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Home My WebLink About203-1207. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L1-15A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-120 50-029-21995-01-00 11800 Surface Intermediate Scab Liner / Liner Liner Liner / Slotted Liner 8744 4241 9666 6346 400 747 10403 13-3/8" 9-5/8" 7-5/8" 5-1/2" 3-3-1/16" x 2-7/8" 8632 40 - 4281 39 - 9705 4169 - 10515 10168 - 10568 10493 - 11240 40 - 4090 39 - 8124 4008 - 8719 8459 - 8761 8701 - 8791 None 2720 4760 4970 6820 10403 4930 6870 6890 7740 10497 - 11800 4-1/2" 12.6# L-80 35 - 10067 8705 - 8744 Conductor 79 20" 40 - 119 40 - 119 1490 470 4-1/2" Baker S-3 Perm Packer 2205, 2205 9346 7864 Bo York Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, LISBURNE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028302 35 - 8384 N/A N/A 1 Well Not Online 26460 1 18 1 1654 0 N/A 13b. Pools active after work:LISBURNE OIL 4-1/2" HES Wellstar TRSV 9346, 7864 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:51 pm, Aug 08, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.08.08 12:20:33 - 08'00' Bo York (1248) DSR-9/10/25JJL 9/5/25 RBDMS JSB 081425 ACTIVITY DATE SUMMARY 6/25/2025 (Assist E-line) TFS U4, Initial WHP T/IA/OA= 1900/0/0, Pumped 240 bbls SW down TBG to load and secure well, Pumped 38 bbls crude on top to Freeze protect tubing, Final WHP T/IA/OA= 0/0/0 ***Well left in Alaska E-line control*** 6/25/2025 ***WELL SHUT IN ON ARRIVAL*** (SET BAKER IBP) RIG UP AK E-LINE PUMP 240 BARRELS OF SEAWATER WITH T-BIRD PT PCE 250L 3000H(good), FUNCTION TEST WLV'S RIH WITH RS, CCL, EWST, TPEV, P.EXT., BELLVILLE DISCO, HYDRO RT, BAKER IBP. OAL=29.5' MAX OD=2.13" CORRELATE AND ATTEMPT TO SET IBP AT 10420' MD. NO INDICATION OF SETTING AFTER 2 HOURS POOH WITH WITH BAKER IBP, EQUALIZE GAS FROM PARTIALLY INFLATED IBP BAG AT SURFACE. RIG DOWN AKES, JOB NOT COMPLETE WILL RETURN AT LATER DATE. ***WELL LEFT S/I, DSO NOTIFIED*** 7/18/2025 SLB CTU #8 1.75" coil 0.145 WT GT-90 Job Scope: Set IBP Mobilize and MIRU CTU #8. ***Job in Progress*** 7/19/2025 SLB CTU #8 1.75" coil 0.145 WT GT-90 Job Scope: Set IBP Continue MIRU CTU #8. Pump drift ball thru 1.75" CT. BOP Test. Make up 2.2" GR/CCL carrier with 2.25" DJN and RIH. Load well with 1% KCl. RIH to tag crossover at 11201 CTMD and log up to 9000', painting tie-in flag at 11350'. Fill hole with 1% KCl while POOH to prevent excessive gas influx. BD HES logging tools (-1' Correction). MU BOT 2-1/8" IBP BHA. RIH. ...Continue on WSR 7/20/25.... 7/20/2025 SLB CTU #8 1.75" coil 0.145 WT GT-90 Job Scope: Set IBP RIH tagged @ 10,036' CTM the X Nip ID 2.313". Could NOT work past. POOH @ 1825' tagged up on Hydrate - pump slick 1% kcl hot down CT. POOH. Element slightly swollen on IBP due to gas. Re kill well with 1% KCl to sweep gas. Make up 2- 1/8" Baker IBP with Bow spring centalizer on bottom and RIH. Continue to fill hole and minimize gas influx. Tie in at flag and circulate 1/2" ball to seat. Standby for thermal stabilization for 3 hours, during which the WHP increased to 1400 psi due to gas migration. Set IBP and it was blown downhole. Tag at top of liner at 10497'. POOH. Recovered IBP w/ all elements and top & btm anchors have some ruptured metal bands & blader ruptured at the btm of IBP. PT MHA. Re kill well w/ 1% kcl to sweep gas. MU 2-1/8" BOT IBP w/ Bow Spring Centralizer on btm & RIH while continue to fill hole and minimize gas influx. ***Continue on WSR 7/21/25**** Daily Report of Well Operations PBU L1-15A Daily Report of Well Operations PBU L1-15A 7/21/2025 SLB CTU #8 1.75" coil 0.145 WT GT-90 Job Scope: Set IBP RIH with BOT 2-1/8" IBP with bow spring centralizer on btm while pumping down CTBS. Tag @ X NIP Reducer @ 10,048' CTM. Could not work past. POOH while pumping down CTBS. Plug showed no marks or damage. Gather tools and then re- kill well at surface. Make up 2-1/8" BOT IBP with bow spring centalizer and knuckle joint. Continue to pump KCl whileRIH and drift through nipple reducer. Tie-in to flag and place ME at 10410 MD (Top of IBP 10403). Circulate ball to seat with diesel to underbalance coil. IBP began to set early, isolating lower liner. Unable to bullhead gas into casing leak. Wait 2-1/2 hours for thermal stability. Pressure IBP to expected set pressure and bleed WHP until correct differential met, setting the IBP. Set down 5k to confirm set. POOH pumping diesel down the backside for FP. Rig down CTU. ****IBP has 1-3/8" JDC FN. Pinned 1840# to EQ, 5500# to release. OAL 15.53' with bowspring centalizer below.**** ***Job Complete**** Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/10/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#2025010 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 211-26 50283201280000 208112 1/27/2025 AK E-LINE PPROF T40287 END 1-41 50029217130000 187032 3/13/2025 HALLIBURTON MFC40 T40288 END 2-14 50029216390000 186149 3/12/2025 HALLIBURTON MFC40 T40289 END 3-33A 50029216680100 203215 3/23/2025 HALLIBURTON COILFLAG T40290 GP AN-17A 50733203110100 213049 12/29/2024 AK E-LINE Perf T40291 KALOTSA 3 50133206610000 217028 3/3/2025 AK E-LINE PPROF T40292 KU 12-17 50133205770000 208089 1/28/2025 AK E-LINE Perf T40293 MPI 2-14 50029216390000 186149 2/17/2025 AK E-LINE Plug/Cement T40294 NCIU A-21 50883201990000 224086 3/28/2025 AK E-LINE Plug-Perf T40295 ODSN-25 50703206560000 212030 3/7/2025 HALLIBURTON CORRELATION T40296 PBU 02-08B 50029201550200 198095 3/17/2025 HALLIBURTON RBT T40297 PBU D-08B 50029203720200 225007 3/22/2025 HALLIBURTON RBT T40298 PBU J-25B 50029217410200 224134 3/10/2025 HALLIBURTON RBT T40299 PBU K-12D 50029217590400 224099 3/18/2025 HALLIBURTON RBT T40300 PBU K-19B 50029225310200 215182 3/27/2025 HALLIBURTON RBT T40301 PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF T40302 PBU M-207 50029238070000 224141 3/18/2025 HALLIBURTON IPROF T40303 PBU P1-04 50029223660000 193063 3/28/2025 HALLIBURTON PPROF T40304 PBU W-220A 50029234320100 224161 3/11/2025 HALLIBURTON RBT T40305 Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40302PBU L1-15A 50029219950100 203120 3/27/2025 HALLIBURTON PPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 13:48:56 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 3/2/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250302 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# CLU 11 50133205590000 206058 2/19/2025 AK E-LINE CBL,CIBP CLU 11 50133205590000 206058 2/13/2025 AK E-LINE CIBP END 1-65A 50029226270100 203212 1/27/2025 HALLIBURTON COILFLAG END 2-56A 50029228630100 198058 2/6/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 2/2/2025 HALLIBURTON PPROF MPU F-29 50029226880000 196117 1/31/2025 HALLIBURTON MFC24 MPU L-02A 50029219980100 209147 2/17/2025 READ CaliperSurvey MPU L-36 50029227940000 197148 1/18/2025 HALLIBURTON MFC24 MPU R-144 50029238090000 224148 2/11/2025 HALLIBURTON WFL-TMD3D NCIU A-21 50883201990000 224086 2/18/2025 AK E-LINE Perf ODSN-25 50703206560000 212030 2/16/2025 READ MemoryLeakPoint PBU 06-05A 50029202980100 224115 1/15/2025 BAKER MRPM PBU 06-15A 50029204590200 224108 12/27/2024 HALLIBURTON RBT PBU 06-16B 50029204600200 223072 1/25/2025 BAKER MRPM PBU B-12B 50029203320200 224133 1/19/2025 BAKER MRPM PBU S-126B 50029233630200 224084 2/7/2025 HALLIBURTON RBT PBU V-105 50029230970000 202131 2/9/2025 HALLIBURTON IPROF PBU W-01A 50029218660100 203176 1/19/2025 AK E-LINE CBL PBU W-01B 50029218660200 224149 1/28/2025 HALLIBURTON RBT PCU 02A 50283200220100 224110 1/24/2025 AK E-LINE CIBP Please include current contact information if different from above. T40161 T40161 T40162 T40163 T40164 T40165 T40166 T40167 T40168 T40169 T40170 T40171 T40172 T40173 T40174 T40175 T40176 T40177 T40178 T40179 END 1-65A 50029226270100 203212 1/27/2025 HALLIBURTON COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.03 10:15:14 -09'00' Image _oject Well History File c!er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~03 - L~Q Well History File Identifier (Count does include cover sheet) VYES Organizing (done) o Two-sided ""1111111" II/III R~AN .f"COlor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. I o Other, No/Type: o Poor Quality Originals: o Other: NOTES: BY: ~ .... Date ~d-, 13 /OS- Project Proofing Dat. /é7- 13/0;; d- x 30 :' lop + Date: la-I ß / os- BY: ~ Scanning Preparation BY: ~ ';. Production Scanning Stage 1 Page Count from Scanned File: 7 (p P.age Count Matches Number in scann¡" g Preparation: ~ Date:1¿)- ta J os- If NO in stage 1, page(s) discrepancies were found: BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed 1111111111111111 III OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: /5/ rY1f III 111111111II1111I Isl mf /5 = TOTAL PAGES m7J (Count does not include cover 5 t In /5/ "I 11111111111111 "'II YES NO /5/ VV1! r NO /5/ 111111111111111111I 11111111111111" III /5/ Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc 19~IElVi®1~AlOTDI710~I To: Jim Regg ~~~ ~ ~l~ f ~~ P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 04, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L1-15A PRUDHOE BAY iJN LIS LI-ISA Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -~~~ Comm Well Name• PRUDHOE BAY UN LIS Ll-15A Insp Num: mitJCr080803135912 Rel Insp Num: API Well Number: 50-029-21995-O1-00 Permit Number: 203-120-0 Inspector Name: John Crisp Inspection Date: 731/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well LlaSA Type Inj. N TVD 7857 IA lsoo 200 - 26so z6ao P.T. 2031200 TypeTest sPT Test psi 1964.25 QA 540 630 630 630 Interval OTHER per, P Tubing 1 Aso I Aso I Aso 1 Aso Notes' MIT-IA for regulatory compliance post seal tote repair. 1.6 bbl's pumped for test ' " ~ ~, I ~L`x~-- ~ T~r~ C?~ic.)„ i °GyL ~ v\ Q . ~~~ ~' 1 c~ ~ Od--a~c~'1` G ~~ 'tO f' --'~ ~ Z- f v~~~lN~~? A,UG ~ ~ 2~~$ Monday, August 04, 2008 Page 1 of 1 • ~ ~ ~~ ,~.. e ~ ~ ~ } B ~ Imo.,. ~~~ ~ $ '~~~ 'a,~\ ~ ~ J #~ d f ~ 4 ~ ~ ~ ~ ~ ~._a ~ s ~ s ~ ~ ~ ~ ° ~' L2 S SARAH PALIN, GOVERNOR ~ast[a-7~A OI~ A~D ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATI011T CO1~ID1Q55IO1Q ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ross Warner Production Engineer BP Exploration Alaska Inc. ~~~~~~~ MAY ~ ~ 2008 PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, L 1-15A Sundry Number: 308-160 a 0 ~'J ~,. ~ °~,~ Dear Mr. Warner: 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, Daniel T. Seamount, Jr. Chair DATED this~~day of April, 2008 Encl. ~~~ • ~~ ~~~ ~E~EIV~[J ~ p STATE OF ALASKA ~~ APR 2 5 20 'V~' ALASKA OIL AND GAS CONSERVATION COMMISSION ' APPLICATION FOR SUNDRY APPROVAL Alaska Oii & Gas Cons. Commisbs on 20 AAC 25.280 Anchor 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ^ Othe Alter casing ^ Repairwell ^~ ~ Plug Perforations^ Stimulate ^ Time Extension ^ SEAL-TITE, Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^~ Exploratory ^ 203-1200 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21995-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: L1-15A Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028302 - 51 KB ~ PRUDHOE BAY Field / LISBURNE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11800 ~ 8744.29 11240 , 8790.59 - NONE NONE Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20" 91.5# H-40 URFACE 119' SURFACE 119' 1490 470 SURFACE 4281' 13-3/8" 68# L-80/K-55 URFACE 4281' SURFACE 4090' 5020 2260 PRODUCTION 9705' 9-5/8" 47# L-80 URFACE 9705' SURFACE 8124' 6870 4760 LINER 6346' 7"X7-5/8" 26#/29.7# L-80 4169' 10515' 4008' 8459' 7240 5410 LINER 400' 5-1/2" 17# L-80 10168' 10568' 8459' 8761' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SL 10496 - 11205 8704 - 8803 4-1/2" 12.6# L-80 27 - 10058 SL11207 - 11239 8803 - 8791 - OH 11240 - 11800 8791 - 8744 - Packers and SSSV Type: 4-1/2" Halliburton Wellstar TRSV Packers and SSSV MD (ft): 2197 7-5/8" Baker ZXP Top Packer 4169 4-1/2" Baker S-3 Perm Packer 9338 5-1/2" Baker CPH Packer 10176 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/6/2008 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ross Warner Printed Name Ross Warner Title Production Engineer Signature ~.w... -w.~4-'hone 564-5359 Date 4/22/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ .t~•a fC.. `~~ Cr~ ~ at~ie• ~'Z ~G~' ~ C~S~ a-~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~'~ Location Clearance ^ ~~~~~~ Other: C~~~c.~~ ~-5 ~~L~ C' ~0 ~ Op~~f) h 'tt3 W l Tt1LS5 ~ ~~ ~ ~ . Subsequent Form R quired: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 evised 06/2(0 ~ ~ ~ ~! (~ L ~~ ~~-. t~~4~ F} ~ Z~Q~' Submit in Duplicate by • ~ April 24, 2008 Alaska Oil & Gas Conservation Commission Attention: Mr. Thomas Maunder 333 west 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Thomas Maunder: Reference: Sundry Notice for L1-15A-Repairing Casing Leak BP Exploration (Alaska) Inc. proposes to perform a repair of an IA/OA casing leak by utilizing a chemical sealant Background: L1-15 was originally drilled and completed in March of 1990. This well was Coiled Tubing Side Tracked in October of 2003. This well has been a full time producer until a December 31, 2007 when it was shut in due to communication between the production casing and the outer annulus. Subsequent pressure tests indicated that the tubing is good, but the communication is from the IA to the OA. This well flows naturally so gas lift is not necessary for production. A leak detection log was run March 10, 2008 and this data identified the leak at 5 feet - below ground level. This leak is in the 9-5/8" production casinq.j Step Operation 1 Inject dead crude into OA. Pressure OA to 2200 psig and establish injection at about 2.7 gpm. (rate determined from previous tests) 2 Follow crude with 1 bbl Gel-Seal (Seat-Tite product) into OA. The leak is about 5 feet below the surface for a volume of approximately 11 gals. Gel-Seal should reach leak after 12.5 gallons of injection. 3 Establish initial seal at +/- 2200 psig. Allow seal to cure for 1 hour. 4 Increase pressure in 300 psi increments with a 30 minute hold period between steps until a final test pressure of 2700 psi is achieved. 5 Allow seal to cure for 24 hours. 6 Slowly bleed OA to zero. 7 Rig up pump to the IA. Inject diesel or crude to increase IA pressure to 2700 psi. Monitor OA pressure to confirm if no communication exists. 8 Once 2700 psi has been reached successfully, conduct all other MITs. 9 Return well to service. L1-15A Casing Leak Repair Currently this well is shut-in. Service work will begin when approval is received from your organization. If you have any questions please contact: Ross Warner at 564-5359 Sincerely, Ross L. Warner GPMA Production Engineer. 2 • ~L T~~11/5/1/1/~4L ^~~: ProActive Diagnostic Services, Inc. To: AOC~C Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP E~loration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka 900 E Benson Blvd. Anchorage, Alaska 99508 and [~!roActive ~3iagnostic: services, Mc.~j a03 ' 1~0 '~ /~c 03~ Attn: Robert. A. Richey. ~/ __ 130 West Ir>ternat~nal Airport Road ~`~l'~ _~~ ~` / ~ ~~ Suite C Anchorage, AK 99518 Fax (907) 245,8952 1) Leak Detection - WLO 04-Mar~08 F-35 1 EDE 50-029-21843-00 2) Leak Detection - WLD 10-Mar~08 L1-15A E~ ~ 50-029 2,99,5-01 ~~ -~ Signed : Date : ~ ~ ~ ,, ~ °~fi(!€~ Print Name: / I ~ yt e=~JI~.~Cl~iri4~y PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)2458952 E-MAIL : ~dsancdaor~ge(a7memor=.~log.com WEBSITE : wwnav.memoryloa.corr3 C:\Dxumanffi and Settings\Owner\LeskWp\Transmit_BP.doc • -,s..,._ 4.~. -~. MICROFILMED 03/01 /2008 DO NOT PLACE :~,. _~r ~,:: ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~vrPgs_Inserts\Microfilm_Marker.doc L 1-15A (PTD #2031200) Interna~aiver Cancellation -Not Operable Well Page 1 of 1 • Regg, James B (DOA) From: Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com} ~~,~ 1~12f ~`f~ Sent: Monday, December 31, 2007 9:42 AM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, LPC DS Ops Lead; GPB, Area Mgr North (Gas PlantslGPMA); GPB, GPMA OTL; GPB, Wells Opt Eng; GPB, EOC Specialists; Engel, Harry R; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Nash, Justin; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Lau, John, Jack; Holt, Ryan P (ASRC); Dahlem, Jason E; Culpepper, Jerry K. (Orbis); Boyles, Gerald J Subject: L1-15A (PTD #2031200) Internal Waiver Cancellation -Not Operable Well All, An internal waiver was issued for IAxOA communication on natural producing well L1-15A (PTD #2031200) on 01/19/06. The dispensation from the Well Integrity System Policy for this we-1T aFi s expired. If not already done, please ensure the well has been shut-in by the end of today and arrangements have been made to freeze protect the well. The well has been reclassified as Not Operable. A secure program will be sent shortly. Please remove ail Waivered well signs and the laminated copy of the waiver from the wellhouse. Please call if you have any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~~~~ ~Q~ ~ ~ ~~~ 1117/2008 11/27/07 il~i~~~~~s~~r~ NO. 4517 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 40o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~~,`,~~ori~l' NpV ~ ~ 2~~~ Attn: Christine Mahnken ATTN: Beth 6TtErI'W' iV 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~~ 3r ~ ~ Field: P.Bay, Milne Pt., Lisburne WPII .Inh df 1 .... no .,~:.,.. n..a., of MPL-33 11661179 MEM INJ PROFILE (REVISED) ...,: '"•~ 11/13/07 1 L1-15A 11661181 MEM PROD PROFILE ~ 11/21/07 1 MPH-08 11686799 USIT ~ _ 11/18107 1 02-09B 11890327 USIT 11/21/07 1 LGI-04 11686752 RST ~l 05127/07 1 1 ---...~ r.......v..~rvv~ .~~v ~,r . v. v~v ~\~~\v ~~\/ ~G 1 VI\I\II\V VIYC VVr T Clllin 1 V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ ~~~., 900 E. Benson Blvd. ~ ~+ ~` Anchorage, Alaska 99508 ' ~ Date Delivered: ~e~~~~~ ~;a ~ ?("1~'~~j Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 n ATTN: Beth ~ n Received by • • i.. Schlumbergel' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECE\VED DEC 2 1 2005 .;Jaska Oil & Gas Cons. CCffiff~1Cn .Anchorage Well Job# Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L 1-15A :20?J .. I df) 10715359 PROD PROFILE WIDEFT 11/04/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE W/DEFT 07/16/05 1 D.S 18-03B 11057071 SBHP SURVEY 12/02/05 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 11057072 SBHP SURVEY 12103/05 1 A-31A 11072881 LDL 08/07/05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE W/DEFT 10/25/05 1 AGI-10 11087429 LDL 09/05/05 1 S-36 11152365 LDL 11/08/05 1 K-20B 11057076 SBHP SURVEY 12/06/05 1 M-18B 11072876 INJECTION PROFILE 08102/05 1 2-18/L-16 11087185 LDL 10/01/05 1 2-62/Q-17 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~CANNeD JAN 2 5 20D5 Date Delivered: 12/21/05 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne pt. Color CD ~ ~' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received bY~n /)~hv ÀÙ~~ DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 5pw! Â9~~ Permit to Drill 2031200 Well Name/No. PRUDHOE BAY UN LIS L1-15A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21995-01-00 MD 1180(J"""'"" TVD 8744 /' Completion Date 10/15/2003 / Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION ~I Survev Yes ~ Mud Log No Samples No -~. DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, CML Comp, Sonic (data taken from Logs Portion of Master Well Data Maint Well Log Information: Logl Electr . Data Digital Dataset Log Log Run Interval OHI Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments 6 C Las 12199 LIS Verification 1118 1 0500 Open 1 0/29/2003 I ~D C Las 12199 Density 10530 11152 Open 10/29/2003 CML Photo Density - Dual Spaced Neutron ~ Density /vi ~/.,...v ~ Blu 10530 11152 Open 1 0/29/2003 CML Photo Density - Dual Spaced Neutron "ED C Las 12199 Neutron 10530 11152 Open 1 0/29/2003 CML Photo Density - Dual < Spaced Neutron Neutron M !;)/rV t~ Blu 1 0530 11152 Open 10/29/2003 CML Photo Density - Dual Spaced Neutron -ÉD C Las 12199 Sonic 8504 8798 Open 10/29/2003 CML Compensated Sonic /ED C Las 12199 Induction/Resistivity 10530 11198 Open 1 0/29/2003 CML Array Induction - . Shallow Focussed -G'g 12199 Sonic ~/¡,}I ~V{) Blu 8504 8798 Open 1 0/29/2003 CML Compensated Sonic ~ 12199 Induction/Resistivity ""ß/ l-v 6 Blu 10530 11198 Open 1 0/29/2003 CML Array Induction - Shallow Focussed ~ C 12302 Gamma Ray 25 10568 11800 ~ 12/11/2003 !iff C Lis 12302 Gamma Ray 10568 11800 ~ 12/11/2003 Log Gamma Ray 25 Blu 10568 11800 Çe"se 12/11/2003 ~ C 12302 Rate of Penetration 25 10568 11800 gpæ 12/11/2003 Multiple Propagation ./ t) ,.tv\. Resistivity, Gamma Ray ED C Lis 12302 Rate of Penetration 10568 11800 Cese 12/11/2003 Multiple Propagation Resistivity, Gamma Ray Log Rate of Penetration 25 Blu 10568 11800 ~ 12/11/2003 Multiple Propagation Resistivity, Gamma Ray DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Permit to Drill 2031200 Well Name/No. PRUDHOE BAY UN LIS L1-15A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21995-01-00 MD 11800 TVD 8744 Completion Date 10/15/2003 Completion Status 1-01L Current Status 1-01L UIC N IZIS C 12302 Induction/Resistivity 25 10568 11800 Cpe" 12/11/2003 Multiple Propagation ~ 12/11/2003 Resistivity, Gamma Ray ~ C Lis 12302 I nd uction/Resistivity 1 0568 11800 Multiple Propagation Resistivity, Gamma Ray Log Induction/Resistivity 25 Blu 10568 11800 ~ 12/11/2003 Multiple Propagation Resistivity, Gamma Ray f1) C 12303 Gamma Ray 25 10568 11243 Open 12/11/2003 PB1 ,.)