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Home My WebLink About200-157MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 30, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC B-22A PRUDHOE BAY UNIT B-22A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/30/2025 B-22A 50-029-20759-01-00 200-157-0 W SPT 8304 2001570 2000 286 288 286 285 112 114 115 115 REQVAR P Guy Cook 11/7/2025 2 year MIT-IA to maximum anticipated injection pressure per AA AIO 3.029. Mazimum anticipated injection pressure is 2000 psi. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT B-22A Inspection Date: Tubing OA Packer Depth 607 2301 2263 2251IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC251107140107 BBL Pumped:5 BBL Returned:4.3 Tuesday, December 30, 2025 Page 1 of 1           MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC B-22A PRUDHOE BAY UNIT B-22A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 B-22A 50-029-20759-01-00 200-157-0 W SPT 8304 2001570 2250 375 375 376 377 109 117 119 118 REQVAR P Brian Bixby 11/19/2023 MITIA as per AIO 3.029 to max anticipated injection pressure 2250 psi. 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 B-22A Inspection Date: Tubing OA Packer Depth 821 2503 2481 2478IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB231119154543 BBL Pumped:4.9 BBL Returned:4.1 Friday, January 12, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 James B. Regg Digitally signed by James B. Regg Date: 2024.01.12 15:19:24 -09'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector Well Name PRUDHOE BAY UNIT B -22A Insp Num: mitSAM211108194345 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 23, 2021 SUBJECT: Mechanical Integrity Tests I-lilcorp North Slope, LLC B -22A PRUDHOE BAY UNIT B -22A Src: Inspector Reviewed By: P.I. Supry S p-- Comm API Well Number 50-029-20759-01-00 Inspector Name: Austin McLeod Permit Number: 200-157-0 Inspection Date: 11/7/2021 Tuesday, November 23, 2021 Page 1 of l Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B -22A - —i Type Inj W, TVD 8304 Tubing 812 812 811 810 PTD 2001570 sI Type Test SPT ',Test psi 2076 IA 994 2297 2278 'I -2274 —_ BBL Pumped: -- 3.2 BBL Returned: 2.7 OA - -1– 88 90 -- _ 90 92 Interval REQVAR �P/F P - - Notes: 2 year. AIO 3.029. MAIP 2000psi- Tuesday, November 23, 2021 Page 1 of l • w► MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,November 27,2017 TO: Jim Regg it('n3 P.I.Supervisor j 1 7 SUBJECT: Mechanical Integrity Tests ll BP EXPLORATION(ALASKA)INC. B-22A FROM: Brian Bixby PRUDHOE BAY UNIT B-22A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT B-22A API Well Number 50-029-20759-01-00 Inspector Name: Brian Bixby Permit Number: 200-157-0 Inspection Date: 11/9/2017 Insp Num: mitBDB171109143136 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B-22A Type Inj W TVD 8304 Tubing 722 724 ' 723 723 PTD 2001570 Type- T Test. -- -- —.__ SPT Test psi 2076 IA 251 230I ' 2280 2271 li BBL Pumped: 4 2 BBL Returned: 4.1 OA 79 81 82 83 Interval REQVAR P/F P Notes: A013.029 Required Test. SCANNE Monday,November 27,2017 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 200-157-0 Inspection Date: 11/5/2019 - Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor' 71 i`r��IIQ DATE: Wednesday, November 13, 2019 SUBJECT: Mechanical Integrity Tests BE Exploration (Alaska) Inc. 15 Min 30 Min 45 Min 60 Min B -22A FROM: Austin McLeod PRUDHOE BAY UNIT B -22A Petroleum Inspector TVD 8304 See: Inspector 797 Reviewed By: 299 P.I. Supry J NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT B -22A API Well Number 50-029-20759-01-00 Inspector Name: Austin McLeod Permit Number: 200-157-0 Inspection Date: 11/5/2019 - Insp Num: mitSAM191105124324 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B -22A "Type lnj W TVD 8304 Tubing 797 799 299 799 PTD 2001570 Type Test SPT Test psi 2076 IA 230 2300 2282 - 2275 - BBL Pumped: 4.4 "BBL : Returned 3.9 - OA 60 61 62 , 63. Interval REQVAR P/F P c` -- Notes: AIO 3.029. 2 year to MAIP which is lower than test pressure off of the packer depth criteria. Wednesday, November 13, 2019 Page 1 of 1 • PRu - ZOO t'-7c Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Thursday,lune 22, 2017 7:56 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Ret ‘422.4( Cc: Cocklan-vendl, Mary E; AK, OPS FF Well Ops Comp Rep; Daniel, Ryan; Richmond, Diane M;AK, RES GPB West Wells Opt Engr;AK, GWO SUPT Well Integrity;AK, OPS GC1 Field O&M TL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead Subject: RE: B-22 Water Injector SVS Defeat Approval Mr. Regg This note is to alert you that the LPP on B-22 has temporarily been returned to normal status due to need to inject at a higher rate (>250 psi).This change occurred on 6/8/17 and is anticipated to remain in place for an additional two weeks until subsidence issues on A-16 are completed. Whenthe well is returned to a defeated LPP state for the targeted low psi injection, we will once again send notice to you. Please feel free to contact us if you have questions relating to this. Regards, Lee Hulme Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. JULOffice: (907) 659-5332 SCANNED L 1 7 2017 Cell: (907) 229-5795 Harmony — 7187 (Alternate: Vince Pokryfki) From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, June 01, 2016 3:06 PM To: AK, OPS FF Well Ops Comp Rep Cc: Cocklan-vendl, Mary E Subject: RE: B-22 Water Injector SVS Defeat Approval Thank you for the supporting documents that accompany the request to defeat the safety valve system on water injector PBU B-22A(PTD 2001570). This well is classified as a WAG injector but injection records indicate it has only injected water since November 2009. The provided information clearly exhibits the concerns expressed below, namely the inability to maintain sufficient positive pressure for the low pressure pilot trip set point with the imposed 2000 bbl water injection limit (for proper reservoir management). BPXA's request for the long term defeat the safety valve system on PBU B-22A is approved subject to water-only injection in the well and sustained wellhead injection pressures—monitored daily—that do not exceed 250psi during a 72-hour period. Please make sure the well is tagged with proper information related to this approval. Jim Regg Supervisor, Inspections AOGCC 1 is-7 0 Regg, James B (DOA) From: Regg, James B (DOA) �7 + Sent: Wednesday, June 01, 2016 3:06 PM � �I+ li To: 'AK, OPS FF Well Ops Comp Rep' Cc: Cocklan-vendl, Mary E Subject: RE: B-22 Water Injector SVS Defeat Approval Thank you for the supporting documents that accompany the request to defeat the safety valve system on water injector PBU B-22A(PTD 2001570). This well is classified as a WAG injector but injection records indicate it has only injected water since November 2009. The provided information clearly exhibits the concerns expressed below, namely the inability to maintain sufficient positive pressure for the low pressure pilot trip set point with the imposed 2000 bbl water injection limit (for proper reservoir management). BPXA's request for the long term defeat the safety valve system on PBU B-22A is approved subject to water-only injection in the well and sustained wellhead injection pressures—monitored daily—that do not exceed 250psi during a 72-hour period. Please make sure the well is tagged with proper information related to this approval. Jim Regg Supervisor, Inspections AOGCC SCpt4NED SEP 212016 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWellOpsCompRep@bp.com] Sent: Wednesday, June 01, 2016 8:15 AM To: Regg, James B (DOA) Cc: AK, OPS FF Well Ops Comp Rep; Cocklan-vendl, Mary E Subject: B-22 Water Injector SVS Defeat Approval Jim, BPXA is requesting long term SVS defeat of water injection Well B-22.This particular Well has been operating above its Recommended Injection Rate (RIR) for several months in order to keep the Low Pressure Pilot(LPP set at 75 psi) sensing device from shutting in the Well and potentially freezing the piping system. Attached are injectivity and pressure plots that show when the reservoir target injection rate of 2000 bwpd is obtained the Well head injection Pressure (WHIP) goes to a vacuum of-30 psig. This condition will trip the LPP and shut in the Well which will freeze in the Winter months if not dealt with in a timely manner. Due to this Wells downhole characteristics, it can only be operated above its RIR which can cause formation issues which need to be avoided for sustained enhanced oil recovery. 1 • S Per the Prudhoe Bay Oil Pool Low Pressure Water Injector Waiver management Procedure during daily wellhead checks if it is discovered that the sustained WHIP during normal daily operations is greater than 250 psi for more than a 72 hr period the Well SVS System must be returned to service or shut-in. Failure to do so results in a violation of the AOGCC agreed waiver if granted. Please call with any questions that you may have. Vince Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907)354-1352 Harmony -7187 Alternate:Lee Hulme 2 t ` . . .— • S .....___ • .. ► p a t q a: 65 p I ` l!•) 5 a E ► 1a a L'' _f c; i tg t v d O & & Loot ° nC Q NN nZ 0z `� , ° :8 V �' .. 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C e"" 1- CI) 1:, 7:3 4'4" r- 0 tiri CO, 0 .ki) E > 444 !ID ...c I 70 a) • , a j 1:5 C 5 NI r- m 0 4-4„„, I.- (..) , — tg) (1) - — — Lu 4-4 r- n IL- i I _, , cua ia) :, 6.... '- f- m ,e) — • n co - u-.1 C .,_--, L.) 00 (1.).. a) •a _a- w .-'. , ' co - c 4-••• 4-0 SOIL (13 ..‘14 r,n ...0 ' * L- •--- •3..-, L.) 11) 1 > .F.' e= 4-, .•-I - .2 (4) ' 0 C.I) 6-4,- (1) PI) 4- .-"' .1...• ° :5. •---• I,- ''' C •- fp co t-- x ( Lu - 7-ti .,_ -c5 c ro.- 0 0 4_, a) :-. r) 0 ,... r U d+7, (L) CU > - ' •— 0 rCi Cc > kr) c c ,..., 4-, - 1, c Z LU g '''' t V) -C 0 `;-..4 CO •- '- 1;1-) ri3 4-4 a) ri) ri) o . I a) cu > 4- .- co no -c c " 0 4..01 tip 4.A 4-' 9 '4 ' :4:: F .1. a ! 1 , , g all CO 0 I t i ' -•'*.- •' vl Z :i- ' c! <7.. . . R MP : 8 § § ii I. P: 6 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: JimDATE: Wednesday,October 28,2015 P.I.Supervisor ' ` (t I-D SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. B-22A FROM: Jeff Jones PRUDHOE BAY UNIT B-22A Petroleum Inspector p SCAt4t4ED r, r, Src: Inspector Reviewed By: P.I.Supry 3' NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT B-22A API Well Number 50-029-20759-01-00 Inspector Name: Jeff Jones Permit Number: 200-157-0 Inspection Date: 10/18/2015 Insp Num: mitJJ151020162329 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B-22A ' IType Inj f w' TVD ,8304 Tubing 533 533 'i 538 - 537 PTD 2001570 - Type Test SPT Test psi 2076 1 IA 909 1 2546 - 2513 - 2497 - Th InteCVal IREQVAR P/F P �A 59 6l 61 61 Notes: 2 year MIT-IA per AIO 3.029,T X IA communication.2.7 BBLS diesel pumped. 1 well inspected,no exceptions noted. Wednesday,October 28,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, November 18, 2011 TO: Jim Regg P.I. Supervisor (� I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B -22A I FROM: Matt Herrera PRUDHOE BAY UNIT B -22A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry IGO - NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT B - 22A API Well Number: 50 029 - 20759 - 01 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH111105172511 Permit Number: 200 - 157 - Inspection Date: 11/2/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B -22A ' Type Inj. W. TVD 8304 IA 610 2600 , 2530 2515 - P.T.D 2001570 ' 1TypeTest SPT Test psi 2076 - 1 OA 140 140 140 140 . Interval REQVAR P/F P — Tubing o 0 0 0 Notes: A}5,6 3,0 2c7 Friday, November 18, 2011 Page 1 of 1 ~~ ~~Q~C~ 00 ~ af~Q~~{Q /,~...w~..~o~A,o. ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 3.029 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RR ~] ~j~~ RE: PBU B-22A (PTD 2001570) Request for Administrative Approval Prudhoe Bay Oil Pool Dear Mr. Rossberg: Pursuant to Rule 9 of Area Injection Order (AIO) 3.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants BP Exploration (Alaska) Inc. (BPXA)'s request for administrative approval to continue water injection in the subject well. BPXA notified the Commission of slow (~90 psi/day) inner annulus (IA) repressurization affecting PBU B-22A while injecting miscible injectant (MI). Diagnostic mechanical integrity testing confirms the well exhibits competent tubing and production casing. BPXA has elected to perform no corrective action at this time on PBU B-22A. The Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the certain constraints. AOGCC's administrative approval to continue water injection only in PBU B-22A is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rates daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; 3. BPXA shall limit the well's IA pressure to 2000 psi. 4. BPXA shall perform anMIT - IA every 2 years to the maximum anticipated injection pressure; AIO 3.029 • • Apri128, 2010 Page 2 of 2 BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer annulus pressure, increased repressure rate, or increased bleed frequency; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is November 13, 2009. DONE at Anchorage, Alaska and dated Apri128, 2010. The Al Daniel T eamount, Jr. Commissioner, Chair Commission Cathy P. oerster Commissioner cc: BPXA Well Integrity Coordinator, PRB-20 P.O. Box 196612 Anchorage, AK 99519-6612 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set ou[ the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MU5T be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • '~~~ BP Exploration (Alaska) Inc. Attn: Welt Integrity Coordinator, PR&20 Poat Office Box 196612 Anchorage, Alaska 99519.8612 March 17, 2010 APR222010 by ~aS~ dil ~ Ga& Cons. Commissiar: ~ncl*oraae Mr. Dan Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well B-22A (PTDfI 2001570) Request for Administrative Approval: Continued Water Injection Operations Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests approval for continued water injection operations into Prudhoe Bay Well B-22A with slow inner annulus repressurization while on MI injection. Well B-22A exhibits inner annulus repressudzation of approximately 90 psi/day while on MI injection. However, a pressure test of the inner annulus passed to 2600 psi, indicating the tubing and production casing are competent. Based upon sound engineering practice, two barriers have been established and the well can be safely operated. Consequently, no repairs are planned at this time. In summary, BPXA believes Prudhoe Bay wep B-22A is safe to operate as stated above and requests administrative approval for continued water injection operations. If you require any additional information, please contact me at 564-5637 or Anna Dube / Torin Roschinger at 659-5102. Sincxrely, /~~ R. Steven Rc><ssber 9 Wallis Manager, BPXA Attachments: • Technical Justification TIO Plot Injection Plot Wellbore Schematic Cc: Steve Rossberg Bixby/Olsen Dube/Roschinger Central Area Manager GC3 Operations Team Leader AI Schmoyer Harry Engel • • Prudhoe Bay Oil Pool Well B-22A Technical Justification for Administrative Approval Request March 17, 2010 Well History and Status Prudhoe Bay well B-22A (PTD #2001570) exhibits manageable inner annulus repressurization while on MI injection indicated by wellhead pressure trends on a TIO plot. An MIT-IA to 2600 psi passed on 11/13/10 indicating competent tubing and production casing. Recent Well Events: > 10/20/09: Notified AOGCC of possible TxIA Comm while on MI Injection > 11/08/09: MITIA Passed to 2500 psi > 11/13/09: AOGCC MIT-IA Passed to 2600 psi Barrier Evaluation The primary and secondary barrier systems consist of tubing and production casing and associated hardware. A pressure test of the inner annulus passed to 2600 psi, demonstrating competent primary and secondary barrier systems. Proposed Operating and Monitoring Plan 1. Record wellhead pressures and injection rate daily. 2. Submit a report monthly of well pressures and injection rates to the AOGCC. 3. Perform a 4-year MIT-IA to 1.2 times maximum anticipated injection pressure. 4. The well will be shut-in and the AOGCC notified if there is any change in the well's mechanical condition. _~ ', Syo~~o ~yt ~l i I • r O a O H ~ N i N m • ~ s ~ ~ 1 _ --- - -1 a ~~~~~~a illli ew~o ? Mc~r~ e ~k'i~m7ai~}~3~F12°° m~ f. i O a C 0 .~ a - ~ a 3 N N m a~~~~~s~~~~~~~~~~e~ m m m m ~~ °. rv `„ dIHM try= a-lets Der Trott ACRiAC li]I?- Axf~s I~ ri~/= a..73 r60P a_._ _ .. _ ._ _ -300 Meit ArBN ~ 53 ~ 10919 Osaene0 ~ 10194 patunTle~ ~0D'SS iYlirmntrrn ~ ~ 3,725" ~ 9711' 4-112" HES XN NIPPLE ~~ryry //~~ seu~rrar~ r~e.ra-sa,tererROereTeo B "~ L!"1 Ara meter crueoaet t.NR rie,amwc u~ ~ •+~ Nor ar+owNaw ov-orast rraow eNtiaur IMNDDMY. ~ ~ 221d' rl-1Il ~ X sap. Ds 9~t3' ~'S.'; J~~ls -.~ GRSLFr-WrDRH.S • I poet ( I se I eralG (Derr I rx t o 9 BAD7 X13 ld WG aK tiC 6 s suo nstl sa r~z oar ac n t 9597 e2~6 st KGB oar set o w,D=sats- ®=as7s• 1~aw~~NSU~w-Rr R~ror~ wiDaNOUZi~oi ANC~Ar1op~: si ~ totsv Nees: Rekr leplydueaen ®ln naex~ peel dNa AL aprrSe~ mom- yr a .7es a Ito-toi~o c asnaos .a • aa3o. loess ~ oeanaui -7 4 ioeee-10720 C 09A2flt ~ ronaFe~wwmw~aeTr• I a av ar€ err Ot J0t T dNYA 91G (0 03 t G V t 14 eAV uer P~ifTNOC X1570 AANtt 5009-278901 11. T1tN. R1+IE 2517'N~. 81037 ~ lnpbrrtlen ~J1Mrksj AOGCC MITIA Forms for 5-215021540), 5-217 (2070950), L-115 (2000), L-215 (... Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, December 01, 2009 1:53 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: NSU, ADW Well Integrity Engineer; MPU, OMS Facility Coordinator; MPU, OMS Field Coordinator Subject: AOGCC MITIA Forms for S-215 (2021540), S-217 (2070950), L-115 (2011400), L-215 (2051270), L-216 (2040650), Z-02A (1960430), Z-25 (1881590), 1-67/T-20 (1891140), MPF- 91 (2051100), MPS-10A (2051250), B-22A (2001570) Attachments: MIT PBU S-215 S-217 11-17-09.x1s; MIT PBU L-115, L-215, L-216 11-30-09.x1s; MIT PBU Z- 02A, Z-25 11-30-09.x1s; MIT MPU MPF-91 11-06-09.x1s; MIT END 1-67(T-20) 11-21-09.x1s; MIT MPU MPS-10A 11-06-09.x1s; MIT PBU B-22 11-13-09.x1s Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: S-215 (PTD #2021540) S-217 (PTD #2070950) L-115 (PTD #2011400) L-215 (PTD #2051270) L-216 (PTD #2040650) Z-02A (PTD #1960430) Z-25 (PTD #1881590) 1-67/T-20 (PTD #1891140) MPF-91 (PTD #2051100) MPS-10A (PTD #2051250) B-22A (PTD #2001570) ~- «MIT PBU S-215 S-217 11-17-09.x1s» «MIT PBU L-115, L-215, L-216 11-30-09.x1s» «MIT PBU Z-02A, Z- 25 11-30-09.x1s» «MIT MPU MPF-91 11-06-09.x1s» «MIT END 1-67(T-20) 11-21-09.x1s» «MIT MPU MPS-10A 11-06-09.x1s» «MIT PBU B-22 11-13-09.x1s» Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~ ~~~~ ~~~ 4/27/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / B-pad DATE: 11 /13/09 OPERATOR REP: Torin Roschinger AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well B-22A Type Inj. W TVD 8,304' Tubing 2,100 2,100 2,100 2,100 Interval O P.T.D. 2001570 Type test P Test psi 2076 Casing 535 2,610 2,580 2,570 P/F P Notes: AOGCC MITIA to 2600 psi for AA OA 130 135 140 140 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU B-22 11-13-09 (4).xls STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS R~cE~vED FHB 4 2 2010 REPORT OF SUNDRY WELL OPERATIOI~,S,-_,,,ie „__„ 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension n4f~ Q~ JOB Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ CEMENT 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory 200-1570 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ API Number: Anchorage, AK 99519-6612 50-029-20759-01-00 8. Property Designation (Lease Number) : 9. Well Name and Numb r: ~ ADLO-028310 PBU B-22A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: \ Total Depth measured 10902 feet Plugs (measured) 10455 feet true vertical ~ 9156.75 feet ~: Junk (measured) None feet Effective Depth measured 10817 feet Packer (measured) 9677 6832 9729 true vertical 9099 feet (true vertical) 8304 5969 8349 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 28 - 138 29 - 138 1490 470 Surface 2649 13-3/8" 72# L-80 27 - 2676 26 - 2676 4930 2670 Intermediate Production 6951 9-5/8" 47# L-80 26 - 6977 26 - 6070 6870 4760 Liner 3073 7"26# L-80 6832 - 9905 5969 - 8501 7240 5410 Liner 1173 4-1/2" 12.6# 13CR80 9729 - 10902 8349 - 9157 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 24 - 9731 24 - 8351 Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Hvdro Set Packer 9677 8304 7" BKR ZXP LNR TOP 6832 5969 4-1/2" BKR LNR TOP BKR 9729 8349 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~'~:rr'~.