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Home My WebLink About204-235MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, April 4, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Y-03A PRUDHOE BAY UNIT Y-03A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/04/2024 Y-03A 50-029-20411-01-00 204-235-0 W SPT 8676 2042350 2169 593 596 596 598 63 249 263 268 4YRTST P Bob Noble 2/11/2024 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 UNIT Y-03A Inspection Date: Tubing OA Packer Depth 151 2414 2370 2357IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240212152815 BBL Pumped:5.3 BBL Returned:5 Thursday, April 4, 2024 Page 1 of 1           MEMORANDUM TO: Jim Regg 1e P.I. Supervisor I j FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March 9, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. Y -03A PRUDHOE BAY UNIT Y -03A Sre: Inspector Reviewed Bj1- P.1. Supry lific— Comm Well Name PRUDHOE BAY UNIT Y -03A API Well Number 50-029-20411-01-00 Inspector Name: Jeff Jones Permit Number: 204-235-0 Inspection Date: 2111/2020 Insp Num: mitJJ200228112909 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Y -03A Type Inj w - TVD 8676 - Tubing 704 705 704 706 PTD 2042350 - Type Test SPT Test psi 2169 IA ss 2407 - 2372 - 2360 BBL Pumped: 6 BBL Returned: 4.7 OA 50 239 262 278 Interval 4YRTST P/F P Notes: I well inspected, no exceptions noted. ' Monday, March 9, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Re DATE: Tuesday,March 08,2016 P.I.Supervisor 7 . (/c" SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. Y-03A FROM: Brian Bixby PRUDHOE BAY UNIT Y-03A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Y-03A API Well Number 50-029-20411-01-00 Inspector Name: Brian Bixby Permit Number: 204-235-0 Inspection Date: 2/18/2016 Insp Num: mitBDB160218173702 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We11 Y-03A Type Inj Wr TVD 8676 Tubing 894 - 883 877 - 881 - PTD 2042350 - Type Test SPT Test psi 2169 IA 3 2531 - 2481 - 2475 " Intervall0T11ER P/F P ✓ OA 12 88 - 106 - 111 - Notes: Post tubing patch. - SCANNED SEP 2 6 2016 Tuesday,March 08,2016 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,February 19,2016 TO: Jim Reggoec l�1( SUBJECT: Mechanical Integrity Tests P.I.Supervisor BP EXPLORATION(ALASKA)INC. Y-03A FROM: Brian Bixby PRUDHOE BAY UNIT Y-03A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T . NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Y-03A API Well Number 50-029-20411-01-00 Inspector Name: Brian Bixby Permit Number: 204-235-0 Inspection Date: 2/18/2016 Insp Num: mitBDB160218173702 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Y-03A ' TType Inj W TVD l 5676 Tubing 1 894 883 - 877 -( 881 PTD 2042350 Type Test SPT Test psi 2169 IA 3 2531 2481 " 2475 _l Interval IINITAL P/F P OA 12 88 106 _ 111 - Notes: SCANNED SEP 2 6 2016 Friday,February 19,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, February 18, 2016 7:46 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad VP; Odom, Kristine; 'chris.wallace®alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric;AK, OPS PCC Ops Lead; Regg, James B (DOA) Subject: OPERABLE:Y-03A (PTD #2042350) AOGCC MIT-IA Passed Post Patch Set Attachments: Y-03A Wellbore Schematic.pdf All, Injector Y-03A (PTD#2042350) passed an AOGCC witnessed MIT-IA to 2500 psi on February 18, 2016. This passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Kevin Parks trOSEDN'l/ Y 1 9 2.016 (Alternate: Whitney Pettus) BP Alaska-Giv Well Integrity Coordinator Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, January 30, 2016 11:41 PM To: AK, OPS GELRSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Rya ; A D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells OK-Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK,`D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'Regg, James B (DOA)'; AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION: Y-03A (PTD #204235) All, WAG Injector Y-03A (PTD#2042350) recently had wellwork performed to remediate annular communication.This was done by setting a patch from 2,235'-2,266'MD. A subsequent passing MIT-IA to 2,500 psi on January 26, 2016, demonstrated competent barriers downhole.At this time, the well has been reclassified as Under Evaluation to facilitate regulatory compliance testing. Please use care bringing the well online as the annuli are fluid packed and susceptible to fluid expansion. 1 STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMM. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Q Re-enter Susp Well 0 Other:Set Tubing Patch II 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-235 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20411-01-00 7. Property Designation(Lease Number): ADL 0028287 8. Well Name and Number: PBU Y-03A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: IV E D 12725 7, Total Depth: measured feet Plugs measured feet true vertical 8997 feet Junk measured feet FEB 12 2016 Effective Depth: measured 12641 feet Packer measured 9040 feet true vertical 8992 feet Packer true vertical 8676.71 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 32-112 32-112 0 0 Surface 2656 13-3/8"72#L-80 32-2687 32-2687 4930 2670 Intermediate 8154 9-5/8"47#L-80 30-8184 30-7939 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11920-11 950 feet 11920-11950 feet 12020-12050 feet 12210-12240 feet 12420-12600 feet 12610-12630 feet True vertical depth: 8926-8929 feet 8926-8929 feet 8936-8939 feet 8956-8959 feet 8977-8990 feet 8990-8992 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 28-9097 28-8717 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): � 8 ;t CANt4E,P , ,r. it' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1488 760 625 Subsequent to operation: 1232 300 787 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service RI Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG m 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: 315-726 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature $perYr„ 6.2 - Phone +1 907 564 4424 Date 2/12/16 Form 10-404 Revised 5/2015.___ L 2114? /l f- RBDMS LA- FEB 1 2 2016 Submit Original Only 4off /6 • • m Q 0000-0 ca 18 Cr. 0.0 — Cflto LO N Cf) I— U 1) 0 0 0 0 0 L CO f', Cr CY) CY) • CA CO N V •cf' CO CO N- co CO N co CY) N (A r CO 0) CO CA f-- CN —N f— CO CO CO at > C3) CO N N O I- CO CO CO CY) I- N- N I— 00 NrOE N 00 00 0) O N O N 00 0) 0) CtS c� o 1 1 1 i 1 Q Q CN NN O N 0) co _ • (Y) c) co O O N � CO 0) M CO O O co O 00 00 = J � � *kk W cY) N *k J CO CO •N N x _� O O (b N _ _ U N N CS)O LC) LU N CO N- C CO O '— N CO O J N CO CO O) W O' ~ a)O • W ' U U D L Z ZUJUJLUE ODD 0 Cn Z J J • • Packers and SSV's Attachment PBU Y-03A SW Name Type MD TVD Depscription • Y-03A PACKER 8035.82 7790.76 7" Baker ZXP Top Packer Y-03A TBG PACKER 9040.42 8676.71 4-1/2" Baker S-3 Perm Packer Y-03A PACKER 9103.32 8721.74 5" Baker ZXP Top Packer • • N C ' OU) (f) - II a)0 ch O a) 7 0 0 N Z iii a) rn E ° _. _c a) z 2 0 n Q Q Q 0 co m 0 W OCO -t b .p 0 to .� r- C (6 . 0 CO H 1..i_ u) Z O N Q II p N N O . N = ,- z m O - oo 'o in fn C) ~ W 0- O 0 • 0 z 3 ) E H. k \ � I 1 = ° ^ < U % ± .g § ri• / k f Cl) 2 £ , = o E � � / \ oU ; \ / / G > \ k ° ° � 0) < § W , \ \ = / - \ co 7 \ / / / / t �� \ i ® . 0 \E E : _ % 7 _ ) _ (7) o ± ® _ Co E / 0_ o_ o a E O $ C H a a 2 ƒ 7\ . E e. 0 0 = $ m e E' � e� CES c CD 0. / E S / 0 $ \ a ( I- _r© E o .§ o o < # > R # n k / \ // / 769 / t2 = O4E / Ek / � 1—„, \ / / 0\ 0 -i « m o . > _ < , / < ,t CO % < 9- / o ^ / O # O _ _< r n = � � n < � / _x % / .// / II CL _ . ¥ n c a e L E C [ < � / § % / H O / / as oE \ \ / / $ -o 2 ® r n S / > \ > _ < o L o a m@ /m g - / \ - ƒ e m o a m n � aco ) m o a 2 m \ CO $ 5 kTD gw / _ \ / § / 0 -c 2 .$ @a) « e ± \ & > / .E > 5 / © c e CS \ \ / / N- CO \2 r-- I 2 A & TREE= 4-1/8"OW • S NOTES:H2S READINGS AVERAGE 125 ppm MI.WELL REQUIRES ACTUATOR= WA 'Y_0 3A MI. WELL ANGLE>7 A SSSV WHEN ON KB.BEV= 80.67 BF.EI.EV= 50.89' KOP= 3082' 2196 H4-1/2"HES X NP,ID=3.813' Max Angle= 99°@ 10127' = 2235'-2266' -14-1/2"BKR FLOGUARD PATCH,D=2.45"(01/26/16) Datum MD= 9127' Datum ND= 8800'SS • lk 2598' H 9-5/8"DV PKR 13-318°CSG 72#,L-80 — 2670" • BTRS,D=12.347" 8024 —9-5/8"x 7"BKR ZXP LNR TOP PKR Minimum ID =2.313" @ 9085'mF &HMC LNR MGR,D=6.290" 4-112" X 2-7/8" NIPPLE REDUCER MILLOUT WINDOW (Y-03A) WHPSTOCK(12/06/04) H 8184' 8184'-8200' 9020 —{4-112"FES X NP,D=3.813" 7-3/4"HES EZSV(12/05/04)1— 8206'ELM I I f 9,040 --17"X 4-1/2"BKR S-3 PKR,0=3.875" Nrt ►rM ►, Nt9064 -14-1/2" 5 X ',D=3.813" OF 7"LNR — 8415' 'yr- TOP 9085 —14-1/2"HES XN NP,D=3.725" FES tom90$5 H 4-1/2"X 2-7/8"X NP REDUCER 4-1/2"TBG, 126#,L-80,D=3.958" H 8464' I 0=2.313"(01/11/16) 9-5/8'CSG,47#,L-80 BTRS,0=8.681" H 8917' ...A.A.*** 9092 -ITEBACK SLV,0=5.250" 7'LNR,29#,L-80 --i 9915' r•-•-•-•-•-•- ` 9097 --I4-1/2"WL.EG,D=3.958" H ELMD TT NOT LOGGED 4-1/2"TBG,12.6#,L-80 TCI, —I 9097' 9103 —7-X5-13KRFMCLMR .0152 bpf,D=3.958" TOP PKR&HMC LNR HNGR,0=4.250- I .250" I 1 PERFORATION SUM1AARY `1 9121 —5-1/2"X 4-1/2" RIS LOG:MM/LYDGR ON 12/08/04 X0,0=4.000" ANGLE AT TOP PERF: 84°Q 11920' 7"LNR,26#,L-80 BTC-M,. H 9248' 1 ` Note:Refer to Production DB for historical pert data 0383 bpf,13=6.276" ` SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 11920- 11950 0 05/12/09 ` 2-7/8" 6 12020-12050 0 05/12/09 2-7/8" 6 12210-12240 0 05/12/09 PBTD 12682' 2-1/7 6 12420-12600 0 12/15/05 r,`k 2-1/2" 6 12610-12630 0 12/15/05 4-1/7 LNR, 12.6#,L-80 BT-M, H 12725' 11, .0152 bpf,D=3.958" DATE REV BY COMMENTS - DATE REV BY COMMENTS PRUDHOE BAY UNfT 08/28/80 INTIAL COMPLETION 01/27/16 STF/JM3 SET FLOGUARD PATCH(01/26/16; %? L: Y-03A 12/20/04 N2ES SIDETRACK(Y-03A) PB2Mf No:"2042350 07/13/12 JRHJMD SET PXN RUG(07/11/12) API No: 50-029-20411-01 02108/14 JMYPJC PILL PXN SEC 34,T11N,R13E,1248.65'FN.&547.47'FWL 11/02/15 JMG/JMD SET PXN PLUG(10/30/15) 01/13/16 MGS/JMD PULL PLUG/SET NPRH?(1/11/16) — BP Exploration(Alaska) • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, January 30, 2016 11:41 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL;AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA); AK, D&C Well Integrity Coordinator Subject: UNDER EVALUATION:Y-03A (PTD#2042350) Attachments: Y-03A Wellbore Schematic.pdf All, WAG Injector Y-03A(PTD#2042350) recently had wellwork performed to remediate annular communication.This was done by setting a patch from 2,235'-2,266'MD. A subsequent passing MIT-IA to 2,500 psi on January 26, 2016, demonstrated competent barriers downhole.At this time, the well has been reclassified as Under Evaluation to facilitate regulatory compliance testing. Please use care bringing the well online as the annuli are fluid packed and susceptible to fluid expansion. Plan forward: 1. Operations: Put well on injection 2. DHD: Perform AOGCC Witnessed MIT-IA An updated copy of the wellbore schematic has been included as reference. Please call with any questions. Thank you, Laurie Climer swop JUL 2 5 2016 (Coloring Jur Kevin Pur•kc) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com rom: AK, D&C Well Integrity Coordinator Sent: Tuesday, August 04, 2015 10:17 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; A , P.S GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well YP; Odom, Kristine; 1 V OF Tye • .0.1" %%ice s9 THE • STATTE Alaska and Gas g:�,, ��, of . /� Conservation Commission s t sKA 333 West Seventh Avenue ITh,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS11J' Fax: 907.276.7542 www.aogcc.alaska.gov Matthew Bergene Production Engineer Challenger �3�-' BP Exploration(Alaska), Inc. 0`-F- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool,PBU Y-03A Sundry Number: 315-726 Dear Mr. Bergene: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080,within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this i'9 day of December, 2015 Encl. SRBDMS DEC UlItlamvUrl V ireis. STATE OF ALASKA DEC 01 2015 • • ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPRO ALS /21 l 4- i i5 20 AAC 25.280 &n G C I1. Type of Request: Abandon D Plug Perforations ❑ Fracture Stimulate 0 Repair Well H Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tabing ❑ Change ApprgvedProgram ❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Set I atch n 7 H 2. Operator Name: BP Exploration(Alaska),Inc 4, Current Well Class: 5. Permit to Drill Number 204-235 3, Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 99519-6612 Stratigraphic 0 Service H- 6. API Number: 50-029-20411-01-00 - 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No H PBU Y-03A - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028287 • PRUDHOE BAY,PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12725 • 8997 " 12641 8992 ' Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2656 13-3/8"72#L-80 32-2687 32-2687 4930 2670 Intermediate 8154 9-5/8"47#L-80 30-8184 30-7939 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 28-9097 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program H BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development ❑ Service H - 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG H - GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Bergene,Matthew be deviated from without prior written approval. Email Matthew.Bergene@bp.com Printed Name Bergene,�Matthew Title Production Engineer Challenger Signature �'"l/ Phone +1 9075644849 O 3 •/%v. ZO i S COMMISSION USE ONLY Date Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 316-72-c-(- Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ , Other: ..fwtc- w,`fh t5S e-c/ An./ T- [Al re i—t'.--d c1 ft-f,--- . ./--4. ,7 i, y(c z5•-•i / !c 1-I- Post Initial Injection MIT Req'd? Yes 0 No 0 / Spacing Exception Required? Yes❑ No 0• Subsequent Form Required: /Q— 40 4, aie, P y� APPROVED BYTHE Approved by: i ►_ COMMISSIONER COMMISSION Date:/ -/41_„- ORIGINAL $ 'RBDMS DEC ri 2015 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate viz_ l -/9,!s7 . /z/ � -C-b f .. Z /S-- • • m Q. 00000 m r� cfl � oo coti . LOL r` r` U O O O O O i M r` CO CO 7 O) OD N •C Ca ' Cfl ti 00 co N- O) LO N N- N CO M N O) O O) co O) N- 0.1 CO CO CO I III I'- O) N N O N r CO CO CO M N- CO E � Cno � " O) CO N O = N CO 0) _ 0) V cor, El i m a CO Q 00 N •CA c%1 o O N ao rn c O O � J H Q Oo0 co o 0 o co co _ J J J • a) OM N *k __I CO CO N N X N. N N O Eo N V coCNI N N t CO CD C)O co co 'Cr M N- C U) CO v— N CD O J N CO '— M O) w • Q N CH 0 ww . 0 U U 0 L Q Z ODHZZj U fn Z J J '— • • cnm L• M V d LC) p, O O O O 0 N M LU CO 0) O CO CO CO CO co > I— o.Q O I- r- O InLU L co co co ( co O O co ooCOco 0 > w w cc a 0 0 W Z wI- w CO W 0 cp 5 W 0 > 0m 0 0 Q O m co cn n 0 0 H uj LLO LC) ,:r O OCA') J J J Q Q U) W W = 0 N N N N _CO U _U U_ J W W -, Z -, O a) r r r r r Z Z Z O 11 = o o a 0 a 2 0 0 0 W M Z o Z W W w d I- I- Q J Q 0 Q 2 2 2 0 co co cn u) co as Q O a 0 C - 0 0 0 0 0 Q (NN r N r •— O = a) O) O N V co Y.1 0 NC N (N r r r r N- al ca a as O 2 acnY = 00aJa O co co co co u) d a. o a 0 0 c C LL_ LL LL Q' X m Q O Cl_ a 0 t a) a m I- 0 0 0 0 C) C) a o ( 0 0 0 0 0 W J J Z co N N N N (Ni Z u- 1 0_ < w y N in LC) W W W J D N LL d CV (NI Z a :9 J :.7 0 W W LL W 0OLC) LCL) _ JJ J Dct a m CI _1W a< Qmaocn E Uucos a) E m Z Q Q Q Q < co co co co co co 00000 LL a cn 0 LLN } > mmu_ J 0 Uw d< < LL co cn a a • • I Packers and SSV's Attachment PBU Y-03A SW Name Type MD TVD Depscription Y-03A PACKER 8035.82 7790.76 7" Baker ZXP Top Packer Y-03A TBG PACKER 9040.42 8676.71 4-1/2" Baker S-3 Perm Packer Y-03A PACKER 9103.32 8721.74 5" Baker ZXP Top Packer • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: Y-03A Well Type: WAG Injection Well API Number: 50-029-20411-01 Well Activity Conventional 4 Classification: Activity Description: Set Patch Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,bopd: Job Type: Mech-Patch Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Matt Bergene Contact numbers: (907)564-4849 (307)630-9653 Well Intervention Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 Lead Engineer: Brian Glasheen Contact numbers: (907)564-5905 (907)545-1144 Date Created: November 17,2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate lnj Rate Gas Injection GOR Gas Lift Rate FTP or Injection Date (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 11/16/2015 0 0 13 Current Status: Not Operable Shut In Inclination>70°at Depth(ft) 9,543'MD Maximum Deviation(Angle and Recent H2S (date,ppm) NA 0 ppm Depth) 99° 10,127'MD Dogleg Severity(Angle and Datum depth,ft TVDss 8,800'TVDss Depth) 17° 9,477'MD Reservoir pressure(date, 3/5/2014 3,284 psi Minimum ID and Depth 3.725'@ 9,085'MD 4-1/2'HES XN psig) Nipple Reservoir Temp,F 194°F Shut-in Wellhead Pressure 830 psi Known mech.integrity MIT-IA to 2500 FAILED on 8/4/15,Archer LDL indicated leak at 2,249'MD problems(specifics) Last downhole operation(date, 11/6/2015 SLB Eline-Archer LDL operation) Most recent TD tag(date,depth, 10/29/2015 9,452'MD SL drifted tbg with 20'x3.70'dummy whipstock toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for>1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, Y-03A was rotary sidetracked in December 2004 and initially came online with low injectivity,in June background information, 2005 a second step rate test indicated the well injectivity had greatly improved after being online for 3 etc: months.Shortly after completion in July 2005 Arctic Pack was flushed due to OA repressurization. In February 2007 WIEs returned to determine the OART,repressurization was minimal and the PPPOT-IC passed on February 19,2007.Aside from WAG swaps this well has had limited interventions.In May 2009 an E-Line Tractor conveyed add perf program added 90'of perforations 200 feet uphole from the original set of perfs.On March 22,2014 the PPPOT-IC failed and the LDS were torqued to 450 ft-lbs, and continued to fail the pressure test.On April 19,2014 the 3-1/8'FMC IA valve was replaced with a 3-1/8'HWO gate valve,the blind was pressure tested to 2500 psi for 5 minutes and passed. The well ' was SI from July 2012-January 2015 due to corrosion in the flow line.The flow line replacement was completed in December 2014,and injection resumed on January 09,2015.The well failed a MIT-IA to 2500 psi on August 4,2015 with a LLR of 6.5 gpm at a 1840 psi differential at surface while pumping diesel. Most recently,the well under went integrity evaluation on 10/30/15. The well passed a CMIT- • • TxIA(to 3000psi)and MIT-OA(to 2000psi),and failed another MIT-IA and MIT-T. A subsequent Archer LDL indicated that the leak in the tubing is located at 2,249'MD. • The propose of this program is to set a patch across the leaking interval and regain injection integrity though passing an MIT-IA. Well Intervention Details Suspected Well Problem: IA communication Specific Intervention or Well Objectives: 1 Set patch over leak at 2249' - 2 Perform a passing MIT-IA 3 Key risks,critical issues: Mitigation plan: 1 Patch not covering leaking interval Use Field print Archer Leakpoint LDL from 11/6/15 to tie into for depth control 2 Collapsing tubing Pressure test to 2750 psi 3 Damaging patch during pressure testing Ensure that 3500 psi differential at patch is not reached prior to performing MIT-IA Summary Step# Service Line Activity 1 S Pull UP,Set nipple reducer,set and pull plug post CMIT 2 F CMIT 3 E Set patch 4 F MIT-IA Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1)D&T with 25'dummy patch with 3.70'OD 2)Pull PXN plug from XN nip at 9085'MD 1 S 3)Set nipple reducer in XN nip at 9085'MD. Min ID through the patch is 2.37' 4)Set 2-7/8'plug in nipple reducer 5)Post passing CMIT,pull plug. If CMIT fails,pull,reset plug and retest. 