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209-041
MEMORANDUM TO: Jim Regg S �Lt /� I P.I. Supervisor �12fq FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 19, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC A-44 PRUDHOE BAY UNIT A44 Ste: Inspector Reviewed By: P.I. Suprv,�� Comm Well Name PRUDHOE BAY UNIT A-44 API Well Number 50-029-23412-00-00 Inspector Name: Adam Earl Permit Number: 209-041-0 Inspection Date: 5/182021 Insp Num: mitAGE210518194324 Rel Insp Num: Notes: MIT IA Wednesday, May 19, 2021 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A-44 .Type Inj w 1TVDp 8288 - Tubing 322 _ 324 323' 322 - PTD 209041 - Type Test SPI Nest SI 2072 - IA 121 2315 2269 2265 BBL u p Pumped: 3 '.BBL Returned: � 3 OAS 3zs i 335 334- 335 ' Interv�— 4YRTST �P/F Notes: MIT IA Wednesday, May 19, 2021 Page 1 of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 20,2017 Jim Regg P.I.Supervisor �CJlgq 6(4/(7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. A-44 FROM: Jeff Jones PRUDHOE BAY UNIT A-44 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT A-44 API Well Number 50-029-23412-00-00 Inspector Name: Jeff Jones Permit Number: 209-041-0 Inspection Date: 5/27/2017 Insp Num: mitJJ170618122427 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A-44 Type Inj W- TVD 8288 Tubing 754 756 • 756 - 756 • PTD 2090410 ' Type Test SPT Test psi 2072 • IA 156 2496 - 2478 2475 - BBL Pumped: 2.6 - BBL Returned: 3.2 - OA 351 367 , 369 - 369 - Interval 4YRTST P/F P Notes: 1 well inspected,no exceptions noted. i 5 NES AUG < 03-,; Tuesday,June 20,2017 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI•N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate IZI Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: in/lel C/13 17 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 209-041 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-23412-00-00 7. Property Designation(Lease Number): ADL 0028286 8. Well Name and Number: PBU A-44 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL E E I 1E D 11.Present Well Condition Summary: Total Depth: measured 12775 feet Plugs 9 measured 12590 feet NOV 2 2 2016 true vertical 9105 feet Junk measured feet Effective Depth: measured 12590 feet Packer measured 11955 feet J3CQ true vertical 8920 feet Packer true vertical 8287.27 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#A-53 29-109 29-109 1533 515 Surface 4346 9-5/8"40#L-80 28-4373 28-3205 5750 3090 Intermediate 12188 7"26#L-80 26-12213 26-8545 7240 5410 Production Liner 710 4-1/2"12.6#L-80 12064-12773 8396-9103 8430 7500 Perforation Depth: Measured depth: 12455-12475 feet 12640-12676 feet True vertical depth: 8786-8806 feet feet 8970-9006 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-12073 23-8405 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED APR 1 9 2U1? 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 4755 20 1897 Subsequent to operation: 3966 20 1895 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service if Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-459 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 11/22/16 Form 10-404 Revised 5/2015 VTI— -. 2 4 l /7.--- Submit Original Only I8/7 RBDMS c" NOV 2 8 2016 • • Packers and SSV's Attachment PBU A-44 SW Name Type MD TVD Depscription A-44 TBG PACKER 11954.63 8287.27 4-1/2" Baker S-3 Perm Packer A-44 PACKER 12076.3 8408.34 5" Baker ZXP Top Packer • • w (I o Cl) 2 rn N in r) o a) " E w N O N -O u) OL Z O ib N-` (0 a) � H - • in (0 V N *. I a 0, N 0 p N Z 0- .�� O O 3 0T- 0 w • Q 0 0' E2 C _N _O LC) E 7 p II F- 2 a) � I- •• n.-,W � � � a) p (h U 0 _ � F- n Lu a o . u) O j i C � 2 > Q = w J W N N 0 "= > � gyp _ W EQ u) O LI 30 (0- cox p a p 0 U4 N p � QLi oN N � N = fn _ ddb• II F- a ca. � o � o c N N m z -1 0 (.90 .4- - OS E._ 1_ 0 p ami -e) eL 00 � m = w J Lu I- � w0 w � � o opo � � � O � a 0 p0 Cr_ > co d o a v ° W v O w o U p p a U O (oic r a„i coa E = stn 2 CLQ ti • F- 9 � p Z H Ern .- g * , ccs = O omU D O � 0- 0W i0Ua C O o (\i J « c c cn 'IT,' 0 F- O (n6Y � JJ W O >- o Cl) c W '-' o U �C cn F- a tL co II Cn B O O a3 :Pi LY (gi ~Q it) U °a o0 � W ``= V - Z N r � 0(na UV = E c/iL M "aZX � V cti 3 o c" in° X ad 'TOY m � 0 < E Q d 2 owU (0 -o -c E a) - Eo O 1 011-- Z 6 (.6 a � >, fl- = E02 ° wm ami t o ra > � b pw F- JDOp , m w U' ~ - `t °? 00 2 0 3 Co 0 .a o Ori N aZ cc00 ° c tii - z 0 7 1. ° , W co c 2 .Nti ca 3w � OW w zI0Q0 z IL Q Z - � cn •Ov O aZU o (:) . m old O_* ° U2 2 woo � 2FLVrx00 a w n : - tai a •� .S r W W O l j w f� W J z -1 O m J � ce 2 W Y : U) � Umc _ F- '" O 1- 0 - 0 F- t o ari = 0 = � '� , � 3 > vpN N z : Zo � Q � QUw0 H O > f/) Et Z .() (n 4- I (n 0 O J M � a Y W •.-:f- J = 0. LL u) � J O (0 2 v.. N N ti-) a MCN - U � O I Gw w , 0 a z _ - N OF. II Oc. LY > X -r mal- 2I- V J >• Z (f) L L 0 O E o O "u_ a < I- a N O in J W J - tl) W W � N � c'� W �twpW J 4=7 . 45 O C� `n2 m W m ~ Om o0Uo0 0 a.< ZZoU � UUU � < wN > a) Hu) = 0 ~ 3 E Su_ =H O z o r O rn 0 0 o E o I- 0 a ? 0 0c\I\I -o 0 3 0_ pwUm m ZF- „ --- u_ -, OtJi = ceN m -a -ocnj = J } O = � � w � � � Qo � a c z ,_ U ao a o _ zNtLY -oy cnI Q = F- = (n= a < O2 r J W °� (/) Zco "a C ai CF- 1- - E V _1 _j W _ 0 CD ZCo \ O N W CO 0) > Q � � p � � O J (nU � � W W < U-" cnMace0 -1 0 ma > a = za •-7O UO ° f% J = U' Ln0 • ' , F_ z � Z - zg JOaO N _cv DcaCTI Ei 1= 46 : °r° F-- «g"* Fa- o* ; ZCLdCLzaW < z7__ : 2 <0 w F- (0 (0 (D O (0 0 r r 0 0 0 0 0 0 N N N N N .0 00 e- In > O O O N m • O V r r r 8' O a 7g TRIS= aw WELLHEAD= FMC • TY NOTES: H2S READINGS AVERAGE 125 ppm "ACTUATOR= BAKER C4 WHEN ON MI.WELL REQUIRES A SSSV WHEN ON KB.ELEV= 28.16 ML ""`CHROME NIPPLES*** BF.ELEV= 28.9 KOP= 108' 0 , / 4 Max Angle= 61°@2938' / — 1027' 9-5/8"TAM PORT COLLAR Datum MD= 12547' • Datum TVD= 8800'SS 1. o. 2210' - 4 112" X NP(9 CR),0=3.813" 20",215.5#,A-53 NVSULAT®COPDUCTOR 1 108' 1. 1• 9-5/8"CSG,40#,L-80 BTC,D=8.835" 1 4374' •' 7"CSG,26#,L-80 TO XO L-80 BTC-M 1 5907' X Minimum ID =3.725" @ 12061' 4-1/2" HES XN NIPPLE I 11924' 14-1/2"HES xPP(9-cl),D=3.813" Z L 11966' H7'X 4-1/2"S-3 BKR PKR,D=3.875" ' ' 11989' 14-1/2"HES x NP(9-CR),ID=3.813" I I 12061' 14-1/2"FES XN NP(9-al,D=3.725" 12064' —7"X 5"C2 ZXPLTP,D=4.380" 4-1/2"TBG,12.6#,L-80 TCN, 1 12074' / 1 12074' H4-1/2-WLEG,D=3.958' .0152 bpf,D=3.958" 12085' H 7"X 5"BKR I-MC LNR HGR,0=4.440" 12091' 15"X 4-1/2"XO,D=3.958" r CSG,26#,L-80 BTC-M,D=6.276" H 12214' I IL PERFORATION SUR*ARY REF LOG: PDC ON 05/25/09 ANGLE AT TOP PERF:4°@ 12455' Note:Refer to Ftoduction OB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 0 3-3/8" 6 12455-12475 0 10/26/16 3-318" 6 12640-12676 C 05/26/09 12590'ELMD 14-1/2"WFDCBP(10/27/16) 1910-4111 0 4-1/2"!BID 1 12691' 4-1/2'LNR, 12.6#,L-80 BT-M, -1 12774' :../......: .0152 bpf,10=3.958" DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDHOE BAY UNI- 04/27/09 NT04/27/09 N7ES ORIGINAL COMPLETION 10/27/16 MRLYJM)SET CBA'ADPERFS(10/26-27/16) WELL: A-44 04/30/09 PJC DRLG DRAFT CORRECTIONS PERMIT No:8209041 05/27/09 JMJMD DRLG DRAFT CORRECTIONS AR No: 50-029-23412-00 05/29/09 MV/TLH PERF REF.LOG SEC 35.,T11 N R13E,2224'FSL&1704'FEL 02/14/11 M3/JMD ADDEDSSSV SAFEIY NOTE 01/17/12 TMN/JMD-ADDED H2S SAFETY NOTE BP Exploration(Alaska) • • v°F Thr A THE STATE Alaska Oil and Gas E�'�'�►,��� Of LASKA Conservation C®m11IISSlOn 333 West Seventh Avenue ' GOVERNOR BILL WALKER 1 Anchorage, Alaska 99501-3572 ^�' OA; � . � Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Brian P. Glasheen SCANNED FEB . 5 2017 Production Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-44 Permit to Drill Number: 209-041 Sundry Number: 316-459 Dear Mr. Glasheen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, al6 "s2at ( Cathy 7 Foerster Chair 11"- DATED this 19- day of September, 2016. RBDMS lit/ SEP 1 6 2016 STATE OF ALASKA • ()ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations m, Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate I 1' Other Stimulate 0 Pull Tubing 0 Chane Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other7"1 6 f 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 209-041• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ID 99519-6612 Stratigraphic 0 Service 0- 6. API Number: 50-029-23412-00-00 7. If perforating: 8. Well Name and N What Regulation or Conservation Order governs well spacing in this pool? ryM, I Will planned perforations require a spacing exception? Yes 0 No Il PBU A-44 - 8 ED 9. Property Designation(Lease Number): 10. Field/Pools: SEP 0 2016 ADL 0028286 ' PRUDHOE BAY,PRUDHOE OIL • larg "7/3//. 11. PRESENT WELL CONDITION SUMMARY AO CC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 12775 , 9105 • 12691 • 9021• Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#A-53 29-109 29-109 1533 515 Surface 4346 9-5/8"40#L-80 28-4373 28-3205 5750 3090 Intermediate 12188 7"26#L-80 26-12213 26-8545 7240 5410 Production Liner 710 4-1/2"12.6#L-80 12064-12773 8396-9103 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12640-12676 8970-9006 4-1/2"12.6#L-80 L-80 23-12073 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 11955/8287.27 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service Ed 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG R GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Glasheen,Brian P be deviated from without prior written approval. Email Brian.Glasheen@bp.com Printed Name Glasheen,Brian P Title Production Engineer k / 4Signature Phon 907 564 5905 Date /Sj__A( COMMISSION USE ONLYV Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: `, ) TSF- IR 1‘'i )`-6 Post Initial Injection MIT Req'd? Yes❑ No Spacing Exception Required? Yes 0 No Ie Subsequent Form Required: 1 [j — 4-d / APPROVED BYTHE Approved by: (9x..4. �L COMMISSIONER COMMISSION Date:9.../4.,46, VII- 8112 / d . ORIGINAL RBDMS L" SEP 162016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachme sin Duplicate . ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: A-44 Well Type: WAG Injection Well API Number: 50-029-23412-00 Well Activity Conventional 4 Classification: Activity Description: APF with CIBP Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK • 12 Month Avg IOR, bopd: Job T Estimated Cost, Ype: Add Perf+WSO $K: AWGRS Job Scope: PROFILE MODIFICATION b;; Other regulatory Sundry Form 10-403 Yep requirements? Required? — Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Brian Glasheen Contact numbers: (907)564-5905 (907)545-1144 Well Intervention Engineer: Contact numbers: No Data No Data Lead Engineer: Brian Glasheen Contact numbers: (907)564-5905 (907)545-1144 Date Created: August 24, 2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate Inj Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (psi) Cut(%) (Mscf/Day) 8/22/2016 5,024 . 0 1,906 Current Status: Operable Flowing Inclination>70°at Depth(ft) NA Maximum Deviation(Angle and Recent H2S (date,ppm) NA 0 ppmDepth) 61° 2,938' MD Datum depth,ft TVDss 8,800'TVDss Dogleg Severity(Angle and Depth) 5° 10,501' MD Reservoir pressure(date, psig) Assume 3,250 psi Minimum ID and Depth 3.725" 12,061' MD Reservoir Temp,F -'212 Shut-in Wellhead Pressure Max would be 2400 all gas. Known mech.integrity None problems(specifics) Last downhole operation(date, 12/25/2009 Pull reset MCX. operation) Most recent TD tag(date,depth, 12/25/2009 2,191' MD tagged MCX with 3.85 gauge ring toolstring OD) Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, A-44 was drilled and completed in 2009. Post rig, ELINE ran a SCMT to confirm good cement behind the background information, liner.After the SCMT was completed and reviewed zone 2 perfs were shot to act as a mist well and allow etc: MI to sweep upwards towards our surronding producers. Now that we have injected MI and water into zone 2 for over 6 years the first cycle of MIST has been completed. • The objective of this program is move uphole to bring our downdip producers in to confromance and allow ' our updip producer to see support from water slumping down into zone 2. • • Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Wells out of conformance Specific Intervention or Well Objectives: 1 SL pull MCX drift for CIBP 2 ELINE SET CIBP and APF 3 Key risks,critical issues: Mitigation plan: 1 Shmoo Shmoo be gone and brush and flush 2 Cement integrity/zonal isolation SCMT confirmed good cement 3 Summary Step# Service Line Activity 1 SL Pull MCX, Drift for CIBP 2 EL Set CIBP APF 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 SL 1) PuII MCX at 2210' MD 2)Drift for 4.5' CIBP to TD 2 EL 1)Set CIBP at 12,590 MD using PDC log dated 05/25/2009 to tie in. 2)Add 20'of perforations following perf form attached. 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 5000 Expected Production Rates: FTP(psi): Choke setting: PI(bfpd/psi dp) Post job POP instructions: P01 ASAP after Eline is completed Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: 0 0 7 REE- ZAN SAFETY NOT ES Q5 READINGS AVERAGE 125 ppm :AEA-+EAC - rA/C A C-1,14 TCR- a40,:F141C A-4,4 WW? °roc writ RCQUIRCS A I SSSV WISUN ON MO —ci1ROM r NPP.EIS-- 4.3 -.IP.,--- 28 16 4CP 7 -79R- •,o. Vap,ANip r 6''a 2939 *) — 1027' 1 1.4 2.43" AM '"...X2 :2-0 1 Ail 12547 7•11_Jr..,TV0- 3800 SS .4 1 2210' 1--14-I7 FEES X Nr.tS-CF4 '0 38137-1 zu ...-'5 se,A'SJ ,`,4:JLA'L.,. C...1M14:_/,..f...`,..1-i** - fie --.. 43_,44 r',I1 •1,4 ,..;.1'I T, 1'1=.4,..' I I *174' I!' CSG 254,_CC Tr:. XD_E,C 131C.M , - 6907' ......, •-•-• I A Minimum ID =3.726" a 12001' !II li 11924 r. I I, ' i.---14- ri+€5 1F4(9-01 1 03 813 -, 4-1/2" HES XN NIPPLE . ilass• 1—L71 A 4 irz.S-3 BAR P4R.,C-3 875- 1 RF_RF-DRA r ION S+JAIMAR', I RFT- 00 ,71-C 00589 L. 11i 11989' i 14-112',I.L'S X N.4,le-CR, 0 3 o'l 5 ANGLE.A "OP•L-'4,/' 4'a 12640 NP:44, Rdittlet t-zPtcc..4.1.3r a3'or.1614,4;41pe,Oates t SI?F SF'S INTE-4_VAL On/SW CATS 5 *i, 11541- 12E16 0 ( l263)9 i 1 li ! 12061' 1 -14 1/2 1-t$ 728' 1 1 , I lif r, 12064' 1 I' A 5'. C.Z LAP L.T''''' L-4 4 1rz wt.; ' 90 .,I ' I 12074' 1 4F: { 12074' 1 {4 1/2"1/til i C. 0 3.....w. cw12:-.4r I.) 39-18' . = 12085' .1 X 5'akl'i-*.IC LME,4." .; 0'.4 440" =,.. ',. 12091' I lb'x 4 ire- ,1341 , 99 4 I I;91 I) 6;lb" j i,._12214' .„21 1 lk F4-1r2- f..a °I--Ir—12691 i ....... •••••• .•••••• •••••• .11110404, 400041 .4•11144, 4401144 14 1,2'' _NR 12.641/ .., SU e' N. -H 12774' 0152 411 O."3 958" REV HY L'UNIVE.NIS --A ':_. * REV 3v' 00IWJ,TS , ' 1 9R...,C4-0E BAy Jhr 0417710'1' NILS 01-9(.314"1 0L-41P....1,DONVvF5.' A 44 ,. 04/300.3, ,,,1C 1:041_G i)94.A,T Z:c)r4RC,C;'IONS . ' F. 4T+01- —0547/1-C19-1..--MQVII7,- FiR1 C .1-64FT coRRFc-iotso ---TA i,No 5C029 234'2 1-10 (F-‘791r9; IVIVr7,1 I-PP.?,REF IOC --i- 021'4."'14.5/121JP4)-ADDL.)SSSV SAFETY NOTE n I t-7/12,-VN.1..AC,ADOED'FOS SA FErY Nio,E i RP Exploration(Alaska) I 0 • Injector t J Techiog Minilog Prosect PBU WWF Laura Well. A-44 Author Laura J.Larson Scale 1 1000 Date 10/23/2015 7I 1 663705 ss-,1;,,04,8 2009.04-12000000 USA .-.•• ...,::.✓n KB v 5947376.01 ,.,.,T:..:..w.2009-0526 00 00 00 Prudhoe Bay te'i.-I t 12775 '.,r*Ibr3rr 448 757110: - Aus1w .wrc.8c.88 S'..t.tct., t1A027 AFT .atIWI 70.2631687 - 8PXA -,,, BPXA C ,R Ba58008 z D 815T GP cc 0 API 2e.02 PE Info u Rate Of Penetration TVO55 MO RI M () wt d tBESTROP (FEET) (FEET) u. . Index.TVD55 BEST.RMEO# 2 2 :0 fJHR •,U2) 1:1000 1:1000 n 9035 ft , 8435 0.2 OHM FA .' .. _. .r:; -------- 8465 - 8475 - TSifR A' 8485 ...._... -may.: 8495 . 8505 T5 _..,. 8515 - 8525 - 8535 -. F 511 B r "m.'�. 8545 -' - - 8555 --12300 -.._- ___.. -- ..__._._ .._.__ _... _. ______ _.—.._' TSM 8565 ?. 8575 8585 C - 8595 - TSAD, - 8605 ...._..._ - 8615 - ' 8625 ." 8635 8645 at 8655 -12400 . __. ... , - 8665 4558' - 8675 -, - 8685 8695 ' _„„ - 8705 - 8715 - -8725 - 1 20' A P FI /- 8735 4258 -8745 1 -8755 . 12500 8765 ... 8775 8785 - 8795 1 -. - 8805 -' c.. 8815 - 8825 8835 = s _12600-4 CIPB -8865 - . -8875 - -8885 -' ' eCG 8895 ' ' 8905 lig,.:, a - 8915 8925 -8935 1 ' - 8945 - ' 8955 12700 ..-... _.. 8965 8975 1358 8985 , -8995 - -9005 -9015 a __.. t - 9025 - • • • PENDING PERFORATING PROCEDURE Well: A-44 API 9:50-029.23412-00 Date: 812412016 Prod Engr Brian Glasheen Office Ph: (907)564.5905 H2S Level: Home Ph: 0 ppm Cell/Pager: ...................._19071545-0144._._ CC or AFE: APBINJEC WBL Entries IOR 72ge Work Description 'See Procedure I i Well Objectives and Perforating Notes: See Procedure. Reference Log Tie in Log Add 0 feet . ...._..._._.._._._..._.__._._.. Log: PDC PDC to the tie-in log to be on Date: 5/25/20095/25/2009 depth with the reference log. _... ...................._.__. Company: PDC PDC Depths(from-to) Depths(from-to) Feat SPF Orient. Phasing Zone AdlRellperf 12,455' 12,475 12,455' 12 475' 20 6 60` Random......................Zone 4..._..._..........Add Perf Requested Gun Size: 2 7/8 Charge: 175 MaxForce HMX Is Drawdown Necessary/Desired/Unnecessary During Perforating No ._._._._..._._..._.._._...._._..._.._._......_..__._..._.__.__._._..._......._._....__..__._. ._._._._._.____.._..__.._._-._...__.._.. Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Noone Last Drift: 2,191 ft MD on ._.12.131/00L Est Res.Pres. 8,800'TVDss MD Is 3250 psi Perforation Summary MEZETE Well: A-44 Town: Date: API 6: 50-029-23412-00 Prod Engr................. Anch Prod Engr 1 P.D.Center PBTD General Comments: Depths ....._......._.........._..............__......._..............._..._._........_........_......_...._.._.___.__... Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone AdperflReperf 0/B/U 0/B/U _....___._............. 0/B/U .._.....-_.._._..__......................_............____._._._._.____..._._..-....____._.___..__._... 0/B/U _._.._......_......_._..__ ..._._._..__..._....._......._. 0/B/U .....- _....._._..._......_.._....._......_................._......_._.... ..._..._._..._...._..._._....._._._._._ 0/8/U ....._............... _........_........_....._...._._.......__..........__._....__..._._...__._..._....._.._...---.._.__. 0/B/U 0/B/U �..._.__... ......_ 0/B/U __..._._.....___......_...._ .__.._._...___......._......_....---...._._...__......