!!D C Lis 12303 Gamma Ray 10568 11243 Open 12/11/2003 PB1 . Log Gamma Ray 25 Blu 10568 11243 Open 12/11/2003 PB1 ~ C 12303 Rate of Penetration 25 1 0568 11243 Open 12/11/2003 PB1 ..eo C Lis 12303 Rate of Penetration 10568 11243 Open 12/11/2003 PB1 Log Rate of Penetration 25 Blu 10568 11243 Open 12/11/2003 PB1 2Ö C 12303 Induction/Resistivity 25 10568 11243 Open 12/11/2003 PB1 Æ"D C Lis 12303 I nd uction/Resistivity 10568 11243 Open 12/1112003 PB1 Log I nduction/Resistivity 25 Blu 10568 11243 Open 12/11/2003 PB1 " ED D .;¡€If (\.}<. \ \ Directional Survey 1 0569 11800 1/2312004 Rpt Directional Survey 10569 11800 1/23/2004 ED D ~ A.S \,,\\ Directional Survey 10500 11243 1/23/2004 PB1 Rpt Directional Survey 10500 11243 1/23/2004 PB1 L--_ Well CoreslSamples Information: Sample . Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~ Daily History Received? (üN (Y/N Formation Tops Analysis Received? - Y/N Comments: Permit to Drill 2031200 MD 11800 TVD 8744 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Well Name/No. PRUDHOE BAY UN LIS L 1-1SA Operator BP EXPLORATION (ALASKA) INC Completion Date 10/15/2003 Completion Status 1-01L Current Status 1-01L ~ Date: API No. SO-029-2199S-01-00 UIC N J] Df,.,_.-It <N) r- . . e e I";·;'! >:;"r:;O ft·'\ C:I'·"'I':.) rr:' \ ~"".~ i ~ . ¡- i . .. \~.,.'~,." ~ t / I \ \ ¡! t ~.:::- ')) \\ ,,'-,\.¡ ·lL (t... L rrL LJ ._, r¡-y\ "f':) I' , I I ,.~ llU U~ , ~ 'L ! "'j r~--'; (;:~;\ l ¡ ¡ ',. : t, \ i ¡ ! h \ \ \.:.J-./\.'.·.l.'.'~ .,/.!I.;\:,.\..... i ! \ \ I i ( i \ \ .,..-.... :... llÙ Lb U\j cQ) J\j Lrü FRANK H. MURKOWSKI, GOVERNOR AI4ASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12, 2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 ;,~ú:.a~ idvD Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location , :PBU Ll PBU L2 PBU L3 Date of SVS Test April 23, 2004 April 26, 2004 April 27, 2004 Failure Rate 30.0% 16.7% 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part ofthe SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU L1, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to w't th SVS test. (t~OITll~' CharrV Commissioner Sincerely, fJ/~ Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) e e Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Waived Submitted By: Ron Marquez Date: 04/23/2004 Unit/Field/Pad: Greater Pt McIntyre/Lisburne/Ll Separator psi: LPS 450 HPS 450 --~~I ~~- ;< . w/·. ~ - I I {lYf:,+.wtWii- ., .. Wi"''''''' , ." - " ".~.~--'" "-'XI" -,'., Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI L1-01 1850550 7/19/2003 SI LI-02 1851720 450 350 320 P 5 P 4/27/2004 OIL L 1-09 1850010 450 700 690 P P P OIL LI-10 1850830 4/30/1990 SI Ll-14 1851400 3/10/1996 SI J:-l-15A 2031200 450 350 350 P P P OIL LI-21 1780300 450 600 550 P 5 P 4/27/2004 OIL LI-27 1891220 5/1 0/1994 SI LI-28 1880250 12/17/1992 SI LI-30 1900180 3/28/1995 SI Ll-31 1980150 450 350 350 P 5 P 4/27/2004 OIL Wells: 5 Components: 10 Failures: 3 Failure Rate: Remarks: L1-02 4/23/2004: Called grease crew and heater Ll-21 4/23/2004: Called grease crew L 1- 31 4/2312004: Called grease crew Page 1 of 1 SVS PBU LIS L 1 04-23-04.xls r----~~.~-- .. Transmittal Form INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: Ll-15A & Ll-15APB1 Contains the following for each wellbore: 1 LDWG Compact Disc {Includes Graphic Image 1 LDWG lister summary 1 blueline GR/Directional Measured Depth Log 1 blueline - MPR Measured Depth Log 1 blueline MPR TVD Log LAC Job#: 543243 Sent By: Glen Horel Date: Received Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & REfiltiBlìING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ .. .. STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HoLe: SIZE WT. PERFT. BOTTOM SIZE 20" 91.5# H-40 Suñace 119' 30" 13-3/8" 68# L-80 / K-55 Suñace 4281' 17-1/2" 2775 sxAS III. SOO sx ·G'. Top Job 90 sxAS I 9-5/8" 47# L-80 Suñace 9705' 12-1/4" 7" x 7-5/8" 26# / 29.7# L-80 4169' 10515' 8-1/2" 5-1/2" 17# L-80 10168' 10568' 6-3/4" 3-3/16" x 2-7/8" 6.2# / 4.7# L-80 10493' 11240' 3-3/4" 23. Peñorations open to Production (MD + TVD of TOE and 24. Bottom Interval, Size and Number; if none, state' none"): 3-3/16" Slotted Section 2-3/8" Slotted Section MD TVD MD TVD 10497' - 11205' 8705' - 8804' 11207' - 11239' 8803' - 8791' 25. o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3 Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Suñace: 2601' NSL, 2484' EWL, SEC. 01, T11N, R14E, UM Top of Productive Horizon: 893' NSL, 2092' WEL, SEC. 02, T11 N, R14E, UM Total Depth: 1611' NSL, 2719' WEL, SEC. 02, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 688605· y- 5974954' Zone- ASP4 TPI: x- 684074 y- 5973132 Zone- ASP4 Total Depth: x- 683429 y- 5973835 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD, GR, RES, CML Comp., Sonic 26. Date First Production: October 17, 2003 Date of Test Hours Tested 11/13/2003 8 Flow Tubing Casing Pressure Press. 653 PRODUCTION FOR TEST PERIOD ... CALCULATED ..... 24-HoUR RATE""'" One Other 5. Date Comp., Susp., or Aband. 10/15/2003 . 6. Date Spudded 9/29/2003 . 7. Date T.D. Reached 10/12/2003 - 8. Elevation in feet (indicate KB, DF, etc.) KBE = 51' 9. Plug Back Depth (MD+ TVD)~rV 11240 +~/9/ Ft 10. Total Depth (MD+TVD) ßPU 11800 + Bz4!{ Ft 11. Depth where sssJ set 2197' MD 19. Water depth, if offshore N/A MSL CEMENTING RECORD 2150# Poleset 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-120 13. API Number 50-029-21995-01 14. Well Number L 1-15A 15. Field and Pool Prudhoe Bay Field / Lisburne Pool 16. Lease Designation and Serial No. ADL 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 500 sx Class 'G' 190 sx 'G' , (XO at 9484) 332 sx Litecrete 570 sx Class 'G' Uncemented Slotted Liner SIZE 4-1/2", 12.6#, L-80 DEPTH SET (MD) 10058' PACKER SET (MD) 9338' DEPTH INTERVAL (MD) 7200' AMOUNT & KIND OF MATERIAL USED Freeze Protected with 110 Bbls of Diesel OR'G'~,LA' Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE \., Y GAs-McF 14,761 GAs-McF 44,283 WATER-Bsl 64 WATER-Bsl 192 PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-Bsl 1,394 Oll-Bsl 4,182 CHOKE SIZE I GAS-Oil RATIO 62° 10,588 Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None /0. 1~·r;.3 IIIJISBFl NOV 2S 2003__~g~ 28. GEOLOGIC MARKERS. 29. eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD Lisburne I Wahoo Zone 6.3 10552' 8748' None Wahoo Zone 6.2 10567' 8760' Wahoo Zone 6.12 10650' 8813' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble --l~ ~ Title Technical Assistant L 1-15A Well Number Date ) /./ ?.. D3 203-120 Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dan Kara, 564-5667 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ORIGINAL .... .. BP EXPLORATION Operations Summary Report Page 1 of 27 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Date From - To : Hours Task Code. NPT Phase Description of Operations --....j. _... ..._..._m. ..._...n____....__... u. 8/27/2003 00:00 - 07:30 7.50 MOB P PRE Prepare to move rig 07:30 - 13:30 6.00 MOB P PRE Move rig from DS-7 to L 1 pad. 13:30 - 20:30 7.00 MOB N RREP PRE Work on kelly standpipe -- had discovered damaged kelly hose from ram during derrick down ops. Will need to replace hose. Welder cut, rotate, and re-weld kelly standpipe to prevent future interference. Also working on centrifuge bearing replacement. 20:30 - 21 :00 0.50 MOB P PRE PJSM concerning raising the derrick. 21 :00 - 00:00 3.00 MOB P PRE Open roof, raise derrick, scope derrick up. Close roof. 8/28/2003 00:00 - 08:30 8.50 MOB P PRE Finish derrick-up ops. Have been flowing OA to tiger tank throughout night. Total of about 150 bbls flowed back since last night (sample caught for analysis). Currently, flowing liquid at 70 psi. SI and disconnect hose. 08:30 - 10:00 1.50 RIGU P PRE Place rig mats around well. Finish replacing kelly hose. 10:00 - 12:30 2.50 RIGU P PRE Position rig over well. RU. PU injector and get it out of the way. MU standpipe manifold. Accept rig 12:30 hrs 8-28-2003. 12:30 - 13:30 1.00 KILL P DECOMP RU BPV lubricator and pull BPV. Tubing on vac. 13:30 - 16:30 3.00 REMCM-C DECOMP Wait on Little Red for injectivity test on OA. Safety meeting. RU. Tbg = 0 psi; IA = 22 psi with slight blow and fluid level at 108'; OA = 95 psi and liquid at surface. PT lines. Pump diesel down OA at 1.0 BPM to 1000 psi. SD. Check/swap transducers -- bled to 900 psi in 20 minutes. No change in IA and tbg. Continue pumping 1.0 BPM. OA broke over at 1800 psi. Est steady injection at 1.0 BPM; 950 psi. Increase rate to 5.0 BPM. Pressure stabilized at 1375 psi. Total of 20 bbls diesel pumped. No change in IA pressure or fluid level. 16:30 - 17:30 1.00 REMCM-C DECOMP Discuss plan forward and cement design. 17:30 - 19:00 1.50 RIGU C DECOMP Finish pumping remaining diesel for a total of 156 bbls of diesel and 100 bbl of 50/50 MeOH to full volume of OA (256 bbls to shoe) to ensure we don't lock up and if we do, to have FP fluids back there. Final injection rate 5 bpm and final injection pressure 1,450 psi. 19:00 - 22:00 3.00 RIGU C DECOMP RU hard lines to tiger tank and test. RU second valve on outer annulus. RU to circulate well. Wait on arrival of crude and water truck for down squeeze. 22:00 - 23:30 1.50 REMCM-C DECOMP RU cementers to outer annulus. 23:30 - 00:00 0.50 REMCM-C DECOMP PJSM for cement down squeeze. 8/29/2003 00:00 - 01 :47 1.78 REMCM-C DECOMP Fluid pack well with 6 bbl. Some gas in returns. Pressure system tubing and inner annulus to 2000 psi. and maintain with .2 bpm. Pump down outer annulus 203 bbls of crude, 20 bbl of DS CW101 surfactant, 200 bbl fresh water, 15 bbl CW 101 spacer and 5 bbl fresh water at 5 bpm 1200 psi. 01:47 - 02:12 0.42 REMCM-C DECOMP Batch mix 60 bbl cement 15.7 ppg Arctic Set 1 with 1/4 #/sk celloflake, displace with 5 bbl H2O. 02:12 - 03:15 1.05 REMCM-C DECOMP Displace with 186 bbl crude. Throught job held 2000 psi on inner annulus and tubing by bullheading at .2 bpm to leak in casing a total of 42.7 bbls injected. .2 bpm at 2000 psi. 03:15 - 03:30 0.25 REMCM-C DECOMP Monitor well OA = 450 psi IA = 888 psi. Bleed of IA to 36 psi OA = 451psi . Shut in OA with 450 psi locked in. 03:30 - 05:00 1.50 REMCM-C DECOMP Wash up and RD cementers. 05:00 - 05:15 0.25 KILL P DECOMP Attempt to bleed off from IA 5+ bbls. Well pressured back to 45 psi. Acts like some gas trapped. 05:15 - 06:15 1.00 KILL P DECOMP Circulate well to 9.8 ppg brine, getting 9.6+ ppg back with some Printed: 10/20/2003 8:56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/29/2003 8/30/2003 8/31/2003 9/112003 '4IIIW .. BP EXPLORATION Operations Summary Report L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Page 2 of 27 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 05:15 - 06:15 ¡From - To Hours Task Code: NPT Phase __... ._...n.. ......_ _ 06:15 - 06:45 06:45 - 08:00 08:00 -10:15 10: 15 - 11: 15 11:15-12:15 12:15 -15:00 15:00 - 15:30 15:30 - 00:00 00:00 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 08:45 08:45 - 11 :00 11 :00 - 16:00 16:00 - 17:00 17:00 - 17:45 17:45 - 18:30 18:30 - 19:00 19:00 - 20:30 20:30 - 00:00 00:00 - 06:15 06:15 - 06:45 06:45 - 14:30 14:30 - 15:30 15:30 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 04:00 1.00 KILL P 0.50 KILL P 1.25 KILL P 2.25 KILL P 1.00 KILL P 1.00 BOPSUR P 2.75 BOPSURP 0.50 BOPSURP 8.50 BOPSURP 6.50 BOPSUR P 0.50 BOPSUR P 1.00 BOPSURP 0.75 BOPSURN 2.25 BOPSURN 5.00 BOPSURP 1.00 BOPSURP 0.75 BOPSURP 0.75 PULL P 0.50 PULL P 1.50 PULL P 3.50 PULL P 6.25 PULL P 0.50 PULL P 7.75 PULL P 1.00 PULL P 8.50 FISH P 1.00 FISH P 2.00 FISH N 1.00 FISH P Description of Operations DECOMP gas -- trace of oil. Pumped 325 bbls (total surface to surface = 667 bbls). DECOMP SI well. Crew change. Safety and ops procedure meeting. DECOMP Take on additional 9.8 ppg brine. Check external tank levels. SI lAP dropped from 80 psi to 40 psi while SI the last two hours. DECOMP Bleed well to zero; slight flow and blow at shakers. Circulate kill well with brine starting at 4 BPM; 1150 psi pump pressure; 200 psi choke pressure at FOC. Returns through buster. Total bbls pumped (including the 325 pumped earlier) = 750. Six bbls lost to formation during last 400 bbls. Choke pressure had fallen to 150 psi. SD. Swap from buster to MM and pump another 30 bbls. Good 9.8+ ppg MM density out. OA at 0 psi. DECOMP Flow check IA and tubing -- dead. DECOMP Set TWC. Pressure choke line to IA to 500 psi (1.5 bbls to get there) to test TWC from below. DECOMP Bleed control lines, voids. ND kill line on wing. ND tree and adapter spool. Plug control lines, trapping 4000 psi on SSSV line. Inspect hanger threads, screw in landing sub, function LDS's. FiIIlA (2 bbls). DECOMP Safety meeting. NU. DECOMP NU BOPE. Periodically filling IA. Losses averaging 2 bbll hr. DECOMP Continue to NU BOPE and riser. DECOMP Crew change safety meeting. DECOMP Hook-up hose to IA. Fill hole -- 3 bbls. SFAL DECOMP Start BOP test. Fix leaks on test hose fittings. SFAL DECOMP Try body test. Leak at 11" x 13-5/8" adapter flange. Retighten. Try test again. Door leak (3-1/2" ram cavity). DECOMP Test BOPE. Witnessed by AOGCC's Chuck Scheve. IA hole fill twice at 3-4 bbls each. DECOMP MU 2ES's shooting nipple and SLB lubricator sections. RIH into stack and close bag. DECOMP MU BPV lubricator. Pull TWC. Well on vac. LD lubricator and shooting nipple. DECOMP Fill hole. RU elevators for landing joint. Position floor valve. DECOMP PJSM Laying down tubing. DECOMP Pull hanger to the floor 55K. Clean PU. RU Camco control line spooler and clear pipe shed for LD tubing. DECOMP LD tubing hanger. LD tubing. DECOMP TOH and lay down 2-7/8 EUE tubing. DECOMP Crew change safety and tech limits meeting. DECOMP Continue to lay down the 2-7/8 EUE tubing. Significant line of external corrosion with several full penetrations in #219 pulled (about 6900'). Also, considerable external corrosion on couplings in this area and deeper. Finish POOH with a total of 296' joints plus one 14' cut joint (clean looking cut). DECOMP Clear and clean floor DECOMP Load twelve 4-3/4" collars and 323 jts of DP into pipe shed. Drift and tally. Add new weights to counter weight bucket, PU tongs and spinners. DECOMP RU and test kelly hose to 3500 psi. DECOMP Repair leaks and retest kelly hose. DECOMP Set wear ring. Bring fishing tools to rig floor. Printed: 10/2012003 8:56:59 AM !. . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Datè From- To, ,Hours "]"åsk CO<ie NPT ., Phase 9/1/2003 04:00 - 06:15 2.25 FISH P DECOMP 06:15 - 06:45 0.50 FISH P DECOMP 06:45 - 12:30 5.75 FISH P DECOMP 12:30 - 14:00 1.50 FISH P DECOMP 14:00 - 18:30 4.50 FISH P DECOMP 18:30 - 19:00 0.50 FISH P DECOMP 19:00 - 22:30 3.50 FISH P DECOMP 22:30 - 23:15 0.75 FISH P DECOMP 23:15 - 00:00 0.75 FISH P DECOMP 9/2/2003 00:00 - 06:00 6.00 FISH P DECOMP 06:00 - 06:45 0.75 FISH P DECOMP 06:45 - 07:00 0.25 FISH P DECOMP 07:00 - 07:30 0.50 FISH P DECOMP 07:30 - 09:30 2.00 FISH P DECOMP 09:30 - 15:30 6.00 FISH P DECOMP 15:30 -16:15 0.75 FISH P DECOMP 16:15 -16:45 0.50 FISH P DECOMP 16:45 - 20:30 3.75 FISH P DECOMP 20:30 - 23:00 2.50 FISH P DECOMP 23:00 - 23:30 0.50 FISH P DECOMP 23:30 - 00:00 0.50 FISH P DECOMP 9/3/2003 00:00 - 01 :30 1.50 FISH P DECOMP 01:30 - 06:15 4.75 FISH P DECOMP 06:15 - 06:45 0.50 FISH P DECOMP 06:45 - 07:15 0.50 FISH P DECOMP 07:15 -11:00 3.75 FISH N RREP DECOMP 11 :00 -13:00 2.00 FISH P DECOMP 13:00 - 17:00 4.00 FISH P DECOMP 17:00 - 22:00 5.00 FISH P DECOMP 22:00 - 23:00 1.00 FISH P DECOMP Page 3 of 27 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 'Description of Operations PU fishing BHA#1 (overshot, jars, 12 collars, accelerator). Crew change safety meeting. PU 120 joints of 3-1/2" drillpipe. Kick drill. Est circulation -- good. Got a little out of balance CSG to DP. CBU. Continue to PU 3-1/2" drillpipe, averaging about 25 - 30 jts per hour. Hole still taking about 2 BPH. Crew change safety meeting. Continue to PU 3-1/2" DP. Establish circulation rate and pressue.3bpm at 450 psi. Up wt 145K, DN WT 108K Rot Wt 125K. Tag top of fish at 9369'. Set down while circulating pressure increase 1100 psi. Latch fish and pull free with 30K over. Well slightly out of balance. Ccirculate 6 bpm at1800 psi. Pump 18 bbl1 O.Oppg for dry job. O.K. POH. POOH with fish. SB collars. Safety meeting. LD overshot and fish. Full recovery of cut tubing, pup, and seal assembly. MU packer milling BHA (BHA #2) and 12 collars. MU 142 stands of DP. PU kelly, service same. Grease swivel. Install safety clamp and chain. Mousehole last joint (#285) and MU. Wt check 140k up and 118k down. Est circulation 4.0 BPM and rotation (280 amps -- 5k ft-Ibs). Set torque limit (400 amps) Mill packer from 9393' DPM to 9395.5' DPM. After making 2.5', start spinning and making very little progress. Stall 3x. Pit gain of 1 bbl. PU 180K, 40k overpull -- dragging for about 15' then pulled free. Shut in well. Circulate bottoms up, routing returns thru poor boy degasser. RIH, attempt to mill. Not losing any weight at 9395.5'. RIH and tag 9414'. Packer/tailpipe likely fell downhole alongside 2-7/8" chemical cut at 9735' to cement top at 9752'. Circulate 50bbl hi vis pill (170K LSRV) surface to surface. Continue circulating 50bbl hi vis pill (170K LSRV). SI, monitor well. No flow. Rack back kelly and POH with BHA #2. Stand back 142 doubles and 6 std of DC's. Safety meeting. Start laying down milling assembly. Normal mill wear and boot basket debris (plus the one missing SSSV control line band). While breaking out BHA, off-driller breakout line failed below the rig floor right next to the swedge/thimble fitting. (LCIR # 609856) SD ops to investigate and discuss actions/plan forward. Inspect make-up line and shieve -- OK. Safety meeting. MU spear BHA #3 with 3.2" grapple and 6 stands of collars. Slip and cut drill line (planned ops). Grease crown sheaves. MU 144 stands drillpipe. Wt check 130K up, 115K down. Bring pump on to 2bpm at 685psi. Lose wt at 9479' DPM, set down 10k. See circ press Printed: 10/20/2003 8:56:59 AM '.... a BP EXPLORATION Operations Summary Report DECOMP increase to 1800psí. PU, see circ press fall, rotate pipe. RIH and engage fish at 9484', set down 10k. PU, 20K overpull. Good sign that fish has been speared. DECOMP Safety meeting. DECOMP Rack back Kelly and POH slowly with fishing BHA #3. DECOMP POH slowly with fishing BHA #3, standing back 3-1/2" DP. Occasional 20K overpull. DECOMP SB collars. DECOMP Safety meeting. DECOMP Finish SB collars. Bounce packer through stack. RU Eckels for the 2-7/8" tailpipe. LD spear, packer, SBE, MOE. POOH with 9 jts of 2-7/8" tubing and 16.5' partial (clean looking chemical cut) Load out packer and 2-7/8" tubing. Bring in wash pipe. RU elevators, spinner. Safety meeting. MU BHA #4: 6-3/4" carbide cutter shoe, 460' of 5-3/4" x 5" washpipe. TIH with DP. RIH to 9785'. Break Circulation, RIH to 9849'. Wt Check: Up=130K, Dn=115K. Tag at 9890', set down 20001bs. Check Torque: 600amps= 1 OKFtlbs PU off tag depth and MU kelly. RIH pumping at 6bpm and tag solid at 9903', set down 10Klbs. PU to disengage KB. Start fluid swap. Circulate 9.9ppg Formate Flo-Pro at 6bpm around corner. RIH, rotate past last tag at 9903'. 6bpm 1250psí. Max torque at 500amps. Continue picking up singles, seeing little or no resistance while RIH. Tag solid at 10168', top of 5-1/2" liner. Looks like 2-7/8" Tailpipe fell to cement top in 5-1/2" liner at 10464'. This would put the top of the fish at 9911', so our initial tag at 9903' was likely the top of the fish. Circulate remainder of formate flopro around. Circulate remainder of formate flopro around. PJSM prior to tripping pipe. POH with BHA #4, stand back DP. Pulling wet, pump a 15bbl 10.2ppg dry job with products on location. No good, still pulling wet. SB DC's and LD washpipe. MU BHA #5 (overshot). RIH with DP. Slip and cut drill line. Appears that the drum on the draworks is misaligned (not centered) with the crown sheave causing excess side wear on the last wrap of line. Continue RIH with DP. RIH to 9886' DPM. MU kelly. Wt Check 130K up, 11 Ok dn. 3bpm, 400psí. RIH set down at 9896', PU, rotate briefly and RIH. Circ press increase to 750psi set down 5' deeper, good indication fish is on. DECOMP Pump a 20bb110.9ppg dry job. DECOMP Rack back Kelly and POH, standing back DP. Still pulling wet, need MI to come up with a solution for this problem. DECOMP POH, standing back DP. Stand back 12DC's. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To : Hours Task Code. NPT Phase ; 9/3/2003 22:00 - 23:00 1.00 FISH P 23:00 - 23:15 0.25 FISH P 23:15 - 00:00 0.75 FISH P 9/4/2003 00:00 - 05:30 5.50 FISH P 05:30 - 06:15 0.75 FISH P 06:15 - 06:30 0.25 FISH P 06:30 - 09:00 2.50 FISH P 09:00 - 10:45 1.75 FISH P DECOMP 10:45-11:00 0.25 FISH P DECOMP 11 :00 - 14:00 3.00 FISH P DECOMP 14:00 -19:30 5.50 FISH P DECOMP 19:30 - 20:30 1.00 FISH P DECOMP 20:30 - 21 :00 0.50 FISH P DECOMP 21 :00 - 21 :30 0.50 FISH P DECOMP 21 :30 - 23:00 1.50 FISH P DECOMP 23:00 - 00:00 1.00 FISH P DECOMP 9/5/2003 00:00 - 01 :00 1.00 FISH P DECOMP 01 :00 - 01 :15 0.25 FISH P DECOMP 01:15 - 08:30 7.25 FISH P DECOMP 08:30 -11:15 2.75 FISH P DECOMP 11:15-13:30 2.25 FISH P DECOMP 13:30 -18:15 4.75 FISH P DECOMP 18:15 - 20:00 1.75 FISH P DECOMP 20:00 - 21 :30 1.50 FISH P DECOMP 21 :30 - 22:30 1.00 FISH P DECOMP 22:30 - 23:00 23:00 - 00:00 0.50 FISH 1.00 FISH P P 9/6/2003 00:00 - 04:00 4.00 FISH P Page 4 of 27 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Operations .. - ... ....