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206-105
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, May 5, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-19A PRUDHOE BAY UNIT Z-19A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/05/2025 Z-19A 50-029-22251-01-00 206-105-0 W SPT 8506 2061050 3600 1410 1410 1407 1400 1218 1202 1214 1216 REQVAR P Guy Cook 4/8/2025 2 year MIT-IA to 1.2 x the maximum anticipated injection pressure per AIO 3B.006. MI header pressure at 3000 psi. Testing was completed with calibrated gauges and a Little Red Services pump truck. 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 Z-19A Inspection Date: Tubing OA Packer Depth 614 3810 3758 3747IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250408065612 BBL Pumped:4.2 BBL Returned:3.6 Monday, May 5, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.05 09:09:06 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-19A PRUDHOE BAY UNIT Z-19A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/12/2023 Z-19A 50-029-22251-01-00 206-105-0 G SPT 8506 2061050 3720 2324 2329 2328 2327 1183 1190 1198 1201 REQVAR P Brian Bixby 4/10/2023 2 Year MIT-IA as per AIO 3B.006 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 Z-19A Inspection Date: Tubing OA Packer Depth 0 3955 3909 3896IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230410143451 BBL Pumped:5.4 BBL Returned:5 Friday, May 12, 2023 Page 1 of 1 9 9 99 9 9 9 9 9 99 9 9 92 Year MIT-IA AIO 3B.006 James B. Regg Digitally signed by James B. Regg Date: 2023.05.12 13:41:15 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 26, 2021 TO: Jim Regg '�ei�. 5 (rr�-Zr,T,t P.I. Supervisor � Z SUBJECT: Mechanical integrity Tess Hilcorp North Slope, LLC Z -19A FROM: Austin McLeod PRUDHOE BAY UNIT Z.19A Petroleum Inspector Sm: Inspector Reviewed By: P.I. sup" NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Z -19A API Well Number 50-029-22251-01-00 Inspector Name: Austin McLeod Permit Number: 206-105-0 Inspection Date: 4/13/2021 , IOsp Num: mitSAM210415164941 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z49A ' Type Inj H'�:P' 8506. Tubing 1124 _ D28 _ H24 - H25 - PTD 2061050 " Type Test SPTsi 3220 - IA 254 3902 3864 3853 BBL Pumped: 3.9 . BBL Returned: 3.4 OA 1250 - 1211. 1229 - 1236 Interval REQVAR P/F P Notes: Two year MIT -IA to 1.2x MAB'. AIO 3B.006. OA-DNE 1500psi. ✓ .s1ad,�e A ro��f 39.au, ero,)tAes �4— J197 Mo 0X14--9 iia , � OA- of Monday, April 26, 2021 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Regg I 5 Q p Jim of DATE: Wednesday, May 8, 2019 l P.I. Supervisor ((, SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC, Z -19A FROM: Guy Cook PRUDHOE BAY UNIT Z -19A Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry 5 9,Z- ZNON-CONFIDENTIAL NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Z -19A API Well Number 50-029-22251-01-00 Inspector Name: Guy Cook Permit Number: 206-105-0 Inspection Date: 4/6/2019 Insp Num: mitGDC190406181315 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- T T' a In W "TVD 8506 - TUbin 1350 1323 1311 - 1414=-� 'Type P — Well �'1���� TJ pe Test SPT Test sI 31zo IA g Iz6 3soo - 3aza - 3azs BBL Pumped: ed:----- — - - PTD zoeloso 4.3 BBL Returned: OA 43 094 nza 11sa� Interval aEQVAR P/F P Notes: AA 38.006 requires 24 month MIT -1A to 1.2 times maximum injection pressure. Job was completed with a triplex pump, bleed trailer and digital gauges. Wednesday, May 8, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 10, 2019 TO: Jim Regg�--� P.I. Supervisor 1l /� T I �1 SUBJECT: Mechanical Integrity Tests 1-( BP EXPLORATION (ALASKA) INC. Z -19A FROM: Guy Cook PRUDHOE BAY UNIT Z -19A Petroleum Inspector Ste: Inspector Reviewed By: P.I. Sup" 391:2 - NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Z -19A API Well Number 50-029-22251-01-00 Inspector Name: Guy Cook Permit Number: 206-105-0 Inspection Date: 4/6/2019 Insp Num: mitGDC190406181315 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 .Min 45 Min 60 Min Well Z -19A "Type Inj _ W TVD - asoe 'Tubing' , 1350 1323 ci )111 _- BBD 2061050 Type Test SPT Test psi 2126 IA 126 3500 1'-I 3475 Pumped: 43 BBL Returned: 3.7 OA 1143 1094 J_ 1124 Irl -_.___QJ_ Interval REQVAR P/F P l— Notes: AA 36.006 requires 24 month MIT -!A to 1.2 times maximum injection pressure. Job was completed with a triplex pump, bleed trailer and digital gauges. Wednesday, April 10, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,April 26,2017 To: Jim Regg5- ltt)I P.I.Supervisor 1 ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. Z-19A FROM: Adam Earl PRUDHOE BAY UNIT Z-19A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Z-I9A API Well Number 50-029-22251-01-00 Inspector Name: Adam Earl Permit Number: 206-105-0 Inspection Date: 4/23/2017 Insp Num: mitAGE170423135848 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z-19A ' Type Inj W •TVD 8506 - Tubing 1388 1455 - 1465• 1456 PTD 2061050 Type Test SPT Test psi 3900 ' IA 1015 4096 - 4079 - 4075 - BBL Pumped: 3.5 BBL Returned: 3.2 ' OA 949 - 757 900 - 962 - Interval REQVAR P/F — P v — Notes: MIT-IA Tested as per AIO 3B.006 / Satiti53 Ci Wednesday,April 26,2017 Page 1 of 1 • Py of TitJ, • w �� �j • THE STATE Alaska Oil and Gas of T c KA Conservation Commission Sf 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 �- Y' Fax: 907.276.7542 www.aogcc.alaska.gov Jessica Sayers Production Engineer BP Exploration(Alaska), Inc. SO P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-19A Permit to Drill Number: 206-105 Sundry Number: 316-244 Dear Ms. Sayers: 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 Zy'day of May, 2016. RBDMS LL MAY 2 5 2016 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROV S ' 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well H . Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 � t�oQ Plug for Redrill 0 Perforate New Pool El Re-enter Susp Well 0 Alter Casing 0 Other OA Squeezenav 3 H 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 206-105 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic 0 Service H 6. API Number: 50-029-22251-01-00 , 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No H PBU Z-19A , RECEIVED IV D 9. Property Designation(Lease Number): 10. Field/Pools: APRd ADL 0047450 • PRUDHOE BAY,PRUDHOE OIL ' !,`•' Veal,54' 11. PRESENT WELL CONDITION SUMMARY OC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): J�k f0) : 13120 4 9148 • 13032 9063 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 29-109 30-110 1490 470 Surface 2398 10-3/4"45.5#L-80 29-2427 29-2234 5210 2480 Intermediate 12616 7"26#L-80 27-12643 27-8692 7240 5410 Production Liner 618 4-1/2"12.6#L-80 12499-13117 8555-9145 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12804-12854 8845-8893 4-1/2"12.6#L-80 L-80 25-12503 Packers and SSSV Type: 5"Baker Liner Top Packer Packers and SSSV MD(ft)and TVD(ft): 12499, 8554.66 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary H Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service H' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG H" GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Sayers,Jessica be deviated from without prior written approval. Email Jessica.Sayers@bp.com Printed Name /Sayers,Jessica Title Well Integrity Engineer / Signature / Phone +1 907 564 4281 Date / 1/ lib 111 / c,%e?---'"1---- "'7 �� -�� COMMISSION USE ONLY Conditions of appr a Notify Commission so t tppresentative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: / Post Initial Injection MIT Req'd? Yes 0 No IE Spacing Exception Required? Yes 0 No LV Subsequent Form Required: /v - 4 0 I- APPROVED BYTHE Approved by: .J , COMMISSIONER COMMISSION Dater � -2.4,1 VTL 5/�0 /14- ORIGINAL RBDMS MAY 2 5 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 1S-4 A--b ({Z-z i6 • • Date: 04-20-2016 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: Z-19 SqueezeCrete MicroOA Squeeze Objective This program is intended to guide the execution of a fully cemented OA, low injectivity, MicroOA squeeze repair treatment with SqueezeCrete. This well exhibits high OA pressure when on-line. The well was previously treated with WellLock and was able to have manageable pressure when on-line until recently, in the last month. Well Detail Current Status: Not Operable Integrity Issues: Fully cemented OA; Well OA pressure is not manageable on- line Well Operation Detail Fluid Density: 14 ppg Equipment: See rig-up diagram Slurry: SqueezeCrete Relevant History: > 06/08/08: Reclassified as Operable, OA repressurization appears to be manageable. Decided not to pursue internal dispensation at this time. > 07/26/09: Conductor treated w/ 1.7 gal RG2401 > 10/09/09: MIT-OA Passed to 2000 psi > 12/22/11: AA for high OAP from hydrates cancelled -well cannot be maintained below MOASP I of 3 • • Procedure: 1 D Strap TOC/WeIlLock in OA 2 D Place, Squeezecrete in OA, until clean, 1:1 SqueezeCrete returns are observed. Take returns to a grounded bucket. 3 D Rig up pneumatic pump, and resume pumping operation by squeezing SqueezeCrete into well. Pump until bump (2500 psi max), bump pressure three times 4 D Let well cure, POP under evaluation. 2 of 3 1.• • 411111 TREE= 4-1/18 GIN SAFETY NOTBEk WELL REQUWES A SSSVIPMEN ON WELLAEAL), RAC Z-1 9A . -.CA PAS SUSTAWFOCSG PFIFSSUPE RIF TO ACTLA FOR- BAKER Si-ALLOW GAS AN)/OR 1-h`DATES OA WAS CARD C.6 H t-v= sr TO%R1-N 100OF SLRFACE DURING FG Of LIE ELEV= 54.12' ENCOUNTERED GAS;FIT CRATES 6 2850' 3300'VALE *OP-' 791' ;:;$ rn G(ACKED 10211407r•AUKILLARY PANEL MUST .•• 1.4ox Angle= 65' i,5978' 1„,4,.• 1,,,4 BE SWITCFS3 TO WA TER TO US WA_CONIC T1ON ON A". Oakum 1/3= 171143' 0°1..143 *V PAM-FOR=V. CONTACT PAO 0P5 FOR Datum ND= 8803 SS cc* 4.• .4 ASSISTANCE %to e• V.40 0 I.. riAinirnuni in=3 313"@ 2311T1.•.• • •4, •••• 2387I- . -4 112'ir_SXMP O-3 alx. 0tr. 14-112"HES X NIPPLE kx , • 41 10 3E4'4.41L4OLII A*DOW12-111A1 242/-2445' ....., TOP OF UKIENT 247V I l _ _ ? 4022' -(CA I CUIATFD TOO I L 1 0-114'csu.44•14 1.110 Lt£,ID-9 e5.• j-i- 3023' - ;"-- ---, 4443' I--r csc,268,1-ao TO XO 't•-•-0 ti ii rket P ?2_1-1, ili_... Il'x TO L-80 BTGAA 1:7 881 t-F_S COP‘011Y05.00 3275' I ( 1U7'-+ He&iv was.CIIIMMTKR 1 ,, _1,2"83(3 STUB 0:10127,06t!-i4000' 75 >, 1 ' i I 1234!1-1:1-1.2"FEs X NIP 0=30131 x 7-5/W CSG,29311,L-80 NSCT 4514' x XO TO c.ao BIC 1244r I r X 4-irr SKR S-3* .._. , -."5010011. t- iArAlif-_ X , .., OS A X I I I 12471' 1-14-1,2-HES X rst.I)=3 813" I X X I-98'C.341,29 for L13402' ' ,Co..kAll,_ ••• x x C-40 BTC,13=8 875" 40? ',A'A' x . A5••••". .1,1,- II I 12492 -14-172-FES X PP ID•3 81 r [--- -_-______. I 411 :. .,,,:" 401.p. 1 A 12SOW I-1r x 5'SKR LIP 0-4 400' I AtrOttr•St tt'' X X , *.-1,.R L 12504' j (4 II? wi.ellk 0-3 46r j 4)4%4.1 -F,2517n-7 x5-exR FLEX 1.00( 143R,0=3 875' ,....,..1...,Xt; 4 112.113u,1.,511. -1 17s04 x ...103337 1-80 la, 0152 OK \*1 1212T f-15'X 4-UT X0,ID 4 3 25r ID-=3 95Er A RERFORATION SUYDAM' ROI-10G 51NU LA0 Se I QINI OW NO r csG.261i. -I 12644' [ A/CLEAT TOP R3if 17 6 12804 L 80 STGII4 Note Fief er to Production OB for hstoncal pert data SIZE * SFE FITERVAL OpriScz I DATE 2-1'? 6 12804 128E4 0 11,017.06 4-VTLP 12511, 13118' •;4;4;4;• 13026 1 mil- "TA--------ncx2:0 tor14400 •••••• 1.OORRAK i ti C4:4,41, 0152 Ord,0=3 95.5• [ATE REV BY 0011.84NTS OA TE 'REV BY COMMENTS FR1,0f1C[@AY 1.114T 04/23192 UICERIORSIMAL COMPLETION WELL 2-19A 08/15108 517E51 SIOETRACK-A- FERNY 145 2061050 1117/01 TEUFAG P5F0RAT13t6 -1 AR No 50 029 22251 01 _ 12190'07 138R18IC ORLG DRAFT CORIECTIONS 1 SEC 19,T11N R12E,984'EN_82031 FAL _ . 02116/11 143/J1.0 A1:11DSSSV SAFETY POTE SP Exploratios(Alsokag 3 of 3 PrD 206-/05- Loepp, Victoria T (DOA) From: Sayers,Jessica <Jessica.Sayers@bp.com> Sent: Tuesday, May 17, 2016 10:03 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU Z-19A(PTD 206-105, Sundry 316-244); PBU L-105(PTD 202-058, Sundry 316-237) Micro OA Squeeze Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria! SCANNED FEB 1 0 201? See answers to question, below: 1. We have performed 15. So far,the 15 wells have been able to be operated within our operating limits post treatment. 2. Z-19: 1,250 psi; L-105: 1,110 psi 3. Some of the wells we have treated have IAxOA communication. However,the majority of wells treated have OA pressure that exceeds our operating limit when on-line. We think it is thermally activated, rather than a sustained casing source.The source is not known for these wells and there are a few theories including shallow hydrate gas. It's not definitive though. We don't have any other options we these wells. By treating them,we can manage the wells within our operating wells. Otherwise,the wells will remain shut-in until they are P&Ad.This is a huge bummer because the actual reservoir barriers (tubing and PC)are often shiny and new from recent rig workovers, casing cut and pulls, in which the OA is cemented to surface and this problem then becomes evident. Hope that makes sense and answers your questions. Please let me know if you need any more information! Thanks! Jess Sayers From: Loepp,Victoria T(DOA) [ma ilto:victoria.Ioepp0alaska.gov] Sent:Tuesday, May 17, 2016 9:38 AM To: Sayers,Jessica Subject: PBU Z-19A(PTD 206-105, Sundry 316-244); PBU L-105(PTD 202-058, Sundry 316-237) Micro OA Squeeze Jessica, A couple questions 1. How many micro annulus squeezes on the OA have been performed on wells in PBU and what have been the results? 2. How high is the OA pressuring up to in each of these two subject wells? 3. Do you know the source of the pressure? Thanx, Victoria Victoria Loepp 1 FTH(r, I4. THE STATE Alaska Oil and Gas s �, of Conservation Commission . _ __ ALAsKA Witt = 333 West Seventh Avenue rh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 • www.aogcc.alaska.gov Jessica Sayers Sat4t4Erj Engineering Team Leader h BP Exploration(Alaska), Inc. aU O(p —� P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-19A Sundry Number: 315-182 Dear Ms. Sayers: 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, St Cathy P. oerster Chair e.JL DATED this 0 day of April, 2015 Encl. • RECEIVED • STATE OF ALASKA MAR 3 1Q� ALASKA OIL AND GAS CONSERVATION COMMISSION / -13 7 ►jq' /s APPLICATION FOR SUNDRY APPROVALS .AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Rednll❑ Perforate New Pool❑ Repair WellIV Change Approved Program Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension UJ} I ri q ru7 rttit Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Well LocRk Teega7:44y • 2 Operator Name. 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 206-1.0.5-0• 3.Address: Stratigraphic ❑ Service 0 • 6.API Number. P.O Box 196612,Anchorage,AK 99519-6612 50-029-22251-01-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU Z-19A • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047450 ' PRUDHOE BAY, PRUDHOE OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured). 13120 • 9148. 13032 9063 None None Casing Length Size MD TVD Burst Collapse Structural Conductor • 80 20"91.5#H-40 28.66-108.66 28.66-108 65 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 12617 7"26#L-80 27.06-12643.66 • 27.06-8692.37 7240 5410 Production None None None None None None Liner 618 4-1/2"12.6#L-80 12499.63-13118 8555 63-9146.09 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12804-12854 8845.03-8892.87 4-1/2"12.6#L-80 L-80 25 59-12504 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft). See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work. Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development ❑ Service E • 14.Estimated Date for 15.Well Status after proposed work: 4/7/15 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16 Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 • Abandoned ❑ Commission Representative. GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Jessica Sayers Email Jessica.Sayers@BP.Com Printed Name Jessica Sayers Title Well Intervetions Engineer Signature a 564281OMMISSION USE ONLY Date Prepared by Garry Catron 564-4424 a/30/16— C Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 6— I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required. / U — 4 a 4-- APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: ¢.-3 •/S vr -3/3/ /i- ORIGINAL eiy345 �. _3,-,j Form 10-403 Revised 10/2012 Approved application is valid for 12 months from the dat pproval. Submit Form andAttachments in Duplicate RBDM APR - 6 2015 ,! w,,r— • Packers and SSV's Attachment ADL0047450 Well Facility Type MD Top Description TVD Top Z-19A PACKER 12447 4-1/2" BOT Perm Packer 8506 ` Z-19A PACKER - 12500 5" Baker Liner Top Packer 8556 by To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 03-16-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: Z-19 WeIlLock MicroOA Treatment Objective This program is for treating the micro-annular leaking in the fully cemented OA. This well exhibits OA repressurization when on production and is not manageable by bleeds. The liquid leak rate has been established at 0.05 gallons per minute at 3000 psi. WeIlLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to use the small diaphragm, suitcase, pump to squeeze the WeIlLock into the micro-annulus with high pressure and low volume. Once pressure fall off dissipates, Musol A followed by diesel, should be flushed across the OA valves to keep WellLock from setting up. Well Detail Current Status: Not Operable — PAL Previous Test: 11-18-14 CMIT-IA passed to 2500 psi Integrity Issues: Fully cemented OA, OA breaks MOASP, unmanageable by bleeds when on-line (all gas), highest observable pressure 1250 psi; Last H2S Reading: Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg 2% KCI: 8.3-8.5 ppg Diesel: 6.8 ppg Equipment: See rig-up diagram Temperature: Maintain 75°-80° F throughout the entire job Relevant History: > 09/13/06: RWO completed cement OA to surface Well Program: 1 D Pump 870 bbls hot, 180° F, crude down IA to heat up the OA. 2 D Over flush diesel out of OA void with several gallons of 2% KCI, 120° F, using the triplex. Purge void with nitrogen, displacing as much KCI as possible. 3 D *** Switch to diaphragm pump. Pump 1.5 gallon WeIlLock pill. Take returns 1:1 in grounded bucket. 4 D Maintain 3,000 psi for two hours by pumping KCI at signs of pressure fall off. This is to squeeze the WeIlLock into the microannulus. Record pressure and temperature readings on casing every hour. Do not exceed 3,500 psi. 5 D Swap to Musol A in suitcase pump, crack needle valve on returns line to grounded bucket. Maintain 3,000 psi on returns line. Pump 1 gallon of Musol A through pump, across valves to returns. 6 D Shut-in suitcase pump and returns. 7 D Swap to Musol A through triplex. Pump 1 bbl of Musol A across well to returns to durms, maintaining 3,000 psi. Swap to neat meth in triplex. Overflush Musol A with neat meth, maintaining 3,000 psi. 8 D Shut down triplex with 3,000 psi on well for one week. 9 D Leave crystal gauge on well and take pressure and temperature readings on casing, twice daily. Record in AWGS. 10 D After seven days, MIT-OA *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period. 2 of 3 f 1151=- 4 1/16'CAN SAFETY NOTE'S;WELL REWIRES A SSSV WHEN ON IVVE U1�W= Fat Z-1 9A MI "'OAH ) MES SURE CSGSU1ECAETO iACTUA1OR- BAKH2 SHALLOW GAS AM)I OR H'UPATES Q0.WASCMFD KB.REV 87 TO WTIFN 100"OF SURFACE CURIC RIG OPS. BF BEV= 5412' E C OU tT13a@ GAS 7 HY ORATES @ 2650'-3300'WFIE K(]P' ►moi+i •ice• ORE 0(A0(U)l0123107p'"AUXILLARYPAWN_NLBT 11ex Angle- 66'0 6978' ►•�•� •i I~Y~~~~ ~r~ject ~1J~il ~#istary File ~+~v~lr i:'age XFIVZE This page identifies tftc~se items that were not scanned during the initial production scanning phase. They are available in tyre original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. o~Q lQ - ~ ©~ Well History File Identifier Organizing (done) .,~.ded iiuumuiiiuii He,~a.~eeced iiiuiuioiuuii RE CAN C r Items: Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ^ Other: BY: Maria Date: D /s/ D~ Project Proofing II I II ~I II (I II) I I III BY: Maria Date: ~ ~ ~ g /s/ Scanning Preparation _~_ x 30 = © + ~ =TOTAL PAGES Q- (Count does not include cover sheet) BY: ~ aria Date: ~ ~ 3 ~ ~ p /s/ Production Scanning Stage 1 Page Count from Scanned Filer (Count does include cover heet) Pa a Count Matches Number in Scannin Preparation: I/ YES NO 9 9 BY: Maria Date: ! a..~~© ~ ~ !s/ ~ V I Stage 1 If NO in stage 1, page(s) discrepanciesrrrrwere found: YES NO YYY DIGITAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. (I I II II II III II ((III ReScanned III II'lll IIIII II III BY: Maria Date: /s/ Comments about this file: a „ ~e~,ed iuumuuuiiii 10/612005 Well History File Cover Page.doc 4Q2010 Not Operable Injector Repo • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sent: Friday, February 25, 2011 12:44 PM To: Maunder, Thomas E (DOA); AK, D &C Well Integrity Coordinator / .l Subject: RE: 4Q2010 Not Operable Report t e rable Injector e P 1 P 2 Tom, Z -210 has yet to be injected into. The well was drilled to support future producers, however, due to the lack of oil found in that fault block while drilling there were no plans to drill aproducer. ,— Z -19 /The well integrity team is waiting to hear back from the asst what the plan forward is. The AA will be cancelled if the asset does not have any near future utility for the well. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator MAR 0 1 2. Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder©alaska.gov] Sent: Friday, February 25, 2011 12:26 PM To: AK, D &C Well Integrity Coordinator Subject: RE: 4Q2010 Not Operable Injector Report Gerry and Torin, am reviewing the LTSI list and have some questions. It is likely that I will send several messages so as not to dump all the questions on you at one time. Here is the first go. So far I have looked up through WB -06 (5 wells). I look forward to your reply. Tom Maunder, PE AOGCC Z -210 204 -181 Our records does not show any injection having occurred into this well. Does your record confirm this? Can you provide a reason as to why the well has never been active? Z -19A 206 -105 If this well is to remain LTSI, should AA 3.017 amended be cancelled? From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIlntegrityCoordinator @ bp.com] Sent: Saturday, February 19, 2011 2:43 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU 2/25/2011 4Q2010 Not Operable Injector Rep, • Page 2 of 2 Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 4Q2010 Not Operable Injector Report Hello Tom, Jim, Phoebe and Guy, Attached is the 4Q 2010 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 402010.zip» Notes on wells: Removed from Quarterly Injection Report: B1 -14: Passed AOGCC MITIA with Badami field restart R -13: Furmanite wrap repaired startinghead leak. Added to Quarterly Injection Report: MPF -92: Added until injection is requested. MPF -95: Added until injection is requested. MPL -09: Added until Furmanite clamp is fabricated and installed to mitigate startinghead leak. 2 -12: Added until TxIA communication is repaired. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/25/2011 Well Z -19A Injection Plot TIO Plot Well: Z -19A Prt.CCllrt. \!C Raft. PTD: 2061050 o 0 o AA: 3.017 N Tbg IA Approval: 05/17/07 o OA 1 Hi Anniversary: 12 /11/06 Reason: High OAP due to rn hydrates Requirement: 2 Q a I year MITIA 1.2x max CI `- a o pressure WAG service o Last MITIA 03/20/08 0 • • Last 90 days • Last Month o 0 , 0 0 0 1 1 1 6/18/10 9/8/10 11/29/10 2/19/11 Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press - t „\._ cc , ,....A.,, v ,„ 6v '> Date (BWPD / MCFPD) (psi) WHP Date 1,600 (psi) (psi) ` �CC_ 't. i°/� 01/01/11 0 0 01/01/11 16 01/01/11 1,600 0 240 th- 12/31/10 0 0 12/31/10 1,600 0 240 12/30/10 0 0 12/30/10 1,600 0 240 _ (� 57 C/ 12/29/10 0 0 12/29/10 1,600 0 240 ` CJC.).�S O� �OD 12/28/10 0 0 12/28/10 1,600 0 240 12/27/10 0 0 12/27/10 1,600 0 240 + l 12/26/10 0 0 12/26/10 1,600 0 240 �= ` < <1 e--CA �� ` _ \ 12/25/10 0 0 12/25/10 1,600 0 ( ` ` 12/24/10 0 0 12/24/10 1,600 0 240 240 \' S . 3 --0 ! ` ` S .A\c\s t= 12/23/10 0 0 12/23/10 1,600 0 240 12/22/10 0 0 12/22/10 1,600 0 240 Q` Cy IIIIII 12/21/10 12/20/10 0 0 0 0 12/21/10 12/20/10 1,600 1,600 0 0 240 �� `�(S� /�� 240 4 ( � S ct 12/19/10 0 0 12/1/10 1,600 0 40 L C 12/18/10 0 0 12/18/10 1,600 0 240 12/17/10 0 0 12/17/10 1,600 0 240 V N. \ S- 4 .L \4 '- 12/16/10 0 0 12/16/10 1,600 0 240 12/15/10 0 0 12/15/10 1,600 0 240 12/14/10 0 0 12/14/10 1,700 0 240 I - - c 12/13/10 0 0 12/13/10 1,600 0 240 12/12/10 0 0 12/12/10 1,550 0 240 12/11/10 0 0 12/11/10 1,550 0 240 12/10/10 0 0 12/10/10 1,400 0 240 /`�' �\ 12/09/10 0 0 12/09/10 1,300 0 240 12/08/10 0 0 12/08/10 1,300 0 240 12/07/10 0 0 12/07/10 1,300 0 240 12/06/10 0 0 12/06/10 1,400 0 240 12/05/10 0 0 12/05/10 1,400 0 240 12/04/10 0 0 12/04/10 1,400 0 240 12/03/10 0 0 12/03/10 1,100 0 240 12/02/10 0 0 12/02/10 1,300 0 240 ,;...~ ~ ~ ;~ ~ ,~:m -~~ .~ ~. .;~~- ..,. r ,~'~ '~ .~'~ -'~ ~ ~! '~~ ~' ~VIICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~~~~ :`~ :' `~ ~ ~~~~i August 14, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7`h Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, ~ bp :5~~~iE~ 1~ G6~' ocT o 5 2oa9 plas~C~ ~ii ~ Gas Cons. Cor~nuR~~pr~ Anchora~e ~b- ~~ ~ ~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA t 1.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-O6 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-O8A 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670100 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 500292~9n0000 NA 1.2 NA 8.50 ~i26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-14B 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-18 1890960 50029219710000 NA 0.2 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 0.2 NA 1 JO 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7l26l2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-226 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-23B 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 50029218790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 5002921871~000 NA 0.3 NA 3.40 7/26/2009 Z-326L1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 5002921s95o10o NA 0.5 NA 3.40 8/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 5002923t820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-1o8 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-t12 2071720 5002923380000o NA surface NA l ~ 1.?~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061050 Well Name/No. PRUDHOE BAY UNIT Z-19A Operator BP EXPLORATION (ALASKA) INC API No. MD 13120 TVD 9148 Completion Date 11/17/2006 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD DIR/GR/RES/PWD/DWOB/DTORQ, AZI DEN / NEU, MWD DIR Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Tye Med/Frmt Number Name Scale Media No (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments D D Asc Directional Survey Rpt Directional Survey i Formation Micro Ima Col 1 I'Tg Cement Evaluation 5 Col 1 Cement Evaluation 5 Col 1 i Pressure 5 Blu 1 4~' C Las 15634 Density `~~ g Leak 5 Blu C Pdf 16509 Leak C Lis 16911 Induction/Resistivity Induction/Resistivity 25 Blu Induction/Resistivity 25 Blu Induction/Resistivity 25 Blu Directional Survey/ Yes 2410 13120 Open 10/4/2006 2410 13120 Open 1/4/2006 12300 12675 Open 10/10/2006 Modular Formation Dynamics Tester (MDT) 8- Sep-2006 100 12450 Case 10/16/2006 USIT, CBL, GPIT Orientation 12-Sep-2006 12250 13031 Case 1/29/2007 SCMT, Pres, Temp, CCL, GR 28-Oct-2006 12700 13015 Case 4/20/2007 STL, Temp, GR, CCL, Pres, Temp 21-Mar-2007 6000 12508 Open 10/26/2007 LAS, DRHB, DRHO, NPHI, RHOB w/PDF graphics 0 5015 Case 6/24/2008 LDL, WLD, XTU, HTU, CCL, WAFB, WAF, 7-Jun- 2008 0 5015 Case 6/24/2008 LDL, WLD, XTU, HTU, CCL, WAFB, WAF, 7-Jun- 2008 2215 13119 Open 9/17/2008 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, DRHO, NPHI 2445 13120 Open 9/17/2008 TVD Vision Service 10- Sep-2006 2445 13120 Open 9/17/2008 MD Vision Service 10-Sep- 2006 2445 13120 Open 9/17/2008 TVD Vision Service Sub Sea 10-Sep-2006 DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061050 Well Name/No. PRUDHOE BAY UNIT Z-19A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22251-01-00 MD 13120 TVD 9148 Completion Date 11/17/2006 Completion Status WAGIN Current Status WAGIN UIC Y Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /Y~ Chips Received? ~~ Analysis '14~L Received? Daily History Received? ~""`" Formation Tops Comments: Compliance Reviewed By: _ ___ __ _ Date: ~ ~)~~ 09/16/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.4881 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 99501 wou i..w ~ 14-18B 11978479 MEM GRADIOMANOMETER LOG ~ ~ _Ig. 08/24!08 1~ yV~V~ 1 04-28 11968951 LDL (REVISED) /~ - 06/29/08 1 1 R-12 12066544 MEM FLUID PROPERTIES LOG ) j 08/20/08 1 1 PSI-05 12103673 MEM DENSITY LOG 08/23/08 1 1 05-35 11962620 USIT (.- (0 08/26/08 1 1 B-36 120175111 USIT ~ ~' 09/03/08 1 1 V-207 12057639 USIT Q 08/11/08 1 1 Z-19A 40013908 OH MWD/LWD EDIT - - ~/ 09/10/06 3 1 12-28A 11962607 RST - U 07/01/08 1 1 B-12A 11998993 RST 03/05/08 1 1 V-207 12057639 CH EDIT (USIT) 08/11/08 1 nr cnee nrv~~nun GfIAC ~G /~CI~T DV n __-___-_-_______~---___.. _. .............-..... ..~. v....,,... v..~vvr, ~na.n ~v. BP Exploration (Alaska) Ina ~ .,,,~„ Petrotechnical Data Center LR2-1 ~ ~ g 900 E. Benson Blvd. - ~=~ 11 Anchorage, Alaska 99508 r•, - Date Delivered: =~) ~ ~ ~ f !}(117~~ -`i(' ~~ ~,~,~ Alaska Data & Consulting Services 2525 Gambell Street, to 400 Anchorage, AK 950 - 38 ATTN: Beth Received by: i3 NOT OPERABLE: Z-19A (PTD #2061450) OA Repressurization due to OA Hydrates Page 1 of 3 ' • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, July 13, 2008 10:56 AM t ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska); GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers Cc: Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: Z-19A (PTD #2061050) OA Repressurization due to OA Hydrates All, Well Z-19A (PTD #2061050} has been reclassified as Not Operable. BP Alaska is pulling together a team to study the hydrate source causing high OA pressure and to review long term operability options including an internal dispensation. Pending the results of this work, the well may be reclassified again. DHD is scheduled to periodically bleed the OA pressure. Please Bhutan and freeze protect Z-19A. Please call with any questions. Thank you, Anna ~?u6e, ~'. E. Wet! Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, June 17, 2008 8:12 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska}; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: NSU, ADW WI Tech; Wellman, Taylor T; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: Z-19A (PTD #2061050) OA Repressurization due to OA Hydrates All, Well Z-19A (PTD #2061050) has again been confirmed to have sustained casing pressure about 1000~si. The wellhead pressures were tubingllAlOA equal to 9501890/1090 on 06/16108. The well has been reclassified as Under Evaluation to evaluate the well far an internal dispensation to operate the well at a higher OA pressure limit. The current AOGCC Administrative Approval allows the well to be operated with an OA pressure limit of 1500 psi. ~. A Tlfl plot and wellbore schematic have bee included for reference. Please call with any questions, Thank you, Anna ~u6e, ~? E. 9/5/2008 NOT OPERABLE: Z-19A (PTD #2061050) OA Repressurization due to OA Hydrates Page 2 of 3 Well Integrity Coordinator GPB Wells Group Phone: (9fl7) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, June 08, 2008 7:47 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska); GPB, Wells Opt Eng; GPB, Optimization Engr Cc: NSU, ADW WI Tech; Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: OPERALBE: Z-19A (PTD #2061050) OA Repressurization due to OA Hydrates Ail, We11 Z-19A {PTD #2061050) was put on injection on 05/15/08. A TecWel Annular Flow Log was run on 06/07/08 and is being analyzed. The OA pressure has continued to increase but at a rate that appears to be manageable at the current MAASP of 1000 psi. A 30-day TIO plot has been attached for reference. The well has been reclassified as Operable under AOGGC AA 3.017 for OA repressurization. The decision has been made to not seek an internal dispensation for a higher MAASP at this time. Please notify Weil Integrity if the rate of OA repressurization increases and becomes unmanageable. « File: Z-19A Ti0 PIot.13MP » ~,/ Thank you, Anna Dude, tP. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, May 04, 2008 3:56 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska); GPB, Wells Opt Eng; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Roschinger, Torin T. Subject: Z-19A (PTD #2061050) UNDER EVALUATION - OA Hydrates AI I, Well Z-19A (PTD #2061050) is approved for continued injection by the AOGCC under AA 3.017 with a maximum OA operating pressure of 1,500 psi. The well has a fully cemented OA with sustained outer annulus pressur~ e likely due to shallow gas hydrates. It has been shut-in for several months and the OA repressurization has slowed to the point that the OAP has been below MAASP for several months. However, the repressurization rate is now too slow to perform further diagnostics. The plan forward for the well is as follows: 1. WOE: Put well on water injection. 9/5/2008 NOT OPERABLE: Z-19A (PTD #2061050) OA Repressurization due to OA Hydrates Page 3 of 3 • 2. E: If OA repressurization occurs, run a Tecwel Annular Flow Log to confirm the flow path behind the pipe. 3. D: Measure the gas flow rate from outer annulus 4. D: Monitor OAP until stabile 5. WIC: Evaluate well for internal dispensation to operate OAP above current MAASP. The well has been reclassified as Under Evaluation and may be put on water injection when convenient. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 9/5/2008 (S I t`U C~ '~\1 i _~ Z O i t~ -. .~ ~ dC O O O O O ~1 _.. o a o o ~~ °v °o °o °o ~'' ~ l'7 N r ~;~ ~ ~ O Q O ~ i __ :a i o0 a o ° I o ~ j ~ c a s ~ ~ ~ ~ m ' i QQ I ~ } i lYJ o Q 1 ~~ a ~; i 1 a~ ~{ ~. a~ ~~ ~. ~, v ~ ~ ~ ~ ~ ~ r ~ ~ I ~ ~ ° ~ ~ ~ o ~ 0 o a o ~ ('7 N r j TREE = 4-1116" CNV V1IELLHEAD FMC ACTUATOR _ _...w, BAKER KB. ELEV == 8Tj BF. ELEV..- 54.12' KOP = 794' Max Angle = 65° @ 5978' I~Datum MD - 12843'':, Datum TV D = 8800' SSA Minimum ID = 3.813°' @ 2387' 4-1i2" HES X NIPPLE I7-518" CSG STUB {0$119106) TOP OF CEMENT 10-314" CSG. 45.5#, L-80 LHE, ID = 9.950" 7-518" CSG CUT (DATE ?) 7-518" HES CIBP {08106106} 4-112" TBG STUB (07127/06} --~ 7-518" CSG, 29.7#; L-80 NSCT XO TO G80 BTC 4443' 7" C5G, 26#, L-80 TCII XO TO L-80 BTGM __ 8557' 9-518" HES ES CEMENTER 12385' I-I4-112" HES X NlP; ID = 3.813" I 12_~~ 7" X 4-112" BKR S-3 PKR, ID = 3.875„ 12471' I~ 4-1/2" HES X NIP, ID = 3.813" I 7-5l8" CSG; 29.7#, G80 BTC, ID = 6.875" PERFORATION SUMMARY REF LOG: SWS LWD GRJ RES ON 09!10108 ANGLE AT TOP PERF: 17° @ 12804' Note: Refer to Production DB for historical perf data SIZE SFF INTERVAL OpnlSgz DATE 2-1,'2" 6 12804 - 12854 O 11!17/06 SU~NOTES. "'OA HAS SUSTAWED CSG PRESSURE ® D HALLOW GAS AND 1 OR HYDRATES. OA WAS CEM TED TO WffHIN 100" OF SURFACE DURING RIG OPERATIONS. ENCOUNTERED GAS I HYDRATES @ 2650' - 3300' WHILE DRILLING (ADDED 10/23107)*** 23$7' ~4-1(2" HES X NIP, ID = 3.813" 10-314" MILLOUT WINDOW {Z-19A) 2427' - 2445' 1 l I 4022' CALCULATED TOC 4-1/2" TBG, 12.5#, L-80 TCII, .0152 bpf, ID = 3.958" 7" CSG, 26#, L-80 BTGM, ID = 6.276" 4-112" LNR, 12.5#, L-80 BTGM, .0152 bpf, ID = 3.958" 13026' I~ PBTD (TAGGED 1011 DATE REV BY ' COMMENTS 04(23!92 CINDER ORIGINAL COMPLETION fl91151fl6 N7ES 'SIDETRACK "A" '~ 11/17/06 TELIPAG PERFORATIONS 12119(07 DBPIPJC DRLG DRAFT CORRECTEONS DATE REV BY COMMENTS PRUDHOE BAY UNfi WELL: Z-19A PERMIT No: 2061050 API No: 50-029-22251-01 SEC 19, T31 N, R12E, 984' FNL & 2031' FWL BP Exploration {Alaska) L 12492' 4-112" HES X NIP, ID = 3.813" 12500' 7" X 5" BKR LTP, ID = 4.400" 12504' 4-1/2" WLEG, ID = 3.958" 1251 T 7" X 5" BKR FLEX LOCK 12504' HGR, ID = 3.875" 12527' S" X 4-1;'2" XO, ID = 3.958" ffV~L~ ~~~ ~~ ~ l°I~a4/t/~11~".4L ~___;~ ;;: ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~O~ -OY ~ ~/la6~i,'S vZC~co -/og ~/(aS~j and ProActive Diagnostic Services, Inc. Attn::. Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakDetection -WLD 15-Jun-08 G28A 1 BL / EDE 50-029-20867-01 2) Leak Detection -WLD / WAF 07,Jun-08 Z-19A 1 BL / EDE Signed Print Name: t_it.~~c}~u o ~~_ 50-029-22251-01 Date : - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (9071245.88952 E-MAIL. ~~:~S~iu"?i`,S:,~i} (~5'?~5a"3a'?iu~^~...~~`~ WEBSITE: l~7°i j',`"'° ~x:~€4. ,~;a9 C:\Documerts and Settings\OwneclDesktop\Transmit BP.doc Z-19A (PTD #2061050) UNDER EVALUATION - OA Hydrates Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~~ ~~(~ Sent: Sunday, May 04, 2008 3:56 PM ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska); GPB, Wells Opt Eng; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Roschinger, Torin T. Subject: Z-19A (PTD #2061050) UNDER EVALUATION - OA Hydrates All, Well Z-19A (PTD #2061050) is approved for continued injection by the AOGCC under AA 3.017 with a maximum OA operating pressure of 1,500 psi. The well has a fully cemented OA with sustained outer annulus pressure likely due to shallow gas hydrates. It has been shut-in for several months and the OA repressurization has slowed to the point that the OAP has been below MAASP for several months. However, the repressurization rate is now too slow to perform further diagnostics. The plan forward for the well is as follows: 1. WOE: Put well on water injection. 2. E: If OA repressurization occurs, run a Tecwel Annular Flow Log to confirm the flow path behind the pipe. 3. D: Measure the gas flow rate from outer annulus 4. D: Monitor OAP until stabile 5. WIC: Evaluate well for internal dispensation to operate OAP above current MAASP. The well has been reclassified as Under Evaluation and may be put on water injection when convenient. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 5/19/2008 ~a Date 10-12-2007 Transmittal Number:92914 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 02-16C ~p3--rQ~~ ~as.ro~~l __ __ _ 02-16CPB1ap ~--0$~--¢lS~ol9 _ _ 02-181 uh /a-I~~ 04-01 A ~p3--a3S, _~ LSI~Ca--._---__ 15-16B_s'X~ =v33----t_~~f 15-166P61 _~?~-Q~-3 «~_.________ 15-16BPB~~~A~-~ L~~~a~-~- 18-27 D_~0~-1,33 I ~~`(__~_ _ __ _ . 18-27D. P61 __-a0~_l~~ _l S~ZC05------__.----- ---- A-42A_ __ ~ -~3v _ __r56a~ .- _ ____ .. _._-- G-24A _ ?6L- ~'~2--1-_ __. G-24APB1 aCVlo_--fl~a....!~fQo~~i----.__.._.~__._ P2-11A ~Q(o -C>o~l(o _15_~ac2.."t_-----.____._.__._. P2-11 APB1 _3C~Ca--c~-a_lo...._1~63.Q_:..___._____._._ P2-36A _ ~~--.-.c~2.~_ _ 1573!--_- _._ ._._ P2-37A o'~OS:-OS~-.__.1.!_-~~Gr3a P2-37AP61-._3;b,S'-_D~.~ --~1~C,o.33..------- - r+ ~--d~,x~ -any ~ ~s`f ____ - ----__ -102 _ _~_.~.._.~ ~.v /~P= c~ -102PB 1 Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 AnchoraDe, AK 99519-6612 «~. SARAH PALIN, GOVERNOR ~~TT oiIL1•-7~ ®ii/ Disf1 X47 333 W. 7th AVENUE, SUITE 100 C®"S~Rs~~®is C®1~1~1Q~7SI®is ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 3.017 (Amended) Mr. Steve Rossberg, Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU Z-19A (PTD 2061050) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order 003.000, the Alaska Oil and Gas Con- servation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. (``BPXA")'s request for administrative approval to inject water and gas in the subject well. PBU Z-19A exhibits outer annulus pressure that stabilizes at 900 to 1100 psi and is con- sistently higher than the inner annulus pressure. BPXA provided supplemental informa- tion on April 8, 2007 demonstrating by gas sample analysis that the outer annulus pres- sure is likely from a know gas hydrate deposit penetrated by PBU Z-19A. The Commis- sion was advised on May 16, 2007 by BPXA of difficulties in maintaining outer annulus pressures below 1000 psi as required in the administrative approval granted April 13, 2007. The Commission finds that, based upon reported results of BPXA's diagnostic procedures, PBU Z-19A exhibits two competent barriers to the release of well. pressure. AOGCC further finds that BPXA is able to manage the outer annulus pressure with pres- sure bleeds and a maximum allowable pressure of 1500 psi. Accordingly, the Commis- sion believes that well operation in water and gas injection service will not threaten the environment or human safety. AOGCC's administrative approval to inject water and gas in PBU Z-19A is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tionrates; AIO 3.017 (Amended) May 17, 2007 ,Page 2 of t 3. BPXA shall perform aMIT - IA every 2 years to 1.2 times the maximum antici- pated well pressure; 4. BPXA shall limit the well's outer annulus pressure to 1 X00 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection; and 7. The MIT anniversary date is December 11, 2006. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, Alaska and dated May 17, 2007. Daniel T. Seamount, Jr. Commissioner Cathy . Foerster Commissioner c.-vim << i i rrwv i.v/v/ i~ca~uw~ Lvi iucica~cu vr-i ~ica~wc uiuu Subje~t:~~-19A (PTD #2061050) Request for increased OA pressure limit '~ From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllnteb tyEngineer@BP.com> Date: Wed, 16 May 2007 16:45:56 -0800 To: James Regg <}im_regg cuadmtn.state.ak.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWe1lIntem-ityEngineer c~~,BP.com>, "Robertson, Daniel B (Alas~a~" <Daniel.B.Robertson a~BP.com>, "EngeI, Harry R" <Harry.Engel a~BP.com> Jim, Z-19A (PTD #2061050) has high outer annulus pressure, which stabilizes between approximately 900 to 1100 psi, due to a hydrate formation at the surface casing shoe. An Administrative Approval has been issued for continued operation of this well. However, the well is not operable under the condition that "BPXA shall limit the well's outer annulus pressure to 1000 psi". The purpose of this email is to request that the pressure limit on the well's outer annulus be 1500 psi; ~'~ this is 30% of the rated casing burst pressure. This will provide for less frequent bleeding of the outer annulus and will allow for the well to remain on injection. Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1 of 1 5/16/2007 4:50 PM Schl+umberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR ~ u 2Q07 ....~ ail ~ (~~~ ~an~, ~;~linrri ,~ .: h f,, ,_ WPII .Inh $ Inn fl~accrinfinn Ihtn NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay RI Rnln. Rfl 04/18/07 02-15 11661130 MEM PROD PROFILE 02/25/07 U-066 11469946 MEM PROD PROFILE 02!24107 P-09L1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL1 11661128 MEM PROD PROFILE 02!19!07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 17676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11 B 11649954 MEM PROD PROFILE 03/22!07 1 P2-37A 11628754 MEM DEPTH CONTROL LOG 02!11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y-06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20/07 1 03-36 11649951 MEM STATIC PRESS 8 TEMP 03/18/07 1 YLtHAt Hl:R1VVVVLtUl9t KtGtIYI tSY SIlaIVllVli AIVU Kt1UK1VIIVli VIVt GVYT tAGH IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: = ~' ~~ ~ ~" 77~~ ~~yy -~1~~~ ~~ ®L~~B'J~~~aa®ld ~®iv~d~i~t7~~®li • Ss3Rsik P,9LlA(, GOVERr`VOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMIlyISTRATIVE APPROVAL AIO 3.017 Mr. Steve Rossberg, ~h/ells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU Z-19A (PTD 2061050) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order 003.000, the Alaska Oil and Gas Con- servation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to inject water and gas in the subject well. , PBU Z-19A exhibits outer annulus pressure that stabilizes at 900 to 1100 psi and is con- sistently higher than the inner annulus pressure. BPXA provided supplemental informa- tion on April 8, 2007 demonstrating by gas sample analysis that the outer annulus pres- sure is likely from a know gas hydrate deposit penetrated by PBU Z-19A. AOGCC finds that BPXA is able to manage the outer annulus pressure with pressure bleeds. The Commission further fords that, based upon reported results of BPXA's diagnostic proce- dures, PBU Z-19A exhibits two competent barriers to the release of well pressure. Ac- cordingly, the Commission believes that well operation in water and gas injection service will not threaten the environment or human safety. AOGCC's administrative approval to inject water and gas in PBU Z-19A is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform aMIT - IA every 2 years to I.2 times the maximum antici- pated well pressu~ ~; 4. BPXA shall limit the well's outer annulus pressure to 1000 psi; ` AI03.Oi7 April 13, 200? Page 2 of 2 5. 13PXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection; and 7. The MIT anniversary date is December 11, 2006. As provided in A5 31:05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, Alaska and dated April 13, 2007. Daniel T. Seamount, Jr. Commissioner ~r !~ Cathy . Foerster Commissioner 01 /25/2007 ~~i~~~IN~~~~fi~ '. - ~.- ~ a ~/ j Alaska Data & Consulting Services p,,^ ~~,i F., ~ .~~~~~ 2525 Gambell Street, Suite 400 "~ - Anchorage, AK 99503-2838 ATTN: Beth _. p ,~ ,;taa~ta41-'?1C~~; Wall _Inh tt : n.. ..~:~ NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay P2-37A 11491392 MEM PROD PROFILE 11/15/06 1~ Y-238 11418299 MEM PROD PROFILE 09/06/06 1 NK-07A 11588698 MEM GLS 12/21/06 1 07-01A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-08A 11485780 MEM GLS 12/20/06 1 NK-27 11588699 MEM G!S 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12/22/06 1 DS 09-32 11555530 INJECTION PROFILE 12116/06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A 11539744 MEM INJECTION PROFILE 12/06/06 1 S-02A 11285936 MEM PROD PROFILE 08/17/06 1 12-32 11536184 USIT 12/05/06 1 MPS-10A 11486087 COMPOSITE WFL/LDL 12/14/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L1 11588700 MEM PROD PROFILE 12/23106 1 E-11B 11434757 DSI 10/24/06 1 E-11 B 11434760 DSI 10/29/06 1 E-11 B 11434760 FMI 10/29/06 1 G-14A 11485777 MEM PROD PROFILE 11/27/06 1 G-14A 11485777 SCMT 11/27/06 1 o: twee wrvw:/1~wn cn~r ~~ w~.w~'..i e ..... ...... ...~ ~~~..~-..-._ __._ _____ _ BP Exploration (Alaska) Inc. --_--- ~ _. _._....__ ~.._ .__..,.............~ .,,,. . ~.,,,,, ,,,. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Dafe Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • \\ ~~. IVE® STATE OF ALASKA • ,~D ALASKA OIL AND GAS CONSERVATION COMMISSION '~4`~~ ~ ~ ~~O% REPORT OF SUNDRY WELL OPERATI®~l~oil (aas Cons. Cofnmission Abandon^ Repair Well^ Plug Perforations^ Stimulate ^ Other Alter Casing Pull Tubing Perforate New Pool Waiver0 Time Extension Change Approved Program Operation Shutdown Perforate XQ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. Name: 4. Current Well Class: Development ~ Exploratory 5. Permit to Drill Number: ~ -1 3. Address: P.O. Box 196612 6. API Number ~ Anchorage, Ak 99519-6612 Stratigraphic~ ServiceQX 50-029-22251-01-00 7. KB Elevation (ft): 9. Well Name and Number: a2.ss Z-19A ADL-047450 1. Present Well Condition Summary: Total Depth measured 13120 feet true vertical 9148.0 feet Effective Depth measured 13032 feet true vertical 9063.0 feet Prudhoe Bav Field / Prudhoe Bav Pool Plugs (measured) Junk (measured) Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20" 91.5# H-40 33 - 110 33.0 - 110.0 1490 470 SURFACE 2990 10-3/4" 45# NT-80 32 - 2427 32.0 - 2427.0. 4230 2270 PRODUCTION 40 7-518" 29.7# L-80 31 - 71 32.0 - 71.0 8890 4790 PRODUCTION 12573 7" 26# L-80 71 - 12644 71.0 - 8693.0 7240 5410 LINER 618 4-1/2" 12.6# L-80 12500 - 13118 8556.0 - 9213.0 8430 7500 Perforation depth: Measured depth: 12804-12854 True vertical depth: 8845-8893 Tubing (size, grade, and measured depth): 4-112" 12.6# L-80/9Cr @ 29 - 12504 Packers & SSSV (type & measured depth): 7" Baker S-3 Packer @ 12447 12. Stimulation or cement squeeze summary: Intervals treated (measured): " ;,a ~ ~~;I~ ~' ~* ~D~I~ Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Infection Data Prior to well operation Subsequent to operation, 14. Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubing Pressure _.. __ SI --- --- --- 1170 --- 722 Copies of Logs and Surveys run _ Daily Report of Well Operations _ X 15. Well Class after proposed work: Exploratory Oil Gas Development Service~X WAG ^X GINJ~ WINJ~ WDSPL~ >ared by DeWayne R. Schnorr (907) 564-5174 7. 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: Contact DeWayne R. Schnorr NIA Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature Phone 564-5174 Date 1/4/07 Form 10-404 Revised 4/2004 --I i I t~-l,~ • • Z-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/28/2006 LOGGED CEMENT BOND LOG FROM TD UP TO 12250'. TD FOUND AT 13026'. LOGGED PASSES AT 30 FPM. DURING LOGGING THERE WAS 500 PSI WHP. LOGGED PRESSURE AND TEMPERATURE DATA ACROSS SAME INTERVAL. NO PROBLEMS RIH OR POOH. DID NOT PERF WELL AFTER LOGGING SCMT. WELL LEFT SHUT IN. TURNED OVER TO DSO. **JOB INCOMPLETE**. CONTINUED ON 29-OCT-2006 AWGRS. 10/29/2006 CONTINUED FROM PREVIOUS DAY DID NOT PERF WELL AFTER LOGGING SCMT. WELL LEFT SHUT IN. TURNED OVER TO DSO. ***JOB INCOMPLETE -DID NOT PERF*** 11/17/2006 ****** WELL SHUT IN ON ARRIVAL. SSV CLOSED. ***** PERFORATE 50' WITH 2.5" POWERJET OMEGA CHARGES LOADED 6 SPF. AVERAGE PENETRATION 30.6" AND AVERAGE ENTRANCE HOLE 0.32". MAX TOOLSTRING LENGTH=39.5'. MAX OD=2.5" GUNS SHOT IN TWO RUNS. TUBING PRESSURE DROPPED FROM 175 TO 0 PSI AFTER FIRING GUN#1. INTERVAL SHOT WAS 12804 TO 12854 FT. INITIAL T/I/0=50/0/150 FINAL = 150/0/150 **** WELL LEFT SHUTIN, SSV CLOSED ***** 11 /26/2006 T/I/0=100/0/150. (Step rate test). Pressure up on IA to 1500 psi. RD off IA. RU to tbg. Spear into tbg w/ 10 bbls 60/40 meth followed by 200 bbls 2% KCL. Shutdown for 30 minutes. Perform step rate test from min. rate of .4 bpm @ 450 psi to max rate of 4.6 bpm @ 2300 psi. Shutdown for 30 minutes. Perform second step rate test Min. rate of .5 bpm @ 500 psi to max. rate of 4.6 bpm @ 2300 psi. Freeze protect tbg w/ 45 bbls 60/40 meth. Bleed IA pressure down to 0 psi. FWHP=100/0/300. 12/11/2006 T/I/0=550/380/960 State wittnesed MIT-IA PASSED (AOGCC MIT-IA post initial injection) IA pressured up with 4.4 bbls -10* meth to 4000 psi, 1st. test, Lost 20 psi in 1 st. 15 min., Lost xx psi. in 2nd 15 min., Bleed OAP from 960 psi. to xxx psi. down tubing, FWHP's 55/300/690 12/11/2006 T/I/0=550/380/960 Temp=126* AOGCC MITIA ***PASSED*** Witness by Chuck Scheve. Pumped 4.4 bbls 100% Meoh to pressure up IAP to 4000 psi. IA lost 20 psi in first 15 min and 0 psi in second 15 min for 20 psi total loss in 30 min. Bled WHPs back to FWHP=550/300/690 12/17/2006 T/I/0=970/840/1110. Temp=126*. Bleed OAP $ note what what is bled back, Monitor BUR. (Eval OA repressurization). OA FL @ 84' (< 4 bbl). Bleed OAP to flow line on well Z-20. Bled OAP from 1110 psi to 280 psi in 10 minutes. switch over to slop trlr. Fluid to surface. 81eed hose froze while switching to slop trlr. Thawed bleed hose to continue bleed, OAP increased 480 psi to 760 psi in 30 minutes. Bled OAP from 760 psi to 140 psi in 15 minutes and took a sample of the fluid comming from the OA for testing. Fluid was not a steady stream, fluid and gas mixed. Monitor BUR for 1 hour. OAP increased 640 psi to 780 psi during 1 hour monitor. No change in TP or IAP during bleed or monitor. Final WHPs=970/840/780. ***NOTE*** OA is increasing beyond IAP (when FO bled OAP). 12/18/2006 T/I/O = 950/840/1100. Temp =Hot. No AL. WHPs (post bleed). TBGP decreased 20 psi, IAP unchanged, OAP increased 320 psi. 81ed IAP to production from 840 psi to 260 psi in 3 min (all fluid). During bleed OAP unchanged. Post 30 min monitor TBGP unchanged, IAP unchanged, OAP unchanged. Bled OAP to production from 1100 psi to 500 psi in 10 min (all gas). Post 30 min monitor OAP increased 560 psi to 820 psi. FWHPs = 950/260/820. ***Informed operator to freeze protect and S/I well as per Area Injection Orders.*** Page 1 L Z-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/19/2006 T/I/0=0/0/1000 Load &LLR OA, MIT OA to 2000 psi.'`'`Failed 3 tests*'` (Post OA bleed) Attempted to LLR OA, Pumped .7 bbls crude before pressuring up to 2000 psi. (LLR too small for unit triplex) OA lost 200 psi in 15 min and 100 psi in second 15 min for a total loss of 300 psi over 30 min on 2nd and 3rd tests. Bled OAP. Final WHP's=0/0/950 12/19/2006 TIO = 160/vac/1090. Temp = SI. WHPs (post bleed). TBGP decreased 790 psi, IAP decreased 260 psi, OAP increased 270 psi overnight. Note: Talked with FO about the OAP being back to over 1000 psi. FO communicated that the OAP bleeds down quickly and then rapidly pressures back up to around 1100 psi and stays there. He is monitoring the OAP. Also, there is a heater trunk in the well house. 12/21/2006 T/I/0=70/VAC/1030. Temp=S1. WHP's. (Post SI). TP decreased 90 psi in 2 days. No change in IAP in 2 days. OAP decreased 60 psi in 2 days. FLUIDS PUMPED BBLS 3 Diesel --- PT Surface E ui ment 4.4 Methanol 58 60/40 Methanol Water 1 Crude 562 2% KCL 628.4 TOTAL Page 2 TREE = CNV 41 /16" 5M WELLHE4D = FMC Gen 5 CSG HEAD = TBG SPOOL = 11" 5M W/ T' MANDREL HANGER $ PACKOFF 11 X 1 t" SM TBG HANGER = ...._... _ - 11" X 4112" _ _~ ~r_ - - ADPFLANGE= 11"X41116" ACTUATOR = BAKER KB. ELEV = 87' BF. ELEV = 54.12' KOP = 794' Max Angle = 61 ~ 12438' Datum MD = ~ 14040' Minimum ID = 3.812" +~ 2200' 4-112" HE5 X NIPPLE 7-518" CSG STUB 3225' HES 7-518" CIBP 3275' 4-1/2" TBG JET CUT 4000' PERFORATION SUMMARY REF LOG: ??? ANGLE AT TOP PERF: 17 @ 12804' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2-1'2" 6 12804 - 12854 O 11117/06 7-5/8" X 4-1/2" BKR SABL-3 PKR, ID = 3.99" 13461' TOP OF 5-1 /2" LNR 13523' 7-5/8" CSG, 29.7#, ID = 6.875" 13802' PBTD 14397' 5-1/2" LNR, 17#, 13-C R, .0232 bpf, 14478' ID = 4.892" I )P JOINT IS 7-5/8", 29.7#, L-80 TC-II 2387' 4-1/2" HES X NIPPLE; ID = 3.812" 3022' 10-314" 45.5#, L-80, .0962 bpf, ~ = 9.950" 4022' CALCULATED CEMENT TOP 4442' 7" 26# TGII, .0383 bpf, ID = 6.276" 8557' 7" HES ES CEMENTER; ID = 6.171" 12384' 4-1/2" HES X NIPPLE; ID = 3.812" 12447' 7" x 4-1/2" BAKER S-3 PKR; ID = 3.88 12470' 4-1/2" HES X NIPPLE; ID = 3.812" 12491' 4-1/2" HES X NIPPLE; ID = 3.812" 12500' 7" x 4-1/2" BKR FLEX LOCK LNR HNGR 12504' 4-112" 12.6# TGII L-80, .0152 bpf, ID = 3.958" 12643' 7" 26# BTC-M, .0383 bpf, ID = 6.276" 13031' PBTD 3118, 4-1/2" 12.6# IBT-M L-80, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS _ 06/12/06 STG ORIGINAL COMPLETION 09/13/06 LV Actual Completion 11!17/06 TEL/PAG PERFORATE PRUDHOE BAY UNIT WELL: Z-19Ai PERMff No: 206-105 API No: 50-029-22251-01 SEC 19, T11 N, R12E, 984' FNL R 3247' FEL BP Exploration (Alaska) Z-19A I DRLG DRAFT RE: Z-19A (PTD #2061050) OA Repressurization plan forward • ~~ 1-1~`~ Subject: RE: Z-I9A (PTD #2061050) OA Repressurization plan forward ~ From: "NSU; ADW Well Integrity Engineer" <NSUADWWe1lIntegrityEngineer a)BP.com> Date: Thu, 041an 2007 15:I 1:07 -0900 To:.Ia~1~es R~~~«' 1iit~ re~~~~~i'adniin.tatc.ak.us=° C'C: "NSU. ,1D~'V ~~Vcll Integrity F_,n~~ineer~~ .~_NSU.AD~~'~~~clllnt~~riwF~n~~inecrrciBP.c~~m~ Hi Jim, During the bleed on 12/18/06, the TIO pressures were 950/840/1100. The IA pressure was bled to production from 840 psi to 260 psi in 3 min (all fluid). During bleed OA pressure remained unchanged. The UA pressure was bled to production from 1100 psi to 500 psi in 10 min (all gas). No sample was taken. Post 30 min monitor the OA pressure increased 560 psi to 820 psi. I have also included a TIO plot that shows the OA pressure stabilized a less than MAASP once the well was shut-in on 12/19/06. I've also include a MIT form showing the failed MITOA. Thank you, Anna Dube -----Original Message----- From: James Regg [mailto:~ii:r;~regg:zadmin_state.ak.us] Sent: Thursday, January 04, 2007 9:56 AM To: NSU, ADW Well Integrity Engineer Subject: Re: Z-19A (PTD #2061050) OA Repressurization plan forward Last test I have is the passing MITIA witnessed by Inspector on 12/11. well was tested to 4000 psi in IA presumably for MI injection. What were IA and OA pressures prior to and at the conclusion of bleeding the IA pressure? Also, please send results of MITOA. Any gas samples that would confirm source of pressure as hydrates? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Jim and Winton, This is a follow-up e-mail to the message I left today regarding well Z-19A (PTD #2061050). The well was recently worked over and converted to injection and is now exhibiting OA repressurization. TIO pressures were 70/VAC/1030 yesterday after an attempt to perform a LLR-OA. Although an MITOA failed, we were unable to establish infectivity into ', the OA. By bleeding IA pressure, we have confirmed the OA is not in communication with the IA. It is suspected that the OA is in communication with a hydrate formation. The well is now shut-in while we continue to evaluate the source of the OA repressurization. The plan forward for this well is as follows: 1. WIE: Put well on injection 2. DHD: Thaw and bleed hydrates from the OA A wellbore schematic has been included for reference. Please call if you have any questions. '; Thank you - */Jack L. Winslow/* 1 of 2 1/19/2007 9:22 AM RE: Z-19A (PTD #2061050) OA Repressurization plan forward • • '; Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 «Z -19A . pdf» ', Content-Description: Z-19A TIO p1ot.BMP ,;Z-19A TIO plot.BMP !Content-Type: image/bmp Content-Encoding: base64 Content-Description: MIT PBU Z-19A 12-19-06.x1s MIT PBU Z-19A 12-19-06.x1s !Content-Type: application/vnd.ms-excel Content-Encoding: base64 2 of 2 1/19/2007 9:22 AM -..., ___,n...,,..... ~.. _.... ti x b..~.e ~ ,,. , a € t~UE4..t..$°E~E~"h 0 = f ~lt{M C"at~E't 5 ~ m ,~.., e~ . ~,~~~,~~ +uSfa t l~A (~ = ` 11" `3ft+I YVi ~" IO~DE~E~ ~Fr° .~' ; 3 ~ , ,^ i-lAEiOER PACE<OFF [ `f°E~ S~OL = _ 11 %` ~ t" ~ TOP JOINT ~~ 7-5r8 ; 29.7#, L-80 TC-II f t~t~HAP~CCakfi 1~'~~-T~~$' € AL1P )=LANCE e~ .__ v_.~..,11" X 4-411€x" _ 237._ .. ~ ~_ ____'. -. :~ dIP C. IQ . E3> 2"-3 I ~.._ _....____ _r_._ A CTUATC?R - .rJ_ ___~ ~. __. BA k°.ER y '~`:.Ett i 1 #£ t __ 7-518` X 4-1 r2" BKR SAB~-3 FAR. [[ 3 {{~~ tEJ _ 3.9 1" { nn t t ~t'3Y 1 g'y'~yy°°y~ ,,rra~yy~ 3 m~~ ^^°a 7-X10";yA3V, f~.rthn ED ~F.Ji~va .,. ~s+s3:g~g PBTD 14387' 5-1/2" LNR, 17#, 13-C R, .02?2 bNf, ' 1447$ ID = 4.892" ` DATE REV BY CONt1e•1E'VTS DATE REV BY COEVSEvtE-_N fS 06/12/06 STG QRIGiNAL COMPLEfIC}N 09i13t06 l_V Actual Completi~~, 11i17i06 TEL.!PAG F~RPORATE PF2UDHOE 3AY l)NIT ~NELIL Z-19Ai PER~tiT No: 206-105 APE No: 50-029-?_2251-01 SEC 19, °T11N, f212E:::, 984' FNL & 3247° FE1.. SP (Exploration {Alaska) I-19A f10 plot.BMP (BMP [mage, 830x283 ~s) 4,000 3,000 • Z-1~TI0 Plot 2,000 L~. r:1.aASP 1 ,000 Off' hAAASP 0 rrrrrrillrl 114f2006 loft 7PSf2Q06 9/412006 1114!2006 + Tbg -~ IA -~ OA ~ . ~ OOA OOOA 1 J4r2007 019/2007 9:23 AM Z-19A (PTD #2061050} Noticed of OA Repressurization ~ ,~~~ Subject: Z-19A (PTD #2061050) Noticed of OA Repressurization From: "NSU,ADW Well Integrity Engineer" <NSUADWVt~ellIntegrityEngineer@BP.com-- Date: Tue, 19 Dec 2006 12:44:34 -0900 To: "AOGC~' .iim R~•g~~ (E-mail)" ~;jimreggr~i'~admin.state.ak.u~= , "AOGCC ~~~ inton Aubert (L.-mail j" .~~~win~on :~ul7er~~ci-admin.state.akus-= CC: "NSU, ,~D~~' ~-Fell Integrity Engineer" <~'CIS[~'1D~1~~~t%elllnl~~,rityEn~inccr(a:BP.com%, "CZobertson, Daniel B (.-~lasha)" ~~_I~~ii~iel.B.kobertson~u?QP.com=° "GPB, GC'2 Area N]~~r~~ ~~GPBGC?TL(uBP.coi~1~, "Rossberg, R Ste~~en" ~ -Steven.Rossberg~ci:BP.com==, "NSU, ADW Well Ohcration~ Su~er~~isor" =:NSL~.4D~~-,~~ellOi~crationsSuper~~isor(a,BP.c~~m=~ "GPB, ~l~'ells Opt. 1/n~~" ~~GPB~y'c1LsOptEng<<iBP.r~>>n'>, "GPB, GC'2 ~~~ellpad Lead" ~~_GPBGC?~~'ellpadLcad~a'BP.conl=~. ~~t~t~~~el, 1-f:~n~~ R" ~~==1larrv.Enge1~1BP.c~i7~=> Jim and Winton, This is a follow-up a-mail to the message I left yesterday regarding well Z-19A (PTD #2061050). The well was recently worked over and converted to injection and is now exhibiting OA repressurization. TIO pressures were 950/260/820 yesterday after an attempt to bleed off OA pressure to 500 psi it built back up. By bleeding IA pressure, we have confirmed the OA is not in communication with the IA. It is suspected that the OA is in communication with a hydrate formation. The well is now shut-in while we continue to evaluate the source of the OA repressurization. ;The well will be added to the Monthly Injection Report until this issue is resolved. The plan forward for this well is as follows: 1. DHD: Bleed OAP, monitor BUR -DONE, no IAxOA communication 2. FB: LLR-OA 3. W IE: Eval to attempt to displace OA with crude or attempt to warm the well and bleed off- pressure from hydrates. A wellbore schematic has been included for reference. «Z-19A. pdf» Please call if you have any questions. Thank you, .~nna tube Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1164 'iiContent-Description: Z-19A.pdf Z-19A.pdf' Content-Type: application octet-stream Content-Encoding: base64 1 of 1 12/20/2006 9:56 AM r~ f ~ °J~ t ~~ ~~r.~ _ ~.> > HtJ~ Li = _.~ _ _ f T ~M J,. ;' P.Y~, IL~f-.E_L NA9~IGER .='~ F.~ CK<~' F: r:~ ,r4~~<;L~ ~~. t,., , , t.. ~.,, _ _._ ~~ r~E_~,~ - ~~'l JF ~t~~ , __ -~,~~ 1~'a~ ;~~gl __ - ~1 f> 1~~,~~ ~~ _ _ _ u-~t.,~r~r9~,= _ . t~4o,r3'j ~ ~-19A ,I+~~ni~ ~r,u,t, ICi= ~.;39z'~ C} 210[3' -'~12" HES X ~;EPP1_E t , ,..5 ~.~c> i ~ ~- ___ J 3 I ~~~ - ;s° ~-~ ~ -- - - ~ rr ~ ~ , ~ ~„ t,,, i n' I~ -~~ _~__ i_. _ I '_ ~ ~..... 13401' L ~~i? Or Eft ''" tPlR 13b23' _ __ OTES: . ~~ ~oiriT is ~-s;s°, 29.7# ~-,~o Tc-ii __ __- - _ ~,~22'~_C .,;~' 4. ~~, t , c]..Q9~2upf, IL` '39;>t t,:<~~ N ~~ t:- ~.~~, _-, - _ -- - .._ ~-L- i __ 11191 ~ -~ -- - _ __ - ~ ~ L:c f I,..; - ~,~ -~ _- . 12 ;U4 ~. I ~~i-_~ ~~ ~ . _J 13031' t'BTD PBTD 14397' 5-1/2" LNR, 17#, 13-C, .0232 bpf, 1447$' I®= 4.892" 311$, 4-112" 12.6# IBT-M L-80, .0152 bpf, ID= 3.958'. DATE REV BY Cc7MMENTS DATE REV BY COhtMENT5 06/12106 STG ORIGENAL COMPLETION 09/13/06 LV Actual Completion 11/17106 TELIPAG PERFORATE PRUDHC)E BAY UNIT WELL: Z-19Ai PERMIT No: 206-105 API No: 50-029-22251-01 SEC 19, T11 N, R12E, 984' FNL & 3247' FEL BP F~rploration (Alaska} I t MEMORANDUM TO: Jim Regg ~~ Z ~~',~J;S~i:~ P.I. Supervisor t FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Wednesday, December 13, 2006 SUBJECT: Mechanical Integrity Tests BP E}CPLORATION (ALASKA) INC Z-I9A PRUDHOE BAY UNIT Z-19A Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UNIT Z-19A Insp Num: mitCS061212055751 Rel Insp Num API Well Number Permit Number: 50-029-22251-01-00 206-105-0 Inspector Name: Chuck Scheve Inspection Date: 12/11/2006 Packer Depth Pretest Initial _. 15 Min. 30 Min. 45 Min. 60 Min. - - ~ -- - --T- Well ~ Z-l9A '.Type IRS. ( W ~ TVD ~ 8505 ~ jA ~ - - , 380 4000 ~ -- -- - 3980 j 3980 ~ --` P T 12061050 TypeTeSt (SPT TCSt pSl ?I26 ~5 ~ QA ~ 960 940 ~, 960 960 i --- P/F P Interval ~IT~- ~ Tubing 550 ~ 550 ~ - ~- i s5o 550 _ --- NOtes Pretest pressures observed and found stable. Wednesday, December li, 2006 Page 1 of 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMI ION „/ ~2ECEI~/EB ~~ DEC 1 4 2006 WELL COMPLETION OR RECOMPLETION REPORT AND L~~~a (1jl & Gas Cons. Commission Anrhnr~nn 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 20AAC 25.105 2oAAC 2s.»o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. ~ 11/1/2006 12. Permit to Drill Number 206-105 306-290 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/22/2006 ~ 13. API Number 50-029-22251-01-00 4a. Location of Well (Governmental Section): Surface: 984' FNL °2031' FWL SEC 19 T11N R12E UM 7. Date T.D. Reached 9/10/2006 - 14. Well Name and Number: PBU Z-19Ai , , . , , , Top of Productive Horizon: 1637' FSL, 3491' FWL, SEC. 07, T11N, R12E, UM 8. KB Elevation (ft): 82.66' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1726' FSL, 3509' FWL, SEC. 07, T11N, R12E, UM 9. Plug Back Depth (MD+TVD) 13032 + 9063 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 599755• y- 599100 Zone- ASP4 10. Total Depth (MD+TVD) ~ 13120 + 9148 ~ Ft 16. Property Designation: ADL 047450 TPI: x- 601112 y_ 5967019 Zone- ASP4 Total Depth: x- 601128 ~ y- 5967108 • Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Surve y ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: 'F'LU vtv Ly~z ~ ~ /?