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204-220
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-211 PRUDHOE BAY UN ORIN V-211 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/22/2025 V-211 50-029-23232-00-00 204-220-0 W SPT 4266 2042200 1500 1430 1403 1437 1435 420 435 440 440 4YRTST P Brian Bixby 3/16/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN V-211 Inspection Date: Tubing OA Packer Depth 50 2206 2144 2115IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250317154024 BBL Pumped:1.4 BBL Returned:1.4 Tuesday, April 22, 2025 Page 1 of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y Anne Prysunka at 3:48 pm, Oct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f perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU V-211 Patch Mandrel Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-220 50-029-23232-00-00 26B ADL 0028240 6440 Conductor Surface Intermediate Production Liner 4788 79 3310 6399 6106 20" 9-5/8" 7" 4559 29 - 108 29 - 3340 26 - 6426 29 - 108 29 - 2701 26 - 4778 None 3090 5410 6106 5750 7240 5764 - 6126 4-1/2" 12.6# x 3-1/2" 9.2#L80 24 - 61284330 - 4572 Structural 4-1/2" Baker S3 Packer 3-1/2" Baker S3 Packers 5667, 4266 5816, 4365 / 5984, 4476 / 6059, 4527 Date: Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, SCHRADER BLUFF OIL, ORION POOL 11/10/2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 2100 By Samantha Carlisle at 1:00 pm, Oct 28, 2021 320-560 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.28 12:44:30 -08'00' Stan Golis (880) MGR28OCT2021 Orion Development Area CO 505B.004 SFD 10/28/2021 321-560 SFD 10/28/2021 10-404 DSR-10/28/21 dts 10/29/2021 JLC 10/29/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.29 10:43:25 -08'00' RBDMS HEW 11/1/2021 WFRV and Patch V-211 PTD:204-220 Well Name:V-211 API Number:50-029-23232-00 Current Status:Operable Injector Rig: Estimated Start Date:Q4 2021 Estimated Duration:2days Regulatory Contact:Abbie Barker First Call Engineer:Brodie Wages (713) 380-9836 (c) Second Call Engineer:Wyatt Rivard (509) 670-8001 (c) AFE Number:215-03146 Last Tag:3/21 install swell dummy MASP:2100 psi (Reservoir – 0.1 psi/ft) Min ID:2.813” 3-1/2” HES X Nip @ 6796’ MD Max Angle: 64 Deg @ 6000’ Brief Well Summary and Objective: After installing the swell dummy valve in Station #2, an attempt at a pressure test of the dummy failed, we now need to patch across the mandrel so we can resume injection into the well to support V-203 and V-202 producers Pre-Rig Work: 1.Slickline Pull/run WFRVs 2.Eline Set Patch Steps by Service Line: S/F Pull and reset WFRVs per targets below: St#Zone WFM Depth Current Target Proposed Target Rate 5 OA 5738 0 260 4 OA 5767 0 0 3 Oba 5842 0 450 2 Obb 5934 Swell DMY Swell DMY 1 Obc 6010 0 Gutted WFRV X-nip in tail Obd 6106 0 RMX set to receive WFRV E Set patch over Mandrel #2 @ 5934' x Use NS 350-272 or similar straddle x ID is 1.815” x We need to be able to pull and set the prong we set in the RMX x Prong is 1.75" OD and will be turned down to 1.375" so the pulling tool can be run through the patch x Would like gutted WFRV S Install gutted WFRV prong in RMX x this can be done prior to setting patch Discuss with OE as necessary -00 WFRV and Patch V-211 PTD:204-220 Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic WFRV and Patch V-211 PTD:204-220 Current Wellbore Schematic WFRV and Patch V-211 PTD:204-220 Proposed Wellbore Diagram Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: October 28, 2021Subject: Changes to Approved Sundry Procedure for Well V-211Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date MEMORANDUM State of Alaska Permit Number: 204-220-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg fir% /} - i DATE: Friday, March 19, 2021 P.I. Supervisor I�FfYn' 1 'I�4z SUBJECT: Mechanical Integrity Tests l Hilcorp North Slope, LLC Well V-211 FROM: Jeff Jones PRUDHOE BAY UN ORIN V-211 Petroleum Inspector bub Tubing 351 Src: Inspector 348 ' Reviewed By: PX Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-211 API Well Number 50-029-23232-00.00 Inspector Name: Jeff Jones Permit Number: 204-220-0 Inspection Date: 3/14/2021 Insp Num: mitJJ210316150615 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i V-211 Type Inj w TVD bub Tubing 351 354 348 ' 345 2042200 Type Test SPT Test psi 150o IA 86 1819 1757 1753umped: 1.3 - r BBL Returned: 1.3 OA 520 533 - 535 536l 4YRTST • P/F P Vi Notes: 1 well inspected, no exceptions noted. ' Friday, March 19, 2021 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,April 10,2017 TO: Jim Regg \1— 0P.I.Supervisor ' SUBJECT: Mechanical Integrity Tests X' BP EXPLORATION(ALASKA)INC. V-211 FROM: Guy Cook PRUDHOE BAY UN ORIN V-211 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry M NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-211 API Well Number 50-029-23232-00-00 Inspector Name: Guy Cook Permit Number: 204-220-0 Inspection Date: 3/28/2017 Insp Num: mitGDC170328155046 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-21 I Type Inj W TVD i 4266 Tubing 1578 1583 1579 t 1580 0.5 BBD - 2042200 Type Test SPT Test psi' 1500 IA 12 2200 2165 2162 s/ Pumped: 1.5 [BBL Returned: OA 384 400 400 399 Interval 4YRTST IP/F P 1 Notes: All went well with no issues. Lou Grimaldi was on site with me. SCANNED AUG 1 5 2017, Monday,April 10,2017 Page 1 of 1 • • 2`� 20 WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. RECEIVED STS/LOGGED 10, K.BENDER MA'r' 2 3 rf`i,:,.. To: AOGCC _► )C . - Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2—1 900 Benson Blvd. Anchorage, AK 99508 ) gancpdc aabp.com and ProActive Diagnostic Services, Inc. Attn: Diane F. Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile 01-May-16 V-211 BL/CD 50-029-23232-00 2) (*)/)/0/2-a426c.,(17) 6,eet Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM N REPORT OF SUNDRY WELL OPERA S 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other MBE Treatment 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number:" 204-220 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: ' 50-029-23232-00-00 7. Property Designation(Lease Number): ADL 0028240 " 8. Well Name and Number: . ORIN V-211 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,SCHRADER BLUF OIL 11.Present Well Condition Summary: RECEIVED Total Depth:P measured . 6440 feet Plugs measured feet true vertical . 4788 feet Junk measured feet SEP 1 1 2 015 Effective Depth: measured 6106 feet Packer measured See Attachment feet true vertical 4559 feet Packer true vertical See Attachment feet A(D( .C C Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"166.4#X-56 32-112 32-112 0 0 Surface 3310 9-5/8"40#L-80 32-3342 32-2702 5750 3090 Intermediate Production 6399 7"26#L-80 30-6429 30-4781 7240 5410 Liner Perforation Depth: Measured depth: 5764-5814 feet 5862-5904 feet 5920-5942 feet 6000-6020 feet 6076-6126 feet True vertical depth: 4330-4363 feet 4395-4423 feet 4434-4448 feet 4487-4501 feet 4538-4572 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 5764-5814 (�reatment descriptions including volumes used and final pressure: `��� iJ DEC 4 ��L. • 35 Bbls 50/50 Methanol,452 Bbls 3%KCL,2640 Lbs Crystal Seal,700 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1048 150 1023 Subsequent to operation: Shut In 40 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-326 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature //Cone-- C, +f Phone +1 907 564 4424 Date 9/11/15 Form 10-404 Revised 5/2015 1771._ (7/715115-- 1 S ial`ii ‘9 . ;.------ RBDMS S�p mit Original Only • • Packers and SSV's Attachment ORIN V-211 SW Name Type MD TVD Depscription V-211 TBG PACKER 5667 4265.66 4-1/2" Baker Premier Packer V-211 TBG PACKER 5816 4364.56 3-1/2" Baker Premier Ret. Pkr V-211 TBG PACKER 5819.42 4366.83 3-1/2" Baker Premier Ret. Pkr V-211 TBG PACKER 5984 4476.43 3-1/2" Baker Premier Ret. Pkr V-211 TBG PACKER 5986.92 4478.39 3-1/2" Baker Premier Ret. Pkr V-211 TBG PACKER 6059 4526.8 3-1/2" Baker Premier Ret. Pkr V-211 TBG PACKER 6062.68 4529.28 3-1/2" Baker Premier Ret. Pkr • • yo Q. 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D=3,813" 1MEix Angie= 49°@ 2158' I N Datum MD= 5991' ;Datum DID= 4400'SS GAS LFT MANDRELS 19-5/8"CSG,40#,L-80,ID=8.835' 1-1 3340' ST I MD TVO DEV 1 TY PE r V LV LA TC}-111 PORT I DATE I t 6 5537 4180 48 !KBG2 DMY i BK I 0 103/02/051 7'MARKER JOINT w/RA TAG H 5188'—1/1 r— = 813 564T i H,4-1/2"HES X NP,113 3. ' ;Minimum ID =2.813" c 5796' , 1 I 13-1/2" HES X NIPPLE i z x_ 5667' —7"X 4-1/2'BKR PREMER PKR, ID=3.875' 7'MARKER JOINT w/RA TAG .1--- 5703' Ht 5727' H4-1/2"X 3-1/2 X0,10=2.990" 1 14-1/2"TBG,12.6#,L-80, 0152 bpf,ED "3.958" -- 5727' ------\ / STI IAD TVD DEV TYPE ' VLV LATCH' PORT! DATE I 5 5738 4313 48 144.1G-W DMY I RC 0 108/21/15 IIID 0 4 5767 4332 48 11.044G-W P15XJR' RTC 13 08/21/15 3 5842 4382 48 WAG-W PI5XJR, RK I 18 01/12/151 Mr 2 5934 4443 48 IANG-W 'DAY I RK 0 06/26/141 1 6010 4494 48 WA3-W DMY 1 RK 0 10/13/13 3-1/2"RP JOINT w/RA TAG ft 5778' t *STATION#2=CMY liAS EXTENDED PACKING 1 ,__ I I 1 1 5796' —3-1/2"HES X NP,ED=2.813" 1 X IX 5816' —I r X 3-1/2'BKR PREMIER R<R ID=2.875' IIN MEI I I 5963' H3-1/2"HES X NP,ID=2.813" I PEFFORATION SUMMARY I Zt:=11Z---- 5984' —7'X 3-1/2"BKR PREMER PKR,I)=2.875" REF LOG:LISIT ON 11/19/04 ANGLE AT TOP PERE: 48°@ 5764' [I Note:Refer Io Production DB for historical perf data6039' —3-1/2"HES X NIP,ID=2.813" SIZE SW ZONE INTERVAL Opn/Sqz SHOT 1 SQZ I I 4-1/2" 5 OA 5764-5814 0 11/18/04 I , 4-1/2' 5 OBa 5862-5904 0 11/18/04 X - 1 6069' —17'X 3-112'BKR PREMER PKR I)=2.875" 4-1/2" 5 OM 5920-5942 0 11/18/04 i 4-1/2' 5 08c 6000-6020 0 11/18/04 4-1/2" 5 OM 6076-6126 0 11/18/041 I I 6086' H3-1/2"HES X NP,ID=2.813' 6106" H3-1/2"I-ES X NP D=2.813' I 11E11 --------"----4 6106' —P-15XJR WF REGULATOR w/x-LOCK &P-FRONG (06/26/14) ! .3-1/2"TBG,9.2/9.3#,L-80, .0087 bpf,ID=2.992" — 6128' 1 , ‘ — I 6128 H3-1/2"WLEG,ID=2.99T 1PBTD — 634Cr .,...,,,,,,,,.,., 6136' 1—ELMO LOGGED ON 06/25/05 1 OW.V.W1 *./....... 4......... 7"CSG,#26,L-80,ID=6.276" — 6426' DATE REV BY CX3MNENTS DATE 1 REV BY COPANENTS ORION UNIT 11/20/04 N9ES INITIAL COMPLETION 102/11/151 PJC 'GLV CORRECTIONS(01/12/15) WL: V-211 10/22/13 TI-111 PJC WR C/0(10/13/13) I 07/29/151MJCIJK)SET PX PLUG(07/06/15) I Flaw nb:' 042200 10/22113 LER PJC MRC/O(10/17/13) 07/29/15 MJQ GLV C/O(07/07/15) AR No. 50-029-23232-00 11/25/13 PJC VVRF CORRECTIONS 09/11/15 S1M/JMIRLL PX PLUG/GLV 010(08/21/15) SEC 11,T11N,R11E,471'FM &1891FE_ 06/30/14 TBID/JFAD WFR 010(06/26/14) 01/20/15 BSE/JMD WFR C/O(01/12/15) - BP Ecploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, July 13, 2015 11:00 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; AK, OPS Well Pad LV; Swensen, Brenden; '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; Pettus, Whitney; Regg, James B (DOA) Subject: UPDATED July 13, 2015: OPERABLE:Injector V-211 (PTD# 2042200) Valves Left out of Pocket Below Packer Attachments: image001.png All, Injector V-211 (PTD# 2042200) had two water flood regulators removed below the packer in preparation for upcoming well work.The gas lift valve above the packer providing two competent barriers to formation remained untouched. Therefore the well has been returned to Operable status. My apologies for any confusion. Please call with any questions or concerns. Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator G1.n1 WOOD JUL 1 5 2015 WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D&C Integrity Coordinator Sent: Sunday, July 12, 2915 8:07 PM To: AK, OPS GC2 OSM; AK,ORS 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 GP st Wells Opt Engr; AK, OPS Well Pad LV; Swensen, Brenden; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D& D Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: NOT OPERABLE: Injector V-211 (PTD# 2042200)TxIA Comm due to Valves Left out of Pocket All, Injector V-211 (PTD#2042200) had a gas lift valve removed in preparation for upcoming well work causing the well to lack two competent barriers downhole. The well is reclassified as Not Operable until tubing integrity can be restored. Please call with any questions or concerns. 1 (7, OF T4. � j ,7THE STATE Alaska ail and Gas ��M of h TAsKA Conservation Commission 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 (3F,9LAg14).- Fax 907.276 7542 www.aogcc.alaska.gov 1y Brenden Swensen �C�N@1��Well Interventions Engineer a 6 d BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, ORIN V-211 Sundry Number: 315-326 Dear Mr. Swensen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by4:30 PM on the 23rd dayfollowingthe date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster ,, ce Chair DATED this � day of June, 2015 End. 'RECEIVED • • STATE OF ALASKA AY 2 7 Z015 ALASKA OIL AND GAS CONSERVATION COMMISSIONG( J/� APPLICATION FOR SUNDRY APPROVALS A,OGCC 20 AAC 25.280 1 Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:_MBE Treatment n • 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 204-220-0 ' 3.Address: Stratigraphic ❑ Service Q 6.API Number P O.Box 196612,Anchorage,AK 99519-6612 50-029-23232-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ORI N V-211 - Will planned perforations require a spacing exception? Yes ❑ No -11 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL0028240 • PRUDHOE BAY, SCHRADER BLUF OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured). 6440 • 4788 • 6109 4561 6109 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"166.4#X-56 32-112 32-112 Surface 3310 9-5/8"40#L-80 31.89-3342 31.89-2701 98 5750 3090 Intermediate None None None None None None Production 6399 7"26#L-80 29.64-6429.07 29.64-4780.62 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size. Tubing Grade. Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft)• See Attachment for Packer Depths 4-1/2"X Nipple 3063 41',2509.74' 12.Attachments: Descnption Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphic n Development n Service n 14.Estimated Date for 15 Well Status after proposed work. Commencing Operations: cQI I SI LOIS OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date GAS ❑ WAG 0 ' GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brenden Swensen Email Brenden Swensen.@BP.Com Printed Name Brenden Swensen Title Well Intervetions Engineer Signatur_ / Phone 564-4887 Date 5/27/2015 Prepared by Nita Summerhays 564-4035 // 41110..' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: SSS-311ti Plug Integrity ❑ BOP Test ❑ Mechanical Integnty Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No g Subsequent Form Required. !e- .4 ,0 4 (§e ,/ APPROVED BY Approved by' P 7 COMMISSIONER THE COMMISSION Date. 6 S —1(- Op n � RBDMS \ JUN 1 1 2015 .$.) T- 2i.‹./5-Form 10-403 Revised 5/2015 I` d a' r s valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate VTL L/5/f5 Sl2BX4.1,- Perforation Attachment ADL0028240 Well Date Perf Code MD Top MD Base TVD Top TVD Base V-211 12/2/12 STO 5764 5814 4330 4363 V-211 12/2/12 STO 5862 5904 4395 4423 V-211 12/2/12 STO 5920 5942 4434 4448 V-211 12/2/12 STO 6000 6020 4487 4501 V-211 3/2/05 STO 6076 6126 4538 4572 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF -0 co co O O (600 CO CO CO 0 J J J J N Q O O OCO NV O &Z...)) O O — o LC) CO N- 0 O O O O '- In CO ( (N N- • N- LO 00 4) N 6) CO Ca CO O O f� N- N CO LC) N .4 H Q O O ~ O N N- O N O CO CO N CO CO L � C1 E t N E (N wO N co asN 'Cr CO CO 3 N Cr CO N- U) 0OCOMLr) c0 O E •— a 0 O N N- M N U a co M N CO 2 O O CO CO CO In CO J J X N J CO 4# *# N O (Ni N CT) (0a) co (V CV i O M N O co V O Cn 0 r O O O M M N CO a) CO CO II) Z 0) O 0 w a3 D Q OOD U p LLZ z O m m Z CCD > > O CL U H H U Packers and SSV's Attachment ADL0028240 Well Facility Type MD Top Description TVD Top V-211 SSSV 3063 4-1/2" X Nipple 2510 V-211 PACKER 5667 4-1/2" Baker Premier Packer 4266 V-211 PACKER 5816 3-1/2" Baker Premier Ret. Pkr 4365 V-211 PACKER 5819 3-1/2" Baker Premier Ret. Pkr 4367 V-211 PACKER 5984 3-1/2" Baker Premier Ret. Pkr 4476 V-211 PACKER 5987 3-1/2" Baker Premier Ret. Pkr 4478 V-211 PACKER 6059 3-1/2" Baker Premier Ret. Pkr 4527 V-211 PACKER 6063 3-1/2" Baker Premier Ret. Pkr 4529 bp V To: AOGCC Date: May 20, 2015 From: Brenden Swensen, Orion PE 907-564-4887 Subject: V-211 MBE Treatment Step Unit Operation 1 _ S Set plug, open stations 4 and 5 2 FB Pre-treatment injectivity test 3 FB Bullhead polymer 4 FB Post treatment injectivity test 5 S Set new WFRV design, pull plug HISTORY V-211 is a Schrader Bluff WAG injector configured to inject into multiple zones through water flood regulator valves (WFRV's). The well was swapped from water to MI in mid-October of 2014. While on MI it was determined that the well has a matrix bypass event (MBE) to V-203 based on an instant MI response. V-211 does not have down hole gauges, so an injectivity test was performed on each zone. The zone with the highest injectivity was the OA, taking 3 barrels per minute at 800psi WHP using diesel. The zone was dummied and the MI response subsequently dissipated in V-203, also confirming the OA in V-211 was the culprit for the immediate gas breakthrough. OBJECTIVE The objective of this job is to remediate the MBE from V-211 to V-203 by pumping water swelling granular cross linked synthetic polymer gel into the matrix breakthrough. CRITICAL ISSUES • Shut in offset producers and injectors to allow reservoir conditions to stabilize • High pre-treatment injectivity to minimize transit time of polymer through tubing to formation • Ensure cleanliness of pump equipment and hard line (pre and post job) • Properly dispose of remnant fluid per guidance from the Environmental Team PROCEDURE 1. Set plug at 5796' to isolate the OBa, OBb/OBc, and OBd sands. 2. Pull live valves and dummies from stations 4 and 5 to open the OA sand. 3. Perform pre-treatment injectivity test. 4. Shut in offset producers and injectors prior to pumping treatment. 5. Bullhead polymer from surface down tubing into OA sand. 6. Perform post-treatment injectivity test. 7. Set dummies and new water flood regulator valve design in stations 4 and 5. 8. Pull plug at 5796'. 