-.-,.-- Printed: 1012012003 8:56:59 AM ,.,.' . BP EXPLORATION Operations Summary Report Page 5 of 27 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 , Date · From - To Hours; Task ; Code NPT Phase Description of Operations . . ._. u______...... 9/6/2003 04:00 - 04:45 0.75 FISH P DECOMP RU Eckels and tidy up rig floor. 04:45 - 06:15 1.50 FISH P DECOMP LD BHA #5 and 142-7/8" full joints and 2 partials. BOF flared to 3-1/4" due to two V-grooves (splits) from sharp chemical cut fish falling on top of other chemical cut fish. Difficult to dress and overshot the remaining fish (it will likely just spin). Call for spear. 06:15 - 06:30 0.25 FISH P DECOMP Crew change. 06:30 - 07:30 1.00 FISH P DECOMP Load out 2-7/8" tubing that was pulled. Bring in a few sticks of 2-7/8" DP and DC's. 07:30 - 08:15 0.75 FISH P DECOMP Spear on location. Inspect and discuss. Prefer spearing fish with slíckline first (and perhaps get fish out, 600#, if it's not stuck in any muck) and bait for jointed pipe overshot run. 08:15 - 08:30 0.25 BOPSURP DECOMP RU for weekly BOPE test. Witness waived by AOGCC's John Crisp. 08:30 - 10:30 2.00 BOPSURP DECOMP PT choke manifold. Pull wear bushing, set test plug. Leaks. Pull and inspect. Put on some teflon sealant. Reset. 10:30 - 14:30 4.00 BOPSURN DECOMP Test plug still leaks. Pull to floor. Don't have tools to break-out test plug to replace packing. Cameron to shop to get seals to redress old hanger and TWC. RIH and set hanger with TWC. 14:30 - 15:45 1.25 BOPSUR P DECOMP Test BOPE. 15:45 - 18:00 2.25 BOPSURN DECOMP Leak in 3-1/2" ram door. Replace seal. 18:00 - 18:30 0.50 BOPSURP DECOMP Continue Testing BOPE. 18:30 - 18:45 0.25 BOPSURP DECOMP Crew Change. Safety meeting with Halliburton Slíckline crew and Rig crew. 18:45 - 20:30 1.75 BOPSURP DECOMP Continue Testing BOPE. 20:30 - 22:20 1.83 FISH P DECOMP RU Slícklíne. 22:20 - 00:00 1.67 FISH P DECOMP RIH, fish 2-7/8" tailpipe on SL. (1.89" OD Spear, 2.43" grapple) 9/7/2003 00:00 - 02:00 2.00 FISH P DECOMP RIH, fish 2-7/8" tailpipe on SL (1.89" OD Spear, 2.43" grapple). Set down, 10252', work past. TOF=10356'md. Make several attempts to spear fish, no bite. POH. Unable to achieve good spang jar action on bottom due to viscous fluid. 02:00 - 03:30 1.50 FISH P DECOMP RIH with 4.5" OD LIB. Set down at 10231' and unable to work past. POH 03:30 - 05:00 1.50 FISH P DECOMP RIH with 2.875" OD LIB. No tight spots above fish. Set down at 10260'. POH. No indication of restricted ID at top of fish. 05:00 - 08:30 3.50 FISH P DECOMP RIH with additional wt bars and same spear. Tag fish 10364'. 800 Ibs up. Spang down. Got bite, but pulled out at 1500 Ibs. Repeat three times, tapping down 20 - 30 times before checking bite. No indication of spear burying itself further into fish (although 2 ft in 2 miles tough to see). POOH. Some junk marks on shaft above spear grapple. Grapple control had skipped over alien screw stop. RD Otis. LD shooting nipple (lubricator). 08:30 - 08:45 0.25 FISH P DECOMP Safety meeting. 08:45 - 10:45 2.00 FISH P DECOMP MU fishing BHA #6: Cut lip overshot, 4-11/16" OD, 3-314" ID, dressed internally with cutrite (2-7/8" will drift through this cutrite) and 2-7/8" grapple. MU 2-7/8" DP and collars. 10:45 - 12:00 1.25 FISH P DECOMP TIH. 12:00 - 12:30 0.50 FISH P DECOMP Nordic crew change. 12:30 - 13:00 0.50 FISH N DECOMP Weld-up chimney section (wind block) above driller console. 13:00 - 17:30 4.50 FISH P DECOMP TIH. 145k and 105k. Lost some RIH wt, up to 20k, starting at about 10,200' -- same depth slícklíne tagged with LIB. Continue TIH -- got wt back after a couple more joints. Printed. 1012012003 8.56.59 AM ·! . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date" 9/7/2003 9/8/2003 9/9/2003 L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To HoUrs Task Code NPT Phase" ..::....: ". 17:30 - 18:30 1.00 FISH P DECOMP 18:30 - 20:30 2.00 FISH P DECOMP 20:30 - 00:00 3.50 FISH P DECOMP 00:00 - 03:00 3.00 FISH P DECOMP 03:00 - 05:00 2.00 FISH P DECOMP 05:00 - 07:30 2.50 FISH P DECOMP 07:30 - 09:30 2.00 FISH P DECOMP 09:30 - 14:00 4.50 FISH P DECOMP 14:00 - 14:30 0.50 FISH P DEcaMP 14:30 - 15:00 0.50 FISH P DECOMP 15:00 - 15:45 0.75 FISH N WAIT DECOMP 15:45 - 16:00 0.25 FISH P DECOMP 16:00 - 17:15 1.25 FISH N STUC DECOMP 17:15 - 23:30 23:30 - 00:00 00:00 - 00:00 - 03:00 6.25 FISH 0.50 FISH 0.00 3.00 FISH P P P P DECOMP DECOMP COMP DECOMP 03:00 - 03:15 0.25 CASE P COMP 03:15 - 05:00 1.75 CASE P COMP 05:00 - 11 :00 6.00 CASE P COMP 11 :00 - 12:00 1.00 CASE P COMP 12:00 - 13:30 13:30 - 15:00 15:00 - 20:00 20:00 - 21 :00 1.50 CASE 1.50 CASE 5.00 CASE 1.00 CASE P P P P caMP caMP COMP COMP 21 :00 - 21: 15 0.25 CASE P COMP Page 6 of 27 Start: Rig Release: Rig Number: Spud Date: 12/31/1989 End: 10/15/2003 8/27/2003 10/15/2003 N2 Description of Operé:1tiors ., Est circ at 2.0 BPM; 650 psi. Tag fish 10,346'. Rotate over to dress, swallowing 4' to 10,350'. PUH clean. PT Kelly. Pump 20bbl dry job (1.5PPG above mud wt). Rack back kelly. POH stand back DP. Pulling dry. See tight spot in 5-1/2" liner, overpull 35K. No overpulls above 5-1/2" liner. Continue POH standing back DP. Stand back 12DC's, LD BHA #6. Did not recover fish. No marks on the inside of the overshot. Discuss plan forward. Gather-up some more tools. MU BHA #7 (spear with 2-5/16" nose so can't go along side fish like spear brought out to location yesterday morning), 2-7/8" collars, 4-3/4" collars. TIH. No tight spots above fish. 147k; 110k. Kelly-up est circ 1.0 BPM; 1500 psi. Tag fish at 10350' with 350 psi increase in pressure. Took about 1 Ok then skipped and got weight back. Ratty weight for next 6', then stack to 80k to 10,360'. PUH clean. Pressure dropped to 1550 psi. This drop in pressure is what we'd expect even with fish on as fish gets pulled off bottom. Repeat set down to same depth without the ratty weight seen previously. PUH 30' clean to rack back kelly. Pump dart to open pump out sub. Finish mixing dry job pill. Pump 20 bbls of 11.5 ppg flo-pro/CaC03 pill. Attempt to TOOH. Planted both directions. Continue working pipe in both directions in small increments. Got free going down, then lost 9' (debris chasing us down). Continue to work pipe. Ratty pulling. Got better after a couple of stands. TOOH, stand back DP. Stand back DC's Stand back DC's, LD Fishing BHA #7. Recoverd entire fish (2 and 1/2 jts of 2-7/8", XN nip, 9.98' Pup, Baker 50S) total of 94.2' long. Top of fish extruded out and peeled back on itself, overshot would not have got a bite. PJSM with Rig crew, TIW and BOT prior to PU polishing mill assembly. PU BHA #8, polishing mill assembly. TIH. Tag lightly with slight weight loss at 9480' DPM. PUH. RIH rotating to polish receptacle with minimal to no work. Tag at 9486'. Repeat 4 times. Polish final time to 9486', stack 3k, and mill for 5 minutes. Everything looked as it should, per TIW rep. CBU and pump dry job. Cut & slip drill line. POOH with polishing mill assembly. Stand back 12DC's and LD BHA #8. TIW Polishing mill has wear on OD and small amount of wear on the leading edge. Locator top has wear grooves on low side indicating it engaged the liner top. Mill looks as expected. PJSM with Halliburton and rig crew prior to running RITS. Printed: 10120/2003 8: 56: 59 AM .....,. - BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date : From - To Hours Task : Code: NPT Phase ............ .. 9/9/2003 21 :15 - 22:00 0.75 CASE P COMP 22:00 - 00:00 2.00 CASE P COMP 9/10/2003 00:00 - 00:45 0.75 CASE P COMP 00:45 - 01 :00 0.25 CASE P COMP 01 :00 - 02:00 1.00 CASE P COMP 02:00 - 05:00 3.00 CASE P COMP 05:00 - 05:30 0.50 CASE P COMP 05:30 - 06:30 1.00 CASE P COMP 06:30 - 18:00 11.50 CASE P COMP 18:00 - 18:30 0.50 CASE P COMP 18:30 - 20:00 1.50 CASE P COMP 20:00 - 22:00 2.00 CASE P COMP 22:00 - 22:30 0.50 CASE P COMP 22:30 - 00:00 1.50 CASE P COMP 9/11/2003 00:00 - 06:00 6.00 CASE P COMP 06:00 - 10:00 4.00 CASE P COMP 10:00 - 11 :00 1.00 CASE P COMP 11 :00 - 15:00 4.00 CASE P COMP 15:00 - 16:00 1.00 CASE P COMP 16:00 - 16:15 0.25 CASE P COMP 16:15 - 18:00 1.75 CASE N STUC COMP 18:00 - 19:30 1.50 CASE N STUC COMP 19:30 - 23:00 3.50 CASE N STUC COMP 9/12/2003 23:00 - 00:00 00:00 - 04:00 STUC COMP STUC COMP 1.00 CASE N 4.00 CASE N Page 7 of 27 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Operations PU BHA #9, Haliburton 9-5/8" RTTS packer & RTTS circ valve. RIH with RTTS packer on DP. RIH with RTTS packer. 132 jts total. Position and Set RTTS Packer at 4198', set down 20K LBs. Close 3.5" Pipe rams and line out to pressure up on the well down kíllline. PT well to 3500psi for 30min. Wellhead pressure fell to 3430psi over 30m in. Good Test. Bleed off pressure and release packer. Pump dry job and POH with RTTS packer. Pulling slow and monitoring string wt to avoid leaving any rubber behind. LD BHA #9 Prep pipe shed for loading 7" Casing Load pipe shed with 125 jts of 7" 26# BTC-M L-80 casing. Drift, strap, install teflon seal rings & install turbolators, one every two joints. Replace and adjust brake bands on draworks. Install 2-3/8" e-line reel. Install 7" pipe inserts in upper rams. MU 7" test joint. PT 7" BOP ram inserts. Good test. Continue loading pipe shed, load a total of 135jts. Drift, strap, install teflon seal rings & install turbolators. One turbo every other joint. RU Nabors casing crew and prep pipe shed, skate and rig floor to PU 7" liner. PJSM with rig crew and Nabors casing crew. Review job roles and discuss plan forward. RIH with 7" Casing for scab liner. RIH with 7" 26# BTC-M L-80 Casing for scab liner. FíIIliner as needed. 60jts picked up at 05:00. Continue to MU 7" liner assembly. (129 jts total) MU Baker liner top packer, hanger, and running tool assembly to 7" liner. RIH with liner on 3-1/2" dp. Drift dp í.d. to 2". On bottom. Wt check 185k up, 130k dn. MU cement manifold and RU cementers. Sit down on liner top, work seal assembly into liner tieback receptacle, progressively stack more wt up to 60K. Should not take this much work to get into the liner top. Bring on pumps and attempt to pressure up, no good. PU, stuck. Work pipe, pull free with 240Kup while pumping. PU above liner top. Slack off and attempt to engage lower set of seals on TIW seal assembly. Looks good, lower set of seals inside tieback receptacle, Circulate at 3bpm 1200psi, full returns. Shut down pumps, PU 200K, see wt bobble as lower seals exit liner top. Everything looks good. RIH set down 30K, top seals engaged, bring on pumps 0.65bpm @ 1000psi, no returns. Good indication top seals are engaged. Bleed off pressure. PU to expose cement ports, no good, stuck. Work pipe, and vary pump rates, unable to pull free, pull up to 250K. Formulate forward plan. Circulate, 2bpm, 11 OOpsí. Circulate, 2bpm, 11 OOpsí. Circulate cement dye around to check volumes. Dye back at surface in 528bbls. Surface to Printed: 10/2012003 8:56:59 AM --" - BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date F"rom - To Hours> Task Code NPT" Phåse ",. 9/12/2003 00:00 - 04:00 4.00 CASE N STUC COMP 04:00 - 07:30 3.50 CASE N STUC COMP 07:30 - 08:30 1.00 CEMT N STUC COMP 08:30 - 09:00 0.50 CEMT P COMP 09:00 - 09:30 0.50 CEMT P COMP 09:30 - 10:45 1.25 CEMT P COMP 10:45 - 12:30 1.75 CEMT P COMP 12:30 - 13:30 1.00 CASE P COMP 13:30 - 17:00 3.50 CEMT P COMP 17:00 - 17:15 0.25 CEMT P COMP 17:15 -18:00 0.75 CASE P COMP 18:00 - 19:00 1.00 CASE P COMP 19:00 - 21 :30 2.50 CASE P COMP 21 :30 - 22:30 1.00 CASE P COMP 22:30 - 00:00 1.50 CASE P COMP 9/13/2003 00:00 - 00:45 0.75 CLEAN P COMP 00:45 - 01 :00 0.25 WHSUR P COMP 01 :00 - 02:00 1.00 WHSUR P COMP 02:00 - 06:00 4.00 WHSUR P COMP 06:00 - 07:00 1.00 WHSUR P COMP 07:00 - 13:00 6.00 WHSUR P COMP 13:00 - 15:00 2.00 WHSUR P COMP Page 8 of 27 Start: Rig Release: Rig Number: Spud Date: 12/31/1989 End: 10/15/2003 8/27/2003 10/15/2003 N2 .. ... Description of Operations Surface vol is 622 bbls. Suspect channeling through flo pro at low pump rates (2.5 bpm). At least we know liner hanger assy is not leaking. Wait for 12ppg cement to be made up and delivered to location. OA=Opsi RU cementers and reversing hose on rig floor. Hold PJSM with all crews involved in cement job. Discuss pumping, displacement, clean up. Pump 5 bbls water. Test lines to 5000 psi. Pump 5 bbls water. Test lines to 5000 psi. Pump 30 bbls CW100 spacer. Pump 135 bbls Litecrete 12.1 ppg cement. Maintain 2.0 bpm. Pressure varied from 300 to 850 psi. Drop dart and chase with 5 bbls water. Displace cement with mud using rig pump. Dart latched liner wiper plug at 27 bbls away (same as calculated). Continue displacement with 9.9 ppg formate mud. Plug bumped at 222 bbls (calculated 223). Pressure varied from 850 to 1350 psi at 2.0 bpm. Held 1500 psi once bumped. Set down max weight on drill string. Bleed back liner to zero psi. Shut-in choke. No pressure build up. Looks like seals are holding. CIP at 12:30 PU to neutral weight (120K#). Pressure up to 4500 psi to set hanger and liner top packer. Packer sheared at 3600 psi, did not see a strong indication of hanger setting. Set slips. Rotate 12 turns to right. PU out of liner (65K# string weight). Reverse circulate out well. Got several bls cmt, strung out, then cleaned up. Continue to reverse circ to hold 850 psi back pressure on well to balance cement, in case seal stem is leaking. Pressure well to 1000 psi to test packer. Held. Bleed same. Hold PJSM before POOH. POOH with liner running tool. Inspect rig floor snub lines, grease same. Continue POOH with liner running tool. LD liner running tool. Running tool looks good. RIH with BHA #10: milling assembly to clean out 7" cement track. Cement sample compressive strength reached 11 OOpsi at 23:00 RIH with BHA #10 milling assembly to 1793' on 44 jts DP. Approx 30k Ibs will be hanging off packer. PJSM with halliburton prior to running storm packer. Discuss ND BOP after running Storm packer. MU Storm packer. RIH and set storm packer, hang 44jts 3.5" DP and BHA#10 below the storm packer. Rotate to release from packer, LD running tool & PT to 1000psi from above. Good test. Bleed off pressure and blow down stack. Remove riser, ND stack. Cameron on location. Hold PJSM before lifting stack. Risk assess cutting tubing head spool bolts with torch. Line up extinguishers, water hose, fire blankets, extra fire watch. Cut tubing head spool nuts off studs. Remove 13-5/8" tubing head. Pull 9-518" packoff. Install new packoff and 13-5/8 x 13-5/8 tbg spool. Test same to 3500 psi. Swap out 7" for 3-112" inserts. Remove 13-5/8 x 11" spool. NU Printed: 10/2012003 8:56:59 AM . . Page 9 of 27 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date Start: Rig Release: Rig Number: Spud Date: 12/31/1989 End: 10/15/2003 8/27/2003 10/15/2003 N2 From - To Hours Task Code NPT Phase Description of Operations 9/13/2003 13:00 -15:00 2.00 WHSUR P 15:00 -16:00 1.00 WHSUR P 16:00 -17:00 1.00 WHSUB P 17:00 -18:00 1.00 CASE P 18:00 -19:15 1 .25 CLEAN P 19:15 - 23:10 3.92 CLEAN P 23:10 - 00:00 0.83 CLEAN P 9/14/2003 00:00 - 00:30 0.50 CLEAN P 00:30 - 02:00 1.50 CLEAN P 02:00 - 03:00 1.00 CLEAN P 03:00 - 04:30 1.50 CLEAN P 04:30 - 05:30 1.00 CLEAN P 05:30 - 07:00 1.50 CLEAN P 07:00 - 10:00 3.00 CLEAN P 10:00 - 15:00 5.00 CLEAN P 15:00 - 17:00 2.00 CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 22:00 4.00 CLEAN 22:00 - 00:00 2.00 CLEAN P 9/15/2003 00:00 - 07:00 7.00 CLEAN P 07:00 - 08:00 1.00 CLEAN P 08:00 - 09:00 1.00 CLEAN P 09:00 - 09:30 0.50 CLEAN P 09:30 - 12:30 3.00 CLEAN P 12:30 -15:30 3.00 CLEAN P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP BOPS & riser. Test 3-1/2" rams and other BOP breaks. Engage Storm packer with running tool on DP. POOH to surface with same. LD storm packer. Test scab liner to 3500 psi for 30 minutes. Record same. Test good. Inspect and adjust air boot on riser. RIH with BHA#10 milling assembly. Tag at 9401 DPM. Set down 10K. PU, MU kelly. Wt check 120K dn, 140K up. 3bpm, 760psi, 300amps. Start milling with 5-8K down 310-320Amps, 3bpm/760psi. Continue milling with 5-10K down, 3bpm. Mill 17' to 9418' and stop making progress. Mill wI increasing weight up to 25K down, very slow going. PU twice and Vary RPM and pump rate. Likely milling on Latch collar. Cement is X linking mud polymer, add some Citric acid, temporarily slow pump rate down to 2.5bpm to avoid losing mud over shakers. Get weight back and break through. PU and make a back reaming pass, clean PU. Continue milling 5-10K dn, 3bpm, 760psi, 250-300amps. Make good progress through cement with little resistance until 9459'. Set down 1 OK-20K and continue milling, slow progress. Milling on floats. Break through floats. Make two backreaming passes across float area. Continue milling, mill easily to 9479', stop making progress. Mill with 10-25K, very slow progress. This is likely the aluminum bullnose. RIH to 5-1/2" liner top. Tag at 10162' dp depth. PU kelly. Circulate bottoms up at 6.5 bpm 11650 psi. Rotate drill string slowly. Getting a lot of solids and clabbered mud over shaker. Hold on tour TL mtg while circulating. Set back kelly. Pump dry job. POOH with 6-1/8" clean out assy. LD half of the 4-3/4" collars and other BHA components. Bit in good condition. Load 2-7/8 PAC and 3-1/8" drill collars into pipe shed. MU BHA #11: 5-1/2" liner clean out assembly with 4.75" mm mill on Anadrill 3.5" motor. Adjust little jerks, not biting well on 3-1/8" DC's. RIH with BHA #11 to cleanout 5-1/2" "nero Continue RIH with BHA #11. Clean pits to prep for milling fluid. Haul off used formate mud for injection. Tag up at top of 5-1/2" liner. LD stands from derrick. RU to circulate. Drill string plugged. Pressure up DP and work pipe. Establish circulation. Circ one DP volume to clear same. Pressure test casinglliner to 1500 psi. Held solid. Displace well to 8.5 flopro lite. Tag up at 10160'. 120K down, 150K# up wt. 2.75 bpm @ 600 psi FS. Begin milling junk. Unable to keep from stalling. Stall pressure= 1250 psi. Continue to work pipe. Try setting down hard with pumps off. Try varying pump rate while creeping Printed: 10120/2003 8:56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/15/2003 ..., .. Page 10 of 27 BP EXPLORATION Operations Summary Report Phase COMP 15:30 - 16:45 1.25 CLEAN P 16:45 - 00:00 7.25 CLEAN P 9/16/2003 00:00 - 01 :30 1.50 CLEAN P 01 :30 - 04:00 2.50 CLEAN P L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From.,To I Ho~rs, Task Code' NPT 12:30 - 15:30 3.00 CLEAN P 04:00 - 06:15 06:15 -13:00 13:00 - 14:30 14:30 - 15:00 15:00 - 22:00 22:00 - 23:00 COMP COMP COMP COMP 2.25 CLEAN P 6.75 BOPSURP COMP COMP 1.50 CLEAN P 0.50 CLEAN P 7.00 CLEAN P 1.00 CLEAN N DPRB COMP COMP COMP COMP 23:00 - 00:00 1.00 CLEAN N DPRB COMP 9/17/2003 00:00 - 06:00 6.00 CLEAN N DPRB COMP 06:00 - 08:00 2.00 CLEAN N DPRB COMP 08:00 - 09:30 1.50 CLEAN N DPRB COMP 09:30 - 14:30 5.00 CLEAN N DPRB COMP 14:30 - 16:30 2.00 CLEAN N COMP 16:30 - 22:00 5.50 CLEAN N COMP 22:00 - 00:00 2.00 CLEAN N COMP 9/18/2003 00:00 - 03:00 03:00 - 06:00 06:00 - 06:30 06:30 - 13:30 13:30 - 15:30 15:30 - 15:45 3.00 CLEAN P 3.00 CLEAN P COMP COMP 0.50 CLEAN P 7.00 CLEAN P 2.00 CLEAN P COMP COMP COMP 0.25 CLEAN P COMP Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 . . .. . ... . ... Òèšcription of Operations down hole & with brake locked just above junk. Never able to get anything but a stall after contacting junk. Drop and circulate circ sub dart down to BHA. Sheared at 2400 psi. Mix and pump small dry job. POOH with milling assy. POOH with milling assy. Stand back DC's. LD BHA #11. Both 3.5" boot baskets contained aluminum cuttings, and formation, 1/2 gallon total. Mill was in good condition, missing one button, no apparent wear pattern on the mill face. Two aluminum pieces were lodged in between the blades on the gage of the mill. One of the pieces of junk looked like it had teeth marks from the HCC 6-1/8" AT J4 we ran to mill the 7" shoe. Slip and Cut Drill line. Organize rig floor. Test BOP equipment. Test witness waived by J. Jones, AOGCC. SOme trouble getting the new Cameron test plug to hold in replacement tbg head. Ran in several lock down screws and plug held. MU 4-3/4" roller cone bit & BHA. PJSM RIH to 7213'.50 stands after crew change. Attempt ot break circulation. Pressured to 4000 psi. Plugged. Attempted to surge pipe pressure to 2500 and bleed off. No Go. Attempt to reverse at 1500 psi. No Go. Re try surging. No Go. POH wet. Continue to POH wet. Stand back BHA. Break off bit. Found about 8' of aluminum & metal chunks above bit and up past boot baskets. (Boot basket id is 3/4", bit has three 3/4" nozzle ports) MU bit and BHA. Add drill pipe float to btm of string. RIH with clean out assembly. Circulate every 20 stands while RIH. At top of 7" liner. Pump 25 bbl hi vis pill with 0.5 ppb super swwep fibers. Did not see much metal in returns. Continue to RIH. Circulate every 20 stands. PU and pressure test Kelly 300psi low and 3500 psi hi. RIH tag liner top at 10,162'. 137K up weight. 