRILL 1 P 1 INTI CIRCULATE AT 300 GPM WTIH 380 PSI 1 I ROTATING AT 40 RPM WITH 3-5K TQ AND 1 RECIPROCATE FULL STAND WHILE 1 CONSULTING WITH TOWN. 23:00 - 00:00 1.00 DRILL P INTI DIRECTIONALLY DRILL AHEAD FROM 235R' , TO 2422'AT 60 RPM PUMPING AT 650 PSI I I WITH 1120 PSI. -MUD WT IN AND OUT 9.0 PPG Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 9 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project:Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release:5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations 5/3/2011 00:00 12:00 12.00 7 DRILL P ! O t INTI 1 DIRECTIONALLY DRILL AHEAD FROM 2,422' I I TO 3,772'MD -PUW 110K,SOW 90K, ROT 100K I -793 GPM,2,300 PSI ON,2,150 PSI OFF -100 RPM,TQ 6K ON,5K OFF -15-20K WOB II -MW IN 9.3 PPG,MW OUT 9.4 PPG _' ART 3.63,AST 3.80,ADT 7.43 12:00 - 00:00 12.00 DRILL P INTI DIRECTIONALLY DRILL AHEAD FROM 3,772' ' TO 5,250'MD -PUW 140K,SOW 92K, ROT 110K -800 GPM,2,960 PSI ON,2,800 PSI OFF -100 RPM, TQ 9K ON,8K OFF 30K WOB -MW IN 9.5 PPG,MW OUT 9.5 PPG ART 4.60,AST 1.68,ADT 6.28 ADT FOR LAST 24 HRS: 13.71 5/4/2011 00:00 - 01:30 1.50 DRILL P INTI DIRECTIONALLY DRILL AHEAD FROM 5,250' -rp TO 5,470'MD -PUW 145K,SOW 90K,ROT 109K I } -800 GPM,3,000 PSI ON,2,890 PSI OFF (fv -100 RPM,TQ 9K ON,8K OFF -25K WOB I I -MW IN 9.5 PPG,MW OUT 9.5 PPG 1 AST 0.13,ART 0.88,ADT 1.01 TD CALLED BY GEOLOGIST AT 5,470'MD 01:30 - 02:00 0.50 DRILL P INTI CIRCULATE TO CLEAR CUTTINGS ABOVE BHA 790 GPM,2,800 PSI OBTAIN FINAL SURVEY AND SLOW-PUMP RATES AT TD j 02:00 - 04:30 2.50 DRILL P INTI BACKREAM FROM 5,470'TO 13-3/8"SURFACE CASING SHOE AT 3,525'MD -760 GPM,2,600 PSI - 100 RPM,TQ 8-9K 104 30 - 06:00 1.50 I DRILL P INTI ENCOUNTER CLAY BALLS AT 3,525'MD DROP ROTATION TO 50 RPM AND VARY PUMP RATE FROM 550 GPM TO 280 GPM TO I PREVENT FLOWLINE FROM PACKING OFF 06:00 - 08:30 2.50 DRILL P INTI CONTINUE TO BACKREAM FROM 3,525'TO 2,235'MD(INSIDE 13-3/8"SURFACE CASING) -750 GPM,2,600 PSI -100 RPM,TQ 7K 08:30 - 10:00 1.50 DRILL P INTI CIRCULATE 2 BOTTOMS-UP VOLUMES -700 GPM,1,600 PSI - 100 RPM, TQ5K FINAL MUD WEIGHT 9.9 PPG IN AND OUT 10:00 - 11:30 1.50 DRILL P INTI SLIP AND CUT DRILLING LINE INSPECT AND SERVICE TOP DRIVE, BLOCKS, AND DRAWWORKS CLEAN DRIP PAN BELOW RIG FLOOR Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 10 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE (DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project:Prudhoe Bay Site:PB W Pad Rig Name/No.:DOYON 14 l Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase ' Description of Operations (hr) (ft) 11:30 - 13:30 2.00 DRILL P INTI CIRCULATE AND CONDITION MUD -ROTATE AND RECIPROCATE DRILL STRING -MUD WEIGHT CLIMBED AFTER CLAY BALLS CLEANED UP -650 GPM,1,350 PSI -50 RPM,TQ 5-6K FINAL MUD WEIGHT 9.4 PPG IN AND OUT 13:30 - 19:00 5.50 DRILL P INTI RIH FROM 2,235'TO TD AT 5,470'MD STOP EVERY 1,000'TO CIRCULATE AND CONDITION MUD -3,261'MD --850 GPM,2,250 PSI --120 RPM,TQ 5K -4,189'MD --825 GPM,2,550 PSI --120 RPM,TQ 6K -5,470'MD --840 GPM,3,310 PSI --120 RPM,TQ 8K --FINAL MUD WT 9.3 PPG IN AND OUT OBTAIN SLOW PUMP RATE WHEN FINISHED CONDITIONING MUD 19:00 - 21:00 2.00 DRILL P l INTI FLOW CHECK WELL -NO FLOW POOH FROM 5,470'TO 2,981'MD -RACK BACK DRILLPIPE STANDS 21:00 - 21:30 0.50 DRILL P INTI PUMP DRY JOB 21:30 - 23:00 1.50 DRILL P INTI POOH FROM 2,981'TO 2,326'MD -RACK BACK DRILLPIPE STANDS 23:00 - 23:30 0.50 DRILL P INTI FLOW CHECK WELL -NO FLOW DROP 2.38"HOLLOW RABBIT DOWN DRILLPIPE POOH FROM 2,326'TO 650'MD -RACK BACK DRILLPIPE STANDS 23:30 - 00:00 0.50 DRILL P INTI CHANGE 4"ELEVATORS TO 5"ELEVATORS RACK BACK 5"HWDP STANDS AND NON-MAG DRILL COLLAR STAND LAY DOWN STABILIZERS 5/5/2011 00:00 - 01:00 1.00 DRILL P INTI LD REMAINING BHA COMPONENTS -INTEGRAL BLADE STABILIZER -MWD -INTEGRAL BLADE STABILIZER -NON-MAG PONY COLLAR • -MUD MOTOR -12-1/4"BIT BIT GRADE 1-1-WT-A-0-4-SS-TD 01:00 - 01:30 0.50 WHSUR P INTI DRAIN STACK AND PULL WEAR BUSHING PULL MOUSEHOLE FOR UPCOMING OPERATION Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 11 of 22 Vperation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date:5/11/2011 X3-00W92-C(4,355,681.00) Project:Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 01:30 - 03:00 1.50 BOPSUR ' P INTI TCHANGE UPPER RAMS FROM 3-1/2"X 6"VBR I TO 9-5/8"FIXED RAMS I REINSTALL MOUSEHOLE AFTER RAMS CHANGED I SIM-OPS DURING RAM CHANGE: CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED FOR LINER RUN ; MOBILIZE EQUIPMENT TO RIG FLOOR FOR LINER RUN 03:00 - 04:30 1.50 BOPSUR P INTI PICK UP 9-5/8"TEST JOINT,MAKE UP LOWER TEST PLUG TO JOINT,AND LAND TEST PLUG IN LOWER BOWL OF WELLHEAD I MAKE UP 4-1/2"PUMP-IN SUB AND RIG UP TEST EQUIPMENT ' I TEST 9-5/8"FIXED RAMS TO 250 PSI LOW, I I 4,000 PSI HIGH FOR 5 MINUTES EACH -CHART BOTH TESTS -AOGCC INSPECTOR BOB NOBLE WAIVED 1 WITNESS I RIG DOWN TEST EQUIPMENT 04:30 - 07:30 3.00 CASING P INTI MOBILIZE LINER RUNNING EQUIPMENT TO RIG FLOOR • CHANGE TO LONG BALES AND BALE EXTENSIONS 107:30 - 15:30 8.00 CASING P . INTI RUN 9-5/8"40#L-80 BTC LINER UTILIZING VOLANT CRTi CASING RUNNING TOOL TO SURFACE CASING SHOE AT 2,326'MD I-TORQUE RINGS INSTALLED IN LINER I JOINTS BAKERLOKSHOETRACK -RUN 9-5/8"X 12"WEATHERFORD CONTOUR CENTRALIZERS ON FIRST 25 JOINTS -TORQUE CONNECTIONS TO 20,000 FT-LBS INITIALLY --STARTED BACKING OUT SAVER SUB I ;ATTEMPTING TO RELEASE CRTi TOOL. I DROPPED MAKEUP TORQUE TO 18,000 ' FT-LBS WITH SAME RESULT. DROPPED MAKEUP TORQUE TO 15,000 FT-LBS WITH SUCCESS. I I I-CHECK FLOATS AFTER MAKING UP ISHOETRACK --FLOATS HOLDING II I-FILL PIPE EVERY JOINT , -RECORD UP, DOWN,AND ROTATING WEIGHTS EVERY 10 JOINTS IN CASED HOLE HELD UNANNOUNCED D1 KICK WHILE ' TRIPPING DRILL 15:30 - 16:00 0.50 7 CASING P INTI CIRCULATE ANNULAR VOLUME AT SURFACE i CASING SHOE 1 '-10 BPM,428 PSI -PARAMETERS AT SHOE: I--PUW 126K,SOW 116K, ROT 124K --30 RPM,TQ 5K Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 12 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations I (hr) (ft) 16:00 - 18:00 2.00 CASING P , INT1 ',CONTINUE TO RUN 9-5/8"40#L-80 BTC LINER UTILIZING VOLANT CRTi CASING RUNNING 'TOOL TO 3,282'MD • -TORQUE RINGS INSTALLED IN LINER I JOINTS j -TORQUE CONNECTIONS TO 15,000 FT-LBS -FILL PIPE EVERY JOINT RECORD UP, DOWN,AND ROTATING WEIGHTS EVERY 10 JOINTS IN OPEN HOLE 18:00 - 19:00 1.00 CASING P INTI MAKE SERVICE BREAKS ON VOLANT CRTi TOOL AND LAY DOWN SAME RIG DOWN LONG BALES AND BALE EXTENSIONS.RIG UP SHORT BALES INSTALL 5"ELEVATORS 19:00 - 20:00 1.00 CASING P INTI MAKE UP BAKER FLEX-LOCK HANGER AND HRD-E ZXP LINER TOP PACKER ASSEMBLY L.--__ - -PUW 167K SOW 125K 20:00 - 21:30 1.50 CASING P INTI CIRCULATE LINER VOLUME I -8 BPM,120 PSI SIM-OPS WHILE CIRCULATING:LAY DOWN __ LINER RUNNING EQUIPMENT 21:30 - 22:30 1.00 CASING ' P I INTI CHANGE ELEVATORS FROM 5"TO 4" I .RIH ON 4"DRILLPIPE FROM 3,326'TO 4,445' 'MD 22:30 - 23:30 1.00 CASING P ! INTI CHANGE ELEVATORS FROM 4"TO 5" CROSSOVER TO HWDP j RIH WITH 5"HWDP FROM 4,445'TO 4,724'MD 23:30 - 00:00 0.50 CASING P INTI CHANGE ELEVATORS FROM 5"BACK TO 4" MAKE UP CROSSOVER FROM 6-5/8"REG TO 4"XT-39 AND 5'DRILLPIPE PUP CROSSOVER TO DRILL COLLARS I i RIH WITH 8"DRILL COLLARS FROM 4,724 TO 4784'MD -SINGLE IN FROM PIPE SHED 5/6/2011 00:00 - 02:00 2.00 CASING P INTI CONTINUE TO RIH WITH 9-5/8"LINER FROM 4,784'TO 5,182'MD -SINGLE IN 8"DRILL COLLARS 02:00 - 02:30 0.50 CASING P INTI CHANGE ELEVATORS FROM 4"TO 5" RIH WITH 1 STAND 5"HWDP FROM 5,182'TO 5,278'MD 02:30 - 03:30 1.00 CASING P INTI CHANGE ELEVATORS FROM 5"BACK TO 4" WASH DOWN LAST 2 STANDS 4"DRILLPIPE FROM 5,278"TO 5,465'MD PICK UP 15'DRILLPIPE PUP JOINT AND TAG TD AT MAKE UP CEMENT HEAD TO DRILLPIPE Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 13 of 22 Uperation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 04:30 1.00 r CASING P INTI j BLOW DOWN TOP DRIVE INSTALL CROSSOVER AND PUP IN TOP OF LINER CEMENT HEAD PICK UP CEMENT HEAD HOOK UP 90 AND 20'CEMENT HOSE EXTENSION MAKE UP CROSSOVER AND PUP IN BOTTOM OF CEMENT HEAD MAKE UP ASSEMBLY TO DRILLSTRING WASH DOWN AND TAG TD AT 5,467'MD -3 BPM,150 PSI -SLACKED OFF 20K AND OBSERVED PRESSURE INCREASE CONFIRMING TAG TD PUW 250K,SOW 155K HELD D1 KICK WHILE TRIPPING DRILL 04:30 - 09:00 4.50 CASING P INT1 PICK UP TO STRING WEIGHT+2' CIRCULATE AND CONDITION MUD -3 BPM,150 PSI -20'RECIPROCATION -STAGE UP RATE IN 1 BPM INCREMENTS TO FINAL CIRCULATING RATE -8 BPM,520 PSI WHILE CONDITIONING MUD, HOLD CEMENTING PJSM WITH ALL PARTIES INVOLVED Printed 6/6/2011 1:32:37PM Oporth America -ALASKA- BP Page 14 of 22 eration Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project:Prudhoe Bay Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:OOAM Rig Release: 5/22/2011 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth' Phase Description of Operations N't~ (hr) (ft) L 09:00 - 11:30 2.50 CEMT P INTI CEMENT 9-5/8"LINER WITH RECIPROCATION ,' 0\AS FOLLOWS: � 08:30 START BATCH MIXING 10.0 PPG MUD �� PUSH II 08:50 STOP CIRCULATING. LINE UP SLB CEMENTERS TO WELL 09:00 PUMP 47 BBL 10.0 PPG MUD PUSH II AT 4.0 BPM,195 PSI.CLOSE LOWER TIW AT END OF MUD PUSH 09:15 TEST LINES AGAINST LOWER TIW TO 4,500 PSI-GOOD. OPEN LOWER TIW 09:20 START FIRST TUB OF 11.0 PPG LITECRETE CEMENT • 09:40 PUMP 91 BBL 11.0 PPG LEAD CEMENT lAWAY AT 6.5 BPM -11.0 PPG LITECRETE -6.5 BPM,450 PSI TREATING PRESSURE -MIXING CEMENT ON-THE-FLY -RECIPRQCATF STRING 20'STRC)KFS.. 09:50 START MIXING 15.8 PPG G CEMENT 09:56 SWITH TO TAIL AND PUMP 207 BBL 15.8 PPG TAIL CEMENT AWAY AT 6.4 BPM - 15.8 PPG CLASS G -6.4 BPM,270 PSI TREATING PRESSURE -MIXING CEMENT ON-THE-FLY -RECIPROCATE STRING 20'STROKES 10:32 STOP PUMPING CEMENT 110:37 DROP DART-POSITIVE INDICATION DART LEFT CEMENT HEAD CHASE DART WITH 10 BBLS CLEANUP 1 WATER FROM CEMENT TRUCK 1 10:40 BEGIN DISPLACEMENT WITH RIG j PUMPS i-DISPLACE WITH 9.4 PPG LSND MUD !-3.5 BPM,50 PSI 10:44 PLUG LATCH 97 STROKES INTO DISPLACEMENT -PRESSURE SPIKED TO 1,400 PSI AT , 'LATCH-UP,SETTING FLEX-LOCK HANGER -UNABLE TO RECIPROCATE LINER 10:50 INCREASE DISPLACEMENT RATE TO 8 'BPM,790 PSI 11:15 DROP RATE TO 3 BPM FOR PLUG BUMP 11:17 PLUG BUMP AT 2,515 STROKES(264 I BBL DISPLACED); CALCULATED DISPLACEMENT WAS 267 BBLS INCREASE PRESSURE TO 4,000 PSI,SLACK OFF TO 60K TO CONFIRM LINER HANGER IS ISET BLEED OFF PRESSURE AND CHECK FLOATS -FLOATS HOLDING PICK UP 8'TO EXPOSE DOGS IN RUNNING TOOL SLACK OFF 75K TO SET LINER TOP PACKER -PICK UP AND SLACK OFF WITH ROTATION TO CONFIRM PACKER SET FULL RETURNS THROUGHOUT JOB WHILE ', RECIPROCATING LINER WITH 15'STROKES Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 15 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay ' Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) CEMENT IN PLACE AT 11:17 CEMENT PUMPED: 90.7 BBLS 11.0 PPG LITECRETE;276 SKS @ 1.87 CUFT/SK 206.8 BBLS 15.8 CLASS G;993 SKS @ 1.17 CUFT/SK -UCA TEST SHOWS COMPRESSIVE STRENGTH AFTER 16 HRS AT 1000PSI i 11:30 - 12:30 1.00 i CEMT P INTI CIRCULATE BOTTOMS-UP 20 BPM,250 PSI -RECOVERED 300 BBLS CEMENT CONTAMINATED MUD 12:30 - 13:00 0.50 CEMT P . INTI LAY DOWN LINER CEMENT HEAD 13:00 - 15:00 2.00 CEMT P INTI CONTINUE CIRCULATING WITH LINER RUNNING TOOL ABOVE LINER -20 BPM,480 PSI -PUW 139K,SOW 135K -RECIPROCATE STRING FULL STAND WHILE ` CIRCULATING 15:00 - 16:00 1.00 CEMT P INTI STAND BACK 2 STANDS 4"DRILLPIPE CHANGE ELEVATORS FROM 4"TO 5" STAND BACK 1 STAND 5"HWDP 16:00 - 16:30 0.50 CEMT P INTI PUMP DRY JOB MAKE UP 5"FOSV TO CROSSOVER FOR 8" DRILL COLLARS WHILE PUMPING DRY JOB 16:30 - 18:00 1.50 CEMT P INTI LAY DOWN 8"DRILL COLLARS 18:00 - 19:30 1.50 CEMT P INTI STAND BACK 3 STANDS 5"HWDP CHANGE ELEVATORS FROM 5"TO 4" POOH WITH REMAINING 4"DRILLPIPE TO LINER RUNNING TOOL -RACK BACK STANDS IN DERRICK 19:30 - 20:30 1.00 CEMT P INTI MAKE SERVICE BREAKS ON LINER RUNNING TOOL AND LAY DOWN SAME -DOG SUB SHEARED LAY DOWN CROSSOVERS USED IN DRILLSTRING 20:30 - 22:30 2.00 BOPSUR P INTI MAKE UP STACK WASHER AND FLUSH OUT STACK PUMP THROUGH CHOKE AND KILL LINES FUNCTION ALL RAMS AND ANNULAR IN BOP • STACK 22:30 - 23:00 0.50 WHSUR P INTI DRAIN BOP STACK PULL WEAR BUSHING AND MOUSEHOLE 23:00 - 00:00 1.00 i BOPSUR P r INTI CHANGE OUT UPPER RAMS FROM 9-5/8" 5/7/2011 00:00 - 00:30 0.50 BOPSUR P INTI NISH CHANGING UPPER RAMS FROM 9-5/8" FIXED TO 3-1/2"X 6"VBR 00:30 01:30 1.00 BOPSUR P INTI RIG UP TEST EQUIPMENT TEST 3-1/2"X 6"VBR UPPER RAMS -TEST CONDUCTED WITH 4"TEST JOINT -250 PSI LOW,4,000 PSI HIGH -5 MINUTES EACH TEST -CHART BOTH TESTS -AOGCC INSPECTOR BOB NOBLE WAIVED WITNESS OF RAM TEST RIG DOWN TEST EQUIPMENT Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 16 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date:5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. •UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT ' NPT Depth Phase ; Description of Operations (hr) (ft) 01:30 - 02:00 0.50 WHSUR P 1 INTI INSTALL WEAR BUSHING 02:00 - 06:00 4.00 CASING P I 1 INTI MAKE UP MULESHOE AND 3-1/2"IF PIN X 4" XT-39 CROSSOVER SINGLE IN 4"DRILLPIPE FROM PIPE SHED TO 3,072'MD -BUILDING STANDS TO TD WELL WHILE WAITING ON CEMENT _ _ _ _9.5PPGMUDINHOLE 06:00 - 10:00 4.00 CASING I P 1 INTI CIRCULATE AND CONDITION MUD -STAGE UP PUMPS TO MAX RATE -20 BPM,1,700 PSI -100 RPM,TQ OK -RECIPROCATE FULL STAND DURING CIRCULATION -FINAL MUD WT IN AND OUT:9.3 PPG 10:00 - 11:30 , 1.50 CASING P T INTI POOH WITH 4"DRILLPIPE FROM 3,072'TO SURFACE ' -RACK BACK DRILLPIPE 11:30 - 12:30 1.00 CASING P INTI CLEAN AND CLEAR RIG FLOOR OF TOOLS RIG UP TO TEST CASING 12:30 - 14:00 1.50 � CASING P INTI CLOSE BLIND/SHEAR RAMS 4 \ TEST 13-3/8"CASING AND 9-5/8"LINER \ I -TEST 250 PSI LOW FOR 5 MINUTES TEST 3,500 PSI HIGH FOR 30 MINUTES • ' -RECORD BOTH TESTS ON CHART I I -8 BBLS PUMPED TO REACH TEST I PRESSURE I-LOST 30 PSI IN FIRST 15 MINUTES -LOST 10 PSI IN SECOND 15 MINUTES I-RECOVERED 8 BBLS AFTER PRESSURE I• , TEST RIG DOWN TESTING EQUIPMENT BLOW DOWN CHOKE MANIFOLD,CHOKE, _ ___L AND KILL LINES 14:00 15:30 1 1.50 CASING P INTI i PICK UP AND MAKE UP RTTS ASSEMBLY PER I HALLIBURTON REP AS FOLLOWS: !