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202-142
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, November 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-104 PRUDHOE BAY UN BORE V-104 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/25/2025 V-104 50-029-23103-00-00 202-142-0 W SPT 6421 2021420 1605 1309 1309 1311 1311 460 465 465 464 4YRTST P Kam StJohn 10/7/2025 4 Year MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE V-104 Inspection Date: Tubing OA Packer Depth 258 2051 1980 1972IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS251007132559 BBL Pumped:2.4 BBL Returned:2.3 Tuesday, November 25, 2025 Page 1 of 1 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse 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 02/09/2024. Dear Mr. Rixse, 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 02/09/2024. 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 DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # 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 date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #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 date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-104 202142 500292310300 5 1/1/2024 MEMORANDUM TO: Jim ReggC� Ij��1(Z+11'f P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 9, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC V-104 PRUDHOE BAY UN BORE V-104 Src: Inspector Reviewed By: P.I. Supry J� Comm Well Name PRUDHOE BAY UN BORE V-104 'API Well Number 50-029-23103-00-00 Inspector Name: Bob Noble Permit Number: 202-142-0 Inspection Date: 10/3/2021 Insp Num: mitRCN2I1004095537 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-104 Type Inj W, TVD 6421-�� Tubing 1479 1480 1481 - 1482 — PTD 2021420 Type Test SPT�Test psi 1605 IA 899 2203 2142 2141 BBL Pumped: 3 3 BBL Returned: 2.3 OA 429 431 432 431 Interval 4YRTST p/F P J Notes: Tuesday, November 9, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor � Cq1Z�Z{rG FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 6, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC V-104 PRUDHOE BAY UN BORE V-104 Sre: Inspector Reviewed By: P.I. Supry I>F— Comm Well Name PRUDHOE BAY UN BORE V-104 API Well Number 50-029-23103-00-00 Inspector Name: Bob Noble Permit Number: 202-142-0 Inspection Date: 10/3/2021 Insp Num: mitRCN211004095537 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-104 - Type Inj w TVD 6421 Tubing 1479 1480, 1481, 1482 - PTD 2021420 - Type Test SPT Test psi 1605 IA 899 2203 - 2142 2141- BBL Pumped: 3.3 3.3 BBL Returned: 2.3 QA 429 _ 431 - 452 432 ' Interval ! 4YRTST P/F P Notes: Wednesday, October 6, 2021 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,October 16,2017 P.I.Supervisort01(/ i Z((7 SUBJECT: Mechanical Integrity Tests D BP EXPLORATION(ALASKA)INC. V-104 FROM: Brian Bixby PRUDHOE BAY UN BORE V-104 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-104API Well Number 50-029-23103-00-00 Inspector Name: Brian Bixby Permit Number: 202-142-0 Inspection Date: 10/15/2017 Insp Num: mitBDB171015165336 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I V-104 Type Inj W TVD 6421 Tubing 1411 1428 - 1424' 1407 PTD 2021420 (Type Test SPT Test psi 1605 IA 470 2484 2444 2440 - BBL Pumped: 1.7 BBL Returned: 1.7 OA 291 ' 295 296 296 - Interval 4YRTST P/F P ✓ Notes: SCANNED ; t Monday,October 16,2017 Page 1 of 1 RECEIVED STATE OF ALASKA l AA OIL AND GAS CONSERVATION COMMON Gc( , i 7:01:1 REPORT OF SUNDRY WELL OPERATIONS St( 1.Operations Abandon U Repair Well U Plug Perforations L1 Perforate [✓] Othe "'°' °" Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weli❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Developments Exploratory ❑ 202-142-0 3.Address: P.O.Box 196612 Stratigraphic Service el 6.API Number: Anchorage,AK 99519-6612 50-029-23103-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028240 BRLS V-104 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: Total Depth measured 8455 feet Plugs measured None feet true vertical 7090.13 feet Junk measured None feet Effective Depth measured 8363 feet Packer measured 7688 feet true vertical 7008.18 feet true vertical 6421.24 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 2956 9-5/8"40#L-80 29-2985 29-2700.05 5750 3090 Intermediate None None None None None None Production 8419 7"26#L-80 26-8445 26-7081.22 7240 5410 Liner None None None None None None Perforation depth Measured depth 7879-7880 feet 7880-7910 feet 7910-7929 feet 7936-7942 feet 7952-7956 feet 8038-8068 feet True Vertical depth 6585.61 -6586.49 feet 6586.49-6612.63 feet 6612.63-6629.2 feet 6635.31 -6640.54 feet 6649.25-6652.74 feet 6723.93-6749.92 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 24-7745 24-6469.62 Packers and SSSV(type,measured and true vertical depth)4-1/2"Baker S-3 Hydro Set Packe 7688 6421.24 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED NOV 2 6 2013 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: 0 0 3270 0 1608 Subsequent to operation: 0 0 4012 0 1576 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPL[] GSTOR ❑ WINJ ❑ WAG Ill 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 GarrvCatron(a.BP.Com Printed Name Garry Catron Title PDC PE Signature 140 (tip Phone 564-4424 Date 10/29/2013 1/7// -7 RBDMS NOV - 4 Iz/t , / t3 Form 10-404 Revised 10/2012 //I (1,7/ 3 Submit Original Only , , • 0 cn ,_ _ x II C M J 2 N _O L O r ., Q o) 6) Oi 0 p c E N ' 0 Q Q = U N L 00 C C (i) o) to = 2 l!') C * O - •L E E O U) a X N Q Q N a) co _ M Q to 0 r CA - O U) o)- O O U O E E �c) w' .0 M x , r " O E .0 E _, E CV O - 7 0 L O Q U N r r U L .Q * U)E to = � j 0 U o O - 2 O U O i x c p) it C a. CV cc C ao O E n D E O X o u) U) U)_ O : r N o) (a CO ix 1— co E E O C o2wZ -o O Cx 0 0 N N co C ca 0 0 Z Q H a) n (Dino n CD CD ° <n ° r Q . aL) O ^ CO CO 2 ° c 2 O cu 0 o - -6 -o° G1 . rn W a C m H a) a) U) Z co .c ca a) * O p - J v - Q U w C N - \ N N m N to U) a- I� U) r N IV co .9E. r in .t G1 Cs1 � - U --� �sow * N N 11 g -0 D02 as N Ur ,' prom. (7) Et ° °c = � OF U) xO CD- 0 N U) _j1� Cc . C c 0 I J J Q +: N U) +% N ..., C 6 M m •O r a W t 0 Q O M r C- ~ CO ~ Q� 'o Q� 73 U O m 2 43 N a) Q C 0. a > 2 r ---Cr) N C\1= '� N w a_ 0 E O .L � O a' r ' � � 2 , � 0) � W C) � � U � � UU) N _0d X XO .Od A O OAF- J �`~ Z C •�O a) t) CM - • Oms- Lo - _ Z Oa' vW O O � C O � C O � prLN (77 - .cu O � � � w ~ � w0 O° O 3 ° U (ONia m x c >zO >D >� � UZO = Z _ m ° = - c° ° = mrno 0 - -jO -a CNI > - > > 0 N m O O U _O o o0 OO O o0 •.E 8 O O Oa O nj CO 000 w w u_ M co I- E N O 'n E �' O tf) E 2 - N "6 O (La � O u_ MZZX 00OZ - 0 • ° � U r vD 0 a) SS Q J � HI— UaW - Z J — O) 3 ' -- U) 3 ' � cA a) c0 ° � 0 J Z Z 2 W H Q a J 3 2 O 3 = O M ti _ _ - _° O -,u_ -J u_ o_� � o� o � oho rn o c °- E 3 `o - * x * * D x o < v * 0 0 - �l 0 U - O U 00. 2 O CO O O * * O * * a. C J H V * O U) 2 ©O U) 2 V O U) O N -0 X CO ; (Y) co co co co r r r r r O O O O O N N N N N O r CO CO l'-- c0 M r r r a CO 0) 0) 0) _ Daily Report of Well Operations ADL0028240 ***WELL SHUT IN UPON ARRIVAL*** (ELINE - PERF/INJECTION PROFILE) INITIAL T/I/O = 500/450/350 PERF GUN RUN # 1 -SHOT INTERVAL @ 7880' -7910'W/30' X 2-78" POWER JET NOVA CHARGES PUT WELL ON INTECTION FOR 4 HOURS (RATES @ 4000 BWPD - 1460 WHP- 133 DEGF) PERF GUN RUN #2 - SHOT INTERVAL @ 8038' -8068' W/30'X 2-78" POWER JET NOVA CHARGES RAN (PROF @ 40, 80, 120 FPM OVER THE INTERVAL 8100'-7840 & STOP COUNTS AT 8072', • 8035', 7947', 7933', 7870' (RATE @ 4000 BWPD - 1460 WHP- 155 DEGF) ZONE SPLITS: 7879-7929 = 100%, 7936-7942 = 0%, 7952-7956 = 0% 8038-8068 = 0%. FINAL T/I/O = 1480/500/350 WELL INJECTING UPON DEPARTURE - NOTIFIED DSO OF WELL STATUS 10/1/2013 ***JOB COMPLETE*** T/I/0=2368/760/397 Temp=INJ Pre state AOGCC MIT-IA to 4000 psi ***PASS*** (ANN-COMM) Pumped 3.5 bbls of meth down IA for MIT-IA to 4000 psi. 15 min IA lost 53 psi. 30 mins IA lost 10 psi. Total test IA lost 63 psi. Bled back—3 bbls of meth. DSO notified of well staus per LRS departure. FWHP's=2381/500/407 SV=C WV,SSV,MV=O IA/OA=OTG ****NO INTERGAL 10/13/2013 _FLANGE ON IA. LRS left intergal flange on well for State Witnessed AOGCC MIT-IA*** T/I/O = 1571/745/379. Temp = 132°. AOGCC MITIA to 2500 psi PASSED (Reg Compliance). On Inj. AOGCC witnessed by Jeff Jones. Used 1.65 bbls of neat methanol to pressure IA from 745 to :2498 psi. IAP decreased 51 psi in 1st 15 min and 9 psi in 2nd 15 min for a total loss of 60 psi in 30 min. Bled IAP from 2438 to 600 psi in 28 min (1.7 bbls). Job Complete. Final WHPs = 1571/630/378. • 10/15/2013 SV= C. WV, SSV, MV= 0. IA, OA= OTG. NOVP. 1300 TIC= 4-1/16"CAN WELLHEAD= FIAT • SA.NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR WHEN ON MI.WELL REQUIRES A SSSV WHEN ON qB.ELEV= 82.3' Mi. BF.ELEV= NA KOP= 300' —I 986' J--I 9-5/8"TAM PORT COLLAR I Ilbx Angie= 41"@ 2245' Datum MO= 7990' Datum 1 VD= 6600'SS I 1 I 2186' H 4-1/2"HES X NP,D=3.813" I GAS LFT MANDRaS 9-5/8"CSG,40#,1-80,D=8.835" H 2985' ST MD 1VD DEV TYPE VLV LATCH FORT DATE L 3 4028-3508 39 KBG-2 DMY BK 11/23/02 2 5318 4504 39 KBG-2 DMY BK 11/23/02 1 7611 6358 38 KBG-2 OMY BK 11/23/02 Minimum ID =3.725" @ 7733' 4-1/2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: TCP PERE ANGLE AT TOP PERF: 29°@ 7879' Note:Refer to Production DB for Nrstorical pert data SIZE SPF MfftVAL Opn/Sqz SHOT SQZ 3-3/8" r 6 7879-7929 0 09/19/02 2' ' 6 7880-7910 0 10/01/13 3-3/8" r 6 7936-7942 0 09/19/02 3-3/8" ' 6 7952-7956 0 09/19/02 2' ' 6 8038-8068 0 10/01/13 7677' H 4-1/2"I-ES X NIP D=3.813" I !� 7688' --I r X 4-1/7 BKR S-3 FKR,D=3.875' I ' ■, I 7712' H 4-1/7 F ES X NIP,D=3.813" I ■ I 7733' H 4-1/2"I-ES XN NP,D=3125' I 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 7745• nom. H 4-112"WLEG,D=4.00" I 7793' H 20'Pl)P JT W/RA TAG(ELM) I I 8181' H 20'R.IP JT W/RA TAG(ELM) I PBTD H 8363' •••••••••• T CSG,28#,1-80,ID=6.276' H 844 • DATE REV BY COI/LENTS DATE REV BY COMM3418 BOREALIS I.Nr 08/26/02 TWA/KK ORIGINAL COMPLETION 10/10/13 JCIINJMD S/ADPERFS(10/01/13) WELL V-104 09/19/02 DBMKK PERFS PE BAT No:' 021420 11/23/02 DTR/TP C/O GLVS AA No: 50-029-23103-00 04/10/03 ORSITP TVTYM)CORRECTIONS SEC 11,T11 N,R11 E, 4827'NSL&1819'WEL 02/15/11 M3/JMD ADDED SSSV SAFETY NOTE 01/19/12 TMNYJMD ADDED H2S SAFETY NOTE BP Exploration(Alaska) MEMORANDUM To: JimRegg ~~~, i1~3~~1~'j P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 02, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-104 PRUDHOE BAY UN BORE V-104 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.1. Suprv ~~- Comm Well Name: PRUDHOE BAY UN BORE V-104 API Well Number: 50-029-23103-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS091030152127 permit Number: 202-142-0 Inspection Date: 10/29/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-104 'I'i`ype Irij. ~/~j TVD ~ - -- - -- 2021420 , T eTCSt SPT P.T.D ~ yp Test Sl h I _ ~ 6421 ~ IA T--660 3980 • ~----- --- 1605 QA 340 340 ~ '~ 3880 T 3860 '' ~------r ? 340 340 ---~ - I-- - I --- _ -- -- -- -- - -- - ------ -- ~ -F-- -- --- - ' Interval aYRTST p~F P --------- 200 Tubing ~ 2100 - -------~- -- zloo zloo 1--~--- ---~------ Notes: !+ r° `~ ° Monday, November 02, 2009 Page 1 of 1 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage,Alaska 99519-6612 August 14, 2009 ~~;~,~~;•~~~~; ~'~ ':.' ' =~ ~ ~~'; . bp ~~~.,IL...~ Y ~b,~ ocT o 5 2~ag Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7ih Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, I~alca Oil ~ Gas Cons. ~ammi~~inn Anchorap~ a.~~-~ ~~ ~` U-~io~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 2t.3 7/1112009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-1o6A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA t 3.6 7/11 /2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-1o9 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 125 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-t21 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-t22 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 v-201 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 5002923t530000 NA 1.75 NA 12.8 7/11/2009 V-203 205168U 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 12 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 "~ 2080200 50029233830000 NA 1.75 NA ~b 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, November 30,2005 SUJJJj<:ç'I; !',1ecl1ªºLc"ll I!1J~grityTests BP EXPLORATION (ALASKA) INC V-104 PRUDHOE BA Y UN BORE V-104 .; ILt-Y lO~ TO: -~~~~:;r~isor --~f1-1~1-r(()Ç Src: Inspector Reviewed By: ~B P.I. Suprv --..: ÇY',,--- Comm NON~CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE V-I04 API Well Number 50-029-23103-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS05lJ 29155936 Permit Number: 202-142-0 Inspection Date: 11/28/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WeIll V-104 IType Inj. w I TVD I 6421 i IA i 420 I 4000 I 3860 I 3840 I I I I I P.T. ! 2021420 !TypeTest I SPT I Test psi I 1605.25 lOA I 350 f 350 I 350 I 350 I I I I i Interval OTHER P/F P Tubing i 1000 i 1000 ! 1000 I 1000 I ¡ Notes MIT performed pre-wag swap. Çj,«'þ¡':'~,~~b&:t' ~n\J.., \j~~" " 2: .L Wednesday, November 30,2005 Page 1 of I ) AItASIiA OIL AND GAS CONSERVATION COMMISSION ~ø~~j,'~a--- ~~~\~! i: ~ fÆ:fÆ~~«!Æ FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bruce Smith Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V-104 Sundry Number: 304-403 Dear Mr. Smith: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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°,¿j !4dY, ~ ~ j~.A A "\.No911ãV" Chairmaìr' BY ORDER OF THE COMMISSION DATED thisKday of November, 2004 Enc!. SCANNE[> NOV 1 6 2004 STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV~.L 20 AAC 25.280' ' Stratigraphic D Service ŒJ /' 9. Well Name and Number: V-104 /" 1 O. Field/Pool(s): Prudhoe Bay Field I Borealis Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 8363 6925.9 MD TVD ) 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: Suspend D RepairWell D Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 82.30 KB 8. Property Designation: ADL-0028240 11. Total Depth MD (ft): 8455 Casing Total Depth TVD (ft): 7090.1 Length Size Conductor 80 Production 8419 Surface 2956 Perforation Depth MD (ft): 7879 - 7929 7936 - 7942 7952 - 7956 Packers and SSSV Type: 4-112" Baker S-3 Perm Packer 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6585.61 6629.2 6635.31 6640.5 6649.25 6652.7 12. Attachments: Description Summary of Proposal D Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: November 17, 2004 Date: PerforateD WaiverD Annular Disposal D StimulateD Time ExtensionD OtherŒJ Re-enter Suspended Well 0 Convert to WAG Inj 5. ..p.,e,.. rmit to Drill t>J.., ...umber: 202-1420 /'. / 6. API Number (' 50-029-23103-00-00 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Exploratory D Plugs (md): Junk (md): None None Burst Collapse top bottom top bottom 30 110 30.0 110.0 1490 470 26 8445 26.0 7081.2 7240 5410 29 2985 29.0 2700.1 5750 3090 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # L-80 24 7745 Packers and SSSV MD (ft): 13. Well Class after proposed work: ExploratoryD Development D 15. Well Status after proposed work: Oil D GasO WAG ŒJ GINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Bruce Smith r~~ )L~ Contact Title Phone Petroleum Engineer 564-5093 Commission Use Only BOP TestO Conditions of approval: Notify Commission so that a representative may witness Location Clearance 0 Other: '-- SCANNED NQV 1 6 2004 Form 10-403 Revised 06/2004 Mechanciallntegrity Test D ~ ç ud d s t-- b:. 5 ~Y\-I1.' 7688 Service ŒJ PluggedO AbandonedO WINJD WDSPLD Prepared by Garry Catron 564-4657. Bruce Smith 1.mlQ! Sundry Number: ~V- tfo3 BY ORDER OF THE COMMISSION Date: '!~ff OR\G\NAL RBDMS 8FL NOV 1 6 7004 SUBMIT IN DUPLICATE ) " TREE = 4-1/16" aw WELLi"EA D = FMC J\CiüÄTÒFf~" ""'f\JA KB. ELBI = 82.3' ~-~-_._--_.... .._...~ BF. ELBI = NA KOP = 300' "Mix-An~iìë";; """"4o:1f@ '2245; 'ïiitüïñ'''rviY;' .."w""", ""'7990ï 't~tüm"lVtf;-'''''''''''''-''{3''6öõi''ss V -104 ) I SAFETY NOTES: I =---I 986' H 9-5/8" TAMPORf COLLAR 1 1 2186' H 4-1f2"I-ESXNIP,D=3.813" 1 I I 9-5/8" CSG. 40#. L-80, ID = 8.835" H 2985' r.JI ~ L ST MD 3 4028 2 5318 1 7611 GA S LIFT tv1A. NDRB..S TVD DEV TYÆ VLV LATŒi 3508 39 KBG-2 DMY BK 4504 39 KBG-2 DMY BK 6358 38 KBG-2 DMY BK FORf DATE 11/23/02 11/23/02 11/23/02 Minimum ID = 3.725" @ 7733' 4-112" HES XN NIPPLE PERFORATION SUMV1ARY RET LOG: TCP ÆRF ANGLE AT TOP PERF: 29 @ 7879' I\bte: Refer to Production DB for historical perf data SIZE SPF INTER\! AL OpnlSqz DA TE 3-318" 6 7879 - 7929 0 09/19/02 3-318" 6 7936 - 7942 0 09/19/02 3-318" 6 7952 - 7956 0 09/19/02 I I 7677' H 4-1/2" HES X NP, ID = 3.813" 1 :8: Z 7688' H 7' X4-1f2" BKRS-3 PKR, ID = 3.875" 1 I \ 7712' H 4-112" HES X NP, ID = 3.813" I 7733' H 4-1/2" HES XN NIP,ID = 3.725" I I 4-1/2" TBG, 12.6#, L-80. .0152bpf, ID= 3.958" H 7745' 1 I 7745' H 4-1/2" WLEG, ID= 4.00" 1 , 7793' 1-1 20' RJP Jr W/ RA TAG (ELM) I SCANNED NO\11 () 2004 I FBTD H 8363' * ~ 8181' H2O' RJP Jr W/ RA TAG (ELM) 1 17" CSG, 26#. L-80, ID = 6.276" H 8446' D6.TE 08126102 09/19102 11/23102 04110103 RBI BY COMV1ENTS TWA/KK ORIGINAL COMPlETON DBM/KK IPERFS DTRIlP C/O GLV S DRSITP TVD/WD CORRECfIONS DATE REV BY COMWENTS BOREALIS UNrr WELL: V-104 PERMT I\b: 2021420 APII\b: 50-029-23103-00 SEC 11, T11N, R11E, 4827' NSL & 1819' WB.. BP Exploration (Alaska) ) q C) 'Jt Â() ~ t{ DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Permit to Drill 2021420 Well Name/No. PRUDHOE BAY UN BORE V-104 Operator BP EXPLORATION (ALASKA) INC S(; Ul¿ I 7 .