2 F Perform a CMIT according to attached pump schedule 1)Run Baker 45 Flo-Guard One trip patch assembled according to the design attached 3 E 2)Tie into PDS Leakpoint LDL dated 11/06/15 and set with center of bottom sealing element at 2261'MD. Leak is at 2249'MD 4 F Perform an MIT-IA according to attached pump schedule. At WSL discression get a FL to verify that 3500 psi differential of patch is not going to be exceeded during pressure testing Performance Expectations(may be NA if no change anticipated due to the intervention) Expected Production BOPD: MMSCFD: BWPD: 3000 Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: Contact WIC if MIT-IA passes to declare the well operable and POI at 3000 BWPD PWI Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies, Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: 0 • TRH-= 4-1/IS OW SAFETY NOTE:IS FEADINGS AVERAGE 126 ppm WIILFEAD- ACTUATOR= KB 13_EV= 50.991' BE LLEV- KOP- 84 57 oez Ma Ankle= 09'0 1 0 1 2 7' I I Ovum PA), 13 Datum TVD- 912/' saw SS Y-0 3A _ b..MI.WELL REQUIRES A SSSV WHEN ON AIL WB.1 ANGLE>IGA fit 9627`. L 2190 1-14-1/2"HE6 X NE,ro--7ier IMO = 2(100 j - 9-5/9"EN ROI 1 13-3/9"CSC mit,L-so —I 2971T i— 11. BTRS,0',--12 34r II CO—' BU24 !--9 5'8". 7'BKRZXP LNR TOP PIKR & PVC LIKII-NOR D (290 ..„... Minimum ID xe 3.725" Ca 9085' 4-1/2-HES XN NPPLE MI LLO U T WINDOW (V 03A) V1--IPST FA K i 1?.16(,4) -i stair I 6184'-8200'k 9020 1—f4-1i-HEs x sc 0=3 air 1 17-3M'I-ES EZSV(12/05/04) -1 0206 ELM 1, ii I \ a MI 11 S040 1 f r X 4 1/2'E 0 R S 3 73 14=1 ;II: ..7.-i4 ai D. 11111, 9064 14 1/2'-ILS X NI'•10=3 86- ror7—ot'r LPFti C iki.---Tin mi . il. 9086 -14 172"-IES XN HP,D=3 725- 4 1/2"MG,12.611 L 80CI, -3 our I-1 9484 f------ Ik, k. — W— -9C— 0— 4-1Q"INN RUG(10030715 .. .1 19-5AY CSG,479,L-90 BTRS D=8 681' I— 691 r I—" :•1, .....- ,, H:)92 7---TFRACK SI V,10.,5 2e,O. I .44:44:1114 — \ , 90412—j— ti-EG-0.•3 969- I-ao mi., '-1 909r ' N.. 9103 7 )(5.13KR HPAC LAR TOP PKR&MAC,.NR 0152 bpi,D-3 9515' MGR,ID-4 250' PERRIDATICM 3104VAKT ih, 9121 REF LOG INCODGR ON 12,0004 ANGLE AT 11)P18- 84"/(Ip 11970 r 1 MR 760,1, 00 Mr i0t, 1 - 924, • Able Heiler to ProdGchon L1 or An torcaI pert data 0 Vi i hp' I) €1 SEE SPF IBERYAL Opc0Sqz SHOT SCIZ 11,. 2718. 6 11920-11950 0 05/12/09 2-7/13'' 6 12020-12030 0 05/12/09 '1 2 TAY 6 12210..12240 0 05/12/09 F-7- law 14^ 2-1/7 6 12420-12600 0 12/15105 111,411,114, 3 1/3-i fi 12610 12610 1 9 12/15AO5 4-1/2-LAR,12 SILL OUST-u. 12725' Ntlitb• 1 _ . 0152 89?,ID-3.O58 DATE FEY BY COASETITS CATE WV BY CXXIIENTS FRU:110E BAY LINT 00,20100 MAL COMPLETION 07/13712 JRP.A.0'SET PXN PI LIG(07/11112) AEL Y-133A 12.121904 NIES SIDETRACK(Y-03A) 02,0814 JPAPJC IFU-L PXAIPnreir ND "o423.5o 12/06/015 GM/1LN BRIG ORAP 1 CCRIA-CITJNS 11/02/1b IJINGARAD SET PXN PLUG(10f"3-0/15) ARIN, Q-0-29-20411 01 05J30/09 RNITYTI II P149-S I05112/139} SEC 34.T11M FOIl 1'4/165 144 8`,41 4r IWL 0206,11 113/JIAD A MED SSSV SAFETY NOTE 01/23112 11/14JP/113 A LDEDEGS SAFETY PIDTE BP Exploration tAllas Pat 410 Local Knowledge for a No rthern Solutions!LC Baker 45 Flo-Guard Global Industry Notan C,14111.0, One trip patch • NSAK Ref: 15465-000xx Well No.: Y-03 V FOR INFORMATION ONLY endor: Drawn By:RDH Requested By: M Bergene BOT 10/24/2015 Description OD ID Length AAA 1.18• —.1111111 : 45"KB"Upper Straddle Packer 4"GS Fishing Neck Up 5 78 3 112"STL Pin Down 3.70" 2.37" 5.76' 30K Shear Release H819634506 4.18' . (8) -20 Shear Pins 11320#'s(3"1 Shear) 25' V io' 31.63 3 1/2"STL Pup Joints 3.50" 2.972" 20' 20.00' 10' A _ , .41,3` — 111 .40' A 45"KB"Lower Straddle Packer •• 5.49 3','2"Sll Box • 278"STL Pin Down 30K Shear Release 3.70" 2.37' 5.49' H819634506 4.26' (5)"1/4"-20 a 70754's(1°Shear) (4)5/16"-18 @ 9529#'s(rd Shear) V y .313' V WLEG 2 7/8"STL BO% 2.875" 2.441" .3W Total Length TW: The enclosed is conceptual for information onty. All feasibility and dimensional data should be verified with the supplying vendor prior to installation. . • • 'rib' ,ii.svelpio ?-s . or LEAKPOINTTM SURVEY , 44. ar C-11 MP XTU-CCL-PRT-LPN -LP Ill 06-Nov-2015 pRoAkcinive DiAcolosTic seRvices I Company BP EXPLORATION (ALASKA), INC. c 1 -cif I Well Y-03A ...Ne to co Field PRUDHOE BAY FIELD t < Borough NORTH SLOPE State ALASKA to. cog tfi a. Surface Location Other Services tu ci la o 09 m None x 4r:t -C 1,248.79'FNL & 547.48'FWL 1 w V) I:5 -t u) , 03 3- 0_ Z •:"T ' SEC: 34 TWP: 11N RGE: 13E , ).4 Elevation Elevation 0.00' 1 Permanent Datum MSL ,K 8 78.04' E = 32 2 z I Log Measured From RKB 79.04 FT.Above Perm.Datum I OF. N/A 0 •-,t2 4) o IS I 0 5 it m u) 1API Serial Number 50-029-20411-01 I GI_ NVA Date ' 06-Nov-2015 - Run Number One 0 : D Driller PBTO ,?,r,r Not Tagged P)(N ' , 2 9 :'-• _ _ Bottom Logged Interval 9,081' Top Log Interval Surface Open Hole Size NIA .__E _.—T -e-I-Tiurd Produced Fluids Max.Recorded Temp,(deg.F,) 198 me Well Ready . :4_ FIELD PRINT i Time Logger on Bottom 07 15 quipment Number REW Unit.*2362 1 Location North Slope 1 Sennce Invoice No "-----T3i .1 , Recorded By B Suhanek D.Sparks By J.Morgan 0.Stidd Borehole Record Tubi ! Record Run Numbirr—B-W--- From To Size LB 1 Ft From To 4 1/2" 12.80 Surface F 9,09T ' 'A A Size LB/Ft Top Bottom , , Casig_n=0.1 1 m -ST-Ace String 133w 7200 Surface 2670' 1f , Prot.String 9 5/8" 47.00 , uS rime i 8,91 ,x. -4- Liner 7 26,00 8,024' 9,248' Liner 4 1t2" 12,60 l 9,121' 12725' ;, - — • 0 --.. .... ... 20 Temperature(LA)(degF) 220 0 LeakPoint''y-A(Bottom)(LA) 6e+00 4000 CCL -430 0 LeakPointTM-C(Bottom)(LA) 60+00 6e+006 LeakPointml-A(Top)(LA) 6e+006 LeakPointTm-C(Top)(LA) -3 Differential Temperature(degF) 1 -... .....4. a P.- . II , Line Speed I a , . 4-- - I 1 ' - - - 1 --4Temperature(LA '4—c _ Temperature(Leak Active) 1 It ), . . CCL * 1 LeakPointm4-A(Bottom)(LA) LeakPointTIA-A(Top)(LA) .a. . 4 ' 1 2100 I a a t 4 4 . , LeakPoint"‘-8(Bottom)(LA) LeakPointTh`-B(Top)(LA) -- LeakPointTm-C(Bottom)(LA) LeakPointl"-C(Top)(LA)4+- 14 7.1 1 Differential Temperature —Iir'l, - -. - - 4 _4. .• 7 .. ,-.. --1- 1 .. 4 4 . t , a . . 'a 1' \ a - .. ,:. 1 - -4. 1 i i -----/ 1 i I , \ ) 1 7, 1 , .. ', . , ....) . .., i ... ' --- Patch to be set with the center * 4 4.) *X Nipple ' of the top sealing element at , . „. 2200 , 2236and the bottom sealing ,. ... , . ,.• . , , • element at 2,261' _ , - .. ' ..- tt ..., . . . , . , , . , . \ , :i• . , Leak Signature -- f . . , . . . . . , .., a • ' ........4--- 2 _-............... - ar , ... •. . 1 --- i---- -- ..--' . . , ...''.-- t t,„\.,_ .. f . . Jr 1111 . -...,, .--.. ) I . . : ---......,, *4 ..7 ,,‘ 14, . 4.. . 4 ( .1. , , -1- '' • • • , / , , 44, . i 2300 • , !. c i t • " a ' ti1. a G K NI--Temperature(LA) "" `" Temperature(Lek Active) -ti K t. 4 4•--•LeakPocntTTh'-A(Bottom) LA) :. LeakPointTM-A(Top)(LA) f 1 -1 4. 4--,'LeakPointV4' -B(Bottom)(LA) _ LeakPointTM-B(Top)(LA) E .= :. =LeakPoinV -C(Bottom)(LA) " :LeakPointIm-C(Top)(LA) I -- m_ . Differential Temperature__ i t , t i i et + = t ..__. � 2400 4. . t _ - - • �,*. +..tom 0 Line Speed(ft/min) -200 60 Temperature(Leak Active)(degF) 8 20 Temperature(LA)(degF) 220 0 LeakPointTM'-A(Bottom)(LA) 6e+00 4100 CCL 430 0 Le3kPoi^t e C(Bot c.,,)(LA) 6e+AM 6e+006 LeakPointTM-A(Top)(LA) 6e+006 LeakPointTM-C(Top)(LA) 1 -3 Differential Temperature(degF) • ! Fullbore Pumping Design Template 1/0/1900 0 ppm H2S(date/ppm) 2700 Max Pumping Pressure(psi) Diesel Main Fluid Type 125 Main Fluid Volume(bbls) Diesel Freeze Protect Type 30 Freeze Protect Volume(bbls) If Applicable Recent Tbg Fluid Level(ft) If Applicable Recent IA Fluid Level(ft) If Applicable Recent OA Fluid Level(ft) If Applicable Expected Tbg Fill Up Volume(bbls) If Applicable Expected IA Fill Up Volume(bbls) If Applicable Expected OA Fill Up Volume(bbls) If Applicable Wellbore Volume to Perfs(bbls) If Applicable Anticipated Bottom Hole Pressure (psi) Yes Tubing/Casing within Pressure Limits? Size Burst/Collapse 80%Burst/Collapse Tubing Burst(psi) 4.5 8430 6744 Tubing Collapse(psi) 4.5 7500 6000 Casing Burst(psi) 9.625 6870 5496 Casing Collapse(psi) 9.625 4760 3808 Select Input Depth Integrity Issues? Tbg 2249' Select Yes-Tbg cond good Tubing Caliper? Burst/Collapse ratings may need to be derated based on tubing condition Yes Production Packer within Pressure Limits? Rated Packer dp Max Anticipated dp at Packer Select Hold Pressure on Other Strings? Tubing(psi) IA(psi) OA(psi) • • < 4 0 o s y o o s & S R ƒ & 2 p / S ^ ^ E b ^ ^ 3 0 k k k I- \ e ) e .) & f E S f E S e E = k ) y 0 C e k 0 e / 0 e 2 0 _ = n = = r 2 = U) m = / 2 k / \ \ / / 7 ELE § >, e $ < _ — e o < _ = e % < E e u) m * ® a) - e * - 2 - e x 7 2 / 2 § - 2_ / 2 ƒ / 7 / 2 § 2 £ e / o k o o o o . / o — e r r � r >° g N- » , w » - / @ tN C �. C c\I — \ filliE / a) o o a 2 f f \ HEE Q. { 2 / / / ( r <\\ § 2 CN \j$ { \) f \ o / \/ 4 2 o r 2 c E n : te a <\ e \ _ _ o / k E k e \ o - 0 \\ % ( a \ / - p Ja e o : ° & f = m = § < _ _ $ : - § ® ® giiiiiR e \ / Q j f 3 7 ( 2 4iiiiiilli 3 o d Z / W / -o 0 \ , ƒ . m Z 7 5 a) $ . Cr) ) ƒ z 2 = i4iiiggi � / 0, \ I \ 7 \\ & 2 7 _ m Iv: g y e 2 - 0 $Liln o .0 : co & _ ( a § a E = y» ® o » c \ E _ _ a 2 \ ^ ._ a) 3 k k -x a & — 0 _ - — S * I- z ° 2 I- \ k 0 _ % m o E E .c « \ u $ § o / \ / & @ = k @ = k e = t \ 3 \ o § G co f \ / ƒ \ / \ ƒ ƒ § 2 o § E E 2 & C \ o > @ _ ƒ k d ƒ P E _ ƒ ƒ \ � ƒ > a C r « r c » I • ,, 1,, ,,.; ,,. ,, i„, „.„ ,,, 1,, 21 13. 03 !`l ^ 7 ! �- / k. � 8 \ ! ) 1` § N � i ® \ / )=;2 j k® «AO ENE M 2„IMI ; N, :2:G: M PN 11. / ! ;Vra §~~§§§9|;s"PI 2§1 rF )\)) \ l.11iggiiiiill, IM1111,.11 1011 . \ . rV, ,..,,��.,,IR„\\§j\\\WA,7, 2 ! _ - j 3 A t ! ,,,�R 28828888888888888888888888888 /k\jj\\}/\§§§§§(§))/ E ! ] ) - } \ / , \\\}(§§k)\\\\\\/)kkkj\j|2|§]K7 ! � { �� . IT- !$«E Q, §§§§§)§))k)))(\( )k 151 % { ,� ��,�� 7 ) `§§§§§§§§§§§j§§)/))§§\ j\§Ekkk ) A1111111111111111111111111111 ® 7 ) '/§§§§/§§/$§§§/kk))k\§(\((§k)) !!: 2 ! : ��. z \ !! §§)§2§)))§/§§§((%()kk)%k)/\/§ Na22, Fp - _ \ rr2!§■e§B:§N§2E!§§/f .` - \%E) ! , !|} ¥ ! { ti B);{ !- /!!f, i ` 2!;!§;mlm!|§§§§§l2+�¥!!!!f9¥§9 i ( , ;) ||!£a;,la A • 0 a DATA ENTRY AREA:MUST ENTER DEPTHS,FLUID DENSITIES AND SURFACE TBG COLLAPSE REFERENCE DATA User Input Tbg Size Class Pressure Derated Depth of Fluid Tubing Conditions IA Conditions Interface Etc. Fluid Fluid 2 7/8"\6.5# L or N-80 (Needs Entry) Density Pressure Density Pressure 80%= 0 Depth-(TVD Ft) (#/gal) (Psi) (#/gal) (Psi) 3 1/2"19.3# L or N-80 0 Enter Tbg= 0 Enter IA= 2700 80%= 0 2249 6.8 794 6.8 794 4 1/2"\12.69 L or N-80 5928 5928 8676 8.51 2840 8.56 2857 80%. 4742.4 r 0 5 1/2"\17# L or N-80 0 80%= 0 0 0 7"1268 Lor N-80 0 80%= 0 0 0 FLUID GRADIENT REFERENCE DATA 0 TYPE DENSITY GRADIENT 0 0 (#/GAL) (PSI/FT) 0 15°CRUDE 8.05 0.4182 DATA ENTRY AREA:ENTER FLUID INTERFACE DEPTHS AND FLUID 0 28°CRUDE 7.40 0.3841 DENSITIES FOR ALL INTERFACES. ENTER SURFACE PRESSURES. 0 30°CRUDE 7.31 0.3793 DENSITIES REFER TO FLUID AT THAT POINT AND ABOVE. ENTRY 0 40°CRUDE 6.88 0.3572 POINTS ARE DESIGNATED BY RED LETTERING. 0 DIESEL 6.80 0.3531 Depths=1)leak 2)packer. Fluids=diesel above PW in tbg,SW in ann,during 0 100%METH 6.64 0.3446 last operation,returns were taken down y-35.diesel was pumped tinto the IA at 0 50/50 M/W 7.49 0.3888 Pressure @ I Pkr=3634 Pkr=6351 60/40 M/W 7.32 0.3800 FRESH WATER 8.34 0.4329 Max Differential at Packer= 2717 SEA WATER 8.56 0.4443 PROD WATER 8.51 0.4417 Brine Water 9.60 0.4985 Differential Pressure across Tbg Brine Water 10.00 0.5193 Brine Water 10.60 0.5505 Prod Gas @ 2000 1.14 0.0592 Calc Differential Pressure! I Calculated Threshold I Prod Gas @ 1000 0.49 0.0254 Your Choice= 2 0.1039 0 1000 2000 3000 4000 5000 0I EXAMPLE CASE I !Too if WelL 1000 • Diesel I� 2000 . . IA Fluid Interface @ 2000' 3000 - 'TVD. `\ 4000 I Gas f 5. s000 Brine 10.6#/gal \ 6000 7000 Tbg Fluid Interface @ 8000' • 8000 - -Diff Pressure TVD -7'126# I ,ii':;:i:i:: : 1. •51/2'117# ;.;; ::'.� 9000 - 41/2'112.6# ,�„_, ‘ 3 1/2'1 9.3# Packer Depth 8200'TVD. 27/8'16.5# p @ ...> 10000 I Crude I • 204-23b WELL LOG S TRANSMITTAL II- PROACTIVE DIACINOSTIC SERVICES, INC_ DATA LOGGED \2! l/201$ M.K,BENDER To: AOGCC •.� 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 nancpdcAbp.comt • rijkOia' and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 06-Nov-15 Y-03A BL/CD 50-029-20411-01 2) 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: PDSANCHORAGEQp MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\AchiveslMasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, August 04, 2015 10:17 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Welipad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE: Y-03A (PTD #2042350) MIT-IA Failed Attachments: Injector Y-03A (PTD #2042350) TIO Plot.docx All, Injector Y-03 (PTD#2042350) Failed a MIT-IA on 08/04/15, indicating the lack of two competent barriers in the wellbore. The well is reclassified as Not Operable until integrity can be restored and confirmed. The well has been added to the AOGCC Quarterly Not Operable Injector report. Plan Forward: 1. APE: Evaluate for repair/secure options. A copy of the TIO plot has been included for reference. Please call if you have any questions. Thank you, Kevin Parks :diet-nate. Whitney Pettus, BP Alaska-Well Integrity Coordinator �E0 AUG 0 4 2015 G'/�/ Global Wells �/ Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, August 02, 2015 11:21 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; 'Regg, James B (DOA)' Subject: UNDER EVALUATION: Y-03A (PTD #2042350)Tubing x Inner Annulus communication All, 1 Injector Y-03A (PTD#2042350) is showing signs of tubing x inner annulus communication. The well has been reclassified as Under Evaluation and is placed on a 28 day clock for additional diagnostics. Plan Forward: 1. DHD: Perform MIT-IA to 2,500 2. DHD: Bleed down IA and obtain a BUR 3. W: PPPOT-T 4. WIE: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions. Thank you, Kevin Parks (Alternate Whitney Pettus) BP Alaska Well Integrity Coordinator GINGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator@bp.com 2 Injector Y-03A(PTD#2042350)TIO Plot .m 30(G •-•-*a .-I, au +-a om, 00oc Oe imc MA... - 054ths O,,15 CS Vt Is OS]t15 0101 06,0515 011115 X 15_ O0515 ((UI! 0,13'1! Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, August 02, 2015 11:21 AM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: UNDER EVALUATION: Y-03A (PTD #2042350) Tubing x Inner Annulus communication Attachments: Injector Y-03A (PTD #2042350) TIO Plot.docx All, Injector Y-03A(PTD#2042350) is showing signs of tubing x inner annulus communication.The well has been reclassified as Under Evaluation and is placed on a 28 day clock for additional diagnostics. Plan Forward: 1. DHD: Perform MIT-IA to 2,500 2. DHD: Bleed down IA and obtain a BUR 3. W: PPPOT-T SCANNED AUG 0 32015 4. WIE: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGOiobal Wrganizate Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 . 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. (Q Q 4. - d.-3S Well History File Identifier Organizing (done) o Two-sided 11111111111 "'11111 o Rescan Needed 1111111111111111111 RES CAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettesl No.~ o Other, No/Type: 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 I 118/b Þ Isl Mf Date " I 'fi /06 ~ X 30 = too Date: t I ~ f6 / 0 b 1111111111111111111 Project Proofing BY: ~ Isl MP BY: Scanning Preparation ~ +:).. = TOTAL PAGES to d- (Count does not include cover sheet) ,^^.o 151 , V \ r Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: fo3 (Count does include cover sheet) BY: Page Count Matches Number in Scanning Preparation: ~ Date:" I «) I ()0 V'YES NO Isl Mf Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Isl 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc • • /' "1k., y 03A- 1'it 2o4 , Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, August 01, 2012 7:24 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) ¶ r 0 0(q(i v Cc: AK, D &C Well Integrity Coordinator Subject: July 2012 AOGCC MIT Forms Attachments: July 2012 MIT Forms.zip Jim, Phoebe, Please find attached MIT forms for July 2012. Sent Previously L -218 (PTD #2051190) sent 7/9/2012 04 -11A (PTD #1931580) sent 7/17/2012 S -112 (PTD #2021350) sent with reclassification notice SCANNED D Enclosed in .zip file END 1- 41/0 -23 (PTD #1870320) END 3- 17F/K -30 (PTD #2032160) NS10 (PTD #2001820) EPA Witnessed NS32 (PTD #2031580) EPA Witnessed L5 -29 (PTD #1870450) MPB -25 (PTD # 1972330) MPB -50 (PTD #2042520) EPA Witnessed MPC -25A (PTD # 1960210) MPC -42 (PTD #2040280) B -31 (PTD #1910460) 04 -09 (PTD #1760300) Corrected packer depth (original sent 7/30) 04 -13 (PTD #1780310) Corrected packer depth (original sent 7/30) 04 -350 (PTD #2111060) 11 -02 (PTD #1811280) 17 -15A (PTD #1991310) E -100 (PTD #1971880) GC -2E (PTD #1970180) L -111 ( PTD #2020300) LPC -01 (PTD #1860480) V -220 080200) — well is currently on gasand was during test, inspector may have been told it was on water -03A (PTD # 2042.55[) secured for drill by on Y -1 Y -07A (PTD #2071050) Please let me know if I can be of further assistance. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator (a�BP.com 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(aalaska.gov; doa.aogcc.prudhoe.bav aalaska.aov; phoebe.brooks(Dalaska.00v; tom.maunder(Dalaska.Qov OPERATOR: BP Exploration (Alaska), Inc. fi e' 11 FIELD / UNIT / PAD: Prudhoe Bay /PBU/Y -Pad DATE: 07/11/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y -03A ' Type Inj. N ' TVD ' 8,676' Tubing 332 2533 ' 2489 2473 - Interval 0 P.T.D. 2042350 - Type test P Test psi - 2169 Casing 9 • 10 - 9 10 • P/F P " Notes: Secured for drilling on Y -19 - OA 0 ' 0 0 0 ' MIT -T / Well Y -03A ' Type Inj. N TVD ' 8,676 Tubing 541 - 943 • 943 943 ' Interval 0 P.T.D. 2042350 ' Type test P ` Test psi ' 2169 Casing 9 2503' 2463 2449 • P/F P Notes: Secured for drilling on Y - 19 - OA 0 0 - 0 0 MIT -IA "/ Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU Y 07 - 11 - 12 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB 20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 y �h December 20, 2010 wow) 3A 4 4 `L01 () 2( " Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue fl, ' : Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Y Pad 3 A Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from Y 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, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12 /20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # cement pumped cement date 'inhibitor sealant date ft bbls ft na gal Y -01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y -02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y - 03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y -04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y -05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y -06A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y - 07A 2071050 50029205600100 14.5 2.0 0.3 NA 1.70 8/4/2010 Y -08A 1880560 50029205720100 NA 4 NA 15.30 8/5/2010 Y -09A 1970830 50029205790100 19 1.5 3.6 NA 17.00 8/4/2010 Y -10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y -11C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y -13 1811120 50029206340000 NA 0.4 NA 3.40 4/15/2010 Y -148 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y -16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y - 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y -19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y -20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y -21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y -22A 1881150 50029215580100 NA 0.5 NA 3.40 8/4/2010 Y -23B 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y -25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y -26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y -27 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y - 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y -29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 Y - 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y -31 1910560 50029221610000 NA 0.5 NA 3.40 4/12/2010 Y -32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y -33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y -34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y -35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y -36 1931310 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y -37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, May 20, 2009 2:19 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Welis Opt Eng; GPB, Optimization Engr; Schmoyer, AI Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T. Subject: OPERABLE: Y-03A (PTD #2042350) AOGCC MIT-IA Passed All, Well Y-03A (PTD #2042350) passed an ROGCC ~itn~s_sd MIT-IA to 4 000 psi on 05/19/09. The passing test verifies the well has two competent barriers and re-establishes compliance with the Area Injection Order. The well has been reclassified as Operable and may be put on MI injection if/when convenient. Piease call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~{ ~ N ry '~3 .~.. Y:~i~.~.oW ~ ~ f ~ ~i} . I_ ~ From: NSU, ADW Well Integrity Engineer Sent: Friday, May 15, 2009 3:45 PM To: 'Regg, ]ames B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GC3 Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Welis Opt Eng; GPB, Optimization Engr; Schmoyer, AI Cc: NSU, ADW Well Integrity Engineer Subject: Under Evaluation: Y-03A (PTD #2042350) AOGCC MIT-IA pre WAG SWAP All, Well Y-03A (PTD #2042350) addperfs have been completed. The well has been reclassified as Under Evaluation and may be POI for an AOGCC witnessed MIT-IA. The plan forward for the well is as follows: 1. WOE: POI 2. F: AOGCC MITIA to 4000 psi Please call with any questions or concerns. Thank you, 8/31 /2009 OPERABLE: Y-03A (PTD #204~50) AOGCC MIT-IA Passed • Page 2 of 3 TOrin RosChinger (filling in for Anna Dube) Well Integrity Engineer Office (907) 659-5525 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1923 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, April 14, 2009 10:55 AM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)' Cc: Holt, Ryan P(ASRC); NSU, ADW Well Integrity Engineer; NSU, ADW WL & Completion Supervisor; NSU, ADW Wells Eline Scheduler Subject: FW: NOT OPERABLE: Y-03A (PTD #2042350) Compliance testing due 04/09/09 Hi Jim and Tom, Well Y-03A (PTD #2042350) is now overdue for UIC Compliance testing. The well has been reclassified as Not Operable until additional perforations are added to improve injectivity. This work has been delayed for at least another week. Once completed, the well wiil be returned to injection and the compliance testing will be completed at this time. Please let me know if you have any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Caordinator GPB Wells Group Phone: {907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, April 04, 2009 10:53 AM To: GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GCS Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; Schmoyer, AI Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P(ASRC); Quy, Tiffany Subject: NOT OPERABLE: Y-03A (PTD #2042350) Compliance testing due 04/09/09 All, Well Y-03A (PTD #2042350) is due for regulatory compliance testing by 04/09/09. However, the weii needs to be on produced water injection to perform the test and the weli will not take water injection without adperfs. The adperFs are currently scheduled for 04/12/09. The well has been reclassified as Not Operable until the work can be completed. The plan forward for the well is as foilows: 1. E: Adperf 2. WIC: Reclassify as Under Evaluation 3. WOE: Put well on PWI 4. F: AOGCC MITIA to 4000 psi 8/31 /2009 OPERABLE: Y-03A (PTD #204~50) AOGCC MIT-IA Passed ~ Page 3 of 3 Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/31 /2009 MEMORANDUM Toy Jim Regg ~ ~I~'~y P.I. Supervisor ( ~~ ~ V I FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y-03A PRUDHOE BAY UNIT Y-03A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT Y-03A API Well Number: 50-029-20411-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS090520063320 Permit Number: 204-235-0 Inspection Date: 5/19/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~- Y-o3A .Type Inj. w TVD 8676 i IA 660 4000 3940 3920 P.T.D 2042350 TypeTest SPT Test psi 2169 OA 440 780 780 800 L--- ~ Interval 4YRTST per, P ~ Tubing 750- 750 750 ~ 'I50 ~ NOtes' Pretest pressures observed and found stable %t. ~ Wednesday, May 20, 2009 Page 1 of 1 STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS MAY ~. ~uu 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Atter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~tQi~l~n ~}~9ft Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended WeIk~OfffiQ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 204-2350 - 3. Address: P.O. Box 196612 StratlgraphlC ~~ Service _ ~` 6. API Number: Anchorage, AK 99519-6612 50-029-20411-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 79.04 KB PBU Y-03A - 8. Property Designation: 10. Field/Pool(s): ADLO-028287 - PRUDHOE BAY Field/ PRUDHOE BAY Pool 11. Present Well Condition Summary: Total Depth measured 12725 - feet Plugs (measured) None true vertical 8997.32. feet Junk (measured) None -, :. ,~~~{{ Effective Depth measured 12641 ~ feet true vertical 8992.25 - feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2689 13-3/8"72# L-80 Surface - 2689 Surface - 2689 5380 2670 Production 8184 9-5/8" 47# L-80 Surface - 8184 Surface - 7939 6870 4760 Liner 1224 7" 26# L-80 8024 - 9248 7779 - 8825 7240 5410 Liner 3633 4-1/2"12.6# L-80 9092 - 12725 8714 - 8997 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 26 - 9097 0 0 - Packers and SSSV (type and measured depth) 9-5/8" DV Packer 2597 7" Baker ZXP Top Packer 8024 4-1/2" Baker S-3 Perm Packer 9040 4-1/2" Baker ZXP Packer 9103 12. Stimulation or cement squeeze summary: ~or~~i ~~ ~~~c T~`tg " Intervals treated (measured): ` Treatment descri tions in ludin volume nd final d p g c s use a pressure: ~i~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 148 649 Subsequent to operation: 2342 805 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas WAG ~ GINJ ~ WINJ WDSPL 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: N/A Contact Gary Preble _ ~ ~~~, ~ ~ ~~4~ Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 5/19/2009 Form 10-404 Revis 04/2006 ~ f j (W`' ~ ~ ~ ~ /,~..~, Submit Original Only .~ .-~- Y-03A 204-235 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Y-03A 12/15/04 PER 12,420. 12,600. 8,976.6 8,989.73 Y-03A 12/15/04 PER 12,610. 12,630. 8,990.35 8,991.58 Y-03A 5/11/09 APF 12,210. 12,240. 8,956.35 8,959.43 Y-03A 5111/09 APF 12,020. ~/ 12,050. 8,936.39 8,939.48 Y-03A 5/12/09 APF 11,920. 11,950. 8,926.37 8,929.31 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • Y-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1 5/9/2009,'`*"WELL SHUT IN ON ARRIVAL""` 'INITIAL T/I/0=350/0/0 FUSIBLE CAP REMOVED ~ , "*"JOB IN PROGRESS AND CONTINUED ON 10-MAY-09 WSR''*'' 5/10/2009"**JOB IN PROGRESS AND CONTINUED FROM 9-MAY-2009*** ISAT DOWN DUE TO DEVIATION AT 9585', TRACTOR TO 12269', TAGGED BO,~ TTOM. LOG TO 8980' ~;***JOB IN PROGRESS AND CONTINUED ON 11-MAY-2009*** 5/11/20091**''JOB CONTINUED FROM 10-MAY-2009*** SAT DOWN DUE TO DEVIATION AT 9585', TRACTOR TO 12269', TAGGED BOTTOM, LOG TO 8980' ESHOT INTERVALS 12210' - 12240'; 12020' - 12050' WITH 2-7/8" POWERJET 6 SPF; RIH TO SHOOT LAST INTERVAL FROM 11,920' - 11,950' ***JOB IN PROGRESS AND_CONTINUED ON 12-MAY-2009 WSR*** _. ~ _~ ~ __~m_____ 5/12/2009~"""JOB CONTINUED FROM 11 MAY-2009""" LSAT DOWN DUE TO DEVIATION AT 9585', TRACTOR TO 12269', TAGGED BOTTOM, LOG TO 8980' ISHOT INTERVAL 11920' - 11950' WITH 2-7/8" POWERJET 6 SPF ;WELL LEFT SHUT-I _ , MASTER,SSV =OPEN, IA/OA = OTG. FINAL T/I/O = 200/0/0 ,"** JOB COMPLETE "'"' FLUIDS PUMPED BBLS 6 METH 1.5 diesel 7.5 Total RE: Y-03A (PTD #2042350) Increase in IA pressure • Page 1 . d.ck~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, June 16, 2008 11:21 AM ~P_> To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Wellman, Taylor T; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer Subject: RE: Y-03A (PTD #2042350) Increase in IA pressure Attachments: Y-03 TIO PIot.BMP Hi Jim and Tom, Well Y-03A (PTD #2042350) was bled on 6/11 /08 when the wellhead pressure were tubing/IA/OA equal to 900/590/60. The IA pressure was bled from 590 psi to 200 psi. The wellhead pressure have been monitored for the last couple of days. Although the well has been off injection the last two days, the wellhead pressures on 06/13 were 850/180/40. At this time it is believed that these wellhead pressures indicate there are no integrity issues. The well will remain on the Monthly Injection Report for the month of June sot at the TIO plot can again be reviewed in early July. A recent TIO plot has been included for reference. «Y-03 TIO PIot.BMP» ;/ Please let me know if you have any questions or concerns. Thank you, Anna ~u6e, ~'. E. Well Integrity Coordinator ~, 1~~~~ ~~~' s 2~~$ GPB Wells Group Phone: {907} 659-5102 Pager: {907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, June 10, 2008 6:54 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Engel, Harry R; NSU, ADW Well Operations Supervisor Subject: Y-03A (PTD #2042350) Increase in IA pressure Hi Jim and Tom, Well Y-03A (PTD #2042350) has shown an increase in IA pressure as evidenced in the attached 30-day TIO plot. The well is on the schedule to bleed the IA pressure and monitor the build-up rate. While this increase in pressure may be contributed to the increase in rate an evidenced in the attached Injection Plot, this notification is to ensure compliance with the Area Injection Order. « File: Y-03A TIO plot.BMP » « File: Y-03A Injection PIot.BMP » Once the IA pressure has been bled and monitored for a few days, an update with any additional planned actions will be sent. The well will also be added to the Monthly Injection Report for at least the month of June. Please let us know if you have any questions. Thank you, Anna tube, ~? 2. 9/5/2008 • ~ ~ ~ ~ a~ ll T yy T ._9 .n O ~_ [+} ~J I G.~ ~ ~ d 'O O O O O y T oa 0 a r~ 0 0 ~ ~~ ---r a o 0 ° o ° o o ~ ~r c+~ cv [i. L7 c c c c PBU Y-03A PTD 204-235 6/ 10/2008 4,000 3,000 I'`. t~.4Ar'+.SP 2,000 Y-03 TIC Plot OA MAASP T I ,VVV r f~ . ~~,, ~~-.-~-rte'- -.- ooaa SM 0!2008 SM 5x1008 Sf2012008 5/2502008 503002008 614x2008 6M 002008 6M 50100$ 6!2002008 6l25t2008 6x3002008 7/502008 • • • a_ + _ Avg 1AIFiIP, prig aaa'tr ooo's aaa'~ aaa' 4 0 ~~ ~~ 1 i 0 0 T d d T ~J O `~`~~ AV W •~ W ~~ r~ V •~ Pn I 1~ J Q ja is T r T M1 O O O r I^~ O O r h- 0 0 T 7 OdlMA810~~4Y `II~kSlU~ka+Ii~kdll~Wt~~ r}I ~I C~ • • ~; MICROFILMED Q3/41/20~8 DO NOT PLACE ..-~,° ~. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicl~\CvrPgs_Inserts\Microfilm Marker.tbc J 7 J",,- À-I..;) ~7 DATA SUBMITTAL COMPLIANCE REPORT 12/11/2006 MD 12725 /"" TVD 8997 /' Completion Date 12/17/2004 / Completion Status WAGIN Current Status WAGIN Jf1£{.¿ ã> ~ ÑM i API No. 50-029-20411-01-00 ~ Permit to Drill 2042350 Well Name/No. PRUDHOE BAY UNIT Y-03A Operator BP EXPLORATION (ALASKA) INC -_.~- REQUIRED INFORMATION Mud Log No Name Interval Start Stop Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OHI . Scale Media No Start Stop CH Received Comments 8098 12725 1/27/2005 IIFR 8098 12725 1/27/2005 MWD 5 Blu 8000 9230 2/11/2005 USIT/GR/CCL 7731 12675 1/31/2006 GRlEWR4/ABI/ROP 7731 12675 1/31/2006 GR/EWR4/ABI/ROP 1-2 7971 8997 5/10/2006 DGR EWR 3-0ct-2004 7731 12682 Open 5/10/2006 GR, ROP Sample Set Sent Received Number Comments DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name ŒD D Asc Directional Survey ub D Asc Directional Survey 0: Cement Evaluation ~t D Lis 13438 I nd u ctionlResistivity Lis 13438 Induction/Resistivity ~ C Pdf 13887 I nd uction/Resistivity oH5 C Lis 13887 I nd uctionlResistivity Well CoreslSamples Information: ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~/N &/N . Chips Received? ...>H-N-' ~ Formation Tops Analysis Received? -,-~,-- Comments: Compliance Reviewed By: ¡h Date: pJ~~ 7 . õ i'f' r é)o~ - <935- . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 April 27, 2006 RE: MWD Fonnation Evaluation Logs Y-03A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 Y -o3A: LAS Data & Digital Log Images: 50-029-20411-01 1 CD Rom rf)tf.-{-:ì3S- t;f 15'/ D ~ c. JJr-- l~3t1-- . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 13, 2006 RE: MWD Formation Evaluation Logs: Y-03A, 1343$ ~04 - cQ.35 AK -MW -3429877 1 LDWG formatted Disc with verification listing. API#: 50-029-20411-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMIIT AL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:DI~II~ Signed~~h MEMORANDUM State of Alaska TO: Jim Regg P.I. Supervisor . ~1l 4'{'t1/0:)' Alaska Oil and Gas Conservation comm. DATE: Wednesday, Apríl13, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC ¥-03A PRUDHOE BA ¥ UNIT ¥-03A FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ~.?' P.I. Suprv 'Jg-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT Y-03A Insp Num: mitCS050409175136 Rei Insp Num: API Well Number: 50-029-20411-01-00 Permit Number: 204-235-0 Inspector Name: Chuck Scheve Inspection Date: 4/9/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i ¥-03A 'Type Inj. ! P I TVD , 8676 i IA 100 2400 2360 2350 I I i I I P.T. ! 2042350 !TypeTest ¡ SPT I Test psi 2169 I OA 350 520 520 520 520 I Interval INITAL P/F P Tubing 900 900 900 900 Notes: Pre-test pressures observed and found stable. Wednesday, April 13, 2005 Page 1 of I a STATE OF ALASKA . RECEI\/ED ALAS~L AND GAS CONSERVATION COM . SION MAR .2 9 20 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 05 Alask. Oil R, r.AIl' f"nno. ro' '. Revised: "1)3'J28IðS,''''I.R~''n Anr.hf\Tsg¡ 1b. Well Class: o Development 0 Exploratory o Stratigraphic 1m Service 12. Permit to Drill Number 204-235 13. API Number 50- 029-20411-01-00 14. Well Name and Number: .. No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 1m WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD DIR I GR, USIT, MWD DIR / GR I RES I ABIIIFR CAZ CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEÞTH WD HOLE lOP BoTTOM lOP Bo1'TOM Size Surface 110' Surface 110' 36" Surface 2689' Surface 2689' 17-1/2" Surface 8184' Surface 7939' 12-1/4" 8024' 9248' 7779' 8825' 8-1/2" 9092' 12725' 8714' 8997' 6-1/8" 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: 1250' SNL, 4732' WEL, SEC. 34, T11 N, R13E, UM Top of Productive Horizon: 483' NSL, 4623' WEL, SEC. 27, T11N, R13E, UM Total Depth: 1961' NSL, 5211' WEL, SEC. 27, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 645361 . y- 5949016 Zone- ASP~_ TPI: x- 645432 y- 5950751 Zone- ASP4 Total Depth: x- 644813 y- 5952217 Zone- ASP4 18. Directional Survey 1m Yes 0 No 22. CASING SIZE 20" x 30" 13-3/8" 9-5/8" WT.PERFr. Insulated 72# 47# 26# 12.6# GRADE Conductor L-80 L-80 L-80 L-80 7" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 6 spf MD TVD MD TVD 12420' - 12600' 8977' - 8990' 12610' - 12630' 8990' - 8992' 26. Date First Production: March 18, 2005 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. 12/17/2004 6. Date Spudded 12/8/2004 7. Date T.D. Reached 12/13/2004 8. KB Elevation (ft): 79.04 9. Plug Back Depth (MD+ TVD) 12641 + 8992 10. Total Depth (MD+TVD) 12725 + 8997 11. Depth where SSSV set (Nipple) 2196' MD 19. Water depth, if offshore NIA MSL PBU Y -03A 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028287 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PUlLED 10 cu yds Concrete 3720 cu ft Permafrost II 1225 cu ft Class 'G', 133 cu ft PF 264 cu ft Class 'G' 533 cu ft Class 'G' 24. TUBING RECOFlD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 9097' PACKER SET (MD) 9040' 25. ACID,FRACTURE, CEMENTSQUEEZE,ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 151 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oll-Bsl GAs-McF WATER-Bsl Oll-Bsl 27. GAs-McF WATER-Bsl 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). Submit core chips; if none, state "none". f(fDt~;" .~; ;-: None .¡!: G.". ..j.f,.''/~ b~.~."..j .'." I VEhi¡·:,'., , " t,/fIJb_....¡ ~.__C'i'~_._,,-.t Form 10-407 Revised 12/2003 i\1 l-'fiBDMS BFL MAR 3 1 2005 CONTINUED ON REVERSE SIDE GF' !8. GEOLOGIC MARKE» NAME MD Sag River 9248' Shublik A 9276' Shublik B 9320' Shublik C 9350' Sadlerochit 9390' 29. .ORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". rvD 8825' None 8844' 8875' 8894' 8918' 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 ~ ~ J ~ Title Technical Assistant Date Ó 3(:;J..R! OS PBU Y -03A 204-235 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Jim Smith, 564-5773 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 __ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION CO.SION 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 25.110 21. Logs Run: MWD DIR I GR, US IT, MWD DIR / GR / RES I ABI/IFR CAZ CASING, LINER AND CEMENTING RECORD SETTING DEPTHMO SETTING DEPTH TVD HOLE lOP BoTTOM lOP BoTTOM SIZE Surface 110' Surface 110' 36" Surface 2689' Surface 2689' 17-1/2" Surface 8184' Surface 7939' 12-1/4" 8024' 9248' 7779' 8825' 8-1/2" 9092' 12725' 8714' 8997' 6-1/8" 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: 1250' SNL, 4732' WEL, SEC. 34, T11 N, R13E, UM Top of Productive Horizon: 483' NSL, 4623' WEL, SEC. 27, T11 N, R13E, UM Total Depth: 1961' NSL, 5211' WEL, SEC. 27, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 6453~_ y- 5949016 Zone- ASP4 TPI: x- 645432 y- 5950751 Zone- ASP4 Total Depth: x- 644813 y- 5952217 Zone- ASP4 _·______________.___.__u~ _________________ ..._________.-_.U.Od_ 18. Directional Survey 1m Yes 0 No 22. CASING SIZE 20" x 30" 13-3/8" 9-518" WT. PER FT. Insulated 72# 47# 26# 12.6# GRADE Conductor L-80 L-80 L-80 L-80 7" 4-1/2" 23. Perforations open to Production (MD + rvD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 6 spf MD rvD MD rvD 12420' - 12600' 8977' - 8990' 12610' - 12630' 8990' - 8992' 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. 