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196-170
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Color items - Pages: ~ ~ GraYScale, halftones, pictures, graphs, charts - [] Poor Quality Original'- Pages: n Other - Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED .Logs of various kinds Other Complete COMMENT~: E] Scanned b~~ MildredlD;relha TO RE-SCAN Notes: Nathan Lowell , O-',_C::r-car~n~ri hr' r:u,v~_riv Mikired Daretha Nathan Lowell Date: /s/ 4,1 \\�I/7,7` 11-1E, S I ArLE i, i a c `e mss/£:1 ,�c C'i G li 9 --'7_,7_:_:_--14-_-_1-.1 / - V Nj_L % t == 333 West Seventh Avenue -'11. -:7- 7-,,------, GOVERNOR SEAN I�AkNI:LL Anchorage, Alaska 99501-3572 <_w't,`` Main. 907 279 1433 F �` Fc x 90'.276.75/2 N�EpMg07ZVI' Ken Allen SLA (J 7 Engineering Team Leaderr BP Exploration (Alaska), Inc. (0...- p \:>---------°. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-29A Sundry Number: 314-181 Dear Mr. Allen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 11°7L4- -- Cathy ` - --Cathy P. Foerster Chair DATED this day of April, 2014. Encl. STATE OF ALASKA 4 , > # . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL orsail sl44,- 20 AAC 25.280 ' . $,, 1. Type of Request: ❑Abandon IS Plug for Redrill i 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic , 196-170 3. Address: 6 API Number: ®Development 0 Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-21472-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? \ PBU C-29A Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatio , , \ • 10.Field/Pool(s): , ADL 028305,028309&028310 Prudhoe Bay Field/Prudhoe Bay Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 13660' 8983' • 13598' 8983' None 13414', 13428', 13429' Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20"x 30" 110' 110' Surface 3085' 13-3/8" 31'-3085' 31'-2771' 4930 2670 Intermediate 10945' 9-5/8" 29'- 10945' 29'-8405' 6870 4760 Production Liner 909' 7" 10580'-11489' 8142'-8780' 7240 5410 Liner 3085' 2-7/8" 10575'-13660' 8139'-8983' 13450 13890 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11575'-13440' 8832'-8988' 4-1/2", 12.6# 13Cr80/L-80 10614' Packers and SSSV Type: 9-5/8"x 4-1/2"Baker S-3 Packer; Packers and SSSV 10380'/7990' 9-5/8"x 4-1/2"TIW HBBP Packer MD(ft)and ND(ft): 10507'/8087' 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal IS BOP Sketch ❑Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: March 25,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG _� Suspended • 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Troy Tempel,564-5698 Printed Name: Ken Allen Title: Engineering Team Leader Email: Troy.Tempel@bp.com Signature: / C::-------, Phone: 564-4366 Date: 3/4.0/ //4 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\Lk \5 ❑Plug Integrity`LTJ BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: 5 0 P c5...II_ 1-0 3 5---O C- )<5 r . f ', .r:= `l 7 2014 Spacing Exception Required? 0 Yes I"No Subsequent Form Required: /0 , 4_0- APPROVED BY Approved By: / - COMMISSIONER THE COMMISSION Date: ¢.-� 7 �— Form 10-403 Revise 10/20 A• t&Gild�Adr 12 months from the date of approval Submit In puplicate VL 4/67'11 �/S, i( 3.z-e7'>/,1 • 0 bp in" GP * . : 1. ^ i Well Name: C-29A Well Type: Producer Current Status: Oil Producer Shut-In Request: P&A—Well Prep for Rotary Sidetrack MIT-IA Passed to 3500 psi (02/16/2014) MIT-OA Passed to 2000 psi (02/17/2014) PPPOT-T Passed to 2000 psi(02/21/2014) PPPOT-IC Passed to 3500 psi (02/21/2014) Well History: C-29A was coil side-tracked in December 1996 to Zone 1B with 590' of perforations. The initial rates were high for Zone 1B and the GOR unexpectedly reached max GOR within 3 months. The well began cycling. Suspecting gas entry at the liner top, an attempt was made to set a RCP liner top packer in May 1997 but the packer would not seal. Several attempts have been made to pull the RCP liner top packer but all failed.Although the packer was pulled from the 2-7/8" liner, it is stuck at 10554' MD. An IBP was set at 13318' to isolate the last set of perforations in June 1997. A STP/PITS was run on 06/13/1997 and confirmed channelling behind pipe. Although the IBP was holding, the two bottommost zones were believed to be in communication. A SCMT was run on 06/30/1997 and indicated good cement below 12650' and poor-to-fair cement from TOC at 11348' to 12650'. The IBP was pulled and reset at 13030' in July 1997. The gas rate decreased slightly but the well continued to cycle poorly. A MCNL was run in August 2004 and identified Z2C and Z2B oil lenses. A GSO IBP was set to isolate all current production and 20' of the Z2B lens was perfed in June 2005. Unfortunately, the well wouldn't flow. 18' of Z2C was shot in August 2005 and flowed competitively for about a year before being shut-in for TxIA communication. A RWO was completed in June 2008 in which Doyon 14 attempted to pull the stuck RCP liner top packer but was unsuccessful. The 4-1/2" completion was changed out with a 4-1/2" chrome stacker- packer from 10485' MD to surface. Once POP'ed the well quickly went to cycle, but no longer heals . and was shut-in for high GOR. I'i Reason for P&A/RST: Due to the stuck RCP liner top packer, in-zone CTD side-tracking options are limited. Retrieving the packer has proven unsuccessful on multiple occasions. The well is currently / ' uncompetitive and a rotary side-track is the last remaining option. Variance Request: As per 20 AAC 25.112. Well Plugging Requirements, Section (c) states that, "Plugging of cased portions of a wellbore must be performed in a manner that ensures that all !, hydrocarbons and freshwater are confined to their respective indigenous strata and are prevented from migrating into other strata or to the surface". A variance is requested for perforated interval plugging methods (1) listed in (A), (B), (C), (D), and (E). The proposed P&A plan will meet 20 AAC 25.112. requirements by the following method: 6� Mt we P/bdvCef �r Off�D1�%opt 0194 q J-0," 1717# • ' ,\ I (Noir. 4 PQ°` 4 �9e� ire w '(( ex4•4.rs /•'tfle , o f rile m 6 "°' J T s c ovIot a// �D/ q,( eliy -ei cicr lbw,* r#4 we fcY /*/ L-298 sundry Applicatio 1 ocf- 18 Mar 2014 v a. Competent 9-5/8" annular cement from 10945' MD to 9126' MD (8405' TVD - 7050' TVD). This provides the Sag River/Ivishak with 9-5/8" annular isolation from the Sagavanirktok. b. Setting a 4-1/2"tubing plug at 10405' MD (8010'TVD). c. Laying a balanced cement plug which provides 9-5/8"x4-1/2" annular isolation from 10380' MD to 9320' MD (7790' TVD - 7190' TVD) and 4-1/2" tubing isolation from 10405' MD to 9320' MD (8010'TVD-7190'TVD)for the Sag River/Ivishak. Pro osed Pre-rig prep work: --- -- -� S« a 1-1 Ac h e*d S1-717-01 � Set a downhole plug at 405' MD -fit,,,,,p 1.c v Fc Y n Remove lower dummy GLM at 10255' RAn fob-11,u0 5tCLGy,c cewtc.4t jab . Perform through-tubing P&A by pun, „ ,cu"/0 excess) cement down the 4-1/2" tubing as a balanced plug. Planned TOC is 9942' MD. 4. Pressure test tubing and IA to 3500 psi 5. Drift and tag TOC with E-line 6. Perform E-line jet cut on 4-1/2"tubing at-4300' MD 7. Secure well with a TWC and perform CMIT on TxIA to 3500 psi. Planned Rig Work: 1. MIRU Parker 273 2. Test TWC from below to 3500 psi for 5 minutes 3. Nipple down three and adaptor flange 4. Nipple up spacer spool and BOP (configured from top to bottom: annular preventer, 2-7/8" x 5-1/2"VBR, blind/shear, mud cross, 2-7/8"x 5-1/2"VBR). 5. Pressure test BOP to 250 psi low / 3500 psi high with 4" and 4-1/2" test joint. Give the AOGCC 24 hour notice before testing. 6. Rig up and test DSM lubricator. Pull TWC. 7. Rig up hardline to BOP. Circulate out diesel freeze protect through choke to tiger tank with seawater. 8. Rig up and pull 4-1/2", 12.6#, 13CR-80 tubing from 4300' MD to surface (tubing cut made pre- rig). a. If tubing comes out clean, RIH with junk basket/gauge ring to the top pf the tubing stub. Ensure gauge ring OD is equal to or greater then whipstock drift. b. If tubing comes out dirty, RIH with 9-5/8" clean-out assembly down to the top of L q& -I F 1D tubing stub. � y_ 9. Rig up E-line with GR/CCL log and set the 9-5/8 EZSV at -4066' MD. Pressure test to 3500 p11.69 psi for 30 minutes. Chart test. reed r'6I 10. Pick up 9-5/8" whipstock, bottom trip anchor, and 8-1/2" window milling assembly (to include Itfull gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. 11. Swap well over to 9.4 ppg LSND milling fluid. 12. Change the 9-5/8"packoff. Pressure test to 3500 psi. 13. Mill window in the 9-5/8"casing plus 20'of formation. Swap well over to 9.4 ppg LSND drilling fluid. Perform LOT. 14. POOH and laydown milling assembly. v 15. Pick-up BHA#1 to include 8-1/2"bit, RSS, GR/RES/PWD. RIH a. Note: Bent housing motor for contingency if RSS trial does not occur. h C tN 16. Kick-off whipstock with RSS and drill ahead to section TD in TSAG at -11816' MD. Use the 1�T following mud weights while drilling the intermediate section: a. KOP-4350'TVDss(UG4): 9.4-9.8 ppg 6 4_U 4 / b. 4350'TDVss(UG4)-6020'TVDss(CM3): 9.8- 10.0 ppg c. 6020'TVDss(CM3)-8367'TVDss(TSAG): 10.4- 10.5 ppg 17. At TSAG CBU until hole is clean (minimum 2x) and POOH on elevators to the ghost reamer depth. 18. RBIH to TD, CBU until hole is clean and POOH on elevators. 19. Change upper 2-7/8"x 5-1/2"VBRs to 7"casing rams and test with 7"test joint to 250 psi low /3500 psi high. 20. Pick up 7", 26#, L-80, VTHC liner, liner hanger, and liner top packer and RIH on liner running tool down to-11816' MD. C-29B Sundry Application 2 18 March 2014 21. Cement 7: liner with -56 BBLS 15.8 ppg Class G cement (40% excess) and displace with mud. Planned TOC is 10318' MD (1300' TVD above DPZ 3). Reciprocate liner during cement job. Bump plug and ensure the floats hold. 22. Set the liner hanger and energize the liner top packer per the liner running tool procedure. CBU lx to ensure no channel cement is left in hole. POOH and laydown the liner running tool. 23. Change 7" casing rams to 2-7/8" x 5-1/2" VBR. Pressure test to 250 psi low/ 3500 psi high with 4-1/2"and 2-7/8"test joints. 24. Pressure test liner to 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high after cement reaches 500 psi compressive strength. 25. Pick up BHA#2 to include 6-1/8" bit, Archer RSS, GR/RES/NEU/DEN/PWD and RIH to PBTD a. Goal is a single BHA run to TD. 26. Rig up E-line and run Gyro through drill pipe to clear up Inc+Trend survey codes. 27. Drill out the shoe track and swap mud to 8.5-8.6 ppg Power-Pro. Perform negative pressure test on the 7" liner lap by monitoring well for no flow for 30 minutes. 28. Drill out 20'of new formation and perform FIT. 29. Drill ahead to section TD at 15746' MD. Geo-steer as required by well-site geologist. 30. CBU until hole is clean, trip out of hole from TD on elevators to 7" shoe and CBU ensuring hole is clean. 31. RIH to TD on elevators. Circulate hole clean. POOH on elevators to 7" shoe. CBU and continue POOH to surface. Laydown BHA and prepare to run 4-1/2" liner. 32. Pick up 4-1/2", 12.6#, VT, 13-CR liner, liner hanger, and liner top packer and RIH on liner running tool down to 15746' MD. 33. Cement 4-1/2" liner with -68 BBLS of 15.8 ppg Class G cement and displace with 8.5 ppg perf pill and used Power-Pro drilling fluid.Planned TOC is at 11818' MD. Reciprocate liner during cement job. Bump plug and ensure floats hold. 34. Set the liner hanger and energize the liner top packer per the liner running tool procedure. 35. Pull liner running tool above liner top and displace well to 8.4-8.5 ppg seawater. 36. POOH, laydown the liner running tool, and prepare to run perforating guns. 37. Pressure test liner to 250 psi low / 3500 psi high for 5 minutes low / 30 minutes high after cement reaches 500 psi compressive strength. 38. RIH with perforating assembly and perforate the well per procedure after cement rwaches 1000 psi compressive strength. CBU and POOH. Laydown guns and verify all shots have fired. Prepare to run 4-1/2"tubing. 39. Rig up and run the 4-1/2", 12.6#, VT, 13-CR completion tubing and stab into the 7" x 4-1/2" liner top packer. Land tubing and run in lock-down screws. 40. Reverse circulate clean seawater followed by corrosion inhibited seawater. 41. Drop ball and rod to the RHC-M plug in the XN nipple at the tubing tail. 42. Set the production packer and pressure test to 250 psi low/3500 psi high to 5 minutes low/ 30 minutes high. Chart each test. 43. Bleed tubing pressure to 2000 psi. Pressure test the IA to 250 psi low/ 3500 psi high for 5 minutes low/30 minutes high. Chart each test. 44. Hold pressure on the IA and bleed tubing pressure to zero, shearing the DCK shear valve. Pump both ways to confirm circulation ability. 45. With landing joint still rigged up, reverse circulate diesel freeze protect using rig injection pump. 46. Allow diesel to U-tube, drain stack, and rig down landing joint. Monitor well for 1 hour to confirm well is dead. 47. Install a TWC with dry rod. Test from below at 250 psi low/3500 psi high. Test from above at 250 psi low/3500 psi high. 48. Nipple down BOPE. Nipple up adaptor flange and double master valves and test to 250 psi low/5000 psi high for 5 minutes low/5 minutes high. Test with diesel. a. Ensure Heet is left on TWC and only diesel (no water) is left in tree. 49. Install all annuls valves and secure the well. Ensure T/IA/OA all have two barriers in place. 50. Secure the well. RDMO. Drilling Engineer: Troy Tempel (907)570-1351 Production Engineer: Noelle McBride (907)564-4619 Geologist: John Boyd (907)564-5384 C-29B Sundry Application 3 18 March 2014 1 1RBE_ (701 IACTUATAR= RNC C-29A TO U�,�'PPIS 10544'117 ACTUATOR= BAKER C OKB.BEV= 67.65' (SEVERAL ATTEMPTS).PKR NOT FULLY SET WI BF A.EV= 38.77 i 20.ri1Nr1 H 110' 1.1 I SHORT TRAVEL LIP&DOWN(TOTAL.LENGTH=5.06). KOP= 850' Max A rglt= 99°/t 13380 Datum M)= 11643' I I I 2117 /14-17 HES X NP,D=3.813' DbmND= 8600'SS GAS LFT KAMS sr AD ND DEV TYPE VLV LATCH PORT DATE I 13-3/8'CSG,724,L-80,13=12 347" 3086' 4 3615 3159 43 MdG DMP RK 0 02/16/14 3 6169 5005 47 11.03 DMP 18( 0 02/16114 2 8346 6496 47 MNG DMP 18< 0 06/04/06 1 10255 7893 38 M&3. DMP RK 0 06/04106 Minimum ID=2.350"(a 10525'7 I I ( 10399' H14-12'HES X NP,D=3.813'( 4-112"HES RCP PACKER 1X — tom -H95I8-X4-12'8KRS-3F702,81=3.870- I I 10408' H4-12'HES XNP,0=3.813' r r4-112'1116,12-19,13C11-1111V AN TOP, H 10464' ` 141��� 4-1/2 HES XN NP,D=3 725•j 0152 bpf,D=3.9519 — 10492' H R TNN EE SEAL ASSY ( 4-10"TBC STIR(05/»,08) H 10485' I 1 104sr H 4-12'TN11 SEAL OVERSHOT w/OUT SEALS ( I 1060T I---l9-5/8'X 4-117119 FBBP PKR D.4.750' J r 1061 Z' _1 f'mumur DT619oN:p is-OF-1 �.- 105177-1-1-7:74- 2'XO,D=3998 d tg1 10644' 1-{4.12'X 2-7/6'FES RCP PKR A=2.50' 1 I I I.. 10G4T HA t/r rn10 X r4R D-'3,01-31 Itop(4 Z-7r8'LM$ -! 10576' 1 H L 10578....,]-(31/4 BKRDER OY SLV D=3000..., ( ideal -1--F-11/2"OTIS XN PP.D 3 80(1A LET)02/08!98)1 I TOP CF r lNR 10699' j 10530' I-J9 sir x r BOT LNR HGR w/T®K SLV,D.7 4.1/2'TBG,1291,L-50 B1RS, 10914 10681* -12-741'LNt XO D=2.441' .0152 bpf,D=s.aoo- ��\/ x 10614' H4-12"NM1.E6,13=3.958-I 19-541-CSG.470,L-80,D-8.881'1- 10146' 1 A di I 1/9177 H Fi 411 TT I On XX/XX/XX", 1 rwics-rOCK(12108/96) -1 11488' 10975' I-IrMARKER JT RA TAG 11498' 11390' TOP CIF CBNBJf 06/3097 1 ref ef. / o ,,,,...n VrnwVV( -4anf 11489'-11498'1 11111 •1111 PBIFOW1110NSt1NAMRY 4411( 4; REF(.OG' b.,r4114.1Latot 1111//V!f 4...3. 411k,ANGLE ATTOP PEFF: 42°.•11575 aa'`a, Pbka P for b Production DB for historical per/data V0104+44404.4 , 13414' FISH 2-18-81CR BP / SIZE SPF I MHZVAL OprVSgz DATE SClZ 01411401 y 11111111 (11/26/12) N/444N* 1-11/16"r 6 111575-11580 0 05/14/10 114411441141414 ` 113421rem FISH-BKR BP 1-11/16'r 6 111594-11612 0 08/02/05 111111111111111 (11/29/00) 1-9/16'r 6 111910-17930 0 0628105 111111111111111 2-18' r 4 112680-12990 0 12/19/98 11144111114441 / 13429 ctrn�/LSH-BKR lip 2 111" I' 4 13070-13280 0 12/19/96 1111111114111111 //111.4 (07130197) 4.4.4.1.4.4.4.1: 4444' 1, 2118" E 4 13370-13440 0 12/19/96 I P070 --113598 ( 4 / i 1 7-LNR,298,L-80 BTRS,.0371 bpf,D=6.184' H 12020' r 12-7/8'LNR,8.164,L-6U,.Was bpi,U=L141'J-I 13660' I CATE. REV BY OOA*6341S OW1E 17FV BY COMBOS pRDH LDE BAY IM 02114(861, NUE ORIGINAL COMPLETION 05118110 JETYSV ADO PERF(05/14/10) WELL C-29A 06/20!861 0122E FIG WORIWVER 11/30112 JJUJM) PUSH 13PTO FBTD(1126/12) PBN&T b'1961700 /2120/961 NOR1 CTD SIDETRACK(C-2!A) 01/15113 0091) BP&FISH TIONS AR Ib 50-029-21472-01 06/09/08, 1314 1890 02/18/14 EISHJM)GLV C/O(02116/14) Ski;19,111N,R14E,1901'FN.&884'Hi 06/26/08 1DAV/PJC GLV d0(06/14/08) 11/13/08 HMSO DRLG CRAFTS BP EXploraUon(Alaska) C-29B Sundry Application 4 18 March 2014 SUPERSEDED 1 TREE= CMV Yre-LlEAD= PVC PROPOSED P&A C-29ASAFETYNOTES:WELL ANGLE>70°ifp11T20". ACTUATOR= BAKER C "'UNABLE TO PULL 4-112"RCP PKR @ 10544' OKB B.EV• 67.65' (SEVERAL ATTEMPTS).PKR NOT FULLY SET WI BF.ELEV= 38.72' ■ "� SHORT TRAVEL LW&DOWN(TOTAL LENGTH•6.06"). IOP= 850' --- — ---- 20'COND 110' Max Angle= 99°@ 13380' 2112' H4-1 ItFs X NP,D=3.813' Datum MD= 11643' 7.01 Datum IVO= 8800'SS ST MD IV D DEV TYPE VLV LATCH PORT DATE 13-0/8'CSG 721.1-80,D=12.34r H 3085 r 4 Ail 3 6169 6) 005 47 164G Y RK 0 02/16/14 4-112'JET CUT TBG(_._./�1_..)i 430D 2 6346 6496 47 WC DMY RK 0 06/04/08 1 i 912v ,4 1 10255 7893 38 AMG -EluP1Y- 740'1VDabove 1: Packer 14�'�*r+�i..i...i., G.IrcAP(JJ_1 8320' X47♦�• ��.� 500'TVD above ��•4►�►4lw 10359' 4-Vr mg X tip.D=3-813' ���(.....• 4":4 t packer Minimum ID=2 350" 10525' 40 ., 10380' 9-98"X4-1/2"BKR S-3A(R,D=3.870' : �• 4,1" .w 10405 4-1/2"HES X NP,D•3.813"I 4-112"HES RCP PACKER * 1040s' _{4-11r_PLUG(_/_/_)1 4-112"1BG,1260,13CR40 VAM TOP, 10484' * � 10464• H4.112"HES XN NP,D"3.725 .0152 bpi,ID=3 958" 1 4 • 10492' TM PBR SEAL ASSY :4 10499' 41/rTIWSEAL OVERSHOT w/OUT SEALS I 4-1/2'TBG STAB(0522/08) 10485` 41 ,'_� „� 10507' I-9-5r8"X4-1/2"TWFBBPPxRD=4.750" I ,re- : 10512' F-r I4LOI I ExTENSDNL D=6.00" I 44 10517" rX41?XO,D=3.968' pERsE�ED r �• • N. 10544' 4-1/2"X 2-7/8"FES RCP FKR D=2.3 It: it 10647' 4-10 OTC X M3,D•3.1112"] i 10575 --13-314"OKR DEFL0Y SIV,D•3 000' I� TOP OF 2-718'Iti3 10575 .��.��. �� ' •RiR. 10880' 4.1/2"01$XNNP,D=380(1418002108/96) I ' it 04 4i TOP OF LTC 10580' 10580' 9.518"X r BOT LN ® D RHGRw/TK SLV, =- I• 10581' F-I2-7/8"LNR XO PN,D=2A41' 4-112'TBG,12.60,L-80 MRS, 10614' • 0152bpi,0-3.958" I I0' 10814' 4-1rrwLeG,D=3-958°) 19.5(8"CSG.470,1-80.D=8.681'H 10945 ` -• 1 lour I—ELMO TT LOG xxlxxnrxv I Y 7• VHrstocx(12108/96) 11458' I 10975 Hr/ARCM a I IRA TAG 1149W 11350" HTOP0f CENANT 06/30197 I 1411 X4414 7"SOB7RACKVVK/CNI(C-sire 1489'-11498' PERFORATION SLM'ARY 14111 4, REF LVIi: JJ 0/0114.1UK On 1111//*JO 4.,,• 4111*NG ALE AT TOP PERF 42°is 11575 '`t, ` Note:War to Production DB for historical pert data r4/1111•11111 , 13414' FISH•2-1/8'BKR BP SIZE SPF INTERVAL Op/Sqz DATE SOZ 4044•444444444414` (11/28/12) 1-11/16"l' 11111111•6 11575-11580 0 05/14/10 444444// 1342rdm FISH-BKRBP 111111141 1-11/16"' 6 11594-11812 0 08/02/05 •111/11/11111/ ` / (11/29/00) 1.9/16" ' 6 11910-11930 0 06/28105 14111♦N 11/1/111 2-1/8" ' 4 12680-12990 O 12/19/96 44401414. 