<0) ){M) ~ API No. 50-029-23103.00-00 MD 8455------ TVD 7090 ~/- Completion Date 9/19/2002 ..-/ Completion Status 1WINJ --~--_._---~------ ----- . ~._---~-------_..__._----------~---- REQUIRED INFORMATION Mud Log No Samples No --~.-----~ -------...---- -_._--~---- -~~---,-~------ .__._._~._...~-- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, PWD, PEX, BHC Sonic, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ---~_._-~-~ Log Sonic 25 Blu 1 u4 .sonic ~ Blu c---Eð-~ ¿;Diréêtional Survey " £a1Íper log ~ 5 Blu ~ QJet1SitY 25 Blu uÆé ~tion/Resistivity 25 Blu ~ Lceñ1ent Evaluation 5 Col u;.r.r. L-Û <tí24 7 Neutron l~ /' tfirosity 25 Blu Rpt Directional Survey d.:óQ'/ v<Íamma Ray ìllD 25 Blu (~ ~ssure Blu ~ cGamma Ray ('Ill) 25 Blu (§p..U M231¿/$ee Notes ~----~-'~--'-----'-~ Well Cores/Samples Information: Name Interval Start Stop Sent Current Status 1WINJ UIC Y Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 2900 8420 Open 10/25/2002 Platform Express / DSL T t-2OO0 8420 Open 1 0/25/2002 Platform Express / DSL T (JY J455 Open 10/2/2002 ..-l900 8420 Open 10/25/2002 Platform Express / DSL T [i9øó 8420 Open 1 0/25/2002 Platform Express / DSL T aroô 8420 Open 1 0/25/2002 Platform Express / DSL T ~70 8350 Case 9/13/2002 L.-2'852 8446 Open 1 0/25/2002 ~ 8420 Open 1 0/25/2002 Platform Express / DSL T 0 8455 Open 10/2/2002 u-12 8458 Open 10/25/2002 t.-2<Y 8361 Case 1 0/14/2002 Static Bottom Hole Pressure Survey tA1'£ 8458 Open 1 0/25/2002 Y'2 8458 Open 10/25/2002 Open Hole editted data containing MWD Data Sample Set Number Comments Received ~ '- Permit to Drill 2021420 MD 8455 TVD 7090 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ---YIN-- Analysis Received? __YJN~- ---- -~.- ~----------~~--- ._-----------~---------~ Comments: _._------------------------ . - ~~-~-~ ~---- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/4/2004 Well Name/No. PRUDHOE BAY UN BORE V-104 Operator BP EXPLORATION (ALASKA) INC Completion Date 9/19/2002 Completion Status 1WINJ Daily History Received? Formation Tops ~~ API No. 50-029-23103-00-00 Current Status 1WINJ r.'- (0N @/N Date: UIC Y ~' /r~ð~( ~ ") STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION RECEIVED . REPORT OF SUNDRY WELL OPERATIONSSCp 2 92004 1. Operations Performed: AbandonD Repair Well 0 Pluq PerforationsD Stimulate D . 01hr~. Cq{lvert WOlniltQ,tiQß.n AiaSI(Ð UI ,as ,",OOS. tJ mmlSälO Alter CasingD Pull TubingO Perforate New Pool 0 WaiverD Time Extension .nchorage Change Approved ProgramD Operation ShutdownO Perforate 0 Re-enter Suspended Well 0 82.30 8. Property Designation: ADL-0028240 11. Present Well Condition Summary: 4. Current Well Class: Development ŒJ Stratigraphic 0 9. Well Name and Number: V-104 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool ExploratoryD Service D 5. Permit to Drill Number: 202-1420 6. API Number 50-029-23103-00-00 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 8455 feet true vertical 7090.1 feet Plugs (measured) None Effective Depth measured 8355 feet true vertical 7001.1 feet Junk (measured) None Casing Conductor Production Surface Length 80 8419 2956 Size 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 MD TVD Burst 30 110 30.0 - 110.0 26 - 8445 26.0 - 7081.2 29 - 2985 29.0 - 2700.1 1490 7240 5750 Collapse 470 5410 3090 Perforation depth: Measured depth: 7879 -7929, 7936 -7942, 7952 -7956 True vertical depth: 6585.61 - 6629.2,6635.31 - 6640.54,6649.25 - 6652.74 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 24 7745 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure @ 7688 13 Prior to well operation: Subsequent to operation: Oil-Bbl 463 0 0.2 0 0 -8458 520 Tubing Pressure 1700 1534 Copies of Logs and Surveys run - Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD Service [!] 14. Attachments: Signature Garry Catron Garry Catron 1f~~ WAG 0 GINJD WINJ[!) WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: 302-329 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 9/22/04 SEP29 ORIGINAL Form 10-404 Revised 4/2004 .. " ) V-104 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/29/02 Convert to Produced Water Injection FLUIDS PUMPED BBLS No Fluids Pumped 0 ITOTAL # Page 1 .. .' ) 1REE = 4-1/16" aw WELLI-EA D = FMC AC1UATOR= ^-~ """""^........~~~,..~~~^"""""""""'""'"'.............."^........""""""'................- KB. ELBI = 82.3' ~...............,-~....,,~'^"""'...............~........~ BF. ELBI = NA KOP = 300' 'M)x"Aïïgië"';;;"" 4Ö~'8'@f2245ì ëiïiÚm"'rvö"';;; """''''',..,,'' ""']'000; 'oaiüffi"iVb'';;'" '" "''''6''6ö''Õj''SS 9-5/8" CSG, 40#, L-80, ID = 8.835" H 2985' ~ Minimum ID = 3.725" @ 7733' 4-1/2" HES XN NIPPLE PERFORATION SUIVtII1ARY RS= LOG: TCP ÆRF ANGLE AT TOP PERF: 29 @ 7879' I'bte: Refer to Production DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA TE 3-3/8" 6 7879 - 7929 0 09/19/02 3-3/8" 6 7936 - 7942 0 09/19/02 3-3/8" 6 7952 - 7956 0 09/19/02 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 7745' I FBTD H 8363' 17" CSG, 26#, L-80, ID = 6.27f)' H 8446' [}\ TE 08l26JU2 09l19JU2 11/23JU2 04l10JU3 RBI BY COIVtll1ENTS TWA/KK ORlGINA.L COMPLETON DBM/KK IPERFS DlR/lP C/O GLVS DRS/lP ND/fIII) CORRECTIONS V-104 - I I l I I ~ I z \ / * ~ DA TE REV BY COMrvENTS ") I SAFETY NOTES: =--f 986' H 9-5/8" TAM PORr COLLAR I I 2186' H 4-112" I-ESX NIP, D =3.813" ~ GAS LIFT MA.NDRELS ND DEV TYÆ VLV LATa; 3508 39 KBG-2 DMY BK 4504 39 KBG-2 DMY BK 6358 38 KBG-2 DMY BK ~Rr DATE 11/23/02 11/23/02 11/23/02 ST MD 3 4028 2 5318 1 7611 7677' H 4-1/2" HES X NP, ID = 3.813" 7688' H 7" X 4-112" BKRS-3 PKR, ID = 3.875" I 7712' H 4-1/2"HESXNP,ID=3.813" 7733' H 4-1/2" HES XN NIP, ID = 3.725" 7745' H 4-1/2" WLEG, ID = 4.00" I , 7793' H2O' FUP JT W/ RA TAG (ELM) I 8181' H 20'FUPJTW/RATAG(ELM) BOREALIS UNIT WELL: V-104 PERMT f'.b: 2021420 API f'.b: 50-029-23103-00 SEC 11, T11N, R11E, 4827' NSL & 1819' WEL BP Exploration (Alas ka) ) -) I a [B-1 t..J d. } I ðOG WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska February 05, 2003 RE: MWD Formation Evaluation Logs PSI-09, AK-MW-22 104 1 LDWG formatted Disc with verification listing. PùPI#: 50-029-23095-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~¿ Oor;) RECE'VED FEB 11 2003 A18Ika Oö &. G8a Cons. Comrni8Iion Andmge ~ " ('. A f~ ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill Commissioner ~\" SUBJ, ECT: MeCh, anicallntegrity Tests THRU: Tom Maunder . \ BPXA Petroleum Engineer, /ùY L& V Pads \?-hçç L-t03, V-104 FROM: Jeff Jones PBU Petroleum Inspector PBF/Borealis NON. CONFIDENTIAL ~vf; DATE: December 14,2002 Packer Depth Pretest Initial 15 Min. 30 Min. T.V.D. 4283 Tubing 1520 1520 1520 1520 Interval Test psi 1071 Casing 1645 2120 2110 2110 P/F OA 360 410 390 390 Notes: Pretest pressuresobseved 15 min. & stable. Test fluid: 36 BBLS diesel. . ~ \\ ~Q~~~ -\\0\ 2} \X'}(" \40' Packer Depth Pretest Initial 15 Min. 30 Min. T.V.D. 6422 Tubing 1560 1560 1560 1560 Interval Test psi 1606 Casing 350 2040 2040 2030 P/F OA 340 340 340 340 Notes: Pretest pressures obseved 15 min. & stable. Test fluid: 3.9 BBLS diesel. Well L-103 Type Inj. P. T.D. 2021390 Type test s P I f Well V-104 Type Inj. P. T.D. 2021420 Type test s P I f Type INJ. Fluid Codes F = FRESH WATER INJ. G = GASINJ. S = SALTWATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval 1= Initial Test 4= Four YearCycle V= Required by Variance W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details December 14,2002: I traveled to BPXA's water injection wells L-I03 and V-I04 to witness initial MIT's. Bryan McLellan was the BPXA representative for the tests, which were performed in a safe and proficient manner. The pretest pressures were monitored and found to be stable and the standard annulus pressure test was then performed with both wells passing the MIT. Summary: I witnessed successful MIT's on BPXA's water injection wells L-I03 and V-I04 in the Prudhoe Bay Field. M.I.T.'s performed: ~ Number of Failures: Q Attachments: Wellbore schematics (2) Total Time during tests: 5.5 cc: MIT report form 5/12/00 L.G. MIT PBU L-!103, V-104 12-14-02 JJ.xls 12/18/2002 !?T D 1t ;¿ O~\ 1f1o ) 'TREE- 4.'f16" OlW waca:í~ D II firJC AClUA lOR ¡;." ............. m -... NÁ KB. a.EY = .n, ""1"8;:4i' ~BF:'-a:'ëV--~ 53.4~ "KÖ"P ;i""''''- -.--- -- 5DD' :t:~m~:':'.::.'~.'~.~~- 4Ö-f3~ DaturnTVD = . .\ '~~àØø"öï'ss' J 9.~e"CSG.40#.L-80.lë=B.836;'~IH 3031" . rA L-1 03 ... - Minimum ID = 2.813" @ 8510' .. .. 3-1/2" HES X NIPPLE 1.4 éø.r.;;: a.(?/'6,Wff ~I lrJbJ,hl) ~ ~~~1/ 1YtÎ~ 8 r " 4-1/~" TBG, 12"~#;L..aO, .0152 bpf I ID = 3.958" H 5779' I '._3~1/2" TBG, !Ü#, L.80, ,0087 bpf. D :,_:~:~2".1 I 3..1/2" TBG. 9.2#, L-BO, .oositíP(1b = ~'992D H .... ,,~79"'" PERFORATION SUMMð.RY REF LOO: TO' PERF ANGLE A T TOP PERF; 52 @ 5695' r-t>le: A.efér to Ftoduction DB for historical perf da1a SIZE SPF INTERV At OpnÎsi:P:' - Cð. TE 4-0/8" ~ 5~5 .5962 o' 'ósÅi9i02. 4--5/6" 5 6018 .6070 0 DBID9fD2 . 4-6/8" 5 6097 - 6119 0 06A)9/02 4-518" 5 6194 - 621 0 0 OSKJ9/02 4-516" 5 6235.6372 0 OS,Q9/02 4.516" 5 6398 - 6415 0 08.09/02 I Fa TO H 92'1S" I r CSG. 26#, L-BO, .03e.iï;¡. ~~ ::.6.276"-- H 9360' ~ 1E. . ~~ ax COM'v1ENTS _g!3l091J2 OM'KAK ORK;~I. COMPLETON 10113J02 JEVKAK GI.,V ao .. ..-. -.., "'" .n." 1Z/17/Øzøo')4ØP P . ØØ4 SA~ETY 1'D1ES: GLM'S @ STA ft1 & #2 ARE 3-1/Z' X 1-1/2" MMJ-Ws, WHCHARE WA"ORFLOOO ~NOREl..S. ;---f" 1019" H -9.?~" iAMPORTCOlt.AR-] I ~.- I 2216" H . ~~.1/2" I-ES X ÑJP,-'D = 3. ~!~~~ I I l . fa $T MD 5 ïf513 , 4 5310 3 5645 'TVO OfY ~J'e VLV" LATCH PORT CATe 3503 51 KBG-2 roM!! BK 16 1'011-3102 4008 50 KBGo2 OOIY BK 0 10/13/02 4232 47 KBG-2 SO BK 20'0113/02 WATæ:tÖOO -rMr-DRa.S TVO 061' rŸÆ VLV LATO-i PORT i:)(TË 4348' "-52 M\1G-W ~Y RK - . 0 'O8~9102 4385 52 MvtG-W [)MY RK 0: 06.09/02 ST 'MD 2 5822 1 5682 I 5711' Ii '4:1/2-. ~~~_~IID !!3,a'3- I ~ . "'-~22'_...\ H 7" X 4.112" BKRMEMI:R PKR. C = 3.~~~ .1 I 5779" H 4~'/2;"X3-1/2' xc, ID= 2.Q92" I "- ---1 ~ DATE ÆV BY -- n' ...-- -..., ". "...-.". COMrJeNTS .. --. o. .--. ~ I .~1.~..__. H' 3.112" JoES X NP, ID = 2.~.1 ~~ I . 8521' H 3-112" X4~1/2" XO, ~~..~.,,~.~~nl I 8522" H 7" X 4-1/2" BKR S-3 RÚ~, 'D~'3.87~"1 1 852~. ,.Ii. 4.1/2" £3:1ïz.-xö~ïD= 2.992" I I 8548' H._..~-1/2..¡::es:XNP,ID=2.S13"1 I.~"~ ~.6.9' H. 3~Y2"I'£SX ~;-D-=2,813" f I 8581. H 3-112" WlB3 . I 8629" H .,.. tVII'A<~JTW/AAJ:AG..J .--L _8933' H r WA~_JT~L~J~~J GPI3 BOÆ':ALl5 WB.L: L.103 ~MT N:>: 2021390 AR No: 50-029-23101-00 -- ...~¡;C 34. i12N. Rf 1E, 2590' NSL & 3618' wa. BP Þploratlon (AIa$ka) ~~~~ ~ f\L~ ~ ~ t'T" ~~~ ~-l()?l '!-!?~ ~~-~~-~:.... ~~:~\~ .f>fD~ Öì oJ. f I.J.2..0 12/17/02 r)0P P.00S __n , TREe'll wELU4ËAD" ¡. A CTUA TOR"" .. KS. ELEV" ElF. a.w.. KOP. 300' M8x AnD" 'II 4J.B @ 224;' 'Õiib"nMÞ II D"'atuïnWD ii' - äeOOI SS . rtlJ" 41/10'" CMf fMC: """'MA' ... -', ç',S" ~, V-104 1'''SAFETVN011;S; , .1 , I =-r'" 98~ .,': 'H Ð-O/Er TAMP_O~! COUAR J " I 2186" I-f 41/2" Hç~ X NIP. o. ~.a1311 I - - I I g.5I8" CSG. a:i..:'ßa.-iD. a.8;!t5u.. H .~'iW .-J L " ()AS LJFT t.M.NDREl!i ,.~T NO -lV' )- -DEV 'tYpe VLV LATCH PORT _,DATE 3 4J28 3ðD8 3ij I<BG-~f - DM'f SK "rz¡1C2 :! !5318 4504 3~, KBG-2 DW BK 11/23102 1 7611 6358 sa J(¡ o.2 )M"( BK 11123102 Minimum Ie II 3.725" @ 71'33' 4-112" HES XN NIPPLE . . ~¿I :r A c....f. ~ Ð. ~) B"b ~ PERFOI\A 1'IOt4 ::iiUMM6.RY REF LOG: Tcr P~F ANG U; A'J' '1'DP PERF: ZI @ 781£1 Nlftt:R.f., ~ fIoodu~n De f~r histOTioal peTf dita SIZE' "'spr" IN~~t'.L OpnJSqz DA 1E 3.3Æ1" 8 787Q - 7Q2Q Ó OQt1~1D2 S.3ÆU 4S 7~ M 1942 , 0 aQI1QI02 s. ~~u fI 78S2 . ;8t5C 0 OQI191D2 6 q).). IV'£> .. . I- L. 7f¡f1' H 41t:l' -~~, ~NP,IO~'i&-13" I ,;> ~ ~ I 7688' H 7" ~.~'rr BKR 5.3 PKR,IO...~,~~H..I r -'u, 41r.r, H~,X.NP;' I)-3.813" I I r-' 711'Z. H I 7733' H :q:.¡fZ' He5 XN .~, ~ ~3.7'25" I ... w. I 7145' ~ 41121 WLE(), I.D" 4.00" i I 41tZ' TBO.12B1. L-BD. .0152 bpf. 1D~'3:.9~ï'. H, .. 7745' I r 119Y i-i 2f)' p\jPJTWI RA TA~<~,I -1 8181"..H 20' P\JPJTWI RA TAO<.El.AC)..! I PEïTD- 'H.., B36!' J L~ 17" CS."'.2Ø'.l.:BO. .IDB3 bpi, lD.e.mo H-I!446' ~ "'" _n. ~'-'" -..---.... ~ 1E RBI BY <: 0 alMENTS 09l2e'ô2" '!WAlK)( ORIGt4AL C OMPlETDN . OQl1.~A:12 )IMKK ~FS 11l23lJ2 D TRJ'IP ClciGl..V S -. ,~-, "'-. . DA TE ReV BY , ... ç-otNE:Ñrs <7PB BORE:ALlS WBL: v. 1 ()4 ~MT N9: ~2'42D APt No: ~.o:2Q.231( 3.00 see ii, T11N, R11E. 4327" NSL& 181Q'Wa. .. ... .. .... - -. . ..a~ .~_.._--, . " ..... -... 0"-' SP Qo(pIQl'atJon (Am kã) '\ n_. -. -.I Pr 1TR<.~ 1"0 ç.\'-..E"~ M\, ~ð~t L-l<3~;"-IO~ '~-I'-t-O~J.J..'J(\..S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) '4" 1. Status of Well Da Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4827' NSL, 1818' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 1913' NSL, 4883' WEL, SEC. 02, T11N, R11E, UM At total depth 2118' NSL, 5074' WEL, SEC. 02, T11N, R11E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 82.3' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/14/2002 8/21/2002 9/19/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8455 7090 FT 8363 7008 FT Da Yes 0 No 22. Type Electric or Other Logs Run . MWD, GR, PWD, PEX, BHC Sonic, USIT ') Classification of Service Well Pre-Produced Injector 7. Permit Number 202-142 8. API Number 50- 029-231 03-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number V-104i 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2186' MD 1900' (Approx.) 23. CASING SIZE 20" 9-5/8" 7" GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 108' 42" 260 sx Arctic Set (Approx.) 29' 2985' 12-1/4" 503 sx PF 'L', 303 sx Class 'G' 26' 8446' 8-3/4" 274 sx Class 'G', 205 sx Class 'G' WT. PER FT. 91.5# 40# 26# 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 7879' - 7929' 6586' - 6629' 7936' - 7942' 6635' - 6641' 7952' - 7956' 6649' - 6653' 25. SIZE 4-1/2", 12.6#, L-80 MD TVD 26. AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 7745' PACKER SET (MD) 7688' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 135 Bbls of Diesel Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA DEC[\V' 111' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chip~ U U 27. Date First Production October 27, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL OIL-BBL GAs-McF WATER-BBL No core samples were taken. Q80MS BFl NOV 2 0 2002 Form 10-407 Rev. 07-01-80 CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) NOV 1 8 2002 £\iaska on & Gas Cons. com_tO! Anchorage Submit In Duplicate .t ) ~) . 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. , Schrader Bluff M Sands 4752' 4071' Schrader Bluff N Sands 5074' 4317' Schrader Bluff 0 Sands 5283' Base Schrader / Top Colville 5745' HRZ 7500' Kalubìk 7734' Kuparuk D 7854' Kuparuk C 7874' Kuparuk B 8068' Kuparuk A 8210' Mìluveach 8304' 4477' 4835' 6266' 6460' 6564' 6581' 6956' REceiVED NOV 1 8 2002 6750' 6873' AJaska Oil & Gas GODS. CommissIon Anchorage 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHUbble~ ~ Title Technical Assistant Date 1 (.l6.o~ V-104i 202-142 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. DrilJing Engineer: James Franks, 564-4468 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Schlum~erger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth dDa - J ~ V-103 V-105 V-105 V-105 V-105 V-105 V-105 V-104 V-104 aQ;)-/t/~ ~:~~: V-104 V.104 dOd-'J5/ Well Job# Log Description 22466 22419 22419 22419 22419 22419 22419 22394 22394 22394 22394 22394 22394 USIT OH PEX AIT/BHC SONICIDEN/NEUTRON PEX RESISTIVITY PEX SONIC PEX NEUTRON/DENSITY PEX RES/NET/DEN/SONIC LOGS PEX CALIPER OH EDIT AIT/BHC SONIC/PEX NEUTRONIDEN PEX RESISTIVITY PEX BHC SONIC PEX NEUTRON/DENSITY PEX TRIPLE COMBO & SONIC PEX CALIPER PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETU~NING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECE\VED OCT 2 5 2002 Alask' on &. Gas Cons. eommiatiOn Ancbtß99 10/05/02 09/04102 09/04/02 09/04/02 09/04/02 09/04102 09/04/02 08/23/02 08/23/02 08/23/02 08/23/02 08/23/02 08/23/02 NO. 2491 10/17/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis P. Bay Date Color Sepia Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATIN: Beth R'~ BL CD ~' . Lt Cbop~ ~ Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth )~~ -~... V-104 'Ã,.r:Y V-104 U" -' V-104 V-107 c: V-107 1~' V-107 éP Od-' Well Job# Log Description 22424 OH EDIT MWD 22424 MD VISION GR 22424 TVD VISION GR 22475 OH EDIT POWERPULSE & IMPULSE 22475 MD VISION RESISTIVITY 22475 TVD VISION RESISTIVITY PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: RECEIVED OCT 25 2002 AJ88ke 0i1 & Gas Cons. Commileion AndKnge 08/21/02 08/21/02 08/21/02 10/13/02 10/13/02 10/13/02 10/24/02 NO. 2509 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis P. Bay Date Color CD Sepia BL .~. Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATIN: Be~ - R~;~~.-/.: ~¿Jbr~ ~' ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned 181 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ?-'-,..':-:"'~'"'-"'~""'> 4827' NSL 1818' WEL SEC. 11 T11 N R11 E UM ¡ GGí\M't.Ef!ON ~ At top of productive interval ' , , ¡ DJ~Tf£ i 1913' NSL, 4883' WEL, SEC. 02, T11 N, R11 E, UM 1--1.'I9.Þ~ At total depth ! VFJ-t~:n J 2118' NSL, 5074' WEL, SEC. 02, T11N, R11E, UM L:::::~~.:::"~ 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 82.3' ADL 028240 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/14/2002 J 8/21/2002 9/19/2002 . 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8455 7090 FT 8363 7008 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, PWD, PEX, BHC Sonic, USIT ~." '.' V"~)~. .~''''. ""'. .~'..-" _:.~~ ~,:~'I , ~. :- , '., . . ~ ," " ."'" f ~ '.'~~ " ,.::::7.r'?-\ '. . I~~~. f'.1'~ ,nr:,,;"""\('¡~;"""'-~'ör~,f¡ Classification of Service Well Water & Gas Injector 7. Permit Number 202-142 8. API Number 50- 029-23103-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number V-104i 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2186' MD 1900' (Approx.) 23. CASING SIZE 20" 9-5/8" 7" GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 108' 42" ,260 sx Arctic Set (Approx.) 29' 2985' 12-1/4" 503 sx PF 'L', 303 sx Class 'G' 26' 8446' 8-3/4" 274 sx Class 'G', 205 sx Class 'G' WT. PER FT. 91.5# 40# 26# 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 7879' - 7929' 6586' - 6629' 7936' - 7942' 6635' - 6641' 7952' - 7956' 6649' - 6653' 25. SIZE 4-1/2", 12.6#, L-80 MD TVD 26. AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 7745' PACKER SET (MD) 7688' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 135 Bbls of Diesel 27. Date First Production Not on Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RE€EIVED 28. No core samples were taken. OCT 23 QSOMS 8Fl Form 10-407 Rev. 07-01-80 /; J OCT 2 1 2002 AlaSKa Ofla Gas Gons. Gommtsslan Anèhomgo . . G (¿::: Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Schrader Bluff M Sands 4752' 4071' Schrader Bluff N Sands 5074' 4317' Schrader Bluff 0 Sands 5283' 4477' Base Schrader / Top Colville 5745' HRZ 7500' Kalubik 7734' Kuparuk D 7854' Kuparuk C 7874' Kuparuk B 8068' Kuparuk A 8210' Miluveach 8304' 4835' 6266' 6460' 6564' 6581' 6750' 6873' 6956' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ Title Technical Assistant Date IO.17~O~ V-104i Well Number 202-142 Permit No. / Approval No. Prepared By Name/Number: Terrie Hubble, 564-4628 Drilling Engineer: James Franks, 564-4468 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: V-104 Common Name: V-104 Test Date 8/17/2002 Test Type LOT Test Depth (TMD) 2,985.0 (ft) SF> EXPLORATION t..èâk-Pff Test Summary n~~tDøpthJTVD) 2,700.0 (ft) AMW 9.70 (ppg) Surface Pressure 690 (psi) Leak Off Pressure (BHP) 2,051 (psi) Page 1 of 1 EMW 14.62 (ppg) ':~ ~ Printed: 9/4/2002 10:58:27 AM ) ) ¡;" BP.E)(PllOJ'RATION -øp~t,~i~li$ ..Surpmal}f.R~ÞQrt Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: V -1 04 V-104 DRILL +COMPLETE NABORS NABORS 9ES Start: 8/13/2002 Rig Release: 8/27/2002 Rig Number: 9-ES Spud Date: 8/14/2002 End: 8/27/2002 Ðate From :To HoÙrs Task -eode NPT 8/9/2002 12:00 - 00:00 12.00 MOB P PRE 8/10/2002 00:00 - 03:00 3.00 MOB P PRE 03:00 - 09:00 6.00 MOB P PRE 09:00 - 00:00 15.00 MOB P PRE 8/11/2002 00:00 - 00:00 24.00 MOB P PRE 8/12/2002 00:00 - 00:00 24.00 MOB P PRE 8/13/2002 00:00 - 17:00 17.00 MOB P PRE 17:00 - 21 :00 4.00 MOB P PRE 21 :00 - 22:00 1.00 MOB P PRE 22:00 - 23:00 1.00 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 00:00 - 08:00 8.00 RIGU P PRE 8/14/2002 08:00 - 14:00 6.00 DRILL P SURF 14:00 - 15:30 1.50 DRILL P SURF 15:30 - 16:00 0.50 DRILL P SURF 16:00 - 18:00 2.00 DRILL P SURF 18:00 - 19:00 1.00 DRILL P SURF 19:00 - 00:00 5.00 DRILL P SURF 8/15/2002 00:00 - 02:00 2.00 DRILL P SURF 02:00 - 02:30 0.50 DRILL P SURF 02:30 - 04:00 1.50 DRILL P SURF 04:00 - 05:00 1.00 DRILL P SURF 05:00 - 06:30 1.50 DRILL P SURF 06:30 - 15:00 8.50 DRILL P SURF 15:00 -16:00 1.00 DRILL P SURF 16:00 - 18:00 2.00 DRILL P SURF 18:00 - 21 :00 3.00 DRILL P SURF 21 :00 - 22:00 1.00 DRILL P SURF Rig released from L-103i. Start move to V-104i. Rig broke through the road 200' down the road. Move the rig back to L pad Lay rig mats on the L to V pad road Move the rig to V-1 04i. Having to move on Rig mats -125'/hr. Continue to move the rig to V-1 04i. Having to move on Rig mats -125'/hr. Continue moving rig on mats between L and V Pads. Progress at approx 130 ftlhr. Estimate being 0.4 miles from V Pad @ 24:00 hrs. Continue moving rig on mats between L and V pads. P I U BOP stack and stand back on stump. Move mats from road and place on pad. Spot rig over Well V-1 04i. Raise Derrick. Spot pit complex and take on water. MIRU. Take on water. N I U diverter and hydraulic lines. Hang back bridal lines. NU riser and flow line. Mix spud mud and load pipe shed wI DP. R 1 U floor. Rig accepted at 00:01 on 8/14/02. PI U 75 jts 4" DP, 21 jts 4" HWDP, 2 jts 5" HWDP + Jars, & 3 jts 7" DC's, from pipe shed and stand back in derrick. Function test diverter. Witness of test waived by Jeff Jones of AOGCC. P I U bit, mud mtr, lead DC, Stab, & MWD. Pre-spud meeting with rig team. Fill & check riser and Diverter system for leaks. Directionally drill fl 108' - 351'. Circulate hole clean. Change out 1 stand 4" HWDP for 5" HWDP wI jars. Directionally drill fl 351' - 910'. GPM: 660, Pmp Press: 1920, WOB: 20 K, ROT: 80 rpm, Up wt: 65 k, Dwn wt: 60 K. AST: 3.7 hrs, ART: .8 hrs, ADT: 4.5 hrs. TO: 7 K on btm, 6 K off btm. Directionally drill fl 910' - 1190'. 25 K WOB, 664 gpm, 2550 psi. Circulate hole clean @ 650 gpm, 1820 psi, 40 rpm. POOH for bit due to low build rate. Pull 25 Kover @ 750', rest of hole slick. Stand back Jar stand collar stand. Change out bit. Clear & clean rig floor. Service Top Drive & blocks. TIH. Work thru & wipe tight spot @ 630'. Ream thru tight hole @ 1130', 40rpm, 300 gpm. Wash I Ream last stand to bottom. Directionally drill fl 1190' - 3000'. PU wt: 102 K, SO wt: 72 K, RT wt: 93 K. 35 K WOB, 650 GPM, 3400 psi on btm, 3000 psi off btm, 80 rpm, 5 K TO on btm, 2.5 K TO off btm. AST: 6.26 hrs, ART: 1.5 hrs, ADT: 7.76 hrs. Circulate sweep around @ 80 rpm, 695 gpm, 3325 psi. TOOH to 500 '. Work tight hole from 2,300' to 1,200'. 20K to 50K over pulls and swabbing during trip. TIH. Hole tight. Wash thru @ 1500' -1700',1831' -1935', 2213' - 2307',2588' - 2682'. Circulate sweep and hole clean. Condition mud to 200 vis for casing run. 650 gpm, 2900 psi. Printed: 9/4/2002 10:58:35 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V -1 04 V -1 04 DRILL +COMPLETE NABORS NABORS 9ES Start: 8/13/2002 Rig Release: 8/27/2002 Rig Number: 9-ES Spud Date: 8/14/2002 End: 8/27/2002 Hours Task Code NPT 8/1512002 22:00 - 23:30 1.50 DRILL P 23:30 - 00:00 0.50 DRILL P 8/16/2002 00:00 - 01 :00 0.00 DRILL P 01 :00 - 03:30 2.50 DRILL P 03:30 - 09:00 5.50 CASE P SURF SURF SURF SURF SURF 09:00 - 11 :00 2.00 CASE P SURF 11 :00 - 14:00 3.00 CEMT N WAIT SURF 14:00 - 16:30 2.50 CEMT P SURF 16:30 - 19:00 2.50 CEMT P SURF 19:00 - 00:00 5.00 BOPSURP SURF 8/17/2002 00:00 - 02:30 2.50 BOPSUR P SURF 02:30 - 03:00 03:00 - 07:00 0.50 BOPSUR P 4.00 BOPSUR P SURF SURF 07:00 - 08:00 1.00 BOPSUR P SURF 08:00 - 14:30 6.50 DRILL P PROD1 14:30 - 16:30 2.00 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 20:30 1.50 DRILL P PROD1 20:30 - 22:30 2.00 DRILL P PROD1 POOH. Hole slick. Stand back Jar stand and DC stand. L / D BHA #2. Bit, Mud mtr, Lead DC, Stab, MWD. Clear rig floor. Make dummy run with casing hanger and mark landing joint. R I U 9 5/8" casing tools. M I U 9 5/8" casing shoe track. Check float equipment. RIH w/ float shoe, float collar, TAM collar, and 71 jts 9 5/8" 40 # L-80 BTC casing. Fill every jt as RIH. PI U landing jt and hanger. Land hanger in wellhead. M I U cement head and circulating equipment. Stage up pumps to 10 BPM, 740 psi. PU wt = 146 K, SO wt = 90 K. 100% returns. R / U Halliburton. Circulate @ 6 BPM, 322 psi while waiting on water for cement job. Hot water plant down for repairs. PU wt = 146 K, SO wt = 120 K. Reciprocate pipe. Pump 10 BW spacer. Test lines to 4000 psi. Pump 10 BW spacer. Pump 70 bbls 10.5 ppg weighted spacer wI red dye. Drop bottom plug. Mix & pump 372 bbls Permafrost L (503 sxs) 10.5 ppg, 4.16 yeild, lead cement @ 7 bpm, 840 psi. Mix and pump 62 bbls (302 sxs) 15.8 ppg, 1.16 yeild, tail cement @ 4.5 bpm, 550 psi. Drop top plug. Displace with 10 BW. Switch to rig pumps and displace with 212 bbls 9.7 ppg mud @ 8 bpm, 590 psi. Bump plug to 1600 psi. Bleed pressure. Check floats. 100% returns. 140 bbls contaminated cement in returns. Reciprocate pipe until 30% of displacement. N I D cement head. Break out landing jt and lay down. Flush Stack. Pump out cellar. RID casing equipment. R / U for DP. N I D diverter stack and line. N I U FMC Gen 5a well head, tubing spool, adapter flange, & BOP stack. Test metal to metal seal between the mandrel casing hanger and speed head to 1000 psi I 10 min. Continue to R I U stack. Continue to N / U BOP stack. Change out blind rams to blind/shear rams. M I U test joint to Top Drive and flush stack. R I U test equipment. Test BOPE including floor valves and choke manifold to 250 psi low 15 min & 4000 psi high / 5 min. Test Hydril to 250 psi low /5 min & 3500 psi high 15 min. Witnessing of test waived by Chuck Scheave (AOGCC). RID test equipment. Pull test plug. Blow down lines. Install Wear Bushing (ID: 9.125"). PI U DP from pipe shed. Drift and stand back in derrick. Clear rig floor. PI U BHA #3: Bit, Mud Mtr, Stab, MWD, 3 DC's, Saver Sub, Jar Stand, 21 HWDP. TIH picking up singles from pipe shed. Test casing to 1000 psi after passing TAM port collar @ 989'. TIH to 2700'. Break circulation. Close pipe rams and test casing to 3500 psi I 30 min. Cut & Slip Drill line. Service Top Drive and Crown. Break circulation. Wash down tag TOC @ 2896'. Drill cement, float collar (2902'), shoe track, & float shoe (2985'). Wash out rat hole to 3000'. Drill new formation fl 3000' - 3021'. Swap out Printed: 9/4/2002 10:58:35 AM ") ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date V -1 04 V -1 04 DRILL +COMPLETE NABORS NABORS 9ES Start: 8/13/2002 Rig Release: 8/27/2002 Rig Number: 9-ES Spud Date: 8/14/2002 End: 8/27/2002 8/17/2002 20:30 - 22:30 From~ To HoÜrs Tåsk. Cöde NPT Descri þtionöfQþèratior1$ 22:30 - 23:00 23:00 - 00:00 8/18/2002 00:00 - 04:00 04:00 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 16:30 16:30 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 00:00 8/19/2002 00:00 - 03:00 03:00 - 04:00 04:00 - 15:30 2.00 DRILL P PROD1 0.50 DRILL P PROD1 1.00 DRILL P PROD1 4.00 DRILL P PROD1 0.50 DRILL P PROD1 1.00 DRILL P 0.50 DRILL P PROD1 PROD1 0.50 DRILL P PROD1 0.50 DRILL P 1.00 DRILL P PROD1 PROD1 8.50 DRILL P PROD1 1.00 DRILL P PROD1 0.50 DRILL P 0.50 DRILL P PROD1 PROD1 1.00 DRILL P PROD1 4.50 DRILL P PROD1 3.00 DRILL P PROD1 1.00 DRILL P PROD1 11.50 DRILL P PROD1 mud to 9.7 ppg LSND while washing rat hole and drilling new formation. PU = 110 K, SO = 75 K, ROT = 90 K. 550 gpm @ 1750 psi. Circulate bottoms up and condition mud. Pull into casing shoe. Perform LOT. MW = 9.7 ppg, TVD = 2700', LO pressure = 690 psi. EMW = 14.6 ppg. Perform ECD baseline test, ECD = 10.13 ppg. Take Slow Pump rates. Directionally drill fl 3021' - 3160'. WOB: 5 - 10 K, 600 GPM, 2100 psi, ART: 0.35 hrs. Directionally drill fl 3160' - 4091'. PU wt: 135 K, SO wt: 85 K, ROT wt: 102 K. 600 gpm @ 2240 psi. TO: 5.5 K, WOB: 5 - 10 K. Back ream all stands @ 100 rpm. Pump Hi I low sweeps I 200'. Circulate hi I low sweep around and hole clean. 100 rpm, 600 gpm, 2100 psi. POOH to 3270'. Max pull 20 Kover. Back ream fl 3270' to 9 5/8" casing shoe @ 2985' due to swabbing & +25 K over pull. Circulate bottoms up. 585 gpm, 1788 psi. Rotate 100 rpm on pick up stroke and 0 on down stroke. Service top drive & blocks. TIH. Wash last stand to bottom. Stage up pumps to drill rate @ 600 gpm. ECD = 10.23 calc, 10.4 actual. Take SPR's. Pump sweep. Directionally drill fl 4091' - 5772'. 600 gpm, 3050 psi, PU wt:162 K, SO wt: 98 K, ROT wt: 119 K. TO 7 K off btm, 9.2 K on btm. Back ream 60' per stand, pump sweeps I 500'. Total AST = 1.5 hrs, ART = 6.86 hrs, ADT = 6.86 hrs. Pump hi I low sweeps around to get ECD down for wiper trip. Calculated ECD = 10.43 ppg, Actual ECD = 10.94 ppg. Flow check. PU wt: 170 K, SO wt: 100 K. POOH. Pulling tight & swabbing @ 5550'. Back ream to 5400'. Stage up pumps. Hole packing off and tight. TO 6 - 12 K & ECD up to 11.8 ppg @ 3 - 4 ftlmin pull rate. TIH to bottom and stage up circulation to drilling rate. Circulate Hi 1 Low sweeps around and shakers clean. ECD actual @ 10.84 ppg. Flow check. POOH to 5300'. Hole tight and swabbing. M I U top drive. Stage up pumps to 600 gpm. Back ream to 4746' @ 3 - 10ft 1 min, 110 rpm, 600 gpm, 3000 psi. Hole tight. TO 6 - 13.5 K, ECD @ 11.8 ppg. Losing mud while back reaming. Continue to backream out of hole @ 600 gpm, 110 rpm. TO: 6 -13 K. Backream to 3998'. Last short trip hole section @ 4091'. Pull 2 stands to 3640' without pumping ok. Pump sweep around while backreaming to 3900'. ECD after sweep = 10.6 ppg. TIH. Hole slick. Break circulation @ 4558'. Continue TIH and wash last stand to bottom. Directionally drill fl 5772' - 6068'. 550 gpm, 3400 psi, TO: 8 K on btm, 10 K off btm. PU wt = 185 K, SO wt = 105 K, ROT wt = 135 K. AST: 0.2 hrs, ART: 6.88 hrs, ADT: 6.9 hrs. Back ream every stand. Pump sweep every 200'. Intermittent Printed: 9/4/2002 10:58:35 AM ) ) Legal Well Name: V -1 04 Common Well Name: V -1 04 Spud Date: 8/14/2002 Event Name: DRILL +COMPLETE Start: 8/13/2002 End: 8/27/2002 Contractor Name: NABORS Rig Release: 8/27/2002 Rig Name: NABORS 9ES Rig Number: 9-ES Date From./fo HoUrs Task Cödé NPT Phase 8/19/2002 04:00 - 15:30 11.50 DRILL P PROD1 losses to 20 bph. Total losses 171 bbls. 15:30 - 20:00 4.50 DRILL P PROD1 Pump high vis sweep around @ 550 gpm, 3350 psi. Calc ECD = 10.54 ppg, Actual ECD = 10.97 ppg. Pump second low I high sweep around. ECD = 10.78 ppg. Bleed in wieghted mud to raise mud weight to 10.1 ppg. New Calc ECD = 10.8 ppg, actual = 10.95 ppg. 20:00 - 20:30 0.50 DRILL P PROD1 Flow check well. Well breathing. Monitor Flow back, 3 bbls 6 min, 1 bbl next 6 min, 0 bbls next 6 min. 20:30 - 21 :30 1.00 DRILL P PROD1 POOH slow. Work pipe up to 6600', Hole fill gain of 5 bbls. Pulling ok. 21 :30 - 22:30 1.00 DRILL P PROD1 Break circulation. Partial returns untill 55 bbls lost. Full returns. Shut down & monitor returns. Gain 50 bbls back. Well stabilized. 22:30 - 00:00 1.50 DRILL P PROD1 Spot 100 bbls "Steel Seal" pill fl 6650' - 5500'. Loss of 51 bbls while spotting pill. Shut down. Monitor flow. Returned 27 bbls. Well stabilized. 8/20/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Monitor well, well static. pooh from 6600 to 5835', intermittent overpulls. 20K overpull @ 5835' wI swabbing/breathing. 01 :30 - 02:30 1.00 DRILL P PROD1 Break circulation@ 5960', 41 bbls away. Circulate bottoms up @ 100 rpms, 530 gpm, 2544 psi. 02:30 - 06:30 4.00 DRILL P PROD1 POOH while back reaming. from 5960', hole taking mud @ 5890'. String in Barafiber, losses slowed. Con't back reaming to 4184'. No overpulls. Torq 5K. 06:30 - 07:00 0.50 DRILL P PROD1 Monitor well, watch flowback ( well breathing) untill well static ( 60 bbls TTL). 07:00 - 08:00 1.00 DRILL P PROD1 Con't POOH ( no pump) keeping hole full. No overpulls. 08:00 - 08:30 0.50 DRILL P PROD1 Circulate bottoms up @ 3060'. Reciprocate DP 525 gpm, 2100 psi, (no loss or gain). Pull up to shoe. Monitor well @ shoe, well static. 08:30 - 09:30 1.00 DRILL P PROD1 Cut & slip 52' of drilling line. 09:30 - 10:00 0.50 DRILL P PROD1 Service top drive, crown & blocks. 10:00 -13:30 3.50 DRILL P PROD1 Change out pump liners to 5". 13:30 - 15:30 2.00 DRILL P PROD1 RIH to 4500'. Fill pipe & break circulation. Lost 11 bbls mud & got 8 back. Con't to RIH to 6984'. Fill DP & break circulation. Stage up pumps to 600 gpm. 15:30 - 16:30 1.00 DRILL P PROD1 Circulate bottoms up & clean hole. Calc.ECD 10.54, ECD 10.72. No fill on bottom. 16:30 - 22:30 6.00 DRILL P PROD1 Con't to directionaly drill from 7078 to 7823'. Pump sweeps every 300'. ECD rose .9 over Calc value. P/U 193K, SIO 117K, rot 145K. 600 gpm, 3880 psi on btm, torq 9000 off, 10500 on. (back ream every stand) 22:30 - 23:30 1.00 DRILL P PROD1 Circulate HI-LO sweep around & lower ECD to 10.99. 