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Home My WebLink About202-154CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector S-215 (PTD #2021540) will lapse on AOGCC MIT-IA Date:Thursday, November 6, 2025 11:26:17 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 6, 2025 11:01 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S-215 (PTD #2021540) will lapse on AOGCC MIT-IA Mr. Wallace, Injector S-215 (PTD # 2021540) is due for its 4-year AOGCC MIT-IA in November 2025. It is currently shut-in with no plans to put on injection by the end of the month. The well is now classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 S-215 202154 500292310700 3 9/19/2023 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 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Matt Herrera. Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, December 10, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC S-215 PRUDHOE BAY UN POL S-215 Src: Inspector Reviewed By: P.I. Supry— Comm Well Name PRUDHOE BAY UN POL S-215 API Well Number 50-029-23107-00-00 Inspector Name: Matt Herrera Permit Number: 202-154-0 Inspection Date:11/28/2021 II1Sp Num: mitMF[-1211129104748 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 9l S-215 Type Inj W ' TVD 4595 Tubing 1678 1676j, 1671 1670 2021540 ' Type Test SPT' Test psi 1500 I A 142 2532395 2373 BBL Pumped: 2.3 BBL Returned: 2.1 OA 35 34 31 28 Interval 4YRTST p/F P Notes: MIT -IA Performed to 2500 PSI Per Operations es� etu (o(si I zaz I � z�—1 Friday, December 10, 2021 Page 1 of 1 From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector S-215 (PTD #2021540) due for AOGCC MIT-IA Date:Monday, November 22, 2021 10:20:53 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 18, 2021 12:27 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector S-215 (PTD #2021540) due for AOGCC MIT-IA Mr. Wallace, Injector S-215 (PTD #2021540) is ready to be put online. An AOGCC MIT-IA will be performed when the well is thermally stable. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, October 16, 2021 2:55 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S-215 (PTD #2021540) due for AOGCC MIT-IA Mr. Wallace, Injector S-215 (PTD #2021540) is due for its 4-year AOGCC MIT-IA this month. The well is currently shut-in and may not be online before the end of the month. The well will now be classified as NOT OPERABLE for tracking purposes. When the well is ready for injection, it will be made Operable and an AOGCC MIT-IA will be performed when stable. Please respond with any questions. Andy Ogg 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 9:16 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector S-215 (PTD #2021540) due for AOGCC MIT-IA From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, October 16, 2021 2:55 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector S‐215 (PTD #2021540) due for AOGCC MIT‐IA Mr. Wallace, Injector S‐215 (PTD #2021540) is due for its 4‐year AOGCC MIT‐IA this month. The well is currently shut‐in and may not be online before the end of the month. The well will now be classified as NOT OPERABLE for tracking purposes. When the well is ready for injection, it will be made Operable and an AOGCC MIT‐IA will be performed when stable. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Reggr.- 6"/1 DATE: Thursday,October 12,2017 P.I.Supervisor N f 1 `U(/t.( 1 SUBJECT: Mechanical Integrity Tests f BP EXPLORATION(ALASKA)INC. S-215 FROM: Lou Laubenstein PRUDHOE BAY UN POL S-215 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL S-215 API Well Number 50-029-23107-00-00 Inspector Name: Lou Laubenstein Permit Number: 202-154-0 Inspection Date: 10/12/2017 Insp Num: mitLOL171012141028 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well s_215 !Type Inj W TVD 4595 - Tubing 1304 ` 1301 ' 1301 1302 PTD 2021540 Type TesyPT Test psi 1500 ' IA 17 2497 ' 2422 ' 2409 BBL Pumped: 1.8 BBL Returned: 1.5 OA 48 49 - 48 - 48 ' Interval 4YRTST [P/F P 4/ Notes: SCANNED FE 2,0 Thursday,October 12,2017 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON • • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:MBE Treatment I! 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 1 202-154 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ® 6. API Number: • 50-029-23107-00-00 7. Property Designation(Lease Number): ADL 0028258 , 8. Well Name and Number: , PLRS S-215 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,POLARIS OIL RECEIVED 11.Present Well Condition Summary: 8 Total Depth: measured . 6930 feet Plugs measured 6366,6536 feet 0 2015 true vertical .. 5523 feet Junk measured None feet �� w Effective Depth: measured 6366 feet Packer measured See Attachment feet #(,,,,'f` true vertical 5147 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#A-53 34-114 34-114 1533 515 Surface 2912 9-5/8"40#L-80 33-2946 33-2847 . ...,...- -•••5•758 -•�� 3090 Intermediate Production 6884 7"26#L-80 31 -6915 31 -5513 7240 5410 Liner Perforation Depth: Measured depth: See Attachment feet e to 3 21 True vertical depth: See Attachment feet SCAB Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 6098'-6595' Treatment descriptions including volumes used and final pressure: 550LBS CRYSTAL SEAL 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations II Exploratory ❑ Development 0 Service ® • Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG m • GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-379 Contact Summerhays,Nita M(WI r N Technologies) ,J Email Nita.Summerhays@bp.com Printed Name Summerhays, IPRO Technologies) ,/ Title Petrotechnical Data Manager Signatu�/ j' �; /%► Phone +1 907 564-4035 Date 09/03/2015 Form 10-404 Revised 5/2015 k TL `/j i{ 1 4.- r RSDMS SEP 10 2015 Submit Original Only • • • Daily Report of Well Operations PLRS S-215 ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL***(profile-mod) SET 3-1/2"WHIDDON @ 6327' SLM PULLED ST#4 RKP-FS FROM 6307' SLM, 6326' MD PULLED ST#5 RK-DGLV FROM 6278' SLM, 6297' MD 8/5/2015 ***JOB CONTINUED ON 8/6/15*** ***JOB CONTINUED FROM 8/5/15***(profile-mod) PULLED 3-1/2" EMPTY CATCHER FROM 6327' SLM 8/6/2015 ***JOB COMPLET WELL TURNED OVER TO PAD OP*** T/I/0=188/vac/vac Temp.=S/I (PROFILE MODIFICATION) Pumped 5 bbls meth spear, 38 bbls DSL, followed by 145 bbls of 110*f 2% KCL to load/Injectivity test. Pumped 39 bbls DSL down TBG for freeze protect, FWHP= 200/0/Vac Valve position @ departure WV, SV, SSV= Closed 8/6/2015 MV= Open IA& OA= OTG HES - Crystal Seal MBE Treatment; MIRU HES pumpers. PT treatment lines to 275 psi low and 4175 psi high. Open well and fluid pack with 60 bbls of 3% KCL. Initial injection 3 bpm @ 1100 psi. Elected to perform treatment at 2 bpm. Pumped Crystal Seal treatment in stages at 2 bpm. Initial stage (0.10 ppa) of CrystalSeal injection 2 bpm @ 950 psi. During the 2nd stage (0.15 ppa) entering the formation, achieved 300+ psi bump in treatment pressure with partial 3rd stage (0.20 ppa) in tubing. Cut to flush and displaced Crystal Seal with 35 bbls of 3% KCL followed by 22 bbls of 50/50 meth for freeze protect. Final CrystalSeal treating pressure 2 bpm @ 1350 psi. Pumped a total of 550 lbs of CrystalSeal. Final SIWHP = 1045 psi. Secure well. Well to remain SI for at least 8/8/2015 24 hrs. ***Job Complete *** T/I/O=0/0/0. Temp=Sl. Injectivity test. Pumped 24.25 bbls of diesel to preform injectivity test. FWHP=0/0/0 SV,WV,SSV= closed IA,OA= OTG 8/10/2015 ***WELL S/I ON DEPARTURE*** (Profile Modification) RIGGED UP SWCP 4520 8/11/2015 ***WSR CONTINUED ON 8/12/15*** ***WSR CONTINUED FROM 8/11/15*** (Profile Modification) BAILED CRYSTAL SEAL FROM 6,307' SLM TO 6,337' SLM w/2.25 BAILERS. SET 3-1/2"WHIDDON @ 6,337' SLM. SET RK-DGLV IN ST#5 @ 6,297' MD. SET RK-WFR IN ST#4 @ 6,377' MD. LRS PERFORMS SRT ON ST#4 (OBa), (Read Log for Details). SET 3-1/2"X SELECTIVE TEST TOOL @ 6,196' MD. 8/12/2015 ***WSR CONTINUED ON 8/13/15*** T/I/O= 106/0/0 Temp=SI Assist slickline. Flush open pocket with 12.5 bbls diesel. Pump 16.5 bbls 8/12/2015 diesel to perform injectivity test on station #7- PASS. Job continued on 8-13-15 WSR Job continued from 8-12-15 WSR Pumped a total of 125 bbls diesel for injectivity tests. Perform Injectivity test on station #5 and#7- Pass. Perform injectivity test on all stations- Pass per slickline 8/13/2015 PE. See log for details. SLB in control of well at departure. FWHP 475/0/0 • • Daily Report of Well Operations PLRS S-215 ***WSR CONTINUED FROM 8/12/15*** (Profile Modification) PULLED 3-1/2"X SELECTIVE TEST TOOL @ 6,196' MD. SET 3-1/2"X SELECTIVE TEST TOOL©6,291' MD. PULLED RK-DGLV IN ST#7 @ 6,227' MD. SET RK-WFR IN ST#7 @ 6,227' MD. PULLED 3-1/2"X SELECTIVE TEST TOOL @ 6,291' MD. LRS PERFORMS SRT ON ST#7 & ST#4 (OA& OBa), (Read Log for Details). RAN 2.25" PUMP BAILER. PULLED 3-1/2"WHIDDON @ 6,337' SLM. RAN 2.25" PUMP BAILER. PULLED PX-PRONG @ 6,366' MD. RAN 2.25' PUMP BAILER. PULLED PX-PLUG BODY @ 6,366' MD. LRS PERFORMS SRT ON ST#7, ST#4, ST#2 & ST# 1 (OA, OBa, OBb, OBc, OBd &OBe), (Read Log for Details). 8/13/2015 ***JOB COMPLETE*** ***WSR CONTINUED FROM 8/13/15*** (Profile Modification) TRAVEL TO MAINTENANCE 8/14/2015 ***JOB COMPLETE*** Fluids Summary BBLS Type 206 DIESEL 5 METH 145 2% KCL 27 50/50 METH 195 3% KCL 578 Total Fluids Summary LBS Type 550 CRYSTAL SEAL 550 Total o • co co co m Ln co co ti co 6 <- co r- L 4 Ln CO CO N Ln V CD N N 0. 00 N6 4o0 O O O 4 N- O a> CO o0 v- N- 00 c) to N co Cp O O D) 0) 0 0 CD .- .- Lo N (N C) 0 d' Ln Lo Ln Ln Ln Ln LO Ln > I- 0. 0 I•' O LU CO CO Ln Ln Cr) 0) CD A- N = 0) . CD CO CO CO Nr V N- o Co 0• D) L CO O C'O O O O 4 M 0 to 0) O N- o co a) V t.C) 0) O O o) 0 0 A- r N N (N o V Ln to to co to to co Lo > I- a CD W m 0 W F- rY t 0 0 0 0 o N O o 1.0 LO Ln W J W W O. s- CO N.- CD CO VCO Ln N '?' C) CC W J 0 = C d r N N CO CO Ln Lo Ln < J 6 J a) O CDOCOCDOOCDOCOCDCD 0 0 Z O D O E V)CD H I- Q = 0 a W > O < 2 ZwZOILO O EliO a O W z O ✓ D. Y O O O co v) m CO N aI CO(n o I- C Cl) = CO C) o CD LO N Ln CD Lo Ln U) O a/ 0- O) N Ln C) COC) N CDLnCO D C) A- N N COC) Ln Ln Ln }r J CD Cfl CO Cfl CD CD CD CD Cfl CD CD N � aID O E a J = H a Cl.accCL 2 2 O co co co co co O Q. a) a 0 C) c •° 0 0 0 U 0 O U 0 U U U m F- I- I- I- I- I- I- H I- I--- I- t `m Cn Cn Cn (n co co (n co Cn (n (n 0. O t a) a a) F- MN." N- r- in in VD O 0 0 6 r- <- Ln in in Ln in C] 0 c o 0 0 0 0 o W W z O o O O O W 0• 0 0�0 ap M M I� N N N N N OO tY cn W N a CC A. N N N N N C\co MO CMD CMD C\�D Z „JCC 0 0 W a w 0. CO a0 CO N N Cr) < 0 J I- -I -J .J D CC a O m o D W Q 0 W W Q a cn LL u_ a co a s tu E m Z Ln Lo Ln Ln Ln LO Ln Ln Ln LO Ln N N N N N N N N N u. a W O U- NN WN N mmJ an Un n UUUOOUw < < u_ 1 co c) a tY S • • m Q,n0O � p O U - M c) 0 0 0 a- M M cr CO O ti N I-- 00 c) • N- M M O I� CO O CO N O Ln 1 1 1 1 1 H ▪ CO O CO CO CO N CO 4.4 G) (O LO v r O LO 0) 0) co 10 N (O11111 CO v o < N v CO O) O a) CO CO CO CO N CO a▪ / O o CO CO00 CO Lo CO e J CO J .� • 4.)N cD N 0) U 00 - CV N N p) V M t N Nt O CO N C aO O) (0 Ln N M CO Z a)0 2 c l— W f— U Uu_ O Z Z Z Et O m m U (1) a_ I— • • Packers and SSV's Attachment PLRS S-215 SW Name Type MD TVD Depscription S-215 Packer 5560.47 4,598.48 3-1/2" HES Dual Feedthru S-215 Packer 6061.81 4,934.50 3-1/2" HES Dual Feedthru S-215 Packer 6211.86 5,040.49 3-1/2" HES Dual Feedthru S-215 Packer 6287.55 5,093.44 3-1/2" HES Dual Feedthru S-215 Packer 6346.27 5,133.49 3-1/2" HES Dual Feedthru S-215 Packer 6477.25 5,222.29 3-1/2" HES Single Feedthru 1HEE= CNV 41/16'5M11111 NDTES: 1-126 READINGS AVERAGE 125 ppm WELL D • 11"FMC S-215 W ©N ML Wi31 REWIRES A SSSV WHEN ON MI ACTUATOR= BAKER I$PKR Q 5655'IS'PULL TO RELEASE'BUT CAN OKB Ely= 71.5' ALSO BE RELEASED BY PRESS. DO NOT EXCEL 2000 BE.ELEV= 41' 41/2'X 3-1/2' - 24' J I PSI ON THE IA w/OUT PERMING TBG MOVEMENT KOP= 2238' XO,D=2.992' Mu CALC'S&DISCUSSING w I APE'"' MAngle= 50'@ 3438' _ tum vi = " Da6256' 2606' -3-1/2'HES X NP,D=2.813' Datum TVD= 5000'SS GAS LFT MANDRELS ST MD NO DEV TYPE VLV LATCH PORT DATE 20'X 34"NSIJLATE)CONDUCTOR -I 114' 9 5479 4545 49 WIG DMY RK 0 11/11/07 91.5#,A53ERW,ID=19.124" 6639' H3-12"HES X NP,D=2.813' TAM FORT COLLAR 1- 976' 9-5/8'CSG,40#,L-80 BTC,D=8.835' H 2946' 7'X 3-1/2'I IC..,DUAL F�TFRLJ PKR,D=2.985" - 6566' 6697 HFIOLE N N7'CSG(NIG 07/30/07) M WATER INJECTION MANUS • ST I ) TVD DEV TYPE VLV LATCH PORT DATE T MARKER DONT 5741' 1-2 8 6177 5016 45 MMC-W DMY RK 0 08/30(07 7'X 3-1/2'HIES DUAL FEEDTFiRl17 6227 5051 45 MMC-W P-15XJR RK 11 08/13/15 PKR,I)-2.965' (-- 6II67' / 6 6263 5077 46 1•941G-W DMY RK 0 03/18/13 5 6297 5100 47 MMG-W DMY RK 0 08/13/15 Minimum ID =2.750" @ 6536" Mr 4 6326 5119 47 MG-W R15XJR RK 12 08/13/15 3-1/2" HES XN NIPPLE I M 3 6377 5155 47 MMG-W DMY RK 0 08/30/07 2 6448 5203 48 MNCrW P-15X1R RK 12 09/17/14 1 64% 5235 48 MIGW R15XJR RK 14 09/17/14 1 T MA RIKE32 Jowl- H 6204' 1--9 - 7'X 3-1/2'ISS DUAL Fffi3TH RU PKR,D=2.965' H 62°3 6196' 3 12'I IVs X NP,D=2.813' 1 6220' ---1 PHOENIX SENSOR SUB,D=2.992" 1 3-1/2'RA PP TAG 6277' I M 7"X 3-12"HES CJUA L FEE{33TFRU PKR,D=2.965" H 6282' ' 6291' 1-3-1/2'HES X NP,D=2.813' PBRFORATIDN SU...ARV Mr REF LOG:SPERRY O ON 08/06/02 = ' MO 6341' H7'X 3-1/2'SINGLE FffiTl-18J PKK,D=2.965' ANGLE AT TOP PERF: 45° 6098' 7ga :3 6364' R-I0E Nd(SENSOR SLB,D=2.992' Note:Refer b Production DB for historical perf dab P II SIZE SFF ZCNE INTERVAL Opn/Sqz SHOT SCE 2-7/8' 2 Nb 6098-6110 0 05/06/03 1 I I 6366' -3-1/2'HES X NP,D=2.813' 2-7/8' 2 6120-6130 0 05/06/03 I 2-7/8" 2 Pb 6150-6170 0 05/06/03 2-7/8' 2 OA 6240-6260 0 05/136/03 2-7/8" 2 6265-6280 0 05106/03 M, / 6477 7'X 3-1/2'SINGLE FESTTFRU PKR,D=2.985' 2-7/8' 2 OBa 6302-6342 0 05/06/03 6486' H3-12'HES X NP,D=2.813' 2-78' 2 OBb 6355-6380 CYC 05/06/03 2-7/8' 2 OBc 6430-6450 C 05/06/03 2-7/8' 6 Obd 6505-6525 C 03/31/03 ' 6616' }-3 12"FES X NP,ID=2.813' 2-7/8' 2 6525-6545 C 05/06/03 2-718' 2 Obe 6585 6595 C 05/06103 8 6636' H 3-12"FPS XN NP,D=2.750' 1 6636' -3-1/2'HES PXN PLUG(07/09/14) 3-1/2'TBG,9.2#,L-80 TCI,.0087 bpi,D=2.992' H 6648' 1-- , 6648' -3-12'1ALEG,D=2.992' PM - 6834' I HELMD NOT LOGGED 7'CSG,26#,L-80 BTC,.0383 bpi,D=6.276" - 6916' ..•1.............1.0 DATE REV BY CONVENTS DATE REV BY CX)M ENTS POLARIS INT 08/16(02 D-14 ORIGINAL COMPLETION 03/02/15 LEC/JM)WFR C/O(02/23/15) WELL 5-215 08/31/07 NOES MVO 06/03/15 JLC/PJC SET PX PLUG FERMI-Pb:'2021540 05/22/13 BSE/JM?WFR CIO(05/06/13) 06/06/15 JLC/PJCWFR CIO AR Pb: 50-029-23107-00 07/15/141M(P'JM7 PILL./RESET PXN PLUG(7/9/14) 08/28/15 JTG/JM)PIAL PX PLUG/WFR C/O(08/13115) SEC 35,T12N,R12E,2003'FPL&717'FWL 07/15/14 JKOJM) GLV C/0(07/11/14) 09/22/14 LEC/ 10.6 IAFR C/O(09/17/14) BP Exploration(Alaska) • • OF 71„, y�s� THE STATE Alaska Oil and Gas ��.��, ofAAS KA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279.1433 OFALASµ Fax: 907.276.7542 www aogcc.alaska gay' scomE© JUL 0 8 2UFJ Eric Zoesch Production Engineer �1 — 1E9- BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PLRS S-215 Sundry Number: 315-379 Dear Mr. Zoesch: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ICg7 Daniel T. Seamount, Jr. .1 Commissioner DATED this Z2hi of June, 2015 Encl. • RECEIVED JUN 1 7 2015 STATE OF ALASKA / ✓6\A,�� ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC ate APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well ❑ Other. MBE Treatment E] 2 Operator Name 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 202-154 ' 3.AddressStratigraphic ❑ Service 0 • 6.API Number P.O Box 196612,Anchorage,AK 99519-6612 50-029-23107-00-00 . 7 If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? PLRS S-215 . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL0028258 . PRUDHOE BAY, POLARIS OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6930 • 5523 . 6366 5147 See Attachment None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91 5#A-53 33.87-113.87 33.87-113 87 Surface 2912 9-5/8"40#L-80 33.37-2945.8 33.37-2847.35 5750 3090 Intermediate None None None None None None Production 6884 7"26#L-80 30.92-6914.97 30.92-5513.28 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth ND(ft). Tubing Size Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft) See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12 Attachments. Description Summary of Proposal ❑ 13 Well Class after proposed work. Detailed Operations Program E BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0• 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 2• GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge_ Contact Eric Zoesch Email Eric.Zoesch@BP.Com Printed Name Eric Zoesch Title Production Engineer Signature Phone 564-4695 Date /// ///� Prepared by Garry Catron 564-4424 icsN___________ COMMISSION USE ONLY 6 b Conditions of approval: Notify Commission so that a representative may witness Sundry Number. , S 7q Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No Subsequent Form Required: /a — 40 F APPROVED BY Date /2Z// Approved by 0 ' COMMISSIONER THE COMMISSION VTL (''B''5 ORIGINAL ,;__ 6 it). /s---- Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of appro\ Submit Form and Attachments in Duplicate RBDMII1M 7 L 701c Plug Attachment 202-154 Well Date MD Plug Type TVD S-215 6/3/2015 6366 3-1/2" PX Plug 5147 S-215 7/10/2014 6536 3-1/2" HES XN Plug 5190 Perforation Attachment 202-154 Well Date Perf Code MD Top MD Base TVD Top , TVD Base S-215 8/28/07 STC 6098 6110 4960 4968 S-215 8/28/07 STC 6120 6130 4976 4983 S-215 8/28/07 STC 6150 6170 4997 5011 S-215 2/23/15 STC 6240 6260 5060 5074 S-215 2/23/15 STC 6265 6280 5078 5088 S-215 9/17/14 STO 6302 6342 5103 5131 S-215 6/3/15 STC 6355 6380 5139 5156 S-215 6/3/15 STC 6430 6450 5190 - 5204 S-215 6/3/15 STC 6505 6525 5241 5254 S-215 6/3/15 STC 6525 6545 5254 5267 S-215 r 6/3/15 STC 6585 6595 5294 5300 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF - CO o 0 0 0 ct5CO CO CO CO Q J J J J a) eL Lo •O- O) O Co • j V O inLO CC) M N- U '— Co V CC) p M O O O M N N- � O CO N- LU CO a) Cn • CO N- M CCl V O N- a CO CO CO NN LU F— Q 0 CO O) O O CO Co C7 N M i F— CD cp C L(- N LUCY O m O) O) M U) Nco N m 0) 0 C N o_ 0 U O co co CO N CO CO CD O O 1-0 O 00 1. CO • CO J CD 4t CO N to y4. V N • (n CO r O Nco O r Cf) N Cr) CO 5 szt N V O co N C CO CO O) ' C1) CO N Co Z O �• H F- w U U 0 0 w Z Z ZOCrmm O 1 D D D Uwv) F- 1- • Packers and SSV's Attachment 202-154 Well Facility Type MD Top Description TVD Top S-215 PACKER 5560 3-1/2" HES Dual Feedthru Packer 4598 S-215 PACKER 6062 3-1/2" HES Dual Feedthru Packer 4935 S-215 PACKER 6212 3-1/2" HES Dual Feedthru Packer 5040 S-215 PACKER 6288 3-1/2" HES Dual Feedthru Packer 5093 S-215 PACKER 6346 3-1/2" HES Dual Feedthru Packer 5133 S-215 PACKER 6477 3-1/2" HES Single Feedthru Packer 5222 bp To: AOGCC Date: June 11, 2015 From: Eric Zoesch, Polaris PE 907-564-4695 Subject: S-215 MBE Treatment Step Unit Operation 1 FB Bullhead polymer 2 FB Post treatment injectivity test 3 S Set new WFRV design, pull plug HISTORY S-215 is a regulated Schrader Bluff injector in the Polaris field. The well supports pentalateral producer S-213 alongside injectors S-217 and S-218. S-215 has zonal downhole pressure gauges, and the OBa zone has a suspiciously low pressure while on injection. Watercut fluctuations in S-213 also seem to correlate with S-215's injection status, so based on these two anomalies an open- pocket step-rate-test was performed on S-215's OBa in early June. This test showed high injectivity, on the order of 3 bwpd/psi. This is similar to rate seen in other wells with known MBE's in Orion field, so the decision has been made to pump a remediation job with water swelling polymer. The well was left as-is following the injectivity tests, meaning it's set up for a MBE job without further intervention. OBJECTIVE The objective of this job is to remediate the MBE from S-215 to S-213 by pumping water swelling granular cross linked synthetic polymer gel into the matrix breakthrough. CRITICAL ISSUES • Shut in offset producers and injectors to allow reservoir conditions to stabilize • High pre-treatment injectivity to minimize transit time of polymer through tubing to formation • Ensure cleanliness of pump equipment and hard line (pre and post job) • Properly dispose of remnant fluid per guidance from the Environmental Team PROCEDURE 1. Shut in offset producer and injectors prior to pumping treatment. 2. Bullhead polymer from surface down tubing into OBa sand. 3. Perform post-treatment injectivity test. 4. Set new water flood regulator valves in stations 4 and 7. 5. Pull plug at 6366'. 6. Return well to injection ATTACHMENTS A. S-215 Well Bore Schematic TREE= CNV 4-1/16"5M Y NOTES: H2S READINGS AVERAGE 125 ppm WaLHERD= 11"FMC S-215 _215 WFB+I ON MI.WELL REQUIRES A SSSV WHEN ON MI ACTUATOR= BAKER HES PKR@ 5555'IS"PULL TO RELEASE'BUT CAN OKB.E.EV= 71.5' ALSO BE RE EASE)BY PRESS. DO NOT IXC®2000 BF.ELEV= 41'" X0/2" X 3-1/2" H 24' L ) IER PSI ON'TFE IA w/OUT PERFORMING TBG MOVEMENT KOP= 2238' CALC'S 8 DISCILSSING w/APE"` Max Angle= 50 3438' — — Datum MD= 6256' 2505` -H3-1/2"HES X NP,D=2.813" I GAS LIFT MANDRELS Datum TVD= 5000'SS //'. ••• ST MD IVD DEV TYPE V LV LATCH PORT DATE 20"X 34"NSULATED CONDUCTOR H 114' 9 5479 4545 49 MMG DMY RK 0 11/11/07 91.5#,A53 ERW,D=19.124" 5539' —,3-1/2"I IES X NP,D=2.813" TAM FORT COLLAR --I 976' 9-5/8"CSG,40#,L-80 BTC,ID=8.835' —I 2946' I 5597' I—HOLE N 7"CSG(RIG 07/30/07) 7'X 3-1/2"HES DUAL FEEDTl- RU RCR D=2.965' —I 5555' x AM WATER NJECTION MANDRELS • ST MD TVD DEV TYPE VLV LATCH FORT DATE 7'MARKER JOINT -I 5741' —t 8 6177 5016 45 MMG-W DMY RK 0 08/30/07 7 6227 5051 45 MNG-W DMY RK 0 06/06/15 7"X 3-1/2'HES DUAL FEE)TI-RU FKR,D=2.965' —I 6057' x �/ 6 6263 5077 46 MNG-W DM'( RK 0 03/18/13 Minimum ID =2.750" 6536" 5 6297 5100 47 MMG-W DMY RK 0 08/30/07 4 6326 5119 47 AMG-W FS RKP - 06/06/15 3-1/2" HES XN NIPPLE 13 6377 5155 47 MMG-W DAY RK 0 08/30/07 2 6448 5203 48 M G-W P-15XJR FE 12 09/17/14 1 6496 5235 48 P lG-W P-15XJR FE 14 09/17/14 7'MARKER JOINT -I 6204' I----t 1 7"X 3-1/2"HES DUAL FEEDTFRJ PKR,D=2.965" - 6207' 6196' -I3 1/2"HES X tom,D=2.813' X ,4 6220' H PHOENIX SENSOR SUB,D=2.997 3-1/7 RA PP TAG —{ 6277' I 7"X 3-1/2"HES DUAL F®TI-RU PKR,D=2.965' —I 6282' .� ' , 6291' I—3-1/2"I IES X NP,D=2.813" PERFORATION SUMMARY REF LOG:SMM)ON 08/06/02 ' SPERM' 6341' H 7"X 3-1/7 SINGLE FEEDTHRU PKR,0=2.965" ANGLE AT TOP FERE: 4500 6098' 13 6354'6354' H PHOENIXSENSOR SUB,D=2.992" Note:Refer to R-oduction DB for historical perf data V\ SIZE SP ZONE NTERVAL Opn/Sqz SHOT SOZ I 2-718" 2 Nb '6098-6110 0 05/06/03 18� 6366' I-13-112"HES X NP,I)=2.813" 2-718" 2 6120-6130 0 05/06/03 in 6366' H3-112"PX PLUG(06/03/15) 2-7/8" 2 Nc 6150-6170 0 05/06/03 ' 2-7/8" 2 OA 6240-6260 0 05/06/03 2-7/8" 2 6265-6280 0 05/06/03 6472' I- 7"X 3-1/2'SCICLE F®l7'IFS I PKR,D=2965" 2-7/8' 2 OBa 6302-6342 0 05/06/03 2-7/8" 2 OBb 6355-6380 O/C 05/06/03 I I 6485' —I3-112"HES X RMP,D=2.813" 2-7/8" 2 OBc 6430-6450 C 05/06/03 2-7/8" 6 Obd 6505-6525 C 03/31/03 2-7/8" 2 6525-6545 C 05/06/03 I I I 6515' --I3-1/2"HES X NP,I)=2.813" 2-7/8" 2 Obe 6585-6595 C 05/06/03 6536' 3-1/2"HES XN IMP,D=2.750" 181 6536' H3-1/7 HES PXN RUG(07/09/14) 3-1/2'TBG,9.2#,L-80 TCI,.0087 bpf,0=2.997 —I 6548' I---/ ' I 6548' —I 3-1/WLEG,�D�2.992" ED FBTD I— 6834' 1......../4..........1 „',',',',',',./41 -i; 7”CSG,26#,L-80 BTC,.0383 bpf,D=6.276" --I 6915' �'�'�'�'.'� 0'1 DATE REV BY COMMENTS DATE REV BY C OMIVENTS POLARIS UNIT 08/16/02+ 1114 MGM L COMPLETWN 03/02/15 LECJJMD WFR C/O(02123/15) WELL: S-215 08/31/07 N9ES RWO 06/03/15 JLCJPJC SET PX PLUG FERMI No:"2021540 05/22/13 BSE/.111i6 WFRCIO(05/06/13) 06/06/15 JLC/PJC WFRCAD AR No: 50-029-23107-00 07/15/14 W(RJMD PULURESET PXN PLUG(7/9/14) SEC 35,T12N,R12E,2003'FIM_&717'FAL 07/15/14 JKOJMD GLV C/O(07/11/14) 09/22/14 LECIJM)WFRCJO(09/17/14) BP Exploration(Alaska) STATE OF ALASKA ALASE~IL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ~ CONVERT TO Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ WAG Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re- ter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory 202-1540 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029- 1 - - 0 8. Property Designation (Lease~Vumber) : ~~ 9. Well Name and Number: ~ ADLO-028258 S-215 10. Field/Pool(s): PRUDHOE BAY FIELD /POLARIS POOL FEB 2 4 2010 11. Present Well Condition Summary: ~&~ Total Depth measured 6930 feet Plugs (measured) None feet true vertical 5523.35 feet Junk (measured) None feet Effective Depth measured 6834 feet Packer (measured) 5555 6057 6207 true vertical 5459.07 feet (true vertical) 4595 4931 5034 Casing Length Size MD TVD Burst Collapse Structural Conductor 114 20" 215.5# A53 SURFACE - 115 SURFACE - 115 Surface 2912 9-5/8" 40# L-80 SURFACE - 2946 SURFACE - 2847 5750 3090 Intermediate 5410 Production 6884 7" 26# L-80 SURFACE - 6915 SURFA ~~~~,5~1 4 a ~ ~AI~ tt9 ~' ~ L Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.2# L-80 SURFACE - 6548 SURFACE - 5269 P Packers and SSSV (type, measured and true vertical depth) 7"X3-1/2" HES DUAL FEEDTHRU PKR 5555 ~ 4595 7"X3-1/2" HES DUAL FEEDTHRU PKR 6057 4931 7"X3-1/2" HES DUAL FEEDTHRU PKR 6207 5034 7"X3-1/2" HES DUAL FEEDTHRU PKR 6282 5090 7"X3-1/2" HES SINGLE FEEDTHRU PKR 6341 5130 7"X3-1/2" HES SINGLE FEEDTHRU PKR 6472 5219 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 567 11 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ^ 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 Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 2/23/2010 Form 10-404 Revised~2009 RE3DMS FEB 2 5 ?~~ ~ Z ~,~~dmit Original Onl%~ ~~lj/ /~ S-215 202-154 PFRF OTT~rHMFNT LJ Sw Name Operation Date Perf Operation Code - ---- --- ----------- Meas Depth Top -- Meas Depth Base Tvd Depth Top Tvd Depth Base S-215 3/31/03 PER 6,505. 6,525. 5,240.76 5,254.01 S-215 5/5/03 APF 6,355. 6,380. 5,139.43 5,156.46 S-215 5/5/03 APF 6,430. 6,450. 5,190.49 5,204. S-215 5/5/03 APF 6,525. 6,545. 5,254.01 5,267.23 S-215 5/5103 APF ~ 6,585. 6,595. 5,293.62 5,300.21 S-215 5/6/03 APF 6,302. 6,342. 5,103.35 5,130.58 S-215 5/6/03 APF 6,265. 6,280. 5,077.85 5,088.24 S-215 5/6/03 APF 6,240. 6,260. 5,060.38 5,074.37 S-215 5/6/03 APF 6,120. 6,130. 4,975.5 4,982.56 S-215 5/6/03 APF 6,098. 6,110. 4,959.99 4,968.45 S-215 5/6/03 APF 6,150. 6,170. 4,996.68 5,010.83 S-215 7/1/07 BPS 5,621. 6,595. 4,638.06 5,300.21 S-215 11/9/07 BPP 5,621. 6,595. 4,638.06 5,300.21 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE _. ~ C~ 5-215 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/22/2009~T/I/0=600/300/20. Temp =Hot. Assist slickline. (Obj. MI swap) Freeze protect FL with 6 bbls 60/40. Pumped 50 bbls 180 deg dsl down tbg to assist slickline on brush and flush rig down (slickline on well has control annulus valves open to ;gauges operator notified of departure) FWHP=1850!40/20 11/22/2009:"*'WELL INJECTING ON ARRIVAL'`** (pre sbg) "PERFORM B&F W/ 3 1/2" BRUSH, 2.75" GAUGE RING TO 3-1/2" PXN @ 6477' SLM WHILE LRS PUMPED 55 BBL OF HOT DIESEL (see Irs reports) '****NOTED: TBG PRESSURING UP @ 55 BBLS MAX PRESSURE WHEN SHUT DOWN PUMP WAS AT 2200#****" .SET 3-1/2" WHIDDON CATCHER SUB @ 6477' SLM MADE 1 ATTEMPT TO PULL RK-P15 FROM STA# 4 @ 6322' SLM (6326' MD) ***CONTINUED ON 11-23-09 WSR"'* 11/23/2009 ***CONTINUED FROM 11-22-09 WSR"** MADE 7 ATTEMPTS (1 HOUR OF JARRING ON EACH ATTEMPT) TO PULL RK-P15 IN ST. #4 @ 6322' SLM/6326' MD(see log). *"*CONTINUED ON 11-24-09 WSR""* ____ ....__. ~_ _._ . ~ _ __ W.... ~. _ ._ _ W...~.~ 11/24/2009 """CONTINUED FROM 11-23-09 WSR*'`"(pre mi swap) PULLED RK-P15 FROM ST. #4 @ 6322' SLM/6326' MD(see log) RAN 3-1/2" OM-1, 1-1/2" POCKET POKER TO ST. #4 @ 6322' SLM, NO PROBLEMS. __SET RK-DGLV IN ST. #4 (a)_ 6322' SLM/6326' MD PULLED EMPTY WHIDDON C-SUB FROM 6503' SLM SET 3-1/2" MCX (1.08" BEAN, SER# BPX-324, 3 1/2" EQU). @ 2489' SLM/2505' MD. ARAN GOOD CHECK SET. GOOD CLOSURE TEST. ~'`*"WELL LEFT S/I, OPER NOTIFIED*** FLUIDS PUMPED BBLS 105 DIESEL 6 60/40 111 Total EE= CIW 4-1116" 5M WELLHEAD"Y' ^ - 11" FMC ACTUATOR= BAKE KB. ELEV = 71.5' BF. ELEV = 41' KOP = 2238' Max Angle = 50 @ 3438' Datum MD = 6256' Datum TV D = 5000' SS ~20" X 34" INSULATED CONDUCTOR, I-j 114' 215.5 #, A53 ERW, ID = ? TAM PORT COLLAR 976 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" 2946 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" 55° 7' MARKERJOINT 57q 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" 6U° Minimum ID = 2.750" @ 6536" 3-1 /2" HES XN NIPPLE 7' MARKER JOINT 62( 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" 62t ES: *** HES PACKERS ARE SHEAR TO~ {SEE WELL FlLE FOR ADDITIONAL 4-1 /2" X 3-1 /2" XO, ID = 2.992" 3-1 /2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS 3-112" HES X NIP, ID = 2.813" HOLE IN 7" CSG (RIG 07130/07) WATER INJECTION MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 8 6177 5016 45 MMG-W DMY RK 0 08/30/07 7 6227 5051 45 MMG-W DMY RK 0 08/30/07 6 6263 5077 46 MMG-W P-15 RK 14 12/13/08 5 6297 5100 47 MMG-W DMY RK 0 08/30/07 4 6326 5119 47 MMG-W DMY RK 0 11/24/09 3 6377 5155 47 MMG-W DMY RK 0 08/30(07 2 6448 5203 48 MMG-W R15 RK 12 12/13!08 1 6496 5235 48 MMG-W P-15 RK 16 12/13108 6196 ~--~ 3-112" HES X NIP, ID = 2.813" ~ PHOENIX SENSOR SUB, ID = 2.992" ~ 3-112" RA PIP TA G ~ 6277' 7" X 3-112" HES DUAL FEEDTHRU PKR, ID = 2.965" 6282 PERFORATION SUMMARY REF LOG: SPERRY MWD ON 08/06/02 A NGLE AT TOP PERF: 45° @ 6098' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 2-7/8" 2 Nb 6098 - 6110 O 05/06/03 2-718" 2 6120 - 6130 0 05/06/03 2-718" 2 Nc 6150 - 6170 O 05/06/03 2-7/8" 2 OA 6240 - 6260 O 05/06/03 2-7/8" 2 6265 - 6280 O 05/06/03 2-718" 2 OBa 6302 - 6342 O 05/06/03 2-7/8" 2 OBb 6355 - 6380 O 05/06/03 2-718" 2 OBc 6430 - 6450 O 05/06/03 2-718" 6 Obd 6505 - 6525 O 03/31 /03 2-7/8" 2 6525 - 6545 O 05/06/03 2-7/8" 2 Obe 6585 - 6595 O 05/06/03 3-1/2" TBG, 9.2#, L-80 TCiI, .0087 bpf, ID = 2.992" i--i 65413' PBTD 6$34' 7" CSG, 26#, L-80 BTC, .0383 bpf, ID = 6.276" 6915' 6291 ~ (-~ 3-112" HES X NIP, ID = 2.813" 7" X 3-112" SINGLE FEEDTHRU PKR, ID = 2.965" PHOENDC SENSOR SUB, ID = 2.992" 6366' ~-i 3-1 /2" HES X NIP, ID = 2.813" 7" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" ~ 64$5' ~--~ 3-1 /2" HES X NIP, ID = 2.813" 61 515' (-i3-1/2" HES X NIP, ID = 2.813" 6536 --{3-1(2" HES XN NIP, ID = 2.750" 6536' 3-1/2" HES PXN TT (11/09/07) 6548' -~3-i/2"' WLEG, ID = 2.992"~ ELMD NOT LOGGED DATE REV BY COMMENTS DATE REV BY COMMENTS 08/16/02 D-14 ORIGINAL COMPLETION 03/13/08 TVV/PJC 7" CSG HOLE (07!30/07} 08/31/07 N9E5 RWO 01/15/09 CJN/SV WFR C(O (12/13/08} 11/19/07 CJN/PJC GLV C/O (11111/07) 11/27/09 JCM/SV WFR Cl0 (11124!09} 11/19/07 CJNiPJC SET PXN TT (11/09!07) 12/01!07 MS/PJC DRLG DRAFT CORRECTIONS 02!17!08 TW/PJC DRAWING CORRECTIONS POLARIS UNIT WELL: 5-215 PERMIT No: 2021540 API No: 50-029-23107-00 SEC 35, T12N, R12E, 2003' FNL & 717' FWL BP 6cpioration (Alaska} 5-215 • MEMORANDUM State of Alaska To: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector • Src: Inspector Reviewed By: P.I. Suprv _~.> NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN POL S-21 s API Well Number: 50-029-23107-00-00 Inspector Name: Jeff Jones mitJJ09 1 22 80800 1 8 Permit Number: 202-154-0 Inspection Date: 11/17/2009 Insp Num: Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45_Min. 60 Min. - -- Well ~ s-21s ~T a In w ' TVD as9s IA -{ - T i __- __ ..__ _ .t Ji- - _i i 1500 ~Y OA 260 i, 4000- _ 3830 I_ _3810 ~ ---- ~ -- - ~i Yp J• I _ _ P.T.D~ zozlsao YP ~ sPT ~ p o o ~ o o ITT eTes ,Test s _ Interval 4~TST P/F P Tubm 1210 ~ 12zo .1220 L 1210 i_ _i__ _ -_ _- --- ----- --- - g~._ ----~-- NOtes: 2.6 bbls methanol pumped. i~~.1 ~ e~' L,V 1~ Alaska Oil and Gas Cmrservation Commission DATE: Tuesday, December 29, 2009 2~~` ~~Z(0`) SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-215 PRUDHOE BAY UN POL S-215 Tuesday, December 29, 2009 Page 1 of 1 ~ • June 25, 2009 ti ~~ F~~~ ~ ~~ ~ ~~~~ `~ ~~~:~ JuL ~ ~. zoos Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~r~~~~~ p;! ~~~~ ~A~~~ ~~~mi~si~~ 333 West 7th Avenue ~~~~~~~~~~ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad ~ b~' ~~ ~ ~ r ~ ~~... Dear Mr. Maunder, Enclosed please find a spreadsheet with a list of wells from S-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, 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, a~ ~~;, ,,~~~~ `° ~ ? DCi i ~~,.'a srtJ'~~' ~ :J L ~ Torin Roschinger BPXA, Well Integrity Coordinator • ! BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-oH Report ot Sundry Operetions (10-404) S-pad Mfn R/25/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cemem Cement top off date Corrosion inhibitor CiOROSIOfI inhibitorl sealant date ft bbls ft na al 5-01 B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 7325 NA 73.25 NA 92.65 5/20/2009 S-Oa 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 7951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26I2009 S-07A 1920980 0 NA 0 NA 0.9 5/2&2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1l2009 5-13 1821350 8 NA 8 NA 55.3 6/1l2009 S•15 1840170 0.25 NA 0.25 NA 3 6l2/2009 S-17C 2020070 0.25 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-19 1861160 0.~5 NA 0.75 NA 22 5/79/2009 S-20A 2010450 025 NA 025 NA 73 5/19/2009 S-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1907270 025 NA 025 NA 1.7 5/25/2009 S-2aB 2031630 0.5 NA 0.5 NA 2.s 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31l2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/37l2009 S-29AL7 1960720 0 NA 0 NA 0.85 5/27/2009 S-30 1900660 0.5 NA 0.5 NA 5.~ 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26J2009 5-32 1901490 0.5 NA 0.5 NA 3.a 5/31/2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-3a 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 NA .85 in 5/31/2009 S36 19211fi0 0.75 NA 0.75 NA 425 5/27/2009 S-3~ 1920990 125 NA 125 NA 17.9 5/27/2009 S-se 1921270 0.25 NA 025 NA 10.2 5/27/2009 S-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28l2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 S•100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 1.25 NA 125 NA 77.9 5/29/2009 5-~02L1 2031560 725 NA 125 NA it.7 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 16.25 NA 7625 NA 174.3 6J2/2009 S-107 2011130 225 NA 225 NA 28.9 5/18/2009 S-108 2071000 3.5 NA 3.5 NA a0 5/30/2009 5-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-~70 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 S-112 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-114A 2021980 125 NA 125 NA 702 5/30/2009 S-115 2022300 2.5 NA 2.5 NA 272 5/29Y2009 5-116 2031810 1.5 NA 7.5 NA 13.6 5/28/2009 5-~77 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-t78 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA W2 5/29/2009 5-121 2060470 4.5 NA 4.5 NA 53.6 5/28/2009 5-~22 2050810 3 NA 3 NA 21.3 5/29/2009 5-723 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-12a 2067360 1.75 NA 1.75 NA 11.9 5l26I2009 S-125 2070830 225 NA 2.25 NA 20.4 5/28/2009 5-726 20710970 1.25 NA 125 NA 15.3 6l1/2009 5-200 1972390 1.25 NA 125 NA 14.5 5l28/2009 5-207 2001840 0 NA 0 NA 0.85 6/79/2009 5-213A 2042130 ~ 2 NA 2 NA 73.6 5/29/2009 S-275 202/540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.)5 NA 51 5/29/2009 S-2t7 2070950 0.25 NA 025 NA tJ 6/1/2009 S-aoo 2070740 2 NA 2 NA 9.a 5/28/2009 S-a01 2060780 16 NA 16 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.85 5/28/2009 • MEMORANDUM To: Jim Regg K~~; ~ ~` ~ ~ ~ ~ ~ P.I. Supervisor It FRO!vt: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 28, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-215 PRUDHOE BAY UN POL 5-21 ~ Src: Inspector NON-CONFIDENTIAL ~"~ Y ~O Reviewed By: P.I. Suprv ~1~~ Comm Well Name: PRUDHOE BAY UN POL S-215 API Well Number: 50-02 9-2 3 1 07-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ071128094823 Permit Number: 202-t54-0 Inspection Date: 11/27/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 IVIin. 