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Home My WebLink About203-056 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, February 7, 2018 12:33 PM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD 5;AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Frankenburg,Amy; Peru, Cale Cc: Wallace, Chris D (DOA);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; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: OPERABLE Producer W-23A(PTD#2030560) passed MIT-IA external-email: 0 All, Producer W-23A(PTD#2030560)was put Under Evaluation on 01/25/18 after it was discovered to have sustained inner annulus casing pressure above NOL.On 02/06/18 Slickline set dummy gas lift valves and fullbore performed a passing MIT-IA to 2,912 psi.The passing MIT-IA confirms two competent wellbore barriers.The well will now be classified as OPERABLE. Please respond with any questions. SCANNE Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Fro . K, GWO Well Integrity Engineer Sent: Thu y,January 25, 2018 3:50 PM To: 'Regg, Jame ; DOA) (jim.regg@alaska.gov)'; AK, OPS EOC Specialists; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OP - 2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad HUQ; AK, OP - I 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 1, • OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Bergene, ` . • sew; Frankenburg, Amy; Peru, Cale Cc: 'chris.wallace@alaska.gov'; AK, GWO Comple Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO v ; Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, '. G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, -suis A; Sternicki, Oliver R; Tempel,Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Producer W-23A(PTD #2030560) sustained inner. ulus pressure above NOL All, 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday,January 25, 2018 3:50 PM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers;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; Bergene, Matthew; Frankenburg,Amy; Peru, Cale Cc: Wallace, Chris D (DOA);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; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras 1 Subject: UNDER EVALUATION:Producer W-23A(PTD#2030560)sustained inner annulus pressure above NOL All, Producer W-23A(PTD#2030560)was shut in and discovered to have inner annulus pressure above NOL on 01/20/18. DHD went to diagnose and reported T/I/O pressures of 2,050/2,060/160 psi.The inner annulus pressure was thought to be induced from the gas lift supply which at the time also had a pressure of 2,060 psi.The gas lift was isolated and bled down along with the inner annulus pressure.On 01/24/18 the inner annulus pressure was reported to be 1,420 psi while the gas lift pressure was 1,140 psi.The inner annulus pressure above gas lift pressure indicates sustained casing pressure due to a failed well barrier.The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics and repair. Plan forward: SCANNEV .1,- 1. 1, r1. Slickline—Set DGLVs 2. Fullbore—MIT-IA 3. Well Integrity Engineer—Additional diagnostics as needed. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, August 29, 2015 9:32 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity;AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'jim.regg@alaska.gov' Subject: OPERABLE: Producer W-23A (PTD #2030560) TIFL Passed All, Producer W-23A(PTD#2030560) passed a TIFL on August 28, 2015. This passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate. Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal Wells y�/ Organization SCANNED SEP 0 3 2015 Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com D&C Well Integrity Coordinator Sent: Sunda , ust 23, 2015 2:27 PM To: AK, OPS GC2 OSM;}OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C.--AkiLeline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AKE, ES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Mom Spencer; 'jim.regg@alaska.gov' Subject: UNDER EVALUATION: Producer W-23A (PTD #2030 69.,),Sustained Inner Annulus Casing Pressure over MOASP All, Producer W-23A(PTD#2030560) was reported to have sustained inner annulus case ressure above MOASP on August 20, 2015. The pressures were reported to be TBG/IA/OA= 2120/2120/210 psi. A'tbsequently cold TIFL failed on August 22,2015. As the well is unavailable to be brought online due to surface constraints,`tt a well has been reclassified as Under Evaluation until further diagnostic work can be done. Plan Forward: • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday,August 23, 2015 2:27 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; Burton, Kaity;AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; jim.regg@alaska.gov' Subject: UNDER EVALUATION: Producer W-23A (PTD#2030560) Sustained Inner Annulus Casing Pressure over MOASP Attachments: Producer W-23A (PTD#2030560)TIO Plot.docx All, Producer W-23A(PTD#2030560)was reported to have sustained inner annulus casing pressure above MOASP on August 20, 2015. The pressures were reported to be TBG/IA/OA=2120/2120/210 psi. A subsequently cold TIFL failed on August 22,2015. As the well is unavailable to be brought online due to surface constraints,the well has been reclassified as Under Evaluation until further diagnostic work can be done. Plan Forward: 1. Downhole Diagnostics: Warm TIFL—(If warm TIFL fails) 2. Slickline: Change out orifice gas lift valve 3. Downhole Diagnostics: Re-TIFL 4. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions or concerns. SCANNED AUG 2 4 2015 Thank you, Kevin Parks (Alternate. Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator@bp.com 1 Producer W-23A(PTD#2030560)TIO Plot +ro Amo II Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, July 13, 2015 11:10 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity;AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettus, Whitney; 'jim.regg@alaska.gov'; Morrison, Spencer Subject: UNDER EVALUATION: Producer W-23A (PTD #2030560)IA exceeded MOASP during Proration Attachments: image001.png All, Producer W-23A(PTD#2030560) is now available for diagnostic work. At this time the well has been reclassified as Under Evaluation so that the high inner annulus pressure reported during proration can be assessed. Plan Forward: 1. Downhole Diagnostics: Perform TIFL 2. Well Integrity Engineer: Additional diagnostics as needed Please call with questions or concerns. Thank you, WOWED JUL 1 5 2015 Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G . 0 O.ganftat.u.i WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator(a)BP.com From: AK, D&C Well Integ . Coordinator Sent: Friday, June 12, 2015 9: M To: AK, OPS GC2 OSM; AK, OPS GC2 . d O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Op tions Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East We Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' -, Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projea5-Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettus,'Whitney; 'jim.regg@alaska.gov'; Weiss, Troy D Subject: NOT OPERABLE: Producer W-23A (PTD #2030560) IA exceed MOASP during Proration All, -�-, 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, June 12, 2015 9:57 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS WELL PAD W; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA);Weiss, Troy D Subject: NOT OPERABLE: Producer W-23A (PTD #2030560)IA exceeded MOASP during Proration Attachments: image001.png; Producer W-23A (PTD #2030560) TIO Plot.docx; Producer W-23A (PTD # 2030560) Wellbore Schematic.pdf All, Producer W-23A (PTD#2030560) inner annulus pressure exceeded MOASP on June 09, 2015. A monitor obtained on June 10, 2015 showed pressures of TBG/IA/OA= 2170/2220/230 psi. At this time, the well has been reclassified as Not Operable until the well can be accessed for additional diagnostics post proration. A copy of the TIO plot and wellbore schematic have been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) �� BP Alaska-Well Integrity Coordinator �� JUN 3 WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 1 Producer W-23A(PTD#2030560) TIO Plot June 12, 2015 awn +n. -II- -0-OA •- .._'"'_'_'�.--..-...-. ��... .1 looa ?q.'! WnS an8 M.01'4 0510^5 CS:. _..,L 06.1^75 Image ~ .bject Well History File C.Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :J..O~ - 056 Well History File Identifier Organizing (done) o Two-sided 11I11111I1111111111 o Rescan Needed I RESCAN DI~AL DATA ~Diskettes, No. , o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Scanning Preparation BY: Helen (Maria ') I x 30 = '""'2¿-'\ + <..-JV o Other:: " I Date: 1. is ,tiS" Isl wtP . ( I· , Date: 1/S" as- Isl VV1¡D t , D = T~OTAL PAGES L¡. 0_ (Count doe:¡ not i~lude cover sheet) A ~1 Date: I' i\-Ç 1l~/sl VVf-- I 1 I · BY: Helen ("Maria ) Project Proofing BY: Helen _~aria ) Production Scanning Stage 1 Page Count from Scanned File: Lf / (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~./ YES NO Helen ~ Date: 7, I, ~ bS- I.J VI1 P If NO in stage 1, page(s) discrepancies were found: YES NO BY: Stage 1 BY: Helen Maria Date: 151 11I1111111111111111 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned I BY: Helen Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 FW: PBU W - 23A - PTD 2030560- Exsion Request for Weekly BOP Test • Page 1 of 3 Regg, James B (DOA) From: AK, D &C Well Services Operations Team Lead [ AKDCWellServicesOperationsTeamLead @BP.com] Sent: Monday, April 25, 2011 6:02 AM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA); Cismoski, Doug A; Brown, Matt (CONTRACT PROFESSIONALS); Forcade, Kirk C ; Olsen, Clark A; AK, D &C Well Services Operations Team Lead Subject: RE: Update #2: PBU W -23A- PTD 2030560 - Extension Request for Weekly BOP Test Jim, We successfully cut our coil tubing free in well W -23 last night. The coil unit will go to the shop today for a new coil string and some maintenance. Once they return to the field, the first step (before starting any downhole operations) will be conducting a new BOP test. Tyra 9Vorene AK. D&C Well Services TL Office: (907) 659 -5872 Cell: Pager: (9�) 903 226 659-5100 € 2s A 6 241 From: AK, D &C Well Services Operations Team Lead Sent: Friday, April 22, 2011 10:50 AM To: 'Regg, James B (DOA)' Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA); Cismoski, Doug A; Brown, Matt (CONTRACT PROFESSIONALS); Forcade, Kirk C Subject: Update #1: PBU W -23A- PTD 2030560 - Extension Request for Weekly BOP Test Jim, Good morning, here is a quick update on the W -23 stuck coil project: We attempted to get free by first pumping down the backside of the coil at high rate (using two cement pumps). In a separate step, we dropped a disconnect ball in the hope that the lower portion of the tool string was stuck rather than the upper portion. Neither attempt was successful at freeing the coil. We are currently in the process of setting up for a downhole cut via e-line deployed down the coil. will provide you a final update once we are free. Regards, 2y&er7Vorene AK D&C Well Services TL Office: (907) 659 -6872 Pager: (907) 659 -5100 x 1023 Cell: (907) 903 -2264 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, April 18, 2011 10:30 AM To: AK, D &C Well Services Operations Team Lead Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: PBU W -23A- PTD 2030560 - Extension Request for Weekly BOP Test An extension is granted allowing you to delay testing until coil becomes unstuck, allowing for time to pull 4/25/2011 FW: PBU W -23A- PTD 2030560 -Ext ion Request for Weekly BOP Test Page 2 of 3 coil from hole before commencing the BIT test. We would appreciate periodic updat s as you proceed with efforts to free the pipe. Copy all in cc: list of this email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Services Operations Team Lead [ mailto: AKDCWelIServicesOperationsTeamLead @BP.com] Sent: Sunday, April 17, 2011 7:15 PM To: Regg, James B (DOA) Subject: FW: PBU W -23A- PTD 2030560 - Extension Request for Weekly BOP Test I � the first Was not certain h if fir note had been sent to the correct address, Regards, Clark From: AK, D &C Well Services Operations Team Lead Sent: Sunday, April 17, 2011 7:12 PM To: Jim_Regg @admin.state.ak.us Cc: AK, D &C Wells CT Scheduler; Kara, Danny T; Cismoski, Doug A; Brown, Matt (CONTRACT PROFESSIONALS); Forcade, Kirk C Subject: PBU W -23A- PTD 2030560- Extension Request for Weekly BOP Test Jim, Schlumberger Coil Tubing Service Unit (CTU) #8 is currently stuck in the hole on well W -23A. We initiated CTU intervention activities on W -23, April 8th, milling scale until Monday April 11th, at which time we