23:30 - 00:00 0.50 DRILL P PROD1 Con't to directionaly drill from 7823 to 7855' as above. 8/21/2002 00:00 - 06:00 6.00 DRILL P PROD1 Directionaly drill from 7855 to 8455'. P/U 218K, SIO 114K, ROT 152K. Torq on 10K, off 8K. GPM 580, PSI ON 3400, OFF 3015. Calc ECD 10.65, ECD 10.83. 06:00 - 07:30 1.50 DRILL P PROD1 Circulate sweep, clean & condition hole. 100 RPM, 600 GPM 3015 psi. 07:30 - 09:00 1.50 DRILL P PROD1 Monitor well, dead. POOH to 7250'. Had 25k overpull @ 7550', wiped same. 09:00 - 10:00 1.00 DRILL P PROD1 Attempt to break circulation @ 7250', no good. RIH w/ 1 stand & break circulation @ 7320'. Stage up pumps (ECD 10.9), circulate bottoms up @ 100 RPM, 540 GPM, 2500 PSI. Printed: 9/4/2002 10:58:35 AM ) ) Legal Well Name: V -1 04 Common Well Name: V-104 Spud Date: 8/14/2002 Event Name: DRILL +COMPLETE Start: 8/13/2002 End: 8/27/2002 Contractor Name: NABORS Rig Release: 8/27/2002 Rig Name: NABORS 9ES Rig Number: 9-ES Date From;;.To HòUrs Task Code NPT Descriptiqr1ofQp~rations 8/21/2002 10:00 - 10:30 0.50 DRILL P PROD1 Backream from 7320 to 7077', no problems. 10:30 - 12:00 1.50 DRILL P PROD1 Con't to POOH to 4500' wI no problems. 12:00 -13:00 1.00 DRILL P PROD1 RIH from 4500 to 8380'. Had one spot @ 7900' 20K, OK. 13:00 - 16:00 3.00 DRILL P PROD1 Fill pipe, stage up pumps to 600 GPM & wash to bottom @ 8455', no fill.ECD 11.1. Pump HI-LO sweep, ECD 10.78. Spot logging pill, monitor well. Flowed back 2 bbls before well was static. Monitor well, OK. 16:00 - 17:00 1.00 DRILL P PROD1 POOH to 5750'. Pulled 25K over @ 8380',8300',8100',7980'. Worked thru tite intervals, OK. P/U 245K, S/O 120K, (NO PUMP) 17:00 - 18:00 1.00 DRILL P PROD1 M/U top drive, break circulation & stage up to 580 GPM @ 2500 PSI. Pump steel seal pill. Monitor well. Flowed back 4 bbl before well was static. 18:00 - 19:30 1.50 DRILL P PROD1 POOH to csg shoe. Monitor well, OK. Con't to POOH & stand back DP. 19:30 - 21 :30 2.00 DRILL P PROD1 POOH & stand back HWDP. Pump out BHA & UD same. 21 :30 - 22:00 0.50 EVAL P PROD1 Clean & clear rig for prior to logging ops. 22:00 - 00:00 2.00 EVAL P PROD1 PJSM. R/U logging tools, load sources & RIH to log. 8/2212002 00:00 - 01 :30 1.50 EVAL P PROD1 RIH wI logging tools to 3028', hit obstruction. Attempted to work thru same, made 42' in 1 112 hrs. 01 :30 - 03:00 1.50 EVAL N DPRB PROD1 POOH wI logging tools & RID same. 03:00 - 03:30 0.50 EVAL N DPRB PROD1 M/U porcupine hole opener, 5" HWDP & jars. 03:30 - 04:30 1.00 EVAL N DPRB PROD1 RIH to shoe @ 2895'. P/U 91K, Slo 71K, Torq 2800. 04:30 - 05:30 1.00 EVAL N DPRB PROD1 Con't RIH to 3172'. Pushing wI 5K @ 3100'. Wipe thru interval & clean up. Circulate bottoms up. 170 RPM, 580 GPM, 1780 PSi, no losses. 05:30 - 10:30 5.00 EVAL N DPRB PROD1 Con't RIH. Staging in @ 4200',5150',6200',7000' & circulate bottoms up. 580 GPM, 170 RPM. 10:30 -14:30 4.00 EVAL N DPRB PROD1 Pushing 15K @ 7842'. M/U top drive & ream to 8455'. Circulate bottoms up @ 8115'. Had 10' offill on bottom. Circulate & pump HI_La sweeps & clean hole. 610 Gpm, 3000 Psi, 165 Rpm, Torq 8400. Spot logging pill & monitor well. P/U 220K SIO 120K. 14:30 - 15:30 1.00 EVAL N DPRB PROD1 POOH. 30K overpull @ 8040'. Wipe hole. Had 70K over @ 7940'. Could not work thru. 15:30 - 19:00 3.50 EVAL N DPRB PROD1 M/U top drive. break circulation & stage up pumps. backream to 6809'. Attempted to pull wlo pump on each stand. above 6809' started to pull wlo pump. 19:00 - 20:00 1.00 EVAL N DPRB PROD1 POOH to 6700', OK. RIH to 8395" hole looked good. 20:00 - 21 :30 1.50 EVAL N DPRB PROD1 Fill pipe break circulation & pump HI-LO sweeps. 600 Gpm, 110 Rpm washed to bottom. Monitor well, OK. 21 :30 - 23:00 1.50 EVAL N DPRB PROD1 POOH wI intermitent drag 15-25K to 8100'. Pull to 6344', had 25K over, worked thru. Had 60K over @ 6080'. Could not work thru. 23:00 - 00:00 1.00 EVAL N DPRB PROD1 M/U top drive & begin backreaming. 600 GPM, 2300 Psi. 8/23/2002 00:00 - 00:30 0.50 EVAL N DPRB PROD1 Backream from 6080 to 5870'. Then POOH w/o pump. RIH to 5877'. 00:30 - 02:00 1.50 EVAL N DPRB PROD1 Circulate sweep around. spot steel seal pill. 580 Gpm, 2230 Psi. 02:00 - 03:00 1.00 EVAL N DPRB PROD1 POOH to csg shoe. No overpull or swabbing. 03:00 - 04:00 1.00 EVAL N DPRB PROD1 Circulate sweep @ shoe. 580 Gpm, 2120 Psi. Monitor well & pump dry job. 04:00 - 05:00 1.00 EVAL N DPRB PROD1 Con't POOH to HWDP. Printed: 9/4/2002 10:58:35 AM ') Legal Well Name: V-1 04 Common Well Name: V-1 04 Event Name: DRILL +COMPLETE Contractor Name: NABORS Rig Name: NABORS 9ES Hôürs 8/23/2002 05:00 - 05:30 0.50 EVAL N 05:30 - 12:00 6.50 EVAL P 12:00 - 13:00 1.00 EVAL P 13:00 - 14:30 1.50 CASE P 14:30 - 15:00 0.50 CASE P 15:00 - 16:00 1.00 CASE P 16:00 - 00:00 8.00 CASE P Phase DPRB PROD1 PROD1 PROD1 COMP COMP COMP COMP 8/24/2002 12.50 CASE P COMP 00:00 - 12:30 12:30 - 13:00 13:00 - 16:30 0.50 CEMT P 3.50 CEMT P COMP COMP 16:30 - 19:00 2.50 CEMT P COMP 19:00 - 19:30 0.50 CEMT P COMP 19:30 - 20:00 0.50 CEMT P COMP 20:00 - 21 :00 1.00 CEMT P COMP 21 :00 - 22:00 1.00 BOPSUR P COMP 22:00 - 22:30 0.50 BOPSUR P CaMP 22:30 - 00:00 1.50 BOPSURP COMP 8/25/2002 00:00 - 02:30 2.50 BOPSUR P COMP 02:30 - 09:30 7.00 EVAL P COMP 09:30 - 10:30 1.00 RUNCOrvP COMP 10:30 - 11 :30 1.00 RUNCOrvP COMP 11 :30 - 12:00 0.50 RUNCOrvP COMP 12:00 - 12:30 0.50 RUNCOrvP CaMP 12:30 - 14:30 2.00 RUNCOrvP COMP 14:30 - 16:00 1.50 RUNCOrvP COMP Start: 8/13/2002 Rig Release: 8/27/2002 Rig Number: 9-ES Spud Date: 8/14/2002 End: 8/27/2002 Description of Operations Stand back HWDP. LID 5" HWDP, Jars & Porcupine hole opener. R/U Schlumberger. M/U & load logging tools wI sources. RIH & log from csg shoe to TD. Log from TD (8455') back up to csg shoe. RID logging equip. Change out top rams for 7" csg & test same. P/U landing jt & make dummy run wi csg hanger. Change bails, R/U csg tools & Franks tool. PJSM P/U shoe track & check floats, Ok. Run 7" 26# 1-80 BTC csg. M/U torq 8000 FtLbs. Run @ 1 min/jt. Fill every jt, Circulate 5 min every 10 jts. Hole taking 10 bbl/hr. Circulate bottoms up every 30 jts. Run 7" production casing. Ran 207 jts 26#, L-80 BTC-M casing. M/U Torq 8000 ftllbs. 1 min/jt fill every jt. Break circulation every 5 jts, circ 15 min every 15 jts. Circulate bottoms up every 30 jts. Hole taking approx 10 bbl/hr most of the way in the hole; 6 bph by the last 2 hrs of running pipe. CBU @ 4288',5498',6718',7730'. Made up landing jt & land casing. set @ 8446'. RID fill up tool & M/U cementing head. Break circulation & stage up to 6 Bpm @ 620 Psi. Losing 8-12 bbls/hr lost 50 bbls total. well then stable. PJSM Test lines to 4000 Psi, Ok. Cement well as follows: Pump 35 bbls Howco Alpha spacer. Mixed & pumped 114 bbls of Prem 'G' lead cmt wi .2% CFR-3, .75% Halad 344, .05% HR-5 & 15 pps Microlite. 12.5 PPG, Yld 2.34 CuFtlSx. Tailed in wI 43 Bbls Prem "G", .4% CFR-3, 1 % Bentonite, 1 Gps L TX 2000, .36 Gps 434B, .05 Gps D-Air 3000. wt 15.8 PPG, Yld 1.16 CuFtlSx. Dropped plug & reciprocated pipe @ 1 SPM till 20 bbls fl total displacement. Displaced @ 5 Bpm wI 320 Bbls Seawater. Bumped plug to 3860 Psi, Held 5 min, OK. Bled off & float held. PD @ 1840 Hrs. Had full returns thru-out job. RID cmenting head & back out landing jt. M/U pack off. RILDS. Test to 5000 Psi, OK. RID casing tools & LID landing jt. Install 3 1/2" X 6" top rams. M/U ported sub & flush out BOP stack. Begin pressure testing BOPE. Test witnessing waived by John Spalding wI AOGCC. Con't to test BOPE. Tested all equip to LP 250 psi, HP 4000 Psi. Annular LP 250 psi, HP 3500 Psi, OK. Install wear bushing. Held PJSM. RlU & run USIT log fl 8350 to 3970'. RID logging equip. Cut & slip 712' of drilling line. Inspect & adjust brakes. Service top drive, crown & inspect & clean under drawworks. M/u bit & scraper assy. RIH. RIH wI HWDP. RIH to 4200'. Fill pipe. Con't to RIH to 8330' & scrape casing. Fill pipe & wash down to 8362'. Tag float collar. Circulate & pump HI-Vis sweep around. 600gpm, 2750 psi, 75 rpm, P/u 190k, S/o 142K. Torq 8k. Displace wellbore wI clean seawater. Printed: 9/4/2002 10:58:35 AM ) ) Legal Well Name: V -1 04 Common Well Name: V -1 04 Spud Date: 8/14/2002 Event Name: DRILL +COMPLETE Start: 8/13/2002 End: 8/27/2002 Contractor Name: NABORS Rig Release: 8/27/2002 Rig Name: NABORS 9ES Rig Number: 9-ES Datè From-To . Hours 8/25/2002 16:00 - 17:00 1.00 RUNCOI'vP COMP Pressure test casing to 4000 psi for 30 min, OK. Chart same. 17:00 - 17:30 0.50 RUNCOI'vP COMP Conduct well kill drill w/ rig supervisor. 17:30 - 21 :00 3.50 RUNCOI'vP COMP POOH & stand back HWDP + 25 stands od DP. Con't POOH & LID excess DP. 21 :00 - 21 :30 0.50 RUNCOI'vP CaMP Stand back HWDP. LID bit & scraper. 21 :30 - 22:00 0.50 RUNCOI'vP CaMP Pull wear bushing. Make dummy run wI landing jt & tbg hanger. 22:00 - 22:30 0.50 RUNCOI'vP COMP Change out bails. 22:30 - 00:00 1.50 RUNCOI'vP CaMP R/U tbg tools & prepare to run 4 1/2" tbg string. 8/26/2002 00:00 - 12:30 12.50 RUNCOI'vP CaMP PJSM RIH w/4 1/2" 12.6# 1-80 TCII tbg & jewelry as per plan. Ran 190 jts. M/U torq 2800 Ft/Lbs. P/U 125K, S/O 85K. Simultaneous operation: Performed injectivity test on 9 5/8 x 7 annulus. EMW 14.9 ppg. Injected 100 bblas 10.1 ppg mud, 2 bpm @ 680 psi. 12:30 - 13:30 1.00 RUNCOI'vP COMP Mlu tbg hanger on landing jt. RIH & check tbg landing. Verify same, OK. R/U head pin, circulating lines & P/U hanger above floor level. 13:30 - 15:30 2.00 RUNCOI'vP COMP Reverse circulate clean brine wI corrosion inhibitor. 3 Bpm @ 300 Psi. 15:30 -16:00 0.50 RUNCOI'vP CaMP Land tbg hanger & RILDS. Drop ball/rod. LID landing jt. 16:00 - 18:00 2.00 RUNCOI'vP CaMP Pressure up on tbg to 4000 PSi & set packer. Test tbg to 4000 Psi for 30 min, OK. Bleed down to 2500 Psi & pressure up on annulus to to 4000 Psi & test same for 30 min, OK. Bleed down both sides & pressure up on annulus to 2500 Psi & shear RP valve. 18:00 - 18:30 0.50 RUNCOI'vP CaMP Install TWC & test from below to 2800 Psi, OK. 18:30 - 20:00 1.50 RUNCOI'vP CaMP N/D BOPE. 20:00 - 21 :30 1.50 WHSUR P COMP N/U adapter flange & X-mas tree. Test adapter seal to 5000 Psi, OK. Test tree to 5000 Psi, OK. 21 :30 - 22:00 0.50 WHSUR P CaMP R/U DSM & pull TWC. 22:00 - 00:00 2.00 WHSUR P COMP RlU circulaing lines & test to 3000 Psi. Pump 135 bbl diesel & freeze protect well. 2.5 Bpm @ 1600 Psi. 8/27/2002 00:00 - 01 :00 1.00 WHSUR CaMP U-Tube diesel freeze protection fluid from annulus to tbg. 01 :00 - 02:00 1.00 WHSUR COMP RID circulating lines. Install BPV. test from below to 1000 psi, OK. Remove secondary annular valve. RID Little Red & DSM. 02:00 - 03:00 1.00 RIGD COMP secure well & Clean cellar. break down all remaining lines. & suck out pits. ...RELEASE RIG @ 0300 HRS 8/27/02... Printed: 9/4/2002 10:58:35 AM ) Well: Field: API: Permit: V -1 04 Prudhoe Bay Unit 50-029-23103-00 202-142 Rig Accept: 08/14/02 Rig Spud: 08/14/02 Rig Release: 08/27/02 Drilling Rig: Nabors 9ES POST RIG WORK 09/16/02 PULL BALL AND ROD FROM RHC @ 7726' SLM. 09/17/02 PULLED RP GLV FROM STA. # 1 AND DGLV'S FROM STA. # 2 & 3. INSTALL NEW GLV DESIGN. DRIFT WI 3-3/8" D-GUN TO 8360' MD CORR. SET 1" DOME (16/64 PORT, 1805# TRO) BK LATCH IN STA-3 @ 4026' MD. SET 1" DOME (16/64 PORT, 1802# TRO) BK LATCH IN STA-2 @ 5318' MD. SET 1" ORIFICE (20/64 PORT) BK LATCH IN STA-1 @ 7611' MD. WELL LEFT SI. 09/18/02 RAN JEWELRY LOG FROM 8662' (TD) TO 7480' AT 60 FPM. 09/19/02 PERFORATED INTERVALS: 7952'-7956', 7936'-7942' & 7879'-7929' IN THREE GUN RUNS. USED 3-3/8" HSD GUNS, PJ3406 POWERJET HMX CHARGES, 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. JOB COMPLETE. 09/23/02 TAGGED TD AT 8362 FT MD. LUB = 11.7 PSI @ 35.7 DEGF (WELL ON A VACUUM). 8105 FT MD (6700 SS) = 2626.7 PSI @ 157.2 DEGF 17990 FT MD (6600 SS) = 2583.0 @ 155.4 DEGF 17875 FT MD (6500 SS) = 2539.4 PSI @ 153 DEGF 12ND STOP AT 7990 FT MD (6600 SS) = 2581.9 PSI @ 155.4 DEGF. LEFT WELL SHUT IN. SSV SHUT IN ALSO. INFORMED PAD OPERATOR. ANADRILL SCHLUMBERGER Survey report Client............. ......: BP Exploration (Alaska) Inc. Field......... ...........: Prudhoe Bay Field / Borealis Well. . . . . . . . . . . . . . . . . . . . .: V-104i API number..... ... .......: 50-029-23103-00 Engineer.. ...............: St. Amour COUNTY:.......... ........: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum... .......: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 54.84 ft KB above permanent.......: 82.30 ft DF above permanent.......: 82.30 ft ----- Vertical section origin---------------- Latitude (+N/S-}... ......: 0.00 ft Departure (+E/W-).. ......: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.32797956 ft Departure (+E/W-)........: W 149.26617789 ft Azimuth from rotary table to target: 309.44 degrees [(c)2002 Anadrill IDEAL ID6_1C_10J 21-Aug-2002 07:57:21 Spud date................: Last survey date...... ...: Total accepted surveys...: MD of first survey.......: MD of last survey...... ..: Page 1 of 5 14-Aug-02 21-Aug-02 91 0.00 ft 8455.00 ft '---J ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date......... ...: 14-Aug-2002 Magnetic field strength..: 1149.61 HCNT Magnetic dec (+E/W-).. ...: 25.96 degrees Magnetic dip.. ........ ...: 80.76 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H. . . . . . . . . . . . . . : Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.61 HCNT 80.76 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees '.~ ----- Corrections --------------------------- Magnetic dec (+E/W-) ... ..: 25.84 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).. ..: 25.84 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 21-Aug-2002 07:57:21 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool: # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual! (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type; -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ¡ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 200.21 0.46 343.42 200.21 200.21 0.67 0.77 -0.23 0.80 343.42 0.23 MWD_IFR_MSA 3 294.35 0.57 325.75 94.14 294.34 1.43 1.52 -0.60 1.63 338.43 0.20 MWD_IFR_MSA 4 385.64 0.69 290.67 91.29 385.63 2.39 2.09 -1.37 2.50 326.73 0.43 MWD_IFR_MSA 5 479.40 0.92 255.72 93.76 479.38 3.37 2.10 -2.63 3.37 308.66 0.57 MWD_IFR_MSA 6 572.24 1.29 269.39 92.84 572.20 4.61 1.91 -4.40 4.79 293.46 0.49 MWD_IFR_MSA 7 663.72 1.74 270.93 91.48 663.65 6.48 1.92 -6.81 7.08 285.73 0.49 MWD_IFR_MSA 8 755.95 2.37 275.42 92.23 755.82 9.16 2.12 -10.11 10.33 281.85 0.70 MWD_IFR_MSA 9 847.21 2.97 281.36 91.26 846.98 12.81 2.77 -14.31 14.57 280.94 0.72 MWD_IFR_MSA 10 941.46 3.04 281.55 94.25 941.10 17.17 3.75 -19.15 19.51 281.07 0.08 MWD_IFR_MSA 11 1034.50 4.30 300.42 93.04 1033.95 22.80 6.01 -24.58 25.30 283.74 1.86 MWD_IFR_MSA 12 1127.86 5.88 314.16 93.36 1126.94 31.02 11.11 -31.03 32.96 289.70 2.13 MWD_IFR_MSA 13 1221.62 9.06 329.14 93.76 1219.91 42.76 20.80 -38.26 43.55 298.53 3.95 MWD_IFR_MSA 14 1313.60 11.83 333.19 91.98 1310.35 58.21 35.43 -46.23 58.25 307.47 3.11 MWD_IFR_MSA 15 1406.45 13.43 330.92 92.85 1400.95 76.96 53.35 -55.76 77.17 313.73 1.80 MWD_IFR_MSA 16 1499.53 17.07 326.84 93.08 1490.74 100.06 74.24 -68.49 101.01 317.31 4.07 MWD_IFR_MSA 17 1593.60 22.06 322.35 94.07 1579.36 130.48 99.80 -86.85 132.30 318.97 5.54 MWD_IFR_MSA 18 1686.43 23.25 321.01 92.83 1665.03 165.42 127.85 -109.03 168.02 319.54 1.40 MWD_IFR_MSA 19 1779.11 25.91 315.65 92.68 1749.31 203.48 156.56 -134.70 206.53 319.29 3.74 MWD_IFR_MSA 20 1872.94 28.25 314.13 93.83 1832.85 246.00 186.68 -164.97 249.13 318.53 2.60 MWD_IFR_MSA '~ 21 1965.66 33.38 311.63 92.72 1912.46 293.39 218.93 -199.81 296.40 317.61 5.70 MWD_IFR_MSA 22 2058.39 37.18 309.53 92.73 1988.14 346.92 253.72 -240.51 349.60 316.53 4.30 MWD_IFR_MSA 23 2152.40 39.24 306.71 94.01 2062.01 405.04 289.58 -286.26 407.19 315.33 2.87 MWD_IFR_MSA 24 2245.22 40.81 299.27 92.82 2133.13 464.26 321.98 -336.29 465.58 313.76 5.42 MWD_IFR_MSA 25 2339.02 40.54 294.69 93.80 2204.29 523.92 349.71 -390.73 524.37 311.83 3.19 MWD_IFR_MSA 26 2432.72 39.75 296.47 93.70 2275.92 582.56 375.78 -445.22 582.61 310.17 1.49 MWD_IFR_MSA 27 2526.51 40.33 299.80 93.79 2347.73 641.71 404.23 -498.41 641.73 309.04 2.37 MWD_IFR_MSA 28 2620.04 40.31 301.33 93.53 2419.04 701.50 435.01 -550.52 701.64 308.32 1.06 MWD_IFR_MSA 29 2713.26 39.88 300.48 93.22 2490.35 760.88 465.84 -602.03 761.22 307.73 0.75 MWD_IFR_MSA 30 2806.47 39.53 300.39 93.21 2562.06 819.69 496.01 -653.37 820.31 307.20 0.38 MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report 21-Aug-2002 07:57:21 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- =====:¡= -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool: # depth angle angle length depth section +N/S- +E/W- displ Azirn (deg/ tool qual; (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type typej --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ====::;::!:: -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 