9. Return well to injection ATTACHMENTS A. V-211 Well Bore Schematic Attachment A: V-211 Wellbore Schematic 114,1_= 4-1116 OW VMELLTEAD it R V1"•2SAFETY NOTES: READINGS ACTUATOR= BAKER WHEN OMIWELL REQUIRES A SSSV WHEN ON Mt. HITIAL KB ELEV 80.91 13F.B.EV= 52.4' I KOP- 20Q' 20' —1 O0 -- iOR-1--• -409-:'-'''''---H'----1 306 /2"0' 4-1HES X NP,D=3.81r MsixAngle= 49°'_,2158' _12 1 Datum 1/D= 5991' Datum TVD= 4400'SS GAS LFT MANDRELS 9-518"CSG,400,L-80,13=8.835' 3340' jAt ST MD I IV) DEV TYPE V LV LATCH PORT DATE 8 5537 4180 48 K8G2-DMY OK - 0 03/02/05 7'MARKER JOINT w/RA TAG — 5188' I it 4T 56J-41/2"H 'VP X ,D13.813- I Minimum ID=2.813"@ 5796' I r' 3-1/2" HES X NIPPLE g �S.____1 566T HBNBPQZD 7'X4-1/2"BKRPR � =3.875" I 1 7"MARKER J0IT w IRA TAG H 5703' Hit 727- H4-12'8 3-112 X0,D=2 990"i •4-'/7" 111(4,1264,L-80, 0152 bpf,D=3958"_ -1 5727' _...I \ / ST WD IVO DE)/ TYPE VW 'LATCH PORI !]ATE 5 5738 4313 48 MM-W DAY RK 0 03/02/05 DI4 5/6T 4332 48 FL(-W DM/ Fa( 0 01/13/15 a 3 5842 4382 48 MI/3-W P15Xki RK 18 01/13/15 MI 2 5934 4443 48 MMG-W 'DAM RIC 0 06/26/14 1 6010 4494 48 MMC W £441 RK 0 10/13713 3-12"RJR JONI-w/RA TAG H 5778' I • * 'STATION#2=rHi'HAS EXTENDED PACYJNG I 3-1/2"EES X NIP,CI=2.813" Ram X v f 5818' H 7•x 3-1/2"BKR P2 PKR,D=2-875- 0 0 I I s 5963' H3-1rr HES X NP,D=2-813" PERFORATION SUMMARY I 5984' )--17"x 3-112'BKR PRBNC2 PKtt IBJ-2_315" I REF LOG:U51T ON 11/19/04 _ ANGLE AT TOP PERE: 48°IP 5764' Note.Refer to Production DB for historical pert data 'f—_60.39.11—t8:5:1185 X NP,D=2.813' SIZE SPF'ZONE INTERVAL Opn1Sgz SHOT SQZ I I _—_ I 4-1/2' 5 OA 5764 5814 0 11/18/04 4-1/7 5 013a 5862-5904 0 11118/04 Z ><- 1,_ MT j__�7'X 3-1/2"BKR PRE MER PKR,D=2.875" I 4-1/2" 5 OBb 5920-5942 0 11118/04 4-1/2" 5 OBc 6000-6020 0 11/18/04 4-117' 6 ORA Fm78-R1?R n 1 i r1l1I(H, I I • 6086' ]—3-12'HES X NP,ID=2.813" • IBI I 6106' —3-1/2-HES x 'F,C=2.813" LJ 8106' ,I—P-15XJR WF RFGUI ATOR w/x-LOCK • TB 3-1/2' G,9.219.34,L-80,.0087 bpf,D=2.992' H 6128' I-----' &P-PRONG (08/28(14) 1 8128" —3-12"WLEG,D.2.992'I I • gm - 63,40• J - t 8135' H Fl MD 1 CX-43F0 ON 36/75105 /'CSG,*26,L-80,D=8.276" H 6426' 44.41:4X*.!..X*a*4 DATE ' REV BY C0tJ 'TSDATE REV BY COMWJTS ! ORION UNIT 11/20104: N9E6 (INITIAL COMPLETION 1 WH..I.-V-711 10/22/13 I 11-11 PJC'WER GO(10/13/13) FERMI No:'2042200 10122/13 LEE PJC;WEIR GO 110/17/13) AFI No 50-029-23232-00 11/25/13 i PJC .WRE CORFECT10N3 SEC 11,T11N,R11E 471'Mt_8 1891'FE_ 0630/14 TE3LYJMD1WFR GO(06/26/14) 01120/15 BSE/JM)WFRG0(01/13/15) BP Exploration(Alaska) · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 y.. - ~ ~ 0 Well History File Identifier Organizing (done) o Two-sided II 111111111" 11/11/ o Rescan Needed 111111111111111111I RESCAN ¡color Items: o Greyscale Items: DIGITAL DATA ~skettes, No. I o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date: IJ.../ ~/ oft; I J 151 vup 1111111111111111111 Project Proofing Scanning Preparation BY: ~ BY: Date: Production Scanning Stage 1 Page Count from Scanned File: 7 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ((Maria) Date: J ~/c1D/ob Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO 151 V11 F NO BY: Maria Date: 151 1/11111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1/11111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked /1111111/11/111/11/ 10/6/2005 Well History File Cover Page.doc ~chl~t~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN; Beth Well Job # LOq uCSCfl~tlnn NO. 5447 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 r 1 • i`( _-~ ~. ~~~~~ ..o,o v~~ ~~C~ ~~'~-~ Alaska Data & Consulting Services 900 E. Benson Blvd.~y{~ 2525 Gambell Street, Sude 400 ~~'" ~'~~ ~~~ ~ ~~~~ Anchorage, AK 99503-2838 . BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage,Alaska 99519-6612 August 14, 2009 a~~~'~t~ ~~ ~ `~` ' `~ ~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, • bp ~~~~~~~~ OCT 0 ~ 2~09 d~adca Oil8~ Gas Cons. ~amm~~~ian Anchorap~ ~ac~-~,a.0 ~-~~I Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, -~" Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) i Date V-pad 8/13/2009 Well Name P7D # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA t7 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 v-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 IVA 20.4 5/9l2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-t03 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 v-t07 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 IVA 1.5 NA 15.3 5J10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-1t9 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-2o~ 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-21t 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 12 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-2i4 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 "~ '~^ 2080200 50029233830000 NA 1.75 NA ~ 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 • MEMORANDUM To: Jim Regg ] / P.I. Supervisor ~~~ ~ Q 6r6( ZOC~~( FROM: Bob Noble Petroleum Inspector State of Alaska E~Iaclta Oil and (:as Conservation ('ommission Dr11'F.: Wednesday, April 15, 2009 SUB.IE('T: Mechanical Integrity Tesis [3P F.`~YLOR.4TION (ALASTtA) IN<.'. V ill YI2UDHOP; I3r\Y UN GRIN V ~l 1 Sre: Inspector NON-CONFIDENTIAL Keviewed Bti: P.I. Suprc Comm Well Name: PRUDHOE BAY' UN ORIN v-211 API Well Number: 50-029-23232-00-00 Inspector Name: $Oh Nobie Insp Num: mitRCN090413055726 Permit Number: 2oa-22o-0 ~ Inspection Date: 4110'2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - _ Well '11 ype In,~ ~' - -- I TVD ~ _ aa66 ~ _ _- Iq _ -- IG(i I anz~~ ~ _.-_ 4sa _. -- sma P T. 2t1422(K1 _ SPT eTest ~ TYP L_._ Test gt _ _ . ~'' _l . q(1~(~ r --_ - -- OA L. -- 39(1 ;Stl i9t~ -~ -- 3~~ - --- r_a,....,.,1 4YRTST D/F P Tubin g 9~xI ~+xl 9a~ ~ ~x>n _._.._ -.----.. -_-- I Notes: Vl-'ednesday, April 15, 2009 Page 1 of 1 03/18/09 a~~~b~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i ~fj~ jf~ n ~ _. N0.5133 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wall _L.h ft ,may J~ ~~ ~l `}_, ~~ f ~ ~,,^'~- 'c'am .- J-27A AY3J-00010 CBL - -_ -__-"( _-- 02/21/09 v 1V~ 1 S-107 AWJB-26 MEM L L U ~ 'a- 02/25/09 1 1 09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE ' 02/23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE _ ~ ~' 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) . ~ ( 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / C/ 03/02/09 1 1 B-25 AVY5-00023 USIT - /'~ /~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG `6- ~~S [ 03/11/09 1 1 F-18 AVY5-00022 USIT [ "%% _ ~'~- 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL l 03/06!09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-211 AY3J-00014 IPROF/RST WFL - ~ 03/16/09 1 1 V-214 AY3J-00013 IPROF/RST WFL - 03/15/09 1 1 K-06B AWJI-00017 MCNL ~ - 01/28/09 1 1 L5-15 12113027 RST - /O ~ ~ - - 12/09/08 1 1 07-18 12071915 RST 9 Q 12!01/08 1 1 15-15C AWJI-00015 MCNL ~ [ 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT ~ 12/07/08 2 1 R-41 40018496 OH MWD/LWD EDIT ~/~ [ 01/04/09 2 1 H-18 11999064 RST / - I p .12/03/08 1 1 _ ~ m owc.~ wnvu~.~n " _-..-- ..-.-..-..---....- ..-...-.. . ... .............. r...v .." vn..maa v.vc vvr ~ GgVfl I V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd, Anchorage, Alaska 99508 Date Delivered: ~, ~ ~ ~~ r2GfLued 3~a1 CY7 3 ~/~- ~~ ~ Cvp~ o"j - Alaska Data & Consulting Services 2525 Gambell Street te~QQO .-, Anchorage, AK ~+NF$i38 ,. ATTN: Beth `"" Received by: kq p~ D `~ r ~ i .:. j , , • • • .~" ~. • MICROFILMED 03!0112008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~L.aserFic~\CvrPgs_Inserts\Miicrofilm Ntarker.doc 01/18/08 3chlumb~r~er NO. 4560 Alaska Data & Consulting Services k ~ ~~~~~ Company: State of Alaska 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 r~~~~~,+ k ~~~*' ~~~ t" Alaska Oil 8. Gas Cons Comm Attn: Christine Mahnken ATTN: Beth ~L ~i 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Pt. Mac, Orion, Borealis Well Joh # Loa Desrrintinn Data RI Cnlnr CD L-219 11966240 MDT ~ ~ - I C 12/22107 1 L-114A 11970807 LDL 12/30/07 1 L-116 11962777 LDL (- ~ 12131/07 1 V-211 12021135 MEM INJECTION PROFILE ~ •- a(~ 12/29/07 1 V-216 12021136 MEM INJECTION PROFILE U 12/30/07 1 L-219 12017479 ISOLATION SCANNER CBL _ L, 01102/08 1 P2-16 11975750 INJECTION PROFILE 12/31/07 1 F-32 11970707 LDL - 01/04108 1 15-04B 12005202 MEM CEMENT BOND LOG - 12/28/07 1 G-31A 11962778 SCMT j - ~ 01/01/08 1 S-26 11978425 USIT 12/29107 1 02-16C 11628793 MCNL '~- ~ 08128/07 1 1 G-04B 11628765 MCNL - ~ ~ 04/06/07 1 1 K-02D 11209613 MCNL tb c, 07/21/06 1 1 17-07B 11649940 MCNL - ~ / 02/17/07 1 1 L2-28 11975742 RST = 12/05/07 1 1 Z-06 11968821 RST ~ - 12/13/07 1 1 YLtA,t AGYINVWLtUGt KtGtIYI I3Y 51GNING ANU Kt1UKNING UNt (:UNY tAGN IU: BP Exploration (Alaska) Inc. - Petrotechnical Data Center LR2-1 " ,?," ~ ~~ , ~ 900 E. Benson Blvd. ~ "" ~' ' ~, `~" ~ ~, ,. Anchorage, Alaska 99508 Date Delivered: ~~a~ ~ f ~, `~". J (~r~"i ~1~3;aiC ~ 1tll ,_ Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: • s ~~ 12/27106 Schlumberger NO. 4087 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Prudhoe Bay Well Job # Log Description Date BL Color CD Z-14B 11414770 SCMT 10/28106 1 ----" --.-- V-211 10919914 CH EDIT USIT PDC-GRI 11119104 1 1 V-221 10919949 CH EDIT USIT (PDC-GR) (Prints sent 311610Gl 03107105 1 ..- ---- L·200 11555032 LDL 12121106 1 -~_._~--_. -- --- -- .- . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Ine PetroteChnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 . ~IM:~ 0 ~þ Date Delivered Received by ~GANNED JAN () B 20D7 ,. ,....,#;: :'-~"I-~)'~";--"'/ ·'-F~_,.j~= U;E~ Q()¿I-ddOl · lLf3Ö0 12/11/06 Schlumberger NO. 4070 Schlumberger~DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Prudhoe Bay Well Job# Log Description Date BL Color CD . V-211 40011188 OH EDIT OF MWD/LWD 11117/04 2 1 S-213A 40011201 OH EDIT OF MWD/LWD 12/11/04 2 1 DS 09-13 11491394 MEM PROD PROFILE 11/24/06 2 14-30A 11485775 MEM PROD PROFILE 11/21/06 2 DS 09-36C 1149225 INJECTION PROFILE 11/23/06 2 W-12A 11418301 MEM PROD PROFILE 09/10/06 2 Y-29A 11485776 MEM PROD PROFILE 11/25/06 2 NK-43 11414407 PROD PROFILE W/DEFT 10/26/08 2 6-13A 11212899 USIT 11/05/06 1 14-30A 11485775 SCMT 11/22/06 1 DS 02-39L 1 11491395 SCMT 11/25/06 1 - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered DEC 1 3 Z006 . Received by: u::rQ., Qcfl- ddO ~14.Q~ PBU Orion V-211 . . Andy, No open hole logging data was submitted for PBU Orion V-211 API 50-029-23232-00. Please send over bluelines, reproduce-ables, and digital logging data for this well. TNX Howard 1 of 1 12/7/20062:07 PM ;;¿ ~ )J~ ~ DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2042200 Well Name/No. PRUDHOE BAY UN ORIN V-211 Operator BP EXPLORATION (ALASKA) INC API ~Ps~_¿ª~~~o~ro ~~ MD 6440 TVD 4788 Completion Date 11/20/2004 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes --_.._--~--" DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data Digital Typý Med/Frmt 'f?Ô-- D Asc 1ßrj( Electr Dataset Number Name Directional Survey Directional Survey See Notes Log Log Scale Media Run No Interval Start Stop o 6440 o 6440 4000 6315 OH/ CH Received 12/22/2004 12/22/2004 2/11/2005 Comments . u----l I ULTRASONIC IMAGING ! TOOL, PRIMARY DEPTH ! CONTROL____~J Log 5 Blu Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORM~ION Well Cored? Y t~ Chips Received? ~ Daily History Received? VN ~/N . Formation Tops Analysis Received? ~ -~-_..,------~- Comments: ·Ik / Date:--2~~Cø Compliance Reviewed By: lVlE1VlU KANlJ lJ M State of Alaska TO: Jim Regg J~ 1 P.I. Supervisor f'{?11 . 4'f 2,1/Ð5' Alaska Oil and Gas Conservation commi.¡ DATE: Wednesday, April 13, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-211 PRUDHOE BAY UN ORIN V-211 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Supr~ßt../" Comm Well Name: PRUDHOE BAY UN ORIN V-211 API Well Number: 50-029-23232-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS050409175655 Permit Number: 204-220-0 Inspection Date: 4/9/2005 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I V-2lI IType Inj. i P TVD i 4265 I IA I 0 i 1700 I 1660 1660 I I I P.T. I 2042200 iTypeTest I SPT Test psi ! 1066.25 lOA i 100 i 280 I 280 280 I I Tubing i 600 I 600 I 600 600 i i Interval INITAL PIF P I Notes: Pre-test pressures observed and found stable. NON-CONFIDENTIAL Wednesday, April 13, 2005 Page 1 ofl \-" Kt:l.,EIVI::D MAR 2 9 2005 _ STATE OF ALASKA . ALAS~L AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT ANrw.ã Oil & Gas Cons. Commîssion Revised: cAoalutr'lJlut on Injection t . No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 181 WAG 20AAC 25.105 20AAC 25.1 10 21. Logs Run: MWD I GR, MWD I GR I RES I DEN I NEU PWD, USIT CASING, LINER AND CEMENTING RECORD SETTING )EPTH MD :;jETTING UEPTH TVD HOLE TOP BOTTOM TOP BOTTOM Size Surface 108' Surface 108' Driven 29' 3340' 29' 2701' 12-1/4" 26' 6426' 26' 4778' 8-3/4" o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4809' NSL, 1891' WEL, SEC. 11, T11N, R11E, UM Top of Productive Horizon: 2241' NSL, 4080' WEL, SEC. 02, T11 N, R11 E, UM Total Depth: 2612' NSL, 4414' WEL, SEC. 02, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- ~041 0 . y- 5970054 Zone- ASP4 TPI: x- 588186 y- 5972740 Zone- ASP4 Total Depth: x- 587847 y- 5973107 Zone- ASP4 ------------------ -- -- --------- 18. Directional Survey 181 Yes 0 No 2. CASING SIZE Wr. PER Fr. 166.4# 40# 26# GRADE X-56 L-80 L-80 20" 9-5/8" 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5spf MD TVD MD TVD 5760'-5810' 4327'-4361' 5858' - 5900' 4392' - 4420' 5916' - 5938' 4431' - 4446' 5996' - 6016' 4484' - 4498' 6072' - 6122' 4536' - 4569' 26. Date First Production: March 21,2005 Date of Test Hours Tested - One Other 5. Date Comp., Susp., or Aband. 11/20/2004 6. Date Spudded 11/12/2004 7. Date T.D. Reached 11/16/2004 8. KB Elevation (ft): 80.9' 9. Plug Back Depth (MD+ TVD) 6340 + 4719 10. Total Depth (MD+TVD) 6440 + 4788 11. Depth where SSSV set (Nipple) 3060' MD 19. Water depth, if offshore NIA MSL 1b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 204-220 13. API Number 50- 029-23232-00-00 14. Well Name and Number: PBU V-211i 15. Field I Pool(s): Prudhoe Bay Field I Orion Schrader Bluff Ft Ft 16. Property Designation: ADL 028240 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD 260 sx Arctic Set (Approx.) 521 sx AS Lite, 379 sx Class 'G' 304 sx Class 'G' AMOUNT PULLED 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 5727' 5667' 3-1/2",9.2#, L-80 5727' - 6128' 5816',5984',6059' 25. ACID,FÀACTURE, CEMENrSoUEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect wI 88 Bbls Diesel ¡ \ Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE WATER-BBl GAs-McF WATER-BBl PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection PRODUCTION FOR Oll-BBl GAs-MCF TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Oll-BBl Press. 24-HoUR RATE CHOKE SIZE I GAS-Oil RATIO Oil GRAVITy-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None i t '" '~ø~~ t·· \;'>:l1'" ",.,., ~'...". I_~ "._..... ,> . . ",' iJ _ .. ~. , \ I- RBDMS 8Ft MAH 3 I 2005 Cr /Ir. 28. GEOLOGIC MARKE 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu Ugnu MA Ugnu MB1 Ugnu MB2 Ugnu MC Schrader Bluff NA 5524' 3614' 5192' 5250' 5346' 5431' None Schrader Bluff NB 5557' Schrader Bluff NC 5619' Schrader Bluff OA 5760' Schrader Bluff OBa 5858' Schrader Bluff OBb 5916' Schrader Bluff OBc 5998' Schrader Bluff OBd 6071' Schrader Bluff OBe 6158' Schrader Bluff OBf 6217' Base Schrader Bluff 6276' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble PBU V-211 i Well Number Title Technical Assistant Date 03J~ DS 204-220 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ocf-2.-¿3 03/15/05 Schlumbergep NO. 3363 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay C 'jj(.ì -/ 01- () ''1.;;) 1'7'0 ~~I·'Z. '/':J r J'1- (j A~ olor Well Job # LOQ Description Date Blueline Prints CD I C-39 10715421 MCNL 08/19/04 1 .~ E-21A 10670030 MCNL 08/22/04 1 00 C-29A , 10715422 MCNL 08/22/04 1 ,- it DS 07-33B 10715361 MCNL 11/04/03 1 1 "'j 07-01A 10889151 RST 08/18/04 1 1 tJ7 X-27 10724364 RST 03/10/04 1 1 E-18A 10621786 RST OS/22/04 1 1 "'I DS 01-24A 10563108 RST 10/09/03 1 1 ;..: E-10A 10621797 RST 06/16/04 1 1 02- Z-12 10704020 RST 07/06/04 1 1 "7 I X-15A 10704021 RST 07/07/04 1 1 1 P1-07A 10831301 RST 07/03/04 1 1 )rJ :G-03A 10889210 LDL 02/13/05 1 2:'; L5-17 A 10942195 PSP PPROF/DEFT/GHOST 02/28/05 1 ¿;Jj P1-05 10687701 PPROF PSP/DEFT/GHOST 08/13/04 1 ¿¥ MPC-42 10889141 RST 07/26/04 1 1 ß MPC-42 10621815 RST 08/07/04 1 1 , I I '!; ~ '13"( r(7-A 9(;- ·1' ..) ,-...r Cf7-/J N~c 17-c '1 )... i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: J/~ (05' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2~38 r ATTN: Beth / -~/II / Receiv~:::--.I{ f."U a/iA".A./l¿,..../ . }fJ1- 010 '5 ).04 - 2.?-,0 ~O!7 - ïl:l'i 9-D4" '3u . Schlumberger NO. 3335 Schlumberger-DCS 2525 Gambel! S~ Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Well Job# Log Description Date Color CD BL L-216 10687775 USIT (PDC 05/14/04 1 1 V·211 10919914 USIT 11/19104 1 L-210 10687666 US IT 01114/04 1 V-216 10687707 USIT 09109/04 1 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 AK 99508-4254 Date Delivered: 2/;~ c:?o '1'-- Z 2-0 02111/05 VV-- ... STATE OF ALASKA .. ALAS~IL AND GAS CONSERVATION COMlfSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 1m WAG 20AAC 25.105 20AAC 25.1 1 0 21. Logs Run: MWD I GR, MWD I GR / RES / DEN I NEU PWD, USIT CASING, LINER AND CEMENTING RECORD ::>ETTliIIG EPTHMDSE'I't'NGQEPTH TVD H6Œ .1 OP tsOTTOM Top I BOTTOM . Size: Surface 108' Surface 108' 29' 3340' 29' 2701' 26' 6426' 26' 4778' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4809' NSL, 1891' WEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 2241' NSL, 4080' WEL, SEC. 02, T11N, R11E, UM Total Depth: 2612' NSL, 4414' WEL, SEC. 02, T11N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 59041.Q~ y- 5970054 Zone- ASP4 TPI: x- 588186 y- 5972740 Zone- ASP4 ~--~ -~- Total Depth: x- 587847 y- 5973107 Zone- ASP4 18. Directional Survey 1m Yes 0 No 22. CASING SIZE WT. PER FT. 166.4# 40# 26# GRADE X-56 L-80 L-80 20" 9-5/8" 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5spf MD TVD MD TVD 5760' - 5810' 4327' - 4361' 5858' - 5900' 4392' - 4420' 5916' - 5938' 4431' - 4446' 5996' - 6016' 4484' - 4498' 6072' - 6122' 4536' - 4569' 26. Date First Production: Not on Injection Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ...... Press. 