1 08K dn weight. Free rotating torque 2250 ft-Ibs. Rotate off liner top. No Junk to mill. Rotate and wash thru liner top. RIH tag at 10,430. PU weight 137K. Dn weight 112K. Drill cement stringers at 36 RPM 6 BPM 1,720 psi. 2250 - 3750 ft-Ibs. Acts like we are pushing junk. At 10,438 torquing junk above bit worked pipe. No jarring. Attempt to drill acts like on junk no progress last half hour. Clculate. Stand back kelly. Mix & pump small dry pill. POOH with milling/bit assembly. Stand back 4-3/4 collars, PAC pipe, 3-1/8 drill collars. Break off bit and empty boot baskets. Several pieces of aluminum, packer slips, rubber, retaining rings. Bit showed severe junk damage, cones pinched. Bit would not have lasted much longer. Test new gen set controls by loading same with draworks. Printed: 10120/2003 8:56:59 AM ~ .. Page 11 of 27 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task'" Cod~ ...NPT Phase 9/18/2003 15:45 - 17:30 1.75 CLEAN P COMP 17:30 - 00:00 6.50 CLEAN P COMP 9/19/2003 00:00 - 02:00 2.00 CLEAN P COMP 02:00 - 03:00 1.00 CLEAN P COMP 03:00 - 03:30 0.50 CLEAN P COMP 03:30 - 04:00 0.50 CLEAN P COMP 04:00 - 07:15 3.25 CLEAN P COMP 07:15 -11:00 3.75 CLEAN P COMP 11 :00 - 15:00 4.00 CLEAN P COMP 15:00 - 16:30 1.50 CLEAN P COMP 16:30 - 17:30 1.00 CLEAN P COMP 17:30 - 00:00 6.50 CLEAN P COMP 9/20/2003 00:00 - 06:00 6.00 CLEAN P COMP 06:00 - 07:00 1.00 CLEAN P COMP 07:00 - 07: 15 0.25 CLEAN P COMP 07:15 - 08:30 1.25 CLEAN P COMP 08:30 - 16:00 7.50 CLEAN P COMP 16:00 - 20:00 4.00 CLEAN P COMP 20:00 - 22:00 2.00 CLEAN P COMP 22:00 - 00:00 2.00 CLEAN P COMP 9/21/2003 00:00 - 02:30 2.50 CLEAN P COMP 02:30 - 03:30 1.00 CLEAN P COMP 03:30 - 11 :30 8.00 CLEAN P COMP 11 :30 - 14:30 3.00 CLEAN P COMP 14:30 - 15:30 1.00 CLEAN P COMP Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Operations .. . MU 4-314" tappered MM mill on collars & 2-7/8 drill pipe. MU jars and 4-3/4" collars. RIH with milling assembly on drill pipe. RIH to 10,162'. liner top. No GO. PU Kelly dress top of liner. Stand back Kelly. RIH to 10,430'. PU Kelly tag at 10,441'. Up weight 128K. Down weight 108K. Mill junk and cement. Establish pattern at 4 bpm 890 psi 2-5 K WOB. 4000 ft-Ibs. Off bottom 3500 -5000 ft-Ibs on bottom. Increasing rate to 8 bpm. Mill to 10470'. Continue milling cement/junk. No evidence of junk above mill when PU singles. 8.0 bpm @ 2600 psi. Torque:3500 off btm/4500 on btm. Continue milling cement at 10500'. Drill parameters staying constnat. ROP: +1- 10 fph. Mill to 10535'. Ciculate 35 bbl super sweep (0.3 ppb in 100K LSRV flo vis). Got a lot of small metal cuttings back. Continue to get good cement returns over shaker while milling, before and after sweep. Milling cement. 3500 amps off btm. 4500 amps on btm. 2600 psi @ 8 bpm. Mill to 10563'. ROP dropped to zero, torque has slowly increased to 4000 - 5000 ftllbs on btm. PU off btm. Work pumps & drill string. Cannot get it drilling again. POOH with milling assembly. Tight at 10,450. Pull 30 Kover. Tight at 10320' PU head pin and circulate 4 bpm. PU no over pull. Continue to POH. Continue to POH. Tight at 9250 (inside 7" scab liner). Work past and continue out of hole. Remove mill and junks baskets. Baskets full of material, large amount of packer slip chunks, roughly thumb sized & smaller. Mill completely worn, all mm buttons gone, several water courses jammed with junk. Signs of scarring on worn mill face indicating junk still on btm. Pressure test wellbore to 500 psi. Bleed off 200 psi in 2 minute. Probably going into perfs above clean out depth. MU 4-3/8" mm mill with additional boot baskets RIH with milling BHA. Through top of 5-1/2" liner - never saw it. PU singles from pipe shed. PU kelly. 2400 psi @ 6.5 bpm. 138k# up, 11 08k# down. 220 amps/3500 ft-Ibs of btm rotating. Tag up and begin milling. 1000-1200 ft-Ibs torque above free spin while milling. First 2 feet hard drilling on junk then broke thru. Drill to TD 10620. Circulate sweep. Ream 10555 -10575. Whipstock setting depth. Wait on KCL. With loss rate of 13 bph need additional fluid to POH. Decided to change over to KCL.Old mud worn out. Continue to change over to KCL. Blow down and stand back kelly. POH standing back. LD 2-7/8 dp & 3-1/8" drill collars. Mill in good condition. Boot baskets full of metal junk, thumb sized packer slip chunks. Slip and cut drill line. Filling hole continuously. Taking 11 bph KCL under static conditions. Printed: 1012012003 8:56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ·"Date 9/21/2003 9/22/2003 9/23/2003 9/24/2003 9/25/2003 .. Page 12 of 27 BP EXPLORATION Operations Summary Report L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 15:30 - 15:45 From - To HoDrs Task Code NPT Phase;:·· .. . .. . .. . Description of Operations 15:45 - 17:00 17:00 - 00:00 00:00 - 00:30 00:30 - 03:00 03:00 - 06:00 06:00 - 07:00 07:00 - 19:00 19:00 - 20:30 20:30 - 00:00 00:00 - 01 :30 01 :30 - 06:00 06:00 - 06:15 06:15 -14:30 14:30 - 16:00 16:00 -16:30 16:30 - 00:00 00:00 - 05:00 05:00 - 06:15 06:15 - 06:45 06:45 - 14:00 14:00 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 21:15 21 :15 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 04:00 0.25 CLEAN P 1.25 CLEAN P 7.00 CLEAN P 0.50 CLEAN P 2.50 CLEAN P 3.00 CLEAN P 1.00 CLEAN P 12.00 CLEAN P 1.50 CLEAN P 3.50 CLEAN P 1.50 CLEAN P 4.50 RUNCOMP 0.25 RUNCOMP 8.25 RUNCOMP 1.50 RUNCOMP 0.50 RUNCOMP 7.50 RUNCOMP 5.00 RUNCOMP 1.25 RUNCOMP 0.50 RUNCOMP 7.25 RUNCOMP 3.50 RUNCOMP 0.50 RUNCOMP 0.50 RUNCOMP 2.75 RUNCOMP 1.25 RUNCOMP 1.50 RUNCOMP 2.50 RUNCOI\IfII 1.50 RUNCOMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP WAIT COMP COMP Rig evacuation drill. Test light & siren system. Secure well. Muster in Tech Limit shack. Continue to cut & slip drill line. RIH with 7"casing scraper Continue to RIH with 7" casing scraper. Mix 50 bbl pill and circulate to shoe 3.5 bpm @ 480 psi. Shut in and pull head 10 bbl to formation 2.3 bpm at 710 psi final rate .4 bpm at 710 psi. Circulate bottom up 5 bpm at 1200 psi. Small amout of materail over shaker, appears to be cement cuttings. Hold PJSM before beginning LD operation. Rig up floor for same. C. Scheve with AOGCC granted 24 hour extension for weekly BOP test to accomodate running completion and BOP change out. POOH and LD 3-1/2" drill pipe. Fill hole every 10 jts. PU Kelly. Break down Kelly Remove Kelly hose LD BHA and Kelly swivel. Pull mouse hole. Clear floor. LD Kelly and mouse hole. Load completion assessories packer, GLM's,TRSV & nipples. Load pipe shed. Drift and tally pipe. 120 joints by 0600 (30 per hr) Crew change. Hold pre tour TL mtg, and brief PJSM before resuming pipe shed loading. Continue to load pipe shed with tubing. RU rig floor to run completion. Safety meeting for running tubing. Run 4-1/2" L-80 tubing completion. Continue to RIH with 4-1/2 L-80 completion string. PU TRSSV Load CL spooler and spool onto floor. Hang sheave. Crew change safety meeting. Hook-up CL to SSSV, pressure to 5000 psi. Continue RIH with 4-1/2" tubing, using one CL clamp per joint. TOTAL OF 71 BANDS USED FOR SSSV CONTROL LINE. RU to reverse circulate hi-vis sweep and corrosion inhibited fluid. Close bag. Break circulation, reverse 50 bbls of 100k+ LSRV pill, 175 bbls of KCL water, and 200 bbls of KCL plus 1 drum of Corexit corrosion inhibitor. Pump at 2.9 BPM; 200 psi lAP. Losses averaged 35 BPH. Total lost during reversing = 90 bbls. MU hanger. PJSM land hanger. Reverse circulate in 135 bbl of dead crude. 450 psi at 3 bpm. Drop ball and rod to set packer. Because of 40 landing joint. Unable to break 3-1/2 IF connection on top to launch ball and rod. Back out and LD landing jouint. remove XO. Reland to drop ball and rod. LD landing joint and MU XO TIW and swivel. RU circulaating hose. Pressure up . Leak in XO on landing joint 4-1/2 IF to 3-1/2IF. 40' landing joint prohibits using rig tongs to tighten IF connection. 15' above floor. Call out pups to MU shorter joint. Need TC-II top and bottom connection. Wait on arrival of pups joints to build new landing joint. Pressure to 2000 psi to shear packer. Pressure to 3500 psi. Printed. 10120/2003 R56.59 AM ~ .. Page 13 of 27 BP EXPLORATION Operations Summary Report COMP Hold for 30 minutes. Good Test. Bleed tubing back to 1500 psi. Pressure IA to 3500 psi. Hold for 30 minutes. NO Test. Landing hanger leaking. COMP Bleed of backside and retighten lock down screws. Out of crude will retest with methanol. Pressure IA to 3497 bleed to 2718 in 20 minutes. OA pressured rose from 0 to 800 psi in 20 minutes. Terminate test. Checked 9-5/8 packoff - no pressure in void. Bleed IA from 2700 to 100. Bleed tubing to O. COMP Crew change, make rounds, check well status. COMP IAP/OAPfTP = 190/18010. Pressure IA with 2.5 bbls methanol -- 1980/43010. Shut-in. After 30 minutes: 1615/740/0. No leak around tubing hanger. Bleed OA into a couple buckets -- looks, smells, feels like mostly methanol (note that no methanol was pumped into the OA during or after the OA downsqueeze). Re-check void between upper and lower 9-5/8" packoffs -- no pressure. Perform postive pressure test on this void to 4500 psi -- good test. Bleed IA. WOO RU to pump down IA and OA simultaneously. PT IA and OA to 800 psi. Bled 40 psi in 30 min. PT IA and OA to 2000 psi. Bled 70 psi in 30 min. PT IA and OA to 2750 psi (80% of 13-3/8" 68# K-55 burst). Bled 70 psi in 30 min. Bleed down annuli. RD Little Red. RD manifolding on IA and OA. LD landing pups. Chug stack dry. Set TWC. Bleed CL to close SSSV. Cut CL. Safety meeting - ND stack. ND BOPE. NU adapter flange and 4-1/2" tree and pressure test tree. NU 7" BOPE. Crew change safety meeting. Continue NU BOPE. PT BOPE. Witness waived by AOGCC's Lou Grimaldi. Wait on BPV lubricator/crew from Rig 2ES -- only one available. RU BPV lubricator. Pull TWC. PJSM for wireline activity. RU slick line and RIH. Tag On SSSV2,202' WLM (control line had 3750 psi). POH to surface. Repressure TRSSV control line to 5000 psi. RIH tag at 10,042' WLM recover ball and rod. RIH and latch RHC plug. POH GS sheared while jarring. RIH second attempt to recover RHC. Recover RHC from 10,050 WLM. Fill hole well took 12 bbl. PU and RIH with dummy whipstock. RIH thru tubing and set down at liner top 10,167. Picked up and set down 2 'deeper slight over pull 200#. Consult with PE's Jeff Jones & Jerry Boíies Currently pinned with brass afraid we could shear GS (GS shears down) POH. Found new gouges on top third of dummy WS. Look like we were partially thru top. WEXIT Crew change safety meeting. DPRB WEXIT MU and RIH with 3.5" OD x 10' pump bailer with mule shoe bottom. RIH. Tag 10168'. No progress after numeraous attempts. Solid tag and clean PU on each attempt. POOH. One ding on MS, a couple tablespoons of parafiin/pipe scale. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date .,_Frbm - To Hours Task "Code NPT"- Phase 9/25/2003 02:30 - 04:00 1.50 RUNCOIIIP 04:00 - 06:15 2.25 RUNCOMN 06:15 - 07:15 07:15 - 09:00 1.00 RUNCOMN 1.75 RUNCOMN 09:00 - 10:30 1.50 RUNCOMN COMP 10:30-11:15 0.75 RUNCOMN COMP 11:15-13:15 2.00 RUNCOMN COMP 13:15 - 16:00 2.75 RUNCOIIIP COMP 16:00 - 16:15 0.25 RUNCOIIIP COMP 16:15 - 16:30 0.25 BOPSURP WEXIT 16:30 - 23:00 6.50 BOPSURP WEXIT 9/26/2003 00:00 - 04:00 4.00 BOPSURP WEXIT 04:00 - 06:15 2.25 BOPSURP WEXIT 06:15 - 06:45 0.50 BOPSURP WEXIT 06:45 -11:15 4.50 BOPSUR P WEXIT 11:15 -16:45 5.50 BOPSUR P WEXIT 16:45 - 17:15 0.50 BOPSURN WEXIT 17:15-18:30 1.25 BOPSUR P WEXIT 18:30 - 19:00 0.50 STWHIP P WEXIT 19:00 - 00:00 5.00 RUNCOIIIP COMP 9/27/2003 00:00 - 03:00 3.00 RUNCOIIIP COMP 03:00 - 06:15 3.25 STWHIP P WEXIT 06:15 - 06:45 06:45 - 10:00 0.50 STWHIP P 3.25 STWHIP N Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 . . .. .. .. . . ... . ._ Descriþtion of Operations Printed, 10120/2003 8;56:59 AM ... .. Page 14 of 27 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date ; I : From - To : Hours Task ! Code NPT· Phase . . ...-..-..... 9/27/2003 3.25 STWHIP N 0.50 STWHIP P 0.25 STWHIP P 2.25 STWHIP P 2.50 STWHIP P 06:45 - 10:00 10:00 - 10:30 10:30 - 10:45 10:45 - 13:00 13:00 - 15:30 15:30 - 17:30 2.00 STWHIP P 17:30 - 20:30 3.00 STWHIP N 20:30 - 22:30 2.00 STWHIP N 22:30 - 23:00 0.50 STWHIP N 23:00 - 23:20 0.33 STWHIP N 23:20 - 23:30 0.17 STWHIP N 23:30 - 00:00 0.50 STWHIP N 9/28/2003 00:00 - 01 :00 1.00 STWHIP N 01 :00 - 01 :45 0.75 STWHIP N 01 :45 - 03:00 1.25 STWHIP N 03:00 - 04:30 1.50 STWHIP N 04:30 - 06:15 1.75 STWHIP N 06: 15 - 06:45 0.50 STWHIP P 06:45 - 08:15 1.50 STWHIP P 08:15 - 10:15 2.00 STWHIP P 10:15-11:00 0.75 STWHIP P 11:00-13:00 2.00 STWHIP N 13:00 - 16:45 16:45 - 17:00 3.75 STWHIP N 0.25 STWHIP N 17:00 - 19:00 19:00 - 20:00 20:00 - 22:00 22:00 - 00:00 2.00 STWHIP P 1.00 STWHIP P 2.00 STWHIP P 2.00 STWHIP P 9/29/2003 00:00 - 08:00 8.00 STWHIP P DPRB WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT DPRB WEXIT WEXIT WEXIT WEXIT WEXIT DFAL WEXIT SFAL WEXIT SFAL WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Operations .. - -..- ..-..... ..... - . "..,.,-.--........ RD slickline. Clear floor and tongs. Fill hole -- 11 bbls. Safety meeting. PU injector. Stab pipe. Prep end of E-line (epoxy). Stab inj on well. Reverse circulate 3.5 BPM to move back slack and to displace methanol freeze protect fluid. Cut 100' of coil (found cable 91' back). Check cable continuity. Install CTC and cable head. MU dressing BHA: Used diamond whipstock mill and string reamer. RIH. Run thru liner top without pumps. didn't see liner top. RIH to 10,285'. 42K up wt. 19K dn wt. Tie-in. Correction -5'. Continue to RIH Tag TD 10,606' POH to 10'167'. To liner top. Backream 2.48 bpm 1660 psi thru liner. Seen nothing. POH. POH to surface. LD BHA 17 and PU dummy whipstock BHA# 18 RIH to 2100'. Gauge on TRSSV control line pegged out( thermal expansion). Change out gauge and adjust pressure to 4700 psi. Continue to RIH 1.5 bpm at 550 psi to 10,609 CTM uncorrected. Clean all the way. POH to surface. Crew change safety meeting. LD dummy whip. MU whipstock and setting tool BHA# 19. RIH. Log tie-in at 10295' GR depth. Correct depth (-6'). RIH and log top of lisburne 10,550'. Correct depth (-3'). Position whipstock on depth. Attempt to orient whipstock from 180 to highside. Orienter not working correctly. Able to move TF 40 deg left to the "stop", but can't get TF past about 20 - 40 deg right of lowside. Acts like weak orienter. No indications from current that tools are in a bind. POOH. At 8600' able to manipulate TF enough to get to highside and hopefully keep it as we RIH. RIH. Looks like we're about 20L just as we approached setting depth. Then short in system. Trouble shoot short. Located at plug-in in collecter. Fix. Recheck tie-in. Correct depth (-1'). Position whipstock on depth. TF at 2L. Close EDC. Pressure up to set whipstock. Shear at 3600 psi. Stack 8k down. Whipstock set with top at 10568' and RA tag at 10577'. Flag pipe at 10000' EOP. POOH. LD setting tools and PU Window milling BHA# 20. RI H to flag correct to flag -11'. RIH to top of whipstock. 43K up wt. 19K dn wt. Tag with minimum pump at 10,571'. PU to 10,555. increase rate to 2.6/2.48 bpm @ 1600 psi = FS. Tag 10,569. Begin milling 2.6/2.47 bpm @1770 psi WOB 1 K DH annular pressure 3,990 psi, DH coil pressure 4,373 psi. Mill to 10,571. Continue to mill window. 2.6/2.6·bpm 1900 psi. FS = 1,700 psi. 100 - 200 psi MW. WOB 2K. At 10,575' (6' milled), started Printed: 1012012003 8:56:59 AM ..... .. Page 15 of 27 BP EXPLORATION Operations Summary Report WEXIT losing returns 2.6/1.7, but returned to full returns within 15 minutes. Continue time milling with minimal motor work, purposely going slow. Pump a couple more 20 bbl sweeps (3.0 PPB bio). Returns fluctuating, but mostly staying 100%. At 10, 569 started pushing on it a little to 10 FPH, 1.5k WOB, 200 psi MW. WEXIT Mill formation to 10,585' at 10 - 20 FPH. Ream and backream window without seeing any more MW. RIH and POOH thru window dry - clean. Continue reaming window area -- send last 15 bbls of 150K LSRV bio pill followed by used Flo-Pro mud. Metal on magnets looked normal. WEXIT Sweep open hole, chase pill OOH while POOH at 2.9 BPM. Slow down in 7-5/8". POOH. Seeing more losses with the mud. At 9000' and with mud all the way around, stop and check losses 2.9/1.5. POOH at 2.9 BPM. Both IA and OA at 1000 psi - bleed off a couple hundred psi. LD milling BHA. Normal wear; both mills at 3.79" OD. Abandon rig drill. MU drilling BHA (BHA #21): 3 deg motor; DPI SP3BBM. RIH. Correct depth at flag (-4'). Orient high side thru liner top -- no trouble. Log down across 10550' marker. Correct depth (-2'). Tag TD try 10587'. Not a bobble thru window at HS TF. Drilling at 2.7/1.8.bpm By 10,600', 2.7/1.0,bpm then gained some. Drilled to 10,6222.7/2.0 bpm. Directionally drill build 2.6 12.0 bpm at 3230 psi. DH annular pressure 4570 psi. DH coil pressure 5165 psi. ECD 10.11 ppg. WOB 4K. while drilling at 10,640'. Drilled to 10650. Break thru hard spot. Lost all returns. Corrected TOP of whipstock 10,567'. Window 10568 -10574'. RA tag 10576'. PROD1 Directionally drill 2.61 0-.7 bpm. @ 3014 psi. DH annular pressure 4465 psi. DH coil pressure 4960 psi. WOB 5K. Spotty drilling. Drill thru hard spots drill ahead to hard spot. 2.6/1.5 bpm 3500 psi. FS = 3000 psi. WOB 8-1 OK. Gas in returns taking returns thru gas buster. Out of mud. Circulate KCL in to bit. Hard drilling at 10670. 2.5/1.9 bpm @ 3250 psi Continue to drill. No progress. Decided to POH to look at bit. POH while circulating in KCL. POH to 5173. Oil in returns. Shut down. Well flowing. RIH. Hung up in GLM # 3 . Orient. Continue to RIH tag GLM #4. and X nipples. RIH to 10505. Circulate via drillers method at 1000 psi. Show a gain. Shut down and start over. Static bottom hole pressure recording 9.2 ppg. Shut in 300 tubing psi at 10505 MD 8706 TVD BKB with 8.4 ppg KCL. Notify Ted Stagg decide to call out brine 9.3 ppg brine versus mud. DPRB PROD1 Circulate out kick using drillers method. 1060 psi 1.5 bpm. Monitoring down hole 9.4 ECD. Periodically oil in returns. DPRB PROD1 Continue circulating 1.55/1.46, 1100 CTP, 210 WHP. DPRB PROD1 SI well and monitor PBU until stablized: SICTP = 280 psi; SIWHP = 330 psi. BHP = 4170 psi (measured). Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 ... Date .. . . Task Cod~ ;"NPT :¡'Phase··· From -1'0 Hours 9/29/2003 00:00 - 08:00 8.00 STWHIP P 08:00 - 10:00 2.00 STWHIP P 10:00 - 13:00 3.00 STWHIP P 13:00 - 13:30 0.50 STWHIP P WEXIT 13:30 - 13:45 0.25 DRILL P PROD1 13:45 - 14:15 0.50 DRILL P PROD1 14:15 - 14:15 24.00 DRILL P PROD1 14:15 - 14:45 0.50 DRILL P PROD1 14:45 - 18:00 3.25 DRILL P PROD1 18:00 - 20:45 2.75 DRILL P PROD1 20:45 - 00:00 3.25 DRILL P 9/30/2003 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01 :30 1.00 DRILL P PROD1 01 :30 - 01 :40 0.17 DRILL N DPRB PROD1 01 :40 - 02:30 0.83 DRILL N DPRB PROD1 02:30 - 03:30 1.00 DRILL N DPRB PROD1 03:30 - 06:00 2.50 DRILL N 06:00 - 08:00 08:00 - 08:30 2.00 DRILL N 0.50 DRILL N Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Operations.:. . .... ...... Printed, 10120/2003 8,56:59 AM -- .. Page 16 of 27 BP EXPLORATION Operations Summary Report Circulate well to 9.3 ppg brine on choke 1.6/1.0. BHP constant throughout displacement at about 4290 psi. At MM in and out of 9.3 ppg, SD pump and check for flow. Flowed a little (probably still a little out of balance CT to CT annulus) then stopped. BHP dropped from 4225 psi to 4200 psi during flow check. RIH to TD. 2.63/1.77. Orient. Slow. Drawing a bunch of current (could be failed GR doing this). Attempt to drill from 10670' and to check losses. 2.6/2.0,2470 FS, 700 - 800 psi MW, BHP = 4390 psi. No progress. A little more gas coming to surface. SI. SIWHP = 150 psi. Circulate out 1.5 BPM thru buster on choke -- BHP stayed above 4270. Go back thru MM -- 1.5/1.4. Check resulting WHP under drilling conditions with choke closed. After 30 minutes at 2.77 BPM: WHP = 425; BHP = 4630; CTP = 2560. Pressure rose gradually during entire test and was still rising at end of 30 minutes. Open well back to FOC and 1.4 BPM. In 10 minutes, BHP at 4370 and slowly dropping. DPRB PROD1 Displace well to 9.5 ppg to get us -130 psi above apparent reservoir pressure noted this morning. Final conditions 2.6/1.9 and 2700 CTP; 4480 BHP. Continue getting pockets of gas and oil. Circulate until get good 9.5 back. SI pump and flowcheck. Flow stopped as BHP leveled out at 4320 psi. POOH. Monitor well. No flow. Change out BHA. Motor setting 2.7 deg. Hole stable during BHA change. Pumped 7 bbls before circulation. RIH. Correct to flag at 10070' a -7'. RIH to 10570'. Tie-in to RA tag -3'. Continue with MAD pass to TD. Corrected TD 10669'. Continue drilling build section. Break-in new bit. Started drilling good after 10-15min. With 9.5 brine 2.65bpm in 11.65 bpm out 2570 psi FS 500 psi MW. BGG increasing f/700u after 20 bbls up then to 2000u after 37bbls up and slowly falling. ROP 20-30'/hr. Bottoms up gas> 2000u turned into buster. Swapped to 8.4ppg 2% KCL. In and out of buster watching BBG. Drilled to 10693'. PROD1 Continue drilling build section from 10693'. Pumping 8.4ppg KCL displacing 9.5 from hole. Motor stall at 10695'. Void to 10697' lost returns momentarily. 2.65/1.87 8.4/9.3ppg After 8.4 turned corner maintaining 9.8ppg ECD slowly closing in well with Super choke. Well completely shut-in. Pumping 2.5bpm annular BHP steadily increased to 10.3 ECD 4670 psi. Slightly opened choke to gas buster and maintaining 650-800 psi wellhead, +1-10.3 ECD. BGG +1- 800u after gas buster. Drilled to 10730' landing at 90 deg and 10' higher to planned landing. DPRB PROD1 Call town to discuss kill procedures options with Ted Stagg and previous drilling parameters prior to TOH. Decide to do injectivity test down backside. DPRB PROD1 Line-up on backside. Bit @ 10400' static ECD 9.98ppg wellhead pressure 625 psi. Pumping 8.4 ppg down coil at 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 : : Date . From - To Hours Task . COde: NPT ¡ Phase , : 0"._... . 