-5"MULESHOE -CROSSOVER PUP -CROSSOVER PUP -12-1/4"NON-MAG INTEGRAL BIT STABILIZER (TO NO-GO ON LINER TOP) -NON-MAG BOTTLENECK CROSSOVER PUP -HALLIBURTON RTTS PACKER I -HALLIBURTON RTTS CIRCULATING VALVE -HANDLING PUP ' -1 STAND NON-MAG DRILL COLLARS -4 STANDS 5"HWDP -CROSSOVER TO DRILLPIPE , TOTAL BHA LENGTH:4.94.97' 15:30 17:00 1.50 CASING P INTI CHANGE ELEVATORS FROM 5"TO 4" RIH WITH RTTS ASSEMBLY FROM 495'TO 2,143'MD -TAGGED UP ON LINER TOP AT 2,143__'MD 17:00 - 18:00 I 1.00 CASING P I INTI CIRCULATE SURFACE-TO-SURFACE ! I-10 BPM,420 PSI RECIPROCATE STRING FULL STAND -OBTAIN SLOW PUMP RATES AT END OF CIRCULATION Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 17 of 22 Uperation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 20:00 2.00 i CASING P i INTI ILAY DOWN TOP JOINT OF DRILLPIPE STAND PICK UP FULL-OPENING SAFETY VALVE (FOSV), SIDE-ENTRY PUMP-IN SUB,AND 10' DRILLPIPE PUP JOINT AND MAKE UP TO DRILLSTRING I SET RTTS AT 2,116' -CENTER OF ELEMENT DEPTH OPEN CIRCULATING VALVE 20:00 21:00 1.00 CASING P INTI CLOSE TOP•R MS LINE UP AND REVERSE CIRCULATE THROUGH CIRCULATING VALVE,TAKING RETURNS THROUGH CHOKE MANIFOLD • -OBTAIN SLOW PUMP RATES 21:00 - 22:00 1.00 CASING P INTI OPEN TOP RAMS CLOSE CIRCULATING VALVE CLOSE TOP RAMS LINE UP AND PRESSURE TEST BACKSIDE TO ' 11,000 PSI FOR 5 MINUTES -CHART TEST I OPEN TOP RAMS 22:00 - 23:00 1.00 CASING P i INTI 'OPEN CIRCULATING VALVE LINE UP LITTLE RED HOT OIL TRUCK TO SIDE ENTRY PUMP-IN SUB • • CLOSE FOSV AND TEST LITTLE RED LINES TO 2,000 PSI OPEN FOSV AND PUMP 23 BBLS 60 DEGREEE 1 DIESEL DOWN DRILLPIPE AT 3 BPM I ' ' DIESEL IN PLACE AT 23:04 -FINAL PRESSURE WHEN SHUT IN:255 PSI 23:00 - 23:30 0.50 CASING 1 P j INTI 1CLOSE CIRCULATING VALVE BLEED OFF DRILLPIPE PRESSURE TO LITTLE RED HOT OIL PUMP TRUCK CLOSE FOSV DRAIN DIESEL LINES BACK TO LITTLE RED PUMP TRUCK REMOVE LINE FROM SIDE-ENTRY PUMP-IN i j SUB AND HOOK UP PRESSURE SENSORS FOR DIGITAL GAUGE AND CHART RECORDER 23:30 - 00:00 0.50 CASING P INTI OPEN FOSV AND BEGIN NEGATIVE PRESSURE TEST -30 MINUTE TEST -CHART TEST WITH CHART RECORDER -RECORD PRESSURE FROM DIGITAL GAUGE EVERY 2 MINUTES -0 PRESSURE BUILD-UP DURING TEST RIG DOWN TEST CHART Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 18 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date:5/11/2011 X3-00W92-C(4,355,681.00) i i Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations ! (hr) (ft) 5/8/2011 00:00 - 00:30 0.50 CASING P INTI OPEN CIRC VALVE AND CLOSE UPPER RAMS LINE UP AND REVERSE CIRCULATE DIESEL FROM DRILLPIPE I -TAKE RETURNS THROUGH SIDE-ENTRY PUMP-IN SUB TO CHOKE MANIFOLD AND OUT TO CUTTINGS BOX AT ROCK WASHER -CAUGHT PRESSURE 10 BBLS INTO I CIRCULATING i -3 BPM,150 PSI • I -DIESEL/MUD INTERFACE 35 BBLS INTO 1 I CIRCULATING , -CLEAN MUD AT TANK 390 BBLS INTO CIRCULATING ! i SHUT DOWN AND OPEN RAMS i FLOW CHECK -NO FLOW 00:30 - 01:00 0.50 CASING P INTI RELEASE RTTS AND ALLOW ELEMENTS TO RELAX RIG DOWN CIRCULATING HOSE BLOW DOWN CHOKE MANIFOLD,CHOKE AND KILL LINES , LAY DOWN DRILLPIPE PUP,SIDE-ENTRY PUMP-IN SUB,AND FOSV 01:00 - 02:00 1.00 CASING P INTI PICK UP SINGLE JOINT AND MAKE UP TO DRILLSTRING LOCK CIRCULATING VALVE IN OPEN i POSITION CIRCULATE SURFACE-TO-SURFACE I-10 BPM,430 PSI '.. '... ! I -FINAL MUD WT AT END OF CIRCULATION: I 9.3 PPG IN AND OUT -- - - -I-- - — - --_-- -- --- 02:00 - 03:00 , CASING P 1 1.00 INTI POOH WITH RTTS ASSEMBLY -STAND BACK 4"DRILLPIPE 03:00 - 04:30 !, 1.50 CASING P 7 INTI CHANGE ELEVATORS FROM 4"TO 5" STAND BACK 5"HWDP AND 6-3/4"NON-MAG DRILL COLLARS PULL RTTS ASSEMBLY TO SURFACE I BREAK OUT AND LAY DOWN MULESHOE, ! CROSSOVERS,STABILIZER AND ! BOTTLENECK CROSSOVER I LAY DOWN RTTS ASSEMBLY 04:30 - 05:30 1.00 CASING ! P INTI CLEAN AND CLEAR RIG FLOOR 05:30 - 06:00 0.50 i DRILL P INTI MOBILIZE 8-3/4"BHA COMPONENTS TO RIG FLOOR 06:00 - 08:30 2.50 DRILL P INTI MAKE UP 8-3/4"PRODUCTION BHA PER SCHLUMBERGER AS FOLLOWS: -8-3/4"HUGHES QD506X PDC BIT • I -SCHLUMBERGER 675M MUD MOTOR;1.5 DEGREE BEND I -ARC6 -MWD •-ADN6 -2 NON-MAG DRILL COLLARS -8-3/4"INTEGRAL BLADE STABILIZER , I-NON-MAG DILL COLLAR 1 5"X 3"HWDP JOINT -SMITH HYDRA JAR - 135"X3"HWDP JOINTS -4-1/2"IF PIN X 4"XT-39 BOX CROSSOVER TOTAL BHA LENGTH:656.55' Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 19 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code 1, NPT ' NPT Depth I Phase Description of Operations (hr) - _ (ft) 08:30 - 09:00 0.50 DRILL P INTI SHALLOW TEST MWD 09:00 - 12.00 3.00 DRILL P I INTI RIH WITH BHA FROM 657'TO 5,200 MD i l -SINGLE IN FIRST 36 JOINTS 4"DRILLPIPE (12 STANDS) -FILL PIPE EVERY 20 STANDS -INSTALL GHOST REAMER AT 2,120'MD I HELD D1 KICK WHILE TRIPPING DRILL 1 12:00 - 15:00 3.00 DRILL P INTI SLIP AND CUT DRILLING LINE SERVICE TOP DRIVE AND DRAWWORKS_ 15:00 - 15:30 0.50 DRILL P INTI OBTAIN SLOW PUMP RATES PRIOR TO DRILLING OUT SHOETRACK I WASH DOWN FROM 5,200'TO 5,375'AND TAG ON CEMENT -PUW 155K,SOW 83K, ROT 106K I . -400 GPM,1,700 PSI ' -40 RPM,TQ 7.5K 15:30 - 17:00 1.50 DRILL P INTI TAG LANDING COLLAR AT 5,390'MD CONTROL DRILL FROM 5,390'TO 5,462'MD -400 GPM,17,00 PSI I -40 RPM,TQ 7.5K 17:00 - 20:00 3.00 1 DRILL P INTI PJSM ON MUD SWAP 1 , I EMPTY PITS 1 AND 2 FOR FLUID I DISPLACEMENT i DISPLACE WELL FROM 9.3 PPG LSND TO 9.0 PPG LSND DRILLING FLUID -35 BBLS WATER SPACER FOLLOWED BY 40 BBL HIGH-VISCOSITY SWEEP PRIOR TO 9.0 PPG LSND DRILLING FLUID I -6 BPM,600 PSI -40 RPM,TQ 7.5K i -RECIPROCATE FULL STAND DURING i DISPLACEMENT i -PUMPED 550 BBLS 9.0 PPG LSND FOR CLEAN MUD IN AND OUT -FINAL MUD WT IN AND OUT:9.0 PPG 20:00 - 21:30 1.50 DRILL P INTI ,CLEAN PITS 1 AND 2.LOAD SAME PITS WITH 19.0 PPG LSND I HELD UNANNOUNCED D2 KICK WHILE DRILLING DRILL 21:30 - 22:00 0.50 DRILL P INTI OBTAIN SLOW PUMP RATES WITH NEW DRILLING FLUID DRILL OUT FROM 5,462'TO 5,490'MD -PUW 155K,SOW 83K, ROT 106K -500 GPM,1,430 PSI -40 RPM,TQ 7K -10K WOB -9.0 PPG MUD WT IN AND OUT 22:00 - 23:00 1.00 DRILL P INTI CIRCULATE BOTTOMS-UP -500 GPM,1,430 PSI -40 RPM,TQ 7K -RECIPROCATE DRILLSTRING DURING CIRCULATION -9.0 PPG MUD WT IN AND OUT Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 20 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date:5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT !; NPT Depth i Phase Description of Operations (hr) - (ft) 23:00 00:00 1.00 DRILL P INT1 1 POOH FROM 5,490'TO 5,411'MD 1 RIG UP AND PERFORM LEAKOFF TEST -9-5/8'.SHOE AT 5,467'MD,3,419'TVD I -9.0 PPG MUD WT IN HOLE -PUMPED TOTAL OF 2.3 BBLS I -PRESSURE DEVIATED AT 580 PSI I -SHUT IN AND MONITOR FOR 10 MINUTES BLED BACK 1.5 BBLS AFTER TEST -EMW FROM LEAKOFF TEST: 12.26 -CHART SENT TO ODE WILSON QUINTA FOR APPROVAL PRIOR TO PROCEEDING I -KICK TOLERANCE AT TD: 57.4 BBLS;KICK TOLERANCE FACTOR:2.014 5/9/2011 00:00 - 01:00 1.00 DRILL P INTI RIG DOWN TEST EQUIPMENT r E-MAIL CONFIRMATION OF LEAKOFF TEST RECEIVED AT 00:57 01:00 - 01:30 0.50 DRILL P INTI RIH TO 5,480'MD I OBTAIN ECD BASELINE i -580 GPM,1,750 PSI -BASELINES AT 0 RPM AND 100 RPM 01:30 - 12:00 10.50 I DRILL P I PROD1 DIRECTIONALLY DRILL AHEAD FROM 5,490' TO 6,949'MD -PUW 156K,SOW 95K, ROT 115K -580 GPM,2,520 PSI ON,2,350 PSI OFF 120 RPM,TQ 9K ON,9K OFF ' 1-20K WOB I-MUD WT IN 9.0 PPG,MUD WT OUT 9.0 PPG I- CALCULATED ECD:9.57 PPG,ACTUAL ECD: 9.80 PPG ART:5.64,AST:0.47,ADT:6.11 HELD SPILL DRILL 12:00 - 00:00 12.00 DRILL P j PROD1 ,DIRECTIONALLY DRILL AHEAD FROM 6,949' � TO 8,020'MD ;-PUW 180K,SOW 95K, ROT 120K 1 -580 GPM,3,190 PSI ON,2,990 PSI OFF -120 RPM,TQ 11K ON,10K OFF '-15KWOB -MUD WT IN 9.1 PPG,MUD WT OUT 9.2 PPG -CALCULATED ECD: 10.01 PPG,ACTUAL ECD: 10.15 PPG I ART:6.90,AST: 1.01,ADT: 7.91 ADT FOR LAST 24 HRS: 14.02 HELD SPILL DRILL 5/10/2011 00:00 - 12:00 12.00 DRILL P PROD1 DIRECTIONALLY DRILL AHEAD FROM 8,020' TO 8,856'MD -PUW 185K,SOW 95K, ROT 128K -580 GPM,3,370 PSI ON,3,190 PSI OFF -110 RPM,TQ 12K ON,12K OFF -20K WOB -MUD WT IN 9.2 PPG, MUD WT OUT 9.2 PPG -CALCULATED ECD: 10.00 PPG,ACTUAL ECD: 10.06 PPG ART:2.32,AST:4.01,ADT: 5.33 HELD UNANNOUNCED D2 KICK WHILE DRILLING DRILL Printed 6/6/2011 1:32:37PM North America -ALASKA- BP Page 21 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) I Project: Prudhoe Bay ' Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL©81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth ' Phase Description of Operations (hr) (ft) 12:00 - 21:30 9.50 DRILL P PROD1 DIRECTIONALLY DRILL AHEAD FROM 8,856' TO 9,742'MD -PUW 200K,SOW 110K, ROT 140K �� -580 GPM,3,750 PSI ON,3,640 PSI OFF -110 RPM,TQ 12K ON,12K OFF -25K WOB -MUD WT IN 9.3 PPG,MUD WT OUT 9.3 PPG • -CALCULATED ECD:9.97 PPG,ACTUAL ECD: 10.32 PPG • -TD CALLED BY WELLSITE GEO,TOWN GEO, AND WSL ART:4.69,AST:2.11,ADT:6.80 ADT FOR LAST 24 HRS: 12.13 21:30 - 22:00 0.50 DRILL P PROD1 CIRCULATE ANNULAR OPENHOLE VOLUME -580 GPM,3,620 PSI 110 RPM,TQ,12K -RECIPROCATE FULL STAND -9.3 PPG MUD WT IN AND OUT • • FLOWCHECK WELL -NO FLOW 22:30 - 23:00 0.50 DRILL P I, ! PROD1 BACKREAM FROM 9,742'to 9,250'MD -580 GPM,3,590 PSI -110 RPM,TQ 13K -MUD WT IN 9.3 PPG,MUD WT OUT,9.4 PPG i 23:00 - 00:00 1.00 DRILL P PROD1 MADD PASS FROM 9,250'TO 9,135'MD -580 GPM,3,590 PSI i -110 RPM,TQ 13K -MUD WT IN 9.3 PPG,MUD WT OUT 9.4 PPG I -PULLING SPEED 300-330 FT/HR TO ACHIEVE DESIRED DATA DENSITY FOR GEOLOGIST 5/11/2011 00:00 - 03:30 3.50 DRILL P PROD1 CONTINUE MADD PASS FROM 9,135'TO 8,400' MD • -580 GPM,3,350 PSI ' -110 RPM,TQ 11K -MUD WT IN 9.3 PPG, MUD WT OUT 9.4 PPG -PULLING SPEED 300-330 FT/HR TO ACHIEVE DESIRED DATA DENSITY FOR GEOLOGIST 03:30 - 05:00 1.50 DRILL P PROD1 BACKREAM FROM 8,400'TO 7,555'MD -580 GPM,3,350 PSI 110RPM,TQ11K 9.3 PPG MUD WT IN AND OUT I -NO ROTATION LAST STAND OUT AS GHOST REAMER PASSES 9-5/8"SHOE 05:00 - 06:00 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP -580 GPM,3,190 PSI -110 RPM, TQ 10K -RECIPROCATE STRING FULL STAND DURING CIRCULATION -FINAL MUD WT IN AND OUT:9.4 PPG 06:00 - 07:30 1.50 DRILL P PROD1 FLOW CHECK WELL -NO FLOW ' RIH FROM 7,555'TO 9,742'MD 07:30 - 10:00 2.50 DRILL P PROD1 CIRCULATE 3 BOTTOMS-UP TO CONDITION MUD -580 GPM,3,610 PSI - 120 RPM,TQ 11K I -FINAL PARAMETERS: PUW 195K,SOW 100K -FINAL MUD WT IN AND OUT 9.3 PPG I HELD FIRE DRILL Printed 6/6/2011 1:32:37PM '"rth America -ALASKA- BP Page 22 of 22 Operation Summary Report Common Well Name:W-223 AFE No Event Type: DRL-ONSHORE(DON) Start Date:4/26/2011 End Date: 5/11/2011 X3-00W92-C(4,355,681.00) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 1 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To I Hrs ' Task Code NPT NPT Depth Phase , Description of Operations (hr) (ft) 110:00 - 14:00 1 4.00 1 DRILL P i PROD1 j POOH ON ELEVATORS FROM 9,742'TO 5,468' MD ' -PULL FIRST 5 STANDS WITH PUMP OFF TO CHECK FOR SWABBING 14:00 - 15:30 1.50 DRILL i P PROD1 FLOW CHECK WELL -FLOW CHECK WITH BIT INSIDE 9-5/8"LINER SHOE -NO FLOW CONTINUE POOH FROM 5,468'TO 2,14r MD 15:30 - 16:00 0.50 DRILL P PROD1 BACKREAM AS BIT PASSES 9-5/8"LINER TOP -600 GPM,1,700 PSI -120 RPM,TQ 2K -CIRCULATE 13-3/8"ANNULAR VOLUME ij WHILE PASSING THROUGH 9-5/8"LINER TOP '--NO ADDITIONAL CUTTINGS OBSERVED AT SHAKERS 16:00 - 17:30 1.50 DRILL P PROD1 BLOW DOWN TOP DRIVE POOH FROM 2,147'TO 656'MD I FLOW CHECK WELL -FLOW CHECK BEFORE PULLING BHA THROUGH BOP STACK I -NO FLOW i HELD D1 KICK WHILE TRIPPING DRILL 17:30 - 18:00 0.50 ! DRILL P PROD1 RIG DOWN 4"HANDLING EQUIPMENT RIG UP 5"HANDLING EQUIPMENT TO LAY - DOWN BHA T — 18:00 - 21:00 3.00 DRILL, 7 P PROD1 LAY DOWN 5"HWDP,JARS,6-3/4"DRILL COLLARS 'REMOVE RADIOACTIVE SOURCES FROM I ,MWD I LAY DOWN MWD TOOLS !BREAK BIT FROM MUD MOTOR • I LAY DOWN MUD MOTOR ;BIT GRADE:3 3-CT-A-X-I-BT-TD BHA LD. END OF DON PHASE.MOVE TO CON PHASE Printed 6/6/2011 1:32:36PM North America -ALASKA- BP Page 1 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) I Start Date: 5/5/2011 End Date: 5/22/2011 X3-00W92-C Project:Prudhoe Bay Site:PB W Pad Rig Name/No.:DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code i NPT NPT Depth Phase Description of Operations ' (hr) (ft) 5/11/2011 21:00 - 21:30 0.50 CASING P RUNPRD LAY DOWN REMAINING BHA COMPONENTS CLEAN AND CLEAR RIG FLOOR 21:30 - 22:00 0.50 WHSUR P RUNPRD DRAIN STACK PULL WEAR BUSHING 22:00 - 23:00 1.00 BOPSUR P RUNPRD CHANGE UPPER RAMS FROM 3-1/2"X 6"VBR TO 7"FIXED 23:00 - 00:00 1.00 BOPSUR P RUNPRD RIG UP TEST EQUIPMENT INSTALL TEST PLUG AND 7"TEST JOINT TEST 7"FIXED RAMS TO 250 PSI LOW,4,000 PSI HIGH FOR 5 MINUTES EACH -CHART TEST -TEST WITNESSED BY DOYON TP MIKE SMITH, DOYON DRILLER ANDY CARLO,AND BP WSL FRANK ROACH -AOGCC INSPECTOR JOHN CRISP WAIVED WITNESS OF RAM TEST 5/12/2011 00:00 - 01:00 1.00 BOPSUR P RUNPRD RIG DOWN TEST EQUIPMENT,7"TEST JOINT AND TEST PLUG 01:00 - 02:00 1.00 WHSUR ' P ,j RUNPRD BLOW DOWN LINES,REMOVE SHORT BALES FROM TOP DRIVE. PICK UP LANDING JOINT WITH 7"HANGER. LAND HANGER IN WELLHEAD AND MARK LANDING JOINT 02:00 - 06:00 4.00 CASING P j RUNPRD RIG UP TO RUN 7"CASING 06:00 - 18:00 12.00 CASING P r RUNPRD RUN 7"26#L-80 VAM TOP HC CASING FROM SURFACE TO 5,450'MD -TORQUE TURN ALL CONNECTIONS -BAKERLOK SHOETRACK -CHECK FLOATS AFTER SHOETRACK ASSEMBLED --FLOATS HOLDING -FILL EVERY JOINT -BREAK CIRCULATION AND OBTAIN PICKUP IAND SLACKOFF WEIGHTS EVERY 10 JOINTS HELD D1 KICK WHILE TRIPPING DRILL 18:00 - 19:00 1.00 CASING P RUNPRD CIRCULATE BOTTOMS-UP AT 5,450'MD -9-5/8"SHOE AT 5,467'MD -STAGE UP PUMPS TO 8 BPM,740 PSI SHAKERS CLEAN AT BOTTOMS-UP 19:00 - 21:30 ! 2.50 CASING P RUNPRD CONTINUE TO RUNT'26#L-80 VAM TOP HC CASING FROM 5,450'TO 6,766'MD -TORQUE TURN ALL CONNECTIONS -FILL EVERY JOINT -BREAK CIRCULATION AND OBTAIN PICKUP AND SLACKOFF WEIGHTS EVERY 10 JOINTS -OBSERVING INCREASED DRAG AT 6,313'(20 JTS OUTSIDE 9-5/8"SHOE) -INCREASED CIRCULATION FREQUENCY TO EVERY 5 JOINTS -STILL OBSERVING INCREASED DRAG AT 6,766'MD Printed 6/6/2011 1:33:15PM '3rth America -ALASKA- BP Page 2 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/5/2011 End Date: 5/22/2011 X3-00W92-C Project: Prudhoe Bay , Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 23:00 1.50 I CASING P RUNPRD CIRCULATE BOTTOMS-UP ' -STAGE UP RATE TO 5.5 BPM,550 PSI I i -FINE SAND ACROSS SHAKERS AT BOTTOMS-UP -VOLUME CLEANED UP 40 BBLS PAST BOTTOMS-UP 23:00 - 00:00 1.00 CASING P RUNPRD CONTINUE TO RUN 7"26#L-80 VAM TOP HC CASING FROM 6,766'TO 6,973'MD -TORQUE TURN ALL CONNECTIONS I -CIRCULATE DOWN EVERY JOINT --5 BPM,550 PSI —r 5/13/2011 00:00 - 10:00 10.00 CASING P RUNPRD CONTINUE TO RUN 7"26#L-80 VAM TOP HC CASING FROM 6,973'TO 9,699'MD -TORQUE TURN ALL CONNECTIONS , -CIRCULATE DOWN EVERY JOINT TO 7,963' • MD ! --5 BPM,550 PSI -CIRCULATE DOWN EVERY 5TH JOINT FROM I7,963'TO 9,699'MD I ! MAKE UP FMC MANDREL HANGER WITH LANDING JOINT LAND HANGER IN SPOOL 1_____.—___—_ • -FLOAT SHOE AT 9,732'MD 10:00 - 10:30 j 0.50 CEMT i P RUNPRD MAKE UP CEMENT HEAD TO LANDING JOINT 10:30 13:30 3.00 CEMT P ' RUNPRD BREAK CIRCULATION :STAGE PUMPS UP TO CONDITION MUD FOR CEMENT JOB I -7 BPM,650 PSI _— - -RECIPROCATE CASING STRING Printed 6/6/2011 1:33:15PM Orth America -ALASKA- BP Page 3 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/5/2011 End Date: 5/22/2011 X3-00W92-C Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release:5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 16:30 3.00 CEMT P RUNPRD CEMENT T'PRODUCTION CASING WITH —RECIPROCATION AS FOLLOWS: '..f,1 • 12:36 HOLD PRE-JOB SAFETY MEETING WITH (, RIG CREW,SCHLUMBERGER CEMENT CREW 0 AND CH2M HILL TRUCK DRIVERS 13:01 START BATCH MIXING 15.8 PPG G CEMENT 13:32 TAIL CEMENT TO WEIGHT I 13:36 BATCH MIX 10.0 PPG MUD PUSH II • 13:40 PUMP 28 BBLS 10.0 PPG MUD PUSH II AT 3 BPM,310 PSI • 13:55 TEST LINES TO 4,500 PSI-GOOD 14:02 START BATCH MIXING LITECRETE LEAD CEMENT 14:03 LEAD CEMENT TO WEIGHT 14:04 DROP BOTTOM PLUG.FLAG INDICATED PLUG DROPPED 14:05 PUMP 79.2 BBL 11.0 PPG LITECRETE • LEAD CEMENT WITH GASBLOK AWAY AT 5.8 BPM -11.0 PPG LITECRETE WITH GASBLOK -5.8 BPM,423 PSI TREATING PRESSURE • 14:19 SWAP TO TAIL CEMENT PUMP 39.1 BBLS 15.8 PPG CLASS G TAIL CEMENT WITH GASBLOK AWAY AT 4.3 BPM -15.8 PPG CLASS G WITH GASBLOK • -4.3 BPM,480 PSI TREATING PRESSURE • 14:43 STOP PUMPING CEMENT • • 114:58 DROP TOP PLUG FLAG INDICATED • PLUG DROPPED 14:59 BEGIN DISPLACEMENT WITH RIG PUMP • DISPLACE WITH 9.2 PPG BRINE -PUMP 7 BPM,330 PSI -PARK HANGER IN WELLHEAD PROFILE AS TAIL ROUNDED SHOE SLOW PUMP RATE TO 5.0 BPM AFTER 2,665 STROKES -780 PSI DISPLACEMENT PRESSURE PRIOR TO DROPPING RATE SLOW PUMP RATE TO 4.0 BPM AT 3,150 STROKES -1,050 PSI DISPLACEMENT PRESSURE PRIOR TO DROPPING RATE UNABLE TO LAND HANGER IN WELLHEAD BOWL AT 3,400 STROKES UNABLE TO PULL UP -HANGER CATCHING ON BOP RAM CAVITY SLOW PUMP RATE TO 2.0 BPM AT 3,440 STROKES -1,460 PSI DISPLACEMENT PRESSURE PRIOR TO DROPPING RATE SLOW PUMP RATE TO 0.5 BPM AT 3,560 STROKES 16:17 PLUG BUMP AT 3,682 STROKES -PLUG BUMPED WITH 2,900 PSI BLEED OFF PRESSURE AND CHECK FLOATS -FLOATS HOLDING -CEMENT HEAD CROSSOVER LEAKING CEMENT IN PLACE AT 16:18 HRS CEMENT PUMPED: Printed 6/6/2011 1:33:15PM ''Nrth America -ALASKA- BP Page 4 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/5/2011 End Date: 5/22/2011 X3-00W92-C Project:Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) l -229 SX OF 11.0 PPG LITECRETE LEAD AT 7, , 1.94 CUFT/SK -187 SX OF 15.8 PPG CLASS G TAIL AT 1.17 CUFT/SK I i TOC 5440 FT PICKED AS PER ISOLATION '- _ SCANNER(USIT) 16:30 - 19:00 2.50 CEMT P ' RUNPRD RIG DOWN CEMENT HEAD AND CROSSOVER FROM LANDING JOINT RIG UP HEAD PIN TO LANDING JOINT PRESSURE TEST 7"CASING TO 250 PSI LOW, 4,000 PSI HIGH FOR 30 MINUTES ' -LOST 20 PSI IN FIRST 15 MINUTES -LOST 10 PSI IN SECOND 15 MINUTES 19:00 - 20:00 1.00 CEMT P RUNPRD CLOSE ANNULAR PREVENTOR AND PRESSURE UP ON 7"X 13-3/8"ANNULUS TO ESTABLISH OA INJECTIVITY -3 BPM,PRESSURE BREAK OVER AT 1,550 PSI -INJECTED ADDITIONAL 3 BBLS AFTER PRESSURE BROKE OVER -FINAL PRESSURE BEFORE SHUTTING DOWN: 1,280 PSI BLEED OFF PRESSURE AND OPEN ANNULAR