24-HoUR RATE""" One Other 5. Date Comp., Susp., or Aband. 11/20/2004 6. Date Spudded 11/12/2004 7. Date T.D. Reached 11/16/2004 8. KB Elevation (ft): 80.9' 9. Plug Back Depth (MD+ TVD) 6340 + 4719 10. Total Depth (MD+TVD) 6440 + 4788 11. Depth where SSSV set (Nipple) 3060' MD 19. Water depth, if offshore NIA MSL Driven 12-114" 8-314" REC;EIVED DEC 3 02004 Alaska Oil & Gas Cons. Commission 1b. Well Class: AntMrgge o Development 0 Exploratory o Stratigraphic 1m Service 12. Permit to Drill Number 204-220 13. API Number 50- 029-23232-00-00 14. Well Name and Number: PBU V-211i 15. Field I Pool(s): Prudhoe Bay Field I Orion Schrader Bluff Ft Ft 16. Property Designation: ADL 028240 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) vEMEN·,n"~ > 260 sx Arctic Set (Approx.) 521 sx AS Lite, 379 sx Class 'G' 304 sx Class 'G' AMOUNT PUllED 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-112", 12.6#, L-80 5727' 5667' 3-1/2",9.2#, L-80 5727' - 6128' 5816',5984',6059' 25. ACID, ;- CI::MI::N I , ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect wI 88 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oll-BBL GAs-McF WATER-BBl Oil -BBL 27. GAs-McF W A TER-BBl CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SubmiCcme çhips; ifnone, state "none". None j4d.~y ..,1... '~I·.,""'.' ..'... JVt:1'L -.t:,); ~-... ~.; ~~_,it Form 10-407 Revised 12/2003 ORIGINAL. CONTINUED ON REVERSE SIDE RBDMS BFl .IAN 0 A 2005 , ¡~ '!)r 28. GEOLOGIC MARKE 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu Ugnu MA Ugnu MB1 Ugnu MB2 Ugnu MC 3614' 5192' 5250' 5346' 5431' None Schrader Bluff NA 5524' R EIVED DEC 3 () 2004 Schrader Bluff NB 5557' Schrader Bluff NC 5619' t\lasìq¡ ~~~ Cornmì$$ on Schrader Bluff OA 5760' Äo!;horege Schrader Bluff OBa 5858' Schrader Bluff OBb 5916' Schrader Bluff OBc 5998' Schrader Bluff OBd 6071' Schrader Bluff OBe 6158' Schrader Bluff OBf 6217' Base Schrader Bluff 6276' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date l~~C?lo PBU V-211i Well Number 204-220 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 0:22:05 AM 1/22/2004 Printed: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-211 V-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11/11/2004 11/20/2004 Spud Date: 11/12/2004 End: 11/11/2004 09:00 - 15:00 6.00 MOB P PRE Move rig fN-210i to V-211i. (Accept rig at 15:00 hrs on 11/11/04) 15:00 - 00:00 9.00 RIGU P PRE Rig up in preparation to spud well. 11/12/2004 00:00 - 00:30 0.50 RIGU P PRE Service top drive. 00:30 - 04:30 4.00 RIGU P PRE PU 81 jts of drill pipe & stnd back. 04:30 - 06:00 1.50 RIGU P PRE PU 24 HWDP & stnd back same. 06:00 - 08:00 2.00 RIGU P PRE Clean floor / service rig prior to PU BHA. 08:00 - 10:30 2.50 RIGU P PRE MU BHA, jar stand (set back), NMDC's (set back). PU bit, motor, NMLDC, NMSTB, MWD, NMSTB, XO. 10:30 - 11 :00 0.50 RIGU P PRE Function test diverter (test witness waived by AAOGC). 11 :00 - 12:00 1.00 RIGU P PRE Pre-spud meeting flwell, fill riser/flow-line & check f/leaks - OK. 12:00 - 14:30 2.50 DRILL P SURF Spud well and drill f/108' tl448'. 14:30 - 15:30 1.00 DRILL P SURF POOH 3 stands HWDP, PU jar stand, RIH, wash down last stand, return to drilling. 15:30 - 00:00 8.50 DRILL P SURF Con't drilling f/448' tl1190', 600 gpm, 1610 psi on, 1560 psi off, 50 rpm, 5k tq on, 2.5k tq off, 88k up, 72k dn, 76k rt. AST = 7.4 hrs I ART = 1.15 hrs 11/13/2004 00:00 - 05:00 5.00 DRILL P SURF Con't drilling f/1190' tl1655', 82k up, 69k dn, 76k rt, 600 gpm, I 1880 psi off, 2080 psi on, 80 rpm, 38k wob, 6k tq on, 2.3k tq I off. 05:00 - 05:30 0.50 DRILL P SURF Circulate hole clean prior to bit trip (2 x BU at 650 gpm, 2100 psi, 100 rpm, 76k rt wt, 3k tq). 05:30 - 07:30 2.00 DRILL P SURF Monitor well & POOH, 90k up, 72k dn, hole good on trip out. 07:30 - 08:00 0.50 DRILL P SURF CO bit, clear & clean floor. 08:00 - 08:30 0.50 DRILL P SURF Service top drive. 08:30 - 09:30 1.00 DRILL P SURF TIH, hit obstruction at 980', work pipe (no go), wash & ream . one stand - OK, con't RIH to 1562' dry. 09:30 - 20:00 10.50 DRILL P SURF MU TDS, stage pumps to drilling rate, wash & ream last stand to bottom at 1655', resume drilling surface hole TD at 3354' TMD (per Geologist), 98k up, 73k dn, 85k rt, 600 gpm, 3000 psi on, 2765 psi off, 80 rpm, 7-8k tq on, 4.5k tq off, 35k wob, back ream after each stand. 20:00 - 21 :00 1.00 DRILL P SURF Circ 2.5 x BU (pumped Super Sweep on #2 BU) at 650 gpm, 3060 psi, 5k tq. 21 :00 - 00:00 3.00 DRILL P SURF Began short trip back to HWDP (@910'), POOH f/3354' 117k up, 76k dn, pulled clean I no obstructions. Encountered over pull at 1975', began to work pipe, began to pump at 1915', 300 gpm, 765 psi. Pull f/1840' to 910' no pump - OK. AST = 5.29 hrs I ART = 5.07 hrs 11/14/2004 00:00 - 01 :00 1.00 DRILL P SURF Con't TIH f/1000', hit obstruction at 1600', work pipe & con't RIH to 3260' taking some weight. 01 :00 - 02:00 1.00 DRILL P SURF MU TDS, stage pumps up to drilling rate and wash last stand to TD at 3354' TMD, CBU x 2 at 650 gpm, 3200 psi, 88k rt wt, 100 rpm, 5.8k tq, clean hole, 110k up, 74k dn, w/pumps. 02:00 - 05:00 3.00 DRILL P SURF Monitor well, POOH, 115k up, 75k dn, no pump, pull over 20k-25k at 2050', work pipe wIno success, pump out f/2030' tl1840', 320 gpm, 800 psi, wipe tight spots wIno pump - OK, con't to POOH to 1000' (top BHA). 05:00 - 08:00 3.00 DRILL P SURF Stand back HWDP, jars, collar stand. LD BHA, BO & grade bit. Clean & clear floor & send out jewelry. Printed: 11/22/2004 10:22: 12 AM ART = 6.67 hrs lAST = 2.33 hrs PROD1 CBU 2X, pump 20 bbls supper sweep, pump another BU, 580 gpm, 2735 psi, 110 rpm, 9k tq off, cal ECD 9.96 ppg, act ECD 10.22 ppg - hole considered "clean". PROD1 Monitor well - OK, pull over 25k at 6225' (made 3 attempts - no Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-211 V-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - 11/14/2004 08:00 - 10:00 2.00 CASE P SURF 10:00 - 15:00 5.00 CASE P SURF 15:00 - 15:30 15:30 - 18:30 0.50 CASE P 3.00 CEMT P SURF SURF 18:30 - 22:00 3.50 CEMT P SURF 22:00 - 23:00 1.00 CEMT P SURF 23:00 - 00:00 1.00 WHSUR P SURF 11/15/2004 00:00 - 02:00 2.00 DIVRTR P SURF 02:00 - 05:00 3.00 DIVRTR P SURF 05:00 - 06:00 1.00 WHSUR P SURF 06:00 - 08:30 2.50 BOPSU P SURF 08:30 - 09:00 0.50 BOPSU P SURF 09:00 - 13:00 4.00 BOPSU P SURF 13:00 - 13:30 0.50 BOPSU P SURF 13:30 - 15:30 2.00 DRILL P PROD1 15:30 - 18:00 2.50 DRILL P PROD1 18:00 - 19:30 1.50 DRILL P PROD1 19:30 - 20:30 1.00 DRILL P PROD1 20:30 - 21 :00 0.50 DRILL P PROD1 21 :00 - 22:30 1.50 DRILL P PROD1 122:30 - 00:00 1.50 DRILL P PROD1 11/16/2004 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 18:00 17.50 DRILL P PROD1 18:00 - 20:00 2.00 DRILL P 20:00 - 22:30 2.50 DRILL P Start: Rig Release: Rig Number: 11/11/2004 11/20/2004 Spud Date: 11/12/2004 End: Make dummy run w/landing joint, MU fill-up tool, change out bails, rig up casing equipment. PJSM for 9 5/8" casing job, Baker lock float equipment, fill pipe & check floats, RIH w/9 5/8" 40# L-80 BTC casing to 3340' TMD, fill each joint, MU torque to 6500 Ibs using Best-O-Life 2000 NM. MU landing joint, LD fill-up tool, MU cement head. Stage up pumps f/cement job, 332 gpm, 515 psi, no losses. Reciprocate pipe 150k up, 100k dn. PJSM wlall personnel flcement job, pump 5 bbl water, test lines to 3500 psi - OK, pump 75 bbls 10.2 ppg Mud Push, drop bottom plug, pump 409 bbls lead slurry (Arctic Set Lite - 10.7 ppg), pump 79 bbls tail slurry (15.8 ppg Premium G), drop top plug, pump 10 bbls water (all cementer fluids pumped @6 bpm), switch to rig pumps, pump 237 bbls 9.5 ppg mud to displace cement (227 bbls at 8 bpm - last 10 bbls at 2 bpm),reciprocated till 50% lead out of shoe, bump plug and pressure to 3500 psi (CIP at 21 :45 hrs 1162 bbls cement to surface), job went per plan. RD casing equipment, flush diverter system. ND diverter & surface hydrill. Clean-out under rotary table wlsuper sucker. ND diverter system & CO 20" nipple to 16". NU FMC Gen-5 Lower "Split" Unihead, test M/M seal to 1000 psi. NU 13 5/8" BOP & all surface related equipment. RU BOP testing equipment. Test BOP's to 250 psi low & 4000 psi high, annular preventor to 250 psi low & 3500 psi high, witness waived by Chuck Scheve--AOGCC. Pull test plug, install wear ring, blow dn choke, kill & TDS. PU 33 joints 4" DP and stand back in derrick. PJSM wlall personnel, PU/MU BHA #3, shallow hole test at 1007',554 gpm, 1650 psi - OK. Con't PU DP 1 x 1 (66 jts total). Fill pipe & lines, test casing to 4000 psi & hold f/30 min - OK. Service TDS. Wash dn f/3064', tag cmt at 3220',550 gpm, 1940 psi, drill float & shoe track, CO rathole, drill 20' new hole to 3374'. Displace well to 9.0 ppg LSND mud 450 gpm, 1050 psi. LOT to 13.55 ppg. Circulate mud I run base-line PWD value (Act PWD (9.55 ppg) - Cal ECD (9.33 ppg) = .22 ppg Differential). Con't drilling 8/4" hole f/3374' 116440', 153k up, 87k dn, 114k rt, 575 gpm, 2880 psi on, 2670 psi off, 80 rpm, 9.3k tq on, 8.7k tq off, 15k wob, cal ECD 9.96 ppg, act ECD 10.62 ppg, survey each stand, backream each stand at drlg rate. Printed: 11/22/2004 10:22:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-211 V-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11/11/2004 11/20/2004 Spud Date: 11/12/2004 End: 11116/2004 20:00 - 22:30 2.50 DRILL P PROD1 success), initiate back ream at 400 gpm, 100 rpm, 7.8k tq, 1660 psi, had to vary flow-rates as required based upon actual ECD observations w/back-reaming (up to 550 gpm's wllower ECD's I down to 400 w/higher ECD's (11.0 ppg+ ECD's observed w/back-reaming)), back-reamed to lower ghost reamer depth of 5679' where pipe began to pull w/o problems_ (NOTE: High ECD's w/back-reaming appeared to be associated with under-gauge hole due to clay swelling or filter cake build-up across the sands as opposed to an excessive cuttings load. Once wiped, ECD's relaxed and the pipe was pulled within normal over-pull ranges.) 22:30 - 00:00 1.50 DRILL P PROD1 Pumped a dry-job and con't to POOH f/6225' tl4600' (no problems). 11/17/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Con't short trip to shoe, pull tight at 3575', wk pipe wlo success, run 2 stds in to 3700', backream to shoe at 3340', stage pumps up to 550 gpm, 1800 psi, 80 rpm, 86k rt wt, 6k tq, cal ECD = 9.96 ppg, act ECD = 10.1 ppg. 01 :00 - 01 :30 0.50 DRILL P PROD1 CBU at shoe, 550 gpm, 1820 psi, 50 rpm, 84k rt wt, 5.5k tq, monitor wel1. 01 :30 - 02:30 1.00 DRILL P PROD1 Cut-n-slip 65' drilling line, check brakes - OK, clean & inspect underneath drawworks. 02:30 - 03:00 0.50 DRILL P PROD1 Service TDS. 03:00 - 04:30 1.50 DRILL P PROD1 Monitor well, 120k up, 70k dn, at 3340' (no pump), some gas hydrates flbelow shoe, begin trip back to bottom, hit obstruction at 3750', wk pipe no go, fill pipe & turn 180 degrees, wk thru 3750' ok, con't TIH to 6365', hole looked good. 04:30 - 06:30 2.00 DRILL P PROD1 MU TDS, fill pipe, stage pumps up to drily rate & wash to TD at 6440', CBU & clean hole at 580 gpm, 2720 psi, 110 rpm, 114 rt wt, pump 20 bbls SS sweep, con't to circ a total of BU x 3, initial ECD = 10.43 ppg, final ECD = 9.94 ppg. 06:30 - 10:30 4.00 DRILL P PROD1 Monitor well, pump dry job, POOH, 180k up, 88k dn, std back DP & HWDP, hole looked good on TOOH. 10:30 - 12:30 2.00 DRILL P PROD1 PJSM on MWD source, down-load source & LD BHA#3, clear & clean rig floor. 12:30 - 14:00 1.50 CASE P PROD1 Flush stack, pull wearring, set test plug, CO upper rams tiT', test seals tl4000 psi. 14:00 - 15:30 1.50 CASE P PROD1 Make dummy run w/landing joint, RU 350 ton equip. 15:30 - 20:00 4.50 CASE P PROD1 PJSM wlall personnel, RIH w/?" BTC-Mod L-80, 26# casing, dope w/BOL2000NM, MU tq to 9400 ftllbs, Baker loc fit equip, fill & check fit equip - OK, spot RA marker pups jts after jts 17 & 29, add floating cent. on jts 4-44, none on RA jts, fill each jt. 20:00 - 20:30 0.50 CASE P PROD1 Circ 1.5 x BU at the shoe (3340'), 253 gpm, 426 psi, 119k up, 85k dn. 20:30 - 00:00 3.50 CASE P PROD1 Con't RIH 40'/min, brk circ every 10 jts, circ f/1 0 min every 15 jts, PU/SO wts every 10 jts, ran 120 jts by 00:00 hrs. 11/18/2004 00:00 - 02:30 2.50 CASE P PROD1 Con't RIH wIT' 26# L-80 BTC-M csg f/5000', 1 min/jt, MU tq to 9400 ftllbs, using BOL2000NM pipe dope. 02:30 - 03:00 0.50 CEMT P PROD1 MU landing jt & land cst at 6426', RD fill-up tool, blow down TDS, RU cmt head & circ line. 03:00 - 04:30 1.50 CEMT P PROD1 Break circ at 3 bpm (365 psi) and staged to 7 bpm (575 psi), CBU x 3 wlreciprocating casing 15'-20' stroke, 210k up, 100k dn, PJSM flcement job. 04:30 - 06:30 2.00 CEMT P PROD1 CO tlDowell, pump 5 bbl water, test lines to 4000 psi, pump 20 Printed: 11/2212004 10:22:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-211 V-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11/11/2004 11 /20/2004 Spud Date: 11/12/2004 End: 11118/2004 04:30 - 06:30 2.00 CEMT P PROD1 bbls 8.34 ppg CW-100 + 35 bbls 10.0 ppg Mud Push, drop bottom plug, pump 65 bbls 15.8 ppg cmt, drop top plug, switch to rig pumps, displaced w/242.5 bbls seawater at 7 bpm, bumped plug to 4000 psi (leak at casing head XO), bled off pressure, floats held. 06:30 - 07:00 0.50 CEMT P PROD1 Blow down & RD circ lines, RD cement head, BO & LD landing joint. 07:00 - 07:30 0.50 CEMT P PROD1 Install 7 x 9 5/8" pack-off, tq gland packing nuts & LDS to 450 ftllbs, test pack-off to 5000 psi f/10 min. 07:30 - 08:00 0.50 CEMT P PROD1 Test csg to 4000 psi & chart f/30 min - OK. 08:00 - 10:00 2.00 CEMT P PROD1 Flush stack & drain, install test plug, CO top pipe rams to 3 1/2" x 6" & test door seals to 4000 psi. 10:00 - 11 :00 1.00 CEMT PROD1 RD & send out csg equip, CO long bails. 11 :00 - 12:00 1.00 PERFO OTHCMP PJSM wlall personnel, PU gun jewelry to rig floor. 12:00 - 13:30 1.50 PERFO OTHCMP MU 4.5" perf assembly per Schlumberger. 13:30 - 14:00 0.50 PERFO OTHCMP Shallow test MWD at 250 gpm, 335 psi. 14:00 - 17:00 3.00 I PERFO OTHCMP RIH on 4" DP (slow) to 6320', verify depth, con't RIH, tag up on FC at 6340. 17:00 - 19:30 2.50 i PERFO P OTHCMP Place guns at depth, correlate depth w/GR on MWD using OH 0.50 I PERFO~ P log dated 11/17/2004 & RA tag. 19:30 - 20:00 OTHCMP Displace well f/seawater to 9.0 ppg brine. 20:00 - 20:30 0.50! PERFO I P OTHCMP Initiate pump sequence to fire guns (guns fired at 20:32 hrs). Perforate following intervals wI 4.5" HSD, 5 SFP, 60 deg phasing guns. 5760-5810 I 5858-5900 I 5916-5938 I 5996-6016 6072-6122 Good surface indication and also recording of guns firing. 20:30 - 21 :30 1.00 PERFO OTHCMP Pull 4 stand (above top perf), monitor well & circ 1 BU at 300 gpm, 810 psi. (Hole taking @4 bph 9.0 ppg brine.) 21 :30 - 22:00 0.50 PERFO OTHCMP POOH - stand back 13 stands. 22:00 - 00:00 2.00 PERFO OTHCMP Con't POOH 1 x 1 & LD DP. 11/19/2004 00:00 - 02:00 2.00 PERFO OTHCMP Con't POOH wlperf guns f/3000', 83k up, LD HWDP, MWD & related jewelry. (NOTE: Brine loss 4 bph to perfs.) 02:00 - 06:00 4.00 PERFO P OTHCMP PJSM, RU LD tools, & LD 4.5" guns (all shots fired), clear & clean floor, send out tools & jewelry flgun run. 06:00 - 08:00 2.00 EVAL P OTHCMP PJSM, RU SWS E-line, RIH w/WL, guage rign 5.95 OD, & junk i basket. 1st RIH made it to 6240', material in JB on return. 08:00 - 10:00 2.00 EVAL P OTHCMP 2nd WL run wlsame assembly made it to 6330', material in JB. 10:00 - 12:00 2.00 EVAL P OTHCMP 3rd WL run w/6.05 guage ring made it to 6200' clean JB. 12:00 - 15:30 3.50 EV AL P OTHCMP PU & run USIT log, RIH to 6315' & log up, TOC @4105', RD SWS. 15:30 - 17:30 2.00 RUNCO RUNCMP Pull wearring, make dummy run, CO to long bails, RU tbg equipement. 17:30 - 20:30 3.00 RUNCO RUNCMP PJSM, RIH w/3 1/2" 9.2# L-80 TC-II tbg & jewelry as per running detail, 2300 ft Ibs tq, using Jet Lube Seal Gaurd pipe dope. 20:30 - 00:00 3.50 RUNCO RUNCMP Con't to RIH w/3 1/2" completion string to the 4 1/2" XO, CO running tools, Con't RIH w/4 1/2" completion and related jewelry, tq to 3850 ft Ibs. Printed: 1 1/22/2004 10:22: 12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-211 V-211 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 11/11/2004 11/20/2004 Spud Date: 11/12/2004 End: RUNCMP Brine Loss f/Day = 81 bbls. 11/20/2004 00:00 - 07:30 7.50 RUNCMP Con't to RIH w/4.5" L-80 TC-II tbg. MU torq t/3850 ft. Ibs. 07:30 - 08:30 1.00 RUNCMP PU/MU space out pups, 1 jt tbg, tbg hanger, land tbg, 100k up, 72k dn, RILDS, back out landing jt. 08:30 - 09:00 0.50 RUNCO~ I RUNCMP PJSM w/SWS, RU/PU wire line. 09:00 - 09:30 0.50 RUNCO I RUNCMP RIH w/GR e-line to confirm depth f/packer set. 09:30 - 10:00 0.50 RUNCO RUNCMP RD e-line. 10:00 - 11 :00 1.00 RUNCO RUNCMP Reverse circ 12 bbls clean 9.0 ppg brine, 2 bbls clean inhibited brine, 115 bbls clean brine at 3 bpm, 250 psi. 11 :00 - 12:00 1.00 RUNCO RUNCMP PU landing jt, drop ball & rod, pressure to 4500 psi to set RUNCOt completion string packers. 12:00 - 13:30 1.50 RUNCMP Hold 4500 psi on tbg f/30 min - OK, bleed tbg pressure to 1500 psi, pressure annulus to 4000 psi & test f/30 min - OK, bleed I off annulus to 0 then tbg to 0, re-pressure annulus to 2500 psi I and shear DCK valve - OK, pump down annulus & tbg w/some RUNCOt restriction to circulation. 13:30 - 14:00 0.50 RUNCMP Bled dn all lines to stack & suck out same, install TWC & test 1.00 BOPSU~P f/below to 1000 psi - OK. 14:00 - 15:00 OTHCMP ND stack. 15:00 - 18:00 3.00 WHSUR I P IOTHCMP Move adapter flange & tree into cellar & steam off, NU adapter flange & tree & test adapter flange void t/5000 psi f/10 min - OK, test tree to 5000 psi - OK. 18:00 - 18:30 0.50 WHSUR P OTHCMP RU DSM, pull TWC wllubricator. 