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205-161
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 06/09/2025 Mr. Jack Lau Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 06/09/2025. Dear Mr. Lau, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 06/09/2025. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525) Date: 2025.06.09 14:30:46 - 08'00' Oliver Sternicki (4525) Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/09/2025Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateF-10C21308650029204100365/29/25F-29B2111475002921627026.25/29/25F-33A20816350029226400145/29/25F-3619519650029226310035/29/25F-39190141500292210100175/29/25F-44A2051615002922130012.55/29/25F-47B21007950029222320215/29/25L-2512231065002923772001.8813/31/24117/29/24L-2532230485002923758004.1201.13/31/24127/29/24L-2542230305002923752003.8321.23/31/24137/29/24L-2922230255002923751003.3301.33/31/24147/29/24N-282141275002923524006.8504.711/19/242212/28/24N-302141245002923523003.5330.311/17/243.512/28/24PAVE1-122309450029237670019.910/27/24PWDW3-221908150029236340014.810/27/24S-40120607850029233130015.31130.511/15/24412/28/245/29/25F-44A2051615002922130012.5 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU F-44A Mill CBP, Patch Perfs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-161 50-029-22130-01-00 10722 Conductor Surface Intermediate Liner Liner 9041 80 2652 8587 717 1724 10080 20" 13-3/8" 9-5/8" 7" 4-1/2" 9044 31 - 110 31 - 2685 27 - 8616 8455 - 9172 8998 - 10722 31 - 110 31 - 2685 27 - 8081 7933 - 8575 8427 - 9041 10080 2260 4760 5410 7500 10080 5020 6870 7240 8430 9330 - 10540 4-1/2" 12.6# 13Cr80 24 - 9005 8703 - 9039 Structural 4-1/2" Baker S-3 Perm Packer 8906, 8345 8906 8345 Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028280 24 - 8433 N/A N/A 406 1659 47564 19146 24 126 50 200 1600 1260 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:46 pm, Jun 19, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.19 13:17:25 -08'00' Torin Roschinger (4662) DSR-6/21/23 RBDMS JSB 120623 WCB 1-9-24 ACTIVITY DATE SUMMARY 5/31/2023 CTU#6 1.75" CT. Job Scope: Mill/Push CBP MIRU. ***Job In Progress*** 6/1/2023 CTU #6 1.75" CT. Job Scope: Mill/Push CBP. MU 2-7/8" milling BHA with 3.70" Venturi burn shoe. RIH. Tag CBP fish at 9868'. Mill/push to CIBP at 10071' CTM/10080' MD. POOH. RDMO CTU 6 ***Job Complete*** 6/8/2023 ***WELL S/I ON ARRIVAL*** DRIFT W/ 4 1/2" GR, 45KB UPPER DRIFT(24' spacer pipe) 45KB LOWER DRIFT (36' oal), DEVIATE OUT @ 9,852' SLM ***WELL LEFT S/I*** 6/13/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 3-1/8" GR/CCL, BKR #10 SETTING TOOL, BAKER 45 KB PATCH (20' ELEMENT TO ELEMENT, 3.70" MAX OD, 32' OAL) PATCH SET DEPTH=9,686'-9,706', CCL OFFSET=12.3', CCL STOP DEPTH=9,673.7' NIGHT CAP INSTALLED & PRESSURE TESTED ***WELL LEFT S/I*** job continued on 6/14/2023 6/14/2023 ***WELL SHUT IN ON ARRIVAL*** PRESSURE TEST PCE RIH W/ 1-7/16" CHD (1" FN), 3-1/8" GR/CCL, BAKER 10 SETTING TOOL, BAKER 45 KB PATCH (30' ELM-ELM, 3.70 MAX OD, 48 OVERALL LENGTH) MIN ID = 2.45" LOG CORRELATED TO AKES PLUG & PERF RECORD DATED 11-DE-2021 PATH SET DEPTH=9,323'-9,354', CCL OFFSET=12.3', 9,310.7' TREECAP INSTALLED & PRESSURE TESTED ***WELL LEFT S/I*** Daily Report of Well Operations PBU F-44A ( PATCH SET DEPTH=9,686'-9,706', g Mill/push to CIBP at 10071' CTM/10080' MD. POOH. 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Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing ❑ Op i h� �4 t 1:1a Suspend 0 Perforate 0 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.Straddle Perforations 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-161 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22130-01-00 7. Property Designation(Lease Number): ADL 0028280 8. Well Name and Number. PBU F-44A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10722 feet Plugs measured 10080 feet true vertical 9041 feet Junk measured feet Effective Depth: measured 10080 feet Packer measured 8903 feet true vertical 9044 feet Packer true vertical 8342 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"Conductor 31-111 31-111 Surface 2652 13-3/8"68#NT-80 31-2683 31-2682 5020 2260 Intermediate 8587 9-5/8"47#L-80 27-8614 27-8079 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9693-9703 feet feet 9859-9889 feet 9929-9959 feet 9990-10040 feet 10100-10160 feet 10310-10380 feet 10460-10540 feet True vertical depth: 8980-8986 feet feet 9046-9051 feet 9053-9054 feet 9053-9048 feet 9041-9038 feet 9038-9038 feet 9039-9039 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-9002 . Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): hi Treatment descriptions including volumes used and final pressure: SCANNED `� 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 358 25706 24 760 2176 Subsequent to operation: 559 27158 28 700 2134 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 Q Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Haffener,Jordan Contact Name: Haffener,Jordan Authorized Title: Production Engineer Contact Email: Jordan.Haffener@bp.com Authorized Signature: _// Date: /0 OC 2017 Contact Phone: +1 9075645383 Forth 10-404 Revised 04/2017e(tylrb V rL. I 0 117-I)V-- R , -_3 oi C::„ , 1 ?.,317 Submit Original Only • • 44, Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 6, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for the Setting of a Straddle Patch across the upper Perforations for Well F-44A, PTD # 205-161. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • a) a o 0 o 0 o as RINos - t Cn CC) p N V IO N- ti U j o 0C) 0 0 OCO CO 00 N d m IO CO t` CO 00 N O) CO co f-- N- t CO CO O in co N CO CO O) CO , I I I- O CO N V CO cO N CA N- CO G) = c) v- OON 00 �- N CO CO c O CN CO Cr) c, 0) 0 1 1 1 1 1 1 Q Q gllog N-CO Ch c0 N �t O0) N CO CO C 11W I— a O O co co O O CO O co Z co - M N c CO CV O m U CO N U - 00 b 1-0N N (N r r N N dt CO O Lo 00 ti N N- C CO CO CO ' N- a) N 00 • 00 W IY — C O uj U w U � u_ Ct Z O D H Z Z D (n z J J • • Packers and SSV's Attachment PBU F-44A SW Name Type MD TVD Depscription F-44A PACKER 8463.82 7941.09 7" Baker ZXP Top Packer F-44A TBG PACKER 8903.36 8342.45 4-1/2" Baker S-3 Perm Packer F-44A PACKER 9006.91 8434.41 5" Baker ZXP Top Packer F-44A PACKER 9686 8975.76 3-1/2" Baker 45 KB Packer F-44A PACKER 9707 8987.69 3-1/2" Baker 45 KB Packer • • as co a O O O N N O cn , -1 ao N •,_.- cn v U w _II o Q c a.CO I- u) Un °O a) Ln a b Y cnp 0 aa) ocm ~ m C Ul Z a) Q N j 4 0 Zs 0 Q Q 0 Q O Q 0J Q O = a r al 0_ _U N ~ L L N O 2 o3 a_ a) o W _ W O O- Cl) U) Ni- Z CO a. 0- c"J -0 I_ Cij = 0 0 N LU 2 w o = .c V u) U 0 O a CO 0 Q F- F O Do a) F � inLor Q.. a a (n O 1- O W n3 m � � a ii m QL - � 0 a ° c O o a_ 'ai as Z � W OaN c o 0 0 co O U = a �:, CC CO 'n F- i > J O " v. .- O Rt Q 0- x QF- W > W p - W LU c n (7) Lr) Q 2 p a s mF w U J � m m = - moo a)in - O0 � crrid Z � c?j � Q � ~ "EZ .v TD N N o Q � z � rx 2 ZZ * Q c o cn o a = pWF- � w � , Fi3 rn p � � o - -,=, Y � •� Q� d d U - < O < wor 0 :� U 0a_ _1 a) LL o �• oCU mco � : TS N- QCCNY a) I- .-T50 QW (nom < o O a) xc,.; Wa I' c) 0I Q OE ? � tO Ea C 45< N C 4-, m o � COcn Q) ca_ a) N0 L a 2 - � Y = --' � 0 < r c < 0r — O ;� _ : _ 5o LL * NO Cn CO N O co S` J W m (� N * * IQ J O O OCL N re X NN W Cn Cn , � I I co A Qor`a) L � - QoZEt > m 0 - ac as Q0 � aa) r a� � :- > choov � * ZO � p � < I- z0 E c13 m > o � I- m -0 i- 3 p E --§ o § � C� o00cn I pl- OIac) � c,� r� cc`oH. a) � o a) Q 2 v 2 2 W _z N 0 D o i- 1-..: _ I O Ow CO Vx 7 7 _c o c. '.' 0mHcncna � " ZZw a � -I _Ia � • 0Nam', Q $ X -a � o - CON0 � -I � ZZQ � wF- CCwo -0 a) cco- o �r�i cncn0coco0U- � 00W � Q � 08N T-- (I) 0 m -a .EN c -laiLaiaiOJ ~ UU _= m � DQ > OLO - c ii -J 1.- V. Z . t 8o w 0 ©©� w _Q mO CQ W O Y U 0 p• m (NI Q = i j `„' °-o ° 0 DD7) F- -» = cAF- UU � � ,_ � p 0 N TO—D C cnov) J5 : Z * . cC < ccnna _1 � 1- a. W w 0 : II= Om n W F- r ar r -- r >- o o 0 0 0 c. 5_ N- N N CO 0.-5 F- CO CO CO m rn 0) 0 Q • • @ c LU / E w u r'- </ ® b < © ± a 0 0 v 2 �: / < — \ E --I < / t $ O u § $ - 7 k L.L. (1347, A Eƒ / O E @ @ % E % ® E Cr) % F-- - � / 0 I H O k 13R E / / L 20 / � / R o $ <H 0 0 b / 0u— Ewa ; 0 0 0 a' w O Z (i) 0 < OZD GmA $ $ k ƒ/ / 0 / CI f ƒ L ® Ec0 $ / ctOo \� E ƒ $ H O - % 2 CO ± 2 £ / � kf / / / 2 � / \ -ƒ / % / i O m cno X a t 5 0 o w % /& $ q 7 I # e TREE= Clw • W43_L EAD= McBIOY C-44A SAFETY NOTES:WELL ANGLE>70°@ 9822'""• ACTUATOR= BAKER (� CHROME TBG*** KB.EEi/= 65.66' I BE ELEV= 37.98' VI KOP= Max Angle- 97°Q i3553T —i COND,D=? --I ? I ' 0 2184' -[4-1/2'HES X NP,D=3.813" Datum MD= 9532' Datum TVD= 8800'SS GAS LFT MANDRELS 13-3/8"CSG,68#,NT-80,13=12-415" -I 2685' ST MD TVD DEV TYPE VLV LATCH FORT DATE L4 2 3379 3378 7 MMG DO' RK 11 0 11/30/13 1 6046 5785 30 MvIG DMY RK r 0 11/30/13 Minimum ID =2.36" @ 9686' ELM I• 8455' -9-518"X 7"BKR C2 ZXP LTP 4-1/2" STRADDLE PATCH '/ w/11.6'TEBACK SLV,D=6.26" 8473' H 9-5/8"X 7"BKR HMC LNR HGR,D=6.33" 9-5/8"WHPSTOCK(05/18/09) 8616' r 9-5/8"CSG,47#,L-80,D=8.681" -8616 te MLLOUT VVPDOW(F-44A)8616'-8633' ►'t 8886' J-{4-1/2"FES X NAP,D=3.813" z $-- 8906' -17"X 4-1/2'BKR S-3 PKR,13=3.875" IF---1 8930' H4-1/2"HES X NP,D=3.813" ' 8993' -14-1/2'HES XN NP,D=3.725' TOP OF 4-1/2"LNR H 8998' 8998' -17"X 5"ZXP LIP w/11-4'TIEBACK,ID=4.410" 4-1/2'TBG,12.6#,13CR 80 VAM TOP, - 9005' 9005' -{41/2"WLEG,D=3.958" .0152 bpf,13=3.958" ( 9016' H 7'X 5"HMC LNR HGR,D=4.420" 7"LNR,26#,L-80 BTC-M,.0383 bpf,ID=6.276' H 9172' 9023' --15"X 4-1/7 XO,D=3-920" FERFORATION SUMMARY I. REF LOG:Sperry ALD/CTN/FRIEWR ON 05/30/07 ANGLE AT TOP PERF:78°@ 9859 R 9686'-9707'ELM J41/2".STRADDLE PATCH, Note:Refer to oduction DB for historical pert data SEE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 9693-9703 C 09/25/11 3-3/8" 6 9859-9889 0 07/07/09 3-3/8" 6 9929-9959 0 07/07/09 2-7/8" 6 9990-10040 0 05/30/07 2-7/8" 6 10100-10160 C 05/30/07loo-4411110080'A-13-3/8"CBP(047/07/09) I 2-7/8" 6 10310-10360 C 05/30/07 2-7/8' 6 10460-10540 C 05/30/07 PBTD - 10635' 4-1/2"LNR 12.6#,L-80 BT--M.0152 bpf,D=3.958"J-1 10722' f DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY(.NT 02/26/91 IMTIAL COMPLETION 09/23/09 GWJMD DRLG DRAFT CORRECTIONS WELL F-44A 06/02/07 N2ES SIDETRACK(F-44A) 12/04/13 BSE/JMD GLV C/O(11/30/13) PERMIT No:"`205161 06/29/07 /SV DRLG HD CORRECTIONS 08/29/17 KS/JM) SET LOWER PKR(08/28/17) AR No: 50-029-22130-01-00 02/09/08 RLM'PJC SFTY NOTE CORRECTION 09/19/17 JGUJMD SET UPPER FKR(09/06/17) SEC 2,T11 N,R13E,3248'FNL&2199'FEL 07/28/09 DVVMI/PJC MP/PEWS(07/07/09) 07/30/09 PJC PERF CORRECTIONS BP Exploration(Alaska) RECEIVED STATE OF ALASKA . A.KA OIL AND GAS CONSERVATION COMMI . N OCT 11 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Lf Pull Plug Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 205-161-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22130-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028280 PBU F-44A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 10722 feet Plugs measured 10080 feet true vertical 9040.77 feet Junk measured None feet Effective Depth measured 10080 feet Packer measured See Attachment feet true vertical 9043.69 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 27-107 27-107 Surface 2657 13-3/8"68#NT-80 26-2683 26-2682.92 5020 2260 Intermediate None None None None None None Production 8590 9-5/8"47#L-80 26-8616 26-8081.35 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9693-9703 feet 9859-9889 feet 9929-9959 feet 9990-10040 feet 10100-10160 feet 10310-10380 feet 10460-10540 feet True Vertical depth 8979.85-8985.5 feet 9045.83-9050.72 feet 9053.29-9053.53 feet 9052.74-9048.05 feet 9041.49-9038.07 feet 9038.24-9037.84 feet 9039.04-9038.79 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-9005 25-8432.74 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): § Treatment descriptions including volumes used and final pressure: scan `i iJ` . J t 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 480 30764 28 0 1322 Subsequent to operation: 1016 41794 81 0 1457 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 151 Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garrv.Catron(cilBP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 10/11/2013 17 LF. ,,O. leW. RBDMS OCT 14 2 Form 10-404 Revised 10/2012 Submit Original Only •• Packers and SSV's Attachment ADL0028280 SW Name Type MD ND Depscription F-44A PACKER 8466 7879.9 7" Baker ZXP Top Packer F-44A PACKER 8906 8281.61 4-1/2" Baker S-3 Perm Packer F-44A PACKER 9009 8373.03 5" Baker ZXP Top Packer it • 0 c Q v a) o To co m J ui Q E N — c' J N E Q co o 0 o c o Z 0) (r) N CO L co CD O rn = W I- c U O w * Q _ * � Cu i F- O — 0 > T I G1 0 2 — 00 Lil o _ ao _a) o1— vo0 _1 C0 d co 2 � m 9_2Nf < 0 w Q O• J ° U W Q N O vt 0 Q co * M U d T II � 0. � � * r � � "' w Q Q < D � o 0o Mi ai O z w Ct C[ II 0 J 2 J U Z < o > co 0 Z w O m Z m W D Ili o i_Ot_ 0 Q c. (Ni n� aD wZN Ovw ) u) NO , u, _ I > U a 0 o 2 0 J "oo 1- X ^Q (/)-- Q ZZ _ O s— (-9 wOri0Oco ED' w Fw II cY> U 501ZOOZ a) w Or..,- II * E2 rr * * cn O 0 * f— U) _M M_ co T 0 0 0 N N N CD CD T T T T T a o •TREE= CIW 1/IELLHEAD= IlltB/OY F-44A SA.NOTES:WELL ANGLE>70° 9822'*** CHROME TRW** ACTUNTOR= BAKER C KB.REV= 65.66' BF.R. = 37.98' KOP= 35W "ODICUCTOR, ? MI= • ,1 I 2184' —14-1/2"HES X NP,ID=3.813" 14ix Angie= r 1003T — Wont MD= 9532' Datum TVD= 8800'SS GAS LIFT MANDRILS ST MD DEV TYPE VLV LATCH 'FORT DATE 13-3/8"CSG,68#,NT-80, =12.415" —I 2685' •q 2 3379 3378 7 AOC DOME RK 16 06/08/07 1 6046 5785 30 MMG SO RK 20 06108107 Minimum ID =3.725" @ 8993' 4-1/2" HES XN NIPPLE 8455' 9-5/8"X 7"BKR C2 ZXP LTP w 11.6"TIEBACK SLV, =6.26" 8473' —19-5/8"X 7"BKR HMC LNR HGR,13=6.33' 9-5/8"WHIPSTOCK(05/18109) H 8616' 40 9-5/8"CSG,47#,L-80,13=8.681" --I —8616 MLLOUT WINDOW(F-44A)8616'-8633' I 8885' —I 4-1/2"HES X NIP,ID=3.813' a.--1 8906' —17"X 4-1/2"BKR S-3 FKR,113=3.875" • , I 8930' H4-1/2"HES X NP,ID=3.813" ir--1 8993' H4-1/2"I-ES XN * 13=3.725" TOP OF 4-1/2"LNR --I 8998' I-i $$$$' H X 5'ZXP L'TP w/11.4'TEBACK, =4.410" I 4-1/2"TBG,12.6#,13CR-80 VAM TOP, 9005' 9005' VVLE-G, =3.958" 1 .0152 bpf, =3.958" LI 8018' H 7"X 5"IllAC LNR HGR,0=4420' 7'LNR,260,L-80 BTC-M,.0383 bpf, =6.276" 9172' 9023' H5-X 4-1/2'X0, =3.920" PERFORATION SUMMARY REF LOG:Sperry ALD/CTNIFREWR ON 05/30/07 ANGLE AT TOP PERE:55°@9693' Note:Refer to Production DB for historical perf data SIZE SPF MERVAL Opn/Sqz SHOT SQZ 2-7/8' 6 9693-9703 0 09/25/11 3-3/8" 6 9859-9889 0 07/07/09 3-3/8" 6 9929-9959 0 07/07/09 2-7/8" 6 9990-10040 0 05/30/07 2-7/8" 6 10100-10160 (; 05/30/07 10080' I--I3-318"CIBP(047/07/09) 2-7/8" 6 10310-10360 U 05/30/07 2-7/8" 6 10460-10540 ( 05/30/07 PBTD — 10635' -44- 4-1/2"LNR,12.6#,L-80 IBT-M.0152 bpf,0=3.958" --I 10722' :111414 (WEE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02126/91 IMTIAL COMPLETION 09/23/09 GI-VJM) DRLG DRAFT CORRECTIONS VVELL: F-44A 06/02107 N2ES SIDETRACK(F-44A) 10/11/11 TIVVIPJC CEP/ADPERF(09125/11) PERMT No:"205161 06/29/07 /SV DRLG HO CORRECTIONS 09/11/13 PJC REFORIAAT SDETRACK AR No: 50-029-22130-01-00 02/09/08 RIAVPJC SFTY NOTE CORFECTION 09113/13'SVVC/PJC PULL WRP(09/11/13) SEC 2,T11N,R13E,3248'FN L&2199'FE 07/28/09 DVVW/PJC CORPS(07/07/09) 07/30/09 PJC FEE ORRECTIONS BP Exploration(Alaska) I • ` TE OF ALASKA ALASKA OIL ANDS CONSERVATION COMMISSION j E CEIVE D T 2 0 20 REPORT OF SUNDRY WELL OPERATIONS n 1. Operations Abandon El Repair Well ❑ Plug Perforations 0 Stimulate Al ktA�r as Uons, Cammissi0 Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension nil. ItCrierfige Lai Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ • 205 -1610 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 22130 -01 -00 8. Property Designation (Lease Number) : - 9. Well Name and Number: ADLO- 028280 . PBU F -44A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10722 feet Plugs (measured) 9748, 10080 feet true vertical 9040.77 feet Junk (measured) None feet Effective Depth measured 10635 feet Packer (measured) 8455 8906 8998 feet true vertical 9040.57 feet (true vertical) 7933 8345 8427 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 28 - 110 28 - 110 Surface 2658' 13 -3/8" 68# NT -80 27 - 2685 27 - 2685 5020 2270 Production 8590' 9 -5/8" 47# L -80 26 - 8616 26 - 8081 6870 4760 Liner 717' 7" 26# L -80 8455 - 9172 7933 - 8575 7240 5410 Liner 1724' 4 -1/2" 12.6# L -80 8998 - 10722 8427 - 9041 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ ..-.. — Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 25 - 9005 25 - 8433 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 8455 7933 4 -1/2" Baker S -3 Perm Packer 8906 8345 5" Baker ZXP Top Packer 8998 8427 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ? ` ` t � t��. 1 ' � f �.G 11 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 236 17,708 50 1,954 Subsequent to operation: 85 4,883 9 1,246 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 ,,, Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 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: NA Contact Joe Lastufka Printed Nam- , e Lastufk -_ Title Petrotechnical Data Technologist Sig natur1�m \c,____./ Phone 564 -4091 Date 10/20/2011 IF / Form 10-404 Revised 10/2010 ����� OCT 0�� / b ° 07'° /( Submit Original Only .•1 /0�6/// F-44A 205 -161 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base p p F-44A 5/7/07 PER 9,990. 10,040. 9,052.74 9,048.05 F-44A 5/7/07 PER 10,100. 10,160. 9,041.49 9,038.07 F-44A 5/7/07 PER 10,310. 10,380. 9,038.24 9,037.84 F-44A 5/7/07 PER 10,460. 10,540. 9,039.04 9,038.79 F-44A 3/6/08 BPS 9,789. 9,990. 9,024.96 9,052.74 F-44A 3/7/08 BPP 9,789. _ 9,990. 9,024.96 9,052.74 F-44A 7/6/09 BPS 10,080. 10,540. 9,043.69 9,038.79 F-44A 7/7/09 APF 9,859. 9,889. 9,045.83 9,050.72 F-44A 7/7/09 APF 9,929. 9,959. 9,053.29 9,053.53 F-44A 9/25/11 APF 9,693. 9,703. 8,979.85 8,985.5 F-44A 9/25/11 BPS 9,748. 10,080. 9,007.99 9,043.69 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER • BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE III M Y • • F -44A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/24/20111 ** *WELL SHUT IN ON ARRIVAL * ** (ELINE PE RF — PLUG) 1 INITIAL T /I /O= 930/1000/0 IRIH WITH MH22 /PGGT/ 3 -38" 3406 HSD 6 SPT 60 DEG PHASE, OAL =24' OAW =350# FISHING NECK SIZE= 1.38 ". TIE IN LOG SPERRY MWD LOG DATED 30— MAY -2007. UNABLE TO GET TOOL PAST 9650' TOOL HAS SOFT SET DOWN ATTEMPT AT `DIFFERENT SPEEDS, PE CALL TOWN TO DISCUSS OPTIONS. DECIDED TO ATTEMPT A 10' 2 -7/8" 2906 PJ, POOH WITH 3 -3/8" GUN ** *JOB CONTINUED ON 25— SEPT -11 * ** 9/24/2011; * ** WELL SHUT IN ON ARRIVAL * * ** RIH W/ QC,3 -3/8" DUMMY GUN,XO,S.BAILER,STOP DUE TO DEVIATION @ 9860' SLM. . RIH W/ QC,3.69" WRP DRIFT,STOP DUE TO DEVIATION @ 9858' SLM, RDMO. ' * ** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. * ** 9/25/2011; ** *JOB CONTINUED FROM 24— SEPT -11 * ** ;RIH WITH MH22 /EQF /UPCT/ 10' 2 -7/8" 2906 PJ 6 SPF 60 DEG PHASHING. CCL ' `TO TOP SHOT= 4.2', OAL =25', OAW =250# FISHING NECK SIZE- SHOOT 9693' -9703' TIE —IN LOG: SPERRY DGR /EWA/ALD /CTN MWD 30— MAY -2007. GOOD INDICATION OF FIRE POOH AND RETURN TO SURFACE TO RIG UP WRP PLUG VISUAL INDICATION OF SHOTS FIRED RIG UP TOOLS FOR WRP eRIH WITH MH22 /EQF /UPCT/ BAKER 10/ WEATHERFORD 4.5" WRP OAL= 23', OAW =300 #, FISHING NECK SIZE = 1.38" CCL TO ME= 8.6'. SET WRP W/ TOP OF : PLUG= 9748', MID— ELEMENT =9750, OAL =4'. GOOD INDICATION OF WRP SET POOH AND RETURN TO SURFACE iVISUAL CONFORMATION OF PLUG SET WELL LEFT SHUT IN SWAB, SSV, WING CLOSED AND OTG DSO NOTIFIED OF 4 ! DEPARTURE FINIAL T /I /0= 920/1000/0 ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 3 DIESEL 3 TOTAL TP EE' =' ` CIW WELLHEAD= McEVOY SAFETY NOTES: * ** ( I ME TBG* ** ACTUATOR = BAKERC -44A WELL ANGLE > 70° .# •22' KB. ELEV = 65.66' _BF. ELEV = 37.98' ' ' GAS LIFT MANDRELS KOP = 3500' Max Angle = 97° @ 10037 1 2184' I- 14 -1/2" HES X NIP, ID = 3.813" 1 Datum MD = 9532' Datum TVD = 8800' SS 13 -3/8" CSG, 68 #, NT 80, ID = 12.415" I-1 26$5' ' ST MD lV D DEV TYPE VLV LATCH PORT DATE 2 3379 3378 7 MMG DOME RK r 16 06/08/07 1 6046 5785 30 MMG SO RK 11 20 06/08/07 8455' H 9-5/8" X 7" BKR C2 ZXP LIP, ID = 6.26" I Minimum ID = 3.725" @ $993' ii 1 8473' 1--19 -5/8" X 7" BKR HMC LNR HGR, ID = 6.33" I 4 -1/2" HES XN NIPPLE i1 11 ►1 1 11 1 . 1 MILLOUT WINDOW (F -44A) 8616' - 8633' + ■ • 1 ' 8885' H 4 -1/2" HES X NIP, ID = 3.813" 1 A 1+ 8906' 1 X 4 -1/2" BKR S -3 PKR, ID = 3.875" I • • 0 ►• 8930' J4 - 1 /2 " HES X NIP, ID = 3.813" 01 11 • 1 , 8993' —14-1/2" HES XN NIP, ID = 3.725" 1 # / 8998' — ' 7" X 5" ZXP HCM BOT LTP, I9 -5/8" WHIPSTOCK (05/18/09) H 8616' I ►'•�∎j'■ �►,;� A ''',' w /HMC LNR HGR, ID = 4.410" ',,V1 411111# 9005' - 1/2" WLEG, 19-5/8" EZSV (05/17/09) I-1 8635' 1 4 ID = 3.958" I3 -1/2" TBG CUT (05115/09) I 8780' I 9023' I^ 5" X 4 -1/2" XO, *a* ID = 3.920" 4-1/2" TBG, 12.6 #, 13CR -80 VAM TOP, 8941' .0152 bpf, ID = 3.958" iI II '► lI 9 -5/8" CSG, 47 #, L-80, ID = 8.681" I 9156' 7" LNR, 26 #, L-80 9172' / :`+ BTC-M, .0383 bpf, il ♦�• 1. 11 _ t PERFORATION SUMMARY 1� ■0 REF LOG: Sperry ALD /CTN/FR/EWR ON 05/30/07 y 4 -1/2" SPECIAL CLEARANCE 9748' ANGLE AT TOP PERF: 78° @ 9859' f+ I ' ', • WRP (09/25/11) Note: Refer to Production DB for historical perf data ►4� 13-3/8" CIBP (07/07/09)1-1 10080' 1 SIZE SPF INTERVAL Opn /Sqz DATE / +1 2 -7/8" 6 9693 - 9703 0 09/25/11 ✓ ► ►1 N S t:� / t 1 1 PBTO i 10635' • • 3 -3/8" 6 9859 - 9889 C 07/07/09 11 441 11 11 3 -3/8" 6 9929 - 9959 C 07/07/09 10 4-1/2" LNR, 12.6 #, L -80 IBT -M — 10722' 2 -7/8" 6 9990 - 10040 C 05/30/07 i� �� � � � � � � ��t: .0152 bpf, ID = 3.958" 2 -7/8" 6 10100 - 10160 C 05/30/07 � uu♦ . 1 . 1 . .�tt�1 C 1 2 -7/8" 6 10310 - 10360 C 05/30/07 2 -7/8" 6 10460 - 10540 C 05/30/07 1 PBTD H 9810' ........ 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" F 1 9852 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/26/91 ORIGINAL COMPLETION 09/23/09 GH/JMD DRLG DRAFT CORRECTIONS WELL: F -44A 06/02/07 N2ES SIDETRACK (F -44A) 10/11/11 T W /PJC CIBP / ADPERF (09/25/11) PERMIT No: /1 205161 06/29/07 /SV DRLG HO CORRECTIONS API No: 50 -029- 22130 -01 -00 02/09/08 RLM/PJC SFTY NOTE CORRECTION SEC 2, T11 N, R13E, 3248' FNL & 2199' FEL 07/28/09 DWW /PJC CIBP /PERFS (07/07/09) 07/30/09 PJC PERF CORRECTIONS BP Exploration (Alaska) i ~... i t ~, ~ 4~' .~:+€ ~ ~ ~xtif1, 4 ,. :~ +r MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc STATE OF ALASKA ~~ i~6-u~ ~ ~~~ ~ ~~~ ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~~~- ~~~~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ r ~~ ~~ ~~~~~~ Performed: Aiter Casing ~ Pull Tubing~ Perforate New Pool ~ Waiver~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q~ Re-enter Suspended Well ~ A~~~~~`~~~ 2. Operator BP Expioration (Alaska), inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory ~ 205-1610 - 3. Address: P.O. Box 196612 Stratigraphic ~'~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22130-01-00 • 7. KB Elevation (ft): 9. Well Name and Number: 63.2 DF PBU F-44A ' 8. Property Designation: 10. Field/Pool(s): ADLO-028280 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10722 - feet Plugs (measured) None '~.\i'3\ t~' '~ true vertical 9040.77 - feet Junk (measured) None ~~L "` F Y Effective Depth measured 10635 - feet true vertical 9040.57 , feet Casing Length Size MD ND Burst Collapse Conductor 110 20" SurFace - 110 Surface - 110 Surface 2685 13-3/8" 68# NT-80 Surface - 2685 Surface - 2685 5020 2270 Production 8618 9-5/8" 47# I-80 Surface - 8916 Surface - 8081 6870 4760 Liner 7738 7" 26# L-80 8455 - 9172 7933 - 8575 7240 5410 Liner 1724 4-1/2" 12.6# L-80 8998 - 10722 8427 - 9041 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 9005' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BOT S-3 PKR _... 8906' .. _ . 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,~ ~r~ U~~ ~'' ~ ' ~ ~ . E s.~"~ ~lifr ~ ~~ ~F • 1~4 ' , , , c 1- Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1314 53333 ; 84 2044 Subsequent to operation: 1209 15388 120 1260 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory C~ Development ~- Service 1~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~~ Gas ~ WAG I~ GINJ ~~ WINJ ~" WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb ~ Title Data Management Engineer Signature ~ ~ Phone 564-4944 Date 7/14/2009 p~Ti Form 10-404 R vised 04/2006 Submit Ori inal Only ~~"~I~ I~l~ ~ui_, ~ ~ ~oos ~~~~~ ~~~~~i F~4A 205-161 PERF ATTACHMENT u Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F-44A 5/7/07 PER 9,990. 10,040. 9,052.74 9,048.05 F-44A 5/7/07 PER 10,100. 10,160. 9,041.49 9,038.07 F-44A 5/7/07 PER 10,310. 10,380. 9,038.24 9,037.84 F-44A 5/7/07 PER S~ 10,460. 10,540. 9,039.04 9,038.79 F-44A 7/26/07 BPS 9,810. 9,815. 9,032.38 9,034.02 F-44A 7/26/07 BPP 9,810. 9,815. 9,032.38 9,034.02 F-44A 3/6/08 BPS 9,789. 9,990. 9,024.96 9,052.74 F-44A 3/7/08 BPP 9,789. 9,990. 9,024.96 9,052.74 F-44A 7/6/09 BPS 10,080. 10,081. 9,043.69 9,043.58 F-44A 7/7/09 APF 9,859. 9,889. 9,045.83 9,050.72 F-44A 7/7/09 APF 9,929. 