9/30/2003 08:30 -11:15 2.75 DRILL N DPRB PROD1 11:15 -11:50 0.58 DRILL N DPRB PROD1 11:50 -12:20 0.50 DRILL N DPRB PROD1 12:20 - 12:45 0.42 DRILL N DPRB PROD1 12:45 - 14:45 2.00 DRILL N DPRB PROD1 14:45 - 15:30 0.75 DRILL N DPRB PROD1 15:30 - 17:00 1.50 DRILL N 17:00 - 17:30 0.50 DRILL N DPRB PROD1 17:30 - 19:15 1.75 DRILL P PROD1 19:15 - 20:05 0.83 DRILL P PROD1 20:05 - 22:05 2.00 DRILL P PROD1 22:05 - 23:00 0.92 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 10/1/2003 00:00 - 02:15 2.25 DRILL P 02:15 - 03:20 1.08 DRILL N 03:20 - 03:35 0.25 DRILL N Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Operations -.. .--,.-...-...- .....--.-----.... Printed: 1012012003 8:56:59 AM ..... . BP EXPLORATION Operations Summary Report Page 17 of 27 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Date : From - To I Hours Task Code NPT; Phase : Description of Operations . .--- ... .. .-.....--........... -.... - . ... .-- ..--. ...-.- ...--. -.--. .---.. ..--.--.,.,.,.,... 10/1/2003 03:20 - 03:35 0.25 DRILL N DPRB PROD1 bpm maintain injectivity at +1- 1250psi. ECD raised to 10.73 slowed pump to 3 bpm and leveled off at 1060 psi. Shutdown pump after pumping 57 bbls. 03:35 - 04:50 1.25 DRILL N DPRB PROD1 Observe well and static ECD's. Quickly lowered to 10.4ppg, after 10mins at 10.3ppg, after 30min 10.1 Rebuilding kill weight volumes to 9.7ppg and continue to monitor well. 04:50 - 06:00 1.17 DRILL N DPRB PROD1 Line up down coil. Wellhead 575psi static ECD 10.0 Bullhead down coil and displace coil to 9.75ppg brine. Pumped 60 bbls at 2.65 bpm final ECD 10.65, injection pressure stablized around 780 psi. Line-up downline annulus. Bullhead at 4.2bpm 1270psi wellhead. Pumped 155 bbls. Final injection was still 1250 psi. Static ECD 11.3. Dropped quickly to 11.0. 06:00 - 08:00 2.00 DRILL P PROD1 TOH. Bleed pressure off WHP. Because of overcharge, well flowed steady -1.5 BPM while POOH. Bump up. SD pump. Well still flowing 1.3 BPM. Total of 90 bbls flowed back from formation. Returned density still at 9.7. SI well, close SSSV, open well and check for flow. 08:00 - 08:30 0.50 DRILL P PROD1 Flow check (pressure test of SSSV). No flow. 08:30 - 08:45 0.25 DRILL P PROD1 Safety meeting. 08:45 - 09:15 0.50 DRILL P PROD1 LD BHA. DPI SB3 BBM had some minor to moderate flattening of the lead cutters. Also, most of the cutters that had this wear had broken PDC wafers with a rough shear plane parallel to the face of the wafer and midway through the wafer. Noticed this on the previous DPI SB3 BBM bit, but to a lesser extent. 09:15 -11:45 2.50 DRILL P PROD1 MU BHA 23 (M-07 bit; 1.0 deg motor; resistivity). 11 :45 - 13:40 1.92 DRILL P PROD1 RIH to 1000'. SI well and continue RIH. WHP rose and stabilized at about 60 psi (must be equalized across SSSV). Open SSSV. WHP = 60 psi. RIH. Correct depth at flag (-6.5') 13:40 -14:40 1.00 DRILL P PROD1 Log tie-in at RA (10577'). Correct depth (-2'). Log MAD pass from window to TD 10730'. 14:40 - 16:30 1.83 DRILL P PROD1 Drilling strategy: Drill with 8.4 ppg brine, keeping BHP above 4200 psi. BU fluid after trip contains significant oil. Start drilling from 10730'. Drilling ROP about 30 FPH intially, but increased to 60 FPH by 10740'. Returns thru buster, gas and oil coming and going. Pumping 2.7 BPM, return rate 2.5 BPM based on pit straps. Drill to 10828'. 16:30 -16:45 0.25 DRILL P PROD1 Wiper to window, with 10 bbl of 150k LSRV Flo-Pro sweep. 16:45 -17:30 0.75 DRILL N DFAL PROD1 Resistivity looks questionable. Make 50' repeat MAD pass. Good solids in returned pill. 17:30 - 20:35 3.08 DRILL P PROD1 Go back to drilling. Gassy returns continue, which requires buster, which requires us to go thru well control choke instead of drilling choke - don't want to do this long term. Set new BHP target at 4300 psi. Losses +1- 20bph. Weight transfer steadily worsening. Drilled to 10922'. 20:35 - 20:55 0.33 DRILL P PROD1 Pumped hi-vis sweep and wiper trip back to window. 20:55 - 21 :50 0.92 DRILL P PROD1 Good weight transfer. Frequent motor stalls. Unable to drill ahead. 21 :50 - 23:30 1.67 DRILL P PROD1 TOH. Following pressure schedule 25psi/1000' over intial250 psi to maintain -4300 BHP. Flag pipe at 10400' EOP. At surface trap 500psi on wellhead and close SSSV. 23:30 - 00:00 0.50 DRILL P PROD1 Flow check (pressure test of SSSV). No flow. Printed: 1012012003 8:56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ..... .. BP EXPLORATION Operations Summary Report L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Page 18 of 27 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Date . , From - To Hours' Task ¡ Code ~ NPT Phase . ...... .---".- 1 0/2/2003 00:00 - 02:00 02:00 - 04:10 04:10 - 04:30 04:30 - 05:30 05:30 - 07:30 07:30 - 08:15 08:15 - 08:45 08:45 - 10:15 10:15 - 12:15 12:15 - 12:45 12:45 - 16:45 16:45 -17:00 17:00 - 17:30 17:30 - 17:45 17:45 - 20:20 20:20 - 22:25 22:25 - 00:00 2.00 DRILL P 2.17 DRILL P 0.33 DRILL P 1.00 DRILL N 2.00 DRILL N 0.75 DRILL N 0.50 DRILL N 1.50 DRILL N 2.00 DRILL N 0.50 DRILL N 4.00 DRILL P 0.25 DRILL P 0.50 DRILL P 0.25 DRILL P 2.58 DRILL N 2.08 DRILL N 1.58 DRILL N Description of Operations PROD1 Swap out BHI resistivity tool and PU another rebuild M07 bit. The M07 just pulled had significant wear in all areas, moderate RO on shoulder, and wear down to the matrix between shoulder and gage. PROD1 RIH to 1200'. Pressure up above SSSV to 350psi and equalize pressure below SSSV. Open valve. Continue RIH. PROD1 Log tie-in at RA tag. DFAL PROD1 MAD pass from window to 10725'. (MAD pass requested again because resistivity looking unusual). DFAL PROD1 GR tool quit working at tail end of MAD pass. TOH following pressure schedule to maintain 4400 psi BHP (500 psi WHP when bump up). DFAL PROD1 Close SSSV, bleed well, monitor for flow for 30 minutes -- no flow. DFAL PROD1 LD BHA. M07 too worn on shoulder (broken cutters) to rerun. Damage probably, but surprisingly, occurred from POOH at full pump rate. DFAL PROD1 MU BHA #25 with DBS FM2533i scribe bit DFAL PROD1 RIH. Pressure above SSSV, broke over at 400 psi, open SSSV, confirmed WHP about 380 psi (jives with 4170 psi SBHP observed earlier). RIH at min rate, maintaining 400 psi WHP. DFAL PROD1 Log tie-in at RA. Correct depth (-10'). RIH to TD. PROD1 Survey data garbage, will go ahead and drill a little using near bit inclinometer. Shoot for BHP of 4400 psi plus. Start drilling from 10921'-- intially seeing several stalls (perhaps due to the scribe profile) then smoothed out after drilling about 10'. ROP 20 - 30 FPH intially. BHP 4450 psi. FWHP about 400 psi to maintain this. Average in/out = 2.7/2.3. So this 2.3 BPM return rate is creating about 300 psi of annular friction. Started getting a bunch of near stalls starting at 10964. ROP continued to drop and by 10980', ROP down to about 10 FPH. GR shift noticed at 10950'; will try to grunt out a few more feet to see this on resistivity before POOH. Crawl to 10,988' PROD1 At 10988', stall and major suck. Well on vaccuum at 2.7 BPM. Lost 650 psi of BHP immediately (from 4450 to 3800), then BHP somewhat stabilized at 3760 psi, then climbed gradually (probably fluid level coming back up). Drill 1 00 FPH to 11000' (not entirely a void, but little resistance) PROD1 Wiper to window. Hole in good shape. Try to get some surveys at minimum flow - nothing, tool not working. DD not comfortable drilling any further without good survey data. PROD1 Check ROP on bottom by drilling a few feet to 11010' -- about 35 FPH, but again, DD not comfortable with continuing on. DFAL PROD1 POOH to window. BHP has climbed to 3900 psi. POOH pumping down backside with charge pump (about 3.0 BPM). IA and OA above 1000 psi -- bleed. DFAL PROD1 Shutdown charge pump. Disconnect and pick-up injector. Re-start charge pump and adjust to keep hole full without overflow. Setback injector. UD BHA. PIU new motor and survey package. Hole taking 2bpm to keep full. DFAL PROD1 RIH. Pumping down backside to fill hole. Printed: 10/20/2003 8:56:59 AM ..... .. Page 19 of 27 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To . Hours . Task CO'de NPT Phase 10/3/2003 00:00 - 00:30 0.50 DRILL N DFAL PROD1 00:30 - 00:45 0.25 DRILL N DFAL PROD1 00:45 - 01 :25 0.67 DRILL N DFAL PROD1 01 :25 - 06:00 4.58 DRILL P PROD1 06:00 - 11 :00 5.00 DRILL P PROD1 11 :00 -12:00 1.00 DRILL P PROD1 12:00 -13:00 1.00 DRILL P PROD1 13:00 -14:30 1.50 DRILL C PROD1 14:30 -16:45 2.25 DRILL N DPRB PROD1 16:45 - 18:15 1.50 DRILL N DPRB PROD1 18:15 - 18:40 0.42 DRILL N DPRB PROD1 18:40 - 00:00 5.33 BOPSURP PROD1 10/4/2003 00:00 - 00:15 0.25 BOPSUR P PROD1 00:15 - 01 :20 1.08 DRILL N DPRB PROD1 01 :20 - 03:00 1.67 DRILL N DPRB PROD1 03:00 - 03:20 0.33 DRILL N DPRB PROD1 03:20 - 03:45 0.42 DRILL N DPRB PROD1 03:45 - 04:45 1.00 DRILL N DPRB PROD1 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Operati9ns RIH to 10560'. Log tie-in -6.5' RIH to bottom. Directionally drill f/11010'. Free-spin 2050psi @ 2.5 bpm with partial returns. Lost complete returns again at 11015'. From 11030' - 11080', ROP averaging about 10 - 20 FPH. Drilling break, acting like rubble zone 11080' - 11085', then back to 10 - 20 FPH. Continue drilling. 0600 depth: 11100' BHP 3845psi ROP gradually improving starting at 11100'. Drill to 11108', wiper to window. Hole in good shape. Returns coming and going. Drill to 11200'. ROP continues to get better. Wiper to window, sweeping open hole with hi-vis sweep while bit is agitating cuttings bed. Losses at 100%. 10k overpull 11180'. Drill to 11243'. The correlations and higher ROP since 11100', suggest we are deep in section. Need to revise plan. Wiper to window. Hole conditions deteriorating in the recently drilled "different" lithology. Several overpulls to 15K over with MW in area 11120' - 11243'. Wait on revised plan. RIH with hi-vis lubetex pill coming out. MW and ratty RIH wt starting 11115'. By 11216' significant MW and by 11225' lots of digging (or drilling new hole). PUH. Heavy with continuous MW. RIH cleaner to 11236'. Try drilling from here. Lots of stick/slip. 6k - 10k WOB. Drilled back to 11240'. Wiper to window. Overpulls with MW 11211' - 11110' then continue pulling smooth to 11045' (CTC at fault). Overpull here -- this time without motor work. Pull to 65k, then turn around and stack weight before popping free. Pull steady 65k - 80k for a few more feet, then RIH again to get BHA movement down. Continue cycling pipe, making slow but steady progress uphole until tool pulled smooth at normal45k starting at about 11,000'. The larger cuttings from the sloughing mudstone are likely getting deposited at the loss zone instead of getting flushed away. This is a carbon copy of conditions seen in wells drilled at Prudhoe with full lost circulation and shale instablity -- even when drilling mud was used. Continue POOH. Saw another spike of MW at 10938' with overpull that required some work to get through. Sweep belly with bit agitation and hi-vis pill. POOH flooding backside. UD BHA. Only wear seen on bit #6 is paint loss. Weekly pressure test of BOP stack. Witnessing wavied by AOGCC rep John Crisp Finish with weekly testing of BOP equipment. Install riser cap and check pressures. Well on vacuum. Pump 8 bbls to fill. P/U Weatherford 3 1/2" Openhole Whipsstock and packerlanchor assembly RIH Log tie-in. RIH and tagged at 10680'. 10k overpull off bottom. Worked again without success. PUH to 10100' within 7 5/8" csg. Lined up on annulus and Printed: 10/2012003 8:56:59 AM ...,. -- Page 20 of 27 BP EXPLORATION Operations Summary Report RIH. Start pill down coil. Position tools across RA for tie-in log. Short in tool string. Won't be able to activate disconnect -- too risky to attempt cleanout. Flush pill away pumping down backside and coil at 6.0 BPM; 350 psi WHP (coil only taking 1.0 BPM -- probably because of viscous pilL). DFAL PROD1 POOH. DFAL PROD1 LD BHI BHA -- failure in orienter. MU next BHA. Had to piece together last of the "working" tools. Will have to limp along with marginally working orienter (rotates very slow to the right; will not rotate to the left) RIH Log tie-in. Correct depth (-6') RIH 2.7 BPM with sweep exiting bit to 10960'. Clean the entire way. POOH filling down annulus. UD BHA # 13 and P/U sidetrack BHA #14 RIH Log tie-in -6' correction. Start troughing at 10905' - 10930' at 30'/hr. Will make 3 passes. 2.4 bpm with no returns. Estimated losses to formation currantly 8800 bbls. Continue making intial trough from 10905' to 10930' (3 passes) Time mill 10930' - 10950' in hourly increments of 1', 2', 3', 3', 5', 6'. TF at 180 until 10948', then 135R from 10948' - 10950'. Rate 2.7 BPM; BHP = 3875 psi. No returns until last hour of milling - then slight (-0.4 BPM). DPRB PROD1 Controlled drilling 10 FPH from 10950' at 90R TF. Confirmed new hole. Continue drilling 2.6/0.3, 20 FPH, BHP 3800. At 10990', drilling break -- may have intersected our fault again, although more resistance than seen before. No change in loss rates. Drill to 10998'. TF dropped to 11 OL, then straight down. Need to get back to 90R but unable to rotate to left (as expected from yesterday's surface test), and rotation to right hits stop at about 135L. POOH for failed orienter. Rebuilt orienter ready to go. LD BHA. Outside cutters broken; some missing. MU BHA #30 (resistivity, 2.0 deg motor, DPI MP3A). RIH. Tie-in and correct depth -4'. RIH lowside to TD. dwn wt. 18.5k up wt. 46k Directionally drill ahead f/10998'md 8773'tvd 2.63bpm, free-spin 2170psi, on bottom -2700psi 3k wob 30-40'/hr. Well shut-in at surface no returns. Drilled to 11034'. Having trouble with stalling. Plenty of WOB. Maybe pyrite. Continued working area for another hour pumping sweeps and small wiper trips to 11036'. Not making much headway. DPRB PROD1 TOH to inspect bit and BHA. DPRB PROD1 Change out bits and motor. Minor wear on lead cutters and a few chipped compacts on gauge. Motor felt good when rotated. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 .. pate ..From - To Hours Task CodEr NPT Phase 10/4/2003 03:45 - 04:45 1.00 DRILL N DPRB PROD1 04:45 - 06:45 2.00 DRILL N DPRB PROD1 06:45 - 08:15 1.50 DRILL N DPRB PROD1 08:15 -10:15 2.00 DRILL N DPRB PROD1 10:15 - 12:15 12:15-15:30 2.00 DRILL N 3.25 DRILL N 15:30 -17:15 1.75 DRILL N DFAL PROD1 17:15 -17:30 0.25 DRILL N DPRB PROD1 17:30 - 18:00 0.50 DRILL N DPRB PROD1 18:00 - 19:45 1.75 DRILL N DPRB PROD1 19:45 - 20:20 0.58 DRILL N DPRB PROD1 20:20 - 22:10 1.83 DRILL N DPRB PROD1 22:10 - 22:25 0.25 DRILL N DPRB PROD1 22:25 - 00:00 1.58 STKOH N DPRB PROD1 10/5/2003 00:00 - 01 :30 1.50 STKOH N DPRB PROD1 01 :30 - 09:00 7.50 STKOH N DPRB PROD1 09:00 - 12:15 3.25 STKOH N 12:15 - 14:30 2.25 STKOH N DFAL PROD1 14:30 - 16:15 1.75 STKOH N DFAL PROD1 16:15 -18:40 2.42 STKOH N DFAL PROD1 18:40 - 22:00 3.33 STKOH N DPRB PROD1 10/6/2003 22:00 - 00:00 00:00 - 00:30 2.00 STKOH N 0.50 STKOH N Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 . ... .. . . . .. ... ... ... . ..... ..... Description ofOperatioriš; pump 200 bbls 8.4 brine at 5 bpm with 650psi. RIH and tagged again at 10680'. TOH for cleanout bit and motor. LD billet. No marks or debris. MU motor and mill for cleanout. Printed: 10/20/2003 8:56:59 AM - . BP EXPLORATION Operations Summary Report Page 21 of 27 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 8/27/2003 10/15/2003 N2 Spud Date: 12/31/1989 End: 10/15/2003 Date From - To Hours Task Code NPT Phase Description of Operations . .. .. . .----.--.... 10/6/2003 00:30 - 02:35 2.0S STKOH N DPRB PROD1 RIH 02:35 - 02:50 0.25 STKOH N DPRB PROD1 Log tie-in -S' correction. 02:50 - 03:05 0.25 STKOH N DPRB PROD1 RIH to TD no problems entering sidetrack. 03:05 - 05:30 2.42 STKOH N DPRB PROD1 Directionally drill ahead f/11 036'md 8773'tvd 2.63bpm, free-spin 2100psi, on bottom -2700psi 5k wob 10-15'/hr. Took right off drilling without stalls. Slower drilling but this mirrors same ROP in hole #1. Pumping sweeps when needed. Drill to 11075'. 05:30 - 06:30 1.00 STKOH N DPRB PROD1 Wiper trip back to 10600' p/u wt 43.5k 06:00 - 12:00 6.00 STKOH N DPRB PROD1 Drilling slow. To stay out of the mudstones, we are forced to stay in lower Zone 6 which is characterized by lower porosity and some chert -- meaning lower ROP. Drill to 11142'. ROP down to < 10 FPH. Steady drop in ROP since the 30 FPH we saw initially; believe bit is getting worn. 12:00 - 14:00 2.00 STKOH N DPRB PROD1 POOH to check bit and to put on stronger bend motor for revised plan. A little MW at 10922', just uphole of junction. 14:00 - 14:45 0.75 STKOH N DPRB PROD1 LD BHA. Bit in good condition -- wear was minimal. 14:45 - 16:45 2.00 STKOH N DPRB PROD1 Wait for revised plan. 16:45 - 17:15 0.50 STKOH N DPRB PROD1 Drop resistivity. MU BHA #32. Reset motor to 2.7 deg (for 35 DLS), PU DPI SP3BBM (performed well in the build). 17:15 -19:10 1.92 STKOH N DPRB PROD1 RIH to 10579' 19:10 - 19:30 0.33 STKOH N DPRB PROD1 Log tie-in -10' correction. 19:30 - 19:45 0.25 STKOH N DPRB PROD1 RIH. No problems at OHST junction. 19:45 - 21:10 1.42 STKOH N DPRB PROD1 Directionally drill ahead f/11142' 2.6bpm 2100psi free-spin, surface choke closed - no returns. Motorwork 5-600psi, wob 3.5k, rop 40-50'/hr, ECD S.19psi with no wellhead pressure. Drill to 11191' NB inc 101*. 21:10 - 21:35 0.42 STKOH N DPRB PROD1 Wiper trip back to 10590'. P/U wt 45k RIH wt 1S.5k 21 :35 - 23:15 1.67 STKOH N DPRB PROD1 Directionally drill ahead holding straight up TF f/11191'. ROP slowing. Drilled to 11998'. Unable to get motorwork. Try different TF 0-30*. 23:15 - 00:00 0.75 STKOH N DPRB PROD1 Wiper trip back to 10590'. Still unable to see MW. Change TF's in attempt to drill off. No MW. 10/7/2003 00:00 - 02: 15 2.25 STKOH N DPRB PROD1 TOH. Unable to get any motorwork. 02: 15 - 03:30 1.25 STKOH N DPRB PROD1 LID 2.7 motor. P/U 2.2 motor and new bit. Bit #12 has only minor damage to gauge row. 1 compact broken on inner row. Should have drilled. 03:30 - 06:30 3.00 STKOH N DPRB PROD1 RIH. Tie-in at window, correct depth (-5.5'), RIH clean. 06:30 - 07: 15 0.75 STKOH N DPRB PROD1 Drill from 11200'. Took a couple minutes to get started (hard spot), then steady drilling at 40 - 50 FPH. Think we've entered bottom of mudstone at about 11205'. Failure in survey package. Continue drilling using near bit inclinometer. At 11225' ROP increased again. Drill to 11233'. Pump 20 bbl sweep. Agitate open hole with pill exiting bit. Wiper to window. 07:15 - OS:40 1.42 STKOH N DPRB PROD1 Pump 20 bbl sweep. Agitate open hole with pill exiting bit. Wiper to window -- hole in good shape. 08:40 - 09:00 0.33 STKOH N DPRB PROD1 Drill mudstone to 11243'. Back on productive time (TD of old wellbore) 09:00 - 10:30 1.50 DRILL P PROD1 Drill mudstone with ROP target of 30 - 40 FPH (purposely holding back -- wants to drill near 100 FPH). Drill to 11260'. Harder drilling here; may have punched thru the top of the mudstone. Continue drilling without holding back. ROP averaging 20 -30 FPH. Drill to 11270'. Stacking here. Printed: 10/20/2003 8:56:59 AM ..... .. BP EXPLORATION Operations Summary Report Page 22 of 27 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 .. .... Qate ·'From - To Hours Té1sk:, Code NPT Phase Description ofQperåtiöns 10/7/2003 10:30 - 11 :00 0.50 DRILL P PROD1 200' wiper with 20 bbl sweep. 11 :00 - 12:45 1.75 DRILL P PROD1 Try drilling from 11270' -- hard spot - could not punch through after 30 minutes. 250 psi MW and a couple of stalls, but no obvious progress. Stack to 11274'. No progress. 12:45 - 15:00 2.25 DRILL P PROD1 POOH. 15:00 -16:15 1.25 DRILL P PROD1 Change out directional package and plu bit #14 16:15 -17:50 1.58 DRILL P PROD1 RIH to 10569'. 17:50 -18:15 0.42 DRILL P PROD1 Log tie-in -8' correction. 18:15 - 18:30 0.25 DRILL P PROD1 RIH to bottom no problems through OHST junction. Setdown at 11150'. PIU once and went through fine. 18:30 - 19:45 1.25 DRILL P PROD1 Directionally drill ahead f/1127 4'. 2.7 bpm free-spin 2150psi. 3-4k wob 30-40'/hr intial rop gradually slowing and increase in stacking weight. By 11288' slow go finding it hard to get wob. Pumping lubetex pills. Working coil. 19:45 - 20:10 0.42 DRILL P PROD1 Wiper trip to 41/2" csg. overpull at 10999'- 10990'. At 10280' seen pinhole in coil at reel. Lineup to pump across top of hole. (very small pinhole NO spill) 20:10 - 22:30 2.33 DRILL N DFAL PROD1 TOH. (Estimate at least 12 hrs to swap coils.) Hold preliminary JSA and outline steps to blowdown, secure and remove reel. Reel has 538807' running feet. Area of pinhole -30% life. Other areas at 11000',10750' & 6750' had >40% life. 22:30 - 22:45 0.25 DRILL N DFAL PROD1 UD BHA 22:45 - 23:00 0.25 DRILL N DFAL PROD1 PJSM for blowdown with N2. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 Blowdown coil wI N2. 1 0/8/2003 00:00 - 02:30 2.50 DRILL N DFAL PROD1 Secure injector. Unstab coil and secure to reel. Lower reel to truck. 02:30 - 04:45 2.25 DRILL N DFAL PROD1 Raise new 2 3/8" e-line reel into place and secure. Install 'snake' for stabbing coil to reel. 04:45 - 05:00 0.25 DRILL N DFAL PROD1 PJSM on stabbing coil to injector. 05:00 - 08:45 3.75 DRILL N DFAL PROD1 Stab coil to injector. Prep for slack management. 08:45 - 10:30 1.75 DRILL N DFAL PROD1 Fill coil with KCL water. Pump eline slack back through reel. 10:30 - 11 :00 0.50 DRILL N DFAL PROD1 Cut coil to find end of e-line. 11 :00 - 12:30 1.50 DRILL N DFAL PROD1 Re-head coil with BHI connecter assembly. 