~ L23`/ ~~ ~ ~ ° ~8' • r~, MWD DIR / GR /RES / PWD / DWOB / DTORQ, AZI DEN /NEU, MWD DIR / GR /RES /AIM, DEN /NEU, MDT, USIT, CBL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP .BOTTOM SIZE CEMENTING RECORD PULLED 20" Conductor Weld Surface 110' Surface 110' 30" 10-3/4" 45# NT-80 Surface 427' Surface 2234' 13-1/2" 1350 sx AS III 3 0 sx Class 'G' 7" 2 L- Surface 12 44' Surface 8693' 9-7/ " 591 x Li r 14 1 sx I s ' 4-1/2" 12.6# L-80 12500' 13118' 8556' 9213' 6-3l4" 73 sx Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TURING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-1/2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 / 9Cr 12504' 12447' MD TVD MD TVD 12804' - 12854' 8845' - 8893' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED Downsqueeze cement into the 10-3/4" x 7" annulus 132.6 Bbis LiteCrete w/ Gasblock (09/04/06) Freeze Protect w/ 80 Bbls Diesel 26. PRODUCTION TEST Date First Production: December 2, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE .SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27• CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach sepa~at~sheet, if necessary). Submit core chips; if none, state "none". ~ r ~ 0i" ~ `t~U~ None , ~ ~F~., I~EC) ~~ 200 ~ ~,~,~ ~ F Vt 'IEI) f I Form 10-407 Revised 12/2003 ~ ~ ~ ~ ! ~O~ TINUED ON REVERSE SIDE I 28 GEOLOGIC MARKERS 29. NATION TESTS Include and briefly s marize test results. List intervals tested, Name MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Schrader Bluff N 6688 4534' Schrader Bluff O 7050 4715' MDT was ran. Attached is a summary of MDT results. Base Schader Bluff/ Top Colville 7888 5104' Analyses (gas and fluid) of the only sample that was analyzed THRZ 10121 6326' -the fourth MPSR sample. All of the samples were collected from the same depth, and this sample was thought be TKLB 10326 6504' representative of the formation contents, plus it had drilling fluid filtrate. Kuparuk C 10366 6540' Kuparuk B 10447 6615' Gas analysis for the fourth MPSR sample from the MDT run. Kuparuk A 10525 6688' The sample is from the Sag River Formation. TMLV 10605 6763' Water analysis for the fourth MPSR sample from the Z-19A MDT run. The fluid also included a thin scum of oily material, TKNG 11400 7517' too small to analyze. TSG R 12637 8686' TSHU 12668 8715' TEIL 12775 8817' TSAD/lvishak Zone 4 12800 8841' lvishak Zone 3 12997 9030' lvishak Zone 2 13061 9091' 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. ~ ~~~ / Title Technical Assistant Date Signed Terrie Hubble PBU Z-19Ai 206-105 306-290 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A r v I NO. Drilling Engineer: .Shane Gagliardi, 564-5251 INSTRUCTIONS GeNew-~: 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). IreM 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 APt number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing toot. 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 Sehlumherg CLIENT BP WELL: Z-A1Pi Na. !f=ile Time MDT Job Report -.. F ` ~~ Mud TVD TVDSS Before Mud After Form Mob Temp S -nF=a~ 7n~ • DATE Page 1 of MRPA MRMU MRML Upper Element Lower Element MRPS 2: MRPS 1: 9/8/2006 Comments 11 19:18 12134.00 Correlation Pass -Down, need to add 6' 12 19:44 12378.00 Correlation Pass -Down 1 14 20;12 12649.00 12655.60 8697.34 8614.64 3914.77 3878.34 3750.92 0.70 203.80 Sa RNer 2 15 20:35 12650.00 12656.60 8698.33 8615.63 3889.25 3873.80 3754.97 0.30 206.50 Sa RNer 3 16 21;05 12651.50 12658.10 8699.80 8617.10 3894.80 3874.90 3710.03 0.70 208.10 Sa River 4 19 21;29 12653.50 12660.10 8701.90 8619.20 3901.22 3876.22 3758.76 0.20 209.90 Sa River 5 20 22:01 12656.50 12663.10 8704.67 8621.97 3914.18 210.10 Ve Ti ht -moved down 0.5' 6 21 22:12 12657.00 12663.60 8705.20 8622.50 3905.52 3877.91 211.40 ossible lost seal in a ti ht test 7 23 22:37 12650.80 12657.40 8699.30 8616.60 3915.37 3877.20 3720.65 0.80 211.20 Sa River 8 24 23:00 12652.50 12659.10 8700.90 8618.20 3905.77 3866.28 3711.94 1.60 212.80 1 MPSR 1397 Sa River 2 MPSR 1398 Sa River 3 MPSR 1399 Sa River 4 MPSR 1400 Sa River 5 MPSR 1401 Sa River 6 MPSR 1402 Sa River 7 MRSC 185 Sa River 9 25 3:02 12660.00 12666.60 8708.10 8625.40 3908.85 3879.60 215.10 Sa River Ti ht - No build u 10 26 12662.00 12668.60 8709.10 8626.40 3910.16 Sa River - Ti ht 11 27 4;03 12675.00 12681.60 8722.30 8639.60 3941.51 3894.00 216,50 Shublik -Tight S. Thornhill MDT results Z 19Ai.zls 12/1M2006 1~ ~ u • GPB LABORATORYANALYTICAL REPORT 907-659-5654 Ea,azi: GPBLab@bp.com Collection Date ~ 09/10/06 Facility Z-PAD Well Z-19 Location SCHLUMBERGER DOWNHOLE SampleType GAS COMPOSITION Sample Description WOA DRILLSITE GAS Analysis Name Analysis Unit Combination Result LINE PRES PSIG 1600 LINE TEMP DEG.F 68 METHANE-MOL% MOL% 87.271 ETHANE-MOL% MOL% 3.353 PROPANE-MOL% MOL% 1.717 I-BUTANE-MOL% MOL% 0.271 N-BUTANE-MOL% MOL% 0.842 I-PENTANE-MOL% MOL% 0.231 N-PENTANE-MOL% MOL% 0.304 C6P-MOL% MOL% 0.443 C02-MOL% MOL% 4.061 NITROGEN-MOL% MOL% 1.507 MOL WEIGHT 19.433 BTU GRSDRY IDEAL BTU@ 14.696PSIA 1065.0 BTU GRSDRY REAL BTU@ 14.65 PSIA 1064.5 BTU GRSSAT IDEAL BTU@ 14.73 PSIA 1048.9 BTU NET BTU@ 14.696PSIA 960.5 L SPG REA 0.6725 02 CONTAM MOL% 0.010 ~ 1 • GPB LABORATORYANALYTICAL REPORT 907-659-5654 Email: GPBLab@bp.COm FACILITY: DATE/TIME: WELL LOCATION: Z-PAD 09/12/00 00:00 Z-19 WELLHEAD SAMPLE DESC: PRODUCED WATER Analysis Name Analysis Unit Combination Result Chloride mg/L 4583 SPECIFIC GRAVITY (60 DEG F) 1.0065 DISTRIBUTION BOB DAWSON Reported by: at 11:55 AM on l2/14/06 BP EXPLORATION Page 1 of 20 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ;From _ To 8/4/2006 10:00 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 21:00 21:00 - 22:00 22:00 - 00:00 8/5/2006 00:00 - 01:30 01:30 - 02:00 01:00 - 03:00 03:00 - 05:30 05:30 - 06:00 06:00 - 10:30 10:30 - 11:30 11:30 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 18:00 18:00 - 20:00 20:00 - 20:30 20:30 - 22:30 Z-19 Z-19 REENTE NABOBS NABOBS Hours ~ R+COM ALASK 7ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 3/16/1992 : 8/4/2006 End: 8/28/2006 Release: 9/13/2006 Number: Description of Operations 6,00 MOB P PRE RD. Move f/Z-14 to Z-19. Spot pits. RU. Accept rig at 16:00. 2,00 WHSUR P WHDTRE RU lines to tree and prepare to circulate. 1.00 WHSUR P WHDTRE RU drill site maintenance and pull BPV. 2.00 WHSUR P WHDTRE Pressure test lines to 3500 psi. Well head/IA psi = 0. Circ. 50 bbls. Safe Surf O followed by 186 bbls. 9.8 ppg. brine at 3 bpm, 1200 psi. Check surface equipment for cause of high circ. pressures. OK. Circulate 8 to 10 bbls of Arctic Pak back to surface. Note: held pretour/prespud meeting for new day crew at 20:00-20:30. Covered general overview of Z-19Ai well plan. Covered Z-19Ai decomplete plan forward in detail. Discussed ABBI safety approach to each task. 1.00 W HSUR P WHDTRE Shut down and note pressure building on tubing. SITP = 600 psi. RU and take returns through choke. Pressure increasing on annulus. Circulate tubing volume of 9.8 ppg brine. 2 bpm, 700 psi. 2.00 WHSUR P WHDTRE Shut down to check SITP/SICP. No gas to surface. Check fluid wt. on returns. OK 9.8 ppg. SITP and SICP concurrently rise from 0 to 340 psi. Shut in and bleed off several times to zero psi. Shut in. Pressure still increasing SITP/SICP concurrently and slowly. 1.50 WHSUR P WHDTRE Check OA and find slight pressure on OA. OA flowing. IA and Tubing go on slight vacuum. Rig hose OA to IA and allow to u-tube for a few minutes. Pressure/flow bleeds to zero at ali points. Monitor well. Confirm well dead. Install gage to OA. 0 psi. Probable hole IA to OA. 0.50 WHSUR P WHDTRE PU TWC and install. Count 5-3/4 turns to lock up and measure 1-7/8" from tag up w/TWC on thread profile in hanger until threads bottom out and lock up. Test TWC f/above as unable to test f/below. 2.00 WHSUR P WHDTRE Monitor gages on IA and OA. Both 0 psi. ND tree. FMC checked threads on hanger. OK. 2.50 WHSUR P WHDTRE NU BOP stack and double stud adaptor. 0.50 WHSUR P WHDTRE RU for BOP test. 4.50 W HSUR P WHDTRE Pressure test BOPS to 250 psi low, 4000 psi high. Test top rams w/4" and 5" test jts. RD test equipment. Test witnessed by Lance Vaughan, BP WSL and Larry Wurdeman Nabors toolpusher. AOGCC representative Chuck Scheave waived AOGCC presence during the test. 1.00 WHSUR P WHDTRE PU Drill Site Maintenance lubricator and pull TWC. Monitor well. No flow. 0.50 PULL P DECOMP MU jt. to hanger. Back out lock down screws. Pull hanger free at 90000 Up wt. 1.50 PULL P DECOMP Circ. 9.8 ppg brine. 3 bpm, 1395 psi. RU to pull and lay down 4.5" completion equipment and tubing. RU Schlumberger spooling unit. 0.50 PULL P DECOMP LD landing jt. remove control lines f/hanger, LD hanger. 4.00 PULL P DECOMP LD 4.5" tubing to SSSV, RD spooling unit. Recovered 27 clamps and 4 stainless steel bands. 2.00 PULL P DECOMP Continue LD tubing. Total pulled = 100 jts. + 27.48" stub. Cut looked good. 0.50 PULL P DECOMP RD 4.5" tubing running equipment. 2.00 BOPSU P DECOMP Function test BOPs. RU and test lower pipe rams w/4" and 5" Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES r Date ;From - To j Hours Task Code ~ NPT 8/5/2006 20:30 - 22:30 2.00 BOPSU P 22:30 - 23:30 1.00 CLEAN C 23:30 - 00:00 I 0.50 I CLEAN I C 8/6/2006 00:00 - 02:00 2.00 CLEAN C 02:00 - 03:30 1.50 CLEAN C 03:30 - 12:00 8.50 CLEAN N WAIT 12:00 - 14:00 2.00 CLEAN P 14:00 - 17:30 3.50 CLEAN P 17:30 - 19:30 I 2.00 I CLEAN I P 19:30 - 21:00 1.50 CLEAN P 21:00 - 21:30 0.50 CLEAN C 21:30 - 22:00 I 0.501 CLEAN I P 21:30 - 22:00 0.501 CLEAN ~ N I WAIT 22:00 - 00:00 2.00 ~ CLEAN I N I WAIT 8/7/2006 100:00 - 00:00 I 24.001 CLEAN I N I WAIT 8/8/2006 100:00 - 03:00 3.00 CLEAN N WAIT 03:00 - 04:00 1.00 CLEAN N WAIT 10:00 - 12:00 2.00 CLEAN N WAIT 12:00 - 15:00 I 3.00 I CLEAN I N I WAIT 8/16/2006 115:00 - 16:00 I 1.001 BOPSUR P 16:00 - 21:30 5.50 ~ BOPSUR P 21:30 - 22:30 I .1.001 BOPSUR P Start: 8/4/2006 Rig Release: 9/13/2006 Rig Number: Page 2 of 20 Spud Date: 3/16/1992 End: 8/28/2006 Phase Description of Operations DECOMP test jts. RD test equipment. Install wear bushing. DECOMP Test casing to 4000. Leak off at 1900 psi w/10 bbls pumped at 1 bpm. Increase rate to 2 bpm, 2300 psi. Shut down. Bled down to 500 psi. in 15 mins. w/no pressure or returns to OA. DECOMP PU cleanouUgage run BHA including 6-3/4" bit, bit sub, hydraulic jars. DECOMP RIH w/ cleanout BHA to 3855'. No obstructions. DECOMP POH and LD cleanout BHA. Function test BOPs. DECOMP Wait on Schlumberger WL crew to get required 6 hrs rest and mobilize. (Left previous work location at 02:00 w/max. hrs.) Load pipeshed w/5" drill pipe. Perform rig maintenance. C/O liners in pumps to 5.5". Clean rig. DECOMP RU Schlumberger E-Line. DECOMP RIH w/USIT and log 7-5/8" casing f/4000' to surface. Receive order f/town team to shut in well, secure well, secure rig at end of USIT/CIBP a-line task at 18:00. Adjust rig for minimum fuel consumption. DECOMP RD/LD USIT equipment. PU wireline setting tool. MU 7-5/8" EZSV CIBP to setting tool. RIH to 3400' and log EZSV CIBP into place. Set top of plug 4' below casing collar at 3277'. DECOMP POH and RD Schlumberger wireline equipment. DECOMP RIH w/killstring of 15 stands of 4" HT-40 drill pipe. 9.8 ppg brine in well 3277' to surface. DECOMP MU TIW valve, top drive. Test casing to 3000 psi f/EZSV at 3277' to surface. Hold for 10 mins. DECOMP Secure welt. Secure rig and adjust rig for minimum power consumption. DECOMP Clean rig. Perform rig maintenance. PJSM at tour meeting on non-standard operation for unknown duration and importance of focus on safe operations during shutdown. Send two man team out to perform HSE audits and seek opportunity to make HSE related rig improvements. Results to be returned via STOP system. DECOMP Wait on orders. PJSM before all operations. RIH (/1425' to 2485'. Perform rig maintenance. C/O brake bands, service drag chain, mud cleaner, LD machine, maintain boilers. DECOMP Wait on orders. PJSM before all operations. Perform rig maintenance. Clean rig. DECOMP CBU. Monitor well. Shut in. DECOMP Wait on orders. PJSM before all operations. Perform rig maintenance. Clean rig. CBU at 10:00. DECOMP MU 7-5/8" Halliburton RTTS Storm Packer. Run RTTS in hole 37'. Set Storm packer. Test packer to 1000 psi. Release from storm packer. LD running tool. Shut well in. Release rig to maintenance at 15:00 hrs. DECOMP Pull wear bushing. Install test plug. Rig up test equipment. Fill BOP with fresh water and hydro test flow line and possum belly. check for leaks. DECOMP Pressure test BOPs to 250 psi low, 4000 psi high. Test with 7 5/8" and 4" test jts. Test witnessed by Wade Frame, BP WSL and Biff Perry Nabors toolpusher. AOGCC representative John Crisp waived AOGCC presence during the test. DECOMP Rig down test equipment and blow down choke manifold. Pull Printed: 9/18/2006 11:08:13 AM ~1 n BP EXPLORATION Page 3 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours Task Code ~ NPT Phase ' Description of Operations 8/16/2006 21:30 - 22:30 1.00 BOPSU P DECOMP test plug. Install wear bushing. 22:30 - 00:00 1.50 DHB P DECOMP Wash down to top of Halliburton 7 5/8" storm packer at 1 bpm 52 psi. Screw into storm packer with 22 right hand turns. Check for pressure. Pull storm packer to rig floor. Up weight. 70k. Brine wt. In 9.8 ppg, Out 9.8 ppg. 8/17/2006 00:00 - 00:30 0.50 DHB P DECOMP Make service breaks on halliburtons 7 5/8" storm packer and lay down. 00:30 - 02:00 1.50 FISH P DECOMP Pull out of the hole with 4" HT-40 drill pipe. 02:00 - 02:30 0.50 FISH P DECOMP Make up BHA #1 consisting of 5 1/2" Baker multi string cutter, 6 3/4" stabilizer, float sub and cross over. Function BOP. 02:30 - 03:30 1.00 FISH P DECOMP Run in the hole to 2210'. 03:30 - 04:30 1.00 FISH P DECOMP Attempt to circulate down drill pipe, pressuring up to 1000 psi after pumping 15 bbl of 9.8 ppg brine. 04:30 - 05:30 1.00 FISH N HMAN DECOMP Pull out of the hole to Bakers casing cutter. Break string cutter and found that a 1/2" function testing ball had been left in string cutter. 05:30 - 06:30 1.00 FISH N HMAN DECOMP Run in the hole with Bakers 5 1/2" multi string cutter to 2290'. Break circulation and attempt to locate casing collars at 2294', 2332' and 2370'. Brine temp pior to bttm. up 58 deg. 06:30 - 07:30 1.00 FISH P DECOMP Cut casing at 2380'. Up weight 55k, SO weight 55k. ROT weight 60k, TO 1 k pumps off, 1.5k pumps on after knives opened, 150 gpm at 500 psi. Staging pumps up to 600 gpm 1430 psi. 07:30 - 08:30 1.00 FISH P DECOMP Rig up to take returns from OA thru casing cut. Confrim ability to circulate pumping 5 bbls of 9.8 ppg brine at 3 bpm 450 psi. 08:30 - 10:30 2.00 FISH P DECOMP Pressure test Hot Oil lines to 3000 psi. Displace 9.8 ppg brine out of well bore with 95 bbls of 160 deg diesel at 5 bpm 1300 psi. Shut down close hydril and displace dead crude/antic pack thru casing cut taking retums out the 7 5/8 x 10 3/4 annulus out to the cutting tank with 95 bbls of 120 deg diesel at 2 bpm 450 psi. 10:30 - 12:00 1.50 FISH P DECOMP Shut in IA and OA. Allow heated diesel to soak. 12:00 - 13:00 1.00 FISH P DECOMP Circulate diesel 74 bbls 7 bbl/min 950 psi from backside up OA 7 5/8" x 10 3/4" taking returns to cuttings tank. Swap over and pump 50 bbl Safe Surf-O sweep down drill pipe up the OA taking returns to cuttings tank until clean brine returns were observered. 13:00 - 14:00 1.00 FISH P DECOMP Rig up and test Casing cut at 2380' to top of cement in 7 5/8" x 10 3/4 " to 2000 psi for 10 min. Good test. Rig down test equipment 14:00 - 14:30 0.50 FISH P DECOMP Pump 50 bbl Safe Surf-O sweep followed by clean 9.8 ppg brine water surface to surface at 6 1/2 bpm 1650 psi. Brine wt. In 9.8 ppg. Out 9.8 ppg. 14:30 - 16:00 1.50 FISH P DECOMP Pull out of the hole from 2380'. Lay down Bakers multi string cutter and stabilizer. 16:00 - 17:00 1.00 BOPSU P DECOMP Pull wear bushing. rig up and pull 7 5/8" packoff with 30k overpull. 17:00.- 18:30 1.50 FISH P DECOMP Pick up BHA #2 consisting of 3 1/2" bull nose, 7 5/8" spear pack off, spear grapple, spear grapple, spear extension, stop sub, and 2 cross ovens. Engauge 7 5/8" casing and confrim engaugement. Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Operations Summary Report Page 4 of 20 Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16h 992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT 8/17/2006 18:30 - 20:00 1.50 BOPSU P 20:00 - 22:00 2.00 BOPSU P 22:00 - 00:00 8/18/2006 ~ 00:00 - 01:00 01:00 - 04:00 04:00 - 05:00 2.00 BOPSU P 1.00 FISH P 3.00 FISH P 1.00 FISH P 05:00 - 05:30 0.50 FISH P 05:30 - 07:00 1.50 FISH P 07:00 - 08:30 I 1.501 FISH I P 08:30 - 09:30 I 1.00 FISH ~ P 09:30 - 14:30 5.00 FISH P 14:30 - 15:00 0.50 FISH P 15:00 - 17:00 2.00 FISH P 17:00 - 18:30 1.50 FISH P 18:30 - 21:00 2.50 FISH P 21:00 - 23:30 2.50 FISH P 23:30 - 00:00 I 0.501 FISH I P 8/19/2006 100:00 - 06:00 6.00 FISH I P 06:00 - 18:00 I 12.001 FISH I P Phase ~ Description of Operations DECOMP Nipple down BOP. Splitting at casing spool. Lift BOP to exspose 7 5/8" casing. DECOMP Pull 7 5/8" free with 25k overpull. Pulled 7 5/8" casing high enough to expose the 7 5/8" emergency slips and false bowl. Verify no hydrocarbons present prior to welding emergency slips to 7 5/8" casing and false bowl to 7 5/8" emergency slips. Attempt to pull 7 5/8" emergency slips and false bowl thru tubing spool, encountering a slight over pull at the base of the tubing spool. Discuss options with FMC rep and it was decided upon to cut /split false bowl and emergency slips from 7 5/8" casing. Rig up casing equipment out of the critical path. Note: No damage to tubing spool. DECOMP Nipple up Casing spool and test casing spool to 2000 psi for 10 minutes. DECOMP Pull 7 5/8" casing to rig floor. Release spear from 7 5/8" casing. Make service breaks and lay down spear assembly. DECOMP lay down 7 5/8" 29.7# L-80 BTC Casing. Recovered 59 full joints and 2 cut joints, 30.28' and 5.58'. DECOMP Rig down casing equipment. Clean rig floor. Clear floor of unnessary equipment. Install wear bushing. DECOMP Pick up BHA #3. Consisting of 5 1/2" multi wring cutter, 6 3/4" stabilizer, float sub and cross over. DECOMP Run in the hole with multi string cutter on 4" HT-40 drill pipe to 3225'. Up wt. 70k. SO wt. 65k DECOMP Cut casing at 3225'. Up weight 70k, SO weight 65k. ROT weight 60k, TO 1 k pumps off, 2k tq pumps on after knives opened, 150 gpm at 500 psi. Staging pumps up to 400 gpm 800 psi. Confrim cut complete by 300 psi loss. DECOMP Displace 9.8 ppg brine from well bore with 9.6 ppg LSND milting fluid. Monitor well. Pump dry job. Mud wt In 9.6 ppg. Out 9.6 ppg. Monitor well bore for 10 minutes. DECOMP Pull out of the hole laying down 4" HT-40 drill pipe. DECOMP Clean rig floor. DECOMP Pick up 30 joints 5" drill pipe from pipe shed and stand back in derrick. DECOMP Change out 4" HT-40 saver sub on top drive to 4 1/2" IF. Change out dies in grabber and lower pipe guide. Adjust travel for back up wrench on top drive. DECOMP Pick up BHA #4 consisting of a 9 x 6 3/4" pilot mill, bit sub, (9) 6 1/4" drill collars, cross over, jar.= 295' DECOMP Run in the hole with BHA #4 picking up 66 joints of 5" drill pipe from pipe shed to 2376'. DECOMP Obtain milling paramenters. UP wt 85k. SO wt 75k. Rot wt. 80k. Tq off 3k. 405 gpm 350 psi. Tag 7 5/8" casing stub at 2380'. Commence milling operations from 2380' to 2380.5' with 1 to 3k WOM to mantain an ROP of 5' an hr. Tq on 3 to 4k. DECOMP Milling 7 5/8" casing from 2380.5' to 2425' with 15 to 20k WOM. 100 RPM. Tq on 4 to 7.5k. Tq off 3.5k. 600 gpm 620 psi. UP wt. 85k. SO wt. 75k. ROT wt. 80k. Pumping 5 bbl fiber sweeps every 5' milled. 5 percent increase in cuttings. DECOMP Milling 7 5/8" casing from 2425' to 2450' with 15 to 20k WOM. Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page 5 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours ~ Task Code NPT Phase ' Description of Operations 8/19/2006 06:00 - 18:00 12.00 FISH P DECOMP 18:00 - 19:00 1.00 FISH N DPRB DECOMP 19:00 - 20:00 1.00 FISH N DPRB DECOMP 20:00 - 21:00 1.00 FISH N DPRB DECOMP 21:00 - 22:00 1.00 FISH N DPRB DECOMP 22:00 - 23:00 1.00 FISH N DPRB DECOMP 23:00 - 00:00 1.00 FISH N DPRB DECOMP 8/20/2006 00:00 - 00:30 0.50 FISH N DPRB DECOMP 00:30 - 04:00 3.50 FISH N DPRB DECOMP 04:00 - 06:00 2.00 FISH N DPRB DECOMP 100 RPM. Tq on 4 to 7.5k. Tq off 3.5k. 600 gpm 620 psi. UP wt. 85k. SO wt. 75k. ROT wt. 80k. Back reaming every 30' of 7 5/8" casing milled to enhance hole cleaning. While milling 7 5/8" casing at 2450' a increase of 90 psi was observed. Picked up off 7 5/8" casing stub encountering a 15k over pull and rotation was lost. Work milling assy. from 2441' to 2443' with unrestricted flow rate. Unable to gain rotation. Trap tq in drill string and continue to work drill string from 2441' to 2443'. Rotation of milling assy. was regained. 80 RPM 4k Tq. Continue to rotate at 2443' attempting to clean obstruction from BHA. Large amounts of cement chunks and clay with a small amount of metal were observered at shale shakers. At a depth of 2430' pipe rotation was lost due to torque. Once again trap torque in drill string. Working pipe to 100k and down to 75k with limited movement. Work drill string to 2420' with torque still trapped in drill string when jars fired, rotation was immediately regained. Circulate and reciprocate pipe. UP wt. 85k. SO wt. 75k. ROT wt. 80k. 100 RPM Tq off 3k. At bottoms up observed cement chunks and clay. Mud wt. In 9.6 ppg. Out 9.6 ppg. Monitor well bore. Pull out of the hole to BHA #4. Lay down jars, stand back drill collars. Inspection of mill /metal muncher found 4 of the 8 milling blades busted off and clay with small amounts of metal in between the remainig blades. Break and lay down mill. Pilot mill found to be full gauge at 6 3/4". Make up new 6 3/4" x 9" mill and run in the hole with drill collars from the derrick, pick up jars. Run in the hole with BHA #5 to 2418'. Pump 10 bbl fiber sweep around at 2418' while rotating and reciprocate pipe. Up wt. 85k, So wt. 75k, Rot wt. 80k, 600 gpm 570 psi. No increase in metal or cement chunks once fiber sweep came back to surface. Begin washing /milling to bottom at 2418'. Up wt. 85k, So 75k, Rot wt 80k, Tq off 3k with 70 Rpm, 600 gpm 570 psi. At 2420' drill string stalled out with 0 WOM and 3.5k Tq. Pick up and ensure string free and begin to mill from 2418' to 2442'. Unable to mantain any weight on mill with out stalling out drill string. Mill with rotatary torque not exceeding 4k to maintain pipe rotation. From 2442' to 2450' rotatary torque fell off to 3k no obstructions or problems getting back to the top of 7 5/8" casing stub at 2450'. After tagging 7 5/8" casing stub picked up to depth of 2410' to ensure that BHA clear of any obstructions. Milling 7 5/8" casing from 2450' to 2461' with 0 WOM. 90 RPM. Tq on 4 to 9k. Tq off 3.5k. 600 gpm 620 psi. UP wt. 85k. SO wt. 75k. ROT wt. 80k. Milling ROP increased to 60' hr from 2450' to 2461' with no weight on mill. While milling cuttings were monitored closely. Getting back a very small amount of metal and clay balls. ROP and Cutting returns at shale shakers indicate that a side Printed: 9/18/2006 11:08:13 AM BP EXPLORATfON Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Event Name: REENTER+COMPLETE Start: 8/4/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date s/2o/2oos From - To Hours ~ Task ~ Code NPT ~ Phase i 04:00 - 06:00 2.00 FISH N 06:00 - 08:00 2.00 FISH N 08:00 - 09:00 1.00 FISH N 09:00 - 10:00 I 1.00 I FISH i N 10:00 - 11:00 1.00 FISH N 11:00 - 11:30 0.50 FISH N 11:30 - 12:00 0.50 FISH N 12:00 - 13:00 1.00 BOPSU P 13:00 - 14:30 1.50 BOPSU P 14:30 - 15:00 I 0.50 I BOPSUFt P 15:00 - 21:30 I 6.50 I BOPSUFI N 21:30 - 22:30 I 1.00 I BOPSUR P 22:30 - 23:00 0.50 BOPSUF~ P 23:00 - 00:00 1.00 CLEAN N 8/21/2006 100:00 - 01:30 1.501 CLEAN N 01:30 - 02:00 0.50 CLEAN N 02:00 - 03:00 1.00 CLEAN N 03:00 - 10:30 I 7.501 CLEAN I N 10:30 - 11:00 0.50 CLEAN N 11:00 - 12:30 1.50 CLEAN N 12:30 - 13:30 1.00 CLEAN N 13:30 - 14:00 I 0.501 CLEAN I N Page 6 of 20 Spud Date: 3/16/1992 End: 8/28/2006 Description of Operations DPRB DECOMP track in 10-3/4" casing has occured. DPRB DECOMP Pull out of the hole to 2410' and circulate. Conutine to monitor shale shakers for metal. No metal just clay balls. Consulat with Anchorage team as to opitions. DPRB DECOMP Monitor well bore for 10 minutes. Pump dry job. Pull out of the hole from 2410' to 1717'. DPRB DECOMP Rig up and perfrom LOT to EMW of 11.8 ppg. 255 psi. Rig down test equipment. DPRB DECOMP Pull out of the hole from 1717' to 295'. DPRB DECOMP Lay down jars. Stand back drill collars in derrick. Break and lay down Bakers 6 3/4 x 9" mill. Inspection of mill found 1 1/2 milling blades broke off. DPRB DECOMP Clean and clear rig floor. DECOMP Pull wear bushing. Flush BOP. Function BOP. Install test plug. DECOMP Remove 7 5/8" rams from top pipe rams and install 3 1/2" x 6" variable rams. DECOMP Rig up test equipment and test Hydril and top pipe rams door seals to 250 low, 3500 psi high. Test top pipe rams with 5" test joint to 250 psi low 4000 psi high. Remove 5" test joint. WAIT DECOMP Mobilize 3 1/2" test joint. Service top drive. Load pipe shed with 3 1/2" NSCT work string. Strap and rabbit the same. Rig up 3 1/2" casing equipment. DECOMP Test bottom pipe rams with 3 1/2" test joint to 250 psi low 4000 psi high. DECOMP Rig down test equipment. Pull test plug. Install wear bushing. DPRB DECOMP Pick up 3 1/2" NSCT tubing (work string) first joint bent +- 2 deg. DPRB DECOMP Continue to pick up 3 1/2" work string to 931'. Make up torque 3000 fpds. DPRB DECOMP Rig down casing equipment. DPRB DECOMP Run in the hole with 5" drill pipe to 2410'. Up wt. 60k, So wt. 60k. DPRB DECOMP Attempt to entry 7 5/8 casing. Working drill string multiple times from 2410' to 2469'. Turning drill string 1/4 turn each time tagging up at 2469' with 5k down wt. Pick up to above 2380' where milling of 7 5/8' began. Working drill string 1/4 to a full turn. Attempts to entry 7 5/8" casing unsuccessful with pumps on 378 gpm 445 psi. and pumps off. Continue to work drill string attempting to enter 7 5/8" casing while consulting with Anchorage team. At the depth of 2464' at 3k down wt. was encountered, setting another 1 k down wt. weight fell off continuing in the hole past 2469'. Run in the hole, tagging up on EZSV at 3275'. DPRB DECOMP Rig up head pin and hoses for cement job. DPRB DECOMP Circulate and condition 548 bbls. 9.6 ppg LSND mud at 252 gpm 500 psi. Mud Wight In 9.6 ppg. Out 9.6 ppg. DPRB DECOMP Pressure test Schlumberger lines to 4000 psi. Pump 7 bbl fresh water followed by 34 bbls of 15.8 ppg cement, followed by 3 bbl fresh water. Displace with rig pumping 37.2 bbl 9.6 ppg LSND mud at 6 bbp 410 psi. Balance plug to cover from 3275' to 2475' in 7 5/8" casing. DPRB DECOMP Pull out of the hole slowly placing tail of 3 1/2" work string at 2540. Drop drill pipe wiper dart and pump down. Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page 7 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3h 6/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date 8/21 /2006 8/22/2006 From - To 14:00 - 15:00 15:00 - 16:00 1.00 CLEAN N 16:00 - 20:00 4.00 CLEAN N 20:00 - 22:00 ~ 2.00 ~ CLEAN ~ N 22:00 - 00:00 2.00 CLEAN N 00:00 - 01:30 1.50 CLEAN N 01:30 - 04:00 2.50 CLEAN N Description of Operations TOW at 2427 - BOW at 2445' 04:00 - 05:30 1.50 CLEAN N DPRB DECOMP Pull out of the hole to 252'. 05:30 - 08:00 2.50 CLEAN N DPRB DECOMP Lay down 6 1/4" drill collars and BHA #6. Note: Pilot Mill showed no wear and minimal wear to leading edge of string mill. Both mills in gauge. 08:00 - 08:30 0.50 CLEAN N DPRB DECOMP Clean and clear floor. 08:30 - 12:00 3.50 CLEAN P DECOMP Pick up BHA #7 consisting of Hughes MX-1 9 7/8" bit, 8" 1.15 PDM, Float sub, NM Cross over, ARC, MWD, NM Cross over, NM Stab, 2 NM Spiral Drill Collars, NM Stab, NM Spiral Drill Collar, Float sub, Hyd Jar, 20 joints 5" HWDP, Ghost Reamer = 920'. 12:00 - 15:00 3.00 CLEAN P DECOMP Run in the hole with BHA #7 picking up 5" drill pipe from pipe shed to 2434. Orient motor to low side and slide thru window. 15:00 - 00:00 9.00 DRILL P INT1 Drill 9 7/8" directional hole f/ 2475' to 3286' w/ 1.15 deg. PDM motor assy. Up wt. 115k, So wt. 85k, Rot. wt 95k, 540 gpm, 1140 psi off, 1260 psi on, tq. off 4k, tq. on 5k, 80 rpm. WOB 12 to 35k. Displace well bore out with new 9.6 ppg LSND while drilling. Encountered hydrates from 2650' to 2840' and from 2909' to 3286'. Hours I Task ! Code I NPT I Phase 1.001 CLEAN I N DPRB DECOMP Circulate bottoms up at 340 gpm 350 psi. At bottoms up approx 1 bbl of contaminated mud was dumped. DPRB DECOMP Pull out of the hole from 2540' to 932'. DPRB DECOMP Rig 3 1/2" casing equipment and lay down 30 joints of 3 1/2" NSCT tubing. (work string) Recover drill pipe wiper dart in plug catcher. Rig down casing equipment. Clean and clear floor. DPRB DECOMP Pick up BHA #6 consisiting of, 8 1/2"Starter Mill, 9 7/8" String Mill, Bit sub, Cross over, 1 joint of 5" HWDP, Jar, Cross over, (6) 6 1/4" Drill collars, Cross over, Cross over, 7" Boot basket, 6 5/8" Boot basket, Cross over, Cross over = 252'. Function blind rams. DPRB DECOMP Run in the hole with BHA #7 picking up 5" drill pipe from pipe shed. ` -" DPRB DECOMP Run in the hole with BHA #6 picking up 5" drill pipe from pipe shed to 2429. Obtain parameters. Up wt. 80k, So wt 70k, Rot wt. 75k, Tq off 3.5k, 100 Rpm, 432 gpm 525 psi. DPRB DECOMP Tag 7 5/8" 2420' commence milling /cleaning up window area. Taking 1 k weight at 2427', Torque increases to 4.5k and fell off to 3.5k after a depth of 2430'. Torque increased to 4.5k at 2445' and fell off to 3.5k after passing 2445'. Continue to 2469' with out any problems. Drill 6' of new hole from 2469' to 2475'. Confirming well is side track thru the 7 5/8" x 10 3/4" casing by milling ROP of 170' ph and a differential pressure increase of 125 psi, WOB 10k. Pick up and back ream area from 2445' to 2427'. Working area with pumps on and off with no problems. Pump a fiber sweep around while working window area. Sweep only brought back clay No metal. Continue to circulate bottoms up. Monitor well bore. Pump dry job. ECDs calc. 9.99 ppg, ECDs actual 10.33 ppg. MW In 9.7 ppg. Out 9.7 ppg. Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page 8 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/22/2006 15:00 - 00:00 9.00 DRILL P INT1 ART = 2.00 Hrs. AST = 3.27 Hrs. ADT = 5.27 Hrs. Jar Hrs = 101.37 hrs. 8/23/2006 00:00 - 12:00 12.00 DRILL P INTi Drill 9 7/8" directional hole f/ 3286' to 4611' w/ 1.15 deg. PDM motor assy. Up wt. 135k, So wt. 90k, Rot. wt 105k, 636 gpm, 1539 psi off, 1581 psi on, tq. off 8k, tq. on 8 to 9k, 100 rpm. WOB 10 to 20k. ECDs calc. 10.7 ppg, ECDs actual 10.14 ppg. MW In 9.6 ppg. Out 9.6 ppg. ART = 5.02 hrs AST = 2.95 hrs ADT = 13.20hrs Jars = 109.3 hrs 12:00 - 22:00 10.00 DRILL P INT1 Drill 9 7/8" directional hole f/ 4611' to 5749' w/ 1.15 deg. PDM motor assy. Up wt. 155k, So wt. 90k, Rot. wt 105k, 636 gpm, 1610 psi off, 1750 psi on, tq. off 9k, tq. 10k, 100 rpm. WOB 10 to 20k. ECDs calc. 10.59 ppg, ECDs actual 10.07 ppg. MW In 9.6 ppg. Out 9.6 ppg. ART = 5.02 hrs AST = 2.95 hrs ADT = 13.20hrs Jars = 109.3 hrs Top of Ugnu Sands 5511' MD 22:00 - 23:00 1.00 DRILL P INT1 Circulate bottoms up at 631 gpm 1760 psi. 100 rpm 10k tq. Monitor wellbore for 10 minutes. 23:00 - 00:00 1.00 DRILL P INT1 Pull out of the hole from 5749' to 5084'. Well began to swab and a 20k over pull was encountered at 5720'. Screw into top drive and pump out of the hole. 269 gpm 420 psi. up wt. 155k, So wt. 90k. Mud wt In 9.6 ppg. Out 9.6 ppg. 8/24/2006 00:00 - 08:00 8.00 DRILL P INT1 Continue pumping out of the hole from 5084' to 4689' 269 gpm 420 psi. Hole quite swabbing and began taking correct amout of fill at 4689'. At a bit depth of 3383' (Ghost Reamer Depth 2464') encountered a 10k overpull. Screw in to top drive and pump at 270 gpm 450 psi. Weight fell off until reaching 3354' (Ghost Reamer depth 2434') Work NM Stabilizer thru the 10 3/4" window. Continue to pull out of the hole to 920'. Mad passing from 2480' to 2270'. 08:00 - 11:00 3.00 DRILL P INT1 Mointor well bore at the BHA for 15 minutes. Hydraites breaking out fluid level in well bore remaining constant. Stand back 5" HWDP and Jar, NM sprail drill collars. Lay down NM stab, NM cross over, MWD, ARC, NM cross over, float sub, 1.15 deg. PDM and bit. 11:00 - 11:30 0.50 DRILL P INT1 Clear rig floor of unnessary tools. 11:30 - 12:00 0.50 BOPSU P INT1 Observe well for 10 minutes, no hydrates, well dead. Pull wear bushing 12:00 - 12:30 0.50 DRILL P INT1 Clean rig floor. 12:30 - 13:30 1.00 BOPSU P INT1 Install test plug. Rig up test equipment. 13:30 - 17:00 3.50 BOPSU P INT1 Pressure test BOPS to 250 psi low, 4000 psi high. Test with 5" test jt. Test witnessed by Duncan Ferguson, Wade Frame, BP WSL and Cris Weaver, Lenward Toussant Nabors toolpushers and AOGCC representative Chuck Scheve. 2 7/8" x 3 1/2" rams failed to test. 17:00 - 19:30 2.50 BOPSU P INT1 Remove 2 7/8" x 3 1/2" Variable rams and Install 5" hard body rams. Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page 9 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 7ES Date From - To Hours Task ~ Code NPT 8/24/2006 19:30 - 20:00 0.50 BOPSUF±;P 20:00 - 20:30 0.50 BOPSU~} P 20:30 - 22:00 I 1.501 DRILL (N I DPRB I INT1 22:00 - 00:00 2.00 DRILL N DPRB INT1 8/25/2006 100:00 - 01:30 I 1.501 DRILL I N I DPRB I INT1 01:30 - 02:00 0.501 DRILL N DPRB INT1 02:00 - 03:00 I 1.001 DRILL I N I DPRB I INT1 03:00 - 04:00 I 1.001 DRILL I N I DPRB I INT1 04:00 - 04:30 0.50 DRILL N DPRB INT1 04:30 - 08:30 4.00 DRILL P INT1 Spud Date: 3/16/1992 Start: 8/4/2006 End: 8/28/2006 Rig Release: 9/13/2006 Rig Number: Phase Description of Operations Test 5" pipe rams to 250 psi low 4000 psi high. Rig down test equipment. Remove test plug and install wear bushing. Pick up BHA #8 consisting of a 6 1/2" bull nose, float sub, cross over, 6 1/4" steel drill collar, cross over, 9 7/8" watermellon mill, cross over, (2) 6 1/4" steel drill collars, cross over, jar, (20) 5" HWDP = 737' Run in the hole with BHA #8 to 2442' (bull nose depth) 2404' watermellon mill depth. Establish milling parmeters. Up wt. 90k, So 80k, Rot 85k, Tq off 3.5k, 550 gmp 580 psi. Tagging up at 2414. Begin cleaning window area up from 2414' to 2453'. Pump fiber sweep around at 550 gpm 580 psi. Sweep brought back to surface a hand full of metal shavings. Monitor well bore for 10 minutes. Hydrates breaking out. Pump dry job. Pull out of the hole to 736'. Stand back HWDP and jar in the derrick. Lay down cross over, (2) 6 1/4" steel drill collars, cross over, 9 7/8" watermellon mill, cross over, (1) 6 1/4" steel drill collar, cross over, float sub, bull nose. INT1 INT1 08:30 - 11:00 2.50 DRILL P INTi 11:00 - 21:00 10.00 DRILL P INTi 21:00 - 22:00 1.001 DRILL P INT1 22:00 - 00:00 2.001 DRILL P I INT1 Note: 9 7/8" Watermellon 1/8" out of gauge. Clean and clear rig floor. Pick up BHA #9 consisting of a 9 7/8" Hycalog RSX619S-A7 bit, Schlumberger rotary steerable, Float sub, Rec sub, (1) NM flex drill collar, ARC, MWD, ADN, (2) NM spiral drill collars, NM stab, (1) NM spiral drill collar, Float sub, Jar, 5 stands 5" HWDP, Ghost reamer, (1) joint 5" dp to 957'. Cut and slip 82' of drilling line. Service top drive. Run in the hole with BHA #9 picking up drill pipe from shed from 957' to 5749'. Work BHA thru window area at 2443' and at 2650'. Taking 20k down wt. at 4370'. Wash and Ream past tight area trom 4360' to 4370'. 40 rpm, 271 gpm 880 psi. Wash from 5669' to 5749' as a precautionary measure. 600 gpm 2000 psi. Down link Schlumberger rotary steerable. Drill 9 7/8" directional hole f/ 5739' to 5855' w/ Schlumberger rotary steerable. Up wt. 160k, So wt. 90k, Rot. wt 100k, 630 gpm, 1730 psi off, 1920 psi on, Tq. off 10k, Tq. on 9k, 130 RPM. WOB 15 to 30k. ECDs calc. 10.59 ppg, ECDs actual 10.07 ppg. MW In 9.7 PP9. Out 9.7 ppg. ART = .73 Hrs ADT = .73 Hrs. Jar Hrs = 116.33 hrs. 8/26/2006 00:00 - 02:00 2.00 DRILL P INT1 Drill 9 7/8" directional hole f/ 5855' to 6045' w/ Schlumberger rotary steerable. Up wt. 160k, So wt. 90k, Rot. wt 110k, 610 gpm, 1930 psi off, 1950 psi on, Tq. off 12k, Tq. on 13.5k, 125RPM. WOB 5 to 10k. ART = 1.79 Hrs ADT = 1.79. Hrs. Jar Hrs = 117.39 hrs. ECDs calc. 10.51 ppg, ECDs actual 10.31 ppg. MW In 9.7 PPg• Out 9.7 ppg. 02:00 - 03:30 1.50 DRILL N DFAL INTi Trouble shoot Schlumberger rotary steerable, Assy buliding Printed: 9/16/2006 11:08:13 AM BP EXPLORATION Page 10 of 20 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: Z ell Name: Z e: Name: From - To -19 -19 REENTE NABOBS NABOBS Hours R+COM ALASK 7ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase j Spud Date: 3/16/1992 : 8/4/2006 End: 8/28/2006 Release: 9/13/2006 Number: Description of Operations 8/26/2006 02:00 - 03:30 1.50 DRILL N DFAL INT1 angle to 65 deg. while rotating instead of holding an inclination of 61 deg. Circulate bottoms up. Monitor well bore. Hydrates nonexistence. Wellbore static. Pump dry job. Mud wt. In 9.7 ppg. Out 9.7 ppg. 03:30 - 08:30 5.00 DRILL N DFAL INTi Pull out of the hole from 6045' to 824'. Lay down ghost reamers. Ghost reamers passed thru window area with out any difficulty. Work BHA /stabilizers thru window area. Requiring rotation of 5 RPM and 5 to 10K over pull to work thru window area at 2463'. Monitor well bore at BHA hydrates breaking out. 08:30 - 12:00 3.50 DRILL N DFAL INT1 Stand back 5" HWDP, jar, NM flex drill collars. Pre job safety meeting with Schlumberger on proper source removal. Remove source from ADN. Pump thur RSS tool at 188 gpm 940 psi and verify that RSS was out of sync. Believe to be a soft ware malfunction causing failure. Lay down Schlumberger BSS. 12:00 - 15:30 3.50 DRILL N DFAL INT1 Pick up BHA #10 consisting of a RR #4- 9 7/8" Hycalog RSX619S-A7 bit, Schlumberger rotary steerable. Down load MWD. Pre job safety melting with Schlumberger on proper installation of source. Install source in ADN. RIH with NM flex drillar collars and HWDP from derrick to 824'. Shallow pulse test MW D at 280'. Good test. 15:30 - 20:30 5.00 DRILL N DFAL INTi Run in the hole from 824' to 5950'. Placing ghost reamers at 919' and 3204'. Work BHA thru window, Rotate /Rock BHA 1/4 turn thru tight areas taking 5 to 15k down wt. from 2414' to 2650' 20:30 - 21:30 1.00 DRILL N DFAL INT1 Wash from 5950' to 6045' as a precautionary measure. 600 gpm 2000 psi. Down link Schlumberger rotary steerable. No fill on bottom. Obtain SPRs. 21:30 - 00:00 2.50 DRILL P INT1 Drill 9 7/8" directional hole f/ 6045' to 6425' w/ Schlumberger rotary steerable. Up wt. 160k, So wt. 90k, Rot. wt 115k, 625 gpm, 1965 psi off, 1979 psi on, Tq. off 11 k, Tq. on 12k, 130RPM. WOB 5 to 30k. ART = 1.56 Hrs ADT = 1.56 Hrs. Jar Hrs = 118.9 hrs. ECDs calc. 10.05 ppg, ECDs actual 10.03 ppg. MW In 9.7 PPg• Out 9.7 PPg• 8/27/2006 00:00 - 12:00 12.00 DRILL P INT1 Drill 9 7/8" directional hole f/ 6425' to 7751' w/ Schlumberger rotary steerable. Up wt. 175k, So wt. 110k, Rot. wt 130k, 622 gpm, 1937 psi off, 1955 psi on, 130 RPM Tq. off 13.5k, Tq. on 16.5k. WOB 25k. Diluted system with 580 bbls of new LSND mud to lower MBTs and low gravity solids. MBT's dropped from 15.5 to 8 ppb ART = 7.92 Hrs ADT = 7.92 Hrs. Jar Hrs = 125.33 Hrs. ECDs calc. 10.50 ppg, ECDs actual 10.59 ppg. MW In 9.7 ppg. Out 9.7 ppg. 12:00 - 00:00 12.00 DRILL P INT1 Drill 9 7/8" directional hole f/ 7751' to 9358' w/ Schlumberger rotary steerable. While crossing fault at 9089' a 15 bbl mud loss was observed, drilling was stopped and wellbore was monitored and wellbore static. Resume drilling. While drilling at 9293' partial returns were lost, wellbore took 60 bbls, drilling was stopped and wellbore monitored. While monitoring at 9293 well slowly flowed back with hydrates breaking out. Well static. Resume drilling. Up wt. 200k, So wt. 120k, Rot. wt 140k, 622 Printed: 9/18/2006 11:08:13 AM BP EXPLORATION PagE 11 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/27/2006 12:00 - 00:00 12.00 DRILL P INT1 gpm, 2339 psi off, 2350 psi on, 130 RPM Tq. off 14k, Tq. on 15k. WOB 15 to 25k. 8/28/2006 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 8/29/2006 100:00 - 12:00 I 12.001 DRILL I P ART = 7.93 Hrs ADT = 14.79 Hrs. Jar Hrs = 132.32 Hrs. ECDs calc. 10.85 ppg, ECDs actual 10.30 ppg. MW In 9.8 PPg• Out 9.8 PPg• INT1 Drill 9 7/8" directional hole f/ 9358' to 10,209' w/ Schlumberger rotary steerable. Up wt. 230k, So wt. 125k, Rot. wt 150k, 625 gpm, 2471 psi off, 2481 psi on, 130 RPM Tq. off 15k, Tq. on 18 to 20k. WOB 15 to 25k. Added 580 bbl of 10.2 ppg spike fluid to mud system at 9800'. Monitor wellbore for flow back on each connection /Hydrates breaking out. ART = 6.27 Hrs ADT = 21.06 Hrs. Jar Hrs = 138.50 Hrs. ECDs calc. 10.72 ppg, ECDs actual 11.26 ppg. MW In 10.2 ppg. Out 10.2 ppg. Held an unannounced BOP drll (flow show) INT1 Drill 9 7/8" directional hole f/ 10209' to 11253' w/ Schlumberger rotary steerable. Up wt. 280k, So wt. 140k, Rot. wt 180k, 572 gpm, 2435 psi off, 2442 psi on, 130 RPM Tq. off 21 k, Tq. on 22k. W OB 25k. Mixed and pumped a 20 bbl 25 Ib/bbl nut plug fine sweep with one drum of tube 776. Sweep did not aid in lowering rotary toqure. ART = 7.93 Hrs ADT = 28.99 Hrs. Jar Hrs = 144.95 Hrs. ECDs calc. 10.72 ppg, ECDs actual 11.11 ppg. MW In 10.2 ppg. Out 10.2 ppg. Held an anannounced BOP drill (pit gain) Monitor wellbore for flow back on each connection. No hydrates. INT1 Drill 9 7/8" directional hole f/ 11253' to 12102' w/ Schlumberger rotary steerable. Up wt. 280k, So wt. 140k, Rot. wt 180k, 572 gpm, 2435 psi off, 2442 psi on, 130 RPM Tq, off 21k, Tq. on 22k. WOB 25k. Pump Hi-Vis sweep at 11909' w/minimal returns. ECDs calc. 10.72 ppg, ECDs actual 11.10 ppg. MW In 10.2 ppg. Out 10.2 ppg. Held an anannounced BOP drill (pit gain) Monitor wellbore for flow back on each connection. Hydrates breaking out. 12:00 - 15:30 3.50 DRILL P INT1 Drill 9-7/8" hole f/12102' to 12285'. 15:30 - 17:00 1.50 DRILL N RREP INT1 Stop drilling due to top drive torque limitation. Top drive traction motor overheating. Set stand back, circulate w/o rotation, 390 gpm, 1250 psi, 42% flow. Cool motor f/285 deg. to 132 deg. bearing temp f/150 deg to 96 deg. Oil 150 deg to 100 deg. 17:00 - 00:00 7.00 DRILL P INT1 Drill directional hole f/12285' to 12643' w/rotary steerable. See hydrates 2300 strokes after each connection. 572 gpm, 2427 psi on, 2403 psi off, 22-25K tq. on, 21 K tq. off, 95 rpm 320K Up wt., 160 SO wt., 205 rot. wt. MW in 10.2 ppg, MW out 10.2 Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page 12 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours ( Task ~ Code NPT ~ Phase ~ Description of Operations 8/29/2006 117:00 - 00:00 I 7.001 DRILL I P INT1 8/30/2006 00:00 - 01:00 1.00 DRILL P INT1 01:00 - 05:30 4.50 DRILL P INT1 05:30 - 08:00 2.50 DRILL P INT1 08:00 - 12:00 4.00 DRILL P INT1 12:00 - 15:30 I 3.501 DRILL I P I I INT1 15:30 - 16:30 1.00 DRILL P INT1 16:30 - 18:00 1.50 DRILL P INT1 18:00 - 19:00 1.00 DRILL P INT1 19:00 - 19:30 0.50 DRILL P INT1 19:30 - 22:00 2.50 DRILL P INT1 22:00 - 22:15 0.25 DRILL P INT1 22:15 - 00:00 1.75 DRILL P INT1 8/31/2006 00:00 - 04:30 4.50 DRILL P INT1 04:30 - 05:00 0.50 DRILL P INT1 05:00 - 05:45 0.75 DRILL P INT1 05:45 - 06:00 0.25 DRILL P INT1 06:00 - 21:00 15.00 DRILL P INT1 21:00 - 00:00 I 3.001 DRILL I P I I INT1 9/1/2006 00:00 - 01:00 1.00 DRILL P INT1 01:00 - 01:15 0.25 DRILL P INT1 01:15 - 01:45 0.50 DRILL P INTi 01:45 - 03:30 1.75 DRILL P INTi 03:30 - 04:30 1.00 DRILL P INTi PP9 10.7 calc. ECD, 10.95 act. ECD. ADT f/24 hrs. = 13.11 Circulate bottoms up for samples and per geos TD section in top of Sag River at 12643' MD/8692' TVD. POH pumping 245 gpm 680 psi. Begin short trip to 3445'. MW. 10.2 ppg in. MW out 10.2 ppg. Circulate bottoms up (/10874'. 588 gpm, 2484 psi., 98 rpm, tq. 18.5K. Bottoms up brought up sand and clay. POH f/10799' without pumping and well began swabbing. Continue to rotate and pump out of hole. Find tool jts. packed w/clay starting at 9925'. Check for swabbing every 5 stds. Rotate and pump out, 511 gpm, 1790 psi. See large hydrate bubbles at surface throughout trip. Check and still swabbing at 9169'. POH to 8981'. .Back ream f/8981' to 7365', 521 gpm 1766 psi, 85 rpm,. tq. 11 K. Monitor well. Hole not taking correct amount of fill. See constant flow of small gas bubbles. RIH to 10495' to point just below Kuparuk formation. Circulate one bottoms up. Reciprocate pipe. 521 gpm, 2033 psi, 79 rpm, 240K Up wt., 130 SO wt. RIH f/10495' to 12567'. Tight at 12567'. 30K over up and down weights. Ream f/12550' to 12643'. 521 gpm, 2343 psi, 85 rpm, 22-25K Tq. Circulate Hi-Vis sweep at 12643', 572 gpm, 2405 psi, 95 rpm, 22-25K Tq. Pump 6000 stks, set lstand back and continue to circulate another 20000 stks. Mud clean. Saw some clay and small amounts of shale come back w/sweep. Monitor well. Well flowing. Steady stream gas breaking out. Well giving up 1 bbl. fluid every 2 minutes. Circulate. Consult w/town engineer and weight up mud system f/ 10.3 ppg. to 10.6 ppg. Up wt. 330K, SO wt. 140K. Continue circulating and weight up system f/10.3 ppg to 10.6 PPg• Pull 1 stand. Monitor well. Well flowing. Circulate bottoms up. 130 gpm, 365 psi. Monitor well f/15 mins. Hydrates breaking out. Fluid level static. POH (/12567' to 6330'. Pump and rotate. 85 gpm, 300 psi. Monitor well every 5 stands. 10K drag f/6803' to 6330'. Attempt to pull w/out pumping and well swabs. Monitor well. No flow. POH pumping f/6330' to 5102'. 172 gpm, 345 psi, 30 rpm. Good quantities of hydrates breaking out. POH to 5174'. Pumping 245 gpm, 395 psi. Monitor well. Hydrates breaking out. Well flowing slightly. Circulate bottoms up at 5174'. 331. gpm, 540 psi. Shut down. Well static. POH to 3500'. Pumping 245 gpm, 375 psi. Circulate new 60 deg. 10.6 ppg. LSND mud from 3500' to surface for hydrate control. Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page ~ 3 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3h 6/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date 9/1/2006 9/2/2006 9/3/2006 From - To ~ Hours Task Code NPT ~ Phase 04:30 - 10:30 ~ 6.00 DRILL ~ P INT1 10:30 - 14:00 I 3.501 DRILL I P 14:00 - 15:30 I 1.501 DRILL I P 15:30 - 18:00 2.50 DRILL P 18:00 - 23:30 5.50 DRILL P 23:30 - 00:00 0.50 DRILL P 00:00 - 01:00 1.00 DRILL P 01:00 - 03:00 2.00 DRILL P 03:00 - 04:30 1.50 CASE P 04:30 - 06:00 1.50 CASE P 06:00 - 08:00 2.00 CASE P 08:00 - 09:30 1.50 CASE P 09:30 - 00:00 14.501 CASE P 00:00 - 00:30 0.50 CASE P 00:30 - 01:00 0.50 CASE P 01:00 - 06:30 5.50 CASE P 06:30 - 09:00 2.50 ~ CASE ~ P 09:00 - 09:30 ~ 0.50 ~ CASE ~ P 09:30 - 10:00 I 0.50 I CASE I P 10:00 - 14:00 I 4.00 I CASE I P INT1 INTi INTi INTi INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INTi INT1 INT1 INT1 INT1 Description of Operations POH w/5" drill pipe. Swabbing. Continue pumping out of hole (/3584' to BHA # 10 at 825'. 167 gpm, 200 psi, 30 rpm. Pulled 15K over at 2586'. Slacked back down and rotated 1/4 turn w/string and pulled ok. No swabbing after BHA up in 10-3/4" casing above 2463'. PJSM w/Schlumberger, all hands, WSL, toolpusher on nuke safety. Remove source. LD MW D and rotary steerable equipment. Geos and town evaluate logs. Clear rig floor. LD stabilizers and equipment. Service top drive. RIH w/3 drill collars, 21 jts. HWDP. POH and LD same. RIH w/mule shoe on 25 stds 5" drill pipe to 2337'. POH and LD same. RIH w/mule shoe on 2nd 25 stands of 5" drill pipe to 2337'. Continue to run second 25 stands of 5" drill pipe w/muleshoe in hole to 2337'. POH and lay down 5" drill pipe. Pull wear bushing. Change top rams to 7" and test to 250 psi low and 4000 psi high and record on chart. Cut and slip drilling line and inspect drawworks. RU 7" 26# L-80 BTC-M casing running equipment. PJSM w/WSL, all hands, tourpusher on casing running plan forward. PU shoe track consisting of Halliburton float shoe, 1 jt w/float collar in collar end, Halliburton bypass baffle on top of float collar, jt. #2 and jt. #3 with landing collar on pin. RIH and check floats. OK. PU Franks fillup tool. RIH w/7" 26# L-80 BTC-M casing to 7841'. Fill each jt. w/Franks tool and break circulation every 15 jts. circulating down 6 mins/jt. Casing taking weight with shoe at 170' and first 5 centralizers entering 10 3/4" casing. Set down 12,000 Ibs and pass obstruction. Run casing to 10 3/4" window fillling every joint. Circulate 1.5 casing volumes at window. Work shoe and first centralizers through window with some difficulty. Vary running speeds f/80'/min to 20'/min. to keep hole fill right. PU wt. 195K, SO wt. 100K at 7841'. Record PU/SO wts ea. 10 jts. Pipe RIH w/no difficulty. RIH w/ 7" 26# BTC-M L-80 casing f/7841' to 8200' RU torque turn equipment and prepare to x-over from 7" BTC-M to 7" 26# TC_II L-80 casing f/8200' to 12643'. RIH w/ 7" 26# TC-II L-80 casing f/8200' to 12616'. No problems or anomalies during trip to this point. Circulate casing down f/12616' to 12643'. Unable to reciprocate. Max. pull = 425K #. Circulate and condition mud per mud engineer. Had to work pipe to establish circulation. 3 bpm/360 psi , 4 bpm/445 psi, 5 bpm/650 psi, 6 bpm/700 psi. RU Schlumberger cementing trucks. RU cementing head and circulating lines. WSL witnessed plug loading. LD Franks tool. INTi Circulate. PJSM w/WSL, toolpusher, Schlumberger, mud engineer, all hands. INT1 Blow down cement lines w/air. Pump 5 bbls. H2O thru washup Tee (no water down hole). Pressure test to 4000 psi. OK. Pump mud push to rig floor to TEE to clear water f/lines. Pump Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Event Name: REENTER+COMPLETE Start: 8/4/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date 9/3/2006 9/4/2006 From - To I Hours I. Task !Code ( NPT I Phase 10:00 - 14:00 I 4.001 CASE I P Page 14 of 20 Spud Date: 3/16/1992 End: 8/28/2006 Description of Operations INT1 100.9 bbls of 11.0 ppg. Mudpush ~ 6 bpm. 588 psi. Drop bottom plug. Pump lead slurry. 121.67 bbls. of 12.3 ppg LiteCrete at 5.4 bpm, 450 psi. Mix and pump tail slurry. 156.84 bbls. Premium G cement w/Gasblok 15.8 ppg at 5.7 bpm, 330 psi. Drop top plug. Pump 1st 5 bbls displacement H2O w/Dowel) to clear lines and switch to rig pumps and displace w/476 bbls. of 10.6 ppg LSND mud f/pits. Slow to 2 bbls/min. Plug bumped at calculated 6820 strokes. FCP = 1255 psi. Pressure up to 2000 psi, hold two minutes. Bleed pressure off and check floats, OK. 1st stage CIP at 14:00 hrs. 14:00 - 14:30 0.50 CASE P INT1 14:30 - 17:30 3.00 CASE P INT1 17:30 - 21:30 21:30 - 00:00 00:00 - 02:00 02:00 - 03:00 03:00 - 12:00 12:00 - 14:00 4.001 CASE I P I I INT1 2.50 CASE P INTi 2.00 CASE P INT1 1.00 CASE P INTi 9.00 CASE P INT1 2.001 CASE I P I I INT1 Load ES Cementer closing plug into cement head before pressuring up to open ES cementer. Pressure casing to 3500 psi and see ES cementer open. Pressure bled off. Establish circulation through ES cementer at 8558' MD. Circulate at 255 gpm, 437 psi. See 70 bbls. cement return to surface. Allow 1st stage cement to set up to 100 BCA and continue circulating through ES cementer. 250 gpm, 450 psi. Good returns. PJSM w/WSL, toolpusher, Schlumberger, mud engineer, all hands for 2nd stage cement job. Mix and pump 91.26 bbls. of 10.8 ppg Mudpush and pump at 5.5 bpm, 397 psi. Pump 168.33 bbls. lead slurry of 10.8 ppg LiteCrete 5 bbls/min. 400 psi. Some difficulty keeping weight and rate up. Pump 155.48 bbls tail slurry of 15.8 ppg Premium G cement w/Gasblok. Slurry weight and pump rate erratic. Slurry pump seals out on cementing unit causing poor loading/mixing of cement in tub. Average weight of slurry stabilized at 15.7 w/pump rate at 3.5 bbls./min. Unit was able to finish mixing slurry. Dropped ES cementer closing plug and saw indicator trip. Schlumberger pumped 1st 5 bbls of displacement H2O to clear lines to floor. Switched displacement to rig pumps and 10.6 ppg LSND mud at 6 bpm w/pressure increasing as expected to 670 psi during displacement. Slow rates to 4 bbls/min and then 2 bbls/min before plug bump. FCP = 670 psi. Bump plug at 4612 strokes w/4626 strokes calculated. Pressure to 1279 psi over FCP to 1949 psi and feel ES cementer shut at rig floor. Hold pressure on chart for 5 minutes. Bleed off pressure to zero and check for flowback. None. CIP at 20:45. WOC f/second stage to acquire 300 psi compressive strength. Clear floor. Rig maintenance. Housecleaning. Wait on call f/Schlumberger lab for 2nd stage compressive strength minimum of 300 psi. RU Schlumberger cementing unit and Hot Oil pump truck for stage 3 downsqueeze. WOC. Rig maintenance. RU Head pin and low torque valve on 7" casing. Pump out inside of 7" to GL w/cellar pump to prepare for cut after landing in slips. Drain BOP stack and fill w/diesel to prepare for 3rd stage downsgeeze. Close top rams on 7". Clean/mop/paint. Paint/mop/clean. RU Schlumberger to annulus and prepare to pump 3rd stage cement downsqueeze for 7" x 10-3/4" annulus. PJSM w/WSL, toolpusher, Schlumberger, mud engineer, all hands for cement Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Event Name: REENTER+COMPLETE Start: 8/4/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date 9/4/2006 From - To I Hours I Task ! Code I NPT ( Phase 12:00 - 14:00 I 2.001 CASE I P I I INT1 Page 15 of 20 Spud Date: 3/16/1992 End: 8/28/2006 Description of Operations job. Tie in /Hot Oil pump truck Tee into Schlumberger discharge hardline. Pump 10 bbls H2O down line w/Schlumberger to 7" x 10-3/4" annulus. Perform infectivity test: 3 bbls/min 417 psi. Infectivity established. Mix and pump 132.6 bbls. 11.6 ppg LiteCrete w/Gasblok, 4.2 bpm, 525 psi down annulus. Switch at Tee to Hot Oil and displace cement w/5 bbls + 1.0 bbl. for discharge line volume. 1.0 bpm @ 150 psi. FCP = 37 psi. Shut down. CIP at 13:26, 9-4-06 Shut in. Suck diesel in treating lines from 7" x 10-3/4" annulus back to Hot Oil truck. 14:00 - 00:00 10.00 CASE P INTi WOC due to 55 deg. F. environment of 7" x 10-3/4" annulus. Rig maintenance. Paint. C/O 5-1/2" liners in pumps to 5" liners for drilling production hole. 9/5/2006 00:00 - 02:30 2.50 CASE P INT1 WOC in 55 deg. F. environment of 7" x 10-3/4" annulus. 02:30 - 03:30 1.00 CASE P INTi Per Schlumberger lab cement will exceed 500 psi at 02:30. RU test pump and pressure test w/diesel down annulus to 1000 psi. Hold for 10 mins. w/chart. OK. 03:30 - 08:00 4.50 BOPSU P INT1 Split BOP stack between casing head and tubing spool flanges. Hold 50K # tension on 7" casing. Clean out casing bowl. Install FMC 7" emergency slips and set down casing weight. Clean all cement and debris out of BOP (no water). Cut casing w/pneumatic cutter and bevel cut. Change bottom pipe rams to 2 7/8" x 5' varible rams. 08:00 - 09:30 1.50 BOPSU P INT1 Break out seized studs on casing spool. Remove casing spool. 09:30 - 10:30 1.00 BOPSU P INT1 Install casing pack off and run in lock down screws. 10:30 - 15:30 5.00 BOPSU P INT1 Nipple up casing spool and BOP. Test pack off to 3800 psi w/7" x 10-3/4" annulus valve open. Remove 7" hard boby rams and install 3 1/2" x 6" varible rams in top pipe rams. 15:30 - 00:00 8.50 CASE P INT1 Lay down 5" drill pipe from derrick out of the mouse hole. 9/6/2006 00:00 - 03:00 3.00 CASE P INT1 Lay down 5" drill pipe from derrick out of the mouse hole. 03:00 - 03:30 0.50 CASE P INT1 Change out saver sub on top drive from 4 1/2" IF to 4" HT-40. 03:30 - 05:00 1.50 BOPSU P INT1 Install test plug and rig up test equipment. 05:00 - 09:00 4.00 BOPSU P INT1 Pressure test BOPS to 250 psi low, 4000 psi high. Utilizing 4" and 4 1/2" test joints. Test witnessed by Wade Frame, Lance Vaughan BP WSL and Lenward Toussant, Larry Wurdeman Nabors toolpushers. Wittness of BOP test waived by AOGCC representative John Crisp. 09:00 - 09:30 0.50 BOPSU P INT1 Rig down test equipment. Blow down lines. Install wear bushing. 09:30 - 11:00 1.50 CASE P INT1 Pick up 30 joints of 4" HT-40 drill pipe and rack back in derrick. 11:00 - 15:00 4.00 DRILL P PROD1 Pick up BHA #11 consisting of Hughes MX-18HDX 6 1/8" bit, 1.15 degree PDM, Float sub, NM IB SZR, NM flex lead collar, MWD, ADN4, (3) NM flex drill collar, Circ sub, Jar, (14) 4" HWDP = 637' Pre job safety melting on source installation in Schlumberger ADN4 tool. 15:00 - 18:30 3.50 DRILL P PROD1 Run in the hole with BHA #11 from 637' to 3411'. Picking up 4" HT-40 drill from pipe shed. Shallow pulse test MW D at 924'. 18:30 - 19:30 1.00 DRILL P PRODi Service top drive and adjust brakes on draw works. Fill drill pipe. 19:30 - 22:00 2.50 DRILL P PROD1 Continue picking up 4" HT-40 drill pipe from 3411' to 6852'. Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page 16 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task ~ Code NPT I Phase Description of Operations 9/6/2006 22:00 - 22:30 0.50 DRILL P ~ PROD1 Circulate at 104 gpm 760 psi. While loading and straping 4" 9/7/2006 9/8/2006 22:30 - 00:00 1.50 DRILL P 00:00 - 01:00 1.00 DRILL P 01:00 - 02:00 1.00 DRILL P 02:00 - 03:00 I 1.001 DRILL I P 03:00 - 03:30 I 0.501 DRILL i P 03:30 - 07:30 07:30 - 09:00 09:00 - 10:00 10:00 - 10:30 10:30 - 11:30 4.00 DRILL P 1.50 DRILL P 1.00 DRILL P 0.50 DRILL P 1.00 DRILL P 11:30 - 13:30 13:30 - 14:30 14:30 - 15:30 15:30 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 21:00 21:00 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 03:30 03:30 - 05:00 05:00 - 08:30 2.00 DRILL P 1.00 DRILL P 1.00 DRILL P 2.50 DRILL P 1.00 DRILL C 0.50 DRILL C 1.50 DRILL C 1.00 DRILL C 0.50 DRILL C 1.50 DRILL C 3.50 DRILL C 1.50 DRILL C 3.501 EVAL I C HT-40 drill pipe in pipe shed. Up wt. 135k So wt.70k. Mud wt. in 10.6 ppg, Out 10.6 ppg. PROD1 Continue picking up 4" HT-40 drill pipe from 6852' to 7617'. PROD1 Continue picking up 4" HT-40 drill pipe from 7617' to 8191'. PRODi Break circulation 4 bpm 985 psi. Pressure test casing to 4000 psi. for 10 minutes. Good test. Install blower hose to top drive and run in the hole to 8543'. PROD1 Break Circulation. Up wt. 165k, So wt. 80k, Rot wt. 105k, 220 gpm 1550 psi, WOB 10k, 60 RPM, 8.5k tq off bottom, 9 to 10k on bottom. Tag soft cement at 8555'. Tag ES cementer at 8557'. Drill ES cementer. PROD1 Circulate and condition mud at 220 gpm 1600 psi, while loading and strapping 4" drill pipe in pipe shed.Mud wt. in 10.6 ppg. Out 10.6 ppg. PROD1 Continue picking up 4" HT-40 drill pipe from 8557' pushing Es cementer closing plug to 12550'. PROD1 Circulate bottoms up at 240 gpm 2475 psi. Mud wt. in 10.6 ppg. Out 10.6 ppg. PROD1 Rig up and test 7" casing to 4000 psi for 30 minutes. Good test, Record test pressure. Rig down test equipment. PROD1 Pump 40 bbls (4 drums EP mud tube) tube sweep., Due to the inability to rotate (torque limitations) PROD1 Tag plug at 12557'. Drill plug and shoe track to 12641'. Up wt. 290k, S/O wt. 90k, Rot wt. 115k, 30 Rpm, 12.5K tq on and off bottom, 240 gpm 2400 psi. PRODi Pump 150 bbl H2O and displace well bore to 8.4 ppg SF Flo pro mud. Mud wt. in 8.4 ppg. Out 8.4 ppg. PROD1 Drill 6 1/8" directional hole f/ 12643' to 12663'. PROD1 Pull out of the hole to 12587', 8710' TVD. Perform FIT to an equivalent mud wt. of 10.0 ppg, 723 psi. PROD1 Drill 6 1/8" directional hole f/ 12663' to 12755'. Up wt. 135k, S/O wt. 135k, Rot wt. 160k, 60 RPM, 7k tq off and on bottom, 274 gpm 2095 psi. ART = 1.08 Hrs. AST = 1.15 Hrs ADT = 2.22 Hrs Jar Hrs = 123.44 PROD1 Circulate bottoms up at 276 gpm 1856 psi. PROD1 Monitor well bore for 10 minutes. Pull out of the hole to 12587'. (2 stands) PROD1 Slip and cut 48' of drilling line. Clean sumps under draw works. PROD1 Run in the hole from 12587' to 12755'. No fill on bottom. Circulate bottoms up at 269 gpm 1776 psi, 50 RPM, 7k tq, Up wt. 210k, S/O wt. 135k, Rot wt. 160k. Mud wt. in 8.4 ppg. Out 8.4 PPg• PROD1 Monitor well bore for 10 minutes, Pull out of the hole to 12587'. Pump dry job. Drop 2.25" rabbit. PROD1 Pull out of the hole from 12587' to 11154' PROD1 Pull out of the from 11154' to 637' PROD1 Stand back 4" HWDP, Jar, NM flex drill collars. Remove source from ADN. Lay down circ sub, ADN, MWD, NM flex lead collar, NM IB SZR, Float sub, 1.15 degree PDM and 6 1/8" bit. PROD1 Load pipe shed with Schlumberger MDT logging tools. Pre Job Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page 17 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABORS 7ES Rig Number: Date From - To ~ Hours Task ~ Code NPT Phase ~ Description of Operations - -- - __ 9/8/2006 ~ 05:00 - 08:30 3.50 EVAL ~ C PROD1 Safety Metting with Schlumberger Personal. Pick up 08:30 - 16:00 7.50 EVAL C 16:00 - 19:30 I 3.501 EVAL I C 19:30 - 20:30 1.00 EVAL C 20:30 - 00:00 3.50 EVAL C 9/9/2006 100:00 - 04:30 I 4.50 I EVAL I C 04:30 - 05:00 0.50 EVAL C 05:00 - 06:30 1.50 EVAL C 06:30 - 07:00 0.50 EVAL C 07:00 - 13:30 6.50 EVAL C 13:30 - 15:00 1.50 EVAL C 15:00 - 15:30 0.50 EVAL C 15:30 - 17:30 2.00 EVAL C 17:30 - 23:00 5.50 EVAL C 23:00 - 23:30 0.50 EVAL C 23:30 - 00:00 0.50 DRILL P 9/10/2006 100:00 - 04:00 I 4.001 DRILL I P 04:00 - 05:00 1.00 DRILL P 05:00 - 05:30 0.50 DRILL P 05:30 - 07:00 1.50 DRILL P 07:00 - 07:30 0.50 DRILL P Schlumberger MDT logging tools and test. PROD1 Run in the hole form 109' to 12143' with drill pipe conveyed logging tools at 80' min. Up wt. 185k, S/O wt. 125k. PROD1 Hang Schlumberger E-Line sheave in derrick, Make up side door entry sub, RIH the hole with head to 11857' WLM. Pump head down at 130 gpm 850 psi to assit in latch up on wet connect. Verify latch up of 2k over pull on E-Line. Secure E-line to side door entry sub. PROD1 Run in the hole from 12143' to 12655' at 1000' an hour. PROD1 Logging with Schlumberger MDT fool. Pulling samples at 12649.0', 12650.0', 12650.8', 12651.5', 12653.5', Formation to tight to pull sample at 12657.0'. Pulling fluid sample at 12652.5' PROD1 Pulling fluid sample at 12652.5'. Pull samples at 12658', 126666.6', 12662', 12668.6', 12,675', 12681.6'. PROD1 Pull out of the hole to 12143'. PRODi Remove securing equipment from Schlumberger side door entry sub. Pull out of the hole with Schlumberger E-Line. PROD1 Remove side door entry sub from drill string. Remove Schlumberger E-Line sheave from derrick. Monitor well bore, Static PROD1 Pump dry job and pull out of the hole moderately to 109'. PROD1 PJSM. Break and lay down Schlumberger MDT logging tools. Clear and clean rig floor. PROD1 PJSM on Skate safety. PROD1 Pick up BHA #12 consisting of Hughes MX-18HDX 6 1/8" bit, 1.15 degree PDM, Float sub, NM IB SZR, NM flex lead collar, MW D, ADN4, Run in the hole with NM flex drill collars and HWDP from the derrick to 637'. Load source in Schlumberger ADN4 tool. PROD1 Run in the hole with BHA #12 from 637' to 12700' Shallow pulse test MWD 270 gpm 860 psi. Filling drill pipe every 30 stands run in the hole. PROD1 Wash to bottom at 12755' as a precationary measure. PROD1 Drill 6 1/8" directional hole f/ 12755' to 12770'. Up wt. 220k, S/O wt. 135k, Rot wt. 155k, 60 RPM, 6.5k tq off 7k on, 219 gpm 1930 psi. WOB 20k. Mud wt. in 8.4 ppg. Out 8.4 ppg. ART = .33 Hrs. AST = 0 Hrs ADT = .33 Hrs Jar Hrs = 123.77 PROD1 Drill 6 1/8" directional hole f/ 12770' to 13060'. Up wt. 225k, S/O wt. 140k, Rot wt. 155k, 80 RPM, 6.5k tq off 7.5k on, 260 gpm 1975 psi. WOB 20k. Mud wt. in 8.4 ppg. Out 8.4 ppg. PROD1 Circulate bottoms up at 260 gpm 1975 psi. PROD1 Monitor well bore for 10 minutes. Pull out of the hole from 13060' to 12600'. Service top drive and crown section. Run in the hole from 12600' to 13060'. No fill on bottom. PROD1 Circulate a 30 bbl Hi-Vis around at 280 gpm 2100 psi. PROD1 Monitor well bore for 10 minutes. Static. Pull out of the hole from 13060' to 12500'. Printed: 9/18/2006 11:08:13 AM BP EXPLORATION Page 18 of 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To 9/10/2006 07:30 - 08:00 Hours I Task I Code I NPT ( Phase Description of Operations 08:00 - 08:30 08:30 - 09:30 1.00 DRILL P 09:30 - 15:00 5.50 DRILL P 15:00 - 17:30 ~ 2.50 ~ DRILL ~ P 17:30 - 18:00 0.50 DRILL P 18:00 - 19:30 1.50 CASE P 19:30 - 21:00 1.50 CASE P 21:00 - 22:00 I 1.001 CASE I P 22:00 - 00:00 2.00 CASE P 9/11/2006 00:00 - 05:00 5.00 CASE P 05:00 - 06:00 I 1.001 CASE I P 06:00 - 06:30 0.50 CASE P 06:30 - 07:00 0.50 CASE P 07:00 - 07:30 0.50 CASE P 07:30 - 09:00 I 1.501 CEMT I P 09:00 - 10:00 1.00 CEMT P 0.50 DRILL P PROD1 Run in the hole from 12500' to 13060'. Geology determined more rat hole was needed. 0.50 DRILL P PROD1 Drill 6 1/8" directional hole f/ 13060' to 131._20'. Up wt. 225k, S/O wt. 140k, Rot wt. 155k, 80 RPM, 6.5k tq off 7.5k on, 260 gpm 1975 psi. WOB 20k. Mud wt. in 8.5 ppg. Out 8.5 ppg. ART = 3.61 Hrs ADT = 3.61 Hrs Jar Hrs = 126.94 PROD1 Circulate a 30 bbl Hi-Vis around at 280 gpm 2100 psi. Monitor well bore for 10 minutes. Static. PROD1 Pull out of the hole from 13120' to 637'. Monitored well bore for 10 minutes at 12600'. Static. Pumped dry job and removed blower hose from top drive. PROD1 Lay down BHA #12, (14) 4" HWDP, Jar, Circ sub, (3) NM flex drill collar, ADN, MWD, NM flex lead collar, NM IB SZR, Float sub, 1.15 degree PDM and Bit. PJSM with Schlumberger on removing source from ADN. PROD1 Clean and clear rig floor. RUNPRD Rig up Nabors casing equipment. PJSM. RUNPRD Run 14 joints of 4 1/2" 12.6# L-80 IBT-M Liner. Baker Loc shoe track. Check floats, OK. Average make up torque 3600 ft/pds. Placing 4 5/8" x 5 3/4" free float centralizers on joints 1 thru 10. RUNPRD Make up Bakers 5" x 7" Flex Loc liner hanger and run in the hole with 1 stand of 4" HT-40 drill pipe. Circulate liner volume at 211 gpm 136 psi. Rig down nabors casing equipment. Up wt. 35k Up. S/O wt. 35k. RUNPRD Run in the hole with 4 1/2" 12.6# L-80 IBT-M liner to 3215'. Filling every 10 stands run with 8.5 ppg Flo-Pro mud. RUNPRD Run in the hole with 4 1/2" 12.6# L-80 IBT-M liner from 3215' to 12643'. Filling every 10 stands run with 8.5 ppg Flo-Pro mud. RUNPRD Circulate bottoms up at 12643'. 