2899.50 39.52 300.12 93.03 2633.82 878.14 525.84 -704.51 879.11 306.74 0.19 MWD- IFR_MSA 32 2939.77 39.25 300.12 40.27 2664.95 903.35 538.66 -726.61 904.50 306.55 0.67 MWD- IFR_MSA 33 3086.46 38.18 300.35 146.69 2779.40 993.91 584.86 -805.88 995.74 305.97 0.74 MWD _IFR_MSA 34 3180.40 39.17 299.90 93.94 2852.74 1051.84 614.32 -856.65 1054.15 305.64 1.10 MWD_IFR_MSA 35 3273.34 40.23 300.51 92.94 2924.25 1110.44 644.19 -907.96 1113.27 305.36 1.22 MWD_IFR_MSA I 3366.52 39.85 301.03 93.18 2995.59 1169.70 674.85 -959.46 1173.03 305.12 0.54 ~ 36 MWD_IFR_MSA 37 3460.34 39.65 301.07 93.82 3067.72 1229.05 705.80 -1010.86 1232.88 304.92 0.21 MWD_IFR_MSA 38 3552.49 39.20 301.43 92.15 3138.90 1286.97 736.16 -1060.89 1291.28 304.76 0.55 MWD_IFR_MSA 39 3646.50 39.05 301.12 94.01 3211.83 1345.69 766.95 -1111.59 1350.50 304.60 0.26 MWD_IFR_MSA 40 3739.70 38.51 301.72 93.20 3284.49 1403.49 797.38 -1161.41 1408.79 304.47 0.71 MWD_IFR_MSA 41 3833.08 39.29 301.11 93.38 3357.16 1461.56 827.94 -1211.45 1467.34 304.35 0.93 MWD_IFR_MSA 42 3925.86 39.33 301.74 92.78 3428.94 1519.76 858.59 -1261.61 1526.05 304.24 0.43 MWD_IFR_MSA 43 4017.48 39.05 302.40 91.62 3499.95 1577.18 889.33 -1310.67 1583.90 304.16 0.55 MWD_IFR_MSA 44 4111.22 38.20 302.30 93.74 3573.19 1635.24 920.64 -1360.10 1642.39 304.09 0.91 MWD- IFR_MSA 45 4204.72 37.92 301.44 93.50 3646.81 1692.38 951.07 -1409.05 1699.99 304.02 0.64 MWD_IFR_MSA 46 4299.12 38.71 300.95 94.40 3720.87 1750.30 981.38 -1459.11 1758.44 303.92 0.90 MWD_IFR_MSA 47 4392.50 39.51 300.73 93.38 3793.33 1808.54 1011.58 -1509.69 1817.26 303.82 0.87 MWD_IFR_MSA 48 4485.97 39.55 300.54 93.47 3865.42 1867.33 1041.89 -1560.88 1876.67 303.72 0.14 MWD_IFR_MSA 49 4579.11 39.44 300.02 93.14 3937.30 1925.82 1071.76 -1612.03 1935.80 303.62 0.37 MWD _IFR_MSA 50 4673.33 39.35 300.02 94.22 4010.11 1984.81 1101.68 -1663.81 1995.48 303.51 0.10 MWD_IFR_MSA '~ 51 4767.03 39.83 300.79 93.70 4082.32 2043.78 1131.90 -1715.31 2055.11 303.42 0.73 MWD - IFR_MSA 52 4861.53 40.15 300.08 94.50 4154.72 2103.76 1162.67 -1767.67 2115.76 303.33 0.59 MWD _IFR_MSA 53 4954.75 40.09 299.16 93.22 4226.01 2162.95 1192.35 -1819.89 2175.71 303.23 0.64 MWD_IFR_MSA 54 5047.56 39.81 302.13 92.81 4297.16 2221.83 1222.72 -1871.15 2235.23 303.16 2.08 MWD_IFR_MSA 55 5140.71 40.29 304.39 93.15 4368.47 2281.41 1255.59 -1921.26 2295.16 303.17 1.64 MWD_IFR_MSA 56 5233.60 40.08 307.11 92.89 4439.44 2341.21 1290.60 -1969.90 2355.02 303.23 1.90 MWD_IFR_MSA 57 5326.65 40.10 310.61 93.05 4510.63 2401.11 1328.19 -2016.54 2414.65 303.37 2.42 MWD_IFR_MSA 58 5421.19 39.43 312.77 94.54 4583.31 2461.53 1368.39 -2061.70 2474.49 303.57 1.62 MWD_IFR_MSA 59 5513.86 39.03 313.16 92.67 4655.09 2520.03 1408.34 -2104.59 2532.33 303.79 0.51 MWD_IFR_MSA 60 5606.85 38.89 315.89 92.99 4727.40 2578.25 1449.33 -2146.26 2589.79 304.03 1.85 MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report 21-Aug-2002 07:57:21 Page 4 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool' # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual! (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type! --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- =====::!: -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 5699.76 39.25 316.90 92.91 4799.54 2636.38 1491.73 -2186.65 2647.02 304.30 0.79 MWD_IFR_MSA 62 5790.92 38.74 316.54 91.16 4870.39 2693.28 1533.49 -2225.97 2703.06 304.56 0.61 MWD_IFR_MSA 63 5885.46 38.51 316.68 94.54 4944.25 2751.83 1576.38 -2266.51 2760.81 304.82 0.26 MWD_IFR_MSA 64 5977.78 38.29 316.90 92.32 5016.60 2808.70 1618.17 -2305.78 2816.93 305.06 0.28 MWD_IFR_MSA 65 6071.56 38.02 316.90 93.78 5090.34 2866.15 1660.47 -2345.36 2873.66 305.30 0.29 MWD_IFR_MSA '~' 66 6164.80 38.00 314.19 93.24 5163.81 2923.23 1701.45 -2385.57 2930.16 305.50 1.79 MWD_IFR_MSA 67 6258.18 38.08 313.79 93.38 5237.35 2980.59 1741.42 -2426.96 2987.09 305.66 0.28 MWD_IFR_MSA 68 6351.67 37.73 314.04 93.49 5311.12 3037.85 1781.25 -2468.34 3043.94 305.82 0.41 MWD_IFR_MSA 69 6444.81 37.00 314.64 93.14 5385.15 3094.17 1820.76 -2508.77 3099.85 305.97 0.88 MWD_IFR_MSA 70 6538.43 36.04 313.73 93.62 5460.38 3149.69 1859.59 -2548.72 3155.00 306.12 1.18 MWD_IFR_MSA 71 6633.15 35.48 313.78 94.72 5537.25 3204.89 1897.87 -2588.70 3209.87 306.25 0.59 MWD_IFR_MSA 72 6726.02 35.06 313.24 92.87 5613.07 3258.38 1934.79 -2627.59 3263.07 306.37 0.56 MWD_IFR_MSA 73 6818.64 34.42 312.95 92.62 5689.18 3311.05 1970.85 -2666.13 3315.49 306.47 0.71 MWD_IFR_MSA 74 6911.61 32.81 313.23 92.97 5766.60 3362.41 2006.01 -2703.72 3366.62 306.57 1.74 MWD_IFR_MSA 75 7005.35 31.00 313.00 93.74 5846.17 3411.85 2039.87 -2739.88 3415.85 306.67 1.94 MWD_IFR_MSA 76 7099.24 29.97 312.32 93.89 5927.08 3459.40 2072.15 -2774.90 3463.22 306.75 1.16 MWD_IFR_MSA 77 7191.69 31.24 312.60 92.45 6006.65 3506.41 2103.93 -2809.62 3510.06 306.83 1.38 MWD_IFR_MSA 78 7285.29 32.34 313.24 93.60 6086.21 3555.62 2137.51 -2845.73 3559.09 306.91 1.23 MWD_IFR_MSA 79 7378.45 33.07 313.15 93.16 6164.60 3605.85 2171.96 -2882.43 3609.13 307.00 0.79 MWD_IFR_MSA 80 7469.96 34.13 313.92 91.51 6240.82 3656.36 2206.84 -2919.13 3659.44 307.09 1.25 MWD_IFR_MSA '~' 81 7562.90 34.81 316.10 92.94 6317.45 3708.70 2244.04 -2956.31 3711.54 307.20 1.52 MWD_IFR_MSA 82 7656.39 33.58 317.75 93.49 6394.77 3760.79 2282.41 -2992.20 3763.33 307.34 1.65 MWD_IFR_MSA 83 7750.21 31.00 316.88 93.82 6474.08 3810.43 2319.26 -3026.16 3812.69 307.47 2.79 MWD_IFR_MSA 84 7842.95 29.45 318.36 92.74 6554.21 3856.64 2353.73 -3057.64 3858.66 307.59 1.85 MWD_IFR_MSA 85 7936.10 29.28 317.58 93.15 6635.39 3901.81 2387.66 -3088.22 3903.59 307.71 0.45 MWD_IFR_MSA 86 8029.68 30.01 316.38 93.58 6716.72 3947.70 2421.50 -3119.80 3949.28 307.82 1.01 MWD_IFR_MSA 87 8123.85 29.91 316.54 94.17 6798.31 3994.37 2455.59 -3152.20 3995.78 307.92 0.14 MWD_IFR_MSA 88 8217.48 28.95 316.99 93.63 6879.86 4040.00 2489.10 -3183.71 4041.25 308.02 1.05 MWD_IFR_MSA 89 8310.09 27.92 317.12 92.61 6961.29 4083.71 2521.38 -3213.76 4084.80 308.12 1.11 MWD_IFR_MSA 90 8385.18 27.01 317.79 75.09 7027.92 4118.00 2546.89 -3237.18 4118.98 308.19 1.28 MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report 21-Aug-2002 07:57:21 Page --- -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At # depth angle angle length depth section +N/S- +E/W- displ Azim (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) --- -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Projected to TD 91 8455.00 69.82 7090.12 4149.38 2570.38 -3258.48 4150.25 308.27 27.01 317.79 [(c)2002 Anadrill IDEAL ID6_1C_1OJ 5 of 5 ----- DLS (deg/ lOOf) 0.00 Srvy tool type ----- Projected , ------ ------ Tool qual type ------ ------ '~' ~ V -1 04 Survey Report - Geodetic Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: bp Report Date: 21-Aug-02 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA (Drill Pads) Structure I Slot: V-Pad I V-104 Well: V-104 Borehole: V-104 UWUAPI#: 500292310300 Survey Name I Date: V-1041 August 21,2002 Tort I AHD I DDII ERD ratio: 110.589° 14193.03 ft/5.7431 0.591 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Location LatILong: N 70 1940.726, W 14915 58.24C Location Grid NIE YIX: N 5970073.730 ftUS, E 590482.650 ftUS Grid Convergence Angle: +0.69099691 ° Grid Scale Factor: 0.99990930 Station ID MD Incl Azim TVD VSec N/.S (ft) (°) (°) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 200.21 0.46 343.42 200.21 0.66 0.77 294.35 0.57 325.75 294.34 1.41 1.52 385.64 0.69 290.67 385.63 2.37 2.09 479.40 0.92 255.72 479.38 3.37 2.10 572.24 1.29 269.39 572.20 4.63 1.91 663.72 1.74 270.93 663.65 6.54 1.92 755.95 2.37 275.42 755.82 9.25 2.12 847.21 2.97 281.36 846.98 12.95 2.77 941.46 3.04 281.55 941.1 0 17.36 3.75 1034.50 4.30 300.42 1033.95 23.02 6.01 1127.86 5.88 314.16 1126.94 31.24 11.11 1221 .62 9.06 329.14 1219.91 42.92 20.80 1313.60 11.83 333.19 1310.35 58.24 35.43 1406.45 13.43 330.92 1400.95 76.82 53.35 1499.53 17.07 326.84 1490.74 99.76 74.24 1593.60 22.06 322.35 1579.36 130.00 99.80 1686.43 23.25 321.01 1665.03 164.78 127.85 V-104 ASP Final Surveys.xls Page 1 of 4 Minimum Curvature 1 Lubinski 308.270° N 0.000 ft, E 0.000 1t KB 82.300 ft relative to MSL 55.000 ft relative to MSL +25.839° 57503.353 nT 80.768° August 19,2002 BGGM 2002 True North +25.839° Well Head Schlumber. ¡ \,,-,,/ Grid Coordinates Geographic Coordinates EI-W DLS Northing Easting Latitude Longitude (ft) (0/100ft) (ftUS) (ftUS) 0.00 5970073.73 590482.65 N 70 1940.726 W 1491558.240 -0.23 0.23 5970074.50 590482.41 N 701940.734 W 149 1558.247 -0.60 0.20 5970075.24 590482.03 N 70 1940.741 W 149 1558.258 -1.37 0.43 5970075.80 590481.25 N 70 1940.747 W 1491558.280 -2.63 0.57 5970075.80 590480.00 N 70 1940.747 W 1491558.317 -4.40 0.49 5970075.58 590478.23 N 70 1940.745 W 149 1558.369 -6.81 0.49 5970075.57 590475.81 N 70 1940.745 W 149 1558.439 -10.11 0.70 5970075.73 590472.51 N 701940.747 W 149 1558.53 , -14.31 0.72 5970076.32 590468.31 N 701940.754 W 149 15 58.65~ I -19.15 0.08 5970077.25 590463.46 N 70 1940.763 W 1491558.799 . ! -24.58 1.86 5970079.44 590458.00 N 70 1940.786 W 1491558.958 -31.03 2.13 5970084.47 590451.49 N 701940.836 W 149 1559.146 -38.26 3.95 5970094.06 590444.14 N 70 1940.931 W 1491559.$57 5970108.60 I -46.23 3.11 590436.00 N 70 1941.075 W 1491559'990 -55.76 1.80 5970126.40 590426.25 N 70 1941.251 W 149 1559.868 ! -68.49 4.07 5970147.13 590413.27 N 701941.457 W 149 16 0.~40 -86.85 5.54 5970172.47 590394.61 N 70 1941.708 W 149 16 0.~76 -109.03 1.40 5970200.24 590372.10 N 701941.984 W 149 16 1.423 i I i 8/29/2002-1 :40 PM: Grid Coordinates Geographic Coordinates Station 10 MO Incl Azim TVO VSec NI.S E/.W OLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) ("/1 OOft) (ftUS) (ftUS) ... 1779.11 25.91 315.65 1749.31 202.72 156.56 -134.70 3.74 5970228.64 590346.09 N 70 19 42.266 W 149162.173 1872.94 28.25 314.13 1832.85 245.14 186.68 -164.97 2.60 5970258.39 590315.45 N 70 19 42.562 W 149 163.057 1965.66 33.38 311.63 1912.46 292.47 218.93 -199.81 5.70 5970290.21 590280.23 N 70 19 42.880 I W 149 164.974 2058.39 37.18 309.53 1988.15 345.97 253.72 -240.51 4.30 5970324.51 590239.12 N 70 19 43.222 W 149 165.262 2152.40 39.24 306.71 2062.02 404.10 289.58 -286.26 2.87 5970359.81 590192.94 N 70 1943.574 W 149 166.597 2245.22 40.81 299.27 2133.13 463.44 321.98 -336.29 5.42 5970391.60 590142.54 N 70 19 43.893 W 149 168.058 2339.02 40.54 294.69 2204.29 523.36 349.71 -390.73 3.19 5970418.67 590087.76 N 70 1944.166 W 149 169.648 I i 2432.72 39.75 296.47 2275.92 582.29 375.78 -445.22 1.49 5970444.08 590032.97 N 70 19 44.422 W 149 16 11 .238 2526.51 40.33 299.80 2347.73 641.67 404.23 -498.41 2.37 5970471.89 589979.45 N 70 1944.702 W 149 1612.t91 .j 2620.04 40.31 301.33 2419.04 701.64 435.01 -550.52 1.06 5970502.03 589926.98 N 70 1945.004 W 149 1614.312 ~ 2713.26 39.88 300.48 2490.35 761.18 465.84 -602.03 0.75 5970532.24 589875.10 N 701945.308 W 149 16 15.~16 2806.47 39.53 300.39 2562.06 820.17 496.01 -653.37 0.38 5970561.78 589823.41 N 701945.604 W 1491617.315 2899.50 39.52 300.12 2633.82 878.80 525.84 -704.51 0.19 5970590.99 589771.92 N 70 1945.898 W 1491618.808 2939.77 39.25 300.12 2664.95 904.09 538.66 -726.61 0.67 5970603.54 589749.66 N 701946.024 W 149 1619.454 3086.46 38.18 300.35 2779.40 994.94 584.86 -805.88 0.74 5970648.77 589669.85 N 701946.478 W 1491621.768 3180.40 39.17 299.90 2852.74 1053.05 614.32 -856.65 1.10 5970677.62 589618.73 N 701946.768 W 149 1623.250 3273.34 40.23 300.51 2924.25 1111.83 644.19 -907.96 1.22 5970706.86 589567.08 N 701947.061 W 1491624.748 3366.52 39.85 . 301.03 2995.59 1171.26 674.85 -959.46 0.54 5970736.90 589515.21 N 70 1947.363 W 149 1626.252 3460.34 39.65 301.07 3067.72 1230.77 705.80 -1010.86 0.21 5970767.22 589463.45 N 701947.667 W 14916 27.t53 3552.49 39.20 301.43 3138.90 1288.86 736.16 -1060.89 0.55 5970796.97 589413.06 N 701947.966 W 149 16 29.?14 3646.50 39.05 301.12 3211.83 1347.74 766.95 -1111.59 0.26 5970827.15 589361.99 N 70 19 48.269 W 149 16 30.6>94 3739.70 38.51 301.72 3284.49 1405.69 797.38 -1161.41 0.71 5970856.97 589311.82 N 701948.568 W 1491632.149 3833.08 39.29 301.11 3357.16 1463.91 827.94 -1211.45 0.93 5970886.93 589261.42 N 701948.868 W 149 16 33.é10 3925.86 39.33 301.74 3428.95 1522.27 858.59 -1261.61 0.43 5970916.96 589210.90 N 701949.170 W 1491635.074 4017.48 39.05 302.40 3499.96 1579.82 889.33 -1310.67 0.55 5970947.10 589161.48 I N 701949.472 W 149 16 36.$07 \~ 4111 .22 38.20 302.30 3573.19 1638.03 920.64 -1360.10 0.91 5970977.81 589111.68 N 70 1949.780 W 149 1637.950 4204.72 37.92 301.44 3646.81 1695.31 951.07 -1409.05 0.64 5971007.65 589062.37 N 701950.079 W 149 1639.380 ; 4299.12 38.71 300.95 3720.88 1753.39 981.38 -1459.11 0.90 5971037.36 589011.95 N 70 1950.377 W 149 1640.841 4392.50 39.51 300.73 3793.33 1811.80 1011.58 -1509.69 0.87 5971066.94 588961.01 N 701950.674 W 1491642.$18 4485.97 39.55 300.54 3865.42 1870.76 1041.89 -1560.88 0.14 5971096.63 588909.47 N 701950.972 W 149 1643.813 4579.11 39.44 300.02 3937.30 1929.42 1071.76 -1612.03 0.37 5~71125.88 588857.96 N 701951.265 W 1491645.$07 4673.33 39.35 300.02 4010.11 1988.60 1101.68 -1663.81 0.10 5971155.16 588805.83 N 701951.560 W 149 1646.819 4767.03 39.83 300.79 4082.32 2047.75 1131.90 -1715.31 0.73 5971184.76 588753.98 N 70 1951.857 W 149 1648.322 4861 .53 40.15 300.08 4154.72 2107.92 1162.67 -1767.67 0.59 5971214.89 588701 .25 N 70 1952.159 W 149 1649.851 4954.75 40.09 299.16 4226.01 2167.30 1192.35 -1819.89 0.64 5971243.94 588648.68 N 70 1952.451 W 149 1651.376 V-104 ASP Final Surveys.xls Page 2 of 4 8/29/2002-1 :40 PM. Grid Coordinates Geographic Coordinates Station ID MD Incl Azlm TVD vSec N/.S E/.W DLS Northing Easting Latitude Longitude ¡ (ft) (°) (") (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) \ ! 5047.56 39.81 302.13 4297.16 2226.36 1222.72 -1871.15 2.08 5971273.68 588597.06 N 701952.749 W 1491652.873 5140.71 40.29 304.39 4368.47 2286.06 1255.59 -1921.26 1.64 5971305.95 588546.57 N 70 19 53.073 W 149 16 54.337 5233.60 40.08 307.11 4439.44 2345.92 1290.60 -1969.90 1.90 5971340.36 588497.52 N 701953.417 W 149 1655.757 5326.65 40.10 310.61 4510.64 2405.82 1328.19 -2016.54 2.42 5971377.38 588450.43 N 701953.786 W 1491657.119 5421.19 39.43 312.77 4583.31 2466.18 1368.39 -2061.70 1.62 5971417.04 588404.79 N 701954.182 W 1491658.438 5513.86 39.03 313.16 4655.09 2524.59 1408.34 -2104.59 0.51 5971456.46 588361.43 N 701954.574 W 149 1659.691 5606.85 38.89 315.89 4727.41 2582.70 1449.33 -2146.26 1.85 5971496.94 588319.26 N 70 19 54.977 W 149 170.908 5699.76 39.25 316.90 4799.54 2640.67 1491.73 -2186.65 0.79 5971538.85 588278.38 N 70 19 55.394 W 149 172.087 5790.92 38.74 316.54 4870.39 2697.41 1533.49 -2225.97 0.61 5971580.13 588238.55 N 701955.805 W 149 17 3.23f 5885.46 38.51 316.68 4944.25 2755.80 1576.38 -2266.51 0.26 5971622.51 588197.50 N 70 19 56.227 W 149 17 4.42L~ 5977.78 38.29 316.90 5016.60 2812.51 1618.17 -2305.78 0.28 5971663.83 588157.74 N 70 19 56.637 W 149 175.567 6071 .56 38.02 316.90 5090.34 2869.79 1660.48 -2345.36 0.29 5971705.65 588117.65 N 70 19 57.053 W 149 176.723 6164.80 38.00 314.19 5163.81 2926.73 1701 .45 -2385.57 1.79 5971746.13 588076.96 N 701957.456 W 149177.897 6258.18 38.08 313.79 5237.36 2983.99 1741.42 -2426.96 0.28 5971785.59 588035.09 N 701957.849 W 149179.107 6351.67 37.73 314.04 5311 .12 3041.15 1781.25 -2468.34 0.41 5971824.92 587993.24 N 701958.241 W 1491710.$15 6444.81 37.00 314.64 5385.15 3097.35 1820.76 -2508.77 0.88 5971863.93 587952.34 N 701958.629 W 149 17 11.496 6538.43 36.04 313.73 5460.39 3152.77 1859.59 -2548.72 1.18 5971902.28 587911.93 N 70 1959.011 W 149 17 12.~63 I 6633.15 35.48 313.78 5537.25 3207.87 1897.87 -2588.70 0.59 5971940.07 587871.50 N 70 1959.387 W 149 17 13.831 6726.02 35.06 313.24 5613.07 3261.27 1934.79 -2627.59 0.56 5971976.52 587832.17 N 701959.750 W 149 17 14.~67 6818.64 34.42 312.95 5689.18 3313.86 1970.85 -2666.13 0.71 5972012.11 587793.20 N 70 20 0.105 W 149 1716.<D92 6911.61 32.81 313.23 5766.60 3365.15 2006.01 -2703.72 1.74 5972046.80 587755.19 N 70 20 0.451 W 1491717.190 7005.35 31.00 313.00 5846.18 3414.51 2039.87 -2739.88 1.94 5972080.22 587718.63 N 70200.783 W 149 1718.