_._. • COMPANY: BP EXPLORATION PDCL (ALASKA)INC bl) LOG Well: A-44 uvvi: 500292341200 Elevation:I/ Total Depth: Elevation Primary Depth Control Lou Components; All available gamma ray logs have been considered and appropriately incorporated into the composite PDC.GR PDCL log. Note that FINAL, Depth-corrected data was used to create this GR PDCL and it may differ from FIELD efifiktirt°: PDCL 1 Start: POLL 1 Stop: POLL 1: PDCL,2 Start: PDCI._2 Stop: PDCL 2: PDCL_3Start: a0C1-3 Stop: PDCL 3: PDCL4 Start: POCL4 Stop: PDCL 4: PDCL 5 Start: POCLS Stop: PDCL 5: , . O • 11600 - 4 7850 ,....r.,..--__ . - ,... - - - ...-- 7875 _je...._ 7900 4 - ....- ,--.... 7925 _ t - ...... _-.--._ .....i.-- 7950 11700 - ,-.- 7975 ..-- - 8000 - . '. 8025 t ..„., ,.... 2-----0--- . ...„.... 8050 11800 - --fe- ...? 8075 -4. 14-. _ND4 8100 - >'.. _4_, --. 8125 - ...--- 8150 11900 - -1•1,- 8175 --0- 8200 4.- .3r. _.- , _,.....0- ..s.'" 8225 • ---T ,"...... 8250 12000 - 8275 _ - -. --5...-,-. 8325...____ _:;,..- 8350 12100 - -•, --- _.......vpr„,_ 8375 .., - 4.- 8400 1"---- .7. -5t... -s. ..5r..__ 8425 7,- -,----. -_-- ....,7 8450 12200 - -„S-- - 8475 8525 ..----- ' - __ .--- -1 --,------ - - 8550 12300 - 4.-- ...4., --- . - -.•-si „,,,-- • - 8575 ,7 - _ -__ - - -1--_ - - 8625 :...,,_ -t.,,:_• 8650 12400 - .--4 8675 1- .11, ...-, 8725 APF _ i' ..;,,..- ,......._ 12500 - 8750 - - ,....", ,,..,_.. ...:„.„. ;7--- •;- . 8775 - e- -4 -- _ <.,.. 8800 . ..t. .._ 8825 t" .t.' A 8850 12600 -.M. 3 , pr ;.Y 8875 CIBP ._.- '.-4 . "-..... ..'- ' 8900 ___.;-- --i S S .. . fm. 4' 4 ..i•.t . .1, C I N ' ! ., i Y , t ' ; A ., . Q.- I ,. . .. II' ! . ' ( A „.,.. a I.4' 0, . -... w ...„, 0 i **) 0 ..#* ___ < " _i '4 liti f ' 1 I 1 e 4. Ct •' '51, , • 40 v 'n ‘t nt . , V° : < 4, .., t ; , ' 4 i 0 \ ., v .,. , 6 a g., ,g. 444to- k1 - ....*;.t.''.40,t/ • ,z)° - .1 1 l' 4 88. 1,..__., • 4 4 c 0 : 1001 ii41/4 $..., 0 I :+7 4.-4.•-7-14 I , ' --.-."------ -..--- 44444. •••41 et> • • 1 1 " 1 , Pr • ' 8 I •-!clt. , ' r _.,...4 r I. I < ' ,...,. N 1 i ... . • ' l', .' '1. —",,-1.. ,:t - „.,,,,,'' ". ,. ( . 1' ,.. , t ,* I— - -1- .A....11' 4* . 8 Ar , 8 * m co i ci , p 0 0 ,.. m , X ,..: .4 u 0 - • 1 '- . , 2 - rn• 0: " 11 . , '.! ' 1.1 ) I ' '..kf.'9' • '.'-'., r•J r, ---i ] ' ' '. ;. • NI - : ' '. ', ;. ," t 1 ).. -c) 1; kl • L. ' :, ' I .%3.° ° '5' 4 ,r , i cos.. .1 • V 1 r "'"*'4&„.. • *t. • ' • . "E' 2 - ,.. . v . . I . - . .., .:-. .., '6'. t''-:, _ ' 'i. LL) 41 ,ii ' `41:,,,- ', . I ON ,4 r , ' ',.....„,_......!, ,,, r'r) (41 'e*.f.'') >,— , , -..., f‘j A i" 1 ' '51, . ..-N >.- 2 i'-.....` wt. 0.,... < , . / _____. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ ~1 Well History File Identifier Organizing ~aone> RE CAN Color Items: ~reyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ^ Two-sided II I II ~I II II II I II II DIGITAL DATA ^ Diskettes, No, ^ Other, No/Type: aes~~~e~~ iiiuiiiiuuiuiu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: /Maria ~_ Date: `~ ~ ~ / / ~ (J /s/ Project Proofing BY: Maria Date: ~ ~ /s/ Scanning Preparation ~_ x 30 = ~_ + =TOTAL PAGES ~IfJ ~' (Count does not include cover sheet BY: / Maria Date:. ~~,~~~ ~~ /s/ Production Scanning III II^11111° "~~' Stage 1 Page Count from Scanned File: ~ (Count does include cove heet) Pa a Count Matches Number in Scannin Preparation: ~ES NO 9 BY: Maria Date: ~ ~~ I ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I (III ReScanned III II'III IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III III) III 10/6/2005 Well History File Cover Page.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,May 31,2013 TO: Jim Regg / P.I.Supervisor \" 9 l I.) SUBJECT: Mechanical Integrity Tests ( ( BP EXPLORATION(ALASKA)INC A-44 FROM: Lou Grimaldi PRUDHOE BAY UNIT A-44 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .1 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT A-44 API Well Number 50-029-23412-00-00 Inspector Name: Lou Grimaldi Permit Number: 209-041-0 Inspection Date: 5/29/2013 Insp Num: mitLG130529111654 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A-44 ' Type Inj I W 8288 IA 259 2482 2480 TVD 2500 PTD Type Test SPT psi . I OA 119 t 163 153 142 - 2090410 iP/Ft st l 2072 Tubing 1 — 319 _F 1 Interval 4YRTST P 318 306 316 Notes: Four year MIT,2.1 bbls pumped 1.8 returned.Good solid test.Li!'Red wireless gauges used,all had current calibration stickers. ,CANNED FEB 2 0 2614 Friday,May 31,2013 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. h ' Attn: Well Integrity Coordinator, PRB -29 Post Office Box 196612 Anchorage, Alaska 99519-6612 - s 2©C — o L tf May 18, 2012 Mr. Jim Regg p , it 7 201? r Alaska Oil and Gas Conservation Commission er ' 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off 1 Report of Sundry Operations (10 -404) A -Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA _ 1.9 NA 13.60 7/22/2009 A -03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A-04 1720060 50029201150000 0.0 NA NA NA NA NA A-05A 2061280 50029201160100 0.0 NA NA NA NA NA A-06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -2611 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 ,��,72 A-44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 DATA SUBMITTAL COMPLIANCE REPORT 8/25/2010 Permit to Drill 2090410 Well Name/No. PRUDHOE BAY UNIT A-44 Operator BP EXPLORATION (ALASKI~ INC MD 12775 TVD 9105 Completion Date 5/26/2009 Completion Status WAGIN Current Status WAGIN API No. 50-029-23412-00-00 ___ REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~_ DATA INFORMATIDN Types Electric or Other Logs Run: GR, RES, PWD, NEUTRON-DENSITY, ABI, SCMT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / pe meQirrmt 1YUIIIUCI name JV41G I~IG41P P1C1 A-all JIV r.! VII 1\GN61YCY Log Cement Evaluation 5 Col 0 12684 Case 6/11/2009 SCMT, PDC, GR< CCL, VDL, Cement Map 25-May- 2009 C Lis 18200-Z'ement Evaluation 1 12676 Case 6/19/2009 LIS Veri, SCMT, CCL C Pds 18154 ~ement Evaluation 0 12684 Case 6/11/2009 SCMT, PDC, GR< CCL, VDL, Cement Map 25-May- 2009 g Cement Evaluation 5 Col 6980 12660 Case 6/19/2009 SCMT, GR< CCL, CBL, VDL, Cement Map 24-Apr- 2009 C Pds 18208~ement Evaluation 6980 12660 Case 6/19/2009 SCMT, GR< CCL, CBL, VDL, Cement Map 24-Apr- 2009 / €~ C Lis 18242 ~-It!iduction/Resistivity 80 12769 Open 7/6/2009 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, RAM, DRHO, NPHI, TRPM og Induction/Resistivity 25 Blu 78 12730 Open 7/6/2009 MD Vision Service og Induction/Resistivity 25 Blu 78 12730 Open 7/6/2009 TVD Vision Service Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • • DATA SUBMITTAL COMPLIANCE REPORT 8/25/2010 Permit to Drill 2090410 Well Name/No. PRUDHOE BAY UNIT A-44 MD 12775 TVD 9105 ADDITIONAL INFORM/~ION Well Cored? Y /~~~\ll Chips Received? '1`T1V' Analysis ~f-Id Received? Completion Date 5/26/2009 Operator BP EXPLORATION (ALASKIy INC Completion Status WAGIN Current Status WAGIN Daily History Received? ~N Formation Tops Y / API No. 50-029-23412-00-00 UIC Y Comments: Compliance Reviewed By: Date: A v i• 06/26/09 NO.5289 Alaska Data R, Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK: 99503-2838 Attn: Christine Mahnke~n ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD A-44 09AKA0048 OH MWD/LWD EDIT _. 04/26/09 2 1 4-04A/T-30 09AKA0040 OH MWD/LWD EDIT 03/28/09 2 1 18-O1A 62WY-00003 MCNL 04/30/09 1 1 15-298 09AKA0143 OH MWD/LWD EDIT - 05/30/09 2 1 05-35A 40017778 OH MWD/LWD EDIT ~U$" 09/10!08 2 1 V-115L2 11962618 OH WIRELINE 08/22/08 1 1 MPS-41 11966289 OH WIRELINE ~c-L.~j /`t~ac~ 11/19/08 6 1 G-O1A BOOR-00006 MCNL ~~~ = ~-y 04/01/09 1 1 4-04A/T-30 BOCV-00014 ~ _ CH EDI i rva.~-GR (SCMT) (REVISE DATA) - ~ 27/09 1 05-35A AWJI-00008 CH EDIT PDCL-GR (MEM CORRELATION) ~ 12/03/08 1 07-146 AYQO-00029 CH EDIT PDCL-GR (LDL) 05/26/09 1 I_3-08 AWL9-00028 RST / 06/11/09 1 1 re..etax si~,n~xvwleuue n~~.errr Dr AIUIV IIVU HIVU FStI UFSNINIi UIVt GUYY tAGri I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 il~i~~p Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.5278 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD 06/16/09 14-23A AYKP-00016 USIT - 04/10/09 1 1 A-44 AP3Q-00036 SCMT 04/26/09 1 1 14-23A AYKP-00016 - U IT 04/10/09 1 1 07-10A B1JJ-00022 MEM CN STP 05/26/09 1 1 07-14B AYQQ-00029 LDL _ - G 05/26/09 1 1 12-09 AYTU-00038 PRODUCTION PROFILE ~ 05/31/09 1 1 V-218 AVY5-00048 INJECTION PROFILE/WFL J^ 05/29/09 1 1 15-34A AWJI-00020 MCNL 04/20/09 1 1 A-44 AWLB-00017 CN EDIT PDCL-GR (SCMT) - 05/25/09 1 A PLEASE ACKNOWLEDGE RECEIPT elf 5icaniroc; wnu nt ~ uttntrv~ urve wrr ew~n ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. W Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 • • STATE OF ALASKA ALASKA AND GAS CONSERVATION COMM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~I 0 ~~ 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoaac zs.,,o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1 b. Well Class: ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 5-26-2009 - 12. Permit to Drill Number 209-041 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4-12-2009 ~ 13. API Number 50-029-23412-00-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 04-26-2009 , 14. Well Name and Number: PBU A-44 ' FEL, SEC. 35, T11 N, R13E, UM 2224 FSL, 1704 Top of Productive Horizon: 4229' FSL, 3857' FEL, SEC. 26, T11 N, R13E, UM 8. KB (ft above MSL): 77.10'' Ground (ft MSL): 48.94 15. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Bay Total Depth: 4235' FSL, 3860' FEL, SEC. 26, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 12691' 9021' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 653705 y- 5947376 Zone- ASP4 10. Total Depth (MD+TVD) 12775' - 9105' , 16. Property Designation: ADL 028286 TPI: x- 651397 y_ 5954615 Zone- ASP4 - 5954621 Zone- ASP4 Total De th: x- 651394 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: y p 18. Directional Survey ®Yes ^ No m' I ni nd Tint inf rm i n r 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR, GR, RES, PWD, NEUTRON-DENSITY, ABI, SCMT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED- 91.5# A-53 Surf 1 rfa 108' 42" ~43 Is Arctic I field . 3 / " 4 rf 7 rf 1 -1/ 889 Bbls 4.79 Dee Crete 89 Bbls 1.16 'G' 7" 2 12214' rfa 8-3/4" 203.6 Bbls 3.52 , LiteCrete, 39 Bbls 1.16 'G' 4-1 12. -8 1 1 774' 1 1 /8" B I 1.1 I ' 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, IISt each I (MD+TVD of To & Bottom Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ; p 3-3/8" Gun Diameter 6 SPF 4-1/2", 12.6#, L-80 12074' 11955' , MD TVD MD TVD 12640' - 12676' 8970' -9006' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT St KIND OF MATERIAL USED Freeze Protected with 75 Bbls Diesel 26. PRODUCTION TEST Date First Production: June 2, 2009 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HouR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) A wired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chi s, photographs and labor$~1yt"` ~y i~ AAC 250.071. ~MPLETION ~ ~ l.._ v None ~ - *, ~~ ,1 a ~~ ~ ,~ Alaska C}~ iu~ `:. _ .~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ri ~~o w+a~` R~ L JUI. 0 7 2009 ~ ~~.~ ~ 28. GEOLOGIC MARI~RS (LIST ALL FORMATIONS AND S ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 2170 2011' detailed test information per 20 AAC 25.071. Ugnu Zone 4 6162 4189' Ugnu Zone 4A 6227 4227' None Ugnu Zone 3 6650 4454' Ugnu Zone 1 7710 5048' West Sak 2 8427 5444' West Sak 1 8865 5687' Coville Mudstone 3 9227 5888' Coville Mudstone 2 9932 6352' Coville Mudstone 1 10685 7028' Top HRZ 10961 7301' Base HRZ 11200 7538' Top Sag River 12212 8544' Top Shublik Zone A 12242 8573' Top Shublik Zone B 12280 8611' Top Shublik Zone C 12296 8627' Top Sadlerochit 12328 8659' 45S6 12379 8710' 42S6 /Zone 4A 12455 8786' TCGL /Zone 3 12532 8863' BCGL /Zone 2C 12609 8940' 23S6 /Zone 26 12688 9018' Formation at Total Depth (Name): Ivishak (Zone 2B) 12688' 9018' 30. List of Attachments: Summary of Daily Drilling Reports and Well Work History, Well Schematic Diagram, Surveys and aLeak-Off Test Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Son a Stewm Title Drilling Technologist DateO~p' PBU A~4 209-041 Prepared ByName/NumGer. Sondra Stewman, 564-4750 Well Number P rml N A r Drilling Engineer: Joshua Mallery, 564-5545 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE = CMJ WELLHEAD = FMC frCTUATOR = BAKER C KB. ELEV = 28.16 BF. ELEV - 28.9 KOP = 108' Max Angle = _.._ 81 ° @ 2938' Datum MD = 12547 DatumTVD= 8800'SS I20", 215.5#, A-53 INSULATED CONDUCTOR ~~ 108, 9-518" CSG, 40#, L-80 BTC, ID = 8.835" 4374 7" CSG, 26#, L-80 TCII XO L-80 BTGM 5907' `!" TES ***CHROME NIPPLES*** A-44 1027 9-5/8" TAM PORT COLLAR ---~- 2210 4-1/2" HES X NIP (9-CR), ID = 3.813" 11924' I~ 4-112" HES X NIP (9-C R), ID = 3.813" Minimum ID = 3.725" @ 12061' 4-1/2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: PDC ON 05/25/09 ANGLE AT TOP PERF: 4° @ 12640' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 12640 - 12676 O 05/26/09 4-1/2" TBG, 12.6#, L-80 TCII, I 12074 .0152 bpf, ID = 3.958" 7" CSG, 26#, L-80 BTGM, ID = 6.276" ~-{ 12214' 4-1/2" PBTDI-I 12691' 4-112" LNR, 12.6#, L-80 IBT-M, I-j 12774' .0152 bpf, ID = 3.958" 955' I-17" X 4-1/2" S-3 BKR PKR, ID = 3.875" 11989' I-i4-1/2" HES X NIP (9-CR), ID = 3.813" 12061' ~-~4-1/2" HES XN NIP (9-CR), ID = 3.725" 12064' -~ 7" X 5" C2 ZXP LTP, ID = 4.380" 12074' 4-1/2" WLEG, ID = 3.958" 12085' 7" X 5" BKR HMC LNR HGR, ID = 4.440" 12091' 5" X 4-1 /2" XO, ID = 3.958" DATE REV BY COMMEMS DATE REV BY COMMENTS 04/27/09 N7ES ORIGINAL COMPLETION 04/30/09 PJC DRLG DRAFT CORRECTIONS 05/27/09 JNVJMD DRLG DRAFT CORRECTIONS 05/29/09 MV/TLH PERF REF. LOG PRUDHOE BAY UNIT WELL: A-44 PERM(f No: 209041 API No: 50-029-23412-00 BP Exploration (Alaska) • M BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: A ell Name: A e: Name: N From - To -44 -44 DRILL+C ABOBS NABOBS Hours ', OMPLE ALASK 7ES Task ~' __ TE A DRI Code i LING NPT Start I Rig Rig N Phase Spud Date: 4/12/2009 : 4/10/2009 End: 4/29/2009 Release: 4/29/2009 umber: Description of Operations 4/10/2009 18:00 - 00:00 6.00 MOB P PRE Rig released from E-05B at 1800 hrs. Mobilizing and staging equipment from E-05B to A-44i. Sub, pits, camp and truck shop have not left E-05B as of midnight. 4/11/2009 00:00 - 04:00 4.00 MOB P PRE Sub moving from E-05B to A-44i. Stage Sub on A pad. 04:00 - 16:30 12.50 MOB P PRE Lay herculite over cellar, mat area. Spot Sub on pad in preparation for pits to move by and be staged. Raise derrick while waiting. PJSM, nipple up surface stack, riser and diverter line. Pits staged, camp and truck shop prepped for movement from E-05B. Waiting on Peak trucks to come from rig move on Point Thompson. Conduct service on auto driller, hange tree in cellar, place wellhead equipment in cellar. 16:30 - 18:30 2.00 MOB P PRE Mobilize and stage pits, camp, truck shop on A pad. 18:00 - 00:00 6.00 RIGU P PRE Spot Sub structure, spot pits, hang bridle lines, secure rig floor. Make up serivice lines from rig to pits. Build containment dike, spot temporary cuttings tank. Take on water and spud mud into pits. Continue checking connections, install riser and berm flowlines. Ri acce ted at 2100 hrs 04/11/09 on well A-44i. 4/12/2009 00:00 - 04:00 4.00 RIGU P PRE Complete taking on fluids and nippling up riser to diverter system. Changing liners in pumps from 5" to 5 1/2". Clear and clean rig floor, mobilize egipment to floor. 04:00 - 10:30 6.50 RIGU P PRE PU 23 joints of 4" HWDP, jars and 111 joints of 4' drill pipe. Stand back. 10:30 - 13:00 2.50 RIGU P PRE W I riser attachment re-install to diverter. Connect riser air boot. MU blower hose, service top drive. Mobilize BHA into pipe shed and to floor. 13:00 - 13:30 0.50 RIGU P PRE Rig up Halliburton Eline and gyro equipment. 13:30 - 14:30 1.00 EVAL P SURF Test Diverter s stem and Accumulator. AOGCC re John Crisp waived witness of test. WSL, Toolpusher witnessed testing. 14:30 - 15:00 0.50 DRILL P SURF Pre spud meeting with crew, WSL, Toolpusher. 15:00 - 16:30 1.50 DRILL P SURF MU 12 1/4" BHA: Hughes milltooth bit, 1.5 deg motor, ARC, stabilizer, UBHO for gyro, DCs, stabilizer, DC, jars, HWDP. , 16:30 - 00:00 7.50 DRILL P SURF Spud A-44i at 1630 hrs. Depth in at 108'. Drill ahead in 12 1/4" hole from 108' to 635'. -465-500 gpm, psi on 1120, psi off 990, WOB 25k, 4k fUlbs on, 1.5k ft/Ibs off, PUW 60k, SOW 55k, ROT Wt 57k, 60 rpm. -AST 2.25 hrs, ART .92 hrs, ADT 3.17 hrs, Bit 3.17 hrs -MW in and out 8.8 ppg, 42 degrees in and 44 degrees out, 600+ viscosity. Small gravels coming across shakers, sand content kept low by occassioinally running cleaning equipment. 4/13/2009 00:00 - 12:00 12.00 DRILL P SURF Drill ahead in 12 1/4" hole from 630' to 1,531' -550 gpm, 1560 psi on , 1445 psi off , WOB 25k, 4.5k ft/Ibs on, 2.5k fUlbs off, PUW 75k, SOW 60k, ROT Wt 65k, 60 rpm. -AST 8.92 hrs, ART .47 hrs, ADT 9.39 hrs, Bit 12.61 hrs -Last clean gyro survey at 714' -MW in and out 9.2 ppg, 42 degrees in with 44 degrees out, 500 viscosity. Gravels still coming across shakers but greatly reduced in size. Running cleaning equipment (desander, centrifuge) to control sand content. 12:00 - 14:00 2.00 DRILL P SURF Drill ahead in 12 1/4" hole from 1,531' to 1,598' Printed: 6/8/2009 71:40:37 AM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: A-44 Common W Event Nam Contractor Rig Name: Date ell Name: A e: Name: N N From - To -44 DRILL+C ABOBS ABOBS Hours OMPLE ALASK 7ES Task , TE A DRI Code LLING NPT ~ Start I Rig Rig N Phase Spud Date: 4/12/2009 : 4/10/2009 End: 4/29/2009 Release: 4/29/2009 umber: Description of Operations 4/13/2009 12:00 - 14:00 2.00 DRILL P SURF -550 gpm, 1680 psi on , 1560 psi off , WOB 25k, 4k ft/Ibs on, 3k ft/Ibs off, PUW 75k, SOW 60k, ROT Wt 68k, 60 rpm. -AST 1.27 hrs, ART 0.0 hrs, ADT 1.27 hrs, Bit 13.87 hrs -MW in and out 9.0 ppg, temp at 50 degrees 14:00 - 15:00 1.00 . DRILL P SURF Trouble ettin si pal back from MWD tool; downhole noise interfering with signal to surface. Circulate to clean hole and see if that helps at 550 gpm, 1550 psi. Vary hertz range on tool signal... Sional did not improve Decide to POH to inspect t ol. 15:00 - 16:00 1.00 DRILL N DPRB SURF POH from 1,598' to 906'. Tight hole from 1,570' to 1,480'. Pump through tight spot at 450 gpm, 1050 psi. 16:00 - 18:30 2.50 DRILL N DPRB SURF LD BHA. Evaluation of ARC tool shows tool operating fine. 18:30 - 21:00 2.50 DRILL N DPRB SURF Chan a out bit and motor. MU 12 1/4" BHA: New Hughes milltooth bit, 1.83 deg motor, ARC, stabilizer, DCs, stabilizer, DC, jars, HWDP. Download data from ARC tool. -Bit grade: 2-3-RG-A-E-2/16-NO-BHA 21:00 - 21:30 0.50 DRILL N DPRB SURF RIH with BHA on 4" DP from 906' to 1,598'. 