9,959. 9,053.29 9,053.53 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • r~ u ~ F-44A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ FLUIDS PUMPED ~ BBLS 35 DIESEL 144 BORAX 46 1 % KCL/SAFELUBE 10 GEOVISC 1329.5 1 % KCL 120 7# BORAX 1684.5 Total ~ ~ Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, June 22, 2009 1:54 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU F-44A / PTD # 205-161 H i Art, Please reference the following well: Well Name: PBU F-44A Permit #: 205-161 API #: 50-029-22130-01-00 Top Perf MD: 9990' Bottom Perf MD: 10540' This well began Production on June 6, 2009 Method of Operations is: Flowing Date of Test: 06/13/09 Hours Tested: 6 24-Hour Rate / Oil-Bbl: 106 24-Hour Rate / Gas-Mcf: 4,992 24-Hour Rate / Water-Bbl: 8 Test Rate / Oil-Bbl: 424 Test Rate / Gas-Mcf: 19,967 Test Rate / Water-Bbl: 32 Choke Size: 60 Gas-Oil Ration: 47,107 Flow Tubing Pressure: 1,850 Casing Pressure: 1,250 Oil Gravity-API: 30 ~~r~°~~ ~" ~~`~ 4 '` ~~~~ ~ ~a 6/30/2009 ~ ~~~7 DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2051610 Well Name/No. PRUDHOE BAY UNIT F-44A MD 10722 ND 9041 Completion Date 6/2/2007 Operator BP EXPLORATION (ALASFCA) INC API No. 50-029-22130-01-00 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ DATA INFORMATI~N Types Electric or Other Logs Run: DIR, GR / RES / NEU / DEN (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~ype meairrmi rvwnoer Name ~caie rviea~a no start stop ~n rceceivea ~ommenrs Rpt 15353 LIS Verification 8309 10722 Open 8/23/2007 LIS Veri, GR, FET, ROP ~D C Lis 1535~nduction/Resistivity 8309 10722 Open 8/23/2007 LIS Veri, GR, FET, ROP D C 16960/See~lotes ~~~~~ l~` ~~`~ ~~ 0 0 Open 9/30/2008 PDF, EMF and CGM graphics for ND and MD EWR Logs og Induction/Resistivity 25 Col 8644 10722 Open 9/30/2008 MD ROP, DGR, EWR, ALD, CTN Log Induction/Resistivity 25 Col 8107 9040 Open 9/30/2008 ND DGR, EWR, ALD, CTN _ ___. - _ _ ~ Well Cores/Samples Information: Name ADDITIONAL INFORMATION Sample Interval Set Start Stop Sent Received Number Comments Well Cored? Y N~ Daily History Received? Y~ Chips Received? ~~ Formation Tops ~ N Analysis / N Received? s ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2051610 Well Name/No. PRUDHOE BAY UNIT F-44A Operator BP EXPLORATION (ALASK/y INC MD 10722 ND 9041 Completion Date 6/2/2007 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-22130-01-00 UIC N Compliance Reviewed By: N.~.~ Date: Q~~ y~,~`~a ~_J ~ U ~ ~ WELL LOG TRANSMITTAL To: State of Alaska September 23, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: F-44A AK-MW-5042662 F-44A: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-22130-0 l 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-22130-01 Digital Log Images: 1 CD Rom 50-029-22130-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: ~ ~ Signed: ~ ~ ~ ~v5 -/~/ ~1~41~d ..,~ ~ ~ WELL LOG TRA.NSMITTAL To: State of Alaska July 17, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Ancharage, Alaska 99501 RE: MWD Formation Evaluation Logs: F-44A, AK-MW-5042662 1 LDWG formatted CD rom with verification listing. API#: 50-029-22130-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~ ~ ~y ~ ~~, . "A~ ~ i ~ 3 lS.~a~'" Date: ,~ ; ; ~ ~ ~, ~,-;,~ 7 Signed: ~~ ~ v ~ ~~`~~~~:Y~3 ~~~ ~"s S:~ ~.~/',i~3. ~v~~iYiE.n]:i~Ci~ ,ai,y t~^1;~.^~~{'~~ a65 -~~~ ~ ,~~s3 STATE OF ALASKA ~ ~~ ALASKA~IL AND GAS CONSERVATION COMMISSION ~ECElVED ~~UI. 0 5 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~,~a~ka Oil & Gas Cons. CQmmission IVnrhnr~na 1 a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. Well Class: 20AAC 25.105 2oaac zs.~,o ~ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aban , 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/2/2007 ~ 205-161 - 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 5/20/2007 50-029-22130-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 5/27/2007 PBU F-44A ' FNL, 2199 FEL, SEC. 02, T11 N, R13E, UM 3248 Top of Productive Horizon: 8• KB (ft above MSL): 63.2' 15. Field / Pool(s): 614' FNL, 2922' FEL, SEC. 11, T11 N, R13E, UM Ground (ft MSL): 34.7' Prudhoe Bay Field / Prudhoe Bay ~ Total Depth: 9. Plug Back Depth (MD+ND) Pool 1464' FNL, 3220' FE~, SEC. 11, T11N, R13E, UM 10635 9041 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+~/D) 16. Property Designation: Surtace: x- 652650 y- 5973564 Zone- ASP4 10722 9041 ADL 028280 ~ TPI: x- 651984 y- 5970906 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 651705 y- 5970050 Zone- ASP4 None 18. Directional Sunrey ~ Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electronic and rinted information er 20 AAC 25.050 N/A ft MS~ 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and pri ed information er 20 AAC 2 071): DIR, GR / RES / NEU / DEN ~~ L,// ds~ ~~6,c.~~1~ ~D~I ~'Jy(S ZZ. CASING, LINER AND CEMENTING ECORD CASING SETTIMG DEPTH MD SETfI1dG DEPTH ND }{OlE A~~f WT. PER FT. GRADE TOP BOTfOM TOP $OTTOM SIZE CEMENTING RECCIRQ PULLED ! 20" Surface 110' Surface 110' 13-3/8" 68# L-80 SurFace 2685' Surface 2685' 17-1/2" 3723 cu ft Permafrost 9-5/8" 47# L-80 Surface 1' Surface 8081' 13-3/8" 1887 cu ft Class'G' 7" 26# L-8 8455' 172' 7933' 8575' 8-1 /2" 213 cu ft Cla s'G' 4-1/2" 12.6# L-80 8998' 10722' 8427' 9041 6-1/8" 278 cu ft Class'G' 23. Open to production or inject ion? ~ Yes ^ No 24. Tuaiwc RECa~n If Yes, IISt @8CI7 I (MD+ND of Top & Bottom; Pe ~t@N21 Op211 rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9005' 8906' MD TVD MD ND 9990' - 10040' 9053' - 9048' ~5: ACio Fw-CTUR~ CEnnEtrr S4u~~ erG ~ 10100' - 10160' 9041' - 9038' , , , . 'I O31 O~ - I O3HO' 9038' - 9038~ DEPTH INTERVAL MO AMOUNT gc KIND OF MATERIAL USED 10460' - 10540' 9039' - 9039' 8635' Set EZSV 8616' Set Whipstock Freeze Protect w/ 155 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: PROOUCTioN FoR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing Casing Press: C,a~cui.aTeo OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVIN-API ~CORR~: Press. 24-HouR RAre• 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s Ac uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND 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 chips, photographs and laboratory analytical results per F~~~~~,1~~ None t~e~.~m5 B~~ ~u~ ~ ~ ~~~~ : ~,'L-~ !~!~ ~-(~ ~ Form 10-407 Revised 02/2007 ~ R f ~ ~ N~~NUED ON REVERSE SIDE ~ r V ZH. GEOLOGIC MARKERS ~LIST ALL FORMATIONS AN ERS ENCOUN7ERED~: Z9. FORMATION TESTS ~ NAME M ND WeIlTested. ^ 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 Permafro5t Base detailed test information per 20 AAC 25.071. Sag River 9174' 8577' None Shublik 9222' 8617' Shublik 9270' 8655' Shublik 9297' 867T Sadlerochit 9326' 8699' Top CGL 9494' 8833' Base CGL 9592' 8911' Zone 2B / 25N 9706' 8987' 23N 9838' 9041' Formation at Total Depth (Name): Zone 26 9706' 8987' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Su-veys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~/ / ' ~D~ Signed Terrie Hubble Title Technical Assistant Date ~~ PBU F-44A 205-161 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Kris Honas, 564-4338 Permit No. / A roval No. INSTRUCTIONS GFNew-i: This form is designed for submitting a complete and correct wel- 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 welt design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completety segregated. Each segregated pool is a completion. Irenn 4b: TPI (Top of Producing Interval). Ire~n 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 ND 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). ITea- 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 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. ITeM 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 , ~ ~ Printed: 6/4/2007 6:50:30 AM ~ ~ ' 13at~: Frc~r~n - T~a H~urs Taslc ~~~ a I~RT F~~ 5/9/2007 04:30 - 00:00 19.50 MOB P PRE 5/10/2007 00:00 - 04:00 4.00 MOB P 04:00 - 16:30 12.50 RIGU P 16:30 - 17:00 0.50 RIGU P 17:00 - 19:00 2.00 WHSUR P 19:00 - 20:00 1.00 WHSUR P 20:00 - 21:00 1.00 WHSUR P 21:00-00:00 I 3.00~ WHSURIP 5/11/2007 100:00 - 01:30 01:30 - 02:30 02:30 - 06:00 06:00 - 08:00 08:00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 13:30 1.50 WHSUR P 1.00 WHSUR P 3.50 WHSUR P 2.00 BOPSU P 0.50 BOPSU P 2.00 BOPSU P 1.50 BOPSU P 1.50 BOPSU P PRE PRE Start: 5/5/2007 Rig Release: 6/2/2007 Rig Number: PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Spud Date: 2/7/1991 End: 6/2/2007 Rig released from 09-15Ai at 0430 hours. Begin rigging down primary unit and satellite buildings. Lower derrick and move off of well. Stage satellite buildings on pad. Move rig from DS 09-15Ai to F-44A. Move rig sub to F-44A. Begin moveing satellite camp and buildings to F pad. Line up rig and lay herculite. Spot rig over well. PJSM. Raise derrick. PJSM. Bridle down. Hang tongs and rig up floor. PJSM. Jack and shim sub to get cellar doors down. Work on berms and pre spud checklist. The pits, camp, shop and out buildings arrived at 1300 hours. Remove jeep and spot pits, camp, shop and out buildings. Spot cuttings tank. Berm all required areas. Hook up lines. Hold pre spud safety meeting. Rig accepted at 1630 hours. Rig up second annulus valve and second kill line to 9-5/8" x 13-3/8" annulus. Rig up DSM lubricator. Pull BPV. Rig down DSM. No pressure on tubing, IA or OA. Establish injection rate at 6 bpm down 9-5/8" x 13-3/8" annulus. Pump 50 bbls seawater followed by 240 bbis 9.8 ppg brine at 6 bpm with 740 psi. Dropped down to 630 psi. Shut down pump. Pressure held at 180 psi. Shut in annulus and bleed down second kill line. Rig up circulating lines from tree through choke to cuttings tank. Circulate down tubing at 8 bpm with 930 psi. Did not clean up. Shut down and mix hi-vis sweep. Reverse circulate 10 bbls with seawater. Got back diesel and then cleaned up. Swap lines and pump long way. Pump hi-vis sweep followed by clean seawater at 10 bpm with 1400 psi. Got back gas and mud on bottoms up. Fluid did not clean up. Shut down. Bleed off and blow down lines. Well out of balance. Allow to u-tube and bleed off. Dry rod TWC. Line up and test tubing, IA and TWC from below to 1000 psi for 30 minutes. Test OK. Monitor OA, no pressure. Bleed off and blow down lines. Nipple down adapter and tree. Remove tree from cellar. Check hanger neck threads. Took 6-1/2 turns by hand. Threads in good shape. Nipple up BOP stack. Make up test equipment for BOPE test. IA at 300 psi. Rig up line to cuttings tank and bleed off pressure, with 7 bbls crude and gas flowing back. Shut in for 30 minutes. Pressure built up to 130 psi. Bleed off 1/2 bbls crude then gas. Shut in and monitor pressure for 30 minutes. Pressure at 60 psi. Bleed off gas no fluid. Monitor for 15 minutes. OK. Rig up to test BOPE. Attempt to test BOPE. TWC is not holding. Open blinds and monitor well. Fluid boiling up in BOP stack. Close blinds and attempt to seat TWC, would not seat. Fluid still boiling up. Shut well in and monitor pressures. Tubing with 100 psi, annulus with 20 psi after 15 minutes. Bleed annulus and tubing off, all gas. Open blinds. Fluid static, no gas detected. Printed: 6/M2007 6:50:36 AM . ~ ! Legal Well Name: Common Well Name: Event Name: Contractor Name: ' Rig Name: 5/11/2007 I 13:30 - 15:00 F-44 F-44 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 1.50 Spud Date: 2/7/1991 Start: 5/5/2007 End: 6/2/2007 Rig Release: 6/2/2007 Rig Number: DECOMP 15:00 - 17:00 2.00 BOPSU P DECOMP 17:00 - 19:00 2.00 BOPSU P DECOMP 19:00 - 20:00 1.00 BOPSU P DECOMP 20:00 - 00:00 I 4.00 I BOPSUFI P I I DECOMP 15/12/2007 100:00 - 01:30 I 1.501 BOPSUp P I I DECOMP 01:30 - 03:30 I 2.001 BOPSUFi P I I DECOMP 03:30 - 04:30 I 1.001 BOPSUR P I I DECOMP 04:30 - 13:00 I 8.50 ~ BOPSUF~ P I I DECOMP 13:00 - 15:00 I 2.001 BOPSUR P I I DECOMP 15:00 - 18:00 I 3.001 PULL I P I I DECOMP 18:00 - 00:00 I 6.001 PULL I P I I DECOMP Make up XO and TIW to a joint of 4" DP. Screw into hanger. Body test BOP stack to 250 psi low, 2500 psi high. Test witness waived by Bob Noble with AOGCC. Crack open TIW on top of tubing. Gas pressure present. Bleed off. Pull 4" DP joint. Break out TIW and XO and lay down. Close blind rams. Monitor tubing. Built up 75 psi. PJSM. Bleed off pressure and drain stack. Monitor tubing and change upper rams to 7". No pressure build up. Make up TIW and XO's to 4" DP. Screw into hanger neck. Fill with water and shut TIW. Body test door seals to 250 psi low and 2500 psi high. No pressure in 4" DP. Rig up DSM lubricator and extension. Attempt to pull TWC. Unable to screw in. Check for pressure, 95 psi on lubricator. Line up and bleed off through choke with 9 bbls crude/water coming back. Monitor well. Pull lubricator with out TWC. Make up joint of 4" DP and flush BOP stack and top of TWC. Install lubricator. Still unable to engage TWC. Check pressure and pull out lubricator. PJSM. Open hydril and remove lubricator. Check DSM retrieval tool. Change out and RIH. Close hydril and screw in TWC. Line up to choke and unseat plug, 80 psi on tubing. Bleed to zero through choke to degasser. Break down lubricator and lay down extension. PJSM. Close blinds. Line up to circulate to cuttings box. Circulate 9.8 ppg brine through tubing cut at 120 gpm with 120 psi. Circulate 9.8 ppg brine to surface. Returns back with crude/mud/diesel and gas. Monitor well 15 minutes. Verify dead. Rig down circulating lines and blow down choke and choke line to cuttings box. Dry rod TWC and set. Verify set with 5-1/2 turns. Fill stack, close blinds and both HCR's. Test against TWC to 250 psi low, 3500 psi high. Test OK. Lay down DSM lubricator and tools off floor. PJSM. Fill choke and begin testing BOPE. Test to 250 psi low, 3500 psi high. Test hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Bob Noble with AOGCC. Change out top rams to 3-1/2" x 6" variable. Pick up 3-1/2" test joint. Test top rams and hydril. Make up 4" test joint and test upper IBOP and outer mud cross. Lay down test joint. Blow down equipment. Rig up circulating line to IA. Test casing and tubing below TWC to 2500 psi for 30 minutes. Test OK. Bleed off and check for pressure. Rig up DSM lubricator and extension. Pull TWC. Monitor well. Lay down lubricator assembly. Line up on IA and lower mud cross. Close blinds and reverse circulate 145 bbis of 9.8 ppg brine at 210 gpm with 500 psi. Take returns to cutting box. Monitor well for 45 minutes. Small stream diminished to trickle. Install low pressure gauge on annulus. Shut in to monitor for any build up. No pressure on both sides after 1 hour. PJSM. Finish rigging up spooling unit. Make up landing joint. Back out lock down screws. Unseat hanger with 50k. Pull hanger to floor. Up weight 47k. Break top drive. Flowing back. Printed: 6/4/2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common W ell Name: F-44 Spud Date: 2/7/1991 Event Nam e: REENTE R+COM PLET E Start : 5/5/2007 End: 6/2/2007 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 6/2/2007 Rig Name: NABOR S 2ES Rig Number: [3ate , Frc~rn - To' , .. Mc~urs~ Task. C~a~e I~PT, Ph~~`" . W ~~~~ript'i~n ~rf :C3p~rafic~~is a ~ , ~G ~ ; -~ TE; 5/12/2007 18:00 - 00:00 6.00 PULL P DECOMP Mix and pump dry job with no success. Circulate around for light spot. Shut down. Break and lay down hanger and landing joint. Change out elevators. Blow down top drive. Pull 3-1/2" tubing with control line. Recovered 64 full joints and cut joint at 21.19', 32 bands, 32 pins, 2 SS bands and 3 pup joints totaling 23.99'. ~i5/13/2007 00:00 - 01:30 1.50 PULL P DECOMP PJSM. Rig down tubing handling equipment. Lay down 3-1/2" !, tubing pups. Clean and clear fVoor. Pick up test plug and wear ring running tool. 01:30 - 05:00 3.50 BOPSU P DECOMP PJSM. Pick up 3-1/2" test joint. Set test plug. Test bottom rams. Test not holding. Run in lock down screws. Test again. Test not holding. Pull test plug and tighten. Run back in hole. Check for leaks. Test again. Test good. Pull and lay down 3-1/2" test joint. Pick up and run in 4" test joint. Test lower and upper rams. Test all to 250 psi low, 3500 psi high as per AOGCC. Test witness waived by Bob Noble with AOGCC. Pull test joint and lay down. 05:00 - 05:30 0.50 BOPSU P DECOMP Run in wear ring. Lay down tools and clear floor. 05:30 - 06:30 1.00 FISH P DECOMP PJSM. Pick up BHA. 06:30 - 09:00 2.50 FISH P DECOMP PJSM. Pick up drill collars and make up washpipe BHA to 310'. Change out handling equipment. 09:00 - 10:30 1.50 FISH P DECOMP PJSM. Pick up drill pipe to 2086'. Tag stump at 2091'. ~i 10:30 - 12:00 1.50 FISH P DECOMP Make up top drive. Establish circulation at 130 gpm with 75 psi. ' Wash down to 2091'. Mill over stub to 2099'. Pick up and slide ' over with no rotary. Up, down and RT weight 75k. Break out ' single and lay down. Blow down top drive. ' 12:00 - 13:30 1.50 PULL P DECOMP POOH with 4" DP to 310'. 13:30 - 15:00 1.50 PULL P DECOMP Stand back drill collars. Break shoe, extension and triple connection. Recovered -20' of control line. Lay down mill tools. Pick up overshot tools. 15:00 - 16:00 1.00 FISH P DECOMP Make up overshot assembly and BHA to 307'. 16:00 - 17:00 1.00 FISH P DECOMP Run in hole to 2083' and pick up single. Up,down and RT weights 75k. Torque at 1 k with 50 rpm. 17:00 - 17:30 0.50 FISH P DECOMP Circulate BU at 500 gpm with 750 psi. Slow pump to 42 gpm. Tag top of fish at 2091'. Swallow 6' of stump. Attempt to release K anchor with max torque of 4k at 110k down to 150k. ~ No release. Let out torque. Pull 125k and rotate 7 turns to the left. Backed off at 5k torque with weight indicator at 95k. Approximately 20k of additonal string weight on indicator. 17:30 - 19:00 1.50 PULL P DECOMP Pull to 1697'. Well began to u-tube up drill pipe. Unable to circulate long way. Install TIW valve. Rig up circulating lines and reverse circulate 170 bbls of clean seawater at 168 gpm with 750 psi. Stop pump. Well stable. Blow down circulating lines. POOH to 307'. 19:00 - 22:00 3.00 PULL P DECOMP Stand back drill collars. Lay down jars and bumper sub. Remove several feet of wadded up control line from fish. Control line still connected to fitting on SSSV. 22:00 - 00:00 2.00 PULL P DECOMP PJSM. Pick up power tongs and re-hang make up rig tongs for back up. Break pup joint from overshot with weight and rotation. Pull 3-1/2" tubing. 5/14/2007 00:00 - 03:30 3.50 PULL P DECOMP PJSM. Continue pulling and laying down 3-1/2" tubing. Total full joints 74, one cut joint at 10.45', 1 GLM and 1 SSSV. Recovered the last 2 SS bands. Rig down casing equipment. Printed: 6/4/2007 6:50:36 AM ~ ~ !Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: F-44 F-44 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS2ES Spud Date: 2/7/1991 Start: 5/5/2007 End: 6/2/2007 Rig Release: 6/2/2007 Rig Number: 5/14/2007 00:00 - 03:30 3.50 PULL P DECOMP 03:30 - 04:30 1.00 PULL P DECOMP 04:30 - 05:00 0.50 PULL P DECOMP 05:00 - 06:00 1.00 PULL P DECOMP ' 06:00 - 08:00 2.00 PULL P DECOMP 08:00 - 09:30 1.50 PULL N WAIT DECOMP 09:30 - 10:30 1.00 PULL P DECOMP 10:30 - 11:00 0.50 PULL P DECOMP 11:00 - 11:30 0.50 PULL P DECOMP 11:30 - 17:00 5.50 PULL P DECOMP 17:00 - 18:30 1.50 PULL P DECOMP 18:30 - 20:30 2.00 PULL P DECOMP 20.30 - 00:00 3.50 PULL P DECOMP 5/15/2007 00:00 - 04:00 4.00 PULL P DECOMP 04:00 - 06:00 2.00 PULL P DECOMP 06:00 - 08:00 2.00 CLEAN P DECOMP 08:00 - 09:30 1.50 CLEAN P DECOMP 09:30 - 14:00 4.50 CLEAN P DECOMP 14:00 - 16:30 2.50 CLEAN P DECOMP 16:30 - 17:30 1.00 CLEAN P DECOMP 17:30 - 20:00 2.50 BOPSU P DECOMP 20:00 - 00:00 4.00 BOPSU P DECOMP Clear and clean floor. Pick up overshot BHA. Make up overshot BHA. RIH to1784'. PJSM. PU drill pipe and RIH to top of tubing at 4487'. Lay down single and make up top drive. Waiting on fluid trucks for disp~acement. PJSM. Bring SWS tools up beaver slide. Clear floor. PJSM. Displace well with clean seawater at 504 gpm with 1078 psi. Break out top drive and blow down. Pick up a joint of DP. Make up top drive. Establish torque of 1 k. Up, down and RT weights 95k. Slack off on tubing stub to 15k. Latch with up weight of 120k. Torque to 4k with 140k up weight. Release torque slack off and set slips with 125k. Break and lay down single. PJSM. Rig up SWS pump in sub, packoff assembly, firing head and cutter assembly. RIH with jet cutter on E-Line. Locate collars and fire cutter at 8780' E-line measurement. Monitor well. No flow or pressure. POOH with wireline. Confirm tubing free with 130k up weight. Break down packoff and XO's. Rig down SWS. Displace well to clean seawater at 450 gpm with 925 psi. POOH with fish to 4300'. Break and lay down overshot. PJSM. Change out handling equipment and rig up Yubing equipment. Lay down tubing from 4300'. Recovered 84 full joints and 1 GLM. PJSM. Pull and lay down 3-1/2" tubing. Pull 103 joints. Well out of balance. Rig up floor valve head pin and pump slug. Shut down, no flowback. Continue to pull tubing. Pull a total of 135 full joints, 3 GLM and 1 cut joint of 21.68'. Clean cut. Rig down casing equipment. Clear and clean floor. Lay casing equipment down beaver slide. PU tools for clean out BHA. PJSM. Make up Cleanout BHA to 323'. Change out handling equipment. RIH to 4803'. Make up top drive. Establish circulation at 400 gpm with 955 psi. Break out top drive and blow down. PJSM. Pick up drill pipe, RIH and tag tubing stub at 8780'. Lay down 2 singles and rack 1 stand back. Circulate surface to surface at 450 gpm with 1725 psi. Some gas in returns. Monitor well 15 minutes. Weli dead. Rig up circulating lines to OA. Fluid pack annulus with 20 bbls of 9.8 ppg brine. Blow down lines. Monitor well. Annulus dead. PJSM. Pick up and make up RTTS on a single of DP. RIH and set at 38'. Up weight 185k, down 160k. Line up and test from below to 1000 psi for 10 minutes. Test OK. Bleed off. Back out running tool and lay down. Pull wear ring. Make up packoff running tool. Back out lock down screws. Engage and work packoff. Max pull 105k. Double check lock down screws. Purge both test and packing voids. Still will not pull free. PJSM. Nipple down and split tubing head flange. Stand back stack. Remove tubing spool with packoff stuck inside. Remove Printed: 6/4/2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 5/15/2007 20:00 - 00:00 4.00 BOPSU P DECOMP old tubing spool from cellar. Bring new McEvoy tubing spool into cellar. Clean up 9-5/8" casing stub and flange. Make up packoff running tool on single joint of DP. 5/16/2007 00:00 - 04:00 4.00 BOPSU P DECOMP PJSM. Make up running tool and install new 9-5/8" packoff assembly. Run in lock down screws. PJSM. Install new tubing spool and PU stack to push tubing spool past packoff seals. Nipple up tubing spool and stack. Torque up tubing spool. 04:00 - 04:30 0.50 BOPSU P DECOMP Test pack off void to 5000 psi for 30 minutes. Good test. 04:30 - 07:00 2.50 BOPSU P DECOMP Torque BOP stack. Flange up valves and flow line. Rig up to test stack break to 250 psi low and 3500 psi high as per AOGCC. 07:00 - 10:00 3.00 BOPSU N SFAL DECOMP PJSM. Test spool against blinds and RTTS to 250 psi low, 3500 psi high. Leaked off. Tubing annulus valve leaking around stem. Attempt greasing and functioning. Run test again with no success. Call out DSM. Install new stem packing. Test again. Test OK. Test secondary annulus valve. Test OK. 10:00 - 13:00 3.00 DHB P DECOMP PU DP single. Make up TIW and RTTS retrieval tool. Unable to engage tool. Back out and make up top drive. Circulate on top of RTTS to clean up. Break out top drive. Make up retrieval tool and jay into RTTS with 20 rounds. Open TIW. No pressure. Break out TIW and make up top drive. Close bag. Open kill line. Release RTfS with 250k. Bleed returns to zero. Open bag. Monitor well. Well dead. Establish circulation at 400 gpm with 1500 psi. Circulate bottoms up. Pull, break and lay down RTTS, XO and DP single. 13:00 - 14:30 1.50 CLEAN P DECOMP PJSM. Slip and cut 97' of drilling line. Inspect traction motor brushes. Lube Elmago Splines. Grease, inspect and adjust brakes. 14:30 - 15:00 0.50 CLEAN P DECOMP Inspect and service top drive and crown. 15:00 - 18:30 3.50 CLEAN P DECOMP Pump dry job. POOH to 325'. 18:30 - 21:00 2.50 CLEAN P DECOMP POOH with BHA. Stand back drill collars. Clean out junk baskets. Recovered 4 gallons of scale and several pieces of tubing control lines. Decision made to run GR/JB on wireline before setting EZSV. Lay down rest of baker BHA. Clear and clean floor. 21:00 - 00:00 3.00 DHB P DECOMP PJSM. Spot and rig up SWS. Run GR/JB on E-line. SIMOPS with LRS freeze protecting 9-5/8" X 13-3/8" annulus with 130 bbls of dead crude. 