conducted the weekly BOP test prior to continuing the intervention. Our job scope for the Coil Service work included Milling scale and acidizing the perforations. Following numerous milling runs, on Wednesday the 13th, we became stuck at 10210' just above the slotted liner. Our various efforts to free the pipe have been unsuccessful to this point. We had milled from approximately 9312' to the current depth of 10210' changing our mill out at various times. Current well T /I /O is 200/0/160, BHP = 3450 psi • We are able to pump down the Coil and have established circulation • We are able to pump down the Tubing X CT annulus allowing us to kill the well Plans Forward • Pump KCL down the Tubing by CT annulus attempting to flush debris / scale, work pipe • Pump the disconnect ball for the BHA, if unsuccessful; • Prepare to Chemical Cut the Coil The weekly BOP test is due tomorrow Monday April 18th, as such, we are asking for a waiver to our weekly BOP test as pipe is across the BOP's. I have notified State Inspector Bob Noble, of our situation this evening, and he suggested that I forward a note on to you. 4/25/2011 FW: PBU W -23A- PTD 2030560- Extsion Request for Weekly BOP Test Page 3 of 3 • If you should need further information please give myself a call. I will also try and call you in the morning. Scott Bundy our Coil Tubing coordinator can also be reached at 907 - 659 -5542 I have included a schematic for your reference along with a copy of the BHA. «W- 23A.pdf» «W -23 CT BHA.pdf» Regards, Clark Olsen BPXA Well Services Team Lead 907 - 659 -5872 4/25/2011 FW: PBU W -23A- PTD 2030560 - Exton Request for Weekly BOP Test • Page 1 of 2 Regg, James B (DOA) From: Regg, James B (DOA) " C 4 ( 1€a ( I Sent: Monday, April 18, 2011 10:30 AM To: AK, D &C Well Services Operations Team Lead Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: PBU W -23A- PTD 2030560 - Extension Request for Weekly BOP Test An extension is granted allowing you to delay testing until coil becomes unstuck, allowing for time to pull coil from hole before commencing the BOPE test. We would appreciate periodic updates as you proceed with efforts to free the pipe. Copy all in cc: list of this email. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Services Operations Team Lead [mailto:AKDCWellServicesOperationsTeamLead@BP.com] Sent: Sunday, April 17, 2011 7:15 PM To: Regg, James B (DOA) Subject: FW: PBU W -23A- PTD 2030560 - Extension Request for Weekly BOP Test Was not certain if the first note had been sent to the correct address, Regards, Clark ; . AWED APR 6 ZDt From: AK, D &C Well Services Operations Team Lead Sent: Sunday, April 17, 2011 7:12 PM To: Jim_Regg @admin.state.ak.us Cc: AK, D &C Wells CT Scheduler; Kara, Danny T; Cismoski, Doug A; Brown, Matt (CONTRACT PROFESSIONALS); Forcade, Kirk C Subject: PBU W -23A- PTD 2030560- Extension Request for Weekly BOP Test Jim, Schlumberger Coil Tubing Service Unit (CTU) #8 is currently stuck in the hole on well W -23A. We initiated CTU intervention activities on W -23, April 8th, milling scale until Monday April 11th, at which time we conducted the weekly BOP test prior to continuing the intervention. Our job scope for the Coil Service work included Milling scale and acidizing the perforations. Following numerous milling runs, on Wednesday the 13th, we became stuck at 10210' just above the slotted liner. Our various efforts to free the pipe have been unsuccessful to this point. We had milled from approximately 9312' to the current depth of 10210' changing our mill out at various times. Current well T /I /O is 200/0/160, BHP = 3450 psi • We are able to pump down the Coil and have established circulation • We are able to pump down the Tubing X CT annulus allowing us to kill the well 4/18/2011 FW: PBU W -23A- PTD 2030560- Extetion Request for Weekly BOP Test Page 2 of 2 Plans Forward • Pump KCL down the Tubing by CT annulus attempting to flush debris / scale, work pipe • Pump the disconnect ball for the BHA, if unsuccessful; • Prepare to Chemical Cut the Coil The weekly BOP test is due tomorrow Monday April 18th, as such, we are asking for a waiver to our weekly BOP test as pipe is across the BOP's. I have notified State Inspector Bob Noble, of our situation this evening, and he suggested that I forward a note on to you. If you should need further information please give myself a call. I will also try and call you in the morning. Scott Bundy our Coil Tubing coordinator can also be reached at 907 - 659 -5542 I have included a schematic for your reference along with a copy of the BHA. «W- 23A.pdf» «W -23 CT BHA.pdf» Regards, Clark Olsen BPXA Well Services Team Lead 907 - 659 -5872 4/18/2011 • • --mi=x MICROFILMED 03/01/2008 DO NOT PLACE .:,"> _,; ~., ~,°_ ~,~~` ~° ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc · STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION COMrBlON REPORT OF SUNDRY WELL OPERATIONS D D D . 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 82.36 KB 8. Property Designation: ADlO-028263 - 11. Present Well Condition Summary: Total Depth 11242 / feet 8972.62 feet measured true vertical Effective Depth 11242 - feet 8972.62 feet measured true vertical Casing Conductor Surface Production Liner Size length 110' 2678' 9681' 1806' 20" 13-3/8" 68# l-80 9-5/8" 47# l-80 4-1/2" 12.6# l-80 Perforation depth: Measured depth: 10312' - 11238' True Vertical depth: 8967' - 8972' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations OiI-Bbl shut in 388 x ~7 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development r;; Stratigraphic StimulateD Other 0 Acid Treatment Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 203-0560 Exploratory Service 9. Well Name and Number: C" 6. API Number: 50-029-21993-01-00 " PBU W-23A < 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 708 591 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Plugs (measured) Junk (measured) MD Surface - 146' Surface - 2678' Surface - 9681' 9434' - 11240' TVD Surface - 146' Surface - 2673' Surface - 8764' 8561' - 8972' SCANNED MAY 222007 - - - - 4-1/2" 12.6# 13Cr80 9-5/8"X5-1/2" BKR S-3 9-5/8"X7" ZXP lNR TOP PKR o o None None Burst Collapse 5020 2260 6870 4760 8430 7500 » iD en ;01:" I» :xJ 2 :š: surface - 9454' Q.O ~ m :ÞCi) (') = Q) 9394' £.cn ...... m 0 c-J .... 0 Q - 9442' c» < CI = CD ~ /".,) 0 c-J 0 m 0 0 -...J 0 CjO .... S' ::a Tubing pressure o 258 Service WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Signature Data Management Engineer Date 5/8/2007 MAY 2 1 20D7 ).-S-}~õ Submit Original Only . . . W-23A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/26/2007 w/ 15821' 1.75" . Continue from Milling Tight spot 9993 to 10001, TOOH to inspect mill. The outside edge of the mill was rounded off. Went on Weather Standby @ 07:00 4/29/2007 CTU#9 w/15821' 1.75" From 04/28/07, Milling with 3.5" three blade junk mill. Break through at 10,321' and lost returns. Pumped final sweep and circulated OOH. RBIH without pumping. Saw ratty spots at 10,367, 1,400', 10,411- 10,425. Tag at 11031' could be fill/scale. PUH to 10,275' and RBIH cleaning out to 11,026 and encountered hard spot, difficult to mill off, stalling motor, and 7 to 10k overpull at 11040. Make another attempt to mill past 11,040' but check weight and have 12k over pull getting back out. Weight returned to normal at 11,016'. Pump 20 bbl final pill and chase OOH based on open hole volume through slotted liner and then at 70% OOH based on - 80% returns. Perform injectivity test - 2.0 BPM at 800 psi WHP. Order 100 bbl 12% acid. MU BHA# 5 with 2" JSN and TIH. Continue on 04/30/07 *** Job in Progress*** 4/30/2007 w/15821' 1.75" From 04/29/07,TIH with 2" Pump 60 bbls diesel in backside, 3 stages of 33 bbl acid followed by 35 bbls 2% KCL. Had a -500 psi drop in wellhead pressure from the acid on formation on 1 st stage. Did not get any breaks on next 2 stages. Flush with up and down passes of 2% KCL and Displaced acid with 125 BBLs of 2% KCL (pulled a little heavy till we left the liner window then the weight went back to normal) as we POOH. RDMO. *** Job Completed*** FLUIDS PUMPED BBLS 49 60/40 Meth 60 Diesel 30 2% KCL 100 12% HCL 239 Total J j",,--ÁA~ r DATA SUBMITTAL COMPLIANCE REPORT 7/12/2005 Permit to Drill 2030560 Well Name/No. PRUDHOE BAY UNIT W-23A Operator BP EXPLORATION (ALASKA) INC SfJ~ 27. ~M~'~ API ¡(Jo. 50-029-2199~-01-00 MD 11242 / NO 8973 / Completion Date 5/3/2003 /' Completion Status 1-01L Current Status 1-01L UIC N ---- ------ -- ---------- REQUIRED INFORMATION Mud Log No Samples No Directional SUNey Yes -------- --- ------- DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, ABI Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments -~------- - --- i ¡W'D Directional SUNey 9592 11242 Open 6/13/2003 Schlumberger SUNey ~. Directional Survey 9592 11242 Open 6/13/2003 Schlumberger Survey lED 0 Directional Survey 9592 11242 Open 6/13/2003 BP Geodetic ; : Rpt Directional Survey 9592 11242 Open 6/13/2003 BP Geodetic !~c~tS 12154 LIS Verification 9709 11242 Open 10/10/2003 LDWG edit of 3 bit Run I LWD Impulse i }HrC Pds 12154 I nd uction/Resistivity 25 2-3 9681 11242 Open 1 0/1 0/2003 Vision Resistivity ~. I nd uction/Resistivity 25 Blu 2-3 9681 11242 Open 10/10/2003 Vision Resistivity ~ C Pds 12154 See Notes 25 2-3 9681 11242 Open 1 0/1 0/2003 Borehole Profile ~ Borehole Profile -, See Notes 25 Blu 2-3 9681 11242 Open 1 0/1 0/2003 ---- ----- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y G> Chips Received? ...- V / N Daily History Received? ~ ÐN Formation Tops Analysis Received? ~ -----~------- -- ------ DATA SUBMITTAL COMPLIANCE REPORT 7/12/2005 Permit to Drill 2030560 Well Name/No. PRUDHOE BAY UNIT W-23A Operator BP EXPLORATION (ALASKA) INC MD 11242 TVD 8973 Completion Date 5/3/2003 Completion Status 1-01L Current Status 1-01L Comments: Compliance Reviewed By: ).h Date: API No. 50-029-21993-01-00 UIC N b -~------ --- 1l0J ~/ )n__2g'~r--- -- , - Schlumbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description Date D.S. S-16f;3 \ q q .... ~ t"î ) LDL P2-60 - .1 q \ -rA -i PROD PROFILE W/DEFT ~N:K~.:2A9 \} ~~~~~&\¡ ~'( ~:~~ ;~~~~ - \ l --J PROD PROFILE W/DEFT D.S.3-29 ; '-()y.Cf PROD PROFILE W/DEFT D.S.15-18 ; ... ....(){çJ~ SBHP SURVEY ~~~~ I ~~ ~~_ ~~~P SURVEY D.S. 9-06 \ '71 CJ ( )~ PROD PROFILE WIDEFT D.S. 2-08B } q ~ :mP5 23375 CH EDIT MCNL d-23A~ 23373 OHEDITLWDIMPULSEDATA W-23A ,- (")3-YY::;(j? 23373 MD VISION RESISTIVITY W-23A 23373 TVD VISION RESISTIVITY W-23A 23373 MD BOREHOLE PROFILE MPS.02-....... ~I"\ -, ..._1 ~ -:::¡- 10624537 CH EDIT SCMT GR (PDC) MPS-02 /""U\..1..J IV" ( 23435 SCMT MPS.18'\,<7'1Cf)Ð4P) 10559235 CH EDIT SCMT GR (PDC) MPS.18/ U- '"^ 10559235 SCMT 09/10/03 09/13/03 09/17/03 09/16/03 09/09/03 09/19/03 09/19/03 09/20/03 09/23/03 09/20/03 05/31/03 04/30/03 04/30/03 04/30/03 04/30/03 08/09/03 08/09/03 03/03/03 03/03/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 R E C lE IVE D Date Delivered: I"\l'ï 1 () ');¡t~ Vl"í AiaBka 0;-; &. G:li Cüns. :)Jmmiø~on j%1C"i1Cr~ge Blueline 09/30/03 NO. 2981 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay r~":"'-:: Color Prints CD 1 1 1 1 1 1 1 1 1 1 1 1 J ~ JL~ 1 J:9}ð 1 / 8- l-F51. (j 2 -~ 1 if) l'?Sf 2 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Received ~ \..N~:-~OCb.~ ( STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 06/26/03, Put on Production 1. Status of Well ~ Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 556' SNL, 1179' WEL, SEC. 21, T11N, R12E, UM At top of productive interval 2598' NSL, 92' WEL, SEC. 16, T11 N, R12E, UM At total depth 1932' NSL, 1014' EWL, SEC. 15, T11 N, R12E, UM X = 614199, Y = 5962222 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 82.36 ADL 028263 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/27/2003 4/30/2003 5/312003 17. Total Depth (MD+ rvD) 18. Plug Back Depth (MD+ rvD) 19. Directional Survey 11242 8973 FT 11242 8973 FT ~ Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, ABI .?3. CASING SIZE 20" 13-3/8" 9-5/8" 4-1/2" Classification of Service Well 7. Permit Number 203-056 X = 612049, Y = 5959701 8. API Number 50- 029-21993-01 9. Unit or Lease Name Prudhoe Bay Unit X = 613081, Y = 5962871 10. Well Number W-23A 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2012' MD 1900' (Approx.) L-80 NSCC L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 146" Surface 2678' Surface 9681' 9434' 11240' CEMENTING RECORD AMOUNT PULLED WT. PER FT. Conductor 68# 47# 12.6# GRADE 17-1/2" 3915 cu ft Coldset II 12-1/4" ,2018 cu ft Class 'G' 6-1/8" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Section SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 9454' PACKER SET (MD) 9394' 25. MD 10312' - 10806' 10826' - 11238' TVD 8967' - 8931' 8932' - 8972' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 7, 2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL 6/19/2003 4 TEST PERIOD 1,094 2,174 846 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL Press. 