45 Min. 60 Min. Well I s-2ts TYPeInj. '~ w ~ TVD as9s ,;~i IA l zso ~ zooo ~ ~ ~zooo j zooo I p T i zoztsao ~TypeTest j sPT ~ Test psi ~~ 2000 ~ OA ~ o ~ 0 0 0 I Interval mzTAL p~F P ,.~'"~ Tubing ~ I I3o j I too t too ~, t too ~ i Notes• The IA was pressured up to 2000 PSI for the test but due to a pigging operation the injection was temporarily stopped. When injection resumed the IA was repressured to 2000 PSI and passed the MIT. 2 BBLS methanol pumped. The well house appeared clean and in good condition. Lam. ~~~~~p DEC ~ 1 2007 Wednesday, November 28, 2007 Page I of I . . Page 1 of 1 Maunder, Thomas E (DOA) From: Tirpack, Robert B [Robert.Tirpack@bp.com] Sent: Wednesday, September 26,20075:17 PM To: Maunder, Thomas E (DOA); Staudinger, Mark Subject: RE: S-215 (202-154) Workover from Hell Mark is on vacation. We suspect that the casing was damaged during the chemical cut of the Baker premier packer. Casing tested fine during pre-rig operations. We later found a hole in the casing as the exact same depth as the original Baker packer. Also found hole in Baker packer that couldn't have passed pressure test. Regards, Rob ~-,--------_._-,--,..-..,."_._--~--"_._--~-"~_._,,-"._-~-----------~--"""~.__._--- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, September 26,200712:28 PM To: Tirpack, Robert B; Staudinger, Mark Subject: 5-215 (202-154) Workover from Hell Rob and Mark, I have just reviewed the 404 for work conducted through the month of August on this well. Great in the beginning and ending, but 9 kinds of problems in the middle! Was there any indication of a casing problem prior to the workover? I don't find any mention of it in the files we have. Thanks in advance. Tom Maunder, PE AOGCC S~¡;MNE.D SE? 2 7 2007 9/27/2007 STATE OF ALASKA ~~-~~~ ~ ~ V ALASKA OIL AND GAS CONSERVATION CO~SION ~ E P 1 9 2007 REPORT OF SUNDRY WELL OPERATIONS ~i;~:,i:.~ )i~ ~ Gas Cons. Calmmissian 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 202-154 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23107-00-00 7. KB Elevation (ft): 71.49' 9• Well Name and Number: PBU S-215i 8. Property Designation: 10. Field /Pool(s): ADL 028258 Prudhoe Bay Field /Polaris Pool 11. Present well condition summary Total depth: measured 6930 feet true vertical 5523 feet Plugs (measured) None Effective depth: measured 6834 feet Junk (measured) None true vertical 5459 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 114' 20" x 34" 114' 114' Surface 2912' 9-5/8" 2946' 2847' 5750 3090 Intermediate Production 6884' 7" 6915' 5513' 7240 5410 Liner Perforation Depth MD (ft): 6098' - 6595' Perforation Depth TVD (ft): 4960' - 5300' 3-1/2", 9.2# L-80 6548' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 6 - HES 7" x 3-1/2" (Dual Feedthru) A HR packers 5555', 6057', 6207', 6282', 6341', 6472' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ®WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mark Staudinger, 564-4337 307-189 Printed Name Terrie Hubble Title Technical Assistant Prepared By Name/Number: ~ 8 Signature Phone 564-4628 Date 07 Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 Submit Original Only ORIGINAL ~1~5~F~s~~~saoo~ ~nt~~ ,~~~ Digital Well File ~ ~ Page 1 of 1 Well: S-215 - Well History Well Date Summary S-215 6/30(2007 *** WELL SHUT IN ON ARRIVAL***(pre sdtrk) RAN 2'x 1-7/8" STEM,3.805" GAUGE RING TO XN NIPPLE 5648' MD MIS-RAN 4-1/2" XXN PLUG(EIGHT 1/8" EO. PORTS) TO XN NIPPLE AT5648'MD CURRENTLY POOH W/ XXN PLUG SITTING ON TOP OF XN-NIP @ 5648'MD ***CONT WSR ON 7-1-07*** S-215 7/1/2007 ***CONT WSR FROM 6-30-07*** (pre sdtrk) RAN 4-1/2" BLB,AND3.625" GAUGE RING TO XN NIPPLE AT 5648'MD SET 4-1/2" XXN PLUG IN XN-NIPPLE(EIGHT 1/8" EO. PORTS) AT 5648'MD RAN 4-1/2" CHECK SET TO XXN PLUG AT 5621'SLM (SHEARED) RAN 4-1/2" 4280 SHIFTING TOOL TO SLIDING SLEEVE AT 5535'MD (OPEN) ***RDMO,TURNED WELL OVER TO OPERATOR*** S-215 7/4/2007 T/IA/OA= 850/150/0 Temp SI PPPOT-T (PASS) PPPOT-IC (PASS) (PRE RWO) PPPOT-T (PASS) RU HP bleed tool onto THA 100 psi bleed to 0 psi, Cycled LDS "ET style" and torqued to 450 ft/#. Flushed void until clean returns achieved, pressured to 5000 psi for 30 minute test, 4800/ 15 minutes, 4750/ 30 minutes. Bleed off void to 0 psi RD test equipment re installed Alemite cap. PPPOT-IC (PASS) RU HP bleed tool onto IC test void 0 psi, Cycle LDS "ET style" and torqued to 450 fU#. Flushed void until clean returns achieved, pressured to 3000 psi for 30 minute test, 2900/ 15 minutes, 2850/ 30 minutes. Bleed off IC test void to 0 psi, RD test equipment re installed Alemite cap S-215 7/4/2007 ***WELL SHUT IN ON ARRIVAL"* RAN 3.7" CENT.4-1/2" BLB TO 5640'MD BRUSH FROM 5550'SLM TO 5613'SLM ***RDMO, LEFT WELL SHUT IN AND TURNED OVER TO OPERATOR**` S-215 7/6/2007 T/I/0=870/170/100 ***Circ-out TxIA*** Pumped 5 bbls neat methanol and 307 bbls 1 % KCL down tubing taking return up IA and down S-16 flowline. Freeze protected tubing and IA with 75 bbls diesel. U-tube one hour. MIT's to be completed at a later date, due to other work on pad. FWHP's = 0/0/0 S-215 7/7/2007 T/I/O = 0/0/0 ***CMIT TxIA PASSED to 4000psi*** 3.9bbls diesel to pressure up. IA and tubing lost 80psi 1st 15min, 20psi 2nd 15min, for a total of 100psi in 30min. ***MITOA FAILED to 2000osi."** At 2bbls diesel away (1800psi) the OA fell off. LLR obtained. 5bpm @ 1600psi. FWHP's = 0/0/0 S-215 7/10/2007 SET BPV, PRE RIG S-215 7(19!2007 T/VO=BPVlOI160 Temp=S/I Bleed WHP's (Rig prep). Bled OAP to bleed trailer from 160 psi to 0 psi in 5 minutes. Monitor for 30 minutes. No change in pressures. FWHP's=BPV/0/0 S-215 7/20/2007 T/I/O=BPV/0/150. Temp=Sl. Monitor WHP (pre rig). No change in IAP, OAP increased 150 psi over night. S-215 7/21/2007 T/I/0= BPV/0!160. Temp= SI. Bleed OAP to 0 psi (pre-rig). OA FL @ surface. Bled OAP to slop trailer from 160 psi to 0 psi in 10 minutes. Monitored for 30 minutes. OAP increased 80 psi. Bled OAP from 80 psi to 0 psi in 5 minutes. Monitored for 30 minutes. OAP increased 60 psi. Continued to bleed to zero and monitor for the next 2 hours. Final WHP's= BPV/0/50. S-215 7/22/2007 T/I/0= BPV/0/150. Temp= SI. Monitor WHP's (pre-rig). OAP increased 100 psi. S-215 7/26/2007 T/I/O =SI/70/120 Load OA w/ Brine (Shut In)(Pre RWO) Pumped 5 bbls Meth, 90 bbls 9.8 ppg NaCI Brine, and 5 bbls Dieel into OA. No Scaffolding--Could Not Reach Swab---IA and OA Valves are Open. Master was Shut on Arrival---We Flagged Master. Final W H P's=SI/500/O+ Print Date: 9/18/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 9!18/2007 • BP EXPLORATION Page 1 of 24 Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To '' Hours ' Task. Code NPT '' Phase Description of Operations 7/29/2007 00:00 - 01:00 1.00 MOB P PRE Prepare rig floor for derrick down move & secure surface stack 01:00 - 03:00 2.00 03:00 - 04:30 1.50 04:30 - 05:00 ! 0.50 05:00 - 09:30 i 4.50 09:30 - 10:30 I 1.00 10:30 - 12:00 1.50 12:00 - 14:00 2.00 14:00 - 15:00 1.00 15:00 - 16:00 1.00 16:00 - 16:30 0.50 16:30 - 19:00 ~ 2.50 MOB P i MOB P MOB P MOB P RIGU ~ P I RIGU ( P RIGU P RIGU P WHSUR P I I WHSUR ~ P KILL P 19:00 - 20:30 I 1.501 WHSUR ~ P 7/30/2007 00:00 - 010:00 1.00 ~ BOPSU~ P 01:00 - 04:30 3.50 BOPSUFj P 04:30 - 06:00 1.50 BOPSU~N 06:00 - 07:00 1.00 BOPSU P 07:00 - 08:00 A 1.00 i W HSUR I P 08:00 - 14:00 ~ 6.00 PULL P 14:00 - 14:30 0.50 PULL P 14:30 - 16:00 1.50 PULL P 16:00 - 17:00 1.00 PULL P 17:00 - 17:30 I 0.501 PULL I P 17:30 - 18:00 I 0.501 PULL I P in cellar. PRE PJSM. Bridle up blocks, remove hydraulic service loop & kelly hose. PRE PJSM w/ Peak trucking. Hook up to pit module & move to S-215. PRE PJSM. Lower derrick & secure lines. PRE Move sub unit off of S-125. Remove mats & herculite from S-125 and spot on S-215. Remove surface hydril from cellar. Move rig & spot on S-215. PRE Move in & spot pit module to sub. Make up connections in interconnect. PRE Raise & pin derrick, raise cattle chute. 'Accept rig on S-215 at 1200 hrs 29-July-2007 DECOMP Spot cuttings tank, berm cellar, take on seawater. DECOMP Prepare 4" drillpipe in shed, bridle down, prepare rig floor. DECOMP PJSM w/drill site maintenence. RU & test lubricator to 500 psi. Pull BPV. Tubing and IA pressures 0 psi. RD drill site maintenence. DECOMP Pre-spud meeting w( Sullivan crew. DECOMP Rig up, pressure test lines to 2500, and circulate out diesel freeze protect. Reverse in 48 bbls 8.4ppg seawater @ 3 bpm, 420 psi down annulus w/ diesel returns to cuttings box. Switch to tubing and circulate in 87 bbls seawater @ 3 bpm, 80 psi w/ diesel returns up annulus to cuttings box. DECOMP Nipple down tree & adapter flange, secure in cellar. Inspect threads in tubing hanger - OK. DECOMP Nipple up BOPE & RU surface equipment to test. DECOMP Continue to RU to test BOPE. Install 4-1/2" test joint. Ready lines. DECOMP Pressure test BOPE w/ 4-1/2" test joint to 250 psi low, 4,000 psi high. Test Annular preventer to 250 psi low, 3,500 psi high. Witnessing of test waived by AOGCC rep Chuck Sheve. Test witnessed by BP WSL M. Martyn, NAD TP R. Axness. RREP DECOMP Change out leaking gate valve #15. DECOMP Continue to test BOPE. Test valve #15 to 250 psi low 4,000 psi high. Rig down 4-1/2" test joint. Test blind rams to 250 psi low 4,000 psi high. Perform accumulator test. Blow down all related lines and prepare for decomplete. DECOMP RU Drillsite maintenence lubricator and pull TWC. Rig down lubricator. ~- DECOMP RU Schlumberger E-Line w/ full grease control and lubricator. DECOMP Pressure test lubricator to 1500 psi - OK. DECOMP RU tools for tubing puncher run. DECOMP RIH to 5,614' on E-line w/ tubing puncher toolstring - rope-socket/ 2-1/8" OD Weight bar/ casing collar locator/ firing head/ tubing puncher/ bowspring bottomnose. DECOMP Correlate w/ CCL and fire tubing puncher - 9 charges shot in interval 5 612-5 614' md. Well losing fluff immarliataly (u? ~, bpm. Took 111 bbls to fill hole in 30 minutes, and then losses stabalized to only intermittant losses between 0 and 300 bph. DECOMP POH w/ tubing puncher toolstring. Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date II From - To 7/30/2007 18:00 - 20:30 20:30 - 22:00 22:00 - 00:00 7(31!2007 00:00 - 00:30 00:30 - 01:30 01:30 - 03:30 03:30 - 04:45 04:45 - 05:30 05:30 - 07:30 07:30 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00 - 17:00 17:00 - 18:00 18:00 - 19:30 19:30 - 22:00 22:00 - 00:00 i 8/1/2007 00:00 - 03:00 03:00 - 04:30 Page 2 of 24 ~ S-215 S-215 Spud Date: 8/8/2002 WORKOVER Start: 7/29!2007 End: 8/29/2007 NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 NABOBS 9ES Rig Number: Hours Task Code i NPT ', Phase Description of Operations 2.50 PULL P 1.50 PULL ~ P 2.00 PULL P i 0.50 PULL N 1.00 PULL N 2.00 PULL N 1.25 PULL ~` N 0.75 PULL ~ P 2.00 PULL P 1.00 PULL ' P 1.00 PULL ! P 0.50 PULL ' P 7.00 PULL P i 1.00 PULL P 1.50 BOPSU P 1 2.50 CLEAN P 2.00 CLEAN ~ P 3.00 CLEAN P 1.50 CLEAN ! P DECOMP Tool at surface. All shot fired. Rig down from tubing puncher, RU for chemical cutter. DECOMP RIH w/ chemical cutter toolstring -Rope sockeU 2-1(8" OD ~ weight bar/ E-Line jars/ CCL/ 3-1/2" chemical cutter. DECOMP Pull up pass to correlate across X-Nipple at 5,625'. Chemical cutter toolstring hung up w/ CCL @ 5,604' md, severing head at 5,615' md. Once toolstring across puncher holes, losses came back at 4-5 bpm. Work toolstring attempting to free. Jars functioning properly. Slack off and attempt to pump tool down @ varying pump rates to 8 bpm. Bring pumps back to keeping hole full @ 4 bpm. STUC DECOMP Working chemical cutter toolstring. Pul{ tool free while attempting to pull out of rope socket. STUC DECOMP POH w/ un-fired chemical cutter. STUC DECOMP Inspect chemical cutter. Some scarring on severing head. Centralizers all intact. Re-head rope socket for run #2. STUC ~ DECOMP RIH w/ chemical cutter #2. DECOMP Correlate chemical cutter and fire. Hole still taking fluid at 4 bpm. Severing head at cut depth is 5604.5' and - 1.4 feet above bottom of Baker packer. Line gained 250# tension when fired and pump pressure dropped 20 psi. Still had returns w/ ~ pumps keeping up w/ 4.5 bpm loss rate. DECOMP POH w/ chemical cutter. Initially had to work tool in 40' joint above packer to work dogs back into anchor sub before able to pull above sliding sleeve. DECOMP Rig up to laydown tubing. Back out hanger Iockdown screws. DECOMP Pull tubing hanger to rig floor. PU - 125k. Rig down SWS equipment. DECOMP Backout and laydown tubing hanger and landing joint. DECOMP Laydown 138 joints of 4.5" 12.6# L-80 TCII tubing and all jewelry from 5,631' to surface. Filling hole @ 2.5 bpm without returns. `Lost 2480 bbls from midnight to noon. DECOMP Rig down tubing equipment. Filled hole by pumping @ 12 bpm. Pumped 250 bbls before filling hole. Slow fill rate back to 2 bpm without returns. OECOMP Rig up BOPE test equipment. Test upper and lower pipe rams with 4" and 3.5" test joints to 250 psi low, 4,000 psi high, 5 min each test. Test witnessed by NAD TP R. Axness. Rig down test equipment. DECOMP Pick up and make up BHA #1 cleanout assembly: Used 6.125" HTC ATJ-4 bit, bit sub w/ float, 6.125" string mill, PxP sub, 7" casing scraper, tea junk baskets, bit sub, Sea 4.75" drill collars, XO, Jars, 24ea 4" HWDP. DECOMP Run in hole with cleanout assembly from 882' to 2,698' 'Lost 1,787 bbls from noon to midnight. 'Lost 3,870 bbls for the day *4'267 bbls total loss for well. DECOMP Continue running in hole with cleanout assembly, picking up drillpipe from 2,698' to top of fill @ 6,540'. PU - 170k, SO - 95k. DECOMP Attempt to wash down without rotating @ 12 bpm without success. Start rotating and wash down from 6,540' to 6,564'. Printed: 9114/2007 10:06:55 AM • • BP EXPLORATION Page 3 of 24 Operations Summary Report Legal Well Name: S -215 Common W ell Name: S -215 Spud Date: 8/8/2002 Event Nam e: WORKO VER Start : 7/29!2007 End: 8/29/2007 Contractor Name: N ABOBS ALASK A DRI LLING I Rig Release: 8/29/2007 Rig Name: N ABOBS 9ES Rig N umber: Date From - To Hours ' Task Code NPT ~, Phase ~ Description of Operations __ : _ -- ' ' _ '~ _ - -- --- -- - _ - 8/1/2007 03:00 - 04:30 1.50 CLEAN P DECOMP I! 12 bpm, 1,800 psi, 50 rpm, 7.8k - 12k TO. PU - 170k, SO - 95k, RWT - 130k. Washed down without rotating from 6,564' I to 6,585'. Work pipe several times - OK. Dynamic loss rate @ ~ 205 bpm. 04:30 - 09:30 5.00 CLEAN P i DECOMP POH laying down drillpipe from 6,585' to 882'. 09:30 - 10:30 1.00 CLEAN P ~ DECOMP Laydown HWDP and cleanout assembly BHA. Junk baskets I j were empty. 10:30 - 11:00 0.50 CLEAN P DECOMP Clear rig floor. 11:00 - 13:00 2.00 EVAL P ~ OTHCMP , PJSM. Rig up Schlumberger E-line for gauge ring /junk i basket, USIT. Lost 1,769 bbls from midnite to noon. 13:00 - 13:30 0.50 EVAL P OTHCMP Rig up and pressure test lubricator to 500 psi low, 1,000 psi i high - OK. " 13:30 - 16:30 3.00 EVAL P OTHCMP W ireline run #1:6.125 guage ring and junk basket to top of fill @ 6,584'. POH and clean junk basket - 1/2 cup of casing ~ ' scale. 16:30 - 17:30 1.00 EVAL P ~ OTHCMP Rig up USIT logging tools and surface test same - OK. 17:30 - 00:00 6.50 EVAL P OTHCMP , Wireline run #2: Run in hole with USIT logging tools to 6,570'. Log up with high density log to 6,050'. Process logs for evaluation. (Inconclusive) Run in hole and log cement quality from 6,570' to 200'. Top of cement 3,400'. Stringers from i i 3,400' to 2,700'. 'Lost 1,993 bbls from noon to midnight. 'Lost 3,762 bbls for the day. '8,029 total bbls for the well. 8/2/2007 i 00:00 - 00:30 0.50 EVAL P OTHCMP Rig down SWS E-line and lubricator. 00:30 - 01:00 0.50 BUNCO P RUNCMP Pull wear bushing and make dummy run with tubing hanger and landing joint. 01:00 - 03:00 2.00 BUNCO P RUNCMP Rig up to run I-wire completion. 03:00 - 00:00 21.00 BUNCO P RUNCMP PJSM with all parties. Make up and run in hole with 3.5" 9.2# L-80 TCII completion assembly to 6,520'. Make I-wire splices and connections as needed. Baker-Lok'd all connections below bottom packer. Torque Turned connections to 2,300 ~ I fUlbs using Jet Lube Seal Guard pipe dope. Check I-wire I continuity every 1,000' *Lost 1,646 bbls from noon midnight to noon. "Lost 1,146 bbls from noon to midnight. 'Lost 2,792 bbls for the day. 18/3/2007 00:00 - 01:00 1.00 BUNCO P RUNCMP ~ Pick up extra joint and pup joint on top to set tubing on planned depth @ 6551.67'. PU - 95k, SO - 65k. 01:00 - 02:30 1.50 BUNCO P RUNCMP PJSM. Rig up Schlumberger E-line wireline tools. Rig up pump-in sub and WL packoff. 02:30 - 04:00 1.50 BUNCO P RUNCMP Run in hole logging down with GR! CL to 6,350'. Log up to 6,185'. Repeat log. ~ 7" marker @ 6,203.8', 3.5" marker @ 6,286.5'. ' Difference of 82.T. Planned setting depth requires 79.5' difference. 3.2' pickup adjustment required. POH with logging tool. Rig down. 04:00 - 04:30 0.50 BUNCO P RUNCMP Laydown pup joint, extra joint and top joint. Space out to land tubing to original well depths. Pick up last joint, tubing hanger and landing joint. i'Will be .49' higher than tubing planned depth - 6551.18' Printed: 9!14!2007 10:06:55 AM • BP EXPLORATION Page 4 of 24 ~ Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date 8/3/2007 From - To Hours _- _ )4:00 - 04:30 __ 0.50 )4:30 - 06:00 1.50 )6:00 - 07:00 1.00 Task i Code I, NPT Spud Date: 8/8!2002 Start: 7/29/2007 End: 8/29/2007 I Rig Release: 8/29/2007 Rig Number: Phase ~ Description of Operations RUNCMP (original well depths) - 6,547.98' (9ES tubing tally depth) RUNCMP Terminate I-wires to tubing spool and test same - OK. RUNCMP Land tubing, run in lockdown screws on tubing spool. Drop ball and rod. Laydown landing joint. Tubing Detail: Original well Depths / 9ES Depths 3.5" 9.2 # WLEG, 3.5" TC-II 6,551 / 6548 Tops: 3.5" HES 'XN' Nipple: ID 2.750 6534 / 6531 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug 6518 / 6515 GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 6499 / 6496 3.5" HES 'X' Nipple: 2.813" ID 6488 / 6485 -~ 3.5" x 7" HES single feedthru Packer #1 packer 6475 / 6472 GLM #2 - 3.5" x 1.5" MMG-W w! RD Dummy- RK latch 6451 / 6448 1 Jt 3.5" 9.2# L-80 TC-II Tubing (#1) GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 6382 / 6379 3.5" HES 'X' Nipple: 2.813" ID 6371 / 6368 '~ ~ Phoenix Sensor sub 6359 / 6356 le feedthru Packer # 2 packer 6346 / 5" x 7" HES Sin 3 ~ -.- g . 6343 GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 6331 / ~:,'"~ 6328 ~ ( GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 6302 / ~~ \~ - 6299 ' " ' " X Nipple: 2.813 ID 6296 / 6293 HES 3.5 ~ -~~ 3.5" x 7" HES Dual feedthru Packer # 3 packer 6288 / 6285 3.5", 9.2#, L-80 TC-II Pup with RA Pip Tag 6283 ! 6280 ~`.` GLM #6 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 6269 / 6266 1 jt 3.5" 9.2# L-80 TC-II Tubing (#2 ) GLM #7 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 6208 / 6205 Phoenix Sensor sub 6201 / 6198 ' " " --~ HES Dual feedthru Packer # 4 packer 6188 / 6185 3.5 x 7 3.5" HES `X' Nipple: 2.813" ID 6177 / 6174 GLM #8 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 6158 / 6155 2 jts 3.5" 9.2# L-80 TC-II Tubing (#3- 4 ) -~ 6051 / 6048 7" HES D l f dth k # 5 acke P 3 5" • ru ac er p r x ua ee . 3.5" HES 'X' Nipple: 2.813" ID 6030/6027 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 5 ) GLM #9 - 3.5" x 1.5" MMG w/ DCR-1 SHEAR VALVE & RKP latch 5969 / 5966 107 jts 3.5" 9.2# L-80 TC-II Tubing (# 6-112 ) 3.5" HES 'X' Nipple: 2.813" ID 2502 12499 76 jts 3.5" 9.2# L-80 TC-II Tubing (#113-188 ) tea 3.5" 9.2# L-80 TC-II Space out Pups (2.05'. 2.05') 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 189 ) 3.5" 9.2# L-80 TC-II Pup 4.5" X 3.5" TC-II Crossover Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION Operations Summary Report Page 5 of 24 ~ Legal Well Name: S-215 Common Wel{ Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29!2007 Rig Name: NABOBS 9ES Rig Number: i ~ Date !From - To .Hours Task Code j NPT I Phase Description of Operations 8!3/2007 106:00 - 07:00 ~ 1.00 BUNCO RUNCMP FMC Tubing Hanger w!4 112" TC-N Lilting Threads i 07:00 - 10:00 3.00 BUNCO P RUNCMP Fill all lines, tubing and annulus. Pressure test lines to 4,000 10:00 - 12:00 I 2.00 12:00 - 13:00 ~ 1.00 13:00 - 15:00 ~ 2.00 15:00 - 15:30 ' 0.50' FISH 15:30 - 18:00 2.50 FISH 18:00 - 21:30 21:30 - 22:30 22:30 - 23:30 23:30 - 00:00 psi - OK. Pr to 4 000 psi and set packers. Hold for 30 minutes for tubing test -Good test. Bleed tubing pressure to 2,500 psi. Attempt to pressure up on annulus. At 1,750 psi pressure straight lined and was iniectinq. Bleed off all pressures. Pressure up on tubing to 4,500 psi. Attempt to ~ pressure up again on annulus with same result. Bleed off all pressures. 'State witnessed tests by Lou Grimaldi and Bob Noble DFAL RUNCMP Wait on Schlumberger E-line. `Lost 800 bbls prior to setting packers. DFAL RUNCMP Rig up SWS E-line. N DFAL RUNCMP Run in hole with GR / CL to verify completion placement. Logs verified that completion was right on depth. POH and rig down SWS E-line. N DFAL RUNCMP Rig up to pull tubing. Crossover to 3.5" drillpipe to 4.5" TCII and make up to tubing hanger. N DFAL RUNCMP Pull 200k (80%) on tubing and attempt to shear out packers. Work pipe up and down pulling up to 200k max without success. Pull up to 200k and hold. Close annular preventer and pressure up and maintain 1,800 psi on annulus for hydraulic force. No success. Laydown drillpipe joint and crossover. N DFAL RUNCMP Wait on SWS slick line. Load pipeshed with 4" drillpipe while waiting. N DFAL RUNCMP Spot slick line unit and rig up 5.5" shooting lubricator and WL BOPE. N DFAL RUNCMP Run in hole with slickline and retrieve ball and rod @ 6,515'. POH with ball and rod. N DFAL RUNCMP Rig down SWS E-line. `Lost 800 bbls for the day. 3.50 ~ FISH 1.00 FISH 1.00 FISH 0.50 FISH 18/4/2007 1 00:00 - 01:30 ~ 1.50 FISH N DFAL RUNCMP Make up 4.5" landing joint to tubing hanger. Pull 40k tension i and set slips. Rig up SWS E-line pump-in sub and pack-off. Make up Jet cutter with CL logging tool. ~, 01:30 - 03:30 ~ 2.00 FISH N DFAL RUNCMP Run in hole with jet cutter to cut tubing below top packer. Make several logging passes from 6,200' to 6,000'. Position and fire Jet cutter @ 6,133', 15' above pup joint on GLM #8. Good fire ', ~ indication. No change in well fluid level. POH and rig down SWS. 03:30 - 05:00 1.50 FISH N DFAL RUNCMP Work pipe up and down pulling up to 200k max without success. Pull up to 200k and hold. Close annular preventer and start pressuring up annulus. @ 1,480 psi, pressure dropped off rapidly. Shut down pump, bleed off remaining pressure and open annular preventer. Fluid went south. Open up TIW valve on landing joint and observed air rushing out. Had communication between annulus and tubing. Work pipe several more times without success. 05:00 - 06:00 ' 1.00 FISH N DFAL RUNCMP Rig up SWS E-line for 2nd Jet cutter run for cut above top packer. Loss rate @ 29 bph. 06:00 - 07:30 I 1.50 FISH N DFAL RUNCMP Run in hole with jet cutter to cut tubing above top packer. ~ , Make several logging passes from 6,100' to 5,900'. Position Printed: 9/14/2007 10:06:55 AM s • BP EXPLORATION Page 6 of 24 Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date 'From - To 'Hours Task ~ Code NPT I Phase ~ Description of Operations 8/4/2007 06:00 - 07:30 ~ 1.50' FISH ' N i DFAL RUNCMP and fire Jet cutter @ 6,005', on joint #5, 15' above pup joint on ~ X nipple. Good fire indication. POH and rig down SWS. 07:30 - 08:00 0.50 FISH N DFAL RUNCMP Pick up and pull tubing free at tubing pick-up weight @ 95k. I ~ Lost 20k string weight after pulling free. PU - 75k. 08:00 - 09:00 1.00 FISH N DFAL RUNCMP Rig up to circulate. Circulate bottoms up @ 5 bpm, 325 psi. 09:00 - 10:00 1.00 FISH N DFAL ' RUNCMP PJSM with Schlumberger completion service. Rig up floor to laydown tubing and recover I-wire. 10:00 - 12:00 ~ 2.00 FISH ~ N . DFAL RUNCMP Pull tubing hanger to rig floor. Remove I-wires and laydown ~ hanger and landing joint. Splice I-wires to spool. ~ 'Lost 85 bbls from 05:00 to noon. 'Loss rate slowed to 9 bph. 12:00 - 20:00 8.00 FISH N DFAL RUNCMP POH laying down 3.5" tubing. Recovered 184 joints of tubing, 17.3 ft cutoff joint, X nipple, GLM #9, 94 full I-wire clamps and 3 I-wire half clamps. All equipment accounted for. 20:00 - 21:30 1.50 i FISH : N , DFAL RUNCMP Clear rig floor. Install wear bushing. Bring fishing tools to rig floor. 21:30 - 23:00 1.50 FISH N DFAL RUNCMP PJSM. Make up BHA #2 fishing assembly: Bowen "C" Dimension Spear, X-over, Bumper sub, Oil jar, pump-out-sub, ' Sea 4 3/4" DC's, Accelerater jar, X-over. 23:00 - 00:00 1.00 FISH N DFAL RUNCMP Run in hole with BHA #2 picking up drillpipe from 314' to 1,558'. 'Lost 74 bbls from noon to midnight. j `Lost 159 bbls for the day. 8/5/2007 100:00 - 03:30 I 3.501 FISH I N 03:30 - 04:30 1.00 FISH ' N 04:30 - 05:00 0.50, FISH ( N 05:00 - 07:00 2.00 FISH ~ N 07:00 - 07:30 0.50 FISH N 07:30 - 08:00 0.50 FISH N 08:00 - 12:00 4.00 j FISH ; N 12:00 - 13:30 I 1.501 FISH i N 13:30 - 14:00 0.50 FISH N 14:00 - 15:00 1.00 FISH N 15:00 - 17:00 2.00 FISH N 17:00 - 18:00 1.00 FISH N 18:00 - 18:30 0.50 FISH N 18:30 - 21:00 2.50 FISH N DFAL RUNCMP Continue running in hole with BHA #2 fishing assembly (Run #1) from 1,558' to 5,883' DFAL RUNCMP Cut and slip drilling line. DFAL RUNCMP Run in hole from 5,883' to top of fish @ 6,005'. PU - 140k, SO - 92k. DFAL RUNCMP Engage fish and work pipe. Start off easy and work up to maximum jar @ 240k, then pick up to maximum pull on tubing (80%) @ 310k. Work pipe repeatedly at maximum jarring and pulling weights until fish was tree. DFAL RUNCMP POH from 6,005' to 5,670'. DFAL RUNCMP Perform a post jarring derrick inspection - OK. DFAL RUNCMP POH from 5,670' to fish. Work string would pull over occasionally when passing by casing collars 'Lost 121 bbls from midnight to noon. DFAL RUNCMP Laydown fish. Retrieved top and bottom cutoff joints #5,#3, X nipple, packer #5, 20' space out pup jt, 1 full joint (#4) for total of 128'. Top of fish @ 6,133' DFAL RUNCMP Clear rig floor. Bring new 2.25" ID bumper sub, oil jar, and overshot to rig floor. DFAL RUNCMP Make up BHA #3: Overshot with burn shoe, bumper sub, oil jar, Sea 4 3!4" DC's, x-over. DFAL RUNCMP Run in hole with BHA #3 from 302' to 6,130'. DFAL RUNCMP Dress top of fish. 115 gpm, 140 psi, PU - 140k, SO - 92k, RWT 120k, 20 rpm, 5-7k TO. Engage fish. Start off easy and work up to maximum jar @ 240k, then pick up to maximum pull on tubing (80%) @ 310k. Work pipe repeatedly at maximum jarring and pulling weights without success. DFAL ~ RUNCMP Perform a post jarring derrick inspection - OK. DFAL RUNCMP PJSM with SWS day crew, rig up and test tools. PJSM with SWS night crew. Printed: 9/14/2007 10:06:55 AM • 00:00 - 00:30 0.50 FISH 00:30 - 03:30 3.00 FISH BP EXPLORATION Page 7 of 24 ~ Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task -- - _ --- 8/5/2007 21:00 - 00:00 I 3.00 I FISH 8/6/2007 ~ 8/7/2007 Code NPT ~Phase ~ Description of Operations N DFAL l RUNCMP Chem cutter run #1: Run in hole with extended 2.125" chemical ~, cutter to fishing BHA. Attempt to pass through numerous times I I @ 5,846' (DC #6) without success. POH with chemical cutter. PJSM on live chemical cutter. 'Lost 55 bbls from noon to midnight. 'Lost 176 bbls total for the day. I '11,956 total bbls seawater lost to well. N I DFAL !RUNCMP PJSM. Make up 2 sinker bars to WL chem cutter assembly. N DFAL !RUNCMP Chem cutter run 2: Run in hole to 5,846' and attempt to work through. Started pulling 200 Ibs over on up stroke. POH with I, chemical cutter. 03:30 - 04:30 1.00 FISH N ;DFAL ~i RUNCMP 04:30 - 07:00 2.50 FISH N !DFAL I RUNCMP 07:00 - 08:00 1.00 FISH N ;DFAL RUNCMP 08:00 - 09:00 1.00 BOPSU N DFAL ~ RUNCMP 09:00 - 09:30 0.50 BOPSU P !RUNCMP 09:30 - 14:00 4.50 BOPSU P RUNCMP 14:00 - 15:00 1.00 BOPSUR I N ', SFAL RUNCMP i 15:00 - 15:30 0.50 BOPSU ~I P III li RUNCMP 15:30 - 16:00 0.50 FISH N ~! DFAL RUNCMP 16:00 - 18:30 2.50 FISH N I DFAL I RUNCMP 18:30 - 19:30 1.00 FISH N DFAL i RUNCMP 19:30 - 21:30 2.00 FISH N DFAL RUNCMP 21:30 - 00:00 2.50 FISH N DFAL I RUNCMP I I i ; • Rig down SWS WL to standby. Release fish and POH from 6,133' to BHA #3. Stand back DC's, laydown fishing assembly. Clear rig floor. Pull wear bushing and flush out BOP stack. PJSM. Rig up to test ROPE. (weekly) Pressure test BOPE to 250 psi low, 4,000 psi high, Annular BOP to 3,500 psi for 10 min each test. Tested with 4" and 3.5" test joints. Performed Accumulator drawdown test. Witnessing of test waived by AOGCC rep Bob Noble. Test witnessed by BP WSL B. Buzby and NAD TP K. Cozby. 'Lost 55 bbls from midnight to noon. 2 TIW valve tests failed, valves replaced and retested - OK. Manual valve on choke line test failed. Serviced and retested - OK. Rig down test equipment and install wear bushing. PJSM. Make up BHA #4: Cut Lip Shoe, Washpipe Ext. top sub, x-over. Run in hole with BHA #4 to top of fish. Swallow fish, tag with top sub and pick up 3 ft. PU - 125k, SO - 85k. Rig up SWS E-line for chemical cut runs. Rigged up TIW, pump-in sub and pack-off. RIH with 2 3/8" chemical cutter with CCL. Correlate cutter for cut @ 6,426'. 15 ft up on tubing joint #1 (15 ft above pup joint on GLM #2. Make cut. Observed 3% decrease in flow after cut. (Hole on continuous fill). Flow returned to normal 5 minutes after cut. POH with WL tool. Anchor body assembly stuck in GLM's #3 and #4. Rigged up to pump down work string. Pumped down @ 3 bpm, 190 psi. Work tool without success. Close annular and pump down work string @ 3.5 bpm, 900 psi. Work tool free. Repeated @GLM #4. POH with W L tool. 'Lost 72 bbls from noon to midnight. 'Lost 127 bbls for the day. *in non +..+,.i ~.. i-.i., i,...++„ ..,..u 00:00 - 02:30 2.50 FISH N DFAL RUNCMP Continue POH with WL chemical cutter running tool. 02:30 - 05:00 2.50 FISH N DFAL RUNCMP Laydown tool. Replace anchor body assembly. Behead WL to rope socket. Make up chemical cutter and test same - OK. 'Anchors had not entirely retracted. 05:00 - 09:00 4.00 FISH N ~ DFAL RUNCMP Run in hole with second chemical cutter for cut @ 6,323'. Correlate for cut 2 ft below top pup joint on GLM #4. Make cut. ~ Hole started losing 100 bph. POH with WL chemical cutter ~j running tool. Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION Operations Summary Report Page 8 of 24 ~ Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8!29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date 'From - To Hours Task Code I NPT ~ Phase Description of Operations 18/7/2007 09:00 - 11:00 2.00 FISH N DFAL RUNCMP Redress tool for jet cutter. , 11:00 - 14:30 3.50 FISH N DFAL RUNCMP Run in hole with jet cutter for cut @ 6,244'. Correlate for cut 15 i ; ft above top pup joint on GLM #6. Make cut. Had a slight increase in losses. POH with W L jet cutter running tool. i *Lost 386 bbls from midnight to noon. 14:30 - 15:00 0.50 FISH N DFAL RUNCMP Rig down SWS and clear floor. ~i 15:00 - 17:00 2.00 FISH N DFAL RUNCMP ! POH with BHA #4. PU - 135k, SO - 85k. 17:00 - 17:30 0.50 FISH N DFAL RUNCMP Laydown Cut lip shoe, washpipe extension and top sub. 17:30 - 18:00 0.50 FISH N DFAL RUNCMP Make up BHA #5: Bowen "C" Dimension Spear, X-over, ~ Bumper sub, Oil jar, pump-out-sub, Sea 4 3/4" DC's, Accelerates jar, X-over. 18:00 - 20:00 2.00 FISH N DFAL RUNCMP Run in hole with BHA #5 and engage fish @ 6,133'. PU - 145k, SO - 95k. 20:00 - 20:30 0.50 FISH N DFAL RUNCMP i, Pick up on fish - 145k. No overpull. Attempt latch up of fish by putting 2 left hand turns in pipe, pumping at 2 bpm, 490 psi. Slack off and set down 15k on fish with 30 psi increase in pump pressure. Work pipe up with same result. 20:30 - 23:30 3.00 FISH N DFAL RUNCMP ~ POH from 6,133' to 302'. No overpulls. ' 23:30 - 00:00 0.50 FISH N DFAL RUNCMP Stand back DC's, laydown fishing assembly. NO FISH. Spear ~, still in the catch position. *Lost 1,418 bbls from noon to midnight. 'Lost 1,804 bbls for the day. *13,887 total bbls lost for the well. 8/8/2007 i 00:00 - 00:30 0.50 FISH N DFAL RUNCMP Make up BHA #6:53/4" overshot, bumper sub, oil jar, pump-out sub, Sea 4 3/4" DC's, accelerator jar, x-over. 00:30 - 03:00 2.50 FISH N DFAL RUNCMP Run in hole to fish for packer #4 with BHA #6 from 311' to 6,050'. Make up topdrive. PU - 145k, SO - 95k. 1 03:00 - 03:30 0.50 FISH N DFAL RUNCMP Run in hole to 6,133' and swallow fish. Pick up string to 175k, let jar bleed off and pick up to 285k and hold for 30 minutes. 03:30 - 05:00 1.50 FISH N DFAL RUNCMP Start jarring @ 50k over and straight pull to 300k. Worked up jarring to 100k over and puN to 300k repeatedly until fish was free. PU - 145k. No pipe movement. 05:00 - 08:00 3.00 FISH N DFAL RUNCMP POH from 6,133' to fish'. Saw packer going through casing connections intermittently until -3,000'. 08:00 - 09:30 1.50 FISH N DFAL RUNCMP Laydown fish. Recovered bottom and top cut joints, GLM's #'s 7 & 8, packer #4, Phoenix sensor sub and X nipple assemblies with related pup joints. 1 full I-wire clamp, 5 half I-wire clamps. *Had to let wear bushing come through stack with packer due to I-wire bird nesting. 09:30 - 10:00 0.50 FISH N DFAL RUNCMP Clear and clean rig floor. ; 10:00 - 10:30 0.50 FISH N DFAL RUNCMP Fish I-wire out of BOP stack and install wear bushing. 10:30 - 12:00 1.50 FISH N DFAL RUNCMP Make up BHA #7, fishing run #6: Bowen "C" Dimension Spear, X-over, Bumper sub, Oil jar, pump-out-sub, Sea 4 3/4" DC's, Accelerates jar, X-over. ~ *Lost 670 bbls from midnight to noon. 12:00 - 14:00 2.00 FISH N DFAL RUNCMP Run in hole from 315' to top of fish @ 6,244'. PU - 145k, SO - 95k. 14:00 - 15:30 1.50 FISH N DFAL RUNCMP Work spear into top of fish. 15:30 - 19:30 4.00 FISH N DFAL RUNCMP j Pull 25k over and let jar bleed off, pull 130k over and hold for 30 min. No pipe movement. Repeat process holding 130k over 3-5 min. 19:30 - 00:00 4.50 FISH N DFAL RUNCMP Start jarring work string starting at 50k over up to jar max @ 1100k over. Straight pull to 170k over. NO GO. Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION Page 9 of 24 Operations Summary Report Legal Well Name: S-215 Common W ell Name: S -215 Spud Date: 8/8/2002 Event Nam e: WORKO VER Start : 7!29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig N umber: Date From - To Hours Task Code I'~ NPT I! Phase Description of Operations ~ 8(8(2007 i 19:30 - 00:00 , 4.50 FISH N DFAL RUNCMP *Lost 530 bbls from noon to midnight. 'Lost 1,200 bbls for the day. '15,087 total bbls lost for the well. 8/9/2007 ~ 00:00 - 03:45 3.75 FISH N DFAL RUNCMP Continue jarring on packer #3 up to jar max @ 100k over. Straight pull to 170k over. NO GO. 03:45 - 04:00 ' 0.25 FISH N DFAL RUNCMP Release from fish by rotating slowly and picking up workstring. ~ PU - 145k, SO - 95k. ~, 04:00 - 04:30 0.50 FISH N DFAL RUNCMP Perform post jarring, derrick inspection. 04:30 - 07:00 2.50 FISH N DFAL RUNCMP POH from 6,264' to fishing assembly'. ~ 07:00 - 07:30 ' 0.50 FISH N DFAL RUNCMP Laydown BHA #7. 07:30 - 08:00 0.50 FISH N DFAL RUNCMP Clear and clean rig floor. 08:00 - 08:30 0.50 FISH P RUNCMP Service topdrive, crown, iron roughneck and drawworks. 08:30 - 10:30 2.00 FISH P RUNCMP Inspection by Alaska Overhead Crane & Hoist rep Dave Putnam. Inspected crown cluster, drilling line, tugger sheaves and stabbing board. i 10:30 - 11:00 0.50 FISH N DFAL RUNCMP Make up BHA #8: Washpipe flat bottom mill, lea washpipe extensions, top sub, x-over. 11:00 - 13:30 2.50 FISH N DFAL RUNCMP Run in hole with BHA #8 to top of fish @ 6,244'. PU - 130k, I SO - 90k. ~ 'Lost 1,140 bbls from midnight to noon. ' 13:30 - 14:30 i 1.00 FISH N DFAL RUNCMP Wash over top of fish to 6,256'. 270 gpm, 440 psi, 2 rpm. Pick ~ up and increase RPM to 60. Wash down to 6,269' (top of GLM #6) with intermittent torque spikes. PU - 130k, SO - 90k, RWT - 100k. 14:30 - 15:30 1.00 FISH N DFAL RUNCMP Pump 50 bbl Hi-vis sweep surface to surface @ 270 gpm, 440 psi. No solids returned to surface. 1 15:30 - 16:00 0.50 FISH N DFAL RUNCMP Pump 50 bbl Hi-vis sweep surface to surface @ 343 gpm, 640 ~ psi, 10 rpm, 5.2k TO. No solids returned to surface. 16:00 - 17:00 1.00 FISH N DFAL RUNCMP PJSM. Rig up SWS E-line. 17:00 - 19:00 2.00 FISH N DFAL RUNCMP Run in hole with 2.46" drift !CCL. Set down on top of fish @ 6,244'. POH. 19:00 - 19:30 0.50 FISH N DFAL RUNCMP Change out nose on drift to 1 11/16", add sinker bars. Pick up 20 ft pup joint to place top sub closer to top of fish 19:30 - 20:30 1.00 FISH N DFAL RUNCMP Run in hole with drift / CCL to 6,300' - OK. POH. 20:30 - 22:30 2.00 FISH N DFAL RUNCMP Change out drift to jet cutter. 22:30 - 00:00 1.50 FISH N DFAL RUNCMP Run in hole with jet cutter / CCL to 5,600'. I 'Lost 593 bbls from noon to midnight. 'Lost 1,743 bbls for the day. '16 820 total bbls lost for the well. 8/10/2007 00:00 - 01:30 1.50 FISH N DFAL , : RUNCMP Continue running in hole with jet cutter /CCL to 6,320'. Log 1 and correlate interval from 6,320' to 6,200'. Position jet cutter for cut @ 6,284'. 1 ft below top of pup joint above packer #3. Fire cutter with good indication of fire. POH and rig down SWS. 01:30 - 04:00 2.50 FISH N DFAL RUNCMP POH from 6,269' to washpipe assembly. 04:00 - 05:00 1.00 FISH N DFAL RUNCMP Laydown washpipe assembly. Mill had appx 2 ft of 4-wire balled up inside. 05:00 - 05:30 0.50 FISH N DFAL RUNCMP Clear rig floor. Bring new fishing tools to rig floor. 05:30 - 06:00 0.50 FISH N DFAL RUNCMP Make up BHA # 9: Bowen "C" Dimension Spear, X-over, Bumper sub, Oil jar, pump-out-sub, Sea 4 3/4" DC's, Accelerator jar, X-over. 06:00 - 08:00 2.00 FISH N DFAL RUNCMP Run in hole to 6,148'. I 08:00 - 09:00 1.00 FISH P ~ RUNCMP Cut and slip drilling line 46 ft. Printed: 9/14!2007 10'.06:55 AM • • BP EXPLORATION Page 10 of 24 ~ Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code' NPT Phase I' Description of Operations 8/10/2007 09:00 - 09:30 _ - - _ _ -- - - - __ ~ 0.50 FISH P RUNCMP Service topdrive, crown and blocks. 09:30 - 10:00 0.50 ~ FISH N DFAL RUNCMP Run in hole 1 stand to top of fish @ 6,244'. PU - 145k, SO - 90k. Spear into fish and pull fish free with 12k over. Continue pull up with intermittent 20k overpulls. 10:00 - 12:30 2.50; FISH N DFAL RUNCMP POH from 6,244' to BHA. *Lost 755 bbls from midnight to noon. 12:30 - 13:00 0.50 FISH N DFAL RUNCMP Stand back drill collars, laydown oil jar and bumper sub. 13:00 - 13:30 0.50 FISH N DFAL RUNCMP Laydown 40' of fish: 15' cutoff joint Qt #2) GLM assembly #6 and cutoff stub with RA Pip Tag. Fish I-wire pieces out of stack. 13:30 - 15:00 1.50 FISH N DFAL RUNCMP PJSM. Make up BHA #10: Flat bottom shoe, washpipe extension, Reverse circulating junk basket, P x P X-over, 2 junk baskets, bit sub, bumper sub, oil jar, pump-out-sub, Sea 4 3/4" DC's, Accelerator jar, X-over. 15:00 - 17:30 2.50 FISH N DFAL RUNCMP Run in hole with BHA #10 to 6,260. Make up topdrive. PU - 145k, SO - 95k. 17:30 - 19:00 1.50 FISH N DFAL RUNCMP Drop 7/8" reverse circulating ball and pump down @ 2 bpm, 80 i psi. Seat ball and increase pump rate to 7 bpm, 570 psi and wash down from 6,260' to top of packer #3 @ 6,288'. 11 rpm, 5k TO. Pump 50 bbl Hi-vis sweep and increase pump rate to 8 bpm, 1,015 psi. 19:00 - 21:00 ~ 2.00 FISH N DFAL RUNCMP POH from 6,288' to BHA. 21:00 - 22:00 1.00 FISH N DFAL RUNCMP Stand back drill collars, laydown and clean junk baskets. Reverse circulating basket had a few pieces of I-wire and a half clamp inside. The 2 upperjunk baskets were empty. 22:00 - 22:30 0.50 FISH N DFAL RUNCMP Clear and clean rig floor. 22:30 - 23:00 0.50 FISH N DFAL RUNCMP Bring next BHA to rig floor. 23:00 - 00:00 1.00 FISH N - DFAL RUNCMP PJSM. Make up BHA #11: Bowen "C" Dimension Spear, X-over, Bumper sub, Oil jar, pump-out-sub, Sea 4 3/4" DC's, Accelerator jar, X-over. 'Lost 1,426 bbls from noon to midnight. *Lost 2,181 bbls for the day. *19,001 total bbls lost for the well. 8/11/2007 00:00 - 01:30 1.50 FISH N DFAL RUNCMP Continue running in hole from 314' to 6,240'. 01:30 - 02:00 0.50 FISH N DFAL RUNCMP Make up top drive. PU - 140k, SO - 95k. Break circulation and stab into top of fish @ 6,284'. 02:00 - 02:45 0.75 FISH N DFAL RUNCMP Pull 25k over and let jar bleed off, pull 125k over and hold for 30 min. No pipe movement. Repeat process holding 125k over 3-5 min. 02:45 - 06:30 3.75 FISH N DFAL RUNCMP Start jarring work string starting at 50k over up to jar max @ 100k over. Straight pull to 175k over. Start pumping @ 3bpm, 1000 psi to increase jar impact. NO GO. Release from fish by turning right 3 times. 06:30 - 09:00 2.50 FISH N DFAL RUNCMP POH from 6,284' to BHA #11. 09:00 - 09:30 0.50 FISH N DFAL RUNCMP Stand back DC's and laydown BHA #11. 09:30 - 10:00 0.50 FISH N DFAL !RUNCMP Make up BHA #12: Flat bottom shoe, washpipe extension, top ~ sub, x-over, Sea drillpipe pup joints. 10:00 - 12:30 2.50 FISH N DFAL RUNCMP Run in hole with BHA #12 to top of packer @ 6,288'. PU - 135k, SO - 90k. *Lost 746 bbls from midnight to noon. 12:30 - 13:30 1.00 FISH N DFAL RUNCMP PJSM. Rig up SWS E-line. 13:30 - 18:00 4.50 FISH N DFAL RUNCMP 2 E-line runs: Run in hole with 2.12" guage assembly and set ~ i down @ 6,285', appx 1 ft inside of fish. Attempt to work Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION .Operations Summalry Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: S-215 S-215 WORKOVER NABOBS ALASKA DRILLING ' NABOBS 9ES Hours ' Task Code NPT 4.50 FISH ~N ` DFAL 3.00 FISH ~ N i DFAL I Start: 7/29/2007 Rig Rehease: 8/29/2007 Rig Number: Page 11 of 24 '~ Spud Date: 8/8/2002 End: 8/29/2007 Date 'From - To 8/11/2007 113:30-18:00 18:00 - 21:00 21:00 - 21:30 0.50 FISH ! ~ N !DFAL 21:30 - 22:00 0.50 FISH N j DFAL 22:00 - 00:00 2.00 FISH N I DFAL 8!12(2007 100:00 - 02:00 I 2.00 I FISH (N I DFAL 02:00 - 04:00 I 2.001 FISH I N I DFAL 04:00 - 04:30 0.50 FISH N I DFAL 04:30 - 05:30 1.00 FISH N ~ DFAL 05:30 - 07:00 1.50 FISH N I DFAL 07:00 - 07:30 0.50 FISH N DFAL 07:30 - 08:00 0.50 FISH N DFAL 08:00 - 10:00 2.00 FISH N I DFAL 10:00 - 10:30 ~ 0.50 FISH N ~ DFAL 10:30 - 12:00 1.50 FISH N i DFAL 12:00 - 14:00 2.00 FISH N DFAL 14:00 - 15:00 1.00 FISH N DFAL 15:00 - 16:00 I 1.001 FISH I N I DFAL Phase Description of Operations RUNCMP through without success. POH and pick up weight bar, RIH, attempt to work through without success. POH. RUNCMP E-line run #3: Pick up work string 1 ft. Pick up 2.12" caliper tool and run in hole. Set down @ 6,285. Caliper indicated that tool was inside of 3.5" tubing stub. Attempt to work through without success. Pick up tool 200 ft. Close annular preventer and pump down IA @ 281 gpm 1,380 psi appx 35 bbls. Shut dotNn, bleed off pressure and attempt to work through without success. Call for slickline availability. POH. RUNCMP PJ•SM. Rig down SWS pump-in sub and pack-off. RUNCMP Make up topdrive and pump @ 171 fpm, 175 psi. Work pipe in 12' strokes while rotating @ 10 rpm, 4k TO, work down and tag top of packer each time with small torque spikes. Shut down and reposition workstring ift higher for WL. RUNCMP E-Tune run # 4: Rig up SWS pump-in sub and pack-off. Make another 2.12" caliper tool run while waiting on slickline. Same results. Position tool on top of obstruction. Close annular preventer and pump down workstring @ 5 bpm, 600 psi. No tool movement. POH, rig down SWS E-line and hold crew and equipment on standby. `Last 685 bbls from noon to midnight. "Last 1,431 bbls for the day. '20,432 total bbls lost for the well. RUNCMP PJSM. Bring slickline tools to rig floor. Reposition work string on top of packer. Rig up slickline equipment. RUNCMP slickline run #1: Run in hole with 2.59" swedge, sinker bars, oil jars: to top of fish. Work through top of fish and work obstruction to RHC-M plug @ 6,518'. Obtruction would stop and go all the way. Work swedge back up to top of fish, hanging up in a few areas. Work swedge up and down until drag was gone. Make 3 passes from 50' above fish to RHC-M plug without drag and without seeing top of fish. POH with slickline swedge. RUNCMP Rig down slickline. Hold crew on standby. RUNCMP Rig up SWS E-line. Make up 2.55" jet cutting tool. RUNCMP E-line run #5: Run in hole with jet cutting tool. Unable to work past 6,248', 36 ft above top of fish. POH. RUNCMP Rig down E-line. RUNCMP Rig up slickline. RUNCMP slickline run #2: Run in hole with sample bailer, wire brush, and 2.625" gauge ring to 4,950'. Attempt to work through without success. POH. RUNCMP Inspect gauge ring. Change out to 2.59" swedge. Add wire grabber to tool. RUNCMP slickline run #3: Run in hole to 6,500'. POH. 'Lo:>t 732 bbls from midnight to noon. RUNCMP slickline run #4: Add bull nose to swedge & brush assembly. Run! in hole and set down @ 6,270', 14 ft above top of fish. POIi. RUNCMP Sliclkline run #5: Run in hole with lead impression block and swedge to 6,288'. POH. Impression was a half moon smiley face. RUNCMP Slicl<line run #6: Make up 2.50" centralizer brush, 2.59" swedge Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION Page 12 of 24 '', Operations Summary Report Legal Well Name: S -215 Common W ell Name: S -215 Spud Date: 8/8/2002 Event Nam e: WORKO VER Start : 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date ' From - To Hours ~ Task Code NPT ` Phase 1 Description of Operations 8/12/2007 15:00 - 16:00 1.00 FISH N DFAL ;RUNCMP with bull nose and run in hole to 6,288'. Work through top of fish then down to 6,500'. POH. Reposition work string 2 ft ii above packer. 16:00 - 17:00 1.00 FISH N DFAL ',RUNCMP slickline run #7: Run same assembly in hole to 6,500'. Did not see top of fish or any obstructions. POH. 17:00 - 18:00 1.00 FISH N DFAL '; RUNCMP ' Rig up SWS E-line. PJSM. Make up jet cutter. 18:00 - 20:00 2.00 FISH N DFAL ',RUNCMP E-line run #6: Run in hole with 2.55" jet cutter. Set down Q I I 6,268', 20 ft above top of fish. Attempt to work through without j success. POH. 20:00 - 20:30 0.50 FISH N DFAL '', RUNCMP Rig down SWS and slickline. Keep E-line on standby, release slickline. 20:30 - 23:00 2.50 FISH N DFAL ~; RUNCMP POH from 6,288' to 71'. 23:00 - 23:30 0.50 FISH N DFAL I RUNCMP Laydown single joint of drillpipe and 3 drillpipe pup joints. I Drifted pup joints to 2.562" - OK. 23:30 - 00:00 0.50 FISH N ' DFAL I RUNCMP Make up stand of drillpipe to top sub and run in hole with BHA #13 to 770'. Flat bottom shoe, washpipe extension, top sub, x-over. No pup joints. ~ ~ ~ I `Lost 978 bbls from noon to midnight. `Lost 1,710 bbls for the day. ~ '22 142 total bbls lost for the well. 8/13/2007 00:00 - 02:00 2.00 FISH N DFAL ', RUNCMP Continue running in hole with BHA #13 from 770' to top of fish ', @ 6,284'. Swallow fish 3 ft. 02:00 - 02:30 0.50 FISH N ; DFAL '~I RUNCMP ~ Rig up SWS for dummy run. 02:30 - 04:00 1.50 FISH N DFAL ~ RUNCMP I E-line run #7: Run in hole with 2.5" gauged tool to 6,500'. Pu{I up 100' above top of fish and make second pass. No indication ' of top of fish or obstruction either pass. POH 04:00 - 04:30 0.50 FISH N DFAL RUNCMP Make up jet cutting tool. ~ 04:30 - 07:00 2.50 FISH N DFAL ~~ RUNCMP E-line run #8: Run in hole with jet cutter to 6,500'. Make ', ~ several correlating passes and position jet cutter for cut @ 6,463', 2' below GLM #2. Cut tubing with good surface indication. POH. 07:00 - 07:30 0.50 FISH N DFAL RUNCMP Re-arm jet cutter. ' 07:30 - 09:00 1.50 FISH N DFAL I RUNCMP E-line run #9: Run in hole with jet cutter to 6,430'. Make several correlating passes and position jet cutter for cut @ 6,342', 2' below GLM #4. Cut tubing with good surface indication. POH. Current tubing cuts: 5 possible fish ' 6,284' Qet cut) > 6,323' (chem cut) 6,323' (chem cut) > 6,342' Qet cut) 6,342' (jet cut) > 6,426' (chem cut) ~ , 6,426' (chem cut > 6,463' (jet cut) 6,463' Qet cut) > bottom of tubing WLEG 09:00 - 09:30 0.50 FISH N DFAL ~ RUNCMP Rig down SWS E-line. 09:30 - 12:30 3.00 FISH N DFAL RUNCMP POH with BHA # lucky 13 from 6,287 to surface. Laydown shoe assembly. ~ 'Lost 592 bbls from midnight to noon. 12:30 - 15:30 3.00 BOPSU N DFAL RUNCMP Pull wear bushing, install BOP test plug. Open all ram doors and inspect ram cavities. Removed small amount of thin, flattened metal appx 5 in X 3 in. Small amount of I-wire plastic i~ covering. 15:30 - 16:00 0.50 BOPSU P !RUNCMP Rig up 4" test joint. 16:00 - 20:00 4.00 BOPSU P '; RUNCMP Weekl BOPE test. Pressure test BOPE to 250 psi low, 4,000 psi high, annular preventer to 250 psi low, 3.500 psi high. Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION Operations Summary Report Page 13 of 24 ~ Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKO VER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours I Task ' Code NPT ~ Phase Descrjption of Operations I I I ~ ~ 8/13/2007 16:00 - 20:00 4.00 BOPSU P i RUNCMP Perform accumulator drawdown test. Witnessing of test was waived by AOGCC rep Jeff Jones. Test witnessed by BP j WSL's T. Anglen, R. French, NAD TP's K. Cozby, B. Tiedemann. ~ 20:00 - 21:00 1.00 BOPSU N SFAL RUNCMP ~ Door seal failed on blind ram test. Replace door seal. 121:00 - 21:30 0.50 BOPSU P RUNCMP I Test blind rams - OK. Rig up 3.5" test joint. j 21:30 - 23:00 1.50 BOPSU P RUNCMP Pressure test upper and lower rams to 250 psi low, 4,000 psi high, annular preventer to 250 psi low, 3.500 psi high. 23:00 - 00:00 1.00 BOPSU P ~ RUNCMP Rig down test equipment, blowdown lines. Install wear bushing. ~ `Lost 500 bbls from noon to midnight. ~ 'Lost 1,092 bbls for the day. 1 23,234 total bbls lost for the well. 8114!2007 00:00 - 00:30 0.50 FISH N DFAL RUNCMP PJSM. Make up BHA #14: Bowen "C" Dimension Spear, X-over, Bumper sub, Oil jar, pump-out-sub, Sea 4 3/4" DC's, II Accelerator jar, X-over. I 00:30 - 02:00 1.50 FISH N DFAL i RUNCMP Run in hole with BHA #i 4 to top of fish @ 6,284'. Make up topdrive and spear into top of fish. PU - 136k, SO - 95k. 02:00 - 03:00 1.00 FISH N DFAL RUNCMP Pick up 25k over, let jar bleed oft, Straight pull 105k over and hold 30 minutes. No pipe movement. Work pipe from 25k over to 105k over without pipe movement. Straight pull 165k i over and hold 10 minutes. ~ t 03:00 - 06:00 3.00 FISH N DFAL RUNCMP Start jarring work string starting at 50k over up to jar max @ 100k over. Straight pull to 175k over. 06:00 - 12:00 ~ 6.00 FISH N DFAL ..RUNCMP Continue to jar and work fish while waiting on burnshoe to be ~ I ~ built. Alternate between jarring on fish for 30 minutes and allowing oil to cool for 30 minutes. Jarring up at 250k and down at 75k. Pull and hold up to 350k on fish, SO & set down I to 50k on fish. 12:00 - 23:30 11.50 FISH N DFAL RUNCMP Continue to jar and work fish while waiting on burnshoe to be built. Alternate between jarring on fish for 60 minutes and i allowing oil to cool for 30 minutes. Jarring up at 250k and down at 75k. Pull and hold up to 350k on fish every 10 hits, SO & set down to 50k on fish. No change in result. f 23:30 - 00:00 0.50 FISH N DFAL RUNCMP Rotate right and slack-off to and work pipe to release spear from fish. Burnshoe expected on location in 2 hours. 8(15!2007 i 00:00 - 00:30 0.50 FISH N DFAL RUNCMP Inspect Derrick after full day of earring on fish - OK. Prepare to 00:30 - 03:00 2.50 FISH N DFAL RUNCMP POH w/ BHA #14 from top of fish @ 6,284' md. 03:00 - 05:00 2.00 FISH N DFAL RUNCMP PJSM. LD BHA #14 & make up BHA #15: 5.37" OD x 4.70" ID burnshoe w/ centralizing ribs at 6.1" OD, 6.06" Stabalizer, double pin sub, Boot baskets, bit sub, 1 ea 4 3/4" DC, Bumper sub, Oil jar, pump-out-sub, Bea 4 3/4" DC's, Accelerator jar, X-over. 05:00 - 07:00 2.00 FISH N DFAL RUNCMP RIH w/ SHA #15 to 6,264' md. PU - 133k, SO - 100k, RT - 115k. Tag up on top of fish at 6,284 07:00 - 15:00 8.00 FISH N DFAL RUNCMP Mill on packer from 6,282' - 6,283'. 80 RPM, 157 gpm, 178 psi off, 395 psi on, 7.4k TO. 15:00 - 15:30 0.50 FISH N DFAL RUNCMP Pump 25 bbls hi-vis sweep while rotating 70 RPM. Pump through choke and kill line to clear. 15:30 - i 8:00 2.50 FISH N DFAL RUNCMP POH from top of fish to 334' top of BHA #15. 18:00 - 19:30 1.50 FISH N DFAL RUNCMP PJSM. LD BHA #15. Gouges on outside of burnshoe up to 18 inches up from bottom. Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION Page 14 of 24 Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8!29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To ' Hours I Task 8/15/2007 ~~ 19:30 - 20:30 1.00 ~~ FISH 20:30 - 22:00 1.50 FISH 22:00 - 00:00 2.00 FISH 8/16/2007 i 00:00 - 02:30 2.50 FISH 02:30 - 07:00 4.50 FISH ~ 07:00 - 07:30 ~ 0.50 FISH 07:30 - 09:30 2.00 FISH 09:30 - 10:30 1.00 FISH j 10:30 - 12:00 1.50 FISH 1 ,12:00 - 13:30 ~ 1.50 FISH 13:30 - 15:00 ' 1.50 FISH ' 15:00 - 22:30 ~ 7.50 FISH I 22:30 - 23:00 0.50 FISH ~ 23:00 - 00:00 1.00 FISH 8/17/2007 00:00 - 01:30 1.50 FISH 01:30 - 02:15 ~ 0.75 FISH 02:15 - 03:30 1.25 FISH 03:30 - 05:30 ~ 2.00 FISH 05:30 - 06:00 0.50 FISH 06:00 - 06:30 0.50 FISH 06:30 - 08:30 2.00 FISH 08:30 - 09:30 I 1.00 I FISH 09:30 - 11:30 2.00 FISH 11:30 - 12:00 I 0.501 FISH '~ Code NPT Phase Description of Operations I MU fishing BHA #16. Fishing spear, XO sub, Bowen Bumper N DFAL RUNCMP `_ _ _ __ sub, Oil jar, pump-out-sub, Sea 4 3/4" DC's, Accelerator jar, X-over. N DFAL RUNCMP Cut & Slip 75' of drilling line. Service topdrive, draworks & crown. N DFAL RUNCMP Continue RIH to 6,244' MD w/ BHA #16 N DFAL RUNCMP Tag up and engage fish at 6,282' md. Fish not pulling free. Work pipe. Pulling to 350k PU and setting down to 50k SO. Jarring at 50-100k over. Fish finally broke free and pulled up hole 15' to 6,267' md. N DFAL RUNCMP Continue to work fish. Pulling to 350k PU and setting down to 50k SO. Jarring at 50-100k over. N DFAL RUNCMP Release spear from fish - OK. Top of fish left at 6,267 Perform post-jarring derrick inspection. N DFAL RUNCMP POH from 6,267' and to top of BHA @ 314' md. N DFAL RUNCMP LD BHA #16. N DFAL RUNCMP Safety meeting with Paul Foreman, BP Safety Manager Jeff Killfoyle, BP WSL Tom Anglen, NAD Toolpusher Roy Hunt and both Haug and Holcombe crews. ~ N DFAL RUNCMP MU fishing BHA #17. Fishing spear, XO sub, Bowen Bumper sub, pump-out-sub, XO Sub, 4-3/4" Dailey Drilling Jar, 11 ea 4 3/4" DC's, Accelerator jar, X-over, 15 jts 4" HWDP. N DFAL RUNCMP RIH from 857' and to top of fish at 6,267' md. PU - 150k, SO - 95k. N DFAL RUNCMP Engage fish and jar up and down w/ pumps off and on. No packer movement seen. Mobilize new burnshoe for BHA #18. N DFAL RUNCMP Release spear from fish - OK. Top of fish left at 6,267 Perform post-jarring derrick inspection. N DFAL RUNCMP POH w/ BHA #17 from 6,267' and to 4,300' md. N DFAL RUNCMP POH w/ BHA #17 from 4,300' and to BHA @ 858' md. N DFAL RUNCMP PJSM. Lay down BHA #17. N DFAL RUNCMP MU BHA #18 - 6" x 4.875" burnshoe, washpipe extension, boot baskets, bumper sub, Bowen oil jars, pump out sub, 10ea 4-3l4" drill collars, XO, 15 jts 4" HWDP. N DFAL RUNCMP RIH from 810' and to to 6,257' and = 10' above top of fish. N DFAL RUNCMP MU single joint, connect blower hose, and take parameters for milling. Off bottom parameters - PU - 155k, SO - 95k, RTW - 115k, 80 rpm, 7k TO, 3 bpm, 170 psi. Tag up on top of fish w/o pumps, PU, resume rotation and pumping. Begin milling. N DFAL RUNCMP Mill on top of packer. 80 RPM, 8.7k TO on, 6 BPM, 575 psi, 5k WOB. After milling junk 6" from tag depth, fish broke free - TO dropped back to 7.5k. Chase fish and found back on bottom at 6,285' md. N DFAL RUNCMP Continue to mill on top of fish. 80 RPM, 7.7-8.Ok TO on, 6 BPM, 575 psi, 5k WOB. Pump 25 bbl hi vis sweep around. I-Wire insulation coming across shakers with returns. N DFAL RUNCMP Bring pumps down to keeping hole full and dry mill on top of fish. 80 RPM, 8.6k TO on, 1 BPM, 80 psi, 5k WOB. Pump 25 bbl hi vis sweep around. N DFAL RUNCMP Continue to mill on top of fish. 80 RPM, 8.7k TO on, 3.5 BPM, 400 psi, 5k WOB. Pump 25 bbl hi vis sweep around. N DFAL RUNCMP PJSM. Lay down single joint. Blow down top drive. Make up ~ blower hose. Monitor well - OK (filling hole from backside) Printed: 9/14!2007 10:06:55 AM • BP EXPLORATION Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To Hours ~ Task ~ Code NPT _ + ~ 8/17/2007 12:00 - 14:00 I 2.00 FISH N DFAL 14:00 - 15:30 1.50 ~ FISH I N DFAL 15:30 - 16:30 1.00 ~ FISH ! N DFAL 16:30 - 18:00 1.50 FISH N ~ DFAL 18:00 - 20:00 2.00 FISH i N DFAL 20:00 - 00:00 I 4.00 ! FISH (N I DFAL ~, 8/18/2007 100:00 - 00:30 00:30 - 01:15 01:15 - 04:15 04:15 - 06:00 06:00 - 10:30 10:30 - 14:00 14:00 - 15:30 15:30 - 17:30 17:30 - 19:30 19:30 - 00:00 18/19/2007 100:00 - 00:45 0.501 FISH N I DFAL 0.751 FISH N 3.00 FISH N 1.75 FISH N 4.50 FISH N 3.50 FISH N 1.50 FISH N 2.00 FISH N 2.00 FISH N 4.50 FISH N 0.75. FISH N DFAL DFAL DFAL DFAL DFAL DFAL DFAL DFAL DFAL DFAL Page 15 of 24 ', Spud Date: 8/8/2002 Start: 7/29/2007 End: 8/29/2007 I Rig Release: 8/29/2007 Rig Number: Phase I Description of Operations RUNCMP POH from top of fish at 6,282' and to top of BHA #18 @ 810' RUNCMP PJSM. Lay down burnshoe BHA #18. Boot baskets had -2 quarts of metal shavings, I-Wire pieces, I-Wire Insulation, and several misc metal chunks to 3" long by 1"wide, and 1 5"x3" 1/16" thick rounded steel chunk, RUNCMP MU fishing BHA #19. Fishing spear, XO sub, Bowen Bumper sub, pump-out-sub, XO Sub, 43/4" Dailey Drilling Jar, 11ea 4 3/4" DC's, Accelerator jar, X-over, 15 jts 4" HWDP. RUNCMP RIH from 857' and to to 6,275' and = 12' above top of fish. RUNCMP Establish parameters - PU - 155k, SO - 95k, 960 psi @ 3 BPM. Engage fish w/ spear and pull freely off bottom. Able to work fish up 18' to 6,265' and before pulling tight. Work and jar fish up and down in 15' strokes until finally worked past tight spot.. RUNCMP Jar both up and down and work fish slowly uphole from 6,265 to 5,831' -very ratty. Jarring up to 100k over repeatedly in several spots. Slow progress, but frequently breaks free for 10-50 feet before needing to jar again. RUNCMP Jar both up and down w/ BHA #19 and work fish uphole from 5,831' - 5,440'. Hole becomming less ratty. Pump out to above suspected hole in casing @ 5,600' md. RUNCMP Shut down, monitor well. Perform post-jarring derrick inspection. RUNCMP POH dry from 5,440' to top of BHA at 857' md. Still pulling slowly, but hole less ratty to -3,000' md. No problem POH above 3,000' md. RUNCMP PJSM. Lay down BHA #19. Fish sticking as final collars coming into wellhead. Back out lock down screws on wear ring as a precaution. Pull slowly into wellhead. Fish pulled tight with packer free in stack and mandrel below IA valves. Working fish. RUNCMP Attempt to work fish into wellhead with up to 100k hookload and bump out with bumper sub. Pump several high-vis sweeps around to help lubricate wellhead and to bring any debris to surface. 174 gpm, 1553 psi when puling tight into wellhead and 288 gpm, 260 psi when slacked off. RUNCMP Work pipe down to tool joint. Break out & lay down drilling jars. MU crossovers and wear ring pulling sub. RUNCMP Attempt to retrieve wear ring but unable to engage. Bring puller back to surface and change out crossovers. Run back down, engage, and pull wear ring to floor. RD puller assembly. RUNCMP Continue to work fish with up to 100k hookload. Turn left 1.5 turns while attempting to pull through wellhead at different orientations. Used up to 2k left hand torque to rotate fish without disengaging spear. Continue working fish and pin pulled out of box end of mandrel. Recover and lay down Packer #3, pup joint, X-Nipple, pup-joint. RUNCMP Redress spear and RIH w/ BHA #21. Engage mandrel w/ spear and continue to work fish with up to 100k hookload. Pull spear free of fish and recover to surface without grapple. Grapple split off inside larger ID of mandrel. RUNCMP Expedite more options for baker fishing tools. Strap and caliper same and bring to rig floor. RUNCMP MU fishing BHA #22. 5-7/8" short catch overshot, Bowen Printed: 9/14/2007 70:06:55 AM • BP EXPLORATION Page 16 of 24 Operations Summary Report Lega{ Wel{ Name: S -215 Common W ell Name: S -215 Spud Date: 8/8/2002 Event Nam e: WORKO VER Start : 7/29/2007 End: 8/29/2007 Contractor Name: N ABOBS ALASK A DRILLING I Rig R elease: 8/29/2007 Rig Name: NABOBS 9ES Rig N umber: Date ~' From - To I Hours ' Task i Code ~ NPT`~ Phase Description of Operations ~ 8/19/2007 00:00 - 00:45 0.75 FISH N DFAL RUNCMP Bumper sub, 1 ea 4-3/4" DC, X-over, 2 jts 4" HWDP. 00:45 - 02:00 1.25 FISH N DFAL 'RUNCMP Engage fish with overshot - OK. Continute to work fish w/ up to 100k hookload - no movement. Attempt to bump downhole ~ with bumper sub - no movement. 02:00 - 03:00 1.00 FISH N DFAL RUNCMP Change out lea 4" HWDP in BHA #22 for lea 4-3/4" DC for more weight on bumper sub. New BHA #23. Consult w/Greg Hobbs on plan forward if no movement after bumping down w/ more weight. 03:00 - 04:00 1.00 FISH N I DFAL .RUNCMP Engage fish w{ overshot BHA #23 - OK. Attempt to bump I down but no movement at all after 15 minutes. MU topdrive to I; BHA. PU & SO to work fish while increasing max hookload by ~ 5k each repetition. At 135k fish started to move again. j Continue to work fish increasing hookload and gained 4-5 ~ I inches. Work right hand torque to fish. Pull to 150k after right j hand torque and overshot pulled off of fish. Pull to surface and inspect - OK. Packer remnants clearly visible and intact on top I of mandel. Re-engage fish and pull free!. 04:00 - 05:00 1.00 FISH ~ N ~ DFAL RUNCMP Bring fish to surface and lay down mandrel w/ egged but intact packer sleeve, waterflood mandrel, 10' pup w/ one I-wire ~ ~ clamp, and 2' them cut pup joint. 05:00 - 06:00 1.00 FISH N i DFAL I, RUNCMP RD BHA #23, MU BHA#24 -Fishing spear, XO, bumper sub, ~~ fishing jar, pump-out sub, 11 ea 4-3/4" DC, accelerator jar, XO, 15ea 4" HWDP. 06:00 - 08:30 2.50 FISH N ` DFAL ~ RUNCMP RIH w/ BHA #24 from 831' to 6,329' md. PU - 161 k, SO - 90k. 08:30 - 09:00 0.50 FISH N DFAL RUNCMP Engage fish w/ spear& pick up - OK. Work fish up hole and pull up to 25k over through tight spot at 6,190' md. 09:00 - 12:00 3.00 FISH N DFAL !RUNCMP POH from 6,190' to top of BHA @ 372' md. No problems POH j after 6,190'. ' 12:00 - 13:00 1.00 FISH N 'DFAL RUNCMP PJSM. LD BHA #24. Recov~ er fish - 7.9ft pup, GLM #4, 1.6 ft !~ pup, 1 piece of fishing grapple, 2-half clamps, 10' length of I-Wire. 13:00 - 14:30 1.50 FISH N DFAL RUNCMP Bring tools to rig floor and MU cleanout BHA #25 -flat bottom , shoe, wash pipe, reverce circulating junk basket, boot baskets, i bit sub, fishing jar, pump out sub, Sea 4-3/4" DC's, 5 stands 4" HWDP. 14:30 - 16:00 1.50 FISH N DFAL RUNCMP RIH w/ cleanout BHA#24 from 791' to 6,243' md. 16:00 - 17:30 1.50 FISH N -DFAL ,RUNCMP Service crown & TD. Cut and slip 42' of drilling line. 17:30 - 20:00 2.50 FISH N DFAL RUNCMP RIH from 6,243' to 6,300' circulating 1 drillstring volume @ 5 bpm, 476 psi. PU - 160k, SO - 90K, RTW - 110K. Tag up on i top of fish at 6,342' md. Drop 7/8" ball for reverse circ junk basket and pump down at 8 bpm, 1635 psi. Rotate 50 rpm and wash to bottom of fish at 6,347' md. Work shoe in 10' strokes ~ at 50 rpm & 7k TO. Pump 30 bbl hi-vis sweep around and recover -2 gal of metal and plastic cuttings as well as some packer rubber debris over shakers. Shut down and prepare to POH. 20:00 - 22:30 2.50 FISH N DFAL RUNCMP POH from 6,347' to 424'. 22:30 - 00:00 1.50 FISH N DFAL RUNCMP LD BHA #25. Recover ~2 cups of stainless steel metal debris in boot baskets. Reverse circulating junk basket recovered 2 slip dies, 1 piece of spear grapple, and other misc. metal chunks. 8/20/2007 00:00 - 01:00 1.00 FISH N DFAL RUNCMP Clean and clear rig floor of all BHA #25 components. 01:00 - 02:30 1.50 ~ BOPSU N DFAL RUNCMP Pull wear bushing, install BOP test plug. Open all ram doors Printed: 9!1412007 10:06.55 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 8/20/2007 101:00 - 02:30 S-215 S-215 WORKOVER NABOBS ALASKA DRILLING I NABOBS 9ES Hours ~ Task Code' NPT ~~ 1.50 ~~ BOPSU~ N ~ DFAL 02:30 - 03:30 I 1.00 BOPSUF~ N DFAL 03:30 - 08:00 i 4.50 BOPSU N DFAL 08:00 - 09:00 ~ 1.00 ~ BOPSUFj N DFAL 09:00 - 10:00 I 1.001 FISH I N i DFAL 10:00 - 12:30 2.50 ~ FISH N ~ DFAL 12:30 - 19:00 I 6.501 FISH I N I DFAL 19:00 - 19:30 I 0.501 FISH I N I DFAL 19:30 - 22:00 2.50 FISH N DFAL 22:00 - 23:30 1.50 FISH N DFAL 23:30 - 00:00 0.50 FISH N DFAL 8I21J2007 00:00 - Oi:00 1.00 FISH N DFAL 01:00 - 03:00 2.00 FISH N DFAL 03:00 - 03:30 0.50 FISH N DFAL 03:30 - 06:30 i 3.00 ~ FISH ~ N ~ DFAL 06:30 - 08:30 I 2.00 FISH N DFAL 08:30 - 10:00 ( 1.50 FISH N DFAL Page 17 of 24 Spud Date: 8/8/2002 Start: 7/29/2007 End: 8/29/2007 Rig Release: 8/29/2007 Rig Number: Phase Description of Operations RUNCMP and inspect ram cavities. Removed a few pieces of thing flattened metal. Small amount of I-wire plastic covering. RUNCMP Rig up 4" test joint and prepare rig floor for BOP testing. RUNCMP Weekly BOPE test. Pressure test BOPE using 3.5" and 4" test I joints to 250 psi low, 4,000 psi high, annular preventer to 250 psi low, 3,500 psi high. Perform accumulator drawdown test. Witnessing of test was waived by AOGCC rep Chuck Scheve. Test witnessed by BP WSL's T. Anglen, M. Martyn, NAD TP's R. Hunt, B. Tiedemann. RUNCMP Rig down test equipment, blowdown lines. Install wear bushing. RUNCMP PJSM. MU BHA #26 -Fishing spear, Bowen Bumper sub, pump-out-sub, XO Sub, 4-3/4" Dailey Drilling Jar, 11 ea 4 3/4" DC's, Accelerator jar, X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #26 to 6,339' and and tag up on top of fish w/ shoulder above spear @ 6,339' md. PU - 157k, SO - 95k, circulate @ 91 gpm, 525 psi. RUNCMP Pull to 280k and hold for 30 minutes: Slack off and jar up and down w/ 20k over !under several times. Pull to 350k and hold 30 minutes. Work w/ dead pulls and jarring repeatedly but no sign of shearing pins. Unsting from fish and move spear up hole to inside packer body @ 6,346' md. Work pipe again for 30 miutes. No result. RUNCMP Unsting from fish, rack back stand, monitor well, perform post-jarring derrick inspection. RUNCMP POH from 6,346' and to top of BHA @ 862'. RUNCMP PJSM. LD BHA #26. RUNCMP Service Topdrive. RUNCMP MU BHA #27: 5.37" OD x 4.70" ID burnshoe w/ centralizing ribs at 6.1" OD, 6.06" Stabalizer, double pin sub, Boot baskets, bit sub, 1 ea 4 3/4" DC, Bumper sub, Oil jar, pump-out-sub, Bea 4 3/4" DC's, Accelerator jar, X-over. RUNCMP RIH w! BHA #27 to 6,300' md. PU - 150k, SO - 90k, RT - 110k. RUNCMP Take parameters and RIH @ 70 rpm, 7k TO, 4 bpm, 300 psi. Tag up on top of junk at 6,340' md. Pick up, shut down pumps, and RIH for dry tag at 6,342' md. RUNCMP Mill on packer #4 & junk on top. 80 rpm, 7.5k-10k TO. 8 bpm, 1000-1200 psi. ~ @ 6341' TO up and pull free @ 6342.2'. Pump 25 bbl hi visc sweep. Rot @ 81 rpms @ 8k tq @ 6341' @ 6342.4' w/ 6k S0 @ 80 rpms w/ 6700 - 6800 tq. Circ 326 gpm @ 1260psi Continue to work and pump pressure would increase to 1500 psi. P/U and dry Tag @ 6343'. Able to set 10k down while rotating w/ 6k tq. PU to just above pressure increase and pump 50 bbl hi visc and circ clean. RUNCMP I Bfow down Top Drive. POOH w/ tools from 6,342' and to 351'. RUNCMP PJSM. LD BHA #27. Missing 5" of burn shoe. 2 cups of metal in boot baskets including 2 slips, 2 pieces of broken spear grapple and a couple of large chucks of brass. Printed: 9/14/2007 10:06:55 AM • BP EXPLORATION Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date 'From - To Hours Task Code' NPT 8/21/2007 10:00 - 11:30 ~ 1.50 FISH N DFAL 11:30 - 12:30. 1.00 FISH N DFAL 12:30 - 14:30 2.00 FISH N DFAL 14:30 - 16:30 2.00 FISH N DFAL 16:30 - 18:30 ~ 2.00 FISH N DFAL 18:30 - 20:30 2.00 FISH N DFAL 20:30 - 21:30 1.00 FISH N DFAL 21:30 - 23:30 I 2.00 I FISH I. N I DFAL 23:30 - 00:00 I 0.501 FISH I N I DFAL 8/22/2007 ! 