7" casing shoe. Staging pumps up to 6 bbl/min 1070 psi. Up wt. 195K. S/O wt. 125k RUNPRD Run in the from 12643' to 13090'. RUNPRD Make up cement head and circulating lines. RUNPRD Wash liner to bottom. Tagging bottom at 13120'. Pick 2' off bottom at 13118'. Circulate liner volume. Staging pumps up to 6 bbl/min 1210 psi from 5 bbl/min 1045 psi, 4 bbl/min 770 psi. PJSM with Schlumberger/Dowell. Batch mix cement. RUNPRD Pump 5 bbls of water and pressure test lines to 4000 psi. Pump 20 bbls 10.0 ppg mud push, followed by 20 bbl of 15.8 ppg class G cement w/ Gaslock. Wash lines thru T to flow line. Drop drill pipe wiper plug, Switch to rig pump and pump 10 bbl of Perf pill followed with 8.5 ppg Flo-Pro mud. Bump plug with 132.2 bbls away. Pressure up to 3000 psi. Bleed off pressure and check floats. Slack off to 50k confriming hanger set. Release from hanger by rotating 20 turns to the right. Pick up 8' and circulate 50 bbl of 8.5 ppg mud. Set down 25k on Bakers ZXP packer, repeating twice with rotation to confrim set. Pull stinger 30' above 4 1/2" liner top. 4 1/2" Liner Top at 12500'. CIP at 0845 Hrs. RUNPRD Circulate out excess cement at 480 gpm 2050 psi. 8 bbls of cement diverted to cuttings tank. Printed: 9/18/2006 17:08:13 AM BP EXPLORATION Page 19 ofi 20 Operations Summary Report Legal Well Name: Z-19 Common Well Name: Z-19 Spud Date: 3/16/1992 Event Name: REENTER+COMPLETE Start: 8/4/2006 End: 8/28/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2006 Rig Name: NABOBS 7ES Rig Number: Date From - To 9/11/2006 10:00 - 10:30 10:30 - 12:00 12:00 - 18:00 Hours ~ Task j Code I NPT ( Phase Description of Operations 18:00 - 18:30 0.50 CEMT P 18:30 - 20:00 1.50 CEMT P 20:00 - 23:30 3.50 CEMT P 23:30 - 00:00 0.50 CEMT P 9/12/2006 00:00 - 01:00 1.00 CEMT P 01:00 - 02:00 1.00 EVAL P 02:00 - 08:00 6.00 EVAL P 08:00 - 08:30 I 0.501 EVAL I P 08:30 - 09:30 I 1.00 09:30 - 10:30 1.00 10:30 - 11:00 0.50 11:00 - 00:00 I 13.00 9/13/2006 100:00 - 02:30 I 2.50 02:30 - 04:00 I 1.50 04:00 - 04:30 I 0.50 04:30 - 05:30 1.00 BOPSUF~ P 05:30 - 08:00 2.50 WHSUR P 08:00 - 08:30 0.50 WHSUR P 08:30 - 09:00 0.50 WHSUR P 09:00 - 10:30 1.50 WHSUR P 10:30-11:00 0.50 WHSUR P 11:00 - 12:30 I 1.501 WHSUR 12:30 - 14:30 2.001 WHSUR P RUNPRD Rig down circulating lines and lay down cement head. RUNPRD Displace well bore to 8.5 ppg KCL fluid. RUNPRD Pull out of the hole from 12500' to 4467' laying down 4" HT-40 drill pipe. RUNPRD Run in the hole with excess drill pipe from the derrick to 4992' RUNPRD PJSM. Cut and Slip 128' of drilling line. RUNPRD Pull out of the hole from 4992 to Bakers running tool, laying down 4" HT-40 drill pipe. RUNPRD Make service breaks on Bakers running tool and lay down. Verify rotating dog sheared RUNPRD Rig up and test 4 1/2" 12.6# IBT-M Liner to 4000 psi. Chart test pressure. Rig down and blow down test equipment. OTHCMP PJSM, Rig up Schlumberger wire line. OTHCMP Run in the hole with Schlumberger Usit log to 12480'. Logging from 12465' WLM to surface. OTHCMP Lay down logging tools and rig down Schlumberger wire line equipment. RUNCMP Pull wear bushing and Run in the hole with tubing hanger for dummy run. OK. Pull tubing hanger. RUNCMP Rig up Nabors casing torque turn equipment. RUNCMP PJSM. Discuss control of pipe while on pipe skate, use of compensator and single jt. elevators, and pipe shed procedures with WSL, Baker, Nabors casing hand, tourpusher and all hands. RUNCMP Run in the with 4.5" 12.6# L-80 TC-II completion to 10116'. Baker-Lok all connections from packer to muleshoe W LEG. Measure and confirm W LEG will drift thru 5.75" ID Baker liner top extension sleeve. Optimum Torque 3850 fUlbs. RUNCMP Continue to run in the hole with 4.5" 12.6# L-80 TC-II completion from 10116' to 12500' ,and tag liner top at 12500'. Up wt. 160K, S/O wt. 90K. RUNCMP Run in the hole 11' and tag bottom at 12515'. Pick up to Up wt. plus 5' off bottom with 6' of tailpipe inside liner top. Top of 4 1/2" liner at 12500'. Space out using 3 space out pups below hanger and land hanger. RUNCMP Run in lock down screws. Install TWC and test from below to 500 psi. RUNCMP Nipple down BOP and set back on stand. RUNCMP Nipple up adapter flange and tree.Test pack off and tree to 5000 psi. RUNCMP Rig up lubricator and pull TWC vavle. RUNCMP Rig up to circulate and freeze protect. RUNCMP Spot 231 bbls of inhibited sea water at 3 bbl/min 330 psi. RUNCMP Disscuss BP code of ethics with both crews and service personal. RUNCMP PJSM with Hot Oil. Pressure test lines to 2000 psi. Pump 80 bbls of diesel down tubing at 3 bbl/min 600 psi. Allow diesel to U-Tube. RUNCMP Drop 1.875" roller assit ball and rod. Pressure up on tubing to 4000 psi to set pkr .Test to 4000 psi down tubing. Chart and hold for 30 mins. OK. Pressure annulus to 4000 psi. Chart and hold for 30 minutes. OK. 0.50 CEMT P 1.50 CEMT P 6.00 CEMT P Printed: 9/1 S/2006 11:08:13 AM Printed: 9/18/2006 11:08:13 AM Digital Wellfile Page 1 of 1 Well Events for SurfaceWell - Z-1~ Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> Z -> Z-19 Date Range: 11/Oct/2006 to 14/Dec/2006 Data Source(s): AWGRS Events Source Well Date Description AWGRS Z-19A 12/11/2006 T/I/0=550/380/960 State wittnesed MIT-IA PASSED (AOGCC MIT-IA post initial injection) IA pressured up with 4.4 bbls -10* meth to 4000 psi, 1st. test, Lost 20 psi in 1st. 15 min., Lost xx psi. in 2nd 15 min., Bleed OAP from 960 psi. to xxx psi. down tubing, FWHP's 55/300/690 AWGRS Z-19A 12/11/2006 T/I/0=550/380/960 Temp=126* AOGCC MITIA ***PASSED*** Witness by Chuck Scheve. Pumped 4.4 bbls 100% Meoh to pressure up IAP to 4000 psi. IA lost 20 psi in first 15 min and 0 psi in second 15 min for 20 psi total loss in 30 min. Bled WHPs back to FWHP=550/300/690 AWGRS Z-19A 11/26/2006 T/I/0=100/0/150. (Step rate test). Pressure up on IA to 1500 psi. RD off IA. RU to tbg. Spear into tbg w/ 10 bbls 60/40 meth followed by 200 bbls 2% KCL. Shutdown for 30 minutes. Perform step rate test from min. rate of .4 bpm @ 450 psi to max rate of 4.6 bpm @ 2300 psi. Shutdown for 30 minutes. Perform second step rate test Min. rate of .5 bpm @ 500 psi to max. rate of 4.6 bpm @ 2300 psi. Freeze protect tbg w/ 45 bbls 60/40 meth. Bleed IA pressure down to 0 psi. FWHP=100/0/300. AWGRS Z-19A 11/17/2006 ****** WELL SHUT IN ON ARRIVAL. SSV CLOSED. ***** PERFORATE 50' WITH 2.5" "~ POWERJET OMEGA CHARGES LOADED 6 SPF. AVERAGE PENETRATION 30.6" AND AVERAGE ENTRANCE HOLE 0.32". MAX TOOLSTRING LENGTH=39.5'. MAX OD=2.5" GUNS SHOT IN TWO RUNS. TUBING PRESSURE DROPPED FROM 175 TO 0 PSI AFTER FIRING GUN#1. INTERVAL SHOT WAS 12804 TO 12854 FT. INITIAL T/I/0=50/0/150 FINAL = 150/0/150 **** WELL LEFT SHUTIN, SSV CLOSED ***** AWGRS. Z-19A 10/29/2006 CONTINUED FROM PREVIOUS DAY DID NOT PERF WELL AFTER LOGGING SCMT. WELL LEFT SHUT IN. TURNED OVER TO DSO. ***JOB INCOMPLETE -DID NOT PERF*** AWGRS Z-19A 10/28/2006 LOGGED CEMENT BOND LOG FROM TD UP TO 12250'. TD FOUND AT 13026'. LOGGED PASSES AT 30 FPM. DURING LOGGING THERE WAS 500 PSI WHP. LOGGED PRESSURE AND TEMPERATURE DATA ACROSS SAME INTERVAL. NO PROBLEMS RIH OR POOH. DID NOT PERF WELL AFTER LOGGING SCMT. WELL LEFT SHUT IN. TURNED OVER TO DSO. **JOB INCOMPLETE**. CONTINUED ON 29-OCT-2006 AWGRS. AWGRS Z-19A 10/21/2006 T/I/O = 160/VAC/240. Temp = S/I. No AL. WHPs &TBG FL (pre-Eline). TBG FL @ 15'. AWG...R....S. Z-19A 10/11/2006 **WELL SI ON ARRIVAL** (post sdtrk) PULL B&R @ 12,481' SLM .PULLED RHC PLUG BODY FROM 12,490'SLM .DRIFTED W/3 3/8 DUMMY GUN ,TAGGED TD @ 13,022'SLM .SAMPLE OF WHAT APPEARS TO BE DRILLING FINES. ***WELL LEFT S/I ON DEPARTURE*** Refresh List http://digitalwellfile.bpweb.bp.com/WellEvents/Home/Default.aspx 12/14/2006 by ~~t4~.d~ _~ _ .. ~ Schlumberger _#,~~ ~-~i ~~- purvey Report - Report Date: 10-Sep-O6 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska vertical Section Azimuth: 12.970° Field: Prudhoe Bay Unit - WOA vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: Z-PAD 12-19 ND Reference Datum: Rotary Table Well: Z-19 TVD Reference Elevation: 82.66ft relative t0 MSL Borehole: Z-19A Sea Bed f Ground Level Elevation: 54.12 ft relative t0 MSL UWUAPNt: 500292225101 Magnetic Declination: 23.996° Survey Name I Date: Z-19A I September 10, 2006 Total Field Strength: 57625.086 nT Tort 1 AHD I DDI I ERD ratio: 225.986° / 8168.53 ft / 6.42310.893 Magnetic Dip: 80.864° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 01, 2006 Location Latllong: N 70.29767889, W 149.19216919 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5959099.970 ftUS, E 599754.940 ftUS North Reference: True North Grid Convergence Angle: +0.76054362° Total Corr Mag North •> True North: +23.996° Grid Scale Factor. 0.99991130 Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub-Sea TVD 1yp Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longkude Depth Section Departure h d d k ft fl k ft ft ft d 100 k ftUS kUS RTE U.UU U.U"L "L4tf.y6 -tSZ.O6 V.UV -V.UI U.UV v.ur u.w -u.vr v.w ayawyy.~r aayraw.~r rvr~.carorooo vv w~.r~cronco GCT-MS 15.66 0.07 248.96 -67.00 15.66 -0.01 0.01 0.02 -0.01 -0.02 0.35 5959099.96 599754.92 N 70 .29767887 W 149.19216937 18.76 0.22 359.58 -63.90 18.76 -0.01 0.02 0.02 0.00 -0.02 8.17 5959099.97 599754.92 N 70 .29767888 W 149.19216938 24.06 0.47 18.43 -58.60 24.06 0.02 0.05 0.03 0.03 -0.02 5.12 5959100.00 599754.92 N 70 .29767897 W 149.19216933 33.86 0.65 23.01 -48.80 33.86 0.12 0.14 0.12 0.12 0.02 1.89 5959100.09 599754.96 N 70 .29767921 W 149.19216905 48.36 0.67 18.53 -34.30 48.36 0.28 0.31 0.28 0.27 0.08 0.38 5959100.24 599755.01 N 70 .29767964 W 149.19216857 63.76 0.67 17.16 -18.90 63.76 0.46 0.49 0.46 0.44 0.13 0.10 5959100.42 599755.07 N 70 .29768011 W 149.19216812 79.06 0.67 18.33 -3.60 79.06 0.64 0.67 0.64 0.61 0.19 0.09 5959100.59 599755.12 N 70 .29768057 W 149.19216768 97.46 0.67 18.85 14.80 97.46 0.85 0.89 0.86 0.82 0.25 0.03 5959100.79 599755.18 N 70 .29768113 W 149.19216713 115.26 0.68 17.77 32.59 115.25 1.06 1.10 1.07 1.02 0.32 0.09 5959100.99 599755.25 N 70 .29768167 W 149.19216659 131.16 0.70 15.82 48.49 131.15 1.25 1.29 1.26 1.20 0.38 0.19 5959101.18 599755.30 N 70 .29768217 W 149.19216615 147.86 0.73 13.39 65.19 147.85 1.46 1.50 1.47 1.40 0.43 0.26 5959101.38 599755.35 N 70 .29768272 W 149.19216572 164.66 0.77 12.70 81.99 164.65 1.68 1.72 1.69 1.62 0.48 0.24 5959101.59 599755.40 N 70 .29768331 W 149.1 181.56 0.78 13.07 98.89 181.55 1.91 1.94 1.91 1.84 0.53 0.07 5959101.82 599755.44 N 70 9 .29768392 W 149.19' 198.26 0.77 12.27 115.59 198.25 2.14 2.17 2.14 2.06 0.58 0.09 5959102.04 599755.49 N 70. 29768452 W 149.1921 451 215.06 0.75 10.70 132.39 215.05 2.36 2.39 2.36 2.28 0.62 0.17 5959102.26 599755.53 N 70. 29768512 W 149.19216415 231.86 0.75 9.81 149.18 231.84 2.58 2.61 2.58 2.49 0.66 0.07 5959102.47 599755.57 N 70 .29768571 W 149.19216383 248.76 0.80 9.48 166.08 248.74 2.81 2.84 2.81 2.72 0.70 0.30 5959102.70 599755.60 N 70 .29768632 W 149.19216352 265.56 0.85 9.85 182.88 265.54 3.05 3.08 3.05 2.96 0.74 0.30 5959102.94 599755.64 N 70 .29768697 W 149.19216319 282.36 0.85 11.68 199.68 282.34 3.30 3.33 3.30 3.20 0.79 0.16 5959103.18 599755.68 N 70 .29768764 W 149.19216281 298.76 0.87 14.29 216.08 298.74 3.54 3.58 3.54 3.44 0.84 0.27 5959103.42 599755.74 N 70 .29768830 W 149.19216237 315.26 0.95 14.94 232.57 315.23 3.81 3.84 3.81 3.70 0.91 0.49 5959103.68 599755.80 N 70 .29768899 W 149.19216183 331.86 1.12 13.40 249.17 331.83 4.11 4.14 4.11 3.99 0.98 1.04 5959103.97 599755.87 N 70. 29768979 W 149.19216124 348.66 1.22 12.96 265.97 348.63 4.45 4.48 4.45 4.32 1.06 0.60 5959104.30 599755.94 N 70. 29769070 W 149.19216061 SurveyEditor Ver SP 2.1 Bld(doc4Ox_1OO) Z-1912-1912-19A1Z-19A current Generated 9/11/2006 1:20 PM Page 1 of 7 Comments Meawred Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft d d ft ft ft ft ft ft ft d 100 ft ftUS ftUS :Sb5.4b 382.26 399.16 415.86 432.66 449.46 466.26 483.16 499.96 516.46 532.66 549.06 565.66 582.26 598.86 615.46 632.06 648.66 665.06 681.66 698.16 714.76 731.36 747.96 764.56 781.06 797.46 814.06 830.56 847.16 863.76 880.36 896.96 913.36 929.86 946.46 962.96 979.66 996.26 1012.76 1029.16 l .Z3 1.25 1.38 1.57 1.67 1.70 1.82 2.15 2.43 2.63 2.87 3.20 3.67 3.97 4.22 4.48 5.02 5.72 6.20 6.65 7.15 7.73 8.35 8.75 8.98 9.30 9.72 10.02 10.27 10.48 10.78 11.10 11.32 11.52 11.78 12.23 12.63 12.83 13.07 13.43 14.02 13.40 LBL./~ 3U~.9L 9.01 V.09 Y.pl Y.V/ ~•~"~ V.VV J.7JA IV-I.VV JJ~/JV.VL 14 IV.GJI V~IVJ YY I~J.IJL IJ.7J7 13.80 299.56 382.22 5.17 5.21 5.17 5.02 1.23 0.13 5959105.01 599756.10 N 70.29769262 W 149.19215925 14.37 316.46 399.12 5.56 5.59 5.56 5.40 1.32 0.77 5959105.39 599756.19 N 70.29769365 W 149.19215848 13.80 333.15 415.81 5.99 6.02 5.99 5.82 1.43 1.14 5959105.81 599756.29 N 70.29769479 W 149.19215764 12.95 349.94 432.60 6.46 6.50 6.46 6.28 1.54 0.61 5959106.27 599756.39 N 70.29769605 W 149.19215675 13.45 366.74 449.40 6.96 6.99 6.96 6.76 1.65 0.20 5959106.75 599756.50 N 70.29769736 W 149.19215584 14.32 383.53 466.19 7.47 7.51 7.47 7.26 1.77 0.73 5959107.25 599756.62 N 70.29769873 W 149.19215483 15.06 400.42 483.08 8.06 8.09 8.06 7.83 1.92 1.96 5959107.82 599756.76 N 70.29770028 W 149.19215363 15.56 417.21 499.87 8.73 8.76 8.73 8.48 2.10 1.67 5959108.47 599756.93 N 70.29770205 W 149.19215219 15.75 433.69 516.35 9.46 9.49 9.46 9.18 2.30 1.21 5959109.18 599757.11 N 70.29770396 W 149.19215060 15.95 449.87 532.53 10.23 10.27 10.24 9.92 2.51 1.48 5959109.93 599757.32 N 70.29770600 W 149.19214888 16.43 466.25 548.91 11.10 11.14 11.10 10.76 2.75 2.02 5959110.76 599757.55 N 70.29770828 W 149.19. 16.67 482.82 565.48 12.09 12.13 12.10 11.71 3.03 2.83 5959111.72 599757.82 N 70.29771089 W 149.19 16.22 499.38 582.04 13.20 13.24 13.20 12.77 3.35 1.82 5959112.78 599758.12 N 70.29771378 W 149.19214209 15.94 515.94 598.60 14.38 14.42 14.39 13.91 3.67 1.51 5959113.93 599758.43 N 70.29771690 W 149.19213943 16.15 532.49 615.15 15.64 15.68 15.65 15.12 4.02 1.57 5959115.14 599758.76 N 70.29772020 W 149.19213661 16.58 549.03 631.69 17.01 17.06 17.02 16.44 4.41 3.26 5959116.47 599759.13 N 70.29772380 W 149.19213348 17.10 565.56 648.22 18.56 18.61 18.57 17.93 4.86 4.23 5959117.96 599759.56 N 70.29772787 W 149.19212983 17.32 581.87 664.53 20.26 20.31 20.28 19.55 5.37 2.93 5959119.59 599760.04 N 70.29773231 W 149.19212575 17.47 598.37 681.03 22.11 22.17 22.13 21.33 5.92 2.71 5959121.37 599760.58 N 70.29773715 W 149.19212125 17.68 614.75 697.41 24.09 24.15 24.11 23.22 6.52 3.03 5959123.27 599761.15 N 70.29774232 W 149.19211640 17.77 631.21 713.87 26.23 26.30 26.26 25.26 7.17 3.49 5959125.32 599761.78 N 70.29774791 W 149.19211110 17.82 647.64 730.30 28.54 28.63 28.58 27.47 7.88 3.74 5959127.54 599762.46 N 70.29775395 W 149.19210536 17.87 664.06 746.72 31.00 31.09 31.05 29.82 8.64 2.41 5959129.90 599763.18 N 70.29776037 W 149.19209923 17.88 680.46 763.12 33.55 33.65 33.61 32.26 9.42 1.39 5959132.35 599763.93 N 70.29776702 W 149.19209288 17.60 696.75 779.41 36.16 36.27 36.23 34.75 10.22 1.96 5959134.85 599764.70 N 70.29777384 W 149.19208641 17.25 712.93 795.59 38.86 38.98 38.94 37.34 11.03 2.59 5959137.45 599765.48 N 70.29778090 W 149.19207984 17.02 729.28 811.94 41.70 41.83 41.78 40.06 11.87 1.82 5959140.18 599766.28 N 70.29778833 W 149.19207305 16.62 745.52 828.18 44.60 44.73 44.69 42.84 12.71 1.57 5959142.97 599767.08 N 70.29779593 W 149.19206624 16.17 761.85 844.51 47.59 47.72 47.68 45.71 13.56 1.36 5959145.85 599767.89 N 70.29780376 W 149.1 15.39 778.17 860.83 50.64 50.79 50.74 48.66 14.39 2.00 5959148.81 599768.68 9 N 70.29781181 W 149.19. 14.69 794.47 877.13 53.79 53.94 53.89 51.70 15.21 2.09 5959151.86 599769.46 N 70.29782013 W 149.19204606 14.41 810.75 893.41 57.02 57.16 57.11 54.82 16.02 1.37 5959154.99 599770.23 N 70.29782866 W 149.19203949 13.94 826.82 909.48 60.26 60.41 60.36 57.97 16.81 1.35 5959158.15 599770.98 N 70.29783726 W 149.19203305 13.37 842.98 925.64 63.60 63.74 63.69 61.21 17.60 1.72 5959161.40 599771.72 N 70.29784611 W 149.19202669 12.49 859.22 941.88 67.05 67.20 67.13 64.57 18.37 2.93 5959164.77 599772.45 N 70.29785530 W 149.19202043 11.81 875.33 957.99 70.60 70.75 70.68 68.04 19.12 2.58 5959168.26 599773.15 N 70.29786478 W 149.19201438 11.62 891.62 974.28 74.28 74.43 74.35 71.65 19.87 1.22 5959171.87 599773.85 N 70.29787463 W 149.19200833 11.41 907.80 990.46 78.00 78.15 78.06 75.29 20.61 1.47 5959175.52 599774.54 N 70.29788459 W 149.19200232 11.15 923.86 1006.52 81.78 81.93 81.84 79.00 21.35 2.21 5959179.24 599775.24 N 70.29789472 W 149.19199633 10.79 939.79 1022.45 85.67 85.82 85.72 82.82 22.09 3.64 5959183.07 599775.92 N 70.29790515 W 149.19199034 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-19~Z-19~Z-19A~Z-19A current Generated 9/11/2006 1:20 PM Page 2 of 7 Commeids Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section DepaRure ft d d ft ft ft ft ft ft ft d HOOft ftUS ftUS 1U4b.6ti 14.tiZ 1U.3/ y55./t5 lUSt5.44 O`J.r4 aa.y~ oy.ry oo.w cc.o4 o.oa oya~ior.~a o~yrro.oc rv r~.caraioi i vv 19~.1.7170'iL/ 1062.16 15.13 9.88 971.73 1054.39 93.97 94.14 94.01 91.00 23.58 3.18 5959191.27 599777.31 N 70.29792751 W 149.19197825 1078.66 15.72 9.15 987.63 1070.29 98.35 98.52 98.38 95.33 24.31 3.76 5959195.61 599777.98 N 70.29793933 W 149.19197238 1095.26 16.38 8.03 1003.59 1086.25 102.93 103.11 102.95 99.87 24.99 4.39 5959200.15 599778.60 N 70.29795173 W 149.19196683 1111.86 17.00 6.67 1019.49 1102.15 107.67 107.88 107.68 104.60 25.60 4.41 5959204.89 599779.15 N 70.29796464 W 149.19196190 1128.36 17.50 5.12 1035.25 1117.91 112.53 112.77 112.53 109.46 26.10 4.12 5959209.76 599779.58 N 70.29797794 W 149.19195784 1144.76 17.93 3.37 1050.87 1133.53 117.46 117.76 117.46 114.44 26.47 4.17 5959214.74 599779.89 N 70.29799153 W 149.19195486 1161.16 18.40 1.48 1066.45 1149.11 122.49 122.88 122.49 119.55 26.68 4.60 5959219.85 599780.03 N 70.29800549 W 149.19195312 1177.66 18.98 359.13 1082.08 1164.74 127.64 128.16 127.66 124.83 26.71 5.76 5959225.14 599779.99 N 70.29801993 W 149.19195290 1194.16 19.48 357.24 1097.66 1180.32 132.90 133.60 132.94 130.26 26.54 4.84 5959230.56 599779.74 N 70.29803477 W 149.19195430 1210.66 19.87 356.10 1113.20 1195.86 138.23 139.15 138.32 135.81 26.21 3.32 5959236.10 599779.35 N 70.29804992 W 149.19195692 1227.36 20.23 355.06 1128.88 1211.54 143.69 144.88 143.85 141.52 25.77 3.03 5959241.81 599778.83 N 70.29806551 W 149.19 1243.86 20.47 354.59 1144.35 1227.01 149.15 150.62 149.38 147.23 25.26 1.76 5959247.51 599778.24 1 N 70.29808112 W 149.19' 1260.36 20.63 354.49 1159.80 1242.46 154.64 156.41 154.98 153.00 24.70 0.99 5959253.27 599777.61 N 70.29809687 W 149.19 1276.66 20.82 354.50 1175.05 1257.71 160.11 162.18 160.57 158.74 24.15 1.17 5959259.00 599776.98 N 70.29811256 W 149.19197363 1293.16 21.18 354.82 1190.45 1273.11 165.72 168.09 166.31 164.63 23.60 2.29 5959264.88 599776.35 N 70.29812864 W 149.19197809 1309.66 21.58 355.23 1205.82 1288.48 171.45 174.10 172.17 170.62 23.08 2.59 5959270.87 599775.75 N 70.29814501 W 149.19198231 1326.16 21.83 355.56 1221.15 1303.81 177.26 180.21 178.14 176.70 22.59 1.69 5959276.94 599775.18 N 70.29816163 W 149.19198627 1342.76 22.05 355.89 1236.55 1319.21 183.19 186.41 184.22 182.89 22.13 1.52 5959283.12 599774.64 N 70.29817853 W 149.19199002 1359.36 22.28 356.14 1251.92 1334.58 189.18 192.67 190.38 189.14 21.69 1.50 5959289.36 599774.12 N 70.29819560 W 149.19199354 1375.86 22.62 356.45 1267.17 1349.83 195.21 198.97 196.58 195.42 21.29 2.18 5959295.64 599773.63 N 70.29821277 W 149.19199684 1392.26 22.90 356.79 1282.29 1364.95 201.30 205.32 202.84 201.76 20.91 1.89 5959301.97 599773.17 N 70.29823008 W 149.19199986 1408.56 23.10 356.99 1297.30 1379.96 207.42 211.69 209.13 208.12 20.57 1.32 5959308.32 599772.74 N 70.29824745 W 149.19200266 1426.06 23.30 357.16 1313.38 1396.04 214.05 218.58 215.95 215.00 20.21 1.21 5959315.20 599772.30 N 70.29826626 W 149.19200551 1451.26 23.72 357.51 1336.49 1419.15 223.73 228.63 225.91 225.04 19.75 1.76 5959325.23 599771.70 N 70.29829369 W 149.19200929 1484.26 24.10 357.84 1366.66 1449.32 236.63 242.01 239.18 238.41 19.20 1.22 5959338.59 599770.98 N 70.29833020 W 149.19201368 1523.56 23.95 358.05 1402.55 1485.21 252.09 258.01 255.08 254.40 18.63 0.44 5959354.57 599770.19 N 70.29837389 W 149.19201833 1564.26 23.73 358.36 1439.78 1522.44 268.00 274.46 271.44 270.84 18.12 0.62 5959371.00 599769.46 N 70.29841880 W 149.19202250 1604.86 23.97 358.74 1476.91 1559.57 283.89 290.87 287.79. 287.25 17.70 0.70 5959387.40 599768.82 N 70.29846364 W 149.19202586 1645.06 24.67 359.22 1513.55 1596.21 299.96 307.43 304.30 303.80 17.41 1.81 5959403.95 599768.31 N 70.29850886 W 149.19202824 1685.56 25.63 359.58 1550.21 1632.87 316.69 324.64 321.48 321.01 17.23 2.40 5959421.16 599767.90 N 70.29855588 W 149.19, 1726.06 26.30 359.64 1586.62 1669.28 333.94 342.37 339.18 338.75 17.11 1.66 5959438.88 599767.55 N 70.29860432 W 149.19 1766.96 26.87 359.12 1623.19 1705.85 351.73 360.68 357.45 357.05 16.91 1.51 5959457.18 599767.11 N 70.29865432 W 149.19203228 1807.86 27.92 358.07 1659.51 1742.17 369.96 379.49 376.22 375.86 16.44 2.83 5959475.98 599766.39 N 70.29870571 W 149.19203604 1848.56 29.13 357.11 1695.27 1777.93 388.70 398.93 395.59 395.28 15.62 3.18 5959495.38 599765.31 N 70.29875876 W 149.19204268 1889.26 30.13 356.69 1730.64 1813.30 408.03 419.05 415.62 415.37 14.53 2.51 5959515.46 599763.96 N 70.29881365 W 149.19205150 1929.56 30.95 356.65 1765.35 1848.01 427.69 439.53 436.02 435.81 13.34 2.04 5959535.88 599762.50 N 70.29886950 W 149.19206114 1970.06 32.03 356.42 1799.89 1882.55 447.98 460.68 457.09 456.93 12.06 2.68 5959556.98 599760.94 N 70.29892719 W 149.19207149 2010.16 33.95 355.48 1833.52 1916.18 468.85 482.52 478.82 478.71 10.52 4.96 5959578.73 599759.10 N 70.29898668 W 149.19208402 2050.46 36.12 354.24 1866.52 1949.18 490.84 505.65 501.82 501.75 8.44 5.67 5959601.74 599756.72 N 70.29904962 W 149.19210085 2090.56 37.45 353.58 1898.63 1981.29 513.53 529.66 525.65 525.62 5.89 3.46 5959625.58 599753.85 N 70.29911485 W 149.19212150 2130.66 38.00 353.45 1930.35 2013.01 536.67 554.20 550.01 550.00 3.12 1.39 5959649.91 599750.76 N 70.29918145 W 149.19214394 SurveyEd~or Ver SP 2.1 Bid( doc40x_100) Z-19~Z-19~Z-19A~Z-19A current Generated 9/11/2006 1:20 PM Page 3 of 7 Commends Measured Inclination Azimuth SulrSea ND ND Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft d de ft ft k k tt k k n ne d 1100 ft n cn kUS cncnco• ce ftUS Gl1lf9A~ CG ~i ~n oeeewnn~ ~ni un ~no~ccoe L~~t~.dd s8.`Ja sas.io Sao i.oo LV99.JL .70V.10 ~7/~7.V.7 J/Y.IY J/1./Y V.JJ G.JV JOJJV19.V1 J~~ITI.VV ~~ ~v.~~..G~a~+ Yv It,'l.~J~~VVVa 2210.46 40.90 354.25 1992.17 2074.83 584.32 604.64 600.16 600.15 -2.32 4.89 5959699.98 599744.65 N 70.29931846 W 149.19218798 2250.26 42.32 354.47 2021.93 2104.59 609.37 631.07 626.47 626.45 -4.92 3.59 5959726.24 599741.71 N 70.29939031 W 149.19220901 2290.36 42.77 354.49 2051.47 2134.13 635.08 658.19 653.48 653.44 -7.53 1.12 5959753.19 599738.74 N 70.29946404 W 149.19223013 2330.66 43.02 354.54 2080.99 2163.65 661.10 685.62 680.82 680.75 -10.15 0.63 5959780.46 599735.76 N 70.29953864 W 149.19225136 GCT-MS 2371.06 43.18 354.58 2110.49 2193.15 687.29 713.22 708.34 708.22 -12.76 0.40 5959807.90 599732.78 N 70.29961371 W 149.19227255 Tie-In Survey 2410.56 43.08 354.64 2139.32 2221.98 712.92 740.22 735.27 735.11 -15.30 0.27 5959834.75 599729.89 N 70.29968716 W 149.19229309 TOW (Inc+trend) ..~ 2427.00 42.96 354.73 2151.34 2234.00 _ 723.57 751.44 746.46 746.28 -16.34 0.82 5959845.90 599728.70 N 70.29971767 W 149.19230151 Inc+Trend 2456.76 41.27 354.73 2173.42 2256.08 742.53 771.40 766.37 766.15 -18.17 5.68 5959865.74 599726.60 N 70.29977196 W 149.19231635 BOW (Inc+Trend) 2460.00 41.13 354.74 2175.85 2258.51 744.55 773.53 768.50 768.28 -18.37 4.33 5959867.86 599726.38 N 70.29977776 W 149.19231794 MWD+IFR+MS 2552.63 37.13 354.92 2247.69 2330.35 800.09 831.98 826.82 826.48 -23.64 4.32 5959925.99 599720.34 N 70.29993678 W 149.19236062 2646.29 33.90 354.15 2323.92 2406.58 851.71 886.38 881.11 880.64 -28.81 3.48 5959980.07 599714.45 N 70.30008473 W 149.19 2740.88 32.29 353.86 2403.16 2485.82 900.55 938.02 932.63 932.00 -34.20 1.71 5960031.35 599708.38 2 N 70.30022505 W 149.19 2835.81 34.70 358.81 2482.34 2565.00 950.73 990.39 984.96 984.25 -37.47 3.84 5960083.54 599704.41 N 70.30036778 W 149.19247264 2931.03 36.87 1.85 2559.58 2642.24 1005.05 1046.05 1040.57 1039.91 -37.11 2.95 5960139.20 599704.03 N 70.30051983 W 149.19246973 3023.86 38.48 2.52 2633.05 2715.71 1060.78 1102.79 1097.15 1096.60 -34.94 1.79 5960195.91 599705.45 N 70.30067471 W 149.19245217 3118.17 41.08 4.58 2705.53 2788.19 1120.30 1163.12 1157.23 1156.81 -31.18 3.09 5960256.16 599708.41 N 70.30083921 W 149.19242168 3213.33 45.63 5.64 2774.70 2857.36 1185.00 1228.43 1222.12 1221.86 -25.34 4.84 5960321.27 599713.39 N 70.30101692 W 149.19237436 3307.21 49.00 6.65 2838.34 2921.00 1253.51 1297.43 1290.58 1290.46 -17.93 3.68 5960389.96 599719.88 N 70.30120433 W 149.19231442 3400.89 54.44 9.75 2896.36 2979.02 1326.76 1370.94 1363.21 1363.19 -7.38 6.36 5960462.82 599729.47 N 70.30140303 W 149.19222893 3496.76 60.22 12.48 2948.10 3030.76 1407.37 1451.60 1442.35 1442.32 8.23 6.49 5960542.14 599744.03 N 70.30161921 W 149.19210251 3590.45 61.80 13.09 2993.51 3076.17 1489.32 1533.55 1522.47 1522.24 26.37 1.78 5960622.29 599761.10 N 70.30183753 W 149.19195562 3686.27 62.30 14.02 3038.42 3121.08 1573.96 1618.19 1605.19 1604.52 46.21 1.00 5960704.82 599779.85 N 70.30206232 W 149.19179493 3782.65 62.56 15.00 3083.03 3165.69 1659,36 1703.63 1688.59 1687.23 67.62 0.94 5960787.80 599800.15 N 70.30228828 W 149.19162156 3875.58 63.31 14.66 3125.31 3207.97 1742.07 1786.38 1769.46 i 767.23 88.80 0.87 5960868.06 599820.27 N 70.30250682 W 149.19145002 3968.53 63.57 13.20 3166.87 3249.53 1825.20 1869.52 1851.12 1847.92 108.81 1.43 5960949.00 599839.20 N 70.30272727 W 149.19128792 4065.93 63.25 13.61 3210.47 3293.13 1912.29 1956.62 1936.95 1932.65 129.00 0.50 5961033.98 599858.27 N 70.30295873 W 149.19112438 4158.25 62.50 13.20 3252.56 3335.22 1994.46 2038.78 2018.01 2012.57 148.05 0.90 5961114.15 599876.25 N 70.30317708 W 149.19097008 4253.36 61.85 12.99 3296.96 3379.62 2078.57 2122.90 2101.15 2094.50 167.11 0.71 5961196.31 599894.22 N 70.30340089 W 149.19081571 4347.30 61.53 12.37 3341.51 3424.17 2161.27 2205.60 2183.06 2175.18 185.26 0.67 5961277.22 599911.30 N 70.30362132 W 149.19 4443.10 61.46 12.40 3387.23 3469.89 2245.45 2289.79 2266.55 2257.41 203.32 0.08 5961359.68 599928.26 0 N 70.30384596 W 149.19 4538.88 60.90 12.24 3433.40 3516.06 2329.36 2373.70 2349.83 2339.39 221.23 0.60 5961441.88 599945.08 N 70.30406993 W 149.19 4 4632.77 60.74 12.50 3479.17 3561.83 2411.33 2455.68 2431.22 2419.47 238.79 0.30 5961522.17 599961.57 N 70.30428868 W 149.19023508 4727.36 61.15 12.85 3525.11 3607.77 2494.02 2538.36 2513.30 2500.14 256.93 0.54 5961603.07 599978.64 N 70.30450906 W 149.19008810 4821.50 60.50 12.82 3571.00 3653.66 2576.21 2620.56 2594.91 2580.28 275.19 0.69 5961683.44 599995.83 N 70.30472800 W 149.18994018 4915.68 62.27 11.88 3616.11 3698.77 2658.88 2703.23 2677.11 2661.04 292.87 2.07 5961764.42 600012.43 N 70.30494863 W 149.18979698 5010.90 61.91 12.15 3660.68 3743.34 2743.01 2787.38 2760.84 2743.34 310.38 0.45 5961846.94 600028.85 N 70.30517347 W 149.18965507 5105.89 61.95 12.27 3705.37 3788.03 2826.82 2871.19 2844.25 2825.26 328.11 0.12 5961929.08 600045.49 N 70.30539727 W 149.18951145 5199.17 61.37 12.35 3749.65 3832.31 2908.92 2953.29 2925.96 2905.47 345.61 0.63 5962009.51 600061.93 N 70.30561640 W 149.18936964 5296.25 60.61 11.95 3796.73 3879.39 2993.81 3038.19 3010.49 2988.47 363.48 0.86 5962092.73 600078.69 N 70.30584314 W 149.18922486 5391.68 59.92 10.79 3844.07 3926.73 3076.64 3121.06 3093.11 3069.71 379.82 1.28 5962174.17 600093.95 N 70.30606506 W 149.18909247 5485.46 61.79 11.44 3889.74 3972.40 3158.50 3202.96 3174.82 3150.07 395.61 2.08 5962254.73 600108.67 N 70.30628461 W 149.18896451 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-19~Z-19~Z-19A~Z-19A current Generated 9/11/2006 1:20 PM Page 4 of 7 Commerds Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Cbsure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft d d ft k ft ft ft ft ft d 100 ft ftUS ftUS 55t}V,3[ Q I,b ~ I I.~L J~JY./ I 4U I !.J/ JG41..7.Y JGVV.Yp JLJV. 1 1 JLJ I.~L T IG.LT V.LV JJVLV~/v.i v vvv ~LT.L ~ ~v ~ V.~lVVJVVLL vv ~Ta. ~vv~ac~vc 5675.63 61.09 11.34 3980.41 4063.07 3325.60 3370.12 3341.53 3313.90 428.81 0.57 5962418.97 600139.69 N 70.30673219 W 149.18869551 5694.15 61,12 12.00 3989.36 4072.02 3341.81 3386.33 3357.70 3329.78 432.09 3.12 5962434.89 600142.76 N 70.30677557 W 149.18866893 5788.93 62.03 12.33 4034.47 4117.13 3425.16 3469.69 3440.77 3411.26 449.66 1.01 5962516.59 600159.24 N 70.30699816 W 149.18852660 5883.11 63.12 13.16 4077.85 4160.51 3508.75 3553.28 3524.02 3492.80 468.10 1.40 5962598.35 600176.60 N 70.30722090 W 149.18837714 5978.18 65.38 15.79 4119.16 4201.82 3594.33 3638.90 3609.04 3575.69 489.52 3.44 5962681.51 600196.91 N 70.30744735 W 149.18820359 6074.38 64.41 13.22 4159.98 4242.64 3681.40 3726.01 3695.56 3660.01 511.34 2.62 5962766.11 600217.61 N 70.30767771 W 149.18802676 6169.64. 61.67 10.18 4203.17 4285.83 3766.27 3810.91 3780.26 3743.13 528.58 4.04 5962849.44 600233.75 N 70.30790477 W 149.18788704 6264.51 63.26 11.85 4247.03 4329.69 3850.33 3895.03 3864.27 3825.69 544.66 2.29 5962932.21 600248.73 N 70.30813033 W 149.18775672 6358.68 62.32 12.35 4290.09 4372.75 3934.07 3978.77 3947.82 3907.58 562.22 1.10 5963014.31 600265.19 N 70.30835404 W 149.18761447 6451.69 61.69 13.02 4333.74 4416.40 4016.20 4060.90 4029.70 3987.70 580.25 0.93 5963094.66 600282.16 N 70.30857292 W 149.18746833 6547.92 59.61 13.64 4380.91 4463.57 4100.07 4144.77 4113.25 4069.31 599.58 2.23 5963176.51 600300.41 N 70.30879588 W 149.18 6642.33 60.22 14.73 4428.24 4510.90 4181.74 4226.46 4194.53 4148.51 619.60 1.19 5963255.96 600319.37 N 70.30901223 W 149.18 6737.81 59.72 15.50 4476.02 4558.68 4264.34 4309.13 4276.65 4228.31 641.16 0.87 5963336.04 600339.86 N 70.30923024 W 149.18697472 6832.79 59.54 17.46 4524.04 4606.70 4346.13 4391.07 4357.84 4306.89 664.40 1.79 5963414.91 600362.06 N 70.30944490 W 149.18678635 6924.10 59.55 18.31 4570.33 4652.99 4424.55 4469.78 4435.57 4381.80 688.57 0.80 5963490.12 600385.23 N 70.30964953 W 149.18659046 7020.89 61.47 16.81 4617.97 4700.63 4508.52 4554.03 4518.88 4462.12 713.98 2.40 5963570.77 600409.57 N 70.30986895 W 149.18638456 7114.87 60.46 14.18 4663.59 4746.25 4590.60 4636.19 4600.53 4541.29 735.94 2.67 5963650.21 600430.47 N 70.31008523 W 149.18620659 7208.65 60.49 12.28 4709.81 4792.47 4672.20 4717.79 4681.93 4620.72 754.61 1.76 5963729.88 600448.09 N 70.31030222 W 149.18605523 7303.83 61.21 10.57 4756.17 4838.83 4755.29 4800.91 4764.99 4702.19 771.07 1.74 5963811.55 600463.46 N 70.31052480 W 149.18592180 7398.64 63.68 10.67 4800.03 4882.69 4839.26 4884.96 4849.02 4784.80 786.56 2.61 5963894.35 600477.86 N 70.31075048 W 149.18579622 7493.61 63.73 11.37 4842.10 4924.76 4924.36 4970.11 4934.12 4868.37 802.84 0.66 5963978.13 600493.02 N 70.31097878 W 149.18566428 7588.33 62.76 12.04 4884.74 4967.40 5008.91 5054.68 5018.63 4951.19 819.99 1.20 5964061.16 600509.07 N 70.31120503 W 149.18552520 7683.75 63.29 12.29 4928.02 5010.68 5093.94 5139.72 5103.57 5034.32 837.91 0.60 5964144.51 600525.89 N 70.31143213 W 149.18537992 7778.27 62.94 11.82 4970.77 5053.43 5178.24 5224.03 5187.79 5116.76 855.52 0.58 5964227.17 600542.40 N 70.31165735 W 149.18523718 7873.35 62.31 11.15 5014.48 5097.14 5262.64 5308.46 5272.17 5199.50 872.33 0.91 5964310.12 600558.11 N 70.31188339 W 149.18510088 7966.51. 62.24 11.24 5057.83 5140.49 5345.07 5390.92 5354.60 5280.40 888.34 0.11 5964391.22 600573.04 N 70.31210438 W 149.18497107 8062.07 61.88 10.92 5102.60 5185.26 5429.44 5475.34 5438.99 5363.25 904.57 0.48 5964474.26 600588.16 N 70.31233071 W 149.18483953 8155.82 61.89 11.13 5146.78 5229.44 5512.08 5558.03 5521.66 5444.41 920.38 0.20 5964555.62 600602.90 N 70.31255243 W 149.18471131 8249.23 61.34 10.98 5191.19 5273.85 5594.21 5640.21 5603.81 5525.06 936.14 0.61 5964636.47 600617.58 N 70.31277277 W 149.18 8345.00 61.72 11.31 5236.84 5319.50 5678.36 5724.40 5687.97 5607.66 952.41 0.50 5964719.27 600632.76 4 N 70.31299842 W 149.1 8438.06 61.42 11.64 5281.14 5363.80 5760.17 5806.24 5769.76 5687.86 968.69 0.45 5964799.67 600647.97 N 70.31321752 W 149.18431959 8534.36 61.83 11.88 5326.91 5409.57 5844.88 5890.97 5854.44 5770.81 985.96 0.48 5964882.84 600664.13 N 70.31344413 W 149.18417956 8629.66 61.44 12.94 5372.19 5454.85 5928.73 5974.82 5938.20 5852.71 1003.98 1.06 5964964.96 600681.06 N 70.31366786 W 149.18403345 8724.79 61.96 13.52 5417.29 5499.95 6012.49 6058.58 6021.81 5934.25 1023.15 0.77 5965046.74 600699.15 N 70.31389060 W 149.18387802 8819.45 61.59 14.09 5462.05 5544.71 6095.88 6141.99 6105.01 6015.24 1043.05 0.66 5965127.98 600717.97 N 70.31411186 W 149.18371666 8913.95 61.65 15.14 5506.97 5589.63 6178.99 6225.13 6187.86 6095.69 1064.03 0.98 5965208.70 600737.88 N 70.31433164 W 149.18354656 9008.33 61.63 16.22 5551.80 5634.46 6261.95 6308.18 6270.50 6175.65 1086.48 1.01 5965288.94 600759.26 N 70.31455007 W 149.18336457 9091.91 61.45 16.52 5591.63 5674.29 6335.30 6381.66 6343.52 6246.15 1107.19 0.38 5965359.70 600779.03 N 70.31474267 W 149.18319667 9197.49 61.89 16.04 5641.74 5724.40 6428.08 6474.59 6435.92 6335.36 1133.24 0.58 5965449.24 600803.89 N 70.31498636 W 149.18298544 9290.99 60.56 14.39 5686.75 5769.41 6509.96 6556.55 6517.55 6414.44 1154.75 2.10 5965528.59 600824.35 N 70.31520238 W 149.18281099 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-19~Z-19~Z-19A~Z-19A current Generated 9/11/2006 1:20 PM Page 5 of 7 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Fasting Latitude Longkude Depth Section Departure ft d d k ft ft k ft ft k d 1100 k ftUS ftUS y3C4. / / ~~.~0 7 L.