*47 7099.24 29.97 312.32 5927.09 3462.00 2072.15 -2774.90 1.16 5972112.08 587683.22 N 70 20 1.101 W 149 17 19.270 7191.69 31.24 312.60 6006.66 3508.94 2103.93 -2809.62 1.38 5972143.43 587648.12 N 70 201.413 W 1491720.284 7285.29 32.34 313.24 6086.21 3558.09 2137.51 -2845.73 1.23 5972176.57 587611.62 N 70 201.743 W 149 1721.33' 7378.45 33.07 313.15 6164.60 3608.24 2171.96 -2882.43 0.79 5972210.57 587574.51 N 70 20 2.082 W 149 17 22.41 t-"" 7469.96 34.13 313.92 6240.82 3658.66 2206.84 -2919.13 1.25 5972245.01 587537.39 N 70 20 2.425 W 149 17 23.483 7562.90 34.81 316.10 6317.45 3710.89 2244.05 -2956.31 1.52 5972281.75 587499.77 N 70 20 2.791 W 149 1724.569 7656.39 33.58 317.75 6394.78 3762.83 2282.41 -2992.20 1.65 5972319.68 587463.42 N 70203.168 W 1491725.617 7750.21 31.00 316.88 6474.08 3812.32 2319.26 -3026.16 2.79 5972356.12 587429.02 N 70203.530 W 149 1726.910 7842.95 29.45 318.36 6554.21 3858.38 2353.73 -3057.64 1.85 5972390.20 587397.13 N 70203.869 W 149 1727,929 7936.10 29.28 317.58 6635.39 3903.41 2387.66 -3088.22 0.45 5972423.76 587366.15 N 70 20 4.203 W 149 17 28.423 i 8029.68 30.01 316.38 6716.73 3949.16 2421.50 -3119.80 1.01 5972457.21 587334.16 N 70 20 4.535 W 149 1729.345 8123.85 29.91 316.54 6798.31 3995.71 2455.59 -3152.20 0.14 5972490.90 587301.36 N 70 20 4.870 W 149 17 30.292 8217.48 28.95 316.99 6879.86 4041.21 2489.10 -3183.71 1.05 5972524.03 587269.45 N 70 20 5.200 W 1491731.213 I I i V-104 ASP Final Surveys. xis Page 3 of 4 8/29/2002-1 :40 PM i J Grid Coordinates Geographic Coordinates Station 10 MO Incl Azlm TVO VSec NI-S E/-W DLS Northing Easting Latitude Longitude ¡ (ft) (") (°) (ft) (ft) (ft) (ft) ("¡100ft) (ftUS) (ftUS) 8310.09 27.92 317.12 6961.30 4084.79 2521.38 -3213.76 1.11 5972555.94 587239.02 N 70205.517 W 149 1732.090 7027.92 4118.97 1.28 5972581.17 587215.30 J 8385.18 27.01 317.79 2546.89 -3237.18 N 70205.768 W 14917 32.f74 8455.00 27.01 317.79 7090.13 4150.25 2570.38 -3258.48 0.00 5972604.39 587193.71 N 70 20 5.999 W 149 17 33.397 ~/ ~/ V-104 ASP Final Surveys.xls Page 4 of 4 I 8/29/2002-1 :40 PM! ) ) W6A- IO/"SO/O"l- /D/JI/01- III 1..3/ /4f.rfA) 'J'T) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon- Suspend- Pre-Producer Alter casing - Repair well - Converted to Inject Change approved program - 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 452' FNL, 1819' FEL, Sec. 11, T11N, R11E, UM At top of productive interval 3366' FNL, 4883' FEL, SEC 02, T11 N, R11 E, UM At effective depth 3193'FNL,5045'FEL,Sec.02,T11N,R11E,UM At total depth 3162' FNL, 5074' FEL, Sec 02 T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 108' 20" Surface 2956' 9-5/8" Production 8420' 7" Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 590482,5970074) (asp's 587387, 5972403) (asp's 587223,5972574) (asp's 587194, 5972605) 8455 feet 7090 feet 8363 feet 7008 feet Plugs (measured) Junk (measured) Re-enter suspended well - Pre-Producer Converted Time extension - Stimulate - to Injector Variance - Perforate - Other _X 6. Datum elevation (OF or KB feet) RKB 82.3 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number V-104 9. Permit number I approval number 202-142 10. API number 50-029-23103-00 11. Field I Pool Prudhoe Bay Field / Borealis Pool Measured Depth 137' 2985' True vertical Depth 137' 2700' Cemented 260 sx ArcticSet (Approx) 503 sx PF 'L', 303 sx Class 'G' 274 sx Class 'G', 205 sx Class 'G' 8446' 7082' measured Open perfS&7929', 7936'-7942', 7952'-7956' true vertical Open Perfs 6586'-6629', 6635'-6641', 6649'-6653' Perforation depth: Tubing (size, grade, and measured depth 4-1/2" 12.6# L-80 TBG @ 7745'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 7688' MD. 4-1/2" HES 'X' Nipple @ 2186'. 13. Attachments Description summary of proposal _X Detailed operations program - 14. Estimated date for commencing operation 15. Status of well classification as: November, 2002 16. If proposal was verbally approved Oil- R!IIIVHÐ OCT 21 2002 AIasIëa ou & Gas CoM. ~n AoaMfAP BOP sketch - Gas- Suspended - Name of approver Date approved Service WATER INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Bruce W. Smith @ 564-5093. SignedsruØ-.ce W~. Sm'lth .-eI~ ~..J. Tjije: Borealis Development Petroleum Engineer Date October 18. 2002 Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - t39P Test - Location clearance- Mechanical Integrity Test -þ . Subsequent form required 10- PI. 1: T ~~ \AA. "-l d - Approved by order of the Commission Form 1 0-403 Rev 06/15/88 . Onglnal Signed By CannilY ûed'\sIi T a~rn fl l.l '-/O'Î I Approval no. -302.-"3Âq Commissioner Date 10/1.1/ () ')... ~ ~ L SUBMIT IN TRIPLICATE bp ') October 18, 2002 ) ... ,\It.,,,. .......,~ ~...~ ~~- --:.~~ ..~ ~,.. . .'+jl\' ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for V-1 04 Conversion from Pre-Produced Injector to Water Injector (Kuparuk 'c' Sands) BP Exploration Alaska, Inc. proposes to convert well V-104 from a pre-produced injection well to an active water injector as part of the Borealis Pool Flood Development project. The procedure includes the following major steps: 1. S Drift, run initial Borealis GL design, place MEOH in IA. 2. E Jewelry log a. [ r'eí foft:itc 601 (Bottom 6hot @ 7056IMD) , / it-JttA- 4. 0 Hot Oil Well simultaneously to POP 5. S Run Static Survey MITIA to 4000 psig. Last test: Max Deviation: Perf deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S value: Wellbore Fluids: BHT & BHP: Reference Log: Note: New completion, never tested. 40.2° @ 5141' MD 300 @ 7875' MD 3.725"XN nipple @ 7745' MD None initial entry None initial entry Not tested (new well). Offset well V-101 '0' ppm 9/01/02. Freeze protected tubing & IA to 3500' with diesel. V-1 01 i 158°F & 3015 psi a @ 6600' TVDSS Schlumberger PEX Aug 23, 2002 Simops on Qoina Construction. drillinCl. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW@BP.com ) ") / ~J1r Hot Oiler: 4. POP well as soon as possible. . CRITICAL ISSUE: . Open lateral valve and wing valve, Pump 100 BBLs heated diesel, followed by 30 bbls warm Neat MEOH down IA. 5. Immediately place well on gas lifted production. (POP well). Start with 2.0 mmscf/d GL. Test Mother Well prior to POP V-104i, Test V-104i as soon as possible, solo. Late into test, pull samples from separator, send to Lab; pull oil sample from oil leg of separator, test for Oil Grav (Carl Fisher), pull sample from up stream of separator for water cut. Re test combined with Mother well and V-1 04i. Back to back if possible. Slickline: 6. (Slickline or E-line) Run Static Survey with pressure gauges and 2 spun down calibrated MRT's. Stops at 7875 md/ 6500 tvd, 7990 md/6600 tvd and 8105 md/6700 tvd. Once Static survey is complete, place 30 bbls Neat MEOH into IA prior to bring well back on. Return well to Production as soon as possible. Sincerely, Þ~-J~4Ø. Bruce W. Smith GPB Borealis Development Engineer prodA:~:~ :~~:~~~~;~~= Office Ph: ."",,,,,,,,,,,,,,,,,,,,,,,?,~~,:?9~~,,,,,,,,,,,,,,,,,,,,,,,,,,, Home Ph: 345-2948 """"""',,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,) Cell/Pager: ,,,,,,.,,,,,,,,,,,,,.,,,,~~Q:~QQ~,,,,,,,,,,,,,,,, "."" CC or AFC: 5m4095 Detail9E>de: 9335-070-770 '''''''/ Description::p.:!3:ç§,TçQ:M~P~f:(QNTÞ.:~B,~""~",..."",,,.,,:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::Z::::"""""""....."""""""",,,.....,,,,"""""",,,.,,,,,,,,,,,,, WBL Entries Work Desciption .'. bp ,\If.'''. ~~~ \~. ..~ F""-' .'I'.~§\- ". Well: Date: ) PERFORATING V-104i >.....,.............,....0...,.,....,............>...".....<.., 9/8/02 ....-,-,.....,.......,...................,....................." ) vJúk version micky E Jewelry log & perforate 60' (Bottom shot 7956 ' / Attachment. Reference log with proposed perfs annotated, 5"/100' scale R erence Log Tie in Log log: ,p,~~"""""""."" ""'"."...,~,,,.,,""",.. *Not Logged Yet Date' ,~!?~f.?:QQ?'."" ","",.""",,,,,.,.,,,,,,,,. Co pany: ,§~b!.~,'!1,þ'~~g,e~.""""""""",."""". Depths (from-to) Depths {from-to} """,.,?~~§,§:..""" - "..",T~~,§?~""" .,.,,,.,,,....,,...,.,,,,,,,... 7,942' - 7,~,36~ ::~'.~~~':: :~: ::::::::::::::::::::::::::::::. Add/Subtract to the tie-in lo'g"to"be"è)iï""""""""""" depth with the reference log. SPF Orient. """..2"""" 1 0,,9,~,g,,9.ftþtm """",§"""" 1 o,..9.~,g"9.ff.,,þtm """".§"""" 1 0,..9,~,g,,Qff..þtm ...........................~".... ......................"...... .,<,.,.,...,.,.,.,.,.,.,.,..." Gas Jetting Expected? Requested Gun Size: At what Depth? 3406 Power Jet, HMX 38.6 ""'-""""""""""'0"""','."'" Describe below how to achieve drawdown (check wjlPad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow wfJl{ Backflow Through Drain or Hardline) Tie in to Jewelry @ Minimum ID: Tail Depth: Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ ".."....""".......,,,......MD 3.725 in .,...........,,,..............'" .."....,??~§.."...... ft M D Last Tag: new well ............................... Well: Date: L:104i /.. .........................................,...".."....... Perforation Summary API#: 50-029-23103-00 General Comments: Phasing Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Gun Dia. Orient. SPF ,..,.,.................".. ,.......................... feet Phasing 60,° ''''''''''''''''''''"6õ'~''''''''''''''''''''' "'''''''''''''''''''6Ö~'''''''''''''''''''' ,.,.,.,...........,...............,......<,...".. Zone Ad/Re/lperf ........ç"...",.,..."..........",...L."....."............ C I .........<,........<,.........,......<,...,.......,.......,.,.,.,.,. C I """""""'0'"'''''''''''''''''''''''''''00''''''''''''''''' .............,..........................,....,...." """""""~""""""""""""'"''''''''''''''''<'<""'" ..................,..............................." <,<,OJ"""""""""""<"""""""""""",,,.'0.....,.., ..",Nf.A.... Balanced .>.>.................................>.>.............................>...................>.>.............................................>.......>.......>.....>.>."""'" Entry Hole Diam: ..........Q:~§......... N/A .,..,.,.....,.,.,....,......................................",..............,..,.............,...,.,....",.................,.,...,.,.......,..,....',....""......",..,. ,X,E::~f~~~ng.~..!29........................"..............,........."....,,,.....,,,....."..,,,,,,,,,,........................,,,,'.......,.,.,,......,.',,. ..,.,...................,......."..~,N,.~!I?p.!~................."................. @ ..,?l,~.?,.. 'MD 7 in ........................... ....."?'!.~~Q,..... MD is Prod Engr: ,,,,,,,,.....,,,,,..,, PBTD 2850 psi ............................. Anch Prod Engr .... P.o. Center "'"'''''''''''''''''''''''''''''''' Zone AperflReperf 0 0 00 0 ""''''''''''''..'..'''. ) ]I' TREE = 4-1/16" aw WELLHEA 0 = FMC AcîîJÄTÕR;;"-'"----"~~""ÑA' 1<8. B-EV;;------82~3' BF~~ËiI3r ='-"--'-~"-'-~' NA KOP = -^-------'^'^"^-^-3üÔ' Il/ax-hAngl~^ = 40.8 @ 2245' Datum I'vÐ = """""'..~---~^,^,"",,,,,,",,"~^'~"""""''''-''''''''''~-''''' Datum lV 0 = 8800' SS I 9-5/8" cSG, 40#, L-80, 10 = 8.835" H 2985' ~ Minimum ID = 3.725" @ 7733' 4-1/2" HES XN NIPPLE ÆRFORA llON SUMMA RY REF LOG: TCP PERF AI\IGLEA TTOP ÆRF: 29 @ 7879' Note: Refer to Production 00 for historical perf data SIZE SA= IN1ERVAL Opn/Sqz OATE 3-3/8" 6 7879 - 7929 0 09/19/02 3-3/8" 6 7936 - 7942 0 09/19/02 3-3/8" 6 7952 - 7956 0 09/19/02 4-1/2" TBG, 12.6#,L-80, .0152bpf, 10= 3.958" 11 7745' I FBTO H 8363' 17" cSG, 26#, L-80, .0383 bpf, 10 = 6.276" H 8446' V-104 I I l I I ;g: I z \ I ~ DA.1E REV BY COrvtv1ENTS 08f26¡Q2 TWA/t<J< ORlGINA.L COMPLETON 09l19¡Q2 OBM/t<J< ¡PERFS OA TE REV BY COMf'v'ENTS ) / =---t 986' H 9-5/8" TAM paRr COLLAR 1 I 2186' H 4-112"HESXNIP,D=3.813" 1 ~ GAS LIFT MA NORELS TVO OE\! TYPE VL V LATCH 3508 39 KBG-2 DMY BK-5 4504 39 KBG-2 DMY BK-5 6358 38 KBG-2 RP BEK-2 PORT DATE ST MO 3 4028 2 5318 1 7611 7677' H 4-1/2" HES X NIP, 10 = 3.813" 7688' 7712' H 7" X 4-1/2" BKR &3 R<R 10 = 3.875" I 1-1 4-112" I-ES X NIP, 10 = 3.813" 1 H 4-1/2" HES XN NP, 10 = 3.725" I H 4-112" WLEG, 10 =4.00" 1 7733' 7745' . 7793' H 20'PUPJTW/RA TAG (ELM) I ~ 8181' H2O' PUPJTW/ RA TAG (ELM) I GPB BOREALIS WELL: V-104 PERMT t-b: 2021420 AR No: 50-029-23103-00 SEC11, T11N, R11E 4827 NSL & 1819'WB- BP Exploration (Alaska) Schlum~erger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well L-105 ðO~-D~~ V-104 ...:;)~~..,~ ~ D.S.15-31AÖ~.J Dd. C-25A J q - - 0 II Job# Log Description SBHP SURVEY SBHP SURVEY 22231 D.S. 15-31A 22234 C-25A PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECe\VED OCT 1 4 2002 Alaska O~ & Gas Cons. CornmiHion Anchorag$ 09/22/02 09123102 06/15102 07/10/02 10/07/02 NO. 2472 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis P.Bay Date Sepia BL CD Color .~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ~~woo~ .) MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Well No V-104i Date Dispatche Installation/Rig Nabors 9ES Dispatched By: } d-oa_~_L~~- Lisa Weepie 29-Aug-02 Nate Rose Data No Of Prints No of Floppies Su rveys 2 R"""'" b.""= ,ë' L.'." 'Ei"~\i ..F \. ¡jk= ~;, 1'"".."., OCT n s> '""", t_". fJt~S~,a ...;~ Received B~{~, J LWD Log Delivery V1.1, Dec '97 Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1@slb.com Fax: 907-561-8417 IIIIì IIIIiI8ìï8 --,-,~"'~'-~'~--'----" - - -- -,-_._,~ .,.....-.- - .;\Móo".~'.~ '.""''<'1Ü'~'''~''","":''1>1 "'¡;:,:,¡,~','J.",'.'1I.'~"~~'.""'¡ "'~""'4"¡""l,,,,-,,,.lj¡",,,,,,, -,,,,,,, i."""'~'.' k:~rljf¡'iW,.l. ,.;., "I""""",""'N.r'~'" 'If'" ,~",j,:!ï""'IS~"¡Io.J.\'''~'''''''' 's;.:.¡<' ""~"'a."""'""a'....~'.'''. .'.''''''"" "'.di""':'¡''''''''',1''''i'¡'.......,~."~L,;o~''''''.I'''''''O:'''''.'~..,,j.''''~,.:'''~.""..... 'i"""\'.".""~""4~:;-~í¡¡'~ Schlum~erger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well V.104 rl.j}é)- J"~ L.105 a()ri.- r1l.1 L-105 I L-105 L-105 L-105 L.105 L.105 "'>..../ V.105 (RUN 1) V.105 (RUN 2}-J Job# Log Description 22414 USIT 22348 OH EDIT PEXlAIT/BHC DATA (PDC) 22348 OH EDIT PEXlAIT/BHC DATA {PDe¡ 22348 OH EDIT PEXlAIT/BHC DATA {PDe¡ 22348 OH EDIT PEXlAIT/BHC DATA (PDe¡ 22348 OH EDIT PEXlAITIBHC DATA (PDC) 22348 OH EDIT PEXlAITIBHC DATA (PDe¡ 22348 OH EDIT PEXlAIT/BHC DATA (PDe¡ 22420 USIT 22421 USIT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2.1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED C. f.:J 1""" "(1""2 VI-I \) ¿v\) Ai~~a J~~ .:1 G~ :~~Jr:J. CcrnmisskJn ,åu¡ct¡.~rgge 08/25/02 07/12/02 07/12/02 07/12/02 07/12/02 07/12/02 07/12/02 07/12/02 09/07/02 09/07/02 NO. 2411 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color BL Sepia 2 2 2 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Receivedb~~' r '09/12/02 CD ~ ) ---- ) ) ~1f~V (ill ~ TONY KNOWLES, GOVERNOR AI1ASKA. OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 333 w. ]1H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit Vl04i BP Exploration (Alaska), Inc. Pennit No: 202-142 Surface Location: 4827' NSL, 1819' WEL, Sec. 11,TllN, RILE, UM Bottom hole Location: 2273' NSL, 5131' WEL, Sec. 02, TllN, RILE, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced service well. The pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (ô~~~/~.~ C~~;;ýbechsli Taylor Chair BY ORDER OF THE COMMISSION DATED thisjJhday of July, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Hole 42" 12-1/4" 8-3/4" ALASKA ¿2 AND ~:~~g:S~~~~ON COMMlbJON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory [J Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB=82.31 Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028240 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / V.104i 9. Approximate spud d~ 07/17/02 . Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8441' MD / 7062' TVD 0 17. Anticipated pres~re {see 20 AAC 25.035 (e) (2)} 37 Maximum surface 2735 psig, At total depth (TVD) 6765' / 3412 psig Setting Depth TOD Bot;om Mn TVD tv1q TVD Surface Surface 110' 110' Surface Surface 2971' 2682' Surface Surface 8441' 7062' 'YJ6Ir' 7/i/ 0 'L ~ itj~ 1 a. Type of work II Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4827' NSL, 1819' WEL, SEC. 11, T11 N, R11 E, UM At top of productive interval 2000' NSL, 4890' WEL, SEC. 02, T11 N, R11 E, UM At total depth 2273' NSL, 5131' WEL, SEC. 02, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028241, 1491 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 400' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize CasinQ WeiQh' Grade CouplinQ 20" 91.5# H-40 WLD 9-5/8" 40# L-80 BTC 7" 26# L -80 BTC-m 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 , enQth 80' 2941' 84111 Quantity of Cement (include staQe data) ,260 sx Arctic Set (Approx.) 449 sx PF 'L', 273 sx Class 'G' ,292 sx Class 'G', 290 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED true vertical JUL 8 2002 Alaska on & Gas Cons. CommiSSion Anchorage Perforation depth: measured II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: James ranks, 564-4468 Prepared By NameINumber: Sandra Stewman, 564-4750 21. I hereby certify that the fore ng is true ~ ;-rrect to the best of my ~nowl~~ge . Signed Lowell Cran ~ (~ Title SeOlor Dnlllng Engineer Date Î - Ý - -Q].- ,- .:.",." '.' .,'«,:,:/',~:~,¿,',\):',~,v~r:::<i,>~;~"f~J,.S~~fi;~\:'i~;;,i)}":~5i.'~:~\>,:/:n:,<", '1' , Permit Number API Number Approv~1 D~te See cover letter con~t:;-; ;;~~ Samp~~ :~r,~ -23/0 30 Yes S No Mud Log R~¿;;l1P~ fO~~:; ã~~ments Hydrogen Sulfide Measures 0 Yes 'SNo Directional Survey Required" Yes 0 No Required Working Pr:.:ssure for BOPE ,..02K 03K 04K ,0 5~~0 1,OK 0 15K, [J 3.5K psi for CTU Other:T~ÙfrlOO~ c.fO((Jo fSII , I4tT) Cu1--t'lual, to, y.¿'jt.U~J. Cammy Oechsli T aylOf ~ ',..1 :1,. 6 by order!. 