00:00 - 00:30 ~ 0.50 ~ FISH ~ N ~ DFAL 00:30 - 02:30 ' 2.00 ~ FISH N DFAL 02:30 - 06:30 4.00 ~ FISH N DFAL 06:30 - 09:00 2.50 FISH N DFAL 09:00 - 10:00 1.00 FISH N DFAL 10:00 - 13:00 3.00 FISH N DFAL 13:00 - 14:30 1.50 FISH N DFAL 14:30 - 15:30 ~ 1.00 ~ FISH ~ N ~ DFAL 15:30 - 17:00 I 1.501 FISH I N I DFAL 17:00 - 18:00 I 1.00 I FISH I N I DFAL 18:00 - 19:00 1.00 FISH N DFAL 19:00 - 21:00 2.00 FISH N DFAL Start: 7/29/2007 Rig Release: 8/29/2007 Rig Number: Page 18 of 24 Spud Date: 8/8/2002 End: 8/29/2007 Phase Description of Operations RUNCMP Clear & Clean rig floor. Conference call with town. RUNCMP Move tools to Rig. PJSM. MU BHA #28 -Fishing spear, Bowen Bumper sub, pump-out-sub, XO Sub, 4-3/4" Dailey Drilling Jar, 13ea 4 3/4" DC's, Accelerator jar, X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #28 to 6,314'. RUNCMP Take parameters. PU - 160k, SO - 95k, 4 BPM, 1520 psi. Attempt to siting into fish with spear. Took 30 minutes and vaying parameters to work into fish. Took 15-25k overpulls to pick back up after tagging solid bottom @ 6,343' on several attempts. On one attempt, took 40k over and jars went off to pull off bottom. Eventually able to work into fish @ 10 RPM and no pumps. RIH 12' and attempt to engage grapple - unable to set. Pulled 15-20k overpull when pulling out of fish. RUNCMP POH w/ BHA #28 from top of fish to 882' md. RUNCMP PJSM. LD BHA #28. Missing grapple from spear. RUNCMP Clean and clear rig floor. Service topdrive, drawworks, and crown. RUNCMP Conference w/ town over BHA configuration. Mobilize spear extension to location. RUNCMP PJSM. MU BHA #29 -Fishing spear w/ 5' extension and 2.625 taper mill, Bowen Bumper sub, pump-out-sub, XO Sub, 4-314" Dailey Drilling Jar, 13ea 4 3/4" DC's, Accelerator jar, X-over, 15 jts 4" HWDP. RUNCMP Continue MU BHA #29 -Fishing spear w/ 5' extension and 2.625 taper mill, Bowen Bumper sub, pump-out-sub, XO Sub, 4-3/4" Dailey Drilling Jar, 13ea 4 3/4" DC's, Accelerator jar, X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #29 from 350' to 6,330' md. RUNCMP Attempt to work spear into fish -unable. PU - 155k, SO - 95k, RT - 115k. Able to work taper mill down to a max of 6,344' md. Vary parameters between 0 and 40 rpm. Pumps off and on at up to 4bpm - 1700 psi. TO off bottom between 5.5 & 7.Ok. Limit RIH TQ to 0.9k above off bottom torque. Shut down, begin POOH. RUNCMP POH w/ BHA #29 from 6,344' and to 869' md. RUNCMP LD BHA #29. RUNCMP PJSM. RU to run Halliburton video log on fiber-optic a-line. ~ RUNCMP RIH w/ HES video logging tools from surface to original packer depth at -5600' md. Fluid not clean enough to see clearly. RUNCMP Bullhead 120 bbls filtered seawater to formation at 2 BPM, 211 psi to help clean debris from in front of camera RUNCMP RIH w/ video logging tools to top of fish at 6,334.5' E-Line md. Pictures show jagged top of tubing stub with slot cut into top by 3-4 inches.. Tag up w/ video tools @ 5.5' into fish. Only able to see any clear pictures from side viewing camera, either debris blocking down looking camera or fluid not clear enough to make out image. RUNCMP POH with logging tools. Due to fluid condition, not practical to log across all pens and packer set depths. RUNCMP RD logging tools. Blow down lines from hole filling operations. RUNCMP PJSM. MU BHA #30 - 6" 6 bladed concave junk mill, 4ea boot baskets, Bowen Bumper sub, Bowen oil jar, Sea 4 3/4" DC's, Printed: 9/14/2007 10:06:55 AM • BP EXPLORATION Page 19 of 24 ~ Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 , Rig Name: NABOBS 9ES Rig Number: Date 8/22/2007 8/23/2007 From - To ~ Hours '~~ Task !Code NPT ~' ~ - - - _ i 19:00 - 21:00: 2.0 ,FISH N DFAL 21:00 - 00:00 ~I, 3.00 FISH N DFAL 00:00 - 03:00 ' 3.00 FISH N DFAL 03:00 - 06:00 ' 3.00 ~ FISH ~ N DFAL 06:00 - 09:00 ~ 3.00 FISH N DFAL 09:00 - 10:00 ', 1.00 FISH N DFAL 10:00 - 11:00 ~! 1.00 FISH N DFAL 11:00 - 12:30 1.50 FISH N DFAL 12:30 - 14:00 I 1.50 FISH N DFAL 14:00 - 17:30; 3.50 FISH N DFAL 17:30 - 20:00 20:00 - 21:30 2.50 FISH N 1.50 FISH N DFAL DFAL 21:30 - 23:00 i 1.50 FISH N DFAL 23:00 - 00:00 ~ 1.00 FISH N DFAL 8/24/2007 00:00 - 01:00 !, 1.00 FISH N DFAL 01:00 - 02:00 1.00 FISH N DFAL Phase Description of Operations RUNCMP X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #30 from 775' to 6,320' md. RUNCMP PU single joint to prepare for milling w/ BHA #30. Take parameters. PU - 145k, SO - 100k, RT - 120k, 75 rpm, 6.2k TQ, 3 bpm, 180 psi. Tag up top of fish @ 6339.4' while pumping 3 bpm and no rotation. PU and rotate 85 rpm. Slack off and tag w/ rotation @ 6,338.9'. Mill down 4.0 feet to 6,342.9' w/ 7-8k TO and 5-12k WOB @ 85 rpm & 3-8 bpm. Pump hi-vis sweeps occasionally. Some I-wire debris and mostly metal fines in returns at surface. Pick up, shut down rotation, back pumps to 3 bpm. RIH & tag @ 6343.5' md. 4 feet gained. RUNCMP Begin milling last 0.5 feet. TO acting grabby and spiking to above 13k. When grabbing, PU off bottom and torque still ratty even 15' off bottom. Suspect mill is breaking up junk in last 6" to top of packer. Mill and work pipe until torque spikes stop. Once done milling last 6" mill acting slightly grabby but only on bottom, PU slightly and no problems. Shut down rotation and pump 3 bpm. SO and tag at 6,344' md. Pump sweep and begin POOH. RUNCMP POH w/ BHA #30 from 6344 to 775' md. RUNCMP PJSM. Lay Down BHA #30. Recover 1.5 gallons of metal cuttings/ shavings in 4 boot baskets. RUNCMP PJSM. MU BHA #31 - 6"x4.75" flat bottom burnshoe, 3.5x5.75" washover boot basket, Bowen Bumper sub, Bowen oil jar, Sea 4 3/4" DC's, X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #31 from 764' and to 6,311' md. RUNCMP Slip & cut 46' of drilling line. RUNCMP PU single joint for milling w/ BHA #31. Take parameters. PU - 150k, SO - 95k, RT - 117k, 70 rpm, 6.7k TO, 3 bpm, 100 psi. Tag up top of fish @ 6344' while pumping 3 bpm and no rotation. PU and rotate 70 rpm. Slack off and tag w/ rotation @ 6,343.5'. Mill down 6-8 inches w/ 7-8k TQ and 5-15k WOB @ 70 rpm & 3 bpm. Metal fines in returns at surface. Last hour of rotation made no footage. Pick up, shut down rotation, pumps at 3 bpm. RIH & tag @ 6344.2' md. Pump sweep and begin POOH. RUNCMP POH w/ BHA #31 from 6,344 - 764' md. RUNCMP PJSM. Lay Down BHA #31. Recover 1 quart of metal debris (I-wire chunks, slip cage pieces, 1 slip die, several broken pieces of grapple) and some packer rubber. Burnshoe worn down 3/4 inches and wear markings on inside only extend up .5 inches from bottom of shoe. Outside of burnshoe and washover boot basket was scarred & junk cut. Notify Anchorage engineer of plan to RU spear instead of overshot based on internal wear of burnshoe. RUNCMP PJSM. MU BHA #32 -Fishing spear w/ 2.81 muleshoe bottom, XO, Bowen Bumper sub, Bowen oil jar, Sea 4 3/4" DC's, X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #32 from 770' and to 3,353' md. RUNCMP RIH w/ BHA #32 from 3,353' and to 6,318' md. RUNCMP PU single from pipeshed for working pipe. Take parameters. PU - 155k, SO - 100k, 3 bpm, 240 psi. Tag up top of fish @ Printed: 9(14/2007 1~:~6:55 AM U BP EXPLORATION Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date ~I From - To Hours Task ~ Code-~ NPT ~ 8/24/2007 01:00 - 02:00 1.00 FISH N i DFAL I I ~ ~ ' I 02:00 - 05:30 3.50 FISH N ~ DFAL 05:30 - 07:30 2.00 FISH N ~ DFAL 07:30 - 08:00 0.50 FISH N I DFAL 08:00 - 09:30 1.50 FISH N ~ DFAL 09:30 - 11:30 2.00 FISH ~ N DFAL 11:30 - 12:30 1.00 FISH I N DFAL 12:30 - 15:00 2.50 FISH N DFAL 15:00 - 16:00 1.00 FISH N DFAL 16:00 - 17:30 1.50 ( FISH N DFAL 17:30 - 19:00 1.50 FISH N DFAL 19:00 - 22:30 3.50 FISH N DFAL 22:30 - 00:00 ~ 1.50 FISH N DFAL 8/25/2007 00:00 - 01:00 1.00 FISH N DFAL 01:00 - 02:00 1.00 FISH N DFAL 02:00 - 03:00 1.00 FISH N DFAL 03:00 - 05:00 2.00 FISH N DFAL Start: 7/29/2007 Rig Release: 8/29/2007 Rig Number: Page 20 of 24 Spud Date: 8/8/2002 End: 8/29/2007 Phase ', Description of Operations RUNCMP 6345.5' while pumping 3 bpm and no rotation. PU and not engaged, rotate 90 deg right tag again @ same depth. Repeat. Sting into fish on 5th attempt and RIH 2 more feet to no-go. Bottom tool depth was 6347.5'. PU to 190k to confirm engaged. Jar up 40k over x2 w/o result. Bump down w/ bumper sub and saw weight kick after 3x.~ PU and nack~ movin but stick . Work packer up next several stands before coming more easily. POOH. RUNCMP POH carefully from 6,346' to 770' with packer #2 on BHA #32. RUNCMP PJSM. Lay down BHA #32. Recover Packer #2, tea 5` pups, Phoenix sensor, 1'pup, 10' pup, X-Nip, 10' pup, 15.05' of joint #1 leaving 15.00' of joint #1 in hole. Chem cut looks in-gauge. Also recovered 3 half & 1 full I-wire clamps, and -80 ft of I-wire. Packer had 4" neck cut on it from BHA #31 and BHA #30 milled down to 4 inches above top of packer body. RUNCMP ~ Clean and clear rig floor of tools and fish components. RUNCMP PJSM. MU BHA #33 - 5.75" cutlip guide overshot w/ 3.5" basket grapple, Bowen Bumper sub, Bowen oil jar, Sea 4 3/4" DC's, X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #33 from 761' and to 6,415' md. RUNCMP Take parameters. PU - 153k, SO - 96k, RT - 123k, 3 bpm, 136 psi. Tag up top of fish @ 6,425' while pumping 3 bpm and no rotation. Rotate and slack off to swallow additional 4' of fish. Blow down top drive and monitor well. RUNCMP POH w/ BHA #33 and fish from 6,425 to 761' md. RUNCMP PJSM. Lay down BHA #33. Recover 15' cut joint, 10' pup, Mandrel #2, 2.42' of 9.8' pup. Jet cut belled to 4" OD. RUNCMP MU BHA #34 - 6.125"x4.75" flat bottom burnshoe, 15' of washpipe, 3.5x5.75" washover boot basket, Bowen Bumper sub, Bowen oil jar, Sea 4 3/4" DC's, X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #34 from 773' and to 6,416' md. RUNCMP Take parameters. PU - 155k, SO - 97k, 3 bpm, 150 psi. T~ up top of fish @ 6,462' while pumping 3 bpm and no rotation. PU and rotate 20 rpm. Slack off and tag wl rotation @ 6,474'. Mill down 1 foot w/ 8-9k TO and 5-10k WOB @ 80 rpm & 3 bpm. After 1 foot of milling, weight came back and_RIH chasing fish downhole to a tap at 6,586' md. Pump sweep and begin POOH. RUNCMP POH w/ BHA #34 from 6,586' to 3,834' md. RUNCMP POH w/ BHA #34 - 6.125"x4.875" flat bottom burnshoe, 15' of washpipe, 3.5x5.75" washover boot basket, Bowen Bumper sub, Bowen oil jar, Sea 4 3/4" DC's, X-over, 15 jts 4" HWDP from 3,834' to 773' md. RUNCMP PJSM. Lay Down BHA #34. Recover 1.5 gallons of metal debris (I-wire chunks, 1 slip die shaved thin, metal shavings) and some packer rubber. Burnshoe worn down 1/2 inch and wear markings on inside extend up 5 inches from bottom of shoe. Outside of burnshoe and washover boot basket was scarred. RUNCMP PJSM. MU BHA #35 -Fishing spear w/ 2.813 bullnose bottom, XO, Bowen Bumper sub, Bowen oil jar, Sea 4 3/4" DC's, X-over, 15 jts 4" HWDP. RUNCMP RIH w/ BHA #35 from 770' to -6,480' md. Printed: 9/14/2007 10:06:55 AM • BP EXPLORATION Page 21 of 24 Operations Summary Report Legal Well Name: S-215 Common Well Name: 5-215 Spud Date: 8!8!2002 Event Name: WORKOVER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 ',Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code i NPT ( Phase i Description of Operations 8/25/2007 05:00 - 06:00 1.00 - - _ - ___ FISH N DFAL tRUNCMP Take parameters. PU - 145k, SO - 98k, RT - 98k, 3 bpm, 280 06:00 - 09:00 3.00 FISH N 'DFAL 09:00 - 12:00 3.00 FISH N DFAL 12:00 - 13:30 I 1.501 CLEAN I N I DFAL 13:30 - 15:00 1.50 CLEAN 4'4 N DFAL 15:00 - 16:30 1.50 CLEAN I N DFAL 16:30 - 18:00 1.50 CLEAN N DFAL 18:00 - 19:30 1.50 CLEAN N I DFAL 19:30 - 20:00 0.50 CLEAN N DFAL 20:00 - 20:30 I 0.501 EVAL I N DFAL 20:30 - 23:00 ~ 2.50 ~ EVAL ~ N DFAL 23:00 - 23:30 I 0.501 EVAL I N f DFAL 23:30 - 00:00 0.50 EVAL N DFAL 8/26/2007 00:00 - 03:00 3.00 EVAL N ,DFAL 03:00 - 03:30 0.50 EVAL N DFAL 03:30 - 04:30 1.00 EVAL N DFAL 04:30 - 05:00 0.50 EVAL N DFAL 05:00 - 06:00 1.00 EVAL N DFAL 06:00 - 06:30 0.50 EVAL N DFAL 06:30 - 07:30 1.00 EVAL N DFAL 07:30 - 08:00 0.50 EVAL N DFAL 08:00 - 09:00 1.00 EVAL N DFAL 09:00 - 10:30 1.50 EVAL N DFAL 10:30 - 11:00 0.50 EVAL N DFAL 11:00 - 13:00 2.00 EVAL N DFAL 13:30 - 15:00 1.50 EVAL N ~ DFAL psi. Tag up top of fish @ 6,573' while pumping 3 bpm and no rotation. Sting into fish and RIH 2 more feet to no-go. Bottom ,tool depth was 6,575'. PU to 220k to confirm engaged. Jar up 40k over w/o result. Bump down w/ bumper sub and saw weight kick after 2x. PU and packer moving. Work packer up next few stands before coming more easily. POOH. ~ RUNCMP POH w/ BHA #35 from 6,575' to 770' '~ RUNCMP PJSM. LD BHA #35. Recover packer #1 and tubing tail. Break and lay down packer cut joint, 5' pup, pkr #1, 5' pup, ~~ X-Nip, tea 5' pup, GLM #1, tea 5' pup, X-Nip, 10' pup, 5' pup, I, XN-Nip, 10' pup, 5' pup, WLEG. Tubing tail plugged above 'nipple w/junk & debris. !CLEAN MU BHA #36 - 6" 6 bladed concave bottom junk mill, 6.125" I string mill, tea boot baskets, string magnet, bumber sub, ~ fishing jars, Sea 4.75" DC, XO, 15jts 4" HWDP. CLEAN ~ RIH w/ BHA #36 from 779' to 6422' md. CLEAN Take parameters. PU - 145k, SO - 96k, RT - 126k, 3 bpm, 180 psi, Wash down from 6,422' to 6,591' and @ 8 bpm 1150 psi, ~, 40 rpm, 2.5k TO off, 3.1 k TQ on. PU 10' and pump 50 bbl hi-vis sweep. Shut down, monitor well. CLEAN POH w/ cleanout BHA from 6,591' to 779' md. CLEAN LD BHA #36. Little debris in junk baskets. Slight scarring on OD of tools, but no major signs of excessive wear. !CLEAN Clear rig floor of any Baker tools while wating on Schlumberger slickline unit to arrive and spot in. OTHCMP PJSM for slickline operations w/ Schlumberger slickline crew, ~! PDS memory caliper hand, and rig crew. OTHCMP RU Schlumberger shooting nipple, wireline rams, pump-in sub ~ for pressure control. OTHCMP MU & test PDS 40-finger caliper tool. Tool not powering up correctly. OTHCMP Wait on PDS to trouble shoot tool. OTHCMP Troubleshoot PDS Caliper tool - no go. Mobilize replacement tools & test. OK. ~, OTHCMP RU new PDS memory caliper tools. OTHCMP RIH w/ PDS 40-finger caliper on slickline from surface to 6500' md. Standby for arms to open. OTHCMP Log from 6,500' and to 5,500' and @ 50' /min. OTHCMP POH to surface w/ caliper tool. No data recovered. OTHCMP RU Calliper for second run OTHCMP RIH w/ PDS 40-finger caliper on slickline from surface to 6500' 1 md. Standby for arms to open. i, OTHCMP Log from 6,500' and to 5,500' and @ 50' !min. ' OTHCMP POH to surface w/ caliper tool. Data recovered. OTHCMP RD slickline lubricator and wireline rams. i OTHCMP PJSM w/ Rig crew and Halliburton packer hand. RU for RTTS storm ackerrun. OTHCMP RIH with RTTS packer to 5.610' md. OTHCMP Set packer and attempt pressure test of casing. Casing test ~, talied at 1800 PSI, with 1 BPM leak rate. Release packer and I pull up hole 20' to 5,590' md. Pressure test casing to 4,000 PSI for 30 min -Pass. Release packer. Lay down single joint. Printed: 9/14/2007 10:06:55 AM • BP EXPLORATION Page 22 of 24 Operations Summary Report Legal Well Name: S -215 Common W ell Name: S -215 Spud Date: 8/8/2002 Event Nam e: WORKO VER Start : 7/29/2007 End: 8/29/2007 Contractor Name: N ABOBS ALASK A DRI LLING I Rig Release: 8/29/2007 Rig Name: N ABOBS 9ES Rig Number: Date - From - To ' + Hours Task Code j NPT _ Phase I Descnption of Operations _ -- -- - - 8/26/2007 ~ 13:30 - 15:00 1.50 EVAL I N DFAL I OTHCMP ~ Blow down topdrive & monitor well. 15:00 - 19:00 4.00 EVAL N DFAL ~ OTHCMP PJSM. POH w/ Packer assembly laying down 4" DP From ~ ~ 5589' to 742'. 1 19:00 - 20:30 1.50 EVAL N DFAL ~ OTHCMP Lay down 15 joints 4" HWDP, and Sea 4-3/4' DCs, XO, RTTS. 20:30 - 21:00 0.50 EVAL N DFAL ~ OTHCMP RIH with 14 stands of 4" HT-40 drillpipe remaining in derrick. 21:00 - 22:00 1.00 EVAL N DFAL ~ OTHCMP Lay down 42 joints of 4" HT-40 drillpipe. ' 22:00 - 22:30 0.50 EVAL N DFAL !, OTHCMP . Clean & clear rig floor. 22:30 - 23:30 1.00 BOPSU N DFAL , RUNCMP Pull wear bushing, Jet out BOP stack, install BOP test plug. RU 3-1/2" test joint. 23:30 - 00:00 0.50 BOPSU N DFAL RUNCMP Begin weekly BOPE test. Troubleshoot slow leak. 8/27/2007 ~ 00:00 - 03:15 3.25 BOPSU N DFAL ' RUNCMP Troubleshoot slow leak off from BOPE pre-test. 03:15 - 06:30 3.25 BOPSU N DFAL RUNCMP Weekly BOPE test w/ 3.5" test joint. Pressure test BOPE to 250 psi low, 4,000 psi high, annular preventer to 250 psi low, 3,500 psi high. Perform accumulator drawdown test. Witnessing of test was waived by AOGCC rep. John Crisp. Test witnessed by BP WSL's M. Martyn, B. Buzby, NAD TP's R. Axness, G. Hoffman, R. Hunt. 06:30 - 07:00 0.50 BOPSU N DFAL j RUNCMP Blow down lines & rig down all testing equipment. 07:00 - 13:00 6.00 BUNCO DFAL RUNCMP Wait on service hand to arrive due to shared services flight ~ cancelations yesterday. Clean under pipe racks, clean all subs ' and send for insepction. Prepare for rig maintenence. !~ 13:00 - 16:00 3.00 BUNCO DFAL RUNCMP Make dummy run w/ tubing hanger and RU two I-Wire spools, ~ i one pressure line spool, two i-wire sheaves, and nabors casing service. 16:00 - 00:00 ~ 8.00 BUNCO DFAL RUNCMP Begin running completion jewelry. Run WLEG, XN-Nip,X-Nip, GLM#1, X-Nip, Pkr #1, GLM#2&3, X-Nip, Phoenix Sensor, Pkr#2, GLM#4&5, X-Nip, Pkr#3, GLM#6&7, Phoenix Sensor, Pkr#4, X-Nip, GLM#8. Take approximately 1 hour to splice t-Wire @ each packer. Torque turn to 2,100 - 2,500 ft-Ibs and dope w/Jet Lube seal guard. Dump valve on torque turning ~ equipment malfunctioning slightly. 4 connections torqued to 2500-2580 ft-Ibs and required backing out and re-torquing. Troubleshooting equipment during packer splicing. 8/28/2007 00:00 - 03:30 3.50 BUNCO DFAL ~ RUNCMP Continue running 3-1/2" completion string to packer #6. Torque turning connections to 2,300 ft-Ibs and doping w/Jet Lube Seal Guard. Make final I-wire splice and test packer voids to 5,000 psi - OK. 03:30 - 14:30 11.00 BUNCO DFAL RUNCMP Continue running in hole with 3.5" completion assembly and position tubing to set on planned depth @ 6,553'. Tested 1-wire continuity every 1,000 ft. 14:30 - 15:30 1.00 BUNCO DFAL RUNCMP PJSM. Rig up SWS E-line. 15:30 - 17:30 2.00 BUNCO DFAL RUNCMP Log in completion string with GR/CCL tools. Correlate depths and make -5 ft correction (-5 ft difference from OKB) Rig down i SW S. 17:30 - 18:30 1.00 BUNCO DFAL RUNCMP Space out tubing to land on depth @ 6,548'. 18:30 - 19:30 1.00 BUNCO DFAL RUNCMP Make up landing joint and tubing hanger with 12 blast rings. Terminate and test I-wire - OK. 19:30 - 20:00 0.50 BUNCO DFAL RUNCMP (Land tubing. Run in lock-down screws. PU - 87k, SO - 63k. Depths (9ES RT): 3.5" 9.2 #WLEG, 3.5" TC-I I - 6548.25' Tops: ~ 3.5" HES 'XN' Nipple: ID 2.750 - 6536'. 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug - 6515'. Printed: 9/14/2007 10:06:55 AM • • BP EXPLORATION Page 23 of 24 ~ Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date. ,From - To 8/28/2007 19:30 - 20:00 S-215 S-215 Spud Date: 8/8/2002 WORKOVER Start: 7/29/2007 End: 8/29/2007 NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 NABOBS 9ES Rig Number: Hours Task 'Code NPT Phase '~ Description of Operations 0.5011II RUNCOt~1N f DFAL ~ RUNCMP GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch - 6496'. 13.5" HES 'X' Nippie: 2.813" ID - 6485'. ---~ 3.5" x 7" HES single feedthru Packer #1 packer - 6472'. GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch - 6448'. 1 Jt 3.5" 9.2# L-80 TC-II Tubing (#1) GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch - 6377'. 3.5" HES 'X' Nipple: 2.813" ID - 6366'. Phoenix Sensor sub - 6354'. 3.5" x 7" HES Single feedthru Packer # 2 packer - 6341'. GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch - 6326'. GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch - 6297' 3.5" HES 'X' Nipple: 2.813" ID - 6291'. -~-~ 3.5" x 7" HES Dual feedthru Packer # 3 packer - 6282'. 3.5", 9.2#, L-80 TC-II Pup with RA Pip Tag - 6277'. GLM #6 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch - 6263' GLM #7 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch - 6227'. Phoenix Sensor sub - 6220'. -~ 3.5" x 7" HES Dual feedthru Packer # 4 packer - 6207'. 3.5" HES 'X' Nipple: 2.813" ID - 6296'. ~ GLM #8 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK Patch - 6177. 3 jts 3.5" 9.2# L-80 TC-II Tubing (#2- 4 ) 3.5" x 7" HES Dual feedthru Packer # 5 packer - 6057' 15 jts 3.5" 9.2# L-80 TC-II Tubing (#5- 19 ) 3.5" x 7" HES Dual feedthru Packer # 6 packer - 5555'. 3.5" HES 'X' Nipple: 2.813" 1D - 5539'. 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 20 ) GLM #9 - 3.5" x 1.5" MMG w/ DCR-1 SHEAR VALVE & RKP latch - 5479'. 92 jts 3.5" 9.2# L-80 TC-II Tubing (# 21- 112 ) 3.5" HES 'X' Nipple: 2.813" ID - 2505' 76 jts 3.5" 9.2# L-80 TC-II Tubing (#113-188 ) tea 3.5" 9.2# L-80 TC-II Space out Pups (5.78', 3.80') 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 189 ) 3.5" 9.2# L-80 TC-II Pup 4.5" X 3.5" TC-II Crossover w/ 12 Blast Rings FMC Tubing Hanger w(4 1!2" TC-ll Lifting Threads 20:00 - 20:30 0.50 BUNCO DFAL RUNCMP Drop ball and rod down tubing. Laydown landing joint. 20:30 - 21:15 0.75 BUNCO DFAL RUNCMP Fill tubing and let air work out. Pressure up to 500 psi and hold 5 minutes. Continue pressuring up to 4,000 psi to set packers. I Hold pressure for 30 minutes -Good test. Bleed tubing pressure down to 2,500 psi. 21:15 - 21:45 0.50 BUNCO DFAL RUNCMP Fill annulus and let air work out. 21:45 - 22:30 0.75 BUNCO RUNCMP Pressure test IA to 4,000 psi for 30 minutes -Good test!!!! No tubing pressure anomalies. Bleed annulus pressure to 0 psi, bleed tubing pressure to 0 psi. Pressure up annulus to shear out DCR shear valve. Sheared at 2,950 psi. Pump both ways to check pumpability - OK. IA @ 3 bpm - 500 psi, tubing @ 3 ~ bpm, 420 psi. Printed: 9/14/2007 10:06:55 AM t • ~ i I BP EXPLORATION Page 24 of 24 Operations Summary Report Legal Well Name: S-215 Common Well Name: S-215 Spud Date: 8/8/2002 Event Name: WORKOVER Start: 7/29/2007 End: 8/29/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/29/2007 Rig Name: NABOBS 9ES Rig Number: Date I From - To I Hours NPT I Phase ' Description of Operations Task 'II Code i I - _ - - - -- - -- --- 8/28/2007 22:30 - 23:30 1.00 RUNCONIP RUNCMP Rig down I-wire spooling equipment and clear rig floor. 23:30 - 00:00 0.50' BOPSU P RUNCMP Rig up and jet out BOP stack in preparation for removing rams. 8/29/2007 00:00 - 00:30 0.50 W HSUR P RUNCMP Set 2-way check valve in tubing hanger with T-bar. Test to 1,000 psi from below - OK. 00:30 - 02:30 i, 2.00 ~ BOPSU P RUNCMP Open all rams and remove same. Close doors. 02:30 - 04:30 2.00 BOPSU P RUNCMP Nipple down BOPE. 04:30 - 08:00 '• 3.50 WHSUR P RUNCMP Install tree adaptor flange. Make wellhead 1-wire termination. i Test adaptor to 5,000 psi - 10 min - OK. Nipple up tree. Orientation of adaptor flange was wrong for tree orientation. 08:00 - 09:00 '; 1.00 WHSUR N HMAN RUNCMP Nipple down tree and adaptor flange. 09:00 - 10:30 ~ 1.50 WHSUR N HMAN RUNCMP Orient and nipple up adaptor flange. Reconnect I-Wire. Test adaptor to 5,000 psi - 10 min - OK. Nipple up tree. 10:30 - 11:00 0.50 W HSUR P RUNCMP Pressure test tree to 5,000 psi - OK. 11:00 - 11:30 ;; 0.50 WHSUR P RUNCMP Rig up Drill Site Maintenance. Test lubricator to 1,000 psi - OK. Putt 2-way check valve. 11:30 - 12:00 0.50 WHSUR P RUNCMP Rig up to circulate corrosion inhibitor and freeze protection. 12:00 - 13:30 ' 1.50 i WHSUR P RUNCMP Reverse circulate 47 bbls of 8.4 ppg clean seawater, followed 'I by 78 bbls of corrosion inhibited seawater at 3 bpm, 320 psi. 13:30 - 14:30 1.00 W HSUR P RUNCMP PJSM with LRHOS. Pressure test lines to 3,000 psi - OK. Reverse circulate 90 bbls of diesel at 2 bpm, 230 psi ICP, 320 psi FCP. 14:30 - 15:30 1.00 WHSUR P RUNCMP Allow diesel to U-tube back to tubing. Well freeze protected to -2,526' MD, 2,500` TV D. 15:30 - 18:00 ~ 2.50 WHSUR P RUNCMP Rig down circulating lines. Lubricate BPV into tubing hanger. Test to 1,000 psi from below - OK. Install IA VR plugs. Secure cellar. 18:00 - 20:00 2.00 WHSUR P RUNCMP Empty mud pits of all fuids. Prepare rig for move while emptying mud pits. 'Release rig from S-2151 operations and start Summer I Maintenance at 20:00 hr. 8/29/2007. Printed: 9/14/2007 10:06:55 AM TF:E"E ~ ~ CA~t 4- i 1 c," Stif lc L~ E~~, w 11, j}~tu~n C4 D = .Ci 7J' SS~ ~„~ ~, ~ ~ SA Tom. GLh1 s ~ S7A #i-#8 ARE 3-'9 t2 X 3- iJ2 ~-OV 4+.fHICfl xi~TE VJA7~tFt..3~D MANS. - _ 2` ~- ~ i 1. " ~ ~ Y,~ '~ Eta - 2 99~" .~ . , .. __~. ~:)'JC}UGIt~R '('~~' ~ ~~[t~' .~- 1 ~' l~E x ~t~P ~~?~2_843" G 0152 lapf . 4G = 3.958" 9-518"' GSG, 413#, ~.°?Q. I,' i = 8.8"a"" -^' ~'~t~..~~ --- 7"" 61CA ~t P't`R J~~R~! t l~'v1 ~ TAG - T17~ rv~ ~ 570' _ . --- -- 7'"X3-1 ~' I'~a AHk:'f'KR. !4~ = ~ ~1?-~"-~~- ~~~' Ho9~ in 7" G~sing a~91' T' X 3-1 t2" HC,S A NR 1''Kf~, IC1= 2.96.s 6{3~t r' r;"~tRl:r>~ ~o~rrrw'~~ T~tG- TfJP :~H ~ 62{?d'~ t ____ ....- __.... _ _ _ __ ~_ RA T,q 'r c~;~:<~r a:;,:~v~ f'~:;k~~ # fs2'7 i'it~lil3~fl'1CtPT4 ~~ =.t~v"' ~ 6~.?~~~ ;~-112" HEM ~~ {~~PPL~ r9c~>ri ~1un.~^~ri,~ ~:~~ ~,n, ~ ar~~J,;~, J.~'~,~~ ~~~a_,_E;aTroF~"c~r ~~°~~ ~~~~;' ~.. ice" F:E'.it.f ':O f'C C)~'~J ,li, ll iP fCf hlS f,~C r,,,t ~~:~Yf i~3(,3 _ rat, Es~~=3~~ f~~ t t n ;~ ~~f ," ,._ ~; 4,,, ._ alb: ail 1-F S,Q r.J ~7 ~;~t~ la ct %^a" ._ ?}~.: r~i ;~-b119 f~ 0 X76'_13 > ?'rte'" ? )A.: ri~ t~ ,26:`S ~ fl nri;':i3 ,.~ 2 ~ F;,~" o~ Cl t3, u;~~~> 2..7;8" 2 i7}~c, r~,tB~J 6•<45CT fl t7~'Dfi'tit ~'. >'~t" 2 rJBi:t~5'~-ri,7.1'~ (~ ±3~ Citi';:;3 r? Fib" 2 Cl+"~ . 6~ d ; E;55U (3 D~ Uc;;'03 -i> 1 r l~, ~ #. 1.~f0, tail U 1)r,3 ~ b~T I) ~= 2 ~JZ' {~'~~'~' - --- - 7"• {°:fi(~, 2F L ;,i}, RlC.~v9 i~) r "f~' ~~ ki91,~' ~ ~ h~1E~ ~ G L f / ~,~ ~ ~s k ~` ice, c ' { pC7 ~:-# L t 1; r+ w., 34 1.z MC i _ R-1 RE ? 1 ~ r, -i >,' ., _,_ .~_. ~... _ _ _ _.Y _ .-. -- S I !Jl[` 1 V f) t)EV T`! ('F ~/[. V 4 i C;H P~JRT N F c`i. E~ 1 > t~ 541:> ~:, t~'Pur{~-L`+/ t:1 _V ~!{ t .5°' Q8l311107 7 22{~ ;r}5~) 4~ 8§Mi3-LV tp~JCw1 RK 1:5" 11813{1#Q7 fi ';Z6~ ,,0%~ ,1E; TvtMG LV I}U'+ti RK 1.5" E18,'3{11437 `, ri-4?i~ >()48 4n ~fi?',ft}-'Rr [aU"~1 R 4.5" 11813(3/[37 4 r~:32 ~ ~ i 1} 4I TvMG-1rV ?_}t)~tii RK 1:5'" 118t31?/f37 i 637? 5154 •S f+~1Pw1G-4'>~ S~UVI FiK 1.5" Q8P3111t17 J !>~M143 a:tl"Z, h? C1`P~'r~-L~.r i}iJ"vi RK 1 ra' 118F3C3#C17 3 E;~19b ^:5'~ 4~# R~1v1G'vV C/=JPl1 RK 9 ~" 118t3t3~1T ~'1 ~~' }-~ 11? "HFG'" }" f`~'F~la~, fE? 7_$13° 62UG' ~---~ _ . ;, 3 f f L" NHS A 1-!f~ r~1tR, 4i3 - 2.965.. 8~~~~--~PtIC: t'I?::'~tE.,c T~to~1P .-y51?R SlFB, (17 = 2 992"" 635A~ rtf0 ~thC e';~ .,,TF'49!' t hl~CzR 5U6, fC3 = 2.992„ - T - -- 53fi1j` i- t ': HFS" X t!8~~~e`_, i! =1 ,,' -- &4$ ~' ~,~ t?"11E;;" X tJ?p}aka, if7 _£>13„ 615' 3-tl2`" HE•`'.X t`h~~t.~a ~:`I-iC; lC1=2.813" ~J~Jfi~ a~,-"~~2~"~~~~ ~. ~J"NipptC ~~=~.t'rJ13>r it rL; rC; ~ s .i_r0 ~~~~~ _. -, ( , ~;T'= Rt_V tTY - Gtr*~1h1~JTS EIAIE REV BY l.t`!'v~'71[^!4S i-'()i.A.RI ~t?J1T DIII3G147 SJE3 S-3'f~i -2'u~}+J i^~TLL ., ='15i _f;h'~T Ja ?U? 1 `~<1 SEC 35, 1`12t~, F?t ~~, ~{;03' i NL, 717' ~l. - ~i• Exploeati~n {Alask~j • PBU_5-215_repaired_2003-0723.txt Subject: Fw: 5-215 (PTD 2021540) T x IA comm diagnostics update Date: wed, 23 Jul 2003 10_52:16 -0500 From: "NSU, ADW We Integrity Engineer" <NSUADWWeIIIntegrityEngineer@BP.com> To: "Jim Regg (E-mail)" <Jim_Reg~@admin.state.ak.us>, "winton Hubert (E-mail)" <winton,ubert@admin.state.ak.us> CC: "NSU, ADW Well Integrity Engineer" <NSUADWwellInte~rityEngineer@BP.com>, "Bob Fleckenstein (E-mail)" <BOb_Fleckenstein@admin.state.ak.us> Hi ]im and winton, Since our last correspondence concerning 5-215i (PTD 2021540), we have performed the following diagnostics: 1. Slickline has re-dummied the GLM. 2. MITIA t0 3000 psi passed. Our plan is to return this well to normal injection status. If you have any questions, or need additional information, please don't hesisitate to call. Thanks, John Cubbon GPB well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 -----original Message----- From: NSU, ADw well Integrity Engineer sent: Wednesday, July 02, 2003 9:15 AM To: AOGCC Jim Regg (E-mail); AOGCC Winton Hubert (E-mail) Cc: NSU, ADW Well Integrity Engineer Subject: 5-215 (PTD 2021540) T x IA comm diagnostics update Hi Jim and winton, Since our last correspondence concerning 5-2151 (PTD 2021540), we have performed the following diagnostics: > 06/05/03: Slickline checked sliding sleeve, re-dummied the GLM in sta #1 > 06/30/03: MITIA Failed, LLR 2.5 bpm @ 2100# Plans forward are as follows: 1. Slickline to cycle the sliding sleeve and re-MITIA. If MITIA fails, a TTP will be set and a leak detection log will be run. 2. Continue with PwI only until diagnostics are complete (Slickline work planned for the week of 7/7/03). Please call if you have any questions, or would like to discuss other options. we will keep you informed on the progress of the diagnostics. Thanks, Page 1 • • PBU_5-215_repaired_2003-0723.txt John Cubbon GPB Well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 -----original Message----- From: NSU, ADw Well Integrity Engineer sent: Thursday, May 29, 2003 3:40 PM To: NSU, ADW Well Integrity Engineer; 'AOGCC Field Inspectors (E-mail)'; 'AOGCC Jim Regg (E-mail)'; 'AOGCC Winton Aubert (E-mail)' Cc: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; Dube, Anna T; Schmohr, Donn R subject: 5-215 (PTD 2021540) T x IA comm diagnostics update Hi Jim and Winton, Since our last correspondence concerning 5-215 (PTD 2021540), the well failed an MITIA on pressure stabilization on 5/26/03. The MITIA data is as follows: T/I/0=380/500/0 MITIA FAILED (Eval IA repress.); IA FL at surface. Well is 52. Pumped 3 bbls of methanol to pressure to 3000 psi. First test lost 160 psi in 15 minutes, second test lost 120 psi in the first 15 minutes and 110 psi in the second 15 minutes for a total of 230 psi in 30 minutes. Third test lost 120 psi in the first 15 minutes and 110 psi in the second 15 minutes for a total of 230 psi in 30 minutes. Pumped a test volume of 14 gallons in 84 minutes for an average leak rate of 0.2 GPM @ 3000 psi. Final WHP's=370/550/0. current plans are to have slickline check to assure that the sliding sleeve (5535' MD on the attached WBD) is closed, changeout the DGLV at 3476', and re-MITIA. We will notify you of the testing results. Please call if you have any questions, or if you prefer some other evaluation procedure. Thanks, John Cubbon GPB well Integrity Coordinator 1-907-659-5102 pgr. 659-5100, x. 1154 -----original Message----- From: NSU, ADW Well Integrity Engineer Sent: Wednesday, May 21, 2003 8:13 AM To: AOGCC Field Inspectors (E-mail); AOGCC Jim Regg (E-mail); AOGCC Winton Aubert (E-mail) Cc: NSU, ADW Well Integrity Engineer; Petty, John C; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Fld TL; GPB, Well Pads NUP; Young, Jim; Soria, Artie L; Johnson, Craig E Subject: FYI: 5-215 IA Re-Pressure Hi Jim & Winton. 5-215 (PTD 2021540) is a recent producer to injector conversion Page 2 • PBU_5-215_repaired_2003-0723.txt exhibiting IA repressurization. An AOGCC witnessed MITIA passed to 2000 psi on 5/15/03, post injection start. The IA has since repressured to the tubing pressure. Recent events: > 04/30/03: Circ pkr fluid, MIT-IA Passed to 1500 psi. > 05/10/03: POI > 05/15/03: MITIA Passed to 2000 psi. AoGCC witnessed. Bled IAP t0 50 psi > 05/16/03: TIO = 950/1200/50. IA repressure 1200 psi overnight to tubing pressure. > 05/17/03: TIO = 900/1200/50. Bled IAP to 100 psi. > 05/18/03: TIO = 900/1170/130. Current plans are to repeat the IA bleed and monitor the buildup rate. Based on results, we'll probably repeat the MITIA, we'll notify you of the testing results. Please call if you have any questions or prefer some other evaluation procedure. ]oe ]oe Anders, P.E. / ]ohn Cubbon well Integrity Engineer, BP Exploration, (Alaska) Inc. work: (907) 659-5102 Mobile: (907) 943-1154 Pager: <907) 659-5100, x1154 Email: NsuA~WWe1lIntegrityEngineer@bp.com Name: 5-215.pdf 5-215.pdf Type: Acrobat (application/pdf) Encoding: base64 Name: MIT PoL s-215 07-22-03.x1s MIT Pot 5-215 07-22-03.x1s Type: Microsoft Excel worksheet (application/vnd.ms-excel) Encoding: base64 Page 3 08/30/07 Schlumbergol' 5r;.,~NEO SEP 1 8 2007 NO. 4401 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company; Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Midnight Sun Borealis Well Job # Log Description Date BL Color CD E-102 11637355 PRODUCTION PROFILE dbL - ["II'( 07/28/07 1 S-215 NIA USIT U'J:..l.' ~{..~ - 1 tc:"1.I 08/01/07 1 Z·102 11637125 CH EDIT PDC GR IUSIT ¿; .J "'I'-O:::>D 05/16/07 1 ~n'J I W-213 11638637 CH EDIT PDC GR fUSIT . r ~ r . .,,-., -nS'"' 05/31107 1 ' ~'-I II. . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: ::~ÇiÙeliJ¡,re,ji ZOO I Schlumberger~DCS 2525 Gambell St, Suite 400 Anchorage AK 99503.2818 A TTN Beth (¡ Received by C. _ ):. '/L.-r- r:Oil.;. . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~ ~ ~~z~;l~_.) DATE: Aug 3, 2007 P. (. Supervisor i~~~ ~.,.~ Li ~~~~' NCB ~ ~ ~pC7 ~~ FROM: Bob Noble SUBJECT: Post Completion MIT Petroleum Inspector PBU S-215 BPXA PTD - 202-154 Auu 03, 2007: i traveled to PBU S-2151, Nabors 9ES, to witness the post completion MITs on the tubing and inner annulus. BPXA completed workover of this injector, installing 5 packers. Joey LeBlanc was the BPXA rep; Kelly Cozby was the Nabors 9ES rep. Summary: On arrival we performed a test on the tubing. Pre T10=0/0/0; Initial T10=40001010; 15 min T10=4000/010; 30 min TI0=400010/0; passed. It took 14 strokes to pressure up. BPXA then performed a test on the inner annulus. Pre T10=2500/0/0; attempted to pressure up to 4000 psi; it should have taken 38 strokes. Pump was shut down after 140 strokes with IA pressure only at 1800 psi. IA was bled down to 800 psi in 7 minutes. Tubing and OA remained 2500 psi and 0 psi respectively. Another test was attempted with same results. Well was shut in and surface equipment was tested - it held. Tubing was pressured up to 4500 psi to make sure top packer was set - confirmed. Joey LeBlanc made some phone calls and someone brought up that the original packer (set at 5599') was released with a chemical cutter and they remembered a cut all the way through the packer when it was removed from the well. This made Mr. LeBlanc think that the chemical cutter might have cut through the IA casing. The new top packer was set at 6502 ft. They think this is where the leak would be. Next step was to rig up a-line and log the packers; decision about recompfetion. I left location and told the BPXA rep to call the Commission Inspector to witness a retest when they recompleted the well. Attachments: MIT reports (MiT-T; MIT-IA) j ~ • State of Alaska • MEMORANDUM Alaska Oil and Gas Conservation Commission -'"1 DATE: Friday, September 07, 2007 Jim Re `` ,.G ~ ~ • Mechanical Inte ri Tests P.I. Su ervtsor ~ `~ ~ SUBJECT. g ty d. P BP EXPLORATION (ALASKA) INC 5-215 FROM: Bob Noble PRUDHOE BAY 1JN POL S-215 Petroleum Inspector Src: Inspector NnN-CnNFiDENTIAL ~ ~~~ ~~ Reviewed By: rn ,^ P.I. SuprvJ~~~ Comm Well Name: PRUDHOE BAY UN POL S-215 API Well Number: 50-024-23107-00-00 Inspector Name: Bob Nobte Insp Num: mitRCN070803210947 Permit Number: 202-154-o Inspection Date: 8/3/2007 Rel Insp Num: Packer Depth Pretest Initial - 15 Min. 30 Min. 45 Min. 60 Min. Well ~ s-zIS Type Inj. , N TVD bosz ~ IA ~-.- o ~ o ~ ~ ° ~ ~ P.T.Dj zo2lsao ITypeTest ~ SPT ,i Test psi aooo ~j ~0A o o ~ ~ o I o _ ~~ ~ j Interval ~OVR PfF ~ P Tubing j o aooo ~ aooo aooo Notes: This is a post completion workover pressure test on the tubing. Well is 5-215i ~`~.,r -- Friday, September 07, 2007 Page I of I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ,.--, ,; ¡ , / gj¡¡ /,-'1 ¡'''- t? r; tJ 'fl/:;:/v ( ~.~ I ,. f ,{ DATE: Thursday, August 09,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-215 PRUDHOE BAY UN POL S-215 FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv GeL Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN POL S-215 Insp Num: mitRCN0708032 10947 Rei Insp N um: API Well Number: 50-029-23107-00-00 Permit Number: 202-154-0 Inspector Name: Bob Noble Inspection Date: 8/312007 Packer Depth Well S-215 Type Inj. ! N ! TVD ¡ 6052 P.T. i 2021540 !TypeTest I SPT ¡ Test psi: 4000 Interval WRKOVR P/F P / Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. o I ! I I i -~ I IA i i OA I Tubing i o o o o o o o ! I i o 4000 4000 I 4000 Notes: This is a post completion workover pressure test on the tubing. Well is S-215i ./ SCANNED AUG 2 3 2007 Thursday, August 09, 2007 Page I of I ò()~.. \ 5 L..