18:30 - 21 :30 3.00 WHSUR P OTHCMP PJSM, RU lines & Little Red's, reverse 88 bbls warm diesel down 7" x 4 1/2" annulus to feeze protect well at 2.5 bpm, 1200 I psi FCP, U-tube diesel thru tree to freeze protect tbg. 21 :30 - 22:30 1.00 WHSUR P OTHCMP Lubricate BPV in w/DSM & test f/below w/Little Red's to 1000 psi - OK, install VR plugs in IA & OA (DSM), RD Little Red's & DSM. 22:30 - 00:00 1.50 RIGD P POST Secure well, cellar, rig floor & pits f/move to L-02A. (RELEASE FN-2111 AT 24:00 HRS ON 11/20/2004.) Printed: 11/22/2004 10:22:12 AM V-211 Survey Report Schlu berger Report Date: 16-Nov-04 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: V-Pad I Plan V-211 (N-C) Well: V-211 Borehole: V-211 UWVAPI#: 500292323200 Survey Namel Date: V-211/ November 16,2004 Torti AHDI DDII ERD ratio: 91.121' /3991.55 ft /5.689/ 0.834 Grid Coordinate SY5tem: NAD27 Alaska State Planes, Zone 04, US Feet Location LatILong: N 70.32792893, W 149.26676892 Location Grid NlE YIX: N 5970054.320 flUS, E 590410.000 ftUS Grid Convergence Angle: +0.69044014' Grid Scale Factor: 0.99990929 Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 320.380' Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 80.90 ft relative to MSL Sea Bed I Ground Level Elevation: 52.40 fI relative to MSL Magnetic Declination: 24.712' Total Field Strength: 57595.441 n T Magnetic Dip: 80.799' Declination Date: November 15, 2004 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North -> True North: +24.712' Local Coordinates Referenced To: Well Head . Comments Latitude Longitude RTE N 70.32792893 W 149.26676892 First MWD IFR MS N 70.32793170 W 149,26677005 N 70.32793766 W 149.26677874 N 70.32795098 W 149.26680738 N 70.32797103 W 149.26685512 574.99 9.78 317.82 492.37 573.27 32.00 32.25 32.03 25.54 -19.34 3.11 5970079.62 590390.36 N 70.32799869 W 149.26692576 667.55 12.58 314.74 583.17 664.07 49.89 50.19 49.89 38.46 -31.78 3.09 5970092.39 590377.76 N 70.32803399 W 149.26702664 759.71 15.37 317.88 672.59 753.49 72.09 72.44 72.10 54.59 -47.10 3.14 5970108.33 590362.25 N 70.32807805 W 149.26715090 851.39 17.24 321.81 760.58 841 .48 97.81 98.17 97.82 74.28 -63.66 2.37 5970127.82 590345.46 N 70.32813185 W 149.26728512 943.99 19.37 322.72 848.49 929.39 126.87 127.25 126.87 97.28 -81.44 2.32 5970150.61 590327.40 N 70.32819470 W 149.26742936 1037.67 21.56 321.64 936.26 1017.16 159.61 160.00 159.61 123.15 -101.54 2.37 5970176.22 590307.00 N 70.32826535 W 149.26. 1130.93 23.74 320.33 1022.32 1103.22 195.52 195.92 195.52 151.04 -124.16 2.40 5970203.83 590284.04 N 70.32834154 W 149,26777575 1224.62 27.64 320.83 1106.73 1187.63 236.12 236.52 236.12 182.41 -149.93 4.17 5970234.90 590257.89 N 70.32842726 W 149.26798478 1318.26 30.48 321.94 1188.58 1269.48 281.59 282.00 281.60 217.96 -178.30 3.09 5970270.09 590229.10 N 70.32852437 W 149.26821481 1412.07 33.07 322.15 1268.32 1349.22 330.97 331.39 330.98 256.91 -208.68 2.76 5970308.67 590198.26 N 70.32863077 W 149.26846116 1505.15 35.70 320.76 1345.13 1426.03 383.52 383.96 383.54 298.00 -241.44 2.95 5970349.36 590165.00 N 70.32874304 W 149.26872690 1598.13 39.09 321.09 1418.99 1499.89 439.97 440.41 440.00 341.84 -277.03 3.65 5970392.76 590128.90 N 70.32886278 W 149.26901547 1692.33 44.04 320.36 1489.45 1570.35 502.45 502.89 502.47 390.19 -316.59 5.28 5970440.63 590088.76 N 70.32899488 W 149.26933635 1784.78 43.49 320.08 1556.21 1637.11 566.40 566.84 566.42 439.33 -357.51 0.63 5970489.27 590047.26 N 70.32912913 W 149.26966817 1876.57 42.64 319.93 1623.27 1704.17 629.07 629.52 629.09 487.35 -397.79 0.93 5970536.80 590006.40 N 70.32926030 W 149.26999487 1970.64 43.62 320.59 1691.92 1772.82 693.38 693.83 693.39 536.80 -438.90 1.15 5970585.75 589964.70 N 70.32939540 W 149.27032828 2064.22 46.03 319.90 1758.29 1839.19 759.34 759.79 759.36 587.51 -481.09 2.63 5970635.94 589921.91 N 70.32953392 W 149.27067046 2158.06 49.30 320.33 1821.48 1902.38 828.70 829.15 828.71 640.74 -525.57 3.50 5970688.62 589876.80 N 70.32967932 W 149.27103114 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) Plan V-211 (N-C)\V-211\V-211\V-211 Generated 12/29/200412:34 PM Page 1 of 3 Comments Latitude Longitude N 70.32982766 W 149.27140054 N 70.32997288 W 149.27176352 2439.37 47.44 319.52 2008.42 2089.32 1038.89 1039.35 1038.89 801.56 -660.91 0.79 5970847.78 589739.54 N 7033011864 W 149.27212889 2533.28 46.71 319.29 2072.37 2153.27 1107.65 1108.11 1107.65 853.77 -705.66 0.80 5970899.45 589694.17 N 70.33026128 W 149.27249181 2626.04 48.99 318.39 2134.62 2215.52 1176.39 1176.88 1176.39 905.54 -750.92 2.56 5970950.66 589648.29 N 70.33040268 W 149.27285896 2718.87 48.26 319.20 2195.98 2276.88 1246.02 1246.54 1246.02 957.95 -796.81 1.02 5971002.51 589601.78 N 70.33054584 W 149.27323117 2812.41 47.73 319.25 2258.58 2339.48 1315.51 1316.05 1315.52 1010.58 -842.21 0.57 5971054.59 589555.75 N 70.33068962 W 149.27359938 2905.77 47.30 319.29 2321.63 2402.53 1384.35 1384.89 1384.36 1062.76 -887.13 0.46 5971106.21 589510.21 N 70.33083214 W 149.27396376 3000.03 47.14 318.83 2385.65 2466.55 1453.51 1454.08 1453.53 1115.02 -932.47 0.40 5971157.92 589464.25 N 70.33097490 W 149.27433148 3092.78 46.87 319.25 2448.90 2529.80 1521.33 1521.92 1521.36 1166.25 -976.94 0.44 5971208.60 589419.17 N70.33111484 W 149.2.0 3185.45 46.36 319.26 2512.55 2593.45 1588.67 1589.26 1588.70 1217.27 -1020.89 0.55 5971259.09 589374.61 N 70.33125422 W 149.2 7 3278.14 45.99 319.20 2576.74 2657.64 1655.53 1656.14 1655.57 1267.91 -1064.56 0.40 5971309.20 589330.34 N 70.33139256 W 149.27 00 3298.65 46.37 319.39 2590.94 2671.84 1670.32 1670.93 1670.36 1279.13 -1074.21 1.97 5971320.30 589320.55 N 70.33142320 W 149.27548128 3362.55 45.15 318.29 2635.52 2716.42 1716.08 1716.71 1716.13 1313.60 -1104.34 2.27 5971354.40 589290.02 N 70.33151735 W 149.27572566 3456.58 44.32 319.63 2702.32 2783.22 1782.24 1782.89 1782.30 1363.51 -1147.79 1.34 5971403.78 589245.97 N 70.33165368 W 149.27607816 3550.78 45.74 321.42 2768.89 2849.79 1848.88 1849.53 1848.93 1414.96 -1190.15 2.02 5971454.70 589203.00 N 70.33179421 W 149.27642174 3644.43 46.27 322.08 2833.94 2914.84 1916.23 1916.90 1916.27 1467.86 -1231.86 0.76 5971507.10 589160,66 N 70.33193873 W 149.27676009 3738.33 47.15 323.90 2898.33 2979.23 1984.50 1985.25 1984.52 1522.44 -1272.99 1.69 5971561.17 589118.88 N 70.33208782 W 149.27709378 3831.94 47.41 325.09 2961.84 3042.74 2053.09 2054.02 2053.10 1578.43 -1312.93 0.97 5971616.67 589078.27 N 70.33224075 W 149.27741779 3925.16 48.04 326.43 3024.55 3105.45 2121.76 2122.99 2121.76 1635.45 -1351.73 1.26 5971673.21 589038.78 N 70.33239650 W 149.27773261 4017.75 47.98 326.19 3086.49 3167.39 2190.21 2191.81 2190.23 1692.71 -1389.91 0.20 5971730.00 588999.93 N 70.33255292 W 149.27804232 4110.49 47.16 327.06 3149.06 3229.96 2258.26 2260.26 2258.31 1749.87 -1427.56 1.12 5971786.70 588961.59 N 70.33270905 W 149.27834785 4203.59 47.75 326.70 3212.01 3292.91 2326.41 2328.85 2326.53 1807.32 -1465.04 0.69 5971843.68 588923.42 N 70.33286597 W 149.27865192 4297.30 48.73 327.19 3274.42 3355.32 2395.85 2398.75 2396.06 1865.90 -1503.17 1.12 5971901.80 588884.60 N 70.33302601 W 149.27896125 4391.08 48.98 325.44 3336.13 3417.03 2466.09 2469.37 2466.40 1924.66 -1542.34 1.43 5971960.08 588844.73 N 70.33318651 W 149.27927903 4484.38 48.59 324.89 3397.60 3478.50 2536.02 2539.56 2536.43 1982.27 -1582.42 0.61 5972017.19 588803.95 N 70.33334386 W 149.27960430 4577.29 48.31 322.91 3459.23 3540.13 2605.42 2609.09 2605.89 2038.45 -1623.39 1.62 5972072.87 588762.32 N 70.33349731 W 149.27993665 4670.22 48.48 322.95 3520.94 3601.84 2674.84 2678.57 2675.35 2093.89 -1665.27 0.19 5972127.80 588719.77 N 70.33364875 W 149.28_ 4763.35 48.53 321.04 3582.64 3663.54 2744.56 2748.33 2745.10 2148.85 -1708.22 1.54 5972182.23 588676.17 N 70.33379887 W 149.280 4856.80 49.17 321.31 3644.14 3725.04 2814.92 2818.69 2815.46 2203.67 -1752.34 0.72 5972236.51 588631.40 N 70.33394861 W 149.28098290 4949.96 49.07 319.68 3705.11 3786.01 2885.35 2889.13 2885.89 2258.01 -1797.14 1.33 5972290.31 588585.95 N 70.33409704 W 149.28134644 5043.40 48.76 318.94 3766.52 3847.42 2955.77 2959.55 2956.26 2311.42 -1843.06 0.68 5972343.15 588539.40 N 70.33424290 W 149.28171899 5136.65 48.08 319.47 3828.40 3909.30 3025.50 3029.31 3025.97 2364.22 -1888.63 0.84 5972395.40 588493.20 N 70.33438713 W 149.28208878 5231.56 47.67 320.06 3892.07 3972.97 3095.89 3099.70 3096.33 2417.96 -1934.10 0.63 5972448.58 588447.09 N 70.33453391 W 149.28245772 5324.49 47.08 319.90 3955.00 4035.90 3164.27 3168.08 3164.69 2470.32 -1978.07 0.65 5972500.40 588402.49 N 70.33467693 W 149.28281450 5417.22 47.14 318.79 4018.11 4099.01 3232.20 3236.02 3232.59 2521.86 -2022.33 0.88 5972551.40 588357.62 N 70.33481770 W 149.28317366 5511.38 47.88 318.12 4081.71 4162.61 3301.59 3305.45 3301.94 2573.83 -2068.38 0.94 5972602.80 588310.95 N 70.33495963 W 149.28354732 5604.94 48.94 318.05 4143.82 4224.72 3371.51 3375.42 3371.81 2625.90 -2115.13 1.13 5972654.30 588263.58 N 70.33510184 W 149.28392662 5696.91 48.30 318.16 4204.61 4285.51 3440.46 3444.43 3440.72 2677.27 -2161.21 0.70 5972705.10 588216.89 N 70.33524214 W 149.28430056 5790.52 48.49 317.61 4266.77 4347.67 3510.39 3514.43 3510.61 2729.19 -2208.15 0.48 5972756.45 588169.33 N 70.33538395 W 149.28468146 5883.60 48.29 318.01 4328.58 4409.48 3579.91 3584.02 3580.10 2780.75 -2254.89 0.39 5972807.44 588121.98 N 70.33552478 W 149.28506073 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) Plan V-211 (N-C)\V-211\V-211\V-211 Generated 12/29/2004 12:34 PM Page 2 of 3 Comments Latitude Longitude N 70.33566932 W 149.28544363 6071.63 47.51 318.21 4454.43 4535.33 3719.53 3723.73 3719.66 2885.11 -2347.77 0.66 5972910.66 588027.86 N 70.33580979 W 149.28581446 6164.74 47.26 317.92 4517.47 4598.37 3787.99 3792.25 3788.10 2936.08 -2393.56 0.35 5972961.08 587981.46 N 70.33594901 W 149.28618607 6257.81 46.55 318.10 4581.05 4661.95 3855.90 3860.21 3855.98 2986.59 -2439.03 0.78 5973011.03 587935.39 N 70.33608696 W 149.28655503 6351.85 46.03 317.78 4646.04 4726.94 3923.81 3928.18 3923.88 3037.06 -2484.56 0.61 5973060.94 587889.25 N 70.33622480 W 149.28692458 Last MWD IFR MS 6366.50 45.95 317.64 4656.21 4737.11 3934.34 3938.72 3934.40 3044.86 -2491.65 0.88 5973068.65 587882.07 N 70.33624609 W 149.28698212 TO ( Projected) 6440.00 45.95 317.64 4707.32 4788.22 3987.10 3991.55 3987.15 3083.89 -2527.25 0.00 5973107.25 587846.01 N 70.33635270 W 149.28727098 Survey Type: Definitive Survey NOTES: MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing.) Surface: 4808 FSL 1891 FEL S11 T11 N R11 E UM BHL: 2612FSL4416FELS2T11NR11EUM NorthinQ (Y) rnUSl 5970054.32 5973107.25 EastinQ (X) rnUSl 590410.00 587846.01 . LeQal DescriDtion: . SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( d031 rt-546 ) Plan V-211 (N-C)\V-211\V-211\V-211 Generated 12/29/2004 12:34 PM Page 3 of 3 TREE = WELL.HeAO = ACTUATOR = KB. ELEV = BF. KOP Max Datu Datu 4-1/16" crw FMC NA 80.9' FROM DR!. DRAFT V -211 i SAÆTY NOTES: GLM'S @ STA #1- #5 ARE 3-112" X 1"1/2" MMG-W WHICH ARE WATERA.OOD MANDRELS. 13- ELEV= 52.4' = 200' /A 3060' H 4-1/2" HES X NIP, 10 = 3.813" 1 Angle = 49 @ 4856' mMO- 6440' 1'/ ¡,... mlVO= 4788' 1 ST MD lVO DE\! TYPE VLV LATCH PORT DATE 6 5537 4170 48 KBG2 DCK BEl< YES 11/20/04 I 9-5/8" CSG, 40#, L-80, 10 = 8.835" I 5 5738 4300 48 MMG-W DUM RK 11/20/04 3340' I ~ 4 5767 4310 48 MMG-W DUM RK 11/20/04 L 3 5842 4360 48 MMG-W DUM RK 11/20/04 2 5934 4432 48 MMG-W DUM RK 11/20/04 Minimum IC = 2.813" 1 6010 4482 48 MMG-W DUM RK 11/20/04 3-1/2" HES X NIPPLE . . 5646' 41/2" HES X Nip, 103.818" . I I /2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" H 5684' :I~ 17" MARKER JOM W/ RA TAG H 5188' l'ì 8 V 5667' II 7" X 4-1/2" BKR PREMIER A<R, 10 = 3.87" I ¡g t 5726' H 4-1/2" X 3-1/2" XO, ID = 2.992" I I 3-1/2" TBG W/ RA MARKERH ¡ 5786' I~ W ~ 5795' 3-1/2" HES X NIP, 10 = 2.813" I ~ . 1 v :8: ¡",-.." 5816' LJ 7" X 3-1/2" BKR PREMIER A<R, D = 2.87" I ~ 17" MARKER JOINTW/ RA TAG 1-1 5702' J¡ Þ ~ 5963' 3-1/2" HES X NIP, ID = 2.813" I 1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I..... 5861' I.. ....1 \ 8 - 5983' I I 7" X 3-1/2" BKR PREMIER A<R, 10 = 2.87" I PERFORATION SUMMARY 2S REF LOG: ~ I ANGLE AT TOP PERF: xxo @ xxxx' Note: Refer to Production DB for historica perf data \ ~ 6038' H 3-1/2" HESX NIP, 10=2.813"1 SIZE SPF INTERV AL Opn/Sqz DATE ......... 4.5" 5 5760-5810 Open 11/18/04 :8 ..,...." 6059' L I 7" X 3-1/2" BKR S-3 A<R, 10 = 3.875" I 4.5" 5 5858-5900 Open 11/18/04 .ð 4.5" 5 5916-5938 Open 11/18/04 . H 3-1/2" HES X NIP, 10 = 2.813"1 4.5" 5 5996-6016 Open 11/18/04 . 6085' 4.5" 5 6072-6122 Open 11/18/04 I 1- --r 6106' 3-1/2" HES X NIP, ID = 2.813" I .......- --- I I PBTD I 6340' 1~ g I 6128' H 3-1/2" WLEG, ID = 3.00" I 7" CSG 26# L-80 10 = 6.276" , H 6425 14-1 DATE REV BY COMMENTS 11/20/04 LV ORIGINAL COWA...ETION DATE REV BY COMMENTS ORION UNrr WELL: V-211i ÆRM1T No: 204-220 API No: 50-029-23232-00 SEC 11, T11N, R11E, 4809' NSL & 1891' WEL BP Exploration (Alaska) SCRLUMBERGER Survey report Client.......... ... ......: BP Exploration (Alaska), Inc. Field. . . . . . . . . . . . . . . . . . . .: Orion Well. . . . . . . . . . . . . . . . . . . . .: V-211 API number............ ...: 50-029-23232-00 Engineer........... ......: J. Rathert Rig:.............. .... ...: Nabors 9ES State:.......... .........: 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.......: 52.25 ft KB above permanent.... ...: N/A ft DF above permanent.......: 80.90 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: 320.38 degrees RECEIVED DEC 2 2 2004 AI'$ka on & Gas Cons. Commissi.Qn Anchorage [(c)2004 IDEAL ID8 1C_02J ,) à ~---¡w 16-Nov-2004 20:12:52 Spud date. . . . . . . . . . . . . . . . : Last survey date... ......: Total accepted surveys...: MD of first survey... ....: MD of last survey........: Page 1 of 4 12 Nov 04 16-Nov-04 71 0.00 ft 6440.00 ft . ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date. ...........: 12-Nov-2004 Magnetic field strength..: 1151.93 RCNT Magnetic dec (+E/w-). ....: 24.72 degrees Magnetic dip... ...... ....: 80.80 degrees ----- MWD survey Reference Reference G..............: Reference R..............: Reference Dip............: Tolerance of G...........: Tolerance of R....... . . . . : Tolerance of Dip..... . . . . : Criteria --------- 1002.68 mGal 1151.93 RCNT 80.80 degrees (+1-) 2.50 mGal ( + I -) 6. 00 RCNT (+1-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.72 degrees Grid convergence (+E/w-).: 0.00 degrees Total az corr (+E/W-)....: 24.72 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 16-Nov-2004 20:12:52 Page 2 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 205.89 0.57 352.21 205.89 205.89 0.87 1. 01 -0.14 1. 02 352.21 0.28 MWD IFR MSA - 3 297.42 2.51 329.74 91. 53 297.38 3.23 3.20 -1.21 3.42 339.26 2.18 MWD IFR MSA - 4 391.71 4.83 321.14 94.29 391. 47 9.24 8.07 -4.74 9.36 329.57 2.52 MWD IFR MSA - 5 483.24 6.97 321.35 91.53 482.51 18.65 15.41 -10.63 18.72 325.41 2.34 MWD IFR MSA 6 574.99 9.78 317.82 91.75 573.27 32.00 25.54 -19.34 32.03 322.86 3.11 MWD IFR MSA . - 7 667.55 12.58 314.74 92.56 664.07 49.89 38.46 -31.78 49.89 320.43 3.09 MWD IFR MSA - 8 759.71 15.37 317.88 92.16 753.49 72.09 54.59 -47.10 72.10 319.21 3.14 MWD IFR MSA - - 9 851. 39 17.24 321.81 91.68 841.48 97.81 74.28 -63.66 97.82 319.40 2.37 MWD IFR MSA - 10 943.99 19.37 322.72 92.60 929.39 126.87 97.28 -81. 44 126.87 320.07 2.32 MWD IFR MSA 11 1037.67 21. 56 321.64 93.68 1017.16 159.61 123.15 -101.54 159.61 320.49 2.37 MWD IFR MSA - 12 1130.93 23.74 320.33 93.26 1103.22 195.52 151.04 -124.16 195.52 320.58 2.40 MWD IFR MSA - 13 1224.62 27.64 320.83 93.69 1187.63 236.12 182.41 -149.93 236.12 320.58 4.17 MWD IFR MSA - 14 1318.26 30.48 321.94 93.64 1269.48 281.59 217.96 -178.30 281.60 320.72 3.09 MWD IFR MSA - 15 1412.07 33.07 322.15 93.81 1349.22 330.97 256.91 -208.68 330.98 320.91 2.76 MWD IFR MSA 16 1505.15 35.70 320.76 93.08 1426.03 383.52 298.00 -241. 44 383.54 320.99 2.95 MWD IFR MSA - 17 1598.13 39.09 321. 09 92.98 1499.89 439.97 341.84 -277.03 440.00 320.98 3.65 MWD IFR MSA - 18 1692.33 44.04 320.36 94.20 1570.35 502.45 390.19 -316.59 502.47 320.94 5.28 MWD IFR MSA - 19 1784.78 43.49 320.08 92.45 1637.11 566.40 439.33 -357.51 566.42 320.86 0.63 MWD IFR MSA - 20 1876.57 42.64 319.93 91.79 1704.17 629.07 487.35 -397.79 629.09 320.78 0.93 MWD IFR MSA 21 1970.64 43.62 320.59 94.07 1772.82 693.38 536.80 -438.90 693.39 320.73 1.15 MWD IFR MSA . - 22 2064.22 46.03 319.90 93.58 1839.19 759.34 587.51 -481.09 759.36 320.69 2.63 MWD IFR MSA - 23 2158.06 49.30 320.33 93.84 1902.38 828.70 640.74 -525.57 828.71 320.64 3.50 MWD IFR MSA - 24 2252.00 48.66 319.69 93.94 1964.04 899.58 695.04 -571.11 899.58 320.59 0.85 MWD IFR MSA - 25 2345.01 48.03 320.13 93.01 2025.86 969.07 748.20 -615.87 969.07 320.54 0.76 MWD IFR MSA 26 2439.37 47.44 319.52 94.36 2089.32 1038.89 801.56 -660.91 1038.89 320.49 0.79 MWD IFR MSA - 27 2533.28 46.71 319.29 93.91 2153.27 1107.65 853.77 -705.66 1107.65 320.43 0.80 MWD IFR MSA - 28 2626.04 48.99 318.39 92.76 2215.52 1176.39 905.54 -750.92 1176.39 320.33 2.56 MWD IFR MSA - 29 2718.87 48.26 319.20 92.83 2276.88 1246.02 957.95 -796.81 1246.02 320.25 1. 02 MWD IFR MSA 30 2812.41 47.73 319.25 93.54 2339.48 1315.51 1010.58 -842.21 1315.52 320.19 0.57 MWD IFR MSA [(c)2004 IDEAL ID8_1C_02J SCHLUMBERGER Survey Report 16-Nov-2004 20:12:52 Page 3 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg 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 2905.77 47.30 319.29 93.36 2402.53 1384.35 1062.76 -887.13 1384.36 320.15 0.46 MWD IFR MSA - 32 3000.03 47.14 318.83 94.26 2466.55 1453.51 1115.02 -932.47 1453.53 320.09 0.40 MWD IFR MSA - 33 3092.78 46.87 319.25 92.75 2529.80 1521.33 1166.25 -976.94 1521. 36 320.05 0.44 MWD IFR MSA - 34 3185.45 46.36 319.26 92.67 2593.45 1588.67 1217.27 -1020.89 1588.70 320.01 0.55 MWD IFR MSA - 35 3278.14 45.99 319.20 92.69 2657.64 1655.53 1267.91 -1064.56 1655.57 319.98 0.40 MWD IFR MSA - 36 3298.65 46.37 319.39 20.51 2671.84 1670.32 1279.13 -1074.21 1670.36 319.98 1. 97 MWD IFR MSA . - 37 3362.55 45.15 318.29 63.90 2716.42 1716.08 1313.60 -1104.34 1716.13 319.95 2.27 MWD IFR MSA - 38 3456.58 44.32 319.63 94.03 2783.22 1782.24 1363.51 -1147.79 1782.30 319.91 1. 34 MWD IFR MSA 39 3550.78 45.74 321.42 94.20 2849.79 1848.88 1414.96 -1190.15 1848.93 319.93 2.02 MWD IFR MSA - 40 3644.43 46.27 322.08 93.65 2914.84 1916.23 1467.86 -1231.86 1916.27 320.00 0.76 MWD IFR MSA 41 3738.33 47.15 323.90 93.90 2979.23 1984.50 1522.44 -1272.99 1984.52 320.10 1. 