5/17/2007 00:00 - 07:00 7.00 DHB P DECOMP Run GR/JB to 8700'. POOH. JB empty. Pick up EZSV and run in hole. SIMOPS with LRS. Pumped 140 bbls crude down 9-5/8" X 13-3/8" annulus. Bleed to 100 psi with 10 bbls back. Bleed to 0 with a total of 11 bbis back. Shut down LRS at 0300 hours. Run EZSV to 8700'. Log for collar with CBUGR. Unable to discern collars below 8300'. Possible corrosion causing magnetic interference. Re-evaluate logs. Attempt to locate casing tally in original well file. No casing ta~ly available on slope. POOH. 07:00 - 13:00 6.00 DHB P DECOMP Run back in hole with CAL-B collar locator. Correlate collars on log with physical pipe talley from town. POOH. Break down tool. Pick up EZSV & running tool. RIH with EZSV to 8635' and set (Collar @ 8641'). POOH with SWS and rig down. 13:00 - 14:00 1.00 DHB P DECOMP Test EZSV to 3500 psi for 30 minutes. Record casing test data for correlation with upcoming FIT data. Test OK. Printed: 6/4/2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 5/17/2007 14:00 - 17:30 3.50 STWHIP P WEXIT PJSM. Pick up and make up whipstock assembly. Scribe offset. Upload MW D. Make up bumper sub, jars and XO to 396'. Pick up 1 stand of DP and test MWD with 400 gpm at 750 psi. 17:30 - 21:30 4.00 STWHIP P WEXIT RIH to 8521'. Fill pipe and test MWD every 3000'. Remove airslips. 21:30 - 23:00 1.50 STWHIP P WEXIT Pump at 455 gpm with 2000 psi. Orient to 70 degrees right. Down weight 158k, up weight 193k. Set depth. Tag plug and attempt to set anchor at 8635'. Put 15k down. Anchor appeared to set when pipe bumped. Pull up with string weight. No overpull or indication of anchor set or release of shear bolt. Set back down with 15k. Pipe going 2' deeper. Suspect EZSV slipped down 2'. Pull up with string weight. Bumper sub opening with 185k, sub traveling 3' with steady 185k then moving up to string weight of 190k. No overpull. Set down with 15k, again with 25k and again with 30k. Each time, no indication of setting and only string weight pulling back up. Bumper sub travel noted each time. Shut down for consultation with team members. 23:00 - 00:00 1.00 STWHIP N DFAL WEXIT Pressure up and test casing integrity with 3500 psi for 5 minutes. Test OK. Retry anchor set. Put 30k down on plug with no indication of whipstock anchor setting. Pull up with indication of bumper sub travel then string weight up. No overpull. Shut down and prepare to POOH with whipstock assembly. 5/18/2007 00:00 - 05:00 5.00 STWHIP N DFAL WEXIT POOH pumping at 453 gpm with 1985 psi. Pull through 2 collars with orientation in case whipstock hangs up. Pull through with no problems or indications of hanging up. Shut down. Blow down top drive. Remove blower hose. POOH to 374'. Up weight 190k. 05:00 - 08:30 3.50 STWHIP N DFAL WEXIT Stand back drill collars, MWD and mills. No whipstock slide. Monitor weli. Clear and clean floor. PJSM. Pick up miils, MW D and RIH. Download MWD. Break off TM collar, lay down MWD tools and bumper sub. RIH with drill collars to 319'. 08:30 - 12:00 3.50 STWHIP N DFAL WEXIT RIH to 8538'. Fill pipe every 30 stands. Make up single of DP. Install blower hose. PU last stand. Fill pipe and tag whipstock slide at 8616'. Down weight 155k, up weight 190k, RT 172k with 5k torque at 60 rpm. 12:00 - 13:30 1.50 STWHIP P WEXIT Pump 50 bb~ hi-vis spacer. Follow and displace with 10.4 ppg LSND mud at 295 gpm with 1000 psi. 13:30 - 00:00 10.50 STWHIP P WEXIT Mill 8-1/2" window in 9-5/8" casing. Pumping at 330 gpm with 1070 psi. Torque off bottom 5k, on bottom 6-9k. WOB 7-9k, Up weight 172k, down 150k, RT 164k. SPR's at 8600' at 1400 hours. Pump #1 30/350, 45/400. Pump #2 30/340, 45/400. Top of window at 8616', bottom at~ 8633_. From middle of window to 20' of new formation will be 8644'. At 1500 hours OA at 500 psi, at 1530 hours OA at 850 psi. Bleed off with 1 bbl of crude and gas back. Loosing 10 bph while milling window. Losses started as soon as casing was penetrated. Minimal cement trace observed at surface. Pumping LCM for treatment. Both pump screens plugged up with LCM at 1930 hours. Pumping at 400 gpm with 1350 psi. Total metal recovered for tour 175 Ibs. Mud weight in and out 10.4 ppg. Up weighY 174k, down 155k, Printed: 6/4/2007 6:50:36 AM s~ +~ Legal Weli Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 5/18/2007 13:30 - 00:00 10.50 STW HIP P W EXIT RT 164k. Losses of 73 bbls for tour. 5/19/2007 00:00 - 06:00 6.00 STWHIP P WEXIT Continue milling to 8644'. Torque 5100 to 5400. RPM at 40 to 120. WOB 8 to 20k. Pump at 330 to 500 gpm with 1050 to 1920 psi. Up weight 172k, down 150k, RT 164k. Finished milling 20' of new formation for FIT. 06:00 - 08:00 2.00 STWHIP P WEXIT Pump super sweep surface to suface. Ream and drift window. Pump 20 bbl, 50 ppb LCM pill and spot on bottom. Pull 3 stands. 08:00 - 08:30 0.50 STWHIP P WEXIT Line up and perform FIT to 11.57 ppg EMW with 490 psi. 08:30 - 12:00 3.50 STWHIP P WEXIT Pump dry job. Remove blower hose. Install air slips. Mud weight in and out 10.4 ppg. POOH to 319'. 12:00 - 15:00 3.00 STWHIP P WEXIT PJSM. POOH with BHA. Clean and clear floor. Lay down milling tools. Pick up test joint. Make up wear ring running tool. and pull wear ring. PU Johnny Wacker. Function all rams on stack. MU Johnny Wacker and top drive. Flush stack at 450 gpm with 80 psi. 15:00 - 15:30 0.50 STWHIP P WEXIT Break out top drive and blow down. Break out Johnny Waker and lay down. Make up wear ring running tool. Install wear ring. Lay down test joint and clear floor. 15:30 - 17:00 1.50 STWHIP P WEXIT PJSM. Pick up drilling BHA. 17:00 - 20:30 3.50 STWHIP P WEXIT PJSM. Pick up motor. Make up bit and BHA to TM collar. Scribe tool. Upload MW D. Continue to pick up BHA to 823'. Cross over to 4" DP. 20:30 - 21:00 0.50 STWHIP P WEXIT Make up top drive and surface test MWD at 242 gpm with 825 psi. Good test. Break down and blow down top drive. 21:00 - 22:30 1.50 STWHIP P WEXIT PJSM. Pick up enough 4" DP to TD well. Tota! of 72 joints at 3060'. 22:30 - 00:00 1.50 STWHIP P WEXIT RIH to 6422' filling and testing MWD every 30 stands. Pumping at 426 gpm with 1648 psi. Up weight 150k, down 125k. Totall losses for lat 24 hours 67 bbls. 5/20/2007 00:00 - 01:00 1.00 STWHIP P WEXIT PJSM. Continue running in hole to 8568' 01:00 - 03:00 2.00 STWHIP P WEXIT PJSM. Slip and cut 56' of drilling line. Adjust brakes. Service and lube top drive. 03:00 - 04:00 1.00 STWHIP P WEXIT RIH to 8644'. Set ECD benchmarks. Rotate at 60 rpm, pumping at 425, 450 and 475 gpm with 10.7 ppg ECD at alf pump rates. Rotate at 80 rpm, pumping at 425, 450 and 475 gpm with 10.7 ppg ECD at all pump rates. No losses on trip in hole. 04:00 - 17:30 13.50 DRILL P INT1 Directional drill ahead to 8723'. Up weight 190k, down 155k, RT 175k. WOB 10-17k. Pump at 450 gpm with 2050 psi off bottom, 2245 psi on bottom. Directional drill ahead to 9172'. Pump at 450 gpm with 2320 psi off bottom, 2609 psi on bottom. WOB 10k. Torque off bottom 6-7k, on bottom 8k at 80 rpm. Up weight 195, down 158, RT 175k. Calculated ECD 10.7, actual 10.97. 17:30 - 18:30 1.00 DRILL P INT1 CBU for samples at 9172'. Geologist calling TD at 9172' MD, 8575' ND. Up weight 210k, down 155k. Pump up survey on bottom. SPR's, #1 30/390, 45/470, #2 30/370, 45/470. Calculated ECD 10.7, actual 10.84, Shut down. Monitor weli. Well dead. 18:30 - 19:30 1.00 DRILL P INT1 Mud weight in and out 10.4 ppg. POOH to 8644' with no problem. Hole taking proper fluid displacement. 19:30 - 21:30 2.00 DRILL P INT1 MAD pass from 8644' to 8350' at 600 fph. No problems through Printed: 6/4/2007 6:50:36 AM ~ ~ 'iLegal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 , Rig Name: NABORS 2ES Rig Number: 5/20/2007 19:30 - 21:30 2.00 DRILL P INT1 window. Clean floor and prep for slip and cut. 21:30 - 00:00 2.50 DRILL P INT1 PJSM. Slip and cut 73' of drilling line. Service drawworks, clutches, and top drive. 5/21/2007 00:00 - 01:00 1.00 DRILL P INT1 PJSM. RIH to 9172' with no problems. 01:00 - 03:00 2.00 DRILL P INT1 Stage pumps up to 450 gpm wtih 2400 psi. Rotate at 100 rpm with 6-7k torque. Calculated ECD 10.7, 11.0 before bottoms up, 10.79 at finish. Pump sweep surface to surface until clean. Up weight 205k, down 165k, RT 175k. Pump dry job and drop i rabbit. 03:00 - 06:30 3.50 DRILL P INT1 Mud weight in and out 10.4 ppg. PJSM. POOH to 8550' inside casing with no problems. Up weights on each stand, 210k to window, down weights 160k from 9172' to 8941' and 155k from 8941' to 8598'. Continue to POOH to 823'. 06:30 - 10:30 4.00 DRILL P INT1 PJSM. Lay down 8-1/2" intermediate BHA. Flush MWD with fresh water. PJSM. Clear and clean floor. Lay tools down beaverslide. 10:30 - 11:30 1.00 CASE P LNR1 PJSM. Pick up casing tools to rig floor. Rig up to run 7" liner. 11:30 - 14:00 2.50 CASE P LNR1 PJSM. Pick up and run 7", 26#, L-80, BTC-M liner to 726'. Change out handling equipment. Lay down casing equipment. Pick up and make up DP pups. 14:00 - 15:00 1.00 CASE P LNR1 Make up top drive. Circulate 1.5 times liner volume at 100 gpm I with 80 psi. Break out and biow down top drive. Up and down weight 45k. 15:00 - 19:30 4.50 CASE P LNR1 PJSM. RIH to 8591' filling every 20 stands. 19:30 - 21:00 1.50 CASE P LNR1 Make up top drive. Establish circulation. Stage pumps up to 210 gpm with 644 psi. Circulate surtace to surface. Hoid PJSM with SCH and Baker. Make up cement head. Prepare to run , into open hole. Up weight 175k, down 145k at top of window. 21:00 - 22:00 1.00 CASE P LNR1 RIH to 9120' with no problems. At 9120' taking weight at 30k down. Pull back up breaking over with 220k, up weight 190k. '~ Work pipe down to 9142'. Make up top drive. Stage up pumps. Pump at 132 gpm with 643 psi. Pump down to 9148'. Circulate for 5 minutes. Up weight 190, down 145k. Break out top drive and blow down. 22:00 - 23:00 1.00 CASE P LNR1 Pick up and make up cement head and manifold. Rig up hoses. Establish circulation at 120 gpm with 600 psi. Work pipe I down to 9172'. Pick up and slack off to verify bottom. Stage ' pumps up to 168 gpm with 743 psi then 210 gpm with 900 psi. Pump 1600 strokes. 23:00 - 00:00 1.00 CEMT P LNR1 Switch over to cementers. Pump 5 bbls water. Pressure test lines to 4000 psi. Test OK. Displace 5 bbls water to flow line with Mudpush II. Switch valves and pump downhole with 20 bbls Mudpush II. Swap over to cement. Pump 38 bbls of Class G, 15.8 ppg tail cement at 3.3 to 52 bpm with pressures ~, between 938 and 1016 psi. Drop plug and kick out with 5 bbls I water. Plug drop verified. Switch over to rig pumps. Bring pumps up to 210 gpm. At 400 strokes 570 psi, 800 strokes 558 psi, 1030 strokes 517 psi. Latch up at 1298 strokes/79 bbis with 1300 psi. At 1400 strokes pressure at 980 psi. Bump plug at 2400 hours with 1709 strokes/103 bbls. CIP at 0000 hours. 5/22/2007 00:00 - 01:30 1.50 CEMT P LNR1 Pressure up to 3500 psi and set hanger. Slack off to 105k and Printed: 6/M2007 6:50:36 AM ~ ~ 'iLegal Well Name: F-44 'Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 !~ Rig Name: NABORS 2ES Rig Number: 5/22/2007 I 00:00 - 01:30 I 1.50 ~ CEMT I P 01:30 - 02:30 1.00 CEMT P 02:30 - 05:00 2.50 CEMT P 05:00 - 05:30 0.50 CEMT P 05:30 - 06:00 0.50 DRILL P 06:00 - i0:00 4.00 DRILL P 10:00 - 14:00 ( 4.001 DRILL I P 14:00 - 14:30 I 0.501 DRILL I P 14:30 - 15:30 1.00 CASE P 15:30 - 19:00 3.50 DRILL P 19:00 - 22:30 ~ 3.50 ~ DRILL ~ P 22:30 - 23:30 I 1.001 DRILL I P 23:30 - 00:00 I 0.501 DRILL I P 5/23/2007 00:00 - 00:30 0.50 DRILL P 00:30 - 01:30 1.00 DRILL P LNR1 bleed off. Float check, floats holding. Turn 20 to the right to back off running tool. Pressure up to 1000 while pulling up. Running tool release verified with pressure drop. Bring pump rate up and circulate 30 bbls up hole. Slow down pumps and set down 50k while rotating to the right to verify packer set. Set OK. Pick up off packer and increase pump rate to circulate out cement. No losses during job. Circulate bottoms up at 425 gpm with 2030 psi. No discemable cement back. High PH of f 1.1 back with cement stringers. Pick up tools for 6-1/8" production section. LNRi PJSM. Rig down cement head. Pump dry job. LNR1 POOH to running tool. LNR1 Lay down tools. Change out handling equipment. PROD1 Clear and clean floor. PROD1 Make Up BHA #4 -6 1/8" Bit, 4 3/4" PDM, Float sub, Stab., LWD / MWD, 3 x NM Flex DCs, Cire sub, # x HWDP, Jar, 2 x HWDP PROD1 RIH to 8980' Breaking Circ @ 290 gpm -3176', 1950 psi -5975', 1990 psi PR001 Precautionary wash down to 9057' -291 gpm / 2460 psi, 20 rpms / 4k Tq. Tag TOC @ 9018', No problems washing down to Landing collar PROD1 Test 7" casing to 3500 psi for 30 minutes, Good Test -Recorded and charted Test PROD1 Drill out cement, Landing collar and float collar -cleaned out shoe tract from 9057' - 9167' -290 gpm C~ 2550 psi - 40 rpm ~ 4-5k ft/Ibs of Torque WOB 5-10k PUW- 180k SOW-137k RtWt - 155k PROD1 Displace 10.4 ppg LSND mud with 8.4 SF Flo-Pro -Pump 144 bbls of fresh water, followed by 40 bbls of Hi-Vis pill -displaced well with 870 bbls of Solids Free Flo-Pro After clean mud back to surface, shut down pumping and clean surface equipment 8.4 ppg solids free Flo-Pro in and out PROD1 Drill out shoe and 20' of New Hole -274 gpm - 1580 psi (off) / 1660 psi (on btm. -WOB 5-10k -40 rpm / 2-3k Torque "'During Displacement the MWD quit pu~sing, Unable to revive tool PROD1 CBU 1 x to perform FIT Test - 274 gpm / 1590 psi MWD never regain the ability pulse PROD1 Finish circ. hole clean for FIT Test -274 gpm - 1550 psi PROD1 Perform FIT test to 10.1 EMW -9172' md / 8575' tvd -8.4 ppg mud in and out Printed: 6/4/2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING i Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 5/23/2007 00:30 - 01:30 1.00 DRILL P PROD1 'i 01:30 - 02:30 1.00 DRILL N DFAL PROD1 02:30 - 03:00 ~ 0.50I DRILL I N I DFAL I PROD1 03:00 - 06:00 3.00 DRILL N DFAL PROD1 06:00 - 06:30 0.50 DRILL N DFAL PROD1 06:30 - 09:00 I 2.501 DRILL I N I DFAL I PROD1 09:00 - 11:00 I 2.001 DRILL I N I DFAL I PROD1 11:30 - 15:30 4.00 DRILL N I DFAL PROD1 15:30 - 00:00 I 8.501 DRILL I P I I PROD1 15/24/2007 100:00 - 12:00 I 12.001 DRILL I P I I PROD1 12:00 - 15:00 I 3.00 I DRILL I P I I PROD1 760 psi, Held for 10 min Charted test, Good Test Attempting to revive mwd, Tooi fail to pulse since displacing to new mud -Pump 25 bbl hi-vis -Surged tool several attempts without success -attempt to change mode, no success Unable to revive tool Drop Ball to open circ. sub, Pump Dry job -Monitor hole, well static 8.4 ppg mud wt. in and out PUW=170k SOW=155k RtWt=160k POH for MW D tool Break Circ. and close circ. sub C/O Handling equipment Set back BHA, Download MWD -Change out MWD tool -A Failed Telemetry Board is the suspected cause of failure on the MW D tool. Continual analysis of the tool will be done by HES with a failure report to follow. M/U BHA #5, Initialize MWD tool, -RIH with BHA C/O Handling equipment Shallow test MWD -250 gpm / 900 psi, Good Test RIH to 9151' -Break Circ and test MW D every 30 stands Break Circ, Tag Bottom, Pump up check shot survey Directional Drill as per HES Sperry Sun Directional Driller, 9192' - 9337' (8706' tvd) - 60 Rpm , 3k Tq off / 4k Tq On - 260 gpm, 1450 psi off / 1550 psi on - 10-15k WOB PUW 170k / SOW 155k / RtWt 165k AST= 1.7 / ART=5.12 ADT=6.82 ABI is sporadic and inconsistent Formations: TSGR 9174'md / 8577' tvd , TSHU 9222'md / 8617' tvd Directional Drill as per HES Sperry Sun Directional Driller, 9337' -9662' -60Rpm,3kTqoff/4kTqOn - 260 gpm, 1500 psi off / 1650 psi on - 10-15k WOB PUW 180k / SOW 155k / RtWt 170k TSAD 9336'md / 8699' tvd ABI is sporadic and inconsistent AST=3.79hrs ART=5.19hrs ADT=8.98 hrs Directional Drill as per HES Sperry Sun Directionai Driller, - 9662'-9713'md (8991' tvd) -40Rpm,4kTqoff/5kTqOn - 260 gpm, 1500 psi off / 1600 psi on - 10-15k WOB PUW 180k / SOW 155k ! RtWt 170k AST=1.90 hrs ART=0.48 hrs ADT=2.38 hrs Printed: 6/4/2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common Weli Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 5/24/2007 I 12:00 - 15:00 I 3.00 I DRILL I P I I PROD1 15:00 - 19:00 I 4.001 DRILL I N I DFAL I PROD1 19:00 - 20:00 I 1.001 DRILL I N I DFAL I PROD1 20:00 - 22:30 2.50 DRILL N DFAL PROD1 22:30 - 23:00 0.50 DRILL N DFAL PROD1 23:00 - 00:00 1.00 DRILL N DFAL PROD1 5/25/2007 00:00 - 01:30 1.50 DRILL N DFAL PROD1 01:30 - 02:30 1.00 BOPSU P PROD1 02:30 - 07:00 4.50 BOPSU P PROD1 07:00 - 09:00 2.00 BOPSU P PROD1 09:00 - 10:00 1.00 DRILL N DFAL PROD1 10:00 - 11:00 1.00 DRILL N DFAL PROD1 11:00 - 11:30 0.50 DRILL N DFAL PROD1 11:30 - 12:00 0.50 DRILL N DFAL PROD1 12:00 - f 6:00 4.00 DRILL N DFAL PROD1 16:00 - 17:30 1.50 DRILL P PROD1 17:30 - 22:00 4.50 DRILL N RREP PRODi 22:00 - 22:30 0.50 DRILL N DFAL PROD1 22:30 - 00:00 1.50 DRILL P PROD1 TSAD 9336'md / 8699' tvd ~"*ABI is sporadic and inconsistent, "*MWD Failed, Electronic Failure in the LWD Circ. High vis sweep 260 gpm / 1500 psi Surface to surface circulation Clean Hole,very few cutting coming across shakers Monitor well, well static 8.4 ppg mud wt. in / out POH from 9713' 9151' No problems pulling in open hole, hole in good shape Drop Ball, pump slug and blow down Top Drive POH to BHA Break Circ, Close Circ. Sub Change over tubular handling equipment Set Back BHA and Plug in to MWD UD MWD , Break Bit and L/D Motor Clear & Clean Floor Pull wear bushing , Install Test Plug Rig Up To Test BOP's PJSM, Test BOPE with 4" test joint, 250 low, 3500 psi high, holding each test for 5 min. Tested Annular to 250 Low and 2500 High Tested Hyd. & Manual choke to 250 low, 1500 high Performed Koomey Test Tested Gas alarms & PVT. Test witnessed by BP WSL Dave Newlon, NAD TP Jon Castle, W itness of test waived by Bob Noble, AOGCC. Good Test, no failures Continue testing BOP's with 4 1/2" test joint -Tested bottom and top pipe rams to 250 psi low, 3500 psi high, -Tested bag to 250 psi low, 2500 psi high Good test, no failures -Retrieve test plug and set wear bushing, -Lay down test joint and test equip., -Clear floor and prepare to pick up BHA Pick up motor and make up bit Make up MWD/LWD Orient motor and MWD Plug in and initialize MWD / LWD P/U Rest of BHA and RIH to 470' Surface check MWD @ 267 gpm / 880 psi -Good Test RIH to shoe -Break circ. every 30 stands, verify MW D each fill Slip and cut Drilling line -Service Top Drive, Crown and Draw Works Change out Wash Pipe on Top Drive -Unable to breakout top nut Cut Nut off after Performing Hazard Risk assessment RIH without issues, good hole Set Depth and take check shot survey Directional Drilt as per HES Sperry Sun Directional Driller, Printed: 6/4/2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 5/25/2007 I22:30 - 00:00 I 1.50I DRILL I P 5/26/2007 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P 12:00 - 00:00 I 12.001 DRILL I P 5/27/2007 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 22:00 I 10.001 DRILL I P 22:00 - 00:00 ~ 2.00 I DRILL I P 5/28/2007 100:00 - 01:00 I 1.001 DRILL I P 01:00 - 01:30 I 0.50I DRILL I P 01:30 - 05:30 4.00 DRILL P 05:30 - 08:00 2.50 DRILL P 08:00 - 11:30 3.50 DRI~L X PROD1 ~ 9713' - 9743' (9002' tvd) - 20 Rpm , 5k Tq off / 6k Tq On - 260 gpm, 1450 psi off / 1550 psi on - 10-15k WOB PUW 180k / SOW 150k / RtWt 160k AST; .66 / ART=.09 ADT=.75 Mud wt in / out 8.5 ppg PROD1 Directional Drill as per HES Sperry Sun Directional Driller, 9,743'-10,033' - 20 Rpm , 4k Tq off / 6k Tq On - 260 gpm, 1500 psi off / 1570 psi on - 10-15k WOB PUW 180k / SOW 150k / RtWt 165k Mud wt in / out 8.5 ppg PRODi Directional Drill as per HES Sperry Sun Directional Driller,10,033'-10,209' (9040' tvd) -20Rpm,4kTqoff/6kTqOn - 260 gpm, 1500 psi off / 1570 psi on - 10-15k WOB PUW 180k / SOW 140k / RtWt 165k Mud wt in 8.4 ppg / out 8.5 ppg PROD1 Directional Drill as per HES Sperry Sun Directional Driller, 10209'-10458' - 20 Rpm , 4k Tq off / 6k Tq On - 275 gpm, 1500 psi off / 1620 psi on - 10-20k WOB PUW 180k / SOW 140k / RtWt 165k Mud wt in / out 8.5 ppg AST=3.64 hrs, ART=5.33 hrs PROD1 Directional Drill as per HES Sperry Sun Directiona~ Driller,10458'-10,722' (9040'tvd) - 20 Rpm , 4k Tq off / 6k Tq On - 275 gpm, 1500 psi off / 1620 psi on - 10-20k WOB PUW 180k / SOW 145k / RtWt 165k AST=1.44 hrs, ART=7.34 hrs Mud wt in / out 8.5 ppg PROD1 Circ. 40 bbl Hi-Vis Sweep around , Surface to Surface 10-15% increase in cuttings return with sweep Minimal cuttings coming over shaker when finished circulating 8.5 ppg Mud Wt. in / out Monitor well for 10 minutes, Static PROD1 POH from 10,722 - 9,150 (shoe) No Problems pulling, hole in good shape No Swabbing , correct fi~l on displacement PRODi Break Circ. @ 2 bpm / 550 psi, Drop Ball and open Circ. Sub, Sheared ~ 2000 psi Pump Dry Job and Monitor well, static 8.5 ppg MW in/out PROD1 POH to BHA -change handling equip. for BHA PR001 Download MWD data, UD MWD, LWD, Mtr. and Bit PROD1 PJSM on safe handling of RA tools on surface. Meeting Printed: 6/4/2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 5/28/2007 I 08:00 - 11:30 I 3.501 DRI~L I X 11:30 - 16:00 I 4.501 DRILL I P 16:00 - 21:00 ~ 5.00 I DRILL I P 21:00 - 22:00 I 1.001 DRILL I P 22:00 - 22:30 I 0.501 DRILL I P 22:30 - 00:00 I 1.501 DRILL I P 5/29/2007 ~ 00:00 - 01:00 I 1.001 DRILL I P 01:00 - 04:00 3.00 DRILL P 04:00 - 06:30 2.50 DRILL P 06:30 - 07:30 1.00 CASE P 07:30 - 10:00 2.50 CASE P PROD1 conducted with HES MWD personnel and Rig crew. -Make up LWD / MWD, NB stab, Bit -initialize MWD, RIH to 366' , -Shallow hole test MWD, 250 gpm ~ 900 psi, good test PROD1 RIH with LWD to 10,722 -No Fill, No Problem Running in -Fill every 30 stands PROD1 MAD pass with LWD - GR/Res/Neutron/Den MAD pass from TD to TSAD / 9326'MD (sensor depth) in recorded mode only, max speed 540'/hr -PUW=180K, SOW=145k, RtWt=165k -260 GPM / 1550 psi -RPM =20, Tq= 4-5k 9730'-9710' hole packed off slightly, work through 3x without anyfurtherissues PROD1 Wash into Shoe ~ 9142' md, 260 gpm = 1550 psi -Drop ball and open circ. sub, 2 bbl/min 480 psi, sheared ~ 1500 psi -Bring pump rate up to 400 gpm / min / 1180 psi -100 rpm 5k fUlbs TQ -Pump 40 bbl hi-vis sweep, pump till sweep cleared the 7" Liner and 1000' above 7" liner lap PROD1 Wash out hole (9100-8670'), Position Circ.Sub Ports across 7" liner lap -Circ. ~ 400 gpm = 1050 psi -100 rpm 5k ft/Ibs TQ PROD1 Wash 7" liner lap -100 rpm 4k ft/Ibs of Tq , 400 gpm / 1250 psi -Wash across Liner Lap 2x @ 400 gpm, -Pulled up above Liner top, Position Circ. Sub Ports in 9 5!8" casing Circ. ~ 490 gpm 1280 psi Sweep brought back a 20% increase in cuttings PROD1 Continued with cleaning up hole C~ top of 7" liner lap -CBU 2x 490 gpm / 1250 psi Monitor well for 10 min, static 8.5 ppg in/out Pump dry job and blow down TDS PROD1 POH to Top of BHA PROD1 PJSM on safe handling of RA tools on surface. Meeting conducted with HES MWD personnel and Rig crew. -Remove Sources -Close Circ. sub and Flush BHA, -Lay Down LWD / MWD, NB stab, Bit -Clear Floor of third party tools RUNPRD Rig up 4 1/2" casing equipment and handling tools RUNPRD PJSM with Rig crews and NAD toolpusher, NAD casing hands, and BP WSL -M/U Shoe track And Check Float equipment, O.K. -M/U a total of 41 joints of 4 1/2" 12.6# L-80 IBT-M Liner -M/U BOT HMC Liner Hanger, ZXP LTP and running tools Printed: 6/M2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 5/29/2007 I 07:30 - 10:00 I 2.50I CASE I P 10:00 - 10:30 ~ 0.50 ~ CASE ~ P 10:30 - 15:00 4.50 CASE P 15:00 - 17:00 2.00 CASE P 17:00 - 18:30 1.50 CASE P RUNPRD -avg make-up 3900 ft/Ibs -Best- O-Life 2000 thread compound RUNPRD Circ. 1.5 times liner volume -5 bpm / 140 psi -50k Pick up and Slack off weight RUNPRD RIH to 9113', filling pipe every 20 stands RUNPRD CBU 7" shoe @ 200 gpm / 6S0 psi RUNPRD RIH to 10701, no problems running in open hole Make up Cement head and tag bottom ~ 10722', no fill 18:30 - 20:00 1.50 CEMT P RUNPRD Break Circulation, Staging up slowly -Circ. 1 full annulus volume at 6 bpm / 1000 psi Reciprocate pipe in 15' strokes 20:00 - 23:00 3.00 CEMT P RUNPRD PJSM, with Schlumberger cementers and rig personnel Started batching cement @ 19:30 hrs , cement to weight ~ 20:17 hrs Pump 5 bbls ahead, Test lines to 4000 psi, pump 35 bbls of 11.8 ppg Mudpush II, pump 51 bbis of 15.8 ppg "G" cement , Drop Dart, and flush lines to flowline, Displace cement ~ 5 bpm with 8.5 ppg mud, latched up ~ 89 bbis away, bump @ 113.9 bbls and pressure up to 3500 psi and hold for 5 min., Bleed off and check floats, CIP @ 22:30 Set down 120k, rotate 15 turns, PU 165k to release liner, Pressure up to 1000 psi, pick up 8 feet, pump 30 blls @ 420 , gpm ~ 1450 psi, pump, slowed pump to 2 bpm, set down and '~ ~ set Liner top packer, set ~ 120k, Pick up 20' 23:00 - 00:00 1.00 CEMT P RUNPRD Circ. ~ 510 gpm /2060 psi, 116 bbls of clabbered up mud , 20 bbls of contaminated cement returns 5/30/2007 00:00 - 00:30 0.50 CEMT P RUNPRD Finished Circulating cement out C~1 TOL -510 gpm / 2060 psi 00:30 - 01:00 0.50 CEMT P RUNPRD R/D cement head and UD 1 Jt. 01:00 - 03:00 2.00 CEMT P RUNPRD Displace to seawater, , -460 gpm 2200 psi , Pumped 900 bbls of seawater, still dirty, ordered another 580 I bbls to finish cleaning up hole and volume for completion I operations 03:00 - 03:30 0.50 CEMT P RUNPRD POH 1 stand 03:30 - 05:00 1.50 CEMT P RUNPRD Slip and cut drilling line -Service Draw Works, Crown and TDS 05:00 - 07:00 2.00 CEMT N WAIT RUNPRD Wait on Trucks hauling seawater ', Rig up to Test Liner ' 07:00 - 08:00 1.00 CASE P RUNPRD Test Casing for 30 min. - Good test 08:00 - 08:30 0.50 CASE P RUNPRD Finish circulating clean seawater to surface ~ 8.4ppg in/out 08:30 - 12:00 3.50 CASE P RUNPRD POH and Lay down BOT liner running tools, Clear floor 12:00 - 14:00 2.00 PERFO N RREP OTHCMP Changeout and rebuild Wash pipe on Top Drive 14:00 - 16:00 2.00 PERFO P OTHCMP PJSM with Schlumberger Perf Crew and NAD rig Crew, -R/U to Make up Perf guns j -M/U 591' of 2 7/8" HSD Perforating guns, 6 spf -260' of loaded guns, 331' of blanks -M/U eFire HDF Firing Head Printed: 6/4/2007 6:50:36 AM ~ • Legal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 ~Rig Name: NABORS 2ES Rig Number: 5/30/2007 14:00 - 16:00 2.00 PERFO P OTHCMP -Change Out Handling equipment 16:00 - 18:00 2.00 PERFO P OTHCMP M/U 1116' of 2 7/8" Pac Pipe ', -Change out handling equipment ', 18:00 - 21:30 3.50 PERFO P OTHCMP RIH,. tag Landing Collar @ 10,631' I -Place perforating guns on depth ~ 10540' 21:30 - 22:00 0.50 PERFO P OTHCMP Break. Circ. -200 gpm @ 950 psi Pump 1x Drill pipe Volume PUW=171k / SOW 150k 22:00 - 22:30 0.50 PERFO P OTHCMP PJSM with Schlumberger Tech and NAD drilling crews -Executed Schlumberger eFire Fire sequence -Positive indictation of guns firing Perf. intervals, 9990' -10,040', 10,100'-10,160', 10,310-10,380, 10460-10540' 22:30 - 23:00 0.50 PERFO P OTHCMP Monitor Hole, Loss ~ less than 10 bbls/hr PUW=171 / SOW 150 POH with 8 stands of Drill pipe to get above Perforations 23:00 - 00:00 1.00 PERFO P OTHCMP Circ. 1 pipe volume, Monitoring hole Hole taking fluid ~ less than 10 bbls/hr 5/31/2007 00:00 -D7:30 7.50 PERFO P OTHCMP Lay Down 4" Drill Pipe, Lay Down 2 7/8" Pac Drill Pipe Loss Rate C~3 7 bph 07:30 - 10:00 2.50 PERFO P OTHCMP PJSM with Schlumberger Tech and NAD Rig Crew on Laying Down PerF Guns UD 27 Guns, Fire Head and Perf. Handling equip All Shots Fired Clean & Clear Floor of Third party equipment Loss Rate ~ 7 bph 10:00 - 13:00 3.00 PERFO P OTHCMP RIH with excess pipe in derrick and lay Down 1 x 1 Loss Rate C~ 7 bph 13:00 - 13:30 0.50 RUNCO RUNCMP Pull Wear Bushing 13:30 - 15:30 2.00 RUNCO RUNCMP P/U Completion running equip -Rig Power tongs Tongs, Compensator and Ready Floor to run Completion String 15:30 - 00:00 8.50 RUNCO RUNCMP PJSM with NAD rig crew and casing hands on running Chrome Tubing Run 4 1/2" 12.6# CR-80 VAM-TOP Tubing Torque Turn, Avg. make up 4460 ft/Ibs Jet Lube Seal Guard for thread compound Loss Rate @ 7 bph 6/1/2007 00:00 - 05:30 5.50 RUNCO RUNCMP PJSM with NAD rig crew and casing hands on running Chrome Tubing Run a total of 210 jts of 4 1/2" 12.6# CR-80 VAM-TOP Tubing Torque Turn, Avg. make up 4460 fVlbs Jet Lube Seal Guard for thread compound 4.5" WLEG 9CR 4.5" TCII Tubing Pup XN Nipple (3.725" bore) Printed: 6/4/2007 6:50:36 AM ~ ~ Legal Well Name: F-44 Common W ell Name: F-44 Spud Date: 2/7/1991 'Event Nam e: REENTE R+COM PLET E Start : 5/5/2007 End: 6/2/2007 'Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: '[~~te '', Fram = T~ H~u~s Tas~ Co~{e ;1~ P"T ` Pfiase , ': E~~`s~ri~tion of t~~'er~~ic~r~~ ~~ M ,. 