13429 CUII-FISH-BKR BP 2-1/8" ' 4 13070.13280 0 12/19/96 •11//1111111/111 i441�,1. (0713097) 1.4.4.1.1.4.4.1. I 41111. 2-118" ' 4 13370-13440 0 12/19/96 FWD 13598' 4 I r LNR 290,1-60 B1PS,.0371 bpt,D=6.184" H 12020' 12-7/8"LNR 6.160,1-110-0058 bpt,D=2.441" 13680'. DATE REV BY CONBENTS DATE REV BY COINENTS PRUCHOE BAY UMT 02/14/86 1422E ORIGINAL COMPLETION WELL C-29A 04120/86 1422E RIGGWORKOVER FERMIT No- 1961700 12/20/96 WWI CTD SIDETRACK(C-29A) AR No 50-029-21472-01 06)04196 044 MO I SBC 19.Tt 1 N,R14E 1901'MIL&884'FEL 02/11/14 JUJM) Ti4U OSED MA BP 6cploralion(Alaska) si,...roct,Q SUPERSEDED C-29B Sundry Application 5 18 March 2014 ti waLlEAD= RiC PROPOSED 29 B SAFETY NOTES:WELL ANGLE>_°� ACTUATOR= BAKBiC C .7 '"PREYIOUSWELLBORE SHOWN ONPAGE _ �� 2"'CHROMETBGa LNR"' 0103 ELEV ' BF.BLV= 38.7r 20'COPD 110 KOP v 850 Ali Angle= _®—' Datum TVD= 8800'SS I - I - ' I-j4-1/2'HES XHP,I)=3.813'1 I 13-3/8'CSG.721.1-80 ETC.D=12.34r H 3085' 1 Lr X -3900' 9-Sir x Rut « D= - 19.618'WHPSTOCK i_fm1_.._J 4088' 6 • - 9-518'CSG.470,1-80,D=8.681" f { - • a-818'SsIEfrtAc rc*MAN/IC-2981 --- . GAS UFT MANDRELS ST M) TVD DEV TYPE VLV LATCH PORT DATE Minimum 1D. "@ 3 2 1 TOC @ 10,318'N® 41/2'FIS X NP,D=3.813• ,� •' 11518 7x4-1/r HES TNT not.D= 3.870" ` ' -.14.1/2"HES Xt '.D=3.813' M ' k 141!7,"HES XN NP,O-3.7:6' 4-1R'TBG,12.61,VIM TOP I3-CR. - ' .0152 bpi,13=3.958" It -14-1/2'WLEG,C=3.958'1 TOP OP4-1/Y LNR -11668' • i?,' -11668' rX4.1/2" PKRw/ LNR IUT(U= . • I r LNR 268,VTHC L-8o, 0383bpf,0=6.276' H -11818' 1 PERFORATION SUMMARY ' REF LOG: on_l i_ ANGLE AT TOP FEN' _ 0 • / Nota.Rear to Production OB to historical parf data `..., SIZE SPF NTERVAL C nlSqz DATE SOZ tr Ili 4 PBTD F 4 ,Fl • 4-1/?LP1.12.88,VAM TOP 13-CR, -1 18848' J ' .0152 bpf,O-3.958" DATE PE/BY COAKENTB DAR riGV BY 036MENTS PRUDHOE BAY UNIT 02114/86 N22E ORIGINAL COMPLETION 019 L.C-295 04/20188 N22E RIG WORKOVBR PERMIT No: 12120196 NOR 1 CU)SIDETRACK(C-29A) AR No.50-029-21472-02 08106108 014 RWO SEC 19.Ti IN R14E,1901'RTL&884'FEL 03/05/14 .N+D SUET PROPOSED 03/11/14 JUJMO CORRECTION TO PKRRHGR BP Ecploratlon(Alaska) C-29B Sundry Application 6 18 March 2014 r PARKER 273 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LSI DOUBLE BOP 13 5/8"-5M fl 13 5/8"-5M STUDDED TOP 13 5/B"—SM FLANGED BOTTOM i, w/(2) '4" JL2 OPERATOR, UPPER CAVITY ,:i . ° ANNULAR BOP: AND(2) 14' MK W/BSTR OPERATOR, i7 nT nTeT 3-5/ 1 R LXT 13 5/8"—SM LOWER CAVITY 13-5/8" SM STUDDED TOP 0 13-5/8"SM FLANGED BOTTOM o i 1 ORLUNG CROSS: 13 5/8"-51,1 FLANGED TOP I■ommo t✓ ■ G 13 5/8"—SM FLANGED BOTTOM E 4•6�.C2 . Si 1.1 W(2)3 I/8"—SM SIDE OUTLETS \o/ 1EMME ' E 9 1011 DI ------------- — 1 1 1 KLL UNE t ati/Ii!l 4, --�CY , a< +•Ii'iy•t� �' I 2-1/16"5M FLEX HOSE • u lVN5J1~2-1/t6"SM x 3-1/8' SM D.S.A. "'II "■y �� 40� , 3-1/8" 5M FLANGED MANUAL GATE VALVE C:: 3-1/8' 5M FLANGED HYDRAULIC GATE VALVE E� _ 1 1 CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL CATE VALVE SHAFFER LXT SINGLE 13 5/8" EM 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP SM FLEX HOSE 13 5/8"— EM FLANGED BOTTOM 3-1/8" 11/(2)14"UL2 OPERATOR I I C-29B Sundry Application 7 18 March 2014 TREE= " CNV WELLHEAD= FMC PROPOSE.. C-2 9A SAFES . .,OTES: WELL ANGLE>70°@ 11720". ACTUATOR= BAKER C UNABLE TO PULL 4-1/2"RCP PKR a©D 10544' OKB.ELEV= 67.65' (SEVERAL ATTEMPTS).PKR NOT FULLY SET W/ BF.ELEV= 38.72' 20"GOND 110' J I SHORT TRAVEL UP&DOWN(TOTAL LENGTH=6.06'). KOP= 850' Max Angle= 99°@ 13380' Datum NO= 11643' 2112' -I4-1/2"HES X NP,D=3.813" Datum TVD= 8800'SS ST MD H I, DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80,D=12.347" -1 3085' in 4 3615 3159 43 MMG DMY RK 0 02/16/14 3 6169 5005 47 MMG DMY RK 0 02/16/14 4-1/2"JLI GUI I BG(_/_/_) -I 4300' 2 8346 6496 47 MMG DMY RK 0 06/04/08 J TOC I l 9126' • P.' 1 10255 7893 38 MMG -EMPTY- 740'TVD above Packer 4. ♦ 1F * ►1• ) 9320' 600'TVD above ,'�* f *r 10359' 4-1/2"HES X NP,D=3.813" packer ., 4101#114.4,11' Nrdh. nil o�= ,=' •40 10380' H9-5/8"X 4-1/2"BKR S-3 PKR,13=3.870" Minimum ID = 2.350 @ 10525' ' $.40:...4 Alb. WAVA 10405' 4-1/2"HESXNP,D=3.813" 4-1/2" HES RCP PACKER + �:. ►`+ �Top offirst plug '► „', : 4-1/2"TBG,12.6#, 13CR-80 VAM TOP, J 10484' NM, I 10464'J-14-1/2"HES XN NP,D=3.725" Well .0152 bpf, D=3.958' �� 10: 5�� 10492' --11TH PB R SEAL AS--Sl WWI 1 iii •. 10499' -14-1/2"TIW SEAL OVERSHOT RSHOT w/OUT SEALS 4-1/2"TBG STUB(05/22/08) -{ 10485' 4 'N.4 i. F . 10507' -19-5/8"X 4-1/2"TNV HBBP PKR,D=4.750" ��_ 'iii �.►1►� •��' 1 10512' Hr MLLOUT EXTENSION,D=6.00" ► • ii .' ♦, i iiiPli 10517' _--17"X 4-1/2"XO,D=3.958" Vii .� 10544' --14-1/2"X 2-7/8"HES RCP PKR,D=2.350" 4 ��• �■ 10547'I-14-1/2"OTIS X NP,D=3.813" [OP OF 2-7/8"LNR H 10575' ' 10575' H 3-3/4"BKR DEPLOY SLV, D=3.000" 4. ♦t IIIIP10580' H4-1/2"OTIS XN NP,D=3.80(MILLED 02/08/96) WO. IMMI MM M. OF 7"LNR J 40 ' 10580' a •4► 10580' -{9-5/8-X 7"BOT LNR HGR w/TIWK SLV,D=? 4 10581' -12-7/8"LNR XO PN,ID=2.441" 4-1/2"TBG,1:2.6#,L-80 BTRS, 10614' WAWA iiii 0152 bpf,D=3.958" 4 7 i„IMAI I*; 10614' -14-1/2"WLEG,D=3.958" �4 My 10622' --IE3MD Tr LOG XX/XX/XX? 9-5/8"CSG,47#,L-80,D=8.681" 10945' ILIAi IMO 10976' -17"MARKER JT F 7"WHPSTOCK(12/08/96) --1 11488' i1 rii 11350' H TOP OF CE]v1B'ff 06/30/97 RA TAG -1 11498' in • iia •• 111 r ••111• 7"SIDETRACK WINDOW(C-29A) 11489'-11498' PEF2FORATION SUMMARY 111 YF/ 4.4, REF LOG: SS MWD/GR of 12/17/96 11 ,'4.1�11t. ANGLE AT TOP PERF: 42°©11575' ,411111 . Note:Refer to Production DB for historical pert data 1114'.441111111'1, 13414' FISH-2-1/8"BKR BP 1111111 111 SIZE SPF INTERVAL Opn/Sqz DATE SQZ 1111111' 111 1111111 1(11/26/12) 111 1-11/16"P. 6 11575 11:180 0 05/14/10 11111116 1111 11111111 **ft 13428'ctm FISH-BKR BP 1-11/16"F 6 11594-11612 0 08/02/05 1111111111111 • 1111141'i (11/29/00) 1-9/16" " 6 11910-11930 0 06/28/05 11111111111111 1111it•.,• 11111111. ,t.+; , 2-1/8" r 4 12680-12990 0 12/19/96 1111111 1'v. 13429'ctm1(07/30/97) FISH-BKR BP 11111•.. • t . •*. 2-1/8" ' 4 13070-13280 0 12/19/96 1111111111111111 .♦1111�1�• 1.1.1.1.1.1..... •111' 2-1/8" ' 4 13370-13440 0 12/19/96 PBTD H 13598' 4.1kti 7"LNR 29#,L-80 BTRS,.0371 bpf,D=6.184" -1 12020' 2-7/8"LNR,6.16#,L-80,.0058 bpf,D=2.441"1-1 13660' DATE REV BY CONNBVTS DATE REV BY COMMENTS PRUDHOEBAY UNIT - 02/14/86 N22E ORIGINAL COMPLETION WELL: C-29A 04/20/86 N22E RIG WORKOVER PERMf No: 1961700 12/20/96 NOR 1 CTD SIDETRACK(C-29A) API No: 50-029-21472-01 06/06/08 D14 RWO SEC 19,T11N,R14E,1901'FAL&884'Fa 03/11/14 .11 LIMO PROPOSED P&A BP Exploration(Alaska) Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Friday,April 11, 2014 2:00 PM To: Tambe,Abhijeet Subject: RE: Sundries for MPH-13A(PTD#202-167)and C-29A (PTD# 196-170) Abhijeet, For C-29A can a mechanical bridge plug be set above t top perforation and cement placed on top as outlined in 20 AAC 25.112(c)(1)(E)? Cy-S " Victoria 0vt�e y1 two Victoria Ferguson t BOJ Senior Petroleum Engineer State of Alaskayp Oil&Gas Conservation Commission P d 333 W.7th Ave, Ste 100 A Iii 4 1 Anchorage,AK 99501 li &Zit/ 17 '-( Work: (907)793-1247 " e victoria.ferqusonalaska.qov From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Friday, April 11, 2014 11:16 AM To: Ferguson, Victoria L(DOA) Cc: Tambe,Abhijeet Subject: Sundries for MPH-13A(PTD #202-167)and C-29A(PTD# 196-170 Good morning Victoria, I was hoping that you could give me a status on the sundries for MPH-13A and C-29A. If you have questions or require any additional information please let me know. Thank you, Joe Lastufka Alaska Wells Technologist Cell: (907) 227-84961 Office: (907) 564-4091 w 4.:111111i llif BP Exploration AlaskaI900 E.Benson Blvd.IRoom: 788DIAnchorage,AK 1 Ferguson, Victoria L (DOA) From: Tempel,Troy <Troy.Tempel@bp.com> Sent Thursday,April 17, 2014 1:02 PM To: Ferguson,Victoria L(DOA) Cc: Tambe,Abhijeet;Joseph.Lastufka@bp.com;Josh.Allely@bp.com Subject: C-29A P&A Plan Attachments: C-29A Proposed PandA.pdf (4/ pifr A p v'0 G G v Victoria, Thank you for the discussion on the plug and abandonment plan for C-29A.After reviewing our equipment availability and the close proximity with rig scheduling, rather than set the CIBP we would like to place a cement plug from 13598' MD(8983'ND)up to 9320' MD(7190'ND).This will be done as a two stage cement job,the first will be a 3193' length plug from PBTD to the 10405' MD.The second will be 1085' length plug from 10405' MD to 9320' MD. Each stage will be pressure tested after setting up.This will conform to both the AOGCC and internal BP plug and abandonment requirements.Attached is a schematic of the proposed P&A. Given the tight timing with rig scheduling we would like to move forward with this C-29A P&A plan as soon as possible. Please let us know if this will work for you. 3113 Thanks again for your time, lG(612 Troy T. Tempel `6 Drilling Engineer BP Exploration,Alaska Mobile:907-570-1351 Home:406-207-0766 Troy.Tempel@bp.com • 1 RECEIVED STATE OF ALASKA � JAN 1 S 2013 . AKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate 11 Otheru Push IBP To Bottom Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Its Exploratory ❑ 196 -170 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 , 50- 029 - 21472 -01 -00 7. Property Designation (Lease Number): 17 J 8. Well Name and Number: . ADL0028310 c)t, V 7 4,45 PBU C -29A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 13660 feet Plugs measured None feet true vertical 8982 feet Junk measured See Attachment feet Effective Depth measured 13598 feet Packer measured See Attachment feet true vertical 8982.89 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 20" 91.5# H -40 29 - 110 29 - 109.99 1490 470 Surface 3057 13 -3/8" 72# L -80 28 - 3085 28 - 2771.22 4930 2670 Intermediate None None None None None None Production 10918 9 -5/8" 47# L -80 27 - 10945 27 - 8405.33 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11575 - 11580 feet 11594 - 11612 feet 11910 - 11930 feet 12680 - 12990 feet 13070 - 13280 feet 13370 - 13440 feet True Vertical depth 8832.46 - 8835.22 feet 8842.82 - 8852.29 feet 8925.88 - 8928.61 feet 9005.64 - 9011.07 feet 9007.87 - 9000.92 feet 8995.47 - 8987.84 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED MAR 6 6 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 515 38867 39 0 890 Subsequent to operation: 1093 34730 80 0 885 14. Attachments: 15. Well Class after work: a Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: n Oil is Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGO 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerha s • b•.com Printed Name Nita Summerhays/ Title Petrotechnical Data Technician Aar' aliorAiwie ignatur- %//� ` _.e:.,6,,,, 4 j� Phone 564 -4035 Date 1/17/2013 RBCMS JAN 8 2010f-'T 1 4: i el3 ''.‘, 2/ //- Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028310 ACTIVITYDATE 1 SUMMARY : • w o. cope: ' qua ize :. us : ® 11/23/2012 MIRU. « <Job in Progress »> CTU#9 w% 1. /5"CT. Job Scope: Equalize & Push IBP to TD Continue RU. Perform weekly BOP test. RIH w / BKR BHA including jars, hyd cent, 2.25" JD hydr overshot. Tagged top of HES RCP packer at 10480'CTM. After multiple failed attempts to pass thru packer POOH. RIH w/ BKR BHA including jars, indexer, 2.25" JD hyd overshot w/ mule shoe. Pass thru RCP packer and liner top at 45 fpm w/o 11/24/2012 issues. « <In Progress »> CTU #9 w/ 1.75 "CT. Job Scope: Equalize & Push IBP to TD « <Continued from 11/24/12 »> Continue RIH. Set down at 11,931'CTM in lower set of open perfs. Unable to RIH at various running speeds, pumping configurations, and attempt depths. Orient tool in 30 deg increments and attempt passage w/o success. Tag at 11,931 "CTM on each attempt. Retry orientation at higher rates w/ slick 1% KCI. No passage. Each tag is solid and same depth. POOH. RIH w/ 2.25" DJN. Tag tubing stub in PBR at 10,480'CTM. After mulitple attempts unable to gain passage. POOH. Marks on DJN indicate setting down on 4.5" tubing stub in PBR. RIH w/ 2.25" DJN and hyd indexer. Pass thru PBR, RCP PKR, and liner top w/o issues. Hard tag at 11,930'CTM. Jet at 1.4 bpm while setting down 11/25/2012 wt. No progress. Swap to slick fluids. « <In Progress »> CTU #9 w/ 1.75 "CT. Job Scope: Equalize & Push IBP to TD « <Continued from 11/25/12 »> Down jet on obstruction /fill at 11,930' CTM at 2.1 bpm. No progress made while jetting and setting wt down (multiple attempts). Obstruction is solid. POOH. RIH w/ slick 1.75" BHA w/ JSN and swivel. Went thru tight spot at 11930' seen a bobble. Tagged IBP @ 12619' started to move continue pushing it to bottom.Made it to 13414' POOH. Well 11/26/2012 freeze protected w/ 45 bbls of 60/40 methanol. Job complete »> FLUIDS PUMPED BBLS 275 60/40 METH 580 1 %KCL 290 1% KCL W /SAFELUBE 1145 TOTAL Casing / Tubing Attachment ADL0028310 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 20" 91.5# H-40 29 - 110 29 - 109.99 1490 470 LINER 3085 2 -7/8" 6.16# L -80 10575 - 13660 8138.54 - 8982.93 13450 13890 LINER 909 7" 29# L -80 10580 - 11489 8142.29 - 8779.73 8160 7020 PRODUCTION 10918 9 -5/8" 47# L -80 27 - 10945 27 - 8405.33 6870 4760 SURFACE 3057 13 -3/8" 72# L -80 28 - 3085 28 - 2771.22 4930 2670 TUBING 10473 4 -1/2" 12.6# 13Cr80 26 - 10499 26 - 8081.3 8430 7500 • TUBING 130 4 -1/2" 12.6# L -80 10484 - 10614 8069.93 - 8167.69 8430 7500 • « • • Packers and SSV's Attachment ADL0028310 SW Name Type MD TVD Depscription C -29A PACKER 10380 7922.55 4 -1/2" Baker S -3 Perm Packer C -29A PACKER 10507 8019.65 4 -1/2" TIW HBBP Packer C -29A PACKER 10544 8047.56 2 -7/8" HES RCP Packer ACT FMC = - BAKE C -2 9A "'UNABLE TO 4-112" RCP P @ 10544' ACTCX2 R C KB. REV = ___ 6785' (SEVERAL ATTEMPTS). PKR NOT RJLLY SET W/ BF. REV = 35.72' I SHORT TRAVEL UP & DOWN (TOTAL LENGTH = 6.06'). . _-.r. __. .- _____.._...._...__, 120 COND H 110' I-1 Max Angle = 99° -; ;; 7 13380'' Datum he= 11643' I 2112' H4 -1/2" HES X NI? D = 3.813" I Datum TVD = 8800' SS GAS LFT MANDRELS ST MD TVD DEV 'TYPE VLV LATCH PORT DATE 113 -3/8' CSG, 72#, L-80, D = 12.347 - H 3086' 4 3615 3159 43 MG DOME RK 16 06/14/08 r 3 6169 5005 47 MMG SO RK 20 06/14/08 2 8346 6496 47 WAG DMY RK 0 06/04/08 1 10255 7893 38 _ MNG DMY RK 0 _06/04/08 Minimum ID = 2.350" @ 10525' I 103W I- 14- 1/2"rESX RP, D= 3.813" 4-1/2" HES RCP PACKER 10380' H9 -5/8 X 4-1 /2° BKR S-3 PKR, D= 3.870" I I 10405' H4-1 /2" FES X NP, D = 3.813" I 4-1/2" TBG, 12.6#,13CR -80 VAM TOP, I 10484' I 10464' 4-112 HE5 XN NP, D = 3.725" I .0152 bpf, D = 3.958" I 10492' —315 PBR SEAL ASSY I 1049$" H 41 /2 OVERSHOT I I4 -1 /2' TBG STUB (05/22108) H 10486' 10507' - 19 -5/8" X 4 -1 /2" 71W HBBP PKR, D = 4.750" I F I 10512' H7" M cT LLOUT DBJSD D N, = 6.00" I 1051T H7 "X4-1/2"XO,D =3.958" I 10544' H4-1 /2" X 2-7/8"1-1M RCP FKR, 13= 2.350' I I 10647' H4 -1/2' OTIS X NP, D = 3.813" I TOP OF 2 -7/8" UR 10575' L I ■ 10575" 3 3/4" BKR DEPLOY SLV, D = 3.000" 10580' 4-1/2 ORS XN NP, 13= 3.80 (MILLED 02/08/96) I R (TOP OF 7" LNR I 10680' 10 580' 9-5/8 X 7" BOT LI HGR w / Ttl33K SLV, D = ? 4 TB 1/2" G, 12.6#, L -80 BTRS, 10614' I_ 10581' H2- 7 LNR XO PIN, 13= 2.441' I 0152 bpf, D = 3.958" r I I 10614 H41 /2" WLEG, D = 3.958' I 1 9-5/8' CSG, 47 #, L -80, D = 8.681" N 10945' I 10622' I —�B_MD TT LOG XX/XX/XX? 17" 1M- °STOCK ( 12108/96) H 11488' I 10876' H T" MARK@2 JT 11350' HTOP OF C EMENT 06/30/97 I RA TAG 11498' 41'1'1 1 7° SDElRACK WI DOW (C -29A) 11489' - 11498' PERFORATION St1M 4ARY 4V REF LOG: SS P4MYGR of 12/17/96 % � �ANGLEAT TOP PER,F: 42° G' 11575' , � Nate: Refer to Production DB for historical perf data ►y�1�1�1 , 13414' — FTSH - 2 -118' BKR BP SIZE SPF INTERVAL n/ z DATE SOZ ►111 (11 /26/12) OP S9 1111 �, �.. r ►111• ►111 ► - ; 1- 11116" 6 11575 -11580 O 05/14/10 111128'ctm - BKR BP 1- 11/16" 6 11594 - 11612 O 08/01/05 1111 ►111 � {1129/00} 1 -9/16" r 6 11910 - 11930 0 06/28/05 1111 4.4 2 -118' 4 12680 -12990 O 12119/96 ►111111111111• \ 1 13429'ctm HSH - BKR BP ►1111111 2 -1/8" r 4 13070 -13280 0 12/19/96 ■ • 1 • • • 1 • 1 � �i'11111.1 (07130/97) 2 -1/8" r 4 13370 - 13440 0 12/19/96 11 1 I SS.* 0/ PBTD 1 359r 17" LIR, 29#, L -80 BTRS, .0371 bpf, D = 6.184' H 12020' 12 -7/8" LNR, 6.16#, L-80, .0058 bpf, D = 2.441" I 13660' DATE REV BY COI/MEWS DATE REV BY COM ENTS PRUDHOE BAY UNIT 02/14/86 N22E ORIGINAL COMPLETION 11/25/08 HJW/ PJC DRLG DRAFT CORRECT1ONS WB-L: C -29A 04/20/86 N22E RIG WORKOVBR 05/18/10 JBYSV ADD FERF (05/14/10) FERMI No: r 1961700 12/20196 NOR 1 CTD SIDETRACK (C -29A) 11/30/12 JJL/JM) PUSH BP TO FBTD (11/26/12) API No: 50 -029- 21472 -01 06/06/08 D14 RWO 01/15/13 GC/AID BP& FISH CORRECTORS SEC 19, T11N, R14E, 1901' SNL & 884' WEL 06/26/08 DAV/PJC GLV C/O (06/14/08) 11/13/08 HB/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 RFCEIVED AUG a 1 `?fl11 Mr. Tom Maunder Ail to 011 & Cos 02116. C mITissitm Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 1 7 Subject: Corrosion Inhibitor Treatments of GPB C -Pad a a . q A Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 0-02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -188 . 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 0-21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -258 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 0-38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C-42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 1 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS RECFNk MAY 1 8 2 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ _1 ~ ,, •fcjz°'"` Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^~ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-ante Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ~ Exploratory ^ 196-1700 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-21472-01-00 8. Property Designation (Lease Numbe ~ 9. Well Name and Number ` ADL028309 ADL028310 PBU C-29A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13660 feet Plugs (measured) 12619 feet true vertical 8982.93 feet Junk (measured) 13428 feet Effective Depth measured 13598 feet Packer (measured) 10380 10507 true vertical 8982.89 feet (true vertical) 7990 8087 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 3085 13-3/8" 72# L-80 SURFACE - 3085 SURFACE - 2771 4930 2670 Intermediate 10945 9-5/8" 47# L-80 SURFACE - 10945 SURFACE - 8405 6870 4760 Production Liner 909 7" 29# L-80 10580 - 11489 8142 - 8780 7240 5410 Liner 3085 2-7/8" 6.16# L-80 10575 - 13660 8139 - 8983 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 35 - 10613 35 - 8167 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X4-1/2" BKR S-3 PKR 10380 7990 9-5/8"X4-1/2" TIW HBBP PKR 10507 8087 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~ f ;. , ~ x ~/ ~~~ f~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 807 37379 22 870 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 5/18/2010 _ ~"",' ~~ lam(. )o „ - `~~~~'' C-29A 196-170 PFRFF ATTArHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-29A 12/19/96 PER 12,680. 