~~~' ~ ~°~~ ~ ~~ t ~, 1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 8397 497 Subsequent to operation: 8117 562 14. Attachments: 5. Well Class after work: Z,3 ~o Copies of Logs and Surveys Run Exploratory ^ Development ~ Service Daily Report of Well Operations X .Well Status after work. Oil Gas WDSPL GSTOR ^ WAG GINJ ^ WINJ [J SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,/'IR oZ-$ • I Q Sundry Number or N/A if C.O. Exempt: N/A //~~~~ Contact Harry R. Eng1~i- Printed Name Harry R. Eng4C Title Engineering Team Leader Signature ~ Phone 564-4194 Date 2/1/2010 .,,,,, ,~-~~~ ,.~.,,~~ „~~.,~ RcsuMS FEB 0 3 .3., .~uvnu~ vnyniai niy ZQ10 Z °~~/o B-22A 200-157 PFRF OTTOCHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base B-22A 6/2/01 PER 10,630. 10,655. 8,976.9 8,992.74 B-22A 6/2/01 PER 10,690. 10,720. 9,015.08 9,034.39 B-22A 5/14/05 APF 10,510. 10,530. 8,901.52 8,914.08 B-22A 7/19/07 BPP 9,704. 10,720. 8,327.6 9,034.39 B-22A 7/19/07 BPS 9,704. 10,720. 8,327.6 9,034.39 B-22A 7/28/07 APF 10,134. 10,192. 8,669.62 8,705.33 B-22A 7/28/07 BPS 10,455. 10,455. 8,866.63 8,866.63 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~~ ~~ B-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE ~ SUMMARY ~ 11 /30/2009 T/I/O = 700/620/160. Temp = 132". Obj: OA top job (pre-Bluegoo). 20" conductor is 34' deep (dry). Pumped 6.5 bbls 15.7# Arctic Set cement into conductor until was filled to 3" from top of the flutes. ***Job Complete*** : SV =Closed. WV, SSV, MV =Open. IA & OA = OTG. NOVP. 3 FLUIDS PUMPED BBLS 6.5 15.7# ACRTIC SET CEMMENT 6.5 Total TREE _ ~. 4-1116" CIW WELLHEAD= ACTUATOR= MCEVOY AXELSON KB. ELEV = 73' BF. ELEV = 45' KOP = 3000' Max Angle = 53 @ 10349' Datum MD = 10464' Datum TV D= 8800' SS I 13-318" CSC, 72#, L-80 BTC, ID = 12.347" ( SAFETY N :WELL HAS 4-1/2" CHROMETBG ~~ ~~ AND 4-1/2" CHROM E LNR. PRE-SDTRK WELLBORE NOT SHOWN ON DIAGRAM BELOW MILLOIJT WINDOW. 2214' 4-1/2" HES X NIP, ID = 3.813" 2620' I'-'I 9-5/8" DV PKR i 2676' I Minimum ID = 3.725" @ 9711' 4-112" HES XN NIPPLE 9-5/8" X 7" BKR ZXP LNR TOP PKR/HNGR, ID = 6.270" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3028 3025 11 MMG DMY RK 0 07/09107 4 4061 3953 39 MMG DMY RK 0 07/09/07 3 6607 5813 46 MMG DMY RK 0 05/07/01 2 8440 7256 33 KGB2 DMY BK 0 05/07/01 1 9597 8236 31 KGB2 DMY BK 0 05/07/01 9666' N 4-112" HES X NIP, ID = 3.813" 9677' 7" X 4-112" BKR S-3 PKR, ID = 3.867" 9700' 4-112" HES X NIP, ID = 3.813" 9711' 4-1/2" HES XN NIP, ID = 3.725" 7" X 4-1 /2" BKR ZXP LNR TOP PKR I 972g' W/TIEBACK, ID = 4.375" 4-112" TBG, 12.6#, 13CR-80, 9731' VAM-ACE, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: MWD ON 04!23/01 ANGLE AT TOP PERF: 51 @.10134' Note: Refer to Production DB for historical oerf data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 6 10134 - 10192 O 07/28/07 2-7/8" 6 10510 - 10530 C 05/14/05 2-7/8" 4 10630 - 10655 C 06/02/01 2-7/8" 4 10690 - 10720 C 06/02/01 ,. ~;~\ g~ 733' I-( 4-1(2" WLEG ELMD TT NOT LOGGED TOP OF MILLOUT WINDOW @ 6977' 9905' 7" LNR, 26#, L-80 BTC, ID - 6.276" I PBTD I _~~- 9-5/8" CSC, 47#, L-80 BTC, ID = 8.681" 10305' ~~~~~~ 4-112" LNR, 12.6#, 13CR-80, VAM-ACE, .0152 bpf, ID = 3.958" 4-1/2" WRPSET (07!28107) DATE REV BY COMMENTS DATE REV BY COMMENTS 08/30/82 ORIGINAL COMPLETION 05/14(05 NBFlPJC PERFORATION 01/31/01 SIS-SLT CONVERTED TO CANVAS 07!19/07 TEL/PJC _ GLV C/O (07109/07) 03(07/01 SIS-LG FINAL 07/29/07 GJB/SV PERFORATION 05/07/01 RIG SIDETRACK 07129!07 GJB/SV SET WRP PLUG (07/28/07) 05/26/01 CHfTP CORRECTIONS 11/18(02 JW/KAK PERF CORRECTIONS __ PRUDHOE BAY UNIT WELL: B-22A PERMIT No: 2001570 AP! No: 50-029-20759-01 SEC 31, T11 N, R14E, 2317' NSL & 4092' WEL BP Exploration (Alaska) Page 1 of 1 Preble, Gary B (SAIC) From: Winslow, Jack L (ASRC) Sent: Saturday, January 23, 2010 8:31 AM To: Preble, Gary B (SAIC) Subject: RE: 10-404s for top jobs from '09 SOD -(5? Gary - Would you need any other information to do 10-404s for these jobs? We will need them filed. Thanks - Jack L. Winslow Well Integrity Engineer ofc: (907) 659-5766 harmony: 2377 alt: Ryan Holt From: Preble, Gary B (SAIC).. ~ ~- U Sent: Friday, January 22, 2010 3:04 PM To: Winslow, Jack L (ASRC) Subject: RE: 10-404s for top jobs from '09 Jack, No requests for those jobs. The only request I got was for a top job for 04-02 on 11/24/09. From: Winslow, Jack L (ASRC) Sent: Friday, January 22, 2010 2:31 PM To: Preble, Gary B (SAIC) Subject: 10-404s for top jobs from '09 Gary - Did anyone request 10-404s for the wells we did top jobs on last year for the RG-2401 project? The following wells were treated: A-2 5.8 BBLs 11/27/09: 1 4.5 BBLs 11/30/09 B-22A 6.5 BBLs 11 /30/09 B-23~- 2.2 BBLs 11/30/09 l~ ~~~ , ~~~ Thanks - ack L. Winslow J Well Integrity Engineer ofc: (907) 659-5766 ~ ~ harmony: 2377 /~ alt: Ryan Holt ( ((( ,~~- iz~ 1/25/2010 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 r by ~~~~~ ,rw.a Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, ~~-1st Q -a a~~- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B 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: 12/11/09 / ' Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 8-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-OSB 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 8-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 &19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA MEMORANDUM To: Jim Regg '~ t1 ~3~~0 j P.I. Supervisor ~;• l FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, November 19, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B-22A PRUDHOE BAY UNIT B-22A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~]~~ Comm Well Name: PRUDHOE BAY UNIT B-22A Insp Num: mitJJ091113131144 Rel Insp Num: API Well Number: 50-029-20759-01-00 Inspector Name: Jeff Jones Permit Number: 200-157-0 Inspection Date: 11/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __ _ ~ _ Well Type Ip'. G • TVD B-22A ~-- --- __ - ~ - 8304 r IA ~ 535 ~ 2610 '~i-- 2580 ~ 2570 'T _ _ y--- -- ---~-- ----1 ----}- ~ P.T.D~ 2001570 ~TypeTest i SPT eSt SI P 130 ~ ]35 ~ 140 140 ~ ~ 2076 /~ ~A _. _. _~-------_ L---'--- -... -~-----'------- - ----- ~-------~- - 210o zloo g 2100 2100 ~ P P/F Interval oT~R _ __ _ _ _ Tubin -~ -- --~---- -~-- 1- _ _ _ ___ NOtes: 5 BBL,S 60/40 methanol pumped. 1 well inspected; no exceptions noted. MIT performed for AA due to IA pressurization. ~~~~~~~. ti1~1~ ~ ~~ ZO~C Thursday, November 19, 2009 Page 1 of 1 OPERABLE: B-22A (PTD #2001570) TxIA comm while on MI, permitted for water inje... Page 1 of,~~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, November 16, 2009 2:13 PM ~' <; ~ ~'~~ ~~~ ~w To: 'NSU, ADW Well Integrity Engineer'; GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; GPB, Well Pad AB; Regg, James B(DOA); Schwartz, Guy L(DOA) Cc: Schmoyer, AI; Quy, Tiffany Subject: RE: OPERABLE: B-22A (PTD #2001570) TxIA comm while on MI, permitted for water injection only Torin, I confirm that the well may continue in operation on water only, pending the AA. Call or message with any questions. Tom Maunder, PE AOGCC From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Monday, November 16, 2009 10:43 AM To: GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; GPB, Well Pad AB; Regg, James B(DOA); Schwariz, Guy L(DOA); Maunder, Thomas E(DOA) Cc: NSU, ADW Well Integrity Engineer; Schmoyer, AI; Quy, Tiffany Subject: OPERABLE: B-22A (PTD #2001570) TxIA comm while on MI, permitted for water injection only All, Well B-22A (PTD# 2001570) is a WAG injector with TxIA communication while on MI. On 11/13/09, an AOGCC witnessed MITIA passed verifying two barriers. The plan forward is to swap the injector to water and apply for an AA on PWI only. The well has been reclassified as Operable and may continue on water injection until the AA is approved. The MIT form has been provided for your reference. «MIT PBU B-22 11-13-09.x1s» Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, October 20, 2009 4:03 PM ~++d'~~;~.:) '~i ~ ~1 '~ ~~ ~~~~ 11~16~2~~9 B-22A (PTD#2001570) TIO Plot ~ a.ooo 3,C°J ~ ~ 2,OC0 ~ ~ i,0U9 ~- Tbg -~- IA -~ OA OQ4 -~- OODA ~ - On ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / B-pad DATE: 11 /13/09 OPERATOR REP: Torin Roschinger AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well B-22A Type Inj. W TVD 8,304' Tubing 2,100 2,100 2,100 2,100 Interval O P.T.D. 2001570 Type test P Test psi 2076 Casing 535 2,610 2,580 2,570 P/F P Notes: AOGCC MITIA to 2600 psi for AA OA 130 135 140 140 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 77J~5l05 08l01109 09;0~/09 C3115;19 031221G9 ('3129/'~3 Q~/OSlQ9 091i2l09 09119IU3 OSi?E105 tUlOS109 10.~10109 1U%17tJ9 LJNDER EVALUATION - B-22~TD #2001570) IA repressurization • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer (NSUADWWeIIlntegrityEngineer@BP.com Sent: Tuesday, October 20, 2009 4:03 PM ~~'~-l r~i~~'ll r ~ To: GPB, GC3 Wellpad Lead; GPB, GC3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; GPB, Well Pad AB; Regg, James B(DOA); Schwartz, Guy L(DOA); Maunder, Thomas E(DOA) Cc: NSU, ADW Well Integrity Engineer; Schmoyer, AI Subject: UNDER EVALUATION - B-22A (PTD #2001570) IA repressurization Attachments: B-22A.pdf; B-22A TIO Plot.doc ~ All, ~ Well B-22A (PTD #2001570) has recently shown an increase in IA pressure as seen in the TIO plot attached below. The well has been reclassified as Under Evaluation. We plan to keep the well on injection and perform further diagnostics. The plan forward is as follows: 1. DHD: Bleed IAP and monitor IA BUR 2. Slickline: Troubleshoot SSSV, control and balance lines ~, ~~~~~ ~~; ~~}~;~' 3. Fullbore: AOGCC MITIA ~'~~`~'~~~ ~ 4. WIC: Eval for AA A wellbore schematic and TIO plot have been included for your reference. «g-22A.pdf» «B-22A TIO Piot.doc» Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 11 /6/2009 PBU B-22A PTD#2001570 10-20-2009 TIO Pressures ~ ~,oa~ ~,ooo ~,O[i0 1.000 ~1-- Tbg -f- IA -~-- OA OOA -~-- OOOA - On ~ ~ 0?l25109 p8101l09 ~D8117~l09 08l15l09 08I22109 0$r'~91C19 Q9f05109 05112l09 09119109 0'~I2fil09 10~03109 10~10I09 10117105 TR~= ~-~r~s° cNv WFILHEAD= MCEVOY ACTUATdR= AXELSON KB. ELEV = 73~ BF. EL.EV - 45~ KOP = 3000' ~ .~.~.~ ~ Max Angle = ~wm.~~.._ .~..,~„ 53 @ 10349' Datum MD = 10464' Datum N D= 8800' SS ~ 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" S ~ SAFEfY : WELL HAS 4-1/2" CHROMETBG e~ ~ AND 4-1/2" CHFtOM E LNR. PI2E-SDTRK WFILBORE NOT SHOWN ON DIAGRAM BEL.dW MILLdUT WINQOW. 221~~ 4-1(2" HES X NIP, 10 = 3.813" 2620' ~-~ 9-5l8" DV PKFt ( 2676' ( Minimum ID = 3.725" @ 9711` 4-1/2" HES XN NIPPLE 9-5/8" X 7" BKR ZXP LNR TOP PKR/HNGR, ID = 6.270" GAS t_IFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3028 3025 11 MMG DMl' RK 0 07/09/Q7 4 4061 3953 39 MMG DMY RK 0 07i09/07 3 6607 5813 46 MMG dMY RK 0 05/07/01 2 8440 7256 33 KGB2 DMY BK 0 05/07/01 1 9597 8236 31 KGB2 QMY &K 0 05(07/01 9666' ~ 4-1(2" HES X NIP, ID = 3.813" ~ ~677' 7" X 4-1/2"' BKR S-3 PKR, ID = 3.867" 9700~ 4-1/2" HES X NIP, ID = 3.813" 9711 ~ 4-112" HES XN NIP, ID = 3.725" 7" X 4-1l2" BKR ZXP LNR TOP PKR I 9729~ W/TIEBACK, ID = 4.375" 4-1/2" TBG, 12.6#, 13GR-$d, 9731' VANt-ACE, .Q152 bpf, ~D - 3.958" PERFORATION SUMMARY REF LOG: MWD ON 04I23/01 ANGLE AT TOP PERF: 51 @ 10134' Nnte: Refer to Production DB for historical qerf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 8 10134 - 10192 O 07/2&/07 2-7/8° 6 1051(7 - 10630 ~ d5/14/05 2-718" 4 10630 - 1 d655 C 06/02/01 2-7/8" 4 10690 - 10720 ~ 06/02/01 9733~ -"~ 4-1/2" WLEG ~ ~~ ELMD TT NOT LOGGEt? TOP OF MILLOUT WINDOW @ 6977' ~ ~ ggp~' ~7'" INR, 26#, L-80 BTC, \~ I I~ = 6.276" 10455, I 4-1(2" WRPSET (07i28/47) ~TD 1-I 10817" 9-5l8" CSG, 47#, L-80 BTC, ID = 8.681 ° ~ 10305~ ~~~~~ 4-1/2" LNR, 12.6#, 13CR-80, VAM-ACE, .D152 bpf, ID = 3.958" 10902' DATE REV BY COMMERITS DATE REV BY CqMMENTS Q8130/82 ORiGINAL COM~ETION 05/14/05 NBF/PJC PERFORATIC7N Q1/31/01 SIS-SLT CONVERTED TO CANVAS 07/19/07 TEL/PJC GLV C!O (Q7/Q9/07} 03J07/01 SIS-LG FINRL 07l29/07 GJB/SV PERFORATION 05/07/Q1 RIG SIDETRACK O7/29/Q7 GJB/SV SET WRP PLUG (d7/28/d7} 05/26l01 CWTP CORRECTIONS 11J1$!02 JW/KAK F'ERF CQRRECTIONS PRUDHOE BAY UNIT WELL: B-22A PERMIT No: ~2001570 API No: 50-029-20759-01 SEC 31, T11 N, R14E, 2317' NSL & 4092' WEL BP F~cploration (Alaskaj MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Wednesday, September 05,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B-22A PRUDHOE BAY UNIT B-22A FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv:fl{R. Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT B-22A API Well Number: 50-029-20759-01-00 Inspector Name: Lou Grimaldi Insp Num: mitLG07083 I 161232 Permit Number: 200-157-0 Inspection Date: 8/28/2007 ReI Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B-22A Type Inj. w TVD 8304 .,/ IA 100 4000 3980 3960 P.T. 2001570 TypeTest SPT Test psi 4000 OA 530 580 570 570 Interval !NIT AL PIF P ./' Tubing 760 780 780 760 Notes: 10 bbl's pumped. Pos-Initial injection MIT, Pre-MI swap. Good test. ./ SCANNED S E P 1 0 2007 Wednesday, September 05, 2007 Page I of 1 1. Operations t' Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: . STATE OF ALASKA I ALA~ OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS o o o ~? 3. Address: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic Stimulate 0 Other 0 INJECTION CONVERSION Waiver 0 Time Extension 0 ' Re-enter Suspended Well 0 5. Permit to Drill Number: 200,1570 P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Exploratory Service w 6. API Number: 50-029-20759-01-00 9. Well Name and Number: 72.3 KB PBU B-22A r 8. Property Designation: ADLO-028310 - 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE BAY Pool -- 11. Present Well Condition Summary: Total Depth measured 10902 / true vertical 9156.75 / feet feet Plugs (measured) Junk (measured) 10661' None RECE\V 0 Effective Depth measured 10817 true vertical 9099 feet feet A.laska Oil & Gas Cons. CGmmi, Anchorage Collapse 470 2670 4760 5410 7500 Casing CONDUCTOR SURFACE PRODUCTION LINER LINER Length Size MD TVD Burst 110 20" 91.5# H-40 28 - 138 28 - 138 1490 2649 13-3/8" 72# L-80 27 - 2676 27 - 2675.69 4930 6951 9-5/8" 47# L-80 26 - 6977 26 - 6069.8 6870 3073 7" 26# L-80 6832 9905 5969.07 - 8500.85 7240 1173 4-1/2" 12.6# 13Cr80 9729 - 10902 8349.04 - 9156.75 8430 Perforation depth: Measured depth; 10510 - 10720 True Vertical depth: 8902 - 9034 - - SCANNED JUL 3 1 2007 - - Tubing; (size, grade, and measured depth) 4-1/2" 12.6# 13Cr80 24 - 9731 Packers and SSSV (type and measured depth) 7" Baker ZXP Mech Liner Top Packer 4-1/2" Baker S-3 Hydro Set Packer 4-1/2" Baker ZXP LNR TOP PKR o 6832 9677 9729 o 12. Stimulation or cement squeeze summary; Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft JUL 3 0 20D7 13. Prior to well operation; Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 000 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work; Oil Gas WAG W Tubing pressure o o Service W x WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/23/2007 Form 10-404 Revised 04/2006 ORiG\NAL /¡-')l~,,\ .#¥¥t'}? Submit Original Only . . B-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 7/17/2007 T/I/O= 1475/440/140 Temp=S/1 MIT-IA PASSED to 3000 psi. Pumped 23.2 bbls of crude to pressure up IA. MIT IA lost 40 psi in 1st 15 min and 0 psi in 2nd 15 min for a total loss of 40 psi in a 30 min test. Bled IA to 450 psi, bled back aprox 6 bbls crude. FWHP's= 1500/450/150. (Valves position at departure. Swab and tree cap needle valve shut,wing valve shut and flagged, IA and OA valves open to gages, tags hung on IA and wing valves) 7/19/2007 T/I/O=1500/360/150 Assist s-line MIT IA PASSED to 4000 psi, MIT TBG PASSED to 3000 psi (Injection Conversion) - Loaded TBG W/ 160 bbls crude, S/L set plug in XN nipple, pressured IA to 4000 psi W/ 7.2 bbls crude, Loss of 60 psi 1st 16 min loss of 20 psi 2nd 15 min. MIT IA to 4000 passed 1 st attempt, loss of 60 1 st 15 min loss of 20 2nd 15 min. MIT-T to 3000 Passed loss of 80 psi 1st 15 min loss of 40 psi 2nd 15 min FWHP=400/320/160 7/19/2007 *** WELL ARRIVAL *** MADE DRIFT RUN W/ 3.805" CENT, BRAIDED LINE BRUSH AND SAMPLE BAILER, UNABLE TO PASS THRU 9663' SLM MADE RUN W/ 3.7" GAUGE RING, WORKED BRUSH THRU X NIPPLES AND THRU XN NIPPLE MADE RUN W/ 3.805" GAUGE RING, WORKED BRUSH THRU X NIPPLES AND THRU XN NIPPLE SET 41/2" CAT STANDING VALVE IN XN- NIPPLE @ 9704' SLM, LRS PRESSURE UP TO 1500 PSI, HOLDING LRS MIT-IA TO 4000 PSI, INITIAL T/IAlOA -1500/4000/150,3940 PSI AFTER 15 MIN, 3920 PSI AFTER 30 MIN ** PASS ** LRS MIT- T TO 3000 PSI, INITIAL T/IAlOA - 3000/340/150,2920 PSI AFTER 15 MIN, 2880 PSI AFTER 30 MIN ** PASS ** PULL 41/2" CAT STANDING VALVE FROM 7104' SLM *** WELL LEFT S/I ON DEPARTURE *** FLUIDS PUMPED BBLS I 176 CRUDE 176 TOTAL . . Page 1 of3 Maunder, Thomas E (DOA) ~-----~ From: Thomas Maunder (tom_maunder@admin.state.ak.us] Sent: Tuesday, June 12, 2007 7:42 AM To: Subekti, Herry Subject: Re: B-22A (200-157) Rerry , A full copy is not needed in the packet, however the full log (X-27) should be submitted as usual for inclusion into the X-27 file. Tom Maunder Subekti, Rerry wrote, On 6/11/2007 4:33 PM: Tom, Related to B-22A sundry request, FYI we ran CBL on B-22A and the planned offtake producer X-27 (Well within 1/4 mile of the proposed injector B-22Ai. Pis advise if you need full copy of the CBL in the AOR pkg. Thank you also for the approved Y-24i Sundry for patch work. Kind regards Herry Subekti B pad engineer. SCANNE.D JUL 3 1 2007 --~~'----.-.----~---'----.----'--.--_._-.----~----~---._--_.~. From: Thomas Maunder [mªilto:torn_r@under@admin.stªte.aK.lJs] Sent: Tuesday, June 05, 2007 6:36 PM To: Subekti, Herry Subject: Re: B-22A (200-157) Thanks Rerry. Nice to have a CBL log. There are a lot of older wells that don't have that. Based on your comments, it would seem that there shouldn't be an integrity problem for B- 22A. The other wells could be another story, but we will have to see. The wild card are drilling plug backs and "ghost holes" or lost sections. As I said, I will look for the sundry when it is submitted. Not sure who you might be working with, but Paul Chan, Phil Smith and an engineer working for Taylor West have recently done such assessments. Regards, Tom Subekti, Rerry wrote, On 6/5/2007 6:28 PM: Thomas, Thanks for the confirmation. r'll work with the drilling/wells grp here to provide all information you need. Just brief, from the B-22A CBL log seems we have couple ten ft of sufficient solid cement bond isolating the target 24. Also as part of our injector surveillance, another Step rate test will be done after 2-3 weeks start up on limited injection to provide a max safe injection rate/press. An IPROF with warm back passes will follow to determine injection integrity down hole. Those are routine surveillance in GPB to make sure conformance is there between 7/27/2007 . . Page 2 of3 injector and surrounding offtake producers. Rgds HS -----Original Message----- From: Thomas Maunder [mailto:tom . k.us] Sent: Tuesday, June 05, 2007 6:20 PM To: Subekti, Herry Cc: Reem, David C; Engel, Harry R; Montague, W Stuart Subject: Re: B-22A (200-157) Harry, You are correct that a sundry is needed to convert the well to injection. Your sundry only mentioned isolating the existing perforations and adding the new ones. I checked our sundry log and I don't find any other sundry applications for B-22A in 2006 or 2007. I will look forward to reviewing the sundry to convert when it is submitted. If you will be responsible for preparing the conversion documents, please include information regarding your assessment of the primary cementing operation(s) of the casing/liner(s) penetrating the Ivishak in B-22A as well as any other wells that are within 1/4 mile radius of the entry into the Ivishak. See 20 AAC 25.402 (c) (15) and 20 AAC 25.412 (d). A cement bond log of B-22A is not strictly required, but the daily reports should be examined to determine if the cementing operation proceeded without problems. Regards, Tom Maunder, PE AOGCC Subekti, Herry wrote, On 6/5/2007 6:01 PM: Thomas, Thank you for the response provided. I just would like to further explain here that this well will be converted into UZI (Updip zone injector) in Z4. The conversion project is right now on going under capital AFE 4P2507. Related to this conversion project, I would think that this recompletion job needs approval from the state in line with GPB Sundry matrix. PIs advise with this additional information. Thank you & rgds Herry Subekti B pad engineer -----Original Message----- From: Thomas Maunder Sent: Tuesday, June 05, 2007 5:54 PM To: Subekti, Herry Cc: Reem, David C; Engel, Harry R Subject: B-22A (200-157) a}(. us] Herry, I have received your sundry application to place a plug above the existing perforations in B-22A and then perforate higher. It appears that all of this work will take place within the defined Prudhoe Bay 7/27/2007 . . Page 3 of3 Oil Pool. Since this is a production well and will remain so after t work is performed, according to the Sundry Matrix no sundry is required. See the middle column of page 1 of the attached document. We will be returning the sundry as not needed. If you are unfamiliar with the matrix, you might check with Harry Engel. He was a member of the group that helped draft the matrix. Call or message with any questions. Regards, Tom Maundèr, PE AOGCC 7/27/2007 . ~1r!A\ 1rŒ (ill ~ !A\~!A\ ~ æ!A\ . AI,ASIiA. OIL AlQ) GAS CONSBRVATlON COJDIISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Heny Subekti Production Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, B-22A Sundry Number: 307-231 Dear Subekti: 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. Sincerely, SCANNED JUL 1 \9 2007 Dan T. Seamount Commissioner DATED this LX day of July, 2007 Enc!. ea:>-- t fir 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 ~ . STATE OF ALASKA C(1.t /);(A ;1,/~? ALASKA Oil AND GAS CONSERVATION COMM'MON X ~ " APPLICATION FOR SUNDRY APPROVAL fA:(" \y:. 