PREVENTOR BLOW DOWN CHOKE AND KILL LINES I RIG UP TO MONITOR WELL 20:00 - 00:00 4.00 CEMT N SFAL RUNPRD I BEGIN MONITORING WELL FOR SETTING 7" ti, (CASING SLIPS I-MONITORING PROCESS PER SOP: ^i "PROCEDURE FOR SETTING CASING SLIPS S� I SON INTERMEDIATE AND PRODUCTION ;CASING" I-MONITOR TIME START:20:05 5/14/2011 i 00:00 - 08:00 8.00 CEMT N SFAL RUNPRD I CONTINUE MONITORING WELL FOR SETTING I7"CASING SLIPS 1-MONITORING PROCESS PER SOP: "PROCEDURE FOR SETTING CASING SLIPS ON INTERMEDIATE AND PRODUCTION CASING" CLEAN RIG FLOOR AND MOBILIZE . EQUIPMENT FOR SETTING SLIPS, RAM CHANGE,AND BOP TEST OPERATIONS 08:00 - 11:00 3.00 WHSUR N SFAL RUNPRD DRAIN BOP STACK AND BLOW DOWN LINES , NIPPLE DOWN BOP STACK AND TUBING ' SPOOL -LEAVE TUBING SPOOL ATTACHED TO ' I BOTTOM OF BOP STACK LIFT STACK TO SET 7"CASING SLIPS AND CUT 7"CASING 11:00 - 12:00 • 1.00 WHSUR N SFAL RUNPRD RIG UP TO SET CASING SLIPS AND PERFORM . WACHS CUT ON 7"CASING 12:00 - 13:00 1.00 WHSUR N SFAL RUNPRD CHECK CASING COLLAR LOCATION FOR CUT. MANDREL HANGER ABLE TO LAND ON SEAT AFTER NIPPLING DOWN TUBING SPOOL NOTIFY ANCHORAGE ENGINEERING AND OPERATIONS LEADS OF SITUATION ISET BOP AND TUBING SPOOL ON WELLHEAD AND NIPPLE UP Printed 6/6/2011 1:33:15PM '1rth America -ALASKA- BP Page 5 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type: COM-ONSHORE(CON) J Start Date:5/5/2011 End Date: 5/22/2011 X3-00W92-C Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 ' Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:WELL @81 90ft(above Mean Sea Level) Date From-To Hrs Task I Code NPT j NPT Depth I Phase Description of Operations (hr) ' I (ft) 13:00 - 15:30 2.50 WHSUR N I WAIT i RUNPRD MONITOR WELL WHILE WAITING ON ORDERS FROM ANCHORAGE ENGINEERING AND • OPERATIONS LEADS CHECK#1 MUD PUMP DRIVE CHAIN SPROCKET,CHANGE OUT BEARING ON CONVEYOR#1,AND INSTALL CHEMICAL PUMP IN HOPPER ROOM WHILE WAITING ON ORDERS 15:30 - 17:30 2.00 WHSUR N SFAL RUNPRD NIPPLE DOWN BOP STACK AND TUBING SPOOL -LEAVE TUBING SPOOL ATTACHED TO BOTTOM OF BOP STACK jPICK UP TO 285K HOOK LOAD • INSTALL 7"CASING SLIPS AND SLACK OFF 5K TO SET SLIPS IN WELLHEAD j -7"CASING LANDED IN WELLHEAD WITH 225K TENSION RIG UP WACHS CUTTER AND CUT 7"CASING BELOW TOP-MOST COUPLING • -CUT LENGTH 3.43' INCLUDING HANGER, PIN X PIN CROSSOVER,CASING COUPLING AND CASING BODY 17:30 - 19:00 : 1.50 WHSUR N ' SFAL RUNPRD INSTALL LOWER PACKOFF ON 7"CASING STUB IN WELLHEAD AND RUN IN LOCKDOWN SCREWS j 1 '-LOCKDOWN SCREWS TORQUED TO 450 FT-LBS INSTALL SECONDARY PACKOFF IN BOTTOM OF TUBING SPOOL • SET BOP AND TUBING SPOOL BACK ON WELLHEAD AND NIPPLE UP 19:00 - 20:30 1.50 WHSUR P RUNPRD INJECT PLASTIC PACKING IN PACKOFF VOID I TEST PACKOFF VOID AND FLANGE BREAK TO 4,300 PSI • -80%7"26#L-80 CASING COLLAPSE RATING • -TEST DURATION 30 MINUTES -TEST CHARTED BY FMC 20:30 - 23:00 2.50 BOPSUR P RUNPRD INSTALL TURNBUCKLES ON BOP STACK NIPPLE UP CHOKE LINE TO CHOKE HCR ON BOP STACK INSTALL RISER 23:00 - 00:00 1.00 WHSUR P RUNPRD HOOK UP INJECTION LINE IN CELLAR TO OA VALVE ATTEMPT TO INJECT DOWN OA -REACH 3,000 PSI HOLD PRESSURE FOR 5 MINUTES AND BLEED OFF ATTEMPT TO INJECT DOWN OA j-REACH 3,000 PSI • I 'HOLD PRESSURE FOR 5 MINUTES AND I BLEED OFF • ATTEMPT TO INJECT DOWN OA -REACH 4,000 PSI HOLD PRESSURE -PRESSURE BROKE OVER -2,330 PSI AFTER 1 MIN 30 SEC INJECT 5 BBLS LSND DOWN OA AT 3 BPM -MAX PRESSURE 2,550 PSI,2 BBLS INTO INJECTION -FINAL PRESSURE 2,060 PSI AT END OF INJECTION Printed 6/6/2011 1:33:15PM -1rth America -ALASKA- BP Page 6 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type: COM-ONSHORE(CON) : Start Date: 5/5/2011 End Date: 5/22/2011 X3-00W92-C Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM I Rig Release: 5/22/2011 Rig Contractor:DOYON DRILLING INC. 'UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth! Phase Description of Operations (hr) (ft) -1-- 5/15/2011 00:00 - 01:30 1.50 1 BOPSUR P RUNPRD CHANGE UPPER RAMS FROM 7"FIXED TO 3-1/2"X 6"VBR 01:30 - 03:00 1.50 : BOPSUR P RUNPRD RIG UP TO PERFORM BOPE TEST REMOVE RUNNING TOOL FROM 4"TEST JOINT AND INSTALL UPPER TEST PLUG SET TEST PLUG IN TUBING SPOOL FILL BOP STACK AND CHOKE MANIFOLD MOBILIZE CROSSOVERS NEEDED FOR 4-1/2" IF FOSV AND TO TEST TOP DRIVE WELL ! _ ICONTROLEQUIPMENT 03:00 - 10:00 7.00 1 BOPSUR P RUNPRD {TEST BOPS PER AQGCC/BP RFG$ 1 -CHART EACH TEST -5 MINUTES EACH TEST I -TEST ANNULAR WITH 3-1/2"TEST JOINT TO HI 250 PSI LOW 3 500 PSI GH 1 -TEST ALL CHOKE MANIFOLD VALVES,3-1/2" X 6"AND 2-7/8"X 5"VBR,3-1/2"IF,4"XT-39, 6-( AND 4-1/2"IF FOSV, IBOP, MANUAL IBOP TO 250 PSI LOW,4,000 PSI HIGH -TEST BOTH VBR WITH 3-1/2"AND 4"TEST JOINT -TEST ACCUMULATOR TEST WITNESSED BY TOOLPUSHERS MIKE SMITH AND BOBBY INGRAM, BP WSL FRANK ROACH AND BLAIR NEUFELD AOGCC INSPECTOR JOHN CRISP WAIVED ' I WITNESS , I !SIMOPS: FREEZE PROTECT OA !PRESSURE TEST LITTLE RED LINES TO 4,500 PSI PUMP 250 BBLS LSND MUD 1-3 BPM,1,100 PSI SWAP TO LITTLE RED !PUMP 250 BBLS 70 DEGREE DEAD CRUDE 'MOBILIZE PERF GUNS TO PIPE SHED FOR _ UPCOMING DPC PERF RUN 10:00 - 11:00 : 1.00 I BOPSUR P RUNPRD RIG DOWN BOP TESTING EQUIPMENT 11:00 - 13:00 2.00 PERFOB ! P : I OTHCMP MOBILIZE PERFORATING EQUIPMENT TO RIG FLOOR MAKE UP SAFETY JOINT CHANGE OUT ELEVATORS TO 3-1/2" 13:00 - 15:00 2.00 PERFOB P OTHCMP MAKE UP DPC PERF GUNS, FIRING HEAD, AND MWD HOLD D1 KICK WHILE TRIPPING DRILL -HOLD AAR AFTER DRILL TO DISCUSS LEARNINGS 15:00 - 16:00 1.00 PERFOB P OTHCMP CHANGE ELEVATORS FROM 3-1/2"TO 4" I BREAK OFF FOSV FROM SAFETY JOINT PICK UP 13 JTS 4"DRILLPIPE TO 726'MD -4 STANDS+ 1 SINGLE 16:00 - 21:00 ' 5.00 PERFOB P OTHCMP RIH ON 4"DRILLPIPE FROM DERRICK FROM 726'TO 1,284'MD FUNCTION TEST MWD TOOL 240 GPM,400 PSI -BRINE WT IN AND OUT:9.2 PPG -GOOD SIGNAL I CONTINUE TO RIH FROM 1,284'TO 9,571'MD Printed 6/6/2011 1:33:15PM .1rth America -ALASKA- BP Page 7 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/5/2011 End Date:5/22/2011 X3-00W92-C Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:OOAM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT i NPT Depth 1 Phase Description of Operations (hr) I _ (ft)__ 21:00 - 21:30 0.50 PERFOB 11 P 1 OTHCMP 1 PICK UP STAND 4"DRILLPIPE -PUW 165K,SOW 102K RIH AND TAG FLOAT COLLAR AT 9,645'MD 21:30 - 00:00 2.50 PERFOB I P 1 OTHCMP PICK UP TO DRILLPIPE CONNECTION AT 9,633'MD LOG FROM 9,633'MD TO 9,478'MD -245 GPM,1,040 PSI -9.2 PPG BRINE IN AND OUT -CORRELATE LOG PASS TO REAL-TIME MWD LOG FROM DRILLING RUN 5/16/2011 00:00 - 02:30 2.50 PERFOB P OTHCMP �RIH TO 9,633'MD LOG UP FROM 9,633'TO 9,390'MD TO CONFIRM LOG CORRELATION MARK DRILLPIPE AT SHOT DEPTH -LOGS MATCH RIH AND PICK UP TO MARK TO SHOOT DPC PERF GUNS -PICK UP TO MARK TO CONFIRM STRING IN TENSION 02:30 - 04:00 1.50 L PERFOB . P 1 OTHCMP HOLD PJSM WITH RIG CREW AND SCHLUMBERGER TCP TECHS OBTAIN SLOW PUMP RATES CLOSE ANNULAR PREVENTOR,OPEN UP • KILL LINE AND RIG UP TO PUMP DOWN BOTH DRILLPIPE AND KILL LINE PRACTICE PRESSURE SEQUENCE • t 1 BLEED PRESSURE TO ZERO AND WAIT 15 I MINUTES TO CLEAR FIRING SEQUENCE 103:27-START PRESSURE SEQUENCE 03:44-BEGIN 6 MINUTE DELAY 03:51 -GUNS FIRED 23 MIN 13 SEC INTO SEQUENCE -CALCULATED TIME 23 MIN 0 SEC 5 INITIAL LOSS:4.5 BBLS lc TC r A TA: 4-1/2"POWERJET 4505;5 SPF;72 DEGREE I PHASING OVER 3 INTERVALS 9,178'-9,212'MD;34'INTERVAL I �9,288'-9,332'MD;44'INTERVAL 9,370'-9,426'MD;56'INTERVAL 04:00 - 04:30 0.50 PERFOB P OTHCM• 'POOH FROM 9,427 TO 9,105'MD I 4- 48-ABOVE s' 5 MONITOR WELL FOR LOSS RATE -LOSS RATE 3 BBL/HR 04:30 - 06:00 1.50 PERFOB P , OTHCMP CIRCULATE BOTTOMS-UP -300 GPM,1,380 PSI -300 GPM MAXIMUM RATE THROUGH MWD TOOL -BRINE WEIGHT IN AND OUT: 9.2 PPG 06:00 - 07:30 1.50 PERFOB P OTHCMP BLOW DOWN TOP DRIVE AND KILL LINE SLIP AND CUT DRILLING LINE -PUMP OVER TOP OF HOLE AND MONITOR WELL WITH TRIP TANK ,FIRE DRILL Printed 6/6/2011 1:33:15PM 'orth America -ALASKA- BP Page 8 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/5/2011 End Date:5/22/2011 X3-00W92-C Project:Prudhoe Bay Site:PB W Pad Rig Name/No.: DOYON 14 1 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. !UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code ! NPT NPT Depth Phase Description of Operations (hr) 11 (ft) F0-7:30 - 13:00 5.50 PERFOB P OTHCMP POOH FROM 9,105'TO 406'MD -OBSERVE POTENTIAL SWABBING WHILE PULLING FIRST 5 STANDS--NO SWABBING OBSERVED -CONTINUOUS HOLE FILL ON AFTER FIRST 5 STANDS HOLD PJSM WITH DPC PERF GUNS AND MWD ASSEMBLY BELOW BOP STACK -FLOW CHECK WELL DURING PJSM 13:00 - 15:30 2.50 PERFOB P OTHCMP LAY DOWN MWD TOOL MAKE UP FOSV ON SAFETY JOINT FOR PERF GUN LAY DOWN OPERATIONS LAY DOWN FIRING HEAD AND PERF GUNS -ALL GUNS FIRED 15:30 - 16:00 0.50 PERFOB P OTHCMP CLEAN AND CLEAR RIG FLOOR OF PERF GUN ;-- _ TOOLS AND HANDLING EQUIPMENT ,—CLEAN P - ---- ---- -- - �-- -------- ----- - 16:00 - 17:00 1.00 , CLEAN MOBILIZE CLEANOUT BHA COMPONENTS TO RIG FLOOR 17:00 - 18:00 1.00 CLEAN P CLEAN MAKE UP CLEANOUT BHA AS FOLLOWS: -6-1/8"USED SMITH BIT(3X14 JETS) -2X BOOT BASKETS -BIT SUB -STRING MAGNET -NON-ROTATING SCRAPER 1 I-CASING BRUSH -STRING MAGNET -BUMPER SUB -OIL JAR 1 -3-1/2"IF PIN X 4"XT-39 CROSSOVER TO I I i DRILLPIPE 'TOTAL BHA LENGTH: 77.58' • 18:00 22:30 4.50 CLEAN P CLEAN RIH WITH CLEANOUT BHA FROM 78'TO 9,107' MD -FILL DRILLPIPE EVERY 20 STANDS OBTAIN SLOW PUMP RATES AND PARAMETERS FOR CLEANOUT RUN 1-PUW 150K,SOW 102K, ROT 123K -50 RPM,TQ 4K 22:30 - 00:00 1.50 CLEAN P CLEAN REAM DOWN ACROSS PERFORATED INTERVALS FROM 9,160'TO 9,573'MD I -50 RPM,TQ 4-5K RIH FROM 9,573'WITHOUT ROTATION AND TAG PBTD AT 9,644'MD i ' -DRILLPIPE MEASUREMENT -STACKED 10K TO CONFIRM TD -- PICK UP 10'OFF BOTTOM 5/17/2011 00:00 - 02:00 2.00 CLEAN P CLEAN FLOWCHECK WELL FOR 10 MIN -NO FLOW I BEGIN CLEANOUT RUN FROM 9,573'TO 9,107' I MD -10 BPM,2,420 PSI -50 RPM,TQ 6K INCREASED DEBRIS OBSERVED ACROSS SHAKERS AT BOTTOMS UP -PERF GUN DEBRIS AND CHARGE RESIDUE -SHAKERS CLEANED UP 15 BBLS AFTER BOTTOMS-UP Printed 6/6/2011 1:33:15PM '-)rth America -ALASKA- BP Page 9 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/5/2011 End Date: 5/22/2011 X3-00W92-C Project: Prudhoe Bay Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL©81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 02:30 0.50 CLEAN P CLEAN CIRCULATE HOLE CLEAN -10 BPM,2,380 PSI SHAKERS CLEANED UP 20 BBLS AFTER BOTTOMS-UP 02:30 - 04:00 1.50 CLEAN P CLEAN REAM DOWN ACROSS PERFORATED INTERVALS FROM 9,107'TO 9,511'MD -50 RPM,TQ 4-6K FLOWCHECK WELL FOR 10 MIN -NO FLOW 04:00 05:00 1.00 CLEAN P CLEAN ,BEGIN CLEANOUT RUN FROM 9,511'TO 9,107' MD -10 BPM,2,400 PSI -50 RPM,TQ 6K INCREASED DEBRIS OBSERVED ACROSS SHAKERS AT BOTTOMS UP -PERF GUN DEBRIS AND CHARGE RESIDUE -SHAKERS CLEANED UP 15 BBLS AFTER BOTTOMS-UP 05:00 - 06:00 1.00 CLEAN P CLEAN CIRCULATE HOLE CLEAN -10 BPM,2,300 PSI -50 RPM,TQ 6K 06:00 - 12:00 6.00 CLEAN P i CLEAN FLOWCHECK WELL FOR 10 MIN -NO FLOW PULL OUT OF THE HOLE FROM 9107'TO 2620' LAYING DOWN 4"DRILL PIPE -MOSES CREW HELD KICK WHILE TRIPPING DRILL, CRT 105 SEC. 12:00 - 12:30 0.50 CLEAN P` j CLEAN LUBRICATE TOP DRIVE,DRAW WORKS,IRON ,ROUGHNECK. 12:30 - 15:00 2.50 CLEAN P CLEAN PULL OUT OF THE HOLE FROM 2620'TO 1286' LAYING DOWN 4"DRILL PIPE. RUN IN THE -- HOLE WITH STANDS FROM THE DERRICK TO 1753'. CONTINUE TO PULL OUT OF THE HOLE FROM 1753'TO 103'. 15:00 - 16:00 1.00 CLEAN P CLEAN FLOWCHECK WELL FOR 10 MINUTES -NO FLOW PULL OUT OF THE HOLE AND CLEAN THE MAGNETS AND JUNK BASKETS. LAYING DOWN THE BHA. JUNK BASKETS HAD APPROX.6 PEBBLE SIZES PIECES OF METAL j • AND MAGNETS HAD APPROX. 1/2 GALLON OF SHAVINGS. 16:00 - 17:00 I 1.00 EVAL P OTHCMP PJSM WITH SCHLUMBERGER E-LINE CREW AND RIG CREW. RIG UP E-LINE SCHEAVES AND TOOLS. 17:00 - 19:30 2.50 ! EVAL P OTHCMP RUN IN THE HOLE WITH 6.05"GAUGE RING AND JUNK BASKET ON E LINE TO 9515'AND PULL OUT OF THE HOLE. JUNK BASKET CONTAINED NOTHING. 19:30 21:30 2.00 EVAL MAKE UP USIT TOOL AND PREPARE TO RUN P I OTHCMP 'IN THE HOLE. --- - 21:30 - 00:00 2.50 i EVAL P OTHCMP RUN IN THE HOLE WITH USIT TOOL TO PERFORM CEMENT LOG. -JENNINGS CREW HELD FIRE DRILL,CRT 94 -- I SEC - 5/18/2011 100:00 - 01:30 j 1.50 EVAL P OTHCMP RUN TO 9550'WITH USIT ON E-LINE. '01:30 - 03:00 1.50 EVAL N DFAL OTHCMP TROUBLESHOOT USIT TOOL WITH SCHLUMBERGER TOWN ENGINEER. Printed 6/6/2011 1:33:15PM 'orth America -ALASKA- BP Page 10 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date: 5/5/2011 End Date:5/22/2011 X3-00W92-C Project:Prudhoe Bay Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL t 81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 06:00 3.00 EVAL N DFAL OTHCMP BEGIN LOGGING FROM 9550'WITH USIT TOOL ON E-LINE. -MOSES CREW HELD A SPILL DRILL,CRT 135 SEC 06:00 - 07:00 1.00 EVAL N DFAL OTHCMP SHUT DOWN E-LINE DUE TO BEING OVER ALLOWED WORKING HOURS. 07:00 09:00 2.00 EVAL N DFAL OTHCMP RUN USIT LOG IN SHORT SECTIONS DUE TO TOOL INTERMITTENTLY HAVING ISSUES. 09:00 - 11:00 2.00 EVAL N DFAL OTHCMP TROUBLESHOOT USIT TOOL WITH SCHLUMBERGER TOWN ENGINEER. 11:00 - 13:00 2.00 EVAL N DFAL OTHCMP RUN USIT LOG IN SHORT SECTIONS DUE TO TOOL INTERMITTENTLY HAVING ISSUES. 13:00 - 15:00 2.00 EVAL N DFAL OTHCMP TROUBLESHOOT USIT TOOL WITH SCHLUMBERGER TOWN ENGINEER. 15:00 - 18:00 3.00 EVAL P OTHCMP LOG USIT BACK TO SURFACE. -SIMOPS:WORK ON BOILER FEED PUMPS AND REPAIR THE MUD PUMP SUCTION CAP PLUGS. -JENNINGS CREW HELD TABLE TOP STRIPPING DRILL 18:00 - 18:30 0.50 EVAL P OTHCMP LAY DOWN THE USIT TOOL AND MAKE UP THE 6.125"GAUGE RING AND JUNK BASKET. TOC 5440 FT PICKED AS PER ISOLATION SCANNER(USIT). 18:30 - 22:00 3.50 EVAL P OTHCMP RUN IN THE HOLE ON E-LINE WITH THE 6.125"GAUGE RING AND JUNK BASKET. JUNK BASKET CONTAINED 1/4 CUP OF I SMALL DEBRIS. 22:00 - 23:00 1.00 EVAL P OTHCMP RIG DOWN E-LINE SHEAVES AND TOOLS. 23:00 - 23:30 0.50 RUNCOM P RUNCMP CLEAR THE FLOOR OF THE CLEAN OUT BHA AND PULL THE WEAR RING. 23:30 - 00:00 0.50 RUNCOM P RUNCMP PERFORM DUMMY RUN WITH THE HANGER AND LANDING JOINT. 5/19/2011 00:00 - 02:00 2.00 RUNCOM P RUNCMP RIG UP TO RUN 3.5"COMPLETION. Printed 6/6/2011 1:33:15PM Orth America-ALASKA- BP Page 11 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/5/2011 End Date: 5/22/2011 X3-00W92-C Project:Prudhoe Bay Site:PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release:5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 06:00 4.00 RUNCOM P RUNCMP HOLD PJSM WITH ALL PERSONNEL INVOLVED IN RUNNING THE 3.5" COMPLETION. BEGIN TO MAKE UP 3.5"TC-II COMPLETION AS PER TALLY. BAKER LOK THE ASSEMBLIES TO FIRST PACKER AND UTILIZE JET LUBE SEAL GUARD ON ALL CONNECTIONS AFTER. TORQUE ALL CONNECTIONS TO 2300 FT/LBS. MAKE UP THE COMPLETION AS FOLLOWS: 3.5"9.2#WLEG,3.5"TC-II 3.5",9.2#, L-80 TC-II PUP -3.5"HES'XN'NIPPLE W/RHC-M:2.750"ID#1 -3.5",9.2#, L-80 TC-II PUP -3.5",9.2#, L-80 TC-II PUP -3.5"HES'X'NIPPLE:2.813"ID #1 -3.5",9.2#, L-80 TC-II PUP -3.5",9.2#, L-80 TC-Il PUP -GLM#1 -3.5"X 1.5"MMG-W W/RD DUMMY- RK LATCH -3.5"9.2#L-80 TC-II PUP -3.5"9.2#L-80 TC-II PUP -NDPG SINGLE SUB#1 -3.5"9.2#L-80 TC-II PUP -3.5"HES'X'NIPPLE:2.813"ID #2 3.5"9.2#L-80 TC-II PUP -3.5"X 7"BOT PREMIER PORTED PACKER #1 PACKER -3.5"9.2#L-80 TC-II PUP -3.5"9.2#L-80 TC-Il PUP -GLM#2-3.5"X 1.5"MMG-W W/RD DUMMY- RK LATCH -3.5"9.2#L-80 TC-II PUP -1 JT(#1)3.5"9.2#L-80 TC-II TUBING -3.5",9.2#, L-80 TC-II PUP -GLM#3-3.5"X 1.5"MMG-W W/RD DUMMY- RK LATCH -3.5",9.2#, L-80 TC-II PUP -3.5",9.2#, L-80 TC-II PUP -NDPG MULTI SUB#2 -3.5"9.2#L-80 TC-II PUP -3.5"HES'X'NIPPLE:2.813"ID #3 -3.5"9.2#L-80 TC-II PUP -3.5"X 7"BOT PREMIER PORTED PACKER #2 PACKER -3.5",9.2#, L-80 TC-II PUP Printed 6/6/2011 1:33:15PM 'xrth America -ALASKA- BP Page 12 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/5/2011 End Date: 5/22/2011 X3-00W92-C Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. 