~3 9480.53 51.27 10.24 9574.07 47.73 8.56 9668.82 47.65 8.43 9764.10 44.23 9.78 9857.92 45.08 10.11 9953.60 44.30 9.78 10048.36 42.76 10.08 10143.36 35.53 10.58 10238.66 28.12 10.80 10331.29 22.72 8.50 10428.62 22.12 7.97 10522.20 20.96 8.19 10617.52 18.00 9.30 10709.51 18.10 11.12 10808.14 18.33 13.76 10902.48 18.27 16.53 10995.90 18.33 19.50 11090.18 18.21 21.61 11185.44 18.91 21.57 11278.90 19.44 15.06 11372.52 19.72 8.26 11467.17 19.92 4.36 11564.06 19.19 5.29 11657.17 20.09 8.02 11751.29 19.23 8.00 11845.99 19.59 10.94 11941.34 18.91 11.52 12034.54 18.87 13.06 12129.68 19.16 15.30 12223.95 19.12 17.72 12321.08 18.66 17.08 12414.41 18.30 17.10 12510.44 18.16 18.53 12568.45 18.43 20.48 12704.68 18.14 13.23 12727.38 17.80 12.39 12824.18 16.89 10.65 12919.79 16.84 12.69 13010.04 16.46 12.95 Last MWD+IFR+MS 13070.19 15.80 8.84 TD Proj - 13120.00 15.80 8.84 .7/JO.JJ .701.7.V i 5793.43 5876.09 5854.17 5936.83 5917.95 6000.61 5984.20 6066.86 6050.94 6133.60 6118.96 6201.62 6187.66 6270.32 6261.29 6343.95 6342.20 6424.86 6425.84 6508.50 6515.81 6598.47 6602.85 6685.51 6692.71 6775.37 6780.17 6862.83 6873.86 6956.52 6963.43 7046.09 7052.13 7134.79 7141.66 7224.32 7231.96 7314.62 7320.25 7402.91 7408.46 7491.12 7497.51 7580.17 7588.81 7671.47 7676.51 7759.17 7765.14 7847.80 7854.46 7937.12 7944.48 8027.14 8032.66 8115.32 8122.61 8205.27 8211.67 8294.33 7846.95 8303.57 8386.23 7878.30 8392.08 8474.74 7907.81 8483.29 8565.95 7937.74 8538.37 8621.03 7955.83 8667.74 8750.40 7998.39 8689.33 8771.99 8005.39 8781.73 8864.39 8034.24 8873.23 8955.89 8061.97 8959.70 9042.36 8087.83 9017.48 9100.14 8104.52 9065.41 9148.07 ~ 8118.04 vao~.a 1 6666.34 6737.32 6807.17 6875.47 6941.32 7008.51 7073.68 7133.55 7183.73 7223.41 7260.40 7294.63 7326.33 7354.79 7385.61 7415.21 7444.42 7473.71 7503.69 7534.21 7565.52 7597.38 7629.48 7660.58 7692.13 7723.53 7754.95 7785.12 7816.11 VVJV.IV VJJV. JI V~J 1. I IIJ.JV v. ~1. I 1• I .VI r ~~ ~ 6712.96 6673 .81 6567.13 1188.52 4.86 5965681.70 600856.08 N 70.31561951 W 149.18253717 6784.08 6744 .92 6637.28 1200.16 4.02 5965752.00 600866.79 N 70.31581116 W 149.18244273 6854.15 6814 .95 6706.58 1210.51 0.13 5965821.42 600876.22 N 70.31600048 W 149.18235875 6922.60 6883 .40 6774.18 1221.32 3.73 5965889.15 600886.13 N 70.31618514 W 149.18227105 6988.54 6949 .33 6839.13 1232.71 0.94 5965954.24 600896.66 N 70.31636257 W 149.18217866 7055.83 7016 .62 6905.41 1244.33 0.85 5966020.66 600907.40 N 70.31654363 W 149.18208438 7121.09 7081 .88 6969.69 1255.58 1.64 5966085.08 600917.79 N 70.31671924 W 149.18199310 7181.03 7141 .82 7028.65 1266.31 7.62 5966144.17 600927.74 N 70.31688032 W 149.18190608 7231.24 7192 .03 7078.00 1275.62 7.78 5966193.64 600936.39 N 70.31701514 W 149.18183060 7270.99 7231 .77 7117.17 1282.35 5.93 5966232.89 600942.60 N 70.31712213 W 149.18177592 7308.11 7268 .87 7153.91 1287.67 0.65 5966269.69 600947.43 N 70.31722249 W 149.1817 276 7342.47 7303 .20 7187.92 1292.50 1.24 5966303.76 600951.81 N 70.31731542 W 149.18 7374.25 7334 .98 7219.34 1297.31 3.13 5966335.24 600956.20 N 70.31740124 W 149.18 7402.75 7363 .47 7247.39 1302.36 0.62 5966363.35 600960.88 N 70.31747786 W 149.18161356 7433.57 7394 .27 7277.48 1309.01 0.87 5966393.53 600967.12 N 70.31756009 W 149.18155967 7463.19 7423 .78 7306.07 1316.74 0.92 5966422.21 600974.48 N 70.31763818 W 149.18149693 7492.52 7452 .83 7333.96 1325.81 1.00 5966450.21 600983.18 N 70.31771435 W 149.18142338 7522.07 7481 .91 7361.63 1336.19 0.71 5966478.01 600993.18 N 70.31778994 W 149.18133926 7552.39 7511 .64 7389.82 1347.34 0.73 5966506.35 601003.96 N 70.31786696 W 149.18124879 7583.06 7542 .00 7418.93 1356.95 2.36 5966535.58 601013.19 N 70.31794647 W 149.18117086 7614.40 7573 .32 7449.61 1363.27 2.45 5966566.34 601019.09 N 70.31803028 W 149.18111960 7646.48 7605 .31 7481.49 1366.79 1.41 5966598.26 601022.19 N 70.31811738 W 149.18109103 7678.91 7637 .59 7513.80 1369.52 0.82 5966630.60 601024.48 N 70.31820566 W 149.18106891 7710.20 7668 .81 7544.88 1373.16 1.38 5966661.72 601027.71 N 70.31829055 W 149.18103934 7741.87 7700 .45 7576.23 1377.57 0.91 5966693.13 601031.71 N 70.31837621 W 149.18100353 7773.33 7731 .91 7607.26 1382.75 1.10 5966724.23 601036.48 N 70.31846098 W 149.18096147 7804.77 7763 .34 7638.10 1388.87 0.74 5966755.14 601042.19 N 70.31854521 W 149.18091182 7834.94 7793 .50 7667.58 1395.30 0.54 5966784.70 601048.22 N 70.31862575 W 149.18085973 7865.93 7824 .42 7697.62 1402.89 0.83 5966814.84 601055.41 N 70.31870783 W 149.18079811 7896.84 7855 .14 7727.25 1411.67 0.84 5966844.58 601063.80 N 70.31878877 W 149.18 7928.28 7886 .35 7757.26 1421.08 0.52 5966874.70 601072.81 N 70.31887074 W 149.18 7957.87 7915 .73 7785.54 1429.77 0.39 5966903.09 601081.12 N 70.31894798 W 149.18058009 7987.91 7945 .52 7814.13 1438.96 0.49 5966931.81 601089.93 N 70.31902611 W 149.18050557 8006.12 7963 .50 7831.30 1445.04 1.15 5966949.05 601095.78 N 70.31907299 W 149.18045625 8048.81 8005 .90 7872.12 1457.43 1.68 5966990.03 601107.63 N 70.31918451 W 149.18035576 8055.81 8012 .89 7878.95 1458.99 1.88 5966996.87 601109.09 N 70.31920316 W 149.18034316 8084.67 8041 .74 7907.22 1464.76 1.08 5967025.22 601114.49 N 70.31928039 W 149.18029631 8112.40 8069 .47 7934.38 1470.37 0.62 5967052.45 601119.74 N 70.31935459 W 149.18025080 8138.26 8095 .31 7959.59 1476.10 0.43 5967077.73 601125.14 N 70.31942347 W 149.18020426 8154.96 8112 .01 7975.99 1479.27 2.19 5967094.17 601128.09 N 70.31946826 W 149.18017855 8168.53 8125 .57 7989.39 1481.36 0.00 - 5967107.60 601129.99. N 70.31950487 W 149.18016164 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-19~Z-19~Z-19A~Z-19A current Generated 9/11/2006 1:20 PM Page 6 of 7 Comments Measured Inclination Azimuth Sub-Sea ND TVp Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure R d d R R ft R R R R d 1100 R RUS RUS Survey Type: Definitive Survey NOTES: GCT-MS - (Schlumberger GCT multishot --GCT surveys in casing or open hole. GCT = "Gyro Continuous Tool". ) INC+TREND - (Inclinometer + known azi trend -Inclination only surveys in near-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. MWD + IFR + MS - (In-field referenced MWD with mult~tation analysis and correction applied In post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4296 FSL 2923 FEL S19 T11 N R12E UM 5959099.97 599754.94 BHL : 1725 FSL 1410 FEL S7 T11 N R12E UM 5967107.60 601129.99 • SurveyEditor Ver SP 2.1 Bid( doc40x_100) Z-19~Z-19~Z-19A~Z-19A current Generated 9/11/2006 1:20 PM Page 7 of 7 TREE = CiW 4-1 Jt 6" 5M WEtLHEA: D = FMC Gen 5 CSG HEAD = 11" 5M VV! 7" MANDREL HANGER & PACKOFF TBG SPOOL = 11" X i i"" SM TBG HANGER = t i" X 4-112" ADPFLA~lGE= ~~ 11"X4-7t16° ACTUATOR = BAKER KB. ELEV ~ _ 87' BF. ELEV -- ~ ~~~ 54.12' KOP = 784' Max Angle = t"st ~ 12438' .w~ _ .. Datum MD = 14040' .._..~ ®...,v,_._..... Minimum ID= 3.892" aG~ 220©' 4-112" HES X NIPPLE 7-5/8" CSG STUB 3225' HES 7-5/S" CIBP 3275' 4-1J2" TBG JET CUT 4000' PERFORATION SUMMARY REF LOG: '?'?? A NGLE AT TOP PERF: 17 @ 12804' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn-Sqz DATE 2-1(2" 6 12804 - 12854 O 11'17106 7-5/8" X 4-1/2" BKR SABL-3 PKR, ID = 3.99" 13461' TOP OF 5-1/2" LNR 13523' 7-518" CSG, 29.7#, ~ = 6.875" 13802' PBTD 14397' 5-1/2" LNR, 17#, 13-CR, .0232 bpf, 14478' ID = 4.892" I 3422' 1d-314" AS.S#, L-80, .0962 bpf, iD=9.950'. 4022' CALCULATED CEMENT TOP i 4442' 7" 26# TG11, .0383 bpf, ID = 6.276" 12384' 4-112" HES X NIPPLE; ID = 3.812" 12447' 7" x 4-1l2" BAKER S-3 PKR; ID = 3.88 12470' 4-1/2" HES X NIPPLE; ID = 3.812" 12491' 4-1/2" HES X NIPPLE; ID = 3.812" 12500' 7" x 4-1 /2" BKR FLEX LOCK LNR HNGR 12504' 4-112" 12.6# TGII L-80, .0152 bpf, ID = 3.958" 12643' 7" 26# BTC-M, .0383 bpf, ID = 6.276" 13031' PBTD 3118, 4-1/2" 12.6# IBT-M L-80, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/12106 STG ORIGINAL COMPLETION 09/13/06 LV Actual Completion 11/17/06 TEL/PAG PERFORATE PRUDHOE BAY UNfT WELL: Z-19Ai PERMfT No: 206-105 API No: 50-029-22251-01 SEC 19, T11N, R12E, 984' FNL & 3247' FEL BP Exploration (Alaska) JP JOINT IS 7-5/8", 29.7#, L-80 TC-II 2387' 4-1/2" HES X NIPPLE; ID = 3.812" ~Z-19A SCHLUMBERGER Survey report Client .................... Field ..................... Well ...................... API number ................ Engineer .................. Rig :...................... STATE :.................... ----- Survey calculation m Method for positions.....: Method for DLS............ BP Exploration (Alaska) Inc. Prudhoe Bay Z-19Ai 50-029-22251-01 I. Hernandez Nabors 7ES Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 54.12 ft KB above permanent.......: N/A Top Drive DF above permanent.......: 82.66 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft Azimuth from Vsect Origin to target: 12.97 degrees 10-Sep-2006 13:11:03 Page 1 of 5 Spud date ................. 22-Aug-2006 Last survey date.........; 10-Sep-06 Total accepted surveys...: 119 MD of first survey.......: 2410.56 ft MD of last survey........: 13120.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............: 21-Aug-2006 Magnetic field strength..: 57625.50 GAMA Magnetic dec (+E/W-).....: 24.01 degrees Magnetic dip .............: 80.86 degrees ----- MWD survey Reference Reference G ..............: Reference H ............... Reference Dip ............: Tolerance of G............ Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.68 meal 57625.50 GAMA 80.86 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.01 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.01 degrees (Total az corr = magnetic dec - grid conv) Survey Correction-Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 1 2410.56 43.08 354.64 2 2427.00 42.96 354.73 3 2456.76 41.27 354.73 4 2460.00 41.13 354.74 5 2552.63 37.13 354.92 6 2646.29 33.90 354.15 7 2740.88 32.29 353.86 8 2835.81 34.70 358.81 9 2931.03 36.87 1.85 10 3023.86 38.48 2.52 11 3118.17 41.08 4.58 12 3213.33 45.63 5.64 13 3307.21 49.00 6.65 14 3400.89 54.44 9.75 15 3496.76 60.22 12.48 16 3590.45 61.80 13.09 17 3686.27 62.30 14.02 18 3782.65 62.56 15.00 19 3875.58 63.31 14.66 20 3968.53 63.57 13.20 21 4065.93 63.25 13.61 22 4158.25 62.50 13.20 23 4253.36 61.85 12.99 24 4347.30 61.53 12.37 25 4443.10 61.46 12.40 26 4538.88 60.90 12.24 27 4632.77 60.74 12.50 28 4727.36 61.15 12.85 29 4821.50 60.50 12.82 30 4915.68 62.27 11.88 [(c)2006 IDEAL ID10 2C O1] Course length (ft) 0.00 16.44 29.76 3.24 92.63 93.66 94.59 94.93 95.22 92.83 94.31 95.16 93.88 93.68 95.87 93.69 95.82 96.38 92.93 92.95 97.40 92.32 95.11 93.94 95.80 95.78 93.89 94.59 94.14 94.18 TVD depth (ft) 2221.98 2234.00 2256.07 2258.51 2330.35 2406.58 2485.82 2564.99 2642.24 2715.71 2788.19 2857.36 2921.00 2979.02 3030.76 3076.17 3121.08 3165.69 3207.97 3249.53 3293.13 3335.22 3379.61 3424.16 3469.88 3516.06 3561.83 3607.77 3653.66 3698.76 10-Sep-2006 13:11:03 Vertical Displ section +N/S- (ft) (f t) 712.92 735.11 723.57 746.28 742.53 766.15 744.55 768.28 800.09 826.48 851.71 880.64 900.55 932.00 950.73 984.25 1005.05 1039.91 1060.78 1096.60 1120.30 1156.81 1185.00 1221.86 1253.51 1290.46 1326.76 1363.19 1407.38 1442.32 1489.32 1522.24 1573.96 1604.52 1659.36 1687.23 1742.07 1767.23 1825.20 1847.92 1912.29 1932.65 1994.46 2012.57 2078.57 2094.50 2161.27 2175.18 2245.45 2257.41 2329.37 2339.39 2411.34 2419.47 2494.02 2500.14 2576.22 2580.28 2658.88 2661.04 Displ +E/W- (ft) -15.29 -16.33 -18.16 -18.36 -23.63 -28.79 -34.19 -37.46 -37.10 -34.93 -31.17 -25.32 -17.92 -7.37 8.24 26.38 46.22 67.63 88.81 108.82 129.01 148.06 167.12 185.27 203.33 221.24 238.80 256.94 275.20 292.88 Pa Total displ (ft) 735.27 746.46 766.37 768.49 826.82 881.11 932.63 984.96 1040.57 1097.15 1157.23 1222.12 1290.58 1363.21 1442.35 1522.47 1605.19 1688.59 1769.46 1851.12 1936.95 2018.01 2101.15 2183.06 2266.55 2349.83 2431.22 2513.30 2594.91 2677.11 3e 2 of At Azim (deg) 358.81 358.75 358.64 358.63 358.36 358.13 357.90 357.82 357.96 358.18 358.46 358.81 359.20 359.69 0.33 0.99 1.65 2.30 2.88 3.37 3.82 4.21 4.56 4.87 5.15 5.40 5.64 5.87 6.09 6.28 5 DLS Srvy (deg/ tool 100f) type 0.00 TIP 0.82 BP_GCT_MS 5.68 BP_INC+TRENL 4.33 BP_INC+TRENL 4.32 BP INC+TRENL 3.48 MWD+IFR+MS 1.71 MWD+IFR+MS 3.84 MWD+IFR+MS 2.95 MWD+IFR+MS 1.79 MWD+IFR+MS 3.09 MWD+IFR+MS 4.84 MWD+IFR+MS 3.68 MWD+IFR+MS 6.36 MWD+IFR+MS 6.49 MWD+IFR+MS 1.78 MWD+IFR+MS 1.00 MWD+IFR+MS 0.94 MWD+IFR+MS 0.87 MWD+IFR+MS 1.43 MWD+IFR+MS 0.50 MWD+IFR+MS 0.90 MWD+IFR+MS 0.71 MWD+IFR+MS 0.67 MWD+IFR+MS 0.08 MWD+IFR+MS 0.60 MWD+IFR+MS 0.30 MWD+IFR+MS 0.54 MWD+IFR+MS 0.69 MWD+IFR+MS 2.07 MWD+IFR+MS • • SCHLUMBERGER Survey Report 10-Sep-2006 13:11:03 Page 3 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (f t) (f t) (ft) (deg) 100f) type 31 5010.90 61.91 12.15 95.22 3743.34 2743.02 2743.34 310.39 2760.84 6.46 0.45 MWD+IFR+MS 32 5105.89 61.95 12.27 94.99 3788.03 2826.83 2825.26 328.12 2844.25 6.62 0.12 MWD+IFR+MS 33 5199.17 61.37 12.35 93.28 3832.31 2908.92 2905.47 345.62 2925.96 6.78 0.63 MWD+IFR+MS 34 5296.25 60.61 11.95 97.08 3879.39 2993.81 2988.47 363.49 3010.49 6.93 0.86 MWD+IFR+MS 35 5391.68 59.92 10.79 95.43 3926.73 3076.64 3069.71 379.83 3093.12 7.05 1.28 MWD+IFR+MS 36 5485.46 61.79 11.44 93.78 3972.40 3158.50 3150.07 395.62 3174.82 7.16 2.08 MWD+IFR+MS 37 5580.32 61.61 11.52 94.86 4017.37 3241.99 3231.92 412.25 3258.11 7.27 0.20 MWD+IFR+MS 38 5675.63 61.09 11.34 95.31 4063.07 3325.60 3313.90 428.82 3341.53 7.37 0.57 MWD+IFR+MS 39 5694.15 61.12 12.00 18.52 4072.02 3341.81 3329.78 432.10 3357.70 7.39 3.12 MWD+IFR+MS 40 5788.93 62.03 12.33 94.78 4117.13 3425.16 3411.26 449.67 3440.77 7.51 1.01 MWD+IFR+MS 41 5883.11 63.12 13.16 94.18 4160.51 3508.75 3492.80 468.11 3524.02 7.63 1.40 MWD+IFR+MS 42 5978.18 65.38 15.79 95.07 4201.82 3594.33 3575.69 489.53 3609.04 7.80 3.44 MWD+IFR+MS 43 6074.38 64.41 13.22 96.20 4242.64 3681.40 3660.01 511.35 3695.56 7.95 2.62 MWD+IFR+MS 44 6169.64 61.67 10.18 95.26 4285.83 3766.27 3743.13 528.59 3780.26 8.04 4.04 MWD+IFR+MS 45 6264.51 63.26 11.85 94.87 4329.69 3850.34 3825.69 544.67 3864.27 8.10 2.29 MWD+IFR+MS 46 6358.68 62.32 12.35 94.17 4372.75 3934.07 3907.58 562.23 3947.82 8.19 1.10 MWD+IFR+MS 47 6451.69 61.69 13.02 93.01 4416.40 4016.20 3987.70 580.26 4029.70 8.28 0.93 MWD+IFR+MS 48 6547.92 59.61 13.64 96.23 4463.57 4100.07 4069.31 599.59 4113.25 8.38 2.23 MWD+IFR+MS 49 6642.33 60.22 14.73 94.41 4510.90 4181.74 4148.51 619.61 4194.53 8.49 1.19 MWD+IFR+MS 50 6737.81 59.72 15.50 95.48 4558.68 4264.34 4228.31 641.17 4276.65 8.62 0.87 MWD+IFR+MS 51 6832.79 59.54 17.46 94.98 4606.70 4346.13 4306.89 664.41 4357.84 8.77 1.79 MWD+IFR+MS 52 6924.10 59.55 18.31 91.31 4652.98 4424.55 4381.80 688.58 4435.57 8.93 0.80 MWD+IFR+MS 53 7020.89 61.47 16.81 96.79 4700.63 4508.53 4462.12 713.99 4518.88 9.09 2.40 MWD+IFR+MS 54 7114.87 60.46 14.18 93.98 4746.25 4590.60 4541.28 735.95 4600.53 9.21 2.67 MWD+IFR+MS 55 7208.65 60.49 12.28 93.78 4792.47 4672.20 4620.72 754.62 4681.93 9.28 1.76 MWD+IFR+MS 56 7303.83 61.21 10.57 95.18 4838.83 4755.29 4702.19 771.08 4764.99 9.31 1.74 MWD+IFR+MS 57 7398.64 63.68 10.67 94.81 4882.69 4839.27 4784.80 786.57 4849.02 9.34 2.61 MWD+IFR+MS 58 7493.61 63.73 11.37 94.97 4924.76 4924.36 4868.37 802.85 4934.13 9.36 0.66 MWD+IFR+MS 59 7588.33 62.76 12.04 94.72 4967.40 5008.92 4951.19 820.00 5018.63 9.40 1.20 MWD+IFR+MS 60 7683.75 63.29 12.29 95.42 5010.68 5093.95 5034.32 837.93 5103.58 9.45 0.60 MWD+IFR+MS [(c)2 006 IDEAL ID10 2C O1] r SCHLUMBERGER Survey Report 10-Sep-2006 13:11:03 Page 4 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 61 7778.27 62.94 11.82 94.52 5053.43 5178.24 5116.76 855.53 5187.79 9.49 0.58 MWD+IFR+MS 62 7873.35 62.31 11.15 95.08 5097.14 5262.64 5199.50 872.35 5272.17 9.52 0.91 MWD+IFR+MS 63 7966.51 62.24 11.24 93.16 5140.48 5345.07 5280.40 888.36 5354.60 9.55 0.11 MWD+IFR+MS 64 8062.07 61.88 10.92 95.56 5185.26 5429.44 5363.25 904.58 5439.00 9.57 0.48 MWD+IFR+MS 65 8155.82 61.89 11.13 93.75 5229.44 5512.08 5444.41 920.39 5521.66 9.60 0.20 MWD+IFR+MS 66 8249.23 61.34 10.98 93.41 5273.85 5594.22 5525.06 936.15 5603.81 9.62 0.61 MWD+IFR+MS 67 8345.00 61.72 11.31 95.77 5319.50 5678.36 5607.66 952.42 5687.97 9.64 0.50 MWD+IFR+MS 68 8438.06 61.42 11.64 93.06 5363.80 5760.17 5687.86 968.70 5769.76 9.67 0.45 MWD+IFR+MS 69 8534.36 61.83 11.88 96.30 5409.57 5844.88 5770.81 985.97 5854.44 9.70 0.48 MWD+IFR+MS 70 8629.66 61.44 12.94 95.30 5454.85 5928.73 5852.71 1003.99 5938.20 9.73 1.06 MWD+IFR+MS 71 8724.79 61.96 13.52 95.13 5499.95 6012.49 5934.25 1023.16 6021.81 9.78 0.77 MWD+IFR+MS 72 8819.45 61.59 14.09 94.66 5544.71 6095.89 6015.24 1043.07 6105.01 9.84 0.66 MWD+IFR+MS 73 8913.95 61.65 15.14 94.50 5589.63 6178.99 6095.69 1064.04 6187.86 9.90 0.98 MWD+IFR+MS 74 9008.33 61.63 16.22 94.38 5634.46 6261.95 6175.65 1086.49 6270.50 9.98 1.01 MWD+IFR+MS 75 9091.91 61.45 16.52 83.58 5674.29 6335.30 6246.15 1107.20 6343.53 10.05 0.38 MWD+IFR+MS 76 9197.49 61.89 16.04 105.58 5724.40 6428.08 6335.36 1133.25 6435.92 10.14 0.58 MWD+IFR+MS 77 9290.99 60.56 14.39 93.50 5769.41 6509.96 6414.44 1154.76 6517.55 10.21 2.10 MWD+IFR+MS 78 9384.77 55.55 12.53 93.78 5819.01 6589.51 6491.79 1173.31 6596.97 10.24 5.60 MWD+IFR+MS 79 9480.53 51.27 10.24 95.76 5876.09 6666.34 6567.13 1188.53 6673.81 10.26 4.86 MWD+IFR+MS 80 9574.07 47.73 8.56 93.54 5936.83 6737.32 6637.28 1200.17 6744.92 10.25 4.02 MWD+IFR+MS 81 9668.82 47.65 8.43 94.75 6000.61 6807.17 6706.58 1210.52 6814.96 10.23 0.13 MWD+IFR+MS 82 9764.10 44.23 9.78 95.28 6066.86 6875.47 6774.18 1221.33 6883.40 10.22 3.73 MWD+IFR+MS 83 9857.92 45.08 10.11 93.82 6133.60 6941.32 6839.13 1232.72 6949.34 10.22 0.94 MWD+IFR+MS 84 9953.60 44.30 9.78 95.68 6201.62 7008.51 6905.40 1244.34 7016.62 10.21 0.85 MWD+IFR+MS 85 10048.36 42.76 10.08 94.76 6270.32 7073.68 6969.69 1255.59 7081.88 10.21 1.64 MWD+IFR+MS 86 10143.36 35.53 10.58 95.00 6343.95 7133.55 7028.65 1266.32 7141.82 10.21 7.62 MWD+IFR+MS 87 10238.66 28.12 10.80 95.30 6424.86 7183.73 7078.00 1275.63 7192.03 10.22 7.78 MWD+IFR+MS 88 10331.29 22.72 8.50 92.63 6508.50 7223.41 7117.17 1282.37 7231.77 10.21 5.93 MWD+IFR+MS 89 10428.62 22.12 7.97 97.33 6598.47 7260.40 7153.90 1287.68 7268.87 10.20 0.65 MWD+IFR+MS 90 10522.20 20.96 8.19 93.58 6685.51 7294.63 7187.92 1292.51 7303.20 10.19 1.24 MWD+IFR+MS [(c)2 006 IDEAL ID10 2C O1] SCHLLTMBERGER Survey Report 10-Sep-2006 13:11:03 Page 5 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (f t) (f t) (ft) (deg) 100f) type 91 10617.52 18.00 9.30 95.32 6775.37 7326.33 7219.34 1297.32 7334.98 10.19 3.13 MWD+IFR+MS 92 10709.51 18.10 11.12 91.99 6862.83 7354.79 7247.38 1302.37 7363.48 10.19 0.62 MWD+IFR+MS 93 10808.14 18.33 13.76 98.63 6956.52 7385.61 7277.48 1309.02 7394.27 10.20 0.87 MWD+IFR+MS 94 10902.48 18.27 16.53 94.34 7046.09 7415.21 7306.07 1316.75 7423.78 10.22 0.92 MWD+IFR+MS 95 10995.90 18.33 19.50 93.42 7134.79 7444.42 7333.95 1325.82 7452.83 10.25 1.00 MWD+IFR+MS 96 11090.18 18.21 21.61 94.28 7224.32 7473.71 7361.63 1336.20 7481.91 10.29 0.71 MWD+IFR+MS 97 11185.44 18.91 21.57 95.26 7314.62 7503.69 7389.82 1347.36 7511.64 10.33 0.73 MWD+IFR+MS 98 11278.90 19.44 15.06 93.46 7402.91 7534.21 7418.92 1356.97 7542.00 10.37 2.36 MWD+IFR+MS 99 11372.52 19.72 8.26 93.62 7491.12 7565.52 7449.60 1363.28 7573.32 10.37 2.45 MWD+IFR+MS 100 11467.17 19.92 4.36 94.65 7580.17 7597.38 7481.49 1366.80 7605.31 10.35 1.41 MWD+IFR+MS 101 11564.06 19.19 5.29 96.89 7671.47 7629.48 7513.80 1369.53 7637.59 10.33 0.82 MWD+IFR+MS 102 11657.17 20.09 8.02 93.11 7759.17 7660.58 7544.87 1373.17 7668.81 10.31 1.38 MWD+IFR+MS 103 11751.29 19.23 8.00 94.12 7847.80 7692.13 7576.23 1377.58 7700.46 10.31 0.91 MWD+IFR+MS 104 11845.99 19.59 10.94 94.70 7937.12 7723.53 7607.26 1382.76 7731.91 10.30 1.10 MWD+IFR+MS 105 11941.34 18.91 11.52 95.35 8027.14 7754.95 7638.10 1388.88 7763.34 10.31 0.74 MWD+IFR+MS 106 12034.54 18.87 13.06 93.20 8115.32 7785.12 7667.58 1395.31 7793.50 10.31 0.54 MWD+IFR+MS 107 12129.68 19.16 15.30 95.14 8205.27 7816.11 7697.62 1402.90 7824.42 10.33 0.83 MWD+IFR+MS 108 12223.95 19.12 17.72 94.27 8294.33 7846.95 7727.25 1411.68 7855.14 10.35 0.84 MWD+IFR+MS 109 12321.08 18.66 17.08 97.13 8386.23 7878.30 7757.26 1421.09 7886.35 10.38 0.52 MWD+IFR+MS 110 12414.41 18.30 17.10 93.33 8474.74 7907.81 7785.54 1429.78 7915.73 10.41 0.39 MWD+IFR+MS 111 12510.44 18.16 18.53 96.03 8565.95 7937.74 7814.13 1438.97 7945.52 10.43 0.49 MWD+IFR+MS 112 12568.45 18.43 20.48 58.01 8621.03 7955.83 7831.30 1445.05 7963.50 10.45 1.15 MWD+IFR+MS 113 12704.68 18.14 13.23 136.23 8750.40 7998.39 7872.12 1457.44 8005.90 10.49 1.68 MWD+IFR+MS 114 12727.38 17.80 12.39 22.70 8771.99 8005.40 7878.95 1459.00 8012.89 10.49 1.88 MWD+IFR+MS 115 12824.18 16.89 10.65 96.80 8864.39 8034.24 7907.22 1464.77 8041.74 10.49 1.08 MWD+IFR+MS 116 12919.79 16.84 12.69 95.61 8955.89 8061.97 7934.38 1470.38 8069.47 10.50 0.62 MWD+IFR+MS 117 13010.04 16.46 12.95 90.25 9042.36 8087.83 7959.59 1476.12 8095.31 10.51 0.43 MWD+IFR+MS 118 13070.19 15.80 8.84 60.15 9100.14 8104.52 7975.99 1479.28 8112.01 10.51 2.19 MWD+IFR+MS 119 13120.00 15.80 8.84 49.81 9148.07 8118.04 7989.39 1481.37 8125.57 10.50 O.OO PROJECTED TO TD [(c)2006 IDEAL ID10 2C O1] ~~ Seblumberger N0.3990 OCT ~- 6 2006 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell SUeet, Suite 400 ~ Alaska Oil 8: Gas Cons Comm ~~ ~ ~ ~ ~ C~i ~ Gas Ccns. Gcmmissior Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth ~TiC~1C(3l~8 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 10/12/06 Well Job # Lo Descri tion Date BL Color CD 12-29 11072867 INJECTION PROFILE 07/07/05 1 Z-19A 11212887 USIT 09112/06 1 MPH-14 11414383 LDL 09/21/06 1 Z-236 40010787 OH EDIT OF MWDILWD 09/04/04 2 1 P-27 40010459 OH EDIT OF MWD/LWD OSI21I04 2 1 Alaska Data & Consulting Services • • Petrotechnical Data Center LR2-1 2525 Gamben Street, Suite goo 900 E. Benson Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTN: Beth c~CT ~. 0 Z00~ Sc~~6erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~pCo -los- t~, ~~~,7 NO. 982 ~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Lo Descri tion Date BL Color CD 10/06/06 3-291J-32 11414759 SBHP SURVEY 09/04/06 1 L4-10 11285941 MEM PROD PROFILE 09/15/06 L2-21A 11421023 LDL 09/11/08 1 C-18A 11285934 MEM PROD & INJECTION 07/29/06 1 Y-24 NIA INJECTION PROFILE 09/03/05 1 Z-31 11414379 INJECTION PROFILE 09104/06 1 S-27B 11285940 MEM PROD PROFILE 09114/08 1 P-13 11414277 INJECTION PROFILE 09/03108 1 X-33 11421024 LDL 09112108 1 Z-19A N/A MDT 09/08106 1 A-17 11414381 USIT 09/07106 1 X-01 11422961 USIT 09/09/06 1 H-04A 11285942 SCMT 09/17/06 1 15-39A 11212888 SCMT 09/18/08 1 C-09A 11209808 MCNL 05/18/06 1 1 C-18A 11285934 MCNL 07129108 1 1 Z-14B 40013765 OH EDIT OF MWDILWD 07/31/06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • • • • Schlumberger Drilling 8 Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No Z-19Ai Installation/Rig Nabors 7ES Dispatched To: AOGCC Library Date Dispatched: 13-Sep-06 Dispatched By: I. Hernandez. Data No Of Prints No of Flo ies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division / ,1 ~~ ~ 2525 Gambell Street, Suite 400 (/ U Anchorage, Alaska 99501 nrose1Qslb.com Fax: 907-561-8317 LWD Log Delivery V1.1, 10-02-03 ~~~~3.~ SchlumgergEr ~E~ ~ 2 2006 NO.3952 Alaska Data & Consultin Services ~S;v3 ~!Iu ~cS CCiiS. ~;fi?IT11S5iGi~ 9 Company: State of Alaska 2525 Gambell Street, Suite 400 -rt ~rCf1G `~ Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 ~,~~~ / ~ ~.~~'' *' ~ j,~ /~ i Attn: Christine Mahnken ATTN: Beth ~ ( r 333 West 7th Ave, Suite 100 Anchorage, AK 99501 osn vos Field: Prudhoe Bay Well Job # Lo Descri tion Date BL Color CD X-16 10830812 RST/GRAVEL PACK 05131/04 1 C-24A 11209609 MEM PROD PROFILE 06/19106 1 V-02 40010525 OH EDIT OF MWD/LWD 06HOI04 2 1 N-07A 40010734 OH EDIT OF MWD/LWD 07/19/04 2 1 17-07A 40010150 OH EDIT OF MWDILWD 02/17/04 2 1 Alaska Data & Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Suite ao0 900 E. Ben50n Blvd. Anchorage, AK 99503-2838 Anchorage, Alaska 99508 ATTrv: Beth • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHOf?AGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-19Ai Sundry Number: 306-290 Dear Mr. Tirpack: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this,~~ay of August, 2006 Encl. ~d~ ~ ~ ~~~~"tl ~S ~` ?STAT~OF ALASKA~~~ ~ 2~/~~ ALA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 $ ~Z`S ~2.0 p(o ~1 ~~' ~ U~ 2 ~ 240 ~~a 0il & Gas r_,,.,w ., 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension AIICIiQra~B. IS ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Re-Enter O s Shutdown ~ 2. Operator Name: 4. Current Well Class: ~ 5. Permit To Drill. Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 206-105 3. Address: ^ Stratigraphic ®Service 6. API Number: ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22251-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU Z-19Ai Spacing Exception Required? ^ Yes ®No ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 047450 Plan 82.62' Prudhoe Bay Field / Prudhoe Bay Pool t2. PRESENT-WELL. CONDITION St1M MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14480 9109 3275 2802 3275 None Casin Len th Size MD TVD Burst Colla se Structural n uctor 11 20" 110' 110' Surface 3022' 10-3/4" 3022' 2638' 5210 2480 Intermediate 13802' 7-5l8" 13802' 8745' Production Liner 955' 5-1l2" 13523' - 14478' 8577' - 9108' 7740 6280 Perforation Depth MD (ft): Perforation Depth lVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Kill String: 4-1/2", 12.6# L-80 2520' Packers and SSSV Type: Below CIBP at 3275: 7-5/8" x 4-1/2" Baker 'BABE-3' Packers and SSSV MD (ft): 13461' packer 13. Attachments: 14. Well Class after proposed work: ~ ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: Augus 16, 006 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Dat ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Gagliardi, 564-5251 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Signature ,~ ~ Phone 564-4166 Date ~~~~ Terrie Hubble, 564-4628 .Commission Use Onl Sundry Number: ~ _ _ ,- Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity dBOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~ t' ~ O ~ F ~ `C" n n ~ S o . ~" l= T~ ~ Wl'~i~/l.~ ~~, ~ ~l~ ~ ~ ~l./~r I"Q ~~7L~dIS D~4, AuGI ~ ~ [~~6 Subsequent Form Required: ~ ~ - ~„p "j per,,,,, ,r, [Q ~~ , '"~~~~t~ APPROVED BY o6 ~ ~ ~ A roved B COMMISSIONER THE COMMISSION Date /on Form 10-403 Revised 06/2006 ~,/ `'~` / ~~~ ~ n i ~ ~ ~Srubmi~ln Duplicate Page 1 of 1 Hubble, Terrie L From: Gagliardi, Shane T Sent: Wednesday, August 23, 2006 7:25 AM To: Hubble, Terrie L Subject: RE: Z-19A Re-Enter Ops Shutdown Attachments: Z-19Ai Ops Shut Down.ZlP; Z-19Ai Proposed.ZlP Terrie, Drilling operations will resume following the completion of necessary rig maintenance, pending the availability of equipment due to the field wide operations. I have also included the currrent and proposed schematics. Thanks, Shane Shane Gagliardi Operations Drilling Engineer 907-564-5251 (Office) 907-632-6789 (Cell) 8/23/2006 TREE = CNV 4-1 /16" SM WELLHEAD= FMC Gen 5 CSG HEAD= 11" SM W/ T MANDREL HANGER i3< PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER= 11" X 4-1/2" ADP FLANGE= 11" X 4-1/16" ACTUATOR = BAKER KB. ELEV = 8T BF. ELEV = 54.12' KOP = 794' Max Angle _ 81 ~ 12438' Datum MD = 14040' O F~ SHUT D OW IVY-19A i SAFETY NOTES: Minimum ID = 3.812" ~ 2200' 41/2" HES X NIPPLE HES 7-5/8" CIBP 3275' 4-1/2" TBG JET CUT 4000' 7-5/8" X 4-1/2" BKR SABL-3 PKR, ID = 3.99" 13461' TOPOFS-1/2" LNR 13523' 7-518" CSG, 29.7#, ID = 6.875" 13802' PBTD 14397' 5-1/2" LNR, 17#, 13-CR 0.0232 bpf, 14478, ID = 4.892" l ~~~ 4~~ ~~ 3022' 10-3/4" 45.5#, L-B0, 0.0962 bpf, ID = 9.950" 13000' TOC INSIDE OF 4-1/2" TBG DATE REV BY COMMENTS DATE REV BY COMMENTS 06/12/06 STG ORIGINAL COMPLETION 08/08/06 STG OPS SHUT DOWN PRUDHOE BAY UNff WELL: Z-19Ai PERMfT No: 206-105 API No: 50-029-22251-01 SEC 19, T11 N, R12E, 984' FNL & 3247' FEL BP Exploration (Alaska) TREE = CMJ 4-1 /16" SM WELLHEA U = FMC Gen 5 CSG HEAD = 11" SM W/ 7" MANDREL HANGER & PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER= 11" X4-1/2" ADPFLANGE= 11"X4-1/16" ACTUATOR = BAKER KB. ELEV - 8T BF. ELEV = 54.12' KOP - 794' Max Angle = 61 ~ 12438' Datum MD = 14040' ~ O P O S E D Z 1~ I ~ SAFETY NOTES: Minimum ID = 3.812" ~ 2200' 41/2" HES X NIPPLE 7-5/8" CSG STUB 3225' HES 7-5/8" CIBP 3275' 4-1/2" TBG JET CUT 4000' 7-5/8" X 4-1/2" BKR SABL-3 PKR, ID = 3.99" 13461' TOPOFS-1 /2" LNR 13523' 7-518" CSG, 29.7#, ID = 6.875" 13802' PBTD 14397' 5-1/2" LNR, 17#, 13-CR, 0.0232 bpf, 14478' ID = 4.892" I )P JOINT IS 7-5l8", 29.7#, L-80 TC-II 2200' 4-1/2" HES X NIPPLE; ID = 3.812" 3022' 10-3/4" 45.5#, L-80, 0.0962 bpf, ID = 9.950" 3150' KOP FROM CEMENT PLUG 4022' CALCULATED CEMENT TOP 4522' 7" 26# TC-II, 0.0383 b f, ID = 6.276" 8~ 7' I$E~~fl~lfH~ ~fi171" 12383' 4-1/2" HES X NIPPLE; ID = 3.812" 12446' 7" x 4-1/2" BAKER S-3 PKR; ID = 3.88 12472' 4-1/2" HES X NIPPLE; ID = 3.812" 12493' 4-1l2" HES X NIPPLE; ID = 3.812" 12504' 7" x 4-1/2" BKR FLEX LOCK LNR HNGR 12504' 4-1/2" 12.6# TGII L-80, 0.0152 bpf, ID = 3.958" 12654' 7" 26# BTC-M, 0.0383 b f ID = 6.276" 12968' PBTD 13054' 4-1/2" 12.6# IBT-M L-80, 0.0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/12/06 STG ORIGINAL COMPLETION PRUDHOE BAY UNff WELL: Z-19Ai PERMfr No: 206-105 API No: 50-029-22251-01 SEC 19, T11 N, R12E, 984' FNL & 3247' FEL BP Exploration (Alaska) • ALASS-A OIL A1~TD G ~~ CO1~T5ERQATI01lT COMl~IISSIOIQ Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKl, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-19Ai Sundry Number: 306-278 Dear Mr. Tirpack: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~liflay of August, 2006 Encl. ~ ~~~ ~/l~,/0~6 G~ g, -a~ RE~1~l ~IZodG ,,~ p STATE OF ALASKA ~'0 v ALA OIL AND GAS CONSERVATION COM SION AUG 1 5 2006 .. ~-~ ~~~(/APPLICATION FOR SUNDRY APPROVAL Alaska Oil b Gas Cons. Comrasslon I ~b 20 AAC 25.280 -nrheraee 1. Type of Request: ^ Abandon ^ Suspend ®Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well _, . ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory, 206-105 /~ 3. Address: ^ Stratigraphic ®Service 6. API Number: j P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22251-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU Z-19Ai / Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 047450 Plan 82.62' Prudhoe Bay Field / Prudhoe Bay Pool '12 PRESENT WELL CONDITfON SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14480 9109 3275 2802 3275 None Casin Len th Size MD TVD Burst Colla se Structural Conductor 110' 20" 110' 110' Surface 3022' 10-3/4" 3022' 2638' 5210 2480 Intermediate 13802' 7-5/8" 13802' 8745' Production Liner 955' 5-1/2" 13523' - 14478' 8577' - 9108' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft None None Kill String: 4-1/2", 12.6# L-80 2520' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: f' ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: Aug st 6, 06 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: te: ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Gagliardi, 564-5251 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Signature _ ~~ Phone 564-4166 Date ~Jy ~ Terrie Hubble, 56a-4628 Commission Use Onl Sundry Number: ~ _ ~'7 Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: ~ ~~ V ~~ !~ ~ ~ "' 4~ 3 '~ uc ~C a ~ ~ s~~' ~ ul~''~L'~' S - APPROVED BY Q 11~ A roved B OMM TONER THE COMMISSION Date v Z' V Form 10-403 Revised 06/2006 ~ ~ ~ ~~(~~ 1 / vR~p~y{$ AFL AUG 2 5100& ~~ /~ubmit'In Duplicate tl\Y' ~/ Z-19Ai Plan forward • 20 ~ ! ©S Subject: Z-19Ai Plan forward From: "Peltier, Brandon" <Brandon.Peltier@bp.com> Date: Sun, 20 Aug 2006 21:00:55 -0800 To: winton_aubert@admin.state.ak.us CC: "NSU, ADW Drlg Rig 7 ES" <NSUADWDrIgRig7@bp.com>, "Tirpack, Robert B" <Robert.Tirpack@bp.com>, "Gagliardi, Shane T" <Shane.Gagliardi@bp.com> Winton We began milling the 7-5/8" casing at 2200' MD on Friday. We intended to mill/pull casing to 3225' MD (SV1) where we had made a cut in the 7-5/8" casing We milled to 2420' MD (2226' TVD) when it became evident that we had milled a hole in the 10-3/4" casing (shoe @ 3022' MD) and sidetracked. At this point we notified you (AOGCC). The plan forward is to spot cement on top of the EZSV (3275' MD) to isolate the cut, but keep the TOC below our KO point (2500-2600' MD). Then, the window will be dressed and it is planned to drill the intermediate hole section to the original planned point. Anew directional plan was completed and showed no close approach issues. A LOT was performed (on both the cut and sidetrack) to 11.8 ppg. With this LOT, our kick tolerance w/ a 10.2 ppg MW would be less than acceptable for the Kup formation (10 ppg pore pressure). We intend to weight up to a 10.8 prior drilling the Kuparuk, as this will give us an acceptable KT of 25 bbls. Please contact me if you have any questions. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon. Peltier@bp.com 1 of 1 8/21/2006 7:08 AM ,. • • Hubble, Terrie L From: Gagliardi, Shane T Sent: Thursday, August 10, 2006 3:41 PM To: Hubble, Terrie L Subject: RE: Operation Shutdowns Attachments: Z-19Ai Ops Shut Down.ZlP Terrie, Here is the schematic for the current condition of Z-19Ai. The well is currently "safed" out w/ 9.8 ppg brine. Current plan is to move off the well and conduct Annual Rig Maintenance. Page 1 of 1 The plan forward will be to return to the well, pull the kill string and resume operations where we left off. That wil! be to pick up the 9-5/8 csg cutter and make the 2 csg cuts and proceed as per program. If you need more than that, let me ~ know. Thanks, Shane Shane Gagliardi Operations Drilling Engineer 907-564-5251 (Office) 907-632-6789 (Cell) From: Hubble, Terrie L Sent: Monday, August 07, 2006 9:24 AM To: Allen, Kenneth W; Cutler, Jeff N; Gagliardi, Shane T; Kolstad, Scott R; Lasley, Barbara M; Marlyn, Matthew; Nadem, Mehrdad; Peltier, Brandon; Phillips, Ron; Rose, John G (FAIRWEATHER); Smith, Phil G (ASRC); Triolo, Mike T; Chan, Paul (PRA); McLellan, Bryan ); Reem, David C; West, Howard J; Cismoski, Doug A; Roach, Frank; Laughlin, Robert; Endacott, Mary S; Johnson, Mark 0; McLaughlin, Sean M; Sarber, Greg J; Worthington, Aras J Cc: Tirpack, Robert B; Wesley, Dave E; Crane, Lowell R; Stewman, Sondra D Subject: Operation Shutdowns Hi All, On those wells where we are shutting down operations, we will need to prepare the paperwork to submit to the State. I'll need a narrative of how the well stands, plan forward and a diagram. Thanks! Terrie 8/14/2006 TREE = CNV 4-1/16" SM 1MELLHEA D = FMC Gen 5 CSG HEAh= 11" 5M W! 7" MANDREL HANGER & PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER = 11" X 4-1/2" ADP FLANGE= 11"X4-1/16" ACTUATOR = KB. ELEV = BAKER _ 8~. BF. ELEV = 54.12' KOP = _ _ 794' Max Angle = 61 ~ 12438' Datum MD = 14040' O~ SHUT D O W IVY-19A i SAFETY NOTES: Minimum ID = 3.812" ~ 2200' 41/Z" HES X NIPPLE HES 7-5/8" CIBP 3275' 4-1/2" TBG JET CUT 4000' 7-5/8" X 4-1/2" BKR SABL-3 PKR, ID = 3.99" 13461' TOPOF5-1/2" LNR 13523' 7-5/8' CSG, 29.7#, ID = 6.875" 13802' PBTD 14397' 5-1/2" LNR, 17#, 13-CR, 0.0232 bpf, 14478' ID = 4.892" I ~~~ I:JOJ Y- UGC fV.LJlfl`~.7 3022' 10-3/4" 45.5#, L-80, 0.0962 bpf, ID = 9.950" 13000' TOC INSIDE OF 4-1/2" TBG DATE REV BY COMMENTS DATE REV BY COMMENTS 06/12/06 STG ORIGINAL COMPLETION 08/08/06 STG OPS SHUT DOWN PRUDHOE BAY UNfT WELL: Z-19Ai PERMIT No: 206-105 API No: 50-029-22251-01 SEC 19, T11 N, R12E, 984' FNL & 3247' FEL BP Exploration (Alaska) `'. ~ ? ~ a ,~~. ~ ~ ~ ? ~°'°t s '" ~ ~ ~ '~ ? ,~ FRANK H. MURKOWSK/, GOVERNOR r ~~~~ ~,~~~++ ~t~~ /~~~ ~~~~rr t~ tsLt>•a7~A OIL t>•isL ti~-7 333 W. T" AVENUE, SUITE 100 COI~TSERQA'1`IO1~T COMAIISSIOI~T `, ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-19Ai BP Exploration (Alaska) Inc. Permit No: 206-1 OS Surface Location: 984' FNL, 2031' FWL, SEC. 19, T11N, R12E, UM Bottomhole Location: 1730' FSL, 3515' FWL, SEC. 07, Tl 1N, R12E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907)-3607 (pager). Chairman DATED this!( day of July, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w J o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~~ PERMIT TO DRILL 20 AAC 25.005 ktC~/4- ~ (zcc~ (Zo o ~o ~~IVC ` ,~i..lh 1 ~ 200fi 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is ~~r„„o ose for: ^ Coalbed MethaTf~~f~@ Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU Z-19Ai 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13054 TVD 9103 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 984' FNL 2031' FWL 19 T11 SEC 7. Property Designation: ADL 047450 Pool , , . , N, R12E, UM Top of Productive Horizon: 1648' FSL, 3499' FWL, SEC. 07, T11 N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 8, 2006 Total Depth: 1730' FSL, 3515' FWL, SEC. 07, T11 N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10,800' 4b. Location of Well (State Base Plane Coordinates): Surface: x-599755 y-5959100 Zone-ASP4 10. KB Elevation Plan (Height above GL): 82,62 feet 15. Distance to Nearest Well Within Pool: 1,640' 16. Deviated Wells: Kickoff Depth: 3150 feet Maximum Hole An le: 60 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3600 Surface: 2745 18. Casin Pro ram: S ecifi lio ns To - Settin ' De th -Bo ttom Quanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 9-7/8" 7" 26# L-80 BTC-M 8132' 4522' 3439' 12654' 8723' See Below 9-7/8" 7" 26# L-80 TC-II 4522' Surface Surface 4522' 3439' 528 sx LiteCrete 1515 sx Class'G' 6-3/4" 4-1/2" 12.6# L-80 IBT-M 55 ' 125 4' 8581' 1 054' 9103' 2 sx Class'G' 19. PRESE NT WELL CONDITION SUMMARY (To,be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 14480 Total Depth TVD (ft): Plugs (measured): 9109 None Effective Depth MD (ft): 14397 Effective Depth TVD (ft): 9068 Junk (measured): None asing Length', Size° ement Voirame MD TVD Conductor /Structural 110' 20" 110' 110' Surface 3022' 10-3/4" 1350 sx AS III 350 sx Class 'G' 3022' 2638' Intermediate 13802' 7-5/8" 2569 sx Class 'G' 13802' 8745' Production Liner 955' 5-1/2" 210 sx Class'G' 13523' - 14478' 8577' - 9108' Perforation Depth MD (ft): 14090' - 14315' Perforation Depth TVD (ft): 8915' - 9028' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Shane Gagliardi, 564-5251 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4166 Date %~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: API Number: 50-029-22251-01-00 Permit App oval Date: 7' See cover letter for other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No ~ ~ 5-~- ~ ~ ~ ~' '~O t~000 ~ 1 i HZS Measures: `Yes ^ No irect' nal Survey Req'd: ,Yes ^ No Other: / t~t.L ~ I`~ L l t Ce Wt.P.rti~ ~ ~l~ t~ ~ Cj ` APPROVED BY THE COMMISSION Date (/ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ `~ i ~ ~/ ~ ~ Submit In Duplicate -___ {~~~fi V~l • Well Name: Z-19Ai Planned Well Summary Well Z-19A1 Well Type Slant Sidetrack Target Ivishak Z4 Injector Ob'ective AFE Number: API Number: 50-029-22251-01 Surface Northin Eastin Offsets TRS Location 5,959,099.97 599,754.94 984' FNL / 2,031' FWL 11 N, 12 E, 19 Target Northin Eastin Offsets TRS Location .5,967,030.00 601,120.00 1648' FSL / 1,421' FEL 11 N, 12 E, 7 Bottom Northin Eastin Offsets TRS Location 5,967,112.00 601,135.00 1,730' FSL / 1,405' FEL 11 N, 12 E, 7 Planned KOP: 3,150' and / 2,719' tvd Planned TD: 13,054' and / 9,103' tvd Ri Nabor ES .- CBE: 54.12' RTE: 82.62' Planned S ud Date: 08/8/2006 Planned O eratin Da s: 20.8 da s Directional Program i A roved Well Ian: W 04b Kick Off oint: 3,150' and / 2,719' tvd Maximum Hole Inclination: 60.3° from -3,628' to 9,437' in the tanned 9-%e" intermediate section. Proximity Issues: There are no close approach issues. All surrounding wells pass major risk criteria. Survey Program: Standard MWD with IIFR / Cas ra. Nearest Well within ool: 1,640' SE of Z-30A toe and 1 60 ' W of Z-13A heel. Nearest Pro ert Line 10,800' to the nearest PBU ert line. ~~~ Rd ©~~ ~ zo4~ ~ ll7o~i,~ ~-r~~- ~~~ sE. 1-~~-~z ~~,~- ~~ Z-19Ai Sidetrack Page 1 • Logging Program Hole Section: Required Sensors /Service 9-%e" intermediate: Real time MWD Dir/GR/Res/PWD/DWOB/DTORQ and recorded AZI Den/Neu throu hout the interval 6-3/a" roduction: Real time MWD Dir/GR/Res/AIM and recorded Den/Neu throu hout the interval Cased Hole: USIT in the 7 5/e" intermediate casing in de-completion phase prior to cut and pull USIT in the 7" new intermediate ost de-com letion O en Hole: None tanned Mud Program Hole Section / o eration: Mill section in the 9 %8" casin to 3,225'. T e Densit Viscosit PV YP MBT API FL H LSND 9.6 50 - 60 10 -18 70 - 90 N/C < 6.0 9 -10 Hole Section / o eration: Drillin 9'/8" Int to above HRZ 3,150' -10,258' . T e Densit Viscosit PV YP MBT API FL H LSND 9.6-9.7 35-50 10-18 18-22 <15 4-6 9-10 Hole Section / o eration: Drillin 9-'/e" intermediate HRZ to To Sa River. T e Densit Viscosit PV YP MBT API FL H LSND 10.0 10.2 35-50 12-20 18-22 <18 4-6 9-10 ~~' Hole Section / o eration: Drillin 6-3/a" roduction interval. T e Densit LSRV PV YP MBT API FL H Flo-ProSF 8.4 - 8.5 > 20,000 8 -12 22 - 28 < 3 6 - 8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. ~ Grade Connection Length Top and / tvd Bottom and / tvd 9'/8" 7" 26.0# L-80 BTC-M 8,132' 4522' / 3,439' 12,654' / 8,723' 9 '/8" 7" 26.0# L-80 TC-I I 4,522' Surface 4,522' / 3,439' 6-3/a" 4 ~h" 12.6# L-80 IBT-M 550' 12,504' / 8,581' 13,054' / 9,103' Tubin 4'/z" 12.6# L-80 TC-II 12,504' Surface 12,504' / 8,581' Z-19Ai Sidetrack Page 2 • Cementing Program Casin Strin 7", 26.0#, L-80, BTC-M / TC-II Intermediate Casin Stage 1 Slurry Design Basis: Lead slurry. 1,794' of 7" x 9-%8" annulus with 40% excess. Lead TOC to 8,560' and (HES ES Cementer). Tail slurry. 2,300' of 7" x 9 '/8" annulus with 40% excess, plus -86' of 7", 26.0# shoe tract. Tail TOC to --10,354' and to cover Ku aruk . Pre-Flush: None tanned S acer Fluid: 100.0 bbls MudPUSH II at 11.0 Slur T e 12.5 LiteCRETE St 1 Mix method Mix on the FI age L d Sl BHST /BHCT 225° F / 157° F ea urry: Thickenin time 5 hrs 02 min Slur Volume 115.5 bbl / 649 cf / 28 sx LiteCRETE, 12.5 .2 cf/sk. Slur T e 15.8 Class `G' ur St 1 Mix method Mix on t he FI age T il Sl BHST /BHCT 225° F / 157° F urry: a Thickenin time 4 hrs 44 min Slurr Volume 155.0 bbl / 870 cf / 4 x Class `G', 15.8 ~ 1.1 f/sk. Stage 2 Slurry Design Basis: Lead slurry. 2,128' of 7" x 9-%8" annu with 40% excess. Lea , OC to 4,022' and (1,000' from surface shoe and cover UG3). Tail slurry. 2,410' of 7" x 9-'/8" annulus with 40% excess. Tail TOC to 6,150' and to cover Schrader . Pre-Flush: None tanned S acer Fluid: 100.0 bbls MudPUSH II at 10.5 Slur T e 11.0 LiteCRETE St Mix method Mix on the FI age 2 L d Sl BHST /BHCT 160° F / 114° F ea urry: Thickenin time TBD hrs TBD min Slurr Volume 140.4 bbl / 788 cf / 23 sx LiteCRETE, 11.0 3.3 f/sk. Slur T e 15.8 Class `G' i r slur St 2 Mix method Mix on the FI age T il Sl BHST /BHCT 160° F / 114° F urry: a Thickenin time 4 hrs 02 min Slur Volume 159.0 bbl / 893 cf / 66 x Class `G', 15.8 .17 f/sk. Casin Strin 4-ih", 12.6#, L-80, IBT-M Production liner Slurry Design Basis: Lead slurry. None planned. Tail slurry. 400' of 4-'h" x 6-3/a" annulus with 40% excess, plus 150' of 4-'/z" x 7 liner lap, plus 200 of 4 drill pipe x 7 annulus, plus ~86 of 4-/z , 12.6#, shoe tract. Tail TOC to 12,504' md. Pre-Flush: None tanned S acer Fluid: 20.0 bbls MudPUSH II at 10.0 Lead Slur Slurry Tye None tanned Slurr T e 15.8 Class `G' liner slur with `GASBLOK' additive Mix method Batch mix Tail Slurry: BHST /BHCT 230° F / 163° F Thickenin time 7 hrs 20 min ~, Slurry Volume 22.4 bbl / 126 c / 8 x Class `G', 15.8 ppg; 1.53 /sk. ~.;. ~~ Z-19Ai Sidetrack Page 3 • Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 10-s/a" casin Cement lu to surface 30 min recorded 2,800 si surface 10-3/a" Surface Shoe 20' new formation be and window LOT 12.9 EMW 7" drillin liner Float a ui ment to surface 30 min recorded 4,000 si surface 7" liner shoe 20' new formation be and shoe FIT 10.0 EMW 4-'/z" roduction liner Float a ui ment to surface 30 min recorded 4,000 si surface Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: Well Interval: 9-%a' intermediate interval Maximum antici ated BHP: 3,400 si at 6,550' sstvd. Maximum surface ressure: 2 SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: 1.4 bls with 12.9 EMW LOT Planned BOPE test pressure: s : 250psi low / 4,000psi high ; Annular : 250psi low / 2,500psi high 7 da test c cle RWO hase ; 14 da test c cle Drillin hase BOPE configuration for 7" intermediate casin Annular, 7" pipe rams and blind/shear rams. Well Interval: 6-3/a" roduction interval Maximum antici ated BHP: 3,600 si at 9,020' sstvd. Maximum surface ressure: 2,700_ ~ SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: finit with 10.0 EMW FIT. Planned BOPE test pressure: s : 250psi low / 4,000psi high ; Annular : 250psi low / 2,500psi high. 14 da test c cle Drillin hase Planned com letion fluid: 8.4 seawater / 7.1 Diesel BOPE and drilling fluid system schematics are currently on file with the AOGCC. DISpOS81 Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j ection. All Class I wastes are to be hauled to Pad 3 for dis osal. for in Z-19Ai Sidetrack Page 4 • Geologic Prognosis Est. Est. Pore Est Est Pore Formation Formation Formation Uncertainty . . Comments Tops Tops press. Press. (MD)(P48) (TVDss) (feet) (Psi) (ppg EMW) SV3 2150 50 ft. 989 8.8 SV2 2335 50 ft. 1074 8.8 KOP 2636 KOP SV1 2650 50 ft. 1219 8.8 UG4 2945 50 ft. 1355 8.8 UG4A 3803 3000 50 ft. 1380 g.g Calculated TOC ~ 4,022' and UG3 4449 3320 50 ft. 1527 8.8 UGi 5579 3880 50 ft. 1785 8.8 Ma 6185 4180 50 ft. 1923 8.8 Mb1 6306 4240 50 ft. 1950 8.8 Mb2 6397 4285 50 ft. 1971 8.8 Mc 6528 4350 50 ft. 2001 8.8 Na 6689 4430 50 ft. 2038 8.8 Nb 6740 4455 50 ft. 2049 8.8 Nc 6841 4505 50 ft. 2072 8.8 OA 7073 4620 50 ft. 2125 8.8 Must have inter zonal cement 7204 isolation in O sands OBa 4685 50 ft. 2155 8.8 OBb 7285 4725 50 ft. 2174 8.8 OBc 7396 4780 50 ft. 2199 8.8 OBd 7517 4840 50 ft. 2226 8.8 OBe 7648 4905 50 ft. 2256 8.8 OBf 7740 4950 50 ft. 2277 8.8 OBf Base 7850 5005 50 ft. 2302 8.8 CM2 8556 5355 50 ft. 2463 g,g Stage Tool ~ 8,560' and Fault 1 9071 5610 100 ft. CM1 9483 5815 50 ft. 2675 8.8 THRZ 10258 6375 50 ft. TKLB 10407 6510 50 ft. Must have good cement across K 10444 uparuk Fina. K-1 6545 50 ft. TKD 10450 6550 50 ft. 3400 10.0 LCU 10492 6590 50 ft. TMLV 10872 6950 50 ft. TKNG 10304 7360 50 ft. Fault 2 11567 7610 100 ft. TJF 11683 7720 50 ft. TJE 11926 7950 50 ft. TJ D 12158 8170 50 ft. TJC 12432 8430 50 ft. TJ B 12548 8540 50 ft. TJA 12590 8580 50 ft. TSGR 12653 8640 50 ft. 7" Casing Set Depth TSHU 12685 8670 50 ft. 3491 7.7 ~©, 2 Z-19Ai Sidetrack Page 5 • Est. Est. Est Pore Est Pore Formation Formation Formation Uncertainty . . Comments To s To s Press. Press. (MD) (TVDss) (feet) (Psi) (ppg EMW) TEIL 12780 8760 50 ft. 3522 7.7 TSAD 12790 8770 50 ft. 3526 7.7 OGOC 12801 8780 50 ft. 3529 7.7 45N 12838 8815 50 ft. 3541 7.7 44N 12864 8840 50 ft. 3550 7.7 43N 12890 8865 50 ft. 3559 7.7 42N 12911 8885 50 ft. 3566 7.7 41 N 12959 8930 50 ft. 3582 7.7 31 N 12991 gg60 50 ft. 3592 7.7 OOWC 12991 8960 50 ft. 3592 7.7 TD 13054 8020 50 ft. 3613 7.7 TD Criteria TD Criteria: I TD well at sufficient depth to get full MWD logs across OWC according to the directional olan (P4B). Fault Prognosis Fault Formation Encountered MD Intersect TVDss Intersect Estimated Throw Direction of Throw Uncertainty Fault #1 U er Colville 9,070' -5,610' 180' D to SW +/- 100' Fault #2 U er Kin ak 11,570' -7,610' 100' D to NE +/- 100' Fault #3 Lower Kin ak 12,440' -8,435' ~10' D to S +/- 100' Operations Summary Pre-Rig Operations: 1. MIRU Schlumberger slickline. Pull TTP C 13,510' SLM. Take static BHP and Temp. 2. MIRU Schlumberger Cement. P&A perfs from 14,090' to 14,315' MD ELM w/ 25 bbls glass G cmt. Planned TOC 13,411', 50' and above existing SABL-3 pkr. 3. Bleed OA, IA and tubing pressures to zero. PPPOT-T and PPPOT-IC passed (12/10/05). Function all LDS, repair or replace as necessary. MIT the OA to 2,000 psi. MIT- T x IA to 3,000 psi after P&A cement has reached 2,000 psi compressive strength. 4. RU E-line. RIH and jet cut 4-'/z" tubing in the middle of the joint ~ 4,000'. 5. Circulate the well to SW. Freeze protect the IA and tubing with diesel to ~ 2,200' md. 6. Bleed all pressures to zero. Set BPV. Secure well. 7. Verify that the well house is removed and that the flow lines are disconnected. If necessary, level the pad. Rig Operations: 1. MIRU Nabors 7ES. 2. Pull BPV. Circulate out freeze protection and displace well to SW. 3. Monitor OA, IA and T for pressure. Verify well is dead. 4. Set TWC. Nipple down tree. Nipple up and test BOP. Pull TWC. Z-19Ai Sidetrack Page 6 • 5. RU spooling unit for dual encapsulated control lines. Pull 4-'h" tubing, control line, 27 rubber control line bands and 4 SS bands from pre-rig cut. 6. Install WB and pick-up 4" drill pipe in singles for a drift run in and out. 7. MIRU E-line. Run USIT from tubing stub to surface looking for casing leaks and evidence of down squeeze. Set CIBP at 3,275'. 8. Test CIBP to 3,500 psi. RIH w/work string to CIBP. CBU and spot a 5 bbl 18 ppg pill. 9. MU Baker Mechanical cutter, RIH and make initial cut above down squeeze cement (no deeper than 3,225'), circ through cut to confirm, and POOH. 10. POOH remove WB, C/O to 7 5/a" rams, and test BOP. 11. MU spear and pull 7 5/s°' csg laying it down. 12. C/O rams to 3-'/z" x 6" variables and test BOP. Install WB. 13. If necessary, PU milling assembly and TIH to casing cut. Swap over to milling fluid and CBU. Mill 7- ~ 5/s" casing to 3,225' and (at minimum, 100' and below surface shoe). POOH. 14. RU to cement. RIH w/ work string, spot a 41 bbl 17 ppg Class G cement for a kick off plug and ~ POOH. ~.... 15. WOC approx 2,000 psi compressive strength. 16. MU the 9 %8" drilling assembly with DIR/GR/RES/NEU/DEN/PWD/DWOB/DTORQ/Vibration Sensor and RIH. 17. Drill 20' new formation and perform LOT. 18. Drill 9'/a" intermediate interval as per directional plan. 19. Drill ahead to casing point at Top Sag River to an estimated depth of 12,653' MD. 20. Run and cement (possible 2 stage cement job) the 7" BTC-M/TC-II 26# csg to 12,654' w/ TC-I 4,522' and (1,500' and below surface casing shoe) to surface. Calculated cement top should b 4,02 ' "' and (1,000' and below surface casing shoe) using a Halliburton ES Cementer if necessary. ~ 21. MU 6-3/a" BHA with DIR/GR/RES/NEU/DEN and RIH to shoe tract. 22. Pressure test wellbore to 4,000 psi for 30 minutes, record test. ~ r 23. Drill shoe tract. Swap over to 8.5 ppg Flo-Pro SF mud and drill 20' of new formation. Perform FIT to ~ 10.0 ppg• ._.. 24. Drill the 6-3/a" production interval as per directional plan to and estimated TD of 13,054'. - 25. Run and cement a 4-~/z" 2.6#, L-80 liner. Ensure that there is 150' of overlap from -the 7-5/8" shoe. ~`" '^ Set liner hanger and li r t p packer. Displace well to clean seawater above the liner top. 26. MIRU SWS. Run U IT BL w/ orienting sub from 4-'/z" liner top to TOC, estimated to be 1,000' and below surface casin . ~`-~ 27. Run 4-'/z", 12.6#, L-80 completion w/ Baker S-3 permanent packer. Space out and land tbg. 28. Install TWC and test to 1,000 psi. 29. ND BOPE and NU adapter flange and tree. Test to 5,000 psi. ,~' 30. Pull TWC. 31. Reverse circulate corrosion inhibitor and seawater. Reverse in sufficient diesel for freeze protection to 2,200' and and allow to u-tube. 32. Drop ball and rod, set packer, 33. Test tubing and annulus to 4,000 psi for 30 minutes each, record tests. / 34. Set BPV and secure the well. 35. RDMO. Post-Rig Work: 1. Install well house and flow lines. - 2. MIRU slickline. Pull the ball and rod / RHC plug from `X' nipple below the packer. 3. MIRU E-line. Perforate -100' of perfs w/ 2.5" Powerjet Omega charges at 4 spf. Z-19Ai Sidetrack Page 7 Phase 1: Move In / Rig Up /Test BOPE Planned Phase Time Planned Phase Cost 24 hours Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards Z-46 will require surface shut in preparation for the rig move onto Z-19. Z-46 is 17.0' to the West. Z-20 is 35.0' to the East. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MIRU operations, the Z-19 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. Prior to pulling the tree, verify there is a static column of kill weight fluid to surface and that no pressure exists. During ND/NU BOPE operations, the Z-17 well bore will be secured with the following barriers: o Tubing: the P&A cement plug, kill weight fluid, and a TWC. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid.. Z-pad is not designated as an HZS site. However, Standard Operating Procedures for W2S precau ` nos should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading Z-18 No Data Z-27 No Data Z-20 10 ppm Z-30 No Data The maximum level recorded of H2S on the pad was 20 ppm from Z-35, measured 8/17/00. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 72 hours Reference RP • "De-completions" RP • "Casing Cut and Pull w/ Baker Back Off Tool" RP • "Setting an Abandonment or Kick Off Plug in Open Hole" Z-19Ai Sidetrack Page 8 • Issues and Potential Hazards - BOP test frequency during this phase is 7 days. - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - Note that this wellhead is an FMC BP Slimhole. The tubing hanger is FMC 10" x 4-~/2" TDS top thread and bottom thread for a Cameron "H" type BPV. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. - There is a 4-'/z" Otis SSSV landing nipple with dual ~/a" control lines. There were 27 rubber control line protectors and 4 stainless steel bands. The 4-'/z" tubing will be jet cut @ -4,000 md. - The 4-~/z", 12.6#, L-80, BTC/TDS tubing may be corroded from 5,090' and to -6,400' md, based upon an LDL run 7/15/95 that indicated possible tubing leaks through this range. - Run USIT from tubing stub to surface looking for evidence of OA down squeeze. - Have appropriate tools (i.e. wash pipe or mills) and fishing equipment on stand by for mediating any cement in the OA prior to cutting and pulling the intermediate casing. - Ensure proper BOPE rams are installed and tested prior to pulling 7-5/a" casing. - Ensure emergency slips on the 7 5/8" intermediate casing are welded prior to pulling to prevent lost junk in the hole. - Ensure that the cement kick off plug is placed on the CIBP and extends at least 200' inside of the 10-3/a" surface casing. Ensure the proper cement additives (i.e. 3% or better Calcium Chloride, etc....) have been included in the blend to compensate for the low bottom hole temperatures. ; Phase 5: Drill 9-'/8" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 162 hours Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - The sidetrack will exit the original wellbore in the SV Sands. This wellbore will drill the Schrader, Colville, HRZ and the Kingak, to the top of the Sag River formation. Previous Z-pad wells have required 9.6 to 10.2 ppg mud weights to drill the Ugnu due to free gas. Seismic data indicates that this well will penetrate through the center of the gas accumulation; care should be taken in this interval. Connection flowback volumes should be well documented prior to drilling the. Ugnu. - For this well, the HRZ will be penetrated at a maximum angle of 28° and require a mud weight of 9.7 ppg to 9.9 ppg. The Kingak shale will require a mud weight of 10.0 ppg. Maintain mud weight at 10.0 ppg, minimally, from above the HRZ to the 7" casing point; allow the behavior of the Ugnu to dictate a higher mud weight if necessary. Follow. all shale drilling practices to minimize potential problems. - Three fault crossings are anticipated in drilling this intermediate section. The first fault will likely be encountered in the upper Colville, the second fault will be crossed in the upper Kingak and the third fault will be crossed in the lower Kingak. These faults are not expected to create any lost circulation hazards. There were no fault related losses associated with the drilling of the original Z-19 well. Z-19Ai Sidetrack Page 9 • - KICK TOLERANCE: In the worst-case scenario of 10.0 ppg pore pressure at the Kuparuk depth, a fracture gradient of 12.9 ppg at the surface casing shoe, and 10.2 ppg mud in the hole, the kick tolerance is 51.4 bbls. With a fracture gradient of 15.5 ppg at the surface casing shoe, the kick tolerance is 157.2 bbls. - Several wells drilled in the the late 1980's and early 1990's had issues with stuck pipe and casing running problems associated with the Kingak instability issues. Use RP for "Shale Drilling Practices", minimize in slips time and watch the shakers for signs of shale instability. If shale instability is encountered, adjust mud weight accordingly. Phase 6: Run and Cement 7" Intermediate Casing Planned Phase Time Planned Phase Cost 68 hours Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running: speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate 'Kingak instability . problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. - Ensure that a TIW valve with a cross over to 7" BTC or TC-II casing is on the rig floor before running the intermediate casing. - The 7" intermediate casing will be cemented in two stages to ensure proper cement coverage over shallow horizons for future development. Ensure the third plug (closing plug) is loaded in cement head prior to opening ES Cementer to avoid possible well control issues. Once the cementer is open, circulate through cementer until the lead cement of the first stage has reached 100 BC (approx 6 hrs 23 min). - The intermediate casing will be crossed over to 7 5/8" 29.7# TC-II just below the wellhead such that existing equipment can be re-used. Phase 7: Drill 6-3/a" Production Hole Interval Planned Phase Time Planned Phase Cost 48 hours Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Z-19Ai Sidetrack Page 10 • Issues and Potential Hazards - The parent well, Z-19, experienced no lost circulation events during drilling operations. - There were no significant lost circulation events in drilling nearby surrounding wells. - The planned well, Z-19Ai, is not expected to cross any faults while drilling the production interval. Phase 9: Run 4-~/s" Production Liner Planned Phase Time Planned Phase Cost 43 hours Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4-1/z", 12.6#, L-80, IBT-M solid liner throughout the production interval - Differential sticking is possible. The 8.6 ppg Flo-Pro will be -450 psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4-~/z" liner will be run to extend 150' back up into the 7" liner. - Ensure the 4-Yz" liner top packer is set prior to POOH. - Run USIT/CBL in 7" intermediate casing from 4-~/z" liner top to TOC. Phase 12: Run 4-~/z" L-80 Completion Planned Phase Time Planned Phase Cost 32 hours Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion, as designed, will be to run a 4-'/z", 12.6#, L-80, TC-II production tubing string, stinging into the 4-'/z" liner tieback sleeve. All TC-II connections will need to be torque turned. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 15 hours Z-19Ai Sidetrack Page 11 • Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - During ND BOPE / NU adapter /tree operations, the Z-19Ai well bore will be secured with the following barriers: o Tubing: TWC and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - During RD/MO operations, the Z-19Ai well bore will be secured with the following barriers: o Tubing: Tree, a BPV and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Z-46 will require surface shut in preparation for the rig move onto Z-19. Z-46 is 17.0' to the West. Z-20 is 35.0' to the East. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. Z-19Ai Sidetrack Page 12 :] Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ugnu is may be over pressured. A 9.9 ppg EMW was required in Z-39. II. Hydrates and Shallow gas A. Gas Hydrates are present at Z-pad and have been encountered in wells as close as Z-17 and Z- 19throughout the SV5, SV4 and SV3. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole; however, hydrates have been encountered below the SV1. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. III. Lost Circulation/Breathing A. Lost circulation is possible. Z-23 and Z-14 had losses of 6,000 bbls 1,000 bbls respectively. B. Breathing is not expected in this well. IV. Kick Tolerance/Integrity Testing A. The 7" casing will be cemented with 15.8 ppg tail and 12.5 ppg (first stage) / 11.0 ppg/gal (second stage) lead cement to 1000' MD below surface casing shoe in two stages. a. The Kick Tolerance for the surface casing is 51.4 bbls with 10.2 ppg mud, 12.9 ppg LOT, and a 10.0 ppg pore pressure. Integrity Testing -12.9 ppg EMW LOT B. The 4-~/2" production liner will be cemented with 15.8 ppg tail cement to the liner top.. a. .The Kick Tolerance for the intermediate casing is infinte with 8.5 ppg mud, 10.0 ppg FIT and a 7.7 ppg pore pressure. Integrity Testing -10.0 ppg EMW FIT V. Stuck Pipe A. Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe. situations. B. 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 shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions C. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide Z Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be ollowed at all times. Personal monitors must be worn at all times. Recent H2S data from the pad is as follows: Adjacent Producers at Surface: Adjacent Producers at TD: Z-17 10 ppm Z-16 10 ppm ~'` Z-18 N/A Z-12 N/A VII. Faults A. Three faults are expected to be crossed by Z-19Ai. No losses are expected to be associated with the faults. Details are listed below for reference: Fault Formation Encountered MD Intersect TVDss Intersect Estimated Throw Direction of Throw Uncertainty Fault #1 U er Colville 9,070' -5,610' 180' D to SW +/- 100' Fault #2 U er Kin ak 11,570' -7,610' 100' D to NE +/- 100' Fault #3 Lower Kin ak 12,440' -8,435' ~10' D to S +/- 100' CONSULT THE Z PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Z-19Ai Sidetrack Page 13 TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATOR = BAKER KB. ELEV = 87' BF. ELEV = 54.12' KOP = 794' Max Angle = 61 @ 12438' Datum MD = 14040' Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~-~ 3022' Minimum ID = 3.725" @ 13512' 4-1 /2" PARKER SWN NIPPLE Z-19 u SAF~~IOTES: 2096' I~ 4-112" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PDRT DATE 5 5318 3876 56 CAM BK 4 8340 5621 54 CAM BK 3 11570 7468 59 CAM BK 2 12855 8131 54 CAM BK 1 13120 8287 54 CAM BK 13461' (-~ 9-5/8" X 4-1/2" BKR SABL-3 PKR, ID = 3.99" 13495' -~4-1/2" PARKER SWS NIP, ID = 3.813" 8 13512' 4-1/2" PARKER SWN NIP, ID = 3.725" 13510' SLM 4-1/2" PXN PLUG (01/02/03) 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 13521' 13521' 4-1/2" WLEG, ID = 3.958" TOP OF 5-1 /2" LNR 13523' 13526' ELMD TT -LOGGED 05/02/92 7-5/8" CSG, 29.7#, ID = 6.875" I~ 13802' PERFORATION SUMMARY REF LOG: CNL/GR/CCL ON 05/02/92 ANGLE AT TOP PERF: 57 @ 14090' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 14090 - 14140 C 05/03/92 3-3/8" 6 14108 - 14128 C 06/30/93 3-3/8" 6 14140 - 14158 C 06/30/93 3-3/8" 6 14170 - 14200 C 05/15/92 3-3/8" 6 14214 - 14230 C 05/15/92 3-3/8" 6 14244-14266 C 05/15/92 3-3/8" 6 14280 - 14315 C 05/15/92 PBTD 14397' 15-1/2" LNR, 17#, 13-CR, .0232 bpf, ID = 4.892" I-i 14478' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/23/92 LINDB2 ORIGINAL COMPLETION 05/18/01 RN/TP CORRECTIONS 09/25/05 TWS/TLH PXN PLUG SET (01/02/03) PRUDHOE BAY UNff WELL: Z-19 PERMIT No: 1920230 API No: 50-029-22251-00 SCE 19, T11 N, R12E, 984' FNL & 3247' FEL BP Exploration (Alaska) TREE = CNV 4-1 /16" 5M WELLHEAD = FMC Gen 5 CSG HEAD = 11" SM W/ 7" MANDREL HANGER 8 PACKOFF TBG SPOOL = 11" X 11" SM TBG HANGER = 11" X 4-1/2" ADP FLANGE= 11" X 4-1/16" ACTUATOR = BAKER KB. ELEV = 87' BF. ELEV = _ _ 54.12' KOP = 794' Max Angle = Datum MD = 61 ~ 12438' 14040' P ~O P O S E D Z -19 ~ SAFETY NOTES: Minimum ID = 3.812" ~ 2200' 41/2" HES X NIPPLE 7-5/8" CSG STUB 3225' HES 7-5/8" CIBP 3275' 4-1/2" TBG JET CUT 4000' 7-5/8" X 4-1/2" BKR SABL-3 PKR, 13461' ID = 3.99" TOP OF 5-112" LNR 73523' 7-5/8" CSG, 29.7#, ID = 6.875" 13802' PBTD 14397' 5-1/2" LNR, 17#, 13-CR, 0.0232 bpf, 14478, ID = 4.892" l )P JOINT IS 7-5/8", 29.7#, L-80 TC-II 2200' 4-1/2" HES X NIPPLE; ID = 3.812" 3022' 10-3/4" 45.5#, L-80, 0.0962 bpf, ID = 9.950" 3150' KOP FROM CEMENT PLUG 4022' CALCULATEDCEMENTTOP 4522' 7" 26# TC-II 0.0383 b f ID = 6.276" 12383' 4-1/2" HES X NIPPLE; ID = 3.812" 12446' 7" x 4-1/2" BAKER S-3 PKR; ID = 3.88 I 12472' 4-1/2" HES X NIPPLE; ID = 3.812" 12493' 4-1/2" HES X NIPPLE; ID = 3.812" 12504' 7" x 4-112" BKR FLEX LOCK LNR HNGR 4-1/2" 12.6# TGII L-80, 0.0152 bpf, 12504' ID = 3.958" 12654' 7" 26# BTC-M, 0.0383 b f, ID = 6.276" 12968' PBTD 13054' 4-1/2" 12.6# IBT-M L-80, 0.0152 bpf, ID = 3.958" /. 1 06/12/061 STG (ORIGINAL COMPLETION 1 I I I PRUDHOE BAY UNIT WELL: Z-19Ai PERMff No: API No: 50-029-22251-01 SEC 19, T11N, R12E, 984' FNL 8~ 3247' FEL BP Exploration (Alaska) by Schlumberger Z-19A (P4c) Proposal Surve 1 DLS Com utation Method• Minimum Curvature I Lubinski . _~_.. __._. ....., ,,..., y p Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Vertical Section Azimuth: O~ Vertical Section Origin: / 12.970° S 0.001 ft, W 0.001 ft Structure 1 Slot: Z-PAD / Z-19 ~ Ot'~ ND Reference Datum: Rotary Table Well: Z-19 rO~ ND Reference Elevation: 82.6 ft relative to MSL Borehole: Plan Z-19A ppp Sea Bed 1 Ground Level Elevation: 54.000 ft relative to MSL UWIIAPI#: 5002922225101 Magnetic Declination: 24.022° Survey Name 1 Date: Z-19A (P4c) /July 17, 2006 Total Field Strength: 57623.783 nT Tort 1 AHD 1 DDI 1 ERD ratio: 122.137° 18184.78 ft / 6.156 10.899 Magnetic Dip: 80.862° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US feet Declination Date: August 10, 2006 Location LatlLong: N 70.29767889, W 149.19216919 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5959099.970 ftUS, E 599754.940 ftUS North Reference: True North Grid Convergence Angle: +0.76054362° Total Corr Mag North a True North: +24.022° Grid Scale Factor: 0.99991130 Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth SulrSea ND TVp Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS lie-m Survey 373y.4Z 4y."L/ 354./tl L6Ly.4tS Z/7Z.7U 7224.31 7L//.yZ 7Z/Y.'Lb 1L/U./1 -li"1.31 U.74 b`J6U3liy.64 byyti/5.