12/17/2004 6. Date Spudded 12/812004 7. Date T.D. Reached 12/13/2004 8. KB Elevation (ft): 79.04 9. Plug Back Depth (MD+ rvD) 12641 + 8992 10. Total Depth (MD+rvD) 12725 + 8997 11. Depth where SSSV set (Nipple) 2196' MD 19. Water depth, if offshore NI A MSL 24. SIZE 4-1/2", 12.6#, L-80 1 b. Well Class: o Development 0 Exploratory o Stratigraphic 1m Service 12. Permit to Drill Number 204-235 13. API Number 50- 029-20411-01-00 Well Name and Number: :,M.~PBU Y-03A .{'. 15.Fielàl'~oQ/(~Vt''" J~u~o~ Bay ~~jPrudhoe Bay PoofÌ {J Ft ; 16":Þ~r~tDe\1l~on: . 4,:1 ADL '~7 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTINGRECOAD 10 cu yds Concrete 3720 cu ft Permafrost II 1225 cu ft Class 'G', 133 cu ft PF 264 cu ft Class 'G' 533 cu ft Class 'G' AMOUNT PUllED TUBINGiRECÖAD DEPTH SET (MD) 9097' PACKER SET (MD) 9040' 25. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATEAIAl USED Freeze Protect with 151 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oll-Bsl GAs-McF WATER-Bsl Oll-Bsl 27. GAs-McF WATER-Bsl 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). Submit core chips; if none, state "none". rrè;,\.,,··.:::.·..·.······: None :;~~~: ~~ ~ t ., f Form 1 0-407 Revised 12/2003 RBDMS 8Ft JAN 2 4 Z005 CONTINUED ON REVERSE SIDE . ,; G'" 28. GEOLOGIC MARK. NAME MD TVD Sag River 9248' 8825' Shublik A 9276' 8844' Shublik B 9320' 8875' Shublik C 9350' 8894' Sadlerochit 9390' 8918' 29. . FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 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 /fÔ~. ~ Title Technical Assistant PBU Y -03A Well Number 204-235 Permit No. / Approval No. INSTRUCTIONS Date 0 (- { 7 -tl c:; Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 JIm Smith, 564-5773 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 18: 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 Legal Name: Y-03A Common Name: Y-03A 12/7/2004 12/11/2004 FIT FIT 8,216.0 (It) 9,268.0 (It) 7,971.0 (It) 8,825.0 (It) 10.60 (ppg) 8.40 (ppg) 580 (psi) 641 (psi) 4,969 (psi) 4,492 (psi) 12.00 (ppg) 9.80 (ppg) . . Printed: 12/27/2004 8:57:32 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y -03A Y -03A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 11/15/2004 End: 12/18/2004 11/29/2004 12/17/2004 Note: All rig equipment on location at 22:00 hrs on 11/30/04 Standing by on Y Pad. Wait on weather/winds to improve to remove well houses and flow lines allowing rig access to Y -03A. Standing by with crews on Y Pad. Wait on weather/winds to improve to remove well houses, snow and flow lines allowing rig access to Y-03A. Raise derrick and prep rig floor. Standing by with crews on Y Pad. Wait on weather/winds to improve to remove well houses, snow and flow lines allowing rig access to Y-03A. Standing by with crews on Y Pad. Wait on weather/winds to improve to remove well houses, snow and flow lines allowing rig access to Y -03A. Well houses removed. Removing flow lines. Clearing snow from area. Removing flow lines. Clearing snow from area. Lay Herculite And Spot Sub Base Over Well - Rig Up Rig Floor. Lay Herculite And Position Pit Complex - Hook Up Utilities. Position Pit Complex - Spot Truck Shop And Welding Shop - Hook Up Utilities And Service Lines From Sub Base To Pit Complex - Set Cutting Tank And Berm DECOMP *NOTE* Rig Accepted For Well Work On Y-03A At 14:00 On 12-04-2004 Hold Pre-Spud And Environmental Meeting With All Personal Regarding Y-03A Well Operations. Rig Up DSM And Pull BPV DECOMP Held PJSM - Rig Up Circulating Lines And Circulate Out Freeze Protection To Cuttings Tank From Tubing. Switch Lines and Pump 40 BBLS Soap Down Tubing At 6 BPM, 850 PSI. Confirm Well Is Dead. Install TWC valve and test from below to 1,000 psi. Good Test. Blow down all lines. Nipple down tree and adapter flange. Secure tree in cellar. Check threads on tubing hanger Held PJSM - Nipple Up BOP And Related Equipment Held PJSM - Nipple Up BOP And Related Equipment Hold Pre-Job Safety Meeting - Install Test Plug - Rig Up Testing Equipment - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Chuck Scheve - Test Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 4,000 Psi. High - Test Annular At 250 Psi Low And 3,500 Psi High - Rig Down Testing Equipment 11/29/2004 15:00 - 21 :00 6.00 MOB P PRE 21 :00 - 00:00 11/30/2004 00:00 - 22:00 3.00 MOB 22.00 MOB P P PRE PRE 22:00 - 00:00 2.00 MOB N WAIT PRE 12/1/2004 00:00 - 00:00 24.00 MOB N WAIT PRE 12/2/2004 00:00 - 00:00 24.00 MOB N WAIT PRE 12/3/2004 00:00 - 16:00 16.00 MOB N WAIT PRE 16:00 - 00:00 8.00 MOB N WAIT PRE 12/4/2004 00:00 - 07:30 7.50 MOB N WAIT PRE 07:30 - 14:00 6.50 RIGU P PRE 14:00 - 15:30 1.50 DHB P 15:30 - 20:00 4.50 WHSUR P 20:00 - 20:30 0.50 DHB P DECOMP 20:30 - 22:00 1.50 WHSUR P DECOMP 22:00 - 00:00 2.00 BOPSUF P DECOMP 12/5/2004 00:00 - 00:30 0.50 BOPSUF P DECOMP 00:30 - 04:30 4.00 BOPSUF P DECOMP Blow Down And Disconnect Utilities Between Pit Complex And Sub Base - Move Cuttings Tank - Lower Cattle Shoot - Lay Mast Over And Pull Sub Base Off Of Well - Have Pre-Job Safety Meeting With Security, CPS, And Rig Team Pull sub base off well and transport sub base to Y-Pad Move Sub Base, pits, camp and equipment From DS 05-24 To Y-03A Printed: 12/27/2004 8:57:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y -03A Y -03A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/29/2004 12/17/2004 Spud Date: 11/15/2004 End: 12/18/2004 12/5/2004 04:30 - 05:30 1.00 WHSUR P DECOMP Held PJSM - Rig Up DSM Lubricator - Pull TWC - Rig Down And Clear Rig Floor 05:30 - 06:30 1.00 PULL P DECOMP Make Up Landing Joint And Crossovers. Back out lock down screws. Pull tubing hanger to rig floor. Pulled free with 145K up weight. Lay down hanger. 06:30 - 07:30 1.00 PULL P DECOMP PJSM. Rig up tubing equipment. Rig up control line spooler. 07:30 - 10:30 3.00 PULL P DECOMP Pull out and lay down 4.5",12.6# tubing from 8,250' to 6,210'. Lay down SSSV. Rig down control line spooler. Recovered 3 SS bands and 25 clamps. 10:30 - 17:00 6.50 PULL P DECOMP Continue POH laying down tubing from 6,210' to surface. 'NOTE' Items Recovered During Decompletion: 1 Tubing Hanger And Pup 3 Stainless Steel Bands 25 Clamps - 25 Pins 197 Joints Of 4 1/2" Tubing 4 GLM With Pup Joints Top And Bottom 1 SSSV With Pup Joints Top And Bottom 1 Cut Off Joint 18.95' Long Clear and clean rig floor. 17:00 - 18:30 1.50 DHB P DECOMP Rig up Sch. wireline. 8.5" gauge ring would not make up to adapter ring. Investigated and found incompatible threads. No other parts on location. 18:30 - 20:30 2.00 DHB P DECOMP Made up and set test joint and tested top and bottom rams to 250 psi low by 4,000 psi high. Tested annular to 250 psi low and 3,500 psi high. Good test. Ran wear bushing and lay down test equipment. Note: Schlumberger to get proper threaded gauge ring from their shop.) 20:30 - 23:30 3.00 DHB P DECOMP PJSM. Make up 8.54" GR with JB and CCL. RIH to tag at 8,244' WLM. Collar located at 8,210' WLM. POOH. 23:30 - 00:00 0.50 DHB P DECOMP Junk basket loaded with scale and remnants of control line encapsulation material. Clean out and re-run GR/JB/CCL. 12/6/2004 00:00 - 02:00 2.00 DHB P DECOMP Continue RIH with GR/JB/CCL. Tag up at 8,239'. Collar verified at 8,210' WLM. POOH with wireline. JB contained small amount of scale and encapsulation debris. 02:00 - 03:00 1.00 DHB P DECOMP Lay down GR BHA. Held PJSM. MU 9-5/8" 47# casing EZSV and setting tools. 03:00 - 05:00 2.00 DHB P DECOMP RIH With GR-CCL And Haliburton EZSV Packer And Set Top Of EZSV At 8,206' WLM - Positive Surface Indication Of Packer Setting - RIH Tag EZSV Confirm Setting Depth - POH With Logging Tools 05:00 - 05:30 0.50 DHB P DECOMP Rig down schlumberger wireline equipment. Clean and clear rig floor. 05:30 - 06:00 0.50 DHB P DECOMP Pressure test the 9-5/8" casing to 4,000 psi against the EZSV for 30 minutes. 06:00 - 10:00 4.00 STWHIP P WEXIT PJSM. Pick up whipstock assembly. Make up BHA to 1,007'. Change out elevators. Pick up one joint of drill pipe and break circulation. Blow down TDS. 10:00 - 11 :30 1.50 STWHIP N RREP WEXIT Troubleshoot TDS brake. 11 :30 - 16:00 4.50 STWHIP P WEXIT Pick up drill pipe from pipe shed from 1,007' to 6,141'. 16:00 - 17:00 1.00 STWHIP N RREP WEXIT Replace master cylinder on TDS. 17:00 - 19:00 2.00 STWHIP P WEXIT Continue picking up drill pipe from pipe shed from 6,141' to Printed: 12/27/2004 8:57:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-03A Y-03A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/29/2004 12/17/2004 Spud Date: 11/15/2004 End: 12/18/2004 12/6/2004 17:00 - 19:00 2.00 STWHIP P WEXIT 8,164'. 19:00 - 21 :00 2.00 STWHIP P WEXIT Rig up wireline. 21 :00 - 23:00 2.00 STWHIP P WEXIT Make up Gyrodata tools and run in hole on wire line to 8,207'. String Weight Up 205,000#, String Weight Down 180,000#- Worked String To Orient Whipstock. Slacked Off And Tripped Anchor With 20,000# - Whipstock Set At 45 Degrees - Picked Up On String 10,000# Above Neutral Weight to Verify That Whipstock Set. Slacked Off 40,000# To Shear Retaining Bolt. *NOTE* Tagged Bridge Plug With Bottom Of Whipstock At 8,207' (DPM) Top of Whipstock @ 8,184' MD 23:00 - 00:00 1.00 STWHIP P WEXIT POOH with wireline. Lay down Gyrodata tools and rig down wireline. 12/7/2004 00:00 - 00:30 0.50 STWHIP P WEXIT Complete rigging down Schlumberger wireline. 00:30 - 01 :30 1.00 STWHIP P WEXIT Held PJSM With Truck Drivers, Drilling Crews, And Service Personnel Regarding Mud Displacement - Pumped 15 Barrel Hi-Vis Spacer Followed Up With 539 BBLS 10.6 PPG LSND Mud At 12 BPM With 1,700 Psi. 01 :30 - 12:00 10.50 STWHIP P WEXIT Recorded Slow Pump Rates w/ New Mud System. Milli window in 9-5/8" casing from 8,184' to 8,200'. Drill new formation to 8,216'. Work pipe across window, pump sweep and clean the hole. Recovered - 200# of metal. Top of window at 8,184' Bottom of window at 8,200' 12:00 - 12:30 0.50 STWHIP P WEXIT Perform FIT to 12 ppg EMW with 580 psi surface pressure and 10.6 ppg fluid - good test. 12:30 - 13:00 0.50 STWHIP P WEXIT Flow check the well - stable. Pump dry job. 13:00 - 15:30 2.50 STWHIP P WEXIT POH standing back 4" DP from 8,216' to top of BHA @ 1,007'. 15:30 - 19:30 4.00 STWHIP P WEXIT Standback De's and HWDP. LD mills. Clean under rotary table. Pull wear ring. Flush the stack. Blow down all surface lines. Run wear ring. Clear floor. 19:30 - 22:30 3.00 STWHIP P WEXIT MU 8-1/2" Drilling BHA. MU bit, motor and MWD/LWD. Orient and upload tools. Set UBHO and test MWD/LWD - good. PU flex collars and remaining BHA to 1,172'. 8-1/2" Drilling BHA - 8-1/2" Hughes HCM 0912 RR/RB, 7" SperryDrill - 7/8 - 6 stg, non-mag float sub, 6-3/4" GR, 6-3/4" DM HOC, 6-3/4" TM HOC, non-mag UBHO sub, 3 x non-mag flex collars, 9 x drill collars, 5 x HWDP, jar, 18 x HWDP, xo. 22:30 - 23:00 0.50 STWHIP P WEXIT PU 4" DP from 1,172' to 2,104'. 23:00 - 00:00 1.00 STWHIP P WEXIT Slip and cut drilling line. 12/8/2004 00:00 - 01 :00 1.00 STWHIP P WEXIT Service top drive and brakes. 01 :00 - 03:00 2.00 STWHIP P WEXIT RIH w/4" DP from 2,104' to 8,134'. 03:00 - 03:30 0.50 STWHIP P WEXIT Install blower hose. Orient and slide through window with pumps off to 8,205'. Ream undergauge hole from 8,205' to 8,216'. 03:30 - 00:00 20.50 DRILL P INT1 Directional drill from 8,216' to 9,150'. AST - 12.56, ART - 2.88. PU - 215K, SO - 175K, ROT - 195K, TO on - 9k, TO off - 8k 12/9/2004 00:00 - 02:00 2.00 DRILL P INT1 Directional drill from 9,150' to 9,248' (TD). PU - 215K, SO- 175K, ROT - 195K, TO on - 9k, TO off - 8k. 02:00 - 04:00 2.00 DRILL P INT1 Circulate bottoms up for samples. Circulate hi-vise sweep and clean up the hole prior to short trip. Monitor well - stable. Printed: 12/27/2004 8:57:37 AM of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y -03A Y -03A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/29/2004 12/17/2004 Spud Date: 11/15/2004 End: 12/18/2004 12/9/2004 04:00 - 04:45 0.75 DRILL P INT1 POH from 9,248' to 8,240'. 04:45 - 06:30 1.75 DRILL P INT1 MAD pass from 8,240' to 7,760'. 06:30 - 07:30 1.00 DRILL P INT1 Service top drive and adjust the brakes. 07:30 - 08:00 0.50 DRILL P INT1 RIH w/4" DP from 7,760' to 9,248'. No problems. 08:00 - 10:00 2.00 DRILL P INT1 Pump hi-vise sweep and circulate bottoms up @ 9,248' - 500 gpm - 3,000 psi. Spot liner running pill. Monitor well - stable. Pump dry job. Blow down top drive. Drop 2-3/8" rabbitt. 10:00 - 13:00 3.00 DRILL P INT1 POH w/4" DP from 9,248' to 8,184' - no problems. Remove blower hose. POH from 8,184' to top of the BHA @ 1,171 '. 13:00 - 16:30 3.50 DRILL P INT1 LD BHA. Flush and download MWD. LD motor and bit. Clean and clear the floor. Bit Graded: 1 / 1 / BT / M / X / I / N /TD 16:30 - 19:00 2.50 CASE P LNR1 RU casing handling tools to run 7" 26# L-80 BTC-M liner. PU 7" float equipment, bakerloc connections, and RIH. Check floats - holding. PU remaining 7" liner, Baker HMC Hanger, ZXP Packer w/C-2 running tool to 1,260'. Changeout handling equipment and clear floor. 19:00 - 20:00 1.00 CASE P LNR1 Circulate liner volume. 20:00 - 23:30 3.50 CASE P LNR1 RIH w'7" Liner on 4" DP from 1,260' to 8,183'. Fill pipe every 1 0 stands 23:30 - 00:00 0.50 CASE P LNR1 Circulate Liner and DP volume - 6 bpm - 650 psi. 12/10/2004 00:00 - 00:30 0.50 CASE P LNR1 Circulate Liner and DP volume - 6 bpm - 650 psi. 00:30 - 01 :30 1.00 CASE P LNR1 RIH w'7" Liner on 4" DP from 8,183' to 9,248'. Top of Tieback Sleeve - 8,024' Top of ZXP Packer - 8,035' Top of HMC Hanger - 8,042' Baker Insert Landing collar - 9,162' HES Float Collar - 9,204' HES Float Shoe - 9,428' 01 :30 - 04:00 2.50 CASE P LNR1 Circulate 2 bottoms up and condition mud for cement job. Hold PJSM. 04:00 - 05:30 1.50 CEMT P LNR1 Pump cement job as follows: Pump 3 bbls of fresh water through "T" Pressure test lines to 4,500 psi Pump 2 bbls 11.7 ppg Mudpush to flush water from the lines through the "T". Pump 34 bbls of 11.7 ppg Mudpush Spacer Mix and pump 47 bbls 15.8 ppg Class G cement + adds. Flush lines with 5 bbls of 10.6 ppg mud through "T". Drop dart and displace with 10.6 ppg fluid with Dowell cementing unit. Pick up plug @ 80 bbls pumped. Bump plug w/ 3,500 psi @ 125 bbls pumped - CIP 0530 12/10/2004 05:30 - 06:00 0.50 CASE P LNR1 SO on top of hanger. Bleed off pressure and check floats - holding. Rotate 15 turns to the right to release from hanger. Increase pressure to 1,000 psi and PU. Observe pressure decrease and increase pump rate to 468 gpm for 500 stks to get the cement off of the top of the liner. SO with 15 rppm and observe the packer set. PU and SO on top of the packer 2 Printed: 12/27/2004 8:57:37 AM of 8 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-03A Y -03A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 11/29/2004 12/17/2004 Spud Date: 11/15/2004 End: 12/18/2004 12/10/2004 05:30 - 06:00 0.50 CASE P LNR1 times to ensure set. 06:00 - 07:00 1.00 CASE P LNR1 Circulate bottoms up @ 12.5 bpm - 3,300 psi. Circulated - 5 bbls of cement returns. Condition mud. Pump dry job. 07:00 - 08:00 1.00 CASE P LNR1 Break and LD cement head, valves and hoses. Blow down surface lines and clear the floor. Clean out possumbellies and cement from under the shakers 08:00 - 11 :00 3.00 CASE P LNR1 POH from 8,024' w/4" DP. LD C-2 liner running tool. Clear the floor. 11 :00 - 13:30 2.50 DRILL P PROD1 MU 6-1/8" BHA. MU bit, motor and MWD. Uplaod MWD. PU flex collars and shallow test the MWD - good. 6-1/8" BHA: 6-1/8" Hughes HeM 406 RR, 5" Sperrydrill 6/7 - 6 stg w/abi, non-mag float sub, GR/RES, DM HOC, TM HOC, 3 x non-mag flex dc's, circ sub, xo, 6 x 4" DP, xo, DNT jar, xo. 13:30 - 17:30 4.00 DRILL P PROD1 PU 4" DP to 5,065'. Fill pipe every 3,000'. 17:30 - 18:00 0.50 CASE P LNR1 Pressure test casing to 4,000 psi - good. Blow down surface equipment. 18:00 - 19:30 1.50 DRILL P PROD1 RIH w/4" DP from 5,065' to 9,079'. Fill pipe every 3,000'. 19:30 - 20:30 1.00 DRILL P PROD1 Cut and slip drilling line. 20:30 - 21 :00 0.50 DRILL P PROD1 Service top drive and lubricate rig. 21 :00 - 22:30 1.50 DRILL P PROD1 Drill cement and float equipment from 9,153' to 9,246'. 22:30 - 00:00 1.50 DRILL P PROD1 Displace the well over to 8.4 ppg Flopro drilling fluid - 320 gpm - 1,750 psi. 12/11/2004 00:00 - 00:30 0.50 DRILL P PROD1 Drill Float Shoe and 20' of new formation to 9,268'. Pull back into the casing shoe. Perform FIT to 9.8 ppg EMW with 8.4 ppg Flopro and 640 psi surface pressure - good test. 00:30 - 12:00 11.50 DRILL P PROD1 Drill 6-1/8" directionally from 9,268' to 9,917'. PU - 175K, SO- 160K, ROT - 170K, TO on - 6K, TO off - 4K, AST - 1.84, ART - 6.01, 324 gpm, 2,230 psi. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6-1/8" directionally from 9,917' to 10,815'. PU - 175K, SO - 145K, ROT - 165K, TO on - 6K, TO off - 4K, AST - 4.67, ART - 3.17, 324 gpm, 2,230 psi. 12/12/2004 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6-1/8" directionallyfrom 10,815' to 11,413'. PU -175K, SO - 145K, ROT - 165K, TO on - 7K, TO off - 4K, 324 gpm, 2,250 psi. AST - 5.74, ART -1.17. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6-1/8" directionally from 11,413' to 12,413'. PU - 180K, SO - 145K, ROT - 165K, TO on -7K, TO off - 5K, 324 gpm, 2,460 psi. AST - 5.74, ART - 1.17. 12/13/2004 00:00 - 03:45 3.75 DRILL P PROD1 Drill 6-1/8" directionally from 12,413' to 12,725' (TD). PU- 180K, SO - 140K, ROT - 165K, TQ on - 7K, TO off - 6K, 324 gpm, 2,460 psi. AST - 0.49, ART - 1.9. 03:45 - 05:30 1.75 DRILL P PROD1 Circulate sweep around @ 323 gpm, 2100 psi. 05:30 - 07:30 2.00 DRILL P PROD1 Short trip from 12,725' to 9,203' - inside 7" shoe. 07:30 - 08:30 1.00 DRILL P PROD1 Service the top drive and the rig. 08:30 - 10:00 1.50 DRILL P PROD1 RIH from 9,203 to 12,725' (TD). Lost 22 bbls on the short trip. 10:00 - 13:00 3.00 DRILL P PROD1 Circulate high vise Safe-Carb sweep - 324 gpm, 2000 psi. Spot liner running pill. Monitor well - static. 13:00 - 15:00 2.00 DRILL P PROD1 POH standing back 4" DP from 12,725' to 9,248' - no problems. Monitor well - static. Drop dart and open circ sub. Pump dry job and blow down the top drive. 15:00 - 17:30 2.50 DRILL P PROD1 POH standing back 4" DP from 9,248' to 212'. 17:30 - 20:00 2.50 DRILL P PROD1 Flush MWD tools. Blow down the top drive. Download MWD tools. LD BHA and clear the floor. Printed: 12/27/2004 8:57:37 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y -03A Y -03A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: Rig Release: Rig Number: 11/29/2004 12/17/2004 Spud Date: 11/15/2004 End: 12/18/2004 12/13/2004 17:30 - 20:00 2.50 DRILL P PROD1 Bit graded: 2/ 1 / CT / N / X / I / ER / TD 20:00 - 00:00 4.00 EVAL P LNR1 RU Schlumberger. RIH with USIT to 9,248'. POH and RD Schlumberger. 12/14/2004 00:00 - 01 :00 1.00 CASE P LOWER1 Hold PJSM with all crew members. RU 4-1/2" liner handling equipment. 01 :00 - 05:00 4.00 CASE P LOWER1 PU float equipment, Bakerloc and RIH. Check floats - holding. RIH with 4-1/2", 12.6#, L-80, IBT-M liner to 3,633'. MU HMC/ZXP hanger assembly on HR running tool and RIH on stand of 4" DP to 3,733'. Applied Best-a-Life thread compound with avg MU torque - 3,900 ft-Ibs. 05:00 - 05:30 0.50 CASE P LOWER1 Circulate liner volume. 05:30 - 09:30 4.00 CASE P LOWER1 RIH with 4-1/2" Liner on 4" DP from 3,733' to 9,240'. Fill pipe every 10 stands. 