'UWI: Active Datum:WELL @81 90ft(above Mean Sea Level) Date From-To 1 Hrs Task ' Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 12:00 6.00 1-RUNCOM P I RUNCMP CONTINUE RUNNING IN THE HOLE WITH 3.5" TC-II COMPLETION AS FOLLOWS: -3.5"9.2#L-80 TC-II PUP -GLM#4-3.5"X 1.5"MMG-W W/RD DUMMY- RK LATCH -3.5"9.2#L-80 TC-II PUP -1 JT(#2)3.5"9.2#L-80 TC-II TUBING -3.5"9.2#L-80 TC-II PUP -GLM#5-3.5"X 1.5"MMG-W W/RD DUMMY- RK LATCH -3.5"9.2#L-80 TC-II PUP -3.5"9.2#L-80 TC-II PUP -NDPG MULTI SUB#3 -3.5"9.2#L-80 TC-II PUP -3.5"HES'X'NIPPLE:2.813"ID #4 -3.5"9.2#L-80 TC-II PUP -3.5"X 7"BOT PREMIER PORTED PACKER #3 PACKER -3.5"9.2#L-80 TC-II PUP -1 JT(#3)3.5"9.2#L-80 TC-II TUBING W/RA TAG @ 9,075' : -3.5"9.2#L-80 TC-II PUP -GLM#6-3.5"X 1.5"DCR-1 SHEAR VALVE& RKP LATCH I -3.5"9.2#L-80 TC-II PUP : i ' -34 JTS(#4437)3.5"9.2#L-80 TC-Il TUBING I-TESTING THE I-WIRE EVERY 1000'AND TESTED THE FEED SCREW TO 7500 PSI ON TALL 3 PACKERS. -MOSES CREW HELD A KICK WHILE , TRIPPING DRILL,CRT 240 SEC. 12:00 - 00:00 12.00 RUNCOM P t I RUNCMP CONTINUE RUNNING THE HOLE WITH 3.5" :TC-II COMPLETION AS FOLLOWS: !-173 JTS(#38-#210)3.5"9.2#L-80 TC-II • !TUBING • 1 !-PLACE I-WIRE CLAMPS ON EVERY JOINT 1-100 AND EVERY OTHER JOINT AFTER AND • • TESTING THE I-WIRE EVERY 1000'. -JENNINGS CREW HELD A SPILL DRILL,CRT 111 SEC. 5/20/2011 00:00 - 02:00 2.00 RUNCOM P i RUNCMP CONTINUE TO RUN 3.5"COMPLETION AS FOLLOWS: , 8 JTS(#211-#218)3.5"9.2#L-80 TC-II TUBING 3.5"9.2#L80TCII PUP -3.5"HES'X'NIPPLE: 2.813"ID #2(@-2000' TVD) : -3.5"9.2#L-80 TC-II PUP -18 JTS(#219-#236)3.5"9.2#L-80 TC-II TUBING -PLACE I-WIRE CLAMPS ON EVERY JOINT 1-100 AND EVERY OTHER JOINT AFTER AND TESTING THE I-WIRE EVERY 1000'. 02:00 - 03:00 1.00 RUNCOM P RUNCMP SERVICE THE PIPESKATE,CASING TONGS, TOP DRIVE,AND DRAW WORKS. Printed 6/6/2011 1:33:15PM 'orth America -ALASKA- BP Page 13 of 15 Operation Summary Report ----__ - --___._- --- ------- ------------------------ Common Well Name:W-223 AFE No Event Type: COM-ONSHORE(CON) Start Date: 5/5/2011 End Date: 5/22/2011 X3-00W92-C Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM 1Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. 'UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth, Phase Description of Operations (hr) I (ft) 03:00 08:00 5.00 RUNCOM P RUNCMP CONTINUE TO RUN 3.5"COMPLETION AS FOLLOWS: 1-51 JTS(#237-#287)3.5"9.2#L-80 TC-Il TUBING -1 PUP JT 3.5"9.2#L-80 TC-II TUBING PLACE I-WIRE CLAMPS ON EVERY JOINT • 1-100 AND EVERY OTHER JOINT AFTER AND TESTING THE I-WIRE EVERY 1000'. 08:00 - 11:00 3.00 RUNCOM P RUNCMP SPOT E-LINE TRUCK AND HOLD PJSM. MOBILIZE TOOLS TO THE RIG FLOOR. ____ 11:00 - 14:00 3.00 RUNCOM P RUNCMP RIG UP SCHLUMBERGER PRESSURE CONTROL EQUIPMENT AND LOGGING TOOLS. PRESSURE TEST THE LUBRICATOR TO 2500 PSI. NO LEAKS. 14:00 - 17:00 3.00 RUNCOM P RUNCMP RUN IN THE HOLE WITH GR/CCL TO LOG COMPLETION ON DEPTH. -JENNINGS CREW HELD TABLE TOP H2S DRILL • -JENNINGS CREW HELD TABLE TOP MAN , DOWN DRILL 17:00 - 19:00 2.00 RUNCOM . P RUNCMP RIG DOWN LOGGING TOOLS AND LUBRICATOR. 19:00 - 19:30 0.50 RUNCOM P j RUNCMP RIG UP I-WIRE AND CASING EQUIPMENT. 19:30 - 21:30 2.00 ' RUNCOM • P TRUNCMP LAYDOWN 14'PUP JT AND JOINTS#289 AND I #288. PICK UP SPACE OUT PUP AND LAND ;COMPLETION AS FOLLOWS: i-1 PUP JT(9.81')3.5"9.2#L-80 TC-II TUBING 1 JTS(#288)3.5"9.2#L-80 TC-II TUBING • -3.5"9.2#L-80 TC-II PUP -4.5"X 3.5"TC-II CROSSOVER -FMC TUBING HANGER W/4-1/2"TC-II LIFTING THREADS -TIE I-WIRE INTO THE HANGER AND TEST j ITHE HANGER TO 5000 PSI FOR 10 MINUTES. GOOD TEST. TEST I-WIRE,GOOD TEST. !TOTAL OF 182 FULL CLAMPS AND 15 • 1HALF-CLAMPS INSTALLED ON I-WIRE. DROP • 'THE BALL AND ROD. 21:30 - 23:30 ; 2.00 RUNCOM P RUNCMP RIG DOWN CASING EQUIPMENT AND CLEAR FLOOR OF ALL UN-NEEDED TOOLS FOR UPCOMING OPERATIONS. 23:30 - 00:00 0.50 RUNCOM PRUNCMP i RIG UP TO TEST THE TUBING/ANNULUS AND SET THE PACKERS. Printed 6/6/2011 1:33:15PM 'orth America -ALASKA- BP Page 14 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/5/2011 End Date: 5/22/2011 X3-00W92-C -------- Project:Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:00AM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth i Phase Description of Operations ft _ ( I RUNCMP PRESSURE TEST THE TUBING TO 250 PSI ' P O 5/21/2011 00:00 03:00 3.00 RUNCOM I LOW FOR 5 MINUTES. GOOD TEST. PRESSURE UP TO 4000 PSI FOR 30 MINUTES. I LOST 40 PSI IN THE FIRST 15 MINUTES AND 10 PSI IN THE SECOND 15 MINUTES. TOOK 1 1.2 BBLS TO PRESSURE UP. GOOD TEST. BLEED THE PRESSURE TO 2000 PSI. j PRESSSURE UP THE ANNULUS TO 250 PSI _. LOW FOR 5 MINUTES. GOOD TEST. PRESSURE UP TO 4000 PSI FOR 30 MINUTES. LOST 25 PSI IN THE FIRST 15 MINUTES AND 10 PSI IN THE SECOND 15 MINUTES. TOOK 3.5 BBLS TO PRESSURE UP. GOOD TEST. BLEED OFF TUBING PRESSSURE AND SHEAR DCK SHEAR VALVE AT APPROX. 1800 PSI DIFFERENTIAL. PUMP AT 2 BPM WITH 120 PSI DOWN THE TUBING AND AT 2 BPM WITH 270 PSI DOWN THE ANNULUS TO CONFIRM CLEAR COMMUNICATION THROUGH THE DCK VALVE. 03:00 - 03:30 0.50 RUNCOM P ' RUNCMP RIG DOWN THE TESTING EQUIPMENT AND LAYDOWN THE LANDING JOINT. 103:30 - 05:00 1.50 WHSUR P RUNCMP SET AND TEST THE TWC TO 250 PSI LOW AND 5000 PSI HIGH FOR 5 MINUTES. GOOD TEST. TEST THE TWC TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES. GOOD TEST. 05:00 - 07:00 2.00 BOPSUR P RUNCMP I NIPPLE DOWN THE BOP'S,REMOVE THE BLEEDER LINE, HOLE FILL LINE, FLOW LINE 'COVERS, FLOW LINE, RISER,TURNBUCKLES, ILAY DOWN THE MOUSE HOLE, CHOKE LINE, + -- — — RACK BACK AND SECURE THE STACK. 07:00 - 10:30 3.50 ' WHSUR P i WHDTRE SCHLUMBERGER TO TERMINATE I-WIRE IN THE ADAPTER FLANGE, INSTALL PUMP IN FLANGE, INSTALL ADAPTER/TREE WITH HYDRAULIC ACTUATOR AND TORQUE UP. TEST THE TUBING HANGER VOID TO 250 PSI LOW FOR 5 MINUTES AND 5000 PSI HIGH FOR 30 MINUTES. GOOD TESTS. 10:30 - 12:00 1.50 WHSUR P WHDTRE I RIG UP TO TEST THE TREE WITH DIESEL TO 1250 PSI LOW FOR 5 MINUTES AND 5000 PSI I!HIGH FOR 10 MINUTES. WORKED VALVES I 'SEVERAL TIMES. -SIM OPS: MOVE THE ROCKWASHER,FUEL TANK AND DISMANTLE THE ROCKWASHER BERM. RIG UP LINES FOR UPCOMING CIRCULATING OPERATIONS. 12:00 - 13:00 1.00 WHSUR P : WHDTRE CONTINUE TESTING THE TREE TO 5000 PSI FOR 5 MINUTES. GOOD TEST. RIG DOWN TESTING EQUIPMENT AND FINISH RIGGING UP CIRCULATING LINES. 13:00 - 17:00 4.00 WHSUR N WHDTRE WAIT ON DSM TO ARRIVE FROM NABORS 7ES. -SIM OPS:CHANGE OUT THE SAVER SUB TO 4.5"IF ALONG WITH THE GRABBERS AND BELL GUIDE ON THE TOP DRIVE IN PREPARATION FOR 5"DRILLPIPE ON THE NEXT WELL. SET RIG MATS FOR THE RIG MOVE. 17:00 - 19:00 2.00 WHSUR P WHDTRE RIG UP DSM AND TEST THE LUBRICATOR TO 500 PSI FOR 5 MINUTES. GOOD TEST. PULL THE TWC AND RIG DOWN DSM. Printed 6/6/2011 1:33:15PM ''rth America -ALASKA- BP Page 15 of 15 Operation Summary Report Common Well Name:W-223 AFE No Event Type:COM-ONSHORE(CON) Start Date:5/5/2011 End Date:5/22/2011 X3-00W92-C Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 14 Spud Date/Time:4/26/2011 12:00:OOAM Rig Release: 5/22/2011 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:WELL @81.90ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 21:30 2.50 WHSUR P WHDTRE PJSM. DISPLACE REVERSING DOWN THE IA AND OUT THE TUBING 70 BBLS OF 9.2 PPG CLEAN BRINE FOLLOWED BY 165 BBLS OF 9.2 PPG CORROSION INHIBITED BRINE AT 4 BPM WITH 920 PSI. FOLLOWED BY 5 BBLS OF CLEAN 9.2 PPG BRINE TO FLUSH OUT THE LINES AND PUMP. 21:30 - 22:30 1.00 WHSUR P WHDTRE PJSM. RIG UP LRS AND PRESSURE TEST 3500 PSI. GOOD TEST. PUMP DIESEL FREEZE PROTECT 1.6 BPM WITH 350 PSI AT 80 DEGREES. RIG UP TO U-TUBE. 22:30 - 23:30 1.00 WHSUR P WHDTRE 1ALLOW DIESEL TO U-TUBE FROM THE IA TO THE TUBING. -JENNINGS CREW HELD A SPILL DRILL,CRT 87 SEC. 23:30 - 00:00 0.50 WHSUR P ' WHDTRE BLEED OFF PRESSURE AND BLOW DOWN THE LINES. RIG UP TO SET THE BPV. 5/22/2011 '00:00 - 02:00 2.00 WHSUR ' P j WHDTRE TEST LUBRICATOR TO 500 PSI LOW FOR 5 MINUTES AND 3500 PSI FOR 5 MINUTES. SET THE BPV. 02:00 - 03:30 1.50 WHSUR P WHDTRE RIG UP LRS AND TEST THE BPV FROM BELOW TO 250 PSI LOW AND 1000 PSI HIGH FOR 5 MINUTES EACH TEST. GOOD TEST. 03:30 - 04:00 0.50 WHSUR P . 1-- RIG DOWN LRS. 104:00 - 04:30 0.50 • .WHSUR i P i WHDTRE •SECURE TREE. REMOVE PUMP IN FLANGES, 1 j REMOVE DOUBLE VALVE FROM THE OA, INSTALL BLANK FLANGES WITH NEEDLE VALVES AND GAUGES. RIG RELEASED @ 04:30 ON 5/22/2011 - MOVING TO W-2211. 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Ql 61 Q1 N N l0 N N N N l0 N CO l0 l0 l0 N U) '--I OJ U) N l0 U) N l0 N 1--1 '--I O O 61 al M M M M M M M M M M M M M M M M M M CM N N N M CO O ri N '--♦ U) U) d' O N lO CO l0 N d' M rl M M O 61 61 M lO dl 6l O N M d' N CO M M 6l LC) N U) Ol d' N M d' lO N N OO N M U) rl rl U) N N CO N alCV d' COLOCOCNCON N . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . d' d' M d' M d' U) U) d' LC) U) lO l6 d' U) d' d' M N d' d' '--I O O CO l0 U) U) U) in d' M M lO lO lO lO U lO U l0 l0 l0 l0 l0 lO lO lO U U U U) Ln Ln Ln Ln U) d' d' d' d' d' d' d' d' d' 61 N OO LO N LC) a) N CO N 61 61 M N d' U) N M O O U) U) d' U) r-I M N ,A M l0 CD U) O N N U) N M 61 O rl U) O rl M '-1 d' O d' O N CO N N U) 61 rl d' N 6l N U) 61 CO O O ▪ [� O CO LC) CO N d' l0 O M LC) 61 CO l0 O N L 61 N U1 00 N d' CO 61 CO d' M M N '-1 O O 61 CO 00 N l0 U) U) d' M M N rl O O 61 CO CO N l0 U) U) d' M M CO d' CO 61 O rl N M d' d' U) l0 N 00 61 O rl N CO d' U) LO N N CO 61 O rl N CO d' U) l0 l0 N l0 lO N N N N NNNNN N N CO CO CO N CO CO CO 00 CO 00 CO 6l 61 6l 61 61 6l 61 61 61 • R $cblumberger Drilling &Measurements MWD/LWD Log Product Delivery Customer BP Exploration(Alaska)Inc. Dispatched To: Christine Mahnken(AOGCC) Well No W-223 Date Dispatched: 18-Apr-11 Installation/Rig Doyon 14 Dispatched By: Brian Muzny Data CEI No Of Prints No of CDs Surveysr{I(U%SSIOt1 2 1 417,1,5: ila1Sf�C � (C��\ Please sign and return to:James H.Johnson Received By: VBP Exploration(Alaska)Inc.gkiNQ Petrotechnical Data Center(LR2-1) 900 E.Benson Blvd. Anchorage,Alaska 99508 Fax:907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.0,01/22/2010 2cc — 00 ‘ STIATIE ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMAIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU W-223 BP Exploration (Alaska), Inc. Permit No: 211-006 (revised) Surface Location: 361' FNL, 1176' FEL, SEC. 21, Ti1 N, R12E, UM Bottomhole Location: 9' FNL, 1967' FEL, SEC. 15, T11N, R12E, UM Dear Mr. Egbejimba: 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. ncerely, Daniel T. Seamount, Jr. Chair f DATED this / day of March, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ,./4 .41 // ALA; OIL AND GAS CONSERVATION COMM 'ON PERMIT TO DRILL 20 AAC 25.005 RDesvoitshioLno:c2.1a 41M1D.cweconmonrbisProcdhaucrtaivse oitlzoMn►/Total I a.Type of work: 1 b.Proposed Well Class: 0 Development Oil ®Service-Winj 0 Single Zone 1 c. Specify if well is proposed for: Ira Drill 0 Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: ® Blanket 0 Single Well 11. Well Name and Number: rt1oi4i0ri BP Exploration(Alaska)Inc. . Bond No. 6194193 PBU W-223 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 9753' TVD 5534' Prudhoe Bay Field/Orion . 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Schrader Bluff Surface: ADL 028263-2&028263-1 361'FNL, 1176'FEL,SEC.21,T11N, R12E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 404'FNL, 1974'FEL,SEC. 15,T11N, R12E, UM March 16,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 9'FNL, 1967'FEL,SEC. 15,T11N, R12E, UM 2560 23690' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 87.60 feet 15.Distance to Nearest Well Open Surface: x- 612049 y-5959896 Zone- ASP4 GL Elevation above MSL: 53.30 feet to Same Pool: 1510' 16.Deviated Wells: Kickoff Depth: 250 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 65 degrees Downhole: 2412 Surface: 1861 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD _ TVD MD ND (including stage data) 42" 20" 129.5# X-65 WLD 80' Surface,Surface 80' 80' -260 sx Arctic Set 16" 13-3/8" 68# L-80 BTC 2303' Surface Surface 2303' 2013' 491 sx Arctic Set Lite:981 sx Class'G' 12-1/4" , 9-5/8" 40# L-80 BTC 3284' 2153' 1912' 5437' 3417' ,196 sx LiteCRETE:815 sx Class'G' 8-3/4" , 7" 26# L-80 VamTopHC 9753' Surface,Surface 9753' 5534' 81 sx LiteCRETE:269 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface RECEIVED' ; Intermediate Production FEB 2 3 2011 Liner 41101181 ii GAS COBIZOMINWIN . Perforation Depth MD(ft): Perforation Depth TVD(ft): AncM age 20.Attachments: 0 Property Plat ®BOP Sketch Z Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch 0 Seabed Report ®Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Wilson Quintet 564-4458 Printed Name John Egbejimba Title Engineering Team Leader Prepared By Name/Number: Signature ---j, U ' Phone 564-5859 Date ,- 3//I Elizabeth Barker,564-5674 Commission Use Only Permit To Drill API Number. PermitA I ate: See cover letter for Number: 211-006 50-029-23440-00-00 "� �\ other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: Ii Other: *IMO 0 �5` 61 op ( c�� ,_ . Samples Req'd: ❑fifes EZ(No Mud Log Req'd: 0 Yes 'No 1Z5776 ,os� /41.'" '*� 7 L r"."`""V HZS Measures: Yes 0 No Directional Survey Req'd: I�Yes 0 No uC''�,rh.a� ap.e_,GA, ah r h. cLGGarae /�4_.'( 4-1 z halt_ �vurc.Y. x /''J11€ rerozoo a.cc < 1° ZoAA�Lt 33 M1 T 4, C Q�- `� 7` c-3) // . ......- -- -- APPROVED BY THE COMMISSION Date �� ,COMMISSIONER Form 10-401 Revised 0 /2009 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit In Duplicate 0_ 3-/-ll .8.-4 ORIGINAL Revision of the PTD n° 211-006 Well Name: W-223 Drill and Complete Plan Summary Name Position Office Home Cell Wilson Quinta Drilling Engineer 4863 929-3984 632-3271 Joe Turak Geologist 4204 644-4855 250-2425 Bob Dawson Ops Geologist 5264 345-3359 242-2391 Taylor West Pad Engineer 4647 337-2028 632-0111 Type of Well (service / producer/ injector): Water Injector Surface Northing Easting Offsets TRS Location 5,959,896 612,049 361' FNL / 1176' FEL 11 N, 12E, 21 Northing Easting TVDss Offsets TRS Lo Taratons et 5,965,200 616,440 -5052 4875' FSL / 1974' FEL 11N, 12E, 15 5,965,350 616,440 -5202 5025' FSL / 1971' FEL 11N, 12E, 15 Bottom Northing Easting TVDss Offsets TRS Location 5,965,594.77 616,440 -5447 5270' FSL / 1967' FEL 11 N, 12E, 15 API NUMBER: Rig: Doyon 14 Estimated Start Date: 03/16/2011 Operating Days to complete: 25.36 MD: 9753' TVD: 5534' RT/GL: 34.3'/53.3' RTE: 87.6' Well Design: Grassroots Schrader Bluff Injector 3-1/2" tbg, 9.2# L80, TC-II, multi-packers, zonal injection Objective: Multi-zonal injector into Schrader Bluff OBa, OBc and OBd sands Directional Plan: Version: Schlumberger P12 KOP: 250' MD, build 1.5°/100' Maximum Hole Angle: 64.92° Close Approach Wells: All wells pass major risk criteria. Reference anti-collision report Nearest well within Pool W-202 @ 1510' Distance to Nearest Property 23,690' to PBU boundary Line: W-223i Permit Application Page 1 Wells within 1/4 mile of this injection well: Well Name Dist, Ft. Annulus Integrity Comments NONE Logging Program: Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole: None Intermediate Interval Drilling, MWD: GR Open Hole: N/A Cased Hole: N/A Production Interval Drilling, MWD: GR, RES, NEU,Azimuthal Density PWD Open Hole: None Cased Hole: USIT-GPIT(PDC mode via tractor) Mud Program: 16" Surface Hole: Fresh Water Drilplex Mud Density Funnel Viscosity LSYP Yield Point API FL �H (ppg) (seconds) (2x3-6 rpm) (Ib/100ft ) (mis/30min) Spud to Base 60-120 (for reference Perm 8.8—9.5 only. Fluid should be 30—50 40—80 <_8 10.8 run off LSYP) Base Perm to 60-120 (for reference TD 9.0—9.5 only. Fluid should be 28—45 40—80 <_6 10.8 run off LSYP) 12 1/4" Intermediate Hole: LSND Density Funnel Viscosity LSYP Yield Point API FL �H (ppg) (seconds) (2x3-6 rpm) (Ib/100ft`) (mis/30min) Csg Shoe to 8.8—9.5 60-120 (for reference TD only. Fluid should be 28—45 40—80 <_6 10.8 run off LSYP) 8 3/4" Production Hole: LSND Interval Density YP PV pH API (ppg) Fluid Loss Csg Shoe to TD 8.8-9.3 18-24 12- 18 9- 10 <6.0 W-223i Permit Application Page 2 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Connection Length Top Btm Tbg O.D. MD/TVD MD/TVD RTE 42" 20" 129.5 X-65 WLD 80' GL 80'/80' 16" 13 3/8" 68 L-80 BTC 2303' GL 2303'/2013' 12 %4" 9 5/8" 40 L-80 BTC 3284' 2153'/ 1912' 5437'/3417' 8 3/" 7" 26 L-80 Vam Top HC 9753' GL 9753'/5534' Tubing 3 '/z" 9.2 L-80 TC-II 9458' GL 9458'/5326' Comments: Tbg crossover to 4 '/2'just below tree Formation Integrity Testing: Test Point Depth Test Type 13-3/8" Surface Casing 20'—50' of new hole below LOT Test Point Depth Test Type 9-5/8" Intermediate Liner 20'—50' of new hole below LOT Cement Calculations: Surface Casing: Casing Size 13'/8" Basis: Lead: Open hole volume +250% excess in permafrost. Port collar used if necessary. Lead TOC: Surface Tail: Open hole volume +250% excess in permafrost and 40% excess below permafrost+ 80' shoe track. Tail TOC: 800' MD above the casing shoe(1503' MD) Total Cement Volume: Lead 388 bbl/2176 ft /490 sks of Arctic Set Lite at 10.7 ppg and 4.44 cf/sk Tail 201 bbl/ 1131 ft'/983 sks of Class `G' at 15.8 ppg and 1.15 cf/sk Intermediate Liner: Casing Size 9°/8" Basis: Lead: Open hole volume with 40% excess. Lead TOC: 200' above liner top (1953' MD) Tail: Open hole volume 40% excess+ 80' shoe track. Tail TOC: 2500' MD above the liner shoe(2936' MD) Total Cement Volume: Lead 155 bbl/868 ft / 195 sks of LiteCRETE at 11 ppg and 4.45 cf/sk Tail 167 bbl/936 ft3/814 sks of Class `G' at 15.8 ppg and 1.15 cf/sk Production Casing: Casing Size 7" Basis: Lead: Open hole volume with 30% excess. Lead TOC: No higher than 1000' MD below drilling liner shoe (6436' MD) Tail: Open hole volume with 30% excess+ 80' shoe track volume, ID 6.276" Tail TOC: 8775' MD (500' MD above Mc) Total Cement Volume: Lead 64 bbl/359 fe/81 sks of LiteCRETE at 11 ppg and 4.45 cf/sk Tail 55 bbl/306 ft4/266 sks of Class 'G' at 15.8 ppg and 1.15 cf/sk W-223i Permit Application Page 3 Formation Markers: (7) Formation Tops(TVDss) and Estimated Pore Pressures Comrrrercrai Hydrocarbon Based on wp12 Est. Formation Tops Uncertainty Bearing fat. Pore Press Est. Pore Press. Formation (TVDss) (feet (YesWo) (Ps+) (ppg EMM NOTE:All Genuation tops ale terrified from 100W above pi oposed KOP to Taforsidetracks n1L-Max NOTE:All formation tops ale requited ham surface to TD foi all new well G1 '-3m -1-25' No 135 8.4-8.4-8.9 SV6 X1205 -/-25' No 542 8.4-8.4-8.9 EiOCIJ -/-25' 8.4-8.4-8.9 Base Permafrost '1840 +l-25' No 823 8.4-8.4-8.9 SV5 '--1860 +/-25' No 837 8.4-8.4-8.9 SV4 -2005 +/-25' Gas Hydrates 902 P 4-3 4-8 9 Fault#1 X2145 +1-150'M.D.