\ MEC~~ICAL INTEGRITY REPORT "'- :. ~ G 2 ~ :.. .:: ;._:.: z ; OPER & FIELD ß? l' \'J~ ?C\()..~<=) \.:=:LL NUMJ3ER ~ - ~ \ S" ~?UD G.:.:::: <¡'l~-c~- '"ë.S ~~g: ~ TD: ~G.~ÒMD SS~\ TVD; ?ETD: ~¡-J '; MD S'-'S~ TV1) Shoe: eo<\\5' è{[) T\TD j DV: ~Þs HDIVTI -r! !:.LL DAI_~_ _:"":ìe::-: Shoe: }ill IVD; ~~.,... _ i,...;.r : HD ;:'ìD _:..lD~:;g: Packe:!:' till TVD; Set: ê. t ::.ole Size ~~f'-\ ana Pe::-£s I~~'t to <o5()S- \" ~\:)\~\r:(\k \~~~~\> :-SC?.Þ.1ECl--L INTEGRITI - PART il Annulus Press Test: :P ; 15 m.~n 30 min Corraents: _+ct.~\~ '!t.ù\\....."=> ~ \ t\ ~ 4t)~~\ <".ltu'o\V'~~ ~S()b ~('"':iA-\Q-\ '> /' ~CfuU'ECÞ.l.. INTEGRITY - PART ¡ 2 Ce!!lenc Volumes: Amt. Liner ; Csg t;~t~~~ DV ~~ . Ctiit -"01 to cove~ De::-=$ C..~O~"'~ '-\Ca~~\~ -'.o(.tÑ(,\ ~~~ ~~ß ScxJt Tteo:!:'ecical Toe Q:3~?o ~~ \Cc:... ~~\~ I " ':> '- '^ '\ \, h(o'" () ~ CemenC Bond Log (Yes or No) \~.~ ; In AOGCC File CEL =:valuation, ::one ë.Dove perfs \o~~Ç:,.ð ~\O~ ~~~\~~~\ \ C 5 ~~(:)' \os '~"t c:..o. ~ c:. '\ c,ô \0.. \- '\ () '" Prociuction Log: Type : Evaluation 5'CANNED JUL 1 ß 2001 CONC;LUSIONS: P ar t if 1 : P ar -= f. 2 : ~'l. '-:, \,,~\ Cl"~~~) .. ~4yV( '(/\~-O~ ~ . ~u~uŒ (ill~ ~~~~æ~ . AI/ASIiA OIL AND GAS CONSERVATION COMMISSION SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration Alaska Inc PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PBU S-215i Sundry Number: 307-189 àDJ--IN S~ED JUN 1 1 l007 Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 5. day of June, 2007 Encl. 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time Extension '" o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. D Development D Exploratory 202-154 3. Address: 181 Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23107 -00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU S-215i Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028258 71.49' Prudhoe Bay Field / Polaris Pool 12. . PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth NO (ft):/Effective Depth MD (ft): Effective Depth NO (ft): Plugs (measured): Junk (measured): 6930 5523 6834 5459 None None Casinn Lenath Size MD NO Burst Collanse Structural Conductor 114' 20" x 34" 114' 114' Surface 2912' 9-5/8" 2946' 2847' 5750 3090 Intermediate Production 6884' 7" 6915' 5513' 7240 5410 Liner Perforation Depth MD (ft): I Perforation Depth ND (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 6098' - 6595' 4960' - 5300' 4-1/2",12.75#/12.6# L-80 /13Cr80 5660' Packers and SSSV Type: 7" x 4-1/2" Baker Perm Packer I Packers and SSSV MD (ft): 5599' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory D Development 181 Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: CommencinQ Operations: July 25, 2007 DOil DGas D Plugged D Abandoned 17. Verbal Approval: Date: 181 WAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Staudinger, 564-4337 Printed Name Robert Tirpack Title Senior Drilling Engineer ~¿;-~~ DateÇ;hh Prepared By Name/Number: Signature Phone 564-4166 Terrie Hubble, 564-4628 ,,' Commission Use On Iv Conditions of approval: I Sundry Number: ( ~() 1 _ I ~ OJ Notify Commission so that a representative may witness D Plug Integrity D BOP Test '~Mechanicallntegrity Test D Location Clearance Other: 4~CD~'\ ~\/ \e'?\.c..,,:> ~\<>.~~ ,0 ~~~t-s'\~ Ú.C-c.D~\)..j I ~\a d-S-~ , ) Subsequent Form Required: 40'-\ ,/f¡ APPROVED BY Date 6'-rf-'ðr Approved Bv: MISSIONER THE COMMISSION Form 10-403 Revised 0612006 V~ '- -- Submit In Duplicate , ~ . STATE OF ALASKA I ALASKA Oil AND GAS CONSERVATION COM ISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25 280 RECEIVED JUN 0 5 2007 Alaska Oil & Gas Cons. Commission OUPLfCt\TE RBDMS 8ft JUN () 82801 . . To: AOGCC Date: May 30,2007 From: Mark Staudinger - BPXA GPB Rotary Drilling Engineer Subject: S-215i Application for Sundry Approval Approval is requested to perform a rig workover on Polaris WAG injection well S-215. The well is currently completed as a Schrader-only injector with all perforation zones open below the tubing tail, and no injection regulation between zones. S-215 is intended to support the heel/mid-section of penta-lateral S-213A which produces from the OA, OBa, OBb, OBc, and OBd sands. S-215 suffered a matrix bypass event (MBE) in early 2006 in which it connected to S-213A in the OBa interval. Injection in S-215 became a direct short- circuit to S-213A, and therefore it lost its effectiveness as an injector. The well was shut-in June 2006, and has remained SI since then. The RWO will alleviate this problem. The RWO scope includes a cut and pull of the existing Baker Premier packer and 4-1/2" tubing, and then running new 3.5" x 4.5" L-80 tubing with premium threads to allow for water and future MI injection. Phoenix downhole pressure gauges will be run across each of the straddled zones to provide real-time sand-face pressure monitoring. Straddle packers will provide individual downhole injection rate regulation via waterflood mandrels and regulating valves over the existing perforated intervals: OA, OBa, OBb/OBc, OBd/OBe. The existing Nb/Nc perfs will also be straddled, but since there is no current offtake from these zones, they will remain dummied, but available for future injection if desired. The new completion will allow zonal injection regulation and monitoring consistent with the Schrader Bluff depletion plan. This work over is currently scheduled for Nabors ges in August of 2007 following S-125. Estimated Pre-Rig Start: 07/25/07 Estimated Rig-on Date: 08/16/07 Mark Staudinger GPB Rotary Drilling Engineer Office: (907) 564-4337 Cell: (907) 440-7403 S-215i Application for Sundry . . S-215i RWO Operations Summary Pre-Rig Work: 1. PPPOT on T and IC to 5000 psi on FMC Gen-5 Wellhead. 2. RU Slickline, drift 4-1/2" tubing, and set Tubing Tail Plug in XN nipple. Bleed OA, lA, and T to zero. 3. Open 4-1/2" Baker CMO Sliding Sleeve. 4. Circulate through sliding sleeve to flush IA with KW brine, then freeze protect to -2500' TVO. 5. Perform CMIT on TxlA to 4000 psi. PT OA to 2000 psi. 6. Install BPV in tubing hanger and test. Ensure IA and T are protected w/two barriers. 7. Prepare pad and neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. 2. Pull the BPV. Circulate out the diesel freeze protect and displace with KW brine. Monitor the IA and tubing pressure to confirm the well is dead. Note: Baker CMD sliding sleeve is open. 3. Set and test the TWC from below to 1000 psi for 30 minutes. NO tree. NU BOPE and pressure test to 4000 psi / 2500 annular. Pull the TWC. 4. RU E-line and Chem-cut the 7" x 4-1/2" Baker Premier Packer. Do not use String-Shot. 5. Pull 4-1/2" tubing. 6. PU 4" OP and perform cleanout/scraper run to TO. Lay down OP. 7. RU e-line and run USIT from TO to surface. 8. Run the 3-W', 9.2#, L-80, TCII completion with a 7" x 3-112" multi ported-packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Before landing tubing, log onto depth using RA marker in tubing and SLB e-line GR/CCL. 9. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to .4,000 psi eacht'\,Shear the. O. C~ shear v¡~ve. and pump both ways to confirm circulation ability. \([."'>\~ ~\..cJ \.cJ ~E: <:.."C).,.~~ ~£~ c. {ý; 10. Install and test FMC TWC. Nipple down the BOPE. Nipple up & test the tree to 5,000 psi. Pull TWC. 11. Freeze protect the well to -2,500' TVO by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ a hot oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 12. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-112" annulus valve and secure the well. Assure that IAlOA are protected with two barriers. 13. Rig down and move off. Post-Rig Work: 1. R/U Slick-line and pull ball and rod / RHC from the tailpipe. 2. Replace the OCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install well house and flow lines. ~\..\<t,~ \\\~ ,\f'... S(:.~"'~ ~ ·\4~\\'i. <;~~\Q. \ Û wANt~~~ k\.\~~-..j~ b~ ~c...~~\J\.~&, fn ~ ?-yv¡ ç /r¡. S-215i Application for Sundry TREE '= CWV 4-1/16" 5M WB..U-EAD = FMC G8\I 5 ACTUATOR = KB. ElEV = BF. ElBl - KOP= Max Angle- Dalum MD- Dalum 1ìI D- 5-215 72 41 2238 50 @ 3723' 6256 5000' SS 9-518" CSG, 40#, L-80, 10 = 8.835" Minimum ID = 3.725" @ 5648" 4-1/2" HES XN NIPPLE I 4-1/2" TBG, 12.75#, 13-CR-80, .0153 bpf, 10 = 3.958" ()6. TE 08/16102 03114/03 03131/03 04/08/03 04/28/03 05'06103 PERFORA TlON SUMMA.RY RB= LOG: SÆRRY MWO ON 08/06102 ANGLEA TTOPPERF: 45° @ 6098' Note: Refer 10 A'oduction æ for historical erf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 2 6098 - 6110 0 05/06/03 2-7/8" 2 6120 - 6130 0 05/06/03 2-7/8" 2 6150 - 6170 0 05/06/03 2-7/8" 2 6240 - 6260 0 05/06/03 2-7/8" 2 6265 - 6280 0 05/06/03 2-7/8" 2 6302 - 6342 0 05/06/03 2-7/8" 2 6335 - 6380 0 05/06/03 2-7/8" 2 6430 - 6450 0 05/06/03 2-7/8" 6 6505 - 6525 0 03/31/03 2-7/8" 2 6525 - 6545 0 05/06/03 2-7/8" 2 6585 - 6595 0 05/06/03 6834' 7" CSG, 26#, L-80, 10 = 6.276" REV BY COMIvENTS OA V iKK ORIGINAL COMR..ETlON JJITLH CORRECTION CAOIìLH ADPERF CRSfTP 1ìI0/MJ CORRECTIONS RLIlP NOTEAOOEDTOSSLV-5535' BJMA<K ADPERFS SAFETY NOTES: 4-1 fl." CHROME TBG. I I 5535' 5599' 5626' 5660' 5651' 5741' 6204' DATE REV BY COMIvENTS 10/04/03 ()6.aTLP Ð<T8\lCEO PAO<ING ON [)lAY 20" X 34" 215.5 b/ft, A53 ERW INSULATBJ I TAM FDRTCOLLAR 4-1/2" HES X NIP, 10- 3.813" 4-112" BKR CMO SLlOII\G SL V, W/4-1/2" X NIP, 10= 3.813" NOTE: SHIFT SLEBlE DOWN TO OPEN, SHIFT LP TO CLOSE - 04/28/03 7" X 4-1/2" BKR PRM PKR, ID - 3.875" 4-1/2" HES X NIP, ID - 3.813" 4-1/2" HES XN NP, 10 = 3.725" 4-1/2" WLEG, 10 - 3.958" ELMJ TT LOGG BJ 03/31/03 7" MARKER JOINT 7" MARKER JOINT POLA RlS UNIT WELL: S-215 PffirvIT N:J: 2021540 API f\b: 50-029-23107-00 SEC35, T12N, R12E, 3276' t£L & 4563'WB.. BP Exploration (Alaska) FIIfC GEN 5 .S-215i RWO WYNOTES: GLM's @ STA#1-#7 ARE 3-1/2" X 1- M G-W WHICH ARE WA TERFLOOD MANDRELS. 6256' 5000' SS CONOUCTOR H -i 114' 0.8' H4-1/2"X3-112"XO, 10=2.992" I 2500' H3-112" HES X NIP, 10 = 2.813" I GAS LIFT I\N\NDR8.S ~11YÆ~1 ~WM3~ WATER INJECTION I\N\NDR8.S lVO DEV 1YÆ VLV LATa-f FORT MWG-W DUM RK 1.5" MWG-W DUM RK 1.5" MWG-W DUM RK 1.5" MWG-W DUM RK 1.5" MWG-W DUM RK 1.5" MWG-W DUM RK 1.5" MWG-W DUM RK 1.5" MWG-W DUM RK 1.5" DATE 4-112" TOO, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 19-5/8" CSG, 40#, L-80, to = 8.835" 17" MARKER JOINT W/RA TAG - TOP Ma 0.8' 13-1/2" HES X NIP, ID =2.813" 1 17" X 3-112" HES AHR PKR, 10 = 2.921" ST MD 8 6165 7 6218 6 6268 5 6303 4 6331 3 6380 2 6449 1 6499 DATE Minimum ID = 2.75" @ 6616' 3-1/2" HES XN NIPPLE 6185' -13-1/2" HES X NIP, 10= 2.813" -i 7" X 3-112" HES AHR PKR, 10 = 2.921" I 17" MARKER JOINT W/RA TAG - TOP OA -i A-iOENIX PRESSfTEMP SENSOR SUB, 10 = 2.992" I 6287' H 7" X 3-112" HES AHR PKR, 10 = 2.921" I ÆRFORA TlON SUM\i1ARY REF LOG: SÆRRY IVWD ON 08106102 ANGLE AT TOP ÆRF: 45° @ 6008' I\bte: Refer to Production DB for historical perf data SIZE SPF INTEfN AL OpnlSqz DA TE 2-718" 2 N:J: 6098-6110 0 05106103 2-718" 2 N:J: 6120-6130 0 05106103 2-718" 2 Nc: 6150-6170 0 05106103 2-718" 2 OA: 6240-6260 0 05106103 2-7/8" 2 OA: 6265-6280 0 05106103 2-7/8" 2 OBa: 6302-6342 0 05106103 2-715' 2 OBb: 6355-6380 0 05106103 2-7/8" 2 OBc: 6430-6450 0 05106103 2-718" 2 OBd: 6505-6525 0 03/31103 2-718" 2 OBd: 6525-6545 0 05106103 2-718" 2 OBe: 6585-6596 0 05106103 6296' -13-1/2" HES X NIP, 10= 2813" 6302' -i3-1/2" MARKER JOINTW/RA TAG - TOPOba -i7" X 3-1/2" HES AHR PKR, 10 = 2.921" I -i A-iOENIX PRESSfTEMP SENSOR SUB, 10 = 2.992" I -13-1/2" HES X NP, 10= 2.813" 6473' -i 7" X 3-1/2" HES AHR PKR, 10 = 2.921"1 6487' -13-112" HES X NP,ID= 2.813" -13-112" HES X NIP, 10 = 2.813" 6539' -13-1/2" HES XN NIP, 10= 2.75" 13-1/2" TBG, 9.2#, L-BO, TC-II, 0.00B7 bpf, 10 = 2.992" H 6551' 6550' -l3-1/2" WLEG, ID = 3.00" I PBTD H 6834' 17" CSG, 26#, L-BO, BTC-M, 10 = 6.276" DATE OS/23107 REV BY MIS COIlfMENTS S-215i RlNO Prop. Compo DATE REV BY COIlfMENTS FOLARIS UNIT WELL: S-215i PERMT I\b: APlI\b: SEC 35, T12N, R12E, 3276' NSL & 4563' WEL BP Exploration (Alaska) . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13,2006 RE: MWD Formation Evaluation Logs: S-106_PB1, S-112, S-205, C-OIA, 2T-218, P2-57A. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 S-106 _PBl: :dO' - 0/ d. tt ¡L.j39a Digital Log Images: 50-029-22999-00, 70 1 CD Rom S-112: u:¡:~ QOd-l3S- f:Þ J'-/~/ Digital Log Images: 50-029-23099-00 5 ¿J/Sí' 4fo~ledwroV\~- 8 205~ U~~Od- IS-~ d: /t.../3 '9-;) Digital Log Images: 50-029-23107 -00 1 CD Rom 1 CD Rom C-OIA: 963 -0/ 0 -it" ILl3ft> SCANNED JAN 302007 Digital Log Images: 50-029-20121-01 1 CD Rom 2T-218: 963 -Olf 1:t-¡'-/3-:J.1 Digital Log Images: 50-029-20449-00 I CD Rom P2-57A: ;)();;f -dlL.{ 'it ¡L./3(A Digital Log Images: 50-029-22183-01 1 CD Rom e e WELL LOG TRAN8MITT AL (JIC 009 -164- To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17,2006 I ?xø--lD RE: MWD Formation Evaluation Logs S-215, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 8-215: LAS Data & Digital Log hnages: 50-029-23107 -00 1 CD Rom c ~ 92Ô-(Ö0 . . "'....... "',..'..,..',.....',",. ..~,:,,,. '~ >r. .'\ ' ,"", .. MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Matker.doc Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well S-215 r:;JOa., / ~ 4- V-114A V-114A V-114A RECEIVED JAN 0 9 2006 ~ C;ft & Gas Coos. Cœvnissln ~ Job # Log Description 11084269 INJECTION PROFILE 40009730 OH LDWG EDIT OF MWD/LWD 40009730 MD VISION SERVICE 40009730 TVD VISION SERVICE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ~1!:l1~~Ít\'íClI¡ E ß rVI '~ 1 2nO-in 0'Jo-¡;n¡C\'i~~ .Jnl Ui do v.... 07/04105 12/15/03 12/15/03 12/15/03 01/06/06 NO. 3656 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 d. 0 'J..- I 9t Field: Polaris Borealis Date BL Color CD ..~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage. AK 99503-2838 :::E~~ ) '- l (J ~~ò~r DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2021540 Well Name/No. PRUDHOE SAY UN POL 5-215 Operator SP EXPLORATION (ALASKA) INC 5523 ~. Completion Date 3/31/2003 v ---", MD 6930 ~ TVD Completion Status 1WINJ REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT Well Log Information: Logl Data Digital ~_~ed/Frmt F- 0/, ~ ~ .......... i~Pt 251 i I~ ¿ C Lis Electr Dataset Number Log Log Scale Media Run No 1 Name Directional Survey Directional Survey ~9 't:r.:;VorifiGaliun ] I' . y{. ¿vl'/l4 eN P ) h. ~ I· rtc.."i' U t / .I Directional Survey Directional Survey Directional Survey Directional Survey LIS Verification Cement Evaluation 5 Blu Production 125 Blu 4S§44 Induction/Resistivity i ').l)-é.{i.{ Well Cores/Samples Information: Name Interval Start Stop Received Sent Current Status 1WINJ Sf ¿~ t' ~ ¿'"O-ù}-' API No. 50-02~~'1 07-00-00 ~ Directional surv~ (data taken from Logs Portion of Master Well Data Maint) A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/24/2002. 5870 Case 5/30/2003 Production -Oilphase Sample, Gradio, Pressure, Temperature 6890 Open 7/9/2004 DRHO RHOB NPHI NCNT GR Includes Graphics Interval OHI Start Stop CH 0 434 Open 434 6930 Open 532 6930 Open 434 6930 Open 434 6930 Open 434 6930 Open 0 434 Open 532 6930 Open 5400 6406 Case Received 9/10/2002 9/10/2002 4/29/2003 9/10/2002 9/10/2002 9/10/2002 9/10/2002 4/29/2003 12/20/2002 o 2890 Sample Set Number Comments . '-..-p Comments GYRO MWD MWD GYRO ---- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2021540 Well Name/No. PRUDHOE BAY UN POL 5-215 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23107-00-00 MD 6930 TVD 5523 Completion Date 3/31/2003 Completion Status 1WINJ Current Status 1WINJ UIC Y ADDITIONAL INFOR~N Well Cored? Y~ Chips Received? ~ Daily History Received? ~N ~ Formation Tops Analysis Received? ~ Comments: ,-",' Compliance Reviewed By: .~ Date: 7, 4-¡~~) "'-' ) ) A "'2' ,-,~,/.. C' ~ C., /s1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Consetvation Comm. Attn.: Robin Deason 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 06, 2003 RE: MWD Formation Evaluation Logs: S-215, AK-MW-22131 8..215: Digital Log Images: 1 CD Rom _.~L ;. . ,/", // ~ ) {- Ul,''/': L-..J / ,/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun 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: 1ft/od I . Signed: /1 ûJiJ Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Well Job# S-215 ~r'.N."" ~ L...\ W-212 ~(')ê) -C)l r{ " Log Description PRODUCTION LOG PRODUCTION LOG 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: r"""EC·· t:i\JEn ~. . ..,1 1\;J LP ~ ":.' . _:1- !i'.1 -? ~ ('"1./·1;'\...;)· ~'I~~ 'f "" ¡ i L·\ ¡i '.' ¡'I.M v 'v ,"" '" Þ~ìa8K~ \jr; 0. {~ti~ :........)~~~. -".,...~{¡¡iijf:X!:~i{ ¡\nctior~~ Date 04/23/03 04/24/03 5/15/2003 NO. 2787 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Borealis BL Color CD --. 1 1 ~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received ~ \~ )"~ \) ~'- ~j''l^, ) ) MEMORANDUM State of Alaska {}2t3j;sflaska Oil and Gas Conservation Commission TO: Randy Reudrich ~ DATE: May 15, 2003 commiSSioner." ;\ /1 þ\W () ~ "J\/) SUBJECT: Mechanical Integrity Tests THRU: Jim Regg \~~\" BPXA P.I. Supervisor OS-14, S,M,O Pads 14-17A, 14-21, S-215, M-29A, D-24 FROM: Jeff Jones PBU Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. Well 14-17 A Type Inj. G TV.D. 8519 Tubing 2560 2575 2575 2575 Interva 4 P.T.D. 2030010 Type test P T est psi 2130 Casing 270 3500 3440 3420 P/F P Notes: Test fluid 6.9 bbls 60/40 me~1 Well 14-21 Type Inj. S TV.D. 8643 Tubing 360 3040 3020 3010 Interva 2N ú!3fJ/" P.T.D. 1820860 Type test P T est psi 1500 Casing 400 3040 3010 3000 P/F P Notes: Test fluid 17 bbls 60/40 methanol. 2 year CMIT TxlA : TBG leak @ 5566 MD; TTP set @ 11762 MO Well 8-215 Type Inj. S TV.D. 4,624' Tubing 1010 1020 1020 1020 Interva I v/ P.T.D. 2021540 Type test P T est psi 1500 Casing 880 2040 1900 1840 P/F P Notes: Test fluid 1 bb160/40 methanol Well M-29A Type Inj. 8 TV.D. 7731 Tubing 940 949 940 940 Interva 4 P.T.D. 2000990 Type test P T est psi 3500 Casing 560 3520 3500 3500 P/F P Notes: Test fluid 3.2 bbls 60/40 methanol Well 0-24 Type Inj. N TV.D. 8041 Tubing 325 325 325 325 Interva 0 <S~ P.T.D. 1852990 Type test P T est psi 2010 Casing 60 2240 2150 2125 P/F P Notes: Test fluid 4.6 bbls 60/40 methanol. (MITIA post-patch set on a category B-3 well) Well 0-24 Type Inj. N TV.D. 8041 IA 2125 2230 2230 2230 Interva 0 P.T.D. 1852990 Type test P T est psi 3000 OA 85 3000 2880 2840 P/F P :5&f?/ Notes: Test fluid 2.3 bbls 60/40 methanol (MITOA on a catagory B-3 well) Type INJ. Fluid Codes F = FRESH WAT~R INJ. G = GAS INJ. S = SALT WATER 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 Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test 0= ~ther (describe in notes) May 15, 2003: I traveled to BPXA's Prudhoe Bay Field wells 14-17A, 14-21, S-215, M-29A and D-24 to witness Mechanical Integrity Tests. Jeff Rea was the BPXA representative for the tests today. The pretest pressures on each well were monitored and fmUld to be stable and the standard annulus pressure tests were then performed with each well passing the MIT. Well 14-21 has a known tubing leak at 5566' NID and a tubing tail plug was set at 11762' NID to accomplish a successful 2 year interval combination Tx IA MIT for Sundry #399-248. Well D-24 is a BPXA designated catagory B-3 well and both the IA and the OA passed the MIT. Five well houses were inspected with no exceptions noted. Summary: I witnessed successful MIT's on BPXA's Prudhoe Bay Field wells 14-17A, 14-21, S-215, M-29A and D-24. Five well house inspections conducted. / M.I.T.'s performed: .§ Number of Failures: º Attachments: well bore schematics (5) Total Time during 1ests: 7.5 hrs ~ MIT report form 5/12/00 L. G. MIT PBU 14-17A,14-21,S-215,M-29A,D-24 5-14-03 JJ.xls 5/20/2003 ') "TREE = GRA Y GEN 3 WELL HEA 0 = CALICO F AtWATOR;'" .... AXEi..Sb"N "kE3:"ËlBl;'" 71 ' ï3F~äËV; "Rap=···· ....... ·2900; fv'ax Angle ='96@ 11658' "b3tüm rVö = . . Ù)562' Datum lV 0 = 8800' SS ) 14-17 A SAFEfY NOTES: H2S W B..L 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2500' ~ Minimum ID = 2.372" @ 10713' XO TO 2-7/8" STL LINER 5-1/2"TBG-IPC, 17#, L-80, 0.0232 bpf,lD =4.892" 1-1 10149' ITOPOF 4-1/2" TBG-IFC 1-1 10149' I ~ 7 1 TOP OF 7" LNR 1-1 10202' t--- I I 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1--1 10243' 3-112" mG, #, L-80, .0000 bpf,lD =2.992" 1-1 10492' I 9-5/8" CSG, 47#, L-80, D = 8.681" 1--1 1 0492' ~ 1 TOP OF WHIPSTOCK 1'1 10588' 1 ITOPOFWINDOW H 10589' 1 ÆRFORA 1l0N SLXv1MARY REF LOG: 14-17 A SÆRRY MWD ON 01/17/03 ANGLE AT TOP PERF: 93 @ 11900' Note: Refer to Production 00 for historical perf data SIZE SFT INTffiVAL Opn/Sqz DAlE 2" 4 11897 - 12447 Opn 01/18/03 2" 4 12497 - 12547 Opn 01/18/03 ITOPOF 4-1/2" mG-IPc 1--1 10838' ITOPOF BRDGEPLUG 1-1 10848' 4-1/2"TBG-IFC, 12.6#, -1 10849' N-80, 0.0152 bpf, ID = 3.958" 1 FEID 1-1 11358' [!Ð-i 11400' 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 1-1 11400' OA TE REV BY COMrvENTS DATE REV BY OS/23/82 ORIGINAL COMR..ETION 01/18/03 lMrvYTP CID I-DRlZONTAL SIDErRACK 02/24/03 TH/KA K PffiF CORRECllONS 2226' 1-1 5-1/2" CA M BA L-O SSSV NIP, 10 = 4.562" I . ~ i 1 10126' 1-1 5-1/2" BA KER LOC SEA LA SSY I ¡I ~ 10129' 1-1 9-5/8" X 5-1/2" BKR ÆRM A<R 1 10149' 1-1 5-1/2" X 4-1/2" XO 1 , 10185' 1-13-1/2" DER..OYMI3\IT SLEEVE, ID = 3.00" 1 10204' 1-13-112" I-DWCO NO-GO XN NIP, D =2.750" 1 I I 10231' 1-1 4-1/2" OTIS XN NIP, ID = 3.725" I ~ 10242' H 4-1/2" BKRSHEAROUT SU3 WLEG \ 1 10243' 1-1 4-1/2" TUBING TAIL 1 ~ 10234' 1-1 8..MD TT LOGGED 05/16/91 10350' I-1TOPOFCEMENT 1 1 10559' 1-13-112" X 3-3/16" XO, D =2.800" 1 I 10713' 1-f3-3/16"X2-7/8"XO,ID=2.441" 1 1 12549' I~ 3-3/16" LNR, 6.2#, L-80,-1 10713' 1 .0000 bpf, ID = 2.80" I 12585' H2-7/8"LNR,6.16#,L-80,.0000bPf,D=2.441" I 10849' 1-1 4-1/2" TU3ING TAIL I - (X) M\1I3\1TS PRUDHOE SA Y UNrr W8..L: 14-17A ÆRMT No: 1810210 API No: 50-029-20562-01 SEC 9 T1 ON R14E4282.68' ÆL & 1682.64' FNL 8P Exploration (Alaska) ) TREE = GRA Y GEN 2 WELLHEAD = GRAY ACTUA TOR = AXELSON KB. B..EV '= 71; ·BF. B..Bt = . ,... kop~ 2800' "Máx Xi,gh;;"'w "'56' @f 9 (fóO"ï "6ã1ürñ 'Mr; '.,""_'M.M "1'fo27'" "Datum TV ^iY;; ... . ···8800·... ss' 14-21 CI·:1¥>«"" ~:¡,¢::::$:,.,.::: .r.:. ~ I 13-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2517' 1 'í~ Letvt..@. .5 '5W ;-t:> Minimum ID = 3.750" @ 11796' 4-1/2" CAMCO DB NIPPLE ø.> L ) SAFETY NOTES: WAlVmEDWB..L. *"'*T x IA COMM UNICATIONAT 5566' (02107/03 WAIVm)"'** FLOWLINE FROZEN, CORROSION DAMAGE, TWINNBJ WITH 1~17. 2156' H 5-1/2" CAM BAL-O SSSV NIP,ID =4.562" GAS LIFT MA.NDRB..S DEV TYÆ VLV LATa; PORT 26 MM-I RK 52 MM-I RK 52 MM-I RK 54 MM-I RK 49 MM-I RK 47 MM-I RKP ~ ST Iv[) lVD 1 3552 3513 2 5746 5011 3 7869 6302 4 9928 7530 5 11375 8418 6 11523 8517 DATE ~qc:'4; 'TV» ~ &----1 11707' I..., 9-5/8" X 5-1/2" BKR FB-1 PKR \) II 1111772095" I~ S-1/2"BAKERSBEASSY I 5-1/2"X ~1/2" XO I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf,lD =4.892" l-i 11725' I TOP OF 4-1/2" TBG-PC H 11725' I TOP OF r' LNR l-i 11762' -. PERF ORA TION SUMMA. RY REF LOG: BHCS ON 08/07/82 ANGLEATTOP PERF: 42 @ 12091' f\bte: Refer to A"oduction DB for historical perf data SIZE I SA= I INTERVAL I Opn/Sqz I DATE I - SEE PAGE 2 FOR PERFORATION DATA I 11796' l-i 4-1/2" CA tv'CO DB NIP ID = 3.75" 1 I 9-5/8" CSG, 47#, L-80, ID = 8.681" H 12036' t-4 .. 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" H 11804' 11804' H 4-1/2" TT W/ BA KER WLEG I 11781' H ELM) TT LOGGED 02105188 I I TOP OF 4-1/Z' TBG H 12395' 14-1/2" lBG-PC, 12.6#, L-80, .0152 bpf,lD =3.958" 1-1 11805' 12395' I..., 7" X 4-1/2" BKR FB-11S0 PKR I 12435' l-i 4-1/2" MAGNA PLUG I 12441 ' r- 4-1/2" CAtv'CO DB NP ID = 3.687" 4-1/2" 1BG,12.6#, L-80, .0152 bpf, D =3.958" H W/BLANKING PLU3 12451 ' 12449' H 4-1/2" TT W/SAKER WLEG I ~ 13018' 13050' H CA-RKED W/O PRONG 1 I 7" LNR, 29#, L-BO, .0371 bpf, ID = 6.184" H 13060' W 13055' H 22' PERF GUN & ŒL 3-1/8" 1 DATE REV BY COMVIENTS DATE REV BY COMM:NTS ffiLDHOE SA Y UNIT 08/13/82 ORIGINAL COrvPLETION WB..L: 14-21 01/25/88 LAST WORKOVER PERrv11T No: 1820860 02/22/01 SIS-LG REVISION API No: 50-029-20756-00 01/08/02 RN'TP CORRECTIONS SEC 9, TION, R14E 1364.03 Fa.. 4846.25 Ff\1. 02/20/03 /lLH WAr.¡ ER SAFETY NOTE BP Exploration (Alaska) ') ) TRŒ = em 4--1/16" 5M WB.LI-EAD = FMC GEN 5 Ä ctÜAfÒrf;' ki3. ËlEV;;;" ...... .... ............ .... .. 72' s'¡:::"E['B/"';' ....., ,···,',·.................·....···'41ï köÞ..;;;;..·· '223'8; 'Max Anglè = 5ë5"@ 3723' 'batum MO;" . 6256' .. ......... ... .- ..-. Datum TVD = 5000' SS 5-215 SAFETY NOTES: 4-112" CHROMETBG. ..4 I ~-t 114' H 20" X 34" 215.5 bItt, A53 ffiW INSULATBJ I =--I 976' 1--1 TAM R:>RTCOLLAR 1 1 2224' H 4-1/2" HES X NIP,ID = 3.813" 1 ~ GAS LIFT MANDRELS ST MD TVD DEV TV Æ VL V LA Ta-I PORr ()ð.TE 1 3476 3203 50 KBG-2 RP BK 08/16/02 19-5/8"CSG, 40#, L-80, ID=8.835" 1-1 2946' ~ L Minimum ID = 3.725" @ 5648" 4·1/2" H ES XN NIPPLE 4-1/2"TBG, 12.75#, 13-CR-80,.0153 bpf, ID =3.958" l-i J 1 1 5535' 1- 4-1/2" BKRCMDSLlDINGSLV, WI 4-1/2" X NIP, ID = 3.813" NOTE: SHIFT SLEBI E DOWN TO OPS\I, SHIFT LP TO CLOSE - 04/28/03 :8 5599' H7" X 4-1/2" BKRPRMPKR,ID = 3.875" 1 5626' 1-1 4-1/2" HESXNIP, ID= 3.813" I 5648' 1-1 4-1/2" HES XN NP, ID = 3.725" 1 5660' H 4-1/2" WLEG, ID = 3.958" I 5651' l-i EUvOTT LOGGBJ 03/31/03 , l{.L Z L Tv'þ > 8 5659' ÆRFORA llON SLMMA. RY RS= LOG: SÆRRY MND ON 08106102 ANGLE AT TOP PERF: 45° @ 6098' Note: Refer to Production œ for historicalyerf data .SIZE SA= INTffiVAL Opn/Sqz DATE 2-7/8" 2 6098 - 6110 0 05106103 2-7/8" 2 6120 - 6130 0 05/06103 2-7/8" 2 6150 - 6170 0 05/06103 2-7/8" 2 6240 - 6260 0 05/06103 2-718" 2 6265 - 6280 0 05/06103 2-7/8" 2 6302 - 6342 0 05/06103 2-7/8" 2 6335 - 6380 0 05/06103 2-7/8" 2 6430 - 6450 0 05/06103 2-7/8" 6' . 6505 - 6525 0 03/31/03 2-7/8" 2 6525 - 6545 0 05/06103 2-7/8" 2 6585 - 6595 0 05/06103 , 5741' 1--1 7" MARKffi JOINT 1 r 6204' l-i 7" MARKffi JOINT I I I PBW 1-1 6834' ~ 7" CSG, 26#, L-80, ID = 6.276" l-i 6915' )6. 1£ 08116102 03114/03 03131/03 04/08/03 04/28/03 05106103 REV BY COMfvENTS DAV IKK ORIGINAL COMR.ETlON JJ/TLH CORRECllON CAOITLH ACPERF DRSffP TVD/fvÐ OORRECTIONS ~1lP NOTEAOOEDTOSSLV-5535' BJMIKK ACPERFS DATE REV BY 00 MfvENTS PŒ..A RlS UNIT WELL: S-215 PffiMT N:J: 2021540 API N:J: 50-029-23107-00 SEC35, T12N, R12E, 3276' NSL & 4563'WB. 8P Exploration (Alaska) ) '~ 7-1/16" aw McEVOY OTIS . ..... 51:L11; .... .... 2â~nï .............. 3ÙW .. 'fóà@ 9'91"7' 1 Ö581i ... 'S8ÖÖï'SS TREE = WB..U"EAO= A CTUA TOR = RB.ËLi?j"·;· BF.ËCËV = R6Þ; rvïaxÄ ng Ie = öäitÙn rVib;' OatU'mTV b =' 113-3/8" CSG, 72#, L-80-BTRS, 10 = 12.347' 1-1 2693' ~ Minimum ID = 2.37" @ 8648' TOP OF 2-7/8" LINER IT' TBG, 26#, L-80-NSCC, .0382 bpf, 10 = 6.276" 1-1 ITOPOF 5-1/2" TBG l-l 8498' 8498' lTOP OF 2-718" LNR 1-1 8648' I 15-1/2"TBG, 17#, L-80-BTRS, .0232 bpf, 10= 4.892" 1-1 I TOP OF 7" LNR 1-1 8720' 8720' M-29A \ I I I :8: . 2š . . . l( III ~~ 19-5/8" CSG, 47#, L-80-BTRS, 10 = 8.681" 1-1 9522' µ ITOP OF 7' BAKER WI-UPSTOO< 1-1 9530' I l2-718" LNR, 6.16#, L-80, .0058 bpf, 10 = 2.44" 1-1 10696' I ~ 10256' IT' LNR, 29#, L-80, .0371 bpf, 10= 6.184" H 10270' ÆRFOAA TION SUI'vMARY REF LOG: SÆRRY MWO/GR ON 07/16/00 ANGLEA TTOP ÆRF: 89° @ 10145' Note: Refer to Production DB for historical perf data SIZE SFf NTERVAL Opn/Sqz D6.1E 2 6 10145- 10170 0 04118/03 2 6 10245 - 10270 0 04/18/03 2 6 10350 - 10375 0 04/18/03 2-718" 10696-10761 SLTO 07/21/00 DATE REV BY COMM:NTS 02/04189 INITIAL OOrvPL AS NJECTOR 07/18100 Jav1 cm SIOErRACK 01/15/01 SIS-MO INITIAL REDAA W 03/08102 RNfTP CORRECTIONS 04/18103 DDNfTLH ADD PERF & CIBP 2-7/8" SLTD LNR, 6.16#, -1 L-80, .0058 bpf, 10 = 2.44" ) SAFETY NOTES: SL TD LNR 1 0696' -10761' - 70° @ 9744' & 900@ 9847' 2098' 1-17" OllS SSSV LANDING NP, 10 = 5.962" I ~ 8498' 1-i7" X 5-112" XO 1 8509' 1-15-1/2" OllS XA SLIDING SLV, 10 = 4.562" I 8573' 1-19-5/8" X 5-112" llW HBBP A<R 1 8631' 1-15-1/2" OllS X NP, 10 = 4.562" I 1-1 DER...OY fvENT SLB I 1-15-1/2" OllS XN NIP, 10 =4.455" I 8648' 8675' 8725' I-IT'TIW SEAL ASSY W/O SEALS 1 7" MlLLOur WINDOW 9533'- 9540' 10640' 1-1 HES aBP (04118103) I TOP OF 2-7/8" SL TO LNR 1-1 10696' I ... ... , , , , , I 10761' I TOPOF2-7/8"LNRI-I 10761' I FISH - (3) 1-1/16" ROLLERS IN WB..L LOCA 1l0N UNKNOWN 12-7/8" LNR, 6.16#, L80-STL, .0058 bpf, D = 2.37" 1-1 10773' I DATE REV BY co rvrv1ENTS PRUDHOE SAY UNIf WELL: M-29A ÆRMI No: 2000990 API N:>: 50-029-21904-01 SEC 1 T11 N, R12E BP Exploration (Alaska) ) TREE = 6" I\ICEVOY WI3..LHEAO= I\ICEVOY 'ActUAtOR;; . .,,,. ··01'IS 'kEfä~EV;;" 71.67' 'BF~ËLË\.Ï;"'· 44.3:2' 'Rbp;';; .m. . .. ... ·····1656' ,.~.~..~~.Q..~ = 50 .~.. ~~g~'. Datum MD = 10720' DatumTVDss= 8800' 113-3/8" CSG, 72#, L80, ID = 12.347" H 2798' ~ 1 5-1/2" EQIPSE PKR, ID = 2.970" (05/11/03) 1-17545. 7605 1 (~ .p~(¡k:k) Minimum ID = 2.970" @ 7545' 5-112" EC LIPS E PAC KER 15-1/2" TBG, 17#, L-80, .0232 bpf, ID =4.892" 1-1 9920' TOP OF 7" LNR l-i 10047' I 19-5/8" CSG, 47#, L-80, ID =8.681" 1-1 10302' 1-----41 ÆRFORA llON SUMMARY REF LOG: SWS-BHCS ON 12/26/85 ANGLE AT TOPPffiF: 19@ 10833' Note: Refer to Production œ for historical perf data SIZE SPF INTffiV AL Opn/Sqz DA TE 4" 4 10833 - 10843 S 01/01/90 4" 4 10856- 10873 S 01/01/90 4" 4 10878 - 10891 S 01/01/90 3-3/8" 4 10840 - 10842 0 03/07/92 3-3/8" 4 10856-10873 0 01/04/91 3-3/8" 4 10878 - 10891 0 01/04/91 3-3/8" 4 10894 - 10900 0 01/04/91 PBTD l-i 11057' 17" LNR 29#, L-80, .0371 bpf, ID= 6.184" 1-1 11098' DATE REV BY OOrvMß\lTS DA.TE REV BY 12130/85 ORlGINA.L COMA..EllON 05/19/01 RN/lP CORRECllONS 05/06103 BJMIKK SEf 5-1/2" EQIPSEPKR 05/11/03 BJ MIK K SEf 5-112" EQIPSEPKR D-24 L ~ ~ I I ~1¡i!1 I :8:,. ~ I :8: ~ I[ I ... COMrv£NTS ) SAFElY NOTES 2086' l-i 5-1/2" OTIS SSSV LAND NIP, ID = 4.562" I ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE SIZE LATCH 6 3388 3119 40 OTIS-LBD 1-1/2" RA 5 5412 4619 44 OTIS-LBD 1-1/2" RA 4 7326 5940 41 OTIS-LBD 1-1/2" RA 3 8593 6943 33 OTIS-LBD 1-1/2" RA 2 9310 7554 30 OTIS-LBD 1-1/2" RA 1 9548 7761 29 OTIS-LBD 1-1/2" RA 9705' 1-15-1/2" OTIS XA SLIDING SLV, ID = 4.562" l-ilBG SEAL ASSY 1 1-i9-5/8" x 5-1/2" TIW PKR, ID = 4.75" I 9768' 9783' 9835' 1-i5-1/2" OTIS 'X' NIP, ID = 4.562" 1 9878' 1-i5-1/2" OTISXNNIP, ID= 4.455" 1 9920' 9962' 1-i5-1/2" OTIS TBG TAIL 1 l-i 8..MD-lT - DA TE NOT AVAILABLE 1 ~ I 10867' 1-1 MA RKffi JOINT I ffiLOHOE SA Y UNIT W8..L: 0-24 PERMIT No: 1852990 A PI No: 50-029-21506-00 SEC 23, T11 N, R13E BP Exploration (Alaska) ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well o Oil 0 Gas 0 Suspended 0 Abandoned a 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 3276' NSL, 4563' WEL, SEC. 35, T12N, R12E, UM At top of productive interval 1042' NSL, 705' WEL, SEC. 34, T12N, R12E, UM X = 617502, Y = 5977223 10. Well Number At total depth 546' NSL, 1067' WEL, SEC. 34, T12N, R12E, UM X = 617149, Y = 5976722 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Polaris Pool KBE = 71.49' ADL 028258 (Undefined) 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 8/8/2002 8/12/2002 3/31/2003 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6930 5523 FT 6834 5459 FT a Yes 0 No (Nipple) 2225' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, PWD, USIT Classification of Service Well Water Injection 7. Permit Number 202-154 8. API Number 50- 029-231 07-00 9. Unit or Lease Name X = 618885, Y = 5979479 Prudhoe Bay Unit S-215i 23. CASING SIZE 20" X 34" 9-5/8" 7" WT. PER FT. 215.5# 40# 26# GRADE A53 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 114' 48" 34' 2946' 12-1/4" 31' 6915' 8-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 545 sx AS Lite III, 219 sx Class 'G' 146 sx LiteCrete, 302 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25. 6098' - 6110' 6120' - 6130' 6150' - 6170' 4960' - 4968' 4976' - 4983' 4997' - 5011' 2-7/8" Gun Diameter, 2 spf MD TVD 6240' - 6260' 5060' - 5074' 6265' - 6280' 5078' - 5088' 6302' - 6322' 5103' - 5117' 6322' - 6342' 5117' - 5131' 6355' - 6380' 5139' - 5156' 6430' - 6450' 5190' - 5204' 6525' - 6545' 5254' - 5267' 6585' - 6595' 5294' - 5300' SIZE 4-1/2",12.6#, L-SOI 13CrSO TUBING RECORD DEPTH SET (MD) 5660' PACKER SET (MD) 5599' 2-7/8" Gun Diameter, 6 spf MD TVD 6505' - 6525' 5241' - 5254' 2-7/8" Gun Diameter. 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 75 Bbls of Diesel 27. Date First Production May 12, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL TEST PERIOD CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ~E C E IVE D No core samPle"!",, ~l R8DMs ~~l MAY 1 5 ?JIW! MA Y 1 4 2003 i::~:.j 0 R,'16' ,I. NA, :,' l', ' ··'~aet'.aœ&G8SG0i1s.Cornmiseion ~ '1.1 !. ," ..."C " ,_ t: An....ontf!e ~1'I"..1¡'~·.""J'~~. . ,.."."~,,....,.., vii 11I.4~ OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Form 10-407 Rev. 07-01-80 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. Ma Mb1 Mb2 Mc Na Nb Nc OA OBa OBb OBc OBd OBe OBf o BCBase 5756' 5833' 5897' 5991' 6073' 6097' 6148' 6238' 6302' 6355' 6428' 6500' 6587' 6649' 6711' 4726' 4778' 4821' 4885' 4942' 4959' 4995' 5059' 5103' 5139' 5189' 5237' 5295' 5336' 5377' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Summary, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble -1ð'lIJ\l' Q ~ ~ Title Technical Assistant Date 0 s- Ic~ -0'6 S-215i 202-154 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Michael Triolo, 564-5774 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: S-215i Common Name: S-215i Test Date 8/11/2002 Test Type LOT Test Depth (TMD) 3,021.0 (ft) BP.EXPLORATION Leak-Off Test Summary TestDepth(TVD) 2,860.0 (ft) AMW 9.20 (ppg) Surface Pressure LeakOffPréssure(BHP) 940 (psi) 2,307 (psi) EMW 15.53 (ppg) -- -' Printed: 8/19/2002 10:42:38 AM ) ) BP EXPLORATION Operations Summary Report Page 1·of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-215i S-215i DRILL +COMPLETE DOYON DOYON 14 Start: 8/7/2002 Rig Release: 8/15/2002 Rig Number: Spud Date: 8/8/2002 End: 8/15/2002 . Date From - To Hours Task Code NPT Phase Description of Operations 8/7/2002 07:00 - 13:00 6.00 MOB P PRE Held PJSM. Skidded Drill Floor. Moved off of S 112i. Moved in Rig and Spotted over S-215i. Shimmed Rig, Skidded Drill Floor into position and connected lines. Spotted Cuttings Tank. 13:00 - 14:30 1.50 DIVRTR P SURF Held PJSM. Measured RKB's. N / U Diverter and Diverter Line. Accepted Rig at 1300 hrs 8 / 7 / 2002. 14:30 - 16:30 2.00 MOB P SURF Loaded Pipe Shed w/ 5" DP. Took on Spud Mud and Water. 16:30 - 18:00 1.50 MOB P SURF M / U Lines Under Rig Floor. R /03-1/2" and 4" DP Handling Equipment. R / U 5" DP Handling Equipment. P / U Bails and Elevators. 18:00 - 18:30 0.50 MOB P SURF General Housekeeping. Cleaned and Cleared Rig Floor, Pipe Shed and Cellar. 18:30 - 19:00 0.50 DIVRTR P SURF Function Tested Diverter System, OK. Koomey Test, OK. Witnessing of Diverter Function Test waived by AOGCC Rep Jeff Jones. 