69 MWD IFR MSA - 42 3831.94 47.41 325.09 93.61 3042.74 2053.09 1578.43 -1312.93 2053.10 320.25 0.97 MWD IFR MSA - 43 3925.16 48.04 326.43 93.22 3105.45 2121.76 1635.45 -1351.73 2121.76 320.43 1.26 MWD IFR MSA - 44 4017.75 47.98 326.19 92.59 3167.39 2190.21 1692.71 -1389.91 2190.23 320.61 0.20 MWD IFR MSA - 45 4110.49 47.16 327.06 92.74 3229.96 2258.26 1749.87 -1427.56 2258.31 320.79 1.12 MWD IFR MSA 46 4203.59 47.75 326.70 93.10 3292.91 2326.41 1807.32 -1465.04 2326.53 320.97 0.69 MWD IFR MSA - 47 4297.30 48.73 327.19 93.71 3355.32 2395.85 1865.90 -1503.17 2396.06 321.15 1.12 MWD IFR MSA - 48 4391.08 48.98 325.44 93.78 3417.03 2466.09 1924.66 -1542.34 2466.40 321.29 1.43 MWD IFR MSA - 49 4484.38 48.59 324.89 93.30 3478.50 2536.02 1982.27 -1582.42 2536.43 321. 40 0.61 MWD IFR MSA - 50 4577.29 48.31 322.91 92.91 3540.13 2605.42 2038.45 -1623.39 2605.89 321.47 1.62 MWD IFR MSA 51 4670.22 48.48 322.95 92.93 3601.84 2674.84 2093.89 -1665.27 2675.35 321.50 0.19 MWD IFR MSA . - 52 4763.35 48.53 321.04 93.13 3663.54 2744.56 2148.85 -1708.22 2745.10 321. 52 1.54 MWD IFR MSA - 53 4856.80 49.17 321.31 93.45 3725.04 2814.92 2203.67 -1752.33 2815.46 321.51 0.72 MWD IFR MSA - 54 4949.96 49.07 319.68 93.16 3786.01 2885.35 2258.01 -1797.14 2885.89 321. 48 1. 33 MWD IFR MSA - 55 5043.40 48.76 318.94 93.44 3847.42 2955.77 2311.42 -1843.06 2956.26 321.43 0.68 MWD IFR MSA 56 5136.65 48.08 319.47 93.25 3909.30 3025.50 2364.22 -1888.63 3025.97 321.38 0.84 MWD IFR MSA - 57 5231.56 47.67 320.06 94.91 3972.97 3095.89 2417.96 -1934.10 3096.33 321.34 0.63 MWD IFR MSA 58 5324.49 47.08 319.90 92.93 4035.90 3164.27 2470.32 -1978.07 3164.69 321.31 0.65 MWD IFR MSA - 59 5417.22 47.14 318.79 92.73 4099.01 3232.20 2521. 86 -2022.33 3232.59 321.27 0.88 MWD IFR MSA 60 5511. 38 47.88 318.12 94.16 4162.61 3301. 59 2573.83 -2068.38 3301.94 321.21 0.94 MWD IFR MSA [(c)2004 IDEAL ID8_1C_02J SCHLUMBERGER Survey Report 16-Nov-2004 20:12:52 Page 4 of 4 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg 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 (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5604.94 48.94 318.05 93.56 4224.71 3371.50 2625.90 -2115.13 3371.81 321.15 1.13 MWD IFR MSA 62 5696.91 48.30 318.16 91.97 4285.51 3440.46 2677.27 -2161.21 3440.72 321.09 0.70 MWD IFR MSA - 63 5790.52 48.49 317.61 93.61 4347.67 3510.39 2729.19 -2208.15 3510.61 321.02 0.48 MWD IFR MSA 64 5883.60 48.29 318.01 93.08 4409.48 3579.91 2780.75 -2254.89 3580.10 320.96 0.39 MWD IFR MSA - 65 5978.74 48.07 318.55 95.14 4472.92 3650.77 2833.67 -2302.07 3650.92 320.91 0.48 MWD IFR MSA 66 6071.63 47.51 318.21 92.89 4535.32 3719.53 2885.11 -2347.77 3719.66 320.86 0.66 MWD IFR MSA . - - 67 6164.74 47.26 317.92 93.11 4598.37 3787.99 2936.08 -2393.56 3788.10 320.81 0.35 MWD IFR MSA - 68 6257.81 46.55 318.10 93.07 4661. 95 3855.89 2986.59 -2439.03 3855.98 320.76 0.78 MWD IFR MSA - 69 6351.85 46.03 317.78 94.04 4726.94 3923.81 3037.06 -2484.56 3923.88 320.71 0.61 MWD IFR MSA - 70 6366.50 45.95 317.64 14.65 4737.11 3934.33 3044.86 -2491. 65 3934.40 320.71 0.88 MWD IFR MSA Final Survey Projected to Total Depth: 71 6440.00 45.95 317.64 73.50 4788.22 3987.10 3083.89 -2527.25 3987.15 320.67 0.00 Projection [(c)2004 IDEAL ID8 lC_02J . . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration IAlaska) Inc. Dispatched To: Helen Warman Well No V-211 Date Dispatched: 10-Nov-04 Installation/Rig Nabors 9ES Dispatched By: J. Bosse Data No Of Prints No of Floppies Surveys 2 Received By: }l~ ~ '1 Please 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 e-mail address:johnsojh@bp.com LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private . ~~~~Œ (ID~ ~~~~[h{~ . AIfASIiA. OIL AND GAS CONSERVATION COMMISSION November 17, 2604 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 27!1-1433 FAX (907) 276-7542 Mr. Randy Thomas GKA Drilling T earn Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Spacing Exception for Kuparuk River Unit 1E-168L2 Well (pennit to Drill Number 204- 220) Dear Mr. Thomas: On October 21, 2004, the Alaska Oil and Gas Conservation Commission ("Commission") received ConocoPhillips Alaska, Inc.'s application, dated October 20,2004, requesting a waiver of spacing requirements for drilling and operation of the Kuparuk River Unit ("KRU") 1E-168L2 oil production well. The surface location of the well is 207 feet :ITom the north line and 640 feet :ITom the east line of Section 21, TIIN, RlOE, Umiat Meridian ("UM"). The proposed total depth of the well is 1 ,302 feet :ITom the north line and 1,249 feet :ITom the east line of Section 15, TUN, RlOE, UM. KRU lE-168L2 will produce :ITom the West Sak Oil Pool within the Kuparuk River Unit, and it will lie entirely within state lease ADL 025651, more than 500 feet :ITom any property lines where ownership or landownership changes. This well will open the pool to production within 375 feet of existing well KRU lE-123Ll. On November 2, 2004, the Commission approved Conservation Order 406B ("CO 406B"), which governs the West Sak Oil Pool within the Kuparuk River Unit. CO 406B revised the well spacing requirements for this pool. Rule 3 of CO 406B states: "There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to an external property line where ownership or landownership changes." The Commission has detennined that drilling and operation of the KRU lE-168L2 well will confonn to the well spacing requirements 0 0 6B. A spacing exception is not required to drill and operate this well as propo cc: Well file 204-220 . ConocóP'hillips . Randy Thomas Kuparuk Drilling Team Leader Drilling and Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 November 3, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Spacing Exception for 1 E-168L2 ~~ l \¡ Dear Commissioner: ConocoPhillips Alaska, Inc. submits the receipts for the notification of the spacing exception to the co-owners for the Kuparuk multilateral on 1 E-168L2. The addresses for the co-owners are: ExxonMobil 800 Bell Street GSC EMB 1488 Houston, Texas 77022 B.P. Alaska, Inc. 900 E. Benson Blvd. Anchorage, Alaska 99508 Chevron U.S.A. Inc. 11111 So. Wilcrest Dr. Houston , Texas 77099 Union Oil Company 909 West 9th Ave. Anchorage, Alaska 99501 If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling and Wells III " I IIIIII UNITED STATES POSTAL SERVICE UNITED STATES POSTAL SERVICE First-Class Mail Postage & Fees Paid USPS Permit No. G-ifl First-Class Mail Postage & Fees Paid USPS Permit No. G-M · Sender: Please print your name, address, and ZIP+4 in this box · skavo¡,t A( lçvr 'Dv<l-k Co~æo~·,I\¡r 1tla~6- léJO G' >\Jed- A-íOlS50 A-,,-ckO{"-~7 Prt- -rtçþ · sendeSr:::t:ur ;m';:~Dr this box · Cø~oco Pk;( {1 Q;ÞfIAÝ 700 'G' Sf;é?:Jt"'" ATOUS-30 A~v,,-O ' It [ttSfCA- qq ':;0 I . II f . I I J U II 'I I "f I ,. II I " II:/¡¡ ¡/!!! ¡ ¡ !!!!!!I!!!/ !i/I! 1!1Ii/¡ ¡¡f¡¡¡dl!1! ¡¡¡II ........ .:::::. 11,1"1,',,, , I 11", ,,11,,11,,1,,',,11,1,1,,11, ./1,"1", /I :::::::. - -_._---~-~.. -----._-- - ------------~- -..--.",- - - - DER: COMPLETE THIS SECTION COMPLETE THIS SECTION ON DELIVERY SENDER: COMPLETE THIS SECTION ;omplete items 1, 2, and 3. Also complete em A if Restricted Delivery is desired. ri Ir name and address on the reverse o l. .__ we can return the card to you. ttach this card to the back of the mail piece, ï on the front if space permits. rticle Addressed to: a..E2-~t(0i\ Ù.$ .Ä.111t" . ore) ~. Jl. (o(S+~off II (( f So. (J:lc(eçt-' þr. fux.s~~1 1~a.S · Complete items 1, 2, and 3. Also complete iterro Æ if Restricted Delivery is desired. · Pr'ur name and address on the reverse so. .. we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: U~(O~ O(C,~~,( 0(0 :}. Hac. Ar4u{ ~ Oq l0es+ t::(.( A~. It ~J.OV(L G I At tl~l<.. o D Agent D Addressee C. Date of Delivery -'Yi D. Is delive address different from i m 1? D Ves If VES, enter delivery address below: D No C. D¡¡te of Delivery l,') D. Is delivery address different from item 1 . D ve. If YES. enter delivery address below: D No ..------------ 3. l1:'ice Type ~rtified Mail D Express Mail D Registered ~eturn Receipt for Merchandise D Insured Mail D C.O.D. 4. Restricted Delivery? (Extra Fee) D Ves 3. Service Type ~rtified Mail D Express Mail D Registered ~eturn Receipt for Merchandise o Insured Mail D C.O.D. 4. Restricted Delivery? (Extra Fee) Dves 2. Article Number (Transfer from service labeO 102595-Q2-M-1540 PS Form 3811. August 2001 icle Number nsfer from service labeO )rm 3811. August 2001 Domestic Return Receipt Domestic Return Receipt 102595-Q2-M-1540 1(;. r"'gt.'2... · Complete items 1, 2, and 3. Also complete itelT' A_ if Restricted Delivery is desired. · Pr( Jr name and address on the reverse so \, ._' we can return the card to you. · Attach this card to the back of the mail piece, or on the front if space permits. 1. Ärt6;d;:tH 01:,; , 1oH.lL~e C~"av(iÁ- B~( stlJ .G5G Et"{ß i~ r\z>0~,~\\ 770 2. Article Number (Transfer from service labeO PS Form 3811. August 2001 C{~~~trl1 I' ßîèJ(p!ovA ~4\(AL.s ¡ 10 P Nèco(>Ov1 t 'tex) 6. "B~so~ 13 \,,~. Á~kðÝt1~1 Alast<- ü qq~ o Agent o Addressee D. Is delivery address different from item 1? 0 Yes If YES. enter delivery address below: 0 No 3~se ice Type Certified Mail 0 Express Mail o R istered \¡;z(Åeturn Receipt for Merchandise o Insured Mail r D"ê:o.D. 4. Restricted Delivery? (Extra Fee) DYes i . Complete items 1, 2, and 3. Also complete item 4. if Restricted Delivery is desired. . Pri Jr name and address on the reverse sO.. _ we can return the card to you. . Attach this card to the back of the mail piece, or on the front if space permits. 2, Article Number (Transfer from service labeO 102595-02-M-1540 PS Form 3811, August 2001 I Domestic Return Receipt !G.. r(¡;'{; L'1- UNITED STATES POSTAL SERVICE IIIIII First-Class Mail Postage & Fees Paid USPS Permit No. (3..1" . · sende'sG::Y¡((:';þ;J: ZIP+4 in ~is box· CoLlOCO "Y!..t;lt;r Mast-a... 100 'b' ~ed- ATO{S3D A-~ðV"ff r A-~ tt'{ç(Õ 3·3~· ¡:' i ..,:~: l+~:"::; II .1. .'.1"1 J. ) ,II,... ..11..11..1,,1..11.1. I.. Ii 1I.1I...I",1i COMPLETE THIS SECTION ON DEUVERY A. Signature X ;ß/. 8. ~ce!ved by (Printeryot.. ame) L-.'<::ôna~ v( D. Is delivery address different from item 1? If YES, enter delivery address below: 3. me ice Type Csrtified Mail 0 Express Mail o egistered ~turn Receipt for Merchar o Insured Mail 0 C.O.D. 4. Restricted Delivery? (Extra Fee) 0 Yes Domestic Return Receipt rç- (~l?.. UNITED STATES POSTAL SERVICE 1 02595-02-M 111111 First-Class Mail Postage & Fees Pa USPS Permit No. (3..4n · Sender: Sk::~~OUAI\: ~d;15~ r in this box · Cow:cO ft~(L'r A(aç.ttL (CO 'G' ~ed- AIOfS3ò A-~var itt- q~<;IÔ ) ) , I. .. ~¡:. :: 11.1..1 i...LL..i.i.! .i. ii II 1\ ¡ i ii i i i i I !:::::H:::: :::::: :::: d::d! n! iH?: n! in :HHHHU:::l::d · SPACING EXCEPTION KRd /C-~ LZ- DONE Area / Well: Operator: CP/l :r /< Hearing Date: ' 1 Application Complete ~ I ~ .t A -1:> " (/ -.L Additional fuformation: Requested ~ via ~t4 i ; Received ~ via ~ Additional fuformation: Requested via ; Received via Additional fuformation: Requested VIa ; Received VIa Additional fuformation Complete d/J Public Notice Text Drafted Text Sent to Attorney General's Office Text Reviewed by Attorney General's Office Text Sent to Jody for Formatting / Publishing Published in Anchorage Daily News on N ¡:::¡. Questions for Operator Questions Drafted Questions Reviewed: By Team ; By Attorney General's Office Questions Sent to Operator VIa Response Received VIa Response Complete ~ Public Hearing Hearing Held Additional fuformation: Requested Additional fuformation: Requested Additional fuformation Complete ; Received VIa VIa ; Received VIa VIa Order I' /...... ~_ ~extDrafted ~ by Æ~ --=== Text Reviewed by Team Jlh L Text Sent to Attorney General's Office 'P Text Reviewed by Attorney General's Office Text Reviewed by Other Agency Text Sent to lody for Formatting / Publishing Text Sent to Commissioners ~u..:,. Spacmg bxceptlOn for KRU lE-168L2 - Question Steve - here is the list of owners we sent notification to. I will be following up with the actual receipt returned to us that the letter was received. I have received all four as of today. The actual date I mailed these was probably 10/20/04 or 10/21/04. The date received by the owner is on the receipt; either 10/25/04 or 10/28/04. Chevron U.S.A. Inc. %G.M. Forsthoff 11111 So. Wilcrest Dr. Houston, Texas 77099 ExxonMobil %Maggie Chavarria 800 Bell Street GSC EMB 1488 Houston, Texas 77022 B.P. Alaska %D. Nicolson 900 E. Benson Blvd. Anchorage, Alaska 99508 Union Oil Company % J. MacArthur 909 W. 9th Ave. Anchorage, Alaska 99501 Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Stephen Davies [mailto:steve davies@~ª~~~.state.?k.u~] Sent: Wednesday, November 03, 2004 12:05 PM To: Allsup-Drake, Sharon K Subject: Spacing Exception for KRU 1E-168L2 - Question Sharon, In the letter of application for a spacing exception for KRU 1E-168L2 (dated October 20, 2004), the second bullet point in the list of attachments to the letter says "A list of those owners, and the addresses to which the above notice was sent, and the date the notice was mailed to those owners." This list of owners, addresses and date of mailing isn't with the letter of application. You attached the letters of notice, and those letters are dated October 20, 2004, but I need the list of owners to ensure all received notice, and the mailing date for the notices. Could you email this list to me and follow it up with a hardcopy sometime in the next few days? I'm drafting the text of the exception, and need this to complete the file. Thanks, Steve Davies AOGCC 1 of 1 11/3/2004 1 :27 PM ~pacmg Exception for KRU lE-168L2 - Question Sharon, In the letter of application for a spacing exception for KRU lE-168L2 (dated October 20, 2004), the second bullet point in the list of attachments to the letter says "A list of those owners, and the addresses to which the above notice was sent, and the date the notice was mailed to those owners." This list of owners, addresses and date of mailing isn't with the letter of application. You attached the letters of notice, and those letters are dated October 20, 2004, but I need the list of owners to ensure all received notice, and the mailing date for the notices. Could you email this list to me and follow it up with a hardcopy sometime in the next few days? I'm drafting the text of the exception, and need this to complete the file. Thanks, Steve Davies AOGCC 1 of 1 1113/2004 12:06 PM Conoc~illipS Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com October 20, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Spacing Exception, We1l1E-168 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a spacing exception for the well bore to be designated 1E- 168L2, under the terms of 20 MC 25.055. At total depth, the 1E-168L2 well bore is expected to be 375 feet from the nearest point of "0" sand production in we1l1E-123L1 (this point being the top of the liner in well bore 1E-123L1), a West Sak production well in the West Sak Oil Pool of the Kuparuk River Unit. This distance will be less than that mandated by Conservation Order 406A, Rule 3, which states, "Nominal spacing within the pool will be 10 acres." Details of the distances between the two wells are depicted on the attached illustration, entitled "Spacing between 1E-168L1 & 1E-123 and 1E-168L2 & 1E-123L1". ConocoPhillips requests this exception to maximize production of the reserves in the West Sak Pool. All properties and lands within 1000' of 1E-168L2 are owned and operated by the same entities, with all those entities having the same percentages of ownership and / or authority to operate across those properties within 1000 feet of 1E-168L2. In addtion to the spacing illustration, please find attached for the review of the Commission the information required by 20 MC 25.055 (d): · A copy of the notice sent to all owners, landowners, and operators of all properties within 1,000 ¡/ feet of 1E-168L2, notifying them of this application. · A list of those owners, and the addresses to which the above notice was sent, and the date the notice was mailed to those owners. · A plat showing the proposed bottom hole location of 1E-168L2, all other completed and drilling ¡/ wells on the property, and all adjointing properties and wells. · An affidavit verifying that all facts are true, and that the plat correctly portrays the pertinent and ./ required data. Please contact Steve Shultz at 265-4620 if more information is needed to grant this spacing exception. Sincerely, ....--:::,. ,--,-4-- \ ~~ \ ~~-==- Randy Thomas GKA Drilling Team Leader CHECWT - SPACING EXCEPTION_PLICATION OPERATOR ConocoPhillips Alaska PROPERTY ID/ LEASE S: ADL 25648 Inc Kuparuk River / West Sak Oil Pool FIELD/POOL WELL NAME PI/SH: ADL 25648 1 E-168L2 VERTICAL EXPLORATORY GAS DEVIATED X DELINEATION OIL X DEVELOPMENT X N. /:Þ/{(."3-.oý SURFACE LOCATION PRODUCTIVE INTERVALS (Top and Bottom) BOTTOM HOLE , 207' ~L, 640' FEL, Section 21, T11 N, R10E, UM 1003' FNL, 1638' FEL, Section 22, T11 N, R10E, UM There is no bottom to the lateral since it is horizontal 1302' FNL, 1249' FEL, Section 15, T11 N, R10E, UM Check applicable reason(s) for spacing exception per 20 AAC 25.055(a): X To drill with spacing closer than the nominal 10 acres spacing mandated by Conservation Order 406A. (1) to drill a well for oil within 500 feet of a property line where ownership or landownership chan es, (2) to drill a well for gas within 1500 feet of a property line where ownership or landownershi chan es, (3) to drill and complete more than one oil well in a governmental quarter section; or to drill and complete an oil well closer than 1000' to any well drilling to or ca able of roducin from the same 001, 4 to drill and com lete more than one as well in a overnmental section; or or to drill and complete a gas well closer than 3000' to any well drilling to or ca able of roducin from the same 001. Does the application contain: X A brief ex lanation for wh the 0 erator has chosen to drill the s ecified location. A plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well or portion of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for as. The names of all owners, landowners, and operators of all properties within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for as. A copy of the notice sent by certified mail to the owners, landowners and operators described above, the date of mailin , and the addresses to which the notice was sent. An affidavit by a person acquainted with the facts verifying that all facts are true and that the lat correctl ortra s ertinent and re uired data. If the operator requests a variance from the notice requirements of 20AAC25.055(d), sufficient information to demonstrate that it is not feasible to comply with the notice re uirements because of the com lexit of ownershi within the notice area. X X X X D-La! B-La! D-La! B-La! From Brio: Well Name 1E-123 1E-123 1E-123 1E-123L1 1E-123PB1 1E-123PB1 1 E-123L1 1E-123L1 1E-123PB1 1E-168 Planned Toe 1E-123 Drilled Heels Api Name SAK B WEST SAK D 5,969,18915 WEST SAK B 5,969,39709 WEST SAK B 5,968,007.77 WEST SAK B 5,964,00625 WEST SAK B 5.963,706.65 WEST SAK D 5,966,02253 WEST SAK D 5,963,70678 WEST SAK D 5.00292E+11 5.00292E+11 5.00292E+11 5.00292E+11 5.00292E+11 5.00292E+11 5.00292E+11 5.00292E+11 5.00292E+11 -3,592 73 -3,540.64 -3,549.54 -3,463.01 -3,39496 -3,436.70 -3,395.03 1,694,86217 1,694,94796 1,694.835.64 1,694,657.90 1,694,63623 1.694,784.44 1,694,636.29 M 1E-168L1: proposed toe J 1 E-123L 1 top of "D" Sand Liner: /--- ,"o'h.,n mo.' po;n' of p,od..";on ;n / D sand. , E-' 68L2' p,opo..., toe \ ,¿-285ft1- 375 ft. 739 ft '- ,.."" 