6/1/2007 00:00 - 05:30 5.50 RUNCO RUNCMP 4.5" 12.6# 13Cr-80 XO pup Vam Top box x TCII pin 1 jt (#1) Jts 4,5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore , 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin ' ~ Baker S-3 7"x 4.5" Packer TCII Box x Pin , 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P ' 4.5" 12.6# 13 Cr-80 XO pup TCiI box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 67 jts (#2-68) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #1 4.5"x1.5" KBG2-1 R 9Cr w/DV RK latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 63 jts (#69-131) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #2 4.5"x 1.5" MMG 9Cr w/DCR Shear & RKP 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P ' 28 jts (#132-159) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing ' 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin ~, 4.5" HES X Nipple 9Cr 3.813 Pkg Bore ~ 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P I, 50 Jts (#160-209) 4.5" 12.6" 13Cr-80 Vam Top tubing i 1 PUP Jt 4.5" 12.6# 13Cr Vam Top Tubing ' 1 jt (#210) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13Cr XO TCII Pin x Vam Top Pin CIW Tubing Hanger 13 5/8" x 4.5" 12.6# TCII BxB Tag NoGo in TBR ~ 9012', Spaced out with 5.81 pup, PUW = 125k / SOW=115k Loss rate ~ 5 bph 05:30 - 06:30 1.00 RUNCO RUNCMP M/U landing Jt and Hanger Rig down Tubing running equipment -UD Double stack Power tongs, Compensator, Airslips Landed Tubing ~ 9007', RILDS 06:30 - 11:00 4.50 RUNCO P RUNCMP Rig up to reverse Inhibted seawater, -Tested lines to 3500 psi -Reverse 137 bbls of Seawater followed with 287 bbls of Seawater with corrision inhibitor, follow with 180 bbis of Seawater -126 gpm = 220 psi 11:00 - 13:30 2.50 RUNCO RUNCMP Set Packer, -Test tubing to 3500 psi for 30 min., charted, Good Test -Bleed down to 1500 psi -Test Annulus to 3500 psi for 30 min. charted, Good Test -Bleed down annulus to zero -Pressure up annulus to 2200 psi and shear DCK valve. -Pump both directions to confirm good shear. 13:30 - 14:30 1.00 RUNCO RUNCMP Install TWC and test to 1000 psi from above and below. 14:30 - 15:30 1.00 RUNCO RUNCMP Blow down al~ surface equipment,rig down circulating lines. 15:30 - 17:30 2.00 BOPSU P RUNCMP Nipple down BOPE's Printed: 6/4/2007 6:50:36 AM . ~ ~ ~ Legal Well Name: F-44 Common Well Name: F-44 Spud Date: 2/7/1991 Event Name: REENTER+COMPLETE Start: 5/5/2007 End: 6/2/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/2/2007 Rig Name: NABORS 2ES Rig Number: 16/1/2007 I 17:30 - 19:30 I 2.001 WHSUR I P 19:30 - 20:30 1.00 W HSUR P 20:30 - 21:30 1.00 W HSUR P 21:30 - 23:00 1.50 W HSUR P ' 23:00 - 00:00 1.00 WHSUR P ~~6/2/2007 00:00 - 00:30 0.50 WHSUR P 00:30 - 03:00 2.50 WHSUR P RUNCMP ~ Nipple up adaptor flange & test to 5000 psi,hold for 30 minutes and chart. Nipple up tree. RUNCMP Fill tree with diesel and test to 5000 psi. RUNCMP Rig up DSM lubricator and pull TWC. -Rig down DSM. RUNCMP Rig up LRHOS and circulating lines to cuttings tank. -PJSM with all personnel -Reverse circulate 155 bbl diesel @ 3 BPM,430 psi. RUNCMP U-Tube tubing and annulus. RUNCMP U-Tube,Suck back diesel to LRHOS. -Blow down and remove circulating lines. RUNCMP Dry rod BPV& test from below to 1000 psi. -Remove secondary annulus valve from IA. -Remove hardlines & valves from OA. -Install flanges,valves,and gauges. Secure well. Rig release 06-02-07 ~ 0300 hrs Printed: 6/4/2007 6:50:36 AM a . ~ ~ Halliburton Company Survey Report ~ 1 I , a,. p i L',. " c i~~~i~~a ~.~~ '~ : 4' E i0) i 4"; ~A~ ' .: i t isr yi ~-rv '~ ~a~;N~sn~[y« BP Am~ ~,~~~~~~ ~q~~'~w ~ a~~~~~ ~ ~;.. k ~i ,~`~e ~12712#~~7 'l~ime i$.2 ~~ ~~~~~ ~t~l~~r~~~`~~~~li ~ ~ ~~ r ~~'.rt~ P~~fd~~~ Ba~ a, r ff ~ ~ ~ ,,io ~ ~o,~yr ~~,~~ ,~;gn~~ ~ ~ ;W .~' ~'~~~~~' 4 Tt~'~"~~t1`~f~ ~ ~f ~ ,a~. ~ " il' ° ~ ~ `~FB F P~G~ r~ `~ _ ~ a ~ , , ~ ,~ ~ ~ ~ ~ ` , ~' J ~ i~f~ ~=i ~~ ~ ,~ ~~~ " ~ ''~~ ~ ~~ ~ C 3 :~e.fereuees ~8.a~t34 7 6~f 2 : ~ ~,~' q(k~w ~~ ~i ~ ~ - s~~e~ . ~ F44 c~"~' , ~~"I~~i~~~~~~~'~~'~~ ~r . ~ i~rlir~i~l~`d~~ti~(V~J~2eferen~ iNelT(4.~ I~~~r{1Q~,~2t~3-4(?A~zr~i~~a~iGy~1~''?z~~~.'~~~~i~;'~,~µ Wellpat}ts : F 4~~4- _'~ N h=-- ~„ ~, ?. v ~rvrc}* C~l~ut~n AL~ili4d, ,~~~ ~ ~ ~T~~ ~~E~i~'~t~9ll~~~N P~ q,~~ Ch~c`~~~ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: F-44 Slot Name: F-44 Well Position: +N/-S 1002.58 ft Northing: 5973564.00 ft Latitude: 70 20 5.142 N +E/-W 1709.95 ft Easting : 652650.00 ft Longitude: 148 45 41.534 W Position Uncertainty: 0.00 ft Wellpath: F-44A Drilled From: F-44 500292213001 Tie-on Depth: 8601.74 ft Current Datum: 28.5+34.7 Height 63.20 ft Above System Datum: Mean Sea Level Magnetic Data: 5/13/2007 Declination: 23.92 deg Field Strength: 57659 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 25.30 0.00 0.00 200.00 Survey Program for Definitive Wellpath Date: 6/27/2007 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 63.24 8601.74 1: Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 8616.00 10675.60 F-44A IIFR+MS+Sag (8616.00-106 MWD+IFR+MS MWD + IFR + Multi Station Survey i4~ ~,, i ,. ~I ~ ~~Azim 't'~ Syb ~~~a NJS E/T'~ , M~pN ' ~ ~ ~ ``~'~t~t~`~ ~ ' ~u 4~ z 3- r~~,,k oa~w~~ ~ , ~~v1.;N ft~~~~,.,';: dec,~ ~~,d~#. ft :ft ~~il~ :: f£ ~t ft = ~, ~ ~ : ~ , n~ ,~, ~ ~y 25.30 0.00 0.00 25.30 -37.90 0.00 0.00 5973564.00 652650.00 TIE LINE 6324 0.00 0.00 63.24 0.04 0.00 0.00 5973564.00 652650.00 GCT-MS 75.04 0.07 191.21 75.04 11.84 -0.01 0.00 5973564.00 652650.00 GCT-MS 97.14 0.08 147.90 97.14 33.94 -0.03 0.00 5973563.97 652650.00 GCT-MS 113.34 0.10 128.36 113.34 50.14 -0.05 0.02 5973563.95 652650.02 GCT-MS 123.29 0.13 130.34 123.29 60.09 -0.06 0.04 5973563.94 652650.04 GCT-MS 138.84 0.13 136.27 138.84 75.64 -0.09 0.06 5973563.92 652650.06 GCT-MS 155.44 0.15 148.44 155.44 92.24 -0.12 0.09 5973563.88 652650.09 GCT-MS 171.99 0.18 161.30 171.99 108.79 -0.16 0.11 5973563.84 652650.11 GCT-MS 188.54 0.22 169.62 188.54 125.34 -0.22 0.12 5973563.79 652650.12 GCT-MS 205.09 0.27 174.23 205.09 141.89 -0.29 0.13 5973563.72 652650.14 GCT-MS 221.69 0.30 174.87 221.69 158.49 -0.37 0.14 5973563.63 652650.15 GCT-MS 238.29 0.30 173.84 238.29 175.09 -0.46 0.15 5973563.55 652650.16 GCT-MS 254.99 0.27 169.32 254.99 191.79 -0.54 0.16 5973563.47 652650.17 GCT-MS 271.74 0.25 161.38 271.74 208.54 -0.61 0.18 5973563.39 652650.19 GCT-MS 288.54 0.27 158.20 288.54 225.34 -0.69 020 5973563.32 652650.22 GCT-MS 305.39 0.30 163.00 305.39 242.19 -0.76 0.23 5973563.24 652650.25 GCT-MS 322.19 0.30 171.73 322.19 258.99 -0.85 0.25 5973563.16 652650.27 GCT-MS 338.99 0.33 177.23 338.99 275.79 -0.94 026 5973563.07 652650.28 GCT-MS 355.69 0.35 177.85 355.69 292.49 -1.04 0.26 5973562.97 652650.28 GCT-MS 372.49 0.33 176.23 372.49 309.29 -1.14 0.27 5973562.87 652650.29 GCT-MS 389.19 0.32 172.58 389.19 325.99 -1.23 0.28 5973562.77 652650.30 GCT-MS 405.99 0.30 166.65 405.99 342.79 -1.32 0.29 5973562.69 652650.32 GCT-MS 422.69 0.32 161.40 422.69 359.49 -1.41 0.32 5973562.60 652650.35 GCT-MS 439.49 0.33 160.79 439.49 376.29 -1.50 0.35 5973562.51 652650.38 GCT-MS 456.29 0.37 162.96 45629 393.09 -1.60 0.38 5973562.41 652650.41 GCT-MS 473.04 0.38 167.97 473.04 409.84 -1.70 0.41 5973562.31 652650.44 GCT-MS 489.79 0.42 175.33 489.79 426.59 -1.82 0.43 5973562.19 652650.46 GCT-MS 506.59 0.45 178.83 506.58 443.38 -1.95 0.43 5973562.07 652650.47 GCT-MS . ~ ~ Halliburton Company Survey Report ~aruii. ~ ~~~ _ f iv ~ ~ ~~i rr~ia. ~~'~ ~i~ ~ '= - ~ ~ - ~~~~~~~ ~~~ ~Ni.;«. ~~~'~12(#t~7 ,.<= : Tlme~ : .. 26 ~ i'~~ a . ;N~ Pz~ges ~ IG~j [el . W~1udFtoe 8~y d ! ~~ ~' '' ~ 0 ~ ~~ _ . ' ~ ~ ~ fs , ~ a i ~" `,orciin~~l%iE~ ~~fer~ 1~kE I~+~ "C"~~t~lclt'~114 j~ ` F~f~ ~ ; ia i J ~ ~ ~i~~~~~ e °E'E3FPc1t~'~' u l ~ ` ` " . ~ ~ ~A , rP~~i~l~;"J~~Nii;~ ?~-~,~`- ~~rLICa1{~T'~ ~~ ..a'~~`~,i`u~~N ~'r~~$~34.~6`.~.~ : ~~"ai"tiiio~~u~~~~~~ii~i~~~7~y~~»" ' ~: ~, '~~~ ~~ ~ '~ l ~ ~" ~ ~ ~ ~ ~ ~ :: ~11v1~ i < < : F- i~?~ o 44 ~ r i ~ ~~Jl ~~ la ,~,~ ay ,E '` ~' SeCtivl- ~~~' ~ ~:. ~~ C '~i~~ r ~ ~ etf {t~.#}Ui~,t3 {}i}E ~ ~ . . G ~r ~i~~Ni , ~ y ~ (#t3~,~'~a .~ ~ ~r;~ ~~~ ~['elipat~i«. ; Fr4#A r'~~q ~~ ~~ ~'~, < ,~~*I~y'~-~i ~ isfton Rfeth~d; hA-C1tm ~"" 1~: C3t',~te ~t~a ~`e~1'~+~~'~`~~ ;: , ~~ ~~~ ,, ~ro ~ ~ ~ Survey i~Ill ' ~'i~.,-xiiel: ~4~~~~'~Yiyn ~i TV~? - ~a`~'~~~~~Tl? i~T~'~5~m~ ~~~in ;~'.d44T Ma~rN : ~i'~~b~!' ~ ~~'""~~ ' ~~ Ta~i: ~ ~~~~~ ~ ,~,1i~ic~~r ;~~r ~° ~~' ~i~ , ;,~ w „ Pli ~~ ~ ~ft~u9i7~"~ ~ fE a i7~a~ !i'~~ ~~~~ ~iii~~~Vm~~t~e~.. ~ ~a~~~~jrvilwt "J~~tiV~~~~; ili~~ ~ ~ ~ '^~ ~ ~ ~~14d :a ' ,xi r [~ ,,;7e^ - _. ,. ~G.uO!r"ru~~ . , _~ ; !~a~a iif ~a~i~~i 523.39 0.47 178.24 523.38 460.18 -2.08 0.44 5973561.93 652650.48 GCT-MS 540.24 0.45 176.55 54023 477.03 -2.22 0.44 5973561.80 652650.49 GCT-MS 556.99 0.45 173.30 556.98 493.78 -2.35 0.45 5973561.66 652650.50 GCT-MS 573.79 0.45 168.27 573.78 510.58 -2.48 0.47 5973561.54 652650.52 GCT-MS 590.54 0.48 164.85 590.53 527.33 -2.61 0.51 5973561.40 652650.56 GCT-MS 607.34 0.50 164.31 607.33 544.13 -2.75 0.54 5973561.27 652650.60 GCT-MS 624.14 0.52 164.97 624.13 560.93 -2.89 0.58 5973561.12 652650.64 GCT-MS 640.89 0.52 166.59 640.88 577.68 -3.04 0.62 5973560.98 652650.68 GCT-MS 657.59 0.53 171.35 657.58 594.38 -3.19 0.65 5973560.83 652650.72 GCT-MS 674.14 0.55 174.69 674.13 610.93 -3.35 0.67 5973560.67 652650.74 GCT-MS 690.64 0.55 174.16 690.63 627.43 -3.50 0.68 5973560.52 652650.76 GCT-MS 707.24 0.55 172.77 707.23 644.03 -3.66 0.70 5973560.36 652650.78 GCT-MS 723.69 0.55 170.45 723.68 660.48 -3.82 0.73 5973560.20 652650.80 GCT-MS 740.19 0.53 167.72 740.18 676.98 -3.97 0.76 5973560.05 652650.84 GCT-MS 756.74 0.55 163.63 756.72 693.52 -4.12 0.79 5973559.90 652650.88 GCT-MS 773.29 0.58 160.37 773.27 710.07 -4.28 0.84 5973559.75 652650.93 GCT-MS 789.94 0.58 159.46 789.92 726.72 -4.43 0.90 5973559.59 652650.99 GCT-MS 806.59 0.60 159.61 806.57 743.37 -4.60 0.96 5973559.43 652651.06 GCT-MS 823.24 0.60 160.49 823.22 760.02 -4.76 1.02 5973559.27 652651.12 GCT-MS 839.94 0.62 164.11 839.92 776.72 -4.93 1.08 5973559.10 652651.18 GCT-MS 856.64 0.65 166.35 856.62 793.42 -5.11 1.12 5973558.92 65265123 GCT-MS 873.34 0.65 165.80 873.32 810.12 -5.29 1.17 5973558.74 652651.28 GCT-MS 889.99 0.65 165.82 889.97 826.77 -5.47 1.21 5973558.56 652651.33 GCT-MS 906.64 0.63 163.86 906.62 843.42 -5.65 1.26 5973558.38 652651.38 GCT-MS 923.34 0.63 159.06 923.32 860.12 -5.83 1.32 5973558.20 652651.44 GCT-MS 939.99 0.65 154.64 939.96 876.76 -6.00 1.39 5973558.03 652651.52 GCT-MS 956.69 0.65 153.02 956.66 893.46 -6.17 1.48 5973557.87 652651.60 GCT-MS 973.34 0.65 153.23 973.31 910.11 -6.34 1.56 5973557.70 652651.69 GCT-MS 989.99 0.65 154.05 989.96 926.76 -6.51 1.65 5973557.53 652651.78 GCT-MS 1006.69 0.65 156.70 1006.66 943.46 -6.68 1.73 5973557.36 652651.86 GCT-MS 1023.34 0.65 160.81 1023.31 960.11 -6.85 1.79 5973557.19 652651.93 GCT-MS 1040.04 0.65 163.16 1040.01 976.81 -7.03 1.85 5973557.01 652652.00 GCT-MS 1056.74 0.62 163.94 1056.71 993.51 -7.21 1.91 5973556.83 652652.05 GCT-MS 1073.44 0.60 164.27 1073.41 1010.21 -7.38 1.95 5973556.66 652652.10 GCT-MS 1090.09 0.60 162.26 1090.05 1026.85 -7.55 2.00 5973556.50 652652.16 GCT-MS 1106.74 0.60 161.79 1106.70 1043.50 -7.72 2.06 5973556.33 652652.22 GCT-MS 1123.44 0.60 165.25 1123.40 1060.20 -7.88 2.11 5973556.16 652652.27 GCT-MS 1140.09 0.58 169.66 1140.05 1076.85 -8.05 2.15 5973556.00 652652.31 GCT-MS 1156.74 0.60 174.58 1156.70 1093.50 -822 2.17 5973555.83 652652.34 GCT-MS 1173.44 0.60 179.07 1173.40 1110.20 -8.39 2.18 5973555.66 652652.35 GCT-MS 1190.14 0.60 181.82 1190.10 1126.90 -8.57 2.18 5973555.48 652652.35 GCT-MS 1206.74 0.57 183.80 1206.70 1143.50 -8.74 2.17 5973555.31 652652.35 GCT-MS 1223.44 0.53 186.16 1223.40 116020 -8.90 2.16 5973555.15 652652.34 GCT-MS 1240.04 0.53 185.59 1240.00 1176.80 -9.05 2.14 5973555.00 652652.32 GCT-MS 1256.64 0.53 185.18 1256.60 1193.40 -9.20 2.13 5973554.84 652652.31 GCT-MS 1273.34 0.52 187.29 1273.30 1210.10 -9.36 2.11 5973554.69 652652.30 GCT-MS 1290.14 0.50 189.89 1290.10 1226.90 -9.50 2.09 5973554.54 652652.28 GCT-MS 1306.94 0.50 193.40 1306.89 1243.69 -9.65 2.06 5973554.40 652652.25 GCT-MS 1323.64 0.52 198.41 1323.59 1260.39 -9.79 2.02 597355426 652652.21 GCT-MS 1340.44 0.55 202.22 1340.39 1277.19 -9.94 1.96 5973554.11 652652.16 GCT-MS 1357.14 0.57 203.36 1357.09 1293.89 -10.09 1.90 5973553.96 652652.10 GCT-MS 1374.04 0.60 203.47 1373.99 1310.79 -10.25 1.83 5973553.80 652652.04 GCT-MS . , ! . ~ Halliburton Company Survey Report - .s.~ a~ IV ~~?~. ~~+ ra i~ ~ fi n- '9PG~ i~l i ~~ s"~?3 ~ ~I~, ~ i s: K~°. ~S-n~11~Y $P Am4c~ ° ~ ~ ~ i i pU ( ~~1 ~~w ~2?1~~7 ~~~y~~ ~8.2$ ~$ ~iri~ ~ Pag~. 3 f~~~~~ 3~ ~? ~r~~~~~ ~'~~~'`~~J~~'h'~~~'y r~~, Ii~,tl~u ~ ~ ~ ~~~ ~~~~ ~eEerence ~~ ~~~,~i~~eS F 4A~, TruB~+Iv~ z ~ i ~.~ d ' ~~U ~~ (4 ~ G~ ~ ~~ a~ , ` ~ ~~fereuec f ~~~~~34~ 7 63.~ . ~ ; ~ 4 Well. 1~+~~k,~! 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(~~t~~~, F ti.~ 1390.74 0.65 203.39 1390.69 1327.49 -10.41 1.76 5973553.63 652651.97 GCT-MS 1407.54 0.73 205.60 1407.49 1344.29 -10.60 1.67 5973553.44 652651.89 GCT-MS 1424.34 0.82 208.40 142429 1361.09 -10.80 1.57 597355324 652651.79 GCT-MS 1441.04 0.88 210.55 1440.99 1377.79 -11.02 1.45 5973553.02 652651.67 GCT-MS 1457.69 0.92 212.98 1457.63 1394.43 -11.24 1.31 5973552.80 652651.54 GCT-MS 1474.14 0.88 216.89 1474.08 1410.88 -11.45 1.16 5973552.58 652651.39 GCT-MS 1490.64 0.78 221.51 1490.58 1427.38 -11.63 1.01 5973552.39 652651.25 GCT-MS 1507.09 0.70 223.58 1507.03 1443.83 -11.79 0.87 5973552.23 652651.11 GCT-MS 1523.54 0.63 218.95 1523.48 1460.28 -11.93 0.74 5973552.09 652650.98 GCT-MS 1540.04 0.58 210.68 1539.98 1476.78 -12.08 0.64 5973551.94 652650.89 GCT-MS 1556.54 0.60 197.86 1556.48 1493.28 -12.23 0.57 5973551.79 652650.82 GCT-MS 1572.99 0.65 184.71 1572.92 1509.72 -12.41 0.54 5973551.61 652650.79 GCT-MS 1589.44 0.70 177.76 1589.37 1526.17 -12.60 0.54 5973551.42 652650.79 GCT-MS 1605.94 0.73 172.37 1605.87 1542.67 -12.80 0.55 5973551.21 652650.81 GCT-MS 1622.44 0.75 168.74 1622.37 1559,17 -13.01 0.59 5973551.00 652650.85 GCT-MS 1638.89 0.75 165.62 1638.82 1575.62 -13.22 0.64 5973550.80 652650.90 GCT-MS 1655.29 0.73 162.40 1655.22 1592.02 -13.43 0.69 5973550.59 652650.97 GCT-MS 1671.74 0.70 159.58 1671.67 1608.47 -13.62 0.76 5973550.40 652651.04 GCT-MS 1688.19 0.65 157.56 1688.12 1624.92 -13.80 0.83 5973550.22 652651.11 GCT-MS 1704.64 0.57 156.94 1704.56 1641.36 -13.96 0.90 5973550.06 652651.1 S GCT-MS 1721.04 0.45 160.16 1720.96 1657.76 -14.10 0.95 5973549.93 652651.24 GCT-MS 1737.44 0.38 166.77 1737.36 1674.16 -14.21 0.99 5973549.81 652651.28 GCT-MS 1753.94 0.35 170.05 1753.86 1690.66 -14.32 1.01 5973549.71 652651.30 GCT-MS 1770.34 0.33 170.04 1770.26 1707.06 -14.41 1.03 5973549.62 652651.32 GCT-MS 1786.89 0.33 169.77 1786.81 1723.61 -14.51 1.04 5973549.52 652651.34 GCT-MS i803.49 0.35 1&4.74 1803.41 1740.21 -14.60 1.06 5973549.43 652651.36 GCT-MS 1820.04 0.33 152.04 1819.96 1756.76 -14.69 1.10 5973549.34 652651.40 GCT-MS 1836.59 0.25 142.52 1836.51 1773.31 -14.76 1.14 5973549.27 652651.44 GCT-MS 1853.14 0.23 141.10 1853.06 1789.86 -14.82 1.19 5973549.21 652651.49 GCT-MS 1869.69 0.18 148.20 1869.61 1806.41 -14.87 1.22 5973549.17 652651.52 GCT-MS 1886.24 0.17 162.95 1886.16 1822.96 -14.91 1.24 5973549.12 652651.55 GCT-MS 1902.79 0.17 170.91 1902.71 1839.51 -14.96 1.25 5973549.07 652651.56 GCT-MS 1919.29 0.15 172.76 1919.21 1856.01 -15.00 1.26 5973549.03 652651.56 GCT-MS 1935.84 0.15 176.26 1935.76 1872.56 -15.05 1.26 5973548.99 652651.57 GCT-MS 1952.39 0.13 175.12 1952.31 1889.11 -15.09 1.27 5973548.95 652651.57 GCT-MS 1968.89 O.iS 160.14 1968.81 1905.fi1 -15.f3 1.28 5973548.91 652651.58 GCT-MS 1985.44 0.13 125.04 1985.36 1922.16 -15.16 1.30 5973548.88 652651.61 GCT-MS 2001.99 0.08 76.13 2001.91 1938.71 -15.17 1.33 5973548.87 652651.63 GCT-MS 2018.49 0.07 36.53 2018.41 1955.21 -15.16 1.34 5973548.88 652651.65 GCT-MS 2035.09 0.05 21.78 2035.01 1971.81 -15.14 1.35 5973548.89 652651.66 GCT-MS 2051.59 0.02 325.60 2051.51 1988.31 -15.13 1.35 5973548.90 652651.66 GCT-MS 2068.09 0.02 251.36 2068.01 2004.81 -15.13 1.35 5973548.91 652651.66 GCT-MS 2084.59 0.05 223.74 2084.51 2021.31 -15.14 1.34 5973548.90 652651.65 GCT-MS 2100.99 0.07 210.27 2100.91 2037.71 -15.15 1.33 5973548.88 652651.64 GCT-MS 2117.59 0.07 191.20 2117.51 2054.31 -15.17 1.32 5973548.87 652651.63 GCT-MS 2133.99 0.10 157.88 2133.91 2070.71 -15.19 1.33 5973548.84 652651.64 GCT-MS 2150.49 0.12 12727 2150.41 208721 -15.22 1.35 5973548.82 652651.66 GCT-MS 2166.99 0.13 109.51 2166.91 2103.71 -15.23 1.38 5973548.80 652651.69 GCT-MS 2183.39 0.13 105.15 2183.31 2120.11 -15.24 1.41 5973548.79 652651.72 GCT-MS 2199.89 0.13 108.66 2199.81 2136.61 -15.25 1.45 5973548.78 652651.76 GCT-MS 2216.29 0.13 118.37 2216.21 2153.01 -15.27 1.48 5973548.77 652651.79 GCT-MS 2232.69 0.13 145.07 2232.61 2169.41 -15.29 1.51 5973548.75 652651.82 GCT-MS 2248.99 0.17 167.10 2248.91 2185.71 -15.33 1.53 5973548.71 652651.84 GCT-MS ~ ` ~ ~ • Halliburton Company Survey Report ~~ ~ iln~~~,~;,# `:BP A~tU~ x~` r'w, ~ ~ p~€~~P ~6f~~~'~(1Q7 ' Ta~p ~v~~r't8:2~.48 ~° ~ ~Mg~ £i i ~ rT~~l 9iitiy~ , ,P3~ld~~~,E~~y ~ ~''ai ~ ~ ~~it~~~~~~)RCfex'~~tCQ ~ ~&~~~ F-?~~E Tru~t~o~~„ ~ ~ ~F ~: Si~& f'~ ~ F'.~i~ ~ v tii~ IU~! w~iil ~ ~ertfe~t {T'~~°l~`~f~ `~~ 2$ ~'~'~~p~ s~H~~!~ ~ ~~,~i~~!rv ~~ ~d t , "~'c?l~ F-4a , ~ k ` " ~~ ~ rt~ ~ se~an {vS) Refere ~ ~~~ VNE.11 {Q:Q~~S' ~ ~ ~-~,2~ ~~zt} z ~~' I~ ~ ~~~~1t~~th°~ !F-~4A '~~" ~ S~rYey ~aleuis-~on ~~ o~r„ h~iir-im~~n C~t._.~ I' ~~ I)b: C~'~~~~~.~ ~° Survey ,r~. 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' '. ri' ~ ~ ( g p ` a ~ . ~ 7 n ~ a..j's~. ~~I ~~,~ h~~' ~G ~j1~J1 l 7 j}~ - ~Sf.~~~ ~V.~~~~IA.~ P ~d nP ~~i~i ' ~~ ~L1Qb ~~~ ~I~`~Il~u~~ ~\i'~ ~~q~ " :~'~ ~ - ai ,. ~ . . ae i ~ ii~l~i~ 6p~ ~ P ii ~4~ ~T P~ ~ ~~i ~i ]q~i~ ~~ ~ .. „,r~ ~t z~ , ~~~~ ~ ~.. ~ ~ ~~(±wey Calcul~~ion _ T~t[ rr ~~E~~~~ ' T , ( n ~murrt tur~ ~~i'" ~ij~ijnu ~?~~1' cl~ ~I ~~'~ i ~ ~„ .; r , ;_ ...~ ~, q ~~ Survey 1~°~ '~ ~ IriCI ~1zim 5 1`VI~~ ~ ~~5~ ~~1 ^~ "~~ '~~ , ~1~yY ~ I+'.£VV ~~~=3VIapAT ~~~j"~ ~ ~ ~,~t ~ ~ ~ii~~ ~ ~~~ti £~ ~ ~ ~' ~r~s~~~G Gdi~ii~l}l? v~~ ~~~ 51~~i- ~. ~i~~~ ~~~ ~( s ~ ' " ° :. iI.~E; ~- . _..,, ~ ~ i ",., 19~ .. m: .. ~ _ la~ ~~~~s h E.r, i a„ I 5563.84 30.20 185.99 5369.90 5306J0 -898.57 -105.95 5972663.53 652562.36 GCT-MS 5589.94 30.20 186.07 5392.46 5329.26 -911.62 -107.33 5972650.45 652561.25 GCT-MS 5616.19 30.20 186.20 5415.15 5351.95 -924.75 -108.74 5972637.30 652560.11 GCT-MS 5642.39 30.25 186.32 5437.78 5374.58 -937.86 -110.18 5972624.16 652558.94 GCT-MS 5668.54 30.37 186.45 5460.36 5397.16 -950.98 -111.65 5972611.02 652557.74 GCT-MS 5694.74 30.45 186.60 5482.96 5419.76 -964.15 -113.16 5972597.82 652556.50 GCT-MS 5720.94 30.52 186.78 5505.53 5442.33 -977.35 -114.71 5972584.59 652555.22 GCT-MS 5747.14 30.58 186.95 5528.10 5464.90 -990.57 -116.30 5972571.34 652553.90 GCT-MS 5773.34 30.62 187.00 5550.65 5487.45 -1003.81 -117.92 5972558.07 652552.55 GCT-MS 5799.54 30.70 186.99 5573.19 5509.99 -1017.07 -119.54 5972544.78 652551.19 GCT-MS 5825.74 30.75 186.96 5595.71 5532.51 -1030.36 -121.17 5972531.47 652549.84 GCT-MS 5851.94 30.75 186.97 5618.22 5555.02 -1043.66 -122.79 5972518.14 652548.48 GCT-MS 5878.14 30.73 187.08 5640.74 5577.54 -1056.95 -124.43 5972504.82 652547.11 GCT-MS 5904.44 30.62 187.16 5663.36 5600.16 -1070.26 -126.09 5972491.47 652545.72 GCT-MS 5930.59 30.60 187.21 5685.87 5622.67 -1083.47 -127.76 5972478.23 652544.33 GCT-MS 5956.84 30.62 187.27 5708.46 5645.26 -1096.73 -129.44 5972464.94 652542.91 GCT-MS 5982.99 30.45 187.26 5730.98 56&7.78 -1109.91 -f31.12 5972451.73 652541.50 GCT-MS 6009.04 30.28 187.08 5753.46 5690.26 -1122.98 -132.77 5972438.64 652540.12 GCT-MS 6034.89 30.20 186.80 5775.79 5712.59 -1135.90 -134.34 5972425.69 652538.81 GCT-MS 6060.89 30.18 186.56 5798.27 5735.07 -1148.89 -135.86 5972412.67 652537.56 GCT-MS 6086.84 30.18 186.37 5820.70 5757.50 -1161.85 -137.33 5972399.68 652536.35 GCT-MS 6112.84 30.05 185.87 5843.19 5779.99 -1174.82 -138.72 5972386.69 652535.23 GCT-MS 6138.84 29.78 184.55 5865.73 5802.53 -1187.73 -139.90 5972373.76 652534.31 GCT-MS 6164.79 29.60 183.26 5888.27 5825.07 -1200.56 -140.78 5972360.92 652533.70 GCT-MS 6190.74 29.58 182.70 5910.84 5847.64 -1213.35 -141.44 5972348.11 652533.29 GCT-MS 6216.79 29.47 182.57 5933.50 5870.30 -1226.18 -142.03 5972335.28 652532.96 GCT-MS 6242.69 29.37 182.70 5956.06 5892.86 -1238.88 -142.62 5972322.56 652532.64 GCT-MS 6268.59 29.32 182.82 5978.64 5915.44 -1251.56 -143.23 5972309.88 652532.28 GCT-MS 6294.54 29.13 182,91 6001.29 5938.09 -126422 -143.86 5972297.21 652531.91 GCT-MS 6320.39 29.05 183.00 6023.88 5960.68 -1276.77 -144.51 5972284.65 652531.52 GCT-MS 6346.39 29.03 183.12 6046.61 5983.41 -1289.37 -145.18 5972272.04 652531.10 GCT-MS 6372.29 28.90 183.29 6069.27 6006.07 -1301.89 -145.88 5972259.51 652530.65 GCT-MS 6398.19 28.73 183.45 6091.96 6028.76 -1314.36 -146.62 5972247.03 652530.17 GCT-MS 6424.09 28.65 183.58 6114.68 6051.48 -1326.77 -147.38 5972234.61 652529.66 GCT-MS 6449.99 28.62 183.70 6137.41 6074.21 -1339.15 -148.17 5972222.21 652529.13 GCT-MS 6475.89 28.48 183.91 6160.16 6096.96 -1351.50 -148.99 5972209.85 652528.56 GCT-MS 6501.74 28.42 184.18 6182.89 6119.69 -1363.79 -149.86 5972197.55 652527.94 GCT-MS 6527.64 28.50 184.41 6205.66 6142.46 -1376.10 -150.78 5972185.22 652527.27 GCT-MS 6553.49 28.62 184.57 6228.37 6165.17 -1388.42 -151.75 5972172.89 652526.55 GCT-MS 6579.39 28.65 184.72 6251.10 6187.90 -1400.79 -152.76 5972160.50 652525.80 GCT-MS 6605.29 28.58 184.94 6273.83 6210.63 -1413.15 -153.80 5972148.12 652525.00 GCT-MS 6631.09 28.60 185.16 6296.49 623329 -1425.45 -154.89 5972135.81 652524.17 GCT-MS 6656.94 28.73 185.33 6319.17 6255.97 -1437.79 -156.02 5972123.44 652523.29 GCT-MS 6682.84 28.77 185.51 6341.88 6278.68 -1450.20 -157.20 5972111.02 652522.36 GCT-MS 6708.84 28.70 185.60 6364.68 6301.48 -1462.64 -158.41 5972098.55 652521.41 GCT-MS 6734.39 28.62 185.20 6387.10 6323.90 -1474.84 -159.56 5972086.33 652520.50 GCT-MS 6760.09 28.60 184.24 6409.66 6346.46 -1487.10 -160.57 5972074.05 652519.74 GCT-MS 6785.69 28.62 183.26 6432.13 6368.93 -1499.33 -161.37 5972061.81 652519.19 GCT-MS 6811.34 28.62 182.72 6454.65 6391.45 -1511.60 -162.02 5972049.53 652518.80 GCT-MS 6836.94 28.65 182.70 6477.12 6413.92 -1523.86 -162.60 5972037.27 652518.46 GCT-MS 6862.54 28.65 182.90 6499.58 6436.38 -1536.12 -163.19 5972025.00 652518.11 GCT-MS 6888.09 28.72 183.12 6522.00 6458.80 -1548.36 -163.84 5972012.74 652517.72 GCT-MS 6913.64 28.78 183.34 6544.40 6481.20 -1560.63 -164.53 5972000.46 652517.28 GCT-MS , 4 • ~ . 