12,990. 9,005.64 9,011.07 C-29A 12/19/96 PER 13,070. 13,280. 9,007.87 9,000.92 C-29A 12/19/96 PER 13,370. 13,440. 8,995.47 8,987.84 C-29A 6/4/97 BPS 13,318. 13,328. 9,000.17 8,999.89 C-29A 7/30/97 BPP 13,318. 13,328. 9,000.17 8,999.89 C-29A 7/31/97 BPS 13,030. 13,040. 9,009.83 9,009.42 C-29A 11/29/00 BPP 13,030. 13,040. 9,009.83 9,009.42 C-29A 6/27/05 BPS 13,428. 13,370. 8,988.71 8,995.47 C-29A 6/28/05 APF 11,910. 11,930. 8,925.88 8,928.61 C-29A 6/28/05 BPS 12,612. 13,440. 8,999.78 8,987.84 C-29A 8/2/05 APF 11,594. 11,612. 8,842.82 8,852.29 C-29A 5/14/10 APF 11,575. 11,580. 8,832.46 8,835.22 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • C-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTfVITYDATE 'SUMMARY 5/14/2010;*"*WELL SHUT-IN ON ARRIVAL"`*" (E-LINE: PERFORATING) INITIAL T/I/O: 2400/600/0 PSI. ;SHOOT 1.56" HSD POWERJET 1606, HMX CHARGES FROM 11575' - ;11580' PHASING: 60 DEG SPF: 6 HOLE SIZE: 0.17" PENETRATION DEPTH: :11.3" ;SWAB, SSV, WING CLOSED. MASTER OPEN. IA/OA OTG. FINAL T/I/O: 2400/600/0 PSI. **'`JOB COMPLETE. WELL LEFT SI.*"* FLUIDS PUMPED BBLS 1 DIESEL 1 METH 2 Total TREE = CNV WELLHEADS FMC ACTUATOR = BAKER C KB. ELEV = 67.65' BF. ELEV - 38.72' KOP = 850' Max Angle = 99° @ 13380' Datum MD = 11643' Datum TV D = 8800' SS 120" CONDUCTOR SAFETY NO WELL ANGLE > 70° @ 11720". *** ~~ ~ ~ UNABLE TO L 4-1 /2" RCP PKR @ 10544' (SEVERAL ATTEMPTS). PKR NOT FULLY SET W/ SHORT TRAVEL UP & DOWN (TOTAL LENGTH = 6.06'). 2112' -j4-112" HES X NIP, ID = 3.813" GAS UFT MANDRELS 13-3/8" C5G, 72#, L-80, ID = 12.347" Minimum ID = 2.350" @ 10525' 4-1/2" HES RCP PACKER 4-112" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 4-1/2" TBG STUB (05/22108) i--i 10485` TOP OF 2-718" LNR ~-) 10575` TOP OF 7" LNR 4-112" TBG, 12.6#, L-80 BTRS, .0152 bpf, ID = 3.958" 9-5/8" CSC, 47#, L-80, ID = 8.681" 7" WHIPSTOCK (12/08/96} RA TAG PERFORATION SUMMARY REF LOG: SS MWDlGR of 12!17/96 A NGLE AT TOP PERF: 59 @ 11594' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11116" 6 11594 - 11612 O 08/02!05 1-9(16" 6 11910 - 11930 O 06!28105 2-1/8" 4 12680 - 12990 C 12/19/96 2-1i8" 4 13070 - 13280 C 12/19196 2-118" 4 13370 - 13440 C 12119!96 7" LNR, 29#, L-80 BTRS, .0371 bpf, ID = 6.184" 4 3615 3159 43 MMG DOM RK 16 06!14108 3 6169 5005 47 MMG SO RK 20 06114108 2 8346 6496 47 MMG DMY RK 0 06104!08 1 10255 7893 38 MMG DMY RK 0 06/04!08 10359` - 4-1/2" HES X NIP, ID = 3.813" 103$0' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" 10405` -~4-1/2" HES X NIP, ID = 3.813", 10464' 4-1/2" HES XN NIP, ID = 3.725" 10492' ~ -~TNV PBR SEAL ASSY i 10499` 4-112" TM/ SEAL OVERSHOT w/OUT SEALS 10507' 9-518" X 4-1/2" TM/ HBBP PKR, ID = 4.750" 10512' 7" MILLOUT EXTENSION, ID = 6.00" 10517' 7" X 4-112" XO, ID = 3.958" 10544` 4-1 /2" X 2-7(8" HES RCP PKR, ID = 2.350" 10~ 4-112" OTIS X NIP, ID = 3.813" 10575` -13-3/4" BKR DEPLOY SLV, ID = 3.000" 105$0' 4-1i2" OTIS XN NIP, ID = 3.80 {MILLED 02!08/96} 105$0' -j 9-5i8" X 7" BOT LNR HGR w / TIEBK SLV, ID = ? 105$1' 2-7/8" LNR XO PIN, ID = 2.441" 10614' -~4-1/2" WLEG, ID = 3.958" 10622' ELMD TT LOG XX/XX/XX? 10976` -j 7" MARKER JT ( 11350` TOP OF CEMENT 06/30197 7" SIDETRACK WINDOW (C-29A} 11489' - 11498' 12619' 2-1/8" BKR IBP (06/28/05} 1342$'ctTn FISH -BKR IBP (11 /29!00) ? FISH -BKR IBP (07!30!97) PBTD (-~ 1359$' ~ 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 02(14/86 N22E ORIGINAL COMPLETION 11/25/08 HJW/ PJC DRLG DRAFT CORRECTIONS 04!20!86 N22E RIG WORKOVER 12!20196 NOR 1 CTD SIDETRACK (C-29A) 06!06/08 D14 RWO 06/26/08 DAV/PJC GLV C/O (06/14/08) 11/13/08 HB/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: G29A PERMfT No: 1961700 API No: 50-029-21472-01 SEC 19, T11 N, R14E, 1901' SNL & 884' WEL BP Exploration {Alaska} STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: /'' ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 196-170 • 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21472-01-00 7. KB Elevation (ft): 67 7' 9. Well Name and Number: PBU C-29A 8. Property Designation: p ~,•S3,/jj ,gyp ~ 10. Field /Pool(s): - ADL Z,Qj%~ / ?•$' '' _ I Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 13660' • feet true vertical 8983' ~ feet Plugs (measured) 12619' Effective depth: measured 13598' feet Junk (measured) 13428' true vertical 8983' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 3085' 13-3/8" 3085' 2771' 4930 2670 Intermediate 10945' 9-5/8" 10945' 8405' 6870 4760 Production Liner 909' 7" 10580' - 11489' 8142' - 8780' 7240 5410 Liner 3085' 2-7/8" 10575' - 13660' 8139' - 8983' 13450 13890 ~~~~~ JUL ~ ~~ 2008 Perforation Depth MD (ft): 11594' - 11930' Perforation Depth TVD (ft): 8843' - 8929' 4-112", 12.6# 13Cr80 / L-80 10612' Tubing Size (size, grade, and measured depth}: Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; 10380'; 9-5/8" x 4-1l2" TIW 'HBBP' packer 10507'13 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: .Subsequent to operation: 1,164 23,988 34 700 350 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: • ^ Explorato ry ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 N/q Printed Name Terrie Hubble Title Drilling Technologist ~` Name/Number: Pre ared B Signature ~ y p Phone Date ~7 ~~ ~S Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 = °~ !. _' +!~ ,~ Submit Original Only ~ ~.~.o~ Digital Well File ~ Page 1 of 1 Well: C-29 Well History Well Date Summary C-29A 4/1/2008 T/I/0=100/200/0 (Pressure Test Maint.} CMIT TxfA PASSED to 2500 psi on 3rd attempta Pumped 31 bbls crude to reach test pressure .TxIA lost 40/40 psi in the 1st 15 min and 20/20 psi in the 2nd 15 min for a total loss of 60/60 psi in 30 min. Bled WHP back to Final WHP= 160/200/0 ***casing valves open to gauges on departure*** C-29A 4/2/2008 T/IA/OA= SSV/200/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP bleed tools onto THA 800 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite cap. Cycle and torque LDS "ET style" all moved with no problems. PPPOT-IC RU 2 HP bleed tools onto IC test void 150 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3400/ 15 minutes, 3400/ 30 minutes. Bleed IC void to 0 psi, RD test equipment re installed Alemite cap. Cycle and torque LDS "ET style" all moved with no problems. C-29A 4/12/2008 ***WELL S/I ON ARRIVAL*"* (pre rwo) TAGGED WRP W/ 3.80" CENT ~ 10531' SLM (10539' MD) (+8' CORRECTION) DUMPED 2 BAGS OF SLUGGITS ON TOP OF WRP & RE-TAGGED ~ 10520' SLM (11' OF ~SLUGGITS) ***WELL LEFT S/I ON DEPARTURE*** C-29A 4/19/2008 ***WELL SHUT-IN ON ARRIVAL*** INITIAL WHP 150/190/0 PREPARE TO CUT 4 1/2" TUBING WITH A 3.65" CUTTER. RIH AND LOG INTO POSITION. FIRED CUTTER, GOOD INDICATION AT SURFACE, POOH. **** CONTINUE AWGRS ON 20-APR-08 *** C-29A 4/20/2008 ***** CONTINUE AWGRS FROM 19-APR-08***** INITIAL WHP 150/190/0 CUT 4 1/2" TUBING WITH A 3.65" CUTTER AT 10457' IN TOP 10' OF FIRST FULL JOINT ABOVE HBBP PKR. DID NOT TAG TD. WELL LEFT SHUT IN. FINAL WHP 100/300/0 ***JOB COMPLETE`** C-29A 4/21/2008 Circ Out (Pre RWO) MIRU. ***Continued on 04-22-08*** C-29A 4/22/2008 T/I/0= 100/140/0+. Circ Out (Pre RWO) Pumped 10 bbls of neat and 1080 bbls of 1 % KCL into the TBG with IA returns to the flowline. Pumped 155 bbls of 110* diesel into the TBG. U-Tube for 75 mins. Flush loop with 1 bbl diesel. Freeze protect flowline with 5 bbls neat and 19 bbls diesel. MIT-OA PASSED to 2000 psi. Pumped 1.6 bbls of diesel to achieve test pressure. Lost 50 psi / 1st 15 min & 20 psi / 2nd 15 min. (3rd attempt) Lost a total of 70 psi during the 30 minute test. Bled back 2 bbls to 0 psi. Bled to final WHP= 0/0/0. Annulus casing valves are open to gauges. C-29A 5/14/2008 T/I/O=VAC/0/0. Set 4" CIW "H" BPV. (Pre Doyon 14) Print Date: 7/1/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 7/1/2008 • • BP EXPLORATION Page 1 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~! Task Code NPT Phase Description of Operations 5/16/2008 03:30 - 08:00 4.50 RIGD P PRE -RD rig floor in preparation to skid same -De-mob rig floor in preparation to lay over derrick 08:00 - 11:00 3.00 RIGD P PRE -Install braces on side wind walls 11:00 - 12:00 1.00 RIGD P PRE 12:00 - 14:00 2.00 RIGD P PRE 14:00 - 17:00 3.00 RIGD P PRE 17:00 - 18:00 1.00 RIGD P PRE 18:00 - 21:00 3.00 RIGD P PRE 21:00 - 21:30 0.50 RIGD P PRE 21:30 - 00:00 2.50 RIGD P PRE 5/17/2008 00:00 - 02:30 2.50 RIGD P PRE 02:30 - 08:00 5.50 RIGD N RREP PRE 08:00 - 08:30 0.50 MOB P PRE 08:30 - 12:00 3.50 MOB P PRE 12:00 - 00:00 12.00 MOB P PRE 5/18/2008 00:00 - 05:30 5.50 MOB P PRE 05:30 - 06:00 0.50 MOB P PRE 06:00 - 08:30 2.50 MOB P PRE 08:30 - 12:00 3.50 RIGU P PRE 12:00 - 14:00 I 2.001 RIGU I P I I PRE 14:00 - 15:30 1.50 RIGU P PRE 15:30 - 17:00 1.50 RIGU P PRE 17:00 - 19:30 2.50 RIGU P PRE 19:30 - 22:00 2.50 RIGU P PRE 22:00 - 23:00 1.00 RIGU P PRE -Unhang blocks. -Remove torq tube, link tilt, IBOP assy. and stand jump rings from top drive. -Unhang rig tongs and mud bucket -Install lay down brace across bales on top drive -Remove top drive rail brace Remove service loop lines from top drive -Remove ODS rollers on top drive. -Tie super tugger line back in derrick for top drive lay down operation -Lay down top drive -Unhang bridle lines from derrick -PU C-section and pin. Bridle up Skid rig floor to moving position Move rig off well MPS-31 and position on pad to lay down derrick Skid rig floor back to lay down derrick position -LD front wind wall. -Lay over derrick -Remove cellar doors -Remove heater from cellar -Install boosters -Hang front stairs Repair gussets on booster saddles Move rig down to MP-S pad entrance. Get clearance from pad operator Move rig f/ MP-S pad, down Milne Point road, to approx. 6 miles from Spine Rd. Cont. moving rig to Kuparuk River (west channel). Cont. moving rig on Spine Rd. f/ Kuparuk River (west channel) to Santa Fe pad Wait at Santa Fe pad for field crews changeout Move rig f/ Santa Fe pad to C-pad -Position rig on pad. RD boosters -Install cellar doors, cellar heater and mouse hole -Raise derrick -Raise front windwall and install braces -Finish pinning braces on front wind wall -Hook up steam heater -Unbridle blocks -Lower C-section wind wall Hang top drive and install ODS roller assembly. -Hang bridle lines in derrick -Hook up service loops to top drive -Set mats around well. -Hang rig tongs and mud bucket -Install lower brace on top drive rails -Install kelly hose Spot rig on well C-29A and shim. Skid rig floor to drilling position Printed: 6/30/2008 9:26:59 AM • BP EXPLORATION Page 2 of 19 ~ Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To j Hours Task II Code NPT 5/18/2008 123:00 - 00:00 1.00 RIGU I P 00:00 - 03:00 I 3.001 RIGU I P Spud Date: 1 /20/1986 Start: 5/16/2008 End: Rig Release: 6/6/2008 Rig Number: Phase ' Description of Operations PRE -Slide conveyor in place -Put beaver slide in place -Install IBOP assembly on top drive PRE Continue rig up rig floor -Spot and berm tiger tank -RU hardline to tank 03:00 - 04:30 ~ 1.50 ~ RIGU ~ P 04:30 - 05:30 I 1.001 WHSUR I P DECOMP Take on seawater to pits -Remove blanks f/ wing valve and IA valve -Install pump in flange on wing valve -Install secondary valve and pump in flange on IA valve -Remove tree cap DECOMP -RU DSM lubricator. Test to 500 psi -RD lubricator 05:30 - 07:30 I 2.001 WHSUR I P 07:30 - 11:00 I 3.501 WHSUR I P 11:00-13:00 2.00 WHSUR~P 13:00 - 15:30 I 2.50 I W HSUR I P 15:30 - 19:00 I 3.501 BOPSUFI P 19:00 - 20:00 1.00 BOPSU~ P 20:00 - 00:00 4.00 BOPSU P 15/20/2008 100:00 - 02:00 I 2.001 BOPSURP DECOMP -Check hard line w/ air. -Heat line and choke manifold w/ steam. -Test line to 3500 psi. Good test -RU lines to tree to displace out freeze protect DECOMP Displace freeze protect out -Pump 70 bbls down IA taking returns out tubing to tiger tank (got returns after 20 bbls pumped away). 2.5 bpm / 500 psi -Switch lines. Pump 200 bbls seawater down tubing taking returns out IA to tiger tank. 3 bpm / 260 psi -Wait 30 min for diesel migration -Pump 50 bbls seawater down tubing taking returns out IA to tiger tank, 3 bpm / 300 psi. Divert returns to pits and cont. pumping circulating addit. 10 bbls, 3 bpm / 300 psi DECOMP -Blow down lines. -Test TWC f/ bottom to 1000 psi x 10 min on chart , -Test TWC f/ to to 3500 six 10 min on chart. -RD testing equipment and blow down lines DECOMP -RD lines to tree -ND tree and adapter flange DECOMP -NU BOP -Install extension on choke line DECOMP RU to test BOP DECOMP Test BOP and related a ui ment er BP / AOGCC r r and regulations. Test to 250 psi low - 3500 psi high (annular preventer to 250 psi low - 3500 psi high) x 5 min. each on chart. Test w/ 4" test joint. Test witnessed by WSL, Tourpusher and AOGCC rep. (Lou Grimaldi). DECOMP Cont. testing BOP and related equipment. -Test to 250 psi low - 3500 psi high x 5 min each on chart. -Test w/ 4" test joint. -Test top and bottom rams w/ 4" and 4-1/2" test joints. -Perform Koomey test. -Test witnessed by WSL, T.P. and AOGCC rep. (Lou Grimaldi). ---BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 3 of 19 Operations Summary Report Legal Well Name: C-29 Common W ell Name: C-29 Spud Date: 1/20/1986 Event Nam e: WORKO VER Start : 5/16/2008 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date I Fr om To Hours ', Task Code NPT Phase Description of Operations 5/20/2008 00:00 - 02:00 2.00 BOPSU P DECOMP -Blind Rams. -Drilling Spool. -2 7/8" X 5" Variables. 02:00 - 02:30 0.50 BOPSU P DECOMP RD testing equipment. 02:30 - 03:30 1.00 WHSUR P DECOMP -Blow down lines. -Bring lubricator extensions to rig floor. -Install lubricator extensions in stack. 03:30 - 04:30 1.00 WHSUR P DECOMP -RU lubricator. Test to 500 psi on chart. -Pull TWC. -RD lubricator and lubricator extensions. 04:30 - 06:30 2.00 PULL P DECOMP -Bring control line spooling unit to rig floor. -PU 1 jt 4" DP. MU XOs. -Screw into tubing hanger 10 1/2 turns. BOLDS. 06:30 - 07:00 0.50 PULL P DECOMP Pull FMC 12" X 4 1/2" Tbg Hanger to Floor. -Max PUW 160k observed. 07:00 - 09:00 2.00 PULL P DECOMP Circulate down Tbg to clean up wellbore &Tbg. -Pump: 40 bbls Safe-Surf-O, 50 bbls Safe-Scav. -Chase pills with 8.5 ppg Seawater. -Circulate hole clean ~ 420 gpm / 650 psi. 09:00 - 10:00 1.00 PULL P DECOMP LD XO's & 1- 4" jt of D.P. LD Tbg hanger. -RU Control line spooler. -RU to LD Tbg. -4 1/2" Tbg is jet cut ~ 10,457 md. 10:00 - 13:00 3.00 PULL P DECOMP POH. -LD 4 1/2", 12.6# L-80, BTC Tbg to the SSSV. -Recovered: 29 Clamps & 4 SS Bands. -Recovered +/- 2,270' of 1/4" Dual encapsulated control line. 13:00 - 19:30 6.50 PULL P DECOMP Continue to LD 4 1/2" Tbg. -Clean, even cut noted on cut jt. -Cut jt length is 10.60'. -Cut jt flare is 4 7/8" O.D. 19:30 - 20:00 0.50 PULL P DECOMP Clean & Clear Rig floor of Tbg handling Tools. 20:00 - 22:00 2.00 PULL P DECOMP PU 1 jt of 4" D.P. &Packoff pulling tool. BOLDS. -Pull FMC 9 5/8" ackoff C~3 25k overpull -Change out Packoff per FMC rep. RILDS. -LD 1 jt o 4" D.P. &Packoff pulling tool. -Test Packoff to 3500 psi / 15 minutes- Pass. 22:00 - 22:30 0.50 PULL P DECOMP Install Wear Ring. 22:30 - 00:00 1.50 PULL P DECOMP PU & MU Dress off BHA: -Dress off shoe, Wash pipe, Dress off Mill, -Washover Boot basket, Sub & 9 5/8" Csg scraper. 5/21/2008 00:00 - 08:00 8.00 PULL P DECOMP Continue to RIH w/ Dress off BHA. -Singling in the hole to dress off the Tbg stub. -PU 4" D.P. from 216'to 10,300' md. 08:00 - 09:30 1.50 PULL P DECOMP Reciprocate Csg scraper f/ 10,300 - 10,395' md. -PUW 215k, SOW 125k, ROT wt 160k. -WOB 5-10k, Tq ~ 80 RPM 7k off & 12k on. 210 gpm / 550 psi. -Wash down & over Tb stub C~3 10 457' to 10 474' md. -Dress off 1' of 4 1/2" Tb Stub from 10 457' to 10 458' md. 09:30 - 11:00 1.50 PULL P DECOMP Pump Hi Vis Sweep (YP-38) surface to surface. -490 gpm / 2550 psi. -Sweep brought up scale and tar balls. Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Operations Summary Report Page 4 of 19 ~ Legal Well Common W Event Nam Contractor Rig Name: Date ' Name: ell Name: e: Name: From - To C-29 C-29 WORKO DOYON DOYON Hours VER DRILLIN 14 Task INC Code . NPT Start Rig Rig Phase Spud Date: 1/20/1986 : 5/16/2008 End: Release: 6/6/2008 Number: Description of Operations 5/21/2008 11:00 - 15:00 4.00 PULL P DECOMP Monitor well-static. -POH w/ 4" D.P f/ 10,474' to 216' md. 15:00 - 15:30 0.50 PULL P DECOMP Stand back two stands 4 3/4" D.C's. 15:30 - 16:30 1.00 PULL P DECOMP LD Dress-Off BHA #1 -Dress Off shoe, Wash Pipe, Casing Mill, Casing Scraper. 16:30 - 17:30 1.00 PULL P DECOMP Pressure test 9 5/8" 47# L-80 casin to 3500 si. -Record on chart for 30 minutes. -Test ood. 17:30 - 19:30 2.00 PULL P DECOMP Clean and clear rig floor to prep BHA. -PU and MU RCJB BHA. -Cut Lip Guide, Wash Pipe, RCJB, Drill Collars. -RIH with BHA to 327' md. 19:30 - 22:30 3.00 PULL P DECOMP RIH to top of Tbg stub at 10,458' md. -Fluid displacement normal. 22:30 - 23:30 1.00 PULL P DECOMP Obtain parameters at 10,458' md. -PUW 205k, SOW 125k. -Attem t to o into to of Tb stub• No Go. -Attempt rotating into stub at 20 r m• No Go. -Attempt to enter stubby rotating while pumping. -178 gpm / 630 psi. -Tried this method several times; No Go. 23:30 - 00:00 0.50 PULL P DECOMP POH from 10,458' and to 10,371' md. 5/22/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Cut and slip 1.25" drilling line. -Double cut with total cut of 118'. -Service top drive. 01:00 - 01:30 0.50 CLEAN P DECOMP Dropped ball to shear out circulating sub. -Sheared at 1700 psi. -Flow checked well for 10 minutes-static. -Blow down top drive. 01:30 - 05:00 3.50 CLEAN P DECOMP POH from 10,371' and to surface to inspect BHA. 05:00 - 06:30 1.50 CLEAN P DECOMP Inspect shear pins on RCJB BHA. -Pins were sheared on Guide Assembly. -Replace 13k shear pins with 20k pins. -MU clean out BHA, &RIH. 06:30 - 10:00 3.50 CLEAN P DECOMP RIH w/ 4" D.P. f/ 327' to 10,371' md. 10:00 - 11:30 1.50 CLEAN P DECOMP Obtain parameters: -PUW 210k, SOW 135k, ROT wt 170k ~ 10 RPM. -168 gpm / 700 psi. -Depth indicates tagging on RCJB, not on guide shoe. -Attem t to work inside stub -Unsuccessful. 11:30 - 12:30 1.00 CLEAN P DECOMP Stand back 2 stds. Drop Ball & Rod to open pump out sub. -Pump Ball & Rod down & open pump out sub 210 gpm / 500 psi. -Monitor well -Static. 12:30 - 16:30 4.00 CLEAN P DECOMP POH w/ RCJB 16:30 - 18:30 2.00 CLEAN P DECOMP Stand back two stands 4 3/4" D.C's. -LD RCJB cleanout BHA. -Clean and clear rig floor. 