19:00 - 23:00 4.00 DRILL P SURF Held PJSM. M / U and Stood back in Derrick 26 Stands of 5" Drill Pipe and 7 Stands of 5" HWDP. 23:00 - 00:00 1.00 DRILL P SURF Held PJSM. M / U BHA #1. 12-1/4" STC FGXiCPS Bit, Ser# MJ9435, dressed w/ 1 x12, 1 x14, 2x20 jets, 8" SperryDrill Lobe 6/7 4.0 stg Motor, Float Sub, Non-Mag Pony Collar, 12" Undergauge Sleeve Stabilizer, XO, Orienting Sub and Drilling Jars. Total BHA Length - 89.99'. 8/8/2002 00:00 - 00:30 0.50 DRILL P SURF Held PJSM. R / U HES Slickline f/ Gyro Runs. 00:30 - 07:00 6.50 DRILL P SURF Held PJSM. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 114' to 419'. WOB 5,000#, RPM 50, Motor RPM 83, Pump Rate 550 gpm, SPP Off Bottom 250 psi, On Bottom 450 psi. Took Gyro Surveys every 90'. 07:00 - 09:00 2.00 DRILL P SURF Circulated and Conditioned Mud to Maintain 300 Viscosity. 09:00 - 11 :30 2.50 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 419' to 598'. WOB 5,000# - 25,000#, RPM 60, Torque On Bottom 4,000 ft/lbs - Off Bottom 2,000 ft/lbs, Motor RPM 83, Pump Rate 555 gpm, SPP Off Bottom 400 psi, On Bottom 650 psi. Took Gyro Surveys every 90'. 11 :30 - 12:00 0.50 DRILL P SURF Circulated Bottoms Up to Clean the Hole. Pump Rate 550 gpm, SPP 400 psi. 12:00 - 13:00 1.00 DRILL P SURF Held PJSM. POOH from 598' to Surface. 13:00 - 15:00 2.00 DRILL P SURF Held PJSM. M / U BHA #2. 12-1/4" STC FGXiCPS Bit, Ser# MJ9435, dressed w/ 1x12, 1x14, 2x20 jets, 8" SperryDrill Lobe 6/7 4.0 stg Motor, Float Sub, Non-Mag Pony Collar, 12" Undergauge Sleeve Stabilizer, XO, Non-Mag Flex Collar, Hang Off Sub, Orienting Sub, 2-Non-Mag Flex Collars, Drilling Jars, 20 jts 5" HWDP. Total BHA Length - 770.55'. Pulse Tested MWD Tools w/ No Success. Changed out MWD Pulser, Pulse Tested MWD, OK. 15:00 - 15:30 0.50 DRILL P SURF RIH w/ 12-1/4" Directional BHA to 500'. 15:30 - 16:00 0.50 DRILL P SURF Washed to Bottom as a Precaution, from 500' to 598'. Pump Rate 550 gpm, SPP 1,000 psi. 16:00 - 00:00 8.00 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 598' to 1,330'. WOB 15,000# - 35,000#, RPM 60, Torque On Bottom 4,400 ft/lbs - Off Bottom 2,000 ft/lbs, Motor RPM 83, Pump Rate 555 gpm, SPP Off Bottom 1,450 psi, On Bottom 1,750 psi. 8/9/2002 00:00 - 08:00 8.00 DRILL P SURF Held PJSM. Drilled 12-1/4" Directional Hole by Rotating and Printed: 8/19/2002 10:42:50 AM ) ) Page 2 of 7 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-215i S-215i DRILL +COMPLETE DOYON DOYON 14 From - To Hours Task Code NPT Phase 8/9/2002 8.00 DRILL P SURF 00:00 - 08:00 08:00 - 08:30 0.50 DRILL P SURF 08:30 - 09:30 1.00 DRILL P SURF 09:30 - 10:00 0.50 DRILL P SURF 10:00 - 10:30 0.50 DRILL P SURF 10:30 - 19:30 9.00 DRILL P SURF 19:30 - 20:30 1.00 DRILL P SURF 20:30 - 22:00 1.50 DRILL P SURF 22:00 - 22:30 0.50 DRILL P SURF 22:30 - 00:00 1.50 DRILL P SURF 8/10/2002 00:00 - 01 :30 1.50 DRILL P SURF 01 :30 - 02:30 1.00 DRILL P SURF 02:30 - 04:00 1.50 CASE P SURF 04:00 - 04:30 0.50 CASE P SURF 04:30 - 06:30 2.00 CASE P SURF 06:30 - 07:00 0.50 CASE P SURF 07:00 - 08:30 1.50 CASE P SURF 08:30 - 09:00 0.50 CEMT P SURF 09:00 - 12:00 3.00 CEMT P SURF Start: 8/7/2002 Rig Release: 8/15/2002 Rig Number: Spud Date: 8/8/2002 End: 8/15/2002 Description of Operations Sliding from 1,330' to 2,110'. WOB 15,000# - 35,000#, RPM 60, Torque On Bottom 5,000 ftllbs - Off Bottom 4,000 ftllbs, Motor RPM 83, Pump Rate 545 gpm, SPP Off Bottom 1,750 psi, On Bottom 1,950 psi. AST=1.8 hrs, ART=3.9 hrs. Circulated Bottoms Up to Clean the Hole. Pump Rate 545 gpm, SPP 1,750 psi. Held PJSM. Made Wiper Trip from 2,110' to 512'. No Drag. RIH after Wiper Trip from 512' to 2,085'. No Fill. Washed down as a Precaution from 2,085' to 2,110'. Pump Rate 545 gpm, SPP 1,750 psi. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 2,110' to 3,001'. WOB 25,000# - 35,000#, RPM 60, Torque On Bottom 7,000 ftllbs - Off Bottom 4,000 ftllbs, Motor RPM 83, Pump Rate 650 gpm, SPP Off Bottom 1,800 psi, On Bottom 2,100 psi. AST=2.99 hrs, ART=1.96 hrs. Total KRevs=102.7 Circulated 2 x Bottoms Up, 720 bbls. Pump Rate 650 gpm, SPP 1,800 psi. Circulated until Returns over Shaker were Clean. Made Wiper Trip from 3,001' to 1,728'. 3,001 to 2,100' Average Drag 5,000#, Maximum Overpull 75,000#, 2,100' to 1,728' No Drag. Flow Checked Well, Static. RIH after Wiper Trip from 1,728' to 2,970'. No Fill. Washed down as a Precaution from 2,970' to 3,001'. Circulated 2 x Bottoms Up, 720 bbls. Pump Rate 650 gpm, SPP 1,800 psi. Circulated until Returns over Shaker were Clean. Held PJSM. POOH wI 5" DP from 3,001' to 770'. Broke Out and LID 12-1/4" Directional BHA. Held PJSM. R / U Equipment to Run 9-5/8" Casing. M 1 U Float Shoe Joint, 1 Jt of 9-5/8" Casing and Float Collar Joint. Filled Casing and Checked Float Equipment, OK. M I U and RIH wi 71 Jts 9-5/8", 40#, L-80, BTC Casing. Average M I U Torque 7,000 ft Ilbs. M I U 9-5/8" Casing Hanger and Landing Joint. Landed Casing. 9-5/8" Casing Set As Follows: Item Length Depth Float Shoe 1.75' 2,945.50' 2 Jts 9-5/8" 40# L-80 BTC Csg 83.20' 2,859.55' Float Collar 1.21' 2,858.34' 46 Jts 9-5/8" 40# L-80 BTC Csg 1,881.49' 976.85' TAM Port Collar 2.92' 973.93' 23 Jts 9-5/8" 40# L-80 BTC Csg 937.44' 38.30' 9-5/8" Casing Hanger 4.42' 33.88' M I U Circulating Head and Lines. Circulated to Condition Hole. Pump Rate 9 bpm, SPP 475 psi. RID Franks Tool, M I U Cement Head wI Plugs to Casing, Continued to Circulate Hole. Held PJSM w/ Dowell Crews, Rig Crews and Peak Truck Drivers. Switched over to Dowell. Pumped 10 bbls of CW 100 Chemical Wash at 4.0 bpm, 275 psi. Shut in Cement Manifold and Tested Lines to 3,500 psi, OK. Pumped 75 bbls of MudPush at 5.7 bpm, 350 psi. Dropped Bottom Plug, Pumped 432 bbls Printed: 8/19/2002 10:42:50 AM ) ") BP EXPLORATION Operations Summary Report Page 3 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-215i S-215i DRILL +COMPLETE DOYON DOYON 14 Start: 8/7/2002 Rig Release: 8/15/2002 Rig Number: Spud Date: 8/8/2002 End: 8/15/2002 Date From - To Hours Task Code NPT Phase Description of Operations 8/10/2002 09:00 - 12:00 3.00 CEMT P SURF (565 sx) 10.7 ppg ArcticSet Lite III Lead Cement, Followed by 45 bbls (220 sx) 15.8 ppg Premium Tail Cement wI 0.300% bwoc Dispersant, 0.360% bwoc Fluid Loss, 0.20 gallsk AntiFoam and 1.00 % bwoc Accelerator. Pumped Cement at the Following Rates: Pumped Rate Pressure 100.0 bbls 8.40 bpm 680 psi 200.0 bbls 8.40 bpm 700 psi 300.0 bbls 8.40 bpm 650 psi 400.0 bbls 8.40 bpm 850 psi 487.0 bbls 4.00 bpm 625 psi Dropped Top Plug, Pumped 5 bbls of Water at 4 bpm, 500 psi. Switched to Rig Pumps and Displaced wI 205 bbls of Mud at the Following Rates: Pumped Rate Pressure 95.0 bbls 9.50 bpm 425 psi 185.0 bbls 9.00 bpm 500 psi 205.0 bbls 4.00 bpm 700 psi Wiper Plug Bumped wI 210 bbls Pumped. Pressured up to 1,200 psi, OK. Cement in Place @ 1145 Hrs. Bled off Pressure, Floats Held. 12:00 - 13:00 1.00 CEMT P SURF Held PJSM. RID Cement Head and Lines. Broke out and LID Landing Joint. 13:00 -13:30 0.50 CEMT P SURF Cleaned and Cleared Rig Floor 13:30 - 15:30 2.00 WHSUR P INT1 Held PJSM. N I D Diverter and Surface Stack. 15:30 - 16:30 1.00 WHSUR P INT1 N I U 11" x 5,000 psi Wellhead and Spool. Tested to 1 ,000 psi fl 10 minutes, OK. 16:30 -19:30 3.00 BOPSURP INT1 Held PJSM. N I U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Top Pipe Ram wI 4-1/2" x 7" Variable Rams, Blind Ram, Mud Cross, Lower Pipe Rams wI 3-1/2" x 6" Variable Rams, Lower Mud Cross. 19:30 - 20:00 0.50 BOPSURP INT1 Held PJSM. R I U to Test BOPE Equipment. 20:00 - 23:30 3.50 BOPSUR P INT1 Tested BOPE. Tested Upper and Lower Rams, Blind Rams, Stand Pipe Manifold, Choke Manifold, Valves, HCR, Kill Line, Choke Line, Floor Valves and IBOP to 4,000 psi High 1250 psi Low. Tested Annular Preventer to 2,500 psi High I 250 psi Low. All Tests Held fl 5 Min. All Pressure Tests Held wI No Leaks or Pressure Loss. Witnessing of BOPE test Waived by John Spaulding-AOGCC. 23:30 - 00:00 0.50 BOPSURP INT1 RID BOPE Test Equipment. Ran and Set Wear Bushing. 8/11/2002 00:00 - 03:00 3.00 DRILL P INT1 Held PJSM. P I U 63 jts 5" DP and Racked in Derrick. 03:00 - 05:30 2.50 DRILL P INT1 Held PJSM. M I U 8-3/4" Directional BHA. 8-3/4" STC S86EHVPX PDC Bit, Ser# JS8283, dressed wI 8x12 jets, 7" SperryDrill Lobe 7/8 6.0 stg Motor, Float Sub, 8-1/4" Undergauge Integral Blade Stabilizer, FEMWD GR/Res/PWD, FEMWD DM, FEMWD CntlSld, Non-Mag Hang Off Sub, 3-Non-Mag Flex Collars, Drilling Jars, 20 jts 5" HWDP. Total BHA Length - 824.21'. 05:30 - 06:00 0.50 DRILL P INT1 Held PJSM on Radioactive Sources. Oriented MWD to Motor, Pulse Tested MWD Tools, OK. Cleared Rig Floor, Sperry Loaded Radioactive Sources into Tools. Ran Tools Below BOP Stack. 06:00 - 06:30 0.50 DRILL P INT1 RIH wI Directional BHA on 5" DP. Rotated Bit Through TAM Printed: 8/19/2002 10:42:50 AM ') ') BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-215i S-215i DRILL +COMPLETE DOYON DOYON 14 Start: 8/7/2002 Rig Release: 8/15/2002 Rig Number: Spud Date: 8/8/2002 End: 8/15/2002 Date From- To Hours Task Code NPT Phase Description of Operations 8/11/2002 06:00 - 06:30 0.50 DRILL P INT1 Port Collar at 973'. Closed Pipe Rams and Pressure Tested Casing to 1,000 psi to Ensure TAM Port Collar Closed, OK. Bled off Pressure and Opened Rams. 06:30 - 09:00 2.50 DRILL P INT1 RIH wI 8-3/4" Directional BHA on 5" DP to 2,850'. 09:00 - 09:30 0.50 DRILL P INT1 Circulated Bottoms Up at 2,850'. Pump Rate 600 gpm, SPP 2,200 psi. 09:30 - 10:00 0.50 DRILL P INT1 Held PJSM. Closed Pipe Rams and Tested Casing to 3,500 psi fl 30 minutes, OK. 10:00 - 11 :30 1.50 DRILL P INT1 Drilled out Float Equipment and Cement from 2,850' to 2,954'. Cleaned out to 3,001. WOB 10,000#, RPM 50, Motor RPM 198, Pump Rate 600 gpm, SPP 2,200 psi. 11 :30 - 12:00 0.50 DRILL P INT1 Drilled New 8-3/4" Hole from 3,001' to 3,021'. WOB 5,000#- 10,000#, RPM 50, Motor RPM 198, Pump Rate 600 gpm, SPP 2,200 psi. 12:00 - 12:30 0.50 DRILL P INT1 Circulated Bottoms Up at 3,021'. Pump Rate 600 gpm, SPP 2,200 psi. 12:30 - 13:00 0.50 DRILL P INT1 Held PJSM. Closed Pipe Rams and Performed LOT. Strokes Pmp'd Pressure 2 110 psi 8 260 psi 14 680 psi 18 890 psi 20 940 psi 22 945 psi Held Test fl 10 minutes wI Pressure Loss from 945 psi to 685 psi. MW 9.2 ppg, Csg Shoe TVD 2,850', Pressure 940 psi = 15.5 ppg EMW. Bled down Pressure, Opened Pipe Rams. 13:00 - 23:30 10.50 DRILL P INT1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 3,021' - 4,942'. WOB 5,000# - 20,000#, RPM 60, Motor RPM 198, Torque Off Bottom 5,000 ftIIbs, Torque On Bottom 8,000 ft/lbs, Pump Rate 650 gpm, SPP Off Bottom 2,050 psi, On Bottom 2,300 psi. ECD = 10.2 ppg. ART = 4.97 hrs, AST = 0.6 hrs. Pumped 20 bbl Hi-Vis Sweeps every 300'. 23:30 - 00:00 0.50 DRILL P INT1 Circulated Bottoms Up. Pump Rate 650 gpm, SPP 2,100 psi. 8/12/2002 00:00 - 02:30 2.50 DRILL P INT1 Held PJSM. Made Wiper Trip from 4,942' to 9-5/8" Casing Shoe at 2,945'.4,942' to 4,850', Hole Swabbed at Varied Tripping Rates. Pumped out of the Hole from 4,850' to 2,945'. Pump Rate 8 bpm, SPP 1,000 psi. Flow Check Well, Static. 02:30 - 03:00 0.50 DRILL P INT1 RIH after Wiper Trip from 2,945' to 4,910'. Washed and Reamed Through Bridge at 3,550'. Washed Down as a Precaution from 4,910' to 4,942'. 03:00 - 17:30 14.50 DRILL P INT1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 4,942' - 6,930'. WOB 5,000# - 20,000#, RPM 60, Motor RPM 198, Torque Off Bottom 9,000 ftllbs, Torque On Bottom 13,000 ftllbs, Pump Rate 650 gpm, SPP Off Bottom 2,350 psi, On Bottom 2,650 psi. ECD = 10.4 ppg. ART = 7.1 hrs, AST = 0.92 hrs. Pumped 5 bbl Lo-Vis 20 bbl Hi-Vis Tandem Sweeps Every 300'. 17:30 - 18:30 1.00 DRILL P INT1 Pumped and Circulated Around 25 bbl Hi-Vis Sweep. Pump Rate 650 gpm, SPP 2,350 psi. Circulated Until Returns over Shaker were Clean. 18:30 - 20:30 2.00 DRILL P INT1 Held PJSM. Made Wiper Trip from 6,930' to 9-5/8" Casing Shoe at 2,945'. 6,930' - 6,800' Average Drag 30,000#, Printed: 8/19/2002 10:42:50 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-215i S-215i DRILL +COMPLETE DOYON DOYON 14 Date From - To Hours Task Code NPT Phase 8/12/2002 18:30 - 20:30 2.00 DRILL P 20:30 - 21 :30 1.00 DRILL P 21 :30 - 22:30 1.00 DRILL P 22:30 - 23:00 0.50 DRILL P 23:00 - 00:00 1.00 DRILL P INT1 INT1 INT1 INT1 INT1 8/13/2002 00:00 - 01 :00 1.00 DRILL P 01 :00 - 04:30 3.50 DRILL P 04:30 - 06:30 2.00 DRILL P 06:30 - 07:00 0.50 BOPSUR P 07:00 - 08:00 1.00 CASE P 08:00 - 08:30 0.50 CASE P 08:30 - 11 :30 3.00 CASE P 11 :30 -12:30 1.00 CASE P 12:30 - 16:00 3.50 CASE P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 16:00 - 16:30 0.50 CASE P INT1 16:30 -18:30 2.00 CASE P INT1 18:30 - 19:00 0.50 CASE P INT1 19:00 - 20:30 1.50 CEMT P INT1 Page 5 of 7 Start: 8/7/2002 Rig Release: 8/15/2002 Rig Number: Spud Date: 8/8/2002 End: 8/15/2002 Description of Operations Maximum Overpull 70,000#. 6,800' - 5,700' Average Drag 15,000#, Maximum OverpuIl50,OOO#. 5,700' - 2,946' Average Drag 15,000#. Serviced Top Drive, Adjusted Brake Bands on Drawworks. RIH after Wiper Trip from 2,945' to 6,750'. No fill. Washed Down as a Precaution from 6,750' to 6,930'. Pump Rate 450 gpm, SPP 1,600 psi. No Fill On Bottom. Pumped and Circulated Around 25 bbl Hi-Vis Sweep. Pump Rate 650 gpm, SPP 2,300 psi. Slight Show of Trip Gas on Bottoms Up. Circulated until Returns over Shaker were Clean. Held PJSM. Pumped and Spotted 75 bbl Casing Running Pill. Pump Rate 400 gpm, SPP 1,600 psi. Flow Checked Well, Static. POOH, L / D 204 jts of 5" DP. Held PJSM on Radioactive Sources. Flushed, Serviced, Broke Out, Sperry Removed Radioactive Sources and L / D 8-3/4" Directional BHA. M / U Retrieving Tool, Latched and Pulled Wear Bushing. L / D Retrieving Tool. Held PJSM. R / U Equipment to Run 7" Casing. M / U Shoe Jt and Float Collar Jt. BakerLock'd Connections. Filled Casing and Checked Float Equipment, OK. RIH w/ 71 jts 7" 26# L-80 BTC-M Casing to 9-5/8" Casing Shoe at 2,945'. Average M / U Torque 7,000 ft / Ibs. Broke Circulation and Circulated Bottoms Up at 2,945'. Pump Rate 7 bpm, 580 psi. RIH w/ a total of 169 jts 7" 26# L-80 BTC-M Casing to 6,915'. Broke Circulation Every 15 joints. Pump Rate 7 bpm, 700 psi. Running Rate 6 min I Jt while Circulating. Average M / U Torque 7,000 ft / Ibs. M I U Landing Jt and 7" Casing Hanger. 7" Casing Set As Follows: Item Length Depth Float Shoe 1.65' 6,915.50' 2 Jts 7" 26# L-80 BTC-M Csg 78.63' 6,835.22' Float Collar 1.00' 6,834.22' 15 Jts 7" 26# L-80 BTC-M Csg 610.92' 6,223.30' 7" 26# L-80 BTC-M Mkr Jt w/ RA Tag 19.50' 6,204.30' 11 Jts 7" 26# L-80 BTC-M Csg 444.32' 5,759.98' 7" 26# L-80 BTC-M Mkr Jt w/ RA Tag 19.54' 5,740.98' 141 Jts 7" 26# L-80 BTC-M Csg 5,707.32' 33.17' 7" Casing Hanger 1.66' 31.51' Circulated to Condition and Cool the Hole. Pump Rate 7 bpm, 710 psi. Reciprocated Casing while Circulating. Held PJSM w/ Dowell Crews, Rig Crews and Peak Truck Drivers. Continued to Circulated to Condition Hole while Dowell Batch mixed Tail Cement. Pump Rate 7 bpm, 710 psi. Switched over to Dowell. Pumped 5 bbls of CW 100 to Clear the Lines of Air. Shut in Cement Manifold and Tested Lines to 3,500 psi, OK. Pumped 35 bbls of CW 100 Chemical Wash at 5.5 bpm, 675 psi. Pumped 30 bbls of MudPush at 4 bpm, 570 psi. Dropped Bottom Plug, Pumped 62 bbls (145 sx) 12.0 ppg LiteCrete Lead Cement and 63 bbls (300 sx) 15.8 ppg Printed: 8/19/2002 10:42:50 AM ) ) BP Operations Summary Report Page 6 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-215i S-215i DRILL +COMPLETE DOYON DOYON 14 Start: 8/7/2002 Rig Release: 8/15/2002 Rig Number: Spud Date: 8/8/2002 End: 8/15/2002 Date From -To Hours Task Code NPT Phase Description of Operations 8/13/2002 19:00 - 20:30 1.50 CEMT P INT1 Premium Tail Cement w/ 0.02% bwoc Retarder, 0.62% bwoc Dispersant, 0.20 gal/sk AntiFoam and 2.00 gal/sk GASBLOK. Pumped Cement at the Following Rates: Pumped Rate Pressure 20.0 bbls 6.00 bpm 1 ,1 00 psi 40.0 bbls 6.00 bpm 1,030 psi 62.0 bbls 6.00 bpm 1,000 psi Tail Cement 80.0 bbls 4.50 bpm 750 psi 100.0 bbls 4.50 bpm 780 psi 126.0 bbls 3.50 bpm 420 psi Cleaned up and Flushed Cement Lines. Dropped Top Plug, Switched to Rig Pumps and Displaced w/ 259 bbls of Sea Water at the Following Rates: Pumped Rate Pressure 5.0 bbls 7.00 bpm 110 psi 50.0 bbls 7.00 bpm 110 psi 100.0 bbls 7.00 bpm 110 psi 150.0 bbls 7.00 bpm 350 psi 175.0 bbls 7.00 bpm 700 psi 200.0 bbls 7.00 bpm 950 psi 225.0 bbls 7.00 bpm 1,250 psi 250.0 bbls slw'd pmps 2.0 bpm 1,250 psi Wiper Plug Bumped w/ 258.5 bbls Pumped. Pressured up to 3,000 psi to Test Casing, Held f/ 10 minutes, OK. Cement in Place @ 2030 Hrs. Bled off Pressure, Floats Held. 20:30 - 21 :00 0.50 CEMT P INT1 R / D Cement Head and Lines. Broke out and L / D Landing Joint. 21 :00 - 22:00 1.00 WHSUR P INT1 Ran and Set 7" Pack off. Tested Packoff to 5,000 psi f/ 10 minutes, OK. 22:00 - 22:30 0.50 RUNCOIVP COMP Cleaned and Cleared Rig Floor. 22:30 - 23:30 1.00 RUNCOIVP COMP Held PJSM w/ Rig Crews and Halliburton Slickline Crew. R / U Slickline. 23:30 - 00:00 0.50 RUNCOIVP COMP RIH w/ 6.00" Gauge Ring and Junk Basket on Slickline. 8/14/2002 00:00 - 02:00 2.00 RUNCOIVP COMP RIH w/ 6.00" Gauge Ring and Junk Basket on Slickline to 6,803'. POOH w/ Gauge Ring and Junk Basket. 02:00 - 02:30 0.50 RUNCOIVP COMP R / D Slickline Unit. 02:30 - 03:30 1.00 RUNCOIVP COMP Held PJSM w/ Crew, Running Completion. R / U Equipment to Run 4-1/2" Completion. 03:30 - 04:30 1.00 RUNCOIVP COMP M / U and RIH w/ 4-1/2" Tail Pipe and Packer Assembly. 04:30 - 12:30 8.00 RUNCOIVP COMP RIH w/ 138 Joints 4-1/2" 12.6# L-80 TC-II Tubing. M / U Torque 2,650 ft / Ibs. 12:30 - 13:00 0.50 RUNCOIVP COMP M / U Tubing Hanger and Landing Joint. Landed Tubing Hanger in Wellhead, RILDS. Completion Equipment Set at the Following Depths: Item Length Depth WLEG XN Nipple Assembly 23.48' 5,659.99' X Nipple Assembly 20.69' 5,615.82' 7" x 4-1/2 S-3 Packer Assembly 26.86' 5,588.96' 1 Jt 4-1/2" 12.6# L-80 TC-II Tbg 39.78' 5,549.18' CDM Sliding Sleeve Assembly 23.81' 5,525.37' 51 Jts 4-1/2" 12.6# L-80 TC-II Tbg 2,032.79' 3,492.58' GLM Assembly w/ RP Shear Valve 26.55' 3,466.03' Printed: 8/19/2002 10:42:50 AM ) ) Page 7 of 7 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-215i S-215i DRILL +COMPLETE DOYON DOYON 14 Date From'- To Hours Task Code NPT Phase 8/14/2002 12:30 - 13:00 0.50 RUNCOrvP COMP 13:00 -14:00 14:00 -15:00 1.00 RUNCOrvP 1.00 RUNCOrvP COMP COMP 15:00 - 17:30 2.50 RUNCOrvP COMP 17:30 - 18:00 0.50 RUNCOrvP 18:00 - 19:00 1.00 BOPSUR P 19:00 - 21 :00 2.00 BOPSUR P 21 :00 - 22:00 1.00 WHSUR P 22:00 - 23:00 1.00 WHSUR P 23:00 - 00:00 1.00 WHSUR P 8/15/2002 00:00 - 01 :30 1.50 WHSUR P 02:00 - 03:30 1.50 WHSUB P 04:00 - 06:00 2.00 WHSUR P COMP COMP COMP COMP COMP COMP COMP COMP COMP Start: 8/7/2002 Rig Release: 8/15/2002 Rig Number: Spud Date: 8/8/2002 End: 8/15/2002 Descri ption of Operations 31 Jts 4-1/2" 12.6# L-80 TC-II Tbg 1,230.86' X Nipple Assembly 20.73' 55 Jts 4-1/2" 12.6# L-80 TC-II Tbg 2,182.78' Tubing Hanger 2.41' Held PJSM. R I U Circulating Equipment. Reverse Circulated 150 bbls of Corrosion Inhibited Clean Sea Water Down 7" x 4-1/2" Annulus. Pump Rate 3 bpm, 390 psi. Held PJSM. Dropped BallI Rod Assembly. Pressured up on Tubing to 4,200 psi to set Packer. Tested Tubing to 4,000 psi fl 30 Minutes. OK. Bled Tubing Pressure Down to 2,500 psi. Pressure Tested IA to 4,000 psi f/30 Minutes, OK. Bled Down Tubing Pressure Sheared RP Valve. Bled Down All Pressure. 2,235.17' 2,214.44' 31.66' 29.25' Simops - Held PJSM. R I U Little Red Hot Oil Unit to 9-5/8" x 7" Annulus. Tested Lines to 3,500 psi. Bullheaded 75 bbls of Dead Crude Oil Down Annulus to Freeze Protect. Pump Rate 2.2 bpm, 1,250 psi. Set TWC in Tubing Hanger Profile. Tested TWC from Below to 2,000 psi. Held PJSM. Opened Ram Doors and Cleaned out Ram Cavities, Changed out Upper Pipe Rams to 2-7/8" x 5" Variables. Held PJSM. N I D BOPE. Held PJSM. N I U Adapter Flange and Production Tree. FMC Tested Adapter Flange to 5,000 psi f/1 0 minutes. R I U and Tested Tree to 5,000 psi, OK. Held PJSM. R I U DSM Lubricator, Pulled TWC. RID DSM. Held PJSM. R I U Little Red Hot Oil. Tested Lines to 3,000 psi, OK. Pumped 75 bbls of Diesel Down 7" x 4-1/2" Annulus to Freeze Protect. Pump Rate 1.5 bpm, 1,800 psi. R I U Lines and U-Tubed Diesel between IA and 4-1/2" Tubing. Freeze Protected IA and Tbg to 2,200'. RID Little Red. Removed 2nd Annulus Valve, Installed Tree Cap & Gauges. Installed Blind Flange on Annulus Valve. Secured Well. Released Rig @ 04:00 Hrs, 08/15 I 2002. Printed: 8/19/2002 10:42:50 AM ) ) Well: Field: API: Permit: S-215i Prudhoe Bay Unit 50-029-23107 -00 202-154 Rig Accept: Rig Spud: Rig Release: Drilling Rig: 08/07/02 08/08/02 08/15/02 Doyon 14 POST RIG WORK 11/14/02 PULL B&R @ 5620' SLM. PULL 1" RPV IN STA #1 @ 3451' SLM. SET 1" DGLV @ SAME. PULL 41/2" RHC PLUG. @ 5622' SLM. DRIFT TBG W/10' X 3.375" DG WrrEL & SB. LOCATE TTL @ 5637' SLM + 31' = 5668' CORR RKB. TAG BOTTOM @ 6399' SLM + 31' = 6430' CORR RKB. RDMO. WELL LEFT SHUT IN. 11/16/03 JEWELRY I SCMT / TEMP LOG. TEMP PASS LOGGED FROM SURFACE TO TD. TAG TD AT 6420'. GREASE PRESSURE APPLIED TO INCREASE PRESSURE IN FLUID PACKED WELL WITH CABLE DISPLACEMENT. SCMT LOGGED WITH 400 PSI WHP. GOOD CEMENT INDICATION. PAD OPERATOR NOTIFIED WELL LEFT SHUT IN. 03/10/03 PERFORM WEEKLY BOP TEST. RIH W/ 2.25" REVERSING NOZZLE. START REVERSING OUT FROM 6200' DOWN TO 6834' CTMD. DID NOT SEE ANY RESTRICTIONS. GETTING GRAY MUD-LIKE MATERIAL IN RETURNS. MAKE 3 SHORT TRIPS REVERSING TO PBTD. RETURNS CLEAN. POOH. FP TUBING FROM 2500' WITH 60/40 METHANOL. 03/14/03 FOUND WELL SHUT IN ON ARRIVAL. DRIFT W. 3.50 CENT TEL SB. TAG TD @ 6808' SLM + 30' = 6838'. CORR TO MD. CEMENT IN SB. TAG TD W/ 27/8 X 20.33' DG @ 6811' SLM + 27' = 6838' CORR TO MD. SHIFT OPEN SSD @ 5512 SLM. RDMO. LEFT WELL SHUT IN. 03/27/03 WELL SI UPON ARRIVAL. RIG UP SLlCKLlNE UNIT. RUNNING IN HOLE W/ SHIFTING TOOL TO SHIFT SLIDING SLEEVE. 03/28/03 SHIFTED SLIDING SLEEVE CLOSED @ 5510' WLM. LEFT WELL SHUT IN. 03/31/03 JEWELRY LOG / PERFORATE FROM 6505'-6525' WITH 2-7/8" HSD, PJ2906 HMX, 6 SPF, WELL STACKED OUT WITH 1250 PSI. RIH WITH GR/CCUSAFE HEAD, OAL=30', JEWELRY LOG FROM 6806'-5450'. TIE INTO SPERRY MWD DGR / 06-AUG-2002. TTAIL FOUND AT 5651', TD TAGGED @ 6826'. 04/14/03 T/I/O = 1430/1180/0. BLEED IA TO 300 PSI. (TIFL PASSED). INITIAL IA FL @ 5425'. BLED IA FROM 1180 PSI TO 300 PSI IN 2 HRS AND 12 MIN. IA FL REMAINED AT 5425'. SI BLEED AND MONITORED FOR 1 HR. NO CHANGE IN lAP OR IA FL. FINAL WHP'S = 1430/300/0. 04/16/03 T/1/0=1450/300/0 (POST TIFL) NO CHANGE IN lAP. 04/22/03 T/I/O = 1430/320/0. BLEED TUBING FOR E-LlNE. BLED TUBING FROM 1430 PSI TO 320 PSI IN 3 HOURS. S-215, Post Drilling Rig Work Page 2 ') ~) 04/23/03 COLLECT OILPHASE SAMPLE @ 5200' MD. RIH W/ HEAD, PBMS, PGMS, OILPHASE SAMPLE CATCHER (TL= 44.4', MOD=1.75"), LOG FROM SURFACE TO 5870' @ 5000 FPH. GAS TO 920', WATER 5480'. STOP TO COLLECT SAMPLE AT 1600' MD. FIRST RUN UNSUCCESSFUL. SECOND ATTEMPT: LOG FROM SURFACE TO 5870' @ 5000 FPH. GAS TO 920', WATER/OIL CONTACT @ 5480'. STOP TO COLLECT SAMPLE AT 5200' MD. GOOD SAMPLE. SHUT-IN. 04/29/03 WELL SHUT IN ON ARRIVAL. RUN SHIFTING TOOL TO SLIDING SLEEVE @ 5513' SLM, ATTEMPTED TO SHIFT OPEN BUT COULDN'T SEE SPANGS HIT DOWN. 04/30/03 OPENED SLIDING SLEEVE, LRS PUMPED 100 BBLS 50/50 INHIB, CLOSED SLEEVE, LRS ATTEMPTING MIT IA. HOT OIL TBG W/ 85BBLS HOT CRUDE. LOAD AND TEST IA W/105 BBLS INHIBITED 50/50MEOH TO 1500 PSI. PASSED. 05/05/03 PERFORATING PROGRAM OF 11 RUNS OF 27/8" 2 SPF 180 DEGREE PHASED WITH A 90 DEGREE OFFSET FROM BOTTOM WAS STARTED. RUNS MADE TODAY WERE: RUN #1 - 10' GUN INTERVAL 6585'·6595' RUN #2 - 20' GUN INTERVAL 6525'·6545' RUN #3 - 20', GUN INTERVAL 6430'-6450' RUN #4 . 25' GUN INTERVAL 6355-6380' DEPTH CORRELATED TO SPERRY MWD 8/14/03. ALL SHOTS FIRED. WHP AT START OF OPERATION 500 PSI, END OF DAY 1000 PSI. TO BE CONTINUED ON 5/6/03. WELL LEFT SI. 05/06/03 CONTINUE PERFORATING WITH 2 7/8" HSD GUNS, LOADED 2 SPF PHASED 180 DEGREES, WITH AN OFFSET OF 90 DEGREES FROM BOTTOM. DEPTHS BELOW ARE CORRELATED TO SPERRY MWD 8/14/02. GUN #1 - 20' INTERVAL 6322'-6342' GUN #2 - 20' INTERVAL 6302'-6322' GUN #3 - 15', INTERVAL 6265-6280' GUN #4 - 20', INTERVAL 6240-6260' GUN #5 - 20' INTERVAL 6150-6170' GUN #6 - 10' INTERVAL 6120-6130' GUN #7 -12'INTERVAL 6098-6110' ALL SHOTS FIRED. WELL LEFT SI FOR SBHPS. 05/09/03 PERFORMED SBHPS. STOP COUNTS TAKEN AT: 6256' (5000' SS) PRESS = 2272.7 PSI, TEMP = 97.2 DEGF 6156' (4929' SS) PRESS = 2243.3 PSI, TEMP = 96.4 DEGF 6056' (4859' SS) PRESS = 2215.6 PSI, TEMP = 95.8 DEGF SITP = 1210 PSI, FLUID LEVEL DETECTED AT 2620'. WELL LEFT SHUT-IN. 05/11/03 TI0=750/920/20 TEMP=110 BLEED IA (PRE MIT-IA). IA FL @ 348' (6 BBLS). BLED IA FROM 920 PSI TO 30 PSI IN 1 HR AND 15 MIN. IA FL REMAINED UNCHANGED DURING BLEED. MONITOR FOR 30 MIN, lAP INCREASED 40 PSI FOR A TOTAL OF 70 PSI. FINAL WHP'S 750/70/20. 05/12/03 10=850/70/150 TEMP=112 LOAD IA. IA FL @ 348' (6 BBLS). BLED IA FROM 70 PSI TO 20 PSI IN 15 MIN. PUMPED 8 BBLS OF METH DOWN IA. PRESSURED IA TO 1300 PSI. THEN BLED IA BACK TO 100 PSI. MONITOR FOR 30 MIN. FINAL WHP'S 850/100/150. } aOd--/5£/ 03-Sep-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well S-215 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) SEP 10 2002 Alaska OH & Gas Cons. Commission Anchorage DEFN T VE North Slope Alaska BPXA PBU_WOA S Pad, Slot S-215; S-215 Gyro Job No. AKF022131, Surveyed: 12 August, 2002 -= SURVEY REPORT 3 September, 2002 Your Ref: API 500292310700 Surface Coordinates: 5979479.33 N, 618885.41 E (700 21' 09.3279" N, 1490 02' 04.7581" W) Kelly Bushing: 71.49ft above Mean Sea Level ~ !5pe!1'r"Y-SUl'1 DRILLING SERVices A Halliburton Company Survey Ref: svy11272 Sperry-Sun Drilling Services Survey Report for 5-215 Gyro Your Ref: API 500292310700 Job No. AKF022131, Surveyed: 12 August, 2002 . BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/100ft) 0.00 0.000 0.000 -71.49 0.00 0.00 N O.OOE 5979479.33 N 618885.41 E 0.00 Tolerable Gyro 106.00 0.250 165.000 34.51 106.00 0.228 0.06E 5979479.11 N 618885.47 E 0.236 0.15 166.00 0.250 215.000 94.51 166.00 0.46 8 0.02E 5979478.87 N 618885.44 E 0.352 0.37 253.00 1.750 125.000 181.50 252.99 1.378 1.00 E 5979477.97 N 618886.43 E 2.032 0.60 343.00 2.400 120.000 271.44 342.93 3.10 S 3.76E 5979476.28 N 618889.21 E 0.749 0.54 434.00 3.250 86.000 362.33 433.82 3.888 7.98E 5979475.58 N 618893.45 E 2.023 -1.13 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 213.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 434.00ft., The Bottom Hole Displacement is 8.87ft., in the Direction of 115.919° (True). Survey tool program for 5-215 Gyro ~/ Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 434.00 433.82 Tolerable Gyro ---------- -- 3 September, 2002 - 14:35 Page 20f2 DrillQlIest 2.00.08.005 é)la¿j- J 54 ) ,) 03-Sep-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well S-215 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 434.00' MD 'MD (if applicable) 6,930.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED SEP 1 0 2002 Alaska QiV & Gas Cons C '. Anch . omm/SSlOn orage Attachment(s) JEFN T VE North Slope Alaska BPXA PBU_WOA 5 Pad, Slot 5-215; 5-215 Job No. AKZZ22131, Surveyed: 12 August, 2002 ~' SURVEY REPORT 3 September, 2002 Your Ref: API 5002923107 Surface Coordinates: 5979479.33 H, 618885.41 E (70° 21' 09.3279" N, 149002' 04.7581" W) Kelly Bushing: 71.49ft above Mean Sea Level Spt=i ·,....,y-SUf'1 t)RILLtNG SEAvtces A Halliburton Company 5U1vey Ref: svy11298 Sperry-Sun Drilling Services . Survey Report for S-215 Your Ref: API 5002923107 Job No. AKZZ22131, Surveyed: 12 August, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 434.00 3.250 86.000 362.33 433.82 3.888 7.98 E 5979475.58 N 618893.45 E -1.11 AK-6 BP _IFR-AK 530.43 3.600 84.650 458.59 530.08 3.40 8 13.72 E 5979476.14 N 618899.18 E 0.372 -4.64 ~ 616.46 4.060 83.690 544.43 615.92 2.828 19.44 E 5979476.82 N 618904.89 E 0.540 -8.25 705.96 4.770 84.860 633.66 705.15 2.148 26.29 E 5979477.61 N 618911.73 E 0.800 -12.56 800.13 5.740 85.740 727.43 798.92 1.44 8 34.89 E 5979478.45 N 618920.32 E 1.034 -17.84 897.43 6.730 91.910 824.16 895.65 1.268 45.44 E 5979478.79 N 618930.86 E 1 .227 -23.75 992.39 6.360 96.090 918.50 989.99 2.018 56.23 E 5979478.21 N 618941.66 E 0.635 -29.02 1 087.44 6.740 102.380 1012.93 1084.42 3.768 66.91 E 5979476.63 N 618952.37 E 0.854 -33.38 1183.63 7.830 123.610 1108.36 1179.85 8.608 77.89 E 5979471.97 N 618963.42 E 2.998 -35.32 1280.30 8.960 127.790 1203.99 1275.48 16.868 89.32 E 5979463.89 N 618974.99 E 1.328 -34.64 1376.53 8.790 136.800 1299.07 1370.56 26.81 8 100.28 E 5979454.11 N 618986.10 E 1 .454 -32.28 1472.70 8.370 141 .960 1394.17 1465.66 37.688 109.62 E 5979443.39 N 618995.61 E 0.911 -28.28 1567.87 9.550 135.510 1488.18 1559.67 48.77 8 119.42 E 5979432.46 N 619005.59 E 1.627 -24.34 1663.38 9.340 140.170 1582.40 1653.89 60.37 8 129.94 E 5979421.03 N 619016.29 E 0.830 -20.36 1758.44 5.830 133.440 1676.61 1748.10 69.62 8 138.39 E 5979411.92 N 619024.88 E 3.803 -17.22 1854.11 5.560 128.940 1771.81 1843.30 75.87 S 145.52 E 5979405.78 N 619032.11 E 0.545 -15.88 1950.67 5.680 129.510 1867.90 1939.39 81.85 S 152.84 E 5979399.91 N 619039.53 E 0.137 -14.87 2048.81 7.270 156.370 1965.44 2036.93 90.63 S 159.08 E 5979391.23 N 619045.91 E 3.441 -10.92 2142.36 9.970 182.930 2057.96 2129.45 104.158 161.04 E 5979377.75 N 619048.08 E 5.068 -0.66 2237.78 10.410 197.180 2151.89 2223.38 120.64 8 158.07 E 5979361.21 N 619045.38 E 2.675 14.77 2333.87 11.720 204.790 2246.19 2317.68 137.808 151.42 E 5979343.95 N 619038.99 E 2.039 32.78 2430.35 14.940 208.310 2340.06 2411.55 157.65 S 141.41 E 5979323.95 N 619029.30 E 3.440 54.88 2526.35 19,890 209.210 2431.64 2503.13 182.81 S 127.56 E 5979298.57 N 619015.85 E 5.164 83.52 2622.52 26.590 211.100 2519.95 2591.44 215.56 8 108.44 E 5979265.52 N 618997.25 E 7.009 121.40 2718.38 33.720 216.910 2602.80 2674.29 255.26 S 81.33 E 5979225.39 N 618970.78 E 8.029 169.46 2813.16 39.920 218.860 2678.64 2750.13 300.02 S 46.42 E 5979180.08 N 618936.58 E 6.656 226.02 2911.84 44.650 219.920 2751.63 2823.12 351.30 S 4.28E 5979128.14 N 618895.26 E 4.847 291.99 2936.20 44.330 218.170 2769.01 2840.50 364.56 8 6.48 W 5979114.72 N 618884.72 E 5.203 308.97 3056.03 46.750 219.140 2852.93 2924.42 431.338 59.91 W 5979047.10 N 618832.36 E 2.100 394.08 3151.66 46.050 219.900 2918.88 2990.37 484.75 S 103.97 W 5978992.99 N 618789.14 E 0,931 462.90 - -- ------ --.- 3 September, 2002 - 14:32 Page 20'5 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 5-215 Your Ref: API 5002923107 Job No. AKZZ22131, Surveyed: 12 August, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3247.36 48.4 70 220.500 2983.82 3055.31 538.43 S 149.34 W 5978938.60 N 618744.63 E 2.570 532.64 3342.87 49.890 217.210 3046.27 3117.76 594.71 8 194.65 W 5978881.60 N 618700.22 E 3.001 604.53 - 3437.74 50.060 214.980 3107.28 3178.77 653.41 8 237.45 W 5978822.23 N 618658.36 E 1.809 677.07 3532.78 49.400 214.290 3168.72 3240.21 713.07 S 278.66 W 5978761.92 N 618618.10 E 0.888 749.56 3628.27 49.880 213.620 3230.56 3302.05 773.43 8 319.30 W 5978700.93 N 618578.42 E 0.734 822.31 3722.93 49.900 213.070 3291.54 3363.03 833.91 8 359.10 W 5978639.83 N 618539.59 E 0.445 894.71 3818.17 48.750 214.430 3353.62 3425.11 893.97 8 399.22 W 5978579.14 N 618500.43 E 1.622 966.93 3915.80 48.280 215.460 3418.29 3489.78 953.92 8 441.11 W 5978518.53 N 618459.50 E 0.925 1040.03 4009.15 47.530 216.420 3480.87 3552.36 1010.008 481.76 W 5978461.81 N 618419.74 E 1.108 1109.21 4106.09 47.040 216.230 3546.63 3618.12 1067.38 S 523.95 W 5978403.77 N 618378.46 E 0.526 1180.32 4203.07 46.310 217 .450 3613.17 3684.66 1123.858 566.25 W 5978346.64 N 618337.07 E 1.185 1250.72 4298.66 46.440 218.210 3679.12 3750.61 1178.508 608.68 W 5978291.32 N 618295.50 E 0.591 1319.68 4394.64 46.730 219.540 3745.09 3816.58 1232.778 652.44 W 5978236.36 N 618252.61 E 1.051 1389.04 4491.39 46.760 219.730 3811.38 3882.87 1287.048 697.39 W 5978181.39 N 618208.53 E 0.146 1459.04 4587.05 47.970 220.020 3876.18 3947.67 1341.048 742.51 W 5978126.67 N 618164.27 E 1.284 1528.92 4681.08 47.380 219.050 3939.49 4010.98 1394.66 8 786.76 W 5978072.37 N 618120.88 E 0.988 1598.00 4777.79 47.630 217.380 4004.82 4076.31 1450.688 830.87 W 5978015.65 N 618077.66 E 1.299 1669.02 4872.91 47.850 217.280 4068.79 4140.28 1506.668 873.56 W 5977959.00 N 618035.87 E 0.244 1739.22 4970.60 47.100 216.200 4134.82 4206.31 1564.35 8 916.63 W 5977900.63 N 617993.72 E 1.119 1811.07 5066.20 48.130 215.620 4199.27 4270.76 1621.54 8 958.04 W 5977842.79 N 617953.22 E 1.167 1881.60 5161.55 47.340 215.850 4263.39 4334.88 1678.82 8 999.25 W 5977784.87 N 617912.92 E 0.848 1952.08 5256.76 48.210 217.740 4327.38 4398.87 1735.27 8 1041.48 W 5977727.76 N 617871.59 E 1.731 2022.43 5353.12 49.080 216.970 4391.05 4462.54 1792.768 1085.36 W 5977669.57 N 617828.63 E 1.084 2094.56 5448.92 49.130 216.840 4453.77 4525.26 1850.67 8 1128.85 W 5977610.98 N 617786.07 E 0.115 2166.82 5544.34 48.840 217.750 4516.39 4587.88 1907.958 1172.47 W 5977553.02 N 617743.36 E 0.781 2238.62 5640.52 49.520 217.460 4579.26 4650.75 1965.61 8 1216.89 W 5977494.66 N 617699.86 E 0.743 2311 . 18 5737.10 48.880 217.640 4642.37 4713.86 2023.57 8 1261.44 W 5977436.00 N 617656.23 E 0.678 2384.07 5833.04 47.880 217.360 4706.09 4777.58 2080.478 1305.11 W 5977378.41 N 617613.48 E 1.065 2455.58 5928.98 47.280 216.520 4770.80 4842.29 2137.088 1347.67 W 5977321.14 N 617571.82 E 0.899 2526.24 6024.71 45.350 216.030 4836.92 4908.41 2192.888 1388.63 W 5977264.69 N 617531.75 E 2.050 2595.36 ----- -_._--~---------- ----------- _.- .- 3 September, 2002 - 14:32 Page 3 0'5 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 5-215 Your Ref: API 5002923107 Job No. AKZZ22131, Surveyed: 12 August, 2002 BPXA North Slope Alaska PBU WOA 5 Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6120.44 45.140 216.180 4904.32 4975.81 2247.80 S 1428.69 W 5977209.14 N 617492.57 E 0.246 2663.24 6216.57 44.780 215.410 4972.35 5043.84 2302.90 S 1468.42 W 5977153.42 N 617453.72 E 0.679 2731.09 6312.39 47.1 50 216.260 5038.95 5110.44 2358.73 S 1508.75 W 5977096.95 N 617414.27 E 2.554 2799.89 ~ 6408.46 47.020 216.610 5104.36 5175.85 2415.34 S 1550.54 W 5977039.69 N 617373.39 E 0.299 2870.13 6504.84 48.480 215.690 5169.16 5240.65 2472.95 S 1592.62 W 5976981.42 N 617332.23 E 1.671 2941.37 6600.88 48.860 215.940 5232.59 5304.08 2531.43 S 1634.82 W 5976922.28 N 617290.96 E 0.441 3013.41 6696.61 48.360 215.980 5295.88 5367.37 2589.56 S 1676.99 W 5976863.49 N 617249.72 E 0.523 3085.13 6792.13 48.020 215.970 5359.56 5431.05 2647.18 S 1718.82 W 5976805.21 N 617208.81 E 0.356 3156.24 6861.02 47.960 216.210 5405.67 5477.16 2688.54 S 1748.97 W 5976763.37 N 617179.32 E 0.273 3207.36 6930.00 47.960 216.210 5451.86 5523.35 2729.88 S 1779.23 W 5976721.56 N 617149.72 E 0.000 3258.51 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 213.090° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6930.00ft., The Bottom Hole Displacement is 3258.51ft., in the Direction of 213.095° (True). -- - ----~ 3 September, 2002 - 14:32 Page 4 0'5 Dri/lQlIest 2.00.08.005 North Slope Alaska Comments Measured Depth (ft) 6930.00 Sperry-Sun Drilling Services Survey Report for 5-215 Your Ref: API 5002923107 Job No. AKZZ22131~ Surveyed: 12 August~ 2002 . 