34d 24-HoUR RATE CHOKE SIZE 1760 OIL GRAVITY-API (CORR) 28.5 GAS-OIL RATIO 1,986 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit R~Et!;r:E ~. '\ ,~', _ ¡', /m--' "~S¡\tï\)":,:'I/I ~~"~ . q 1~~:'J.."L.'fI:It <'"'''''r, ,; 1'\."",,", No core samples were taken. ?8. JUN 2 7 2003 Alaska OH 8, Form 10-407 Rev. 07-01-80 ORIGIN^L Submit In Duplicate RBDMS BFl JUt O? 7mr~ G~ \ 29. Geologic Markers Marker Name Measured Depth Sag River 9686' Shublik A 9722' Shublik 8 9802' Shublik C 9834' Shublik D 9875' Eileen 9877' Sadlerochit I Zone 48 9890' 31. List of Attachments: ( 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8768' 8797' 8853' 8871' 8894' 8896' 8903' Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fO~ing .is true and correct to the best of my knowledge Signed TerrieHubble "IQJú\J..R ,Hu MeR Title Technical Assistant Date OfrJ' ;zJo·œ W-23A 203-056 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Neil Magee, 564-5119 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the pìOducing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 I~ é)03 -Cð(p K~~Y\~ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W-23A Date Dispatche 22-Apr-03 I nstallation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2V 1 ~. RECE-VED JUN 1 3 2003 AI_a Oii & Gas Con:t. Commíseion "~ AndtORtQ! Received By: "~'"'~ N\. .!:::>""n (J"'" ~~Iease sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 LWD Log Delivery V1.1 , Dec '97 e-mail address:johnsojh@bp.com ( { STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 556' SNL, 1179' WEL, SEC. 21, T11 N, R12E, UM At top of productive interval 2598' NSL, 92' WEL, SEC. 16, T11 N, R12E, UM At total depth 1932' NSL, 1014' EWL, SEC. 15, T11 N, R12E, UM X = 614199, Y = 5962222 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 82.36 ADL 028263 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/27/2003 4/30/2003 5/312003 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ rvD) 19. Directional Survey 11242 8973 FT 11242 8973 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, ABI 23. CASING SIZE 20" 13-3/8" 9-518" 4-1/2" Classification of Service Well 7. Permit Number 203-056 X = 612049, Y = 5959701 8. API Number 50- 029-21993-01 9. Unit or Lease Name Prudhoe Bay Unit X = 613081, Y = 5962871 10. Well Number W-23A 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2012' MD 1900' (Approx.) L-80 NSCC L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 146" Surface 2678' Surface 9681' 9434' 11240' CEMENTING RECORD AMOUNT PULLED WT. PER FT. Conductor 68# 47# 12.6# GRADE 17-1/2" 3915 cu ft Coldset II 12-1/4" 2018 cu ft Class 'G' 6-1/8" Uncemented Slotted Liner 24. Perforations open to Production (MD+ rvD of Top and Bottom and interval, size and number) 4-1/2" Slotted Section MD TVD 10312' -10806' 8967' - 8931' 10826' - 11238' 8932' - 8972' 25. SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 9454' PACKER SET (MD) 9394' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls Diesel 27. Date First Production Not on Production Yet Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR, OIL-BBL TEST PERIOD }ii, GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE æ. ~ED~ ,~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiPR E C E \ V\:::. \J No core samples were taken. ,.' ~ BfL jU~ . 9 2.003 U~ \) 5 7 GG] '. l ~l~;- i' c,f :, & Gas (;0\1$. C.OI\I\1iis5\OI' t::~;;:~=~,:~~::} Mas\ta \ . ~nc.nonw~e ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate i \ 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 9686' 8768' Shublik A 9722' 8797' Shublik B 9802' 8853' Shublik C 9834' 8871' Shublik D 9875' 8894' Eileen 9877' 8896' Sadlerochit I Zone 48 9890' 8903' RECEI\/E[) JUN 0 5 2003 Alaska Oil & Gas Com>. Comrr¡ission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~0fAÎ ~ fL,~ Title Technical Assistant Date (){g -0t.{-CJ3 W-23A 203-056 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer: Neil Magee, 564-5119 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any a1:tachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. ut-<iGl,~/-\L Form 10-407 Rev. 07-01-80 Legal Name: W-23A Common Name: W-23A Test Datê 4/27/2003 Test Type ·Te~tpepttîrrM[n 9,709.0 (ft) l'~$tl)epP1(TVD)· 8,786.0 (ft) AMW 8.70 (ppg) FIT Surface Pressure Leak Off Pressure (BHP) 600 (psi) 4,571 (psi) Page 1 of 1 EMW 10.01 (ppg) -- ---- Printed: 5/5/2003 11 :29:02 AM ( (' BP Operations Summary Report Page 1 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-23A W-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 4/19/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 4/19/2003 End: 5/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/19/2003 16:00 - 18:00 2.00 MOB P PRE Move sub off from W-207. Move down pad and spot rig over W-23 18:00 - 20:00 2.00 RIGU P PRE Spot pits, camp. 20:00 - 22:00 2.00 RIGU P PRE RU service lines; water, steam, electric. RU rig floor. Berm cellar and rig areas. Take on seawater. Rig Accepted @ 20:00 hrs. 22:00 - 23:00 1.00 CLEAN P DECOMP Clean rig 23:00 - 00:00 1.00 WHSUR P DECOMP RU surface lines to circulate out diesel and displace with clean seawater 4/20/2003 00:00 - 02:30 2.50 RIGU P DECOMP Continue taking on clean seawater and RU to circulate out freeze protect. 02:30 - 03:30 1.00 RIGU P DECOMP Rig Service, top drive. CO bails, install elevators 03:30 - 04:30 1.00 WHSUR P DECOMP RU DSM, pull BPV through lubricator. Monitor well for 15 minutes - static 04:30 - 05:00 0.50 KILL P DECOMP PJSM with MI and all rig personnel on rigging up manifold and choke to circulate out freeze protect and pressure testing lines. 05:00 - 08:30 3.50 KILL P DECOMP Pressure test manifold and choke lines to 3000 psi. Reverse circulate 19 bbl diesel out of tbg. Pump 50 bbl soap down tbg with approximately 134 bbls diesel + seawater returns from annulus going to cuttings tank through flare line. Pump at 3.5 bpm, 230 psi until clean seawater to surface, 08:30 - 10:30 2.00 KILL P DECOMP Blow down secondary kill line. Line up returns to pits. circulate bottoms up at 5 bpm, 315 psi. 10:30 - 11 :30 1.00 WHSUR P DECOMP Monitor well - static. blow down lines. Install TWC with FMC. 11 :30 - 13:00 1.50 WHSUR P DECOMP Bleed down adapter. ND tree and adapter flange 13:00 - 18:00 5.00 BOPSUR P DECOMP Break adapter flanges off BOP stack. MU mud cross. NU BOP and mud cross to tbg spool. 18:00 - 21 :00 3.00 BOPSUR N SFAL DECOMP Attempt to test tbg hanger and TWC. Leak between tbg spool and mud cross. ND BOP, dress ring seal groove, replace API ring seal. NU BOP on tbg spool. 21 :00 - 00:00 3.00 BOPSUR P DECOMP Test hanger, TWC and new seal ring to 3500 psi - OK. Test BOPE, choke manifold and all related equip. 250 psi low and 3500 psi high for 5 minutes each. Witness of BOPE test waived by Jeff Jones, AOGCC. 4/21/2003 00:00 - 02:00 2.00 BOPSURP DECOMP Continue test BOPE to 3500 psi high and 250 psi low for 5 minutes each. Blow down lines and RD test equipment 02:00 - 03:00 1.00 BOPSUR P DECOMP RU DSM and pull TWC through lubricator 03:00 - 03:30 0.50 PULL P DECOMP MU landing joint and pull tbg. Unseat tbg hanger and pull to rig floor, tbg pulled free at 90 klbs up. 03:30 - 05:00 1.50 PULL P DECOMP Fill hole with 70 bbl clean seawater. Circulate clean seawater surface to surface, 8.5 bpm @ 513 psi. 8 bblloss during circulation. 05:00 - 05:30 0.50 PULL P DECOMP Monitor well - static. RU tbg equipment. RU Camco unit to spool control lines. RD control lines from tbg hanger 05:30 - 09:00 3.50 PULL P DECOMP LD tbg hanger, 3 pup joints. Continue LD tbg while spooling SSSV control lines. Recovered all 34 clamps & 4 SS bands. SLM all tbg joints 09:00 - 09:30 0.50 PULL P DECOMP LD SSSV. RD Camco. Clear floor 09:30 - 15:30 6.00 PULL P DECOMP Continue LD 3-1/2" tbg & jewelry. Corrosion holes in joints #130-#142 and #211-#223. Recovered 223 joints + 16.80' of parted joint. Top of tbg stub calculated at 6985'. 15:30 - 16:00 0.50 PULL P DECOMP Clean and clear rig floor. RD tbg equipment. Printed: 5/5/2003 11 :29:09 AM ( {" ( BP Operations Summary Report Page 2 of? Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-23A W-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 4/19/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 4/19/2003 End: 5/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/21/2003 16:00 - 16:30 0.50 WHSUR P DECOMP Install wear bushing - 8.75" ID 16:30 - 18:00 1.50 PULL P DECOMP PU 30 single joints of DP, stand back 10 stands. 18:00 - 20:00 2.00 PULL P DECOMP MU BHA #1 - shoe, tbg cutter, 3 joints of wash pipe, drive sub, bumper sub, 9 x 61/2" DC, 9 x 4" HWDP. 20:00 - 00:00 4.00 PULL P DECOMP RIH with BHA #1to 2500', picking up DP. 95 klbs up, 85 klbs down. Drift DP to 2.5" Losses last 24 hrs. = 205 bbls Total losses = 205 bbls 4/22/2003 00:00 - 02:30 2.50 FISH P DECOMP Continue PU DP and RIH with tbg cutter to 6870'. Drift DP to 2.5". 02:30 - 03:30 1.00 FISH P DECOMP Continue RIH with stands from derrick to 6923'. Drift DP to 2.5". 03:30 - 04:45 1.25 FISH P DECOMP Wash down from 6923'.150 gpm @ 54 psi. 165 klbs up, 144 klbs down, 156 klbs rotate. Engage top of fish at 6987'. Wash over 101' of fish to 7088'. POH to 7073' and engage collar to make tbg cut. 04:45 - 06:30 1.75 FISH P DECOMP PU and engage mechanical tbg cutter @ 7065' per Baker Rep. 06:30 - 09:30 3.00 FISH P DECOMP Monitor well - static. Blow down top drive. POH to HWDP 09:30 - 10:00 0.50 FISH P DECOMP Stand back 3 stands HWDP and 3 stands DC 10:00 - 12:30 2.50 FISH P DECOMP LD bumper sub, drive sub, and 1 joint washpipe. Retrieve stub and 2 joints 3-1/2" tbg - total length 77.60'. LD remaining BHA 12:30 - 13:00 0.50 FISH P DECOMP Clear and clean rig floor. 13:00 - 16:00 3.00 FISH P DECOMP PU BHA #2 - overshot, bumper sub. RIH to 7065' 16:00 - 16:30 0.50 FISH P DECOMP Wash down and engage fish at 7065'. 145 klbs up, 125 klbs down, 135 klbs rotate. 200 gpm at 140 psi. Rotate over fish, ensure fish is in grapple. PU 45 klbs over string weight. set slips. 16:30 - 16:45 0.25 FISH P DECOMP PJSM with SWS and rig personnel. On MU and running string shot and chemical cutters. 16:45 - 19:00 2.25 FISH P DECOMP RU SWS. RIH with 2.5" blank perf gun, drift DP and 3-1/2" tbg to 9850' 19:00 - 19:30 0.50 FISH P DECOMP POH with 2.5" blank perf gun drift. 19:30 - 22:00 2.50 FISH P DECOMP LD 2.5" blank perf gun. MU string shot and RIH to 9850'. POH and correlate depth to tbg tally. Shoot string shot at 9740' 22:00 - 22:30 0.50 FISH P DECOMP POH with string shot 22:30 - 00:00 1.50 FISH P DECOMP LD string shot. MU chemical cutter and RIH. Losses last 24 hrs. = 227 bbls Total losses = 432 bbls 4/23/2003 00:00 - 01 :00 1.00 FISH P DECOMP Continue RIH with chemical cutter on wireline to 9750'. 01 :00 - 01 :30 0.50 FISH P DECOMP Depth correlate chemical cutter #1 to tbg tally. Make chemical cut in 3-1/2" tbg at 9750'. 01 :30 - 02:45 1.25 FISH P DECOMP POH with chemical cutter #1. 02:45 - 03:00 0.25 FISH P DECOMP PJSM with chemical 200' below surface. SWS and all rig personnel, no non-essential personnel on rig floor while picking up or laying down chemical cutters. 03:00 - 03: 15 0.25 FISH P DECOMP LD chemical cutter #1 and clear rig floor of same. 03:15 - 04:45 1.50 FISH P DECOMP MU chemical cutter #2 and RIH on wireline 04:45 - 05: 15 0.50 FISH P DECOMP Depth correlate chemical cutter #2 to tbg tally. Make chemical cut in 3-1/2" tbg at 9469'. 05: 15 - 07:00 1.75 FISH P DECOMP POH with chemical cutter #2 07:00 - 08:30 1.50 FISH P DECOMP Pick up DP 10' to verify tbg cut, 165 klbs up. CBU @ 415 gpm, Printed: 5/5/2003 11 :29:09 AM ( ~[ BP Operations Summary Report Page 3 of? Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-23A W-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 4/19/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 4/19/2003 End: 5/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/23/2003 07:00 - 08:30 1.50 FISH P DECOMP 1170 psi. Monitor well - static. pump dry job, blow down top drive. 08:30 - 11 :00 2.50 FISH P DECOMP POH with DP 11 :00 - 12:00 1.00 FISH P DECOMP LD BHA #2 12:00 - 12:30 0.50 PULL P DECOMP RU tbg eqipment to LD 3-1/2" tbg fish 12:30 - 14:30 2.00 PULL P DECOMP LD 3-1/2" tbg fish - 73 joints, 4 GLM's, 1 X-nipple 14:30 - 15:00 0.50 PULL P DECOMP Clear and clean rig floor 15:00 - 16:00 1.00 FISH P DECOMP MU BHA #3 - overshot, bumper sub, hydraulic jar and 9 DC's 16:00 - 17:00 1.00 FISH P DECOMP RIH picking up DP from pipe shed 17:00 - 19:30 2.50 FISH P DECOMP Continue RIH with stands from derrick. 