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Survey ~„~ - ML~ f~te~ ~ ~ ~, ~ i~zim ~i a. ~ TY~ " ~" ~US ~<~ , ~ ~ ~ ~ ~~iry ~n ~-~ i~ ' ~ ~a ti ~~ ~,~1 ~d~.~ ~,<>,~ N~ x ~ ~ x~ ~ ]4~ai~ ~ ~''i'~~r~ 1`°~'1`' ~ ,r~'~~r ~ ~~::; i ~"~~t~ d ~ ~ ~ ~ ~ ~~~~ ~r ~~~~~ ~ ft r~ ~~, ~~ ~ ~ ,~ti~~~~ r~~~ ' ~ ~ ~~ ~,~~ ~~a~ ~ ~ i i~~.= , .: w . ~ : ~ i ~~ ~w ~~~~~~i~ ~~ ~ ~. ~~ ~ ; ,~ 6939.24 28.85 183.65 6566.83 6503.63 -1572.95 -165.28 5971988.13 652516.78 GCT-MS 6964.84 28.93 183.78 6589.24 6526.04 -1585.29 -166.08 5971975.78 652516.23 GCT-MS 6990.44 28.92 183.78 6611.65 6548.45 -1597.65 -166.90 5971963.41 652515.66 GCT-MS 7016.09 28.88 183.97 6634.10 6570.90 -1610.01 -167.74 5971951.03 652515.08 GCT-MS 7041.69 28.87 184.15 6656.52 6593.32 -1622.34 -168.61 5971938.68 652514.45 GCT-MS 7067.29 28.75 184.27 6678.95 6615.75 -1634.65 -169.52 5971926.36 652513.80 GCT-MS 7092.94 28.68 184.40 6701.45 6638.25 -1646.94 -170.45 5971914.06 652513.12 GCT-MS 7118.54 28.70 184.64 6723.90 6660.70 -1659.19 -171.42 5971901.79 652512.40 GCT-MS 7144.14 28.70 184.86 6746.36 6683.16 -1671.44 -172.44 5971889.52 652511.63 GCT-MS 7169.74 28.58 185.02 6768.83 6705.63 -1683.66 -173.49 5971877.28 652510.82 GCT-MS 7195.34 28.37 185.16 6791.33 6728.13 -1695.82 -174.58 5971865.10 652509.99 GCT-MS 7221.04 28.15 185.36 6813.97 6750.77 -1707.94 -175.69 5971852.97 652509.12 GCT-MS 7246.64 27.95 185.63 6836.56 6773.36 -1719.92 -176.85 5971840.97 65250821 GCT-MS 7272.24 27.80 185.90 6859.19 6795.99 -1731.83 -178.05 5971829.04 652507.25 GCT-MS 7297.84 27.72 186.14 6881.84 6818.64 -1743.69 -179.30 5971817.16 652506.24 GCT-MS 7323.44 27.73 186.41 6904.50 6841.30 -1755.53 -180.60 5971805.29 652505.18 GCT-MS 7348.94 27.63 186.68 6927.09 6863.89 -1767.29 -181.95 5971793.50 652504.07 GCT-MS 7374.74 27.43 186.98 6949.96 6886.76 -1779.13 -183.37 5971781.64 652502.89 GCT-MS 7400.24 27.33 18723 6972.61 6909.41 -1790.77 -184.82 5971769.97 652501.68 GCT-MS 7425.64 27.25 187.45 6995.18 6931.98 -1802.32 -186.31 5971758.40 652500.43 GCT-MS 7450.79 27.13 187.68 7017.55 6954.35 -1813.71 -187.82 5971746.98 652499.15 GCT-MS 7476.09 26.95 187.94 7040.09 6976.89 -1825.11 -189.38 5971735.55 652497.82 GCT-MS 7501.44 26.62 188.19 7062.72 6999.52 -1836.42 -190.98 5971724.21 652496.44 GCT-MS 7526.74 26.17 188.10 7085.38 7022.18 -1847.55 -192.58 5971713.05 652495.08 GCT-MS 7552.09 25.68 18729 7108.18 7044.98 -1858.54 -194.06 5971702.04 652493.82 GCT-MS 7577.39 25.23 186.10 7131.02 7067.82 -1869.34 -195.33 5971691.22 652492.77 GCT-MS 7602.74 24.78 185.41 7154.00 7090.80 -1880.00 -196.41 5971680.54 652491.91 GCT-MS 7627.98 24.47 185.49 7176.94 7113.74 -1890.47 -197.41 5971670.05 652491.13 GCT-MS 7653.24 24.37 185.86 7199.94 7136.74 -1900.86 -198.44 5971659.64 652490.30 GCT-MS 7678.49 24.48 186.21 7222.93 7159.73 -1911.24 -199.54 5971649.24 652489.42 GCT-MS 7703.69 24.70 186.54 7245.85 7182.65 -1921.66 -200.70 5971638.80 652488.47 GCT-MS 7728.89 24.78 186.92 7268.73 7205.53 -1932.14 -201.94 5971628.30 652487.44 GCT-MS 7754.19 24.65 187.36 7291.71 7228.51 -1942.63 -20325 5971617.78 652486.34 GCT-MS 7779.29 24.50 187.67 7314.54 7251.34 -1952.98 -204.62 5971607.41 652485.19 GCT-MS 7804.49 24.33 187.77 7337.49 7274.29 -1963.30 -206.01 5971597.06 652484.00 GCT-MS 7829.69 24.15 187.86 7360.47 7297.27 -1973.55 -207.42 5971586.78 652482.80 GCT-MS 7854.89 24.03 188.03 7383.47 7320.27 -1983.74 -208.84 5971576.57 652481.59 GCT-MS 7879.99 23.95 188.22 7406.40 734320 -1993.84 -210.29 5971566.44 652480.35 GCT-MS 7905.09 23.87 188.43 7429.35 7366.15 -2003.91 -211.76 5971556.35 652479.09 GCT-MS 7930.19 23.85 188.49 7452.30 7389.10 -2013.95 -213.25 5971546.28 652477.80 GCT-MS 7955.39 23.80 188.49 7475.36 7412.16 -2024.02 -214.76 5971536.18 652476.50 GCT-MS 7980.49 23.72 188.60 7498.33 7435.13 -2034.02 -216.26 5971526.15 652475.20 GCT-MS 8005.59 23.72 188.85 7521.31 7458.11 -2044.00 -217.79 5971516.14 652473.87 GCT-MS 8030.69 23.75 189.16 7544.29 7481.09 -2053.98 -219.37 5971506.14 652472.49 GCT-MS 8055.79 23.83 189.42 7567.25 7504.05 -2063.97 -221.01 5971496.11 652471.06 GCT-MS 8080.89 23.90 189.57 759021 7527.01 -2073.99 -222.68 5971486.07 652469.59 GCT-MS 8106.09 23.85 189.69 7613.25 7550.05 -2084.04 -224.39 5971475.98 652468.09 GCT-MS 8131.09 23.80 189.76 7636.12 7572.92 -2094.00 -226.09 5971465.99 652466.59 GCT-MS 8155.89 23.78 189.75 7658.81 7595.61 -2103.85 -227.79 5971456.10 652465.09 GCT-MS 8180.79 23.75 189.75 7681.60 7618.40 -2113.74 -229.49 5971446.18 652463.60 GCT-MS 8205.58 23.72 189.82 7704.29 7641.09 -2123.58 -231.18 5971436.32 652462.10 GCT-MS 8230.49 23.72 189.95 7727.10 7663.90 -2133.45 -232.90 5971426.41 652460.58 GCT-MS « • . . Halliburton Company Survey Report ~t~ E3PAmUCt~ UF~ ~N~ ~~~o~ ~7 ~n ~~ ~ ~te .. fi127f2t~3~ s,, <p~~~~~~ ~ tE#:~E`s~$~~~°a :ry p~ " ~~~~~"~~ ~ ~ ' wi~ ~ ,, .,. P~1~{~ ~ "` " ~ ~n~ ,„; :~ ,,~ ~ ~ ~ i ~~r~ ~,i,r r',~~p~it~;~~',~~eier~ec ~~'tiv~~~u~~~* ~~* TrUB' [~'b~#'y ~ ~ ~ 6 " ~, Si~e FB F Pad . ~ ~ ~ ~,. ~: ~a~~'~I~i~~I~~V~ ~~' ~ ~~r~ , ~ ~erltesi ~ n jT~U} R~ e~f ~ ~; 28 ~ ~ r ~+3~q: ~ ~ ~ ~~: ~ "` e~ ?' l~r~~~ ~~ ~ F-~4 ~ , ~, /~N,~~'~~~' ~~ ~~ai~i~ii~ ~ ~ ~~~ ~~vn(V~)Referene~.~'~~~~~ ~' ~iY~~ {fl U{~~A+t,~"~~'~t~~A~~~ ~~hdi ~ ~k 0 ~ , r ' ~ ~~' '~~ :F ~~}~ ~.~ ~ ~ ~' ., - '-:- - ~~ " ~ ' _ a ~~ d ~~~~~~~ ~~Ill¥(~ ~ ~ ~ ~ s~~~,,,yyy~~~~~~r~~i~t~~ ~ , rt~ ~ -AU;;'= ~4mk~l4~~ ~ , -.... , .. . ,~ . . . ' .' , . ....~ , ;. - s.~«, , .. _ . _ _' Survey ~~ ~~~ ~ ~ Iri~ tf~m ~'VA ~ c~'~5~~~ ~ ~~~~ ~l~a ~ El~ `~~~ ~ ~~ ~p~ ~ x ~ ~I'tHtl ~ ~ < ~ ~ " ~ a ~ ~ f[ ~ iii ~i.ti r ~ d~l~~~ ~t ~~~ ~f ! ' ~~ ~ 1 ~ ~a ; ~{ ~ ~ 5 ~t ~s ~ ~ ~ ~.~ . ^~o .~,, ,,, . . n . ~ E ~a ~ „ ,, ~ ~,~ ., . ,., ~ ~, uu~ t ,ti ~~ _- ,. . n 8255.24 23.77 190.07 7749.76 7686.56 -2143.26 -234.64 5971416.57 652459.05 GCT-MS 8279.99 23.85 190.06 7772.40 7709.20 -2153.10 -236.38 5971406.70 652457.51 GCT-MS 8304.79 23.82 190.06 7795.08 7731.88 -2162.97 -238.13 5971396.80 652455.96 GCT-MS 8329.49 23.68 190.34 7817.69 7754.49 -2172.76 -239.89 5971386.97 652454.39 GCT-MS 8354.29 23.58 190.77 7840.41 7777.21 -2182.53 -241.71 5971377.16 652452.77 GCT-MS 8379.04 23.42 191.16 7863.11 7799.91 -2192.22 -243.59 5971367.44 652451.09 GCT-MS 8403.79 23.22 191.57 7885.84 7822.64 -2201.83 -245.52 5971357.80 652449.36 GCT-MS 8428.58 23.05 191.97 7908.63 7845.43 -2211.36 -247.51 5971348.23 652447.57 GCT-MS 8453.29 22.87 192.40 7931.39 7868.19 -2220.78 -249.54 5971338.76 652445.73 GCT-MS 8478.04 22.72 192.87 7954.20 7891.00 -2230.14 -251.64 5971329.37 652443.82 GCT-MS 8502.79 22.70 193.36 7977.03 7913.83 -2239.45 -253.81 5971320.02 652441.84 GCT-MS 8527.59 22.73 193.90 7999.91 7936.71 -2248.75 -256.07 5971310.67 652439.77 GCT-MS 8552.29 22.82 194.38 8022.69 7959.49 -2258.02 -258.40 5971301.35 652437.63 GCT-MS 8577.04 22.95 194.69 8045.49 7982.29 -2267.34 -260.82 5971291.99 652435.40 GCT-MS 8601.74 23.00 195.01 8068.23 8005.03 -2276.66 -263.29 5971282.62 652433.12 GCT-MS 8616.00 23.07 195.17 8081.35~ 8018.15 -2282.05 -264.74 5971277.21 652431.78 MWD+IFR+MS 8685.75 24.51 204.80 8145.20 8082.00 -2308.38 -274.39 5971250.68 652422.67 MWD+IFR+MS 8779.23 24.24 217.60 8230.40 8167.20 -2341.21 -294.25 5971217.46 652403.49 MWD+IFR+MS 8871.96 26.27 229.42 8314.32 8251.12 -2369.66 -321.47 5971188.46 652376.85 MWD+IFR+MS 8917.70 26.61 234.11 8355.28 8292.08 -2382.25 -337.45 5971175.55 652361.12 MWD+IFR+MS 8965.19 27.21 238.62 8397.63 8334.43 -2394.14 -355.34 5971163.30 652343.48 MWD+IFR+MS 9059.23 31.57 239.72 8479.55 8416.35 -2417.76 -394.98 5971138.88 652304.34 MWD+IFR+MS 9103.34 31.94 237.35 8517.06 8453.86 -2429.88 -414.77 5971126.36 652284.80 MWD+IFR+MS 9196.62 32.78 235.60 8595.85 8532.65 -2457.46 -456.38 5971097.94 652243.76 MWD+IFR+MS 9227.47 36.10 234.06 8621.29 8558.09 -2467.52 -470.64 5971087.60 652229.71 MWD+IFR+MS 9257.99 37.67 231.87 8645.70 8582.50 -2478.55 -485.25 5971076.27 652215.33 MWD+IFR+MS 9289.09 37.93 231.91 8670.28 8607.08 -2490.32 -500.25 597106420 652200.57 MWD+IFR+MS 9335.38 37.92 231.88 8706.79 8643.59 -2507.87 -522.64 5971046.20 652178.55 MWD+iFR+MS 9384.54 37.49 232.37 8745.69 8682.49 -2526.33 -546.37 597102726 652155.20 MWD+IFR+MS 9428.90 37.46 233.43 8780.89 8717.69 -2542.61 -567.90 5971010.55 652134.01 MWD+IFR+MS 9479.05 37.13 238.49 8820.80 8757.60 -2559.61 -593.06 5970993.04 652109.20 MWD+IFR+MS 9541.86 36.21 238.47 8871.18 8807.98 -2579.22 -625.03 5970972.78 652077.64 MWD+IFR+MS 9573.38 36.05 236.70 8896.63 8833.43 -2589.19 -640.72 5970962.50 652062.16 MWD+IFR+MS 9604.97 41.47 233.59 892126 8858.06 -2600.51 -656.92 5970950.86 652046.19 MWD+IFR+MS 9636.11 4626 233.36 8943.71 8880.51 -2613.35 -674.25 5970937.67 652029.12 MWD+IFR+MS 966625 50.74 235.57 8963.67 8900.47 -2626.45 -692.63 5970924.19 652011.02 MWD+IFR+MS 9696.06 55.27 237.81 8981.61 8918.41 -2639.51 -712.52 5970910.73 651991.40 MWD+IFR+MS 9726.91 60.47 241.06 8998.01 8934.81 -2652.77 -735.02 5970897.02 651969.18 MWD+IFR+MS 9758.27 64.31 239.98 9012.54 8949.34 -2666.45 -759.20 5970882.86 651945.28 MWD+IFR+MS 9790.45 68.21 239.38 9025.50 8962.30 -2681.31 -784.62 5970867.47 651920.17 MWD+IFR+MS 9821.71 71.95 237.94 9036.15 8972.95 -2696.60 -809.72 5970851.68 651895.39 MW D+I FR+MS 9851.74 76.75 236.82 9044.25 8981.05 -2712.19 -834.06 5970835.60 651871.37 MWD+IFR+MS 9882.79 82.14 237.13 9049.93 8986.73 -2728.82 -859.65 5970818.46 651846.13 MWD+IFR+MS 9913.70 87.40 237.46 9052.75 8989.55 -2745.44 -885.54 5970801.31 651820.59 MWD+IFR+MS 9944.04 89.62 23324 9053.54 8990.34 -2762.68 -910.48 5970783.57 651796.00 MWD+IFR+MS 9975.08 91.22 227.76 9053.31 8990.11 -2782.42 -934.42 5970763.35 651772.47 MWD+IFR+MS 10007.05 95.31 221.92 9051.49 8988.29 -2805.03 -956.92 5970740.28 651750.44 MWD+IFR+MS 1003724 96.56 216.88 9048.36 8985.16 -2828.23 -975.97 5970716.71 651731.86 MWD+IFR+MS 10069.07 96.07 211.76 9044.86 8981.66 -2854.35 -993.80 5970690.23 651714.57 MWD+IFR+MS 10100.38 96.44 207.58 9041.45 8978.25 -2881.38 -100920 5970662.89 651699.72 MWD+IFR+MS 10130.67 93.34 202.10 9038.86 8975.66 -2908.76 -1021.87 5970635.26 651687.61 MWD+IFR+MS 10162.46 89.44 196.58 9038.09 8974.89 -2938.73 -1032.39 5970605.09 651677.71 MWD+IFR+MS 10192.48 89.74 192.97 9038.31 8975.11 -2967.75 -1040.05 5970575.92 651670.65 MWD+IFR+MS ~~ ~ ~ . • Halliburton Company Survey Report ~ TREE = 4' CNV LHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 59.7' BF. ELEV = KOP = 34J' 86U0' Max Angle = 91 @10100' Datum MD = 9419' Datum ND = 8800' SS ~ F-44A SA~~TES: THE TIW PKRS MAY FAIL IF MORE THAN 100 PSI DIFFERENTIAL PRESSURE IS Act u a I IXGEEDED. 2184' 4-1/2" X Nipple ID=3.813" GAS LIFf MANDRELS ~ 13-3/8' CSG, 68~kk, NT-80, ID = 12.415" ~-~ 2685' ~9-5/8" x 7" BOT ZXP/Liner top packer {~ 8455' ~ ~~~X~~~~"~11C~F~3'~' 8473' 15.8 ppq Class G Cement OT Whipstock H 8616' ~ 9-5/8" E ZS V 8635' ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 3379 6046 MAAG MAAG DCR Dumry RKP RKP 1.5" 1.5" O6/02/07 06/02/07 6` ~Top of Window (KOP) ~ 8885' 4-1/2" X Nipple, ID=3.813„ 8906' 4-1/2" x 7" BOT S-3 Packer 8930' 4-1/2" X Nipple, ID=3.813" 8941' 4-1/2", 12.6#, 13Cr-80, VamTop TI 8993' 4-1/2" XN Nipple, ID=3.75" 9005' 4-1 /2" W LE G 8998' 7" x 41/2" ZXR'HCM BOT Liner 7', 26#, L-80, BTGM Liner 3-1/2" Tubing Cut 8800' / ~4-1/2" 12.6~, L-80, BT-M Liner}~ .~~~ Gass G Cement w ith Gas Bbck ~ $$39~ -i9-5/8" X 3-1/2" HBBRR PKR, ID= 4.00" TOPOF 7" LNR 8891~ gg62'~8866' TBG PUNCH (11/OS/OS) 9-5/8" CSG, 47~E, L-80, ID = 8.681 ^ 9156~ CMT SQZ'D TO 9-5/8" SHOE (11/07/OS) ~ ~ J4~' 13-1l2" CAAACO SLIDING SLEEV E C&1, ID = 2.750" PERFORATION SUMMARY REF LOG: Sperry ALD/CTNlGR/EWR dated May 30 2007 9565' EZSV (11l06/OS) ANGLEATTOPPERF:91 deg Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2 7/8 6 9990-10040 Open OS/30l07 2 7/8 6 10100-10160 Open OS/30/07 2 7/8 6 1031U-10380 Open OS/30/07 2 7/8 6 10460-10540 Open OS/30/07 962$~ ~TMI PERM PKR HBBP W/ ANCHOR LATCH, ID = 4.00' 9636' 3-1/2' SVNS NIP, ID= 2.750" 9636' 3-1/2" XX PLUG (09/23/05) 9643' 3-1/2" SVUS NIP, ID=2.750" ~ 3-1l2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992' ~ 964$' ~48' 3-1/2" OTIS TBG TAIL W/LEG 9649' ELMD TT LOGGED 02/23/91 ~TD 9810' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9852' DATE REV BY CAMMENTS DATE REV BY COMMENTS 02/26/91 ORIGINALCOMPLETION 11/07/05 JLGlTLH CMTSQZ 09/09/01 RN/TP CORRECTI~NS 11/12/05 SFNlPJC ABORTED CTD-WS STUCK ~2111' 01/03/03 JANKAK PULL XX PLUG O6/02/07 BWDM Sidetrack & Re-completan 07/13/03 CAAO/TLP MAX ANGLE CORRECTION 09/23/OS JAF/TLH XX PLUG SET 71/06/05 GJB/TLH TBG PUNCH, PFRFS, QSV PRUDHOE BAY UNff WELL: F-44A PERMfT No: 205-161 API No: 50-029-22130-01-00 SEC 2, T11 N, R13E, 3248' FNL & 2199' FEL BP 6cploration (Alaska) Re: F-44A (205-161) Pre-Rig Change. ~ ~ Thanks Kris, While it is important to verify the competency of the casing and tubing strings, you all choose the pressure values based on the anticipated operating conditions and internal policies. Good luck with the work. Tom Maunder, PE AOGCC Honas, Kristopher wrote, On 4/6/2007 9:52 AM: Tom, In the approved Sundry for F-44A the pre-rig operations call for a combination mechanical integrity test on the tubing x IA to 3500 psi. The existing tubing packer is not designed to take this pressure, so we are only going to perform the CMIT to 2500 psi. I wanted to let you know that this would change would occur and make sure that you have no objections. Thank you. Kris Honas GPB Rotary Drilling 564-4338 1 of 1 4/6/2007 10:00 AM ~ ~. - _ -- - - ,~ ~_. , ._~ -~, - , -- _ ~,' ,~ ~ ~ ,. ~,~ ' - ~ ~ ~ ~, i ; ' ; _ ' '` ' ' ~ s _, -: _ __ -_ _ ~ , _ SARAH PAUN, GOVERNOR pi~~ ~~j ~~ > 333 W. 7thAVENUE, SUITE 100 C~`-SER~g-~~l~t CO~IISSIDi` ,~~ ANCHORAGE,ALASKA 99501-3539 PNONE (907) 279-1433 FAX (907} 276-7542 Greg Hobbs Senior Petroleum Engineer, ENS ~ BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F-44A Sundry Number: 307-084 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants far good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sxncerely, DATED this v day of March, 2007 Encl. ~~~~~~~ ~ ~ ~ ~~ To: Alaska Oil and Gas Conservation Commission From: Kristopher E. Honas - BPXA GPB Rotary Drilling Subject: F-44A Application for Sundry Approval ~ Date: March 2, 2007 Sundry approval is requested for a rotary sidetrack on F-44A. A coil sidetrack was planned in 2005; however, the sidetrack was aborted after the whipstock set prematurely in the tubing. A rotary rig is now necessary to recover the fish, pull the tubing and sidetrack the well. The F-44 wellbore is already P&A'd. The following barriers are currently in place: • XX plug set in the 3-1/2" tubing at ~9636' MD. • Cement plug inside the 3-1/2" tubing from ~9636' MD to 9565' MD. • 3-1/2" EZSV set at 9565' MD. • The 3-1/2" x 7" annulus is cemented from the packer at ~9628' MD to the 9-5/8" shoe at ~9156' MD. The original Sundry approval for P&A is on file with the AOGCC, the number is 305-354 dated November 14, 2005. The rotary sidetrack will drill to the same TD planned in 2005. The kickoff point, however, will change by moving ~940' above the CTD KOP. This will be above the Sag River formation and two liner strings will be needed to reach TD. An updated directional plan has been included for the AOGCC's records. The new Sundry request asks to remove the fish and existing tubing, enabling a whipstock exit from the 9-5/8" casing at ~8600' MD. To do this the 3-1 /2" tubing will be cut in three sections and individually pulled out of the wellbore. The first cut will be ~10' above the fish at ~2100' MD. The second cut will be made below the fish using an outside cutter on wash pipe. The final cut will be a jet cut at ~8800' MD. A 9-5/8" EZSV will be set at 8620' MD. A whipstock will set on top of the EZSV allowing a window to be milled at 8600' MD. After de-completing the well, the sidetrack plans call for an 8-1/2" BHA to exit the parent wellbore and drill to the top and the Sag River formation. The liner will be 7 inches and fully cemented 150' back inside the 9-5/8" casing. The production interval will be drilled with a 6-1/8" BHA building to 90 degrees at the base of zone 2A. The planned well then runs horizontally for -862' to TD. The production interval is a 4-1/2" fully cemented liner extending 150' inside the shoe. The F-44A sidetrack is currently scheduled for Nabors 2ES beginning April 20, 2007. The pre-rig work for this sidetrack will be scheduled once Sundry approval has been obtained. Estimated Pre-Rig Start Estimated Spud Date: Kristopher E. Honas GPB Rotary Drilling Engineer Ph: 564-4338 (office) 440-2389 (cell) 04/01 /2007 04/20/2007 F-44A Application for Sundry ~ STATE OF ALASKA ~ a~ ~~~EI~E ,p~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION g~~ (1~AR O~ 2007 '~b" ~J~ APPLICATION FOR SUNDRY APPROVAL ~ 20 ~C 25.2so Alaska Oil ~ Gas Gana. Commission 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensid~k~chorage ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ~ Other Re-Start O erations 2. Operator Name: 4. Current Well Class: 5. Perm~ To Drill Number BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 205-161 / 305-354 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22130-01-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU F-44A i Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028280 ~ 65.66 ~ Prudhoe Bay Field / Prudhoe Bay Pool J 12- PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9852 9174 9565 8934 9565 2111' Casin Len th Size MD TVD Burst Colla se S ructural n r 110' 2" 110' 110' Surface 2685 13-3/8" 2685' 2685' 4930 2270 Intermediate 9157' 9-5/8" 9157' 8575' 6870 4760 Produ tion Liner 961' 7" 8891' - 9852' 8333' - 9174' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None (Isolated w/ Cement) None 3-1/2", 9.2# L-80 9648' Packers and SSSV Type: 7" x 3-1/2" TIW Perm'HBBP' packer; Packers and SSSV MD (ft): 9628', 9-5/8" x 3-1/2" 'HBBP-R' packer 8839' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 1, 2007 ~ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kris Honas, 564-4338 Printed Name G H t3`~s Title Senior Petroleum Engineer, ENS Prepared By Name/Number: Signature Phone 564-4191 Date ,~/S ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number. .~.~: , Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~ ~°-~ ~''~~~ ~~sc~"` ~~~-? ?s-~-_ ~ _ ~' ~ ~f G C ~l=t`~`C~SO~ci'C.3-~~bbs'j C~C.-C~~~ ~~J~ ~~~ ~~C~S ~ Subsequent Form Required: 1~, o APPROVED BY 2 ~ ~~ A roved B: MMISSIONER THE COMMISSION Date c/ Form 10-403 Revised 06/2006 ~~~~~~~~ Submit In Duplicate ~~~ ~L MAH ~ `L 20D7 ~~` ~ ~ F-44A Operations Summarv 1 2 3 4. 5. 6. 7. 8. ,~-~~~~ 9. ~ 10. ~ 11 scope - Retrieve the fish set at -2110' MD. - Cut and Pull 3-1/2" L-80 tubing from above the production packer. - Sidetrack the well from ~8600' MD drilling ~570' of 8-1/2" intermediate hole to the top of the Sag River formation. - Drill a 6-1/8" production interval, building to horizontal in zone 2A with ~862' of >90 degree inclination to TD at ~10,799' MD. - Run 4-1/2" 12.6# 13Cr-80 Vam Top Completion. Pre-Riq Operations: 1. Bleed the OA, IA and tubing to 0 psi. PPPOT - T& IC. Function all the LDS and repair/replace as needed. 2. Jet cut the 3-1/2" tubing at ~2100' MD (5' - 10' above fish set at 2110' MD). 3. CMIT - T x IA to 3500 psi for 30 minutes. MIT - OA to 2000 psi for 30 minutes. 4. Circulate the wellbore with seawater through the tubing cut until returns are clean. Freeze protect the tubing and IA to ~2200' TVD. 5. Bleed the OA, IA and tubing to zero psi. 6. Set a BPV and test to 1000 psi from the tubing annulus. 7. Secure the well, remove the wellhouse, and level the pad as necessary. Riq Operations: MI / RU Nabors rig 2ES. CMIT - T x IA to 3500 psi for 30 minutes. Pull the BPV. Circulate out diesel freeze protection and displace the well to seawater. Set and test the TWC. Nipple down the tree. Nipple up and test the BOPE to 3,500 psi. Pull the TWC. R/U. Pull and lay down the 3'/2", 9.2#, L-80 tubing from the cut at 2,100' MD. M/U an outside cutter on wash pipe, RIH and cut the 3-1/2" tubing at -2,120' MD. M/U an overshot w/ grapple. RIH and latch the tubing. POOH. R/U e-line, RIH and jet cut the tubing in the middle of a joint at ~8,800' MD. RIH and spear the tubing at ~2120' MD. Pull tubing from the cut at ~8800' MD. RU E-line and run a full gauge 8.5" GR/JB & CCL/GR to confirm access to set an EZSV (CIBP) and to run the BOT whipstock assembly. (If the GR/JB run passes, proceed with this wellplan. If GR/JB indicates a scraper run is needed, PU 4" drill pipe and 9-5/8" clean-out assembly and clean-out well to below the EZSV setting depth at ~8620' MD. RIH and set an EZSV (CIBP) at 8620' MD. Pressure-test the casinq to 3,500psi for 30 minutes. Record test. ~ ~ s. Nu a y-5iu~~ wnipstocK, bottom trip ancnor ana ts.5~~ window mming assemaiy ~to inciuae tuii gauge scring mills). RIH to the top of the EZSV. Orient and set the whipstock. Swap well over to 10.2 ppg fresh water LSND milling fluid. 14. Mill a window in the 9-5/8" casing plus 20' of formation from mid-window. Verify that the mud weight is ~~ ~ 10.2 ppg prior to cutting the window. ~~ 15. Pull up into 9 5/8" casing and conduct an FIT to 11.5 ppg EMW. POOH. ~ 16. M/U an 8%z" Dir/GR/Res/PWD assembly. RIH, kick off and drill 570' of the 8%2" intermediate section to the top of the Sag River formation at ~9170' MD. 17. Clean and circulate the hole, POOH. 18. Run and cement a 7", 26#, L-80, BTC-M drilling liner throughout the 8-1/2" hole and 150' back into the 9- 5/8" casing to ~8450' MD. Set the hanger and displace cement with mud. Release and set the packer. POOH. F-44A Application for Sundry ~ # 19. Test the 9-5/8" x 7" liner to 3,500 psi for 30 minutes once sufficient compressive strength has been achieved. Record the test. 20. M/U a 6-1/8" BHA with Dir/Gr/Res. run in the hole to the 7" landing collar. 21. Drill out the shoe track. Swap over to 8.4 ppg FloPro mud and drill 20' of new formation. Perform an FIT to 9.6 ppg. 22. Drill ahead building to the horizontal landing point at ~9937' MD. Circulate bottoms up. POOH to change the bit & BHA. 23. MU a 6-1/8" BHA with DIWGR/RES/DEN/NEU. RIH and MAD pass the build section. Drill ahead in the horizontal as per plan to an estimated TD of ~10,799' MD. 24. CBU, short trip, circulate until clean and spot a liner running pill. POOH. 25. Run and cement a 4-1/2", 12.6#, L-80, IBT-M solid production liner through the 6-1/8" wellbore from TD to 150' inside the 7" shoe (~9020' MD). Displace the cement with a perf pill. 26. Set the liner top packer. Circulate the well from above the 4-1/2" liner with clean seawater. 27. RIH with 2-7/8" PowerJet perf guns at 6 spf on drill pipe. The Perf intervals will be determined from LWD logs. Plan to perforate overbalanced. POOH, LD DP and perf guns. 28. R/U and run 9,020' of 4%", 12.6#, 13Cr, VamTop tub+ng completion. Sting into the 4%z" liner tie back sleeve. 29. Reverse circulate with seawater and corrosion inhibitor. 30. Drop the ball and rod, set packers. 31. Test the tubing and annulus separately to 3500 psi for 30 minutes. Record each test. 32. Install a TWC, and test. Nipple down the BOPE. 33. Nipple up the tree, and test to 5000 psi 34. Freeze protect to ~2,200' TVD 35. Install a BPV. 36. Secure the well. RDMO. Post-Riq Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install the well house and instrumentation. Well Coordinates: SurFace Northin Easting _ Offsets TRS ~ Location ~ 5973564.7 652649.92 3249' FNL / 3080' FWL 11 N, 13 E, 2 Target Northin Eastin Offsets TRS Location 5970796.25 651796.91 720' FNL/2168' FWL 11 N, 13 E, 11 Bottom Northing Eastin Offsets TRS Location 5970000 651705 1514' FNU2059 FWL 11 N, 13 E, 11 F-44A Application for Sundry ....................... 