2729.88 S Survey tool program for 5-215 BPXA PBU_WOA S Pad Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5523.35 From Measured Vertical Depth Depth (ft) (ft) 0.00 434.00 3 September, 2002 - 14:32 0.00 433.82 To Measured Vertical Depth Depth (ft) (ft) Comment ~J 1779.23 W Projected Survey Survey Tool Description 434.00 6930.00 433.82 Tolerable Gyro (5-215 Gyro) 5523.35 AK-6 BP _IFR-AK (5-215) - -------.----- Page 50f5 DrillQlIest 2.00.08.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 , 03-Sep-02 Re: Distribution of Survey Data for Well S-215 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 434.00 I MD 'MD (if applicable) 6,930.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 10 2002 Alaska Oj~ & Gas Cons. Commission Anchorage ~ò;;;;.-) 5 '1 North Slope Alaska BPXA PBU_WOA S Pad, Slot S-215; 5-215 - 5-115 MWD Job No. AKMW22131, Surveyed: 12 August, 2002 -~' SURVEY REPORT 3 September, 2002 Your Ref: AP/500292310700 Surface Coordinates: 5979479.33 N, 618885.41 E (70021'09.3279" N, 149002'04.7581" W) Kelly Bushing: 71.49ft above Mean Sea Level ~- =ru==at''-'Y-BUI! tlAILLING SERVICES A Halliburton Company Survey Ref: svy11299 Sperry-Sun Drilling Services . Survey Report for $-215 - $-115 MWD Your Ref: API 500292310700 Job No. AKMW22131~ Surveyed: 12 August~ 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 434.00 3.250 86.000 362.33 433.82 3.888 7.98E 5979475.58 N 618893.45 E -1,11 MWD Magnetic 530.43 3.600 84.650 458.59 530.08 3.40 8 13.72 E 5979476.14 N 618899.18 E 0.372 -4.64 616.46 4.060 84.130 544.43 615.92 2.848 19.44 E 5979476.80 N 618904.89 E '-J 0.536 -8.23 705.96 4.770 72.230 633.66 705.15 1.388 26.13 E 5979478.36 N 618911.56 E 1.291 -13.11 800.13 5.740 85.940 727.44 798.93 0.15 N 34.56 E 5979480.03 N 618919.96 E 1.678 -18.99 897.43 6.730 92.030 824.16 895.65 0.29N 45.11 E 5979480.34 N 618930.51 E 1.222 -24.87 992.39 6.360 96.240 918.50 989.99 0.48 8 55.90 E 5979479.74 N 618941.31 E 0.638 -30.12 1 087.44 6.740 102.240 1012.93 1084.42 2.238 66.59 E 5979478.15 N 618952.02 E 0.823 -34.48 1183.63 7.830 123.300 1108.36 1179.85 7.038 77.58 E 5979473.53 N 618963.09 E 2.977 -36.47 1280.30 8.960 127.580 1204.00 1275.49 15.24 8 89.05 E 5979465.51 N 618974.69 E 1.335 -35.85 1376.53 8.790 136.590 1299.08 1370.57 25.15 8 100.04 E 5979455.77 N 618985.84 E 1.454 -33.55 1472.70 8.370 142.010 1394.17 1465.66 36.00 8 109.40 E 5979445.07 N 618995.37 E 0.947 -29.57 1567.87 9.550 135.350 1488.18 1559.67 47.088 119.21 E 5979434.15 N 619005.36 E 1.649 -25.64 1663.38 9.340 139.730 1582.40 1653.89 58.63 8 129.79 E 5979422.77 N 619016.12 E 0.784 -21.74 1758.44 5.830 133.930 1676.62 1748.11 67.87 8 138.26 E 5979413.67 N 619024.73 E 3.775 -18.62 1854.11 5.560 129.110 1771.81 1843.30 74.168 145.35 E 5979407.48 N 619031.92 E 0.574 -17.22 1950.67 5.680 129.560 1867.91 1939.40 80.16 8 152.67 E 5979401.61 N 619039.33 E 0.132 -16.19 2048.81 7.270 155.540 1965.44 2036.93 88.90 S 158.98 E 5979392.96 N 619045.79 E 3.355 -12.31 2142.36 9.970 182.650 2057.96 2129.45 102.39 8 161.06 E 5979379.51 N 619048.08 E 5.138 -2.15 2237.78 10.410 196.660 2151.89 2223.38 118.908 158.21 E 5979362.95 N 619045.49 E 2.631 13.24 -' 2333.87 11.720 205.000 2246.20 2317.69 136.07 8 151.59 E 5979345.69 N 619039.14 E 2.149 31.23 2430.35 14.940 208.890 2340.07 2411.56 155.84 8 141.44 E 5979325.75 N 619029.31 E 3.463 53.34 2526.35 19.890 209.330 2431.64 2503.13 180.93 8 127.46 E 5979300.45 N 619015.72 E 5.158 82.00 2622.52 26.590 211 .140 2519.96 2591.45 213.65 8 108.29 E 5979267.43 N 618997.08 E 7.006 119.88 2718.38 33.720 217.070 2602.81 2674.30 253.30 8 81.12 E 5979227.35 N 618970.53 E 8.053 167.93 2813.16 39.920 219.300 2678.65 2750.14 297.87 S 45.96 E 5979182.22 N 618936.09 E 6.691 224.47 2911.84 44.650 220.140 2751.64 2823.13 348.91 8 3.53E 5979130.52 N 618894.47 E 4.827 290.40 2936.20 44.330 217.880 2769.01 2840.50 362.178 7.22W 5979117.09 N 618883.94 E 6.633 307.37 3056.03 46.750 219.140 2852.94 2924.43 429.08 8 60.48 W 5979049.35 N 618831.75 E 2.154 392,51 3151.66 46.050 220.020 2918.89 2990.38 482.468 104.60 W 5978995.28 N 618788.48 E 0.990 461.32 ---- ----------------- 3 September, 2002 - 14:30 Page 20f5 DrillQllest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 5-215 - S-115 MWD Your Ref: API 500292310700 Job No. AKMW22131, Surveyed: 12 August, 2002 . BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) 3247.36 48.4 70 220.950 2983.83 3055.32 535.90 S 150.24 W 5978941.11 N 618743.69 E 2.627 531.01 3342.87 49.890 218.110 3046.27 3117.76 591.65 8 196.22 W 5978884.64 N 618698.60 E 2.697 602.82 3437.74 50.060 215.410 3107.29 3178.78 649.84 8 239.69 W 5978825.77 N 618656.06 E 2.187 675.30 - 3532.78 49.400 214.910 3168.72 3240.21 709.138 281.45 W 5978765.83 N 618615.25 E 0.802 747.77 3628.27 49.880 214.220 3230.56 3302.05 769.04 8 322.73 W 5978705.26 N 618574.93 E 0.746 820.51 3722.93 49.900 213.500 3291.55 3363.04 829.168 363.06 W 5978644.51 N 618535.55 E 0.582 892.90 3818.17 48.750 214.920 3353.62 3425.11 888.90 8 403.66 W 5978584.14 N 618495.90 E 1.654 965.11 3915.80 48.280 215.990 3418.30 3489.79 948.47 8 446.09 W 5978523.90 N 618454.43 E 0.952 1038.19 4009.15 47.530 217.010 3480.88 3552.37 1004.168 487.28 W 5978467.57 N 618414.12 E 1.141 1107.33 4106.09 47.040 216.940 3546.64 3618.13 1061.06 S 530.12 W 5978410.00 N 618372.19 E 0.508 1178.39 4203.07 46.310 217 .960 3613.18 3684.67 1117.078 573.02 W 5978353.31 N 618330.19 E 1.073 1248.74 4298.66 46.440 218.960 3679.13 3750.62 1171.25 8 616.05 W 5978298.46 N 618288.02 E 0.769 1317.63 4394.64 46.730 220.070 3745.10 3816.59 1225.03 8 660.42 W 5978243.98 N 618244.52 E 0.893 1386.90 4491.39 46.760 220.560 3811.39 3882.88 1278.768 706.00 W 5978189.53 N 618199.78 E 0.370 1456.81 4587.05 47.970 220.450 3876.18 3947.67 1332.27 8 751.71 W 5978135.30 N 618154.93 E 1.268 1526.59 4681.08 47.380 219.750 3939.50 4010.99 1385.44 8 796.49 W 5978081.42 N 618111.00 E 0.835 1595.59 4777.79 47.630 217.700 4004.83 4076.32 1441.078 841.10W 5978025.10 N 618067.29 E 1.584 1666.55 4872.91 47.850 217.900 4068.80 4140.29 1496.708 884.24 W 5977968.79 N 618025.03 E 0.279 1736.71 4970.60 47.1 00 217.000 4134.83 4206.32 1553.85 8 928.02 W 5977910.95 N 617982.16 E 1.025 1808.50 5066.20 48.130 217.160 4199.27 4270.76 1610.188 970.60 W 5977853.95 N 617940.48 E 1.084 1878.94 - 5161.55 47.340 216.650 4263.40 4334.89 1666.608 1012.97 W 5977796.86 N 617899.01 E 0.918 1949.34 5256.76 48.210 218.420 4327.39 4398.88 1722.50 8 1055.93 W 5977740.29 N 617856.95 E 1.652 2019.63 5353.12 49.080 217.740 4391.06 4462.55 1779.448 1100.54 W 5977682.65 N 617813.25 E 1.047 2091.68 5448.92 49.130 217.710 4453.78 4525.27 1836.728 1144.85 W 5977624.68 N 617769.85 E 0.057 2163.86 5544.34 48.840 217.770 4516.40 4587.89 1893.658 1188.91 W 5977567.05 N 617726.69 E 0.308 2235.62 5640.52 49.520 217.930 4579.27 4650.76 1951.13 8 1233.58 W 5977508.88 N 617682.95 E 0.718 2308.16 5737.10 48.880 217.990 4642.37 4713.86 2008.77 8 1278.55 W 5977450.53 N 617638.90 E 0.664 2381.00 5833.04 47.880 217.340 4706.09 4777.58 2095.54 8 1322.37 W 5977393.07 N 617595.98 E 1.159 2452.49 5928.98 47.280 216.720 4770.81 4842.30 2122.088 1365.03 W 5977335.86 N 617554.23 E 0.787 2523.15 6024.71 45.350 216.080 4836.93 4908.42 2177.79 S 1406.11 W 5977279.50 N 617514.03 E 2.073 2592.26 f 3 September, 2002 - 14:30 Page 30'5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . ... Survey Report for 8-215 - 8-115 MWD Your Ref: API 500292310700 Job No. AKMW22131, Surveyed: 12 August, 2002 BPXA North Slope Alaska PBU_WOA S Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6120.44 45.140 215.860 4904.33 4975.82 2232.81 S 1446.04 W 5977223.86 N 617474.98 E 0.273 2660.15 6216.57 44.780 215.530 4972.35 5043.84 2287.97 S 1485.67 W 5977168.07 N 617436.23 E 0.446 2728.01 "- 6312.39 4 7.150 216.710 5038.95 5110.44 2343.61 S 1526.29, W 5977111.80 N 617396.50 E 2.627 2796.79 6408.46 47.020 217.050 5104.37 5175.86 2399.89 S 1568.51 W 5977054.86 N 617355.18 E 0.292 2867.00 6504.84 48.480 216.220 5169.17 5240.66 2457.14 S 1611.08 W 5976996.94 N 617313.52 E 1.643 2938.20 6600.88 48.860 216.290 5232.59 5304.08 2515.29 S 1653.72 W 5976938.12 N 617271.80 E 0.399 3010.21 6696.61 48.360 216.520 5295.89 5367.38 2573.09 S 1696.35 W 5976879.64 N 617230.10 E 0.553 3081.90 6792.13 48.020 216.320 5359.57 5431.06 2630.38 S 1738.62 W 5976821.69 N 617188.75 E 0.389 3152.98 6861.02 47.960 216.760 5405.67 5477.16 2671.51 S 1769.09 W 5976780.09 N 617158.93 E 0.482 3204.08 6930.00 47.960 216.760 5451.87 5523,36 2712.55 S 1799.75 W 5976738.56 N 617128.92 E 0.000 3255.20 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertic31 Section is from Well and calculated along an Azimuth of 213.090° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6930.00ft., The Bottom Hole Displacement is 3255.31ft., in the Direction of 213.564° (True). '- -----_. - ------- --- 3 September, 2002 - 14:30 Page 4 0'5 DriTIQuest 2.00.08.005 North Slope Alaska Comments Measured Depth (ft) 6930.00 5523.36 Sperry-Sun Drilling Services Survey Report for S-215 - S-115 MWD Your Ref: API 500292310700 Job No. AKMW22131, Surveyed: 12 August, 2002 . BPXA PBU_WOA S Pad Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment '~-,c= 2712.55 S 1799.75 W Projected 8urvey Survey tool program for S-215 - S-115 MWD Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 434.00 3 September, 2002 - 14:30 0.00 433.82 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 434.00 6930.00 433.82 Tolerable Gyro (8-215 Gyro) 5523.36 MWD Magnetic (8-115 MWD) .~, ------- ----- Page 50'5 DrillQlIest 2.00.08.005 ) ) ¿;¡œ-/5LJ //IoSe¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 25, 2003 RE: MWDFormation Evaluation Logs S-215, AK-MW-22131 1 LDWG formatted Disc with verification listing. API#: 50-029-23107-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun DriUing 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: Sign~~ / RECEIVED APR 29 2003 Alaska Un ò; bas L.:ons. Comrn~ AnchOft!ce ,:,¡ Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well Job# Log Description Date S-114A ~Od -/Gj'i( S-215 aDa-IS,! 22534 SCMT 22525 SCMT 12/05/02 11/16/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. RECE\VED Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 DEC 20 2.002 Date Delivered: Ala..~a O~ & GaS ConS. Commission Anchorage 12/17/02 NO. 2616 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Aurora Color Sepia '~ CD BL 2 2 '~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Beth Receivdø- 6. O~ Changes from 8-215 Permit ) , Subject: Changes from S-215 Permit 201. .,. 1'5t.f Date: Fri, 2 Aug 2002 13:54:34 -0500 From: "Triolo, Mike T" <TrioloMT@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Crane, Lowell R" <CraneLR@BP.com> Winton, We have changed a couple of things from the permit stage and I wanted to let you know to make sure you were OK with them prior to spud. We should spud on Monday morning. No matter how hard you try to think of everything for the permit, there always seems to be one or two things that could be modified for the best. 1) We decided to conduct a LOT at surface casing shoe instead of a FIT to gather another formation strength data point. 2) We decided to run the bond log post rig instead of while the rig is over the well to save time and money. 3) We moved the WLEG depth up 90' MD which would now put the WLEG 140' MD above the top Ma sand. a. This would place the packer * 200' above the top Ma sand Thanks, Michael (Mik) Triolo Operations Drilling Engineer (GPB) Work: 564-5774 Cell: 240-8076 E-mail: triolomt@bp.com , " -) \ @ r=-;J Iff. <=¡ ,e @ ~ LnJ~ Lb ,..-;;) I ~' TONY KNOWLES, GOVERNOR A.11A.~IiA. OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit S-215i BP Exploration (Alaska), Inc. Pennit No: 202-154 Surface Location: 3276' NSL, 4563' WEL, Sec. 35, T12N, R12E, UM Bottomho1e Location: 676' NSL, 981' WEL, Sec. 34, T12N, R12E, UM Dear Mr. Crane: Enclosed is the approved application forpennit 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 pennit 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 perfonned 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, ~ ~~ cam~chsli Taylor Chair BY ORDER OF THE COMMISSION DATED this~\day of July, 2002 cc: Department ofFish & Game, Habitat"Section w/o encl. Department of Environmental Conservation w/o encl. ALASKt:, STATE OF ALASKA ..~ JL AND GAS CONSERVATION COMf\.. }SION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan KBE = 72.101 Prudhoe Bay Field I Polaris 6. Property Designation Pool (Undefined) ADL 028258 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / S-215i 9. Approximate spud date 08/06/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 69131 MD I 55221 TVD 17. Anticipated pressure {see 2g,1\AC 25.035 (e) (2)} 480 Maximum surface 1846 psiQ,' At total depth (TVD) 53151 12377 psig Setting Depth TQD Bottom MD TVD MD TVD 341 341 1141 114' 341 34' 3028' 28921 341 341 69131 55221 VJ(;A 1/l1/hL :::W-. '7( z!7( ~ 1 a. Type of work II Drill 0 Redrill (J Re-Entry (J 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 32761 NSL, 45631 WEL, SEC. 35, T12N, R12E, UM At top of productive interval 976' NSL, 7541 WEL, SEC. 34, T12N, R12E, UM At total depth 676' NSL, 9811 WEL, SEC. 34, T12N, R12E, UM 12. Distanoe to nearest property line 13. Distance to nearest well /' ADL 028261,6761 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 3001 MD Maximum Hole Angle 18. Casin~ Program Specifications Size CasinQ WeiÇJht Grade CouDlina 20" x 34" 215.5# A53 Welded 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-M 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Hole 48" 12-1/4" 8-314" Lenç¡th 801 2994' 6879' Quantitv of Cement (include staae datay 260 sx Arctic Set (Approx.) 487 sx PF 'L', 201 sx Class IG' ,3i8'''sx Class IGI S'7 (/ id G,t- 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD R f'" ('"'t IC ¡\(ICD ~;\. k: " ,~, IL ~ ~J (, . .. true vertical .JUL 2.4 2002 Alaska Oil & Gas Cons. Gomm¡SSIOi Anchorage Perforation depth: measured 20. Attachments II Filing Fee 0 Property Plat (J BOP Sketch (J Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot (J Refraction Analysis (J Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Micha riolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th fore i 9 is true a~~ct to the best of my ~nowl~~ge . Signed Lowell CraIe ~ Titlt €cnlor Drilling Engineer Date 7- ? '1-02- ,~$siÔO·,~·,Only~::;: .:);.,';- "'..:, Permit Number API Number. ? 3/ "-7 AP~~~al~. e'.l. See cover letter -2. 02. - / s- 5' 50- 0 2.. 9 - <.. CJ /" I .'XJ () 11 \ for other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log R quired 0 Yes I8J No Hydrogen Sulfide Measures 0 Yes .EI No Directional Survey Required gJ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T€s {- ß~·pe. (.e:; 4'~ed~B r~ . MIT) c.~ct- q,lú.lJ, tv¡ kq ""t¡4...i;-..eJ,_ vngmal Sign Y by dfder of l l ð 1 /)J\ I Approved By G~mmy Oechsli T~~.r~N' .. j\ Jhe commission Date . " 1.) p~ Form 10-401 Rev. 12-01-85 U ì~\ i lJ ~ ~ '.! ¡-\ L_ Submit In Triplicate ) Well Plan Summary ·:Well··Nam:é::';J..::S-2l.5i:·.·::: Greater Prudhoe Bay Polaris S-215i Permit -- ) . . '. '~'. ·1 ." .. I Type of Well (producer or injector): I USH Injector Surface Location: 3,2761 FSL, 4,5631 FEL, Sec. 35, T12N, R12E X = 618,885.41 Y = 5,979,479.33 4,3031 FNL, 7541 FE!..., Sec. 34, T12N, R12E X =617,454.48 Y = 5,977,156.52 Z = 5,042' TVDss 4,6041 FNL, 981' FEL, Sec. 34, T12N, R12E X = 617,232.20 Y = 5,976,852.25 Z = 5,387' TVDss S-112i Target Start: S-112i Target End: I AFE Number: I PLD5M1024 / I Rig: I Doyon 14 / I Estimated Start Date: I Aug 6m 2002 I Operating days to complete: 112.00 MD /6,913' I I TVDrkb: TD 15,522' I I Max Inc. I 47° I I KBE I 72.10' Well Design: USH Grassroots Schrader Injector. 4-%" TCII Completion. Current Well Information General Well Name: API Number: Well Type: Current Status: BHP: BHT: S-215i 50-029- ????? Development - Polaris Schrader Injector New well, 20" X 34" insulated conductor 2,377 psi @ 5,315' TVDss (8.6 ppg EfV,1W). Normal pressure gradient. 100°F @ 5,315' TVDss Estimated ./ Mechanical Condition S-112i: Doyon 14: Conductor: Cellar Box above MSL = 38.1' KB I MSL = 34.0' 20" X 34", 215.5 Ibltt, A53 ERW set at 114' RKB Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: 9,058 mstb 1,100 bwpd 950 bwpd Final 7/24/02 Materials Needed ) Suñace Casing: 3,100' 1 each 1 each 25 each 1 assembly 1 each 1 lot Intermediate Casing: 7,000' 1 each 95 each 2 lots 2 each 2 each L-80 Completion: 6,000' 1 each 1 each 3 each 1 each 1 each 1 each 1 each Drillina Proaram Overview Surface and Anti-Collision Issues Greater Prudhoe Bay Polaris S-215i Permit ) 9-%", 40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%",40#, BTC Type TAM Port Collar 9-%" x 12 14" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" TAM Port Collar 9-%" casing pups 5', 10', 20'. 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" x 8 14" Rigid Straight Blade Centralizers 7" casing pups 5', 10', 20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 4 Y2" 12.75Ib/ft, L-80, TCII tubing Baker PRM Production Packer 7" X 4-Y2" Halliburton XN-Nipple (3.725" 10) Halliburton X-Nipple (3.813" 10) 11" X 4-%" FMC tubing hanger 4-1/16", 5m Cameron Tree 4-%" x 1" KBG-2 GLM 4-%" WLEG /'" Suñace Shut-in Wells: S-15 may need to be shut-in for the rig move on and off S-215i. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: Well Name . Ctr-Ctr Distance S-15 18.20-ft S-216 86.36-ft Reference MD 596.00-ft 3107.78-ft Mud Program 12 'IA" Suñace Hole Mud Properties: Interval! Density (ppg) Funnel vis Initial 8.6 - 8.8 300 Base Perm 8.8 - 9.6 /' 200 - 300 Interval TD 9.3 - 9.6 200 8 %" Intermediate Hole Mud Properties: Interval! Density (ppg) Funnel vis Initial 8.6 - 9.0 45 - 55 Ugnu / Schrader 9.5 I 45 - 55 YP 50 - 70 30 - 60 25 - 48 YP 21 - 28 21 - 28 Allowable'Deviation ' . . Precautionary Comment . 4.16-ft Use Traveling Cylinder (Gyro) 17.24-ft Use Traveling Cylinder I Spud - Freshwater Mud (PHPA) Tauo PH Plastic Vis FL 10 - 18 8.5 - 9.5 20 - 45 15 - 20 8 - 16 8.5 - 9.5 20 - 40 < 15 9 - 14 8.5 - 9.5 14 - 20 < 10 Freshwater Mud (PHPA) PH: 8.5 - 9.5 Tauo PV API Filtrate MBT 3 - 6 9 - 14 < 5 < 20 3 - 6 11 - 15 < 5 < 20 2 Final Approved Greater Prudhoe Bay Polaris S-215i Permit ) ) Formation Markers .' '~ . . Formation Tops· .. ,,:,FtTVDs8: ···FtMD:··' ,.,;Ft-TVD :' . Pore· psL:' EMW(ppaY" . Hydrocarbons.·, Base Permafrost 1,900 1,984 1,972 850 8.60 No SV5 2,150 2,236 2,222 950 8.62 No SV4 2,350 2,444 2,422 1,040 8.62 Poss. Hydrates SV3 2,720 2,891 2,792 1,200 8.48 No SV2 2,860 3,083 2,932 1,270 8.54 No SV1 3,200 3,581 3,272 1,550 9.31 No UG4 3,550 4,099 3,622 1,700 9.29 . Yes UG4A 3,600 4,173 3,672 1,940 10.48**/ Yes UG3 3,870 4,573 3,942 1,820 8.97 Yes q.C Ma (Top Schrader Bluff) 4,660 5,743 4,732 2,090 8.6 Yes Mb1 4,700 5,802 4,772 2,110 8.6 Yes Mb2 4,760 5,891 4,832 2,135 8.6 Yes Mc 4,795 5,943 4,867 2,150 8.6 Yes Schrader Buff Na 4,855 6,031 4,927 2,175 8.6 Yes Nb 4,875 6,061 4,947 2,180 8.6 Yes Nc 4,910 6,113 4,982 2,190 8.6 Yes Schrader Bluff OA 4,970 6,202 5,042 2,210 8.6 Yes OBa 5,030 6,291 5,102 2,220 8.5 Yes Obb 5,065 6,343 5,137 2,230 8.5 Yes OBc 5,120 6,424 5,192 2,245 8.4 Yes OBd 5,165 6,491 5,237 2,260 8.4 Yes OBe 5,220 6,572 5,292 2,280 8.4 Yes Obf 5,270 6,646 5,342 2,295 8.4 Yes OBf (Base Schrader) 5,315 6,713 5,387 2,310 8.4 Yes TD 5,450 6,913 5,522 2,345 8.5 No **Very unlikely. Only one well in pad history took kick 5-200** CasinglTubing Program Tbg MD . MDITVDrkb 48" 20" X 34" 215.5# A53 Welded 80' 34' / 34' 114' / 114' 12-1A" 9-%" 40# L-80 BTC 2,994' 34' / 34' 3,028' / 2,892' 8-%" 7" 26# L-80 BTC-M 6,879' 34' / 34' 6,913' / 5,522' Tubing 4 'V2" 12.75# L-, TCII 5,666' 34' / 34' 5,700' /4,694' Cement Calculations Casin~ Size I 9-%-in 40-lb/ft L -80 BTC - Single Stage Basis I 215% excess over gauge hole in permafrost interval, 300/0 excess over gauge hole below permafrost Total Cement Volume: Tam Port collar located at 1,000' as a contingency for cement to surface Wash 10 bbls CW100 Spacer 75 bbls of Viscosified Spacer weighted to 10.20 ppg Lead 385 bbls (487 sks) 10.7 Ib/gal Permafrost L cement - 4.44 cuft/sk Tail 42 bbls (201 sks) 15.8 Ib/gal Class G + adds - 1.17 cuft/sk Temp I BHST ::::: 50° F from SOR, BHCT 75° F estimated by Dowell .-/ /' In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. 3 Fi nal Approved '} Greater Prudhoe Bay Polaris S-215i Permit ) Casin~ Size 17" 26 Ib/tt L-80 BTC-M - Single Stage Basis I 30% excess - TOC: 500' MD above the UG4 sands (planned TUG4: 4,098' MD) => 3,598' MD Total Cement Volume: Wash 40 bbls CW1 00 Spacer bbls of Viscosified Spacer (Mudpush XL Design) Weighted to 10.4 ppg Tail 15.8 Class G - 1.16 cuft/sk Temp F from SOR, BHCT 80° F estimated by Dowell o \tJbÅ- ./' 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,028' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar. c) This centralizer program is subject to change pending actual hole conditions. 7" String Centralizer Placement a) Place 2 centralizers rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints (see illustration at the end of the well plan) . b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 3,598' MD (500' MD above UG4 sand). Zonal isolation with cement is required across the UG4 sands. The centralizer program is subject to change pending modeling and hole conditions. Bit Recommendations Surface 12-%" 0' - 3,028' Hughes MXC-1 Hughes DP1012 2x20 1x14 1x12 8x12 Interm. 8-3,4 3,028' - 6,913' Survey and Logging Program 12-1A" Hole Section: Open Hole: Cased hole: 8-%" Hole Section: Cased Hole: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) MWD I GR (Utilize 6-%" tools and collars to save time) None MWD I GR I Res I Den I Neu I PWD (Den I Neu recorded only) USIT Bond Log Motors and Required Doglegs BHA No~ 1 . . Motor Size:and Motor Required 8" Sperrydrill 6/7, 4 stg Mud Motor, 1.5° adj. with 12" screw on stabilizer 7" Sperrydrill 7/8, 6 stg FTC Performanc motor, with 1.22° adj. with 8.5" concentric sleeve Flow Rate.. 400 - 650 gpm 500 - 600 gpm ,RPMs 40-60 . Required Doglegs 1.5°- 2.5°/100' initial build 6°/100' final build 2°/100' nudge Hold 4 7° Tangent 2 60-120 4 Final Approved Well Control ) Greater Prudhoe Bay Polaris S-215i Permit ) Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. /" Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 2,377 psi @ 5,315' TVDss - Schrader · Maximum surface pressure: 1,846 psi @ surface /' (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4,000 psi (the 7" casing will be tested to 4,000 psi) / Estimated 8.6 ppg Seawater / 6.8 ppg Diesel Planned ¡:JOPE"Test Pres~ 4,000/250 psi Rams & Valves / 2,500/250 psi Annular Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class " wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 5 Final Approved ) Drillina Hazards and Continaencies Greater Prudhoe Bay Polaris S-215i Permit ) POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The 8chrader in this fault block is expected to be normal pressured at 8.6 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and' Shallow gas A. Hydrates have not been a significant issue thus far on S-Pad during the recent drilling of 8-108, S-110, S- 113, and S-112i however there is always a potential. III. Lost Circulation/Breathing A. Lost circulation is unlikely. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail cement slurry to 500' MD above the UG4 sand -3,550' MD. C. The Kick Tolerance for the surface casing is 51.7 bbls with 9.5 ppg' mud, 11.8 ppg FIT, and an 8.6 ppg pore pressure. If the FIT is less then 11.8 ppg EMW, then the kick tolerance will be < 50 bbls. D. There is a slim potential to take a kick in the UG4 sand. On S-200 a 4 bbl influx was taken while drilling this interval. The influx was a 10.1 ppg EMW. Taking this into account, the kick tolerance at the UG4 sand would be 25.4 bbls with 9.0 ppg mud, 12.6 ppg FIT, and a 10.1 ppg pore pressure. In order to get a 50 bbl kick tolerance, we would need a 13.6 ppg FIT. E. Integrity Testing . .. .. .' .... , '.'..,.'.'....'.::. .",,:...:::. ·:6<·:·ß'C:·'··'¡'·:·"'·'i.t········, ':¡;::;;r'J~$~:.'~ø. .n'iif: 9-%-in shoe .. ......::u:::::1i:i,':l:·l::,::j:::f.::':~:::'i':' .,:mt$Î,:"aïì:)th: i::::;,;'::·.::·:,·;.;"::::';';·'::'::') 20-ft minimum from 9-%--in shoe iM·:J,::I:t'·¡ii:IÎ~tI,týPI:n"¡':::;"'EI\I1'W.:~ll:)ltîÎÎì}::.,::::, FIT 11.8 minimum V. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues across the Ugnu. Centralizers will be run to mitigate. VI. Hydrogen Sulfide / A. S Pad is not designated as an H2S site, however 8tandard Operating Procedures for H2S precautions should be followed at all times. Recent H28 data from the pad is as follows: B. Adjacent producers at Surface: a. 8-17 less than 40 ppm b. 8-40 less than 60 ppm C. Adjacent producers at TD: a. 8-216 0 ppm b. 8-213 0 ppm D. The maximum level of H28 recently recorded on the pad was -80 ppm from 8-26. The maximum level ever recorded on the pad was -130 ppm from 8-32 back in 3/2001. Both of these wells are Ivishak producers while the adjacent producers at TD and subject well are Schrader wells. VII. Faults A. No faults are planned to be crossed CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Final Approved , Greater Prudhoe Bay Polaris S-215i Permit ) ') Drill and Complete Procedure Summary Pre-Rig Work: A 20" conductor will be required. 1. Survey the site and set a 20" conductor to 80' below GL. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells on 15' centers for the rig move and simops production. Rig Operations: I' / / 1. MIRU Doyon 14. / 2. Nipple up diverter spool and function test diverter if required. PU 5" DP as required and stand back in derrick. 3. MU 12-%" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,028'. The actual surface hole TD will be +/-100' TVD below the top of the SV3 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port collar or stage tool will be run in the casing string to allow secondary cementing, in the event cement is not ciçculated to surface during primary cementing operations. 4/)00 ~Iit 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to.,3.;8Ot) psi. ",/ 6. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu/PWD and RIHto float collar. Test the 9-%" casing to 3,500 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace oveTfo new 9.0 ppg mud / 8. Drill new formation to 20' below 9-%" shoe and perform FIT (minimum 11.8 ppg EMW). 9. Drill ahead to the base of Schrader formation to approximately 6,913' MD 10. Perform wiper trip and condition the hole for casing. 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with seawater during cementing operations and freeze protect the 7" x 9-%" annulus as required. 12. LD 5" DP /' 13. Run e-line cement evaluation log through the 7" casing for cement evaluation and AOGCC requirements 14. Run the 4-%" 12.75#, L-80 TCII completion assembly. Test the production casing/tubing annulus and tubing to 4,000 psi each. 15. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 16. Freeze protect the well to ....2,200' and secure the well. 17. Rig down and move off. Post-Riq Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the RP shear with a dummy GL V. 7 Final Approved ) Greater Prudhoe Bay Polaris S-215i Permit ........,,'''''''''_.....,~'''''''''''' "."..,.,,,,,,,,,,,,,,,,......, )""",,,,,,,,,,,,, """''''''''''''''''''''''''''''''''''''''''''''.''."'' ~·,'M..'''''''''''''''''''''"",,,,,,,",, "11I:I:illmll.,. ·-:II'._IIIII:lamu' _ "nlml_II(:cmaln_-lmlUlm!mllo'~m:I:_I_:I,mUU,IIU,mr _1:~'lIlmm~''I( _IWUIII,,/IIllam~:lmI1,11rlll,U,I,:I,U:ml1rr""'m',I.mlmCr>l.,!lUtUlIIlI,rmllmlnlIl>CIIIUWIIIIIUlIIIII1I1,IIIIo!,llUliUlaa- Job 1: MIRU Hazards and Contingencies: )0> Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL onW-212i). ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ The adjacent well, S-15, is approximately 20' from the 8-215 conductor. No wells are required to be shut in. ~::_lmllmCla:I~D:III:,m,:n!I,Wmllml~III:lllaDwmlmlmCIIIIlm:lmaC~,r,r:m,mmma:11_:aalmrmUI'~la,mal,mlll:ID::mCIIImlllll:mlm:lma:mm":¡¡:~:II:m;,lmrlUmacmll:,mllallll:m,umml;,m,IIIII~I:II:IC:I_Immlm~!Io'mmC~lltmammll:_Iu:rllmDcmmm,:::am;IWI::lml,mc:mal,:I:mm,II,I!:_:_'II,nml,II:W:~IIC:,ml,a~ma,I,\~I.mlamau.U:aumUlmlllla~.m-' _aaamm:a"'~aal~.....\t,~~mll_ " '~:'!!~1111:_, -:Immlal:* Job 2: Dri1l12W1 11 Surface Hole Hazards and Contingencies: ~ At S-Pad, no significant surface hole drilling problems have been identified. Minor tight hole has been encountered in the clay sections below the permafrost, some lost circulation thought to be in conjunction with the tight hole, possible packing off has been encountered. ,--'-';.....,n-, HI_ _1_1_U:lal:;,:' _ _lm!l1l11Im-nllnltnmmll!!n'_I_1 _-r:nllllla- _ !nlmln:I':-1111:11'''': _ ,_nl! _:llrT'I:la:II;.I:-1 mL _~WTITlm;.l: ,I: _~mm!lL!I:-'-mlmm':m_W-IIIlln:¡t 'T_I,I'I)/'I- _~"mm_~II::II:II:m- _1:-'111111:11 11'1: ¡(11:I:nn~:I_--:lnl:lalmlft Job3: Install Surface Casinø Hazards and Contingencies: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV3 sands to ensure wellbore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to insure circulation is attained at TD at the desired cementing rates without losses. ~ Casing drift: 9-%" special drift casing is being used (8.75" drift required). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-%" bit, Le. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 2150/0 excess in the permafrost and 30% excess below the permafrost. As we will be downsizing the nozzles on the bit this may increase hole erosion slightly due to the extra nozzle velocity. A TAM Port collar will be placed at 1 ,OOO-ft MD. ~ Stuck Pipe While Running Casing: Several wells on S-Pad have experienced stuck pipe while running casing. Spend as much time as needed to ensure the wellbore is clean prior to POOH with the drilling BHA. ~ Losses during cement job: At S-Pad lost circulation has been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV3 sands is 12.5-lb/gal EMW, however the SV sands above this shale may not be so forgiving. Follow the Dowell recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. 8 Final Approved " Greater Prudhoe Bay Polaris S-215i Permit ") 'm,ml!~!':,~mmIIIII,IIIIIU_'II!UI:W!lmllml,lan,almllll,'T- _ "lm~_aa,I~::,lmmaUlIIIIII~,IIIIIII,'D';IaIIIIIII.lII"III"'~II,IIIIIIUIU:;-:1111' alUum.,mD;:I,: .1,. ,.,II:I,II,IIIIIIII;I::II:III!1I11111::1I11(1:,I. _maaalUII',rIWIII,U,:'_I:a-- '::IIIW'.. --I;;':I_;;;';U:O:" .. 'm;¡I';,:,:I;rmmmmlla:rlll,III~!I':.:mla!III_I\OI,:IDa!I,n:mll:l~:,IIIr,DIII,n:'al:-'l,"aal,rl,n""I:-!I,amr,wa,llI1,rmm_I:I;-,IICI1,11111' Job 4: Drill 8%" Production Hole Hazards and Contingencies: ~ Gas cut mud/well flowing has been observed in the Ugnu (3,520' TVDss). ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.8 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the expected Schrader reservoir pressure of 8.6 ppg and a 9.5 ppg mud, an 11.8 ppg leak-off will provide just over 50 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.8 ppg. Based upon off-set drilling data on S-Pad, a minimum leak-off of 12.5 ppg is expected at the 9-%" shoe and will provide -25 bbls of kick tolerance if an influx of 10.1 ppg EMW was taken in the UG4 interval. It will be more important on this well to conduct extra flow checks until the 7" casing is landed and cemented due to the possible smaller kick tolerance. 1:~'mmlla'I-:I_ --I---llllIlIm:II-:I. --,:mll-Illml'. .1 Ulllllla- .m,::mmllllllr- .1111. _1'lnHlIIIUU"!IUUwn:IllIliU_ _~LTilmHl::aLnrmn1I1!mlmml: rUmUOOI!1II11WU!WIILwnm:mmllmum:uml1lmmlt_I':IIITllllllm:llllllllllllrm::u--:V:WIIUiI;O »'I'!IIIII--;nllU-- _T/m:mlllmm: Job 6: Install 7" Production CasinQ Hazards and Contingencies: ~ Tight hole, packing off and lost circulation have been experienced while running casing though this interval. Good hole cleaning and mud conditioning are required for running this string. ~ Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ Cement Job: It is imperative to achieve a good cement job on this well due to the oil in the Ugnu sands. At this location the Schrader interval is expected to have oil therefore, good zonal isolation of this sand is imperative to meeting the AOGCC regulations for this well. Reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job across the Ugnu sands. ~l,Iml_. _~'-lmr'-~lu;.r;III;-.... . --¡-I-' :;-.m.U.l.l~~I¡.I:ml.l.lI;¡C)-II,IAllmmU". --I/!:m:)o:ou).:' -:~-:. :.n:.I.I~ml;II,II-. ('.~II;-"U:·;~:JIIJI:~,.",,,.,"~!h"Vv""'-· .mll;;I¡I::I;......'-¡-. -:-.l--Ult~;I~I~;- . -~l,Immlll:m.I-.. . ~;II.¡U-I:I Job 12: Run Completion Hazards and Contingencies: Reference RP: .:. 'Completion Design and Running' RP (1,\I,\I,;;,.(~I,l.IJ,~-.I,I.;;,I,I,IIß.-,\-:, ,(.U,'I,~- '~A-;"-",;,'I,~.~:o,.wm .-,' .,;, ,,¡,I~w~ ,·,·,...,,·,';;"I,I,I,I'-'-,-'-,~m;~,lm\l.I,rJ,I,\I,I,I,II!,:,'I):\,<I;"I,'I,\1;"1.1.1.11.I. ,)n-,;..~-.\I,I,\'I,\r;"I,I..;,IA"r,l.I,õi:,\I~-AI,\I¡,:J.\II,:,;",A. ,-:I,:.I.I,\-.I.I.\I.I-I,\'I.J,'I,\I)~,I.lI,\-'-I,I,\I,II.\I.¡.I.IIA~;1!'-~"'I}.:,'1,U.I--ß-,l.:.lI)I,;<:"I,I,IMWV~I;.I,IIAr;'4,1,I1,¡IW.l.-,'-I;\:¡1,\1;,q,;AI.;;,\\I,\\I,Ulmm.'I:II.l.DJ.In:,:,:.-,'-,II,I:),I.I:,'I.O.I,';~a,..;,I,\"I).::-.l.;,;AAI,I,I,l.I¡I,\I,Uml,I.J.:A-¡fllJU:.\IAIAI.I.lII,II.lI: "r,\~'I"lm~.lÿ.~AI,:-m,I)IJ.:n-,'-,"II,'I.I.I,I.:.lI,;~'I,;I¡IÞ.,;;.I.)I,'I.llml,;,)'~\I.I..l-lWAI.l.O~ Job 13: ND/NU/Release RiQ Hazards and Contingencies: ~ Diesel will be used to freeze protect the well. The diesel flash point Is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. 9 Final Approved ) S-215i Proposed Completion ') ~ l TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head wIT' mandrel hanger & packoff 11" x 11", 5M I tbg spool wI 11" x 4-1/2" tubing hanger 11" X4-1/16" Adaptor Flange Cellar Elevation = 38.1' Doyon 14 RKB = 72.1' 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 1141 ~ TAM Port Collar 11,000' 1 ~ 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2,200' TVD I 9-5/8", 40 Hlft, L-80, BTC 13,028' I j ~ Cameo gas lift mandrel 4-1/2" x 1" KBG2 I 3,200' TVD I With RP Shear Valve pinned to 2,500 4-1/2", 12.75 I bItt, L-80, TCII Coupling 00: 4.932" OrifUIO: 3.833"/3.958" 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7-5/8" x 4-1/2" Baker '5-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. n 7" Short Joint & RA Tag < Top M-$and _I -5,743' MD - 4-1/2" WireLine Entry Guide .....50' MD above the M-Sand 5,692' MD / Top O-Sand -6,202' MD ~ 7", PBTD 6,833' MD 7", 26 #/ft, L80, BTC-Mod 6,913' MD Date 7/24/02 Rev By Comments Mik T Proposed Completion POLARIS WELL: S-215i API NO: 50-029- BPX Polaris Field Plan: S-215i WP07 (S-215/Plan S·2 Date: 7123/2002 Date: Date: Created By: Ken Allen Checked: Reviewed: SURVEY PROGRAM DepthFm DepthTo ~/PIan Tool 34.00 900.00 Planned: S·215; WP07 VI CB-GYRO-SS 900.00 6912,77 Planned: 50215; WP07 VI MWD+IFR+MS REFERENCE INFORMA 1l0N Well Ceo<re: 50215. True North 72.111 72.10 SIoI- (O,OON,O.OOE) 72.10' 72.10 Minimwn 0naM'e Co-ordioate (NIE) Reference: Vertical (lVD) Reference: Section (VS) Reference: Measured Depth Refeteoce: CalcoJation Method: COMPANY DETAILS BP Amoco Calculation Method: Minim.." 