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Development ø !/".·."í ""~CE'VE: tV"4;) iot- " \.L- ..JUL 1 0 2001 1. Type of Request: Suspend Repair well D Pull Tubing D ..1.. WàIÈÌ'r' ~ er' Stimulate D Time Extension D Am::h~~g; c.o"~t:.,~ .0 Re-enter Suspended Well D ~ .... fc:..~ \,~ 5. Permit to Drill Number: ~~ "'f\~ Abandon Alter casing D Change approved program D 2. Operator Name: Stratigraphic 0 Exploratory 0 Service 0 200-1570 ./ Anchorage, AK 99519-6612 6. API Number: 50-029-20759-01-00/ 7. If perforating. closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D 9. Property Designation: 8. Well Name and Number: B-22A /' ADLO-028310 ' No 0 10. KB Elevation (ft): 11. Field/Pools(s): 72.3 KB . PRUDHOE BAY Field / PRUDHOE OIL Pool / 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10902 / 9157 / 10817 9099 10661' Casing Length Size MD TVD Burst CONDUCTOR 110 20" 91.5# H-40 28 13828 138 1490 SURFACE 2649 13-3/8" 72# L-80 27 2676 27 2676 4930 PRODUCTION 6951 9-5/8" 47# L-80 26 6977 26 6070 6870 LINER 3073 7" 26# L-80 6832 9905 5969.07 8501 7240 LINER 1173 4-1/2" 12.6# 13Cr80 9729 10902 8349.04 9157 8430 Junk (measured): None Collapse 470 2670 4760 5410 7500 Perforation Depth MD (ft): 10510 - 10720 Perforation Depth TVD (ft): 8902 - 9034 Tubing Size: 4-1/2" 12.6# Tubing Grade: 13CrBO Tubing MD (ft): 24 - 9731 Packers and SSSV Type: 7" Baker ZXP Mech Liner Top Packer 4-1/2" Baker S-3 Hydro Set Packer 4-1/2" Baker ZXP LNR TOP PKR Packers and SSSV MD (ft): 6832 9677 9729 o 0 13. Well Class after proposed work: Exploratory 0 Developm ent Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct~o the best of my knowledge. Printed Name Title 7/23/2007 $~vice 12. Attachments: Descriptive Sum m ary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Date: Gas 0 0 Abandoned 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by \.:Icuy r-rtlule 564-4944 Contact Herry Subekti Production Engineer 7/9/2007 Signature Phone 564-5112 COMMISSION USE ONLY Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: <J:),,~c..\- :C"~~r ~ ~~",E;;.c¡,,> \."'\ \\ ~~ ~"'~~~~ ~\c.\)\\-\'2J(. Subsequent Form Required: R8DMS 8Ft JUL 1 9 2007 Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: 711Y! Form 10-403 Revised 06/2006 0 R \ G \ N A L L ¥*? Submit in Duplicate bp .~. ,\If.''I. -..~~ ~#.- ~..- ~..~ ~~ ~~.. ·I~·ji\' ". . . To: Clark Olsen /Jerry Bixby, GPB Well Ops TL Date: May 15, 2007 From: Herry Subekti, B pad engineer Subject: B-22A WRP & Add perforation AFE 4P2507 Pre UZI conversion Revision#2 : 7/09/07 Est. Cost: $40 M lOR: 500 Please set WRP & Add perforation in the B-22A. This procedure includes the following major steps: Step Type Procedure 1 S Drift/Tag pre perforation. DGL V sta#3,#4 - Done. 2 DHD Tbg FL 3 FB Liquid pack Tbg. Hold tbg 1500#. MITIA-4000#. LLR if fails. 4 EP Correlate and perforate 10,134'-10,192' (58 ft), DrifVset WRP in the liner @ 10,455'MD - Pending Press test & sundry approval. Status: Last test: Max Deviation: Perf Deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S level: Reference Log Est BHP/BHT Note SI high GOR 6/17/05268 BOPD, 3292 BFPD, 129K GOR, 63.9 Choke 53 degrees @ 10349'MD 51 degrees @ 1051 O'MD 3.725" @ 9711' (4-1/2" HES XN Nipple) Tagged TD at 10661 'ELMD during perforation 5/14/05 Static survey 7/23/06 Not in Database MWD 4/23/2001 3244#/216°F @ -8800'TVD SS 4.5" prod liner tested 3500# 5/6/2001 7"X4-1/2" BKR S3 packer was tested to 3500# 5/7/01 Well B-22A was rig sidetracked and completed on 05/07/01. The well was wet since the beginning. Add perf was done on 5/14/2005 but did not help the productivity. The well was kept SI in 2005 due to high GOR. Well is candidate for UZI injector where the conversion pkg approval had been obtained and scheduled for start up in mid 2007. The objective of this WRP set is to abandon the existing perforations in Zone 2. The add perforation in zone 4 will follow after WRP is set. Injection conformance will be evaluated later after the well is put on injection. A remedial cmt sqz might be needed to ensure the well is injecting in zone to meet UZI injection strategy. B-22A does not have any existing mechanical integrity issues. All cost related to this re completion would be charged to B-22A Facility Conversion AFE. If you have any questions or comments regarding this procedure, please call Herry Subekti at (W) 564- 5112, 349-0215(H), or (C) 744-0937. cc: w/a: Well File Jennifer Julian ...\t~ ....... ~..~ --.."'- ." Cost: CC or AFE: lOR: . . PERFORATING PROCEDURE Well: Date: B-22A ............................................... 5/15/07 API #: 50-029-20759-01 .............-.................. _nouuuounouun......uu Prod Engr.~~!~'>::9~t:E;~i. _.. Office Ph: Home Ph: Cell/Pager: 564-5112 .~~~~~-~~~------------------- 349-0215 .,.,.,.,~~..,.,.,.,.,.,.,~.,~~.....'.,.,~~. 744-0937 H2S Level: .----------------------. ---------------- 25 ppm 1/25/03 B 26B .nnn......nUnnnnnnnn $30,000 .......................................-..... AFE 4P2507 .----------------------. 500 ............................................................. ~~~~~~~~~~~~~~~~~~~~~~r. WBL Entries lOR Type Work Oesciption Priority/Comments 1 : ~ ~ ~ }J~ò. ~ ~ ~ ¡ ~ ~ ~ ~ ~ ~ $ ~ ~ ~ ~ ~ ~ 1 Þri!f pr~~?~~p.~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 1 ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~} 2: 500: E : Perforate 58' 10134'-10192'MO : ~ ~----------~-------------~--------------------------------~--------------------------------~ { ~ f f . ~__________1_____________~________________________________!____________________~~~~~~~~~~~~J Well Ob'ectives and Perforatina Notes: Min 10 = 3.725"@ 9711' MO, 4-1/2" HES XN Nipple; Angle at Min 10 = 31 deg Max Angle to adperfs - 52 deg @ 10192' MD; Angle at current perforations = 51 deg Well was ST in 2001 and opened in Z2BU. The well was wet since the beginning. Add perf on 5/14/05 did not help the production (high GOR). The current Z2 production will be isolated and Z4 will be perforated to establish injection in Z4 as part of UZI project. Log: Date: Attachment: Reference log with proposed perfs annotated, 1"/100' scale Tie in Log SCMT ...~...~~...~~~.... 5/31/2001 --..-................... SWS Add 0 .,.~,.,.,.,.,.,.,.,...~~~,.,. to the tie-in log to be on depth with the reference log. Reference Log MWD .~~~"'''''''.........~ 4/23/2001 ............................... Company: "~P!3!ry, ~.u.n. Depths (from-to) ...1.q"!?~'.. -.Jg,)~?:_ feet ...~~~~~..~....... Depths (from-to) Jq,.~~~:.. ...1_q"!~?:.. Feet 58 SPF 6 Orient. Random Phasing 60° Zone Ad/Rellperf ...4. _ .... .A<:!(>~.~..... ~...............~~...............~ _......~..........................."'''''''....... ..............................~~ ....~~..................... ............................... ..........~...~...~......~ ...~.........~~...~.............. -.........................................."'. ........~~~...~~......_-_................ ......~......~~~........ ............................... ............................... ....~~...~~............ .. ~ ~....... ...... "'..... ..................'""'........................" ....... "'........... "'....................................... ~.~~~..~...."'... ............................... ~.......................... .............."'..."'''''''.. .."''''.''''''...'''................. ...................................................." ................."'........................................... ......................"'..."'... ......................"'...... "'''''''...~......~...'''. .......~"''''''''''...'''..... .........."''''....................... _...........................~....................., .~............................................................... ...~~......."'............... ................"''''......''' ............~~~~~.. ................................. ......"'.....................~........ ...............................~................... ................................................................... .........~........................ ..........~~~~"''''... ............................... . "'............................. .......................................~ .~................................."'............" .................................."''''~........................ Requested Gun Size: ... .2..-?!~o:... Charge: .?~.q9 .f;>?":Y_~~~C?!,.Ij~.QJjJ0X... Is Drawdown Necessary/Desired/Unnecessary During Perforating Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Prod: Last Tag: _ Y~~!3.c!3.s.s.a.ry...................... _............ _... _ _. _ _ _ _ _. _. __ NA .,.,.,.'.'.'M.'M.'.....RER.'....'.'.'EE..E..'.'.'.,.,~~EE...._E..'.'.._.E~.'..~_.,.,.,. 268 BOPD . ___~,_o_~~__. BWPD 129K GOR ...................... -..-----............- "'" ,1 9.¡~~1.... ft MD on 5/14/2005 Est Res. Pres. @ ....1 9¡~~~.,.. MD is 3244 psi . ~ ,. ,. ,. ,. ~ ~ ~ '. '." ..,.'..~~~~~~..,.,.,.,.,.~, B-22A Summary Dist Town: Prod Engr: ............ . ............ Anch Prod Engr P.D. Center Well: Date: General Comments: Perforation Summary API#: 50-029-20759-01 . ,. ,. ~ .. .. .' .' .' .' .' ...................~......~~~~~~............... PBTD .....................'.'...'.-.....'. ............... .......... ........................ ....... ... ........... ................. ..... .....,.,.,.,.,.,.,.,...,.....,.,.,.,...,.,.,.,.....,...,.,.,.,.,.,...,.,.,.,...,.,.....,...,.,.,.,.,.,.,.,.,.,.,...,.,.,.,.,.,.,.,.,.,..'....,...,.,.,.,.,.,.,.,.,.,.,.,.,.,.,.,.,.,.,.,.........,.,.,.,.,.,.....,.....,.,.,.,.,.,.,.....,. Zone Adperf/Reperf Balance O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Gun Dia. Orient. SPF Phasing ........... ... ........ .... ....... ............. . ................... ...... ................ ..... ...... ........ ... ........... ............. . ......... .......... ............ ...... .... ..... ...... ........... ........... ............. . '........... ....... .......... ........ .... ........... ........... ........... ,............ . .. ........... ..... .. ...... ........ ...... ........... ........... .... ....... ,.... ......... ,... .......... ..... . ..... .......... ...... ........... ...... ..... ........... ..... ......... .... .... ........... . .... ................. ........... ........... ........... .............. ,... .... ........ ... ............... ....... ........... ........... ........ ... .............. ,.... .............. ...... ................ . . Area of Review ß-22A UZI Conversion Project: To convert inactive producer B-22A into an Updip Zone 4 Injector (UZI) capable of both water and MI injection. The objective of the conversion is to provide pressure support to current producers, improve volumetric sweep efficiency and to mobilize and capture remaining oil saturation above the expanded GOe. This conversion was included as part of the Waterwheel 3 West project which delivered makeup water injection volumes to GC-3. This program is also consistent with a larger regional strategy to manage and develop the GDWFI area in a manner that considers the maturity of the waterflood areas, the maturing of the GD process and the possible impact of gas sales on overall recovery. B-22A has produced from Ivishak Z2 and will be recompleted for MI injection into Zone 4 as part of the Updip Zone 4 Injection (UZI) project for a period of one to two years until the GOR's in the surrounding producers - especially the up dip wells - decrease in response to injection. The MI slug will be followed by chase water injection for at least 7 years. The UZI project will utilize water injection capacity in GC-3 and prevent further gas encroachment into GDWFI areas. ~-"ð). \<6ð-o~ ß-22A status: Well B-22A was rig sidetracked and completed on 05/07/01. The well produced 100% water cut when brought on line after initial perforations in Zone 2 on 06/02/01 and was shut-in. Close proximity to an East-West fault might explain the high watercut relative to the offset producers in the same fault terrace. B-22A is offset by B- 14 (493 BOPD, 66% WC, 48K GOR on 11/14/2006) and B-29A (508 BOPD, 1 % WC, 77K GaR on 10/1/2006). B-22A had 20 feet of additional perforations in upper Zone 2 shot in May 2005. Oil production increased to 383 BOPD with 95% watercut, but the GOR was above 49,000. Several attempts to reduce the gas production by adjusting the choke size were not successful; the GaR exceeds MGOR (last test on 6/17/2005 was 129k) and the well was shut-in. A separate well work program using service coil will be submitted to abandon the existing perforations in Zone 2 and recomplete to Zone 4. B- 22A does not have any existing mechanical integrity issues. B-22A Production liner primary cementing: No lost circulation was reported during 4- 1/2" liner primary cementing on 5/5/2001. 31 bbls of 15.8 Class G tail slurry was pumped, bumped plug 3200# and float equipment was holding when running tool was released. Approximately 80 bbls of cement contaminated mud was recovered on bottom up circulation up post cementing. 4-1/2" liner was tested to 3500# during completion. Subsequent SCMT log was run on May 31,2001 indicated a fair isolation between Ivishak Zone 4 and the target injection Ivishak Zone 2 (PIs see section copy attached). Offset wells within 1/4 mile : , ~ <ø - \\ \ \ '~~-Od-C) 1. ß-02 within 750 ft : The well has been abandoned and sidetracked to B-02A. \G;d-\ \;} 2. ß-23 within 940 ft : The well has been abandoned and sidetracked to B-23A. 34 bbls of 15.8 ppg cmt slurry was sqz'ed below EZSV at 9275'MD on P&A April 22,1997. . . \'-\~~ 3. B-23A within 1260 ft. The well was rig sidetracked in 1997 and completed with 4-112" solid cemented and perforated liner. The most recent RWO was done in May 2005 for a simple tbg swap. The well is currently producing from Ivishak zone 2B with the last test of 595 STBOPD, 1448 BFPD, 24 K GOR( 06/05/2007). The 4-112" liner was run and cemented without difficulties, although it was noted that a 35 bbls per hour loss rate was experienced while circulating and cementing. No losses after cementing. Total 54 bbls of 15.7 ppg class G cement slurry was pumped. No CBL log has been run in the well. 4. X-27 within 860 ft. The well was was drilled and completed on June 08,1984 with 7" solid cemented and perforated liner . The well is currently on line producing from Zone 3 and zone 4 Ivishak with the last test of 1050 STBOPD, 5790 BFPD, 25 K GOR (05/27/2007). 35 bbls of sepiolite followed by 320 cu ft 267 sacks of class G cement with 18% salt was pumped during the 7" primary cementing. No cement found during cleaning out to top of liner and liner lap would not test. A subsequent remedial liner lap sqz was done with 102 cu ft class G cement with 18% salt thru EZ drill that was set at 10772'MD. Liner lap was then tested to 3000# & passed. CBL log run 6/7/84 prior to running completion and well perforation to confinn a sufficient isolation.. \ G;\A -tJ~ '" Well work scope: 1) Dummy off all mandrels. 2) Press test completion: MITIA-4000#. LLR if fails. 3) Perforate Ivishak zone 4 10,134' -1O,192'MD (58 ft), set WRP in the liner to isolate the existing Ivishak Z2 prior to POI. TREE = WELLHEAD'" ACTUA TOR= KB. ELEV = BF. ELEV - KOP= Max Angle = Datum MD = DatumTVD= 4-1/16" CrN MCEVOY AXELSON 73' 45' 3000' 53 @ 10349' 10466' 8800' SS B-22A SAF NOTES: WELL HAS 4-1/2" CHROMETBG AND 4-1/2" CHROM E LNR. PRE-SDTRK WELLBORE NOT SHOWN ON DIAGRAM BELOW MILLOUT WINDOW. --I 4-1/2" HES X NIP, ID = 3.813" I I 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" l-i 2676' ~ 2620' -i 9-5/8" DV PKR I Minimum ID = 3.725" @ 9711' 4-1/2" HES XN NIPPLE 9-5/8" X 7" BKR ZXP LNR TOP --I 6832' 1- PKR/HNGR, ID = 6.270" 7" X 4-1/2" BKR ZXP LNR TOP PKR WITIEBACK, ID = 4.375" 4-1/2" TBG, 12.6#, 13CR-80, V AM-ACE, .0152 bpf, ID = 3.958" ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: 51 @ 10510' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10510 - 10530 0 05/14/05 2-7/8" 4 10630 - 10655 0 06/02/01 2-7/8" 4 10690 - 10720 0 06/02/01 GAS LIFT MANDRELS ST MD TVD DEV TYÆ SIZE 5 3028 2944 12 MMG 1-1/2" 4 4061 3875 39 MMG 1-1/2" 3 6607 5735 46 MMG 1-1/2" 2 8440 7183 31 KBG-2 1" 1 9597 8163 31 KBG-2 1" LA TCH RK RK RK BK BK 4-1/2" HES X NIP, ID = 3.813" 7" X 4-1/2" BKR S-3 PKR, ID = 3.867" 4-1/2" HES X NIP, ID = 3.813" I 4-1/2" HES XN NIP, ID = 3.725" I 4-1/2" WLEG I ELMD TT NOT LOGGED TOP OF MILLOUT WINDOW @ 6977' 9905' 7" LNR, 26#, L-80 BTC, ID = 6.276" 10817' HPBTD I 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" l-i 10305' l"- I 4-1/2" LNR, 12.6#, 13CR-80, V AM-ACE, .0152 bpf, ID = 3.958" l-i 10902' I DATE 08/30/82 01/31/01 03/07/01 05/07/01 OS/26/01 11/18/02 PRUDHOE BA Y UNIT WELL: B-22A ÆRMIT No: '2001570 API No: 50-029-20759-01 SEC 31, T11 N, R14E, 2317' NSL & 4092' WEL DATE REV BY COMMENTS 05/14/05 NBF/PJC ÆRFORATION REV BY COMMENTS ORIGINAL COMPLETION SIS-SLT CONVERTED TO CANVAS SIS-LG FINAL RIG SIDETRACK CH/TP CORRECTIONS JW/KAK ÆRF CORRECTIONS BP Exploration (Alaska) · · · , , · · · · 102( 0 ~ - , .... - · , - t-:- -- , · · , · · , , 00 .- ..... ~ 0' , -:' · , _i- , 0 · I I , i I · · o' .0 I ......... . , '- , .. - - · · I · I . i-! I · I I · I I' , ,- · - .- · . -. .. · , . . . -- 0 I -I . 0- 103( 0 ~ - c.::.:: - ..... · · 1:.. · · - I · T ! T , ....... ~ · I· -: -.. · t: , I I ! , T ì T · ·T ..oil! I · i ~ , · ; · , I ; T I , I · 104( 0 , · , , , ..1-. . .- , · - . · - , · - - - f-- , f-- - f-- - i-- I , I , t , I I I I I ..J-.J . . Page 1 of 1 Maunder, Thomas E (DOA) From: Subekti, Herry [Herry.Subekti@bp.com] Sent: Thursday, July 12, 20079:30 AM To: Maunder, Thomas E (DOA) Cc: Preble, Gary B (SAIC) Subject: RE: B-22A Tom, Thank you for the quick response. Really appreciate it Answering your question, yes, this well will be converted into injector in Zone 4 Ivishak. Pis advise if you need any other information. Rgds HS From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) Sent: Thursday, July 12,20079:11 AM To: SUbekti, Herry Cc: Preble, Gary B (SAle) Subject: B-22A Herry , We have received the sundry. The application reads that BP is intending to convert the well to injection. but that is not entered in Block 1. Is the intent to convert to injector? Thanks, Tom Maunder, PE AOGCC 19 2007 scANNED jUL 7/12/2007 . . MEC~~ICAL INTEGRITY REPORT aOQ-- \ 5 '\ "'-." :~~G 2S~~;'_S::: OPER á FIELD ~Ç> þt".)ð~C- ~'f- w~LL NUM:BER ~ - ã d- ~ :: ?üD G _:.:::: - '"'\I~~ - () \ 'rl~LL DAT}·_ J,.\NU'" 'r\ ., ~s..¡.~ : \ ID: '()~O")MD. C\ 'S"\ TVD; :?ETD: l-t)~\~ MD <1<1\~ TV!) Shoe: C\<$)S'" HD TilD j íbi>: ~C¡?>:> 11]) -T'Vu _:':1e~ : '-\'1") Shoe: \~~$').. 'MJ) ::.¡bi::g: 14'1) Packer Gb'\' HD ::01 e S:"z e <is \ I'). a.nå l.