21:30 - 00:00 2.50 DRILL P SURF Drill ahead in 12 1/4" hole from 1,598' to 1,700' -530 gpm, 1610 psi on , 1480 psi off , WOB 25k, 4k Wlbs on, 3k fUlbs off, PUW 75k, SOW 60k, ROT Wt 70k, 40 rpm. -AST 1.42 hrs, ART 0.0 hrs, ADT 1.42 hrs, Bit 1.42 hrs -MW in and out 9.1 ppg, temp at 50 degrees 4/14/2009 00:00 - 12:00 12.00 DRILL P SURF Drill ahead in 12 1/4" hole from 1,700' to 2700' -525 gpm, 1960 psi on , 1855 psi off , WOB 20k, 8k fUlbs on, 5k ft/Ibs off, PUW 85k, SOW 62k, ROT Wt 70k, 40 rpm. -AST 6.33 hrs, ART 3.21 hrs, ADT 9.54 hrs, Bit 10.96 hrs -MW in and out 9.0 ppg, 52 degrees 12:00 - 00:00 12.00 DRILL P SURF Drill ahead in 12 1/4" hole from 2,700' to 4,085' -600 gpm, 3175 psi on , 2950 psi off , WOB 25k, 7.5k ft/Ibs on, 5k Wlbs off, PUW 97k, SOW 65k, ROT Wt 80k, 40 rpm. -AST 1.90 hrs, ART 7.05 hrs, ADT 8.95 hrs, Bit 19.91 hrs -MW in and out 9.4 ppg, temp at 61 degrees 4/15/2009 00:00 - 04:00 4.00 DRILL P SURF 1 4" hole from 4,085' to 4,389' -600 gpm, 3220 psi on , 3085 psi off , WOB 25k, 7k fUlbs on, 5.5k ft/Ibs off, PUW 115k, SOW 68k, ROT Wt 80k, 40 rpm. -AST .27 hrs, ART 2.90 hrs, ADT 3.17 hrs, Bit 23.10 hrs -MW in and out 9.4 ppg, temp at 62 degrees 04:00 - 06:00 2.00 DRILL P SURF CBU x3 to clean hole at 600 gpm, 2990 psi, 60 rpm, 6k ft/Ibs torque. MW in and out 9.4 ppg, vis at 180. 06:00 - 11:00 5.00 DRILL P SURF Monitor well -Static. POH from 4,389' to 1,571' with intermittent overpulls of 30k at: -4,040', 3,970', 3,925', 3,895', 3,671' -Work and wipe tight areas. Pump out of the hole from 3,650' to 3,272' at 250 gpm, 760 psi. -Continue to POH with 40k overpull. Pump out of hole to 1,571' at 250 gpm, 685 psi. -MW in and out 9.4 ppg 11:00 - 15:00 4.00 DRILL P SURF RIH from 1,571' to 1,688'; took 30k SO; ream down at 100 gpm, 300 psi, 10 rpm, 4k ft/Ibs torque. -RIH to 1,733', took 35k SO; ream down at 100 gpm, 320 psi, 10 rpm, 4k fVlbs torque. -RIH to 3,670 ;tight hole at 3,670' to 3,700'; ream down at 120 gpm, 680 psi, 20 rpm, 5.8k fUlbs torque Printed: (i/S/"1009 11:4U:3/HM BP EXPLORATION Operations Summary Report Page 3 of 12 ~ Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase 4/15/2009 11:00 - 15:00 4.00 DRILL P SURF 15:00 - 16:00 1.00 DRILL P SURF 16:00 - 19:30 I 3.501 DRILL I P 19:30 - 22:30 3.00 DRILL P 22:30 - 00:00 1.501 CASE P 4/16/2009 100:00 - 17:00 17.00 CASE P 17:00 - 21:30 4.501 CEMT P 21:30 - 00:00 2.501 CEMT P 14/17/2009 100:00 - 01:30 I 1.501 CEMT I P Description of Operations -RIH to 3,802 ;tight hole at 3,802' to 4,389 ;ream down at 400 gpm, 2100 psi, 20 rpm, 7.3k ft/Ibs torque Circulate 30 bbl nut plug sweep and continue pumping while reciprocating. Pump at 600 gpm,. 3290 psi, 80 rpm, 8k ft/Ibs torque, ROT Wt SOk Monitor well- static. MW 9.4 ppg in and out. POH from 4,389' to 2,450'. Tight hole from 2,450'-1,762 ; pump out at 120 gpm, 460 psi. Continue to POH with no problems from 1,762' to 902'. Standback HWDP & DC's. LD 12 1/4" BHA. Bit grade: 1-2-WT-A-E-1 /16th-RG-TD. PJSM on rigging up to run 9 5/8" casing. Rig up Power Tongs, Slips, Elevators and Franks fill-up tool. Make Dummy run with landing joint and mandrel hanger. Run 9 5/8" 40# L-80 BTC casing -Bakerlock all connections below Float Collar; check floats - good. -Tam Port Collar set at 1,028'; total of 107 joints run. -Bow Spring Centralizer on joints 1, 3-26, one on each side of the Tam Port Collar, and joints 105, 106. -Avg Torque on BTC connection 8500 fUlbs -Fill and break circulation every 10 joints for 10 minutes C~ 3bpm -MU landing joint, land hanger; PUW 190k, SOW 75k -MW in and out 9.3 ppg -Circulate through Franks fill-up tool at 180 gpm, 355 psi Circulate bottoms up with Franks fill-up tool. RD Franks fill-up tool. RU cement head; reciprocate and circulate surface to surface to condition mud and wellbore for cementing; final MW in and out 9.5 ppg, vis at 70, PUW 190k, SOW 90k. Stage pumps up from 1 to 5 bpm. -Initial circulation pressure for 5 bpm 430 psi -Final circulation pressure for 5 bpm 300 psi -PJSM with crew, SLB, CH2mHill, Mud Engineer, Toolpusher, WSL on cement job Cement 9 5/8" 40# L-80 BTC casing -Pump 10 bbls of 10.5 ppg Mud Push II -Test lines to 3500 psi -Pump 45 bbls 10.5 ppg Mud Push II Spacer -Drop bottom plug; positive indication plug dropped -Pump 889 bbls of 10.7 ppg ArcticSet Lite lead slurry per SLB cementing program at 6.9 bpm; yield 4.79 cu/ft per sack, 1080 sacks. SURF SURF SURF SURF SURF SURF (Continued pumping -see next report) SURF Complete cementing the 9 5/8" 40# L-80 BTC casing: -Pump 889 bbls of 10.7 ppg ArcticSet Lite lead slurry at 6.9 bpm; yield 4.79 cu/ft per sack, 1080 sacks -Pump 89 bbls of 15.8 Class G tail cement at 5.5 bpm; yield 1.16 cu/ft per sack, 406 sacks -Drop top plug, positive indication plug left cement head -Wash out plug with 5 bbls water from cementers; wash down Printed: 6/8/2009 11:40:37 AM ~ ~ BP EXPLORATION Operations Summary Report Page 4 of 12 Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours .Task I, Code NPT Phase I Description of Operations 4/17/2009 00:00 - 01:30 1.50 CEMT P SURF and blow down cementers lines -Displace with 322 bbls used 9.5 ppg mud from rig pumps at 5 bpm -Bum ed lu at 4579 strokes, 760 psi and pressure up to 1260 psi and hold for 3 minutes -CIP at 0120 hours; Tail cement 500 psi compressive strength in 20 hrs, 1000 psi compressive strength in 26.75 hrs. -Full returns throughout iob. 447 bbls cement returns to 01:30 - 02:00 0.501 CEMT P ~ SURF 02:00 - 07:00 I 5.001 CEMT I P I I SURF 07:00 - 10:00 3.00 CEMT P SURF 10:00 - 12:00 2.00 WHSUR P SURF 12:00 - 17:00 5.00 BOPSU P SURF 17:00 - 18:00 1.00 BOPSU~P SURF 18:00 - 20:30 2.50 BOPSU P SURF 20:30 - 00:00 3.50 BOPSU P SURF 4/18/2009 00:00 - 04:00 4.00 BOPSU P SURF 04:00 - 10:00 6.00 BOPSU N RREP SURF 10:00 - 12:00 2.00 BOPSU P SURF 12:00 - 13:00 1.00 BOPSU P SURF 13:00 - 14:00 1.00 BOPSU P SURF 14:00 - 18:30 18:30 - 21:00 surface. Confirmation at surface of cement returns with pH spike, weight increase. -Shoe at 4,374 ;collar at 4,292' and -Reciprocated 3-4' strokes throughout cement iob; PUW 195k, SOW 95k. Parked casing when SOW dropped to 50k. Slowly pressure up to 3500 psi from 1260 psi for casing test. 5n nci Insc in first R minutes. short test. Bled pressure to 0 osi - uuuis naiu. RD, blow down cementing equipment. Clear and clean rig floor. Clean under rotary and flush down diverter stack (heavy build up of cement). ND diverter and clean equipment, cellar of cement. NU wellhead equipment and casing spool. PT seal to 1000 psi. Good test. NU BOP equipment, rated to 5000 psi. Annular bag, 3-1/2"x6" variable top pipe rams, blind shear rams, mud cross, 2-7/8"x5" variable bottom pipe rams. RU BOP test equipment. Begin BOP test with 4" and 4 1/2" test joints. WSL, Tourpusher on hand to witness. AOGCC representative Jeff Jones on hand to witness test. During first test, visual and sound indication that wellhead may have moved. Call FMC hand to inspect wellhead, pressure test seal. Everything okay. Continue BOP test with 4" and 4 1/2" test joints. Test pressure 250 psi low, 4000 psi high. Continue BOP test with 4" and 4 1/2" test joints. Test pressure 250 psi low, 4000 psi high. Test Accumulator. Attempt to test Annular Preventer to 2500 psi but would not pass the high test. Tests witnessed by WSL Rob O'Neal, Tourpusher Biff Perry and AOGCC representative Jeff Jones. Changed out element in Annular Preventer. Test Annular Preventer with 4" test joint. Test good. Test witnessed by AOGCC rep Jeff Jones, Toolpusher Larry Wurdeman and WSL Mike Dinger. RD BOP testing equipment. Blow down lines. Clear and clean rig floor. chart. Lost 20 psi in first 15 minutes and 10 psi in second 15 minutes. 4.50 DRILL P INT1 MU used 8 3/4" Hughes MX-C1 bit, stabilizer, 3-DCs, jars and HWDP. PU and RIH with 4" DP one-by-one. Tag cement strip er at 4 282'. 2.50 DRILL P INT1 Drill out cement stringer and tag plugs at 4,288'. Drill out plugs and cement to 4,363'. Drilling parameters: WOB 10k, 60 rpm, 450 gpm, 800 psi, P/U wt 105k, S/O wt 60k. Printed: 6/8/2009 11:40:37 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: A-44 Page 5 of 12 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task Code NPT Phase ~I, Description of Operations 4/18/2009 21:00 - 22:00 1.00 DRILL P INT1 Displace 9.5 ppg spud mud with 8.8 ppg LSND mud at 450 gpm, 850 psi, 55 rpm and reciprocating 15' strokes. 22:00 - 23:00 1.00 DRILL P INT1 Conduct Well Control Drill with crew simulating open hole kick with well control equipment. 23:00 - 00:00 1.00 DRILL P INT1 Continue to drill out shoe track and new hole to 4400'. Drilling 4/19/2009 00:00 - 00:30 00:30 - 00:45 00:45 - 01:15 0.50 0.25 0.50 DRILL RIGU EVAL P P P INT1 INT1 INT1 parameters: WOB 10k, 60 rpm, 450 gpm, 800 psi, P/U wt 105k, S/O wt 60k, MW in and out 8.8 ppg. 4 '. CBU. MW in and out is 8.8 ppg. Pull back into shoe. -10k WOB, 450 gpm, 800 psi, PUW 105k, SOW 60k, 60 rpm Rig up test equipment on rig floor to conduct LOT. Conduct LOT with 8.8 ppg mud. LOT of 13.3 ppg, 751 psi., Hold for charted 10 min. 01:15 - 01:30 0.25 RIGD P INTi Rig down test equipment and clear rig floor. 01:30 - 02:45 1.25 DRILL P INT1 POH from BHA from 4350' to 822' racking back DP in stands. 02:45 - 04:30 1.75 DRILL P INT1 RIH picking up DP one by one from 822' to 2712'. 04:30 - 05:30 1.00 DRILL P INT1 Cut and slip 75' of 1-1/4" drilling line. Service TD, blocks, crown, inspect brakes and drawworks. 05:30 - 06:30 1.00 DRILL P INT1 POH from 2712' standing back DP, HWDP, jars, and DCs in derrick. 06:30 - 07:00 0.50 DRILL P INT1 LD stabilizer and used 8 3/4" bit. Bit grade: 1-1 WT-A-E-I-O-BHA 07:00 - 09:30 2.50 DRILL P INTi MU 8 3/4" drilling BHA: 8 3/4" DTX619M PDC bit, 1.5 degree motor, ARC, MWD telescope, stabilizer, 2 DCs, stabilizer, DC, jars, circ sub, 4" HWDP, Ghost reamer (at 1266' behind bit). 09:30 - 13:30 4.00 DRILL P INTi RIH with BHA to shoe picking up DP one by one. Ciruculate surface to surface, mud wt in and out 8.8 ppg. Obtain base line ECD of 9.6ppg. 13:30 - 00:00 10.50 DRILL P INT1 Drill ahead in 8 3/4" hole from 4409' to 6410'. - 550 gpm, 2455 psi on, 2266 psi off, 15k WOB, 8k ft/Ibs torque on, 6k ft/Ibs torque off, 80 rpm - PUW 125k, SOW 80k, ROT Wt 95k - 9.64 ppg calc ECDs, 10.41 ppg actual ECDs -AST .83 hrs, ART 7.11 hrs, ADT 7.11 hrs, Bit 7.6 hrs - 0 bbls fluid loss while drilling - Mud Weight in/out - 9.2 ppg - Pump Two 30 bbl nut plug sweeps for hole cleaning and to prevent bit balling. - Slow pump rates taken and recorded. 4/20/2009 00:00 - 12:00 12.00 DRILL P INT1 Drill ahead in 8 3/4" hole from 6410' to 8240'. - 555 gpm, 3115 psi on, 2880 psi off, 18k WOB, 11.5k fUlbs torque on, 10.5k fUlbs torque off, 80 rpm - PUW 158k, SOW 92k, ROT Wt 112k - 9.72 ppg calc ECDs, actual ECDs running avg from .6ppg to .9ppg over calculated. -AST .17, ART 7.65, ADT 7.82, Bit hrs 14.91 - 0 bbls fluid loss while drilling - Mud Weight in/out - 9.2 ppg - Slow pump rates taken and recorded - Pump 30 bbls hi-visc sweep; increased sand and clay returns across shakers. 12:00 - 00:00 12.00 DRILL P INT1 Drill ahead in 8 3/4" hole from 8240' to 9453'. - 550 gpm, 3361 psi on, 3263 psi off, 15k WOB, 9k fUlbs torque Printed: 6/8/2009 11:40:37 AM BP EXPLORATION Operations Summary Report Page 6 of 12 Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABORS 7ES Rig Number: Date ~~ From - To Hours ' Task Code NPT Phase 4/20/2009 4/21/2009 12:00 - 00:00 00:00 - 12:00 12.00 12.00 DRILL DRILL P P INT1 INT1 12:00 - 00:00 I 12.001 DRILL I P I I INT1 4/22/2009 00:00 - 12:00 12.00 ~ DRILL P INT1 12:00 - 20:30 I 8.501 DRILL I P I I INTi Description of Operations on, 7k ft/Ibs torque off, 80 rpm - PUW 175k, SOW 95k, ROT Wt 120k - 9.73 ppg calc ECDs, actual ECDs running avg from .6ppg to .9ppg over calculated. - AST 2.02, ART 4.85, ADT 6.87, Bit hrs 21.63 - 0 bbls fluid loss while drilling - Mud Weight in/out - 9.2 ppg - Slow pump rates taken and recorded - Pump 30 bbls high vis sweeps as needed to help with hole cleaning. Drill ahead in 8 3/4" hole from 9453' to 10106'. - 550 gpm, 3510 psi on, 3250 psi off, 15k WOB, 11k ft/Ibs torque on, 9k ft/Ibs torque off, 100 rpm - PUW 175k, SOW 108k, ROT Wt 128k - Calc ECDs 9.83 ppg, actual ECDs running from.4 ppg to .6 ppg over calculated. - AST 5.25, ART 2.32, ADT 7.57, Bit hrs 30.01 - 0 bbls fluid loss while drilling - Mud Weight in/out - 9.3 ppg - Slow pump rates taken and recorded. Drill ahead in 8 3/4" hole from 10106' to 10533'. - 550 gpm, 3408 psi on, 3263 psi off, 15k WOB, 12k ft/Ibs torque on, 10k fUlbs torque off, 100 rpm - PUW 200k, SOW 110k, ROT Wt 135k - Calc ECDs 9.85 ppg, actual ECDs running from .4 ppg to .6 ppg over calculated. - AST 5.8, ART 1.37, ADT 7.17, Bit hrs 37.4 - 0 bbls fluid loss while drilling - Mud Weight in/out - 9.3 ppg - Slow pump rates taken and recorded. Drill ahead in 8 3/4" hole from 10533' to 11490'. - 500 gpm, 3460 psi on, 3170 psi off, 10-15k WOB, 12k ft/Ibs torque on, 11 k Wlbs torque off, 90 rpm - PUW 210k, SOW 125k, ROT Wt 150k - 10.37 ppg calc ECDs, actual ECDs average 0.5 ppg over calculated. - AST 1.92, ART 6.80, ADT 8.72, Bit hrs 45.92 - No fluid loss noted while drilling. - Mud Weight in/out - 9.3 ppg - Slow pump rates taken and recorded - Weight up from 9.3 ppg to 9.7 ppg at 10740' with 580 bbls of 10.3 ppg spike fluid at 550 gpm with 3520 psi. Drill ahead in 8 3/4" hole from 11490' to TD of 12217'. - 500 gpm, 3680 psi on, 3408 psi off, 15k WOB, 14k fUlbs torque on, 10k ft/Ibs torque off, 100 rpm - PUW 230k, SOW 125k, ROT Wt 160k - 10.3 ppg calc ECDs, actual ECDs average 0.4 ppg over calculated. - AST .22, ART 6.38, ADT 6.60, Bit hrs 15.32 _ I ncc fh iiri at ~ AR hnh altar raarhinn Tn_ Strina in LCM (G and Mix II Medium). yFluid loss taper down to 24 bah in -Mud Weight in/out - 9.7 ppg Pnntea: waizooa 11:4U:3/ HM ~ ~ BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABORS 7ES Rig Number: Phase Description of Operations Date 'From - To Hours Task Code NPT ' 4/22/2009 12:00 - 20:30 8.50 DRILL P INT1 -Slow pump rates taken and recorded. 20:30 - 22:30 2.00 DRILL P INT1 Circulate 2x bottoms up at 500 gpm with 3484 psi, 100 rpm, 22:30 - 00:00 1.50 DRILL P 4/23/2009 00:00 - 00:30 0.50 DRILL P 00:30 - 01:30 1.00 DRILL P 01:30 - 05:00 3.50 DRILL P 05:00 - 07:30 2.50 DRILL P 07:30 - 08:30 1.00 DRILL P 08:30 - 12:00 3.50 DRILL P 12:00 - 19:00 4/24/2009 19:00 - 20:30 20:30 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01:00 01:00 - 02:30 02:30 - 03:30 03:30 - 06:00 06:00 - 4.,1:00 11:00 - 12:00 12:00 - 22:00 22:00 - 00:00 14/25/2009 100:00 - 01:30 7.00 DRILL P 1.50 DRILL P 2.50 DRILL P 1.00 DRILL P 0.50 DRILL P 0.50 DRILL P 1.50 CASE P 1.00 CASE P 2.50 CASE P 5.001 CASE I P 1.00 CASE P 10.00 CASE P 2.00 CASE P 1.50 CASE P PUW 230k, SOW 125k, ROT 160k. First BU confirmed casing point as per geologist. Actual ECDs lowered to 0.25 ppg over calculated after 2nd BU. INT1 Monitor well for 10 min. -static. Attempt to POH. Have to pump out due to swabbing at 52 gpm with 815 psi. Pump out from 12217' to 11603'. INT1 Continue to pump out from 11603' to 10930' at 126 gpm with 800 psi. INTi Monitor well -static. RIH from 10930' to 12217'. Upon reachino TD loss rate of 150 bph. Rack one stand back. No loss rate noted. INTi Pump 40 bbl high visc sweep at 500 gpm with 3600 psi. 70% increase in cuttings when high visc sweep back at surface. CBU x 3 . INT1 Monitor well -static. POH from 12063' to 9510'. Worked through intermittent tight spots with 35k over pull from 10350' to 9620'. From 9550' to 9510' unable to work tight spots, pump out at 125 gpm with 580 psi. INT1 Pump 40 bbl high visc sweep at 550 gpm with 3300 psi. Circulate to clean up tangent section for total of 750 bbls. INTi Monitor well -static. Attempt to POH. Start to swab and over pull. Backream from 9510' to 8177" at 550 gpm with 3320 psi, 11-14k ft-Ibs torque, 100 rpm, ROTW 110k. INT1 Continue to backream from 8177' to 4383' at 550 gpm with 2908 psi, 9k ft-Ibs torque, 100 rpm, ROTW 110k. INT1 Circulate 1 1/2 BU at 550 gpm with 2370 psi. INT1 Monitor well -static. Pump dry job. BD top drive. POH from 4383' to 910' standing back 4" DP and 4" HWDP in derrick. INTi LD 8 3/4" drilling BHA #4. All components in gauge. Inspect and grade bit: 1-2-WT-T-XI-PN-TD. INT1 Continue LD 8 3/4" drilling BHA. INT1 Clean and clear rig floor. INT1 Pull wear ring. Install test plug. PJSM with rig crew. Change out rams from 3 1/2 " x 6" to 7". INT1 Test rams to 250 psi low / 4000 psi high. Held each test for charted 5 min -good test. RD test equipment. Pull test plug. INT1 PJSM with rig crew, WSL, Tourpusher, and Csg rep. Make dummy run and RU to run 7" BTC &TCII 26# L-80 with torque turn equipment for TCII. INT1 Make up shoe track with bakerlock and check floats. Run 7" BTC from surface to 4383', fiilling every joint, record PUW and SOW every 15 jts while inside 9 5/8" csg. Average make up torque 8000 ft-Ibs, PUW 125k, SOW 85k. INT1 Circulate 1 1/2 csg vol at 5 BPM with 530 psi. INT1 Continue to run 7" csg from 4383' to THRZ at 10961' filling every joint, record PUW and SOW every 10 jts. INT1 CBU at 10961' at 3 BPM with 650 psi. Initial fluid loss rate of 120 bph. Final fluid loss rate of 77 bph, for a total fluid loss of 55 bb s while circulatin . INT1 Continue running in with 7" TCII from 10961' to 12185' filling every joint. Pick up mandrel hanger, landing jt, and land Nnnteo: oiuiluua ii:au:siNm BP EXPLORATION Operations Summary Report Page 8 of 12 ~ Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABOBS 7ES Rig Number: Date 'From - To Hours Task Code NPT Ph ase Description of Operations 4/25/2009 100:00 - 01:30 1.50 CASE P INTi hanger - Ran total of 156 jts of BTC-M, 1 26' crossover pup jt from BTC-M to TCII, and 144 jts of TCII. -BTC-M average make up torque 8,000 ft-Ibs with Best-O-Life pipe dope. - TCII use torque turn services to optimum make up torque 10,100 ft-Ibs with Jet Lube Seal Gaurd. - Ran a total of 141 centralizers from the THRZ to projected top of cement. 