09:30 - 10:00 0.50 CASE P LOWER1 Circulate Liner and DP volume - 4 bpm, 480 psi. PU - 160K., SO - 145K 10:00 - 13:00 3.00 CASE P LOWER1 RIH w/4" DP from 9,240' to 12,699'. RU cement head, valves and hoses. Break circulation and tag bottom @ 12,725'. PU- 190K, SO - 150K. Set liner on bottom. Top of Liner Tie-back Sleeve @ 9,092' Top of ZXP Packer @ 9,103' Top of HMC Liner Hanger @ 9,114' Top of Insert Landing Collar @ 12,641' Top of Float Collar @ 12,682' Top of Float Shoe @ 12,723' 13:00 - 14:30 1.50 CEMT P LOWER1 Circulate and stage up the pumps to 6 bpm, 1,240 psi. Hold PJSM while circulating. 14:30 - 16:30 2.00 CEMT P LOWER1 Pump 5 bbls water ahead through "T". Shut down and test Ines to 4,000 psi. Bleed pressure and mix 9.5 ppg MudPush Spacer. Flush water from lines with 5 bbls 9.5 MudPush spacer. Pump 30 bbls 9.5 MudPush at 4 bpm, 1000 psi. Pump 95 bbls 15.8 ppg Class G + adds Tail Slurry at 5 bpm, 1600 psi initial, 1200 psi final. Shut down and wash down lines through "T". Drop dart. Displace with 65 bbls perf pill using Schlumberger @ 5.5 bpm, 350 psi. Switch to displacing with 8.5 ppg FloPro. Observed dart latch at 92 bbls away. Drop rate to bump plug. Bumped the plug to 3500 psi and set hanger with 145 bbls total displacement. Increase pressure to 4,500 psi to release running tool. Release pressure and check floats - holding. PU and extend dogs. Weight set packer. Pressure up DP to 1000 psi. Unsting running tool. Observe pressure drop. CIP @ 15:20 hours. 16:30 - 17:30 1.00 CEMT P LOWER1 Circulate bottoms up @ 9,091' - 13 bpm, 2400 psi. 17:30 - 19:00 1.50 CEMT P LOWER1 Displace the well over to clean seawater - 7 bpm, 1000 psi. Clean surface equipment. 19:00 - 19:30 0.50 CEMT P LOWER1 LD cement head, valves and hoses. Clear and clean the floor. Printed: 12/27/2004 8:57:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y -03A Y -03A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/29/2004 12/17/2004 Spud Date: 11/15/2004 End: 12/18/2004 12/14/2004 19:30 - 21 :00 1.50 CASE P LOWER1 Cut and slip drilling line. Lubricate the rig and the top drive. 21 :00 - 00:00 3.00 CASE P LOWER1 POH standing back 4" DP from 9,091' to the top of the liner running tool. 12/ 15/2004 00:00 - 01 :00 1.00 CASE P LOWER1 LD HR running tool. Clear and clean the floor. 01 :00 - 02:30 1.50 PERF P OTHCMP Hold PJSM. RU to tubing convey 8LB 2.5", 6 spf, PowerJet perforating guns. 02:30 - 04:15 1.75 PERF P OTHCMP Wait on cement compressive strength test. 04: 15 - 05:00 0.75 PERF P OTHCMP Pressure test 9-5/8" x 7" x 4-1/2" to 4,000 psi. Hold and chart for 30 minutes - good test. Blow down suface equipment. 05:00 - 09:30 4.50 PERF P OTHCMP PU 232' 8LB perforating BHA and 2-7/8" PAC DP to 3,586' 09:30 - 15:00 5.50 PERF P OTHCMP Crossover to 4" HT40 and RIH with 4" DP from 3,586' to 12,550'. 15:00 - 16:30 1.50 PERF P OTHCMP RIH to 12,640' and tag landing collar. Space out and fire 2.5", 6spf PowerJet guns. No definitive indication of guns firing. 8paceout guns and repeat process. No definitive indication of guns firing. Perf Depths: 12,420' to 12,600' and 12,610' to 12,630' 16:30 - 17:00 0.50 PERF P OTHCMP POH from 12,630' to 12,363'. Monitor well - stable. Pump dry job and blow down surface equipment. 17:00 - 22:30 5.50 PERF P OTHCMP LODP from 12,363' to 3,589'. 22:30 - 00:00 1.50 PERF P OTHCMP Change out handling tools and LD 2-7/8" PAC DP from 3,589' to 2,219'. 12/16/2004 00:00 - 02:00 2.00 PERF P OTHCMP LD 2-7/8" PAC DP from 2,219' to 232'. 02:00 - 03:30 1.50 PERF P OTHCMP Change out the handling tools and LD 2.5" perf guns. All shots fired. Clear and clean the floor. 03:30 - 04:45 1.25 PERF P OTHCMP Change out handling tools. RIH w/4" DP from the derrick. 04:45 - 07:30 2.75 PERF P OTHCMP LD 4" DP. 07:30 - 08:00 0.50 PERF P OTHCMP Pull wear ring and clear the floor. 08:00 - 09:30 1.50 RUNCOMP RUNCMP Remove saver sub. RU 4-1/2" torque turn equipment. 09:30 - 10:30 1.00 RUNCOMP RUNCMP PJSM. MU Baker 8-3 packer and 4-1/2" tailpipe assy. Tailpipe assy: WLEG, 10' pup, XN profile, 2 x 10' pups, X profile, 2 x 10' pups, packer, 2 x 10' pups, X profile, 10' pup 10:30 - 21:00 10.50 RUNCOMP RUNCMP MU 4-1/2" 12.6#, L-80, Tell tubing and tag up on liner top packer @ 9,103'. 21 :00 - 22:30 1.50 RUNCOMP RUNCMP Spaceout and land tubing hanger. PU - 130K, 80 - 115K. RILDS. X profile (3.813" ID) - 2,195' X profile (3.813" ID) - 9,020' S-3 packer - 9,040' X profile (3.813" ID) - 9,064' XN profile (3.725" ID nogo) - 9,085' WLEG - 9,097' 22:30 - 00:00 1.50 RUNCOMP RUNCMP RU circulating lines and test to 4,000 psi. Reverse circulate tubing volume of clean seawater followed by seawater w/corrosion inhibitor @ 3 bpm, 120 psi. 12/17/2004 00:00 - 02:00 2.00 RUNCOMP RUNCMP Reverse circulate seawater w/corrosion inhibitor @ 3 bpm, 200 psi. 02:00 - 04:00 2.00 RUNCOMP RUNCMP RU LRH08 and pump 151 bbls diesel freeze protect fluid down the annulus. Allow fluids to u-tube. Printed: 12/27/2004 8:57:37 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . PLORA TION ummary Report 3.00 RUNCOMP Start: Rig Release: Rig Number: 11/29/2004 12/17/2004 Spud Date: 11/15/2004 End: 12/18/2004 Y -03A Y-03A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES 12/17/2004 04:00 - 07:00 RUNCMP Drop ball and rod and allow to seat. Pressure up to 4,000 psi with LRHOS to set the packer and test the 4-1/2" tubing for 30 minutes - good test recorded on chart. Pressure test the tubing annulus to 4,000 psi, hold and chart for 30 minutes - good test. Bleed pressure off tubing and annulus. Install TWC and test from above to 1,000 psi - good. Blow down all surface equipment and RD circulation lines. ND BOPE. NU 4-1/8 5M tree and adapter flange. Pressure test tree and adapter flange to 5,000 psi - good. Pull TWC w/DSM lubricator. Dry rod install BPV. Remove secondary annulus valve and secure the well. 07:00 - 08:30 1.50 BOPSUF P POST 08:30 - 11 :00 2.50 BOPSUF P POST 11 :00 - 13:00 2.00 BOPSUF P POST 13:00 - 14:00 1.00 BOPSUF P POST 14:00 - 16:00 2.00 BOPSUP P POST 16:00 - 20:00 4.00 RIGD P POST 20:00 - 00:00 4.00 DEMOB N WAIT POST 12/18/2004 00:00 - 12:00 12.00 DEMOB N WAIT POST 12:00 - 14:00 14:00 - 18:00 18:00 - 00:00 2.00 DEMOB P 4.00 DEMOB P POST POST 6.00 DEMOB P POST Rig Released @ 1600 hrs 12/17/2004 RD floor. Bridle up. Blow down rig water. Remove derrick pins. Lower chute. Hold PJSM and lower the derrick. Standby with full crews waiting on weather and road clearing. Move tools and equipment to DS 5. Clean up location and prep for rig move. Standby with full crews waiting on weather and road clearing. Move tools and equipment to DS 5. Clean up location and prep for rig move. Prepare for rig move. Load truck shop. Pull out pit complex. Jack up the sub and prepare to move sub off of well. PJSM. Move the sub off of the well. Move the camp, shop, pits and sub to J pad. Stage sub @ J-pad. Move camp, pits and shop to DS 5-20B. Standby on J-pad with sub due to phase 2 weather conditions. Printed: 12/27/2004 8:57:37 AM . . Survey Ref: svy4465 Halliburton Sperry-Sun North Slope Alaska BPXA Y-03A Job No. AKZZ3429877, Surveyed: 13 December, 2004 Survey Report 17 December, 2004 Your Ref: API 500292041101 Surface Coordinates: 5949016.00 N, 645361.00 E (70016' 05.1647" N, 148049'28.2137" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 79.04ft above Mean Sea Level Sr-=:tn.....y-suil! c^F'HLt..:."fNt:íC SERVICES A Halliburton Company Halliburton Sperry-Sun Survey Report for Y-03A Your Ref: API 500292041101 Job No. AKZZ3429877, Surveyed: 13 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8098.44 3.220 7.800 7774.24 7853.28 1362.78 N 420.59 W 5950370.40 N 644914.17 E 1382.92 Tie On Point INC Only 8184.00 3.220 11.730 7859.66 7938.70 1367.51 N 419.78 W 5950375.15 N 644914.89 E 0.258 1387.61 Window Point 8221.98 6.060 29.830 7897.52 7976.56 1370.30 N 418.56 W 5950377.96 N 644916.05 E 8.323 1390.33 8255.26 8.360 36.840 7930.53 8009.57 1373.76 N 416.24 W 5950381.46 N 644918.31 E 7.387 1393.66 . 8286.71 10.440 40.660 7961.56 8040.60 1377.75 N 413.01 W 5950385.52 N 644921.46 E 6.901 1397.48 8313.96 12.430 42.870 7988.27 8067.31 1381.77 N 409.41 W 5950389.61 N 644924.99 E 7.476 1401.31 8349.11 14.280 44.880 8022.46 8101.50 1387.62 N 403.77 W 5950395.56 N 644930.51 E 5.426 1406.85 8380.46 15.800 46.190 8052.74 8131.78 1393.31 N 397.96 W 5950401.37 N 644936.20 E 4.968 1412.23 8407.62 17.160 47.080 8078.78 8157.82 1398.60 N 392.36 W 5950406.76 N 644941.70 E 5.093 1417.22 MWD+IIFR+MS 8442.11 18.750 47.980 8111.59 8190.63 1405.78 N 384.52 W 5950414.09 N 644949.41 E 4.680 1423.97 8473.35 20.400 49.400 8141.03 8220.07 1412.68 N 376.65 W 5950421.14 N 644957.14 E 5.496 1430.46 8502.05 22.050 51.160 8167.78 8246.82 1419.32 N 368.66 W 5950427.93 N 644965.00 E 6.162 1436.66 8535.24 23.850 52.130 8198.34 8277.38 1427.34 N 358.51 W 5950436.15 N 644975.00 E 5.542 1444.15 8566.65 25.700 53.320 8226.86 8305.90 1435.31 N 348.03 W 5950444.32 N 644985.32 E 6.100 1451.56 8594.84 27.210 53.570 8252.10 8331.14 1442.79 N 337.94 W 5950451.99 N 644995.26 E 5.371 1458.50 8628.88 29.470 54.510 8282.05 8361.09 1452.27 N 324.86 W 5950461.73 N 645008.15 E 6.767 1467.28 8658.96 31.570 55.630 8307.96 8387.00 1461.01 N 312.34 W 5950470.71 N 645020.51 E 7.233 1475.36 8688.40 33.640 56.110 8332.76 8411.80 1469.91 N 299.21 W 5950479.86 N 645033.46 E 7.086 1483.56 8721.75 35.390 56.180 8360.24 8439.28 1480.44 N 283.51 W 5950490.69 N 645048.95 E 5.249 1493.25 8751.98 36.360 56.060 8384.74 8463.78 1490.32 N 268.81 W 5950500.85 N 645063.46 E 3.217 1502.34 8780.94 37.760 56.210 8407.85 8486.89 1500.04 N 254.31 W 5950510.85 N 645077.77 E 4.844 1511.29 . 8812.46 39.270 56.560 8432.51 8511.55 1510.91 N 237.97 W 5950522.03 N 645093.90 E 4.840 1521.29 8844.18 40.940 56.650 8456.77 8535.81 1522.15 N 220.91 W 5950533.60 N 645110.74E 5.268 1531.63 8871.69 42.710 56.310 8477.27 8556.31 1532.28 N 205.62 W 5950544.03 N 645125.83 E 6.487 1540.94 8922.93 45.080 56.800 8514.19 8593.23 1551.86 N 175.97 W 5950564.17 N 645155.09 E 4.673 1558.94 8966.63 44.880 56.820 8545.10 8624.14 1568.77 N 150.12 W 5950581.58 N 645180.61 E 0.459 1574.47 9019.15 44.430 56.620 8582.46 8661.50 1589.02 N 119.26 W 5950602.42 N 645211.07 E 0.898 1593.09 9061.59 44.110 57.020 8612.85 8691.89 1605.24 N 94.47 W 5950619.11 N 645235.55 E 1.001 1607.98 9153.89 45.050 56.660 8678.59 8757.63 1640.67 N 40.23 W 5950655.59 N 645289.09 E 1.055 1640.53 9203.76 44.410 56.710 8714.02 8793.06 1659.95 N 10.91 W 5950675.43 N 645318.04 E 1.285 1658.25 9291.65 44.970 55.650 8776.51 8855.55 1694.35 N 40.44 E 5950710.82 N 645368.72 E 1.061 1689.92 9324.30 48.680 58.350 8798.84 8877.88 1707.30 N 60.41 E 5950724.15 N 645388.43 E 12.862 1701.80 9356.26 51.890 61.570 8819.27 8898.31 1719.59 N 81.70 E 5950736.85 N 645409.47 E 12.684 1712.96 9384.42 55.290 63.440 8835.98 8915.02 1730.05 N 101.80E 5950747.69 N 645429.37 E 13.203 1722.35 9418.41 58.510 68.520 8854.55 8933.59 1741.61 N 127.80 E 5950759.75 N 645455.14 E 15.696 1732.53 17 December, 2004 - 14:27 Page 2 of 6 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Y-03A Your Ref: API 500292041101 Job No. AKZZ3429877, Surveyed: 13 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9448.77 60.170 73.940 8870.04 8949.08 1750.00 N 152.51 E 5950768.61 N 645479.69 E 16.299 1739.61 9477.13 63.050 78.420 8883.53 8962.57 1755.94 N 176.73 E 5950775.02 N 645503.79 E 17.209 1744.28 9511.26 67.120 75.360 8897.90 8976.94 1762.97 N 206.87 E 5950782.64 N 645533.78 E 14.432 1749.73 9543.36 71.160 73.700 8909.33 8988.37 1770.98 N 235.77 E 5950791.20 N 645562.52 E 13.481 1756.21 9571.14 75.330 71.970 8917.34 8996.38 1778.83 N 261.17 E 5950799.54 N 645587.78 E 16.151 1762.72 . 9605.39 79.830 68.750 8924.71 9003.75 1790.07 N 292.66 E 5950811.39 N 645619.04 E 16.027 1772.30 9636.90 84.680 67.230 8928.95 9007.99 1801.77 N 321.60 E 5950823.65 N 645647.74 E 16.117 1782.47 9664.82 89.200 65.900 8930.44 9009.48 1812.86 N 347.17 E 5950835.22 N 645673.10 E 16.873 1792.20 9698.30 94.260 63.610 8929.43 9008.47 1827.12 N 377.43 E 5950850.07 N 645703.07 E 16.587 1804.87 9729.75 94.700 62.360 8926.97 9006.01 1841.37 N 405.36 E 5950864.85 N 645730.73 E 4.202 1817.63 9757.51 96.310 59.350 8924.31 9003.35 1854.82 N 429.49 E 5950878.77 N 645754.59 E 12.252 1829.80 9849.26 97.170 58.330 8913.54 8992.58 1901.96 N 507.46 E 5950927.41 N 645831.64 E 1 .448 1872.80 9941 .40 97.610 57.730 8901.69 8980.73 1950.35 N 584.97 E 5950977.28 N 645908.20 E 0.803 1917.06 10034.77 98.240 57.370 8888.82 8967.86 1999.96 N 663.01 E 5951028.40 N 645985.27 E 0.775 1962.52 10127.30 98.790 57.230 8875.12 8954.16 2049.40 N 740.02 E 5951079.31 N 646061.31 E 0.613 2007.86 10161.61 97.610 54.950 8870.22 8949.26 2068.35 N 768.20 E 5951098.80 N 646089.11 E 7.422 2025.31 10193.22 95.070 51.440 8866.73 8945.77 2087.17 N 793.35 E 5951118.10 N 646113.89 E 13.651 2042.78 10221.25 93.700 50.740 8864.59 8943.63 2104.72 N 815.09 E 5951136.07 N 646135.30 E 5.485 2059.18 10315.01 94.570 49.870 8857.83 8936.87 2164.45 N 887.05 E 5951197.17 N 646206.09 E 1.311 2115.06 10381.42 94.630 49.080 8852.50 8931.54 2207.46 N 937.37 E 5951241.15 N 646255.56 E 1.189 2155.38 10409.21 92.590 46.430 8850.75 8929.79 2226.10 N 957.89 E 5951260.19 N 646275.73 E 12.019 2172.92 . 10443.59 91.170 42.960 8849.62 8928.66 2250.53 N 982.06 E 5951285.07 N 646299.41 E 10.900 2196.04 10474.54 92.040 39.400 8848.76 8927.80 2273.81 N 1002.42 E 5951308.74 N 646319.33 E 11.836 2218.23 10502.82 93.020 38.200 8847.51 8926.55 2295.82 N 1020.13 E 5951331.10 N 646336.60 E 5.475 2239.29 10537.08 94.140 34.920 8845.37 8924.41 2323.28 N 1040.49 E 5951358.94 N 646356.43 E 10.099 2265.65 10568.20 94.510 29.900 8843.02 8922.06 2349.47 N 1057.12 E 5951385.45 N 646372.55 E 16.129 2290.93 10596.20 94.450 25.790 8840.83 8919.87 2374.15 N 1070.15 E 5951410.37 N 646385.11 E 14.635 2314.89 10629.90 94.260 21.770 8838.27 8917.31 2404.89 N 1083.70 E 5951441.37N 646398.06 E 11 .908 2344.88 10662.77 94.380 19.910 8835.79 8914.83 2435.52 N 1095.36 E 5951472.22 N 646409.12 E 5.654 2374.86 10690.19 95.000 16.990 8833.55 8912.59 2461.45 N 1104.01 E 5951498.31 N 646417.27 E 10.852 2400.29 10724.00 95.690 12.860 8830.40 8909.44 2493.97 N 1112.68E 5951530.99 N 646425.31 E 12.332 2432.31 10755.61 95.070 8.010 8827.44 8906.48 2524.91 N 1118.37 E 5951562.03 N 646430.41 E 15.401 2462.91 10783.59 94.140 3.870 8825.19 8904.23 2552.64 N 1121.26E 5951589.82 N 646432.76 E 15.118 2490.46 10818.35 93.090 358.910 8823.00 8902.04 2587.31 N 1122.10 E 5951624.49 N 646432.93 E 14.558 2525.04 10849.32 93.460 353.620 8821.23 8900.27 2618.15 N 1120.09 E 5951655.29 N 646430.32 E 17.095 2555.94 17 December, 2004 - 14:27 Page 3 of 6 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Y-03A Your Ref: API 500292041101 Job No. AKZZ3429877, Surveyed: 13 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10877.29 92.720 351.030 8819.72 8898.76 2645.83 N 1116.36 E 5951682.89 N 646426.06 E 9.617 2583.78 10911.28 92.900 346.530 8818.05 8897.09 2679.12 N 1109.75 E 5951716.05 N 646418.81 E 13.234 2617.37 10943.11 94.510 342.060 8815.99 8895.03 2709.69 N 1101.16 E 5951746.45 N 646409.63 E 14.898 2648.35 10970.52 93.950 339.650 8813.97 8893.01 2735.51 N 1092.19 E 5951772.09 N 646400.17 E 9.003 2674.60 11005.24 92.040 336.240 8812.16 8891.20 2767.64 N 1079.18 E 5951803.96 N 646386.53 E 11 .245 2707.37 . 11036.87 90.930 332.410 8811.34 8890.38 2796.13 N 1065.48 E 5951832.18 N 646372.28 E 12.603 2736.54 11064.82 89.880 328.820 8811.14 8890.18 2820.48 N 1051.77 E 5951856.26 N 646358.11 E 13.382 2761.57 11098.80 89.070 324.080 8811.45 8890.49 2848.79 N 1032.99 E 5951884.21 N 646338.79 E 14.151 2790.82 11130.65 89.320 321.790 8811.90 8890.94 2874.20 N 1013.80E 5951909.24 N 646319.11 E 7.232 2817.20 11158.92 89.070 321.500 8812.29 8891.33 2896.37 N 996.26 E 5951931.06N 646301.14 E 1.354 2840.26 11193.06 87.530 317.800 8813.31 8892.35 2922.37 N 974.17 E 5951956.64 N 646278.56 E 11.734 2867.38 11224.48 87.720 315.550 8814.61 8893.65 2945.20 N 952.63 E 5951979.05 N 646256.58 E 7.180 2891.31 11251.52 88.090 313.540 8815.60 8894.64 2964.16 N 933.37 E 5951997.63 N 646236.96 E 7.553 2911.25 11285.34 87.900 311.030 8816.78 8895.82 2986.90 N 908.37 E 5952019.88 N 646211.52 E 7.438 2935.26 11317.14 87.590 307.790 8818.03 8897.07 3007.07 N 883.82 E 5952039.57 N 646186.59 E 10.227 2956.69 11344.58 88.150 305.610 8819.05 8898.09 3023.45 N 861.84 E 5952055.53 N 646164.29 E 8.197 2974.21 11379.76 88.150 302.050 8820.19 8899.23 3043.03 N 832.64 E 5952074.54 N 646134.72 E 10.114 2995.28 11411.20 88.330 299.150 8821.16 8900.20 3059.02 N 805.59 E 5952090.01 N 646107.37 E 9.237 3012.67 11439.04 88.330 295.180 8821.97 8901.01 3071.72 N 780.84 E 5952102.23 N 646082.37 E 14.254 3026.65 11473.01 88.150 293.140 8823.01 8902.05 3085.62 N 749.86 E 5952115.53 N 646051.13 E 6.026 3042.15 11504.37 88.400 290.710 8823.95 8902.99 3097.32 N 720.78 E 5952126.66 N 646021.84 E 7.786 3055.36 . 11531.98 89.010 288.490 8824.58 8903.62 3106.58 N 694.78 E 5952135.42 N 645995.66 E 8.337 3065.96 11566.47 88.580 284.110 8825.30 8904.34 3116.26 N 661.69 E 5952144.45 N 645962.39 E 12.758 3077.36 11598.25 89.140 283.240 8825.94 8904.98 3123.77 N 630.82 E 5952151 .37 N 645931.38 E 3.255 3086.47 11626.31 89.070 284.100 8826.37 8905.41 3130.40 N 603.56 E 5952157.47 N 645903.99 E 3.075 3094.52 11720.40 88.270 284.480 8828.56 8907.60 3153.62 N 512.40 E 5952178.92 N 645812.41 E 0.941 3122.48 11753.99 84.750 282.220 8830.60 8909.64 3161.36 N 479.79 E 5952186.03 N 645779.65 E 12.446 3131.92 11785.05 84.130 281.390 8833.61 8912.65 3167.68 N 449.53 E 5952191.77 N 645749.28 E 3.325 3139.82 11812.92 83.630 280.250 8836.58 8915.62 3172.89 N 422.31 E 5952196.45 N 645721.96 E 4.445 3146.43 11847.91 84.130 278.480 8840.31 8919.35 3178.55 N 387.99 E 5952201.45 N 645687.53 E 5.229 3153.88 11879.04 84.500 275.480 8843.40 8922.44 3182.31 N 357.24 E 5952204.62 N 645656.72 E 9.663 3159.25 11906.81 84.500 275.510 8846.06 8925.10 3184.96 N 329.73 E 5952206.73 N 645629.16 E 0.108 3163.34 12000.62 84.130 271 .490 8855.36 8934.40 3190.66 N 236.57 E 5952210.63 N 645535.92 E 4.282 3173.90 12094.46 84.000 271.380 8865.06 8944.10 3192.99 N 143.27 E 5952211.16 N 645442.58 E 0.181 3181.12 12186.29 83.820 271.520 8874.80 8953.84 3195.30 N 51.98 E 5952211.71 N 645351.27 E 0.248 3188.20 17 December, 2004 - 14:27 Page 4 of 6 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Y-03A Your Ref: API 500292041101 Job No. AKZZ3429877, Surveyed: 13 December, 2004 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12280.13 84.560 270.800 8884.30 8963.34 3197.19 N 41.35 W 5952211.80 N 645257.91 E 1.097 3194.98 12373.79 84.440 271.250 8893.28 8972.32 3198.86 N 134.57 W 5952211.67 N 645164.69 E 0.495 3201.52 12467.25 85.430 271.250 8901 .53 8980.57 3200.89 N 227.64 W 5952211.90 N 645071.59 E 1.059 3208.42 12560.69 86.360 271 .840 8908.22 8987.26 3203.40 N 320.80 W 5952212.61 N 644978.40 E 1.178 3215.80 12654.21 86.540 272.200 8914.01 8993.05 3206.69 N 414.09 W 5952214.10 N 644885.07 E 0.430 3223.97 . 12725.00 86.540 272.200 8918.28 8997.32 3209.41 N 484.70 W 5952215.45 N 644814.42 E 0.000 3230.38 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 357.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12725.00ft., The Bottom Hole Displacement is 3245.80ft., in the Direction of 351.412° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8098.44 8184.00 12725.00 7853.28 7938.70 8997.32 1362.78 N 1367.51 N 3209.41 N 420.59 W 419.78 W 484.70 W Tie On Point Window Point Projected Survey . 