ø '~ !V'D; :OP: ~'d<\ HD :..-D TV1) ; See ê.t: Go '\S \ " \t)\ ~LL! ~~~1"\.t~ Perfs :SC?..Þ~-1IC;'J... INTEGRITY - PART f I Anhulus Press Test: 7~ 15 ül~n 30 min Co¡:¡¡¡:¡}ents: /' SGft\NNED JUL 1 '9 2007 ~CH1Ü\fICAL INTEGRITY - PART /2 Cemenc Volumes :-, l--IIlt. Liner \~\\\; l...'~r 3\~\.\ DV ~~ CUlt: -·m1 to cover perfs ~<å{ 'Þ\.> \~ ~ c:()~cr~ \>e~~ (..~""~\- <:O"-~~\1'CL\tð t\~~ órc..u\u\-~'d O.\Ç TC L Theoret:ical Toe Cement: Bond Log (Yes or No) ~É.: ~ j In AOGCC File CBL Evaluation, =ooe above perfs <..""'~"'"> ~~~. ~"'a~ 'o(),~~)''\ "'"~ 0"- ~~ \~'> Prociuc.tion Log: Type Evaluation CONc;LUSIONS: ?art: i1: \-\!: ~ ,~,~~ /ð2.. 'VV\ '\1, i' -O~ ?ar-:: f2: AI~~1iA. OIL Al'Q) GAS CONSERVATION COMMISSION . / / I SARAH PALIN, GOVERNOR . ~V~VŒ lID~ ~~~~[K(~ 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279·1433 FAX (907) 276-7542 Heny Subekti Drilling Engineer BP Exploration (Alaska) Inc PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Niakuk Oil Pool, B-22A Sundry Number: 307 -168 5~~ JUN 1 1 2007 Dear Mr. Subekti: Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. According to the workover operations matrix, the proposed work does not require filing a sundry notice. DATED this.l:. day of June, 2007 Enc!. éJCO-/6-~ _..~ -?RECEIVED . STATE OF ALASKA .s:~.pf" Al A Oil AND GAS CONSERVATION COMMe)N MAY 2 1 2007 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool 0 4. Current Well Class: Development ø Abandon Alter casing D Change approved program D 2. Operator Name: 1. Type of Request: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Exploratory 0 Service 0 -.,'" "...... Stratigraphic 0 Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes D 9. Property Designation: Descriotive Summary Detailed Operations Program 0 BO 14. Estimated Date for 11. Total Depth MD (ft): 10902 Casing CONDUCTOR SURFACE PRODUCTION LINER LINER Perforation Depth MD (ft): 10510 - 10720 Packers and SSSV Type: 12. Attachments: Commencing Operations: 16. Verbal Approval: 17. I hereby certify Printed Name Signature Other: o No ADLO-028310 10. KB Elevation (It): 11. Field/Pools(s): 72.3 KB PRUDHO PRESENT WELL CONDITION SUMMARY Effective Depth MD (It): Effective Depth TVD (It): 10817 9099 None Collapse 470 2670 4760 5410 7500 Total Depth TVD (It): 9157 Length Size Burst 110 20" 91.5# H-40 28 1490 2649 13-3/8" 72# L-80 27 2676 4930 6951 9-5/8" 47# L·80 26 6070 6870 3073 7" 26# L-80 6832 8501 7240 1173 4·1/2" 12.6# 13Cr80 9729 9157 8430 Perforation Depth TVD (It): 8902 - 9034 Tubing MD (It): 24 - 9731 7" Baker ZXP Mech Liner Top Packer 4·1/2" Baker S-3 Hydro Set Packer 4-1/2" Baker ZXP LNR TOP PKR 6832 9677 9729 o rop sed work: Developm ent ø Service 0 Oil ø WAG 0 o 0 Abandoned 0 o WINJ 0 WDSPL 0 Prepared by \.:IälY t"'Itlule 564-4944 o ect t!' the best of my knowledge. Title Contact Herry Subekti Production Engineer 5/21/2007 Phone 564-5112 COMMISSION USE ONLY Date mmission so that a representative may witness Sundry Number: 3J7 - t to 8 Mechanical Integrity Test D Location Clearance D 6- Submit in Duplicate bp .,. ,\1'.'11. --..~ ~#.- ~.,- ~.,- ..#~ ~.... ·'1'·'-\- ". . . To: Clark Olsen /Jerry Bixby, GPB Well Ops TL Date: May 15, 2007 From: Herry Subekti, B pad engineer Subject: B-22A WRP & Add oeñoration AFE 4P2605 Pre UZI conversion Est. Cost: $40 M lOR: 500 Please set WRP & Add perforation in the B-22A. This procedure includes the following major steps: Step Type Procedure 1 S Drift/Tag pre perforation. DGL V sta#3,#4. Set WRP in the liner @ 10,455'MD 2 DHD T&IA FL's 3 FB Liquid pack T & IA. Press up tbg 1500#. MITIA-4000#. MIT-3000#. If either fails CMIT- TxlA 3000#. LLR if any fails. 4 EP Correlate and perforate 10,134'-10,192' (58 ft) - Pending Press test. SI high GOR 6/17/05268 BOPD, 3292 BFPD, 129K GOR, 63.9 Choke 53 degrees @ 10349'MD 51 degrees @ 1051 O'MD 3.725" @ 9711' (4-1/2" HES XN Nipple) Tagged TD at 1 0661'ELMD during perforation 5/14/05 Static survey 7/23/06 Not in Database MWD 4/23/2001 3244#/216°F @ -8800'TVD SS 4.5" prod liner tested 3500# 5/6/2001 7"X4-1/2" BKR S3 packer was tested to 3500# 5/7/01 Well B-22A was rig sidetracked and completed on 05/07/01. The well was wet since the beginning. Add perf was done on 5/14/2005 but did not help the productivity. The well was kept SI in 2005 due to high GOR. Well is candidate for UZI injector where the conversion pkg approval had been obtained and scheduled for start up in mid 2007. Status: Last test: Max Deviation: Perf Deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S level: Reference Log Est BHP/BHT Note The objective of this WRP set is to abandon the existing perforations in Zone 2. The add perforation in zone 4 will follow after WRP is set. Injection conformance will be evaluated later after the well is put on injection. A remedial cmt sqz might be needed to ensure the well is injecting in zone to meet UZI injection strategy. B-22A does not have any existing mechanical integrity issues. All cost related to this re completion would be charged to B-15 CRWO AFE. If you have any questions or comments regarding this procedure, please call Herry Subekti at (W) 564- 5112, 349-0215(H), or (C) 744-0937. cc: w/a: Well File Jennifer Julian Well: Date: Cost: CC or AFE: lOR: . . PERFORATING PROCEDURE B-22A ~~~~~~~'~~~~-----------' 5/15/07 API #: 50-029-20759-01 Office Ph: Home Ph: Cell/Pager: 564-5112 .~~~~~~~~~~~~~~~~~~~~~~~~~~~~ 349-0215 ~..~.'....~.,_.,---_.,.,-_.,.,_.,_...,.,.,. 744-0937 ................................j. H2S Level: i ~~:.~~:~~:~~~:.~ i ----------------- .~~~~~----------------_. Prod Engr.~~!~'I:?~~~~i___. .---------------------------- WBL Entries lOR Type Work Desciption Priority/Comments 1 ¡ ~~ ~ §P.ò. ~ ~ ~: ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ 1~ri!t.P!~~9~P.~~~ ~~ ~ ~~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ 1 ~ ~ ~ ~ ~ ~~~~~ ~~ ~ ~ ~ ~ ~ ~ ~ ~~~~ ~~~~ ~ ~ ~ ~ ~} 2 ;... .5.~~...:.....!Of... ..l~~!!~r.~t~~~~. J 9]~::! º! ??~Iy!I?. .1~~!1.c:!i!1.Q p'r~.~~~~ .t~~!.. ---........1 ,¡ l t ~ ~~_________1_____________j________________________________J________________________________j Log: Date: Attachment Reference log with proposed perfs annotated, 1"/100' scale Tie in Log SCMT ............................. 5/31/2001 ........................ ._.~Y:J..~.... $30,000 -----------------------" AFE 4P2605 ............................................................. 500 ~....................._.._......_............__.......... Depths (from-to) J.q,J?~:.. - ...1.Q"1§J?:.. Feet 58 SPF 6 Well Obiectives and PerforatinM Notes: Min ID = 3.725" @ 9711 ' MD, 4·1/2" HE5 XN Nipple; Angle at Min ID = 31 deg Max Angle to adperfs - 52 deg @ 10192' MD; Angle at current perforations = 51 deg Well was 5T in 2001 and opened in Z2BU. The well was wet since the beginning. Add perf on 5/14/05 did not help the production (high GOR). The current Z2 production wiil be isolated and Z4 wiil be perforated to establish injection In Z4 as pasr of UZI project. Reference Log MWD ~.................... 4/23/2001 ~.......-............ Company: ,~P~!~ ~.u."!. Depths (from-to) ...1.QJ~~'.. - ...1.q,J??:. .......................... ..................... ..................... .........-_........~ ....................-..... ......................... ......................... ._-......................~ ................................. ............................. .......................... ............................ ............................. ............................ ........................... ............................. ................................ ......................... .....................v ............................ ......................... ..................... ......................... ....................... feet Add 0 ._--,..,.'.'.,.~..,.,._,..,. to the tie-in log to be on depth with the reference log. Orient. Random Phasing 60° Zone Ad/Re!lperf ...4....... Aqp.~.~..... ..............................~ ........................................ ................................. ....................................-. ............................................... ............................. ..................................... ....................-........................... ............................... .............-....................... .......---~~~--~~~......_..._-~-~ ~.........~......................." ~......-..................~~~...~......_" ...._~...-..._-_...........~~..._-_......... .......-...-....................... a........................_........_............. ._..........._..................__.............._...... ........................................ a................................................· ..........__........................................._...... Requested Gun Size: ....2:?!~':... Charge: .?~.q~ .~£\Y.~~~~!,.Ij~p. .tl.¥X... Is Drawdown NecessarylDesiredlUnnecessary During Perforating Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Prod: Last Tag: 268 BOPD . __ _ ~'!>_~~ _ _. BWPD . Y!:,!:,~~!!.s_s.?ry . . . . _ _ . _ _ . . . . . . _ . _ . . _ . _ . . _ . . . . . _ . _ _ _ _ _ _ . . _ . . . . . _ _ . . _ .~~..............,._........._..................._............. 129K GOR ............................ ..., } 9\1~~.... MD Is psi ........................ ... } 9\~~L. ft MD on . .. ~/.1.4!?~~? .. Est Res. Pres. @ 3244 ------.,...--.--...,. Well: Date: General Comments: Perforation Summary B-22A API#: 50-029-20759-01 Summary Dist ¡Town: Prod Engr: ,. . . . .' ... .,. ....... ...... Anch Prod Engr P.D. Center PBTD .'.............'.'.'.'.'.'...'.'...'.............'. . ~ .' .' .' .' .. .' .. .' .' ............................................................ ... .......... ... ...... ... ................ ................. ................. ........... ...... Depths Referenced to BHCS Gun Dia. Orient. SPF ..........................................,.......,.,.........,.....,.......,....,......................,..,.,...,....,...,.....................,....... .....,......,.,....,...............................,.......,.......... Phasing Zone Ad perflReperf Balance O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U O/B/U ........... ........... ........... .... ....... ....... .... ...... ..... .... ....... ........... ........ ... .....,..... ........... ........ ... ...., I ..," ........... ........... ...., ...... ........... ........... ....., ..,.. ... I ....... ....... .... ........... .,, ........ ........... .,............ ,..... ......... .... ..... ....... .... ...... ............. . ,.............. .,.' I....... I.. .... I ...... I........... .. ,.................. .......... ............ I........... ., ,........ .......... . ..... .... .... ........ .......... .... ,........ ... ....... ... ........... ........ .............. ......... ...... .... ..... ........ .... ..... .............. ,.. ............ .... .... ........ ...... .... ... ........... ... ................ ... ........ ........... ,. ....... '" '" .... ..... ....... .......... . . TREE = W'EU_HEA ACTUA TOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD= 4-1/16" CrN MCEVOY AXELSON 73' 45' 3000' 53 @ 10349' 10466' 8800' SS B-22A SAF TES: WELL HAS 4-1/2" CHROM E TBG AND 4-1/2" CHROM E LNR. PRE-SDTRK WELLBORE NOT SHOWN ON DIAGRAM BELOW M ILLOUT WINDOW. -1 4-1/2"HESXNIP,ID-3.813" I I 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" I~ 2676' ~ 2620' -i 9-5/8" DV A<R I Minimum ID = 3.725" @ 9711' 4-1/2" HES XN NIPPLE GAS LIFT MANDRELS ST MD TVD DEV TYPE SIZE 5 3028 2944 12 MMG 1-1/2" 4 4061 3875 39 MMG 1-1/2" 3 6607 5735 46 MMG 1-1/2" 2 8440 7183 31 KBG-2 1" 1 9597 8163 31 KBG-2 1" LATCH RK RK RK BK BK 9-5/8" X 7" BKR ZXP LNR TOP -1 6832' 1- A<RlHNGR, ID = 6.270" 7" X 4-1/2" BKRZXPLNRTOPA<R W/TIEBACK, ID = 4.375" 4·1/2" HES X NIP, ID = 3.813" 7" X 4-1/2" BKR S-3 A<R, ID = 3.867" 4-1/2" HES X NIP, ID = 3.813" I 4-1/2" HES XN NIP, ID = 3.725" I 4-1/2" WLEG I ELMD TT NOT LOGGED 4-112" TBG, 12.6#, 13CR-80, V AM-ACE, .0152 bpf, ID = 3.958" TOP OF MILLOUT WINDOW @ 6977' ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: 51 @ 10510' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-7/8" 6 10510 - 10530 0 05/14/05 2-7/8" 4 10630 - 10655 0 06/02/01 2-7/8" 4 10690 - 10720 0 06/02/01 9905' 7" LNR, 26#, L-80 BTC, ID = 6.276" 9-5/8" CSG, 47#, L-80 STC, ID = 8.681" l-i 10305' r-- I 4-1/2" LNR, 12.6#, 13CR-80, VAM-ACE, .0152 bpf, ID = 3.958" 1--1 DATE 08/30/82 01/31/01 03/07/01 05/07/01 OS/26/01 11/18/02 REV BY COMMENTS ORIGINAL COMA-ETION SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL RIG SIDETRACK CH/TP CORRECTIONS JW/KAK PERF CORRECTIONS DATE REV BY COMMENTS 05/14/05 NBF/PJC ÆRFORATION PRUDHOE SAY UNrr WELL: B·22A PERMrr No: "2001570 API No: 50-029-20759-01 SEC 31, T11 N, R14E, 2317' NSL & 4092' WEL BP Exploration (Alaska) B-22A (200-157) . . Herry, I have received your sundry application to place a plug above the existing perforations in B-22A and then perforate higher. It appears that all of this work will take place within the defined Prudhoe Bay Oil Pool. Since this is a production well and will remain so after the work is performed, according to the Sundry Matrix no sundry is required. See the middle column of page 1 of the attached document. We will be returning the sundry as not needed. If you are unfamiliar with the matrix, you might check with Harry Engel. He was a member of the group that helped draft the matrix. Call or message with any questions. Regards, Tom Maunder, PE AOGCC Content-Type: application/pdf SundryMatrix-1.pdf! . . Content-Encodmg: base64 1 of 1 6/5/2007 5:54 PM "~ ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA1jÐfij~:¡J 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ŒJ ExploratoryD Stimulate D JUN 2 Ii 200~therD ~~~~GJOi! & mWß~:~~~,~r~i.iQ~Çl" Re-~ht~rJ$..~~~~~ded Well D 5. Permit to Drill Number: 200-1570 6. API Number 50-029-20759-01-00 Service D 1. Operations Periormed: Abandon D Alter CasingD Change Approved Program D Repair WellD Pull Tubing 0 Operation Shutdown 0 PluQ Perforations D Perforate New Pool D Perforate IX) P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 72.30 8. Property Designation: ADL-028310 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: B-22A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 10902 feet true vertical 9156.8 feet Effective Depth measured 10817 feet true vertical 9098.9 feet Plugs (measured) Tag TD @ 10661 ELMD (05-14-2005) Junk (measured) None Casing Length Size MD TVD Bu rst Collapse CONDUCTOR 110 20" 91.5# H-40 28 138 28.0 138.0 1490 470 SURFACE 2649 13-3/8" 72# L-80 27 - 2676 27.0 - 2675.7 4930 2670 PRODUCTION 6951 9-5/8" 47# L-80 26 - 6977 26.0 - 6069.8 6870 4760 LINER 3073 7" 26# L-80 6832 - 9905 5969.1 - 8500.9 7240 5410 LINER 1173 4-1/2" 12.6# 13Cr80 9729 - 10902 8349.0 - 9156.8 8430 7500 Perforation depth: Measured depth: 10510 - 10530, 10630 -10655,10690 -10720 SCANNE.D JUt o 7 2.005 True vertical depth: 8901.52 - 8914.08,8976.9 - 8992.74,9015.08 - 9034.39 TubinQ ( size, Qrade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 24 9731 Packers & SSSV (type & measured depth): 7" Baker ZXP Liner Packer 4-1/2" Baker S-3 Packer 4-1/2" Baker ZXP Liner Packer 4-1/2" HES X Nipple @ @ @ @ 6832 9677 9729 2214 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl SHUT-IN 257 Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 13 10943 4344 1149 ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Development ŒJ Service D 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne Schnorr Printed Name DeWayne Schnorr ) /) . Signature 4'~.. vf' J~ Title Petroleum Engineer Phone 564-5174 Date 6/22/05 RBDMS BFL JUN 2 4 Z005 Form 10-404 Revised 4/2004 ) ) B-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY JUN 2 4i Z005 ,)~~J~ 05/13/05 ***WELL SHUT IN ON ARRIVAL*** (DRIFT W/3 3/8" D-GUN PRE ADPERF) ***. DRIFT W/3 3/8" DUMMY GUN ISB TO 10649' SLM WORKED THROUGH TIGHT SPOTS @ 9935 TO 9963' SLM. PIU WEIGHT 1200# @ 9935 THROUGH 9963 SLM. PIU WEIGHT OFF BTM = 1050 #. APPROX. 70' OF FILL. S BAILER EMPTY. TARGET DEPTH = 10530' MD.. *** LEFT WELL SHUT IN*** 05/14/05 CORRELATION LOG SWS CEMENT BOND LOG DATED 31-MAY-2001. PERFORATED 10510 - 10530 FT WITH 2-7/8 PJ 2906 HSD HMX 6 SPF 60 DEG PHASE. ALL SHOTS FIRED. LEFT WELL SHUT IN. TAGGED TD AT 10661 FT. FLUIDS PUMPED BBLS o No Fluids Pumped o TOTAL Page 1 9-5/8" X 7" BKR ZXP LNR TOP -I 6832' r-~ ~ PKR/HNGR, ID = 6.270" I I 9666' Z Z 9677' ~~ ~ 9700' 9711' 7" X 4-1/2" BKR ZXP LNR TOP PKR -I 9729' W/TIEBACK, ID = 4.375" I~ ~ 9733' 4-1/2" TBG, 12.6#, 13CR-80, -I 9731' VAM-ACE, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" 1-1 10305' 1 I 4-1/2" LNR, 12.6#, 13CR-80, VAM-ACE, .0152 bpf, ID = 3.958" 1-1 10902' 1 DA TE REV BY COMMENTS 05/14/05 NBF/PJC ÆRFORA TION , TREE = .Y'!,~~~Ij§l\ ~~, ... ACTUA TOR= } ................................... KB. ELEV = BF. ELEV = , ,,~'"'''''' . ....., .... "... KOP= Max Angle = ",,"""" """,,,,,.,,,,, "".. , """ , , Datum MD = Datum rvD= 4-1/16" CrN MCEVOY AXELSON 73' 45' 3000' "....~.~..(~..~.~.~~.~.'. 1 0466' 8800' SS ) I 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 1-1 2676' Minimum ID = 3.725" @ 9711' 4-1/2" HES XN NIPPLE ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: 51 @ 10510' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 10510 - 10530 0 05/14/05 2-7/8" 4 1 0630 - 1 0655 0 06/02/01 2-7/8" 4 1 0690 - 1 0720 0 06/02/01 DATE 08/30/82 01/31/01 03/07/01 05/07/01 OS/26/01 11/18/02 REV BY COMMENTS ORIGINA L COMPLETION SIS-SL T CONVERTED TO CANV AS SIS-LG FINAL RIG SIDETRACK CH/TP CORRECTIONS JW/KAK ÆRF CORRECTIONS B-22A ~ J ~t...) NOTES: WELL HAS 4·1/2" CHROM E TBG AND 4·112" CHROM E LNR. PRE-SDTRK WEL L BORE NOT SHOWN ON DIAGRAM BELOW M ILLOUT WINDOW. 2214' 1-1 4-1/2" HES X NIP, ID = 3.813" 1 ~~ -----1 ~ 2620' 1-1 9-5/8" DV PKR 1 L GAS LIFT MANDRELS ST MD rvD DEV TYÆ SIZE 5 3028 2944 12 MMG 1-1/2" 4 4061 3875 39 MMG 1-1/2" 3 6607 5735 46 MMG 1-1/2" 2 8440 7183 31 KBG-2 1" 1 9597 8163 31 KBG-2 1" LA TCH RK RK RK BK BK JUN 2 4 2.005 r-14-1/2" HES X NIP, ID = 3.813" 1 r-I 7" X 4-1/2" BKR S-3 PKR, 10 = 3.867" I 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 I--L 4-1/2" HES XN NIP, ID = 3.725" 1-1 4-1/2" WLEG 1 ELMD TT NOT LOGGED TOP OF MILLOUT WINDOW @ 6977' 9905' 1- 7" LNR, 26#, L-80 BTC, ID = 6.276" ...... .......... . ~ ~ . ¿ ~"X xx X ... PRUDHOE BA Y UNIT WELL: B-22A ÆRMIT No: '2001570 API No: 50-029-20759-01 SEC 31, T11 N, R14E, 2317' NSL & 4092' WEL BP Exploration (Alaska) F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C4:~'.'-' ~...........~., . -""!'. ,,' "'.. ~.~~ Permit to Drill 2001570 MD 10902 J TVD DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. PRUDHOE BAY UNIT B-22A Operator BP EXPLORATION (ALASKA) INC 9157 / Completion Dar 6/2/2001 ,-~- Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20759-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type~,Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments Directional Survey R Directional Survey L ~ ., ~ _ Cement Bond Log L ¢~ ~ t/~'~ X..Cemem Bond Log Ver LIS Verification Ver LIS Verification Cn See Notes FINAL FINAL FINAL 9850 10738 FINAL 9850 10738 1 6771 10863 1 6771 10863 1 6772 10902 CH 6/1/2001 CH 6/1/2001 CH 6/22/2001 CH 6/22/2001 Open 7/2/2002 Open 7~2~2002 Case 1/31/2003 Directional Survey, Digital Data Directional Survey, Paper Copy 9850-10738 9850-10738 BL, ScF, ic - 10951 ~ 11562/Digital Well Logging data Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/,,N~ Chips Received? Analysis R ~. r.~. iv~.d ? Daily History Received? ~ N Formation Tops ~__~/N Comments: Permit to Drill 2001570 MD 10902 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. PRUDHOE BAY UNIT B-22A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-20759-01-00 9157 /(mpletion Dat 6/2/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N To~ RE: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950'1 January 30, 2003 MWD Formation Evaluation Logs · B-22A, AK-MM- 10128 B-22A:, Digital Log hnages 50-029-20759-01 I CD Rom PLEASE ACKNOWLEDGE iRECEIPT BY SIGNING AND RETURNING A COPY O.F THE TRANSMITTAL LETTER TO TIlE ATTENTION OF: Sperry-Sun 'Drilling Services Attn: .Rob Kalish 6900 Arctic iBlvd. Anchorage, Alaska 99518 BP ExPloration (Alaska) Inc. Petro-technical .Data Center LR2-1 900 E. Benson 'Blvd. Anchorage, Alaska 99508 Date: RECEIVED JAN ,3 1 2003 ~a Oil & G~ C~ns. Commi~ WELL LOG TRANSMITTAL To: State of Alaska June 27, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 74 Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs B-22A, AK-MM- 10128 1 LDWG formatted Disc with verification listing. API#: 50-029-20759-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED ala~a Oil & Gas Cons. Cmmi~i~ (' STATE OF ALASKA ~i',,.,SION ALASKA OIL AND GAS CONSERVATION COM WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 200-157 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20759-01 4. Location of well at surfaceI ~-:'-"' '[-~"-~¥;TZ'{~"~ LOC.