0 1/ I ' Approved By Commlss'oher';~ J the commiSSion Date q O,~ Form 10-401 Rev. 12-01-85 . Submit In Triplicate 20. Attachments ) ,\tA-I. bp ......,..~...,"~#..- ~~- ~...~ ~.~ F"'''' .'J'~\" ) To: Winton Aubert, AOGCC Date: July 8, 2002 From: J ames Franks Subject: Contin2enCY Well V -104i Permit Currently BP Alaska Drilling and Wells is drilling the L-I05 Injection well with Nabors Drilling Rig 9ES. The next well in the program is to be the L-I03 Injection well which has already been approved and permitted by the AOGCC. Following the L-I03 well will be 2 more Injectors, V-I05 and V-I04. Due to partner approvals, or lack thereof, to this point, BP Alaska Drilling and Wells is in need of expediting the permit approval of the attached V-I 04 Injection well. We certainly do not intend on this being a regular occurrence. BP Alaska Drilling and Wells is appreciative of your patience and support in this matter. Please contact me if you have any comments. Sincerely, ~ GPB Rotary Drilling Engineer 564-4468 RECEIVED JUL 8 2002 Alaska Oîi & Gas Cons. LJUIIiI¡¡i:-.;:\IOi Anchorage ORiG1 t- ) ) IWell Name: V-104i Drill and Complete Plan Summary I Type of Well (service I producer I injector): Injector Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: x = 590,482.65' Y = 5,970,073.73' 48271 FSL (4531 FNL), 18191 FEL (34611 FWL), Sec. 11, T11 N, R11 E X = 587,380.00' Y = 5,972,490.00' 2000~ FSL (3280' FNL), 48901 FEL (3901 FWL), Sec. 2, T11 N, R11 E X = 587,135.10' Y = 5,972,760.02' 22731 FSL (3007' FNL), 5131' FEL (1491 FWL), Sec. 2, T11N, R11E I AFE Number: I BRD5Mxxxx I I Estimated Start Date: 17/17/2002 I I MD: 18441' l TVD: 17062' I I Rig: I Nabors 9ES /' I OperatinQ days to complete: 114.1 1 RT/GL: 128.5' I RKB: 182.3' I Well DesiQn (conventional, slim hole, etc.): Ultra Slimhole (Iongstring) Objective: I Single zone water/miscible injection into the Kuparuk formation. Mud Program: 12 %" Surface Hole (0-2971 '): Densitv (ppg) 8.5-9.2 9.0 - 9.5 9.5 max / 8 314" Production Hole (2971 ' - 8441 '): Interval Density Tau 0 YP (ppg) 9.2-9.7 10.1 j Initial Base PF to top SV SV to TD Upper Interval Top of HRZ toTD V -1 04i Drilling Program (Draft) Viscosity (seconds) 250-300 200-250 150-200 4-7 25-30 3-7 20-25 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/1 OOft~) (mls/30min) 50 - 70 15 - 20 8.5- 9.5 30 - 45 <10 8.5-9.5 20 - 40 <10 8.5-9.5 LSND PV pH API 10' Gel Filtrate 1 0-15 8.5-9.5 6-10 10 1 0-15 8.5-9.5 4-6 10 Page 1 ') ) Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-1 ,857 550 4" 17.5# 90 1800 10.0 N/A 18,18,18,16 .942 1,857' -2, 770' 650 4" 17.5# 110 2400 10.2 N/A 18,18,18,16 .942 Production Hole: 8 3A" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2971' - 8441' 600 4" 17.5# 240 3400 11.0 N/A 3x14,3x15 .969 Hole Cleaning Criteria: Interval Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation 110'-2971' Surface Superior hole cleaning practices at to SV-1 connections will greatly enhance cuttings transport in the sliding mode 185 60 500 9.5 Acceptable 210 60 600 9.5 Acceptable 200 80 500 9.5 Acceptable 235 80 600 9.5 Acceptable 260 80 700 9.5 Acceptable 205 100 500 9.5 Acceptable 250 100 600 9.5 Acceptable 315 100 700 9.5 Acceptable 2742' -8441 ' 9-5/8" to Sweeps and fully reamed connections TD to maintain minimum hole cleaning requirements 300 60 550 9.7 Acceptable 325 80 600 9.7 Acceptable 340 60 700 9.7 I Acceptable 200 80 550 10.1/ Acceptable V-104i Drilling Program (Draft) Page 2 Directional: Ver. Anadrill P4 KOP: 400' Maximum Hole Angle: Close Approach Wells: None Logging Program: Surface ) ) 37 deg at 2121' MD Nearby Wells: All wells pass major risk criteria. V-101 -13.25' @ 1104' MD V- 201 - 24.14' @ 1440' MD IFR-MS corrected surveys will be used for survey validation. GyroData will be needed for surface hole nearby wells to 1000' MD. Intermediate/Production Hole Formation Tops SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 Na WS1 Oa Obf Base CM2 (Colville) THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU (Kuparuk B) Kuparuk A TMLV (Miluveach) TD Criteria Formation Markers: MDbkb 1664 1815 1857 2285 2504 2920 3329 3732 4175 4543 4836 5035 5484 5851 7459 7659 7734 7822 7822 8022 8172 8291 8441 V-104i Drilling Program (Draft) Drilling: Open Hole: Cased Hole: Drilling: . Open Hole: Cased Hole: TVDss 1535 1665 1700 2050 2225 2559 2877 3210 3565 3860 4095 4255 4615 4910 6195 6355 6415 6485 6485 6645 6765 6860 MWD/GR None None MWD / GR / PWD PEX/ BHC Sonic USIT cement evaluation Estimated pore pressure, PPG Hydrocarbon bearing, 8.5 ppg EMW /' Hydrocarbon bearing, 8.5 ppg EMW Hydrocarbon bearing, 8.5 ppg EMW Hydrocarbon bearing, 8.5 ppg EMW Hydrocarbon Bearing, 9.7 ppg EMW <'" Hydrocarbon Bearing, 9.7 ppg EMW Hydrocarbon Bearing, 9.7 ppg EMW 150' below Miluveach top Page 3 ) ') CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top 8tm Size Tbg O.D. MDITVD MDITVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 11 0/11 0 12 %" 9 5/8" 40# L-80 BTC 294 1 ' GL 2971 '/2682' 8 %" 711 26# L-80 BTC-m 8411' GL 8441 '/7062' Tubing 4 Y211 121# L-~ TC-II 7692' GL 7622'/6390' Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' min from LOT 12.0 ppg EMW Target surface shoe Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casinq Size 19-5/8" Surface I Basis: Lead: Based on 1857' of annulus in the permafrost @ 2250/0 excess and 364' of open hole from top of tail slurry to base permafrost @ 300/0 excess. Lead TOC: To surface Tail: Based on 750' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2221' MD . / Total Cement Volume: Lead 332.5 bbl I 1865fe I 449 sks of Halliburton Permafrost L at 10.7 ppg and 4.15,gf/Sk. Tail 56 bbl I 313 fe 1273 sks of Halliburton 'G' at 15.8 ppg and 1.15 cf/sk. Casinq Size 17" Production Longstring I Basis: Stage 1: Based on TOC 1000' above top of Kuparuk formation + 30% excess + 82' shoe Cement Placement: From shoe to 6821' MD. / Total Cement Volume: Lead 96.8 bbls I 543 fe 1292 sks of Halliburton Premium "G" at 12.5 ppg and 1.86cf/sk. Tail 59.5 bbl I 334 fe I 290.ßks of Halliburton 'G' at 15.6 ppg and 1.15 cf/sk. V-104i Drilling Program (Draft) Page 4 ) ) Well Control: I Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the need to test the production casing to 4000 psi (MI service Well) the BOP equipment will be tested to 4000 psi Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: 3412 p~ 6765' TVOss - Kuparuk A Sands . Maximum surface pressure: 2735 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: 4000 -þsi (The casing and tubing will be tested to 4000 psi as required for MI service.) . Planned completion fluid: ppg diesel Filtered seawater with 2% KCL with corrosion inhibitor / 6.8 Disposal: . No annular disposal in this well. I . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-104i Drilling Program (Draft) Page 5 ') ') DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed in Feb. 2002. 1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: . 1. MIRU Nabors 9ES. I 2. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWD/GR and directionally drill surface hole to approximately 100' TVD below the SV1 Sands. An intermediate wiper/bit trip to surface ~ will be performed prior to exiting the Permafrost. y.l6k- 4. Run and cement the 9-5/8", 40# surface casing back to surface. qOOO ~ 5. ND riser spool and NU casing / tubing head. NU BOPE and test to ~ psi. 6. MU 8-3/4" drilling asse~ly with MWD/PWD/GR and RIH to float collar. Test the 9-5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.5 ppg drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead and increase mud weight to 9.7 ppg prior to first wiper trip. 9. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.1 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 10. Drill ahead to TD at -150' below Top Miluveach. 11. Rig up Schlumberger and run PEX/BHC sonic. One attempt on wireline will be made after which TLC will be utilized. 12. Condition hole for running 7" 26# long-string casing. 13. Run and cement the 7" production casing in a single stage. (To be reviewed based on log results.) Displace the cement with heated 8.5 ppg heated filtered brine (20/0 KCL) if single stage. 14. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. ,< 15. Test casing to 4000 psi for 30 mt!Jutes. / 16. RU Schlumberger and run USIT log on e-line from the 7" float collar to 500' above TOC. 17. Run the 4-1/2", 12.6#, L-80 TC-II completion assembly. Set packer and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. Shear RP valve and install TWC. Test below to 1000 psi. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 19. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize. 20. Rig down and move off. V-104i Drilling Program (Draft) Page 6 ') ) V-104 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ~ V-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. » Check the landing ring height on V-104i. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ~~'M"_"'~_.~..,'" Job 2: Drillina Surface Hole Hazards and Contingencies » There are two nearby well issues in the surface hole. Refer to page 4 for details. » Gyro Data survey will be required per the directional plan to 1 000' MD or until the magnetic interference has dissipated. » Gas hydrates have been observed in wells drilled on V-Pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" 1>""""",,J',~~.1,,,,,,~. Job 3: Install surface CasinQ Hazards and Contingencies » It is critical that cement is circulated to surface for well integrity. 2250/0 excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be positioned at :f:1 OOO'MD to allow remedial cementing. » "Annular Pumping Away' criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 300/0 excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Halliburton Cement Program" .:. ¡¡Surface Casing Port Collar Procedure" V -1 04i Drilling Program (Draft) Page 7 ) ) Job 7: DrillinCl Production Hole Hazards and Contingencies ~ V-104i will cross a fault at the base of the Schrader at - 4625'TVD (+/- 150'). The estimated throw of the fault is 160'. The well will be - 37 degrees when crossing the fault. Loss circulation is considered a risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERANCE: In the case scenario of 9.8 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.0 ppg at the surface casing shoe, 10.1 ppg mud in the hole the kick tolerance is 28 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 12.0 ppg. ~ V-Pad development wells have "kick tolerances" in the 25-50 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals ~ There are no "close approach" issues with the production hole interval of V-104i. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "Shale Drilling- Kingak & HrZ" Job 8: LOQ Production Hole Hazards and Contingencies ~ Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7" longstring casing. Reference RPs .:. Follow Schlumberger logging practices and recommendations. .:. "Drill pipe Conveyed Logging" m..~.~~"~:",~",.,,..,':".,,.,,,,,,,,,,,,.- Job 9: Case & Cement Production Hole Hazards and Contingencies ~ A 15.6 ppg latex cement slurry will be used from TD to 1000' above the Kuparuk and if hydrocarbons are evident from the open hole logs, a 12.5 ppg extended slurry will be used to cover the remaining interval to 500' above the uppermost Schrader hydrocarbon show. The actual cement requirement will be based on the open hole log evaluation. ~ Ensure the lower production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 63 bbls of dead crude (2300' MD, 2221 'TVD), the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could V -1 04i Drilling Program (Draft) Page 8 ') ") be 110 psi underbalance to the open hole. (A second LOT will be required prior/to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ~ Ensure a minimum hydrostatic equivalent of 10.1 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. ~ Considerable losses during running and cementing the 7" longstring has been experienced on offset wells. A casing running program will be issued detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will be placed across the Schrader and Ugnuto help arrest mud dehydration. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Halliburton Cement Program" Attached. .:. "Freeze Protecting an Outer Annulus" ",~xx#JWm;m))Sm»nm.m.. Job 12: Run Completion Hazards and Contingencies ~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be underbalance if there is a casing integrity problem. ~ Shear valves have been failing at lower than the 2500 psi differential pressure. When test annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus ¡,>:,,,"',,,,m.""WMy,.:.,»".'m¡¡.¡.¡. , Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus V-104i Drilling Program (Draft) Page 9 ')- Borealis V-104i: Proposed Completion - TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 Cellar Elevation = :i:53.8' RKB-MSL = :i:82.3' I . 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' I 9-5/8",40 #/ft, L-80, BTC ~ ~ 2971' 4-1/2" x 1" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS TVD Size Valve Type # 1 2 3 4500 3500 TBD 4-1/2" KBG-2 4-1/2" KBG-2 4-1/2" KBG-2 RP Dummy Dummy L ~ ) 4-1/2" 12.6# L-80, TC-II Tubing L 1r 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'Premium' Packer +/-200' above Kuparuk 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.75" seal bore. 4-1/2" WireLine Entry Guide set at +/-130' above the Kuparuk Formation Plug Back Depth I 7",26 #/ft, L-80, BTC-Mod ~ I 8361' :... 8441' Date 7 -3-02 Rev By jdf Comments Borealis WELL: V-104i API NO: 50-029-????? Proposed Completion (4) BP Alaska V-104 SchlumbepUIP Proposed Well Profile - Geodetic Report Report Date: July 2, 2002 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 309.440° Field: Prudhoe Bay Unit - WOA (Drill Pads) tLl y Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: V-Pad/V-104 lilt)' TVD Reference Datum: KB Well: V-104 ØII TVD Reference Elevation: 82.2 ft relative to MSL Fe.51 Borehole: V-104 Sea Bed I Ground Level Elevation: 55.000 ft relative to MSL UWI/API#: 50029 Magnetic Declination: 25.831° Survey Name I Date: V-104 (P4) I July 2,2002 Total Field Strength: 57503.700 nT Tort I AHD I 0011 ERD ratio: 47.873° 14326.27 ft /5.394 I 0.61~ Magnetic Dip: 80.769° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: August 27,2002 '--' Location LatlLong: N 70.32797935, W 149.2661793€ Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5970073.650 ftUS, E 590482.470 ftUS North Reference: True North Grid Convergence Angle: -+û.69099553° Total Corr Mag North -> True North: +25.831 ° Grid Scale Factor: 0.99990930 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates I Station 10 MD I Incl I Azim I TVD I VSec N/-S I E/-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) KBE 0.00 0.00 310.00 0.00 0.00 0.00 0.00 0.00 5970073.65 590482.47 N 70.32797935 W 149.26617936 KOP Bid 1.5/100 300.00 0.00 310.00 300.00 0.00 0.00 0.00 0.00 5970073.65 590482.47 N 70.32797935 W 149.26617936 Base Gubik 327.20 0.41 310.00 327.20 0.10 0.06 -0.07 1.50 5970073.71 590482.40 N 70.32797951 W 149.26617993 400.00 1.50 310.00 399.99 1.31 0.84 -1.00 1.50 5970074.48 590481.46 N 70.32798165 W 149.26618747 500.00 3.00 310.00 499.91 5.23 3.36 -4.01 1.50 5970076.96 590478.42 N 70.32798853 W 149.26621188 600.00 4.50 310.00 599.69 11.77 7.57 -9.02 1.50 5970081.11 590473.36 N 70.32800003 W 149.26625250 700.00 6.00 310.00 699.27 20.92 13.45 -16.03 1.50 5970086.90 590466.28 N 70.32801609 W 149.26630935 Cry 2/100 800.00 7.50 310.00 798.57 32.68 21.01 -25.03 1.50 5970094.35 590457.19 N 70.32803675 W 149.26638233 900.00 9.50 310.00 897.47 47.46 30.51 -36.36 2.00 5970103.72 590445.75 N 70.32806270 W 149.26647421 Cry 2.5/100 925.00 10.00 310.00 922.11 51.69 33.23 -39.60 2.00 5970106.40 590442.48 N 70.32807013 W 149.26650048 '-' SV6 965.78 11.02 310.00 962.20 59.13 38.01 -45.30 /;.50 5970111.11 590436.72 N 70.32808319 W 149.26654670 1000.00 11.87 310.00 995.74 65.92 42.37 -50.50 2.50 5970115.40 590431 .47 N 70.32809510 W 149.26658887 1100.00 14.37 31 0.00 1093.12 88.62 56.97 -67.89 2.50 5970129.79 590413.90 N 70.32813499 W 149.26672989 1200.00 16.87 310.00 1189.42 115.55 74.28 -88.52 2.50 5970146.85 590393.07 N 70.32818228 W 149.26689718 1300.00 19.37 310.00 1284.45 146.66 94.28 -112.35 2.50 5970166.56 590369.00 N 70.32823691 W 149.26709043 1400.00 21.87 310.00 1378.03 181.88 116.92 -139.33 2.50 5970188.87 590341.75 N 70.32829876 W 149.26730922 1500.00 24.37 310.00 1469.99 221.15 142.16 -169.42 2.50 5970213.74 590311.36 N 70.32836771 W 149.26755323 1600.00 26.87 310.00 1560.15 264.39 169.96 -202.54 2.50 5970241.14 590277.91 N 70.32844366 W 149.26782181 V-104 (P4) report.xls Page 1 of 3 7/2/2002-12:01 PM Grid Coordinates Geographic Coordinates I Station ID MD Incl I Azim I TVD I VSec N/.S I E/-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) SV5 1664.43 28.49 310.00 1617.20 294.32 189.19 -225.47 2.50 5970260.09 590254.76 N 70.32849619 W 149.26800776 1700.00 29.37 310.00 1648.33 311.52 200.25 -238.65 2.50 5970270.99 590241.44 N 70.32852641 W 149.26811464 1800.00 31.87 310.00 1734.38 362.46 233.00 -277.67 2.50 5970303.26 590202.04 N 70.32861587 W 149.26843108 SV4 1815.13 32.25 310.00 1747.20 370.49 238.16 -283.83 2.50 5970308.35 590195.82 N 70.32862997 W 149.26848103 End Crv 1826.97 32.55 31 0.00 1757.20 376.84 242.24 -288.69 2.50 5970312.37 590190.91 N 70.32864111 W 149.26852045 Base Permafrost 1856.63 32.55 31 0.00 1782.20 392.79 252.49 -300.91 0.00 5970322.47 590178.57 N 70.32866912 W 149.26861955 Crv 2.5/100 1886.29 32.55 310.00 1807.20 408.75 262.75 -313.14 0.00 5970332.58 590166.21 N 70.32869714 W 149.26871873 1900.00 32.78 309.53 1818.74 416.15 267.48 -318.82 2.50 5970337.24 590160.48 N 70.32871006 W 149.26876479 2000.00 34.50 306.26 1902.00 471.50 301.47 -362.55 2.50 5970370.70 590116.34 N 70.32880292 W 149.26911943 2100.00 36.30 303.26 1983.51 529.22 334.46 -410.15 2.50 5970403.11 590068.35 N 70.32889304 W 149.26950545 End Crv 2120.87 36.69 302.67 2000.29 541.56 341.22 -420.56 2.50 5970409.74 590057.86 N 70.32891150 W 149.26958987 -.