12:30 - 13:00 0.50 DRILL N DFAL PROD1 Pressure test coil connector to 4000 psi. 13:00 - 14:15 1.25 DRILL N DFAL PROD1 MU BHA #36 (2.2 deg motor with S725 diamond bit) 14:15 - 15:30 1.25 DRILL N DFAL PROD1 RIH with drilling assembly. Pump flo pro light with 3% lubtex down coil annulus (110 bbls) WHP increased to 300 psi at 2.7 bpm, then bleed off immediately after slowing to minimum rate. 15:30 - 15:45 0.25 DRILL N DFAL PROD1 Log gr tie in from 10610'. Subtract 10' correction. 15:45 - 16:15 0.50 DRILL N DFAL PROD1 Tag btm at 11280'. 2180 psi@2.6 bpm. 16:15 - 16:40 0.42 DRILL N DFAL PROD1 Log tie-in -10' correction. 16:40 - 17:00 0.33 DRILL N DFAL PROD1 RIH to bottom. 17:00 - 21 :00 4.00 DRILL P PROD1 Drill ahead. 2.9 bpm 2400psi free-spin. Good motorwork but very slow rop <5'/hr. Drilled to 11298'. Motorwork 5-600 psi. No penetration. 21 :00 - 23:00 2.00 DRILL P PROD1 TOH 23:00 - 23:30 0.50 DRILL P PROD1 P/U new bit and check motor. Keep AKO at 2.2 deg Bit #15: inner and heel sections worn cutters down to diamond followers. Others cracked several missing. Junklwater courses filled with mudstone. Several chunks of chert. 23:30 - 00:00 0.50 DRILL P PROD1 RIH Total bbls to downhole -19900 10/9/2003 00:00 - 01 :00 1.00 DRILL P PROD1 RIH wI BHA #36 and bit #16 Printed: 10120/2003 8:56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ....... .. Page 23 of 27 BP EXPLORATION Operations Summary Report L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: Spud Date: 12/31/1989 End: 10/15/2003 8/27/2003 10/15/2003 N2 Date FrortL;:' To Hours · ... . ...... · ...... .............. · . .. ... .. . . .... . .. .... Task Code NPT:Pha$Ê:!!. '.'.' ... ............ .. .. . .. ... . .. .. ... ...... .. Description ofOperam,hs' . 10/9/2003 01:00-01:15 01: 15 - 01 :35 01 :35 - 02:05 02:05 - 06:00 06:00 - 08:00 08:00 - 09:00 09:00 - 09: 15 09:15 - 10:30 10:30 - 12:00 12:00 - 13:45 13:45 - 14:00 14:00 - 14:30 14:30 - 17:00 17:00 - 19:00 19:00 - 19:30 19:30 - 20:45 20:45-21:15 21:15 - 22:15 22:15 - 00:00 10/10/2003 00:00 - 00:35 00:35 - 01 :50 01 :50 - 03:05 03:05 - 05:00 05:00 - 07:00 07:00 - 07:30 07:30 - 12:15 0.25 DRILL P 0.33 DRILL P 0.50 DRILL P 3.92 DRILL P 2.00 DRILL P 1.00 DRILL P 0.25 DRILL P 1.25 DRILL P 1.50 DRILL P 1.75 DRILL P 0.25 DRILL P 0.50 DRILL P 2.50 DRILL P 2.00 DRILL P 0.50 DRILL P 1.25 DRILL N 0.50 DRILL P 1.00 DRILL P 1.75 DRILL P 0.58 DRILL P 1.25 DRILL P 1.25 DRILL P 1.92 DRILL P 2.00 DRILL N 0.50 DRILL N 4.75 BOPSURP PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 WAIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 DFAL PROD1 PROD1 Log tie-in _5' correction. RIH. Setdown at 11215',11270'. Ream f/11290' to bottom. Directionally drill ahead. Free-spin @ 2.65bpm 2400psi. Good motorwork 6-700psi good weight transfer. Drilling at 15-20'/hr 0600 depth 11370'. Drill to 11460'. 2850 psi @ 2.69 bpm. 200-600 dpsi. 2K-4K# WOB. Drilling at up to 80 fph. Average ROP: 30-40 fph. Estimate bit inclination at 91 deg. Wiper trip while pulling out of hole for lateral assembly and resistivity. Pulled heavy as top of BHA passed sidetrack junction at 10930'. Cleaned up ok, possibly indicates some cuttings are going down original hole for "disposal". Rig genset #3 shut down. Cooling fans power failed. Switch to gen set #2. Trouble shoot fan circuit while POOH. Continue to POOH. At surface. Lay down BHA to prep for picking up resistivity tool. Bit showing some chipped cutters but no flattening. Over all in very good shape. General grade 2-2-1. PU new Hycalog bicenter wI t-rex cutters (same as previous run, DSX100) RIH with BHA #37 and bit #17 (1.2 motor lateral assembly/DS100). Log gr tie in from 10600'. Subtract 7' correction. Run into open hole. 2300 psi@2.68 bpm fs. 17.5k#dn I 42k# up wt. Hole very smooth. No bobbles. Drill ahead. 2300 psi @ 2.66 bpm fs. 2890 dpsi 4K-6K# WOB. Drill to 11540'. Unable to get enough build with 1.2 deg mtr. POOH to increase motor angle. Found a few small pieces of motor stator rubber in bit. Bit graded 1-1-1 Wait on motor from Deadhorse. (spare ExTreme motor was in shop for rebuild). While waiting work on injector gooseneck alignment PIU motor and set at 1.7* and new DSX100 bi-center bit. Stab on well RIH to 380'. Continue working on gooseneck alignment with the new 2.375" coil. RIH to 11600' (hold Fire Drill) Log tie-in f/1 0600'. Correction Directionally drill f/11540'. free-spin 2450psi @ 2.7 bpm 3-400psi MW 3k wob 20-30'/hr. Drilled to 11571'. Wiper trip into 5 1/2" csg. bullhead 94 bbls flo-pro down backside at 3.7bpm 540 psi. Hole good shape going to bottom. Directionally drill f/11571' 3-4k wob 25-30'/hr Drilled to 11616'. Having trouble with injector hydraulics. Not able to adjust slow RIH speed needed to drill. Getting a bad signal from orienter. TOH for orienter. Also on injector having problems with slow RIH speed adjustment needed to drill. Good time to do weekly BOP test. Notified AOGCC and rep. Chuck Scheve wavied witnessing. LD BHA. Remove orienter for inspection. Bit in perfect condition. Weekly test of BOP equipment. All components tested ok. No Printed: 10/20/2003 8:56:59 AM ..... .. Page 24 of 27 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date ; From - To Hours' Task Code. NPT Phase . .--. ....... . . 10/10/2003 07:30 - 12:15 4.75 BOPSURP PROD1 12:15 -13:00 0.75 DRILL N DFAL PROD1 13:00 - 15:00 2.00 DRILL N DFAL PROD1 15:00 -15:15 0.25 DRILL N DFAL PROD1 15:15 -16:00 0.75 DRILL N DFAL PROD1 16:00 - 20:00 4.00 DRILL P PROD1 20:00 - 21 :10 1.17 DRILL P PROD1 21:10-00:00 2.83 DRILL P PROD1 10/11/2003 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 01 :50 0.83 DRILL P PROD1 01 :50 - 02:30 0.67 DRILL P PROD1 02:30 - 03:15 0.75 DRILL P PROD1 03:15 - 05:15 2.00 DRILL P PROD1 05: 15 - 05:30 0.25 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 08:00 2.00 DRILL P PROD1 08:00 - 10:00 2.00 DRILL P PROD1 10:00 - 11 :30 1.50 DRILL P PROD1 11 :30 - 13:45 2.25 DRILL P PROD1 13:45 - 14:00 0.25 DRILL P PROD1 14:00 - 15:00 1.00 DRILL P PROD1 15:00 - 18:35 3.58 DRILL P PROD1 18:35 - 20:40 20:40 - 21 :20 21 :20 - 23:35 2.08 DRILL P 0.67 DRILL P 2.25 DRILL P PROD1 PROD1 PROD1 Start: Rig Release: Rig Number: Spud Date: 12/31/1989 End: 10/15/2003 8/27/2003 10/15/2003 N2 Description of Operations failures. MU BHA#39 (1.8 mtrwith DS100 bit). RIH. Log grtie in from 10600'. Add 8' correction. Continue to RIH. 2480 psi @ 2.71 bpm fs while RIH. 19.5K# dw. Set down at 10216' (middle of mudstone). PU at orient to 90R. Ran through ok with 100-200 psi motor work. Drill ahead from 11616'. FS 2450psi 2-300psi MW 1-3k wob. Increasingly difficult to obtain WOB. Pumping 5-10bbl pills wI lubetex and short wiper trips. Drilled to 11667'. Wiper trip to 10800'. Have instucted hotwater plant to start adding 1/2#/bbl biozan to all trucks in addition to the 2% KCL. Directionally drill ahead f/11667'. Fairly good weight transfer right after reaching bottom. Pumping 10 bbl pills wI 2% lubetex and bha length wiper trips. Still very difficult to get wob. Does not appear to be a bit problem. WOB=MW=ROP. ROP picking up after 11678' -10-15'/hr maintaining 2k wob and pumping 5 bbllubetex pills. Drilled to 11687'. Directionally drilled f/11687' to 11700'. Fairly good weight transfer. Pumping 5 bbllubetex pills every 15 min. Wiper trip into 5 1/2" casing up wt 41 k (spot 20 bbllubetex pill in coil followed by slick water). Bullhead 125 bbls Flo-pro lite with 4% Lubetex down annulus at 3.7 bpm 500 psi. Pulling coil slowly while bull heading, not pumping down coil. TIH. RIH wt 18k. One small bobble at the OHST other wise clean. Directionally drill f/11700' free-spin 1900psi at 2.6 bpm (reduced psi fl slickwater), 400psi mw, 3.6k wob (-6k ct wt.) 10-14'/hr Drilled to 11723'. Wiper trip to 11500'. Directionally drill ahead. Drill ahead at 11730'. 2040 psi@ 2.67 bpm fs. 150-250 psi mtr work. 1.5-2.5k# WOB. 3-8 fph ROP. WHO: 300-400 psi while drilling. Drilling very slow. Pump sweeps. Make wiper trips. Decide to pull BHA to check bit. Drilled to 11735'. POOH with lateral BHA. Some motor work noted in several spots, but no overpulls. LD 1.7 mtr. Bit plot cutting structure completely worn & ringed out. MU 1.5 deg slow speed motor with HTC STX 30DX tri-cone. RIH with lateral BHA. Log gr tie in from 10600'. -7' correction. RIH. Tag up at 11216'. Orient to 30R TF. Went through ok. Slight motor work at several spots, no more weight bobbles to 11735'. Drill ahead fl 11735'. 1950 psi @ 2.70 bpm fs. 50-150 psi motor work (typical for roller cone bit). 2K-3K# WOB (maximum to obtain). 319 psi WHP climbing to 425psi at 1800hrs. ROP slowing to <2'/hr. TOH pump at min rate P/U new bit and Ex-Treme motor. RIH to 10600'. Printed: 1012012003 8:56:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: m[)åte ..... . Page 25 of 27 BP EXPLORATION Operations Summary Report L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To ·,Hours Task Code NPT Phase 10/11/2003 23:35 - 23:50 23:50 - 00:00 10/12/2003 00:00 - 01:15 01: 15 - 01 :35 01 :35 - 01 :55 01 :55 - 03:00 03:00 - 04:00 04:00 - 06:45 06:45 - 07:30 07:30 - 11 :00 11 :00 - 13:00 13:00 - 15:30 15:30 - 17:00 17:00 - 17:20 17:20 -18:15 18:15 - 18:45 18:45 - 19:45 19:45 - 22:10 22:10 - 23:45 23:45 - 00:00 10/13/2003 00:00 - 01 :50 01 :50 - 02:10 0.25 DRILL P 0.17 DRILL P 1.25 DRILL P 0.33 DRILL P PROD1 PROD1 PROD1 PROD1 0.33 DRILL P PROD1 1.08 DRILL P PROD1 1.00 DRILL P PROD1 2.75 DRILL P PROD1 0.75 DRILL P PROD1 3.50 DRILL P PROD1 2.00 DRILL P PROD1 2.50 DRILL P PROD1 1.50 DRILL P 0.33 DRILL P 0.92 DRILL P PROD1 PROD1 PROD1 0.50 DRILL N DPRB PROD1 1.00 DRILL N DPRB PROD1 2.42 DRILL N 1.58 DRILL N DPRB PROD1 DPRB PROD1 0.25 DRILL N 1.83 DRILL N 0.33 DRILL N DPRB PROD1 DPRB PROD1 DPRB PROD1 Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Op~rations Log gr tie-in -5' correction. Continue RIH at min pump rate. RIH to bottom. 1 setdown at 11210' pick-up and went through. Directionally drill f/11749'. Free-spin 1670psi at 2.7 bpm. Break-in bit first 2'. Drilling good with nice weight transfer 2k wob and 25-30'/hr. Unfortunately need to plu and replace a master link in reel drive. Shouldn't take long. Replace master link on drillers side reel motor. Auto-driller shuttle valve also not working. Mechanics disconnected it from injector and rebuilding a replacement at SLB shop Back on bottom. Drill ahead f/11753'. Back to having trouble obtaining WOB. Drill to 11761'. Something is hanging us up above the WOB sensor. Not able to get more than .6k wob where as at the start of bit run it was easy to have 2k WOB and positive CT weight. Wiper trip to 10800' p/u wt 41 k. Stacked out at 11214' orient to 90r and went through. RIH wt at 11700' 12k Drill ahead f/11761' 2.5k wob (-4k CTW) drilled off and back to zero wob again but have 2-300psi motorwork. Work pipe. Drilling maintaining 1-2k wob w/-7k ctw 8-10'/hr. Fluids pumped last 24hrs have 2% KCL and 2#/bbl biozan. Pumping 5-10bbl sweeps every 20 min but not seeing any responce to weight transfer. Total bbls pumped since bullheading -28000. Drill to 11785'. Wiper trip to 10600'. Hole smooth. Tag ledge at 11216' with TF:170R. Orient to 60R. Pass through smooth. Drill ahead f/11785'. Open up well and slowly bleed WHP from 400 psi to 100 psi. Full returns. Some gas. Order flopro system to (hopefully) improve hole cleaning & weight transfer. Drill to 11800'. Unable to get much motor work even with 2K# on bit. Suspect bit may be dulled. POOH for bit. Send unused kcl water to MI as base fluid for mud. At surface. Break out bit. Adjust motor to 1.5 deg. DS100 graded 6-3-1. Several broken cutters on pilot cutting structure.. Change out mwd comm package. Repair auto drill system component on injector. MU BHA #42 (1.5 mtr with M07 bit). RIH with BHA #42 Log gr tie in from 10600'. Start swap to Flo-Pro mud. RIH tagged at 11215'. Same area of trouble on previous trips. This is a shale. Work area wo pump for 30 min with varying TF within the range it was drilled. W/R from 11215' to 11225' at 11 OR TF same as drilled. Continue with swap to Flo-pro mud with +1- 60% returns Working pipe wo pump at different toolfaces. Discuss problem with town. Decide best approach would be to p/u a balled cap taper mill or used bi-center to find old hole. TOH Bit #22 2-6-1 brokenlchipped cutters on heal and gauge. Drop out Resistivity tool. Reset motor to 2.2 deg. Pick-up 2.71" bald nose taper mill. RIH RIH Log gr tie-in -16' correction. Printed: 1012012003 8:56:59 AM - .. ~ BP EXPLORATION Operations Summary Report Page 26 of 27 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 8/27/2003 10/15/2003 N2 Spud Date: 12/31/1989 End: 10/15/2003 Date . From - To i Hours Task Code: NPT Phase Description of Operations _.1... . .,. ... ,..... ... .--.... ..- .. 10/13/2003 02:10 - 02:30 0.33 DRILL N DPRB PROD1 RIH. Tagged at 11224'. 02:30 - 04:30 2.00 DRILL N DPRB PROD1 Washing starting f/11220' with 110 TF 2.7 bpm in I .78 bpm out 1820 psi free-spin motorwork at 1980 psi. Moving TF from 110 up to highside then back to 135R seeing 2-300psi MW at the 135TF with 6-8k wob but stacking weight without any give back on weight. Returns increasing over time. Have picked up several times and setdown is now 11226' after 2 hrs of washing (intial setdown 11224-5'). Little progress has been made. Samples stuck on previous bit run suggest the shale is gummy/sticky. May need a more aggressive approach. Full returns now. 04:30 - 06:30 2.00 DRILL N DPRB PROD1 POOH with crayola mill. 06:30 - 08:30 2.00 DRILL N DPRB PROD1 LD crayola mill. No signs of wear, some clay like material on cutting pads. Well flowing slightly. Shut in well. 10 psi WHP. MU DS100 bicenter on 2.7 deg motor. Hold BOP drill while MU BHA. 08:30 - 10:45 2.25 DRILL N DPRB PROD1 RIH with BHA #44. 10:45 - 11 :00 0.25 DRILL N DPRB PROD1 Log gr tie in from 10600'. -10' correction. 11 :00 - 13:30 2.50 DRILL N DPRB PROD1 RIH to 11220. Orient to 110 R. Try to run in hole. Tagging up at 11224'. PU and try several different TF orientations with min pump. Try same, pumping at 2.76 bpm. Orient to 11 OR. Drill ahead to 11240'. Drilling at 35 fph with 5K# WOB. Appear to be drilling new formation. 2.75 bpm in 11.5 bpm out. 13:30 -14:30 1.00 DRILL N DPRB PROD1 Wiper trip through open hole back to window. 14:30 -16:15 1.75 DRILL N DPRB PROD1 POOH with drilling assembly. 16:15 -17:00 0.75 DRILL N DPRB PROD1 LD BHA #44 17:00 - 20:45 3.75 EVAL P PROD1 Hold PJSM with evening shift. MU Reeves open hole logging assembly. (problem with firing up memory section. Wait for replacement f/Deadhorse) Stab-on injector. 20:45 - 22:45 2.00 EVAL P PROD1 RIH shallow test BHi tools-ok RIH 22:45 - 23:10 0.42 EVAL P PROD1 Log tie-in -13' correction. 23:10 - 00:00 0.83 EVAL P PROD1 PIU to 10575'. Maximum setdown weight allowable is 4k. Begin logging down at 30'/min to 11200'. No problem area-smooth. (Logging tools stabilizer scheduled to open at 00:15hrs, must be logging up only when it opens) Kill time by relogging below OHST at 10930'. Log up 10'/min to 11000' then down to 11200'. 10/14/2003 00:00 - 01 :30 1.50 EVAL P PROD1 Log up from 11200' to 10500' at 12'/min 01 :30 - 04:20 2.83 EVAL P PROD1 TOH 04:20 - 05:30 1.17 EVAL P PROD1 UD logging tools. 05:30 - 07:00 1.50 CASE P COMP Prep to run 3 3/16" liner. Down load logging data. 07:00 - 10:00 3.00 CASE P COMP Make 22 jts 3-3/16" slotted & 1 jt 2-3/8" slotted with round nose guide. 10:00 - 10:30 0.50 CASE P COMP MU GS spear and BHI motor head assembly. 10:30 - 12:15 1.75 CASE P COMP RIH. Correct depth at liner flag -17'. Continue to RIH. Begin hauling off fluids for recycle & injection. Will have 270 bbls new flo pro available at mud plant. 12:15 - 13:00 0.75 CASE P COMP At window. 42k# up, 20k# dn wt at window. Run into open hole. On bottom, tag at 11240'md. Unable to work past ledge. Release from liner. 13:00 - 16:15 3.25 CASE P COMP POH, pumping 2% KCL to keep hole full. Park at 2100', shut down pumps and monitor well. Well flowing at 0.3bpm. SI SSSV. Monitor well, no flow. Continue POH filling across the Printed: 10/20/2003 8:56:59 AM ·. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ...... .. Page 27 of 27 BP EXPLORATION Operations Summary Report L 1-15 L 1-15 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 . . . Date .. From - TåF-lours Task' Code NPTPhase 10/14/2003 13:00 -16:15 16:15 - 17:15 17:15-18:30 18:30 - 20:30 20:30 - 23:00 23:00 - 00:00 10/15/2003 00:00 - 01 :00 01 :00 - 06:00 3.25 CASE P 1.00 CASE P 1.25 WHSUR P 2.00 WHSUR P 2.50 WHSUR P 1.00 WHSUR P 1.00 WHSUR P 5.00 WHSUR P COMP COMP COMP COMP COMP COMP COMP COMP Start: 8/27/2003 Rig Release: 10/15/2003 Rig Number: N2 Spud Date: 12/31/1989 End: 10/15/2003 Description of Öperations top. LD liner running tools, blow back CT. Line out HBR Hot oil to bullhead diesel down tubing. Open SSSV. Bullhead 11 Obbls at 3bpm. Pull coil back & clean pits. Clear pipe shed and rig floor. Set BPV ( 400PSI ON TUBING). Blow down stack and hard line to tiger tank. ND BOPE. Release rig @ 0600 hours. Printed, 1012012003 8;56,59 AM ~ ObP . BP-GDB . Baker Hughes INTEQ Survey Report ¿)êB-jé)ð ... &AIDa IUGIIIS INTEQ .... . , CO!ßpany: Fièld: Site: Well: Wellpath: BPAmoco lisbume lis DS 01 L 1-15 L1-15A Date: 10/30/2003 Time: 13:53:42> J>ágt!: Co-ordinate(NE) Reference: Well: L 1-15, Tru~N()rth Vertical (rVD) R~ference: 6: 15 12/31/1989>00:00 51.0 Section (VS) Reference: Well (0.00N,O.00E,335.00Azi) Survey Calculation l\fethOd: Minimum Curvature Db: Oracle Field: lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: lis DS 01 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5970246.77 ft 683519.17 ft Latitude: 70 19 Longitude: 148 30 North Reference: Grid Convergence: 25.721 N 42.654 W True 1.40 deg Well: L1-15 Slot Name: 15 L 1-15 Well Position: +N/-S 4581.30 ft Northing: 5974953.56 ft Latitude: 70 20 10.759 N +E/-W 5199.48 ft Easting : 688604.75 ft Longitude: 148 28 10.805 W Position Uncertainty: 0.00 ft Wellpath: L 1-15A 500292199501 Current Datum: 6: 1512/31/198900:00 Magnetic Data: 10/11/2003 Field Strength: 57585 nT Vertical Section: Depth From (TVD) ft 37.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L 1-15APB1 10930.28 ft Mean Sea Level 25.63 deg 80.89 deg Direction deg 335.00 Height 51.00 ft Survey Program for Definitive Wellpath Date: 10/30/2003 Validated: Yes Version: 6 Actual From To Survey Toolcode ft ft 100.00 10500.00 1 : Schlumberger GCT multishot (100.00-11~ 10569.00 10930.28 MWD (10569.00-11243.00) (2) MWD 10960.2311800.00 MWD(10960.23-11800.00) MWD Tool Name Schlumberger GCT multishot MWD - Standard MWD - Standard Annotation 10569.00 10930.28 11800.00 8761.60 8827.32 8744.30 Window KOP TD Survey: MWD Start Date: 10/12/2003 Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Engineer: Tied-to: From: Definitive Path RECE\VEO J~N ~ 3 '2.004 . Gommi$6\On .\ & Gas Gons. ~\as~a 0\ ~ntM{a\le ~~~(\f\~ ... . . .Ii. ObP BP-GDB BA_ IUGIIIS Baker Hughes INTEQ Survey Report INTEQ . Time: 13:53:42 .... .......... Page: i/ i:: ":;" Well: L1-15, True N()r"th </";:'/; 6:.1512/3111989.00:005-1.0 ";':y,"' Well (0.OON,O.OOE,335:00Ä2:0 Oracle Minirnum Curvature Db: Survey SSTv])· VS DLS ft ft l1eg/1 QOft 10569.00 37.28 250.64 8761.60 8710.60 -1712.23 -4584.19 5973126.68 684065.34 385.55 0.00 10930.28 95.94 273.94 8827.32 8776.32 -1684.37 -4919.01 5973146.11 683729.94 552.30 17.13 10960.23 91.46 271.45 8825.39 8774.39 -1682.97 -4948.86 5973146.77 683700.08 566.19 17.10 10987.61 90.55 285.24 8824.91 8773.91 -1679.01 -4975.88 5973150.05 683672.97 581.20 50.47 11025.84 93.93 287.85 8823.41 8772.41 -1668.13 -5012.49 5973160.00 683636.09 606.53 11.17 11055.76 94.48 298.94 8821.21 8770.21 -1656.30 -5039.83 5973171.13 683608.46 628.80 37.01 11087.99 90.86 305.58 8819.71 8768.71 -1639.13 -5067.04 5973187.62 683580.84 655.87 23.44 11118.91 91.68 309.82 8819.02 8768.02 -1620.23 -5091.49 5973205.90 683555.92 683.33 13.96 11153.67 94.86 314.38 8817.04 8766.04 -1596.98 -5117.23 5973228.49 683529.60 715.28 15.97 11183.51 109.27 317.23 8810.82 8759.82 -1576.12 -5137.53 5973248.83 683508.79 742.76 49.18 11214.73 111.94 316.90 8799.83 8748.83 -1554.73 -5157.43 5973269.71 683488.35 770.56 8.61 11255.99 109.56 337.79 8785.07 8734.07 -1522.44 -5178.06 5973301.47 683466.92 808.54 47.66 11297.61 98.73 349.85 8774.88 8723.88 -1483.79 -5189.17 5973339.82 683454.85 848.26 38.26 11337.01 1 08.42 352.10 8765.64 8714.64 -1446.02 -5195.18 5973377.43 683447.88 885.04 25.21 11370.57 104.38 358.95 8756.16 8705.16 -1413.95 -5197.67 5973409.43 683444.59 915.16 22.98 11411.65 93.83 359.78 8749.67 8698.67 -1373.45 -5198.12 5973449.90 683443.12 952.05 25.76 11443.13 91.39 11.67 8748.23 8697.23 -1342.22 -5194.98 5973481.20 683445.47 979.03 38.52 11474.74 89.69 10.27 8747.93 8696.93 -1311.19 -5188.97 5973512.37 683450.70 1004.61 6.97 11531.37 92.85 350.70 8746.66 8695.66 -1254.86 -5188.49 5973568.69 683449.77 1 055.46 34.99 11560.67 97.02 346.36 8744.14 8693.14 -1226.26 -5194.29 5973597.13 683443.25 1083.83 20.50 11590.67 98.30 349.86 8740.14 8689.14 -1197.17 -5200.41 5973626.06 683436.40 1112.78 12.32 11627.90 98.17 358.58 8734.80 8683.80 -1160.55 -5204.12 5973662.57 683431.77 1147.54 23.18 11656.34 93.26 356.80 8731.97 8680.97 -1132.28 -5205.26 5973690.80 683429.92 1173.64 18.35 11685.74 89.32 349.47 8731.31 8680.31 -1103.13 -5208.77 5973719.86 683425.68 1201.55 28.30 11716.39 85.37 1.18 8732.73 8681.73 -1072.67 -5211.27 5973750.24 683422.42 1230.21 40.27 11745.63 81.34 7.19 8736.12 8685.12 -1043.72 -5209.16 5973779.23 683423.80 1255.55 24.63 11800.00 81.34 7.19 8744.30 8693.30 -990.40 -5202.43 5973832.70 683429.18 1301.04 0.00 Wellpath: (L 1-1 5/L 1-1 SA) Created By: Brij P6ttiis Azimuths to True North Magnetic North: 25.63' Magnetic Field Strength: 57585nT Dip Angle: 80.89' Date: 1011112003 Model: bggm2003 T BP Amoco Pa",nl Wollpath: Tie on MO: North +f;J,W 1 1 f .... . BP-GDB Baker Hughes INTEQ Survey Report . (~o3-- )&0 Bit. BAKD IUGHU INTEQ ( ObP Company: BP Amoco Field: Lisbume Site: Lis DS 01 ~:::~ath:..4Iii·~ Field: Lisburne North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: Lis DS 01 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Date: 10/30/2003 Time: 14:07:53 Page: 1 Co-ordinate(NE) Reference: Well: L1-15..True North Vertical (TVD) Reference: 6: 1512/31/198900:00 5hO Section (VS) Reference: Well (0.ooN,0.00E,253.31Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 5970246.77 ft 683519.17 ft Latitude: 70 19 Longitude: 148 30 North Reference: Grid Convergence: 25.721 N 42.654 W True 1.40 deg Well: L1-15 Slot Name: 15 L1-15 Well Position: +N/-S 4581.30 ft Northing: 5974953.56 ft Latitude: 70 20 10.759 N +E/-W 5199.48 ft Easting : 688604.75 ft Longitude: 148 28 10.805 W Position Uncertainty: 0.00 ft Height 51.00 ft Wellpath: L 1-15APB1 500292199501 Current Datum: 6: 1512/31/198900:00 Magnetic Data: 9/13/2003 Field Strength: 57583 nT Vertical Section: Depth From (TVD) ft 37.00 Survey Program for Definitive Wellpath Date: 10/4/2003 Validated: Yes Actual From To Survey ft ft . 