~T~ ' 9. Unit or Lease Name At top of productive interval 2993' SNL, 1213' EWL, SEC. 32, T11N, R14E, UM ~ ~'F_~J.~ii~ ; ~ 10. Well Number At total depth ' B-22A s.., s c. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 72.30' ADL 028310 12. Date Spudded4,27,2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'5,4,2001 6,2,2001 115' Water depth' if Offsh°reN/A MSL 116' N°' °f COmpletiOnsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV setI 21. Thickness of Permafrost 10902 9157 ETI 10817 9099 ETI [] Yes [] NoI (Nipple) 2214' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, NEU, DEN, 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLFD 20" X 30" Insulated Conductor Surface 110' 36" B cu yds Concrete 13-3/8" 72# L-80 Surface 2676' 17-1/2" 3720 cuft Permafrost 9-5/8" 47# L-80 Surface 6977' 12-1/4" 1470 cuft Class 'G'r 130 cuft PF 7" 26# L-80 6832 9905' 8-1/2" 421 cuft Class 'G' 4-1/2" 12.6# 13Cr80 9729' 10902' 6-1/8" 174 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 9733' 9677' MD TVD MD TVD 10630' - 10655' 8977' - 8993' 10690' - 10720' 9015'- 9034' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 151 Bbls of Diesel , , , "27. ' ' PRODUCTION TEST ' ' ,, Date First Production :Method of Operation (Flowing, gas lift, etc.) June 3, 2001 Flowing Date of Test Hours Tested PRODUCTION FOR OIL'BBL GAS'MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure C'ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 2~. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. JUL 1 ;5 ; 001 ~ ,~ L~. Alaska 0il & Gas Cans. Commission Anchorage Form 10-407 Rev. 07-01-80 (~ ~ Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Zone 3 10378' 8818' COWC 10544' 8923' 25N 10636' 8981' 25P 10639' 8983' 24N 10674' 9005' 24P 10690' 9015' HOT 10717' 9032' 23 / 22N 10774' 9070' oowo RECEIVED ,JUL ? g 2001 Alaska Oil & Gas C0~s. Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Formation Integrity Test 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,~~ ~~~--__..~. Title TechnicalAssistant Date B-22A 200-157 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval' No. INSTRUCTIONS GENERAL; This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5; Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 .. : ..... . . .::: .... 'BP'. EXPLORATION Page 1 of 1 ' ' .... '" " ".' .kOffTests mma~ ~:~: · ....~...' '........ Lea., u Legal Name: B-22 Common Name: B-22A TeSt Date... .. . Test TyPe:.:." . ...... Test' DePth.:.(TMD) Test DePth:(TVD)' · ' AMW SU~ce preSSure Leak Off pressure (BHP) EMW 412612001 FIT 7,000.0 (ft) 6,085.0 (ft) 9.80 (ppg) 855 (psi) 3,953 (psi) 12.50 (ppg) 51212001 FIT 9,925.0 (ft) 8,500.0 (ft) 8.50 (ppg) 442 (psi) 4,195 (psi) 9.50 (ppg) Printed: 6/28/2001 2:16:56PM BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: B-22 Common Well Name: B-22A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 4/22/2001 End: 5/7/2001 Contractor Name: NABORS Rig Release: 5/7/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/22/2001 00:00 - 14:30 14.50 MOB P PRE PJST, Move pits, camp, shop, to B pad Lower mast, and secure, commence move rig from DS 17-22 to B-22-A. Move in and spot sub over well. Spot pits, camp, shop. 14:30 - 17:30 3.00 MOB P PRE Make misc connections, raise mast, hang bridle lines, ready rig floor. 17:30 - 19:00 1.50 MOB P PRE Make up working valve on tree, connect circ lines, manifold to cuttings tank, flare line. ( Accept Rig @ 19:00 hrs April 22, 2001 ). 19:00 - 22:30 3.50 MOB P PRE Cont mis¢ connections / rig up, receive fluid, load pipe shed, pull BPV. Note "0" psi tbg and annulus. Start filling Rig mud pits with water. Note: There was severe shortage of trucks today, only one 300 bbl & one 150 bbl Vacume truck came available to haul water. This set us back about 4.5 hrs. 22:30 - 00:00 1.50 MOB P PRE Fill rig mud pits with seawater. Make ready pumps. Prime and test lines 3500 psi. test successful. 4/23/2001 00:00- 05:00 5.00 CLEAN P DECOMP PJSM, cont receive sea water, observe well, 0 psi Commence pump dn annulus, take returns from tbg thru choke, 3 bpm @ 296 psi. Reverse connections, pump dn tbg, take returns 5 1/2 X 9 5/8 ann. Displace ... 150 bbl diesel from well. 05:00 - 07:00 2.00 PULL P DECOMP Flow check, install twc, test tw¢ to 1000 psi dn ann to btm of check. 07:00 - 09:00 2.00 BOPSUF P DECOMP ND tree / adptr flange 09:00 - 12:00 3.00 BOPSUF P DECOMP NU bope, all related components 12:00 - 18:00 6.00 BOPSUF P DECOMP Test bope, all related equip, koomey unit, floor valves to 250 / 3500 psi. all tests successful. 18:00 - 19:30 1.50 PULL P DECOMP Place Camco equip on floor, ru same, ready power tongs, install Idg jr. (PJSM lay out hgr / tbg / lines) 19:30 - 20:30 1.00 PULL P DECOMP Commence pull tbg free, parted with 205K, flow check, pull hgr to floor, remove same. 20:30 - 21:30 1.00 CLEAN P DECOMP Break ¢irc to clear tbg, note foaming / bubbling, fluid out of balance. Cont circ btms up, flow check, well foam free, fluid equalized. 21:30 - 00:00 2.50 PULL P DECOMP Flow check, poh 5 1/2 tbg, disconnect control lines, spooling on reel. 4/24/2001 00:00 - 05:00 5.00 PULL P DECOMP Cont poh laying dn 5 1/2 tbg / control lines, SSSV (25 rubber clamps, 4 SS bands) 05:00 - 05:30 0.50 PULL P DECOMP Inspect top drive 05:30 - 09:30 4.00 PULL P DECOMP Resume poh laying dn 5 1/2 tbg Total 161 jts tbg, cut off 18.36 ft, 5 GLM, 1 SSSV 09:30 - 19:00 9.50 WHSUR P DECOMP Replace 9 5/8 pkf, test to 5000 psi, install wear bushing. 19:00 - 00:00 5.00 CLEAN P DECOMP Assemble bha #1, rih same, follow with 4" dp 186 jts. 4/25/2001 00:00 - 00:30 0.50 CLEAN P DECOMP Cont rih 4" dp to 7010 ft. 00:30-01:00 0.50 CLEAN P DECOMP Flowcheck, putopdr, brkcirc, 175up, 143dn, wash and tag at 7043 ft. 01:00 - 02:00 1.00 CLEAN P DECOMP Cir¢ hi vis pill, take clean returns at shaker. 02:00 - 07:30 5.50 CLEAN P DECOMP Flow check, poh, lay out jar, 1 jt hwdp, pu mill assy. 07:30 - 09:00 1.50 DHEQP P DECOMP PJSM (wireline bridge plug), ru Schlum equip, seta and arm running tool. Printed: 5/24/2001 2:45:3,9 PM BP EXPLORATION Page 2 of 5 Operations Summa Report Legal Well Name: B-22 Common Well Name: B-22A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 4/22/2001 End: 5/7/2001 Contractor Name: NABORS Rig Release: 5/7/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 4/25/2001 09:00 - 12:00 3.00 DHEQP P DECOMP Rih wireline, correlate cci, set bridgr plug at 7000 ft. Poh wireline, rig dn Sclum, release unit. Clear floor. 12:00 - 13:00 1.00 STWHIP P WEXlT Test 9 5/8 csg / bridge plug 3500 psi / 30 min. Test successful. 13:00 - 14:00 1.00 STWHIP P WEXlT PJSM, Slip / cut 85 ft drlg line. 14:00 - 18:30 4.50 STWHIP P WEXlT PJSM, assemble bha #2, flow check, rih same 18:30 - 23:00 4.50 STWHIP P WEXlT Follow bha with 4" dp, slo-go, to 7000 ft. 23:00 - 23:30 0.50 STWHIP P WEXlT Orient tool face to 80 deg r, tag 5 1/2 stub, set dn, set whipstock at 7000 ft, cont dn, shear at 45000K 23:30 - 00:00 0.50 STWHIP P WEXlT Displace well with 9.8 ppg LSND fluid. 4/26/2001 00:00 - 01:00 1.00 STWHIP P WEXlT Cont displace well with Isnd fluid while orient for milling operation. 500 gpm @ 1930 psi ~ 01:00 - 06:30 5.50 STVVHIP P WEXIT Commence cut / mill window at 6977 ft. Sweep well at 5 ft intervals. 175 up, 140 dn, 155 rot, wob 1,,1,-12, complete window at 7008 ft, and sweep well. 06:30 - 08:00 1.50 S'I'WHIP P WEXIT .Execute passes thru window, pump on, pump off. Recip / circ sweeps, returns clean. 08:00 - 11:30 3.50 STWHIP P WEXIT .Flow check, prepare and poh for drlg assy. 11:30 - 14:00 2.50 S'I'WHIP P WEXIT Handle bha #2, lay out non essential components, flush bop stack. 14:00 - 15:30 1.50 STVVHIP P WEXIT Function bope, flush, lay out jet tool, blow dn stand pipe. 15:30 - 17:00 1.50 STVVHIP P WEXIT Handle / mu bha #3, motor - mwd, surface test same, 175 psi @ 250 gpm. 17:00 - 21:30 4.50 STVVHIP P WEXIT Flow check, follow bha with 4" dp in sgls. 21:30 - 22:30 1.00 STWHIP P VVEXIT Rih stds from mast to 6800 ft. 22:30 - 23:00 0.50 STVVHIP P WEXIT Orient toolface to 80 deg R. Work thru window. Window clear. 23:00 - 00:00 1.00 STWHIP P VVEXIT (:;irc / wash to 7008 ft, no fill, obstructions. 4/27/2001 00:00 - 01:00 1.00 STWHIP P WEXIT I~JSM, test lines, perform FIT 6085 ft TVD at window, results = 855 psi, bleed to 717 psi, 12.5 EMW. Bleed press, blow lines dry. 01:00 - 10:30 9.50 DRILL P LNR1 Flow check, commence drill ahead 8 1/2 hole 7008 - 7300 ft. up 161, dn 135, rot 145 10:30 - 11:00 0.50 DRILL P WEXIT Base line PWD, correlate parameters with MWD at 7300 ft. 11:00 - 00:00 13.00 DRILL P WEXIT Resume drill ahead 8 1/2 hole 7300 - 7912 ft Torque stable, normal up / dn drag, no loss circ. Survey 30 ft intervals. AST = 5.25 hrs, ART = 1.75 hrs. Motor at 1.5 deg. 4/28/2001 00:00 - 19:30 19.50 DRILL P LNR1 Cont drill 8 1/2 hole from 9 5/8 window, 7912 - 8753 ft. Bring mud wt to 10.8 on fly during drlg. this interval. ( 8600 - 8753 ) 19:30 - 21:00 1.50 DRILL P LNR1 Flow check, circ, pump sweep, pump pill. 21:00 - 22:00 1.00 DRILL P LNR1 Prepare and poh short trip to 7000 ft. Note no abnormalties. Hole good cond. 22:00 - 22:30 0.50 DRILL P LNR1 Service top drive 22:30 - 23:30 1.00 DRILL P LNR1 Flow check, Orient tool face, pass window, no obstruction, tih to 8600 ft. AST = 1.25 hrs ART = 12.75 hrs 23:30 - 00:00 0.50 DRILL P LNR1 Fill pipe, brk circ, up 178, dn 167, rot 155. 4/29/2001 00:00 - 00:00 24.00 DRILL P LNR1 PJSM, resume drill ahead 8 1/2 hole 8753 - 9873 ft. Printed: 5/24/2001 2:45:39 PM BP EXPLORATION Page 3 of 5 Operations Summa Report Legal Well Name: B-22 Common Well Name: B-22A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 4/22/2001 End: 5/7/2001 Contractor Name: NABORS Rig Release: 5/7/2001 Rig Name: NABORS 9ES Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 4/29/2001 00:00 - 00:00 24.00 DRILL P LNR1 Hi Vis sweeps at 300 ft intervals, no increase cuttings returns, hole clean. Up 196, dn 165, rot 180, Tq 6 -7 K AST = 0, ART = 18.25 hrs Encounter top" Sag River" at 9905 MD, 8499 TVD Top" Kingak" 9016 ft MD, 7762 ft TVD 4/30/2001 00:00 - 00:30 0.50 DRILL P LNR1 Cont drill ahead 8 1/2 hole 9873 - 9905 ft. Up 208, dn 167, rot 185, tq 6-7 K. 00:30 - 02:00 1.50 DRILL P LNR1 Flow check, circ for samples as per Co. geo. Geologist confirms" Sag R" at 9905 MD, 8499 TVD Cease drilling. 02:00 - 04:30 2.50 DRILL P LNR1 Prepare and poh short trip to window at 6805 ft. Normal drag, no problems. 04:30 - 05:00 0.50 DRILL P LNR1 Flow check, service top dry. 05:00 - 07:30 2.50 DRILL P LNR1 Rih, wash 90 ft to btm, no fill, no dn drag. 07:30 - 11:00 3.50 DRILL P LNR1 Circ / cond mud, spot liner pill. 11:00 - 15:30 4.50 DRILL P LNR1 Flow check, poh for 7" liner. No abnormalties, window clear. SLM, and shots at 9533, 9346 ft. No correction pipe strap. 15:30 - 18:30 3.00 DRILL P LNR1 Std bk hwdp, lay out DCs, drctnl equip. Clear floor. 18:30 - 19:30 1.00 CASE P LNR1 Place 7" csg equip on floor and ru same. 19:30 - 00:00 4.50 CASE P LNR1 PJSM, Make up shoe track, rih, test float equip, follow with 7"csg, filling 5 jt intervals. 5/1/2001 00:00 - 00:30 0.50 CASE P LNR1 Ran total 75 Jts 7" Liner. M/U HMC Hanger & ZXP Packer. 00:30 - 01:30 1.00 CASE P LNR1 Circulate Liner volume @ 235 gpm - 290 psi. 01:30 - 05:00 3.50 CASE P LNR1 Run Liner on 4" DP to 6900'. 05:00 - 06:00 1.00 CASE P LNR1 Circulate Liner & DP volume @ 223 gpm - 530 psi 06:00 - 09:00 3.00 CASE P LNR1 Continue RIH w/Liner to 9889'. P/U Jr. w/cement head and tag bottom @ 9905'. P/U 245K S/O 153K. 09:00 - 12:00 3.00 CASE P LNR1 Break circulation & stage pumps up to 8 bbm. @ 1575 psi. 12:00 - 13:30 1.50 CEMT P LNR1 R/U Dowell Schlumberger. Pump 5 bbls. CWl00. Test lines to 3500 psi. Pump 5 bbls. CWl00 followed by 50 bbls. 12.0 ppg MudPUSH XL then 75 bbls 15.8 ppg Cement. Drop plug w/5 bbls Water. Displace Cement w/Rig Pumps @ 8 bpm - 1100 psi. 13:30 - 14:00 0.50 CASE i P LNR1 Set Hanger and Packer. Check floats - OK 14:00 - 15:00 1.00 CASE !P LNR1 Circulate bottoms up @ 10 bpm - 1800 psi. 15:00 - 19:00 4.00 CASE =P LNR1 POH w/4" DP. LID 5" HWDP and C 2 Liner setting tool. 19:00 - 22:00 3.00 BOPSUF~,P LNR1 Pressure test BOPE to 250 / 3500 psi. Witness of test waived by Lou Grimaldi, AOGCC. 22:00 - 00:00 2.00 CASE P LNR1 M/U 6 1/8" BHA # 4. Orient MWD and Motor. 5/2/2001 00:00 - 01:30 1.50 CASE N DFAL LNR1 Attempt to flow test MWD. Unable to recieve signal. P/U & BIO MWD. Repair same. 01:30 - 02:00 0.50 CASE P LNR1 M/U MWD. Flow Test - OK. 02:00 - 03:30 1.50 CASE P LNR1 Continue M/U BHA # 4. PJSM w/Sperry & all hands. Load Nuclear Source. 03:30 - 04:30 1.00 CASE P LNR1 P/U 30 singles 4" DP RIH. 04:30 - 09:00 4.50 CASE P LNR1 Slip & Cut Drilling line. Service Draworks, Top Drive. Torque ' Nuts on fluid end # 1 Mud Pump. CIO 5 1/2" Liner & test to ' 3500 psi. Clear floor and Clean Rig. 09:00 - 13:30 4.50 CASE P LNR1 RIH w/4" DP to 6832' Printed: 5/24/2001 2:45:39 PM' BP EXPLORATION Page 4 of 5 Operations Summa Report Legal Well Name: B-22 Common Well Name: B-22A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 4/22/2001 End: 5/7/2001 Contractor Name: NABORS Rig Release: 5/7/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/2/2001 13:30 - 14:00 0.50 CASE P LNR1 Hold Stripping Drill w/Rig Team. 14:00 - 15:00 1.00 CASE P LNR1 Cont. RIH. Tag Cmt @ 9753' 15:00 - 16:00 1.00 CASE P LNR1 M/U Top Drive< break circulation. Close rams and test 7" Liner to 3500 psi. for 30 minutes. 16:00 - 19:00 3.00 CASE P LNR1 Drill Cmt from 9753 to Landing Collar @ 9819. Drill L/C. No Cmt. below. Drill Float Collar @ 9861'. Drilled Cement from 9880' to 9900'. 19:00 - 21:00 2.00 CASE P LNR1 Drop ball to open PBL. Displace old mud with 8.4+ ppg. Quickdrill N Mud. Drop ball to close PBL. 21:00 - 21:30 0.50 DRILL P LNR1 Drill out Shoe and 20' of new Hole to 9925'.ART =0.5 Hrs. P/U = 186K, S/O = 156K ROT = 176K. 230 GPM @ 1000 psi. 21:30 - 00:00 2.50 DRILL P LNR1 Circulate Hole clean in preparation for FIT test. 5/3/2001 00:00 - 00:30 0.50 EVAL P PROD1 Perform FIT to 9.51 ppg. EMW. 00:30 - 00:00 23.50 DRILL P PROD1 Drill 6 1/8" Directional Hole from 9925' to 10470'. AST = 7.5 Hrs.ART = 12 Hrs. 272 GPM @ 1490 psi. P/U = 198 K, S/O = 154 K, ROT = 175 K Torque = 6- 8 K, WOB=4-10K 5/4/2001 00:00 - 13:30 13.50 DRILL P PROD1 Drill 6 1/8" Directional Hole from 10,470' to 10,902'. TD as per on site Geologist. ^ST = 1.75 Hrs. ART = 8.25 Hrs. 272 gpm @ 1525 psi. P/U = 208K S/O = 155K ROT = 178K WOB = 5 - 10K Torque = 7 - 8K @ 75 RPM 13:30 - 15:30 2.00 DRILL P PROD1 Clean Hole w/Hi Vis Sweep 15:30 - 16:30 1.00 DRILL P PROD1 Wipe to shoe - No Drag. RIH to 10,807'. Hole Slick. 16:30 - 19:00 2.50 DRILL P PROD1 Wash to TD @ 10,902' - No Fill. Pump Hi Vis Sweep Spot Liner Running Pill 19:00 - 20:30 1.50 DRILL P PROD1 POH to spot PBL Tool at top of 7" Liner @ 6832'. :20:30 - 22:00 1.50 DRILL P PROD1 Open PBL Tool and circulate at 13BPM @ 1100psi. Quite a lot of cuttings over shakers from liner top and casing. Close PBL, pump pill & blow down Top Drive. .22:00 - 00:00 2.00 DRILL P PROD1 Continue POH w/4" DP. 5/5/2001 '00:00 - 01:00 1.00 DRILL P PROD1 Continue POH to BH^ ' 01:00 - 03:30 2.50 DRILL P PROD1 PJSM, Remove Rad. Source, Download MWD, L/D BHA. 03:30 - 05:00 1.50 CASE P PROD1 Rig up to run 4.5" Chrome Production Liner. '05:00 - 05:30 0.50 CASE P PROD1 PJSM with Crew, Casing hands & Baker hand on running Liner. 05:30 - 08:30 3.00 CASE P PROD1 Run 27 Jts.,12.6 #, 13Cr-80, Vam Ace Production Liner. 08:30 - 09:30 1.00 CASE P PROD1 M/U Flex Lock II Hyd. Liner & ZXP Liner Top Pkr. as per Baker hand. 09:30 - 10:00 0.50 CASE P PROD1 Run 1 std. 4' DP and Circulate liner volume. R/D csg tools. 10:00 - 17:30 7.50 CASE P PROD1 RIH w/Liner on 4" DP, filling every 5 stds.to 9870' M/U Cement head to single. ~ 17:30 - 18:30 1.00 CASE P PROD1 Circulate DP + Liner volume @ 4 bpm - 630 psi. P/U = 180K S/O = 150K. !18:30 - 19:00 0.50 CASE P PROD1 Continue RIH w/Liner to 10,876.No Drag. Hole slick 19:00 - 21:00 2.00 CASE P PROD1 M/U Cement Head, Break circ., wash down to TD @ 10,902. Stage pumps up to 6 bpm @ 875 psi. Reciprocate while cirulating bottoms up. R/U SWS. Held PJSM's with Crew, Baker, Dowell and Peak Drivers on Cmt. Job and Setting Hgr and Pkr. 21:00 - 22:30 1.50 CEMT P PROD1 With SWS; Pump 5 bbls. CW 100, Test Lines to 4500 psi., Pump 5 bbls CW 100, 25 bbls. 9.5 ppg. MudPUSH XL followed Printed: 5/24/2001 2:45:39 PM BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: B-22 Common Well Name: B-22A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 4/22/2001 End: 5/7/2001 Contractor Name: NABORS Rig Release: 5/7/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 5/5/2001 21:00 - 22:30 1.50 CEMT P PROD1 by 31 bbls. 15.8 ppg. Class G Tail Slurry. Wash lines, Drop Dart and displace w/45 bbls Perf Pill and 68 bbls. Mud. Observed Dart engaging Wiper Plug. Bump plug and set Hanger wi 3200 psi., per Baker Hand. Set 50K to check. 22:30 - 23:00 0.50 CASE P PROD1 Pressure to 4000 psi to release running tool> Bleed pres. - floats OK. P/U to clear Pkr. setting dogs and slack off 50K to set ZXP Packer. Liner Set @ 10,900' Top of ZXP packer @ 9727'. 23:00 - 00:00 1.00 CEMT P PROD1 Pressure up DP w/Rig Pumps to 1000 psi. P/U to clear seals and Circulate Bottms up @ 11 bbm, 1750 psi. Approx. 80 bbls of strung out cement contaminated Mud. Well bore clean. 5/6/2001 00:00 - 01:30 1.50 CASE P PROD1 Displace well bore with clean Seawater. Pumped 700 bbls @ 10 bbl/min. 01:30 - 02:00 0.50 CASE P PROD1 LID Cement Head & single on skate. PJSM 02:00 - 10:30 8.50 CASE P PROD1 POH and stand back 45 stands. PJSM. POH and Lay Down 213 Jts. of 4" DP. L/D running tool and pull wear bushing. 10:30 - 11:00 0.50 CASE P PROD1 Test 4.5" Production Liner to 3500 psi for 30 minutes. 11:00 - 12:00 1.00 RUNCOr P COMP Rig Up to Run 4.5" Completion Assembly. PJSM 12:00 - 00:00 12.00 RUNCOr F) COMP Run 4.5" 12.6# 13Cr80 VAM ACE Completion String as per program. 5/7/2001 00:00 - 05:00 5.00 RUNCO~ P COMP Complete running 4.5" Tubing Completion as per program. Ran total 226 Jts 12.6 # 13Cr-80 Vam-ACE Tubing with Accesories. Tagged Btm.of ZXP Pkr tie-back receptacle @ 9737'. 05:00 - 06:30 1.50 RUNCO~ P COMP Space out to place WLEG in tie back receptacle @ 9733'. M/U Tubling Hanger & landing Jr. Land Tubing. Pull Tubing Hanger to floor and R/U to reverse circulate. 06:30 - 11:00 4.50 RUNCO~ P COMP Reverse Circulate Clean Seawater @ 3 bbm., cleaning up wellbore. Add corrosion inhibitor and circulate around. 11:00 - 12:00 1.00 RUNCO~ F' COMP Land Tubing Hanger. RILDS. Drop ball & rod. 12:00 - 13:30 1.50 RUNCOr F' COMP Test lines to 3500 psi. Pressure Tbg to 3500 psi to Set Baker S3 Packer. Hold pressure for 30 Minutes. Bleed Tubing pressur to 1500 psi.and pressure Annulus to 3500 psi.for Packer Test - Hold for 30 minutes. Bleed off Tubing pressure to shear RP. 13:30 - 14:00 0.50 BOPSUF P COMP Set TWC. Test to 1000 psi from below. 14:00 - 16:00 2.00 BOPSUF P COMP N/D BOP. 16:00 - 18:30 2.50 WHSUR P COMP N/U McEvoy 4 1/16", 5000 psi Tree and 4 1/16" X 13 5~8" Adaptor Flange. Test both to 5000 psi. 18:30 - 19:30 1.00 WHSUR P COMP N/U DSM w/lubricator. Pull TWC. R/D DSM. 19:30 - 22:30 3.00 RUNCO~ F) COMP R/U Hot Oiler. Test lines to 3000 psi. Reverse circulate 151 bbls diesel down annulus. Shut down and allow to U-tube. Freeze Protected to 2200'. Blow down all lines and RID Plot Oiler. 22:30 - 23:00 0.50 WHSUR P COMP Set BPV 23:00 - 00:00 1.00 WHSUR P COMP Remove secondary valve off annulus. Secure Tree. RIG RELEASED @ 00:00 Hrs. Printed: 5/24/2001 2:45:39 PM Well: B-22A Rig Accept: 04122/01 Field: Prudhoe Bay Rig Spud: 04/27/01 APl: 50-029-20759-01 Rig Release: 05/07/01 Permit: 200-157 Drilling Rig: Nabors 9ES , :. , , . · · PRE / POST - RIG WORK 02/17101 MIRU CTU #3. RIH with 4" GS spear. Spot 20 Bbls acid on slug and latch plug. Circulate all to system. Hit one jar lick on plug and pull free. Recover 4-1/2" XXN plug. Freeze protect flowline with 60 Bbls dead crude. RIH with cementing nozzle. Pump KCL down backside to load and kill well. Tag TD at 11100' ctmd. Pump 30 Bbls cement. Lay in from TD to 10300'. Establish squeeze pressure of 100 psig for 30 minutes. Estimate well took approximately 10 Bbls cement. 