-i SV3 2285.37 36.69 302.67 2132.20 639.16 394.27 -503.29 0.00 5970461.79 589974.51 N 70.32905642 W 149.27026080 SV2 2503.60 36.69 302.67 2307.20 768.64 464.66 -613.05 0.00 5970530.84 589863.92 N 70.32924869 W 149.27115094 SV1 2920.12 36.69 302.67 2641.20 1015.76 599.00 -822.53 0.00 5970662.63 589652.85 N 70.32961564 W 149.27284986 9-5/8" Csg pt 2971.25 36.69 302.67 2682.20 1046.09 615.49 -848.24 0.00 5970678.81 589626.95 N 70.32966069 W 149.27305838 UG4A 3329.15 36.69 302.67 2969.20 1258.44 730.93 -1028.24 0.00 5970792.06 589445.59 N 70.32997600 W 149.27451826 UG3 3731.95 36.69 302.67 3292.20 1497.42 860.85 -1230.82 0.00 5970919.52 589241 .47 N 70.33033084 W 149.27616133 UG1 4174.65 36.69 302.67 3647.20 1760.08 1003.64 -1453.47 0.00 5971059.60 589017.14 N 70.33072083 W 149.27796725 Ma 4542.53 36.69 302.67 3942.20 1978.35 1122.29 -1638.49 0.00 5971176.00 588830.72 N 70.33104486 W 149.27946801 Na 4835.59 36.69 302.67 4177.20 2152.22 1216.82 -1785.88 0.00 5971268.73 588682.21 N 70.33130302 W 149.28066357 Oa 5035.12 36.69 302.67 4337.20 2270.60 1281.17 -1886.22 0.00 5971331.86 588581.11 N 70.33147875 W 149.28147750 Schrader Target 5234.65 36.69 302.67 4497.20 2388.98 1345.53 -1986.57 0.00 5971395.00 588480.00 N 70.33165451 W 149.28229152 Obf Base 5484.05 36.69 302.67 4697.19 2536.95 1425.97 -2112.00 0.00 5971473.92 588353.62 N 70.33187417 W 149.28330901 Crv 2/100 5484.06 36.69 302.67 4697.20 2536.96 1425.97 -2112.01 0.00 5971473.92 588353.61 N 70.33187417 W 149.28330909 5500.00 36.66 303.20 4709.99 2546.42 1431 . 15 -2120.00 2.00 5971479.00 588345.56 N 70.33188831 W 149.28337391 5600.00 36.56 306.55 4790.27 2605.85 1465.24 -2168.91 2.00 5971512.49 588296.25 N 70.33198141 W 149.28377068 5700.00 36.54 309.91 4870.61 2665.37 1502.08 -2215.67 2.00 5971548.76 588249.05 N 70.33208201 W 149.28415002 '""-'" 5800.00 36.62 313.27 4950.92 2724.91 1541.63 -2260.23 2.00 5971587.77 588204.02 N 70.33219002 W 149.28451153 CM2 5851.46 36.70 314.98 4992.20 2755.53 1563.02 -2282.29 2.00 5971608.89 588181.71 N 70.33224844 W 149.28469051 5900.00 36.80 316.60 5031.09 2784.39 1583.84 -2302.53 2.00 5971629.46 588161.22 N 70.33230530 W 149.28485472 End Crv 5956.99 36.94 318.48 5076.68 2818.23 1609.06 -2325.61 2.00 5971654.40 588137.84 N 70.33237418 W 149.28504198 CM1 6783.37 36.94 318.48 5737.20 3308.67 1980.92 -2654.78 0.00 5972022.23 587804.24 N 70.33338977 W 149.28771289 Top HRZ 7458.97 36.94 318.48 6277.20 3709.63 2284.92 -2923.88 0.00 5972322.93 587531.52 N 70.33422000 W 149.28989658 Base HRZ 7659.15 36.94 318.48 6437.20 3828.43 2375.00 -3003.62 0.00 5972412.04 587450.71 N 70.33446601 W 149.29054369 K-1 7734.22 36.94 318.48 6497.20 3872.98 2408.78 -3033.52 0.00 5972445.45 587420.40 N 70.33455826 W 149.29078634 V-104 (P4) report.xls Page 2 of 3 7/2/2002-12:01 PM Grid Coordinates Geographic Coordinates I Station ID MD I Incl I Azim I TVD I VSec I N/-S E/-W I DLS Northing I Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) Top Kuparuk 7821.80 36.94 318.48 6567.20 3924.96 2448.19 -3068.40 0.00 5972484.43 587385.06 N 70.33466588 W 149.29106941 Kuparuk Target 7834.31 36.94 318.48 6577.20 3932.38 2453.82 -3073.39 0.00 5972490.00 587380.00 N 70.33468126 W 149.29110990 LCU I Kup B 8021.98 36.94 318.48 6727.20 4043.76 2538.26 -3148.14 0.00 5972573.53 587304.24 N 70.33491186 W 149.29171654 KupA 8172.11 36.94 318.48 6847.20 4132.86 2605.82 -3207.94 0.00 5972640.36 587243.64 N 70.33509636 W 149.29220186 TMLV 8290.98 36.94 318.48 6942.21 4203.41 2659.31 -3255.29 0.00 5972693.27 587195.65 N 70.33524243 W 149.29258615 TO I 7" Csg pt 8440.97 36.94 318.48 7062.09 4292.42 2726.80 -3315.03 0.00 5972760.02 587135.11 N 70.33542674 W 149.29307100 Leaal Description: Surface: 4827 FSL 1819 FEL S11 T11N R11E UM Schrader Target: 892 FSL 3804 FEL S2 T11 N R11 E UM Kuparuk Target: 2000 FSL 4890 FEL S2 T11 N R11 E UM BHL: 2273 FSL 5131 FEL S2 T11N R11E UM NorthinQ eV) rftUSl 5970073.65 5971395.00 5972490.00 5972760.02 Eastina eX) rftUSl 590482.47 588480.00 587380.00 587135.10 ~ ~' V-104 (P4) report.xls Page 3 of 3 7/2/2002-12:01 PM ~. ,$,4 '~~i~~f'~h¿~,~;? ~~;~ ~ ,~ìho ~1' :'- ~~~- .;i~~~~~~;,*~ ~i'$j;;,. 0-....,... 1 000 ..&;;.....:::: - 2000 _no - +-' Q)- ~~ 8 : 3000 --.... ~ > II ~ c: ro ~4= -° ..r::."! ã.~ Q) - n. 0 c:a 4000 - ... -~ CO .. . ~ '(¡) ~a:: > > Q)~ ::sW l- I- -) ') VERTICAL SECTION VIEW Client: Well: Field: BP Exploration Alaska V-I04 (P4) Prudhoe Bay Unit - WOA Schlumberger Structure: V-Pad Section At: 309.44 deg Date: July 02, 2002 . . . . . . . ""1' ...............n..................n...........n................t.' ..,.....................n............................................+.. KOP Bid 1.St1OO300 MD 300 TVD n. .~..O,O~.: ~~O'e: az...~ d~~.art~:~ ..... ..... Cry 21100 800 MD 799 TVD ~ 7,50. j310.00. az 33departure Cry 2.51100 925 MD 922 TVD ~ 10.0q' 310.00. az 52 departure .n.'¡'.... ..... ,'m. 'n" ..... ..n. ..... ...... ¡ 8a$e Gubik 327 r...1D 327 TVD . . . , -------- ....t"'S\¡f"96.tnŸfër9Ö2'TVi5"''''''''''''''''''~'''''''' - - - - , . . . - .- - - - - - - .- .............t.............................................................,,,......~......... ------ End Cry 1827 MD 1757 TVD ; 32.55. 310.00. az 377 departure Cry 2.51100 1886 MD 18071vD 2.55. 310.00. az 409 dep~rture ; End Cry 2121 MD 20þO TVD ~~.'.L~::. :.:2:~: a:~.~54r.;.~e:~ur.:; .... ..... ..... j'S\i5""66tf'MCf":¡Ô'¡TTVD .:.:: t:~¥.1d%.1WiMRiiiFm~Nb ;'idF0D'::::: .::':: :::.:' '~':.: .....¡..... ....¿.m .....¡..... .....¡..... - ~,/n26:)MD"-:~1:~Tvr; - - - '- - - - - - - - - --:------ - r-sv:.r?~.:O~:V1[n:>;OTTVr.r - - - -.- - - -- ----------- ...-- - - - - ~ - _.- - - - - - . . . . j 9-518" qsg Pt2971 MD 2682 TVD \~ ------------ 36.69. :302.67. az 1046 departure þj~~- - - - - - ~ - - - - - - ¡ SV'1 2920 MD 26¡¡1 ¡Va ------ -..------ - - - ~JG3 3732MD 3292TVD TD/r Csg PI 8441 MD 7062TVD 36.94. 318.48" az 4292 departure :"'fjt~4i\:::~i~FMt5::2:~~~:i\7¡}._..::::::...~.... n... ;n.. ..... ..n. ...... .-... """""y""""""""""'''''''''''''''''''''''''''' ..... ..... +... ..... ,.... ....;.... ----...-- ----- ~---- Hold Angle 36.99° - - - ~JG1 4175MD ~~4l1V¡) . , , . . . . , -¡--------~- . . ------- . f'läAß?3~1'b.:i¡¡:,12'fV.D:'~ ',.... , Schrader Target ..... (::$2~P::MP.::' M!P.JYP~. . : 36.69. 302.67" az ~...?3~!1.deJ?~rtu.r~ .. <;r.1! 21,"90..... ..... .... 5484 MD 4697 TVD 36.69. 302.67. az 2537 departure ¡Ñ~~ 4iÜ~; M£) if;'? :¡:VD ... . pä' 5635 rJ;1) .1:j'37 T\)D .., ~5¡:;f B~~~;;:~ '54!~4"~~1D '46HfTv'Ö"" End Cry : 5957 MD 5077 TVD . . . . . . 5000 --"'-1"M2'5âtf"M'b7902T\TG..._.L..._~...._...._...._..._...._....t-....-..-.-..-. . 6000 - . ''''-'''''._''.''''-'' 2818 departur Hold Angle 36.94° . ~;rJ:1 'ë~;"~;:~"~1J:} ';-~'3i""7'./r5'" . . . . . . ¡ Tëp Ff.'":.a ~59'1?:D 027TTVa- ~- - - - - - Kuparuk Target 7834 MD 6577 TVD -:36:911. 318.48. az - - - 393~ departure - - -- - - -- . , ~-g¿3€""RRZ7~3mv1()!,1437Tv"1} ¡- - - - - - - - - - - - :;t:1 m41lD ì349:-;-VT - ;- - - - - - - ~ - - - - - - ~~~~~~n~-------r--- ----- . . . . ¡;:cu f?up""õ 8~ t..m f.'i'¿"? ~¡- - - - - -- -'----- . . . . . . .- - - - - - - ._- - - - -. -- - - - - - - - ¡K;;p A ~1"i2 ~.~G 6547 ¡YD ¡ ¡ 7000 ~....=....=..:ffd:,r::ë..zE.Mñ::'"s..Q:I\i.E.. - ,- - - - - - - ,..... - - - - - - ----- I 0 I 1000 I 2000 I 3000 Vertical Section Departure at 309.44 deg from (0.0,0.0). (1 in = 1000 feet) -5000 , -4000 I 3000 _. ^ ^ ^ I I- 0:: 0 Z 2000 _. 1000-.. I I- :J 0 en V V V 0- -1000 - ..¡. . i ~ -5000 ~ -4000 Client: Well : Field: PLAN VIEW BP Exploration Alaska V-I04 (P4) Structure: V-Pad Prudhoe Bay Unit - WOA Scale: Date: 1 in = 1000 ft 02-Jul-2002 -3000 , ..~ TO I T' Csg pt 8441 MD 7062 TVD 36.94° 318.48° az 2727 N 3315 W ..~....... 0'6- ~~ . ~ð): f'Ó> : 'Vc9o ...-t.....-..... - Kuparuk Target 7834 MD 6577 TVD 36.94° 318.48° az 2454 N 3073 W -2000 I 1000 , -1000 , 0 , True North Mag Dee ( E 25.830 ) ....~..... ""'¡"h' ....,;..... End Cry 5957 MD 5077 TVD /36.94° 318.48° az 1609 N 2326 W Cry 2/100 : m 5484 Mö".469'i"ïV5¡' 36.69° 302.67" az i 1426N 2112W i Schrader ~arget 5235 MD :4497 TVD 36.69° 3Q2.67° az 9-518" Csg PI ¡ 1346N 1p87W 2971 MD 268~TVD ¡ 36.69° 302.67f az : ..~.....'.f""M~l~~~!f::L+ ~ /V::;~~"~N' I i A; V A :~;.,;;:~" ~ I 1827 MD 1757 TVq 32.55° 310.00° az ¡ 242N 289W i .m'¡'.... .....}.... Ito/~ i -1qÍ7}(¡0 ~O') <:6''>0 I -3000 «< WEST ......m1'~r:.;.~~~..~/m_.. '. J\ ¡ 925 MD 922 TVD : : 10.00° 310.00° az i KOP Bid 1.51100 ¡ 33 N 40 W Cry 2/100 ¡ 300 MD 300 TVD : 800 MD 799¡TVD 0.00° 310.00° az 7.50° 310.0<1° az 0 N 0 E 21 N 25 W ¡ I -2000 ~ -1000 EAST »> ~ 1000 t 0 SchlumblPger 2000 , ..+.- 3000 '-.-" ..+..- 2000 ..+-1000 --' ..+.-0 ......---+-- - -1 000 t 2000 Company: Field: Reference Site: Reference Well: Reference Wellpath: B P Amoco Prudhoe Bay PB V Pad V-104 Plan V-104 ') Schlumberger Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 8440.97 ft Maximum Radius: 3000.00 ft Survey Program for Definitive Wellpath Date: 9/12/2001 Validated: No Planned From To Survey ft ft 28.50 1000.00 1000.00 8440.97 Casing Points Planned: Plan #4b V1 Planned: Plan #4b V1 Date: 7/2/2002 Time: 11 :39:38 Co-ordinate{NE) Reference: Vertical (TVD) Reference: Version: Toolcode GYD-GC-SS MWD+IFR+MS 4 ) Page: Well: V-104, True North V-104 plan 82.2 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name Gyrodata gyro single shots MWD + IFR + Multi Station 2971.25 2682.20 8440.97 7062.10 Summary EX WKUPST-01 PB V Pad PB V Pad PB V Pad PB V Pad PB V Pad 9.875 7.000 OffšefWéllþatb Well WKUPST-01 V-100 V-101 V-102 V-106 V-201 12.250 8.750 97/8" 7" WKUPST-01 V1 V-100 V7 V-101 V7 V-102 V5 V-106 V10 V-201 V8 Referençe MD ft 8434.12 298.60 1103.68 497.98 249.39 1439.48 Offset MD ft 6250.00 300.00 1100.00 500.00 250.00 1450.00 Ctt~CtrNo-Gò DištänceArea ft ft 1862.40 0.00 308.34 5.23 30.83 17.58 63.76 9.53 176.02 4.32 48.94 25.29 Allówable Deviation ft 1862.40 303.12 13.25 54.23 171.69 24.14 Pass: Minor 1/200 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Site: PB V Pad Drilling Target Conf.: 99% Description: Map Northing: 5971395.00 ft Map Easting : 588480.00 ft Latitude: 70019'53.956N Shape: Circle ) Target: V-I04 SB Tgt "'l 11: V-104 )ed on: Planned Program vertical Depth: 4415.00 ft below Mean Sea Level Local +N/-S: 1345.53 ft Local +E/-W: -1986.57 ft Longitude: 149°16'56.250W Radius: 150 ft IlOO 1500 1500 14-00 1300 1200 1100 0 C) C) C) C) C) CJ 0 0 C) C) C) C) C) CJ 0 0 ~ C) CT CD I LO 0 ~ J GJ GJ 0 J J I I ~ J Polygon 1 2 3 4 Site: PB V Pad Drilling Target Conf.: 99% Description: Map Northing: 5972490.00 ft Map Easting : 587380.00 ft Latitude: 70020'04.852N +N/-S ft -166.76 -163.13 161.88 158.25 '') Target: V-I 04 Kup Tgt .' +E/-W ft 143.01 -157.00 -153.07 146.94 --J ll: V -104 Jed on: Planned Program Vertical Depth: 6495.00 ft below Mean Sea Level Local +N/-S: 2453.81 ft Local +E/-W: -3073.38 ft Longitude: 149°17'27.996W Northing ft 5972324.99 5972325.00 5972650.01 5972650.00 Easting ft 587525.00 587224.99 587225.00 587525.01 800 2100 2500 '" 2500 24-00 / 2300 2200 0 C) C) C) C) C) C) 0 0 C) C) C) C) C) C) 0 0 ( N C) CT CD I 0 0 ~ ~ (I) (I) (I) r"J N r"J 0 ~ ~ I I I I I I ~ ~ ') -) V-104i Well ,Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates may be encountered near the base of the Permafrost at 1857'MD and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: . A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. . The production section will be drilled with a recommended mud weight of 10.1 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.8 pore pressure. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . V-104i will cross a fault at -4625' TVD (+/-150'). The estimated throw of the fault is approximately 160'. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies H 206973 DATE 7/01/02 INVOICE / CREDIT MEMO CK0626021 \(-- \ CY4; DESCRIPTION Permit to Drill Fee MøW"",,~, '\,""("";~"t~').~ -;.~.." "~.""-,','.~,'''7, '.'.:~";.'~\:,",':-;'~',~"~\¡.':", Êo .f ~f~ ::," '~:t/.',':" ;.t.. i., "U¡," ~t:,. ': . ,.,"~,'~,' t\.."I'~C:K.I>'Ÿ1", f ....."~~:~ '" "..k" 'h'~ l~' """, '.IF' "~~;t~ . .~':'~t%~~..~~~"~l.\r ,'. '.'.. 'l~~@.:(¡¡tl':;'¡:I';~;''''\'' : ..f.-:"..,;-..., .'; , ~":"::t=~~= GROSS RECE"'ED 'I ':\ J¡UL 8.2 )02 , .\ I , ':q Alaska Oil & Gas Cons. comffilSs'on Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ..... No. H 20S973 BP EXPLORATION, (ALASKA) INC. P,O. BOX 196612 ANCHORAGE, ALASKA 99519~6612 PAY TO THE ORDER OF ALASKA STATE ALASKA OIL & COMMISSION 333 W 7TH AVE ANCHORAGE, AK. STE 100 99501 III 20bg? 3111 -:0... ¡. 20 jagS-: ooa...... ¡.g,,1 , J H -' .~ CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTIOX INJECTION WELL REDRILL Rev: 6/18/02 C\jody\templates ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ) WELL NAME ?'¿~ v-Io'l/ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CLUE" The permit is for a new wellbore segment of existing well --' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). ANNULAR DISPOSAL Please note that an disposal of fluids generated. .. INTO ANNULUS OF ANOTHER WELL ON SAME PAD <-) SP ACING EXCEPTION DRY DITCH SAMPLE Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY fUJ:X WELL NAME.PB~ (/ .... II) '/J' PROGRAM: Exp - Dev - Redrll - Se~ ~ Wellbore seg - Ann. disposal para req -. FIELD&POOL Ç;9"'./~{",,) , INITCLASS /--~.¥ ^ GEOLAREA ç;'jr" UNIT# //Ç.L;ð ON/OFFSHORE nit) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . Y. . . . . . 'Y\\ N 2. Lease number appropriate. . . . . .. . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . .. . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N A~ _D~Tji 12. Permit can be issued without administrative approval.. . . . . Y N ..~ ~Wð2.. 13. Can permit be approved before 15-day wait.. . . . . . . .' . . ;:p N I ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . - ~' N J¿,,:; .t'@I(O. 15. Surface casing protects all known USDWs. . . . . . . . . . . ì N. ~ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ~, M.t 1 ÜI A./Ìf e¡.C2-S ç . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ (j 18. CMT will cover all known productive horizons. . . . . . . . . . ~, N ~~: ~~:~~a~:~~~~~::~i~:~~~~~it::~~:~r~~f~o~t.. : : :: : : ~ ~ ^lQ,~Qr~ ~G~ 21. If a re-drill,'has a 10-403 for abandonment been approved. . . --¥-M" ""It 22. Adequate wellbore separation proposed.. . . . . . . . . .-. . ¡<j2 N 23. If diverter required, does it meet regulations. . . . . . . . . . ~~'" N 24. Drilling fluid program schematic & equip list adequate. . . . . ' , N 25. BOPEs, do they meet regulation. . . . . . . . . . . .. . . . -' N +- t 26. BOPE press rating appropriate; test to L.J- 0 0 ~ psig. ' N M ~ P :: 7,751:) P So /. lJ1u ~7'" ¥#'-;J '-/Oø f!-<", 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N 28. Work will occur without operation shutdown. . . . . . . . . . . ~, 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y, , 30. Permit can be issued w/o hydrogen sulfide measures. . . . . N 31. Data presented on potential overpressure zones. . . . . .. ?N ~ / ,¿ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / l-/" " h A~R .PM~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ¥ /. ;prtÝ -7. 34. Contact name/phone for weekly progress reports [exploratory ?n. Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. ., to surface; (C) will not impair mechanical integrity of the well used for dispos (D) will not damage producing formation or impair recovery fro a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.4 Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPÞ JDH ~,.. #~ WGA ~r :¡,J ~/ 'fJGA- 7/Klo l- - GEOLOGY APPR DATE 11f~ ~~z. Comments/Instructions: COT, . DTS~7/C'17Iø?- G:\geology\permits\checklist.doc