// N /0.3U77bU4U W 74y.1926/3tf3 KOP Crv 4/100 3150.00 49.32 354.80 2636.38 2719.00 1231.94 1285.94 1280.26 1278.71 -63.04 0.46 5960377.61 599674.94 N 70.30117222 W 149.19267972 SV1 3170.98 49.73 355.76 2650.00 2732.62 1247.14 1301.90 1296.21 1294.61 -64.35 4.00 5960393.49 599673.42 N 70.30121566 W 149.19269036 3200.00 50.31 357.07 2668.65 2751.27 1268.45 1324.13 1318.44 1316.80 -65.74 4.00 5960415.67 599671.73 N 70.30127630 W 149.19270160 3300.00 52.42 1.42 2731.10 2813.72 1344.31 1402.23 1396.47 1394.87 -66.72 4.00 5960493.71 599669.72 N 70.30148958 W 149.19270955 3400.00 54.68 5.53 2790.53 2873.15 1423.62 1482.65 1476.42 1475.12 -61.81 4.00 5960574.01 599673.57 N 70.30170882 W 149.19266975 3500.00 57.07 9.40 2846.64 2929.26 1505.99 1565.42 1558.01 1557.17 -51.02 4.00 5960656.18 599683.26 N 70.30193296 W 149.19258238 3600.00 59.58 13.07 2899.15 2981.77 1591.03 1650.50 1640.97 1640.61 -34.41 4.00 5960739.83 599698.76 N 70.30216090 W 149.19244787 End Crv 3628.05 60.30 14.06 2913.21 2995.83 1615.30 1674.78 1664.45 1664.21 -28.72 4.00 5960763.50 599704.14 N 70.30222537 W 149.19240175 UG4 3692.22 60.30 14.06 2945.00 3027.62 1671.03 1730.51 1718.34 1718.27 -15.18 0.00 5960817.73 599716.96 N 70.30237308 W 149.19229210 UG4A 3803.22 60.30 14.06 3000.00 3082.62 1767.43 1826.93 1811.82 1811.80 8.25 0.00 5960911.55 599739.14 N 70.30262859 W 149.1921 UG3 4449.04 60.30 14.06 3320.00 3402.62 2328.30 2387.90 2360.39 2355.96 144.52 0.00 5961457.43 599868.17 N 70.30411520 W 149.1909 UG1 5579.23 60.30 14.06 3880.00 3962.62 3309.81 3369.60 3330.35 3308.25 383.01 0.00 5962412.71 600093.97 N 70.30671675 W 149.18906 Ma 6184.69 60.30 14.06 4180.00 4262.62 3835.63 3895.51 3852.42 3818.41 510.76 0.00 5962924.47 600214.93 N 70.30811043 W 149.18803135 Mb1 6305.78 60.30 14.06 4240.00 4322.62 3940.79 4000.69 3956.95 3920.44 536.32 0.00 5963026.82 600239.13 N 70.30838917 W 149.18782429 Mb2 6396.60 60.30 14.06 4285.00 4367.62 4019.66 4079.57 4035.38 3996.96 555.48 0.00 5963103.59 600257.27 N 70.30859822 W 149.18766899 Mc 6527.78 60.30 14.06 4350.00 4432.62 4133.59 4193.52 4148.69 4107.49 583.16 0.00 5963214.47 600283.48 N 70.30890018 W 149.18744466 Na 6689.23 60.30 14.06 4430.00 4512.62 4273.81 4333.76 4288.19 4243.54 617.23 0.00 5963350.94 600315.74 N 70.30927183 W 149.18716856 Nb 6739.69 60.30 14.06 4455.00 4537.62 4317.62 4377.59 4331.80 4286.05 627.88 0.00 5963393.59 600325.82 N 70.30938797 W 149.18708228 Nc 6840.60 60.30 14.06 4505.00 4587.62 4405.26 4465.24 4419.02 4371.07 649.17 0.00 5963478.88 600345.98 N 70.30962025 W 149.18690971 OA 7072.69 60.30 14.06 4620.00 4702.62 4606.82 4666.84 4619.69 4566.63 698.14 0.00 5963675.05 600392.35 N 70.31015449 W 149.18651278 OBa 7203.87 60.30 14.06 4685.00 4767.62 4720.75 4780.79 4733.15 4677.17 725.83 0.00 5963785.93 600418.56 N 70.31045645 W 149.18628841 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-19\2-19iPlan Z-19A\Z-19A (P4c) Generated 7/17/2006 12:43 PM Page 1 of 3 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea ND 7Vp Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS V6V /L64.OV OV.JV 74.V0 4/C7.VU 46V/AL 4/;/V.00 407U.`J7 46UL. `JO 4/47. I`J /4L.00 V.VV 7JOJ674.7/ OVV4J4.0`J /V /U.J IU04LL/ VV 74J.IU077VJ4 OBc 7395.60 60.30 14.06 4780.00 4862.62 4887.26 4947.32 4899.02 4838.72 766.28 0.00 5963947.99 600456.86 N 70.31089778 W 149.18596049 OBd 7516.69 60.30 14.06 4840.00 4922.62 4992.42 5052.51 5003.80 4940.75 791.83 0.00 5964050.34 600481.06 N 70.31117651 W 149.18575337 OBe 7647.88 60.30 14.06 4905.00 4987.62 5106.34 5166.45 5117.33 5051.28 819.52 0.00 5964161.22 600507.27 N 70.31147847 W 149.18552899 OBf 7738.70 60.30 14.06 4950.00 5032.62 5185.22 5245.34 5195.94 5127.80 838.68 0.00 5964237.99 600525.41 N 70.31168752 W 149.18537364 OBf Base 7849.70 60.30 14.06 5005.00 5087.62 5281.62 5341.76 5292.03 5221.33 862.10 0.00 5964331.81 600547.59 N 70.31194302 W 149.18518377 CM2 8556.07 60.30 14.06 5355.00 5437.62 5895.07 5955.32 5903.75 5816.51 1011.15 0.00 5964928.86 600688.71 N 70.31356896 W 149.18397539 Fault Crossing 9070.71 60.30 14.06 5610.00 5692.62 6342.01 6402.34 6349.66 6250.14 1119.75 0.00 5965363.86 600791.53 N 70.31475356 W 149.18309487 Crv 4/100 9437.32 60.30 14.06 5791.66 5874.28 6660.40 6720.79 6667.40 6559.05 1197.11 0.00 5965673.74 600864.78 N 70.31559745 W 149.18246754 CM1 9483.16 58.47 13.92 5815.00 5897.62 6699.84 6760.23 6706.77 6597.33 1206.65 4.00 5965712.13 600873.81 N 70.31570200 W 149.18239021 9500.00 57.80 13.87 5823.89 5906.51 6714.14 6774.53 6721.04 6611.21 1210.08 4.00 5965726.06 600877.06 N 70.31573993 W 149.182362 9600.00 53.81 13.54 5880.09 5962.71 6796.82 6857.23 6803.60 6691.55 1229.67 4.00 5965806.64 600895.58 N 70.31595939 W 149.182203 9700.00 49.82 13.17 5941.90 6024.52 6875.40 6935.81 6882.08 6768.00 1247.83 4.00 5965883.32 600912.72 N 70.31616825 W 149.182056 9800.00 45.83 12.76 6009.03 6091.65 6949.49 7009.90 6956.09 6840.20 1264.47 4.00 5965955.73 600928.40 N 70.31636548 W 149.18192125 9900.00 41.84 12.29 6081.15 6163.77 7018.73 7079.14 7025.29 6907.79 1279.50 4.00 5966023.51 600942.53 N 70.31655013 W 149.18179934 10000.00 37.86 11.75 6157.91 6240.53 7082.79 7143.20 7089.33 6970.45 1292.86 4.00 5966086.33 600955.05 N 70.31672129 W 149.18169102 10100.00 33.87 11.09 6238.94 6321.56 7141.34 7201.78 7147.90 7027.86 1304.47 4.00 5966143.89 600965.90 N 70.31687814 W 149.18159684 10200.00 29.90 10.28 6323.83 6406.45 7194.11 7254.59 7200.71 7079.75 1314.28 4.00 5966195.90 600975.02 N 70.31701989 W 149.18151725 THRZ 10258.36 27.58 9.71 6375.00 6457.62 7222.13 7282.65 7228.77 7107.38 1319.15 4.00 5966223.59 600979.52 N 70.31709538 W 149.18147769 10300.00 25.93 9.25 6412.18 6494.80 7240.84 7301.39 7247.51 7125.87 1322.24 4.00 5966242.11 600982.37 N 70.31714588 W 149.18145263 10400.00 21.97 7.87 6503.55 6586.17 7281.30 7341.97 7288.06 7165.99 1328.32 4.00 5966282.31 600987.91 N 70.31725548 W 149.18140331 TKLB 10406.94 21.69 7.76 6510.00 6592.62 7283.87 7344.55 7290.64 7168.55 1328.67 4.00 5966284.87 600988.23 N 70.31726246 W 149.18140046 K-1 10444.42 20.21 7.10 6545.00 6627.62 7297.21 7357.95 7304.02 7181.83 1330.41 4.00 5966298.18 600989.79 N 70.31729876 W 149.18138638 TKD 10449.74 20.00 7.00 6549.99 6632.61 7299.02 7359.78 7305.84 7183.65 1330.63 4.00 5966299.99 600989.99 N 70.31730372 W 149.18138456 Z-19A Tgt Kup 10449.75 20.00 7.00 6550.00 6632.62 7299.03 7359.78 7305.85 7183.65 1330.63 4.00 5966300.00 600989.99 N 70.31730373 W 149.18138455 LCU 10492.14 18.69 10.25 6590.00 6672.62 7313.02 7373.82 7319.88 7197.53 1332.72 4.00 5966313.90 600991.90 N 70.31734165 W 149.18136757 End Crv 10499.97 18.45 10.90 6597.43 6680.05 7315.52 7376.31 7322.37 7199.98 1333.18 4.00 5966316.36 600992.32 N 70.31734835 W 149.18136386 TMLV 10871.66 18.45 10.90 6950.00 7032.62 7433.10 7493.98 7440.03 7315.52 1355.44 0.00 5966432.17 601013.04 N 70.31766397 W 149.18118331 TKNG 11303.89 18.45 10.90 7360.00 7442.62 7569.84 7630.80 7576.85 7449.87 1381.32 0.00 5966566.85 601037.13 N 70.31803101 W 149.18097` Fault Crossing 11567.44 18.45 10.90 7610.00 7692.62 7653.21 7714.23 7660.28 7531.80 1397.10 0.00 5966648.96 601051.82 N 70.31825481 W 149.1808 TJF 11683.41 18.45 10.90 7720.00 7802.62 7689.90 7750.94 7696.99 7567.85 1404.04 0.00 5966685.10 601058.29 N 70.31835328 W 149.18078899 TJE 11925.88 18.45 10.90 7950.00 8032.62 7766.60 7827.70 7773.74 7643.22 1418.56 0.00 5966760.65 601071.80 N 70.31855918 W 149.18067120 TJD 12157.80 18.45 10.90 8170.00 8252.62 7839.97 7901.11 7847.16 7715.31 1432.45 0.00 5966832.91 601084.73 N 70.31875612 W 149.18055853 TJC 12431.90 18.45 10.90 8430.00 8512.62 7926.68 7987.88 7933.92 7800.51 1448.86 0.00 5966918.31 601100.01 N 70.31898888 W 149.18042537 TJB 12547.86 18.45 10.90 8540.00 8622.62 7963.37 8024.59 7970.63 7836.56 1455.80 0.00 5966954.45 601106.47 N 70.31908735 W 149.18036903 7JA 12590.03 18.45 10.90 8580.00 8662.62 7976.71 8037.94 7983.98 7849.66 1458.33 0.00 5966967.59 601108.82 N 70.31912316 W 149.18034855 TSAG 12653.29 18.45 10.90 8640.00 8722.62 7996.72 8057.96 8004.00 7869.33 1462.11 0.00 5966987.29 601112.35 N 70.31917687 W 149.18031782 7" Csg Pt 12653.30 18.45 10.90 8640.01 8722.63 7996.72 8057.97 8004.01 7869.33 1462.11 0.00 5966987.30 601112.35 N 70.31917688 W 149.18031781 Shublik 12684.91 18.45 10.90 8670.00 8752.62 8006.73 8067.97 8014.02 7879.16 1464.01 0.00 5966997.15 601114.11 N 70.31920373 W 149.18030245 TEII 12779.79 18.45 10.90 8760.00 8842.62 8036.74 8098.01 8044.05 7908.65 1469.69 0.00 5967026.71 601119.40 N 70.31928429 W 149.18025636 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-19\2-19\Plan Z-19A\Z-19A (P4c) Generated 7/17/2006 12:43 PM Page 2 of 3 Measured Vertical Along Hole Comments Inclination Azimuth SulrSea ND 7yp Closure NS EW DLS Northing EasGng Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS L-l `JH Ig[ lL/`JU.33 1i5.4b lU.`JU i5//U.UU iSiSbL.bZ TSAD 12790.34 18.45 10.90 8770.01 8852.63 OGOC 12800.88 18.45 10.90 8780.00 8862.62 45N 12837.77 18.45 10.90 8815.00 8897.62 44N 12864.13 18.45 10.90 8840.00 8922.62 43N 12890.48 18.45 10.90 8865.00 8947.62 42N 12911.57 18.45 10.90 8885.00 8967.62 41 N 12959.01 18.45 10.90 8930.00 9012.62 31 N / OO WC 129 90 . 6 3 18.45 10.90 8960.00 9042.62 TD / 4-1/2" Lnr r? ~ ~ • ~ ~ 18.45 10.90 9020.00 9102.62 fi Legal Deiscria Ion: -! Surface : 4296 FSL 2923 FEL S19 T11 N R12E UM Tie-In : 4296 FSL 2923 FEL S19 T11 N R12E UM Z-19A Tgt Kup : 919 FSL 1564 FEL S7 T11 N R12E UM Z-19A Tgt : 1647 FSL 1422 FEL S7 T11 N R12E UM BHL : 1729 FSL 1405 FEL S7 T11 N R12E UM i5U4U.V25 tf1U"1.3b i5V4/ .3y /`,111.`JS l4/U.3L U.UU byb/U3U.VU 8040.08 8101.35 8047. 39 7911.93 1470.32 0.00 5967030.00 8043.41 8104.68 8050. 72 7915.20 1470.95 0.00 5967033.28 8055.08 8116.36 8062. 40 7926.67 1473.16 0.00 5967044.78 8063.42 8124.71 8070. 75 7934.86 1474.74 0.00 5967052.99 8071.76 8133.05 8079. 09 7943.06 1476.32 0.00 5967061.20 8078.43 8139.72 8085. 76 7949.61 1477.58 0.00 5967067.77 8093.44 8154.74 8100. 78 7964.36 1480.42 0.00 5967082.55 8103.44 8164.75 8110. 79 7974.19 1482.31 0.00 5967092.41 8123.45 8184.78 8130 .81 7993.85 1486.10 0.00 5967112.11 Northing (Y) [ftUS] 5959099.97 5959099.97 5966300.00 5967030.00 5967112.11 Fasting (X) [ftUS] 599754.94 599754.93 600989.99 601119.99 601134.68 • bu~llly.yy N /V.3~IyLy3Z0 VV l4`9.12fUZb1 Z4 601119.99 N 70.31929325 W 149.18025123 601120.57 N 70.31930220 W 149.18024611 601122.63 N 70.31933353 W 149.18022819 601124.10 N 70.31935591 W 149.18021538 601125.57 N 70.31937829 W 149.18020258 601126.74 N 70.31939619 W 149.18019234 601129.39 N 70.31943648 W 149.18016929 601131.15 N 70.31946333 W 149.18015392 601134.68 N 70.31951705 W 149.18012319 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-19\Z-19\Plan Z-19A\Z-19A (P4c) Generated 7/17/2006 12:43 PM Page 3 of 3 by Schlumberger WELfi Z-19A (P4c) FIELD Prudhoe Bay Unit - WOA 6~D~TNRE Z-PAD Ma5~re1c Paramele,a Sur+aca L.w:aiun NAp2y Alaska Sine PN~res. Zone d. US FeN MauNlaneuus MoEel. BGGM 200fi Dip 60.862' Dale Auqus110. 200fi N]O ti Stfiu NuMag. 5959095 nUS Gn6Dmv: x0.]6056362' 6M. Z-t9 ND Red Rwary Ta61e ~B2.6211aWVn MSL, Mag Dec: •26.022" FS 5]6236 nT Lon W169 11 31 809 Eaw,g 559y549611US Srale FaU-0.9999113042 Plan. 2~19A1P4c, Sny pale July 1]. 200fi 1200 2400 3600 4800 6000 7200 8400 9600 3600 4800 3= O O N C li 6000 N U 7200 8400 9 Tietin Survey KOP Crv U100 .... _..-. ..-..-..-..-..-. -..-..-..-..-..-..-..-..a..-..-..-..-..-..-..-.. .-..-..-..-..-..-..-..-.t-..-..-, ~ End Crv ..-x.-.. _..-i. _.. _.. ..-..-..-..-..y..-..-..-..-..-..-..-..-..~..-..-..-..-..-..-..-..-..r..-..-..-..-..-..-..-..-.~-..-..-, .-..-.._. - _.._..- .A..-..-. -..-..-..-..-..-..-..- -..-..-..-..-..-..-.. .-..-..-..-..-..-..-.. ..-..-, -i.-..-..-..-..-..-..-..-. ..-..-..-..-..-..-..- _.._.._.._.._.._.. -j.-..-..-..-..-..-..-..-.. y.-..-..-..-..-..-..-..-.. y..-..-..-..-..-..-.. -. -~.-..-..-..-..-..-..-..-.. r,.-..-..-..-..-..-..-..-.. y..-..-..-..-..-.. -.. -. Fault Crossing -• - - - - - - - Crv 4h 00 - - -..-..-..-..-. -..-..-. -. -..- -..- -.. ..-..-..-.. -.. ..-..-..-..-..-..-..-. ..-..-..-..-..-..-..-.. i..-..-..-..-..-..-.. .-..-..-.t-..- ~.. ~..-..-..-..-..-..-:.-..-..-..-..-..-..-..-...'..-..-..-..-..-..-..-. fault Cro;sin ._.._.._. .._.._.._..-.._.._.._..~. .._.._.._.._.._.._.._ .i..-.._.._.._.._.._..-.. .-..-..-..-..-..-.. _.. .._.._.._.._.._.._..-.. .._.._.. TD I F112" Lnr Z-f9A (P4c) 1200 2400 3600 4800 6000 7200 8400 9600 Vertical Section (ft) Azim = 12.97°, Scale = 1(in):1200(ft) Origin = -0.00116292 N/-S, -0.00129304 E/-V 3600 • 4800 6000 7200 • 8400 b • • P Schlumberger WELL FIELD STRUCTURE Z-19A (P4c) Prudhoe Bay Unit - WOA Z-PAD Magnetic Parameters SuNace LnfdllU'I NAp3I AIasNa SUte PNnes Zona Oa, US FeN Miscelareous Abtlel RGGM 2006 Dip 90863' Dale Jury ~1200fi hr0'I St 6a~ NorIMn9 69590999)905 Gna Conv ~0.J6056]fi2° SKK: Z~'9 ND Re/ Rdary iatile 183839 a6ova MSLI Mag Ox ~3<023" FS 5)6238 nT W/a9 t13~809 Eas~np 6991549a XUS Scala Fad.09999113042 Plan: 2~19A IPic~ Sivy Dale: JuN 1T. 2006 '1000 0 1000 2000 8000 7000 6000 n n n Z 5000 0 0 0 c a~ m U ~ 4000 V V V 3000 2000 1000 8000 7000 6000 5000 4000 3000 2000 1000 1000 0 1000 2000 «< W Scale = 1(in):1000(ft) E »> Z-19/Plan Z-19A __ _ __ __ ~~00 000 ~5~~ 6~~~ ~5~~ 2~0 0500 1200 0 ~~~~ s °o o° 0 2r o i r ~ , i I I i 1 1 ~ ~: ,220 -- Z-19 (Z-19) Plan Z-19A ~"s %o 00 'o °o s 900 00 0 • • STANDARD ALASKA PRODUCTION COMPANY WELLHEAD L TION DATA 1) WELL: Z-19 FIELD: Prudhoe Bay Unit 2) Well Head Location 984 'from North line 2031 'from lJest line Section 19 T 11 N, R 12 E. UPM X ~ 599,754.94 Y ~ 5,959,099.97ASP tone 4 LAT . 70°17'51.644" N, LONG . 149°11' 31.809" W 3) Local Benchmark Elevation Pad "Mon.-1" E1. 48.35 Ft. AMSL 4) Top E dge of Cellar NE Corn. (Plant) E1. 54.12 Ft. AMSL 5) Kelly Bushing to Base Flanges Ft. AMSL 6) Kelly Bushing to Ground Levels Ft. AMSL 7) Base Flange Elevation Ft. AMSL 8) Kelly Bushing Elevation Ft. AMSL sMeasured by Drilling Foreman NOTES: 1) The surveyor should fill in Items 2, 3 and 4. 2) The completed form should be returned to Drilling Dept. for distribution. CT RCULATIO~: North Slope Production Engineering (North Slope, BOC) - 1 Reservoir Engineering Operations (MB9-2) - 1 North Slope - to Rig for Posting (North Slope, BOC) - 2 Well Records (LR2-1) - 11 Nell Files (MB12-1) - 1 Drilling, Technical Assistant (M612-1) - 1 Drilling, Completion Technical Assistant (MB12-1> - 1 Graphic Services, Supv., Cartography (MB2-4) - 1 ~. OF A~ ~~ P. 1 _ • ~ ~ /t i ~~,`~•••«•••,,•~45~ 1 .,~~ i"'49T!+ ' ...................~...... j... • i ~; berror~ Tor.:uDch c n ^'~ F - .- ~``i.:.. November 18, 1986 Date • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907)561-8367 Monday, July 17, 2006 Shane Gagliardi BP Exploration Alaska Schlumberger Prudhoe Bay Z-19A (P4c) Nabors 7ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survev Proaram: Instrument Type Start Depth End Depth GCT-MS 33.82'md 3139.42'md BLIND 3139.42'md 3,400.00'md MWD 3,400.00'md 4,800.00'md MWD + IFR + MS 4,800.00'md 13,053.89'md Close Approach Analvsis results: Under method (2), all wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Checked by: Scott DeLapp 07/17/06 • BP Alaska Anticollision Report Company: BP Amoco Date: 7/17/2006 Field; Prudhoe Bay ' Reference Site: PB Z Pad ~o-ordipate(NE) Reference: Reference Well: Z-19 . Verdcat (TVp) Reference: keference Wellpath: Plan Z-19A - _ __ - NO GLOBAL SCAN: Using user defined selection & scan criteria - - Interpolation Method: MD Interval: 5.00 ft Depth Range: 3150.00 to 13053.89 ft Maximum Radius:10000.00 ft - - - Survey Program for Definitive Wellpath - - - - - ', Date: 10!26/2005 Validated: No Version: 3 Planned From To Survey Toolcode ft ft 33.82 3139.42 1 : Schlumberger GCT multishot GCT-MS ', 3139.42 3400.00 Planned: Plan #4 V1 BLIND 3400.00 4800.00 Planned: Plan #4 V1 MWD i~ 3400.00 13053.89 Planned: Plan #4 V1 _- MWD+IFR+MS Time: 14:17:57 Reference: Error Model: Scan Method: Error Surface: Page: WeII: Z-19, True North Z-19A Plan 82.6 Dh:_ Oracle I Principal Plan & PLANNED PROGRAM ISCWSA Ellipse ', Trav Cylinder North Ellipse + Casing ', 'fool Name Schlumberger GCT multishot Blind drilling MWD -Standard MWD +IFR + Multi Station Casing Points - - MD TVD Diameter Hole Size Name ft ft is in 3017.62 2633.46 10.750 13.375 10 3/4" ', 12632.20 8702.62 7.000 8.500 7" ', 13053.89 9102.62 4.500 6.750 4 1 /2" Summary ---------- Offset Wellpath.: - --> -- Ste WeII ' Wellpath PB Z Pad - ExpansiorPlan Ivi Z-40 (SH) Plan Z-40 V1 Plan: Pla PB Z Pad - ExpansiorPlan Ivi Z-41 (SC) Plan Z-41 V1 Plan: Pla PB Z Pad - ExpansiorPlan Ivi Z-42 (SJ) Plan Z-42 V1 Plan: Pla PB Z Pad - ExpansiorPlan Ivi Z-44 (SF) Plan Z-44 V1 Plan: Pla PB Z Pad - Expansiorl~lan Ivi Z-55 (SB) Plan Z-55 V1 Plan: Pla PB Z Pad - ExpansiorPlan Ivi Z-57 (NC) Plan Z-57 V1 Plan: Pla ', PB Z Pad - ExpansiorPlan Ivi Z-60 (NK) Plan Z-60 V1 Plan: Pla PB Z Pad - Expansiorl~lan Ivi Z-63 (NA) Plan Z-63 V1 Plan: Pla PB Z Pad - ExpansiorPlan Kup Z-105 (SL) Plan Z-105 V2 Plan: PI PB Z Pad - Expansiori~lan Kup Z-106 (NL) Plan Z-106 V1 Plan: Pt PB Z Pad - Expansiorl~lan Kup Z-113 (NG) Plan Z-113 V1 Plan: PI PB Z Pad - ExpansiorPlan Kup Z-115 (NI) Plan Z-115 V1 Plan: PI PB Z Pad - ExpansiorPlan Sch Z-200 (SE) Plan Z-200 V1 Plan: PI PB Z Pad - ExpansiorPlan Sch Z-307 (NM) Plan Z-307 V1 Plan: PI PB Z Pad - Expansiorfr'lan Sch Z-308 (NN) Plan Z-308 V1 Plan: PI PB Z Pad - Expansiorl~lan Sch Z-309 (NP) Plan Z-309 V1 Plan: PI PB Z Pad - ExpansiorPlan Sch Z-310 (SD) Plan Z-310 V1 Plan: PI PB Z Pad - ExpansiorlPlan Sch Z-311 (SO) Pfan Z-311 V1 Plan: PI PB Z Pad - ExpansiorPlan Sch Z-312 (SP) Plan Z-312 V1 Plan: PI PB Z Pad - Expansiorl~lan Sch Z-314 (SN) Plan Z-314 V1 Plan: PI PB Z Pad - Expansiorl~lan Sch Z-322 (NJ) Plan Z-322 V1 Plan: PI PB Z Pad - Expansiorl~lan Z-34 (SG) Plan Z-34 V1 Plan: Pla PB Z Pad - ExpansiorPlan ZW-46 (SM) Plan ZW-46 V1 Plan: PI PB Z Pad Plan Z-102 (27.5) Plan Z-102 V2 Plan: PI PB Z Pad Plan Z-104 (27+30) Plan Z-104 V1 Plan: PI PB Z Pad Plan Z-109 (5.5) Plan Z-109 V3 Plan: PI PB Z Pad Plan Z-110 (30.5) Plan Z-110 V1 Plan: PI PB Z Pad Plan Z-111 (27+15) Plan Z-111 V1 Plan: PI PB Z Pad Plan Z-112 (29.5) Plan Z-112 V2 Plan: PI ', PB Z Pad Plan Z-114 (27+45) Plan Z-114 V1 Plan: PI ', PB Z Pad Plan 2-400 (21-35) Plan Z-400 V1 Plan: PI ', PB Z Pad Plan 2-401 (33-35) Plan 2-401 V1 Plan: PI Reference '- Offset: Ctr-Ctr ?lo-Go ~Ilowafile MD MD Distance Area Deviation Warning °- ft ft ft ft ft ' - --' 3150.12 4035.00 3150.73 7705.00 3150.00 4570.00 3152.19 3130.00 12898.10 13050.00 3150.00 3650.00 3150.94 4820.00 3151.37 4905.00 5688.22 5415.00 9537.84 9280.00 7993.85 12650.23 3156.55 3080.00 3165.54 3245.00 3156.47 3420.00 3150.00 4320.00 3666.60 3710.00 3690.00 4085.00 1875.36 79.61 1795.75 5753.99 80.50 5673.50 2424.78 70.33 2354.45 323.58 84.20 239.38 328.39 213.49 114.90 1535.78 95.29 1440.48 2896.71 81.70 2815.01 3053.10 85.87 2967.23 401.79 139.33 262.47 219.81 136.12 83.69 2565.94 232.83 2333.12 1191.69 88.18 1103.51 1166.43 91.55 1074.88 1296.15 8724 1208.91 2114.88 76.24 2038.64 1929.07 103.60 1825.47 2490.03 104.88 2385.15 3152.47 3755.00 1359.85 72.07 1287.79 3151.37 4960.00 3067.96 78.60 2989.36 3150.00 3715.00 6724.41 12882.84 3150.00 3665.00 3150.00 3065.00 3150.00 4250.00 3150.19 3070.00 1421.27 4189.34 1944.57 563.08 2714.03 578.63 68.04 1353.23 173.54 4015.80 81.15 1863.42 81.46 481.62 81.04 2632.98 77.58 501.05 PB Z Pad Plan 2-402 (21-70) Plan Z-402 V1 Plan: PI 3150.00 3015.00 1472.96 92.29 1380.66 ', PB Z Pad Z-01 Z-01 V1 3150.00 10435.00 8392.41 74.51 8317.90 PB Z Pad Z-02 Plan Z-02B V2 Plan: PI 3150.00 5420.00 3412.46 74.30 3338.16 ~ PB Z Pad Z-02 Z-02 V3 3150.00 5430.00 3413.37 74.30 3339.08 ~, PB Z Pad Z-02 Z-02A V1 3150.00 5420.00 3411.51 74.30 3337.21 '~ PB Z Pad Z-03 Z-03 V4 3150.00 7230.00 5089.39 87.99 5001.40 PB Z Pad Z-04 Z-04 V6 3150.00 4165.00 2047.39 71.68 1975.71 PB L Z Pad -- - - Z-04 - Z-04A V10 3150.00 4155.00 2046.62 71.79 1974.84 Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk _ Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Out of range Pass: Major Risk Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk BP Alaska Anticollision Report Compan~: -- BP Amoco - Date: 7!17/2006 Timed 14:17:57 Fade: 2 Field: Prudhoe Bay Reference Sitr. PB Z Pad Co-ordina te(NE) Reference: Well: Z- 19, True Nort h Reference Well: Z-19 Verticall~('fVD) liefer ence: Z-19A Plan 82.6 '~ Reference Wellpath: Plan Z-19A __,. Db: Oracle Summan -- <------- _ _~ - Offset Wellpath - - ----> - - --- Reference Offset Ctr-Ctr No-Go Allowable " Site Well Wellpath MD 1~ID Distance Area Deviation Warning ~ ~--- -- - --- - - - ft ft ft ft ft I ~i PB Z Pad Z-05 ~.-~~- -- - Plan#3 Z-05AP61 VO Pla 3150.00 4030.00 1903.53 77.16 1826.37 Pass: Major Risk ', ~ PB Z Pad Z-05 Plan#4 Z-05A VO Plan: 3150.00 4030.00 1903.53 77.16 1826.37 Pass: Major Risk ', PB Z Pad Z-05 Z-05 V3 3150.00 4030.00 1903.53 77.12 1826.40 Pass: Major Risk ', PB Z Pad Z-06 Plan#7 Z-06A V3 Plan: 3150.00 4380.00 2395.51 77.29 2318.22 Pass: Major Risk PB Z Pad Z-06 Z-06 V1 3150.00 4380.00 2395.51 77.18 2318.33 Pass: Major Risk i ', PB Z Pad Z-07A Z-07A V1 3150.00 3915.00 2141.76 93.93 2047.83 Pass: Major Risk ', PB Z Pad Z-07 Z-07 V1 3150.00 3915.00 2141.80 94.04 2047.75 Pass: Major Risk ', PB Z Pad Z-08A Z-08A V1 3150.00 3955.00 1920.36 80.73 1839.63 Pass: Major Risk ', PB Z Pad Z-08 Z-08 V1 3150.00 3955.00 1920.36 80.84 1839.52 ~ Pass: Major Risk PB Z Pad Z-100 Z-900 V7 12149.43 3680.00 1214.07 65.79 1148.29 Pass: Major Risk ', ~~ PB Z Pad Z-101 Plan Z-101A V3 Plan: Z 3151.33 3015.00 869.12 112.64 756.48 Pass: Major Risk ', j PB Z Pad Z-101 Plan Z-101AP61 VO Plan 3151.33 3015.00 869.12 112.91 756.22 Pass: Major Risk PB Z Pad Z-101 Z-101 V5 3151.80 3015.00 869.40 112.84 756.56 Pass: Major Risk ', PB Z Pad Z-103 Z-103 V1 3150.00 5170.00 2948.57 70.36 2878.21 Pass: Major Risk PB Z Pad Z-103 Z-103PB1 V3 3150.00 5170.00 2948.57 70.36 2878.21 Pass: Major Risk ', PB Z Pad Z-103 Z-103PB2 V1 3150.00 5170.00 2948.57 70.36 2878.21 Pass: Major Risk ', ', PB Z Pad Z-108 Z-108 V5 Out of range PB Z Pad Z-10 Z-10 V1 3150.00 3615.00 2287.30 101.46 2185.84 Pass: Major Risk ', PB Z Pad Z-10 Z-10A WPS V1 Plan: Z-1 3150.00 3605.00 2284.72 101.48 2183.24 Pass: Major Risk ', PB Z Pad Z-11 Z-11 V1 3150.00 6680.00 4621.20 72.36 4548.84 Pass: Major Risk ', PB Z Pad Z-11 Z-11A V3 3150.00 6680.00 4621.20 72.30 4548.90 Pass: Major Risk PB Z Pad Z-12 Z-12 V1 Out of range PB Z Pad Z-13 Z-13 V3 12988.59 13100.00 798.89 241.31 557.58 Pass: Major Risk PB Z Pad Z-13 Z-13A V2 12618.60 12885.00 1327.69 230.67 1097.02 Pass: Major Risk ' PB Z Pad Z-13 Z-13APB1 V3 12624.20 12910.00 1208.67 239.10 969.57 Pass: Major Risk ' PB Z Pad Z-14A Z-14A V1 3150.00 4020.00 1612.55 76.43 1536.13 Pass: Major Risk PB Z Pad Z-14 Plan Z-14B V5 Plan: PI 3150.00 4010.00 1612.16 76.41 1535.75 Pass: Major Risk PB Z Pad Z-14 Z-14 V1 3150.00 4020.00 1612.55 76.42 1536.13 Pass: Major Risk ', PB Z Pad Z-15 Z-15 V1 3150.16 3760.00 1146.76 95.36 1051.40 Pass: Major Risk PB Z Pad Z-16 Z-16 V6 Out of range ', PB Z Pad Z-17 Z-17 V1 Out of range ', PB Z Pad Z-18 Z-18 V1 Out of range PB Z Pad Z-19 Z-19 V1 3150.62 3155.00 0.00 0.67 -0.67 FAIL: NOERRORS ' PB Z Pad Z-20 Plan Z-20A V1 Plan: PI 3150.14 4255.00 1939.46 96.31 1843.15 Pass: Major Risk ', PB Z Pad Z-20 Z-20 V1 3150.39 4265.00 1940.32 96.25 1844.07 Pass: Major Risk PB Z Pad Z-210 Z-210 V6 3159.79 4865.00 2360.06 85.75 2274.31 Pass: Major Risk j ~ PB Z Pad Z-210 Z-210P61 V7 3629.25 4720.00 2259.25 99.49 2159.77 Pass: Major Risk PB Z Pad Z-21 Z-21 V3 3150.00 3695.00 1297.60 67.02 1230.58 Pass: Major Risk ~, PB Z Pad Z-21 Z-21A V5 3150.00 3690.00 1298.46 66.92 1231.54 Pass: Major Risk ~~ PB Z Pad Z-22A Z-22A V1 3150.95 3065.00 738.42 101.44 636.99 Pass: Major Risk 'i PB Z Pad Z-226 Z-226 V1 3150.95 3065.00 738.42 101.44 636.99 Pass: Major Risk ~, PB Z Pad Z-22 Z-22 V1 3150.95 3065.00 738.42 101.44 636.99 Pass: Major Risk PB Z Pad Z-23 Z-23 V3 3150.00 3875.00 1540.91 66.77 1474.15 Pass: Major Risk PB Z Pad Z-23 Z-23A V2 3150.00 3865.00 1543.86 66.78 1477.08 Pass: Major Risk '~ ', PB Z Pad Z-23 Z-23B V7 3150.00 3870.00 1546.33 66.81 1479.52 Pass: Major Risk PB Z Pad Z-24 Z-24 V1 3150.00 3770.00 1359.39 70.53 1288.86 Pass: Major Risk PB Z Pad Z-25 Z-25 V1 3150.00 3770.00 1345.51 69.73 1275.79 Pass: Major Risk ', PB Z Pad Z-26 Z-26 V1 3151.90 3770.00 1331.63 69.57 1262.06 Pass: Major Risk PB Z Pad Z-27 Z-27 V1 3152.21 3215.00 706.41 94.17 612.24 Pass: Major Risk PB Z Pad Z-28 Z-28 V1 3150.00 3665.00 1363.49 72.45 1291.04 Pass: Major Risk ', PB Z Pad Z-29 Z-29 V1 3150.00 3400.00 1028.65 83.92 944.73 Pass: Major Risk ', PB Z Pad Z-30 Z-30 V7 3150.00 3075.00 817.05 99.30 717.75 Pass: Major Risk PB Z Pad Z-30 Z-30A V9 3150.00 3065.00 817.01 99.28 717.72 Pass: Major Risk I PB Z Pad Z-31 Z-31 V1 3150.00 3080.00 920.11 102.65 817.46 Pass: Major Risk ', i PB Z Pad Z-32A Z-32A V7 3150.00 3635.00 1439.95 73.61 1366.34 Pass: Major Risk ', PB Z Pad Z-326L1 Z-32BL1 V2 3150.00 3650.00 1438.15 73.65 1364.50 Pass: Major Risk ' PB Z Pad Z-32BPB1 Z-32BPB1 V2 3150.00 3650.00 1438.15 73.65 1364.50 Pass: Major Risk ', PB Z Pad Z-32BP62 Z-32BP82 V2 3150.00 3650.00 1438.15 73.65 1364.50 Pass: Major Risk PB Z Pad ~ Z-326 Z-326 V2 3150.00 3650.00 1438.15 73.65 1364.50 Pass: Major Risk PB Z Pad Z-32 Z-32 V2 3150.00 3650.00 1438.15 73.65 1364.50 Pass: Major Risk PB Z Pad Z-33 Plan Z-336 V2 Plan: PI 3150.00 3960.00 1788.65 71.01 1717.65 Pass: Major Risk ~ PB Z Pad Z-33 Z-33 V1 3150.00 3840.00 1690.28 66.98 1623.30 Pass: Major Risk PB Z Pad Z-33 Z-33A V1 3150.00 3960.00 1788.65 70.90 1717.75 Pass: Major Risk ! ~ BP Alaska Anticollision Report Company: BP ArnoCO - - Date: 7!17/2006 - 'Time; 14:17:57 - Page: 3 ~ ~ Field; Prudhoe Bay Reference Site: PB Z Pad Co-ordinat e(NE) Reference: Well: Z-19, True North ~ Reference Well: Z-19 ~ VerticaT(T VD) Reference: Z-19A P lan 82.6 Reference Wellpath: Plan Z-19A Db: Oracle ~~ Summary <---- --- O - ____ tf'sef Weilpath - -- - ------------> _ Reference - Offset Ctr-Ctr No-Go Allowable Site Well Wellpath ~A1D MD Distance area Deviation Warning ft ft ft ft ft ', PB Z Pad Z-35PB1 Z-35PB1 V2 3150.00 3735.00 1707.25 85.51 1621.74 Pass: Major Risk ', PB Z Pad Z-35 Z-35 V2 3150.00 3785.00 1781.84 78.66 1703.18 Pass: Major Risk i PB Z Pad Z-38P61 Z-38P61 V3 3150.00 3955.00 2234.87 86.79 2148.09 Pass: Major Risk ~i PB Z Pad Z-38 Z-38 V5 3150.00 4030.00 2330.31 86.76 2243.55 Pass: Major Risk PB Z Pad Z-39 Z-39 V18 3150.00 5400.00 3229.83 85.55 3144.28 Pass: Major Risk !, PB Z Pad Z-39 Z-39A V4 3150.00 5400.00 3229.83 85.58 3144.25 Pass: Major Risk PB Z Pad Z-46 Z-46 V14 Out of range PB Z Pad Z-46 Z-46A V15 Out of range • ' Field: Prudhoe Bay Site: PB Z Pad '- - ~ell~ Z-19 _..__ Wellpath: Plan Z-19A 0 zoo -o zoo `313 Travelling Cylinder Azimuth (TF6+AZq [deg] vs Centre to Centre Separation [200R/in] Target: Z-19A Kup Tgt Site: PB Z Pad Drilling Target Conf.: 95% Description: Map Northing: 5966300.00 ft ', Map Easting : 600990.00 ft Latitude: 70° 19'02.293N Shape: Circle 0 o°~ o~ ~~ Well"Z-19 Based on: Planned Program Vertical Depth: 6550.00 ft below Mean Sea Level Local +N/-S: 7183.64 ft Loca] +E/-W: 1330.64 ft Longitude: 149° 10'S2.984W - -- Radius: 150 ft X000 1200 0 0 0 0 0 ~ 00 X000 0000 0 0 Target: Z-19A TSAD Tgt Site: PB Z Pad We1L• Z-19 Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 8770.00 ft below Mean Sea Level Map Northing: 5967030.00 ft Local +N/-S: 7911.91 ft Map Easting : 601120.00 ft Local +E/-W: 1470.33 ft Latitude: 70° 19'09.456N Longitude: 149° 10'48.904W _-._ Shape: Circle Radius: 150 ft _- ---- --- _------ __ - ~ 8 3 0 0 I 8200 8 00 8000 ~~00 X800 __ _ - _ __ _'~ ~ ~ 0 0 0 0 0 0 0 0 0 o 0 0 ~ o o D~ ~ ~ - - - - ar ~ ~ ~ ~ D~ ~~ • Terri Hubble BP Exploration AK Inc. PO Box- 196612 MB 7-5 Anchorage, AK 99519 n PAY TO THE l ORDER OF ~,jXd.. "Mastercard Check" • ss-siiz5z 291 DATE ~~~' ~, ~~ s (cam , ~v DOLLARS First National Bank Alaska Anchorage, AK 99 01 MEM0 2 f ~.<,~~~- ~:L252OOO6O11:99L46227L556.11' O29L r~ • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~ ~, ~' PTD# ~.D~ ~ /~ Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Compan Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/25/06 C:\jodyltransmittal checklist Field & Pool PRUDHOE BAY, PRUDHOE OIL - 64015 WELL PERMIT CHECKLIST _ __ -__ ____ ___ __ _ ______ - --__ ____ ~ __. __Well Name: PRUDHOE BAY UNITZ-19A __ _ ____ Program SER ___ Well bore seg ~ PTD#:2061050 Company BP EXPLORAT_ ION (ALASKA I) NC __ _ ___ Initial Classlfype .. _SER I WINJ___GeoArea 890- ____ __ Unit 11650 __ OnlOff Shore On ____ Annular Disposal ~] Administration 1 Permit fee attached Yes 2 Lease number appropriate Yes 3 Unique well_n_ame and number - - . Yes i 4 Well located in a defined pool _ , Yes 5 Well located pr_operdistancefrom_drilling unit_boundary Yes _ - _ - _ ! 6 Well located proper distance_f[om other wells. Yes - - 7 Sufficient acreage ayail_able in_drilling unit- - - - Yes - - - - 8 If deviated, is_wellbore plat_included _ _ - . - - - - - - .Yes - - - - - _ 9 Operator only affected party- - Yes - - - - - - - 1 10 Operator has appropriate_bond in force _ . - Yes - _ - - - _ - 11 Permit can be issued without conservation order_ _ _ _ - _ _ _ Yes - - - - - - - - - - - - - _ - - - ~ 12 Permitcanbeissuedwithoutadministrative_approva_I------------------------- Yes- -----__-- -___- _-__ _ - Appr Date 13 Can permit be approved before 15-daywait_ _ _ _ _ _ _ _ - - . _ - - - - - - - _ - - , Yes _ - _ - - - - RPC 7I2512D06 14 Well located within area an_d strata authorized by_Injection Order # (put1O# in_comments)_(For- Yes - - - - AIO 3- ~~ 15 All wells_within 114 mile area of review identified (For service well only) Yes Z-13, Z-1.3AP61, Z-13A, Kuparuk St. 711-12 16 Pre produced mlector; duration of pre p[oduction less than 3 months_(For service well_only) NA. _ _ ' 17 Nonconven, gas conforms to AS31,05,D30Q.1.A),((.2.A-f)) - - _ _ - NA_ _ - - - - - - 18 --- - - - Conduckor stung provided - _ _ _ _ _ _ NA- - _ Engineering 19 Surface casing protects all known USDWs _ _ - - _ NA- _ _ _ - _ _ 20 CMT vol_adequate_to circulate on conducto[& surf-csg - - _ - - NA_ - - - - - - . 21 CMT-vol_ adequate-to tie-in long string tosurf csg- . - - - - - - - - - - - NA.. - - - - - 22 CMT_will coyer_all knownprotluctive horizons- - - - Yes - - - - - -Adequate excess, ! 23 Casing designs adequate for C, T, B & permafrost- _ _ - _ - - - _ Yes _ 24 Adequatetan_kage-or reserve pit -_ ---._--.__---------------------- Yes_ ---_ -Nabors_7ES, X 25 .If a re-drill, has-a-1.0-403 for abandonment been approved _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ __ _ Yes . - - - _ - - 7113/2006._ 26 Adequatewellbore&eparationproposed- - - - - Yes - ~ 27 If diverter required, does itmeet-regulations- - - _ - - - - - NA. _ - Sidetrack. _ _ - - _ i28 Dnllrnq fluid. program schematic & egwp list adequate- - - Yes _ - Max MW 10 2_ppg._ Appr Date !29 BOPES, do they meet regulation _ _ . - _ _ Yes - - - - - - - - - - - - - _ - _ _ WGA 7126!2006 30 BOPE.press rating appropriate; test to_(put psig in comments)_ - - Yes - - - - - Test to 4000_psi _MSP 2745 psi.- i31 Choke-man'rfold comRlies wlAPl_RP-53 (_May 84)- _ _ _ _ _ _ _ Yes _ - - - - _ j32 Work will occur withoutcperationshutdown__ ______ Yes_ - __- ____ ______ ______ _ ___ _ _ -__ ___ _____ ~I33 Ispresence of H2Sgas-probable _ . _ - - - - No_ _ - Not an H2S ad. - p 'x,34 Mechanical condition of wells within AOR verified (Fors_en+ice well only) Yes - _ - . -Records indicate meth integrity of all AOR wells. 35 Permit. can be issued wlo_ hydrogen s_ul_fide measures _ - _ - - _ No Geology 1 ,36 Data presented on_ potential overpressure zones _ _ _ _ _ _ _ - NA _ _ _ . - - - - _ - _ - - _ _ - - - - - _ _ _ 137 Seismcanafysisofshallowgaszones_----___----- --- ------------- NA_ __-______ _..-. Appr Date 38 Seabed condition survey-(ifoff-shore) - - - - - - , - - - - - - - - - - - - - - - - - - - - - NA- - - - - RPC 7120120D6 39 Contact Hamel hone for week) - ro ress re orts_[Qxploratory onl p Y p 9- P Yl - - - - fJA - - Geologic Date; Engineering Date c Date Commissioner: Commissioner: 'Her DTs 7 (~.71~- --- ~~.~_ 0~_ _ •