7""'" "$;n~*'., southern rnostpointof production in "8" sand. Con Alaska Spacing between 1 E-168 & 1E..123 Sheet 2 of 2 prepared by Steve Shultz 1 E-168 1 E-123 Spacing Diagram p2. vsd 10/14/2004 ¡¡::: o (!) (!) 660 ft. I ft. 330 ft. "·'.'L2, P~_dtoe-1 1--285 ft. , 1E-123L1 top of / southern most ¿ Dsand. I ; II 1 E-1 S8L 1: proposed toe ----.t'1 i 739 ft \ 11:-123 U¡¡a" «:::asingshoe, - southern mostpoint of production in "8" sand. .¿ o (!) (!) 660 ft. Alaska Spacing between 1 E-168l1 & 1 E-123 and 1 E-168l2 & 1 E-123l1 Sheet 1 of 2 prepared by Steve Shultz 1Ë-168 ~ 1E-123 Spaçìng dìagram.vsq 10114/2004 . . AFFIDA VIT TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF STEVEN M. SHULTZ STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Steven M. Shultz, declare and affirm as follows: 1. My name is Steven M. Shultz. I am over 19 years old and have personal knowledge ofthe matters set forth herein. 2. I am a Drilling Engineer for the operator, ConocoPhillips Alaska, Inc. 3. I am acquainted with the facts associated with the drilling of the 1E-168L2 well. 4. I have reviewed the application submitted for the exception to the spacing requirements of Conservation Order 406A and affirm that all facts therein are true. 5. I have reviewed the plat attached to the application and it correctly portrays pertinent and required data. DATED at Anchorage, Alaska this cXO V!J- day of October, 2004. J~ øf ~ Steven M. Shultz SUBSCRIBED AND AFFIRMED before me at Anchorage, Alaska this 2004. ~<1f2- day of October, NOTARY PUBL TE OF ALASKA ~---_._..._-" STA'IE- l')~' AI. /\ ';;~¡{A' .""'_ j'"\ . '-'.1. .. ._~ ,J _ ;¡., ',.. ,_ .t,.. /.'_ I~'_" . ,.'S..'\ 1/," N")T" ""\.' . ~.' %.'-' L . F,h¡ (~..;., -~) Carol l<eBy \,,?M.!J ~-=- .,' l(,'~';^"^' f""'fY'_,' .~"" ' , , -', r..r', . Mt Comm"':":::::'i>.r:{::~~~¿;!.::_;g,;_16, ¿v08 My commission expires f.,4,. lto.. ~tJOß ConoccJ'hillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 October 20, 2004 Chevron U.s.A. Inc. G. M. Forsthoff 11111 So. Wilcrest Drive Houston, Texas 77099 Re: Application for Spacing Exception, West Sak Oil Pool We1l1E-168 L2 To Whom it May Concerm: ConocoPhillips Alaska, Inc. has applied, on October 20,2004, to the Alaska Oil and Gas Conservation Commission for a spacing exception for the wellbore to be designated 1E-168L2, under the terms of 20 MC 25.055. At total depth, the 1E-168L2 well bore is expected to be 375 feet from the nearest point of "0" sand production in we1l1E-123L1 (this point being the top of the liner in wellbore 1E-123Ll), a West Sak production well in the West Sak Oil Pool of the Kuparuk River Unit. This distance will be less than that mandated by Conservation Order 406A, Rule 3, which states, "Nominal spacing within the pool will be 10 acres." The total depth location of 1E-168 L2 is expected to be 1302' FNL, 1249' FEL, of Section 15, T11N, R10E, Umiat Meridian. This is in ADL 25648, wholly within the Kuparuk River Unit. Please contact Steve Shultz at (907) 265-4620, or email steven.m.shultz@conocophillips.comif more information is needed regarding the spacing exception. Sin~~ dt .j¡ L Sharon Allsup-Drake ~ Administrative Aide I Conoc~illips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 October 20, 2004 ExxonMobil Alaska Production, Inc. J. P. Williams, Jr. 3301 'C' Street Suite 400 Anchorage, Alaska 99519-6601 Re: Application for Spacing Exception, West Sak Oil Pool We1l1E-168 L2 To Whom it May Concerm: ConocoPhillips Alaska, Inc. has applied, on October 20, 2004, to the Alaska Oil and Gas Conservation Commission for a spacing exception for the well bore to be designated 1E-168L2, under the terms of 20 MC 25.055. At total depth, the 1E-168L2 well bore is expected to be 375 feet from the nearest point of "D" sand production in we1l1E-123L1 (this point being the top of the liner in well bore 1E-123L1), a West Sak production well in the West Sak Oil Pool of the Kuparuk River Unit. This distance will be less than that mandated by Conservation Order 406A, Rule 3, which states, "Nominal spacing within the pool will be 10 acres." The total depth location of 1E-168 L2 is expected to be 1302' FNL, 1249' FEL, of Section 15, T11N, R10E, Umiat Meridian. This is in ADL 25648, wholly within the Kuparuk River Unit. Please contact Steve Shultz at (907) 265-4620, or email steven.m.shultz@conocophillips.comif more information is needed regarding the spacing exception. ~n~r^- Ji .aL Sharon Allsup-Drake I Administrative Aide ConoccJ'hillipS Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 October 20, 2004 Union Oil Company of California J. MacArthur 909 West 9th Avenue Anchorage, Alaska 99501 Re: Application for Spacing Exception, West Sak Oil Pool We1l1E-168 L2 To Whom it May Concerm: ConocoPhillips Alaska, Inc. has applied, on October 20,2004, to the Alaska Oil and Gas Conservation Commission for a spacing exception for the wellbore to be designated 1E-168L2, under the terms of 20 MC 25.055. At total depth, the 1E-168L2 well bore is expected to be 375 feet from the nearest point of "D" sand production in weIl1E-123L1 (this point being the top of the liner in well bore 1E-123L1), a West Sak production well in the West Sak Oil Pool of the Kuparuk River Unit. This distance will be less than that mandated by Conservation Order 406A, Rule 3, which states, "Nominal spacing within the pool will be 10 acres." The total depth location of 1E-168 L2 is expected to be 1302' FNL, 1249' FEL, of Section IS, TllN, Rl0E, Umiat Meridian. This is in ADL 25648, wholly within the Kuparuk River Unit. Please contact Steve Shultz at (907) 265-4620, or email steven.m.shultz@conocophillips.comif more information is needed regarding the spacing exception. Sinc~^, Æ . ~~L Sharon Allsup-Drake Administrative Aide Conoc~illipS Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 October 20, 2004 BP Exploration (Alaska) Inc. D. Nicolson 900 E. Benson Blvd. Anchorage, Alaska 99508 Re: Application for Spacing Exception, West Sak Oil Pool We1l1E-168 L2 To Whom it May Concerm: ConocoPhillips Alaska, Inc. has applied, on October 20,2004, to the Alaska Oil and Gas Conservation Commission for a spacing exception for the well bore to be designated 1E-168L2, under the terms of 20 MC 25.055. At total depth, the 1E-168L2 well bore is expected to be 375 feet from the nearest point of "D" sand production in well 1E-123L1 (this point being the top of the liner in we II bore 1E-123L1), a West Sak production well in the West Sak Oil Pool of the Kuparuk River Unit. This distance will be less than that mandated by Conservation Order 406A, Rule 3, which states, "Nominal spacing within the pool will be 10 acres." The total depth location of 1E-168 L2 is expected to be 1302' FNL, 1249' FEL, of Section 15, T11N, R10E, Umiat Meridian. This is in ADL 25648, wholly within the Kuparuk River Unit. Please contact Steve Shultz at (907) 265-4620, or email steven.m.shultz@conocophillips.comif more information is needed regarding the spacing exception. since~1'- JlÄ .?;,.L Sharon Allsup-Drake / Administrative Aide - ~ lFUI rff\ Cj7u IT: (ñì~ ~.. jÃ\ n ~ ~ æJ ltù u: lJl) ¡J LnJ ~ Lru æJ . AItASIiA OILAlVD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V-211i BP Exploration (Alaska) Inc. Permit No: 204-220 Surface Location: 4809' NSL, 1891' WEL, SEC. 11, TIIN, RIlE, UM Bottomhole Location: 2604' NSL, 4435' WEL, SEC. 02, TIIN, RIlE, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (90 659-3 ager). Si c e BY ORDER OF THE COMMI ION DATED this-1 day of er,20,04_ / ð velN\ \( ØV cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~C)A 1011.1/2-004 r . STATE OF ALASKA . ALAS~OIL AND GAS CONSERVATION C~MISSIO~ PERMIT TO DRILL \w~;. 20 MC 25 005 /' ~ ') OL\ ,¡¿ 1a. Type of work II Drill o Redrill 1b. Current Well Class o Exploratory . 0 Development Oi.1 flM~'tÌþ'e,zone ORe-Entry o Stratigraphic Test II Service 7' 0 Q~v~QP(l1~!1t.Gás " :Smg/éLone '''h.·.. ':.., 2. Operator Name: 5. Bond: 181 Blanket o Single Well 1 1. Well Nam$.i1tlJÔtNtiØtber: / BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU V-211i 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box' 196612, Anchorage, Alaska 99519-6612 MD 6467' TVD 4788' Prudhoe Bay Field I Orion 4a. Location of Well (Governmental Section): 7. Property Designation: Schrader Bluff Surface: ADL 028240 4809' NSL, 1891' WEL, SEC. 11, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top'of Productive Horizon: 2414' NSL, 4277' WEL, SEC. 02, T11N, R11E, UM 11/11/04 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2604' r'I~L, 4435' WEL, SEC. 02, T11 N, R11 E, UM 2560 9902' 4b. Locatipn of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surfade: X-590410 y-5970054 Zone- ASP4 (Height above GL): 80.9' feet 1372' away V-104 at Na top 16. Deviated Wells: Kickoff Depth: 300 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.0~ ~ Maximum Hole Angle: 48.1 dearees Downhole: 2050 Surface: 1588 ~' . C!........õ...".,;n.......... .'. (i;.f. !Pf.....~!:9' TtlD Hole . 'Casina Weiaht Grade CouplinQ LenQth MD TVD MD TVD (includinQ staae data) Driven . 20" 166.4# X-56 Welded 80' 29' 29' 109' 109' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3315' 29' 29' 3344' 2701' ::>40 sx AS Lite, 378 sx Class 'G' 8-3/4" , 7" 26# L-80 BTC-M 6438' 29' 29' 6467' 4788' 346 sx Class 'G' 119. , ,.,.."".,.., q·WEI.L VUI'\IUJI "",. i'i:l '(Ti .11.. " ,jj....,..... Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 1f"'"".,I...""; ....i.. i Lehotn .," .. C!õ...... ···..r r··..···,·, i"r'~',i'jij I;'i., .... i Structural r.nnrtlJr.tnr Surface IntAr ,. I Production I inAr Perforation Depth MD (ft): IPerfOration Depth TVD (ft): 20. Attachments 181 Filing Fee, $100 o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis 181 Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that t~X~regOing is true and correct to the best of my knowledge. Contact Rob Tirpack, 564-4166 Printed Name Lowel rane A Title Senior Drilling Engineer Signature Ä-.~ __ ~~ ~ Prepared By Name/Number: PhonE~ Date k· -2::.--cV ··/<·';'X~>· ....;. ..y..ir;·y...··· r]}r':V.,.....·r,·.· '.. ".....'y.;..¥y ··;ij"ii.j·.;r·;:;]j,r'·riN;'!·j'¡(;.! .F.· Permit To Drill ,I API Number: -9,' 3 3 Permit APprOVjl/ IDJ I See cover letter for Number:..2{)~ _ 2...~ 50- 02. - 2.. 2~' 2- Date: ') other requirements Conditions of Approval: Samples Required DYes ~lNo Mud Log Requirèd DYes 1KNo Hydro Sulfide Measures DYes )2jrNo Directional Survey Required ~Yes DNo Other:T€~t ¡SO P L= ~OOO P <;) , fll L TJ Ù wL 't'4IL 1- V¿UßJ¡ ~ tV1 ' d 0 f'Pí U-{ f"{€' , (l;)J i. I 11f¡ lð cf 'ÃþPROVED BY Aooroved Eli:' -/( j ..- THE COMMISSION Date Form 1 0-401 ~ised 06~4 -- Subn:!t In Duplicate . . I Well Name: I V-211 i I Well Plan Summary I Type of Well (producer or injector): I USH Injector Surface Location: 4,809' FSL, 1,891' FEL, Sec. 11, T11 N, R11 E ,// (As Built) X = 590,410 Y = 5,970,054 " V-211 i Polygon 2 Target 1 2,246' FSL, 4,139' FEL, Sec. 2, T11 N, R11 E Top OA: X = 588,127 Y = 5,972,745 Z = 4,290' TVDss V-211i Polygon 2 Target 2 2,414' FSL, 4,277' FEL, Sec. 2, T11 N, R11 E Top OBd: X = 587,987 Y = 5,972,910 Z = 4,485' TVDss / V-211 i Polygon 2 BHL: 2,604' FSL, 4,435' FEL, Sec. 2, T11 N, R11 E 7 X = 587,827 Y = 5,973,099 Z = 4,707' TVDss I AFE Number: I ORD5M3563 I []!Œ] Nabors ges (I GL: I 52.4' I I KB: I 28.5' I Estimated Start Date: I November 11m, 2004 I I Operating days to complete: 11.5 TD: 6,467' MD I I TVD: I 4,788' I I Max Inc: I 48.10 I I . KBE: I 80.9' Well Design: USH Grassroots Schrader Injector 4-%" X 3-V2" TCII Completion. The 0 sands will have a 4-%" X 3-%" TCII Completion in the Schrader Bluff. Current Well Information General Distance to Nearest Property: Distance to Nearest Well in Pool: API Number: Well Type: Current Status: Conductor: BHP: BHT: -9,902' at top OA to the nearest PBU property line 1372' trom V-211 i to V-104 at the Na top 50-029-XXXXX Development - Orion Schrader Injector New well, 20" X 34" insulated conductor 20" X 34", 215.5 Ib/tt, A53 ERW set at 109' RKB 2,050 psi @ 4,625' TVDss (8.5 ppg EMW). Normal pressure gradient. 90°F @ 4,625' TVDss estimated % Mile Wellbore Near Wellbore Mechanical Integrity Summary: No wells with-in a % mile radius / No near wellbore integrity issues. C IT b· P asmgJ u mg rogram Hole CsgI Wt/Ft Grade Co~ Burst Collapse Length Top Bottom Size Tbg O.D. ,/ (psi) (psi) MD I TVDrkb MD I TVDrkb Driven* 20" 166.4# X-56 Welded 80' 29' I 29' 109' I 109' 12-%" 9-%" 40# L-80 BTC 5,750 3,090 3,315' 29' I 29' 3,344' 12,701' 8-%" 7" 26# L-80 BTC-M 7,240 5,410 6,438' 29' I 29' 6,467' 14,788' Tubinq 4 %" 12.60# L-80 TCII 8,430 7,500 5,814' 29' I 29' 5,843' 14,371' Tubinq 3 %" 9.30# L-80 TCII 10,160 10,530 292' 5,843' I 4,371' 6,135' I 4,566' V-211 i Permit to Drill Page 1 . ,Formation Markers V -211 (Based on Schlumberger wp05) . I Formation Tops MD TVD TVDss Pore psi EMW (ppg) Hydrocarbons SV6 967' 956' 875' 403 8.8 No SV5 1,727' 1,611' 1,530' 704 8.8 No SV4 1,901' 1,735' 1,655' 761 8.8 Pass. Gas Hvdrates Base Permafrost 1,967' 1,780' 1,700' 782 8.8 No SV3 2,476' 2,121' 2,040' 938 8.8 Pass. Gas Hydrates SV2 2,738' 2,295' 2,215' 1019 8.8 Poss. Gas Hydrates SV1 3,194' 2,601' 2,520' 1159 8.8 Pass. Gas Hydrates UG4 3,643' 2,901' 2,820' 1297 8.8 Thin coal UG4A 3,688' 2,931' 2,850' 1311 8.8 Heavy Oil-2850' to 3020' TVDss UG3 4,152' 3,241' 3,160' 1454 8.8 Heavy Oil-3160' to 3360' TVDss UG1 4,848' 3,706' 3,625' 1615 8.6 Heavy Oil-3625' to 3895' TVDss Fault 1 5,075' 3,769' 3,850' Top Schrader/Ma Sand 5,252' 3,976' 3,895' 1770 8.7 Heavy Oil-3895' to 3940' TVDss Mb1 5,320' 4,021' 3,940' 1790 8.7 Heavy Oil-3940' to 3950' TVDss Mb2 5,409' 4,081' 4,000' 1815 8.7 Heavv Oil-4000' to 4080' TVDss Mc 5,522' 4,156' 4,075' 1840 8.7 No Na 5,611' 4,216' 4,135' 1865 8.7 No Nb 5,641' 4,236' 4,155' 1870 8.7 Yes Nc 5,701' 4,276' 4,195' 1885 8.6 Yes OA 5,843' 4,371' 4,290' 1670 7.5 Yes OBa 5,933' 4,431' 4,350' 1885 8.3 Yes OBb 5,986' 4,466' 4,385' 1900 8.3 Yes OBc 6,068' 4,521' 4,440' 1935 8.4 Yes OBd 6,135' 4,566' 4,485' 1750 7.5 Yes OBe 6,217' 4,621' 4,540' 2015 8.5 Yes OBf 6,277' 4,661' 4,580' 2035 8.5 Yes OBf Base 6,345' 4,706' 4,625' 2050 8.5 No T.D.* 6,467' 4,788' 4,707' *TD is based on 250' TVD below the Top OBe marker* M dP u rogram: 12 W' Surface Hole Mud Properties: I Spud - Freshwater Mud I Interval Density Funnel Vis PV YP FL Chlorides PH Initial 8.5-9.2 250-300 20-45 50-70 NC-8.0 <500 8.5-9.0 Base Perm 9.0 -..9:'5\ 225-250 20-40 30-45 8.0 <500 8.5-9.0 Interval TD 9.5f 9.6) 225-250 15-20 30-40 5.0-7.0 <500 8.5-9.0 ~. Chlorides <600 Pro ram: Surface Gyro will be needed (run to 1200' or as conditions dictate MWD / GR None 8-%" Hole Section: MWD / GR / Res / Den / Neu / PWD (All realtime with recorded porosit ) Cased Hole: USIT Bond Log V-211 i Permit to Drill Page 2 . , Surface and Anti-Collision Issues Surface Shut-in Wells: Nearb Wells V-101 Distance to V -211 i 15' . V-101 and V-108 will require surface shut-in and wellhouse removal in order to move over well V-211i. V-Spare and V-203 are conductors only and should be evaluated before the rig move. V-202 should not require wellhouse removal, but should also be evaluated prior to the rig move for any potential interference. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautionary Comment V-101 18.66-ft 398-ft 12.16-ft Use Travelina Cvlinder Gvro V -108 21.07-ft 549-ft 11 .83-ft Use Travelina Cvlinder Gyro V-202 45.98-ft 398-ft 39.04-ft Use Travelina Cvlinder Gyro V-104 75.76-ft 496-ft 67.87-ft Use Travelina Cvlinder Gvro V-02 86.23-ft 447-ft 78.78-ft Use Travelina Cvlinder Gvro / In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Basis: Centralizer Recommendations: 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,344' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (if run). c) This centralizer program is subject to change due to actual hole conditions. 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 4,652' MD (600' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. V-211 i Permit to Drill Page 3 . . Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon ,/ calculations below, BOP equipment will be tested to 4,000 psi. Due to test pressures not exceeding 5,OOOpsi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for V-211 i will be 14 days. / Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: 2,050 psi - Base of Schrader (8.5 ppg @ 4,625' TVDss) 1,588 psi - Based on a full column of gas @ 0.10 psi/ft 4,000 psi/250 psi Rams / 2,500 psi/250 psi Annular 4,000 psi ~ppg minimum EMW LOT 20' from 9-5/8" shoe o Is with an 11.8 ppg EMW LOT timated 9.0 ppg Brine / 6.8 ppg Diesel · 7" Casing Test: · Integrity Test - 8-3/4" hole: · Kick Tolerance: · Planned completion fluid: 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 waste to Pad 3 for disposal. V-211 i Permit to Drill Page 4 · . DrillinQ Hazards and ContinQencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 2 fault block is expected to be normal pressured at 8.5-8.8 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad and have been encountered in wells as close as V-100 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to V-100 and V-111 had to have the mud treated and were able to drill to section TO. In V-100 the hydrates came from the SV1. Occasionally hydrates are encountered below the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected at V Pad. This fault has been intersected by several other wells on V-pad at this depth with out problem. · Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. We do not expect breathing on this well. IV. Kick Tolerancellntegrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Iblgal tail cement to 600' MD above the Ma sand -4,652' MD. C. The Kick Tolerance for the surface casing is 50 bbls with 9.3 ppg mud, 11.8 ppg LOT, and an 8.8 ppg pore pressure. D. Integrity Testing - 11.8 ppg EMW V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide / V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 PPfll is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: V-108 V-101 10 ppm 10 ppm Adjacent producers at TO: V-102 10 ppm V-106 15 ppm ,/ VII. Faults A. One fault is expected to be crossed at V-211 i. This fault has been intersected by several other wells on V-pad at this depth with out problem. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 (UG1): 5,075' MD 3,769' TVD 3,850' TVDss Throw: 80' SW CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-211 i Permit to Drill Page 5 · . V-211 i Drill and Complete Procedure Summary Pre-Rig Work: 1. The V-211 i conductor has been set. See As-Built. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in V-101 and V-108 and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. /' 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-'\4" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,344' MD. The /,C actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port Collar should be on location. _ Cement was not circulated to surface on V-103 and V-106 1st stage surface cement job. Therefore a port / collar will be run in the casing string if hole conditions dictate. /' 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4,000 psi. 6. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to float collar. Test the 9-%" casing to 4,000 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.0 ppg mud 8. Drill new formation to 20' below 9-%" shoe and perform LOT (If a 11.8 ppg EMW is not obtained contact /' ODE). 9. Drill ahead to Polygon 2 Target TD at 6,467' MD, (250' below top OBe marker). 10. Circulate and condition hole, POOH to run casing. Perform wiper trip only if hole conditions dictate. 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace /' the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-%" annulus. 12. PU DPC guns and RIH w/ -200' of 4.5" Power Jet 5 spf perf guns (total assembly length to be -400') with Schlumberger LWD GR. Tag PBTD. 13. Circ hole over to 9.0 brine. 14. Space out utilizing GR and RA tags in 7" casing. Once spaced out correctly, confirm cement compre~e strength is at least 2,000 psi. Perforate OA, OBa, OBb, OBc, and OBd. 15. RU Schlumberger E-line. RIH with gage ring and junk basket to recover any perf debris. Repeat until clean. 16. Run USIT/GR log. USIT will be primary depth control for future well work. ,/ 17. Run the 4-%" X 3-%", L-80 TCII completion with a 7" x 3-%" straddle packer assembly and injection mandrels. /' 18. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCK shear valve. 19. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. / 20. Freeze protect the well to -2,500' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-%" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 21. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCK shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. V-211 i Permit to Drill Page 6 . . V-211 i Detailed Drilling Procedure Job 1: MIRU Critical Issues: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ V-101 and V-108 will have to be shut in and require well house removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. ~ V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: V -102 V-101 10 ppm 10 ppm Adjacent producers at TD: V-102 10 ppm V-106 15 ppm Reference SOP: .:. "Drillingl Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 12%" Surface Hole Critical Issues: ~ At V-Pad, no significant surface hole drilling problems are present. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. ~ Close Approach: The V-101 and V-108 are required to be shut in and have their wellhouses removed due to surface location proximity to the V-211 i. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder I no-go plot per established procedures. A gyro should be run to at least 900'-1200'. ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque I drag in the later hole sections and allow for easier 9 5/8" casing running. A graduated build profile is planned. It is preferred that DLS are not pushed ahead of plan on the surface hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.830 motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. Before pulling out of the hole for the final time, make sure that the hole is clean, full returns are observed, and that the pipe pulls without significant overpull. Lost circulation is possible while cementing if these conditions are not satisfied. V-211 i Permit to Drill Page 7 . . ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. Reference RPs: .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations Job 3: Run 9-%" Surface CasinQ Critical Issues: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. Hydrates are prevalent on V-pad all the way into the SV1. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ~ Casing drift: 9-%", 40# special drift casing is being used (8.835" ID, 8.75" drift). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-3,4" bit (float equipment, casing hanger, etc). ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar should be placed at 1,000-ft MD as a contingency, if hole conditions warrant. ~ Losses during cement job: Lost circulation has been experienced on offset pads while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7-lb/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs: .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" Job 4: Drill 8-3;4" Production Hole Critical Issues: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.8 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Schrader reservoir pressure of 8.8 ppg and 9.3 ppg mud, a 11.8 ppg leak-off will provide 50 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.8 ppg. Based upon off-set drilling data, a minimum leak-off of 13 ppg is expected at the 9-%" shoe. ~ Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for ECDs not to exceed 0.6ppg above calculated. If ECDs are sustained above this threshold, it is V-211 i Permit to Drill Page 8 . . advised that drilling should be stopped and the hole circulated before continuing. ECD should not exceed 11.0 ppg once the M sand has been penetrated. ~ Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Faults: One fault is expected to be crossed at V-211 i. This fault has been intersected by several other wells on V-pad at this depth with out problem. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 (UG1): 5,075' MD 3,769' TVD 3,850' TVDss Throw: 80' SW ~ Screen Blinding: Add BDF-263 as per MI mud program while drilling the Ugnu/heavy oil sands ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the production hole section. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the OBf and OBd sands using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. ~ Directional Constraints: It is important to keep the wellbore smooth and the tangent angle close to plan to facilitate casing running and slickline access. It is important to design a BHA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept as close as possible to ::;10 over planned. Dogleg will take priority over angle as long as mainbore tangent angle does not approach 68 degrees. ~ 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the top OBe marker. After seeing the top OBe, TD will be picked based on drilling 250' MD past this marker. This footage is critical for future well work. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. Reference RPs: .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "ERD Operating Practices" Job 6: Run and Cement 7" Production CasinCl Critical Issues: ~ Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. ~ Cement Job: It is imperative to achieve a good cement job on this well to achieve zonal isolation and effective injection control. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. ~ Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the 7" x 9-%" casing outer annulus with 72 bbls of dead crude (2,570' MD, 2,200'TVD), the hydrostatic pressure will be 8.0 ppg vs. 8.8 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be over 100 psi underbalance to the open hole. ~ Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement V-211 i Permit to Drill Page 9 . . strategy is: o Pip #1: Top Ma Sand o Pip #2: 40-60' above top OA sand ~ Mud Requirements: Thin the mud as per Ml's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. ~ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor before running casing. Reference RPs: .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 7: DPC Peñorate Well Critical Issues: ~ The well will be perforated ±130 psi over-balanced. Ensure all personnel are well briefed on Shlumberger's perforating procedures and that all responsibilities are understood. ~ It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, Schlumberger perforating crew. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. ~ Contact Schlumberger to prepare for approximately 200' of 4-1/2" Power Jet guns at 5 spf to be run on DP. Exact perforation depths will be provided after reviewing the LWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater and brine on location and be prepared with LCM if necessary. Losses are not expected to be severe based on past perforation jobs. It is expected that the formation will take a little drink due to the extra pressure induced by the detonation of the perf guns. ~ It is planned to utilize LWD GR to correlate to the formation and casing RA tags to position the perforation assembly. The GR tool will be placed above the perforating assembly, the assembly is then RIH past the perf depth, the well will be logged up to correlate DP depth, and then the guns can be brought on depth and fired. ~ The LWD GR tool requires a 150-260 gpm flowrate to establish a signal. Modeling indicates a maximum pressure of 2,400 psi will be seen when pumping @ 250 gpm. Reference RPs: .:. "Wireline Pressure Control SOP" .:. "Alaska Wells Group Standard Operating Procedure: Perforating" .:. Follow Schlumberger perforating practices and recommendations Job 8: Run 4-1h" Completion Critical Issues: ~ Barriers: o The well will have the OA, OBa, OBb, OBc, and OBd production intervals open with an 8.6 ppg EMW formation pressure during completion operations. o Completion will be run with BOPs in place and kill weight fluid for annulus side barriers. Tubing side barriers will be provided via TIW and kill weight fluid. V-211 i Permit to Drill Page 10 . . o Once packers are set the annulus above the packer will be tested to 4,000 psi to verify packer/annulus integrity. Kill weight fluid and the tubing hanger provide additional annulus side barriers. At this point the ball and rod with kill weight fluid and a TIW valve comprise the tubing side barriers. o Since it is not feasible to test the lower packer/annulus integrity, when the DCK valve is sheared a casing annulus valve must be in place along with kill weight fluid to provide sufficient annular barriers. Tubing side barriers are still kill weight fluid on ball and rod and a TIW. o A TWC will be installed and tested from above to 1,000 psi for 30 minutes prior to nippling down the BOP's. With the DCK valve sheared the TWC in addition to kill weight fluid provide the tubing side barrier. The annular side barrier is the casing annulus valve and the kill weight fluid. With the TWC in place BOPs can be nippled down and the tree nippled up. o With the tree nippled up freeze protecting removes the kill weight fluid as a barrier. We then count on the tree for tubing side barriers, and two casing annulus valves for annulus side protection. o Before rigging down a BPV tested from below to 1,000 psi will be left in the tubing hanger to provide an additional tubing side barrier once the rig is off. Since the DCK valve is still open it will be necessary to leave one casing annulus valve and a VR plug for annular barriers. Make sure that a lubricator is used to install the VR plug while both casing annulus valves are still in place. ~ Thread Dope: Jet Lube is the BP approved thread compound for Premium Carbon API connections. All TCII pipe should arrive on location with Jet Lube thread compound. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. ~ Torque Turn: Injectors will be used for MI injection and therefore must have all connections torque turned and charted to help reduce risk of leaks. ~ Shear Valve: We will be using a DCK-2 shear valve due to the RP shear valve failure on numerous wells. The DCK-2 shear valve has had good success due to the locking mechanism that keeps the sleeve from migrating back down over the ports after the tool is sheared open. This valve does require a higher differential pressure to open. ~ Injection Mandrels: Remove the check valves from the MMGW waterflood mandrels. This will allow us the flexibility to circulate between mandrels and clean up the tubing/casing annulus later in the well life. Reference RPs: .:. "Completion Design and Running" RP .:. "Tubing Connections" RP Job 9: ND/NU/Release RiQ Critical Issues: ~ See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~ Diesel: 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 RPs: .:. "Freeze Protecting an Inner Annulus" RP V-211 i Permit to Drill Page 11 TREE: FMC A$-1J16u fiM WELLHEAD: ,5M 1 x 1 tiu ( 11» X 4-1116" ~ 9ES RKB= S(Hl 20" X 34" 215.5Ibffl:, A53 ERW inßl.ilaœd 4-1/2" 'X' with 3_813" seal b(m!~, lift mandrel 4-1/2" x 1" Shear Valve pinned to with seal 'PRM' Production Packer TBD amco 3-1/2" x 1-112" MMG-W GLM 3-112" 'X' 2.813" sea! bore. x 3-1/2° Baker 'PRM' Productìon Packer x 1-1/2" MMG-W GLM Perfs: TBD 3-1/2" x 1-1/2" MMG-W GLM TBD with seal bore. Production Packer bp o V-211 P5 Schlumberger RI IOII 0.11: October 18, 2004 Clltnt: BP Exploration Alaska Field: Prudhoe Bay Unlt- WOA SIrucIu.., Slot: V-Pad I Plan V-211 (N-C) IIIIY stu WeI!: Plan V-211 (N-C) F sib 1IorIhoIe: Plan V.211 I... UWIIAPII: 50029 ... Survey ~I 0.11: V-211 (P5) 1 October 18, 2004 TOIt/AHDIDDl/ERD1'1IIo: 48.072" 1 3993.38 ftl 5.414 10.834 GrId CoonIInatI SysWn: NAD27 AIasIæ State Planes, Zone 04, US Feet Loc.IIon L.ItILong: N 70.32792893. W 149.26676892 Loc.IIon GrId HIE YIX: N 5970054.320 flUS, E 590410.000 flUS GrId Con¥IIgIncI Angle: ..0.69044014· GrId ScalI FICtor: 0.99990929 Proposal Survey I DI.S CcImpuIMIon .....od: Minimum Curvalule 1 Lublnsld VtItIcII SIctIon AzImutII: 320.380· VeItICII SIctIon OrIgIn: N 0.000 It, E 0.000 ft 1VD ~ Dllum: Rotary Table 1VD R""-e EIIvaIIon: 80.90 It reIaIIve to MSL Sea BId I Graund LIVII EIIvaIIon: 52.40 It reIaIIve to MSL IIIgneIIc DIcInIIIon: 24.706· Tala! FIIId.........: 57595.932 nT IIIgneIIc DIp: 80.799· DIc:IInaIIon 0.11: November 20. 2004 IIIgneIIc DIcIInIIIon 1IodII: BOOM 2004 NoIth Relllwlce: True North Tala! CoII'.... North -> True North: +24.706" LocII CoonIn.... RIIwwnced To: WeN Head . 700.00 10.50 320.09 617.14 696.04 32.63 32.63 24.90 -21.09 3.00 0.37G 3.00 0.15 5970076.96 590388.61 N 70.32799694 W 149.26693994 600.00 13.50 320.17 714.94 795.84 53.41 53.42 40.85 -34.41 3.00 0.000 3.00 0.08 5970094.75 590375.10 N 70.32804053 W 149.26704799 900.00 16.50 320.23 811.53 892.43 79.29 79.29 60.73 -50.98 3.00 0.000 3.00 0.05 5970114.43 590358.30 N 70.32809484 W 149.26718231 966.56 18.50 320.25 875.00 955.90 99.30 99.30 76.11 -63.78 3.00 0.000 3.00 0.04 5970129.65 590345. 32 N 70.32813687 W 149.26728609 1000.00 19.50 320.26 906.62 987.52 110.19 110.19 84.48 -70.74 3.00 0.000 3.00 0.03 5970137.94 590338.26 N 70.32815973 W 149.26734253 1100.00 22.50 320.29 999.97 1080.87 146.02 146.02 112.04 -93.63 /3.00 O.ooG 3.00 0.03 5970165.22 590315.03 N 70.32823502 W 149.26752822 1200.00 25.50 320.31 1091.31 1172.21 186.68 186.69 143.33 -119.61 3.00 O.ooG 3.00 0.02 5970196.19 590288.68 N 70.32832050 W 149.2677. 1300.00 28.50 320.33 1180.41 1261.31 232.07 232.08 178.27 -148.59 3.00 0.000 3.00 0.02 5970230.77 590259.29 N 70.32841594 W 149.2679 1400.00 31.50 320.34 1267.00 1347.90 282.07 282.07 216.75 -180.50 3.00 0.000 3.00 0,01 5970268.86 590226.92 N 70.32852107 W 149.26823 1500.00 34.50 320.36 1350.86 1431.76 336.52 338.53 258,68 -215.25 3.00 0.000 3.00 0.01 5970310.36 590191.67 N 70.32863561 W 149.26851445 1800.00 37.50 320.37 1431.75 1512.65 395.29 395.29 303.94 -252.74 3.00 0.000 3.00 0.01 5970355.16 590153.84 N 70.32875925 W 149.26881850 1700.00 40.50 320.37 1509.46 1590.36 458.21 458.22 352.40 -292.88 3.00 0,000 3.00 0.01 5970403.13 590112.93 N 70.32889164 W 149.26914398 1727.18 41.31 320.38 1530.00 1610.90 476.01 476.01 366. 11 -304.22 3.00 O.OOG 3.00 0.01 5970416,70 590101.41 N 70.32892908 W 149.26923802 1800.00 43.50 320.38 1583.77 1684.67 525,12 525.12 403.93 -335.54 3.00 O.ooG 3.00 0.01 5970454.14 590069.65 N 70.32903242 W 149.26948999 1900.00 46.50 320.39 1654.47 1735.37 595.82 595.82 458.40 -380.62 3.00 0.000 3.00 0.01 5970508,08 590023.92 N 70.32918120 W 149.26985559 1900.77 46.52 320.39 1655.00 1735.90 596.37 596.38 458.83 -380.98 3.00 O.OOG 3.00 0.01 5970508.48 590023.56 N 70.32918238 W 149.26985847 1952.40 48.07 320.39 1690.02 1770.92 634.32 634.32 488.06 -405.17 3.00 O.ooG 3.00 0.01 5970537.41 589999.02 N 70.32926223 W 149.27005485 1967.34 48.07 320.39 1700.00 1780.90 645.43 645.44 496. 