18:30 - 20:00 1.50 CLEAN P DECOMP MU RC B BHA wi -RIH with completed BHA to 334' md. 20:00 - 23:00 3.00 CLEAN P DECOMP RIH from 334' and to 10,378' and w/4" DP. -Obtain parameters: Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 5 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date ~~ From - To Hours ~', Task Code NPT Phase Description of Operations 5/22/2008 20:00 - 23:00 3.00 CLEAN P DECOMP -PUW 205k, SOW 135k, ROT wt 162k. 23:00 - 00:00 1.00 CLEAN P DECOMP Tag top of Tbg stub. at _1.0,458' md. 5/23/2008 100:00 - 00:30 I 0.501 CLEAN I P 00:30 - 02:00 I 1.501 CLEAN I P 02:00 - 02:30 I 0.50 I CLEAN I P 02:30 - 06:00 3.50 CLEAN P 06:00 - 08:00 2.00 CLEAN P 08:00 - 08:30 0.50 CLEAN P 08:30 - 09:30 1.00 CLEAN P -I-Ll~J l7 WUUIU I IVL CI ILCI JUV IICCI Y. -Begin rotation of 20 rpm ~ 7k torque. -Entered stub after 15 min rotation. -Reamed and circulated 178 gpm ~ 650 psi. -Entered 7' into tubin but could not o an further. DECOMP Continue to try to work RCJB into top of Tbg stub at 10,458' md. -Rotated at 20 rpm ~ 7k torque, 178 gpm / 650 psi. -No Go on further penetration. DECOMP Drop ball to open RCJB. -Ball set, increase pump rate to 160 gpm / 950 psi. -Continue to work RCJB with rotation and pumping. DECOMP Stand back two stands 4" DP. -Drop ball and rod. -Pump down with 100 gpm / 430 psi to close RCJB. -Closed at 1830 psi. -Flow check well -static. DECOMP POH from 10,377' to 333' md. DECOMP Stand back two stands 4 3/4" D.C's. -LD RCJB BHA. -Inspect junk basket. -Retrieved a 1 "x3" iece f me DECOMP Clean and clear rig floor. -Mobilize tools for next BHA to floor. DECOMP -RIH with BHA to 315' md. -Prep tools to Cut and Slip drilling line. 09:30 - 11:00 1.50 CLEAN P DECOMP Cut and Slip 1.25" drilling line. -Cut approximately 60' of line. -Service top drive. 11:00 - 14:00 3.00 CLEAN P DECOMP RIH with 4" DP from 315' and to 10,340' md. 14:00 - 15:00 1.00 CLEAN P DECOMP Obtain operational parameters. -PUW 1210k, SOW 140k, Rot wt 167k. -Pump rate of 253 gpm / 750 psi. -Torque 4k~ 50 rpm. -Mill 4 1/2" Tb stub to 10.460, md. -Pull off of stub. 15:00 - 16:00 1.00 CLEAN P DECOMP Pump Hi-Vis sweep. -Pump rate of 120 spm / 2400 psi. -Slide back over Tbg stub w/o pumps and no rotation. 16:00 - 20:00 4.00 CLEAN P DECOMP Rack back one stand 4" DP, LD 1 jt 4" DP. -Blow down Top Drive. -POH from 10,340' and to 220' md. 20:00 - 21:00 1.00 CLEAN P DECOMP Rack back two stands of 4 3/4" D.C's. -Break down washover extensions. -Recovered 5.35' of 4 1/2" tubin from inside -Clean out junk basket-retrieved approximately 6 Ibs metal cuttings. 21:00 - 00:00 3.00 CLEAN P DECOMP Clean and clear rig floor of Dressoff BHA and wash pipe. -Load pipe shed with nine 6 3/4" D.C's. Printed: 6/30/2008 9:26:59 AM • ~ BP EXPLORATION Page 6 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations __ - _- 5/23/2008 ~ 21:00 - 00:00 I 3.00 CLEAN I P DECOMP -Strap D.C's and record ID / OD. 5/24/2008 100:00 - 02:00 I 2.00 I CLEAN I P 02:00 - 05:00 ~ 3.00 ~ CLEAN ~ P -Mobilize 4 1/2" Overshot Grapple BHA to rig floor. DECOMP MU oil jars, bumper jars, overshot and extension. -PU nine 6 3/4" D.C's. -MU jar intensifiers and XO's. DECOMP RIH with 4 1/2" Overshot ra le BHA on 4" DP. -RIH from 317' and to 10,465' md. -Obtained parameters: PUW 230k, SOW 140k, ROT wt 175k. -Tagged Tbg stub with grapple. -PU 250k over, no movement. -PU 275k over, jars fired. 05:00 - 09:30 4.50 CLEAN P 09:30 - 11:00 1.50 CLEAN P 11:00 - 11:30 0.50 CLEAN P 11:30 - 13:00 1.50 CLEAN P 13:00 - 15:30 2.50 CLEAN P 15:30 - 17:00 1.50 CLEAN P 17:00 - 21:00 I 4.00 I CLEAN I P 21:00 - 23:00 I 2.001 CLEAN I P 23:00 - 23:30 I 0.50 I CLEAN I P 23:30 - 00:00 I 0.501 CLEAN I P 5/25/2008 ~ 00:00 - 01:00 ~ 1.00 ~ CLEAN ~ P 01:00 - 04:30 I 3.501 CLEAN I P -Set down 10k to verify; tagged 2' high. -Monitor well-static. DECOMP POH with fi h from 10,465' to 317' md. DECOMP LD BHA. -LD XO's, jars, D.C's. -Break off overshot and extension. -Retrieved 7.22' of 4.5" tubin . -Replace grapple with same size (4.5"). DECOMP Lubricate rig equipment. -Service top drive. DECOMP PU, MU Overshot grapple BHA. -Two extensions, nine 6 3/4" D.C's, jars, intensifier, XO's. DECOMP RIH with Overshot ra le BHA on 4" DP. -RIH from 323' and to 10,472' md. DECOMP PU 1 jt 4" DP. -Bottom of Overshot grapple BHA at 10,485', top at 10,472' md. -Obtain operational parameters. -PUW 220k, SOW 150k, ROT wt 175k. -Free torque 4k. -En a e fish and work i e er Baker re . -Set torque Stall at 18k. -Attempting to disengage from Packer anchor. -Monitor well-static. DECOMP LD one jt 4" DP. -POH from 10,462' to 323' md. DECOMP LD iars. stand back three stands 6 3/4" D.C's. -Change out 4 1/2" grapple. Replace with same size. -Retrieved Grapple was spread and oversized. -PU three stands 6 3/4" D.C's and jars. DECOMP RIH with Overshot grapple BHA on_4" DP. -RIH from 323'to 1,082' md. DECOMP Clean and clear rig floor. -Prep for Cut and Slip 1.25" drilling line. -PJSM for Cut and Slip. DECOMP Cut and Slip 1.25" drilling line. -Cut approximately 60' of line. -Service top drive. -Clean and clear rig floor. DECOMP RIH with Overshot grapple BHA on 4" DP. Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 7 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours ~ Task Code NPT Phase ', Description of Operations 5/25/2008 01:00 - 04:30 3.50 CLEAN P DECOMP -RIH from 1,082' to 10,367' md. -Obtain parameters: PUW 220k, SOW 145k, ROT wt 175k. 04:30 - 05:00 0.50 CLEAN P DECOMP Work down over Fish ~ 10,474' md. -Engage Fish. Jar on Fish er Baker re . -Jar up to 350k. -After several Jarring attempts Fish broke loose ~ 320k. 05:00 - 10:00 5.00 CLEAN P DECOMP Monitor well -Static. Inspect Derrick. -POH with Fish from 10,474' to 323' md. 10:00 - 12:00 2.00 CLEAN P DECOMP LD jars, stand back three stands 6 3/4" D.C's. -Breakoff overshot and extensions. -Release grapple. -Break off partial tubing it. -Cut jt 10.5', pup jt 5.13', barrel) of seal guide assembly 14.85'. 12:00 - 14:30 2.50 CLEAN P DECOMP Mobilize Cleanout BHA to rig floor. -MU shoe assembly, washpipe extensions, boot basket. -MU bumper sub, jars, XO, nine 6 3/4" D.C's. -Change out elevators. 14:30 - 17:30 3.00 CLEAN P DECOMP RIH with Cleanout BHA. -RIH from 318'to 10,457' md. 17:30 - 18:30 1.00 CLEAN P DECOMP Obtain operational parameters. -PUW 223k, SOW 148k, ROT wt 175k, free torque 4k. Wash down from 10,457' to 10.504' and with washpipe. 18:30 - 19:30 I 1.00 I CLEAN I P 19:30 - 22:00 I 2.501 CLEAN I P 22:00 - 23:30 ~ 1.50 ~ CLEAN P 23:30 - 00:00 I 0.501 CLEAN I P 5/26/2008 00:00 - 03:00 3.00 CLEAN P 03:00 - 05:00 2.00 CLEAN P 05:00 - 07:30 I 2.50 I CLEAN I P -worK over SucK sucK several umes. DECOMP Pump Hi-Vis sweep. -Pumped at 120 spm / 2450 psi. -Once sweep past BHA PU to 10,465' and and rotate C~ 60 RPM. -Nothing to note from sweep. -Monitor well-static. DECOMP Attem t to slide over fish - No Go. -Pump and rotate over Fish per Baker rep. -Keep working pipe until it slid over Fish without rotation. -Reciprocate ~ 6' several times to ensure good sliding w/o pumps. DECOMP Pump Hi-Vis sweep (61-YP) surface to surface. -Pump rate 120 spm / 2450 psi. -Once sweep past BHA PU to 10,465' and and rotate ~ 60 RPM. -Slide over Slick stick several times - OK. DECOMP Monitor well -Static. -POH with Cleanout BHA. -POH from 10,489' to 9,304' md. DECOMP POH with Cleanout BHA. -POH from 9,304' to 318' md. DECOMP LD Cleanout BHA: -Nine 6 3/4" D.C's., Washpipe extensions, Shoe. -LD Oil jars & Bumper sub. -Dressoff mill in good condition. -Inspect boot basket-recovered ~ 7 Ibs metal cuttings. DECOMP Clean and clear rig floor. Printed: 6/30/2008 9:26:59 AM • BP EXPLORATION Page 8 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code II NPT Phase Description of Operations 5/26/2008 05:00 - 07:30 2.50 CLEAN P DECOMP -Mobilize RCJB BHA to rig floor. -MU RCJB BHA. -Components: Cut lip guide, two Washpipe ext., one Washpipe -(cont) bushing, RCJB with mule shoe, four 2 7/8" PAC D.C's -(cont) bumper sub, jars, pump out sub, six 4 3/4" D.C's. 07:30 - 10:00 2.50 CLEAN P DECOMP RIH with RCJB BHA on 4" -RIH from 342' to 9,817' md. 10:00 - 11:00 1.00 CLEAN P DECOMP Cut and slip drilling line. -Cut approximately 60' of 1.25" drilling line. -Clean and clear rig floor. 11:00 - 11:30 0.50 CLEAN P DECOMP RIH with RCJB BHA from 9,817' to 10,480' md. -Obtain operational parameters. -PUW 220k, SOW 140k. -Pump rate of 182 gpm / 720 psi. -Drop 9/16" ball to activate RCJB. -Pump rate of 182 gpm / 780 psi when ball seated. 11:30 - 14:30 3.00 CLEAN P DECOMP Tag top of slick stick at 10,489'. -Attempt to work RCJB into slick stick several times. -Entered slick stick, washdown from 10,489' to 10,513' md. Operational parameters: -PUW 220k, SOW 140k, ROT wt 170k, 6k torque ~ 20 rpm. Pump rate of 5 bpm / 920 psi. -Circulate to clean hole. -POH to 10,480' md. -Monitor well-static. 14;30 - 15:00 0.50 CLEAN P DECOMP POH with RCJB BHA. -POH from 10,480' to 10,007' md. 15:00 - 15:30 0.50 CLEAN P DECOMP Drop 1 7/8" ball to open Pumpout Sub. -Pin sheared at 2100 psi. -Circulate one DP volume. 15:30 - 21:30 6.00 CLEAN P DECOMP POH from 10,007' to 342' md. 21:30 - 22:30 1.00 CLEAN P DECOMP Stand back two stands 4 3/4" D.C's. -LD two jts 2 7/8" PAC D.C's. -Ins ected RCJB mule shoe-'a ed ed es lost .08' to dama e. -Suspect metal debris on top of sluggits and WRP. -Changed out mule shoe for bladed mill. -PU the two jts 2 7/8" PAC D.C's and four 4 3/4" D.C's. 22:30 - 00:00 1.50 CLEAN P DECOMP RIH with Bladed Junk Mill BHA. -RIH from 342' to 5,266' and on 4" DP. 5/27/2008 00:00 - 01:30 1.50 CLEAN P DECOMP Continue to RIH with Bladed junk mill BHA. -RIH from 5,266 to 10,386' md. -Obtain operational parameters: -PUW 220k, SOW 140k, ROT wt 175k. -Pump rate of 173 gpm / 460 psi. 01:30 - 05:00 3.50 CLEAN P DECOMP RIH and to to of slick stick with mill at 1 4 ' -Confirmed shear of shear guide at 20K WOB. -Entered slick stick a roximatel 6' to 10 495' md. -Mill from 10,495' to 10,516' md. -Circulate to clean hole while rotating & reciprocate 15' w/mill. -Continue to attem t to mill as 1 ' 05:00 - 06:30 1.50 CLEAN P DECOMP Pump Hi-Vis sweep (61 YP). -Pump rate of 478 gpm / 3530 psi. -Monitor returns across shakers visually and with magnets. Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 9 of 19 ~ Operations Summary Report 'Legal Well Name: C-29 Common Well Name: C-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 5/27/2008 05:00 - 06:30 1.50 CLEAN P 06:30 - 07:00 0.50 CLEAN P 07:00 - 10:00 3.00 CLEAN P 10:00 - 11:00 1.00 CLEAN P 11:00 - 12:00 I 1.00 I CLEAN I P 12:00 - 16:30 I 4.50 I EVAL I P 16:30 - 17:00 0.50 ~ CLEAN ~ P 17:00 - 18:30 ~ 1.50 ~ CLEAN ~ P 18:30 - 21:30 3.001 CLEAN P 21:30 - 00:00 ~ 2.50 ~ CLEAN ~ P 5/28/2008 ~ 00:00 - 01:00 ~ 1.00 ~ CLEAN ~ P 01:00 - 02:30 1.50 CLEAN P Spud Date: 1/20/1986 Start: 5/16/2008 End: Rig Release: 6/6/2008 Rig Number: Phase Description of Operations DECOMP -Very little amount of metal shavings captured. DECOMP Stand back one stand 4" DP. -Drop ball, shear Pumpout Sub at 2000 psi. -Pump dry job. -Blow down topdrive. DECOMP P from 10,480' to 342' md. DECOMP Stand back six 4 3/4" D.C's. -LD jars, bumper sub, stand back one stand and one jt 2 7/8" PAC -(cont.) D.C's (w/3 1/8" OD), washpipe and cut lip guide. -Ins ect Bladed 'unk mill-dama e DECOMP Clean and clear rig floor. -Pull wear ring, install test plug. -RU to test BOP's. DECOMP PJSM for testing BOP's. -Test BOP's, Choke & associated valves: -BOP Configuration: -Hydril GK 13 5/8" 5000. -3 1/2" X 6" Variables. -Blind /Shear Rams. -Drilling Spool. -2 7/8" X 5" Variables. -Test TIW & Dart valves. -Test upper & lower Rams w/ 4" & 4 1/2" test jts. -Test 250 low psi & 3,500 psi High-Pass. -Hold each test for 5 minutes. Perform Koomie test. -Test witnessed by TP, WSL. -Test witness waived by Jeff Jones of AOGCC. DECOMP RD BOP test equipment. -Pull test plug, install wear ring. -Blow down choke /kill lines and Topdrive. DECOMP MU Bladed mill BHA. -MU cut lip guide, washpipe extensions and bushing, mill, -(cont) shear pin guide assembly, four 2 7/8" PAC D.C's (3.125" OD), -(cont) XO, Bumper sub, jars, Pumpout sub, XO, six 4 3/4" D.C's. DECOMP RIH with Bladed 'unk mill BHA o " DP. , -RIH from 342'to 10,480' md. -Obtain parameters: -PUW 218k, SOW 140k, ROT wt 167k, tree torque 4k. DECOMP RIH and to to of slick stick with mill at 10 489' md. -Positive indication of shear of mill shear assembly at 20k. -Several attem is to enter slick stick. -Mill from 10,513' to 10,518' md. -Add 2 bbls Safe-Lub lubricant to fluid. -Circulate to clean hole while rotating & reciprocate 10-15' w/mill. DECOMP Continue milling operations from 10,518' to 10,522' md. -169 gpm / 660 psi. DECOMP Pump Hi-Vis sweep (YP=61) while milling, looking f/ Sluggits. -Pump rate 460 gpm / 3660 psi. Printed: 6/30/2008 9:26:59 AM • BP EXPLORATION Page 10 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours I! Task Code NPT Phase Description of Operations __ _ _ - - 5/28/2008 01:00 - 02:30 1.501 CLEAN P DECOMP -Monitor returns-metal shavings on magnets and shakers. 02:30 - 04:30 2.00 CLEAN P DECOMP Continue milling operations from 10,522' to 10,523' md. -Operational parameters: -PUW 218k, SOW 135k, ROT wt 170k, torque 9k, 50 rpm. -Pump rate 178 gpm / 405 psi. -Pressure spikes to 800+ psi when rotating on bottom -Work mill. PU above Slick stick. Run back into Slick stick. Tag up C~ 10.518' md. -Work mill ~ 10,518' md. No Go. 04:30 - 05:00 0.50 CLEAN P DECOMP Stand back one stand 4" DP to 10,470' md. -Drop ball, shear pin on Pumpout sub. -POH with Bladed junk mill BHA. -Seawater wt= 8.5 ppg in & out. 05:00 - 08:00 3.00 CLEAN P DECOMP POH w/ 4" D.P from 10,470' to the BHA ~ 342' md. 08:00 - 09:00 1.00 CLEAN P DECOMP Stand back 4 3/4" D.C's. LD Oil jars & Bumper sub. -Stand back 1 Std of PAC D.C's. -Break off Shear pin assembly. Break off Mill. 09:00 - 10:00 1.00 CLEAN P DECOMP Rebuild Shear pin assembly. Rebuild Pump out sub. -MU Mill & Wash i e. MU PAC D.C's. -PU OIL jars & Bumper sub, 4 3/4" D.C's. -RIH w/ 10 Stds of D. P. to 1,291' md. 10:00 - 11:00 1.00 CLEAN P DECOMP RU to cut drilling line. Cut & Slip 59.50' of 1.25" drilling line. 11:00 - 14:30 3.50 CLEAN P DECOMP RIH w/ 4" D.P. from 1,291' to 10,480' md. 14:30 - 20:00 5.50 CLEAN P DECOMP Obtain parameters: -PUW 215k, SOW 140k, ROT wt 170k. 168 gpm / 490 psi. -Free Tq 4k ~ 50 rpm. On bottom Tq 9k ~ 50 rpm. -Tagged with mill at 10,519' md. - ore mill down to 10.521' and and milled to 10,524' md. -MIII with 252 gpm / lUSU pSl. 20:00 - 00:00 4.00 CLEAN P DECOMP Stand back one stand 4" DP. -Dropped ball to shear pins in Pumpout sub. -POH w/bladed junk mill BHA from 10,480' to 342' md. -Seawater wt= 8.5 ppg in & out. 5/29/2008 00:00 - 01:30 1.50 CLEAN P DECOMP Stand back two stands 6 3/4" D.C's. -LD Pumpout sub, jars, bumper sub. -Stand back four 2 7/8" PAC D.C's (3 1/8" OD). -Break off shear pin assembly and mill. -Rebuild shear pin assembly and Pumpout sub. 01:30 - 03:00 1.50 CLEAN P DECOMP Clean and clear rig floor -MU flat bottom shoe mill to RCJB. -MU shear pin assembly. -MU four 2 7/8" PAC D.C's, jars, bumper sub and Pumpout sub. -MU two stands 6 3/4" D.C's. 03:00 - 06:00 3.00 CLEAN P DECOMP RIH with RCJB BHA on 4" DP. -RIH from 342' to 10,483' md. -Seawater 8.5 ppg in. 06:00 - 07:00 1.00 CLEAN P DECOMP Obtain operational parameters: -PUW 210k, SOW 140k -Drop ball to open RCJB; pump down 85 gpm / 170 psi. -Wash over slick stick and shear assembly guide ~ 20k. -Wash down to 10,519' md. Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 11 of 19 ~ Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours ', Task .Code NPT 5/29/2008 I CLEAN P os:oo -07:00 1.0o 07:00 - 07:30 I 0.501 CLEAN I P 07:30 - 11:30 I 4.001 CLEAN I P Spud Date: 1 /20/1986 Start: 5/16/2008 End: Rig Release: 6/6/2008 Rig Number: Phase Description of Operations DECOMP -Increase pump rate to 254 gpm / 1570 psi. -Wash down to 10,524' md. -Work up and down seven times. -Increase pump rate to 300 gpm / 2030 psi. -Work to bottom three times. -Pull completely out of stub, wash back down to bottom. DECOMP Stand back one stand of 4" DP. -Monitor well-static. -Drop ball to open Pumpout sub. -Blow down topdrive. -Put in dry job. -POH from 10,476' to 342' md. DECOMP Stand back one stand 2 7/8" PAC D.C's (3 1/8" OD). -LD Pumpout sub, jars, bumper sub. -Stand back two stands 4 3/4" D.C's. -Break off shear pin assembly. -Break off flat bottom shoe mill and RCJB. -Inspect RCJB. 11:30 - 12:00 0.501 CLEAN P 12:00 - 14:30 ~ 2.50 ~ CLEAN ~ P 14:30 - 17:00 i 2.50 I CLEAN i P 17:00 - 20:30 3.50 CLEAN P 20:30 - 22:00 1.50 CLEAN P 22:00 - 00:00 I 2.00 I CLEAN I P 5/30/2008 100:00 - 02:00 2.00 CLEAN P 02:00 - 03:00 1.00 I CLEAN P 03:00 - 05:30 I 2.50 I CLEAN I P DECOMP Clean and clear rig floor. -MU WRP retrieval tool BHA. DECOMP RIH with WRP retrieval BHA on 4" DP. -RIH from 342' to 10,480' md. DECOMP Ta WRP with retrieval tool at 10,524' md. -Obtain operational parameters: -PUW 215k, SOW 140k, pump rate 220 gpm / 720 psi. -Seawater in and out at 8.5 ppg. -Washed over at 220 gpm with 5k to 25k WOB. -Picked up w/out overpull in attempt to equalize and latch WRP. -Worked retrieval tool at different parameters attempting to -Stand back one stand 4" DP. DECOMP Drop ball to open Pumpout sub. -Blow down topdrive. -Monitor well-static. -POH from 10,480' to 342' md. DECOMP Break down WRP retrieval BHA per Baker rep. -Stand back 4 3/4" D.C's, LD Pumpout sub, jars, bumper sub, -stand back 2 7/8" PAC D.C's, break down Shear pin guide -w/WRP retrieval tool, break down washpipe and cut lip guide. DECOMP -Mobilize SLB Wireline Service (SWS) tools to rig floor. -RU lubricator extension through riser into rig's 3 1/2"x6" variable rams. -RU SWS pump-in sub and wireline BOP's. -OA pressure 0 psi at 2330. DECOMP Continue to RU SLB Wireline Services (SWS). -RU sheaves, line and stuffing box. DECOMP Cut wireline, re-tie rope socket on tool. -MU wireline tools. -Test lubricator to 500 psi for five minutes-no leaks. DECOMP RIH with slickline WRP retrieval tool._ -Tag slick stick at 10,489' md. Printed: 6/30/2008 9:26:59 AM • ~ BP EXPLORATION Page 12 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 ,Rig Name: DOYON 14 Rig Number: Date From - To I Hours Task I Code I NPT ~I Phase Description of Operations 5/30/2008 03:00 - 05:30 2.50 CLEAN P DECOMP -Attempt to work retrieval tool into slick stick-No Go. _ 05:30 - 06:00 0.50 CLEAN P DECOMP SWS POH with WRP retrieval tool. 06:00 - 07:30 1.50 CLEAN P DECOMP Inspect retrieval tool-damaged on bottom. -SLB ordered new tool and guide to help entry. 07:30 - 10:30 3.00 CLEAN P DECOMP Receive tool from SLB. -Modify WRP retrieval tool with guide. 