17 December, 2004 - 14:27 Page 5 of 6 Dril/Quest 3.03.06.006 North Slope Alaska Survey tool program for Y-03A From Measured Vertical Depth Depth (ft) (ft) 0.00 8098.44 8407.62 0.00 7853.28 8157.82 17 December, 2004 - 14:27 To Measured Vertical Depth Depth (ft) (ft) 8098.44 8407.62 12725.00 7853.28 8157.82 8997.32 Halliburton Sperry-Sun Survey Report for Y-03A Your Ref: API 500292041101 Job No. AKZZ3429877, Surveyed: 13 December, 2004 BPXA Survey Tool Description BP High Accuracy Gyro - Boss Gyro (Y-03) INC Only (Y-03A) MWD+IIFR+MS (Y-03A) . . Page 6 of 6 DrillQuest 3.03.06.006 2598' = 2670' .it TOW @ 8,184' BOW @ 8200' EZSV@ 8206' 8250' 8361' 8374' 8415' 8464' 8800' 8917' ~ 9240' V-OIAi 2ES As .uilt TREE = 4-1/8" CrN WELLHEAD = CrN ACTUA TOR = nla KB. ELEV = 79.4' BF. ELEV = 28.5' ~KOP ;--"~---a184" ·M~.~Ä·ngJ~~··9à.â.~·.·1·Ò~~-Fi Datum MD = 9127' " , . ..~~. ~<"" h."...~~."'u Datum TV 0 = 8800' SS = 9-5/8" OV Packer ~ 13-3/8" 72# L-80 2195' -'HES'4-1/2" X Nipple 10 = 3.813" ~ 4-1/2",12.6#, L-80, TCII tiili. 8,024' - 9-5/8" X 7" Baker HMC Liner Hanger with ZXP 9020' 9040' 9064' 9085' 9091' 9097' 9103' 4 1/2" X Nipple (3.813" 10) 7" x 4-1/2" Baker S-3 Packer 4112" X Nipple (3.813" 10) 4 1/2" XN Nipple (3.725" 10) 4 1/2" Top of Liner Tieback Sleeve 4 1/2" WLEG 7" x 5" HMC Hanger / ZXPliner top packer fB\ 9248' - 7",26#, L-80, BTC-M (6.276" 10) 4-1/2", 12.6#, L-80, IBT-M @ 12,725' :g :g .- . ' Top of 7" Liner 4-1/2" Tbg Tail Top of P&A Cement ... 9-5/8", 47#, L-80 PERFORA TION SUMMARY Top of Sand Plug ANGLE AT TOP PERF: 85 @ 12,420' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.5 6 12420-12600 Opn 12/15/04 2.5 6 12610-12630 Opn 12/15/04 9915' ~ 7", 29#, L-80 Date 06-02-04 12-16-04 Rev By Comments RBT Proposed Completion 2ES As Built Completion PRUDHOE BAY UNIT WELL: Y-03A API NO: 50-029-20411-01 Permit NO: 204-235 GPB Rotary Drilling . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well Y-03A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,098.44' MD 8,184.00' MD 12,725.00' MD (if applicable) 01-Jan-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date) ì J~ Á1~\- Signed 11 / ¡ ¡J en¡ II I' ~~ J;ÆAv,/ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) JO(l"'A3s- . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well Y-03A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,098.44' MD 8,184.00' MD 12,725.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ..' 1 Date;Z7\.1~~Ç-- Signed 41 / 1/ C~k~! / <"'!I, / 1/ J, I, , .N /I-.-.^...., V ,,' " ~. /\nv, v~__ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 01-Jan-05 )~Y-).3J- '. ~~!A\~! (fi} !A\~fÆ~~~fÆ . ~I/ASIi& ORAND 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 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Y -03A BP Exploration (Alaska) Inc. Permit No: 204-235 Surface Location: 1250' SNL, 4732' WEL, SEC. 34, Tl1N, R13E, UM Bottomhole Location: 1969' NSL, 5210' WEL, SEC. 27, TIIN, R13E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill 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 (907) 659-3607 (pager). Sincerely 0{¿ aniel T, Seamount, Jr. Commission Ie) \ìOV' DATED thiS1l. day of~, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. FW: Y-03Ai Distance to Offset Producers . . Bob, Here is the information pertaining to the distances from along the proposed Y-03A injector wellbore to adjacent producer wells. Sorry to have failed to provide this on the initial application. Regards, Jim Smith GPB ODE 564-5773 From: Montague, W Stuart Sent: Thursday, November 18, 2004 7:30 AM To: Smith, James E; Hubble, Terrie L Cc: Buza, John W (PRA) Subject: Y-03Ai Distance to Offset Producers Jim/Terrie, The attached PDF has a map of the Y-03Ai wellpath and the offset producers. Distances to the offsets are recorded in a table on page 2, and wells within the regulkatory limit of 1/4 mile are highlighted in yellow. Let me know if there are questions. «Y-03Ai_Dist20ffsets_AOGCC.pdf» Stuart Montague GPB PWZ Geophysicist (907) 564-4029 (office) (907) 830-8718 (cell) (907) 564-5016 fax Content-Description: Y -03Ai_ Dist20ffsets _AOGCC.pdf 'Y -03Ai_ Dist20ffsets_AOGCC.pdf . Content-Type: application/octet-stream I Content-Encoding: base64 1 of 1 11/18/20048:30 AM o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1250' SNL, 4732' WEL, SEC. 34, T11N, R13E, UM Top of Productive Horizon: 614' NSL, 4433' WEL, SEC. 27, T11 N, R13E, UM Total Depth: 1969' NSL, 5210' WEL, SEC. 27, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 645361 y- 5949016 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 8200 feet Maximum Hole Angle: 98 degrees . STATE OF ALASKA . ALASKÃ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 11 b. Current Well Class 0 Exploratory- 0 Development Oil 0 Multiple Zone o Stratigraphic Test II Service / 0 Development Gas 0 Single Zone 5. Bond: !HI Blanket 0 Single Well 11. Well Name and Number: \1/%104 Bond No. 2S100302630-277 PBU Y-03A 6. Proposed Depth: 12. Field / Pool(s): MD 13108 rvD 8999 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028287 V-i 4 Æ ¡ ¡Jig ( 1..004 8. Land Use Permit: 13. Approximate Sp_~~: Novemb~L004 14. Distance to Nearest Property: 17,150' 9. Acres in Property: 2560 18. Casing Program: Size Casinç¡ 7" Hole 8-1/2" 6-1/8" 4-1/2" Weiç¡ht 26# 12.6# ppeçifications Grade Coupling L-80 BTC-M L-80 IBT-M Length 1135' 3137' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):Plan 79.4 feet Y-16, 700' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3108 Surface: 2220 SèttinøDepth. QIJ;,tntity<Ç)iCement Top . ··.··<6ottom (c:{.orsé!cks) MD rvD M¡;V: rvD (includinç¡ stage data) 8050' 7805' /911~ßv" 8804' 269 cu ft Class 'G' /" 9035' 8697' 1:1107' 8999' 523 cu ft Class 'G' 19. PRESENTWIi;LL CONDITIONPI.JMMARY (To be CQh'1pletedforRedrill Total Depth MD (ft): Total Depth rvD (ft): Plugs (measured): Effective Depth MD (ft): 9915 9668 9240 9240 Structural Conductor 110' 20" x 30" 10 cu yds Concrete 110' 110' Surface 2670' 13-3/8" 3720 cu ft Permafrost II 2670' 2670' Intermediate 8917' 9-5/8" 1225 cu ft Class 'G', 133 cu ft PF 8917' 8671' Production 401 cu ft Class 'G' Liner 1500' 7" 8419' - 9915' 8169' - 9668' 20. Attachments !HI Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IperfOration Depth rvD (ft): 8831' - 8992' !HI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report !HI Drilling Fluid Program !HI 20 AAC 25.050 Requirements Perforation Depth MD (ft): 9077' - 9238' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Date: Contact Jim Smith, 564-5773 A. Phone 564-5521 Date Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill API Number: Permit Approval. \ r See cover letter for Number:20S7' - 2.-:3 _.ç 50- 029-20411-01-00 Date: \ \ \"Î' other requirements Conditions of Approval: Samples Required D Yes ~No Mud Log Required D Yes ~ No Hydrogen Sulfide Measures ~es DNa . Directional Survey Required ~Yes DNa Other: T t'.. L.7 t· E é? P E tc 4 0 ~ 0 r)' '.." N:l ¡; ~ ¿e, 11-'" t'-vt. f.. 11 u<.LL/ ~ to c¡ rvð u_~·Ì"\.( d ' ¡J*'ì( '2-0 f\A-<... Z 5". 0 'S C; Od (1),.1 .:\-( te..,· ilL 4. t-e Bo p~ ¡' ~ t:<¡1J1() ¡Je ~ . r· ,4 , APPROVED BY THE COMMISSION Date I ) ~ 0 ~ SL bmit In Duplicate Approved By: Form 10-401 Revised 06/2004 \.!iiig.nat ~ned ey ,,~ sr\MOUNT . . :) -06Ai ~wpOl Y-04 J jOt Y-17B .. ( rY-~ o Y -03:\ i--+wp06 Y-19 Y-16 . ,.Y-26 .. Y...03Alilnjector Sidetrack Wells Within 1/4 mile of the wellpath in Well Y-30 Y-19 Y-16 Y-28 Y -02A Y -02APB 1 Y-02 Y-17A Y -17B Y-17 Y-04 Y..38 reservoir Distance from Y-03Ai closest approach 2460' .' . 1 Well Name: I Y -03A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Injector Surface Location: x = 645360.3 Y = 5,949,017.3 4031' FSL, 4732' FEL Sec. 34, T11N, R13E Umiat / X = 645620 Y = 5950885 TVD 9009' 614' FSL, 4433.2' FEL Sec. 27, T11N, R13E Umiat X = 644814 Y = 5952225 TVDss 8999' 1969.1' FSL, 5209.9' FEL Sec. 27, T11N, R13E Umiat /'. Target Location: Ivishak Zone 4 Bottom Hole Location: (TD) I AFE Number: I PBD4P2257 I I Estimated Start Date: 111/20/04 I Rig: I Nabors 2ES / I Operating days to complete: 124.0 I MD: 113,108' I I TVD: 18,999' I I BF/MS: 150.9' I I I KBE: 179.4' I Well Design (conventional, slim hole, etc.): 1 Horizontal Sidetrack Injector / I Objective: I Ivishak Zone 4B Nearest well in pool: Y-16 is offset 700'. / I ~~~D4q Nearest property boundary: 17150' Present CasinglTubing Program: CsglTubing WttFt Grade Conn Top Bottom 20" 91.5 H-40 Welded Surface 110' 13 3/8" 72 L-80 BTC Surface 2670' 9 5/8" 47 L-80 BTC Surface 8917' 7" liner 29 L-80 BTC-Mod 8415' 9915' 4-J.1!" Tubing 12.6 L-80 AB Mod BTC Surface 8464' CasingITubing Program (Proposed): Hole Size CsgJ WtlFt Grade Con~ Tbg a.D. ./ 8-1/2" 7" 26# L-80 BTC-Mod 6-1/8" 4-1/2" 12.6# L-80 IBT-Mod Tubing 4-1/2" 12.6# L-80 TC-II 7" 26 Iblft casing: Burst 7240 psi, Collapse 5410 psi 4-1/2" 12.6 Iblft casing: Burst 8430 psi, Collapse 7500 psi Len2th Top Btm MDITVD MDITVD -1135' 8050'17805' 9,186' I 8,804' -3137' 9,035' / 8697' 13,107' I 8999' -9,035' Surface 9,035' I 8697' . . Directional WP IP6 KOP: 8,200MD Maximum Hole Angle: Close Approach Well(s): Survey Program: -980 at 9,770' MD (Horizontal Section) All wells pass major risk criteria. MWD, IFR + Cassandra Logging Program NOTE: Primary depth control log isSchlumberger Y-3 SHCS dated 7/29/80 8 1/2" Interm. : Drilling: Open Hole: Cased Hole: 6 1/8" Production: Drilling: Open Hole: Cased Hole: MWD Dir/GR - Real time throughout entire interval. None USIT on 7" liner Sample Catchers - as required by wellsite geologist for geosteering MWD Dir/GRlRes/ABVIFR Caz - Real time GR/Res throughout entire interval. None No cased hole logs required. Formation Markers Formation Tops (P2) MD TVDss Press. Comments CM2 -6241 CM1 -6982 THRZ -7275 BHRZ -7490 LCU -7511 KICK OFF POINT -7860 T JE 8275 -7950 TJD 8598 -8260 T JC 8780 -8420 TJB 8949 -8555 T JA 9039 -8620 TSGR 9186 -8725 3080 Hydrocarbon bearing TSHA 9221 -8750 TSHB 9274 -8787 TSHC 9298 -8803 TSAD 9342 -8830 3117 6.8 ppg EMW, hydrocarbon bearing Top HOT -8970 TSAD at crest of well -8775 TD Criteria: Planned TD at 131 07'MD, 8920TVDss TD may be shortened due to severe mud losses in faults. Mud Program: Intermediate Hole: Derw,' (ppg) QQ. Kingak KOP Viscosity 20-35 PV 10-18 YP 22-28 MBT <25 pH 9.0-9.5 LSND APIFI <8 Production Hole: I Density (ppg) I 8.4 Viscosity 45 - 55 PV 4-7 YP 20 - 28 MBT <3 pH 8.5 - 9.0 FloProSF 1 APIFI N/C Y-03A Well Plan AOGCC.doc 2 . . Hydraulics: Intermediate Hole: 8-1/2" Interval Pump Drill AV (fpm) Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe ppg-emw ("/32) (in2) 8200'-9186' 450-500 4" 15.7# 196 3200 11.0 N/A 0.902 Production Hole: 6 1/8" Interval Pump Drill Pipe AV (fpm) Pump PSI ECD Motor Jet Nozzles TFA GPM ppg-emw ("/32) (in2) 9186'- 275 4" 15.7# 290 3200 9.7 8 6x10 .460 13107' Integrity Testing: Test Point Intermediate Hole Sidetrack Point Intermediate Casing Shoe Depth 20' min from whipstock exit 20' min from 7" shoe Test Type FIT EMW 11.6 ppg EMW Target FIT 9.8 ppg EMW Target based on a case 9.7 ppg ECD at shoe Cement Program: Casing Size 17" Casing I Basis: Lead: Based onæ' g.1 stage cement job, 30% excess and a 80' shoe joint. Cement to cover from TD at 9186 . to 05 (150' above whipstock exit point) plus 200' of 4" DP by 9-5/8" casing Estimated Bott· ole Static Temperature = 190F Fluid Sequence & Volumes: Pre Flush Spacer Tail 25 bbls MudPUSH ;tiseçsified Spacer weighted to 11.6 ppg 47.4~69 fe ~s of Dowell Premium 'G' at 15.8 ppg and .1 uft/sk. (use actual circulating temps recorded by MWD atT . None Estimated Bottom Hole Static Temperature= 200F Casing Size 14-1/2" pro~tion Liner I Basis: Lead: Based 0~2 'open hole with 30% excess, 80' shoe joint, 150' liner lap and 200' cement above liner to . . ct 0 ~<; Estimated Bottom ole Static Temperature= 200F Fluid Sequence & Volumes: Pre None Flush Spacer 40 bbls MudPUSH Tail 93.2 bbl 1 523 f 3 15.8 ppg and .1 sified Spacer weighted to 9.5 ppg 4 sks of Dowell Premium 'G' plus latex at uft/sk. Y-03A Well Plan AOGCC.doc 3 . . Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed. Based upon the need to test the production casing to 4000 psi the BOP equipment will be tested to 4000 psi. During the de-completion phase up to the time the well is sidetracked and new hole is drilled, the BOP test frequency will be 7 days. Afterwards the tests will be conducted on a 14 day frequency. Except for significant operational issues that may effect well integrity or pose ~ safety concerns, an extension to the 14 day BOP test period should not be requested. , BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams. drilling liner. The rig will follow the current, best practice of picking up a joint of drill -11::- pipe, crossed over to casing thread, in the event of a kick. This configuration provides two sets of employable rams, rather than one. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3108 psi @ -8800' TVDss - Sadlerochit 2220 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 6.8 ppg diesel 4000 psi / Filtered brine (8.5 ppg) with 2% KCL with corrosion inhibitor / Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class " wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. ,Sidetrack and Completion Procedure SUmmary Pre-Riq Work: 1. Rig up slickline, drift 4-1/2" tubing to WLEG. 2. Fluid pack tubing and inner annulus. 3. P&A perfs from the PBTD to -8,800' MD. RIH with coil to PBTD @ 9,240' MD. Lay in 17 bbls of cement to -8,800' MD. Obtain Squeeze on cement with 5 additional bbls. POH with coil. 4. Rig up slickline, tag TOC. 5. RU E-line. Chemical cut the tubing at 8,250' MD. 6. Fluid pack T X IA with seawater, test IA to 4000 psi (NOTE: normal test against a Guiberson packer is limited to 2000 psi, since the well is P&A below, the pressure is OK). Freeze protect with diesel to 2,200' MD. 7. Test the 9-5/8" pack-off and tubing hanger seals to 5000 psi. 8. Function all lock-down screws. Repair or replace as needed. 9. Bleed casing and annulus pressures to zero. 10. Set a BPV in tubing hanger. Secure well. 11. Remove the well house. 12. If necessary, level the pad. Please provide total well preparation cost on the handover form. Y-03A Well Plan AOGCC.doc 4 . . v Riq Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from pre-rig tubing cut at 8,250' MD. 5. RU e-line. Run GR/JB for 9-5/8",47# casing with CCl to just above top of tubing stub. 6. RIH with CIBP on e-line. Set CIBP to avoid'cutting a casing collar during window milling operations. 7. Test casing to 4000 psi against bridge plug: T~ '$ 10 ,. 401 avp p j19"~ . 8. PU 9-5/8" Baker bottom trip whipstock assembly. RIH, orient whipstock with gyro and set on CIBP. 9. Swap over to 10.6 ppg lSND milling and drilling fluid (Kingak KOP). ~ 10. Mill window in 9-5/8" casing at 8,200' MD (top of window) plus 20' past middle of window. Perform FIT. POOH. 11. MU 8-1/2" drilling assembly with Dir/GR and wet connect. RIH. 12. Orient BHA with gyro to kick off and drill ahead. Drill with gyro until a gravity tool face is obtained. 13. Drill the 8-1/2" intermediate interval, building and turning at 6°/100' to a 4?-~-h9>ld an~. 14. Drill ahead to casing point at Top Sag River to an estimated depth of !);2'3~MD. 15. Run and cement a 7" drilling liner throughout the 8-1/2" hole and b~êKinto the 9-5/8" casing with 150' of overlap. Displace cement with mud. POOH. 16. RU E-line. RIH and run USIT log from PBTD to top of 7" liner. Quality cement bond required by AOGCC ,/ to allow water injection. 17. MU 6-1/8" BHA with Dir/GR/RES/ABI and RIH to the landpª'collar. 18. Pressure test wellbore to 4000 psi for 30 minutes. 19. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT. 20. Drill the 6-1/8" production interval building at 11 °/1 00' to horizontal, targeting Z4 Ivishak. Drill ahead to an // estimated TD of 13,107' MD. 21. Run and cement a 4-1/2" liner throughout the 6-1/8" wellbore and back into the 7" drilling liner to place top of liner with 150' of overlap. Displace cement with perf pill and mud. / 22. Release from liner, displace well to clean seawat~r. 23. Pressure test wellbore to 4000 psi for 30 mins. / 24. RIH with DPC perf guns. Perf intervals to be determined from lWD logs. 25. POOH. lD DP and perf guns. 26. Run 4-1/2",12.6#, l-80 TC-II completion tying into the 4-1/2" liner top. / 27. Set packer and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. 28. Set and test TWC. 29. ND BOPE. NU and test the tree to 5000 psi. / 30. Freeze protect the well to -2200' and secure the well. 31. RDMO Post-Riq Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. Y-03 Well Historv V-03 was drilled as a producer in July 1980. The well was initially perforated with 33' of perforations in Zone 4. First oil production was in January 1981, with initial rates of 3000 bopd, 0% WC, and approximately 600 scf/STB GOR. However, rates declined quickly and the well was shut in due to low PI in May 1982. In May 1984 V-03 was stimulated with a 2000 gallon EDT A wash - benefits were short-lived as post-stirn production declined rapidly. V-03 was identified as a conversion candidate as part of the peripheral wedge zone waterflood project. So, again, in early 1985 a second EDT Alscale inhibitor treatment was performed prior to adding the future injection perforations. In June 1985, 58' of perforations were added in Zone 4 in order to maximize the pre-waterflood oil production - rates post-add perfs were -2000 bopd, 10% WC, and solution GOR. V-03 was converted to an injector in September 1985 and injected -10,000 bwpd of seawater for the first six years on injection. Starting in 1992 through 1994 V-03i was switched over to PWI and in 1995 V-03i started WAG injection - injecting 35-40 mmscfd of MI for short periods of time followed by lengthier periods of PWI. Throughout 2000 and into early 2002 V-03i was consistently injecting -8000 bwpd of PWI. However, it was determined that V-03i's injection was ineffective and concluded that the problem was most likely that the well was injecting into a fault/fracture and not achieving effective sweep. Additionally a Kinley caliper run in December 2000 showed 108 joints of tubing to be in 21-40% penetration range (fair) and 77 joints of tubing to V-03A Well Plan AOGCC.doc 5 . . be in 41-85% penetration range (poor). In 2002 Y-03i developed TxlA communication and had minimal time on injection in 2002 and has been shut in since January 5, 2003. An RST is the best solution for solving the conformance and integrity issues. Current Well Information Well Name: Y-03 API Number: 50-029-20411-00 PBTD: 9746' MD, currently sanded back to 9240'MD. Perfs open up to 9077'MD Well Type: Last function asWAG injector Current Status: Currently shut in with tubing leak. Will be P&A in pre-rig program. /' BHP: 3080 psi@8725' TVDss (Sag River top) BHT: 2001 ° F in Ivishak Mechanical Condition: Tubing: 4-1/2",12.6 #/ft, L-80 IPC, AB-mod-BTC , Guiberson Polar packer (9-5/8") at 8374'. Guiberson Polar tubing seal assyat 8361'. The tail pipe extends to 8464'. See current schematic. 