100.00 10500.00 10569.00 11243.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 L 1-15 10569.00 ft Mean Sea Level 25.66 deg 80.89 deg Direction deg 253.31 Version: Toolcode Tool Name 1 : Schlumberger GCT multishot (100.00-11~ MWD (10569.00-11243.00) MWD Annotation l\ID TVD ft ft 10500.00 8706.93 TIP 10569.00 8761.60 KOP 11243.00 8804.07 TD Survey: MWD Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Survey Incl Azim TVD SSTVD dElg dElg ft ft 10500.00 37.92 249.13 8706.93 8655.93 10569.00 37.28 250.64 8761.60 8710.60 10611.24 50.51 262.43 8792.02 8741.02 10640.45 62.02 268.04 8808.22 8757.22 10669.01 70.22 278.81 8819.80 8768.80 10699.66 80.25 289.21 8827.62 8776.62 10741.54 84.89 274.50 8833.07 8782.07 10771.19 86.93 273.31 8835.18 8784.18 10800.55 89.32 271.42 8836.14 8785.14 10841.24 93.64 277.26 8835.09 8784.09 10873.00 94.88 281.21 8832.73 8781.73 ~~'b {\\~~ Schlumberger GCT multi shot MWD - Standard KECFIVFD JAN23~:z004 Start Date: Alaska Oil & Gas Cons. Commiss'ol Anchorage 10/4/2003 Engineer: Tied-to: From: Definitive Path NIS EIW MapN MapE VS DLS ft ft ft ft ft dElg/100ft -. -1697.75 -4544.66 5973142.15 684104.49 4840.77 0.00 -1712.23 -4584.19 5973126.68 684065.34 4882.80 1.63 -1718.66 -4612.59 5973119.55 684037.12 4911.84 36.71 -1720.59 -4636.75 5973117 .01 684013.02 4935.54 42.49 -1718.96 -4662.74 5973117 .98 683986.99 4959.97 44.83 -1711.75 -4691.40 5973124.48 683958.16 4985.35 46.30 -1703.27 -4731.92 5973131.93 683917.44 5021.73 36.54 -1701.26 -4761.42 5973133.20 683887.90 5049.41 7.96 -1700.04 -4790.74 5973133.67 683858.56 5077.15 10.38 -1696.97 -4831.27 5973135.73 683817.97 5115.09 17.85 -1691.89 -4862.53 5973140.02 683786.60 5143.57 13.00 ObP Company: Field: Site: Well: Wellpath: Survey MD ft 10930.28 10969.50 10999.38 11045.86 11077.85 11109.03 11146.68 11178.78 11243.00 BP Amoco Lisbume Lis DS 01 L1-15 L 1-15APB1 Incl deg 95.94 96.22 95.42 94.78 96.02 95.93 93.63 91.08 91.08 Azim deg 273.94 279.14 285.05 289.21 293.37 296.75 302.59 308.60 308.60 . BP-GDB . Baker Hughes INTEQ Survey Report II.. BAKD HUGMIS INTEQ Date: 10/30/2003 Time: 14:07:53 Page: 2 Co-ordinate(NE) Reference: Well: L1-15, True Nörth Vertical (TVD) Reference: 6: 1512/31/198900:0051.0 Section (VS) Reference: Well (0.00N,O.00E,253.31Azi) Survey Calculation Method: Minimum Curvature Db: Oracle TVD SSTVD N/S EIW MapN MapE VS DLS ft ft ft ft ft ft ft deg/100ft 8827.32 8776.32 -1684.37 -4919.01 5973146.11 683729.94 5195.52 12.77 8823.17 8772.17 -1679.93 -4957.75 5973149.58 683691.11 5231.35 13.20 8820.13 8769.13 -1673.71 -4986.80 5973155.07 683661.92 5257.39 19.86 8816.00 8765.00 -1660.07 -5031.03 5973167.59 683617.36 5295.84 9.02 8812.99 8761.99 -1648.51 -5060.70 5973178.40 683587.41 5320.94 13.51 8809.74 8758.74 -1635.38 -5088.78 5973190.82 683559.00 5344.07 10.79 8806.60 8755.60 -1616.82 -5121.37 5973208.56 683525.97 5369.95 16.62 8805.28 8754.28 -1598.16 -5147.43 5973226.55 683499.44 5389.56 20.32 8804.07 8753.07 -1558.10 -5197.61 5973265.34 683448.27 5426.13 0.00 .. . T BP Amoco 51,OOft 0,00 0.00 37.00 Oligìn +EI·W pa...,nt Wellpath: Tie on MD: .00 51 1 600 5h"f~ . !3ô3-/âÒ . Date: 10-27-2003 Transmittal Number: 92627 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. This data set from Reeves is not LDWG. Reeves WireLine is a new company working on the North Slope. We did not want to over burden them with special processing. They will only log two wells this year and are a special case. If you have any questions, please contact me in the PDC at 564-4091 Ll-15A REEVES AIT;RESISTIVITY 14-0CT-03 1 OR 8504 8798 GPMA LISBURNE AIT;RESISTIVITY 14-0CT-03 1 OR 10530 11198 LWD (DEN) ; LWD DENSITY 14-0CT-03 1 OR 8~04 8798 LWD (DEN) ; LWD DENSITY 14-0CT-03 1 OR 10530 11152 LWD (NEU);LWD NEUTRON 14-0CT-03 1 OR 8504 8798 LWD (NEU);LWD NEUTRON 14-0CT-03 1 OR 10530 11152 SONIC; ACOUSTIC 14-0CT-03 1 OR 8504 8798 SONIC;ACOUSTIC 14-0CT-03 1 OR 10530 11198 o~..¡.. 10 S- 30 \tlqf3 LWD y;;, 14r14 C CD-!èð,...,) 1 L¡- Cl¿7- 03 ~'''-- ... ~ ~.,\:~ /~~.'\'_') '- () .~,,~.,,<"'-.. Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center o C: 1~' ~~' Attn: Howard Oakland (AOGCC) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 · . ~~£ mJ} !Æ ~!Æ ~ ~ ~IÆ / FRANK H. MURKOWSKI, GOVERNOR A.,ASKA. OILAlO) GAS CONSERVATION COMMISSION / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit LI-15A BP Exploration (Alaska), Inc. Permit No: 203-120 Surface Location: 2601' NSL, 2484' EWL, Sec. 01, TIIN, RI4E, UM Bottomhole Location: 2787' NSL, 2949' WEL, Sec. 02, TUN, Rl4E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~ í~~ Randy R'hedrich Commissioner BY ORDER OF THE COMMISSION DATED this 5'0 day of June, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section i¡...J.(,Æ- v¡z..'(1..-0é) '5 Hole 4-1/8" STATE OF ALASKA ALASKA AND GAS CONSERVATION COM&ION PERMIT TO DRILL 20 AAC 25.005 11 b. Type of well 0 Exploratory Oßtratigraphic Test II Development Oil o Service 0 Development Gas I!" Single Zone~ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 51' Prudhoe Bay Field I Lisburne 6. Property Designation Pool ADL 028302 7. Unit or Property Name Prudhoe Bay Unit / 8. Well Number /' L 1-15A 9. Approximate spud date 08/01/03 /" Amount $200,000.00 14. Number of acres in property 15. pr~sed depth (MD and TVD) 2560 13076' MD / 8841' TVD o 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 100 Maximum surface 268(}Aþsig, At total depth (TV D) 8900' I 3750 psig Setting Depth Top Bottom .Lenath MD TVD MD TVD 25'r6' .:J.95ðO'"' 8656' 13076' 8841 ' UOi' /0 «flf ¡N4k 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 688605. Y = 5974954 2601' NSL, 2484' EWL, SEC. 01, T11 N, R14E, UM . At top of productive interval x = 684077, Y = 5973130 891' NSL, 2089' WEL, SEC. 02, T11 N, R14E, UM At total depth x = 683169, Y = 5975005 2787' NSL, 2949' WEL, SEC. 02, T11N, R14E, UM 12. Distance to nearest property line 113. Distance to nearest well / ADL 028301, 2492' MD No Close Approach ./ 16. To be completed for deviated wells Kick Off Depth 10568' MD Maximum Hole Angle 18. Casing Program S ·f· at' Size pecl IC Ions Casina Weight Grade CouDlina 3-3/16" 6.2# L-80 TCII Number 2S 100302630-277 Quantity of Cement (include staae data) Uncemented Slotted Liner ..-/ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11042 feet Plugs (measured) true vertical 9141 feet Effective depth: measured 10996 feet Junk (measured) See Diagram true vertical 9104 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner Liner JUN .;~ f; 119' 20" 4281' 13-3/8" 9705' 9-5/8" 1030' 7-5/8" 869' 5-1/2" Cemented MD TVD 2150# Poleset 119' 119' 2775 sx AS III, 500 sx 'G', Top Job 90 sx AS I 4281' 4090' 500 sx Class 'G' 9705' 8124' 190 sx Class 'G' 9485' - 10515' 7965' - 8719' 570 sx Class 'G' 10168' ·11037' 8459' - 9137' Perforation depth: measured 10552' - 10942' (Multiple Intervals) true vertical 8748' - 9060' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th~for,~e and correct to the best of my knowledge Signed Ted Stagg ~ ~~ Title CT Drilling Engineer Date ~Æ~:3 Perm' ":>"1)3 _ I~ 1:~1~~~~~1' ~'-"F lfJ'f':)'b"je I :~:£;:':~ments Conditions of Approval: Samples Required 0 Yes .No Mud L~ Required º~s ~o Hydrogen Sulfide Measures ~es 0 No Directional Survey Required .aves 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 Oti~øä-¡-~~ to ~500 psJ, Randy Ruedrlch Approved By Form 10-401 Rev. 12-01-85 20. Attachments Commissioner ORIG!~Jl\ by order of the commission DaIS SU~~i~2. e e BP L 1-15A RWO/CTD Sidetrack Summary of Operations: Well Ll-15 is scheduled for a through tubing sidetrack with coiled tubing. Prior to CTD sidetracking, the 2 7/8" tubing will be pulled, a leak in the 9 5/8" casing will be covered with a cemented scab liner and new 4 V2" tubing will be installed. The sidetrack, Ll-5A, will kick off from a window milled off a mechanical whipstock near the top of the Lisburne, / Approximately 2,564 ft of 3.75"-4 1/8" open hole is planned to access the target. The well will be completed with a pre-drilled, un-cemented liner. Pre-rig Prep work. Planned for July 07, 2003 startup. 1. IA leak rate of 5.8 gpm at 2460 psi established. Communication with Cretaceous confirmed. 2. MIT-OA tested to 2000 psi on 6.2.03. 3. Obtain static BHP and run caliper over 5 Yz" liner and 2 7/8" tubing. 4. Kill well with sized salt pill and seawater (est. 8.1 ppg pore pressure). 5. Set plug in 2 7/8" tailpipe. 6. Chemical cut tubing just above existing 2 7/8" x 9 5/8" packer. Circulate seawater and freeze protect. Nordic 2 RWO - Tubing swap, scab liner. Planned for ~ust 01, 2003 startup. 1. RU Nordic 2 with 13-5/8" BOPE. Test stack. 2. Pull 2 7/8" tubing. Mill and recover 2 7 /8" p~er and tailpipe. 3. Use RTTS to locate leak in 9 5/8" casing. /,,/ 4. Install and cement 7" scab liner from top of 7 5/8" liner to a point above 9 5/8" leak. 5. Install 4 V2" tubing with packer, 4 GLMs and SSSV, new tubing spool and 4 1/16" tree. 6. PT completion. NU 7-1/16" CTD BOPE. Test. /' 7. Use e-line to install whipstock in 5 1/2" liner at approx. 10,568' MD. 8. Squeeze perforations with minimum 25 bbls cement leaving TOC approx.10 ft above whipstock. 9. Continue with CTD window milling and open hole drilling. Nordic 2 CTD - Mill window, Drill and Complete sidetrack: 1. Mill 3.80" window from whipstock at 10,568' (871Oss), through the 5 1/2" liner. 2. Directionally drill-2508' of 3.75"-4 1/8" open hole. Log open hole with GR/Resistivity. 3. Run 33/16" pre-drilled liner from TD up to approx.~ md (8656ss). 4. RD Nordic 2. IOc(,!.,~ Mud Program: · RWO: 2% KCI and 2ppb Biozan for milling. · CTD: PIo-Pro (8.6 - 8.7 ppg). 2% KCI will be used for drilling if losses are near total. /" Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / · 2560 ft of 3 3/16" pre-drilled liner. .. Well Control: · BOP diagrams are attached. · Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. / e e Directional · See attached directional plan. Max. planned hole angle is approx. -100 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray and Resistivity will be run over the entire open hole section. Hazards / · H2S at 45 ppm was seen during drilling of L 1-15. The highest H2S measured on L I drill site is 50 ppm · Lost circulation risk is considered high. Drilling may be done with water if losses are near total. Reservoir Pressure · Pore pressure is estimated to be 3750 psi at 8900'TVDss (8.1 ppg emw). . · Maximum surface pressure with gas (0.1 psi/ft) to surface is 2680 psi /" TREE = CIW 2-9/16" WELLHEAD = CIW ACTuATOR ,;~~ ~~,~ KB. ELEV = 52' BF. ELEV = h"M~'~'~=",,'"M"'W=~_~=""N.~._A_._"""'V<.__~.,=w KOP = 2900' ....................................................... Max Angle = 45 @ 9800' Datum MD = 10681' ~·~~~~"n~~'=~ Datum lVD = 8800' SS e L 1-15 . SAFETY NOTES: 9·5/8" TO FORMATION 1 COMMUNICATION, CRETACEOUS LEAK 1 13-3/8"CSG, 68#, L-80,ID=12.415" H 4281' ~ Minimum ID = 2.250" @ 10276' 2-7/8" OTIS XN NIPPLE :g: 1 TOP OF 7-5/8" LNR H 9484' . 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9705' r-- TOP OF 5-1/2" LNR H 10168' I 12-7/8" TBG-IPC, 6.5#, L-80, .00578 bpf, ID = 2.441" H 10288' I 17-5/8" LNR, 29.7#, L-80, .0459 bpf, ID = 6.875" H 10515' 1 '" PERFORATION SUMMARY REF LOG: LDT/CNL ON 01119/90 ANGLE AT TOP PERF: 38 @10551' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERV AL I Opn/Sqz I DA TE SEE PAGE 2 FOR PERFORATION DATA . 2160' H 2-7/8"CAMCOTRDP-1A SSSV, ID=2.312" 1 - cL CHEMICAL MANDRELS ~ 1ST I MD IlVDI DEVI TYPE IVLVILATCHI PORT I DATE I 1 2284 2284 0 KBMG-L DMY BK-2 0.0 03/07/90 GAS LIFT MANDRELS DEV TYPE VLV LATCH PORT DATE 8 D-14R TG 43 D-14R TG 40 D-14R DMY TG 43 RKED RKP L ST MD lVD 2 2774 2773 3 5618 5057 4 7874 6750 5 9327 7849 o 04/13/03 ~ .--1 9414' 1-1 9-5/8" x 2-7/8" BAKER SB-3A PKR, ID = 2.441" 9493' H 9-5/8" X 7-5/8" TIW HYDRO HNGR, ID = 6.875" I ~ z . 10176' H 7-5/8' X 5-1/2" BAKER CPH PKR, ID = 4.875" I ~ 10178' H 7-5/8" X 5-1/2" BAKER HYFLO II HNGR, ID = 4.9375" I 10276' H 2-7/8" OTIS XN NIP, ID = 2.250" 1 10288' H WLEG WI BAKER, SHEAR SUB, ELMD 10265' H ELMDTTLOGGED03/15/90 I .. I 10942' 11 I PBTD H 10996' 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" H 11037' ~ DATE 03/07/90 03/10/01 09/30101 02/09/03 03/14/03 04/13/03 REV BY SIS-MD RNlTP A TDITP EHlTLH JJ/KAK COMMENrS ORIGINAL COMA-ErION FINAL CORRECTIONS DELETE WAIVER SAFETY NOTE CORRECTED DIAGRAM GLV C/O DATE REV BY PREF BALLS- STUCK IN PROD LOG TOOL CENTERALIZER- 04/10/97 COMMENTS LISBURNE UNIT WELL: L1-15 PERMIT No: 1891320 API No: 50-029-21995-00 SEC 1, T11 N, R14E, 2367.58' FEL & 4479.83' FNL BP Exploration (Alaska) e L 1-15 . ~ ~ CL L :8: ~ PERFORA TION SUMMARY II . REF LOG: LDT/CNL ON 01119/90 ANGLE AT TOP PERF: 38° @ 10552' ... ~ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 'S 10552 - 10599 0 03/15/90 Z Z 2-1/8" 4 10562 - 10602 0 09/08/96 2-1/8" 4 10609-10619 0 09/08/96 . . 2" 'S 10614 - 10705 0 03/15/90 2-1/8" 4 10634 - 10639 0 09/08/96 2-1/8" 4 10662 - 10672 0 09/08/96 2-1/8" 4 10685 - 10690 0 09/08/96 2-1/8" 4 10720 - 10730 0 09/08/96 2" 'S 10724 - 10798 0 03/15/90 2-1/8" 4 10735 - 10740 0 09/08/96 2-1/8" 4 10763 - 10768 0 09/08/96 .. 2" 'S 10814 - 40873 0 03/15/90 ... 2-1/8" 4 10838 - 10848 0 09/08/96 2-1/8" 4 10868 - 10886 0 09/08/96 2-1/8" 4 10896 - 10912 0 09/08/96 2-1/8" 4 10934 - 10942 0 09/08/96 . Selective Shots & DATE REV BY COMMENTS DATE REV BY COMMENTS 03/07/90 ORIGINAL COMPLETION 03/10/01 SIS-MD FINAL 09/30/01 RNITP CORRECTIONS 02109103 A TDITP DELETE WAIVER SAFElY NOTE 03/14/03 EHlTLH CORRECTED DIAGRAM e LISBURNE UNIT WELL: L 1-15 PERMIT No: 1891320 API No: 50-029-21995-00 SEC 1, T11N, R14E, 2367.58' FEL & 4479.83' FNL BP Exploration (Alaska) '. TREE '" WELLHEAD '" ACTUATOR '" KB. ELEV '" BF. KOP'" Max Angle '" Datum MD '" Datum TV D '" CPN CPN SAFETY NOTES: 9·5/8" TO FORMATION COMMUNICATION, CRETACEOUS lEAK ..15A Proposed Completion 2900' 45 @ 9800' 10681' 8800' SS 113-318" CSG, 68#, L-80, ID'" 12.415" 4281' ¡---4 I TOP OF 7-5/8" LNR H 9484' 19-5/8" CSG, 47#, L-80, ID'" 8.681" H 1 TOP OF 5-1/2" LNR l-i 10168' 17-5/8" LNR, 29.7#, L-80, .0459 bpf, ID'" 6.875" H 10515' I 10996' ¡ 5-1/2" LNR, 17#. L-80, .0232 bpf, ID = 4.892" l-i 11037' DATE REV BY COMMENTS DATE REV BY 03/07/90 ORIGINAL COMPLETION 03/10/01 SIS-MD FINAL 09/30/01 RNlTP CORRECTIONS 02/09/03 A TDITP DELETE WANER SAFETY NOTE 03/14/03 EHlTLH CORRECTED DIAGRAM 04/13/03 JJ/KAK GL V C/O H H H H 9493' l-i 9-5/8" x 7-5/8" TPN HYDRO HNGR, ID = 6.875" ~ I. 10176' I--L 7-5/8' x 5-1/2" BAKER CPH PKR, ID =4.875" I 10178' H 7-5/8" X 5-1/2" BAKER HYFLO II HNGR, ID = 4.9375" I Top Lisburne 10,555' MD (8700'ss) Â tt.. I 10942' 11 PREF BALLS- STUCK IN PROD LOG TOOL CENTERALIZER - 04/10/97 COMMENTS LISBURNE UNIT WELL: L 1-15 PERMIT No: 1891320 API No: 50-029-21995-00 SEC 1, T11 N, R14E, 2367.58' FEL & 4479.83' FNL BP Exploration (Alaska) L1-15 Marker Depths @Orig Wellbore 01 OlftTVD 01 Olft TVD Vertical Section Path Distance (Feet) 0 500 8200 8250 8300 8350 8400 8450 8500 .-.. ... w w k::.B550 0 ¡:: 8600 8650 8700 8,693 8750 ~~ 8800 8850 8,842 8900 reI M5 1,000 1,500 2,000 2,500 3,000 3,500 8,7131 8,7131ft TVD 8,6931 8,693ft TVD Kick Off 8,71 0lft TVD 10,568 ft MD Deprtr @KO 4,908 ft LH5A Case 115 June 26, 2003 Ted x4694 MD KO Pt 10,568 MD New Hole 2508 Total MD 13,076 TVD TD 8,841 DLS Angle @ K.O.= 37 deg/100 Tool Face Length deg MD:10568 1 Curve 4 12 600 Tot Dr!d:2508 ft 13076 TD 1 5 2,508 L1-15 IWell Name 2,000 CLOSURE I Distance ft Az. deg 1,500 NEW HOLE EIW (X) NIS (Y) L1-1 5A Kick Off Case 11 5 June 26, 2003 1,000 TD Ted x4694 State Plane 683,169 5,975,005 Surface Loc 688,605 5,974,952 500 u DLS .9 11II deg/100 Tool Face Length J:? ° (J) E e .... B c::: -500 Curve 4 12 -94 600 1\1 .... III 'S >- 0 5 1 -1 ,000 2,508 -2,000 -6,000 -5,500 -5,000 -4,500 X distance from Sfc Loc -4,000 -3,500 -3,000 Drawn: 6/26/2003 11 :20 Plan Name; Case 1 22 · , e ( '-- ~ =q Choke line HCR valve ~ I =e:: ~ I capped off O@ =@ ~ L ~ " I 2{@~ MOJ 6/13/03 7 1/16" annular preventor I 071/16" OBOP 071/16" () BOP ó0 I / 13 5/8" mud cross e 7" riser to rig floor '" Nordic 2 drilling BOP with CoilTrak pressure .J deployment capability / þ= Blind/shear combi ram /"" þ= 2 3/8" pipe/slip combi ram Kill line ~Rvarve I þ= 3 1/8" slip ram ~- F:J= 2 3/8" x 3 1/2" VBR pipe ram / 7" full opening master valve (optional) I \ I J@I®~ oa_off ~ 2.1/8" x 5" VBR pipe ram n 135/8" BOP / I 11" tubing head I ~@ e e 055085 DATE I I CHECK NO. 6/9/2003 055085 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 3/2003 INV# CK060403E PERMIT TO DRILL FEE )J~ \sA- H 'TTACHED CHECK IS IN PAYMENT FOR rrEMS DESCRIBED ABOVE. TOTAL ~ AY: PO BOX 196612 .... ANCHORAGE, AK 99519-6612 . . . .. . . . B P··· r..·~1· ". .¡till.. "UII ""1 ....~, .'" III. ,_ l ,I t..· I". 'I" . ..~.. qUI .,nl '111111 ....... "IO' DATE .... AMOUNT June 9, 20031 ¡ .. *******$1ÖO.00*******1 NOT VALID AFTER 120 DAYS . r:..·.....:·..........~"....u..:;.._."....... .....~...n~..:.......¡......i?l .:.:..:; :.~..:.:·:···.:~>.:.:.:~\;/.S. .>:; ~·~·:·:~\:·5:·. ~~;:ø~=1:.?~i: OTHE rRDER rF: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 11105 SOB Sill =:0... ~ 20 j8 q 51: 0 ~ 218 q bill e - TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BEINCLUDEDINTRANSNUTTALLETTER WELL NAME ~ L I ~/~4 PTD# 2-03 - 12D CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing weD-, 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(1), 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). PJLOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. 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. PTD#: 2031200 Administration 1 2 3 4 5 6 7 8 9 10 11 Appr Date 12 SFD 6/27/2003 13 14 15 16 17 Engineering 18 19 20 21 22 23 24 25 26 27 Appr Date 28 WGA 6/27/2003 29 30 31 32 33 34 Geology 35 36 Appr Date 37 SFD 6/27/2003 38 39 Geologic Commissioner: j) I-J? Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UN LIS L1-15A Program DEV Well bore seg 0 Field & Pool PRUDHOE BAY, LISBURNE OIL - 640144 Initial Class/Type DeV 11-01L GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal 0 pjrmitfee attache~:L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Leasj_number_appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Unique weltnamj_aod Ollmb_er _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ . . . . _ . _ _ _ . . _ . _ _ _ _ _ . _ Yj$ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . _ . _ . _ _ _ . . . . _ _ _ _ _ . . _ . _ _ _ _ . . . . _ _ _ _ _ . . . _ _ _ _ _ _ . . . _ _ _ . WelUocatjd in.a_ctefjoe.dppoL _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ WeJUocatjd pr_oper .distance_ from driJling ullilb_oundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yj$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ WellJocat~ proper _distaoce_ from other welJs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yj$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _S_uffjcient.acreage_ayailable in_dJilliogun_iL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ Yj$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Jtdjviated, js weJlbore plaUncJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Operator only: affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Oper:ator bas.apprppriate.Qond inJorce . . . _ _ _ _ . . . . _ _ _ _ _ _ . _ . _ _ _ _ . . . _ _ _ . _ . .Yj$ _ _ _ . . . . _ _ _ . _ . _ . _ _ _ _ . . . _ _ _ _ _ . . _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . . . . _ _ _ . . _ _ _ _ pjrmit cao be iS$lIed without ço_nserva_tiOIl order _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YjS _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ pjrmit cao be iSSlIed wjthout actministratÏ\le_approvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YjS _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Can permit be approved before 15-day wait Yes WeJUocatedwithinareaand_strata_authorizedby_lojectipoOrd~r#(PutlO#in_comm~ots)_(For. NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e AJI welJs.witJ1in Jl4.mile.area_of reyiew jdjotified (For servjCj.we[l ooly:). . . . _ _ _ _ _ . . _ _ _ _ _NA. . _ . _ _ _ . . . _ . . _ _ . . . . . _ _ _ _ . . . . _ _ _ _ . . _ _ _ _ _ _ . . . . _ . _ _ . . . . . _ _ _ _ _ . . _ . _ _ _ . _ . . _ _ _ _ . . . PJe-produ~ectiojector; .dur.ation_ofpre-pro.ductiooj$sthan_3months_(For_ser:.vicewellonJy) _ _ _NA. _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _AÇMP_FJndjng_of Con.sisteoçy_h_as bee_nJssued_ forJbi$ project_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA. _ _ _ _ _ _ _ Sidetraçk of.e~i$ting welJ. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _C_oodu_ctor stringpJovided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _NA. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ S_urfaCj _casing_PJotects alLknown_ USDWs _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _CMTv_oladequ_ate.to circjJlate_o_n_cond_uctor_& SUJf.C$g _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ .CMT v_ol_ adeqllate.to tie-in Jong _striog to_surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ NA. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _CMTwíll coyer_aJl koown_productiye horilOn.s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ Slotte_d, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _C_asiog desigos actecua_te for C,.T. B_&_perruafrO$t _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ .Yj$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 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PP9_EMW;_will ctriJI with 8.6-8..7_ppg mjJd._ _ _ _ _ _ _ _ . _Sji.smic_analysjs_ of shallow gas_z..ooes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _NA. _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Sjabed _condjtipo survey _(if off-shore) _ _ _ _ _ _ _ . _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Conta_ct oamelpJ1oneJorweekly prøgress.reports [e)Cploratøry _onlYl _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Date: Engineering Commissioner: Date Public Commissioner °cJl21\:~~~ ~ Date ~~~ LJ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, 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. . . ¿jO(3-/é)O RECEIVED OEC 11 2003 **** REEL HEADER **** MWD 03/11/10 BHI 01 Alaska Oil & Gas Coo$, commi$1Jion Andlomge LIS Customer Format Tape };t1(J"- **** TAPE HEADER **** MWD 03/11/10 543243 01 3.75" CTK *** LIS COMMENT RECORD *** ! !!!! !!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10542.0000: STOP.FT 11800.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 1 TOWN. N 11N RANG. 14E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 52 DMF KB EKB .F 52 EDF .F N/A EGL .F N/A CASE.F 10575 OSl . DIRECTIONAL -Remarks MNEMONICS: ROP Rate of Penetration, ft/hr GRAX Gamma Ray APPARENT [RWD], MWD-API RPCHX Phase Resistivity, 2 MHz (LS) [MWD], Compensated & Borehole Corrected, ohm-m Phase Resistivity, 400 kHz (LS) [MWD], Compensated & Borehole Corrected, ohm-m Attenuation Resistivity, 2 MHz (LS) [MWD], Compensated & Borehole Corrected, ohm-m 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska) Inc. Ll-15A Prudhoe Bay Unit 70 deg 20' 10.759" N, 148 deg 28' 10.805" W North Slope Alaska Baker Hughes INTEQ 3.75" CoilTrak - USMPR/Gamma Ray 12-0ct-03 500292199501 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 RPCLX RACHX = Atten4lllon Resistivity, 400 kHz (LS) [~ Compensated & Borehole Corrected, ohm-m COMMENTS: (1) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface acquisition system. (2) Tools run in the string included CCL, Electrical Disconnect & circulating sub, a Drilling Performance sub (inner & outer downhole pressure, downhole weight on bit, & downhole temperature), a Gamma & Directional sub, Ultra Slim Multiple Propagation Resistivity (USMPR), & a Hydraulic Orienting sub with near bit inclination. (3) Baker Hughes INTEQ runs 1 - 3 were casing milling runs for sidetrack window. (4) Baker Hughes INTEQ run 4 - 6 utilized Gamma Ray with Directional services from 10568 - 10730 feet MD (8710 - 8781' SSTVD). (5) Baker Hughes INTEQ run 7 - 10 utilized an Ultra Slim Multiple Propagation Resistivity (USMPR) and Gamma Ray wth Directional services from 10730 - 11243 feet MD (8781 - 8753 SSTVD). MWD run 7 included a MAD pass up to the casing window. TD was reached on the wellbore Ll-15APB1 on MWD run 10. (6) Baker Hughes INTEQ runs 11 - 13 were used to create the open hole sidetrack at 10930 feet (8776 SSTVD) for the final hole section on Ll-15A. (7) Baker Hughes INTEQ run 14 utilized Gamma Ray with Directional services from 10930 - 10998 feet MD (8776 - 8774 SSTVD). (8) Baker Hughes INTEQ run 15 - 16 utilized an Ultra Slim Multiple Propagation Resistivity (USMPR) and Gamma Ray wth Directional services from 10998 - 11142 feet MD (8774 - 8767 SSTVD). MWD run 15 included a MAD pass up to the open hole sidetrack window. (9) Baker Hughes INTEQ run 17 - 21 utilized Gamma Ray with Directional services from 11142 - 11460 feet MD (8767 - 8697 SSTVD). (10) Baker Hughes INTEQ run 22 - 26 utilized an Ultra Slim Multiple Propagation Resistivity (USMPR) and Gamma Ray wth Directional services from 11460 - 11800 feet MD (8774 - 8767 SSTVD). (11) Per BP Exploration (Alaska) instructions, the data presented here is final and has been depth shifted to the PDC (Primary Depth Reference) for this well (Reeves Wireline, 14-0ct-03). REMARKS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are bit depths unless otherwise noted. (3) All Gamma Ray and USMPR data is real time data. (4) This wellbore was tied into parent well Ll-15 at 10550 feet MD. Top of casing window: 10569 feet MD (8710' SSTVD) Bottom of casing window: 10575 feet MD (8715' SSTVD) (5) An RA tag is located at 10577' MD (8717' SSTVD). (6) An open hole sidetrack was made at 10930 feet MD (8776' SSTVD) from Ll-15APB1. (7) The USMPR tool failed during at roughly 11645 feet MD (8682' SSTVD) . (8) The interval from 11768 to 11800 feet MD (8689 - 8693 TVD) was not logged due to sensor-bit offset at TD. CURVE SHIFT DATA BASELINE, MEASURED, 10550.4, 10549.4, 10560.8, 10559.8, 10567.0, 10565.7, 10575.1, 10574.9, 10580.6, 10579.1, 10589.2, 10588.5, 10593.4, 10592.7, 10613.6, 10612.7, 10628.3, 10626.8, 10637.7,10638.7, 10650.0, 10648.6, 10653.7, 10651.8, 10665.8, 10664.6, 10675.6, 10674.6, 10690.7, 10689.4, 10697.1, 10695.4, 10710.2, 10707.9, 10727.2, 10725.0, 10770.3, 10767.6, 10779.7, 10777.0, 10804.1, 10801.2, 10820.8, 10817.3, 10828.7, 10824.5, RACLX DISPLACEMENT -0.988281 -0.987305 -1.23438 -0.246094 -1.48145 -0.740234 -0.741211 -0.987305 -1.48145 0.987305 -1.48145 -1.97559 -1.23438 -0.988281 -1. 23438 -1. 72852 -2.22266 -2.22266 -2.71582 -2.71582 -2.96289 -3.45703 -4.19727 10847.7, 1084. -3.20996 . 10863.0, 10860.0, -2.96289 10881.0, 10878.6, -2.46973 10887.1, 10883.6, -3.45605 10891.0, 10888.3, -2.7168 10899.4, 10896.5, -2.96289 10911.2, 10909.9, -1.23438 10930.0, 10929.6, -0.494141 10952.8, 10952.5, -0.24707 10969.8, 10969.3, -0.494141 10979.8, 10979.6, -0.24707 10992.9, 10990.9, -1. 97461 11015.1, 11012.6, -2.46973 11046.8, 11047.8, 0.987305 11062.0, 11063.0, 0.988281 11075.8, 11075.4, -0.493164 11084.7, 11084.5, -0.24707 11090.7, 11090.7, 0 END Tape Subfile: 1 143 records. . . Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT Ll-15Afinal.xtf 150 BP Exploration (Alaska) Inc. Ll-15A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!! !!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by Reeves, 14-0ct-03 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX05 0.0 ROP ROP ROPA05 0.0 RACH RACH RACHX05 0.0 RACL RACL RACLX05 0.0 RPCH RPCH RPCHX05 0.0 RPCL RPCL RPCLX05 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per4lllord is: One depth per frame (value= 0) Datum Specification Block Sub-type 36 . is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RACH MWD 68 1 ohmm 4 4 4 RACL MWD 68 1 ohmm 4 4 5 RPCH MWD 68 1 ohmm 4 4 6 RPCL MWD 68 1 ohmm 4 4 ------- 24 Total Data Records: 70 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10542.000000 11800.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 83 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT Ll-15Afinal.xtf 150 BP Exploration (Alaska) Ll-15A Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP RACH GR ROP RACH GRAX ROPA RACHX 0.0 0.0 0.0 RACL RACL . RACLX 0.0 . RPCH RPCH RPCHX 0.0 RPCL RPCL RPCLX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RACH MWD 68 1 ohmm 4 4 4 RACL MWD 68 1 ohmm 4 4 5 RPCH MWD 68 1 ohmm 4 4 6 RPCL MWD 68 1 ohmm 4 4 ------- 24 Total Data Records: 70 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10542.000000 11800.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 3 83 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/11/10 543243 01 **** REEL TRAILER **** MWD 03/11/10 BHI 01 Tape Subfile: 4 2 records... . . Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Data Listing !!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!! ! !!!!!!! !! !!!!!! !!! Tape Subfile 2 is type: LIS DEPTH GR ROP RACH RACL RPCH RPCL 10542.0000 100.7540 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10542.5000 101. 9098 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10550.0000 140.3801 -999.2500 6064.5430 1426.7234 48895.1953 35674.1797 10600.0000 25.1542 44.7835 93.9647 2203.5962 78.7728 90.6954 10650.0000 25.0193 17.6640 6144.2070 2179.3960 173.6031 39979.6250 10700.0000 17.7805 22.0114 60.6546 33.1799 117.4793 94.6904 10750.0000 28.8140 66.0131 6064.4043 2179.3960 213.0156 492.7747 10800.0000 39.9353 54.9724 6064.5430 2179.3960 184.3169 298.9375 10850.0000 34.2923 81. 2169 6064.5430 2179.3960 202.5878 289.0109 10900.0000 36.7953 22.7620 6064.5430 2179.3960 108.5467 183.0615 10950.0000 26.2725 5.9271 4872.7793 2179.3960 109.9964 170.0875 11000.0000 26.6076 31. 8319 4988.9033 2179.3960 83.9705 88.2362 11050.0000 23.0879 14.9282 6042.7109 2179.3960 104.4524 166.6000 11100.0000 18.1128 13.8077 6064.5430 2179.3960 133.2947 220.0941 11150.0000 14.5368 46.4378 -999.2500 -999.2500 -999.2500 -999.2500 11200.0000 26.7513 5.8288 -999.2500 -999.2500 -999.2500 -999.2500 11250.0000 46.3047 34.3918 -999.2500 -999.2500 -999.2500 -999.2500 11300.0000 45.5101 22.7020 -999.2500 -999.2500 -999.2500 -999.2500 11350.0000 24.7732 36.5171 -999.2500 -999.2500 -999.2500 -999.2500 11400.0000 26.6624 44.4499 -999.2500 -999.2500 -999.2500 -999.2500 11450.0000 29.7391 59.9122 -999.2500 -999.2500 623.6766 -999.2500 11500.0000 19.4400 32.1225 -999.2500 -999.2500 616.0920 -.2500 . 11550.0000 24.4520 33.4980 -999.2500 -999.2500 409.0930 -999.2500 11600.0000 44.5923 31. 5698 -999.2500 -999.2500 239.8185 -999.2500 11650.0000 27.1395 30.6708 -999.2500 -999.2500 -999.2500 -999.2500 11700.0000 33.9936 10.5802 -999.2500 -999.2500 -999.2500 -999.2500 11750.0000 70.9178 43.3796 -999.2500 -999.2500 -999.2500 -999.2500 11800.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 10542.000000 Tape File End Depth 11800.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet . . Tape Subfile 3 is type: LIS DEPTH GR ROP RACH RACL RPCH RPCL 10542.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10542.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10550.0000 161.1069 -999.2500 6060.1768 1033.2388 25168.3789 18356.1562 10600.0000 24.7138 44.8887 83.7151 2175.6167 72.7637 77.7534 10650.0000 18.9861 13.3052 3077.5024 2222.9009 81. 6031 13214.3301 10700.0000 18.3266 25.1101 59.0644 15.3246 92.2294 49.7257 10750.0000 29.5776 66.4173 4675.1797 2179.3960 227.0927 301.7648 10800.0000 35.6932 46.1919 6108.8135 2179.3960 251.1372 649.5388 10850.0000 37.2246 85.3196 6064.5430 2179.3960 215.5271 382.1602 10900.0000 39.8513 29.5187 6064.5430 2179.3960 119.6684 209.3479 10950.0000 26.8266 4.9262 5445.3633 2179.3960 111.8124 169.6681 11000.0000 23.7998 62.7938 6087.7852 2179.3960 68.9326 86.1317 11050.0000 21. 7832 16.5338 6064.5430 2179.3960 102.9343 162.6128 11100.0000 18.1128 13.8077 6064.5430 2179.3960 133.2947 . 220.0941 11150.0000 14.5368 46.4378 -999.2500 -999.2500 -999.2500 -999.2500 11200.0000 26.7513 5.8288 -999.2500 -999.2500 -999.2500 -999.2500 11250.0000 46.3047 34.3918 -999.2500 -999.2500 -999.2500 -999.2500 11300.0000 45.5101 22.7020 -999.2500 -999.2500 -999.2500 -999.2500 11350.0000 24.7732 36.5171 -999.2500 -999.2500 -999.2500 -999.2500 11400.0000 26.6624 44.4499 -999.2500 -999.2500 -999.2500 -999.2500 11450.0000 29.7391 59.9122 -999.2500 -999.2500 623.6766 -999.2500 11500.0000 19.4400 32.1225 -999.2500 -999.2500 616.0920 -999.2500 11550.0000 24.4520 33.4980 -999.2500 -999.2500 409.0930 -999.2500 11600.0000 .5923 31. 5698 -999.25. -999.2500 239.8185 -999.2500 11650.0000 27.1395 30.6708 -999.2500 -999.2500 -999.2500 -999.2500 11700.0000 33.9936 10.5802 -999.2500 -999.2500 -999.2500 -999.2500 11750.0000 70.9178 43.3796 -999.2500 -999.2500 -999.2500 -999.2500 11800.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 10542.000000 Tape File End Depth 11800.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet Tape Subfile 4 . is type: LIS . . ey03--/dU . **** REEL HEADER **** MWD 03/11/11 RECEIVE!) BHI 01 DEC 11 2003 LIS Customer Format Tape Alaska 011 & Gas Gvn$. CommiS8ton Anchorage **** TAPE HEADER **** MWD 03/11/11 J l- >1:1) 543243 01 3.75" CTK *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! !! !! ! ! ! ! ! !!!!!!!! ! ! !!!! !!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10542.0000: STOP.FT 11243.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 1 TOWN.N 11N RANG. 14E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 52 DMF KB EKB .F 52 EDF .F N/A EGL .F N/A CASE.F 10575 OS1 . DIRECTIONAL -Remarks MNEMONICS: ROP Rate of Penetration, ft/hr GRAX Gamma Ray APPARENT [RWD], MWD-API RPCHX Phase Resistivity, 2 MHz (LS) [MWD], Compensated & Borehole Corrected, ohm-m Phase Resistivity, 400 kHz (LS) [MWD], Compensated & Borehole Corrected, ohm-m Attenuation Resistivity, 2 MHz (LS) [MWD], Compensated & Borehole Corrected, ohm-m Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. L1-15APB1 Prudhoe Bay Unit 70 deg 20' 10.759" N, 148 deg 28' 10.805" W North Slope Alaska Baker Hughes INTEQ 3.75" CoilTrak - USMPR/Gamma Ray 03-0ct-03 500292199570 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 RPCLX RACHX RACLX Attentlllon Resistivity, 400 kHz (LS) [~ Compensated & Borehole Corrected, ohm-m COMMENTS: (1) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface acquisition system. (2) Tools run in the string included CCL, Electrical Disconnect & circulating sub, a Drilling Performance sub (inner & outer downhole pressure, downhole weight on bit, & downhole temperature), a Gamma & Directional sub, Ultra Slim Multiple Propagation Resistivity (USMPR), & a Hydraulic Orienting sub with near bit inclination. (3) Baker Hughes INTEQ runs 1 - 3 were casing milling runs for sidetrack window. (4) Baker Hughes INTEQ run 4 - 6 utilized Gamma Ray with Directional services from 10568 - 10730 feet MD (8710 - 8781' SSTVD). (5) Baker Hughes INTEQ run 7 - 10 utilized an Ultra Slim Multiple Propagation Resistivity (USMPR) and Gamma Ray wth Directional services from 10730 - 11243 feet MD (8781 - 8753 SSTVD). MWD run 7 included a MAD pass up to the casing window. TD was reached on the wellbore Ll-15APB1 on MWD run 10. (6) Per BP Exploration (Alaska) instructions, the data presented here is final and has been depth shifted to the PDC (Primary Depth Reference) for this well (Reeves Wireline, 14-0ct-03). A block shift was applied for that portion of the wellbore below the kick off point at 10930 feet MD. REMARKS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are bit depths unless otherwise noted. (3) All Gamma Ray and USMPR data is real time data. (4) This wellbore was tied into parent well Ll-15 at 10550 feet MD. Top of casing window: 10569 feet MD (8710' SSTVD) Bottom of casing window: 10575 feet MD (8715' SSTVD) (5) An RA tag is located at 10577' MD (8717' SSTVD). (6) An open hole sidetrack was made at 10930 feet MD (8776 SSTVD) for Ll-15A. (7) The interval from 11212 to 11243 feet MD (8754 - 8755 TVD) was not logged due to sensor-bit offset at TD. CURVE SHIFT DATA BASELINE, MEASURED, 10550.4, 10549.4, 10560.8, 10559.8, 10567.0,10565.7, 10575.1, 10574.9, 10580.6, 10579.1, 10589.2, 10588.5, 10593.4, 10592.7, 10613.6, 10612.7, 10628.3, 10626.8, 10637.7, 10638.7, 10650.0, 10648.6, 10653.7, 10651.8, 10665.8, 10664.6, 10675.6, 10674.6, 10690.7, 10689.4, 10697.1, 10695.4, 10710.2, 10707.9, 10727.2, 10725.0, 10770.3, 10767.6, 10779.7, 10777.0, 10804.1, 10801.2, 10820.8, 10817.3, 10828.7, 10824.5, 10847.7, 10844.5, 10863.0, 10860.0, 10881.0, 10878.6, 10887.1, 10883.6, 10891.0, 10888.3, 10899.4, 10896.5, 10911.2, 10909.9, 10930.0, 10929.6, 11201.0, 11200.5, END Tape Subfile: 1 Minimum record length: DISPLACEMENT -0.988281 -0.987305 -1.23438 -0.246094 -1.48145 -0.740234 -0.741211 -0.987305 -1. 48145 0.987305 -1.48145 -1.97559 -1.23438 -0.988281 -1. 23438 -1. 72852 -2.22266 -2.22266 -2.71582 -2.71582 -2.96289 -3.45703 -4.19727 -3.20996 -2.96289 -2.46973 -3.45605 -2.7168 -2.96289 -1. 23438 -0.494141 -0.5 121 records... 10 bytes Maximum record length4IIÞ 132 bytes . **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT Ll-15APBlfinal.xtf 150 BP Exploration (Alaska) Inc. Ll-15APBl Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by Reeves, 14-0ct-03 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX05 0.0 ROP ROP ROPA05 0.0 RACH RACH RACHX05 0.0 RACL RACL RACLX05 0.0 RPCH RPCH RPCHX05 0.0 RPCL RPCL RPCLX05 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RACH MWD 68 1 ohrnm 4 4 4 RACL MWD 68 1 ohrnm 4 4 5 RPCH MWD 68 1 ohrnm 4 4 6 RPCL MWD 68 1 ohrnm 4 4 ------- 24 Total Data Reco4llÞ: 39 . Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10542.000000 11243.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT LI-15APBlfinal.xtf 150 BP Exploration (Alaska) LI-15APBl Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!! !! !!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 RACH RACH RACHX 0.0 RACL RACL RACLX 0.0 RPCH RPCH RPCHX 0.0 RPCL RPCL RPCLX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: . . Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RACH MWD 68 1 ohrnm 4 4 4 RACL MWD 68 1 ohrnm 4 4 5 RPCH MWD 68 1 ohrnm 4 4 6 RPCL MWD 68 1 ohrnm 4 4 ------- 24 Total Data Records: 39 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10542.000000 11243.000000 0.500000 teet **** FILE TRAILER **** Tape Subtile: 3 52 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/11/11 543243 01 **** REEL TRAILER **** MWD 03/11/11 BHI 01 Tape Subtile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Data Listing 111'11111111111111""""""""",.",1""" . . . . . . ...... .. .. ... ................... . . ..... . . ..... . . Tape Subfile 2 is type: LIS DEPTH GR ROP RACH RACL RPCH RPCL 10542.0000 100.7540 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10542.5000 101.9098 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10550.0000 140.3801 -999.2500 6064.5430 1426.7234 48895.1953 35674.1797 10600.0000 25.1542 44.7835 93.9647 2203.5962 78.7728 90.6954 10650.0000 25.0193 17.6640 6144.2070 2179.3960 173.6031 39979.6250 10700.0000 17.7805 22.0114 60.6546 33.1799 117.4793 94.6904 10750.0000 28.8140 66.0131 6064.4043 2179.3960 213.0156 492.7747 10800.0000 39.9353 54.9724 6064.5430 2179.3960 184.3169 298.9375 10850.0000 34.2923 81. 2169 6064.5430 2179.3960 202.5878 289.0109 10900.0000 36.7953 22.7620 6064.5430 2179.3960 108.5467 183.0615 10950.0000 37.5751 23.6534 6064.5430 2179.3960 122.8800 166.3270 11000.0000 27.8436 16.4005 3886.1230 2179.3960 34.9469 45.4178 11050.0000 38.6467 15.0675 499.8303 2179.3960 29.2035 38.1517 11100.0000 56.7988 29.9193 40.1115 2179.3960 15.7403 21.3506 11150.0000 93.9286 53.4427 6064.5430 2179.3960 67.1112 98.5866 11200.0000 80.6825 107.2338 6064.5430 2179.3960 79.5270 100.4425 11243.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 10542.000000 Tape File End Depth 11243.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet . . Tape Subfile 3 is type: LIS DEPTH GR ROP RACH RACL RPCH RPCL 10542.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10542.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10550.0000 161.1069 -999.2500 6060.1768 1033.2388 25168.3789 18356.1562 10600.0000 24.7138 44.8887 83.7151 2175.6167 72.7637 77.7534 10650.0000 18.9861 13.3052 3077.5024 2222.9009 81. 6031 13214.3301 10700.0000 18.3266 25.1101 59.0644 15.3246 92.2294 49.7257 10750.0000 29.5776 66.4173 4675.1797 2179.3960 227.0927 301.7648 10800.0000 35.6932 46.1919 6108.8135 2179.3960 251.1372 649.5388 10850.0000 37.2246 85.3196 6064.5430 2179.3960 215.5271 382.1602 10900.0000 39.8513 29.5187 6064.5430 2179.3960 119.6684 209.3479 10950.0000 40.5636 22.7273 6064.5430 2179.3960 130.7235 170.7751 11000.0000 24.2053 16.1762 2256.8540 2179.3960 27.8477 37.1708 11050.0000 38.1172 16.6456 496.4922 2179.3960 29.0742 38.8872 11100.0000 55.7733 28.0392 35.1324 2179.3960 13.6844 18.6539 11150.0000 91. 9221 51.2217 6064.5430 2179.3960 79.0774 109.2967 11200.0000 81.1526 94.9062 6064.5430 2179.3960 77.9483 101.2377 11243.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 10542.000000 Tape File End Depth 11243.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet . Tape Subfile 4 is type: LIS .