01:30 - 02:00 0.50 CEMT P INT1 LD Franks Fill-up tool and rig up SLB cement head and lines. Blow down top drive. 02:00 - 05:30 3.50 CEMT P INTi Stage up pumps in 1/2 bbl increments. Initial 1/2 bpm @ 620 psi, final 5 bpm @ 625 psi. Circulate to condition mud for PJSM with WSL, Tourpusher, Schlumberger, and rig crew on cement job. CBU x2+ for total for 726 bbls, lost 93 bbls while circulatin . 05:30 - 08:30 3.00 CEMT P INTi Pump 5 bbls of 10.5 ppg Mud Push to warm lines. Shut in and pressure test lines to 4000 psi -good test. Resume pumping as follows: Pump remaining 25 bbls of 10.5 ppg Mud Push. Drop bottom plug. Pump 203.6 bbls of 11.0 ppg LiteCRETE Lead Slurry (325 sacks) at 5 bpm, followed by 39 bbls of 15.8 ppg Class G Tail Slurry (217 sacksl at 5 bpm. Drop top plug and kick out with 10 bbls of water via cementers. Displace cement with 454.3 bbls of 9.8 ppg LSND mud with rig pumps at 5 bpm, slow pumps to 2 bpm to bump plug at 500 psi over displacement pressure with 7929 stks. 94.4% PE. Hold at 1600 si for 3 min slow) increase ressure to 4000 si. Test casing to 4000 psi. Hold and chart for 30 min. Bleed pressure and check floats -floats holding. - Lost 129 bbls while dis lacing cement. - Lead: 500 psi compressive strength in 10:37 hrs, yield 3.52 cult / sk. - Tail: 500 psi compressive strengh in 5:51 hrs, yield 1.16 cult / sk. 08:30 - 09:00 0.50 CEMT P INTi Rig down Schlumberger cementers, 7" casing equipment, and landing jt. 09:00 - 10:30 1.50 WHSUR P INT1 Install 9 5/8" x 7" Pack-Off. RILDS and test Pack-Off to 5000 psi for 30 min -good test. Line up and pump 6 bbls of 9.8 ppg down OA. Break over pressure 7 0 psi. 10:30 - 13:00 2.50 BOPSU P INT1 Install test plug and change out 7" rams to 3 1/2" x 6" variables. 13:00 - 14:30 1.50 BOPSU P INT1 RU test equipment and test 3 1/2 " x 6" upper rams with 4" and "- test joints to 250 psi / 4000 psi -good test. RD test equipment. 14:30 - 16:00 1.50 CEMT P INTi Clear and clean rig floor. Service the Top Drive. 16:00 - 18:00 2.00 DRILL P PROD1 PU and RIH with 6 1/8" drilling BHA: Rerun Hycalog RSX613M-A2, 1.15` Motor, Impulse MWD, and ADN. 18:00 - 18:30 0.50 DRILL P PROD1 PU 15 jts of 4" DP from shed from 910' to 1387'. At 1000' perform shallow hole test at 249 gpm with 1236 psi. 18:30 - 22:00 3.50 DRILL P PROD1 RIH with 6 1/8" drillin BHA 4" HWDP, and 4" DP from derrick to 9500'. 22:00 - 23:30 1.50 DRILL P PROD1 Slip and Cut 125' of Drilling Line and service drawworks. Printed: 6/8/2009 11:40:37 AM ~ ~ BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABORS 7ES Rig Number: Date From - To Hours Task i Code NPT Phase ', Description of Operations - ---- 4/25/2009 23:30 - 00:00 0.50 DRILL P PROD1 Continue to RIH from 9500' to 12071' 4/26/2009 00:00 - 01:00 1.00 DRILL P PROD1 Continue to RIH with drilling BHA #5 from 12071' MD and taaaed plugs on depth at 12128' MD. Drill up landing cement and plugs to within 5' of the shoe with 218 gpm, 2190 psi, 60 rpm, 16.7 ft-Ibs torque and 18k Ibs WOB. 01:00 - 03:30 2.50 DRILL P PROD1 Pump 100 bbl of water, followed by 45 bbl spacer (Flowzan and water). Displace to 8.5 ppg FloPro mud at 225 gpm with 2166 psi for a total of 398 bbls of FloPro pumped. 03:30 - 04:00 0.50 DRILL P PROD1 Drill u shoe and 20' of new hole to 12237' MD with the following parameters: - 242 gpm, 1993 psi on, 1780 psi off - 60 rpm, 8k ft-bls torque on, 6k ft-Ibs torque off, 5k Ibs WOB 04:00 - 04:30 0.50 DRILL P PROD1 Circulate one bottoms up at 250 gpm and 1840 psi while rotating and reciprocating at 65 rpm with 6k ft-Ibs torque for a total of 272 bbls pumped. Bottoms up showed clean sand returns. 04:30 - 05:30 1.00 DRILL P PROD1 onduct FIT to EMW 10.5 , TVD 05:30 - 12:00 6.50 DRILL P PROD1 Drill ahead in 6 1/8" hole to from 12237' to 12740'. - 250 gpm, 2090 psi on, 1868 psi off, 5k WOB - 210k PUW, 140k SOW, 157k ROTW - 90 rpm, 7.1 k ft-Ibs torque on, 10.5k ft-Ibs torque off - ADT 5.62 hrs, AST 0 hrs, Bit 5.62 hrs, Jars 5.62 hrs - No fluid loss noted while drilling - MW in /out - 8.5 ppg 12:00 - 12:30 0.50 DRILL P PROD1 Drill ahead in 6 1/8" hole to from 12740' to 12775'. y - 250 gpm, 2069 psi on, 1827 psi off, 10k~ - 210k PUW, 140k SOW, 160k ROTW - 90 rpm, 10k ft-Ibs torque on, 7k ft-Ibs torque off - ADT 0.55 hrs, AST 0 hrs, Bit 6.17 hrs, Jars 6.17 hrs - No fluid loss noted while drillin - MW in /out 8.5 ppg 12:30 - 13:30 1.00 DRILL P PROD1 Circulate four open hole volumes at 250 gpm with 1790 psi. PUW 210k, SOW 140k. MW in /out 8.5 ppg. 13:30 - 14:00 0.50 DRILL P PROD1 Backream from 12775' MD to 12200' MD (inside 7" casing shoe at 12214' MD) at 250 psi with 1790 psi, 90 rpm and 6k ft-Ibs torque. MW in /out 8.5 ppg. 14:00 - 15:30 1.50 DRILL P PROD1 Open Circ Sub and circulate casing clean at 500 gpm with 2200 psi. Monitor well -static. Pump dry job and drop 2.25" rabbit. 15:30 - 19:30 4.00 DRILL P PROD1 POH from 12200' MD to 910' MD. MW in /out 8.5 ppg. 19:30 - 21:30 2.00 DRILL P PROD1 LD BHA. PJSM on removing nuclear source. Remove source. Continue to lay down BHA. LD 6 1/8" Hycalog RSX613M-A2 bit. Bit grade: 6-2-WT-N-X-I-BT-TD. 21:30 - 22:00 0.50 CASE P PROD1 RU 4 1/2" liner running equipment. 22:00 - 00:00 2.00 CASE P PROD1 MU shoe assembly, check floats. Floats good. RIH with 4 1/2" 12.6# L-80 IBT-M liner. Baker-Lok shoe track joints #1-3. RIH with 4 1/2" 12.6# L-80 IBT-M liner filling every joint. Average make up torque = 3800 ft-Ibs. Total of 17 joints of 4 1/2" 12.6# L-80 IBT-M run. Printed: 6/8/2009 11:40:37 AM BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations 4/26/2009 22:00 - 00:00 2.00 CASE P PROD1 Centralizers: one centralizer on joint #1 10' from shoe, one centralizer on joint #2 in middle, one centralizer on joint #3 in middle, two centralizers on joints #4-13 with stop ring in middle of joint, one centralizer on joint #16 with stop ring in middle of joint, one centralizer on joint #17 with stop ring in middle of joint. Total of 25 centralizers. MU liner running tool, liner and packer to 4 1/2" liner. MU one stand DP, circulate 1.5 times liner volume at 126 gpm, 100 psi. PUW 35k, SOW 33k 4/27/2009 00:00 - 06:30 6.50 CASE P RUNPRD Continue to RIH with 4 1/2", 12.6#, L-80, IBT-M production liner from 733 to 12214' MD (7" casing shoe). PUW 190k, SOW 06:30 - 07:00 0.50 CASE P RUNPRD Stage up pumps as follows: 2 bpm 568 psi, 3 bpm 769 psi. Circulate 1 1/2" drill pipe and liner volume at 7" casing shoe prior to going into open hole. 07:00 - 07:30 0.50 CEMT P RUNPRD Continue to RIH from inside the 7" casing shoe at 12214' MD to 12774' MD on 4" DP. MU cement head. 07:30 - 08:30 1.00 CEMT P RUNPRD Stage up pumps as follows: 1 bpm with 520 psi, 2 bpm with 660 psi, 3 bpm with 769 psi, 4 bpm wtih 911 psi and 5 bpm with 1093 psi. Circulate prior to cement job while reciprocating. RU SLB cementers. PJSM with crew, SLB cementers, WSL, Toolpusher, Mud Engineer. 08:30 - 11:00 2.50 CEMT P RUNPRD Cement liner as follows: Pump 10 bbls of 10.5 ppg MudPush II and pressure test cement lines to 3500 psi. Pump remaining 10 bbls of 10.5 ppg MudPush II. Pump 23 bbls of 15.8 ppg Class G cement at 5 bpm. Drop wiper dart and switch over to rig pump and displace with 129 bbls of 8.5 ppg. FloPro mud at 5BPM while reci rocating. Slow rate to 3BPM prior to latching liner wiper plug, shear at 2000 psi. Bump plug at 3 bpm with 2235 psi. Increase pressure to set hanger to 3500 psi, slack off 25K to ensure hanger set. Bleed pressure to zero and check floats - floats holding. Rotated 20 turns to right to release from C2 liner running tool. Pressure up to 1000 psi. Picked up 10 ft and saw 300 psi pressure drop. Circulated 20 bbls at 6.5 bpm with 1500 psi. Slowed to 2 bpm and set down 50k Ibs down weight to set ZXP liner top packer and see good surface indication of set. Repeat sequence with rotation (-20 rpm). PU 35 ft and circulated cement out of hole at 12 bpm at 2400 psi. Slow pump rate down to 7 bpm with 1360 psi due to discharge on pump #1 developing a leak. Approximately 12 bbls of contaminated cement returns. To of liner at 12064' MD, shoe at 12774' MD. Liner is full of 8.5 ppg FloPro mud. Full returns throughout cement job. CIP C~ 09:42 hrs. 15.8 ppg Class G cement: Yield 1.17 cu-ft/sx, Sacks 139. Compressive strength: 500 psi at 10:40 hrs, 1000 psi at 11:52 hrs 11:00 - 12:00 1.00 CEMT P RUNPRD Pump 50 bbls of fresh water and displace well to 8.5 ppg Print2tl: 6/8/LUUy 11:4U:S/ AM BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To ii Hours Task Code NPT Phase 4/27/2009 11:00 - 12:00 12:00 - 12:30 12:30 - 20:30 20:30 - 21:30 21:30 - 22:30 22:30 - 00:00 4/28/2009 00:00 - 06:30 06:30 - 07:00 07:00 - 09:30 09:30 - 22:00 22:00 - 23:00 23:00 - 00:00 4/29/2009 00:00 - 04:00 04:00 - 05:30 05:30 - 06:00 1.00 CEMT P 0.50 CEMT P 8.00 CEMT P 1.00 CEMT P 1.00 CEMT P 1.50 EVAL P 6.50 EVAL P 0.50 BUNCO P 2.50 WHSUR P 12.50 BUNCO P 1.00 BUNCO P 1.00 BUNCO P 4.00 BUNCO 1.50 0.50 06:00 - 09:30 3.50 BOPSU~ P 09:30 - 11:30 2.00 WHSUR P 11:30 - 14:00 I 2.501 WHSUR I P Description of Operations RUNPRD seawater from top of 4 1/2" production liner to surface. RUNPRD RD cementing equipment RUNPRD POH from 12064' MD to 381' MD laying down 4" DP. RUNPRD La down C2 roduction liner runnin tool. Confirmed dog sub sheared. Clean and clear rig floor. RUNPRD Pressure test 4 1/2" roduction liner to 4000 si for 30 minutes once 1000 psi compressive strength was acquired. Lost 30 psi during 1st 15 min, lost 10 psi during 2nd 15 min -Good test. OTHCMP RU Schlumberger E-line unit to perform SCMT log in 4 1/2" liner and 7" casing. OTHCMP Continue to perform SCMT log (cement evaluation log) from 12671' MD to 7000' MD. Estimated TOC on 7" intermediate casing found at 7930' MD. RD Schlumberger E-line unit. RUNCMP RU to run 4.5" 12.6# L-80 TC-II completion (torque turn computer). RUNCMP Pull wear bushing. Make dummy run with tubing hanger. LD hanger and test joint. RUNCMP RIH with 4 1/2" 12.6# L-80 TC-II completion tubing. Baker-Lok all connections below S-3 packer. Average make-up torque at 3850 ft-Ibs. Tailpipe assembly: WLEG, XN nipple with RCH-M plug, 1 full joint 4 1/2" 12.6# L-80 TC-II, X nipple, S-3 packer, X nipple. X nipple at 2210' MD. Total of 284 joints run. RUNCMP Space out for pup joints. MU tubing hanger and land. RILDS. Bottom of WLEG at 12073' MD. Top of packer set at 11955' MD. RUNCMP Reverse circulate 187 bbls clean seawater at 3 bpm, 200 psi. RUNCMP Finished reverse circulating clean seawater followed by 147 bbl of seawater treated with corrosion inhibitor into the annulus and displace with 75 bbl diesel to position inhibited water between the bottom of the diesel and production packer at 2 bpm with an Initial Circulating Pressure of 100 psi and Final Circulating Pressure of 400 psi. U-tube diesel freeze protect while keeping U-tube flow rate at less than 3 bpm and 500 psi through Wells Group Choke Manifold and Micromotion Flow Meter (to prevent S-3 packer damage as per Baker Rep). RUNCMP Drop the roller stem ball /rod to RCH plug to XN Nipple at 12061' MD to set acker. Set the acker and test the tubing to 4000 psi for 30 min -lost 30 si durin 1st 15 min and 0 si during last 15 min -good test. Bleed tubing pressure to 1500 psi. Test the 7" x 4.5" IA annulus to 4000 psi for 30 minutes -lost 20 psi during 1st 15 min and 10 osi during last 15 min -good test. Lou Grimaldi from AOGCC waived witness of test. RUNCMP Install TWC and pressure test from above to 1000 psi for 10 min -good test. RUNCMP Suck fluid out of stack. ND BOP. Rack back in cellar and secure. RUNCMP MU adapter flange and NU tree. Pressure test adapter flange and tree to 5000 psi with diesel -good tests. RUNCMP Pull TWC with lubricator. Lubricate in BPV. BPV cannot be Printed: 6/8/2009 11:40:37 AM • BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: A-44 Common Well Name: A-44 Spud Date: 4/12/2009 Event Name: DRILL+COMPLETE Start: 4/10/2009 End: 4/29/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/29/2009 Rig Name: NABOBS 7ES Rig Number: Date From - To ', Hours Task Code NPT ', Phase Description of Operations 4/29/2009 11:30 - 14:00 2.50 WHSUR P RUNCMP tested from below. 14:00 - 15:00 1.00 RIGD P RUNCMP Secure well and continue to prepare rig for move to 15-29B. Release rig at 15:00 hrs. rnniea: oioizwa i rvu.oi rm • • A-44 Wel I History Date Summary 04/29/09 T/I/O=Vac/0/0. Pull 4-1/16 CIW H TWC thru tree, post tree test (7es). 1-2' ext used, tagged C~ 96". Set 4- 1/16" CIW H BPV thru tree 7es move off well. 1-2' ext used, tagged Q 96". No problems. 05/14/09 T/I/O = 0/0/0 Pulled 4 1/16" CIW H BPV w/ 1-2' ext C~ 96" Post Rig. 05/15/09 T/I/0=0/0/0. Pull 4-1/16" CIW H BPV #152 thru tree, post rig. 1-2' ext used, tagged C«?96". No problems 05/19/09 _ P D BALL & ROD FROM 12050' SLM 05/20/09 PULLED 4 1/2" RHC FROM 12065' SLM TAGGED TD W/ 3-3/8" DUMMY GUN DRIFT & 3.50" S. BAILER ~ 12692' SLM (RECOVERED --1 GAL MUD) 05/20/09 T/I/0=720/0/80. Temp=S1. Monitor (conductor for Blue Goo). Flutes @ the 5, 6 & 12 O'Clock positions are cemented to surface, Flutes C~ the 1, 3, 9 & 11 O'Clock positions are open to 44". Coductor is 20" and the cellar depth is Q 44" with ice sheet covering the bottom. No Blue Goo in conductor.SV, WV=Closed. SSV, MV=Open. IA & OA=OTG. NOVP. 05/25/09 (SCMT, PDC, PERFORATE) SSV, MASTER -OPEN. SWAB, WING -CLOSED. INITIAL T/I/O = 700/0/0. RIG UP ELINE. RIH WITH GR/CCUSCMT. TOOL DEPTH SET TO 23.86' AT TUBING HANGER. RUN CEMENT BOND LOG IN 4.5 IN LINER. GOOD CEMENT THROUGHOUT TOP OF LINER; NO TOC OBSERVED. LOG PRIMARY DEPTH CONTROL FROM SURFACE TO TD; LOG IS 6' SHALLOW WITH RESPECT TO MWD LOG DATED 12-APR-09. TAGGED TD AT 12684' ELM (12690' ON MWD LOG). GUN 1: RIH WITH 3-3/8" PJ HSD GUN. API DATA: 36.5" PENETRATION, ENTRANCE HOLE: 0.37" 6 SPRAT 60 DEG PHASING. PERFORATED 12662' - 12682'. 05/26/09 GUN 2: RIH WITH 3-3/8" PJ HSD GUN. API DATA: 36.5" PENETRATION, ENTRANCE HOLE: 0.37" 6 SPR AT 60 DEG PHASING. PERFORATED 12646' - 12662'. PERFORATIONS TIED ~ INTO MWD GR DATED 12-APR-2009 (TIE IN LOG). -6' CORRECTION TO PDC LOG DATED 25-MAY-2009 (REFERENCE LOG). VALVE POSITIONS UPON DEPARTURE, SWAB, WING -CLOSED. SSV, MASTER.- OPEN. FINAL T/I/O = 0//0/0. 06/05/09 T/I/0=160/240/150. Temp=135'._MIT-IA *`PASS"' to 2500 psi (AOGCC). State witness by Chuck Scheve. MIT-IA to 2500 psi w/ 2.6 bbl diesel. IA lost 30 psi in the 1st 15 min and 0 psi in the 2nd 15 min for a total of 30 psi in 30 min. Bled IAP from 2470 psi to 10 psi. OAP decreased 50 psi. Final WHPs=160/10/100. 06/05/09 T/I/0=160/240/150 Temp=Hot MIT IA PASSED 2500 psi (AOGCC MITIA post initial injection) State witness by C.Scheve Pumped 2.6 bbls of 40' diesel down IA to reach 2500 psi for MIT IA 1 s test 1st 15 min lost 30 psi 2nd 15 min lost 0 psi for a total of 30 psi in 30 min Bleed IA psi down bleed back aprox. 3 bbls Final Whp's=160/10/100 Well on injection casing valves open to gauge's Page 1 of 1 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: A-44 Common Name: A-44 Test Date Test Type 4/19/2009 LOT 4/26/2009 FIT Test Depth (TMD) Test Depth (TVD) AMW 4,373.0 (ft) 3,205.0 (ft) 8.80 (ppg) 12,214.0 (ft) 8,546.0 (ft) 8.50 (ppg) Surface Pressure Leak Off Pressure (BHP) EMW - -- - ___ 751 (psi) 2,216 (psi) 13.31 (ppg) 889 (psi) ~ 4,663 (psi) 10.50 (ppg) Printed: 6/8/2009 11:40:31 AM by _ _ . _ _ S~hlumberger _ - - H-44 ~u I-tepvri Report Date: 26-Apr-09 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 343.720° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 fl, E 0.000 ft Structure /Slot: A-PAD / A-44 TVD Reference Datum: Rotary Table Well: A-44 TVD Reference Elevation: 77.10 ft relative to MSL Borehole: A-44 Sea Bed /Ground Level Elevation: 48.94 ft relative to MSL UWVAPI#: 500292341200 Magnetic Declination: 22.705° Survey Name /Date: A-44 /April 26, 2009 Total Field Strength: 57700.139 nT Tort /AHD / DDI I ERD ratio: 186.502° / 7627.86 ft / 6.300 / 0.838 Magnetic Dip: 80.884° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 17, 2009 Location LaVLong: N 7015 47.404, W 148 45 26.339 Magnetic Declination Model: BGGM 2008 Location Grid NIE Y/X: N 5947375.660 ftUS, E 653705.230 ftUS North Reference: True North Grid Convergence Angle: +1.16970145° Total Corr Mag North -> True North: +22.705° Grid Scale Factor: 0.99992664 Local Coordinates Referenced To: Well Head i Comments Measured Inclination Azimuth Subsea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de tt n n ft ft ft ft de 00 it ftUS ftUS RTE 0. 00 O.UU U.UU -//.lU U.UU U.UU U.UV U. UU U.UU U.UV V.VV b`J4/J/b.bb bb3/Ub.Z3 IV /U Ib 4/.4V4 VV 14154D Zb.33`J GYD GC SS 82. 26 0.57 326.59 5.16 82.26 0.39 0.41 0. 41 0.34 -0.23 0.69 5947376.00 653705.00 N 70 15 47.407 W 148 45 26.346 177. 60 0.57 325.49 100.49 177.59 1.29 1.36 1. 36 1.13 -0.76 0.01 5947376.77 653704.45 N 70 15 47.415 W 148 45 26.361 267. 60 1.93 306.01 190.47 267.57 2.92 3.31 3. 27 2.39 -2.23 1.56 5947378.00 653702.95 N 70 15 47.427 W 148 45 26.404 356. 60 4.54 302.18 279.32 356.42 6.74 8.33 8. 23 5.15 -6.43 2.94 5947380.67 653698.70 N 70 15 47.454 W 148 45 26.526 446. 60 7.35 300.13 368.83 445.93 13.58 17.65 17. 51 9.93 -14.42 3.13 5947385.30 653690.61 N 70 15 47.502 W 148 45 26.759 534. 60 8.84 301.68 455.95 533.05 22.68 30.04 29. 89 16.31 -25.05 1.71 5947391.45 653679.86 N 70 15 47.564 W 148 45 27.068 624. 60 10.05 311.95 544.73 621.83 34.49 44.77 44. 58 25.19 -36.77 2.30 5947400.09 653667.95 N 70 15 47.652 W 148 45 27.409 714. 60 11.27 318.35 633.18 710.28 49.12 61.40 60. 