9915'/9746' MD, Sanded back to 9240'MD 22.1 ° at 4800' MD (Intermediate Hole) 3.8°/100' at 2850' MD (hole angle is 2.47degrees at this depth) TBD TBD TBD TBD TBD 9077-9238' are open, 9248-9316' are sanded back. All will be cemented off in pre-rig program. Planned: 8.5 ppg brine 1 diesel Planned: 8.5 ppg brine 1 diesel TD 1 PBTD: Maximum Angle: Max Dogleg of interest: Tubing. Spool: Tubing. Hanger: Tubing. Head Adapter: Tree: BPV Profile: Perforations: Tubing Fluids: Annulus Fluids: Y-03A Well Plan AOGCC.doc 6 . . Detailed Procedure Job 1: MIRU Hazards and Contingencies þ> The Y-03A is on the southeast side of V-pad 35' from Y-35 and 37' from Y-34. No wells should require removal of the wellhouse other than Y-03. þ> V-Pad is notan H2S pad. 2004 H2S data from the pad is as follows: Y-30L 1 120 ppm, Y-19 50 ppm and Y-16 30 ppm. The Y-30L 1 well is the maximum recorded H2S well on the pad. Standard operating procedures for H2S precautions should be reviewed and followed at all times. Þ> Post Permit to Drill prior to spud. Pressure Barriers: 1) P&A cement across perfs in pre-rig work, tested to 4000 psi. 2) kill weight fluid above production interval 3) wellhead/tree with BPV Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-Complete Well Hazards and Contingencies þ> NORM test all retrieved well head and completion equipment. þ> The tubing has internal corrosion, there is a possibility it may part during recovery efforts. Plan to have fishing tools available in the event only partial recovery is made on the initial attempt. þ> Pressure barriers: 1) Tested P&A cement across the productive interval, 2) kill weight fluid above the production interval, 3) wellhead and tree with BPV. Reference RP .:. "De-completions" RP Job 3: Run Whipstock and Mill Out Hazards and Contingencies Þ> Pressure Barriers: 1) P&A cement across productive interval, 2) kill weight fluid above production interval þ> PU whipstock assembly with orienting sub, it will be necessary to orient the whipstock with a gyro survey since hole angle is only 3 degrees at the KOP. Set whipstock to kick off 30° right of high side. Þ> If for any reason the whipstock must be pulled back through the BOP stack, extreme caution must be employed to ensure the assembly does not hang in the stack and release the shear pin. þ> Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. Whipstock sidetracks. Y-03A Well Plan AOGCC.doc 7 . . Job 4: Drillinq Intermediate Hole Hazards and Contingencies Y-03A is at such low angle that it will be necessary to "steer" with gyro surveys until hole angle is large enough to use MWD tools > Kingak Wellbore Stability: The mud weight required to safely drill the Kingak has been selected based on Kingak Shale Stability analysis which takes into consideration the angle and the azimuth at which the formation will be penetrated. Should wellbore stability be an issue with the selected mud weight, preparations should be in place to increase the mud weight by at least .2ppg initially. > Risk of Mud Loss: It is highly possible that mud loss will occur in the Sag River formation if it is penetrated with the planned 10.3 ppg LSND mud. The geologist will forecast expected TO based on the silt that overlies the Sag River, at 25'MD above that depth it will be necessary to circulate samples to the surface for inspection, the geologist will request an additional 5' of new hole and repeat the process until the casing point is selected. > KICK TOLERANCE: In the case scenario of 6.8 ppg pore pressure at the Sag River depth prior to running 7" casing, gauge hole, a fracture gradient of 11.5 ppg at the surface casing shoe, 10.6 ppg mud in the hole the kick tolerance is infinite. An accurate LOT will be required as well as heightened awareness for kick detection. Contact ODE if LOT is less than 10.6 ppg. (Maximum anticipated ECD of intermediate hole.) > There are no "close approach" issues with the intermediate hole interval of Y-03A. IFR/Cassandra will be run on this hole section to satisfy JORPS. > Follow recommended practice to not exceed 500 gpm flow rate or 100 fph ROP. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Dri/ling- Kingak & HRZ" Job 6: Case & Cement Intermediate Hole Hazards and Contingencies * There is no faulting expected in the intermediate hole interval on this well * Ensure a minimum hydrostatic equivalent of 10.3 ppg remains on the formation during pumping of cement pre-flushes/chemical washes. Loss of hole integrity and packing off have resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. * Considerable losses during running and cementing the 7" liner has been experienced on some offset wells. A casing running program will be issued detailing circulating points and running speed * Ensure the 7" casing covers all of the Kingak, It is planned to set the liner within l' of bottom. * Change to 7" casing rams and test the BOP doors prior to picking up the casing string. > Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. > Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "DS Cement Program" Attached. Y-03A Well Plan AOGCC.doc 8 . . 7",26#, L-BO, BTC-mod 100% 80% Collapse 5410 psi 4328 psi Burst 7240 psi 5792 psi Tensile 604,000 Ib 483,200 Ib ID 6.276" 6.151" drift Make-up Torque To Position Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies > There are 3 expected faults in the 6-1/8" interval and 3 additional potential faults for a total of 6 crossings that may occur. Prepare for mud losses, LCM treatments and in the worst case; drilling with full loss of returns. Management of ECD limitations and preparations for losses are the primary contingencies. > Fault Summary: > Should mud loss continue at extreme rates, there will be a consultation with the asset team to shorten planned TD. The minimum acceptable TD for this well is across fault 3, fault 3 is expected at to be found near 12, 195'MD. Discussions of cost and value for the remaining interval will determine how long the efforts to drill to plan TD are continued. :> Prompt response to mud loss per the LCM decision tree is warranted on this well. If significant mud losses (> 50 BPH) are observed, proceed directly to the high concentration LCM pills in an effort to forego substantial mud system loss. See LCM discussion in MI Mud Program. > Due to the proximity of faults to the entry point of the wellbore into the Shublik it is possible that lost circulation from fractures in the Shublik could be seen. Maintain offset from faulting as developed in the directional program, stay on the directional program line through the Shublik. If fluid losses and ballooning are observed it will be necessary to hold the planned mud weight and expect flowback and gas from the Shublik while drilling the remaining interval. See the "Operational RP for Hydrocarbon Influx While Drilling the Shublik Formation" document at the end of this drilling program. > There are no close approach issues with the production hole interval on Y-03A. :> The kick tolerance is infinite for the 6-1/8" open hole section assuming a kick from Zone 4 at -8830' TVDss. This is based on an 6.8 ppg pore pressure, a minimum fracture gradient of 10.6ppg at the 7" shoe, and 8.4 ppg mud in the hole. :> Expect a certain amount of geo-steering, but significant changes to the planned directional profile should be discussed with the Drilling Manager/Operations Drilling Engineer. There are restrictions concerning adding lubricants to the mud whilst drilling the horizontal hole. Lubetex/Flolube concentrations of 2.250/01.75% are approved however the use of EP Mudlube is on an as needed basis if weight transfer issues compromise the drilling of the production hole. If sliding issues are encountered while drilling the production hole, the addition of EP MudLube is approved in .5% additions up to 1.0% after discussion with town. Y-03A Well Plan AOGCC.doc 9 . . Reference RPs .:. Lost Circulation Decision Tree .:. "Operational RP for Hydrocarbon Influx While Drilling the Shublik Formation"" Job 9: Case and Cement Production Hole Hazards and Contingencies > Mud loss into expected and possible faults is the primary hazard on this well. Should losses occur, treat with the pre-planned LCM treatment program. If losses become excessive and cannot be reduced to an acceptable level it may be necessary to accomplish the liner cementing in a two step process, i.e., cement the shoe and then perform a top down squeeze to isolate from the liner top back down to the fault which is taking fluids. If this occurs it will be necessary to forego setting the liner top packer. > Differential sticking and sand collection in low segments of the hole are risks. The mud system will be approximately 700-800 psi over balance to the Ivishak formation with 8.4 ppg FloPro. Minimize the time the pipe is left stationary while running the liner and circulate thoroughly prior to POOH for the liner. > The undulations in this wellplan may cause difficulty running the liner to bottom. Placement of the liner running pill prior to POOH should help to produce a slick and clean hole. > A 150' liner lap will be required on this well in order to provide additional isolation in the event a "top down" squeeze is required due to a failed/poor production liner cement job. Cement isolation from any of the faults which take mud is "CRITICAL" to prevent detriment to waterflood performance. Reference RPs .:. "Running and Cementing a Liner Conventionally" 4-1/2",12.6#, L-80, IBT·M Collapse Burst Tensile ID Make-up Torque, ft*lbs 100% 7500 psi 8430 psi 288,000 Ib Body 3.958" To "Mark" Pin 3.918" 80% 6000 psi 6745 psi 230,000 Ib 3.833" drift Job 10: DPC Perforate Well Hazards and Contingencies > The Ivishak interval of the well will be TCP perforated prior to running the completion. After placing a KCL brine perf pill at 8.5 ppg the well will be perforated across a 6.8 ppg EMW reservoir for an overbalance of 800 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. > The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach the landing collar due to cement/fill. Reference RPs .:. DPC Perforating RP .:. Schlumberger DPC Perforating Guidelines Y-03A Well Plan AOGCC.doc 10 . . Job 12: Run Completion HazardsandConüngencres ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing the annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. ~ Well Integrity: The well will have an open production interval with a 6.8 ppg EMW formation pressure. The annulus above the packer will be tested to 4000 psi to verify packer/annulus integrity. The well will have a RHC plug installed in the lower XN with kill weight brine above. A ball and rod will be on seat at rig release. A second annulus valve will be in place on the tubing spool flange prior to completion operations. (This valve will be removed after RDMO. A VR plug will be installed in tubing spool outlet prior to RDMO.) A VR plug will be installed in the casing annulus outlet ( 9-5/8") to meet the Double Barrier" standard. A TWC will be installed and tested from below to 1000 psi for 30 minutes prior to nippling down the BOP's. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: NDINUlRelease RiCl Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus Y-03A Well Plan AOGCC.doc 11 . . Y-03A Well Summary of DrillinQ Hazards Decompletion Section: · Well will have kill weight fluid above the P&A cement plug (to be tested in pre-rig) and a BPV installed in the tubing hanger during nipple up. Intermediate Hole Section: · There are no faults expected in the intermediate hole section. . The intermediate hole section will be drilled initially with a 10.6 ppg mud weight and maintained at 10.6 ppg until reaching TD at the Sag River formation. The elevated mud weight is necessary to stabilize the Kingak shale according to the azimuth and inclination of the wellbore. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ or Kingak shales gives problems. Back reaming at connections and good hole cleaning practices and close monitoring of PWD data will contribute to favorable hole conditions. Production Hole Section: o Three faults are expected to be encountered with potential for three additional faults. o Mud loss to the faults is expected, to what degree is unknown. Maintain LCM stockpiles and be prepared to transport either mud or seawater to the drillsite should losses escalate. o HYDROGEN SULFIDE - H2S · This drill-sitenotßesignated as an H2S drill site. Recent well tests indicate up to 120ppm (Y -30L 1) with typical for the other wells at less than 50ppm H2S. As a precaution, Standard Operating Procedures for H2S should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Y-03A Well Plan AOGCC.doc 12 y- d m lieti 2598' 2670' ~ ...... - .. 13-3/8",72#, L-80 4-1/2", 12.6#, L-80, TCII 8250' Baker HMC Hanger and running tool 8050' 8200' of window approx. 8200' - 7 X 4-1/2" Baker Packer Baker HMC Liner Hanger running tool L-80, BTC-M 8361' 8374' 841 Top of 7" Liner 8464' 8800' 891 ~ , 4-1/2" Tbg Top of P&A Cement .. 9-5/8", 47#, L-80 Top of Sand Plug 991 , 29#, L-80 I 55DD985.~2 -, i-D jtblJ I ~ I ~."H\ 53 L L Ü· (U~, u::-\ (C 1L-L~ ¡Ii ~, ~ I \~ : II r II ,J I -,, ( '. I: \ J ) \ ( _ -- ~~ , ; . J . ~!q. ofi1TIl'!~r.~~~':'-~ -~--~N-~~-~~~~~œ~~~~~œ~ ~~ ~ - ~.œ~~~o-~-o~~CO~·· o.þ. -~ ~ œ 33' .-JÞ-... ~ . -~-----==-_._------- j J;:. § l Entry/Exit LO o CD . . WELL PRODUCER . WELL INJECTOR .... DATE: 09/18/2001 k ..)j) . ==ì\;, II - ræ "', '__._~ ~ \ 785" 109' I i I I I (.~ 1 SCALE: 1" = 250' MAP DATE: 1995 r '. ì I i ! / \ (75á'~'" I I ..-'~>- - Q) .. -~ œœ - ~ - ~- ~ œ.þ. 'L-LR / -~ - -< (J 767' /.--..,.._.J í ,( Exlt/EntJY . '\ . . M . 0) ,T"" , M en en \\ . . (( " ...It. /....... '1\) !.. I ". t . t PRUDHOE BAY UNIT - Y PAD bS14495.dgn Plan: Y-03A wp06 (Y -o31Plan Y-03A) Created ay: Troy Jakabosky Date: 6/2/2004 Checked: Date' - Reviewed: Date' - SURVEY PROGRAM Depth Fm Depth To Survey/Pbn To, 8200.00 13107.73 Planned: Y..Q3A wp06 V44 MWD+IFR+MS WELL DETAILS Basting 645]61.00 Slot NIA Shape Point Point Point Point Point Polygon Polygon Latitude Longitude 70oI6'05.165N 148°49'28.214W Bastmg 646554.99 645904.99 645299.17 644813.76 645620.00 644990.00 645054.58 TARGET DETAILS +N/-S +E/-W Northing 5951660.00 5952280.00 5952252.06 5952225.28 5950885.00 5950725.00 5950716.42 1244.93 606.97 0.67 -485.20 295.06 337.96 273.55 Northing 5949016.00 2620.65 3253.13 3236.90 3219.50 1863.79 1715.97 1706.15 +F.J-W -2378.14 TVD 8869.39 8894.39 8914.39 8999.39 9009.39 9009.39 9009.39 +N/·S 5 Name Y'{)3A T2 Y-03A T4 A Y'{)3A T5 A Y-03A T6 A Y'{)3AT1 Y-03A Geo Poly Y'()3A DD Poly N~ Y.<J' FORMATION TOP DETAILS No. TVDPath MDPath FOffilation 1 8029.39 8275.15 TJE 2 8339.39 8598.33 Till 3 8499.39 8780.20 TJC 4 8634.39 8949.44 TJB 5 8699.39 9038.77 TJA 6 8804.39 9185.91 TSGR 7 8829.39 9220.95 TSHA 8 8866.39 9273.60 TSHB 9 8882.39 9297.89 TSHC 10 8909.39 9342.1\ TSAD REFERENCE INFORMATION Co-ordinate (NIE) Reference: We]] Centre: Y...o3, True North VeJ1ic&' (/1'V) Reference: 28.5+50.8979.39 Section (VS) Refeteuce: S]ot - (O.OON,o.ooE) Measured Depth Reference: 28.5+50.89 79.39 Calculation Method: Minimlm1 Curvature , - COMPANY DETAIL: BP Amoco ~ Calculation Method: Minimum Curvature ~:ffI¡;;~~~!~:.;,,!!~.V.I~. Error System: ISCWSA Scan Method: Trav Cylinder North Mor Surtàce: Elliptica] + Casing Warning Method: RuJes Based CASING DETAILS No. TVD MD Name Size 8804.39 9185.91 7" 7.000 8999.14 13107.00 4112" 4.500 _e- . '--'+! -i- ! i'- i I . . , ·····'i 'i . ..... ¡'~d.9" I. Vi'S" I / I I I J' I I I ! !i 0,\1 ! / U I -, f " ' ~oo \J I ...... '......1] ¡i- 1 . '-J i -J- . V -1-:lT i iii.il . Targe Y-03A T1 Y-03A T4 A Y-03A T2 VSee 1415.73 1417.04 1590.01 1667.87 1799.01 18/5.61 1872.44 2405.86 2848.32 2909.46 3126.35 3140.55 3194.60 3200.65 3255.85 TFaee 0.00 30.00 30.22 0.00 21.29 38.15 0.00 -91.51 -93.88 0.00 -86.54 -106.92 0.00 -1.35 -179.99 DLeg 0.00 12.00 5.00 0.00 11.00 11.00 0.00 10.00 9.00 0.00 9.00 9.00 0.00 4.00 4.00 SECTION DETAILS +N/-S +E/-W -419.67 -419.15 -172.63 -45.15 295.06 383.52 831.85 ]244.93 1038.54 980.14 606.97 525.81 53.71 0.67 -485.20 1368.47 1369.87 1581.94 1679.90 1863.79 1893.92 2018.95 2620.65 3037.00 3090.02 3253.13 3255.26 3238.77 3236.90 3219.50 TVD 7954.68 7974.62 8681.90 8845.66 9009.39 9002.77 8936.54 8869.39 8880.87 8884.50 8894.39 8895.90 8913.41 8914.39 8999.39 Azi 12.35 25.14 52.46 52.46 68.00 74.42 74.42 355.00 312.24 312.24 275.00 268.00 268.00 267.95 267.95 1ne 3.21 5.43 44.47 44.47 90.00 98.10 98.10 90.00 87.36 87.36 90.00 87.88 87.88 90.00 70.17 MD 8200.00 8220.00 9014.26 9243.74 9676.00 9769.8 ] 10239.94 11035.]7 11511.01 11589.98 12004.64 12085.90 12558.61 12611.69 13107.73 See 1 2 3 4 5 6 7 8 9 10 II 12 13 14 15 _.... 8000 8200 . Y-03A T5 A Y-03A T6 A t ....... . , .... ..... f' I 8400 8800 c ;j§ o o r!, -S ¡; ç:¡ ] '€ ;; 2 f-< , , , , , 3200 , , , , 3000 , , , I , , , , 2800 , , I , , , 2600 , Vertical Section at 351.43° [200ft/in] I , I , I , 2400 , , , , , 2200 , I , I I I I I I , I I I , , , I , I , , , I , , 1600 1800 2000 9000- - Y.03) I , 1400 . BP Planning Report PBD . Principal: Yes Plan: "Y-03A wp06 Date Composed: Version: Tied-to: 4/21/2004 44 From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: Y-03 Y-03 Well Position: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 5948541.48 ft 647748.73 ft 0.041 N 18.991 W True 1.12 deg Latitude: 70 16 Longitude: 148 48 North Reference: Grid Convergence: Slot Name: +N/-S 521.33 ft +E/-W-2378.14 ft Position Uncertainty: 0.00 ft Northing: Easting : 5949016.00 ft 645361.00 ft 70 16 5.165 N 148 49 28.214 W Latitude: Longitude: Wellpath: Plan Y-03A Current Datum: Magnetic Data: Field Strength: Vertical Section: Casing Points 28.5+50.89 4/21/2004 57582 nT Depth From (TVD) ft 30.39 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Y-03 8200.00 ft Mean Sea Level 25.22 deg 80.83 deg Direction deg 351.43 9185.91 8804.39 13107.00 8999.14 Formations Height 79.39 ft +N/-S ft 0.00 7.000 4.500 8.500 6.125 7" 41/2" 8275.15 8598.33 8780.20 8949.44 9038.77 9185.91 9220.95 9273.60 9297.89 9342.11 0.00 0.00 0.00 0.00 0.00 0.00 8029.39 8339.39 8499.39 8634.39 8699.39 8804.39 8829.39 8866.39 8882.39 8909.39 CM2 CM1 THRZ BHRZ LCU TJF TJE TJD TJC TJB TJA TSGR TSHA TSHB TSHC TSAD 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 . BP Planning Report PBD . Survey 8200.00 3.21 12.35 7954.68 1368.47 -419.67 0.00 0.00 0.00 Start Dir 12/100' : 8200' 8220.00 5.43 25.14 7974.62 1369.87 -419.15 12.00 11.06 63.95 Start Dir 5/100' : 8220' 8275.15 7.93 35.25 8029.39 1375.34 -415.84 5.00 4.54 18.32 TJE 8300.00 9.11 37.95 8053.97 1378.29 -413.64 5.00 4.73 10.90 MWD+IFR+MS 8400.00 13.96 44.19 8151.92 1393.19 -400.36 5.00 4.85 6.24 MWD+IFR+MS 8500.00 18.88 47.24 8247.82 1412.84 -380.06 5.00 4.93 3.05 MWD+IFR+MS 8598.33 23.76 49.03 8339.39 1436.64 -353.41 5.00 4.96 1.82 TJD 8600.00 23.84 49.05 8340.92 1437.09 -352.90 5.00 4.97 1.46 MWD+IFR+MS 8700.00 28.81 50.27 8430.52 1465.75 -319.08 5.00 4.97 1.22 MWD+IFR+MS 8780.20 32.80 51.01 8499.39 1491.78 -287.32 5.00 4.98 0.91 TJC 8800.00 33.79 51.16 8515.94 1498.61 -278.86 5.00 4.98 0.79 MWD+IFR+MS 8900.00 38.77 51.84 8596.52 1535.42 -232.55 5.00 4.98 0.68 MWD+IFR+MS 8949.44 41.24 52.13 8634.39 1554.99 -207.51 5.00 4.99 0.58 TJB 9000.00 43.76 52.39 8671.66 1575.89 -180.49 5.00 4.99 0.52 MWD+IFR+MS 9014.26 44.47 52.46 8681.90 1581.94 -172.63 5.00 4.99 0.49 End Dir : 9014.26' MD, 8 9038.77 44.47 52.46 8699.39 1592.41 -159.01 0.00 0.00 0.00 TJA 9100.00 44.47 52.46 8743.08 1618.54 -125.00 0.00 0.00 0.00 MWD+/FR+MS 9185.91 44.47 52.46 8804.39 1655.21 -77.27 0.00 0.00 0.00 7" 9200.00 44.47 52.46 8814.44 1661.23 -69.44 0.00 0.00 0.00 MWD+IFR+MS 9220.95 44.47 52.46 8829.39 1670.17 -57.81 0.00 0.00 0.00 TSHA 9243.74 44.47 52.46 8845.66 1679.90 -45.15 0.00 0.00 0.00 Start Dir 11/100' : 9243. 