-See Fault Section for Details i SV3 -2470 +1-25' Gas Hydrates 1112 3.4-13.4-3.9 SV2 12675 +/-25' Poss.Free Gas or Gas Hydrates 1204 8.4-8.4-8.9 SV-1 X3005 +/-40' Poss.Free Gas or Gas Hydrates 1352 8.4-8.4-8.9 IJG4 P3360 +/-40' Thin coals. 1512 6.4-8.4-8.9 11(AA P3405 --I-40' Heavy Gil down to-3520'SS 1532 8.4-8.4-8.9 IJG3 P-373U -,-/-40' No,water. Thin coals. 1679 8.4-8.4-8.9 UG1 P4260 +/-40' No,water 1917 8.4-8.4-8.9 UG Ma -4595 +1-40' No,water 2068 8.4-8.4-9.0 IG Mb -4650 +/-40' Heavy oil possible 2093 8 4-8.4-9.0 111; WIb2 -4700 +1-40' No,water 2115 .1 4-8.4-9.0 NG Mc +/-40' No,water 2150 8.4-8.4-8.8 SB Na -;tai_ +/-25' No,water 2132 8.4-8.4-8.8 SB Nb -4870 t1-25 No,water 2192 ;.4-8.4-8.8 SB Nc -4T +/-25' No,water 2208 8.4-8.4-8.8 SB Ne -45 +/-25' No,water 2212 6.4-8.4-8.8 SB 0,4 002 +/-25' No,water 2251 8.4-8.4-8.8 SB OBa -5052 +/-25' No,water 1865-2146 7.3-7.9-8.4 I SB 06115087 +/-25' Yes 2221-2300 8.4-8.5-8.7 SB OBC -5087 +1-25' Yes 2136-2296 8.0-8.4-8.6 SB 0641 -5202 +f-25' Yes 1893-2271 7.0 -7.7-8.4 SB OBe -5270 +1-25' No 2372 8 3.8 SB OBI -531 +/-25' No 2390 8.4-o.4-8.8 _ Base SB OBf 5.7. +/-25' No 2412 6.4-8.4-88 TD IWell TD Ctitelia T.D. is 250'MD past Top_OBe marker. lie ??ft TVD.??ft Rathole.etc.l Comments Formation pressures from surface to the Ma are calculated based on a.450 water gradient. Formation pressures from the UG_Ma down to the SB_OA are based on W-200PB1 RFT pressures taken before start of W Pad Schrader Bluff production. Formation pressures in the SB_0Ba through S8_06d sands are estimated and assume these sands will show pressure depletion resulting from offset producers W-204 and W-201. Review Schrader Bluff Formation pressures after adjacent injector W-220i is drilled(October,2010). Well Control: 16" holes will be drilled with diverter. The 12-1/4" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. I Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. IW-223i Permit Application Page 4 Diverter, BOPE and drilling fluid system schematics of Doyon 14 are attached to this permit to drill. Production Interval- • Maximum anticipated BHP: 2412 psi @ 5334' TVD, 8.7 ppg EMW • Maximum surface pressure: 1861 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: • Annular Preventer 250 / 2500 psi • Rams 250 / 4000 psi • Planned completion fluid: 9.0 ppg brine / 6.8 ppg diesel (9753' MD, also TD) Kick Tolerance/Integrity Testing Summary Table Casing and Casing Maximum Influx Mud Exp Pore LOT/ Interval Test Volume Weight Press FIT Pressure 133/8" Surface 3500 psi 36 BBLS (assuming 9.2 8.8 LOT Casing 11 LOT) 95/8" Intermediate 3500 psi 58 BBLS (assuming 9.2 8.8 LOT Liner 11.0 LOT) 7" Production 4000 psi NA NA NA NA Casing Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. 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. W-223i Permit Application Page 5 Drill and Complete Procedure Summary Pre-Rig Work: The 20" insulated conductor is installed. 1. Weld an FMC 13-3/8" landing ring for the FMC bigbore well head on the conductor. 2. If necessary, level the pad and prepare location for rig move. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Doyon 14. Nipple up diverter spool and function test diverter. 2. PU & stand back 4" DP as needed. MU 16" drilling assembly with MWD/GR. Directionally drill surface hole to the base of permafrost. CBU or until hole is clean, then POOH and lay down BHA. 3. Run and cement the 13-3/8", 68.0 lb/ft L-80 surface casing to surface with the Tesco CDS Tool, displacing cement with mud. 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test rams @ 4,000 psi / 250 psi, and annular to 2500 psi/250psi. 5. Pressure test the 13-3/8" casing to 3500 psi for 30 minutes. 6. MU 12-1/4" drilling assembly with MWD/GR and RIH to float collar. Drill shoe track and displace to new 8.8 ppg LSND mud. Drill new formation to 20-50' below 13-3/8" shoe and perform LOT. 7. Drill ahead to TD in the SV1. CBU or until hole is clean, then POOH, and lay down BHA. 8. Change to 9-5/8" casing rams and test. 9. Run and cement the 9-5/8", 40.0 lb/ft L-80 drilling liner with 150' overlap into the 13-3/8". Displace cement with mud and set hanger/liner top packer. POOH. 10. PU 4" DP as needed. MU 8-3/4" drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to 9-5/8" float collar. Pressure test to 3500 psi for 30 minutes. Drill shoe track and ensure 8.8 ppg LSND mud is in good condition. Drill new formation to 20-50' below 9-5/8" shoe and perform LOT. 11. Drill ahead to production hole TD 250' below the top of OBe. Clean and wipe hole. POOH. 12. Change to 7" rams and test prior to running casing. 13. Run and cement the 7", 26#, L-80, BTC-M x TCII production casing. Displace the casing with 9.0 ppg brine, and 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 13-3/8" annulus. 14. PU DPC guns and RIH to shoot 149' of perfs with of 4.5" Power Jet 4505 5 spf, perf guns with GR/CCL for gun correlation. W-223i Permit Application Page 6 15. Once correlated correctly, confirm cement compressive strength is at least 1,000 psi before firing. Perforate the OBa, OBc, and OBd sands. POOH stand back DP and lay down guns. 16. Make clean out run using DP. 17. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation. 18. Run USIT/GPIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 19. Run the 3-W, 9.2#, L-80, TCII completion with a 7" x 3-1/2" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TCII threaded tubing. Top packer must be within 200' of OBa perfs. Confirm that packers are on depth using E-line. 20. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 21. Install and test FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Pull TWC. 22. Freeze protect the well to 2,500' TVD by pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u- tube into tubing. 23. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-W annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 24. Rig down and move off. Post-Rig Work: 1. R/U slickline and pull the ball and rod/ RHC plug. 2. Replace the DCR shear valve and dummy valves with GLV as required by PE. 3. Pull VR plug from annulus valves (if installed). 4. Install wellhouse and flowlines. 5. Pump RG2401 on top of surface casing cement. W-223i Permit Application Page 7 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control/ Reservoir Pressures: Interval _Psi (EMW) TVDss MD Schrader Bluff 1893-2412 5202- 9407- Sands (7.0-8.7) 5447 9753 II. Hydrates and Shallow gas: A. Free gas and/or gas hydrates may likely be present in the SV5 through the SV1 surface hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. Set surface casing below deepest SV1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. III. Running Gravels: A. Unconsolidated sand, gravel, &cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. Hazards include wood and cobbles, lost circulation, and tight hole problems while drilling and running casing. See W Pad Data Sheet for details. B. Recent W Pad wells have experienced tight hole, running gravels, and lost circulation with drilling and running casing in Permafrost interval. Use best practices for drilling and lining surface hole interval. Base plan is to use the Tesco CDS casing running tool to address this problem for 13- 3/8" casing. IV. Faults Formation Where MD Throw Encounter Fault Intersect tvdss Est. Throw Direction Uncertainty Fault#1 -SV4 2673 -2145 -10'to -30' West +/-150' M.D. V. Kick Tolerance/ Integrity Testing: A. The 13 3/8" casing will be cemented to surface using a port collar at 1000' if necessary. The 9 5/8" intermediate liner will be cemented to the top of the 9 5/8" liner. The 7" production casing will be cemented to at least 500' MD above the Ma and no closer than 1000' below 9-5/8" intermediate shoe. Kick Tolerance/ Integrity Testing Summary Table Casing and Casing Maximum Influx Mud Exp Pore LOT/ Interval Test Volume Weight Press FIT Pressure 133/3" Surface 3500 psi 36 BBLS (assuming 9.2 8.8 LOT Casing 11 LOT) 95/8" Intermediate 3500 psi 58 BBLS (assuming 9.2 8.8 LOT Liner 11.0 LOT) 7" Production 4000 psi NA NA NA NA Casing W-223i Permit Application Page 8 • VI. Lost Circulation/ Breathing: A. Lost circulation potential when crossing Fault#1. No faults expected in the reservoir interval. Follow LCM decision tree; reduce mud weight slightly. B. Minor pressure depletion of OBa, OBc, and OBd zones from W Pad Polaris off take. Follow LCM decision tree; reduce mud weight slightly. VII. Broaching A. Monitor adjacent wells for broaching while drilling surface hole. VIII. Heavy Oil A. Heavy oil is expected in the UG4A and M sand intervals which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones. IX. Hydrogen Sulfide A. All W Pad gas lift wells are expected to have H2S levels in the 5 to 60 ppm range; result of PBU gas lift gas. This site should be treated as an H2S site with all the required precautions. Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level , W-204 12 ppm 11/9/2009 #2 Closest SHL Well H2S Level W-201 18 ppm 10/8/2009 #1 Closest BHL Well H2S Level ._W-201 18 ppm 10/8/2009 #2 Closest BHL Well H2S Level W-205 20 ppm 1/15/2010 Max. Recorded H2S on Pad/Facility W-01 60 ppm 8/16/2005 Other Relevant H2S Data: All W Pad gas lift wells are expected to have H2S (H2S alarms from rigs, etc.) levels in the 5 to 60 ppm range. CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION W-223i Permit Application Page 9 Area of Review— Map of all wellbores within 1/4 mile radius. None well for W-223. Polaris Pool- Markers O-UG_Mc(Top of Pool) W-220 '��,: �-SB_OBa :- 0-SB_OBI_Base(Base) * 4853 5,968,000 W-218 1,4 mi. radius Circle - 1 \ ,. . Centered on i W-223 OBa 64 ' . j $w-223 wp12 5,966,000 W-217 r -4914A \t& \ Y -463 ' / ! Ir W-216 N ` 5,964,000 f f' i/ 4- —21 w-201 sl,41#11 O — 3. `4NO w-21 s r y 1 j!r 4695 ` 5'S7V g 5,962,000 A - L. I_ .._ Schrader Bluff SB OBa Depth Map (20' contour interval) No Wells within 1/4 mile of W-223 In the Schrader Bluff Pool W-223i Permit Application Page 11 TREE = cWW 223 WELLHEAD= FMC PROPOSED � SAFETY NOTES: ACTUATOR= Hyd KB ELEV= 34 4' BF ELEV= 53 3' ! ' { 23' —j4-12"X 3-1/7'X0,10=2.992" KOP= 250' Max Angle= 64'6 2920' 20„CONDUCTOR, — 80' Datum MO= 9753' 2150' 13.3/8"X 9-5/8"BKR ZXP LTP/HGR 1 Datum TVD= 5446'SS 94a,A-55,WELDED, ID=19-124' 113318"CSG.8811,L-80 BTC,D=12.415' H 2303• ' ' 3500' H3-1/2"HES X MP.D=2.813" WATER WECTION MANDRELS 9-5/8"LNR,40a,L-80,BTC,ID=8835" H 5437' ST AD TVD DEV TYPE VLV LATCH PORT DATE 6 MMG DCR 5 MMG-W 4 MMG-W 3 MMG-W 2 MMG-W 1 MMG-W 3-1/7 PUP JOINT w/RA TAG H 9069' ' �► L�_"� 9082' —T X 3.1/2"BKR FREM FEED T-RU 3-1/2"HES X NIP,D=2 813" 908T ' R(R,0=2.965" • 9083' I +3-12"NDPG MULTI SUB,ID=2.997 IT PUP JOINT w/RA TAG 1— 9109' z 9237 1 7"X 3-1/2"BKR PREM FEED THRU 13-1/7 HES X NP,D=2.813" 9240 THRU PKR D=2.965' — Minimum ID=2.75"a 9447' I 9247' f—[3-12'NDPG MULTI SUB.ID r 2.997 3-1/2" HES XN NIPPLE 0 _ 9347' — T'X 3-1/2"BKR PREM FEED TI-RU _ THRU F1(R ID=2.965" 13-1/7 HES X NIP.10=2 813" 93 — 82' 1 I PERFORATION SUMMARY REF LOG.LWD LOG ONxx/xx/xx I ' . { 9357' —3-1/7 NDPG SINGLE SUB,D=2.997' ANGLE AT TOP FERFxx'6xxxx' Note:Refer to Rocuction DB for historical peri data SIZE SFF ZONE INTERVAL Opn/Sqz DATE 4-1/7 5 OBa ' , 1 941T —1312"HES X NP,D=2.813" 1 4-1/2" 5 OBe 4-1/2" 5 OBd 9447' H3.1/7HES XNNP,D=2.750" 1 13-1/7 TBG,9.2N,L-80 TM,.0087 bpf,ID=2.997 H 9458' ' '---{ 9458' H3-1/7 WLEG,ID=2.997 9653' ,!!!!!!1l1///�11/!! / T CSG,26#,L-80 Van Top HC,.0383 bpf,0=6.276" H1 8763 / DATE REV BY COMMENTS DATE REV BY COMMENTS POLARIS LINrT ((!/// 06100/10 GJS PROPOSED COM PLMON WELL:W223 PERMIT No: 211-006 AR No. SEC21,T11N,R12E 4918.1'FSL&1175.7'FEL BP Exploration(Alaska) W-223i Permit Application Page 10 N 0 Y O)^ NN,-Oq N OD.M. 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A i I i ii i i iii ii 11111111 7 C R W 1 lep 1 ■V I ' 1 1 1 11 1 1 111 I N 11111111 3 K 1 • ! ■0! n 1 1 1 li 1 1 1 1 1 !N 1111 1 111 Si 1^ 1 ■ 1 i 1 1 11 1 1 iii 1■ 11111 111 0 ••f !d•-•b I ! ! !i i i !ld.b.y -Iiii1!1!1}i o II 11. i i ii i I III l u ii iii l lit i Uc 0 Bo nO O o O o 8 n L o ~W 0 0 0 V' U)U U tC O 6 U Y (1!)0001:(u!)I.=ahS 0A1 • by Schhimberger WELL W-223 (P12) FIELD STRUCTURE Prudhoe Bay Unit-WOA W-PAD Ma9ne9c Parameter Surface Location NA027 Alaska State Plane,Zone 04.US Feat Miaullaneoua Madel: BGCM 2010 Dip: B0.941Date:' March 25,2011 Lat N 701757.766 Northing: 5959805.67fUS Grid Cony:0.65436165' SIC'. W-223 plan TVD Ref: Rotary Tabele7.6R above MSL) Mag Dec: 21474" FS'. 57644.17T Lan: W 149 533.106 Easing: 612048.92 RUS Scale Fac:0.99991428 Plan'. W.223(P12) 5rvy Dale'February 09,2011 0 1000 2000 3000 4000 ID -223(P12) W-221 Tgt OBd W-223 Tgt OBa 5000 M End-Cry 5000 a Cry 4.51100 4000 4000 A A A Z • 3000 3000 c 9-5)8"Cs. II CD P CO U 2000 2000 V fpf -223 Fit/2145 v. F 1000 1000 13-318"Cs End Cry Cry 3.25/100 Cry 2.75/100 COP Cry 1.5/100 Cry 4/100 RTE End Cry 0 z 0 End Cry Cry 2.75/100 0 1000 2000 3000 4000 << W Scale=1(in):1000(ft) E >» 1 BPPASSPORT Anticollislion Report Company: North America-ALASKA-BP Local Co-ordinate Reference: WO Plan W-223 Project: Prudhoe Bay TVD Reference: W-223 Plan @ 87.60ft;Doyon 14) Reference Site: PB iW Pad MD Reference: W-223 Plan @ 87.E+0ft{Doyon 14) Site Error: 0.O0it North Reference: True Reference Well: Plan W-223 Survey Calculation Method: Minimum Curvature Well Error: 0.00R Output errors are at 1.00 s.gma Reference Wellbore Plan W-223 Database: EDM.16-ANC Prod-Vt'H24P Reference Design: Plan#12 W-223 Offset TVD Reference: Offset Datum Reference Plan#12 W-223 Filter type: GLOBAL FILTER APPLIED All weilpaths within 200'-100.1000 of refer Interpolation Method: MD Interval 5.