98 37.01 -48.46 1.89 5947411.67 653656.03 N 70 15 47.768 W 148 45 27.749 MWD+IFR+MS 748. 02 11.22 322.31 665.96 743.06 55.09 67.91 67. 34 42.03 -52.62 2.32 5947416.60 653651.77 N 70 15 47.817 W 148 45 27.870 838. 02 12.97 324.77 753.96 831.06 72.80 86.77 85. 69 57.21 -63.80 2.03 5947431.55 653640.28 N 70 15 47.966 W 148 45 28.196 935. 09 16.09 326.16 847.91 925.01 95.93 111.12 109. 50 77.28 -77.58 3.23 5947451.34 653626.10 N 70 15 48.164 W 148 45 28. 1029. 97 16.64 329.51 938.95 1016.05 121.64 137.84 135. 68 99.91 -91.79 1.15 5947473.67 653611.42 N 70 15 48.386 W 148 45 29. 1126. 51 17.70 331.48 1031.19 1108.29 149.38 166.34 163. 56 124.72 -105.81 1.25 5947498.18 653596.90 N 70 15 48.630 W 148 45 29.4 1222. 21 20.33 332.69 1121.66 1198.76 179.92 197.52 194. 12 152.28 -120.39 2.78 5947525.44 653581.77 N 70 15 48.901 W 148 45 29.842 1316. 94 21.94 335.44 1210.02 1287.12 213.59 231.67 227. 58 183.00 -135.30 2.00 5947555.84 653566.24 N 70 15 49.204 W 148 45 30.276 1413. 19 23.54 337.42 1298.78 1375.88 250.49 268.87 263. 97 217.10 -150.15 1.84 5947589.64 653550.69 N 70 15 49.539 W 148 45 30.709 1508. 82 24.89 337.29 1386.00 1463.10 289.47. 308.09 302. 44 253.30 -165.25 1.41 5947625.52 653534.85 N 70 15 49.895 W 148 45 31.148 1602. 47 26.60 337.71 1470.35 1547.45 329.91 348.77 342. 50 290.88 -180.82 1.84 5947662.77 653518.53 N 70 15 50.265 W 148 45 31.601 1698. 79 29.14 339.37 1555.49 1632.59 374.74 393.79 386. 86 332.79 -197.26 2.76 5947704.33 653501.23 N 70 15 50.677 W 148 45 32.080 1794. 91 29.96 340.09 1639.11 1716.21 422.03 441.19 433. 57 377.26 -213.68 0.93 5947748.45 653483.91 N 70 15 51.114 W 148 45 32.558 1889 .63 34.73 341.54 1719.11 1796.21 472.63 491.85 483. 49 425.12 -230.29 5.10 5947795.96 653466.33 N 70 15 51.585 W 148 45 33.041 1983 .67 38.92 342.95 1794.37 1871.47 528.96 548.20 538. 95 478.79 -247.44 4.55 5947849.27 653448.09 N 70 15 52.113 W 148 45 33.540 2077 .81 41.64 344.14 1866.18 1943.28 "589.82 609.06 598. 82 537.16 -264.66 3.00 5947907.27 653429.68 N 70 15 52.687 W 148 45 34.041 2172 .91 44.06 344.98 1935.90 2013.00 654.48 673.73 662. 46 599.50 -281.87 2.61 5947969.24 653411.21 N 70 15 53.300 W 148 45 34.542 SurveyEditor Ver SP 2.1 Bld( users) A-44W-44W-44W-44 Generated 6/11/2009 1:37 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North tt de de n n tt tt tt ft tt de 100 ft ftUS ftUS LLb25.14 4/.4/ 34J.33 LVVL.3L LU/~.4L /LL.Ob /41.yJ /L~. O/ OOJ.4J -Ly~.34 J.Jy Jy46VJ4.01 OJJ3~L.Jy IV /V IJ ."1J.~40 VV 140 4) JJ.VJ1 2363.69 50.71 345.74 2064.89 2141.99 794.84 814.15 800. 92 735.36 -317.37 3.41 5948104.33 653372.94 N 70 15 54.636 W 148 45 35.576 2458.89 52.85 345.07 2123.78 2200.88 869.60 888.94 874. 91 807.73 -336.22 2.31 5948176.30 653352.62 N 70 15 55.348 W 148 45 36.124 2555.40 56.68 345.26 2179.45 2256.55 948.39 967.75 953. 06 883.92 -356.40 3.97 5948252.05 653330.89 N 70 15 56.097 W 148 45 36.712 2650.62 58.76 343.66 2230.30 2307.40 1028.88 1048.25 1033. 10 961.47 -377.97 2.61 5948329.14 653307.74 N 70 15 56.860 W 148 45 37.340 2747.16 59.29 343.82 2279.99 2357.09 1111.65 1131.02 1115. 55 1040.93 -401.15 0.57 5948408.11 653282.95 N 70 15 57.641 W 148 45 38.014 2842.24 59.73 343.14 2328.23 2405.33 1193.58 1212.95 1197. 24 1119.48 -424.45 0.77 5948486.16 653258.05 N 70 15 58.414 W 148 45 38.693 2937.94 60.63 343.04 2375.82 2452.92 1276.60 1295.98 1280. 09 1198.92 -448.60 0.94 5948565.08 653232.29 N 70 15 59.195 W 148 45 39.396 3030.49 59.97 341.07 2421.68 2498.78 1356.95 1376.37 1360. 40 1275.39 -473.36 1.98 5948641.03 653205.97 N 70 15 59.947 W 148 45 40.116 3124.32 58.53 341.72 2469.65 2546.75 1437.52 1457.01 1441. 00 1351.81 -499.09 1.65 5948716.90 653178.69 N 70 16 0.699 W 148 45 40.865 3217.51 58.44 342.73 2518.37 2595.47 1516.94 1536.45 1520. 38 1427.46 -523.34 0.93 5948792.04 653152.90 N 70 16 1.443 W 148 45 41.572 3311.12 58.39 343.57 2567.40 2644.50 1596.68 1616.19 1599. 99 1503.78 -546.46 0.77 5948867.86 653128.23 N 70 16 2.193 W 148 45 42.244 3404.93 58.74 343.95 2616.32 2693.42 1676.72 1696.24 1679. 87 1580.63 -568.84 0.51 5948944.23 653104.29 N 70 16 2.949 W 148 45 42.~ 3497.80 59.01 344.16 2664.33 2741.43 1756.22 1775.74 1759. 20 1657.07 -590.68 0.35 5949020.21 653080.89 N 70 16 3.701 W 148 45 43. 3593.01 58.91 343.61 2713.42 2790.52 1837.79 1857.31 1840. 63 1735.44 -613.32 0.51 5949098.09 653056.66 N 70 16 4.472 W 148 45 44.191 3687.58 58.69 343.09 2762.41 2839.51 1918.68 1938.20 1921. 43 1812.94 -636.50 0.52 5949175.10 653031.90 N 70 16 5.234 W 148 45 44.866 3783.60 59.24 343.56 2811.92 2889.02 2000.95 2020.48 2003. 62 1891.76 -660.11 0.71 5949253.41 653006.69 N 70 16 6.009 W 148 45 45.553 3879.82 58.57 344.77 2861.61 2938.71 2083.34 2102.87 2085. 87 1971.02 -682.59 1.28 5949332.19 652982.60 N 70 16 6.788 W 148 45 46.208 3975.55 57.09 344.70 2912.58 2989.68 2164.36 2183.90 2166. 73 2049.19 -703.93 1.55 5949409.90 652959.67 N 70 16 7.557 W 148 45 46.829 4069.71 57.09 344.96 2963.74 3040.84 2243.40 2262.95 2245. 61 2125.49 -724.61 0.23 5949485.76 652937.44 N 70 16 8.308 W 148 45 47.432 4165.22 56.98 345.62 3015.71 3092.81 2323.50 2343.09 2325. 54 2202.99 -744.96 0.59 5949562.82 652915.51 N 70 16 9.070 W 148 45 48.024 4260.25 57.71 345.25 3066.98 3144.08 2403.47 2423.09 2405 .35 2280.43 -765.08 0.84 5949639.83 652893.82 N 70 16 9.831 W 148 45 48.610 4324.63 57.73 344.59 3101.37 3178.47 2457.89 2477.52 2459 .68 2332.99 -779.24 0.87 5949692.08 652878.59 N 70 16 10.348 W 148 45 49.023 9-5/8" C~ 4374'md 4383.83 56.50 344.39 3133.51 3210.61 2507.60 2527.24 2509 .33 2380.89 -792.54 2.10 5949739.70 652864.32 N 70 16 10.819 W 148 45 49.410 4482.37 56.38 343.51 3187.98 3265.08 2589.71 2609.35 2591 .38 2459.80 -815.24 0.75 5949818.12 652840.01 N 70 16 11.595 W 148 45 50.071 4577.92 56.54 342.94 3240.78 3317.88 2669.35 2688.99 2670 .99 2536.05 -838.22 0.52 5949893.88 652815.48 N 70 16 12.345 W 148 45 50.740 4673.77 56.48 341.79 3293.67 3370.77 2749.26 2768.93 2750 .92 2612.23 -862.44 1.00 5949969.55 652789.71 N 70 16 13.095 W 148 45 51.445 4768.44 57.44 341.31 3345.28 3422.38 2828.56 2848.29 2830 .28 2687.51 -887.56 1.10 5950044.29 652763.07 N 70 16 13.835 W 148 45 52.177 4864.66 57.69 341.06 3396.89 3473.99 2909.69 2929.50 2911 .48 2764.38 -913.75 0.34 5950120.61 652735.31 N 70 16 14.591 W 148 45 52.939 4960.39 55.79 343.93 3449.40 3526.50 2989.70 3009.54 2991 .51 2840.70 -937.84 3.20 5950196.41 652709.67 N 70 16 15.341 W 148 45 53.641 ~ 5055.67 55.55 343.09 3503.13 3580.23 3068.38 3088.22 3070 .15 2916.15 -960.17 0.77 5950271.38 652685.80 N 70 16 16.083 W 148 45 54. 5151.19 54.56 342.73 3557.84 3634.94 3146.67 3166.52 3148 .43 2990.99 -983.18 1.08 5950345.73 652661.27 N 70 16 16.819 W 148 45 54.962 5246.91 53.89 341.18 3613.80 3690.90 3224.29 3244.17 3226 .09 3064.82 -1007.23 1.49 5950419.05 652635.72 N 70 16 17.546 W 148 45 55.662 5342.82 57.37 343.05 3667.94 3745.04 3303.41 3323.32 3305 .24 3140.15 -1031.51 3.97 5950493.87 652609.91 N 70 16 18.286 W 148 45 56.369 5438.36 58.31 343.73 3718.80 3795.90 3384.29 3404.20 3386 .08 3217.66 -1054.63 1.15 5950570.88 652585.22 N 70 16 19.049 W 148 45 57.043 5534.45 57.52 343.40 3769.84 3846.94 3465.70 3485.62 3467 .46 3295.74 -1077.66 0.87 5950648.47 652560.60 N 70 16 19.817 W 148 45 57.713 5629.03 57.66 342.60 3820.53 3897.63 3545.54 3565.46 3547 .29 3372.10 -1101.01 0.73 5950724.33 652535.70 N 70 16 20.568 W 148 45 58.393 5724.44 58.00 343.87 3871.33 3948.43 3626.30 3646.22 3628 .03 3449.43 -1124.30 1.18 5950801.16 652510.84 N 70 16 21.328 W 148 45 59.072 5819.94 57.05 344.87 3922.61 3999.71 3706.85 3726.79 3708 .53 3527.01 -1146.01 1.33 5950878.28 652487.55 N 70 16 22.091 W 148 45 59.704 5916.73 57.01 344.57 3975.28 4052.38 3788.04 3807.99 3789 .64 3605.34 -1167.41 0.26 5950956.15 652464.56 N 70 16 22.861 W 148 46 0.328 6011.19 56.23 344.80 4027.25 4104.35 3866.91 3886.87 3868 .43 3681.42 -1188.25 0.85 5951031.78 652442.18 N 70 16 23.610 W 14 8 46 0.935 6106.36 55.43 344.00 4080.71 4157.81 3945.64 3965.61 3947 .11 3757.26 -1209.42 1.09 5951107.17 652419.46 N 70 16 24.355 W 14 8 46 1.551 6202.01 54.98 343.63 4135.29 4212.39 4024.19 4044.16 4025 .63 3832.69 -1231.31 0.57 5951182.13 652396.03 N 70 16 25.097 W 14 8 46 2.189 SurveyEditor Ver SP 2.1 Bld( users ) A-44~A-44W-44~A-44 Generated 6/11/2009 1:37 PM Page 2 of 4 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft n ft ft ft ft de 00 ft ftUS ftUS Fi1U-y.U;i 5li.:iU :S4:i.41 41`JU. U4 4Lb/.14 41 V4.Lt5 41 L4.L4 41 VS.b`J JyVy.4y -l Lb4.V.S 1.3/ b`JSILbr5.4b bSCJ/l. /b IV /U lb Cb.iSbJ VV 14r54b L.rSbl 6393.42 58.61 343.61 4240. 82 4317.92 4183.84 4203.81 4185.24 3985.78 -1276.61 2.45 5951334.25 652347. 62 N 70 16 26.603 W 148 46 3.509 6488.90 58.07 344.61 4290. 93 4368.03 4265.11 4285.08 4266.46 4063.95 -1298.87 1.06 5951411.94 652323. 78 N 70 16 27.372 W 148 46 4.157 6584.12 57.61 345.51 4341. 62 4418.72 4345.69 4365.69 4346.98 4141.83 -1319.65 0.93 5951489.38 652301. 41 N 70 16 28.137 W 148 46 4.763 6679.73 57.39 345.16 4392. 99 4470.09 4426.30 4446.32 4427.51 4219.84 -1340.06 0.39 5951566.95 652279. 41 N 70 16 28.905 W 148 46 5.358 6774.89 56.61 344.50 4444. 82 4521.92 4506.09 4526.13 4507.24 4296.86 -1360.95 1.01 5951643.53 652256. 96 N 70 16 29.662 W 148 46 5.966 6871.10 56.14 344.29 4498. 10 4575.20 4586.20 4606.24 4587.31 4374.02 -1382.50 0.52 5951720.22 652233. 84 N 70 16 30.421 W 148 46 6.594 6966.78 56.42 344.21 4551. 21 4628.31 4665.78 4685.82 4666.85 4450.62 -1404.10 0.30 5951796.36 652210. 68 N 70 16 31.174 W 148 46 7.223 7063.13 56.66 344.57 4604. 33 4681.43 4746.15 4766.21 4747.19 4528.04 -1425.73 0.40 5951873.31 652187. 48 N 70 16 31.936 W 148 46 7.854 7157.46 56.48 344.17 4656. 30 4733.40 4824.87 4844.93 4825.87 4603.85 -1446.94 0.40 5951948.67 652164. 73 N 70 16 32.681 W 148 46 8.472 7253.48 55.92 344.37 4709. 72 4786.82 4904.66 4924.72 4905.63 4680.65 -1468.57 0.61 5952025.01 652141. 53 N 70 16 33.436 W 148 46 9.102 7349.27 55.15 344.09 4763. 92 4841.02 4983.63 5003.70 4984.57 4756.65 -1490.03 0.84 5952100.55 652118. 53 N 70 16 34.184 W 148 46 9.727 ~ 7444.33 54.85 344.10 4818. 45 4895.55 5061.50 5081.56 5062.41 4831.54 -1511.37 0.32 5952174.98 652095. 66 N 70 16 34.920 W 148 46 10. 7540.74 54.97 343.15 4873. 87 4950.97 5140.38 5160.45 5141.29 4907.23 -1533.61 0.82 5952250.19 652071. 89 N 70 16 35.665 W 148 46 10.997 7635.41 54.98 344.03 4928. 21 5005.31 5217.91 5237.98 5218.80 4981.59 -1555.51 0.76 5952324.09 652048. 47 N 70 16 36.396 W 148 46 11.635 7731.65 54.99 344.16 4983. 43 5060.53 5296.73 5316.80 5297.60 5057.40 -1577.11 0.11 5952399.43 652025. 33 N 70 16 37.142 W 148 46 12.265 7826.97 55.50 343.97 5037. 77 5114.87 5375.04 5395.11 5375.89 5132.70 -1598.61 0.56 5952474.27 652002. 30 N 70 16 37.882 W 148 46 12.891 7922.99 54.59 343.20 5092. 78 5169.88 5453.73 5473.81 5454.58 5208.19 -1620.85 1.15 5952549.29 651978. 53 N 70 16 38.624 W 148 46 13.539 8018.13 55.78 343.09 5147. 10 5224.20 5531.84 5551.92 5532.68 5282.94 -1643.50 1.25 5952623.56 651954. 36 N 70 16 39.360 W 148 46 14.199 8113.05 56.62 342.84 5199. 90 5277.00 5610.71 5630.79 5611.56 5358.36 -1666.61 0.91 5952698.48 651929. 72 N 70 16 40.101 W 148 46 14.873 8208.94 57.01 342.05 5252. 39 5329.49 5690.94 5711.04 5691.81 5434.87 -1690.81 0.80 5952774.48 651903. 96 N 70 16 40.854 W 148 46 15.578 8305.77 58.70 341.65 5303. 90 5381.00 5772.88 5793.03 5773.78 5512.77 -1716.35 1.78 5952851.84 651876. 83 N 70 16 41.620 W 148 46 16.323 8399.88 58.68 343.77 5352. 81 5429.91 5853.26 5873.43 5854.18 5589.54 -1740.25 1.92 5952928.09 651851. 38 N 70 16 42.375 W 148 46 17.019 8494.81 56.85 346.20 5403. 45 5480.55 5933.53 5953.72 5934.40 5667.08 -1761.07 2.90 5953005.18 651828. 99 N 70 16 43.137 W 148 46 17.626 8591.06 56.57 347.16 5456. 28 5533.38 6013.88 6034.18 6014.67 5745.37 -1779.60 0.88 5953083.07 651808. 86 N 70 16 43.907 W 148 46 18.166 8687.71 56.08 347.82 5509. 87 5586.97 6094.13 6114.61 6094.83 5823.89 -1797.03 0.76 5953161.22 651789. 84 N 70 16 44.679 W 148 46 18.674 8781.65 55.89 347.38 5562. 42 5639.52 6171.82 6192.47 6172.43 5899.94 -1813.75 0.44 5953236.90 651771. 57 N 70 16 45.427 W 148 46 19.162 8876.23 55.45 347.00 5615. 76 5692.86 6249.78 6270.58 6250.32 5976.10 -1831.06 0.57 5953312.69 651752. 70 N 70 16 46.176 W 148 46 19.666 8973.15 55.90 347.28 5670. 42 5747.52 6329.68 6350.62 6330.16 6054.13 -1848.88 0.52 5953390.34 651733. 30 N 70 16 46.944 W 148 46 20.186 9067.33 56.73 346.57 5722. 65 5799.75 6407.92 6428.98 6408.34 6130.47 -1866.61 1.08 5953466.29 651714. 02 N 70 16 47.694 W 148 46 20. 9163.18 56.74 345.29 5775. 23 5852.33 6488.00 6509.13 6488.38 6208.20 -1886.09 1.12 5953543.60 651692. 95 ~ N 70 16 48.459 W 148 46 21. 9259.68 55.75 343.43 5828. 85 5905.95 6568.23 6589.36 6568.59 6285.46 -1907.71 1.90 5953620.40 651669. 76 N 70 16 49.219 W 148 46 21.901 9355.65 54.77 342.69 5883. 54 5960.64 6647.08 6668.22 6647.45 6360.90 -1930.69 1.20 5953695.35 651645. 25 N 70 16 49.961 W 148 46 22.571 9450.57 52.16 341.84 5940. 04 6017.14 6723.32 6744.48 6723.70 6433.54 -1953.91 2.84 5953767.49 651620. 55 N 70 16 50.675 W 148 46 23.248 9546.16 50.91 343.46 5999. 50 6076.60 6798.14 6819.32 6798.54 6504.97 -1976.23 1.86 5953838.45 651596. 78 N 70 16 51.377 W 148 46 23.898 9641.14 47.96 345.15 6061. 26 6138.36 6870.28 6891.46 6870.67 6574.42 -1995.77 3.39 5953907.47 651575. 83 N 70 16 52.060 W 148 46 24.468 9737.16 44.95 345.69 6127 .41 6204.51 6939.84 6961.05 6940.20 6641.76 -2013.30 3.16 5953974.44 651556 .93 N 70 16 52.723 W 148 46 24.979 9832.42 40.61 345.57 6197 .31 6274.41 7004.49 7025.74 7004.82 6704.42 -2029.35 4.56 5954036.76 651539. 61 N 70 16 53.339 W 148 46 25.447 9928.14 37.31 345.70 6271 .73 6348.83 7064.63 7085.92 7064.95 6762.72 -2044.28 3.45 5954094.73 651523 .49 N 70 16 53.912 W 148 46 25.882 10022.87 35.01 346.29 6348 .21 6425.31 7120.48 7141.81 7120.77 6816.95 -2057.81 2.46 5954148.67 651508. 85 N 70 16 54.445 W 148 46 26.277 10118.19 31.60 345.40 6427 .86 6504.96 7172.77 7194.14 7173.04 6867.69 -2070.59 3.61 5954199.14 651495 .04 N 70 16 54.945 W 148 46 26.650 10213.66 29.18 345.99 6510 .21 6587.31 7221.04 7242.43 7221.29 6914.49 -2082.53 2.55 5954245.68 651482 .15 N 70 16 55.405 W 148 46 26.998 SurveyEditor Ver SP 2.1 Bld( users) A-44W-44W-44W-44 Generated 6/11/2009 1:37 PM Page 3 of 4 Measured Azimuth Venial Along Hole NS EW Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True Narth True North ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS I u3va.u / 10404.21 10500.80 10596.07 10691.52 10787.69 10882.25 10978.38 11073.55 11166.50 11260.22 11353.53 11447.16 11540.73 11633.12 11729.31 11824.40 11920.91 12015.67 12110.55 Gb .V/ 34J.1 I bJ~4 ./3 bb/ 1. 233 /LbJ. LJ /L60. b/ /LbJ.4`J b`JJ/.3L -LVy3.bJ 3.Ly b954LtSt5.'L25 22 .44 345.83 6681 .46 6758. 56 7304. 31 .7325. 74 7304.54 6995.15 -2103.38 3.83 5954325.89 17 .81 345.14 6772 .13 6849. 23 7337. 51 7358. 97 7337.74 7027.32 -2111.68 4.80 5954357.88 14 .09 345.30 6863 .71 6940. 81 7363. 68 7385. 14 7363.90 7052.62 -2118.36 3.90 5954383.04 10 .36 348.30 6956 .98 7034. 08 7383. 86 7405. 35 7384.06 7072.27 -2123.05 3.96 5954402.59 7.71 353.75 7051 .95 7129.05 7398.83 7420. 44 7399.03 7.83 350.43 7145 .64 7222.74 7411.47 7433. 22 7411.66 7.24 348.74 7240 .94 7318.04 7424.01 7445. 82 7424.18 7.01 346.89 7335 .38 7412.48 7435.79 7457. 62 7435.95 6.93 346.61 7427 .64 7504.74 7447.05 7468. 90 7447.21 6.76 347.47 7520 .69 7597.79 7458.20 7480. 07 7458.36 6.70 348.63 7613 .36 7690.46 7469.10 7491. 01 7469.25 6.72 348.84 7706 .35 7783.45 7480.00 7501. 95 7480.15 7.27 349.30 7799 .22 7876.32 7491.35 7513. 34 7491.48 6.77 349.15 7890 .92 7968.02 7502.59 7524. 63 7502.72 7.19 351.06 7986 .40 8063.50 7514.20 7536. 32 7514.32 7.02 351.33 8080 .76 8157.86 7525.86 7548. 08 7525.98 6.12 349.67 8176 .63 8253.73 7536.82 7559. 13 7536.93 5.58 351.24 8270 .90 8348.00 7546.42 7568. 78 7546.52 5.48 348.54 8365 .34 8442.44 7555.50 7577. 93 7555.60 7087.16 -2125.51 7099.81 -2127.27 7112.21 -2129.54 7123.75 -2132.03 7134.73 -2134.62 7145.61 -2137.12 7156.31 -2139.39 7167.04 -2141.52 7178.23 -2143.68 7189.32 -2145.79 7200.84 -2147.79 7212.46 -2149.60 7223.35 -2151.41 7232.87 -2153.01 7241.87 -2154.62 7245.55 -2155.32 7250.30 -2156.21 7257.55 -2157.66 7264.47 -2159.08 7271.18 -2160.45 7278.00 -2161.50 7284.91 -2162.14 2.89 5954417.42 0.49 5954430.04 0.66 5954442.39 0.34 5954453.87 0.09 5954464.79 0.21 5954475.62 0.16 5954486.27 0.03 5954496.95 0.59 5954508.10 0.54 5954519.14 0.50 5954530.61 0.18 5954542.20 0.95 5954553.05 0.59 5954562.53 0.29 5954571.50 12151 .64 4.98 349.81 8406.26 8483. 36 7559.23 7581.67 7559.33 7" ~ 12214'md 12209 .78 4.56 349.05 8464.19 8541. 29 7564.04 7586.51 7564.13 12305 .63 4.29 348.33 8559.76 8636. 86 7571.41 7593.90 7571.50 12401 .70 4.14 348.43 8655.57 8732. 67 7578.45 7600.96 7578.53 12496 .66 4.13 348.45 8750.28 8827. 38 7585.27 7607.81 7585.35 12592 .50 4.14 354.11 - 8845.87 8922. 97 7592.11 7614.71 7592.19 12688 .35 4.16 355.19 8941.47 9018. 57 7598.92 7621.65 7599.00 1.25 5954575.16 0.73 5954579.89 0.29 5954587.11 0.16 5954594.00 0.01 5954600.68 0.43 5954607.48 0.08 5954614.37 Last Survey 12720.13 4.10 353.81 8973.17 9050.27 7601.17 7623.94 7601.24 7287.19 -2162.36 0.37 5954616.64 TD (Projected) 12775.00 4.10 353.81 9027.90 9105.00 7605.03 7627.86 7605.10 7291.09 -2162.79 0.00 5954620.53 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) fftUSl Easting (X) fftUSl Surface : 2223 FSL 1704 FEL S35 T11 N R13E UM 5947375.66 653705.23 BHL : 4234 FSL 3860 FEL S26 T11 N R13E UM 5954620.53 651394.23 ti514/U."1S N /U 16 bb.8Z6 W 148 461/.319 651459.67 N 70 16 56.198 W 148 46 27.605 651450.71 N 70 16 56.514 W 148 46 27.848 651443.51 N 70 16 56.763 W 148 46 28.042 651438.42 N 70 16 56.956 W 148 46 28.179 651435.66 N 70 16 57.103 W 148 46 28.251 651433.64 N 70 16 57.227 W 148 46 28.302 651431.12 N 70 16 57.349 W 148 46 28.369 651428.39 N 70 16 57.463 W 148 46 28.441 651425.58 N 70 16 57.571 W 148 46 28.517 651422.86 N 70 16 57.678 W 148 46 28.590 651420.37 N 70 16 57.783 W 148 46 28.656 651418.02 N 70 16 57.888 W 148 46 28.~ 651415.63 N 70 16 57.998 W 148 46 28. 