9250.00 45.11 52.82 8850.10 1682.57 -41.64 11.00 10.26 5.64 MWD+IFR+MS 9273.60 47.54 54.08 8866.39 1692.73 -27.93 11.00 10.30 5.35 TSHB 9297.89 50.06 55.28 8882.39 1703.30 -13.02 11.00 10.35 4.94 TSHC 9300.00 50.28 55.38 8883.74 1704.22 -11.68 11.00 10.38 4.74 MWD+/FR+MS 9342J 1 54.67 57.26 8909.39 1722.72 16.11 11.00 10.42 4.45 TSAD 9350.00 55.49 57.58 8913.91 1726.20 21.56 11.00 10.46 4.16 MWD+IFR+MS 9400.00 60.74 59.53 8940.31 1748.33 57.77 11.00 10.49 3.89 MWD+IFR+MS 9450.00 66.01 61.28 8962.71 1770.38 96.63 11.00 10.54 3.51 MWD+IFR+MS 9500.00 71.30 62.89 8980.91 1792.16 137.77 11.00 10.58 3.23 MWD+IFR+MS 9550.00 76.60 64.41 8994.72 1813.47 180.82 11.00 10.61 3.03 MWD+IFR+MS 9600.00 81.92 65.86 9004.04 1834.12 225.37 11.00 10.62 2.90 MWD+/FR+MS 9650.00 87.23 67.27 9008.76 1853.90 271.03 11.00 10.63 2.82 MWD+IFR+MS 9676.00 90.00 68.00 9009.39 1863.79 295.06 11.00 10.64 2.80 Y-03A T1 9700.00 92.08 69.63 9008.96 1872.46 317 .44 11.00 8.65 6.80 MWD+IFR+MS 9750.00 96.39 73.05 9005.26 1888.41 364.66 11.00 8.63 6.84 MWD+IFR+MS 9769.81 98.10 74.42 9002.77 1893.92 383.52 11.00 8.61 6.91 End Dir : 9769.81' MD, 9 9800.00 98.10 74.42 8998.51 1901.95 412.31 0.00 0.00 0.00 MWD+IFR+MS 9900.00 98.10 74.42 8984.43 1928.54 507.68 0.00 0.00 0.00 MWD+IFR+MS 10000.00 98.10 74.42 8970.34 1955.14 603.04 0.00 0.00 0.00 MWD+IFR+MS 10100.00 98.10 74.42 8956.25 1981.73 698.40 0.00 0.00 0.00 MWD+IFR+MS 10200.00 98.10 74.42 8942.17 2008.33 793.77 0.00 0.00 0.00 MWD+IFR+MS 10239.94 98.10 74.42 8936.54 2018.95 831.85 0.00 0.00 0.00 Start Dir 10/100' : 10239 10250.00 98.07 73.40 8935.13 2021.71 841.43 10.00 -0.28 -10.10 MWD+IFR+MS 10300.00 97.90 68.35 8928.18 2037.93 888.19 10.00 -0.35 -10.09 MWD+/FR+MS 10350.00 97.66 63.31 8921.41 2058.20 933.38 10.00 -0.47 -10.08 MWD+IFR+MS 10400.00 97.37 58.28 8914.87 2082.38 976.63 10.00 -0.59 -10.07 MWD+IFR+MS 10450.00 97.02 53.25 8908.60 2110.28 1017.63 10.00 -0.70 -10.05 MWD+IFR+MS 10500.00 96.61 48.23 8902.67 2141.69 1056.06 10.00 -0.81 -10.04 MWD+IFR+MS 10550.00 96.16 43.22 8897.10 2176.36 1091.62 10.00 -0.91 -10.02 MWD+IFR+MS 10600.00 95.66 38.22 8891.95 2214.04 1124.06 10.00 -1.00 -10.00 MWD+IFR+MS 10650.00 95.12 33.23 8887.25 2254.44 1153.11 10.00 -1.09 -9.99 MWD+IFR+MS 10700.00 94.54 28.24 8883.04 2297.25 1178.57 10.00 -1.16 -9.97 MWD+IFR+MS . BP Planning Report PBD . Survey 10750.00 93.92 23.27 8879.35 2342.15 1200.23 10.00 -1.23 -9.95 MWD+IFR+MS 10800.00 93.28 18.30 8876.21 2388.79 1217.93 10.00 -1.29 -9.94 MWD+IFR+MS 10850.00 92.61 13.34 8873.64 2436.82 1231.54 10.00 -1.34 -9.92 MWD+IFR+MS 10900.00 91.92 8.38 8871.66 2485.87 1240.95 10.00 -1.38 -9.91 MWD+IFR+MS 10950.00 91.22 3.43 8870.30 2535.57 1246.09 10.00 -1.41 -9.90 MWD+IFR+MS 11000.00 90.50 358.48 8869.54 2585.54 1246.92 10.00 -1.42 -9.90 MWD+IFR+MS 11035.17 90.00 355.00 8869.39 2620.65 1244.93 10.00 -1.43 -9.90 Y -03A T2 11050.00 89.91 353.67 8869.40 2635.40 1243.46 9.00 -0.61 -8.98 MWD+IFR+MS 11100.00 89.61 349.18 8869.61 2684.83 1236.01 9.00 -0.61 -8.98 MWD+IFR+MS 11150.00 89.30 344.69 8870.09 2733.52 1224.71 9.00 -0.60 -8.98 MWD+IFR+MS 11200.00 89.01 340.20 8870.83 2781.18 1209.63 9.00 -0.59 -8.98 MWD+IFR+MS 11250.00 88.72 335.71 8871.82 2827.50 1190.87 9.00 -0.58 -8.98 MWD+IFR+MS 11300.00 88.43 331.21 8873.06 2872.20 1168.54 9.00 -0.57 -8.98 MWD+IFR+MS 11350.00 88.16 326.72 8874.55 2915.02 1142.78 9.00 -0.55 -8.99 MWD+IFR+MS 11400.00 87.90 322.23 8876.27 2955.68 1113.75 9.00 -0.52 -8.99 MWD+IFR+MS 11450.00 87.65 317.73 8878.21 2993.93 1081.63 9.00 -0.50 -8.99 MWD+IFR+MS 11500.00 87.41 313.23 8880.37 3029.53 1046.62 9.00 -0.47 -9.00 MWD+/FR+MS 11511.01 87.36 312.24 8880.87 3037.00 1038.54 9.00 -0.45 -9.00 End Dir : 11511.01' MD. 11589.98 87.36 312.24 8884.50 3090.02 980.14 0.00 0.00 0.00 Start Dir 9/100' : 11589. 11600.00 87.42 311.34 8884.96 3096.70 972.67 9.00 0.55 -8.99 MWD+IFR+MS 11650.00 87.70 306.84 8887.09 3128.19 933.91 9.00 0.57 -8.99 MWD+IFR+MS 11700.00 88.00 302.35 8888.97 3156.55 892.79 9.00 0.59 -8.99 MWD+IFR+MS 11750.00 88.31 297.86 8890.58 3181.61 849.57 9.00 0.62 -8.98 MWD+IFR+MS 11800.00 88.63 293.37 8891.92 3203.21 804.51 9.00 0.64 -8.98 MWD+IFR+MS 11850.00 88.95 288.88 8892.97 3221.22 757.89 9.00 0.66 -8.98 MWD+IFR+MS 11900.00 89.29 284.39 8893.74 3235.53 710.00 9.00 0.67 -8.98 MWD+/FR+MS 11950.00 89.63 279.90 8894.21 3246.05 661.13 9.00 0.68 -8.97 MWD+IFR+MS 12004.64 90.00 275.00 8894.39 3253.13 606.97 9.00 0.68 -8.97 Y-03A T4 A 12050.00 88.81 271.09 8894.86 3255.54 561.69 9.00 -2.62 -8.61 MWD+IFR+MS 12085.90 87.88 268.00 8895.90 3255.26 525.81 9.00 -2.61 -8.62 End Dir : 12085.9' MD. 8 12100.00 87.88 268.00 8896.42 3254.77 511.73 0.00 0.00 0.00 MWD+IFR+MS 12200.00 87.88 268.00 8900.12 3251.28 411.86 0.00 0.00 0.00 MWD+IFR+MS 12300.00 87.88 268.00 8903.83 3247.79 311.99 0.00 0.00 0.00 MWD+IFR+MS 12400.00 87.88 268.00 8907.53 3244.30 212.12 0.00 0.00 0.00 MWD+IFR+MS 12500.00 87.88 268.00 8911.24 3240.82 112.25 0.00 0.00 0.00 MWD+IFR+MS 12558.61 87.88 268.00 8913.41 3238.77 53.71 0.00 0.00 0.00 Start Dir 4/100' : 12558. 12600.00 89.53 267.96 8914.34 3237.31 12.36 4.00 4.00 -0.09 MWD+IFR+MS 12611.69 90.00 267.95 8914.39 3236.90 0.67 4.00 4.00 -0.09 Y-03A T5 A 12700.00 86.47 267.95 8917.11 3233.74 -87.52 4.00 -4.00 0.00 MWD+IFR+MS 12800.00 82.47 267.95 8926.74 3230.18 -186.97 4.00 -4.00 0.00 MWD+IFR+MS 12900.00 78.47 267.95 8943.30 3226.65 -285.51 4.00 -4.00 0.00 MWD+IFR+MS 13000.00 74.47 267.95 8966.68 3223.17 -382.65 4.00 -4.00 0.00 MWD+IFR+MS 13107.00 70.20 267.95 8999.14 3219.52 -484.52 4.00 -4.00 0.00 41/2" 13107.73 70.17 267.95 8999.39 3219.50 -485.20 4.00 -4.00 0.00 Y-03A T6 A . . TERRIE L HUBBLE BP EXPLORATION AKINC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 160 DATE \ \~ ID-DL{ ~~YT~o'rE ~:tc L- ~ I~ ¡OZ). ðV ti~ll~~C1'ÓlO)'¡ ðD DOLLARS First National Bank Alaska Anchorage,AK 99501 ~'..' .'tf~ \7,.,^ ~Q,. 11 ,\ ¡\ 1 , MEMO r VJlJ . !{U'!I !^-"\_ ¿ . "Mastercard Check" I: ¡ 25 2000bOI:Qq ¡l,llIb 2 27111 ¡ 55b"· 0 ¡bO ", . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ft4 ~-O 3A PTD# 2°9-2 ~_> x Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic ~'CLUE". Tbe permit is for a new wellbore segment of existing well,. . Permit No, .' API No. Production. sbould continue to be reponed as a function 'of tbe original API number. stated above. HOLE )n accordance with 20 AAC 25.005(1), aU records, data and logs acquired for tbe pilot bole must be clearly differentiated In both name (name on permit plus PH) and API Dumber (SO 70/80) from records, datJI and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fun compliance with 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:Jcep1ion. _ {Company Name) assumes tbe liability of any protest to tbe spacing .e~ception tbat may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater 1ban 30' sample inten-sb from below tbe permafrost or from where samples are first caught and 10' sample iJiter:vals tbrough target zones. Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT Y-03A PTD#: 2042350 Company BP EXPLORATION (ALASKA) INC Initial Classrrype SER / WAGIN GeoArea 890 1 Permit fee attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ 2 Leas_e_numberappropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_n[que well. n_arn_e _and lJl!mb.er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . . . . .Yes. . . . _ . . . . . . . _ . . . . . _ . . . . . . . _ . . . . . . . _ 4 Welllocaled [nadefined.ppol _ Yes . _ _ _ _ . _ _ _ _ . . . 5 WeUlocated properd[stance from driJIing unitb.oundary_ . _ Yes. . _ . _ _ . . . . _ _ _ _ . . . _ _ _ _ _ . . . _ _ _ _ . . . _ 6 WellJoc¡;¡t~d pr9per .d[stan~ from other welJs. _ _ _ . . . . _ _ _ _ . . . _ _ . Yes _ _ . _ . . _ 7 .S.ufficientacreage_ayailable jndrillilJg \.mjt . _ Yes _ _ _ . . _ _ _ _ _ . . _ _ . _ _ _ _ _ . . . _ _ _ _ _ . . _ _ _ _ _ . 8 Itd~viated, js. weJlbore platincJuded . . . Yes _ _ _ . . . . . _ _ _ . . . 9 .Qperator only affected party. _ _ _ _ . . . _ Yes _ _ _ . . . _ _ _ _ . . . . _ _ _ _ . . . 10 .Qperator hé!s.apprppriate. bond inJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . 11 p.ermit Gan be iSSl!ed wjthout conservaJion order. . . _ _Yes. . _ _ _ _ . . . . _ _ _ _ _. . _ _ _ . . . Appr Date 12 pefllJit Gan be iSSl!ed wjthout aclministratille. apProval _ . _ _ _ _ _ . . . _ _ Yes _ _ _ . . . _ _ _ . . . _ _ _ _ _ _ . . . _ _ RPC 11/15/2004 13 Can permit be approved before 15-day wait Yes 14 Wellloc¡;¡ted within area alld_strata .authorized by.lnjecti9o Ord.er # (puUO# hC9l1lments) (For Yes. _ _ 8103 _ _ . . . . _ 15 AJI welJs.wit]1in.1l4.mile.area.of reyieW id.eotified (F9r servj~we!l only). . . . . . . . . _ . . . . . Y.es. . . . . . . Y-JJ4..Y-17.B, Y-:028.Y-16. . . . . . . . . . . _ _ . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre-produ.cecl injector; .durationof pre-productioo Less thall3 months_ (For.service well only) _ _No. . _ _ _ _ . . . _ _ _ _ . . . _ _ _ _ _ . . . _ 17 ACMP.F:indingof Con.sistency.h.as beenissuecl forthis Project . _ _ _ _ _ . . . .NA _ _ _ . . . . _ _ _ . . . . _ 18Condu.ctor string. provided _ _ . . . . _ _ _ _ . . . _ _ _ . . . . . .NA . . _ _ _ . . . 19S.urfa~casing. prQteGls alLknowll USDWs . . _ _ . _ . . _ _ _ _ _ _ . . . . _ . .NA . _ _ _ . . . _ _ _ _ . . . . _ _ _ . . 20CMT vol é!deql!ate. to circ.ulateoncond.uctor. 8. SLlrf.c,sg _ _ _ . . .. _ _ _ _ . . . _ .NA. . . _ _ _ _ . . . . _ _ _ . . . _ _ _ _ _ . . 21CMT v.ol é!deql!ateto tie-inJon9.string to.s.urf csg _ _ _ _ _ _ _ .NA _ _ _ . . . _ _ _ _ . . . _ _ _ . . . . 22 .CMT will çoYerall koown.productiye horizon_s_ . _ Yes. _ _ . . . _ _ _ _ . . . _ _ _ _ _ . . _ _ _ _ _ . . _ . _ _ _ . . . . _ _ _ . . . . _ _ _ _ . . . _ _ _ _ _ . . . _ _ _ . . _ 23 .G.asing designs aclequa.te {or C,T, ß&permé!frost _ _ _ _ _ . . . . _ Y.es_ 24 Adequate.tan.kageor re.serve pit _ _ _ . . . . _ Yes. . _ _ _ . . Nabors2_ES. . _ . . . . . _ _ _ _ . . . _ 25 Itare-drill, has a 10~403 for abandonlT!e_nt be~o approved _ _ _ . . . _ _ _ _ _ . _ Yes _ . _ _ 11J13/04. . 26 Adequate.we!lbore separatjo.n.propOsed. . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . _ . . . . . . 27 ItdjverterJeQ.uired, does itmeet reguJations. . . . . _ . _ _ _ _ . . . _ _ _ . _ . . . _ _ _ _ . .NA . Sidetrack. Appr Date 28 .DJilIiog f)ujd progré!m SGhematic.& eQ.uipJistadequate _ _ _ _ .' _ _ _ . _ . Y_es _ _ Max MW. to,6_ppg.. _ . WGA 11/18/2004 29 _B.0.P.Es, do .they meet regulation _ ...... _ _ _ . .. _ Yes.. _ _ . . . . _ _ _ _ . . . _ _ _ _ . . . _ _ _ _ . . . _ 30 BOPE.press ra_tiog approprié!te;.test to.(pu.t psig incoml1lentS) _ _ _ _ . . Yes _ . _ Test to AOOQ psi. .MSf> 22.20 psi.. 31 Choke. manifold complies w/APL Rf>-53 (May 84) _ . _ . . _ _ _ _ . . . . _ _ _ . _ . . . Yes. . _ _ . . . . _ _ _ _ . . . _ . _ _ _ . . . _ . _ . . . . _ . 32 Work will OCCUr withoutoperation .shutdown. . . _ _ _ _ _ . . . _ Yes _ _ _ . .. _ _ _ . . . . _ _ _ _ . . . _ _ _ . . . _ . _ _ _ . . _ . 33 Is presence of H2S gas prob.able _ _.... _ _ _ _ . . . _ _ _ . . . . _ _ _ _ . . . _ _ _ _ _ . . _ _ No _ _ _ . NoLan H2S pad. . . _ _ _ . . . _ _ _ _ . . . . . _ _ _ . . . 34 Mecha.nicaLcpoclition 9{ wells within 80B yerifiecl (For service well ollly) . Yes. . Cmtng records indiÇélte l1l~ch. integrity oLa!l AOR w~lJs.. . _ ..... _ _ _ . . . _ _ _ . . . . _ _ Program SER On/Off Shore On Well bore seg Annular Disposal Unit 11650 Adm i nistration - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 35 36 Date 37 11/15/2004 38 39 Permit. Gan be iSSl!ed w/o hYdrogen. sulfide meaS.UTes. . . . . . . . . . . . . . . . . _D_ata. preseoted on pote_ntié!1 9ve.rpres.sur~ .zone,S. . . _ . . . .Seisl1lic.analysis of shallow gé!sz.ones. . . . . . . . _ . . . . . . . _ .S~Çlbedconditipo Sl!rvey -<if off-shore) . . . . . . . . . . . Conta.ct na.m.elpl1oneJorwe~kly progres.s.reports [exploratpryonlyl . _ - - - - - - . _ _ _ _... .No_ _ _ _.._ NA......... . NA _ .NA ...... .NA - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - Appr RPC - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - Geologic Commissioner: Engineering Commissioner: Date ,/ ~ ~ý Public Commissioner Date: Date D~ J}I /8'/1- Original Signed By John K. Norman o o . . . . Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drtlting Services LIS Scan Utility . $Revision: 3 $ LisLib $Revision: 4 $ Fri Jan 13 13:19:42 2006 Reel Header Service name......... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/01/13 Origin.................. .STS Reel Name...... ....... ...UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments.... .., ........ ..STS LIS Writing Library. Jò43B Q04-;;235 Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/01/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.... ..01 Previous Tape Name.......UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Y-03a 500292041101 BP Exploration Sperry Drilling Services 13-JAN-06 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003429877 N. WHITE J. RALL MWD RUN 2 MW0003429877 D. RICHARDSO J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 34 11N DE 1250 4732 MSL 0) 79.04 50.89 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.750 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 8050.0 9246.0 # REMARKS: . . 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE EXITS THE Y-03 WELLBORE AT 8184'MD / 7939'TVD, BY MEANS OF A WHIPSTOCK. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 5. MWD RUN 2 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND AT-BIT INCLINATION (ABI). 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN Y-03. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 28 DECEMBER 2005. MWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL (PDC). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 & 2 REPRESENT WELL Y-03A WITH API#:50-029-20411-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12725'MD/8997'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name... ........ ..STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation... ... .06/01/13 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 7731.0 7761. 5 STOP DEPTH 12675.5 12727.0 RPD RPM RPS RPX FET $ 9206.' 9206.5 9206.5 9206.5 9206.5 . 12682.5 12682.5 12682.5 12682.5 12682.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH 7731.0 7734.5 7743.5 7751.5 7754.5 7755.5 7758.5 7761.0 7771.0 7776.0 7781.0 7783.5 7790.0 7795.5 7802.5 7808.5 7811.0 7820.5 7825.0 7826.5 7836.0 7851.5 7867.0 7876.5 7906.5 7921.5 7925.0 7926.5 7933.0 7960.0 7964.5 7970.5 7975.0 7977.5 7986.0 7998.0 8005.5 8024.0 8045.5 8065.0 8078.0 8087.0 8111.5 8121.0 8132.5 8139.0 8159.5 8163.0 8172.0 8180.0 8182.5 8183.5 8185.5 12727.0 $ # MERGED DATA SOURCE GR 7728.5 7732.0 7740.5 7749.0 7752.0 7753.5 7756.0 7758.5 7767.0 7772.5 7777.5 7780.5 7787.0 7792.0 7801.0 7805.0 7808.5 7819.0 7822.5 7825.0 7833.0 7846.0 7862.0 7873.0 7905.5 7919.5 7921. 0 7923.5 7930.0 7957.0 7961. 5 7966.0 7973.0 7975.0 7983.5 7999.5 8005.5 8024.0 8045.0 8065.0 8076.0 8084.5 8109.0 8117.5 8129.0 8136.0 8160.0 8163.5 8170.5 8177.5 8181. 0 8182.0 8183.0 12724.5 PBU TOOL CODE MWD MWD $ BIT 1 2 RJtO . MERGE TOP 7728.5 9248.0 MERGE BASE 9248.0 12724.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.. .............. . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.. ......... ..... .....60 .1IN Max frames per record........... ..Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7731 12727 10229 9993 7731 12727 ROP MWD FT/H 0.9 445 139.607 9932 7761.5 12727 GR MWD API 14.21 617.9 65.143 9890 7731 12675.5 RPX MWD OHMM 0.28 621. 08 11.3018 6953 9206.5 12682.5 RPS MWD OHMM 0.25 1526.61 12.0119 6953 9206.5 12682.5 RPM MWD OHMM 0.81 2000 28.9081 6953 9206.5 12682.5 RPD MWD OHMM 0.52 2000 30.6875 6953 9206.5 12682.5 FET MWD HOUR 0.18 47.42 1.26239 6953 9206.5 12682.5 First Reading For Entire File..... .....7731 Last Reading For Entire File....... ... .12727 File Trailer Service name.... ...... ...STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/01/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name. ......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number. ....... ...1.0.0 Date of Generation...... .06/01/13 Maximum Physical Record. .65535 File Type........ ........LO Previous File Name... ...~SLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 1 .5000 START DEPTH 7728.5 7759.0 STOP DEPTH 9216.5 9248.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet 09-DEC-04 Insite 66.37 Memory 9248.0 8216.0 9248.0 6.1 45.1 TOOL NUMBER 103770 8.750 8050.0 LSND 10.60 47.0 9.5 3400 4.2 .000 140.000 .000 .000 .0 148.0 .0 .0 · Data Reference Point... .~...... .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Nsam 1 1 1 Units FT FT/H API Size 4 4 4 MWD010 MWD010 Rep 68 68 68 Code Channel 1 2 3 Offset o 4 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7728.5 9248 8488.25 3040 7728.5 9248 ROP MWD010 FT/H 1. 01 445 143.016 2979 7759 9248 GR MWD010 API 47.98 205.62 107.142 2977 7728.5 9216.5 First Reading For Entire File......... .7728.5 Last Reading For Entire File.......... .9248 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .06/01/13 Maximum Physical Record. .65535 File Type.......... ..... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.. ..... ....1.0.0 Date of Generation...... .06/01/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 92 04.0 9204.0 9204.0 92 04.0 9204.0 9217.0 9248.5 # LOG HEADER DATA DATE LOGGED: STOP DEPTH 12680.0 12680.0 12680.0 12680.0 12680.0 12673.0 12724.5 13-DEC-04 . SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point...... ....... . Undefined Frame Spacing.. ....... ........... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . Insite 66.37 Memory 12725.0 9248.0 12725.0 45.0 98.8 TOOL NUMBER 178513 159439 6.125 9246.0 LSND 8.60 61. 0 9.6 3700 3.5 .850 .410 1.500 2.000 70.0 150.8 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9204 12724.5 10964.3 7042 9204 12724.5 ROP MWD020 FT/H 0.9 360.91 138.049 6953 9248.5 12724.5 GR MWD020 API 14 .21 617.9 47.0564 6913 9217 12673 RPX MWD020 OHMM 0.28 621. 08 11.3018 6953 9204 12680 RPS MWD020 OHMM 0.25 1526.61 12.0119 6953 9204 12680 RPM MWD020 OHMM 0.81 2000 28.9081 6953 9204 12680 RPD MWD020 OHMM 0.52 2000 30.6875 6953 9204 12680 FET MWD020 HOUR 0.18 47.42 1.26239 6953 9204 12680 First Reading For Entire File........ ..9204 Last Reading For Entire File.......... .12724.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/01/13 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name...... ...... .LISTPE Date.................... .06/01/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.... ......... ...UNKNOWN Continuation Number..... .01 Next Tape Name. . . . . . . . . . .UNKNOWN Comments............ .... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name....... ..... .LISTPE Date.................... .06/01/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File