19:30 - 20:00 0.50 FISH P DECOMP Wash down. Engage fish at 9450', wash over 5' of fish to ensure fish was engaged in overshot. Pull 1 0 klbs over rotating weight and make 8 turns to the right to unscrew the K-anchor. 200 klbs up, 155 klbs down, 180 klbs rotate. 20:00 - 00:00 4.00 FISH P DECOMP POH with k-anchor. 200 klbs up, 155 klbs down. 4/24/2003 00:00 - 00:30 0.50 FISH P Losses last 24 hrs. = 146 bbls Total losses = 578 bbls DECOMP LD fishing assembly and K-anchor. 00:30 - 01 :00 01 :00 - 01 :30 01 :30 - 05:00 0.50 FISH 0.50 FISH 3.50 FISH P P P Fish shows a groove where coiled tubing milled down between the 9-5/8" csg and the K-anchor mandrel to the top of the packer. Possibly milling through the 9-5/8" casing. DECOMP MU BHA #4 - packer milling assembly, and 3 stands of DC's DECOMP PU 21 joints of 5" HWDP and RIH. Drift HWDP to 2.5" DECOMP RIH with DP 05:00 - 06:30 1.50 FISH P 06:30 - 07:00 0.50 FISH P 07:00 - 11 :00 4.00 FISH P 11 :00 - 11 :30 0.50 FISH P 11 :30 - 15:00 3.50 PULL P 15:00 - 15:30 0.50 PULL P 15:30 - 16:00 0.50 PULL P 16:00 - 16:30 0.50 PULL P 16:30 - 17:00 0.50 PULL P 17:00 - 18:30 1.50 STWHIP P 18:30 - 21 :30 3.00 STWHIP P 21 :30 - 23:00 1.50 STWHIP P 23:00 - 00:00 1.00 STWHIP P RU bleed tank and bleed 13-3/8" X 9-5/8" annulus pressure to o psi DECOMP Cut and slip 90' of drilling line. Service top drive. DECOMP Circulate at 300 gpm, 1576 psi. 220 klbs up, 178 klbs down, 200 klbs rotate, torque 4500 Ibs. DECOMP Mill packer asembly Tag up on packer at 9457', milled to 9460' DECOMP Monitor well - static. Blow down choke, gas buster and top drive DECOMP Pull packer and tbg tail. Pulled slow for the first 10 stands, to prevent swabbing. Pulling 15 to 20 klbs over original up weight through csg collars on first 10 stands. DECOMP Stand back BHA #4 DECOMP LD milling assembly and packer. DECOMP Clean out junk baskets. CO elevators DECOMP LD 7 joints 3-1/2" tbg, 2 X-nipples, 2 10' tbg pups DECOMP MU BHA #5 - upper window mill and casing scraper DECOMP RIH, tag tbg stump @ 9730' DECOMP Circulate sweep surface to surface. 590 gpm, 2330 psi. 225 klbs up, 170 klbs down, 200 klbs rotate, torque 5800 Ibs @ 65 rpm. DECOMP Monitor well - static. Pump dry job. TOH. 230 klbs up, 170 klbs down. 4/25/2003 00:00 - 03:00 3.00 STWHIP P Losses last 24 hrs. = 61 bbls Total losses = 639 bbls DECOMP POH with mill and casing scraper. Printed: 5/5/2003 11 :29:09 AM ( BP Operations Summary Report Page 4 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-23A W-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 4/19/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 4/19/2003 End: 5/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/25/2003 03:00 - 03:30 0.50 STWHIP P DECOMP Stand back HWDP and DC's 03:30 - 04:30 1.00 STWHIP P DECOMP LD BHA #5. Clean out junk basket. Clean and clear rig floor 04:30 - 04:45 0.25 STWHIP P DECOMP PJSM with SWS, HOWCO and all rig personnel on RU and running EZSV, and explosives safety. 04:45 - 05:30 0.75 STWHIP P DECOMP PU SWS BP setting tool and MU EZSV. 05:30 - 08:00 2.50 STWHIP P DECOMP RIH with EZSV. Tag tbg stub at 9730' ELMD 08:00 - 08:30 0.50 STWHIP P DECOMP Depth correlate wireline to CNLlGR log of 01/08/1990. Set EZSV at 9721' ELMD 08:30 - 09:30 1.00 STWHIP P DECOMP POH with wireline. LD setting tool. RD SWS. Clear floor 09:30 - 10:00 0.50 BOPSUR P DECOMP Pull wear bushing. Flush BOP stack. 10:00 - 11 :00 1.00 WHSUR P DECOMP Pressure test packoff anf 9-5/8 csg to 1000 psi for 5 minutes - OK. MU pack off running tool. Pull 9-5/8" packoff. 11 :00 - 11 :30 0.50 WHSUR P DECOMP PU up new 9-5/8" packoff, attempt to install - no go 11:30 -16:00 4.50 BOPSUR N SFAL DECOMP ND BOPE, inspect 9-5/8" csg hanger. Hanger not seated, 5-1/2" above load shoulder. Ran packoff with BOP racked back to visually inspect csg hanger and packoff position. Pull packoff and RD running tool. 0 psi on 13-3/8" X 9-5/8" annulus 16:00 - 18:00 2.00 BOPSUR N SFAL DECOMP NU BOPE and riser 18:00 - 19:30 1.50 WHSUR N SFAL DECOMP MU mule shoe. RIH with DC's and HWDP 19:30 - 21 :30 2.00 WHSUR N SFAL DECOMP RIH with DP to 5100' 21 :30 - 23:00 1.50 WHSUR N SFAL DECOMP Circulate 350 bbls 33 degree water around to cool csg and reduce thermal expansion. 5 bpm, 150 psi 23:00 - 00:00 1.00 WHSUR N SFAL DECOMP MU RTTS. RIH 1 stand. Set RTTS, with ....127 klbs below to re-seat 9-5/8" csg hanger. POH with 1 stand, break down stinger 4/26/2003 00:00 - 01 :30 1.50 WHSUR N SFAL DECOMP MU running tool and packoff. RIH seat packoff. RILDS. Test packoff to 5000 psi for 30 minutes - OK 01 :30 - 03:00 1.50 WHSUR N SFAL DECOMP MU stand and RTTS stinger. Sting into RTTS, pump down DP and test casing below RTTS to 3000 psi for 5 minutes - OK Release RTTS and POH, LD same 03:00 - 04:00 1.00 CASE P DECOMP Fill lines close pipe rams. Test 9-5/8" csg & packoff to 3000 psi for 30 minutes - OK 04:00 - 07:30 3.50 STWHIP N SFAL DECOMP Blow down top drive and choke. POH to pick up whipstock 07:30 - 08:00 0.50 STWHIP N SFAL DECOMP Stand back 5" HWDP and DC's 08:00 - 08:30 0.50 STWHIP P DECOMP Clean and clear rig floor. Install wear bushing and mouse hole 08:30 - 09:30 1.00 STWHIP P WEXIT MU whipstock, milling assembly and MWD. Orient MWD 09:30 - 10:00 0.50 STWHIP P WEXIT Rig service, top drive, blocks and crown 10:00 - 11 :00 1.00 STWHIP P WEXIT RIH with DC's and HWDP, 1-1/2 minute per stand 11 : 00 - 11: 30 0.50 STWHIP P WEXIT Shallow test MWD 11 :30 - 16:00 4.50 STWHIP P WEXIT RIH with DP to 9614' MD @ 1-1/2 minute per stand, fill hole at 5700' MD 16:00 - 16:30 0.50 STWHIP P WEXIT Orient whipstock to 60 degrees right of high side. Tag EZSV at 9704' MD, EZSV set at 9721 ELMD'. Set down 20 klbs to set anchor, pick up and check anchor set - OK. Set down 45 klbs to shear off. 230 klbs up, 180 klbs down. 16:30 - 18:00 1.50 STWHIP P WEXIT Displace well with 8.6 ppg Flo-Pro mud, 7 bpm, 1300 psi 18:00 - 00:00 6.00 STWHIP P WEXIT Mill window from 9681' to 9703' MD. 450 gpm, 1880 psi. 230 klbs up, 180 klbs down, 201 klbs rotate. 4/27/2003 00:00 - 02:30 2.50 STWHIP P WEXIT Continue milling window to 9709' MD. 450 gpm, 1880 psi. 230 klbs up, 180 klbs down, 201 klbs rotate. Approximately 100 Ibs of metal recovered. 02:30 - 03:30 1.00 STWHIP P WEXIT Circulate hi-vis sweep surface to surface. 500 gpm, 1870 psi. Work mills through window while circulating. Printed: 5/5/2003 11 :29:09 AM f ~ BP Operations Summary Report Page 5 of? Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-23A W-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 4/19/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 4/19/2003 End: 5/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/27/2003 03:30 - 04:00 0.50 EVAL P WEXIT POH to top of window. Perform FIT to 10.0 EMW. 8.7 ppg mud at 8786' TVD = 600 psi pump pressure 04:00 - 08:00 4.00 STWHIP P WEXIT Monitor well - static. Pump dry job and POH 08:00 - 09:00 1.00 STWHIP P WEXIT LD 21 joints of 5" HWDP and 9 joints of 6-1/2" DC's 09:00 - 10:30 1.50 STWHIP P WEXIT Break down milling assembly and clear rig floor 10:30 - 11 :00 0.50 WHSUR P WEXIT Pull wear bushing and flush BOP stack 11 :00 - 14:00 3.00 BOPSURP WEXIT PU BOPE test equipment. Test BOPE to 250 psi low and 3500 psi high for 5 minutes each. Witness of BOP test waived by Chuck Scheeve, AOGCC 14:00 - 14:30 0.50 WHSUR P WEXIT Install wear bushing. RD BOP test equipment 14:30 - 16:30 2.00 DRILL P PROD1 MU BHA #7. Orient MWD, RIH with BHA and shallow test MWD 16:30 - 19:30 3.00 DRILL P PROD1 RIH with DP to 9115', fill every 30 stands 19:30 - 21 :00 1.50 DRILL P PROD1 Cut and slip 92' of drilling line. Service top drive 21 :00 - 22:00 1.00 DRILL P PROD1 RIH to 9675'. Log MWD up at 400 ft/hr to 9500' for geologic tie-in and correlation. 300 gpm, 1600 psi. Then orient 60 degrees right of high side and exit window 22:00 - 00:00 2.00 DRILL P PROD1 Directional drill from 9709' to 9749', sliding 100%. Building angle at -23 degrees per 100'.300 gpm, 1880 psi. 193 klbs up 152 klbs down. 13-3/8" X 9-5/8" annulus pressure up to 1000 psi, bled down to 0 4/28/2003 00:00 - 16:45 16.75 DRILL P PROD1 Directional drill from 9749' to 10173', 100% sliding, building angle at -23 degrees per 100' through build section, final inclination at 10173' is 88.77 degrees at 105 degrees azimuth. 300 gpm, 1910 psi. 201 klbs up, 155 klbs down Sliding time last 24 hrs = 9.1 hrs. Total sliding time = 10.1 hrs 16:45 - 17:00 0.25 DRILL P PROD1 Monitor well - static 17:00 - 17:30 0.50 DRILL P PROD1 POH, pumping out at 300 gpm to 9704' putting the motor at the bottom of the window. Shut down pupms and pull out of the window to 9650'. Monitor well- static. 17:30 - 19:00 1.50 DRILL P PROD1 CBU at 300 gpm, reciprocate DP while circulating 19:00 - 22:30 3.50 DRILL P PROD1 Monitor well - static. Pump dry job and POH to the BHA 22:30 - 23:00 0.50 DRILL P PROD1 Stand back jars and DC's. Break out bit #1 and LD motor 23:00 - 00:00 1.00 DRILL P PROD1 PU up new motor and MU bit #2. Download and Orient MWD. 4/29/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Continue to download MWD. RIH with BHA and shallow test MWD, 280 gpm and 840 psi 01 :00 - 02:30 1.50 DRILL P PROD1 RIH to 3988' with Bit #2, break circulation. 02:30 - 03:00 0.50 DRILL P PROD1 Service top drive and blocks 03:00 - 05:00 2.00 DRILL P PROD1 Continue RIH to 9586'. Break circulation at 7709'. At 9586' break circulation again and orient 60 degrees right of high side to exit window 05:00 - 06:00 1.00 DRILL P PROD1 RIH through window and continue on to bottom pumping surveys as required by MWD. Wash last stand to bottom. No adverse hole conditions or fill. 06:00 - 00:00 18.00 DRILL P PROD1 Drill from 10,173 to 10,891 pumping 30 bbls. Hi-Vis. sweeps every 200 to 300 ft. or as hole dictates. Backreaming every connection. ART==4 AST==7.33 Drilling with following parameters: WOB==5-10 UP WT==194K DWN==170K RT==170K TRQ==5,700 off bottom Printed: 5/5/2003 11 :29:09 AM t ( BP Operations Summary Report Page 6 of? Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-23A W-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 4/19/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 4/19/2003 End: 5/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/29/2003 06:00 - 00:00 18.00 DRILL P PROD1 / 8,500 on bottom GPM==300 @ 1900 PSI RPM==50 to 60. 4/30/2003 00:00 - 08:00 8.00 DRILL P PROD1 Drilling 6 1/8 production hole from 10,891 to 11,242. Pump 25 bbl. Hi-Vis sweeps every 200 ft. ART==3.33 AST==2 Drilling Parameters: GPM==300 @ 1870 RPM==60 TRQ==7,500 on bottom and 5,500 off. Up==196K Dwn==144K Rot==170K 08:00 - 10:00 2.00 DRILL P PROD1 Pump Hi-Vis sweep S-S @ 300 GPM while rotating and reciprocating string @ 60 RPM. No significant amount of cutting seen with sweep. 10:00 - 12:00 2.00 DRILL P PROD1 Monitor well. POH to 10,083. Pump out to 9,727 to obtain surveys. 12:00 - 13:30 1.50 DRILL P PROD1 Pull inside window and Circulate sweep S-S while rotating and reciprocating string. 13:30 - 14:30 1.00 DRILL P PROD1 RIH with no adverse hole conditions or fill. 14:30 -17:00 2.50 DRILL P PROD1 Circulate Sweep S-S at 300 GPM while rotating and reciprocating string @ 60 RPM. Spot 60 bbls. liner running pill with 2% Lubetex and 2% Flo-Iube. 17:00 - 18:00 1.00 DRILL P PROD1 POH to 9840 putting circ. sub at 9681. Drop ball and shear open circ. sub. 18:00 - 19:30 1.50 DRILL P PROD1 Pump sweep out and around circ. sub. Clean window area while pulling up into casing. Rotate and reciprocate string inside casing while circulating sweep out of hole at 620 GPM @ 2,000 PSI. Pump dry job. Observe well. 19:30 - 22:30 3.00 DRILL P PROD1 POH to BHA. 22:30 - 00:00 1.50 DRILL P PROD1 Layout BHA. Break and grade bit. 1 1 NO A X i NO TD Clear floor of all vendors excess equipment. 5/1/2003 00:00 - 01 :00 1.00 CASE P COMP Clear floor of all vendors excess equipment. Rig up 4 1/2 liner running equipment. 01 :00 - 03:00 2.00 CASE P COMP RIH with 41/2 slotted/solid liner with 2 markers spaced as per program. 03:00 - 08:00 5.00 CASE P COMP P/U 21 jts. 5" HWDP and RIH @ 60 FPM to window at 9681. No losses to wellbore while TIH. 08:00 - 10:00 2.00 CASE P COMP Circulate BU at 215 GPM 780 PSI. Up wt.==200K Dwn wt.