651413.30 N 70 16 58.108 W 148 46 28.843 651411.06 N 70 16 58.221 W 148 46 28.901 651409.02 N 70 16 58.335 W 148 46 28.954 651406.99 N 70 16 58.442 W 148 46 29.006 651405.19 N 70 16 58.536 W 148 46 29.053 651403.40 N 70 16 58.624 W 148 46 29.100 651402.62 651401.64 651400.04 651398.48 651396.97 651395.79 651395.00 651394.73 651394.23 N 70 16 58.661 W 148 46 29.121 N 70 16 58.707 W 148 46 29.146 N 70 16 58.779 W 148 46 29.189 N 70 16 58.847 W 148 46 29.230 N 70 16 58.913 W 148 46 29.270 N 70 16 58.980 W 148 46 29.301 N 70 16 59.048 W 148 46 29.320 N 70 16 59.070 W 148 46 29.326 N 70 16 59.108 W 148 46 29.338 u SurveyEditor Ver SP 2.1 Bld( users) A-44W-44W-44W-44 Generated 6/11/2009 1:37 PM Page 4 of 4 ~ ~~-~ . 1~C:3ANZCAL ~N'~`~~ R~ORT - -. ?UD DA~~ : .~~~ ""O~l OPER ~ FIELD ~~ ~ ~ry hOcc ~JG-`4 M + ~ I ~.~ ~ NUI~ER I~ - ~-~LL ~AS4 Tv: ~~~~_ ~, \b S Tvn.; ~ sTn : ~a~~ \ ~ ~~ t Tvi3 ca$in~ : ' '-~ ~ V1 ~ shoe : `~a~ tin ~~ : ~~ : ~ ~ ~. ~ A :~v-~ .^. - :.:~.:~er : `-~`~ i` shoe : ~aah`~Mn ~~~~ITVC : ZCP : ~~~~ C6~i ~ ""~ ______. _abi:~g: i-11~~-~ Packer ~ ~~'S~'M~3 TvD; met sr 70`l~ ~rrr~~ w..r.r..+.. ~.^'.~ :ale S{ze ~'~`'l anc ~~~~5" i Perfs l~(~`tC~ to 1a~~1~ ~aZcrs ~~~cRTTy - ?ART #~ . Aanuius~ S rasa Test: 1.~' ~~ t Gotmaae~ts : ~~~~ S~~~~\~~~ rv ~~~ ' ~y~~~ ~ *~fECgAI~IIC~I,. XNTEG~RI1'F -PART # Z 3~~b~ ~~ ~ Gemenz Volumes r Amt. i.iaer 23 ~~, ~ -- - Csg O~„~~~.. ~ . Cmt sol to cover pes.;.s ~~~,\ s~~~ -- --,..,:.,~,,.,~. \ ~~t . - ~; Theoretical IOC c..on ~• ~~`~ ' ~ •~~~5 ia~ -O~ Ctmeac Soad Log tYea or rIo) ~:5 In AOGCC File ~~C~~, C9L Evaiuatio~tt, cone above perfs 1~~~ ~~~~~~;Q~....S~y~~? ~~. .. . FroduCtion Log: Type _ z Evaluatiau ' - CONCLUSit3NS srt ~ 3 ~~ vJGS R.~. M ^ L '~'~ 5 ~~~-~ `tOC~~~~ w~~ M~~'- ~ ~ F, rS ~~~1~~~ 06/08/09 i ~~ i~ )~.,i~, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # NO.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Color CD H-35 AYTO-00018 CROSS FLOW CHECK ` 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE °--' r 05/15/09 1 1 06-08A AV1H-00012 IBP/FBS/CFS/GRADIO/PRESS/T P - 05/11/09 1 1 A-44 AWLS-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP q 05/17/09 1 1 H-29A AYOO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK , 05/06/09 1 1 15-456 ANHY-00010 PRODUCTION PROFILE %}~ 05/09/09 1 1 13-13A AYTU-00033 USIT r ~ / ~ 05/08/09 1 1 M-196 AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A BiJJ-00018 MEM CNUSTP f 05/18/09 1 1 X-30A B2WY-00005 MEM PROD PROFILE C 05/10/09 1 1 12-23 AYKP-00021 USIT L - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE - 05/19/09 1 1 Z-146 AZCM-00022 PROD PROFILE/JEWELRY LOG ~ (o- 05/20/09 1 1 L1-21 B2NJ-00006 PRODUCTION PROFILE - 05/24/09 1 1 A-31A AZCM-00023 USIT Z - Q {~ L 05/22/09 1 1 H-19B' 62WY-00004 MEM PROD PROFILE L 05/07/09 1 1 G-16 AYKP-00022 SCMT / J - 05/09/09 1 1 M-19B AY3J-00024 SCMT - 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE _ [/Ca / 04/21/09 1 1 11-04A AYQO-00028 USIT / L/ _ 05/21/09 1 1 18-30 BiJJ-00015 MEM PROD PROFILE jG/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ - l 05/11/09 1 1 3-37/L-35 AWL9-00035 e PROD/INJECTION PROFILE 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL t~ /~(,'S 04/26/09 1 1 PLEASt AGKNUWLtUGt Fitl;tlY1 tfT SIGNING ANU F{tl VFSNING VNC GVYT CHI.n I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 r ~_ MEMORANDUM TO: Jim Regg f P.I. Supervisor (.1' 7~ZZ,,(j~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC A-44 PRUDHOE BAY iJNIT A-44 Src: Inspector Reviewed By: P.I. Suprv ~~'- NON-CONFIDENTIAL Comm __. Well Name: PRUDHOE BAY UNIT A-44 Insp Num: mitCS090606074903 Rel Insp Num: API Well Number: 50-029-23412-00-00 Inspector Name' Chuck Scheve Permit Number: 209-041-0 ~ Inspection Date: 6/5/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A-aa Type Inj. ~' TVD 8288 IA zao zsoo 2a~o za~o P.T.D 2090410 TypeTest SPT Test psi 2072 OA I50 370 340 340 Interval ~T^L ~ P/F P ~ Tubing 160 160 160 160 Notes: Pretest pressures observed and found stable. Wednesday, June 10, 2009 Page 1 of 1 E ~ ~ L SARAH PALIN, GOVERNOR AI.ASSA OITi A1~D GAS ;~ 333 W. 7th AVENUE, SUITE 100 C01~5ER~"ATIOI~T COrzdIISSION ~ ANCHORAGE, ALASKA 99501-3539 /~ PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-44 BP Exploration Alaska Inc. Permit No: 209-041 Surface Location: 2224' FSL, 1704' FEL, SEC. 35, T11N, R13E, UM Bottomhole Location: 4313' FSL, 3852' FEL, SEC. 26, T11N, R13E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cathy . Foerster Commissioner DATED this ~s day of March, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~~""~ ,~2 ALASI~IL AND GAS CONSERVATION COMMI~N 3'-~ D~ PERMIT TO DRILL ,~-3~~~..\ ~p~ 1 `~~~ 20 AAC 25.005 ~r_.~., ~;, ~, roc f`nn±~ C~mmiss1011 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. pecify if w i ~( ed for: ^ Coalbed N~YTeGas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Boni No. 6194193 11. Well Name and Number: PBU A-44 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12718' TVD 9066' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: k 2224' FSL 1704' FEL SEC 35 T11 N R13E UM A St d 7. Property Designation: ADL 028286 Oil Pool , , , , ( s- a e ) . , Top of Productive Horizon: 4024' FSL, 3788' FEL, SEC. 26, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 15, 2009 Total Depth: 4313' FSL, 3852' FEL, SEC. 26, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 23,465' 4b. Location of Well (State Base Plane Coordinates): Surface: x-653705 y-5947376 Zone-ASP4 10. KB Elevation (Height above GL~'lan 75.5' feet 15. Distance to Nearest Well Within Pool: 1,357' 16. Deviated Wells: Kickoff Depth: 200 feet Maximum Hole An le: 56 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3142 Surface: 2291 i r m:' i n- T in -B m n' rs Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 2 1.5# A- 3 W Id 80' urface S 80' 2 sx Ar i A rox. 12-1/4" 9- / " 40# L-80 BTC 4255' S rface Surf 4255' 3050' 24 Bbls De Cre e 4 Bbl Clas ' 4" 7" -I 7 ' 8- /4" 7" 26# L-80 BTC-M 6447' 7 0' 12202' 8480' 207 B Is i rete 38 Bbl I s ' ' 6-1/ " 4-1/2" 12. -8 Vam T 6 1 2' 1271 1 B Is la s' ' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrilf and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD` TVD Conductor /Structural Surface Intermediate Pr i n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foreg~ig is true and correct. Contact Joshua Mallery, 564-5545 Printed Name Gr o Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date Terrie Hubble, 564-4628 Commission Uae Onl Permit To Drill N tuber: 0~0 Off/ API Number: 50-Q,?9a3~laooOO Permit A pr See cover letter for a . d°~' h rr ire n Conditions of Approval: ~ \"'t' ~ t~,~~~~y ~4~~'~~~p~ ~ I,~-~v~~d ~QcC~ C~S`'~~c+.C~ ~/ /~`~~ If box is checked, well may not be used to explore for, tes , or produce coalbed methane, gas hydrates, or gas contained shales: ~',®~~ QS° ~f~~5~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ,^,( Yes L~No s~~d S`~ •k~ ^~ J°'~'~'''i'~G`'~~~~~ ~5~ HZS Measures: [Yes ^ No ~S Directional Survey Req'd: eu Yes ^ No Other. ~~~ ~ C~ \ GC~~c.~b~C "~©, ~ ~ Q ~ L~-S.l ~~ \~~ R U APPROVED BY THE COMMISSION Date 3 ~~' ~ / ,COMMISSIONER Form 10-401 Revised 12!2005 Submit In Duplicate ~ ~ r To: Alaska Oil & Gas Conservation Commission From: Joshua Mallery, ODE Date: March 18, 2009 Re: A-44 Grassroots Permit to Drill A-44 is planned as a slant, ultra-slim hole design grassroots well to Ivishak Zone 2 and Zone 4. Nabors Rig 7ES will move onto location around April 15th, 2009. The 12-1/4" hole will be drilled to the topmost, competent shale of the SV3 where the 9-5/8" surface casing will be run and cemented. An 8-3/4" hole will be drilled to the top of the Sag River and a 7" TC II x BTC- M casing string will be run to surface, with the top of cement 1000' from the surface shoe. A 6- 1/8" production hole will be drilled to the bottom-hole target at approximately 12,718'. A 4-1/2" production liner will have 150' overlap into the 7" liner. The production liner will be cemented to the liner top. The production tubing will be 4-1/2" 12.6#, L-80. Post rig operations include installing the well house, flowline, and perforating on a-line. Please note the following Well Summary as detailed on the next few pages: A-44 Permit to Drill Application Page 1 Planned Well Summary~ Well A-44 Well Grassroots Target Zone Z2 T e Injector Ob'ective and Z4 API Number: TBD Current Status A-44 is a new well Estimated Start Date: 15-A r-2009 Time to Com lete: 24 Da s Surface Northin Eastin Offsets TRS Location 5,947,375 653,706 3057' FNL / 3577' FWL 11 N, 13E, 35 Northin Eastin TVDss Offsets TRS Target 5,954,412 651,470 -6,980 1255' FNL / 1491' FWL 11 N, 13E, 26 Locations 5,954,625 651,420 -8,500 1041' FNL / 1446' FWL 11 N, 13E, 26 Bottom Northin Eastin TVDss Offsets TRS Location 5,954,700 651,400 -8,990 966' FNL / 1428' FWL 11 N, 13E, 26 Planned KOP: 200'MD Planned TD: 12,718'MD 125' TVDss 8,990' TVDss Ri Nabors 7ES GURT: 47'/28.5' RTE: 75.5' Directional - Schlumberger P5 KOP: 200' MD Maximum Hole Angle: 57° in the 12-1/4" grassroots section 57° in the 8-1/2" intermediate section 9° in the 6-1 /8" roduction section Close A roach Wells: D-08 is a close approach well in the production section. Reference A/C Scan Surve Pro ram: MW D Standard + IFR /Cassandra / MS Nearest Pro a Line: 23,465' to the nearest ropert line Nearest Well within Pool: 1357' to A-29 BHL Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Joshua Mallery 564-5545 Cole Abel 564-5576 Nancy Hibbert 564-5672 E-mail Joshua.Mallery @ bp.com Cole.Abel @bp.com Nancy.Hibbert @bp.com A-44 Permit to Drill Application Page 2 Formation Markers A-44 (B~ on SOR) Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation (TVDss) (eet) (Yes/No) (Psi) (ppg EMW) BPRF -1950 50 No SV4 -2680 30 No SV3 -3030 30 No SV2 -3204 30 No SVl -3600 30 No UG4 -4080 30 No UG3 -4335 30 No UGl -4840 50 No WS2 -5385 30 No WSl -5650 30 No CM3 -5845 50 No CM2 -6300 50 No CMl' -6975 50 No THRZ -7230 30 No BHRZ -7440 30 No LCU -7455 30 No TJF -7620 30 No TJE -7720 30 No TJD -8015 30 No TJC -8175 30 No TJB -8325 30 No TSGR -8480 30 Yes 3131 7.1 TSHA -8510 30 Yes 3142 7.1 TSAD -8585 30 Yes 3170 7.1 45SB -8635 30 Yes 3188 7.1 42SB -8710 3216 7.1 TCGL -8785 30 Yes 3243 ~• 1 BCGL -8850 30 Yes 3267 ~• 1 23SB -8940 3301 7.1 HO/T -8955 20 N/A 3306 7.1 PTD -8990 SSTVD OOWC (Pro'ected) -9005 20 N/A 3325 7.1 Wells within a ~/a mile of this infection well, scanned from the top of the reservoir to TD Well Name Distance (ft) Annulus Integrity Comments D-08 491' P&A'd and Sidetracked to D-08A, 2155' NNE of A-44 D-31 435' P&A'd and Sidetracked to D-31 A, 2710' NE of A-44 Both D-08 and D-31 have been P&A'd above the top production interval TVD depth. Planned Casinq/Tubinq Program x Hole Size C;sg / Tb T O.D. Wt/Ft Grade Conn Burst (si) Collapse (si) Length Top MD /TVDss Bottom MD /TVDss 42" 20" Insulated 91.5# A-53 Weld 80' GL 80'/80' 12-1/4" 9-5/8" 40# L-80 BTC 5,750 3,090 4,255' GL 4255' / 3050' 8-3/4" 7" 26# L-80 TC-II 7,240 5,410 5755' GL 5755' / 3880' 8-3/4" 7" 26# L-80 BTC-M 7,240 5,410 6447 5755' / 3880' 12202' / 8480' A-44 Permit to Drill Application Page 3 6-1/8" 4 ~/z" 12.6# -80 Vam To 8,430 7,500 6' 12052' / 8332' 12718' / 8990' Tubin 4 ~/z" 12.6# L-80 Vam To 8,430 7,500 12052' GL 12052' / 8332' Mud Proaram Surface Mud Pro erties: DRILPLEX AR 12-1/4" hole section Depth Interval Density (ppg) LSYP (2x3) YP API FL Chlorides MBT PH -6r m m I 0' - 2,284' 8 8 - 9 2 40-60 50-70 NC - 8 <1000 NC 10 - 11 ~BPRF 2,284' - 4,255' g 2 - 9 5 30-50 45-60 NC - 8 <1000 NC 10 - 11 --BPRF - SV3 Intermediate Mud Pro erties: LSND 8-3/4" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH 4,255 - 10,939' (Surface shoe 8.8-9.0 12 - 18 18 - 24 <6.0 N/C <15 9-10 to THRZ 10,939'-12,202' ~g 7 12 - 22 18 - 28 4 0 - 6.0 < 10.0 <18 9-10 THRZ - Sa . Production Mud Pro erties: FLO-PRO SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densit PV YP LSVR API FI H MBT 12202'-12718' 8.5 6-12 22-28 >20,000 6-8 9.0-9.5 <3 Loaaina Proaram 12-1/4" Surface• Surface Gyro until MWD surveys are clean. Drilling: Dir/GR/Res/ Open Hole: None Cased Hole: None 8-3/4" Intermediate: Drilling: Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/Neutron-Densit /ABI Open Hole: None Cased Hole: GR/SCMT in PDC mode to surface A-44 Permit to Drill Application Page 4 Cement Program Casin Size: 12-1/4" OH x 9-5/8" 40#, L-80 Surface Casin Lead: [Volume of -80' of cased hole] + [Volume of 971' of open hole + 40% excess ]+ [Volume Basis: of 2204' of open hole in permafrost + 250% excess] Lead TOC: Surface Tam Port collar if necessa Tail: Volume of 1000' of o en hole + 40% excess + 80' shoe track Total Cement Spacer 50 bbls of Viscosified Spacer weighted to 10.5 ppg (Mud Push II) Volume• Lead 524.2 bbls, 2943.4 cuft, 615 sks 10.7 Ib/ al Dee Crete + adds - 3.85 cuft/sk Tail 84.2 bbls, 473 cuft, 411 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Tem BHST = 71 ° F, BHCT TBD b Schlumber er Casin Size: 8-3/4" OH x 7" 26#, L-80 Intermediate Casin Basis: Lead: [Volume of --6,947' of open hole + 30% excess] Lead TOC: 5,255' MD 1000' below surface shoe Tail: [Volume of 1000' of open hole + 30% excess] + 80' shoe track Total Cement Volume• Spacer 30 bbls of Viscosified Spacer weighted to 10.5 ppg (Mud Push II) Lead 207.2 bbls, 1163 cuft, 350 sks 11.0 Ib/ al Lite Crete + adds - 3.33 cuft/sk Tail 37.9 bbls, 213 cuft, 184 sks 15.8 Ib/ al Class G + adds -1.16 cuft/sk Tem BHST = 198° F, BHCT TBD b Schlumber er Casin Size 6-1/8" OH x 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: [Volume of open hole + 40% excess] + 80' shoe track + 150' of liner lap + 200' of 7" x 4" DP excess. Tail TOC: 11,852' MD 0200' above Liner Top) Total Cement Volume• Spacer 20 bbls of Viscosified Spacer weighted to 10.5 ppg (Mud Push II) Lead N/A Tail 17.8 bbls, 100 cuft, 85.5 sks 15.8 Ib/ al Class G + adds -1.17 cuft/sk Tem BHST = 205° F, BHCT TBD b Schlumber er A-44 Permit to Drill Application Page 5 Surface and Anti-Coll~n Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface A-42 to the north and A-21 to the south are nearest at 35' centers. Close Approach Wells: The P&A D-08 wellbore fails major risk criteria. The A-44 well path in the production section has the closest approach of 423' at 12,715' MD. Hydrogen Sulfide A-Pac esignated as an N25 site. Recent F Well #1 Closest SHL Well H2S Level A-21 #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility A-42 data trom the 20 St ~~ Is as tollows: 10/1/1999 8/10/1998 A-28 13 m 4/22/2008 A-07 10 m 1/20/2008 6/4/99 and A-43 and A-37 400 m 3/17/98 In the past 5 years the highest recorded H2S level on A- Pad was 190 ppm at well A-29 Other Relevant H2S Data (H2S alarms from rigs, etc.) Faults The A-44 wellpath is expected to intersect one possible fault in the intermediate section. Possible Fault 1 (15'-20') has a planned intersection in CM3 C~ 6,222' TVDSS Other faults in the area: Fault A on the south side of the target polygon can be penetrated above the target interval in the Kingak if the well drops below the planned trajectory profile. Well Control 12 1/4" hole will be drilled with diverter. The 8 3/4" intermediate hole and 6 1/8" will use well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. Based upon calculations below, BOP equipment will be tested to 4,000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, ROPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3131 si ~ 8480' TVDss 7.1 EMW Maximum surface ressure 2283 si .10 si/ft as radient to surface Kick tolerance 53.1 bbls with an 12.0 ppg LOT assuming 9.2 ppg reservoir, 4" DP and 8.8 MW Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface ressure Inte rit Test - 8-3/4" hole LOT after drillin 20' from middle of window. A-44 Permit to Drill Application Page 6 Production Interval Maximum antici ated BHP 3142 si @ 8510' TVDss 7.1 EMW Maximum surface ressure 2291 si .10 si/ft as radient to surface Kick tolerance Infinite with an 8.8 ppg FIT assuming 7.1 ppg reservoir, 4" DP and 8.5ppg MW Planned BOP test pressure Rams test to 4,000 psi/250 psi. Annular test to 2,500 si/250 si 7" Casin Test 4000 si surface ressure Inte rit Test - 6-1/8" hole FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 6.8 Diesel Variance Requests: • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. While the flow paddle is removed from the flow line, PVT alarms will be used and the pit levels accurately monitored for any pit gain. Also, a visual check will be made during connections by looking down the riser to ensure the well is not flowing. After returned debris that could plug the flow line diminishes the flow paddle will be reinstalled. Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. A-44 Permit to Drill Application Page 7 ~'~Hazards and Conting~`ici POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. Within the production interval the Sag River reservoir is expected to be pressured to 7.1 ppg EMW; Pressures can be anticipated to reach 9.2 ppg EMV in the Cretaceous. 