02/18/01 Pump 40 Bbls Biozan from 10300', POH at 80% circulating to tank and maintaining 200 psig WHP. Freeze protect tubing from 2000' with methanol. Secure well with 150 psig WHP. RD DS CTU #3. 02/19101 Tagged TOC at 10264' ELM. Ran 4.5" drift to 8000' SLM. Pulled ST#3 RA-DGLV. 02/20/01 Circulate out well, rig prep. 02/22/01 Tubing cut with 4-7/16" jet cutter at 7020'. 05/26/01 Made drift with dummy gun. Bailed drilling mud from bridge, tagged TD. Ran 2-7/8" dummy gun down to 10765' SLM. Well still shut-in, wing valve flanged off. 05/31/01 RIH to log SCMT, tagged TD at 10745'. Logged two SCMT passes, rechecked tool in free pipe section, run back to TD, pressured up pipe with Tri-plex to 2000 #, logged SCMT pass to check for micro- annulusing. POOH. 06/02/01 Pedorated well. Shot 10690' to 10720' with 2-7/8" power jet charges at 4 spf. WHP increased 400 psi after firing. Shot 10630' to 10655' On run #2. DEFiNITiVE North Slope Alaska Alaska Drilling & Wells PBU_WOA B Pad, Slot B-22 B-22A Job No. AKMMfOf28, Surveyed: 4 May, 200~ SURVEY REPORT 26 May, 2001 Your Reft AP1-500292075901 Surface Coordinates: 5949860.00 N, 663738.00 E (70° 16' 09.753~" N, 148° 40' 32.8529" VI/) Kelly Bushing: 72.30ft above Mean Sea Level DRILLING SERVICES .. Survey Reft svy10825 A Halliburton Company Sperry-Sun Drilling Services Survey Report for B.22A Your Ref: API-500292075g01 Job No. AKMM10128, Surveyed: 4 May, 2001 North Slope Alaska Measured Depth (ft) 6892.08 46.000 95.013 Sub-Sea Depth (ft) 5938.51 Vertical Depth (fi) 6010.81 6977.00 46.000 95.010 5997.50 6069.80 7009.97 44.980 102.380 6020.63 6092.93 7041.57 42.570 105.490 6043.45 6115.75 7075.61 40.840 109.090 6068.87 6141.17 7102.55 39.860 110.840 6089.40 6161.70 7134.57 38.880 114.240 6114.15 6186.45 7165.22 38.800 118.440 6138.03 6210.33 7195.36 38.440 122.610 6161.58 6233.88 7228.24 38.050 123.410 6187.41 6259.71 7261.23 37.680 128.600 6213.46 6285.76 7289.52 37.480 133.370 6235.88 6308.18 7319.30 37.370 139.180 6259.54 6331.84 7350.83 37.720 143.130 6284.54 6356.84 7382.35 37.560 145.820 6309.50 6381.80 7412.60 37.280 148.270 6333.53 6405.83 7443.71 36.890 150.780 6358.35 6430.65 7474.84 36.290 154.050 6383.35 6455.65 7506.59 35.530 157.660 6409.07 6481.37 7539.52 35.580 161.190 6435.86 6508.16 7568.39 35.580 164.280 6459.34 6531.64 7662.43 35.140 163.320 6536.03 6608.33 7755.37 34.730 162.020 6612.23 6684.53 7848.39 34.000 163.640 6689.01 6761.31 7942.10 33.750 163.800 6766.82 6839.12 8034.55 33.230 164.260 6843.92 6916.22 8128.37 32.780 164.890 6922.60 6994.90 8221.83 33.500 171.650 7000.88 7073.18 8316.30 33.230 170.700 7079.78 7152.08 8409.65 32.910 170.340 7158.01 7230.31 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 218.89 S 2416.87 E 5949693.74 N 666159.06 E 224.23 S 2477.72 E 5949689.73 N 666220.01 E 227.76 S 2500.93 E 5949686.70 N 666243.29 E 233.01 S 2522.15 E 5949681.91 N 666264.62 E 239.73 S 2543.76 E 5949675.66 N 666286.38 E 245.68 S 2560.16 E 5949670.07 N 666302.90 E 253.46 S 2578.91E 5949662.70 N 666321.82 E 261.98 S 2596.13 E 5949654.55 N 666339.22 E 271.53 S 2612.33 E 5949645.36 N 666355.62 E 282.62 S 2629.40 E 5949634.65 N 666372.92 E 294.51S 2645.77 E 5949623.11N 666389.55 E 305.82 S 2658.78 E 5949612.09 N 666402.81 E 318.88 S 2671.28 E 5949599.30 N 666415.59 E 333.84 S 2683.33 E 5949584.61 N 666427.95 E 349.50 S 2694.51E 5949569.19 N 666439.48 E 364.93 S 2704.51 E 5949553.99 N 666449.81 E 381.09 S 2714.02 E 5949538.04 N 666459.67 E 397.53 S 2722.62 E 5949521.79 N 666468.62 E 414.51S 2730.23 E 5949504.98 N 666476.61 E 432.43 S 2736.96 E 5949487.21 N 666483.72 E 448.47 S 2741.95 E 5949471.28 N 666489.05 E 500.73 S 2757.13 E 5949419.37 N 666505.37 E 551.53 S 2772.98 E 5949368.92 N 666522.32 E 601.69 S 2788.48 E 5949319.11 N 666538.91 E 651.83 S 2803.12 E 5949269.30 N 666554.64 E 700.87 S 2817.16 E 5949220.57 N 666569.74 E 750.14 S 2830.75 E 5949171.62 N 666584.40 E 800.10 S 2841.10 E 5949121.89 N 666595.83 E 851.44 S 2849.07 E 5949070.74 N 666604.92 E 901.68 S 2857.46 E 5949020.69 N 666614.40 E Dogleg Rate (°/100ft) 0.003 16.232 10.222 8.678 5.560 7.397 8.597 8.716 1.917 9.719 10.305 11.859 7.713 5.236 5.008 5.024 6.551 7.084 6.235 6.227 0.754 0.914 1.258 0.283 0.626 0.603 4.027 0.623 0.402 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 926.92 950.09 96O.36 971.68 984.51 995.07 1008.06 1021.32 1035.25 1050.90 1067.12 1081.78 1097.97 1115.83 1134.11 1151.81 1170.07 1188.32 1206.80 1225.91 1242.70 1297.11 1350.33 1402.83 1455.05 1506.05 1557.13 1607.91 1659.30 1709.77 Tie On Depth MWD Magnetic Window Point 26 May, 2001 - 6:24 Page 2 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-22A Your Ref: API-500292075901 Job No. AKMM10128, Surveyed: 4 May, 2001 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 8502.48 32.200 170.360 7236.25 7308.55 8596.44 33.970 170.970 7314.98 7387.28 8688.13 33.820 170.620 7391.08 7463.38 8783.20 33.180 171.910 7470.36 7542.66 8875.49 32.630 171.130 7547.85 7620.15 8968.55 32.030 169.640 7626.48 7698.78 9061.62 31.610 169.010 7705.56 7777.86 9155.26 31.260 169.260 7785.46 7857.76 9248.90 31.050 168.530 7865.59 7937.89 9343.90 30.990 167.220 '7947.01 8019.31 9435.86 31.020 167.050 8025.83 8098.13 9529.22 31.070 167.320 8105.82 8178.12 9623.62 31.360 166.520 8186.55 8258.85 9717.08 30.980 165.310 8266.52 8338.82 9809.91 30.520 165.320 8346.30 8418.60 9839.56 30.120 165.040 8371.89 8444.19 9879.99 29.860 165.020 8406.91 8479.21 9911.39 30.320 165.000 8434.08 8506.38 9941.92 32.690 164.970 8460.11 8532.41 9972.98 37.080 167.090 8485.58 8557.88 10005.31 42.830 169.210 8510.35 8582.65 10036.31 44.770 168.680 8532.73 8605.03 10069.01 47.500 169.190 8555.38 8627.68 10100.25 50.210 169.190 8575.94 8648.24 10132.76 51.100 169.020 8596.55 8668.85 10163.11 52.010 169.040 8615.42 8687.72 10194.17 52.870 169.430 8634.35 8706.65 10256.18 52.360 169.030 8672.00 8744.30 10349.19 53.030 169.390 8728.37 8800.67 10442.62 50.140 169.370 8786.42 8858.72 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 950.93 S 2865.83 E 5948971.64 N 666623.84 E 1001.54 S 2874.14 E 5948921.22 N 666633.25 E 1052.01S 2882.32 E 5948870.94 N 666642.53 E 1103.87 S 2890.30 E 5948819.26 N 666651.62 E 1153.46 S 2897.69 E 5948769.85 N 666660.09 E 1202.53 S 2905.99 E 5948720.97 N 666669.46 E 1250.75 S 2915.08 E 5948672.96 N 666679.60 E 1298.71S 2924.29 E 5948625.21N 666689.85 E 1346.25 S 2933.62 E 5948577.89 N 666700.21 E 1394.11S 2943.90 E 5948530.26 N 666711.53 E 1440.29 S 2954.45 E 5948484.32 N 666723.08 E 1487.24 S 2965.13 E 5948437.62 N 666734.78 E 1534.89 S 2976.20 E 5948390.22 N 666746.88 E 1581.80 S 2987.97 E 5948343.57 N 666759.67 E 1627.72 S 3000.00 E 5948297.93 N 666772.70 E 1642.19 S 3003.83 E 5948283.54 N 666776.84 E 1661.71S 3009.05 E 5948264.14 N 666782.48 E 1676.92 S 3013.12 E 5948249.03 N 666786.89 E 1692.33 S 3017.25 E 5948233.71 N 666791.35 E 1709.56 S 3021.52 E 5948216.57 N 666796.00 E 1729.88 S 3025.76 E 5948196.35 N 666800.68 E 1750.93 S 3029.88 E 5948175.39 N 666805.25 E 1774.07 S 3034.40 E 5948152.36 N 666810.27 E 1797.17 S 3038.81 E 5948129.36 N 666815.19 E 1821.86 S 3043.56 E 5948104.78 N 666820.47 E 1845.20 S 3048.09 E 5948081.55 N 666825.50 E 1869.39 S 3052.68 E 5948057.46 N 666830.63 E 1917.79 S 3061.89 E 5948009.27 N 666840.88 E 1990.46 S 3075.74 E 5947936.92 N 666856.31 E 2062.41S 3089.23 E 5947865.28 N 666871.36 E Dogleg Rate (°/100ft) O.765 1.917 0.268 1.007 0.752 1.072 0.575 0.399 0.461 0.713 0.101 0.158 0.536 0.784 0.496 1.431 0.644 1.465 7.763 14.661 18.275 6.369 8.424 8.675 2.767 2.999 2.942 0.969 0.783 3.093 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 1759.28 1810.07 1860.70 1912.59 1962.13 2011.45 2060.19 2108.72 2156.89 2205.64 2252.87 2300.87 2349.66 2397.96 2445.37 2460.33 2480.52 2496.25 2512.19 2529.92 2550.57 2571.90 2595.34 2618.71 2643.70 2667.32 2691.78 2740.74 2814.24 2886.95 26 May, 2001 - 6:24 Page 3 of 5 DriilQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-22A Your Ref: API-500292075901 Job No. AKMMlO?28, Surveyed: 4 May, 200~ North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (fi) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10536.66 51.300 168.800 8845.95 8918.25 2133.88 S 3103.02 E 5947794.13 N 666886.70 E . 10629.97 50.840 167.700 8904.59 8976.89 2204.94 S 3117.79 E 5947723.40 N 666903.02 E 10724.23 49.710 167.520 8964.83 9037.13 2275.75 S 3133.35 E 5947652.95 N 666920.11 E 10818.57 46.660 168.130 9027.72 9100.02 2344.47 S 3148.18 F 5947584.57 N 666936.44 E 10848.96 47.270 168.010 9048.46 9120.76 2366.21 S 3152.78 E 5947562.94 N 666941.50 E 10902.00 47.270 168.010 9084.45 9156.75 2404.32 S 3160.87 E 5947525.01 N 666950.42 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference Magnetic Declination at Surface is 26.686° (18-Apr-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 162.720° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10902.00ft., The Bottom Hole Displacement is 3971.38ft., in the Direction of 127.258° (True). Dogleg Rate (°/'~OOft) 1.320 1.041 1.208 3.269 2.028 0.000 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 2959.29 3031.54 3103.77 3173.79 3195.91 3234.71 Projected Survey 26 May, 2001. 6:24 Page 4 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-22A Your Ref: API-500292075901 Job No. AKMMlO128, Surveyed: 4 May, 200~ North Slope Alaska Alaska Drilling & Wells PBU WOA B Pad Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6892.08 6010.81 218.89 S 2416.87 E 6977.00 6069.80 224.23 S 2477.72 E 10902.00 9156.75 2404.32 S 3160.87 E Comment Tie On Depth Window Point Projected Survey Survey tool program for B-22A From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) 0.00 0.00 6892.08 6010.81 6892.08 6010.81 10902.00 9156.75 Su~rvey Tool Description AK-1 BP_HG - BP High Accuracy Gyro (B-22) MWD Magnetic (B-22A) 26 May, 2001 - 6:24 Page 5of5 DrillQuest 2.00.08.005 STATE OF ALASKA ALASKA(` ...,L AND GAS CONSERVATION C~, .,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 784' SNL, 1897' WEL, Sec 31, T11N, R14E UM At top of productive interval 2962' SNL, 1187' EWL, Sec 32, T11N, R14E UM At effective depth n/a At total depth 3089' SNL, 1214' EWL, Sec 32, T11N, R14E UM CTD Prep-Work 5. Type ~ well: Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 73.52 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number B-22A 9. Permit Number / Approval No. 200-157 10. APl Number 50- 029-20759-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11275 feet true vertical BKB 9164 feet Effective depth: measured 11161 feet true vertical BKB 9088 feet Casing Length Size Structural Conductor 110' 20"X30" Surface 2641' 13-3/8" Intermediate 10269' 9-5/8" Production Liner 1449' 7" Plugs (measured) Junk (measured) Cemented 72 c.f. Concrete 3720 c.f. Permafrost 1470 c.f. Class 'G', 130 c.f. PF 450 c.f. Class 'G' MD TVD BKB 110' 110' 2676' 2676' 10304' 8495' 9821' - 11270' 8143' - 9161' Perforation depth: measured Sqzd Perfs 10920'- 10958', 10972'- 11032', 11038'- 11052', 11062' - 11082' true vertical Sqzd Perfs 8925' - 8951', 8960' - 9001', 9005' - 9014', 9021' - 9034' Tubing (size, grade, and measured depth) 5-1/2" L-80 tubing to 9744' with 4-1/2" tailpipe to 9877' Packers and SSSV (type and measured depth) 9-5/8" packer @ 9744', 5-1/2" Otis SSSVLN @ 2141'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 2001 Anch0r~ge 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed scott LaVoie ~~) ~¢' y~,,~'~ Title Technical Assistant Prepared By Name/Number: Date De Wayne E'chnoCr 564-5174 Form 10-404 Rev. 06/15/88 ORIGINAL Submit In Duplicate B-22A i' DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/15/2OO 1 02/16/2001 02/17/20O 1 02/18/2001 02.19/2001 02/20/2001 02/22/2001 DRILL-PREP WORK: DRIFT TUBING (DRLG PREP WORK) DRILL-PREP WORK: WELLHEAD PACKOFF TESTING, PRE-RWO DRILL-PREP WORK: PULL XXN PLUG; P & A DRILL-PREP WORK: P&A (RWO PREP) DRILL-PREP WORK: TAG TOC AT 10,264'ELM, RAN 4.5"DRIFT TO 8000'SLM, PULLED ST#3 DGLV DRILL-PREP WORK: CIRC.OUT WELL DRILL-PREP WORK: 4-7/16" JET CUTTER SUMMARY 02/15/01 RIH W/3.625 SWAGE & TEL & SET DOWN @ 9800' SLM, COULDN'T GET ANY DEEPER 02/16/01 PPPOT-T PASSED, PPPOT-IC INCONCLUSIVE 02/17/01 MIRU CTU #3. RIH W/4" GS SPEAR. SPOT 20 BBLS ACID ON SLUGGIT AND LATCH PLUG. CIRCULATE ALL TO SYSTEM. HIT ONE JAR LICK ON PLUG AND PULL FREE. ***RECOVER 4 1/2" XXN PLUG***. FREEZE PROTECT FLOWLINE W/60 BBLS DEAD CRUDE. RIH WITH CEMENTING NOZZLE..PUMP KCL DOWN BACKSIDE TO LOAD AND KILL WELL. TAG TD AT 11,100' CTMD. PUMP 30 BBLS CEMENT. LAY IN FROM TD TO 10,300'. ESTABLISH SQUEEZE PRESSURE OF 1000 PSIG FOR 30 MIN. EST. WELL TOOK APPROX. 10 BBLS CEMENT. 02/18/01 CONT' FROM WSR 2/17/01 ... PUMP 40 BBLS BIOZAN FROM 10,300', POH AT 80% CIRCULATING TO TANK AND MAINTAINING 200 PSIG WHP. FREEZE PROTECT TUBING FROM 2000' WITH METHANOL. SECURE WELL WITH 150 PSIG WHP. RD DS CTU #3. ***JOB COMPLETE - WELL TO REMAIN SHUT IN*** 02/19/01 TAGGED TOC AT 10,264'ELM. RAN 4.5" DRIFT TO 8000'SLM. PULLED ST#3 RA-DGLV. - NOTIFIED DSO - WELL TO REMAIN SHUT IN - 02/20/01 CIRCULATE OUT WELL, RIG PREP 02/22/01 4-7/16" JET CUTTER AT 7020' ***LEFT WELL SHUT IN AND NOTIFIED WELL SUPPORT READY TO INSTALL BPV*** Fluids Pumped BBLS. Description 137 DIESEL. 6O DEAD CRUDE 500 2% KCL XSL 300 2% KCL 40 1.5 PPB BIOZAN 60 MEOH 105 60/40 METHANOL 20.2 12% HCL 537 SH20 1759.2 TOTAL 26-May-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well B-22A 2o0-'~5"1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and I disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,892.08' MD 6,977.00' MD 10,902.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JUN 0 1 2.001 Ala~ 0il & GaS Coos. 6em~ MEMORANDUM TO: THRU: Julie Heusser Commissioner Tom Maunder P.I. Supervisor FROM: Inspectors Name Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 23, 2001 SUBJECT: Blowout Preventer Test Nabom 9ES BPX/B Pad B-22A 200-157 Prudhoe / PBU NON- CONFIDENTIAL Operator Rep.: Dou~Williams Contractor Rep.: Kpith, Spo, al~ Op. phone: 659-4,,83.1 Op. E-Mail: Rig phone: Rig E-Mail: Test Pressures Rams: 25013500 MISC. INSPECTIONS: P/F PIF Location Gen.: P Sign: P Housekeeping: P Rig cond: ..... p PTD On Location P Hazard: P Standing Order: P BOP STACK: Quantity Size PIF Annular Preventer 1 13 518 P Pipe Rams' 1" 3 112 X 6 .... Lower Pipe Rams 1 2 718 X 5 P Blind Rams 1 13 518 P Choke Ln. Valves I 3 118" P HeR Valves 2 3 1/8" P Kill Line Valves ..... 1 ' ' 3' 1i8"' .... Check Valve NIA NIA NIA Annular: 25013500 Choke: 25013,,500 TEST DATA FLOOR VALVES: Quantity PIF Upper Kelly I P Lower Kelly 1 P Ball Type 1 P Inside BOP I P CHOKE MANIFOLD: Quantity PIF No. Valves 14 P Man. Chokes 1 P Hyd. Chokes I P MUD SYSTEM: Visual Alarm Trip Tank P P · : :~. : :: - Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 3000 P After Closure ' i '.'~6~)0 ., P. 200 psi Attained 23 sec ' ~ P Full Pressure 2:14 P Blind Covers (All Stati'~)'~'s): .... P 'i N2 Bottles (avg): 6_@ 200_~psi .... . . Test's Details I traveled to B Pad in the Prudhoe Bay Unit and witnessed the initial BOP test on well' B-22A by Nabors Rig 9ES. As is usually the case on this rig, the testing went very well and no failures were noted. This rig is extremely clean and all equipment continues to be very well maintained. Total Test Time: _S Number of failures: 0 Attachments: BOP Test (for inspectors) BFL 11/20/00 BOP Nabors 9ES 4-23-01 CS ALASKA OIL AND GAS CONSERVATION COPI~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re~ Prudhoe Bay Unit B-22A BP Exploration (Alaska) Inc. Permit No: 200-157 Sur Loc: 784'SNL, 1897'WEL, Sec. 31, T1 IN, RI4E, UM Btmhole Loc. 3089'SNL, 1214'EWL, Sec. 32, T1 IN, RI4E, 'UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until ali other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORD'ER OF THE COMMISSION DATED this ?~ r* ,~ day of October, 2000 .dlf/Enclosures cc: Department offish & Gmne, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASI~'." STATE OF ALASKA .)IL AND GAS CONSERVATION COMM,SSION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work I~ Drill [] Reddll lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone Re-Entry [] Deepen i2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 73.52' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028310 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AA'~ 25.025) 784' SNL, 1897' WEL, SEC. 31, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2962' SNL, 1187' EWL, SEC. 32, T11N, R14E, UM B-22A Number 2S100302630-277 At total depth 9. Approximate spud date 3089' SNL, 1214' EWL, SEC. 32, T11N, R14E, UM 10/10/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028313, 2189' MDI 284' From B-02A at 7078' 2560 10848' MD / 9207' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 6970' MD Maximum Hole Angle 32 o Maximum surface 2450 psig, At total depth (TVD) 8800' / 3330 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei.qht Grade Couplin.q Len,qth MD TVD MD TVD (include sta.qe data) 8-1/2" 7" 26# L-80 IBT-M 3195' 6820' 5961' 10015' 8500' 419 cu ft Class'G' 6-1/8" 4-1/2" 12.6# 13Cr80 FOX 983' 9865' 8350' 10848' 9207' 166 cu ft Class'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. I~ '~,.~,..~.~ ~.~ ~1 ¥ ~ ...... ~-,~ Present well condition summary Total depth: measured 11275 feet Plugs (measured)SEP 2 7 2:000' true vertical 9164 feet Effective depth: measured 11161 feet Junk (measured) Fill at 11161' (11/89) A~88ka 0il & Gas CorIs, true vertical 9088 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' Surface 2641' 13-3/8" 3720 cuft Permafrost 2676' 2676' Intermediate 10269' 9-5/8" 1470 cu ft Class 'G', 130 cuft PF 10304' 8495' Production Liner 1449' 7" 450 cu ft Class 'G' 9821' - 11270' 8143' - 9161' Perforation depth: measured Open: 11000'- 11032', 11038'- 11052', 11062'- 11082' Sqzd: 10920' - 10955', 10972' - 11000' true vertical Open: 8979' - 9001', 9005' - 9014', 9021' - 9035' Sqzd: 8925' - 8949', 8961' - 8979' ,, 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Nurnbefi Steve Schmitz, 564-5773 Prepared By Name/Nurnbefi Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~------"~,~.. ~'~. ~ Title Senior Drilling Engineer Date ~t~ Permit Number /..~.71APINumber O/ I ApErovalDate- .. J Seecoverletter .~ '~ 50- 029-20759;~'?i) / ~ - ~:::)r~ '-'~)~-'/ for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures I~ Yes [] No Directional Survey Required [] Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K 1~3.5K psi for CTU Other: ORIGINAL SIGNED Approved By D Taylor Seamount by order of ' Commissioner the commission Date /~ -~)~ '" ~ --: Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IB-22A Sidetrack Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location: Target Location: TZ2 Bottom Hole Location' TD 784' SNL & 1897' WEL, Sec. 31, T11N, R14E, Umiat X: 663738 Y: 5949860 2962' SNL, 1187' EWL, SEC. 32, T11N, R14E, Umiat X: 666877 Y: 5947750 TVDss 8925' 3089' SNL, 1214' EWL, SEC. 32, T11N, R14E, Umiat X: 666907 Y: 5947623 TVDss 8800' Well Design: 1. Conventional Sidetrack orient out of 9 5/8", 47#. 2. Drill 8 Y2" Intermediate hole directionally. 3. Set 7" drilling liner at TSGR. 4. Drill 6 1/8" Production hole directionally into Zone 2. 5. Set 4 Y2" solid, Cr, cemented liner, & DPC perforate. 