10:30 - 11:30 1.00 CLEAN P DECOMP PJSM with crew, SLB Wireline crew, WSL. -Pre-job for testing wireline BOPE and running retrieval tool. -Pressure test lubricator, BOPE to 500 psi-test good. 11:30 - 14:00 2.50 CLEAN P DECOMP RIH with SWS WRP retrieval tool with two bowspring 14:00 - 15:30 I 1.501 CLEAN P 15:30 - 17:00 1.50 CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 19:30 I 1.501 CLEAN P 19:30 - 22:00 I 2.501 CLEAN I P 22:00 - 00:00 2.00 CLEAN P 5/31/2008 100:00 - 01:00 I 1.001 CLEAN I P 01:00 - 01:30 0.501 CLEAN I P 01:30 - 02:00 0.501 CLEAN P -RIH to 10,525' and per SWS measurement. -Attem t to a ualize or latch to WRP-no success. DECOMP POH with SWS retrieval tool. -Break apart lubricator. -Change out retrieval tool to Weatherford equalizer and -shear pin tattletale tool. -MU lubricator. -Pressure test lubricator, BOPE to 500 psi-test good. DECOMP RIH with Wetherford equailizer and tattletale tool. -Tag with WRP at 10,525' md. -Attem t to a ualize-not able toe ualize. -POH with equalizer tool. -No tattletales were sheared in Weatherford equalizer tool, -indicating no contact with WRP. DECOMP Break apart lubricator. -RD: Weatherford tool, SWS line wiper, BOPE, Pump-in sub, -and lubricator extension. -Released SWS. -Blow down kill and choke lines. -Fill hole. DECOMP Cut and Slip 1.25" drilling line. -Cut 59.5' of drilling line. -Service topdrive and blocks. DECOMP MU RCJB BHA f r cleanout run. -MU: Shoe guide, two washpipe extensions & bushing, -shear guide assembly (w/RCJB), four 2 7/8" PAC D.C. (3.125" OD), -bumper sub, jars, pump-out sub, six 4 3/4" D.C's. DECOMP RIH with RCJB BHA on 4" DP. -RIH from 342' to 6,300' md. -Seawater in and out 8.6 ppg. DECOMP Continue to RIH with RCJB BHA on 4" DP. -RIH from 6,300' to 10,480' md. DECOMP Obtain operational parameters: -PUW 205k, SOW 140k, pump rate 240 gpm / 700 psi. -Free torque 4k. -Monitor well-static. -Drop ball to open RCJB. -Pump rate after ball reached RCJB 220 gpm / 1130 psi. DECOMP Taa and enter slick stick at 10,489' md. -Sheared shear guide assembly at 25k. -Tap up at 10,524' md. Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 13 of 19 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To C-29 C-29 WORKO DOYON DOYON Hours VER DRILLIN 14 Task INC Code . NPT 5/31/2008 02:00 - 03:00 1.00 CLEAN P 03:00 - 04:00 1.00 CLEAN P 04:00 - 05:00 1.00 CLEAN P 05:00 - 08:30 3.50 CLEAN P 08:30 - 10:30 2.00 CLEAN P 10:30 - 12:00 1.50 CLEAN P 12:00 - 13:00 1.00 CLEAN P 13:00 - 14:00 1.00 CLEAN P 14:00 - 16:30 2.50 CLEAN P 16:30 - 19:00 2.50 CLEAN P 19:00 - 20:00 1.00 CLEAN P Spud Date: 1 /20/1986 Start: 5/16/2008 End: Rig Release: 6/6/2008 Rig Number: Phase Description of Operations DECOMP Monitor well-static. -Rotate 20 rpm with uniquely modified flat bottom mill assembly -on RCJB. -WOB 2-5k, torque 5-6k, pump rate 168 gpm / 1000 psi. -Reciprocate and rotate RCJB over junk. -Burned over approximate) 4' to 10,528' md. DECOMP Monitor well-static. -Pump Hi-Vis sweep around. -Pump rate 168 gpm / 1000 spi. DECOMP -Drop ball to open pumpout sub; pump rate 540 gpm / 2600 psi. -Pump Hi-Vis sweep (YP 58) surface-to-surface. -Monitor returns across shakers-trace of metal shavings. DECOMP Monitor well-static. -Stand back one stand 4" DP. -Fill trip tank. -Seawater in and out 8.6 ppg. -Blow down topdrive. -POH from 10,480' to 342' md. DECOMP Stand back two stands 4 3/4" D.C's. -LD pumpout sub, jars and bumper sub. -Stand back 2 7/8" D.C's. -LD washpipe assembly and RCJB. -Retrieved several chunks 'unk metal. DECOMP Clean and clear rig floor. -Send uniquely modified flat bottom mill shoe to Baker for redress. DECOMP Wait on custom modified mill from Baker shop. -Service topdrive, blocks and drawworks. DECOMP MU RCJB BHA: -Cut lip guide, washpipe assembly with RCJB and uniquely modified -flat bottom shoe mill attached, shear pin guide assembly, four 2 7/8" -PAC D.C's (3.125" OD), bumper sub, jars, pumpout sub six 4 3/4" D.C's. DECOMP RIH with RCJB BHA on 4" DP. -RIH from 342' to 10,480' md. DECOMP Obtain parameters: -PUW 210k, SOW 140k, free torque 4k, pump rate 84 gpm / 290 psi. -SPR: Pump 1 20 spm=180 psi, 30 spm=340 psi. -SPR: Pump 2 20 spm=100 psi, 30 spm=280 psi. -Drop ball to open RCJB. -Sheared guide assembly at 20K down wt. -Torque 5k l~ 20 rpm, pump rate 189 gpm / 1080 psi. -Tag bottom at 10,528'; burn down 5' to 10,533' md. - ncrease pump ra a gpm psi to get dun up into RCJB. DECOMP Circulate Hi-Vis sweep around bit. -Drop ball to open pumpout sub. -Pump rate 448 gpm / 1880 psi. i -Fill trip tank; seawater in and out 8.5 ppg. Printed: 6/30/2008 9:26:59 AM From - To 'Hours Task Code i NPT Phase - - --~ i ~ BP EXPLORATION Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Event Name: WORKOVER Start: 5/16/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date 5/31 /2008 20:00 - 00:00 ~ 4.00 CLEAN P 6/1/2008 100:00 - 00:30 I 0.501 CLEAN I P 00:30 - 01:30 I 1.00 I CLEAN I P 01:30 - 04:30 3.00 CLEAN P 04:30 - 05:30 1.00 CLEAN P 05:30 - 07:00 I 1.50 I CLEAN I P 07:00 - 10:00 I 3.00 I CLEAN I P 10:00 - 11:00 I 1.001 CLEAN I P • Page 14 of 19 ~ Spud Date: 1 /20/1986 End: Description of Operations DECOMP Monitor well-static. -Stand back one stand 4" DP. -Blow down topdrive. -POH from 10,480' to 342' md. -Stand back two stands 4 3/4" D.C's. -LD pumpout sub, jars and bumper sub. -Stand back 2 7/8" D.C's. DECOMP LD washpipe assembly and RCJB. -Retrieved several chunks junk metal and ~ 15 lbs. Sluggits. DECOMP MU RCJB BHA: -Cut lip guide, washpipe assembly with RCJB and uniquely modified -flat bottom shoe mill attached, shear pin guide assembly, four 2 7/8" -PAC D.C's (3.125" OD), bumper sub, jars, pumpout sub six 4 3/4" D.C's. DECOMP RIH with RCJB and uni ue flat bottom shoe mill BHA on 4" DP. -RIH from 342'to 10,480' md. DECOMP Obtain operational parameters: -PUW 200k, SOW 140k, pump rate 160 gpm / 770 psi. -Free torque 4k. -Monitor well-static. -Ta bottom at 10,533' md. -Shear guide assembly at 20k. -Drop ball to open RCJB. -Pump rate 200 gpm / 1020 psi. -Wash down (no rotation) from 10,533' to 10,541' md. -Set down 10k. -Pump Hi-Vis sweep; monitor shakers. DECOMP Pump Hi-Vis sweep around BHA. -Drop ball to open Pumpout sub. -Pump sweep to surface. -Monitor shakers-slight metal slivers. -Blow down topdrive. -Stand back one stand 4" DP. DECOMP POH with RCJB BHA. -POH from 10,480' to 342' md. -Fill trip tank. DECOMP Stand back two stands 4 3/4" D.C's. -LD pumpout sub, jars and bumper sub. -Stand back 2 7/8" D.C's. -LD washpipe assembly and RCJB. 11:00 - 12:00 1.00 CLEAN P DECOMP Clean and clear shear guide assembly. -Mobilize WRP retrieval tool BHA. 12:00 - 13:30 1.50 CLEAN P DECOMP MU WRP retrieval tool BHA: -Cut lip guide, washpipe assembly with WRP retrieval tool, -shear pin guide assembly, four 2 7/8" PAC D.C's (3.125" OD), -bumper sub, jars, pumpout sub, six 4 3/4" D.C's. 13:30 - 14:30 1.00 CLEAN P DECOMP PJSM with crew on Slip and Cut drilling line. -Slip and cut 1.25" drilling line. -Cut approximately 59.5'. -Service topdrive, blocks, drawworks. Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 15 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/1/2008 14:30 - 17:00 2.50 CLEAN P DECOMP RIH with WRP retrieval BHA on 4" DP. -RIH from 342' to 10,480' md. 17:00 - 17:30 0.50 CLEAN P DECOMP Obtain operational parameters: -PUW 210k, SOW 140k, pump rate 195 gpm / 540 psi. -Monitor well-static. -Shear guide assembly at 20k down wt. -Ta bottom at 10,541' md. -Set down 5k; pick up to see PUW. -Set down 10k; pressure increase from 540 psi to 1120 psi. -Latch plug at 10,451 md. -Drop ball to open Pumpout sub. -Pull BHA out of slick stick into 9 5/8" casing. 17:30 - 22:00 4.50 CLEAN P DECOMP BU -Noted gas bubbles to surface. -Sit for 15 min. while monitoring well- 24 bbls / hr losses. -CBU -Noted gas bubbles to surface but not as much as fii time. -Sit for another 15 min. while monitoring well- 32 bbls / hr I -CBU-more gas bubbles again but less than two previous times. -Pum ands of wei hted, viscous ill (8.8 ppg / YP 81). 22:00 - 00:00 I 2.00 I CLEAN I P 6/2/2008 00:00 - 03:00 3.00 CLEAN P 03:00 - 03:30 I 0.501 CLEAN I P DECOMP -POH from 10,480' to 10,007' md. -Flow check well-(very slight losses). -Continue to POH from 10,007' to 7,444' md. -Total Seawater lost toda : 73 bbls. DECOMP Continue to POH with WRP retrieval BHA. -POH from 7,444' to 342' md. DECOMP Stand back two stands 4 3/4" D.C's. -LD pumpout sub, jars and bumper sub. -Stand back 2 7/8" D.C's. -Break WRP retrieval tool with WRP from washpipe. -Losses since midni ht-Obbls. 03:30 - 04:30 1.00 CLEAN P DECOMP Clean and re-dress shear guide assembly. -MU "GS" packer spear BHA: -Cut lip guide, washpipe assembly with packer retrieval spear, -shear pin guide assembly, four 2 7/8" PAC D.C's (3.125" OD), -bumper sub, jars, pumpout sub, six 4 3/4" D.C's. 04:30 - 07:30 3.00 CLEAN P DECOMP RIH with packer retrieval BHA on 4" DP. -RIH from 342' to 10,480' md. 07:30 - 09:00 1.50 CLEAN P DECOMP Enter slick stick at 10 489' md. -Tag with shear guide assembly at 10,501' md, shear at 22k. -Tag packer at 10,544' md, attempt to latch several times. 09:00 - 09:30 I 0.50 I CLEAN I P 09:30 - 12:00 I 2.50 I CLEAN I P 12:00 - 16:00 ~ 4.00 ~ CLEAN ~ P DECOMP Pick up a few feet, drop ball to open pumpout sub. -Sit down on packer 5k. -Pump rates while pumping dart 84 gpm / 2350 psi. DECOMP Monitor well-1 b h losses. -LD 4" DP into pipe shed. -POH from 10,480' to 6,785' md. DECOMP Service drawworks at Tour change. -Continue LD 4" DP into pipe shed from 6,785' to 4,416' md. Printed: 6/30/2008 9:26:59 AM C] • BP EXPLORATION Page 16 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date !, From - To Hours Task Code ~ NPT Phase Description of Operations 6/2/2008 ~ 12:00 - 16:00 4.001 CLEAN P 16:00 - 20:30 4.50 CLEAN P 20:30 - 00:00 I 3.501 CLEAN I P 6/3/2008 100:00 - 02:30 I 2.501 FISH I P 02:30 - 03:30 I 1.001 FISH I P DECOMP -Start standing back 4" DP stands into derrick. -POH from 4,416' to 342' md. DECOMP Stand back two stands 4 3/4" D.C's. -LD pumpout sub, jars and bumper sub. -Stand back 2 7/8" D.C's. -Break "GS" 4" spear retrieval tool from washpipe. -Clean and re-dress shear guide assembly. -MU "GS" acker s ear BHA: -Cut lip guide, washpipe assembly with "GS" 3.5" packer -retrieval spear, shear pin guide assembly, four 2 7/8" -PAC D.C's (3.125" OD), bumper sub, jars, pumpout sub, -six 4 3/4" D.C's. DECOMP RIH with packer retrieval BHA on 4" DP. -RIH from 342' to 6,791' md. DECOMP Continue RIH with packer retrieval BHA on 4" DP. -RIH from 6,791' to 10,480' md. DECOMP Obtain operational parameters. -PUW 205k, SOW 140k, pump rate 105 gpm / 1200 psi. -Enter slick stick at 10 489' md. -Taa with shear auide assembly at 10,501' md, shear at 13k. at 03:30 - 07:00 3.50 FISH P DECOMP POH from 10,544' to 10,480' md. -Drop ball to open pumpout sub. -POH from 10,480' to BHA 07:00 - 08:00 1.00 FISH P DECOMP -Rack back 4-3/4" DCs -LD bumper sub and jars. -Rack back 2-7/8" DCs -LD washpipe assembly 08:00 - 08:30 0.50 BOPSU P DECOMP -Clear rig floor -Pull wear bushing 08:30 - 09:00 0.50 BOPSU P DECOMP RU to test BOP 09:00 - 13:30 4.50 BOPSU P DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high (annular to 250 psi low - 3500 psi high) x 5 min each on chart. Tested w/ 4" test jt. Tested upper and lower rams w/ 4" and 4-1 /2" test jts. Test witnessed by WSL and Toolpusher. John Crisp, AOGCC rep, waived witness of test. -Perform koomey test: 1. System Pressure: 3100 psi 2. Pressure after close: 1800 psi 3. 200 psi attained at 39 sec 4. Full pressure attained at 2 min 44 sec 5. Nitrogen bottles: 4 x 2150 psi avg. -Tested 29 components: 1. 13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 17 of 19 ~ Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/3/2008 09:00 - 13:30 4.50 BOPSU P DECOMP 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) 13:30 - 14:00 0.50 BOPSU P DECOMP -RD testing equipment -Blow down kill and choke lines -Install wear bushing 14:00 - 14:30 0.50 FISH P DECOMP MU RCP retrievin BHA w/ cut lip guide, 2 washpipe extensions, spear assembly and shear pin guide assembly to fish on RCP fishing neck. -Spear dressed w/ 2.648" Nom. Catch Grapple (2,608" min, 2.688" max) and No-Go set to enter 5" max inside RCP fishing neck. 14:30 - 15:00 0.50 FISH P DECOMP RIH to 1291' w/ RCP retrieving BHA on 4" DP 15:00 - 16:00 1.00 FISH P DECOMP -Cut and slip 49.5' drilling line -Service top drive and blocks 16:00 - 19:00 3.00 FISH P DECOMP Cont. RIH w/ RCP retrieving BHA on 4" DP from 1291' to 10479' 19:00 - 22:30 3.50 FISH P DECOMP -Screw in top drive and check parameters: PUW 200k /SOW 140k -Tag top of slick stick C~3 10489', Swallow slick stick on washpipe extensions and shear pins in guide assembly with +/- 20k slack. -Cont. running spear inside 4-1/2" stub and tag top of RCP ~ 10544' -Engage spear and ensure being inside RCP slacking 15k on spear stop -Work pipe and attempt to retrieve RCP pulling to 50k over PUW and holding x 5 min each time for aprox. 45 min. N~ success -Pull 2 times to 50k over PUW and hold x 15 min each time. -Pull 2 times to 75k over PUW and hold x 15 min each time. No success -Pull 2 times to 100k over PUW (max. permisible overpull) and hold x 15 min each time. No sucess -No jar action on any attempt._ -Release spear from RCP 22:30 - 00:00 1.50 FISH P DECOMP -Rack back one stand 4" DP -Drop dart and open pump out sub -Cont. POOH and racking back 4" DP (pipe will stay racked back on derrick for rig move to well C-196) 6/4/2008 00:00 - 01:30 1.50 FISH P DECOMP Cont. POOH and racking back 4" DP to 6791' -Racked back 40 stands. Pipe will stay racked back for rig move to well C-19B 01:30 - 05:30 4.00 FISH P DECOMP POOH and LD 4" DP 1 xi to pipe shed f/ 6791' to 342' 05:30 - 06:30 1.00 FISH P DECOMP LD 4-3/4" DCs, bumper sub and jars, 2-7/8" DCs and washpipe assy. 06:30 - 07:30 1.00 FISH P DECOMP -Mobilize Baker tools off rig floor -Clear and clean rig floor -Pull wear bushing 07:30 - 09:00 1.50 BUNCO RUNCMP RU to run com letion -C/O bales and elevators. RU tubing tongs. Install torque turn equipment and compensator. Printed: 6/30/2008 9:26:59 AM • • BP EXPLORATION Page 18 of 19 Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Spud Date: 1/20/1986 Event Name: WORKOVER Start: 5/16/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/6/2008 Rig Name: DOYON 14 Rig Number: Date !From - To Hours Task Code NPT Phase Description of Operations 6/4/2008 109:00 - 22:30 22:30 - 00:00 6/5/2008 100:00 - 05:00 05:00 - 07:30 07:30 - 09:30 09:30 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 14:00 14:00 - 17:00 17:00 - 20:30 13.50 BUNCO RUNCMP -Run 4-1/2" 12.6# 13Cr80 Vam Top tubing and completion e ui ment. -Bakerlock all connections below packer. Torque turn all connections to 4440 ft-Ibs make up torque. -Tubing joints run: 268 -Check parameters: PUW 175k /SOW 121 k 1.50 BUNCO RUNCMP -PU and run jt 269 and 270. -Observe 1st row of pins shear w/ +/- 10k. Observe 2nd row of pins shear w/ +/- 15k. Bottom out (No-Go) TIW overshot ~ 10508' (bottom of TIW overshot) w/ 9' in on jt 270. -LD jt 270. MU 9.82' pup jt and run. MU head pin. -Attempt to reverse circulate. Pressure up to 830 psi w/ no returns. Slick stick in overshot -LD 9.82' pup joint. MU head pin on top of joint 269. Attempt to reverse circulate. Presure up to 900 psi w/ no returns. Slick stick still in overshot. -PU 6' and establish reverse circulation @ 3 bpm / 120 psi. Overshot above slick stick. 5.00 BUNCO RUNCMP Reverse circulate down IA clean seawater and corrosion inhibitor, taking returns out tubing -Reverse circulate total 843 bbls -Added corrosion inhibitor from 280 bbls to 650 bbls pumped away. -3 bpm / 130 psi 2.50 BUNCO RUNCMP -PU jt 270. Run and bottom out TIW overshot and confirm space out -LD jts 270, 269 and 268. MU 7.75' pup jt. -MU jt 268, tubing hanger and landing joint w/ XOs and head pin. -Land completion. RILDS -Bottom of TIW overshot ~ 10499'. XN nipple C~? 10464'. Production Packer ~ 10380'. GLMs ~ 10255', 8346', 6169' and 3614'. Top X nipple ~ 2112' 2.00 BUNCO RUNCMP -Drop ball and rod. RU to test tubing and IA -Pressure up tubing to 3500 psi. Set packer. Hold 3500 30 min on chart. -Bleed off tubing to 1500 psi. Pressure up IA to 3500 qsi x 30 -Bleed off tubing and observe DCR-1 valve shear. Bleed off all pressures and confirm circulation through DCR-1 valve. 0.50 BUNCO RUNCMP -RD testing equipment. -LD landing joint, head pin and XOs 0.50 BUNCO RUNCMP Safety meeting w/ BP Workover Ops. Superintendent (J. Willingham} and ADW HSE Advisor (J. Kilfoyle) 1.50 BUNCO RUNCMP -D rod TWC -Test TWC f/ below to 1000 psi x 10 min on chart. Test f/ 2.00 BUNCO RUNCMP -Blow down kill line, choke line and hole fill line. -Clear rig floor of tools not needed for upcoming operations 3.00 BOPSU P RUNCMP -RD flow line and riser -ND BOP 3.50 WHSUR P RUNCMP -NU adapter flange and tree -Test adapter flange and void to 5000 psi per FMC Printed: 6/30/2008 9:26:59 AM r r~ u BP EXPLORATION Operations Summary Report Legal Well Name: C-29 Common Well Name: C-29 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date 'From - To Hours Task I Code. NPT 6/5/2008 17:00 - 20:30 ~ 3.501 WHSUR P 20:30 - 22:30 I 2.001 WHSUR I P 22:30 - 23:30 1.00 WHSUR P 23:30 - 00:00 0.50 WHSUR P 6/6/2008 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:30 I 1.501 WHSUR I P Page 19 of 19 Spud Date: 1 /20/1986 Start: 5/16/2008 End: Rig Release: 6/6/2008 Rig Number: Phase Description of Operations RUNCMP -Fill tree w/diesel and test to 5000 psi. -RU lubricator and test same to 500 psi. Pull TWC. RD lubricator RUNCMP -RU Little Red Services. Test lines to 3000 psi -Pump 140 bbls diesel down IA, taking returns out tubing, for freeze protect -2 bpm / 700 psi RUNCMP Jump IA to tubing and let diesel U-tube RUNCMP RU lubricator. Test to 500 psi. RUNCMP -Set BPV -RD lubricator -Test BPV f/ below to 1000 psi x 10 min on chart w/ Little Red. RUNCMP -Suck diesel from lines. RD Little Red -Blow down and RD lines, valves and hoses -Remove pump in flanges. Remove secondary valve f/ IA -Install flanges and gauges. Secure tree Release ri ~ 02:30 . OA= 0 psi / IA= 0 psi / TBG= 0 psi Printed: 6/30/2008 9:26:59 AM TREE= '` 4-1/16" CNV WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV - 67.65' BF. ELEV - 38.72' KOP = 850' ---- Max Angle = 99 @ 13380' Datum MD = 11643' Datum TV D = 8800' SS SAFET~TES: WELL ANGLE> 70° @ 11720' 8 > 90° @ 12875 SEVERAL ATTEMPTS MADE TO PULL OUT 4- ~f ti ~ ~- ~ ~ -~ ~~ 1/2" RCP PKR @ 10544' MD W/O SUCCESS. PKR NOT FULLY SET W/SHORT TRAVEL UP 8 DOWN. MIN ID = 2.35" /TOTAL LENGTH = 6.06'.; ATTEM PTED AGAIN DURING 6/2008 RWO **"' """4-1/2" CHROMETBG~"" I--~--f - 2112' 4-112" HES X NdP, ED 3.813" 13-318" CSG, 72#, L-80, ID = 12.347" I~ 3085' Minimum ID = 2.350" @ 10544' 4-1/2" HES RCP PACKER 4-112" TBG, 12.6#, 13Cr-80, VAM TOP; .0152 - bpf, iD = 3.958" ~ 4-1/2" X 2-7/8" HES RCP PKR, ID = 2.350" I (TOP OF 2-7/8" LNR, 6.16#, L-80, ID = 2.372" ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 10581' 9-5/8" CSG, 47#, L-80, ID = 8.681" I~ 10945' PERFORATION SUMMARY REF LOG: SS MWD/GR of 12/17/96 ANGLE AT TOP PERF: 59 @ 11594' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 11594 - 11612 O 08/02/05 1-9/16" 6 11910 - 11930 O 06/28/05 2-1/8" 4 12680 - 12990 C 12/19/96 2-1/8" 4 13070 - 13280 C 12/19/96 2-1/8" 4 13370 - 13440 C 12/19/96 ^ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3815 3159 43 ~,1MG DOIv9 RK 16 06;14108 3 6169 5005 47 MMG SO RK 20 06;14!08 2 8346 6496 47 MMG DMY RK 0 06; 04108 1 10255 10255 38 MMG DMY RK 0 06/04108 10359' 4-1/2" HES X N1P, ID = 3.813" 10380' 9-518" X 4-112" BKR S-3 P}CR, ID = 3.875" 10404" 4-112" HES X NIP; ID = 3.813" 10464' 4-1/2'" HES XN NIP, ID = 3.725" 10499' TM/ SEAL OVERSHOTw10 SEALS 10492' TMJ PBR SEAL ASSY~ 10507' 9-5l8" X 4-1/2" TMJ HBBP PKR, ID = 4.750" 10547' 4-1/2" OTIS X NIP, ID = 3.813" 10575' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.000" 10580' 4-1/2" OTIS XN NIP, ID = 3.800" 10580' 7" BOT LNR HGR TIEBACK SLEEVE 10613' 4-1/2" WLEG (SOS ) 10622' ELMD TT LOG NOT AVAILABLE 10987' 7" MARKER JT 7" SIDETRACK WINDOW 11489' - 11498' (OFF WHIPSTOCK ) 11350' TOP OF CEMENT 06/30/97 11498' RA TAG 12619' -~ 2-1/8"BKR IBP (06/28/05) 13428'ctm FISH: 2-1/8" BKR IBP 11/29/00 UNKNOWN FISH:2-1/8"BKR IBP 07/30/97 PBTD I~ 13598' 7" LNR, 26#, L-80, IJ4S, ID = 8.276" I--I 12020' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I~ 13660' DATE REV BY COMMENTS DATE REV BY COMMENTS 02/14/86 ORIGINAL COMPLETION 06/06/08 D14 RWO 04/24/86 RIG WORKOVER 06/09/0 8 /TLH CORRECTIONS 12/20/96 CTD SIDETRACK _ 06/28/08 DAV/PJC GLV GO (06/14/08) 10/03/01 CH/TLH CORRECTIONS 10/26/06 CJN/PAG SET WFD WRP @ 10539' 11/15/06 OOBlTLH PERF & FISH CORRECTIONS PRUDHOE BAY UNff WELL: G29A PERMff No: 1981700 API No: 50-029-21472-01 SEC 19, T11 N, R14E, 1901' SNL & 884' WEL BP Exploration (Alaska) C-29A (PTD #1961700) Classified as Problem Well . All, Well C-29A (PTD #1961700) has sustained casing pressure on the IA and has been classified as a Problem well. A TIFL failed on 10/12/06. TIO's on 10/12/06 are 2260/2160/vac. The plan forward for this well is as follows: 1. SL: Install DGL V in top GLM 2. DHD: Re-TIFL Attached is a wellbore schematic. Please call with any questions. «C-29A.