4000 psi test pressure is in accordance with injection well casing tests. II. Lost Circulation/Breathing A. The A-44 wellpath is expected to intersect one possible fault in the intermediate section. Possible Fault 1 (15'-20') has a planned intersection in CM3 C~3 6,222' TVDSS. B. Lost circulation events in the area have been a problem. Severe lost circulation events have happened in the production hole sections. A-30A production hole being the largest volume lost at 107,489 bbls. III. Kick Tolerance/Integrity Testing A. Kick Tolerance Hole Section Fracture Gradient at weak oint ( ,) Kick Tolerance (bbls) Intermediate Assuming 12.0 from LOT 53.1 Production Assumin 8.8 from FIT Infinite B. Integrity Testing Test Point Test De th Test t 9 5/8" shoe 20-ft minimum from the 9 5/s" shoe LOT 7" shoe 20-ft minimum from the 7" shoe FIT IV. Stuck Pipe A. There are differential sticking tendencies across the Kingak in the intermediate section and within the under-pressured production section. Keep the pipe moving and follow Stuck Pipe Prevention Procedures while drilling and running the 7" casing in this interval of the well. VI. Hydrogen Sulfide A. A-pad did record an H2S reading of 400 ppm as recently as 6/4/99 (see below), A-Pad is considered an H2S pad, therefore, the Standard Operating Procedures for H2S precautions should be followed at all times. Please review this document to confirm compliance. #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) A-21 20 m 10/1/1999 A-42 5 m 8/10/1998 A-28 13 m 4/22/2008 A-07 10 m 1/20/2008 6/4/99 and A-43 and A-37 400 m 3/17/98 In the past 5 years the highest recorded H2S level on A- Pad was 190 ppm at well A-29 A-44 Permit to Drill Application Page 8 VII. Faults A. The A-44 wellpath is expected to intersect one possible fault in the intermediate section. Possible Fault 1 (15'-20') has a planned intersection in CM3 @ 6,222' TVDSS B. Other faults in the area: Fault A on the south side of the target polygon can be penetrated above the target interval in the Kingak if the well drops below the planned trajectory profile. VIII. Anti-Collision Issues A. The P&A D-08 wellbore is a close approach concern. The A-44 well path in the production section has the closest approach of 423' at 12,715' MD. CONSULT THE A-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION A-44 Permit to Drill Application Page 9 Operations Summary Current Condition and history: / This is a grass roots well. Scope Pre-Rip Operations: 1. Install 20" conductor casing. 2. Weld an FMC landing ring to for the FMC Gen 5/5A wellhead, on the conductor. 3. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MI/RU Nabors 7ES. 2. Nipple up the diverter spool and riser. P/U sufficient length of 4" drill pipe to TD the surface hole and stand back in the derrick. 3. M/U a 12-'/a" drilling assembly with Dir/GR/Res. Spud and directionally drill surface hole to the base of the permafrost. Gyro data will be required until clean surveys can be taken 0500). Circulate and condition hole. Short trip to the top of the heavy weight drill pipe and/or trip for a new bit if necessary. 4. RIH and drill the remainder of the surface hole to the .planned surface hole TD in a shale member of the SV3 sand at approximately 4,255' MD (3050' TVDSS). Circulate and condition hole. Wiper trip to base of permafrost. POOH and UD BHA. 5. R/U, run, and cement the 9-5/8', 40# casing back to surface. A TAM port collar (preferably metal-to- metal) may be run as a contingency if hole conditions indicate a problematic primary cement job. Test 9-5/8" casing to 3500psi on plug bump. (NOTE: Efforts to ensure the final TOC is within 3' of surface will be required.) 6. N/D diverter and the riser spool and N/U the FMC casing head and tubing spool. Test as necessary. 7. N/U the BOPE and test to 4,000 psi. 8. MU 8-3/a' drilling assembly with Dir/GR/Res and RIH. Pick up 4" drill pipe as necessary 9. Drill out cement, float equipment, and the shoe. Displace the well to 8.8 ppg LSND drilling fluid. 10. Drill approximately 20' new formation and perform the planned LOT. 11. Drill ahead, according to directional proposal, to 100' above the HRZ. 12. Increase mud weight, via spike fluid, to 9.7 ppg per the Kingak/HRZ polar plot. 13. Drill according to directional plan to intermediate TD approximately 5' MD below the top of the Sag. Circulate bottoms up as necessary for sample collection to properly identify shale/siltstone cap. 14. Condition hole as necessary and POOH. 15. R/U, run, and cement the 7", 26# intermediate casing. (Note: Original plan is to set casing with a mandrel hanger. If hole conditions indicate problems getting casing to bottom, the casing will be hung on emergency slips instead. Also, the planned TOC will be 1000' below the surface casing shoe.) Test Casing at plug bump to 4,000 psi. 16. Install casing pack-off and test per FMC representative. 17. Confirm that the OA is open by moving small volumes of mud down the annulus as soon as possible after the cement job. Freeze-protect the 9 5/e" x 7" annulus, once the cement has reached 500 psi compressive strength. Ensure that the mud/diesel/brine in the OA is overbalanced to formation at the 9 5/e" shoe. 18. M/U a 6-%a" drilling assembly with Dir/GR/Res/ADN. RIH, P/U additional 4" drill pipe as required. 19. Displace the well to 8.5 ppg Flo-Pro SF fluid. 20. Drill out shoe and 20' of new formation and perform an FIT. 21. Drill ahead, per directional proposal and rig site geologist, to well TD. 22. Condition the hole as required in preparation of running and cementing the 4-'/z" production liner. If necessary, spot liner running pill on bottom. POOH, UD excess 4" drill pipe, and UD BHA. 23. R/U and run the 4'h", 12.6#, L-80, IBT-M liner. CBU at 7" shoe and TD as necessary. Cement the liner per Dowell program. Release from the liner and set the packer. Circulate excess cement to surface. A-44 Permit to Drill Application Page 10 24. Displace the well to seav~ldCer above the liner top. POOH UD drill pi~VD and inspect liner running tools. RIH with any remaining DP stands in derrick and VD. 25. Run SCMT in the 4-1/2" production liner and 7" intermediate casing as required to confirm cement bond/isolation. 26. R/U and pressure test the casing x liner string to 4,000 psi for 30 minutes. Record the test. Notify the state of pressure test 24 hours in advance of test. (Note: Test after 500psi compressive strength has been achieved.) 27. R/U and run a 4-'h", 12.6#, L-80, Vam Top completion. Space and land the tubing with the tubing tail inserted into the liner tie back sleeve. RILDS. 28. Reverse circulate filtered seawater, corrosion inhibitor and diesel freeze protect into the tubing x casing annulus. 29. Drop ball/rod and set packer. 30. Individually test the tubing and annulus to 4,000 psi for 30 minutes. Record each test. 31. Install TWC and test. 32. N/D the BOPE. 33. N/U the adapter flange and tree. Test tree and adapter to 5,000 psi. 34. RU DSM. Pull TWC. 35. Install a BPV, then the VR plugs in the annulus valves. 36. Secure, rig down and move off. Post-Rig Operations: 1. MI / RU slick line. Pull the BPV. Pull the ball and rod / RHC plug from landing. nipple below the production packer. 2. E-Line pert well. 3. Install the well house, instrumentation, and flow line. Estimated Spud Date: 4/15/2009 A-44 Permit to Drill Application Page 11 KB. ELEV = 75.5 BF. ELEV = 28.5 KOP = 425' Max Angle = 7 DEG ~ 2306' Datum MD = 12575' DatumTVD= 8800' Proposed TOC 5255' (top SV1) Minimum ID = 3.725" ~ 12,042' 4-112" HES XN NIPPLE 412", 12.61fft, L-80, TGII, ID= 12,052' 3.958" PERFORATION SUMMARY (TBD) REF LOG: A NGLE AT TOP PERF: Note: Refer to Production DB for historical perf data S¢E SPF INTERVAL OpNSgz DATE -108' 20", 215.51, A-53, Insulated Conductor -2200' HES 4-1 /2 'X' Landing Nipple; ~ = 3.813" 4,255' 9-518", 40 #/tt, L-80, BTC, ID = 8.835" GAS LI FT MANDRELS (412" x 1" KB MG) ST MD TVD DEV TYPE VLV LATCH PDRT DATE 11,982' HES 4-12" X NIPPLE I.D. 3.813" 12,002' BAKER PKR 7" X 4-12" S-3, ID = 3.88", 12' TBS 12,022' HES 412" X NIPPLE ID = 3.813" 12,042' HES 4-1/7' XN NIPPLE ID = 3.725" WELLHEAD = FMC Gen 5 CSG HEAD = 11" 5M W% T' MANDREL HANGER & PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER= 11" X 412" ADP FLANGE= 11"X41/16" 12,052, 7" x 4-1/2" Baker Flex-Loc Liner Hanger (ID X2.992") w/ ZXP Liner Top Pkr w! 12' TBS (ID = 5.25") 12,202' ID = 6.276" to 12,838' 4-1/2" PBTD 12,718' 4-1/2", 12.6#, L-80, IBT-M, ID = 3.958", 0.01522 BPF DWTE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/02108 JEM INITIAL WELL: A-44 PERMIT No: API No: 8P 6cploration (Alaska) A ~,~4 Proposed 0 z o a ~ -N- 11°0 ~ '~ ~~I , ' ti GC-1 ~ ^ ] C-PAD ~ Si ~ ~; D-PAD '~ -N-~ ~ ~ `~ ~ ~ f _ b, ~ ~; ,~~~ ~. . i ~ ~ ~ ~ . GC-3 q ~ ~a u ~ PROJECT ~ '°°<; B-PAD ~~ ~ ~ `~A-PAD.' ~ ~ ~~ ~ v ~~ o l ?© % .e ~ ..~ ~ i ~ I ~,e ,`` _ r ~ o ;- o ~trA,J li VICINITY MAP N.T.S. A- 44 A-PAD NOTES: 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. 2. BASIS OF LOCATION IS A-PAD MONUMENTS A-D & A-4. 3. BASIS OF ELEVATION IS A-PAD MONUMENT A-D. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. GEODETIC POSITIONS ARE NAD27. 5. PAD MEAN SCALE FACTOR IS 0.9999273. 6. DATE OF SURVEY: FEBRUARY 20, 2009. 7. REFERENCE FIELD BOOK: NS09-11 PGS. 49-52. LEGEND • AS-STAKED CONDUCTOR • EXISTING CONDUCTOR LOCATED WITHIN PROTRACTED SECTION 35, T. 11 N., R. 13 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEV. OFFSETS A-44i Y=5,947,37.5.52 N= 1,240.00 70'15'47.402" 70.2631672' 48 9' 2,224' FSL ' X= 653,705.27 E= 220.00 148'45'26.338" 148.7573161° FEL 1,704 i~. ievuci ~-~ ~~ JACOBS CHECKED: WOLF Q ~~ DATE: 2/21/0 DRAWING: FR809 WOA 01- ~~ (~~ ~IVI~~I~I~n ~oeNO. by WOA A-PAD SHEET: AS-STAKED CONDUCTOR LOCATION WELL A-44i ~ °F ~ by A-44 (P5) Proposal Schlumberger Report Date: February 2, 2009 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: Well: A-PAD / A-44 ~~~'~~ Plan A-44 Borehole: ~ Plan A-44 UWIIAPI#: 50029 Survey Name 1 Date: A~4 (P5) sperry /February 2, 2009 Tort 1 AHD 1 DDI I ERD ratio: 107.009° 17686.38 ft / 6.062 10.848 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.26316589, W 148.75731036 Location Grid NIE YIX: N 5947375.000 ftUS, E 653705.990 ftUS Grid Convergence Angle: +1.16970711 ° Vertical Section Azimuth: 343.700° Vertical Section Origin: N 0.000 ft, E 0.000 ft ~~ TVD Reference Datum: Rotary Table TVD Reference Elevation: 75.50 ft relative to MSL Sea Bed 1 Ground Level Elevation: 47.00 ft relative to MSL Magnetic Declination: 22.687° Total Field Strength: 57701.526 nT Magnetic Dip: 80.884° Declination Date: April 30, 2009 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North -> True North: +22.687° Measured Vertical Mag 1 Grav Directional Comments Inclination Azimuth Sub•Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de H ft ft ft R de de 1100 it Index ftUS ftUS Klt U. UU U.VU 3ZU. UU -/O. OV U. VU U .VV V. VV U. UV --- U.VU U.VV 0`J4/3/O .UU 003/V0 .`J`J IV /V. LO3lb08`J VV 148./0/3lUJb WRP 28. 50 0.00 320. 00 -47. 00 28. 50 0 .00 0. 00 0. 00 --- 0.00 0.00 5947375 .00 653705 .99 N 70. 26316589 W 148.75731036 KOP Buld 2.25/100 200. 00. 0.00 320. 00 124. 50 200. 00 0 .00 0. 00 0. 00 320.OOM 0.00 0.00 5947375 .00 653705 .99 N 70. 26316589 W 148.75731036 300. 00 2.25 320. 00 224. 47 299. 97 1 .80 1. 50 -1. 26 320.OOM 2.25 0.65 5947376 .48 653704 .70 N 70. 26317000 W 148.75732056 400. 00 4.50 320. 00 324. 29 399. 79 7 .19 6. 01 -5. 05 320.OOM 2.25 1.55 5947380 .91 653700 .82 N 70. 26318232 W 148.75735114 Crv 2.5/100 425. 00 5.06 320. 00 349. 21 424. 71 9 .10 7. 61 -6. 39 4.OOR 2.25 1.70 5947382 .48 653699 .45 N 70. 26318668 W 148.75736197 500. 00 6.93 321. 08 423. 79 499. 29 16 .31 13. 67 -11. 36 2.92R 2.50 2.09 5947388 .43 653694 .36 N 70. 26320323 W 148.75740216 Crv 2.5/100 550. 00 8.18 321. 53 473. 36 548. 86 22 .39 18. 80 -15. 47 24.97R 2.50 2.30 5947393 .48 653690 .14 N 70 .26321726 W 148.75743538 600. 00 9.33 324. 79 522. 77 598. 27 29 .52 24. 90 -20. 02 21.76R 2.50 2.48 5947399 .48 653685 .47 N 70. 26323392 W 148.75747217 700. 00 11.69 329. 36 621. 09 696. 59 47 .00 40. 24 -29. 86 17.25R 2.50 2.78 5947414 .62 653675 .32 N 70 .26327583 W 148.75755169 800. 00 14.10 332. 41 718. 56 794. 06 68 .76 59. 75 -40. 66 14.29R 2.50 3.02 5947433 .91 653664 .12 N 70. 26332913 W 1483903 900. 00 16.53 334. 58 815. 01 890. 51 94 .76. 83 .40 -52. 41 12.19R 2.50 3.23 5947457 .30 653651 .90 N 70. 26339373 W 148. 73400 1000. 00 18.98 336. 20 910. 24 985. 74 124 .93 111 .13 -65. 08 10.65R 2.50 3.41 5947484 .77 653638 .66 N 70 .26346949 W 148.75783643 1100. 00 21.44 337. 46 1004. 07 1079. 57 159 .23 142 .90 -78. 65 9.46R 2.50 3.56 5947516 .25 653624 .45 N 70 .26355628 W 148.75794612 1200. 00 23.91 338. 48 1096. 34 1171. 84 197 .59 178 .64 -93. 09 8.53R 2.50 3.70 5947551 .69 653609 .28 N 70 .26365392 W 148.75806287 1300. 00 26.39 339 .31 1186. 85 1262. 35 239 .93 218 .29 -108. 38 7.77R 2.50 3.83 5947591 .01 653593 .19 N 70 .26376223 W 148.75818646 1400. 00 28.87 340 .01 1275. 44 1350. 94 286 .18 261 .77 -124. 48 7.15R 2.50 3.95 5947634 .15 653576 .20 N 70 .26388102 W 148.75831664 1500. 00 31.35 340 .61 1361. 95 1437. 45 336 .25 308 .99 -141. 37 6.63R 2.50 4.06 5947681 .02 653558 .35 N 70 .26401004 W 148.75845318 1600. 00 33.83 341 .13 1446. 19 1521. 69 390 .04 359 .88 -159. 01 6.20R 2.50 4.16 5947731 .53 653539 .68 N 70 .26414905 W 148.75859581 1700. 00 36.32 341 .58 1528. 03 1603. 53 447 .46 414 .33 -177. 38 5.82R 2.50 4.25 5947785 .59 653520 .21 N 70 .26429780 W 148.75874425 1800. 00 38.81 341 .99 1607. 29 1682. 79 508 .38 472 .23 -196. 42 5.50R 2.50 4.34 5947843 .09 653499 .98 N 70 .26445599 W 148.75889824 1900. 00 41.29 342 .35 1683. 83 1759. 33 572 .70 533 .48 -216. 12 5.22R 2.50 4.42 5947903 .92 653479 .04 N 70 .26462332 W 148.75905747 WeIlDesign Ver SP 2.1 Bld(doc40x_100) A-44\Plan A-44\Plan A-44W-44 (P5) sperry Generated 2/2/2009 3:50 PM Page 1 of 3 Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS ZUUU .W 43 ./S 34"L. 6S 1/5/ .51 1tf33 .U'I 64U .Ly by/. y/ -Z36 .4Z 4 .yt5K Y.bV 4.bV Oy4/yb/. y/ GJ340/ .43 N /V. ZU4/`J`942f VV "1415 ./DyZGlbb 2100 .00 46 .28 342. 98 1828 .18 1903 .68 711 .02 665. 56 -257 .30 4 .77R 2.50 4.57 5948035. 12 653435 .17 N 70. 26498414 W 148 .75939045 2200 .00 48 .77 343. 26 1895 .70 1971 .20 784 .76 736. 13 -278 .71 4 .58R 2.50 4.64 5948105. 23 653412 .33 N 70. 26517693 W 148 .75956357 Base Perm 2284. 16 50. 86 343. 47 1950. 00 2025. 50 849. 05 797. 73 -297. 12 4. 44R 2.50 4.70 5948166. 44 653392. 68 N 70. 26534521 W 148. 75971236 2300 .00 51. 26 343. 51 1959 .96 2035 .46 861 .38 809. 54 -300 .62 4 .42R 2.50 4.71 5948178. 18 653388 .93 N 70. 26537749 W 148 .75974067 2400 .00 53. 75 343. 75 2020 .82 2096 .32 940 .71 885. 66 -322 .97 4 .27R 2.50 4.77 5948253. 82 653365 .03 N 70. 26558545 W 148 .75992141 2500 .00 56. 25 343. 98 2078 .17 2153 .67 1022 .62 964. 35 -345 .73 4 .14R 2.50 4.83 5948332. 02 653340 .67 N 70. 26580040 W 148 .76010545 End Crv 2505 .78 56. 39 343. 99 2081 .38 2156 .88 1027 .43 968. 97 -347 .06 --- 2.50 4.84 5948336. 61 653339 .25 N 70. 26581303 W 148 .76011618 SV4 3587. 23 56. 39 343. 99 2680. 00 2755. 50 1928. 08 1834. 69 -595. 48 --- 0.00 5.16 5949197. 01 653073. 23 N 70. 26817808 W 148. 76212513 SV3 4219. 53 56. 39 343. 99 3030. 00 3105. 50 2454. 67 2340. 86 -740. 73 --- 0.00 5.28 5949700. 07 652917. 69 N 70. 26956086 W 148. 76329993 9-5/8" Csg 4355. 02 56. 39 343. 99 3105. 00 3180. 50 2567. 51 2449. 32 -771. 86 --- 0.00 5.30 5949807. 87 652884. 36 N 70. 26985717 W 148 5170 SV2 4533. 87 56. 39 343. 99 3204. 00 3279. 50 2716. 46 2592. 49 -812. 94 --- 0.00 5.33 5949950. 17 652840. 36 N 70. 27024830 W 14 . 8404 SV1 5249. 27 56. 39 343. 99 3600. 00 3675. 50 3312. 25 3165. 19 -977. 28 --- 0.00 5.43 5950519. 34 652864. 38 N 70. 27181280 W 148. 1352 WS2 6116. 43 56. 39 343. 99 4080. 00 4155. 50 4034. 43 3859. 36 -1176. 47 --- 0.00 5.53 5951209: 25 652451. 07 N 70. 27370916 W 148. 76682529 WS1 8952. 74 56. 39 343. 99 5650. 00 5725. 50 6396. 56 6129. 88 -1828. 02 --- 0.00 5.76 5953465. 83 651753. 37 N 70. 27991172 W 148. 77209917 CM3 9305. 02 56. 39 343. 99 5845. 00 5920. 50 6689. 94 6411. 89 -1908. 94 --- 0.00 5.78 5953746. 11 651666. 71 N 70. 28068209 W 148. 77275443 Crv 4/100 9370 .30 56. 39 343. 99 5881 .14 5956 .64 6744. 31 6464. 15 -1923 .94 179 .10R 0.00 5.78 5953798. 04 651650 .65 N 70. 28082484 W 148 .77287586 9400 .00 55. 20 344. 01 5897 .83 5973 .33 6768. 87 6487. 76 -1930 .71 179 .09R 4.00 5.79 5953821. 51 651643 .40 N 70. 28088934 W 148 .77293068 9500 .00 51. 20 344. 09 5957 .72 6033 .22 6848. 93 6564. 74 -1952 .70 179 .04R 4.00 5.83 5953898. 01 651619 .84 N 70. 28109962 W 148 .77310882 9600 .00 47. 20 344. 18 6023 .04 6098 .54 6924. 61 6637. 54 -1973 .39 178 .98R 4.00 5.86 5953970. 38 651597 .67 N 70. 28129851 W 148 .77327636 9700 .00 43. 20 344. 29 6093 .48 6168 .98 6995. 56 6705. 82 -1992 .67 178 .91 R 4.00 5.89 5954038. 24 651577 .00 N 70. 28148502 W 148 .77343247 9800 .00 39. 20 344. 41 6168 .71 6244 .21 7061. 41 6769. 24 -2010 .44 178 .82R 4.00 5.92 5954101. 28 651557 .94 N 70. 28165826 W 148 .77357640 9900 .00 35. 21 344. 55 6248 .34 6323 .84 7121. 86 6827. 49 -2026 .62 178 .71 R 4.00 5.94 5954159. 18 651540 .58 N 70. 28181739 W 148 .77370744 CM2 9962. 29 32. 71 344. 65 6300. 00 6375. 50 7156. 65 6861. 03 -2035. 86 178. 62R 4.00 5.96 5954192. 53 651530. 65 N 70. 28190902 W 148. 77378227 10000 .00 31. 21 344. 72 6331 .99 6407 .49 7176. 61 6880. 28 -2041 .13 178 .56R 4.00 5.96 5954211. 67 651524 .99 N 70. 28196161 W 148 .77382496 10100 .00 27. 21 344. 94 6419 .26 6494 .76 7225. 39 6927. 37 -2053 .90 178 .37R 4.00 5.99 5954258. 48 651511 .27 N 70. 28209024 W 148 .77392838 10200 .00 23. 21 345. 23 6509 .72 6585 .22 7267. 96 6968. 52 -2064 .87 178 .11 R 4.00 6.01 5954299. 39 651499 .46 N 70. 28220265 W 148 .77401719 10300 .00 19 .21 345. 63 6602 .92 6678 .42 7304 .12 7003. 53 -2073 .98 177 .73R 4.00 6.03. 5954334. 21 651489 .64 N 70. 28229828 W 148 .77409097 10400 .00 15. 22 346. 24 6698 .42 6773 .92 7333 .69 7032. 22 -2081 .19 177 .16R 4.00 6.04 5954362. 75 651481 .85 N 70. 28237668 W 1 44935 10500 .00 11 .22 347. 25 6795 .75 6871 .25 7356 .52 7054. 47 -2086 .46 176 .17R 4.00 6.06 5954384. 88 651476 .13 N 70. 28243745 W 148 . 19206 End Crv 10586 .36 7 .78 348. 96 6880 .92 6956 .42 7370 .73 7068. 41 -2089 .43 --- 4.00 6.07 5954398. 76 651472 .87 N 70. 28247553 W 148 .77421616 CM1 10681. 32 7. 78 348. 96 6975. 00 7050. 50 7383. 53 7081. 03 -2091. 89 --- 0.00 6.07 5954411. 32 651470. 15 N 70. 28250999 W 148. 77423610 Target 1 10686. 35 7. 78 348. 96 6979. 99 7055. 49 7384. 21 7081. 70 -2092. 02 --- 0.00 6.07 5954411. 99 651470. 01 N 70. 28251182 W 148. 77423716 Crv 3/100 10686 .36 7 .78 348. 96 6980 .00 7055 .50 7384 .21 7081. 70 -2092 .02 19 .16E 0.00 6.07 5954411. 99 651470 .01 N 70. 28251183 W 148 .77423716 10700 .00 8 .17 348. 02 6993 .50 7069 .00 7386 .10 7083. 55 -2092 .40 18 .22E 3.00 6.07 5954413. 83 651469 .59 N 70. 28251689 W 148 .77424022 End Crv 10700 .65 8 .19 347. 