3504' ....................... ~ @ 9779' .. ...sass~ . ..................... asoo~ ss PERF~RATION SUMMARY REF LOG: SVUS BHCS ON 02C10191 ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 2-1 t2" 6 9580 - 9590 S 11 AD5/05 4-1 f2" 5 96D7 - 961 S C 02l24FJ1 2-9 t2" 4 9685 - 9695 C 03 t24196 2-11'8" 8 9695 - 9710 C OSM 1191 4-1 r2" 5 9705 - 9720 C 02l24FJ1 ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3116 30$0 ~ MERLA RA ST73 5508 31 MERLA RA 3 7581 7469 25 MERLA RA 2 8706 8098 24 MERLA RA 1 8799 8183 24 MERLA RA CMT SQZ'D T09-518" SHDE(11l07/05) 9648' 3-1C2" OTIS TBG TAIL WILEG 9649~ ELMD TT LQGGED 02123191 DATE REV BY COMMENTS DATE REV BY COMMENTS O~F161q1 ORIGINAL COMPLETION 11/07105 JLG17LH CMT SQ2 09/09/01 RNffP CORRECTIONS 11M2105 SFNIPJC ABORTED CTD-VVSSTUCK @2111' 01l03lp3 JM11tAK PULL }{}{ PLUG 07M3AD3 CMOITLP MAHANGLECORRECTION 09~23IpS JAF7TLH }{}{ PLUG SET 11~D6lOS GJB/fLH TBGPUNCH,PERFS,EZSV PRUDHOE BAY UNIT WELL: F-44 PERMIT No: ~ 910084 API No: 5 0-029-221 3 0-00 SEC 2. T11 N. R13E, 3248' FNL 8 2199' FEL BP E~larotion ~Alosko~ TREE _ `~~~ ~~ F ~ ~ A WELLHEAD = McEVOY S N~TES: THETIW PYfRS MAYFAIL IF MORE ..........._._ ..................................................... ~ ACTUATOR = OTIS THIW F700 P51 UIR~REFlTIAL PRESSURE IS KB..ELEV= 65.66' ,F"'~'~A~iTC~~LbC~~~`~ ~~~'~~~I~' EXCEEUEO. .. . . .......................................................... BF. ELEV = 37.98' TREE = 4" CIW VVELLHEAD = McEVOY A CTU ATOR...- .. ..... ................ ........ ........... .........OT IS ............................... ICB. ELEV = .. .. .... . . . 59.1' . . . . .. . ................... ... BF. ELEV = . ... ............ .............. 34.7' K 4P .. ...................... .................. 860 0~. Max Angle = .. ...... 91 ~10104' ................. Datum MD - ...................................... 9419' ................................. Datum TVD = 8800' SS I 13-3P3" CSG, 68#, NT-80, ID =12.41 S" ~ 2685 ~ 9-518" x 7" ZXPIHGM BOT LinerTop 8450' 9-5J8" x 7" BOTZXPlHCM Liner Packer $d~a~ 15.8 Class G Cement 9-5/$" BOT VU hi StOCk $E2O' 9-~a!'8" EZSU 8620' 3-1I~" Tubing Cut W 88D0' ' ~TOP OF 7" LNR~ 8897 ~ ', 9-SP8" CSG , 47# , L-80 , ID = 8.681 "~ F~~ ~~ SAF QTES: THETNIt PKRS MAYf~51L IFMORE ~~~~~~~[~ DCCEEDED.PSIDIFFERENIIAL PRESSURE IS ~,,,„,~ 2200' 4-1I2" }C Nipple ID=3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE S 4 3 8600' - To of W indow KOP 8900' 4-1t2"}CNi le ID=3.813" 8911' 4-112" x 7" BOT S-3 Packer $937' 4-1I2" X Ni le ID=3.813" 902D' 4-112", 12.6#, 13Gr-80, VamTop TBG. $999' 4-112" ?CN Ni le ID= 3.75" 9020' 4-1/2" V+(LEG ~ 9020' ~~~X4~rz°ZXPlHCMBOTLinerPacker `~.,,, 9170' 7", 26#, L-80, BTC-M Liner PB~F01~`I110N SIJNIMAF~( REF LOG: SWUS BHCS ON 02120/91 A NGLE A T TO P P9~F: IVate: Fae~Fer to Production DB for histarical erf data SIZE SPF INT6~VAL OprJSqZ CKITE 2-1l2' 6 9580- 9590 S 11Id5I05 4117' S 9607- 9615 C 02124i91 2-1I7' 4 9685- 9695 C 03J24196 2-1I8" 8 9695- 9710 C 05J11t91 4-1I2" 5 970a- 972D C 02l24l91 3-1J2" TBG, 9.2#, L-80, .Od87 bpf, ID = 2.992" 9648' , PBTD 9810~ ', 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 985F' ~ 41~2" 12.6#, L-80, IBT-M Liner 107JJ~ 15.8ppg Class G Cemerrt with Gas Black 8839' 9-Sf8" X 3-1 C2" HBBP-R PKR, ID = 4.00" Ss~7z'-8866~ TBG PUNCH (11105AD5) ~ C MT SQZ'D TO 9-5f8" SHDE (11107~1D5) 9459' 3-1 f1" CAMCO SLIDING SLEEVE CB-1 , ID = 2.750" 9565~ EZSV (11ADBA05) 96~8' ~TNV PERM PICR HBBP W! ANCHOR LATCH,10 = 4.OD" 9636~ 3-7C2" SWS NIP. ID = 2.750" 9636' a-~rz" 7CX PLUG (09C23ld5) 96d3~ 3-1 C2" SWS NIP, ID = 2.750" 9648, I~13-1C2" OTIS TBG TAIL WlLEG ~ g64g' ~t ELMD TT LOGGED 02l23191 DATE REV BY COMMENTS DATE REV BY COMMENTS 42fr6~47 OFiIGIHAL COMPLETION 11rtD7lOS JLGlTLH CMTSQZ 09l09l01 RNtTP CORRECTIONS 11i12105 SFNiPJC ABORTED CTD-WS STUCK ~2111' 01103N3 JMMAK PULL }{}{ PLUG 07113AD3 CMOITLP MAX ANGLE CORRECTION 09C23lOS JAFfTLH H34 PLUG SET 11AOBA]5 GJBlTLH TBG PUNCH, PERFS, EZSV PRUDHOE BAY UNIT WELL: F-44 PERMIT No:'191 D080 API No: SD-029-2 21 30-00 SEC 2, T11N, R13E, 3248' FNL & 2199' FEL BP Explorrtion (Alrakr~ l'(1M1'ANY I~I~:INI ti tlYAm~k~i ~ hf~ c~.E,~u,oM.w~d~. M~w~~~w.~~~ r v+y..•.m: ~s~'wsn 1'~m M 1hx1: I~re~ 1'>Ln4 Iiivlh Fn~u f~uNCC~. I:~q~IrW ' (~uW~ ~1 W M WN 14~ IW am~oy e : . 7800~ ~ ~ . . . _ _ . . . ~\. . „ . . . . __.-._ . . . °0 84U0 ~ ~-- =-' . . . --... . L u C~ . . . _._ _~. ~ . HINN _ ~ _ ~ . > 2 r ~. 8600 . . .. . . . . . . . ,I ~ , f W~IJUJJI~ 1: INFf )IthlAllUN SIINVI:Y YI[(Ni1UM PWo: F-41A x7N17 (t'-~4~YLw 1'-NAI 1~~.~Nuuu• lN:l~:l F4Ln~na: wellt'~vte-. F-W. InrN~mh I~p1E km U7nA 1'n 5~vy/1'Lv inul l'~¢atpl BY: Tmy lakaM~ck1 U~„I(i,Ap.aJlµe: ?,'_M,'_IIUG ~'uv:J11VU1141awii: _YS.i]'J%fi/~dlt 1.x~~~o1~'11141~reai~. ti4~1-1i1~WN.I/.W~1 %GMIUII IIITM/.l. Woood:F-4Uw~/J)VIS MWU ('y~~~' Uile: AI.~:~.un~ll~phK.~lan~uc~. 2,v5~t].'J\ fi6.4X (~:J.uLiriuAlM~: Mwmum('unanue Ae~~iM~'N' Uale', WFJ.1. DI:'fAL ti CASING DETAILS r+~o -w-s •~-w wwmiq ~~moe ~m~.fc ~,o~a~ sni !-Ct 100257 1]106~ SY]156iW 65.hSU4X )Il-'_U115.IJ3N Itti'05'iISI~W 94 - No. TVD MD Name Size ~--~ I 8575.48 9169.69 7" 7.000 TARGET DETAILS 2 9041.48 10799.00 4.5 4.500 ' '~~ Name TVD +Ni-S +E--W Nonhing Eattiag Shape I f, I I ' ---' F-04A Tazget 3 9041.48 -354428 -1018.1 I 5970000.00 65 U05.00 Point FORMATION TOP DETAILS F-44A Target 1 9054.48 -2750.00 -910.00 597079625 651796.91 Poim ~~~ F-44A Polygon 9054.48 -2853.87 -1274.13 59J0685.00 651435.00 Polygon No. TVDPaW MDPat6 Formatiou ' 1 8575.48 91G9.69 TSGR SBCTION DETAILS ID, %I~.xY rv D 2 $$48.48 95I1.50 TCGL t~, xox5.2x~7v D 3 8923.48 961131 BCGL Sec MD Inc Azi TVD +N/-S +Ei-W DLeg TFace VSec Target . .. --~--~ 1 8600.00 2?.99 194.95 8066.89 -2274.77 -262J8 0.00 0.00 L27.46 ~ ~~~ ~ 2 8620.00 2332 201.00 8085.28 -2'_82.24 -265.21 1'_.00 65.00 ?2353I ~ ~ ~ ~ ~ ~ -~--~~ ~ - ~ ~ ~ -~- ~ - 3 9064.96 30.?5 238.19 8485.01 -?424.66 -393.0? 4.00 SSAZ 241?.86 --. -~. ~ - -- ~- - ~ ~ ~ ~ - - ~- - --~ - - 4 9198.07 30.?5 238.19 8600.00 -2460.00 -450.00 0.00 0.00 ?465.55 . . . -_-. . . . . .. _ .___. . . . . . ... ___ _ ... _ . 5 9419.05 41.29 237.72 8779.0? -2528.48 -55928 5.00 -1.61 256717 6 9612J6 4L29 237]2 89?4.56 -?596.73 -66735 0.00 0.00 266836 - 7 9937.48 90.00 237J2 9054.48 -2750.00 -910.00 15.00 -0.01 269539 F-04A Target I . . . __-__ .___.. . . . . ._ .___ . . . ---~ --.. . 8 1038?.32 9L11 171.00 9049.59 -3132.68 -108330 IS.00 -88J9 331427 . . .___._ -~-- _.--- -~ ... . . _ .~-.._. ~r'-- - - . . . ._.._----. _. . . . . . . . . ~ . 9 10799.12 91.11 171.00 9041.48 _ ~ 3544._8 -IOIS.i I 0.00 0.00 3678.75 F-44A Target 3 ~ ~~ ~~ _ ~ -. . . - - - ~ - ~ ~ --_ . . ~ ~-- -r -- - . _ . . . . . . . ... . . _ ... . ____..._ __ .__ __-... FndDir:91M 4.46'M ,8485.UI'TVD . -.--_ . . . .. I . - i ~ , . . . . - . ' _~ - . - . ~t' ~ ~/ - ~ ~ ~ ~ ,\ Start Dir 5'!/Il ' : 9198.07' MD, NfilNl'ND ~ ~ ~ . ~ . . _ ._~ ~ _. __~-- ~ ~'t : ----_ . . _ . . . . . . ~ . '~ - -- ~ ' . . . . _~ . . . . . . . . . . '- -- ' .. _ --_.-~. . ~ { ~ . ___ . . . . . . . . . . . . -- .. . - / . ..., ~ . . . . . . . .. . . . . . . . _ .. . __- ~= - / '~ ' ~ 5~ ~ F _ ; A ~ ~ -~~ . ~ .: _ : : ^ ~--E-~- , ~ , i~nu~~ Faan iyx~ F-4t Tuget 1 F-04 ( F-44) ~ , I 2600 2800 3000 3200 Vertical Scetion at 200.00° [200ft/in] . F-44 Targa J 3600 3800 4000 I ~ • - - - ~ - - y,y^~~,, ~. j V~] ('()MYANY UI:IAILti tlYAmixu ItF}F7tF.t~M L P1FUIfMA1MIN ('oonimiYlNL)141rnv W 11l'iaue-.F-t1.TneN~wlh " SURVEY PltOlilUM UeplhFm IkpW fu timvy/PLv fa~l pWp: k~-1iA xpU7 (F-4MYleu F-0YA) C'fG~rdUy:'ImylakaAU5l7'Qa4a10(u:ImcuLpe:~_8.IN6 utl , !i~ f'ukuLmi~uM~h~J'. Mmw~m(lv~'alwe I4%/fJ% Vaxt~al(IVIl1Nrl~a~a- 1 ~~ Sa~ ~nIV\I~(en:n VLn-~J11)WN.I1.Wk) M4IMIOU 10'/YY.12 PL d:FSNwpO'/VIS MWD ('~~~_ Uute. , In~rt\Y.~•m'. Itil'WSA \'..mMnh~J~.Im~~l'Y~odulAxW Mrs+wNlXpthite[ercui•: 2x3~~]!/Y fi4.0!{ ('a4ulauuuMn6wi:Mmwuml'un~Awe W Fl1IKIAlIti ~~~~ s~~. r~qw ~ c~ W+mw6MMW'. IWY:>tla~i Nme - W-Y -Fi'-W ~~o€ ~~Y ` ' IatOUJe Wppaule SWI '~ ' I]i560W (32(3U(.Y 711 21)Y)5.14:N I~1X95 JI.SIdW 41 F-37 IW3S I IJIU6~ 5 ' 1 TARGE'C DETAILS ~ . -.. . ~ ~ I Name 7VD +N;-S +6,'_W Northing Easting SGape I I ~--.!. . I.-_~:- .~~-.._ . . -'-~-~-~ ~ F-44A Target 3 9041.48 -354428 -1018.11 5970000.00 651705.00 Point ~~ . . _-_. .. . . ... - - -- -.._. . . . F-44A Target 1 9054.48 -2750.00 -910.00 5970796.25 651796.91 Point . . . . . . . _ . . . . F44A Polygon -1274.13 9054.48 -2853.87 5970685.00 651435.00 Poi ygon -ISUO , . . . . . . . . _ - . . . . . .. _. _ __ . . . ' . . . . . . . . CASING DETAILS , . . . . . , . . . . . . . . . . . . . . . . .._. . . . _ .. _ _ . . . - ...---._ . . ~ : Qpp . . . . . . . No. TVD MD Name Size ~, . .. ~-;__.T._~ . . . ._. . .;.T. . . . ~ _ . . . ~ I- ~I~- - _ ~ ~ --- - 1 8575.48 9169.69 7" 7.000 ~ I -~.-~-; -~---.... . . -4-~... . . _.__ . . . . - . . ~-'-. . .._. . . -~--~-~-~-- ~ .. . . j ~ . I _ ~ --1--~-1-~' . . . , .__. --1--~.. . . . _ _ 2 9041.48 10799.00 4.5 4.500 ~ ~ . .. . . . . , .. . . . . _ . . . .. _ . . . . . . . . . .._ . . . . . _ ...--- . . . _--. _ . . . . + ~ . . . . . . . . . . . . . . _ . . . . . . . . . FORMATION TOP DETAILS ...._ .._ . . . . _ _ . . . . . . . --- -._... . ' 7~00 . . . _ _ . . No TVDPath MDPath Formation ~ -2100 . ' . . _ . . . . . . . . . . . _ . __.__. .. . . . . ~ S Dir 12?;100' : 6600' MD 066 . 89'TVD I 8575.48 9169.69 TSGR . '. ...... . . . . . . . . . . . ---- -- ~- I , . 2 8648.48 951I.50 TCGL ~ ~ ' __.. . -+- ~T . . +-,- . __ . _ . ' _ . . . ~ . -- . . -t- ~ ~ ; t / ~ . - - . 3 6923.48 9611.31 BCGL . I ,~ ~ . - . ;- ~ _ - ~° ~_ 6000 . Star t ir 4?i 100' : 8620' MD. 80 .28'T VD ~ - -?400 _ . . . . . . . . . p~ ~ - - - - -- . End Dir : 064.96' MD. 8485.01' 7'V . - . . ` . . . / ~ _" ~ o ~ _ . . . . . . ___ . SSUO .850 _. __ Start Dir 5?. I ' : 9198.0~' MD, 8600 _. . _ . . . ._ r_ _ . / ~ ~ r ~_ ._ . - 44A PolYBan ~.. - ~- ---- . : - . .~.. ..-.. . ~ / t o ' ~ " ~ ' ' - ~ ~ ~ , ~ En d Dir : 9419.03 D. 8779.01 ND : _ _ _ , ~ I s . ~ . . , . . . . . . ~ o' -'700 ' . ~ . _ _ r . . . , . . . _ . F-44A Target I , 9000 ~- . . . . ~ ~ / '~q --~' I --- tartDir IS?,100':9612 J 89?4 MD 56'TVD - '---~-- ~ ~ ' .. . . F 4 (F-44) ` . . ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ,i_!_ -~--!- ~,~ "O I _ . • ' ~ , ; - ~ ~ ..~ - - ~ . _ . _~- . ... . .. _ . . . rt~_ . _ ~ ~ ~ ~ -- ~ ---- ~ End Dir : 10382.31' MD, 9049.59' D -^ , _ ~ ._. . .', . . . _ . ~. . -~~ ~ ~ . . ~ ~ ~ . ___-_ . . . . ~- ._.. . . . . .r .. .. . ~ ~ . _~..__ . . . - . ~, ~~, . ~ , . . ..~ . . ~._.~., _.. . . ,._._ . . .~. . . . . . . .. .. . . . . . . ... . . . . . . . . . . . . . . . .. . . _ . . . . . SECTION DETAILS ~. i -330 . . . . . . . . . . . . . . . . . Sec MD Inc Azi TVD +N;-S +Ei-W DLeg TFacc VSec Target ... . ~. . Total Depth : I 799.12' MD, 9041.48' 1'V ~ ~ g600.00 22.99 194.95 8066.89 -227477 -262.76 0.00 0.00 2227.46 ~ - - ~ - ~ ~ - ~ ~ ~ 2 8620.00 2332 201.00 8085.28 428'_.24 -26511 1?.00 85.00 2135.31 ~ ~~-~ --- F-44A Target 3 3 9064.96 3015 238.19 8485.01 -2424.66 -393.0: 4.00 85.02 ?41?.86 --~--~ ~ ~~~ ~~ 4 9198.07 30.25 238.19 8600.00 -2460.00 -450.00 0.00 0.00 ?465.55 ~ ~ - - F-44A wp07 5 9419.05 4119 237.72 8779.0? -2528.48 -559.28 5.00 -1.61 '_567.27 . . . _ 6 9612J6 41.29 237J2 8924.56 -2596J3 -667.35 0.00 0.00 2668.78 LL _ F-04,PIan F-04 ,F-M14A wp06 7 9937.48 90.00 237J2 9054 48 -2750.00 -910.00 I5.00 -0.01 ?895.39 F-44A Targe~ I 8 1038232 91.11 171.00 9049.59 -313?.68 -108330 I5.00 -88.79 331417 Pian F-44A 9 10799.12 91.1 I 171.00 9041.48 -3544.?8 -1018.11 0.00 0.00 3676.75 F-44A Target 3 -3600 -I500 -1200 -900 -600 -300 West(-)~ East(+) [300ft~in] 300U- • Sperry-Sun BP Planning Report ~ Company: BP Amoco Date: 2/28/2006 Time: 16:13:38 Page: '` 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL• F-44, True North Site: PB F Pad Vertical (TVD} Reference: 28.5+37:9$ 66:5 Well: F-44 Section (VS) Referencee WeII j0.00N;0.00E,200.00Azi) Wellpath: Plan F-44A Survey Galcutation Method: Minimum Curvature Db: Oracle Plan: F-44A wp07 Date Composed: 10/7/2005 Version: 15 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB F Pad TR-11-13 UNITED STATES : North Slope Site Position: Northing: 5972527.29 ft Latitude: 70 19 55283 N From: Map Easting: 650960.70 ft Longitude: 148 46 31.468 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.15 deg Well: F-44 Slot Name: 44 F-44 Well Position: +N/-S 1002.57 ft Northing: 5973564.00 ft Latitude: 70 20 5.142 N +E/-W 1710.63 ft Easting : 652650.68 ft Longitude: 148 45 41.514 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9169.69 8575.48 7.000 8.500 7" 10799.00 9041.48 4.500 6.750 4.5 FormaHons MD TVD Formations Lithology Dip Angle DipDirecdon ft ft deg deg 9169.69 8575.48 TSGR 0.00 0.00 9511.50 8848.48 TCGL 0.00 0.00 9611.31 8923.48 BCGL 0.00 0.00 Targets Map Map ~-- Latitude --> <-- Longitude --> Name Descripdon TVD +N/-S +E/-W Nort6ing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft F-44A Target 3 9041.48 -3544.28 -1018.11 5970000.00 651705.00 70 19 30.283 N 148 46 11.231 W F-44A Target 1 9054.48 -2750.00 -910.00 5970796.25 651796.91 70 19 38.095 N 148 46 8.078 W F-44A Polygon 9054.48 -2853.87 -1274.13 5970685.00 651435.00 70 19 37.073 N 148 46 18.707 W -Polygon 1 9054.48 -2853.87 -1274.13 5970685.00 651435.00 70 19 37.073 N 148 46 18.707 W -Polygon 2 9054.48 3537.14 -1122.99 5970005.00 651600.00 70 19 30.353 N 148 46 14.292 W -Polygon 3 9054.48 -3532.54 -857.82 5970015.00 651865.00 70 19 30.399 N 148 46 6.552 W -Polygon 4 9054.48 -3030.57 -947.63 5970515.00 651765.00 70 19 35.336 N 148 46 9.176 W -Polygon 5 9054.48 -2929.14 -770.52 5970620.00 651940.00 70 19 36.333 N 148 46 4.006 W -Polygon 6 9054.48 -2677.35 -855.42 5970870.00 651850.00 70 19 38.810 N 148 46 6.485 W Plan Section Information MD Incl Azim 1'VD +iV/-S +FJ-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100k deg/100ft deg 8600.00 22.99 194.95 8066.89 -2274.77 -262.78 0.00 0.00 0.00 0.00 8620.00 23.32 201.00 8085.28 -2282.24 -265.21 12.00 1.63 3025 85:00 9064.96 30.25 238.19 8485.01 -2424.66 -393.02 4.00 1.56 8.36 85.02 9198.07 3025 238.19 8600.00 -2460.00 -450.00 0.00 0.00 0.00 0.00 9419.05 41.29 237.72 8779.02 -2528.48 -559.28 5.00 5.00 -0.21 -1.61 9612.76 41.29 237.72 8924.56 -2596.73 -667.35 0.00 0.00 0.00 0.00 • Sperry-Sun BP Planning Report ~ Company: $PAmoco Date: 2/28/2006 Time: 16~13:38 Page: 2 Field: Prudhoe Bay Co-ordinate(N E) Reference: WeIL• F-44, Ttue North Site: PB F Pad Vertical ('fVD) Reference: ' 2$. 5+37.98 66.5 Well: F-44 Section (VS)Beference: WeIC(O.OON,O.OOE,200.OOAzi) WeRpathe Plan F-A4A S urvey Caiculation Method: Minimum Curvature Db: OraCle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Buiid Turn TFO Tatget ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9937.48 90.00 237.72 9054.48 -2750.00 -910.00 15.00 15.00 0.00 -0.01 F-44A Target 1 10382.32 91.11 171.00 9049.59 -3132.68 -1083.30 15.00 0.25 -15.00 -88.79 10799.12 91.11 171.00 9041.48 -3544.28 -1018.11 0.00 0.00 0.00 0.00 F-44A Target 3 Survey MD Incl Azim T'VD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 8600.00 22.99 194.95 8066.89 8000.41 2227.46 -2274.77 -262.78 0.00 5971284.53 652434.27 Start Dir 1 ? 8620.00 23.32 201.00 808528 8018.80 2235.31 -2282.24 -265.21 12.00 5971277.01 652432.00 Start Dir 4. 8700.00 23.80 208.92 8158.63 8092.15 2267.09 -2311.15 -278.69 4.00 5971247.83 652419.11 M W D 8800.00 24.93 21822 8249.76 8183.28 2307.06 -2345.38 -301.49 4.00 5971213.14 652397.01 MWD 8900.00 26.60 226.60 8339.84 8273.36 2347.11 -2377.34 -330.81 4.00 5971180.60 652368.35 M W D 9000.00 28.69 233.95 8428.45 8361.97 2387.06 -2406.86 -366.50 4.00 5971150.36 652333.27 MWD 9064.96 30.25 238.19 8485.01 8418.53 2412.86 -2424.66 -393.02 4.00 5971132.03 652307.12 End Dir : 9100.00 30.25 238.19 8515.28 8448.80 2426.73 -2433.96 -408.02 0.00 5971122.42 652292.32 M W D 9169.69 30.25 238.19 8575.48 8509.00 2454.32 -2452.46 -437.85 0.00 5971103.32 652262.87 7" 9198.07 30.25 238.19 8600.00 8533.52 2465.55 -2460.00 -450.00 0.00 5971095.54 652250.88 Start Dir 5. 9200.00 30.34 238.19 8601.66 8535.18 2466.32 -2460.51 -450.83 5.00 5971095.01 652250.06 MWD 9300.00 35.34 237.94 8685.65 8619.17 2509.00 -2489.19 -496.83 5.00 5971065.40 652204.65 MWD 9400.00 40.34 237.76 8764.60 8698.12 2557.43 -2521.83 -548.75 5.00 5971031.71 652153.41 MWD 9419.03 41.29 237.73 8779.00 8712.52 2567.27 -2528.47 -559.27 5.00 5971024.86 652143.03 End Dir : 9419.05 41.29 237.72 8779.02 8712.54 2567.27 -2528.48 -559.28 5.00 5971024.85 652143.02 MWD 9500.00 41.29 237.72 8839.84 8773.36 2609.53 -2557.00 -604.44 0.00 5970995.42 652098.45 M W D 9511.50 41.29 237.72 8848.48 8782.00 2615.53 -2561.05 -610.86 0.00 5970991.24 652092.12 TCGL 9600.00 41.29 237.72 8914.98 8848.50 2661.72 -2592.24 -660.23 0.00 5970959.05 652043.39 MWD 9611.31 41.29 237.72 8923.48 8857.00 2667.63 -2596.23 -666.55 0.00 5970954.94 652037.16 BCGL 9612.76 41.29 237.72 8924.56 8858.08 2668.38 -2596.73 ~67.35 0.00 5970954.42 652036.37 Start Dir 1 ? 9700.00 54.38 237.72 8983.00 8916.52 2719.42 -2631.19 -721.91 15.00 5970918.86 651982.53 M W D 9800.00 69.38 237.72 9030.00 8963.52 2788.98 -2678.15 -796.26 15.00 5970870.40 651909.15 M W D 9900.00 84.38 237.72 9052.64 8986.16 2865.79 -2730.01 -878.36 15.00 5970816.88 651828.13 M W D 9937.48 90.00 237.72 9054.48 8988.00 2895.39 -2750.00 -910.00 15.00 5970796.25 651796.91 F-44A Tar 10000.00 90.20 228.34 9054.37 8987.89 2947.75 -2787.55 -959.90 15.00 5970757.70 651747.79 M W D 10100.00 90.50 213.35 9053.76 8987.28 3040.93 -2862.98 -1025.11 15.00 5970680.96 651684.13 MWD 10200.00 90.77 198.35 9052.64 8986.16 3140.12 -2952.72 -1068.58 15.00 5970590.37 651642.50 MWD 10300.00 90.99 183.35 9051.10 8984.62 3238.56 -3050.64 -1087.35 15.00 5970492.09 651625.73 MWD 10382.32 91.11 171.00 9049.59 8983.11 3314.27 -3132.68 -1083.30 15.00 5970410.15 651631.45 End Dir : 1 10400.00 91.11 171.00 9049.24 8982.76 3329.73 -3150.14 -1080.53 0.00 5970392.75 651634.57 M W D 10500.00 91.11 171.00 9047.30 8980.82 3417.18 -3248.89 -1064.89 0.00 5970294.35 651652.21 M W D 10600.00 91.11 171.00 9045.35 8978.87 3504.62 -3347.64 -1049.25 0.00 5970195.94 651669.86 MWD 10700.00 91.11 171.00 9043.41 8976.93 3592.07 -3446.39 -1033.61 0.00 5970097.54 651687.51 M W D 10799.00 91.11 171.00 9041.48 8975.00 3678.64 -3544.16 -1018.13 0.00 5970000.12 651704.98 4.5 10799.12 91.11 171.00 9041.48 8975.00 3678.75 -3544.28 -1018.11 0.00 5970000.00 651705.00 F-44A Tar nent F-44A Cement Caiculations Tom, These are my calculations for cement on F-44A. I realized in my phone message 1 said 150 ft above the liner top, that isn't right. It is 200 ft above the liner top and 150 ft of liner lap inside the previous string. Both liners are going to be fully cemented with a 15.8 ppg class G cement. I am in a training class tomorrow, but you can call me on my cell at 440-2389 with any questions. Intermediate Liner 8-1/2" open hole x 7" liner + 40°/a excess; 553 ft= 17.5 bbls 9-5/8" x 7" liner lap; 150 ft= 3.8 bbls 9-5/8" casing x 4" drillpipe; 200 ft = 11.5 bbls 7" shoe; 80 ft.= 3.1 bbls Total = 36 bbls ~ ~ °Z~ ~~ -r x ~, !G Production Liner 6-1/2" hole x 4-1/2° liner + 40% excess; 1629 ft = 38.3 bbfs 7" x 4-1/2" liner lap; 150 ft= 2.8 bbls 7" liner x 4" drillpipe; 200 ft= 4.5 bbls 4-1/2" shoe; 80 ft. = 1.2 bbls Total = 47 bbls ~ a 3~ ~~ Thanks, ~~ ~ Kris Honas GPB Rotary Drilling 564-4338 440-2389 , 1 of 1 3/9/2007 7:41 AM ~ • ~~ "~~'~~ Fieltl & Pool PRUDHOE BAY, PRUDH~E OIL - 640150 ~ Well Name: PRUDHOE BAY UNIT F-44A_ "' __Prograrr~ DEV _ Well bore seg __ ~~N~~ ~~ f, ~. - -- - _ PT6#:2051610 Company BP EXPLORATION_ALASKA INC__ Initial Classlfype _DEV/1-OIL __GeoArea 89~___ _________ _ _ Unit 11650__ _____ Cn/OffShore On ___ _ AnnularDisposal ',_, ' Administration 1 Permit_fee atkached ____ _ . Yes 2 Lease number appropriate . _ _ _ _ _ Yes _ 3 Unique well_name and number - - - - - Yes - - - - - - - - - - - - 4 Well locat_ed in a_d_efined_pool_ _ _ _ _ . - Yes _ _ _ _ _ _ _ 5 Well located proper distance_f[om drilling unit_boundary_ . _ _ _ _ _ . Yes _ _ _ _ . _ . . . 6 Well located proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 7 Sufficient acreage ayailable in_d_rilling unit _ _ _ _ _ _ _ . YeS _ '~i 8 If tleyiated, is_we_Ilbore plat_inclu_ded _ . _ _ _ _ _ . Yes . _ _ _ _ _ . . . 'i 9 Operator only zffected part~ - - Yes . ~ 10 Ope[atorhas_appropriate_bondinforce.------_------.-- _------ Yes- -_----- - -------_-- ----- -- --- - ------ _- ------- i 11 Permit_can be issued without conservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Ye~ _ _ _ _ _ _ _ . . . . pp A r Date I 12 Permitcan be issued without administrative_approval ... Yes RPC 10/31/2005 I ~ 3 Can permit be approved before 15•day wait Yes 14 Well located within area antl strata authorized by_Injection Order# (put10# in_comments)_(For_ NA. . . 15 Allwelis_withinll4_mileareaofreyiewidentified(Forservicewellonly)_______________ NA_. _____._.____________..______________ 16 Pre-produced injector; duration of pre p[oduction I_ess than_ 3 months_ (For service well. only) __ NA_ _ .. . i NA . . . . - - - - -- -- - -- . _- - -- -- - _ __ _ _ - -- --- - -- _ ---- -- - ~n^ir^~ring 1 18 ConducfoCStringprovided . NA j !, 19 Surface casing_protects all known_ USDWs . . NA . ~ ~'~ ~ 20 CMT_vol adequale to circulafe on conductqr & surf csg _ . NA . . . ~ 21 CM i vol adequate tg tie-m long slring to_surf csy _ . NH 22 _C_MT_will coyer_all known_pro_ductive horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Adequate excess, _ _ _ _ _ 23 Casingdesignsadequatefo[C,T,B&_permafrost-------------------------- Yes- ----------------------------------- -------------.---------------- - 24 Adequ~te tankage_o_r reseCve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ _ _ _ _ _ Rig is_e_quippetl with st_eel_pits. _No reserve_p_itplanned, All waste to approved disposal_well(s). _ _ _ _ . _ _ . _ . , 25 If a re-drill, has_a 10-403 for abandon~nent been approved Yes Pr_oposed pluggingper_305-332. Operations_halfetl per 305-354. F-4~1 is ~onsidered_P&Aed in RaDMS database ~ i , 26 Adequate wellbore separatio_n_proposed- - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - ~ 27 If tlive[ter required, does it meel regulations_ . _ _ _ _ _ _ NA_ _ . _ - - Sidet[ack. _ . _ _ _ _ _ _ _ ;;Npr Date 28 Dri!ling fluid_pr~gram schematic & equip list adequate_ _ _ . . . . . Yes - - - . - Max MW 8,6 pp9, - - - - _ _ - . TEM 07 29 BOP:=s, do they meet_ regulation __ Yes _ ___ . ~ 30 dOF~ ~ress rating appropnate; tesi to_(qut psig in comments). .___ Yes _ _ Test to 3500_ psi. MSP 2280 psi._ __ ~ 31 Cho~e_manifold complies w/API. RP-53 ~May 84) Yes _ __ ~ 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ Yes . . _ _ _ _ _ 33 Is presence_of H2S gas.Rrobable - Yes . - 100 PPm, -. - - - - 34 Mechanical_contl_ition of wells within AOR verified ~For.s_eNice well onlya _ . _ _ . , _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 35 Permit.can be issued w/o hydrogen_sulfide measures __. ._ No_ _ ____ 36 Data_presented on potential ove_rpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ , . _ . _ . _ _ _ _ _ _ - Appr Date 37 Se~s,mic analysis of shalipw gas_zones- - - - - - - - - - - - - - - . NA_ . RPC 10/31l2005 ~ 38 Seabed condition suryey.(if off-sho[e) _. .._.__ NA 39 Contact namelphone for weekly.progress reports_ [exploratory only] . NA, Geologic Engineering Public Date Dat Date: Original plan aborted when CT whipstock was stuck shallow. Plan revised to clear out wellbore and redrill using a rig rather Commissioner: Commissioner o is ioner: than coil. BHL has not changed. WGA reviewed 10l31105. Originally appr~ved 11/1l05. Sundry 307-084 submitted with 3 ~~ ~ revised plans 3106107. ~ ,. v ~ ~ ~~ FRANK H. MURKOWSKI, GOVERNOR Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU F-44A Sundry Number: 305-354 Dear Ms. Endacott: FAX (90~ 276-7542 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisl~day of November, 2005 Encl. C ~incPrPlv STATE OF ALASKA ~J j ~~ /S~,$ • ~ (( / js`O~ ALASKA OIL AND GAS CONSERVATION COM SION a:j7 ~~~8 ~- 1?a..~''~ ~ECEIVE[~ NOV 14 2QQ5 APPLICATION FOR SUNDRY APPROVI~~s~a Oi! & Gas Cons. cornmission 20 AAC 25.280 Anchorap~ J 1. Type of Request: ^ Abandon ^ Suspend ~ Operation Shutdown ^ Perforate ^ Other ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension 2. Operator Name: 4. Current Well Class .- 5. Permit To Drill Number BP Expbration (Ataska} Ina ~ Development ^ Exploratory 205-161 % 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22130-01-00 ~ 7. KB Elevation (ft): 65.66 9. Well Name and Number: PBU F-44A ~ 8. Property Designation: 10. Field / Pool(s): ADL 028280 Prudhoe Bay Field / Prudhoe Bay Pool ~~. PRESENT WELL CQ NDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9852 9174 9565 8934 9565 2120 Casin Len th Size MD ND Burst Colla se I 110' 20" 110' 110' 2685 13-3/8" 2685' 2685' 4930 2270 9157' 9-5/8" 9157' 8575' 6870 4760 961' 7" 8891' - 9852' 8333' - 9174' 7240 5410 Perforation Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None (Isolated w/ Cement) None 3-1/2", 9.2# L-80 9648' Packers and SSSV Type: 7" x 3-1/2" TIW Perm 'HBBP' packer; 9-5/8" x 3-1/2~ Packers and SSSV MD (ft): 9628', 8839' 'HBBP-R' packer 12. Attachments: ~ Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program 13. Well Class after proposed work: ~ ^ Exploratory ~ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November i2, 2005 ~ Oil ^ Gas ^ Plugged ^ Abandoned 16. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer Prepare0 By Name/Number: Si nature Phone 564-4388 Date 1~ ~ (~ Terrie Hubble, 564-4628 Commissfon Use Onl Sundry Number: 4 Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integriry p BOP Test ^ Mechanical Integrity Test ^ Location Clearance _ ~. ' , .- / ~ \.ro Other: ~~; p~ ~ ~.~~~l.i' r~ ~-~-' v r- ~,,,._. ~ (~ - ~ r:,r ~ ~.., ~ ::.,~ .,.~ ~, ~;; J,...~ c ~vv~ 4 ~'~~-~ ~ ~-z~;-°~t.3 . / ubsequent For ii: y; ~ ~ . ~~~ ~~~... (~j~tt ~. gp ?~Q~j APPROVED BY ~ ~ Approved COMMISSIONER THE COMMISSION Date f~ Form 1o-ao3 d 0 0 ubm' In Duplicate ~~ ~ ~~~~~~ ~ • Hubble, Terrie L From: Endacott, Mary S Sent: Monday, November 14, 2005 2:25 PM To: Tom Maunder (tom_maunder@admin.state.ak.us) Cc: Zamora, Chris A; Hubble, Terrie L; NSU, ADW Wells Tech Aide Subject: F-44 whipstock premature set Attachments: F-44CURRENT.CNV Tom On Saturday, Nordic 1 ran a whipstock into F-44 and it prematurely set in the SSSV. They have RDMO to DS 15-48. / The perfs are isolated by a plug in the SWS nipple as well as a cement retainer and cement job. BP will work on a workover plan to recover the whipstock. See attached schematic. ~ F-44CURRENT.CNV (169 KB) Mt~~YS. END~kCOTT $P i~LikSK~ COIL TU$INC~ D~ZLC~ £NC~~ OFC 74.7 907-564-4.3$$ endacomsCbp.com 'h~ _ • a° crov WElLHEAD = McEVOY ACTUATOR = OTIS KB. ELEV = 65.66' BF. ~EV = 37.98' KOP = 3500' Max Angle = 35@9779' Datum A~ = 9486' Datum N D= 8800' SS 13-3/8" CSG, 68#, NT-80, ~D = 12.415" 2685' Minimum ID = 2.750" @ 2111' 3-1/2" OTIS SSSV NIPPLE F~4 4 S ES: THE TIW PKRS MAY FAIL IF MORE THAN 2 PSI DIFFERENTIAL PRESSURE IS IXCEEDED. 2111~ 3-1/2" OTIS SSSV LANO NIP, ID = 2.75" 2120ctm 3 1/2" WFD LSX WHIPSTOCK TOF GAS LIFT MANDREIS l ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3116 3050 5 MERLA RA 4 5773 5508 31 MERLA RA 3 7581 7069 25 MERL.A RA 2 8706 8098 24 MERLA RA 1 8799 8183 24 MERLA RA 8829~ 3-1l2" PARKER SWS NIP, ID = 2.750" ~ 8839' TNV ANCHOR LATCH ASSY, RH RELEASE 8839' 9-5/8" X 4-1l2" HBBP-R PKR ID = 4.00" Tbg Punch 8862-64 - - ~ TOP OF 7" LNR $$91' 8891' 7" TNV Liner Hanger _Rn i~ Q15R~ Tbg Perforated ~ 9580-90 ~3-1/2" CAMCO SLIDING SLEEVECB-1, ID=2.750" ~ PERFORATION SUMIMARY \ REF LOG: SWS BHCS ON 02/20/91 ANGLE AT TOP PERF: 32 @ 9607' ~~ Note: Refer to Production DB for historical perf data t SIZE SPF IM'FRVAL Opn/Sqz DATE 4-1/2" 5 9607 - 9615 isolated proposed 2-1/2" 4 9685 - 9695 isolated proposed 9599~ BLAST JOINT, OD = 2.992" BTM 9618' 2-1/8" S 9695 - 9710 isolated proposed 4-1/2" 5 9705 - 9720 isolated proposed 9628' TNV 4 1/2" x 7" PERM PtCR HBBP WI ANCHOR LATCH, ID = 4.00" ~- 9636~ 3-1/2" SWS NIP, ID = 2.750" ~ 3-1/2" TBG, 9.2#, L-80, TDS, 0.0087 bpf, ID = 2.992" ~ ~~ 9810' , i~ = s.2~s° -~ g 9648' J ~ 9643~ ~-{3-1/2" SWS NIP, ID = 2.750" ~ J64$' 3-1/2" OTIS 1BG TAIL W/LEG J649' E1MD TT LOGGED 02/23/91 DATE F2EV BY COMMENTS DATE REV BY COMMENTS 02/26/91 ORIGINAL COMPLETION 09/09/01 RWTP CORRECTIONS 01/03l03 JMIKAK PUL XX PLUG 07/13/03 CMO(TLP MAX ANGLE CORRECTION 9/23/05 JAFITLH XX P~UG SET 11/14/05 MSE WHIP STl1CK iN SSSV NIP PRUDHOE BAY UNff WE1L: F-44 PERMff No: API No: 50-029-22130-00 SEC 2, T11 N, R13E, 3248' FNL 8~ 2199' F~ BP Exploration (Alaska) FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU F-44A BP Exploration (Alaska), Inc. Permit No: 205-161 Surface Location: 3248' FNL, 2199' FEL, SEC. 02, T 11 N, R 13E, UM Bottomhole Location: 1512' FNL, 3215' FEL, SEC. 11, T 11 N, R 13E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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 speci~cally authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleurr,y~"ield inspector at (907) 659- 3607 (pager) . ,~ ~ DATED thir~ day of October, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. iz~ ~A---~ ~ o i~ t~~~ z~ ~- ~ STATE OF ALASKA ~ ALASKA AND GAS CONSERVATION CO ~iSSION PERMIT TO DRILL 20 AAC 25.005 ~ ~,~ ° ~~` ~~., ~ ~~r~~~,~r ~C t .~ ~ ~00~ 1a. Type of work ~ Drill ~ Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ~ O' Multiple Zone ^ Stratigraphic Test ^ Service ^ ~~ ~~ ~~r~gle-~one , 2. Operator Name: BP Exploration {Alaska) Ina 5. Bond: ~ Blanket ^ Single Well Bond No. 6194193 11. Well Na ,, ~ber: . v..,.: PBU F-44A / 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10950 ND 8975ss 12. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surtace: 3248' FNL 2199' FEL SEC 02 T11 N R13E UM 7. Property Designation: ADL 028280 P~~ , , . , , , Top of Productive Horizon: 513' FNL, 2568' FEL, SEC. 11, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 8, 2005 / Total Depth: 1512' FNL, 3215' FEL, SEC. 11, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 14,130' 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 652650 Y- 5973564 Zone- ASP4 10. KB Elevation (Height above GL): 65.66 feet 15. DistanCe to Nearest Well Within Pooi F-02 is 400 feet away at 10771' 16. Deviated Wells: Kickoff Depth: 9540 feet Maximum Hote Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3170 Surtace: 2280 / ~ s. as ng rogram: Size Specifications Setting Depth To Bottom uanUty o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta e data 3" 2-3/8" 4.7# L-80 ST-L 1550' 9400' 8726' 10950' 8975' 9 cu ft Class 'G' 19. PRESENT WELL CONDlTI ON SUMMARY (To be completed for Redrill AND Re-entryOperations) Total Depth MD (ft): 9852 Total Depth ND (ft): 9174 Plugs (measured): 9636 Effective Depth MD (ft): 9810 Effective Depth TVD (ft): 9139 Junk (measured): None Casin Len th ' Size Cement Volume MD ND n r 110' 20" 110' 1 f 0' 2685 13-3/8" 723 cu ft Permafrost 2685' 2685' 9157' 9-5/8" 1887 cu ft Class 'G' 9157' 8575' Pro i n 961' 7" 82 cu ft Class 'G' 8891' - 9852' 8333' - 9174' Pertoration Depth MD (ft): 9607' - 9720' Perforation Depth ND (ft): 8969' - 9064' 20. Attachments ~ Filing Fee, $100 ~ BOP Sketch ~ Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Anatysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer Preparetl By Name/NUmber. Si nature Phone 564-4388 Date Terrie Hubble, 564-a628 Commission Use Only Permit To Drill API Number: Number: z p,s ,~ 50- 029-22130-01-00 Permit pr val Date: • ~ See cover letter for other requirements Conditions of Approval: Sa I s Required ^ Yes No Mud Log Reqwred ^ Yes ~No dro en Sulfide Measures ~Yes ^ No Directional Survey Required ~:Yes ^ No Other: ~ ~ S~ ! ~ ~ ' `~ ~~ c~ ~1 i.~: ; ~ APPROVEO BY O /~~ A roved THE COMMISSION Date ~~ Form 10-401 Revise /2 ~ y ' ~ ; `~ ' ~, ~ ~_~ Su it (n upliCate } ~ 4 s ~ , , 's3 i _ ~_~ ,. . .. ~^ - • BP ~ Prudhoe Bay F-44A CTD Sidetrack Mud Program: • Well kill: 8.5 ppg e • Milling/drilling• 8. ppg Flo Pro or biozan for milling, new Flo Pro for drilling, Disposat: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 2 3/8", L-80, 4. , ST-L fully cemented liner - 9400'MD to 10950'MD in a 3" hole. / • A minimum 7 ls 15.8 ppg cement will be used for liner cementing. Casin in formation 13 3/8", NT-80, 68#, Burst 5020 psi; collapse 2260 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 7", L-80, 26#, Burst 7240 ; collapse 5410 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. r • The annular preventer vvill be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 91 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 14,130 ft. • Distance to nearest well within pool - 400 ft to well F-02 at 10771'. Logging • MWD directional and Gamma Ray will be run over all of the open hole section. • A cased hole CNL/GR/CCL log will be run. Hazards • The maximum recorded HZS level on F pad is 10 ppm . Reservoir Pressure • Res. press. is estimated to be 3170 psi at 8800'ss (6.9 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2280 psi. / i TREE _ 4" CNV F -44A Proposed CTD Sidei S OTES: THE TIW PKRS MAY FAIL IF MORE THAN 2100 PSI DIFFERENTIAL PRESSURE IS IXCEFDm. WELLHEAD = McEVOY ACTUATOR = OTIS KB. ElEV = 65.66' BF. E1EV = 37.98' KOP = 3500' Max Angle = 35 @ 9779' Datum MD = 9486' Datum ND = 8800' SS 13-3/8" CSG, 68#, P!T-80, ID = 12.415" Minimum ID = 2.750" @ 2111' 3-112" OTIS SSSV NIPPLE Punch ~~ 8845' TOP OF 7" LNR = 80, ID = 8.681" Cmt Retainer ~ 9565' Tbg Punch 9580' P~2FORATION SUANNFIRY REF LOG: SWS BHCS ON 02/20/91 ANGLE AT TOP PERF: 32 @ 9607' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 4-1/2" 5 9607 - 9615 isolated proposed 2-1/2" 4 9685 - 9695 isolated proposed 2-1l8" 8 9695 - 9710 isolated proposed 4-1/2" 5 9705 - 9720 isolated proposed ~ 3-1/2" TBG, 9.2#. L-80, .0087 bpf, ID = 2.992" ~--~ 9648~ PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" Q 211~-13-~i2" OTIS SSSV LAND NIP, ID = 2.75" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3116 3050 5 MERLA RA 4 5773 5508 31 MERLA RA 3 7581 7069 25 A~RLA RA 2 8706 8098 24 MERLA RA 1 8799 8183 24 MERLA RA 3-1/2" PARKER SWS NIP, ID = 2.750" ~ 9-5/8" X 3-1/2" HBBP-R PKR ID = 4.00" ~ 9390' Liner Top Pkr 9400' Top of 2-3/8" liner 9400' Top of Cemenl ~ ~45~ 3-1/2" CAMCO SLIDING SLEF/ECB-1, ID = 2.750" / 10950' ~j ~ Mechanical Whipstock 9540' / I 9599' Bu~sr ~oirvr, OD = 2.992° BTnn ss~e~ 9628' Trov ~tnn ~cR HBBP W/ ANCHOR LATCH, ID = 4.00" ~$s' 3-1/2" SWS NIP,ID = 2.750" 9643' 3-1/2" SWS NIP, ID = 2.750" 9~~ 3-1/2" OTIS TBG TAIL W/LEG J649' ELMD TT LOGGm 02/23/91 DATE REV BY COMMENTS DATE REV BY CAMMEMS 02/26/91 ORIGINAL COMPLErION 03l05/01 SIS-MH CONVERTED TO CANVAS 03/10/01 SIS-MD FINAI 09/09/01 RWTP CORRECTIONS 01/03/03 JANKAK PUL XX PLUG 07i 13/03 CMOiTL P tiv'~ h ti~~ ~ ~ PRUDHOE BAY UNff W~L: F-44 PERMff No: 1910080 API No: 50-029-22130-00 SEC 2, T11 N, R13E, 3248' FNL 8 2199' FQ BP Exploration (Alaska) TREE = 4" CNV WELLHEAD= IVkEVOY ACTUATOR = OTIS KB. ELEI/ = 65.66' BF. E1EV - .. 37.98' KOP = 3500' Max Angle = 35 @ 9779' Datum MD = 9486' Datum TVD = 8800' SS • F-44 S NOTES: THE TIW PKRS MAY FAIL IF MORE TH 100 PSI DIFFERENTIAL PRESSURE IS IXCEEDED. 2111~ 3-1/2" OTIS SSSV LAND NIP, ID = 2.75" 13-3/8" CSG, 68#, NT-80, ID = 12.415" 2685~ Minimum ID = 2.750" @ 2111' 3-1i2" OTIS SSSV NIPPLE I TOP OF 7" LNR ~ 8$91 ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 9~ 56' PERFORATION SUMMARY REF LOG: SWS BHCS ON 02/20/91 ANGLE AT TOP PEF2F: 32 @ 9607' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 9607 - 9615 O 02/24/91 2-1/2" 4 9685 - 9695 O 03/24l96 2-1/8" 8 9695 - 9710 O 05(11/91 4-1/2" 5 9705 - 9720 O 02/24/91 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" ~-~ 9648~ PBTD ~ 981 p, 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9852~ ^ GAS LIFf MANDREIS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3116 3050 5 MERLA RA 4 5773 5508 31 MERLA RA 3 7581 7069 25 MERLA RA 2 87Q6 8098 24 MERLA RA 1 8799 8183 24 MERLA RA $$29' 3-1/2" PARKER SWS NIP, ID = 2.750" 8839~ TIW ANCHOR LATCH ASSY 8839~ 9-5/8" X 3-1l2" HBBP-R PKR; ID = 4.00" 9459' ~-{3-1/2"CAMCOSLIDINGSLEEVECB-1,ID=2.750" ~ 9599~ ~~ BLAST JOINT, OD = 2.992" BTM 9618' 9628~ TNV PERM PKR HBBP -- W( ANCHOR LATCH, ID = 4.00" 9636' 3-1l2" SWS NIP, ID = 2.750" 9636' 3-1/2" XX PLUG (Q9/23/05) 9643~ 3-1/2" SWS NIP, ID = 2.750" 9648~ 3-1/2" OTIS TBG TAIL WlLEG 9649~ ELMD TT LOGGED 02/23/91 DATE REV BY COMMENTS DATE REV BY COMMENTS 02/26/91 ORIGINAL COM PLETION 09J09/01 RWTP CORRECTIONS ~1l03(03 JNUKAK PULL XX PLUG 07(13/03 CMO/TLP MAX ANGLE CORRECTION 09/23/05 JAF/TLH XX PLUG SET PRUDHOE BAY UNff WELL: F-44 PERMff No: ~1910080 API No: 50-429-22130-00 SEC 2, T11 N, R13E, 3248' FNL & 2199' FEL SP Ezploration (Alaska) • ~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~ ~ '~ ~€~;r~~ ~eid: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB F Pad TR-11-13 UNITED STATES : North Slope Site Position: Northing: 972527. 9 ft Latitude: 70 19 55.283 N From: Map Easting: ~509 .70 ft Longitude: 148 46 31.468 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.15 deg Well: F-44 Slot Name: 44 F-44 Well Position: +N/-S 1002.57 ft Northing: 5973564.00 ft Latitude: 70 20 5.142 N +E/-W 1710.63 ft Easting : 652650.68 ft~Longitude: 148 45 41.514 W Position Uncertainty: 0.00 ft Wellpath: Plan 5, F-44A Drilled From: F-44 500292213001 Tie-on Depth: 9532.49 ft Current Datum: 47 : 44 2/7/1991 00:00 Height 65.66 ft Above System Datum: Mean Sea Level Magnetic Data: 10/7/2005 Declination: 24:74 deg Field Strength: 57602 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.16 0.00 0.00 200.00 Plan: Plan #5 Date Composed: 10/7/2005 Copy Lamar's Plan 5 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets F-44A Polygon 65.66 -2853.87 -1274 .13 5970685. 00 651435.00 70 19 37. 073 N 148 46 18.707 W -Polygon 1 65.66 -2853.87 -1274 .13 5970685. 00 651435.00 70 19 37. 073 N 148 46 18.707 W -Polygon 2 65.66 -3537.14 -1122 .99 5970005. 00 651600.00 70 19 30. 353 N 148 46 14.292 W -Polygon 3 65.66 -3532.54 -857 .82 5970015. 00 651865.00 70 19 30. 399 N 148 46 6.552 W -Polygon 4 65.66 -3030.57 -947 .63 5970515. 00 651765.00 70 19 35. 336 N 148 46 9.176 W -Polygon 5 65.66 -2929.14 -770 .52 5970620. 00 651940.00 70 19 36. 333 N 148 46 4.006 W -Polygon 6 65.66 -2677.35 -855 .42 5970870. 00 651850.00 70 19 38. 810 N 148 46 6.485 W F-44A Fault 1 65.66 -2330.67 -687 .31 5971220. 00 652011.00 70 19 42 .219 N 148 46 1.579 W -Polygon 1 65.66 -2330.67 -687 .31 5971220. 00 652011.00 70 19 42. 219 N 148 46 1.579 W -Polygon 2 65.66 -2946.11 -1411 .04 5970590. 00 651300.00 70 19 36. 165 N 148 46 22.703 W F-44A Fault 3 65.66 -3695.70 -1294 .27 5969843. 00 651432.00 70 19 28. 794 N 148 46 19.291 W -Polygon 1 65.66 -3695.70 -1294 .27 5969843. 00 651432.00 70 19 28. 794 N 148 46 19.291 W -Polygon 2 65.66 -3564.36 -572 .39 5969989. 00 652151.00 70 19 30. 086 N 148 45 58.221 W -Polygon 3 65.66 -3113.13 -626 .22 5970439. 00 652088.00 70 19 34. 524 N 148 45 59.793 W -Polygon 4 65.66 -2913.31 -320 .07 5970645. 00 652390.00 70 19 36. 489 N 148 45 50.857 W -Polygon 5 65.66 -3113.13 -626 .22 5970439. 00 652088.00 70 19 34. 524 N 148 45 59.793 W -Polygon 6 65.66 -3564.36 -572 .39 5969989. 00 652151.00 70 19 30. 086 N 148 45 58.221 W F-44A Fault 2 65.66 -3152.68 -9386 .24 59703&4. 00 651329.00 70 19 34 .134 N 148 46 21.978 W -Polygon 1 65.66 -3152.68 -1386 .24 5970384. 00 651329.00 70 19 34. 134 N 148 46 21.978 W -Polygon 2 65.66 -3695.70 -1294 .27 5969843. 00 651432.00 70 19 28. 794 N 148 46 19.291 W F-44A Fault 4 65.66 -2913.31 -320 .07 5970645. 00 652390.00 70 19 36. 489 N 148 45 50.857 W -Polygon 1 65.66 -2913.31 -320 .07 5970645. 00 652390.00 70 19 36. 489 N 148 45 50.857 W -Polygon 2 65.66 -2601.62 -398 .75 5970955. 00 652305.00 70 19 39. 555 N 148 45 53.154 W -Polygon 3 65.66 -2330.96 -673 .31 5971220. 00 652025.00 70 19 42. 217 N 148 46 1.170 W . • ~ , ~ Baker Hughes INTEQ ~ . Baker Hughes INTEQ Planning Report ~~;~-~,,~, . a~ - ca~ ~ n ~r BR R~o ~ ~ ~_ . ~ ~, I~ate: '~~ 1E}l7t2~}U5, ~ ~~, `lime: ~~ "!~ 40 A2 ~ag~ Z _ ~ Fielr~ PrUrl~: Bay ~n~urd~ate{1!tT~ lt~ferenee W€~~~ ~~4 ; T"t~~=t+tiitt~t ~it~ PB F~-~d _ Y+ertacat ('k"~ll~~Ref~c~ ~7 44 2Rf~991 ~UAU 6"~~ 1'~?elt , . F-44 ~ C~S)1Z~~er~e~ ;. V1~1! {D bOC~ ~? ~4E;2~0 Q~Azt}- ~ ~S?~llpath: ', Piz~tt ~` ~-44A . :: .. - ' ' ~ ', , S ur~~ y Catculatian MetSo~ ° Mit~mum Gut'vature £13!b ~ ~t~r~cle . ;~: Targets MAp 1l7ag ~ ~ahtud~ ---~ ~ Lon~hide. -~ l~Ta~n~ ' D~ess~~-~i~-~ ~ , ' 1'VD ~l~l-S fEl ~ NarChin~ La~tmg D~g 1#+~iu Sec ,', ~e~ Miirr ~ec .., ^ ~_~ . .. _.~:.. ~ ~`. ~~~ =~~....... . R : . ,..~ _._ __.. ,. : , _-- . . f~_ .._ __ ~ Ft.' ~k _ . . ; ~ „ _ .. -Polygon 4 65.66 -2601.62 -398.75 5970955.00 652305.00 70 19 39.555 N 148 45 53 .154 W F-44A Target 3 9040.66 -3544.28 -1018.11 5970000.00 651705.00 70 19 30.283 N 148 46 11 .231 W F-44A Target 2 9049.66 -2947.93 -1075.99 5970595.00 651635.00 70 19 36.148 N 148 46 12 .923 W F-44A Target 1 9053.66 -2813.35 -808.17 5970735.00 651900.00 70 19 37.472 N 148 46 5 .106 W Annotation , ~`:,~ ~1VI1} -'~~ TVi~ ` ?, ft R . ' ' ' ' _. ... __.._ _. .. 9532.49 8905.87 TIP 9540.00 8912.31 KOP 9560.00 8929.29 End of 9°/100' DLS 9818.37 9053.72 End of 2 7°/100' DLS 9953.37 9053.72 5 10053.37 9053.72 6 10328.37 9050.41 7 10778.37 9042.29 8 10950.00 0.00 TD Plan Section Information __ `~~ Mb ~'~~ _ Ync1 ~.; _ c~im ~ ==~'_~'VB.; ~'~, ~-1~1-5- : _ +~~V . ~= I~L~~ ' B~cil~ = Turn . _ __ _ .; TFQ~~ 't'arg~t __ ~ F ~ ft ~ ~ deg '~ de~ _ : ,-ft :; ~~ . , . ft _e.. ~~~~ _ de~T'ffl(1ft'~,d~g/7Q4~ i~?t~N1C1f~~ d~~ _ ~ ~~ ~. = 9532.49 30.93 201.10 8905.87 -2650.23 -41327 0.00 0. 00 0.00 0.00 9540.00 31.04 200.91 8912.31 -2653.84 -414.66 1.96 1. 46 -2.53 318.27 9560.00 32.74 202.05 8929.29 -2663.67 -418.53 9.00 8. 48 5.69 20.00 9818.37 90.00 252.27 9053.72 -2782.85 -589.46 27.00 22. 16 19.44 55.00 9953.37 90.00 272.52 9053.72 -2800.62 -722.58 15.00 0. 00 15.00 90.00 10053.37 90.00 257.52 9053.72 -2809.27 -821.92 15.00 0. 00 -15.00 270.00 10328.37 91.32 216.29 9050.41 -2956.17 -1047.36 15.00 0. 48 -14.99 272.00 10778.37 90.50 148.79 9042.29 -3380.10 -1066.11 15.00 -0. 18 -15.00 270.00 10950.00 90.45 174.53 9040.83 -3541.64 -1012.56 15.00 -0. 03 15.00 90.00 Survey ' M~ ' Inel:; ,A~m ' ~S';'~'~TI?; . ; Nl~ ~ , . ~.,, ElW '' Mag1~F := 1-~apE . . DLS ' YS TF~', ~'~~ ~' ~ ' ~~~~ ' ~l~,q ~ f~. . ~ . ~t = € ~ ~ ~ ft ~ ~ ~, ft ~ ~ z e _ ~ ~ ~C ~ tiec~l 1D{~ft ft d@ __c~ ~ - m ~ ~ 9532.49 30.93 201.10 8840.21 -2650.23 -413.27 5970906.11 652291.46 0.00 2631.75 0.00 MWD 9540.00 31.04 200.91 8846.65 -2653.84 -414.66 5970902.47 652290.15 1.96 2635.61 318.27 MWD 9550.00 31.89 201.49 8855.18 -2658.70 -416.55 5970897.57 652288.36 9.00 2640.83 20.00 MWD 9560.00 32.74 202.05 8863.63 -2663.67 -418.53 5970892.56 652286.48 9.00 2646.18 19.50 MWD 9575.00 35.20 207.81 8876.08 -2671.25 -422.07 5970884.91 652283.10 27.00 2654.52 55.00 MWD 9600.00 39.81 215.92 8895.92 -2684.12 -430.14 5970871.88 652275.29 27.00 2669.37 50.22 MWD 9625.00 44.89 222.54 8914.39 -2697.12 -440.81 5970858.67 652264.89 27.00 2685.23 43.78 MWD 9650.00 50.28 228.04 8931.26 -2710.06 -453.94 5970845.46 652252.03 27.00 2701.88 38.88 MWD 9675.00 55.90 232.73 8946.27 -2722.78 -469.34 5970832.44 652236.89 27.00 2719.10 35.16 MWD 9700.00 61.67 236.82 8959.23 -2735.08 -486.81 5970819.78 652219.68 27.00 2736.63 32.34 MWD 9725.00 67.55 240.49 8969.94 -2746.80 -506.10 5970807.67 652200.63 27.00 2754.25 30.22 MWD 9739.27 70.95 242.45 8975.00 -2753.18 -517.82 5970801.06 652189.04 27.00 2764.24 28.64 F-44A T 9750.00 73.51 243.86 8978.27 -2757.79 -526.93 5970796.27 652180.02 27.00 2771.69 27.95 MWD 9774.44 79.38 246.96 8984.00 -2767.66 -548.53 5970785.96 652158.64 27.00 2788.36 27.52 F-44A T 9775.00 79.52 247.03 8984.10 -2767.88 -549.04 5970785.73 652158.13 27.00 2788.73 26.79 MWD 9800.00 85.56 250.07 8987.35 -2776.93 -572.10 5970776.21 652135.27 27.00 2805.13 26.78 MWD 9818.37 90.00 252.27 8988.06 -2782.85 -589.46 5970769.94 652118.03 27.00 2816.63 26.38 MWD 9825.00 90.00 253.27 8988.06 -2784.82 -595.80 5970767.84 652111.73 15.00 2820.65 90.00 MWD 9850.00 90.00 257.02 898&.06 -2791.22 -619.96 5970760.94 652087.71 15.00 2834.93 90.00 MWD ~ Baker Hu hes INTE ~ . ~ g Q Baker Hughes INTEQ Planning Report ~~~-~,~ ~~~~~ ~~ ~~,~ ~ ~_. ~ ~~ ~ ~ = t5ntu s ~'f0171~t~ ~'~me: ~~~ i1.4~~~ : ~I*a~ge 3 ~ Fie1d #~tt~+dhc~e Bay , Cz~-~r~iint~te i~~fereqce 1N~11 F-44:TrUe Nat^~'t (~} ; ~~ _... !?'~3 . F Pad °~ ~ _ ti*~al ('1'vA~~ ~eferen~~ 47 44~t,~i ~1 QO.QO f,5 7' ~ ~V~elt F•44 . ; ~Sect3ou {YS; Re€~r~a~e ~Nel~ (fl~~Q~*I fl Q#lE ~(~0 t~(~A~i} , 4~e11 di, P.1 pa : .. : an 5. F-44A • , , Su~y CaLeutat~n lV,~e~hndf 1GITntt~Utri:~turu~tu~e,~. I~-E ~Facie .. Survey MT? ' Iiac1: tiz~ SS', T~- I~TF~ E/4'~l -• ' 1-'Eag~ `. _ Map~ ;1~T~ _', ~'S 'I"E(~ Tao~ : fit ; . . tieg. . . .. ._ ~1e~ fk ~ _._ _._ _m~ _.. ft ', _. __. ' ii `. ft d~~ ~ft',,, __ f~ _..... d~: . _~ 9875 .00 90. 00 260.77 8988.06 2796.04 -644.48 5970755.63 652063.29 15.00 2847.84 90 .00 MWD 9900 .00 90. 00 264.52 8988.06 -2799 .24 -669 .27 5970751.93 652038.57 15.00 2859.33 90 .00 MWD 9925 .00 90. 00 268.27 8988.06 -2800 .81 -694 .22 5970749.85 652013.66 15.00 2869.34 90 .00 MWD 9950 .00 90. 00 272.02 8988.06 -2800 .75 -719 .22 5970749.40 651988.67 15.00 2877.83 90 .00 MWD 9953 .37 90. 00 272.52 8988.06 -2800 .62 -722 .58 5970749.47 651985.31 15.00 2878.85 90 .00 MWD 9975 .00 90. 00 269.28 8988.06 -2800 .28 -744 .21 5970749.37 651963.68 15.00 2885.93 270 .00 MWD 10000 .00 90. 00 265.53 8988.06 -2801 .41 -769 .18 5970747.73 651938.74 15.00 2895.54 270 .00 MWD 10025 .00 90. 00 261.78 8988.06 -2804 .17 -794 .02 5970744.46 651913.96 15.00 2906.63 270 .00 MWD 10050 .00 90. 00 258.03 8988.06 -2808 .55 -818 .63 5970739.58 651889.45 15.00 2919.16 270 .00 MWD 10053 .37 90. 00 257.52 8988.06 -2809 .27 -821 .92 5970738.80 651886.17 15.00 2920.96 270 .00 MWD 10075 .00 90 .11 254.28 8988.04 -2814 .54 -842 .90 5970733.10 651865.30 15.00 2933.09 272 .00 MWD 10100 .00 90 .24 250.53 8987.96 -2822 .09 -866 .72 5970725.06 651841.64 15.00 2948.33 272 .00 MWD 10125 .00 90. 37 246.78 8987.83 -2831 .19 -890.00 5970715.50 651818.55 15.00 2964.85 271 .99 MWD 10150 .00 90. 50 243.04 8987.64 -2841 .79 -912 .64 5970704.44 651796.14 15.00 2982.55 271 .96 MWD 10175 .00 90. 63 239.29 8987.39 -2853 .84 -934 .54 5970691.94 651774.49 15.00 3001.36 271 .94 MWD 10200 .00 90. 75 235.54 8987.09 -2867 .30 -955 .60 5970678.06 651753.71 15.00 3021.22 271 .90 MWD 10225 .00 90. 87 231.79 8986.74 -2882 .11 -975 .73 5970662.84 651733.89 15.00 30A2.02 271 .85 MWD 10250 .00 90. 98 228.04 8986.33 -2898 .20 -994 .85 5970646.37 651715.10 15.00 3063.68 271 .80 MWD 10275 .00 91. 10 224.29 8985.88 -2915 .51 -1012 .88 597062870 651697.43 15.00 3086.11 271 .74 MWD 10300 .00 91. 20 220.55 8985.38 -2933 .96 -1029 .74 5970609.91 651680.95 15.00 3109.21 271 .67 MWD 10325 .00 91 .31 216.80 8984.83 -2953 .47 -1045 .35 5970590.09 651665.73 15.00 3132.88 271 .60 MWD 10328 .37 91 .32 216.29 8984.75 -2956 .17 -1047 .36 5970587.34 651663.79 15.00 3136.11 271 .52 MWD 10350 .00 91 .32 213.04 8984.2fi -2973 .96 -1059 .66 5970569.31 651651.85 15.00 3157.03 270 .00 MWD 10375 .00 91 .31 209.29 8983.68 -2995 .34 -1072 .59 5970547.67 651639.36 15.00 3181.55 269 .93 MWD 10400 .00 91 .30 205.54 8983.12 -3017 .52 -1084 .10 5970525.26 651628.30 15.00 3206.33 269 .84" MWD 10425 .00 91 .28 201.79 8982.55 -3040 .41 -1094 .13 5970502.18 65161874 15.00 3231.26 269 .75 MWD 10450 .00 91 .25 198.04 8982.00 -3063 .90 -1102 .64 5970478.52 651610.71 15.00 3256.25 269 .67 MWD 10475 .00 91 .22 194.29 8981.46 -3087 .91 -1109 .60 5970454.38 651604.24 15.00 3281.19 269 .59 MWD 10500 .00 91 .19 190.54 8980.94 -3112 .31 -1114 .97 5970429.87 651599.37 15.00 3305.96 269 .51 MWD 10525 .00 91. 15 186.79 8980.43 -3137 .02 -1118 .74 5970405.10 651596.11 15.00 3330.46 269 .43 MWD 10550 .00 91. 10 183.04 8979.94 -3161 .92 -1120 .88 5970380.16 651594.47 15.00 3354.59 269 .35 MWD 10575 .00 91. 05 179.29 8979.46 -3186 .90 -1121 .38 5970355.17 651594.48 15.00 3378.24 269 .28 MWD 10600 .00 91 .00 175.54 8979.02 -3211 .87 -1120 .26 5970330.24 651596.11 15.00 3401.32 269 .21 MWD 10625 .00 90 .94 171.79 8978.59 -3236 .71 -1117 .50 5970305.46 651599.37 15.00 3423.72 269 .14 MWD 10650 .00 90 .88 168.04 8978.20 -3261 .31 -1113 .12 5970280.95 651604.25 15.00 3445.34 269 .08 MWD 10675 .00 90 .81 164.29 8977.83 -3285 .58 -1107 .14 5970256.81 651610.72 15.00 3466.10 269 .02 MWD 10700 .00 90 .74 160.54 8977.49 -3309 .41 -1099 .59 5970233.15 651618.76 15.00 3485.91 268 .96 MWD 10725 .00 90 .67 156.79 8977.18 -3332 .69 -1090 .50 5970210.06 651628.32 15.00 3504.67 268 .91 MWD 10750 .00 90 .59 153.04 8976.91 -3355 .32 -1079 .90 5970187.64 651639.37 15.00 3522.32 268 .86 MWD 10775 .00 90 .52 149.29 8976.66 -3377 .22 -1067 .85 5970166.00 651651.87 15.00 3538.77 268 .82 MWD 10778 .37 90 .50 148.79 8976.63 -3380 .10 -1066 .11 5970163.15 651653.66 15.00 3540.89 268 .79 MWD 10800 .00 90 .50 152.03 8976.44 -3398 .91 -1055 .43 5970144.56 651664.72 15.00 3554.91 90 .00 MWD 10825 .00 90 .50 155.78 8976.22 -3421 .36 -1044 .44 5970122.35 651676.17 15.00 357225 90 .03 MWD 10850 .00 90 .50 159.53 8976.01 -3444 .48 -1034 .94 5970099.43 651686.14 15.00 3590.72 90 .06 MWD 10875 .00 90 .49 163.28 8975.79 -3468 .17 -1026 .97 5970075.91 651694.59 15.00 3610.26 90 .09 MWD 10900 .00 90 .48 167.03 8975.58 -3492 .33 -1020 .56 5970051.88 651701.48 15.00 3630.77 90 .13 MWD 10925 .00 90 .47 170.78 8975.37 -3516 .86 -1015 .75 5970027.46 651706.79 95.00 3652.17 90 .16 MWD 10950 .00 90 .45 174.53 8975.17 -3541 .64 -1012 .56 5970002.75 651710.49 15.00 3674.37 90 .19 MWD ~ • ~ Q E g o Cr ~ Q d 'I ~ LL ~ ~ ~ . .l 1 __. q "' 1"""" lq ^ m • ~ .... ic.- ~ - :~`~:.~:'.::~ :'. ~ ~ :' ~ pNp - '~~. 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C'~ t7 Iu!/~300 6l (+)4~+aN/~-)4~~aS - ~ ~~~~~~~~ i 1 } : - t : ' . ~ . ~ ~ ` ~ ~-~ I ' ~ ~~F~^zsc - t F. r-; a o ' . t.p.. .. e ~_--... .. . --- -+- ~ ~''~:p g7 ~ F;~~~es~ : + ; . ~ ~~~A~RiAR ' ~ ~ _ ._ - %_ ~ m a 66R~~R8X{ ____ . ... ~ ~~ ~ ags~~~aae ~ ~ ~~~~a~~~ : _ wg RCi~GGY t, ? ~ ° O $ ~ ~9$ F ° 88888885 - --- ~. .. F ,~ o t: ~ ~ t i: II o$~+ig~ ~ B~t~~~~33 ~~ e~~~ g `::_: W ~ q m ' F ~gm2 S ~- ' ~ ~ s ~ ~~°~'~ 5j4tq~a-q ~ ^ % : g G. ~ ~ ~R S ~ 8 ~ E~~g E ~ ~ ii,$P~a~s ~:::::~: . ... . . w : ~ i ~.