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com :-:;.1; ~,~ ~\'~~~E[' - _...., . ,~ (ì {,I <.:.: Content-Description: C-29A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 10/16/2006 9:30 AM TREE '" 4-1/16" Cr.N WElLHEA D '" FMC ~-"""'-~.",.,.......,=~. ACTUA TOR = AXElSON KB. ElEV = 67.65' BF. ElEV '" 38.72' KOP = 850' ~"""""""'~ Max Angle "'~ 13380' Datum MD '" 11643' Datum TVD '" 8800' S8 113-3/8" CSG, 72#. L-80, ID'" 12.347" I Minimum ID = 2.350" @ 10525' 4-1/2" HES RCP PACKER ITOPOF 2-7/8" LNR, 6.16#, L-80, 10 = 2.372" 14-1/2" TBG, 12.6#, L-80, .0152 bpI, 10'" 3.95S" 10612' 10581' I 9-5/8" CSG, 47#, L-80, 10'" 8.681" I ÆRFORA TION SUMMARY REF LOG: 88 MWD/GR of 12/17/96 ANGLE AT TOP ÆRF: 59 @ 11594' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 11594-11612 0 08/02/05 1-9/16" 6 11910-11930 0 06/28/05 2-1/8" 4 12680 - 12990 C 12/19/96 2-1/8" 4 13070 - 13280 C 08/31/97 2-1/8" 4 13370 - 13440 C 08/31/97 17" LNR, 26#, L-SO, 1J4S, 10 = 6.276" I 12020' DATE 02/14/86 04/24/86 12/20/96 10/03/01 04/11/03 07/03/03 DATE 09/15/03 08/27/04 06/28/05 07/03/05 08/03/05 REV BY COMMENTS ORIGINAL COMPLETION RIG WORKOVER CTD SIDETRACK CH/TLH CORRECTIONS MHlKAK IBP DEPTH CORRECTION CMO/TLP MAX ANGLE CORRECTION C-29A S~: WELL ANGLE> 70° @ 11720' & > 90° @ 12875'. *** SEVERAL ATTEMPTS MADE TO PULL OUT 4-1/2" RCP PKR@ 10525' etm WIO SUCCESS. PKR NOT FULLY SET WI SHORT TRAVEL UP & DOWN. MIN ID = 2.35" I TOTAL LENGTH = 6.06'. . 2275' -14-1/2" OTIS DBESSSVN.ID 3.813" I GAS LIFT MANDRElS DEV TYPE VLV LATCH PORT DATE 43 LBO SIO RA 20 12/25/96 46 LBO DV RA 0 12/25/96 46 LBO DV RA 0 12/25/96 44 LBD DV RA 0 12/25/96 41 LBD DV RA 0 12/25/96 38 LBO DV RA 0 12/25/96 39 LBD DV RA 0 12/25/96 ST MD 7 3318 6 5909 5 7688 4 8822 3 9794 2 10217 1 10363 TVD 2874 4759 5975 6761 7469 7794 7909 I I 10432' -14-112" OTIS XA SLIDING SLV, ID = 3.813" 10492' -iTr.N PBR SEAL ASSY I 10507' -i 9-5/8" X 4-1/2" Tr.N HBSP PKR, 10 = 4.750" I 1052S'ctm -14-1/2" X 2-7/8" HES RCP PKR, ID = 2.350" I -14-112" OTIS X NIP, ID = 3.813" I -\3-3/4" BKR DEPLOYMENT SLV, 10 = 3.000" -14-1/2" OTIS XN NIP, 10'" 3.800" I -iT' BOT LNR HGR TIEBACK SLEEVE -14-1/2" WLEG (SOS) H ElMD TT LOG NOT A V AILABLE ¡ -1 T' MARKER JT ¡ -i TOP OF CEMENT 06/30/97 -1RA TAG I 12-7/S" LNR, 6.16#, L-80, .0058 bpf, 10 = 2.441" I REV BY COMMENTS /TLP DATUM MO & ÆRF ANGLE ROY /TLP TOP OF CEMENT - 06/30/97 MDClPJC ÆRFS/ SET BKR IBP /TLH ÆRF CORRECTIONS GJB/TLH ADPERFS PRUDHOE BA Y UNIT WElL: C-29A PERMIT No: 1961700 API No: 50-029-21472-01 SEC 19, T11N, R14E, 1901' SNL & 884' WEl BP Exploration (Alaska) ) STATE OF ALASKA '\ ALA5"A OIL AND GAS CONSERVATION COMM. JION REPORT OF SUNDRY WELL OPERATIONSSEP ~ q, ,<_ 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 - Otllteri)t].UU5 Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 waiverDi:i:;'11!mr;.~~te~si~,n 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspehded'1 \Älel1l[9 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit tobfill Number: Name: Development 'r;?ì Exploratory [] 196-1700 3. Address: P.O. Box 196612 Stratigraphic r Service C 6. API Number: Anchorage, AK 99519-6612 50-029-21472-01-00 7. KB Elevation (ft): 9. Well Name and Number: Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl I Casing Pressure Tubing pressure SHUT - IN 36743 I 7 I 0 2220 15. Well Class after proposed work: Exploratory r Development P' Service r 16. Well Status after proposed work: Oil P' Gas r WAG r GINJ r WINJ r WDSPL r 67.7 KB 8. Property Designation: ADl-028310 11. Present Well Condition Summary: Total Depth measured 13660 feet true vertical 8982.93 feet Effective Depth measured 13598 feet true vertical 8982.89 feet Casing length Size MD CONDUCTOR 71 20" 91.5# H-40 39 - 110 SURFACE 3047 13-3/8" 72# l-80 38 - 3085 PRODUCTION 10908 9-5/8" 47# l-80 37 - 10945 LINER 914 7" 26# l-80 10580 - 11494 LINER 3085 2-7/8" 6.16# l-80 10575 - 13660 Perforation depth: Measured depth: 11594 - 11612 True Vertical depth: 8842.82 - 8852.29 11910 - 11930 8925.88 - 8928.61 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# Packers and SSSV (type and measured depth) 4-1/2" TIW HBBP Packer 2-7/8" HES RCP Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations 816 x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal _ _ I Signatu~~ --~/;:f C-29A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Plugs (measured) Junk (measured) 12612, 13428 13406 TVD Burst 39 - 109.99 1490 38 - 2771.22 4930 37 - 8405.33 6870 8142.29 - 8783.07 7240 8138.54 - 8982.93 13450 Ir'k···k~\ìr\.'I\,Ü¡;:;~·ì/ (~,rp\ ). ~:\, ?OU~:¡ 'I.::lr~~~lf"'ð f'~ ~.~ ~~ ".." ~~} ,..... L Collapse 470 2670 4760 5410 13890 l-80 35-10613 10507 10525 RBDMS BFl, SEP 1. 3 2005 Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Form 10-404 Revised 04/2004 Phone 564-4424 Submit Original Only Date 9/12/2005 O i-) '< '--... ~ f\: f¡ L ¡-\ I b ~ r'\JA BBLS 1 Diesel 1 TOTAL FLUIDS PUMPED C-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/2/2005 CORRELATED TO MCNL DATED 20-AUG-2004 PERFORATED 11594 - 11612 FT WITH 1.56" 1606 PJ 6 SPF GUNS NO PROBLEMS PASSING RCP RESTRICTION OF 2.35", MAX TOOL OD WAS 1.6875" ,.J ) ) ) STATE OF ALASKA) RECl:IVl!1 ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 3 2005 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Com:. Com 1. Operations Performed: ~hor~ Abandon 0 Repair Well 0 PluQ PerforationsD Stimulate 0 Othe"rD age Alter CasingD Pull TubingD Perforate New PoolD WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate ŒJ Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ]] ExploratoryD 5. Permit to Drill Number: 196-1700 6. API Number 50-029-21472-01-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 67.70 8. Property Designation: ADL-028310 11. Present Well Condition Summary: Stratigraphic 0 serviceD 9. Well Name and Number: C-29A 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 13660 feet true vertical 8982.9 feet Effective Depth measured 13428 feet true vertical 8988.7 feet Plugs (measured) 12612 Junk (measured) None Casing Length Size MD TVD Burst Collapse CONDUCTOR 71 20" 91.5# H-40 39 110 39.0 110.0 1490 470 LINER 914 7" 26# L-80 10580 - 11494 8142.3 - 8783.1 7240 5410 LINER 3085 2-7/8" 6.16# L-80 10575 - 13660 8138.5 - 8982.9 13890 13450 PRODUCTION 10908 9-5/8" 47# L-80 37 - 10945 37.0 - 8405.3 6870 4760 SURFACE 3047 13-3/8" 72# L-80 38 - 3085 38.0 - 2771.2 4930 2670 Measured depth: 11910 -11930 True vertical depth: 8925.88 - 8928.61 TubinQ ( size. Qrade, and measured depth): 4-1/2" 12.6# L-80 @ 35 10613 Packers & SSSV (type & measured depth): 4-1/2" TIW HBBP Packer 2-7/8" HES RCP Packer 4-1/2" Otis SSV Nipple @ 10507 @ 10525 @ 2275 SCANNEj) AUG 0 8 2005 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure 13 Prior to well operation: Subsequent to operation: Oil-Bbl SHUT-IN SHUT-IN Tubing Pressure ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil [!] Gas D Development ŒJ ServiceD 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Nam e DeWayne R. Schnorr Signature A~- ÞfJ~ Title Petroleum Engineer Phone 564-5174 Date 7/28/05 r'~ r\, : ¡ \ 1 ~) ~\ (~"ií\f l\, (:)I ; ¡\~ 1-\ t_ RBDMS BFL AUG 0 4 2005 Form 10-404 Revised 4/2004 ) ) C-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/27/05 CTU #5, IBP/ADD PERF; MIRU DS CTU #5. RIH WITH PDS MEMORY GR/CCL INSIDE 2.20" CARRIER FOR DRIFT AND FLAG. NO PROBLEMS PASSING THROUGH 'RCPI PACKER OR LINER TOP. LOGGED GR/CCL FROM 12910' CTMD UP TO 11400' CTMD. FLAGGED PIPE AT 12600' AND AT 11900' CTMD. POOH. RIH WITH BAKER 2 1/8" IBP. TIE-IN AND SET CENTER OF PACKER ELEMENT AT 12619' CORRECTED DEPTH (TOP OF IBP AT 126121). POOH. WSR CONTINUED ON 06/28/05......... 06/28/05 CTU #5, IBP/ADD PERF, WSR CONTINUED FROM 06/27/05......... POOH. MU AND RIH WITH 1.56" PJ1606 GUN. PERFORATE 20',6 SPF, FROM 11910'-11930'. TIE-IN LOG SLB MCNL 08/20/04, CONNECTION (+131). POOH. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 124 50/50 METHANOL WATER 70 2% KCL WATER 194 TOTAL Page 1 ! TREE = WELLHEAD = 'ÄCTUÄT6R'~"'" ··KS:···Ëï..E\J; BF. ELEV = ï<Ór3; m. ~~~w~~~.I~..~..... Datum MD = Datum TVD = 4-1/16" CrN FMC . M",,,,,,,,-,,,,' ",..."..".."",,,'r,../ AXELSON . . ,.",...,.....,.,.,....,.,..,.,... 67.65' ... . . ....... ..... ,,~ 38.72' 850' . ",,,,,..,,....,,....,,..,,,..,..,,,..,...,.. 9,~, ~. 1,33.80' 11643' 8800' SS ) 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 3085' ~ Minimum ID = 2.350" @ 10525' 4-1/2" HES RCP PACKER TOPOF 2-7/8" LNR, 6.16#, L-80, ID = 2.372" l-i 10581' \4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 10612' 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 10945' ~ ÆRFORA TION SUMMARY REF LOG: SS MWD/GR of 12/17/96 ANGLEATTOPÆRF: 83@ 11910' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-9/16" 6 11910 -11930 0 06/28/05 2-1/8" 4 12680 - 12990 C 12/19/96 2-1/8" 4 13070 - 13280 C 08/31/97 2-1/8" 4 13370-13440 C 08/31/97 C-29A SAFE. )oTES: WELL ANGLE> 70° @ 11720' & > 90° @ 12875'. *** SEVERAL ATTEMPTS MADE TO PULL OUT 4-1/2" RCP PKR @ 10525' ctm W /0 SUCCESS. PKR NOT RJLL Y SET WI SHORT TRAVEL UP & DOWN. MIN ID = 2.35" I TOTAL LENGTH = 6.06'. e 2275' 1-i4-1/2" OTIS DBE SSSVN, ID = 3.813" I GAS LIFT MANDRELS ~ ST MD TVD DEV TYÆ VLV LATCH PORT DATE 7 3318 2874 43 LBD S/O RA 20 12/25/96 6 5909 4759 46 LBD DV RA 0 12/25/96 5 7688 5975 46 LBD DV RA 0 12/25/96 4 8822 6761 44 LBD DV RA 0 12/25/96 3 9794 7469 41 LBD DV RA 0 12/25/96 2 10217 7794 38 LBD DV RA 0 12/25/96 1 10363 7909 39 LBD DV RA 0 12/25/96 L I I 10432' 1-i4-1/2" OTIS XA SLIDING SLV, ID = 3.813" 10492' I-iTrN PBR SEAL ASSY I 10507' 1-i9-5/8" X 4-1/2" TrN HBBP PKR, ID = 4.750" I 10525'ctm 1-i4-1/2" X 2-7/8" HES RCP PKR, ID = 2.350" I 10547' 1-i4-1/2" OTIS X NIP, ID = 3.813" I 10575' l-i 3-3/4" BKR DEPLOYMENT SL V, ID = 3.000" 10580' 1-i4-1/2" OTIS XN NIP, ID = 3.800" I 10580' l-i 7" BOT LNR HGR TIEBA CK SLEEV E 10613' 1-i4-1/2" WLEG (SOS) I 10622' I-iELMDTT LOG NOT AVAILABLE I 10987' l-i 7" MA RKER JT I I z ZJ ~ ~ ~ .t-J~ i ~ / 7" SIDETRACK WINDOW 11489' - 11498' (OFF WHIPSTOCK) 11350' l-i TOP OF CEMENT 06/30/97 11498' l-i RA TAG I 12619' l-i 2-1/8" BKR IBP (06/28/05) I I PBTD l-i 13598' I 7" LNR, 26#, L-80, IJ4S, ID = 6.276" l-i 12020' I 12-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" l-i 13660' DATE 02/14/86 04/24/86 12/20/96 10/03/01 04/11/03 07/03/03 REV BY COMMENTS ORIGINAL COM PLETION RIG WORKOVER CTD SIDETRACK CHlTLH CORRECTIONS MH/KA K IBP DEPTH CORRECTION CMO/TLP MAX ANGLE CORRECTION DATE 09/15/03 08/27/04 06/28/05 07/03/05 REV BY COMMENTS CMOITLP DATUM MD & ÆRF ANGLE ROY ITLP TOP OF CEMENT - 06/30/97 MDClPJC ÆRFS/ SET BKR IBP ITLH ÆRF CORRECTIONS PRUDHOE BAY UNIT WELL: C-29A ÆRMIT No: 1961700 API No: 50-029-21472-01 SEC 19, T11N, R14E, 1901' SNL & 884' WEL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth /7 ~ -/70 03/15/05 NO. 3363 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color ~ Well Job # Log Description Date Blueline Prints CD ! q,; -my. C-39 10715421 MCNL 08/19/04 1 '!I (n-H'? E-21A 10670030 MCNL 08/22104 1 t9tr 170 C-29A " 10715422 MCNL 08/22/04 1 ::/ J.C3· i¡''}...DS 07-338 10715361 MCNL 11/04/03 1 1 !9J-/53-07-01A 10889151 RST 08/18/04 1 1 ~1'wC¡ X-27 10724364 RST 03/10/04 1 1 .~ E-18A 10621786 RST OS/22/04 1 1 !.~7:C:.«('( DS 01-24A 10563108 RST 10/09/03 1 1 ! ). L;z.. E-10A 10621797 RST 06/16/04 1 1 '?;9 Z-12 10704020 RST 07/06/04 1 1 I! -102- 10704021 RST 07/07/04 1 1 ZOI~ 00] i X-15A 1:Þl..~)1 P1-07A 10831301 RST 07/03/04 1 1 .' q '7.. 07rJ:G-03A 10889210 LDL 02/13/05 1 1;41- '2..l, L5-17 A 10942195 PSP PPROF/DEFT/GHOST 02/28/05 1 ; ~i"j .,-r;¡lp1-05 10687701 PPROFPS~DEFTIGHOST 08/13/04 1 Lti'l- r; ¿. MPC-42 10889141 RST 07/26/04 1 ?£4 -oß MPC-42 10621815 RST 08/07/04 1 ~/ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCANNED P,PR : 8 2005 Date Delivered: ! I _3/({¡} í 0 ç Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28.38 r ATTN: B~j/I Receiv~_ /¡Vl tVa/i/I4fÞ{,¿-'/ Schlumbel'gel' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well If~.; /7r; C-29A /~?·IJ E-25 Iqð~ð./~1 G-02A ,()j)f: he.¡ W-27A ~~Dt4 D-25A r----- jLfq-Ob(, DS 15-25A """ ~.Ø~E-39A '\ 02-16B 11,... 0 II C-25A ~ot{.:LÐ1 E-17A r(Ð1..1t6~ C-41A .I 1i- ÒW'- DS 07 -30A '-f/I'-DS 15-38A . .ifR{ 02-28A 115- if63 ~ D-11A IDt{-2.I1S DS 05-24A Job# 10715422 10715423 10715424 10670031 10854314 10715428 10715430 10928597 10928598 10928602 10928606 10715445 10715446 10928607 10928608 10928609 (Prints~ only-Job not complete) MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL SCANNED JUN 1 7 2005 Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ¿<ßf:r ¡1c¡r;,-I'70 01/24/05 NO. 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 08/20/04 1 08/21/04 1 08/23/04 1 08/24/04 1 08/27/04 1 09/11/04 1 09/13/04 1 10/02/04 1 10/03/04 1 10/30/04 1 11/24/04 1 12/09/04 1 12/11/04 1 12/11/04 1 12/16/04 1 12/22/04 1 ~ "-" --- - ~"IS coVER os c)p. ANUARY 03 2001 PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 11/25/98 RUN RECVD 96-170 NGP-TVD 96-170 NGP-MD 96-170 7912 96-170 EOW SRVY J~8 - 9112 03-13660 RIL ,X 11 00-13660 FINAL 02/19/97 FINAL 02/19/97 02/13/97 05/08/97 10-407 ~'/CO~PLETI ON DATE DAILY WELL CPS R /'~ ~/~/ TO Are dry ditch samples required? yes ~-~A~d received? Was the well cored? yes ~~ysis & description received? Are well tests required?~tyes ~eceived? ..... Well is in compliance In t~i2~ COMMENTS STATE OF ALASKA ALASKA ' AND GAS CONSERVATION C( :MISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDEE: ~' ABANDONED ~J, SERVICE [] 2. Name of Operator 7. Permi~m~r BP Exploration 8. APl Number 3. Address P. O. Box 196612 Anchoraqe Alaska 99519-6612 4. Location of well at su rface 1901' SNL, 884' WEL, SEC. 19, T11N, R14E, UPM At Top Producing Interval 949' SNL, 1124' WEL, SEC. 29, T11N, R14E, UPM At Total Depth 178' SNL, 424' EWL, Sec28, T11N, R14E 5. Elevation in feet (ind icate KB, DF, etc.) KBE = 67.65 AMSL 6. Lease Designation and Serial No. 28310 50- 029-21472-01 9. Unit or Lease Name Prudhoe Ba F Unit 0. Well Number C-29A 11. Field and Pool Prudhoe Bay Field/Prudhoe Bay Pool 1112/7/962' Date Spudded 13.12/17/96Date T.D. Reached !12/20/9614. Date Comp., Susp. or Aband. 15. Water Depth, n/afeetMsLif offsh ore II16.0neNO. of Completions 17. Total Depth (MD+TVD) li18' Plug Back,, Depth (MD+T VD)i 19. Directional Survey _ 20. Depth where SSSV set 21. Thickness of Permafro st 13660" MD 8915 TVD ! 13660 MD 8915 TVD I YES [] NO I~ 2190 feet MD approx2100' 22. Type Electric or Othe r Logs Run GR 23. CASING, LINER AND CEMENTING RECORD i SETTING DEPTH ME: i , i CASING SIZE I WT. PER FT. , GRADE ! TOP BOTTOM HOLE SIZE ! CEMENTING RECORE AMOUNT PULLED 27/8"1 6.1611 L-80 i 10575 13660 I 33/4 I 21.1 bbl I I and Bottom and 25. TUBING RECORD 24. Perforations open to Production (MD+TVD of Top interval, size and number ) 12680-12990 8937-8946 2.125" 4 spf 13070-13280 8940-8933 2. 125" 4 spf 13370-13440 8926-8919 2.125" 4 spf SIZE I DEPTH SET (MD) PACKER SET (MD) I 26. ACID, FRACTURE, CEMENT SOJEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED '27. PRODUCTION TEST Date First Production iMethod of Operation (Flow lng, gas lift, etc.) Dec 251996 I Flowinq ~ Date of Test Hours Tested PRODUCTION FOR OIL~BBL iGAS-MCF WATER-BBL ICHOKE SIZE !GAS-OIL RATIO ! ,TEST PERIOD ~ Flow Tubing iCasing Pressure [CALCULATED [OIL-BBL IGAS-MCF iWATER-BBL iOIL GRAVITY-APl (corr) Press. i 24-HOUR RATE 28. CORE DATA Briefdescriptionoflith ology, porosity, fracture s, apparentdips, andpre senceofoil, gasorwate r. Submitcor.~iFC~,# ~j~l~ Form 10-407 r_ Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS ~" 30. ~- RMATION TESTS NAME !i MEAS. DEPTI- i TRUE VERT. DEPTI- ! ; Sag ~ 10963' 8417' Shublik A i', 11005' 8446' Zone4 ii 11118' 8525' !i .~:! ii ,i Include interval tested, pressure data, all fluids GOR, and time of each pha se. recovered and gravity, 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and co rrect to the best of my k nowledge Title ST IDrillin.qT~.nhni¢.~l A.q.