97 6994 .14 7069 .64 7386 .19 7083. 64 -2092 .42 --- 3.00 6.07 5954413. 92 651469 .57 N 70. 28251713 W 148 .77424038 THRZ 10938. 93 8. 19 347. 97 7230. 00 7305. 50 7420. 02 7116. 82 -2099. 49 --- 0.00 6.07 5954446. 95 651461. 82 N 70. 28260778 W 148. 77429766 BHRZ 11151. 09 8. 19 347. 97 7440. 00 7515. 50 7450. 15 7146. 37 -2105. 79 --- 0.00 6.07 5954476. 36 651454. 93 N 70. 28268849 W 148. 77434865 LCU 11166. 25 8. 19 347. 97 7455. 00 7530. 50 7452. 30 7148. 48 -2106. 24 --- 0.00 6.07 5954478. 46 651454. 43 N 70. 28269426 W 148. 77435230 TJF 11332. 95 8. 19 347. 97 7620. 00 7695. 50 7475. 97 7171. 69 -2111. 18 --- 0.00 6.07 5954501. 57 651449. 02 N 70. 28275768 W 148. 77439237 WeIlDesign Ver SP 2.1 Bld( doc40x_100) A-44\Plan A-44\Plan A-44W-44 (P5) Sperry Generated 2!2/2009 3:50 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS IJt 174JJ.Y/ C.7`J J4 /.`J/ //LU. VV //`/O. OU /4`JV.J7 //tSJ. /O -L714.Itl --- V.VV O.V/ OJA4010. A/ 007447. /) IV /U. LOL/JOII VV 140. //44/00 TJD 11732.01 8.19 347.97 8015. 00 8090. 50 7532.63 7227. 27 -2123.02 --- 0.00 6.06 5954556. 88 651436. 04 N 70. 28290949 W 148. 77448830 TJC 11893.66 8.19 347.97 8175. 00 8250. 50 7555.58 7249. 78 -2127.82 --- 0.00 6.06 5954579. 29 651430. 79 N 70. 28297098 W 148. 77452716 TJB 12045.20 8.19 347.97 8325. 00 8400. 50 7577.10 7270. 88 -2132.31 --- 0.00 6.06 5954600. 30 651425. 86 N 70. 28302864 W 148. 77456359 Crv 3/100 12193.49 8.19 347.97 8471 .78 8547 .28 7598.16 7291 .53 -2136.71 18.47E 0.00 6.06 5954620 .85 651421 .04 N 70 .28308505 W 148 .77459923 12200.00 8.37 347.55 8478 .22 8553 .72 7599.09 7292 .45 -2136.91 18.05E 3.00 6.06 5954621 .76 651420 .83 N 70 .28308755 W 148 .77460084 TSAG 12201.80 8.42 347.43 8480. 00 8555. 50 7599.35 7292. 71 -2136.97 HS 3.00 6.06 5954622. 02 651420. 77 N 70. 28308825 W 148. 77460130 7" Csg Pt 12201.81 8.42 347.43 8480. 01 8555. 51 7599.36 7292. 71 -2136.97 17.94E 3.00 6.06 5954622. 02 651420. 76 N 70. 28308826 W 148. 77460131 End Crv 12222.03 9.00 346.24 8500 .00 8575. 50 7602.41 7295 .69 -2137.67 --- 3.00 6.06 5954624 .99 651420. 01 N 70 .28309640 W 148 .77460697 Target 2 12222.04 9.00 346.24 8500. 01 8575. 51 7602.42 7295. 69 -2137.67 --- 0.00 6.06 5954624. 99 651420. 01 N 70. 28309641 W 148. 77460697 TSHA 12232.16 9.00 346.24 8510. 00 8585. 50 7604.00 7297. 23 -2138.05 --- 0.00 6.06 5954626. 52 651419. 60 N 70. 28310061 W 14 1002 TSAD 12308.09 9.00 346.24 8585. 00 8660. 50 7615.87 7308. 77 -2140.87 --- 0.00 6.06 5954638. 00 651416. 54 N 70. 28313213 W 148. 8 3292 45S8 12358.72 9.00 346.24 8635. 00 8710. 50 7623.78. 7316. 46 -2142.76 --- 0.00 6.06 5954645. 65 651414. 50 N 70. 28315315 W 148. 77464818 TD / 4-1/2" Lnr 12718.14 9.00 346.24 8990 .00 9065. 50 7679.96 7371 .09 -2156.14 --- 0.00 6.06 5954699 .99 651400. 01 N 70 .28330237 W 148. 77475656 Lestal Descri ption: Northinst IY) fftUSl Eastinst IX) fftUSl Surface : 2222 FSL 1703 FEL S35 T11 N R13E UM 5947375.00 653705.99 Target 1 : 4024 FSL 3789 FEL S26 T11 N R13E UM 5954411.99 651470.01 Target 2 : 4238 FSL 3834 FEL S26 T11 N R13E UM 5954624.99 651420.01 BHL : 4313 FSL 3852 FEL S26 T11 N R13E UM 5954699.99 651400.01 WeIlDesign Ver SP 2.1 Bld( doc40x_100) A-44\Plan A-44\Plan A-44\A-44 (P5) sperry Generated 2/2/2009 3:50 PM Page 3 of 3 by ~ ~ Schlumherger WELL FIELD STRUCTURE A-44 (P5) Prudhoe Bay Unit - WOA A-PAD Magnetic Parameters Surtace LOCa~IOn NA02]Alaska Sale Planes. Zone 04. U5 Feet n Motlel: BGGM 2008 Dlp: 80.880" Ua~e: Apn130. 2009 N>0154]}9] Northing'. 594])]500 AUS Gntl Conv1169]0]11° Sloted~A~44 TVD Ret. Rotary Table (]550kabove MSL) Mag Uec. 2268]° FS'. 5]]015ni Wid8 4526.31] Easting 65310599 fY15 Scale Fact 05999268384 44 (PSj Sperry Srvy Gate: February 02, 2009 0 1500 3000 4500 6000 7500 0 1500 3000 0 c 4500 a~ U H 6000 7500 9000 zsnoo rv z.sn o0 dCrv -.._..-..-.._..-..i..-.._..-.._..-.._.._..-..i..-.._.. _..-.._..-.._.. _..~.._.. _.. _.. _.. _. .. .. _.:_.._..-..-.._.._.._..-.._v-.._..-.._..-.._.._..-...i. _..-..-. Crv 41100: ]• csg Pi ...............i.................................. i.................................. <...................................y..................................; ........................... TD 14.1/2" A-44 (P! 0 1500 3000 4500 6000 7500 9000 0 1500 3000 4500 6000 7500 Vertical Section (ft) Azim = 343.7°, Scale = 1(in):1500(ft) Origin = 0 N/-S, 0 E/-V by ~ ~ Schiumberger WELL FIELD STRUCTURE A-44 (P5) Prudhoe Bay Unit - WOA A-PAD Magneuc Paramaten Surface Loca~wn NAD2] Alaska State Planes, Zane Da, US Feet Miscellaneous MoCel: SGGM 2008 Dip: 80880° Date: Aprd b, 2009 Lat'. N]0150139] Nw(M1ing'. 590]3]5 GO flUS Gritl Cpnv: X1.169]0]11° Slol: A-04 TVD Rat Rotary iada (]5.50 ft a0ova MSL) Mag Dec: X2268]° FS'. 5]]015nT Lan: W1080526.31] Easting: 653]05.99 flUS Style Fact: 0.9999268384 Plan: A~44 (P5l sporty Srvy Date. FaOruary 02. 2009 -3000 -2000 -1000 0 1000 n n n Z 0 0 0 c u a~ m U v v v 7000 6000 5000 4000 3000 2000 1000 0 A-44 (P5) TD l 4.1IT" Lnr ~" Csg Pt End Crv End Crv • Target 2 Crv 31100 Crv 31100 ~ Target 1 ° End Crv A-44 Flt -44 FIt 1 °N i I Crv 41100 ..............................:..................................i.......................... ......:..................................s..................................:........................ I '. Crv 2.51100 ~ RTE KOP Buld 2.251100 .......................:..................................:........................... .......................:..................................y........................... crv cnz.stlon ........................................................... 7000 6000 5000 4000 3000 2000 1000 0 -3000 -2000 -1000 0 1000 c« W Scale = 1(in):1000(ft) E »> -- Company: BP Amoco Date: 2/2/2009 Time: 15:59:54 Page: l Field: Prudhoe Bay True North Well: A-44 Plan R f di t NE; d C PBA P ---- - } , erence: o-or na e( e a Reference Site: Reference Nell: A-44 Plan Vertical ('fVD) Reference: 47.0 GL + 28.5 75.5 Reference ~Yellpath: A-44 Plan Dh: Oracle - - - - -- - -- GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are [i:@I~L'Hoeells in thisRl+iidlpal Plan S~ PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse - eptKRange~~50- to~l2~t8~t~ ~t---- __ - -Sean 1Vlethod:- ~rav Cytin~erNurt~-_... '~ Maximum Radius: 1468.96 ft Error Surface: Ellipse + Casing -- i Survey Program for Definitive Wellpath Date: 8/25/2008 Validated: No Version: 1 _-___ Fr-om--Ta Sarvey ___._ T-0olcoa~--- Tee(-.Name - - --- ft ft -- 800_00 PlannedA-44 Wp 5.0 V12 ___ GYD GC-SS _ G rodata_ ro sin le shots _ 28.50 ~ 919- - -- --_ -_ _ - - 800.00 2200.00 Planned: A-44 Wp 5.0 V12 MWD MWD -Standard 800.00 4355.00 Planned: A-44 Wp 5.0 V12 MWD+IFR+MS MWD +IFR + Multi Station - 43-55:00-~~291.^~~RlaFlned: A-44-Wfr~E}~F4~-- --M:"m+.~,_„ro+o~~_.a"y;~D-~ '-~°~"~ItLStatien- 12201.00 12718.14 Planned: A-44 Wp 5.0 V12 MWD+IFR+MS MWD +IFR + Multi Station -- ------- -- - as~ -ing Points _ __ - - - - ~ID l'VD Diameter Hole Size Name ! '- ~ _- i ft ft in in ~, 4355.02 3180.50 9.625 12.250 9 5/8" cnn " ' ' _ _ _ - --- - - - - - - _- 7 L80- -85-55:5© 7:000--8-~.. L22EL ' 12718.14 9065.50 4.500 6.125 4 1 /2" - _- ummary <---------- Offset Wellpath -----------> Reference Offset Ctr-Ctr No-Go Allowable in - i ti W D - - arn g ev a on i11D ItID Distance Area Site Welt We-tpath ft ft ft ft ft _- P~A~ad- _~ ~8 -- --~r'~-- "2:51- X25:00- X40:~2--~?~44(~56-Rass~V}ajeFRis PB A Pad A-21 A-21 V1 277.57 280.00 36.04 7.67 28.37 Pass: Major Risk ' PB A Pad A-21 A-21A Plan VO Plan: A- 279.15 280.00 36.08 7.60 28.48 Pass: Major Risk !I ~~B ~ --,q=22- 7a-22-V3-----X83:75-_ _79~0~_ 39:77- 14:T4--25.03--Pass: Major i}7~_-.__ PB A Pad A-23 A-23 V1 1090.65 1070.00 78.88 21.00 57.88 Pass: Major Risk A-24 V1______ 1373.22 1345 00 124.02 29.78 --94.24 ._ Pass: Major Risk A-24 _ PB A Pad ~~_ _.___ -__ __ __ ', PB A Pad A-25 A-25 V12 1551.89 1435.00 314.55 33.25 281.30 Pass: Major Risk PB A Pad A-25 A-25A V14 1549.61 1425.00 314.45 33.04 281.41 Pass: Major Risk - APadA26---A-26 \F1 ---_. __ +~4~1-V0-,03--1685:09'F99~846x20-~5~9~ ~a~TAiFajor-Risk-- PB APad A-26 A-26L1 V1 1780.03 1685.00 199.18 46.20 152.97 Pass: Major Risk ~~ PB A Pad A-26 A-26L1 P61 V1 1780.03 1685.00 199.18 46.20 152.97 Pass: Major Risk pB-A Pact__.__- ~_2r -___-~=27 V2-- ~ 93088~f800:00-2356'1- -51:86- 187:75_ asps: Wlalor Ris -- -_ PB A Pad A-27 A-27A V2 1930.88 1800.00 239.61 51.86 187.75 Pass: Major Risk A-28_V1 _-2727.64 2385.00 152.44 79.32__. 73.12. Pass: Major Risk _ A-28 PB A Pad __ _ _ _ . _ _ PB A Pad A-29 A-29 V1 2225.64 1955.00 301.66 61.24 240.41 Pass: Major Risk PB A Pad A-33 A-33 V2 3827.35 3675.00 709.30 93.38 615.91 Pass: Major Risk ' - - - ' ~B-A Rad- -37 _-__ -A-37- ~'~- ~3~53 245:000:24 " -.^" -- 620-- amass:-Major Rises - ;-- PB APad A-41 A-41 V7 3075.46 2940.00 278.81 74.02 204.79 Pass: Major Risk PB A Pad A-42 A-42 V2 666.68 675.00 24.06 11.04 13.02 Pass: Major Risk -PBS ---_-,~ 42 __~4~A Vim- - ~6fi:6887500-2~II6-_ 176- 13:3 Pass: lVralor Ri`s~ I -- -- PB A Pad A-42 A-42P61 V6 666.68 675.00 24.06 11.04 13.02 Pass: Major Risk A-42PB2 V1__ _666.68 675.00 2_4.06 11.04 - 13.02 - Pass: Maior Risk _.__ A-42 ~' PB A Pad - . ._ __ _ ______ PB D Pad D-08 D-08 V7 12715.30 10155.00 423.74 536.42 -112.68 FAIL: Major Risk PB D Pad D-31 D-31 V1 12703.27 10597.67 444.32 263.98 180.34 Pass: Major Risk ~ --_T ` - ~ t~P~~-A_I'acL-- _-~- ' - ' - ~ -Well. A-44 Plan 1x7o11...~41,. A _AA Dl.... From Surface to TD S-carrintervat~l 00-ft Scale 1:100 313 300 200 100 ~ 283 4q~ 1 ~~ ~- x02 1116 1421 I- I bUl k / i o z7 ~ ~~ zv22 ~~ ~ ~ ~ ?ate voo~ ~ ~ ~ --~~ ~' r ..._ ~- - ( ~ ~ ~' t ~- i ~ i _ i2oP ~ ;~ ~ ~ ~ / so13 I ~~ a~q v~41 ~ Isob `~) / =f-~ __- ~~qQ v+•u IOHA .11296) -., 0 1 3104 ._t~ -'---- ~,~' H7R4 ~ LiB~~ 1 .n I _ ~ _ h0 100 3195 -' - - 'I ,~ ~ 100 'ti7~ ~ 1174'. I,~t 0>. __ %_ _ _ .j-. =I (~fl7b.- ~ l° ~,s9 166 \ ~_ j !y'~.96b ~~ 2005 24 y ~ ~ %~ 48 '~.,- .. IaG~ ~ 120 / a' 7. - 210 ,. ~ 1030 ~~ 94' -_ ~- - _.._ ~ 1 4U ~. .. 1312 ~~_ 0 ~, 200 I , __ .200 .. x !_ I~ 113A i !>3v .__.___ 9 -_.__ '~ 4_ ~ ~- A-2Q (A-24) 1114 1219 _-- ~ ~ - - ~~ ~' 6l4 21 1 LOi 1 ~ --50 A-23 (A-23) .__.. - - ----~~ li)t-"* 12Q0. .4-22~~A-22) -~ ". - '-~ A-21 (A-2l)1 Plan) 300 ~-.- -300 ~ A-37 (A-37) Alaska Department of Natural~ources Land Administration System • Page 1 of~ ` =Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins ~~tuf a~ Res[~urt2s Alaska DNR Case Summary File Type: ADL File Number: 28286 ~ Printable Case Fle..Summary See Township, Range, Section and Acreage? New Search Yes C`J No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28286 ~ ' ' Search for Status Pfa#_llpdakes As of 03/20/20.09 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASS IGNMENT APPROVED Meridian: U Township: O11N Range: 013E Section: 25 Section Acres: 640 Search Plats Meridian: U Township: Ol 1N Range: 013E Section: 26 Section Acres: 640 Meridian: U Township: Ol 1N Range: 013E Section: 35 Section Acres: 640 Meridian: U Township: O11N Range: 013E Section: 36 Section Acres: 640 Legal Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* Cl-1-97 TIIN-RISE-UM 25,26,35,36 2560.00 End of Case Summary Last updated on 03/2012009. httn://dnr.alaska.aov/oroiects/las/Case Summary.cfm?FileType=ADL&FileNumber=2828... 3/20/2009 Page 1 of 2 Maunder, Thomas E (DOA) From: Mallery, Joshua [Joshua.Mallery@BP.com] Sent: Monday, March 23, 2009 1:35 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: A-44 Attachments: A-44 quarter mile plot.pdf Tom, Please note the comments below: I presume the distances given are at the top of the reservoir? Yes, the measurements were from the top of the reservoir in A-44 to BHL in D-08 and D-31. Is this all penetrations? It is all the reservoir penetrations. Could you provide a plan view starting at the top of the reservoir showing these wells and the proposed A-44? A- 29 well path penetrates within 1/4 mile, however, this penetration is at a deeper TVDSS that is not in the injection reservoir. The plan view is attached with a comment about A-44. Thanks, Joshua Mallery 907.564.5545 From: Hobbs, Greg S (ANC) Sent: Monday, March 23, 2009 9:34 AM To: Mallery, Joshua Subject: FW: A-44 Josh- A question from Tom- Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 20, 2009 4:19 PM To: Hobbs, Greg S (ANC) Subject: A-44 Greg, Please forward to Josh. On page 3, D-08 and D-31 are identified as being within'/ mile radius of the proposed trajectory of A-44. I presume the distances given are at the top of the reservoir? Is this all penetrations? Could you provide a plan 3/23/2009 . • Page 2 of 2 view starting at the top of the reservoir showing these wells and the proposed A-44? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 3/23/2009 Project: Prudhoe Bay Site: PB A Pad Well: A-44 Plan lellbore: A-44 P5 Modeling Design: A-44 Wp 5.0 c s~4 p~srJA'g4 WG 5.0 7 ~ ~-44114 Mile @ Ivi 91 89 R~1 ioplo~wk 87 (8'1~1,5~ 6000 A-071A•07 5600 85 36pp -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1900 -1600 -1400 -1200 -1000 -800 West(-East(+) (400 ftlin) TRANSMITTAL LETTER CHECKLIST WELL NAME f~- ~~ ,LJ- L~.f~ PTD# o?O90•S~~ Development ~ Service Exploratory Stratigraphic Test Non-Conventional Welt FIELD: pe,/D~/D~- ~I~ POOL: ~..E!/D~OE".1~~1J~ !7/L Circle Appropriate Letter / Paral;raphs to be Included in Transmittal Letter CHECK WHAT APPLIES ADD-ONS (OPTIONS) TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing weii Permit No. ,API No. 50- - _ Production should continue to be reported as a function of the on ~ i ucil API number stated above. PLOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs ac;; u i ~-ed for the pilot hole must be clearly differentiated in both we!' name ( PH) and API number (50- - -1) from records, data and logs acquired for well SPACING Tl::• ~e;mit is approved subject to full compliance with 20 AAC EXCEPTION 25.L'~5. Approval to perforate and produce /inject is contingent upo,; issuance of a conservation order approving a spacing e"~~~'' '~n' assumes the lial::;;,y of any protest to the spacing exception that may occur. DRY DITCH All <~:, ~, ditch sample sets submitted to the Commission must be in SAMPLE no ~ , ;ter than 30' sample intervals from below the permafrost or fron, where samples are first caught and 10' sample intervals th ro ~ ~ ~_ !~ target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for Lune of well until after (Company Name) has designed and imple,~;cnted a water well testing program to provide baseline data on w~ ' ~r quality and quantity, (Company Name) must contact the Com,:.ssion to obtain advance approval of such water well testing roUr ~;,. Rev: 1 / 1 I /2008 W~L,~± ' .Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 _ ___ _ ___ _ ~ITC1~~#:1ST. __ __WeIlName: PRUDHOEBAYUNIT_A-44_. _ ___- Program SER _____ Well boreseg ^ __ ___ PTD#:209041D Company BP EXPLORATION (ALA$~ INC _ _ _ Initial ClasslType _ SER / PEND GeoArea 890 __ _ Unit 11650. On/Off Shore On___ Annular Disposal ^ Administration '1 Permit fee attached NA_ - j2 Lease number appropriate- - - - Yes - 3 Unique well name and number _ - Yes - - _ - 4 1 -Well located in a defined pool _ - Yes 5 Well located proper distance-from drilling unit. boundary- - Yes 6 Well located proper distance-from other wells_ - Yes - ~ 7 Sufficient acreage available in-drilling unit- - - - Yes - _ - - - 8 If deviated, i&wellbore plat included - Yes - - _ _ 9 Operator only affected party_ Yes - - - i~ 10 Operator has appropriate-bond in force - - Yes Blanket Bond 6194193. - 11 Permitcan be issued without conservation order Yes Appr Date '12 Permit_can be issued without administrativ_e_approval Yes 13 Can permit be approved before 15~1ay wait- Yes ACS 3!23/2009 14 Well located within area and strata authorized by Injection Order # (put-10# in comments) (For Yes AIO 3 - - - !15 All wells within 114-mil_e area of review identified (For service well only) Yes ',16 Pre-produced injector: duration ofpre-production lessthan 3 months (For service well. only) IJA 17 Nonconven, gas conforms to AS31.05.030(f.1.A) O.2.A-D) NA -_ __ __ 18 Conductor stung provided Yes _ - Engineering x!19 Surface casing protects all known U$DWs - NA- - All. aquifers exempted, AEO.1_. 20 CMT vol adequate_to circul_ale on conductor& surf csg _ Yes 21 CMT vol adequale_to tie-in long string to surf csg No 22 .CMT will cover all known productive horizons- - Yes X23 Casing designs adequate for C, T, B _& permafrost- Yes 24 Adequate tankage_or reserve pit Yes Rig equipped with steel pits. No reserve pit planned.. All. waste-to approved disposal well(s).. ',25 If a_re-drill, has_a 1.0-403 for abandonment been approved NA - 26 Adequate wellbote separation-proposed Yes Proximityanalysis performed, Traveling cylinder path calculated. Gyros possible in surfaceh_ol_e, i27 If dwerter requued, does itmeet-regulations- - - - Yes 28 program schematic & equip list adequate Dnllingf1uid Yes Maximum expected.formation pressure 7,1_EMW. MW planned up to 9,7-ppg in-8.75" hole and 8,6 ppg in zone, Appr Date - TEM 3124!2009 '29 BOPEs, do they meet regulation - Yes 30 BOPE_press rating appropriate; test to (put prig in comments) Yes MASP calculated at 2291 psi. 4000 psi ram test planned. - I31 Choke. manifold complies wlAPl RP-53 (M_ay 84) Yes ',32 Work will occur without operation shutdown- Yes '33 Is presenceof H2S gas probable Yes - H2S present_at A_pad. Mud should preclude H2S_on rig.- Rig has sensors and alarms.- - 34 Mechanical condition of wells within AOR verified (For service well only) Yes No AOR issues. 35 Permit_can be issued w!o hydrogen_sulfideineasures - No Max level H2S on pad 400ppm on wel_Is A-43, A-37 (614199).. Geology i36 Data_presented on_ potential overpressure zones - NA - _ _ - Appr Date 37 Seismic analysis of shallow gas zones_ - _ _ NA _ - - - _ ACS 312012009 38 Seabed condition survey_(ifnff-shore) NA I39 Contact namelphone for weekly. progress reports [exploratory only] No- Joshua Mallery - 564-5545._ Geologic Engineering Public Commissioner: Date: Commissioner: Date Com ' ner Date ~~s 3 l~ f~ s ~, 3-zs- ~I ~3~5-~~