==163K. No losses while circulating BU. 10:00 - 11 :00 1.00 CASE P COMP RIH with 4 1/2 liner to 11,242 with no adverse hole conditions or fill. 11 :00 - 12:30 1.50 CASE P COMP Pick up off bottom to 11,240 and drop setting ball. Seat ball and pressure up to 3,000 and set hanger. Rotate 15 turns to the right and release dogs. Set down 60K over down wt. and set liner top packer. Rotate down while setting 60k to confirm packer has set. Sting out of liner top at 9434. 12:30 - 15:30 3.00 CASE P COMP Pump 50 bbls. seawater with "dirt magnet", followed by 50 bbls. Hi-Vis sweep. Displace well over to seawater @ 450 GPM @ 1350 PSI. Clean and flush all surface equipment. 15:30 - 00:00 8.50 CASE P COMP POH laying down all 4" DP in hole. RIH with 25 stands in derrick. POH 1 x 1. 5/2/2003 00:00 - 01 :30 1.50 CASE P COMP Lay down 4" HT-40 DP 1x1. Break and lay down Baker liner running tool. Inspect tool for integrity--Good. 01 :30 - 02:30 1.00 BOPSURP COMP Clear floor of all excess vendors equipment. P/U test joint and pull wear ring. 02:30 - 03:00 0.50 CASE P COMP Service top drive and grease drawworks. 03:00 - 04:30 1.50 RUNCOrvP COMP PJSM. R/U casing equipment. Change Bails. Prepare to run 4 1/2 Vam Ace 13 Cr tubing Printed: 5/5/2003 11 :29: 09 AM t ( BP Operations Summary Report Page 7 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-23A W-23A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 4/19/2003 Rig Release: 5/3/2003 Rig Number: Spud Date: 4/19/2003 End: 5/3/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/2/2003 04:30 - 21 :00 16.50 RUNCorvP COMP RIH with 4 1/2 VAM Ace 13 Cr tubing. Space out inside liner Tie-back putting WLEG at 9453. (Tagged up slightly deeper on liner top.) M/U tubing hanger and land in bowl. RILDS and torque to specs. 21 :00 - 00:00 3.00 RUNCOrvP COMP Reverse circulate bottoms up followed by 300 bbls. seawater treated with inhibitor. Chase inhibitor treated seawater to Shear valve on GLM #5 @ 3,730. Pump rate for all circulating--3 bpm @ 200 PSI. 5/3/2003 00:00 - 01 :00 1.00 RUNCOrvP COMP Reverse circulate in inhibitor treated seawater and chase to below Shear valve in GLM #5. 01 :00 - 03:00 2.00 RUNCOrvP COMP Drop ball to set packer. Back out landing joint. Pressure up to 3,500 PSI and set packer and test tubing for 30 minutes on chart. Bleed tubing to 1,500 and apply 3,000 to annulus and test packer. Hold test for 30 minutes on chart. Bleed annulus and tubing to zero. Pressure up annulus and shear valve in GLM # 5 with 2,900 PSI. 03:00 - 03:30 0.50 RUNCOrvP COMP Install 2-way check and test to 1,000 from below. 03:30 - 05:00 1.50 RUNCOrvP COMP Nipple down BOP's. 05:00 - 07:00 2.00 RUNCOrvP COMP NU adapter flange & tree. Test both to 5000 psi-OK. 07:00 - 08:00 1.00 RUNCOrvP COMP Pull TWC w/lubricator. 08:00 - 10:30 2.50 RUNCOrvP COMP RU Little Red. Reverse circ 155 bbls diesel down 4.5" x 9.625" annulus. U-tube. 10:30 - 12:00 1.50 RUNCOrvP COMP Set BPV w/lubricator. Test to 1000 psi from below. Secure cellar. Rig released f/ W-23A @ 1200 hrs on 5/3/2003 Printed: 5/5/2003 11 :29:09 AM SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: PBU - WOA Well. . . . . . . . . . . . . . . . . . . . .: W-23A API number...............: 50-029-21993-01 Engineer.................: St. Amour IG: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES ~--$TATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 54.46 ft KB above permanent.......: N/A OF above permanent.......: 82.36 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ~_,----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 113.56 degrees RECEIVED JUN 1 3 2003 Alaska ŒI & Gas Cons. ('Æmf11ÌS8iOn Anchomge 30-Apr-2003 15:57:19 Spud da t e. . . . . . . . . . . . . . . . : Last survey date... ......: Total accepted surveys...: MD of first survey.. .....: MD of last survey... .....: ~03 -05 (c; ~~~VY\~ Page 1 of 3 26-Apr-03 30-Apr-03 52 9591.76 ft 12242.00 ft ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2002 Magnetic date............: 23-Apr-2003 Magnetic field strength..: 1150.43 HCNT Magnetic dec (+E/W-) .....: 25.66 degrees Magnetic dip.. ....... ....: 80.78 degrees ----- MWD survey Reference Reference G..... .........: Reference H..... .........: Reference Dip... .........: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1150.43 HCNT 80.78 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.67 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-). ...: 25.67 degrees (Total az corr = magnetic dec - grid conv) SCHLUMBERGER Survey Report 30-Apr-2003 15:57:19 Page 2 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N!S- +E!W- displ Azim (deg! tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (de g) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 9591.76 35.00 41.48 0.00 8690.45 -394.47 3064.22 905.83 3195.30 16.47 0.00 TIP 2 9681.00 34.55 42.28 89.24 8763.75 -378.48 3102.12 939.81 3241.35 16.85 0.72 TOW 3 9697.00 35.54 45.15 16.00 8776.85 -375.31 3108.75 946.16 3249.55 16.93 12.01 BOW 4 9722.16 37.45 54.36 25.16 8797.09 -368.70 3118.38 957.57 3262.09 17.07 23.04 MWD Inc. Only - 5 9753.37 43.29 63.90 31.21 8820.88 -356.89 3128.63 974.92 3277.01 17.31 27.20 MWD Inc. Only - 6 9783.44 49.65 71.47 30.07 8841.60 -341.69 3136.82 995.08 3290.87 17.60 27.91 MWD-IFR-MSA ._~ 7 9813.82 56.71 72.66 30.38 8859.79 -323.47 3144.30 1018.20 3305.05 17.94 23.45 MWD-IFR-MSA 8 9845.91 55.54 84.42 32.09 8877.72 -301.73 3149.59 1044.24 3318.19 18.34 30.63 MWD-IFR-MSA 9 9875.66 54.69 81.23 29.75 8894.74 -280.76 3152.64 1068.44 3328.77 18.72 9.25 MWD-IFR-MSA 10 9907.48 56.56 81.75 31.82 8912.71 -258.50 3156.52 1094.42 3340.86 19.12 6.03 MWD-IFR-MSA 11 9937.89 60.32 86.44 30.41 8928.63 -235.94 3159.16 1120.18 3351.88 19.52 18.04 MWD-IFR-MSA 12 9969.08 64.67 88.99 31.19 8943.03 -211.05 3160.25 1147.81 3362.24 19.96 15.72 MWD-IFR-MSA 13 9999.99 67.37 92.31 30.91 8955.59 -185.04 3159.93 1176.04 3371.68 20.41 13.14 MWD-IFR-MSA 14 10031.01 72.27 96.24 31.02 8966.30 -157.57 3157.74 1205.06 3379.87 20.89 19.77 MWD-IFR-MSA 15 10063.77 78.44 97.54 32.76 8974.58 -127.22 3153.94 1236.51 3387.66 21.41 19.22 MWD-IFR-MSA 16 10096.47 84.23 100.48 32.70 8979.50 -95.94 3148.87 1268.42 3394.74 21.94 19.81 MWD-IFR-MSA 17 10125.89 88.77 105.87 29.42 8981.30 -67.08 3142.18 1296.99 3399.33 22.43 23.92 MWD-IFR-MSA 18 10157.03 91.58 110.66 31.14 8981.20 -36.08 3132.42 1326.55 3401.74 22.95 17.83 MWD-IFR-MSA 19 10187.81 95.29 112.81 30.78 8979.36 -5.38 3121.05 1355.09 3402.53 23.47 13.92 MWD-IFR-MSA 20 10217.91 96.05 116.75 30.10 8976.38 24.56 3108.50 1382.28 3401.98 23.97 13.27 MWD-IFR-MSA 21 10249.67 95.70 120.87 31.76 8973.13 56.01 3093.27 1409.95 3399.46 24.50 12.95 MWD-IFR-MSA --~ 22 10280.98 95.71 124.38 31.31 8970.02 86.77 3076.48 1436.19 3395.20 25.02 11.15 MWD-IFR-MSA 23 10311.77 95.84 126.74 30.79 8966.92 116.74 3058.67 1461.11 3389.73 25.53 7.64 MWD-IFR-MSA 24 10343.96 96.01 127.21 32.19 8963.60 147.88 3039.41 1486.69 3383.53 26.06 1.55 MWD-IFR-MSA 25 10375.69 95.87 126.75 31.73 8960.31 178.58 3020.42 1511.90 3377.69 26.59 1.51 MWD-IFR-MSA 26 10406.44 95.09 131.42 30.75 8 9"5 7 . 3 8 208.06 3001.13 1535.65 3371.20 "27.10 15.33 MWD-IFR-MSA 27 10437.25 94.57 133.45 30.81 8954.78 237.11 2980.42 1558.31 3363.21 27.60 6.78 MWD-IFR-MSA 28 10468.37 95.29 134.07 31.12 8952.11 266.21 2958.97 1580.70 3354.72 28.11 3.05 MWD-IFR-MSA 29 10498.88 95.71 134.96 30.51 8949.18 294.57 2937.68 1602.36 3346.27 28.61 3.21 MWD-IFR-MSA 30 10530.66 95.91 135.34 31.78 8945.96 323.97 2915.27 1624.65 3337.41 29.13 1.35 MWD-IFR-MSA SCHLUMBERGER Survey Report 30-Apr-2003 15:57:19 Page 3 of 3 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 10560.83 94.71 134.07 30.17 8943.17 351.98 2894.14 1646.00 3329.47 29.63 5.78 MWD-IFR-MSA 32 10592.17 93.13 131.02 31.34 8941.03 381.55 2873.00 1669.04 3322.62 30.15 10.94 MWD-IFR-MSA 33 10622.84 92.17 130.19 30.67 8939.61 410.84 2853.06 1692.30 3317.20 30.67 4.14 MWD-IFR-MSA 34 10654.79 93.20 129.63 31.95 8938.12 441.46 2832.58 1716.78 3312.23 31.22 3.67 MWD-IFR-MSA 35 10685.91 93.85 129.11 31.12 8936.20 471.35 2812.88 1740.79 3307.97 31.75 2.67 MWO-IFR-MSA 36 10717.51 94.02 128.57 31.60 8934.03 501.76 2793.11 1765.34 3304.22 32.29 1.79 MWO-IFR-MSA 37 10748.19 93.51 127.37 30.68 8932.02 531.41 2774.27 1789.48 3301.34 32.82 4.24 MWO-IFR-MSA 38 10779.15 90.21 127.39 30.96 8931.01 561.45 2755.49 1814.06 3299.02 33.36 10.66 MWO-IFR-MSA 39 10810.16 88.91 124.68 31.01 8931.25 591.72 2737.25 1839.13 3297.72 33.90 9.69 MWO-IFR-MSA 40 10839.84 88.84 124.92 29.68 8931.83 620.83 2720.32 1863.50 3297.39 34.41 0.84 MWO-IFR-MSA 41 10871.98 89.15 124.17 32.14 8932.40 652.38 2702.09 1889.97 3297.47 34.97 2.52 MWO-IFR-MSA 42 10902.09 88.50 124.26 30.11 8933.02 681.96 2685.17 1914.86 3298.00 35.49 2.18 MWO-IFR-MSA 43 10933.27 87.26 124.31 31.18 8934.17 712.57 2667.62 1940.61 3298.81 36.03 3.98 MWO-IFR-MSA 44 10964.05 86.19 124.95 30.78 8935.93 742.73 2650.15 1965.89 3299.70 36.57 4.05 MWO-IFR-MSA 45 10995.41 85.51 126.44 31.36 8938.20 773.31 2631.90 1991.29 3300.33 37.11 5.21 MWO-IFR-MSA 46 11026.28 84.55 126.07 30.87 8940.87 803.31 2613.72 2016.09 3300.93 37.64 3.33 MWO-IFR-MSA 47 11057.52 83.17 126.34 31.24 8944.21 833.62 2595.37 2041.16 3301.86 38.18 4.50 MWO-IFR-MSA 48 11088.39 82.29 126.43 30.87 8948.12 863.47 2577.21 2065.81 3302.96 38.71 2.87 MWD-IFR-MSA 49 11119.76 81.24 125.57 31.37 8952.61 893.79 2558.96 2090.92 3304.58 39.25 4.31 MWO-IFR-MSA 50 11150.87 80.52 124.82 31.11 8957.54 923.88 2541.25 2116.03 3306.89 39.78 3.32 MWD-IFR-MSA 51 11192.68 80.46 126.29 41.81 8964.45 964.21 2517.28 2149.57 3310.19 40.49 3.47 MWD-IFR-MSA --- Projected to TO: 52 11242.00 80.46 126.29 49.32 8972.63 1011.65 2488.49 2188.78 3314.11 41.33 0.00 Projected [(c)2003 IDEAL 108 OC 07] W-23A Survey Report - Geodetic Schlumberger Report Date: 30-Apr-03 Survey / DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 113.560° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: W-PAD/W-23 TVD Reference Datum: KB Well: W-23 TVD Reference Elevation: 82.360 ft relative to MSL Borehole: W-23A Sea Bed / Ground Level Elevation: 47.830 ft relative to MSL UWUAPI#: 500292199301 Magnetic Declination: +25.650° Survey Name / Date: W-23A 1 April 30, 2003 Total Field Strength: 57521.473 nT r___ Tort / AHD / DDI/ ERD ratio: 249.504° 14874.84 ft /6.1831 0.543 Magnetic Dip: 80.779° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: May 07,2003 Location Lat/Long: N 70.29884712, W 149.09255294 Magnetic Declination Model: BGGM 2002 Location Grid N/E Y/X: N 5959700.860 ftUS, E 612048.920 ftUS North Reference: True North Grid Convergence Angle: +0.85433666° Total Corr Mag North -> True North: +25.650° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (o/100ft) (ftUS) (ftUS) 9591.76 35.00 41 .48 8690.45 -394.48 3064.22 905.83 5962777.97 612908.88 N 70.30721818 W 149.08521493 9681.00 34.55 42.28 8763.75 -378.48 3102.11 939.80 0.72 5962816.37 612942.29 N 70.30732170 W 149.08493965 9697.00 35.54 45.15 8776.85 -375.31 3108.75 946.15 12.01 5962823.10 612948.54 N 70.30733983 W 149.08488821 9722.16 37.45 54.36 8797.09 -368.70 3118.37 957.56 23.04 5962832.89 612959.80 N 70.30736611 W 149.08479576 9753.37 43.29 63.90 8820.88 -356.89 3128.63 974.92 27.20 5962843.40 612977.00 N 70.30739412 W 149.08465518 9783.44 49.65 71.47 8841.60 -341.69 3136.82 995.08 27.91 5962851.89 612997.03 N 70.30741649 W 149.08449187 9813.82 56.71 72.66 8859.80 -323.48 3144.29 1018.20 23.45 5962859.71 613020.04 N 70.30743690 W 149.08430451 9845.91 55.54 84.42 8877.73 -301.73 3149.59 1044.23 30.63 5962865.39 613045.99 N 70.30745136 W 149.08409361--~' 9875.66 54.69 81.23 8894.74 -280.76 3152.63 1068.44 9.25 5962868.80 613070.15 N 70.30745967 W 149.0838975(,' 9907.48 56.56 81.75 8912.71 -258.50 3156.52 1094.42 6.03 5962873.07 613096.06 N 70.30747027 W 149.08368709 9937.89 60.32 86.44 8928.63 -235.95 3159.16 1120.18 18.04 5962876.09 613121 .77 N 70.30747748 W 149.08347840 9969.08 64.67 88.99 8943.03 -211.05 3160.25 1147.81 15.72 5962877.60 613149.38 N 70.30748045 W 149.08325454 9999.99 67.37 92.31 8955.60 -185.04 3159.92 1176.04 13.14 5962877.69 613177.62 N 70.30747954 W 149.08302583 10031.01 72.27 96.24 8966.30 -157.57 3157.74 1205.06 19.77 5962875.94 613206.66 N 70.30747355 W 149.08279077 10063.77 78.44 97.54 8974.58 -127.22 3153.93 1236.51 19.22 5962872.60 613238.16 N 70.30746314 W 149.08253600 10096.47 84.23 100.48 8979.50 -95.95 3148.87 1268.42 19.81 5962868.01 613270.14 N 70.30744929 W 149.08227750 10125.89 88.77 105.87 8981.30 -67.08 3142.18 1296.99 23.92 5962861.75 613298.81 N 70.30743099 W 149.08204604 10157.03 91.58 110.66 8981.20 -36.08 3132.42 1326.55 17.83 5962852.43 613328.51 N 70.30740433 W 149.08180659 W-23A ASP Final Survey.xls Schlumberger Private Page 1 of 2 6/4/2003-3:00 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) r) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 