-~ . ;~ : _ ~ ~ LLLL.LL -~ ~• ~ w 3 md ~ ~ Ai4M45E=i ~~~~~ii7 Q < ~~ ~ 8 z ~.uu~LL r ~ ~ _~ w s ~ ~B ~ ~~~e€g~~~ ~~ ~.~ ' - ~ m ~ ~ ~:! &II~ ~~~~~ =~3~!!$~~E i~ - ~ ' F . ~ -- ~.:- - -` - i 'liowSS ~ fj : 1 +~ . ~ • '.'. ~' _. : - : : ::.. . : ~- . . . qE~ ~ ~ ~~ ~~$~ 3 ~~~~~c9+' F da33..~.e F _ j Eg~~ RFS1iY~:~2 $ ¢ ~i~ ,~ $g ____-_-_"'_'____'__.___.,_ .. .._.......,...___. ~,-.-.»,-.-.._.~..:"' ~ ~ ~ ;$~&p.aq~$ ~ ~$~'s~~S~E ~i v~ ~ ~ o ~ $ ~ ~ ~i ~ ~ ~~~~SB~eS ~~t 7ElE~II m ao ao m m a~o m ~ m m rn rn 1..,..:::: ~~~~~~~i~ IulMOSI 43daG leali,+aA arul easqng ~ ~ ,.~, C ~~ cgi 0 8 ~~ m . v°, O ~O ~ , °o ~ ~ O " N ~r ~~ N O N ~ M ~ °o y ~ ~ o v ~ ~ S d ~~ 0 N 0 ~ ~ 0 ~ N ~ a N S 0 N O O ~ ~ Nordic 1 slimhole All Measurements are from top of Riser ######## i ~ ~ ~ top of bag BAG 7 1/16" 5000psi of bag Blind/Shears TOTs ~ 2" combi ram/slips 7 1~16" 500opsi ~ ~ Mud Cross Mud Cross of flow cross 7 1/16" 5000psi of blind/shears 2 3~8~~ ram TOTs f 2" combi ram/slips ~ 1/16~~ sooopsi nf nina/slinc _. Flow Tee ~ ~ TRAi~TSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of ' LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as ` I ' tast two (2} digits a function of the original API number stated ( i are between 60-69) above. PILOT IIOLE In accordance with 20 AAC Z5.005(fj, all ~p~ ( records, data and logs acquired for the pilot ~ hole must be clearly differentiated in both name (name on permit plus PI~ and API number (50 - ~ ~ 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full ( EXCEPTION compliance with 20 AAC 25.05~. Approval to ~ ~ ~ perforate and produce/iniect is contingent upon issuance of a conservation order ~ approving a spacing exception. ' (Companv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH Alt dry ditch sample sets submitted to the ~ SAMPLE Commission must be in no greater than 30' ~ ~ sample intervals from below the permafrost I or from where samples are first caught and i i I_ 10' sample intervals through target zones. I Rev: 04/O1/OS C\jody\transm ittai_checklist ~ ~ TERRIE L HUBBLE ss-snzs2 232 ~ , BP EXPLORATION AK INC „ , PO BOX 196612 MB 7-5 Mastercard Check ANCHORAGE, AK 995 i 9-6612 •a~'~~ DATE PAY TO THE ~ I~ • ~' OR R OF $ r W ( 1 $ First National Bank Alaska Anchorage, AK 99501 MEMO C ~_-L~ ~ , ~:i25200060~:99Lti~~~6227~~~L556~~' D232 : Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT F-44A Program DEV _ Well bore seg ^ PTD#:2051610 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-OIL GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mitfeeattached_______________________ _______________ ______Yes_ _____ - - 2 Leasenumberappropriate_________________________________ ______Yes_ ____.____..__ 3 Uniquew@II_nameandnumber-- -- - ------ --- - - --- - Yes ------------------- -- - --------- - 4 Welllocatedinade_fined_pooi.--.--_--_--------------------- ------Yes- _---__--.-,-.------, , 5 Well located properdistance.from drilling unit_bounda_ry_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ - - - 6 Welllocatedproperdistancefromotherwelis,_____________________ _ ____Yes_ ______._ - I 7 Su~cientacreageayail_ablein_dril_lingunit___..____________________ ______Yes. __________________ - ~I 8 If_deviated,is_wellboreplat_inc_luded_____.______________________ __ ___Yes_ _______._ -- ~I 9 Operatoronlyaffectedpady-----------------. -,---Yes- ------------------- - '~ 10 Operatothas_appropnate.bondinforce----------- - ----- --- - ---Yes- ------ ---- -- -- --------- --- ---------- -~ ----~- - -- 11 Permit can be issued without conservation order Yes -- - Appr Date ~ 2 Pe(mit_can be issued without administrative_appr_oya_I _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ -- - RPC 10/3112005 13 Can permit be approved before 15-day wait Yes 14 WelllocatedwithinarQaandstrataauthorizedby_InjectionOrder#(put10#in_comments)(For_ NA__ ___________________.,.._____.________________________,___.___._ 15 All wells.within 114_mile area of reyiew identified (For seNice well oniy) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ - -- --~ - - - - -------- -- ---------- -- -- ------- - -- 16 Pre-produced injector_ duration_of preproduction I_ess than 3 months_ (For service well only) _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 ACMP_Finding of Consistency_h_as been issued_fo[this project . . . . . . . . . . . . . . . . . . . . NA_ _ _ . _ _ _ _ _ _ _ _ Engineering ' 18 Condu_ct_orstcin_rqvided___ 9P - - NA_ __________________________________ -- - 19 Surface casing_protects aII known USDW& _ - - - NA - - - - - - - - - - 20 CMT_vol adequate_to circulate_on conductor_& surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ . . _ _ . _ . _ _ - - - -- 21 CMT_vol_adegu_ate_totie-inlongstringtosu_rfcsg______________________ ______ NA_. .___________________ 22 _C_MT_wilicoyerallknow_n_productiyehonzons_______________________ ___.._Yes_ ______Adequateexcess,_______________ - 23 Casing design~ adequate for C, T, B &_ permafrost. _ _ _ _ . . _ _ Yes _ _ _ _ _ _ _ _ _ _ _ . 24 Adequateiankage.orreservepit____________ _______ _________ ___.__Yes_ _,____CTDU.____________ 1 25 Ifa_re-d[ill,has_ai_0-403forabandonmentbeenapproved_______________ „___Yes_ ______'._____________ .__.__._..____,__._.__._,.__ 26 Adequatewellboreseparationproposed__...____________________ ______Yes. ___________._ ----- -- --------~---- --- -- - --... ~-- ------ - - 27 If_dive[terrequired,doesitmeetregulations_________________________ __,__ NA__ _..__Sidetrack._________,_._ Appr Date 28 Drillingfluid,programschQm~tic.&equiplistadequate___________________ __ __Yes_ ______MaxMW8.6ppg,..__.__._ .___._.______._.____________________________ WGA 10l31/2005 29 BOPEs,_dotheymeetregulation---------------------------- ----Yes- ---------------------------------------------------------------------- 30 _B_OPE_press raSing appropriate; test io_(put psig in comments)_ _ . _ _ _ . _ _ _ _ _ _ _ . , _ _ Yes _ _ _ _ _ _ _ Test to 3500 psi. _MSP 22_80 psi._ _ _ _ _ . _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 Choke_manifoldcompliesw/APl_RP-53GMay84)____________________ Yes_ _____._._.___ - - -- 32 Workwilloccu[withgutoperationshutdown______.___ Yes_ __________________,_,._______ ,33 IspresenceofH2Sgas_probable______________________________ ______ Yes_ ____..100_ppm,______._,___„__ 34 Mechanical condition of wells within AOR yenfed ~For_seruice well only~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ . . _ _ _ _ _ , _ _ . . - -- Geology 35 Permit_canbeissuedwlohydrogen_sulfidemeasu[es___________________ ______ No__ __________._______„_._ - 36 Data_presentedonpotentialoverpressurezones____________________. ______ NA__ ___________.__.___,. _,___.__________._ - Appr Date 37 Seismic analysis_of shallow gas_zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - - - - - RPC 10131I2005 38 Seabed condition survey_(if off-sho[e) _ _ _ _ _ _ _ _ . NA 39 , Contact namelphone_for weekly progress.repo[ts [exploratory only~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ Geologic Engineering ic Commissioner: Date: Commissioner: Date o mi r Date l/~'"/~~if/~/ / V'~ lO ~~lf D~ ~O V/ r O.~J ~ ~ ~ • Well I-iistory File APPE~IDIX Information of detailed nature that is not pa~ticula~iy germane to the Weli Permitting Process but is part of the history file. To improve the readability of the Weti History file and to sim.plify fiinding information, information of this nature is accumulaled at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. ~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jul 13 09:14:22 2007 Ree2 Header Service name ............. LISTPE Date ..................... 07/07/13 Origin ...............'.... STS Reel Name ................ UNKNOWN Continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Writing Library Tape Header Service name ............. LISTPE Date ..................... 07/07/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MWD RUN 2 JOB NUMBER: W-0005042662 LOGGING ENGINEER: M. BUCKLEY OPERATOR WITNESS: B. DECKER MWD RUN 5 JOB NUMBER: W-0005042662 LOGGING ENGINEER: S. POLAK OPERATOR WITNESS: B. DECKER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD i Scientific Technical Services Scientific Technical Services F-44A 500292213001 BP Exploration (Alaska) Inc. Sperry Drilling Services 13-JUL-07 MWD RUN 3 MWD RUN 4 W-0005042662 W-0005042662 M. BUCKLEY S. POLAK B. DECKER B. DECKER MAD RUN 6 W-0005042662 S. POLAK B. DECKER 2 11 13 2030 2199 63.20 34.70 OPEN FiOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8616.0 2ND STRING 6.125 7.000 9172.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE aOS /(~/ '°~ 15-35~ ~ ~ NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL EXITS THE F-44 WELLBORE BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 8616'MD/8018'TVD. 4. MWD RUN 1 WAS WHAT WAS INITIALLY THOUGHT TO HAVE BEEN A FAILED ATTEMPT TO SET THE WHIPSTOCK. AFTER POOH, HOWEVER, IT WAS FOUND THAT THE WHIPSTOCK HAD INDEED BEEN SET. THE WINDOW WAS MILLED AND ABOUT 20' OF NEW HOLE WERE DRILLED ON A SUBSEQUENT RUN WITHOUT MWD TOOLS IN THE BHA. NO MWD DATA WERE ACQUIRED FOR RUN 1. 5. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 3-5 ALSO INCLUDED AT-BIT INCLINATION (ABI). UPHOLE MAD SGRC DATA WERE MERGED WITH RUN 2 MWD SGRC DATA. 6. MWD RUN 6 WAS A MAD PASS FROM TD TO ABOUT 9330'MD/8703'TVD. IT COMPRISED DIRECTIONAL, DGR, EWR4, COMPENSATED THERMAL NEUTRON (CTN), AND AZIMUTHAL LITHO-DENSITY (ALD). THESE MAD DATA ARE INCLUDED AS A SEPARATE PRESENTATION. 7. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D.DORTCH DATED 1 JLTNE 2007, QUOTING AUTHORIZATION FROM ROGER SELS (BP GEOSCIENTIST). MAD DATA WERE CORRECTED (SHIFTED) TO THE MWD DATA. 8. MWD RUNS 2-6 REPRESENT WELL F-44A WITH API#: 50-029-22130-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10722'MD/9041'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL RUNNING SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. AN 'M' SUFFIX ON CURVE NII~TEMONICS DENOTES MAD PASS DATA. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.125" BIT ~ MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/13 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER ~ 8.4 - 8.5 PPG 3700 - 4700 PPM CHLORIDES 11500 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8309.0 10657.0 RPS 8599.0 10664.5 RPX 8599.0 10664.5 RPD 8599.0 10664.5 RPM 8599.0 10664.5 FET 8599.0 10664.5 ROP 8644.5 10722.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9302.0 9299.5 9315.5 9312.5 9325.5 9323.0 9344.0 9340.5 9358.5 9356.5 9361.5 9359.0 9391.0 9388.0 9403.5 9400.0 9408.0 9404.0 9416.5 9413.5 9430.5 9427.5 9464.0 9460.0 9494.5 9491.0 9521.0 9517.0 9531.0 9529.5 9539.5 9535.0 9542.5 9538.5 9551.0 9547.5 9564.0 9562.0 9573.0 9569.0 9575.5 9571.5 9579.5 9575.0 9586.0 9579.0 9596.5 9588.5 9602.5 9594.0 9612.5 9604.5 9640.5 9633.5 9667.5 9661.0 9680.0 9674.0 9683.5 9678.0 9700.5 9694.5 9707.0 9702.0 9713.0 9709.0 9724.5 9718.5 9734.0 9729.0 9748.0 9744.0 9789.0 9782.0 9799.5 9792.5 • 9810.5 9804.5 9832.5 9826.0 9847.5 9843.0 9873.0 9868.5 9909.0 9904.5 9934.0 9930.0 9942.5 9938.0 10015.0 10004.5 10026.5 10017.0 10035.0 10023.5 10059.5 10048.5 10072.0 10061.0 10076.5 10065.0 10097.5 10086.5 10128.0 10118.5 10147.5 10139.5 10154.0 10145.0 10167.0 10158.5 10175.5 10167.5 10189.5 10179.5 10194.5 10184.0 10202.0 10192.0 10209.0 10199.0 10228.5 10218.5 10234.0 10224.0 10257.0 10247.5 10265.5 10256.0 10270.0 10260.5 10276.0 10269.5 10293.5 10284.5 10303.5 10297.0 10318.0 10312.0 10333.5 10327.0 10340.0 10334.0 10344.0 10337.5 10366.5 10359.5 10382.0 10376.5 10391.5 10385.5 10400.5 10395.0 10410.0 10404.5 10423.5 10417.0 10431.0 10425.5 10455.0 10449.5 10472.0 10467.0 10490.0 10485.5 10502.5 10498.0 10505.5 10499.0 10507.5 10500.5 10508.5 10502.0 10541.5 10537.0 10549.5 10545.5 10562.0 10557.0 10572.0 10568.0 10587.5 10584.5 10591.5 10587.5 10593.0 10589.0 10594.5 10590.0 10619.0 10614.5 10635.0 10632.5 10637.5 10634.0 10640.5 10637.0 10642.0 10639.5 10647.0 10644.5 10650.5 10647.5 10654.5 10651.5 10656.0 10653.0 10658.5 10655.5 10663.5 10661.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 8309.0 9172.0 MWD 3 9172.0 9192.0 MWD 4 9192.0 9713.0 MWD 5 9713.0 10722.0 ~ ~ S # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel ~ DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8309 10722 9515.5 4827 8309 10722 RPD MWD OHMM 0.54 2000 50.4009 4132 8599 10664.5 RPM MWD OHMM 0.76 1985.28 20.5944 4132 8599 10664.5 RPS MWD OHMM 0.7 2000 11.2209 4132 8599 10664.5 RPX MWD OHMM 0.44 2000 9.25845 4132 8599 10664.5 FET MWD HOUR 0.34 71.85 4.83922 4132 8599 10664.5 GR MWD API 11.9 540.12 59.8904 4697 8309 10657 ROP MWD FT/H 0.97 194.45 45.7183 4156 8644.5 10722 First Reading For Entire File..........8309 Last Reading For Entire File...........10722 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/13 Maxi[num Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .......... ...STSLIB.002 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/07/13 Maximum Physical Record..65535 File Type ............. ...LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH • NPHI 9267.0 10667.0 NCNT 9267.0 10667.0 FCNT 9267.0 10667.0 RHOB 9291.5 10692.5 PEF 9291.5 10692.5 DRHO 9291.5 10692.5 GR 9294.0 10694.0 RPS 9301.0 10701.5 FET 9301.0 10701.5 RPD 9301.0 10701.5 RPM 9301.0 10701.5 RPX 9301.0 10701.5 RAT 9323.5 10722.0 $ # MERGED DATA SOURCE ~ PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MWD 6 1 9267.0 10722.0 $ # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CNTS 4 1 68 4 2 NCNT MAD CNTS 4 1 68 8 3 RHOB MAD G/CM 4 1 68 12 4 DRHO MAD G/CM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HOUR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD BARN 4 1 68 44 12 RAT MAD FT/H 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 9267 10722 9994.5 2911 9267 10722 FCNT MAD CNTS 260.33 2943.59 612.219 2801 9267 10667 NCNT MAD CNTS 18231.3 45512.5 26933.7 2801 9267 10667 RHOB MAD G/CM 2.094 3.347 2.36195 2803 9291.5 10692.5 DRHO MAD G/CM -0.448 0.745 0.0723767 2803 9291.5 10692.5 RPD MAD OHMM 0.44 2000 21.9585 2802 9301 10701.5 RPM MAD OHMM 1.1 830.24 17.9449 2802 9301 10701.5 RPS MAD OHMM 0.8 2000 16.0679 2802 9301 10701.5 RPX MAD OHMM 0.62 2000 13.3372 2802 9301 10701.5 FET MAD HOUR 19.56 119.42 64.3384 2802 9301 10701.5 GR MAD API 8.4 472.13 36.2176 2801 9294 10694 PEF MAD BARN 1.01 9.31 2.24817 2803 9291.5 10692.5 RAT MAD FT/H 1.59 2161.11 424.719 2798 9323.5 10722 NPHI MAD PU-S 5.47 38.78 23.6859 2801 9267 10667 First Reading For Entire File..........9267 Last Reading For Entire File...........10722 File Trailer . ~ Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Next File Name......... STSLIB.002 1.0.0 07/07/13 65535 LO STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.....,.07/07/13 Maximum Physical Record..65535 File Type ................LO Previous File Name.....,.STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8309.0 9106.5 FET 8599.0 9127.0 RPX 8599.0 9127.0 RPM 8599.0 9127.0 RPS 8599.0 9127.0 RPD 8599.0 9127.0 ROP 8644.5 9172.0 $ # LOG HEADER DATA DATE LOGGED: 20-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9172.0 TOP LOG INTERVAL (FT}: 8644.0 BOTTOM LOG INTERVAL (FT): 9172.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23.1 MAXIMUM ANGLE: 31.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 230207 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTI-I (FT): 8616.0 # BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.35 MUD VISCOSITY (5): 56.0 MUD PH: 8.7 MUD CHLORIDES (PPM): 7000 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .580 73.0 MUD AT MAX CIRCULATING TERMPERATURE: .360 122.0 MUD FILTRATE AT MT: .550 73.0 MUD CAKE AT MT: .610 73.0 ~ # # # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .Down Optical log depth units.......... .Feet Data Reference Point ............. .Undefined Frame Spacing .................... .60 .lIN Max frames per record ............ .Undefined Absent value ..................... .-999 Depth Units ...................... . Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel ~ DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MLVD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8309 9172 8740.5 1727 8309 9172 RPD MWD020 OHMM 0.54 2000 35.5453 1057 8599 9127 RPM MWD020 OHMM 0.76 1850.38 7.04964 1057 8599 9127 RPS MWD020 OHMM 0.73 1734.55 4.05696 1057 8599 9127 RPX MWD020 OHMM 0.44 1727.01 4.46832 1057 8599 9127 FET MWD020 HOUR 0.34 2.58 1.13104 1057 8599 9127 GR MWD020 API 48.81 155.29 100.004 1596 8309 9106.5 ROP MWD020 FT/H 1.18 145.22 70.5405 1056 8644.5 9172 First Reading For Entire File..........8309 Last Reading For Entire File...........9172 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name ............ .STSLIB.004 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07/07/13 Maximum Physical Record. .65535 File Type ................LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER • ~ FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9107.0 9126.5 RPX 9127.5 9133.5 RPD 9127.5 9133.5 RPS 9127.5 9133.5 FET 9127.5 9133.5 RPM 9127.5 9133.5 ROP 9172.5 9192.0 $ # LOG HEADER DATA DATE LOGGED: 23-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9192.0 TOP LOG INTERVAL (FT): 9172.0 BOTTOM LOG INTERVAL (FT): 9192.0 HIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 23.1 MAXIMUM ANGLE: 31.9 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 90518 ABI AT-BIT INCLINATION 150573 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9172.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .Down Optical log depth units.......... .Feet Data Reference Point ............ ..Undefined Frame Spacing ................... ..60 .lIN Max frames per record ........... ..Undefined Absent value .................... ..-999 Depth Units ..................... .. Fresh Water Gel 10.40 56.0 9.2 7000 6.0 580 73.0 440 99.0 550 73.0 610 73.0 • • Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9107 9192 9149.5 171 9107 9192 RPD NiWD030 OHMM 134.97 2000 1069.72 13 9127.5 9133.5 RPM MWD030 OHMM 2.48 1069.6 198.066 13 9127.5 9133.5 RPS MWD030 OHMM 2.62 4.24 2.98077 13 9127.5 9133.5 RPX MWD030 OHMM 1.99 2.55 2.19 13 9127.5 9133.5 FET MWD030 HOUR 54.29 54.66 54.3754 13 9127.5 9133.5 GR MWD030 API 74.22 89.86 82.211 40 9107 9126.5 ROP MWD030 FT/H 5.03 56.66 39.8142 40 9172.5 9192 First Reading For Entire File..........9107 Last Reading For Entire File...........9192 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/13 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9127.0 9649.5 RPS 9134.0 9655.5 RPX 9134.0 9655.5 RPM 9134.0 9655.5 RPD 9134.0 9655.5 FET 9134.0 9655.5 ROP 9192.5 9713.0 $ # LOG HEADER DATA DATE LOGGED: 24-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 , • ~ DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9713.0 TOP LOG INTERVAL (FT): 9192.0 BOTTOM LOG INTERVAL (FT): 9713.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 33.0 MAXIMUM ANGLE: 46.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 90518 ABI AT-BIT INCLINATION 10815495 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 9172.0 # # # # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Fresh water Gel 8.40 50.0 9.7 5700 6.0 580 73.0 400 111.0 550 73.0 610 73.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9127 9713 9420 1173 9127 9713 RPD MWD040 OHMM 1.05 2000 115.902 1044 9134 9655.5 RPM MWD040 OHMM 0.94 1985.28 40.4837 1044 9134 9655.5 RPS MWD040 OHMM 0.7 527.41 10.1064 1044 9134 9655.5 RPX MWD040 OHMM 0.66 462.69 7.50349 1044 9134 9655.5 FET MWD040 HOUR 1.01 71.85 8.41225 1044 9134 9655.5 • ~ GR MWD040 API 12.38 540.12 62.1055 1046 9127 ROP MWD040 FT/H 0.97 155.2 39.0488 1042 9192.5 First Reading For Entire File..........9127 Last Reading For Entire File...........9713 File Trailer Service name ........... ..STSLIB.005 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/07/13 Maximum Physical Record..65535 File Type .............. ..LO Next File Name......... ..STSLIB.006 Physical EOF File Header Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Previous File Name..... .STSLIB.006 .1.0.0 .07/07/13 .65535 .LO .STSLIB.005 Comment Record FZLE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9650.0 10657.0 RPD 9656.0 10664.5 RPS 9656.0 10664.5 RPM 9656.0 10664.5 RPX 9656.0 10664.5 FET 9656.0 10664.5 ROP 9713.5 10722.0 $ # LOG HEADER DATA DATE LOGGED: 25-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10722.0 TOP LOG INTERVAL (FT): 9713.0 BOTTOM LOG INTERVAL (FT): 10722.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 46.5 MAXIMUM ANGLE: 96.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232602 EWR4 Electromag Resis. 4 228502 ABI AT-BIT INCLINATION 150573 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9172.0 # 9649.5 9713 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel ~ • ~ MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 52.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): 6.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .490 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 5.700 120.2 MUD FILTRATE AT MT: .450 72.0 MUD CAKE AT MT: .480 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9650 10722 10186 2145 9650 10722 RPD MWDO50 OHMM 2.14 1139.65 17.7291 2018 9656 10664.5 RPM MWDO50 OHMM 1.54 995.58 16.256 2018 9656 10664.5 RPS MWDO50 OHMM 1.63 2000 15.6029 2018 9656 10664.5 RPX MWDO50 OHMM 0.93 2000 12.7209 2018 9656 10664.5 FET MWDO50 HOUR 1.47 35.52 4.61391 2018 9656 10664.5 GR MWDO50 API 11.9 112.59 26.5248 2015 9650 10657 ROP MWDO50 FT/H 1.34 194.45 36.29 2018 9713.5 10722 First Reading For Entire File..........9650 Last Reading For Entire File...........10722 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/13 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header ~ ~ Service name .............STSLIB.007 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/07/13 Maximum Physical Record..65535 File Typ e ............. ...LO Previous File Name.... ...STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: 1 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9267.0 10667.0 FCNT 9267.0 10667.0 NPHI 9267.0 10667.0 DRHO 9291.5 10692.5 PEF 9291.5 10692.5 RHOB 9291.5 10692.5 GR 9294.0 10694.0 FET 9301.0 10701.5 RPD 9301.0 10701.5 RPX 9301.0 10701.5 RPS 9301.0 10701.5 RPM 9301.0 10701.5 RAT 9323.5 10722.0 $ # LOG HEADER DATA DATE LOGGED: 28-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10722.0 TOP LOG INTERVAL (FT): 9330.0 BOTTOM LOG INTERVAL (FT): 10722.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 CTN COMP THERMAL NEUTRON 231708 EWR4 Electromag Resis. 4 228502 ALD Azimuthal Litho-Dens 179170 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9172.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: Fresh Water Gel 8.40 50.0 9.3 5000 6.0 .450 69.0 5.600 118.0 .490 69.0 .480 69.0 ,, # # ~ HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .Down Optical log depth units.......... .Feet Data Reference Point ............. .Undefined Frame Spacing .................... .60 .lIN Max frames per record ............ .Undefined Absent value ..................... .-999 Depth Units ...................... . Datum Specification Block sub-typ e...0 Name Service Order Units Size Nsam Rep Code Offset Channel ~ DEPT FT 4 1 68 0 1 FCNT MAD061 CNTS 4 1 68 4 2 NCNT MAD061 CNTS 4 1 68 8 3 RHOB MAD061 G/CM 4 1 68 12 4 DRHO MAD061 G/CM 4 1 68 16 5 RPD MAD061 OHMM 4 1 68 20 6 RPM MAD061 OHMM 4 1 68 24 7 RPS MAD061 OHMM 4 1 68 28 8 RPX MAD061 OHMM 4 1 68 32 9 FET MAD061 HOUR 4 1 68 36 10 GR MAD061 API 4 1 68 40 11 PEF MAD061 BARN 4 1 68 44 12 RAT MAD061 FT/H 4 1 68 48 13 NPHI MAD061 PU-S 4 1 68 52 14 Fir5t Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9267 10722 9994.5 2911 9267 10722 FCNT MAD061 CNTS 260.33 2943.59 612.219 2801 9267 10667 NCNT MAD061 CNTS 18231.3 45512.5 26933.7 2801 9267 10667 RHOB MAD061 G/CM 2.094 3.347 2.36195 2803 9291.5 10692.5 DRHO MAD061 G/CM -0.448 0.745 0.0723767 2803 9291.5 10692.5 RPD MAD061 OHMM 0.44 2000 21.9585 2802 9301 10701.5 RPM MAD061 OHMM 1.1 830.24 17.9449 2802 9301 10701.5 RPS MAD061 OHMM 0.8 2000 16.0679 2802 9301 10701.5 RPX MAD061 OHMM 0.62 2000 13.3372 2802 9301 10701.5 FET MAD061 HOUR 19.56 119.42 64.3384 2802 9301 10701.5 GR MAD061 API 8.4 472.13 36.2176 2801 9294 10694 PEF MAD061 BARN 1.01 9.31 2.24817 2803 9291.5 10692.5 RAT MAD061 FT/H 1.59 2161.11 424.719 2798 9323.5 10722 NPHI MAD061 PU-S 5.47 38.78 23.6859 2801 9267 10667 First Reading For Entire File..........9267 Last Reading For Entire File...........10722 File Trailer Service name .......... ...STSLIB.007 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/07/13 Maximum Physical Recor d..65535 File Type ............. ...LO Next File Name........ ...STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/07/13 ~ i Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/07/13 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