62 -412.25 0.00 O.OOG 0.00 0.00 5970545.89 589991.83 N 70.32928562 W 149.27011212 2476.16 48.07 320.39 2040.00 2120.90 1023.98 1023.98 788.26 -653.58 0.00 O.OOG 0.00 0.00 5970834.58 589747.03 N 70.33008232 W 149.27206941 2738,05 48.07 320.39 2215.00 2295.90 1218.81 1218.82 938.37 -777.80 0.00 O.OOG 0.00 0.00 5970983.17 589621.03 N 70.33049237 W 149.27307691 CœIIIIIIII RTE KOP BId 1.5/100 Bid 3/100 SV6 SV5 SV4 End Bid Base Perm SV3 SV2 WellDeslgn Ver 3.1 RT -SP3.03-HF5.oo BId( do31rt-546 ) Plan V-211 (N-C)\PIan V-211 (N-C)\Plan V-211\V-211 (P5) Generated 1011912004 8:20 þJoA Page 1 of 2 ComInIntI SV1 9-518" Csg PI UG4 UG4A UG3 UG1 4848.15 48. 07 320.39 3625.00 3705.90 2788.66 2788.66 2147.83 -1778.61 0.00 0.000 0.00 0.00 5972180.37 588605.81 N 70.33379605 W 149.28119589 Ma 5252.21 48.07 320.39 3895.00 3975.90 3089.27 3089.27 2379.43 -1970.25 0.00 0.000 0.00 0.00 5972409.62 588411.40 N 70.33442862 W 149.28275089 Mb1 5319.55 48.07 320.39 3940.00 4020.90 3139.37 3139.37 2418.03 -2002.19 0.00 O.CIOG 0.00 0.00 5972447.83 588379.00 N 70.33453405 W 149.28301006 Mb2 5409.34 48.07 320.39 4000.00 4080.90 3206.17 3206.18 2469.50 -2044.78 0.00 O.CIOG 0.00 0.00 5972498.77 588335.80 N 70.33467462 W 149.28335564 Me 5521.58 48. 07 320.39 4075.00 4155.90 3289.67 3289.68 2533.83 -2098.01 0.00 O.CIOG 0.00 0.00 5972562.45 588281.80 N 70.33485033 W 149.2837_ Na 5611.37 48.07 320.39 4135.00 4215.90 3356.48 3356.48 2585.30 -2140.60 0.00 O.CIOG 0.00 0.00 5972613.40 588238.60 N 70.33499090 W 149.2841 Nb 5641.30 48.07 320.39 4155.00 4235.90 3378.74 3378.75 2602.45 -2154.80 0.00 O.CIOG 0.00 0.00 5972630.38 588224.20 N 70.33503776 W 149.28424838 He 5701.17 48.07 320.39 4195.00 4275.90 3423.28 3423.28 2636.76 -2183.19 0.00 O.CIOG 0.00 0.00 5972664.34 588195.40 N 70.33513147 W 149.28447878 OA 5843.32 48.07 320.39 4289.99 4370.89 3529.04 3529.04 2718.24 -2250.61 0.00 O.CIOG 0.00 0.00 5972744.99 588127.01 N 70.33535401 W 149.28502591 V-211 Target 5843.33 48.07 320.39 4290.00 4370.90 3529.05 3529.05 2718.25 -2250.62 0.00 0.000 0.00 0.00 5972745.00 588127.00 N 70.33535403 W 149.28502597 OBa 5933.13 48.07 320.39 4350.00 4430.90 3595.85 3595.85 2769.72 -2293.21 0.00 O.CIOG 0.00 0.00 5972795.95 588083.80 N 70.33549460 W 149.28537157 08b 5985.50 48.07 320.39 4385.00 4465.90 3634.82 3634.82 2799.74 -2318.05 0.00 O.CIOG 0.00 0.00 5972825.67 588058.60 N 70.33557660 W 149.28557317 OBc 6067.81 48.07 320.39 4440.00 4520.90 3696.05 3696.06 2846.92 -2357.09 0.00 O.CIOG 0.00 0.00 5972872.36 588019.00 N 70.33570545 W 149.28588997 OBd 6135.16 48.07 320.39 4485.00 4565.90 3746.15 3746.16 2885.52 -2389.03 0.00 O.CIOG 0.00 0.00 5972910.57 587986.60 N 70.33581087 W 149.28614918 6217.47 48.07 320.39 4540.00 4620.90 3807.39 3807.39 2932.69 -2428.07 0.00 0.000 0.00 0.00 5972957.27 587947.00 N 70.33593972 W 149.28646599 0Ba 6217.48 48.07 320.39 4540.01 4620.91 3807.40 3807.40 2932.70 -2428.08 0.00 O.CIOG 0.00 0.00 5972957.28 587946.99 N 70.33593975 W 149.28646605 OBf 6277.33 48.07 320.39 4580.00 4660.90 3851.92 3851.93 2967.00 -2456.46 0.00 O.CIOG 0.00 0.00 5972991.24 587918.20 N 70.33603343 W 149.28669641 OS, Base 6344.67 48.07 320.39 4625.00 4705.90 3902.02 3902.03 3005.60 -2488.40 0.00 O.CIOG 0.00 0.00 5973029.44 587885.80 N 70.33613885 W 149.28895562 TD/7" Csg 6467.47 '-/48.07 320.39 4707.05 4787.95 3993.38 3993.38 3075.99 -2546.64 0.00 O.ooG 0.00 0.00 5973099.11 587826.72 N 70.33833108 W 149.28742829 Lea" Desc:rtDtlon: NOIthtna M ntUS1 Eatlna 00 IftUS1 Surface 4808 F5L 1891 FEL 511 T11N R11E UM 5970054.32 590410.00 V-211 Target 2246 F5L 4139 FEL 52 T11N R11E UM 5972745.00 588127.00 BHL 2604 F5L 4435 FEL 52 T11N R11E UM 5973099.11 587826.72 e WeUDesign Ver 3.1 RT -SP3.03-HF5.oo BId( cIo31rt-546 ) Plan V-211 (N-C)\Plan V-211 (N-C)\Plan V-211\V-211 (P5) Generated 1011912004 8:20 AM Page 2 of 2 V·211 {P5} BOOM 2004 u (/.! ;¡¡ (,) (J) §! 3200 I- 4000 4800 5600 DIp; 6(1100' M¡:¡g 000; +2UOO' Prudhoe Bay Unit· WOA - "", o 800 1600 2400 3200 4000 o o 800 1800 2400 5600 o 800 1600 2400 3200 Vertical Section (ft) Azim = 320.38°, Scale = 1(in):800(ft) Origin = 0 1'4/-8, 0 e/-w 4000 V-211 (P5) f1EU) Prudhoe Bay Unit - WOA StIffl:aceloeøfut¡ 00,700" Date: Novémtw20.2004 lat Nro194b.544 .¡.24-]OO~ FS; :57005J1nT too: W1491fHJ.3E\ß -2500 -2000 -1500 -1000 3000 2500 2000 ^ ^ ^ Z -500 o 3000 2500 2000 1500 II ø ~ (f) (f) v v v 1000 1000 500 o -2500 -2000 -1500 .1000 «< W Scale = 1(in):5OO(ft) E »> 500 o -500 o . Compaoy: BP Amoco Date: 1011912004 11me: 08:31:17 hP: t Fiekt: Prudhoe Bay Refereoee Site: PB V Pad Co-enØoate(NE)Rerereøee; Well: PlanV"2t1(/II.C).r,,-~ Refereoee WeD: Plan V"211 (N-C) V~ (TVD) Refereoee: V-211 PlanN-C .80.9 Refereoee WeUpatll: Plan V-211 ØJt:·.·.···SJbase NO GLOBAL SCAN: Usiog user defilled seleetioo &: sean criteria Refereoee: Principal Plan & PLANNED PROGRAM loterpolatioo Method: MD loterv": 50.00 ft Error Model: ISCWSA Ellipse Depth Raoge: 28.50 to 6467.47 ft Seao Method: Trav Cylinder North Maximum Radios: 1??oo.00 ft Error Surface: Ellipse + Casing Survey Program for Defioitive WeUpath Date: 8/19/2002 vaUdated: No Venloo: 3 Plaooed From To Survey TooIeode Tool Name ft ft 28.50 1400.00 Planned; Plan #5 V1 MWD MWD - Standard 28.50 6467.47 Planned: Plan #5 V1 MWD+IFR+MS MWD + IFR + Multi Station Casiog Pomts MD 1VD Diameter Bole SIze Name ft ft in in 3344.14 2700.90 9.625 12.250 9 5/8" 6467.47 4787.96 7.000 8.750 7" Summary -< Offset WeUpath > Refereaee· ...Oft'set etr-etr. . No-Go ~ Site Well WeUpath MD MD ~..·Atea DêvfaticNr W~ ft ft ft ft ft EX WKUPST-01 WKUPST -01 WKUPST -01 V1 6437.79 3400.00 2776.46 0.00 2776.46 Pass; Minor 11200 PB V Pad Plan V-112 (5oA) Plan V-112 V1 Plan: PI 346.62 350.00 182.99 6.40 176.59 Pass; Major Risk PB V Pad Plan V-203 (N-A) Plan V-203 VO Plan: V 600.38 600.00 32.60 12.15 20.45 Pass; Major RIsk PB V Pad Plan V-205 (5oP) Plan V-205 V2 Plan: PI 345.21 350.00 296.57 6.43 290.14 Pass; Major Ris~ PB V Pad Plan V-206 (50S) Plan V-206 V1 Plan: PI 344.98 350.00 333.48 6.43 327.05 Pass: Major Risk PB V Pad Plan V-210 (N-G) Plan V-210 V5 Plan; PI 399.06 400.00 60.92 6.88 54.05 Pass: Major RIsk PB V Pad Plan V-212 (S-D) Plan V-212 VO Plan: V 394.76 400.00 181.72 8.54 173.19 Pass: Major Risk PB V Pad Plan V-214 (N-R) Plan V-214 V3 Plan: V 395.73 400.00 265.74 7.99 257.76 Pass; Major Risk PB V Pad Plan V-2a06 (N-M) Plan V-2a06 VO Plan; V 444.67 450.00 191.16 9.39 181.77 Pass; Major Risk PB V Pad Plan V-3a06 (5oU) Plan V-3a06 V1 Plan: P 345.29 350.00 359.00 7.56 351.43 Pass: Major Risk PB V Pad V-01 V-01 V15 298.39 300.00 274.00 5.18 268.81 Pass: Major RIsk PB V Pad V-02 V-02 V12 447.06 450.00 88.23 7.46 78.78 Pass: Major RIsk PB V Pad V-03 V-03 V7 346.93 350.00 342.37 5.35 337.02 Pass: Major Risk PB V Pad V-1oo V-1oo V7 343.71 350.00 372.30 5.66 366.64 Pass: Major Risk PB V Pad V-101 V-101 V7 398.37 400.00 18.66 6.51 12.16 Pass: Major RIsk PB V Pad V-102 V-102 V5 445.48 450.00 137.71 8.43 129.29 Pass: Major RIsk PB V Pad V-103 V-103 V6 395.17 400.00 281.63 6.61 275.02 Pass: Major RIsk PB V Pad V-104 V-104 V13 495.97 500.00 75.76 7.89 67.87 Pass; Major RIsk PB V Pad V-105 V-105 V13 396.07 400.00 205.71 6.45 199.25 Pass: Major Risk PB V Pad V-106 Plan V-106A V6 Plan: P 248.09 250.00 251.03 4.46 246.57 Pass: Major RIsk PB V Pad V-106 Plan V-106APB1 V4 Plan 248.09 250.00 251.03 4.46 246.57 Pass: Major Risk PB V Pad V-106 V-106 V10 248.09 250.00 251.03 4.12 246.90 Pass: Major RIsk PB V Pad V-107 V-107 V5 348.04 350.00 105.70 5.13 100.57 Pass: Major Risk PB V Pad V-108 V-108 V7 549.30 550.00 21.07 9.24 11.83 Pass: Major Risk PB V Pad V-109 V-109 V2 395.28 400.00 183.12 6.64 176.48 Pass: Major RIsk PB V Pad V-109 V-109PB1 V5 395.28 400.00 183.12 6.64 176.48 Pass: Major RIsk PB V Pad V-109 V-109PB2 V2 395.28 400.00 183.12 6.64 176.48 Pass: Major Risk PB V Pad V-111 V-111 V25 347.26 350.00 313.43 6.29 307.14 Pass: Major RIsk PB V Pad V-111 V-111PB1 V8 347.26 350.00 313.43 6.29 307.14 Pass: Major Risk PB V Pad V-111 V-111PB2V2 347.26 350.00 313.43 6.29 307.14 Pass: Major RIsk PB V Pad V-111 V-111PB3 V6 347.26 350.00 313.43 6.29 307.14 Pass: Major Risk PB V Pad V-113 V-113 V6 346.95 350.00 179.84 5.22 174.62 Pass: Major RIsk PB V Pad V-114 V-114 V5 299.09 300.00 191.53 4.94 188.59 Pass: Major Risk PB V Pad V-114 V-114A V4 299.09 300.00 191.53 4.94 186.59 Pass: Major Risk PB V Pad V-114 V-114APB1 V4 299.09 300.00 191.53 4.94 186.59 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 299.09 300.00 191.53 4.94 186.59 Pass: Major Risk PB V Pad V-115 V-115 V5 297.89 300.00 399.65 4.89 394.76 Pass: Major RIsk PB V Pad V-115 V-115PB1 V4 297.89 300.00 399.65 4.89 394.76 Pass: Major Risk PB V Pad V-117 V-117V9 343.68 350.00 346.05 5.83 340.22 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 343.68 350.00 346.05 5.83 340.22 Pass: Major RIsk PB V Pad V-117 V-117PB2 V6 343.68 350.00 346.05 5.83 340.22 Pass: Major Risk PB V Pad V-119 V-119V13 394.74 400.00 185.62 6.75 178.88 Pass: Major Risk PB V Pad V-120 V-120 V5 298.78 300.00 355.12 5.21 349.91 Pass: Major RIsk Schlumberger Anticollision Report . . . Schlumberger Anticollision Report Company: BP Amoco Daæ: 10119/2004 TIme: 08:31:17 hF 2 Field: Prudhoe Bay Refereace Site: PB V Pad c-nu.ate(NE)~: Well: Plan V·2H (~), TrueNorlh Refereuce WeD: Plan V·211 (N..c) VerdaI ('l'VD)Ret'ereøce: V·211 PlanN..c 80.9 Reference Wellpath: Plan V·211 DJ,J:SyÞâ$e Summary -< Offset Wellpath > Ret'ereøce Offset Ctr..Qr No.Go Allowable Site WeD Wellpath MD MD Distaaeè Area om.tioII W.~ ft ft ft it ft PB V Pad V-201 V-201 V8 831.83 850.00 125.28 14.24 111.05 Pass: Major Risk PB V Pad V-202 V-202 V9 397.95 400.00 45.98 6.94 39.04 Pass: Major Risk PB V Pad V-202 V-202L 1 V5 397.95 400.00 45.98 6.90 39.08 Pass: Major Risk PB V Pad V-202 V-202L2 V5 397.95 400.00 45.98 6.90 39.08 Pass: Major Risk PB V Pad V-204 V-204 V2 576.44 600.00 177.68 9.92 167.75 Pass: Major Risk PB V Pad V-204 V-204L 1 V2 576.44 600.00 177.68 9.92 167.75 Pass: Major Risk PB V Pad V-204 V-204L 1PB1 V6 576.44 600.00 177.68 9.92 167.75 Pass: Major Risk PB V Pad V-204 V-204L2 V2 576.44 600.00 177.68 9.92 167.75 Pass: Major Risk PB V Pad V-204 V-204L2PB1 V5 576.44 600.00 177.68 9.92 167.75 Pass: Major Risk PB V Pad V-204 V-204L3 V3 576.44 600.00 177.68 9.92 167.75 Pass: Major Risk PB V Pad V-204 V-204PB1 V9 576.44 600.00 177.68 9.92 167.75 Pass: Major Risk PB V Pad V-204 V-204PB2 V2 576.44 600.00 177.68 9.92 167.75 Pass: Major Risk PB V Pad V-213 V-213 V5 520.38 550.00 380.32 9.35 370.97 Pass: Major Risk PB V Pad V-213 V-213PB1 V5 520.38 550.00 380.32 9.35 370.97 Pass: Major Risk PB V Pad V-216 V-216 V8 249.27 250.00 297.09 4.47 292.62 Pass: Major Risk 94 zoo 100 100 200 94 Field: Prudhoe Bay Site: PB V Pad Well: Plan V-211 (N-C) Well path: Plan V-211 27 V-103 (V-103) Plan V-2a06 (N-M) (Plan V-2o(6) V.IOA (fII¡f()J'¡-I06AJ'Bl) S V-106 (V-I (6) 8 Plan V-214 (N-R) (Plan V-ZI4) V-IOS (V-IOS) 8 Plan V-203 (N-A)"'_~) Plan V-iiitS-A) (Plan V-I 12j80 Travelling Cylinder Azimuth (TFO+AZI) (deS) vs Centre to Centre Separation [IOOftIin) Site: PB V Pad . Drilling Target Conf.: 95% Description: Map Northing: 5972745.00 ft Map Basting: 588127.00 ft Latitude: 70020'07.274N Shape: Circle Target: V-211 OA Tgt 1 . Well: Plan V-211 (N-C),V-03 Based on: Planned Program Vertical Depth: 4290.00 ft below Mean Sea Level Local +N/-S: 2718.24 ft Local +E/-W: -2250.61 ft Longitude: 149°17'06.093W Radius: 150 ft 3100 3000 2900 2800 2100 2500 2500 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 o 0 ~ -+ (Y) N C) () o 0 J ) N N N N N I I , , I o ~ J ^' J r.:.----------. --- . 1 J E 5,172 I I I I I I I I I I I I I 1 I I I I Ig I') I~ Iz I I \ I I I I I I I I I I I GRiD 75'00'00"( PLANT · V-118 · V-03 · V-110 · V-111 · V-103 · V-106 · V-105i · SLOT N-M · V-102 · V-201 · V-107 ¡. ~=~ð4i V-210i V-202 V-SPARE (SLOT N-E) V-101 . V-211i / V-10B V-203 I I I I I I I I I I I I , I I 1 I I I I · V-SPARE (SlOT 5-L) I I 01 121 .,;, z¡ I I I I 1 , I l \ " --------- I ~Z- I · V-115 · V-213i · V-100 · V-117 · SLOT S-R · V-01 · SLOT S-J · V-204 · V-114 · V-119 · V-109 · V-113 v-p AD ,.0 sPINE RO....D NOTES 1. DATE OF SURVEY: JULY 17 & 18, 2004. 2. REFERENCE FIELD BOOK: W004-11 PGS. 19-26. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPElINE CONTROL. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. --- VICINITY MAP N.T.S. LEGEND -+- AS-BUILT CONDUCTOR . EXISTING CONDUCTOR -- SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 18, 2004. LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.s.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINA TES COORDINA TES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS V-203 Y=5,970,046.49 N=10,180.05 70'19'40.471" 70.32799086' 527' 4,801' FSL X= 590,380.87 E= 4,629.84 149'16'01.221" 149.2670058' . 1,920' FEL V-210i Y=5,970,069.62 N=10,179.79 70'19'40.688" 70.3279689' 52.6' 4,823' FSL X= 590,468.21 [::: 4,720.20 149'15'58.663" 149.2662953' 1,833' FEL V-211i Y:::5,970,054.32 N:::10,180.08 70'19'40.544" 70.3279289' 52.4' 4,809' FSL X= 590,410.00 E::: 4,660.00 149'16'00.368" 149.2667689' 1,891' FEL y=5,970,061.76 N=10,179.73 70'19'40.614" 70.3279483' 53.1' 4,816' FSL X::: 590,439.13 E= 4,690.07 149'15'59.515" 149.2665319' 1,862' FEL R£VISlON ~, i tlJgs~Q KIM! MLO 8Y QIK EffQffŒRS",., LMIIO SUM:YQItS eDI II(n ntCI'ŒP LNC ~~ ÞUSf,A Ø5Ø3 DRA1M'-I; HACKLEMAN CHECKED: ONEIL DATE: 7 22/04 ORÂ'MNG: FRB04 WOV 07-00 JOB NO: SCALE: 1'·150' ObP GREATER PRUDHOE BAY V-PAD AS-BUlL T WELL CONDUCTORS V-203, V-210i, V-211i and V-SPARE (SLOT N-E) SHEET: 1 Of 1 e f . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ./ð 0 v 1/-2-// PTD# ;?C) '1- 2 ;>ð Development X Service . CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two. (2) digits are between 60-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new weJlboresegment of nisting wen , Permit No, API No. . Production. sbould continue to be reponed as a function' of tbe original API Dumber. stated above. .. HOLE 10 accordance with' 20 AAC 25.005(1), an records, data and logs acquired .for tbe pilot bole must be dearly differentiated ID botb name (name on permit plus PH) .' and API :Dum ber (SO - 70/80) from records, data and logs acquiTed for we)) (name on penn it). PJLOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE .' Tbe permit is appToved subject ·to full . compliance with 20 AAC 25..0SS~ Approval 10 perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:Jcep1ion. (Company Name) assumes tbe Jiability of any protest to tbe spacing .exception that may occur. AlJ dry ditcb sampJe sets submitted to tbe Commission must be in no greater tban 30' sample intervals from beJow tbe permafrost or from wbere sampJes are fint caught aDd ] 0' sampJe inter-vals tbrough target zones. .' Field & Pool PRUDHOE SAY, ORION SCHR SL OIL - 640135 Well Name: PRUDHOE SAY UN ORIN V-211 Program SER Well bore seg 0 XPLORATION (ALASKA) INC Initial ClassfType SER 11WINJ GeoArea Unit _ On/Off Shore On Annular Disposal 0 Administration .Permit fee attache.d. . . - - - - - Y~s 2 .Leas~ .number .appropriate. . . Y~s 3 .U.nlq!Je well.nam~.and oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . ... .Y~s - - - - . - - - . - -. - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- . - - - - - 4 WellJQcat~d in.a. d.efine.dpool . . . Y~s . - - - - 5 WellJQcat~d pr.oper .distance. from driJling unitb.oundary · Y~s - - - - - 6 WellJQcat~d proper .distance. from Qtber wells. Y~s . . . Then~arest.Qrioo PooJ well prod.uctive jntEHvaJ i$ .over .a.1[4 rnileaway.QriolJ Pool spacing is 20 ac. .RP.C. 7 .S.utficientacreageavailable in.drilliog unjt . . · . .Y~s 8 Jf.d~viated, js. weJlbore platincJuded . Y.es 9 OJ)er.ator only: aftected party. . . Y~s 10 .OJ)er.ator bas.appr.opriate.Q.ond in.force . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~$ - - - - - - . - - - - ~ - - - - - - - - - - - - - 11 P~rmit C.ao be issued wrtbout co.nservation order. . . Y~s - - - -- Appr Date 12 P~rmit C.ao be iS$ued witbout ad.ministratil¡e. aJ)provaJ . . · Y~s . RPC 10/26/2004 13 Can permit be approved before 15-day wait Yes 14 WeJlJocated within area and.strata .authorized by lojectiolJ Ord~r # (put 10# in.comm~ots). (For. Y~s 810.24.... . 15 .AJlwells.withi!1.1[4.mile.area.ofreyiewid~otlfjeQ(For.se!'Vj~.w.ell only). .............. Y~s . . . . . !\.lone. . . . . . . . . . . . . . . . . 16 Pre-produced. injector; duratio.n.of pre-production I~ss than. 3 months. (For service well onJy) . . .NA - - - - - - - - 17 .ACMP. finding .of ConsisteoGyhas been Issued for tbis proiect . NA - - - - - Engineering 18 .C.ooductor string.prQvided . . . . Y~s . . 20" @ 1 Q9'. . 19 .Sw:face .ca$ing. protect!i all known. USQWs . · Y~s 20 .CMT v.ol adequ.ate.to circulate on .conductor. & su.rf CJ>g . Y~s 8deJ: uate exce$S, . 21 .CMT v.ol adequate to tie-in JQngstring to.surf C$g. . . No. - - -- 22 CMTwill Gover.aJl /<rJownpro.ductive bQrizon.s . - - - - - · . Y~s 23 C.asiog desigos ad.eQua.te for C,.T~ B.&.p.ermafrost . · . .Y~s 24 .Adequatetankage.oJ re.seIYe pit. . Y~s !\.Iabors.9ES, 25 Jf.a.re-drilL has.a 1,0-403 for abandonment be~o apprQved . . NA .!\.Iewwelt. 26 .Adequate.weJlbore sepªratjo.nJ)roposed. . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s - - - - - - - - - - - - - - - - - - - - - - - - - 27 Jf.diverter required, dQes jt meet reguJations. . · . .Yes - - - - - - - - - Appr Date 28 .Drilliog fluid. p.rogram schematic.& eq.uip Jistadequate. . . . Yes · Max MW.9~6 ppg.. . . WGA 10/27/2004 29 .SOPEs,.d.o they meet reguJatiol) . . Yes 30 .SOPE.press ra.tiog appropriate; .test to (put psig i.ncomments) . . . · . Y~s · Test to40QO.psi. .MSF> 1586 psi. 31 Choke. manifold cQmp.lies wlAPI RF>-53 (May 64) Y~s 32 Work will oçCur withput.operationshutdown. . .Y~s - - - - - 33 .1$ pre$ence. Qf H2S gas. proQ.able. . . . . N.o. · !\.Iotan H2S pad.. . 34 Meçhanical.COl)dJlioo .ot wells withil) 80R verified. (For. service welJ on.ly). . Y~s !\.Io wells witbio AOR.. Geology 35 Permit c.al1 be issued wlo hydrogen s.ulfide meas.ures. . · Y~s 36 .D.atapreseoted on. pote.ntia' pverpre!isurezOl)es. . . . - - - - NA Appr Date 37 .Seismic.analysJs. Qf sballow gaszooes. NA RPC 10/26/2004 38 S~abedcOl)ditipo survey (if oft-shore) . . NA - - - - - - - - 39 . CQnta.ct l)ame[phoneJor.weekly progre$sreports [exploratoryonlYl . . · .NA. - - Geologic Date: Engineering Public Commissioner: Commissioner Date Commissioner Date 'Þ\~ I() 1<'71<1- /0/8/ /'ð;c