10187.81 95.29 112.81 8979.36 -5.38 3121.05 1355.09 13.92 5962841 .49 613357.20 N 70.30737324 W 149.08157546 10217.91 96.05 116.75 8976.38 24.56 3108.49 1382.28 13.27 5962829.34 613384.58 N 70.30733894 W 149.08135521 10249.67 95.70 120.87 8973.13 56.01 3093.27 1409.95 12.95 5962814.54 613412.47 N 70.30729734 W 149.08113104 10280.98 95.71 124.38 8970.02 86.77 3076.48 1436.19 11.15 5962798.14 613438.95 N 70.30725144 W 149.08091853 10311.77 95.84 126.74 8966.92 116.73 3058.67 1461.11 7.64 5962780.70 613464.13 N 70.30720277 W 149.08071670 10343.96 96.01 127.21 8963.60 147.88 3039.41 1486.68 1.55 5962761 .83 613489.99 N 70.30715014 W 149.08050951 10375.69 95.87 126.75 8960.31 178.58 3020.42 1511.90 1.51 5962743.22 613515.48 N 70.30709826 W 149.08030531 10406.44 95.09 131.42 8957.37 208.06 3001.13 1535.65 15.33 5962724.29 613539.52 N 70.30704554 W 149.08011293 /~---- 10437.25 94.57 133.45 8954.78 237.11 2980.42 1558.30 6.78 5962703.92 613562.48 N 70.30698894 W 149.07992943. /, 10468.37 95.29 134.07 8952.11 266.21 2958.97 1580.70 3.05 5962682.81 613585.19 N 70.30693034 W 149.07974806 10498.88 95.71 134.96 8949.18 294.57 2937.68 1602.35 3.21 5962661.85 613607.16 N 70.30687216 W 149.07957268 10530.66 95.91 135.34 8945.96 323.97 2915.26 1624.65 1.35 5962639.77 613629.78 N 70.30681092 W 149.07939209 10560.83 94.71 134.07 8943.17 351 .98 2894.13 1646.00 5.78 5962618.96 613651.44 N 70.30675317 W 149.07921917 10592.17 93.13 131.02 8941.03 381.54 2873.00 1669.03 10.94 5962598.17 613674.79 N 70.30669541 W 149.07903263 10622.84 92.17 130.19 8939.61 410.83 2853.06 1692.29 4.14 5962578.58 613698.34 N 70.30664093 W 149.07884425 10654.79 93.20 129.63 8938.11 441 .46 2832.58 1716.77 3.67 5962558.47 613723.12 N 70.30658497 W 149.07864598 10685.91 93.85 129.11 8936.20 471.34 2812.88 1740.79 2.67 5962539.13 613747.42 N 70.30653113 W 149.07845150 10717.51 94.02 128.57 8934.03 501.75 2793.11 1765.34 1.79 5962519.73 613772.27 N 70.30647710 W 149.07825263 10748.19 93.51 127.37 8932.02 531 .41 2774.27 1789.47 4.24 5962501.26 613796.68 N 70.30642563 W 149.07805717 10779.15 90.21 127.39 8931.01 561 .45 2755.49 1814.06 10.66 5962482.85 613821.54 N 70.30637430 W 149.07785805 10810.16 88.91 124.68 8931.25 591 .72 2737.25 1839.13 9.69 5962464.98 613846.88 N 70.30632446 W 149.07765499 10839.84 88.84 124.92 8931.83 620.83 2720.31 1863.50 0.84 5962448.42 613871.49 N 70.30627817 W 149.07745764 10871.98 89.15 124.17 8932.40 652.37 2702.09 1889.97 2.52 5962430.59 613898.23 N 70.30622837 W 149.07724326 10902.09 88.50 124.26 8933.02 681.96 2685.16 1914.86 2.18 5962414.04 613923.37 N 70.30618211 W 149.07704165.-- 10933.27 87.26 124.31 8934.17 712.57 2667.61 1940.61 3.98 5962396.87 613949.37 N 70.30613415 W 149.07683315 10964.05 86.19 124.95 8935.93 742.73 2650.15 1965.89 4.05 5962379.79 613974.91 N 70.30608642 W 149.07662836 10995.41 85.51 126.44 8938.20 773.31 2631.90 1991.29 5.21 5962361 .93 614000.58 N 70.30603655 W 149.07642264 11026.28 84.55 126.07 8940.87 803.31 2613.71 2016.09 3.33 5962344.11 614025.64 N 70.30598684 W 149.07622179 11057.52 83.17 126.34 8944.21 833.61 2595.37 2041 .15 4.50 5962326.14 614050.97 N 70.30593671 W 149.07601882 11088.39 82.29 126.43 8948.12 863.47 2577.20 2065.81 2.87 5962308.35 614075.89 N 70.30588706 W 149.07581917 11119.76 81.24 125.57 8952.61 893.79 2558.95 2090.92 4.31 5962290.48 614101.27 N 70.30583719 W 149.07561576 11150.87 80.52 124.82 8957.54 923.87 2541.25 2116.02 3.32 5962273.15 614126.63 N 70.30578880 W 149.07541247 11192.68 80.46 126.29 8964.45 964.21 2517.27 2149.57 3.47 5962249.68 614160.53 N 70.30572327 W 149.07514079 11242.00 80.46 126.29 8972.63 1011.65 2488.49 2188.77 0.00 5962221.48 614200.16 N 70.30564460 W 149.07482330 W-23A ASP Final Survey.xls Schlumberger Private Page 2 of 2 6/4/2003-3:00 PM ~~~~E ~ I' f ~~~~~~~ FRANK H. MURKOWSK/, GOVERNOR ~ AIfA~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaccson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe W-23A BP Exploration (Alaska), Inc. Permit No: 203-056 Surface Location: 556' SNL, 1179' WEL, Sec. 21, TI1N, RI2E, UM Bottomhole Location: 1945' NSL, 1022' EWL. Sec., 15, TI1N, RI2E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~L-, / A~~~ Randy Ifuedrich Commissioner BY ORDER OF THE COMMISSION DATED this~day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ì¡.J(j 1+ 4' ~ I lOC' '3' 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 612049, Y = 5959701 556' SNL, 1179' WEL, SEC. 21, T11 N, R12E, UM At top of productive interval x = 613360, Y = 5962800 2524' NSL, 185' EWL, SEC. 15, T11 N, R 12E, UM At total depth x = 614207, Y = 5962235 1945' NSL, 1022' EWL, SEC. 15, T11N, R12E, UM { STATE OF ALASKA .' ALASKA_.... AND GAS CONSERVATION COMrvt......310N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 90.6' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool / ADL 028263 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' W-23A 9. Approximate spud date 04/15/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11243' MD / 9035' TVD o 17. Anticipated pressure {see 2.Q,.AAC 25.035 (e) (2)} / 93 Maximum surface 2707 psig, At total depth (TVD) 8930' / 3600 psig Setting Depth Top Bottom Quantity of Cement Lenath MD TVD MD TVD (include staae data) 1700' 9570' 8675' 11243' 9035' Uncemented Slotted Liner 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 12. Distance to nearest property line 13. Distance to nearest well/ ADL 028261, 3335' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9720' MD Maximum Hole Angle 18. CaSing;~~gram Specifications Hole Casina Weiaht Grade Couplina 6-1/811 4-1/211 12.6# L-80 I IBT 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 1 0200 feet 9203 feet 10150 feet 9161 feet Length Plugs (measured) Magna RarR~E4VEesand to about 9900' Junk (measured) 3915 cu ft Coldset II APR 0 2 200] Cemented I I~ {'\)II øG' ('" .MD, , l~ ~$I\a \',11 r.it :ÏiS )OíÞ5. Ccmm::;,:s¡on A·,!",'ht""",~, ~ ';,., .,.'~:~''''' 146' 2678' TVD Size 146' 2678' 2011 13-3/811 146' 2673' 9766' 9-5/811 2018 cu ft Class 'G' 9766' 8836' Perforation depth: measured Open: 9850' - 9890', 9898' - 9917', 9928' - 9954', 9966' - 9996'; Open Hole: 10171' - 10200' Sqzd: 10020' - 10040' true vertical Open: 8906' - 8940', 8947' - 8963', 8972' - 8994', 9005' - 9030'; Open Hole: 9179' - 9203' Sqzd: 9050' - 9067' II Filing Fee 0 Property Plat II Drilling Fluid Program 0 Time vs Depth Plot o BOP Sketch 0 Diverter Sketch II Drilling Program o Refraction Analysis 0 Seabed Report 1120 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 20. Attachments Contact Engineer Name/Number: Nei/ Magee, 564-5119 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ,. ',' ..... ;~~~~.., ,~~,I:~':~i..,fJ:~tl:::;;;~":¡"""i~"'ji 'r'I~':'::':'I""';;:"i~¡¡;;¡:'=:"~~:~~~""~:~~'~'!;~~:~I~¡'::~'~'~!~;~:I:I~q:f"I:~":¡il;i:(il:,";';";'1",:,';I"~,I.~:.II" ...,,~~:tlll:".'I."..·.:'II~,,!:~~'I~' .,:",,~:,; .~I'~."";?~'I~"" .,.',.... Permit Number API Number Appro/~ D9.te See cover letter .2.03 - CJ S C, 50- 029-21993-01 c.¡ I f¡ U_J for other reauirements Conditions of Approval: Samples Required 0 Yes tBI No Mud Log Required 0 Yes J&1 No Hydrogen Sulfide Measures iii Yes 0 No Directional Survey Required mI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: "T.et;. 1;- BO' P E fc '~5" 00 p" i . Approved By R~ ~ Form 10-401 Rev.' 12-01-85) by order of Com"Ott GNÄ:ion Date futL ~t¿e ( (' IWell Name: IW-23A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Existin~ Target Location: Ivishak Zone 4 Bottom Hole Location: x = 612,048.92 Y = 5,959,700.86 556' FSL, 1179' FEL Sec. 21, T11N, R12E Umiat X = 613,360 Y = 5,962,800 TVD 8966' 2524' FSL, 5094' FEL Sec. 15, T11N, R12E Umiat X = 614,207.2 Y = 5,962,234.7 TVD 9035' 19451 FSL, 4257' FEL Sec. 15, T11 N, R12E Umiat I AFE Number: 1 PBD4P??? 1 1 Estimated Start Date: 1 04/15/03 /' I RiQ: I Nabors 9ES /" I OperatinQ days to complete: 117.0 1 MD: 111,243' 1 1 TVD: 19,035' I 1 BF/MS: 154.46' 1 1 KB: 1 I I KBE: 190.6' I Well Desi~n (conventional, slim hole, etc.): 1 Horizontal Sidetrack I Objective: I Zone 4B Formation Markers Formation Tops TJA TSGR TSHU TElL TSADfTZ4B 45N 44N Land/Invert 44N 45N Invert 2 45N 44N POWC Low Case 43N POWC (Exp Case) 42N TD OOWC TVD 58 -8599 -8686 -8715 -8812 -8827 -8868 -8883 -8887 -8881 -8867 -8855 -8877 -8893 -8912 -8916 -8940 -8947 -8945 -8983 Comments Hydrocarbon Bearing Hydrocarbon Bearing Hydrocarbon Bearing Hydrocarbon Bearing Hydrocarbon Bearing Hydrocarbon Bearing Hydrocarbon Bearing Hydrocarbon Bearing, 3600 psi (7.8 ppg) Hydrocarbon Bearing /' HYDROCARBON BEARING? HYDROCARBON BEARING? TD Criteria: TD below 43N sand or when 6 ohm resistivity in clean sand is encountered. W -23A Sidetrack { ~. CasinQ/TubinQ Pro~ ram Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDfTVD MDfTVD 61/8" 4 ¥2" Slotted 12.6# L-80 1ST -1,700' 9570' / 8675' 11,243'/ 9,035' ,.,- Tubing 4 ¥2" 12.6# 13Cr80 V AM ACE -9570' GL 9570' / 8675' Directional KOP: I 9720' MD Maximum Hole Angle: Close Approach Well: -930 in 6 1/8" horizontal section There are no close approach issues with the planned sidetrack. The closest well is W-21 at a 213' center-to-center in the reservoir section. MWD from kick-off to TD. (Change MWD to satisfy JORSS Survey Program: Mud ProQram Section Milling Mud Properties: Flo-Pro Drill-in I Whip Stock Window 9 5/8" Density (ppg) Viscosity PV YP 10 sec gel 8.6 45-60 14 -18 35-40 15 - 20 I MBT 6-8 PH 9.0-9.5 API FI 8 Production Mud Properties: Flo-Pro Drill-in Density (ppg) ... LSRV PV 8.6 - 8.7 ,/ 55,000+ 7 - 11 I 6 1/8" hole section YP LSYP 30-35 8 - 14 I MBT <6 pH 9.0 - 9.5 API FI 4-6 Logging Program 6 1/8" Production: Sample Catchers - 30' intervals Drilling: MWD Dir/GR/Res/ABI- Real time GR/Res throughout entire interval. Open Hole: None Cased Hole: None Cement Program (N/A) Casing Size I 4 1/2", 12.6#, L-80 Slotted 1 Solid Production Liner Basis: I None. Uncemented solid/slotted liner W -23A Sidetrack ( Well Control 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. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 3600 psi (7.7 ppg @ 8930' TVD) 2707 psi psi (.10 psi/ft gas gradient to surface) Infinite ~soo ~ Rams test to.5r0G9 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure ~ 8.4 ppg Seawater / 7.2 ppg Diesel 9-5/8" Casing /4-1/2" Liner Test Planned completion fluids Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. H2S · W Pad is not and H2S site. As a precaution however Standard Operating Procedures for H2S should be followed at all times. W -23A Sidetrack ~. ( Sidetrack and Complete Procedure Summary Pre-Ria Work: 1. Pressure test the tubing and casing pack-offs to 5000 psi. 2. RU coil tubing. RIH with mill and attempt to mill/push obstruction at 6976' to top of sand at approximately 9900'. 3. Liquid pack tubing and IA. 4. Pressure test verify repairs on lower wellhead housing. 5. String shot and chemical cut the 3-1/2" tubing at +/-9750' GR and the upper 3' of the short joint at 9455' above the Otis HC packer at 9471' 6. Circulate the well to seawater and shut in after 1.25X circulations. Freeze protect the well to 2200' with diesel. 7. Back out and run in all LDS. Set BPV. 8. Remove wellhouse and level pad if necessary. Well preparation cost to be provided on the Handover Form. Ria Operations: 1. MIRU Nabors 9ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to.éQ9&pS~6~ 4. Pull 3Y2" tubing from above pre-rig cut. 3'~OO 5. Make up overshot assembly and recover anchor from Otis HC packer. Mill over and recover /. packer from tubing cut at 9,750'. 6. MU window milling BHA and drift down through the BP setting depth. Set BP on E-line (set as needed to avoid cutting casing c<;!!pr). 7. Test 9-5/8" casing to 3000 psi. 8. RIH with 9 5/8" Baker bottom-trip anchor ~ipstock assembly. Orient whipstock and set on BP. Mill window in 95/8" casing at ±9,700' MD (top of window). Perform FIT to 1æ;.:.5 ~ W. POH. 9. Kick-off and drill the 6-1/8" hole as per directional plan to an estimated TD of , . 10. Run a 4 Y2", 12.6# L-80 production liner consisting of a combi!)9-tion of s --and slotted liner. Displace well to clean seawater above liner top. POH LD DP. 11. Run 4-1/2", 12.6# 13Cr completion tying into the liner top. . 12. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. ,..,- 13. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. .",..-. 