0nahI'e ~~= ~~W¿'~Nonh Error Surface: Elliptical + Casing WamÚ!l Method: Rules Based bp WELL DETAILS Nan» +NI-S +£I-W NoItbing Easting Latitude Loogitude Slot 943.80 597947933 618885.41 70'21'09328N 149"02'04.751!W NlA TARGET DETAILS Easting Shape 619065,00 PoIygoo 616570.00 Polygon 616240.00 Polygoo 617454,48 PoIygoo 61723220 Circle (Radius: 100) Nonhing 5979600.00 5982620.00 5982620.00 597715652 5976852.25 +F1-W 18150 -2265.47 -259S,46 -1467.13 -1694.83 +NI-S 117.81 317728 3182.52 2300.0 I 2600.13 1VD 2187.10 3237.10 3942.10 5042.10 5387.10 Name S-215 SVI S-215OO3 502150A 50215 Base OB Size 9.625 7.000 CASING DEf AILS MD Name 95/8' 7" ,'1I2!UI 6912.76 o 5 TVD 2892. 5522. No. MD. .IOOTVD MD,49<19('T\'D IOf)' 5 5tl!HI I SIJn D, S!"n [ Jà ,// - -' Target S-2150A VSec 0.00 0.00 -1.91 -21.03 -32.40 -26.56 -21.23 -13.43 -0.45 28.74 261.87 411.41 567.43 2728.20 3104.22 3251.42 TFace 0.00 0.00 90.00 0.00 100.58 0.00 160.00 0.00 63.99 63.98 14.82 0.00 0.01 0.00 0.00 0.00 DLeg 0.00 0.00 1.00 1.50 1.50 0.00 2.00 0.00 4.00 5.00 5.90 0.00 2.00 0.00 0.00 0.00 +F1-W 0.00 0.00 3.49 38.34 89.07 127.21 144.74 156.97 161.27 153.04 21.78 -68.53 -162.76 -1467.73 -1694.82 -1783.72 SECTION DErAILS +N/-S 0.00 0.00 0.00 0.00 -19.70 -51.69 -69.58 -86.93 -105.29 -134.79 -327.50 -447.10 -571.88 -2300.01 -2600.74 -2718.46 TVD 14.00 \(11).00 J'N.96 !NX.26 ~j;"i.70 t.'III.OO 11\1111.00 ~!I~ ~.OO ~17U4 ~ 1~(.47 :' ìJ "i.00 :'I(I"i.OO ""'1.58 "'J2.1O ~ \x7.10 5~:2.15 Azi 0.00 0.00 90.00 90.00 130.00 130.00 144.84 144.84 178.88 206.65 217.06 217.06 217.06 217.06 217.06 217.06 Inc 0.00 0.00 2.00 8.00 9.00 9.00 5.39 5.39 9.66 14.58 43.13 43.13 47.53 47.53 47.53 47.53 MD 34.00 300.00 500.00 900.00 1291.42 1609.64 1811.24 2037.24 2187.24 2337.24 2826.75 3045.98 3265.91 6201.85 6712.77 6912.77 Sec I 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 MDPath 1984.11 2236.39 2443.94 2891.29 3083.34 3580.63 4098.95 4172.99 4572.84 5742.76 5802.00 5890.86 5942.69 6031.54 6061.16 6112.99 6201.85 6290.70 6342.54 6423.99 6490.63 6572.08 6646.12 6712.77 TVDPalh 10 10 In HI HI In Iu 10 10 10 HI IU In In 10 In IU In In In In 10 IU III 11)72. 2222. 2422. 27Q2. 29-'2. 3272. 3h22. 3t.72. 3'142. 4732. 4772 4832. 4:0<67. 4927. 4')47. 4982. 5042. 5102. 51.n. 51n. 52 J7. 5N2. 5,'42. 53R7. No. I 2 .' 4 5 6 7 8 'l In II 12 U 14 15 It. 17 18 19 20 21 22 2.' 24 ~85.7' TVD lóOO'1VD 037 24' MD. 2n251 \'D 8724' MD. 217J.74'1VD 37 ]J' MD, ]3]0 4'T1VD ]4' MD, I ROO' TVD I (.(IQ.M' MD. 91.42' MD. Q/IOO' 2/1(,r.. R 4 / ~" Sun Do B.rcnn'f~~)(;~/ Sian [I, 1/ I ~ :!C"," D, SV5 \-(t1' -SV.J _:\'~t." \,1 rf. /" nd DI $IJn D, f"d D, g" ./ ,/ ~ ,/ o - - Æ ~ o o ~ 2700 .<: i5. Ö "N '1: -> 2 ¡- 900 800 .----' 274~'1V[ 'SVT ~,,/ Sbr1 Dlr 2, . T . 3l145.Q8' MD. 2905'1 VD 'i:' 'l ~t8·· .1000 ., fnd D" . 31b5 Ql' MD. 3059 ~R· T\'D S~ ~ 5\7\ ';; roRMA TION TOP DErAILS Fonnation B.PennatTost SV5 SV4 SV3 SV2 SVl UG4 UG4A UG3 MalSchrader Mbl Mb2 Mc Na Nb Nc OA Sand OBa OBb OBc OBd OBe OBf OBfbase X]b 75' MD. End Di .~~ LlG4 - lIG''\ UGJ ~~' ___ ,. , , >J. ~Ol.ll , '" M3/SchI"Jd V MÞ2 ==~~~~~Bd '-ÖBf base All TVD depths are ssTVD plus 72.1'for RKBE. - 3600 o 7' !~ ""1ft I I (,912.17' ~ID. 2700 1 ubi Dt:plh 900 1800 Vertical Section at 213.270 [900ft/in] --.-........-- - - - o - 4500 5400 Plan: S·2ISi WP07 (S-2ISlPlan S-2 CreaIed By: Ken Allen Date: 7/23/2002 SURVEY PROGRAM Depth Fm Depth To SmoeylPlan Tool 34.00 900.00 PIamed: 5021Si WP07 VI CB-<JYRO-SS 900.00 6912.71 PIamed: 5021Si WP07 VI MWD+IFR+MS Narœ +NI-S +EI-W 50215 -1390.36 943.J1O Dale: Date: Checked: Reviewed: WElL DETAILS lIb1Iúng Easting Laâ<tde 5919479.3 618885.41 70"21'09.328N REFERENCE INFORMA 110N CD-ordinate (N1E) Reference: Wen Centre: 5021S, Trœ North Vertical (lVD) Reference: 72.111 72.10 Section (VS) Reference: SIoI- (O.OON,O.ooE) M~~~= ~~IÐl~ Y' aJMPANY DETAILS BP Amoco Cokul1tioo Method: MinimlÐl Oøvanre ~ =: ~S;;V¿;iOOer North Enol' s...làœ: ElIipücaI + Casing W.rniJ1l Method: Rules Baxd ö Slo( MIA TARGET DETAILS Narœ lVD +NI-S +EI-W Northing Euting Shape 50215 SVS 2187.10 111.81 18150 S979600.00 61906S.00 PolygOll 50215 SVI 3237./0 317728 -2265.47 5982620.00 616S70.00 PoIY8on S-215 003 3942.10 3182.52 -2595.46 5982620.00 616240,00 PolygOll S-2150A 5042.10 -2300.01 -1467.73 5971156.52 617454.48 PoIyg"" 5021 S Base OBr 5387.10 -2600.73 -1694.83 5976852.25 61723220 Cin:1e (Radius: 100) SECTION DErAILS See MD Ine Azi TVD +N/-S +F1-W DLeg TF ace VSee Target 1 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 500.00 2.00 90.00 499.96 0.00 3.49 1.00 90.00 -1.91 4 900.00 8.00 90.00 898.26 0.00 38.34 1.50 0.00 -21.03 5 1291.42 9.00 130.00 1285.70 -19.70 89.07 1.50 100.58 -32.40 -- 6 1609.64 9.00 130.00 1600.00 -51.69 127.21 0.00 0.00 -26.56 7 1811.24 5.39 144.84 1800.00 -69.58 144.74 2.00 160.00 -21.23 8 2037.24 5.39 144.84 2025.00 -86.93 156.97 0.00 0.00 -13.43 9 2187.24 9.66 178.88 2173.74 -105.29 161.27 4.00 63.99 -0.45 10 2337.24 14.58 206.65 2320.47 -134.79 153.04 5,00 63.98 28.74 II 2826.75 43.13 217.06 2745.00 -327.50 21.78 /5.90 14.82 261.87 12 3045.98 43.13 217.06 2905.00 -447.10 -68.53 0.00 0.00 411.41 13 3265.91 47.53 217.06 3059.58 -571.88 -162.76 2.00 0.01 567.43 14 6201.85 47.53 217.06 5042.10 -2300.01 -1467.73 0.00 0.00 2728.20 S-2150A 15 6712.77 47.53 217.06 5387.10 -2600.74 -1694.82 0.00 0.00 3104.22 16 6912.77 47.53 217.06 5522.15 -2718.46 -1783.72 0.00 0.00 3251.42 Loogittd. 149"02'04.7S8W 95~rëonf. MD, 3059.58' TVD art Dir 5.9/100' 2337.24' MD, 2320.47'TVD Start Dir 5/100' ,2187.24' MD, 2173.74'TVD Start Dir 4/1(0': 2037.24' MD, 2025'TVD End Oir : 1811.24' MD, 1800' TVD .....ß~~....nniï~:.M:l~YZ',~:..-:~~i.';.:~~:g'ß~f.W:f-~n ,.....:.....·1·-·.'.....:. St1ïtf"DifI:5nOOo-;',OO"MD:" 499.96'TVD·-·"- .. .. .-...- L..StartDir..U IOC ,.;:.JOÒ,..MD~JODTVD,~ _.. :" ¡,-- 500 ··..J~·Q~2b.l·-- ._......., .........,..... _ n ......,.....n._.__._. ,_...... ...._.n ._.. .. ..:~n1 ?5 :?&~~_t..~I?· 2745' TVD . . . .. .. ·.~t3:t1l?ir.[?fld.O'n:Jº~~~'?~ '.¥P, __".n. . ... ,. .. F1~ 600- o ---..",,/ FORMATION TOP DErAILS TVDPath MDPath Fonnation B.Pennaftost SV5 SV4 SV3 SV2 SVI UG4 UG4A UGJ MalSehrader Mbl Mb2 Me Na Nb Ne OA Sand OBa OBb OBc OBd OBe OBf OBfbase 1984.11 2236.39 2443.94 2891.29 3083.34 3580.63 4098.95 4172.99 4572.84 5742.76 5802.00 5890.86 5942.69 6031.54 6061.16 6112.99 6201.85 6290.70 6342.54 6423.99 6490.63 6572.08 6646.12 6712.77 1972.10 2222.10 2422.10 2792.10 2932.10 3272.10 3622.10 3672.10 3942.10 4732.10 4772.10 4832.10 4867.10 4927.10 4947.10 4982.10 5042.10 5102.10 5137.10 5192.10 5237.10 5292.10 5342.10 5387.10 No. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 CASING DErAILS No. TVD MD Name Size I 2892.10 3028.31 95/8' 9.625 2 5522.15 6912.76 7" 7.000 Q -600 1200 All TVD depths are ssTVD plus 72.1'for RKBE. .I I , .I I _'4>, I ~ ;, --. , ' # e:. , ;< .#" Ba$e O$f f"P~7 : . Depth: 6912.77' \1D,552~.15';TVD I 600 -600 West(-)/East(+) [600ft/in] 200 - ~ fs ~ - l '<I ¡ v .....:7.~ I 800 800 -2400 Æ 2: o o :£. + :c 1:: ~ :c '5 o en -3000 ') BP My Planning Report MAP '') Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB S Pad TR-12-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: S-215 Map Zone: Coordinate System: Geomagnetic Model: 5980854.54 ft 617919.92 ft Latitude: Longitude: North Reference: Grid Convergence: Slot Name: Well Position: +N/-S -1390.36 ft Northing: 5979479.33 ft Latitude: +E/-W 943.80 ft Easting: 618885.41 ft Longitude: Position Uncertainty: 0.00 ft Well path: Plan S-215 Current Datum: Magnetic Data: Field Strength: Vertical Section: 72.10' 2/11/2002 57510 nT Depth From (TVD) ft 0.00 Plan: S-215i WP07 Principal: Yes Casing Points )MD ··TvD, . .... . ... ,))i~rriete..' ' .. aOle,$i:ie ¡, . ',:"ft "'. ..ft·'·· ;¡in hi . 3028.31 2892.10 9.625 12.250 95/8" 6912.76 5522.15 7.000 8.500 7" Formations 1984.11 1972.10 B.Permafrost 2236.39 2222.10 SV5 2443.94 2422.10 SV4 2891.29 2792.10 SV3 3083.34 2932.10 SV2 3580.63 3272.10 SV1 4098.95 3622.10 UG4 4172.99 3672.10 UG4A 4572.84 3942.10 UG3 5742.76 4732.10 Ma/Schrader 5802.00 4772.10 Mb1 5890.86 4832.10 Mb2 5942.69 4867.10 Mc 6031.54 4927.10 Na 6061.16 4947.10 Nb 6112.99 4982.10 Nc 6201.85 5042.10 OA Sand 6290.70 5102.10 OBa 6342.54 5137.10 OBb 6423.99 5192.10 OBc 6490.63 5237.10 OBd 6572.08 5292.10 OBe Height 72.10 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Alaska. Zone 4 Well Centre BGGM2002 70 21 23.002 N 149 2 32.343 W True 0.90 deg 70 21 9.328 N 149 2 4.758 W Well Ref. Point 0.00 ft Mean Sea Level 26.17 deg 80.81 deg Direction deg 213.27 7/23/2002 12 From Well Ref. Point +N/-S ft 0.00 Date Composed: Version: Tied-to: "'i~~Pd~~gl~ . 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ·:qip ,p~r~tif}l( . '. .d,~·· . 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ) BP My Planning Report MAP ') )' " :, '." ~'. : ..... i },. .....', :':',,',,' .., .... ,i! ' . , . ': ',,: "'., "" ., .' , " ,.:' ..'...... '" '...... ..... ¡ ..,' n~,' '" ,"" ,: ~ " Formations 6646.12 5342.10 6712.77 5387.10 OBf OBf base 0.00 0.00 0.00 0.00 Targets 5-215 SV5 2187.10 117.81 181.50 5979600.00 619065.00 70 21 10.487 N 149 1 59.453 W -Polygon 1 2187.10 117.82 181.50 5979600.00 619065.00 70 21 10.487 N 149 1 59.453 W -Polygon 2 2187.10 112.58 511.49 5979600.00 619395.00 70 21 10.435 N 149 1 49.808 W -Polygon 3 2187.10 -590.57 385.31 5978894.99 619280.00 70 21 3.520 N 149 1 53.497 W -Polygon 4 2187.10 -585.33 55.32 5978895.00 618950.00 70 21 3.571 N 149 2 3.142 W -Plan out by 226.32 at 2187.10 -107.60 161.25 5979374.31 619048.33 70 21 8.270 N 149 2 0.045 W S-215 5V1 3237.10 3177.28 -2265.47 5982620.00 616570.00 70 21 40.573 N 149 3 11.001 W -Polygon 1 3237.10 3177.28 -2265.47 5982620.00 616570.00 70 21 40.573 N 149 3 11.001 W -Polygon 2 3237.10 794.08 -507.57 5980265.19 618365.35 70 21 17.137 N 149 2 19.595 W -Polygon 3 3237.10 -730.52 -551.67 5978740.21 618345.44 70 21 2.143 N 149 2 20.881 W -Polygon 4 3237.10 -2182.62 -1709.77 5977270.04 617210.63 70 20 47.860 N 149 2 54.717 W -Polygon 5 3237.10 -3318.02 -2017.67 5976130.00 616920.80 70 20 36.693 N 149 3 3.704 W -Polygon 6 3237.10 -4190.02 -1896.37 5975260.11 617055.91 70 20 28.117 N 149 3 0.154 W -Polygon 7 3237.10 -3318.02 -2017.67 5976130.00 616920.80 70 20 36.693 N 149 3 3.704 W -Polygon 8 3237.10 -2182.62 -1709.77 5977270.04 617210.63 70 20 47.860 N 149 2 54.717 W -Polygon 9 3237.10 -730.52 -551.67 5978740.21 618345.44 70 21 2.143 N 149 2 20.881 W -Polygon 10 3237.10 794.08 -507.57 5980265.19 618365.35 70 21 17.137 N 149 2 19.595 W -Plan out by 4379.97 at 3237.10 -726.62 -279.60 5978748.43 618617.39 70 21 2.182 N 149 2 12.930 W 5-215 UG3 3942.10 3182.52 -2595.46 5982620.00 616240.00 70 21 40.623 N 149 3 20.650 W -Polygon 1 3942.10 3182.52 -2595.46 5982620.00 616240.00 70 21 40.623 N 149 3 20.650 W -Polygon 2 3942.10 798.82 -802.56 5980265.25 618070.35 70 21 17.184 N 149 2 28.218 W -Polygon 3 3942.10 -716.78 -1421.56 5978740.15 617475.52 70 21 2.277 N 149 2 46.303 W -Polygon 4 3942.10 -2179.38 -1909.76 5977270.11 617010.63 70 20 47.892 N 149 3 0.560 W ·Polygon 5 3942.10 -3314.18 -2252.66 5976130.11 616685.81 70 20 36.730 N 149 3 10.569 W -Polygon 6 3942.10 -4183.68 -2296.36 5975260.09 616655.91 70 20 28.178 N 149 3 11.838 W -Polygon 7 3942.10 -3314.18 -2252.66 5976130.11 616685.81 70 20 36.730 N 149 3 10.569 W -Polygon 8 3942.10 -2179.38 -1909.76 5977270.11 617010.63 70 20 47.892 N 149 3 0.560 W -Polygon 9 3942.10 -716.78 -1421.56 5978740.15 617475.52 70 21 2.277 N 149 2 46.303 W -Polygon 10 3942.10 798.82 -802.56 5980265.25 618070.35 70 21 17.184 N 149 2 28.218 W -Plan out by 4888.03 at 3942.10 -1341.16 -743.66 5978126.66 618163.18 70 20 56.137 N 149 2 26.490 W . 5-2150A 5042.10 -2300.01 -1467.73 5977156.52 617454.48 70 20 46.706 N 149 2 47.644 W -Polygon 1 5042.10 -2399.86 -1573.82 5977055.00 617350.00 70 20 45.724 N 149 2 50.743 W -Polygon 2 5042.10 -2199.87 -1570.64 5977255.00 617350.00 70 20 47.691 N 149 2 50.651 W -Polygon 3 5042.10 -2203.05 -1370.65 5977255.00 617550.00 70 20 47.660 N 149 2 44.808 W -Polygon 4 5042.10 -2403.04 -1373.83 5977055.00 617549.99 70 20 45.693 N 149 2 44.899 W -Plan hit target 5-215 Base OBf 5387.10 -2600.73 -1694.83 5976852.25 617232.20 70 20 43.748 N 149 2 54.277 W -Circle (Radius: 100) -Plan hit target Plan Section Information MD !rid Azirh TVD +N/.;S +E/- W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10Qft deg/10Oftdeg/10Oft 'deg 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 2.00 90.00 499.96 0.00 3.49 1.00 1.00 0.00 90.00 900.00 8.00 90.00 898.26 0.00 38.34 1.50 1.50 0.00 0.00 1291.42 9.00 130.00 1285.70 -19.70 89.07 1.50 0.26 10.22 100.58 1609.64 9.00 130.00 1600.00 -51.69 127.21 0.00 0.00 0.00 0.00 1811.24 5.39 144.84 1800.00 -69.58 144.74 2.00 -1.79 7.36 160.00 2037.24 5.39 144.84 2025.00 -86.93 156.97 0.00 0.00 0.00 0.00 2187.24 9.66 178.88 2173.74 -105.29 161.27 4.00 2.85 22.70 63.99 2337.24 14.58 206.65 2320.47 -134.79 153.04 5.00 3.28 18.51 63.98 2826.75 43.13 217.06 2745.00 -327.50 21.78 5.90 5.83 2.13 14.82 3045.98 43.13 217.06 2905.00 -447.10 -68.53 0.00 0.00 0.00 0.00 ) BP ) My Planning Report MAP . . ., ....... .... . ,"'. ... ... _..... ............ ... ........ . 'f3~,Am~pþ"'¡ . . . . . .. . .. ... '.,." ....... . . ...., .. '.','. . 'i ". ,. "..,., ,','" , "'.' ".,'" ,. 123,2002"{" ;i'i':¡Ti):i .~f~h~:~;~,,¡....:: #i~~~j~~f¢r~,Il¢~;;..·i: <t~p ,,' '1;"~~ç~:·U': i~~~~!~:l~~.~'..¡.' ·.I·..¡¡: '$) ., ,.~~;::,ir:¡ ,.~içtlI ·~tbºd:i: Plan Section Information 3265.91 47.53 217.06 3059.58 -571.88 -162.76 2.00 2.00 0.00 0.01 6201.85 47.53 217.06 5042.10 -2300.01 -1467.73 0.00 0.00 0.00 0.00 S-2150A 6712.77 47.53 217.06 5387.10 -2600.74 -1694.82 0.00 0.00 0.00 0.00 6912.77 47.53 217.06 5522.15 -2718.46 -1783.72 0.00 0.00 0.00 0.00 Survey 34.00 0.00 0.00 34.00 -38.10 5979479.33 618885.41 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 27.90 5979479.33 618885.41 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 127.90 5979479.33 618885.41 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 227.90 5979479.33 618885.41 0.00 0.00 Start Dir 1/100' : 300' MD, 30 400.00 1.00 90.00 399.99 327.89 5979479.34 618886.28 -0.48 1.00 CB-GYRO-SS 500.00 2.00 90.00 499.96 427.86 5979479.39 618888.90 -1.91 1.00 Start Dir 1.5/100' : 500' MD, 600.00 3.50 90.00 599.84 527.74 5979479.46 618893.70 -4.55 1.50 CB-GYRO-SS 700.00 5.00 90.00 699.56 627.46 5979479.58 618901.11 -8.61 1.50 CB-GYRO-SS 800.00 6.50 90.00 799.06 726.96 5979479.74 618911.12 -14.11 1.50 CB-GYRO-SS 900.00 8.00 90.00 898.26 826.16 5979479.94 618923.74 -21.03 1.50 CB-GYRO-SS 1000.00 7.86 100.84 997.30 925.20 5979478.87 618937.43 -27.46 1.50 MWD+IFR+MS 1100.00 8.01 111.67 1096.35 1024.25 5979475.22 618950.68 -31.47 1.50 MWD+IFR+MS 1200.00 8.42 121.78 1195.33 1123.23 5979468.99 618963.48 -33.06 1.50 MWD+IFR+MS 1291.42 9.00 130.00 1285.70 1213.60 5979461.05 618974.78 -32.40 1.50 End Dir : 1291.42' MD, 1285.7 1300.00 9.00 130.00 1294.17 1222.07 5979460.20 618975.82 -32.24 0.00 MWD+IFR+MS 1400.00 9.00 130.00 1392.94 1320.84 5979450.34 618987.96 -30.41 0.00 MWD+IFR+MS 1500.00 9.00 130.00 1491.71 1419.61 5979440.48 619000.10 -28.57 0.00 MWD+IFR+MS 1609.64 9.00 130.00 1600.00 1527.90 5979429.66 619013.41 -26.56 0.00 Start Dir 2/100' : 1609.64' MD 1700.00 7.33 134.85 1689.44 1617.34 5979421.21 619023.04 -24.58 2.00 MWD+IFR+MS 1800.00 5.58 143.52 1788.81 1716.71 5979412.92 619030.59 -21.62 2.00 MWD+IFR+MS 1811.24 5.39 144.84 1800.00 1727.90 5979412.06 619031.23 -21.23 2.00 End Dir : 1811.24' MD, 1800' 1900.00 5.39 144.84 1888.37 1816.27 5979405.33 619036.14 -18.17 0.00 MWD+IFR+MS 1984.11 5.39 144.84 1972.10 1900.00 5979398.94 619040.79 -15.27 0.00 B.Permafrost 2000.00 5.39 144.84 1987.92 1915.82 5979397.74 619041.67 -14.72 0.00 MWD+IFR+MS 2037.24 5.39 144.84 2025.00 1952.90 5979394.91 619043.72 -13.43 0.00 Start Dir 4/100' : 2037.24' MD 2100.00 6.87 164.05 2087.41 2015.31 5979388.93 619046.55 -9.90 4.00 MWD+IFR+MS 2187.24 9.66 178.88 2173.74 2101.64 5979376.62 619048.32 -0.45 4.00 Start Dir 5/100' : 2187.24' MD 2200.00 9.96 182.20 2186.31 2114.21 5979374.45 619048.33 1.38 5.00 MWD+IFR+MS 2200.80 9.98 182.40 2187.10 2115.00 5979374.31 619048.33 1.50 5.00 S-215 SV5 2236.39 10.96 190.57 2222.10 2150.00 5979367.90 619047.68 7.27 5.00 SV5 2300.00 13.14 201.74 2284.31 2212.21 5979355.17 619044.10 19.94 5.00 MWD+IFR+MS 2337.24 14.58 206.65 2320.47 2248.37 5979346.99 619040.56 28.74 5.00 Start Dir 5.9/100' : 2337.24' 2350.00 15.31 207.37 2332.80 2260.70 5979344.04 619039.11 32.01 5.90 MWD+IFR+MS 2400.00 18.19 209.68 2380.67 2308.57 5979331.29 619032.41 46.37 5.90 MWD+IFR+MS 2443.94 20.73 211.19 2422.10 2350.00 5979318.56 619025.19 60.99 5.90 SV4 2450.00 21.08 211.37 2427.76 2355.66 5979316.69 619024.09 63.15 5.90 MWD+IFR+MS 2500.00 23.99 212.67 2473.94 2401.84 5979300.30 619014.18 82.31 5.90 MWD+IFR+MS 2550.00 26.91 213.70 2519.08 2446.98 5979282.14 619002.70 103.79 5.90 MWD+IFR+MS 2600.00 29.83 214.55 2563.07 2490.97 5979262.27 618989.68 127.54 5.90 MWD+IFR+MS 2650.00 32.76 215.25 2605.79 2533.69 5979240.75 618975.16 153.50 5.90 MWD+IFR+MS 2700.00 35.69 215.85 2647.13 2575.03 5979217.62 618959.18 181.59 5.90 MWD+IFR+MS 2750.00 38.62 216.37 2686.98 2614.88 5979192.95 618941.77 211.75 5.90 MWD+IFR+MS 2800.00 41.56 216.83 2725.23 2653.13 5979166.81 618922.98 243.89 5.90 MWD+IFR+MS 2826.75 43.13 217.06 2745.00 2672.90 5979152.24 618912.38 261.87 5.90 End Dir : 2826.75' MD, 2745' 2891.29 43.13 217.06 2792.10 2720.00 5979116.62 618886.36 305.89 0.00 SV3 ') BP My Planning Report MAP ') ;" : ., ;' , ..: ", ";, ; 8 ,., , :} Ii: ,.,. ; -", :;: '; Survey 1\10 loci Azim TVD Sys TVD MapN MapE vs DLS TooVCommeot ft deg deg ft ft ft ft ft deg/1000 2900.00 43.13 217.06 2798.46 2726.36 5979111.81 618882.85 311.84 0.00 MWD+IFR+MS 3000.00 43.13 217.06 2871.44 2799.34 5979056.61 618842.53 380.05 0.00 MWD+IFR+MS 3028.31 43.13 217.06 2892.10 2820.00 5979040.99 618831.11 399.36 0.00 95/8" 3045.98 43.13 217.06 2905.00 2832.90 5979031.23 618823.99 411.41 0.00 Start Dir 2/100' : 3045.98' MD 3083.34 43.87 217.06 2932.10 2860.00 5979010.47 618808.82 437.08 2.00 SV2 3100.00 44.21 217.06 2944.07 2871.97 5979001.12 618801.99 448.63 2.00 MWD+IFR+MS 3200.00 46.21 217.06 3014.53 2942.43 5978943.82 618760.13 519.44 2.00 MWD+IFR+MS 3265.91 47.53 217.06 3059.58 2987.48 5978904.99 618731.76 567.43 2.00 End Dir : 3265.91' MD, 3059.5 3300.00 47.53 217.06 3082.61 3010.51 5978884.68 618716.93 592.52 0.00 MWD+IFR+MS 3400.00 47.53 217.06 3150.13 3078.03 5978825.13 618673.42 666.12 0.00 MWD+IFR+MS 3500.00 47.53 217.06 3217.66 3145.56 5978765.58 618629.92 739.72 0.00 MWD+IFR+MS 3528.79 47.53 217.06 3237.10 3165.00 5978748.43 618617.39 760.91 0.00 S-215 SV1 3580.63 47.53 217.06 3272.10 3200.00 5978717.56 618594.84 799.05 0.00 SV1 3600.00 47.53 217.06 3285.18 3213.08 5978706.02 618586.41 813.31 0.00 MWD+IFR+MS 3700.00 47.53 217.06 3352.71 3280.61 5978646.47 618542.91 886.91 0.00 MWD+IFR+MS 3800.00 47.53 217.06 3420.23 3348.13 5978586.91 618499.40 960.51 0.00 MWD+IFR+MS 3900.00 47.53 217.06 3487.76 3415.66 5978527.36 618455.90 1034.10 0.00 MWD+IFR+MS 4000.00 47.53 217.06 3555.29 3483.19 5978467.81 618412.39 1107.70 0.00 MWD+IFR+MS 4098.95 47.53 217.06 3622.10 3550.00 5978408.88 618369.35 1180.52 0.00 UG4 4100.00 47.53 217.06 3622.81 3550.71 5978408.25 618368.89 1181.30 0.00 MWD+IFR+MS 4172.99 47.53 217.06 3672.10 3600.00 5978364.78 618337.13 1235.02 0.00 UG4A 4200.00 47.53 217.06 3690.34 3618.24 5978348.70 618325.38 1254.90 0.00 MWD+IFR+MS 4300.00 47.53 217.06 3757.86 3685.76 5978289.14 618281.88 1328.49 0.00 MWD+IFR+MS 4400.00 47.53 217.06 3825.39 3753.29 5978229.59 618238.37 1402.09 0.00 MWD+IFR+MS 4500.00 47.53 217.06 3892.91 3820.81 5978170.04 618194.87 1475.69 0.00 MWD+IFR+MS 4572.84 47.53 217.06 3942.10 3870.00 5978126.66 618163.18 1529.30 0.00 S-215 UG3 4600.00 47.53 217.06 3960.44 3888.34 5978110.48 618151.36 1549.28 0.00 MWD+IFR+MS 4700.00 47.53 217.06 4027.97 3955.87 5978050.93 618107.86 1622.88 0.00 MWD+IFR+MS 4800.00 47.53 217.06 4095.49 4023.39 5977991.37 618064.35 1696.48 0.00 MWD+IFR+MS 4900.00 47.53 217.06 4163.02 4090.92 5977931.82 618020.85 1770.08 0.00 MWD+IFR+MS 5000.00 47.53 217.06 4230.54 4158.44 5977872.27 617977.34 1843.67 0.00 MWD+IFR+MS 5100.00 47.53 217.06 4298.07 4225.97 5977812.71 617933.84 1917.27 0.00 MWD+IFR+MS 5200.00 47.53 217.06 4365.59 4293.49 5977753.16 617890.33 1990.87 0.00 MWD+IFR+MS 5300.00 47.53 217.06 4433.12 4361.02 5977693.60 617846.83 2064.46 0.00 MWD+IFR+MS 5400.00 47.53 217.06 4500.65 4428.55 5977634.05 617803.32 2138.06 0.00 MWD+IFR+MS 5500.00 47.53 217.06 4568.17 4496.07 5977574.50 617759.82 2211.66 0.00 MWD+IFR+MS 5600.00 47.53 217.06 4635.70 4563.60 5977514.94 617716.31 2285.26 0.00 MWD+IFR+MS 5700.00 47.53 217.06 4703.22 4631.12 5977455.39 617672.81 2358.85 0.00 MWD+IFR+MS 5742.76 47.53 217.06 4732.10 4660.00 5977429.92 617654.20 2390.33 0.00 Ma/Schrader 5800.00 47.53 217 .06 4770.75 4698.65 5977395.83 617629.30 2432.45 0.00 MWD+IFR+MS 5802.00 47.53 217.06 4772.10 4700.00 5977394.64 617628.43 2433.92 0.00 Mb1 5890.86 47.53 217.06 4832.10 4760.00 5977341.72 617589.78 2499.32 0.00 Mb2 5900.00 47.53 217.06 4838.27 4766.17 5977336.28 617585.80 2506.05 0.00 MWD+IFR+MS 5942.69 47.53 217.06 4867.10 4795.00 5977310.86 617567.23 2537.47 0.00 Me 6000.00 47.53 217.06 4905.80 4833.70 5977276.73 617542.29 2579.65 0.00 MWD+IFR+MS 6031.54 47.53 217.06 4927.10 4855.00 5977257.94 617528.57 2602.86 0.00 Na 6061.16 47.53 217.06 4947.10 4875.00 5977240.30 617515.68 2624.66 0.00 Nb 6100.00 47.53 217.06 4973.33 4901.23 5977217.17 617498.79 2653.24 0.00 MWD+IFR+MS 6112.99 47.53 217.06 4982.10 4910.00 5977209.43 617493.14 2662.81 0.00 Ne 6201.85 47.53 217.06 5042.10 4970.00 5977156.52 617454.48 2728.20 0.00 S-2150A 6290.70 47.53 217.06 5102.10 5030.00 5977103.60 617415.82 2793.60 0.00 OBa 6300.00 47.53 217.06 5108.38 5036.28 5977098.06 617411.78 2800.44 0.00 MWD+IFR+MS 6342.54 47.53 217.06 5137.10 5065.00 5977072.73 617393.27 2831.74 0.00 OBb ') BP My Planning Report MAP ) Survey .MD Incl Azim TVD Sys TVD MapN MapE vs DLS Tool/Comment ft deg deg ft ft ft ft ft deg/10OO 6400.00 47.53 217.06 5175.90 5103.80 5977038.51 617368.27 2874.03 0.00 MWD+IFR+MS 6423.99 47.53 217.06 5192.10 5120.00 5977024.22 617357.84 2891.69 0.00 OBc 6490.63 47.53 217.06 5237.10 5165.00 5976984.54 617328.85 2940.73 0.00 OBd 6500.00 47.53 217.06 5243.43 5171.33 5976978.96 617324.77 2947.63 0.00 MWD+IFR+MS 6572.08 47.53 217.06 5292.10 5220.00 5976936.03 617293.41 3000.68 0.00 OBe 6600.00 47.53 217.06 5310.95 5238.85 5976919.40 617281.26 3021.23 0.00 MWD+IFR+MS 6646.12 47.53 217.06 5342.10 5270.00 5976891.93 617261.20 3055.17 0.00 OBt 6700.00 47.53 217.06 5378.48 5306.38 5976859.85 617237.76 3094.83 0.00 MWD+IFR+MS 6712.77 47.53 217.06 5387.10 5315.00 5976852.25 617232.20 3104.22 0.00 S-215 Base OBt 6800.00 47.53 217.06 5446.01 5373.91 5976800.29 617194.25 3168.42 0.00 MWD+IFR+MS 6900.00 47.53 217.06 5513.53 5441.43 5976740.74 617150.75 3242.02 0.00 MWD+IFR+MS 6912.76 47.53 217.06 5522.15 5450.05 5976733.14 617145.20 3251.41 0.00 7" 6912.75 47.53 217.06 5522.14 5450.04 5976733.15 617145.20 3251.40 0.00 Total Depth: 6912.77' MD, 552 6912.77 47.53 217.06 5522.15 5450.05 5976733.14 617145.19 3251.42 0.01 MWD+IFR+MS H 206981 DATE 7/01/02 INVOICE / CREDIT MEMO DESCRIPTION PERMIT TO DRILL FEE CK062602A RECEIVEr) JUL 2 4 2002 . Alaska Oil & Gas Cons. GO\TlfOíSSlor' Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY TO THE ORDER OF DATE 7/01/02 CHECK NO. H206981 GROSS VENDOR DISCOUNT NET S~~\Si -=. -- - - - - - - - -.".-- ~--- - - ,. -- NO....H·····.···.·2QS.S·Sl ' FIRST. NATlQtW,:8ÄNKQFASHLAND ~AtfAFFIUATE:OF. . NATiQÑAi.. CITY BANK ÇLEVE~D,OHIO' , CONSOÜDAtED COMMERCíAL ACCOlJNT Ð. D...··. Œt....~. :",...::...~......~....,.."'...'...J~1Ilj..A:.~'f..·..,.··.·... Ð. :. t.jt D.F ...I~~f \¡W....... _<t... ~LAS~ STliTE<.. ..i:; ..... .P.:,. .àLASISA 0:I:~·& (j~S.CONSERVATION 333\yr 7'!'tl.~'VE. STE 100 ANCtiQRAGJ? 11\1<. 99501 .......... .... - ___ - no" "----:.- ."-n- _.- __" . .-- - - ~ -"-. "_ ". ., _, - -_-.-.-u" ¢QMM!SSION/' .. -".-' p---- "**~**:~iQO~ÖO****ffi; .. "2'li.'~ì.!t!1;;¡I· III 20 b q a ~ III I: 0 ~ ¡. 20 :i B q 51: 00 a ~ ~ ~ q III , t H '-' '-- ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /ßÚ .Ç-/.¡Ç/~ PTD# 202.. -I ~ 7' CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (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. HOLE In accordance with 20 AAC 25.005(t), 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). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates 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. (Company Name) assumes 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..ð.P'.J! WELL NAME/fib ,)-215; FIELD & POOL b 4rJ I b¡?) INIT CLASS /- ¿.U{)'rv;í ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells.. . . . . . . . . APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . .A?/ --< / 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 4J..-:::- If/';f CJ2- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE ~A- 7/'lQloL (Service Well Only) GEOLOGY APPR DATE ,PIj/ 7d ~Z íf:"(~~oratory Only) Rev: 07/12/02 -:1...'II( i/ Z<;?tl C"I i I L/ I . 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ? J'- ~ 16. Surface casing protects all known USDWs. . . . . . . . . . . N A . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . N '~!L,e¿ (..~ ~ç~ 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . tæ 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N D 0-0 a1v"-. 1 c¡. 22. If a re-drill, has a 10:.403 for abandonment been approved. . . '¥::-N""""N/# 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . N 25. Drilling fluid program schematic & equip list adequate. . . . . N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ./)/1 ')1_ ..L ._ ¡... ;/ IJ") r 27. BOPE press rating appropriate; test to L/ooo psig. N M s,p J o'"t"b f~ c:.., ÞUJl.;y: ~ ræ'<-d ..,.OJO If;.{ , 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N $ Ä' ~o {- [:-'}o f~'-LM . I (' n I 31. Mechanical condition of wells within AOR verified. . . . . . . . V @ I~e \ I\.LO rt o. All. Gtr..t ~c.µ.R,( ç ~ .)-' -'CL({ . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . ;rL9 N 33. Data presented on potential overpr.essure zones. . . . . . . . . V N ./ J /7 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . V /( / , n " 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N 36. Contact namelphone for weekly progress reports. . . . . . . . V N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ TEM JD~f6!/ JBR SFD_ WGA yJGA:- G:\geology\permits\checklist.doc PROGRAM: Exp _ Dev _ Redrll _ Re-Enter _ Serv.2(. Wellbore seg _ GEOL AREA 5?'f (") UNIT# / / b .5 c> ON/OFF SHORE ~ ~~ vŒIT éi)N W ,~~ /~ a ~~~~~ 4/ ~/-Þj '~ /:~,,;.5 //..-./ ~ q~d!:v--~ _~4/.J-A:h /~~,.~./~"c ~7 - A..A-j ~¿/~~ ~/ A/c), ( ( UIC ENGINEER COMMISSIONER: Comments/Instructions: COT DTS 07 J 3oJð< MJW ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim,plify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ 1 '"" , ') ) ~r:B-J5C¡ I / 05'1 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 24 15:51:15 2003 Reel Header Service name..... ....... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number.. ... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA S-215i 500292310700 BP Exploration (Alaska) Inc. Sperry Sun 24-APR-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22131 T. MCGUIRE L. VAUGHN MWD RUN 2 AK-MW-22131 T. MCGUIRE L. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 12N 12E 3276 4563 MSL 0) .00 71.49 38.10 # WELL CASING RECORD OPEN HOLE CASING DRILLERS , I 'J 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: ) ) BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 20.000 85.0 8.750 9.625 2946.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLOR TUBE DETECTORS. 4. MWD RUN 2 WAS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY (EWR-4), STABILIZED LITHO-DENSITY (SLD), AND COMPENSATED NEUTRON POROSITY (CNP). REFERENCES. 5. DEPTH SHIFTING WAS WAIVED, PER THE 9/5/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). ALL DATA RETAIN ORIGINAL DRILLER'S DEPTH 6. MWD RUNS 1-2 REPRESENT WELL S-215 WITH API # 50-029-23107-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6930' MD / 5523' TVD. SROP SGRC SEXP SESP SEMP SEDP SFXE SBD2 SC02 SNP2 SPSF SNFA SNNA SMOOTHED RATE OF PENETRATION WHILE DRILLING SMOOTHED GAMMA RAY - GEIGER-MULLER TUBE DETECTORS SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SMOOTHED FORMATION EXPOSURE TIME SMOOTHED BULK DENSITY (LOW-COUNT BIN) SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. PARAMETERS USED IN NEUTRON / POROSITY LOG CALCULATIONS: HOLE SIZE: 8.75" MUD WEIGHT: 9.2 - 9.4 PPG MUD FILTRATE SALINITY: 350 - 1200 PPM CHLORIDE FORMATION WATER SALINITY: 22000 PPM CHLORIDE FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.OOl Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/04/24 Maximum Physical Record. .65535 File Type............. . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE ROP GR NCNT NPHI FCNT PEF FET RPD RPM RPS RPX DRHO RHOB $ ) 1 ) and clipped curves; all bit runs merged. .5000 START DEPTH 532.0 532.5 2891.5 2896.5 2897.0 2897.0 2925.0 2925.0 2925.0 2925.0 2925.0 2951.5 2951.5 STOP DEPTH 6930.0 6892.0 6840.0 6840.0 6840.0 6850.0 6884.0 6884.0 6884.0 6884.0 6884.0 6850.0 6850.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: BIT RUN NO 1 2 MERGED MAIN PASS. $ MERGE TOP 532.0 2891.5 MERGE BASE 3001.0 6930.0 # Data Format Specification Record Data Record Type..................O Data specification Block Type.....O Logging Direction................ . Down Optical log depth units.... ..... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 ) ) RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 532 6930 3731 12797 532 6930 ROP MWD FT/H 1.03 1690.9 297.403 12797 532 6930 GR MWD API 12.43 143.9 66.3153 12711 532.5 6892 RPX MWD OHMM 0.16 106.37 7.37949 7919 2925 6884 RPS MWD OHMM 0.61 2000 9.01927 7919 2925 6884 RPM MWD OHMM 0.23 136.92 7.94344 7919 2925 6884 RPD MWD OHMM 0.44 2000 15.9055 7919 2925 6884 FET MWD HOUR 0.0561 41.436 1.15549 7919 2925 6884 NPHI MWD PU-S 18.81 66.31 38.0941 7888 2896.5 6840 FCNT MWD CNTS 402 775 537.621 7887 2897 6840 NCNT MWD CNTS 2008 3544 2678.44 7898 2891.5 6840 RHOB MWD G/CM 1.235 3 2.22762 7798 2951.5 6850 DRHO MWD G/CM -0.09 0.554 0.0645666 7798 2951.5 6850 PEF MWD BARN 0.24 11.61 1.88642 7907 2897 6850 First Reading For Entire File.... ..... .532 Last Reading For Entire File...... .... .6930 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/24 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/24 Maximum Physical Record. .65535 F i 1 e Typ e. . . . . . . . . . . . . . . . LO Previous File Name. ..... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP GR 2 header data for each bit run in separate files. 1 .5000 START DEPTH 532.0 532.5 STOP DEPTH 3001.0 2935.0 · . ) $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.. ...0 Logging Direction..... ........... . Down Optical log depth units...... .... .Feet Data Reference Point...... ..... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value......... ..... .... ... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 09-AUG-02 Insite 4.3 Memory 3001.0 532.0 3001.0 .0 44.7 TOOL NUMBER 83562 12.250 85.0 Spud Mud 9.20 300.0 8.9 600 13.4 .000 .000 .000 .000 .0 84.2 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel · ' ') ) DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 532 3001 1766.5 4939 532 3001 ROP MWD010 FT/H 1.03 538.75 195.392 4939 532 3001 GR MWD010 API 14.52 112.71 55.7695 4797 532.5 2935 First Reading For Entire File......... .532 Last Reading For Entire File.......... .3001 File Trailer Service name............ .STSLIB.002 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/04/24 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/24 Maximum Physical Record. .65535 Fi Ie Type.. .. .. .. .. .. .. .. LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT PEF FET RPD RPM RPS RPX GR DRHO RHOB ROP 3 header data for each bit run in separate files. 2 .5000 START DEPTH 2891.5 2896.5 2897.0 2897.0 2925.0 2925.0 2925.0 2925.0 2925.0 2935.5 2951.5 2951.5 3001.5 STOP DEPTH 6840.0 6840.0 6840.0 6850.0 6884.0 6884.0 6884.0 6884.0 6884.0 6892.0 6850.0 6850.0 6930.0 ) $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CNP SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ...... ....0 Data Specification Block Type... ..0 Logging Direction....... ..... .... . Down Optical log depth units.......... .Feet Data Reference Point.... ....... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ... .Undefined Absent value........ ............. .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . ) 12-AUG-02 Insite 66.37 Memory 6930.0 3001.0 6930.0 46.8 50.1 TOOL NUMBER 155789 136749 66017 039307 8.800 2946.0 Water 9.20 47.0 10.4 900 7.8 Based 2.400 1.630 2.200 1.600 72.0 109.4 72.0 72.0 '~ . ) ) Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2891.5 6930 4910.75 8078 2891.5 6930 ROP MWD020 FT/H 4.52 1690.9 361.52 7858 3001.5 6930 GR MWD020 API 12.43 143.9 72.7075 7914 2935.5 6892 RPX MWD020 OHMM 0.16 106.37 7.37949 7919 2925 6884 RPS MWD020 OHMM 0.61 2000 9.01927 7919 2925 6884 RPM MWD020 OHMM 0.23 136.92 7.94344 7919 2925 6884 RPD MWD020 OHMM 0.44 2000 15.9055 7919 2925 6884 FET MWD020 HOUR 0.0561 41.436 1.15549 7919 2925 6884 NPHI MWD020 PU-S 18.81 66.31 38.0941 7888 2896.5 6840 FCNT MWD020 CNTS 402 775 537.621 7887 2897 6840 NCNT MWD020 CNTS 2008 3544 2678.44 7898 2891.5 6840 RHOB MWD020 G/CM 1.235 3 2.22762 7798 2951.5 6850 DRHO MWD020 G/CM -0.09 0.554 0.0645666 7798 2951.5 6850 PEF MWD020 BARN 0.24 11.61 1.88642 7907 2897 6850 First Reading For Entire File......... .2891.5 Last Reading For Entire File.......... .6930 File Trailer Service name........... ..STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/04/24 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name........ .... .LISTPE Date. . . .. . . . . . . . . . . . . . . . .03/04/24 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN \':r I':'~ ) ') Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/24 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File