~i.qt~nt Date General: This form is des igned for submitting a co all types of lands and le ases in Alaska. Item 1' Classification of Service Wells: Gas injec water disposal, water sup ply for injection, observ Item 5: Indicate which el evation is used as refere given in other spaces on this form and in any atta Item 16 and 24 · If this completion), so state in in item 27. Submit a sep data pertinent to such in well is completed for sep item 16, and in item 24 s arate form for each addit terval. Item 21' Indicate whether from ground level (GL) o Item 23: Attached supplem ental records for this we lng and the location of t he cementing tool. Item 27: Method of Operat ion: Flowing, Gas Lift, R jection, Gas Injection, S hut-in, Other-explain. Item 28: If no cores take n, indicate "none". INSTRUCTIONS mplete and correct well c tion, water injection, st ation, injection for in-s nce (where not otherwise chments. arate production from mor how the producing interva ional interval to be sepa r other elevation (DF, KB II should show the detail od Pump, Hydraulic Pump, ompletion report and log on eam injection, air inject ion, salt itu combustion. shown) for depth measurem ents e than one interval (mult iple Is for only the interval reported rately produced, showing the , etc.). s of any multiple stage c ement- Submersible, Water In- Form 10-407 Daily Operations Well: C-29A Accept: 1 2/6/96 Field Prudhoe Bay Spud: 1 2/7/96 APl: 50-029-21472-01 Release: 12/20/96 Permit: 96-170 CTD Unit Nordic #1 Date Day Depth I 2~7/96 I I I 489 Finish MI DS/NORDIC #1 from F-13A. Position BOP stack above swab flange. Lower rig onto base. ACCEPT RIG AT 1200 HRS ON 12-06-96. Spot ancillary equipment and M/U hardline. N/U BOP stack. Function test rams. Perform BOP test. AOGCC waived witnessing. Displace MEOH in CT w/FSW and recover MEOH. MU BHA #1. RIH taking returns down FL. 1 2/8/9 6 2 I I ,498 RIHw/BHA#1. MillthruXNnipplein 15men using Few. Ream up and down t~ "¥* RIH and set down on whipstock at 11488 it CTD. Mill for a total of 4 hrs'Wth 1.~'~-.~.~ progress. Total of 48 stalls. POOH to check mill. Mill had normal wear, but hadn't ' ,~,~'~-~/. penetrated liner. Cut off 26' CT, rehead. Change out mill. RIH w/ BHA #2. Tag ~?~,~, TD and then mill 3.5' in 4 hours with 5 stalls until mill was out of window. previous POOH for BHA. Mill was worn in center indicating window is cut. RIH w/ BHA #3. 1 2/9/9 6 3 I I ,602 RIH w/ BHA #3. Set down wt. near flag. Flag CT and ream window area with 3.80" string reamers arid formation mill. Mill window from 11491-11493 ft bkb. Lost 180 psi while milling. No progress below 11,493' CTD. POOH. Found Drilex 2 7/8" motor shaft had failed at btm of'.radial bearings. Left shaft, string reamers and mill in hole. Freeze protect flowline while WO WL. R/U slickline and RIH with grapple to fish 1.875" OD shaft. Latch fish and POOH. MU and RIH w/BHA #4. Ream window and drill 4' of open hole based on whipstock top. Had trouble drilling off (CT memory/balled up bit). POOH to check/change BHA. 1 2/1 0/96 4 I I ,830 POOH with milling BHA. Lay out BHA-mill was bald. Cut off 60' of CT. M/U directional building BHA with Sperry MWD and 1.6 deg Drilex motor. RIH, Test Sperry MWD at 2000 ft. Cont. RIH. Test new fluid end on Pump #2. OK. Orient Tool Face to 360 deg. Drill new hole. Tie into GR marker. Directional drill 120' of build section. Precautionary backream new hole and check drag thru window, clean. Mud pump #2 that had been out of service for 30 days for repair lasted 11 hours and developed a washout. Nordic put HB&R pump on standby on location. Drill ahead building angle to 84 deg. 12/11/96 $ 12,073 Drill from 11830 - 11859 ft. Slow ROP due to directional corrections. Pump #1 started leaking. Switch to HB&R standby pump. Re-orient TF. Slow ROP. POOH for bit and BHA change. Bit was well used. Change bit, motor, orienter. RIH w/ BHA #6 pumping w/ repaired rig pump #2. Set down on top of whipstock and top of window. Log on depth to GR-add 9.3'. Pump #2 began leaking again. Switch to repaired pump #1 (HB&R back on standby on location). Precautionary ream to bottom. Drill ahead and turn to left. Drill to 11957' and lost 20 bbls mud and hole became sticky (GR confirmed that projected fault was crossed right on depth). Ream and condition hole. Drill ahead to 12060'. Backream to window. Drill ahead. 12/12/96 6 12,337 Drill from 12073-12286' where ROP slowed. POOH for BHA. Change bit, motor, BS (0.7 deg), MWD and leaking CTC. RIH w/BHA #7. Log on depth at window. RIH and had to ream fault area 11932-50'. Finish RtH to prior TD. Had trouble making hole due to sloughing shales/clays. Drilled to 12337' while backreaming each 5'. Lost pump #2 and pulled tire. Ream back to bottom with pump #1 and MWD quit. Work to regain signal while reaming hole. Hole is clean. Can't get MWD signal, POOH f/BHA. 1 2/1 3/96 7 I 2,585 Finish POOH for BHA. L/O Bit #6 and MWD. RIH with Bit #7 and new MWD tools. Ream hole from 11945-11957 ft. Finish RIH to previous TD. Orient TF and drill from 12337- 12450'. Backream to window. Ream sticky hole 11930-950'. Drill from 12450- 12517' where pump #1 began leaking (pump #2 just got back from shop, but not functional). Pull up hole while waiting to switch to HB&R pump. Precautionary ream 11900' to TD, no problem. Drill from 12517-12585'. Backream to window and tie-in to GR marker-add 8'. RIH. 12/14/96 8 13051 Finish backream trip to window. Tag previous TD at corrected 12593'. Drill from 12593-12685 FT. Short trip to 11900 ft. Clean mud pits and circ in 460 bbls of new Flopro. Orient TF and Cont Drlg from 12685-793'. Short trip to window. Drill from 12793-927'. Backream to window. Tie-in to GR. Add 12'. Drill from 12927-13051'. Short trip to window. I 2/1 5/9 6 9 1 3299 Short trip to window. Drill horiz hole from 13051 - 13200 ft. Fast drilling. Short trip to window. Check depth control with RA marker. Drill horizontal hole from 13200 - 13229 Ft. POOH for change in bent motor from 0.7 deg bend to 1.20 deg bend. Trying to get a higher rate of turn to right for geology. RIH with Bit #8, 1.20 deg bent motor, new MWD and DS constant WOB tool for a comparison test run. Tie-in to GR marker-add 8'. RIH to previous TD @ 13229'. Drill to 13299' turning to right and then begin a 100' backream. Stuck BHA at 13269'. Pump 10 bbls crude and came free. Backream to window. 12/16/96 I 0 13472 Tie-in to GR marker-add 18'. RIH. Rig mud pump #2 started leaking, switched to DS frac pump. Drilled from 13299 - 13394 ft. Saw a large inc. in deviation at 13,335 ft. from 91.6 to 99.0 deg at 13380 ft. Short trip to window. Tie-in to GR marker-add 3'. RIH and ream with TF at 180 deg with 4 down passes. Drill from 13394 ft. Found good sand at 13,378'. Drill to 13472' and MWD quit. POOH for MWD. LD WOB Equalizer tool and MWD. Perform weekly BOP test. Witness waived by AOGCC. RIH w/BHA #10. Test MWD @ 700' and wasn't pulsing. POOH for MWD. Found trash. Replace pulser. RIH w/ same BHA. Surface test MWD, OK. Continue RIH. 12/17/96 I I 13660 Continue RIH after change out MWD. Tie-in with RA tag at window and RIH to TD. Geology requested a TD of 13,675 ft. Drilled from 13472 - 13588 ft at 90 deg dev. Made short strip to window. Tie-in to RA tag-added 4'. Fix pump problems then RIH. Drill from 13588 to TD at 13660'. Pump sweep, then backream to window. Tie-in to RA tag-add 4.5'. RIH. Hole is clean. Tag TD. POOH for liner. 12/18/96 1 2 13660 POOH for liner. Circ in 1600 ft of water in 4.5" tbg. Layout drlg BHA.. Held safety meeting prior to running liner. Run 2 7/8" STL liner with 1,500 ft lbs torque to make up threads. Run 1 centralizer per jt in horiz. Hole. 2 centralizers per jt above perfs, no centralizers above 11300 ft in 7" liner. Run total of 3175' of 2 7/8" liner and running eqpt. PU 1 _" CS Hydril cementing string. Run total of 92 jts Hydril. Spaced out 2.5 ft above no go without pup joints. Made up running tools and pull/pressure tested. Made up to Hydril string and pull tested Baker running tool against liner. 12/19/96 I 3 13660 TIH w/liner. Bottom of liner 13660', top of liner 10,575'. Drop ball and release ctlrt, pick up off liner and re-tag to verify running tool released. Pump 21.1 bbl class G cement + additives. Drop dart and displace cement. Dart on seat 0.4 bbl early. Shear dart and circ at minimum rate while pulling cementing string out of liner. Circ at top of liner. After 6 hrs, compressive strengh exceed 1000 psi. Ran in and jetted liner @ 1.7 bpm-no obstructions. Layed in 25 bbl pill of clean hi-vis Flowpro. Layed dwn Baker tools and stood back 37 stds CS Hydril cmt. String. Prep to run perf guns. 12/20/96 I 4 13660 Pick up Schlumberger 2.125" HD perf guns loaded 4 spf w/25A UJ charges. Picked up 590' of loaded guns, 170' of blank guns. (perf intervals : 12680 - 12990 / 13070 - 13280 / 13370 - 13440). Pick up 1 _" CS Hydril tubing and TIH on coil. Shot guns. Pulled out. Placed 2400' water cap on well. Stood back 1-1/4". Layed down guns. All shots fired. PU inj hd& nzl. RIH to displace hole to sea water. 12/21/96 1 5 13660 RIH w/NZL and displace hole with sea wtr. Leave 2000 ft MEOH cap on well. Change out Pack-off, Clean Pits, ND BOP. RIG RELEASED @ 2100 hrs 12/20/96. Continued rig down. Prep and move off of well. Finished rig down from C-29. PAGE NO. 1 C-29AEOW.XLS ?_J3/97 12:52 AM C-29 A END OF WELL SURVEYS BP EXPLORATION ALASKA INC. END OF WELL SURVEY REPORT FOR THE C-29 A SIDETRACK JAN. 31. 1997 VERTICAL SECTION USED I · 52.90° RELATIVE TO TRUE -67.7' i i i ' I ' ' I ' .. GRID N/S AND ENV OFFSETS ARE REQUIRED FOR GEOLOGICAL WORK i ~ ~ ]. OFFSETS ARE CALCULATED TO GRID AND TRUE NORTH AS INDICATED ' : 1.25° t 1 GRID CONVERGENCE I i I PREPARED BY: i t . DRiLEX i i , ,~,~c~-,o.,,,co. t I .~,,,~.,.~,~s.,,c. I ~co. i ii 'SPERR¥SUN i i i i i i 146.0' ' ' i i 5198,3' t i 0.0' T,, 1~50o.o{ 48.2i 8719.4i 0.0f-~56.0! 0.0 0.01 -4,~1.60 5297.40 5954880.0 669~o7.4 KOP i 11559.9i 55.6i 146.0 8756.41 -2.5i-4595.0 5224.7i 12.3 0.0i 123, -4480.00 5324.60 5954841,5 669834.6 111623.11 59.9t' 127.9 8790.31' 3.21 -4633.61 5261.1i 6.8 -28.61 25.1 -4517,80 5361.80 5954803.5 669871.8 I 11656.9~ 61.41 121.1 8806.9! 12.6! -4650.31 5285.4t 4.4 -20.1! 18.1 -4533.90 5386.50 5954787.5 669896.4 11742.5t 74.4 i 117.7 8839.6i 45.1 -4688.0 5354.61 17.2-;i; 17.41 4570.10 5456.50 5954751.5 65~-:-:~6.5 !, 11770.7 ! 79.5 i 117.6 t~,6.0 ! 56.81 -4700.7. 5379.01 18.1 18.1 -4582.30 5481.10 5954739.5 C:~0~1.1 11801.01 84.3i 118.1J 8850.3i 69.5i-4714.7j 5405.5i 15.81 1.7i 15.91 -4595.70 5508.00 5954726.0 670017.9 I 11895.3] 63.5i 101.11 8856.5i 121.41 -4745.6 5493.9l -14.7 -12.4 19.2 -4624.70 5597.001 5954697.5 670106.9 I 1t925,91 81,8i ~,7i 8860,4i '~42.5i -47~,3~ ~23.9i -5.6 -14.41 15.3~ -4628.70 5627.10~ 5954693.5 670137.0 119632! 80.6t. 88.71 8888.1i 170.8 -4752.0 55~.71 -3.2 -21.41 21.4 -4629.60 5663.90 5954692.5 670173.8 , 11994.7 ! 80.0! 81.7] 8871.41 197.0, -4749.4. 5591.61 -1.9 -22.21 22.0 -4626.30 5694.801 5954696.0 670204.7 i 12029.8' '75.9' i i ' ' I 82.2 t 8876.81 228.2 -4742.6 5625.61 6.3 -16.51 17.5 -4618.80 5728.60 5954703.5 670238.5 5954718.5 5770.80 -4603.70 27.2 85.4C:~.3 8881.8 t 270.71 -4728.41 -26.0 I 12075.01 , 5668.1 8.4 j 12097.01 87.0. 62.3 8883.3 t 292.21 -4718.91 5687.9 7.3 -18.21 19.5 -4593.70 5790.40 5954728.5 67O30O.3 ' ' ' 5727.1i -1.1 -15.9{ -4569.00 5829.00 5954753.5 670338.9 12143.0~ 86.5 55.0i 6885.9 i337.9 i -4695.0 15.9 ! · i 65.3~ · , · · i -4.9 -22.9 23.3 -4553.60 5848.00 5954769.0 670357.9 12201.0} 83.9i 44.1i 8890.8i 395.51 -4657.11 5770.6 -4.2 -15.81 16.3 -4530.20 5871.80 5954792.5 670381.6 12233.8 63.01 37.91 ~4.6t 427.31 -4632.51 5792.01 -2.7 -18.9t 19.0 -4505.10 5892.60 5954817.5 670402.4 12264.6 82.6 i 30 9 8898.41 456.3 -4607.3 i 5809.2 -1.3 -22.7 i 22.6 -4479.50 5909.20 5954843.0 670419,1 2910 5826,7 4.2 6.8 -4448.70 5926.10 5954874.0 670436.0 12375.91 83.2i 23.7t 8910.~i 555.7, -4508.7 5859.31 -4.5i -3.21 5.61 -4379.90 5957.205954942.5670467.11 · 12399.0 i82.9 i 22.5 t 8912.9 ! 575.6 i -4487.61 5868.3 i -1.3 -5.2 5.3 i -4358.60 5965.70 5954964.0 670475.6 82.9t 8915.6i 594.11 -4467.7 -2.8i 2.7! -4338.50 5973.40 5954984.0~ 670,~3.31 -4449.8t 5883.31 3.1 -7.81 8 3 -4320.50 5979.90 5955002.0 670489.8 · 12440.01 83.5i i 8917.9J 610.4~ . I ! i , ~ ~ -4417.0 i 5895.0 i 2.9 1 i 5.4' , -4.6 -4287.40 5990.90 5955035.0 670500.8 , 12504.01 84.8i 16.1 ! 8924.2 i 663.0 -4389.5 5903.6i 1.0~ 9.3] -4259.70 5998.90 5955062.5 670508.8 12576.9t 86.61 19.01 8929.8 ] 721.5! -4319.8i 5924.31 3.1 10.4 4.8 10.8 -4189.60 6018.10 5955132.5 670528.0 I 12606.0 85.9~ 20.2i 8931.7i 745.8i -4292.5i 5934.1i -2.4 4.11 -4162.00 6027.20 5955160.0 670537.1 I , 5.9 12¢::~.3 64.4i 893~.4! 795.2i -4238.3i 5955.1i -3.7 4.5 -4107.40 6047.00 5955214.5 670556.9 12~.01 1~l.2 ~ 8939.6! 822.3t -4209.1 i 5~7.0t -0.6 -1.9 2.0 -4077.90 6058.30~ 5055244.0 6705~.2 I 12735.0t 85.71 8943.01 855.8i -4173.2 5901.0i 3.8 2.01 -4041.70 6072.30 5955280.0 670582.2 ! 12756.0 t 86.6 i 23.51 8944.4 874.0' -4153.9 ! 5990.0 4.3 2.4[ 4.9' -4022.30 6080.10 5955299.5 670590.0 PAGE NO. 2 C-29AEOW~J_S 2/3/97 12:52 AM C-29 A END OF WELL SURVEYS COMMENTS ] MDI Inc.{ Dir SS DEPTHI VSl TRUEI TRUEI BuildI Turn! Doglegi GRID GRIDI ASP Y ASP X { 12788.01 88.81 24.4i 8945.7! 902.0{-4124,7i 6003.0i 6.91 2.81 7.41 -3992.80 6092.40 5955329.0 670602.3 i 12831.0' 89.5i 24.4, 8946.41 939.7 -4085.5 6020.7 1.6l 0.0' 1.6 -3953.20 6109.30 5955368.5 670619.2 12875.0 90.2 26,0 8946.51 978.7t -4045.7 6039.4 1.6 3.61 4.0 -3913.00 6127.10 5955408.5 670637.0 i 12894.0i 90.5i 26.6 8946.4, 995.7i -4028.6, 6047.8j 1.6 3.6j 4.0 -3895.80 6135.20 5955425.5 670645.1 ! ' ' i 5.4 5.4 670657.9 5955452.5 -3868.70 6148.00 12924.0i 92.1i 26.5l 8945.71 1022.5l -4001.8 6061.2t -0.6 12987.0 91.7I' 29.9 8943.5i 1079.5 ! -3946.1i 6090.61 -13.6.1 -2.08'1 ' 2.08'2 -3812.406176.10 5955509.0 670686.0 , 13017.0i 91.7i 29.3 ! 8942.6 1107.1 -3920.0 j 6105.3 i 0.0 -3785.90 6190.30 5955535.5 670700.2 3O.2] 13045.0i 92.7l 8941.5t 132.81 6203.70 5955560.0 670713.5 13074.0! 93.5i 31.1 8940.0 1159.6! -3870.8, 6134.0, 2.8t . . -3736.101 6217.90 5955585.0 670727.7 i 32.0 1 8938.4 i i i _18 1°'°i 9.9' I 6231 '8°I 13101.8, 93.01 1185.4, -3847.11 6170.9{ -0:5' -3678.40 6253.505955643.0 670763.4 I- , I 6148.51 3.2 3.7 -3712.10 5955609.0 670741.7 i 13142.0i 92.81 :36.0 i 8936.4 ~ 1223.4 j -3813.8i i 13177.9 91.4i 38.31 8935.1i 1257.9i -3785.2i 6192.5i -3.91 6.4 7.5' -3649.30 6274.50 5955672.0 670784.4 i 13206.0! 91.1i' 39.9 8934..4i 1285.21 -3763.41 6210.2 -1.1 5.7 5.8 -3627.10 6291.705955694.0 670801.6 i 13240.0 90.8! 43.7 8933.9i 1318.5' -3738.01 6232.8i -0.91 11.2 i 11.21 -3601.20~ 6313.805955720.0 670823.6 I 13270.0! 9091 i 46.0 8933.4! 1348.2! -3716.8, 6254 O i 0.3 7.7 7.7 -3579.50 6334.50 5955741.5 670844.3 i :Oi 8933.01 1372.1i -3700.5i 6271.6i 0.4 '10.4 -3562.80 ! 13294.0 91 48.5 10.41 6351.70 5955758.0 67O861.6 13326.0 91.6i 50.1 8932.3i 1404.0,-3679.6i 6295.81 1.9; 5.0i -3541.40 6375.50 5955779.5 670885.3 ! 13349.0i 96,9i 54.4 8930.6i 1426,9i-3665.5! 6313.9i230; 18.71 29.6! -3527.00 6393.30 5955794.0 670903.1 t 13414.0 94.9i 64.5l 8922.2j 1490.9' -3633.0i 6369.4! -12.1t 14.4i · i -3493.20 6448.10 5955828.0 670957.9 i 1523.2 i I 13447.0{ 93.71 66.062'7 8919.7 -3618.31 6398.91 -3.61 -5.5' 6.5 -3477.90 6477.20 5955843.51 670987.1 13487.0i 93.3i 89173 1562.3, -36010 6434.9i -1.0 8.2 8.3 -3459.80 6512.80 5955861.5! 671022.6 68.7' 0.0 13517.0i 90.31 71.4 8916.31 1591.4i -3589.41 6462.5i 9.0 13.4 -3447.60 6540.20 5955873.5 671050.0 i 13547.0l 90.51 8916.1J 1620.01 .-3579.2i 6490.7 0.71 9.0 9.0 -3436.80 6568.20 5955884.5 671077.9 i 13571.0i 91.5 73.8 8915.71 1642.6 35720j 6513.61 4.2 1001 10.8 -3429.10 6590.90 5955892.0 671100.7 :3563'5i 12 ! 13606.0{ 90.2i 78.2, 8915.2! 1674.81 6547.51 -3.7 . 13.1 -3419.80 6824.60 5955901.0 671134.4 I -3412.40 6659.90 5955908.5 671169.7 TD ! 13642.0 89.8 80.7 89152i 1707.0 -3556:91 6582.9i -1.1 6,9 7.07'0' 13660.0 ~ 89.6 81.9 8915.3i 1722.9 -3554.11 6600.71 -1.1 i 6,9 -3409.30 6677.601 5955911.5 671187.4 THESE suRVEY S ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. I BIMOHADIPOTRO i ' ' j i i DISTRICT MANAGER - DRILEX SYSTEMS, INC. i II OF:III--I--lNG S E I:! ~./I I~~::: c~ WELL LOG TRANSMITF~ To: State of Alaska February 19, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 / \qO MWD Formation Evaluation Logs C-29A, AK-MW-60193 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 C-29A: 2" x 5" MD Gamma Ray Logs: 50-029-21472-01 2" x 5" TVD Gamma Ray Logs: 50-029-21472-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company r'l !:t I I_1_ I I~] G S I:: F:! ~./I r' I:: S WELL LOG TRANSMITTAL To: State of Alaska February 19, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor .. / \"1, C),~ 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - C-29A, AK-MW-60193 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-21472-01. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 10/31/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10532 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape MPU A-02A PERFORATION RECORD 961 01 8 I I ..... MPU F-02 PERFORATION RECORD 9 61 01 8 I 1 MPU F-02 GRAVEL PACK LOG 9 61 02 3 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: tt0V 0 8 1996 Alaska Oil & Gas Co~s. Om ni'~i~ic~', Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received~'~~--~ TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 25, 1996 Ted Stagg Coiled Tubing Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Prudhoe Bay Unit C-29A BP Exploration (Alaska), Inc. Permit No. 96-170 Sur. Loc. 1901'SNL, 884'WEL, Sec. 19, T11N, R14E, UM Btmnhole Loc. 940'SNL, 169'WEL, Sec. 29, T11N, R14E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to ~vitness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 fwnr~ i~'Drill I-'lRedrill Jlb Typeofwell r-lExploratory I-IStratigraphic Test I~'De'~elopment Oil .!_._a. _T_yp__e_0]__].]]]___E]_____R__e_7__E___n_!__.w___._E]___D_e__e__P_e__n]_ ..... ] ......................... ._E]___Se_r__v__ic__e___ __D___Devel0Pment_ Gas ___.[] __Singl_e____z_o_ne .......... []_Mu!!ip!e Zone __ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Explor~atio._n (.A_la.?_ka! I.n5. _ ........................... KBE=67.65 . Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028310 4. Location of well at surface 7. Unit or Property Name' 11. Typ~ B~nd (See 20 AAC'25.025) 1901' SNL, 884' WEL, Se¢.19, T11N, R14E, UPM Prudhoe Bay Unit At top of productive interval "~;---W-~ii-'N-~-~-6~r- .......... Number 2S 100302630-277 949'SNL, 1124'WEL, Sec.29, T11N,R14E, UPM 0-29A Attotal depth '9. Approximate spud date Amount $200,000.00 940' SNL, 169'WEL, Sec.29, T11 N, R14E, UPM Nov. 1,1 996 ;12. Distance to nearest property line! 13. Dista'~'~"e to nearest well .... 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028309 @169'! No close approach 2560 13302 MD 8940TVD il 6. To be completed for deviated wells 17. AnticiPated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11546/8750 Maximum Hole Angle 82 o Maximum surface 2260 psig, At total depth (TVD) 8800'ss-3350 psig.. 18. Casing Program Specifications Setting Depth Size To Bottom Quantit of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) _____3_3__/__4'_'_ ........ _2_ 7___/8'i___ ! ___6._1_ 6~ ....... _L__-_80_ ........... _S_T___-L ......... .2__73__.7_'_ ..... _1___0_5_6_5- ...... _8__0_6__3. ....... .!73__0_2 ...... _89__40____ _8_5 C_U'_!_t_:' _ ........... ] 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary ORIGINAL Total depth: measured 12025 feet Plugs (measured) true vertical BKB 9124 feet Effective depth: measured 11945 feet Junk (measured) Fill at 11945'MD(10/89) true vertical BKB 9073 feet Casing Length Size Cemented MD TVD Structural BKB Conductor 110 20X30 8 c.y 139 139 Surface 3056 13 3/8 4252 c.f. 3085 2783 Intermediate 10916 9 5/8 435 c.f. 10945 8421 Production Liner 1440 7 365 c.f. 10580-12020 8155-9135 Perforation depth: measured 11560'-11570', 11589'-11599', 11844'-11897' Sqzd:11796'-11826' true vertical 8942'-8975'ss 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Ddlling Fluid Program ri Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ContaCt Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 -2ii i hereby certify th~,t~e, foregoing is true and correct to the best of my knowledge ................ Title Coiled Tubing Drilling Engineer Date 74~ P,/_~__~ S igned~_____ __~ ...................................... -C~-m-~-is-;-,0-~----~ ~-;----(~-I~,-~ ..................................................................... /~ .......................... /¢~'_/,..,~<E~ 50- ~ Z'~--" .¢__._ ,/ ~ .~.2.--' ~ / l fO _;;~,,~_o~ for other requirements Conditions of Approval: Samples Required' ' [] '~'es. '~ No Mud Log Required [] y~S .~ No Hydrogen Sulfide Measures /~Yes [] No DirectionaISurvey Required ,~Yes [] No Required Working Pressure for' BOPE ©2M; F13M; [] 5M; [] 10M; [] 15M ~: '35'00 Other: Original Signed By by order of ..% ~._Ap..proved By ,-~.,,,,4, ,~, ,..~._^.~_., Commissioner the commission Date (.f~- c~'~ .. Form 10-401 Rev. 12-01-85 Submit In Triplicate C-29A Proposed Sidetrack Program Current Status Well C-29 is currently shut-in due to high GOR. Tubing and liner have been drifted, pressure tested and calipered in preparation for sidetracking. Abandon perfs, mill window from cement whipstock and drill sidetrack: (planned for Nov. 1 -Nov. 15, 1996) Neat and fiber cement will be layed from PBTD, squeezed and dressed off to approximately 11,500' MD to abandon existing perforations and provide competent cement to whipstock from. A 3 3/4" pilot hole will be drilled and a window milled at approximately 11,536'MD. Drilling will proceed to 13,302' MD per the attached directional plan. An MWD will be used for directional control and surveys will be taken every 30 ft. No gyro will be run. Drilling Fluid Program: Solids Free FIo-Pro (8.8 ppg to provide approx. 675 psi overbalance) Logging Program: A Gamma Ray log will be used in geosteering while drilling and will be run over the entire drilled section. Induction and porosity logs will be coil conveyed at TD. Liner / Completion Program: A 2 7/8", ST-L, L-80 liner will be run to TD and cemented. A PBR at the top of the liner will be located in the existing 4 1/2" tubing tail at approximately 10,565' MD. Well Control: The BOP schematic for drilling and completion operations is attached.. TREE: WELLHEAD: ACTUATOR: 4" ClW ~c '~O-29A Proposed Side'~'~ck AXELSON KB. ELEV = 67.65' BF. ELEV = 38.72' SSSV LANDING NIPPLE I (OTIS DBE)(3.813" ID) 2275' 13-3/8", 72#/ft, L-80, BTRS 13085'1 FOC m KOP: 500' MAX ANGLE: 51 ° @ 11,900' 4 1/2", 12.6#/ft, L-80, AB/MOD BTRS TUBING (IPC) TUBING ID: 3.958" CAPACITY: .01522 BBL/FT TOP OF I 10,S80'I 7" LINER 9-5/8", 47#/ft, L-80, BTRS I10,945' I ~ GAS LIFT MANDRELS 'OTIS LBD w/ RA LATCH) N° MD(BKB) TVDss DEV 7 3318' 2874' 43° 6 5909' 4759' 46° 5 7688' 5975' 46° 4 8822' 6761' 44° 3 9794' 7469' 41 ° 2 10,217' 7794' 38° 1 10,363' 7909' 39° 41/2" SLIDING SLEEVE I OTIS "XA" (3.813"1D) 10,432' TIW PBR SEAL ASSY. 9-5/8" TIW PACKER ( HBBP)(4.750"1D) 0,492'I 1 lO,SO7'1 4 1/2",12.6#/ft, L-80 TAILPIPE 4 1/2 .... X" NIPPLE (OTIS) ( 3.813" ID) 4 1/2 .... XN" NIPPLE (OTIS) ( 3.725" ID) 4 1/2" TBG TAIL (BAKER SOS) (ELMD) 110,547'1 1 lO,5So'1 I 10,613'1 Proposed top of whipstock cement after dressing off -- 11,500' MD Proposed window = 11536' MD PERFORATION SUMMARY REF LOG: DA- BHCA - 2-8-86 33/~"I 4I 33/8"I 4 I 31/8"j 4 I INTERVAL 11,560 - 11,570' 11,589' - 11599' OPEN/SQZ'D OPEN/9-7-90 OPEN 8/26/94 11,796 - 11,826' SQZD/2-4-89 11,844 - 11,897' OPEN/3-20-89 PBTD ~ 7", 26#/ft, L-80, IJ4S 112,020'1' %%%%% 3.75" open hole ITREE: WELLHEAD: ACTUATOR: 4" ClW ~c ~"C-29A Proposed Com AXELSON ' 'etion KB. ELEV = 67.65' BF. ELEV = 38.72' SSSV LANDING NIPPLE (OTIS DBE)(3.813" ID) I 2275' I 13-3/8", 72#/ft, L-80, BTRS I 3085'1 FOC -- KOP: 500' MAX ANGLE: 51 © @ 11,900' 4 1/2", 12.6#/ft, L-80, AB/MOD BTRS TUBING (lPG) TUBING ID: 3.958" CAPACITY: .01522 BBL/FT TOP OF I 10,580'I 7" LINER ~,-~/~", 4.'~#/ft, L-80, BTRS 11o,945'1 2.7/8" ST-L Cemented Liner with proposed top of liner cmt. = 11,300'MD GAS LIFT MANDRELS OTIS LBD w/ RA LATCH) N° MD(BKB) TVDss DEV 7 3318' 2874' 43© 6 5909' 4759' 46© 5 7688' 5975' 46© 4 8822' 6761' 44© 3 9794' 7469' 41 o 2 10,217' 7794' 38© 1 10,363' 7909' 39© 41/2" SLIDING SLEEVE I OTIS "XA" (3.813"1D) 10,432' TIW PBR SEAL ASSY. 9-5/8" TIW PACKER ( HBBP)(4.750"1D) 110,492'J [ 10,S07'I 4 1/2",12.6#/ft, L-80 TAILPIPE 4 1/2 .... X" NIPPLE (OTIS) ( 3.813" ID) 4 1/2 .... XN" NIPPLE (OTIS) ( 3.725" ID) 4 1/2" TBG TAIL (BAKER SOS) (ELMD) I 10,547' 110,580' I 10,613 I 0,s22'1 Proposed top of whipstock cement after dressing off -- 11,500' MD Proposed window -- 11536' MD PERFORATION SUMMARY REF LOG: DA-BHCA- 2-8-86 33/8"I 4111,560-11,570' OPEN/9-7-90 ~ ~/~'"1 ~ I 11,589'- 11599' OPEN 8/26/94 31/8"I 4 J11,796-11,826' SQZD/2-4-89 2 7/8"1 4 111,844- 11,897' OPEN/3-20-89 PBTD ~ 7", 26#~t, L-80, IJ4S I 12,020'1 %%%%% C-29 4OO 8650 87OO 8750 8800 8850 8900 8950 9000 9O5O 9100 600 800 1,000 Vertical Section Path Distance (Feet) 1,200 1,400 1,600 1,800 2,000 2,200 2,400 2,600 Angle @ K.O.= 49 deg M D: 11546 DL I= 21 deg/100 FAULT FAULT 14N 14N 13N 133O2 TD Tot Drld:1756 ft Marker Depths 27P eOrig Wellbore 8,714Jrt TVD O[ O[ff TVD O[ O[ff TVD O[ Olft TVD I Kick Off 8,75Ol[t TVD I 11r5461ff MD Deprtr @KO 6r961 ft MD KO Pt 11,546I MD New Hole 1756I I Total MD 13,302I TVD TD 8,9401 Build Fit de.q/1 O0 MD (ft) 0.0 240 0.0 450 6.0 125 0.0 250 6.0 15 0.0 450 0.0 1 Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 1,756 Drawn: 9/1 7/96 17:27 Plan Name: Case 1 -3,200 T -3,400 -3,600 ~ -3,800 -4,000 -4,200 -4,400 -4,600 -4,800 I -5,000 C-29 Plan 5,400 5,600 5,800 6,000 6,200 6,400 6,600 6,800 7,000 7,200 X distance from Sfc Loc Well Name C-29 ] Distance 7,400 ft Az 1 24 deq I NEW HOLE Kick Off TD State Plane Surface Loc E/W (X) N/S I 670~6121 5~955'~ 1371 664,509 5,959,322 I Az Ch¢ MD (fl:) -21.0 240 -~.0 450 0.0 125 6.0 250 0.0 15 -6.0 450 0.0 I Curve 1 Curve 2 Curve 3 Curve 4 Curve 5 Curve 6 Curve 7 Curve 8 1,756 Drawn: 9/1 7/96 17:27 Plan Name: Case 1 CT Drilling BOP 2 3/8" CT 110,000 psil Pack-Off J Lubricat°r~ I 2" 36" 22.5" 1 8" 38" 7 1/16" Annular I Pipe/Slip 2 3/8" P,pe ~ ~ 2 7/8" SWAB OR MASTE~ VALVE 9/5/96 DOWELUNORDIC RIG PIPING ~KER -~ , CHOKE OUT. DE RLL STACK Ct3~1ENT UNE LEGEND OUTSIDE CENTRIFUGE SETTLING VCLUME SUCTION MIXING HOPPER TR~P TANK OUTSIDE POF~OFFS jj~ HiGH PSI LINE ~ LOWF~ CHARGE ~ LOWPSI SUCTION STATE OF ALASKA ALASK/ ILAND GAS CONSERVATION CC 41SSION APPLICATION FOR SUNDRY APPHOVAL 1. Type of Request: [] Abandon F'3 Suspend [] Plugging [] Time Extension [] Perforate Eq Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other ~ Change Approved Program ~ Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator 151 Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska)Inc. t (~ Development KBE=67.65 [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P. O. Box 196612, Anchorage, Alaska 99519-6612 F-IService 4. Location of well at surface 8. Well Number C-29 1901' SNL, 884' WEL, Sec.19, T11N, R14E, UPM At top of productive interval 949'SNL, 1124'WEL, Sec.29, T11N,R14E, UPM At effective depth 1460' SNL, 775'WEL, Sec.29, T11N, R14E, UPM At total depth 1512' SNL, 741'WEL, Sec.29, T11N, R14E, UPI~t 9. Permit Number 85-256 10. APl Number 50-029-21472 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 12025 feet Plugs (measured) BKB 9124 feet 11945 feet Junk (measured) BKB 9073 feet Fill at 11945'MD(10/89) Length Size Cemented Structural Conductor 110 20X30 8c.y Surface 3056 13 3/8 4252 c.f. Intermediate 10916 9 5/8 435 c.f. Production Liner 1440 7 365 c.f. D TVD BKB 139 139 3085 2783 10945 8421 10580-12020 8155-9135 Perforation depth: measured 11560'-11570', 11589'-11599', 11844'-11897' true vertical 8942'-8975'ss Sqzd:11796'-11826' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10507 with 4 1/2" tailpipe to 10613 Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 10507'; 4 1/2" SSSV at 2275' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation Nov 1, 1996 16. If proposal was verbally approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Name of approver Date approve¢ Contact Engineer Name/Number: Ted Stagg 564-4694 Prepared By Name/Number: Theresa Mills 564-5894 17. I hereby certify that th..e foregoing is true and correct to the best of my knowledge Signed ~~ ~ Title Coiled Tubing Drilling Engineer [ ' '"¢ Commission Use Only Conditions of Approval: Notify Commission so representative may witness i Approval No....~.. Plug integrity __ BOP Test __ Location clearance __ - --"~ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commission ("~,.~ ~ Commissioner Date Form 10-403 Rev. 06/15/88 .Submit In Triplicate WELL PERMIT CHECKLIST ,,, :IELD & POOL ~ .C//(~,/ ¢',,/;) INIT CLASS ~.DMINlSTRATION "ENGINEERING G~:oiLOGy ...... WELL NAME/:::)/~/_.,,/ ~~~-~-~/~ PROGRAM: exp E] dev~ reddl.~ serv a wellborn seg [] ann. disposal para mq [] GEOLAF~EA ~'?r"5 UNIT#" ,//~/'~,.~'c::, ON/OFFSHORE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number ................ 4. Well located in a defined pool ................. Y Y Y Y Well located proper distance from dflg unit boundary .... Y Well located proper disi~mce from o~her we~s ......... Y Sufficient acreage available in drilling unit. .......... If deviated, is weilbore plat included .............. .~. Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ....... IY Permit can be issued wilhout administmJNe approval ..... Can permit be approved before 15-day wail ......... 6. 7. 8. 9. 10. 11. 12. 13. 14. Conductor string provided ................... Y N '~ ~ 15. Surface casing protects all known USDWs .......... Y N ~ L,,._ 16. CMT vol adequate to circulate on conductor & surf csg .... Y N 17. CMT vol adequate to ~-in long s~ng to surf csg ...... .~ N 18. CMT will cover all known productive horizons ......... ~ N 19. Casing designs adequate for C, T, B & permafrost. ..... L~ N 20. Adequate tankage or reserve pit. ............... ~ N 21. If a re-drill, has a 10.403 for abndnmnt been approved .... ,~Y N i t~ ¢ {/'~'~ 22. Adequate wellbore separation proposed ........... ~ .. L/ 23. If diverter required, is it adequate ................ '~/,"-h~'~~. 24. Ddlling fluid program schematic & equip list adequate .... .(~ N 25. BOPEs adequate ........................ (..Y2 N 26. BOPE press rating adequate; test to '~2~ psig. ~, N 27. Choke manifold complies w/APl RP-53 (May 84) ...... (~.,N ~-~J~ ¢ 28. Work will occur wibhout opem~on shutdown .......... ~,~N, 29. Is presence of H2S gas probable ............... U.~'~ 31. Data presented on potential overpressure zones ........ 32. Seismic analysis of shallow gas zones ............. /Y/N N 33. Seabed condition survey (if off-shore) ........... /. Y N 34. Contact name/phone for weekly progress repoT ,.....//.. Y Jexploratory ono,J REMARKS GEOLOGY: ENGINEERING: COMMISSION: DWJ JDH ~ JDN TAB~;~'-~. Comments/Instructions: ~OWA~. A.-~CORMS',chekr~t rev 4/96 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 information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. CN : BP EXPLORATION (ALASKA) WN : C-29A FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA : ~~)~'~'~ ' .. 2 Curves: /~ Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 R0P MWD 68 1 FPHR 4 4 90 310 01~ 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 13700.000000 Tape File End Depth = 13400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24316 datums Tape Subfile: 8 71 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 8 'is t~pe: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13441.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERS ION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 13636.0 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 6. 17-DEC-96 MSC VER 1.32 DEP 2.042, SPC 5.74 MEMORY 13660.0 13472.0 13660.0 0 89.6 93.7 TOOL NUMBER NGP 46 3.750 11489.0 FL0- PRO 8.80 .0 8.5 42000 5.2 .000 · 000 .000 .000 .0 162.7 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : C-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID- F 2 Curves- Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 13500.000000 Tape File End Depth = 13200.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code- 68 5712 datums Tape Subfile: 7 71 records... Minimum record length- 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 'is t~pe- LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13210.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13439.0 15-DEC-96 MSC VER 1.32 DEP 2.042, SPC 5.74 MEMORY 13472.0 13229.0 13472.0 0 90.8 99.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 320 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 11489.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATLTRE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATI/RE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO- PRO 8.80 .0 8.5 43000 5.2 .000 .000 .000 .000 .0 162.7 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 5. CN WN FN COUN STAT BP EXPLORATION (ALASKA) C-29A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID- F 2 Curves- Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 24 Tape File Start Depth = 13300.000000 Tape File End Depth = 12300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary- Rep Code. 68 22512 datums Tape Subfile. 6 87 records... Minimum record length- 62 bytes Maximum record length- 1014 bytes Tape Subfile 6 is type- LIS FILE HEADER FILE NITMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12311.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13210.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 14-DEC-96 MSC VER 1.32 DEP 2.042, SPC 5.74 MEMORY 13229.0 12337.0 13229.0 0 82.9 93.5 TOOL NUMBER NGP 46 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 11489.0 BOREHOLE CONDITIONS MI/D TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATLrRE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO-PRO 8.80 .0 8.5 36000 6.6 .000 .000 .000 .000 .0 162.7 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 4. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : C-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID- F 2 Curves- Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records. Tape File Start Depth = 12400.000000 Tape File End Depth = 12200.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary- Rep Code- 68 3908 datums Tape Subfile- 5 68 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12266.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERS ION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12318.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MI/D CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 3. 12-DEC-96 MSC VER 1.32 DEP 2.042, SPC 5.74 MEMORY 12337.0 12286.0 12337.0 0 84.1 84.1 TOOL NUMBER NGP 320 3.750 11489.0 FLO- PRO 8.80 .0 9.0 36000 6.2 .000 .000 .000 .000 .0 154.4 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : C-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves- Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records- 12 Tape File Start Depth = 12300.000000 Tape File End Depth = 11800.000000 Tape File Level Spacing = 0.500000 Tape File'Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code. 68 16508 datums Tape Subfile. 4 75 records... Minimum record length- 62 bytes Maximum record length- 1014 bytes Tape Subfile 4 is type- LIS FILE HEADER FILE NITMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11838.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12267.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ Il-DEC-96 MSC VER 1.32 DEP 2.042, SPC 5.74 MEMORY 12286.0 11865.0 12286.0 0 80.0 88.0 TOOL NUMBER NGP 46 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11489.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO- PRO 8.80 .0 8.5 36500 6.0 .000 .000 .000 .000 .0 154.4 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 2. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : C-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID- F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 R0P MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records- 11 Tape File Start Depth = 11900.000000 Tape File End Depth = 11450.000000 Tape File Level Spacing = 0.500000 Tape File' Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary- Rep Code- 68 2704 datums Tape Subfile: 3 74 records... Minimum record length- 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type- LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11476.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERS ION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11839.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 10-DEC-96 MSC VER 1.32 DEP 2.042, SPC 5.74 MEMORY 11865.0 11503.0 11865.0 0 50.8 86.5 TOOL NUMBER NGP 320 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 11489.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPEP~ASTrRE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLO- PRO 8.90 .0 9.5 39500 6.8 .000 .000 .000 .000 .0 154.4 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STAArDOFF (IN) : EWR FREQUENCY (HZ) .0 0 REMARKS: MWD RUN 1. Tape File Start Depth = 13700.000000 Tape File End Depth = 11450.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code- 68 13504 datums Tape Subfile: 2 142 records... Minimum record length- Maximum record length: 62 bytes 1014 bytes FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11476.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: STOP DEPTH 13636.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 11503.0 11865.0 11865.0 12286.0 12286.0 12337.0 12337.0 13229.0 13229.0 13472.0 13472.0 13660.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : C-29A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 54 Tape Subfile 9 is type: LIS 97/ 2/11 0i **** REEL TRAILER **** 97/ 2/11 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 11 FEB 97 10:42a Elapsed execution time = 1.92 seconds. SYSTEM RETURN CODE = 0 NO DEPTH SHIFTS WERE APPLIED.