14. Freeze protect the well to -2200' and secure the well. 15. Rig down and move off. Post-Ria Work: 1. MIRU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. W -23A Sidetrack ( ( Backqround: Well W-23 was drilled and completed in January 1990. The well was completed with a series of sliding sleeves and CTC packers across the open hole interval. The well initially produced 500 BOPD at 80% WC. A cement squeeze was performed on the well ,/' in March 1990 to isolate the lower 42P interval which was suspected of being the source of the produced water. The cement squeeze clogged up the open sliding sleeves above and the well was perforated through the tubing interval to restore productivity in March and April of the same year. After a period of one year, production had fallen to 100 BOPD. Subsequent HCL stimulations were able to stabilize the well at approximately 600 BOPD. A frac was performed on the well in 1997 with no increase in oil rates. The production rate subsequently fell to 250 BOPD. The well is currently sanded back to 9900' and shut in due to well integrity issues. Currently the well appears to have a fish or perhaps collapsed tubing at 6976' and numerous holes in the completion tubing above the packer. (A video surveillance run was run to verify the tubing condition and to try and identify the fish.) Coil tubing operations are planned in late March to clean out the fish/ascertain if the tubing is collapsed. Based upon the poor tubing condition and added drainage by drilling a lateral through the existing completion interval (46P through 43P), the decision was made to pursue a sidetrack using a rotary rig. Job 1: MIRU Hazards and Contingencies ~ The closest surface locations are W -24 and W -22. The wells are on 35' centers. If well houses are removed for the move in the offset wells will require a surface shut-in. ~ W Pad is not an H2S site. Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP :mmmm.-mW;¡¡.m¡.,m;m;J¡m;J..IAlmm¡.¡.;mmm!m;!¡"-,-~-,-,-W:.-,-¡.,-.-;mm;,-!'-A-!~m#ffl!Hf¡jm¡¡;I»i;I,-~u,-m.-.-".,,-,-!M,--n;!!)!,:mm'~¡J~~;m;.-AA-;';:!.-!¡.m.:¡AI'm/#'mm~1mm~'mAlAAI,I'¡m!m!;¡'ßWAA¡;'m¡'¡¡'-.)¡;:ff;:;:;,";:;;;;"';';;';;';",,,,",;"'~m!mm¡.mmmm¡¡';»Immm!;~~,~~,I'i¡;m;"'''N";",.,mm~,.,-¡"I.o''''....m..,,;,mm'~ Job 2: De-complete Well Hazards and Contingencies ~ The lower section of this well is isolated by the tubing hanger and BPV and kill-weight fluid only. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ The existing wellhead is an FMC Big Bore and has a 3 V2" TDS tubing hanger (FMC PIN 82-745- 630). Hanger has a Cameron Type H BPV profile. Verify the landing joint connection with FMC representative. Be prepared with necessary removal equipment. ~ The tubing currently has an obstruction ay 6,976'. Pre-rig coil work will attempt to mill/push this obstruction below the lower tubing cut depth at 9750' GR. If this is unsuccessful, the rig will need to perform an outside cut below this obstruction and recover the fish. ~ Tubing appears to be corroded and have a number of holes present. Exercise care when handling tubing and pulling tubing free from cuts. Reference RP .:. "De-completions" RP ">'>1">W"""'''''''''''''''''''''H'''''''''''''''''''"""",,,,~Im'~ ~~~~~~~t~~~_~)~x. W -23A Sidetrack ( Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. ~ It is critical that the Kingak shale above the proposed KOP is isolated. The shale is over pressured and will compromise the drilling of the production hole section if it is left open. Reference RP .:. "Whipstock Sidetracks" RP . "''''II'' .I.L.'.IL_U. _I "'11I.1"111__11_ .I. _, ,- ·'III·...·....'III_L'.'-I Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies ~ No faults are anticipated in the production hole interval. However should losses occur, follow the Lost Circulation Decision Tree. ~ The anticipated reservoir pressure is 3550 to 3600 psi (7.7 ppg EMW). At 8.6 ppg the Flo-Pro /' mud density will provide about 400 psi overbalance. ~ An FIT of 12.0 ppg EMW will provide infinite kick volume with 8.6 ppg mud weight in the hole. ~ Tie MWD into parent log by running approximate 200' overlap log with MWD. ~ Observe hardlines in directional plan to maintain at least 200' separation from small fault to the North. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP _1=:;:==:~~--_~~:II:_I:a:lallal::III:II:::I:II!II:_ ---n-----·-·--""T·.;~+e:~I:m:ml!imn::clll:lmlclll::::_I'!:111111'1:11: -1',-'-=-_i«I'¡'¡~:<W""'''':':>:' ~'·.~!I:I:I!r-::mlllllm:lmlll:m¡'-I':II_II~~1111111Im:ml':1III:-mlm:m:,,-.....- Job 9: Install 41h" Slotted Production Liner Hazards and Contingencies ~ The completion design includes a 4 Y2", 12.6#, L-80 slotted liner throughout the production interval. Solid liner will be placed through non productive intervals as determined by the subsurface team. ~ High differential pressure between hydrostatic and reservoir creates concern for stuck pipe while running the liner. Ensure that the well is particularly clean prior to the final trip out of the hole and minimize connection time while running liner. ~ Sufficient 4 Y2" liner will need to be run to extend -150' back up into the 9-5/8" intermediate casing. W -23A Sidetrack ( f Reference RP .:. None applicable Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP .:. "Handling and Running 13 Chrome" RP '~:!m¡:lmUUlIIIIII~:IIIWlllaIJ_'I""-i'/I(:!lImmlll"C:m:!:lllla!1IIIII.I:IIIIIUIIU__I_.IIIIII-'oIV''CIII/IHmWY>),III:.HII/IUlmllllmummLmIIlIIIL-·'-....:lulIL,·mlllllm:mmll.mm__III.IIIIIL:W:/lIIIIUIIUIIIIUIIUIIII!'\II'I:w.:llamICIIllIIIIIUIIL.IIL:LI--II:IIcmlw.lIJo'lClm1IIIIIIIIIIIIma,al__IUIL,:IU:I:J:II,IIIIW"''IlIlJo'ICIIIIoi\fo'\IHIo/It.'lmla:lllml:mlll,lIIII~I:IIUIIC:-:II---:'I>'IIUllrC_--1I Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ There are no identified hazards particular to this phase of the operation. Reference RP .:. "Freeze Protecting an Inner Annulus" RP W -23A Sidetrack BF. REV = 54.46' KOP = 3300' "Max"Äñ'Qie";'"""-""" ,"'"""-_..,,,,,,,.,," '5ãtLlm'MÕ-;-"""-''''"""""""" "-,,-,,, . batuïï,TVÖ;';' ( 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 26781 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 9-5/8"X 4-1/2" Baker S-3 Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.75" NoGo. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. Tie Back Sleeve BAKER 7" x 9-5/8" HMC Liner Hanger Window Milled from Whipstock Top of Window at +/-9700' MD Bridge Plug set at +/-9740' MD 9-5/8" CSG, 47#, L-80, ID = 8.681" r-I 97661 1 20' CTC PKR r-I 98591 PERFORA TION SUMMARY REF LOG: BHClGR ON 01/08/90 A NGLE AT TOP ÆRF: 33 @ 9850' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 8 9850 - 9890 0 09/01/97 2" 4 9898 - 9917 0 04/01/90 2" 4 9928 - 9954 0 03/26/90 2" 4 9966 - 9996 0 03/21/90 2-1/2" 4 10020 - 10040 S 03/08/90 ~ ~~ ~ ~~------------------------II¡i: I ~ __________________________1 . , W-23a Sidetrack . . I~ L z! ~~ . ~: : ~ +;/~::;.r .t~;:'I '~I ~":w;~~~,!;<" ZI ;?~]~ , ',.!--.)Ji.~::~.~(: , ':'.;; .-~; ,..~ . -. ~ s.",·.··: > ..:. . ,;. ~ 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" r-I 101711 I -----IX I I 101501 r-IMAGNA RANGEBP I 18-1/2" OÆN HOLE r-I 102001 DATE 03/18/03 REV BY NM COMMENTS Proposed Sidetrack DATE I~.~ I I ~ CMT;'" I ~ ¡~ REV BY COMMENTS ( 20001 1-14-1/2" HES X NIP, ID = 3.813" 1 4-1/2" 12.6# 13Cr-BO Yam Ace with GLM's GA S LIFT MA NDRB...s ST MD "TVD DEV ìYÆ VLV LATCH PORT DATE 6 KBG-2 RK 5 KBG-2 RK 4 KBG-2 RK 3 KBG-2 INT 2 KBG-2 INT 1 KBG-2 INT ~ ....-- I TD 11428' 1-14-1/2" 12.6# L-80 Slotted/Solid Liner XI PRUDHOE BA Y UNIT WELL: W-23A PERMrr No: PERMrr No: 50-XXX-OO SEC21, T11N, R12E, 556' FSL & 1179' FEL BP Exploration (Alas ka) bp Report Date: Client: Field: Structure / Slot: Well: Borehole: UWI/API#: Survey Name / Date: Tort / AHD / DDI/ ERD ratio: Grid Coordinate System: Location LatlLong: Location Grid N/E YIX: Grid Convergence Angle: Grid Scale Factor: W-23A Proposed Well Profile - Geodetic Report March 19.2003 BP Exploration Alaska Prudhoe Bay Unit - WOA (Drill Pads) ty ~~~:D/W-23 feasibill W-23A 500292199301 W-23A (P4) 1 March 19, 2003 215.965° /4862.17 ft 16.116/ 0.53E NAD27 Alaska State Planes. Zone 4, US Feel N 70.29884712, W 149.09255294 N 5959700.860 ftUS, E 612048.920 ftUS -+D.85433666° 0.99991426 Survey / DLS Computation Method: Vertical Section Azimuth: studY Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed / Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: Schlumberger Minimum Curvature / Lubinski 113.560° N 0.000 ft, E 0.000 ft KB 81.1 ft relative to MSL 47.830 ft relative to MSL 25.673° 57520.536 nT 80.778° April 15,2003 BGGM 2002 True North +25.673° Well Head _0_ Grid Coordinates Geographic Coordinates I Station ID MD Incl I Azim TVD I VSec NJ·S E/·W I DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) Survey 9590.51 35.00 41.48 8689.20 -394.48 3064.22 905.83 0.00 5962777.98 612908.88 N 70.30721818 W 149.08521491 Sag River 9685.34 34.53 42.32 8767.11 -377.46 3104.46 941.94 0.71 5962818.75 612944.39 N 70.30732810 W 149.08492234 Tie-in Survey 9690.51 34.50 42.37 8771.37 -376.52 3106.63 943.91 0.71 5962820.94 612946.33 N 70.30733403 W 149.08490638 KOP Crv 22/100 9720.00 34.10 41.91 8795.73 -371.23 3118.95 955.06 1.62 5962833.43 612957.29 N 70.30736768 W 149.08481604 Shublik 9720.46 34.13 42.08 8796.11 -371.14 3119.14 955.23 22.00 5962833.62 612957.46 N 70.30736820 W 149.08481467 9800.00 42.80 66.77 8858.69 -345.35 3146.58 995.33 22.00 5962861.65 612997.14 N 70.30744315 W 149.08448979 TElL 9849.99 50.28 77.92 8893.11 -318.02 3157.33 1029.84 22.00 5962872.92 613031.48 N 70.30747251 W 149.08421021 TSAD 9874.50 54.28 82.49 8908.11 -301.82 3160.61 1048.94 22.00 5962876.48 613050.53 N 70.30748146 W 149.08405548 -- 9900.00 58.61 86.77 8922.21 -283.22 3162.57 1070.09 22.00 5962878.76 613071.65 N 70.30748681 W 149.08388414 45N 9961.52 69.53 95.69 8949.11 -232.12 3161.19 1125.24 22.00 5962878.20 613126.81 N 70.30748301 W 149.08343738 10000.00 76.58 100.60 8960.32 -196.66 3155.95 1161.63 22.00 5962873.50 613163.27 N 70.30746868 W 149.08314259 44N 10018.68 80.03 102.87 8964.11 -178.76 3152.23 1179.54 22.00 5962870.05 613181.23 N 70.30745851 W 149.08299750 10072.02 89.97 109.15 8968.76 -126.18 3137.58 1230.52 22.00 5962856.16 613232.42 N 70.30741847 W 149.08258453 Crv 8/100 10072.11 89.97 109.15 8968.76 -126.09 3137.55 1230.60 0.00 5962856.13 613232.50 N 70.30741839 W 149.08258389 10100.00 90.42 111.33 8968.66 -98.24 3127.90 1256.77 8.00 5962846.88 613258.81 N 70.30739201 W 149.08237190 10200.00 92.02 119.17 8966.54 1.61 3085.29 1347.12 8.00 5962805.62 613349.77 N 70.30727556 W 149.08164004 Target 10211.68 92.20 120.09 8966.11 13.21 3079.52 1357.26 8.00 5962800.00 613360.00 N 70.30725979 W 149.08155790 End Crv 10257.58 93.31 123.59 8963.90 - 58.58 3055.33 1396.20 8.00 5962776.40 613399.29 N 70.30719369 W 149.08124249 Schlumberger Private W-23A (P4) report.xls Page 1 of2 3/19/2003-9:49 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NJ·S EJ-W DLS Northing I Easting Latitude I Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) Cry 8/100 10628.24 93.31 123.59 8942.48 422.96 2850.59 1704.44 0.00 5962576.29 613710.52 N 70.30663418 W 149.07874586 Target 10675.70 90.00 125.45 8941.11 469.53 2823.71 1743.53 8.00 5962550.00 613750.00 N 70.30656072 W 149.07842925 End Cry 10699.70 88.08 125.45 8941.51 493.01 2809.79 1763.07 8.00 5962536.38 613769.75 N 70.30652268 W 149.07827099 Orp 8/100 10866.74 88.08 125.45 8947.11 656.37 2712.98 1899.08 0.00 5962441.61 613907.17 N 70.30625811 W 149.07716943 10900.00 85.42 125.45 8948.99 688.86 2693.72 1926.13 8.00 5962422.76 613934.51 N 70.30620548 W 149.07695035 11000.00 77.42 125.45 8963.90 785.54 2636.42 2006.61 8.00 5962366.67 614015.82 N 70.30604888 W 149.07629855 Target / Orp 2.34/100 11030.24 75.00 125.45 8971.11 814.28 2619.39 2030.54 8.00 5962350.00 614040.00 N 70.30600234 W 149.07610474 11100.00 73.37 125.45 8990.12 879.96 2580.46 2085.21 2.34 5962311.90 614095.24 N 70.30589594 W 149.07566198 11200.00 71.03 125.45 9020.69 973.12 2525.24 2162.77 2.34 5962257.84 614173.61 N 70.30574503 W 149.07503385 ,- TO /4-1/2" Lnr pt 11243.23 70.02 125.45 9035.11 1013.01 2501.60 2195.97 2.34 5962234.70 614207.16 N 70.30568042 W 149.07476497 LeQal Description: Surface: 4723 FSL 1179 FEL S21 T11N R12E UM Tie-In: 2508 FSL 266 FEL S16 T11 N R12E UM Target: 2523 FSL 5095 FEL S15 T11N R12E UM Target: 2267 FSL 4709 FEL S15 T11N R12E UM Target: 2063 FSL 4423 FEL S15 T11N R12E UM BHL: 1945 FSL 4257 FEL S15 T11N R12E UM NorthinQ ey) rftUSl 5959700.86 5962777.97 5962800.00 5962550.00 5962350.00 5962234.70 W-23A (P4) report.xls Schlumberger Private Page 2 of 2 EastinQ eX) rftUSl 612048.92 612908.88 613360.00 613750.00 614040.00 614207.16 - 3/19/2003-9:49 AM VERTICAL SECTION VIEW Client: Well: Field: Structure: Section At: Date: BP Exploration Alaska W-23A (P4) Prudhoe Bay Unit - WOA W-PAD 113 . 