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North i Results Limited by: Maximum center-center distance of 1.171.906 Error Surface: Elliptical Conic Survey Tool Program Dale 2/9/1011 From To (p (ft) Survey(We!bore) Tool Name Description 34.30 900.00 Plan#12 W-223;Plan W-223) GYD-GC-SS Gyrodata gyro single shots 900.00 1,900.00 Plan#12 W-223(Plan W-223) MWD MWD-Standard 900.00 2,303.37 Plan#12 W-223(Plan W-223) MWD+IFR+MS MWD+ 1FR+Multi Station 2,303.37 3,300.00 Plan#12 W-223(Plan W-223) MIND MWD-Standard 2,303.37 5,436.65 Plan#12 W-223(Plan W-223) MW/D+IFR+MS MWD+ IFR+Multi Station 5,436.65 6,500.00 Plan#12 W-223(Plan W-223) MWD MWD-Standard 5,436.65 9.75328 Plan#12 W-223(Plan W-223) MWD+IFR+MS MWD+ IFR+Multi Station 229/2011 2:41:21PM cage 2 cf4 COMPASS 2003.16 Buiio 73 BPPASSPORT Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: WO Plan W-223 Project: Prudhoe Bay TVD Reference: W-223 Plan 5 87.60ft(Doyon 14) Reference Site: PB'W Pad MD Reference: W-223 Plan 5 87.608(Doyon 14) Site Error: 0 DDft North Reference: True Reference Well: Plan W-223 Survey Calculation Method: Minimum'Curvature Well Error: 0.00ft Output errors are at 1.00 sgrna Reference Wellbore Plan W-223 Database: EDM.16-ANC Prod-WH24P Reference Design: Ptan#112W-223 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB W Pad W-200-YW-200-W-200 372.68 370.00 125.62 6.78 118.85 Pass-Major Risk I W-200-W-200PB1-W-200P61 372.68 370.00 125.62 6.93 118.69 Pass-Major Risk i W-201-W-201-W-201 340.37 335.00 90.95 6.07 84.88 Pass-Major Risk ! W-201_DIMS-W-201-W-201 34.40 34.40 89.94 1.23 88.71 Pass-Major Risk W-202-W-202-W-202 210.71 210.00 75.59 3.93 71.67 Pass-Major Risk W-202-W-202L1-Plan#8 W-202L1 210.71 210.00 75.59 3.82 71.77 Pass-Major Risk W-202-W-202L1-W-202L1 34.80 34.80 75.07 1.23 73.84 Pass-Major Risk W-202-W-202L2-W-202L2 34.80 34.80 75.07 1.23 73.64 Pass-Major Risk W-204-W-204-W-204 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-204-W-204L1-W-204L1 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-204-W-204L2-W-204L2 295.76 290.00 61.60 6.42 55.1B Pass-Major Risk W-204-W-204PB1-W-204PB1 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-213-W-213-W-213 385.28 380.00 45.49 7.29 3820 Pass-Major Risk W-214-W-214-W-214 381.17 375.00 31.32 7.65 23.67 Pass-Major Risk W-214_DIMS-W-214-W-214 34.30 34.20 29.77 122 28.54 Pass-Major Risk 1N-216-W-216-W-216 559.74 555.00 13.11 4.88 8.24 Pass-Minor 1/200 W-216_DIMS-W-216-W-216 87.60 87.60 15.12 1.87 1325 Pass-Major Risk W-217-W-217-W-217 521.65 515.00 3123 8.92 22.34 Pass-Major Risk W-217-W-217P31-W-217PB1 521.65 515.00 3123 9.03 22.23 Pass-Major Risk W-217 DIMS-W-217-W-217 87.60 87.60 29.91 1.37 28.04 Pass-Major Risk W-217DIMS-W-217PB1-W-217 PB 87.60 87.60 29.91 1.87 28.04 Pass-Major Risk W-218_-W-218-W-218 301.03 295.00 46.90 526 41.67 Pass-Major Risk W-218 DIMS-W-218-W-218 87.60 87.60 44.92 1.87 43.04 Pass-Major Risk W-219-W-219-W-219 442.61 445.00 109.65 8.48 101.16 Pass-Major Risk W-219-W-219P81-W-219 WP 8.0 384.16 385.00 109.16 7.33 101.83 Pass-Major Risk W-219-W-219PB1-W-219P61 442.61 445.00 109.65 8.59 101.06 Pass-Major Risk W-219-W-219PB2-W 219PB2 442.61 445.00 109.65 8.48 101.16 Pass-Major Risk W-22-W-22-W-22 28926 285.00 23046 6.05 224.41 Pass-Major Risk W-220-DELETE"'-W-220PB1 34.30 3420 15.07 1.22 13.85 Pass-Major Risk W-220-W-220-W-220 480.42 480.00 10.90 3.54 7.37 Pass-Minor 11200 W-220-W-220-W-220 Cont wp 1.0 500.35 500.00 11.08 8.79 2.31 Pass-Major Risk W-220-W-220PB1-W-220PB1 480.42 480.00 10.90 3.66 724 Pass-Minor 1/200 W-220-W-220P32-W-220 WP 12.0 45520 455.00 15.31 8.76 6.56 Pass-Major Risk W-220-W-220PB2-IN-220P82 480.42 480.00 10.90 3.54 7.37 Pass-Minor 1,200 W-23-W-23-W-23 412.11 420.00 197.77 9.15 188.62 Pass-Major Risk W-23-W-23A-W-23A 410.43 410.00 197.72 9.10 188.62 Pass-Major Risk W-23A DIMS-W-23A-W-23A 87.60 87.60 194.87 1.87 193.00 Pass-Major Risk W-24-W-24-W-24 348.78 345.00 16034 6.61 153.93 Pass-Major Risk • 242011 2:41:21 PM ?age 3 cf 4 COMPASS 2003.16 Build 73 r Project: Prudhoe Bay Site: PB W Pad Well: Plan W-223 Wellbore: Plan W-223 From Colour To MD Design: Plan #12 W-223 34 300 300 500 500 — 700 From Surface to TD 700 900 Scan interval 100 ft Scale 1 50 900— 1300 W-216 and W-220 risk based 1 200 1300 1500 • 1500 1700 1' 1700 2000 2000 2500 330 30 2500 3000 1p , i,' 220P62 1 is 300 -220P81 60 / - .:1"-- I, JP ri; '44,.4..4thlre 9 •i., , sos Aes� .�tii .4. Aril .803 4:.s !j j►•.. 745 .� .. 270 ��993 111 `� ' 90 142 703 \\\ \\I ' \ 780 588, w-213IW-213 , 44.7 202/W-2021.2 Goo'''. i, 240X�* 120 ��* 118 /695 1 t 5' 1+C 'yay 1-. 78 730 Vf : y ' %fir. 0150 \ � D � m -4 '.24 -6V-21901i-2`1i-2191W 219P62 Travelling Cylinder Azimuth (TFO+AZI)[']vs Centre to Centre Separation [50 ftin] • • BPPASSPORT Antico#kision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Wet Plan W-223 Project: Prudhoe Bay TVD Reference: W-223 Plan 5 87.60ft%Doyon 14) Reference Site: PB W Pad MD Reference: W-223 Plan 4 87.&ft riDoyon 141.j Site Error: 0 00f1 North Reference: True Reference Well: Plan W-223 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1..00 sigma Reference Wellbore Plan W-223 Database: EDM.15-ANC Prod-WH24P Reference Design: Plan#12 W-223 Offset TVD Reference: Offset Datum Reference Plan#12 W-223 Filter type: GLOBAL FILTER APPLIED.All wellpaths within 200'- 100.1000 c'•efer Interpolation Method: MD Interval 5.00ft Error Model: ISCWSA 'Depth Range: Unlimited Scan Method: Tray.Cylinder North !Results Limited by: Maximum center-center distance of 1.171.90ft Error Surface: Elliptical Conic • Survey Tool Program Date 2192011 From To HO (ft) Survey(Wellbore) Tool Name Description 34.30 900.00 Ptan#12 W-223 iPlan W-223; GYD-GC-SS Gyrodata gyro single shots 900.00 1.900.00 Plan#12 W-223(Plan W-223) MWD MWD-Standard 900.00 2,303.37 Plan#12 W-223(Plan W-223) MWD+IFR+MS MWD+ IFR+Multi Station 2,303.37 3,300.00 Plan#12 W-223(Plan W-223) MWD MWD-Standard 2,303.37 5.436.65 Plan#12 W-223(Plan W-223) MWD+IFR-MS MWD+ IFR-Multi Station 5,436.65 6.500.00 Plan#12 W-223(Plan W-223) MWD MWD-Standard 5.436.65 9,75328 Plan#12 W-223(Plan W-223) MWD+IFR+MS MWD+ FR+Multi Station 2'9t•2011 10:02:15AM Page 2 cf 4 COMPASS 2003.16 Bulk 73 • BPPASSPORT Antieollision Report Corn pany: North America-ALASKA-BP Local Co-ordinate Reference: WeN Plan W-223 Project: Prudhoe Bay TVD Reference: W-223 Plan @ 87_60ft iDoyon 14) Reference Site: PB W Pad MD Reference: W-223 Plan @ 87.60ft i Doyon 14 j Site Error: 0.00ft North Reference: True Reference Well: Plan W-223 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sgma Reference Wellbore Plan W-223 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#12 W-223 Offset IVO Reference: Offset Datum Summary ' Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) jft) I PB W Pad 1IW-200-W 200-W-200 372.68 370.00 125.62 6.78 118.85 Pass-Major Risk • W-200-W-200PB1-W-200PB1 372.68 370.00 125.62 6.93 118.69 Pass-Major Risk W-201-W-201-W-201 340.37 335.00 90.95 6.07 84.88 Pass-Major Risk W-201 DIMS-W-201-W-201 34.40 34.40 89.94 1.23 88.71 Pass-Major Risk W-202--W-202-W-202 210.71 210.00 75.59 3.93 71.67 Pass-Major Risk W-202-W-202L1 -W-202L1 34.80 34.80 75.07 1.23 73.84 Pass-Major Risk W-202-W-20212-W-202L2 34.80 34.80 75.07 123 73.84 Pass-Major Risk W-204-W-204-W-204 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-204-W-204L1-W-204L1 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-204-W-204L2-W-204L2 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-204-W-204P31 -W-204PB1 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-213-'W-213-W-213 38528 380.00 45.49 729 38.20 Pass-Major Risk W-214-W-214-W-214 381.17 375.00 31.32 7.65 23.67 Pass-Major Risk W-214_DIMS-W-214-W-214 34.30 34.20 29.77 122 28.54 Pass-Major Risk ' j W-216-W-216-W-216 579.58 575.00 13.41 11.71 1.72 Pass-Major Risk W-216_DIMS-W-216-W-216 87.60 87.60 15.12 1.87 13.25 Pass-Major Risk W-217-W-217-W-217 521.65 515.00 3123 8.92 22.34 Pass-Major Risk W-217-W-217PB1 -W-217PB1 521.65 515.00 31.23 9.03 22.23 Pass-Major Risk W-217 DIMS-W-217-W-217 87.60 87.60 29.91 1.87 28.04 Pass-Major Risk W--217 DIMS-W-217PB1 -W-217 PB1 87.60 87.60 29.91 1.87 28.04 Pass-Major Risk W-218-W-218-W-218 301.03 295.00 46.90 526 41.67 Pass-Major Risk W-218_DIMS-W-218-W-218 87.60 87.60 44.92 157 43.04 Pass-Major Risk W-219 W-219-W-219 442.61 445.00 109.65 8.48 101.16 Pass-Major Risk W-219-W-219PB1 -W-219 WP 8.0 384.16 385.00 109.16 7.33 101.83 Pass-Major Risk W-219-W-219PB1-W-219PB1 442.61 445.00 109.65 8.59 101.06 Pass-Major Risk W-219-W-219PB2-W-219PB2 442.61 445.00 109.65 8.48 101.16 Pass-Major Risk W-22-W-22-W-22 28926 285.00 230.46 6.05 224.41 Pass-Major Risk W-220-DELETE!!!-W-220P161 34.30 3420 15.07 122 13.85 Pass-Major Risk W-220-W-220-W-220 500.35 500.00 11.08 8.79 2.31 Pass-Major Risk W-220-W-220-W-220 Cont wp 1.0 500.35 500.00 11.08 8.79 2.31 Pass-Major Risk W-220-W-220PB1 -W-220PB1 500.35 500.00 11.08 8.90 2.20 Pass-Major Risk W-220-W-220PB2-W-220 WP 12.0 455.20 455.00 15.31 8.76 6.56 Pass-Major Risk W-220-W-220PB2-W-220P32 500.35 500.00 11.08 8.79 2.31 Pass-Major Risk W-23-W-23-W-23 412.11 420.00 197.77 9.15 188.62 Pass-Major Risk W-23-W-23A-W-23A 410.43 410.00 197.72 9.10 188.62 Pass-Major Risk W-23A_DIMS-W-23A-W-23A 87.60 87.60 194.87 1.87 193.00 Pass-Major Risk W-24-W-24-W-24 348.78 345.00 160.54 6.61 153.93 Pass-Major Risk 2 12011 10:02:15AM �32.e 3:,°4 COMPASS 2003.16 Build 73 1 Project: Prudhoe Bay Site: PB W Pad Well: Plan W-223 Wellbore: Plan W-223 From Colour To MD Design: Plan #12 W-223 34 300 300 500 500 700 From Surface to TD 700 900 Scan interval 100 ft Scale 1 50 900 1300 1300 1500 0 1500 1700 1 1700 _-- 2000 2000 _.__.__ 2500 330 30 1511 2500 _ 3000 4. 220111 • 120 12 litl %� rl t. ,11���".�7,-tup1_ 300.E lam, i 'yah;.• 60 ,14011,W,4.7.-..'444:4,;. i��t ��ij� t •t -i 4`!-' ice /►.. 4 a, �7\ �'�'���lP�� ‘i_ zts aMs^IJ-218 f<::� ji►' i,.4 ,. ► N f =- 1 010.1,41017 �.41‘/, ��". �. 2n_aMsw-zv P81 ' , ►1, • 796 ''-•.,1 r a'W-22DPB1 /r ++;EE S 270 ill :.. 30 90 703 ,, I t 1 *216 0043,1 11-21 t 1-214_DIMiV & -214 1 `,LJJJ i p 598� 1 780 \ a91 3044, w-213FW-21 055 s�o ;�y'-Zo2�w-zo2a� ^10 \ f •'--xp DIMS^Id-20 120 i.0 u3B ` '`.., 1 •' S18 ��5 `5s5 / • 730 W-2 -'-y 691 . _ 784 Mr i 210 °e.. 150 VW „ 44-1 jM•rff- •' 'W- 9W 219PB2 Travelling Cylinder Azimuth (TFO+AZI)['J vs Centre to Centre Separation [50 ft,in] 12 Lei 0 • o csi )1. 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C----1 — V----- , v4 ,:.1;11 (2_05-!---, , . :1:r u i5 .,r l oc ea 0 0 a Page 1 of 3 Schwartz, Guy L (DOA) From: Quinta, Wilson [Wlson.Quinta@ao.bp.com] Sent: Tuesday, February 08, 2011 3:09 PM To: Schwartz, Guy L(DOA) Cc: Saltmarsh, Arthur C (DOA); Smith, Phil G(ASRC); Egbejimba, Uchenna J Subject: RE: W-223i AOR ( PTD 211-006) Guy, You are correct; the target change is based on the result from W-220 and W-202 well. y ova -l- J 6/44.- Thanks k - Thanks for your prompt response, g Ua ' lit/es+ • Nat.0 /•ed:sc.Q PTO Wilson Quinta D Drilling Engineer a�'`- Z- Z8-�� Office: +1 (907) 564 4863 Cell: +1 (907) 632 3271 BP Exploration(Alaska), Inc. GPB Rotary Drilling II, From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: February 08, 2011 2:48 PM To: Quinta, Wilson Cc: Saltmarsh, Arthur C (DOA) Subject: RE: W-223i AOR( PTD 211-006) Wilson, I am assuming this is in response to the OWC issues in the area of W-202 and the need to move the injector BHL to a more favorable location. You will need to send in a revised PTD for W-223 if the BHL is moved more than 500' as you suggest. Just include data that has changed from the original PTD and make sure the AOR is not impacted as well... Be sure and mark the PTD application as"Revision" on the top of the page. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Quinta, Wilson [mailto:Wilson.Quinta@ao.bp.com] Sent: Tuesday, February 08, 2011 2:37 PM To: Schwartz, Guy L (DOA) Subject: RE: W-223i AOR ( PTD 211-006) Guy, I'm writing to get support from you regarding to the approved application for permit to drill number 211-006, Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU W-223 well. vii-mi1 Page 2 of 3 The actual W-223 target was changed to -800' west from the current targets accessed by wp10b directional planning. So, I would like to know from you the procedure to address these changes, if we should just review the approved permit to drill or submit a new permit. The approximate spud date is for 03/16/2011. I'm working on new directional planning and all related documents in order to provide to you. - ow are the revised targets . • •reliminary geotop • • • i the ne an: OBa x=616440 y=5965200 z= -5052 tvdss OBd x=616440 y=5965400 z= -5202 tvdss T.D. - Top OBe Marker + 250' M.D. - no XY specified. Prelim GeoTops for New Plan: G1 -300 SV6 -1205 -1760 -EOCU Base Permafrost -1840 SV5 -1860 SV4 -2005 Fault#1 -2145 SV3 -2470 SV2 -2675 SV1 -3005 UG4 -3360 UG4A -3405 UG3 -3730 UG1 -4260 UG_Ma -4595 UG_Mb1 -4650 UG_Mb2 -4700 UG Mc -4778 SB_Na -4848 SB_Nb -4870 SB_Nc -4906 SB_Ne -4915 SB_OA -5002 SB_OBa -5052 SB_OBb -5087 SB_OBc -5137 SB_OBd -5202 SB_OBe -5270 SB_OBf -5310 Base_SB_OBf -5360 I look forward to hearing from you about the PTD and if you have further questions for me or need additional information, please call or send an email. 3/1/2011 Page 3 of 3 Thanks, Wilson Quinta Drilling Engineer Office: +1 (907) 564 4863 Cell: +1 (907) 632 3271 BP Exploration(Alaska),Inc. GPB Rotary Drilling From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: January 21, 2011 11:46 AM To: Quinta, Wilson Subject: W-223i AOR ( PTD 211-006) Wilson, With injectors a Map view plot of the surrounding wells is required as per 20 AAC 25.402 ( c) (1). A statement that no wells are within 1/4 mile of the injection zone (that includes any wellbore) needs to be backed up with an actual plot showing this. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 3/1/2011 Area of Review-Map of all wellbores within 1/4 mile radius. None well for W-223. Polaris Pool- Markers y— O-UG_Mc(Top of Pool) W-220 - '- \ 0-SB_OBa , . 0-SB_OBf_Base(Base) * 4853 5,968,000 W-218 / 1/4 mi. radius N Circle - .4t, C) ' Centered on A W-223 OBa 64 1 I W-223 wp12 5,966,000 r W-217 I� 4-491► ` X I-)1 \___. -463,, �� 13 f U 1/4ki 5,964,00D W-216 w .+or. 4. -2-21 .-�►,W-201 0, 4- 4 1 /I -- 10 .-- I P`1 0 Al ,---- W-215 /4i� -4695 _- -5415 5,962,000 - _ iletig L\ A\'' -ilik Schrader Bluff SB_OBa Depth Map (20' contour interval) No Wells within 1.4 mile of W-223 In the Schrader Bluff Pool V W-223i Permit Application Page 11 TRANSMITTAL LETTER CHECKLIST 1 WELL NAME / EI/ /rv- Z ?3 �,G'c"vAs/ 0 PTD //0006 Development ✓ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: �.e!/Q/7DE___0A/ POOL: ce/Di✓����:Ll/2' Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER 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 between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well . SPACING The permit is approved subject to full compliance with 20 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 occur. 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. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 0 -o o I- 'a CO0 -a 3 o n o cn a o cn v cn $ yt �. 3G) co m 0) r. 1 13 0 �.00 N W 7 N a) 0 m (J) O(0. co" 0 N 0 N 0 O C) 773 N O 0 O' co O CD CO CJ G.) CO W W W W W CO N Ni Ni N Ni N.) N Ni Ni N -' ' CO CO V 0) C) A (w) N - - 0 n I CO CO V a) (T A W N - 0 CO CO V 0) (T A W N - 0 CO CO 6) O1 A W N - 0 V D m 0 u) (n 0 m K F * 0 W 00 0 D �. D C) O O O 0 O m D * O v 13 O O =, (n * * * C r -o z ? ° 0 0 CD CD N CD CD 7- p p 2• 0_ n 0 n 0) c O = N CD (D -a "a n c 7 (D (D O X w (u -o ° o = m m v_ -r -i E m c (D m CD 35 m m m v o- 0 3 0) m i- m m < a a -� -� v a = 3 < _ 31-17E DiF b D SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, PBU W-223 BP Exploration (Alaska), Inc. Permit No: 211-006 Surface Location: 361' FNL, 1176' FEL, SEC. 21, T11N, R12E, UM Bottomhole Location: 5203' FNL, 1165' FEL, SEC. 10, T11N, R12E, UM Dear Mr. Egbejimba: 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. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2 s day of January, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKAC i. , i • ALASK 'L AND GAS CONSERVATION COMMIE N PERMIT TO DRILL ,:'.N "I 8 2011 /*"/"' 20 AAC 25.005 ta la.Type of work: lb.Proposed Well Class: 0 Development Oil ®Service-Winj 0 Single Zone 1 c•^SReif' ! i _ .::' :AIN ® Drill 0 Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply A Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp ❑"Sialeirrs 2. Operator Name: 5.Bond: 0 Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 619 193 PBU W-223 3. Address: 6. Proposed Dept s. 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 10415' TVD 5508' Prudhoe Bay Field/ hoe 1 yl•ll s 4a. Location of Well(Governmental Section): 7. Property D=.ignation(Lease Number): Bey- pbp1 Surface: ADL 0 .263-2,028263-1,028261 S.Li'-c 1' ' 15144 O ( Poe i 361' FNL, 1176'FEL, SEC. 21,T11N, R12E, UM Top of Productive Horizon: 8. Land U e Permit: 13. Approximate Spud Date: 416'FNL, 1174'FEL, SEC. 15,T11N, R12E, UM March 16,2011 Total Depth: 9.Ac :- in Property: 14.Distance to Nearest Property: 5203'FNL, 1165'FEL, SEC. 10,T11N, R12E, UM 2560 23,230' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 1#.KB Elevation above MSL: 87.60 feet 15.Distance to Nearest Well Open Surface: x- 612049 y-5959896 Zone- ASP4 GL Elevation above MSL: 53.30 feet to Same Pool: 3580' 16.Deviated Wells: Kickoff Depth: 250 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 69.37 degree- Downhole: 2412 Surface: 1861 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Couplin Length MD ND MD ND (including stage data) 42" 20" 129.5# X-65 WL 80' Surface Surface 80' 80' —260 sx Arctic Set 16" 13-3/8" 68# L-80 BT 2303' Surface Surface 2303' 2013' 491 sx Arctic Set Lite:981 sx Class'G' 12-1/4" 9-5/8" 40# L-80 B C 3885' 2150' 1912' 6038' 3418' 196 sx LiteCRETE: 1045 sx Class'G' 8-3/4" 7" 26# L-80 V TopHC 10495' Surface Surface 10495' 5508' 71 sx LiteCRETE:332 sx Class'G' 19. PRESENT WELL C DITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): lugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): Casing Length • Cement Volume MD TVD Conductor/Structural Surface Intermediate Production ( i‘lli\ T1 I Liner 1�1 e, i 1 Perforation Depth MD(ft): U Perforation Depth ND(ft): 20.Attachments: 0 Prope Plat 0 BOP Sketch _• Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 MC 25.050 Requirements 21. Verbal Approval: ommission Representative: Date: SA- 22. I hereby certify that a for-•oing is true and correct. Contact Wilson Quinta, 8`1-123 Printed Name oh 'f--ji,ba Title Engineering Team Leader Prepared By Name/Number . Signature C - Phone 564-5859 Date I 2_o,, Elizabeth Barker,564-4628 Commission Use Only Permit To Drill API Number: Permi r Da See cover letter for Number: o2IIOC� 50-00?9,2's1y�0� Vfr) �. other requirements Conditions of Approval: If box is checked,well�not be used to explore for,test,or produce comethane,etgas hydrates,or gas contained shales: Wf Other: k405° 'Ds` 1.3 aP Te----SF �-r—� Samples Req'd: 0 Yes U No Mud Log Req'd: ❑Yes liNo 1`Z S-00 S& /4 n"- � , `s� �S Measures: ' 'Yes 0 No Directional Survey Req'd: Yes 0 No l� L Al / .- Mir G,SL fc1 k�'r� �j/ Z..5 / APPROVED BY THE COMMISSION C �J ` ! Date ,COMMISSIONER Form 10-401 Revised I /2009 This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit In Duplicate ORIGINAL 712/1/ 0,7„ t , Well Name: W-223 Drill and Complete Plan Summary Name Position Office Home Cell Wilson Quinta Drilling Engineer 4863 929-3984 632-3271 Joe Turak Geologist 4204 644-4855 250-2425 Bob Dawson Ops Geologist 5264 345-3359 242-2391 Taylor West Pad Engineer 4647 337-2028 632-0111 Type of Well (service/producer/ injector): Water Injector ✓ Surface Northing Easting Offsets TRS Location 5,959,896 612,049 4918' FSL/ 1176' FEL 11N, 12E, 21 Northing Easting TVDss Offsets TRS Locaget 5,965,200 617,240 -5050 4863' FSL/ 1174' FEL 11N, 12E, 15 on5,965,400 617,240 -5200 5063' FSL/ 1170' FEL 11N, 12E, 15 Bottom Northing Easting TVDss Offsets TRS Location 5,965,693.32 617,240 -5420 76' FSL/ 1165' FEL 11N, 12E, 10 API NUMBER: Rig: Doyon 14 Estimated Start Date: 03/16/2011 Operating Days to complete: 25.36 MD: 10495' TVD: 5507' RT/GL: 34.3'/53.3' RTE: 87.6' Well Design: Grassroots Schrader Bluff Injector 3-1/2" tbg, 9.2# L80, TC-II, multi-packers, zonal injection Objective: Multi-zonal injector into Schrader Bluff OBa, OBc and OBd sands Directional Plan: Version: Schlumberger P10b KOP: 250' MD, build 1.5°/100' Maximum Hole Angle: 69.37° Close Approach Wells: All wells pass major risk criteria. Reference anti-collision report Nearest well within Pool W-201 @ 3580' Distance to Nearest Property 23,230'to PBU boundary Line: W-223i Permit Application Page 1 Wells within 1/4 mile of this injection well: Well Name Dist, Ft. _ Annulus Integrity Comments NONE Logging Program: Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole: None Intermediate Interval Drilling, MWD: GR Open Hole: N/A Cased Hole: N/A Production Interval Drilling, MWD: GR, RES, NEU,Azimuthal Density PWD Open Hole: None Cased Hole: USIT-GPIT(PDC mode via tractor) Mud Program: 16" Surface Hole: Fresh Water Drilplex Mud Density Funnel Viscosity LSYP Yield Point API FL �H (ppg) (seconds) (2x3-6 rpm) (Ib/i00ft)— (mis/30min) Spud to Base 60-120 (for reference Perm 8.8—9.5 only. Fluid should be 30—50 40—80 <_8 10.8 run off LSYP) Base Perm to 60-120 (for reference TD 9.0—9.5 only. Fluid should be 28—45 40—80 <_6 10.8 run off LSYP) 12 1/4" Intermediate Hole: LSND Density Funnel Viscosity LSYP Yield Point API FL g_H (ppg) (seconds) (2x3-6 rpm) (Ib/100ft ) (mis/30min) Csg Shoe to 8.8—9.5 60-120 (for reference TD only. Fluid should be 28—45 40—80 <_6 10.8 run off LSYP) 8 3/4" Production Hole: LSND Interval Density YP PV pH API (ppg) Fluid Loss Csg Shoe to TD 8.8-9.3 18-24 12- 18 9- 10 <6.0 W-223i Permit Application Page 2 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Connection Length Top Btm Tbg O.D. MD/TVD MD/TVD RTE 42" 20" 129.5 X-65 WLD 80' GL 80'/80' 16" 13 3/8" 68 L-80 BTC 2303' GL 2303'/2013' 12 '/<" 9'/8' 40 L-80 BTC 3885' 2150'/ 1912' 6038'/3418' 8%" 7" 26 L-80 Vam Top HC 10495' GL 10495'/5508' Tubing 3 A" 9.2 L-80 TC-Il 10200' GL 10200'/5330' Comments: Tbg crossover to 4 'A"just below tree Formation Integrity Testing: Test Point Depth Test Type 13-3/8" Surface Casing 20'–50' of new hole below LOT Test Point Depth Test Type 9-5/8" Intermediate Liner 20'–50' of new hole below LOT Cement Calculations: Surface Casing: _Casing Size 13'/8" Basis: Lead: Open hole volume+250% excess in permafrost. Port collar used if necessary. Lead TOC: Surface — Tail: Open hole volume+250%excess in permafrost and 40%excess below permafrost+ 80' shoe track. ✓ Tail TOC: 800' MD above the casing shoe(1503' MD) Total Cement Volume: Lead 388 bbl/2176 ft /490 sks of Arctic Set Lite at 10.7 ppg and 4.44 cf/sk Tail 201 bbl/ 1131 ft5/983 sks of Class'0' at 15.8 ppg and 1.15 cf/sk Intermediate Liner: Casing Size 9 618" Basis: Lead: Open hole volume with 40%excess. Lead TOC: 200' above liner top (1953' MD) Tail:Open hole volume 40%excess+80' shoe track. Tail TOC: 2500' MD above the liner shoe(6038' MD) Total Cement Volume: Lead 155 bbl/868 ft / 195 sks of LiteCRETE at 11 ppg and 4.45 cf/sk Tail 214 bbl/ 1199.6 fti/ 1043 sks of Class`G'at 15.8 ppg and 1.15 cf/sk Production Casing: Casing Size 7" Basis: Lead: Open hole volume with 30%excess. Lead TOC: No higher than 1000' MD below drilling liner shoe. (7038' MD) Tail: Open hole volume with 30%excess+ 80' shoe track volume, ID 6.276" Tail TOC: 8637' MD(500' MD above Ma) Total Cement Volume: Lead 56 bbl/312.5 ft'/70 sks of LiteCRETE at 11 ppg and 4.45 cf/sk Tail 68 bbl/380 ft'/331 sks of Class`G' at 15.8 ppg and 1.15 cf/sk W-223i Permit Application Page 3 , Formation Markers: Co mlercra' E . Fa c>atron Tops i_lneertaircy , 14yd~cea'bon Roaring Est Pore Press. Est Porn Pr ASS*. Formation 17-V ss! (feet! iYesirlb! (Py) ow 0,11,V) NOTE:All formation tops are required from 1007 above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells G1 -300 +-50' No 135 8.7 SV6 -1205 el-50' No 542 9.7 Base Permafrost -1840 i-/-50' No 828 8.7 SV5 -1960 +1-50' No 837 9.7 Poss.Free gas or Gas SV4 -2005 +/-50' H.'tates 902 8.7 Fault 81 -2145 +l- 150'M.D.-See Fault Section for Details Poss.Free Gas or Gas SV3 -2470 +r-50' H,'_tates 1112 9.7 Puss.Free Gas or Gas SV2 -2675 +,-50' 14,4ates 1204 8.7 Pnss.Free Gas or Gas SV1 -3005 +1-50' Hyiates 1352 8.7 UG4 -3360 el-50' Thin:cels. 1512 8.7 UG4A -3405 +1+-50' Heavy Oil clown to-3539'55 1532 9.7 UG3 -3735 +11-50' Na water. Thin•cels. 1681 8.7 UG1 -4265 +,+-50' No.water 1919 8.7 ' UG Ma -4605 +1-50' No.water 2072 8.7 UG Mb1 -4655 el-50' Hea•ry oil possible 2095 8.7 UG_Mb2 -4705 +1-50' No.water 2117 8.7 UG Mc -47.80 +1-50' No.wafer 2151 8.7 SB Na -4850 +1-50' No.water 2183 8.7 SB Nb -487.0 +i-50' No.water 2192 8.7 SB Nc -4905 +1-50' No.water 2207 9.7 SB_Ne -4914 +1-50' No.water 2211 9.7 SB OA -5000 +1-50' No,water 2250 8.8 SB OBa -5050 e:-50' No.water 1865-2146 7.3-.8.4 SB OBb -5085 +1-50' Yes 2221-2300 8.4-8.7 SB OBc -5135 +1-50' Yes 2134-22)6 8.0-3.6 SB_OBd -5200 4-50' Yes 1893-2271 7.0-3.4 SB OBe -5270 +i-50' No 2372 8.7 SB OBf -5310 +1-50' No 2390 8.7 Base SB OBI -5360 +1-50' No 2412 8.7 TD -5400 Well TD Criteria T.D.is 250'MD past Top_OBe marker. (ie ??ft ND,??ft Rathole,etc.) • Comments Formation Fressur from sulfate to the Ma are calculated based on a.450 water gradient. Formation pressures from the UG Ma dawn to the SB_OA are Lowed on W-200PB1 RFT pressures taken before start of W Pad Schrader Bluff prc•duction. Formation pressures in the SB_OBa through SB_OBd sands are estimated and assume these sands will show pressure depletion resulting from offset producers W-204 and W-201. Review Schrader Bluff Formation pressures after adjacent injector W-220i is drilled(October,2010). Well Control: 16" holes will be drilled with diverter. The 12-1/4" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. W-223i Permit Application Page 4 Diverter, BOPE and drilling fluid system schematics of Doyon 14 are attached to this permit to drill. Production Interval- • Maximum anticipated BHP: 2412 psi @ 5507' TVD, 8.4 ppg EMW • Maximum surface pressure: 1861 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: • Annular Preventer 250/2500 psi • Rams 250/4000 psi • Planned completion fluid: 9.0 ppg brine/6.8 ppg diesel (10495' MD, also TD) Kick Tolerance/Integrity Testing Summary Table Casing and Casing Maximum Influx Mud Exp Pore LOT/ Interval Test Volume Weight Press FIT Pressure 133/8" Surface 3500 psi 42 BBLS (assuming 9.2 8.8 LOT -' Casing 11.0 LOT) 95/8" Intermediate 3500 psi 57 BBLS (assuming 9.2 8.8 LOT Liner 11.0 LOT) 7" Production 4000 psi NA NA NA NA Casing Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. 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. W-223i Permit Application Page 5 • Drill and Complete Procedure Summary Pre-Rig Work: The 20" insulated conductor is installed. 1. Weld an FMC 13-3/8" landing ring for the FMC bigbore well head on the conductor. 2. If necessary, level the pad and prepare location for rig move. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Doyon 14. Nipple up diverter spool and function test diverter. ' 2. PU & stand back 5" DP as needed. MU 16" drilling assembly with MWD/GR. Directionally drill surface hole to the base of permafrost. CBU or until hole is clean, then POOH and lay down BHA. 3. Run and cement the 13-3/8", 68.0 lb/ft L-80 surface casing to surface with the Tesco CDS Tool, . displacing cement with mud. 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test rams @ 4,000 psi /250 / psi, and annular to 2500 psi/250psi. 5. Pressure test the 13-3/8"casing to 3500 psi for 30 minutes. 6. MU 12-1/4" drilling assembly with MWD/GR and RIH to float collar. Drill shoe track and displace to new 8.8 ppg LSND mud. Drill new formation to 20-50' below 13-3/8"shoe and perform LOT. 7. Drill ahead to TD in the SV1. CBU or until hole is clean, then POOH laying down 5" DP, and lay down • BHA. 8. Change to 9-5/8"casing rams and test. 9. Run and cement the 9-5/8", 40.0 lb/ft L-80 drilling liner with 150' overlap into the 13-3/8". Displace cement with mud and set hanger/liner top packer. POOH. 10. PU and stand back 4" DP as needed. MU 8-3/4" drilling assembly with MWD/GR/Res/Azi- Den/Neu/PWD and RIH to 9-5/8" float collar. Pressure test to 3500 psi for 30 minutes. Drill shoe track and ensure 8.8 ppg LSND mud is in good condition. Drill new formation to 20-50' below 9-5/8" shoe and perform LOT. 11. Drill ahead to production hole TD 250' below the top of OBe. Clean and wipe hole. POOH. 12. Change to 7" rams and test prior to running casing. 13. Run and cement the 7", 26#, L-80, BTC-M x TCII production casing. Displace the casing with 9.0 ppg ,,, brine, and 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 13-3/8"annulus. 14. PU DPC guns and RIH to shoot 149' of perfs with of 4.5" Power Jet 4505 5 spf, pert guns with GR/CCL for gun correlation. W-223i Permit Application Page 6 15. Once correlated correctly, confirm cement compressive strength is at least 1,000 psi before firing. Perforate the OBa, OBc, and OBd sands. POOH stand back DP and lay down guns. 16. Make clean out run using DP. 17. RU Schlumberger E-line. RIH with gauge ringand basket to recover anyperf debris. Repeat until 9 9 9 junk clean to at least 50' below the bottom perforation. 18. Run USIT/GPIT log following Primary Depth Control procedures as USIT log will be primary dept control for future well work. 19. Run the 3-1/2", 9.2#, L-80, TCII completion with a 7" x 3-1" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TCII threaded tubing. Top packer must be within 200' of OBa perfs. Confirm that packers are on depth using E-line. er lc M 20. Run in the lockdown screws and set the packers. , then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 21. Install and test FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Pull TWC. 22. Freeze protect the well to 2,500'TVD by pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u- tube into tubing. 23. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-1/2" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 24. Rig down and move off. Post-Rig Work: 1. R/U slickline and pull ball and rollers/RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pump RG2401 on top of surface casing cement. 5. Pull VR plug. 6. Install wellhouse and flowlines. W-223i Permit Application Page 7 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control/Reservoir Pressures: Interval Psi (EMW) TVDss MD Schrader Bluff 1893-2412 5015- 10128- Sands (7.0-8.7) 5508 10495 II. Hydrates and Shallow gas: A. Free gas and/or gas hydrates may likely be present in the SV5 through the SV1 surface hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. Set ✓ surface casing below deepest SV1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. III. Running Gravels: A. Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. Hazards include wood and cobbles, lost circulation, and tight hole problems while drilling and running casing. See W Pad Data Sheet for details. B. Recent W Pad wells have experienced tight hole, running gravels, and lost circulation with drilling and running casing in Permafrost interval. Use best practices for drilling and lining surface hole interval. Base plan is to use the Tesco CDS casing running tool to address this problem for 13- 3/8" casing. IV. Faults Formation Where MD Throw Encounter Fault Intersect tvdss Est.Throw Direction Uncertainty Fault#1 - SV4 2731 -2145 -10' to -30' West +/- 150' M.D. V. Kick Tolerance/ Integrity Testing: A. The 13 3/8" casing will be cemented to surface using a port collar at 1000' if necessary. The 9 5/8" intermediate liner will be cemented to the top of the 9 5/8" liner. The 7" production casing will be cemented to at least 500' MD above the Ma and no closer than 1000' below 9-5/8" intermediate shoe. Kick Tolerance/Integrity Testing Summary Table Casing and Casing Maximum Influx Mud Exp Pore LOT/ Interval Test Volume Weight Press FIT Pressure 133/8" Surface 3500 psi 42 BBLS (assuming 9.2 8.8 LOT Casing 11.0 LOT) 95/8" Intermediate 3500 psi 57 BBLS (assuming 9.2 8.8 LOT Liner 11.0 LOT) 7" Production 4000 psi NA NA NA NA Casing W-223i Permit Application Page 8 VI. Lost Circulation/Breathing: A. Lost circulation potential when crossing Fault#1. No faults expected in the reservoir interval. Follow LCM decision tree; reduce mud weight slightly. B. Minor pressure depletion of OBa, OBc, and OBd zones from W Pad Polaris off take. Follow LCM decision tree; reduce mud weight slightly. VII. Broaching A. Monitor adjacent wells for broaching while drilling surface hole. VIII. Heavy Oil A. Heavy oil is expected in the UG4A and M sand intervals which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones. IX. Hydrogen Sulfide A. All W Pad gas lift wells are expected to have H2S levels in the 5 to 60 ppm range; result of PBU gas lift gas. This site should be treated as an H2S site with all the required precautions. Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level W-204 12 ppm 11/9/2009 #2 Closest SHL Well H2S Level W-201 18 ppm 10/8/2009 #1 Closest BHL Well H2S Level W-201 18 ppm 10/8/2009 #2 Closest BHL Well H2S Level W-205 20 ppm 1/15/2010 Max. Recorded H2S on Pad/Facility W-01 60 ppm 8/16/2005 Other Relevant H2S Data: All W Pad gas lift wells are expected to have H2S (H2S alarms from rigs, etc.) levels in the 5 to 60 ppm range. CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION W-223i Permit Application Page 9 NEL LhEAD- Ff,IC PROPOSED W-223 SAFETY NOTES: AC711,+41ON• Mild . 101 d.@#* 31,4' B* ELEV* 19.3 1 L -1 f I 23' H4-117 X 3-117'x0,n•2.110? KOP. ab; Ms[Angle. diplif 1 Dew*MD- 1 la'CONDUCTOR �'T 1 2110' H 133#0'x 9-841r DXR ZXP LTA/Henj Dsh+r ND- 54 NC AID,WILCOX D*11124' 113-3 5 C5 3 t359 L-e0,OTC ID=12 415` H 2303' rt I I f 3600' Hyl 1fl rem it ill ID"2.01D' 6-W LNX,04,L40,We,0-8.0 — ewe. ` A I VIER I 11BGTIGN 11ANDIiF1,S ST MD 1Vt) CH/ TYPE VLV LATCH PORT {ATE. a huG3 DCR 5 MMC1-W 4 MMGW 3 WOW 2 Iw 1 8143-W 1141?PI-PJ0041 w f-63, '.a•:s. 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N N > N ; V E 3fV t { c 5y O W $ o u 2 ' u t i U W O O r lk Ark. 8 f0 4 d� aa; a M 1 C4 i Cil u u a O O o O O O 0 O 0 N t0 «< N (8)00ZI:(w)L=aje0g s >» BPPASSPORT Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan W-223 Project: Prudhoe Bay TVD Reference: W-223 Plan @ 87.60ft(Doyon 14) Reference Site: PB W Pad MO Reference: W-223 Plan @ 87.60ft(Doyon 14) Site Error: 0.00ft North Reference: True Reference Well: Plan W-223 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan W-223 Database: EOM.16-ANC Prod-WH24P Reference Design: Plan#10 W-223 Offset TVD Reference: Offset Datum Reference Plan#10 W-223 Filter type: GLOBAL FILTER APPLIED All wellpaths within 200'+100/1000 of refer Interpolation Method: MD Interval 5.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,246.11ft Error Surface: Elliptical Conic Survey Tool Program Oats 12/21/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 34.30 900.00 Plan#10 W-223(Plan W-223) GYD-GC-SS Gyrodata gyro single shots 900.00 2,303.37 Plan#10 W-223(Plan W-223) MWD+IFR+MS MWD+IFR+Multi Station 2,303.37 6,038.07 Plan#10 W-223(Plan W-223) MWD+IFR+MS MWD+IFR+Multi Station 6,038.07 10,495.38 Plan#10 W-223(Plan W-223) MWD+IFR+MS MWD+IFR+Multi Station I 12/21/2010 9:20:29AM Page 2 of 4 COMPASS 2003.18 Build 73 BPPASSPORT Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan W-223 Project: Prudhoe Bay TVD Reference: W-223 Plan @ 87.60ft(Doyon 14) Reference Site: PB W Pad MD Reference: W-223 Plan @ 87.60ft(Doyon 14) Site Error: 0.00ft North Rehrence: True Reference Well: Plan W-223 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan W-223 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#10 W-223 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB W Pad Plan W-221-Plan W-221 -Plan#12 W-221 689.24 685.00 57.26 13.29 43.99 Pass-Major Risk W-200-W-200-W-200 372.68 370.00 125.62 6.78 118.85 Pass-Major Risk W-200-W-200PB1-W-200PB1 372.68 370.00 125.62 6.93 118.69 Pass-Major Risk W-201-W-201-W-201 340.37 335.00 90.95 6.07 84.88 Pass-Major Risk W-201_DIMS-W-201-W-201 34.40 34.40 89.94 1.23 88.71 Pass-Major Risk W-202-W-202-Plan#7 W-202 OBd 364.39 365.00 75.95 7.00 68.95 Pass-Major Risk W-202-W-202-W-202 34.80 34.80 75.07 1.23 73.84 Pass-Major Risk W-202-W-202L1-Plan#7 W-202L1 OBc 364.39 365.00 75.95 7.00 68.95 Pass-Major Risk W-202-W-202L1-W-202L1 34.80 34.80 75.07 1.23 73.84 Pass-Major Risk W-202-W-202L2-Plan#7 W-202L2 OBa 364.39 365.00 75.95 7.00 68.95 Pass-Major Risk W-202-W-202L2-W-202L2 34.80 34.80 75.07 1.23 73.84 Pass-Major Risk W-204-W-204-W-204 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-204-W-204L1-W-204L1 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-204-W-204L2-W-204L2 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-204-W-204PB1 -W-204PB1 295.76 290.00 61.60 6.42 55.18 Pass-Major Risk W-213-W-213-W-213 385.28 380.00 45.49 7.29 38.20 Pass-Major Risk W-214-W-214-W-214 381.17 375.00 31.32 7.65 23.67 Pass-Major Risk W-214 DIMS-W-214-W-214 34.30 34.20 29.77 1.22 28.54 Pass-Major Risk W-216-W-216-W-216 579.58 575.00 13.41 11.71 1.72 Pass-Major Risk W-216_0IMS-W-216-W-216 87.60 87.60 15.12 1.87 13.25 Pass-Major Risk W-217-W-217-W-217 521.65 515.00 31.23 8.92 22.34 Pass-Major Risk W-217-W-217PB1-W-217PB1 521.65 515.00 31.23 9.03 22.23 Pass-Major Risk W-217_DI MS-W-217-W-217 87.60 87.60 29.91 1.87 28.04 Pass-Major Risk W-217_DIMS-W-217PB1-W-217 PB1 87.60 87.60 29.91 1.87 28.04 Pass-Major Risk W-218-W-218-W-218 301.03 295.00 46.90 5.42 41.51 Pass-Major Risk W-218_DIMS-W-218-W-218 87.60 87.60 44.92 1.87 43.04 Pass-Major Risk W-219-W-219-W-219 442.61 445.00 109.65 8.48 101.16 Pass-Major Risk W-219-W-219PB1-W-219PB1 442.61 445.00 109.65 8.59 101.06 Pass-Major Risk W-219-W-219PB2-W-219PB2 442.61 445.00 109.65 8.48 101.16 Pass-Major Risk W-22-W-22-W-22 289.26 285.00 230.46 6.05 224.41 Pass-Major Risk W-220-DELETE!!!-W-220PB1 34.30 34.20 15.07 1.22 13.85 Pass-Major Risk W-220-W-220-W-220 500.35 500.00 11.08 8.79 2.31 Pass-Major Risk W-220-W-220-W-220 Cont wp 1.0 500.35 500.00 11.08 8.90 2.20 Pass-Major Risk W-220-W-220 Pb2-W-220 PB2 500.35 500.00 11.08 8.79 2.31 Pass-Major Risk W-220-W-220PB1 -W-220PB1 500.35 500.00 11.08 8.90 2.20 Pass-Major Risk W-23-W-23-W-23 412.11 420.00 197.77 9.15 188.62 Pass-Major Risk W-23-W-23A-W-23A 410.43 410.00 197.72 9.10 188.62 Pass-Major Risk W-23A_DIMS-W-23A-W-23A 87.60 87.60 194.87 1.87 193.00 Pass-Major Risk W-24--W-24-W-24 348.78 345.00 160.54 6.61 153.93 Pass-Major Risk 12121/2010 9:20:29AM Page 3 of 4 COMPASS 2003.16 Build 73 Project: Prudhoe Bay Site: PB W Pad Well: Plan W-223 Wellbore: Plan W-223 From Colour To MD Design: Plan#10 W-223 34 300 300 500 500 700 From Surface to TD 700 900 Scan interval 100 tt 900 1300 Scale 1 : 50 1300 1500 All wells pass Major Risk 0 1500 1700 t7 1700 2000 2000 2500 330 Plan W-221iPbn 1112 W-221 30 1['a 2500 3000 15 1 1199_1 12 4A �' + 2 wp 1.0 1103— .1, �� 1► v� 10+ 300+�( + .PB1 1005 60 Y 4„; eliiik."4‘4,. 'ti‘' , , /..rz,\ ,--...._ , W-216NV-216 4AIIIP Q3 '' c2_____. `,- �-_-. 11l 1088 41001 , 796 i?. 20NW220P81 993 6:: . .:11 .- 11• 270 9211_ d0 60.0: 90 \ 703 ' ' 05 •05 '•,, 780--_ 691/ d0 W2131N-213 05 30 f -2021W-2021.2 240 i tt+i+,. 120 I 7 088 .. tl+.Y + :\4„....-,-," t 695T88 +C )t,, W204NV-204 1 mt/.- - 40114 ;t Tti1' 'N \, , ' 6 W-214NV-214 -41�a4i. + 1. i W-201/W-201 . 210 '\ /;. ! \ 150 -W-200/W. +,•:x'1071 4 - 500 W-24PN•24'W-202120132+W-219/W-219P82 180 Travelling Cylinder Azimuth(TFO+AZI)(°i vs Centre to Centre Separation[50 Mn] • Project: Prudhoe Bay Site: PB W Pad Well: Plan W-223 From Colour To MD Wellbore: Plan W-223 Design: Pfan#10 W-223 34 300 300 500 500 700 From Surface to TO 7700 900 Scan interval 100 900 1300 Scale 1 : 10 All wells pass Major Risk 1300 1500 0 1500 1700 \ 1700 2000 530 !1/0171w•217P8 ` 1 / i 30 2000 2500 �„�.�_- . 2500 3000 ' 300 --'-'� \ 60 illi .i20P81 /,'' t(\ W1/4110k00, ,; W-220�Vv220PR1?41.0 � , 7 6 I _. 270 , r. 190 W-218/W-216 u„n ` 3 1 f 703 j 604 N I i 505 j •306 l 240 ...,/ r 120 2 210 ti '4'. 1 150 /3 W-214/W-214 180 Travelling Cylinder Azimuth(TFO+AZI)[°]vs Centre to Centre Separation[10 Mn] eve d a p d S. �, ' HV) Z 2O °1u o W = �' c �+ co 0 tilio J 3 z o� z ii 011116 r o Cil 3taNt 11 4k, 0 V/ ED ©1 411 1 \ al II, � Q1 4, LL. co �\ oa? i .. , _ - 4 kW . * T4W 0 0 . Dill -• 411' €,7 , 4r l1 0 III 't cu GJ 41 .,ii,L ,‘ .> .r 4 0 4 t (5 O Q ;to � W m E- cQ m m onn M 71 iz:AMIO Y (Sp < 2V, 2 a 2 Nt. I ,:VW. W p' aro lift " Po m 6 �= a FNM (IIID Illillimii w ` m — N11:t giii SR �.tq, NRPV-11 ,741Q 1aO.;17, <.18"1"rVD YCNNrvN NISI.�✓1.Nr1.h.7V.�Irv.71 1✓2 .0 Qp� V 70 �p .9h NNNNNNNNNN NNNN ..1..i.- 1h 7r'j✓IhMr'Irj.�ir.lr..i'f+iH.-ih.i.-.'1r.j,.,--f a O S' Ya ighl go, w �� IT LJ IPG. a..„—Nn+No..00v. • „ naAron.9, Hams, vlto"(In Nur.wm -N" r v ._.')✓i/1H,!.j h.•i K h� '1 nA %.h Ji N N vl=b b b.d(p.c 'b 0rA�y d+ % A0: 1' to ase, g _ s ! g 0 g '4. iOWo-cA0v(�Tj(�nONoir4W.5%v.O (Vt f�/ty .”. .^lr'].Ph E..g. N.�/ '✓10.4, i +3 .-NN.iNNO4 NNNNNN NNNN1NNNNNN(VNSV(vNN(.iNN a =`Q _ R II ✓s r..,a.„ ,(y,PO,,, .W ,,,, ,,,..nN1V ,,,,--n,,,, 1_ aov01.0aivev NOIp Q I0 �•__•—•-• . -Fia VI s so I re..0017 1 h r r —, P. EL_ L , 0______ ...... •.11 P c. I I V U i 0 LL 3.50 ; x.., A . • ... A ! - •.....-'7 -----i i , 5 ---..„.. -k-,,:-.-,-1 • k i.i 1 II 11-11- -r - ..0 .,f LL tali 6. tei I I —....r1\13 1111 1 ., .e- la L . 7 41;1 1 i ili ..,— \ N..., -1,. 4 i (4-i V 0‘,5 : *i NI. . 4- 4) . 0 gig q•-- / t... .. I I NI---- \-II ' 2't) ----x–i ' . --- _–\ '7T ® I- 1 11 k ay..1 :7, - _.., — ' a. 1 ".—.—/ . _T _ ii..._____. ..- 11Iiii, It :\. -,..., ' . 0 ._. D.,_ . Ei vx 1- ir":--; . 1.x..2 _.,. . • s_ .. ocx0) 5.! „....,, s 00 / ....... 0 .....10 • • , ...0 34 § 4a. 2..„. "1- 1 • t„.. . " .., .. .. . i A F c 7., i 010 . N , 00 gg • a --I • . ,... c41-) r.: ••I' . .L--- b I 00 rcw : ....e • ',dt\Y1 ..r . I t • IIN L..... 1.4 1 ..-- ,4 I .. 1 a I L.-/ " TIII:111ELilf— 4 1E571 0 I t --.): r71, .i< , ._... , ri I F 1'f I( 111T1 I 1 • q j "f"." • 'N---)e 3 C-31-1„ A 1 I . "--1 .f w .., t... e• .7 r * - tc ,s. " e: e• .. 4., 4 r,-xi' e 1 S•q!: 1 4TrL,, tcril. ! 41 • !.1 r. .._..s i ,r, ..: n 51 il 1 rz v , 17i. ' .d*•• • „ e4y. .I. Ir.e4 7.---: '—' , CI• r , irrl (---§_ -I- v It--I V i."1-.. ;1 - •• ., - .. a ... 0 0 a 0 0 0 0 0 ci- [..1 PLI r-,1 U) ., ri §ii , ,JL ii 1 t '' v g . 6. . 0 s a k = • 4 = oI of ril r . A �, > ry n v a .p nO •Q 37 f 13 E 1 ^ I Wit Ft1t � - 444440 1/1tir ,� z zii� n i © .3 o. O _ °;' c z l Ali g g R r b g Ake fl 5 5 w ; t.'s, 1 , t ---- .- - -------€4== II ini* < -- I of I I 1 lie -- . e,'( -r-;:--- I ,ci i _ i Page 1 of 1 Schwartz, Guy L (DOA) From: Quinta, Wilson [Wilson.Quinta@ao.bp.com] Sent: Friday, January 21, 2011 2:45 PM To: Schwartz, Guy L(DOA) Cc: Tiernan, Elizabeth P; Stewman, Sondra D; Egbejimba, Uchenna J Subject: RE: W-223i AOR ( PTD 211-006) Attachments: W-223_gtr mile_res map.pdf Guy, Thanks for your prompt response and please have a look attached the 1/4 mile Map area of review and let me know if you need anything. I look forward hearing from you. Best regards, Wilson Quinta Drilling Engineer Office: +1 (907) 564 4863 Cell: +1 (907) 632 3271 BP Exploration(Alaska), Inc. CPB Rotary Drilling From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent:January 21, 2011 11:46 AM To: Quinta, Wilson Subject: W-2231 AOR( PTD 211-006) Wilson, With injectors a Map view plot of the surrounding wells is required as per 20 AAC 25.402(c) (1). A statement that no wells are within %mile of the injection zone(that includes any wellbore) needs to be backed up with an actual plot showing this. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) 1/21/2011 V 0 0 1 No 0 0 0 0 0 0 0 0 0 0 0 1 00 c0 -4 N 1— co co c0 CO iri : IIL CI) CD r !CI:3 a o }' M Ln C N d 0 N O CV .4— d. \ ol ._ " _ .. ....000- 2„,‘,. . 0 E csi. S ;r--) co 40i I 1 cr) or -C N :::. N � - � '� Ls CO c `II IIV 2 cn M� Z NI ^\ 0 Zi. il s. ica IL; I co 2I O O 'a`a. ( COl ml 03 M co N 2 OOO I O 0 0 0 00 i I M .0 0 ..... o N • I • p Co O ti IirCeW - a VN O gzr �-ll r O O ON `- ■. W cl U E 41) X 0 W O O L. jLO m cra .N. 0 CL W o Co O o O 0 0 0 0 0 0 0 o Nr 0 0 0 0 0 0 0 0 LO 00 cfl CO Ln 1.0 L Alaska Department of Natural '3-sources Land Administration System Page 1 of- F Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources I-- Alaska DNR Case Summary File Type: ADL File Number: 28263 8 Printable Case File Summary See Township,Range, Section and Acreage? (O Yes 0 No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28263 MaP - Search for Status Plat Updates As of 01/19/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/11/1965 Total Acres: 2560.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 10/06/2009 Case Subtype: NS NORTH SLOPE Last Transaction: CHNGTEXT CHANGE LEGAL TEXT Meridian: U Township: 011N Range: 012E Section: 15 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 012E Section: 16 Section Acres: 640 Meridian: U Township: 011N Range: 012E Section: 21 Section Acres: 640 Meridian: U Township: O11N Range: 012E Section: 22 Section Acres: 640 Legal Description 05-28-1965 *** SALE NOTICE LEGAL DESCRIPTION *** C14-59 T11N, R12E, UM 15, 16, 21, 22 2560.00 11-28-1969 SEGMENT 1 T 11N, R 12E, UM SECTION 15: 640 ACRES SECTION 16: 640 ACRES http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=2826... 1/19/2011 Alaska Department of Natural r,sources Land Administration System Page 1 of 1 Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28261 e Printable Case File Summary See Township,Range, Section and Acreage? New Search ® Yes 0 No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28261 Mal) Search for Status Plat Updates As of 01/19/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/11/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 012E Section: 03 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 012E Section: 04 Section Acres: 640 Meridian: U Township: O11N Range: 012E Section: 09 Section Acres: 640 Meridian: U Township: O11N Range: 012E Section: 10 Section Acres: 640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-56 11 N 12E UM 3,4,9,10 2560.00 04-01-1977*** UNITIZED LEGAL DESCRIPTION*** PRUDHOE BAY UNIT TRACT 48 http://dnr.alaska.gov/projects/las/Case Summary.cfrn?FileType=ADL&FileNumber=2826... 1/19/2011 TRANSMITTAL LETTER CHECKLIST WELL NAME ,4'u .0-2,2J PTD# Development V Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: .4/440e".L / POOL: .:),e//L3tT3 1Y'Q/G Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER 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 between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 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 occur. 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. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 D D 0 O g M DD Q O '° 0 r cn c-) -03 0 11 1 o cn Cf) cn v p S. r 3 G) < o co (7,. iv r 13 30 3 :: o m y.co cc G - G co (0 C o 0) 73 CD -- — � _-CO COV 0) COA CON 0 _ CO CO CO CO W CO CO CO C.) CO N N N N N N N N N N V CCO V CA CT A Co) N O CO CO V CA fT A CO N O CO Co CA CJ, A CO N -+ O V m uuM C * n W bob D _« D ,c') c') n n 0) 0 - D * n - v O O � * g * C r -0Z , %J 0 3. 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