6. Install 4 1/2 Cr Tubulars & completion. Objective: Development producer targeting sands in Zone 2. Option. al: Completion as injector. MD: 10848 TVD: 9207 I IcBE: 45 I I7Es: 28.5 II RKB: 73,52 I Mud Program- Milling/Cutting ¢ :asing, Mud Properties: LSND Density (ppg) Funnel Vis I Yield Point 10.5 45 - 55I 25 - 35 IpH HTHP FL 9 - 9.5 <10 Intermediate Mud Properties: LSND Density(ppg)l 0.5I Funnel Vis 145 - 55 Yield Point23 - 28 Y2" hole I PV I tau0 I 10-17 3-7 pH 9- 9.5 APl FL <10 to 6 Production Mud Properties: Low Density QUICKDRILn Density (ppg) I Funnel vis LSRV PV 8.3 - 8.5I 40 - 50 < 12,000 cP 5 - 8 6 1/8 .... hole 17 - 22 Ca++ <1 O0 APl FI <10 pH 9.0-9.5 Directional: IKOP: I 6970' MD, 6065' TVD - 9 5/8" Casing 46 deg. inclination Maximum Hole Angle: Drop angle to 32 degrees & hold to TD RECEIVED SEP 2 7 2000 Cor,s. Corr~mission Current Well Information Well Name: APl Number: Well Type: Current Status: B-22 50-029-20759 Producer Shut-in BHP: BHT: Last H2S Sample: 205f PSI 3305 TVD I PSI/FTI PPG 8800 0.376 7.22 Mechanical Condition: Wellhead: BFE = 45.02 Tubing: TD / PBTD / Fill: 11270/11212/no fill rpt'd Pre-rig expected to place P&A cement 100' above perfs. Casing Head: Tubing Spool: Tubing Head Adapter: Tbg Hanger: BPV Profile: Tree: 13 5/8 x 13 3/8 x 12 ¼ bore x 9 5/8" Mandrel Hanger 13 5/8 x 13 5/8 13 5/8 x 6"x 5M 5 Y2" IJ4S Landing Thread J Plug, TWC 6 3/8" 5M Open Perfs: Tubing Fluids: Annulus Fluids: 11024-11062, 10920-11024 previously P&A'd Seawater and diesel as per handover Seawater and diesel as per handover Tubing Test: Annular Test: SFC CSG Test: 9 5/8" Pack-off Test: Failed Tubing x IA test, Kinley Caliper Indicates corrosion & holes. Test pending rig setting CIBP. No record Pending Surface Casing Intermediate Prod Liner 13 3/8", 72# @ 2676' 9 5/8", 47# @ 10305' 7", 26# from 9821 to 11207' TD @ 47 degrees inclination. SEP 2 7 2_000 A~ska Oil & Gas Cc~,,s. Cor~rnissio~ .Anchorsge Pre-Riq Work: * Notify the field AOGCC representative with intent to plug and abandon * 1. "S" MIRU slick-line. Drift/tag liner top packer/tailpipe SN -9821'. Tubing is internally corroded per results of Kinley Caliper survey 12/1/99 and will not pressure test. . "C" RIH with CTU. Clean out to below bottom perf. Perform a cement P&A using 15.8 ppg class 'G' cement with adequate cement volume to fill the 7" liner from top of fill to a minimum of 100' above the top perforation with a minimum squeeze of 5 bbls into the perforations. RIH with CTU to confirm TOC in 7" liner. If TOC is higher than WHIPSTOCK DEPTH of 6970' then RIH w/a mill to clean up cement stringers. 3. "S" Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. . "O" Liquid pack the tubing and 9-5/8" x 5-1/2" annulus to surface. Test the integrity of the cement plug and 9-5/8" casing by simultaneously pressure testing both the tubing and 9-5/8" annulus to 3500 psi for 30 minutes. Increase tubing pressure prior to the 9-5/8" annulus to avoid possibility of tubing collapse. . "E" Chemical Cut (preferred vs Jet Cut due to weak/corroded tubing)the 5 1/2" L-80 tubing at approximately 7000' MD(minimum). This cut will not be fished, however avoid cutting a tubing collar. 6. "O" Displace the well to clean seawater by circulating down tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200' MD with diesel. . . , "O" Test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. Service lock down studs by backing out & re-torqueing one at a time. Notify ODE of problems. "O" Bleed tubing and annuli pressures to zero. Set a TWC in the tubing hanger and test from below to 1000 psi. Secure well. "O" Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. SEP 27 2_000 A~aska Oil & Gas Co,~s. Oommissiot~ Ri.q 1. Operations: MIRU Drilling Rig. 2. Circulate out freeze protection and displace well to seawater. Set TWC & BPV/TWC TEST PRESSURE: 3000 PSI. 3. Nipple down tree. Nipple up and BOPE TEST PRESSURE: 3500 PSI. 4. Pull and lay down 5-1/2" tubing from E-line cut and above. 5. MU 9-5/8" whipstock window milling assembly and RIH to top of tubing stub. POOH. 6. RU E-line and set CIBP at - WHIPSTOCK DEPTH -6970' MD. (set as needed to avoid cutting casing collar). 7. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set. Mill window. POOH. 8. RIH with 8-1/2" drilling assembly (with MWD/GR/RES) to whipstock. Kick-off and drill the 8-1/2" intermediate section to Top Sag R. @ +10,015' MD (8500' TVD). 9. Run and cement a 7", 26# intermediate drilling liner. 10. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/NEU) to the landing collar. 11. Test the 9-5/8" casing and 7" liner from the landing collar to surface for 30 minutes. CASING TEST PRESSURE: 3500 PSI 12. Drill the 6-1/8" production section as per directional plan to an estimated TD of 10,848' MD (9206' TVD). 13. Run and cement a 4 Y2", 12.6# 13Cr-80 solid production liner throughout the 6-1/8" wellbore. Displace well to clean 2% KCI water above liner top. POOH LD DP. 14. Test the 4-1/2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 3500 psi for 30 min. 15. Rig up E-line and RIH with cement bond evaluation tool. Log production interval across 4-1/2" liner and cement behind 7" liner up to -500' above the 4-1/2" liner top. POOH and RD. 16. Run the 4-1/2", 12.6# 13Cr-80 New Vam completion tying into the 4-1/2" liner top. 17. Set packer and TUBING TEST PRESSURE 3500 PSI psi and annulus to 3500 psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and TREE TEST PRESSURE 5000 PSI. 19. Freeze protect the well to -2200' and secure the well. 20. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the new production packer. Install gas lift valves, 2. Perforate -100' of Zone 2 with E-line conveyed guns. Formation MD ( TVDss ) Comments: WS1/West Sak 6750 -5827 KOP/Sidetrack 6970 -5992 CM3/K12 7030 -6032 CMl 8517 -6515 Top HRZ 8890 -7505 +/-20' BHRZ 9085 -7655 Kuparak LCU Miluveach Top Kin[lak 9128 -7690 TJH TJG TJF THE TJD TJC TJB Sag River 10015 -8427 Shublik 10049 -8456 Top Sadlerochit 10143 -8535 TZ4 -8535 TZ3 10368 -8726 TZ2 10450 -8796 CGOC 10487 -8827 25P 10549 -8880 24P 10602 -8925 HOT 10648 -8964 22N Shale 10673 -8974 22P 1070O -8985 OOWC 10704 -901.1 Total Depth 10848 -9133 50' + 80' shoe= 130' Rathole below Top HOT LWD & Logging Program: Intermediate Section Drilling: Open Hole: Cased Hole: Production Hole Drilling: Open Hole: Cased Hole: MWD/GR/RES None None MWD / GR / RES/NEU/DEN through "heel" MWD/GR/RES/through horizontal to TD. Contingent on LWD data quality. CBL/CET to verify zonal isolation. WELL CONSTRUCTION DATA Casing/Tubing ram: Hole Size Liner' #/f~ Grade Conn Ft, Req'd Top MD TVD Btm MD TVD ID 8 1/2 7 26 L-80 IBT-M 3195 6820 5961 10015 8500 6.276 6 1/8 4 1/2 12.6 13Cr80 FOX 983 9865 8350 10848 9207 3.958 Tubing 4 1/2 12.6 13Cr80 FOX 9865 0 0 3.958 Drilled Interval 1: Whipstock/window/side-track depth to intermediate casing point. KOP 9 5/8 47# I ID 8.681 I KOP: 6970 I Bit: 8 1/2 to 10015 Total length to be drilled this interval:>>>>> ~ 3045 ft.>>>>>>>>>>>>>>>>>>>>>>>>>>>> Bit Run Bit Mfr Model IADC Krev's Hrs In Out Footage Run I 6970 10015 3045 Run 2 Drilled Interval 2: Drill out of intermediate casing to TD in pay zone. Drill out: 7 26 I ID 6.276 I Shoe: 10015 I Bit: 6 1/8 to 10848 Total length to be drilled this interval:>>>>> ~ 833 ft.>>>>>>>>>>>>>>>>>>>>>>>>>>>> Bit Run Bit Mfr Model IADC Krev's Hrs In Out Ftg Run I 16.66 10015 10848 833 PDC Run 2 4028 feet from top of 7" liner to TD of production interval. Cement Calculations: Liner: Intermediate 8 1/2 inch bit 7 in liner 4 in. DP I Lead: None Tail: Design based on 80' shoe track volume, open hole @ 30% XS, 150' liner lap, 200' XS. Barrels I CF I Sacks I PPG CF/sk TOO, MD TOL ITopOHIBtm, MD Type 74.7 I 419 I 361 I 15.8 1.16 7750 7950 I 8100I 10015 Dowell Class'G" Cement Length, feet 200 150 I 1915 80 Barrels/ft calc's 0.058 0.026 0.029 0.038 Liner: Production 6 1/8 inch bit 4 1/2 inch liner 4 in. DP I Lead: None Tail: Design based on 80' shoe track volume, open hole @ 50% XS, 150' liner lap, 200' XS. Barrels I CF I Sacks I PPG CF/sk TOC, MD TOL ITopOH Btm, MD Type 29.5 I 166 I 142 I 15.8 1.17 9665 9865 I 10015 10848 Dowell CI 'G"+adds Cement Length, feet 200 150 I 833 80 Barrels/ft calc's 0.023 0.019 0.025 0.015 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Maximum Anticipated Surface Pressure: (based on BHP & full gas column at 0.10 psi/ft). Section MaxSfcPres. Presv TVD Gas Grad. EMW FM Intermediate 2427 3264 8369 0.1 7.5 Sag R Production 2450 3330 8800 0.1 7.3 Zone 1 · Planned BOP test pressure: · Planned completion fluid: 3500 psi Intermediate/3500 psi Production 8.6 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies' HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site and does not have wells with over 20 ppm, (1/99). Standard Operating Procedures for H2S precautions should be followed at all times. RIG MOVE & SHUT-IN REQUIREMENTS DRILLING CLOSE APPROACH: There are close approach wells associated with the directional plan for this well. The risk of collision is considered to be minor. The consequences of a collision could include lost circulation or a hydrocarbon influx (kick). Remedial action could include squeeze cementing and sidetracking. IClose Approach Well' B-02A 284' Approach while drilling at 7078' Producing Well INTERMEDIATE SECTION DISCUSSION: Hydrocarbons could be present in the intermediate section. Follow good well control practices at all times. Monitor pit volumes and mud returns for any signs of insufficient mud weight. Tight hole, Torque, Packing-off, Washing & Reaming, and Stuck Pipe have been encountered on this drill-site. Kick-off with sufficient mud weight and maintain MW into the Kingak shale. It is advisable to minimize pressure surges while drilling, tripping, and running liner. After sidetracking the intermediate hole angle will be held @ 32 degrees inclination to casing point. Good drilling practices and 10.5 ppg mud weight will be used to maintain the shales in the intermediate hole section. Also, asphalt shale products such as Baranex and Barotrol in the mud system and the HTHP filtrate values below 10 cc/30 minute will assist with shale stability. It is critical that the intermediate casing depth be located at the Top of the Sag River(TSGR). The site geologist should be on location to correlate depths, analyze cuttings, and to advise on setting depth. KICK TOLERANCE: In INTERMEDIATE open hole section is 44 bbls at an ISIP of 353 psi. This assumes an influx from the Sag River formation at a 10.5 ppg pore pressure, exerting pressure against an 12.5 ppg fracture gradient at the window depth(assumed weak-point). F.I.T. to 12.5 ppg 20' out of casing window. See Kick Tolerance Worksheet. PRODUCTION SECTION DISCUSSION: Hydrocarbons could be present in the production section. Follow good well control practices at all times. Monitor pit volumes and mud returns for any signs of insufficient mud weight KICK TOLERANCE Production hole is an infinite influx (the annular volume) assuming a hydrocarbon influx at section TD. This is a worst case scenario based on a 7.5 ppg pore pressure, a minimum fracture gradient of 9.5 ppg at the intermediate casing shoe, and 8.5 ppg mud in the hole. F.I.T. to 9.5 ppg 20' out of drilling liner. See Kick Tolerance Worksheet. Disposal: · No annular injection in this well. ° Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Ri_qsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Section: ~/ The intermediate section will be drilled with mud weight @ 10.5 ppg to combat shale instability in the HRZ shale and Kingak shale, after side-tracking from the kick-off-point. 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. Production Interval: ~/ Lost Returns & Stuck Pipe have been experienced during past Drill Site Operations. Mud weight will be maintained in the 8.3-8.5 ppg range to control formation EMW at 7.3 ppg. This Drill Site is not a designated H2S pad. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION ]0 TREE: 6" - 5M CIW L-80 WELLHEAD: 13 5/8" - 5M McEvoy SSH 13-3/8", 72 #/ft, L80, BTC I 2676' I B-22A Proposed Completion 4-1/2" 'X' Landing Nipple with 3.813" seal bore. Cellar Elevation = 43.02' Base Flange = 45.02' Nabors 7ES RKB = 73.02' Window Milled from Whipstock Top of Window at +/-6970' MD Bddge Plug set at +/-6994' MD I +/-6820' IBAKER 7" x 9-5/8' Tie Back Sleeve ZXP Liner Top Packer 'Flex Lock' Hydraulic Liner Hanger 4-1/2" 12.6# 13Cr-80, New VamTubing with GLM's GAS LIFT MANDREL,~ I IVD Size -- V al~/e Type ' TBD 1-1/2" RP Shear " 1-1/2" DV " 1-1/2" DV " 1" DV " 1" DV " 1" DV 3 4 5 6 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7' x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I I BAKER 5" x 7" Tie Back Sleeve +/-9865' ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 9-5/8", 47 #/ft, L80, BTC I +/-10,015' I 7", 26 #/ft, L-80, BTC-Mod 4-1/2" 12.6 #/ft, 13Cr-80, New Vam Plug Back Depth I +/-10,848' I I +/-10,760' I 7", 26 #/it, L80, IJ-4S ~ Date Rev By Comments PRUDHOE BAY UNIT 08/17/00 WSl Proposed Completion WELL: B-22A APl NO: 50-029-20759-01 Shared Services Drilling ~ SERVICES a uxu_t~.rt~.,~ cmmun~- Current Well Properties Well: B-22A Horizontal Coordinates: Ref, Global Coordinates: Ref. Structure Reference : Ref. Geographical Coordirates: RKB Elevation: North Reference: Units: 5949860.00 N, 663738.00 E 3383.98 N, 1718.00 E 70° 16' 09.7531' N, 148° 40' 32.8529' W 73.02ft above Mean Sea Level 73.02ft above Stracture Reference True North Feet 6000 6600 - 7200 - 7800- 8400 - ._~ 9000 - ,I- -- Shared Services Drilling B-22A Wp 02 Single Well Target Data for B-22A Measurement Units: It Coordinate Target Point TVDrkb TVDss Northinge EasUnge ASP Y ASP X Target Name Type Shape B-22A Polygon Enlry Point 1850.70 S 2816.41 E 5948071.00 lq 666594.00 E Polygon Boundary PoinlA 1850.70 S 2816.41 E 5948071.00N 666594.CO E B 2380_61 S 3035.93E 5947546.00N 666825.00E C 2283.76S 3320.11 E 5947649.CON 667107.00E D 1735.32 S 3075.98 E 5948192.00 N 666851.00 E Emry Point8500.02 8427.00 1873.22 S 3028.01 E 5948053.09 N 666806.05 E Poinl B-22A TSGR Target 80.000° TF: 6970.00ft MD, 6065.15ft TVD · 7010.00ft MD, 6092.70ft TVD ST Exit @ 12 ~Q00°/10...0ft 80.000° TF: 6970.00ft MD.L_6 c/~3//o2 ~egin t)~r ~ 9.000°/100ft: 7010.00ft MD 6]05.02 End Dir: 7501.30ft MD, -600 .30ft MD, 6472.81ft TVD CM2 I DrillQuest' Eastings Scale: linch = 60Oft 24OO :TVD 3000 I d'r'm m 8412A [_ -600 Formation/BHA Trend @ 0.400°/100ft· 8516.79ft MD 7273.02ft TVD -1200 .......... ~...o.._4o..o.o/_!.o.~t ;._8_5..1.6....79c~}VID, 7273.02ft TVD 7273.02 Top HRZ ........................... x~' ............................. 7578.02 ( ~ Base HRZ ................................... ! .................. .'X ........................... 7728.02 .................................... ~ ...........-" :: ~" ....................... Top Kingak X 'X~oo.oo 7763.02 ~s~.oo h~4oo.oo B-22~ TSGR Target \ Vo~ ~ ssoo. ox, ro \\ 18, ., qo28.o1 ~ 7" Uner ~ 5m ~B .... 1~15.30 X~'~ ~ ~ 85~.~ k End dir: ~0015.36ft MD, 85~.0~t TVD .................................... .......................................... X ....... ~ .................... ~ ................... ~X ~ ...... .................................... ~ .................. ~& .............. ............ ........................................... x .............................................. .,.x ................ ................................................................ X- ~ ....... ~. ~ ............ ~.o~ ..................................................................~~~~~~~...~~~'" ~ ~:~ ...... ~o, ..... ~?o,~ ~.o~ I I I I 4 1/2" Uner 10~.58 1200 1800 2400 3000 ~06.~ Scale: linch = 600ff Section Azimuth: 162.717° ~rue Nodh) Vedical Section -1800 End Dir' -2400 7" Liner 10015.36 MD 8500.02 'I-VD MD, 8500.02ft 4 1/2" Liner 10848.58 MD. 9206.63 TVD I 2400 3000 Scale: I incl~e~t(i~l~ee is True North Eastings -1200 ~ o Z -1800 Target 0 TVD S, 3028.01 E II ._ _ -2400 g Proposal Data for B-22A Wp02 Ve~cal Origin: Well Ho~.ontal Origin: Well Measurement Units: ft Norih Reference:True Noflh Dogleg severity:Degrees per 10Oft VerticaISectionAzJmuth: 162,717° Verlical Section DescriplJon.'Well Vertical Section Origin: 0.00 N,O.O0 E Measured Incl. Azhn. Vertical NorlhIngs Eastings VerticalDogleg Depth Depth Section Rate 6970.00 46.00095.013 6065.15 223.74 S 2472.211E948.11 7010.00 47.018101.481 6092.70 227.91 S 2500.89 E9611.61 12,000 7501.30 38.000168.000 6472.81 421.31 S 2719.40 E1211L20 9.0{10 8516.79 38.000168.000 7273.02 1032.84 S 2849.39 E1832.73 0.000 10015.3632.000168.000 8500.02 1873.22 S 3028.01 E2688.24 0.400 10557.7632.000168.000 8960.00 2154.37 S 3087.77 E2974.44 I}.110¢1 10648.5832.000168.000 9037.02 2201.44 S 3097.78 E3(122.37(I.(X}0 10848.5832.000168.000 9206.63 2305.11 S 3119.81 E3127.911 Sperry-Sun Drilling Services Proposal Data - B-22A - B-22A Wp02 :::11: 6970.00 .2 :: ,: 7010,~ 40.00 ~ .47;018 : :.::..: 27:54:: '~: 12.000 80.000 3 7501,30 491.30 38.0001 168.000 6472.81 380.11 421.31S 2719.40E 9.000 125.932 4' 8516,791 1015.48 38.0001 16e.000 7273.02 800.21 1032.84. S 2849,39EI 0.000 0.000 5 10015,38 1498,58 32.0001 168.000 8500.02 1227.00 1873.22S 3028.01E 0,400 179.998 6 10557.76 542,40 32.000 168.000 8960,00 459°98 2154.37S 3087.77E 0,000 0.000 --7' 10648,58 90,82 32,000 168,000 9037.02 77.02 2201.44 S 3097.78 E 0.000 0.000 8 10848,58 200.00 32.000 168.000 9206,63 169.61 2305.11 S 3119.81 E 0.000 0.000 17 A ugus t, 2000 - 10:50 - 1 - DriliQuest DATE CHECK NO. vcr~uu~ ¢"~[,.~ ~:31~¢'~1;t~ I ~ ! 1 U DATE INVOICE / CREDff MEMO DE~RIPT~N GRO~ DI~OUNT NET B2200 ~KOB2200F ~00. O0 ]00. O0 HANDLIJqG INST: TERR[E HUBBLE X4&28 : A~ACHED CHECK IS IN PAYME~ FOR ~US DE~RIB~ ABOVE. ~ 1OO. OO 1 OO. OO ':-;:-;"::.i; -":. :'!: .:A~.I~i UATE:.~ -:!::ii;':.:' ::;:: 7.: .. :i.::!:]!: ::...;:]' NA'QON~.~-:blTyj~,~K ::'!: .-:.; ::..;; :;:??:---F:~ '~.~vE~D, ~'~ib :.;'.::; ;'.- '" :': ": ~- F:: -r :::.:. ':. '-". :':~:: :.1 ~': -:: -:: ~':: Z 412 '00173374 ':-'-" ANCHORAGE AK 99501 ,' ], ? :~ :~ ? h," ~:O~,~i~O~,P, qiS~: OO,Bhh],~," S£P 7 000 Nasl(,,.a Oil & Gas G~ns, Anchor.age STATE OF ALASKA ALASKa" .~IL AND GAS CONSERVATION COM~..~SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: I~1 Abandon [] Suspend [] Plugging [] Time Extension [] Pedorate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 784' SNL, 1897' WEL, SEC. 31, T11N, R14E, UM At top of productive interval 1583' SNL, 2497' WEL, SEC. 32, T11N, R14E, UM At effective depth 1862' SNL, 1962' WEL, SEC. 32, T11N, R14E, UM At total depth 1907' SNL, 1890' WEL, SEC. 32, T11N, R14E, UM 6. Datum Elevation (DF or KB) KBE = 80.20' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number B-22 9. Permit Number 182-089 10. APl Number 50-029-20759-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Casing Present well condition summary Total depth: measured 11275 feet Plugs (measured) true vertical 9164 feet Effective depth: measured 11161 feet Junk (measured) Fill at 11161' (11/89) true vertical 9088 feet Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' Surface 2641' 13-3/8" 3720 cu ft Permafrost 2676' 2676' Intermediate 10269' 9-5/8" 1470 cuft Class 'G', 130 cu ft PF 10304' 8495' Production Liner 1449' 7" 450 cu ft Class 'G' 9821' - 11270' 8143' - 9161' Sqzd: 10920' - 10955', 10972' - 11000' true vertical Open: 8979'- 9001', 9005'- 9014', 9021'-9035' ~F_P ~- Sqzd: 8925' - 8949', 8961' - 8979' Tubing (size, grade, and measured depth) 5-1/2", 17, L-80 to 9744' with 4-1/2" tailpipe to 9877~:.~ '0i~ & '"'~ ' Packers and SSSV (type and measured depth) 9-5/8" Baker packer at 9744,; 5-1/2" SSSV Landing Nipple at 2141' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch 4. Estimated date for commencing operation ~15. October 3, 2000 16.. If proposal was verbally approved Name of approver Date Approved Status of well classifications as: [] Oil [] Gas [] Suspended Service Contact Engineer Name/Number: Steve Schmitz, 564-5773 Prepared By Name/Numbec Terrie Hubble, 564-4628 "i 7. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed'Dan Stone 4::~.,--,~"~. ~ Title Senior Drilling Engineer Date ~ 1,3,$ I~ Conditions of Approval: Notify Commission so representative may witness I Approval No. Plug integrity __ BOP Test __ Location clearance __ I Mechanical Integrity Test Subsequent form required 10-.... Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate North Slope Alaska Alaska State Plane 4 PBU WOA B Pad B-22A Wp02 PROPOSAL REPORT 17 August, 2000 Surface Coordinates: 5949860.00 N, 663738.00 E (70° 16' 09.7531" N, 148° 40' 32.8529" W) Kelly Bushing: 73.02ft above Mean Sea Level Proposal Ref: pro9932 Sperry-Sun Drilling Services Proposal Report for B-22A Wp02 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 6970.00 46.000 95.013 5992.13 7000.00 46.729 99.885 6012.84 7010.00 47.018 101.481 6019.68 7027.92 46.086 103.293 6032.00 7100.00 42.654 111.174 6083.56 7200.00 38.935 123.744 6159.38 7300.00 36.763 138.007 6238.49 7400.00 36.424 153.121 6318.95 7500.00 37.968 167.816 6398.76 7501.30 38.000 168.000 6399.79 7600.00 38.000 168.000 6477.56 7647.51 38.000 168.000 6515.00 7700.00 38.000 168.000 6556.36 7800.00 38.000 168.000 6635.16 7900.00 38.000 168.000 6713.97 8000.00 38.000 168.000 6792.77 8100.00 38.000 168.000 6871.57 8200.00 38.000 168.000 6950.37 8300.00 38.000 168.000 7029.17 8400.00 38.000 168.000 7107.97 8500.00 38.000 168.000 7186.77 8516.79 38.000 168.000 7200.00 8600.00 37.667 168.000 7265.72 8700.00 37.266 168.000 7345.09 8800.00 36.866 168.000 7424.89 Vertical Local Coordinates Depth Northings Eastings (fi) (~) (~) 6065.15 223.74 S 2472.20 E 6085.86 226.56 S 2493.72 E 6092.70 227.91S 2500.89 E 6105.02 230.70 S 2513.59 E 6156.58 245.50 S 2561.68 E 6232.40 275.26 S 2619.52 E 6311.51 315.03 S 2665.77E 6391.97 363.86 S 2699.28 E 6471.78 420.52 S 2719.23 E 6472.81 421.31S 2719.40 E 6550.58 480.74 S 2732.04 E 6588.02 509.35 S 2738.12 E 6629.38 540.96 S 2744.84E 6708.18 601.18 S 2757.64 E 6786.99 661.40 S 2770.44E 6865.79 721.63 S 2783.24 E 6944.59 781.85 S 2796.04 E 7023.39 842.07 S 2808.84 E 7102.19 902.29 S 2821.64E 7180.99 962.51S 2834.44E 7259.79 1022.73 S 2847.24 E 7273.02 1032.84 S 2849.39 E Global Coordinates Northings Eastings (ft) (ft) 5949690.10 N 666214.48 E 5949687.75 N 666236.06 E 5949686.55 N 666243.26 E 5949684.04 N 666256.02 E 5949670.28 N 666304.42 E 5949641.79 N 666362.89 E 5949603.03 N 666409.99 E 5949554.95 N 666444.56 E 5949498.73 N 666465.74 E 5949497.95 N 666465.92 E 5949438.80 N 666479.85 E 5949410.33 N 666486.55 E 5949378.87 N 666493.96 E 5949318.95 N 666508.06 E 5949259.02 N 666522.17 E 5949199.09 N 666536.28 E 5949139.16 N 666550.38 E 5949079.23 N 666564.49 E 5949019.31N 666578.60 E 5948959.38 N 666592.71 E 5948899.45 N 666606.81E 5948889.39 N 666609.18 E 7338.74 1082.76 S 2860.00E 5948839.71N 666620.88 E 7418.11 1142.26 S 2872.65 E 5948780.50 N 666634.82 E 7497.91 1201.22 S 2885.18 E 5948721.83 N 666648.63 E Dogleg Rate (°/100fi) 12.000 12.000 9.000 9.000 9.000 9.000 9.000 9.000 9.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.400 0.400 0.400 Alaska State Plane 4 PBU_WOA B Pad Vertical Section (ft) 948.11 957.19 960.61 967.05 995.47 1041.07 1092.79 1149.36 1209.40 1210.20 1270.70 1299.83 1332.01 1393.31 1454.62 1515.92 1577.22 1638.53 1699.83 1761.14 1822.44 1832.73 1883.56 1944.13 2004.15 Comment ST Exit @ 12.000°/100ft, 80.000° TF: 6970.00ft MD, 6065.15ft TVD Be_qin Dir @ 9.000°/100ft: 701'0.00ft MD, 6092.70ft TVD CM3/K12 End Dir: 7501.30ft MD, 6472.81ft TVD CM2 Formation/BHA Trend @ 0.400°/100ft: 8516.79ft MD, 7273.02ft TVD CMl Continued... 17 August, 2000- 10:51 - 2- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for B-22A Wp02 North Slope Alaska Measumd Sub-Sea Depth Incl. Azim. Depth (~) (~) 8899.88 36.466 168.000 7505.00 8900.00 36.466 168.000 7505.10 9000.00 36.065 168.000 7585.73 9085.51 35.723 168.000 7655.00 9100.00 35.665 168.000 7666.77 9128.58 35.551 168.000 7690.00 9200.00 35.265 168.000 7748.21 9300.00 34.864 168.000 7830.07 9400.00 34.464 168.000 7912.32 9500.00 34.063 168.000 7994.96 9600.00 33.663 168.000 8078.00 9700.00 33.263 168.000 8161.42 9800.00 32.862 168.000 8245.23 9900.00 32.462 168.000 8329.42 10000.00 32.062 168.000 8413.98 10015.36 32.000 168.000 8427.00 10049.56 32.000 168.000 8456.00 10100.00 32.000 168.000 8498.78 10142.71 32.000 168.000 8535.00 10200.00 32.000 168.000 8583.58 10300.00 32.000 168.000 8668.39 10367.94 32.000 168.000 8726.00 10400.00 32.000 168.000 8753.19 10450.48 32.000 168.000 8796.00 10487.03 32.000 168.000 8827.00 Ve~ical Local Coordinates Global Coordinates Depth Nothings Eastings Nodhings Eastings (~) (~) (~) (~) (~) 7578.02 1259.56 S 2897.58 E 5948663.77 N 666662.29 E 7578.12 1259.63 S 2897.59 E 5948663.70 N 666662.31 E 7658.75 1317.49 S 2909.89 E 5948606.12 N 666675.86 E 7728.02 1366.53 $ 2920.32 E 5948557.32 N 666687.35 E 7739.79 1374.80 S 2922.07 E 5948549.09 N 666689.29 E 7763.02 1391.07 S 2925.53 E 5948532.90 N 666693.10 E 7821.23 1431.55 S 2934.14 E 5948492.62 N 666702.58 E 7903.09 1487.74 S 2946.08 E 5948436.70 N 666715.75 E 7985.34 1543.38 S 2957.91E 5948381.33 N 666728.78 E 8067.98 1598.45 S 2969.61 E 5948326.53 N 666741.68 E 8151.02 1652.95 S 2981.20 E 5948272.29 N 666754.45 E 8234.44 1706.89 S 2992.66 E 5948218.62 N 666767.08 E 8318.25 1760.25 S 3004.00E 5948165.52 N 666779.58 E 8402.44 1813.04 S 3015.22 E 5948112.98 N 666791.95 E 8487.00 1865.25 S 3026.32 E 5948061.02 N 666804.18 E 8500.02 1873.22 S 3028.01 E 5948053.09 N 666806.05 E 8529.02 1890.94 S 3031.78 E 5948035.46 N 666810.20 E 8571.80 1917.09 S 3037.34E 5948009.44 N 666816.32 E 8608.02 1939.23 S 3042.04 E 5947987.40 N 666821.51 E 8656.60 1968.92 S 3048.35E 5947957.85 N 666828.46 E 8741.41 2020.76 S 3059.37 E 5947906.27 N 666840.61E 8799.02 2055.97 S 3066.86 E 5947871.23 N 666848.86 E 8826.21 2072.59 S 3070.39 E 5947854.69 N 666852.75 E 8869.02 2098.76 S 3075.95 E 5947828.65 N 666858.88 E 8900.02 2117.71 S 3079.98 E 5947809.80 N 666863.32 E Dogleg Rate (°/100fi) 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.400 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA B Pad Ve~ical Section (fi) 2063.53 2063.61 2122.51 2172.43 2180.85 2197.41 2238.62 2295.83 2352.46 2408.52 2464.01 2518.91 2573.24 2626.97 2680.13 2688.24 2706.28 2732.90 2755.44 2785.67 2838.43 2874.28 2891.20 2917.84 2937.12 Comment Top HRZ Base HRZ Top Kingak End Dir: 10015.36ft MD, 8500.02ft TVD 7" Liner TSGR B-22A TSGR Target, Geological TSHU TSAD/TZ4 TZ3 TZ2 CGOC Continued... 17August, 2000- 10:51 - 3 - DrillQuest 1.05o05a Sperry-Sun Drilling Services Proposal Report for B-22A Wp02 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) (~) 10500.00 32.000 168.000 8838.00 10549.53 32.000 168.000 8880.00 10557.76 32.000 168.000 8886.98 10600.00 32.000 168.000 8922.80 10602.59 32.000 168.000 8925.00 10648.58 32.000 168.000 8964.00 10660.37 32.000 168.000 8974.00 10673.34 32.000 168.000 8985.00 10700.00 32.000 168.000 9007.61 10704.00 32.000 168.000 9011.00 10800.00 32.000 168.000 9092.41 10848.58 32.000 168.000 9133.61 Ve~ical Local Coordinates Global Coordinates Depth Nothings Eastings Nothings Eastings (~) (~) (~) (~) (~) 8911.02 2124.43 S 3081.41E 5947803.11N 666864.89 E 8953.02 2150.10 S 3086.86 E 5947777.56 N 666870.91E 8960.00 2154.37 S 3087.77E 5947773.31 N 666871.90 E 8995.82 2176.26 S 3092.42 E 5947751.53 N 666877.03 E 8998.02 2177.60 S 3092.71 E 5947750.19 N 666877.35 E 9037.02 2201.44 S 3097.78 E 5947726.47 N 666882.93 E 9047.02 2207.55 S 3099.08 E 5947720.38 N 666884.36 E 9058.02 2214.28 S 3100.50 E 5947713.69 N 666885.94 E 9080.63 2228.09 S 3103.44E 5947699.94 N 666889.18 E 9084.02 2230.17 S 3103.88 E 5947697.88 N 666889.66 E 9165.43 2279.93 S 3114.46E 5947648.36 N 666901.32 E 9206.63 2305.11S 3119.81E 5947623.30 N 666907.22 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 162.717° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10848.58ft., The Bottom Hole Displacement is 3879.02ft., in the Direction of 126.459° (True). Dogleg Rate (°/100fi) 0.000 0.000 0.000 0.0o0 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 PBU_WOA B Pad Ve~ical Section (fi) 2943.97 2970.10 2974.44 2996.73 2998.10 3022.37 3028.59 3035.43 3049.50 3051.61 3102.27 3127.90 Comment 25P 24P HOT 22N SHALE 22P OOWC Total Depth: 10848.58ft MD, 9206.63ft TVD 4 1/2" Liner Continued... 17August, 2000- 10:51 -4- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for B-22A Wp02 North Slope Alaska Alaska State Plane 4 PBU WOA B Pad -- Comments Measured Depth (ft) 6970.00 7010.00 7501.30 8516.79 10015.36 10848.58 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6065.15 223.74 S 2472.20 E 6092.70 227.91 S 2500.89 E 6472.81 421.30 S 2719.40 E 7273.02 1032.84 S 2849.39 E 8500.02 1873.22 S 3028.01 E 9206.63 2305.11 S 3119.81 E Formation Tops Measured Ve~ical Sub-Sea Depth Depth Depth (~) (~) (~) 7027.92 6105.02 6032.00 7647.51 6588.02 6515.00 8516.79 7273.02 7200.00 8899.88 7578.02 7505.00 9085.51 7728.02 7655.00 9128.58 7763.02 7690.00 10015.36 8500.02 8427.00 10049.56 8529.02 8456.00 10142.71 8608.02 8535.00 10367.94 8799.02 8726.00 10450.48 8869.02 8796.00 10487.03 8900.02 8827.00 10549.53 8953.02 8880.00 10602.59 8998.02 8925.00 10648.58 9037.02 8964.00 Comment ST Exit @ 12.000°/100ft, 80.000° TF: 6970.00ft MD, 6065.15ft TVD Begin Dir @ 9.000°/100ft: 7010.00ft MD, 6092.70ft TVD End Dir: 7501.30ft MD, 6472.81ft TVD Formation/BHA Trend @ 0.400°/100ft: 8516.79ft MD, 7273.02ft TVD End Dir: 10015.36ft MD, 8500.02ft TVD Total Depth · 10848.58ft MD, 9206.63ft TVD Northings Eastings Formation Name (ft) (ft) 230.70 S 2513.59 E CM3/K12 509.35 S 2738.12 E CM2 1032.84 S 2849.39 E CMl 1259.56 S 2897.58 E Top HRZ 1366.53 S 2920.32 E Base HRZ 1391.07 S 2925.53 E Top Kingak 1873.22 S 3028.01 E TSGR 1890.94 S 3031.78 E TSHU 1939.23 S 3042.04 E TSAD/TZ4 2055.97 S 3066.86 E TZ3 2098.76 S 3075.95 E TZ2 2117.71 S 3079.98 E CGOC 2150.10 S 3086.86 E 25P 2177.60 S 3092.71 E 24P 2201.44 S 3097.78 E HOT Continued... 17 August, 2000- 10:51 -5- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for B-22A Wp02 North Slope Alaska Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) Formation Tops (Continued) 10660.37 9047.02 8974.00 10673.34 9058.02 8985.00 10704.00 9084.02 9011.00 Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 10015.36 <Surface> <Surface> 10848.58 Targets associated with this wellpath Target Name B-22A Polygon Northings Eastings Formation Name (ft) (ft) 2207.55 S 3099.08 E 22N SHALE 2214.28 S 3100.50 E 22P 2230.17 S 3103.88 E OOWC Vertical Depth Casing Detail (ft) 8500.02 7" Liner 9206.63 4 1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 Target Entry Coordinates TVD Northings Eastings (~) (~) (~) 8500.02 1850.70 S 2816.41E 8427.00 5948071.00 N 666594.00 E 70°15'51.5450"N 148° 39'10.8830"W 8500.02 1850.70 S 2816.41E 8500.02 2380.61 S 3035.93 E 8500.02 2283.76 S 3320.11 E 8500.02 1735.32 S 3075.98 E Alaska State Plane 4 PBU WOA B Pad -- Target Target Shape Type Polygon Geological Continued... 17August, 2000 - 10:51 - 6 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for B-22A Wp02 North Slope Alaska Target Name Targets associated with this wellpath (Continued) B-22A TSGR Target Mean Sea Level/Global Coordinates #1 #2 #3 #4 Geographical Coordinates #1 #2 #3 #4 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 8427.00 5948071.00 N 666594.00 E 8427.00 5947546.00 N 666825,00 E 8427.00 5947649.00 N 667107.00 E 6427.00 5948192.00 N 666851.00 E 70° 15' 51.5450" N 148° 39' 10.8830" W 70° 15' 46.3322" N 148° 39' 04.5001" W 70° 15' 47.2836" N 148° 38' 56.2287" W 70° 15' 52.6789" N 148° 39' 03.3269" W 8500.02 1873.22 S 3028.01 E 8427.00 5948053.09 N 666806.05 E 70° 15' 51.3228" N 148° 39' 04.7246" W Alaska State Plane 4 PBU_WOA B Pad Target Target Shape Type Point Geological 17August, 2000- 10:51 - 7- DrillQuest 1.05,05a : WELL PERMIT CHECKLIST FIELD & POOL & V~) ADMINISTRATION WELL NAME ~-~ PROGRAM: exp GEOLAREA ENGINEER--~NG 14. II 15. 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and*number.~E, ~°¢~. ~.f?-~-.~. ~', ~ .~---. '(~..~z,.,i~t 4. Well located in a defined pool .................. dev ~'' reddl ~ serv wellbore seg ann. disposal para req UNIT# ON/OFF SHORE 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... (~ N 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ ~) N 26. BOPE press rating appropriate; test to ..~ ~'00 psig. ~.N. 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. (~N N I ~ C~'"'c-.~ ~DN GEOLOGY 30. 31. 32. .~ DATE 33. ~" Z,~' ,~ 34. Permit can be issued w/o hydrogen sulfide measures ..... ~ Data presented on potential overpressure zones ...... . .,~ ~,"~ Y N Seismic analysis of shallow gas zones ........ ~ ~. Y N Seabed condition survey (if off-shore) ..... .~,~_.._.. _.. Y N Contact name/phone for weekly progress reed'As[exploratory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain was~ in a suitable receiving zone; ....... Y N APPR DATE (B) will not contami/late freshwater; or cause~..ddtli~ste ... Y N to surface; / (C) will not impa/me~f the well u~e/~ f~ Y N (D) will not dam very from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/RI~nu,~ COMMISSION: Comments/instructions: c:\msoffiCe\wordian\diana\checklist (rev. 02/17/00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this. .nature is accumulated at the end of the file under APPE .NDIXi No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utilit3' SRevision: 3 $ LisLib SRevision: 4 $ Thu Jun 27 11:27:45 2002 Reel Header Service name ............. LISTPE Date ..................... 02/06/2~ Origin ................... STS Reel Name ................ UNKNOWN Continuation Nun~er ...... 01 Previous Reel Name ....... UNKNOWN CoI~ents ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/06/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMP.ANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-10128 M. HANIK T. ANGLEN B-22A 500292075901 BP Exploration (Alaska), Inc. Sperry Sun 27-JUN-02 MWD RUN 3 AK-MM-10128 R.MCNEILL T. ANGLEN 31 lin 14E 784 189'7 .00 72.30 45.02 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ]_ST STRING 6977.0 2ND STRING 8.500 7.000 9905.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL, DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). MWD RUN 3 IS DIRECTIONAL WITH DUAL, GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LiTH-DENSITY (SLD). GAMMA RAY {DGR) FROM 6772' MD, 5927' TVD TO 6977' MD, 6070' TVD WAS OBTAINED ON A MADPASS WHILE RUNNING IN THE HOLE TO DRILL MWD RUN 2 AND IS LOGGED BEHIND CASING. GAMMA RAY (DGR) FROM 9873' MD, 8474' TVD TO 9905' MD, 8501' TVD IS LOGGED BEHIND CASING. RESISTIVITY DATA FROM 9866' MD, 8467' TVD TO 9905' MD, 8501' TVD IS LOGGED BEHIND CASING. 7. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHNORR OF 02/08/02 PER B. METZGER OF BP EXPLORATION (ALASKA), INC.. MWD DATA CONSIDERED PDC. THIS WELL KICKS OFF FROM B-22 AT 6977' MD, 6070' TVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUNS 2 & 3 REPRESENT WELL B-22A WITH AP1 # 50-029-20759-01. THIS WELL REACHED A TOTAL DEPTH OF 10902' MD, 9157' TVD. SROP = SMOOTHED iRATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING ) SEMP= SMOOTHED PHASE SHIFT DERIVED RESISTIVITY MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SCO2 = BIN) SNP2 = ABSORPTION TNPS = (SANDSTONE CTNA = RATE CTFA = RATE SMOOTHED BULK DENSITY (LOW-COUNT BIN) SMOOTHED STANDOFF CORRECTION (LOW-COUNT SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC FACTOR (LOW-C SMOOTHED THERMAL NEUTRON POROSITY MATRIX, FIXED HOLE SI SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.125" MUD WEIGHT: 8.5 - 8.5 PPG MUD FILTRATE SALINITY: 1000 PPM CHLORIDES FORMATION WATER SALINITY: 28,000 PPM CHLORIDES FLUID DENSITY: 1.00 G/' CC MATRIX DENSITY: G/CC LiTHOLOGY: SAN DSTON E Fi2e Header Service name ............. STSLIB.00i Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/27 Ma:.:imum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP FCNT NCNT RHOB DRHO PEF NPHI $ BASELINE CURVE FOR SHIFTS: START DEPTH 6771 5 6967 0 6967 0 6967 0 6967 0 6967 0 7008.0 9895.0 9895.0 9895.0 9895.0 9895.0 9895.0 CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 10863.5 10870.5 ].0870.5 1.0870.5 10870.5 10870.5 10902.0 10828.0 10828.0 10842.0 10842.0 10842.0 10828.0 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 2 6771.5 MWD 3 9905.5 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 9905.0 10902.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 NCNT ~'~WD CP30 4 1 68 FCNT MWD CP30 4 1 68 RHOE, b~qD G/CM 4 1 68 DRHO ~YWD G/Chi 4 1 68 PEF MWD B/E 4 1 68 32 36 4O 44 48 52 9 i0 il 12 13 14 Name Service Unit Min Max DEPT FT 6771.5 10902 ROP MWD FT/H 0.65 153.1 GR MWD AP1 13.43 574.64 RPX MWD OHMM 0.6 1775.55 RPS MWD OHHM 0.43 1812 RPM MWD OHMM 0.42 2000 RPD MWD OHMM 0.51 2000 FET MWD HR 0.3 73.23 NPHI MWD PU-S 3.75 49.34 NCNT MWD CP30 14766.9 55163 FCNT MWD CP30 139.15 4338.5 RHOB MWD G/CM 1.08 3.4 DRHO MWD G/CM -1.28 0.34 PEF MWD B/E 1.37 12.04 Mean 8836.75 58.°617u 103.813 8. 98591 11. 0366 28.741 26.8777 1.76543 20.1183 30926.2 855. 933 2.32034 0. 020153 2.49268 First Reading For Entire File .......... 6771.5 Last Reading For Entire File ........... 10902 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Nsam 8262 7789 8185 7808 7808 7808 7808 7808 1867 1867 1867 1895 1895 1895 First Reading 6771.5 '7008 6771.5 6967 6967 6967 6967 6967 9895 9895 9895 9895 9895 9895 Last Reading 10902 10902 10863.5 10876}.5 10870.5 1087{}.5 10870.5 10870.5 10828 10828 10828 10842 10842 10842 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6771.5 RPX 6967.0 RPS 6967.0 FET 6967.0 RPD 6967.0 RPM 6967.0 ROP 7008.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 9873.5 9866 0 9866 0 9866 0 9866 0 9866 0 9905 0 30-APR-01 SURFACE SOFTWARE VERSION: DO?~HOLE SOFTWARE VERSION: DATA TYPE iMEMORY OR REAL-TIME): Ti, DRILLER (FT): TOP LOG INTERVAL (FT): 8OTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG H!NIMUM ANGLE: MAI{IMUM ANGLE: Insite 4.05.5 66.16 Memory 99{!5.0 32.2 45.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01990HWGR6 EWR4 ELECTROMAG. RESIS. 4 PB01990HWGR6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.000 9905.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.80 MUD VISCOSITY (S): 42.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 1300 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.700 MUD AT MAX CIRCULATING TERMPERATURE: .849 MUD FILTRATE AT MT: 1.900 MUD CAKE AT MT: 2.200 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 70.0 147.0 70. {} 70. {} Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 RPM MWD020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEP'r FT 6771.5 9905 ROP MWD020 FT/H 1.6 153.1 GR MWD020 API 23.17 381.71 RPX MWD020 OHMM 0.6 1775.55 Mean 8338.25 64.3149 121.272 2.9593 Nsam 6268 5795 6205 5799 First Reading 6771.5 7008 6771.5 6967 Last Reading 9905 9905 98'73.5 9866 RPS PR4D020 OHMM 0.6 1812 RPM PRqD020 OHb~'I 0.62 1861.74 RPD MWD020 OHMM 0.57 2000 FET MWD020 HR 0.3 5.33 2.83508 4. 19526 7.19569 0. 970717 First Reading For Entire File .......... 6771.5 hast Reading For Entire File ........... 9905 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 57 99 5799 5799 5799 6967 6967 6967 6967 9866 9866 9866 9866 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE RPD RPX RPM FET RPS GR PEF NPHI NCNT FCNT RHOB DRHO ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 9866.5 9866.5 9866 5 9866 5 9866 5 9874 0 9895 0 9895 0 9895 0 9895.0 9895.0 9895.0 9905.5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10828 1,0828 10828 10842 10842 1.0902 STOP DEPTH 10870.5 10870.5 10870.5 10870.5 10870.5 10863.5 10842 0 0 0 0 0 0 04-MAY-01 Insite 4.05.5 66.16 Memory 10902.0 29.9 53.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB01993HAGR4 EWR4 ELECTROMAG. RESIS. 4 PBO1993HAGR4 CTN SLD COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (P?M): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Uni'ts ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 0 ROP MWD030 FT/H 4 1 68 4 GR MWD030 API 4 1 68 8 RPX MWD030 OHMM 4 1 68 12 RPS MWD030 OHMM 4 1 68 16 RPM MWD030 OHMM 4 1 68 20 RPD MWD030 OHMM 4 1 68 24 FET MWD030 HR 4 1 68 28 NPHI MWD030 PU-S 4 1 68 32 NCNT MWD030 CP30 4 1 68 36 FCNT MWD030 CP30 4 1 68 40 RHOB MWD030 G/CM 4 1 68 44 DRHO MWD030 G/CM 4 1 68 48 PEF MWD030 B/E 4 1 68 52 PB01931NL4 PBO193iNL4 6.125 QUI KDRI L-N 8.50 42.0 9.3 1000 13.0 2.800 1.167 3.200 2.600 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 69.0 175.0 69.0 69.0 Name Service Unit Min Max Mean DEPT FT 9866.5 10902 10384.3 ROP MWD030 FT/H 0.65 135.29 43.0136 GR MWD030 API 13.43 574.64 49.098 RPX MWD030 OHMM 1.34 452.69 26.3818 RPS MWD030 OHMM 0.43 1538.35 34.7102 RPM MWD030 OHMM 0.42 2000 99.5926 RPD MWD030 OHMM 0.51 2000 83.6901 FET MWD030 HR 0.48 73.23 4.05937 NPHI MWD030 PU-S 3.75 49.34 20.1183 NCNT MWD030 CP30 14766.9 55163 30926.2 FCNT MWD030 CP30 139.15 4338.5 855.933 Nsam 2072 1994 1980 2009 2009 2009 2009 2009 1867 1867 1867 First Reading 9866.5 9905.5 9874 9866.5 9866.5 9866.5 9866.5 9866.5 9895 9895 9895 Last Reading 10902 10902 10863 5 10870 5 10870 5 10870 5 10870 5 10870 5 10828 10828 10828 RHOB MWD030 G/CM 1.08 3.4 DRHO MWD030 G/CM -1.28 0.34 PEF MWD030 B/E 1.37 12.04 2.32034 1895 9895 10842 0.020153 1895 9895 10842 2.49268 1895 9895 10842 First Reading For Entire File .......... 9866.5 Last Reading For Entire File ........... 10902 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/06/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/06/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/06/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File