56 deg March 19, 2003 Schlumberuer 8100 ------- __________m____.. - ~___ ________m________"______________ ~__ _~ ___~ _________~__ _ ____ __ ~__________ ------------------...------.----------- . -- i-.. ~~ 8400 ------ -....-----.----.--...---..--------.---- -_.._---~._------_._----_._- ---------..------.-------- ------------ ---------.-- _._._------_._-_._-_.~.- --_.._--.._---.----_...-- j -I ......... m::J ~cn 02 o 0> ('f) > II ß .~ ro ~¢:: ..........~ ~ Survey : 9591 MD 86891YD 35.00° 41.48° ai -394 departure '~ 8700 -----..-----.---..--------f---.--------- : Tie-in Survey : 9691 MD 8771 TVD ! 34.50° 42.37° az -J:.~~~!"S. ! -::-œE~!i¡;o="~,,:.~~t:,~ .------ Y}- - 10212 MD 8966 TVD 423 departure 1;470 departure 88.08" ! 125.45° az Drp 81100 : - 92:20~ 1:;p.09° az . \ 493 deJiarture / 10867 MD 89471YD 13 depa~e . /! 88.08° 125.45' az: ! 656 departure ! Target I Drp 2.341100 ! Y 11030 MD 8971 TVD .:::: -= ß~D~~il¡?~~R'{f5 = =- -= = .== +- Hold Angle 9;3.31 0-00 ! 0 /" ¡ ~~4O:::p~~r:5'az ~1~q~7i~~~a~~~~ =" ~= ~.____ =·::it:~~,~:[~!:*~ ---+-..--------..----- ----------..;.--------..----. ---------------.-.._----, ..s::: .... a. ~ O>CO o f9 9000": ro~ o.¡...: :e 0> 0>0::: > > O>~ 2W I- '-'b b ..---¡- o 10258!MD 8964 TVD 93.311 123.59" az 59 deJiarture TO 14-112" Lnr Ì>t 11243 MD 903~ TVD 70.02" 125.45°:az 1013 departure i _.............~ 9300 --.--- ·_______··_________._h_....._ __...._.-!____._m.___________ ___.._____________.~--------- -------------"-------------- ~-------------------------_...;..---_._- . . ..--.---.----.----.-----.---..-.-....¡-..-.-. ..-..........-............ 9600 -900 I -600 I -300 0 -300 600 900 Vertical Section Departure at 113.56 deg from (0.0, 0.0). (1 in = 300 feet) t 1200 Schlumberuer PLAN VIEW Client: Well: Field: Structure: Scale: Date: BP Exploration Alaska W-23A (P4) Prudhoe Bay Unit - WOA W-PAD 1 in = 300 ft 19-Mar-2003 600 900 1200 1500 1800 I I I I f 3600 __------------l-------~~-~------__j_~_____________'_____--------------+-------- 2100 , 2400 , · . · . · . -----------------------------------------..---- --- · . · . True North Mag Dee ( E 25.67° W-23 · . · . · . · . · . · . · , · . · . ª"~~!:D I . ! I ~I ~-~~~~~r--T-------¡ N .... I l- => o (f) V V V 3300 --- KOP CN 22/100 9720 MD 8796 TVD 34.10" 41.91' az 3119 N 955 E ^ ^ ^ I l- n:: o z 3000 _-----------L----------______.__ : Survey : 9591 MD 8689 TVD End CN 10700 MD 8942 TVD 88.08' 125.45' az 2810 N 1763 E --------------------,~--~..-- - 2700 ------.----- -.-------------------..--.----------.------- 2400-· .- ---- ---- - - - - -- --- ------- ---- -~~ --. 2100 I 900 2400 I 2100 600 1200 «< WEST 1500 1800 EAST »> 2700 ..-- - 3600 -~~~ __O______h"._____.._O·._ - 3300 . . q - 3000 .-- ... - 2700 -~;.g,~ - 2400 2100 2700 t: BP Exploration Alaska (: Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Prudhoe Bay PB W Pad W-23 Plan W-23A NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 9700.00 to 11243.23 ft Maximum Radius: 3000.00 ft Survey Program for Definitive Wellpath Date: 3/18/2003 Validated: No Planned From To Survey ft ft 90.51 9690.51 Survey #1 (0) 9690.51 11243.23 Planned: Plan #4 V1 Casing Points MD TVD Diameter Hole Size Name ft ft in in 2668.51 2663.62 13.375 17.500 13 3/8" 9720.00 8795.73 9.625 12.250 95/8" 11243.23 9035.11 4.500 6.125 4 1/2" Summary <.;.----.,;.--~--:----Offset Wellpath .;....:--..;---..:....;------> Site Well Wellpath PB MPTR3 PB W Pad PB W Pad PB W Pad PB W Pad MP00151112 W-21 W-21 W-22 W-23 MP00151112 V1 W-21 V3 W-21A V12 W-22 V1 W-23 V3 Date: 3/19/2003 Time: 09:28:56 Page: Co-ordinate(NE) Reference: Vertical (fVD) Reference: Well: W-23. True North W-23A plan 81.1 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 3 Toolcode Tool Name GYD-GC-MS MWD+IFR+MS Gyrodata gyrocompassing m/s MWD + IFR + Multi Station Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft· ft 1" 10532.18 12300.00 1461.581206.47 271.98 Pass: Major Risk 11192.04 10200.00 213.01 133.62 94.78 Pass: Major Risk 11188.13 9650.00 657.57 123.26 580.75 Pass: Major Risk 11179.88 8750.00 1974.10 111.83 1881.79 Pass: Major Risk 9740.46 9750.00 0.85 162.85 -162.18 FAIL: Major Risk ~. W-23A Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Decompletion: · Tubing appears to be pitted and have a number of holes above the packer. Care must be taken while laying down/handling the corroded tubing. Tubing will be checked for NORM while laying down. · Well will have 8.4 ppg seawater as kill fluid circulated beforehand. Monitor fluid level continuously while recovering completion as the well will have open perforations exposed. Production Hole Section: · The production section will be drilled with a recommended mud weight of 8.6 ppg to ensure adequate overbalance in the 7.7 ppg EMW reservoir. · High differential pressure between hydrostatic and reservoir pressure created concerns for stuck pipe while drilling and running liner. Minimize time drill pipe and liner is spent motionless. · No faults are anticipated in the production hole. Directional hardline maintains a 200' separation from a fault to the Northern side of the well course. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. / CONSULT THE W-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies p055034 DATE ~l INVOICE I CREDIT MEMO DESCRIPTION 3/12/2003 INV# CK030603G THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. . TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHOAA<3E, AK995J 9-6612 PAY: TO TH E ORDER OF: ::C\ '".'::':: . B .:p F::.... ''/:'.'.<... ¡.llllild.I!I..........'.·.} / .... Iai,.. f '/1 f ;/...1"" .. . .............. . ...11..11..> '11I' 'rrfl.··"PII' :( GROSS PERMIT TO DRILL '.,Ù r~j?r NATIONAL CITY BANK Ashland, Ohio ... DATÈ( . .. ...... .. . .' ~" '. . . " . , .....,.., .', ." , :, ':,',': .:, "'::"', ":',,:::,:,:;' :';':.:'0: ::. "",' ",:, "', "':':"" ,:,:' ...... ................... .. ....... ........ .........:.:.'... .......... ....:".. ':'::.: '> : """'.' " ALASKA C?IL &G~S CQNSERVATldN CÔMMIS$ION· . 333 W 7TH AVENUE SUITE 100 ANCHORA<';¡::, AK 99501-3539 1110 5 5 0 :\ ~ III ! : 0 ~ ). 2 0 :\ a 9 5 I: o. 2 7 B 9 b lIa DATE ---CHECK NO:-- 3/12/2003 055034 / VENDOR DISCOUNT NET f{ECEi\IED APri 0 2 2lJ03 AI;¡ska em & G~ COH&. C ;mm:~::.\on ^,"d~'~~l·~;.c 56-389 412 No. P 0 5 5 0 3 4 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT ****:***$100.00******* .,".:' :'. .. ....:: . ,. ". .".;. NOTVALI~¡¡¡R-1~O ~ys,:..~~_.~"._.....:"L~., ." "~ < ... '.;~'~\~~:::~:::: ?::::::;~:~::: :is::;1~:i; :'", ~;~i7\~>~:::; ~~.:: ~~ :\.:;:, .:.1 , I.. ·tJ.~··.·· f...., .....\ ...... ...... ....... ..... .......,..........:: fÞli,·¡·~' ,i <".\'. ';'.' ::'.' :'.. .:\:' ...:.;,,/ ~ 1':' ~~s:;¡...,-,~.\ ~'. ':: (::~,:'.::.::~.:: :;:.~:~:.::>.... ··}~.·:~·:~;Ù1L\~~.:~·:~~~~):~}~;;:?:jl ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is . contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. r·f,.·~..>.; ':;"',.;~., "~.:¡.".'> '·,""r ~ ~ W~1.:.~;~~EJ~M1.:r~,ÇH.ECK~.I§þ'J COMPANY BPX FIELD & POOL 640150 - Prudhoe Bay, Prudhoe ADMINISTRATION APPR RPC DATE 4/3/2003 (For Service Well Only) (For Service Well Only) (For Service Well Only) ENGINEERING APPR WGA \NGA- DATE 4/3/2003 GEOLOGY (For Service Well Only) APPR RPC WELL NAME W-23A Initial ClasslType DEV /1-0IL 1. Perm it fee attached ................................................................................................... 2. Lease number appropriate...... ... ... ... ... ... ... ... ... ...... ... ... ... ... ... ... ... ... ...... ... .., ... ... ... ... ... ... 3. Unique well name and number ............... ............... ...... ............... ...... .......................... 4. Well located in a defined pool......... ...... ... ...... ...... ............ ...... ...... ...... ...... ......... ...... ... . 5. Well located proper distance from drilling unit boundary ................................................... 6. Well located proper distance from other wells ................................................................. 7. Sufficient acreage available in drilling unit..................... ... ... ... ... ... ... ... ... ... .., ... ... ... ...... '" . 8. If deviated, is well bore plat included ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .., ...... ... ... ... ... 9. Operator only affected party........................................................................................ 10. Operator has appropriate bond in force ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .., ... ... ... ... ... ... ... 11. Permit can be issued without conservation order...... ... ... ... ... ... ... ... ... ... ... ... ... .., ... ... ... ... .. 12. Permit can be issued without administrative approval... ...... ... ... ... ... ... ... ... ... ... ... ... ...... ... .. 13. Can permit be approved before 15-day wait...... ......... ...... ... '" ... ... ......... ...... ...... ... ... ...... 14. Well located within area and strata authorized by Injection Order # 15. All wells within 1/4 mile area of review identified... ... ... ... ... ... ... ... '" ... ...... ... ...... ... ... ... ... ... 16. Pre-produced injector: duration of pre-production less than 3 months... ... ... ... ... ... ...... ... ... .. 17. ACMP Finding of Consistency has been issued for this project...... ...... ...... ... '" ... ......... ..... 18. Conductor string provided...... ... .., ... ... ... ... .., ... ... ... '" ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .. 19. Surface casing protects all known USDWs ................................................................... 20. CMT vol adequate to circulate on conductor & surf csg ... ... ... ... ... ... ... .., ... ... ... ...... ... ....., ... 21. CMT vol adequate to tie-in long string to surf csg .......................................................... 22. CMT will cover all known productive horizons '" ... ... ... ... ... ... ... ... ... ... .., .,. .., ... ... ... ... ... ... ... 23. Casing designs adequate for C, T, B & permafrost... ...... ... ......... ............ ...... ...... ...... ... ... 24. Adequate tankage or reserve pit... ...... .., ... ... ... ... ,.. ...... ... ... ... .., ...... ... ...... ... ...... ... '" '" ... 25. If a re-drill, has a 10-403 for abandonment been approved......... ... ... ... ... ... ... ...... ... ... ... .... 26. Adequate well bore separation proposed...... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .., ... ... ... . 27. If diverter required, does it meet regulations...... ...... ... ... ... ...... ... ... ... ... ... ...... ... ...... ... '" .. 28. Drilling fluid program schematic & equip list adequate ... ...... ... ... ... ...... ... ... ... ... .., ... ... .., .... 29. BOPs, do they meet regulation.................................................................................. 30. BOPE press rating appropriate; test to ............ .......... 3500 psig ......minimum.......... 31. Choke manifold complies w/API RP-53 (May 84) .......................................................... 32. Work will occur without operation shutdown ... ... '" ... ... '.. ... ... ... ... ... ... ... ... ... ... ... ... ... ... ... .., 33. Is presence of H2S gas probable ...................................................... ............ .............. 34. Mechanical condition of wells within AOR verified... ... ... ... ... ... ... ...... .., ... ... ... ... ... ... ...... ... . 35. Permit can be issued w/o hydrogen sulfide measures............ ... ... ... ... .., ... ... ... ... ... ... ... ... .. 36. Data presented on potential overpressure zones... ......... ...... ... ... ......... ...... ...... ... ... ...... .. DATE 37. Seismic analysis of shallow gas zones... ... ...... ... ... ... ...... ... ... ... .., ... ...... ... ... ... ... ... ... ...... 38. Seabed condition survey (if off-shore) ....................................,.................................... 4/3/2003 39. Contact name/phone for weekly progress reports [exploratory only] ......... ............... ........ SFD: RPC: RPC WGA: X MJW: TEM: JDH: COMMISSION: RR: ~~~ DTS: O~J O!~(O:S SP: L( / Lf 0 3 GEOLOGY: ENGINEERING: RES. ENGINEERING: PROGRAM Exploratory (EXP) _ Development (DEV) ~ Redrill ~ Service (SER) _ Well bore seg _ Annular disposal para req GEOL AREA 890 UNIT No. 011650 ON/OFF SHORE On Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Not Applicable NA Slotted. Yes Yes Nabors 9ES. Yes 3/27/2003. Yes NA Not Applicable Yes Max MW 8.7 ppg. Yes Yes MSP 2707 psi. Yes Yes No NA Not Applicable Yes Yes NA Not Applicable NA Not Applicable NA Not Applicable ( Com ments/I nstructions